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Home My WebLink About185-1057. 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 A-34A OA Sealant Squeeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-105 50-029-21339-01-00 341J ADL 0028286 9382 Conductor Surface Intermediate Production Liner 9234 80 2651 8744 880 8923 20" x 30" 13-3/8" 9-5/8" 7" 8776 32 - 112 31 - 2684 29 - 8773 8502 - 9382 32 - 112 31 - 2684 29 - 8626 8356 - 9234 None 2670 4760 5410 8923 5380 6870 7240 8898 - 8923 5-1/2" 17# x 4-1/2" 12.6# 13cr80 x 13cr80, L80 27 - 85338751 - 8776 Structural Date: Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 10/8/2025 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 4-1/2" BOT Packer 5-1/2" Baker S3 Packer 4-1/2" Baker S3 Packer 8435, 8290 8174, 8031 8296, 8152 By Grace Christianson at 3:26 pm, Sep 25, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.24 16:52:34 - 08'00' Torin Roschinger (4662) 325-580 A.Dewhurst 26SEP25JJL 10/8/25 10-404 JLC 10/8/2025 10/08/25 OA Sealant Squeeze Well: A-34A PTD: 185-105 API: 50-029-21339-01 Well Name:A-34A Permit to Drill Number:185-105 Well Type PAL API Number:50-029-21339-01 Job Scope:OA Sealant Squeeze Reg.Approval Reqd?Yes Current Status:Operable, Online Date Reg. Approval Recvd: Estimated Start Date:10/8/25 Estimated Duration:2 day Regulatory Contact:Abbie Barker 907-564-4915 First Call Engineer:Oliver Sternicki 907-564-4891 Second Call Engineer:Leif Knatterud 907-564-4667 Current Bottom Hole Pressure:3236 psi @ 8800 TVD Max. Anticipated Surface Pressure:22356 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:1800 psi Min ID:3.725 4.5 XN Nipple @ 8506 MD Max Angle:16 deg @ 6500 MD Top of Sag:8800 MD Brief Well Summary: A-34A is a gas lifted well that has had a history of IAxOA communication. A 2008 RWO replaced the upper production casing and cemented the OA to surface from 2060 MD. OA repressurization continued and the OA was squeezed with cement on 6/16/16. The OA was later squeezed with wellock on 8/14/17 and 7/4/18. Most recent CMIT-TxIA and MIT-T passed on 6/11/18. Well status changed to under evaluation on 9/23/25 due to unmanageable IAxOA repressurization rate. Current Status: A-34A is currently Under evaluation and online. Scope of Work: OA squeeze with WellLock (or similar) to repair OA repressurization. Procedure: 1.Fullbore/ SL Load tubing and IA with 550 bbls crude. Set PX plug at 8217 MD. MIT-T, CMIT-TxIA to 2500 psi max applied pressure, 2250 psi target pressure. Sundry Work 2.Valve Shop Nipple down OA gate valve, nipple up OA integral. 3.DHD Wellock (or similar) OA squeeze. Max pressure= 2500 psi. 4.SL Pull plug. 5.DHD POP, monitor for OA repressurization, resqueeze if necessary. 6.Valve Shop Nipple down OA integral, nipple up OA gate valve. OA Sealant Squeeze Well: A-34A PTD: 185-105 API: 50-029-21339-01 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 A-34A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-105 50-029-21339-01-00 9382 Conductor Surface Intermediate Production Liner 9234 80 2651 8744 880 8923 20" x 30" 13-3/8" 9-5/8" 7" 8776 32 - 112 31 - 2684 29 - 8773 8502 - 9382 32 - 112 31 - 2684 29 - 8626 8356 - 9234 None 2670 4760 5410 8923 5380 6870 7240 8898 - 8923 5-1/2" 17# x 4-1/2" 12.6# 13cr80 x 13cr80, L80 27 - 8533 8751 - 8776 Structural 5-1/2" Baker S3 Packer - 8174, 8031 No SSSV Installed 8174, 8296, 8435 8031, 8152, 8290 Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com 907-564-4891 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 0028286 27 - 8387 IC Packoff test void at Surface Pump 2.2-cups of greenstick in two treatments. Final pressure = 0-psi. 877 80 1528 496 12614 10274 1900 1700 440 340 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer - 8296, 8152 4-1/2" BOT Packer - 8435, 8290 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Gavin Gluyas at 3:11 pm, Sep 22, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.22 13:40:45 - 08'00' Torin Roschinger (4662) J.Lau 11/6/25 RBDMS JSB 092525 ACTIVITY DATE SUMMARY 8/25/2025 T/I/O = 440/1880/1240. Temp = 134°. Greenstick IC void (eval TxIA). ALP = 1880 psi, online. OA cemented to surface. Bled OAP to 0 psi and held open bleed for duration of job. RU Packing gun to IC void and pumped 1 & 2/3 guns of liquid greenstick. SI OA and monitored for 30 min. OAP increased 20 psi. Bled to 0 psi. Final WHPs = 440/1880/0. **Subsidence noted**- Tree cap gauge 1/4" from wellhouse roof hatch. Well house backing sitting on flow line. Flow line behind well house unsupported. Flutes out of conductor 9 1/2" measured from top lip of conductor to top of flute @ 12:00 side. Ladder for swab platform no longer touching floor. Ops & subsidence crew notified. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 9/7/2025 T/I/O = 420/1870/140. Temp = 170°. Bleed OAP to 0 psi (Eval IAxOA). ALP = 1900 psi. Bled OAP from 140 psi to 0 psi in seconds (Gas). Monitored for 30 min. OAP increased 60 psi. Hold open bleed on OA for 1 hr. FWHP's = 420/1870/0 SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:30 9/14/2025 T/I/O = 420/1880/330. Temp = 160°. Re-Treat IC test void w/ Semi Liquid Greenstick. ALP = 1920 psi, online. OA cemented to surface. Bled OAP to 0 psi in <1 min (gas) and held open bleed for duration of job. RU Packing gun to IC void and pumped 1/4 gun of Semi Liquid Greenstick in 4 hrs. SI OA and monitored for 30 min. OAP increased 10 psi. Final WHPs = 420/1880/10 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:00 Daily Report of Well Operations PBU A-34A 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 A-34A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-105 50-029-21339-01-00 9382 Conductor Surface Intermediate Production Liner 9234 80 2651 8744 880 8923 20" x 30" 13-3/8" 9-5/8" 7" 8776 32 - 112 31 - 2684 29 - 8773 8502 - 9382 32 - 112 31 - 2684 29 - 8626 8356 - 9234 None 2670 4760 5410 8923 5380 6870 7240 8898 - 8923 5-1/2" 17# x 4-1/2" 12.6# 13cr80 x 13cr80, L80 27 - 8533 8751 - 8776 Structural 5-1/2" Baker S3 Packer - 8174, 8031 No SSSV Installed 8174, 8296, 8435 8031, 8152, 8290 Torin Roschinger Operations Manager Andrew Ogg Andrew.Ogg@hilcorp.com 907.659.5102 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 0028286 27 - 8387 IC Packoff test void at Surface Pump 1/2-cup of greenstick twice. Final pressure = 0-psi. 599 613 4642 613 11611 11529 1850 1900 400 420 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer - 8296, 8152 4-1/2" BOT Packer - 8435, 8290 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:12 am, Mar 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.03.18 08:57:55 - 08'00' Torin Roschinger (4662) DSR-3/25/25JJL 4/8/25 RBDMS JSB 032625 ACTIVITYDATE SUMMARY 2/8/2025 T/I/O = 420/1860/980. Temp = 156°. Re-treat IC test void w/ Greenstick (eval IAxOA). AL online @ 1860 psi. Bleed OAP to BT to 0 psi in 2 min. Held open bleed on OA for duration of job. RU PKG gun to IC test port and pumped ~1/2 cup of green stick into test port. Held pressure for 1 hr to verify good pack. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00. 3/2/2025 T/I/O = 400/1800/220. Temp = 162°. Retreat Greenstick IC void. ALP = 1880 psi, online. PREFORMED FIRE DRILL ON EQUIPMENT. OA cemented to surface. Bled OAP to BT to 0 psi in 1 min, hold open bleed through out job. R/U gun to hoke valve on IC test void. Used 1/4 gun to squeeze greenstick into IC void for 6 hrs. Monitored OAP for 45 min. OAP increased 10 psi. Final WHPs = 400/1800/10. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 Daily Report of Well Operations PBU A-34A 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 A-34A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-105 50-029-21339-01-00 9382 Conductor Surface Intermediate Production Liner 9234 80 2651 8744 880 8923 20" x 30" 13-3/8" 9-5/8" 7" 8776 32 - 112 31 - 2684 29 - 8773 8502 - 9382 32 - 112 31 - 2684 29 - 8626 8356 - 9234 None 2670 4760 5410 8923 5380 6870 7240 8898 - 8923 5-1/2" 17# x 4-1/2" 12.6# 13cr80 x 13cr80, L80 27 - 8533 8751 - 8776 Structural 5-1/2" Baker S3 Packer - 8174, 8031 No SSSV Installed 8174, 8296, 8435 8031, 8152, 8290 Torin Roschinger Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 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 0028286 27 - 8387 IC Packoff test void at Surface 1 cup of Greenstick packing pumped with 3500-psi squeeze pressure. 646 593 2491 669 11711 10923 1900 1800 420 400 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer - 8296, 8152 4-1/2" BOT Packer - 8435, 8290 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 3:53 pm, Mar 22, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.22 14:51:02 -08'00' Torin Roschinger (4662) RBDMS JSB 040224 WCB 2024-07-01 DSR-3/29/24 ACTIVITY DATE SUMMARY 3/5/2024 T/I/O = 400/1770/650. Temp = 160*. Re-treat IC test void w/ Greenstick (eval IAxOA). AL online @ 1840 psi. Bleed OAP to BT to 0 psi in 2 min. Hold open bleed on OA for 5 hrs. RU PKG gun to IC test port, pump approx 1/2 gun load of green stick into test port. IC test void pressured up and would not take any more plastic, held pressure for 1 hr to verify good pack. SV = C. WV, SSV, MV = O. IA & OA = OTG. 16:00. Daily Report of Well Operations PBU A-34A pump approx 1/2 gun load of green , ggg stick into test port. IC test void pressured up and would not take any more plastic held pressure for 1 hr to verify good pack. 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 A-34A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-105 50-029-21339-01-00 9382 Conductor Surface Intermediate Production Liner 9234 80 2651 8744 880 8923 20" x 30" 13-3/8" 9-5/8" 7" 8776 32 - 112 31 - 2684 29 - 8773 8502 - 9382 32 - 112 31 - 2684 29 - 8626 8356 - 9234 None 2670 4760 5410 8923 5380 6870 7240 8898 - 8923 5-1/2" 17# x 4-1/2" 12.6# 13cr80 x 13cr80, L80 27 - 8533 8751 - 8776 Structural 5-1/2" Baker S3 Packer - 8174, 8031 No SSSV Installed 8174, 8296, 8435 8031, 8152 Torin Roschinger Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 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 0028286 27 - 8387 IC Packoff test void at Surface 8 cups of Greenstick packing pumped with 3500-psi squeeze pressure. 548 Well Not Online 660 11481 1762 0 336 0 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer - 8296, 8152 4-1/2" BOT Packer - 8435, 8290 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:12 am, Aug 03, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.03 06:01:47 -08'00' Torin Roschinger (4662) RBDMS JSB 080323 WCB 3-8-2024 DSR-8/4/23 ACTIVITY DATE SUMMARY 7/28/2023 T/I/O = LOTO/19/1200. Temp = SI. Greenstick IC test void (Eval IAxOA). ALP = 0 psi, SI @ CV. OA cemented to surface. Bled OAP to 0+ psi in 5 min (gas), held open bleed for 6 hrs. SI open bleed to monitor pressure. RU PKG gun to Hoke valve on IC test port. Pumped 4 gun loads of Greenstick (Self Mold) plastic into test void. Held pressure for 1 hr to pack IC void. OAP increased 200 psi. FWHP's = LOTO/19/200 SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:30 Daily Report of Well Operations PBU A-34A Greenstick IC test void RU PKG gun to Hoke valve on IC test port. Pumped 4 gun loads of Greenstick (Selfgg Mold) plastic into test void. Held pressure for 1 hr to pack IC void. 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): 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 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 A-34A Wellhead Sealant Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-105 50-029-21339-01-00 9382 Conductor Surface Intermediate Production Liner 9234 80 2651 8744 880 8923 20" x 30" 13-3/8" 9-5/8" 7" 8776 32 - 112 31 - 2684 29 - 8773 8502 - 9382 32 - 112 31 - 2684 29 - 8626 8356 - 9234 None 2670 4760 5410 8923 5380 6870 7240 8898 - 8923 5-1/2" 17# x 4-1/2" 12.6# 13cr80 x 13cr80, L80 27 - 8533 8751 - 8776 Structural 5-1/2" Baker S3 Packer 8174, 8031 Stan Golis Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 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 13.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 0028286 4-1/2" Baker S3 Packer 27 - 8387 8296, 8152 IC Packoff test void at Surface 1/4 cup of Greenstick packing pumped with 3500-psi squeeze pressure. 657 613 430 857 11269 11600 1763 1784 339 339 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 4-1/2" BOT Packer 8435, 8290 8174, 8296, 8435 8031, 8152, 8290 pressure: By Samantha Carlisle at 8:25 am, Oct 08, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.08 07:02:28 -08'00' Stan Golis (880) MGR15OCT2021 RBDMS HEW 10/8/2021 DSR-10/11/21SFD 10/8/2021 ACTIVITY DATE SUMMARY 9/24/2021 T/I/O = 380/1760/220. Temp = 162°. Green stick IC void (eval IAxOA). ALP = 1760 psi, AL online. Found leaking LDS @ the 11 o'clock position on TBG hanger, torqued to 500 ft/lbs. Leak mitigated. RU PKG gun to IC test void, 100 psi. Pumped ~1/8 of packing gun of green stick into viod @ 3500 psi, held pressure for 1 hr. Bled pump equipment to 0 psi, left 3500 psi on IC void. Final WHPs = 380/1760/220. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 Daily Report of Well Operations PBU A-34A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS E`'�` nrr ? _ nn4n 1. Operations Performed LUTJ-- Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Doer h pyn_ ❑ goo Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Cha IArAJL; ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Wellhead Sealant 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 185-105 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service❑ 6API Number: 60-029-21339-01-00 7 Property Designation (Lease Number): ADL 028286 8. Well Name and Number: PBU A -54A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9382 feet Plugs measured 8923 feet true vertical 9234 feet Junk measured None feet Effective Depth: measured 8923 feet Packer measured 8181, 8302, 8435 feet true vertical 8776 feet Packer true vertical 8038. 8157 8290 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 34-114 34-114 Surface 2651 13-3/8" 33-2684 33-2684 5380 2670 Intermediate 8744 9-5/8" 29-8773 29-8526 6670 4760 Production Liner 880 7" 8502-9382 8356-9234 7240 5410 Perforation Depth: Measured depth: 8698 - 8928 feet True vertical depth: 8751 -8781 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6#, 13Cr80 / L-80 26-8533 26-8387 5-1/2" Baker S-3 Packer 8181 8036 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 8302 8157 true vertical depth) 4-1/2" BOT 3H Perm Packer 8435 8290 12. Stimulation or cement squeeze summary: Intervals treated (measured): OA cemented to surface. Install PKG gun and pump green stick packing into test void. Pumped approx the equivalent of 1/2 J stick into IC test void, pressure locked up. Held 3500 psi of pressure on void for 1 hr. No more plastic movement. IC test void appears to be packed off. Treatment descriptions including volumes used and final pressure: 1/2 J Stick. Final Pressures: OA = 180 psi, IA = 1650 psi, TBG = 340 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 833 2080 12060 1775 337 Subsequent to operation: 855 2117 12320 1751 339 14. Attachments: (required per2p nac 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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: N/A Authorized Name: Semmens, Travis Contact Name: Semmens, Travis Authorized Title: Intervention & Integrity Engineer Contact Email: travis.semmens@bp.com Authorized Signature: I Date: l 7—/-L L Contact Phone: +1 9072979672 Form 10404 Revised 04/2017 .A.6p m-'� .., r2gDMS01%^' nGr, n i 9n1n Submit Onoinal Omv TWO = 380/1750/610. Temp = 1420. Bleed IAP & OAP to 0 psi (Assist Cameron w/green stick). ALP @ 1750 psi, online. IA FL @ 5781' (Sta #4, SO, 253 bbls). OA cemented to surface. Bled IAP to production from 1750 psi to 270 psi in 2 hrs. IA FL unchanged. Bled IAP to OT from 270 psi to 0 psi in 5.5 hrs. Bled OAP from 520 psi to 0 psi in <1 min (gas). SI bleeds and monitor for 1 hr. Placed heater in well house towards IC hanger. IAP increased 1 psi and OAP increased 35 psi. Bled OAP to 0 psi in <10 sec (gas). Final WHPs = 180/1/0. 11/6/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:45 T/I/O=SSV/7/0, Temp=Sl. Re -treat IC test void with green stick plastic. RU to Hoke valve on IC test void (0+ psi), bled to 0 psi. Install PKG gun and pump green stick packing into test void. Pumped approx the equivalent of 1/2 J stick into IC test void, pressure locked up. Held 3500 psi of pressure on void for 1 hr. No more plastic movement. IC test void appears to 11/7/2019 be packed off. T/I/0 = SSV/7/50. Temp = SI. Assist Cameron (Green Stick). ALP = 1930 psi, SI @ casing valve. Heater installed in wellhouse working properly. OA cemented to surface. Bled OAP to 0 psi in 15 secs. Assisted Cameron as needed. Removed heater from wellhouse prior to departure. 11/7/2019 ISV, WV, SSV = C. MV = 0. IA, OA = OTG. 1600 hrs. TREE= 6318" CEW VVELU-EAD= Acruki R= OKB. Ei-w CNV BAKEtC - 75.69' 49.29 KOP=_ 3300' Maz Angle = TW@6W 6200' Datum MD= 902Y Oatum —TVD= 8800'SS 91.5#, H-00, D =19.124' 1 —1107 1 9-5/8' CSG, 47#, L-80 HYD 563, D = 8.681" I--� 26 13-3/6" CSG, 7212, L-80 BUTT, D =12.347•26 Minimum ID = 3.725" @ 8506- 4-1/2" OTIS XN NIPPLE bpf, D = 4.892" 4-122^ TBG 3, 12.6#, 13CR-80 VAM TOP, D= 3.958' 1 8382' 1 4-1/2" TBG, 12.6#, LA .0152 bpf, D = 3.958" n47#, L-80 BUTT, D PERFORATION SLU ARY RE= LOG: BRCS ON 05/28/85 ANGLEATTOP PERF: 27" @ 8896 We: Refer to Production DB for historical pert data S¢E SPF MH2JAL OprJSgz SHOT I SOZ SEE PAGE2 FOR PERFORATION GATS 26#, L-80 LKS, .0383 bpf, D= W. L-80 BUR, .0371 bpf- D = A_34A SAFETYNOTES: ***4-112"CHROME TBG... HM x GAS FT MA KFVP C ST AD TVD DEV TYPE VLV LATCH 16R -r GATE 6 3636 3623 14 Mr/; DOEOE W 16 0625!18 5 5210 5153 14 MMG DOW RK r 16 06125/18 4 5781 5706 15 MdG SO RK 32 06/25/18 3 6354 6259 16 MoIG DMY RC r 0 06/03/08 2 6882 6768 15 MdG DW RK r 0 06103/08 1 7497 7365 12 MAG DIN RK 0 06/03/08 area- NS-trz- FEs x n>p. D = a.562" I 8174' 9-518" x 5-1/2^ BKR S-3 PKR D=4 , 821T 8229' 5-12^IE.SXNP,D=4.562' 5-1/2" X 4-1/2" XO, D= 3.958^ 8266' 9-58" X 4-112" UNDUE OVERSHOT 8274' 4-112" HES X NP, D = 3.613' 8296' 9-51W x 4-1/2" 13KR S-3 PKK D = 3.1 06/12118 MVJMD GLV CJO(06l11/18) 8361' 4-1/Z" FES x NP, D = 3.813" 839W9 -58•X4 -1/2"U QUEUEOV62SHOT 8411' TBG SEAL ASSY 6436' 9-5/8" X 4-1/2' BOT PKR D =3.813" 3478' 4-112' OTIS X NP, D = 3.813" 8601' 9-5/a• x 7• BKR LNR HGR D = 1606' (633' 4-112" Ol'IS XN NP, D = 3.725" 4-t/2' VVLECi, D = 3.958' 1634' �MDTT LOGGED 02/08/86 DATE REaf BY ODWA34TS 06204185 MISE ORG COMPLETION (A -34A) 06/26/18 DG1JM) GLV C!O (0625/18) 01112/05 WES RWO 07/26118 GJB1J PELL®PX PLUG (07118118) 06103MB NUB RNO 03108115 PJC RIFORIAT ABS 06112118 MVJMJ SET PRE PLUG (06/11/18) 06/12118 MVJMD GLV CJO(06l11/18) PR IDHOE BAY LINT VVELL A -34A PERM! W: 1851050 API No: 50-029-21339-01 S C 35, T11N, R13E, 1171' FNL 8 921' FEL EP Exploration (Alaska) A -34A PERFORATIONSL&WRY FEF LOG: BRCS ON 0528185 ANGLEAT TOP R#: 27° @ 8898' Note: Refer to Rodwtion OB for historical perf data SIZE SP1' INTERVAL OpnlSgz SHOT SOZ 33/8' 4 8898-8912 O 0328100 06/12118 KUJMJ GLV C1O (06/11118) 33/8" 6 8916-8928 O 11/27/96 3-3/8" 4 8928-8948 S 09120/9204/05/01 33/8" 4 8953-8963 S O4M92 04105/01 3118" 6 8970- 9002 S 018)8/91 04/05/01 3118' 8992-9002 S 03(31/86 03/03188 2-718" 4 8992-9002 S 04/01/88 12!20/90 3-318" 4 9006-9031 S 04!26/92 04/05101 3-1/8" 9012-9016 S 03131/86 03/03/88 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 2-718" 4 9012-9016 S 04101/8812(10190 2-718" 4 9012-9016 S "01/88 12r2" 3-1/8" 9021-9031 S 03131/8603!03188 2-71W 2 9040-9051 S 04101/8812/ aM 31/8" 9040-9056 S 03/31/8603103188 2-718" 2 9051-9056 S 0323/88 12/20/90 DATE REV BY CDWVE TS DATE REV BY I COMJBJfS O6/OM85 MBE OHGCOMPLEnON(A-34A) 06/26118 DG1JM0 GLV CJO(0625/18) 01/12105 N4E35 FANO 0726118 GJB/JNC RLLED PX PLIIG (07/18(18) 06/03/08 N46i FANO 03/08/15 PJC RffORMATWBS 06/12118 MVJAU SEr PX RA1G(06/11/18) 06/12118 KUJMJ GLV C1O (06/11118) PRUDHOE BAY Ift41r WFLL A -34A P87Mr No: 1851050 AR No: 50.029-2133901 T1IR Rl3F- 11 71'FTL & 921' FrL BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Semmens Intervention and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU A -34A Permit to Drill Number: 185-105 Sundry Number: 319-488 Dear Mr. Semmens: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o o gc c. a laska. gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ere .Price Chair DATED this�day of October, 2019. ABDMSI& OCT 3 01019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 HLULIVED OCT 2 8 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well D n h6i Qo iv n ❑ s Suspend El Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA WellLock Squeeze 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development El 5. Permit [o Drill Number: 185-105 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21339-01-00 ' 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? S. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No PBU A -34A 9, Property Designation (Lease Number): 10. Field/Pools: ADL 028286 ` PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): • Total Depth TVD(ft): y Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9382 9234 8923 8776 8923 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 34-114 34-114 Surface 2651 13-3/8" 33-2684 33-2684 5380 2670 Intermediate 1 8744 9-5/8" 29-8773 29-8626 6870 4760 Production Liner 1 880 7" 8502-9382 8356-9234 1 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (fl): 8898 - 8928 8751 - 8781 5-1/2" 17# x 4-1/2" 12.6# 13CrB0 / L-80 26-8533 Packers and SSSV Type: 5-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 8181'/ 8037' 4-1/2" Baker S-3 Penn Packer 8302'/ 8157' 4-1/2" BOT 3H Perm Packer 8434'/ 8289' 12. Attachments: Proposal Summary 21 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 9 Service ❑ 14. Estimated Date for Commencing Operations: November 1, 2019 15. Well Status after proposed work: Oil RI WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Semmens, Travis be deviated from without prior written approval. Contact Email: Tmvis.Semmens@bp.com Authorized Name: Semmens, Travis Contact Phone: +1 907 297 9672 Authorized Title: Intervention & Integrity Engineer / Authorized Signature: Date: 42 / 9 I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: XXUU Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ URR 19 Other: IMS 1� OCT 3 0 2019/ Post Initial Injection MIT Req'd? Yes 11No ❑ Spacing Exception Required? Yes No fl Subsequent Form Required: 16-4dry APPROVED BYTHE 10 Approved by: ) COMMISSIONER COMMISSION Date JV 9,1c t o/341`/ Form 10-403 Revised 04/2017 ORIGINAL /ftad l Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate fie6 by Well: A -34A A -34A OA Well -Lock Squeeze Expected Start Date: November 1, 2019 Well Interventions Engineer: Travis Semmens (907) 297-9672 History A -34A is a gas lifted well that has had a history of IAxOA communication since 2002. A 2008 RWO replaced the upper PC and cemented the OA to surface, but problems persisted. Since 2016 the well has had an OA Squeeze Crete job, an OA Well -Lock squeeze, a Seal-Tite IC void treatment, and then a Belmar plastic packing of the IC void accompanied by a 2nd OA Well -Lock squeeze. The most recent OA Well -Lock squeeze, performed just over a year ago, did not reduce communication` The well passed its most recent PPPOT-IC, MIT -T and CMIT-TXIA in 2018. Current Status The well is currently under evaluation and will be soon shut-in and classified as "NotOperable" by BP. - Objective Squeeze the cemented OA with Well Lock to seal off the OA re -pressurization. Valuable well with average oil production of 700-900 BOPD. Procedure 1. ND OA Gate Valve, NU OA Integral 2. Bleed Annuli, Prep OA, Welllock OA top job squeeze to 2500 psi per RPs. Monitor for 7 days. pk .""A TTS 6-318" CNV VVFiLFEAD= CNV ACTUATOR= BAKERC OKB. t3EV = ----T5-69 BF. ELEV = 49.29 KOP= ---`3300 3636 Max Angle = 16" @6200 Datum M)= 9023' Datum TVD= 8800SS 20"CONDUCTOR, H --11W 91.5#, D=19.724" 9-5/8' Ifs CBv1BViH2 2060' 9-518" CSG, 47#, L-80 HYD 563, D = 8.681" 2084 13-318' F.C. 264V 13-38" CSG, 72#, L-80 BUTT, D = 12 347" 2684' Minimum ID = 3.725" @ 8506' 4-112" OTIS XN NIPPLE TBG, 17#, 13CR 80 VAM TOP, pf, D = 4.892" 4-1/2" TBG, 12.6$, 13CR-00 VAM TOP, 0152 bpf, D= 3.958" 4-1/2' TBG STUB (0786/051 4-7/1- TBG, 12.6#, L-80 BTR.S, .0152 bpf, D = 3.958' 9-5/8" CSG, 47#, L-80 BUTT, D = 8.681" PffiFORATION SUMMARY REF LOG: BRCS ON 05118/85 ANGLE AT TOP PERF. 27" @ 8898' Note: Refer to Production DB for historical perf data SIZE I SPF I Mff AL I OprVSgz I SHOT SOZ SEE PAGE FOR PE€ORATION D1TS 7" LNR 29#, L A -34A ISAFETYNOTES: '"'4-112"CHROME TBG `•' GAR FT 1MtJlGG C Sr M) TVD DEV TYPE VLV LATCH FORT DATE 6 3636 3623 14 MW DOMEJRWKO 06125/18 5 5210 5153 14 MMG DOME06115/18 4 5781 5706 15 MMG SO06/25/18 3 6354 6259 16 MMG DW06/03/08 2 6882 6768 15 MMG DMY06/03/08 1 7497 7365 12 nMG DWY06/03108 8154' H 5-111• HES X NP, D = 4.562' 8174' 9-5/8" X 5-112" FBKR PKR 8217' 5-12' Ht3 X NP, D = 4.562' 8229' 5-1/2" X 4-12' XO, ID = 3.95! 8266- - 266' 9-58' X 4-111" 11fV101lE OV E7 8274' 4-7/2" TES X NP. D = 3.813' 8296' H9-5/8" X 4-1/2" BKRS-3 PKR, 836T 4 11Z' HES X NP, D = 3.813" 1 8949' 1 DATE REV BY COMIMEIM DATE REV BY COMM31T5 06104185 6118E ORIG COM PLEnON (A -34A) 06!26/18 DG/JM0 GLV CIO (06115/18) 0111285 WES RWO 07/26/18 WB/JPULL® PX PLUG (07118/18) 0610388 WES RWO 03/08/15 PJC REFORMAT WBS 06/12/18 Mi/JAD SET PX PLUG (06111/18) 06/12/18 MfVJM) GLV CIO (06/11/7 B) (Y RV X 4-12' BOT PILR, D = 3.873" 11 4-1/2' OTIS X NP, D= 3.813' X 7" SKR LNR P OTT. XN NP. D 1" A -34A PERFORATIONS~RY REF LOG: BRCS ON 05/28/85 ANGLEAT TOPPERF. 27" @ 8898' Note: Refer to Pfodmtion DB for historical pert data SIZE SPFj N19NAL Opn/Sgz SHOT SOZ 3-3/8' 4 8898-8912 O 03/28/00 0612118 MYJI10 GLV CJO (0611/18) 33/8" 6 8916-8928 O 11(27/96 3-318" 4 8928- 8948 S 09/20!92 04/05J01 33/8' 4 8953-8963 S 04/26/92 04AWOI 3118' 6 8970-9002 S 01/06/91 04/05101 3116' 8992-9002 S 0381/86 03/0388 2-718' 4 8992 - 9002 S 04/01188 12/20190 33/8" 4 9006 - 9031 S 0426/92 04/05/01 31/8' 9012-9016 S 03/31/86 03/0388 2-718" 4 9012-9016 S 04/01/88 1220190 2-7/8" 4 9012-9016 S O4101/8812/20/90 2-718' 4 9012-9016 S 04/01/88 1220190 3-118' 9021- 9031 S 03/31186 03103/88 2-718' 2 9040-9051 S 04/01/881220/90 31fi' 9040-9056 S 03131/8603AKY88 2-718' 2 9051-9056 S 03(23188 12/20190 047E REV BY OOIM, NTS DATE REV BY COMAWS 06/04/85 MSE ORIG COM PLErION(A-34A) 06rMI8 DG/JMJ GLV CIO(06125118) 01/12105 NOES RWO 072618 GIE—VJhC PULLED PXPLUG(07/1618) 06103/08 NOES RWO 0310615 PJC REFORMIT WBS 0612/18 WVAV SEF PXPLLX3(O6/11118) 0612118 MYJI10 GLV CJO (0611/18) PRUDHOE BAY LW WILL' A -34A PERMIT No: 1851050 AP No: 50-029-21339-01 SBC 35, T11N, RI 3E, 11 71'FNL & 921' FA BP Exploration (Alaska) VOF Tit • • y "• I y7, s THE STATE Alaska Oil and Gas �►.-s'�� OfALASKA Conservation Commission =_ 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 n.4 Main: 907.279.1433 J.S� Fax: 907.276.7542 www.aogcc.alaska.gov Travis Montgomery �� Interventions and Integrity Engineer BP Exploration(Alaska), Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Oil Pool, PBU A-34A Permit to Drill Number: 185-105 Sundry Number: 318-191 Dear Mr. Montgomery: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French -EL Chair DATED this 6 day of May, 2018. 6 RBDMS�� MAY 1 4018 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION C SION 07:f ,5/,'s//f APPLICATION FOR SUNDRY APP ALS 20 AAC 25.280 MAY 0 7 2018 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well Q ' Operations shutdownwn0 ' Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Chang 4 • ; Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA WellLock Squeeze Q • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 185-105 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21339-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q PBU A-34A. 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028286 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9382 9234 . 8923 8776 8923 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x30" 34-114 34-114 Surface 2651 13-3/8" 33-2684 33-2684 5380 2670 Intermediate 8744 9-5/8" 29-8773 29-8626 6870 4760 Production Liner 880 7" 8502-9382 8356-9234 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8898-8928 8751-8781 5-1/2"17#x 4-1/2"12.6# 13Cr80/L-80 26-8533 Packers and SSSV Type: 5-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and ND(ft): 8181'/8037' 4-1/2"Baker S-3 Perm Packer 8302'/8157' 4-1/2"BOT 3H Perm Packer 8434'/8289' 12.Attachments: Proposal Summary Q Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Q Service 0 14.Estimated Date for Commencing Operations: May 14,2018 15. Well Status after proposed work: Oil Q ' WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery,Travis J be deviated from without prior written approval. Contact Email: Travis.Montgomery©bp.com Authorized Name: Montgomery,Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions&77741 ._ % �T Integritys/g/riEngineer "7 t 8Q Authorized Signature: i 474. i Date: S/ 7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: fg1 q i _ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No It Spacing Exception Required? Yes ■ No Q Subsequent Form Required: I b— !q-0 4- • / 41\ APPROVED BYTHE II Approved by: '• COMMISSIONER COMMISSION Date: - l t Ie VTL 6/I 4 I I b 6x 6c/\bORIGINAL RBDMMAY 16 a0. .da fiKe Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate bp • • Well: A-34 A-34 OA WeIlLock Squeeze Well Interventions Engineer: Travis Montgomery (907) 564-4127 Pad Engineer: Wade Boman (907) 687-4468 History A-34A is a vertical well drilled and completed in June 1985. It began production from Zone 4 during April 1986 at —5000 BOPD with no water. Within 2 months, water had broken through and within 6 months the water cut was at —80%. A WSO cement squeeze was done March 1988 and shut-off 8,000 bwpd. By late 1990, the water cut was back up to 75% and a second WSO squeeze was done. This squeeze broke back 4 times, never did hold pressure but still shut off 5,000 bwpd. The water cut climbed up to 90% by mid-1992. An IBP was set for WSO but had little impact. A-34A continued on full-time production until integrity problems in 2004. The initial integrity issue for A-34A was slow IAxOA communication that was flagged in 2002. The well was evaluated for waiver and returned to production. Surface casing problems began in May 2004, when the DSO reported crude oil and bubbling in the cellar. The OA was pressure tested with N2 and failed. The leak appeared to be at approximately 80'MD based on the OA fluid level. The IAxOA waiver was cancelled and the well was SI. A RWO was performed in January 2005 to replace corroded tubing. The scope of work included replacing the existing L-80 tubing with 13-Cr 4-1/2" tubing and repairing the slow IAxOA leak which was suspected to be a wellhead issue. Integrity of the 9-5/8" production casing was tested and passed. The surface casing leak was not addressed during the RWO, following the Well Integrity Policy (WIP) in place at that time. Revisions to the WIP implemented in October 2005 restricted production of wells with surface casing leaks and forced A-34A to be secured until the surface casing_leak could be repaired. In 2008, a RWO was completed to address the SC leak. The 9-5/8" casing was cut and pulled before 9-5/8" tie-back casing was ran to 2084'. The OA was cemented to surface during the RWO. It was SI in 2009 for frequent OA bleeds. Sampl� ___es taken 3/21/09 indicate that the' •as source was from shallowg_as and not GL gas. The well passes a PPPOT-IC. It had passing MIT-Ts an• TxlAs in both 2011 and 2012. ✓ Further testing of the OA was completed in 2013. The OA was pressured up to 2000 psi and showed rapid bubblin• in the conductor, indicating that the micro annuli are connected to the SC leak. After OA was bled down to zero I- • _ -_ : s opped. A micro OA squeeze to 2000 psi was completed on 6/16/2016 and restored the operability of the well. The micro OA squeeze appeared to have broken down when OA repressurization became unmanageable by bleeds and reached 1600 psi. A WeIlLock OA top job was then performed on 8/14/17 to squeeze off the micro annulus to restore operability. • • A Seal-Tite treatment on the wellhead resulted in a passing PPPOT-IC on 4/6/18. This program is to repeat the WeIlLock OA top job after OA repressurization became unmanageable by bleeds and reached 1600 psi. Current Status The well is classified as "Not Operable." Objective Squeeze the OA with Well Lock to mitigate OA repressurization. / Procedure 1. ND OA Gate Valves, NU OA Integrals. 2. Bleed Annuli, prep OA, WeIlLock OA top job squeeze to 3000 psi per RPs. 2 • • • 11 = 6318"CMI _�� SAFETY NOTES: "'4-112"CHROME TBG"' WEL EEAD CAN ACTLWTOR BAKER (�vbblin5ln Ccc`c1o'L OKB.ELE'E1= 7569' i 4 1 BF,HSV= 49 n I (r �,, qs ►� 14° 6,3 _ 2__.330(7 20^"cxjfiouCTaR • • -110? rix Angle= 16' 6200 91.5#,lido, / g---I 2117' 5-112'FES X NP,Ifj=4.592 D°Un PAD= 9023' ID=19.124' Datum TVD= 8800'SS - ------ __ _ [9-5/8'I-FS CF*34T11T 1-I 2080'..i ` GAS LFT IAANDREDS — 8 �� — ... ST 1.&) BIDE V TYPE VLV LATG13 FORT DATE 9-5/8'CSC 4111,L HYD-60 583 D 681 -f 2084' i. 6 3636 36231 14 MDOKE RK ' 16 03/31/17 13 3/9'F.C. ,-- 34I 44' 5 5210 51531 14 MIG DOME FE ' 16 03/31/17 1133/8'CSG,1201, L-80 BUTT,ID=12,347' -{ 2684' 4 5781 5706 15 6141G SO RK ' 32 03/31/17 3 6354 6759 16 NM MY RK ' 0 06/03108 2 6882 6768 15 MMG DMr' RK r 0 06103/08 Minimum ID =3.725"@ 8506' 4 1 7497 7365 12 WAG OW RK ' 0 06/03/013 4-1/2" OTIS XN NIPPLE [ 8154 /—5-1/2rESX n13,a=4562' J © 8174' {9-5/8"X 5-1/2'BKR 5-3 FKR,10=4,750 821 T --r -1/2"HES X NIP,fV 4.592' 5-1/7'1H3G,17%,13CR-80 VAN 10P, ,--r 8229' J 0232 bp1,C) 4.897' ° �� 8229' 5-1/2 X 4-1/2 XO IU 3.958' r__ 4--1/2'eTBG STUB(0 /26108) 8241' I-1,41 _l ( ,.o.........�.w ,1- —� 8266' :.318' 4-1/2'UNC)V F3Si.5Ri II L 8274' H4-1/2'FES X MP.ID=3.813 I 8245 1,—{9- 3"X 4-1P1'BKR 5-3 WR ID 3.875' I 4-112'133G,12.6#,13C R-88 VAM TOP. 8382' I 8351' 1-14-1/2'T .S X►1P ID=3 813' 1 0157 bpt,0=3.958' 4-1/2'TBG STUB(01/06/05) -i 8387 I ` 8390" 95/8'X 4-112'umuti.OVf34SHQT 8411` -I- 43C SEAL ASSY i 043G' to 61F1 X! irn,DOT rvf�93 3 813' 8478 4-1/T 0Ti3 X NP 0 0 3 813' 4-1/2'TBG, 12,6#,L-80 01335,.. 85533'�� % 6501' 1—9-5/8'X 7-BKR LNR NGF,0--_' 0152bpf,ID=3.958' ` 86' —4-12"OTISXN NIP, 0=3725' 5/8'CSG,470,L- BUTT,D=8.881' --/: 8773' 8113' j--14.7/'2'WLEG,D=3.958' I FERFORATION SUI/MARYi s 8534' l�E1T�TT LOG(" 021081 RIT LOG- BI-1C5 ON 05/28/85I ANGLE AT TOP FF:27`"�•t`8' 1 Ibte. Refer to Production DB for hector/scat pert data ' I SIZE SFF IFTE1WAL Opn/Sgz SHOT SOZ �,4, 8$23 7 TOP OF CEMNT(04106/61) SEE PAGE 2 FOR PERFORATION OATS .a ..P 6_. ' 8949` --{COP OF SAND(041t76101) M 900? —17 MARKER JONT 7"LNf+ 260,1-80 1145,,0383 bpi,©=6.276 -I 926$' max_ I 9335' — ' 1 I r LM,290,L 80 BUTT, 0371 bpf,D`8.164' 1-- 9382' 1 DATE REV BY/ ©OMENTS 1 DATE ]REV BY OOM.CNTS FIUL)I-nE BAY INT 108104/85 N18E !MG COMPLETION(A-34A) 03/29/16 DJ5/JMO'FULLED XX PLUG(03/21/16) WELL: A-34A s01MV05 NIEs #FdiO 03/29/16 JF1[/JMDiGLV C10(03/21/16) FAIT No:.1651050 106103/084 N4ES law 04/11/17' LGIIJND GLV C/O(03/31/17) API fb_ 50-029-21339-01 !03106/15,SW /PJG/GLV 00 SEC 35,T11N,R13E,1171'EN_&921'FEL 03/08/15/,' PJC /REFORMAT WSS 1 !02/11/16!TK/JAD!R)4)VEOSAFETY NOTE I. -*•Exploration(Alaska) • A-34A I I PERFORATION SUMMARY REF LOG, BRCS ON 05/28/85 ANGLE AT TOP FEW 2T al 8898' Note Refer to Prod uctIon EB for historical pert data SIZE SW' /4TB:VAL Opn/Sqz %DT SQZ 3 3/8" 4 8898 8912 0 03/28/00 33/8' 6 8916-81328 0 11/27/96 3-3/8" 4 I 8928-8948 S 09/20/92 04/05/01 •i 3-3/8" 4 18953-8963 S 04/26/92 04/05/01 13-1/8' 6 I 8970-9002 S 01/06191 04/05/01 13-1/8" 8992-9002 S 03/31/86 03/03/88 2-7/8" 4 8992-9002 S 04/01/88 12/20190 33(0' 4 19006-9031 S 04/26/92 04/05/01 3-118" 9012-9016 S 03/3146 03/03/138 2-7/8' 4 19012-9016 S 04/01/ 12/20090 2-7/8" 4 9012-9016 S 04/01/;; 12f2OFJO 2-718" 4 19012-9016 S 04/0148 12/20/90 3-1/8" 19021-9031 S 03/31/86 03/03/88 2-7/8" 2 I 9040-9051 S 04/01/ 12/20/90 @Kan 3-1/8' 19040-9056 S 03131/ 03/03/88 11_713:e 7 anSi_angAc ./7-katra 1,mA/I "•#C.X've k4 V;es .444e tee: LITE REV BY — COMENTS - DATE REV BY comagirs FRUL/tDE BAY UMT 06104185 N1 13E ORIG COM PLUM(A-34A) 03/29/16 DJS/JMD PULLED XX PLUG(03/21/16) WB_L A-34A 01/12105 FREE MVO 03/29/16 JFK/.1114YGLV C./0(03(21/16) FERMI No '1851050 06/03106 NOM RWO 04/11/17 LG/JP4) GLV pan 1/17) AAM: 50-029-21339-01 03/06/15 SWC/PJC GLV CFO SEC 35,T11N,R13E 1171'FM_&921'Fla.. 03/08/15 PJC REFORMAT1NS 02/11/16 TX/J144) REMOVED SAFETY N2/1F I P Exploration(Alaska) 4 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,April 14, 2018 3:22 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL; AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad AB;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Boman,Wade; Glasheen, Brian P;Von Tish, Douglas B; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA);AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer A-34(PTD# 1851050)Well barriers restored with Seal-Tite wellhead repair All, Producer A-34(PTD#1851050)was made under evaluation on 3/17/18 for having sustained outer annulus casing pressure above NOL. Wellhead diagnostic work performed on 4/2/18 found both the primary and secondary seals on the inner casing packoff leaking causing IAxOA communication. A Seal-Tite treatment was performed on the wellhead on 4/6/2018 and the well passed a subsequent PPPOT-IC. The well was brought online 4/7/18 and has shown no signs of IAxOA communication. The passing PPPOT-IC and stable OA pressure indicate the IAxOA communication has successfully been mitigated. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 SCAN Cell: 907-341-9068 wo _.,...•....,...«.o. From: AK, G • - Integrity Engineer Sent: Saturday, March 1 , : 9:53 AM To: AK, OPS EOC Specialists; AK, 0' - ield O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OP - 'ad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Bo . ade; Glasheen, Brian P; Von Tish, Douglas B; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, t • Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp ';•• AKIMS App User; Cismoski, • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, March 17, 2018 9:53 AM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad AB;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Boman,Wade; Glasheen, Brian P;Von Tish, Douglas B; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer A-34 (PTD# 1851050) Sustained outer annulus casing pressure above NOL Attachments: A-34A.pdf All, Producer A-34(PTD#1851050)was found to have sustained outer annulus casing pressure above NOL on 3/16/18. The pressures were confirmed to be T/I/O=SSV/1980/1850psi. The high annulus pressure indicates a potential failure of one or more well barriers. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. DHD-bleed IA and OA pressure 2. Wellhead—Diagnostics on inner casing packoff 3. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens ANNED Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO 1 STATE OF ALASKA "'REPORT OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Il Re-enter Susp Well 0 Other:OA WellLock Squeeze I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 185-105 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21339-01-00 7. Property Designation(Lease Number): ADL 028286 8. Well Name and Number: PBU A-34A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED V CG D Total Depth: measured 9382 feet Plugs measured 8923 feet G true vertical 9234 feet Junk measured None feet SEP 2 0 2017 Effective Depth: measured 8923 feet Packer measured See Attachment feet y� true vertical 8776 feet Packer true vertical See Attachment feet AG j Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 34-114 34-114 Surface 2651 13-3/8" 33-2684 33-2684 4930 2670 Intermediate 8744 9-5/8" 29-8773 29-8626 6870 4760 Production Liner 880 7" 8502-9382 8356-9234 7240 5410 Perforation Depth: Measured depth: 8898-8928 feet True vertical depth: 8751-8781 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#13Cr80 x 4-1/2"12.6#L-80 26-8533 26-8387 Packers and SSSV(type,measured and See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: r; ik- 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 793 1807 11634 1530 332 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25 071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: 317-289 Authorized Name: Lastufka,Joseph N Contact Name: Montgomery,Travis J Authorized Title: Information a ata Controller Contact Email: Travis.Montgomery@bp.com c),,Lct,.) 1, Authorized Signature: , Date: 1/2,461 Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 yr t_ I/2. li e P� Submit Original Only WV SEP2 20+r 'Ili' • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. RECEWE® Report of Sundry Well Operations Summary SEP 2 0 2017 AOGCC September 19, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for A-34A PTD# 185-105. After WellLock was pumped across the OA's integral and block valves until clean WellLock was returned and a squeeze pressure of 2500 psi was obtained, 0.875 gallons of WellLock was squeezed. The objectives of the work were met. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment A-34A SW Name Type MD TVD Depscription A-34A TBG PACKER 8181 8037 5-1/2" Baker S-3 Packer A-34A TBG PACKER 8302 8157 4-1/2" Baker S-3 Perm Packer A-34A TBG PACKER 8435 8289 4-1/2" BOT 3H Perm Packer • • Daily Report of Well Operations A-34A ACTIVITYDATE SUMMARY Job Scope - OA WeIlLock Squeeze Install viton 1502 seals in both OA outlets. Mix 4 gal WeIlLock. Pump across the OA until clean WeIlLock returns (used 1.5 gal), Additional 1 gal WeIlLock required to reach 2500 psi. Squeezed appx 1/2 gal of WeIlLock every 4 hours. Discuss w/Well Int. Engineer and extend pump time additional 12 hours to maximize volume pumped into OA. At 6 pm .75 gal of WeIlLock pumped since reaching 2500 psi sqz pressure. Mix new batch of WellLock 8/14/2017 and purge 1 gal across the Wellhead. Resume squeeze. Cont from WSR 8/14/17. Job Scope - OA WeIlLock Squeeze Continue squeezing WeIlLock. Achieve 2500psi sqz with 1.875 gal sqz'd away+ 1.5 gal to initially fill void (total 2.37g gal of WeIlLock in OA). Hold Sqz pressure f/ 1 hour. Purge acroos top unit) N2 returns from off-side OA valves. Hold 2200 psi N2 pressure. 8/15/2017 ***Job Complete -start monitoring *** Continued from 08/15/17 WSR. Job Scope-OA WeIlLock Squeeze. Continued monitoring of OA pressure and wellhead temp. Bled OAP down to 800 psi, after 24 hour squeeze. Crystal gauge on OA, recording. Heater in wellhouse upon departure. Wellhouse doors open. Swab valve open per safe out tags. 8/16/2017 WV, SSV= C. SV, MV= O. IA, OA= OTG. 03:30 T/I/O = SSV/40/827. Temp = SI. WHPs &Temps (Post WeIlLock). ALP = 160 psi and is SI © casing valve. One wellhouse door is open and heater has beed removed from well house. Crystal gauge batteries @ 75%. WeIlLock sample on wellhead is like syrup in consistancy. Wellhead temp @ 6 o'clock position between OA valves =68°. Temp decreased 8°, OAP increased 27 psi in 12 hours. Re-installed heater in wellhouse upon 8/16/2017 departure. T/I/O = SSV/40/842. Temp = SI. WHPs &Temp (Post WeIlLock). ALP = 160 psi, SI @ CV. Heater in WH working. WH doors are open. Wellhead temp at the 10 o'clock position = 80*. WeIlLock sample has not set up. OAP decreased 73 psi since 04:30 this 8/17/2017 morning. T/I/O = SSV/40/915. Temp = SI. WHPs &Temps (Post WeIlLock). ALP = 160 psi, AL SI @ casing valve. Heater in wellhouse, both doors open. Crystal gauge batteries @ 75%. WeIlLock sample on wellhead has syrup like consistency. Wellhead temp @ 10 o'clock position = 106°. Moved heater from pointing directly on wellhead. OAP increased 88 psi and wellhead temp increased 38° in 12 hours. 8/17/2017 WV, SSV= C. SV, MV= O. IA, OA= OTG. 04:30 T/I/O = SSV/40/835. Temp = SI. WHPs &Temp (Post WeIlLock). ALP = 160 psi, SI @ CV. Heater in WH working. WH doors are open. Wellhead temp at the 10 o'clock position = 80*. WeIlLock sample is almost set up. OAP increased 8 psi since 03:00 this 8/18/2017 morning. T/I/O = SSV/40/827. Temp = SI. WHPs &Temps (Post WeIlLock). ALP = 160 psi, AL SI @ casing valve. Heater in wellhouse. Both doors open. Crystal gauge batteries @ 50 %. WeIlLock sample on wellhead has syrup like consistency. Wellhead temp @ 10 o'clock position = 74°. OAP decreased 15 psi and wellhead temp decreased 6° in 12 hours. 8/18/2017 WV, SSV= C. SV, MV= O. IA, OA= OTG. 03:00 T/I/O = SSV/40/799. Temp = SI. WHPs &Temp (Post WeIlLock). ALP = 160 psi, SI © CV. Heater in WH working. WH doors are open. Wellhead temp at the 10 o'clock position = 60*. WeIlLock sample is firm but still tacky. OAP decreased 2 psi since 02:00 8/19/2017 this morning. T/I/O = SSV/40/801. Temp = SI. WHPs &Temps (Post WeIlLock). ALP = 160 psi, AL SI @ casing valve. Heater in wellhouse. Both doors open. Crystal gauge batteries @ 50 %. WeIlLock sample on wellhead is solid. Wellhead temp @ 10 o'clock position = 60°. OAP decreased 34 psi and wellhead temp decreased 20° in 12 hours. 8/19/2017 WV, SSV= C. SV, MV= O. IA, OA= OTG. 02:00 • • • Daily Report of Well Operations A-34A T/I/O = SSV/40/836. Temp = SI. WHPs &temp (post Wellock). ALP = 160 psi, SI © CV. WH temp= 60° @ 10 o'clock position. OAP increased 37 psi in 10 hrs. 8/20/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 00:00 T/I/0 = SSV/40/845. Temp = SI. WHPs &Temp (Post WeIlLock). ALP = 160 psi, SI @ CV. Heater in WH working. WH doors are open. Wellhead temp at the 10 o'clock position = 80*. WeIlLock sample is firm and tacky. OAP increased 9 psi since 00:00 this 8/20/2017 morning. T/I/0 = SSV/40/845. Temp = SI. WHPs &Temp (Post WeIlLock). ALP = 160 psi, SI @ CV. Heater in WH working. WH man doors are open. Wellhead temp at the 6 o'clock position between OA CV's = 86*. WeIlLock sample is firm and very slightly tacky. WHP's unchanged since 14:00 on 8/20/17. Replaced Crystal data recorder(memory full). 8/21/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 17:00. T/I/0 = SI/0/0. (Post cement job). RD intergal and block valves from OA and OA companion, RU 3"gate valve to OA, torqued to API specs, Installed VR plug and blind flange with alemite fitting to OA companion, Torqued to API specs. RDMO. ***Job 8/22/2017 Complete***. See log for details. T/I/0 = SSV/40/620. Temp = SI. WHPs &Temp (Post WeIlLock). ALP = 220 psi, SI @ CV. Heater in WH working. WH man doors are open. Wellhead temp at the 6 o'clock position between OA CV's = 90*. WeIlLock sample is firm and dry , fingernail will leave a slight indentation. OAP decreased 225 psi since 17:00 on 8/21/17. Bled OAP from 620 psi to 0 psi in < 1 minute (gas). Monitored 30 min. OAP increased 10 psi. Bled OAP back to 0 psi. Removed Crystal data recorder. FWHP's = SSV/40/0 8/22/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 09:00. D= aw 4110 A-34A SA OTES: *"*4-1 CI"CHROME TBG*** ACTUATOR= BAKER C E1EV= 75.69' � ii 1 I BF.ELEV= 49.29' KOP= 3300' 20'CONDUCTOR, -{ -110? Max Angle= 16" ,6200' 91.5#,H-40, / ' ' 2117* H5-1/2"I-ES X P .D=4.562' Datum MD= 9023' D=19.124" Datum TVD= 88007 SS 9-5/8"1-ES CB/ENTER -I 2060' I , GAS LFT A4AAIJF5 ST MD TVD DEV TYPE VLV LATCH PORT GA1E 9-5/8"CSG,47#,L-80 HYD 563,D=8.681' -4 2084' I , r 6 3636 3623 14 WC DOME RK P 16 03/31/17 13-3/8"F.C. 2641' I 1 5 5210 5153 14 MWG DONE PK ' 16 03131/17 13-3/8"CSG,72#,L-80 BUTT,D=12.347" H 2684' "`iii 4 5781 5706 15 AMG SO RK 32 03131/17 3 6354 6259 16 MNG DMY RK r 0 06/03/08 2 6882 6768 15 MNG DMY RK ' 0 06/03/08 Minimum ID =3.725" @ 8506' 1 7497 7365 12 MNG DMY RK ' 0 06/03/08 4-1/2" OTIS XN NIPPLE • 8164' I-15-112* � MD IX , =4.562' X X- 8174' H9-518"X 5-1/2"BKR S-3 PKR D=4.750" (amu I 8217' H5-1/2"HES X NMS,ID=4.562" 5-1/2"TSG,17#,13CR-80 VAM TOP, -{ 8229' .0232 bpf,0=4.892" ---------I 8229' IHS-112"X 4-1/2'XO,D=3.958" 4-1/2'TBG ST1, (05/26/08) - 8241' —I 8266' -19-5/8'X 4-1/2'L#IIQL E OVERSHOT I 8274' R4-1/2"ISS X tom,D=3.813' _, 8298' -{9-518'X 4-112"BKR S-3 PKR,D=3.875' 8361' H4-112"I SXNW,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -{ 8382" I .0152 bpf,D=3.958" 4-1/2'TBG ST016(01/06/05) H 8382` 1 - 8390' H9-5/8"X 4-1/2"MAQUEOVERSHOT ----I 8411' -{TBG SEAL ASSY =, ► 8435' H9-5/8-X 4-1/2"BOT PKR,D=3.813" 847$` -14-1/2-OTIS X NIP D=3.813" 4-1/2"TBG,12.6#,L-80 BTRS, -{ 8533' 8501' -19-5/8'X 7'BKR LNR HGR,D=_^ .0152 bpf,D=3.958" 8506' H4-1/2"OTIS XN MP, D=3.725' 9-5/8"CSG,47#,L-80 BUTT,D=8.681' H 8773' 8533' H4-1/2"WLEG,D=3.958" PERFORATION SUMMARY 8634' ---IELAM TT LOGGED 02/08/86 REF LOG: BHCS ON 05/28/85 I ANGLE AT TCW PERF:27'@ 8898' Note:Refer to Production DB for historical perf dataI SIZE SPF INTERVAL I Opn/Sgz SHOT SO2 8923' -{TCW OF CEMENT(04/06/31) SEE PAGE 2 FOR PERFORATION GATIS ft/1910W' .' .N. i 8949' L TOP OF SAND(04/06/01) t ;,-.7,' ■ 9002' —{7'MARKER JOINT 4 L4 0:eveie 7"LM,261/,L-80 U4S,.0383 bpf,D=6.276" -{ 9268' 1 &4i9335' H MID — 7"LM,29#,L-80 BUTT,.0371 bpf,D=6.184- -{ 9382' " % DATE REV BY COMMENTS DATE REV BY COMLUfR S PRUDH E BAY UNT 06104/85 118E ORIG COMPLETION(A-34A) 93/29/16 CJS/A3 PULLED XX PLUG(03/21/16) WELL: A-34A 01112/05 N4ES RWO 03/29/16 JPKJJMD GLV C./O(03/21/16) PERMIT Na:9851050 06/03/08 N465 RWO 04/11/17 LG/JMD GLV C/O(03/31/17) API No: 50-029-21339-01 03/06/15 SWC/PJC GLV 00 SEC 35,T11N,R13E,1171'FAL&921'FEL 03/08/15 PJC REFORMAT T WBS 02/11/16 TK/JMD RE)VB)SAFETY NOTE BP Exploration(Alaska) • A-34A • ILl g g PERFORATION StMAARY REF LOG BRCS ON 05128/85 ANGLE AT TOP FERE:2r a. 8898' 1 �� Note:Refer to Roduction DB for historical perf data SIZE SFF t+1TO2VAL Opn/Sgz SF DT SQZ 3.3/8" 4 8898-8912 0 03/28/00 3-3/8" 6 8916-8928 0 11/27/96 3-318" 4 8928-8948 S 09/20/92 04/05/01 3-3/8' 4 8953-8963 S 04/26/92 04/05/01 3-1/8" 6 8970-9002 S 01/06/91 04/05/01 3-1/8* 8992-9002 S 03/31/86 03/03/88 2-7/8" 4 8992-9002 S 04/01/88 12/20190 4 , 3-3/8" 4 9006-9031 S 04/26/92 04/05/01 3-1/8* 9012-9016 S 03131/86 03/03/88 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 2-7/8" 4 9012-9016 S 04/01/88 12/20190 2-718" 4 9012-9016 S 04/01/88 12/20/90 3-1/8" 9021-9031 S 03/31/86 03/03/88 2-718" 2 9040-9051 S 04/01/88 12/20/90 3-1/8" 9040-9056 S 03/31/86 03/03/88 2-718" 2 9051-90.56 S 03/23/88 12/20/90 DATE REV BY COMVENTS DATE REV BY CONIVENTS PRUDFIOE BAY INT 06/04/85 NI8E OBIG COMPLETION(A-34A) 03/29/16 DJS/JM)PULLED XX PLUG(03/21/16) WEIL: A-34A 01/12/05 NOBS MO 03/29/16 .1 K/JM)GLV GO(03/21/16) PERMT No:r1851050 06/03/08 WS MO 04/11/17 LG/JM) GLV GO(03/31/17) API No: 50-029-21339-01 03/06/15 SWC/PJC GLV GO SEC 35,T11N,R13E,1171'FM..8 921'FE. 03108/15 PJC T WBS 02/11/16 TK1JM) REM)VEO SAFETY NINE BP Bcploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, September 12, 2017 3:51 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M TL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad DG;AK, OPS Well Pad EKG;AK, OPS Well Pad YP;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Alatalo, Travis; Cerveny, Philip F; Derrick, Laurie R; Frankenburg,Amy; Haffener,Jordan; Oshiro,Joleen; Regg,James B (DOA);Wallace, Chris D (DOA); Glasheen, Brian P;AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel, Joshua;Worthington, Aras 1 Subject: UNDER EVALUATION: Producer A-34A (PTD# 1851050)WellLock Treatment on Outer Annulus Complete All, Producer A-34(PTD# 1851050)was classified as Not Operable on 06/5/17 for rapid outer annulus repressurization that was not manageable by bleeds. The wells outer annulus was treated with Well-lock product on August 14, 2017 to remediate the bled frequency. The well has been reclassified as Under Evaluation to determine if the treatment was successful. Plan Forward/Work Completed: 1. Down Hole Diagnostics: Squeeze Well-lock into outer annulus—Completed 08/13/17. 2. Down Hole Diagnostics: Monitor OA during cure time-Complete 3. Well Integrity Engineer: Return well to Under Evaluation 4. Operations: POP 5. Downhole Diagnostics: Monitor wellhead 6. Well Integrity Engineer:Additional diagnostics as needed Please be mindful of possible fluid packed annuli when bringing well online. Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED =1-? 2 . ^ , Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 oF�jy' "is. STATE Alaska Oil and Gas ti p fA ASKA Conservation Commission 333 West Seventh Avenue x'- Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g no- Main: 907.279.1433 Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Travis Montgomery t Interventions & Integrity Engineera�® JUL �� BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-34A Permit to Drill Number: 185-105 Sundry Number: 317-289 Dear Mr. Montgomery: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. • As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair L DATED this day of July, 2017. RBDMS JUL 1 1 2017 STATE OF ALASKA .ALASKA OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well RI • Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other. OA WellLock Squeeze II• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 185-105 , Exploratory 0 Development [JJ• 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-21339-01-00 • 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU A-34A , RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: JUN 1 n ADL 028286 • PRUDHOE BAY,PRUDHOE OIL • JUN9 2017 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): JI* GCC 9382 . 9234 ' 8217 8073 8923 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 34-114 34-114 Surface 2651 13-3/8" 33-2684 33-2684 4930 2670 Intermediate 8744 9-5/8" 29-8773 29-8626 6870 4760 Production Liner 880 7" 8502-9382 8356-9234 7240 5410 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8898-8928 8751-8781 5-1/2"17#x 4-1/2"12.6# 13Cr80/L-80 26-8533 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development RI• Service 0 14.Estimated Date for Commencing Operations: June 30,2017 15. Well Status after proposed work: Oil l • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery,Travis J be deviated from without prior written approval. Contact Email: Travis.Montgomery@bp.com Authorized Name: Montgomery,Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions&Integrity Engineer Authorized Signature: Date: WPM 7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 317- 2$9 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No IJ, Spacing Exception Required? Yes 0 No L Subsequent Form Required: /6 4 5+- Approved by: (bt—CXA COMMISSIONER COMMISSION Date: 5 I'� /� ?l1 APPROVED BYTHE /f7- C( — "7-3-i7 ORIGINAL RBDMS -JUL 1 12°" Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,4 �j. ',z -/7 i Packers and SSV's Attachment A-34A SW Name Type MD TVD Depscription A-34A TBG PACKER 8181 8037 5-1/2" Baker S-3 Packer A-34A TBG PACKER 8302 8157 4-1/2" Baker S-3 Perm Packer A-34A TBG PACKER 8435 8289 4-1/2" BOT 3H Perm Packer • • bp • Well: A-34 A-34 OA WelKLock Squeeze Well Interventions Engineer: Travis Montgomery (918) 281-9663 Pad Engineer: Brian Glasheen (907) 545-1144 History A-34A is a vertical well drilled and completed in June 1985. It began production from Zone 4 during April 1986 at -5000 BOPD with no water. Within 2 months, water had broken through and within 6 months the water cut was at -80%. A WSO cement squeeze was done March 1988 and shut-off 8,000 bwpd. By late 1990, the water cut was back up to 75% and a second WSO squeeze was done. This squeeze broke back 4 times, never did hold pressure but still shut off 5,000 bwpd. The water cut climbed up to 90% by mid-1992. An IBP was set for WSO but had little impact. A-34A continued on full-time production until integrity problems in 2004. The initial integrity issue for A-34A was slow IAxOA communication that was flagged in 2002. The well was evaluated for waiver and returned to production. Surface casing problems began in May 2004, when the DSO reported crude oil and bubbling in the cellar. The OA was pressure tested with N2 and failed. The leak appeared to be approximately 80'MD based on the OA fluid level. The lAxOA waiver was cancelled and the well was SI. A RWO was performed in January 2005 to replace corroded tubing. The scope of work included replacing the existing L-80 tubing with 13-Cr 4-1/2" tubing and repairing the slow IAxOA leak which was suspected to be a wellhead issue. Integrity of the 9-5/8" production casing was tested and passed. The surface casing leak was not addressed during the RWO, following the Well Integrity Policy (WIP) in place at that time:-Revisions to the WIP implemented in October 2005 restricted production of wells with surface casing leaks and forced A-34A to be secured until the surface casing leak could be repaired. In 2008, a RWO was completed to address the SC leak. The 9-5/8" casing was cut and pulled before 9-5/8" tie-back casing was ran to 2084'. The OA was cemented to surface during the RWO. It was SI in 2009 for frequent OA bleeds. Samples taken 3/21/09 indicate that the gas source was from shallow gas and not GL gas. The well passes a PPPOT-IC. It had passing MIT-Ts and CIVIITTx-Rs in both 2011 and 2012. Further testing of the OA was completed in 2013. The OA was pressured up to 2000 psi and showed rapid bubbling in the conductor, indicating that the micro annuli are connected to the SC leak. After OA was bled down to zero, the bubbling stopped. A micro OA squeeze to 2000 psi was completed on 6/16/2016 and restored the operability of the well. The micro OA squeeze appears to have broken down. The OA repressurization is unmanageable by bleeds. OA exceeded NOL and reached 1600 psi. The program is designed to squeeze off the micro annulus to restore operabilityno o rt.0 +` ►m �-? Current Status The well is classified as "Not Operable." • • Objective Squeeze the OA with Well Lock to mitigate OA repressurization. Procedure 1. ND OA Gate Valves, NU OA Integrals. 2. Bleed Annuli (bleed IA as low as possible). 3. Prep OA, WellLock OA top job squeeze t• 500 'si per RP "We!LLock Treatment for Cemented OAs." Note: The following are •- well-sp- is equipment ratings that support squeezing to a higher pressure than usual 2500 psi) veo a. Burst of 13-3/8 -80: 5,38013)9(80% is 4304 psi b. Collapse of 9-5/8" 47# L-80: 4757 psi, 80% is 3805 psi c. Casing packoffs tested to 3800 psi upon installation (on rig, 5/29/08). 5. After 1 week cure, ND OA Integrals, NU OA gate valves. 2 • Loepp, Victoria T (DOA) From: Montgomery,Travis J <Travis.Montgomery@bp.com> Sent: Tuesday,June 27, 2017 2:29 PM To: Loepp,Victoria T (DOA) Subject: RE: PBU A-34A(PTD 185-105, Sundry 317-289)OA WeIlLock Squeeze Attachments: AK-GWO-RP-DOC-0026.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Answers to your questions are below: 1. The last MIT-IA was performed on 6/2/08. It passed to 3500 psi.The last CMIT TxIA and MIT-T were performed on 9/26/12.They passed to 2500 psi. 2. Attached is the RP for WellLock Treatment for Cemented OAs: 3. The OA shoe is cemented. 4. We won't be squeezing to a pressure higher than 2500 psi. 5. I theorize that gas is entering the OA from an external source via a thread leak in the surface casing. Please let me know if you have any further questions. Thanks, Travis From: Loepp,Victoria T(DOA) (mailto:victoria.Ioepp@alaska.gov] Sent:Tuesday,June 27,2017 9:48 AM To: Montgomery,Travis J<Travis.Montgomery@bp.com> Subject: PBU A-34A(PTD 185-105,Sundry 317-289)OA WeIlLock Squeeze Travis, A couple of questions: 1. When was the last MIT-IA? 2. Please provide the RP"Welllock Treatment for Cemented OAs" 3. Is the OA shoe cemented? 4. Will you be squeezing to a higher pressure than 2500 psig?What pressure? 5. Please outline what you theorize to be the source of the gas and flowpath. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska 1 • 0 0 TREE= 6-3/8"CM A34A SAFETY NOTES: **"4-112"CHROME TBG*** IIIIR.LI-EAD= t Ifk.f.iS - ACTUATOR= BAKER 451 ---,., I, DiC3.B_EV= 75.6g ,'i I BF BIN/= 49 rl ''- ..' .,- I -1- KOP= 3300' 20"CONDUCH•OR, _ -110? j. AS .. , 1 2M—n-15-112-HES X RP,ID,4.562" Max Angle= 16"Le.62017 91,5'1,1440, ,/ I I Dat um MD,-. 9029' [3=19.124' -'DatumTV D= 8800 , ,,,,...../ I ri 5/8'Hin criAmtrm 11 2060' I 11‘. GAS LFT MANDRELS ST IC WU DEV TYPE VLV LATCH PORT DATE 2084' i• 6 3636 3623 14 WIG DOW PK ' 16 03/31/17 1. ---i-ii-P.C.I--1 241' I 5 5210 5153 14 DAC COW FE F 16 03/31/17 4 5781 5706 15 WAG SO FE F 32 03/31/17 I 13-3/0"CSG.12i t, --60 6U-11,ID= 12.34r I-I. 2684' 3 6354 6259 16 WAG DAY FE r 0 06003/08 2 6882 6768 15 NAG DAY FE F 0 06/03/08 1 7497 7365 12 N143 Mt/ RK ' 0 06/03/08 Minimum ID = 3.725" @ 8506' 4-1/2" OTIS XN NIPPLE • I 8164' _I-5-i r2"i-Es x Nil,,ID=4.562- I I .X., >-<- 8I74' -19-5/8"X 5-1/2"BKR 3-3 PM,A=4.750- I , II I 12 8217' 1-15-1/2'HES X NIP.10,.,.4..562' I 5-1/2'TBG,170,13CR-86 VAM 10P,1- 8229' — 0232 bp f,CI---'4.882 A --------- 8229' -15-1/2-x 4-1/2"X0,ID.3.958" 4-1/2'TBG STUB(05)26106) H 8241 r1 I---f 8266' 1-495/8" (4 I r2.11N1011F OVFRSF11 I 1 82741' H4-1/2"HES X NIP,ID=3_813" I 8296' '-.j95/B'X 4-1/7 BKR 9-3 PKR,i0=3.875' 1. 8361' 14-1/2"HES X W,ID.3.813' 4-1/2'TBG,12.60.13CR-80 VAM TOP, -I 8382' I I- 1 _ 0152 bpf,13-z 3,958' 4-117 180 STUB(01/06/05) --I 8382' 1 8390' 9-5/8'X 4 1/2'UNIQUE'OVERS1nOT 1— 8411' --4T6SFAL ASSY c,jij 043G' ID(5.fa"...V 4 IV _ I 8478' --14-1a-oTn X NP,ID..3.813' [4-12'180,12.8*,L-80(1-M, - 8533 Is„\ = ,, 6501• -I8- R 5dr X 7'BKR LNR HG ,13= " .0152 bpf ID=3 958" \ • 8506' -4-1/2"OTIS XN NP, 13=3.725' N I 9-5/8'CSG.474,L-80 BUTT,ID=8861' -I 877T \A gigaT }.. 7 WLEG,ID.3.9511' ._ IL 8534' 1-ELMO TT Locc,a) 02/08/86 PERFORATION SUPMARY REF LOG BHCS ON 05/28/85 I ANGLE AT TOP FERF-2r @ 8898' 1431.e Fbfer to Production DB for historical pert data I SIZE I SPF INTERVAL I Opri/Sqz I SI-DT I XLZ---- ' 8923;---1-1 TOP OF CEMBVT(04/0601) SET PAGE 2 FOR PERFORA TION DA TS 591;1; 8949' ---11OP OF SAM)(04/58/01 1 1 1 WMP rvfloNN: 9002' - ,7"MARKER JONI 7'LNR,260,L-80 U4S,.0383 bpf,El=6.276" 9268' _._ _. _ 9335' -I (WM j 7"LNR,290,l 80 BUTT, 0371 bpf,0-6.184' H 9382' tatit DATE REV BY' CONMNTS : GATE REV BY COMAINTS PRL BAY MT 06/04/85 N18E ORIG COMPLETION(A-34A) 03/29/16 EUS/J1.43 RLLB)XX PLUG(03/21/16) WR 1: A-34A 01/12/05 N4E5 RINO 0329/16 JFKIJMD GLV CIO(03/21/16) REMIT Na_'1851050 06/03/08 MES RWO 04/11/17 LG/JIVO GLV C/0(03/31/17) AR Pb: 50-029-21339-01 03/06/15 SINC/PJd.G(.V GO SEC 35,T11N,R13E 1171'FN_&921'Al 03/08/15 PJC REFORMAT WS 02/11/16!Mat) REMOVED SAFETY NOTE BP Exploration(Alaska) 3 •• A-34A I I FEFFORATION SUMARY REF LOG. 131-1CS ON 05/28/85 ANGLEAT TOP FERE77"r.z.8898' Note-Refer to Rod uction DB for historical pert data SIZE SPF, NTERVAL Opn/Sqz SI-IDT SOZ 3-3/8" 4 8898-8912 0 03/28/00 3-3/8' 6 8916 8928 0 11/27/96 I. es 3-3f8" 4 8928 3948 S 09/20/92 04/06/01 3-3/8“ 4 8953-8963 S 04/26/92 04/05/01 3-118 6 8970-9002 S 01/06191 04/05/01 3-118- 8992-9002 S 03/31/86 03/03/88 2-718" 4 8992-9002 S 04/01/88 12/20/90 3-3/8' 4 9006 9031 S 04/26/92 04/05/01 3-118 9012-9016 S 03/31/86 03/03/86 2-7/8W 4 ;9012-9016 S 041011E18 12/20/90 2-718' 4 9012-9016 S 04/01/88 12/20/90 2-71T 4 9012-9016 S 04101/88 12120/90 3-1/Er 9021- 9031 S 03/31/86 03/03/88 2koss 2-7/8 2 9040-9051 S 04/01/38 12/20190 3-1/8 9040-9056 S 03/31/36 03103/88 x-rhe / grigl_ f11/11.0:01 1/011/0A 9.. 4, 4, - - 55M4 DATE REV BY 006.4kENTS DATE REV BY COMMENTS PRLCHOE BAY ONT 06,04185 N18E ORIG COMPLETION(A-34A) 03/29/16 DJS/JM)FULLED XX PLUG(03/21/16) WELL A-34A 01/12/05 NUM RWO 03/29116 JPK/IfA)GLV CIO(03/21/16) FERMI No.'1851050 06/03i08 WES RWO 04/11/17 LG/JM) GLV C/0(03/31/17) A R No: 50-029-21339-01 03/06/15 SWOPJC GLV 00 SEC 35,T11N,R13E 1171'F!&8 921'Fa 03/08115 PJC REFORMAT WBS 02/11/16 TIQJMD REMOVED SAFETY NOTE BP Exploration(Alaska) 4 S RP:WeIlLock Treatment for CZ'Rfented OAs Page 1 of 13 GWO Alaska Region Recommended Practice: WeIlLock Treatment for Cemented OAs Authority: Well Superintendent- Custodian: Well Intervention Special Projects Engineer GWO Alaska: Special Document Control GWO Alaska, Scope: Projects Administrator: Document Control Specialist Issue Date: April 16, 2015 Issuing Dept: GWO Alaska Revision Date: February 22, 2017 Control Tier: Tier 4 Next Review Date: February 22, 2020 Purpose/Scope This RP provides guidelines for planning and executing pressure remediation for cemented OA and surface casing pressure remediation. Suggestions and feedback for changes to this RP should be sent to: akwellsRP(c�bpc.boglobal.com. 1.0 Definitions AFE-Annular Fluid Expansion DHD—Downhole Diagnostic Team HES—Halliburton LDD—Leak Depth Determination LLR—Liquid Leak Rate SP—Special Projects TOC—Top of Cement WSL—Well Site Leader 2.0 General Requirements Contractor Every WeIlLock job will have a well specific program to accompany the guidelines of this RP with a model of the job prepared by Halliburton. The model should include (blend library to be included in Appendix D): • Resin blend • Resin composition lab testing which includes the following: o Rheology o Initial temperature conditions o Graphical illustration of Slurry temperatures/Compressive strength vs. Time o Plot of Exothermic Reaction Temperatures vs. Time • Recommendations for treatment, including: o Initial temperature range o Surfactants/pre-flush fluids for preparing the well, e.g., Musol A. o Exothermic reaction temperature range o Assumptions about the condition of the well, e.g.,wellbore fluids, LLR, pressure equipment, applied pressure,fill up volume. o Estimate of cure period After the well specific program has been executed, Halliburton shall provide a post job summary within two weeks of the job execution that includes: • Resin composition and accelerator concentrations • Temperature of the slurry during treatment • Volume of WeIlLock used Classification:BP Internal ©BP plc Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT attp://eportai.bpweb.bp.com/omsop/Home.aspx � S RP:WeIlLock Treatment for CLRTfented OAs Pane 2 of 13 • Pictures of the sample taken, during the job and one week after the job (documented in S: drive) • Suggestions for improving and lessons learned Waste Management Plan Reference the waste management plan (Appendix A)for disposal practice and approval. 3.0 Key Responsibilities: Special Projects Superintendent is: • To designate the person to update this RP as necessary to incorporate new policies or procedures. Well Interventions Engineers are: • To ensure conformance to this RP for well specific programs. • To update this RP to conform to incorporate lesson learned, new policies/regulations. • To obtain the necessary AOGCC 10-403/404s. NOTE: AOGCC has indicated that their need for 10-403s for this treatment is a temporary request. • To ensure that there is an approved AFE for a WeIlLock repair performed in conjunction with a rig workover or coil sidetrack. Well Site Leaders are: • Responsible for identifying and submitting changes to the procedures and methodology based on new technology, lessons learned and improved ways of performing work to the address specified in Section 1.0. 4.0 Procedure for Open Flute Conductor Treatment 4.1 WeIlLock shall not be used by itself on conductor treatments. Past experiences have not been favorable due to exothermic reactions. 5.0 Procedure for Cemented OA Treatment Well preparation: 5.1 Obtain LLR. 5.2 Strap TOC in OA. 5.3 Contact Valve Shop to have casing valves and if installed VR plug removed. Valve Shop will install flanged integral connections with 2"plug valve and cap with needle valve on both sides of the OA annulus spool. 5.4 ALL of these 1502 connections will need to be Viton seals as the nitrile ones currently provided by well support are not rated for the temperature that WeIlLock can produce. Viton seals are rated for-20degF to 400degF. 5.5 Day before the scheduled treatment. Install heater in wellhouse as needed if temperatures are 40°F or below. 5.6 Bleed tree cap, IA if fluid packed and OA to zero to prevent over pressuring due to thermal fluid expansion. Well treatment: 5.7 Rig up equipment and fluid, example located in Appendix C. 5.8 Upon loading out the job, ensure that 1:1 WeIlLock to Musol A and a 55 gallon open top drum are on location as a contingency should you need to dilute and dump the WeIlLock product. Locate 55 gallon drum outside the wellhouse. Musol A will dilute and neutralize the WeIlLock if needed. 5.9 Record initial starting temperature of external casing and wellhead. 5.10 Discuss the casing/OA temperature profile with Halliburton to confirm initial starting temperature is compatible with the planned WeIlLock blend. Classification:BP Internal ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND ATottp://eportal.bpweb.bp.com/omsop/Home.aspx • RP:WeIlLock Treatment for ented OAs Page 3 of 13 5.11 Verify that the'Pilot Micro OA WeIlLock'blend, testing and data located in Appendix D, is the blend being used for treatment. 5.12 Collect two samples of the blend 5.12.1.1 Collect approximately one cup sample of WeIlLock in Halliburton sample container. Place sample in representative condition INSIDE the Wellhouse(do not remove from the Wellhouse until after seven day cure)and monitor viscosity throughout job. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 5.12.1.2 Collect approximately one cup sample of WeIlLock in Halliburton sample container. Take sample to shop. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 5.13 Bleed off IA pressure as low as possible. This is for positive pressure differential between IA and OA. 5.14 Remove all iron from flanges and verify or install viton seals. 5.15 Reinstall iron on opposite side of OA spool and cap. 5.16 Based upon the TOC strap, mark the point on the Tygon tubing where the tubing should tag bottom. Extend pre-measured tygon tubing to TOC. 5.17 Back feed Tygon tubing through 2"Tee and install tee on integral flange so that returns will flow into a metal bucket below to catch returns. Use a rag to act as a packoff around hose. 5.18 Begin pumping WeIlLock ata slow rate, taking returns. Flush until 1:1 returns of clean WeIlLock are observed. Stop pumping and remove hose from the OA. 5.19 Using Lincoln pneumatic pump, squeeze placed fluid by applying 2200 psi or max recommended pressure in SoR. 5.19.1 If max pressure is achieved and pressure fall off is less than 400 psi in the first 30 minutes, bump back up to max pressure three times. After third pressure bump go to step 6.22 5.20 Hold squeeze on OA for not less than 1 hour. Squeeze will be deemed complete at WSL discretion. Note the volume of WeIlLock it takes to obtain squeeze pressure in AWGRS. 5.21 After one hour and confident that no more WeIlLock can be injected into the OA. Bleed pressure off and remove all iron from both sides of OA spool piece. 5.22 Clear/clean both plug valves, iron and VR profile with Musol A then reinstall iron on both sides of the OA spool piece. 5.22.1 Pump Musol through pneumatic pump and lines for cleanup,taking returns to disposal drum. 5.22.2 See appendix A Waste Management Plan for guidance on how to handle leftover welllock product from the treatment. 5.23 Reapply pressure using N2 to the maximum of the bottle, but no higher than original squeeze pressure, this will vary dependent on ambient outside temperatures. 5.24 Monitor temperature and pressure every 15 minutes for 24 hours.At the end of 24 hours, bleed back N2 OA cap pressure to 800 psi.After the first 24 hours, monitor well once every 12 hours for 6 days to ensure casing is above 40°F. Record pressure,temperature and physical condition of the sample in wellhouse in AWGRS. (e.g. liquid, spongy, hard). After 7 days, discuss sample with WSL. 5.24.1 If temperature falls below 40°F restage heaters to bring temperature back up. 5.25 Place well on-line under evaluation after the 14 day cure period. Do not fluid pack the OA due to Annular Fluid Expansion (AFE) considerations post treatment. Classification.BP internal O BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT h;tp://eportal.bpweb.bp.comiomsop/Home.asp RP:We!lLock Treatment for ented OAs Page 4 of 13 Revision Log Revision Date Approving Authority Custodian/Author Revision Details April 16,2015 Clint Spence Jessica Sayers Ori•inal Issue Title Change, updated heater September 15, 2015 Clint Spence Jessica Sayers temps, squeeze pressure, removed conductor treatment section Daniel Scarpella/ Updated contacts, positional February 22, 2017 Tyler Norene Ryan Thompson responsibilities and current practices. Classification:BP Internal ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/omsop/Home.aspx RP:WeIlLock Treatment for ented OAs Page 5 of 13 Appendix A Waste Management Plan — WellLockTreatment Prepared by: Matt Brown/Jess Sayers Date: August 13, 2014 Purpose and Scope: Pump Halliburton's WeIlLock treatment to seal holes/leaks in the wellbore to shut off reservoir fluids. WeIlLock is resin that sets up with temperature to a hard, plastic-like material. It is used for squeeze applications to repair cement or tubulars/casing.WeIlLock consists of four chemicals that are mixed on location. Once mixed, the WeIlLock system is designed to set up at bottom hole temperatures. Project Contacts: Dan Scarpella/Arvell Bass 659 5580 or 907 441 0135 Secondary contact: Aras Worthington 564 4102 or 907 440 7692 Jess Worthington 564 4281 or 907 602 8715 Activity Description: The WeIlLock treatment will be bullheaded down the well and allowed to set up. Treatment volume may vary from 1/2 bbl for a small job up to 10 bbls of WeIlLock for a larger job. Once the WeIlLock resin has set up, coiled tubing will mill out any remaining WeIlLock in the tubing. The MSDS sheets for the chemicals listed in the table are attached. The chemicals are approved in the NCE process. The MSDS for the solidified WeIlLock is attached. WeIlLock Description WeIlLock in its liquid state weighs about 9 ppg and has a viscosity of 30-50 cp. Fluid compatibility testing with common intervention fluids shows that WeIlLock is immiscible with brine, methanol, 60/40 methanol/water, diesel and acid. To stop WeIlLock from setting up, Musol is added in proportions of 25%WeIlLock/75% Musol. Cleanup of surface equipment is performed by flushing pumps/lines with Musol, then freshwater. The anticipated waste streams from a WeIlLock job include: 1. Surface equipment washup water with some WeIlLock and Musol 2. Small volumes(<1bb1)of WeIlLock+Musol from OA squeezes 3. Larger volumes(+20 bbls)of WeIlLock+Musol mixed with 2%KCI from cleaning out a well with coiled tubing after a WeIlLock squeeze 4. Solidified WeIlLock at surface(if the job can't be pumped after additives are put in WeIlLock due to weather, equipment issues etc.) 5. WeIlLock cuttings from milling solid WeIlLock downhole(cuttings look like ground up plastic) Classification:BP Internal ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT>",ttp:/ieportal.bpweb.bp.com/ornsop/Home.aspx S RP:WeIlLock Treatment for tented OAs Page 6 of 13 Anticipated Waste and/or Recycle Streams Stream Classification Amount Disposal/Reuse Accountable/ Options contact numbers Solidified WeIlLock Up to 10 bbls Take unused WeIlLock Arvell Bass/Dan to Halliburton shop, put Scarpella 659-5580 into 55 gal drums to set up, and then to Environmental Advisor landfill after WeIlLock Central 659-5893 solidifies Mix of 25%WellLock+ Put in 55 gal drum and Arvell Bass/Dan 75%Musol Small vols(<lbbl) comingle with Scarpella 659-5580 inceneration and hazardous waste Geoff Kany- stream. Environmental Advisor Central 659-5893 2%KCI water+Mix of 25% Slipstream direct inject Arvell Bass/Dan WeflLock+75%Musol. >20 bbls of mixture into GNI Scarpella 659-5580 The fluid would be about 90%KCI water and 10% Geoff Kany- WellLock/Musol Environmental Advisor Central 659-5893 Cleanup water for washing Up to 10 bbls Slipstream direct inject Arvell Bass/Dan surface equipment after into GNI Scarpella 659-5580 pumping WeIlLock: 95% Fresh water with 5%mix of Geoff Kany- WellLock+Musol Environmental Advisor Central 659-5893 Solid WeIlLock particles Up to 10 bbls Slipstream direct inject Arvell Bass/Dan from milling with coiled into GM Scarpella 659-5580 tubing Geoff Kany- Environmental Advisor Central 659-5893 EX` MSDS_WLR1.pdf MSDS_WLR2.pdf MSDS_WLH1.pdf MSDS_WLA2.pdf MSDS_WellLock_Set. pdf Musol.pdf RE Well Lock waste management plan.ms Classification:BP Internal ©BP p I c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.boweb.bo.com/omsop/Home.aspx • RP:WellLock Treatment for ented OAs Page 7 of 13 Appendix B Saaykus. Jessica From: Csmoski,Doug A Sent: Tuesday,Aprd 14,2015 11:27 AM To: Sayers.Jessica:Darrel.Ryan:AK D&C Well Integrity Coorrinaor Cc: Stemicki,Oliver R:Spence,Clint J;Bit,Michael L(AMC) Subject: IRE:Clarification of pass fait testing for OA's.... During the operation of a well,fresh liquid is observed staining the wellhead. Doug From:Sayers,Jessica Sent:Tuesday,April 14,2015 10:26 AM To:Daniel,Ryan;AK,D&C Well Integrity Coordinator Cc:Ste nicki,Oliver R;Spence,Clint 3;Bill,Michael L(ASRC);Cismoski,Doug A Subject:RE:Clarification of pass fail testing for OA's.... Thanks,Ryan. Just wondering if you can clarify the intent of'active leaks to atmosphere'? Thanks. Jess Sayers From:Daniel,Ryan Sent:Tuesday,April 14,2015 10:01 AM To:AK,D&C Well Integrity Coordinator Cc:Sayers,Jessica;Ste nicki,Oliver R;Spence,Cant 3;Bil,Michael L(ASRC);Ctsmaski,Doug A Subject:Clarification of pass fail testing for OA's.... Importance:nigh Al. Rev-2 WIOP criteria for well operability,in this case any active(confirmed)leak to atmosphere determines whether the well can remain online or not post repair/treatment. Internal OA repair at surface • Rass tai criteria tar OA's using the post treatment example of welllock shall use the MIT criteria.Le liquid test to 1200psi using current 1045 small volume criteria when the OA is fully cemented/well locked to surface. External OA repair at surface • Pass fair criteria for OA's using the post treatment example of a welllock donut in the SC by Conductor annulus shall also use the MIT criteria.t.e Liquid test to 1200psi using current 1045 large volume criteria when the OA is liquid packed.If the OA shoe is open or breaks down under 1200psi there are two options but the definitive result is no active teak to atmosphere with liquid.Typically in these cases a)minimum of 400.500psi may be held Classification:BP Internal ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/omsop/Home.aspx RP:WelILock Treatment for ented OAs Page 8 of 13 while pumping MIT for 15 minutes,orb)bring the well online Under evaluation which achieves the same result (in time). During all OA testing please ensure contingency measures are in place to mitigate and minimize returns to surface. Trouble shooting and diagnostics only • Other integrity tests using gas such as N2 are valid for diagnostics type work only when the well is called into question for anomalies,bubbling in cellar,returns to atmosphere etc.However these should not be used to explicitly and independently to determine operability,pass/fail of treatments etc. Thanks Ryan Classification:BP Internal ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT litp://eportal.bpweb.bp.com/omsop/Home.aspx • S J-0000 J%/ \IX § fg2Ei t §nom /% ° ¥Q& , _ . 1c .. o \ \q$ {3 &»79o� f�\*E co . ETo« 2 30• s"/ \ 3Z0s 3 }0X / 2m• ro / • 0 0 ( \§ - ƒ x /g O � r / › \ < ; # » < — , 2 . .< . . ^ y a ; i y Q o - ' ro r [ r- o . - . , 4 ~ ` * j w . m -1 ± 1 \ s \ / 1 73 ® E CD = { ; / - \ . _ ( / •$ ®n� - Om M • _ 9 •iEo,7 x . ::::...i..5' §7- ® 1111 . eao ( fCI ) �gm F « I 2 iii _.. $\ K3\ ... . / 3§ N / 0 §eew z4 - , CO 0 m «/ 0 \ 2 w \ q 0 § 0 j • RP:WellLock Treatment for OAs Page 10 of 13 Appendix D HALLIBURTON cernensi.,g Pilot Micro OA WellLockTM JOB INFORMATION Company: BP Alaska Job Type: Micro-Annulus Lab: GPB Well: Test Type: Pilot Engineer: Gareth Pollock Well=: District: Alaska Gram Tvpe: Basis: Yield(m1): ]dell:it'::ppz: Resin Wt.(g): `__.. . .Material V.:lame tmD C=i.iIn: .VellLockT'Ri :,'eillockni P: :['ellLocknd H: Classification:BP Interna! ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http://eportal.bpweb.bp.com/omsop/Home.aspx 0 RP:WeliLock Treatment forented OAs Page 11 of 13 HALLIBURTON com.nxina Pilot Micro OA WeHLockTM 9.16ppj Wenlock Rheologies K1=0.275 K2=0.534 Time Temp 600 300 200 100 6 3 Stir Speed (F) rpm rpm rpm rpm rpm rpm (rpm) 7:50am 72.8 124 60 40 20 2 1 300 7:55am 72.6 128 62 40 20 1.5 1 300 8:00am 71.6 132 64 42 21 2 1 300 8:05am 67.3 184 84 52 26 2 1 300 8:10am 56.3 MAX 155 101 50 3 2 300 8:15am 53.1 MAX 241 154 78 5 3 300 8:20am 47.7 MAX 293 199 101 6 4 200 8:25am 46.5 MAX MAX 241 122 8 4.5 200 8:30am 42.5 MAX MAX 280 140 9 S 200 8:35am 41.3 MAX MAX MAX 151 10 5 100 8:40am 40.8 MAX MAX MAX 160 11 5 100 9.16pp6 Wenlock Compressive Strength at 90F Time(hr) Strength(psi) 24 To Soft to Crush 48 To Soft to Crush 72 6369 21 3g Classification:BP Internal ©BP p.l.c Control Tier: 4—GWO Alaska Revision Date: 2/22/2017 Document Number: AK-GWO-RP-DOC-0026 Print Date:7/3/2017 PAPER COPIES ARE UNCONTROLLED. 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N W i N C. 61 - .� .• O C 0 0 C O C C C C a'a pg 8p I O O D • • # 0 0 0 -9 airT13 at'. o R- c Slurry Temp(f) . c a ' 3 co a ,., 1111 [ 111 111111R 1' 21t )) 7 C I C c ---- 0 OH Temp VF) 4 r -sT _ • . , ,, - 10 * tit188888 ; 8t4' . n r 0 r _ 11111 : 1111 1 CD 43 -n Am 3 4. , a_ 1 rt C Fo' i ).. ....,- P. - ca lu'i 24 c- -.414N ; 1 2 •-•? 7,-• .0 , C 0 ir _ ,.. i fir e: C V F 74 f. •::, - 1:1 - c- —:. 7 , El..; MINIM IIIIMI• — - I 0 ' 3 1 es. 3 gl- E- C- 1 ;•': i 3;7 I ... 0 1,t ell1 " 1, z rit 0 t 5 . C , , -I .... k 4 re " 0 wo. e 7 (1) 4.- ...... g. r a -, :,! , C, tu • , -I 3 0 a- I c• 1 i gt n n C- gII F- 1 - g 0 g I;, . , . (30)g a 3 3.3 2 6 g 1 i 1 i i C 1 I 1 C 41 O c 8 8 § (154).astsca.Ad 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMA. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Cement OA Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 185-105 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21339-01-00 7. Property Designation(Lease Number): ADL 0028286 8. Well Name and Number: PBU A-34A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: r, =, -,,, Total Depth: measured 9382 p feet Plugs measured 8923 feet true vertical 9234 feet Junkmeasured feet A U G 1 0 2016 Effective Depth: measured 8217 feet Packer measured See Attachment feet true vertical__ 8073 feet Packer true vertical See Attachment feet A0G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 29-109 29-109 Surface 2651 13-3/8"72#L-80 29-2680 29-2680 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet SCANNED r > 4,, , True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): In OA:Surface-1.5'. Treatment descriptions including volumes used and final pressure: 1 Gallon F-103/U-67 Surfactant,1 Gallon Fresh Water,5 Gallons Squeeze Crete Cement,2500 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2010 2910 11130 1736 435 Subsequent to operation: 3149 2350 738 1679 614 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-412 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Chattrron,Garry R(Wipro)1 I d4........741.\ Title PDC Principal Engineer Signature LI Phone +1 907 564 4424 Date 8/10/16 Form 10-404 Revised 5/2015 VDL ''1Z/ / ( RBDMS 0- AUG 1 1 2016 Submit Original Only • • al 000000000 r- COCON- N 0000 p N LO n In c0 N- r- L1; 0 0 0 0 0 0 0 0 0 i 00 N- ct CO Nt M 00 7 O 00 CO N c- N Nr m CO C0 f- co r- r- 00 00 O O 00 O N CO O) N- O O CO N N M 40 r- CO O O O N N N M N N 00 CA O 00 00 CO i I— O O r Cfl O O CO O 41 N up O ct N N N r- 00 v- N N r- N N CO O) 00 00 cl O co co CD 00O- Co 00 4/ CO CD 00 r- Cfl O N 00 N N M 41 N N 00 O O 00 00 00 V 0 1 I I 1 1 1 ++ Q Q M N O CD CO O O C0 cr O) N N N N co CV N N NCO 00 C Q 1- M a 00 O CD 00 O` CO CD CD CD C) O _J _I 00 00 00 MM C: d M N *k 4# J J J ' 4t (� NX N 14 4# 4* 4t CO • N U N N 00 0\0 - a \O N N N N CV r O O I \ ' 10 Nt I= is N Cn O L0 Cfl (O CO N01 O c- c00 Cfl O O CO CVNI- V 0) N N CO t` 00 v- LU W Q aI— Li] 00 U C) LU LLI U 0 u z z z z ZoWWUW 55 55 55m • s a, N a3 m - 00 I- M O _ O) O V N N I- M t = O O O C) C) O CO 00 00 O OO N- a to O O t V- V' Cb M N M M 00 a, CO 00 C) v- V' Cn CO CO N- OO 00 O O • N- N- N- CO CO 00 00 00 00 00 00 00 CA O) p 00 00 O 00 CO CO CO OO 00 00 00 00 00 00 F a 0 r 000rn0) COOD OD 0000 O- O O CO N V' 00 V CO M N N M 0 d O N- 00 O N V' CO LU O N- CO O W O N O N N- 00 OO (b O CO OO 00 OO OW O CO CO CO 00 CO 00 00 O CO 00 O 00 0 2 w o w p p Z W W O 0 Op_ Y V 0 0 0 0 W Y Y L N CO CO N- CO N N N Cfl - O LU -j J J < < (� W a' ++ a ,- N N V' LU O CD - - N M M (U CU Q Q Q w 0_ 0_ Z_ = a> O O O m 0 0 0 0 0 0 0 0 0 0 _o o _o J W w O J O O 00 CO 00 CO 00 00 O O O) CA O CA O) O Z Z Z O J J J p J Q Q Q m 0 0< a w a al 2 2 2 Za H o 2 0001-1-IW W W a M z O z 2 2 0 cmn cn (/) (/) Q) Q M a 0 C 00 LU M OO M O N CO N CO - 0 0 O = N NC) N- CA(. O = N M V' LO 0 aM/y� O O O) 0) C)) 0 0 CD 0 CD 0 0 .jJ W ,11C00)CO LU CO CO CO CO CO 03 CD CA O) CA 03 (A a0 L N ` 2 ago nU ow 0 0 0 c • a. a a. a. a. a a_ a. a. a a. a as E a. a. a. a. a a a. a. a. a. a. a. a. a a, mmmmmmmmmmmmmm a 0 t a, a II5a, H CO CO CO CO CO CO CO CO CO CO CO CO CO C0 0 0 C O O O O 0 0 O O O O O O O O W Z O N N N N N N N N N N N N N N Z a < L w O a wo J V N w 1- N N N N N N N N N N N N N N Z a J U -Li ° W w CC W 0. 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L a) (p to a) * N a) * co a) : - a) U) -o > > ,- > a) L.L. LL 0 H .- .- H (n LL I- w \ H rn 2 F- ii O a) 11 > II ID N N 2 a) C C C cnvcocn � = cn � oo [n -a cn o cnp p .c � � � O o O Lt � C) � 0 t 0 � W o � CC \ c� CO � > � co i•---: > m a1) i miu To J r- N J 2 J 2 N- J 2 J I- (L I- Q(n I- o O (n o Z e“U 0 0 O co O CO O OO co r r a a o O O O O O O O to N N N N N N N N ,- N co ,- LO t\ coo \ co 6) N m N- N- N- N- !NEL= 6-3r8"CM/ WELLHEAD= ow I S) fY NOTES: ***4-1/2"CHROME TBG*** ACTUATOR= BAKERC A 34A OKB ELEV= 75.69' I 0 ,, BF ELEV= 49.29' }xW�, .,i KOP= 3300' 20'CONDUCTOR, -110? Max Angle= 16°@ 6200 9t.5#,hf 40, / , 1 2117' --f`5-1/2"FES X NP,D=4.562" Datum AV= 9023' D=19.124" Datum TVD= 8800'SS 9-5/8"FES CEMENTER -f 2060' , GAS LFT MANDRELS 9-5/8"CSG,47#,L-80 HYD 563,D=8.681" -I 2084' 1 ST MD TVD DEV TYPE VLY LATCH PORT DATE 13-3/8"F.C. -{— -2641" I 6 3636 3623 14 MMG DONE RK 16 03/21/16 5 5210 5153 14 MMG SO RK r 22 03/21/16 113-3/8"CSG,72#,L-80 BUTT,D=12.347" -I 2684' 4 5781 5706 15 MMG DMY RK r 0 03/06/15 3 6354 6259 16 MMG DMY RK r 0 06/03/08 2 6882 6768 15 IVMG DMt' FE ' 0 06/03/08 Minimum ID = 3.725" @ 8506' 1 7497 7365 12 MING DM' RK ' 0 06/03/08 4-1/2" OTIS XN NIPPLE1118154' -I5-1/2'HES X NP,D=4.562" Z '/ 8174' -I9-5/8"X 5-1/T BKR S-3 PKR,D=4 750" ' 821r H 5-1/2"FES X NP,D=4.562" 5-1/2"TBG,17#,13CR-$0 VAM TOP, H 8229' 1--- .0232 bpf,ID=4.892" 8229' H5-1/2"X 4-1/2"XO,D=3.958' 4-1/2"TBG STUB(05/26/08) - 8241' 8256' -{9-5/8"X 4-1/2"UNIQUE OVERSHOT 8274' -j4-1/2'FES XMP,D=3.813" 8295' -19-5/8'X 4-1/2'BKR S-3 PKR,ID=3.875" 8361' H4-1/2"FES X NP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, H 8382' .0152 bpf,D=3.958" 4-1/2'TBG STUB(01/06/05) - 8382' 8390' H9-5/8"X 4-1/2"UNDUE OVERSHOT 8411' -j TBG SEAL ASSY ,' 8435' _I-1--11139-5G/8S"X 4-1/2"BOT PKR,D'3.813" 8478' H4-1/2"OTS X NIP,D=3.813" 4-1/2"1BG,12.6#,L-80 BTRS, --I 8533' \M8501' -I9-5/8'X 7"BKR LNR FIGR D=_" D .0152 bpf, =3.958" t8606' H4-1/2"OTS PD XN N , =3.725" 9-5/8"CSG,47#,L-80 BUTT,D=8.681" - 8773' 8533' H4-1/2"WLEG,D=3.958" PERFORATION SUMMARY I 8534' IH 6-ND TT LOGGED 02/08/86 REF LOG: BHCS ON 05/28/85 I ANGLE AT TOP PERE:27°Lail 8898' Note:Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 8923' JH TOP OF CEMENT(04/06/01) SEEPAGE 2 FOR PERFORATION CATS 8949' -TOP OF SAND(04/06/01) ♦~`,a0; 9002' --17"MARKER JOINT 7"LNR,26#,L-801J4S,,0383 bpf,D=6.276" - 9268' mow. 6336 --I PBTD NM7"LNR,29#,L-80 BUTT,.0371 bpf,D=6.184' -I 9382' DATE REV BY COMMENTS DATE I REV BY COMMENTS PRUDHOE BAY UNIT 06/04/85 N18E ORIG COMPLETION(A-34A) 03/29/16 DJS/JMD PULLED XX PLUG(03/21/16) WELL A-34A 01/12/05 N4ES RWO 03/29/16 JPK/JMD GLV C/O(03/21/16) PERMIT Noe 1'1851050 06/03/08 N4ES RWO _ AR Nb: 50-029-21339-01 03/06/15 SWC/PJC GLV GO SEC 35,T11 N,R13E, 1171'FNL&921'FEL 03/08/15 PJC REFORMAT WBS 02/11/16 TK/JMD REMOVED SAFE I Y NOTE BP Exploration(Alaska) • A-34A / ri z � 1 PERFORATION SUMMARY REF LOG: BHCS ON 05/28/85 ANGLE AT TOP F 2F:270 @ 8898' Note:Refer to Fkoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 4 8898-8912 0 03/28/00 3-318" 6 8916-8928 0 11/27/96 3-3/8" 4 8928-8948 S 09/20/92 04/05/01 3-3/8" 4 8953-8963 S 04/26/92 04/05/01 3-1/8" 6 8970-9002 S 01/06/91 04/05/01 3-1/8" 8992-9002 S 03/31/86 03/03/88 2-7/8" 4 8992-9002 S 04/01/88 12/20/90 4 ' 3-318" 4 9006-9031 S 04/26/92 04/05/01 3-1/8" 9012-9016 S 03/31/86 03/03/88 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 3-1/8" 9021-9031 S 03/31/86 03/03/88 2-7/8" 2 9040-9051 S 04/01/88 12/20/90 ,.. 3-1/8" 9040-9056 S 03/31/86 03/03/88 w. *. 2-7/8" 2 9051 -9056 S 03/23/88 12/20/90 v DATE REV BY COMutEN S DATE REV BY COMMENTS F'RUDFIDE BAY UNT 06/04/85 N18E OIG COMPLETION(A-34A) 03/29/16 DJS/JMD PULLED XX RUG(03/21/16) WELL: A-34A 01/12/05 N4E5 RWO 03/29/16 JRQJMD GLV GO(03/21/16) FERMI No:'1851050 06/03/08 N4ES RWO API Pb: 50-029-21339-01 03/06/15 SWGPJC GLV GO SEC 35,T11 N,R13E,1171'FM_&921'FEL 03/08/15 PJC REFORMAT WBS 02/11/16 TK/JMD REMIOVEDSAFETY NOTE y BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday,July 05, 2016 5:28 AM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Field OTL;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS Well Pad AB; Glasheen, Brian P; Sayers,Jessica; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey,Adrienne;Wallace, Chris D (DOA);AK, GWO Well Testing WSL;AK, D&C Wells Special Projects;AK, D&C Valve Shop Coordinator; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J Subject: OPERABLE: Producer A-34A(PTD#1851050) MIT-OA Passed All, Producer A-34A(PTD#1851050) passed an MIT-OA on July 4th 2016 post OA cement squeeze to repair a surface casing leak.The well is now reclassified as Operable. Ryan Holt Well Integrity—GWO Alaska (Alternate:Lee Grey) (907)0: 659-5102 scow DEC ® 9 2.016 H: Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Saturday,June 11, 2016 6:05 PM •• AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&0 - •SM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Sur .i tendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS ® I is Lead; AK, OPS Well Pad AB; Glasheen, Brian P; Sayers, Jessica; 'Regg, James B (DOA) (jim.regg@alaska.gov)' laska.•ov) Cc: AK, D&C DHD Well Integrity Engi • AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, • : ienne; 'chris.wallace@alaska.gov' (chris.wallace@alaska.gov); AK, D&C Well Testing WSL; AK, D&C Wells Special Projects; . D&C Valve Shop Coordinator; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; ttus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer A-34A(PTD #1851050) II Test Prior to OA Squeeze All, Producer A-34A(PTD#1851050) has a confirmed surface casing leak.An OA cement seeze to repair the leak is scheduled for 06/16/16. Prior to pumping the treatment,the well will be produced to a portable test separator for 3 days, in order to warm up the well and help increase injectivity into the OA.The well is reclassified as Under Evaluation. Plan Forward: 1. Well Testers: 3 day well test 2. Special Projects: Hot water/surfactant wash OA, bleed IA, pump OA squeeze job 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, June 11, 2016 6:05 PM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Field OTL;AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS Well Pad AB; Glasheen, Brian P; Sayers, Jessica; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; Wallace, Chris D (DOA); AK, D&C Well Testing WSL;AK, D&C Wells Special Projects;AK, D&C Valve Shop Coordinator; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer A-34A (PTD #1851050)Well Test Prior to OA Squeeze All, Producer A-34A (PTD#1851050) has a confirmed surface casing leak. An OA cement squeeze to repair the leak is scheduled for 06/16/16. Prior to pumping the treatment,the well will be produced to a portable test separator for 3 days, in order to warm up the well and help increase injectivity into the OA.The well is reclassified as Under Evaluation. Plan Forward: 1. Well Testers: 3 day well test 2. Special Projects: Hot water/surfactant wash OA, bleed IA, pump OA squeeze job 3. Valve Shop: ND integral flanges, NU OA valve and blind flange on OA side-outlets 4. DHD: After WOC 7 days, MIT-OA and TIFL Please reply if in conflict with proposed plan. Thanks, Adrienne McVey SCANNED JUN 1 7 2016 Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C: (907)943-0296 H: 2376 Email: AKDCWeIlIntegrityCoordinator@BP.com -From: AK, D&C Well Integrity Coordinator Sent: Wednesday, October 02, 2013 8:25 PM To: AK, OPS GC3 Facility_& Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Rr AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; A<3-RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS Well Pad AB; Wermager, Chad R Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer Subject: NOT OPERABLE: Producer A-34A (PTD #1851050) Confirmed Surface Casing Leak 1 l� pra /85-- /D5 Loepp, Victoria T (DOA) From: Sayers,Jessica <Jessica.Sayers@bp.com> Sent: Tuesday,July 21, 2015 9:10 AM To: Loepp, Victoria T(DOA) Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378)Well Lock top job to micro annular squeeze procedure Follow Up Flag: Follow up Flag Status: Flagged Awesome! Thank you Victoria! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, July 21, 2015 9:07 AM To: Sayers, Jessica Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Well Lock top job to micro annular squeeze procedure Jessica, The proposed change to add a Well Lock top job to the micro annuli squeezes for the following sundries is approved. Please include this approved modification with the approved sundries. • A-340 PTD185-105, Sundry 315-412 • H-11: (PTD180-068, Sundry 315-413) • R-24: (R-T-111.93-&74, Sundry 315-414) • M-16(PTD 181-086, Sundry 315-378) Thanx, Victoria SCANNED AUG 3 2015 Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppt ialaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Sayers, Jessica [mailto:Jessica.SayersObp.corii] Sent: Tuesday, July 21, 2015 8:55 AM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Hi Victoria! Just wondering if I can be of any further help. Would it be okay to move forward with the portion of these jobs we already have approval for(the SqueezeCrete portion only), while we wait for the WeIlLock piece to get sorted? Thanks! Jess Sayers From: Sayers, Jessica Sent: Thursday, July 16, 2015 2:33 PM To: 'Loepp, Victoria T(DOA)' Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) The results and findings have not yet been released or finalized. WeIlLock is a Newtonian fluid that reacts exothermically. Preliminary findings suggest that the heat capacity of the overall system should be carefully considered. The heat of reaction, heat transfer capability of the medium in which it is placed, whether the system is open/closed and under pressure or open to the atmosphere are prime factors for this evaluation. Empirical data suggests that microOA squeezes and downhole treatments are suitable and effective applications of WeIlLock. As such, BP management has given approval to proceed with both microOA squeeze jobs, as well as downhole treatments. Let me know if you need more information. Thanks, Victoria! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, July 16, 2015 1:04 PM To: Sayers, Jessica Cc: Daniel, Ryan Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) What were the results of the investigation of the Well Lock incident on V-101? From: Sayers, Jessica [mailto:Jessica.Sayers©bD.com] Sent: Thursday, July 16, 2015 9:26 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: RE: PBU M-16(PTD 181-086, Sundry 315-378) Hi Victoria, Thanks for approving this requested 403. I have decided to add a conservative step to the well treatment for M-16 (this well is a well that has a fully cemented OA and we are using SqueezeCrete to remediate the surface casing leak). After the well is squeezed with SqueezeCrete, a nitrogen cap will be left on the OA. After the SqueezeCrete cures(going to allow 2 weeks)and before the MIT-OA, a WeIlLock top job will be added. This is for a couple of reasons: 1)we are more confident in the properties of WeIlLock to cure MicroOAs (it has no yield point because it is a Newtonian fluid) and 2)we have seen that we get the best WeIlLock jobs before MIT'ing with diesel (while WeIlLock will swap with diesel, it does not effectively do this in microannuli space- we therefore try to move forward with WeIlLock jobs without saturating the microOA with diesel). This step will be added to the other recently approved, similar jobs: • A-34A: (PTD185-105, Sundry 315-412) 2 • H-11: (PTD180-068, Sunary 315-413) • R-24: (PTD193-074, Sundry 315-414) Just wondering if you wouldn't mind helping us get navigated in the right direction here, in terms of the existing 403s? Are the already approved 403s ok, as is? If not, would we need to reapply for new 403s or would it be sufficient to update/add to the already approved 403s? Thank you so much for your time! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, June 19, 2015 2:12 PM To: Sayers, Jessica Subject: PBU M-16(PTD 181-086, Sundry 315-378) Jessica, What is the maximum squeeze pressure allowed at the discharge of the pumps for this procedure? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a�a laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or 'ctoria.Loepp@alaska.gov_ 3 tior Ty • ew��\��jj�s� THE STATE Alaska Oil and Gas w -.' .',?•04 .., - 91 fA LAsKA Conservation Commission ,ems - _>_ - tri _,_, :_ - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 o1"ALASY'P �D _I`lFax. ZV3 Fax 907.276 7542 pta� ! ' www.aogcc.alaska.gov SO Jessica Sayer O� Well Integrity Engineer .s I BP Exploration(Alaska), Inc. I/2.-6-- -----. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-34A Sundry Number: 315-412 Dear Ms. Sayer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7 Cathy P oerster Chair DATED this rr day of July, 2015 Encl. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM, JN J U L 0 8215 . APPLICATION FOR SUNDRY APPROVALS 7 n / -.. 20 MC 25.280 Vv`///111, 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑J �P ti�1`s shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing `Q Change Approved Program ❑ IV)/CV tJnt,v/v) Plug for Rednll 0 Perforate New Pool 0 Repair Well•Q Re-enter Susp Well 0 Other Orqueeze 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5 Permit to Drill Number: 185-105 • 3. Address: P O.Box 196612 Anchorage,AK Exploratory 0 Development Q 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21339-01-00• 7. If perforating: 8 Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q PBU A-34A• 9 Property Designation(Lease Number): 10. Field/Pools: ADL 0028286 • PRUDHOE BAY,PRUDHOE OIL • 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured)' Junk(measured): 9382 • 9234 • 8217 8073 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade Tubing MD(ft)• See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type' See Attachment Packers and SSSV MD(ft)and TVD(ft) See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13 Well Class after proposed work: BOP Sketch 0 Detailed Operations Program Q Exploratory 0 Stratigraphic 0 Development Q • Service 0 14 Estimated Date for Commencing Operations. 7/27/15 15. Well Status after proposed work: Oil Q • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 1 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer Signature n n/ Phone +1 907 564 4281 Date ig I 15 I/ I v Jr COMMISSION USE ONLY Conditions of approval: tify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other Spacing Exception Required? Yes 0 No LN Subsequent Form Required: AO — ¢V 4— APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 7_/ _t e i e TX05 ORIGINAL 7,,0, s— RBDMS1yW1`� JUL 1 5 1015 Submit Form and ` Attachments in Duplicate Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. A-34A 185-105 Plugs Attachement SW Name Date MD Description A-34A 04/02/2011 8217 5-1/2"XX Plug A-34A 04/06/2001 8923 Cement Plug C, a 0 0 0 0 O_ 0 0 0 Ca C` CO M N aO O O CO 1� O V N lC) N V N- Cf) to CO f,- N- U y O O O O O O O O O i M f- I� CO V' M CO O CO CO <- N N V CO CO CO CO f- N- N- CO CO O O CO V N O CO N- a 0 CO CO N CO N LO CO CO O CO N N CO N N N 00 O O CO CO CO i H O O CO x- O CD CO O N CO V CO V O N N N x- CO N N N N CA CO CO CO E 00 00 co 00 (..0 to Cfl co 0, CO O N- M N N N CC) CO N N CO CO O CO CO CO V QLC) 1.0 O O M O (9 O 'Cr CO ON) 'Cr Ca O N N N N CD C N N CO CO CO111 � r F' OO co co O O Cb co O J co OJO co 00 00 co J M lzk M N41t J J J (13 •(i) N X 4)k k *k *CO CO L k CO O =60 N N N _ o N V L2) r N (b O C c0 CO O CO CO N V V C, N N CO N" CO J WI- Q C W o 0 y U U W W OCD LLI:tf2CCLCLZZZZ Z Q W W 07) m m m d N i0 m = cor- M O .- O Ml.o V N N I- (O t .- O O O 6) 6) a0 m M 00 00 m r N- O. to CO O Q6 V' V 4 a0 M N M M a0 a Co I- 00 O V' it) Co CO I,- 00 00 O O ❑ I- N- ti CO CO CO CO 00 00 CO 00 00 6) O) ❑ CO 00 00 00 CO CO 00 CO 00 CO CO 00 00 CO > 0 W Q o 0 < H H V aO N- aD M N 0 J w w t = O O O O) o) ao ao a0 m 00 NW - w z l CO Cfl N V a0 V 00 M N N M Q W ay coo N- 00 O N LU Co Co N- a0 O D O U J D 0 ❑ N (b N N- a0 00 00 a0 00 00 a0 00 a0 O) w W z 0 0 w 0 LU ❑ ao 00 a0 ao ao ao a0 CK) 00 aO a0 00 H H Q = w (L > g n O w O w Z H O O W m _j m Q j 0 w m L• N M C0 N- M N N N Co S O = S (.fl ++ O. = CV N V CO 6) O = = N M M to LO = a) O) O o) CA CA 0) (0 0 0 0 0 0 0 0 O COMMCOCOMMMMMMMMM �0 a) cc0 Y 00 u) o 2 2 2 0 c~i) u~) woo RS Li) Q O 00. � o C L co Co M CO M o N CO N (fl - o o N- a 0) — N N 2 I� O) O T- •- N C) V SR 0) CA CA CA CA O) O O O O o 0 0 I" ❑ CK) CO 00 00 00 00 Cil C)) 0) O) o) 6) O) o) 0 L a� O 2 0 o w D W 0 2• LI- 11- WWWWWWWWWWWW 0- WI- y z 0mdddMMMMMMMdMO_ d 0 0 QQmmmmmmmmmmmm o 0a z O Z _ < 0 ww w WW CC awCCU w W W W m 0 CC CC -1 -J 00w w Q m m E w v) Cn a CC a) m o ❑ o 0 = = = = 0 0 0 0 0 0 0 0 C O O O o 0 0 0 0 0 0 0 0 0 0 o N N N N N N N N N N N N N N OOD v v v v v v v v v v v v m a w 0 0 WU' NN0 w w Q Q m m w E w o o_ cc 0 E m z « « « « « « « w M M M M M M m M M m m m m M Q Q Q Q Q Q Q Q Q Q Q Q Q Q Packers and SSV's Attachment 185-105 SW Name Type MD TVD Depscription A-34A PACKER 8178.48 8035 5-1/2" Baker S-3 Packer A-34A PACKER 8299.61 8155.13 4-1/2" Baker S-3 Hydro Set Packer A-34A PACKER 8434.72 8289.32 4-1/2" BOT 3H Perm Packer Date: 07-06-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: A-34 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, surface casing squeeze repair treatment with SqueezeCrete. This well exhibits bubbling in the conductor when on production and returns fluid to the conductor when pressure tested. As such, it is suspected that the parent leak (leak present prior to fully cementing the OA) from surface casing to conductor is the anomaly. SqueezeCrete has been chosen as the repair medium due to both the low injectivity squeeze capability and also the benign reaction conditions of returns that may be present in the conductor (in comparison to WellLock). Well Detail Current Status: Not Operable Previous Test: 10-02-13 Shell test w/diesel: LLR 0.015 gpm @ 2000 psi (fluid returns in conductor) 09-26-12 MIT-T to 2500 psi, Pass Integrity Issues: Fully cemented OA; OA presents bubbling in conductor on production and returns fluid to conductor when pressure tested Last H2S Reading: 06-26-08 40 ppm Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 09/26/12: MIT-T to 2500 psi Passed, CMIT-TxIA to 2500 psi Passed > 07/01/13: OA LLR 0.015 gpm @ 2000 psi > 10/02/13: MITOA Failed confirming SC leak w/ FTS in conductor 1 of 3 Procedure: 1 D Remove blue goo and ice/material in conductor. - 8 D Place, Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 12 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump (2500 psi max) or until SqueezeCrete returns are observed in the conductor. 14 D Let well cure for 7 days. 15 D MIT-OA to 1200 psi with diesel 2 of 3 • MI- 6 ur cani SAFETY NOTES:WARPING: RADIO TRANSMITTER IN WELLHEAD= -WI A-34A VI FADER MONITORING SHACK MUST BE TURNED ACTUA TOR= BAKER C OFF BEFORE ANY WELL WORK INVOLVING NON OKB ELEV= 75.69 ,..") ,le., 11 a RADIO SAFE EXPLOSIVES CAN BE-GIN CONTACT IW ELEV= 49 29' 2.301). 120'CONCLICTOR -i -110i 2•1 Max Art04,, 16'.(§)6209 91 t4I,ii.40, /11 I --..--; 2117' I '5-1/7 HES X NP,ID=4 ser 1 ucum no= 9023ID iti 124' , J Da1um ND= WOO'SS 19-5/8'tES CBABRER -I 20813 I 1, GAS LETIAAPERELS 9-518CSG 479.L-80 H13563.0-868r -1 2084 I ST AC--Iv l) DEV TY PE VLA1 LATa-1 PORT CATE - - ' 1 ' r fi.- 3836 4823 14 IUNIG 1-S , 14c ' - .0.3,06(15' 13 3/8'F.C. 284V Mg 5 5210 i 5153 14 WIG 014Y FE 0 03.09151 1 )11-.1JA.rwt 174.I-An RI mr 0-12.34r HI 21114. 1 4 5781 5706 15 WC MY RK 0 03/059151 3 6354 6259 16 MATO OW 14K L 0 .06873/98 2 6882 6768 15 WC OW , RK i_r o siso3191 1 Minimum ID=3/25"@ 8506* 4-112"OTIS XN NIPPLE I I 1 7497 7365 12 KIC DAY i RK r 0 ,06.03/38 i I, j---Lturtrsx firr)-4 sir I 1 X st7e j,19-sfr x s,fir BKR S3 PKR Dal 750' 1 ist..____ . ____6_2121._i i5•1/7 HES X NP n.4 scri -5-It,-Inn.1711 13CR410 VA IA TOP,i I- -8229' -1 -. 821T ,--ir,1,-.,XX Fl UG(04102/11) .3232 bIDp'. -4 892* --------- 8229' IS Iti•X 4 10'tn IT) 3 we 1 4 1.'2"T3G STUB:05123(08)'---I 8241' X 4 la'1..440.21.1c OVErrat 8274' 1-14-1/V HES X NIP ID,--3.air_i . f 6301F Hio sir V.4 111"Ogg V 3 Wit U.3 375" I :26 _ 8381' j 14 1/2f_S X NIP ID-3 613' I '4 1/2"T8G.12 00.'SCRAM VAIA TOP. I 11382 , I 1015213p(D..31158' too S11A3 mom)i. L aux' I 8390' 1 i9 5/0'X 4 I.,2'LNIGUE OV P65-01 1 I 8411' j ,IBC.f,.'/A L A ''! 84369-X 4 OJT BOTFXR,ID-1 mr) >1 .. , atm 1 14.1 a-can x NIP,D..3 61 3'I I 4-1.7 MG 12134.L-80 RT7- - 8533' 1. /350i. H9-54r X 7'91KR I NR IIGR,Ifl, "I 0152 Ppt,ID-3 15 NE U-3/25' I I 9-5,8'CSG 479.1-50 MT,0=8€81" I i 8773' I 1/201XN 8613' Hi i,2*wi we: o 1 tViii*1 1 bik [ 6634' ; In NE.TT I or,om opnam( 1 ma-ORA noti suksaRy REF LOG: MACS ON 0508/85 I ANGLE AT TCP FERE 27-cgo 8893 Note Refer to Rocuction refor hisamical pert data I SIZE I SIT[ NTERVAL TOpriSqz.I SHOT SOZ 8923•TOP OF CEMENT(04,06/911 i ‘ 4 SEE PAGE 2 FOR PERFORATION CATS ..t*.t".',`,..";'?` 88MW --I TOP OF SANDI04/06.491) 1 li I :\X :,' • ••• ' 41',41` c 1100i -;i---1 -4-L. 0_2_____71bCN-4104.11 •• - 1 7'LNR 269,..so ulu 0383 bse.I)-8278' HI 9288' r'I NR 299,. 80 BUTT, 0371 bpf,13,6 184' I-4—9382' _ EJA FE REV BY CONIANTS ' CA TE 'riEv BY COA8/B1TS FRICHOE BAY UNIT ' 08104485 MIRE OG COMPLETION(11.34A) 0495111 RCT/PJC SET XX FLUG(04/02/11) WELL A-34A - -01/12M NI ES RWO 0313114 TACVAC ADDEDSAFETY NOTE PERMIT ND-5851050 06(03408 NIES RINO 03106/15 SWG'FJC GLV(20 APT No, 50-029-2133941 06/06/08 11_11 CORRECTIONS 03978115 PC -REFORMAT V413S SEC 35,MN R13E,117r Fla_&921.ra 08/28108 G.15,SV GIN 00(C6/25108) 101/01/93130.164)col_G ORA Fr CORRECTIONS _: IIP Ekploration(Alas Ital , 3 of 3 , A-34A I z IBI 11 X 1 1 PERFORATION SUMMARY REF LOG BHCS ON 05/28/85 ANGLE AT TOP FERE:27°@ 8898' Pbte:Refer to Production DB for historical pert data ' ' SCE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 8898-8912 0 03/28/00 3-3/8' 6 8916-8928 0 11/27/96 3-3/8" 4 8928-8948 S 09/20/92 04/05/01 3-3/8" 4 8953-8963 S 04/26/92 04/05/01 3-1/8" 6 8970-9002 S 01/06/91 04/05/01 3-1/8" 8992-9002 S 03/31/86 03/03/88 2-7/8" 4 8992-9002 S 04/01/88 12/20/90 4 3-3/8" 4 9006-9031 S 04/26/92 04/05/01 3-1/8' 9012-9016 S 03/31/86 03/03/88 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 I 2-7/8" 4 9012-9016 S 04/01/88 12/20/90 3-1/8" 9021-9031 S 03/31/86 03/03/88 2-7/8" 2 9040-9051 S 04/01/88 12/20/90 3-1/8" 9040-9056 S 03/31/86 03/03/88 . . 2-7/8' 2 9051-9056 S 03/23/88 12/20/90 r DATE REV BY COMMENT DATE REV BY' COPvLENTS PRUDHOE BAY UNIT 06/04/85 1418E OIG COMPLETION(A-34A) 04/05/11 RCT/PJC SET XX PLUG(04/02/11) WELL: A-34A 01/12/05 N4t98 RWO 03/13/14 TAO/JMD ADDED SAI-tlY NOTE PERMIT Pb:'1851050 06/03/08 N46 RWO 03/06/15 SVI CIPJC GLV C/O API No: 50-029-21339-01 06/06/08 TLH CORRECTIONS 03/08/15 PJC REFORMAT WBS SEC 35,T11 N,R13E,1171'FTC&921'FEL 06/28/08 GJB/SV GLV C/O(06/25/08) 10/01/08 MD/JMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612, Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 5a AUG 1 7 e°12. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue t� " 5 Anchorage, Alaska 99501 6J � O , Subject: Corrosion Inhibitor Treatments of GPB A -Pad 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A-03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A-04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA _ 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 e 3? A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 • UNDER EVALUATION: A-3~(PTD #1851050) Sustained OA Casin~ressure Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, March 12, 2009 5:01 PM t Z To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC3 Wellpad Lead; GPB, GC3 OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Cismoski, Doug A; Reem, David C Cc: Quy, Tiffany; Hibbert, Nancy; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: A-34A (PTD #1851050) Sustained OA Casing Pressure Attachments: A-34A TIO Plot.doc; A-34A.ZIP Ali, )-~~` Well A-34A (PTD #1851050) has been confirmed to have sustained casing pressure on the OA. The wellhead pressures were tubing/IA/OA equal to SSV/820/1010 on 03/10/09 when the OA pressure was bled to 0 psi. The OA repressured to 870 psi overnight. The well was worked over in June 2008 to repair a surface casing leak. It is unclear at this time in the high OA pressure is due to communication from the IA or due to a shallow gas source. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. Lab: Obtain IA and OA gas samples for analysis 2. DHD: Bleed IA and OA pressure to 0 psi ~ 3. Wellhead: PPPOT-IC to confirm pack-off seals are holding 4. DHD: Conduct an OA repressure test to determine if OA repressurization has been mitigated. A TIO plot and wellbore schematic have been included for reference. «A-34A TIO Plot.doc» «A-34A.ZIP» ,~ Please let us know if there are any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/15/2009 PBU A-34A PTD #1851050 3/12/2009 TIO Pressures a,or~a ~._._~. 3,000 -~- T bg ^ IA z,ooo -~-- oa oo.a oooa 1,000 ~ ~ On 12!13108 12120108 1212?108 01!03!09 01110!09 01/1?109 01/24109 01/31109 0210?109 0211~f09 02121109 02128109 0310?109 • __ ~~,.. KB. ELEV - 75.69' BF. ELEV = 49.29' KOP = 3300' Max Angle = 15° @ 6500' Datum MD = 9023' DatumTVD= 8800'SS 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" 9-5/8" HES CEMENTER 9-5/8" CSG, 47#, L-80 HYD 563, ID = 8.681" 13-3/8" F.C. 13-3/8" CSG, 72#, L-80, ID = 12.347" u 2084' 2641' 2684' Minimum ID = 3.725" @ 8506' OTIS XN NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3636 3623 14 MMG DOME RK 16 06/25/08 5 5210 5153 14 MMG DOME RK 16 06/25/08 4 5781 5706 15 MMG SO RK 28 06/25/08 3 6354 6259 16 MMG DMY RK 0 06/03/08 2 6882 6768 15 MMG DMY RK 0 06/03/08 1 7497 7365 12 MMG DMY RK 0 06/03/08 8154' I~ 5-1 /2" HES X NIP, ID = 4.562" 8174' ~ 9-5/8" X 5-1 /2" BKR S-3 PKR, ID =4.750" 8217' 5-1 /2" HES X NIP, ID = 4.562" 5-1/2" TBG, 17#, 13CR-80 VAM TOP, .0232 bpf, ID = 4.892" 4-1/2" TBG STUB (05/26/08) I 8241' I 8229' -~ 5-1/2" X 4-112" X0, ID = 3.958" 8256' 9-5/8"X4-1/2"UNIQUEOVERSHOT 8274' 4-1/2" HES X NIP, ID = 3.813" 8295' I-I 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 0152 bpf, ID = 3.958" S OTES: WARNING: RADIO TRANSMITTER A-34A IN W ER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY W ELL WORK INVOLVING IXPLOSIVES CAN BEGIN -CONTACT DSO. ***4-1 /2" CHROME TBG*** 2117' 5-1/2" HES X NIP, ID = 4.562" I 8382' I 4-1/2" TBG STUB (01/06/05) 3361, I.14-1/2" HES X NIP, ID = 3.813" I 8390' 9-5/8" X4-1/2" UNIQUEOVERSHOT 8411' TBG SEAL ASSY 8435' 9-518" X 4-1/2" BOT PKR, ID = 3.813" 8478' I~ 4-1 /2" OTIS X NIP, ID = 3.813" 9-5/8" x 7" BKR LNR TOP PKR, ID = ? 1- 4-1/2" TBG, 12.6#, L-80 BTRS, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80 BUTT, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 05/28/85 A NGLE AT TOP PERF: 27° @ 8898' Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL I Opn/Sqz I DATE I SEE PAGE 2 FOR PERFORATION DATA TOP OF CEMENT ~~ TOP OF SAND I 1 PBTD - 7" LNR, 26#, L-80 BUTT, .0383 bpf, ID = 6.276" -I 9382' I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/85 N18E ORIG COMPLETION (A-34A) 10/18/08 PJC DRLG DRAFT CORRECTIONS 01/12/05 NOES RWO 06/03/08 NOES RWO 06/06/08 TLH CORRECTIONS 06/28/08 GJB/SV GLV C/O (06/25/08) 10/01/08 MD/JMD DRLG DRAFT CORRECTIONS 14-1/2" OTIS XN NIP, ID = 3.725" I 8533' ~ 4-1/2" WLEG, ID = 3.958" 8534' ELMD TT LOGGED 02/08/86 9002' I~ 7" MA RKER JOINT I PRUDHOE BAY UNff WELL: A-34A PERMfI- No: 1851050 API No: 50-029-21339-01 SEC 35, T11 N, R13E, 1171' FNL & 921' FEL BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: BHCS ON 05/28/85 ANGLE AT TOP PERF: 27° @ 8898' Note: Refer to Production DB for historical perf c SIZE SPF INTERVAL Opn/Sqz D/ 3-3/8" 4 8898 - 8912 O 03/: 3-3/8" 6 8916 - 8928 O 11/: 3-3/8" 4 8928 - 8948 C 09/( 3-3/8" 4 8953 - 8963 C 04/( 3-1/8" 6 8970 - 9002 C 01/( 3-3/8" 4 9006 - 9031 C 04/( 3-3/8" 4 9012 - 9016 S 12/( 3-3/8" 4 9021 - 9031 S 12/( 3-318" 4 9040 - 9051 S 12/( 2-7/8" 2 9051 - 9056 S 12/( DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/85 N18E ORIG COMPLETION (A-34A) 10/18/08 PJC DRLG DRAFT CORRECTIONS 01/12/05 NOES RWO 06/03/08 N4ES RWO 06/06/08 TLH CORRECTIONS 06/28/08 GJB/SV GLV C/O (06/25/08) 10/01/08 ?/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: A-34A PERMff No: 1851050 API No: 50-029-21339-01 SEC 35, T11 N, R13E, 1171' FNL & 921' FEL BP Exploration (Alaska) A-34A ~ ~'~b~~ STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~ tv~~ _`? 2Q0& 1. Operations Performed: ~ ~`~'~ ' ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ®Alter Casing - ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension - 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. • ®Development ^ Exploratory 185-105 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21339-01-00 7. KB Elevation (ft): 75 7' 9. Well Name and Number: PBU A-34A 8. Property Designation: 10. Field /Pool(s): ADL 028286' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9382 ' feet true vertical 9234 " feet Plugs (measured) None Effective depth: measured 8923 feet Junk (measured) None true vertical 8776 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2684' 13-3/8" 2684' 2684' 5380 2670 Intermediate 8773' 9-5/8" 8773' 8626' 6870 4760 Production Liner 881' 7" 8501' - 9382' 8355' - 9234' 7240 5410 ~~~~~ JUL ~; ~ 2DD8 Perforation Depth MD (ft): gggg~ - gg2g' Perforation Depth TVD (ft): 8751' - 8781' 5-1/2", 17# x 4-1/2", 12.6# 13Cr80 & L-80 8533' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker'S-3' packer; 9-5/8" x 4-1/2" Baker'S 8174'; 8295'; 8435' -3' Packer; 9-5/8" x 4-1/2" Baker packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut, pull and dress tubing 8241'. Cut, pull and dress 9-5/8" casing to 2083'. Run and cement 9-5/8" tieback with 143 Bbls Class 'G' w/ Gas Blok 803 cu ft . Clean out and run new 5-1/2" 17#, 13Cr80 to 8256'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 2,580 3,005 7,439 1,760 680 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ 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 Mackie Derrick, 564-5891 308-166 Printed Name Terrie Hubble Title Drilling Technologist _ ~ Prepared By Name/Number: ~ b~ Signature p Phone 564-4628 Date ~~/vp Terrie Hubble, 564-462 Form 10-404 Revised 04/2006 r ~. Submit Original Only .~ ~ ~J ~ ; , ~ S ~~~ ~iJ~ ~ ~ 20D6 7, a.o8 lat A-34A, Wel I History • Date Summary 5/15/2008 WELL SHUT IN ON : T/I/O: 200/180/0. FLUID LEVEL SHOT PROX 500'. SET H FASDRILL PLUG AT 8330' IN LE OF THE FIRST FU NT BELOW THE TOP PACKE MIT-T TO 3500 PSI. N®~- ZypSS ~ `YV`~ ~~~ ~ 5/15/2008 WELL SHUT IN ON ARRIVAL. PULLED PRONG FROM PX PLUG BODY AT 8331' SLM. MADE TWO ATTEMPTS TO PULL PLUG BODY FROM 8361' MD W/ 4-1/2" GR. MADE ONE ATTEMPT TO PULL PLUG BODY FROM 8361' MD W/4-1/2" GS. 5/16/2008 T/I/O=SSV/150/0+, Temp=S1. PPPOT-T (PASS), PPPOT-1C (PASS). Pre RWO. PPPOT-T: External Alemite check installed. Stung into test port (1300 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void until clean returns achieved. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: External Alemite check installed. Stung into test port (500 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void until clean returns achieved. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. ***Suspect Internal check is still installed.*** 5/16/2008 PULLED 4-1/2" PX PLUG BODY FROM X-NIPPLE AT 8361' MD. DRIFTED W/ 3.70" GAUGE RING TO 8400' SLM. RDMO, LEFT WELL SHUT IN AND TURNED OVER TO OPERATOR. 5/17/2008 T/I/0=200/180/0+. Temp=S1. Shoot TBG & IA FL pre TBG cut. TBG FL C~3 580' (10 bbls). IA FL C~ 1050' (56 bbls). 5/17/2008 WELL SHUT IN ON ARRIVAL: T/I/O: 200/180/0. FLUID LEVEL SHOT AT APPROX 500'. SET H FASDRILL PLUG AT 8330' IN THE MIDDLE OF THE FIRST FULL JOINT BELOW THE TOP PACKER. SURFACE CASING LEAK NOTICED IN THE PAST AND HAS NOT BEEN REPAIRED. VAC. TRUCK ON LOCATION. DHD INSPECTED CELLAR AND CONTAINMENT AREA AND DECIDED THAT ADDITIONAL PREPARATION IS NEEDED PRIOR TO CMIT TxIA TO 3500 PSI. PE INSTRUCTED TO MIT-T TO 3,000 PSI TO TEST PLUG AND IF PASS TO RIG DOWN. WILL WAIT ON DHD TO PREP CELLAR AND WILL COME BACK AFTER CMIT TxIA to 3500 PSI IS COMPLETED TO JET CUT THE TUBING. 5/18/2008 T/I/O =SSV/200/0. Temp = SI. Monitor for cellar liner & determine conductor size (SC leak) (gravel sample). A/L spool dropped. Heater on location on arrival and trunk placed in cellar. Cellar will need gravel removed for liner installation. Cellar is 32" deep. Gravel in cellar is flush with flutes. 13" SC & Conductor is 30" in diameter. Flutes are 8" - 12" deep with crude in flutes -2" below top of flutes. Obtained gravel sample for flash point. 5/18/2008 MIT-T TO 3000 PSI. PLUG PASSES. RIG DOWN. NOTIFIED PAD OP. WELL LEFT SHUT IN. FINAL T/I/O: 0/180/0. JOB COMPLETE. 5/18/2008 WELL SHUT IN ON ARRIVAL. T/I/O: 0/180/0 PSI. SLB 3.65" POWER CUTTER FOR TUBING CUT AT 8240,•. SURFACE AND VISUAL CONFIRMATION OF FIRING. POOH. WELL LEFT SHUT IN. FINAL T/I/0: 560/180/0 PSI. JOB COMPLETE. 5/18/2008 T/I/0= N/A/180/0. Temp= SI. Monitor for cellar prep upcoming FB CMIT for RWO prep (SC leak). Conductor size is unknown at this time due to ice and gravel frozen flush with the flutes. Installed heater in cellar. Cellar is 32" deep. Will require gravel removal to install liner. E-Line and LRS were on well to set mechanical plug and test TBG. 5/18/2008 T/I/0=0/180/0 MIT TBG to 3000# ***PASSFI~".** Pumped 3.8 bbls crude to reach test pressure tbg lost 140 psi in 1st 15 min and 40 psi in 2nd 15 min for a good test bleed back wellhead pressure rig down FWHP=0/200/0 Annulus valves open to gauges a-line still on well. Page 1 of 2 • A-34A, WeII History Date Summary 5/19/2008 T/I/0= 160/160/20 Temp=Sl Circ-Out TxIA (RWO).Pumped 5 bbls meth spear followed by 65 bbls 1% KCL down Tbg thru jet cut at 8240' up IA taking returns thru jumper to flowline. 5/20/2008 Circ-Out (RWO) Pumped 825 bbls [890 total] 1 %KCL down Tbg to jet cut at 8240' up IA taking returns thru jumper to flowline. Freeze protected TxIA with 151 bbls 120°f diesel. U-tubed for 1 hr. CMIT TxIA PASSED to 3500 psi. Pressured up TxIA to 3500 psi w/ 5.3 bbls diesel. 2nd test results= 1st 15 min T/IA lost 50/30 psi, 2nd 15 min T/IA lost 20/10 psi with a total of 110 psi loss in 30 min test. Bled back 9 bbls. Freeze protected flowline with 7 bbls meth, 80 bbls crude capped with 10 bbls diesel per WOA freeze protect procedure. Final WHP's= 0/0/0 "Annulus casing valves tagged and left open on departure". 5/20/2008 T/I/O = 0/0/0. Temp = SI. Assist FB with CMIT TxIA &Circ. (RWO prep). A/L spool dropped. Monitored OAP, flutes and cellar during Circ &CMIT. Final WHP's = 0/0/0. 5/24/2008 T/I/O=Vac/0/0; uIQ 14.1/16 CIW "H" BPV #250 thru tree for 4ES Decompletion; 1-2' ext. used, tagged C~ 96". Complete. 5/24/2008 Pulled 4-1/8" CIW "H" TWC thru stack. RKB=20.16. 18' ext used, tagged C~ 60". Page 2 of 2 • • BP EXPLORATION Operations Summary Report Legal Well Name: A-34 Common Well Name: A-34 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date From - To Hours Task Code NPT __ - 5/23/2008 10:00 - 13:30 ~ 3.50 RIGD ~ P 13:30 - 18:00 4.50 MOB P 18:00 - 21:00 3.00 RIGU P 21:00 - 23:00 2.00 RIGU P 23:00 - 00:00 1.00 RIGU P 5/24/2008 00:00 - 02:00 2.00 KILL P 02:00 - 02:30 I 0.501 KILL I P 02:30 - 05:00 I 2.501 KILL I P 05:00 - 06:00 I 1.001 WHSUR I P Start: 5/20/2008 Rig Release: 6/3/2008 Rig Number: Page 1 of 8 Spud Date: 5/1 /1985 End: Phase ', Description of Operations PRE R/D rig & equip & move off well X-16a. Stage equip & wait on Security for 1 1/2 hrs. PRE Move rig from X-16a to A-34. Moved 9 miles. PRE Spot in rig over well. Spot in pits & pipe shed. Set camp. R/U equip. Pad operator removed locks from wellhead. PRE Raise & scope up derrick. Con't to R/U equip. Spot Tiger Tank. A CEPT D RIG ~ 2300hrs. DECOMP R/U lines to tree & tiger tank. Install 2nd annular valve. DECOMP Take on seawater in pits. P/U lubricator & test to 500 psi. Pull BPV & UD lubricator. DECOMP Pressure test lines, 250/3500 psi, OK. Hold PJSM & review well program w/all hands. DECOMP Circulate well & displace diesel freeze protect out. SITP 0 psi. SIAP 0 psi. Pump 6 BPM C~ 650 psi. Pumped 605 bbls. S/D & monitor well. Drain stack. R/D lines. DECOMP Install TWC w/ T-bar. Pressure test plug from above w/ 3500_ test from below w/ 1000 psi for 10 min. 06:00 - 08:00 I 2.001 WHSUR I P 08:00 - 10:00 2.00 BOPSU P 10:00 - 15:00 5.00 BOPSU P 15:00 - 16:00 1.00 PULL P 16:00 - 17:30 I 1.50 I PULL I P 17:30 - 18:00 I 0.50 I PULL I P 18:00 - 18:30 0.50 PULL P 18:30 - 19:30 1.00 PULL P 19:30 - 00:00 I 4.501 PULL I P 5/25/2008 ~ 00:00 - 06:00 ~ 6.00 ~ PULL ~ P 06:00 - 06:30 I 0.501 PULL I P 06:30 - 10:00 I 3.501 PULL I P 10:00 - 11:00 1.00 CLEAN P 11:00 - 13:00 2.00 CLEAN P 13:00 - 18:00 5.00 CLEAN P 18:00 - 18:30 0.50 CLEAN P 18:30 - 22:00 3.50 CLEAN P DECOMP PJSM. Nipple down existing wellhead. Inspect threads on hanger, screw crossover into hanger to verify threads are good. DECOMP PJSM. N/U 13 5/8" x 5M BOPE. DECOMP PJSM. Conduct full test on BOPE. Test all rams and choke valves ~ 250 /low, 3500 psi high pressure. Test VBRs w/ 3 1/2" & 4 1/2" test joints. Test annular preventor w/ 3 1/2" test joint C~? 250 / 3500 psi. Witnessing of test waived by AOGCC rep Lou Grimaldi, 24 hour notice given. Rig down test equipment. DECOMP PJSM. Rig up lubricator, pressure test to 500 psi, OK. Pull two way check valve. DECOMP PJSM. M/U landing joint, BOLDs. P/U & Pull hanger free w/ 105K. Con't OOH w/ hanger (102K1. Break out & UD hanger & landing jt. DECOMP M/U head pin. Circulate bottoms up ~ 5 1/2 BPM, 270 psi. R/U floor & compensator to pull completion. DECOMP Crew change. Service rig. check PVT alarms. Inspect derrick. DECOMP Con't to circulate bottoms up. 5 1/2 BPM ~ 270 psi. Pumped total of 450 bbls. Con't to R/U floor to pull & UD completion. DECOMP POOH & UD 4 1/2" com letion. Using compensator to avoid pin damage. Marking any questionable jts. POOH w/ 65 jts. DECOMP Con't to POOH & UD 4 1/2" completion. Using compensator to avoid damage to tubulars. Marking any questionable jts. OOH w/ 150 jts. DECOMP Rig service, check crown o matic, PVT system, OK. Conduct daily derrick inspection. DECOMP PJSM. Continue to POOH w/ 4 1/2" completion. 190 jts total, & jewelry length of cutoff jt = 17.28', 4 7/8" OD. DECOMP PJSM. Set wear bushing, clear /clean rig floor. DECOMP PJSM. Pick u tubin dress off BHA and 6 1/4" DCs. DECOMP PJSM. RIH w/dress off BHA on 3 1/2" 15.5# drill pipe, picking up drill pipe 1 x 1 out of pipeshed. DECOMP Crew change. Service rig. Check PVT alarms. Inspect derrick. DECOMP Con't to P/U 3 1/2" DP 1x1 &RIH. Ran 250 jts. Printed: 6/30/2008 9:26:34 AM • BP EXPLORATION Operations Summary Report Page2of8~ Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: ,Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/3/2008 ',Rig Name: NABOBS 4ES Rig Number: Date From - To ~I Hours Task 'Code ~' NPT Phase ', 5/25/2008 22:00 - 23:00 I 1.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 5/26/2008 100:00 - 02:00 I 2.001 CLEAN I P 02:00 - 04:30 I 2.50 I CLEAN I P 04:30 - 06:00 I 1.501 CLEAN I P 06:00 - 06:30 I 0.50 I CLEAN I P 06:30 - 08:30 2.00 CLEAN P 08:30 - 09:30 1.00 CLEAN P 09:30 - 10:00 0.50 CLEAN P 10:00 - 11:00 1.00 EVAL P 11:00 - 14:30 3.50 EVAL P 14:30 - 16:00 1.50 EVAL P 16:00 - 16:30 0.50 DHB P 16:30 - 18:00 1.50 DHB P 18:00 - 18:30 0.50 DHB P 18:30 - 19:00 0.50 DHB P POOH & UD runn P/U & M/U BHA # 19:00 - 21:00 I 2.001 DHB I P I ITIEBI 21:00 - 22:00 1.00 DHB P TIEB1 22:00 - 23:30 1.50 CASE P TIEB1 23:30 - 00:00 0.50 CASE P TIEB1 5/27/2008 00:00 - 01:00 1.00 CASE P TIEB1 01:00 - 02:00 1.00 CASE P TIEB1 02:00 - 04:00 2.00 CASE P TIEB1 04:00 - 06:00 2.00 CASE P ITIEBI Description of Operations on top of plug., Displace out DP. Allow Finish M/U 9 5/8" cutting assy. RIH w/ BHA #2 to cut casing. Locate casing collar ~ 2060'. Space out cutter to 2080'. 22 stands, BHA + 15' Kelly. Displace we ore w 120 degree seawater. Pump 6 BPM ~ 780 psi. Begin rotation & Cut casing in 12 min. Con't to rotate, casing in compression. rotary table stalled. Had to pul cutters ree w over pu . cutte- r stud Work pipe & free string w/ 80K over pull. P/U & UD kelly. P/U Wt = 45K, S/O wt = 45K, Rot Wt = 45K. 75 RPMs, free torq 1000 ft-Ibes. Stalled out (~ 10K ft-Ibs. P/U & UD kelly. P/U 10' pup & circuating head. Hold PJSM w/ DECOMP Hold weekly safety meeting w/ all hands. Discussed recent rig incidents & stop cards. DECOMP Con't to P/U 7 additional jts, 10' DP pup & kelly. Break circulation Scrape casing & tag up on tubing stub ~ 8240'. _ DECOMP Break circulation, 3 BPM ~ 320 psi. Mill down over stub & swallow 15' to 8255'. P/U off stub & took weight when going back over. Mill & dress off 1' of tubing stub to 8241'. P/U Wt = 140K, S/O Wt = 132K, Rot Wt = 136K. 5 BPM ~ 850 psi. 55 / 85 RPMs, WOB = 3-5K. Torq = 2.5 -4K ft-Ibs. P/U off stub & S/O Had to rotate slightly to go back over top, then slid to bottom w/o problem. DECOMP P/U 1' & close annular. Reverse circulate 5 BPM C«~ 1220 psi. Pumped 40 bbls Hi-Vis sweep Pumped total of 595 bbls. Recovered small amount of V.F. sand & metal millings. DECOMP Set back kelly, 10' pup & 1 single. Scrape casing 4 times over 8175' interval. UD 1 more single & POOH & stand back 3 1/2" DECOMP Service rig, check PVT system, crown o matic, OK. Daily derrick inspection performed. DECOMP PJSM. Continue to POOH w/ 3 1/2" DP and dress off BHA. DECOMP PJSM. Stand back collars, lay down dress off BHA. Good indication of making contact with and milling off top of tubing stub on inner face of dress off mill. DECOMP Clear /clean rig floor. TIE61 PJSM. Rig up Schlumberger E line. TIEB1 Perform USIT log, logging from 3000' to surface. Good indication of to of cement ~ 2130'. Discussed with senior engineer in town. TIEB1 PJSM. Rig down Schlumberger E line services. TIEB1 PJSM. Pick up Halliburton 9 5/8" 47# retrievable bridge plug. TIEB1 PJSM. RIH w/ Halliburton bridge plug on 3 1/2" DP to 2225'(+ -). Attempt to set RBP ~ 2250' No good. appear to be on a collar. TIEB1 P/U 20' to 2231' Center of element ~ 2236'. Set RBP w/ 15K, P/U wt = 53K, S/O Wt = 53K. Pull 1 stand & verif lu is set TIE81 Pressure test RBP to 1500 si for 15 min. tested Ok. Charte test. Printed: 6/30/2008 9:26:34 AM • BP EXPLORATION Page 3 of 8 Operations Summary Report Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/3/2008 Rig Name: NABORS 4ES Rig Number: Date I From - To Hours II Task Code NPT Phase Description of Operations 5/27/2008 04:00 - 06:00 2.00 CASE P TIEB1 all hands. R/U Hot oilers & PT lines to 4000 psi. Break circulation w/ seawater. Pumped 10 bbls. Follow w/ Hot diesel 130 degrees ~ 1 BPM, 100 psi. 06:00 - 09:00 3.00 CASE P TIEB1 PTSM. Continue to pump heated diesel w/LRS, pumped 100 bbls total. Crude coming ac in returns, no arc is pac present in this well. Pump 50 bbls sweep and chase with heated seawater to clean seawater returns, taking all returns to open top tank. 09:00 - 10:00 1.00 CASE P TIEB1 PJSM. POOH w/ 3 1/2" drill pipe and multistring cutting assembly. 10:00 - 10:30 0.50 CASE P TIE61 Break out and lay down multi-string cutter BHA. 10:30 - 11:30 1.00 CASE P TIEB1 Clear and clean rig floor and rig up casing handline tools. 11:30 - 13:00 1.50 CASE P TIEB1 Pick up 9-5/8" casing spear. Engage 9-5/8" casing. BOLDS. Unland 9-5/8" casin and hoist mandrel ackoff and han er to ri floor. Break out and lay down casing packoff and hanger. 13:00 - 17:00 4.00 CASE P TIEB1 POH laying down 9-5/8" casing. Connections extremely tight and some connections are eing egged when breaking out. OOH w/ 28 jts. 17:00 - 18:30 1.50 CASE P TIEB1 Getting some gas bubbles to surface from oil being wiped off casing. Circulate out oil & small amount of aas. Pumped 6 BPM ~ 200 psi. Wellbore cleaned up. 18:30 - 19:00 0.50 CASE P TIEB1 Check PVT alarms, Inspect derrick. Service rig. 19:00 - 20:30 1.50 CASE P TIE61 Con't to POOH & UD 9 5/8" casing. connections are very tight. Tongs crushing tubes. OOH w/ 35 jts. 20:30 - 21:00 0.50 CASE P TIEB1 Had some oil & gas bubbles to surface. Circulate well ~ 6 BPM C~3 130 psi. Pumped 75 bbls & well cleaned up. 21:00 - 00:00 3.00 CASE P TIE81 Con't to POOH & UD 9 5/8" casing. Connections very tight. Tongs crushing tubes. Pulled & UD total of 52 jts, + 20.40' cut off jt. Also recovered 10 turbolators. Cut ve 'a ed from being run in compression. See photos. 5/28/2008 00:00 - 02:00 2.00 CASE P TIEB1 Clear & clean rig floor. Floor very dirty from residual oil from casing. R/D false bowl & casing tools. 02:00 - 04:30 2.50 CASE P TIEB1 P/U & M/U BHA #3 to dress casing stub as follows: Dress Off Shoe, Ext. W/O Boot Basket, Dress Off Mill, PxP Sub, Casing Scraper, Bit Sub, Jars, PxP Sub, Bit Sub w/ Float, 6 ` 6 1/4" DCs, X-Over. TL = 219.63'. 04:30 - 07:00 2.50 CASE P TIEB1 RIH w/ 9 5/8" Dress off assy. Stage in hole. Break circ every 5 stands &circ out Arctic Pak. 07:00 - 08:00 1.00 CASE P TIE61 Kelly up and circulate surface to surface to clean up hole and prepare to dress stub. 08:00 - 10:30 2.50 DRILL P TIEBi D to 9-5/8" casin stub @ 2081'. Obtain milling parameters: PUW/SOW = 55K w/kelly, free torque = 1500 ft-Ibs., RPM = 50, pump rate and pressure = 5.5-bpm @ 250-psi. Skim cut top of casing stub to remove hang nail on top. Mill total of 2' oft to of stub. New 9-5/8" casin stub de th = 2083'. 10:30 - 12:30 2.00 DRILL P TIEBi Mix and pump 35-Bbl. Flo-Vis sweep surface to surface ~ 6.0-bpm and 250-psi to ensure a clean and tidy hole and casing stub. 12:30 - 13:00 0.50 DRILL P TIEB1 POH w/17 stands DP. 13:00 - 14:30 1.50 DRILL P TIEB1 PJSM. Slip and cut drilling line. 14:30 - 15:00 0.50 DRILL P TIEB1 POH & stand back DCs. 15:00 - 17:30 2.50 DRILL P TIEB1 Break out & UD BHA #4. Recovered 1/3 bucket of metal shavings. Inspected mill, good indication of wear pattern on Printed: 6/30/2008 9:26:34 AM ~ ~ BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: Contractor Name: NABOBS ALAS KA DRI LLING I Rig Release: 6/3/2008 Rig Name: NABOBS 4ES Rig Number: Date ~I From - To Hours I Task Code NPT Phase Description of Operations 5/28/2008 15:00 - 17:30 2.50 DRILL P TIEB1 inner mill. 17:30 - 18:00 0.50 DRILL TIEB1 P/U spear & release cut off jt from spear grapple. UD same. 18:00 - 18:30 0.50 DRILL P TIEB1 Crew Change. service rig. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 CASE P TIEB1 P/U RTTS &RIH to 508' Set RTTS. 19:00 - 20:30 1.50 CASE P TIE61 Pressure test below RTTS to 2000 psi, hold for 10 min. Testes good. Monitored conductor x 13 3/8" annulus.. no indication of pressure or I~ak. Pressure uq above RTTS ~ 508' to 15~s 5/29/2008 held for 15 min...no real leak off. Notified town engineer of results. 20:30 - 21:30 1.00 CASE P TIE61 Unset RTTS & allow to relax. POOH & stand back DCs. Clean & L/D RTTS. 21:30 - 23:30 2.00 CASE P TIE61 Clear & clean rig floor. R/U Torque Turn equip. & false bowl. R/U floor to run casing. 23:30 - 00:00 0.50 CASE P TIEB1 Hold PJSM w/all hands. Review casing running order. Assign tasks to specific personnel. 00:00 - 06:30 6.50 CASE P TIEB1 P/U &RIH w/ 9 5/8" 47#, L-80, Hyd 563 Tie-Back casin .Ran 52 jts. Baker o 'd all connections below ES Cementer. Torq Turned connections to 15200 Ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections. no bad connections experienced while running casing. Engaged 9-5/8" casing stub with Bowen casing patch. Applied 30K downweight and pulled 30K over string weight. Slacked off total string weight (96K) onto patch. Pull tested casing to 250K. 06:30 - 07:30 1.00 CASE P TIEB1 Pressure tested casing and casing patch seals to 2000-psi for 30-charted minutes. Good test. Sheared o en ES cementer with 2800-psi and verified circulation throw h cementer. 07:30 - 08:00 0.50 CASE P TIEB1 PJSM - ND/NU BOPE. 08:00 - 09:00 1.00 CASE P TIEB1 Split tubing spool from casing speed head and set McEvoy casin sli s/ ackoff with 100K tension. Cameron wellhead tech RILDS. 09:00 - 10:00 1.00 CASE P TIEBi Makeup tubing spool to casing speed head. Inflate and test boot seals on flow riser. 10:00 - 10:30 0.50 CASE P TIE61 Pressure test tubing spool/casing s e - Lo/1000- si Hi for 5-charted minutes each res 10:30 - 12:30 2.00 CASE P TIEB1 Circulate heated seawater to achieve 80F returns while rigging up Schlumberger cementers. 12:30 - 13:00 0.50 CASE P TIEB1 PJSM -All rig, Schlumberger, CH2MHill, Halliburton and MI personnel. Reviewed cement job pumping plan and HSE issues with regard to high pressure pumping and fluid transfers. 13:00 - 13:30 0.50 CEMT P TIE61 Prime up and pressure test lines and cement head to 500-psi Lo/4500-psi Hi. 13:30 - 15:30 2.00 CEMT P TIEB1 Batch up tub of 15.8-ppg cement Pumped 143-Bbls. 15 8-noa Class G cement w/gas block mixing on the fly at 5.0-bpm C~ 180-300 psi while taking returns through Super Choke to rig pits. Shut down pumping and dropped wiper plug. Closed Super Choke to keep cement column in place. Opened Super Choke. Resumed pumping seawater at 5.0-bpm displacing cement with seawater. Swapped to taking returns to open top tank at 90-Bbls. displacement away. Noted neat cement returns at 128-bbls. displacement away. Slowed rate to 1.0- om at 40-bb s. isolacement awav. Calculated Printed: 6/30/2008 9:26:34 AM • BP EXPLORATION Operations Summary Report Page 5 of 8 Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/3/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/29/2008 113:30 - 15:30 15:00 - 15:30 15:30 - 18:00 18:00 - 21:30 21:30 - 23:30 23:30 - 00:00 5/30/2008 00:00 - 04:00 04:00 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 18:30 2.00 CEMT P TIEB1 displacement to bump plug = 151.5-Bbls. Bumped plug at 154.5-Bbls. displacement away. Bled off pressure slowly from O/A. Final displacement pressure = 810-psi. Increase - si to close ES cementer. Increased pressure to 2500-psi and held for 3-minutes to verify ES cementer closed. Bled off pressure and recovered 1.5-Bbls. fluid calculated to bleed off pressure to cementer. Verified r~ flow from 9-5/8" casin to cementers and no flow from O/A to o en to tank. Flushed O/A valves to open top tank with seawater from rig pits. Blew down Schlumberger cementers lines and rig lines with air. RDMO Schlumberger cementers. Note: At no time before, during or after pumoina cement iob were there anv indication of returns from leak in 13-3/8" casina 0.50 CEMT P TIEB1 PJSM -All rig personnel and Cameron wellhead tech. Reviewed nipple down and cut casing procedures. Notified AOGCC -Jeff Jones, of desire to perform weekly BOPE test a day earlier than the required 7 day interval. AOGCC right to witness test waived by Jeff Jones. 2.50 CEMT P TIE61 ND BOPE. Cameron wellhead tech. cut 9-5/8" casing with Wachs cutter. Laid down cut joint. Cut joint length = 27.42'. Set back BOPE and ND tubing spool. 3.50 CEMT P TIE61 Replaced 1 lock down screwon casing head. NU new McEvoy SSH 13-5/8" x 13-5/8" 5M tubing spool with pre-loaded YBT 9-5/8" casing packoff per Cameron wellhead tech. Pressure test pack off to 3800 psi for 30 min. 2.00 CEMT P TIE61 Install Flange & 2nd annular valve on new tubing spool. N/U BOPE. R/U test equip. Install test plug. Notified Well Tie-In supervisors of readiness for them to take measurements for future well tie-in. 0.50 CEMT P TIEB1 Begin pressure testing ROPE as per BP/AOGCC re~uir _mants 4.00 BOPSU P TIEB1 Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Test 12 valves on choke manifold. TIW valve & VBRs w/ 3 1/2" test jt. Could not get annular to test. Call for replacement. Con't to test VBRs failed on 5 1/2" test jt. Call for new 3-1/2" x 6" VBRs. 4.50 BOPSU N RREP TIEB1 PJSM. Change out annular element. 1.00 BOPSU N RREP TIEB1 PJSM. Changeout 3-1/2" x 6" VBRs. 2.50 BOPSU P TIEB1 Resume pressure testing BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Tested 3-1/2" x 6" VBR's with 3-1/2" and 5-1/2" test joints. Tested annular preventer with 3-1 /2" test joint. Tested upper and lower kelly cock valves and performed Koomey test. Rigged down test equipment. 3.00 DRILL P TIEB1 PJSM. PUMU shoe track cleanout BHA as follows: 8-1/2" bit, 7" boot basket, 9-5/8" scraper, bit sub, 6-1/4" oil jar, XO, 6' 6-1/4" drill collars, XO = 207.09'. Well Tie-In surveyors took measurements for future well tie-in. 1.00 DRILL P TIEBi RIH w/cleanout BHA on 3-1/2" DP from derrick. 2.00 DRILL P TIEB1 Ta cement C«~ 2023'. Kelly up. Establish drilling parameters: PU/SO wt. w/kelly = 55K/53K, 5.5-BPM ~ 250-PSI, 65-RPM and 1200 ft.-Ibs. free torque. 0.50 DRILL P TIEB1 Crew change. Service rig. Inspect derrick. Check PVT alarms. Printed: 6/30/2008 9:26:34 AM BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/3/2008 Rig Name: NABOBS 4ES Rig Number: I ! Task Code NPT Phase Description of Operations Date From - To Hours 5/30/2008 18:30 - 21:00 2.50 DRILL P TIEB1 Con't to drill out shoe & cement. drill from 2060 to 2066'. Finish washing kelly down to 2079'. P/U Wt = 55K, S/O Wt = 53K, Rot Wt = 54K, 75 RPMs, WOB = 2-6K. Torque = 1.5K ft-Ibs. Pump 5.5 BPM @ 270 psi. 21:00 - 22:00 1.00 DRILL P TIEB1 Circulate & Pump 30 bbl Hi-Vis sweep. Recovered rubber, cmt & aluminum. Pumped 5.5 BPM ~ 290 psi. 22:00 - 23:00 1.00 DRILL P TIE61 Rotate & wash down to 2181'. Rotate thru cement /junk. Tag u fill ~ 2183' Wash down 2' into sand. Pump 30 bbl Hi-Vis sweep, recovery cmt, rubber, Aluminum & sand at the end of sweep. 23:00 - 00:00 1.00 DRILL P TIEB1 Set back kelly, blow down lines. POOH & stand back DP & DCs. 5/31/2008 00:00 - 01:00 1.00 DRILL P TIEB1 Break out & UD BHA. Recovered, 20# of cement & aluminum millings w/ 3 pcs of metal. All 10 scraper blade springs were broken. 01:00 - 02:00 1.00 CASE P TIEB1 R/U & close in blind /shear rams. Pressure up & test casing to 3500 si or min. a e es . es a es egwp. 02:00 - 03:00 1.00 CASE P TIE61 P/U & M/U RCJB Assy as follows: RCJB, Bit Sub, X-Over, 6' 6 1/4" DCs, X-Over, Pump Out Sub. TL = 195.51' 03:00 - 03:30 0.50 CASE P TIEBi RIH w/ RCJB ass . 03:30 - 04:00 0.50 CASE P TIEB1 P/U kelly & tag up ~ 2186'. Break circulation & wash down to 2208' pumped 4 BPM ~ 1950 psi. P/U Wt, S/O Wt & Rot Wts = 50K. Rotated ~ 45 RPMs. 04:00 - 05:30 1.50 CASE P TlEB1 POOH & stand back DP &DCs. Well U-tubing. Drop bar & open pump out sub. Con't to POOH. 05:30 - 07:00 1.50 CASE P TIE61 Break out & empty RCJB. Recovered 7 large pieces of aluminum ES cementer and small amount of rubber pieces which indicate 2/3 of wiper plug seat recovered. Redressed pump out sub and recovered ball from RCJB. 07:00 - 08:00 1.00 CASE P TIE61 RIH w/RCJB BHA and to TOS at 2186'. 08:00 - 10:00 2.00 CASE P TIEB1 Dropped RCJB ball, kelly up and establish circulation with 38-Bbl. Hi-Vis sweep at 5.5-BPKM at 1600-2200 PSI. R4S;3I~ and wash RCJB down to 2217'. Continue circulating sweep around and recovered large amount of sand and rubber. Break off kelly and drop ball and rod. makeup kelly and pump ball and rod on seat and shear open pump-out sub at 2400-psi. Break out kelly, blow down same and set back in shuck. 10:00 - 11:00 1.00 CASE P TIEB1 POOH & stand back DP &DCs. 11:00 - 11:30 0.50 CASE P TIEB1 Break out and lay down RCJB. Recovered 5 large pieces of aluminum from ES cementer and two small pieces of rubber. 11:30 - 13:00 1.50 CASE P TIEB1 PJSM. RIH w/9-5/8" RBP retrieval overshot. Taa sand at 2214'. 13:00 - 14:00 1.00 CASE P TIEB1 Makeup headpin/floor valve and circulating hose. Close annular preventer and reverse circulate sand down to RBP ~ 2227'. Reverse circulate hole clean and latch up on RBP. 14:00 - 14:30 0.50 CASE P TIEBi Release RBP with left hand torque and 15K upweight over string weight per Halco serviceman. RIH past original set depth and CBU. 14:30 - 16:00 1.50 CASE P TIEB1 POH standing DP and DC's in derrick. Conducted BOP drill while tripping. All hands reported to assigned stations as per requirements and well was shut in efficiently and safely within 1.5 minutes from time drill was initiated. Post drill review of drill Printed: 6/30/2006 9:26:34 AM ~J BP EXPLORATION Operations Summary Report Page 7 of 8 Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/3/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours '~~ Task Code NPT 5/31/2008 14:30 - 16:00 1.50 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 18:30 2.00 CASE P 18:30 - 22:00 22:00 - 23:00 23:00 - 00:00 6/1/2008 00:00 - 06:00 06:00 - 07:00 07:00 - 08:00 08:00 - 11:00 11:00 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 15:00 15:00 - 15:30 15:30 - 17:00 17:00 - 00:00 3.50 CASE P 1.00 CASE P 1.00 CASE P 6.00 CASE P 1.00 DHB N WAIT 1.00 DHB N WAIT 3.001 BOPSURN IWAIT 0.50 DHB N WAIT 0.50 CASE P 1.00 CASE 0.50 CASE P 1.50 BUNCO 0.50 BUNCO 1.50 BUNCO 7.001 RUNC01~I1N IWAIT Phase Description of Operations - -- TIE61 effectiveness and safety with all hands. TIEB1 Break out and lay down Halco 9-5/8" RBP per Halco serviceman. RBP 100% intact. No foreign objects or materials noted on top of RBP when pulled through rotary table. TIEB1 PJSM. PUMU milling BHA as follows: 8-3/8" cut lip guide, 8-1/8" TSWP bushing, 5-3/4" TSS extension, 3-5/8" convex mill, 5-3/4" TSS shear guide assy., 11 jts. 2-7/8" PAC DP, XO, 6-1/4" oil jar, XO, 6' 6-1/4" drill collars, XO, 3-1/2" IF pump-out sub. TIEBi RIH w/milling BHA on 3 1/2" DP. TIEB1 Ta Fas-dril lu ~ 8322'. P/U kelly & break circulation, 4 BPM ~ 910 psi. Tag up & wash 4' of debris off top of plug to 8326' Mill plug, lost circulation after 1'. RIH w/ remainder of kelly. Had a little torq when started to mill, apparently some junk on top of plug. P/U Wt 140K, S/O Wt = 125K. Rot Wt = 135K. 70 RPMs, Free Torq = 2K ft-Ibs. TIEB1 Set back kelly & chase plug out tubing tail to 8541'. (WLEG ~ TIEB1 POOH & LDDP. Had some trouble pulling off tubing stub, apparently trash fell over 8 1/8" guide. Once out of stub, no problems. Stop POH w/23 jts. and BHA in hole. Call for Halco storm packer. Stab floor valve and close annular preventer. aintain +60- h hole fill. TIEB1 Wait on Halco serviceman to arrive with storm packer. TIEBi RIH w/9-5/8" Halco storm packer and set at 35', Hanging weight on packer = 40 pac er o -psi or -c arted minutes. Pull wear ring and set test plug. RILDS. Change out 3-1/2" x 6" VBR's for rebuilt set of 3-1/2" x 6" VBR's fromfrom NOC. TIEB1 Change out 3-1/2" x 6" VBR's for rebuilt set of 3-1/2" x 6" VBR's from NOC. Pressure test VBR pipe rams with 3-1/2" and 5-1/2" test joints. , TIEB1 RIH with retrieving tool and open packer storm valve. Check DP for pressure/vacuum. No pressure/vacuum noted. Release packer and monitor well. Well on strong vacuum. Commenced filling hole with charge pump at 140-BPH. POH and L/D storm acker. TIEB1 Resume POH laying drill pipe and milling BHA down 1 x 1 through pipe shed. TIEB1 BOLD FasDril milling BHA. TIE61 Clear and clean rig floor. RUNCMP RU floor with 5-1/2" tubing handling tools: Single joint elevators, single joint compensator, double stack tongs and torque turn equipment. RUNCMP PJSM. Reviewed RP for running/handling chrome tubing and rig specific running/handling procedure. RUNCMP PU and RIH w/completion BHA: 4-1/2" x 9-5/8" Unique chrome guided overshot, 4-1/2" x 5-1/2" XO, "X" nipple assy., 2 x 5' 5-1/2" 13Cr80 TCII pups, Baker 5-1/2" x 9-5/8" S-3 packer. torque turning and Baker-Locking thread connections. Galled thread connection between packer assy. and 2 x 5' pup joint assy. Layed packer assy. and pup joint assy. down and sent into Baker Machine for re-threading. RUNCMP Wait on packer and pup joint assy. to return from Baker Printed: 6/30/2008 9:26:34 AM BP EXPLORATION n Page 8 of 8 Operations Summary Report Legal Well Name: A-34 Common Well Name: A-34 Spud Date: 5/1/1985 Event Name: WORKOVER Start: 5/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/3/2008 Rig Name: NABOBS 4ES Rig Number: Date ;From - To ~~ Hours Task ~ Code NPT ~'~~ Phase 6/1/2008 17:00 - 00:00 7.00 6/2/2008 00:00 - 00:30 0.50 00:30 - 01:00 0.50 01:00 - 01:30 0.50 01:30 - 15:00 13.50 Description of Operations WAIT RUNCMP Machine shop. WAIT RUNCMP Con't to wait on re-threading of assys. RUNCMP Hold PJSM & review running order, well control & assign specific tasks to personnel. Re-measure assys w/ re-cut pins. RUNCMP P/U & M/U completion tail pipe assys, Baker-lok &RIH. RUNCMP ['on't to RIH w/ 5 1/2" 17#. 13Cr-80 Vam Too HC tubing. Torque turn all connections to 6580 ft-Ibs. Used Jet Lube Seal Guard thread compound on all connections. Ran in hole w/ 65 jts ~ 0600 hrs. Called for 580-Bbls. 120E seawater w/.006 gallons per bbl. of EC1124A corrosion inhibitor mixed at 06:45-hrs. to be on pad at 13:00-hrs. RIH w/192 jts. RUNCMP Obtain landing parameters: P/U Wt. = 142K, S/O Wt. = 131 K. Ta 4-1/2" tubin stub at 8 246'. Ease guided overshot over stub and note both sets of shear pins shearing. Tag stub with No-Go and apply additional 15K downweight. P/U to neutral + additional 2' leaving 25' in on jt. #192. Calculated spaceout to obtain 9.23' of swallow. Layed down joints #192, #191 = 39.23' and #190 = 41.85'. Picked joint #191 back up and replaced joint #190. Picked up jt. of 37.32' in length and made up tubing hanger and landing joint with closed TIW valve. Landed tubing hanger_and RILDS. RUNCMP Reverse circulate in 580-Bbls. packer fluid at 3.0-BPM ~ 40 psi. RUNCMP Drop Ball /Rod & allow to fall. Fill tubing w/ 41 bbls (FL ~__ 15:00 - 17:30 17:30 - 21:00 21:00 - 00:00 2.50 3.501 RUN 3.OO RUN I pressure to 3500 psi & test tubing for 30 min. Bleed tubi~Cn re up to 3500 re to bleed to 0 psi. Pump thru tubing & IA to insure 6/3/2008 00:00 - 00:30 00:30 - 01:30 0.50 1.00 BUNCO BUNCO RUNCMP RUNCMP R/D test equip. Blow down lines. Drain stack. T-bar TWC into han er. Pressure u & test TWC from above & below to 1000 si for 10 min Test Ok. Charted testing. 01:30 - 02:30 1.00 BOPSU RUNCMP N/D BOPE. Set stack back. 02:30 - 04:30 2.00 WHSUR RUNCMP N/U adapter flange. Test hanger void to 5000 psi, Tested Ok. N/U X-mas tree. Attempt to test tree. TWC leaking. 04:30 - 10:30 6.00 WHSUR RUNCMP P/U lubricator & ressure test to 500 si. Pull & check TW Reset same. P!f tree to 50 - si. Crew change. Pre-tour HSE/Ops meeting. Check PVT alarms, derrick inspection and rig service. 10:30 - 12:00 1.50 BUNCO RUNCMP MIRU LRS. PJSM. Reviewed freeze protection procedure and assigned tasks to individual crew members. LRS P!T lines to 3500-psi. Freeze protect well with 140-Bbls. diesel pump at 2.0-bpm at 150-psi. 12:00 - 13:00 1.00 WHSUR RUNCMP Weekly rig HSE meeting. Reviewed last weeks ADW HSE incidents and how they relate to our operations. Allow diesel to U-tube for 1 hr. 13:00 - 13:30 0.50 WHSUR RUNCMP Well equalized. T/I/O = 0/0/0. 13:30 - 15:00 1.50 WHSUR RUNCMP Cameron wellhead tech. dry rod set BPV verifying adequate travel to ensure 100% engagement of BPV in hanger profile. LRS pressure test BPV from below to 1000-psi for 10-charted minutes. RIG RELEASED AT 15:00-HRS. Printed: 6/30/2008 9:26:34 AM TREE = 7-1/96" x 6-3/8" CMJ WELLHEAD = McEVOY ACT;JATOR = CMJ KB. ELEV = 75.69' BF. ELEV....- 49.29' KOP = 3300' Max Angle = 15 @ 6500' Datum MD = 9023' Datum TV D = 8800' SS .. 20" CONDUCTOR 91.5#, H-40 9-5/8" SCAB CSG, 47#, L-80HYGBTC, ID = 8.681" 13-3/8" CSG, 72#, L-80, ID = 12.347" --~ 2084' 2684' 2060' ~ 9-518" HES CEMENTE32 2117' -~ 5-112" X I~UPPLE, ID = 4.562"' GAS LIFT MANDRELS ^ ST MD TV D DEV TYPE V LV LATCH PORT DATE 6 3636 3623 14 MMG DOME RK 16 06/25/08 5 5210 5153 14 MMG DOME RK 16 06/25/08 4 5781 5706 15 MMG SO RK 28 06/25/08 3 6354 6259 16 MMG DMY RK 0 06/03/08 2 6882 6768 15 MMG DMY RK 0 06/03/08 1 7497 7365 12 MMG DMY RK 0 06/03/08 Minimum ID = 3.725" @ 8506' OTIS XN NIPPLE SIDETRACK 2861' - 2982' 5-1/2" TBG, 17#, 13CR, .023 bpf, ID = 4.892" I-I 8241' 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" I-i 8382' TOP OF 7" LNR I• 4-1/2" TBG, 12.6#, L-80, IP CAB , .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 05/28/85 ANGLE AT TOP PERF: 27 @ 8898' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8898 - 8912 O 03/28/00 3-3/8" 6 8916 - 8928 O 11/27/96 3-3/8" 4 8928 - 8948 C 09/01/92 3-3/8" 4 8953 - 8963 C 04/01/92 3-1/8" 6 8970 - 9002 C 01/01/91 3-3/8" 4 9006 - 9031 C 04/01/92 3-3/8" 4 9012 - 9016 S 12/01 /90 3-3/8" 4 9021 - 9031 S 12/01/90 3-3/8" 4 9040 - 9051 S 12/01/90 2-7/8" 2 9051 - 9056 S 12/01 /90 8154' --~ 5-1/2" X NIPPLE, ID = 4.562" I 8174' 9-5/8" X 5-1/2" BAKER S-3 PKR. 8217' 5-1/2" X NIPPLE, ID = 4.562" 8241' 9-5/8"X4-1/2"UNIQUEOVERSHOT 8274' 4-1/2" HES X NIP, ID = 3.813" 8295' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8361' 4-1/2" HES X NIP, ID = 3.813" 8390' 9-5/8" X 4-1/2" UNIQUEOVERSHOT 8411' TBG SEAL ASSY 8435' 9-5/8" X 4-1/2" BOT PKR, ID = 3.813" $47$' 4-1/2" OTIS X NIP, ID = 3.813", 8506' 4-1/2" OTIS XN NIP, ID = 3.725"~ 8533' 4-1/2" WLEG, ID = 3.958" 8534' ELMD TT LOGGED 02/08/86 i23~-iTOP OF CEMENT I 8949' ~ TOP OF SAND 8996' I-I MA RKER JOINT I PBTD I-I 9335' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 9382' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/85 ORIGINAL COMPLETION 02/06/07 JCM~TLH PX TTP SET (01/30/07) 01/12/05 WRR/TLH RWO 06/03/08 N4ES RWO 02/04/05 KSB/TLH GLV GO 06/06/08 /TLH CORRECTIONS 10/19/05 KSB/PJC GLV C/O 06/28/08 GJB/SV GLV GO (06/25/08) 11/12/05 RPH/PJC WANER SFTY NOTE DELETED 06/24/06 SKB/PJC CONDUCTOR CORRECTION PRUDHOE BAY UNIT WELL: A-34A PERMfT No: ®1851050 API No: 50-029-21339-01 SEC 35, T11 N, R13E, 1172' SNL & 921' WEL BP Exploration (Alaska) I 8501' I I 8772' I 05/30/08 ~7~i~1~~~~~~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnll _Inl. 1! NO.4727 ~~~~~~~ ~~~ ~ ~ 2~~© Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ .... new.. ...:.... n... m Z-03 11975773 SFRT ~ (~ 05/20/08 1 1 P2-32 12066522 MEM TEMP SURVEY - 05/19/08 1 1 18-13B 12021159 MEM PROD PROFILE '~- ~ ( 05/18/08 1 1 Z-03 11975773 USIT - L~~3 05/19/08 1 1 W-29 11999017 INJECTION PROFILE ( 05/26/08 1 1 15-39A 11999018 PRODUCTION PROFILE ~(p - 05/28/08 1 1 07-30A 11963095 SCMT - ~ 05/27/08 1 1 14-09B 11982432 PROD PROFILE W/FSI - Q. v 05/27/08 1 1 A-34A 12057614 USIT - p '" /(pG/jy~ 05/26/08 1 1 GNI-04 11824353 OH LDWG EDIT (DSI) V-C .l I 4 11/07/07 1 1 r~~ewc .+v new vr~cvur. n~~.ur~ or ,71V rv11V171 AIVY nCl UrS1V11V1a VIYC VVYT GAI..n I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. - Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2 38 ' / ATTN: Beth /'" /'/ Received by: IlJ/I • • • David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 '~~~~ I~~Y ~. 2008 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-34A Sundry Number: 308-166 ~ ~ ~~5r~ Dear Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, :' Daniel T. Seamount, Jr. Chair DATED this ~ ~ day of May, 2008 Encl. ~~V~ ~ STATE OF ALASKA s .08 ® ~~ ' ~'~ ALAS IL AND GAS CONSERVATION COMMI N f ' APPL~ATION FOR SUNDRY APPR~AL I ~• 0 `Z MAY 0 ~ 2008 e ~ 20 AAC 25.280 ~,'~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ l1{~~& ~a5 ~Of1S. COtll ® Alter Casing - ` ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspeni~~8t~e ^ Change Approved Program ~ ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 185-105 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21339-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU A-34A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028286 ~ 75.7' - Prudhoe Bay Field / Prudhoe Bay Pool 12'. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9382 ~ 9234 - 8923 8776 8346' & 8923' N/A in L n i e M TVD Burt olla s r tur I n r 11 11 110' Surf a 2684' 13- /8" 26 4' 2684' 5380 2670 In ermedi 8773' 9-5/8" 8773' 2 ' 687 4760 Pr n in r 81' 7" 1' - 9382' 3 5' - 9234' 724 41 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8898' - 8928' 8751' - 8781' 4-1/2", 12.6# 13Cr & L-80 8535' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft): 8295' 9-5/8" x 4-1/2" BOT Packer 8435' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date §~~, p g Sondra Stewman, 564-4750 Commission Use Onl r<-S Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~~ ^ Plug Integrity .BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~,~~,\~ `~5~ ~~~~~ ~,~~~ other: 3 S®Q ~~ ~ ~~~ ~ ~5~- Subsequent For ,Required: i.-~~L~ L ~ A roved B ~ COMMISSIONER THE COMMISSI N Date ~ Form 10-403 Re~sed~6/2006 ORIGINAL _ Submit In Duplicate ' ~. ~~~ 1SSIOt~ '®~ by GPG~eipm,~uaeBad A-34A Expense Rig Workover Scope of Work: Repair Surface Casing Leak: Pull 4-%2" 13Cr-80 completion, cut and pull 9 °/." casing, run and cement to surface 9 s/." casing, run 5?h" 13Cr-80 "stacker-packer" completion. MAASP: 2370 psi Well Type: Producer Estimated Start Date: June 1, 2008 Production Engineer: Megan Kimmet Intervention Engineer: Mackie Derrick Pre-Ria Work Reauest: S 1 Pull TTP at 8361' MD. Drift thru 4-'/2" tubin for tubin cut and settin FasDrill. E 2 Set 4 '/2" HES composite plua at 8330' MD, in the middle of the first full joint below the top packer. CMIT T x IA to 3500 psi. Power Jet cut 4-%2" 13Cr-80 tubing at 8240' MD, in the middle of the first full 'oint above the Baker S-3 aaker. Reference tubin tall dated 01/06/05. F 3 Circulate well with kill wei ht fluid and diesel thru the cut. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks a check one at a time . PPPOT-T 8~ IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3'/z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-'/z" tubing string to the cut. 3. Run USIT log to determine top of cement in 9'/." x 13-3/8" annulus. 4. Set ~, -tri yable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9 a." casing from above the top of cement. Note: Pipe rams will not e c ange to 9~ °/a" as the well has two tested barriers (FasDrill plug and RBP) to the reservoir. 6. Run and fully cement new 9 °/e" casing to surface. Squeeze cement thru surface casing leak 7. Pull retrievable bridge plug '~~_~~~~~~ ~ 1~55.:•r-fc .~.5 ~, `lsl~ CGS ~ 8. Drill out FasDrill Plug, LDDP Q ~ ~~(~ 9. Run 5'/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 8160' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE _ ~ 4" CM/ WELL D = McEVOY ACTUATOR = CNV KB. ELEV = 75.69' BF. ELEV = 49.29' KOP = 3300' Max Angle = 15 (6~ 6500' Datum MD = 9023' Datum TV D = 8800' SS ~--34A SAF TES: WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST t3E TURNED OFF BEFOREANY WELL WORK INVOLVING EXPLOSIVES CAN I~i'a1N. CONTACT DSO. "*' 4-1/2" CHROMETB(a "'* "CONDUCTOR 110' ' .5#, H-40 2100' 4-1l2" HES X N~, ID = 3.813" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, D = 12.347" Minimum ID = 3.725" ~ 8506' OTIS XN NIPPLE SIDETRACK 2861' - 2982' ~ 4-1/2" TBG, 12.8#, 13CR, .0152 bpf, D= 3.958" ~-~ 8382' TOP OF 7" LNR )~ $501' 4-1/2" TBG, 12.8#, L-80, IP GAB , .0152 bpf, ID = 3.958" ~ 8533' 9-5/8" CSG, 47#, L-80, ~ = 8.881" 8772' PERFORATION SUMMARY REF LOG: BRCS ON 05/28/85 ANGLEATTOP PERF: 27 ~ 8898' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8898 - 8912 C 03/28/00 3-3/8" 8 8916 - 8928 C 11/27/96 3-3/8" 4 8928 - 8948 C 09/01/92 3-3/8" 4 8953 - 8963 C 04/01/92 3-1/8" 6 8970 - 9002 C 01/01/91 3-3/8" 4 9006 - 9031 C 04/01/92 3-3/8" 4 9012 - 9018 S 12/01/90 3-3/8" 4 9021 - 9031 S 12/01/90 3-3/8" 4 9040 - 9051 S 12/01/90 2-7l8" 2 9051 - 9056 S 12!01/90 $534' ELMD TT LOGGED 02/08/86 OF CEMENT )P OF SAND 8996' H MARKER JOINT I PBTD I 7" LNR, 28#, L-80, .0383 bpf, ~ = 8.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/85 ORIGINAL COMPLETION 02!06/07 JCM/TLH PX TTP SET (01/30/07) 01/12/05 WRRRLH RWO 02/04/05 KSB/TLH GLV CJO 10/19/05 KSB/PJC GLV C/O 11/12/05 RPWPJC WANERSFTY NOTE DELETED 06/24/06 SKB/PJC CONDUCTOR CORRECTION PRUDHOE BAY UNIT WELL: A-34A PERMtT No: 1851050 API No: 50-029-21339-Ot SEC 35, 711 N, R13E, 1172' SNL 8~ 921' WEL t5P Exploration (Aluka) ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3210 3208 9 MMG-M DMY RK 0 01 /06/05 6 3952 3930 14 MMG-M DMY RK 0 10/19/05 5 5239 5181 14 MMG-M DMY RK 0 10/19/05 4 5777 5697 15 MMG-M DMY RK 0 01/06/05 3 6472 6372 16 MMG-M DMY RK 0 01!06/05 2 7001 6883 14 MuIG-M DMY RK 0 01/06/05 1 7533 7401 12 MMG-M DMY RK 0 01/06/05 8274' 4-112" HES X NIP, D = 3.813" 8295' 9-5/8" X 4-1/2" BKR S-3 PKR, ~ = 3.875" 8361' 4-1/2" HES X NIP, ~ = 3.813" 8346' SLM 4-1/2" HES PX TTP (01/30/07) $$90' 9-5/8" X 4-1/2" UNIQUE OVERSHOT 8411' TBG SEAL ASSY 8435' 9-5/8" X 4-1/2" BOT PKR, ID = 3.813" 8478' 4-1/2" OTIS X N~, ID = 3.813" $506' 4-1/2" OTIS XN NIP, ID= 3.725" 8533' ~ 4-1 /2" WLEG, ID = 3.958" ., TREE = 7-1/16" x6-3/8" CNV WELL4iEAD= MCEVOY ACTUATOR= CNV KB. ELEV = 75.69' BF. ELEV = 49.29' KOP = 3300' Max Angle = 15 ~ 6500' Datum MD = 9023' Datum TV D = 8800' SS 120" CONDUCTOR I 91.5#, H-40 13-3/S" CSG, 72#, L-80, ID = 12.347" Minimum ID = 3.725" ~ 8506' OTIS XN NIPPLE SIDETRACK 2861' - 2982' 15-1 /2" TBG, 17#, 13CR, .023 bpf, ID = 4.89" I 8225' A-34A Proposed RWO 14-1/2" TBG, 12.6#, 13CR .0152 bpf, ID = 3.958" I ITOPOF 7" LNR ~~ 8501, 41 /2" TBG, 12.6#, L-80, IP CA B , .0152 bpf , ID = 3.958" 853 9-5/8" CSG, 47#, L-80, ID = 8.681 " 877 PERFORATION SUMMA RY REF LOG: BHCS ON 05/28/85 A NGLE A T TOP PERF: 27 ~ 8898' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8898 - 8912 03/28/00 3-3/8" 6 8916 - 8928 C 11 /27/96 3-3/8" 4 8928 - 8948 C 09/01 /92 3-3/8" 4 8953 - 8963 C 04/01/92 3-1 /8" 6 8970 - 9002 C 01!01/91 3-318" 4 9006 - 9031 C 04/01/92 3-3/8" 4 9012 - 9016 S 12/01!90 3-318" 4 9021 - 9031 S 12/01/90 3-3/8" 4 9040 - 9051 S 12/01/90 2-7/8" 2 9051 - 9056 S 12/01/90 I PBTD I 7" LNR, 26#, L-80, .0383 bpf, ID = SAF TES: WARNNG: RApO TRANSMITTER IN WEATHER MONTORlNG SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT DSO. '"' 4-1/2" CHROM E TBG "' ~t-Cement to surface 2100' 5-1 %2" X NIPPLE, ID = 4.562" GA S L IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE F ?61 ^_ 3600 14 DMY 5 5~0 5150 14 CMY 4 5775 5701 15 DMY 3 6345 6250 15 DMY 2 6864 6741 14 DMY 1 7481 7350 12 DMY 8140' S-1 /2" X NIPPLE, ID = 4.562" 8160' 9-5,8" X 5-1;2" BAKER S-3 FKR, 8210' 5-112" X NIPPLE. ID = 4.562" 8240' 9-SB" X 4-1; " L!Fil!;'JE CV ER ;HOT ~ $274' 4-1 /2" HES X NIP, ID = 3.813" $295' 9-5/8" X 4-1l2" BKR S-3 PKR, ID = 3.875" 8361' 41/2" HE5 X NIP, ID = 3.813" $390' 9-5/8" X 41/2" UNIQUE OVERSHOT $4~~' -~GSEALASSY 8435' 9-5/8" X 41 /2" BOT PKR, ID = 3.813" $47$' 4-1 /2" OTIS X NIP, ID = 3.813" 8506' 4-1/2" OTIS XN NIP, ID = 3.725" 8533' 41 /2" WLEG, ID = 3.958" $534' ELMD TT LOGGED 02/08/86 $923' --TOP OF CEMENT $9es9' TOP OF SAND I MA RKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04!85 ORIGINAL COMPLETION 02106/07 JCMITLH PX TTP SET (01 /30/07) 01!12/05 WRRITLH RWO 02/04/05 KSB/TLH GLV C/0 10/19/05 KSBlPJC GLV C/0 11/12/05 RPH/PJC WANERSFTY NOTE DELETED 06/24!06 SKB/PJC CONDUCTOR CORRECTION PRUDHOE BAY UNIT WELL: A-34A PERMIT No: 1851050 API No: 50-029-21339-01 SEC 35, T11 N, R13E, 1172' SNL 8921' WEL BP Exploration (Alaska) RE: A-34A Reclassified from Waiver to Trouble e e ¡Þï/) "* (ß> -( 0& Suhject: RE: A-34/\ Reclassified fh)111 Waiver to Trouhle From: "\ISU, ADW \\'elllntegrity Enginccr" <NSlJADWWelllntegrityEnginccr@ßP.com> Datc: Sat, 12 1\ov 2005 II :00:03 -0900 To: "Rossbcrg, R Steven" <:RossheRS@BP.com>·, "Engel, Harry R" <:Engcll-Œ.(~;;BP.com>, "NSlJ, ADW Well Operations Supcn'isor" <NSUADWWellOpcrationsSupervisor@BP.com>, "GPß, GC3 Arca Mgr" <GPßGC3TL@BP.com>, "GPB, GC3 \Vellpad Lead" <GPßGC3WellpadLcad@BP.com>, "GPB, Well Pads BAX" <GPBWeIlPadsBAX@HP.com>, "Carlson, Brian H" <Brian.Carlson@ßP.com>, "GPB, Optimization Engr" <:(jPßOptimizationEngr@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@:BP.com>, jim__rcgg~(adll1in.statc.ak.us, winton. aubcrt@)ldmin.state.ak.us cc: "NSU, ADW Welllntcgrity Engineer" <NSLJADWWcllTntegrityEngincer(i.i)ßP.com>, "Reeves, Donald F" <RccvesDft~DBP.com>, "Frazier, Nicholas B" <fraznb@;BP.com>, "Hughcs, Andrea (VECO)" <hugha4(~~)3P.com>, "llolt, Ryan P (VECO)" <Ryan.Holt@13P.com>, "Reese, Brent R." <reeshr@BP.com> Hello all. 3ttA Well A-34"has been reclassified from Waiver to Trouble. Attempts to flow the well without gas lift have been unsuccessful and gas lifted wells are not candidates for surface casing leak waivers. GC3 Lead Operator, would you please ensure any waiver related signage is removed from the wellhouse. Please call if you have any questions. Joe 1-907 -659-5102 From: Reeves, Donald F Sent: Saturday, October 29,20053:19 PM To: NSU, ADW Well Integrity Engineer Subject: A-34A recommend cancel waiver ~ 'It·'·'~Ií\.'~·ß·'·'; ¥~v.!/~tj~Jh~l\=l...) ( Hi Anna, A-34A is a PAL well waivered for a SC leak but was believed to flow without gas lift. Recent attempts to flow the well with the AL spool dropped prove the well still requires gas lift. Because the well will not flow without gas lift I recommend the waiver be cancelled and the well safed out. Thanks, Donald Reeves Well Integrity Engineer (907) 659-5525 (907) 659-5100 #1923 Pgr 1 of 1 12/13/200510:17 AM -:~'" STATE OF ALASKA "-"- ALASKJ-, ,.~IL AND GAS CONSERVATION C~..~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1171' SNL, 920' WEE, Sec 35, T11N, R13E, UPM At top of productive interval 334' SNL, 32' EWL, Sec 36, T11N, R13E, UPM At effective depth 4956' SNL, 5230' EWL, Sec 36, T11N, R13E, UPM At total depth 317' SNL, 61' EWL, Sec 36, T11N, R13E, UPM Sand Plug 5. Typel~ well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 75.69 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-34A 9. Permit Number / Approval No. 85-105 / 10. APl Number 50- 029-21339-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9382 feet Plugs (measured) BKB 9234 feet 9335 feet Junk (measured) BKB9187 feet Length Size Cemented MD 110' 20"X30" 72 cuff 136' 2658' 13-3/8" 3720 cuff 2684' 8747' 9-5~" 1744cu ff 8773' 880' 7" 198 cuff 8502'-9382' TVD BKB 136' 2684' 8626' 8356'-9234' Perforation depth: measured true vertical Open Peds 8898'-8912', 8916'-8948', 8953'-8963', 8970'-9002', 9006'-9031' Sqzd Perfs 9012'-9016', 9021'-9031', 9040'-9056' Open Perfs 8751'-8765', 8769'-8801', 8806'-8816',-8823'-8855', 8859'-8884' Tubing (size, grade, and measured depth) 4-1/2" L-80 to 8435' with 4-1/2" tailpipe to 8533' Packers and SSSV (type and measured depth) 9-5/8" packer BOT @ 8435', 4-1/2" Otis SSSV @ 2125' 13. Stimulation or cement squeeze summary See Attachment ' ~ ~ ~ I VED Intervals treated (measured) Treatment description including volumes used and final pressure MAy 0 ~ 2001 Alaska Oil & Gas Cons. Anchorage Commission 14. Prior to well operation: Subsequent to operation: - Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended [] Daily Report of Well Operations 17. I hereby certif~ that t~e for/going is truflral;~l correct to the best of my knowledge Slgne ,,~ Title Technical Assistant Service Date Form10-404 Rev. 06/15/88 Prepared By Name/Number: DeWayne Schnorr 564-5174 --~ Submit In Duplicate-N~ A-34A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/11/2001 04/04/2001 04/05/2001 04/06/2001 SAND PLUG: DRIFT & TAG SAND PLUG: LAY SAND PLUG SAND PLUG: LAY SAND PLUG W/CEMENT CAP FOR WSO SAND PLUG: TAG CMT CAP SUMMARY 03/11/01 DRIFT TBG W/3.6" CENT./T.E.L./& SAMPLE BAILER TO 9306' CORRECTED. NO SAMPLE POP WELL 04/04/01 MIRU. PERFORM WEEKLY BOP TEST. 04/05/01 LOAD WELL W/FILTERED 2% KCL CAPPED W/CRUDE. RIH WITH PIGS EAR NOZZLE. TAG TD. MIX AND PUMP 1ST STAGE SAND SLURRY (5400# 20X40 SAND). ALLOW SAND TO SETTLE OUT. TAG SAND TOP AT 9123' CORRECTED ELM. LAY IN 2ND SAND PLUG (4300#). TAG HIGH AT 8903' CTM. PUSH SAND DOWN TO 8936' CTM (8949' ELM). PLACE I-BBL 15.6 PPG CL "G" IN COIL W/FOAM PIG AHEAD AND BEHIND CEMENT. DISPLACE CEMENT. FREEZE PROTECT COIL POH. (ESTIMATED CEMENT TOP- 8923 ELMD) RDMO ***WELL REMAINS SI FOR SLICKLINE TAG.*** 04/06/01 TAGGED CMT CAP @ 8947' CORR. DEPTH, W/3.5" CENT. T.E.L. & SAMPLE BAILER, SAMPLE OF WHAT APPEARS TO BE CONTAMINATED CMT. NOTIFY OPERATOR OF STATUS- WELL LEFT SHUT IN TILL SATURDAY AM. Fluids Pumped BBLS. Description I DIESEL, FOR PRESSURE TEST. 11.5 METHENOL 296 2% KCL 73 60/40 METHANOL WATER I CEMENT 132 DEAD CRUDE 4 GEL 11 DIRTY GEL 39 SLURRY (9700# 20X40 RIVER SAND) 568.5 TOTAL CONSERVATION COMMISSION ALASKA OIL AND GAS 3oo~ PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: {907) 279-1433 TELECOPY: (907) 276-7542 July 20,-1994 Steve Farris/Jerry Bixby Wireline/Completion Supervisors BP Exploration (A~laska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX PBU A Pad Wells Nos. A-12, -13, -26, -30, -34A, & -37 Dear Mr. Farris/Bixby: On July 18, 1994, our Inspector Lou Grimaldi witnessed no-flow tests on BPX's PBU A Pad wells 12(PTD 80-117), 13(PTD 81-159), 26(PTD 82-117), 30(PTD 85-119), 34A(PTD 85-105), and 37(PTD 93-007). The wells had been shut in on the previous day. All wells were bled down to atmospheric tanks on-site. Five of the wells were essentially dead; the sixth well (A-30) made a small amount of gas; a gas meter showed that the flow rate was approximately 360 SCF per hour versus 900 SCF per hour acceptable. Since these rates are well below the limits for "no-flows", the Inspector concluded that subject wells were not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from BPX's PBU wells A-12(PTD 80-117), A-13(PTD 81-159), A-26(PTD 82-117), A-30 (PTD 85-119), A-34A(PTD 85-105), and A-37(PTD 93-007) on the condition that the iow-pressure sensors and surface safety valves must be maintained in good condition and, if for any reason, 'the wells again become capable of unassisted flow of hydrocarbons, the subsurface safety valve(s) must be reinstalled and maintained in good working condition. Sincerely, Blair E. W PI Supervisor c: Lou Grimaldi bew/n 1 pba 5 MEMORANDb.J TO: . David John.~~, Chairmafi ~ State o, Alaska Alaska Oil and Gas Conservation Commission DATE: July18,1994 ,.,'. THRU: Blair Wondzell, ¢ ..0.~, FILE NO: P. !. Supervisor FROM: Lou Grimaldi, ¢o,.~. SUBJECT: Petroleum Inspector 9A9JGRBD.DOC No Flow verification BPX wells A-12,13,26~34,&37 Prudhoe Bay Field Sunday, July 17,1994; I verified the NO-FLOW status of 4 BPX wells, A-12,26,34 &37, in the Prudhoe Bay field. The subject wells had been flowed down to separator pressure the night before and then bled to zero in a bleed trailer. Ali four wells were dead either no gas flow or just a whisper when opened to atmosphere. I recommend the approval of the NO-FLOW status for these wells. Monday, July 18, 1994; I returned to A pad today and verified NO FLOW status on well # A-13. This well like the others produced no fluid or had significant gas flow. There was a additional well tested, this being A-30. Although no fluid was produced a small amount of gas was steadily coming from the tubing. A residential type gas meter was installed on a hose routed from the tree cap to. The pressure was stabilized at approximately .5 psi with the meter registering on the two foot scale thirty subdivisions (or three revolutions) in thirty seconds. As there were no instructions with this meter and we were not sure of its operation I did not approve the test at this time, if the instructions prove out that two standard cubic feet is measured per revolution instead of a subdivision this well would pass the NO FLOW test. SUMMARY: I witnessed NO-FLOW tests on six BPX A pad wells. ~"/' ? 3- ALASKA OIL & GAS CONSERVATION CO~ISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 28 February 1994 RE: Transmittal of Data ECC #: 5792.01 Data: CN/GR Dear S£r/Madam, Reference: BP A-34A (11-36-11-13) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 CN/GR FINAL BLUELINE Run # j~ 1 CN/GRI FINAL RF SEPIA Run # Sent by U.S. MAIL ~OD-'~O~ Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson · % Received by: Date: %% ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 February 1994 RE: Transmittal of Data ECC #: 5792.01 Data: CN/GR Dear Sir/Madam, Reference: BP A-34A (11-36-11-13) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: Sent by U.S. MAIL CN/GR LDWG TAPE+LIST Run # 1 Received by: Date: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson RECEIVED FEB Alaska OiJ & (?,as Co,,~. uom~,'_Ss, lo.n .Anchorage .... STATE OF ALASKA ,,~_ , AL, ._,,A OIL AND GAS CONSERVATION COMMIS~. :q OZ~)/.,.,,/~. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging__ Perforate × "O~. I Pull tubing Alter casing __ Repair well Other 2. Name of Operator 6. Datum elevation (DF or KB) ' ''~ BP Exploration (Alaska) Inc. KBE = 75.69 AMSL fe~ 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1171' SNL, 920'WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 334'SNL, 32' EWL, SEC. 36, T11N, R13E, UPM At effective depth 4956' SNL, 5230' EWL, SEC. 36, T11N, R13E, UMI At total depth 317' SNL, 61' EWL, SEC. 36, T11N, R13E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Service 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-34A (11-36-11-13) PBU 9. Permit number/approval number 85-105 / 10. APl number 50- 029-21339-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9382 feet BKB 9234 feet 9206 feet BKB 8983 feet Plugs (measured) Junk (measured) fill at 9230' MD (02/89) Casing Length Size Cemented Structural -- Conductor 110 20X30 8 c.y. Surface 2658 13 3/8 3720 c.f. Intermediate 8747 9 5/8 1744 c.f. Production -- Liner 880 7 198 c.f. Perforation depth: measured 8970'-9002" Measured depth True vertical depth BKB 136 136 2684 2684 8773 8626 8502-9382 8356-9234 Sqzd: 9012'-9016', 9021'-9031 °, 9040'-9051', true vertical subsea 8747'-8769' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8435'; 4 1/2" SSSV at 2125' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure ,J U L_ 2. 1 t993 Alaska 0ii & Gas Cons. Cornmissio' Anchorage 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 700 2269 3362 1800 970 -~" 5650 5434 0 257 315 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby c. ertify that the foregoin~is - -- 'ev 06/15/88 ~ true and correct to the best of my knowledge. ~:~¢ ~'/¢v,~ Title Senior Technical Assistant I Date ,~7//¢//~ SUBMIT IN D0/PLI~ATE WELL A-34A(11-36-11-13) AddPerf/Ret~erf 4/26/92 4/26/92 9/18/92 9/2O/92 The following intervals were added using 3 3/8" guns, 4 SPF, 0° orientation, 120° phasing. 8953' - 8963' MD The following intervals were reperforated using 3 3/8" guns, 4 SPF, random 0° and 120° phasing. 9006' - 9031' MD Set a Inflatable Bridge Plug The following intervals were added using 3 3/8" guns, 4 SPF, random orientation, 60° phasing. 8928'- 8947' MD fjh 11/22/92 Alaska Oil & Gas Cons. Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 DATE: 04/07/93 T# 84449 BP/PBU CH~NET. Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) A-iS CH/DSN 9079.50- 9785.00 API#5002920672~_~[~ 10578.00-11400.00 API#500292074300 8738.50- 9327.50 API#500292133901 FIN 1600B?I 9306->TP# 07/22/92 #1 FIN 07/12/92 !600BPI 9307->TP# FIN 07/13/92 !600BPI 9308->TP# #1 #1 IC TAPES W/LISTINGS ff you have any 564-4004. HALiBUR REF#L84730-0 HALiBUR REF#L84700-X HALiBUR REF#L84722-6 Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 DATE: 04-06-93 T# 84504 BP h~LOGS Enclosed ~s vour copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004 4% A-04 ~O_! DSN 07/06/92 ~1 ~ A-24~ Z/\%~ DSN 07/12/92 #l A_34A~TM DSN 07/13/92 #1 ~ 05/22/92 #~ M-26A ~RF ~ ~ Z-09~ DSN 07/25/92 #! 10400 00-11143.00 HLS 9095 00- 9782.00 HLS 10587 00-11386.00 HLS 8736 00- 9310.00 HLS 10680 00-11360.00 HLS 10330 00-10914.00 HLS 5 " 5 " 5 " 5 " 5 " Information Control Well Records APR 1 2 993 AJaska 0ii & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/30/92 T# 84137 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-16 $0'/~ INJ 11/26/92 #1 A-34A~J'-/cJ' pRODUCTION LOG 11/26/92 #1 B-12 ]~- ~/<PDK-100) ~/¢~ 11/27/92 #1 B-15 ~--/~ ~PERF~ CC a- 11/26/92 #1 Y-15~$.~ PRODUCTION LOG 11/27/92 #1 10470.00- 1110.00 ATLAS 5 " 8750.00- 9025.00 ATLAS 5 " 9000.00- 9400.00 ATLAS 5 " 8900.00- 9500.00 ATLAS 2/5" 9700.00-10394.00 ATLAS 5 " Information Control Well Records ,/ R CEiVED DEC 1 8 1992 .~mska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 10/27/92 T# 83998 BP CH LOGS Enckosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 4-20/M-35 CH 10/03/92 f~dA-34A ~--I o~- CH 09 / 18 / 92 E-19 ~f-)3 CH 10/03/92 N-06 q[--I~ CH 10/03/92 N-09 ~o-~9 CH 09/30/92 ~-2 3 ~:j~$ CH 10/03/92 X-11 CH 09/21/92 REF#72346 REF#69213 ~e~x,,,.~l,,f,.l.l-. ~,-;',[le ?1-% REF#69099 ~k ~~3~ S~.~ REF#72752 TEMP FLOWlV/ETER SURVEY CAMCO CAMCO ~ CAMCO ~/ CAMCO cAMco cAMco ~ CAMCO ~/' Information Control Well Records RECEIVED OCT 2 9 1992 Alaska Oil & Gas GODS. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/16/92 T# 83900 BP MAGNETIC LIS TAPES EnClosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) A-0 CH/PSGT W/COMPUTED RESULTS #1 -9 10389.50-11172.00 API#500292011500 9012->TP# A-13t CH/PSGT W/COMPUTED RESULTS #1 -1 9240.00- 9791.00 A_~!%5002920~7200 9013->TP# A-24 CH/PSGT W/COMPUTED RESULTS #1 -1 10778.50-11356.00 API#500292074300 9014->TP# A-34A CH/PSGT W/COMPUTED RESULTS #1 -2 8886.00- 9310.50 API#500292133901 9015->TP# FIN. 07/05/92 1600BPI FIN 07/21/92 1600BPI FIN 09/11/92 1600BPI FIN 07/12/92 1600BPI If you have any 564-4004. HLS REF#L84720 HLS REF#L84723 HLS REF#L84721 HLS REF#L84722 Information Control Well Records Shirley Hale ECEIVED OCT 0 8 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 /D DATE: 09/20/92 T# 83907 BP CASED HOLE FINALS EnClosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-04 2j~ PULSED SPECTRAL GAMMA 07/05/92 #1 10400.00-11196.00 HLS "-A-04 GR 07/05/92 ~,1 10400.00-11150.00 HLS 5 " A-09 ~1-') PFC 09/09/92 ~1 8545.00- 9600.00 ATLAS 5 ~-13 PULSED SPECT~L G~ 0?/21/92 ¢1 9260.00- 9??8.00 HLS 5 " {a-24 PULSED SPECT~L G~ 07/11/92 ¢1 10780.00-11437.00 HLS 07/11/92 ~1 10780.00-11335.00 HLS A-24 ~SG~ A-34A~- GR 07/12/92 ~1 8890.00- 9303.00 HLS 5 " A-34A PULSED SPECT~L G~ 07/12/92 ~1 8890.00- 9335.00 HLS l! B-24~'1~ PRODUCTION LOG 09/13/92 ~1 C-01 7~-3"_ CCL 09/09/92 ~1 G-14~]"~'~' PERF 05/25/92 ~1 S-03 ~1'{~ CL 07/25/92 ~1 Y-28~1'~'¢'' CL 04/25/92 #1 Y-32 ~1.~.1 PERF 07/28/92 #1 10300.00-10650.00 SCH 5 " 7200.00- 7600.00 ATLAS 5 " 9190.00- 9620.00 HLS 5 " 9950.00-10498.00 HLS 5 " 8637.00- 8802.00 HLS 5 " 11939.00-12547.00 HLS 5 " Information Control Well Records Shirley Hale / RECEIVED OCT 0 8 '1992 Alaska 0ii & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/29/92 T# 83937 BP CASED HOLE FINALS EnClosed is your copy of the materials listed -questions, please contact BP Well Records at A-34AO COMPLETION $-29Jg-/~ TDT-P BORAX R-28 ~-j-~ CCL/PERF R-31 ~--~ CCL/PERF s-27~.¢~ PFC/CR/P~.RF 5 " 09/20/92 #1 09/15/92 #1 09/23/92 #1 09/25/92 #1 09/22/92 below. If you have any (907) 564-4004. 8473.00- 8998.00 SCH 5 " 8800.00- 9420.00 SCH 5 " 8868.00- 9700.00 ATLAS 5 " 9720.00-10533.00 ATLAS 5 " #1 10690.00-10849.00 ATLAS Information Control Well Records Shirley Hale - RECEIVED OCT 0 8 1992 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 {907) 561-5111 'DATE: 05/11/92 T# 83498 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. F_3037'#° GAS LIFT SURVEY 04/18/92 #1 F-41ST~/'~°~GAS LIFT SURVEY 04/10/92 #1 -14' PROD-F 04/05/92 #1 1481-/.~" - PROD-F 04/22/92 ~1 K-07 ~./~ PROD-F 04/07/92 ~1 N-06 ~/--/~ GAS LIFT SURVEY 04/11/92 ~1 N-18~3--~ TIE IN LOG 04/02/92 91 N-21~--~ LEAK DET 04/16/92 91 N-10~e~f~ PROD-F 04/20/92 ~1 A-3~_fo~BAKER INFLAT/BRIDG PLG 5 " 0.00-11750.00 CAMCO 2/5" 613.00-10020.00 CAMCO 2/5" 9200.00- 9650.00 CAMCO 5 " 9200.00- 9658.00 CAMCO 5 " 9990.00-10180.00 CAMCO 5 " 1800.00- 9000.00 CAMCO 2/5" 9100.00- 9732.00 CAMCO 5 " 10100.00-11230.00 CAMCO 5 " 2900.00-10230.00 CAMCO 2/5" 04/28/92 #1 8900.00- 9110.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED MAY 1 8 1997. Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/14/92 T~ 83406 BP MAGNETIC LIS TAPES Enclosed is your copy of the materials listed below. questions, plea se contact BP Well Records at (90~7) A-34A CH/TDT-P ~ FIN 03/29/92 ~1 8750.00- 9190.00 1600BPI API~500292133901 8561->TP# ~-09 / CH/TDT-P BORAX FIN - 03/27/92 #1 9200.00- 9923.00 1600BPI API#500292055200 8562->TP# Information Control Well Records Adrian J. Martin If you have any 564-4004. SCH REF#92232 SCH REF#92231 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/03/92 T# 83369 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. B_10 l~' ~' CPERF A-09 ~(--~ TDT-P A-34~,~TDT-P 03/26/92 #1 03/27/92 #1 03/29/92 #1 10250.00-10480.00 SCH 9200.00- 9923.00 SCH 8750.00- 9190.00 SCH ii 5 " 5 " Information Control Well Records Adrian J. Martin RECEIVED APR 1 5 1992 Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Date :06~06~91 T#:82487 RECEIVED JUN 77 1991 Alaska Oil & Gas Cons. Cornrn-sionis Anchorage Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. A-01 A-02 A-04 A-09 A-12 CL Temp Temp Static Temp · Temp : A-13 - Temp · - ....... A-23 - - ·PITS ~-~- A-34A Temp B-02 Prod-F '~' ~ ' B-14 Jewelry · B-23 Prod-F B-24 Gas Lift 05/08/91 #1 05/12/91 #1 05/12/91 # 1 05/12/91 #1 05/12/91 #1 05/12/91 #1 05/15/91 .-. #1 05/12/91 #1 05/17/91 #1 05/17/91 #1 05/18/91· # 1 05/26/91 #1 7733-8200 11100-11394 10700-11115 9340-9931 8700-9300 9150-9529 -11200-11651 8800-9102 10300-10536 10490-11900 9600-9920 9423-9900 Carnc~ Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco 5" 5" 5" 5" 5" 5" 5- 5" 5" 5"' 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS,,.,N REPORT OF SUNDRY WELL OPERATIONS t' 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter caSing Repair well Perforate x Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1171' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 334' SNL, 32'EWL, SEC. 36, T11N, R13E, UPM At effective depth 4956' SNL, 5230' EWL, SEC. 36, T11N, R13E, UMI At total depth 317' SNL, 61' EWL, SEC. 36, TI 1N, R13E, UPM 5. Type of Well: Development X Exploratory Strafigraphic Service 6. Datum elevation (DF or KB) KBE = 75.69 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8, Well number A-34A (11-36-11-13) PBU 9. Permit number/approval number 85-105/8-624 10. APl number 50- 029-21339-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9382feet BKB 9234feet 9206feet BKB 8983feet Plugs (measured) Junk (measured) fill at 9230' MD (02/89) Casing Length Size Cemented Structural - Conductor 110 20X30 8 c.y. Surface 2658 13 3/8 3720 c.f. Intermediate 8747 9 5/8 1744 c.f. Production - Liner 880 7 198 c.f. Perforation depth: measured 8970'-9002" Measured depth True vertical depth BKB 136 136 2684 2684 8773 8626 8502-9382 8356-9234 Sqzd: 9012'-9016', 9021'-9031', 9040'-9051 ', 9051'-9056' true vertical subsea 8747'-8769' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' RECEIVED APR 1 2 t991 Packers and SSSV (type and measured depth) 9 5/8" BO T packer at 8435'; 4 1/2" SSSV at 2125' Alaska Oil & R~,~ Cons. Or, remission 13. Stimulation or cement squeeze summary see attachment ~l~jlch0rag8 Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation RePresentative Daily Average Production or Injection Data -OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1380 1897 4484 1760 2030 2696 911 1100 Tubing Pressure 271 304 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. ned ~, (~,/~C~ 'J ~,L~ -~ ~,~,/~ ~g~; (,/~_ 3'itle Manager Production Engineering Form 10-404 Rev 06/~5/~ ~ ~ -- SUBMIT IN DUPLIOATE WELL A-34A (11-36-11-13) PBU ADDITIONAL PERFORATING OPERATIONS The following additional interval was perforated January 6, 1991, using Atlas's 3 1/8" carrier guns at 6 spf: 8970' - 9002' MD BKB The well was returned to production immediately following perforating operations, then tested. RECEIVED APR 1 2 t99J .0il .& Gas Cons. Commission ~nchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :01/15/91 T#:82045 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. "A-30 Prod-F 12/15/90 #1 10650-11080 Camco ,, A-34A PITS 12/28/90 #1 8900-9190 Camco -, B-25 Prod-F/Jewelry 12/11/90 #1 9800-10164 Camco -C-15 Prod-F 12/24/90 #1 9350-9757 Camco - '- "E-02 - Prod-F/Jewelry ---12/20/90 -- - #1 9675-9981 ......... Camco · - #1 #1 #1 "E-27 Prod-F 12/13/90 "'G-07 CCL/Temp 12/13/90 "' P-13 Prod-F 12/27/90 ~. M-28 INJ/PITS 12/16/90 '~S-32 Prod-F 12/27/90 -.S-29 Prod-F 12/21/90 "WV-40 Prod-F 12/14/90 ~Y-14 Prod-f/PiTS 12/23/90 · 'Y-14 Jewelry Log 12/23/90 %- Y-19 Jewelry Log 12/22!90 #1 #1 #1 #1 #1 #1 #1 1, ...... 5"... 9450-9720 Camco 5" 11150-11396 Camco 5" 9000-9380 Camco 5" 8750-8925 Camco 5" 10100-10540 Camco 5" 12850-13190 Camco 5" 10200-10510 Camco 5" 9900-10401 Camco 5" 9600-10300 Camco 5" 8900-9701 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED JAN 199 · Alaska Oil & (~as Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :01/11/91 T#:81983 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. · A-34A CCL/Perf 01/06/91 #1 8900-9180 Atlas 5" , F-18 CCL-B. Plug 01/07/91 #1 11170-11435 Atlas 5" --J-08 PLS 01/05/91 #1 12050-12400 Atlas 5" ', M-03 CCL 01/09/91 #1 10705-11117 Atlas 5" ~ S-03 PFC 01/07/91 #1 10900-11341 Atlas 5" Distribution' ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED dAN 75 1991 Alaska 0ii & ~as Cons. Commission Ancholage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 10/19/90 T#:81603 FROM: SUBJECT: Information Control Well Records LR2-1 .,BP CASED HQLE FINAL,~ Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. TEMP PROD-F PROD-F LEAK DET PROD-F PITS GR PROD-F PROD-F 10/08/90 1 0/08/90 10/06/90 10/06/90 10/05/9O 10/07/90 1 0/07/90 10/04/90 10/03/90 #1 0.0-11050 CAMCO 5" #1 8850-9216 CAMCO 5" #1 3200-10510 CAMCO 5" #1 9790-11010 CAMCO 5" # 1 2883-10730 CAMCO 5" #1 8750-9497 CAMCO 5" #1 9450-11218 CAMCO 5" #1 2920-10807 CAMCO 5" #1 11920-12995 CAMCO 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS F ALASKA ~VES R£CEIV£D OCT 2 4 Alaska Oil & BP EXPLORATION RECEIVED Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: ARCO EXXON PHILLIPS STATE OF ALASKA ARCHIVES DATE: 05/23/90 T#: 81208 SYSTEM Tape & Transmittal Only BP MAGNETIC LIS TAPE & LISTING Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-dddS. A-24 CH/CNL 05/13/90 #1 SCH#73858 1600BPi A-34A CH/CNL 05/13/90 #1 SCH#73859 1600BPI H-02 CH/CNL 05/12/90 #2 SCH#73856 1600BPI 10597-11452 TAPE POS.#07055 AP1#50-029-20734 8745-9231 TAPE POS.#07056 8444-8880AP1#50-029-21339TAPE POS.#07057 AP1#50-029-20100 Information Control Well Records LR 2-1 J. Dietz/S. McCurry ' r BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :05/16/90 T#:81156 FROM- Information Control" Well Records LR2-1 SUBJECT: I~P (~ASE'D HOLE FINALS Enclosed is your copy of the matedai listed below, if you have any questions, please contact BP Well Records at (907) 564-'Hd5. A-24 CNL/GR 05/13/90 #1 10600-11432 Sch 5" A-34A CNL/GR 05/13/90 #1 8750-9218 Sch 5" K-11 PERF 05/14/90 #1 10434-11586 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS ARCHIVES----- BP EXPLORATION HOUSTON ARCO CHEVRON EXXON TE~VJkC0 'tO: MOBIL PHILLIPS STATE OF ALASKA INDEXED BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5111 Date: 05~18-89 80071 REFERENCE: BP FINAL DATA - PRESSURE SURVEY DATA The following material Is being sqbmlt'-I'ed herewith, Please acknowledge receipt by signing a copy of this .let'l'er and returning it to this office: A-34A Flo.wing Gradient 05-04-89 H-3A'. Static Gradient 05-03-89 H-9i Static Gradient 05-06-89 K-04 Static Gradient 05-03-89 K-10 Flowing Gradient 05-0~-89 R-24 Static Gradient 05-05-89 S-lli Static Gradient 05-06-89 W-40 Static Gradient 05-13-89 Y-8A Static Gradient 05-14-89 W-40 Static Gradient -04-21-89 Y-17 Static Gradient 05-~-89 Rece I ved Date Camco Camco Camco Camco Camco Camco Camco Camco Camco Halliburton Camco BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO HOUSTON ARCO CHEVRON EXXON MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES BP CASED HOLE FINAL LOGS Date: 05/17/89 T%: 80065' The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-34A DTL 05/04/89 %1 0-8600 Camco C-28 Collar 05/12/89 ~1 10700-11050 Camco C-29 Prod-F 05/05/89 ~1 11650-11958 Camco 5" F-35 PFC 05/11/89 ~1 11550-11955 Atlas 5" J-03 Collar 05/11/89 ~1 9350-10076 Atlas M-29I Perf-F 05/10/89 ~1 9550-10194 Sch Received: Date: Information Control Well Records LR2-1 J. Dietz/S. McCurry BP EXPLORATION April 4, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, Manager Production Engineering JAB: J~34 Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File RECEIVED gla:S~0~l & Gas Cons. Commissioa · ' STATE OF ALASKA AI..qSl~ OIL AND OAS GONSERVATION GOMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing . . Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development ..~ Exploratory Strafigraphic ~ Service. 4. Location of well at surface 1171' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 334'SNL, 32' EWL, $EC. 36, T11N, R13E, UPM At effective depth 322'SNL, 51'EWL, SEC. 36, T11N, R13E, UPM At total depth 317'SNL, 61'EWL, SEC. 36, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 9382feet BKB 9234 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 75.69 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-34A (11-36-11-13) PBU 9. Permit number/approval number 85-105 / 8-624 10. APl number 50- 029-21339-01 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 9230feet true vertical BKB 9082feet Junk (measured) fill at 9230'MD (02/89) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Co nd ucto r 110 20X30 8 c.y. 136 136 Surface 2658 13 3/8 3720 c.f. 2684 2684 Intermediate 8747 9 5/8 1744 c.f. 8773 8626 Production -- Liner 880 7 198 c.f. 8502-9382 8356-9234 Perforation depth: measured 8992'-9002', 9012'-9016', 9021'-9031', 9040'-9056' true vertical subsea 8769'-8833' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8435'; 4 1/2" SSSV at 2125' RECEIVED 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure ~laska 0ii .& Gas Cons. C0mmissi0r~ 14. Prior to well operation Subsequent to operation ReDresent~ive Daily Average Production orln!e~ion D~a OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1420 1546 3078 1500 2190 2284 5090 1820 Tubing Pressure 294 3O2 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended, Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed r~--'~~ ~~, ~ Title Manager Production Eng/neer/ng Form 10-4~Rev 06,15,88 ~,/~/ SUBMIT IN DUPLICATE WELL A-34A (11-36-11-13) PBU STIMULATION OPERATIONS A half-strength mud acid treatment and scale inhibition was performed on the following perforated intervals in Well A-34A. 8992'- 9002'MDBKB 9012'- 9017'MDBKB 9021'- 9031'MD BKB An inflatable packer on coiled tubing was set at 9035' and the following fluids were pumped down the coiled tubing aanulus (2/15/89). 12 bbls. 15% HC1 4 bbls. diverter 24 bbls. 15% HC1 4 bbls. diverter 24 bbls. 15% HC1 24 bbls. 6% HC1 - 1.5% HF 4 bbls. diverter 36 bbls. 6% HC1 - 1.5% HF 48 bbls. 2% NH4C1 brine 12 bbls. xylene w/5% mutual solvent 128 bbls. produced water The packer was retrieved following the treatment and the well put back on production and tested. The following scale inhibition treatment was performed 3/6/89 with an inflatable packer set as above. 10 bbls. diesel preflush w/mutual solvent 12 bbls. EDTA 44 bbls. scale inhibitor 264 bbls. seawater overflush The well was left shut in for 24 hours, then the well was returned to production and tested. jm 3/29/89 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION August 11, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours vezy truly, JAB:J~ Enclosures (9) cc: J. L. Haas (MB12-1) A-34AWell File Manager t £oduction Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing El ~me extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Olher [] Name of Operator Standard Alaska Product/on Company Address P. O. Box 196612, Alaska 99519-6612 1171' SNL, 920' WEL, SEC. 35, TIIN, RI3E, UPM At top of productive interval 334'SNL, 32'EWL, SEC. 36, TIIN, R13E, UPM At effective depth 322' SNI., 53'EWL, SEC. 36, T11N, R13E, UPM At total depth 317' SNL, 61'EWI., SEC. 36, T11N, R13E, UPM Present well condition summary Total depth: measured 9382 feet Plugs (measured) 5. Datum elevation (DF or KB) KBE = 75.69 AMSL feet S. Unit or Property name Prudhoe Bay Unit 7. Well number A-34A (I 1-36-11-13) PBU 8. Permit number 85-105 9. APl number 5 O- 029-21339-01 O. Pool Prudhoe Oil Pool true vertical Effective-depth: measured true vertical Casing Length Structural - Conductor 110 Surface 2658 Intermediate 8747 Production - Liner 880 Perforation depth: measured B/~ 9234 feet 9252 feet BKB 9104 feet Size 20X30 133/8 95/8 Junk (measured) fill at 9252' (04/88) Measured depth 136 2684 8773 8c.y. 3720c. f. 1744c. f. 7 198 c.f. 8502-9382 8992'-9002; 9012'-9016; 9021'-9031; 9040'-9056' true vertical subsea 8769'-8&33' Tubing (size, grade and measured depth) 4 1/2'L-80to8435'with 4 1/2"tailpipe to 8533' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 84357 4 1/2" Sssvat True Vertical depth BKB 136 2684 8626 8356-9234 12. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August/September 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, ge~fy that the,fore~3, oing is true and correct to the best of my knowledge Signed ~..~~ ..~~ Title Mana, er Production Engineering dit~'~ Commission Use Only Con lions of approval Noti[y.commission so- representative may witness [] Plug integrity [] BOP Test ~.. ::INAL StGNEO 6¥ ~ nl~llE C. SMITH A~roved by Form 10-403 Rev 12-1-85 El Location clearance~Appjrovai No. Approved Copy Returned _ <~/~{Ol~ by order of Commissioner the commission Date ~ ~t~-1~9~' Submit in triplicate WELL A-34A (11-36-11-13~ PBU STIMULATION PROPOSAL A half-strength mUd acid wash 8992' - 9002' MD BKB 9012' - 9017' MD BKB 9021' - 9031' MD BKB is proposed for the following perforated intervals. A TAM inflatable straddle packer run on coiled tubing will bc utilized to selectively stimulate thc .perforations in five-foot stages with thc following treatment fluids. 300 gal. 15% HCI wf20% xylene 7500 gal. 6% HCI - 1.5% I-IF 350 gal. 3% NH4C1 The packer will bc retrieved following thc treatment, and thc well will bc put back on production and tested. jm 8/10/88 · -. 0 Coiled Tubing Blow-Out-Preventers Tubing Pack-Off Blind Rams Cutter Rams "Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (Circulate/Returns) W ell Head Swab Valve Standard Alaska ~-.. Production Compar 900 East Benson Bou, .d P.O. Box 196612 Anchorage, Alaska 99.519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION July 5, 19 88 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing a cement squeeze and reperforation of the well. Yours very truly, JAB: JAM ~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 A-34A Well File pager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland Ohio in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation performed: Operation shutdown [] Stimulate [] Plugging [] Alter casing [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 ¢. Location of well at surface 1171' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 334'SNL, 32' EWL, SEC. 36, T11N, R13E, UPM At effective depth 322' SNL, 53' EW/_, SEC. 36, T11N, R13E, UPM At total depth 317'SNL, 61'EWL, SEC. 36, T11N, R13E, UPM Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 110 2658 8747 .. 88O measu red 9382 feet BKB 9234 feet 9252 feet BKB 9104 feet Size Plugs (measured) Junk (measured) Perforate [] Pull tubing [] 20X30 133/8 9 5/8 5. Datum elevation (DF or KB) KBE = 75.69 AMSL feet 6. Unit or Property name ~rudhoe Bay Unit 7. Well number A-34A (11-36-11-13) PBU 8. Approval number 8-120 9. APl number 5 0 - 029-21339-01 0. Pool Prudhoe Oil Pool fill at 9252' (04/88) Cemented Measured depth True Vertical depth BKB 8 c.y. 136 136 3720 c.f. 2684 2684 1744 c.f. 8773 8626 7 198 c.f. 8502-9382 8992'-9002', 9012'-9016', 9021'-9031', 9040'-9056' true vertical subsea 8769'-8833' 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' Tubing (size, grade and measured depth) 8356-9234 Packers and SSSV (type and measured depth) 2. Stimulation or cement squeeze summary Intervals treated (measured) see attachment ~ ~ ~ ~ '- " ' ' '''~ Treatment description including volumes used and final pressure , Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2170 2263 9336 1853 1700 1232 472 1800 Tubing Pressure 288 253 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form Rev. 12 Tit I e Manager Production Engineering Submit in Duplicate W~I~L A-34A (11-36-11-13~ PBU CTU CEMENT SOUEEZE OPERATIONS A coiled tubing cement squeeze of existing perforations and a confirmed channel to the WOC was performed as detailed below. Following the CTU operations, all intervals were reperforated. Rigged up coiled tubing unit and pressure tested BOP's to 4000 psi. 2. Performed mud acid wash of the perforated intervals; flowed well. 3. Cleaned out wellbore, then fluid packed wellbore with produced water. 4. Performed cement squeeze of all existing perforations. 5. Contaminated cement in the wellbore then reversed out after 24 hours. 6. Tested squeeze. 7. Reperforated the following intervals using Schlumberger 2 7/8" Hyperdome guns. 8992' - 9002' MD BKB @ 4 sp~ 9012' - 9016' MD BKB @ 4 spf 9021' - 9031' MD BKB @ 4 spf 9040' - 9056' MD BKB @ 2 spf 8. Returned well to production and tested. The above work was completed April 1, 1988. jm 6/24/88 INDEXED DAI.I.AS ARCO CHEVRON E~XON TEY~ACO Date: 04/08/88 HOBIL TI: 78719 PHIL~ ""~S TAT E OF GEOSCIENCES STANDARD REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning it to this office: ~A-i1 ~'~. A-27 '~A- 34 A -~'~-qA- 34A ~ A-34A ~B-2 ~C-4 ~C-9 ~H-25 K-10 --- N-8 ~N-8 ~R-2 ~R-11 R-23 ~X-4 ~ X-26 Injection Profile 04/03/88 #l 9700-10124 Sch 5" Tubing Puncher Record 03/31/88 H1 8390-8570 Sch 5" PITS/EM 03/24/88 #1 8800-9260 Camco TE~-~ 03/31/88 H1 8750-9260 " 5" Completion Record 04/01/88 H1 '8500-9236 Sch 5" Completion Record 03/25/88 H1 10295-10527 Sch 5" Production Profile 03/29/88 H1 10250-10690 Camco 5" CNL/GR 03/26/88 H4 9050-9731 Sch 5" Production Profile 04/02/88 H1 11000-11335 Camco 5" Temp 03/12/88 H1 10100-10742 " 5" Production Profile 03/31/88 H1 9800-10050 " 5" H-28 03/15/88 H1 8700-8940 " 5" Injection Profile 03/26/88 #1 9550-9840 " 5" Injection Profile 04/01/88 H1 9550-9840 " 5" Injection Profile 03/15/88 #1 9400-9830 " 5" PITS 03/14/88 #1 10229-10705 " 5" Production 04/02/88 H1 11500-11751 Sch 5" PITS 03/25/88 H1 9400-10050 Camco 5" Completion Record 04/04/88 H1 8900-9595 Sch 5" 1! Rece i ved Dafo Alaska Oil & Gas Cons. Commission Anchorage Victoria Aldridge INFORMAT ION CONTROL Well Records LR2-I Standard Alaska j Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION February 25, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform a cement squeeze and reperforation of the well. Yours very truly, JAB: JAM Enclosures (9) cc: J. L. Haas (MB12-1) A-34A Well File Bragg V t/ anager Production Engineering A unit of the original Stondard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Time extension [] Change approved program [] Plugging [] Stimulate [] 2. Name of Operator Standard Alaska Production Company 3. Address . P. O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1171' SNL, 920' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 334' SNL, 32' EWL, SEC. 36, T11N, R13E, UPM At effective depth 319'SNL, 57'EWL, SEC. 36, T11N, R13E, UPM At total depth 317'SNL, 61'EWL, SEC. 36, T11N, R13E, UPM Re-enter suspended well [] Alter easing [] Pull tubing [] Amend order [] Pertorate [] 5. Datum elevation (DF or KB) Other [] KBE = 75.69 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-34A (11-36-11-13) PBU 8. Permit number 85-105 9. APl number 5 0 - 029-21339-01 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 S u rface 2658 Intermediate 8747 Production -- Liner 880 Perforation depth: measured 9382 feet BKB 9234 feet 9335 feet BKB 9187 feet Size Plugs (measured) Junk (measured) Cemented Measured depth 136 2684 8773 20X30 8 c.y. 13 3/8 3720 c.f. 9 5/8 1744 c.f. 7 198 c.f. 8502-9382 8992'-9002', 9012'-9016', 9021'-9031', 9040'-9056' true vertical subsea 8769'-8833' Tubing (size, grade and measured depth) 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' True Vertical depth BKB 136 2684 8626 8356-9234 Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 8435'; 4 1/2" SSS V at 2125' ,. .... 2. Attachments Description summary of proposal [] Detailed operations program [] 3. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I her~yjcertify that the/f.o~regoing is true and correct to the best of my knowledge Signe~_~~ ..,~. ,~/c~~ Title ManagorProductionEnginooring Commission Use Only Condifions of approval Notify commission so representative may witness IApproval [] Plug integrity [] BOP Test [] Location clearance I Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy by order of Form 10-403 Rev 12-1-85 Date Commissioner the commission Date Submit in triplicate WELL A-34A CTU CEMENT SQUEEZE PROPOSAL The following coiled tubing cement squeeze of existing perforations is proposed. Following CTU operations all intervals will be reperforated: 8992-9002, 9012-9016, 9021-9031, 9040-9056'MD (ref BHC 5/28/85). The objective is to eliminate a channel from the lower perforations to zone 3. Zone 3 water influx is within 30' of the bottom perforations in zone 4. Limited shot density (2 spf) is planned for the lowest reperforation interval to maintain offtake and limit water production. 1. Rig up coiled tubing unit and pressure BOP's to 4000 psi. 2. Perform mud acid wash of the perforated interval and channel. 3. Return well to production and flow back spent mud acid. 4. Clean out wellbore to PBTD or to top of solid fill. 5. Fluid pack the wellbore with produced water. 6. Perform cement squeeze on existing perforations. 7. Contaminate cement in the wellbore. WOC. 8. Reverse out contaminated cement after 24 hours. 9. Test squeeze. 10. Reperforate the following intervals: 8992 - 9002 MD BKB (10') 4 spf 9012 - 9016 MD BKB (4') 4 spf 9021 - 9031 MD BKB (10') 4 spf 9040 - 9056 MD BKB (16') 2 spf 11. Put well back on production and test. Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off' Blind Rams Cutter Rams 2" Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (C ircula te/R e turns ) Well Head Swab valve ARCO EXXON PHILLIPS SYSTEMS STATE OF AK PDBY Systems (Transmittal Only) (Transmittal & Tape) ARCHIVES STANDARD AL ASICA. Pk?(3I)UC J ION Date' 09/16/87 78170 SA_PC MAGNETIC LIS TAPES & LISTINGS The follawing material is being su~tted herewith. Please acknowl~e receipt signing a copy of this letter ~qd returning it to this office: A-34A K-9 CH/CNL Mag tape 09/06/87 :.:/1 Sch ~]72435 Tape Pos. /.:05379 - _<.. ~ <~-'" , ~ .- 8688 75-9305 91 =,-r .... -? ,~:~ ,<-z~.~ ~ ~ ~~-~. -- ; ~_ > . ~ :v, ' ' ' - .....,i~ --' , ..... / -- ' ' OH LIS Mag tape 09/06/87 ~1 Sch ~t72436 Tap~ Pos. ~0538l * EXXON: An Asterisk/~(;*) next tg.,~a--li,}sting--X above_m~ns/ you should have received the.Tapt~(.sO an~.L~ting(~) direct}y ~'/bm the respective service company<' , ," ,, , / Victoria Aldridge ~ / / / Producl~or~ Compo 900 Loc Bc,,,o,, Bo,, .,. P 0 Bo~ Ar~cho,o9,. AIc~xko ~'9~19 907 564 S!l ~ I N[)L XED !)Al.lAS ARCO _ _. CHE'.'-RON STANDARD EXXON TEXACO Date' 09/] 4/87 MOBIL T#: 78171 PHIl. LIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge rece pt by signing a copy of this letter and returning it to this office: A-34A B-3B B-3B C-3 F-8 J-19 J-22 J-24 J-25 J-26 J-26 M-15 M-15 -15 Y-2 CN 09/06/87 H1 8700-9260 Sch 5" CET 08/31/87 #1 8633-9872 Sch 5" CNL/GR 09/01/87 #1 9000-9893 Sch 5" Temp. 08/15/87 H1 Surf-960 GO 5" Perf. Record 09/03/87 H1 11000-11233 Sch 5" CCL/Perf. 07/15/87 #1 9120-10209 GO 5" CCL/Perf, 07/14/87 Hi&2 9300-10500 GO 5" CCL/Perf. 07/18/87 H1 11195-11470 GO 5" CET 09/04/87 #1 8200-9600 Sch 5" CBT 08/28/87 #1 9200-10661 Sch 5" CET 08/28/87 H1 9550-10665 Sch 5" GR 08/05/87 H1 8900-9500 Go 5" Hydro 08/05/87 #1 8900-9300 GO 5" Temp. 08/05/87 H1 8900-9300 GO 5" CFS 08/05/87 H1 8900-9300 GO 5" CCL/Perf. 08/16/87 #1 9170-10944 GO 5" Victoria Al. dridge I Nf. ORMATION COt.~INOL We I I Nocoros, INT- I INDEXED DALLAs ARCO CHEVRON EX2<ON TEXACO Da're: 09/22/86 TO: MOBIL T#: 77349 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD /'Xt ASK'A, PRODtJC I-ION REFERENCE: SA_PC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: ~,~A-34A CBT ' 02/08/86 #1 8700-9315 Sch 5" ~ ~^ 02/15/n~ ~,_ e~ 5" ---J~ CET -ob ~;9 8900-9740 ~,i ]?'"'B-30 GCT 03/28/86 #1 15.2-10170 Sch 5" "~'~-D-27 GCT 03/15/86 #1 20-9593 Sch 5" ~H-7 CET 02/23/86 #1 9900-10966 Sch 5" ~'M-2 EPL 02/11/86 #1 9700-10342 Sch 5" --'~-M-7 EPL 02/27/86 #1 9250-9770 Sch 5" ~'M-19 EPL 02/04/86 #1 9950-10592 Sch 5" "~N-8 EPL 0i/28/86 #2 9950-9968 Sch 5" '"'~N-8 EPL 02/09/86 #3 9550-9969 Sch 5" ~N-8 EPL 02/19/86 ~4 9550-9970 Sch 5" ""'~R-15 EPL 02/02/86 #1 8500-9438 Sch 5" ~R-20 EPL 01/20/86 #4 11300-11900 Sch 5{' '$-11 EPL 01/26/86 #1 9150-9650 Sch 5" Y-10 EPL 02/12/86 #1 9050-9776 Sch 5" ~Y-13 EPL 02/26/86 #1 10250-10800 Sch 5" ~ / t..-~%/ 4 D lq~¢fl ~ g:~ Victoria Aldridge LR2-] .//~ ,/~ ..... ~- INFORMAT ION CONTR~ Da~. ~ ~a~aOi~a, Uu', Well Records LR2-1 -~"ho .... ...... TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS . GEOSCIENCES I NDFXED STANDARD ALASK~ PRODUCTION Date: 07/31/86 TI: 77232 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being subml~ted herewith. Please acknowledge receipt by signing a copy of this letter end returning it to this office: ~ A-33 ~A-34A ~ E-13 ~R-23 Cont. Flow Su~ey 05/19/86 #1 10950-11350 GO 5" Temp. 05/29/86 #1 8800-9320 GO 5" DFT 05/29/86 #1 9600-10200 GO 5" DFT 05/22/86 #1 11550-12000 GO 5" Received Vic toria Aldridge I NFORMAT I ON CONTROL Dote ~.~.., ,~ .: ,-:.- ;. r~.~- '-~.~..~ienin~ Wel I Recoro$ LR2-1 _.; .... ' .~,., ~_ , .~=~.'li,,..~,~, lo.,.,,wJrtJ ~,u ,,, IHIO LR2-1 Standard Alaska ~ Production Compam' 900 East Benson Bouk P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION July 10, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 A-34A Well File ~peA~vlsor Production Operations JUL Alaska 0~1 & G~',s Cons. A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. ..-. STATE OF ALASKA ' ALAStl ;:)IL AND GAS CONSERVATION COMI~ ,;ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~.' Perforate C Pull tubing -' Alter Casing~.'--.: Other ~ 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1171' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM At top of productive interval 334' NSL, 32' EWL, Sec. 36, TllN, R13E, UPM At effective depth 319' SNL, 57' EWL, Sec. 36, TllN, R13E, UPM At total depth 317' SNL, 61' EWL, Sec. 36, TllN, R13E, UPM 5. Datum elevation (DF or KB) KB~E = 7~;,69 Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-34A (11-36-11-13) PBU 8. Approval number 65 9. APl number 50-- 029-21339-01 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 9382 feet Plugs (measured) 9234' feet BKB Effective depth: measured true vertical 9335 feet Junk (measured) 9187 feetBKB 12. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size . Cemented __ 61' 20"x30" 8 cu.ydso 2635' 13 3/8" 3720 c.f. 8724" 9 5/8" 1744 c.f. --m 880' measured 8992' - 9056' Measured depth 110' 2684' 8773' True Vertical depth BKB 110' 2684' 8626' 7" 198 c.f. 8502'-9382' 8356'-9234' (four intervals) true vertical(subsea) 8769' - 8833" ~bing(size, grade and measured depth) 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' Packers and SSSV(type and measured depth) 9 5/8" BOT packer at 8435'; 4 1/2" Camco SSSV at 2125' Stimulation orcementsqueeze summary Bullheaded scale inhibitor treatment Intervalstreated(measured) 8992' - 9056' ~eatmentdescriptionincluding volumes used and finalpressure 36 bbl. scale inhibitor followed by 200 bbl. diesel overflush RFCEIVED · · · ~ ~ I_ qFN~F JUL .!. "~ Alaska 0il & 6~:s Cons. Corem Anchorarje 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4580 2849 510 0 \ 2880/~ 1604 979 0 14. Attachments Daily Report of Well Operations 250 259 Copies of Logs and Surveys Run C 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ .~- :~-~!; Signed y~//7/~. ';/~L~ Title Supervisor Production Operations DateT' /(''}' ~ Form 10-404 Rev. 12-1-85 Submit in Duplicate Well A-34A (11-36-11-13) PBU STIMULATION OPERATIONS A bullheaded 36-bbl. scale inhibitor treatment followed by a 200- bbl. diesel overflush was performed on the following perforated intervals on June 29, 1986. 8992' - 9002' MD BKB 9012' - 9016' MD BKB 9021' - 9031' MD BKB 9040' - 9056' MD BKB The well was shut in for 24 hours following the treatment, then put back on production and tested. 7/9/86 INOEXED STANDARD AL ASKA PRODUC ~ ION DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA . GEOSCIENCES Date: 06/25/86 TO: Tt: 77147 Page 1 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledg~ receipt by signing a copy of thls lel-ter and returning it to this office: A-26 ~ BHP Survey A-29 ~'~" " A-31 '"-BHPD A-31 '"-.BH Pres. Survey A-33 "~HPD &"~PBU A-33 '~Static Gradient A-34A ~BU A-34A ~HPD F-17 ~tat F-24 tat J-3 ~tat J-18 05/28/86 Otis 05/29/86 Otis 05/11/86 Dres 05/09-11/86 Dres 06/03/86 GO 06/11/86 Camco 05/19-20/86 Camco 05/20/86 . Camco ic Gradient 06/04/86 Camco ic Gradient 06/06/86 Camco ic Gradient 06/13/86 Camco &'~BU 04/26/86 Otis ~a--PBU 04/19/86 Otis ic Gradient 06/06/86 Camco " 06/02/86 Camco " 06/03/86 Camco " 06/08/86 C-a~-6o " 06/08/86 Camco ~,survey 05/24/86 GO Gradient 05/31/86 Camco " 06/05/86 Camco " 06/05/86 Camco " 06/10/86 Camco " 06/11/86 Camco " 06/07/86 Camco o5/2 /s6 co Static Gradient Received Da?e I I';FCNq.NIAT I C~; CONTRC~_ Wel I Records LR2-1 Date: 06/25/86 T#: 77147 Page 2 of 2!! R~BHPD & Flowing Gradient 05/13/86 Camco S-16 _~Static Gradient 05/27/86 Camco U-2 ~ " " 06/01/86 Camco U-10~BHPD ~lowing Gradient 06/01/86 Camco U-12 ~"Static Gradient 05/27-28/86 Camco ~22-I1-12 Static Gradient 03/16/86 Camco ~/sl~ .Oil& Gas Cons. Oommissi~,-.'- An~r~orage. Victoria Aldridge LR2-1 Well Records LR2-1 PO J~o~ 190~01:~ 1907) .S64-511 ! I NI~XED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS GEOSCIENCES STANDARD ALASKA PRODUCTION Date: 06/09/86 Ti: 77104 Page 1 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submit"ted here~ith. Please acknowledge receipt by signing a copy of fhis let-let and returning it ?o ?his office: A-1 Static Gradient 05/18/86 Camco A-5 " " 03/22/86 " A-31 " "& BHPD 04/08/86 Otis A-34A " "& " 04/09/86 Otis A-35 " "& " 05/17/86 GO A-35 Pres. BU Survey 05/15/86 GO B-1 Static Gradient 05/15/86 Otis B-2 " " 03/17/86 Camco B-23 " " 05/21-22/86 Camco D-6 " 03/14/86 GO D-19 " " 03/23/86 Camco D-19 BHPD & Survey 04/29/86 Otis D-23 Static Gradient 05/23/86 Camco E-1 " " 03/14/86 Camco F-4 BHP Survey 04/03/86 Otis F-10 Static Gradient 03/23/86 Camco F-24 BHP Survey 04/04/86 Otis H-26 Static Gradient 05/25/86 Camco H-27 " " 05/25/86 Camco K-8 Static Survey 03/26/86 GO M-5 BHP Survey 05/18/86 Otis M-17 Static Gradient 05/06-07/86 Camco N-4A " " 03/20/86 Camco N-20 BHP Survey 04/05/86 Otis N-20 BHPD & PBU N-22 BHPD Received Date L Vli~t~iT~ d~rid0N CU~m~e Wel I Records LR2-1 LR2-1 06/09/86 T#77104 Page 2 of 2!! R-23 Flowing Gradient N-22 BHPD & PBU S-8 Flowing Gradient S-10 " " X-2 Static Gradient X-5 Flowing Gradient X-9 Static Gradient X-25 " " Y-2 _ BHP Survey Y-9 BHP Survey o5/11/86 05/15/86 03/13/86 05/17/86 03/16/86 05/26/86 03/26/86 05/19/86 05/14/86 04/07/86 o5/15/86 GO Camco Camco Camco Camco Camco Camco Camco Camco Otis Otis Victoria Aldridge LR2-1 DAL. L~S M~CO CHEVRON EXXON TEXACO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES I NOEXED STANDARD AL ASk"/-, PRODUCT ION Date: 06/04/86 TI: 77083 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material is being submitted herewlth. Please acknowledge receipt by signing a copy of this letter and returning it to thls office: A-7 Temp. 05/17/86 #1 3100-9950 Camco 5" A-34A Spinner 05/19/86 #i 8850-9150 Camco 5" B-16 Temp./GLM 04/16/86 #1 9500-9700 Camco 5" B-23 WOPITS 05/21-22/86 #1 9300-9900 Camco 5" F-24 Spinner 05/03/86 #2 11900-12300 Camco 5" N-20 Cont. Flow Survey 05/06/86 #1 9800-10100 GO 5" N-22 Spinner 05/14/86 #1 10450-10700 Camco 5" R-5 Temp/Spin 04/29-30/86 #2 8900-9200 Camco 5" R-7 Injection Profile 04/30/86 #I&2 9600-10200 GO 5" R-9 Pump-in Temp. 04/27-28/86 #1 8200-9712 Camco 5" S-5 Pump-in Temp. 04/30/86 #1 10100-10550 Camco 5" X-24 Injection Profile 05/02/86 #i 9200-9620 Camco 5" Race iveC ~aTe Victoria Aidridge LR~=-I INF~TIO~ i~e I I Recocos LR2-1 e, Standard Alaska Production Company 900 East Benson Boule,,. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907} 564-5111 May 6, 1986 STANDARD ALASKA PRODUCTIO Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM -~ Enclosures (6) cc: J. L. Haas, MB12-1 Well Records, LR2-1 A-34AWell File . . C'"', '.' x x / · ,/~T/~ A. Bragg, Super~i~or ~roduction Operations A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. - STATE OF ALASKA ALASK/ IL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon % Suspend ~ Operation Shutdown C Re-enter suspended well - Alter casing -' Time extension ~ Change approved program -- Plugging C Stimulate ~ Pull tubing -- Amend order ~ Perforate r. Other -- 2. Name of Operator 5. STANDARD ALASKA PRODUCTION COMPANY 3. Address 6. P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 7. 1171' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM At top of productive interval 334' SNL, 32' EWL, Sec. 36, TllN, R13E, UPM At effective depth 319' SNL, 57' EWL, Sec. 36, TllN, R13E, UPM At total depth 317' SNL, 61' EWL, Sec. 36, TllN, ~R13E, UPM Datum elevation (DF or KB) :~3~E = 75.69 feet Unit or Property name Prudhoe Bay Unit Well number A-34A (11-36-11-13) PBU 8. Permitnumber 85-105 9. APInumber 50-- 029-21339-01 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured 9382 feet true vertical 9234 feet BKB Plugs (measured) Effective depth: measured 9335 feet Junk (measured) true vertical 9187 feet B:K.B Casing Length Size Cemented Measured depth Structural - ,-- Conductor I 61 ' 20"x30" 8 cu .yds. 110 ' Surface 2635' 13 3/8" 3720 c.f. 2684' Intermediate 8724' 9 5/8" 1744 c.f. 8773' Production -- Liner 880' 7" 198 c.f. 8502'-9382' Perforation depth: measured 8992' - 9056' (four intervals) true vertical (subsea) 8769' - 8833' Tubing (size, grade and measured depth) 4 1/2" L-80 to 8435' with 4 1/2" tailpipe to 8533' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8435'; 4 1/2" Camco SSSV at 2125' 12.Attachments True Vertical depth BKB 110' 2684 ' 8626' 8356 '-9234 ' Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May/June 1986 14. If proPosal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig~ned (~'/~'~""~'A. Bragg ~/~-~ Title Supervisor Production O~)erations Date,_~- Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. Q Plug integrity I Approved by ~? [~ii g, ~ifJ] Form 10-403 Rev 12-1-85 · ~' BOP Test ,.,, Location clearance ,~.p.~ roved Co~y by order of e Commissioner the commission Dat Submit in triplicate Well A-34A (11-36-11-13) PBU SCALE INHIBITION PROPOSAL A bullheaded 36-bbl. scale inhibitor treatment followed by a 200-bbl. diesel overflush is proposed for the following perforated intervals in well A-34A. 8992' - 9002' MD BKB 9012' - 9016' MD BKB 9021' - 9031' MD BKB 9040' - 9056' MD BKB The well will be shut in for 24 hours following the t.reatment. The SSSV will be removed prior to the treatment and reset in the ball valve nipple at 2127' following the job. SOHIO ALASKA PETROLEUM COMPANY April 24, 1986 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502~612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well A-34A (11-36-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for-the'above-named well. This contains our sub- sequent repOrt of'the initial perforating of this well for production. PFB: JAM ~ Yours very truly, Po F. Barth Supervisor, Reservoir/Production Surveillance Unit I Enclosures (44) cc: Drilling Well File (MB12-1) Well Records (LR2-1) A-34A Well File STATE OF ALASKA ALASKA . AND GAS CONSERVATION COMMIS 'N REPORT OI;-- SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown C Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing ~ Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 75.69 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit '4. Location of well at surface 1171' SNL, 920' WEL, Sec. 35, TllN, R13E, UPM At top of productive interval (top Ivishak/Sadlerochit) 334' SNL, 32' EWL, Sec. 36', TllN, R13E, UPM At effective depth 319' SNL, 57' EWL, Sec. 36, TllN, R13E, UPM At total depth 317' SNL, 61' EWL, Sec. 36, TllN, R13E, UPM 7. Well number A-34A (11-36-11-13) PBU 8. Approval number N/A 9. APl number 50-- 029-21339-01 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 9382 feet Plugs (measured) 9234 feet BKB Effective depth: measured 9335 feet Junk (measured) true vertical 9187 feet BKB 12. Casing Length Size Cemented Structural -- Measured depth True Vertical depth BKB Conductor 61 ' 20"x30" 8 cu.yd. Surface 2635' 13 3/8" 3720 c.f. Intermediate 8724' 9 5/8" 1744 c.f. 110' 2684' 8773' 110' 2684' 8626' Production Liner 880' 7" 198 c.f. Perforation depth: measured 8992' - 9056' (four intervals) true vertical (subsea) 8502'-9382' 8356'-9234' 8769' -- 8833' Tubing (size, grade and measured depth) 4 1/2" L-80 to 8435" :with 4 1/2"' tailpipe to 8533' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8435'; 4 1/2" Camco SSSV a% 2125' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 4580 2849 510 0 25O 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run r~ 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed i ' '' TitleSupvr. Res./Prod. Surveillance I Date Form 10-404 Rev. 12-1-85 Submit in Duplicate PERFORATING DATA - Well A-34A (11-36-11-13) PBU March 30, 1986: Pressure tested tubing and inner annulus. March 31, 1986: April 7, 1986: Installed and tested lubricator to 3500 psi for all well work. Rigged up Gearhart and perforated the following intervals using 3 1/8" Select Fire guns at 4 spf: 8992' - 9002' BKB (8769' - 8779' TVDss) 9012' - 9016' BKB (8789' - 8793' TVDss) 9021' - 9031' BKB (8798' - 8808' TVDss) 9040' - 9056' BKB (8817' - 8833' TVDss) All depths are referenced to LSS/GR, 5/28/85. Put'well on production. Shut in well to prepare for static pressure survey. April 9, 1986: Ran static pressure/temperature survey at 8800' TVDss. April 18, 1986: Set and tested SSSV in ball valve nipple at 2127'. Well on production. jm 4/22/86 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS Df~ II_LIr'~G WELL COt,;i'Llil-E[) WELL Standard Alaska Production Company P. O. BOX 196612, ANCHORAGE~ ALASY~A 4. Location of At surface: 99519-6612 1171' SNL, 920' WEL, sec. 35, TllN, R13E, UPM 5. Elevation in fee! (~nd~:a(e KS. OF. etc. I KBE = 75.69' A~SL 12. I. 6. Lea~e 0e'~gnal~on and Serial No. ADL 28286 85-105 8. APl 50- 029-21339-01 t9. Unit o, Le.~e Prudhoe Bay. 10. %~11 A-34A (11-36-11-13) PBU ! I. F ,eld and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriale Box To lad;cate Nature of Notice, Report. or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Sub-hi! in TriDllca~e] Perforate ~ Alter Cash~g [] Perloration~ Slimulale - [] A/)andon ~ St,mulalion Pull Tub,ng ~ Olher ~ Pull;ag Tub,ag (Noir; R~ofl mulllpl~ comple~on~ on Form 10407 w,~h ~su{)m,iled Form 10407 {Or tach (Subm;I in Dupl,cale) [] Alle¢~ng Ca~ing [] ~ Abandonmenl [] L3 O,he, [] C3 13. De,.crit~e Proposed or Complet~:l Operations (Clearly slale all perl;nenl de(ails and g;ve pert;nent dates. ;nclud;ng est;ranted date of stnrl;ng ~ny proposed work. for A/)andonmen! see 20 AAC 25.10.~-1 70}. The following intervals will be perforated for initial production during March/April, 1986, at 4spf. 8992' - 9002' BKB (Ref. LSS/GR, 5/28/85) 9012' - 9016' BK~3 ( " ) 9021' - 9031' BKB ( " ) 9040' - 9056' BKB ( " ) A lubricator will be installed and tested to 3500 psi for all well work. An SSSV will be set and tested in the ball valve nipple at 2127' 14. I hereby Cart,fy Iha! th.~ foreqo,ng ,s t.,' .... d./O,,e.C~ to Ihe b~l o! my knowledge' $,gned __/ .-. _ ' r,,,, Supv.r_. Regervoir/ProdoctionL_ The ~O.4ce t)elow lO, Corem,ss,on use P. F. Barth Cond,l,nn~ ot App, ovdl ,! any Y'k () I) ~' 0 ',,"~ ( 1 Fo,~ 10403 Surveillance I _ _ . C0.%~'1 tSS ION E Fi ~Jv O,,le, ol Su{),,.r~,l "lnlt~nl,r)n%" ,n Tt,;)l,(dl(' SOHIO ALASKA PETROLEUM COMPANY 311 ] "C- ANCHORACoE. ALASKA SFO ARCO TELEPHONE 1907) 265-0000 MAIl..' POUCH 6-612 ANCHORAGE. ALASKA 99502 EXXON ~o: Date: j.: .~ ~ PHILLIPS . ; ;-~ ~ TI~: ~--':'~. ' STATE OF AK' "~ ENCLOSED ARE TWO COPIES OF A RECENTLY SENT TRANSMITTAL. CORRECTIONS LISTED AT THE BOTTOM OF THE PAGE AND RETUR}] ONE COPY TO [~E. ';:- ANY QUESTIONS, PLEASE CALL Victoria Aldridge AT 907-564-4445. 7/Dq/85 76293 A PLEASE MAKE THE NECESSARY IF YOU HAVE REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- -16 --~ w/Listing 5/26/85 Job #304968 GO Tape Pos.#03426 * G-13 CH-CNL w/Listing 5/22/85 Job #70469 Sch Tape Pos.#03427 * ~-34A OH w/Listing 5/28/85 Job #70474 Sch Tape Pos.f/03428 *~22 O~ w/Listing 6/10/85 Job #70541 Sch Tape Pos.#03429 7 ~~ w/Listing 5/22/85 Job f/305048 ~ Tape Pos. f/03430 N-21 OH w/Listing 5/20/85 Job ~282024 ~ Tape Pos.#03431 *+ N-13 CH-PDK-100'w/Listing 6/26/85 Job #ECC#2189 Dres Tape Pos.#03432 *+ M-9 CH-PDK-100 w/Listing 6/24/85 Job #ECC~2187 Dres Tape Pos.#03433 ~ *~ R-4 ~-PDK-100 w/Listing 6/26/85 Job #ECC#2190 Dres Tape Pos.#03434 ./~(~f *~]H-10 CH-PDK-100 ~/Listing 6/26/85 Job ~ECC#2188 Dres Tape Pos.#03&35 ~~~U-4 - OH w/Listing 10/16/84 Job ~/281915 ~ Tape Pos.#03436 ,r~~~~~l ~' w/Listing 5/20/85 Job #282024 GO Tape Pos.#03437 ~~~~~-20 ~H> w/List~g 5/04/85 Job #304964 ~ Tape Pos.f'03&38 ~'~H-~ ' ~ w/Listing 5/25/85 JQb #305050 ~ Tape Pos.f/03439 , ~~. 3.) ~-21 tape ~ren on June 2~, 1985 5s the ~P~CE~T tape for June 6 rape. 4.)~-~ 5s the ~P~C~T tape for the tape prevSously sent 5n Nov. 19a~ REC£~VEO ~'~"'~ Oi] Victoria Aldridge LR2-i ....... & Cas Ccns. Commission f--i' -AJ ;_... ,'3. ~ Technical Doc~entation ~ ?.~a ~/[~~, ~ Records Management SOHIO ALASKA PETROLEUM COMPANY SFO ARCO TO: EXXON PHILLIPS STATE OF AK- 3111 "C'° ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 7/Q9/8 Ti/: 76293 .EF~E~// SOHIO MAGNETIC LIS TAPES & LISTINGS ~'~/e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ---J-16' ~ w/Listing /G-13' CH-CNL w/Listing A-34A · OH w/Listing ~* N-22' OH w/Listing ~ K-7 , ~.~r..DR~ w/Listing j N-21' OH w/Listing 5/26/85 Job #304968 GO 5/22/85 Job #70469 Sch 5/28/85 Job #70474 Sch 6/10/85 Job #70541 Sch 5/22/85 Job #305048 GO 5/20/85 Job #282024 GO Job #ECC#2189 Job #ECC#2187 Job #ECC#2190 Job #ECC#2188 Job #281915 Job #282024 Job #304964 'Job #305050 ~- *+ N-13 ~ /*+ M-9' /*+ R-4' j*+ M-lO 1,t-21. CH-PDK-100 w/Listing 6/26/85 CH-PDK-100 w/Listing 6/24/85 CH-PDK-100 w/Listing 6/26/85 CH-PDK-iO0 w/Listing 6/26/85 OH w/Listing 10/16/84 OH w/Listing 5/20/85 /N-20. OH w/Listing 5/04/85 z,/H-5' ~ ;',~ w/Listing 5/25/85 + SFO & * E~ON: An Asterisk (*) Tape Pos. #03426 Tape Pos. #03427 Tape Pos. #03428 Tape Pos. #03429 Tape Pos.#03430 Tape Pos.#03431 Dres Tape Pos.#03432 Dres Tape Pos.#03433 Dres Tape Pos.#03434 Dres Tape Pos.#03435 GO Tape Pos.# 03436 GO , Tape Pos.~!03437 GO Tape Pos.#03438 GO Tape Pos.#03439 above means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this. . _.. - ........... Victoria Aldridge LR2~ DA]'E Alaska Oii& ~ ~o~. -.~ ....... 19 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON .3111 "C" SIR[IT ANCHORAG[:. ALASKA IELEPHONE (9071 265.0000 MAIL: POUCt4 6.612 ANCHORAGE, ALASKA 99502 SFO/UNIT/ TEXACO Date' 6/20/85 STATE: MARATHON ~" -'~~ MOBIL__ T#: 76255 ..._ ,:~.':~ '.~tx~ .- PHI .... S _?~ *STATE OF ~ _ *Da~e to State ?'~'~[' ??~ BPAE (TransmitQal Only) Via Dril~7 REFERENCE T~e following material is being submitted herewith. Please acknowledge receipt by signing a s~o/u~/s~,~: !! PLEASE DESTROY ALL PREVIOUS PRINTS ON THIS WELL. THE HEADING INFOP&tATIOII WAS iNCORRECT. THESE ARE THE CORRECTED PRINTS. l! A-34A DIL/SFL 5/28/85 #1 8770-9367 Sch 5" & 2" A-34A LSS 5/28/85 ,~E1 8770-9328 Sch 5" & 2" A-34A LDT/CNL-Poro 5/29/85 fEI 8770-9373 Sch 5" & 2" A-34A LDT/CNL Raw 5/29/85 #1 8770-9373 Sch 5" & 2" A-34A LSS-Waveforms 5/28/85 lei 8779-9328 Sch 5" STATE ONLY' DIRECTIONAL SURVEYS · agnetic Single Shot Directional Survey t~Gyr RECEivED OAI[ Date' 5/18/85-Job#' 0585-018 5125/85 oscopic DirectionaJ~Surv~ //~ F~~\/.I~.['~: 6/7/85 Job/)' 7LK-BO-50057 Techn~caZ Doc~entat~on Alaska 0il &, Gas C~,ns C0r:~-~e,~grds Hana~e~nt SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 June 17, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gent lemen: WELL A-34A (11-36-11-13) PBU Enclosed in duplicate is Form 10-407, Well Completion Report, for the above named well together with the Well History, Well Logs and Directional Survey. This well has been completed as a non-perforated oil well. Very_ truly yours, SOHIO ALASKA PETROLEUM COMPANY RHR :MSS: elw 61385/0342w Enclosure cc: Well File $17 RECEIVED J U L 0 2 ]985 A/asJ~a Oil & ~s Gu[~s. ~u.~rnissJorl Anchorage '. " " '*~'~ STATE OF ALASKA .--- 0 I~ f (~ l~ J~ l ' ALASI~,~, :~.,L AND GAS CONSERVATION CC: yllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 85-105 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-21339-01 4. Location of well at surface , 9. Unit or Lease Name 1171' SNL, 920' WEL, Sec. 35, TllN, R13E, OPM .LOCATIONS Prudhoe Bay Unit VERIFIED At Top Producing Interval (Top ~vi_shak) Surf. ~ 10. Well Number 334 SNL, 32' EWL, Sec. 36, TllN, R13E, UPM A-34A (11-36-11-13~ PBU At Total Depth B.H. _j~___' 11. Field and Pool 317' SNL, 61' EWL, Sec. 36' TllN, R13E UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe 0il Pool 75.69 AMSLI ADL 28286 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/18/85 05/28/85 06/04/85I N/A feet MSL] one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9382!MD 9158'TVDs 9335"MD. 9111'TVD ~ES ~ NO []I 2127 feet MD 2075' 22. Type Electric or Other Logs Run DIL/SFL, LDT/CNL, LDT/CNL, Cyberlook, BHCS, LSS- Waveforms, CBL 23. CASING, LINER AND CEMENTING RECORD & gyroscopic survey SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" x 30' Insulate( Conduct( r Surfac~ 110' 36" 8 cu. yds. concrete 13 3/8" 72# L-80 Surfac~ 2684' 17 1/2" 3720 cu. ft. Permafr()st E & Permafrost 9 5/8" 47# L-80 Surfac~ 8773' 12 1/4" 1484 cu. ft. Class G with 8% Gel 230 cu. ft. Class G 7" 26# L-80 8513' 9382' 8 1/2" 198 cu. ft. Class G with 18% salt & 24. Perforations open to Production (MD+TVD of Top and Bottom and 25.4- 10#/sack gils~El~ RECORD CU. ft. Class interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 18% ¢~-. 12.6# L-.80 8535 ~ 8437' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9 ~/8" x 13 3/8' Annulus 285 cu. ft. Permafr¢ C down Squeeze followed by 'q150~-2697~ 345 c~_ fr. don.qifio~ Cla.q.q 27. PRODUCTION TEST to kick off. Date First Production Method of Operation (Flowing., gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR iOIL-BBL GAS-MCF WATER-EEL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. COp E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED J U L 0 2 1985 Alaska 0~J & Gas Cons. b~,,.,;nissio. Anchorage 38 witb it st Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . GEOLOGIC MARKERS : : : ' '' " FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sub-Sea Sag River 8800' 8576' Shublik C 8876' 8653' Zone 4 (top Ivilsad) 8896 ' 8673 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the~ue 7 u~..~u~re~helest of my knowledgeDistric Signed ~ '~' -- ~ "~ Title Drilling Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- in9 and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". WELL A-34A (11-36-11-13) PBU 9~LL HISTORY The surface hole of A-34A was vertically drilled as A-34 (24-26-11-13) PBU to 2700'. 68 jts 13 3/8" 72# L-80 Buttress casing were run to 2684'. Cemented with 3720 cu. ft~ Permafrost E and Permafrost neat. A-34 was plugged and abandoned. Accepted Rig for A-34A at 0200 hrs 05/18/85. Cut 9 5/8" casing at 3000'. Pulled and layed down 76 its. 9 5/8" casing. RIH and set EZ-Drill plug at 3150'. Pumped 345 cu. ft. densified Class 'G' cement. Tagged cement at 2697'. Dressed off plug to 2861'. Tested BOPE and kicked off. Directionally drilled 12 1/4" hole to 8781'. Ran 225 jts. 9 5/8" 47# L-80 Buttress casing to 8773'. Cemented with lead slurry of 1484 cu. ft. Class G cement with 8% Gel followed by tail slurry of 230 cu. ft. Class G neat. Installed and tested packoff to 5000 psi, okay. Pumped 175 bbls. 9.3 ppg. NaCl down 9 5/8" x 13 3/8" annulus. Tested BOPs. Drilled cement and FC. Tested casing to 3000 psi. Cleaned out cement and shoe and directionally drilled 8 1/2" hole to 9382'. Ran open hole logs. Ran 21 jts. 7" 26# L-80 liner to 9382'. Pumped 35 bbls. Sepiolite followed by 198 cu. ft. Class G with 18% salt and 10# per sack gilsonite and 138 cu. ft. Class 'G' with 18% salt to cement liner. Down-squeezed the 9 5/8" x 13 3/8" annulus with 285 cu. ft. Permafrost C cement followed by Arctic Pack. Cleaned out 9335', tested liner to 3000 psi, okay. Changed well over to NaCl. Tested casing to 3000 psi. Ran CBL. Ran 203 jts. 4 1/2" 12.3# L-80 Buttress IPC tubing with 4 1/2" tailpipe assembly to 8535'. Landed tubing with ball valve at 2127'. Installed and tested tree. Displaced tubing to diesel, set packer at 8437'. Tested tubing to 3500 psi, okay. Released rig at 1900 hrs., June 4, 1985. Ran gyroscopic survey, tested and secured well June 7, 1985. RECEIVED J u L 0 2 Alaska Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM CO. PAD- A (11-36 - II- A.34A Controlled LES HENDERSON 3334552 Drilling Consultants, Inc. RE :'- i~~e~t~i-c :~Si'n~-:l~[~i Shot Survey ' jo6:~N-o, o585=01B · W~%'l. __A-34Ai'..(ll-36-11-13) .NO~ h-~S~%~bP e.~:- Ai'a S.:~a D~a'~e -~-f .survey:--May 18, 1985 to May 25, 1985 ~ De'at'Mr ~ Rose: ' ". -" .' .~_ .-- .._-.!.'.'./-' ' ~ ~ ..... ~?~ ...- '_ i .' ~ .' '- --. ....~.'.~~ - -? :... · ' .... i - .~-~p~a~j!e~._-~f ~:d( ~.~e ~."~!:i !/[ia~d~'~i-s~x~. ( 6 ) Copies .of our "-:M~Jgfi'~'t/i '~s-h°~'.S~u~V~/':~o~n~~_ ~b0v~/~eil.~ The method used -in-'6~-i~Cu th:is ~s. urve -~adi.us of CUrvature.. The depth · of-. ~n'e- sd~9::'Wa's"'---2s00 %'~s~o.. ' --'.:- . '_ _ - . _ - :.>._. . . - _ ~' "Thafi~S-Y°u~:'~f6~-~iVing~s~-thiS o'~Or~unity to be of service. Yours Very truly, ContrOi~ed Drilling Consultants, w .~-~-~an-d- Directional Supervisor Igc. ,, SOHIO ALf;i'SKA PETROLEUM MAGNETIC ,S~NGL~ SHOT SURVEY SURVEY RAN BY WAYLAND YANCY :CONPUTED FOR CDC E~Y OCEANTE'CH<Ft,~ L;~6~DSEY .~;~ ASSOC, ,) JO9 i,.iO A-- 0'5'85 .... 0 i 8 h! E L L. A--34 ~:~ k:L9 EL.E'V 75,69 SURVEY DATE ~8/05/85 ;' ;" ,C: ~'] R ['~ ¢ F' '"' U ,R V E Y T R U E t'IEAS DRIFT VERTICAL , DEPTH ~}NGLE DEPTH b 'N 2.800 284 O 2~87 I 3451 ~762 4289 4788 5282 5744 62~9 7264 7765 79 03 8 058 8214 288'0, O0 2dl4O, 2S?0,9.9 290i ,3 i '3'3, ~ t 3352,67 3444,53 3746,77 4744 38 5672 51 6630 78 '7142 72 76S2 28 776,7 86 oOr'5 2.724 ;3123,42 ~276,98 3368,84 4 f 82,98 4668,69 ~i 49, O4 5~96,82 607= 6555,0 7 067, 7692, 7845,04 7999,4 F T C; 'T R L C'O 0 R D t N A T E S '"'O N i ;'":' E t i~, r v.= 26 N 2! ~,~, 4~ 48 H ~i,.~ '~07,58 N ItO,F'S !90,50 N 204,6t '266,28 t4 290,27 .";42 69 f~ 3¢., 64 4.~c' 05 N 46'~ oi SOS "?'-' N , ~.o 55E,, 24 5'93, t 5 N 649,5'i 765 74 N 80c~ ~a ':~:33,93 N 827,$8 .... :.-~6 ~ ~4 C L 0 S U R E S , O0 $ 9.0 n 0 6 i i. 54 509 62.2. 749 879 ~008 'ii it"9 li~5 .~f' S I 'i 7 2 ,:t .? C~, -;:,;, 4 4 ':2' 50 50 , ~ N -,:- :.=.,;:3 ~'..~, ~, .60 f-i, ,4:" 3:3' 49 E ,07 N 4;:" 0 .:.;6 E ,06 ;446 24 49 S 79 N .... ~'; '"0 E 37 N '" SS 56 E :40 fi46 .7,65 E SEVER I E G / '~ O 0 F' T , OOO :~?,, '-' ~," . / 2;?.6 44 S 24i 202 '; u,'~ 065 :~ r= ,,~, KB ELEV 7'5:e'.',9 F:T, DRIFT VERTICAL SUB Dfq .T, F T THE FOLLOI~ttNh i,:., EXTRAPOI...HTEi,, TO T ~7'1 0 :~ 45 8568,6~ 84~,,~, O0 N,46,,50'E ~;48 6~; N BOTTOH HOLE ~:.LOSU. RE 1236 O0 'FEET '"," . )--- 8OHIO WELL HEASU~C*~D D'EPT*H AND DEPTH I ~876 2076 22, _, 2376 2476 2876 29, 6 327~ 3380 TRUE VERT I ,,,HL $.UB HC,-TV,~ VEF:., T I C:AL DEPTH SER ':" ' .... r, .~ .... . ,~., I F F E RE N C: E' b OR R E & F .I ON T 0 T H L 276, 376, 576, 87.6, 1 076, t176, 2076 22.76 2376 2676 2776, 29~6 3 3476, 0 0 0 O 0 0 0 0 0 0 O 0 0 0 0 0 O 0 0 0 0 0 2. 3 C 00 R D f N A T E S ,0'0 ,00 O0 , O0 , O0 ,00 ,,00 O0 ,,,OO ,00 ,00 ,O0 ,O0 ,00 ,00 .00 ,00 ,00 ,OO ,00 5,35 23,65 4.'9,69 "7,8 4 K 8 EL E V '~ N C;, L,, E S i,4 0 T ,:,'J R V E Y .... Fc:~.:T OF SUD .,.EM DEP'FH C:OOR D I 'N~ TES 42~4 4512 46~5 402~ ~ 026 %, $129 52St 5438 5644 5747 6057 6265 6368 64'72 6575 6886 3??6, 3876, 4076, 4176, 4376, 4476, 4676, 4776, 4876, 4976, 51 52~6, 5~76, 5476, 5676, 5776, 5876 6076 6176 6476, 6576, 6676, 6776, 6876, 6976, 16! ,, !9 N J77,26 N '193,20 N 224,72 N .:'a4..e, 38 N ,~?'t,,08 N 286,59 N 302,34 N .-'.~ ,36 t'! 334,62 N :351 14 ..... "4 · z,?, 59 N 4..~5 87 N 45~ 41 N 4:39,30 N 507 64 ~'..!:' 526 'i 7 N 344 86 i'-~ 563 68 N 582 'S5 ~.~ 60! 72 N E, 2.'9 lE, H 't 34 207 ,. '" ' ;;a6O ,. 90 078 '~ .. ~, , ,:, r=, · .:.~1 , ~'" L,,:, ..E:49, 'I2; 4,9f q':' 501 581,i! 639, ~,~. 67 E. r"OHPE~TER.-.. K £~ E L E V SOHIO W~t,.L A,-34A S:f/{.{;~LE S/,..!OT SURVEY ,JO~ i,40 TRUE MEASU. RE£,~ V£R'r.i[CA~ SUFS i"iO .... 'FVC' YERTICRL DEPTN DEPTH SEA ~ IFFE,;~!ENCE CORRECTION TOTAL. COORDINATES 7503 7G 05 7476 ~ 74 7707 ~ ~ i 4 7 83~ 5 84'¢ 6 8276, 8200 85t 6 8~Y6, 8~00 861 7 8476 871 O 8569, 8493 675 ,,, 7 ! 0, :2.7,,g N 726,64, 742 ,.,39 N 757,48 N 77 ~ 796,4.8 N 8~'8,28 N 848,66 772 70 828 4 ~ 887,60 C 0 H P t,f T' E I~, i'(E~ ELEV I NTE'RPOLA TED DEP'I'H i 000 ::ZOO0 ~000 6000 ?000 8000 87{ 0 TRUe. ~000. 8569, O0 O0 O0 4} 4~, i'-~, ..... :-,~ ..... ,t~---7~-.-T--:-~-' ,--:-7-~ -7': ..... i ...... :_-[ .......... ~ ....1.~--': ......... : ....... ! ..... ~. :'.. ....... :j~=_ ,~ ..... . ...................... , ......... J,.' ' i J - ' - ; , J ~ : . :. ,J '. { , :,i,,,ii,; ,I i ....... i . : . : · , - · _ - -_ .~.' '' i ....... '-J-: 7- i:_~.: j~ 7-: :-i ......... j-~--i :' ," ..... j ..... i ...... HORIZONTAL. ~/IEW--~ ..... j .... I ..... i-- ~ -'- !"--~,--j-=' ' :-i '-.-': .... j ..... "-~--'~-:---J .... :-,'- .... i ......... : ;: - -- WELL A-34A(I'--36-t1413).-- ~ ..... ~ ' :RADIUS-OF CURVATURE ' , ~ , . . I. ~ J · I ' : ........ .:- ....... t , ....... r .......j- .................................. t-' ' -' ..... j_ .... -':---~-=--:-- I-j ..... : ~ =':-:j~-: .... ~-~:'- .-~-T--:T : : .... : ....... MA6NET' SINGLE SHOT:-J ~--' -~' '-: : .... i-: ~-:--:-: t .... -~ ~- ...... '~----J-~ : : .:_T,-'L~: _:-: .l/_ L :-_:?~::.: . SCALE: I':= I000' .-:'.-~ J '-T77:--;.-7- ~ I': ;7: ..... j~-: :-;~ i ~: - ' ~ · . · i. · . ~ ~ ..... ' ' : ~ MAY-3tFIgS~ ' ' ' .'---~ .......... j :-:--E - ,, I' - - : ..... -I---:---'-.~ ..... ': -: ....... I- -: ..... :'i .......... ' ....... :- ::-:' .... --: .... ~i7 .... -T!; '.-'. :! ~-;-.'i- i 1-.--;.7-:. !--T: !-~-:-?-~ .,' ' : · · J_ ...... i . ! I :. ~!' .j, . : . . , J~ ? , .......... J ........t ....... ---;-" ......... ~ ...... '-: ! P" .... ~ .......... *' .......... ':-: .............. ~ ...... t ": ............. -: ...... : ....i ....... t-t .... -~-~- ..... j~-:.: _~ :__-: ..... ;._ ..... i_ ...... f ...... ~ ~, ' . ; i -- , : , J l _ ~ : I . - t _ : _ . _ - _, '. . . . / . : ~ . , . ........ ~-=-"'---- II-: .... : ....... ' ....... ~-:---:-: ........ t ....... I'-'- -~- ....... .... :-i' - '!-:fi'-: .'.il"-:~ i' - ! .... l .... =---:~"i-:' ~j ...... ,~-:'-:: .... J'- : ......... , '-i~ ........... : .... : : ........ : ' J-: : ~ - I : -~ ~ : t '" ~ ........ : ..... ~ ~ ...... j_ .... :' - ' ~ ' ' : ...... 1-: '" ! .... ]' " ' t .................... ": : ' ' : ' ' : - ' .... ', .......................... : .......... '-:-4- . ~ ........ - ............................................ · '-'l . ,: :.t .,. ~ E ..t.,. ; t. ~ . , ' t .~ , _ . j ,.,., ...... i ' ' ' ' 4-MD_8~7'j-0' [ ": , , .... [ ........ :-:---[ .... :-!T .... ~t- ...... :-: ....... ~:-:: ......... i: :"~%,'~R/'~t',,:-=-'-i .... -~--I--~ .... 7: ..... Is ........ i ........ :--:7..t_:-: ..... !-:::---:::--F:---/:- :-i" -: --i-:- :- .... ::.:i:i t--:-:-:':' i' :-:-:-:---:-:' ::-i:-I " ~.'':'t-' -?~c,'q;,,~,T,~%-%'"'t=~ : .... t=.'.,,, ' .i ; :I .... .~z_._.. j' ...... ~ ;~--'--': ....... . j- ....... -- ~ __~' _ j :_:__ ~ .....2_ ~k~,7.~_,~'~"O_ ;'" J~"O.. ; ~: !~: _ .: ...... :.:__ ....: _ J . :_. ........... : ~ ........ , J : ....... ~ ..... : 4__ ; -. ] . , i J , ~ ! - ~ , , n-.._~ - -': ,- : - - . , , : . . . ' ~ ' , ~ · '- . ~. ' · ''- -~- ~-:.--~,; '' · ...... :-:~:- ............... i--.: ............ ~'-:--'! .......... J June 18, 1985 Directional Services Pressure Services Chemical Transmission Systems Mr. Oames A. Bragg Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Our BOSS Gyroscopic Survey Job No. AK-BO-50057 Well: A-34-A Prudhoe Bay, Alaska Survey Date: June 7, 1985 Operator: T. Mcguire Mr. Bragg: Please find enclosed the "Original" and sixteen (16) copies of our BOSS Gyroscopic Survey on the above well. Thank you .for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. B.'.~ n Broussard District Manager Enclosures CONFIDENTi [ STATE OF ALASKA RECEIVED NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 .J u L 0 2 ]9[15 Alaska Oil & Gas Cons. Comrnission Anchorage .) ....................... ~'~ I I ~ ~ ................................ .=,FERRY-.=,UN WELL 'SURVEYINO COMPANY F'AGE 1. ANL. HURAo E ALA.=,I....A SOHIIZI AI_A.=,I,..A I='ETROLEUM I-:0. I:IATE OF .=,_IRVEY ,.IUNE 7, :L,~,-,-,=' A =34 A ( S E ...:-, 5 T 1 l N R 1"3 E) I.':l:'l M F' I'1 T'A-TI' I'IN'--[! AT E B ri S :=:'" G Y R 0 S C: 0 P'I C"'"S Iii R V E Y I='RLIDHOE BAY ,.JI. INE 10., 1 .,:, ,=,._, J 0 B N U M B E R A K - B 0 - 5 (') O, 57 i"', .' ALAoKA KELLY BLISH'rNG ELEV. = 75./...,9 FT. C~F'ERA TOR=MCr. iUI-RE VERTIC:AL SECTION CALCULATED ALONG uLu.=,_IRE MEASURED VERT I IS:AL VERT I C:AL I NC:L I NAT I ON D I RECT I ON SEVER I TY RI-_-r:TANGLILAR C:OORD I NATES VERT I DEPTH DEF'TH [ EF ] H BEG M i N DEUREE~=, DEG/100 Nr'~RTI-I/~]I I]'H EAST/WEoT SECT 0 0.00 -75.69 0 0 N O. 0 100 100.00 24.31 0 42 S 23.50 · ' ........................... 200 ......................... 1 ".~ 9; "P 9 .......................... 1-2 ~'7-30 ..................... 0 ..... 54- ........... S"'--2 'F*' ;-'80 ..... :300 29'P. 98 224.29 0 46 S 10.89 400 399.97 324.28 0 49 S 20.L-':0 500 4'~?,~-~6 ............... 424', 27 .................. 0 .......... 4'1 .............. S'-' 1'9';'30" 600 599.95 524.26 0 51 S 2:3.60 700 6':::"~..... ¢'4 624 . .."""~,., () 45 S 24 . ,=,'-"~¢ ........................ 800 .................... 7".~9';-93 ........... 72~'.-24- ....................... (r ...... ~'7 .......... S-26¥30'- WOO 899.92 824.23 0 42 S 28.10 1000 ?99. '? 1 924.22 0 28 S 43.80 .................. 11 O0" 109.9. 'P1 1024, ._'::'2 ........... ~ ......... 4._,~ .............. S 58. 8':? 1200 119':?. 90 1124.21 0 41 S 68. :30 1300 12'P9.90 1224.21 0 18 S 18. 0 ......................... 1 ~00 ....... 1399; 89 .........1324 ;' 20 ................... 0 .... 23 ........... S ..... 7 ir-I- 0 :1. 500 1499.89 1424.20 0 18 S 55. :--:0 1600 15..09.89 1524.20 0 17 S 15. :39 ............. 1700 ....... 1677.89 1624 ;20 .............. 0 .... 2'1 ............. S 65.10 1800 1799.89 1724.20 0 :37 S 31.:-]9 1~00 1899 q'-~ :s:24 - - .. . ~ c, 1 . 19. 0 27 5 ~ 1 . ~,~~'-' ] 2000 .......... 1 ?'..~P.; '~'-' ........ ~.3 S ' ,=,o 1192~-;--1..'?:'.' 0 ...... '" ...... 38 0 - 21 O0 2099.~.'R~ ~_.'.-'024 .1:3 0 37 S 41 . :=:'.~_. -' -' O0-. l'Oe..... 87 2124. 18 0 36 .'_4 .=,_. 69 ................. ~'~ ] ....... '~"~"~'~ ' '~ ............ 2224 .......... · .',:,Or ~_~...... 06 ;'1-7 ........0 ..... 39. .... c-~, ._'~'-?. 30 2400 23~..... 85 2324 .16 0 34 :,~' 54 . :--:¢~_. 2500 2499.85 2424, 16 0 :39 :--; 4'.-?. 0 ................. 2600 .............. 259'?'.'. . :~4_ ........... ...~'~.~"~ =-,. 1 ~, ~ ............ 0 51' - S a~_. .10 -- .--, ..~ 2700 2699.83 ...~ .-'4.14 0 :37 .=,'-' 62 .60 .',. OL) 2799.83 2724. 14 2900 o'800 7:3 ':"-' 58 ....... ..' ,_, .' 4.0'? 2 N 47 · 30 .................................................................. !:':;PERRY=..'SLIN' WELL'-~'" I' "; · =,L RVEY I NL-, I lCii'"iMPANV F'AGE 2 ANCHOIRAGE ALASKA 8OHIO ALASKA F'ETROLEUM RO DATE OF'-'oLRVEYI" dUNE 7, · .. ='~ 'q "'"' .... ~ ..... B_.=,.=, L',YRU.=,L.U¢~U c, URVEY A ,.. 4A ( ._ EC..=,ST131. NRI.:,E ) COMPUTATICqq "K~ATE C,'"':"-'"''~ "r.-'-," ~ ~-.="'r, '"~ F'RUDHOE BAY ,JUNE 10., ":,'~'~ . 1.': .... dOB NLIIdBER AI'::-BC~-50057 ALASKA KELLY BUSHING ELEV, = 75.6'.'.-¢ FT, t_]PERA' ' 'FUR-ML.L',U' ' ..... ':"' I RE" ' VERT I CAL SEC'T I ON CALCULATED ALONG L. LL-' ]'-'.=,I. IRE' ] RLIE ..,LIB'-'.' · ='-'._--,ECl .................... IL. OI:IR._,E"' - ~ ..................... COLIR._,E~ ' ' ................... DI_iI_.~'-'-EEb'- - "" T Iii T AL[ ..................................................................... '-' I' '-I .... '~' ' -'i'1' ' :-' MEA.=,LRED VERTICAL VERTICAL INC:LINATION DIRE_.1 ION .=,EVERI ¢Y RECTANGULAR L. JJRDINATE.=, VERTI(" ] ~ '"" '-'Et'Ti Y DEPTH DEPTH DEPTH [EU I'I I N DEGREE:=; DEG/10,0 NORTI4/'.=;~'~U TH EAST/WEST .= ...... 3800 3782.33 3706,64 3900 3879.30 38.03.6 i ............... 4'000 .................. 3?76: 30 .........3700~;'7_-, 1 41 O0 4073.38 3997.6'~ 4200 4170.50 40':74.81 4300 ............. 4267';-62 ............ 4 I? 1-, 73 4400 4364.77 4289.07 4500 4461. 'F¢4 4386.25 4'600 .......... 4559:1'4 ............. 4483;'45 4700 4656.38 4580 · 69 4800 4753.66 4677. 4:PO0 ..... 485'I ;-'07 ......... 4775=37 5000 4'~48.50 4872.81 5100 5045.8:_--: 4?70.14 · :, (.) 00 29'-?'-? 47 ..' 9-..' .=~ 78 ,.,-'= .... , N E ,::'- · · :, J 06 1 ~' "=' ''~ .:, ...... -", '-, ._,. 4-0 :--; E 7 47 ::~ 1 0 0 3 0 '=~ ::: 8 1 ,.,':' ,.0 ~.'~ ,_'=: 31. '-' - - ':' .'-] ':, ,:, ~: 7 10 N L::b.: 60 E 1 '"'-' /= ...... '" · :, '~('}... ,_, E 18.66 ................. '":"-":'._,.,:..t)O .............. '":.., .......... I '.:'¢7 · ':',..,L} ....................... ._,z,.1.-o-~,.,:. -.' ................................... · 1 I ~".'-.~ ............... ........ ~ ............ N Z~l · .1_ '~:: ....................................... E ]. · ,_'q ~ ............................... iq. "-44 ~\' ................. .~-c/'-'%4 :"--~" ............. "'"'" P]"-."~ i i .- .': · .-.-{ ~ ._~ .~2. _ . · ':,.~ r~ r}:R 29/., :'=: 1 '-"-' '-'" .... ,:,..'-.'0 62 10 4.1 N 44 3'.-? E 1 75 31.6 97 N 51 00 E 49.61 344]0 '--'- '-' ..... "~" 0o..-,,+ 26 8 ,.7 12 N 47 i'.-? E 1'"'" · --,.- .~ ~ 28 '" ') A~' · =,< · 'P 4 N _ ,., - . . · · · ,--,,=, .4:2 E 6?. 65 ................ "':' .................. ~ .......... ' ~ :_--,'2 s ...... . ,:,..,00 .:,iq... i ;-F,:-R... _ · ,:,~ i ._. :=:? ....... 14: ........... '4'" ........... N 4-8 80 .................................... I= 1.7:,.=, ' ................ 46.2'-?. N .............. ._ · .:,6UO .-,F,,-,o ?,.=, · : .... : .... 3512 ':~ 6:2 '=''-'"~ · ,_ 4 i 4 ~ 7 N 4':?. 6 0 E 0. :2'i~ . .... .,._.. hi 101 04 E 117 10 :_--:650 '=:63A ?7 "=:~61 ":"=' - '- - ..........=,-, 14 24 Iq 4. 8 1 '-? I.= 0.7:3 70.44 Iq .1. 1 ............... {4~5'0. ............... ._, ,, c, c,'"'-"~ -'"'. c~ c.-, ............................... ............. 365~";- 1. 7 1 iq: I -'='-._, ................. ~ 4-9. ~--._-,~ ................. E- .... ~3' .................. ,=,6.'-' ....... 7.:,-'= ....................... N i ~'-"<'/.., _1.4 11 Iq 49. 0 E 0.,'4 94.77 N 1.'_4:_-:. :30 E 166.54 14 4 N 4'.=/. '-'c . . . . .:,] E 0 13 110 7.'.5 N 156 78 E ....... 14 ........... I .......... N--4-°-''~'¢~,. ,:,; .... E ........... .................... 0'2-11 1 ...Z=,.'-~ ..... 6._~ ...................... N 17~.5 .... i.:,'~'- .............. E ..'1~?,'. 24 13 4.5 N 49.69 E 0.34 142.30 N 1':73.33 E 2:3 13 48 N 4'.-?./_-,'~ E 0. ' ~ . . . {..)~ 157 70 N '.Pll 4.':? E 263 0 / ........... ~ ..... ,~, ................. cZ-- ........................... ~ ........... )" -I._, zl_, N z~; ,E,O E O. 0-.' "173,-1'5-'N ............... 22'.=/':'~7 E ............. 286" 1 ''~ ':"=' N 4:7. '-"' ,-,=~ E 0 17 188.47 N 247 77 E '::10 A3 13 '-"-' o,=, N 49.69 E 0. (34 ,,.":'(").._, '<' . 70 N .' =,._, .'-'/' '~?- ...... ...... ~-~ ....... N'-'503-"I O'--E .................... O'ZiT_-; .............. 218.-:_--::_"-: ............. N '~'"~"'..'.:..:.. ...................... 76 E 13 30 N 4'P.89 E 13 15 N 49.50 E 1"2 55~N-z;..c~. 1'?- E 13 5 Iq 49.89 E 13 25 N 4'.-?. 60 E .................. 5200. ............. 51-iq.3=0I ...... 5067'-''~. ,=,-- ............ Io~ .......... ~ N z[o ..... 78..~ .......... E 5300 5240.02 5164.32 14 16 N 48 · :E:O E O. 4:3 .'-::24 · 42 5400 5336. '.'74 5261.25 14 14 N 4?7. :E:O E 0.25 340.47 5500 ....... '" 5433='80- ......... 53582'1 1 ............. I'4 ........ 33 ......... N'-z~72'89-E ...... O. 56 ' .... :_--:56,'83 5600 55:30.62 5454...o:3 14 22 N 4.9.50 E 0.4:_:: :373.32 5700 5627.42 5551.73 14 42 N 4'..='. 1'~ E 0.34 E::39.68 ................ 5800 ..... 5724 ~-1'2 ..... 564:3,43 14 48 ...... N 4'P.'39 E 0.'10 406.2'P N 407.20 E 520. 14 Iq 425.87 E 544.76 -N ............. '44-4-.-'59-E ........... 569./.-.2 I\1 463.35 E 5'.'? 4.5'.-7-' N 482.40 E 619.7C) I\1 501.71 E 645.17 ,LHIO ALAoKA PETROLEUM CO ...... A=3~A,.CSEC35Ti,.1. NRi-3E) PRUDHOE BAY ALASKA · =,PERRY-.=,UN WEI_L ._ L RVEY I I',IL.', L. UMF ANY F'AGE ._,":' ANF:HF~RARE ALA._ I....A DATE (iF SURVEY ,JUNE 7, :1."'-"=::.',=,._, IL."'I'.IMF'U'I ............. AT I ON £1A'~ E B I'.1.:,.:,'"'" ..... bYR I"1"., .:,IZ. LIF' I C..:,URVE Y- ,JUNE 10, I'~F".=,,...,.. ,_I¢;B NUMBER AK-BL-..,O .).:,7 KELLy BUSH INC4 ELEV. = 75.69 FT. OF'ERATOR=MC:RU I RE VERTICAL SEC:TION r':ALCI. ILATED ALONG L. LL.'",LIRE ............................................. TRUE .......................... SUB----SEA ......................... COURSE ................ COURSE ............ DOG~.LEG .......................................... TOTAL: ........................................................... MEASURED VERT I CAL VERT I CAL I NCL I NAT I ON D I REC:T I ON '.=-;EVER I 'FY RECTANGULAR COC~RD I NATES VERT I C' DEF'TH DEPTH DEPTH DEG M IIq DEGREES fiEG/100, NI_]RTH/SOI_ITH EAST/WEST . SEF:T I 5900 5820.75 5745.05 15 3 N 49, (") E 0,27 423.12 N 521.21 E 670,93 /_.-,000 5917, 29 5841.59 15 10 Iq 4.8, 6,0 E 0, 17 440.29 1'4 540, 83 E 697.00 ..................... '6'I'00 .................. 6013;'76 ....................... 5938;"07 ........................ 15 ....... -20 ........... N"'"48;"60'-'E .................. 0;"1'6 ............................ 457;"70 'N 5/_-,0';57-"E .................. 723 /.>200 6110, 16 6034, 46 .:1.5 30 Iq 47,80 I:-. O, 27 4.75, 4.::: Iq 580, 3..'.'9 E 74'P. 92 6300 6206.50 6130· 81 15 33 N 47.30 E O. 14 493.50 N 600.15 E 776.68 .................... 6400 ................ 6302,82 ........ 6;227;'1'2 ....................... I5 ........ 40 ............. N-'-46';' 60' 'E ............ 10-;'22 ..................... 51'1-; 87' N .............. 6,1.9 ;"SI'""E ................. 803.58 6500 63..o9.07 632:3.5:8 15 46 N 45. :39 E O. 34 530.69 N 639.31 F_: 8:30.64 6600 6495.32 6419.63 15 4.2 N 45.50 E 0.07 549.7::: N 658.65 E 857.73 ............ 6~50 ............. 65~,3;'-~8 .............. 6467 ;~79 ............. 1-5 ...... 30 ........ NI. 6"-,' ....... 0 .... 6750 663~. 92 656,4.2:3 15 :3 N 4-5. 0 E 0.44 ._77 ,64 N 687 .1'"'.:, E :--:97 . ._.=;4 6800 6688. 19 .............. '~..°00 6784; 86" 7000 6881.69 6806.00 7100 6978.66 6902.97 ................. 7200 .......... 7075; 74 ........ 7000.' 05 7300 7172· 97 7097.28 7400 7270.40 7194.71 .......... 7500 7368, 03 7600 7465.86. 7700 7563.80 .................. 7800 ........ 766'1 .' 84 7900 7760.05 8000 7858.50 ............ 81-00 .......... 7957,' 18 :::200 8056.15 8300 8155.34 ........... 8400 ............ 8254 ;65' :q45(3 '~'::'""~ '-"-' · . . ~. ~- ~.,-'r · 8550 8403.83 .... 86'00 ,_ q "' ="-' ~ ,.., c,. 66 6612.50 15 4 N 4.4.39 E 0.34 586.91 N 696.:30 E 910.54 6709.16 ................. 1"4 ....... 35 ................ N-'-Zl.Z~;'30' E .............. 0';'.49 ............... 605.21 ....N ................ 71'4':'20""E 97:6.0/_-, 14 1':' N 4::: '-"- ,=, .':,' E 0.30 / '""-' .... :,-,' ..'~. 1:3 N 7.'2_': 1.57 E '? 60.9:2 13 56 N 4.3. 0 E 0.42 640,85 Iq 748.36 E 'P85.:.-- .... 1.-3-, ...... 49 ........... N-.42;'50--E .................. 0-;-1'7 .......... 6,58 ;-4.8'-'N ............... 76'4 ,' 65' E .......... 1' 009, (. 1:3 11 N 4.4.30 E 0.77 675.46 N 780.69 E 10:32.34 12 49 N 43.30 E 0.43 691.70 N 796.27 E 1054.75 7292'"" .... ~- ................ · c. 4 ......... 1. 10" N 43';-60 E 7390. 17 11 45 N 43.60 7488.11 11 32 N 44. 0 ............. 7586;] ti. ..... :"l.- .... 12 ......N-'zl-Zl·; 50 '- 7684.36 10 26 N 46.69 7782.81 9 46 N 49,10 ..... 788'1-,'49 ..........8 ...... 49 .......... N'--Zl-8.80 7980.46 7 34 N 4:_=:. 50 8079.65 6 58 N 45.30 ...... 8'178; 96 ....... 6 - 30 ........N'-46, 0 8228.64 6 :2:--: N 46,. 10 832:3. 14 4 56 N 52. :3C) 8377.97 4 27 N 54. 0 0'6.5' 0·41 0.23 '0,-34 0.87 0.7'.-? ' 707,41 Iq ............. 81'1 ;15 E 1076.28 722 42 N '-""'=' · ,:.-' ..,. 45 E 1096. '..-?'.--. ' 736.99 N 839.42 E 1117.04 ........ 751";"I2'" N ......... 853;-I"8'-' E- .......1136¥69 764.27 Iq 866.59 E 1155.44 776.04 N 879.60 E 1172.97 0-..04 ~ ................. _. _ 7o =. 65 -'N 8..'9"1%-79 E ..... 1 I R9 1 ."'4 1.25 0.72 0.48 O, 09 :1.. 65 I:'00 796.07 N 9(_]2.50 E' 1203.40 804.72 N 911.76 E 1216.06 8 I2, 'P3 N ............... ?20. '16"'-'E ............ 1227':'7..~ 816.85 Iq 924.22 E 1233.4.3 ,'_--:2:::. 39 N 931.69 E 1243. :::6 ,=,-'._,. ,:,._ N 934;97 E 1247 44 SPERRY=SUN WELL '.:;LIRVEYING L':OMPANY ANCHORAGE AI_ASKA :':;OHIO ALA..~.,A PETR¢~LEI IM C:O A ,. z~A ( ._.El ..... 5T ].-1NR1 .:.E) Ri-ii';'IPi]TATI ON DATE PRLIDHOE BAY .JUNE 10, 19:_=:5 ALA~k.A VERTICAL F~ECTION CALE:ULATED ALONG CLOSURE PAGE 4 DATE ~']F SURVEY ..JUNF' 7, 1'--,''-''=.-. BI.I ..... -I]VRI"i:":'I'~I"I¢~'~ i]'" '~'":1' I¢''''~'''' ~ dOB NUMBER AK-BO-5¢~057 KELLY BUSFIING ELEV, = 75,6.9 FT. ~ PERA' '"1 '~ L~ R ~ ~1 b. L'~ b~m' ,,,., ..... '"% ~' I .......................................................... TRLIE .................... SI,IB-='SEA ....................... COLIRSE ............... COURSE ............ DOG-LEG .................................... TOTAL .................................................................................. MEASURED VERT I CAL DEF'TH DEF'TH VERTICAL INCLINATION DIRECTION DEF'TH BEG M I N DEGREES 8700 8553.41 8477.71 3 41 N 55, 3°:] E 8800 8653.1S~ :_--:577.50 3 52 N 56.1 S/ E ...................... 8.900 ................. 8752';"'T~5 8677;-26- ..................... 3 ......... 58 .............. N'-58 ;'"IO 'E !.')000 :=:852.71 8777.02 4 4 1'4 59.39 E S~100 8'?¢52.47 8876.78 3 50 N 61. i'F/ E ?200 ..................... :T,'052;"24 ................ 8:~7~;755 .................. 3 ......... 515 .................. Ixi'"60."30 E '..-~3 O0 91 ="-' · ._,..'-. O0 '~¢~'76.30 4 1 N 5.c:,'. 10 E 9382 '7233.79 ¢~158.10 4 1 N 5.9.10 E SEVER I TV REC]'ANGULAR R¢~,]RD I NATES VERT I DEG/100 N JRTH/SOU]'I4 EAST/WEST SECT 0.77 82'?¢. 'F?7 0.'19 833.68 O. I6 ...................... L=.'37." 3 .-'F.~ 0.14 :941.03 0 · 26 844.45 0 ." I'3 ................ 847;' 77 O. 11 851.28 0.00 854.23 N ?,'40.77 E 1254.52 N '.-."'/46.24 E 1261 · 0'..;' N .................. 751% "?D'-E .......................... 1' 2~7 ;-86 N '.~57 · '~8 E 1274.77 N '~63·97 E 1281.53 N .................. ~67;"..90""E ............ 1'288, 18 ' N ?~75 · 8'~ E 12'~5 · 01 N $~80.83 E, 1300.66 HORIZONTAL D I8PLACEMENT = 130¢~ 66 FEET AT NORTH 4:9 DEG. ~/--, M IN EAST AT MD = .~..,.=,...- ........ ~HE"-C'AL'CL~L'AT'~ ON'-F'ROCEDURES'-ARE-BASED-L'~N-THE--USE' OF '" THREE- BI MENSI ONAi£" RAD I US- OF-'CEIRVATL~RE-PIETHOD ............ ANCHORAGE ALASKA · :,L HIO ALA'.=;KA F'ETROLEUM CO. A = :.3 Zl-A (.=,,"-"- r'''''' '= '''''''_. .:., .., ~ 1 1NR 1 '"..:,E .................................................... ) i-:I'IM F'I_ _ _ITAT I fiN'"_ [FATE F'RI_IDH~'~E BAY dUNE 10, 1985 ALASI<A % ""i I '"' I f'" · = PERRY-..--,. N HELL .=,L RVEY Z N..., COMPANY F'AGE._,'~:' L]A]'E ~"~F :_.=;LII-RVEY dUNE 7, 1'--~"'"-.-. ,_-,._-, ,_lOB NUMBER AI....-BJ-._,L)L)..,7 = .'=,, .,;-,, KELLY BU:--;H I NG EI_EV, 7 .... 6 F'T. I]. F' ERA'" '['LIR-MI...UU- ' .......... I RE' I NTERF'OLATED VALUES FOR EVEN 1000 FEET OF MEA.:,I_REL; [EF]H , ] RUE SUB-SEA TOTAL MEAoL RED VERT I CAL VERT I CAL RECTANGULAR COORD I NA]'ES MD-TVD VERT I CAL .... I]EPTH ...........DEP]'H ............... DEPTH NORTH/:_=;OUTH ............. EA._ T / WE,..,T P I FFEREI',IRE ........... E:ORREC:]' II]IN ,¢ 0 O. O0 -75· 69 ......................... .1000 ................ 999;-91 .................... 924 ~ 22 2000 1999.88 1924.19 3000 2999.47 2923.78 .................... 4000 ............ 3976 ;'30 ....... 3900; 61 5000 4948 · 50 4872 · 81 6000 5917.29 5841.57 7000 ............. ~881 ]-69 ................ 6'806;00 .................... ~523".-'1-S"--N 8000 7:358.50 7782.81 776.04 N :?000 8852.71 8777.02 841.03 N ................. 9382 .... ..0233.79 .... .9158, I 0 - O. O0 O. 00 0.00 ............. 1'1;5'! ........ S ............. 5';07' E .... 0.0'.:~ ................................. 0,0? ...................................................................................... 17.14 '._:; 10.27 E O. 12 0.04 15.40 :-'; 23.32 E 0.53 0.41 ......... 1'26';'65-N ...................... I75'; 13"' E ................ ~2::: ;'70 ................................. 23 ;'-'1'6 278.16 N :353.61 E 51.50 27.80 440.29 N 540.8:3 E 82.71 31.2:L 731-'.- 57"' E ..... ---~-'1~,'-~'- 31 879./_-,0 E 141.50 .957. '.-.'..'8 E 147.29 ........ 854,23'"'N ............. 9:-':0. :'-':3 E ............ 148-21 .............. 35 ';' 5::* ...................................................... 5.79 0;91 .............................. ]"HE L. ALL. I_LATION PROCEDURES ARE BASED ~]N ]'HE USE OF THREE D IMEN:=;IONAL RADIUS ElF 6:URVA'FLIRE METHOD. .=,PERRY-oLIN WEL.L .=,IJI-,VEYINI] "'COMF'C~NY' PAGE 6 i~, ANCHORAGE ALA.:,~.,A c.,LHIO ALASKA PETRF~LEI. IN CL-I DATE OF .:,I_RVEY ,JUNE 7, ~.. ,:,._, ........A ~ ._,4A '':'? ..... ( rZ;._ E I"..,:,._, 1'-' '='' ' ..... 11 NB" I '".:,E ............................................................................................................................................................................................................................................................... ) CO~PUT'~T I ON DATE 'i PRL DHOE BAY ,.ILINE 1 ¢~, 1 ,:,,,r,,= I "- ' .... .'.,:,.-, ,JOB NLMBER AI'.:'-B¢I-S0057 ALASKA KELLY BUSFilNE~ ELEV. : 75.6'R FT. ........................................................................................................................................................................................................................................................................................... i-.iF E~A j i_iR_Mi_.i_.ii.~i ~, ~1~', , ... ; ,:.,.:..-.,. ; ..................................................... I I',ITERF'OLATED VALLE._-, FOR EVEN :1.00 FEET ~ZIF c.,LIB-.:,EA DEF'TH ]'RUE '..Il ' '-' " ~ JB-~.EA TO]'AL MEASURED VERT I CAL VERT I CAL RECTANGLILAR COORI] I NATES MD-TVD VERT I CAL ) DEPTH .................... DEPTH ....................... DEPTH ............. NORTH'TSOI-ITH ..........EAST'7 WEST .......... DIFFERENCE ................ CORREL.-TFION 0 O. O0 -75.6'.9 O. O0 O. 00 0.00 ...................... '7.5- ................... 75 :-6.9 ................. :'7'"0700' 0;-2 ~ S 0';-13'-b 0': 0 0 ....................... 0]-00 ..................................................... 175 175, 6? 100~ O0 1.4'.:) L=: O./:.':? E O. O1 0.01 275 275.6'.9 200.00 2.84 S 1.34 E 0.02 0.01 ..................... 3~5 .................. 375 ;"6'~ .................... 300, O0 ....................................... 475 475.6.9 400.00 5.48 S 2.15 E 0.04 0.01 575 575.6'? 500.00 6.68 S 2.60 E 0.05 0.0 .................. -675 ...................... 6-75'~ '67 ...................... 60 0;' 00 .......................... 8 ;00--":F.; ............... 3';-I 8'--E '0 70 ~ --'070'1- 775 775./_-9 700 · O0 875 875.6? 800.00 .................... ?.75 .......... 975.6'.-.) ........ '.'?00 ;'00 1075 1075.69 1000· 00 1175 1175.6~-* 1100.00 ~:275 .......... 1275"6:-? .......... 1'200, O0 1375 1375.69 1300.00 1475 1475.6..° 1400.00 .............. 1'575 ........... 1575 ;'-~? ........... -1500. O0 :t 675 1675.6'~ 1600. O0 1775 1775.69 1700.00 '-?.. 21 :-]_ ._,':'. 75 E O. 07 0 .01 10.40 S 4.35 E 0.') ~' ¢. ,:, C). 01 ........................ 1'1 .... ~- ~'-;-'--~ ............... z~ .............................. ........... ,' ..ex3-"'E .............................. 0',"'08 ............................... 0','-01 ................. 11.'~9 S 5.65 E 0.0'? 0.00 12.61 S 6.79 E 0.10 0.01 1370% ~ 77'/_-: ~;--E -- '07TO O'ZOI -- 13.61 S 7.80 E 0.11 0.00 14.1'.9 S 7.97 E 0.11 0.00 I-'4]-SzT-S 87'33'- E .......... ,- ....... 0';' 1' 1 0700 14.'..-?~ S 8.57 E 0.11 0.00 15.3'.9 S 9.1:3 E 0.11 0.00 ~:,PERRY-oI.IN WEEE .:,I_IRVEYINC;-"COMPANY ................................................................................................................ PAGE 7 ANCHORAGE ALASKA ol_ H ICl ALASKA F'ETI-2EILEI IM. i]:l_-i . FIATE CIF .:,-;1_1'"" "-"r~¥,- ~ JUNE 7, 1':,' '-R ='.~ ,.._, ...........A-.:,z~A '-' ..... ( ,. ~ EC,:,,.,T 1 ~'=' ......... INRIoE) "" ........................................................................ CDMPIJTr4TION ! ............................................................................................................................................................................... BATE F'i-~LIDHOE BAY JLINE 10, 1':,"-'~.. ,:,._ ,.II_-IB NLIMBER AK-BO-50057 ALASKA KELLY I '" . = . B.I.:,H ING ELEV 75, 69 FT I NTERF'OLATED VALUES FOR EVEN 100 FEET OF SUB-:::EA DEPTH "I'RUE .:,LIB .:,EA ]'ATAL '\ MEASURED VERT ]' F:AL VERT I CAL RECTANGLILAR F:OORD I NATES MD-TVD VERT l' CAL ...... DEPTH .......................... DEPTH ........................... "' '?' ..................... DEF ~1 H ..... NORTH/S'OIJTH ...........EAE;T/WEST ........ D I FF'ERENF:E ' CFIRREC"I' I O1~1 ........................................ 1875 1875.69 1800.00 16.25 S 9.66 E 0.12 0.01 ............ .1:"9'75 2075 2075.69 2000.00 17.73 S 10.75 E 0.1:3 0.01 2175 2175.69 2100.00 18.61 S 11.27 E 0.13 0.01 .................... 2275 ............ 2275"';'69 ................... 220'0';' 00 ............................. I?. '-;' r_-r2'"'S ................ I-I T38'"-F2 ....................... 0:-1 '4 ................................... 0:01 ................................................................ 2375 2375.69 2300.00 20.42 S 2475 2475· 69 2400.00 21.05 S 2575 ............... 2575-;"/:;?. ......... -25 OD .--0 O' 2I'.---/~-~o 2675 2675.69 2600. O0 22.27 S 2775 2775.69 2700.00 22.76 S ............. 2875 ................. 2875 ;-'~:;? .............. 2800 ;~00 ........................ 22';'05-S :2976 2975.6::' 2900. O0 17.2.'_:: :=; 3076 3075.69 :_--:000 · 00 8 · 6:3 S 3I 77- ......3175 g 6:.:>--- ..... 3 :~ 00-;-00 -- I-;-79- N 3279 3:275.6':.-, :::200.00 14.19 N 3380 3:375.69 3300. O0 28.14 N ........ o--~, 83 ........ 3475.'69 .......... 3400 :'00 .................. z~'3 -.--r_-;z5_-, '- - N 3586 3575.69 3:500. O0 60.17 N 3689 3675.69 3600.00 77.07 N 12.12 E 0.14 0.01 12.95 E 0.15 0.01 ---- ].'3T?5"'E -- O'T-I'/_-;~ .......................... OTO'I ...... 15.24 E 0.17 0.01 16.08 E 0.17 0.01 1'7;'54' ' E .......................... 0 ;-"I9 .................................... 0 ;"02 21.5'3 E 0.4.2 0.23 28.46 E 1.01 0.59 ~._7---n:,---= ..................... ~-'-9~- 0:.0.2 ')- · --, ! · -.- --.~ ~,. ,a. · . -.,.! . 4:3.2:3 E 3.33 1.40 62.41 E 5.2'.-? 1.96 79 '50 E 7 .... :,' ......................... 2:64- 98.5~ E 11.06 :_--:. 13 117.79 E 14.29 3.23 oPERRY-.:,.IN WELL .=,_IRVEYINJ i]!OPIt~ANY ................................................................................... F'Ai3E 8 ANCHr]RAGE ALASKA "" -I '-' ..... ' -' '1 . _ .. .=,LHIA ALAc, I-...A I-ETI.-,,LLELIM I]:O. DATE OF SLIRVEY ,JUNE 7, 1'.-?:.~.~ A-._-,4~ (._ E_..:,,. T ! ! NR 13E') .......................................................................... C'ONPEFFAT'ILgN-"DATF: I--'RUDHOE BAY JUNE lO, 1"""~- N ' ' .',,:,.., ,JIDB I II.IMBER AI<-BI3-50A57 ALA,.KA KELLY BLISHING ELEV. - 75./_-,9 FT. ......................................................................................................................................................................................................................................................e~ PERA' ' ~- "'"'i LIR ~1~ e.e'~ LI-~'=' ~ ....... .¢, .,~ .... I- REI' ~' I NTERF'ALATED VALLEc, FOR EVEN lOC) FEET OF SI IB-REA DEPTH ]'RUE ~.,L B ,_,EA TOTAL MEASURED VERT I CAL VERT I CAL REbTANL ULAR CiDORri INA] E._ MD-TVD VERT I CAL ..... lIEF'TH DEPTH DEPTH .................... NOR'TI-iTSOUTFi R79'7 3775 69 3700 O0 ';';,:,.4 67 N 1:37.04 E 17 47 :3 1'::' ..................... ,., ~., ,:~-~ ......... -~,-, ,,~, ~..... ,.,,.._ ,,~, ,:,,:,.. ,-', .:,,:,/._,. c,.. 3800';"00 ........................ 1- I'O-;~l-'5--'N 1'5~,--07. -E .............................. 20]5? ......................................... 3 :'i-2 .................................................. 3'-."/'~'-0 3975 A'9 '-"~'¢ ""-, F,:' ".,":, -,'-, · :,.. (-).) (')(-') 1~., .., N 175 (').'..'-" E /_'¢, 3 0'::/ · · , ~ -- , I m I . . ,~ ._l i i .. ~"~ .-~,:.. 76 E 26.69 ,:: 01 41~ ~s 4A75./_-,?/ 4000, O0 142.67 N 1'-'-' ". 4....,":' (.)' ,.-,: '~' ~ --,. "7 F, 6'.9 42 (") 0 00 174 4:3 Iq '": .... :' '"4 ':::' /- ":' 2 ~._~1 1 E . n · · .- d~ _,._l 4411 '~'=~ 69 43(')o.00 1'-.?('~ IO N 249 80 E '7-~ m"- '- ,-, . ,..J.._ ..T.~ ~ , ":/'-' 4' 5':1. '-4 ......... 4'4--75; "G"...:,'-- ............. 440 Ct;-, '('fA 2057~6-, "N .... ] G8';'"34'' '-b 38';-4'~;' '22'9 'I 4617 4575 69 4~(")¢). O0 ":'""1:38 N '""'"/' '=' .... ....__, r..,. '.' 1 E 4' .1 · 'R'R 9. 87 4'7 i ~ ...... ' 4/--"75. 6'."? 4/:'00 O0 27'A '='"''"'""--'" N -...' .":' ¢') ~.-- "'(.'--' ') E 4'4 .17 2 . '='4'--' ........... 4822 ............ 4775" "A ...... 9 ................. 47 ~[') ¢')7'n (~ .................... .'._ O.--"S, 0--".. ........ ~'0 ---~,'~ "'":'"' ':'.""' ~ -- '--"" 'J'='"-- "-- C. ......................... ,.~.,.....,, .'?" ...... U.. ,.,~"' ......................... .................... 2.'77 ' q''"-:'; 4:3 6'.';' .... 49 .--7 2 6:3 4.' .,:::--- 75. 4RO(') 00 2/--"7 26 Iq 3.7.:4(.').7/_'. E ..'=; . %]"'" "--' ' ' '":""~":' 24 R'.':' '":' ~C .--7 4975 69 N 65 47 u u. 0 (:) ~,':'._, ~,_, ':' 45 E ':' 3 .'9 -'~' -' -. -~ ............... '-":;' ..................... "" 55"1.= 5'~'~'-~ 5175 &9 ~100.00 31:_:: 72 N :3'24 '2'.-? E ..7 '-?A '-.'.'.':76 ."~ . ,_ . . ~ . . _ .~.--,.-~x, F,~''~' ~,'~ P:2AO. O0 '-"-' ] 'R':~ ~'-' · :,.:,C Iq 414 C .:, E 61 1 ":' ........ ,...-/._,. :'4 "=' '"~ ":'-' ':~._,-e ~ .. ............... ..m~/._,~'-'~--'-¢"--/. C.', .: ........ ._~'-'.-,0 (.') ....................... · O0 ,:, Z~ ~'--' ' --~'--'-" ................. N ~ .--, .-, ~"" -m.._'~ ............................................... E 64.2~ .............. .'--': ~-" ~' 7 5543 5475.6? ~ ' ' _ ~'-' - .. 4(JU. O0 3/',4 11 lq ._. ~. 30 · 4,...'. 66 E 67 · .~'.'] 564/-, 5575./',? 55(')(:) O0 :--::--:(').:--:4 N 472. 15 E 70 :_'34 :--: -- _ · · · ..._1 ...........................................................................................................oPERR¥-.=,.N-~- -'""i i .......... WEEE .=,_IRVE¥INL~-I ' ' ] .... COMFAIq¥~ ............................................................................................ .... PAGE ANCHORAGE ALA.=,KA '~ '" '-'11 ' ;'o-_, '.E;OHIO ALASKA I='ETROLEUM CO, DATE OF .:,_RVEY dUNE 7, 1'-"-'~ --A=J, 4A (.:, EC~,._,T I'I-NRI ~,E') ~MPUTATI'ON-'-DATE PRUDHOE BAY dUNE ~0, 1~ .... , I ' ' ' . ._ ':/'~= dOB NJMBER AK-BA-50(')~7 ALASKA KELLY I'" . - _. . BL.:,HING ELEV - 75. A';/ FT ' ' ; OPERAT~]R=M~]rlIRE I NTERFLLATE[ VALLIES FOR EVEN 100 FEET IDF SUB-SEA DEF'I'H I RUE '-' ' '"'' ;.-,. I.IB-;=,EA TOTAL MEA~,L RED VERT I CAL VERT I CAL RECTANGULAR "' r" L.U JRD I NATES MD-TVD VERT I CAL .... DEPTH .......................... DEPTH .............................. DEPTH ..... NORTF ...O_TH EA..,T7'WE._T [ IFFEREN_.E - L. CI-~REC. TIuN 574¢/ 5675.6'~ 5600.00 397.96 N 4'.-.72. O0 E 74.22 3.38 '5853 ..... .5'775;,-6-?,' ........ 5700;.-C~ ................... ----zi:1-5-.-~-8-N ...... 5T2.-OT-E ............................... 77';"6'6- ............ 3-;-~.q: 5956 5875.69 5800.00 432.83 N 532· :::6 E 81.21 3.55 6060 5775./_-,'~ 57/00.00 450.7'~ Iq 552.74 E 84.84 3.62 '~;]"~'4 ............... ~'075]~5:-."'/- .............. Y_-;O0'O';-'O0 ......................... 4'~'..~;' 00'- N ............... 573;-3 '1- E ........................ 88 ;'5 ~ ........................ 3';-7 I 6268 6175.6~? 6100.00 4'87.68 Iq 5Sx3.85 E 92.32 3.78 6371 6275.6'.-? 6200. O0 506.64 N 614.2'.-? E 'P6.14 3.81 /=,475---~75;-. 6,::~------6-30Cr.-00 -- 52~ .-05-N--~'--/J3q~'-6(r- E .... --I-0'0;-0I 3.--8,'7 6579 6475.67 6400.00 545.86 N 654.71 E 103.91 3.'~0 6683 6575.69 6500.00 565.32 N 674.71 E 107.74 3.82 '~; 787 ...... '~'~75 ;"~; ..'P ............. 6600-~00 ......................... 5 8'4-;- 50"- N ............ ~.~3 ;'75 "-E ................... 11'1";~ 6' .................................. ~: ;-'~; 2 ......................................................... /_-,8..q"0 6775, 6.9 6700, O0 60:3, 51 N 712,53 E 114,84 3,4.7 69'~3 6875.6'.~ 6800. O0 622.03 N 730.50 E 118.12 3.28 ? O' .~6'-------¢_~ .'~. 7 ~;-~ ..'P- ............. 6~00],'-0 0 ~;z)'O..-'3'-I, --N -- Z-477-85 '- b I' 2'1-,~25' 3',--I .--_-~ ...... .'), 7177 7075· 6'.-.'2 7000· 00 658 · 47 N 764, 64 E 124,2/_-, 3, 02 7302 7175, 6'.-.-/ 7100, O0 675, 92 N 781,14 E 127, 11 2 · 84 ........... 740 5 ............... 7275-;"59 .......... 7200';'00 .................... 672 ;-57-N ..........797 ;'10"-E .............. 1'29 ;"73 ................................ -2';-63 .............. 7507 7375.6'~ 7:2:00 · O0 708 · 60 Iq 812.29 E 132.14 2.41 '"'~ '.-' 21 7610 7475 6'P 7400 (]0 7~ :?0 N 826.86 E 1:34 ':4=' · · . · · ,_ .~1 i · ............................ i ............................................................................ SPERRY=SUN-'WEEE' "¢-'fEIRVEY"i NC4'-i]~O~¢'ANY ................................................................................................ ¢;'AGi~- ' 10 ANCHORAGE ALASKA SOHIO ALASKA PETROLELIM CO. DATE OF' SURVEY JUNE 7, 1985 A=34A ('SEC35T I'1NR I'3E ) -COHPOT ATI-OIq-' -DATE PRUDHOE BAY ,JUNE 10, 1985 .JOB NUMBER AK-B0-50057 ALASKA KELLY BUSHING ELEV. = 75.69 FT. ; OPER~TOR::r4O~O/:' R~ INTERPOLATED VALUES'FOR EVEN 100 FEET OF SUB-SEA DEF'TFI I'RUE MEASURED VERTICAL ...... DEPTH .......... ; ................. DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTIC:AL ....... DEPTH .................. NORTW~SOL~ ............ EASTTW'EST ..... DIFFERENCE .................. CORR~CT~'ON 7712 7575.69 7500.00 78~ ........... 76'-757~ ............. 7'60'0."00' 7915 7775.69 7700.00 8017 7875.6? 7800.00 81-]'8 ............. 7975;'"~9 .................. 7900;00 8219 8075.69 8000.00 8320 8175.69 8100.00 ........ ~. -~ ......... ~ .... ~.'~/~ ~ ,_ ~7~.. ~00. O0 '~R'~ ~'~ 69 o ~ ~ 1 8300.00 ,_ ,_ 8622 8475.69 8400.00 738.74 N 841.11E 17:6.44 2.09 753708-'~ ............ 8557-i-1 .... E .................. ¥38';"43 .............................. I-;-9: ............................................................... 766.24 N 868.69 E 140..21 1.78 777.98 N 881.83 E 141.75 1.54 788';"'5~-N ................ 8'93'~'95"":E .................... 1'~3204 .............................. 797.80 N 904.45 E 144.02 0.98 806.47 N 913.53 E 144.81 0.79 B'IWT~O--I~----- .... .92I%-88-E .................. 1~.5;-~B" 0~68 821.91N 929.77 E 146.07 0.59 826.86 N 936.:36 E 146.41 0.34 8722 ............ 85'757~9 ........... 8822 8675.69 8600.00 8922 8775.69 8700. O0 .............. 9023 ........ 8875;' 69 .......... 8._°,00';-0'0 9123 8975.69 8900. O0 9223 9075.69 9000.00 9323 ........91- 75 .-7._49 .......... 91'-00; 0'0 9382 9233.79 9158.10 8500; -00- .............. ~0 '~"79-- N ..... -9.41'; '?5' '-E ................. I z~'6~--/_-; 4 ................................ O' ':]3 ...................................... :::::4.5:2: N 947.50 E 146.86 0.22 838.23 N 953.3'.} E 147.10 0.24. 8z~ 1-'.' 86 -N ............. '759; '39"-'E ............. 147"35 ........................... 0;'"25' ................................. :::45 20 N ' ~ E 147 F,:R 0 .._, 96._,. "::"~ '":'":' · *-- '~! - -- -- 848.57 N 971.30 E 147.82 0.2:3 8.52;-1~-N ..........977;~32 ' E ............. I48-; 06 ......................... 0 ~ % 854.23 N '.-780.83 E 148.21 0.14 ........ THE" -CAECUhAT I ON'-PROC. EDLIRES-'LISE-Pi--L-I-NEAR--I NTERPOL'iqTI ON BETWEEN ............................................. THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS '_~-34~ ~SEC~STii~RiSE) qI{ -,5~ -50957 ~ ~UE NOaT~ 590. OO ' -' 60/Jq.. 39 .8 0 :-' d. 20 · .~ .: $cq~ ~ , - _ .'. : :!~ 2.~.:0{:. ¢.;0 / 2:30 5 :'edOhOE BRT qLqSr,q ~,¢'= ,5 0 H 1 61 '" . ~ , C '. "./x.. q-3-~¢1 ',SEC35~ i iN~.i 3E] Jdhff ?, i985 VE'R T.I Cfi~ · s . P R 0 J ~ Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPEiLATOR; W-ELI] NAME AND NUMB~l~ Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Samples Core Chips Core Description ~o/~ .... -- ..... ~' .... Registered Survey Plat , Inclination Survey Directional.. Survey 7e: ~,V/ 7--'-~ a' ~r~.¢.~~ 0 .~, Drill Stem Test Reports Production Test Reports ~.- Digitized Data .... SOHIO ALASKA PETROLEUM COMPANY SFO ARCO ANCHORAGE ALASKA TO TELEPHONE 19071 265 0000 MAIL POUCH 6 61 ? ANCHORAGE ' ALASKA 99502 EXXON Date' 6/13/85 PHILLIPS Tt! ' 76239 STATE OF AK REFERENCE SOHIO ttAGtlETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- / ~* A-34-~~:H.-LSS/Wav:es~ 5/16/85 #1 Sch ~770q34 ~* A-34A /O.H -Waveforms 5/28/85 #1 Sch #70474 -* A-35'~ RFT Field : 4/25/85 #1 Sch #70408 '* E-1/ CH-CN~ LIS 3/17/85 #3 Sch #70224 '* N-20 ~ 0 H.-LIS ' 5/4/85 ~ · . ~tl G0#304964 Tape Pos.~'J03390 Tape Pos . (]03377 Tape Pos. #03397 Tape Pos. #03395 Tape Pos. #03379 * EXXON' An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm thins. ~; 2 [~ ~ ' ~ /r r'-: & · ,' ' "-- ~t ' ~ ~ J ~- ~ ' J ." DATE SOHIO ALASKA PETROLEUM COMPANY 311 1 "C" STREET ANCHORAGE. ALASKA SFO TELEPHONE (907) 265-0000 A~CO MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 * EXXON PHILLIPS Date: 6/11/85 T#: 76232 STATE OF AK !/. f.,.R/EFERENCE: t'~/~ SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- * A-35 O.H. 4/25/85 #1 Sch #70408 Tape Pos.#03383 * D-15 CH-CNL 5/19/85 #2 Sch #70450 Tape Pos.#03384 * C-18 CH-CNL 5/23/85 #1 Sch #70467 Tape Pos.#03385 * E-10 \ .* G-10 ~ * C-15 ' ~ * B-15 /- * E-.17 ~ * H-4 ~ * H-13 ~ * D-9 v,,.-'l ..,.....-/~ ' * A-34 /¢~/' * H-8 CH-CNL 5/20/85 #1 Sch #70451 Tape Pos. #03386 CH-CNL 5/22/85 #2 Sch ,~J70466 Tape Pos.ii03387 CH-CNL 5/25/85 #2 Sch #70464 Tape Pos.#03388 CH-CNL 5/23/85 ~[1 Sch #70465 Tape Pos.#03389 CH-CNL 5/21/85' ~1 Sch #70460 Tape Pos.#03390 CH-CNL 4/28/85 #2 Sch f[70407 Tape Pos.#03391 CH-CNL 5/27/85 #2 Sch ~J70478 Tape Pos.#03392 CH-CNL 5/18/85 ~1 Sch ~/70449 Tape Pos.t/03393 CH-CNL 5/26/85 ~/2 Sch ~/70477 Tape Pos.i/03394 ,-'~ ........... ~ 'lape PO-~.i~ O.H. 5/16/85 f,t! Sch ~70434 Tape Pos.~t0338! CH-CNL LIS 4/28/85 #3 Sch ~]70406 Tape Pos,#03380 * EXXON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this. .... :.__ ¥,~.'- ,'../- ---_,~._. ., , ...... . . . ....... ,.. /~.{ AJaska Oil S Gas Cons. Commission','. Anchomae :' ,.r-..' ::i- ~ (0~ ~ ~ (' {JJ~ ~ 1~_'-['. May 17, 1985 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company P.O. Box 6612 Anchorage, Alaska 99502-0612 Re: Prudhoe Bay Unit A-34A Sohio Alaska Petroleum Company Permit No. 85-105 Sur. Loc. ll71'SML, 920'WEL, Sec. 35, TllN, R13E, UPM. Btmho!e Loc. 450'SNL, 100'EWL, Sec. 36, TllN, R13E, UPM. Dear Mr. Reiley: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted,, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.0.50(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their, drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Envi~or~nen~al Conservation. P_~adhoe Bay Uni~ A-34A. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, t~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly_ypurs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~-~ISS!OM be Enc 1 o sure CC: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowery SOHIO ALASKA PETROLEUM COMPANY May 17, 1985 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well A-34A (11-36-11-13) PBU Enclosed are the following documents, in triplicate along, with our check for $100 to cover the permit filing fee. 1. Application for Permit to Drill 2. Proposed Drilling Program Outline 3. Proposed Blowout Prevention Diagram 4 Surveyor's Plat Showing Well Location 5 Directional Map Due to a close approach Well A-12 will be shut in and plugged during the drill by. If you have any questions, please call Ted Stagg at 564-5173. Very truly yours, District Drilling Engineer RHR: IBG: elw 51785/0287wp2 Enclosures Well File #17 RECEIVED Alaska Oji & GaS Cons. Commission Anchorage --.. STATE OF ALASKA '- ALASKAC AND GAS CONSERVATION CO, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work.' DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 1171' SNL, 920' WEL, Sec 35, TllN, R13E, OPM At top of proposed producing interval 450' SNL, 100' EWL, Sec 36, TllN, R13E, OPM At total depth 450' SNL, 100' EWL, Sec. 36, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Est. KBE = 75' AMSL I ADL 28286: i 12. Bond information (see 20 AAC 25.025) 9. Unit or lease name Prudhoe Bay Unit 10. Well number A-34A(11-36-11-13) 11. Field and pool Prudhoe Bay Prudhoe Oil Pool iType Blanket Surety and/or number Safeco Ins. 2975387 13. Distance and direction from nearest town 14. Distance to nearest property or lease line AmountS200,000,00 15. Distance to nearest drilling or completed t N~ of Deadhorse 10 miles 16. Proposed depth (MD & TVD) 9368' ~,D 9230" ~ feet ADL 47472 4830feet 17. Number of acres in lease 2491 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2800 feet. oJ 20. Anticipated pressures MAXIMUM HOLE ANGLE 12. (see 20 AAC 25.035 (c) (2) well A-9 1500 feet 18. Approximate spud date 05-17-85 3 3 3 0 psig@ Surface 3990 .psig@ 8800 ft. TD (TVD) t 21 SIZE Hole Casing 36" 20"x30'~ 172"2 13-3/8'~ 12!-4" 9-5/8" 8½" 7" Proposed Casing, Liner and Cementing Program Weight Insulat~ CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Grade MD TOP TVD (include stage data) id Condt Coupling .ctor Length 80' SurfaceI SurfaceI 72# L-80 Butt 2654 47# L-80 iButt 8637 Surfacel I 26# L-80 851 iIJ4S I 8517, 83R~ MD BOTTOM TVD 110' ~110' I 87a71 aR?9 I I 93681 9230 Ins'tailed' " Installed [484 cuft Clagg G+ g% c 230 cuoft. Class G 22. Describe proposed program: See attached Proposed Drilling and Completion Program, 18% salt £CEIvED -q/at~.,~, 01,' ~;. ~i~:s Cons 'qnChorage' C°mrni8$ioo 23. I hereby certify that the foregogcug, is true and correct to the best of my knowledge * The space be CONDITIONS OF APPROVAL Samples required [~]YES ~NO Permit number APPROVED BY Form 10-401 Mud log required []YES ~NO Approval date 0 /z7./85. Directional Survey required I APl number ~JES []NO I 50_OLg-?-13%q SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM I SSI ON ER DATE by order of the Commission May 17, 1985 el PROPOSED DRILLING AND COMPLETION PROGRAM WELL A-34A (11-36-11-13) PBU Well A-34A will be sidetracked from Well A-34. Well A-34 was abandoned with a continuous cement plug in the 8 1/2" hole and across the 9 5/8" shoe. A bridge plug will be set at 3150' MD and the 9 5/8" casing will be cut at 3000' MD and recovered. A kick off cement plug will be set from 3150' to 2800' MD. The 20" x 30" insulated conductor and 13 3/8" surface casing already installed will be used for Well A-34A. Kick off and directionally drill 12 1/4" hole to the Sag River Sandstone. Run 9 5/8" 47# L-80 Buttress casing to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by nonfreezing fluid. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement with 18% salt. Clean out to 7" float equipment. Change over to 9.6 ppg. NaCl completion fluid. Test casing and lap to 3000 psi. Run CBL. Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Suspend well for perforating subsequent to rig release. Maximum possible bottomhole pressure is 3990 psi at 8800' TVDss based on revised reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Tubing Size: 4 1/2", 12.65, L-80, A/B Mod. BTC, IPC with GLMs. Tailpipe Size: 4 1/2", 12.65, L-80, BTC PRELIMINARY WELL PLAN Well: AFE NUMBER: L~ATION: Surface: Target: T.D.: ESTIMATED START: OPR. DAYS TO COMPLETE: CONTRACTOR: MAX . ANGLE/SECTION COURSE: A-34A (11-36-11-13) PBU 120138 1171' SNL, 920' I~rEL, Sec. 35, TllN, R13E 450' SNL, 100' EWL, Sec. 36, TllN, R13E 450' SNL, 100'~ E~rL, Sec. 36, TllN, R13E May 18, 1985 16 Nabors 18E 12 51'/N53 38'E KOP: 2800' MD Item TVDss MD(BKB) Mud Wt. 30" x 20" Insulated Conductor 110 13 3/8" Casing 2609 2684 9.0 Base Cretaceous Sands 5926 6074 9.5 PBU/LCU 7685 7878 9.7 9 5/8" Casing 8554 8767 9.7 Sag River Sandstone 8559 8772 8.9 Shublik 8585 8798 8.9 Sadlerochit 8664 8879 8.9 Gas/Oil Contact Target 8800 9013 8.9 H.O.C. 8960 9173 8.9 O.W.C 8910 9123 8.9 Kavik Shale TD 9155 9368 8.9 LOGGING PROGRAM: Open Hole - Record all logs on magnetic tape where applicable. 12 1/4" Hole: GR/SP/DIL and dipmeter to be used at the well site geologists discretion. 8 1/2" Hole: GR/SP/DIL/BHCS, GR/FDC or LDT/CNL/CAL. Dipmeter to be available. Cased Hole GR/CCL/CBL/VDL Directional survey after rig release. RECEIVED MAY I 7 1985 Alaska O~J & Gas Cons. Commissio. Anchorage 20" x 30" Insulated Conductor Ball Valve 13 3/8" Casing Shoe 17 1/2" Open Hole PROPOSED ~OLE DIAGRAM ~/., A-34A (11-36,-.11-13) PROPOSED DEPTH BKB 2125' 2684' 2700' 4 1/2", 12.6#, L-80, A/B Mod. BTC, IPC with 8 GLMs 9 5/8" Packer 7" Tieback Assembly 8467' 8517' 9 5/8" Casing Shoe 12 1/4" Hole 8767' 8772' 7" PBTD 7" Liner Shoe 8 1/2" Open Hole 9328' 9368' 9368' RECEIVED Alaska Oil & Gas Cons. C, ornmissiori 'qnchorage B.'O. F .... ~" STACK .. CON FIGUR'~'TION 13 5/8" TRIPLE RAM STACK 50O0 PSI WP DRILLING . _ ANNULAR PREVENTER .o .L KILL LINE . CHECK GATE GATE 1 1 I 1 I PiPE 'R'~k M S © · BLIND RAMS -. DRILLING sPOOL -I I PIPE RAMS I I HYDR. ASST. GATE 'RECEIVED ~A¥ 1 7 1985 Al '~ ~' (~:~; Cons Commission HAND GAT E CHOKE LINE ~o 4o ~o ~ ~0 i ~o ~ 4o ot 03 04 ~ OI 02 o~ J_ _ !O 20. I I I I I !- l.; T -- " iON' T. ,0'8, i-, N. SCA-LE' I'''= I/2 MILE i ,R. 13 E..,.U..M CERTIFICATE OF SURVEYOR · : . I hereby .certify that. lam PrOPerly registered to practice land surveying in the State of Alaska and fhaf this pier represents a location survey of the weiipad shown and the Wells thereon: This ,survey was made by me or under' my supervisi(~n and all dimensions and other details are correct. Bottom hole locations are fur'nished by others. · Date Surveyor PLAT 4 OF 4 SUMP SUMP 520' PAD DETAIL SCALE' I"= 400' ABANDON. WELL A-34, ADDED PROPOSED WELL A-~4A BHL REVISED SURFACE LOCATION WELLS A-35, A-34, A-33 ADDED PROPOSED WELL A-33 BHL RECEIVED MAY 1 7 ~85 Alaska Oil &-Gas Go'ns. Commi, Anchorage ~ 5/17/85 L,--- PAD "A" EXTE'NSION Located in E I/2 PROTRACTED SEC.35 UMIAT MER. Surveyed for s~HlO ALASKA PETROLEUM CO. . Surveyed by OCEAN TECHNOLOGY LTD. LAND I~ HYDROGRAPHIC SURVEYORS :>502 West No~fhern Lights Boulevord A nchm'age, Alaska ~56 _ . (10 and ':1 · . " (22 thru' 26') . . \ 'i3. :14. 15. I6'. 17. d~Viated,.,,,,~ .the':/O, nlY,'?af ~i approved...b, prope~ other 18.. 19. 20. 21. 22. 23. 24. 25. 26. 27. o , ...... ::.: ...: .... :.. 'Is a.:c°nse~atiOn'°rder' , ..,~',~'. .... '~,'~".' '.. ne ...... L'~ .':":iI's':"admihistrative approval' eded., ........ ' ~ .' ~',~ ,'.'~:, '' '~ ....... ~s the :~ease ,,number' approp~Sate,. , . --... ~ ....... ~ .'"~. ........................ . e: ~ ..,' .? ~,: . : :. : ~'~:,..., . ~s conductor strohg provided --.': ' ' · ' - '.eel e'~ ~ eee e ~ · · · · · ee ee · · ' ee. e e e · · · · · ~ · · . - . · · Is enough cement .used to 'ci:rcula~e 0n co~duC~or-and, surface ....... Will cement' tie. in.-.surface ?and~',~inte~ed~a~e..or production., s~rin~s..:: ' Will cement cover all kn~'~:P~odUctive,.:.horiz°ns ............ ;.'. ~..." · :Will surface casin~ pro~ect fresh ~ate~ zones .... ; .................. Will a!l~-casin~ ~ive' adequate .safety in. collapse, ':'tension. and burst.. Is · ~his -well. to -'be kicked, off' from an ex~st~n~ Weltbore :. ~- ~' ;': ~.~ ...... Is. adequate wellb, ore -separatiom proposed ........ ;, J;'. ................. . . . Is a diverter system required ....................................... Are necessary diagrams of diverter' and .BOP equipment attached ....... Does BOPE have sufficient pressure ratine - Test to ~~ psi~ .. ~' .. ' .... . Does '.the. choke manifold comply w/~I ~-S3 (Feb.78) ... ' ........... ............. .~s the p~c~ of HCS ~s pr0~... ...... .~..~... ...... :.... ....... _~ ..... ..... ire ........ Additional requ ments ............................................. _.. . . . .... Addi~iomal Remarks: ' '.:~.-:.:'" ~-':- - /N.~ r///-/.. £D Geology: En$%B~e~ing: j~~~LCS~BEW 2---" HJH~ rev: 03/13/85 6.011 .... · INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry 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. CEIVED NOV 15 1996 Alaska Oil & Gas Cons, Coa~n Anchorage * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAME : A - 34A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292133901 REFERENCE NO : 96325 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PA GE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/11/13 ORIGIN : FLIC REEL NA~E : 96325 CONTINUATION # : PREVIOUS REEL : COM~fENT : BP EXPLORATION, PRUDHOE BAY, A-34A, API #50-029-21339-01 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 96/11/13 ORIGIN · FLIC TAPE NAME : 96325 CONTINUATION # : 1 PREVIOUS TAPE : COF~ENT : BP EXPLORATION, PRUDHOE BAY, A-34A, API #50-029-21339-01 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: A - 34A API NUMBER: 500292133901 OPERATOR: BP EXPLORATION (ALASKA) INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 13 -NOV- 96 JOB NUFiBER: 96325 LOGGING ENGINEER: PAWLUK OPERATOR WITNESS: E. KRUMANOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 1 iN RANGE: 13 E FNL: 1171 FSL : FEL: 921 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 75.60 DERRICK FLOOR: 74.60 GROUND LEVEL: 47. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 8770.0 47. O0 2ND STRING 7. 000 9382.0 26. O0 3RD STRING 4. 500 8533.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 9020 5 9012 0 9008 5 9005 5 8992 5 8978 5 8970.0 8966.0 8930.5 8915.5 8913.5 8898.5 8896.5 8892.0 8872.0 8869.5 8863.0 8856.0 8854.O 8836.0 8834.0 8828.5 8804.5 8803.5 8800.5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH NPHI 88886.5 88885.5 8991.0 8978.0 8964.5 8914.5 8897.5 8873.5 8864.5 8855.0 8835.5 8830.0 8805.0 8801.5 101.0 9018.0 9010.0 9006.5 9004.0 8968.5 8964.0 8927.5 8914.5 8898.0 8893.0 8869.0 8855.0 8835.5 8805.0 100.5 The depth adjustments shown above reflect cased hole GR to open hole GR and cased hole NPHI to open hole GR. Ail other CNTD curves were carried with the NPHI shifts. $ $ PAGE: **** FILE HEADER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: FILE HEADER FILE NUM~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8999.0 8792.0 CNTD 9026.0 8792.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUFIBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: This file contains CNTD Pass #1. shifts were applied to this data. $ LIS FORMAT DATA No pass to pass ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553852 O0 000 O0 0 1 1 NPHI CNTD PU-S 553852 O0 000 O0 0 1 1 NRAT CNTD 553852 O0 000 O0 0 1 1 CRAT CNTD 553852 O0 000 O0 0 1 1 NCNTCNTD CPS 553852 O0 000 O0 0 1 1 FCNT CNTD CPS 553852 O0 000 O0 0 1 1 CFTC CNTD CPS 553852 O0 000 O0 0 1 1 CNTC CNTD CPS 553852 O0 000 O0 0 1 1 GRCH CNTD GAPI 553852 O0 000 O0 0 1 1 TENS CNTD LB 553852 O0 000 O0 0 1 1 CCL CNTD V 553852 O0 000 O0 0 1 1 GR BCS GAPI 553852 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9364.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL.CNTD -999.250 GR.BCS DEPT. 9200.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD -999.250 CCL.CNTD -999.250 GR.BCS DEPT. 9000.000 NPHI.CNTD 18.726 NRAT. CNTD 3.605 CRAT. CNTD NCNT. CNTD 4124.031 FCNT. CNTD 1160.305 CFTC. CNTD 1157.964 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1255.000 CCL.CNTD 0.000 GR.BCS DEPT. 8800.000 NPHI.CNTD 43.506 NRAT. CNTD 6.636 CRAT. CNTD NCNT. CNTD 2372.746 FCNT. CNTD 341.085 CFTC. CNTD 346.087 CNTC. CNTD GRCH. CNTD 69.438 TENS.CNTD 1235.000 CCL.CNTD 0.000 GR.BCS DEPT. 8751.000 NPHI.CNTD -999.250 NRAT. CNTD -999.250 CRAT. CNTD NCNT. CNTD -999.250 FCNT. CNTD -999.250 CFTC. CNTD -999.250 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD -999.250 CCL.CNTD -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 18.563 3.582 4235.049 15.352 6.580 2320.172 178.250 -999.250 -999.250 53.500 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMEaYT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8998.0 8787.0 CNTD 9025.0 8787.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFiBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88887.0 88886.0 9014.5 9012.5 9010.5 9008.5 9006.5 9005.0 8990.5 8989.0 8986.5 8984.5 8983.5 8982.5 8982.5 8981.0 8979.5 8978.5 8978.5 8977.0 8974.5 8972.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 8971.5 8970.0 8970.5 8968.0 8966.5 8964.5 8962.5 8960.5 8959.5 8958.0 8958.5 8956.0 8955.5 8954.5 8951.5 8950.5 8947.5 8946.0 8943.5 8943.0 8942.5 8940.0 8939.5 8939.0 8938.5 8935.5 8935.5 8935.5 8931.5 8932.5 8927.5 8928.0 8926.5 8923.5 8923.5 8923.5 8922.5 8921.0 8919.5 8920.5 8915.5 8916.5 8911.5 8912.0 8906.5 8905.0 8902.5 8901.5 8898.5 8897.5 8895.5 8896.0 8894.5 8895.5 8891.5 8892.5 8890.5 8891.0 8887.5 8888.0 8886.5 8886.5 8883.5 8884.5 8882.5 8882.5 8878.5 8878.0 8870.5 8870.0 8866.5 8865.5 8858.5 8857.5 8854.5 8853.0 8850.5 8849.0 8847.5 8848.5 8846.5 8845.5 8843.5 8844.0 8842.5 8841.0 8839.5 8840.5 8838.5 8837.5 8834.5 8833.5 8830.5 8830.0 8827.5 8828.5 8826.5 8826.0 8823.5 8825.5 8822.5 8821.5 8818.5 8818.0 8814.5 8813.5 8810.5 8810.5 100.0 102.0 100.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: REMARKS: This file contains CNTD Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and NPHI pass #2 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT 553852 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 553852 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 553852 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 553852 O0 000 O0 0 2 1 1 4 68 0000000000 NCNTCNTD CPS 553852 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTD CPS 553852 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 553852 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 553852 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 553852 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 553852 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 553852 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: ** DATA ** DEPT. 9023.000 NPHI.CNTD 17.702 NRAT. CNTD NCNT. CNTD 4266.667 FCNT. CNTD 1242.719 CFTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1280.000 CCL. CNTD DEPT. 9000.000 NPHI.CNTD 19.276 NRAT. CNTD NCNT. CNTD 4093.023 FCNT. CNTD 1099.237 CFTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1205.000 CCL.CNTD DEPT. 8800.000 NPHI.CNTD 40.311 NRAT. CNTD NCNT. CNTD 2240.631 FCNT. CNTD 362.205 CFTC. CNTD GRCH. CNTD 55.563 TENS. CNTD 1175.000 CCL. CNTD DEPT. 8787.000 NPHI. CNTD 49.439 NRAT. CNTD NCNT. CNTD 1767.442 FCNT. CNTD 248.062 CFTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1170.000 CCL. CNTD 3. 300 CRA T . CNTD 1198.512 CNTC. CNTD O. 000 3. 833 CRA T . CNTD 1146.830 CNTC . CNTD O. 000 6.261 CRAT. CNTD 354.521 CNTC. CNTD 0.000 7. 125 CRA T . CNTD 245. 410 CNTC. CNTD O. 000 3.443 4318.456 3.656 4253.107 6.227 2255.118 7.260 1827. 291 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · 0 O1 CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS AUJM~ER: 3 DEPTH INCREMENt: 0.5000 FILE SDTV~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: GRCH 8999.0 8790.0 CNTD 9026.0 8790.0 $ CURVE SHIFT DATA - PASS TO PASS (~IEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTD 88888.0 88890.0 88887.0 9014.5 9013.5 9010.5 9009.5 9006.5 9006.0 9002.5 9002.0 8998.5 8998.5 8994.5 8994.0 8990.5 8990.0 8986.5 8986.5 8982.5 8982.5 8978.5 8978.0 8966.5 8966.0 8962.5 8961.5 8958.5 8957.5 8954.5 8953.0 8946.5 8945.0 8942.5 8940.5 8938.5 8937.0 8931.5 8933.5 8930.5 8929.0 8926.5 8924.5 8922.5 8922.5 8902.5 8902.5 8898.5 8899.0 8894.5 8896.5 8891.5 8893.5 8890.5 8892.5 8887.5 8890.0 8886.5 8888.0 8882.5 8884.0 8878.5 8879.5 8874.5 8875.0 8859.5 8862.0 8858.5 8859.0 8855.5 8857.5 8854.5 8854.0 8850.5 8850.0 8846.5 8846.5 8834.5 8834.5 8830.5 8831.0 8818.5 8819.0 8814.5 8816.0 8810.5 8811.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 10 100.0 $ 102.0 101.0 RE~APJfS: This file contains CNTD Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 553852 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 553852 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 553852 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 553852 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 553852 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 553852 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 553852 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 553852 O0 000 O0 0 3 1 1 4 68 0000000000 GRCM CNTD GAPI 553852 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 553852 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 553852 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 11 ** DATA ** DEPT. 9025.000 NPHI.CNTD 18.639 NRAT. CNTD 3.556 CRAT. CNTD NCNT. CNTD 4305.344 FCNT. CNTD 1236.641 CFTC. CNTD 1187.253 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1160.000 CCL.CNTD 0.000 DEPT. 9000.000 NPHI.CNTD 18.958 NRAT. CNTD 3.562 CRAT. CNTD NCNT. CNTD 4159.500 FCNT. CNTD 1200.875 CFTC. CNTD 1168.500 CNTC. CNTD GRCH. CNTD 24.734 TENS.CNTD 1152.141 CCL.CNTD 0.000 DEPT. 8800.000 NPHI.CNTD 39.277 NRAT. CNTD NCNT. CNTD 2267.716 FCNT. CNTD 377.953 CFTC. CNTD GRCH. CNTD 66.688 TENS.CNTD 1150.000 CCL.CNTD DEPT. 8791.000 NPHI.CNTD 47.049 NRAT. CNTD NCNT. CNTD 1798.816 FCNT. CNTD 217.054 CFTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1175.000 CCL.CNTD 5. 833 CRA T . CNTD 359. 459 CNTC. CNTD O. 000 8.143 CRAT. CNTD 259.530 CNTC. CNTD 0.000 3.570 4474.871 3.613 4288.625 6.114 2284.241 6. 986 1835. 896 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 4 DEPT~ INCREFIENT: 0.5000 FILE SU~IMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 12 GRCH 8998.0 8793.0 CNTD 9025.0 8793.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9014.5 9010.5 9006.5 8986.5 8982.5 8974.5 8971.5 8970.5 8966.5 8962.5 8959.5 8958.5 8955.5 8951.5 8947.5 8946.5 8942.5 8935.5 8931.5 8930.5 8922.5 8906.5 8902.5 8898.5 8894.5 8891.5 8890.5 8887.5 8886.5 8883.5 8882.5 8879.5 8878.5 8874.5 8870.5 8858.5 8854.5 8850.5 8846.5 8842.5 8838.5 8834.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88887.0 88886.0 9012.5 9009.0 9005.5 8985.5 8981.0 8973.0 8970.5 8958.5 8955.5 8951.5 8948.0 8936.0 8932.5 8892.5 8889.0 8885.5 8881.0 8969.5 8965.5 8961.0 8956.5 8944.5 8940.0 8928.0 8921.5 8905.5 8902.0 8898.5 8895.5 8891.5 8887.0 8883.0 8878.5 8874.5 8870 0 8858 0 8853 5 8849 5 8846 0 8841 5 8838.0 8834.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 13 8830.5 8830.5 8822.5 8822.5 8818.5 8819.0 8814.5 8814.5 100.0 101.5 100.0 $ REMARKS: This file contains CNTD Pass #4. The depth shifts shown above relect GRCH pass #4 to GRCH pass #1 and NPHI pass #4 to NPHI pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N~IE SERV UNIT SERVICE API API fi~PI API FILE ~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 553852 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTD PU-S 553852 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNTD 553852 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNTD 553852 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTD CPS 553852 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNTD CPS 553852 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTD CPS 553852 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTD CPS 553852 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 553852 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELE~ CODE (HEX) TENS CNTD LB 553852 O0 000 O0 0 4 1 1 4 68 0000000000 CCL CNTD V 553852 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9023.000 NPHI. CNTD 17.280 NRAT. CNTD 3.520 CRAT. CNTD NCNT. CNTD 3944.773 FCNT. CNTD 1181.102 CFTC. CNTD 1197.499 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1155.000 CCL.CNTD 0.000 DEPT. 9000.000 NPHI.CNTD 19.311 NRAT. CNTD 3.680 CRAT. CNTD NCNT. CNTD 4124.031 FCNT. CNTD 1183.432 CFTC. CNTD 1151.299 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1185.000 CCL. CNTD 0.000 DEPT. 8800.000 NPHI. CNTD 39.354 ArRAT. CNTD 6.286 CRAT. CNTD NCNT. CNTD 2236.220 FCNT. CNTD 342.159 CFTC. CNTD 370.296 CNTC. CNTD GRCH. CNTD 60.156 TENS. CNTD 1165.000 CCL.CNTD 0.000 DEPT. 8793.000 NPHI.CNTD 48.249 NRAT. CNTD 7.600 CRAT. CNTD NCNT. CNTD 1661.914 FCNT. CNTD 236.220 CFTC. CNTD 246.823 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1170.000 CCL. CNTD 0.000 3.386 4197.032 3.660 4297.676 6.123 2281.703 7.124 1787.771 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE ' 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 15 FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 0 DEPTH INCREMENT: 0.5000 FILE SUMPIARY LDWG TOOL CODE START DEPTH STOP DEPT~ GRCH 8998.0 7260.0 CNTD 9025.0 7260.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASSNUMBER: 1 BASELINE DEPTH .............. 88888.0 9020.0 9018.0 9005.0 9004.0 8969.5 8968.5 8969.0 8968.5 8965.5 8964.5 8959.5 8957.5 8915.5 8914.5 8913.0 8914.0 8898.0 8898.0 8896.5 8897.5 8891.5 8892.5 8871.5 8873.0 8869.5 8869.0 8867.5 8868.5 8865.5 8865.0 8863.0 8864.5 8847.5 8848.5 8828.5 8830.0 8828.0 8829.5 8803.5 8805.0 8804.5 8779.0 8779.0 8775.5 8775.5 100.0 100.0 100.0 $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTD .............. 88887.0 88886.0 REMARKS: This file contains CNTD Pass #0. The depth shifts shown above relect GRCH pass #0 to GRCH pass #1 and NPHI pass #0 to NPHI pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553852 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNTD PU-S 553852 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNTD 553852 O0 000 O0 0 5 1 1 4 68 0000000000 CRAT CNTD 553852 O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNTD CPS 553852 O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNTD CPS 553852 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNTD CPS 553852 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNTD CPS 553852 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNTD GAPI 553852 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CNTD LB 553852 O0 000 O0 0 5 1 1 4 68 0000000000 CCL CNTD V 553852 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9023.000 NPHI.CNTD 17.280 NRAT. CNTD 3.520 CRAT. CNTD NCNT. CNTD 3944.773 FCNT. CNTD 1181.102 CFTC. CNTD 1197.499 CNTC. CNTD GRCH. CNTD -999.250 TENS.CNTD 1155.000 CCL. CNTD 0.000 DEPT. 9000.000 NPHI.CNTD 19.311 NRAT. CNTD 3.676 CRAT. CNTD NCNT. CNTD 4118.125 FCNT. CNTD 1177.563 CFTC. CNTD 1149.125 CNTC. CNT~ GRCH. CNTD -999.250 TENS. CNTD 1185.000 CCL. CNTD 0.000 3.386 4197.032 3.660 4287.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 17 DEPT. 8800.000 NPHI.CNTD 44.281 NRAT. CNTD NCNT. CNTD 2173.000 FCNT. CNTD 356.063 CFTC. CNTD GRCH. CNTD 68.813 TENS. CNTD 1175.313 CCL.CNTD DEPT. 8600.000 NPHI. CNTD 47.152 NRAT. CNTD NCNT. CNTD 1984.496 FCNT. CNTD 270.677 CFTC. CNTD GRCH. CNTD 40.313 TENS. CNTD 1140.000 CCL.CNTD DEPT. 8400.000 NPHI. CNTD 52.842 NRAT. CNTD NCNT. CNTD 1737.828 FCNT. CNTD 248.062 CFTC. CNTD GRCH. CNTD 45.844 TENS. CNTD 1105.000 CCL.CNTD DEPT. 8200.000 NPHI.CNTD 58.216 NRAT. CNTD NCNT. CNTD 1684.210 FCNT. CNTD 186.047 CFTC. CNTD GRCH. CNTD 39.531 TENS. CNTD 1085.000 CCL.CNTD DEPT. 8000.000 NPHI.CNTD 36.178 NRAT. CNTD NCNT. CNTD 1984.962 FCNT. CNTD 372.093 CFTC. CNTD GRCH. CNTD 31.219 TENS. CNTD 1105.000 CCL.CNTD DEPT. 7800.000 NPHI. CNTD 52.530 NRAT. CNTD NCNT. CNTD 1744.361 FCNT. CNTD 217.054 CFTC. CNTD GRCH. CNTD 63.406 TENS. CNTD 1080.000 CCL.CNTD DEPT. 7600.000 NPHI.CNTD 48.344 NRAT. CNTD NCNT. CNTD 1798.449 FCNT. CNTD 248.062 CFTC. CNTD GRCH. CNTD 41.656 TENS.CNTD 1060.000 CCL. CNTD 6.355 331.781 0.000 7.333 278.792 0.000 7.000 228.964 0.000 9.333 211.034 0.000 5.500 352.119 0.000 7.429 211.037 0.083 6.750 244.294 0.000 DEPT. 7400.000 NPHI.CNTD 8.580 NRAT. CNTD 2.208 NCNT. CNTD 6697.674 FCNT. CNTD 3084.337 CFTC. CNTD 3074.543 GRCH. CNTD 52.438 TENS.CNTD 1050.000 CCL. CNTD 0.000 DEPT. 7260.000 NPHI.CNTD 10.022 NRAT. CNTD 2.359 NCNT. CNTD 5975.903 FCNT. CNTD 2418.604 CFTC. CNTD 2372.700 GRCH. CNTD 74.438 TENS. CNTD 1015.000 CCL. CNTD 0.000 CRA T. CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD CRA T. CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD CRA T . CNTD CNTC. CNTD 6.671 2207.875 6.998 2059.518 7.650 1766.397 8. 265 1787.160 5. 769 2080. 779 7. 614 1705. 585 7.134 1805. 057 2.197 6944.352 2.396 6038.479 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, 4 CNTD $ RE~ARKS: The arithmetic average of passes 1,2,3 & 4 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 19 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MODNUI~ SAMP ELaM CODE (H~X) DEPT FT 553852 O0 000 00 0 6 1 1 4 68 0000000000 NPHI CNAV PU-S 553852 O0 000 O0 0 6 1 1 4 68 0000000000 NRAT CNAV 553852 O0 000 O0 0 6 1 1 4 68 0000000000 CRAT CNAV 553852 O0 000 O0 0 6 1 1 4 68 0000000000 NCNTCNAV CPS 553852 O0 000 O0 0 6 1 1 4 68 0000000000 FCNT CNAV CPS 553852 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC CNAV CPS 553852 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC CNAV CPS 553852 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH CNTD GAPI 553852 O0 000 O0 0 6 1 1 4 68 0000000000 TENS CNTD LB 553852 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9023.000 NPHI. CNAV 17.749 NRAT. CNAV 3.318 CRAT. CNAV NCNT. CNAV 4150.090 FCNT. CNAV 1228.652 CFTC. CNAV 1190.885 CNTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1218.750 DEPT. 9000.000 NPHI. CNAV 19.068 NRAT. CNAV 3.670 CRAT. CNAV NCNT. CNAV 4125.146 FCNT. CNAV 1160.962 CFTC. CNAV 1156.148 CNTC. CNAV GRCH. CNTD -999. 250 TENS. CNTD 1199. 285 DEPT. 8800.000 NPHI. CNAV 40.612 NRAT. CNAV 6.254 CRAT. CNAV NCNT. CNAV 2279. 329 FCNT. CNAV 355. 850 CFTC. CNAV 357. 591 CNTC. CNAV GRCH. CNTD 62.961 TENS. CNTD 1181.250 DEPT. 8792.500 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD -999.250 TENS. CNTD -999.250 3.450 4256.274 3.627 4268.614 6. 261 2285.309 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 20 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : CNTD LOG HEADER DATA FILE HEADER FILE AU3MBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS N-UMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9026.0 8792.0 DATE LOGGED: 25-0CT-96 SOFTWARE VERSION: 42.2 TIME LOGGER ON BOTTOM: 1520 25-0CT-96 TD DRILLER (FT) : 9030.0 TD LOGGER (FT) : 9030.0 TOP LOG INTERVAL (FT): 8787.0 BOTTOM LOG INTERVAL (FT) : 9025.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTD THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUM~ER CPLS-A 812 CNC-D 146 8770.0 BRINE 30.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 21 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): 1.0 REMARKS: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 22 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NTJMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553852 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS2 PU 553852 O0 000 00 0 7 1 1 4 68 0000000000 RTNR PS2 553852 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS2 553852 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS2 CPS 553852 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS2 CPS 553852 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS2 CPS 553852 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS2 CPS 553852 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 553852 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 553852 O0 000 O0 0 7 1 1 4 68 0000000000 CCLDPS2 V 553852 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9043.000 NPHI.PS2 16.991 RTNR.PS2 3.324 TNRA.PS2 RCNT. PS2 4175.520 RCFT. PS2 1256.351 CNTC.PS2 4289.229 CFTC. PS2 GR.PS2 16.016 TENS. PS2 1080.000 CCLD.PS2 0.030 DEPT. 9000.000 NPHI.PS2 18.280 RTNR.PS2 3.639 TNRA.PS2 RCNT. PS2 4155.039 RCFT. PS2 1116.279 CNTC. PS2 4278.816 CFTC. PS2 GR.PS2 24.438 TENS.PS2 1265.000 CCLD.PS2 0.000 DEPT. 8790.500 NPHI.PS2 49.172 RTNR.PS2 7.600 TNRA.PS2 RCNT. PS2 1732.283 RCFT. PS2 232.558 CNTC.PS2 1814.203 CFTC. PS2 GR.PS2 44.750 TENS. PS2 1235.000 CCLD.PS2 0.000 3.347 1235.540 3.521 1152.882 7. 229 245.246 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 23 **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ND?4BER: 2 DEPTH INCR~4ENT: 0.5000 FILE SUMM~RY VENDOR TOOL CODE START DEPTH STOP DEPTH 9025.0 8787.0 CNTD LOG HEADER DATA DATE LOGGED: 25-0CT-96 SOFTWARE VERSION: 42.2 TIME LOGGER ON BOTTOM: 1520 25-0CT-96 TD DRILLER (FT) : 9030.0 TD LOGGER (FT) : 9030.0 TOP LOG INTERVAL (FT) : 8787.0 BOTTOM LOG INTERVAL (FT) : 9025.0 LOGGING SPEED (FPHR) '. 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~IA RAY CNTD THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER ........... CGRS-A 814 CNC-D 146 8770.0 BRINE 30.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 24 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): 1.0 REMARKS: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15: 05 PAGE: 25 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUFIB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553852 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 553852 O0 000 O0 0 8 1 1 4 68 0000000000 RTNR PS3 553852 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 553852 O0 000 O0 0 8 1 1 4 68 0000000000 RCNT PS3 CPS 553852 O0 000 O0 0 8 1 1 4 68 0000000000 RCFT PS3 CPS 553852 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 553852 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 553852 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 553852 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 553852 O0 000 O0 0 8 1 1 4 68 0000000000 CCLD PS3 V 553852 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 9042.500 NPHI.PS3 17.742 RTNR.PS3 3.424 TNRA.PS3 RCNT. PS3 4175.520 RCFT. PS3 1219.399 CNTC. PS3 4289.229 CFTC. PS3 GR.PS3 15.500 TENS.PS3 1160.000 CCLD.PS3 0.030 DEPT. 9000.000 NPHI.PS3 17.842 RT1FR.PS3 3.325 TNRA.PS3 RCNT. PS3 4163.106 RCFT. PS3 1221.374 CNTC.PS3 4260.018 CFTC.PS3 GR.PS3 21.750 TENS.PS3 1195.000 CCLD. PS3 0.000 DEPT. 8800.000 NPHI.PS3 40.311 RTNR.PS3 6.261 TNRA.PS3 RCNT. PS3 2240.631 RCFT. PS3 362.205 cNTC. PS3 2255.118 CFTC. PS3 GR.PS3 92.250 TENS.PS3 1175.000 CCLD. PS3 0.000 DEPT. 8784.000 NPHI.PS3 52.799 RTNR.PS3 7.200 TNRA.PS3 RCNT. PS3 1674.418 RCFT. PS3 232.558 CNTC.PS3 1741.298 CFTC. PS3 GR.PS3 47.250 TENS.PS3 1165.000 CCLD. PS3 0.000 3.449 1199.200 3. 462 1177. 020 6. 227 354. 521 7.645 217.335 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 26 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH CNTD 9026.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTD THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE 'BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : STOP DEPTH 8790.0 25-0CT-96 42.2 1520 25-0CT-96 9030.0 9030.0 8787.0 9025.0 1800.0 NO TOOL NUMBER CGRS-A 814 CNC-D 146 8770.0 BRINE 30.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 27 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STAIVDOFF (IN): 1.0 REd. ARKS: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 i LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 28 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) O0 000 O0 0 9 1 1 4 68 0000000000 DEPT FT 553852 NPHI PS4 PU 553852 O0 000 RTNR PS4 553852 O0 000 TNRA PS4 553852 O0 000 RCNT PS4 CPS 553852 O0 000 RCFT PS4 CPS 553852 O0 000 CNTC PS4 CPS 553852 O0 000 CFTC PS4 CPS 553852 O0 000 GR PS4 GAPI 553852 O0 000 TENS PS4 LB 553852 O0 000 CCLD PS4 V 553852 O0 000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 9040.500 NPHI.PS4 16.988 RTNR.PS4 3.323 TNRA.PS4 RCNT. PS4 3990.762 RCFT. PS4 1200.924 CNTC.PS4 4099.440 CFTC. PS4 GR.PS4 17.047 TENS. PS4 1010.000 CCLD.PS4 0.026 DEPT. 9000.000 NPHI.PS4 19.214 RTNR.PS4 3.653 TNRA.PS4 RCNT. PS4 4093.023 RCFT. PS4 1162.791 CNTC.PS4 4257.582 CFTC. PS4 GR.PS4 24.859 TENS. PS4 1150.000 CCLD.PS4 0.000 DEPT. 8800.000 NPHI.PS4 42.866 RTNR.PS4 6.400 TNR~.PS4 RCNT. PS4 2170.542 RCFT. PS4 388.349 CNTC. PS4 2349.227 CFTC. PS4 GR.PS4 109.625 TENS.PS4 1145.000 CCLD.PS4 0.000 DEPT. 8788.500 NPHI.PS4 45.530 RTNR.PS4 7.059 TNR~.PS4 RCNT. PS4 1922.480 RCFT. PS4 267.716 CNTC. PS4 1964.560 CFTC. PS4 GR.PS4 47.156 TENS.PS4 1175.000 CCLD.PS4 0.000 3.347 1181.031 3.647 1147.334 6. 502 401. 765 6. 812 272. 098 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15: 05 PAGE: 29 **** FILE HEADER **** FILE NAME : EDIT . O10 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : CNTD $ LOG HEADER DATA FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREbIENT: O. 5000 FILE SUb~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9025.0 8793.0 DATE LOGGED: 25-0CT-96 SOFTWARE VERSION: 42.2 TIME LOGGER ON BOTTOM: 1520 25-0CT-96 TD DRILLER (FT) : 9030.0 TD LOGGER (FT) : 9030.0 TOP LOG INTERVAL (FT) : 8787.0 BOTTOM LOG INTERVAL (FT) : 9025.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO)'. NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAb~4A RAY CNTD THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL ~ER ........... CGRS-A 814 CNC-D 146 8770.0 BRINE 30.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 30 FLUID RATE AT WELLH~ (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): 1.0 REMARKS: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 31 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG 2'TPE CI. dtSS MOD ~ SA31P ELE~ CODE (HEX) DEPT FT 553852 00 000 O0 0 10 1 1 4 68 0000000000 NPHI PS5 PU 553852 O0 000 O0 0 10 1 1 4 68 0000000000 RTNR PS5 553852 O0 000 O0 0 10 1 1 4 68 0000000000 TNRA PS5 553852 O0 000 O0 0 10 1 1 4 68 0000000000 RCNT PS5 CPS 553852 O0 000 O0 0 10 1 1 4 68 0000000000 RCFT PS5 CPS 553852 O0 000 O0 0 10 1 1 4 68 0000000000 CNTC PS5 CPS 553852 O0 000 O0 0 10 1 1 4 68 0000000000 CFTC PS5 CPS 553852 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS5 GAPI 553852 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS5 LB 553852 O0 000 O0 0 10 1 1 4 68 0000000000 CCLD PS5 V 553852 O0 000 00 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 9041.500 NPHI.PS5 15.861 RTNR.PS5 3.171 TNRA.PS5 RCNT. PS5 4101.616 RCFT. PS5 1293.302 CNTC. PS5 4213.313 CFTC. PS5 GR.PS5 25.828 TENS.PS5 990.000 CCLD.PS5 0.030 DEPT. 9000.000 NPHI.PS5 18.662 RTNR.PS5 3.577 TNRA.PS5 RCNT. PS5 4094.488 RCFT. PS5 1138.277 CNTC. PS5 4233.530 CFTC. PS5 GR.PS5 19.313 TENS. PS5 1180.000 CCLD.PS5 0.000 DEPT. 8800.000 NPHI.PS5 39.354 RTNR.PS5 6.286 TNRA.PS5 RCNT. PS5 2236.220 RCFT. PS5 342.159 CNTC. PS5 2281.703 CFTC. PS5 GR.PS5 106.875 TENS. PS5 1165.000 CCLD.PS5 0.000 DEPT. 8790.000 NPHI.PS5 42.338 RTNR.PS5 6.500 TNRA.PS5 RCNT. PS5 1763.527 RCFT. PS5 260.692 CNTC.PS5 1842.866 CFTC. PS5 GR.PS5 54.250 TENS.PS5 1160.000 CCLD.PS5 0.000 3.194 1271.879 3.573 1136.496 6.123 370.296 6.446 269.413 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 32 **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE · FLIC VERSION · O01CO1 DATE · 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 0 DEPTH INCREMENT: 0.5000 FILE SUb~ffiRY VENDOR TOOL CODE START DEPTH STOP DEPTH 9025.0 7260.0 CNTD $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAb~4A RAY CNTD THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 25-0CT-96 42.2 1520 25-0CT-96 9030.0 9030.0 8787.0 9025.0 1800.0 NO TOOL NUMBER CGRS-A 814 CNC-D 146 8770.0 BRINE 30.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 33 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): 1.0 REMARKS: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-NOV-1996 15:05 PAGE: 34 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NIIFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD ~ S~a~P ELI~I CODE (HEX) DEPT FT 553852 O0 000 O0 0 11 1 1 4 68 0000000000 NPHI PS1 PU 553852 O0 000 O0 0 11 1 1 4 68 0000000000 RTNR PS1 553852 O0 000 O0 0 11 1 1 4 68 0000000000 TNRA PS1 553852 O0 000 O0 0 11 1 1 4 68 0000000000 RCNT PS1 CPS 553852 O0 000 O0 0 11 1 1 4 68 0000000000 RCFT PSi CPS 553852 O0 000 O0 0 11 1 1 4 68 0000000000 CNTC PS1 CPS 553852 O0 000 O0 0 11 1 1 4 68 0000000000 CFTC PS1 CPS 553852 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS1 GAPI 553852 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS1 LB 553852 O0 000 O0 0 11 1 1 4 68 0000000000 CCLD PS1 V 553852 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 9041.500 NPHI. PS1 15.861 RTNR.PS1 3.171 TNRA.PS1 RCNT. PS1 4101.616 RCFT. PS1 1293.302 CNTC.PS1 4213.313 CFTC. PSi GR.PS1 25.828 TENS.PSI 990.000 CCLD.PS1 0.030 DEPT. 9000.000 NPHI. PS1 18.662 RTNR.PS1 3.577 TNRA.~S1 RCNT. PS1 4094.488 RCFT. PS1 1138.277 CNTC. PS1 4233.530 CFTC. PSi GR.PS1 19.313 TENS.PSi 1180.000 CCLD.PS1 0.000 DEPT. 8800.000 NPHI.PS1 39.354 RTNR.PS1 6.286 TNRA.PS1 RCNT. PS1 2236.220 RCFT. PS1 342.159 CNTC. PS1 2281.703 CFTC. PSI GR.PS1 106.875 TENS.PSi 1165.000 CCLD.PS1 0.000 DEPT. 8600.000 NPHI.PS1 47.152 RTNR.PS1 7.333 TNRA.PS1 RCNT. PS1 1984.496 RCFT. PS1 270.677 CNTC.PS1 2059.518 CFTC. PSi GR.PS1 40.313 TENS.PSI 1140.000 CCLD.PS1 0.000 DEPT. 8400.000 NPHI.PS1 52.842 RTNR.PS1 7.000 TNRA.PS1 RCNT. PS1 1737.828 RCFT. PS1 248.062 CNTC. PS1 1766.397 CFTC. PSI GR.PS1 45.844 TENS.PSI 1105.000 CCLD. PS1 0.000 DEPT. 8200.000 NPHI.PS1 58.216 RTNR.PSi 9.333 TNRA.PS1 RCNT. PS1 1684.210 RCFT. PS1 186.047 CNTC. PS1 1787.160 CFTC.PSi GR.PS1 39.531 TENS.PSI 1085.000 CCLD.PS1 0.000 DEPT. 8000.000 NPHI.PS1 36.178 RTNR.PS1 5.500 TNRA.PS1 RCNT. PS1 1984.962 RCFT. PS1 372.093 CNTC. PS1 2080.779 CFTC.PSI GR.PS1 31.219 TENS.PSi 1105.000 CCLD.PS1 0.000 DEPT. 7800.000 NPHI.PS1 52.530 RTNR.PS1 7.429 TNRA.PS1 RCNT. PS1 1744.361 RCFT. PS1 217.054 CNTC. PS1 1705.585 CFTC.PSI GR.PS1 63.406 TENS.PSi 1080.000 CCLD.PS1 0.083 3.194 1271.879 3.573 1136.496 6.123 370.296 6.998 278.792 7. 650 228. 964 8. 265 211. 034 5. 769 352.119 7. 614 211. 037 LIS Tape Verification Listing Schlumberger A1 aska Compu ting Center 13-NOV-1996 15:05 PAGE: 35 DEPT. 7600.000 NPHI.PS1 RCNT. PS1 1798.449 RCFT.PS1 GR.PS1 41.656 TENS.PSi DEPT. 7400.000 NPHI.PS1 RCNT. PS1 6697.674 RCFT. PS1 GR.PS1 52.438 TENS.PSi DEPT. 7258.000 NPHI.PS1 RCNT. PS1 6573.643 RCFT. PS1 GR.PS1 76.875 TENS.PSI 48.344 RTNR.PS1 248.062 CNTC. PS1 1060.000 CCLD. PS1 8.580 RTNR.PS1 3084.337 CNTC. PS1 1050.000 CCLD.PS1 9.333 RTNR.PS1 2912.000 CNTC.PS1 1015.000 CCLD.PS1 6.750 T1VRA.PS1 1805.057 CFTC. PSi 0.000 2.208 TNRA.PS1 6944.352 CFTC. PSI 0.000 2.198 TNRA. PS1 6757.033 CFTC. PSi 0.000 7.134 244.294 2.197 3074.543 2. 301 2774.107 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : 001C01 DATE : 96/11/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/11/13 ORIGIN : FLIC TAPE NAME : 96325 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, A-34A, API #50-029-21339-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/11/13 ORIGIN : FLIC REEL NAME : 96325 CONTINUATION # : PREVIOUS REEL COFk4ENT : BP EXPLORATION, PRUDHOE BAY, A-34A, API #50-029-21339-01 8775 Run 1' 17 - January - 1994 CN/GR Cased Hole 9039 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: 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 A-34A (11-36-11-13) 500292133901 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 04-FEB-94 5792.01 J. DAHL C. HUGHES 35 liN 13E 1171 921 75.60 74.60 47.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 2ND STRING 9.625 8770.0 3RD STRING 7.000 9382.0 PRODUCTION STRING 4.500 8534.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 18-MAY-85 SCHLUMBERGER WELL SERVICES BASELINE DEPTH 8775.0 8777.0 8779.0 8796.0 8803.0 8804.0 8813.0 8813.5 8814.5 8827.0 8832.0 8834.0 8838.0 GRCH 8775.0 8777.0 8779.5 8793.5 8800.5 8801.0 8811.0 8811.5 8812.0 8825.0 8830.0 8832.0 8836.0 EQUIVALENT UNSHIFTED DEPTH 47.00 26.00 12.60 8841.0 8846.0 8849.0 8853.0 8867.0 8867.5 8869.0 8870.0 8879.5 8880.5 8881.0 89OO.5 8909.5 8910.0 8912.5 8915.0 8917.5 8923.0 8928.0 8940.0 8944.0 8952.0 8954.0 8956.0 8958.0 8962.5 8965.0 8966.5 8969.0 8970.5 8977.5 8991.0 9003.5 9004.0 9008.0 9010.0 9013.5 9017.5 9039.0 9041.0 $ REMARKS: 8838.5 8844.0 8847.0 8851.0 8865.0 8866.0 8867.5 8868.0 8877.5 8878.0 8879.0 8899.0 8907.5 8908.0 8911.0 8913.0 8915.5 8922.0 8926.0 8938.0 8944.5 8951.5 8953.5 8955.O 8958.5 8962.5 8965.0 8967.0 8969.0 8971.0 8978.5 8991.5 9003.5 9004.5 9008.5 9010.5 9013.5 9015.5 9039.0 9041.0 CN/GR CASED HOLE. LOG TIED INTO BHCS (28-MAY-85). CN LOGGING PARAMETERS: SANDSTONE MATRIX CHISM OFF CASING CORRECTIONS OFF NO CALIPER CORRECTION APPLIED SALINITY = 0 PPM. THE OPEN HOLE GAMMA RAY WAS DOWNLOADED FROM BPX UPS/CSS SYSTEM 27-JAN-94. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY.' 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. / ? ?MATCH1. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRC}{ 8777.0 9016.0 2418 8789.0 9024.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 8775.0 8799.5 8813.0 8826.0 8843.5 8848.0 8886.5 89O0.5 8914.5 8928.0 8940.0 8965.0 8966.5 8969.0 8984.5 8990.5 9004.5 9025.0 9028.0 9028.5 9039.0 9041.0 $ REMARKS: NPHI 8775.0 8799.5 8814.0 8827.5 8842.0 8846.5 8885.5 8897.5 8911.5 8924.5 8937.0 8964.5 8966.0 8967.5 8983.0 8990.0 9004.5 9022.5 9025.5 9026.0 9039.0 9041.0 EQUIVALENT UNSHIFTED DEPTH PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ? ?MATCH2. OUT $ : BP EXPLORATION : A - 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-S 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 2O * DATA RECORD (TYPE# 0) Total Data Records: 13 1014 BYTES * Tape File Start Depth = 8775.000000 Tape File End Depth = 9039.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3175 datums Tape Subfile: 2 195 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH NPHI $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8779.0 9014.0 8791.0 9022.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH NPHI 8775.0 8775.0 8775.0 8784.0 8785.5 8797.0 8798.5 8798.0 8799.0 8799.0 8799.5 8799.5 8796.5 8800.5 8801.0 8801.5 8801.5 8802.5 8802.0 8803.0 8803.0 8809.5 8809.5 8810.0 8807.5 8810.5 8810.5 8811.0 8811.0 8812.0 8813.0 8811.5 8814.0 8815.0 8823.0 8823.5 8825.5 8823.5 8831.0 8831.5 8832.0 8829.5 8834.0 8831.5 8834.5 8834.0 8835.0 8834.5 8835.5 8833.5 8838.0 8835.5 8840.5 8839.0 8842.0 8840.5 8843.0 8840.0 8841.0 8844.5 8842.5 8845.5 8843.5 8848.0 8846.5 8856.0 8854.0 8857.0 8854.5 8857.5 8856.0 8858.5 8856.0 8859.0 8857.0 8864.0 8862.0 8864.5 8866.0 8867.0 8872.5 8873.0 8878.0 8883.5 8885.0 8886.0 8886.5 8888.0 8889.0 8893.5 8897.5 8898.5 8900.5 8902.0 8903.0 8905.5 8906.0 8907.0 8907.5 8908.0 8909.0 8911.5 8913.0 8914.0 8914.5 8918.0 8923.0 8925.0 8927.5 8930.0 8938.5 8940.0 8944.0 8951.5 8954.0 8955.5 8958.0 8962.5 8964.5 8965.0 8967.0 8968.5 8969.0 8970.0 8970.5 8972.0 8973.0 8977.0 8984.5 8987.0 8990.5 8994.0 8996.0 8999.0 8999.5 9000.0 9004.5 8876.0 8881.5 8885.5 8899.0 8910.0 8912.5 8916.0 8921.0 8923.0 8926.0 8928.0 8935.5 8937.5 8951.0 8953.0 8955.0 8958.0 8963.0 8964.5 8967.0 8969.0 8970.5 8973.0 8977.5 8985.0 8987.0 8990.0 8996.0 8998.5 9004.5 8863.0 8864.5 8865.0 8870.5 8871.5 8883.5 8884.0 8886.0 8886.5 8891.0 8895.0 8895.5 8899.0 8899.5 8902.0 8903.0 8904.0 8905.0 8905.5 8906.0 8910.0 8910.5 8940.5 8963.5 8967.5 8968.5 8970.5 8971.0 8993.0 8998.5 8999.5 9008.0 9008.5 9016.0 9016.5 9017.5 9019.5 9025.0 9026.5 9027.5 9028.0 9028.5 9029.0 9031.0 9031.5 9039.0 9041.0 $ REMARKS: 9008.5 9008.0 9014.5 9015.0 9015.5 9017.0 9022.5 9024.0 9024.5 9025.5 9026.0 9027.5 9029.5 9030.0 9039.0 9039.0 9041.0 9041.0 PASS 2. FUCT, NUCT, AND TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH3. OUT / ??MATCH4. OUT $ : BP EXPLORATION : a - 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-S 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 13 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 8775.000000 9039.000000 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3175 datums Tape Subfile: 3 160 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8784.0 9016.0 8797.0 9024.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 8775.0 8775.0 8796.0 8793.5 8796.5 8794.0 8797.0 8795.0 8799.0 8801.0 8799.5 8797.5 8803.0 8805.0 8805.5 8805.5 8806.0 8806.5 8807.5 8808.5 8809.0 8810.0 8809,5 8811.0 8812.5 8810.5 8813.0 8811.5 8815.0 8821.0 8819.5 8826.0 8824.5 8827.0 8830.5 8832.0 8832.0 8831.0 8833.5 8832.5 8834.5 8835.0 8835.5 8834.0 8836.0 8837.5 8836.0 8841.0 8840.5 8841.5 8840.5 8841.0 8842.5 8841.5 8843.5 8842.5 8844.5 8843.0 8843.0 8845.0 8843.5 8845.5 8844.5 8844.5 8849.0 8847.0 8850.0 8848.0 8851.5 8849.5 8852.5 8851.0 8856.0 8855.0 8857.0 8855.5 8857.5 8856.5 8863.5 8862.0 EQUIVALENT UNSHIFTED DEPTH NPHI 8775.0 8864.0 8875.0 8876.5 8877.0 8878.0 8878.5 8881.0 8883.5 8884.5 8885.0 8886.0 8886.5 8887.5 8888.5 8889.5 889O.O 8890.5 8892.0 8893.0 8897.0 8898.0 8899.0 8901.5 8902.0 8903.5 8908.0 8909.0 8909.5 8910.0 8910.5 8914.5 8916.5 8917.0 8918.0 8918.5 8919.5 8921.0 8921.5 8922.5 8924.5 8928.0 8929.0 8933.0 8939.5 8940.0 8945.5 8946.0 8953.5 8956.0 8959.5 8962.0 8964.5 8965.0 8966.5 8968.5 8969.0 8970.0 8970.5 8972.5 8973.0 8875.5 8876.0 8877.0 8883.0 8884.0 8887.5 8888.0 8888.5 8889.5 8891.0 8891.5 8900.0 8901.0 8913.5 8917.5 8920.0 8922.0 8927.0 8940.5 8947.0 8947.5 8953.5 8956.0 8960.0 8965.5 8967.0 8969.0 8970.5 8971.5 8863.0 8874.0 8876.0 8876.5 8881.0 8883.5 8884.0 8884.5 8885.0 8885.5 8886.0 8895.5 8896.0 8896.5 8901.0 8905.5 8906.0 8906.5 8907.5 8908.5 8913.5 8914.5 8915.5 8917.0 8917.5 8918.0 8920.5 8922.0 8925.0 8930.0 8937.0 8962.0 8965.0 8969.0 8971.5 8972.0 8974.0 8977.5 8979.0 8983.5 8986.0 8990.5 8991.5 8992.5 9000.0 9001.0 9003.0 9004.0 9004.5 9008.5 9010.0 9013.0 9015.5 9017.0 9017.5 9018.5 9020.5 9028.5 9029.0 9031.0 9031.5 9039.0 9041.0 $ REMARKS: 8975.0 8978.5 8980.5 8985.0 8987.0 8991.5 8991.5 8992.5 9000.5 9002.0 9001.5 9003.5 9005.5 9005.0 9009.5 9011.5 9014.0 9014.5 9016.5 9016.5 9017.0 9019.0 9027.0 9027.5 9029.5 9030.0 9039.0 9039.0 9041.0 9041.0 PASS 3. FUCT, NUCT, AND TENS WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH5. OUT / ? ?MATCH6. OUT $ : BP EXPLORATION : A - 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units GRCH 2418 68 1 GAPI NPHI 2418 68 1 PU-S FUCT 2418 68 1 CPS NUCT 2418 68 1 CPS TENS 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 * DATA RECORD (TYPE# 0) Total Data Records: 13 1014 BYTES * 20 Tape File Start Depth = 8775.000000 Tape File End Depth = 9039.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6350 datums Tape Subfile: 4 171 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: CN WN FN COUN STAT 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES. $ : BP EXPLORATION : A - 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH CNAV 68 1 GAPI 4 2 NPHI CNAV 68 1 PU-S 4 3 FUCT CNAV 68 1 CPS 4 4 NUCT CNAV 68 1 CPS 4 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 4 35 725 65 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 11 Tape File Start Depth = 8775.000000 Tape File End Depth = 9039.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5821 datums Tape Subfile: 5 34 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8775.0 2418 8785.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9023.0 9031.0 17-JAN-94 FSYS REV. J001 VER. 1.1 1119 17-JAN-94 9033.0 9029.0 8800.0 9028.0 1200.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ TOOL NUMBER 3507XA 1310XA 2418XA 2323NA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9382.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS) : 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. $ CN WN FN COUN STAT : BP EXPLORATION : A- 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 43 Tape File Start Depth = 8775.000000 Tape File End Depth = 9039.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16921 datums Tape Subfile: 6 Minimum record length: Maximum record length: 118 records... 62 bytes 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8779.0 2418 8786.0 $ LOG HEADER DATA STOP DEPTH 9023.0 9031.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 17-JAN-94 FSYS REV. J001 VER. 1.1 1144 17-JAN-94 9033.0 9029.0 8800.0 9028.0 1200.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA 0.000 9382.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION : A - 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units GR 2418 68 1 GAPI CNC 2418 68 1 PU-S CN 2418 68 1 PU-L LSN 2418 68 1 CPS SSN 2418 68 1 CPS CCL 2418 68 1 SPD 2418 68 1 F/MN TTEN 2418 68 1 LB TEN 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) Total Data Records: 43 1006 BYTES * Tape File Start Depth = 8775.000000 Tape File End Depth = 9039.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16392 datums Tape Subfile: 7 Minimum record length: Maximum record length: 118 records... 62 bytes 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8784.0 2418 8792.0 $ LOG HEADER DATA STOP DEPTH 9023.0 9031.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MODULATOR GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 17-JAN-94 FSYS REV. J001 VER. 1.1 1201 17-JAN-94 9033.0 9029.0 8800.0 9028.0 1200.0 YES TOOL NUMBER 3507XA 1310XA 2418XA 2323NA 0.000 9382.0 0.0 PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL SANDSTONE 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION : A - 34A (11-36-11-13) : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-S 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TTEN 2418 68 1 LB 9 TEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 27 466 87 5 4 4 28 122 23 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 41 Tape File Start Depth = 8783.000000 Tape File End Depth = 9039.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27172 datums Tape Subfile: 8 Minimum record length: Maximum record length: 116 records... 62 bytes 1006 bytes Tape Subfile 9 is type: LIS 94/ 2/ 4 01 **** REEL TRAILER **** 94/ 2/ 4 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 4 FEB 94 3:17p Elapsed execution time = 27.41 seconds. SYSTEM RETURN CODE = 0 HALLIBURTON L O~GIN~ S~R VIC~S, INC. OA Halliburton Company LIS TAPE VERIFICATION LISTING LDWG FORMAT Page 1 REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 93/04/02 --- ANCH --- 847266 ****************************************************************************** TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 93/04/02 --- ANCH ****************************************************************************** COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: A-34A API NUMBER: 500292133900 OPERATOR: BP EXPLORATION LOGGING COMPANY: HALLIBURTON LOGGING SERVICES TAPE CREATION DATE: 02-APR-93 JOB NUMBER: L84726-6 LOGGING ENGINEER: ROEDER OPERATOR WITNESS: ROBERTSON SURFACE LOCATION SECT ION: 35 TOWNSHIP: 11N RANGE: 13E FNL: 1172 FSL: FEL: 921 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 75.60 DERRICK FLOOR: 74.60 GROUND LEVEL: 47.00 WELL CASING RECORD OPEN HOLE CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) lST STRING 13.375 2684.0 72.00 2ND STRING 12.250 9.625 8770.0 47.00 3RD STRING 8.500 7.000 9382.0 26.00 PRODUCTION STRING 12.250 4.500 8533.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BCS PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH CNSG 8740.5 8738.5 8807.0 8805.0 8864.5 8862.5 8914.5 8912.5 8964.5 8964.5 9004.5 9004.5 9060.0 9060.0 9127.0 9127.0 9161.5 9162.0 9198.0 9198.0 9250.0 9249.5 9310.5 9310.0 $ REMARKS: TIED INTO CBL DATED 08-FEB-86. LOGGED WITH WELL SHUT-IN. WELLHEAD PRESSURE = 1225 PSI. $ FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 ~t 0 --- 93/04/02 --- 1024 --- LO COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. Page 3 PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9310.5 8750.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH CNSG 847266 GAPI FUCT CNSG 847266 CPS NUCT CNSG 847266 CPS CPHI CNSG 847266 PU-S NRAT CNSG 847266 API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP REPR. 1 68 1 68 1 68 1 68 1 68 1 68 Page 4 DATA RECORD TYPE 0 DEPT = 9310.500 GRCH = 45.500 FUCT = 306.300 NUCT = 368.800 CPHI = 31.130 NRAT = 1.228 DEPT = 9110.500 GRCH = 38.400 FUCT = 418.800 NUCT = 446.300 CPHI = 22.940 NRAT = 1.087 DEPT = 8910.500 GRCH = 32.200 FUCT = 385.300 NUCT = 400.400 CPHI = 20.100 NRAT = 1.060 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --- 93/04/02 --- 1024 --- LO --- COMCEN.002 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 --- 93/04/02 --- 1024 --- LO --- COMCEN.001 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9310.5 8740.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS Page 5 PBU CURVE CODE: GR PASS NUMBER: 01 BASELINE DEPTH CNSG EQUIVALENT UNSHIFTED DEPTH ......... NO PASS TO PASS DEPTH SHIFTS REQUIRED. CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH CNSG 847266 GAPI 00000000 0 4 1 68 FUCT CNSG 847266 CPS 00000000 0 4 1 68 NUCT CNSG 847266 CPS 00000000 0 4 1 68 CPHI CNSG 847266 PU-S 00000000 0 4 1 68 NRAT CNSG 847266 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9310.500 GRCH = 44.600 FUCT = 300.600 NUCT = 366.800 CPHI = 30.770 NRAT = 1.245 DEPT = 9110.500 GRCH = 39.500 FUCT = 403.200 NUCT = 436.300 CPHI = 23.470 NRAT = 1.104 Page 6 DEPT = 8910.500 GRCH = 32.200 FUCT = 377.500 NUCT = 397.000 CPHI = 21.760 NRAT = 1.073 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 ~gm 0 ~mg 5 --- 93/04/02 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --~t 0 --- 93/04/02 --- 1024 --- LO --- COMCEN.002 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9310.5 8748.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH CNSG 8746.0 8745.5 8805.0 8804.5 8862.5 8862.0 8912.5 8912.0 Page 7 8964.5 9004.5 9060.0 9127.0 9162.0 9198.0 9249.5 9310.0 $ REMARKS .- 8964.0 9004.0 9060.0 9127.0 9162.0 9198.0 9249.5 9310.0 CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH CNSG 847266 GAPI 00000000 0 4 1 68 FUCT CNSG 847266 CPS 00000000 0 4 1 68 NUCT CNSG 847266 CPS 00000000 0 4 1 68 CPHI CNSG 847266 PU-S 00000000 0 4 1 68 NRAT CNSG 847266 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9310.500 GRCH = 40.200 FUCT = 304.000 NUCT = 372.200 CPHI = 31.170 NRAT = 1.249 DEPT = 9110.500 GRCH = 37.600 FUCT = 401.800 Page 8 NUCT = 446.000 CPHI = 24.110 NRAT = 1.132 DEPT = 8910.500 GRCH = 33.000 FUCT = 394.400 NUCT = 410.100 CPHI = 21.080 NRAT = 1.061 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 --- 93/04/02 --- 1024 --- LO --- COMCEN.004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 93/04/02 --- 1024 --- LO --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CNSG 9310.5 8747.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH CNSG 8745.5 8745.0 8805.0 8804.5 8862.5 8862.0 Page 9 8912.5 8964.5 9004.5 9060.0 9127.0 9162.0 9198.0 9249.5 9310.0 $ REMARKS: 8912.0 8964.0 9004.0 9060.0 9127.0 9162.0 9198.0 9249.5 9310.0 CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 24 4 i 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH CNSG 847266 GAPI 00000000 0 4 1 68 FUCT CNSG 847266 CPS 00000000 0 4 1 68 NUCT CNSG 847266 CPS 00000000 0 4 1 68 CPHI CNSG 847266 PU-S 00000000 0 4 1 68 NRAT CNSG 847266 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9310.500 GRCH = 44.600 FUCT = 306.100 NUCT = 369.600 CPHI = 30.200 NRAT = 1.232 Page 10 DEPT = 9110.500 GRCH = 40.900 FUCT = 396.800 NUCT = 446.900 CPHI = 25.590 NRAT = 1.149 DEPT = 8910.500 GRCH = 32.000 FUCT = 374.300 NUCT = 400.600 CPHI = 22.200 NRAT = 1.092 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 ~w~ 0 --- 93/04/02 --- 1024 --- LO --- COMCEN.005 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 --- 93/04/02 --- 1024 --- LO --- COMCEN.004 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS CNSG $ REMARKS: 01,02,03,04 CPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ Page 11 LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i 1 66 0 2 i 66 0 3 2 79 24 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .lin 11 2 79 42 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH CNAV 847266 GAPI FUCT CNAV 847266 CPS NUCT CNAV 847266 CPS CPHI CNAV 847266 PU-S NRAT CNAV 847266 AP1 CODE FILE# SIZE #SAMP REPR. 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9310.500 GRCH = 43.725 FUCT = 304.250 NUCT = 369.350 CPHI = 30.817 NRAT = 1.238 DEPT = 9110.500 GRCH = 39.100 FUCT = 405.150 NUCT = 443.875 CPHI = 24.028 NRAT = 1.118 DEPT = 8910.500 GRCH = 32.350 FUCT = 382.875 NUCT = 402.025 CPHI = 21.285 NRAT = 1.071 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 93/04/02 --- 1024 --- LO --- COMCEN.006 Page 12 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --- 93/04/02 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT $ LOG HEADER DATA 9327.5 8748.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 13-JUL-92 DDL 0367-96 1223 13-JUL-92 9335.0 9312.0 8736.0 9310.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): 4515 27002 8.500 9382.0 PRODUCED 7.45 Page 13 BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 15000 8200.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8. 500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9200.0 BASE NORMALIZING WINDOW (FT): 9250.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 95 FAR COUNT RATE HIGH SCALE (CPS): 1095 NEAR COUNT RATE LOW SCALE (CPS): 160 NEAR COUNT RATE HIGH SCALE (CPS): 1160 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #1. NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 26 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 39 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: Page 14 MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GR CNT 847266 GAPI 00000000 0 4 1 68 MCCL CNT 847266 MV 00000000 0 2 1 79 FCNL CNT 847266 CPS 00000000 0 4 1 68 NCNL CNT 847266 CPS 00000000 0 4 1 68 NPHI CNT 847266 PU 00000000 0 4 1 68 NRAT CNT 847266 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9327.500 GR = .000 MCCL = 0 FCNL = .000 NCNL = .000 NPHI = 29.760 NRAT = .000 DEPT = 9227.500 GR = 37.400 MCCL = 23 FCNL = 262.300 NCNL = 334.900 NPHI = 32.510 NRAT = 1.302 DEPT = 9127.500 GR = 48.700 MCCL = 26 FCNL = 398.700 NCNL = 436.600 NPHI = 24.060 NRAT = 1.117 DEPT = 9027.500 GR = 65.100 MCCL = 114 FCNL = 456.700 NCNL = 461.900 NPHI = 20.080 NRAT = 1.032 DEPT = 8927.500 GR = 32.100 MCCL = 31 FCNL = 442.500 NCNL = 464.700 NPHI = 21.560 NRAT = 1.071 DEPT = 8827.500 GR = 194.800 MCCL = 45 FCNL = 298.200 NCNL = 349.600 NPHI = 28.960 NRAT = 1.196 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 --- 93/04/02 --- 1024 --- LO --- COMCEN.007 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME --- COMCEN.007 Page 15 SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- 93/04/02 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT $ LOG HEADER DATA 9327.5 8738.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 13-JUL-92 DDL 0367-96 1223 13-JUL-92 9335.0 9312.0 8736.0 9310.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): 4515 27002 8.500 9382.0 PRODUCED 7.45 15000 8200.0 Page 16 GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9200.0 BASE NORMALIZING WINDOW (FT): 9250.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 95 FAR COUNT RATE HIGH SCALE (CPS): 1095 NEAR COUNT RATE LOW SCALE (CPS): 160 NEAR COUNT RATE HIGH SCALE (CPS): 1160 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #2. NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 26 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 39 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GR CNT 847266 GAPI MCCL CNT 847266 MV FCNL CNT 847266 CPS API CODE FILE# 00000000 0 00000000 0 00000000 0 00000000 0 SIZE 4 4 2 4 #SAMP REPR. 1 68 1 68 1 79 I 68 Page 17 NCNL CNT 847266 CPS 00000000 0 4 1 68 NPHI CNT 847266 PU 00000000 0 4 1 68 NRAT CNT 847266 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9327.500 GR = .000 MCCL = 0 FCNL = .000 NCNL = .000 NPHI = 60.630 NRAT = .000 DEPT = 9227.500 GR = 41.000 MCCL = 17 FCNL = 275.700 NCNL = 335.300 NPHI = 31.100 NRAT = 1.241 DEPT = 9127.500 GR = 49.600 MCCL = 45 FCNL = 395.300 NCNL = 420.400 NPHI = 23.630 NRAT = 1.085 DEPT = 9027.500 GR = 67.400 MCCL = 107 FCNL = 445.300 NCNL = 455.100 NPHI = 20.230 NRAT = 1.042 DEPT = 8927.500 GR = 31.000 MCCL = 39 FCNL = 442.300 NCNL = 455.200 NPHI = 21.570 NRAT = 1.050 DEPT = 8827.500 GR = 193.600 MCCL = 82 FCNL = 320.500 NCNL = 356.900 NPHI = 27.860 NRAT = 1.136 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 m~ 0 --- 93/04/02 --- 1024 --- LO --- COMCEN.008 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.008 --~-- 0 --~ 5 --- 93/04/02 --- 1024 --- LO Page 18 OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT 9327.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 8745.5 13-JUL-92 DDL 0367-96 1223 13-JUL-92 9335.0 9312.0 8736.0 9310.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY CNT COMPENSATED NEUTRON $ 4515 27002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9382.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED 7.45 15000 8200.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERI~ Page 19 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9200.0 BASE NORMALIZING WINDOW (FT): 9250.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 95 FAR COUNT RATE HIGH SCALE (CPS): 1095 NEAR COUNT RATE LOW SCALE (CPS): 160 NEAR COUNT RATE HIGH SCALE (CPS): 1160 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS ~3. NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 26 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 39 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILES SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 GR CNT 847266 GAPI 00000000 0 4 1 68 MCCL CNT 847266 MV 00000000 0 2 1 79 FCNL CNT 847266 CPS 00000000 0 4 1 68 NCNL CNT 847266 CPS 00000000 0 4 1 68 NPHI CNT 847266 PU 00000000 0 4 1 68 NRAT CNT 847266 00000000 0 4 1 68 ****************************************************************************** Page 20 DATA RECORD TYPE 0 DEPT = 9327.500 GR = .000 MCCL = 0 FCNL = .000 NCNL = .000 NPHI = 55.070 NRAT = .000 DEPT = 9227.500 GR = 39.000 MCCL = 60 FCNL = 259.400 NCNL = 324.500 NPHI = 32.420 NRAT = 1.276 DEPT = 9127.500 GR = 44.600 MCCL = 20 FCNL = 381.500 NCNL = 434.600 NPHI = 25.690 NRAT = 1.162 DEPT = 9027.500 GR = 66.600 MCCL = 162 FCNL = 455.200 NCNL = 465.800 NPHI = 19.930 NRAT = 1.044 DEPT = 8927.500 GR = 33.200 MCCL = 33 FCNL = 425.100 NCNL = 460.500 NPHI = 23.420 NRAT = 1.105 DEPT = 8827.500 GR = 168.900 MCCL = 62 FCNL = 351.100 NCNL = 386.100 NPHI = 26.160 NRAT = 1.122 FILE TRAILER RECORD TYPE 129 FILE NAM]Z SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 m~ 0 --- 93/04/02 --- 1024 --- LO --- COMCEN.009 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 ~t 0 --- 93/04/02 --- 1024 --- LO --- COMCEN.008 COMMENT RECORD TYPE 232 Page 21 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNT $ LOG HEADER DATA 9327.5 8745.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 13-JUL-92 DDL 0367-96 1223 13-JUL-92 9335.0 9312.0 8736.0 9310.0 1800.0 NO TOOL NUMBER GR GAMMA RAY CNT COMPENSATED NEUTRON $ 4515 27002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.5OO 9382.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED 7.45 15000 8200.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE Page 22 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 9200.0 9250.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 95 FAR COUNT RATE HIGH SCALE (CPS): 1095 NEAR COUNT RATE LOW SCALE (CPS): 160 NEAR COUNT RATE HIGH SCALE (CPS): 1160 TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #4. NPHI PRESENTED WITH THE FOLOWING PARAMETERS: BIT SIZE = 8.5" CASING SIZE = 7.0" CASING WT. = 26.0 LB SALI. FORM. = 15.0 KPPM $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 26 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 39 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 GR CNT 847266 GAPI 00000000 0 4 1 68 MCCL CNT 847266 MV 00000000 0 2 1 79 FCNL CNT 847266 CPS 00000000 0 4 1 68 NCNL CNT 847266 CPS 00000000 0 4 1 68 NPHI CNT 847266 PU 00000000 0 4 1 68 NRAT CNT 847266 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9327.500 GR = .000 MCCL = 0 FCNL = .000 NCNL = .000 NPHI = 56.800 Page 23 NP~T = .000 DEPT = 9227.500 GR = 36.000 MCCL = 55 FCNL = 262.300 NCNL = 328.900 NPHI = 32.720 NRAT = 1.279 DEPT = 9127.500 GR = 42.500 MCCL = 27 FCNL = 390.300 NCNL = 430.100 NPHI = 24.460 NRAT = 1.124 DEPT = 9027.500 GR = 72.400 MCCL = 184 FCNL = 452.400 NCNL = 452.400 NPHI = 19.750 NRAT = 1.020 DEPT = 8927.500 GR = 33.400 MCCL = 23 FCNL = 437.600 NCNL = 454.000 NPHI = 21.480 NRAT = 1.058 DEPT = 8827.500 GR = 149.200 MCCL = 74 FCNL = 351.200 NCNL = 406.500 NPHI = 27.460 NRAT = 1.181 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --- 93/04/02 --- 1024 --- LO TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 93/04/02 --- ANCH w~ 0 REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA --- COMCEN --- 93/04/02 --- ANCH Page 24 REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- 847266 END OF TAPE ENCOUNTERED Page 25 * LIS TAPE VERIFICATION LISTING * * COMPANY: BP EXPLORATION * * WELL: A-34A * * API #: 50-029-21339-00 * * DATE: 07-12-92 * * FIELD: PRUDHOE BAY * * BOROUGH: NORTH SLOPE * * STATE: ALASKA * * LOGS: PSGT * Page 1 OCI' 0 8 '!99'2. AnChorage REEL HEADER RECORD TYPE 132 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 92/09/04 --- ANCH --- 847222 TAPE HEADER RECORD TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 92/09/04 --- ANCH ~ 0 COMMENT RECORD TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: 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 OPEN HOLE A-34A 500292133900 BP EXPLORATION INC. HALLIBURTON LOGGING SERVICES 04-SEP-92 L84722-2 KILLINGSWRTH ROBERTSON 35 liN 13E 1172 921 75.60 74.60 47.00 CASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LS/FT) lST STRING 13.275 2684.0 72.00 2ND STRING 12.250 9.625 8770.0 47.00 3RD STRING 8.500 7.000 9335.0 26.00 PRODUCTION STRING 8.500 4.500 8534.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: BHC PBU CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... PSGT 8888.0 8886.0 8915.0 8913.0 8964.5 8964.5 9004.5 9004.5 9058.5 9058.5 9112.5 9112.5 9162.0 9162.0 9198.0 9198.0 9250.0 9249.0 9301.0 9300.0 $ REMARKS: FILE ORGANIZATION: FILE 1: EDITED PASS 1 DATA ( .50 FT DEPTH INCREMENT ) FILE 2: EDITED PASS 2 DATA ( .50 FT DEPTH INCREMENT ) FILE 3: EDITED PASS 3 DATA ( .50 FT DEPTH INCREMENT ) FILE 4: EDITED PASS 4 DATA ( .50 FT DEPTH INCREMENT ) FILE 5: EDITED PASS 5 DATA ( .50 FT DEPTH INCREMENT ) FILE 6: AVERAGED PASS 1-5 ( .50 FT DEPTH INCREMENT ) FILE 7: RAW DATA OF PASS 1 ( .25 FT DEPTH INCREMENT ) FILE 8: RAW DATA OF PASS 2 ( .25 FT DEPTH INCREMENT ) FILE 9: RAW DATA OF PASS 3 ( .25 FT DEPTH INCREMENT ) FILE 10: RAW DATA OF PASS 4 ( .25 FT DEPTH INCREMENT ) FILE 11: RAW DATA OF PASS 5 ( .25 FT DEPTH INCREMENT ) FILE 12: COMPUTED DATA FILE ( .25 FT DEPTH INCREMENT ) $ ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001 --- 92/09/04 --- 1024 --- LO Page 3 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9301.0 8888.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH PSGT $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #1. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 847222 GAPI LIRI PSGT 847222 AP1 CODE FILE# 00000000 0 00000000 0 00000000 0 SIZE #SAMP REPR. 4 1 68 4 1 68 4 1 68 Page 4 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 ITCR PSGT 847222 00000000 0 4 i 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 1 68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 1 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9301.000 GRCH = 17.709 LIRI = 1.338 COIR = .451 STUN = .010 ITCR = 3234.665 HPLI = 1.327 TCCR = 5969.790 OAI = 4.065 SIAI = 4.274 RIC = .542 KIC = .391 HIC = .073 SIIC = .067 CLIC = .015 CAIC = .003 FEIC = .086 SIC = .094 FERC ~ 2.507 TMDS = 18.217 TENS = 2519.421 TEMP = 17.200 DEPT = 9101.000 GRCH 18.606 LIRI = 1.328 COIR = .449 STUN = .006 ITCR = 2816.758 HPLI = 1.380 TCCR = 6187.571 OAI = 2.080 SIAI = 2.586 RIC = .455 KIC = .389 HIC = .073 SIIC = .076 CLIC = .016 CAIC = .002 FEIC = .084 SIC = .093 FERC = 2.419 TMDS = 13.783 TENS = 2447.758 TEMP = 17.600 DEPT = 8901.000 GRCH = 28.906 LIRI = 1.329 COIR = .476 STUN = .009 ITCR = 2602.035 'HPLI = 1.338 TCCR = 5696.791 OAI = 8.394 SIAI = 3.387 RIC = .457 KIC = .394 HIC = .072 SIIC = .074 CLIC = .020 CAIC = .002 FEIC = .083 SIC = .097 FERC = 2.380 TMDS = 18.042 TENS = 2404.759 TEMP = 19.100 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME --- COMCEN.001 Page 5 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ------ 5 --- 92/09/04 --- 1024 --- LO --- COMCEN. 002 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER' DATE OF GENERATION · MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 g~ 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.001 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 02 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9300.0 8889.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 8887.0 8887.5 8896.0 8896.5 8964.5 8965.5 9004.5 9005.5 9058.5 9059.5 9112.5 9113.5 9162.0 9163.0 9198.0 9199.0 9249.0 9250.0 9299.0 9300.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #2. $ Page 6 LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE ~SAMP REPR. DEPT F 00000000 0 4 1 68 GRCH PSGT 847222 GAPI 00000000 0 4 1 68 LIRI PSGT 847222 00000000 0 4 1 68 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 1 68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 I 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9300.000 GRCH = 46.150 LIRI =. 1.323 COIR = .453 STUN = .010 ITCR = 2342.087 HPLI = 1.411 TCCR = 4567.872 OAI = 2.646 SIAI = 5.462 RIG = .513 KIC = .390 HIC = .074 SIIC = .064 CLIC = .016 Page 7 CAIC = .002 FEIC = .090 SIC = .090 FERC = 2.410 TMDS = 16.769 TENS = 2591.085 TEMP = 19.500 DEPT = 9100.000 GRCH = 35.104 LIRI = 1.300 COIR = .463 STUN = .007 ITCR = 2507.835 HPLI = 1.348 TCCR = 5498.945 OAI = 2.209 SIAI = 3.184 RIC = .456 KIC = .388 HIC = .072 SIIC = .077 CLIC = .015 CAIC = .002 FEIC = .085 SIC = .095 FERC = 2.368 TMDS = 12.781 TENS = 2490.756 TEMP = 21.500 DEPT = 8900.000 GRCH = 55.857 LIRI = 1.375 COIR = .499 STUN = .010 ITCR = 2275.205 HPLI = 1.387 TCCR = 4497.815 OAI = 7.615 SIAI = 4.788 RIC = .506 KIC = .401 HIC = .072 SIIC = .074 CLIC = .026 CAIC = .001 FEIC = .080 SIC = .096 FERC = 2.331 TMDS = 21.783 TENS = 2404.759 TEMP = 23.800 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 --- 92/09/04 --- 1024 --- LO --- COMCEN.003 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE'OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --- 92/09/04 --- 1024 --- LO --- COMCEN.002 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 03 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 Page FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9300.5 8889.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE~URVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 8887.5 8887.5 8896.0 8896.0 8964.5 8965.0 9004.5 9005.0 9058.5 9059.0 9112.5 9113.0 9162.0 9162.5 9198.0 9198.5 9249.0 9249.5 9299.5 9300.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #3. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 i 66 0 2 1 66 0 3 2 79 - 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 '11 12 4 68 -999.000 14 4 65 -F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F GRCH PSGT 847222 GAPI LIRI PSGT 847222 API CODE FILE# 00000000 0 00000000 0 00000000 0 SIZE #SAMP REPR. 4 1 68 4 1 68 4 1 68 Page 9 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 1 68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 1 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 i 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9300.500 GRCH = 63.322 LIRI = 1.341 COIR = .466 STUN = .009 ITCR = 2296.556 HPLI = 1.448 TCCR = 4407.636 OAI = 5.955 SIAI = 8.168 RIC = .521 KIC = .393 HIC = .072 SIIC = .067 CLIC = .018 CAIC = .002 FEIC = .088 SIC = .091 FERC = 2.376 TMDS = 17.493 TENS = 2519.421 TEMP = 24.300 DEPT = 9100.500 GRCH = 45.231 LIRI = 1.300 COIR = .462 STUN = .007 ITCR = 2510.707 HPLI = 1.410 TCCR = 5348.873 OAI = 2.539 SIAI = 3.599 RIC = .469 KIC = .389 HIC = .073 SIIC = .077 CLIC = .017 CAIC = .002 FEIC = .084 SIC = .092 FERC = 2.378 TMDS = 12.787 TENS = 2562.420 TEMP = 27.200 DEPT = 8900.500 GRCH = 47.738 LIRI = 1.347 COIR = .462 STUN = .009 ITCR = 2331.629 HPLI = 1.353 TCCR = 4834.498 OAI = 6.850 SIAI = 3.111 RIC = .482 KIC = .397 HIC = .071 SIIC = .072 CLIC = .020 CAIC = .003 FEIC = .083 SIC = .096 FERC = 2.459 TMDS = 19.548 TENS = 2476.423 TEMP = 30.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME --- COMCEN.003 ttt 0 Page 10 VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- 92/09/04 --- 1024 --- LO --- COMCEN. 004 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 tit 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.003 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 04 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 04 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9301.0 8900.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH PSGT 8898.0 9300.0 $ REMARKS: 8898.0 9300.0 THIS FILE CONTAINS EDITED DATA FOR PASS #4. NO PASS TO PASS DEPTH SHIFTS WERE PERFORMED. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 OCT 0 8 199Z Page 11 Ala~k~ OJl ~ ~m~ O~n~. Commission Anchorage TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT' F 00000000 0 4 i 68 GRCH PSGT 847222 GAPI 00000000 0 4 1 68 LIRI PSGT 847222 00000000 0 4 1 68 COIR PSGT 847222 00000000 0 4 i 68 STUN PSGT 847222 00000000 0 4 I 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 i 68 TCCR PSGT 847222 00000000 0 4 1 68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 1 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 I 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 i 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 ****************************************************************************** DATA RECORD - TYPE 0 DEPT = 9301.000 GRCH = 46.686 LIRI = 1.345 COIR = .461 STUN = .009 ITCR = 2148.588 HPLI = 1.409 TCCR = 4236.563 OAI = 3.508 SIAI = 9.182 RIC = .507 KIC = .391 HIC = .073 SIIC = .067 CLIC = .015 CAIC = .001 FEIC = .089 SIC = .091 FERC = 2.460 TMDS = 16.277 TENS = 2619.751 TEMP = 30.600 DEPT = 9101.000 GRCH = 47.308 LIRI = 1.319 COIR = .463 STUN = .007 ITCR = 2449.642 Page 12 HPLI = 1.417 TCCR = 5254.245 OAI = 2.158 SIAI = 3.550 RIC = .466 KIC = .388 HIC = .073 SIIC = .077 CLIC = .016 CAIC = .003 FEIC = .083 SIC = .091 FERC = 2.352 TMDS = 12.121 TENS = 2490.756 TEMP = 32.700 DEPT = 8901.000 GRCH = 41.830 LIRI = 1.302 COIR = .468 STUN = .008 ITCR = 2427.175 HPLI = 1.360 TCCR = 5240.225 OAI = 6.745 SIAI = 3.202 ~ RIC = .463 KIC = .392 HIC = .071 SIIC = .073 CLIC = .016 CAIC = .003 FEIC = .084 SIC = .095 FERC = 2.415 TMDS = 17.590 TENS = 2519.421 TEMP = 34.800 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 w~ 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.005 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 ~ 0 ~ 5 --- 92/09/04 --- 1024 --- LO --- COMCEN.004 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 05 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH PSGT 9300.5 8891.0 $ Page 13 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 01 .EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH PSGT 8889.0 8889.0 8896.0 8896.0 8964.5 8964.5 9004.5 9004.5 9058.5 9058.5 9112.5 9112.5 9162.0 9162.5 9198.0 9198.5 9249.0 9249.5 9299.5 9300.0 $ REMARKS: THIS FILE CONTAINS EDITED DATA FOR PASS #5. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 88 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F GRCH PSGT 847222 LIRI PSGT 847222 COIR PSGT 847222 STUN PSGT 847222 ITCR PSGT 847222 HPLI PSGT 847222 TCCR PSGT 847222 OAI PSGT 847222 SIAI PSGT 847222 GAPI API CODE FILES SIZE ~SAMP REPR. 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 1 68 00000000 0 4 i 68 Page 14 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 I 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT. 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9300.500 GRCH = 66.541 LIRI = 1.323 COIR = .449 STUN = .009 ITCR = 2186.227 HPLI = 1.410 TCCR = 4201.051 OAI = 6.617 SIAI = 9.174 RIC = .520 KIC = .387 HIC = .075 SIIC = .068 CLIC = .013 CAIC = .003 FEIC = .089 SIC = .088 FERC = 2.401 TMDS = 17.960 TENS = 2648.417 TEMP = 39.000 DEPT = 9100.500 GRCH = 43.208 LIRI = 1.299 COIR = .453 STUN = .008 ITCR = 2318.645 HPLI = 1.344 TCCR = 5130.152 OAI = 1.808 SIAI = 3.148 RIC = .452 KIC = .389 HIC = .071 SIIC = .076 CLIC = .015 CAIC = .003 FEIC = .085 SIC = .095 FERC = 2.367 TMDS = 12.121 TENS = 2490.756 TEMP = 40.600 DEPT = 8900.500 GRCH = 44.837 LIRI = 1.326 COIR = .464 STUN = .010 ITCR = 2302.271 HPLI = 1.308 TCCR = 4940.106 OAI = 4.392 SIAI = 3.310 RIC = .466 KIC = .395 HIC = .072 SIIC = .072 CLIC = .018 CAIC = .004 FEIC = .084 SIC = .098 FERC = 2.358 TMDS = 16.872 TENS = 2376.094 TEMP = 41.700 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.005 --- 92/09/04 --- 1024 --- LO --- COMCEN.006 Page 15 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --- 92/09/04 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS PSGT $ REMARKS: 01,02,03,04,05 THIS FILE CONTAINS AVERAGED DATA OF EDITED PASSES 1-5. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 84 4 1 66 1 5 1 66 1 8 4 73 60 9 4 65 .liN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: Page 16 MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 GRCH PGAV 847222 GAPI 00000000 0 4 1 68 LIRI PGAV 847222 00000000 0 4 i 68 COIR PGAV 847222 00000000 0 4 I 68 STUN PGAV 847222 00000000 0 4 1 68 ITCR PGAV 847222 00000000 0 4 i 68 HPLI PGAV 847222 00000000 0 4 I 68 TCCR PGAV 847222 00000000 0 4 i 68 OAI PGAV 847222 00000000 0 4 i 68 SIAI PGAV 847222 00000000 0 4 i 68 RIC PGAV 847222 00000000 0 4 1 68 KIC PGAV 847222 00000000 0 4 i 68 HIC PGAV 847222 00000000 0 4 1 68 SIIC PGAV 847222 00000000 0 4 i 68 CLIC PGAV 847222 00000000 0 4 1 68 CAIC PGAV 847222 00000000 0 4 1 68 FEIC PGAV 847222 00000000 0 4 1 68 SIC PGAV 847222 00000000 0 4 1 68 FERC PGAV 847222 00000000 0 4 1 68 TMDS PGAV 847222 CU 00000000 0 4 1 68 TEMP PGAV 847222 DEGC 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9300.000 GRCH = 17.709 LIRI = 1.332 COIR = .454 STUN = .009 ITCR = 2426.111 HPLI = 1.384 TCCR = 4649.620 OAI = 3.063 SIAI = 6.147 RIC = .520 KIC = .389 HIC = .073 SIIC = .066 CLIC = .015 CAIC = .002 FEIC = .089 SIC = .092 FERC = 2.428 TMDS = 17.395 TEMP = 26.140 DE?T = 9100.000 GRCH = 18.103 LIRI = 1.307 COIR = .460 STUN = .007 ITCR = 2520.839 HPLI = 1.377 TCCR = 5469.414 OAI = 2.210 SIAI = 3.203 RIC = .461 KIC = .388 HIC = .071 SIIC = .076 CLIC = .015 CAIC = .003 FEIC = .085 SIC = .093 FERC = 2.385 TMDS = 12.823 TEMP = 27.920 DEPT = 8900.000 GRCH = 41.581 LIRI = 1.353 COIR = .477 STUN = .009 ITCR = 2333.071 HPLI = 1.345 TCCR = 4702.175 OAI = 6.896 SIAI= 4.209 RIC = .496 KIC = .399 HIC = .072 SIIC = .072 CLIC = .022 CAIC = .002 FEIC = .081 SIC = .097 FERC = 2.393 TMDS = 20.362 TEMP = 29.900 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME --- COMCEN.006 Page 17 SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME ------ 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.007 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 --- 92/09/04 --- 1024 --- LO --- COMCEN.006 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 07 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 01 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 9310.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8886.0 12-JUL-92 2.23 2020 9335.0 9310.0 8888.0 9310.5 300.0 NO 12-JUL-92 TOOL NUMBER GR NGRT-A PSGT PSGT-A $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 114434S 0O8 8.500 Page 18 DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8OREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 9335.0 PRODUCED NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #1. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 Page 19 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE ~SAMP REPR. DEPT F 00000000 0 4 i 68 CCL PSGT 847222 MV 00000000 0 4 i 68 GR PSGT 847222 GAPI 00000000 0 4 I 68 LIRI PSGT 847222 00000000 0 4 i 68 COIR PSGT 847222 00000000 0 4 i 68 STUN PSGT 847222 00000000 0 4 I 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 i 68 OAI PSGT 847222 00000000 0 4 i 68 SIAI PSGT 847222 00000000 0 4 i 68 RIC PSGT 847222 00000000 0 4 I 68 KIC PSGT 847222 00000000 .0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 i 68 CLIC PSGT 847222 00000000 0 4 i 68 CAIC PSGT 847222 00000000 0 4 i 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 I 68 FERC PSGT 847222 00000000 0 4 i 68 TMDS PSGT 847222 CU 00000000 0 4 i 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9310.500 CCL = 5461.000 GR = 17.709 LIRI = 1.393 COIR = .451 STUN = .000 ITCR = 3352.531 HPLI = 1.279 TCCR = 6053.423 OAI = 10.600 SIAI = 7.600 RIC = .554 KIC = .389 HIC = .073 SIIC = .066 CLIC = .017 CAIC = .001 FEIC = .085 SIC = .096 FERC = 2.648 TMDS = 14.216 TENS = 2003.441 TEMP = 17.200 DEPT = 9210.500 CCL = 5466.000 GR = 29.439 LIRI = 1.380 COIR = .470 STUN = .008 ITCR = 2990.652 HPLI = 1.372 TCCR = 5510.536 OAI = 2.187 SIAI = 2.525 RIC = .543 KIC = .406 HIC = .085 SIIC = .074 CLIC = .021 CAIC = .003 FEIC = .073 SIC = .088 FERC = 2.460 TMDS = 18.710 TENS = 2519.421 TEMP = 17.300 DEPT = 9110.500 CCL = 5464.000 GR = 25.898 LIRI = 1.339 COIR = .452 STUN = .006 ITCR = 2830.328 HPLI = 1.377 TCCR = 5535.858 OAI = 2.748 SIAI = 2.201 RIC = .511 KIC = .389 HIC = .076 SIIC = .075 CLIC = .014 CAIC = .003 FEIC = .084 SIC = .091 FERC = 2.451 TMDS = 14.602 Page 20 TENS = 2447.758 TEMP = 17.600 DEPT = 9010.500 CCL = 5461.000 GR = 47.155 LIRI = 1.333 COIR = .457 STUN = .009 ITCR = 2559.857 HPLI = 1.312 TCCR = 4786.948 OAI = 1.306 SIAI = 2.253 RIC = .535 KIC = .389 HIC = .072 SIIC = .068 CLIC = .015 CAIC = .004 FEIC = .087 SIC = .096 FERC = 2.350 TMDS = 15.938 TENS = 2419.092 TEMP = 18.400 DEPT = 8910.500 CCL = 5466.000 GR = 24.832 LIRI = 1.393 COIR = .488 STUN = .009 ITCR = 2406.952 HPLI = 1.323 TCCR = 4755.501 OAI = 5.806 SIAI = 2.316 RIC = .506 KIC = .394 HIC = .070 SIIC = .065 CLIC = .022 CAIC = .001 FEIC = .088 SIC = .097 FERC = 2.425 TMDS = 15.114 TENS = 2419.092 TEMP = 19.000 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 92/09/04 --- 1024 --- LO --- COMCEN.008 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 --- 92/09/04 --- 1024 --- LO --- COMCEN.007 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT: 0.2500 Page 21 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 9310.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM= TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM L°G INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8887.5 12-JUL-92 2.23 2020 9335.0 9310.0 8888.0 9310.5 300.0 NO 12-JUL-92 TOOL NUMBER GR NGRT-A PSGT PSGT-A $ 114434S OO8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9335.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): _ NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): PRODUCED THERMAL SANDSTONE 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 Page 22 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #2. $ LIS FORMAT DATA DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 i 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 1 68 CCL PSGT 847222 MV 00000000 0 4 1 68 GR PSGT 847222 GAPI 00000000 0 4 1 68 LIRI PSGT 847222 00000000 0 4 1 68 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 I '68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 I 68 RIC PSGT 847222 00000000 0 4 i 68 KIC PSGT 847222 00000000 0 4 i 68 HIC PSGT 847222 00000000 0 4 I 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9310.000 CCL = 5460.000 GR = 46.150 Page 23 LIRI = 1.327 COIR = .595 STUN = .004 ITCR = 1515.284 HPLI = 1.459 TCCR = 3326.249 OAI = 5.179 SIAI = 3.206 RIC = .456 KIC = .401 HIC = .066 SIIC = .067 CLIC = .015 CAIC = .007 FEIC = .084 SIC = .088 FERC = 2.321 TMDS = 18.168 TENS = 2089.438 TEMP = 19.500 DEPT = 9210.000 eCL = 5463.000 GR = 41.244 LIRI = 1.383 COIR = .467 STUN = .009 ITCR = 2256.893 HPLI = 1.384 TCCR = 4341.159 OAI = 1.302 SIAI = 2.411 RIC = .520 KIC = .403 HIC = .089 SIIC = .074 CLIC = .018 CAIC = .005 FEIC = .074 SIC = .085 FERC = 2.291 TMDS = 16.422 TENS = 2505.089 TEMP = 20.200 DEPT = 9110.000 CCL = 5470.000 GR = 37.330 LIRI = 1.325 COIR = .444 STUN = .006 ITCR = 2496.742 HPLI = 1.365 TCCR = 4956.139 OAI = 2.248 SIAI = 2.692 RIC = .504 KIC = .389 HIC = .078 SIIC = .076 CLIC = .015 CAIC = .003 FEIC = .083 SIC = .091 FERC = 2.319 TMDS = 14.174 TENS = 2490.756 TEMP = 21.300 DEPT = 9010.000 CCL = 5462.000 GR = 50.917 LIRI = 1.322 COIR = .484 STUN = .009 ITCR = 2413.650 HPLI = 1.366 TCCR = 4906.840 OAI = 1.340 SIAI = 2.806 RIC = .492 KIC = .390 HIC = .072 SIIC = .072 CLIC = .015 CAIC = .002 FEIC = .087 SIC = .092 FERC = 2.418 TMDS = 16.994 TENS = 2419.092 TEMP = 22.600 DEPT = 8910.000 CCL = 5460.000 GR = 29.956 LIRI = 1.372 COIR = .480 STUN = .009 ITCR = 2236.338 HPLI = 1.358 TCCR = 4691.532 OAI = 6.350 SIAI = 3.182 RIC = .477 KIC = .393 HIC = .073 SIIC = .073 CLIC = .018 CAIC = .002 FEIC = .086 SIC = .094 FERC = 2.308 TMDS = 13.681 TENS = 2433.425 TEMP = 23.600 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 ~ 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.009 Page 24 FILE HEADER RECORD ................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 ~t 0 --- 92109104 --- 1024 --- LO --- COMCEN.008 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ LOG HEADER DATA 9309.0 8887.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO-BOTTOM) VENDOR TOOL CODE TOOL TYPE 12-JUL-92 2.23 2020 12-JUL-92 9335.0 9310.0 8888.0 9310.5 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): Page 25 114434S 008 8.500 9335.0 PRODUCED RECEIVED OCT 0 8 199~ Alaska 0[~ & G~ (~on~. Commission Anchorage SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #3. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i 1 66 0 2 i 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 -73 30 9 4 65 .lIN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS DEPT F CCL PSGT 847222 MV GR PSGT 847222 GAPI API CODE FILE# 00000000 0 00000000 0 00000000 0 SIZE #SAMP REPR. 4 1 68 4 1 68 4 1 68 Page 26 LIRI PSGT 847222 00000000 0 4 1 68 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 1 68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 i 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 I 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 . FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9309.000 CCL = 5461.000 GR = 63.322 LIRI = 1.493 COIR = .497 STUN = .004 ITCR = 2331.774 HPLI = 1.382 TCCR = 4683.444 OAI = 14.027 SIAI = 6.510 RIC = .498 KIC = .399 HIC = .070 SIIC = .064 CLIC = .020 CAIC = .003 FEIC = .086 SIC = .092 FERC = 2.338 TMDS = 15.148 TENS = 2046.439 TEMP = 24.300 DEPT = 9209.000 CCL = 5461.000 GR = 45.211 LIRI = 1.433 COIR = .473 STUN = .009 ITCR = 2280.225 HPLI = 1.453 TCCR = 4205.666 OAI = 1.934 SIAI = 2.870 RIC = .542 KIC = .407 HIC = .087 SIIC = .076 CLIC = .026 CAIC = .002 FEIC = .071 SIC = .084 FERC = 2.368 TMDS = 16.327 TENS = 2619.751 TEMP = 25.300 DEPT = 9109.000 CCL = 5460.000 GR = 44.729 LIRI = 1.311 COIR = .467 STUN = .007 ITCR = 2376.659 HPLI = 1.404 TCCR = 4764.65'7 OAI = 2.028 SIAI = 3.316 RIC = .499 KIC = .389 HIC = .078 SIIC = .076 CLIC = .015 CAIC = .004 FEIC = .083 SIC = .090 FERC = 2.363 TMDS = 12.753 TENS = 2562.420 TEMP = 27.000 DEPT = 9009.000 CCL = 5472.000 GR = 51.663 LIRI = 1.342 COIR = .448 STUN = .009 ITCR = 2412.004 HPLI = 1.378 TCCR = 4886.180 Page 27 OAI = 1.611 SIAI = 3.188 RIC = .494 KIC = .388 HIC = .068 SIIC = .074 CLIC = .014 CAIC = .003 FEIC = .087 SIC = .095 FERC = 2.379 TMDS = 16.029 TENS = 2490.756 TEMP = 28.700 DEPT = 8909.000 CCL = 5462.000 GR = 35.820 LIRI = 1.326 COIR = .463 STUN = .009 ITCR = 2326.327 HPLI = 1.391 TCCR = 4963.090 OAI = 7.907 SIAI = 2.814 RIC = .469 KIC = .393 HIC = .072 SIIC = .078 CLIC = .017 CAIC = .003 FEIC = .081 SIC = .093 FERC = 2.321 TMDS = 12.083 TENS = 2462.090 TEMP = 30.000 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --- 92/09/04 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** . . FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.010 --- 92/09/04 --- 1024 --- LO --- COMCEN.009 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 04 DEPTH INCREMENT: 0.2500 '- FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 9309.5 8898.0 $ Page 28 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 12-JUL-92 2.23 2020 12-JUL-92 9335.0 9310.0 8888.0 9310.5 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-A $ 114434S 008 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 9335.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 8.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #4. $ LIS FORMAT DATA Page 29 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 I 66 0 2 I 66 0 3 2 79 92 4 i 66 1 5 I 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE# SIZE #SAMP REPR. DEPT F 00000000 0 4 i 68 COL PSGT 847222 MV 00000000 0 4 1 68 GR PSGT 847222 GAPI 00000000 0 4 1 68 LIRI PSGT 847222 00000000 0 4 1 68 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 ITCR PSGT 847222 00000000 0 4 1 68 HPLI PSGT 847222 00000000 0 4 1 68 TCCR PSGT 847222 00000000 0 4 1 68 OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 1 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 i 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 i 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9309.500 CCL = 5461.000 GR = 46.686 LIRI = 1.380 COIR = .471 STUN = .004 ITCR = 1421.050 HPLI = 1.390 TCCR = 2943.082 OAI = 4.647 SIAI = 4.542 RIC = .483 KIC = .390 HIC = .069 SIIC = .071 CLIC = .018 CAIC = .002 FEIC = .090 SIC = .090 FERC = 2.175 TMDS = 11.095 Page 30 TENS = 2046.439 TEMP = 30.600 DEPT = 9209.500 CCL = 5467.000 GR = 48.951 LIRI = 1.374 COIR = .458 STUN = .009 ITCR = 2194.773 HPLI = 1.444 TCCR = 4109.158 OAI = 1.310 SIAI = 2.788 RIC = .534 KIC = .405 HIC = .086 $IIC = .076 CLIC = .024 CAIC = .003 FEIC = .072 SIC = .084 FERC = 2.396 TMDS = 18.577 TENS = 2533.754 TEMP = 31.400 DEPT = 9109.500 CCL = 5464.000 GR = 51.426 LIRI = 1.319 COIR = .458 STUN = .007 ITCR = 2349.087 HPLI = 1 390 TCCR = 4701.716 OAI = 2.139 SIAI = 3.592 RIC = .500 KIC = .389 HIC = .078 SIIC = .075 CLIC = .015 CAIC = .003 FEIC = .082 SIC = .090 FERC = 2.407 TMDS = 13.497 TENS = 2447.758 TEMP = 32.600 DEPT = 9009.500 CCL = 5453.000 GR = 59.329 LIRI = 1.356 COIR = .462 STUN = .009 ITCR = 2284.686 HPLI = 1.345 TCCR = 4586.965 OAI = 1.158 SIAI = 3.203 RIC = .498 KIC = .387 HIC = .070 SIIC = .071 CLIC = .015 CAIC = .004 FEIC = .087 SIC = .093 FERC = 2.416 TMDS = 16.244 TENS = 2433.425 TEMP = 33.800 DEPT = 8909.500 CCL = 5466.000 GR = 45.547 LIRI = 1.370 COIR = .474 STUN = .009 ITCR = 2299.919 HPLI = 1.396 TCCR = 4720.141 OAI = 8.262 SIAI = 3.657 RIC = .487 KIC = .391 HIC = .071 SIIC = .075 CLIC = .018 CAIC = .002 FEIC = .084 SIC = .091 FERC = 2.294 TMDS = 13.291 TENS = 2390.426 TEMP = 34.700 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.010 tmm 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.011 FILE HEADER RECORD TYPE 128 --- r C E !'V E ~-,,'-- ~ (3 ~ i992 Page 31 Ancfforage: SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME ------ 0 --- 92~09/04 --- 1024 --- LO --- COMCEN.010 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 05 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 9309.5 8889.0 12-JUL-92 2.23 2020 12-JUL-92 9335.0 9310.0 8888.0 9310.5 300.0 NO TOOL NUMBER GR NGRT-A PSGT PSGT-A $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): 114434S 008 8.500 9335.0 PRODUCED Page 32 GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 8.5O0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 0.0 REMARKS: THIS FILE CONTAINS RAW DATA FOR PASS #5. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 1 66 0 2 1 66 0 3 2 79 92 4 1 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 11 12 4 68 -999.000 14 4 65 F 15 1 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS DEPT F CCL PSGT 847222 GR PSGT 847222 LIRI PSGT 847222 COIR PSGT 847222 STUN PSGT 847222 ITCR PSGT 847222 HPLI PSGT 847222 TCCR PSGT 847222 MV GAPI API CODE FILE~ SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 ~SAMP REPR. 1 68 i 68 1 68 I 68 I 68 1 68 1 68 RE IVED Page 33 OCT 0 8 1992 Alaska Oil & G~e Cons. Commission Anchorage OAI PSGT 847222 00000000 0 4 1 68 SIAI PSGT 847222 00000000 0 4 1 68 RIC PSGT 847222 00000000 0 4 1 68 KIC PSGT 847222 00000000 0 4 1 68 HIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CLIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 FEIC PSGT 847222 00000000 0 4 1 68 SIC PSGT 847222 00000000 0 4 1 68 FERC PSGT 847222 00000000 0 4 1 68 TMDS PSGT 847222 CU 00000000 0 4 1 68 TENS PSGT 847222 LB 00000000 0 4 1 68 TEMP PSGT 847222 DEGC 00000000 0 4 1 68 DATA RECORD TYPE 0 DEPT = 9309.500 CCL = 5461.000 GR = 66.541 LIRI = 1.341 COIR = .469 STUN = .006 ITCR = 2261.665 HPLI = 1.350 TCCR = 4474.697 OAI = 22.474 SIAI = 12.227 RIC = .505 KIC = .390 HIC = .076 $IIC = .072 CLIC = .020 CAIC = -.001 FEIC = .085 SIC = .094 FERC = 2.372 TMDS = 29.756 TENS = 2046.439 TEMP = 39.000 DEPT = 9209.500 CCL = 5463.000 GR = 42.956 LIRI = 1.375 COIR = .467 STUN = .010 ITCR = 2108.208 HPLI = 1.396 TCCR = 4030.401 OAI = 1.375 SIAI = 2.744 RIC = .523 KIC = .407 HIC = .087 SIIC = .075 CLIC = .024 CAIC = .002 FEIC = .072 SIC = .086 FERC = 2.369 TMDS = 16.794 TENS = 2519.421 TEMP = 39.700 DEPT = 9109.500 CCL = 5485.000 GR = 47.649 LIRI = 1.325 COIR = .443 STUN = .007 ITCR = 2337.718 HPLI = 1.406 TCCR = 4636.840 OAI = 2.030 SIAI = 2.854 RIC = .504 KIC = .389 HIC = .077 SIIC = .075 CLIC = .015 CAIC = .003 FEIC = .083 SIC = .090 FERC = 2.372 TMDS = 14.438 TENS = 2462.090 TEMP = 40.500 DEPT = 9009.500 CCL = 5461.000 GR = 61.842 LIRI = 1.280 COIR = .464 STUN = .010 ITCR = 2346.491 HPLI = 1.365 TCCR = 4516.401 OAI = 1.418 SIAI = 3.567 RIC = .520 KIC = .386 HIC = .073 SIIC = .071 CLIC = .014 CAIC = .004 FEIC = .086 SIC = .092 FERC = 2.460 TMDS = 15.486 TENS = 2404.759 TEMP = 41.100 Page 34 DEPT = 8909.500 CCL = 5460.000 GR = 37.034 LIRI = 1.347 COIR = .458 STUN = .010 ITCR = 2195.806 HPLI = 1.374 TCCR = 4540.276 OAI = 4.255 SIAI = 3.031 RIC = .484 KIC = .393 HIC = .072 SIIC = .072 CLIC = .020 CAIC = .003 FEIC = .084 SIC = .094 FERC = 2.310 TMDS = 13.331 TENS = 2390.426 TEMP = 41.700 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.Oll --- 92/09/04 --- 1024 --- LO --- COMCEN.012 FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.012 s~t 0 --- 92/09/04 --- 1024 --- LO --- COMCEN.011 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 12 STATIONS & COMPUTED RESULTS DEPTH INCREMENT 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PSGT 9309.0 8900.0 $ H.L.S. PULSED SPECTRAL GAMMA STATION SUMMARY STATION #1 STATION #2 STATION #3 STATION #4 STATION #5 STATION #6 ( 9293.50): ( 9268.50): ( 9217.50): ( 9192.50): ( 9127.00): ( 9096.00): TAKEN AFTER LOGGING PASS #4 TAKEN AFTER LOGGING PASS #4 TAKEN AFTER LOGGING PASS #4 TAKEN AFTER LOGGING PASS #4 TAKEN AFTER LOGGING PASS #4 TAKEN AFTER LOGGING PASS #4 Page 35 STATION* LIRI DEV * COIR DEV * RIC DEV * KIC DEV * HIC DEV · ............ *---- * ............ * ............ * ............ 9293.50* 1.346 .0121' .4524 .0097* .5115 .0027* .3907 .0016' .0798 .0010 9268.50* 1.320 .0205* .4549 .0090* .5171 .0029* .3936 .0014' .0755 .0010 9217.50' 1.386 .0137' .4659 .0100' .5285 .0027* .3992 .0013' .0863 .0012 9192.50' 1.393 .0174' .4987 .0151' .5330 .0036* .3991 .0019' .0913 .0010 9127.00' 1.331 .0176' .4593 .0093* .4942 .0024* .3893 .0014' .0761 .0011 9096.00* 1.319 .0156' .4495 .0110' .4931 .0016' .3913 .0014' .0771 .0010 STATION* SIIC DEV * CLIC- DEV * CAIC DEV * FEIC DEV * SIC DEV .-- * ............ * ............ * ............ * ............ * ............ 9293.50* .0692 .0012' .0166 .0020* .0022 .0012 .0850 .0005* .0874 .0012 9268.50* .0726 .0015' .0176 .0023* .0024 .0012' .0831 .0009* .0898 .0019 9217.50' .0755 .0010' .0178 .0015' .0034 .0010' .0763 .0006* .0848 .0014 9192.50' .0773 .0009* .0188 .0030* .0029 .0011' .0743 .0010' .0831 .0018 9127.00' .0734 .0009* .0150 .0017' .0030 .0007* .0848 .0005* .0900 .0007 9096.00* .0783 .0010' .0153 .0020* .0033 .0010' .0813 .0004* .0887 .0016 THIS FILE CONTAINS COMPUTED RESULTS FOR: VSH - SHALE VOLUME SOIL - CASED HOLE OIL SATURATION PHSO - CASED HOLE BULK VOUME OIL PHSW - OPEN HOLE BULK VOLUME WATER SPHI - SONIC POROSITY = (OHDT-55.0)/(189.0-55.0) PHIE - EFFECTIVE POROSITY = SPHI*(1.0 - VSH)) ALSO INCLUDED IS OPEN HOLE DATA PROVIDED BY BP EXP.: OHGR - OPEN HOLE GAMMA RAY OHDT - OPEN HOLE SONIC OHSW - OPEN HOLE WATER SATURATION AVERAGE OF PASS #1 - #5 USED FOR COMPUTATIONS. OPEN HOLE GAMMA RAY & SONIC POROSITY USED TO COMPUTE VSH & PHIE. OPEN HOLE DATA HAS BEEN INTERPOLATED FROM 1 SAMPLE/FT. TO 4 SAMPLES/FT. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY 1 I 66 0 2 1 66 0 3 2 79 68 4 I 66 1 5 1 66 1 8 4 73 30 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 Page 36 14 4 65 F 15 1 66 68 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ SIZE SSAMP REPR. DEPT F 00000000 0 4 I 68 OHGR OH 847222 GAPI 00000000 0 4 I 68 OHDT OH 847222 US/F 00000000 0 4 1 68 OHSW OH 847222 % 00000000 0 4 i 68 VSH CHARM 847222 % 00000000 0 4 1 68 SOIL CHARM 847222 % 00000000 0 4 1 68 PHSO CHARM 847222 % 00000000 0 4 I 68 PHSW CHARM' 847222 % 00000000 0 4 1 68 SPNI CHARM 847222 % 00000000 0 4 1 68 PHIE CHARM 847222 % 00000000 0 4 1 68 GR PSGT 847222 GAPI 00000000 0 4 I 68 LIRI PSGT 847222 00000000 0 4 1 68 COIR PSGT 847222 00000000 0 4 1 68 STUN PSGT 847222 00000000 0 4 1 68 RIC PSGT 847222 00000000 0 4 1 68 SIIC PSGT 847222 00000000 0 4 1 68 CAIC PSGT 847222 00000000 0 4 1 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9309.000 OHGR = 12.961 OHDT = 89.125 OHSW = 1.000 VSH = .006 SOIL = .910 PHSO = .023 PHSW = .023 SPHI = .255 PHIE = .253 GR = 17.709 LIRI = 1.309 COIR = .507 STUN = .017 RIC = .515 SIIC = .070 CAIC = .000 DEPT = 9209.000 OHGR = 26.078 OHDT = 93.000 OHSW = .615 VSH = .094 SOIL = .246 PHSO = .194 PHSW = .158 SPNI = .284 PHIE = .257 GR = 33.011 LIRI = 1.391 COIR = .469 STUN = .009 RIC = .535 SIIC = .076 CAIC = .003 DEPT = 9109.000 OHGR = 19.703 OHDT = 80.625 OHSW = .665 VSH = .048 SOIL = .131 PHSO = .158 PHSW = .121 SPHI = .191 PHIE = .182 GR = 21.744 LIRI = 1.325 COIR = .451 STUN = .007 RIC = .501 SIIC = .076 CAIC = .004 DEPT = 9009.000 OHGR = 32.688 OHDT = OHSW = .565 VSH = .147 SOIL = PHSO = .060 PHSW = .060 SPHI = PHIE = .111 GR = 35.791 LIRI = Page 37 72.375 1.335 0 8 992 Alaska Oil & GaS C~ons. (~ommismon Anchorage COIR = .467 STUN = .009 RIC = .496 SIIC = .072 CAIC = .003 DEPT = 8909.000 OHGR = 22.422 OHDT = 91.844 OHSW = .241 VSH = .067 SOIL = .383 PHSO = .158 PHSW = .062 SPHI = .275 PHIE = .256 GR = 22.081 LIRI = 1.323 COIR = .466 STUN = .009 RIC = .459 SIIC = .080 CAIC = .003 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.012 --- 92/09/04 --- 1024 --- LO ****************************************************************************** TAPE TRAILER RECORD TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME COMMENTS: --- COMCEN --- 92/09/04 --- ANCH ****************************************************************************** REEL TRAILER RECORD TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS: --- COMCEN -~- 92/09/04 --- ANCH --- 847222 ****************************************************************************** END OF TAPE ENCOUNTERED Page 38 RECEIVED APR 2 4 1992 Alaska 011 & Gas Cons. Commission Anchorage .,~$ ",'ep..e ver.i~tcatJon ~,istino ;chlum~".erg~r. ,llaska Co~tT, utJ. r,q Center D/~TP' : g2/0.4t 7 OP IGi r<~ : F'b/C 'I/XF'F r:A~,lt';': ,' ~2232 PPgVlOdS TAPE : (".O.q?,'g~T : BP F;XPI.,[iRA~F![:ti,PRUDHE'E bAY,A-34A,SO-029-21339IO0 .I.: A p E t~ E A 1) F, P TAP~ CREATION ODE;DAT[)R. w]l', 8 U P F A. C E l, C) C A SECTIO~i: t.) E R R i C K (; R 0 l.t wgl,~!, CA,S.ICG q !ST STRI~tG 3Rb l;: A' [':'~ [.~ ti C T I O N $ T R ! ~i,! (; A- 3,-1: A 5()02921339 BP EXFLORATIOi'.! $CNLtIi;'~BERGER .!:~¢EL[.., SgRVICE8 7 -APl<-92 92232 JACK FATHERT CR Ai~' FOR D / ixt[",TA 1, 1172 92,1. '7~. 7U 4'9.30 N 14'0 t., ..... '" I (., ~'. r ( !,, B / F T ) S J,' Z }~] ( .... . .................... 250 9,625 8770, 47, ,),) ,P,,, 5 f') o 7,000 9382 · n 26.00 PAGE: .I.S ?'a~e Ver.~flcatJon Li. stj. na chlurr~L~e.rc~e.r AlasKa Comc, utinq Cent. er ......... ...... 9164.5 9162,0 9~63.5 9061 ,5 9061 .0 {)060,5 9059. C n020.O 901 9009.0 900~. 0 9~05.5 gO04. () ~970.0 8969.0 8969,5 8969, C) 8966.0 ~964,5 8957,5 8{~56. {) 8952,5 8952,0 8944,0 89~. 0 8938,5 8~)40,0 A927.0 8928,5 801 ?" 5 8915.0 8867,5 8869.0 g836.0 8838.0 8828,5 g830,5 ~806 0 8B08,0 ! 00,0 1,01,5 ! 01,, 5 .........- FOl!IVALEF~7' .... '!F!SHIb'~'MJ. ,1') [;E.[.'~'".~t~---------- PAGE: SFPV IC[:i : FI,lC VFRSIO~',: : t')a~.!'~ : 92/04/ 7 F'I I,E TYPE LaBq: FILE : EDI TE;[~ CURVES Pe;:,tn s~i,~t:ed and cl, J,p~ed curves roi each pass i.n scoarate files, Pi'!U TOO!,, CODE START DEPTH S'J,"OP DEPTH .... ~75~'~"' ...... ... ..... ;;;;~; .... (; R (' H * T ~,.> T P 9 1 8 9 . f) 8 7 5 0 . 0 C RV}~;', StilF'T aTa ASS TO PAS;5(;~,":EI, S~'f~[';D DEPTH) SH DEPTt4.. · , - .. ,, - - - - ,, - E !21,t i V ,h L E; l',t' T U ',1 2~ F T E ,Is '].ave veri. iic~.:tiov l,jst:.in~ .chlu~:t:erger n.!as~:a Ca.,~[~utin~ Cer',ter 7- a FR,..1. 997 !2:4,4 PAGE .1. 66 0 2 66 3 73 5 66. 6 73 7 65 8 68 0.5 9 65 FT 1~ 66 1.2 12 68 ! 3 66 14 65 FI" 15 66 6.8 16 66 1 0 66 o SET i.,:IT . RV!C[: A.P API ¢ FILE N U~q ROCF, S. DEP'1' p,r a25243 oo 0o0 oo (:, I 1 1 4 68 S 1 (; ~,~ '.r D q" P C .J 4:2524. 3 00 000 0 O b 1. 1 1 4 68 TPHI TDTP PU 425243 0() OOO O0 0 1 1 1 4 6~ $ B i~ [~ T D T P C U 425243 00 (~ 00 00 ('~ 1 I 1 4 68 $ B ~ ~,,~ T D 7' P C U 425243 00 0 (.> 0 00 (; 1 1 1, 4 68 61., f P C b 4. 25243 00 (~ (.) 000 0 1, 1 1. 4 ~ 8 SIBH TDTP CU a, 25243 00 000 O0 0 1. 1 I 4 68 T R A 'r 'r t.) T p 4; 25243 00 (') 00 00 0 1 1. 1. 4 68 s [) s I ? D T P C ~ 425 ~ 43 (), 0 00 O 0 O 0 1. 1 1 4 68 ~'~ ,~ C K T D T P C P S 425243 0 o o (, 0 00 0 1 1 l. 4 68 F¢A.C TDTP CPS 4.25243 00 000 00 0 I. 1 1 4 68 T C A ~x~ T O T P C P $ ~ 25243 00 000 00 {',, 1 1 1 4 6 ~ T C p, F~P [> T P C P S 4:25243 00 000 00 0 I I I 4 68 T C 1'~ r~ t'(' D T P C P $ 4252.43 00 000 00 0 I, 1 1 4 68 T C ~" F, 70 T P C P S ,425243 00 000 00 0 I, I 1 4 68 T S C't~' T D T P C P S 425243 C, 0 000 00 0 !, 1 I 4 68 TSC[' TDTP CPS 425243 00 000 00 O I 1 1, 4 68 ! ~,~ a D T [7~ T P C P S 4. 25243 00 000 00 0 ! 1 1 4 68 I~Fr) TDTP CPS 425243 00 000 O0 0 1. 1 1 4 68 G~'C'~4 TOTP GAPI 4252.43 O0 0o0 o0 (.) ! I. i 4 68 T~(;AtS TDTP LB 4252.43 00 000 00 0 I 1 I 4 68 000 (it 000000 0000000000 0000000000 000000000o 0000000000 0000000000 0000o00000 0000000000 0000000000 0(t00000000 0000000000 0~)00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00o0000000 0000000000 DATA Verification !..i. $ t, lr~q ichl,]~eraer Alaska Co,r.!2utin~ Center PA(" [' K ? ...... ~' ~ I's .9 003 $ J'- G ~"'!. 'J i':, T P i 2.93 ~ T P H I . ,r .... .,, .-r.p lq. S~t~r'. ~TF 42.~2 S~GC.~¥)TP 1. 194 S~H.TDT~ 43.502 SD~I wi)~p 0.402 ~ACK.'i~F,~.'P 2~.489 Fi~AC.'i_'DTP ?.438 TCAF.TOTP 1~/0~4.551 TCt,~O. TD~P 16315.352 TCFO. ']'DTP 5686,389 TSCF. T[>TP 22~,4.~05 I ?~ ~t',. TDq'P 1056. 102 I ~'IF[~. Tf)TP 232.799 TF;.=,S. T'qTP 1. 315.00(',, ['_,Ft':.T. 90',qt,'. t~ 0~_~ $ i G;"~. TI')TP 1 ! .546 TPbI. i'[,:.t'P 16.628 S~rlt'.Ti','1,'P. .,_ a7 . ~.414. SIGC.TD'/'P. O. q25. $IBH.'?O~'P..-, 52.242 ,SDST. T0"rF 0.312 B,~CK. TD'i'P 42.1.45 FBAC. 'I'Oi'? 10.180 T C' A l'". 7 D T P 130 ? 0. t.} 00 T C N r.',. T 0 T P I t5784,, o (: 0 :I' C F f.,. 'i' P T P 54:8 a. 7 $ 0 TSCF.TOTP 2789.756 TFt.,S. TPTP 1.292.281 hFpT. ~750.00(~ S I. (?',,~:. '.I' [~ T p 4.4.7i8 q'F'H! o TOTP 66.9a5 8 P~ ~,~,". !'i~T P 57.019 S.i C,C. TDTP 0.,.553 SI B~i.'iTDTP 76.900 SD~I'. 'ri.',TP 1..70! BACK. TI.~TP 03.066 FBAC. '.I'DTP 12.247 TCAP.T!~TP ~252.0~9 TC ~'~ [,). TI',TP 8305.89;3 TCFO.TI)TP 18i~a.320 ~SCF. TlbWP 1~6.542 l ?,~N O. T[>'j'P 10(>6. 334 I i'.~ F f.). TDTP 174.422 TFh,~S. ~[)TP 1235.000 o." B i~ F o T 0 T P 70. AT.TOTP TCI,~,!. TbTP ,'!.'S C N. TOTP G[~CH. TDTP 5BHF. TI)TP ",rRb T . TDTP TCAk:. Ti)TP TSCh~. TDTP GRCH. TDTP 35.180 2.i25 22639.590 4791.393 -999.250 37.961 1.933 251.68.00(3 5392.500 25.0!6 3.664 13240.137 683,511 37.813 !.~X ~EC SIZE F I L ~ T :t P E LaST FILE and C l i. p, ,o e e'~ 2 0,5 0 0 '[) cttrves f or each pass irt separate files. ,1S 'rspe' Ver~.icat.ion Listina ;ChlOmberqer Alaska Cou~,ut. inq Cer~r. er t~ START DiE P'Y~ q199.0 T ~ T D $ PBU Ci.J~I~E CrlOF: GRCH 9163,0 9~1.63,5 9164,5 9~.~ 3,5 9114,5 91 J, 2. r~ 9:1. 13.5 90,q .1.. 0 00.~ 2.0 ~oho. 5 9061.5 9040.5 9(),~,!. 5 Q.,(~37,5 903~,. 5 ~965, C, 8966. () 6'964,5 8965.5 88q,1,0 8892.0 8B52.5 ~53.5 8839,5 8940. $ 88o2,5 8~03.5 100,0 101.0 10f,0 875,. ~750.5 ~'[S 7are. t'erlf~cation ~is.tlnu cblu~'erqer AlasKa CO,T, Out~nG Le ter 7-A[:'R-1".]92 1 2: PAGE C t:~ 4 '252 P t) 4252 C~]~ 4 ,~"'52 CU CU C L.i C P $ CPS CPS (,'.PS CPS CPS CPC~ CPS C PS G A P I ** I AP1 I F TYPE CLASS MOD W I l, ['] N U M , N tt M R, E P R R ,'....! M a S A M P g b E a C 0 D E ( H E X ) .1 1 4 6B 0000000000 1 1 4 ~8 0000000000 ! 1 4 OH 0()00000000 1 1. ..i 68 000000 0000 .!. 1 4 68 0000000000 1. 1, 4 6 R 00000000 (1. 0 1. I. 4 68 (;000000000 1 !, 4 o 8 0000000000 1 1 4 68 0000000000 1. 1. 4 6 8 C, 0 (.) 0000000 1 1. 4 68 0000000000 1 'I. 4 68 0000000000 1 1, 4 68 0000000000 1 1 4 68 0000000000 1 1. 4 68. O0000000OO .11, 1 4 68 0000000000 1, 1 4 68 0000000000 1. 1. 4 68 0000000000 1 1 4 68 0000000000 1. I 4 6 8 0000000000 , * [:, A T A * * 31.1.43 2,204 23650.641 4902,21.8 -999.2,5() Tape Ver~.f~cation I.;j. st. ir~o ;c~luf~,t~er~er h].aska Come>or.in~ Center 7-,~\FP 1992 1 '~ - ,,.:4,4 PAGE I_'.:F PT, R750. bO('~ S I G.,','i, T£:TP SB~'~N. TF'TP 5.~I. 357 SIC, C, TI>TP SDS T ,'r[~Tp 1.7 ~ CA~'. T[>~P 3286.~2~ TCNi). T[~TP TSCF. TDTP 17g. 130 I~,:~,~D. TC~TP TF,': S. TPrP 1265. 11.2'~ l TPFt!.'i~o'rp 17. 235 1 .OeO SI B¼. T. [-'TP 54.994 77 118 F~C,TD'q'P 16. 273 1693B~438 TCF'D,TDTP 6438.875 128.344 I ~F[',, TDTP 245.328 46 ' ~ 1 ,~ l T p H !. T O T P 6 g. 732 0. ()C'O SIB?i. TDTP 69.499 ~6.044 FP.~A C. T[~TP !,7.293 %~777.4°9 q'CFD.TDTP 2036.900 1114.012 I~F0,TDTP 196.7~0 S6hF. TI.)TP TRA?. TDTP TCA~,I. TDTP TSC,~. GRCP~ .TOTP SBPF.TDTP TRAT.TOT'P TCA~. TOTP T S C ~'.~ .TDTP GRCH. TOTP 38.899 1,954 26493 500 5448:750 36.219 57,956 3,957 13324,676 704 865 42~g38 **** FILE TkA I [,E:t; **** F.ILF ~',~qE : EDiT .002 SERVICE : FLIC [:~AT~ : 92104/ 7 FILE TYPE : .L~} LAST FILE : ~, I,,; U ~',,! 5 E F:: 3 TEn CUR'VE$ Depth shiftec~ and cl, J. ppe~ curves , T A R T 9156' 91 ~ 9 , each pass ,,, [! t:, 0E'P T ~"'! ~ 51.5 8751.5 separate files, · ,IS 7ap...e Vei-iftcatJen !,:.i. stir.,n ;¢hlUm!~er~er Alask~ ¢:o,',~-uti.~ Cer~t..er ~:,'hSE[.,.!~il:;. Cl.i.~Vf:; Fflk PFU C'.IaI:F; (.'Of~F; .......... E {...! U I V A 1, k. f,i 7 9162.5 9!.63.5 91fi4,0 ~1.12,0 9113.5 906o. 0 9061,0 9n54,5 9056.5 9049,5 ~050,5 9010,5 901 2,0 9~5i) 4.0 90D5.5 a990,5 g991.5 ~96a. 5 f~970.0 S964.0 a965.5 ~t954,5 g 957,5 g950.5 ~ ~52.5 8911,5 ggl 3,0 ~903,0 ~ 904,5 ag70.O ~7~1 ,5 6826.5 88~8.0 100,0 101.5 101 . 5 PASS. TkI< DEPT SET T,t'Pe.'.;- 64~iB ~g q.' Y P E: REP {':~ COi)E .......... V A i, {.l 1 66 0 2 66 0 3 73 d 66 i 5 66 6 73 7 65 8 68 0.5 .IS q'at~e Veri. i~icet.~on Listina .ch] umberger ,'~leska Coir, ptlt:inq Center 7-APU-I992 12i 10 IImII~II[III#It~I II mi IImIIl/I! · ~' Y P E R E P P C O t.:, ~': v A !.., U E: 1.1 66 12 15 66 0 66 1 I III Im m m ID [.:J~[)ER ~- bog TYPE CLUBS F 7' 4:2, S 243 TDTP C~] 425243 TDTP .P!; 425243 'f D T P C b 4:25243 T DTP Cu 4,25243 T D T P C U a 2524. 3 T O T P C l:' 425243 T f) T P 4. 252 ~ 3 TOTP Ci,i 425243 T D T P C [-' 8 ~'a 25 ~'~ 43 TDTP CPS 4252~3 T [') q' P C P 8 425243 ? f) T P C P 8 4. 252,43 1t) TP CP8 425243 TPTP CPS a:2524,3 T D T P C P S 4, 2 5 2 4 3 T 0 T P C P 5 4. 25243 T J:) T P C P S .~ 252.43 t P T P C P S 4. 2524 ] T [:) T P G A p :l. a~ 25243 :'i' I') T P b 17, 425243 .1 i 4 68 0 I.~ 000000 i.) 0 ! I 4 08 0000000000 1 1 4 68 0000000000 1 1 4 68 Ot) oO000000 1. I 4 68 00 f) 0000000 I 1 4 68 ()000000000 1. 1 4 68 000000000O 1.. ]. 4 68 0000 o 0 o 000 1 I 4 68 0000000000 1 1 4 68 0000000000 i .t .4 68 0 o 00000000 I 1, 4 68 0 t) 000 o 0000 l I ~ 6a OO00000000 I I 4 68 0o00000000 1, 1, 4, 68 0 0 0 0 0 0 0 0 0 0 1 1 4 68 0000000000 1 i 4 68 OOOO000000 I 1 4 68 0000000000 i 1. 4. 68 00o0000000 i. I 4 68 O0OOOO0000 !. I /4 68 0000000000 D E p .'l.?. $ B t4 r,!. q" O T P ,S D S l. T t') T P T C A P, f!.' D 'T P 'I:'SCF, T t?,T P 22,869 SBHF,.TOTP "hq', 4, 4.979 'l B: ...... T l,') T P . I ..... Af'~.'IDTP 25,860 5412.259 ~.8C. ,~.L1 239,612 GRCH,TDTP 36,414 2,256 24?72 059 4801:726 -999,250 34,912 1.939 26998,844 5427,395 40,922 ~I$ ~at)e Verittcat, ion [,isti~a ;ChlUn':~:er<~er !~l. aska Comput, it'~o Center 129I 7-^P~:- !. 97~? 12:44 S~ ~ r'~. Ti)~P ~o. 62'7 S!~C, 'F[,TP 0.000 SIBH.'f~TP al ..455 TRA I~.TDTP SPSl. 7'D'PP 1.~44 SiiCi<. q'B'~P 100.59~ FBAC.'I'DTP 21.166 TC~N.TOTP TCAF'.~OTP 3033.992 'rC~9~.'?r~TP 8492.357 ?CFO. TOTP !935.094 TSCN,. TL)TP TSCF.TDTP 168.633 I Wr,~ O. T f'.,?P 1024.440 IPFD. T[';TP 174.7()7 TF~V,S. T,')TP J 265,000 P~GE: 52.192 4.126 12760.311 695.857 52.219 1.1 **** FII,F' ?' R l',, .f [, EI~ **** [)~'r~ : 92/o4/ 7 **** FILE SERVICE : Fb!C VERSIO}',~! : 001~07 'DtTF' M~X RF:C SIZE : 1024 FII,,E TY'DE; I,,~, ST FILM 'l:' 0 T P $ # C I.] 1.?. v t.: g :.i I ? 7' D A :1::' a r'~ d c 11 'o ~,.~ e d 4 0.5000 curves for STOP DEPTH 8753.5 D g P T H ) .I$ Tac'.e 'vetj. f:~eation '7-~i::'R-!,gq2 '!2:44 9160.5 ~C;5~I. 5 g06! 9043. g()(;5.5 gOO9 g 002. 8gR3.~ gggs.5 Rg64,5 [~Q67 89 !0. O ~9! 3 ~889,0 g~613.0 886a.5 8867,5 ~$53, C) 8856 g~02.5 8 g 00,5 ~ 8 ('., 3 8766,0 g769 1. (} 0.0 I 03 88891 .5 9! 64,.q 9114.0 9019.5 9005.5 8967.5 8847.0 8805,5 103.5 THIS F.!'I,,E COi',:IT:,.%It'~,S THE: F'IRST BORAX, PreSS. THE DEPTF~ ADJUSTt':;!E?'i~'TS SHOW?,; ABOVE REFLECT P~88 4 GRCH TO PASS GRCi,4 A~qi) PhS8 4 8]:G~ TL) PASS 1 S PAGg: 1.2 F'ORiqAT 8PECIiF"ICA:I'ION REC(3RD ** .,]ES 'ra~,e '~]el:'ifi.¢at.!..on !'..,istin~ '7-APR-:1992 ;ch].t]~t:erqer A].~sKa Com.L:,t~t. inq Cent:er PAGE: 1.3 13 66 0 ~4 65 FT 15 66 '16 66 0 66 I emlmmmmmmlemmmmmmmmmmm~mmmm~mm ** SET TYPE - Ct-!AN ~mmmmmmmmm mm I m m ~,m ..,mmmmmmem mm mmmm/i mm mmmmmmmem m ieim !.D OR[)ER ~ b[)G TYPE CLAS~; ~',UD N'!.J~.5 8~.NIp EbE~ C~]OE (HEX) mmmmm~m~m~mmm~m~mmm~mmmmmm~mmm~mmmmm#mmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmm#mmmmmmmmm~m~mmmmmm~mm STG~,' 'r~'rp Cml 42.5243 oo 000 O0 O 4 1 I 4 68 DO00000000 TDNT 'rDTP PI.l 425243 O0 c)00 O0 0 4 1 1 4 68 0000000000 S~HF ?DTP CI~ 425243 OO 000 O0 0 4. 1. I 4 68 0000000000 8~!4~ TtoTP CU 425243 OO 000 O0 0 4 ~ 1 4 6~ 000oo00000 S!GC T()TP CU 425243 Oo o0(> O0 0 4 1 I 4 68 0000000000 STB~ TDTP Ct] 425243 oo 000 O0 0 4 1, I 4 68 O00OO00000 TPA'r 5'OTP 425243 00 000 O0 0 4 1 i 4 68 fi000000000 SDSl ~'U'? P CU 425243 O0 000 O0 0 4 1 I 4 68 O000000OO0 B ~ C ~ T L} '!, P C P S 425 ~2 ~ 3 00 000 00 0 4 1. 1. 4 68 0000000000 F[3AC TDTP CPS 425243 O0 O00 O0 0 4 1 l 4 68 O000000000 TCAN TDTP CPS 425243 O0 000 O0 0 4 1 1 4 68 0000000000 "rCAF TDTP CPS 425243 O0 ()OO O0 0 4 1. I 4 68 0000000000 TCN9 TDT¢ (:PS 425243 O0 C)O0 O0 0 4 1. 1 ~ 68 0()00000000 TCF~ TDTP CPS 425243 O0 000 O0 O 4 1 I 4 68 0000000000 TSCN' TDTP CPS 425243 O0 000 O0 0 4 1, 1, 4 68 0000000000 TSCF TOmB CPS d, 25243 O0 000 O0 O 4 I 1 4 68 0000000000 5 ~.~ ND TDTP CPS 425243 O0 000 O0 0 4 1 1 4 6~ 000()000000 I~FP TI')? P CPS 425243 O0 000 O0 0 4 ~, I 4 68 0000000000 (;RCI4 TDTP (.;AP~ 425243 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 425243 O0 000 O0 0 4 1 I 4 68 0000000000 * * D A T g * * D~PT. 9()0©.()00 $ ;[.. G ~"i,. T[:)T P 1,4.999 TPHI, T[)TP 1.7.242 SB~'F.TDTP S ~.~ ['{ ',~'!. T l;'.'~ T P 95.234 S I (; C. T [.~ T P 0.09.3 $ J; 5 H, 'r D T P 138.301 T R A T. T D T iF, S D $ !. T D T P 0.427 ~;!~ A C K. T I") T'P 69.957 'F [! A C. T !:)'£ P 15.9 $ 4 T C g, N. T D T P A F. T 0 T P 6375.0 O 0 T C N D T D T P 7,253.750 T C F D. T ..... D'r .P 3125. P 25 T ,.>° (..~ .~,~,~:. T D T P ~C:~" ....... T [,,,"P P 12.47. c>On. . I ~,}NO'. Ti'",TP ......... 1145. '32a ~ ~,: F~:). TDTP 24~ .1, 45 GRCH,. . TDTP 'g g ?~ S. ¢ D'r P 1230,563 40,188 2.200 21700.883 4255,931 '999,250 68.751 1,747 11131.000 21,77.375 37'154 ,IS Tare verification T,iStin~ ichlumberqer Alaska CoI,~putir, o, Center PAGE: 14 [)F:p7. ~753.50r~ .~ 1 C, ,~,". 'r t} T P 44.626 ~PHI.TDTP 71 4!4 ., . ]'~TP 7~ ~355 'rR~T T~T:P SD ~ ~. =' r' T P. ,.I . 922 ~:~ ~ C "~_ , . Tt)TP_.. b~ . ()iQ.. FF~ A C. T pT P. 1 R. 466. :r c A t'.~. T D T P TCAF'. 7'DTP 32~6.338 I'CaD. TF, TP ~;559.98~ TCF[;., TDTP 1996,537 YSC~?.TDTP TSC~'. T91'P ia6.35~: I ~ fqF,. TO'TP I 119.6i, 4 I~FP. TD%'P ~20.51.~ TF' k,S, T[.)mP 1 55.982 3.891 13165.127 725.090 49.938 DAT'F' : 92194/ 7 ~! [,,? TYPE : LLST FILS D~TE: : 92/(),'1/ 7 ~AX RF:C SIZE : :1,924 FIL, F: ?YPE : I,,, I,,,, a S T F 1 I, E : F ]' L E': ~\~ U [,,': B E R: DePth Shifted PASS N'Ut46ER: G F~ C H aqd cl ip'ped 5 0.5 ~:,) 0 ctlrves 9:156 g 1, 8 9.0 for each pass in separate files. ~775,5 8775.5 I') E P 7: H ) U,!'t $t~t I FTED ils 're~e Verification t.;Jst]na ;c.hlt.l~,Der~er ~].aska Cor:l::,.~tinr.~ Center 15 916'2.5 9!64.5 ~I61,5 ql 6.3,5 6112,5 9114,0 9! 12.0 911 ~a60,0 9061.5 9044.5 9046.0 9036.5 o()3~, 9016 5 n020.O 900g:O 9010, 9007.5 On~9.0 900 ~. 5 9005. g9~9,5 ~1991,5 g~r!4.0 g96~,5 8965,5 8Q36,0 8938, ~gl 1.0 g9 1 3.0 8894.0 8896,5 8B90.5 8892. ~5~!,. 0 ~ g56.5 8851.5 8853,5 8826.0 ~:~82~. $ 80:1,. 5 8~03.5 .i., 1 o F' 0 R !",~ A T !) A..t~ A 5 (:;R, CI.t TD PASS ,IS Tape verificatior, List:Jnr~ ch].umberqe~ AlasKa Comptlt. ing Center 7-APR-1992 12'44 !.6 ~III~I",I,I~II.IlIIJIIII~I*II*II ,I, Ill~II II~llII II II .iii II ~IlI II II ** SET 'rY'PK - CHAbi' ~lF SI' ;..J';,llTS.R .CE AP P APl Ii.', ORDEP # LOG TYPD CLA~S P v, p T F 'J:' 425243 00 (~ 00 00 0 5 S.IG~.~ Ti.)TP Ch 425243 O0 000 O0 0 5 TPH~ TDTP PU 425243 0o 000 OO ~ 5 SBHF TDTP CU 425243 O0 000 O0 () 5 STGC 'FI) TP Ct':' 425243 O0 000 00 0 5 ~ I B H T 1) T P C t..~ 42524, 3 0 (.} 900 00 () 5 T R A T T [,.', T P 425243 00 000 00 0 5 "? ~.5243 O0 000 nO 0 5 BACK Tt..)TP CPS 42524,3 00 000 OO 0 5 FBAC TDTP CPS 425243 00 000 00 0 5 TCA~ ~I) TP CPS 4252.43 00 000 00 0 5 T C A r T ~:'.) T P C P S 425243 00 00 o 00 0 5 T C r,.~ l) T D T 'P C P S 425243 00 00 (', 00 0 5 TCf'~ TDTP CPS 425243 00 000 O0 0 5 T: S. C ~',~ TDTP CPS 425243 00 000 T $ C F T r) T P C P S 4252' 43 00 (.') 00 0. 0 0 5 I N ~',~ DT I)T P. C P6 42524, 3 00 00 o 0 O 0 5 I. NFD TDTP CPS 425243 00 000 00 0 5 G~CH TI'.)TP GAP"[ 42524:3 O0 000 O0 0 5 TEt,~$ TDTP L, 8 425243 00 000 00 0 5 1 ! 4 68 OO00000000 I 1 4 68 0000000000 i 1. 4 6S 0000000000 1. 1. 4 68 O000000000 1 1 4 6 8 u ¢) 0 00 (') 0000 ! I 4 68 000 C, (.; 00000 !. ! 4 68 0O00000000 1 I 4 6~. 0o00()00000 1 '.l 4 68 0000000 O 00 1, ! 4 6 8 0 0 0 o () 0 0 0 0 0 !. I 4 68 0000 :n 00000 1 .1 4 68 O000oO0000 1. 1. 4 68 ()000000000 1. 1 4 68 O000000000 1 1, 4 68 0000000000 1 1. 4 68 0000000000 I 1 4 68 0000000000 1. ! 4 68 0000000000 1 1 4 68 0000000000 !. 1, 4. 68 00000OO000 1 1 4 68 0000000000 , * 'C' A T A * * . . t' "' 8H ~ .... T b ,'I ,~ 32,423 TPHI Tt) TP 22.321 o . ' ' ''~ SI. BH, TDTP 51., 282 TRAT. T[.)TP 2,175 .. n'" T . P g g C, 'r L.. I P 18.818 C A. t~. T i)T P 21754 '723 T C F C;, T D T P 5 0 4 5.8 4 9 T 8 C N. T D T.P 4 3 1 5,5 91 I NFt3. TDTP 2 1, 1. 799 (.;RCH.TDTP -999,250 ,IS lar.-,e verif!catJon L,,isttnq f)F:p 'r · 9 t.: 0 0. ,'! 0 ('; SDS~.TDTP o,547 ]'CA F. Ti:;q'p 7665. 1,25 1"Ch~3. ~r~f P TSC~. 7 D'I'P ]. 547.00'J I ;,~'D, 7'D'rP T~r"S. TI:,TP ! 22 I. 563 7-~PP-1992 42,058 TP~;I. TD'¥P 56,796 0.0o0 SIg~..'rorp 54,405 98,365 FBAC,TDTP 21.04.8 11486.039 TCFI]. TD'['P 3002.7U0 99~.697 INFD.TPTP 212.604 GBHF. T!)TP 'YRAT. TDTP TCA t,! TSCN. TDTP G R (: l'.t oTD~P SBI.4F.TDTP I"RaT.TOTP TCA~',i.TDTP TSC~.TDTP GRCH.TOTP PAGE: 43.926 1 734 13289:000 2682. ,300 45,428 39.539 3.537 14239.143 1320.374 60,906 V F .R 8 I, t) ;~,~ : 0 C, 'I A 07 L)ATK : 921o4/ 7 ~qt, X REC SIZE : 1, LAST FiLE and 6 C 1 i, loped 6 0.500() curves "" '"'" EP H o I,AR! D T 9 t 56 0 , ~ . 91. 89 . 0 ior each pass ],n separate 82,'0PL~Pla')' ""':" 8750.0 files ,'IS Tar>e ~erlf.J. catJcn Listing ;chlumberc~er Alaska Com;)ut_~.no, Cente£ 992 ! 2: 44 10 0,0 966,0 904:, 0 892,0 ~28,0 192,0 164' 5 1!4,0 38,5 20,0 9,5 9164.0 ~:~163.5 Sll. 3.5 9113,5 S06~ ,5 9061 9032,5 ~o32,0 9011,0 <,01 ~., 0 9965,5 ~871.5 8871.5 9 t) 4.0 S92.0 828.5 192,5 ].64.5 114.5 100.0 39,0 0,0 P K S: 'r' H I. $ F i L E' C 0 ~"':.~ 7' .~ I.... ~', $' T H. E; T D T' P THE DEPT'~4 TO PhSb 1 GRCH D~.;PTH ) i;ix:SHTF rED L'~FPT H .......... PASS 3 HRS POST ABOVE REFLECT PASS 6 GRCI. t ~ilO~ TfJ P/~SS 1 SIG~4, P AGE: ,IS ;chlu~nberger AlasKa ComputJnq Center 7"hFR-1902 12:44 P A G ~: lq $* 55([ TYPE - CHAN T . ,. ' II) ORDER ~ LOG TYPE CLASS I) ~:P'l" FT 425243 O0 0o0 O0 6 SIG ~.~ TDTP CD 425243 O0 OOO O0 0 TPH! Tr3TP pl..~ 425243 O0 0~10 O0 0 SBHF 'TDTP Ct.~ ~25243 O0 000 O0 0 $ ~ H ~',~: TDTP Cb 425243 O0 000 O0 SIGC TI3TP CU 425243 O0 000 O0 0 SI61q TDTP CU 425243 O0 000 O0 0 TRA,i' TE) TP 425243 O0 i) O0 O0 0 81951 TDTP CU 425243 00 000 00 0 6ACK TDTP CPS 42524] O0 000 00 FBAC q.,'D T P CPS 4252~3 00 000 00 0 T C ~ ~ T [)'.P P C P 8 4, 252,43 00 000 00 0 TC.aP TDTP CFS 425243 O0 000' O0 0 TCNP, TDTP CPS ,425243 00 000 00 0 TCFD TDTP CPS 425243 O0 000 O0 0 TSCP TDTP CPG 425243 O0 000 O0 0 INND TDTP CPS 425243 O0 000 O0 0 I. NFr> TDTP CPS 425243 O0 000 O0 0 GRCS~ TDTP Cg, PI 4:25243 O0 000 O0 0 T r.': ~,~ s T D q,' P h B 425243 00 000 00 0 mmllllllm lelmllmlmmlmmmlmmmll ml mlmmlmllmlmlm mmmmlm !.LE NUM6 S REPR P 6 1 I 4 68 0000000000 6 1. .1 4 68. 0000000000 6 1 i 4 ~ OOO0000000 6 1. I 4 68 (';:O00OO0000 6 1 1 4 68 000 ('.) 00000 6 1 1 4 68 0000000000 6 1 1, 4 68 0000000000 6 !, 1 4 68 0000000000 6 1 I 4 68 0000000000 6 I 1 4 68 0000000000 6 1 1. 4 68 0000000000 6 71 I 4 68 (? 000000000 6 1 I 4 68 00()0000000 6 1 !. 4 68 0000000000 6 1 I 4 68 0000000000 6 1 1 4, (~ 0000000000 6 1 1 4 68 0000000000 6 1 1 4 68 0000000000 6 I 1 4 68 0000000000 6 1 I 4 68 0000000000 6 1 1,, 4 68 0000000000 , * l)/X T A * .* P P P T. 9 ,:t a 9.000 81 G ~','t. T 13, T P 12.900 T P N 'I. T .D T P 23.468 S :B t'~ ~l. '.P P T P 44,, .119 81 G C, T D'r P I · 1. 54 S '.l:.: B i.~, T D T P 45.742 TC~F.TDTP 8885.000 TCND,T,:),,P 14921..000 '.C,,DO.TD'TP 4978 438 : .Ir P 1036 SVS I,,~F'D .iD~.P 208 732 ,r 8 c :" T T:)T P :!, 961,, 31 3 l ?,] N [), , T .... ~,.~ ,S;. T [) ~ P 1170.500 $ B H F T D T P T R ,A T; T D T P ]" ¢"/x lq TDTP T SCN . TDTP GRCF . TDTP 36.887 2.292 2036}.000 449 .875 '999,250 ,iS 'raCe Verification ,chlumherger hl. aska Computina CeDt. e~- 7-AF'W-1992 :t. 2:44 PAGE: 20 D F' p T. 9 ~ ~ 00, O 0 C S I G ~,4. ':J D T P &~%P.~-~. ?DTP 47.7(.,5 S!.GC.TDTP SDS 1. TDTP 0.470 BACk. TF;TP TC~r. TOTP 8.!. 33.75C, TC,"~D. 'TOTP ~'SCF. ?'F, TP 1785. :lBS T. ~41,; P. TOTD Tg?~S.TOTP 1137.2fli DFPT, ~750.u0() SIGr~oI'I:TP $[~i'~. 1DTP 59.002 $IGC.'.r. DTP SPSI .'rOTP I. 740 5ACK. TD'rP q.,'C AF. TP, TP 29_~1.40~ TC['; D. TDT~ 7SCF.TDTP 173.869 l'~,l,;D, rD?P T~: k'~. TOTP :1095. O0a 14.240 TPH [.'i'OTP 16 7t~6 1 .~75 S1 ~H. ~.rO'.?P 51:902 43.167 F~AC. 'I'DTP 11.147 132~5.000 TCFD.TDTP 4967.250 1083.~13 INFh,TOTP 234,992 46.025 TPHI.TD'FP 71.2.44 0.000 SIBh. FDTP 80.037 o0.2 l. 6 FbAC. TOTP 12.951 [~t02.9~,0 TCF'D.TOTP 1882.188 8~8.413 i ~,~ FI:~. 't'DT ~ 185,026 SBHF . TCAN, TOTP TSCK. TDTP GRCH, TDTP SBHF. TI]TP TRAq'. 1't.)TP TCA~ .TDTP TSCM .TOTP GRCH,TDTP 35.227 1.956 15914.000 3492.750 37.031 49.356 3.843 12017.289 668.104 39.125 '**** [;' I [ ~ !'."] TRAILER **** SERVICE : ["[,,IC 'V~:RS]iO!'.i : O01A07 [>ATE : 92104/ 7 ~."~AX REC 5'TZE : 1024: F'!LF 'tYPE : LO L~ST' FILE ~ F' I L, F i',,! a..t~ ii; : E D 1' T , O 07 SERVICE ~ Fi., I C ~ERSIO;'.~ : O01A07 DATE'. : 92/04/ 7 ~,~X REC STZ~ : 1,024 F!LF: TYPE : I., LAST FILE AvE~AGE[; Ct{RYES or, pensat, ed ~qoutr~n: Arithmetic averaqe ul~ed ~,ieutron: Lnaveraged edited Pags of edited static oaseline passes for ail, I,> E P T ~,~ 1 ~,:~ C R E M. E N T 0.5 0 0 0 P~SSES Ii'~CI,,,,ttgED IN ,~VERAGE q';[.:>TP 1,, 2, 3, o~' edited passes for all ct.,~rves. 1 ~amma ray and backround cou, nt$; ot~er curves, arithmetic average ,~$ Tar..e Veri. f:icati, on I..,i. st.i. no ~¢hlumb'erqer Alaska ComPutj.:ncj C¢~nter ?-A~R-!.992 PAGE: 21 66 4 66 1 5 66 6 73 7 65 ~ 68 0,5 9 65 F'T I1 66 .1..2 ,.1.2 68 I 3 66 0 14 65 F T 15 66 68 16 66 1 0 66 DEPT F'I:' 425243 00 ()00 00 0 7 i i 4 68 0000000000 SI:Gu P !:,~A V Ct..! 4252,4,3 00 000 O0 0 7 1. 1 4 68 0000000000 T P t.i !: P ~,. 4. V P U 42524. 3 00 0 O 0 00 0 7 1. 1 4 68 0000000000 $ B l,,:~ F P.N A. v C u 4. 2 5 2 4 3 0 0 0 0 0 0 0 o 7 1 1, 4 6 8 0 0 0 0 0 0 O0 0 o SBH~: P :,..:: ~ v CU 425243 00 000 O0 0 7 1, I 4 68 0000000000 5IGC P~'~AV Cd' 425243 00 000 00 0 7 i 1 4 68 0000000000 SIS~'~ P~qAV CU 4.25243 00 00c) 00 0 7 1 I 4 68 0000000000 T R i 'r p ~; A "v 4.: 2524. 3 00 ~) (> 0 00 0 7 ~ t 4 (~ 8 0000000000 8DSI P~AV CD 425243 O0 000 O0 0 7 1 1 4 68 0000000000 $ ~,C~. P~',~ A v CPS 425243 O0 000 O0 0 7 1 1 4 68 0000()00000 F'BAC Pi':;AV CPS ,125243 O0 o00 O0 0 7 1, i 4 68 0000000000 TCA~,: P~V CPS 425243 O0 000 00 0 7 1. I 4 68 0000000000 TC.AK PNAV C ['?,S 425243 O0 000 00 0 7 1 I 4 6R O000000000 T C ~ P P N A V C P ~ 4 2 5 24 3 0 0 0 (; 0 C) 0 0 7 1 I ,i 6 8 0 0 0 0 0 0 0 0 0 0 TCF[> F'["~AV CPS 425243 O0 000 O0 0 7 1 I 4 68 0000000000 TS C ~'~ PNAV CPS 42524.] 00 000 O0 0 7 I 1, 4 68 0000000000 IS Tape vertficatior', f...,isti~o chlun'.ber".~er Al~.sKaa CnmI.:L~tinO Center 992 ~12: 44 PAGE: 22 m ~ m~ mmm m_ mmm~m ~ mm ~m ~ mm~ m Mm m m ~,,~ 425 4 c, 0 0 0 I 4 8 00000 00 I ~ ~-~D P~,: ~ V CPS 4252,43 oo o00 00 0 7 ~. t 4 6~ 0000000000 I ¢,~ FPP(,. ~V CPS 425243 00 000 00 0 7 1 I 4 68 0000000000 GPC~ Pt.:AY ,.GAP! 425243 0O 000 00 0 7 1 1 4 68 0000000000 T E ~.~ S F~AV b~'~ ~+25243 Of) OOO O0 0 7 1 I 4 69 0000000000 ~ * D A T A ~ ~ DFPT. 91~9.0('~0 S '[ G.,"~. P ~'J A V 12.670 TPHi.PNAV 21.135 SBHF. P~,~AV SBH~;~. P;'!A V 43.192 S.IGC PL. AV 1.339 SIBH.~NAV 43.930 TPAT.PNAV S~,S]. P?,: AY (). 395 BACK~ Pk, AV 2fl. 4~9 FBAC. P~,fAV 7.438 TCA~'a. PNA V TCA~.PhAV 10797.~;69 ~CND. P~AV 16259,732 TCF['). PNAV 5571.002 TSC~J.PNAV TSCF. Pf'?AV 2202.375 I ¢-~?¢1). P~':AV 1073.928 l ~,:FD, P~,~AV 235.537 GRCH'.PNAV ..... . PNAV 52 110 TRAT PNAV SB~,4,*; P~,'AV 47.766 S.I. GC P~:~AV 1.()Z5 SIBk~. . .. 8Dfi;T.P;',:~V (,).328 BACK,P~AV 42.145 FBA, C,PN'AV 10 ]~0 TCA~,~ PNAV TCAF. P~.AV 13500.732 TCf~D. P?;AV 16880 543 TCFD.PNAV T S C F'. p r,,~ A V 2792,388 I ;'~ N D, P ~.~ A V l 142.6 O 7 I ~,~ F D, P N A V 242,120 G R C H. P N A V P~'AV 1301,771. .[: 8: P :]". 8750,000 $ I G t,,:;, p ~,i A ¥ ,, 999,25 (,} T P H ,f. P N A V - 999.250 S B H F. P ~:,i A V $ B :q ~,?. P "'; A. 'v - 999.250 8 :l G C, P ~":~ A V ' 999.250 8 ]~ B H, P ,',~ A 'V - 999.250 T R A T. P :~ A V P ~. A V 12,247 3','C A N. P ;,~ A V SDS]~ . P,".}AV -999,25(,) ,?~ACK,t?~:;AV 63,006 ~'BAC, ......... ~' ,C ,A F. P ~,,~ A V - 999.250 t,~ C N O. P ~{ A V - 999.250 'I' CF !].~, P (~ A V - 99 9.250 7,'S C t',4. P ~:,q A V . ' ,. - " ' -'~F' 9 ~4 250 I;',~X~'~.,,).Pf,¢AV q9c~,250 INFi:,:).PN,AV -99q,25o GF, CH, 'P~A V -9qq 34.242 2,195 23685,063 48~1.296 -999,250 37,254 I,.942 26217,492 5422.340 25,016 '99:9,250 '999,250 '999,250 '999,250 3'7.81,3 FILE; NA~',¢IE : EDIt! ,007 SERV'~[CE : FLIC V E R ,S I O ~',~; : 001 ,A 07 l;:,.~?g : 92104/ 7 P:AX REC SIZE : ]024 F '1] b E '.f~'"~ P E; : [,, 0 LAST FILE .~I$ 'rare Veri~icatfor~ [,ist. inc~ ;¢hlun, berf,.~er .&]..aska ¢'o,~Putina Center 7-~PR-1992 12:44 23 SFZR VIC?: ~ FblC ~'FRSI.O;,~ : 001~(~7 [)~'I~ : 92/04/ 7 t','~X REC SIZ~ : ~024 FILF tYPE : LO Curves and io,:.~ header data ~or each mass in semarate files; raw back,round pass in last. file P!%SS :']U'<BF, R: [) [4: P T t.! I NC RF]!,'i EFiT: -. 5()00 ;[., ................. T p' o.. 7;;7;. .... LOG HEADE:R DATA 8750.0 NG (TOP TO B(;~TT£,iM) TOOt, Ci"'~DE TOGL TYPE 29-.v,~AR-92 CF:' 32.6 1100 9193,0 8750.0 9190.0 !800o0 1. 2 2:50 8770.0 IS s'sne veri. ficatlon L.istf. no chlu~L',erqer ~.~las~a Co~F~utInO Center 7-Al>R-I,. 992 12:44 24 PF,~('],'.). F'I.~!JT.i')8 & !'l(314. AX 226. ¢; B I., ;.~ F: [, i r~' E C r.)U .,'.,! T R l T E ,ri C A b E S. ,S E: 'i' Fl Y F I F..:: b D ~: i'~ G I N E F..; R FAR C O [t !':! 'l> R.~TF. LOW SCALE CC'PS): 0 FAF? C{301',~T RAnT'if, HiGH SCALE (CPS): 12000 NI.i;AR CF]UNT RA'i?F; I,(,)t~.' 8CAL~':i CCP,S): 0 ~iF:AR COUP;7 RAI"E tq.l(;H 8CA[,,~;:' (CPS): 30000 T 0 01 .... $ T A ~',.~ [..':> O F F' ( I r,.l ): ...... ,. CBt' 2~8~86 >>>>>>>>>>>>>>>>> SF;(:iI. Et~CE OF ii;VENTS <<<<<<<<<<<<<<<<<< .,':.-', I', '~': I N (,; P.R I' O.~,t T O [4 1 H .. R ! H ~¢ I T lq' T D T - P a g f)] ~I P-PR ~.;8,'3 ~:' O U l.. ,.S, 1 ~, A, K E: 6 A $ El t, I ~, E: T [;1 t',~ P. P A S $ P 0 ~ ixt p R I 0 R T I,:t p'U i:~'! P I N ¢" ~;~AK'E 3 EIASF, I,,II'.IE; P,~,SSES PR]]O~, "') 4. PU~'!P-I?'~! 4.0 B[~!.~S BORAX; I,.:!AKE BORAX PaSS :f~l, .... , C,, ';'~ ~ 6, ~",~A.K:E ! HR, 2 t:"iR:, & .3 :HR 9.'"~;PIP PA,,S~,,..: D;3~.t 7. ~.t A'K E ~1.": [) T,. P P h S tj P h F T El R 3 H R 'i,',; / 0 P U ,,~" P ING.' ' $ ,I$ Ta~e Verj,f~cation Lls[tnc~ ;cblumberqer AlasKa ComputInc] Center 7-AF'~-19!-12 .t2:44 P AGE: ** l~a'i'X FORUAT SPECIF'I.C,A',II{~c~ REC()RD ** mmm~mm~mmmmmmmmm~mmmmmmmm~mm#m ** $~T 7'¥Pg - CNAN ** t:q ¢ 2.. .I F [.71 AP1 FILE i NtlMB S ZE: REPR OCESS ID ORDER ~ BOG TYPE CLASS Nfl)E) NIJ~B SB~iP EI,,,P]M CODE l..~ ~:: p 'r' F T ,~* 25243 00 000 00 0 a 1 ! 4 68 $ I G ~." P S ! C ~J 425243 00 000 00 0 8 1. 1. 4 68 8T[.>T PS1 4.25243 00 000 00 0 8 1 1 4 68 ':ir P ~-~ 1' P $1 P I! 4252 '::} 3 00 n 00 00 0 8 1. I 4 68 i S'~ U PS1 V ~25243 00 000 00 0 8 1. I, 4 68 S F F'D P S, 1. C 1..j a 25243 o 0 000 00 0 8 !. 1 4 68 S F'r,~ D PSI CI.J 425243 00 O0o 00 0 a 1 l. 4 68 SBHF PSI, Cb ~2524:3 00 t.~00 00 0 8 1 1 4 68 SBhN PSI CU 4:25243 00 o00 O0 0 8 1 1. 4 68 FTbT' PS1 CPS 425243 00 000 00 0 8 1 I 4 68 NT~,T P,Sl CPS 425243 O0 O00 O0 0 8 I 1 4 68 AFFD PSI. CPS 4.25243 O0 000 00 0 8 1 1. ~ 68 ABFn ps1 CPS 425243 00 000 00 0 8 1. i 4 68 ' AFN¢ PS1. CPS 42fi24.3 00 000 00 0 8 I 1 4 68 A Bi~;D PSl CPS 425243 00 000 00 0 8 1. 1 ~ 68 &IGC PSl.. C{~ 425243 00 000 00 0 8 I !, 4 6~ S ILEUM PS1 Ct~ 425243 00 O0() 00 0 8 I. 1 4 68 M ~ 0 F' P $1, 425243 00 000 00 0 8 :1 1, 4 68 SE)SI PSi Cfi 425243 O0 000 O0 0 8 I i 4 68 B,I C~: PS1, CPS 4,25243 O0 000 O0 0 8 1, 1 4 68 F~,AC PS1 CPS 425243 oO 000 00 O 8 1 I 4 68 TCAN PS1 CPS ~.25243 O0 000 00 0 8 I 1, 4 68 'r C A F P 51, C P S ~ 25243 00 O 00 0 O 0 R 1 1 4: 68 TCNP PS1 CPS 425243 O0 o0o oo 0 8 1. 1 4 68 TCFD PS! CPS 425243 O0 000 O0 0 8 !. I 4 68 0000000000 0000000000 (:, 000 {,,) 00000 O0(}000OO00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 c~. 000000000 0000000000 0000000000 0000000000 0000000000 aoO0000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 25 .,IS qar.;e verification L~stinc! ;ChlUmberger ~.laska Co~.putir;c3 CenT:er 2:4,4 PAGE: 26 .[' f" F.i.R DE [o .~. i'_, U d mmmmmmMmmmmmM~m~m**~mmmmmmm.mm~m T$Cf,' PS! CVS 425243 O0 000 O0 I~'.'.~ .... PST L:o"P~ ~25243 O0 I ~F F~ P81 CPS 425243 O0 ()00 O0 R~:~I PSI CPS ~25243 Oo 00(; O0 R ~ 2 P S ~ C P ,$ 42524.3 0 RiO3 PSI CP~ z52 3 O0 000 O0 Rf':4 PS1 CPS 425243 O0 000 O0 RS5 PSt CPS 425243 oo R~,6 PSI CPS 42524 3 O0 000 O0 R~,'7 PS.I CPS 425243 O0 OO{~ O0 R U ~'~ P S 1 C P 8 425243 0 RN9 PS1 CPS 4252,43 O0 c~OO O0 kNlO PS] CPS 4.25243 O0 000 O0 R~31,~ PS1 CPS &252.43 O0 000 O0 R~'t l 2 PS1 CPS 425243 O0 00(', RNI3 PS! CPS 425243 0() 000 O0 R~'14 PS1 CPS 4,25243 0(') 000 O0 RN15 PSl CPS 4252.43 O0 000 O0 RS'~ 16 PS1 CPS 425243 O0 000 O0 R F 1 P S 1 C P S 425243 0 (') 000 00 RF2 PSi. CPS 425243 O0 00o O0 RF3 PS1 CPS 425243 O0 000 O0 RE4 PS :{.. CPS 425243 O0 t:,OO O0 RE5 PS1 CPS ,425243 0o 0o0 0 RF6 PS1 CPS 425243 00 0o0 00 RF7 'P81 CPS 4.25243 00 000 00 R F 8 P 81 C P 8 4, 25243 00 000 00 ~ F 9 P $1, C P $ 425243 00 000 00 RFlO PS1 CPS 425243 O0 000 O0 RFll PS1 C['.','~ 4.252,43 O0 000 O0 RF12 P81 CPS 4,252,43 O0 000 O0 R ~ '.t 3 P 8 't C P S 425243 0 0 00 (~ 00 RFI4 PSI CPS 425243 O0 000 O0 RF15 PS1 CPS 425243 0(.) 000 O0 RF16 PS:l. CPS 4252 <%3 O0 000 O0 GP PS1 GAPl .425243 O0 00() O0 TE:N8 PS1 L,B 425243 O0 000 O0 CCLb PSI V' 4,25243 O0 000 O0 W EP Pol LEG~ 4 2 3 O0 ** DATA ** n 8 I 1 4 68 0000000000 0 8 ~1 1 4 OB o000000000 0 8 I I 4 68 oo00000000 0 8 I 1 4 08 (',000000000 o f~ 1 I 4 b 8 {.~ 000000000 n g I 1 4 68 O0000000OO 0 8 1 1 4 C, 8 0000000000 0 $ 1 1. 4 68 0000000000 0 8 I 1, 4 68 0000000000 0 8 1. I 4 68 0000000000 0 8 1 1 4 68 0000000000 0 ~ I 1 4 t~ 0000000000 0 8 1 1 4 68 0000000000 0 a ! 1 4 08, 0000000000 r,, ,~ I 1. 4 66 0¢)00000000 0 8 1 1. 4 68 0000000000 0 8 :~ 1 4 68 O0OOOnOOOO o 8 ~ 1. 4 68 0000000000 0 8 1. 1 4 68 o 000000000 0 8 1. 1. 4 68 0000000000 0 8 J. 1 4 68 0000000000 0 8 ! 1 4, 68 0000000000 0 8 1 1 <~ 68 o 000000000 () 8 I i 4 68 0000o00000 r) 8 1 1 4 68 c,.~ 000000000 0 8 I 1 4. 6~ 0000000000 0 8 1 1 4 68 0000000000 0 8 I i 4 68 0000000000 0 8 ~ 1 4: 6.9 0000000000 0 8 1. ,:t, 4 6 ~ 0000000000 0 8 1. I 4 68 00 00000000 0 8 ~1., 1 4 68.. 0000000000 0 8 1 ,.1,. 4 68 0000000000 0 8 1, I 4 68 0000000000 0 8 1 I 4 68 0000000000 0 8 !, 1 4 08 0000000000 0 8 1 !. 4. 68 00000()0000 0 8 1. 1. 4 68 0000000000 0 a 0 000 65.192 0.000 1.724 0,000 ~T$ ~'a~e ',/er,! flcat i on l',ist ;¢hluii~ber<ler ;,1.~$~ Comput~nq C. enter -105. 0. O, 13, O, C1 , 224. I.~FP'I' q{. {'~{; ('nO SiG,.,i.PSi 12 · · ~ .. ISHI],PSi 3g .063 SFF[", PS j 13. SBH~ Fol 4~.397 F[E,T PSl 7, APeD,PS1 ~0.953 AP;~O,PSi 2~8, [~ACK. PS1 4. 3.01 `1 F'"b A C. PS1 l, 1.. TCF~lb. PS 1. 1524.5.51 2 'rCFO. PSI 5828. IN{',~D. PS 1 1054,35b i :'aF'[>. PS 1 231. R:',~ 3. PS1 63~, 571 R~. PS1 874. Rb~ 7. [>51 655.714 R~8. DS1 6I 7. RNI1.PSI J002,857 R,:',~ 12. PS 1 1624. RF3 PSi 'lPi} 571 RF4.PS] 2Ol. - ~ .... , ~ . . RFT.Pe.,1 261.429 RFS.P8, I 184. kFl. 1 .PS1 57(~. 000 RF12.P51 8?7. RF15.PS1 728.571 RF'16.PS1 312. DEPT. [!748.00(; 8IGf,!. PS1 -999. ISHU.PS1 -999.250 8FFD.PS1 -999. SBHN,P51 -999.250, FTDT,[>$1 -999, ~'BFD,FSI -99~ 25r: ~F~:.D.PS1 -99~. SIBN,PSI -99g.250 ~OF,PSI. -999. B~C~.PS1 -999.250 FBAC.PS1 -099. TC~,iD. PS1 -999,250 TCFD.P81 -999. .PS1 -999. 15'~ N D. P,s 1 - 999,250 I ~ F D. P 81 - 999 [,-o 1 - 9 ~ 9,25 (':, R N 4. . . ~'N7, PS 1 -999. ~0 RNS, PS 1 -099. I':{. ~'~ 1. 1. P 8 ] - 999,2 .... 0 R ~'~ 12, P 8 i, - 99 ~. DF3, 1 -999,250 RF4.PSJ -999: ~7"7. [)~S 1,, -999:. ,. , 250 RF8, PS l -990,, ')" '9q9. R 'F 1 ~ . P ~' ~, P 8 ~ .... RF15 PS1 -99q 250 RF16.PS1 '999, CCLD' iPSI -5:)g{"~.' 250 ~TEP, PS1 .... '999, 7-AER-19q2 12:44 ** F:kiD OF' nATA ** 342 TSC!',;. PS t 316 R'NI .PS1 231 RNS.PS1 0 u 0 R ~,: 1, 3. ~-' $ i OuO F-,F! .PSI ~46 RF5. P,%l OUO F,.Fg, P8 l 000 G P · P S 1 506 © , 000 9.23]. 9.231 o.000 0. 000 4.61.5 9.231 0,000 0. 000 .1.4.469 172 STh1". PS1 66.000 128 ;',;TO"[', PS ! t5:1~9 123 A[~NO,PS1 273.0~9 140 7'RAT,PS1 ] .927 192 q'CA ~, PS 1 22192 227 ,302 q'SC{,:, PS 1 4753~300 3~5 Ri,~I,PSi 587,143 206 R6~5.PSi 900.000 1,/~3 Rfig,PsI 1118,571 286 F~I 3,PS1 1778.571 5'11 RF1,PSI. 162.857 429 RFS, PS1 278.571 2~,'6 RFg.,PS 1 411 429 14:3 RF1 3,PS1 S27~143 857 GR,PS1 24.516 210 250 S T D 250 SF'gD,P$I. 250 2 50 ~i~ B ~,,i 0, P $1 250 2SO 250 TSCN .PSI 250 .R~5.P81 250 F',Ng. PSi 250 RN 13, e'$1 250 R F 1,, P $1 250 RF'5,PS1 250 RFg,P81 250 RFI3.PS1 2 ~ 0 -990.250 -c99,250 .999, .... ~ -. 25t, 999 250 :999 25( :' ) -999 250 999 25( -999 250 -999.250 -999.250 -999. 250 -999,250 -999,250 -999 · 25 () -999. 250 -999.250 T$CF, PS ! ~',2 .PS1 FN16. PS1 R;,il4.P£1 RF'2.PS1 RF6.P$1 RFIO.P$1 RF14.PS1 'r E t,,; 8. P $1 TP~e I. PS 1 SBHF. PSi AFFD,PSI $1GC.P81 SDS! TC~FoP81 TSCF.P81 R?!2 .PS1 RN6.P$! I~ ,~ 10. PS1 RNI4..PS1 RF2.P$1 RF6.PS1 RF'IO.PSI RFJ, 4.P~I TENS. PS1 PAGE: 27 0,000 13.846 0,000 0.000 0,000 13,846 0.000 0,000 0.000 975,000 1.6.399 36.229 64,648 0.91.0 0.381 516 1ll 41.280 942,g57 1097 143 1,4571,143 7,740 317.143 ,t07 143 81~[:571 1310.000 -999.250 -999,250 -999.250 -999.250 999,250 999,250 999.250 -999,250 -999,250 ~999 250 -999,250 -999.250 -999 250 -999:250 "999.250 Tare verificat,ien l,istih(.] ch,]umberr?,e,l:- ~lasKa Computlnq Center 992 !,2:44 2g S~RV.ICE : VFR$ I0,',~ : 00lA07 E:/~.'1'F : q2/04/ 7 F'ILV TYP[,,: : L, Curves and loc header data for each pass i,D seDarate fj. les~ raw backqrou~d pass i.n last file 750.0 V' E ',:~ D 0 R T ~ 0 I,., C D D E T O 0 I., T Y P Fl .],r,,, I.P 1. Hk, kaA SLAY TO L T 9 T P T H E a ,~ ~ I., D E C.~ Y T ("){:~ L "'r' D T P T H F: R ~ A L D E C A Y T O [) L TDTP TDTP CARTRIDGE 29-PiAR-92 CP 32,6 1, 100 29-agR-92 9193.0 875o.0 91,90.o 800,0 .0 :IS 'repe Verilication I,istin.q iChltomberger AlasKa C.7omputin,~ Cemt. e~~ ?DTP TL $ RAY .,50U P C E TF!h:R~'~,~[, DECAY TOOL £}PE~,'~ J-~gLE r:IT SIZE (I.?,!): E"f.~]'!.,I:ERS C- A ,5 '[ ,',; (; DEPTH (E'T): [,QRGE~RS C.AS£NG DEPT~ ~ F3R E:hD[.,E FLI.I.[[? TYPE: FLL;ID OEi'~,SI'!.".~' (t'~B/(.';): SLiRFACF TE[.,~PEPA'r~RE:' (DF, GF): P, OTTt~,./ HOLE ']:Ki,"~Pf":RA'I"L. tRt~: ([~EG[-,'"): FLU]'L) ~Ab.!:i'.."I[TY (PP~4): FLUI[:) bP:VgL (FT): F'I,UI!) RA:.!']h-'_ AT V,"EI,[.,HE4D WATER CUTS (PCT).' GAS/OIL Ri~TIC,'". CHC.)KF ([:)g(.;): SAN DSTi3.. N E: 2.65 'B. I., I.] [": 1L, ! !'..l E[: .............. C [~ [,i ',.t 1' FAR cguiqm R.ATE FAR CO[.~t':.,,T RATE'. HIGt~'I SCALE (C.P$): 120()0 '~:E.'~R COiJNt! R~.TE I..,O~,~' SCALE (CPS): 0 ~,:~g.l~ COitNT RATE HIGH SCALE: (CPS): 30000 TF}I3L STA'N[)['IFF (I.F.f): TIED INTO CBT 218186. >>>>>>>>>>>>>>>>> SE(,)UE~,ICE O~'"' EV:E]NT$ <<<<<<<<<<<<<<<<<< R I H 'W I '1.." ~'! T P T,-P & T E ~' P -'P R g ,S $ T 00 J.,., S,,,, 2, ~,AKE 3 P, ASE.L,I!\"~E PASSE8 F'RIOR .TO .4. P(.i~v~tl)-I~,i 4() :i:.iBI:..8 BORAX; i4AK. F: BORA× EASS ~:1. 5, PU~',:~P""i,I'~,:~ 10 gBl.,S BOiRA×; i''~,AkE ~ORAX,, P/tS.S #2, 6, i~,!~Al,{~:}: ,.1, /.iR 2 HR & 3 P.,'}"~ TE:!,'IP PASSES DOWN, 7, ~ ....... .~ I< F.. :r r~. T... ,::,15 P A 5' ~ P AFT [.: R 3 H .~. i,:i' ! 0 P L] M P ,1' i',J G, POt:,i & RIG DOWIW, T~,,G-PB-400 CTS~'~-a-32, 12.250 8770.0 PRDU.FI,~JIOS & B[.)PAX "'2.0 22...6.0 ~IS 'l'ar~e Veri:fication b:ist]nc~ ,chlumber~er AlasKa Computinq Center PAGE: 2 66 0 3 73 2~>,¢ 4 66 5 66 6 73 7 65 ~ 6~ 0.5 9 65 FT Il 66 3 12 13 66 0 1,4 65 FT 15 66 68 16 66 1 © 66 I DEPT F','I: ,425243 00 000 00 o 9 I 1 4 68 S I Gl'4 PS2 Cl,; 4252a3 00 000 00 0 9 STDT P82 425243 O0 000 O0 0 9 TPFtl PS2 PU 425243 O0 000 O0 0 9 1 1. 4 68 I $ r,~ PS2 V 425243 00 000 O0 0 9 1 I 4 68 srFr, PS2 CU 42524,3 00 000 00 0 9 I 1 4 68 5F~',,D PS2 CU ~25243 O0 000 O0 0 9 1 I 4 68 8 ['~ ~'J Y P S 2 C ~.J' 42524:3 00 O 00 00 O 9 1, 1 4 68 S B~i~: P82 C[~ 425243 O0 000 O0 0 9 1 1 4 68 F T [)']7: P S 2 C P 5 42524:3 00 000 00 0 9 ~qTDT P82 CPS 4.79524.3 O0 C}O0 O0 O 9 1 ! 4 68 AF'FP P8,2 C'PG 425243 O0 000 O0 0 9 1 1 4 68 A ~ F t'~ P S 2 C P 8 42524, 3 00 0 a 0 00 0 9 i. .1 4 68 gFND PS2 CPS 425243 00 000 00 0 9 ], 1, 4 68 ~ B ~',:~ r> PS2 CPS 425243 O0 000 O0 0 9 $IgC PS2 CU ,12524:3 O0 000 O0 0 9 ! i 4 68 Sl[3~ P52 Ct; 425243 00 000 00 0 9 1 1 4 68 ~OF P52 42524:3 O0 o00 O0 0 9 I I, 4 68 T~' PS2 425243 8P51 PS2 CU 42524;3 O0 000 O0 0 9 1 1.. 4 68 0000000000 0000000000 0000000000 c~O00000000 0000000000 0000000000 00 (') 0000 O 00 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OOOO000000 0000000000 ~7,~ 000000000 0000000000 O00OO00000 0000000000 0000000000 ,IS 'rape 'veri~ication ;chluu:berqer h]aska Computinq Center 7-aPR-1992 .1, ~ , 44 P A G 1~.;: 31 '~:" P h C PS2 CPS 4252q. 3 00 l:,00 00 TCA~! PS2 CPS 4.25243 Oi~ 000 00 TCA~ PS~ CPS ~2~243 00 000 TCaD PS~ CPS ~25243 O0 (>O0 00 TCF'D PS2 CPS 425243 00 0 ('~ ,3 O0 TSC~ PS2 CPS 4252~3 O0 COO OO TSCF P82 CP3 425243 O0 o00 00 IhS'iD PS2 CPS 425243 O0 000 O0 INWD PS2 CPS 4252~3 O0 000 00 R~>I PS2 CP6 425243 O0 000 O0 P ~,~ 2 P 82 C P $ 42 fi 243 0 ~'~ 000 k~43 P82 CPS 425243 On 000 00 RN4 PS2 CPS 425243 O0 000 O0 R~,:5 ps2 CPS 425243 O0 000 O0 R ',~ 6 P $ 2 C P S 425243 o 0 000 00 R[~7 PS2 CPS 425243 O0 000 O0 Rt'~8 PS2 CPS 425243 (')0 000 O0 R i~: 9 P 82 C P $ 42524. 3 00 000 00 Pt:~ 1. (> PS2 CP3 425243 O0 (tOO O0 RN:I. 1 PS2 CPS 425243 00 000 O0 R ix~ 1 '2 PS2 CPS 425243 00 000 O0 fin !. 3 PS2 CPS 425243 O0 000 R¢~14 PS2 CPS 425243 O0 000 O0 V~ ~,'.' 15 P $ 2 C P 8 425243 00 000 00 ~.~ 1. 6 PS2 CPS 425243 00 000 00 RF 1 PS2 CP$ 425243 O0 000 00 R P 2 P S 2 C P 8 425243 () 0 000 00 RF3 PS2 CPS 425243 00 000 00 RF4 PS2 CPS 425243 O0 000 O0 R F 5 P 82 C P $ 425243 () 0 000 00 R~6 PS2 CPS 425243 O0 000 O0 CF7 PS2 CPS 425243 O0 RF'2 P82 CPS 425243 O0 000 O0 RF9 PS2 CPS 425243 00 000 O0 RFIO P82 CP~ 42524.3 O0 000 O0 ~Fll PS2 CPS 425243 O0 000 O0 RF12 PS2 CPS 425243 O0 000 O0 RF13 PS2 CPS 425243 O0 000 O0 ~ F 14, 'p 82 C P S 4252 ,,~ 3 00 000 0 o RF15 P82 CPS 425243 O0 000 O0 R,~J6 p82 CPS 425243 oo 000 O0 g [¢ P S 2 (4 A. P I 4. 25243 O o 000 00 TENS '..[>82 LB 4:25243 O0 0()0 00 oCESS CC}DE (HEX) iii ! ImiiIli iii ~ i iii, I ii[I! 9 I 6~ O. .000 O, 9 ! !. 4 68 OO00000OO0 o 9 1 1. 4 o8 O000000OO0 0 q ,.l 1 4 68 O0OO000CO0 0 q 1 1 4 68 OOOO000000 0 9 1 ! 4 ~,~ 0000000000 0 9 1 !. 4 o8 Cf;O0000O00 0 9 !. 1 4 b8 0000000000 0 c~ 1 1 4 68 0000000o0o C} 9 1 1 4 68 0000000000 0 9 .t 1 4 68 0 00 C, 000000 0 9 ! 1 4 68 0000000000 0 9 .1 1 4 68 00000000oo 0 9 I 1 4: 68 0000000000 0 O I 1 4 68 0000000000 0 O 1 1. 4 68 0(>00000000 0 q 1 1 4 68 o000000000 (') 9 1 1 4 68 0000000000 0 9 I 1 4 68 0000000000 0 9 !.. 1 4 68 0000000000 0 9 1. 1, 4 68 OHO0000000 0 9 ~ 1 4 68 0000000000 0 9 1. 1 4, 68 0000000000 0 9 1 1 4 08 0000000000 0 9 i 1. 4 68 0000000000 C, 9 1 1 4 68 0000000000 0 9 5- I 4 68 0000000000 0 0 i, 1 4 68 0000 o 00000 0 9 I I 4, 68 0000000000 0 9 I. 1 4 08 0000000000 0 9 l,. '1 4 68 0000000000 0 9 ! l 4, 68 0000000000 0 9 1 l 4 68 0000000000 0 9 ,I. 1, 4 68 000()000000 0 9 !, 1. 4 68 0000000000 0 9 J. 1 4, (58 0000000000 0 9 1 1, 4 68 0000000000 0 9 I, I 4 68 0000000000 0 9 1, 1 4 68 0000000000 0 9 I 1 4 68 0000000000 0 9 1 I 4 68 0000000000 0 9 1. 1 4 68 0000000000 O' 9 J, I 4 (ia oooooooooo 0 9 ! i 4 68 000u000000 ?. i 1 oo..oooooooo. * * D h T A * * ,I$ ~'a~e Verification bist.ir~(] ;ChlUmberc~er alaska Computihq Center DFPI. 922?. o SO:~. S I(~::i. PS2 ISd~. P.%2 -999.25t.' SFFD.PS2 sF",h N. p ~ _9., -9~9.25,0 FTDI". ?$2 ABFD..PS2 -999. 250 IBFI PS2 -9a9,250, TC~F.PS2 -999.25o TCFD.PS2 !b'bD. PS~ -9o9.250 I aFD. PS2 RI',~ 3. P8P -999. 250 RN ~. PS2 P~ 7.PS2 -999.25n Rii~.PS2 Ra~!J PS2 -~9u.250 R,,~I. 2.PS2 R~.:!n:~. [.o2 Gaq._.,~.25(; F::I1..6.P$2 PF3, P82 -999.25(~ RF4, P82 F:F7 ,PS2 -999,250 RFR .PS2 NFl ~ ,PS2 -999. 250 RF12.P82 F. F15.PS2 -999.25a RF16.PS2 CC[,D.PS2 -999.250 ~'.~.'EP, PS 1 D ti: p 7. 900 (.~. 000 S I G ~",i. P S 2 ISH'.!. P82 62.688 SFFr.). PS2 $~H~;.PS2 49.206 FTDT,PS2 ABFn. PS2 87. :t32 AFND.PS2 815[~.P82 54.768 ~iMOF'. PS2 B. ACK.PS2 76,849 F'6~C,PS2 TCNB. P82 16908,031 TCFD. PS2 I~]SO,P82 1.114,052 INFO.PS2 Pf,:~:3.PS2 737, i 43 RN4. PS2 at,:;7, PS2 737' 143 RNS. PS2 R~,~I I.PS2 1779.571 RN12,PS2 R ~,~ 15, P $ 2 ! 341. ,428 R ~,,~ 16, P 82 P82 200 000 RF4 P89 PF7, PS2 276,000 RF~. P82 PS 2 RF'I 1, PS2 6(}4. 000 RF~.2, pe RF15.PS2 708.000 RFI. 6, o2 CCI,.D. PS2 0,000 WTEP.PS1. P$2 D:~PT. ¢,748. 000 SIGM, P82 i8!',t11.1:>82 69.563 SFFD, SENN. PS2 5<+, 357 FTDT. PS2 .... . h [ ,.,~ D, ~ ~ F D, P S 2 57,785 ' ~" PS 2 ~>~:o 69.499 MMOF PS:2 $ :1' 6 ~, r ,,,,, " "'3 ' ' B A .... C K, P $ 2 fi O .044 ~ t'.. h C. P ,S 2 TCND.PS2 87~7,469 TCFD,PS2 ! N [,: n, p S 2 1.. i. 14,0 l. 2 I N F D, P S '2 PN 3. P82 704,00{:> RN4. PS2 ~S2 42a t>()o t:~,~8 PS2 RN7 , ......... , , . RNll r',<~ 11.24 o00 Ral2 PS2 [:~ ~415. P $ 2 288, (~ 00 R ~ 16. P S 2 PS'2 5 714: RI'4 P82 ~ F 3, .... 17 , . .... RI'?. P52 107,143 R~8.PS2 RF 1 i. P82 308,571 ~F,12, PS2 RF !5, PS2 47,143 aF16.PS2 C C !..~ D, P S 2 0.000 'w T E P, P 81 '7-APR-lq92 12:-~4. -999.250 8'.rDl', PS2 -999.250 -999.250 SF'NiS,PS2 -999.25O -q99.250 NTDi'.P$2 -999.250 -999.250 A B..lq {:',. PS 2 -999.250 999,250 TR A'I'. P$2 999 250 :999.250 TCA~,PS2 Z999:25o -999.25{) TSCN.PS2 -999.250 -999.250 RNI.PS2 -999.250 -99o 250 RNS.P82 q99.25(1 -99~.~250 f,'N9. PS2 2999.250 -999. 250 R~,i 13. PS2 -999. 250 -9-~9. 250 RF'I ,PS2 -999.250 -999.2b0 RF5.PS2 -999.250 -090.250 RFg,PS2 -999.250 -999.250 RF13,PS2 -999.250 -999,250 GR. PS2 -999. 250 224,566 11.547 ST'DT, PS2 66,000 12 638 SFND PS2 14 392 · . . 7.668 N'TD'I:', PS2 17,1.00 317.236 ABN~'), PS2 289.277 1.196 'rRAI'. PS2 1 953 16.002 TCA ~",~ . PS2 26253:574 6421 505 T,SCN.PS2 5400,181 239[033 R,NI,'P,,.2S 604 ., ~ "') } ~ 930 000 Rt'~5,~ ~2 964~.286 651,428 RN9,P82 1272.857 857 2005,714,., NN1.3,PS2, o,,, 1992,00() 690 000 RFI,,to2 1'12, 304.000 RF5':¢82 292.000 224.00o RF'9.PS2 408. 000 684 000 PF! 3,~.o~ 892,000 3'72. 000 C;R, eS2 36. 219 2~5.2~0 4:6.441 STDT.P$2 47.311 SFND.P$2 1,854 N T D ~.1::', P $ 2 266.705 hBNf~,PS2 17,293 TCAa. PS2 2036,9()0 TSC~"J. PS2 196,760 ~N1 ,PS2 924. 000 RNS,P$2 888. 000 R~;I 3, P82 344.000 R F .1. P o"' 2 201. ,429 RFS,PS2 192.857 RFg,P82 218,57I RF13,P52 77. 143 GR.,PS2 -999. 250 6 000 ? 202 264:640 3 957 ! 3324," 676 704. 865 588,000 888.000 i 0 60,000 608,000 :1,,45.714 21,8 757t 295~, 14 4, 2 .38 TPhI. P$2 SSFiF. PS2 AFF[). P$2 S!GC.PS2 SD$I..P82 TCAF. PS2 TSCF.P82 RN2.P$2 RNIO.PS2 Rt,:14.P82 RF2 .PS2 RF6.PS2 RFlO.P62 fkF'14. P52 TENS. P&2 T P }!i I. P S 2 8BHF. P52 AFFD.P$2 5lgC,P$2 8DSI,P82 TCAF.PS2 TS CF. PS 2 a~i 2, PS2 RN6,P82 R N 10, P 52 RN1,4.P52 RF2. RF6.P62 RFI. O,PS2 RF14.PS2 TENS. [)82 PAGE: 32 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 999,250 1999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 17.319 38.927 68,918 1,077 0 31.9 13441~740 2764,874 73,530 1.045,714 1212,857 ~937,143 19,350 348.000 384,000 936'000 1330.000 68,732 57,956 57,411 0.000 328~'~10 .22 178,130 6.1.920 784,000 948.000 352.000 11,610 0~,429 ~3 .714 98 571 126.5' ,000 :iS 'rope verification l,j. stinq .chlumbercler .,~.iasKa C. ombutj, nc] Center 12:44 PAGE; 33 Fl!i) r,.',,F [~a'l'a ***~ F T t.., F. T.q A t I,F,F S~P. VTCE : FL].C DA'].F : 9~t04/ 7 ~X REC SIZE : 1. FII.,E TYPE : L i~& S~' FILE **** FIbE h EAD~R **** F I L f;' iu .A '.,'~ E : g .E> 17: ,010 D~TF : '~2/04/ 7 ~'~X REC SIZE : 1024 L~ST FII,,,E CURVE'iS Curves ahd 109 header data for each pass 1, n separate ~lles; raw bac~qrounO pass in last file T H I r'J C P E H g I~< ,l,': -, 5000 ~ S t.'~' ~v~ h A R Y VE~',~O()R TOO[.~ CODE START DEP~rF~ ;;~;'''''' .........9,1 ;':;7 .... b A T E; L 0 G f; E !.): "1 ..... . 'r'p .L,E, Gt, ER(F )1 TOP bOG I¢,~TERVAL (F'.f): V E i,,.~ I)0 R T 0 (,} L C ['~ t,) E T 0 r) L 'T' y p E STOP DEPTH 87 0 29 ' i~t h R ' 92 CP 32.~ 1, I O0 29'1~!AR-92 91,93.0 ~750 0 18 0 0.0 ,lis Ta~.e Yer..l.~icat~on b~st~nq ;chlu~:berce~ Alask~ Co~,!';~ut..Jn~ Center 7-~PR-1992 12:44: AGE: 3¸4 Ti',TP 'I ~)T P TDTP THEP, i,';AL DECAY 'lOt)t, TRff:Pr4AL, F)k'CAY TOOl'., T~'ER~!aL DEC~,Y TOOt, T;4E~hI.~I, DECAY TOOL TO'¢P C,~TR IbC;E Ti)5'P SONDE DETEC'I'Ok TD"!/P S(?~.gE GENE~aT()R THER.41[, DECAY TOO[, CPSC-~-~20 CPI. S-A-778 TI.)IC-&-7q4 T I~ C - ? .3 '" 390 TND-PC-395 T ~,~ (; - P B - 400 GS~-h-568 C.,pa:l [4©l.,E L',I'/' SIZf;. fit, t): DRIb!,ERS CI',SIi',[G I?,EPTH (FT): t,c,r;g~'a8 CaS'Ir~(; I)F;PT~t (F'r); !,2.250 8770.0 8770.0 -2°0 226.0 2.65 B.I~IIE[,If~!E C.P, UNT R~.q'E $CAb,li;S SET GY FIELD EI'~;GINEER FAR COI, Ii'.,;IT Rg'l:E bO:~ SCALE fiC, PSJ: 0 FAR COUNT PATE HIGH SCAf,,,E (CPS): 12000 . "' ' ~' C ,~J E A [~', C 0 f..l 1',! ti' R: ~ ..I,. E '1'_, ('2 ~ S C A 1.., L(. P S ) 0 "' ~" SCAI,,t ..... (CPS :) 30000 ,IS Ta~,e Verificatic~u L, isti, no ,CblUmberger ~lasKa ¢:omputinq' Center [,'AGE: 35 73 5 6 b 6 73 7 65 ~ 6 ~ 0,5 J. 1 66 3 12 68 13 66 0 14 65 FT 15 66 6~, ~6 66 0 6 6 1 DEPT FT 425243 O0 000 O0 0 10 1 1 4 68 $ l G ~' P' S 3 C U 4252 ~: 3 () 0 000 00 0 10 I 1 4 68 8TDT PS3 4'25243 O0 000 O0 0 1.0 ~ 1 4 6~ TPHI PS3 PU 425243 O0 0(')0 00 0 10 ] I 4 68 I $ ~,{11 PS3 '~' 4.25243 O0 Oa() O0 0 '.10 I 1 4 68 $~'D PS3 CU 425243 O0 000 OO (.) 10 1 1 4 68 SEI'~F PS3 CO 425243 O0 000 O0 0 10 I 1 4 68 8aHt~i pS3 CT.~ 425243 O0 000 O0 0 10 I t, 4 68 FTOT PS3 CPS 425243 0() 000 O0 0 I0 ! 1 4 68 NTOT PS;3 CPS 425243 O0 000 O0 0 1 0 I I 4 6~:~ ,~ F" F' r) p $ 3 C P S ,t 25243 00 000 0 (3 0 :1, 0 1 1 4 68 ~ B ~' I'5 P S 3 C P 8 425243 C) 0 000 00 0 ! 0 1, i 4 6 ~ ,A F'~ I) P 83 C P 6 425243 00 000 00 0 10 I 1, 4, 68 0000000000 0000000000 O00OO00000 0000000000 0000000000 o000000000 0000000000 0000000000 0000000000 0000000000 000o000000 0000000000 0000000000 0000000000 I$ Taoe %~er]ficati..on [,istin9 chlumberger Alaska Comp~r, inci Center 7-AFR-~997 ~2:4,4. PAGE: 36 m mm mlmm iiiI mm ,m~ m m iI Imm ~m{mmmmm mm mmmmmmm mm m mm mm mm{~m mmmmmmmm~mmmmm AgNI) ~ 3 CP 243 . 000 00 SIGC PS3 CU 425243 O0 000 o0 SIBN PS3 Ct] 425243 O0 ~,*; a I'_'t f~'' PS3 4252'!3 '.['RAT PS3 425243 O0 SDSI PS3 Ct.! 425243 00 B.~CK PS3 CPS 425243 O0 FR~C PS3 CPS ..'125 ~43 TCikl PS3 CPS 4252'i3 ()0 5'CAF PS3 CPS 425243 TCf.; P PS3 CPS 425243 00 TCFD PS3 ' CPS 4252.43 O0 TSC~¢ PS3 CPS 425243 00 TSCF PS3 CPS 425243 O0 INND PS3 CPS 425243 00 I N F'C, PS3 CPS 425263 RN1 PS3 CPS ,125243 00 RN2 P83 C~5 425243 O0 R~.3 PS3 CPS 425243 R~,~4 PS3 CPS 425243 R ~ 5 P $ 3 C P 5 425243 0 R ~,' e, PS3 CPS 425243 O0 aN7 PS3 CPS 425243 00 RN8 PS3 6P~ ~252&3 O0 RN9 PS3 CPS 4252~3 O0 R ~ :t O PS3 CPS 425243 00 Rt'<~ 1 ! PS3 CPS 425243 00 R'N!2 PS.3 CPS 425243 O0 RN13 PS3 CPS 4.25243 00 R~414 P53 CPS 425243 O0 R~l, 5 P23 CPS 425243 O0 RN16 PS3 CP& ,4252.43 O0 F'. F' 1. P 83 C P S 425243 0 RF2 PS.3 CPS 425243 O0 R~;'3 PS3 CPS 4,~5243 00 RF4 PS3 CPS .425243 00 RF5 PS3 CPS 425243 00 f:.{F 6 PS3 CPS ,425243 00 RF7 PS3 CPS 425243 O0 R F 8 P 8.3 C P $ 425243 00 RF'9 PS3 CPS 425243 00 R'F.1. 0 P83 CPS 4252,i3 00 RFI! PS3 CPS 425~43 O0 RFI2 PS3 CPS 425243 O0 f.,{'F13 PS3 CPS 425243 O0 RFI4 P83 CPS 425243 O0 RF15 PS3 CPS 4.25243 RF16 PS3 CPS 425243 00 GR PS3 GAFI 425243 'I7 g N,~ PS3 LEi 425243 O0 C'CLP P5'~ V 425243 o 000 00 o o 0 o 0 o (! o 0 o 0 o 0 o 0 OOO c, 00 0 o 00 () o 0 t300 o0 000 C, 0 000 O0 000 00 000 O 0 000 00 O O () 00 000 00 000 00 000 00 000 00 000 00 000 00 O00 O0 000 00 000 O0 00 (~ 00 000 00 000 00 000 00 00 0 0 0 000 00 000 0 0 {..) O 0 00 000 00 000 00 000 00 000 00 (;O0. 00 000 O0 000 00 000 00 00 0 00 000 O0 O. O (.) 00 000 00 000 O0 O 00 00 000 00 000 00 000 00 000 00 APl ElL ,,¢.!.~ ~ SIEE R ,. ~{']D ~I..j~B SA~P FLE~,: CODE (HEX) 0 1 68 000 O lO 1 ] 4 68 0000000000 0 10 ! 1 4 68 0000000000 0 10 ! I 4 68 0000000000 0 10 1 I 4 68 OOO0000000 0 10 1 t 4 68 0000000000 0 10 I. 1 4 ~8 000000000o o lu I 1 4 08 0000000000 0 10 I I 4 08 0000000000 0 10 ! 1 4 68 0000000000 0 10 ~ 1 4 6~ 0o0o000000 o lO ] 1 4 ~8 0000000o00 0 10 i 1 4 68 0000000000 0 10 I 1 4 68 0O00000000 0 10 1. 1 4 68 0o00000000 0 10 1 1 4 08 0000000000 0 10 i I 4 68 0000000000 0 !0 1 1 4 68 0000000000 0 l0 1 i 4: 68 0000000000 0 10 1 1. 4 68 0000000000 0 10 1 1 4 68 0000000000 0 10 I 1 4 68 0000000000 O 10 I 1 4 68 0000000000 0 lO I 1, 4 58 0000000000 0 lO 1, 1 4 68 0000000000 0 1 () 1 i 4 68 O 000 (,',> 0 ~ 000 0 10 I 1 4 68 0000000000 0 l 0 I 1 4 68 0000000000 0 i 0 1 1 4 c>8 0000000000 0 I0 1. I 4 68 0000000000 0 lO I 1 4 68 0000000000 0 lO 1 I, 4 68 0000000000 0 1.0 ] 1 4 68 O0O0000000 0 10 !, I 4 68 0000000000 0 1.0 1 1 4 68 0000000000 0 I0 1, l, 4 68 00000o0000 0 10 I 1 .4 68 0000000000 0 1,0 j. 1. 4 68 0000000000 0 !0 I 1 4 6~ 0000000000 0 10 1 1 4 68 0000000000 0 l0 1. 1 4 68 0000000000 0 !0 ! !. 4 68 0000000000 0 10 I 1, 4 68 0000000000 0 10 1 I 4 68 0000000000 0 1.0 1 1 4 68 0000000000 0 10 1 1 4 08 0000000000 0 I0 1. 1, 4 6a 0000000000 0 10 1. 1 4 68 ()000000000 0 10 I 1 4 68 OOOO0OO000 0 10 1, 1. 4 68 0000000000 o 10 I. 1 4. 68 0000000000 ,I$ '"ape verification I.j. stir,~'.7 ;chlumberqer Alask'a ~,,,,,~.,ut. ir;~ Center 37 [.;,.FPq q272.~0" $I(1`.~ F,q3 -099 250 ,STDq' P$3 -q99 250 TPH1 P$3 I. SE~U. PS.~ -9~9,250 SFFD,P83 -999,250 SFND,PS3 -999,250 SBHF.PS3 $~.FS3 -99q.250 FTDT.P83 -999.250 N'I.'DT'. PS 3 -99q.250 AFFD.P53 AnFD,PS] -999.250 AFNg,PS3 -999,250 ~Nt_),PS3 999,250 SI. GC,PS3 SIaM.PS3 -999.250 k,,iOF. PS 3 -999.250 "FF~AT. PS 3 ~999.250 5DSI'.PS3 BACk.PS3 -999.25o eL~.AC. PS3 -999.2b0 TCA'~q, PS ~ -999.250 TCAF.P53 TC~'~D. PS3 -999,250 TCFD.FS3 -99q.250 'PSC~,,. PS3 -999.250 TSCF'.P53 INkeD.PS3 -999.250 ['?,~FD. PS 3 -999.250 HNI ,PS3 -999.~50 RN2.PS3 P~x',, 3. P83 -999.250 RP4.PS3 -999.~50 F~L5. PS3 -999.25o RN6.PS3 [::~u 7, PS3 -999.250 a'aa. PS3 -999.250 ~',[",; 9, PS 3 -99~ 250 !k':~ 10.PS3 R"~,~I. 1 PS3 -999 250 ~,~,~12,PS3 -999 250 Rb, i~B.PS3 -99~250 aN14 Pa3 ~!5,P83 -999.250 ~;1.6.PS3 -999,250 ~F'I.PS3 -999.250 RF~,PS3 "'PF3.P53 -999.250 kF.i. FS3 -999.~b0 ~FS.PS3 -999.250 RF6.PS3 ~F7.P83 -99q,250 RVa,PS3 -999 250 ~F'9,~83 -999 250 RFIO.PS3 RFll ,PS3 -996 250 RF12,PS3 -999~2b0 ~F"I].~.:-S3 -999~250 RFI4.PS3 .... '' 5f~ .... .' ' ( PS3 -99a 250 q"E['.~S PS3 ~F1.5.~$3 -999,2.., r~FI.a,PS3 -99o 250 .,,R, .... . . CC t,,r:, .. 33 -999,250 ~,~FEP, PS3 -999.250 00,000 $IGM p83 11 64~9 $'rDT,PS3 66.000 TPl-tI ~ ~ · .. "') ~ ..... 74,.063 ~?:FD PS3 12.678 SFND.~:o3 14 383 SadiSt" 46. !5~ IPT.PS3 7. 827 NTI')T.PS3 17.178 AFFD 90 301. AFND.PS3 322.903 ~!!,_6ND,PS3 ~93.313 SIGC .4, 9.09 S ?~ M 0 F, P a 3 !, · 279 a A T. P $ 3 I. 934 5 P S I. 99,..,.9(,)0 F'SAC.P53 1B,.466 TCAN,PS3, 27004.21.! TCAF :16a63,,192 ,rc~ [.,, PS3 04:i;4,. 137 TSC~, PS3 5428.159 TSCF 2a. O0 R~' ,P,..,~3 944.000 ~NS,PS3 ~016.000 R~6 784,000 R,NS.P83 704.0~)0 Rb, q PS3 1280 000 Ri,ilO . t 3 6 0 0: "' ' ' ~4.000 F~N12 PS3 9 . 0 R~.413.PS3 2132.000 RNI, 4 76' 000 RN16.P&3 776. 000 [~:FI .PS3 176,000 RF2 92, OOn Ri~4,PS3 2~0. 000 ~:FS,P83 308.0o0 RF6 ~', ' r,q'~ 216 000 RFg,°S3 42,4,000 RFiO 52. 000 ~FI, 2. PS3 752,000 RF'i 3. PS3 924. ()00 RF1, 4 000 afl, 6. PS3 384,000 GR. PS3 43. 906 TENS 28,000 :~ITEP. PS3 225. 356 0. 't?'"' pS~ 999 250 TPFi!..P$3 D E: P T. ~.~ 74, a ~:~ 00 $ I G ~,~ P 83 - 999.250 S ~, ,,.) ].,. - 250 SF'ND.P83 999 250 S~,i,,~F.P~3 ' '~ ' PS3 - ~99,250 SFF'T:) P53 -99 *~5 PS'~ 9 AF~"'D P53 5Bi,~N,PS3 -999.250 ~'TD',t'.PS3 -99 ,2..0 NI,,D,I,. ,, . · A. BF'D. PS 3 -999.250 ,~ F,N i:') P83 999.250 ABNI,). P83 999.250 SIGC.P83 's ' ' : 9' 250 TaAT.PM3 ~999.250 St',)SI,PS3 PS3 999 250 TC,,AN,PS3 999 25) TC~,F P83 F~AC',., 83 999'250 TSCN,PS3 99 8CF,PS3 T C ~',:~ P, P 83 - 999.25 o "i," C F i:,). P "' - ' : 9 ~ 250 T INND.PS3 9'c',:,~9.250 1:"'~ ~''n p83 -099,250. RNI.PS3 -999.250 R~2.PS3 ' '"' ' .... .~o9.250 PS3 -999.250 'RN6,PS] ~ ~i 3. P S 3 - 9 g 9.250 R N ,4. P S 3 ...... [~ a 5, -999.250 -999.250 -999.250 -999.250 -999.250 :999.250 999,250 -999,250 -999,250 -999.250 -999,250 -999 250 -9991250 -999,~50 -999, 50 -999.250 16.514 34,753 69,907 1.050 0,36! 13959.900 2806,106 98,040 1140,000 1260 000 1932~000 11'610 332,000 396,000 916,000 129C).000 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999'250 -999,250 -999.250 ,iS Tar, ever. lf.i. cat:,t, on [,istinq ;¢hlUmherqer AlasKa Co~.putinq Cent:er 7-AE [~-1992 17...:4 PAGE: 38 [?'~7.PS3. -9a9.~, .:2qr.).... R.r',t~.PS3 -qga. ..250 r.~,:c~:,..ps3 -a9q.250_, _ P~:11..PS3 -999,250 R~!2,PS3 -999.25a Rbl3.PS3 -999.250 R~ 5.PS.~ -999.250 ~ ~',i 16. PS 3 -~99.250 kF~.PS3 -999.250 PF3.PS3 -999.250 a~ ,1..P83 -999.250 RFS,PS3 -999.250 ~FT.P83 -999.250 R~B.PS3 -999.250 ~,Fg.P83 RFiI.PS3 -990.250 PF12,PS3 -Q99.250 RF'I 3,PSI -999.250 RF'I 5. PS ] -999. 250 R~I 6, P83 -~99,250 GR. PS3 -999. 250 CCLr>.P83 -909.250 WTEP,PS3 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 **** F' I I..,E Ti;~A 1LEP F1LF ',iA~;~ : EDIT SFFVIC~ : FLIC VFPSI~,; : OdlA07 UATE : 92/04/ 7 ~,~X R~.;C SIZE : 1024, **** F"!LE F I t, S': ~,: A a E: S E R V ',[ C ~; : F 1,, i C VERSION : O01A07 D.~TE : 92t[~4,./ 7 ~4!)( I?EC SIZE : 1.0~4 F I b E T ~ P E : L I,,~ A S ~" FILE C[,RVES Curves a~d log rleader data E $ U ~ ?,.~ A F< Y each pass in separ.ate fi. les; raw STOP [)EPTH $751,0 C. P 32.6 ,1, 100 29-~,~.R-92 ~ 1 ::~ .~ , Il) bac Kg r o t~ r'~ d pass last file Tape verification bist~n9 ,chlu,mher~er i~laska Con~.p, utin~ (.enter PAGE 39 ? ['..' [..! l:., $7'Ril',iG (TOP V E':I',: D i'~ .R '~ '"'- I'l] C['~ .. ~.,. , m ,i m iii m m mm m m~ mm m ,I m m mml m 'J"DT P .~ DTP '~" P T P .t .' '.I'D T P T[)TP Ti~TP $ 875 (.'.. a 9190.0 18 00.0 DRJ[..,I..ERS CASi~,~(; DEPTH (FT): /.,O(;G~aS CASI:'.iG DEPTH E H 0 I',., E C 0 ~',1 !? 13, I 0 !.,: S FLUID I~"LUI.[~ [)Eb~$1:TY ([,BIG): SURF/~,CE 'I'~':~'qPI:,,.',~ATURE (DE:GF) 60TTOf~ HOLE TE:~'.'tPERATI.IRE ( Ft, UI[; SALI~',~IT¥ (PPt,,:): FLI}ID LEVEI, (FT): FLIjI[) RATE AT ~ATER CLIT8 (PCT) G ~$ I[.)'I L R A'].'I []: CHOKE (DEG) 12,250 8770 0 ~ 77 (.,': 0 PROD. FLU IDS .g.'. BORAX -2,0 226,0 T H' E R ~ ~t L 2 .~5 }:.{aTE: SC..,~LES SET l!~Y F:IEL, D E;',iG.'[NEER A T [!:: [,., 0 ;,~ SC A t, E; ( C P S ): 0 ..ATt.': HIGH SCALE (CPS): 12000 RAT,F. L[)V,~ SCAI,,E (CP~): 0 RATE HIGH SCALE (CF'S): 30000 q': 00 L S T A'.,I' D O F F ¢. t {,~ ): TIED !'?'!q'O CBm 218186. Verification Listir, q ;cb].umberc~er Alaska Comk.,utinO Center 7-aPR--lqg2 t2144 4 0 >>>>)>>>>)>>>>>>> SEOUENCE F'~[" EVE,~.:TS <<<<<<<<<<<<<<<<<< S I t,? i kin PUPP-iN I0 Bt':~I_.8 f~ORAX; :'~: 80RAX PASS ~2. 6. ~ AK f;: t. i,~ A Y [C DATA t','Oi,,i~,~A'i' 8'PE(.],TFICATI;F}N I~E.',CE)PD ** ** 8[.:;T TYP?'; - CI"iAN ** .... ''' ;~''!~V I..l ~,,'? .... ' '~" ....... ..... ,'"' ;'' ..... ''''''''''''''''''''''''''''''''''''''' ..... .... ! [.) {'} R 1:) E; R ~ I..., 0 G 'I"Y P E C [..,.A 88 N 0 t) N U t~', S $ A ap E I, E ~ C 0 O E ( H E; X } D E.: P T E' T 425243 00 000 00 0 11. 1 .I, 4: 68 0000000000 8 IG~¢~ P24 CU 425243 0() 000 O0 0 1, 1 I 4 6$ 0000000000 STP? PS4 425243 O0 C)O0 O0 0 !,I I I 4 68 0000000000 TPHT P84, p[,t 425243 O0 000 O0 0 li 1 1, 4 68 0000000000 I S ~'.'~ t~ p 84 V 425243 () o 000 00 0 l. I 1 I 4 68 o 000000000 8FF[) PS4 CU 425243 O0 000 0(.) 0 1]. 1 l 4 68 0000000000 'ch,lUn, berqer Alaska Com[,u, t inc~ Center 41 mm~mm, m ~m~ m mm ! mm m m m ~m e m~, ~i !m 8 F r,.~ DPS4 C!~ 425243 O0 000 S~PF P84 C[~ 425243 O~ OOO 8~k~'~ P84 Cb 4252a3 FTK, T F'S4 CPS 4252~3 ;,;TD~ P84 CPS ,!25243 0() o00 AFFP P84 CPS 425243 O0 OD,) ABF[' PS4 CPS 425243 0(', 000 A F~,:~ Pg4 C~$ 425243 O0 A~ND PS4 CP& 425243 S!(;C PS4 CI~ 425243 Or) 0()0 S I~%~4 PS4 CT~ 425243 n(3 00o ;,~ k~ O FPS4 425243 Oo 000 TRA'Y PS4. 425243 O0 SDST PS4 C~ 425243 O0 pACK PS4 CPS 4252~3 0() 0c, O f'BAC PS4 CPS 425243 O0 'TCAM PS4. CPS 4~524,3 O0 000 7CAF PS4 CPb 425243 oo ()00 TCt,~D PS4. C[:>~ 425243 00 000 TCFD P'S4 CPS 425243 00 oo0 TSCN PS4 CPS 425243 O0 000 TBCF PSS CPS 425243 O0 000 ! N ~'.; DP84 CPS 425243 O0 OOO INFD PS4 CPS .~252.43 O0 000 ~ ~: i P S 4: C P ~, 4. 25243 0 (::) 000 ~: ~.: 2 P 8 ,i C P 8 425243 0 t..~ 000 F: ~: 3 P S 4 C P 8 425243 00 00 o R N 4 P $ 4 C P 8 42524.3 0 o o 00 R ~: 5 p s 4 C P $ 425243 00 00 R N 6 P S 4 C P S 4252.43 00 0 o u RN7 PS4 CPS 425243 O0 0~0 R~.:S PS4 CPS 425243 O0 000 RN9 PS4 CPS 425243 RNIO PS4 C:P8 425243 O0 0(:)0 R ~:' 1. JP 84 C P S 42524, 3 00 o 00 R~:I2 PS4 CPS 425243 O0 00() .Rh~ 13 PS4 CP8 425243 0o RNI4 P84 CP~ 425243 00 000 RN15 P8,4 CPS 4:25243 O0 0o0 R :: 1 [;,P S 4 C P S 4252,43 00 000 P r I PS 4. C P 8 42524:3 00 00 R r 2 P S 4 C P 5 4252 ¢ 3 00 00 RF3 PS4 CPS 425243 00 000 R F 4 P S 4 C.P S 4. 25243 0 () 000 RF5 PS4 CPS 425243 O0 000 RF6 PS4 CPS 425243 00 00O RF7 PS4 CPS 425243 O0 O0 R r 8 P S 4 C P 8 42524, 3 00 000 RE9 PS4 CPS 425243 00 000 R~iO p84 CPS 425243 00 000 RF!.! PS4 CPS 425243 O0 000 ~ 1 4 ~6 00On000000 i 1 4 68 O00000000O ! I. 4 6~ (~000000000 ! I 4 68 00C) 0000000 ~. 1 4 08 0o00000000 1 1 4 6R 0o00000000 1. I 4 68 0000000000 1 1 4 68 t) f)0000000C~ 1 1 4 68 O0000OO000 I 1 4 08 000000OO00 ~ 1 4 o~ (;0O0000000 1 1 4 68 0000000000 1 I 4 6~ 0000000000 1. I 4 68 0000000000 J 1 4 68 0000000000 I 1 4 6~. f',000000000 1 1 4 68 (.:.000000000 ~. I 4 68 OOO0000000 1 I 4 68 000000 ,':) 000 I I 4 6~ 0000000000 !, 1 4 68 000()00()000 1. 1 4 68 0000000000 1 1 4 68 0000000000 .! 1 4 68 0000000000 1. i 4 ~8 0000000000 1, I 4 b8 0000000000 I 1 4: 68 0 O00000000 .!. I 4 68 0000000000 1 1 4 a8 0000000000 I 1 4 ~)8 00(;0000000 1 1 4 68 0000000000 I I 4 68 0000000000 :! I 4 68 0000000000 1. 1 4 68 o000000000 .,.!, 1 4 68 0000000000 1 i 4 68 0000000000 1, i, 4 ~ 8 (; 000000000 ,!, 1 4 68 0000000000 i !, 4 68 0000000000 1 1, 4 68 0000000000 1 I 4 68 0000000000 '.! I 4 68 00000 (': 0000 ! :1 .4. 68 0000000000 1, 1, 4: 68 0()00000000 :!. 1. 4 68 0000000000 1. I. 4 68 00 (.') 0000000 1, 1. 4 68 0000000000 1, I 4 68 0000000000 1. I. 4 68 0000000000 !. 1. 4 6 8 0000000000 1. I 4 68 0000000000 ;¢hlumbercter AlasKa Comput. JnQ Center 7-APR-!992 12:44 P A (; E: ¸4 2 afl4 P$4 CPS RVl5 PS/.· CPS RF! 6 PS4 CPS CCLF PS 4 V ~TED PS4 DEGF S~'jK:V I CE A. API APl ()PI)ER # i.,0'"',,.-, 'TYPE. C.L/X':'$. ,:, im iii! m i. m, . ' 257243 . O0 425243 O0 000 o0 425243 Ou o00 O0 0 425243 O0 OOO O0 0 425243 o() 0o0 O0 a25243 OO 00o O0 0 42524,3 O0 0()o O0 42524,3 O0 000 O0 ~,~ 25243 0 (> C, 0 ,,:'>(') 0 0 ...-- m .... mmm,~., m.. m. m',~ -- m--. mm~mmmmmmm m.mm~mmm.mmm.mmmmmmmmm..m .00000 0()00000 0000000 OuO0000 0 () 0 00 0 0 0 0 o 00 0 0 0000000 0000000 0000000 * * [.) A T A :'}: *: t) g P'T. 92 ? 2.. ISHU. P$,4 -999. SBH~,~. PS4 -999. ABB'D. P54. -999. SI P.,.H, P$4 -999. [.4ACK' , PS4 -999. TCK~F',. PS4 -999. INND.PS4 -999. ~,:: 3. PS4, -999, R~;7. P$4 '999. RN 1 J 'PS4 -999. RN.15.PS4 -999. RF 3, PS4, -999. RF7. ['}~[4 -999. R. Fi 1,.PS4 -999. RF15. P84 999 50(} SIGM, 250 SFFD, 250 250 AFND, 250 ~,,I 250 FtSAC. 250 '.FCFO. 250 INFD, 250 250 25 u P. ~':! 12, 2 5 ,') R N 16. 250 RP4. 250 RF8 250 RF12, 250 RF16. 250 W T E P PS4 P84 P84 PS4 PS4 PS4 PS4 PS4 PS4 PS4 PS4 PS 4 PS,'~ P$4 P S 4 PS4 PS4 -999.250 -999.250 -999.250 -999.250 -999.2bo -999 250 -qo91250 '999.250 -999.250 -999.250 -999.25(i) -999.250 -999.250 -999,250 -999.250 -999.250 -9~9.250 0 () 0 S I G r4, p S 4, 16.01 () 75 ('> S F P 0, P S 4 1. 6. O 2 !. .7 $ E, F T D T. P S ,4 4,401 957 AFND,PS,4 1.39,582 229 MMOP, P54 1.3,35 008 F"BAC. PS.4 17.363 008 TCFD.PS4 3155.9~9 532 I t'~ F D. P,84. 253.376 000 R N 4. P 84 588,00 (..) 000 RNS. P84 708. 000 0 t) 0 R f',~ ! 2. P $ 4 800.000 000 R['~16.PE4 408,000 000 R P 4. P ~ ,'i 1, 76.000 00 () R F 8. P ,S ,1 220, (t 00 0 C) (,) R F' 12. P $ 4, 384.000 000 ~"rri:p, ps 4 IB4,675 ST[>T,PS4 -999,250 TPHI, SFi\li), PS4 -999 25() SBHF, NTDT.PS4 -999:250 AFFD. ABt',tP,. PS 4 -999 250 SIGC, TRgT.PS4 -999~250 SDSI. TCAF~.PS4 -999.250 TCAF. T~. C;~..PS 4 -999 250 RN1.PS4 -999.250 RN2. RNS.PS4 -999 250 RN6. RNg,PS4 -999~250 RNI. O. R~,~l 3.P54 -999 ~50 RN14. RFI,PS4 -999.250 RFS,PS4 -999.~50 RF6. RFg. P84 -999 ~50 RFIO ~:P13'PS4 -999:,.50 GR.P8~: -999,250 TENS. 66,000 TPt'ii, 16,010 SBHF, 7 , 934 AFI:;'D , 176,936 SIGC, 1.804 SDSI, :1.1,533 186 TCAF. 2252:360 TSCF. 612.000 RN2, 472'000 600. 000 RN 10. 9 40.00 () ,R N 14. 1, 72,030 R ,F'2 160,000 R,~6:" ' 192.0()0 RFI O. 492.000 R F 14,. 45. 531 TE'NS, PS4 P$4 PS4 PS4 P$4 PS4 PS4 PS4 PS4 PS4 PS4 PS4 P84 P$4 PS4 PS4 PS4 PS4 PS4 PS4 PS4 PS4 PS4 !>84 PS4 P$4 P84 ,P S 4, -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999 0 -999 250 -999 250 '999,250 '999.250 '999.250 1,9,604 70,124 39'600 0,000 0,550 6392 254 1248'368. 46,440 456,000 568,000 912,000 15,480 180.000 228'000 ,476.000 1225,000 ~chlumberqer i~]as<a Compt,~tinq CeP. ter "7 ' A PR - 1 :. ,,': 12,4:4 4.% IS[4U. pt3 '.l. -999.25n StFb. PS4 SB~-;~,'. P&4. -99Q, 25¢ Fl'PT. PS4 A~.vr',. PS4 .t-,~o,, -, ~. 25o S] 6H. PS4 -999. 250 ~,:~,~OF. PS4 BACK, PS~ -999,250 FnAC, PS4 ~a4 -999.250 ~CFD.PS4 I ~,: ~,: P. P & 4 - 999.250 I ;,, F D. P S 4 ~:,'~ 3. P,S4 -99 ~. '250 ~N 4. PS4 ~.~, 7. PS4 -999. 250 ~ ~ 11. P S 4. - 9 g 9. '250 R ~,,, 12. P S .~ R~'J 5.P84 -999.250 Ri,~l 6.PS4 RF'3.'P&4 -9~9. 250 RF4. PpT, rS4 -909. 250 RF'E, P84 RF 1 I. PS4 -909. 250 RF],5.'PS4 -9Q9.250 RF.16.PS4 CC[,,D. P84 -999.250 -999.250 STD'F. P$4 -999.250 -99n.250 -999.250 -999.250 '999.250 TCA¢.PS4 -999.250 TSCS.PS4 '999. 250 -999.250 RNS.PS4 -999.250 -999. 250 RN 13. PS4 -99~.250 PF1 .PS4 -9~9.250 F'FS.PS4 -999. 250 ~Fg. PG4 -999.250 RFi 3.P54 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -990.250 -999.25f) -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 TPF].,PS4 8~hF.P$4 AFFD.PS4 Si(;;C.PS4 SDSI.PS4 TC~F.PS4 TSCF.PS4 Rh?.PS4 R~,i6.PS4 R~iO.P$4 RK14.P$4 ~F2.PS4 RF6.P~4 RF!O.P$4 RFla. PS4 TENS.PS4 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999 250 -999~250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 FILE TRAII,(qR E : E : FbIC : 001 A 07 : 92104/ 7 STZF: : J 024 [: : l., 0 FI~L,E : P.TLE ~fA~,IE : EDIT ,012 SERVICE : FLIC VERS I 0~',~ : 001A07 [:),A. TE : 92/0,4t 7 ~",AX R EC SIZE : ~024 FIb[C TY'PE : l.:,O LAST FiLE : F I: [, g !,{ E A D Y R FILF NU~!BER 12 RAw~ CURvEs Curves and 1, oq header data ~or V E )',~ P O R T O 0 I,, C 0 D E $ T A [:{ T D E P T ~.{ each [)ass in separate files; raw b a C K q r' 0 !J P d pass ,in .last file ~IS 'Tape ~erification ;chlumherqer Alaska Computjnq Center PAGE: 44 . 9 , 0 SOFT'~ARE VFRS!Q:~:: hOG 'fhTERVAi.. (F3:]: POTPTO~'~ LOG If~l'~ERVAf_.. (FT): VE:<;~DR TO(~t., COPE TOt'~I. TYPE T,H£R,XAL [>ECAY '/r~OL TDTP CARTRIDGE TDTP Sf}N E)E TDTP SO~',itT.)g GENE',RATOR GA~'4~A RAY SOURCE THF;RI~ A h DECAY FORF:H()LE AND C.ASI,';G DATi.~ L}Pti,';N I,,.tOLE ~IT SIZE (I~,;): DRI:bLERS CASI~,;(; DEPTH (FT): L[~GGERS CASING DEPTH (FT): FLUID TYPE: F'L[,;ID DE¢SI3>'Y (I,,,R/G): SURFACE 3;'EaPERATURE (DEGF): ['r, OTTO,~'~ H,',][.,E TEblPERATURE fDEGF): FLUID SALINITY (PPY~): FLI. fII) I~E;VEL (FT): F 1., u I 1) R A T b.', A T ','; E I,,,, I,, t,,.i E A D ( ~ ['., ~,'~ ): ~ATER CUTS (PCT): GAS/OIl.., R.ATIO: CHOKE (D,CG): 29-~'t~a-92 CP 32.6 !.100 29-~,s.A R-92 91 ~-~ 3.0 .fi. 750.0 91,90.0 N 0 12.250 8 7 7 () 0 s ? 7 o: o PROO.FLUI[)$ & BORA× -2.0 226.0 $ A N D 2.65 ,IS Tar~e veritication bistinr~. ,chlU~,ber<..~er AlasKa Computino Center '7-APR- 199'2 12:44 PAGE: 45 FAR COI,~FiT F~A'!'K HI(iH $ca!ja (CPa): ~.~:A!q' COL,'N'[~ RA'.T~: Li_)~'~ SCA[~E (CP~): (,' 'PIB:[:~ I,'~'FL; cB'~' 2/8/86, :~~:~ ....................... >>>)>>>)>>))))))> SEOIJENCE Of' EVENTS ~,-~.[NG PRI{IR TO R].H. 2. ~',~AKE 3 BASFLIP',~E PASSKS PRIOF: TI'] ,i. D!.I~P-IN 4Q !-~bS BORAXI ~,~AKE aORAX PaSS ~1. 6. ~AKI~: 1 [.iR~ 2 HR, & 3 HP TE~P PASSES b 7. ~{AK.g T[~'I'-P PAS lip AF'T~'.R 3 MR ~/O PIf~PI~,.~G, ,,A Ff']R~tAT S~ .... L,![.;'IC,A It,',!'bi REC(}RD ** · ,IS Tape Verification bistJnq ;chlumherqer AlasKa Comr.,.utJno Center 7-h6R-!992 PAGE: 46 g ~ P T ~ 't 425243 00 0 $IG ~'~ PS5 CU 425243 O0 000 0 STD7 PS5 425243 O0 ~00 O0 0 12 1 1 4 68 IPH] PS5 p[i 425243 O0 000 O0 0 12 I SH'I~ PS5 ~ 4252~3 O0 SFF'P PS5 C[~' 425243 O0 000 O0 0 12 1 1 4 68 SFNP PS5 C(i 425243 O0 000 O0 0 12 1 1 ~ 68 SBHF PS5 CU 425243 OD CO0 O0 0 12 1 1 4 68 SBH~ PS5 Cf, 425243 O0 000 O0 0 12 I 1 4 68 FTDT PS5 CP& 425243 O0 OOC, O0 0 12 1 1 4 b8 amDT PS5 CPS 425243 OO 000 oo () 12 ! i 4 68 AFF:D PS5 CPS 425243 O0 000 O0 0 12 i I 4 68 A~FP PS5 CPS 425243 O0 000 Oo 0 12 1 1 4 68 A F,~ D PS5 CPS 425243 oo oo0 O0 0 12 I 1. 4 68 A Bt'~P PS5 CPS 425243 oo 000 oO 0 12 1 1 4, 68 SIGC PS5 CI~ 425243 Oo 000 oO 0 12 ~ .1. 4. 68 818}4 PS5 CU 425243 O0 000 00 0 12 1. 1 4 68 t.,~ ~.a 0 F PS5 425~43 O0 000 00 0 T~AT PS5 425243 O0 000 8gSI PS5 Cf) 425243 O0 oOO O0 0 B~C~ 'PS5 CPS 4,25243 O0 000 O0 o 12 1. 1 4 68 FB~C PS5 CPS 425243 O0 000 O0 0 12 TCA~ PS5 CPS 425243 O0 000 O0 (, 12 1 1. 4 68 TC~F P85 CPS 425243 O0 (,>00 O0 0 TCNr> p55 CPS 42524,3 0 TCFP PS5 CPS 425243 O0 0()0 O0 0 12 l 1 4 68 TSCk PS5 CPS 425243 O0 000 O0 0 12 1, ! 4 68 TSC~" PS5 CPS 425243 O0 000' O0 0 12 I I 4 68 !N~'~D PS, 5 CPS 425243 O0 000 O0 0 12 I ~ F' [) P $ 5 C P S 425243 00 000 00 0 12 RN1 PS5 CPS 425243 O0 00(> O0 0 t2 I I 4 68 RP2 PS5 CPS 425243 O0 O00 O0 0 12 1 1 4 68 R~3 PS5 CPS 425243 O0 000 O0 0 12 i 1 4 68 R ~'~ ~ PS5 CPS 4,25243 O0 000 O0 0 12 1' 1 4 R~5 PS5 CPL~ 425243 O0 000 O0 0 12 1. i 4 68 ¢ ~ 6 P S 5 C P 8 ,425243 O o 000 ~ 0 O 12 1 I 4 68 R~,;7 PS5 CPS 425243 O0 000 O0 0 12 1 1 4 68 ~ PS5 CPS 425243 O0 000 O0 0 ' 12 1 I 4 68 R~,~9 P85 CPS 425243 00 000 O0 0 12 1 1 ,4 68 R ~,~. !.o PS5 CPS 425243 O0 00() O0 0 1.2 l. ! 4 68 [~:~*!1. PS5 CPS .425243 O0 000 O0 0 12 1 l 4 68 RNt2 P85 CP,5 4,25243 O0 000 O0 0 12 1, 1 4 68 R~',i 13 PS5 CPS ,425243 O0 000 O0 0 1,2 1 1 4 68 R ~:~: 1, 4 PS5 CTM [,' ,:, 4252 ~ 3 O 0 000 00 0 1. 2 1. i 4 68 R~,~t5 PS5 CPS 425243 O0 000 O0 0 1,2 J, I 4 68 P~16 PS5 CPS 425243 (:'.) (:~ 000 O0 o ~.2 i, I. 4 68 R ~' I, PS 5 C P 5 4, 252.43 00 000 00 0 12 1 I 4 68 a F 2 P 85 C P S 425243 O 0 0 ('~ 0 00 0 12 1, 1. 4 68 RF3 PS5 CPS 425243 OO 000 O0 0 1.2 i i 4. 68 ~V4 PSfi CPS 425243 O0 000 O0 0 1.2 l. 1 4 68 ot'Ooo00000 0000000000 O00000OO00 0000000000 0000000000 0000000000 0000000000 O000000000 ooooooooon l:O00000000 O 000 (.) 00000 OOOO000000 O00000UO00 Oooo000000 OOOO000000 C, OOO000000 0000000000 0000000000 OOOO000000 0000000000 0000000000 0000000000 0000000000 0000OO0000 C, 000000000 0000000000 0000 t) 00000 0000000000 0000()00000 0000000000 000()000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 uO00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000()000000 0OO0000000 0000000000 0000000000 0000000000 ',chlun~erc:er Al. as~a Computitan Center 'I-A.R 19c)2 [2:44 P A (.'1 F,: 4'1 r4A".. S R ~.. SKRVI. .... APl A. UI FII, Diri~b,.. -, LI . SIZE R E PRC.'.,CESS .fP ~!RDER # .T,f~(.'-: '!'~'PE CLASS ~(~t', RF6 PS5 CPS 925243 O0 OOU u(.) 0 12 1. 1 4 68 OD00000000 ~F7 PS5 CPS 425243 ~)~) 000 O0 0 12 1 1 4 68 O000OO0000 RwH PS5 CPS 4252~3 0(,, 000 O0 (. 12 I. 1 4 68 UUO()O00000 RF9 PS5 CPS 425243 ()0 OOo OO 0 I 2 1 1 4. 6~ 0000000000 RFIO PS5 CPS 425243 oO t)O0 O0 n I2 1 1 4 68 0000000000 [~Fll PS5 CPS 425243 O0 O00 O0 0 12 ! i 4 08 F;OO6(')O0000 RFL2 PS5 CPS 4252~3 O0 000 O0 0 12 I 1 4 t)a 0000000000 RFi3 P55 CPS 425243 O0 000 oo o 1.2 i 1 4 6a OOOOOOO0OO RF14 PS5 CPS ~25243 O0 OOu O0 0 12 1 1 4 68 0000000000 RF15 PS5 CPS 425243 O0 000 O0 O 12 1 .t 4 68 0000000000 RFI. 6 PS5 CPS 425243 O0 000 O0 0 12 1 I 4 68 OOOOOOO000 GR PS5 GAPI .425243 O0 00() nO 0 12 I 1 q 6~ 0000000000 TENS PS5 LB 425243 O0 OOO O0 0 12 t 1 4 68 O()OOOOO000 CC'[~D PS5 v 425243 O0 o0() oo 0 12 1 1 <~ 68 o00oo0000o ** [>A?A ** DEPT. 9222.500 SIGP~ PS5 -999 ~DO',. $'.FDT,PS5 -9q9,250 TP}.II.PS5 ISHU.PS5 -999,250 ,.. [' f J,), PS5 -999. 50 SF?~}I.), P85 -999,250 SBHF,PS5 SBH[I.PS5 -999.250 FTDT.PS5 -999.250 NTDT.'P85 -999 250 AF'FD PS5 A~,FD. PS5 -999 250 A~..D,PS5 -99Q,250 ABNO,PS5 -99q:250 SIGC.PS5 $ I B H. P S 5 - 9 c~ g 250 ~,~ ~'~ 0 F, . P S 5 .. PS5 -999 250 TROT. B~CK,PS5 -999' ..... PS5 -99g 25() 8D8I, ,25() FBAC.PS5 '999.250 TCAN~, PS5 -999,250 TCAF.PS5 "C,'" PS5 -999 250 TSCN, ......... - .. TChD PS5 -999,250 '! ~t), , o~5 999.25C) TSCF,PS5 TI'NIxeD:PS~. ,,.~ .., -999,250 I'~')FO,PSS:?, . -999. .250, RN1 . P85 -999,250 RN2,PS5 RN3,PS5 -999' 25{,) RN4,PS5 '9c~9.250 RN5,PS5 q99.25o RN6,PS5 p ~ 7, p $ 5 - 9 e 9,250 R n ~. ,p $ 5 - g ~') q, 250 ~ N 9. P S 5 : 999.250 R N 1, 0. P ~ 5 RNI] .PS5 -999.250 PI~I., 2. P85 -999,250 RNI 3.P35 -999.250 RN14,PS5 R~l.B.P85 -999,250 RNIO,PS5 -999,250 RFi,PS5 -999,250 RF2.:P85 RF'3.PS5 -999.250 RF4..PS5 -999.250 RF'5,PS5 999.250 ~,~F6. P~5 PFT,PS5 -999,25o RFS,PS5 -999,2b0 F~f'9,.PS5 :999,250 Rr 10.PS5 ~FI~,PS5 -999.250 RF12.PS5 -999.250 R~I3,P~5 -999.250 RF14.PS5 }'? F' .11 5, PS 5 -999.250 RF1,6.PS5 -999.250 GR,PS5 -999,250 TENS,PS5 CCLD.PS5 -999,250 ~".t'E P, PS 5 -999,250 ISHu:PS5 "' 51.094: SF'F'O. P~5 1.5: 1, Si5 SF'?~ [,), PS 5 1,7:531 SBHF:PS5 SAaFD PS 5B H, ~:~, · P, ,,,, ~c: r~ 67o,2430, 387 RFND'~ 1., [ r. P SS 55 2065 ,' 029146 NA E~.'*"' N ,DI .' PSS~r,~ ¢ .:;,.., ,., ,23710 .. 788811 S'I GC, PS 5AFFD'. . PS5 :[ [:}H, PS5 74.679 MMOF.PS5 1,155 ~RAT,PS5 1.796 SDSI.PS5 ~ ' o PS5 4340.124 TSCN.PS5 2796713 ISCF PS5 .aC. ,~ [,,'o~ ..... 5 87 -<i:4(; FBAC,.P85 18,7U1: ~,'CAU,PS5 13848219 T CAF PS5 IN~ ' Ps5 I, 1, 1,9:3.42., 'J('"~["'PS5 240,927 RNI.PS5 64~:000 RN2:PS5 ~.~, D, P S 5 I 097,711 I ~ F [), ' ~ ' ' Rt,~3 P~:~,) 708,00t) RN4. o5 32 000 .RN5 PS5 ~92 OOn RNf.PS5 ' , . "~ N PS5 1060:000 Rt,JlO,P85 RN7'PS5 528,000 RN8 PS5 688 Or,,,) ;~{ 9, , ,, Rr~IJ.,PS5.~ .... 1288.00() R;~!2,?$5p 1296'000 ~{;~:13,PSSF?, 1248.000, R~'4J. 4 PS5, R~,:~l, 5.Po5 792.000 ~,.{~16, 85 440.000 F1.PS5 180.00{) RF2:PS5 -999.250 -999,250 -999,250 -999,250 :999,250 999,250 '999.250 -999'250 '999 250 -999o250 '999,250 '999,250 '999 250 -999:250 -999,250 15,739 46,825 ,47,500 1,208 0521 7'110:480 1557.16@ 81.270 860.000 1.032'000 1044,000 23,.220 ,I$ Tape Verifica'tior~ I,i. sttn~ ,ChlUmberqer alaska Colnputin.cj Center P~'3. P55 1 t~ O. O00 P~ ,1. F'.q5 PF'7. P$5 1 ? 1. 429 RF~. P55 RFII .Pa5 492.~57 RF'I 2. P~5 RF] 5.PS5 4n2.857 RF16,PS5 CCI,~, PS 5 o. OO 0 ~':TEP. PS5 [: E F T. 87 d ~ . r._, 0 {'; q. i G ~'~ , P S 5 I$~.I',, PS5 -999.2SO SFFD. PS5 - ~ · ~ .-. ABFn. PS5 -999.250 AFN[).PS5 SI6~.PS5 -999.25{) BaCK.PS5 -999.250 F,4AC. PS5 TCr'.~D. PS5 -999.250 TCFD.PS5 ¢r'~ ~. PS5 -999. '250 a~i4. PS5 PS5 -~q9 250 k~'~l !.PS5 -999.250 R{.I12.PS5 RN15.PS5 -999.250 RF3, PS5 -999,250 RF4. PS5 RF7. PS5 -999,250 RF11 ,PS5 -999,250 kFl2, P85 RF15,PS5 -999.250 RF16,PS5 CCbD,PS5 '999,250 12:44 2o5.7!.4 RFb. PS5 252,~57 RFg. PS5 527.14,~ RF13.PS5 227.143 CR,PS5 18~.~76 -~99.250 STDTF.P$5 -n90.250 SFNf).P$5 -999,250 NTDT,PS5 -999,250 AB~!I.).PS5 -099.250 TRAI'.PS5 -999,~50 -999,250 T$C~.PS5 -999.250 -999.250 -999.250 -999,250 RNJ3,PS5 -999o250 ~FloPS5 -999,250 RFS,PS5 -999.250 .RFg,P$5 -999.250 ~13.PS5 -999,250 GR,P&5 -999,250 278,571 RV6.PS5 377,!.43 }{F10.P55 608.571 RFI4.P55 44.688 -999.250 TPHI.P85 -999.250 SRHF.PS5 -999.250 ~FFD.PS5 -999.250 $IGC.PS5 -999.250 SDSI,P55 -999,250 TCAF.PS5 -999,250 TSCF.PS5 -999.250 Rh2.PS5 -999.250 R~,:6.PS5 -999.250 R~IO.P¢5 -999.250 ~k, 14.PS5 -999 250 ~F2.PS5 -999~250 RF'6.PS5 -999,250 RFIO,PS5 -999,250 ~F14,PS5 -999,~50 TENSoP85 PAGE: 4~ 278,571 325,714 488,571 1245,000 -999,250 -999,250 -999,250 -999,250 -999,250 - 9,250 -999,250 -999,250 -999.250 -999,250 '999.250 -999,250 -999.250 -999,250 -999,250 * * * * F I L g T t:~ A I L ~;; R , *,, F!LF: b~aCE : E~..)IT .01.2 SERVICE : F'LIC VERSII3~;, : 001 A97 DATE : 92/04! 7 ~4AX REC S~ZE : 1024 F!LF TYPE LAST FILE' F * * * * FI L, .... ~.:~ [{i il D.E R T ... $ E P V :i C E : ~,' I,~ I: C VERSIO[~ : 001.,A07 DATE ~ 92/04/ 7 iq.AX REC SIZE : 1024 L~,ST F It,,g : FILE ~'~E'ADER R A !,'.: C U R V E S Ct,'~r. ves and Ior';~ r:eader data for each. pass in separate fi, les; ra~,~- ba, ck;grourd pass last file Tape Veri,~icatior; '[,istjr',q ;chlumhe. roer il.las~a ¢'omPutin..q Center 7-5P~-1992 12:4,'; PAGE 49 T p 91, ~7,0,. bOG HE~DE~ DATA S',[ ();:' bEPTH SOFTt, JARF: VEPSIOt,J: T[~ I~RILLER CF'T): TOP bOG IH~'ER~'AL (Fl'): n(~T'.i'0M [,fig I~'.~TEkVA[., (FT): I,(~)GCT~<IG SPEED { 'TOOL STP I r,~G VEhI)CR TOC;b CObE TOOL TYPE TDTP THEPP'AI~ L')EC~Y TOOl., TDTP T~ER~,,~AI, DEC~Y TOOL TDTP ~',"HER~'~AI L::ECAY TOOl., TDTP TH~:R/',:t~[, DEC~Y TOO[, TDTP TOTP CARTRIDGE {('DTP TI>TP SO~",~!,)E GE.NE;RATt,/~R TDTP GAM?,,t6 RAY SOORCE ~P D T P T 'H E R '~,~ A 1.., 1) E C A'Y ']:' O Ct L CP 32.6 1 ! O0 2g-i~';AR-92 8750.0 9~9C.0 .!.~00.0 0 1 2.25 0 877 0.0 8770.0 P P, [).D. ir !..., [,! I D $ & B 0 P A X -2. (! 226 , 0 2,65 ;CblUmberoer AlaSk. a C.o,:puti~G Center ~'~[.,UKI,I~'~? COUt.,T RATE SCALES SET ~V F1EI,I:, Ei;GINEf:'~R FAR COUkT RATE .hO~,~ SCALE (CPS): 0 PAP CO[JNT [~A'FE HIGI4 SCA[.,~: (CPS): 120:~c, ;,IEAf~ COUNT F:~TE bGt~' SCAL, E (CPS): 0 ~4EAR CO0~,~'i' RA~'K HIGH 5CAI,E CCPS): 300~.)0 T [') [3 b ,SIr A ~'; i) I"~ F F ( I N ) : PAGE 5O ** DA.T~,t FOR~'AT SP~;C!F'IC,ATIOI't PECORD ** IS Ta~.e Yerificat.ion L, istJn~ chlumK, erc~er AlasKa Computin¢~ CeDLer 7-APR-lO93 12:.-4.4 5 :t 0 66 ! MmmMmmmmmmmmm m m m m mm *Mm mm mmmmM mmmmmmmmmmmmmmmmmmMmmmmmmmmmmmmMMmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm mmmm mmmm m m mmm I) [< P T F'r .425243 0 o 00 F) 00 0 ~ 3 ! I 4 6 ~ SIG~~ PS6 CI.t 425243 00 000 00 a 1. 3 1. I 4. 68 STl?q 086 425243 00 000 60 0 13 1 1. 4 ~ TPHT PS& P~ 4.25243 00 000 00 0 13 I 1 4 08 I Si,{TT PS6 q q25243 00 000 00 0 13 I 1 4 8a SFFB PS6 CU 425243 o0 ()00 O0 0 13 1 I 4 08 SFk:D PS6 CU 425243 O0 (100 O0 0 13 J. i 4 b~ SBHP PSA CU 425243 c,o o0o OO 0 13 1 1 4 OS SaHe~[ PS6 CI; 425243 00 00() 00 0 13 ! I 4 68 F~ [')T 956 CPS ~25243 00 000 00 0 1.3 ! 1 4 68 NTDT PS6 CPS 425243 00 000 00 0 13 1 i 4 68 AFFD P86 CPS 425243 OO 000 O0 0 13 1 1 4 6~ AP, FI) PS6 CPS 425243 00 000 00 o 13 J I 4 68 AFND PS6 CPS 4252.43 0('~ 000 O0 0 1.3 1 1 4 68 aS~,".D PS6 CPS 425243 O0 000 OO 0 13 1. I 4 6a SIGC P86 CU 425243 O0 000 00 O 13 I I 4 68 SIBT.{ PS6 C[..t 425243 O0 0o0 00 0 13 1 1 4 68 ~; ~a ~."~i~ F PS6 425243 00 O(')0 00 0 13 1 I 4 6~ TRAT PS6 425243 O0 000 0() 0 13 1 1 4 68 SDST PS6 CU 425243 00 000 O0 0 1,3 1 1 4 68 8 ACF,: PS6 CPS 425243 0() 000 ()0 0 13 1 1 4 ~8 FBAC P~-;6 CPS 425243 0() 00() O0 0 13 ! I 4 68 TCAN PS6 CPS 425243 00 000 O0 0 13 1 i 4 68 TCA.~ PS6 CPS 425243 00 000 OO 0 13 1. 1 4 68 TCSD ps6 CPS 425243 o0 000 O0 0 13 1 i 4 68 TCF~ PS6 CPS 42524] 00 000 00 0 13 I 1 4 6a TSCN PS6 CPS 425243 0(') 0()0 O0 0 13 1. I 4 68 T $ C.F' P S 6 C P S 4252.43 00 00 (.) 0 o (, 13 l 1 4 68 INND PSt,~ CPS 425243 O0 060 O0 0 13 :! i 4 68 I ~ F' t? P S 6 C P $ ~ ~ g , ..... z ... 2.43 00 000 00 0 1:3 1 i 4. 68 RNI. PS6 CPS 4252~3 OO 000 ()0 0 1.3 i 1 4 68 R N 2 P S 6 r~ p a z ~, .... . ,......:,, ..... ~, ~. 5243 0 () (~ n () 00 0 13 1 1. 4 b 8 F¢N 3 P 86 C P S 42 fi 243 00 00 O O 0 0 13 I 1. 4 68 RN4. PS6 CPS a25243 00 000 00 0 l. 3 1 i 4 68 ¢"al 5 PS6 CPS 425243 00 0(~0 00 0 13 I I 4 e8 ~: ~'~ 6 P S 6 C P S 4. 25243 O (') n 00 00 0 13 1 l, 4 68 R ~,47 P S 6 C P 8 425243 00 0 (.) () 00 0 1. 3 1 1. 4 68 R N [~ P S 6 C P 5 425243 0 o n 00 00 0 1,3 1 1 4 68 R N 9 P S 6 C P S & 25243 0 o 00 (,, 00 0 1. 3 i.. 1 4 68 [k '~',~ 10 P $ 6 C P $ 4252 .~, 3 (.) 0 0 o 0 00 0 13 1. 1 4 68 F~Nll PS6 CPS 4,25243 00 00o 00 0 13 1 I 4 68 ~: ~':~ 12PS 6 C P $ 4.25243 00 0 () 0 00 0 1, 3 I 1, 4 b 8 [~N l.. 3 PS6 CP;5 425243 00 000 O0 0 ]3 1 t 4. 68 0000000000 o000000000 000000000o uO00000000 0060000000 0000000000 0C, O0000000 0000000000 0000000000 0000000000 0000000000 t)OOO000000 0000000000 00o0000000 O00C)O00000 t) O00000000 0 (.) 00000000 0000000000 00 (,)0000000 0000 C) 00000 0000000000 00 (:) 0000 (') 00 00 C) 0000000 0000000000 0000000000 0000000000 0000000000 0000000000 000O000000 0000000000 0000000000 0000000000 0000 () 00 ()00 0 C) 0000 (} 000 (:000000000 ('; (i 00000000 00()0000000 (",',~ 0000000 O 0 0000000000 {,:':) 000000000 (,~oC,,O0000 O0 (; 000 (') 00000 0 o (,, 0000000 .,IS Tape !.;erificatior~ l~..tstlna ;cblu,~'berqer A].aska ComputJnq Center 7-~PR-1992 1.2:44 AGk.: 52 ,,,'!4 PS ' 243 ~0 0 F;'~15 PS6 CPS 42524~ RNI~, PS6 CPS 4252~.~ RF1 ~86 CPS a25243 c,O nO0 RF2 PS6 CPS 425243 O0 600 RF3 P86 CPS 425243 O0 RF4 P56 CPS 425243 O0 RF5 PS6 CP~ 4252,4 .] O0 riO() ~ PS6 CPS 425243 00 RF7 PS6 CPS 425243 O0 nO0 RF8 PS6 CPS ~25243 O0 RF9 PS6 CPS q252a3 O0 060 RF!O P56 CPS 425243 O0 COP ¢Fll PS& CPS 425243 O0 RF12 PS6 CPS 425243 RFI. 3 P86 CPS 4252,13 O0 oOO ~FI4 PS6 CPS 42524~ O0 nO0 RFi6 PS6 CPS 425243 oO 000 GR 086 GAPI 425243 O0 000 TgM8 PS6 LR 4.25243 O0 000 CC[,D PS6 V 425243 O0 000 ~i T .... . D E G i E CLASS 00 OO 0 O0 0 00 O 00 O0 00 0 O0 0 00 0 O0 0 O0 0 O0 0 00 0 0o 0 00 0 00 0 00 (.; O0 0 O0 0 00 0 O0 0 ()()(.) O~ O. q" 2 S}.il.t*P$6. . -(~99., .250., SFFD.PS6 S 13 [..~ N, P $ 6 - 999,25 () F ':F O T, P S 6 ABFt'). PSfi -999,250 .AFND,'""'t~..$6 SIBN.PS6 -999,250 BACK,PS6 -999.250 FBAC. [)S~ PS6 -999 250 TCFD PS6 T C N 1), , . I N l."'~ D, P $ 6 - 999,250 1 N F'P, P 86 RN 3. PS6 -999. 250 aN4. PS6 RN7, PS6 -999. 250 RNS, PS6 RNlJ,P86 -999.250 RN1.2 P86 RNI. 5 PS6 999 250 · ' , ~l, 6. P86 RI;'"3, PS6 -999,250 RF4. PS6 PF7. PS6 -999,'250 RF'a,PS6 afl! ,P'S6 -999,25(; Rf':J. 2. PS6 RF 16. PS6 -999,250 GR, PS6 ~,~TF:P. PS6 -999,250 m m mmmm! m mmmmmmm! .m mm [~D ~LiNB Si~iP EDEZ CODE (NEX) ...... T ' ; 13 I 4 8 0 ... 000 13 J. 1 4 'r,. 8 O 0 (~ 0000000 I 3 ! 1 4 68 O00OO000OO I 3 1 1 4 68 O0(:O000000 I 3 1 1 4 oR 000¢)000000 I 3 1. !. 4 b8 O000000000 13 .1 'i 4 68 000O00()000 l 3 :1. .!. 4 6 [,,} nO 00 (: 00 O, 00 13 !. 1 4 ~8 00O00000uO 13 1 1 4 68 (,000000000 13 1 1 4, 6~ (,o00000000 13 ! 1 4 ~8 0000000000 13 1 I q~ 68 0000000000 13 1 1. 4 68 0000000000 13 ! 1 4 08 O000000000 !3 I. 1. 4 68 0000000000 13 1 1 4 68 000(:000000 13 1 1 4 6~ 0000000000 13 I 1 4 68 ()O00()OOOO0 13 I 1, 4 ~8 0000000000 13 .1.. i 4 oooooooooo ~999 250 -999:2S0 -999.250 '999,250 -999.250 -999.250 -999.950 -999,250 -999,250 -999.250 -999,250 999,250 2999.250 -999,250 -999.250 -999.250 STDT,PS6 -999.250 TPKIZ,P:S6 SFNO,PS6 -999,250 SSEF.PS6 N T [:'. T . ,PS6 -999 25t) A F'F"[,), P86 /k.[!,N i:), PS 6 -999.250 SIGC,PS6 TRAT, PS6 -999'250 SDSI PS6 JCA~',', PS6 ~999,2S0 TCAF:P86 ("i~J, PS6 999,25() TSCF.PS6 N1 ,PS6 999,250 .RN2 , P,,.>~'" ; RNS,:PS6 999.250 R~6. RNg,PS6 -999.250 Rk:IO.PS6 RNI3,PS6 -999,250 R~'14. PS6 RF1 ,PS6 -999,250 RF2, PS6 RFS,PS6 -999.250 RF6,PS6 RFg,PS6 -999.250 RFi(),P56 ~',F1, 3, P86 -999,250 RFI, 4,P86 TEl,J5, PS6 -q99 250 CCi.,D. P° :999,250 999,250 '999.,250 '999,250 "999,250 '999,250 -999.250 -999,250 '999,250 '999,250 '999,250 '999,250 "999.250 '999.250 '999 250 -999:250 1~ 914 4 o s 59 009 1!765 0 465 8619,947 ~IS Tare Veri!ication Listi. nq ;CblUmberoer AlasKa ComF, ur. inq. Center TC~.!D. P5¢, 14354.734. f'CFO. I'~3'~D. PS6 1123. ~ 03 I ;~FO, PS6 P~',: 3. [:56 74.3. b77 ~N 4, PS6 RNI~ ,PS6 1.735,]~5 R:~12.P5~ PS'IS,PS6 923.077 R~6.PS6 gF3,PS6 !92. 957 RF4.PS6 RP'7. ~S6 248.571 ~FI~ ,PS6 578.571 RF16, PS6 201. 429 GR. wTE~, P56 2! I .~52 DEPT. 8748.000 SIG~. PS6 ISHU,PS6 -999.25~,) SFFD,PS6 S~iN, PS6 -99 ~, 250 FTI')T. PSb ABFD. PS6 -999,250 AFN[). PS6 S I ~.~}-1. PS6 -999.250 ~ICK.P56 -999.250 Fa,~C. P56 TC~,:D. PS6 -999.250 TCFO.PS5 INr,:D.PS6 -999.250 INFO,PS6 R{~ 3,986 -999. 250 ii~'4:. PS6 PN7, PS6 -999. 250 RNS. PS6 RNll,PS6 -999.250 ~:.~v 12. PS6 RN15.PS6 -999.250 R{~16.PS6 RF3. PS6 -999,250 RF4. PS6 RF7, P56 -999. 250 RF8, PSO RF1 ~, PS6 -999.25C, ~F12, PS6 RFI6. PS6 -999,250 GR, PS6 ~'YE:D, PS6 -999,250 7-AP~-1992 12:44 5183.985 248.769 RN!,PS6 909.231 696.923 Rag. PS6 1721.538 406.154 ~Fl PS6 ~52.857 ~FS~PS6 218.571 PF9.PS6 694.2~6 PF~3.PS6 39.500 TEN~,PS6 '999.250 S3'D'r,¢S6 '999.25O SFND.PS6 -999.250 NTDT.PS6 -999.250 AE~,~O.PS6 -g99.250 TEAT,PS6 -99~.250 TCA~,PS6 '99q.250 TSCN,PS~ '999.250 [<'N1,P56 '999.250 ~Nb.PS6 '999,250 RN9,PS6 '999,250 R~,!13,PS6 -999,250 ~FI.PS6 '999,250 RFs. P$6 -999.250 RF9.PS6 -999,250 RFI, 3,PS6 -999.250 TENS,PS6 3R86 023 600~ooo 941.538 1227 692 j. 790~769 197,143 325.714 394 286 711~428 1135.000 -999.250 -999.250 -999.25(3 999 250 29991250 -999.250 -999.250 -999.250 -999.25{) 99,250 -999°25O -999,250 -999 250 -999~250 -999.250 7SCF.PS6 P~2.P56 R;.:6.P$6 R{'¢!O.PS6 k~l. 4.PS6 Rb'2.P66 aF6.P56 RFi0.PS6 RFI4.PS6 CCLD.PS6 TPhI.PS6 AFFD.PS6 &IGC.PS6 SD$I.P$6 TC~F'.PS6 ~>$CF.P56 R~2,FSO RN6,PS6 RN],o.PS6 RN14.PS6 ~F2,PS6 RFIO.P$6 RFI4.P56 CCLD.PS6 1894.091 38.700 1052.308 1232.308 1476.923 15.480 312.857 398.571 724.286 0.000 -999.250 -999.250 -999.25O -999.250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 '999.250 '999.250 99 250 '999,250 '999.250 53 **** FILE TRA I [,,ER **** SERVICE : FblC VERSIO~',~ : O01A07 DATE : 92104/ 7 ~4~X, REC SIZE : 1024 FI'be TYPE : LAST FI[.E : SERVICE !!~!A~{E : MOlT D/~TE : 92/04/ 7 ORI, G'IN : FLIC TAP~; NAI'~E : 9'223'~ CO..riNU,~TIO ~; : PREVIOUS TAPE COf,'~[;:NT ~ aP gXPI,[)RATION,PRLJDHOE t/l,A¥, A-34&, 50'029-21339-00 ,IS Tape Verification Ll~stfnc! ~chlUnher~er Alaska Cor,~r.,utlne. Center 7-APg-.!q92 12.:44 PAGE: ALASKA COMPUTING CENTER SCHLUMBERGER COMPANY NAME : BP EXPLORATION WELL NAME : A - 3~A CZ~-36-~Z-Z3) FIELD NAME : PRUDHOE BAY ~OR,OUGH : NORTH SLOPE STATE : ALASKA API NUMBER :' 50-029-21339 REFERENCE NO : 73859 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: ~ REEL HEADER SERVICE NAME : EDIT DATE : 90/05/17 ORIGIN : FLIC REEL NAME : 73859 CONTINUATION a : PREVIOUS REEL : COMMENT : BP EXPLORATION~PRUDHOE BAY,A - 34A Cll-36-11-13),$0-029-21339 **** TAPE HEADER SERVICE NAME : EDIT DATE : 90/05/[7 ORIGIN : FLIC TAPE NAME : 73859 CONTINUATION ~ : ! PREVIOUS TAPE : COMMENT : BP EXPLORATION~PRUOHOE BAY~A - 34A (11-36-11-13),50-029-21339 · ~ FILE HEADER ~ FILE NAME : EDIT .00! SERVICE : FLIC VERSION : 001A04 DATE : 90/05/17 MAX AEC SIZE : 1024 FILE TYPE : LO LAST FILE : · ~ SCHLUMBERGER 'WELL SERVICES COMPANY NAME: BP EXPLORATION WELL: A - 34A (11-36-11-13) FIELD: PRU,DHOE BAY~ BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-029-21339 LOCATION:' 1171' SNL E 921' WEL SECTION: 35 TOWNSHIP: llN RANGE: 13E 'PERMANENT DATUM: MSL ELEVATION: O' LOG MEASURED FROM KB 75.6' ABOVE PERMANENT DATUM IS TAPE VERIFICATION LISTING :HLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: ELEVATIONS KB: 75.6* DF: 74.6t GL: 47~ DATE LOGGED: 13-MAY-9 0 RUN NUMBER: 1 TD DRILLER: 9190m CASING 1: CASING Z: CASING 3: 5/8" 47 LB @ DRILLER DEPTH OF Om TO 8770m 26 LB @ DRILLER DEPTH OF 8501~ TO 9382w 1/2" 12.6 LB @ DRILLER DEPTH OF Om TO 8533~ BIT SIZE 1: 12 1/4" BIT SIZE 2: 8 1/2" TYPE FLUID IN HOLE: PRODUCEO FLUIDS TIME LOGGER ON BOTTOM: 15:30 13-MAY-90 LOGGING DISTRICT: 4615 LOGGING ENGINEER: JACK RATHERT WITNESS: RICK WHITLOW TOOL NUMBERS: ATC-CB-11 52 NLS-L-3039 CNC-DA-101 ATM-AA-374 FIELD REMARKS: TIED INTO LSS 2B-MAY-85 WELL SHUT-IN @ 07:00 13-MAY-gO SIWHP : 1100 PSI. B 15:'00 13-MAY-90 DATE JOB STARTED: 17-MAY-90 JOB REFERENCE NO: 73859 LOP/ANA: R,. KRUWELL FILE- EDIT.OOZ BP EXPLORATION PRUDHOE BAY A - 34A (11-36-11-13) 50-029-21339 "Z 1/2" CNT-D PASS #1" DATA SAMPLED EVERY --5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: ~ CNT-O .PS1 COMPENSATED NEUTRON TABLE TYPE : CONS TUNI VALU DEFI CN BP EXPLORATION FN PRUDHOE BAY WN A- 34A Cll-36-11-13) APIN 50-029-21339 FL 1171m SNL & 921' WEL SECT 35 TOWN 11N RANG 13E COUN NORTH SLOPE STAT ALASKA NATI USA WITN RICK WHITLOW SON 350057 PDAT MSL EPD FT 0. LMF KB APO FT 75.60001 EKB FT 75.60001 EOF FT 74.60001 EGL FT 47. COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESSm NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV DEPT NPHI TNRA RTNR RCNT RCFT CNTC CFTC GR TENS CCL DEFI DEPTH CHANNEL NAME NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO RAW NEAR CNT COUNTS RAW FAR CNT COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY TENSION CCL AMPLITUDE IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~ TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 56 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN -*~- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 350057 O0 000 O0 0 I 1 ! 4 68 0000000000 NPHI PSI PU 350057 O0 TNRA PSI 350057 O0 RTNR PS1 350057 O0 RCNT PS1 CPS 350057' O0 RCFT PS1 CPS 350057 O0 CNTC PS1 CPS 350057 O0 CFTC PS1 CPS 350057 O0 GR PS1 GAPI 350057 O0 TENS PS! LB 350057 O0 CCL PS! V 350057 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 0 O0 O0 000 O0 0 I 1 I 4 68 0 I I I ,4 68 0 I 1 I 4 68 0 I I I 4 68 0 I 1 I ,4 68 0 I I I ,4 68 0 1 1 1 4 68 0 1 I I 4 68 0 1 i I 4 68 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEP'T. 9231.500 NPHI.PS1 RCNT.PS1 -999.250 RCFT.PS1 GR.'PS1 16.188 TENS.PS1 DEPT. 9200.000 NPHI.PS1 RCNT.PS1 2290.672 RCFT.PS1 GR.PS1 19.094 TENS.PS1 -999.250 ~ TNRA.PS1 -999.250 CN'TC" PS1 -999.250 C'CL. PS1 35.442 TNRA.PS1 416.486 CNTC'PS1 1085.000 CCL.PS1 -999.250 RTNR.PS1 -999.25:0 CFTC.PS1 0.000 5.685 RTNR.PS1 2378.359 CFTC.PS1 0.000 -999.250 -999.250 5.417 414.399 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 9100.000 NPHI.PS1 RCNT.PS1 4255.319 RCFT.PS1 GR.PS1 15.516 TENS.PS1 DEPT. 9000.000 NPHI.PS1 RCNT.PS1 3887.202 RCFT.PS1 GR.PS1 29.609 TENS.PSI DEPT. 8900.000 NPHI.PS1 RCNT.PS1 4373.102 RCFT.PS1 GR.PS1 17.406 TENS.PS1 DEPT. 8800.000 NPHI.PS1 RCNT.PS1 2110.638 RCFT.PS1 GR.PS1 100.875 TENS.PS1 DEPT. 8745.000 NPHI.PS1 RCNT.PS1 -999.250 RCFT.PS1 GR.PS1 37.844 TENS.PS1 1T-MAY-1990 20:39 18.067 TNRA.PS1 1214.750 CNTC.PS1 1150.000 CCL.PS1 18.932 TNRA.PS1 1191.489 CNTC.PS1 1065.000 CCL.PS1 15.580 TNRA. PS1 1480.851 CNTC.PS1 1080.000 CCL.PS1 42.077 TNRA.PS1 416.486 CNTC.PS1 1065.000 CCL.PS1 -999.250 TNRA.PS1 -999.250 CNTC.PS1 -999.250 CCL.PS1 3.493 4414.041 0.000 3.609 4099.232 0.000 3.156 4506.207 0.000 6.418 2271.542 0.000 -999.250 -999.250 0.000 RTNR.PS1 CFTC.PS1 RTNR.PS1 CFTC.PS1 RTNR.PS1 CFTC.PS1 RTNR.PS1 CFTC.PS1 RTNR.PS1 CFTC.PS1 PAGE: 3.429 1233.908 3.371 1146.309 2.920 1435.800 5.500 394.578 -999.250 -999.250 END DF DATA **** FILE TRAILER et** FILE NAME : EDIT .001 SERVICE :' FLIC VERSION : O01A04 DATE : 90/05/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .OOZ SERVICE : FLIC 'VERSION : O01A04 DATE : 90/05/17 MAX REC SIZE : 1024 FILE TYPE, :: LO LASTFILE FILE - EDIT.OOZ BP EXPLORATION PRUDHOE B,AY IS TAPE VERIFICATION LISTING CHLUM~ERGER ALASKA COMPUTING CENTER 1T-MAY-1990 20:39 PAGE: A - 34A (11-36-11-13) 50-029-21339 "2 1/2" CNT-D PASS a2" DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME CNT-D .PS2 COMPENSATED NEUTRON TABLE TYPE : CONS TUNI C N FN WN APIN FL SECT TOWN RANG C DUN S T A T NATI WITN SON POAT E PD FT L MF APO FT EtCB FT EOF FT EGL FT VALU BP EXPLORATION PRUDHOE BAY A - 34A (11-36-11-13) 50-029-21339 1171' SNL E 921' WEL 3,5 11N 13E NORTH SLOPE ALASKA USA RICK WHITLOW 3,50057 M S L 7,5. 60001 75o60:001 T4. 60001 DEFI COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESS' NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV DEPT NPHI TNRA RTNR RCNT DEFI DEPTH C'HANNEL NAM'E NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO RAW NEAR CNT COUNTS IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: RCFT CNTC CFTC GR TENS CCL DEFI RAW FAR CNT COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY TENSION CCL AMPLITUDE DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *:'* TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 1Z 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API API AiPI API FILE NUMB NUMB SIZE REPR PROCESS ~D ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE CHEX) DEPT FT 3'50057 O0 000 O0 NPHI PS2 PU 350057 O0 000' O0 TNRA PS2 .35'0057 DO 000 O0 RTNR PSZ 350057 O0 000 O0 RCNT PSZ CPS 350057 O0 000 O0 RCFT PSZ CPS 350057 O0 000 O0 CNTC PS2 CPS 350057 O0 000 O0 CFTC PS2 CPS 350057 O0 000 O0 GR PS2 GAPI 350057 O0 000 O0 TENS PSZ LB 350057 O0 000 O0 CCL PSZ V 350057 O0 000 O0 0 2 I I 4 68 0000000000 0 Z I I 4 68 O00OO00000 0 2 I I 4 68 0000000000 '0 2 1 1 ¢ 68 0000000000 0 Z 1 1 4 68 0000000000 0 2 1 1 4 68 O00OO00000 0 2 1 1 4 68 0000000000 0 Z 1 1 4 68 O00OO00000 0 2 1 1 4 68 0000000000 0 2 1 1 ~ 68 0000000000 0 2 i I 4 68 0000000000 IS 'TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DATA DEPTo 9229.500 NPHI.PS2 RCNT.PS2 2395.939 RCFT.PS2 GR.PS2 16.969 TENS.PS2 DEPT. 9200.000 NPHI.PS2 RCNT.PS2 Z360.086 RCFT.PS2 GR.PS2 21.172 TENS.PS2 DEPT. 9100.000 NPHI.PS2 RCNT. PSZ 4153.191 RCFT.PS2 GR.PSZ 13.031 TENS.PS2 DEPT. 9000.000 NPHI.PS2 RCNT.PSZ 3866.667 RCFT.PS2 GR.PS2 26.859 TENS.PSI DEPT. 8900.000 NPHI.PS2 RCNT.PSZ 4255.319 RCFT.PS2 GR.PS2 17.250 TENS.PSI DEPT. 8800,,000 NPHI.PS2 RCNT.PS2 2309.979 RCFT.PS2 GR.PSZ 101.313 TENS.PSI DEPT. 8745.000 NPHI.PS2 RCNT.PS2 1804.772 RCFT.PS2 GR.PS2 38.281 TENS.PSI END OF DATA FILE NAME SERVICE. V'ER SION DATE MAX REC SIZE FILE TYPE LAST FILE · *** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER ,~** : EDI'T .002 : FLIC : 001A04 : 90105/17 : 1024 : LO : HEADER :*~ = EDIT .003 : FLIC : 001A04 : 90/05/17 : 1024 : LO : 17-MAY-1990 20:39 31.101 TNRA.PSZ 487.310 CNTC.PS2 865.000 CCL.PS2 34.101 TNRA.PS2 424.628 CNTC.PSZ 1070.000 CCL.PS2 5.177 Z491.454 0.000 5.530 2409°368 0.000 18.752 TNRA.PSZ . 3.585 1214.750 CNTC.PS2 4369.796 1055.000 CCL.PS2 0.000 19o546 TNRA.PS2 1171.974 CNTC.PS2 1040.000 CCL.PS2 16.149 TNRA.PS2 1460.722 CNTC.PS2 1060.000 CCL.PS2 44.143 TN~A. PSZ 459.574 CNTC.PS2 1050.000 CCL.PS2 57.197 TNRA.PS2 Z20.807 CNTC.PS2 945.000 CCL.PS2 3.692 4074.908 0.000 3.233 443B.654 0.000 6.653 2499.955 0.000 8.149 1816o198 0.000 RTNR.PSZ CFTC.PSI RTNR.PS2 CFTC.PSI RTNR.PSZ CFTC.PSI RTNR.PS2 CFTC.PSI RTNR.PS2 CFTC.PSI RTNR.PS2 CFTC. PS2 RTNR.PSZ CFTC .PSI PAGE: 4.917 481 .Z55 5.360 434.108 3.400 1189.095 3.449 1142.956 2.907 1374.723 6.222 439.g88 7.692 221.241 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-lBS0 Z0:39 PAGE. · FILE - EDIT.O03 BP EXPLORATION PRUDHOE BAY A - 34A {11-36-11-13) 50-OZg-Z1339 "g 1/2" CNT-D PASS #3" DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME CNT-D .PS3 COMPENSATED NEUTRON TABLE TYPE : CONS TUN! VALU DEFI CN BP EXPLORATION COMPANY NAME FN PRUDHOE BAY FIELD NAME WN A - 34A (11-36-11-13) WELL NAME APIN 50-029-21339 API SERIA'L NUMBER FL 117'1' SNL & 921' WEL 'FIELD LOCATION SECT 35 SECTION TOWN ll'N TOWNSHIP RANG 13E RANGE COUN NORTH SLOPE COUNTY STAT ALASKA STATE OR PROVINCE NATI USA NATION WITN RICK WHITLOW WITNESSm NAME SON 35005'7 SERVICE ORDER NUMBER PDAT MSL PERMANENT DATUM EPO FT O. LMF KB LOG MEASURED FROM APO FT 75.60001 EKD FT 75.60001 EOF FT 74.60001 EGL FT 47. IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: 10 TABLE TYPE : CURV DEPT NPHI TNRA RTNR RCNT RCFT CNTC CFTC GR TENS CCL DEFI DEPTH CHANNEL NAME NEUTRON POROSITY CALIBRATEO THERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO RAW NEAR CNT COUNTS RAW FAR CNT COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY TENSION CCL AMPLITUDE DATA FORMAT SPECIFICATION RECORD ~ ~ SET TYPE - 64EB ~ TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0°5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 1,6 66 1 0 66 I SET TYPE - CHAN NAME SERV UNIT SER~VICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM DEPT FT 350057 O0 000 O0 0 3 I 1 NPHI PS3 PU 350057 O0 000 O0 0 3 TNRA PS3 350057 O0 000 O0 0 3 i 1 RTNR PS3 350057 00' 000 O0 0 3 ! ! 4 RCN'T PS3 CPS 350057 O0 000 O0 0 3 I 1 RCFT PS3 CPS 350057 O0 000 O0 0 3 ! ! 4 PROCESS CODE CHEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68, 0000000000 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOO NUMB SAMP ELEM COOE PROCESS CHEX) CNTC PS3 CPS 350057 O0 000 O0 0 3 I I 4 68 CFTC PS3 CPS 350057 O0 000 O0 0 3 I I 4 68 GR PS3 GAPI 350057 O0 000 O0 0 3 1 I 4 68 TENS PS3 LB 350057 O0 000 O0 0 3 1 I 4 68 CCL PS3 V 350057 O0 000 O0 0 3 ! ! 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 :~ DATA DEPT. 9230.000 NPHI.PS3 32.999 TNRA.PS3 RCNT.PS3 2402.036 RCFT.PS3 468.193 CNTC.PS3 GR.PS3 27.641 TENS.PS3 745.000 CCL.PS3 DEPT. 9200.000 NPHI.PS3 33.336 TNRA.PS3 RCNT.PS3 2400.000 RCFT.PS3 466.667 CNTC.PS3 GR.PS3 29.500 TENS.PS3 1085.000 CCL. PS3 DEPT. 9100.000 NPHI.PS3 19.255 TNRA.PS3 RCNT.PS3 4187.233 RCFT.PS3 1222.930 CNTC.PS3 GR.PS3 15.203 TENS.PS3 1090.000 CCL.PS3 DEPT. 9000.000 NPHI.PS3 20.540 TNRA.PS3 RCNT.PS3 3966.667 RCFT.PS3 1116.667 CNTC. PS3 GR.PS3 28.813 TENS.PS3 1090.000 CCL.PS3 DEPT,. 8900.000 NPHI.PS3 17.070 TNRA.PS3 RCNT.PS3 4400.000 RCFT.PS3 1450.000 CNTC.PS3 GR.PS3 22.813 TENS.PS3 1110.000 CCL. PS3 DEPT. BBO0.O00 NPHI,.PS3 40.900 TNRA.PS3 RCNT,.PS3 ZlO0.O00 RCFT.PS3 366.667 CNTC.PS3 GR.PS3 119.1Z5 TENS.PS3 1090.000 CCLoPS3 DEPT. 8745.500 NPHI.PS3 51.749 TNRA. PS3 RCNT.PS3 1697.959 RCFT.PS3 233.333 CNTC.PS3 GR.PS3 36.500 TENS.PS3 1105.000 CCL.PS3 END OF 'DATA ~. 5.402 2497.793 0.000 5.441 2426.356 0.000 3.653 4280.277 0.000 3.825 4118. 945 O. 000 3.358 4463.543 0.000 6.291 2193.825 0.000 7.525 1778.712 0.000 RTNR.PS3 CFTC.PS3 RTNR.PS3 CFTC.PS3 RTNR.PS3 CFTC.PS3 RTNR.PS3 CFTC.PS3 RTNR.PS3 CFTC.PS3 RTNR.PS3 CFTC.PS3 RTNR.PS3 CFTC.PS3 5.130 462.376 4.929 441.753 3.444 1198.247 3.522 1070.792 3.011 1338.731 5.7 :Z 7 351. 162 7.571 238.237 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-lOg0 20:39 PAGE= 12 ~=)% FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001A04 DATE = 90/05/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **:¢', F I L E H E FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001A04 DATE : 90/05/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE - EDIT.O04 BP EXPLORATION PRUDMOE BAY. A - 34A Cll-36-11-13) 50-029-21339 "2 1/2" CNT-D PASS DATA SAMPLED EVERY -.5000 FEET DATA INCLUDED - TOOL EXTENSION 'TOOL TYPE USED NAME CNT-D .PS4 COMPENSATED NEiUTRON TABLE TYPE : CONS TUNI CN FN VAL'U DEFI BP EXPLORATION PRUDHOE BAY COMPANY NAME FIELD NAME IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 1T-MAY-1990 20:39 PAGE: 13 TUNI WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD FT LMF APD FT EKB FT EOF FT EGL FT VALU A - 34A Cll-36-11-13) 50-029-21339 1171' SNL E 921' WEL 35 11N 13E NORTH SLOPE ALASKA USA RICK WHITLOW 350057 MSL O. 75.60001 75.60001 74.60001 47. DEFI WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESS' NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CURV DEFI DEPT NPHI TNRA RTNR R CNT RCFT CNTC CFTC GR TENS CCL DEPTH CHANNEL NAME NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO RAW THERMAL NEUTRON RATIO RAW NEAR CNT COUNTS RAW FAR CNT COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY TENSION CCL AMPLITUOE DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 4 66 1 5 66 6 73 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: 14 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I SET TYPE - CHAN ~ NAME SERV UNIT ID SERVICE API API API ORDER # LOG TYPE CLASS MOD DEPT FT NPHI PS4 PU TNRA PS4 RTNR PS4 RCNT PS4 CPS RCFT PS4 CPS CNTC PS4 CPS CFTC PS4 CPS GR PS4 GAPI TENS PS4 LB CCL PS4 V FILE NUMB NUMB SAMP NUMB SIZE ELEM 350057 O0 000 O0 0 350057 O0 000 O0 0 4 I I 4 350057 O0 000 O0 0 4 i 1 350057 O0 000 O0 0 350057 O0 000 O0 O 4 1 1 4 350057 O0 000 O0 0 4 I I 4 350057 O0 000 O0 350057 O0 OOO O0 0 4 I I 4 350057 O0 000 O0 0 4 I I 4 350057 O0 000 O0 0 4 I I 4 350057 O0 000 O0 0 4 I I 4 REPR CODE 68 68 68 68 68 68 68 68 68 68 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEPT. RCNT.PS4 GR.PS4 DEPT. RCNT.PS4 GR.PS4 DEPT. RCNT.PS4 GR.PS~ DEPT. RCNT.PS4 GR.PS4 9231.000' NPHI.PS4 240Z.036 RCFT.PS4 29.7'66 TENS.PS4 31.101 488.550 820.000 9200.000 NPHI.PS4 34.784 Z270.510 RCFT.PS4 424.779 31.109 TENS.PS4 1085.000 9100.000 NPHI.PS4 19.717 4008.869 RCFT.PS4 1188.470 18.156 TENS.PS4 1070.000 9000.000 NPHI.PS4 18.940 3937.916 RCFT.PS4 1140.271 30. 656 TENS.PS4 1060. 000 TNRA.PS4 CNTC.PS4 CCL.PS4 TNRA.PS,4 CNTC. P S4 CC'L. P S4 TNRA.PS4 CNTC. PS4 CCL.PS4 TNRA. PS4 CNTC.PS4 CCL.PS4 5.177 2497.793 0.000 5.609 2322.424 0.000 3.715 4230.188 0.000 3.610 4087.791 0.000 RTNR.PS4 CFTC.PS4 RT'NR.PS4 CFTC.PS4 RTNR.PS4 CFTC.PS& RTNR.PS4 CFTC.PS4 4.917 482.479 5.250 414.282 3.582 1161.151 3.333 1122.812 IS 'TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 8900.000 NPHI.PS4 RCNT.PS4 4390.022 RCFT.PS4 OR.PS4 24.891 TENS.PS4 DEPT. 8800.000 NPHI.PS4 RCNT.PS4 2057.649 RCFT.PS4 GR.PS4 110.500 TENS.PS4 DEPT. 8746.500 NPHI.PS4 RCNT.PS4 1667.406 RCFT.PS4 OR.PS4 41.719 TENS.PS4 END OF DATA 17-MAY-1990 20:39 17.586 TNRA.PS4 1433.628 CNTC.PS4 1060.000 CCL.PS4 44.475 TNRA.PS4 301.552 CNTC.PS4 1060.000 CCL.PS4 55.'789 TNRA.PS4 230.599 CNTC.PS4 1070.000 CCL.PS4 3.428 RTNR.PS4 4548.599 CFTC.PS4 0.000 6.691 RTNR.PS4 2176.654 CFTC.PS4 0-000 7.'987 RTNR.PS4 1708.596 CFTC.PS4 0.000 PAGE: 3.086 1337.858 7.059 329.405 6.923 217.507 15 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001A04 DATE : 90/05/17 MAX RE( SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001A04 DATE : 90/05/17 MAX RE( SIZE : 1024 FI~LE TYPE : LO LAST FILE : FILE - EDIT,.O05 BP EXPLORATION PRUDHOE BAY A - 34A (11-36-11-13) 50-029-21339 "2 1/2'" CNT-D HOOGES LEHMANN. AVERAGED NPHI" DATA SAMPLED EVERY -.5000 FEET IS TAPE VERIFICATION LISTING 17-MAY-1990 20:39 CHLUMBERGER ALASKA COMPUTING CENTER PAGE: 16 DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME CNT-D .HLA COMPENSATED N'EUTRON TABLE TYPE : TUNI CONS VALU DEFI CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI WITN SON PDAT EPD LMF APO EKB EOF E GL FT FT FT FT FT TABLE TYPE : CURV DEFI DEPT DEPTH CHANNEL !NAME NPHI NEUTRON POROSITY BP EXPLORATION PRUDHOE BAY A - 34A (11-36-11-13) 50-029-21339 1171' SNL & 921' WEL 35 11N NORTH SLOPE ALASKA USA RIC~ WHITLOW 350057 MSL O. K5 75.6'0001 75.6000! 74.6000! 47. COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMSER FIELO LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION WITNESS' NAME SERVICE OROER NUMBER PERMANENT DATUM LOG MEASURED FROM IS TAPE VERIFICRTIDN LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 Z0:39 DATA FORMAT SPECIFICATION RECORD *~ SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 4 66 S 66 6 T3 7 65 8 68 0.5 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS CHEX) PAGE: 17 DEPT FT 350057 O0 000 O0 0 5 I I 4 68 NPHI HLA PU 350057 O0 000 O0 0 5 I 1 4 68 0000000000 0000000000 ~ DATA ~ DEPT. 9231.500 NPHI.HLA 26.709 DEPT. 9200.000 NPMI.HLA 34.81¢ DEPT. 9100,000 NPHI.HLA 19.336 DEPT. 9000.000 NPHI.HLA 19.434 DEPTo 8900'000 NPHI.HLA 16.406 DEPT. 8800.000 NPHI.HLA 41.$95 DEPT. 8745.000 NPHI.HLA O.O00 END OF DATA ~:~: IS TAPE VER'IFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 17-MAY-1990 20:39 PAGE: 18 ~t FILE TRAILER ~ FIrE NAME : EDIT .005 SERVICE : FLIC VERSION : O01A04 DATE : 90/05/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~ TAPE TRAILER ~ SERVICE NAME : EDIT DATE : 90/05/17 ORIGIN : FLIC TAPE NAME : 73859 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION~PRUDHOE BAY~A - 34A (11-36-11-13)~50-029-2133g **** REEL TRAILER SERVICE NAME : EDIT DATE : '90/05/17 ORIGIN : FLIC REEL NAME : 73859 CONTINUATION # : PREVIOUS REEL : COMMENT : ~P EXPLORATION,PRUOHOE BAY~A - 34A (11-36-11-13)mSO-OZg-z1339 UOl~}~oo 'suoO se9 ~ I!0 s~s~iV £,IS '~APE VERIFICATION [,ISTING VP O,tO,H02 VERIFICATIOi~] LISTIhG PAGE 1 * ~E~, READER *~ ERVICE NAME :EDIT ATE ~87/09/ 9 RIGIN : EEL NAME :72435 ONTINUATION # :0! 'REYXOUS REEL : 'O~MENTS :LIS TAPE,STANDARD PRUDHO~] BAY A-34A,API # 50-029-21339 * TAPE HEADER ,ERVICE NAME :EDIT ~ATE 187/09t 9 ~RIGIN :7243 'APE NAME ONTINUATIO 'REVIOUS TAPE : IO~NENTS :LIS TAPE,STANDARD PRUDHOE BAY A-34A,API # 50~029~21339 FILE HEADER :' LE NAME :EDIT ,00! ;ERVICE NA~E 'ERSION # IATE ,t ,AXI~U~ LENGTH' : 1,024 'ILE TYPE 'R£V IOUS FILE : INFORMATION RECORDS ** CONTENTS iN : STANDARD ALASKA PRODUCTION CO, 'N : A - 34A (11-36-11-13) ~N : PRUDHOE BAY ~ANG: 13E ~O, WN: lin ~ECT~ 35 ~OUNt NORTH SLOPE ~TAT: ALASKA ~TRY~ USA 4NEM CONTENTS ~* COM~ENTS ** UNIT TYPE CATE SIZE CODE 000 000 030 065 000 000 O22 O6 5 oo 065 ooo o 00o 0 6~ 000 000 004 06 000 000 002 065 000 000 012 065 000 000 O0 6 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 VP 010,HO2 VERIFICATI[Ib', L{iSI'ING PAGE ************************************************************************************ SCHLUMBERGER ALASKA COMPUTING CENTER ***********************************************************************************'OI~PAN~ : STANDARD ALASKA PRODUCTION CO, ~ELL : A'"34,~ (11-]6-11'"'13) ,PI ~ = 50-029-21339-01 'IELD : PRUDHOE BAY ',OUNTY -' NORTH SLOPE BOROUGH ',TATE '- ALASKA IDB NUMBER AT AKCC: 72435 IUN #1, DATE LOGGED: 06-SEPT-@7 ,DP: R, KRUWELL ~A$ING ~ASING 7UBING !YPE FLUID 9,625" @ 8770' 7,000" @ 9382' 4.5" ~ 8533' PRODUCED CRUDE ~ATRIX SANDSTONE ~OTE: 1,)CHANNEhS WITS THE EXTENSION P$1 ARE FRO~ BLUELINE PASS 2,)CHANNELS WITH TME EXTENSION PS2 ARE FRO~ B~UELINE PASS 3,)CHANNELS WITH THE EXTENSION PS3 ARE FROM BLUELINE PASS 4 )CHANNELS WITH THE EXTENSION PS4 ARE FRO~ BbUELINE PASS 4 5:)CNAN~!EL WITH THE EXTENSION WI, A IS HODGES LEHMANN AVERAGE NEUTRON POROSITY 6 )FILE EDIT,O0! CONTAINS DATA SAMPLED m 5' 7:)FILE EDIT.O02 CA$SING COLLAR bOCATOR'D~TA SA~,PLED ~ .083' 8,)MTEM NOT PRESENTED ON THIS LIS TAPE DUE TO IT NOT BEING ACQUIRED WHILE LOGGING WITH A CNTA TOOL ****************************************************************************** ****************************************************************************** PASS 1 DATA AVAILABLE~ 9260' TO ~ ,HbA) PASS 2 DATA AVAILABLE: 9260' TO 8708' PASS ] DATA AVAILABLE: 9260' TO 8708' PASS 4 DATA AVAILABLE: 9~60' TO 8708' ****************************** DATA FORMAT RECORD ** ~NTRY BLOCKS TYPE SIZE REPR CODE ENTR'Y 2 ! 66 0 4 ! 66 B 4 7~ 60 9 4 65 ,lin 16 1 ,66 0 ! 66 0 VP 010.H02 VERIFICATION LISTIf;G PAGE 4 ATU~ SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT API AP1 APl APl FILE SIZE SPL REPR ID EPT PHI PSi RAT CNL PSi CNL EN$ R PS2 PHI PS2 RAT PS2 NRA FS2 CNb PS2 'CNb PS2 EN$ PS2 R PS3 PHI PS3 RAT PS3 NRA PS3 CNb PS3 CNL PS3 ,R PS4 ~PH! 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VEPIWlCA?I.~N LISTIMG PAGE 1 ,_qERV ICF NA~g :EDIT DATE :~5106t~8 ORIGTN : CONTI~q[~A~IO~ ~ :01 PRMVTO~S REEL CO~MRNTS :T,I~R5RY TAPE ** TAP~' WEADFR ** ,~ERVTCE DATE OR.T. GT.N :0000 TAPE MAiM :0474 CONT!NI~A~InN PREVIOUS TAPM : CDWMMNTS :T,IBRARY ********** EOF ********** ** FTBM NEADER ** FILE NAME :EDTT ,001 SERVICE NA~E VERSION DATE : ~A×i~[,J~ LEMGTH : 1024 ~ILE TYPM : PRMVTOU$ F'Tb~ ** INF~R~ATION RMCORDS ** MN~ CONTENTS CN ! SOHIO ALASKA ,PMTROI,EUM COMPANY WN : ~'34 ~ FN ~ PRUD~OE BAY ~AMG~ ~ECTt 35 COUN,: W.SBOP~ CTmY: 2 MNMM CONTMNT$ ** COb~ENTS ** UNIT TYPE CATE SIZE CODE 000 000 030 065 000 000 020 065 000 000 012 065 000 000 004 065 000 000 OO4 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 OOq 065 UNIT TYPE CATE SiZE CODE 000 000 001 065 LVP ~.1~.~40~ VEPIFICATI~N LISTI~IG PAGE 2 * SCM[,U~BMRGEP * * Ab~SKA cnNPUTING CENTER * ************************************************************************************ COMPANY : SOHIO A~,ASKA PE?ROhEU~ COMPANY WELL : A-BUS FIFLD : PRUDHOE BAY COUNTY : NOR~ SLOPE BoROUgH STAT~ : ALASKA JOB N!J~BER AT aCC: 70474 RU~ ~1., DATE bnGGED: 2~ ~A¥ 95 LOP: L.B,CI~DME¥ CASING TYPE FLUID DEW$ITY VISCOSITY WbUID LOSS = 9,695" ~ 877P' ' }{IT SIZE = ~.5" = CbS = 8.8 bg/S Rg = 3~.0 $ R~F : 9.5 R~C : 10,0 C3 R~ ~T BHT 4,460 m 68,~ DF 4,020 ~ 68, DF 3.860 *. 68 ? 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