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Home My WebLink About204-1937. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU J-23A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-193 50-029-21712-01-00 11406 Conductor Surface Intermediate Scab Liner / Liner Liner 9044 80 2634 9014 2797 2713 11318 20" 13-3/8" 9-5/8" 7" 4-1/2" 9048 29 - 109 29 - 2663 27 - 9041 6269 - 9066 8693 - 11406 29 - 109 29 - 2663 27 - 8431 5924 - 8454 8108 - 9044 11316, 11317 2670 4760 5410 7500 None 5380 6870 7240 8430 9554 - 11310 4-1/2" 12.6# 13Cr80 25 - 8697 8917 - 9049 Structural 4-1/2" Baker S-3 Hydro Set Packer 8640 8060 Torin Roschinger Area Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-350-8420 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028281 25 - 8112 N/A N/A 94 921 4323 4269 210 2125 825 900 180 200 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8640, 8060 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 12:22 pm, Jun 12, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.11 17:31:08 - 08'00' Torin Roschinger (4662) RBDMS JSB 061924 WCB 8-30-2024 DSR-6/12/24 ACTIVITY DATE SUMMARY 6/7/2024 ***WELL FLOWING ON ARRIVAL*** (DRIFT/ADPERF) MIRU AKEL, SHUT IN WELL PT 250 LP 3000 HP, FUNCTION TEST WLVS RIH WITH 20' OF 2.875" DUMMY GUNS DEVIATED OUT AT 9785' LAY DOWN FOR THE EVENING, NOTIFY PAD OPERATOR ***JOB CONTINUES ON 08-JUN-24 WSR*** 6/8/2024 ***WELL SHUT IN ON ARRIVAL*** (ADPERF) MIRU AKEL TEST 250 LP 3000 HP, FUNCTION WLVS PERFORATE THE FOLLOWING ZONES WITH 2.75" GEO RZR CHARGES 60 DEGREE PHASE (9646-9662) CCL STOP DEPTH= 9633.4' (CCL-TS=12.6') (9610-9630) CCL STOP DEPTH= 9601' (CCL-TS=9') (9554-9574) CCL STOP DEPTH=9545' (CCL-TS=9') CORRELATED TO BAKER RPM DATED 03-OCT-23 RDMO AKEL ***WELL SHUT IN ON DEPARTURE NOTIFY OPERATOR*** Daily Report of Well Operations PBU J-23A (9554-9574) (9646-9662) (9610-9630) () () Adperfs are shown correctly on WBS below. -WCB 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU J-23A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-193 50-029-21712-01-00 11406 Conductor Surface Intermediate Scab Liner / Liner Liner 9044 80 2634 9014 2797 2713 11318 20" 13-3/8" 9-5/8" 7" 4-1/2" 9048 29 - 109 29 - 2663 27 - 9041 6269 - 9066 8693 - 11406 29 - 109 29 - 2663 27 - 8431 5924 - 8454 8108 - 9044 11316, 11317 2670 4760 5410 7500 None 5380 6870 7240 8430 9666 - 11310 4-1/2" 12.6# 13Cr80 25 - 8697 8997 - 9049 Structural 4-1/2" Baker S-3 Hydro Set Packer 8640, 8060 8640 8060 Torin Roschinger Area Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028281 25 - 8112 N/A N/A 45 92 1546 1549 232 320 1000 875 160 180 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 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 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2024.02.15 13:15:51 -09'00' Aras Worthington (4643) By Kayla Junke at 2:39 pm, Feb 15, 2024 DSR-2/25/24WCB 2024-06-25 RBDMS JSB 022824 ACTIVITY DATE SUMMARY 12/21/2023 ****WELL FLOWING ON ARRIVAL*** (Perforating) DRIFT w/ 3.25" CENT & 3" S. BAILER TO DEVIATION AT 9,806' SLM (~81* Deviation) ***CONTINUED ON 12/22/23 WSR*** 12/21/2023 (Assist SL) TFS 3, Travel to location ***Job continued on 12/22/2023*** 12/22/2023 ***Job continued from 12/21/2023*** Temp = S/I T/I/O = 1600/1600/0 TFS UNIT 3 Assist SL with Brush and flush.Pumped 9 BBLS 60/40 and 35 BBLS crude to Freeze protect the Flowline. Pumped 235BBLS crude to Pump SL down. FWHP=0/1500/0 12/22/2023 ***CONTINUED FROM 12/21/23 WSR*** DRIFTED W/ 30'x2 7/8" DUMMY GUNS w/ 3.16" SWELL RING TO 9,726' SLM, LRS PUMPED DOWN TO 9819' SLM AND STALL. POOH AND RECONFIGURE TS. DRIFTED W/ 20'x2 7/8" DUMMY GUNS w/ 3.16" SWELL RING TO 9,819' SLM. LRS PUMPED DOWN TO 9839' SLM AND STALL. UNABLE TO MAKE TARGET DEPTH OF 9950'. ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 12/26/2023 T/I/O = SSV/1520/20. Temp = SI. Bleed IAP (Ops). PBGL = 1520 psi, SI @ BV. IA FL @ 8350' (201' above sta # 1 DMY). Bled IAP to OT to 440 psi in 2 hrs. PBGL tracked IA bleed. Schedueled grease service. No monitor. Final WHPs = SSV/440/20. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 2/3/2024 *** WELL SI ON ARRIVAL *** PT PCE 250LP-3000HP RAN 2-3/4" X 21' 6 SPF, 60 DEG PHASED GEO RAZOR GUN TO 9800' MD, TRACTOR FROM 9800' - 9960' CORRELATION PASS FROM 9950-9500' CORRELATED TO MWD D6R LOG DATED 10/19/04. SHOT INTERVAL: 9894-9915' WITH 21' 2.75" 6 SPF, 60 DEG, 15 GM RAZOR CHARGES *** JOB CONTINUED ON 4-FEB-2024**** 2/4/2024 *** JOB CONTINUED FROM 3-FEB-24 *** PT PCE 250LP - 3000PSI HP LOG CORRELATED TO SPERRY MWD D6R LOG DATED 19-OCT-04 RAN 2-3/4" X 21' 6 SPF, 60 DEG PHASED GEO RAZOR GUN TO 9800' MD, TRACTOR FROM 9800' - 10020' SHOT INTERVAL: 9873-9894' WITH 21' 2.75" 6 SPF, 60 DEG, 15 GM RAZOR CHARGES SHUT DOWN SO TRACTOR CAN BE SERVICED. *** JOB CONTINUED ON 5-FEB-24 **** Daily Report of Well Operations PBU J-23A SHOT INTERVAL: 9873-9894' SHOT INTERVAL: 9894-9915' Daily Report of Well Operations PBU J-23A 2/5/2024 *** JOB CONTINUED FROM 4-FEB-2024 *** PT 250LP AND 3000 HP RAN 2-3/4" X 20' 6 SPF, 60 DEG PHASED GEO RAZOR GUN TO 9800' MD, TRACTOR FROM 9800' - 10100' SHOT INTERVAL: 9853-9873' WITH 21' 2.75" 6 SPF, 60 DEG, 15 GM RAZOR CHARGES RAN 2-3/4" X 20' 6 SPF, 60 DEG PHASED GEO RAZOR GUN TO 9800' MD SHOT INTERVAL: 9754-9768' WITH 14' 2.75" 6 SPF, 60 DEG, 15 GM RAZOR CHARGES *** JOB CONTINUED ON 6-FEB-2024 *** 2/6/2024 *** JOB CONTINUED FROM 5-FEB-24 *** PT TO 250 LP AND 3000 HP LOG CORRELATED TO SPERRY MWD D6R LOG DATED 19-OCT-04 RAN 2-3/4" X 12' 6 SPF, 60 DEG PHASED GEO RAZOR GUN. SHOT INTERVAL: 9731-9743' WITH 12' 2.75" 6 SPF, 60 DEG, 15 GM RAZOR CHARGES RAN 2-3/4" X 16' 6 SPF, 60 DEG PHASED GEO RAZOR GUN. SHOT INTERVAL: 9666-9682'' WITH 16' 2.75" 6 SPF, 60 DEG, 15 GM RAZOR CHARGES WELL LEFT SI ON DEPARTURE. *** JOB COMPLETED *** Adperfs are correctly shown on the new WBS, below. -WCB SHOT INTERVAL: 9731-9743' SHOT INTERVAL: 9853-9873' SHOT INTERVAL: 9754-9768' SHOT INTERVAL: 9666-9682'' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231017 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE Mechanical Cutter Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Tubing Punch/RCT PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN Please include current contact information if different from above. T38062 T38063 T38065 T38064 T38066 T38067 T38068 T38069 T38072 T38073 T38074 T38075 T38076 10/20/2023 T38070 T38071 PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 08:34:04 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU J-23A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-193 50-029-21712-01-00 11406 Conductor Surface Intermediate Scab Liner / Liner Liner 9044 80 2634 9014 2797 2713 11318 20" 13-3/8" 9-5/8" 7" 4-1/2" 9048 29 - 109 29 - 2663 27 - 9041 6269 - 9066 8693 - 11406 29 - 109 29 - 2663 27 - 8431 5924 - 8454 8108 - 9044 11316, 11317 2670 4760 5410 7500 None 5380 6870 7240 8430 9687 - 11310 4-1/2" 12.6# 13Cr80 25 - 8697 9009 - 9049 Structural 4-1/2" Baker S-3 Hydro Set Packer 8640, 8060 8640 8060 Torin Roschinger Area Operations Manager Josh Stephens josh.stephens@hilcorp.com 907.777.8420 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028281 25 - 8112 N/A N/A 55 65 3032 3639 260 492 900 875 160 180 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 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 10:35 am, Oct 11, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.10.11 04:50:40 -08'00' Torin Roschinger (4662) RBDMS JSB 101223 WCB 3-14-2024 DSR-10/13/23 ACTIVITY DATE SUMMARY 10/2/2023 ***WELL FLOWING ON ARRIVAL MIRU HES RE-BUILD WP / PREPARE EQUIPMENT WAIT ON WATER CONTINUE AWGR 3 OCT 2023 *** 10/3/2023 **** CONTINUING FROM AWGR 02-OCT-2023 MIRU HES E-LINE PT PCE 300PSI LOW 3000PSI HIGH FREEZE PROTECT FLOWLINE LOG BAKER SPN PASSES FIRST PASS 9820' TO 9008' SECOND PASS 9820' 9000' CONTINUING ON AWGR 04-OCT-2023 **** 10/3/2023 T/I/O= 1150/750/0 (Assist E-Line) TFS U-3, Pumped 9 bbls 60/40 and 34 bbls crude down FL for (westside recipe) FP. Pumped 260 bbls 1% KCL to load TBG and 507 bbls for logging. ***Job Continued on 10-4-23*** 10/4/2023 ***Job Continued from 10-3-23*** (Assist E-Line) TFS U-3, Pumped 83 bbls 1%KCL for logging, Pumped 1.5 bbls 60/40 and 38 bbls crude for TBG FP. FWHP= 0/700/0 E-Line in control of well upon departure. 10/4/2023 **** CONTINUE FROM AWGR 03-OCT-2023 SECOND SPN PASS FROM 9820' TO 9000' CORRELATE TO SPERRY DGR ATED 19-OCT-04 PERFORATE 9687' TO 9717' WITH 2.875" 6SPF 60PHASE HSC W/MAXFORCE CHARGES CCL TO TOP TS=21.1', CCL STOP AT 9665.9' RDMO HES E-lINE ***WELL S/I UPOND DEPARTURE*** Daily Report of Well Operations PBU J-23A PERFORATE 9687' TO 9717' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU J-23A Mill Plugs, Squeeze Perfs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-193 50-029-21712-01-00 11406 Conductor Surface Intermediate Scab Liner / Liner Liner 9044 80 2634 9014 2797 2713 11318 20" 13-3/8" 9-5/8" 7" 4-1/2" 9048 29 - 109 29 - 2663 27 - 9041 6269 - 9066 8693 - 11406 29 - 109 29 - 2663 27 - 8431 5924 - 8454 8108 - 9044 11316, 11317 2670 4760 5410 7500 None 5380 6870 7240 8430 9695 - 11310 4-1/2" 12.6# 13Cr80 25 - 8697 9014 - 9049 Structural 4-1/2" Baker S-3 Hydro Set Packer 8640, 8060 8640 8060 Torin Roschinger Area Operations Manager Josh Stephens josh.stephens@hilcorp.com 907.777.8420 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028281 26 - 8112 Perforations from 9065' - 9253'MD Squeeze 6-bbls of 15.8-ppg Class G cement into perforations with final squeeze pressure =1700-psi. 6 27 7879 2023 18 308 300 1700 160 180 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:01 pm, Aug 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.21 12:37:14 -08'00' Torin Roschinger (4662) DSR-8/21/23 RBDMS JSB 082423 WCB 3-12-2024 ACTIVITY DATE SUMMARY 8/6/2023 CTU#9 1.75" Coil x 0.156" Job Scope: Mill 2 CIBPs, Squeeze Perfs MIRU. ***Job In Progress*** 8/7/2023 CTU#9 1.75" Coil x 0.156" Job Scope: Mill 2 CIBPs, Squeeze Perfs BOP test, drifted coil, MU & RIH w/YJ 3.70" Venturi & Burnshoe BHA, encountered injector issues. POOH to troubleshoot, at surface LD YJ BHA, then swapped balance valve per SLB mechanic. RBIH with same. At 5200' encountered same injector issue, POOH. Swapped counter balance valves, RBIH. Tag top plug at 9116'. Milled and pushed to second plug top (9171'). ***Job In Progress*** 8/8/2023 CTU#9 1.75" Coil x 0.156" Job Scope: Mill 2 CIBPs, Squeeze Perfs RIH w/ YJ 3.70" Venturi & Burnshoe BHA. Tag top plug at 9116' CTMD. Milled and pushed to second plug top (9171'). POOH. Recovered plug 1 slips and debris. MU Junk Mill & RIH going after second plug. Dry tag CIBP @ 9193 CTMD'. Milled 5 hrs - made ~1', then started seeing ~10k over pulls. Trip for venturi/burnshoe. MU & RIH w/ YJ 3.70" venturi/burnshoe BHA. Tag CIBP at 9192' CTMD. Mill/push downhole to PBTD at 11329' CTM. Perform injectivity test: 5 bpm @ 810 psi. POH. ***Job In Progress*** 8/9/2023 CTU#9 1.75" Coil x 0.156" Job Scope: Mill 2 CIBPs, Squeeze Perfs LD YJ 3.70" Venturi & Burnshoe BHA. Minimal recovery in Venturi basket. MU NS 4- 1/2" CBP and RIH. Set CBP at 9330'. POH. Ball recovered. Stack down. Change Packoffs. RIH w/ 2.0" BDJSN. Tag CIBP and correct depth to 9330'. Puh to 9000'. Bullhead 110 bbls diesel to underbalance well. 1 bpm Injectivity down Coil = 1bpm @ ~ 1070psi. Squeezed Sag & Z4 Perfs: pumped 16.2 bbls of 15.8 ppg CMT, squeezed 6 bbls behind pipe with 5 hesitations, final squeeze pressure = 1700 psi. Cement In Place at 21:50 hrs. Contaminate with PowerViz down to CBP at 9330', maintaining 500 psi WHP. Decreased target WHP after contamination pass, maintaining 1:1 returns with WHP 50-200 psi. Chase OOH at 80% annular velocity, jetting jewelry. ***Job In Progress*** 8/10/2023 CTU#9 1.75" Coil x 0.156" Job Scope: Mill 2 CIBPs, Squeeze Perfs Continue POH after cement squeeze, jetting jewelry. Jet BOPs. LD cementing BHA. Ball recovered from BDJSN. WOC. 12 hours to 1000 psi compressive strength. MU & RIH w/ YJ 3.70" Milling BHA. Took 6 bbls to catch pressure. Pressure up to 650psi. Lost 395psi in 5 mins. LLR ~ 0.2 bpm at ~ 650psi. Discuss with OE. Continue RIH to mill plug. Dry Tag at 9081'. Mill Cement Stringers from 9081 - 9106. RIH freely to 9265'. Attempt to mill; stacking weight but no motor work. Make bit trip; motor is shot. Change out motor and mill and RBIH. ***Job In Progress*** Daily Report of Well Operations PBU J-23A Job Scope: Mill 2 CIBPs, Squeeze Perfs MU NS 4- 1/2" CBP and RIH. Set CBP at 9330'. jy Squeezed Sag & Z4 Perfs: pumped 16.2 bbls of 15.8 ppg CMT,g g squeezed 6 bbls behind pipe with 5 hesitations, final squeeze pressure = 1700 psi. Cement In Place at 21:50 hrs j RBIH. Tag top plug at 9116'. Milled and pushed to second plug top (9171') Tag top plug at 9116' CTMD. Milled and gg pushed to second plug top (9171'). POOH. Recovered plug 1 slips and debris. MU g( )g Junk Mill & RIH going after second plug. Dry tag CIBP @ 9193 CTMD'. Milled 5 hrs -gg g yg @ made ~1', then started seeing ~10k over pulls. Trip for venturi/burnshoe. MU & RIHg w/ YJ 3.70" venturi/burnshoe BHA. Tag CIBP at 9192' CTMD. Mill/push downhole to PBTD at 11329' CTM. Daily Report of Well Operations PBU J-23A 8/11/2023 CTU#9 1.75" Coil x 0.156" Job Scope: Mill 2 CIBP's, Squeeze Perfs RBIH with YJ 2-7/8" Milling Assembly after changing out motor and mill. Tag at 9275'. Mill through cement restriction easily. Wash/ream in hole to CBP. Tag CBP at 9338'. Mill CBP and start pushing to bottom. Push CBP to TD at 11,323' ctm. Pooh. Freeze Protect Tbg w/ Diesel to 2500' tvd. Rig Down CTU. ***Job Complete*** RBIH with YJ 2-7/8" Milling Assembly after changing out motor and mill. Tag at 9275'.gy gg g Mill through cement restriction easily. Wash/ream in hole to CBP. Tag CBP at 9338'. gy g Mill CBP and start pushing to bottom. Push CBP to TD at 11,323' ctm. 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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 J-23A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-193 50-029-21712-01-00 11406 Conductor Surface Intermediate Production Liner 9044 80 2634 9014 2797 2713 9198 20" 13-3/8" 9-5/8" 7" 4-1/2" 8580 29 - 109 29 - 2663 27 - 9041 6269 - 9066 29 - 109 29 - 2663 27 - 8431 5924 - 8454 8108 - 9044 None 2670 4760 5410 7500 9198 5380 6870 7240 8430 9065 - 11310 4-1/2" 12.6# 13Cr80 25 - 8697 8453 - 9049 Structural 4-1/2" Baker S-3 Hydro Set Packer 8640 8640 8060 Stan Golis Sr. Area Operations Manager John Condio - (C) John.Condio@hilcorp.com 907 564 4696 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 0028281 No SSSV Installed 26 - 8112 8060 N/A N/A 229 694 8275 52362 48 72 250 1850 156 1598 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: 8693 - 11406 By Meredith Guhl at 10:49 am, Jan 03, 2022 N/ADigitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.12.30 17:18:05 -09'00' Stan Golis (880) MGR18JAN2022 SFD 8/15/2022 RBDMS HEW 1/3/2022 DSR-1/3/22 ACTIVITY DATE SUMMARY 12/7/2021 *** WELL FLOWING ON ARRIVAL *** JOB SCOPE: (ADPERF) T-BIRD FP FLOWLINE & LOADS TBG W/ 138 BBLS CRUDE. RIH W/ 2-7/8" X 10' GEO RAZOR PERF GUN. TAG TOP OF EVO PLUG AT 9193'. PERFORATE INTERVAL 9160' - 9170'. CCL - TS = 10'. CCL STOP= 9150'. REFERENCE LOG PERF DEPTHS = 9152' - 9162'. CORRELATED TO SLB PERF RECORD 6/16/2018. ***JOB COMPLETE / TURN WELL OVER TO POP*** 12/7/2021 T/I/O=2100/250/0, Assist Slickline(Perforating) Freeze protected flowline w/ 9 bbls of 60/40 Methanol and 27 bbls of Crude per DSO. Pumped 3 bbls 60/40 followed by 138 bbls crude down tubing, FWHP=1800/250/0, Tag hung on WV. Eline in control of well upon departure. Daily Report of Well Operations PBU J-23A PERFORATE INTERVAL 9160' - 9170'. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-193 6.50-029-21712-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11406 9198 8759 8640 None 9198 8060 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 29 - 109 29 - 109 Surface 2634 13-3/8" 29 - 2663 29 - 2663 5380 2670 Intermediate 9014 9-5/8" 27 - 9041 27 - 8431 6870 4760 Liner 2797 7" 6269 - 9066 5924 - 8454 7240 5410 Perforation Depth: Measured depth: 9065 - 11310 feet True vertical depth:8453 - 9049 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 8697 26 - 8112 8640 8060Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 2713 4-1/2" 8693 - 11406 8108 - 9044 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1003325 439234 1700198 180 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9044 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028281 PBU J-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 419 47804 173 By Samantha Carlisle at 1:57 pm, Sep 09, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.09 12:32:28 -08'00' Stan Golis (880) RBDMS HEW 9/10/2021 MGR14OCT2021 DSR-9/9/21 ACTIVITY DATE SUMMARY 8/21/2021 T/I/O=2300/275/0 (TFS Unit 2 Assist E-Line with Load and Log) Pumped 180 bbls of crude down the tbg to load. Pumped 60 bbls of crude down the tbg to assist E-Line with log (Total crude=240 bbls) FWHP=50/275/0 E-Line still on well upon departure. 8/21/2021 ***WELL SHUT IN ON ARRIVAL*** MIRU HES ELINE. RIH W/ STP LOGGING TOOLS. DEVIATE OUT AT 9848'. BULLHEAD/LOAD TBG W/ 180 BBLS CRUDE THEN REDUCE TO 1BPM. PERFORM STATION STOPS AT 9000', 9150', 9200' & 9300'. SUSPECT TOP OF PATCH 9235'-9263' IS TAKING 75% OF FLUID. PATCH LOOKS ON DEPTH. SET 4.5" HES EVO PLUG WITH MID ELEMENT AT 9200'. TOP OF PLUG AT 9198'. CCL TO MID ELEMENT 17.8', CCL STOP DEPTH AT 9182.2' DEPTHS CORRELATED TO SLB PERF RECORD DATED 16-JUNE-2018 RIG DOWN ELINE. ***JOB COMPLETE / TURN OVER TO PAD-OP TO POP*** Daily Report of Well Operations PBU J-23A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-193 6.50-029-21712-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11406 11318 9049 8640 None None 8060 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 29 - 109 29 - 109 Surface 2634 13-3/8" 29 - 2663 29 - 2663 5380 2670 Intermediate 9014 9-5/8" 27 - 9041 27 - 8431 6870 4760 Production 2797 7" 6269 - 9066 5924 - 8454 7240 5410 Perforation Depth: Measured depth: 9065 - 11310 feet True vertical depth:8453 - 9049 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 8697 26 - 8112 8640 8060Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 2713 4-1/2" 8693 - 11406 8108 - 9044 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 879900425 23143744 300 9713 430 1153 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9044 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Patch Perforations Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028281 PBU J-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 3:15 pm, Aug 04, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.04 14:43:11 -08'00' Stan Golis (880) DSR-8/4/21 RBDMS HEW 8/5/2021 MGR04AUG2021 ACTIVITY DATE SUMMARY 7/23/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(45 kb patch set) RIH W/ BAKER 45 FLOGARD 1-RUN PATCH. SET PATCH FROM 9245' - 9271' (Tie-In Log Depth) / ( 9237' - 9263' Reference Log Depths) TOP OF PATCH @ 9235'. MIN ID= 2.45". OAL = 33.10'. CORRELATED TO SLB PERFORATION RECORD DATED 16-JUN-2018. ***JOB COMPLETE / TURN OVER TO PAD-OP TO POP*** 7/23/2021 T/I/O= 2350/320/20. Assist E-Line (PATCH / LINER). Pumped 200 BBL's of 1% KCl with safe lube down the TBG. Freeze protected with 40 BBL's of of crude. Final T/I/O = 0/320/0. Daily Report of Well Operations PBU J-23A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-193 6.50-029-21712-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11406 11318 9049 8640 None None 8060 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 29 - 109 29 - 109 Surface 2634 13-3/8" 29 - 2663 29 - 2663 5380 2670 Intermediate 9014 9-5/8" 27 - 9041 27 - 8431 6870 4760 Production 2797 7" 6269 - 9066 5924 - 8454 7240 5410 Perforation Depth: Measured depth: 9065 - 11310 feet True vertical depth:8453 - 9049 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 8697 25 - 8112 8640 8060Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 2713 4-1/2" 8693 - 11406 8108 - 9044 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 989950154129 49713 900 10761 25 879 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9044 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Retrieve patch, PX plug Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028281 PBU J-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 3:01 pm, Jun 28, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.28 13:37:52 -08'00' Stan Golis (880) SFD 6/29/2021MGR30JUL2021RBDMS HEW 6/30/2021DSR-6/28/21 ACTIVITY DATE SUMMARY 6/6/2021 ***WELL FLOWING ON ARRIVAL***(profile mod). RAN 2-7/8" BRUSH, 2.30" GAUGE RING TO X NIPPLE @ 9,257' MD. SET 2.313" PX PLUG BODY @ 9,257' MD. RAN 2-7/8" CHECK SET TO PX PLUG BODY @ 9,257' MD (sheared). SET P-PRONG IN PX PLUG BODY @ 9,257' MD. ***WELL LEFT S/I ON DEPARTURE, JOB COMPLETE*** 6/11/2021 T/I/O = 930/920/20. Temp = 97°. Bleed IAP to CLP (for DP). No AL. IA FL @ 6270' (Between Sta #2 & 3, domes, 335 bbls). Bled IAP to production (J-20 from 920 psi to 350 psi in 1.75 hrs. Monitor for 30 min. WHPs and IA FL unchanged. Final WHPs = 930/350/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:45 6/17/2021 T/I/O= 2400/325/0 TFS Unit # 2 (Assist SL) Pumped 197 bbls crude down TBG to assist Slickline pull patch. Slickliine unable to pull patch, released from job. 6/17/2021 ***WELL S/I ON ARRIVAL*** (drift / tag for rate) **PATCH STUCK ACROSS TREE** ATTEMPT TO LATCH PRONG INSIDE OF PATCH, SD @ -3.6' SLM, (~5' insdide patch) RAN LIB'S TO TOP OF PATCH INDICATING JAGGED F/N OF KB PACKER T-BIRD LOADED TBG W/ 178bbls CRUDE AND PATCH FELL TO 2' SLM RAN 3.70" x 2.65" RELEASABLE SPEAR AND RECOVERED THE TOP 21" OF 45KB PACKER RAN 3.70" LIB TO TOP OF REMAINING PATCH @ 337' SLM, TAP DOWN TO 387' SLM (impression of top of remaining patch) RAN 3.70" WFD RELEASABLE SPEAR, UNABLE TO LATCH, TAP / PUMP DOW N TO SVLN @ 2,085' MD RAN 3.70" WFR RELEASABLE SPEAR, UNABLE TO LATCH @ 2,085' MD. ***JOB INCOMPLETE, ~27' PATCH LEFT IN HOLE*** 6/25/2021 ***WELL S/I ON ARRIVAL***(fishing patch) FISHED COMPLETE 45KB PATCH FROM SSSVN @ 2043' SLM. ***WSR CONT ON 6/26/21*** 6/26/2021 ***WSR CONT FROM 6/25/21*** DRIFT TO 9550' SLM W/ 3.70 CENT, 4 1/2 BLB 4 1/2 WIRE GRABS(no recovery. one element and one lock-ring) ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU J-23A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-193 6.50-029-21712-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11406 11318 9049 8640 None None 8060 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 29 - 109 29 - 109 Surface 2634 13-3/8" 29 - 2663 29 - 2663 5380 2670 Intermediate 9014 9-5/8" 27 - 9041 27 - 8431 6870 4760 Liner 2797 7" 6269 - 9066 5924 - 8454 7240 5410 Perforation Depth: Measured depth: 9065 - 11310 feet True vertical depth:8453 - 9049 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 8697 26 - 8112 8640 8060Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hydro Set Packer Liner 2713 4-1/2" 8693 - 11406 8108 - 9044 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 20425006456047455 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9044 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Patch Perforations Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028281 PBU J-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 146 10409 210 1080925 By Meredith Guhl at 9:40 am, May 28, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.27 14:49:25 -08'00' Stan Golis (880) RBDMS HEW 6/7/2021 SFD 6/16/2021DSR-5/28/21MGR27JUL2021 ACTIVITY DATE SUMMARY 4/17/2021 ***WELL FLOWING ON ARRIVAL*** (profile mod) THUNDERBIRD LOADS TBG w/ 212 bbls 1% SKL. RAN 45KB PACKER DRIFT (3,70" MAX OD, 30' OAL) TO S/D IN DOGLEG @ 9,703' SLM. RAN READ CCL/CBL/40 ARM CALIPER FROM 9,820' SLM - 8,600' SLM. (Good Data) ***JOB COMPLETE, WELL LEFT S/I*** 4/17/2021 T/I/O=2400/500/0 ( TFS Unit 2 Assist Slickline with Load and Log) Pumped 2 bbls of 60/40 followed by 212 bbls of 1% SKL down the tubbing to load. Pumped 253 bbls of 1% SKL (Total=465) down the tbg to assist SL with log. FWHP=0/420/0 Slickline still on well upon departure. 4/22/2021 T/I/O = 2080/1810/0. Temp = 132°. WHPs (Check GLT). No AL. IA FL @ 7603' (#2 Dome, 359 bbls). SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:40 4/25/2021 T/I/O = 2080/1820/20. Temp = 133*. Bleed IAP (For DP). No AL. IA FL @ 7603' (#2, dome). Bled the IAP from 1820 psi to 1000 psi in 1 hour (Production, #08). No change in the IAP or the IA FL during the 30 minute monitor. FWPs = 2080/1000/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:20 5/9/2021 T/I/O= 2500/875/0 Assist E-Line Pump Down (Profile Mod) Pumped 2 bbl 60/40 methanol followed by 140 bbl 1% KCL w/ Safelube to pump E-line down hole. Freeze protected surface lines w/ 1 bbl 60/40 methanol. FWHP= 100/875/0 IA/OA=OTG E- Line in control of well upon departure. 5/9/2021 WELL FLOWING UPON ARRIVAL, SHUT WELL IN AND LOAD WITH SAFE LUBE. NO ISSUES GETTING PATCH TO DEPTH. PATCH GOT HUNG UP ON PERFS AT 9256' - 9261'. DROP DOWN AND TRY AGAIN TOOLS HUNG UP 3' AWAY FROM SET DEPTH. ABLE TO FALL BACK DOWN. DICISION TO TRY AND PULL INTO POSITION AND SET PATCH. ABLE TO GET TOOLS INTO POSITION. SET PATCH FROM 9250' - 9273' (9242'-9265' Ref Log) W/ 2.313" X-NIPPLE IN PATCH @ 9257' MD (REFERENCE LOG DEPTH). CCL - TOP ELEMENT = 12.6', CCL STOP DEPTH = 9237.4' 5/10/2021 BLEED TUBING DOWN 100 PSI TO UNDER BALANCE WELL. PERFORATE INTERVAL 9073' - 9100' (REFERENCE LOG DEPTHS 9065' - 9092), CCL TO TOP SHOT = 10.9', CCL STOP DEPTH = 9062.1'. JOB COMPLETE 5/10/2021 T/I/O= 1170/917/19Load TBG with 150 bbls diesel and FP FL with 9 bbls meth and 37 bbls crude per WOA . SV WV SSV closed, MV open CV OTG FWHP= 900/872/14 Daily Report of Well Operations PBU J-23A Samuel Gebert Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/23/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU J-23A (PTD 204-193) RCBL Radial Cement Bond Log 04/17/2021 Please include current contact information if different from above. PTD: 2041930 E-Set: 35043 Received by the AOGCC 04/23/2021 04/26/2021 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. (;lQ l} - L Cf- 3 Well History File Identifier Organizing (done) o Two-sided III II 111111" 111111 o Rescan Needed ""1111111 II "1111 RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~kettes, No. ~ o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date: f I L1DJ Ob I I Dale U /30/00 , I .2- 00 + '1 = TOTAL PAGES (/1'7 1_ --(ëmmt does not include cove~ Date: t? 151 ' o Other:: BY: ( Mar~ 151 Vl1P Project Proofing III 111/1/1111111111 BY: ~ 151 ·mP Scanning Preparation BY: p Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) 1/ YES III II 111111111 11111 Stage 1 Page Count Matches Number in Scanning Preparation: ~~ Date: I I /Jð/Ob If NO in stage 1, page(s) discrepancies were found: NO BY: 151 V11f NO YES BY: Maria Date: 151 111111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned III II 111/11 "'"111 BY: Maria Date: 151 Comments about this file: Quality Checked 111111111111 1111111 10/6/2005 Well History File Cover Page.doc RECEIVED O SKA OIL AND G S CONSERVATION COMMISSION N r 2 3 2013 REPORT OF SUNDRY WELL OPERATIONS Pkg3CO 1. Operations Abandon Li Repair Well Li Plug Perforations U Perforate U Other [J Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat. Shutdown Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc • • Development el Exploratory ❑ 204 -193 -0 ' 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029- 21712 -01 -00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028281 PBU J -23A • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL• 11. Present Well Condition Summary: Total Depth measured 11406 feet ' Plugs measured None feet true vertical 9044.43 feet Junk measured None feet Effective Depth measured 11318 feet Packer measured See Attachment feet true vertical 9048.22 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 110 20" 94# H-40 27 - 137 27 - 137 1530 520 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 9022 9 -5/8" 47# L -80 27 - 9049 27 - 8438.05 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9695 - 9720 feet 9780 - 9805 feet 9970 - 10460 feet 10720 - 10740 feet 10750 - 10780 feet 10890 - 10950 feet 11060 - 11210 feet 11210 - 11235 feet 11235 - 11310 feet True Vertical depth 9013.67 - 9026.27 feet 9050.01 - 9056.19 feet 9058.07 - 9060.62 feet 9059.08 - 9059 feet 9058.98 - 9059.06 feet 9059.95 - 9061.08 feet 9059.74 - 9052.76 feet 9052.76 - 9051.74 feet 9051.74 - 9048.56 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 28 - 8697 28 - 8111.82 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUN 4 ZO13 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 227 10295 188 0 996 Subsequent to operation: 308 8777 352 0 897 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorator,❑ Development el • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Ei , Gas L] WDSPLLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCO 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: X N/A Contact Nita Summerhays Email Nita.Summerh ( ilBP.com Printed Name Nita Summerhays / Title Petrotechnical Data Technician ig . i�f�� ►� %�� Phone 564 -4035 Date 5/22/2013 V I„, r , •‘ RBDMS MAY 2 8 2111 � ( Form 10 -404 Revised 10/2012 W 1 d Submit Original Only • S Daily Report of Well Operations ADL0028281 CTU #9 1.75" coil Job Objective: Add perf Arrive location, Begin rig up and prep for weekly BOPE test. 4/26/2013 «Job continued on 04 -27 -13 WSR» CTU #9 1.75" Coil Job Objective: Add perf Tie in Log: SLB PPROF dated 14- Apr -2010 Perform weekly BOPE test Passed, Rlh w/ BOT MHA and PDS logging carrier with memory gamma ray /CCL logging string, and a 3.4" drift nozzle. Tag down at 11302 ctm, come up to 10850 and start logging up to 9700, flagged coil at 10750. Came out of the hole, downloaded the logging, made a correction +17'. RIH with 30 feet preforating gun Perf gun #1: 2.88 "x 20', 2.88 "x 10' 2906 PJ Omega HMX to 10758' to 10788' Tie in log depth. Reference log depth 10750- 10780' Shot perfs 300# underbalanced. All shots fired. 1/2" ball recovered 4/27/2013 « <Job cont'd on 04- 28 -13 »> CTU #9 1.75" Coil Job Objective: Add Perf <Job cont'd from 8 - Tie in Log: SLB PPROF dated 11- Apr -2010 Note: 8' shift to reference log Perf Gun #2: 2.88" x 20' 2906 PJ Omega HMX (6 spf, 60 deg) Perforate 10728' - 10748' Tie in log depth. Reference log depth 10720- 10740' All shots fired . 1/2" ball recovered. Turn over Pad Operator to POP 4/28/2013 «Job Complete» FLUIDS PUMPED BBLS 146 60/40 METH 100 1% KCL W /SAFELUBE 246 TOTAL Casing / Tubing Attachment ADL0028281 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94# H-40 27 - 137 27 - 137 1530 520 LINER 2797 7" 26# L -80 6269 - 9066 5924.45 - 8453.71 7240 5410 LINER 2713 4 -1/2" 12.6# L -80 8693 - 11406 8108.11 - 9044.43 8430 7500 PRODUCTION 9022 9 -5/8" 47# L -80 27 - 9049 27 - 8438.05 6870 4760 SURFACE 2014 13 -3/8" 72# L -80 27 - 2041 27 - 2040.93 4930 2670 SURFACE 623 13 -3/8" 80.7# S -95 2041 - 2664 2040.93 - 2663.92 7210 4990 • TUBING 8669 4 -1/2" 12.6# 13Cr80 28 - 8697 28 - 8111.82 8430 7500 • 1 • • • Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription J -23A PACKER 6260 5847.07 7" Top Packer J -23A PACKER 8640 7989.25 4 -1/2" Baker S -3 Perm Packer J -23A PACKER 8693 8038.47 4 -1/2" BAKER LINER TOP HGR /PN J -23A PACKER 8797 8134.92 7" Top Packer TREE= 6X7 CAN FLS SAFETY NOTES: WELL ANGLE > -70° @ 9772'. WELLHEAD= McEVOY 'ACTUATOR = BAKER C' J -23A =• *44 1 = CHROME TBG*** NTWL KB. ELEV = 78.70' BF ELEV = 42.35 KOP= 9066' I i M9x Angle 94 9973 2085' H 4 -112" HES X NP, D= 3.813' I Detum MD= 952T_ Datum IV O= = 8800' SS 1 13.3/8" CSG, 72#, L-80, D= 12.347" H 2672' -A wi ■ 4 3320 TVD 0EV MME DOME RK 16 1228104 3 5772 5499 31 MG DOME RK 16 12128/04 1 9-5/8" CSG, 47#, L-80,113= 8.681" IH 4600' I — 2 7603 7101 25 KBG-2 DOME BK 16 12/28/04 1 8551 7976 _ 21 KBG-2 DMY BK 0 _11/11/12 ITOPOF r SCAB LNR H 6269' # 1 ► 8620' 4-112" HES X MR D= 3.813" I� I Minimum It? = 3.725" 8685' 1 -� r, 8640' Hr x 4-1/2' BKR S-3 HYDRO PKR D= 3.875" I l 4 -1/2" HES XN NIPPLE ►/ 8664 H 4-1 / 7 HES X NP, 1 = 3.813" �1 ' 8685' H4- 1CYHESXN MP, D= 3.725" I • • )•• A 8697' 4-1/2 wLEG, D = 3.958' N 1 1 4-12" TBG, 12.6#, 13CR -80, .0152 bpf, D= 3.958" H 869T � �L - I HEAD TT NOT LOGO I */ 1 8693' I — r X 4-12" BKR LNR TOP PKR & MGR 4 I 1 . 11114 w /i1�ACK SLV, D = 4.43" I TOP OF7" LNR H 8806' > 1 1 ��" N Il 1 1 1 9-5/8" CSG, 47 #, L -80, D = 8.681' H 9058' ► ' 4 ' • 1 14 MILLOUT WINDOW (J -23A) 9066' - 9078' I ITOP OF WHIPSTOCK H 9066' I 74 ,A ;',4' \ EZSV 9084' —411 111■ \ I TOPOFcEm iF(1a11/04), -- 9500' '/•/��,- r LNF; 1 1 1 1 1 1 • • " : Ci 2611, L 80, D ► • • = 6.276" H 9912' • FEFFORATDN SUMMARY ` REF LOG: SPERRY -SUN MWD/GR ON 1027/04 ` ANGLE AT TOP PERF: 58° @ 9695' ` Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz ' SHOT SOZ 2 -7/8" 6 9695 - 9720 0 0524/07 -2-7/8" 6 9780 - 9805 0 05/23/07- ' -- Alit, 2-7/8" 6 10720 - 1070 O 0428113 .4.4 2 - " 6 07 - 780 O 0427/13 PBTD 11318' ik 2 -12" 9970 -10460 O 10 29/[74 2 -12" 6 10890 - 10950 O 10129/04 2 -112" 6 11060 - 11210 O 1029/04 1 4-1/2 UM , 12.6 #, L -80, .0152 bpf, D = 3.958" H 11406" 2 -7/8" 6 11210 - 11310 0 0627/05 [GATE REV BY COA/IENITS DATE REV BY (X)PLUJTS PRUDHOE BAY UNT 04/20187 ORIGINAL COMPLETION 03/12/13 PJC NTIAL KB ELEVATION VVELL J-23A 10/31104 F6NL/TLH RWO 8 SIDETRACK (J -23A) 05/02/13 JRP/JMD ADPERFS (0427 - 28/13) P(3RMT No: 2041930 06/01/07 SRBIPAG AOPERFS (0523 & 24/07) All No: 50- 029 - 21712 -01 07/25/09 CS/PJC REF LOG CORRECTION (PEWS) SEC 9, T11 N, R13E, 1182' FM.. & 802" Fes. 08/09/12 RJ/JMD TREECJO (08108/12) 11/14/12 C.INYJMD GLV CIO (11/11/12) BP Bcpioration (Alaska) 4~. 1~ F' I~ ~ ~ ~ (~ .{ ~ 04/2,/,0 ~YW'~~ NO. 5511 .. C~1 {~ ~• V,c~ Alaska Data & Consulting Services Company: State of Alaska ~~ry~~' 2516 Gambsa street, suite aoo Alaska Oil & Gas Cons Comm Anehwage, AK 99603-2a3a Attn: Christine Mahnken ATiN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job N Log Description Date BL Color CD ~~ o~ ~- ~~ bK ~~ F-30 BBUO-00014 PRODUCTON PROFILE 03/17/10 1 1 12-14AL1 AYKP-00079 PRODUCTION PROFILE 03/18/10 1 1 12-15 B3SQ-00049 PRODUCTION PROFILE 03118/10 1 1 17-11 17-05 J•23A 833400053 8350-00052 BCUE-D0010 PRODUCTION PROFILE PRODUCTO4 PROFILE MEM PRODUCTKN! PROFIL C .~ 03/30/10 03/29!10 04/14110 1 1 1 i 1 1 07-18 BC72-00008 FL DETERMINATIONIPERF 04/17110 1 1 LE 04/14/10 1 1 P2-91A C-15A K-07E 83S0.00046 AWJI.00069 B2NJ-00054 CH EDIT PDC JUNK BASKET - MCNL - L MCNL oanno 02127/20 01/27/10 02/18/10 1 1 1 1 1 1 1 Ot-28A BAUJ-00004 MCNL 17118/09 1 1 or eecc wrvunwr en BP Exploration (Alaska) Inc. Petrotechnical Data Canter LR2-, 900 E. Benson Blvd. °~`y~~~f„yf~~ ~ V~ J t f 1 k~ I i '`°` J SU Alaska Oata & Consulting Services 2525 Gambell Slreal, Suits 400 Anchorage, AK 99503-2838 v • • ~, .,~ °'` ~,~. ~~ _.~.. .~ __ l 1 03~o~~zoos DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc . STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 69.64 KB <' 8. Property Designation: ADLO-028281 / 11. Present Well Condition Summary: Total Depth measured 11406/ feet true vertical 9044.43 <' feet Effective Depth measured 11318 [ feet true vertical 9048.22 / feet Casing Length Size Conductor 110 20" 94# H-40 Surface 2014 13-3/8" 72# L-80 Surface 623 13-3/8" 80.7# S-95 Liner 2334 7" 26# L-80 Liner 97 7" 26# L-80 Production 9022 9-5/8" 47# L-80 Liner 269 7" 26# L-80 Perforation depth: Measured depth: 9970 - 10460 True Vertical depth: 9058.07 - 9060.62 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl SHUT-IN SHUT-IN x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic ~ ¿ .þ-P¡7 ~(~ EIVED Stimulate D O\tJerQ " WaiverD Time Exten~i~~:D ,':;1 Re-enter Suspended Well D 5. Permit to Drill Number: 204-1930 <' TVD 27 . 137 27 - 2040.93 2040.93 - 2663.92 5924.45 - 8024.48 8024.48 . 8114.61 27 . 8438.05 8205 - 8454 11060 - 11210 9059.74 - 9052.76 13CR-80 7" Top Packer 4-1/2" Baker S-3 Hydro Set Packer 4·1/2" Top Packer 7" Top Packer Exploratory Service 9. Well Name and Number: It ,:iôs GUllS. Com ¡55; itfìCI¡ara e 6. API Number: 50-029-21712-01-00 - PBU J-23A / ._._,.1.0. Field/t;'aol(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Plugs (measured) None Junk (measured) None SCANNED JUN 1 1 200? MD 27 . 137 27 - 2041 2041 - 2664 6269 . 8603 8603 - 8700 27 - 9049 8797 - 9066 10890 - 10950 9059.95 - 9061.08 4-1/2" 12.6# Burst 1530 4930 7210 7240 7240 6870 7240 Collapse 520 2670 4990 5410 5410 4760 5410 Contact Gary Preble Surface - 8697' 6260 8640 8700 8797 RBDMS 8Fl .JUN 0 8 Z007 Tubing pressure o o Service Title Data Management Engineer Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil .P Gas WAG WINJ WDSPL Date 6/1/2007 . . J-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/21/20071***WELL S/I ON ARRIVAL***(pre ctu ad perfs) :DRIFT 3 3/8" DMY GUN W/ S-BAILER TO DEVIATION @ 9741' SLM (MAX O.D. '3.45" / OAL =164") NO SAMPLE. ***WELL LEFT S/I*** 5/22/2007CTU #8 w/I-COIL, Add Perf; MIRU. RIH w/ SLB memory GR/CCL (no I collar/jewelry log in this well). Log from 10100' ctmd up to 8500' ctmd. Stop and Iflag pipe at 9650' ctmd. POOH. Correct log +2 feet to Sperry Sun MWD-GR 27- IOct-04 tie-in log. MU and RIH with perforating assembly and i-coil sub. Continued Ion WSR OS/23/07. -" - -- 5/23/2007 CTU #8 w/ 1.75" OD i-coil. Add perf. Cont from WSR OS/22/07. Continue RIH with perforating assembly. Use i-coil ccl readout to depth correlate to memory tie-in log. Align perforation across interval and fire guns from 9780' - 9805' ELMD. Perforations are 2-7/8" HSD PJ Omega 2906 HMX, 6 spf, 60 degree phasing. to log out of hole after shot, i-coil lost functionality: no longer reading ccl, bottom hole pressures, bottom hole temperature. POOH. Inspect tool at surface, a missing component important for shock absorbtion. MU new i-coil head and second perforating assembly and RIH to depth. Standby while troubleshoot i-coil. SLB reports i-coil cannot be made to function correctly while we are on location and in hole. Decide to correlate perf off of coil flag from memory run. Correct depth at RIH past perforation interval and pull into position. Continued on WSR #8 w/ 1.75" i-coil. Perf. from OS/24/07. On depth with perforating assembly. Fire perforations from 9695' - 9720' ELMD with reference to Sperry Sun MWD-GR 27-0ct-04. Shots are PJ Omega 2906 HMX, 6 spf, 60 degree phasing. POOH while freeze protecting well with a total of 40 bbls 50/50 methanol/water. Job Complete. BBLS 40 40 FLUIDS PUMPED ISO/50 METHANOLJW A TEA TOTAL 'J () flI' 1)v ~.b DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041930 Well Name/No. PRUDHOE BAY UNIT J-23A Operator BP EXPLORATION (ALASKA) INC gf'~ ,z 3> O~ ~1 API No. 50-029-21712-01-00 MD 11406/ TVD 9044./ Completion Date 10/31/2004'/ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 9044 11406 Open 11/15/2004 IIFR I 9044 11406 Open 11/15/2004 IIFR 9044 11406 Open 11/15/2004 MWD 9044 11406 Open 11/15/2004 MWD 9027 11346 Open 1/27/2005 GRlEWR4/ABIICNP/SLD/R OP/ Open 1/27/2005 GR/EWR4/ABI/CNP/SLD/R OP/ í 9066 11406 Open 2/22/2006 Rap DGR EWR SLD CTN i ~ Sample Set Sent Received Number Comments . DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES / NEU / DEN / ABI Well Log Information: Electr Digital Dataset Med/Frmt Number Name D Asc Directional Survey Directional Survey D Asc Directional Survey Asc Directional Survey D Lis 12940 Gamma Ray 12940 LIS Verification C Lis 13505 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORM~N Well Cored? Y V Daily History Received? éDN ~N Chips Received? '{ I I~ Formation Tops Analysis Received? ~/M - Comments: Permit to Drill 2041930 MD 11406 TVD 9044 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Well Name/No. PRUDHOE BAY UNIT J-23A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21712-01-00 Completion Status 1-01L Current Status 1-0~ A \ UIC N Date: ''0 ~ if ~fc . . . . WELL LOG TRANSMITTAL ,J(YÎ ¡q 'j To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 13ED5 RE: MWD Fonnation Evaluation Logs J-23A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 J-23A: LAS Data & Digital Log Images: 50-029-21712-01 1 CD Rom &milt} ¡y / 9 ol(J(~ A..._L 1. Operations Performed: .. Abandon D Repair WellO PluQ PerforationsD Stimulate D OtherD Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time Extension 0 Change Approved Program 0 Operation Shutdown 0 Perforate IXJ Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 204-1930 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-21712-01-00 7. KB Elevation (ft): 9. Well Name and Number: 69.64 J-23A 8. Property Designation: 10. Field/Pool(s): ADL-028281 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11406 feet true vertical 9044.4 feet Plugs (measured) None Effective Depth measured 11318 feet Junk (measured) None true vertical 9048.2 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" 94# H-40 27 - 137 27.0 - 137.0 1530 520 Surface 2014 13-3/8" 72# L-80 27 - 2041 27.0 - 2040.9 4930 2670 Surface 623 13-3/8" 80.7# S-95 2041 - 2664 2040.9 - 2663.9 7210 4990 Production 9022 9-5/8" 47# L-80 27 - 9049 27.0 - 8438.1 6870 4760 Scab Liner 2334 7" 26# L-80 6269 - 8603 5924.5 - 8024.5 7240 5410 ST Liner 97 7" 26# L-80 8603 - 8700 8024.5 - 8115.0 7240 5410 ST Liner 2706 4-1/2" 12.6# L-80 8700 - 11406 8130.4 - 9044.4 8430 7500 Liner 269 7" 26# 26# L-80 8797 - 9066 8205.0 - 8454.0 7240 5410 Perforation depth: Measured depth: 9970 -10460,10890 -10950,11060 -11210,11210 -11235,11235 -11310 True vertical depth: 9058.07 - 9060.62, 9059.95 - 9061.08, 9059.74 - 9052.76,9052.76 - 9051.74, 9051.74 - 9048.56 TubinQ ( size, Qrade, and measured depth): 7" 26# L-80 @ 25 - 28 4-1/2" 12.6# 13Cr80 @ 28 - 8697 Packers & SSSV (type & measured depth): 7" Top Packer @ 6260 4-1/2" BKR S-3 Hydro PKR @ 8640 RBDMS BFl AUG () 4 ZDDS 4-1/2" Top Packer @ 8700 7" Top Packer @ 8797 4-1/2" HES X Nipple @ 2085 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: 75 33 117 205 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr " Title Petroleum Engineer Signature A?J- .A: ~ j) Phone 564-5174 Date 7/27/05 r\ ' ¡ A ¡ 7,. I ,1\ T - ....) t", ¡ C) \; ¡.,\ L. IitCE/VED . STATE OF ALASKA. AUG 0 3 2005 ALASKA OIL AND GAS CONSERVATION COM SiaN Alas/t;a. " REPORT OF SUNDRY WELL OPERATION~OIl&GasCons.Commission I , Form 1 0 404 Revised 4/2004 . . J-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/26/05 CTU #5, ADD PERF, MIRU UNIT. ***WELL SHUT-IN ON ARRIVAL*** NOTIFY PAD OPERATOR AND PCC TO POP WELL AND PUT INTO TEST SEPARATOR. WILL USE PBGL FROM J-08. WELL WILL REMAIN IN TEST SEPARATOR FOR DURATION OF PERFORATION JOB. MU AND RIH WITH GUN #1; 2-7/8" PJ-2906. REFERENCE LANDING COLLAR AT 11317" MDBKB FOR DEPTH CONTROL. PERFORATE 25', 6 SPF, FROM 11285' TO 11310'. POOH. MU AND RIH WITH GUN #2; 2-7/8" PJ-2906. REFERENCE LANDING COLLAR AT 11317' MDBKB FOR DEPTH CONTROL. PERFORATE 25',6 SPF, FROM 11260' TO 11285'. POOH. MU AND RIH WITH GUN #3; 2-7/8", PJ-2906. REFERENCE LANDING COLLAR AT 11317' MDBKB FOR DEPTH CONTROL. PERFORATE 25', 6 SPF, FROM 11235' TO 11260'. POOH. MU AND RIH WITH GUN #4; 2-7/8" PJ-2906. WSR CONTINUED ON 06/27/2005. 06/27/05 CTU #5, ADD PERF; WSR CONTINUED FROM 06/26/05........ CONTINUE RIH WITH GUN #4. REFERENCE LANDING COLLAR AT 11317' MDBKB FOR DEPTH CONTROL. PERFORATE 25',6 SPF, FROM 11210'-11235'. POOH. NOTIFY PAD OPERATOR AND PCC TO KEEP WELL FLOWING. PCC WILL GO FULL OPEN CHOKE AND PUT WELL IN TEST. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 32 50/50 METHANOL WATER 167 2% KCL WATER 199 TOTAL Page 1 TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = . . J-23A McEvoy Otis As Built ". ''1' 27.29 (.; 8.-Vf 9066 94 @ 9972' I TOP OF 7" LNR I 8619' 8640' 8664' 8684' 8692' 8697' 8692' 113-3/8" CSG, 72#, L-80, BTRS, ID = 12.347" I 2085' - HES 4-1/2" X Nipple 10 = 3.813" 19-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" I 4600' ST MD TVD 4 3320 3316 5772 5499 2 7603 7100 1 8551 7976 4-1/2" TBG, 12.6#, 13Cr-80, 10 == 3.958" I TOP OF 7" SCAB LNR H 6269' Sqeezed Perf's (4/12/87) 6790' - 6793'- Perf's (4/17/87) 8700' - 8705'- 19-5/8" CSG, 47#, L-80, BRTS, ID = 8.681" I Top of Whipstock - 9066' EZSV - 9084' ÆRFORA TION SUMMARY ANGLE AT TOP ÆRF: 94 @ 9970' Note: Refer to R'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.5 6 09970 -10460 0 10/29/04 2.5 6 10890 - 10950 0 10/29/04 2.5 6 11060 -11210 0 10/29/04 2-7/8" 6 11210 - 11310 0 06/27/05 TOC - 9500' I PBTD I I 7" LNR, 26#, L-80, IJ4S, .0383 bpf, 10 = 6.276" I GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 11.5° MMG OCR RKP 1.5" 0/30/2004 31.3° MMG DV RKP 1.5" 0/30/2004 29.8° KBG-2 DV BK 1" 0/30/2004 21.20 KBG-2 DV BK 1" 0/30/2004 4 1/2" X Nipple (3.813" ID) 7" x 4-1/2" Baker S-3 Packer 41/2" X Nipple (3.813" ID) 4 1/2" XN Nipple (3.725" ID) 41/2" Top of Liner Tieback Sleeve 4 1/2" WLEG 7" x 4.5" Hanger /Iiner top packer 4-1/2" Solid LNR, 12.6#, L-80, 11406' -5bbls squeezed into perf's REV BY COMMENTS ORIGINAL COMPLETION RN/TP CORRECTIONS CMO/KK MAX ANGLE CORRECTION McNrrL SET PA TCH (LOWER) SET 4-1/2" PA TCH ÆRF CORRECTIONS DA TE REV BY COMMENTS 10/31/04 RJB R'esent Completion 06/27/05 MDClPJC ÆRFS -i 21' OF 2.5" ÆRF GUN - 02/10/01 I PRUDHOE BA Y UNIT WELL: J-23A ÆRMIT No: 204-193 API No: 50-029-21712-01 BP Exploration (Alaska) REP~~~~~~~~~~;S~~~~N~~~~~';IO~Ee~IV;6 1. Operations Performed: . Abandon 0 Repair WellD Pluq PerforationsD Stimulate 00 A\aska ni\ & Gaft!lffi~ommIÖiIÖ Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time ~~tffiirQII Change Approved ProgramD Operation ShutdownO Perforate 0 Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development 00 ExploratoryD 5. Permit to Drill Number: 204-1930 6. API Numbel 50-029-21712-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7, KB Elevation (ft): 69.64 8. Property Designation: ADL-028281 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: J-23A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 11406 feet true vertical 9044.4 feet Effective Depth measured 11318 feet true vertical 9048.2 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse Conductor 110 20" 94# H-40 27 137 27.0 137.0 1530 520 Liner 2806 7" 26# L-80 6260 - 9066 5916.7 - 8453.7 7240 5410 Liner 2689 4-1/2" 12.6# L-80 8717 - 11406 8130.4 - 9044.4 8430 7500 Liner 24 7" 26# L-80 8693 - 8717 8108.1 - 8130.4 7240 5410 Production 9022 9-5/8" 47# L-80 27 - 9049 27.0 - 8438.1 6870 4760 Surface 2014 13-3/8" 72# L-80 27 - 2041 27.0 - 2040.9 4930 2670 Surface 623 13-3/8" 80.7# S-95 2041 - 2664 2040.9 - 2663.9 7210 4990 Perforation depth: Measured depth: 9970 - 10460, 10890 - 10950, 11060 -11210 True vertical depth: 9058.07 - 9060.62,9059.95 - 9061.08, 9059.74 - 9052.76 Tubing ( size, grade, and measured depth): 7" 26# L-80 4-112" 12.6# 13Cr80 @ 25 @ 28 28 8697 Packers & SSSV (type & measured depth): 7" Top Packer 7" Top Packer 4-1/2" Top Packer 4-112" Baker S-3 Hydro Set Packer @ @ @ @ 6260 8797 8700 8640 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9970' - 11210' Treatment descriptions including volumes used and final pressure: 68 Bbls 7.5% HCL @ 2800 psig Prior to well operation: Subsequent to operation: Oil-Bbl 25 25 Representative Dailv Averaqe Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0.9 90 903 0.9 112 900 Tubing Pressure 160 184 13 14. Attachments: ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron & C~ Title Production Technical Assistant Form 1 0-404 Revised 4/2004 4/13/05 Signature ~o~ . . J-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/10/05 OFF WEATHER STANDBY DUE TO HIGH WINDS. FINISH RIG UP. MU BHA - 2" DUAL FLAPPER CHECKS, 2"MANDREL BYPASS, 2.5" JSN. FLUID PACK WELL WITH 5 BBLS 60/40 METH, 150 BBLS 1% KCL, 50 BBLS CRUDE, 5 BBLS METH/WTR. TAG TD @ 11307' (UP-CTM). PRE ACID INJECTIVITY IS 1.4 BPM/1930 PSI WHP. SPOT 22 BBL OF 7.5% HCL ACROSS PERF INTERVAL. SOAK ACID 30 MIN'S. COTNINUED ON 02/11/05 WSR. 02/11/05 CONTINUED FROM 02/10/05 WSR. COMPLETE 30 MIN SOAK ON 22 BBL 7.5% HCL STAGE. JET 46 BBLS OF 7.5% HCL ACROSS PERFS. JET 100 BBLS KCL ACROSS PERFS. PRE-ACID INJECTIVTY = 1.4 BPM/1930 PSI WHP. POST-ACID INJECTITY = 1.15 BPM/1930 PSI WHP. POOH, KEEPING HOLE FULL. RDMO. WELL IS READY TO POP. . ***JOB IS COMPLETE*** FLUIDS PUMPED BBLS 115 60/40 Methonal 251 1 % KCL 50 Crude 68 7.5% HCL 484 TOTAL Page 1 TREE = . ELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = . . J-23A FROM DRLG - DRAFT McEvoy Otis 28.5 27.29 9066 94 @ 9972' 113-3/8" CSG, 72#, L-80, BTRS, ID" 12.347" I 2085' - HES 4-1/2" X Nipple 10 = 3.813" 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" I ST MD 1VD 4 3320 3316 5772 5499 2 7603 7100 1 8551 7976 4-1/2" TBG, 12.6#, 13Cr-80, 10 = 3.958" I TOP OF 7" SeA B LNR H 6269' Sqeezed Perf's (4/12/87) 6790' - 6793'- 8619' 8640' 8664' 8684' 8692' 8697' 8692' Perfs (4/17/87) 8700' - 8705'- I 9-5/8" CSG, 47#, L-80, BRTS, ID" 8.681" I Top of Whipstock - 9066' EZSV - 9084' ÆRFORA TION SUMMA RY ANGLE AT TOP ÆRF: 94 @ 9970' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2.5 6 9970-10460 Opn 10/29/04 2.5 6 10890-10950 Opn 10/29/04 2.5 6 11060-11210 Opn 10/29/04 TOC - 9500' I PBTD I 7" LNR, 26#, L-80, LJ4S, .0383 bpf, ID" 6.276" I GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE 11.5' MMG OCR RKP 1.5" 0/30/2004 31.3' MMG DV RKP 1.5" 0/30/2004 29.8' KBG-2 DV BK 1" 0/30/2004 21.2' KBG-2 DV BK 1" 0/30/2004 4 1/2" X Nipple (3.813" ID) 7" x 4-1/2" Baker S-3 Packer 41/2" X Nipple (3.813" ID) 41/2" XN Nipple (3.725" ID) 4 1/2" Top of Liner Tieback Sleeve 4 1/2" WLEG 7" x 4.5" Hanger /Iiner top packer 4-1/2" Solid LNR, 12.6#. L-80, 11406' -5bbls squeezed into perf's REV BY COMMENTS ORIGINAL COM PLETION RNlTP CORRECTIONS CMO/KK MAX ANGLE CORRECTION McNlTL SET PA TCH (LOWER) SET 4-1/2" PA TCH ÆRF CORRECTIONS DATE 10/31/04 REV BY COMMENTS RJB Present Completion -121' OF 2.5" ÆRF GUN - 02/10/01 I PRUDHOE BA Y UNfT WELL: J-23A ÆRMfT No: 204-193 API No: 50-029-21712-01 BP Exploration (Alaska) . . :2ßf--/93> WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 November 19, 2004 RE: MWD Formation Evaluation Logs: J-23A, AK-MW-3341819 1 LDWG formatted Disc with verification listing.. d (J 0 API#: 5(}029-217/2-OI -1t 1)...-\-' I)LEASE ACKNOWLEDGE RECEIlYj' BY SIGNING AND RETURNING A COPY OF THE TRANSMITIAL LETTER TO THE ATIENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: / /z 7 10.5 / I Signed: . STATE OF ALASKA .. ALASKA I AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG " 1a. Well Status: 181 Oil DGas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/31/2004 204-193 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/23/2004 50-029-21712-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10/2712004 PBU J-23A 1182' SNL, 802' WEL, SEC. 09, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1216' SNL, 3268' WEL, SEC. 09, T11N, R13E, UM 69.64' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ rvD) 1984' SNL, 1715' WEL, SEC. 09, T11 N, R13E, UM 11318 + 9048 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ rvD) 16. Property Designation: Surface: x- 643559 y- 5970172 Zone- ASP4 11406 + 9044 Ft ADL 028281 -~-~ ~~-- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 641094 y- 5970091 Zone- ASP4 ~~~-- -~ (Nipple) 2085' MD Total Depth: x- 642663 y- 5969353 Zone- ASP4 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost 181 Yes DNo NI A MSL 1900' (Approx.) 21. Logs Run: DIR I GR I RES I NEU I DEN I ABI 22. CASING, LINER AND CEMENTING RECORD CASING ~ETTIN<3 EPTH MD SEtTING EPTH TVD HOIl~ SIZE WT.PER FT. GRAbe lOP BOTTOM lOP I BOTTOM SIZE P(JI.:LEÓ 20" Conductor Surface 110' Surface 110' 8 cu vds Concrete 13-3/8" 72# L-80 I S-95 38' 2672' 38' 2672' 17-1/2" 3258 cu ft PF 'E', 465 cu ft PF 9-518" 47# L-80 36' 9050' 36' 8440' 12-1/4" 575 cu ft Class 'G' 7" 26# L-80 6269' 9066' 5924' 8454' 8-1/2" 375 cu ft Class 'G' 4-1/2" 12.6# L-80 8693' 11406' 8108' 9044' 6-1/8" 393 cu ft Class 'G' 23. Perforations op'en to Production (MD + rvD of Top and 24. TUB IlliG RecORb Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6spf 4-1/2", 12.6#, 13Cr80 8697' 8640' MD rvD MD rvD 9970' - 10460' 9058' - 9061' 25. ACID, FRACTlJRE,CEMENTS9uE~e,eTP, 10890' - 10950' 9060' - 9061' 11060' - 11210' 9060' - 9053' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2100' Freeze Protect with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 24, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-Oil RATIO 11/24/2004 4 TEST PERIOD ... 10.5 467 38 860 44,722 Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF W A TER-Bsl Oil GRAVITY-API (CORR) Press. 171: 1,160 24-HoUR RATE 63 2,804 228 39 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). s'r';TI!~;m~~i~S; if none, state "none". Nooe! ¿~~ RBDMS 8Fl DEC 0 7 2004 ORIGINAL !~ ' """j ;' I n_....._. .,.~.__ l,~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28~ GEOLOGIC MARKERS 29. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", Sag River 9065' 8453' None Shublik 9104' 8489' Sadlerochit 9162' 8545' Top CGL I Zone 3 9347' 8726' Base CGL I Zone 2 9405' 8783' 25N 9555' 8918' 22N 9597' 8951' 21N 9650' 8987' 14N / Zone 1B 9753' 9041' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date II /::<.,q 10 PBU J-23A Well Number 204-193 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00), ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 10/16/2004 10/23/2004 (ft) 9,066.0 (ft) (It) 8,453.0 (ft) (ppg) 8.40 (ppg) (psi) 705 (psi) FIT FIT (psi) 4,394 (psi) 10.00 (ppg) 10.01 (ppg) Printed: 11/1/2004 1 :48:29 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 3/27/1987 End: 10/31/2004 1 0/14/2004 1 0/31 /2004 Rig released from E-20A. Rig down the floor and lower the derrick. Prepare to move off of well. 10/17/2004 00:00 - 01 :00 1.00 MOB PRE Prepare rig to move off of E-20A location. Raise Sub. Pull rig mats. 01 :00 - 06:30 5.50 MOB P PRE Move rig sub off of E-20A and over to J-23A 06:30 - 09:00 2.50 RIGU P PRE PJSM. Raise the derrick and RU the rig floor. Lay herculite. IWAIT Move pits and camp from E pad to J pad. 09:00 - 12:30 3.50 RIGU N PRE Standby with full crews and wait for well house removal of adjacent well J-20. 12:30 - 16:30 4.00 RIGU P PRE Spot and level the sub base. Spot pits, camp, shop and cuttings box. Rig accepted @ 1630 hrs. 16:30 - 17:00 0.50 RIGU P DECOMP Prespud meeting with all rig personnel. 17:00 - 19:00 2.00 RIGU P DECOMP Install secondary annulus valve. OA - 0 psi. IA - 0 psi. RU DSM and pull BPV with lubricator. RU circulation lines and test to 3,500 psi - good, 19:00 - 21 :00 2.00 KILL P DECOMP Pump down the OA and remove diesel from the tubing. Swap circulation lines and pump soap pill down the tubing to remove remaining diesel freeze protection fluid. Well dead. 21 :00 - 00:00 3.00 WHSUR P DECOMP Set TWC and test from below to 1,000 psi. Blow down surface equipment. ND tree and adapter flange. 1 0/18/2004 00:00 - 02:00 2.00 BOPSU P DECOMP NU BOPE. 02:00 - 07:00 5.00 BOPSU P DECOMP Test BOPE and associated equipment to 250 psi / 3,500 psi. Test Annular to 250 psi /2,500 psi. Witness of the BOPE test was waived by Jeff Jones of the AOGCC. 07:00 - 09:00 2.00 WHSUR P DECOMP RU DSM to pull TWC with lubricator - no go. MU joint of DP and flush debris from top of TWC. Pull TWC with lubricator. RD DSM. 09:00 - 10:30 1,50 PULL P DECOMP MU landing joint to hanger. BOLDS and pull hanger to the floor - 11 OK to free. LD landing joint and hanger. 10:30 - 11 :30 1.00 PULL P DECOMP RU 4-1/2" tubing handling equipment. RU control line spooling unit. 11 :30 - 14:00 2.50 PULL P DECOMP LD 4-1/2" 12.6# BTC tubing from cut @ 5,980' ELM to SSSV @ 3,772'. 14:00 - 15:00 1.00 PULL P DECOMP LD SSSV. RD control line spooling unit. Clear the floor. 15:00 - 17:30 2.50 PULL P DECOMP LD 4-1/2" completion string from 3,772' to surface. Recovered: 148 jts 4-1/2" tubing + 20.2' cut joint, 1 SSSV, 2 GLM's, 26 clamps, 26 clamp pins, 5 SS bands 17:30 - 18:30 1.00 PULL P DECOMP RD tubing handling equipment. Clear and clean the floor. 18:30 - 20:00 1.50 BOPSU P DECOMP RU 4" test joint. Set test plug. Test rams and related valves to 250 psi / 3,500 psi. Test annular preventer to 250 psi /2,500 psi. RD test joint and pull test plug. 20:00 - 22:00 2.00 FISH P DECOMP MU Overshot BHA #1 to 965' - Guide shoe, overshot, overshot extension, xo, bumper sub, jar, 9 x 6-3/8" DC's, accelerator jar, 21 x HWDP, xo. 22:00 - 00:00 2.00 FISH P DECOMP PU 4" DP from 965' to 4,044'. 10/19/2004 00:00 - 01 :30 1.50 FISH P DECOMP PU 4" DP to 5,975' - top of fish. PU - 165K, SO - 135K, Rot- 150K, TO @ 30 rpm - 4.5K. 01 :30 - 02:00 0.50 FISH P DECOMP SO while rotating @ 30 rpm, 4 bpm, 220 psi. Observe pressure increase when over the fish. Swallow - 6' of fish. PU and set grapple @ 225K PU. Rotate on fish with max TO of 9K while maintaining 160K. Weight and torque dropped off- believe grapple slipped off. Printed: 11/1/2004 1 :48:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS2ES 1 0/14/2004 1 0/31/2004 Spud Date: 3/27/1987 End: 10/31/2004 Start: Rig Release: Rig Number: 10/19/2004 02:00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 20:00 20:00 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 22:30 22:30 - 00:00 10/20/2004 00:00 - 02:45 02:45 - 04:00 04:00 - 05:30 05:30 - 07:30 07:30 - 09:00 09:00 - 10:30 10:30 - 13:00 1.00 FISH I P DECOMP Commence jarring operations. Maximum pull to fire jars - 350K, Weight dropped off to 165K PU. SO with pumps on to verify the grapple did not slip off. Tagged up without seeing any pressure increase. DECOMP Circulate bottoms up. Well stable. DECOMP Service top drive and perform derrick inspection. DECOMP Pump dry job. Blow down surface equipment. POH from 5,975' to 965'. Change out handling equipment. DECOMP POH with BHA from 965' - no fish - broken grapple. Confer with town. DECOMP MU Overshot BHA #2 - guide, bowl, bushing, bowl, 2 x overshot extension, top sub, bumper sub, oil jars, 9 x DC's, accelerator, 21 x hwdp, xo to 972'. Change out handling equipment. DECOMP RIH w/4" DP from 972' to 5,636'. DECOMP Slip and cut drilling line. DECOMP RIH from 5,636', PU - 160K, SO - 135K, Rot - 150K. Engage fish @ 5,975' and swallow 11'. PU tp 200K and allow the jars to bleed off. PU straight pull to 310K. DECOMP CBU - 11 bpm, 1500 psi. PJSM with all personnel. DECOMP Jar on fish @ 5,975'. Stage up to 165K over string weight. LD single and blow down top drive. DECOMP RU SLB wireline w/lubricator for string shot. DECOMP RIH with SLB 8' string shot. Fire string shot from 6,230' to 6,238', POH with SLB wireline. RD lubricator DECOMP Commence jarring operations. Stage up to 190K overpull to fire jars - max pull for jars - not free. DECOMP Inspect derrick and travelling equipment. DECOMP While engaged with double grapple, attempted to rotate out. Torque went up to 8K and then dropped down to 5K. Rotate 5 turns. PU dragging fish. Saw PU of 300K straight pull dragging for the first 30' and then pulled free. PU - 165K, - 5K over. DECOMP CBU, 12 bpm, 1,300 psi. Monitor well - stable, Blow down top drive. DECOMP POH w/4" DP from 6,237' to 3,566'. DECOMP POH from 3,566' to 255'. LD Overshot BHA #2. DECOMP LD fish from 255'. Recovered 3 jts 4-1/2" tubing + 19.49' cut joint, GLM assy, SS assy, Overshot assy and K-anchor. Total length recovered 254.69'. No indication of tubing patch recovery. DECOMP Breakdown Overshot BHA #2. MU Overshot BHA #3 to fish tubing patch. DECOMP MU Overshot BHA #3 to 677' - guide shoe, bowl, extension, sub, bumper sub, jar, pump out sub, 9 x DC's, 21 x hwdp, xo. POH to change BHA. Break down overshot. LD jars. Clear floor. DECOMP Discuss options with town. Wait on Baker rolling dog tool to be delivered. Prepare for BHA #4, DECOMP MU BHA #4 to 1,017' - cut lip guide, rolling dog sub, 2 x washpipe, washover boot basket, bumper sub, jar, 9 x DC's, 21 x hwdp, xo. Changeout handling equipment. DECOMP RIH w/4" DP from 1,017' to 6,147'. PU - 162K, SO - 140K, Rot 1.00 FISH P 1.00 FISH P 2.00 FISH P 3.50 FISH P 1.50 FISH P 2.00 FISH P 1.00 FISH P 0.50 FISH P 0.50 FISH P 0.50 FISH P 1.00 FISH P 2.50 FISH P 1.00 FISH P 0,50 FISH P 0.50 FISH P 0.50 FISH P 1.50 FISH P 2.75 FISH P 1.25 FISH P 1.50 FISH P 2.00 FISH P 1.50 FISH P 1.50 FISH P 2.50 FISH P Printed: 11/1/2004 1 :48:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 10/14/2004 1 0/31 /2004 Spud Date: 3/27/1987 End: 10/31/2004 10/20/2004 10:30 - 13:00 2.50 FISH P DECOMP - 150K 13:00 - 13:30 0.50 FISH P DECOMP Wash over from 6,147' to top of the packer @ 6,225' - set down 10K. 13:30 - 14:30 1.00 FISH P DECOMP CBU, 13 bpm, 1650 psi. Saw some sand come across the shakers on bottoms up. Monitor well - stable. 14:30 - 16:30 2.00 FISH P DECOMP Pick up and engage tubing patch collar. POH to 1,017' 16:30 - 18:00 1.50 FISH P DECOMP Stand back BHA#4 from 1,017' to 92'. LD BHA from 92'. Recovered 22' piece of 2-7/8" 10rd tubing and seal assembly. 18:00 - 19:00 1.00 FISH P DECOMP MU BHA #5 to 991' - burn shoe, pup, washpipe, washover boot basket, bumper sub, jar, 9 x DC's, 21 x hwdp, xo. 19:00 - 21 :30 2.50 FISH P DECOMP RIH w/4" DP from 991' to 6,153'. 21 :30 - 22:00 0.50 FISH P DECOMP Lubricate rig. Service top drive. 22:00 - 22:30 0.50 FISH P DECOMP Washover from 6,153' to 6,225'. PU - 160K, SO - 140K, Rot - 150K 22:30 - 00:00 1.50 FISH P DECOMP Burn over 9-5/8" packer assembly. 1 0/21/2004 00:00 - 07:00 7.00 FISH P DECOMP Burn over 9-5/8" packer assembly - PU - 160K, SO - 140K, Rot - 150K, TO on - 6/1 OK, TO off - 4K, 07:00 - 09:00 2.00 FISH P DECOMP Monitor well - static. Blow down top drive and remove blower hose. POH from 6,226' to 991'. 09:00 - 10:00 1.00 FISH P DECOMP Stand back BHA #5 and change out Burn Shoe. 10:00 - 11 :00 1.00 FISH P DECOMP Empty boot basket - recovered - 2 gal sand and iron cuttings. RIH w/BHA #6 to 992' - burn shoe, pup, wash pipe, washover boot basket, bumper sub, jar, 9 x DC's, 21 x hwdp, xo. 11 :00 - 13:30 2.50 FISH P DECOMP RIH w/4" DP from 992' to 6,123'. 13:30 - 14:00 0.50 FISH P DECOMP Lubricate rig. Service top drive. Install blower hose. 14:00 - 16:30 2.50 FISH P DECOMP Wash over top of fish to the top of the packer @ 6,226'. Burn over packer and push down to 6,248'. Packer stuck in the shoe, PU - 20K over. 16:30 - 17:30 1.00 FISH P DECOMP Circulate bottoms up through bottom of the 3-1/2" tubing tail @ 8,869' - 13 bpm - 1,830 psi. Monitor well - stable. 17:30 - 20:30 3.00 FISH P DECOMP POH w/4" DP from 6,248' to 992'. 20:30 - 21 :30 1.00 FISH P DECOMP LD BHA #6 from 992' to 42'. 21 :30 - 23:00 1.50 FISH P DECOMP POH and set slips below 4-1/2" x 3-1/2" xo. Break connection and set 9-5/8" packer in the mousehole. LD boot basket and washpipe. LD 2-7/8" tubing patch which was lodged in the 9-5/8" packer. LD burn shoe and packer. Clear the floor. 23:00 - 23:30 0.50 FISH P DECOMP RU 3-1/2" tubing handling equipment. 23:30 - 00:00 0.50 FISH P DECOMP LD 3-1/2" tubing tail from 2,619' to 2,291'. 10/22/2004 00:00 - 03:00 3.00 FISH P DECOMP LD 3-1/2" tubing from 2,291' to surface. Clear floor. Recovered: 82 jts 3-1/2" tubing, SS assy, X assy, XN assy, WLEG 03:00 - 12:00 9.00 DHB P DECOMP RU SWS and run 6.13" GRlCCUGamma. Could not go past 9,088'. POH for 5.9" GR. RIH. Could not go past 9,088'. POH. LD E-line tools. RU and RIH w 7" EZSV on E-line. Set Plug @ 9,086' ELM. POH. RD Schlumberger. 12:00 - 12:30 0.50 DHB P DECOMP Pressure test the 9-5/8" x 7" to 3,500 psi and hold for 30 minutes. Good test. 12:30 - 16:30 4.00 STWHIP P WEXIT MU Whipstock BHA to 93'. Orient, upload and surface test MWD. RIH with Whipstock and remaining BHA to 1,125'. Change out handling equipment. Whipstock BHA: anchor, whipstock, window mill, bit sub, Printed: 11/1/2004 1:48:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS2ES Start: Rig Release: Rig Number: 1 0/14/2004 1 0/31 /2004 Spud Date: 3/27/1987 End: 10/31/2004 1 0/22/2004 12:30 - 16:30 4.00 STWHIP P WEXIT upper mill, 1 x hwdp, float sub, mwd, pos, bumper sub, 9 x dc's, 21 x hwdp, xo 16:30 - 18:30 2.00 STWHIP P WEXIT PU 4" DP from 1,125' to 4,023'. 18:30 - 21 :30 3.00 STWHIP P WEXIT RIH from 4,023' to 8,975', Fill pipe every 3,000'. Install blower hose. 21 :30 - 22:00 0.50 STWHIP P WEXIT Orient whipstock to 90 LHS and RIH. Tag EZSV @ 9,084'. Set Anchor w/15K down. Shear lug w/ 25K down. TOW: 9,066' BOW: 9078' 22:00 - 22:30 0.50 STWHIP P WEXIT Displace well over to 8.4 ppg Flo-Pro drilling fluid - 275 gpm - 1 ,400 psi. 22:30 - 00:00 1.50 STWHIP P WEXIT I Mill 6-1/8" window from 9,066' to 9,068'. PU - 180K, SO- 155K, ROT - 170K, TO - 6K. 10/23/2004 00:00 - 05:00 5.00 STWHIP P WEXIT Mill 6-1/8" window from 9,068' to 9,078'. PU - 180K, SO- 155K, ROT - 170K, TO - 6K. Drill 20' of new hole to 9,092'. TOW: 9,066' BOW: 9,078' 05:00 - 05:30 0.50 STWHIP P WEXIT Circulate Hi-vise sweep to clean up the hole. Run BHA across window, TO - 5K, ROT - 175K, 100 rpms - good. 05:30 - 06:00 0.50 STWHIP P WEXIT Perform FIT to 10 ppg EMW - 700 psi @ 8,453' TVD. 06:00 - 07:00 1.00 STWHIP P WEXIT Open Circ Sub. Circulate Hi-vise sweep out of the hole @ 500 gpm. Pump dry job. 07:00 - 10:00 3.00 STWHIP P WEXIT POH from 9,092' to 920'. 10:00 - 12:00 2.00 STWHIP P WEXIT Change out handling equipment. LD BHA and mills. Starter mill - 0.125" to 0.25" under gauge. Upper mill full gauge. Clean and clear the floor. 12:00 - 13:30 1.50 STWHIP P WEXIT Remove wear ring. Flush and function BOPE. Install wear ring. 13:30 - 15:00 1.50 STWHIP P WEXIT PJSM. MU 6-1/8' Drilling BHA to 366'. Orient and surface test - good. 6-1/8" BHA #1: 6-1/8" MX18HDX, 4-3/4" SS 7/8 - 2 stg motor w/1.83 bend, non mag straight blade stabilizer, non mag float sub, GR/Res, non mag DM HOC, non mag TM HOC, 3 x non mag DC's, circ sub, 3 x HWDP, DNT jars, 2 x HWDP, xo. 15:00 - 17:30 2.50 STWHIP P WEXIT Change out handling equipment. PU 4" DP from 366' to 3,450'. Fill pipe. 17:30 - 20:00 2.50 STWHIP P WEXIT RIH with 4" DP from 3,450 to 8,962'. Fill pipe every 3,000' 20:00 - 21 :30 1.50 STWHIP P WEXIT Cut off 108' of drilling line. Service Crown. Service Top Drive, 21 :30 - 22:00 0.50 STWHIP P WEXIT Orient to 90 LHS and slide through the window with the pumps off. Tag up at 9,087'. Ream from 9,087' to 9,092'. 22:00 - 00:00 2.00 DRILL P PROD1 Dir drill 6-1/8" hole from 9,092' to 9,148'. PU - 165K, SO- 150K, AST - 1.82. 1 0/24/2004 00:00 - 16:30 16.50 DRILL P PROD1 Dir drill 6-1/8" hole from 9,148' to 9,760'. PU - 185K, SO- 150K, Rot - 165K, AST - 11.69, ART - 0.53 16:30 - 17:00 0.50 DRILL P PROD1 Circulate Hi-vise sweep into 9-5/8" casing - 275 gpm @ 1,850 psi. 17:00 - 17:30 0.50 DRILL P PROD1 Monitor well - stable. POH from 9,760' to 8,960'. 17:30 - 19:00 1.50 DRILL P PROD1 Drop dart and open up the circ sub. Circulate the hole clean - 10.5 bpm @ 1,100 psi. Pump dry job and blow down the top drive. Printed: 11/1/2004 1:48:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 1 0/14/2004 1 0/31 /2004 Spud Date: 3/27/1987 End: 10/31/2004 10/24/2004 19:00 - 22:00 3.00 DRILL P PROD1 POH from 8,960' to 366'. Change out handling equipment. 22:00 - 23:30 1.50 DRILL P PROD1 POH from 366' to 85'. Flush MWD and download tools. 6-1/8" MX18 graded 2/4/L T/GIE/1/BT/PR 23:30 - 00:00 0.50 DRILL P PROD1 MU 6-1/8" Smith XR20. MU BHA to 93' and orient. 1 0/25/2004 00:00 - 02:00 2.00 DRILL P PROD1 MU remaining BHA. Upload MWD. Surface test. Load Nuclear sources. RIH to 387', 16-1/8" BHA #2: 6-1/8" XR20, 4-3/4" 7/8 2 stg motor w/1.83 bend, non mag float sub, GR/RES, non mag DM HOC, 4-3/4" nuclear source, non mag TM HOC, 3 x dc's, cric sub, 3 x HWDP, DNT jar, 2 x HWDP, XO. 02:00 - 05:00 3.00 DRILL P PROD1 RIH w/4" DP from 387' to 8,981' filling pipe every 3,000'. Install blower hose. .05:00 - 07:00 2.00 DRILL P PROD1 RIH. MAD pass from 9,144' to 9,720'. 07:00 - 15:00 8.00 DRILL P PROD1 Directional drill from 9,760' to 9,980'. AST - 3.82, ART - 0.86, PU - 185K, SO - 150K, ROt - 170K, TO on - 7K, TO off - 5K. 15:00 - 15:30 0.50 DRILL P PROD1 Circulate open hole - 275 gpm @ 1,850 psi. Monitor well - stable. 15:30 - 16:00 0.50 DRILL P PROD1 POH from 9,980' to 8,982'. 16:00 - 17:00 1.00 DRILL P PROD1 Drop dart and open the circ sub. CBU - 11.5 bpm @ 1,300 psi. Pump dry job. Blow down top drive. 17:00 - 20:00 3.00 DRILL P PROD1 POH from 8,982' to 386'. Change out handling equipment. 20:00 - 22:00 2.00 DRILL P PROD1 POH with BHA from 386'. Flush MWD and pull nuclear sources. Download tools. Change out motor and pulser. Change out bit. 6-1/8" XR20 graded: 4/1/BT/N/E/1/CT/DTF 22:00 - 00:00 2.00 DRILL P PROD1 MU 6-1/8" BHA #3 to 104'. Upload MWD and surface test. Install nuclear sources. MU remaining BHA to 387'. 6-1/8" BHA #3: 6-1/8" FM2643, 5" 6/7 6 stg motor w/1.5 bend, non mag float sub, 4-3/4" GR/RES, non mag OM HOC, 4-3/4" nuclear source, non mag TM HOC, 3 x dc's, cric sub, 3 x HWDP, DNT jar, 2 x HWDP, XO. 1 0/26/2004 00:00 - 03:45 3.75 DRILL P PROD1 RIH with 4" DP from 367' to 8,982' filling pipe every 3,000'. 03:45 - 04:15 0.50 DRILL P PROD1 Install blower hose and service the top drive. 04:15 - 05:00 0.75 DRILL P PROD1 RIH from 8,982'. Take weight @ 9,760. Work pipe. RU top drive and wash last 3 stands to bottom. Precautionary ream last stand to bottom. 05:00 - 00:00 19.00 DRILL P PROD1 Drill directionally from 9,980' to 11,126'. AST - 4.83, ART- 4.97, PU - 180K, SO - 145K, ROT - 165K, TO on - 6K-8K, TO off - 4K-6K. 10/27/2004 00:00 - 04:30 4.50 DRILL P PROD1 Drill directionally from 11,126' to 11,406' TD 04:30 - 06:00 1.50 DRILL P PROD1 Circulate sweep at TD. Rotate and reciprocate during circulation. Blow down TDS, 06:00 - 07:00 1.00 DRILL P PROD1 POOH on short trip from 11,406' to 9,635' No significant problems, Minor overpull 20-30K at 9,815 and 9,610. Wiped through, not seen again. 190K UP 150K ON MAX UP=225K MAX DN=140K 07:00 - 08:00 1.00 DRILL P PROD1 RIH on short trip from 9,635' to 11,406'. No problems encountered. 08:00 - 10:30 2.50 DRILL P PROD1 Pump sweep and circuate until hole clean. Spot liner running Printed: 11/1/2004 1 :48:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 1 0/14/2004 1 0/31 /2004 Spud Date: 3/27/1987 End: 10/31/2004 10/27/2004 08:00 - 10:30 2.50 DRILL P PROD1 pill. 10:30 - 12:00 1.50 DRILL P PROD1 POOH to run liner from 11,406' to 8,982'. Work through and clean up one tight spot at 9,500'. No other problems encountered. 12:00 - 13:30 1.50 DRILL P PROD1 Drop dart - Open circ sub. Circulate bottoms up. 200 SPM, 1,300 psi. Pump slug, blow down TDS. 13:30 - 16:30 3.00 DRILL P PROD1 POOH from 8,982' to 387' 16:30 - 19:30 3.00 DRILL P PROD1 Change out handling equipment. Lay down BHA from 387'. Flush MWD & motor. PJSM. Remove and secure sources sources. Download MWD. Clear and clean rig floor. 19:30 - 20:00 0,50 CASE P RUNPRD Rig up to run 4.5",12.6#, BTC-M, L-80 liner. 20:00 - 20:30 0.50 CASE P RUN PRO PJSM. Make up float and shoe track. Check float, holding OK. 20:30 - 22:30 2.00 CASE P RUNPRD Make up and run 4.5", 12.6#, BTC-M, L-80 liner as per running program. Average make up torque, 3,800 ftllbs. 22:30 - 23:00 0.50 CASE P RUNPRD Make up hanger/packer assembly and pick up one stand drill pipe. Liner weight, 60K. RIH 0 DP to 2,822'. 23:00 - 23:30 0.50 CASE P RUNPRD Circulate one liner volume at 5 bpm, 150 psi. 23:30 - 00:00 0.50 CASE P RUNPRD RIH on DP from 2,822' to 4,131'. Fill every 10 stands. 10/28/2004 00:00 - 03:30 3.50 CASE P RUNPRD Continue RIH on DP from 4,131 to 9,086' 03:30 - 04:00 0.50 CASE P RUNPRD Circulate one DP and one liner volume at 9,086' 04:00 - 05:00 1.00 CASE P RUNPRD RIH from 9,086 to 11,406'. Tight spot at 9,537' (45K down to break through), Additional tight spots requiring no more than 15-20K to break through encountered at 9,703',10,160', 10,402',10,445',10,525',10,608',10,935', 11,100', 11,180'. Worked through without difficulty. 05:00 - 05:30 0.50 CEMT P RUNPRD Pick up and rig up cement head and drill pipe single. 05:30 - 07:00 1.50 CEMT P RUNPRD Tag bottom at 11,406'. Stage up pumps to 6 bpm, 1,000 psi. Reciprocate pipe during circulation. 180K UP - 145K DN. Hold PJSM and Schlumberger batch up during circulation. 07:00 - 08:30 1.50 CEMT P RUNPRD Pumped 5 BBLS of water. Pressure tested lines to 4500 psi. Pump 20 BBLS of 8.3 CW100 preflush. Pumped 25 BBLS of 9.5 ppg Mud Push XL spacer followed by 69 BBLS (321 sxs) of 15.8 ppg Dowell Latex cement. Washed out lines with perforating pill and dropped wiper plug. Displaced cement with remainder of perforating pill and 87 BBLS of mud. (128 BBLS total) Observed latchup and bumped plug at calculated strokes. Pressure up to 3,500 psi and set liner hanger anchor slips. Set down 25K Ibs to confirm set. Bled pressure to 0 psi checked floats. Held okay. CIP at 08:30. Reciprocated liner while cementing. 08:30 - 09:30 1.00 CASE P RUNPRD Switch to rig pumps. Rotate to right 15 turns to release. Pressure up drill pipe to 1,000 psi. Pick up 4' and observe pressure drop to 400 psi. Pick up additional 4' (8' total) and unsting. Pump 30 bbls 8.5 FloPro mud at 12 BPM, 2070 psi. Reduce rate and set packer, confirm set. Top of liner tie back at 8,692.6' 09:30 - 11 :00 1.50 CEMT P RUNPRD Displace with 8.5 ppg FloPro mud at 12 BPM. Approximately 10 BBLS cement back to surface. Displace well to sea water at 12 BPM. 11 :00 - 13:00 2.00 CEMT P RUNPRD Lay down cement head and single of drill pipe. POOH from 8,693' to 3,570'. 13:00 - 14:30 1.50 CEMT P RUNPRD Slip and cut drilling line, inspect brakes, service TDS. 14:30 - 17:30 3.00 CEMT P RUNPRD POOH from 3,570'. Lay down running tool. Printed: 11/1/2004 1 :48:35 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1 0/14/2004 1 0/31/2004 Spud Date: 3/27/1987 End: 10/31/2004 Rig up perf gun equipment. Hold PJSM. Perform casing test on 4.5" liner job. Good test. Hold perforating PJSM while holding pressure for chart recording. 20:00 - 00:00 4.00 OTHCMP Make up perf guns and RIH on 2-7/8" drill pipe to 2,731. Rig down perf gun handling equipment. 10/29/2004 00:00 - 03:00 3.00 OTHCMP Continue to RIH with perf guns on drill pipe from 2,731' to tag landing collar at 11,317'. 03:00 - 03:30 0.50 OTHCMP POOH to set guns on depth to 11,209'. Top perfs at 9,970'. Perf intervals: 9,970' to 10,460' 10,890' to 10,950' 11,060' to 11,210' 03:30 - 04:00 0.50 PERFO P OTHCMP PJSM. Close rams and pressure up to 3,000 psi. Hold for one minute and dump pressure. With pressure at 0 psi, open rams. Positive indicaton of 1 st shot at 7 min 57 seconds after pressure dump. Positive indication of second shot at 9 minutes and 26 seconds. Fluid dropped approximately 2 BBLS following first shot and stabilized. 04:00 - 05:00 1.00 PERFO OTHCMP POOH 18 stands to get guns above top perfs. 05:00 - 09:30 4.50 PERFO OTHCMP Monitor well. POOH laying down drill pipe to 2,731'. 09:30 - 16:00 6.50 PERFO OTHCMP Change out handling equipment. POOH laying down 2 7/8" drill pipe, perf guns and equipment. All shots fired. Clear and clean rig floor. 16:00 - 20:00 4.00 PERFO OTHCMP RIH with 44 stands of drill pipe from derrick and lay down same. Losses averaged 2.9 BPH since shots fired. 20:00 - 20:30 0.50 RUNCMP Pull wear bushing. Clear rig floor. 20:30 - 22:30 2.00 RUNCMP Break out saver sub and rig up to run 4.5",12.6#, 13Cr80, VAM Top tubing. 22:30 - 00:00 1.50 RUNCMP Hold Pre-Job Safety Meeting Regarding Chrome Tubing Running Operation. Run 41/2" Completion - Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S-3 Hydro-Set Retainer Production Packer - RIH With 41/2" (9 JOints) 13 CR80 12.6 lb. Vam Top Tubing To 450' -Torque To 4,440 ft/lbs. 1 0/30/2004 00:00 - 11 :30 RUNCMP Hold Pre-Job Safety Meeting Regarding Chrome Tubing Running Operation. Run 4 1/2" Completion - RIH With 4 1/2" (201 Total Joints Run) 13 CR80 12.6 lb. Vam Top Tubing and other completion jewelry as per program TO 8,697'.-Torque To 4,440 ft/lbs, 11 :30 - 13:30 RUNCMP Space Out 41/2" Completion String - Lay Down 2 Joints Of 4 1/2" Tubing - Pick Up 4 Space Out Pup Joints - Make Up Landing Joint And 12" X 7" McEvoy SSH Tubing Hanger - Up Weight At 125,000 Ibs. Down Weight At 115,000 Ibs. Drain Stack And Land Hanger. Run In Lock Down Screws. Back Out Landing Joint And Line Up Circulating Lines. 13:30 - 15:30 2.00 RUNCO RUNCMP Reverse circu;ate 262 BBLS inhibited seawater and displace with clean seawater at 3 BPM, 140 psi to top GLM. Clear and clean rig floor. 15:30 - 17:30 2.00 RUNCO RUNCMP Make up landing joint. Drop ball and rod and allow to fall. Set packer with 3,500 psi tubing pressure and hold for 30 minutes. Bleed tubing pressure to 1,500 psi. Pressure up annulus to 3,500 psi and hold for 30 minutes. Both tests good. Bleed off tubing pressure and observe OCR shear. Bleed a/l pressures Printed: 11/1/2004 1 :48:35 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-23 J-23A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 1 0/14/2004 1 0/31/2004 Spud Date: 3/27/1987 End: 10/31/2004 RUNCO RUNCO 2.00 BOPSU P 3.50 WHSUR P 01 :30 - 03:00 1.50 WHSUR P to 0 psi. Install TWC and test from below to 1,000 psi, good test. Nipple down BOP's and prep wellhead. Bring 13-5/8" X 7", 5-Seal adapter flange and 6-3/8" Bore McEvoy tree into cellar, nipple up same. Test tree and adapter to 5,000 psi, good test. RUNCMP Rig Up DSM Lubricator To Pull Two Way Check Valve RUNCMP Rig Up DSM Lubricator And Pull Two Way Check Valve. Rig Down Lubricator. POST Held PJSM. Rig Up Little Red Hot Oil. Test Surface Lines At 3,500 Psi. (Test Good) - Reverse Circulate 150 BBLS Diesel Freeze Protection Down Inner Annulus To 2,100' At 3 BPM With 2,250 Psi. 23:30 - 00:00 10/31/2004 00:00 - 01:30 0.50 WHSUR P 1.50 WHSUR P 03:00 - 04:00 04:00 - 05:30 1.00 WHSUR P 1.50 RIGD P POST POST Note: Clocks set back one hour actual time was 2,5 hours. U Tube Diesel Into Tubing. Held PJSM - Install BPV - Test From Below To 1,000 Psi (Test Good), Break Down Surface Equipment - Remove Secondary Annulus Valve - Install Tree Cap And Gauges - Secure Well Rig Released From Well Work On J-23B At 05:30 Hours On 10/31/2004 Printed: 11/1/2004 1 :48:35 PM . . 14-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well J-23A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,044.69' MD 9,066.00' MD 11,406.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I S- N ßV ~~ cl Signed i] I /" '......' ^ i l 'i ~\r\;~ .'. J ()w Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) EFI Halliburton Sperry-Sun North Slope Alaska BPXA J-23A Job No. AKZZ3341819, Surveyed: 27 October, 2004 Survey Report 10 November, 2004 Your Ref: API 500292171201 Surface Coordinates: 5970172.00 N, 643559.00 E (70019' 33.5510" N, 211009'51.1201" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 69. 64ft above Mean Sea Level SpE!í'í'Y-SUI! DRlLLlNG SeRVlCeS A Halliburton Company I I . . Survey Ref: svy4439 Halliburton Sperry-Sun Survey Report for J-23A Your Ref: API 500292171201 Job No. AKZZ3341819, Surveyed: 27 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9044.69 22.750 280.200 8364.43 8434.07 18.34 N 2567.08 W 5970141.22 N 640992.04 E -1802.24 Tie On Point MWD+IIFR+M8 9066.00 22.910 280.490 8384.07 8453.71 19.82 N 2575.22 W 5970142.55 N 640983.88 E 0.918 -1806.94 Window Point 9076.30 23.200 277.520 8393.55 8463.19 20.45 N 2579.20 W 5970143.10 N 640979.88 E 11.637 -1809.31 9111.04 19.330 264.720 8425.94 8495.58 20.82 N 2591.72 W 5970143.23 N 640967.36 E 17.338 -1817.90 9142.45 14.910 248.890 8455.96 8525.60 18.88 N 2600.68 W 5970141.12 N 640958.44 E 20.330 -1825.60 9171.18 14.560 230.610 8483.76 8553.40 15.26 N 2606.92 W 5970137.38 N 640952.27 E 16.164 -1832.58 . 9203.84 13.820 204,950 8515.46 8585.10 9.11 N 2611.74W 5970131.14 N 640947.56 E 19.236 -1840.34 9234.94 11.670 177.790 8545.82 8615.46 2.59 N 2613.19 W 5970124.60 N 640946.24 E 20,245 -1845.97 9263.65 11.430 147.930 8573.97 8643.61 2.738 2611.56 W 5970119.31 N 640947.97 E 20.614 -1848.58 9295.62 9.970 117.440 8605.41 8675.05 6.69 S 2607.42 W 5970115.43 N 640952.18 E 18.053 -1848.46 9327.39 9.710 82.100 8636.74 8706.38 7.598 2602.32 W 5970114.63 N 640957.30 E 18,735 -1845.49 9356.15 10.840 71.000 8665.04 8734.68 6.37 S 2597.36 W 5970115.93 N 640962.23 E 7.909 -1841.12 9390.27 11.700 80.580 8698.51 8768.15 4.768 2590.92 W 5970117.67 N 640968.65 E 6.029 -1835.42 9421.71 15.580 89.840 8729.06 8798.70 4,23 S 2583.55 W 5970118.34 N 640976.01 E 14.124 -1829.83 9450.58 20.150 92.520 8756.53 8826.17 4.44 S 2574.70 W 5970118.30 N 640984.86 E 16.080 -1823.72 9483.78 25.280 94.830 8787.14 8856.78 5.29 S 2561.91 W 5970117.70N 640997.66 E 15.681 -1815.28 9514.90 30.330 98.040 8814.66 8884.30 6.95 S 2547.50 W 5970116.32 N 641012.10 E 16.920 -1806.27 9542.77 34.110 102.490 8838.24 8907.88 9.628 2532.89 W 5970113.92 N 641026.75 E 16.006 -1797.83 9575.63 39.040 106.640 8864.63 8934.27 14.588 2513.97 W 5970109.32 N 641045.77 E 16.777 -1787.96 9607.27 43.080 111.660 8888.48 8958.12 21.438 2494.37 W 5970102.85 N 641065.50 E 16.474 -1778.93 9635.46 47.920 114.320 8908.24 8977.88 29.29 S 2475.87 W 5970095.34 N 641084.14 E 18.438 -1771.42 9669.80 53.830 117.060 8929.90 8999.54 40.86 S 2451.89 W 5970084.24 N 641108.34 E 18.287 -1762.64 . 9695.15 57.980 117.420 8944.11 9013.75 50.478 2433.23 W 5970074.99 N 641127.18 E 16.413 -1756.24 9726.24 62.400 120.080 8959.56 9029.20 63.45 8 2409.60 W 5970062.46 N 641151.06 E 16.037 -1748.71 9755.92 67.300 122.850 8972.17 9041.81 77.48 S 2386.70 W 5970048.87 N 641174.22 E 18.543 -1742.44 9787.56 74.620 124.660 8982.49 9052.13 94.09 S 2361.86 W 5970032.74 N 641199.38 E 23.758 -1736.62 9818.60 81.390 126.560 8988.94 9058.58 111.778 2337.19 W 5970015.54 N 641224.38 E 22.616 -1731.67 9845.78 87.470 126.270 8991.57 9061.21 127.828 2315.43 W 5969999.91 N 641246.44 E 22.395 -1727.64 9880.08 92.470 121.390 8991.59 9061.23 146.908 2286.96 W 5969981.37 N 641275.27 E 20.366 -1721.00 9911.15 91.170 116.170 8990.61 9060.25 161.858 2259.75 W 5969966.95 N 641302.76 E 17.305 -1712.33 9938.89 91.600 117.100 8989.93 9059.57 174.288 2234.96 W 5969954.99 N 641327.78 E 3.693 -1703.59 9972.51 94.140 118.160 8988.25 9057.89 189.858 2205.21 W 5969939.99 N 641357.82 E 8.185 -1693.56 10005.00 93.150 116.510 8986.19 9055.83 204.74 S 2176.41 W 5969925.66 N 641386.91 E 5.914 -1683.73 10032.67 90.490 117.040 8985.31 9054.95 217.208 2151.72 W 5969913.68 N 641411.83 E 9.802 -1675.08 10066.77 89.690 117.690 8985.25 9054.89 232.87 8 2121.44W 5969898.59 N 641442.41 E 3.023 -1664.75 10 November, 2004 - 14:41 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for J-23A Your Ref: API 500292171201 Job No. AKZZ3341819, Surveyed: 27 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 10097.16 90.250 117.660 8985.27 9054.91 246.98 S 2094.53 W 5969884.99 N 641469.58 E 1.845 -1655.70 10126.83 90.490 118.120 8985.08 9054.72 260.86 S 2068.30 W 5969871.61 N 641496.07 E 1.749 -1646.97 10161.07 90.370 118.660 8984.82 9054.46 277. 14 S 2038.18 W 5969855.91 N 641526.49 E 1.616 -1637.18 10191.86 89.940 119.140 8984.74 9054.38 292.02 S 2011.23W 5969841.55 N 641553.73 E 2.093 -1628.64 10218.66 90.310 119.220 8984.68 9054.32 305.09 S 1987.83 W 5969828.94 N 641577.37 E 1.412 -1621.34 10252.88 88.770 119.440 8984.95 9054.59 321.85 S 1958.00 W 5969812.75 N 641607.52 E 4.546 -1612.09 . 10283.86 88.950 120.010 8985.57 9055.21 337.21 S 1931.10 W 5969797.91 N 641634.71 E 1.929 -1603.93 10312.10 89.260 119.910 8986.01 9055.65 351.31 S 1906.63 W 5969784.28 N 641659.44 E 1.153 -1596.61 10346.10 87.720 116.500 8986.91 9056.55 367.37 S 1876.69 W 5969768.79 N 641689.69 E 11.001 -1586.79 10377.66 87.840 113.960 8988.13 9057.77 380.81 S 1848.16 W 5969755.90 N 641718.46 E 8.051 -1576.12 10405.92 87.590 113.880 8989.26 9058.90 392.26 S 1822.35 W 5969744.95 N 641744.49 E 0.929 -1565.97 10455.27 88.640 112.710 8990.88 9060.52 411.77 S 1777.05 W 5969726.31 N 641790.16 E 3.185 -1547.73 10499.26 90.250 110.900 8991.31 9060.95 428.10 S 1736.21 W 5969710.76 N 641831.30 E 5,507 -1530.40 10548.07 90.190 110.110 8991.12 9060.76 445.20 S 1690.49 W 5969694.54 N 641877.33 E 1.623 -1510.16 10593,21 90.560 110.600 8990.82 9060.46 460.90 S 1648.17 W 5969679.65 N 641919.95 E 1.360 -1491.34 10685.94 90.740 111.410 8989.77 9059.41 494.14 S 1561.61 W 5969648,07 N 642007.13 E 0.895 -1453.63 10780.07 89.690 117.180 8989.42 9059.06 532.85 S 1475.86 W 5969611.01 N 642093.61 E 6.230 -1420.37 10873.89 89.440 116.700 8990.13 9059.77 575.35 S 1392.22 W 5969570.11 N 642178.04 E 0.577 -1391.29 10966.04 88.400 115.850 8991.87 9061.51 616.14 S 1309.61 W 5969530.92 N 642261.42 E 1 .457 -1361.71 11059.28 93.710 116.580 8990.15 9059.79 657.30 S 1226.00 W 5969491.36 N 642345.80 E 5.748 -1331.70 11153.30 92.160 114.210 8985.34 9054.98 697.57 S 1141.19 W 5969452,73 N 642431.37 E 3.009 -1300.20 11245.11 92.410 114.100 8981.68 9051.32 735.11 S 1057.48 W 5969416.80 N 642515.78 E 0.297 -1267.55 11341.96 92.470 114.570 8977.55 9047.19 774.98 S 969.32 W 5969378.62 N 642604.69 E 0.489 -1233.40 . 11406.00 92.470 114.570 8974.79 9044.43 801.58 S 911.13 W 5969353.13 N 642663.37 E 0.000 -1211.07 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 45.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11406.00ft., The Bottom Hole Displacement is 1213.55ft., in the Direction of 228.660° (True). 10 November, 2004 - 14:41 Page 3 of4 Dril/Quest 3.03.06.006 Halliburton Sperry-Sun Survey Report for J-23A Your Ref: API 500292171201 Job No. AKZZ3341819, Surveyed: 27 October, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9044.69 9066.00 11406.00 8434.07 8453.71 9044.43 18.34 N 19.82 N 801.58 S 2567.08 W 2575.22 W 911.13W Tie On Point Window Point Projected Survey . Survey too/ørogram for J-23A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9044.69 0.00 9044.69 8434.07 11406.00 8434.07 BP High Accuracy Gyro - GCT-MS (J-23) 9044.43 MWD+IIFR+MS (J-23A) . 10 November, 2004 - 14:41 Page 4 of 4 DrillQuest 3.03.06.006 . . 14-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well J-23A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,044.69' MD 9,066.00' MD 11,406.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 U /) / / . Date ¡r-ItJ. J )JJ) "1 Signed / . J/M/ ( Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA J-23A (mwd) . Job No. AKMW3341819, Surveyed: 27 October, 2004 Survey Report 10 November, 2004 Your Ref: API 500292171201 Surface Coordinates: 5970172.00 N, 643559.00 E (70019' 33.5510" N, 211009' 51.1201" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 69. 64ft above Mean Sea Level . SPE!r"'r""Y-SUI'1 D A ILL t N GS eA\! t c: e S A Halliburton Company Survey Ref: svy4440 Halliburton Sperry-Sun Survey Report for J-23A (mwd) Your Ref: AP/500292171201 Job No. AKMW3341819, Surveyed: 27 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9044.69 22.750 280.200 8364.43 8434.07 18.34 N 2567.08 W 5970141.22 N 640992.04 E -1802.24 Tie On Point MWD Magnetic 9066.00 22.910 280.490 8384.07 8453.71 19.82 N 2575.22 W 5970142.55 N 640983.88 E 0.918 -1806.94 Window Point 9076.30 23.200 277.520 8393.55 8463.19 20.45 N 2579.20 W 5970143.10 N 640979.88 E 11.637 -1809.31 9111.04 19.330 253.650 8425.98 8495.62 19.73N 2591.53 W 5970142.14 N 640967.57 E 27.064 -1818.54 9142.45 14.910 244.740 8456.00 8525.64 16.54 N 2600.18 W 5970138.79 N 640958.98 E 16.325 -1826.91 . 9171.18 14.560 230.920 8483.79 8553.43 12.68 N 2606.32 W 5970134.81 N 640952.91 E 12.267 -1833.98 9203.84 13.820 205.210 8515.48 8585.12 6.56 N 2611.18W 5970128,60 N 640948.17 E 19.273 -1841.74 9234.94 11.670 178.040 8545.84 8615.48 0.05 N 2612.65 W 5970122.06 N 640946.82 E 20.251 -1847.39 9263.65 11 .430 148.040 8574.00 8643.64 5.275 2611.05 W 5970116.77 N 640948.53 E 20.709 -1850.02 9295.62 9.970 117.450 8605.44 8675.08 9.24 S 2606.91 W 5970112.89 N 640952.74 E 18.107 -1849.90 9327.39 9.710 82.270 8636.77 8706.41 10.15 S 2601.81 W 5970112.08 N 640957.86 E 18.653 -1846.93 9356.15 10.840 71.060 8665.07 8734.71 8.94 S 2596.85 W 5970113.37 N 640962,80 E 7.968 -1842.57 9390.27 11.700 80.690 8698.53 8768.17 7.345 2590.40 W 5970115.10 N 640969.21 E 6.055 -1836.88 9421.71 15.580 89.540 8729.08 8798.72 6.79 S 2583.03 W 5970115.79 N 640976.57 E 13.979 -1831.28 9450.58 20.150 91.750 8756.55 8826.19 6.915 2574.18 W 5970115.84 N 640985.43 E 16.000 -1825.11 9483.78 25.280 93.700 8787.17 8856.81 7.55 S 2561.38 W 5970115.45 N 640998.24 E 15.615 -1816.50 9514.90 30.330 97.310 8814.69 8884.33 8.98 S 2546.94 W 5970114.30 N 641012.69 E 17.099 -1807.31 9542.77 34.110 101.550 8838.27 8907.91 11.44 S 2532.30 W 5970112.12N 641027.38 E 15.796 -1798.69 9575.63 39.040 106.160 8864,65 8934.29 16.17 S 2513.32 W 5970107.75 N 641046.45 E 17.166 -1788.61 9607.27 43.080 111.050 8888.51 8958.15 22.82 5 2493.65 W 5970101.4 7 N 641066.24 E 16.305 -1779.42 9635.46 47.920 113.580 8908.27 8977.91 30.47 S 2475.06 W 5970094.18 N 641084.97 E 18.321 -1771.68 9669.80 53.830 116.590 8929.93 8999.57 41.79 S 2450.96 W 5970083.33 N 641109.28 E 18.501 -1762.64 . 9695.15 57.980 117.880 8944.14 9013.78 51.40 5 2432.31 W 5970074.08 N 641128.12 E 16.904 -1756.24 9726,24 62.400 119.970 8959.59 9029.23 64.45 5 2408.71 W 5970061.48 N 641151.96E 15.366 -1748.79 9755.92 67.300 121.740 8972.20 9041.84 78.23 S 2385.66 W 5970048.14 N 641175.28 E 17.369 -1742.23 9787.56 74.620 124.410 8982,52 9052,16 94.55 5 2360.62 W 5970032.30 N 641200.62 E 24.469 -1736.07 9818.60 81.390 126.440 8988.96 9058.60 112.15 5 2335.90 W 5970015.18 N 641225.67 E 22.728 -1731.03 9845.78 87.470 124.140 8991.60 9061.24 127.76 S 2313.83 W 5969999.99 N 641248.04 E 23.901 -1726.47 9880.08 92.470 120.980 8991.62 9061.26 146.21 5 2284.94 W 5969982.10 N 641277.28 E 17.243 -1719.08 9911.15 91.170 119.920 8990.63 9060.27 161.955 2258.17 W 5969966.87 N 641304.35 E 5.398 -1711.28 9938.89 91.600 115.930 8989.96 9059.60 174.945 2233.67 W 5969954.36 N 641329.09 E 14.463 -1703.14 9972.51 94.140 121.980 8988.28 9057.92 191.185 2204.30 W 5969938.68 N 641358.76 E 19.495 -1693.86 10005.00 93.150 109.960 8986.20 9055.84 205.35 S 2175.21 W 5969925.07 N 641388.12 E 37.046 -1683.31 10032.67 90.490 114.970 8985.32 9054.96 215.925 2149.66 W 5969915.00 N 641413.87 E 20.491 -1672.71 10066.77 89.690 114.970 8985.27 9054.91 230.31 5 2118.75 W 5969901,20 N 641445.05 E 2.346 -1661.03 10 November, 2004 - 14:41 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for J-23A (mwd) Your Ref: API 500292171201 Job No. AKMW3341819, Surveyed: 27 October, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10097.16 90.250 123.900 8985.29 9054.93 245.23 S 2092.31 W 5969886.78 N 641471.77 E 29.442 -1652.89 10126.83 90.490 123.540 8985.09 9054.73 261.70 S 2067.63 W 5969870.79 N 641496.76 E 1 .458 -1647.08 10161.07 90.370 121.010 8984.84 9054.48 279.98 S 2038.68 W 5969853.06 N 641526.05 E 7.397 -1639.54 10191.86 89.940 123.310 8984.75 9054.39 296.37 S 2012.62 W 5969837.18 N 641552.42 E 7.599 -1632.70 10218.66 90.310 122.090 8984.70 9054.34 310.85 S 1990.07 W 5969823.13 N 641575.25 E 4.757 -1626.99 10252.88 88.770 120.310 8984.97 9054.61 328.57 S 1960.80 W 5969805.97 N 641604.85 E 6.878 -1618.83 . 10283.86 88.950 110.970 8985.59 9055.23 341.96 S 1932,91 W 5969793.12 N 641632.99 E 30.148 -1608.57 10312.10 89.260 122.460 8986.03 9055.67 354.63 S 1907.73 W 5969780.93 N 641658.41 E 40.697 -1599.73 10346.10 87.720 110.320 8986.93 9056.57 369.71 S 1877.34 W 5969766.44 N 641689.08 E 35.979 -1588.91 10377.66 87.840 109.700 8988.15 9057.79 380.51 S 1847.71 W 5969756.21 N 641718.91 E 2.000 -1575.58 10405.92 87.590 108.660 8989.28 9058.92 389.78 S 1821.04W 5969747.45 N 641745.76 E 3.782 -1563.28 10455.27 88.640 108.430 8990.90 9060.54 405.47 S 1774.27 W 5969732.66 N 641792.81 E 2.178 -1541.31 10499.26 90.250 108.050 8991.33 9060.97 419.24 S 1732.50 W 5969719.69 N 641834.84 E 3.760 -1521.51 10548.07 90.190 114.970 8991.14 9060.78 437.12S 1687.12 W 5969702.68 N 641880.56 E 14.178 -1502.06 10593.21 90.560 110.380 8990.85 9060.49 454.52 S 1645.48 W 5969686.08 N 641922.52 E 10.201 -1484.92 10685.94 90.740 114.970 8989.79 9059.43 490.25 S 1559.94 W 5969651.99 N 642008.72 E 4.953 -1449.71 10780.07 89.690 110.060 8989.44 9059.08 526.29 S 1473.02 W 5969617.63 N 642096.32 E 5.334 -1413.72 10873.89 89.440 107.840 8990.15 9059.79 556.75 S 1384.29 W 5969588.87 N 642185.62 E 2.381 -1372.52 10966.04 88.400 113.970 8991.89 9061.53 589.61 S 1298.26 W 5969557.66 N 642272.26 E 6.746 -1334.93 11059.28 93.710 109.890 8990.17 9059.81 624.41 S 1211.83 W 5969524.52 N 642359.34 E 7.181 -1298.42 11153.30 92.160 115.240 8985.36 9055.00 660.43 S 1125.16 W 5969490,16 N 642446.68 E 5.917 -1262.60 11245.11 92.410 108.080 8981.69 9051.33 694.27 S 1039.96 W 5969457,96 N 642532.52 E 7.797 -1226.28 11341.96 92.470 113.730 8977.56 9047.20 728.78 S 949.60 W 5969425.19 N 642623.52 E 5.829 -1186.79 . 11406.00 92.470 113.730 8974.80 9044.44 754.53 S 891.03 W 5969400.56 N 642682.57 E 0.000 -1163.58 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 45.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11406.00ft., The Bottom Hole Displacement is 1167.58ft., in the Direction of 229.742° (True). 10 November, 2004- 14:41 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for J-23A (mwd) Your Ref: API 500292171201 Job No. AKMW3341819, Surveyed: 27 October, 2004 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9044.69 9066.00 11406.00 8434.07 8453.71 9044.44 18.34 N 19.82 N 754.53 S 2567.08 W 2575.22 W 891.03 W Tie On Point Window Point Projected Survey . Survey tool proç¡ram for J-23A (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9044.69 0.00 9044.69 8434.07 11406.00 8434.07 BP High Accuracy Gyro - GCT-MS (J-23) 9044.44 MWD Magnetic (J-23A (mwd)) . 10 November, 2004 - 14:41 Page 4 of 4 DrillQuest 3.03.06.006 J 3 - HES 4-112" X ;:: 9-5/8" CSG, 47#, Perf's (4/17/87) 8700' Top of PERFORA TION SUMMARY ANGLE AT TOP PERF: 94 @ 9970' Note: Refer to Froduction TOC - 9500' into ~ . 1I Œ (ill ~ . \ n ® @f , l1 fP.~ riD ! FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA OIL A.lD) GAS CONSERVATION COMMISSION I 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay J-23A BP Exploration (Alaska) Inc. Pennit No: 204-193 Surface Location: 1182' SNL, 802' WEL, SEe. 09 T11N, Rl3E, UM Bottomhole Location: 2052' SNL, 1687' WEL, SEC. 09, T11N, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). BY ORDER O} THE COMMISSION DATED this~ day of October, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. VJbI\- 9{3012004- . STATE OF ALASKA . ALASKA OIL~D GAS CONSERVATION COMMISSiONRECEIVED PERMIT TO DRILL SEP 2 9 2004 20 AAC 25.005 1a. Type of work DDrill IBI Redrill rb. Current Well Class D Exploratory II ~tðl~~ß ~Blti.6ItIBffißSlOn D Re-Entry D Stratigraphic Test D Service D eve opmeniqà_s _ La,.. . ~i"Jlle Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Namë'ánã ber: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU J-23A ./' 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11441 TVD 9058 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028281 1182' SNL, 802' WEL, SEC. 09, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1281' SNL, 3104' WEL, SEC. 09, T11N, R13E, UM 10/10104 ..... Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2052' SNL, 1687' WEL, SEC. 09, T11N, R13E, UM 2560 22,200 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 643559 y- 5970172 Zone- ASP4 (Height above GL):Plan 70.9' feet J-09A is 945' away at 9579' MD 16. Deviated Wells: Kickoff Depth: 9068 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 89.4 dearees Downhole: 3165 Surface: 2285 /' 16. Casll"l~p"()9ram: SpecifICations settingDEtpth Jc.f.& S<lUl\s} Size TODi ...... ............aòttòm i·' Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD lincludina staae data) 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2741' 8700' 8115' 11441' 9058' 383 cu ft Class 'G' 19. PRESENT WELL CONDITlgNSl.lMMARY CT'obf) completed for RedrillAND Rf}-Elt'lgyoperatÎøns) ..... Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): \ Effective Depth MD (ft): \Effective Depth TVD (ft)T Junk (measured): 9122 9234 None 9869 9194 9648 ,. . i . ,Lehgttìi .. ii 'i SiZe;..····· "'.. .......... iiii i;.iii,: ii ii"MDi7? ii' i: ifY!.?i Con('h Ir.tor 80' 8 cu vds Concrete 110' 110' ~.,.f...,..", 2634' 13-3/8" 3258' cu ft Permafrost 'E', 465 cu ft PF "c" 2672' 2672' ,. 9014' 9-5/8" 575 cu ft Class 'G' 9050' 8440' Pronur.tion Liner 1105' 7" 375 cu ft Class 'G' 8807' - 9912' 8214' - 9234' Perforation Depth MD (ft): 9650' - 9695' perforation Depth TVD (ft): 8992' - 9033' 20. Attachments a Filing Fee, $100 o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name Bill Isaacson Title Senior Drilling Engineer l. tJÅ, 1 '/1.,-10'1 Prepared By Name/Number: SiQnature þ~~ Phone 564-5521 Date Terrie Hubble, 564-4628 :. i/ ci; . .... ..ii: ......:i: iii; ....~... ii :i ...:.i....i ...;i ii- i ii'·..i..· i. ii Permit To Drill I API Number: Permit APprov,~ / I See cover letter for Number: Z. ð9-/ 9..~ 50- 029-21712-01-00 Date: /0' i' other requirements Conditions of Approval: Samples Required 0 Yes ~o Mud Log Requiréd .(. DYes )i:r'No . HYdro+; Sulfide Measures, ~Yes FJ No Directional Surve~ Required ~ Y ~s, 0 No _ Qlhe' T E',,-t-P"~ < ~ÇOO y.:> çA, r~< (,0 < S ì & ' ODD d,i.t I-' I y\ «1 a-tV v'\. f.-¿.. VVt (: e-tf- f) ~ ¡¿. 4t<Æ '. I 0 4. 0 I < APPROVED BY 16~ Idcr Aooroved Bvr '..A -- THE COMMISSION Date Form 10-401 ~ed iJZ604 U ¡~\ I Glf~AL $'ubmli In Dtfplicate · . I Well Name: J-23A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: X = 643,559.0 Y = 5,970,172.0 Estimated 1182' FNL 802' FEL Sec. 9, T11 N, R13E Umiat / Target Location: X = 641,259.0 Y = 5,970,029.0 TVDss 8960' Ivishak Zone 1 B /2A 1281' FNL 2175' FWL Sec. 9, T11 N, R13E Umiat Bottom Hole Location: X = 642,693.0 Y = 5,969,286.0 TVDss 8987' 2052' FNL 3593' FWL Sec. 9, T11N, R13E Umiat t' I AFE Number: I PBD4P2292 I I Estimated Start Date: 110/10/04 [MQJ 11,441' I I TVD: 19058' I I Rig: I Nabors 2ES (". I Operating days to complete: 116.5 I GL: 142.4' I KB: 128.5' I I KBE: 170.9' I Well Design (conventional, slim hole, etc.): I Single String Horizontal Sidetrack I Objective: I Ivishak Zone 1 B / 2A Formation Markers Formation Tops (wp03) MD TVD TVDss Comments TSGR 9058 8447 -8376 ABOVE KICKOFF KO 9068 8456 -8385 " SHUBLIK 9099 8484 -8413 " EILEEN NA " TSAD / TZ4B 9156 8539 -8468 " TCGL / TZ3 9343 8724 -8653 " BCGL / TZ2C 9403 8782 -8711 " 25N 9496 8869 -8798 " 22N 9593 9100 -8874 " PGOC 9640 8974 -8903 Expected BHP = 3165 psi (6.9 ppq EMW) 21N 9652 8981 -8910 " MHOIHOT (INITIAL " LANDING) 9788 9028 -8957 TZIB 9788 9028 -8957 " TDF / TZIA BelowTVDSS -8998 BSAD BelowTVDSS TD 11 ,441 9058 -8987 TD Criteria: The well objective is for 600' of perforations. The minimum is 300' of perfable sand incorporating 150' standoff from faults. g- ~ J-23A Permit to Drill Page 1 . . Directional - Sperry wp02 KOP: I 9068' MD Maximum Hole Angle: -89.4° in the 6 1/8" horizontal section Close Approach Wells: All wells pass major risk criteria for this well plan. The nearest well is 945' ctr-ctr with 754' allowable deviation. Survey Program: MW D Standard Nearest Property Line: 22,200' to the nearest PBU property line Nearest Well within Pool: J-09A at 945' center to center at 9579' planned depth. C IT b· P aSlngJ U mg rogram Hole Size CsgITbg WtlFt Grade Conn Length Top Btm O.D. MDfTVD MDfTVD 61/8" 4-1/2" 12.6# L-80 IBT-M 2741' 8,700'/8115' 11,441/9058' TubìnQ 4-1/2" 12.6# 13Cr-80 VAM Top -8675' GL 8,700'/8115' PV <10 Flo Pro PV <10 Logging Program 6 1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRlRes/Neu/Den/ ABI Open Hole: None Cased Hole: None Cement Program 4.5" 12.6#, L-80 Production Liner #,~"..? 3 sacks Class G @ 15.8 pp ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. J-23A Permit to Drill Page 2 . . Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure Summar'l Current Condition: ./ Callipered tubing: general corrosion and isolated pitting 20-35% with no significant wall loss 04/06/03. ./ Found leak at 6022' with leak detection log at 1.5 bpm / 850 psi 04/25/03. ./ Set tubing patch at 6000' - 6060' MO, 09/01/03 ./ Passed MITlA to 2500 psi; failed MITOA (on vacuum, not cemented) 9/05/04. ./ BPV set in tubing hanger 09/?/04 Scope Pre-Riq Operations: 1. Remove BPV from tubing hanger; bleed IA and tubing or fluid pack as necessary, 2. Test the 9-5/8" and tubing pack-offs, function all LOS, repair or replace as necessary. 3. RU Slick-line. RIH and pull Eclipse patch at 6000'. RIH and drift 4-1/2" tubing to 3-1/2" crossover at 6250'. RIH and drift 3-1/2" tail pipe and tag PBTO. 4. RU coil tubing. RIH and P&A the perforation with cement to 9500', Squeeze - 5 bbls into perf's. 5. CMIT fA and Tubing to 3500 psi for 30 minutes. 6. RU E-line. RIH and perform a tubing punch in the first 3-1/2" pup joint (-6257') just below the 4-1/2" x 3-1/2" crossover. This will minimize gas when packer milling commences with the rig. Perform tubing punch and string shot above the packer as per Schlumberger recommendation for the upcoming chemical cut. RIH and chemical cut the 4-1/2" tubing in the middle of joint #1 - 6197' Oust below sliding sleeve and just above the seal assy). 7. Circulate the well to seawater. Freeze protect the IA and tubing with diesel to - 2200'. 8. Bleed all pressures to zero. Set BPV. Secure well. 9. Remove the well house. If necessary, level the pad. RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to Sea Water. 3. Monitor OA, IA and T for pressure. Verify well is dead. J-23A Permit to Drill Page 3 . . ¡ 4. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 5. Pull 4-1/2" tubing from pre-rig cut at - 6197'. (Have a spear on location as a contingency). 6. PU overshot assy. RIH picking up 4" DP. Washover tubing stub and rotate latch assy free, POOH. NOTE: If SBR rotates free a second trip to retrieve the latch assy. will be required. 7. PU packer mill and PRT assy. RIH, engage PRT and mill until packer releases as per Baker representative, POOH with packer and 4-1/2" x 3-1/2" tailpipe assy. Note: Tailpipe assembly should be 2632' long. 8. RU e-line. Run GR/JB for 7",26# casing to about 9238' (-150' past expected EZSV setting depth). 9. MU 7", 26# EZSV bridge plug on e-line with gamma ray/CCL. RIH and set the plug at - 9088' MD. Set the bridge plug at ±9088' to avoid cutting a casing collar with the whipstock mill a~re KOP is below TSGR (planned 10' below). RD e-line. Close blinds and test 9-5/8" casing t~psi for 30 minutes while recording on chart. T k<, (~ t 0 ~ 4 0 { c...p p. ('O¡j tl. f . 10. MU and RIH with 7" whipstock, MWD and milling assem'bly to t~e EZSV. Orient and set whipstock,/ swap over to 8.5 ppg mud before milling the window. 11. Mill a window through 7" casing at -9068' plus 20' from mid window. Perform FIT to 10.0, POOH for /' drilling BHA. 12. MU the 6-1/8" drilling assembly with DIR/GR/RES/NEU/DEN and RIH. Kick off and drill 6-1/8" ,/ production interval as per directional plan to an estimated TD of 11441 '. 13. Run and cement a 4-1/2", 12.6#, L-80 liner throughout the 6-1/8" well bore and 368' back into the 7" . liner to 8,700' MD. Note: The extra lap covers bottom of the 7" scab liner and top of original 7" liner. / Set liner top packer and displace well to clean seawater above the liner top. 14. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns 15. Run 4-1/2",12.6#, 13Cr-80 completion tying into the 4-1/2" liner top. 16. Set packer, test and record the tubing to 3500 psi and annulus to 3500 psi for 30 minutes each. 17. Set and test TWC to 1000 psi. 18. ND BOPE. NU and test the tree to 5000 psi. Pull TWC. / 19. Freeze protect the well to -2200'. Set BPV and secure the well. 20. RDMO. / Post-RiÇl Work: 1. Install wellhouse and flowlines. 2. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. J-23A Drilling Program Job 1: MIRU Hazards and Contingencies ~ J-23 is on 33' centers with J-08 to the north and J-20 to the south. No well houses will require removal or shut-in for the rig move onto J-23. ~ J-Pad is ..!!Ejßesignated as an H2S site. Recent H2S data from the pad is as follows: Well Name H2S ReadinÇl Date #1 Closest SHL J-08 N/A #2 Closest SHL J-20B N/A #1 Closest BHL J-09A 10 ppm 8/8/2004 #2 Closest BHL J-11 A 10 ppm 11/16/2000 The maximum on the pad is J-26 at ~ppm on 9/20/2000 ~ Post Permit to Drill in the dog house and camp prior to spud J-23A Permit to Drill Page 4 . . Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies >- Though pre-rig work includes a tubing punch immediately below the production packer, expect a small amount of gas after milling through the packer. In the event the tubing punch was ineffective, the gas volume will be very large behind the 2600' tailpipe. >- Ensure all crossovers and safety valves for the 3 W' and 4 W' tubing are on the rig floor. >- In the event the packer cannot be milled and recovered, the contingency is to move up to 6000 MD for a two-string sidetrack. >- NORM test all retrieved well head and completion equipment. >- Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies >- Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies >- Must tie MWD - GR-Sonic back to PDC log of parent well J-23 (copy provided in wellsite geologist's package). CAUTION: KB for J-23 and J-23A are different. MD values reported in this SOR are referenced to the J-23A KB. >- A second tricone bit may be required if conglomerates wear out the first run, though the directional plan is designed to drill Zn3 at a low angle which will minimize footage drilled in Zn3. >- Geosteer into lower 2A if Zone 1 B has less then 10 feet NLOC in Zn 1 B >- The well plan passes through a possible fracture at 10680' MD (-8979' TVDSS) in Zone 1 B. The fracture is not visible on seismic but the location and throw (less then 10' of throw down to the east) are inferred based on nearby fault patterns. The risk of losses at this fracture is low. Overall. the risk of faults and fracture associated lost circulation with is low in the target area. Lost circulation events from 4 nearby wells are summarized and addressed below: o The parent well, J-23 did not lose any fluid. / o J-09 lost 1200 barrels of fluid at -8540 TVDSS in Zone 4. These losses are within 150' of a large NW-SE trending fault. J-23A does not drill within 150' of any large NW-SE faults. o J-09A lost 30, 240, 20, and 145 barrels of fluid in Zone 3 and 1. These losses occurred in close proximity to a large NW-SE trending fault. J-23A maintains at least more than 500' from any large faults. J-23A Permit to Drill Page 5 . . o J-01 A lost 57 barrels of fluid at -8977 TVDSS (9900 MD) in Zone 2 sand. The losses occurred near TD and within 150' of a large SW-NE trending fault with more than 200 ft of throw, J-23A and all contingency plans will maintain at least 250' of standoff from this fault to minimize risk of lost circulation. o The Q-04A well lost 48 barrels of fluid at -8975 TVDSS in Zone 2 in a region of no observed faults or features. Reason for losses are unknown. >- KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture grad!~. of .5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance iS~. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Cement job is critical for isolation from gas through build section and any intersecting faults. ~ Differential sticking is a concern. The 8.5 ppg mud will be -750psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. >- Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. >- Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program Job 10: DPC Perforate Production Casinq Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. ~ Initial perfs should be 500' from parent well to avoid gas cone Reference RPs .:. Follow Schlumberger perforating practices and recommendations. .:. "OPC Perforating" RP J-23A Permit to Drill Page 6 · . Job 12: Run Completion Hazards and Contingencies > Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Ria Hazards and Contingencies > No wells will require well house removal or shut-in for the rig move off of J-23A. See MIRU section for nearest well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP J-23A Permit to Drill Page 7 TREE = 6" CAMERON W8...LHEAO = M;EVOY A CfLÞHOR = OTIS KB. ELEV = 78.65' B K M o o J-23 I SAFElY NOTES 14- F.ELEV- 42.35' OP- 3300' ax AnQB - 31 @. 5892' . 2093' CAtv'CO SSSV SlÐING NIP, Ð = 3.813" I atum MO = 952T atumTVO = 8800' SS 1 13-3I8"CSG, 72#, L-80, BTRS, 10= 12.347" 2672' ~ .. GAS LIFT MANDRElS L ST NO lVO DEV TYPE VLV LATQ-I FORT DATE 3 2996 2917 5 OTIS RA Minimum ID = 2.250" @ 6000' ~ ~ 2 5274 4995 31 OTIS RA "" 1 6094 5697 31 OTIS RA 4-1/2" ECLIPSE PATCH f'-.. 1 6000' - 6060' 4-1/2" EQ/PSEPATCH j (06/18/03 & 09/01/03). 10 = 2.250" 9-5/8" CSG, 47#, L-80, NSCC, 10 = 8.681" 4600' ~ ~ I I 6163' BAKER SLIDING SLEEVE, Ð=3.813" 1 ~ ..,....,. 6237' 9-5/8" TW fi3BP PKR,IO - 4.750" J "'--" I 1/2" BUTTTBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 6250' I I 6250' 4-1/2" x 3-1/2" XO TOPOF3-1/2"lBG H 6250' I r-- II I 6263' -13-1/2" SLIDING SLEEVE I TOP OF T' SCAB LNR 6269' r II ~ ~ . . I 8804' 3-1/2" OTIS X NIp, 10 = 2.750" J I TOP OF 7" LNR 8806' I ~ . . I 8836' 3-1/2" OllS XN NIP, 10 = 2.635" J 13-1/2" TBG, 9.2#, L-80, .0087 bpf, 10 = 2.992" 8869' I I 8869' 4-1/2" Sl-EAROUT SUB 1 I 8856' H ELNO TT LOGGED 03102/91 I J 9-518" CSG, 47#, L-80, BRTS, 10 = 8.681" 9058' l---J ~ PERFORATION SUrvMARY I. REF LOG: BHCS ON 04/06/87 ANGLE AT TOP PERF: 23 @ 9636' I Note: Refer to Production DB for historcal perf data I SIZE SPF INTERV AL Opn/Sqz DATE I 2-1/8" 4 9636 - 9640 S 03111/93 2-1/8" 6 9650 - 9660 0 03115/93 I 2-1/8" 4 9658 - 9672 S 03111/93 2-1/2" 6 9660 - 9680 0 02/07/01 I 2-1/8" 4 9670 - 9695 0 10/27/93 9695 - 9703 S I -.. I 9648' 21' OF 2.5" ÆRF Gl.N - 02/10/01 I J R3ID 9869' I 17" LNR. 26#, L-80, 1J4S, .0383 bpf,lO = 6.276" 9912' I DATE REV BY COMMENTS 04/20187 ORIGINAL COMPLETION 07/19/01 RNITP CORRECllONS 04/16103 CMO/KK MAXANGLECORRB:::llON 06/18103 M;i'VTL SET PA TQ-I (LOWER) 09/01/03 BJMIKK SET 4-1/2" PATQ-I OS/28104 JOG/KA PERF CORRB:::TONS DA TE RBI BY COrvMe-.JTS PRUDHOE BAY l.NfT WELL: J-23 ÆRrvIT I\b: 1870310 APII\b: 50-029-21712-00 SB::: 9, T11 N, R13E, 1182' FNL & 802' FEL BP Exploration (Alaska) TREE = 6" CA MERON WELLHEAD = McEVOY ACTUA TOR = OTIS KB. ELEV = 78.65' BF. ELEV = 42.35' KOP = 3300' Max Angle = 31 @ 5892' Datum MD = 9527' Datum 1VD:: 8800' SS . J-23 Pre-Rig . 13-3/8" CSG, 72#, L-80, BTRS, 10 = 12.347" I . -JCAMCO SSSV SLIDING NIP, ID = 3.813" I I 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" I ST MD 1VD 3 2996 2917 2 5274 4995 1 6094 5697 GAS LIFT MANDRELS DEV TYPE VLV LATCH PORT 5 OTIS RA 31 OTIS RA 31 OTIS RA DATE Unknown CMT height behind 9-5/8 CSG Initial job cales TOC = 8047' 1st sqz (4/12/87) = - 1975' Ann FT of CMT I I 6163' -lBAKER SLIDING SLEEVE, 10 = 3.813" Chemical Cut tubing - 6197' 6237' -l 9-5/8" TIW HBBP PKR, ID = 4.750" I I 4-1/2" BlJTT TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-i TOPOF 3-1/2" TBG H 6250' 6250' 6263' -13-1/2" SLIDING SLEEVE 8804' -l 3-1/2" OTIS X NIP, 10:: 2.750" I 13-1/2" TBG, 9.2#, L-80, .0087 bpf, 10 = 2.992" I I 9-5/8" CSG, 47#, L-80, BRTS, 10:: 8.681" I -þ-1/2" OTIS XN NIP, ID = 2.635" I -i4-1/2" SHEAROlIT SUB I H ELMD TT LOGGED 03/02/91 I ÆRFORA TION SUMMARY REF LOG: BHCS ON 04/06/87 ANGLEAT TOP ÆRF: 23 @ 9636' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-1/8" 4 9636-9640 S 03/11/93 2-1/8" 6 9650 - 9660 0 03/15/93 2-1/8" 4 9658 - 9672 S 03/11/93 2-1/2" 6 9660 - 9680 0 02/07/01 2-1/8" 4 9670 - 9695 0 10/27/93 9695 - 9703 S TOC - 9500' -5bbls squeezed into perf's -J 21' OF 2.5" ÆRF GUN - 02/10/011 PBTD 17" LNR, 26#, L-80, U4S, .0383 bpf, ID:: 6.276" REV BY COMMENTS ORIGINAL COM PLETION RNlTP CORRECTIONS CMO/KK MAX ANGLE CORRECTION McNlTL SET PATCH (LOWER) SET 4-1/2" PATCH ÆRF CORRECTIONS DATE REV BY COMMENTS PRUDHOE BA Y UNrr WELL: J-23 ÆRMrr No: 1870310 API No: 50-029-21712-00 SEe 9, T11 N, R13E, 1182' FNL & 802' FEL BP Exploration (Alaska) TREE; WELLHEAD = ÄCtÛÄTOR :; Kê:äèi:: BÞ.Ët...Ë\/ :; KOP= Max Angle = Datum MD = Datum rvD = . J -23A . Proposed Completion Perf's (4/17/87) 8700' - 8705'- 2200' - HES 4-1/2" X Nipple 10 = 3.813" 8800' SS 113-3/8" CSG, 72#, L-80, BTRS, 10 = 12.347" I 4-1/2" TBG, 12.6#, 13Cr-80, 10 = 3.958" TOPOF7" SCAB LNR H 6269' Sqeezed Perf's (4/12/87) 6790' - 6793'- GAS LIFT MANDRELS ST MD rvD DEV "TYPE VLV LATCH PORT DATE 4 3300 1.5" 3 5500 1.5" 2 7100 1" 1 8115 1" I 9-5/8" CSG, 47#, L-80, NSCC, ID = 8.681" I HES 4-1/2" X Nipple 10 = 3.813" BKR 7" x 4-1/2" PKR HES 4-112" X Nipple 10 = 3.813" HES 4-1/2" XN Nipple 10 = 3,725" 4-1/2" WLEG 8700' - T' x 5" BKR LNR Hanger and Packer I 9-5/8" CSG, 47#, L-80, BRTS, ID = 8.681" I Unknown CMT height behind 9-5/8 CSG Initial job cales TOC = 8047' 1st sqz (4/12/87) = - 1975' Ann FT of CMT Top of Whipstock - 9068' ~ EZSV - 9088' 4-1/2" Solid LNR, 12.6#, L-80, 11441' I PBTD I 17" LNR, 26#, L-80, IJ4S, .0383 bpf, 10 = 6.276" I TOC - 9500' -5bbls squeezed into perfs -1 21' OF 2.5" PERF GUN - 02/10/01 I DA TE REV BY COMMENTS 04/20/87 ORIGINAL COM PLETION 07/19/01 RNITP CORRECTIONS 04/16/03 CMO/KK MAX ANGLE CORRECTION 06/18/03 McNl1L SET PATCH (LOWER) 09/01/03 BJMlKK SET 4-1/2" PATCH OS/28/04 JOG/KA PERF CORRECTIONS DA TE REV BY COMMENTS 09/09/04 KWA Proposed Completion PRUDHOE SA Y UNIT WELL: J-23A PERMIT No: API No: 50-029-21712-01 BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMA. nON HP Amoco SURVEY PROGRAM IX>pth Fm fÀ>pth To Survey/PJan 9068:00 ! 1440.64 Planned; J-23A wp02 V16 Too! 70.85 MWD CASING DETAILS No. TVD MD Name Size 9057.84 II 440.00 41/2" 4.500 Name +N!·S +E/.W Northing )·23 1%2.39 2439.60 5970172.00 643:559.00 70"19'3355IN 148"50'08..880W 23 TARGET DETAILS ---- Plan; J~23A wp02 (J-23/Plan J~23A) Created By: Troy Jakabo¡:ky CJlecke-d- Date: 9nn004 Date- Reviewed Date WELL DETAILS &sting flltitude Longìtude Slot Name TVD +N/-S +E/-W Northing Easting Shape J-23A 1'1 9030.85 -98.98 -2302.49 5970029.00 641259.00 Point J-23A 1'2 9050.85 -513.45 - 1447.20 5969631.00 642122.00 Point J-23A 1'3 9057.85 -869.34 -882.86 5969286.00 642693.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee 1 9068.00 2L92 280.50 8455.65 19.89 -2575.52 0,00 0.00 1821.21 2 9088.00 23.25 274.43 8474.05 20.91 -2583.29 12;00 -85.00 1826.03 3 9300.67 í2.96 100.78 8682.34 19.65 -2602.35 17.00 -177.59 1840.50 4 9403.23 12;96 100.78 8782.29 15.35 -2579.76 0.00 0.00 1827.42 5 9822.40 88.00 11 5.00 9030.85 -98.98 -2302.49 -fl;gg 14.69 1710.07 6 9826.63 88.74 115.20 9030.97 -100.77 -2298.66 15.38 1708.60 7 ]059MO 88.74 115.20 9047.97 -428.64 -1601.97 0.00 0.00 1442.22 8 10773.42 89.40 122.24 9050.85 -513.45 -1447.20 4.00 84.67 1391.44 9 ] 1440.64 89.40 122.24 9057.85 -869.34 -882.86 0.00 0.00 1239.03 -¡¡ € ~ Æ Target J-23A 1'1 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 2 3 4 5 6 7 8 9 8483.85 8538.85 8723.85 8781.85 8868.85 8944.85 8973.85 8900.85 9027.85 9098.60 WHU 9156.05 WAD 934327 TCGL 9402.78 BeGL 9496.39 25N 9593.44 22N 9639.57 PGOC 9652,18 2JN 9788.36 TZ JB ---- COM1~A}.¡'YDETAllS REFERENCE INFORÞ-iJ\ TiON BPAmê!i;(' 7û.85 SECTION DETAILS See MD Ifie Azi TVD +NI-S +E/-W DLeg TFace VSec Target I 9068.00 22.92 280.50 8455.65 19.89 -2575.52 0.00 0.00 -180nO 2 9088.00 23.25 274.43 8474.05 20.91 -2583.29 12.00 -85.00 -1811.88 3 9300.67 12.96 100.78 8682.34 19.65 -2602.35 17.00 -177.59 -1826.25 4 9403.23 12.96 100.78 878229 15.35 -2579.76 0.00 0.00 -1813.31 5 9822.40 88.00 11 5.00 9030.85 -98.98 -2302.49 18.00 14.69 -1698.09 J-23A Tl 6 9826.63 8K74 115.20 9030_97 -100.77 -2298.66 1KOO 15.38 -1696.65 7 10596.80 88.74 115.20 9047.97 -428.64 -1601.97 0.00 0.00 -1435.86 8 10773.42 89.40 122.24 9050.85 -513A5 -144720 4.00 84.67 -1386.39 J-23A T2 9 11 440.64 89.40 122.24 9057.85 -869.34 -882.86 0.00 0.00 -1238.99 J-23A T3 Deptb Fm Depth To Survey/Plan 9068.00 11440-64 pjanm.'<± J-23A 'WpÜ2 V16 roo! pJan: }-21A \vp02 (J-23!P!an J-23A) Cr!;''ated By: Troy Jakabn8ky Date: W7120M SURVEY PROGRAM MWD Cheçked: Date:_ Name ~Ni",," Northing EastÎ¡:¡g La.titude LOI1girud.; S!ol 190239 243%0 5970172.fiO 643559.00 70"19'3355iN 148~5Û'08.880W 23 TARGET DETA1LS Name TVD +Ni-S +E/-W Northing Easting Shape J-23A T! 9030.85 -98.98 -2302.49 5970029.00 Point J-23A T2 9050.85 -513.45 -1447.20 596963 LOO Point J-23A T3 9057.85 -869.34 -882.86 5969286.00 Point CASING DETAILS No. TVD MD Name Size " ~ '" f3. ¿ "" 15 ~ :¡g " o VJ 9057.84 11440.00 4 112" 4.500 FORMA nON TOP DET ArLS No. TVDPatb MDPath Formation 1 8483.85 9098.60 TSHU 2 8538.85 9156.05 TSAD 3 8723.85 9343.27 TCGL 4 8781.85 9402.78 RCGL 5 8868.85 9496.39 25N 6 8944.85 9593.44 22N 7 8973.85 9639.57 PGQC 8 8980.85 9652.18 21N 9 9027.85 9788.36 TZlB . . BP BP Planning Report J-23A wp02 Rev. from Ken A 10' deeper TVD KOP Yes Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB J Pad TR-11-13 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5968224.22 ft 641155.79 ft Latitude: 70 19 Longitude: 148 51 North Reference: Grid Convergence: 14.845 N 20.092 W True 1,08 deg WelI: J-23 Slot Name: 23 J-23 WelI Position: +N/-S 1902.39 ft Northing: 5970172.00 ft Latitude: 70 19 33.551 N +E/-W 2439.60 ft Easting : 643559.00 ft Longitude: 148 50 8.880 W Position Uncertainty: 0.00 ft Casing Points 0,00 TSGR 0.00 0.00 9098.60 8483.85 TSHU 0.00 0.00 9156.05 8538.85 TSAD 0.00 0.00 9343.27 8723.85 TCGL 0.00 0.00 9402.78 8781.85 BCGL 0,00 0.00 9496,39 8868.85 25N 0.00 0.00 9593.44 8944,85 22N 0.00 0.00 9639.57 8973.85 PGOC 0,00 0.00 9652.18 8980.85 21N 0.00 0.00 9788.36 9027.85 TZ1B 0.00 0.00 Targets J-23A T1 9030.85 -98.98 -2302.49 5970029.00 641259.00 70 19 32.574 N 148 51 16.089 W J-23A Fault 1 9049.85 -694.11 -1519.67 5969449.00 642053.00 70 19 26.723 N 148 5053.235 W -Polygon 1 9049.85 -694.11 -1519.67 5969449.00 642053.00 70 19 26.723 N 148 5053.235 W -Polygon 2 9049.85 -218.25 -1453.55 5969926.00 642110.00 70 1931.403N 148 50 51.308 W J-23A T2 9050.85 -513.45 -1447,20 5969631.00 642122.00 70 19 28.500 N 148 5051.121 W J-23A GEO Poly 9050.85 35.92 -2661.01 5970157.00 640898.00 70 19 33.900 N 148 51 26.555 W -Polygon 1 9050.85 35.92 -2661.01 5970157.00 640898.00 70 19 33.900 N 148 51 26.555 W -Polygon 2 9050.85 -329.86 -2363.93 5969797.00 641202.00 70 19 30.303 N 148 51 17.880 W -Polygon 3 9050.85 -564.45 -1604.22 5969577.00 641966.00 70 19 27.998 N 148 50 55.703 W -Polygon 4 9050.85 -1042.16 -842.16 5969114.00 642737.00 70 19 23.301 N 148 50 33.459 W -Polygon 5 9050.85 -784.92 -642.18 5969375.00 642932.00 70 19 25.831 N 148 50 27.623 W -Polygon 6 9050.85 -1.40 -2174.59 5970129.00 641385.00 70 1933.534 N 148 51 12.356 W J-23A T3 9057.85 -869.34 -882.86 5969286.00 642693.00 70 19 25.001 N 148 5034.648 W . . BP BP Planning Report 9068.00 22.92 280.50 8455.65 19.89 -2575.52 0.00 0.00 0.00 0.00 9088.00 23.25 274.43 8474.05 20.91 -2583.29 12.00 1.63 -30.33 -85.00 9300.67 12.96 100.78 8682.34 19.65 -2602.35 17.00 -4.84 -81.65 -177.59 9403.23 12.96 100.78 8782.29 15.35 -2579.76 0.00 0.00 0.00 0.00 9822.40 88.00 115.00 9030.85 -98.98 -2302.49 18.00 17.90 3.39 14.69 J-23A T1 9826.63 88.74 115.20 9030.97 -100.77 -2298.66 18.00 17.36 4.78 15.38 10596.80 88.74 115.20 9047.97 -428.64 -1601.97 0.00 0.00 0.00 0.00 10773.42 89.40 122.24 9050.85 -513.45 -1447.20 4.00 0.38 3.98 84.67 J-23A T2 11440.64 89.40 122.24 9057.85 -869.34 -882.86 0.00 0,00 0.00 0.00 J-23A T3 Survey 9068.00 22.92 280.50 8455.65 8384.80 19.89 -2575.52 0.00 5970142.62 640983.77 Start Dir 12/10 9075.00 23.01 278.36 8462.10 8391.25 20.34 -2578.22 12.00 5970143.01 640981.06 MWD 9088.00 23.25 274.43 8474.05 8403.20 20.91 -2583.29 12.00 5970143.48 640975.98 Start Dir 17/10 9098.60 21.45 274.23 8483.85 8413.00 21.21 -2587.30 17.00 5970143.71 640971.96 TSHU 9100.00 21.21 274.20 8485.16 8414.31 21.25 -2587.81 17.00 5970143,74 640971.45 MWD 9125.00 16.97 273.53 8508.78 8437.93 21.80 -2595.97 17.00 5970144.14 640963.29 MWD 9150,00 12.73 272.43 8532.94 8462.09 22.15 -2602.37 17.00 5970144.36 640956.89 MWD 9156.05 11.70 272.05 8538.85 8468.00 22,20 -2603.64 17.00 5970144.38 640955.61 TSAD 9175.00 8.49 270.27 8557.51 8486.66 22.27 -2606.96 17.00 5970144.39 640952.29 MWD 9200.00 4.30 263.90 8582.34 8511.49 22.18 -2609.74 17.00 5970144.25 640949.51 MWD 9225.00 0.95 183.13 8607.32 8536.47 21.87 -2610.69 17.00 5970143.92 640948.57 MWD 9250.00 4.41 109.06 8632.29 8561.44 21.35 -2609.79 17.00 5970143.42 640949.48 MWD 9275.00 8,61 102.93 8657.13 8586.28 20.62 -2607.06 17.00 5970142.74 640952.23 MWD 9300.00 12.84 100.82 8681.68 8610.83 19.68 -2602.50 17.00 5970141.89 640956.80 MWD 9300.67 12.96 100.78 8682.34 8611.49 19.65 -2602.35 17.00 5970141.86 640956.95 End Dir : 9300 9325.00 12.96 100.78 8706.05 8635.20 18.63 -2596.99 0.00 5970140.94 640962.32 MWD 9343.27 12.96 100.78 8723.85 8653,00 17.86 -2592.97 0.00 5970140.25 640966.36 TCGL 9350.00 12.96 100,78 8730.41 8659,56 17.58 -2591.49 0.00 5970140.00 640967.85 MWD 9375.00 12.96 100.78 8754.77 8683.92 16.53 -2585.98 0.00 5970139.06 640973.37 MWD 9400.00 12.96 100.78 8779.14 8708.29 15.49 -2580.47 0.00 5970138.12 640978.90 MWD 9402.78 12.96 100.78 8781.85 8711.00 15.37 -2579.86 0.00 5970138.01 640979.51 BCGL 9403.23 12.96 100.78 8782.29 8711.44 15.35 -2579.76 0.00 5970137.99 640979.61 Start Dir 18/10 9425.00 16.78 104,22 8803.32 8732.47 14.12 -2574.32 18.00 5970136.87 640985.08 MWD 9450.00 21.21 106.67 8826.96 8756.11 11.94 -2566.49 18.00 5970134.84 640992.95 MWD 9475.00 25.66 108.30 8849.89 8779,04 8.94 -2557.01 18.00 5970132.02 641002.48 MWD 9496.39 29.48 109.33 8868,85 8798.00 5.74 -2547.64 18.00 5970129.00 641011.91 25N 9500.00 30.13 109.48 8871.98 8801.13 5.15 -2545.95 18.00 5970128.44 641013.61 MWD 9525.00 34.60 110.38 8893.09 8822.24 0.58 -2533.38 18.00 5970124.11 641026.27 MWD 9550.00 39.08 111.09 8913.09 8842.24 -4.73 -2519.36 18.00 5970119.07 641040.38 MWD 9575.00 43.56 111.68 8931,86 8861,01 -10.75 -2504.00 18.00 5970113.35 641055,86 MWD 9593.44 46.87 112.05 8944.85 8874.00 -15.63 -2491.86 18.00 5970108,71 641068.09 22N 9600.00 48.05 112.18 8949.29 8878.44 -17.45 -2487.38 18.00 5970106.97 641072.60 MWD 9625.00 52,54 112.61 8965.26 8894.41 -24.77 -2469.60 18.00 5970099.99 641090,52 MWD 9639.57 55.15 112.84 8973.85 8903.00 -29.32 -2458.75 18.00 5970095.65 641101.45 PGOC 9650.00 57.03 113.00 8979.67 8908.82 -32,69 -2450.78 18.00 5970092,43 641109.48 MWD . . BP BP Planning Report 9652.18 57.42 113.03 8980.85 8910.00 -33.41 -2449.09 18.00 5970091.75 641111.18 21N 9675.00 61.52 113.34 8992.44 8921.59 -41.14 -2431.03 18.00 5970084.36 641129.39 MWD 9700.00 66.01 113.66 9003.49 8932,64 -50.09 -2410.47 18.00 5970075.81 641150.12 MWD 9725.00 70.50 113.96 9012.75 8941.90 -59.46 -2389.23 18.00 5970066,85 641171.53 MWD 9750.00 74.99 114.24 9020.17 8949.32 -69.20 -2367.44 18.00 5970057.52 641193.50 MWD 9775.00 79.48 114,51 9025.69 8954.84 -79.26 -2345.24 18.00 5970047.89 641215.89 MWD 9788.36 81,88 114.65 9027.85 8957.00 -84.75 -2333,25 18.00 5970042.64 641227,97 TZ18 9800,00 83.97 114.77 9029.28 8958.43 -89.58 -2322.76 18.00 5970038,01 641238.56 MWD 9822.40 88.00 115.00 9030,85 8960.00 -98.98 -2302,49 18.00 5970029.00 641259.00 J-23A T1 9825.00 88.45 115.12 9030.93 8960.08 -100.08 -2300.14 18.00 5970027.95 641261.37 MWD 9826.63 88.74 115.20 9030.97 8960.12 -100.77 -2298.66 18.00 5970027.28 641262.87 End Dir : 9826 9850,00 88.74 115.20 9031.49 8960.64 -110.72 -2277.52 0.00 5970017.74 641284.19 MWD 9875.00 88,74 115.20 9032.04 8961.19 -121.36 -2254.91 0.00 5970007.53 641307.00 MWD 9900.00 88.74 115.20 9032.59 8961.74 -132.00 -2232.29 0.00 5969997.32 641329.81 MWD 9925.00 88.74 115.20 9033.14 8962.29 -142.65 -2209.68 0.00 5969987.12 641352.62 MWD 9950.00 88.74 115.20 9033.69 8962.84 -153.29 -2187.06 0.00 5969976.91 641375.44 MWD 9975.00 88.74 115.20 9034.25 8963.40 -163.93 -2164.45 0.00 5969966.70 641398.25 MWD 10000.00 88.74 115.20 9034.80 8963.95 -174.58 -2141.83 0.00 5969956.49 641421.06 MWD 10025.00 88.74 115.20 9035.35 8964.50 -185.22 -2119.22 0.00 5969946.29 641443.87 MWD 10050.00 88.74 115.20 9035.90 8965.05 -195.86 -2096.60 0.00 5969936.08 641466,69 MWD 10075.00 88.74 115.20 9036.45 8965.60 -206.50 -2073.99 0.00 5969925.87 641489.50 MWD 10100.00 88.74 115.20 9037.00 8966.15 -217.15 -2051.37 0.00 5969915.67 641512.31 MWD 10125.00 88.74 115.20 9037.56 8966.71 -227.79 -2028.76 0.00 5969905.46 641535.12 MWD 10150.00 88.74 115.20 9038.11 8967.26 -238.43 -2006.14 0.00 5969895.25 641557.94 MWD 10175.00 88.74 115.20 9038.66 8967.81 -249.08 -1983.53 0.00 5969885.04 641580.75 MWD 10200.00 88.74 115.20 9039.21 8968.36 -259.72 -1960.92 0.00 5969874.84 641603.56 MWD 10225.00 88.74 115.20 9039.76 8968.91 -270.36 -1938.30 0.00 5969864.63 641626.37 MWD 10250.00 88,74 115.20 9040.32 8969.47 -281.00 -1915.69 0.00 5969854.42 641649.19 MWD 10275.00 88.74 115.20 9040.87 8970.02 -291.65 -1893.07 0.00 5969844.21 641672.00 MWD 10300.00 88.74 115.20 9041.42 8970.57 -302.29 -1870.46 0.00 5969834.01 641694.81 MWD 10325.00 88.74 115.20 9041.97 8971.12 -312.93 -1847.84 0.00 5969823.80 641717.62 MWD 10350.00 88,74 115.20 9042.52 8971.67 -323.57 -1825.23 0.00 5969813.59 641740.44 MWD 10375.00 88.74 115,20 9043.07 8972.22 -334.22 -1802.61 0.00 5969803.38 641763.25 MWD 10400.00 88.74 115.20 9043.63 8972.78 -344.86 -1780.00 0.00 5969793.18 641786.06 MWD 10425.00 88.74 115.20 9044.18 8973.33 -355.50 -1757.38 0.00 5969782.97 641808.87 MWD 10450.00 88.74 115.20 9044.73 8973.88 -366.15 -1734.77 0.00 5969772.76 641831.69 MWD 10475.00 88.74 115.20 9045,28 8974.43 -376.79 -1712.15 0.00 5969762.55 641854.50 MWD 10500.00 88.74 115.20 9045.83 8974.98 -387.43 -1689.54 0.00 5969752.35 641877.31 MWD 10525.00 88.74 115.20 9046.39 8975.54 -398.07 -1666.92 0.00 5969742.14 641900.12 MWD 10550.00 88.74 115.20 9046.94 8976,09 -408.72 -1644.31 0.00 5969731.93 641922.94 MWD 10575.00 88.74 115.20 9047.49 8976.64 -419.36 -1621.69 0.00 5969721.72 641945,75 MWD 10596.80 88.74 115,20 9047.97 8977.12 -428.64 -1601.97 0.00 5969712.82 641965.64 Start Dir 4/100 10600.00 88.75 115.33 9048.04 8977.19 -430,01 -1599.08 4.00 5969711.51 641968.56 MWD 10625.00 88.84 116.33 9048.57 8977.72 -440.90 -1576.58 4.00 5969701.06 641991.26 MWD 10650.00 88.93 117.32 9049.05 8978.20 -452.17 -1554.28 4.00 5969690.21 642013.78 MWD 10675.00 89.03 118.32 9049.50 8978.65 -463.84 -1532.17 4.00 5969678.97 642036.10 MWD 10700.00 89.12 119.31 9049.90 8979.05 -475.89 -1510.27 4.00 5969667.34 642058.23 MWD 10725.00 89.22 120.31 9050.26 8979.41 -488.31 -1488.58 4.00 5969655.34 642080.15 MWD 10750.00 89.31 121,30 9050.59 8979.74 -501.12 -1467.11 4.00 5969642.95 642101.86 MWD 10773.42 89.40 122.24 9050.85 8980.00 -513.45 -1447.20 4.00 5969631.00 642122.00 J-23A T2 10775.00 89.40 122.24 9050.87 8980.02 -514.29 -1445.86 0.00 5969630.18 642123.35 MWD 10800.00 89.40 122.24 9051.13 8980.28 -527.62 -1424.72 0.00 5969617.26 642144.74 MWD 10825,00 89.40 122.24 9051.39 8980.54 -540.96 -1403.57 0.00 5969604.33 642166.14 MWD . . BP BP Planning Report 10850.00 89.40 122.24 9051.65 8980.80 -554.29 -1382.43 0.00 5969591.40 642187.53 MWD 10875.00 89.40 122.24 9051.92 8981.07 -567.63 -1361.28 0.00 5969578.48 642208.93 MWD 10900.00 89.40 122.24 9052.18 8981,33 -580.96 -1340,14 0.00 5969565.55 642230.32 MWD 10925.00 89.40 122.24 9052.44 8981.59 -594.30 -1318.99 0.00 5969552.62 642251.72 MWD 10950.00 89.40 122.24 9052.70 8981.85 -607.63 -1297.85 0.00 5969539.70 642273.11 MWD 10975.00 89.40 122.24 9052.96 8982,11 -620.97 -1276.70 0.00 5969526.77 642294.51 MWD 11000.00 89.40 122.24 9053.23 8982.38 -634.30 -1255.56 0.00 5969513.84 642315,90 MWD 11025.00 89.40 122.24 9053.49 8982.64 -647.64 -1234.41 0,00 5969500.92 642337.30 MWD 11050.00 89.40 122.24 9053.75 8982,90 -660.97 -1213.27 0.00 5969487.99 642358.69 MWD 11075.00 89.40 122.24 9054.01 8983.16 -674.31 -1192.12 0.00 5969475.06 642380,09 MWD 11100.00 89.40 122.24 9054.28 8983.43 -687.64 -1170.98 0.00 5969462.14 642401.48 MWD 11125.00 89.40 122.24 9054.54 8983.69 -700.98 -1149.83 0.00 5969449.21 642422.88 MWD 11150.00 89.40 122.24 9054.80 8983.95 -714.31 -1128.69 0.00 5969436.28 642444.27 MWD 11175.00 89.40 122.24 9055.06 8984.21 -727.65 -1107.54 0.00 5969423.36 642465.66 MWD 11200.00 89.40 122.24 9055.33 8984.48 -740.98 -1086.40 0.00 5969410.43 642487.06 MWD 11225.00 89.40 122.24 9055.59 8984.74 -754.31 -1065.25 0.00 5969397.50 642508.45 MWD 11250.00 89.40 122.24 9055.85 8985.00 -767.65 -1044.11 0.00 5969384.58 642529.85 MWD 11275.00 89.40 122.24 9056.11 8985.26 -780.98 -1022.96 0,00 5969371.65 642551.24 MWD 11300.00 89.40 122.24 9056.37 8985.52 -794.32 -1001.82 0.00 5969358.72 642572.64 MWD 11325.00 89.40 122.24 9056.64 8985.79 -807.65 -980.67 0.00 5969345.80 642594.03 MWD 11350,00 89.40 122.24 9056.90 8986.05 -820,99 -959.53 0.00 5969332.87 642615.43 MWD 11375.00 89.40 122.24 9057.16 8986.31 -834.32 -938.38 0.00 5969319.94 642636.82 MWD 11400.00 89.40 122.24 9057.42 8986.57 -847.66 -917.24 0.00 5969307.02 642658.22 MWD 11425.00 89.40 122,24 9057.69 8986.84 -860.99 -896.09 0.00 5969294.09 642679.61 MWD 11440.00 89.40 122.24 9057.84 8986.99 -868.99 -883.40 0.00 5969286.33 642692.45 41/2" 11440.64 89.40 122.24 9057.85 8987.00 -869.34 -882.86 0.00 5969286.00 642693.00 J-23A T3 lPRRIE L HUBBLE Po B~~f9~~~ TlOIV A/( lIVe " A.NCHORA.GE lk M99B 7-5 lvIas'ercard Cheek ' 519-6612 89-6/1252 DArE First National Bank Alaska Anchorage, AI( 99501 MEMO e . °'5, ,,- '55£, £'22?'I! C¿252000GOC99¿,. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~4" 7- 234 PTD# ~-1C¡3 x Exploration Stratigraphic Development Service CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new wellboresegment of LATERAL existing weD . Permit No, API No. . (If API num ber Production. sbould continue to be reponed as last two. (2) digits a function· of tbe original API number, stated are between 6.0-69) above. PILOT HOLE In accordance witb . 2.0 AAC 25..0.05(1), an (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .' and API number (5.0 - 7.0/8.0) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION .. compliance witb 2.0 AAC 2S.055~ Approval to periorate and produce is contingeDt UpOD issuance of ~ conservation order approving a spacing e:J ception. (Company Name) assumes tbe liability of any prot est to tbe spacing .e:Jception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 3.0' sample intervals from below tbe permafrost or from wbere samples are first caugbt and 10' sample iIiter:vals tbrougb target zones. . . Well bore seg D Annular Disposal D PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY _UNIT J-23A _Program DEV ALASKA) INC Initial ClasslType DEV /1-0IL GeoArea 890 Unit 11650__ On/Off Shore On Administration P~(mit fee attaçhe~ - - - - - - - - - - - - - - - - · Y~s - - - - - - - - - 2 .Leas~-"Umberappropriate. . . . . . . . . . - - - - - - Y~s - - - - - - - - - - - - - 3 .U.niq!le weltn.arne.and Ollmb.er . . . . . . . . . _ . . . . _ . . . . . . . _....... Y~s - - - - - - - - - - - - - - - - - - - - . - -- 4 WeJUocat~d ina. d.efine~ pool - - - - - - - - - - - - .. Y~s - - - - - - - - - - - - - - - - - - - 5 WeJUocated proper .distance. from driJling !lnitb.o!lnd~lY. . . . Y~s - - - - - - - - - - - 6 We.ll JQcat~d pr.operdistance. from otbe.r welJs. . - - - - - Yes - - - - - - - - - - - - - - - 7 .S.uffiçient.açreage.ayailable indrilliOQ unjt. . . . . - - - - - .. Yes - - - - - - - - - - - - - - - - - - - 8 Jtdeviated, js weJlbore plaUncJu.ded . . . . . . . . . . . . . . . . . . · Yes - - - - - - - - 9 .Ope(ator onl}' affected party. . . . . . - - - - - Y~s - - - - - - - - - - - - - - - - - -- 10 .Oper.atof bas.appropriate.b.ond inJorce . . . . . . . . . . . . . . . . . ........ Y~s - - - - . ~ - - - - - - - - - - - - - - - - - - 11 P~(mit can be issued wjtbout co.nservation Qrder. . - - - - Yes - - - -- Appr Date 12 P~(mit c.an be issued witbout administ(atÍlle.approvaJ . . . . · Yes - - - - - - - - - - - - - - - - - - - - RPC 9/29/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUocat~d within area and strata authorized by Injectioo Ord~( # (put 10# in. comments). (ForNA - - - - - -- - - - - - - - 15 AJI welJs.withlnJl4.roite.area.of reyiew jd~otified (Fpr servjc.e.w.ell on I}'). . . . . . . . . . . . . . . .NA - - - - - - - - - - . - - - - - - - - - - - - - 16 Pre-produced injector; ~uration.of pre-pro~uGtioo I~ss than.:3 montbs. (For serYlce well onJy) . . NA - - - - - - - - - - - - - 17 ACMPFjndjngof Conslstencyhas been Jssued. fortbis proieçt . . . . .NA - - - - - - - - - - - - - - - Engineering 18 .Condu.ctor st(Îng.provided . . - - - - - - - - - - - - - - - · NA - - - - - - - - - - -- 19 .S.ur:fac~ .casing protects alLknown USDWs . . . .NA - - - - - - - - - - -- 20 .CMT. vol adequate. to çircuLate.onconduçtor. & su.rfC$g . - - - - - - - NA 21 .CMT v.oL adequ.ate. to tie-tn .long .string tos!Jr:f çs.g . . .NA - - - - - - - - - - - - - - - - - - - - 22 .CMTwill coyeraJl knownPfo.ductiye bori~on.s. . . . . . . . . . Yes 23 .C.asing de.si.gns ad.equa.te fo( C,.T, B.&.permafr.ost . . .Y~s - - - - - - - - - - 24 Adequate.tankage.or re.serye pit. . . - - - - - - - - - - Y~s . . . Nabors2ES, . . . . . . . . 25 Jf.a.re-~(ilL bas.a 10-403 for ~bandon.ment be~o approved. . ... Y~s * - - - - - - - - - - - - - - 26 A~equate.v.¡e[lbofe~eparatjon.proposed. . . . . _ _ . . . . . . . . . . . . ... Y~s - - - - - - - - - - . - - - - - - - - - - - - + 27 Jf.djverter required, does jt meet reguJatioos. . . . . . . . . . . . . . . . NA · . Sidet(açk.. . . . . Appr Date 28 .DriUioQ fJujdprograro sc.hematic& eq.uipJist.adequatß. . . . .. Yes . MaxMW8,5ppg. WGA 9/30/2004 29 .BOPEs,. do .they meet reguJation . - - - - - - - - - - .. Y~s - - - - - - - - - - - - - - -- 30 .BOPE.press ra.tiOQ approp(iate; .test to (pu.t PSig Ln .comments) .Y~s · . Test to 3500. psi.MSF' 2285 psi 31 .C.hoke. roanjfold çomplies w/API RF'-5:3 (May ß4). . - - - - - - - - - - .. Y~s - - - - - 32 Work will OCcU( withouLoperatjonsbutdown. . . . . . - - - - - - · .Y~s 33 .Is presence. of H2S gas. prob.able. - - - - - - - - - - - - - - - - - ... No · . NoLan H2S pad. 34 Meçba.nicaLcoodjtionpf wells wtthin ,ð"Oß yerified (for. service w~1J onJy) NA Geology 35 P~(mit can be issued w!o hyd(ogen s.ulfide O1eaS!J(es . · No 36 .D.ata preseoted on. potential overpressurezOl1e.s. . . .NA Appr Date 37 .SßÎ.smicanalysjs. of sbaJlow gas. zones. . . . .NA - - - - - - - 38 .S~abed .col1ditioo survey.(if off-shpre) . . . . . . . . - - - . .NA 39 . Conta.ct namelp!1onefor."",eeldy progress.reports [exploratpry .only] NA - - Geologic Date: Engineering Date Date Commissioner: Commissioner: /Ý~f' (JT.f '1/30/4- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplìfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dri~ng Services LIS Scan Utility . ;(r)£(- (C¡3 $Revision: 3 $ LisLib $Revision: 4 $ Thu Nov 18 14:53:18 2004 Ree~e~~~~:r name. . . . . . . . . . . . . LISTPE 4f. . f;).. q c{ 0 Date. . . . . . . . . . . . . . . . . . . . .04/11/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. ..... ........ ..UNKNOWN Continuation Number......01 Previous Reel Name...... . UNKNOWN Comments. ............... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name......... .......UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments... .... ........ ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA J-23A 500292171201 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 18-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003341819 J. BOBBITT R. BORDES / MWD RUN 2 MW0003341819 D. RICHARDSO R. BORDES / MWD RUN 3 MW0003341819 J. BOBBITT R. BORDES / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003341819 J. BOBBITT R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 11N 13E 1182 802 69.64 42.40 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 9066.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. J-23A WAS DRILLED FROM A WHIPSTOCK IN THE J-23 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 9066'MD/8453'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. SROP DATA ARE PRESENTED. 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND AT-BIT INCLINATION (ABI). MWD RUNS 3 & 4 ALSO INCLUDED STABILIZED LITHO-DENSITY (SLD) AND COMPENSATED THERMAL NEUTRON (CTN). UPHOLE MAD CTN AND SLD DATA ACQUIRED WHILE RIH FOR RUN 3 WERE MERGED WITH RUN 3 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED 8' UPHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 11 NOVEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL J-23A WITH API#: 50-029-21712-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 11406'MD/9045'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT . . BIN) . SLIDE = NON-ROTATED INTERVALS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 2800 - 4000 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name.... ....... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/18 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPX RPS RPM RPD NPHI FCNT NCNT PEF DRHO RHOB ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9027.0 9034.0 9034.0 9034.0 9034.0 9034.0 9058.0 9058.0 9058.0 9060.0 9060.0 9060.0 9070.0 STOP DEPTH 11346.5 11353.0 11353.0 11353.0 11353.0 11353.0 11309.5 11309.5 11309.5 11324.5 11324.5 11324.5 11398.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 9027.0 11398.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: GR 9035.0 11406.0 BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ # Data Format Specification Record MERGE TOP 9078.0 9092.0 9760.0 9980.0 MERGE BASE 9092.0 9760.0 9980.0 11406.0 . Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........ .... . Undefined Absent value......... ....... ... ...-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9027 11398 10212.5 4743 9027 11398 Rap MWD FT/H 0.07 426.2 117.736 4657 9070 11398 GR MWD API 12.98 539.88 43.4159 4640 9027 11346.5 RPX MWD OHMM 0.74 1578.67 12.6228 4639 9034 11353 RPS MWD OHMM 0.81 2000 19.2927 4639 9034 11353 RPM MWD OHMM 0.14 2000 21.5302 4639 9034 11353 RPD MWD OHMM 0.19 2000 24.3772 4639 9034 11353 FET MWD HOUR 0.16 25.05 2.10619 4639 9034 11353 NPHI MWD PU-S 8.8 44.59 21.1752 4504 9058 11309.5 FCNT MWD CNTS 196 .1 2013.8 784.591 4504 9058 11309.5 NCNT MWD CNTS 14311 44088 31186 4504 9058 11309.5 RHOB MWD G/CM 1.56 3.451 2.39775 4530 9060 11324.5 DRHO MWD G/CM -0.78 1.202 0.0721355 4530 9060 11324.5 PEF MWD BARN 1. 27 6.79 2.43477 4530 9060 11324.5 First Reading For Entire File.. ....... .9027 Last Reading For Entire File..... ..... .11398 File Trailer Service name........ .... .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/11/18 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name... ........STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..~11/18 Maximum Physical Record..65535 File Type................ La Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE Rap $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 9078.0 STOP DEPTH 9092.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. .......... ......0 Data Specification Block Type.. ...0 Logging Direction. . . . . . . . . . . . . . . . . Down 23-0CT-04 Insite 66.37 Memory 9092.0 9066.0 9092.0 .0 .0 TOOL NUMBER 6.125 6269.0 Flo-pro 8.40 82.0 8.8 2500 .0 .000 .000 .000 .000 .0 100.0 .0 .0 . . Optlcal log depth units........ ...Feet Data Reference Point... ......... ..Undefined Frame Spacing..................... 60 .1IN Max frames per record.. ......... ..Undefined Absent value.... ................ ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT Rap MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 9078 0.07 Mean 9085 5.19172 Max 9092 8.28 First Reading For Entire File......... .9078 Last Reading For Entire File... ....... .9092 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation...... .04/11/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.... ...04/11/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET Rap $ 3 Nsam 29 29 . First Reading 9078 9078 Last Reading 9092 9092 header data for each bit run in separate files. 2 .5000 START DEPTH 9035.0 9042.0 9042.0 9042.0 9042.0 9042.0 9092.5 STOP DEPTH 9702.5 9709.5 9709.5 9709.5 9709.5 9709.5 9760.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 24-0CT-04 . SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .......... .......0 Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units. ......... .Feet Data Reference Point... ........ ...Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ... . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O Insite 66.37 Memory 9760.0 9092.0 9760.0 . 9.7 53.8 TOOL NUMBER 156435 156404 6.125 6269.0 Flo-Pro 8.40 58.0 8.8 2800 9.8 1. 600 .972 1. 400 1. 200 69.0 118.0 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9035 9760 9397.5 1451 9035 9760 Rap MWD020 FT/H 1. 32 156.76 55.2349 1336 9092.5 9760 GR MWD020 API 12.98 539.88 45.95 1336 9035 9702.5 RPX MWD020 OHMM 0.74 1578.67 19.8415 1336 9042 9709.5 RPS MWD020 OHMM 0.81 2000 42.4748 1336 9042 9709.5 RPM MWD020 OHMM 0.14 2000 49.7191 1336 9042 9709.5 RPD MWD020 OHMM 0.19 2000 58.6707 1336 9042 9709.5 FET MWD020 HOUR 0.76 25.05 3.00904 1336 9042 9709.5 First Reading For Entire File...... ....9035 Last Reading For Entire File.......... .9760 File Trailer Service name. ........... .STSLIB.003 Service Sub Level Name. . . Version Number..... ..... .1.0.0 Date of Generation.... ...04/11/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name... ........STSLIB.004 Physical EOF File Header Service name....... ......STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.......04/11/18 Maximum Physical Record..65535 File Type........... .... .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT DRHO RHOB PEF GR RPM RPD FET RPX RPS Rap $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9066.0 9066.0 9066.0 9068.0 9068.0 9068.0 9703.0 9710.0 9710.0 9710.0 9710.0 9710.0 9760.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: STOP DEPTH 9894.0 9894.0 9894.0 9906.5 9906.5 9906.5 9928.0 9935.0 9935.0 9935.0 9935.0 9935.0 9980.0 25-0CT-04 Insite . DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN CaMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...... ... ......0 Data Specification Block Type.....O Logging Direction.. .......... .... . Down Optical log depth units.. ..... ....Feet Data Reference Point........ ......Undefined Frame Spacing..................... 60 .1IN Max frames per record.. ...........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 66.37 Memory 9980.0 9760.0 9980.0 62.4 92.5 TOOL NUMBER 156435 112439 100983 156404 6.125 6269.0 Flo-Pro 8.40 48.0 9.2 3100 8.0 .900 .530 1.500 1. 200 69.0 122.0 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 . . FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9066 9980 9523 1829 9066 9980 Rap MWD030 FT/H 0.88 217.55 62.2375 440 9760.5 9980 GR MWD030 API 17.63 139.48 43.9573 451 9703 9928 RPX MWD030 OHMM 3.8 16.51 8.60654 451 9710 9935 RPS MWD030 OHMM 4.7 15.57 8.61922 451 9710 9935 RPM MWD030 OHMM 5.37 14.86 8.80729 451 9710 9935 RPD MWD030 OHMM 6.09 15.09 9.16732 451 9710 9935 FET MWD030 HOUR 0.73 18.36 5.15333 451 9710 9935 NPHI MWD030 PU-S 8.8 44.59 20.8454 1657 9066 9894 FCNT MWD030 CNTS 196 .1 2013.8 823.831 1657 9066 9894 NCNT MWD030 CNTS 14311 44088 31131.1 1657 9066 9894 RHOB MWD030 G/CM 1. 56 3.451 2.35908 1678 9068 9906.5 DRHO MWD030 G/CM -0.78 1.202 0.0686341 1678 9068 9906.5 PEF MWD030 BARN 1.34 6.79 2.58068 1678 9068 9906.5 First Reading For Entire File... ...... .9066 Last Reading For Entire File...... .....9980 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.. ...... ...1.0.0 Date of Generation...... .04/11/18 Maximum Physical Record. .65535 File Type................ La Next File Name.......... .STSLIB.005 Physical EOF File Header Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation...... .04/11/18 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name.... ...STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB 5 header data for each bit run in separate files. 4 .5000 START DEPTH 9894.5 9894.5 9894.5 9907.0 9907.0 9907.0 STOP DEPTH 11317.5 11317.5 11317.5 11332.5 11332.5 11332.5 GR RPX RPS RPM RPD FET Rap $ . 9928.5 9935.5 9935.5 9935.5 9935.5 9935.5 9980.5 11354.5 11361.0 11361.0 11361. 0 11361.0 11361.0 11406.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN CaMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...... .....0 Data Specification Block Type.. ...0 Logging Direction...... ...........Down Optical log depth units...........Feet Data Reference Point... ..... ......Undefined Frame Spacing..... .......... ......60 .1IN Max frames per record.. ..... ......Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 . 27-0CT-04 Insite 66.37 Memory 11406.0 9980.0 11406.0 87.6 93.7 TOOL NUMBER 156435 112439 100983 156404 6.125 6269.0 Flo-pro 8.40 46.0 9.8 4000 8.0 .900 .455 1.500 1. 200 69.0 143.0 69.0 69.0 . . Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9894.5 11406 10650.3 3024 9894.5 11406 ROP MWD040 FT/H 7.25 426.2 156.721 2852 9980.5 11406 GR MWD040 API 18.84 303.54 42.1437 2853 9928.5 11354.5 RPX MWD040 OHMM 5.23 17.4 9.87632 2852 9935.5 11361 RPS MWD040 OHMM 6 17.23 10.121 2852 9935.5 11361 RPM MWD040 OHMM 6.05 16.81 10.3372 2852 9935.5 11361 RPD MWD040 OHMM 5.97 17.18 10.7178 2852 9935.5 11361 FET MWD040 HOUR 0.16 16.08 1.20139 2852 9935.5 11361 NPHI MWD040 PU-S 14.89 32.34 21.3672 2847 9894.5 11317.5 FCNT MWD040 CNTS 313.2 1176.1 761.753 2847 9894.5 11317.5 NCNT MWD040 CNTS 19241 37225 31217.9 2847 9894.5 11317.5 RHOB MWD040 G/CM 2.037 3.077 2.42051 2852 9907 11332.5 DRHO MWD040 G/CM -0.1 0.732 0.0741956 2852 9907 11332.5 PEF MWD040 BARN 1.27 5.42 2.34892 2852 9907 11332.5 First Reading For Entire File........ ..9894.5 Last Reading For Entire File.......... .11406 File Trailer Service name.... ...... ...STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/11/18 Maximum Physical Record. .65535 File Type......... .......LO Next File Name. ....... ...STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ............ ...UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/18 · . Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File