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194-097
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 04-22A Squeeze Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 194-097 50-029-21454-01-00 12460 Surface Intermediate Liner Scab Liner Liner 8696 2484 7669 4131 3366 873 11230 13-3/8" 9-5/8" 7" 4-1/2" 4-1/2" 8648 33 - 2517 31 - 7700 7553 - 11684 7394 - 10760 11587 - 12460 33 - 2494 31 - 5797 5712 - 8737 5618 - 8387 8735 - 8696 11175 2670 4760 7020 7500 7500 11230 5380 6870 8160 8430 8430 11195 - 12437 4-1/2" 12.6# 13Cr-80 8633 - 8698 Conductor 80 20" 34 - 114 34 - 114 1490 470 4-1/2" Baker S-3 Perm , 7325 , 5578 No SSSV 7325 , 10795 5578 , 8414 Bo York Operations Manager David Wages David.Wages@hilcorp.com (713) 380-9836 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 0028323 Squeeze Perforations 11086' to 11100' Pump 13.7 bbls 15.8 ppg Class G Cmt to 1500 psi 0 71 1554 1607 4368 2565 1666 0 225 240 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S-3 , 10795 , 8414 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 10748 - 10795 29 - 7456 8377 - 8418 29 - 5655 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.07.31 12:29:59 -08'00' RBDMS JSB 080323 WCB 3-8-2024 DSR-8/4/23 ACTIVITYDATE SUMMARY 6/4/2023 CTU #9 1.75" Coil Tubing - Job Scope = Cementing Travel to location, MIRU, BOP Test. Load well with 350 bbls crude. Spot salt plug. ***Job in Progress*** 6/4/2023 T/I/O = SSV/1250/150. Temp = SI. Bleed IAP (assist CTU). ALP = ## psi, SI @ CV. IA FL @ 7215' (sta#1 SO, 386 bbls). Bled IAP to production from 1250 psi to 550 psi in 2 hrs. No monitor. CTU in control of well upon departure. Final WHPs = SSV/550/150. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:00 6/4/2023 T/I/O= 0/532/84 TFS unit 4 Assist Coil Pumped 1 BBL of 50/50 folowed by 700 BBLS Crude down TBG, continue job on 6/05/23 6/5/2023 CTU #9 1.75" Coil Tubing - Job Scope = Cementing Load well with 350 bbls crude. Spot salt plug. Chase salt plug with 115 bbls crude. Wait for salt plug to settle 5 hrs. Tag @ 11,095' CTMD. Unable to establish circulation down coil. POOH. At surface, tools packed off with salt. RBIH. Jet to top of salt plug. Perform injectivity test - no injectivity. Jet across sqz interval. Perform 2nd injectivity test - no injectivity. Jet across sqz interval w/ KCL to 11105' CTMD. Perform injectivity test - WH on a vac at 1.5 bpm down coil - good injectivity in perfs from 11086' - 11100'. All other perfs isolated with salt plug. ***Job in Progress*** 6/5/2023 ***JOB CONTINUED FROM 06/04/23**** Pumped 117 BBLS Crude, To place Salt Pill on Perfs. CTU in control of well upon depareture FWHP=0/520/60 6/6/2023 CTU #9 1.75" Coil Tubing - Job Scope = Cementing Bullhead well w/ 145 bbls DSL. Establish injection WHP of ~300 psi @ 1.5 bpm w/ DSL in well. Pump 13.7 bbls 15.8 ppg Class G Cement, Pushed 1.4bbls into perf interval 11,086-11100 w/1800psi squeeze pressure for 40 min. RIH jetting to 11224. Make multiple passes across lower perf interval @ 3 bpm. POOH while chasing bottoms up. Perform injectivity test .1bpm injectivity. F/P well RDMO. ***Job Complete*** 6/8/2023 **INJECTIVITY TEST** Pumped 9 bbls crude down the TBG at .10 BPM at 1500 PSI. Was unable to establish any constant rate. Pumped 7 bbls crude down the flowline to establish communication per DSO. 6/10/2023 T/I/O = 230/1260/80. Temp = 120°. T & IA FL (OPS request). ALP = online. T FL @ 7215' (sta # 1, SO, 110 bbls). IA FL @ 7215' (sta # 1, SO, 386 bbls). SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:00 6/13/2023 T/I/O = 1900/1840/0. Temp = SI. TBG FL (OP's request). AL SI @ CV = 1880 psi. TBG FL @ 7433' (218' below sta#1 SO). SV, WV, SSV = C. MV = O. IA & OA = OTG. 16:30. 6/14/2023 ***WELL S/I ON ARRIVAL*** TRAVEL & RIG UP POLLARD 59 ***CONTINUE 6/15/23*** Daily Report of Well Operations PBU 04-22A g Spot salt plug. Chase salt plug with 115 bbls crude.gg Wait for salt plug to settle 5 hrs. Tag @ 11,095' CTMD. Unable to establishgg@ circulation down coil. POOH. At surface, tools packed off with salt. RBIH. Jet to top of salt plug. Perform injectivity test - no injectivity. Jet across sqz interval. Performgjyjy 2nd injectivity test - no injectivity. Jet across sqz interval w/ KCL to 11105' CTMD.jy jy Perform injectivity test - WH on a vac at 1.5 bpm down coil - good injectivity in perfsjy from 11086' - 11100'. All other perfs isolated with salt plug. gg Travel to location, MIRU, BOP Test. Load well with 350 bbls crude Perform injectivity test .1bpm injectivity. gg Bullhead well w/ 145 bbls DSL. Establish injection WHP of ~300 psi @ 1.5 bpm w/j@ DSL in well. Pump 13.7 bbls 15.8 ppg Class G Cement, Pushed 1.4bbls into perfg interval 11,086-11100 w/1800psi squeeze pressure for 40 min. RIH jetting to 11224.jg Make multiple passes across lower perf interval @ 3 bpm. POOH while chasing@ bottoms up. Daily Report of Well Operations PBU 04-22A 6/15/2023 ***CONTINUE FROM 6/14/23*** RAN 3.25" CENTRALIZER, 2 1/2" SAMPLE BAILER TO 11,074' SLM, STICKING, MARKS ON BAILER, POSSIBLY BINDING UP TRYING TO GET INTO TUBING TAIL ***RIG DOWN FOR STATE WITNESSED JOB ON DS4-350, JOB INCOMPLETE, WELL LEFT S/I*** 6/15/2023 ***RETURN AFTER STATE WITNESS TAG ON DS4-350*** DRIFT W/ 20' x 2 7/8" DMY GUNS (3.16" swell rings), SD @ 11,076' SLM DRIFT W/ 20' X 2 1/2" DUMMY GUNS (2.77" swell rings) S/D @ 11,076' SLM DRIFT W/ KJ, 2' STEM, 2.80" SWEDGE, 1 3/4" SAMPLE BAILER S/D @ 11,077' SLM (recovered 2 cups formation sand) RUN 4 1/2" TEL LOCATE END OF TUBING @ 10,782' SLM ***CONTINUE 6/16/23*** 6/16/2023 ***CONTINUE FROM 6/15/23*** RIG DOWN POLLARD 59 ***WELL LEFT S/I*** 6/30/2023 CTU 9, 1.75" 0.156" Job Scope: Drift/Log. RePerforate Travel to location, MIRU. MU HES Mem logging 2.9" carrier w/ 3.5" JSN. RIH. Tagged high at 11080'. Attempted to jet restriction at various rates with no change. Log from compression, paint flag at 11,000' top of log 10,000. POOH +2' correction. Make up YJ 2-7/8" motor to 3.5" Mill. RIH ***Continued to WSR on 7/1/23*** 7/1/2023 CTU 9, 1.75" 0.156" Job Scope: Drift/Log. RePerforate Continue to RIH with YJ 2-7/8" milling BHA 3.5" mill. Correct depth at flag, RIH tag restriction at 11088. Easy milling at start and then slow after 11170. Clean out down to 11230 corrected depth. pump gel sweep off bottom and chase OOH. Clean up top of tubing stump. POOH. BD YJ Tools. Cut CT. Change Pack-offs. MU YJ MHA two 2" MBT w/ 3.5" JSN. RIH. Corr Depth @ White Flag. RIH tag @ 11,186'. try jet thru just stack down and CTP increases. POOH. ***Job in progress*** 7/2/2023 CTU 9, 1.75" 0.156" Job Scope: Drift/Log. RePerforate Finish cleaning up between 11160-11230. Make multiple passes across tight areas with 3.68" DSM. chase 10bbls gel pill from bottom to surface. L/D YJ Milling BHA and M/U HES logging BHA. RIH. Tag HEX Plug @ 11,237' CTM. PUH pump to roll hole to Diesel. RIH Tag HEX Plug again. Log Up to 11,000.62' CTM, paint Flag. Log Up to 7150' CTM. POOH. BD HES logging tools (-5' corr). PT MHA. MU 20' HES 3.125" perf guns. RIH to Flag. Corr Depth to Top Shot. RIH and PUH to Top Shot. Perf 11,195' - 11,215'. POOH. L/D spent 3-1/8" perf guns, and Y/J MHA, 5/8" ball recovered. RDMO ***Job Complete*** REPERF & SQZ (07/02/23) REPERF & SQZ (07/02/23)REPERF & SQZ (07/02/23) Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 02/27/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230227 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 233-23 50283201360100 222050 1/20/2023 AK E-LINE Perf END 2-06 50029216990000 187018 1/23/2023 AK E-LINE Perf PBU 04-22A 50029214540100 194097 1/10/2023 AK E-LINE PPROF PBU 11-39 50029235180000 214099 2/8/2023 READ MultipleArrayProductionProfile SRU 23-33 50133101630000 161019 1/3/2023 AK E-LINE Plug_Cement_Jet Cut TBF A-01RD 50733100550100 190147 1/24/2023 AK E-LINE Tubing Punch Please include current contact information if different from above. PBU 04-22A 50029214540100 194097 1/10/2023 AK E-LINE PPROF STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed UEC Z .! 2M Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Cham p0'Q �f: 11Plug for Redrill El Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: �Vj�..1 �;j ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number: 194-097 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 1 6. API Number: 50-029-21454-01-00 7 Property Designation (Lease Number): ADL 028324 & 028323 8. Well Name and Number: PBU 04-22A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 12460 feet Plugs measured 11230 feet true vertical 6696 feet Junk measured 11175 feet Effective Depth: measured 11230 feet Packer measured 7325, 10795 feet true vertical 8647 feet Packer true vertical 5578, 8414 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 2484 13-3/8" 33-2517 33-2494 5380 2670 Intermediate 7669 9-5/8" 31-7700 31-5797 6870 4760 Liner 4131 7" 7553-11684 5712-8737 8160 7020 Liner 873 4-1/2" 11587-12460 8734-8695 8430 7500 Perforation Depth: Measured depth: 11195 -12437 feet True vertical depth: 8633-8698 feet 4-1/2" 12.6# x 726# x Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.8#, 13Cr80 / L-80 29-10799 29-8417 4-1/2" Baker S-3 Perm Packer 7325 5578 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 10795 8414 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11086 - 11230 Treatment descriptions including volumes used and final pressure: Lay in Powervis from top of HEX to bottom pert. Pump 50 bbls of 15.8 ppg Class G cement and then cut cement as well was squeezing off rapidly. Lay in 33 boils of cement and achieve squeeze to 2300 psi with a total of B.8 boils behind pipe. Standby for cement to reach compressive strength. Pressure Test Squeeze to 1000 psi - Good Test. Final Pressures: OA = 8 psi, IA = 1005 psi, TBG = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In 1640 0 Subsequentto operation: Shut -In 1005 0 14. Attachments: (required per 20 enc 25 070.25.071, s 25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 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: WA Authorized Name: Lastufka, Joseph N Contact Name: Lastufka, Joseph N Authorized Title: peciali t Contact Email: Joseph. Lastufka@bp.com Authorized Signature: Date :'Z.` 1- 1 Contact Phone: +1 907 564 4091 Form 10-404 Revised 04/2017 pf_/ / MZk-2:'?t0:49 RBDMS' DEC 2 4 2019 Submit Original Only Daily Report of Well Operations PBU 04-22A ACTIVITVr1ATF tl IMMAOV CTU#9 1.75" CT. Job Scope: Cement Sqz / Adperf MIRU CTU. Pump 1.188" Drift Ball. Perform Weekly BOP Test. Wait on Cement Lab Tests to be completed. 12/2/2019 ***In Progress' CTU#9 1.75" CT. Job Scope: Cement Sqz / Adperf RIH w/ 2.50" BDJSN Cement BHA. Tag HEX plug at 11230'. Load well with 1% KCI and underbalance with diesel. Lay in Powervis from top of HEX to bottom perf. Pump 50 bbls of 15.8 ppg Class G cement and then cut cement as well was squeezing off rapidl . Lay in 33 bbls of cement Nd achieve squeeze to 2300 psi with a total of 8.8 bbls behind pipe. Contaminate cement back down to HEX at 11230' and leave clean powervis from 11230' to 11000'. Chase contaminated cement OOH at 80%. FP well and standby for cement to reach compressive strength. 12/3/2019 ***In Progress' CTU#9 1.75" CT. Job Scope: Cement Sqz / Adperf Makeup 2-7/8" GR/CCL Logging Carrier with 3.50" DJN and RIH. Pressure Test Squeeze to 1000 psi - Good Test. RIH and Tag high at 11080' (Cement). Unable to jet through. Log from compression to 10300'. Flagged pipe at 10950'. Received good data (+4' Correction). Correlated to Sib 27 -Jan -2018 Plug Setting Record - which is the Reference Log. MU & RIH with Baker 2-7/8" Milling BHA w/ 3.63" DSM. 12/4/2019 ***In Progress*** CTU#9 1.75" CT. Job Scope: Cement Sqz / Adperf Continue Rih w/ Milling BHA. Correct depth at Flag to the bottom of the mill. Tag cement obstruction at 11090'. Mill thru easily. Tag HEX Plug at 11233' down. Weight back at 11227.2'. Corrected Top of HEX Plug= 11227.2'e. Pump 17 bbl gel pill & chase ooh. Lay in Meth freeze protect from 2500'. Break down tools. Trim 100' of pipe & re -head. RIH with SLB 2.88" PJO 20' gun and perforate 11195-11215'. Perfs shot using reference log as per APE. FP well with 38bbl of 60/40. RDMO 12/5/2019 ***Complete*** TRff= FMC WELLHEAD= FMC ACTUATOR= BAKERC OKB. ELEV = 60' 3F. ELEV = 3776 3509 7215 5512 (OP= 7100' ao a liboo 20" CONDUCTOR, 114' 91.5#, H-40, )= 8800' SS D= 19.124" I/8' CSG, 72#, L-80 BTC, D =12.347^ 2521' P 2 JOINTS = 660, KS5, ID =12.415-) Minimum ID =2.377" @ 74180' 2-7/8" COLLAR w/PIN 4-112" 7BG, 12.6#, 13CR-BO VAMTOP, 7456' .0152 bpf, D= 3.958" TOP OF 4-12' SCAB LNR 7394' 9-5/8' X 7" Slut -6 -AT LTP w / LNR HGP ID = 6.208" 7653' TOC(08/04/94) 7697 9-5/8" CSG. 47#. L-80 BTC ID = 8 681" 7" LNR, 29#, NT -80 XO TO 13CR-80 NSCC, .0371 bpf, D=6.1114' 4-12" SCAB LNR, 12.6#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958" 4-12' TBG STUB (0628/09) .0152 bpf, D = 3.958" A SAFETY NOTES: WELL ANGLE> 70^ @ 11291-- CHROME TBG & LINERS ""' OWG WELBORE NOT SHOWN BELOW CMT IN 9-518" CSG'" TTT7 1982' H4-12'FES X NP, ID=3.813' GAS LFT MANDRELS ISTI MD ITVDIDEVI 7394' 11230' IMERW9-L 363-700 HIX PLUG (0127/18) 4-12" X 7- WHIPSTOCK (11/09/10) 9-5/8" X 7" G2 ZXP LTP PORT DATE 2 1 3776 3509 7215 5512 51 54 MMG MMG DN1Y DMY RK RK 0 0 07/22/18 07/22118 FES X 9-518" X 4-12' BKR S3 PKP D = 3.875' I 14b6' 4-1/2'WLEG, D=4.00" 7394' 11230' IMERW9-L 363-700 HIX PLUG (0127/18) 4-12" X 7- WHIPSTOCK (11/09/10) 9-5/8" X 7" G2 ZXP LTP 7 7 w / BKR HMC LNR HGR, D = 6.20" 0126186 7602' 7' X 4-12" XO, D = 3.93" 7" IuLLOUT WIDOW (04-22AL1) 11278' - 11286' 9-518° MLLOl1T V1TApW (04-22A) 7700' - 7750' 4-11Z 7-X 4-12' BKR S-3 R(R, D= 3.875" FISFL 71' OF TBG TAIL FELL TO HEX PLUG. TOP T OF FISH IS BOT OF S-3 PKR w /5.20" D. REST OF FISH IS 4-1/2" TBG w /FES X NP, ID = 3.813" (08/04/18) I2-7/8' JET CUT LNR(12/20/17) 11266' DATE 11230' IMERW9-L 363-700 HIX PLUG (0127/18) 4-12" X 7- WHIPSTOCK (11/09/10) 11274' 7 7 KFM/JMD SET HEX PLUG (0127118) 0126186 WW1 ORIGINAL COMPLETION I I I I \ 7" IuLLOUT WIDOW (04-22AL1) 11278' - 11286' 7"X 4-1/2"TTN SS PKR & HA NIGER, ID 11687' 08/02/18 GJB/JMD DROPPED TALPPE(07)23/18) 07M4199 014 RWO 08/06/18 14180' 2-718' COLLAR 7" LNR, 29#, 13CR-80 NSCC, 11684' I I w /PIN, D = 2.377' .0371 bpf. ID = 6.184" JDM/JMD PULLED LNR(01/04/18) I I 13080' 4-12" LNR, 12.6#, L-80 NSCT 12460' D 14192'.0152 70058b bpf, D = 3.958" 2-710" LNR, 6.4# 13 -CR STL2.441" 14199' DATE REV BY COMMENTS DATE REV BY COMMENTS 1210218& ROW 35 PARTIAL COMPLETION 0129/18 KFM/JMD SET HEX PLUG (0127118) 0126186 WW1 ORIGINAL COMPLETION 0726/18 ZV/JMD GLV C/O (07/22/18) 0826194 N28E SIDETRACK (04-22A) 08/02/18 GJB/JMD DROPPED TALPPE(07)23/18) 07M4199 014 RWO 08/06/18 CJN/JMD EDITS TO DROPPED TALPPE 1123H0 NORDIC CTO SIDETRACK (04-22AL7) 12/09/19 JTC/JMD ADPERFS&SOZ(I2 bf19) 01105/18 JDM/JMD PULLED LNR(01/04/18) PRUDHOE BAY UNIT WELL: 04-22A/AL1 PERMIT No: 1940970 / 2101540 API No: 50-029-21454-01 (60) Ti t N, RI 5E, 1089' FSL & 217' FWL BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: MEM LEE CCU GR/ TNF/ TNN ON 11/1 E ANGLE AT TOP PERF: N/A Note: Refer to Production DB Tor historical erfdat SIZE SPF INTERVAL Opn/Sgz DA - 0126/86 WWI ORIGINAL COMPLETION 0726/18 04 -22A 082694 N28E SIDETRACK (04-22A) 08/02/18 2-12" 6 11086-11100 CJN/JMD EDITS TO DROPPED TAILPPE 12/0' 2-7/8' 6 11195-11215 O 12/0: 2-7/8' 6 11300-11575 C 11/1 f 4-12' 32 11676-11914 C 082E 4-12" 32 11953-12032 C 082E 4-12" 32 12070-12110 C 082( 4-12" 32 12120-12437 C 082E 04-22AL1 2' 6 11394-11424 C 06/1E 2' 6 11948-12148 C 1121 2" 6 12275-12305 C 0611E 2" 6 12328-12418 C 1121 2' 6 12508-12718 C 1121 2" 6 12868-13098 C 1121 1.56" 6 13280-13310 C 06/18 1.56" 6 13722 -13822 C 06/17 2" 6 14053-14191 C 1121 DATE REV BY COMMENTS DATE REV BY COMMENTS 12)02185 ROW 35 PARTIAL COMPLETION 0129/16 KFM/JMD SET HEX PLUG (01,27118) 0126/86 WWI ORIGINAL COMPLETION 0726/18 ZV/JMD GLV C/O (0722/18) 082694 N28E SIDETRACK (04-22A) 08/02/18 GJB/JMD DROPPED TALPIPE(0723/18) 07)04109 D14 RWO 08/06/18 CJN/JMD EDITS TO DROPPED TAILPPE 1123110 NORDIC I CTD SIDETRACK(04-22AL1) 12/09/19 JTC/JMD ADPERFS B SOZ(12/05/19) 01)05118 JDM/JMD PULLED LNR(01/04/18) PRUDHOE BAY UNrr WELL 04-22A/ALI PERMITNo: 1940970/2101540 API No: 50-029-21454-01 (60) SEC 26, T71 N. R75E. 1069' FSL 8 217' F1N BP Exploration (Alaska) tECEIVED STATE OF ALASKA • SKA OIL AND GAS CONSERVATION COMMIS EPORT OF SUNDRY WELL OPERATIO FEB 2 0 2018 1. Operations Performed Abandon ❑ Plug Perforations IRI Fracture Stimulate 0 Pull Tubing 0 Operations rrrgP�7% Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approvea� Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: HEX Plug RI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 194-097 3. Address: P.O.Box 196612 Anchorage, Development Ir Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21454-01-00 7. Property Designation(Lease Number): ADL 028323 8. Well Name and Number: PBU 04-22A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12460 feet Plugs measured 11230 feet true vertical 8696 feet Junk measured None feet Effective Depth: measured 11230 feet Packer measured 7324 feet true vertical 8647 feet Packer true vertical 5577 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 34-114 34-114 1490 470 Surface 2484 13-3/8" 33-2517 33-2494 3450/4930 1950/2670 Intermediate 7669 9-5/8" 31-7700 31-5797 6870 4760 Liner 4131 7" 7553-11684 5712-8737 8160 7020 Scab Liner 3475 4-1/2" 7394-10865 5618-8465 8430 7500 Liner 873 4-1/2" 11587-12460 8734-8696 8430 7500 Perforation Depth: Measured depth: 11086-12437 feet True vertical depth: 8587-8698 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 29-7454 29-5654 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Packer 7324 5577 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNEU k ;i 1 4 F ,)016: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 93 602 4341 1515 872 Subsequent to operation: 245 15360 6815 1374 389 14.Attachments:(required per 20 AAC 25.07025.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory 0 Development Il Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil II Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-391 Authorized Name: Lastufka,Joseph N Contact Name: Thompson,Ryan Authorized Title: IM Specialist Contact Email: RYAN.THOMPSONabp.com Authorized Signature: Date: 2101 a Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 1/71L 3/11;4, E f.:;E"`- L V �r , - n, /� - _,J F�- , _J18 Submit Original Only • • Daily Report of Well Operations 04-22A ACTIVITYDATE SUMMARY (SLB ELINE JET CUT) INITIAL T/I/O = 2400/1250/200. MIRU, LPT/HPT = PASS. RIH W/ HEAD(FN=1-3/8")/ERS(FN=1-11/16")/EQF-43(2.5" GEMCO)/EQF-43/EQF-43(2.5" GEMCO)/UPCT/WPSA/SHOCK MANDREL (2.5" GEMCO)/SHOCK MANDREL/TOP SUB/2.125" CUTTER. DRIFT DOWN TO 11,321'. TIE-IN USING SLB MEMORY CEMENT BOND EVALUATION LOG DATED 23-JAN- 2016. JET CUT 2-7/8" LINER AT 11256'. GOOD INDICATION OF SHOT. POOH, RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 2450/1275/200. 12/20/2017 ***JOB COMPLETE*** T/I/0=2500/1300/100 Temp=S/I Load TBG/IA(Pre Wellwork Platform)AL shut in at lateral/casing valve. Spotted unit and all support equip, bled AL pressure to 100 psi. Did 12/21/2017 not pump any fluids. ***Continued on 12-22-17 WSR*** (Pre Wellwork Platform) AL shut in @ pit valve, AL casing valve pressure locked. Pumped 2 bbls 60/40 and 328 bbls of 120* inhibited 1% kcl down IA to load. Pumped 2 bbl 60/40 spacer and 135 bbls 24**diesel down IA for freeze protect. Spear in to TBG with 2 bbls of 60/40 followed by 204 bbls of Inhibited 1% KCL. F-protect TBG with 40 bbls of 25* diesel. Bleed AL line psi down & monitor. AL lateral still leaking by, IA casing valve holding, Wing shut swab shut ssv shut master open casing valves open to gauges Final 12/22/2017 Whp's=vac/1026/96 T/I/0=2500/600/50 Set 4" CIW "H" TWC#440 pre-WWP FWP's TWC/600/50 see log for 12/24/2017 details. T/I/O = TWC/1030/70. Temp = SI. Bleed IAP to 0 psi (pre CTU). ALP = 1060 psi, SI © CV. IA FL @ 2710' (145 bbls). Currently bleeding IAP to flowback tank. 12/27/2017 Cont on WSR 12/28/17. CTU#9 2.0" CT. Job Scope: Fish Liner(Klondike Job) Perform Pipe Swap to 2.0" Coil. 12/27/2017 ***Continue on 12/28/17 WSR*** CTU#9 2.0" CT. Job Scope: Fish Liner(Klondike Job) Continue Pipe Swap. Depart to 04-22. MIRU CTU. Rig up hardline & hook up to BOP's. 12/28/2017 ***In Progress*** Cont from WSR 12/27/17. Bleed IAP to 0 psi (pre CTU). IA FL @ 2710' (145 bbls). Bled IAP to flowback tank from 1030 psi to 50 psi in 5 hrs 30 min. No monitor. Final WHPs = TWC/50/70. 12/28/2017 CT in control of valves upon departure. CTU#9 2.0" CT Job Scope: Fish Liner(Klondike Job) Continue rig up CTU. Pump 1.375" Drift Ball. Begin BOP Test without AOGCC Inspector. 12/29/2017 ***Job Continued on 12/30/17*** CTU#9 2.0" CT ***Continued from 12/2817*** Job Scope: Fish Liner(Klondike Job) Continue rig up. Pump 1.375" drift ball. Begin drawdown test. 12/29/2017 ***In Progress*** CTU#9 2.0" CT Job Scope: Fish Liner(Klondike Job) Continue rig up CTU. Pump 1.375" Drift Ball. Begin BOP Test without AOGCC Inspector. 12/29/2017 S • Daily Report of Well Operations 04-22A CTU#9 2.0" CT Job Scope: Fish Liner(Klondike Job) Complete Preliminary BOP Testing. Call out AOGCC Inspector. Begin Testing BOP's with AOGCC Inspector(Guy Cook). AOGCC wants a low pressure test between 250psi - 350psi and a high above 3500psi. AOGCC Inspector has no pressure loss criteria other than the test chart must show a perfect flat line for 5 mins. 12/30/2017 ***Job in Progress*** CTU#9 2.0" CT Job Scope: Fish Liner(Klondike Job) Continue state witnessed BOP test. Complete repairs and re-test. Standby for inspector. 12/31/2017 ***Job Continued on 1/1/18*** CTU#9 2.0" CT Job Scope: Fish Liner (Klondike Job) Standby for state inspector. State Inspector on location at 4:45am. Resume BOP Test. Complete AOGCC Witnessed BOP Test. Winds too high to use crane to pull TWC. Make up safety joint. Begin weather standby. 1/1/2018 ***Job Continued on 1/2/18*** CTU#9 2.0" CT. Job Scope: Fish Liner (Klondike Job) Winds below 30mph. Have valve crew Pull TWC. Perform D1 Tripping Drills. 1/2/2018 ***In Progress*** T/I/O=TWC/0/0. Klondike Decompletion. Pulled 4" CIW TWC#440 at 145"with 11" of 1/2/2018 tooling through tree. ***Job Complete***See log for details. Final WHP's 2500/0/0. CTU#9 2.0" CT. Job Scope: Fish Liner (Klondike Job) Make up fishing BHA, with lockable swivel. Bullhead 280 bbls 1% Slick KCL w/Safelube. Weight check above TOL = 35k. Tagged TOL down at 10677' ctm. Latched liner and pulled free off bottom without jarring. Now weighing —6k heavier. Pooh with Liner. Park at 50' and perform well kill. Bullhead backside & Coil/Liner fish. Establish overbalance method. Well is on a vac, decision to utilize continuous hole fill method used. Deployment sleeve, 3.5" pup joint, 17 joints of 3.5" LNR, and 1 partial joint of 2.875" LNR recovered. Well freeze protected with 38bbI of 60/40. 1/3/2018 ***Job Continued on 1/4/18*** Bleed Flowline &ALP (Coil call-in). Bled Flowline from 200 psi to 0 psi in <5 mins (fluid). Bled AL from CV to manifold building to 50 psi. 1/3/2018 Coil in control of valve positions upon departure. 11:00 CTU#9 2.0" CT. Job Scope: Fish Liner(Klondike Job) Blow down reel with N2. RDMO. Swap pipe back to 1.75" 1/4/2018 ***Job Continued*** CTU#9 2.0" CT. Job Scope: Fish Liner(Klondike Job) Swap pipe back to 1.75" 1/5/2018 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (Profile Mod) RIG UP HES SLICKLINE UNIT 046 1/22/2018 ***CONT. ON 01/23/2018 WSR*** ***CONT. FROM 01/22/2018 WSR*** (Profile Mod) DRIFT FREELY TO 11,229' SLM @ 150 FPM W/35' x 3.70" DRIFT 1/23/2018 ***WELL LEFT S/I, READY FOR E-LINE (set plug)*** ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE HEX PLUG) INITIAL T/I/O = 2350/50/50 RIH W/ INTERWELL 363-700 HEX PLUG. OAL= 24', OAW = 430 LBS, MAX OD = 1/26/2018 3.63". • • Daily Report of Well Operations 04-22A ***JOB CONTINUED FROM 26-JAN-2018*** (SLB E-LINE HEX PLUG) CONTINUE RIH W/ INTERWELL 363-700 HEX PLUG. OAL = 28', OAW = 435 LBS, MAX OD = 3.63". SET HEX PLUG AT 11235' MID-ELEMENT. TIED INTO SLB MEMORY DEPTH CORRELATION DATED 07-NOV-2018 WELL S/I DEPARTURE. FINAL T/I/O = 2450/50/50 1/27/2018 ***JOB COMPLETE 27-JAN-2018*** I Fitt= FMC VVELLFI AD= FMC 04-22A CH OTES: WELL TBG&LIPS ANGLEORIG WELBORE NOT ACTUATOR= BAKER AL1 SHOWN BELOW CMT IN 9-5/8"CSG*** Of<8.ELEV= 60' ' I BF.ELEV KOP_ —— — 21.00 Max Angle=ui98°@ 13685' 20"CONDUCTOR, H 114' I I 1982' H4-1/2"HES X NP,D=3.813" -------- ----- Datum MD= N4 91.5#,H-40, Datum TVD= �=19.124" ' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2521' 2 3776 3509 51 MMG DOME RK 16 01/23/16 (TOP 2 JOINTS=6811,K=55,ID=12.415") L 1 7215 5512'54 v?4G SO RK 20 01/23/16 ' , 7296' HI 4-1/2"HES X NIP,D=3.813" Minimum ID =2.377" @ 14180' 2-7/8" COLLAR w/PIN g X 7325' H9-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" 7360' H4-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —+ 7456' .0152 bpf,D=3-958" 7456' —I4-1/2" LEG, =4-00" TOP OF 4-1/2"SCAB LNR H 7394' \� WD L 7394' —9-5/8"X 7"C-2 ZXP LTP T w/BKR HMC LNR HGR,D=6.20" 9-5/8"X 7"SM-6-AT LTP w/LNR HGR,D=6-208" H 7553' _ /— \ 7502' —17-X 4-112"XO,D=3.93" TOG(08/04/94) —{ 7697' ------- 9-5/8"MILLOUT WINDOW (04-22A)7700'-7750' 9-58"CSG,47#,L-80 BTC,D=8.681" —I —7700 7"LNR,29#,NT-80 XO TO 13CR-80 NSC C, H 10674' —X X .0371 bpf,U=6.184" 4-1/2"SCAB LNR,12.6#,13CR-80 H 10745' VAM TOP,.0152 bpf,D=3.958" /f 1' 10760' H 7"X 4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(06/28/09) —) —10748 // 10795' H7"X 4-1/2"BKR S-3 PKR,U=3.875" ' ' 10857' —14-1/2"HES X NIP,D=3.813" 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,U=3.958" H 10869' / • 10869' H4-1/2"WLEG,U=3.958" ❑ 10862' —I ELMD TT LOGGED??/??/?? 2-78"JET CUT LNR(12/20/17) —1 11256' ` 11230' —I AYTERV1+13L 363-700 HEX PLUG(01/27/18) 4-1/2"X 7" WHIPSTOCK(11/09/10) --j 11274' lilt 7"MFLOUT WQNDOW (04-22AL1)11278'-11286' 7"X 4-1/2"TNV SS PKR&HANGER,D=?" H 11587' 1 rt. 14180' —2-7/8"COLLAR 7"LNR,29#,13CR-80 NSC C, --1 11684' A / w/FIN,D=2.377" .0371 bpf. D=6-184" ` ,i TIGHT SPOT 13080° 4-1/2"LNR 12.6#,L-80 NSCT, —I 12460' PBTD —{ 14192' q-, .0152 bpf,D=3.958" 2-7/8"LNR,6.4#,13-CR STL,.0058 bpf,D=2.441" 14199' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/02/85 ROW 35 PARTIAL COMPLETION 01/27/16 JMMVJMD GLV C/O&SET XX PLUG(1/23/1 WELL: 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION 10/20/16 ZV/JMD FILLED XX PLUG(10/17/16) PEfWIT Nb: 1940970/2101540 08/26/94 N28E SIDETRACK(04-22A) 11/02/16 ZV/JND ADPE FS(10/27/16) API No: 50-029-21454-01 (60) 07/04/09 D14 RWO 12/21/17 MS/JMD JET CUT LNR(12/20/17) SEC 26,T11 N,R15E,1089'FSL&217'FVVL 11/23/10 NORDIC 1 CTD SIDETRACK(04-22A L1) 01/05/18 JDM/JMD FULLED LNR(01/04/18) 07/09/15 BLS/JMD ADFERFS(06/17-19/15) 01/29/18 KFM/J1VD SET I-EX PLUG(01/27/18) BP Exploration(Alaska) • 04-22A !R AL1 I I 1 1 L 1 1 x g 1 1 '� L. PERFORATION SUMMARY REF LOG:NEM I FF CCU GR/TNF/TNN ON 11/19/10 ANGLE AT TOP PEW:N'A Note:Refer to R-oduction DB for historical per(data I Ils. SIZE SFF NTERVAL Opn/Sgz DATE 04-22A 2-1/2" 6 11086-11100 0 10/27/16 2-7/8" 6 11300-11575 C 11/18/10 4-1/2" 32 11676-11914 C 08/26/94 1 4-1/2" 32 11953-12032 C 08/26/94 4-1/2" 32 12070-12110 C 08/26/94 ` 4-1/2" 32 12120-12437 C 08/26/94 04-22AL1 2" 6 11394-11424 C 06/19/15 2" 6 11948-12148 C 11/21/10 2" 6 12275-12305 C 06/18/15 2" 6 12328-12418 C 11/21/10 1111111` 2" 6 12508-12718 C 11/21/10 2" 6 12868-13098 C 11/21/10 1.56" 6 13280-13310 C 06/18/15 1.56" 6 13722-13822 C 06/17/15 1 r `` 2" 6 14053-14191 C 11/21/10 ' ' • I , I JJI ` 1 ice. DATE REV BY C OMENTS DATE REV BY COMVHVTS PR DHOE BAY MT 12/02/85 ROW 35 PARTIAL COMPLETION 01/27/16 JMMJM) GLV C/O&SET XX PLUG(1/23/1 1NE-L: 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION 10/20/16 ZV/JMD FtLLE D XX PLUG(10/17/16) }TRW No: 1940970/2101540 08/26/94 N28E SIDETRACK(04-22A) 11/02/16 ZV/JMD ADPERFS(10/27/16) AR No: 50-029-21454-01 (60) 07/04/09 D14 RWO 12/21/17 MS/JMD JET CUT LM (12/20/17) SEC 26,T11 N,R15E,1089'FSL&217'FWL 11/23/10 NORDIC I CTD SIDETRACK(04-22AL1) 01/05/18 JDMJMD PILLED LNR(01/04/18) 07/09/15 BLS/JMD ADPE RFS(06/17-19/15) 01/29/18 KFM/JMD SET HEX PLUG(01/27/18) BP Exploration(Alaska) OF T�� • • y$,\ Iy/, ,A THE STATE Alaska Oil and Gas • �a� Of LAsKA Conservation Commission 333 West Seventh Avenue " ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 04, "^++t �P ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Thompson Well Intervention Engineer SHED SEP 2 7 2.011 BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-22A Permit to Drill Number: 194-097 Sundry Number: 317-391 Dear Mr. Thompson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, °11)QT-'\ Hollis S. French Chair DATED this 19 day of September, 2017. RBDMS l SEP 1 9 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPRO ALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0. Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program ❑ , Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other k 6orldrkl� p b ,Ww ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 194-097 3. Address: P.O.Box 196612 Anchorage,AK Exploratory CI Development B. 99519-6612 Stratigraphic 0 Service 0 8. API Number: 50-029-21454-01-00 • 7. If perforating: 8. Well Name and Nu What Regulation or Conservation Order governs well spacing in this pool? 'RECEIVED L' Will planned perforations require a spacing exception? Yes 0 No 0 PBU 04-22A' AUG 9. Property Designation(Lease Number): 10. Field/Pools: U 1 5 9 017 ADL 028324,028322&028323' PRUDHOE BAY,PRUDHOE OIL 6 q 1 4i[7 11. PRESENT WELL CONDITION SUMMARY 0G C Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12460• 8696 • 11278 8668 2416 None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 34-114 34-114 1490 470 Surface 2484 13-3/8" 33-2517 33-2494 3450/4930 1950/2670 Intermediate 7669 9-5/8" 31-7700 31-5797 6870 4760 Liner 4131 7" 7553-11684 5712-8737 8160 7020 Scab Liner 3475 4-1/2" 7394-10865 5618-8465 8430 7500 Liner 873 4-1/2" 11587-12460 8734-8696 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11086-12437 8587-8698 4-1/2"12.6# 13Cr80 29-7454 Packers and SSSV Type: 4-1/2"Baker S-3 Packer Packers and SSSV MD(ft)and TVD(ft): 7324/5577 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 - Service 0 14.Estimated Date for Commencing Operations: October 1,2017 15. Well Status after proposed work: Oil 0 • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Thompson,Ryan be deviated from without prior written approval. Contact Email: RYAN.THOMPSON@bp.com Authorized Name: Thompson,Ryan Contact Phone: +1 907 564 4535 Authorized Title: Interventions Engineer Authorized Signature: 19,.. ..._i,____, Date: 8//,j//-7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: \-7- 39 Plug Integrity 0 BOP Test Ir' Mechanical Integrity Test 0 Location Clearance 0 Other: orP 1-4-5 t -f0 3. t,19 p --1%-,-1- 5.-/--- -Yv 05-00 P� t J Post Initial Injection MIT Req'd? Yes 0 No I '" Spacing Exception Required? Yes 0 No Subsequent Form Required: /r 4(.2 4- Approved by: APPROVED BYTHE q +� 11t COMMISSIONER COMMISSION Date: 1 1 9 2917 ���� ORIGINAL RBDMS SEP �o.1 Submit ubmit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate bp • Sundry Request Water Shut Off with Well Work Platform Operations Well: 04-22 Date: 8/14/2017 Engineers: Ryan Thompson: 907-564-4535 Bernhard Stechauner: 907-564-4594 MASP: 2416 psi Well Type: Producer Estimated Start date: October 2017 History: In 2016 we performed a successful rich gas add perfjob on this well. The production from the two horizontal legs has been marginal for years and we would like to shut it off. The "plop-and-drop"ctd liner makes a WSO hard to achieve, so the proposal is to cut and pull the liner just above the window and then set a plug to shut-off all production (+99% WC) from the laterals and increase the drawdown of the productive Z2 perforations. Scope of Work: The objective of this intervention is to utilize Service Coil and the Well Work Platform to pull -550' of CTD Liner and then utilize E-Line to set a plug and perform a WSO above the liner stub Pre WWP Work S Drift for HEX Plug to Liner top Drift for E-Line Cutter into the liner E Cut 2 7/8" liner at 11,256' MD (just above window) F Load IA and Tubing ✓ Tree work pre WWP Proposed WWP Procedure: • MIRU WWP, BOPE and support equipment • MIRU CTU • Test BOPE with four preventers configured top down (annular, blind shears 2" pipe/slips, mud cross, 2-3/8"x 3-1/2"VBR's, 2" pipe/slips). Test pressures will be per the 10-403. • Drift • Pull —550' of CTD Liner. • RDMO CTU and WWP. Post WWP Work S Tree work post WWP E Drift for HEX Plug to Liner cut F Set HEX plug at 11,200' MD • III 04-22A WELLFfEAD= FMC ACTUATOR= BAKER C OTY NOTES: WELL ANGLE>TO" 11291'"' CHROME TBG&LINERS"'ORIG WR..BORE NOT ACT TOLEV= AL1 l SHOWN BROW CMT IN9-5/8"CSG"" BF.fiEV= I KOP= 2100' Max Angle= 98"@ 13685' 20"pp OR H 114' i 11 1987 --14-1/2"NEB X NP,D=3.813" Datum M3= NA 91.5#,H-40, Datum TVD= 13=19.124" 1 ' GAS LET MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2521' 2 3776 3509 51 WIG DOME RK 16 01/23/16 (TOP 2 JOINTS=680,K=55,ID=12.415") L 1 7215 5512 F 54 MAG SO RK 20 01/23/16 Minimum ID =2.377" @ 11226' 7296' -14-1/2"F+Es X NP,D=3.813" 3-1/2" X 2-7/8" XO > 7325' .1-19-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" II ' 7360' --14-1/2"FES X NP,D=3.813" 4-1/7 TBG,12.6#,13CR-80 VAM TOR -I 7456' .0152 bpf,ID=3.958" / 7456' -14-Vr WLEG,13=4.00" TOP OF 4-1/2"SCAB LNR -{ 7394' I 7394' -9-5/8"X 7"C-2 ZXP LIP '❑` w/BKR HMC LM HGR,D=6.20" 9-5/8"X 7"SM-6-AT LTP w/LNR HGR D=6.208" -1 7553' _ - 7502' -17"X 4-1/2"XO,D=3.93" TOC(08/04/94) --f 7697' qq� 9-5/8"MLLOUT WPDOW (04-22A)7700'-7750' 9-5/8"CSG,47#,L-80 BTC,0=8.681" -I -7700 Da 7"LNR,29#,NT-80 XO TO 13CR-80 NSCC, -I 10674' X X 10694' -14-BTT DEPLOY SLV,D=3.00" 0371 bpf,D=6.184" Fr 10715' --13-1/2"OTIS X NP,D=2.812- 4-1/2"SCAB LI1,12.6#,13CR-80 -! 10745' ` VAM TOP,.0152 bpf,D=3.958" I 10760' --17"X4-1/2"UNIQUE OVERSHOT 4-1/2"TBG STUB(06/28/09) -{ -10748 X 10795' -17"x 4-1/2"BKR S-3 PKR,D=3.875" I r 10857' -{4-11"HES X NP,D=3.813" 41/2-TBG, 12.6#,13CR-80,.0152 bpf,D=3.958" H 10869• 1---/ • 10869' H4-1/2"WLEG,D=3.958" 3-1/2"LNR,9.3#,13CR SIL,.0087 bpf,D=2.992- -1 11226' ( ‘ J 10862' -i ELWD TT LOGGED??/??/?? 11226' -13-1/T X 2-7/8"XO,D=2.377" 4-1/2-X 7" VVI-PSTOCK(11/09/10) -1 11274' I- I7"MLLOUT WINDOW (04-22AL1)11278'-11286' Iik.. 7"X 4-1/2"TNN SS PKR&HANGER D=T -I 11587' P` 14180' 2-7/8"COLLAR �w/RN,D=2.377" AIL NP 7"LNR 29#,13CR-80 NSCC, -{ 11684' I .0371 bpf. D=6.184" I JJ; Nk PBTD - 14192' TIGHT SPOT ---1 13080' 4-1/2"LNR,12.6#,L-80 NSCT, -1 12460' .0152 bpf,D=3.958" ,i�. 2-7/8'LN R,6.4#,13CR STL,.0058 bpf,13=2.441" H 14199' Vii' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/02185 ROW 35 PARTIAL COMPLETION 01/27/16 ,JI MJMD GLV CIO&SET XX PLUG(1/23/1 VVELL: 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION 10/20/16 ZV/JM) FULLED XX PLUG(10/17/16) PERMIT Nb: 1940970/2101540 08/26/94 N28E SIDETRACK(04-22A) 11/02/16 ZV/JMD ADPERFS(10/27/16) AR No: 50-029-21454-01(60) 07/04/09 D14 RWO SEC 26,T11N,R15E, 1089'FSL&217'FVVL 11/23/10 NORDIC 1 CTD SIDETRACK(04-22AL1) 07/09/15 BLS/AD ADPERFS(06/17-19/15) BP Exploration(Alaska) • • 04-22A • AL1 1 I i I I L 1 1 1 1 Jr T Jr PERFORATION SUufAARY REF LOG:MEM I FF OCU GR/TPF/TNN ON 11/19/10 ANGLE AT TOP FERF:WA Note:Refer to Production DB for historical perf data l SIZE SPF INTERVAL Opn/Sgz DATE 04-22A 2-1/2" 6 11086-11100 0 10/27/16 S 8 2-7/8" 6 11300-11575 0 11/18/10 4-1/2" 32 11676-11914 0 08/26/94 I 4-1/2" 32 11953-12032 0 08/26/94 4-1/T 32 12070-12110 0 08/26/94 / • 4-1/2" 32 12120-12437 0 08/26/94 04-22AL1 • 1 2" 6 11394-11424 0 06/19/15 2" 6 11948-12148 0 11/21/10 2" 6 12275-12305 0 06/18/15 2" 6 12328-12418 0 11/21/10 11111L2' 6 12508-12718 0 11/21/10 2" 6 12868-13098 0 11/21/10 1.56" 6 13280-13310 0 06/18/15 1.56" 6 13722-13822 0 06/17/15 lig ` 2" 6 14053-14191 0 11/21/10 I I ` A `I DATE REV BY COM LENTS DATE REV BY CONVENTS PRUJHOE BAY UNIT 12/02/85 ROW 35 PARTIAL COMPLETION 01/27/16 JMWJM) GLV C/O&SET XX PLUG(1/23/1 WELL: 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION 10/20/16 ZV/JM) FULLED XX PLUG(10/17/16) F'ERMT No: 1940970/2101540 08/26/94 POSE SIDETRACK(04-22A) 11/02/16 ZV/JM) ADPERFS(10/27/16) AR No: 50-029-21454-01 (60) 07/04/09 D14 RWO SEC 26,T11 N,R15E, 1089'FSL&217'FAIL 11/23/10 NORDIC 1 CTD SIDETRACK(04-22AL1) 07/09/15 BLS/JM) ADPERFS(06/17-19/15) BP Exploration(Alaska) • • Planned Wellbore Configuration TREE= FMC 16iE3ufAD_ 04-22A E ^69 OG L ,NI ,O1 ACTUATOR- BAKER C SHOWN BROW CM T IN 0-6B'CSO^ C3KB aEV= 60'.'" ' ` BF EEV= f KOP= 2100 MaxAngle= 98"@'13685{{: ax 20"COM1CTOR - 114' i III1962' -1 I4-1/2'111S X tip 53=7.87" 1 E>atumMD- Me,}91.51k,I1.40. Datum TVD= 8800'SS D 19.124' I GAS LFT MANDRELS STS ND TVD DEV TYPE 3 VLV LATCH PORT; DATE r 13 318'CSU,em180 FAC u 12 14r i I 2521' �' 2 3776 A1G 0OG1E I11( 216 (TOP2JOINTS=p/,IW55,ID=12415') - 1 1215 SS723508r54X51 PR-I4I SO RK 20tfi !0112101116 i ' r— ! 7296' 1 4--117'FES X P 'D-3.813', Minimum ID=2.377"a 11226' 3-112"X 2-718"XO S 7325' 1-{9-518'X4-1/7Bra S-3 P504,D-3.875" I I r 7360' -f4117I-E.SXMP,ID=3.813' 4 V7 TBG,72111,13C1440 VAMT019I 7456 0152144 (D=3 958' .._--., / 7466 4•VT wf,,D-4.00' I ITOP OF 4-1rr SCAB LW I- 7394' I '1-!' - 731 9-5,1•X r C-2 ZXP LIP w18161111[;1.WI4GR,D=6.20" 114 5/8'X T SM-6-AT LTP v!L14i HICK D=8.208' H 7557 - _ `1--7 -17'X 4-1z XO,El-3.93" TOC 100104061) i 7A9T Ito- o-L ti,4771.L-80 OTC,D=6.661' -7700 �' 7'..,Er hl LWl 1hT[X)W(04.22A)1100 7750 r LW 4296 NT-SO XO TO 13CR-10 NSCC. -1 10674' ! X .0311 bpf.D=6.184' 412'SCAB LPR 12.61.13C6E0 -I 10745' VAAI TDP 0152 bp1.ID 3958' 14 117 TBG STUB(06£28100) ...a -10748 $ :I 10796' -Jr x i-ie EBN s3 FKR,D-3. 75' • 10867 -V-1.7 HES XNP,13=3.813' 4-112'TBG,126N,13CE4/0,.0152 bpf,D=3.056' I 10669' 1—• 10w {4 117 WI PG,D-3116r Set HEX Plug 11200'MD -- .), I I 10667 j in 1TEne,r.FD7arrrm 1 Tubing Cut—11,256'MD 14 1/2"X r 7 IIPS10 4.111100110) { 11274' 1-- I 7'AtLOUTHOC4oe-22AL1)11278'-11291 1I1I.. LX41/7TIWSSRG3&FWNCD=r H 115871i ii Ill 4. 14140' 2-718 COLLAR w!Pr(D=2.37 r LINK,291,13CR-10 Moo, H 11684' I I I + 0311 bpt IU n MA' III ! VOTE) 14192' I. JJl 441114` 4 1,7 I NR 1:114 , 60 PFCT. 12460' I I IncifTSPOT I 13080' 012 bp'.D 3958' I .. 12 78•LM 8 48 13CR STL, 00'.8 OK D 7 441" 14199' I w+; ' EY1it- Iry BY IX71.11-NIS r DA!lT[ /I UY CCMIINRITS PDE BAY LW 12132165 ROW 35 PARTIAL COMPLETION 01/27iP!JEI JND GLV CD S SET XX PLUG 11/2311 NH l 04-27A 1A11 01£26/06 WWI OWCQNALCOMPLETION 10/20(16 ZVIJIID PULLU)XXPLUG(10!17116) + P6aArNo' 1440970 I 2101540 05/26/14. 121E SIDEIRACK(04-22AJ 11.ro/,i6 rvubo A(344s(1W'/.r1h) AR No, 50-B29-71454-01 560) 0711401 014 RM/O SEC 26 T11(4,R1S( 1069'TSL 8 21r PAL 11/23/10 NORC1C 1 CTO SIDETRACK(04-22AL1) 0/119.19 III S7.104)Ar 31444S 3 BP Exploration(Alaska) BOP rig up t I Platform Floor Riser to platform floor I i Annular OEM NE! i en mos t HI lam' IEi1uulji Blind Shear Hydra. :aIv Actuated Valve � A.I(,C me 1 it Coil Pi Sii �e per p .T. rte. Choke Linenomm �. ` 4 r I1= 00 1 1.10 ci �sl•I Com°'' Ill-,..11111:*� sl. Lr'le WIN eL t Iii i imi•IIE1auiii 1� Variable Bore Ram �. 1na.a �� �, 111110 1� I I ICI. I Cod Pipe/Slip .T.. 7 x 7 Spool as needed GPFlow Cross Qo SSV twoliw �iR 4.� �I I Master Valve THA • :.'_ 11111.o i I I i. Tubing Head Ground Level STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 194-097 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21454-01-00 7. Property Designation(Lease Number): ADL 0028323 8. Well Name and Number: PBU 04-22A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12460 feet Plugs measured feet NOV 2 3 2016 measured feet true vertical 8696 feet Junk Effective Depth: measured 12460 feet Packer measured See Attachment feet AO GCC true vertical 8696 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 34-114 34-114 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7665 9-5/8"47#L-80 31-7696 31 -5795 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11086-11100 feet 11300-11575 feet 11676-11914 feet 11953-12032 feet 12070-12110 feet 12120-12437 feet True vertical depth: 8587-8593 feet feet 8677-8734 feet 8736-8729 feet 8725-8718 feet 8716-8714 feet 8714-8698 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 5C NSED MAR 4) 8 201 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 100 413 7352 1551 259 Subsequent to operation: 110 436 9865 1576 277 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 11 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature J� Phone +1 907 564 4424 Date 11/23/16 Form 10-404 Revised 5/2015 �'rl, 2./ //-7-- NOVo �i RBDMS L L S 2 p 2016 Submit Original Only • • Packers and SSV's Attachment PBU 04-22A SW Name Type MD TVD Depscription 04-22A TBG PACKER 7323.83 5576.63 4-1/2" Baker S-3 Perm Packer 04-22A PACKER 7392.24 5617.03 7" Baker ZXP Top Packer 04-22A PACKER 7557.23 5714.28 7"TIW Liner Top PKR 04-22A TBG PACKER 10791.14 8411.18 4-1/2" Baker SABL-3 Packer 04-22A PACKER 11583.01 8734.34 4-1/2"TIW SS Horiz Packer • • m Q. 0 0 0 0 0 0 0 0 0 0 LnN- CO 53 ((i?O CO I L() O O LO Ln L() C T- N Tr L() f- I- r- r- r- ti V 0) 53 c' N- c M CO CO M M C') m T M N (O N- CO CO 00 COCCOC000 • CD CD CD OO OD 001 CO UD CO Ul COMM (O COT N LO to co O O O LO OD f� - O N T- Lf) Tr CO O T- T- 00 r- r- M O) f- M CO Ln M (O CO M N- N co LO L() t() 00 00 00 4.0 (00000000 � to • M UD CO N N- O CO N O � V 44,N C"../ co N vMrn �- rnovODrnCD v co co to M p N p C 0 M_ W O O O a LC) p 0 22 0 00 00 Lo op 1 Y 00 O M 00 ( _M M_ = J 00 i = d *kN4J4tZMCC00 *k *k .y Cl) - � ICON *k � NN 03 CA bp uuQO N T- N N - • -• LO CO CaO ti O CO O Ul N_ Or C./ N O) J 0 N N N- O M M r O N W Q Cn C I- UJ UJ w N U V V 0 L W W n W c W Z Z Z i w W W W W W W pp m O D F_ ZZZZZDD U oo u) Z J J J J J F- F • • LL a2 m D m m Z O Z 0L z a o z Z 0 0 ❑ = 0 W Q a w O ❑ O - a cc ct ce < > 0 0 Q Z 0 > co -m LU w Y O O OJ O D Ce W 2 OO W Z .� ❑ Q J - w CC 0 U-I CL W ❑www2 m o � CC I- _ Z J Z co Q � � � � ~ J F- ❑ W W 0 W Oz LL f- wwwwO 0JO I m N W 0 F- ( 0 Z Wwww ❑ m — N Z Q _ co 0 W Wu. Z O ❑ ❑ ❑ ❑ 2 2 6'm-- m = - ' W Q >- w I Q z U Q 2 2 2 r — 1— a (V 2 ❑ z0W W � � ininQo I� LOZ * 2 cn II OZ M ‹ F- 0 = JOz ❑ NNN 1 N o 17. 0 * D 2 ❑ F- Co0 ZW 4, 01mm O 2 0 w � _ � o o o O 2 o Q W z O O W N 2 O Nm J cocaLL UU) 0 � ���0 U �W PJ 2 � w � a lio ^Q w XQOao < mccoccnco bo cJi) - Om 0 0 < a U CO X 2 4- < n , o ❑ 22o o c oh. arowm o � 2 O � - <° Q Q ❑ 2 _1 _1 •- CO CO (O J r (ow u) ... cc o --- LL �r a � J * Q MMO * "- OOOw 0 OCO * ❑ * W NNN N N Q : I- - - - F- : O Y I * w J N N N 0 CQ. N * LL * •- O o ��0 6o * COEDDDO 0 D '* j > o0 § 0 ❑ WV QI- to � Z , OOZ , CDCOaJJJZ Z Jx- CON. F- ceLo < b id ceo J _ — O ,- .- O , . XXaXXXaXam 0 a0 \ \ aavLL0 0 > COOa � a � � OXXXX , cc XF- 000 QQOa � , z ce0o20 (7312120- mo20000Q 0 0zo2 wzOCO2 oLo I F- co m �i mai 0 Z1 Oz ti W CL N- 0E- F- F- F- W Z F- 2x- 0 ❑ 00 -� mbi- j N � C m O_ � r Ea) L ) Q C. N v) I— C) Q a N _z G� O � 115 < O▪ N Q N • O >1 CU (7 N a) a TRS FMC • S TES: WELL ANGLE>TO* " 11291" V11�LIfAD= FMC04-2 2A CHROME RTBG&LINERS""ORIG WELBORE NOT , ACTUATOR= BAKER C AL1 SHOWN BELOW CMT IN 9-5/8"CSG**" OKB.E LEV= 60' BF.BEV KOP_ 2100' Max Angle= 98°©13685' 20'CONDUCTOR 114' 1982' 141/2"HES X NP D=3.813" Datum P.4)= NA 91.5#,H-40, Datum TVD= 8800'SS D=19.124" GAS LIFT MANDR�S ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" - 2521' 2 3776 3509 r 51 MMG DOME RK 16 01/23/16 (TOP 2 JOINTS=68#,K=55,ID=12.415") 1 1 7215 5512'54 MMG SO RK 20 01/23/16 Minimum ID =2.377" @ 11226' 1 I 7296' -14-1/2"HES X NB' D=3.813• 3-1/2" X 2-7/8"XO g X 7325' J-I9-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" ' ' 7360' H4-1/2"IES X NP,ID=3.813" 4-1/2"TBG,12.6#,13CR 80 VAM TOP, -I 7456' .0152 bpf,0=3.958" 7456' -I 4112"WLEG,D=4.00" TOP OF 4-1/2"SCAB LNR --I 7394' i. \--'...--.............-.1 7394' -9-5/8"X 7"C-2 ZXP LTP T w/BKR HMC LNR HGR,D=6.20" ' 9-5/8"X 7"SM-6-AT LTP w i LNR HGR ID=6.208" - 7'553' - . 7502' -17"X 41/2"XO,ID=3.93" TOC(08/04/94) --{ 7697' 9-5/8"CSG,47#,L-80 BTC,D=8.681" H 7700 ^' Et / 9-5,8-PoLLOIJT V1tPD4W (�` )7700-7750' 7"LNR,29#,NT-80 XO TO 13CR-80 NSCC, H 10674' X X 10694' H4"BTT DER OY SLV,0=3.00" .0371 bpf,ID=6.184" 10715' -I3-1/2"OTIS X NP,D=2.812" 4-1/2"SCAB LNR,12.6#,13CR-80 -{ 10745' 1-Tf VAM TOP,.0152 bpf,D=3.958" 10760' -17"X 41/2"UNDUE OVERSHOT 4-1/2"TBG STUB(06/28/09) -I -10748 g g10795' -{7"x 4112"BKR S-3 PKR,D=3.875" I r 10857' ---I4-1/2"FPS X NP,D=3.813" 4-1/2'TBG, 12.6#,13CR-80,.0152 bpf,D=3.958" H 10869' I---/ %. 10869• -I4-112"WLEG,D=3.958" 3-1/2"LNR 9.3#,13CR STL,.0087 bpf,ID=2.992" H 11226' I--'. 1 10862' -I aMD TT LOGGED??/??/?? - 11226' -13-1/2"X 2-7/8"XO,13=2.377" 41/2'X 7" WfFSTOCK(11/09/10) - 11274' 1--- i I ult.. - 7"WLLOUT WPDOW (04-22AL1)11278'-11286' 7'X 41/2"11W SS PKR&HANGER,13=?" H 11587' li 14180' -2-7/8"COLLAR w/RN,D=2.377" 7"LNR,29#,13CR-80 NSCC, --i 11684' .0371 bpf. D=6.184" PBTD - 14192' I. J TIGHT SPOT - 13080' 4-1/2"LNR,12.6#,L-80 NSCT, H 12460' .0152 bpf,D=3.958" ��� 2-7/8'LNR 6.4#,13CR STL,.0058 bpf,ID=2.441" -I 14199' 4 i! DATE REV BY COMoENTS DATE REV BY COMMENTS PIRI/DHOE BAY UNIT 12/02185 ROW 35 PARTIAL COMPLETION 01/27/16 JMMJM? GLV GO&SET XX PLUG(1/23/1 VV>3L: 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION 10/20/16 ZV/JND FULLED XX PLUG(10/17/16) FERMI-No: 1940970/2101540 08/26/94 N28E SIDETRACK(04-22A) 11/02/16 ZV/JM) ADFE RFS(10127/16) AR No: 50-029-21454-01 (60) 07/04/09 D14 RWO SEC 26,711N,R15E, 1089'FSL&217'FWL 11/23/10 NORDIC 1 CTD SIDETRACK(04-22AL1) 07/09/15 BLS/JMD ADPERFS(06/17-19/15) BP Exploration(Alaska) • 04-22A • " AL1 1J [I I I L 1 1 S S I 1 i. IF PERFORATION SUMMARY REF LOG:MEN LEE CCL/GR/TNF/TNN ON 11/19/10 ANGLE AT TOP PERF:N/A Note:Refer to Production OB for historical pert data r l SIZE SPF INTERVAL Opn/Sqz DATE I I 04-22A 2-1/2" 6 11086-11100 0 10/27/16 S 3 2-7/8" 6 11300-11575 0 11/18/10 4-1/2" 32 11676-11914 0 08/26/94 1 4-1/2" 32 11953-12032 0 08/26/94 4-112" 32 12070-12110 0 08/26/94 i • 4-112" 32 12120-12437 0 08/26/94 04-22AL1 J T 6 11394-11424 0 06/19/15 2" 6 11948-12148 0 11/21/10 2" 6 12275-12305 0 06/18/15 2" 6 12328-12418 0 11/21/10 1111 . 2" 6 12508-12718 0 11/21/10 2" 6 12868-13098 0 11/21/10Ili ` 1.56" 6 13280-13310 0 06/18/15 1.56" 6 13722-13822 0 06/17/15 I 2" 6 14053- 14191 0 11/21/10 1 I ` I ` A b. • : r- 9 • 0 I o E C 1 (0c07�o Lto J4m U �a 6 L` a�Y o Q p N ops CC til � � � p 11 O EE o B AJ a. _u u, j O aO -O w O 0 E 0 -.1 LY O O O t0 co CO O co O v E L COtn U c C c c _D C *' C O -•-'---(8 t- F- OJ as as ca as a) a) m E C c -) ? LL LL E O_ QJ Z a N M N M r rt, v Q O Ln 2 Q 0 O _6 O >- u u i-, F- C C '' CO C 0 0 0 0 0 0 0 "a ca" u _C p- W J J J J J J J C ,.-, CL W W W W W W W oC C ca 0 0 *-, I- LL LL LL Li. LL. LL LL N N E -o 'n + N C < J J J J J J J Q (0 c > Q Q Q Q Q Q QO <zZZZZZZZ v `,, v `" '-' O v uca0 u N VvIt LL LL LL LL LL LL LL O O L_,(-) N ,- • � Z C O Q O N = U o , 0 L v a) v CCI •� t F- F F < WC c ca uu CU O ,i:_. w 0 0 0 J I- J 2 d CI O a! Lu V) N cn p j 0 U -4:1 ,y 0, J J J J N CO 03 C E O ;,G < U U U ccW DI 8 a1 U '- ' U ci `< 0 tom// 0 h OS cOo > E EEEE3E3 Z zaM C) � 0C222 0 2 Z d ,* V R W Q Q Q Q Q 2mmmm <nm z0000 < 0 S 2 2 < 2 J 2 [`a�� ' L 0 0 0 D O D t `> m W > > > Z D d = LL a a a a a o cc W U � Y Ca � cn X 'v) 0 > I _ 00 00 co N N tp c, fl' pp �/r' N V O o o O o o a� O o 0 0 0 0 0 0in M 0 0 0 0 0 0 0 m V rn v v 6 co O1 O CO N N a0 Q m O O O C� V • 111 0 0 0 0000 ai mlao Z a o O O O O O 0 m C Cr (D O O O o o O O V M M)O c0 h c0 +O'' C in r- coTr Tr a0 N '6Q m O r CO 0) ) Y O N 0 N 4 N N NNNNNN p] n O O O O o T o) E C O N N N N N N N O O O O O O O ON o O O O O O O c c In In In In LO N in ..., 4-4 m COr44444 co C O. 'C w ce Lu 0CU� 1 E RI ( = O Q1 ) .5 O 2 Lu he 8 C4 ir "d1 N N N N Y O C N N O CO !_4 a+ = „ V1 i N v in Y th N v E Z NE cu cc -0 U o_ 4 N O o Z o ,) 0 r . N t n C c c6 V O_ LIP 8 y E 1 d F' N c d a a m m RECEIVhU STATE OF ALASKA \LASKA OIL AND GAS CONSERVATION COMM! V _in L 2 7 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed /\Q(3 1JL Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Pull LIP IA 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 194-097 3 Address' P.O Box 196612 Anchorage, Development Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21454-01-00 7. Property Designation(Lease Number): ADL 0028323 8. Well Name and Number: PBV 04-Y2A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12460 feet Plugs measured feet true vertical 8696 feet Junk measured feet Effective Depth: measured 10650 feet Packer measured 7325 feet true vertical 8294 feet Packer true vertical 5577.03 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 79 20"91 5#H-40 34-113 34-113 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7669 9-5/8"47#L-80 31-7700 31 -5797 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth Measured depth: 11300-11575 feet 11676-11914 feet 11953-12032 feet 12070-12110 feet 12120.12437 feet True vertical depth: 8677-8734 feet 8736-8729 feet 8725-8718 feet 8716-8714 feet 8714-8698 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8O 29-7455 29-5654 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary' Intervals treated(measured): r h�1 G� U , )(1 i., SCg1 �H 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: 277 427 6720 1620 252 Subsequent to operation: 106 0 8548 1594 262 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory 0 Development IZ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16 Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp corn Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature /,�� Phone +1 907 564 4424 Date 7/23/15 Form 10-404 Revised 5/2015_ �� ��3 S Submit Onginal Only 45`. 45.----- RBDM ,I AUG - 2 2015 m a o 0 0 0 0 0 0 0 0 0 0 0 r' Le) LiN-ci CO — OCV NOo0 O C) . 0 0 0 0 0 0 0 0 CD 0 0 0 0 C) U7 M M N M CD M (.5 M 0) Q) co N Cr r- A-- m Ce) Nr NI. CO aocoOOoaoao O r A— CO N- CD N- M U) O) M 0) CO 03 A— M Cr) CD U7 CO lC) N- CO co co N- co CD N N U) CO CO CO CO CO U) 1- A— I— CO l() e- co M r-- co -M co CO co CO CO N- M ti M N In U) co co co CO O co co O N CDM U7 N Lo O U) N- co co co in O co C N- U) O C N O .t C.) Q5 N co (NJ MLI) NNr v- co 00 r O O U) c° cn 4 M M CD M C) U) Cf) O O N C O • W O O O 00 O 00 OO u7 0 0 0 � � � \ Y JO M CO c co co a) = J 00 () T- • o *k co N N J *k Z C) CD *k *k N N U) CD N- N % CD nj CO CO • 0) 00 W 0000 pO N N N - _ N V O M 7 Ps N - (V CV Cy MMM 4 r O M O 0) •n CD 117 N . N N I� COMA— I� W C a)O 0 ° 000 • u_ u_ CL Z Z CL' trCL' W W W W W W W m O D D D , Z Z Z Z Z Z D 0 fn fn (/) J J J J J J _se U Cd d I ` O Y O O V Y O (I) a) U �p Ha Hd N2 a � a Qaa •` TYaVMN J m O CL cy)tyw(/) U) N _NC Q Y Y co va mYcmm � �.+ N m N N N r r r r E U co03 4-1 Cr) 1` — N CO 0 O CO O CO f� I� to N M N CO I-- M ▪ N LO LO to Q0 c0 c0 o O ▪ O- E c 03 ✓ co ` La a, CO NI- M D6 O LO Y2 NLt) O LO ✓ r CO a receWireCCCL O.YYYYYY >'0 0 0 0 0 0 Q Q Q Q Q Q aaaaa - m E < < < < < < Cp N N N N N N Z N N N N N 000000 U) / • = § e i - 2 q . q co co (q _ lJ -73 O - ƒ a) _ _ > / z CD Z to 0 Co L co > % E / co O co w \ o >- k 2 \ § o E I 2 $ E 4 f o= = E ■ 2 _z �_ @2 e m ® _� � k22 \ � � � a3 k1 $ w 0 � \ � / b kz ƒ t / CL - u) a 0-L 2 � E CO / ° w om 6 `- @ * 02 ® 2w t CO _ 2 m - k 6 ° w o � k0 � \ aE # ƒ k : w LL Z •- 6a. E :-.= ƒ CO CC \ w / 6 2 f o ƒ E D cC >. « Y ® cam / 3 � cC _ 2 U r m n = ^2 « 2 « ® � 2 e o § / 0- m CI ƒ 0_ ZtU) OER Ou_ zO OU- Doc - E zo e w 2 0_ a) c — _ _ # O c w & _ - 7w < zz & O - o cn7 \ = 2 Z Z' c e w . \ R k _10 / 0222 , = 0_k _1 U) * _ , , « o « 5 2 E - , m : o_ m : : cC .- ce = 2 Q : ; o w i- < � ® >- N N/ .- 5 a @ co w » ® 0 FMC TREE=. = FMC 04-22A Y NOTE& WELL ANGLE>70'a 11291'"" --- CHROME TBG&LII ""OIG WELBOfiE NOT ACTUATOR= BAKER C AL1 SHOWN BELOW CMT IN 9-W CSG" 0103.E-EV 60' I I BF.ELEV= KOP= 2100' -- --- -- -- 1982' H 4-1/2'HES X NP,ID=3.813" Max Angle= 98'@ 13685 20"OOrDU(,'TOIZ 114' I 11 Datum MD= NA 91.58,H-40, Datum NO= 8800'SS 13=19.124' GAS LFT MAM3RELS ST MD ND DEV TYPE VLV LATCH FORT DATE 13-318'CSG,728,L-80 BTC,D=12.347" - 2521' 2 3776 3509 51 MNG DOME RK 16 12/02/10 (TOP 2 JOINTS=8811,KRS,ID=12415") L, 1 7215 5512 54 1.610 SO RK 20 12/02/10 ' ,----I 7296' H4-117 HES X NP,D=3.813' Minimum ID =2.377" @ 11226' 3-1/2" X 2-7/8" XO g x 7325' H9-5/8"X 4-12"BKR S-3 FKR,D=3.875" ' I I 7360' -{4.1/2'FES X RP,13=3.813' 4-1/2'TBG, 12.68,13CR-80 VAMTOP, H 7456' .0152 bpf,0=3.958' i 7456' H4-1/7 Y EG.0=4.00" I TOP OF 4-1/7 SCAB LP H 7394' -q.. v. 7394 H-{9.5/8'X 7'C-2 ZXP LIP T Iw/BKRHMCLNRHGR,D=6.20'_ I9-5/8'X 7'SM-6-AT LTP w/LNR HGR,D=6.208' H 7553' 'j 7507 HT'X 4-12"X0,D=3.93' TOC(08/04/94)H 7697' 9-5/8'CSG,478,L-80 BTC,13=8.681" -1 -7700 ^' a 9-5/8'MLLOUT IM OOW (04-224)7700'-7750 7'LW,2911,NT-80 X0 TO 13CR-80 NSCC, 10674' X X 10694' -114'BTT CEPLOY SLV,13=3.00' .0371 bpf,D=6.276' 1 10715' -I3-1/70T1SXNP,D=2.817 4-1/7 SCAB LFR 12.68,13CR-SO 10745' VAMTOP,.0152 bpf,D=3.958' 1-I 10760' H7"X4-1/2'UNDUE OVERSHOT 4-1/2'TBG STUB(0628/09) --I -10748 g 10795' -j7'x 4-1/2'BKR S-3 FAQR D=3.875' I l 10867" -4-1/7 HES X NP,D=3.813' 4-12"TBG,12.68,13CR-80,.0152 bpf,D=3.958" H 10869' i 10869' H4-1/7 WLEG,D=3.958' 3-1/7 LNR 9.38,13CR STL,.0087 10862' H��TT LOGGED??/??/?? bpf,D=2.997 -I 11226' I-- 11226' I-13-112'X 2-7/8"XO,V=2377" 4-1/7 X r w- T'OCK(11/09/10) H 11274' I- 7"MLLOUT VMDOW (04-22AL1)11278'-11286' Iill. T X 4-1/7 TNV ss FiO2&HANGER D=Y H 1158T 14180' 2-7/8'COLLAR w/Pik D=2.377" 7'UR,2941,13CR-80 NSCC, 11684' I I ` .0371 bpf. D=6.276' rl FBTD 14 92' TIGHT SPOT 13000' 4-1/7 LIR 12.68,L-80 NSCT, -I 12460' .0152 bpf,D=3.958" .4 12-7/8'LP ,6.4S,13CR STL, 0058 bpf,13=2 441' H 14199' ILI DATE , REV BY 001.6ENTS DATE REV BY COMMB8ITS PRIAHOEBAY U�TT 12102185 ROW 35 PARTIAL COMPLETION 03/31/11 JCPAPJC PUL LTTP(0328/11) WELL 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION 07/09/15 BJO/JM) PULL®LIP(06/05/15) PBINIT No: 1940970/2101540 08/26/94 N28E SIDETRACK(04-22A) 07/09/15 BLS/JMD ADPERFS(06/17-19/15) AFI No: 50-029-21454-01(60) 07/04/09 D14 RWO SEC 26,T11 N,R15E,1089'FSL 8 21T FVVL 11/23/10 NORDIC 1'CTDSIDETRACK(04-22AL1) 03/26/11 BSE/PJC SET KB LIP<TP(03/21/11) BP Exploration(Alaska) 04-22A AL1 1 1 I I 1 1 S S I . r H PERFORATION SUMMARY I l REF LOG:MEM LEE OCU GR.TNF/TNN ON 11/19110 ANGLE AT TOP FERF:WA Note:Refer to Production DB for historical perf data X X SIZE SPF INTERVAL Opn/Sgz DATE 04-22A I I 2-7/8" 6 11300-11575 0 11/18/10 4-1/? 32 11676-11914 0 08/26/94 i • 4-1/7 32 11953-12032 0 0826/94 4-1/7 32 12070-12110 0 0826/94 4-1/? 32 12120-12437 0 08/26/94 04-22AL1 7 6 11394-11424 0 06/18/15 7 6 11948-12148 0 11/21/10 2" 6 12275-12305 0 06/18/15 7 6 12328-12418 0 11/21/10 7 6 12508-12718 0 11/21/10 2" 6 12868-13098 0 11/21/10 , ` 1.56" 6 13280-13310 0 06/18/15 1.56" 6 13722-13822 0 06/17/15 2" 6 14053-14191 0 11/21/10 ` JJI 1 A t0' DATE REV BY CO/LENTS • DATE REV BY CO VEN1S PRUDHOE BAY INT 3,3 12/02185 RDW 35 PARTIAL COMPLETION 03/31/11 JCUMPJC PIA/_LTTP(03/28/11) VYH..L 04-22A/AL1 01/26/86 WWI ORIGINAL COMPLETION a 07/09/15 BJO/JP4) PULLED LW(06/05/15) PERMT No: 1940970/2101540 08/26/94 N26E SIDETRACK(04-22A) 07/09/15 BLS/JM)ADPEIRFS(06/17-19/15) AR No: 50-029-21454-01(60) 07/04/09 D14 IRWO SEC 26,T11N,R15E,108g FSL&21T MIL 11/23/10 NORDIC 1 CTD SIDETRACK(04-22AL1) 0326/11 BSE/PJC SET KB LIP<7P(0321/11) BP Exploration(Alaska) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned bY: Bevedy ~cent Nathan Lowell Date: [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ " STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI0410 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other El LINER TOP PACKER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ S o t ) ,,c4,.1L.J Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ r 194 -0970 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 _50- 029 - 21454 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 28322, 28323,28324, 28325 „ PBU 04 -22A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: y >����, Total Depth measured 12460 feet . APR 1 3 ` t?F .jgs (measured) None feet true vertical 8695.52 feet Junk (measured) None feet Effective Depth measured 12460 feet Packer (measured) 7327. 7394 7561 10670, 11587 feet true vertical 8695.52 feet (true vertical) 5579. 5618 5716 8311, 8734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 91.5# H-40 37 - 114 37 - 114 1490 470 Surface 64' 13 -3/8" 68# K -55 36 - 100 36 - 100 3450 1950 Surface 2457' 13 -3/8" 72# L -80 100 - 2557 100 - 2531 5380 2670 Production 7715' 9 -5/8" 47# L -80 35 - 7750 35 - 5827 6870 4760 Liner 3121' 7" 29# NT -80 7553 - 10674 5712 - 8315 8160 7020 Liner 1010' 7" 29# 13CR80 10674 - 11684 8315 - 8737 8160 7020 Liner 873' 4 - 1/2" 12.6# L -80 11587 - 12460 8734 - 8696 8430 7500 Liner 3192' 4 -1/2 "12.6# 13CR80 7502 - 10694 5682 - 8332 8430 7500 Liner 86' 4 -1/2" 12.6# L -80 10694 - 10760 8332 - 8387 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 32 - 7458 32 - 5656 4 -1/2" 12.6# 13Cr80 10748 - 10871 8377 - 8470 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR S -3 PKR 7327 5579 7" BKR C -2 ZXP LTP „ 5618 7” SM -6 -AT LTP 75 5716 4 -1/2" BKR KB LTP V GO 10670 8311 4 -1/2" TIW SS PKR - 11587 8734 12. Stimulation or cement squeeze summary: ) , '1 xi Intervals treated (measured): 1 Wane Olt Treatment descriptions including volumes used and final pressure: pp�� �k , F.� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 416 801 12,220 267 Subsequent to operation: 193 839 10,124 245 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 - Service ❑ Stratigraphic p Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na " - astu a likt Title Data Manager Signatu�'�, Phone 564-4091 Date 4/11/2011 Form 1 ';jf - evise '" • �' '• ! 'R 131011 swim, t mgmai c n! s'.,,, A`W,0r 04 -22A 194 -097 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04 -22A 8/26/94 SL 11,676. 11,914. 8,736.35 8,728.9 04 -22A 8/26/94 SL 11,953. 12,032. 8,724.88 8,718.29 04 -22A 8/26/94 SL 12,070. 12,110. 8,715.69 8,714.27 04 -22A 8/26/94 SL 12,120. 12,437. 8,714.08 8,697.64 04 -22A 7/14/08 BPS 10,830. 10,831. 8,440.37 8,441.1 04 -22A 7/27/08 BPS 10,818. 10,819. 8,431.5 8,432.25 04 -22A 6/1/09 BPP 10,830. 10,831. 8,440.37 8,441.1 04 -22A 6/8/09 BPS 10,820. 10,821. 8,432.99 8,433.73 04 -22A 7/2/09 BPP 10,820. 10,821. 8,432.99 8,433.73 04 -22A 11/8/10 PER 11,300. 11,575. 8,677.3 8,734.26 04 -22A 3/21/11 BPS ✓ ,5,, 10,650. 12,437. 8,294.01 8,697.64 04 -22A 3/28/11 BPP ,.-" �,...It," 10,650. 12,437. 8,294.01 8,697.64 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 4111 • • 04 -22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/21/2011 SET BAKER KB 45 FLOGUARD PACKER AT 10670' SLM( 10694' MD !SFT 2.81" LTTP W/ 4 1/2" G- F.N. IN BKR KB PACKER AT 10650' SLM 1 * ** WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED * ** I F 3/28/2011 ** *WELL S/I ON ARRIVAL * ** (post CTD) . � .__.__ PULLED LTTP FROM 10647' SLM/ 10694' MD ** *WELL S/I ON DEPARTURE, DSO NOTIFIED * ** FLUIDS PUMPED BBLS 5.5 CRUDE 1 DIESEL 6.5 TOTAL • SAFETY ES: WELL ANGLE> 70° @ 11291' *°* W� FMC HEAD = FMC 04 -22A CHROMETBG & LINERS "**ORIGWB -BORE NOT ACTUATOR = BAKER C AL1 SHOWN BELOW CMT IN 9-5/8" CSG*** KB. ELEV = 60' BF. ELEV= KOP = 2100' 1 1982' (--I4 -1/2" FES X IW, D = 3.813" I Max Angle = 98° @ 13685' 20" CONDUCTOR, --1 114' I i J Datum MD = NA 91.5#, H40, Datum TVD = 8800' SS D = 19.124" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72#, L -80 ETC, D = 12.347" H 2521' I . 2 3776 3509 51 AVM DOME IRK 16 12/02/10 (TOP 2 JOINTS = 68#, K5, ID = 12.415") I r I — ' 1 _ 7215 _ 5512 54 MMG SO RK 20 12/02/10 7296' H4 -1/2" H E S X N P , D= 3.813° 1 Minimum ID = 2.36" @ 10670' 4 -1/2" KB LINER TOP PKR g a 7325' H9-5/8" X 4-1/2" BKR S- 3 PM, D= 3.875" I ' 1 7360' H4-1/2" HES X NP, D = 3.813" I 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, H 7456' .0152 bpf, D= 3.958" I 7456' H4 -1/2" WLEG, D =4.00" I 'TOP OF 4-1/2" SCAB L� 7394' % 7394' H 9-5 X 7" C-2 ZXP LTP m w /BKRHMCURHGR, D =6.20" 19 -5/8" X 7" SM -6-AT LTP w / LNR HGR, D = 6.208" H 7553' 1 7502' H7" X 4-1/2" XO, D = 3.93" 1 1TOC (08/04/94) H 769T 19-5/8" CSG, 47 #, L-80 ETC, D = 8.681° H -7700 9•5/8" MLLOUT WINDOW (04 -22A) 7700' - 7750' I 10670' H4 -1/2" BKR KB LW, D = 2.36" (03/21/11) I 7" LNR 29#, NT-80 XO TO 13CR-80 NSCC, 10674' X I 10694' I-14" BTT DEPLOY SLV, D = 3.00" ( .0371 bpf, D = 6.276" I 10715' H 3-1 /z" OTB X NP, D = 2.812° 4-1/2" SCAB LNR, 12.6#,13CR -80 10745' ` VAM TOP, .0152 bpf, 13= 3.958° i I 1 10760' Hr X 4-1/2" UNIQUE OVERSHOT 1 14 -1/2" TBG STUB (06/28/09) H —10748 ■4 $ I 10795' Fir x 4-1/2" BKR S-3 PKR, D = 3.875" 1 I 1 10857' H4-1/2" HES X Imo, D = 3.813° I 141/2" TBG, 12.6#,13CR.80, .0152 bpf, D = 3.958" H 10869' I - .' 1 10869' H41/2° WLEG, D = 3.958" I L 10862' H &W TI' LOGGED ??/??/?? 13-1 /2" LNR, 9.3#, 13CR STL, .0087 bpf, D = 2.992° H 11226' I - ---1 11226' H3 -1/2" X 2 -7/8" X0, D = 2.377" 1 14-1/2" X 7" WHFSTOCK (11/09/10) H 11274' I II IL. 7" MLLOUT WIDOW (04-22AL1) 11278' - 11286' IT x 41/2" TfW ss PKR & HANGER, D = ?" H 11587' ire Sir ` 14 80' 2 -7/s" COLLAR w / PIN, D = 2.377" I 7" LNR, 29#,13CR -80 NSCC, 11684' I , , ` .0371 bpf. D = 6.276" I I ` PBTD 14 92' i 1 sip 4-1 /2" LNR, 12.6#, L -80 NSCT, –I 12460' I ' • .0152 bpf, D = 3.958" 2-7/8 ; :+ " LNR, 6.4#, 13CR STL, .0058 bpf, D = 2.441 " H 14199 • DATE REV BY WMMB'lTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/02/85 ROW 35 PARTIAL COMPLETION 12/05/10 PJC DRLG DRAFT CORRECTIONS WELL: 04-22A /AU 01/26/88 WWI ORIGINAL COMPLETION 12/16/10 CSR/PJC PBRF CORRECTIONS PERA No: 1940970 / 2101540 08/26/94 N28E SIDETRACK (04 -22A) 12/16/10 MK/PJC FINAL DRLG CORRECTIONS API No: 50- 029 - 21454-01 (60) 07/04109 D14 RWO 03/26/11 BSE/PJC SET KB LIP & LTTP (03/21/11) SEC 26, T11 N, R15E, 1089' FSL & 217' FWL 11/23/10 NORDIC 1 CID SIDETRACK (04-22AL1) 12/02/10 JKC/PJC GLV C/O (12/2/10) BP Exploration (Alaska) 04 -22A AL1 t i i „. if E ci. 4 PERFORATION SUMMARY REF LOG: ME M LEE CCL/ GR/ TNF/ TNN ON 11/19/10 ANGLE AT TOP PERF: N/A Note: Refer to Production DB for historical pert data S¢E SPF M62VAL Opn /Sqz DATE 1 04-22A 2 -7/8" 6 11300 -11575 0 11/18/10 4 -1/2" 32 11676 - 11914 0 08/26/94 4-1/2' 32 11953 -12032 0 08/26/94 4-1/2" 32 12070 - 12110 0 08/26/94 4 -1/2" 32 12120 - 12437 0 08/26/94 04-22AL1 2" 6 11948 - 12148 0 11/21/10 2" 6 12328 - 12418 0 11/21/10 ., , 2" 6 12508 - 12718 0 11/21/10 2" 6 12868 - 13098 0 11/21/10 2" 6 14053 - 14191 0 11/21/10 I■ 1 4 . SIP •I N. I II 4 4., . , 0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/02/85 ROW 35 PARTIAL COMPLETION _ 12/05/10 PJC DRLG DRAFT CORRECTIONS WELL: 04-22A /AL1 01/26/88 WWI ORIGINAL COMPLETION 12/16/10 CSR/PJC PERF CORRECi10NS PERMT No: 1940970 / 2101540 08/26/94 N28E SIDETRACK (04 -22A) 12/16/10 MK/PJC FINAL DRLG LIONS AR No: 50- 029 - 21454-01 (60) 07/04/09 D14 RWO _03/26/11 BSEIPJC SET KB LTP & LTTP (03/21/11) SEC 26, T11N, R15E, 1089' FSL & 217' FWL 11/23/10 NORDIC 1 CTD SIDETRACK (0422AL1) 12/02/10 JKC/PJC . GLV CJO (12/2/10) BP Exploration (Alaska) STATE OF ALASKA ALASfIL AND GAS CONSERVATION COMM! N REPORT OF SUNDRY WELL OPERA ONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown C4 Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 0 Development ❑ Exploratory ' 194 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 we 50 - 029 - 21454 - 01 - 00 7. Property Designation: 8. Well Name and Number. ADL 028324, 028322 & 028325 0 83,Z3 f PBU 04 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 12460' feet Plugs (measured) None feet true vertical 8696' feet Junk (measured) None Effective depth: measured 12460' feet Packer. (measured) 7325 & 10795 feet true vertical 8696' feet Packer. (true vertical) 5577 & 8414 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 20" 114' 114' 1490 470 Surface 2521' 13 -3/8" 2521' 2498' 3450 1950 Intermediate 7700' 9-5/8" 7700' 5797' 6870 4760 Production Liner 4131' 7" 7553' - 11684' 5712' - 8737' 8160 7020 Liner 873' 4-1/2" 11587' - 12460' 8734' - 8696' 8430 7500 Scab Liner 3401' 4-1/2" 7394' - 10760' 5618' - 8387'' 8430 7500 Perforation Depth: Measured Depth: Perf & Slotted Section: 11300' - 12437' MAR 0 3 Z 14i I True Vertical Depth: Perf & Slotted Section: 867T - 8698' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# 13Cr80 10869' 8468' Packers and SSSV (type, measured and true vertical depth): 9 x 4 Baker 'S - packer 7325' 5577' 7" x 4 Baker 'SABL - 3' packer 10795' 8414' 11. Stimulation or cement squeeze summary: }+e� � ��� , Intervals treated (measured): C Treatment description including volumes used and final pressure: MAR 0 2 2011 Perforate with 2 -7'8" Gun Diameter, 6 SPF, interval 11300' and - 11575' and / 8677' tvd - 8734' tvd Op & Gas Cons. Commission 12, Representative Daily Average Production or Injection Data l nchorege Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: _ _ Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory • 0 Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations 0 Well Schematic Diagram 15. Well Status after work: ❑ GINJ . 0 Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Wilmer Hoffman, 564 -4592 N/A Printed Name Sondra Stewman Tale Drilling Technologist 7 _ Prepared By Name/Number Signatu y Phone 564 - 4711 Date ` 3 oz-1/1 Sondra Stewman, 564 -4750 Form 10-404 evised 10/2010 3.31( bmit Original Only TREE = FMC • SAFETY N WELL ANGLE> 70° @ 11291''"'* WELLHEAD = FMC 04.-22A CHRON'& LINERS *** ORIG WELBORE NOT • ACTUATOR = BAKER C AL 1 SHOW, LOW CMT IN 9 -5/8" CSG*** KB. ELEV 60 I Li BF. ELEV = KOP= 2100' 1 1982' I- 4 - 1/2" HES X NIP, ID = 3.813" i 111 Max Angle = 98° @ 13685' 20" CONDUCTOR, 114' Datum MD = NA 91.5 #, H-40, Datum TVD = 8800' SS ID = 19.124" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72#, L -80 BTC, ID = 12.347" -1 2521' I 2 3776 3509 51 MMG DOME RK 16 12/02/10 I (TOP 2 JOINTS = 68 #, K =55, ID = 12.415") ' = 1 7215 5512 54 MMG SO RK 20 12/02/10 ' , 1 7296' H4 -1/2" HES X NIP, ID = 3.813" Minimum ID = 2.377" @ 11226' 3-1/2" X 2 -7/8" XO g I 7325'1-19-518" 7325'J-19-518" BKR S -3 PKR, ID = 3.875" I ' ' I 7360' 1 HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13CR - 80 VAMTOP, --I 7456' .0152 bpf, ID = 3.958" 7456' I- I4 -1/2" WLEG, ID = 4.00" I 'TOP OF4 -1/2" SCAB LNR 1- 7394' I . 7394' I 9 -5/8" X 7" C-2 ZXP LTP 19 -5/8" X 7" SM -6 -AT LTP w / LNR HGR, ID = 6.208" H 7553' I _ I w / BKR HMC LNR HGR, ID = 6.20" - 'TOG (08/04/94) I 7697' 7502' 1 - j 7" X 4-1/2" XO, ID = 3.93" I 9 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" H - 7700 I a. 9 -5/8" MILLOUT WINDOW (04 - 22A) 7700' - 7750' 7" LNR, 29 #, NT -80 XO TO 13CR NSCC, --I 10674' (-X X 0371 bpf, ID = 6.276" 10694' H4. BTT DEPLOY SLV, ID = 3.00" I 10715' - 3 - 1/2" OTIS X NIP, ID = 2.812" I 4 -1/2" SCAB LNR, 12.6 #, 13CR - 80 - 10745' I VAM TOP, .0152 bpf, ID = 3.958" 10760' H7" X 4 -1/2" UNIQUE OVERSHOT 1 I4 -1/2" TBG STUB (06/28/09) I-I - 10748 $ 1 10795' I--17" x 4 -1/2" BKR S -3 PKR, ID = 3.875" I 10857' H4 -1/2" HES X NIP, ID = 3.813" 1 I4 -1/2" TBG, 12.6 #, 13CR - 80, .0152 bpf, ID = 3.958" I--I_ 10869 1 10869' , - 1/2 „ _ WLEG, ID - 3.958 " I 10862' H ELMD TT LOGGED ? ? / ? ? / ?? I 13-1/2" LNR, 9.3 #, 13CR STL, .0087 bpf, ID = 2.992" H 11226' I 11226' H3-1/2" X 2 -7/8" XO, ID = 2.377" I 14-1/2" X 7" WHIPSTOCK (11/09/10) H 11274' 7" MILLOUT WINDOW (04 22AL1) 11278' - 11286' 7" X 4 -1/2" TM/ SS PKR & HANGER, ID = ?" - 1158T ! `i J I L ( ` ± ' - 2 - 718" COLLAR ` w/ PIN, ID = 2.377" 7" LNR, 29 #, 13CR - 80 NSCC, - 11684' 1 • J � c 5 .0371 bpf. ID = 6.276" P 41 ` I PBTD I . . ill?: , 4 -1/2" LNR, 12.6 #, L -80 NSCT, - 12460' 1--A--6 3 .3./( .0152 bpf, ID =-3.958" I C0 Ai* 12-7/8" LNR, 6.4 #, 13CR STL, .0058 bpf, ID = 2.441" 1-1 14199 Vii' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/02/85 ROW 35 PARTIAL COMPLETION 12/05/10 PJC DRLG DRAFT CORRECTIONS WELL: 04 -22A /AL1 01/26/86 WWI ORIGINAL COMPLETION 12/16/10 CSR/PJC PERF CORRECTIONS PERMIT No: 1940970 / 2101540 08/26/94 N28E SIDETRACK (04 - 22A) 12/16/10 MK/PJC FINAL DRLG CORRECTIONS API No: 50- 029 - 21454 -01 (60) 07/04/09 D14 RWO SEC 26, T11 N, R15E, 1089' FSL & 217' FWL 11/23/10 NORDIC 1 CTD SIDETRACK (04 22AL1) 12/02/10 JKC/PJC GLV C/O (12/2/10) BP Exploration (Alaska) • • 04 -22A • AL1 1 1 ►z. is 1 I PERFORATION SUMMARY REF LOG: MEM LEE CCL/ GR/ TNF/ TNN ON 11/19/10 ANGLE AT TOP PERF: WA Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE r 04 - 22A t i - 04 io 2 -7/8" 6 11300 - 11575 0 t4/48i43- 4 -1/2" 32 11676 - 11914 0 08/26/94 E irj • 4 -1/2" 32 11953 - 12032 0 08/26/94 4-1/2" 32 12070 - 12110 0 08/26/94 4 -1/2" 32 12120 - 12437 0 08/26/94 04 2" 6 11948 - 12148 0 11/21/10 2" 6 12328 - 12418 0 11/21/10 s 2" 6 12508 - 12718 0 11/21/10 2" 6 12868 - 13098 0 11/21/10 2" 6 14053 - 14191 0 11/21/10 Ali 1 NP ff3ov- ■ A l i iS75" 1 1 i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/02/85 ROW 35 PARTIAL COMPLETION 12/05/10 PJC DRLG DRAFT CORRECTIONS WELL: 04 -22A /AL1 01/26/86 WWI ORIGINAL COMPLETION 12/16/10 CSR/PJC PERF CORRECTIONS PERMIT No: 1940970 / 2101540 08/26/94 N28E SIDETRACK (04 - 22A) 1 12/16/10 MK/PJC FINAL DRLG CORRECTIONS API No: 50- 029 - 21454 -01 (60) 07/04/09 D14 RWO ( SEC 26, T11 N, R15E, 1089' FSL & 217' FWL 11/23/10 NORDIC 1 CTD SIDETRACK (04 12/02/10 JKC/PJC GLV /O (12/2/10) BP Exploration (Alaska) • • 04 -22AL1 V►►ell History (Pre Rig Lateral Leg) Date Summary 09/07/10 T /I /0= 200/1200/800 TEMP= HOT RG 2401 (SURFACE CASING CORR MITIGATION) PJSM. SET UP HYDRO VAC AND JOB SITE. START AND COMPLETE EXCAVATION ON WELL CELLAR. RDMO. VOID= 408 ", NEEDS TOP JOB. TOP PLATE, INSTALLED 2 PLUGS. 10/19/10 LRS FRZ PROTECTS TBG & FLOWLINE (see Irs log) DRIFT W/ 20'x 3.70" DMY WHIPSTOCK TO 7603' SLM (unable to work deeper). DRIFT W/ 3.50" CENT, SAMPLE BAILER TO DEVIATION © 11344' SLM (bailer empty). CURRENTLY RUNNING W/ CALIPER. 10/19/10 T /1/0 = 900/1300/400 Assist Slickline. Freeze Protect Tbg and Flowline. Pumped into the Tbg with 38 bbls of crude. Pumped into the Flowline with 5 bbls of neat methanol and 108 bbls of crude. DSO shut in IGV, left 1500 psi on the flowline. Final WHP's = 800/1500/220 Turned well over to Slicklilne. Slickline on the well at the time of departure. 10/20/10 ** *WSR CONT FROM 10/19/10 * ** (pre ctd) RAN PDS 40 ARM CALIPER FROM 11340' SLM TO SURFACE (incomplete data from -1800' slm to surface) RAN PDS 40 ARM CALIPER FROM 2100' SLM TO SURFACE (good data) SET X CATCHER SUB IN X -NIP © 7261' SLM/ 7296' MD PULLED ST# 1 RK -OGLV FROM 7191' SLM/ 7215' MD PULLED ST #2 RK -LGLV FROM 3752' SLM/ 3776' MD SET RK- DGLV IN ST# 2 © 3752' SLM/ 3776' MD LRS PUMPED 400 BBLS DOWN THE IA SET RK -DGLV IN ST# 1 037,191' SLM/ 7,215' MD * ** *JOB STILL IN PROGRESS, WSR CONTINUED ON 10/21/2010 * * ** 10/20/10 T /I /0= 1500/1440/20 Assist s -line Load & MIT IA to 3500 psi, MIT OA to 2000 psi (CTD) Load IA with 5 bbls neat meth & 400 bbls crude. Pump 65 bbls crude to reach test pressure. Could not pressure up IA above 1325 Psi. Shut Down / Standby for SL to RIH and Fluid support. WSR continued on 10- 21 -10. 10/21/10 T /I /0= 1500/1440/20 ( WSR continued from 10 -20 -10 ) Assist S -Line MITx IA Passed to 3500 Psi (CTD) Pumped 65 bbls dead crude down IA / IA and TBG communicating. IA reached 1900 Psi and TBG reach 3000 Psi. SLB reset DV. Pumped 12 bbls dead crude to achieve a test pressure of 3500 Psi. IA lost 140 Psi in 1st 15 min and lost 40 Psi in 2nd 15 Min for a total loss of 180 Psi in 30 Min test. FWHP's= 1850/500/20 S -line in control of well at dep. IA/OA =OTG 10/21/10 ** *WSR CONTINUED FROM 10/20/2010 * ** (pre ctd) RAN KOT AND RUNNING TOOL AND VERIFIED THAT ST #1 @ 7,215' MD WAS EMPTY. FISHED DROPPED RK -DGLV FROM X- CATCHER CO 7,261' SLM. SET RK -DGLV IN ST #1 Q 7,191' SLM (7,215' MD) LRS PERFORMED MIT -IA TO 3500 #. PASSED. PULLED EMPTY 4 -1/2" X- CATCHER FROM X NIP C© 7261' SLM (7296' MD) DRIFTED W/ 3.75" CENT & 3.00" S.BAILER TO DEVIATION C© 11,392 SLM. NO SAMPLE. DRIFTED W/ 3.70" x 20' DMY WHIPSTOCK TO DEVIATION @ 11,376' SLM. (NEEDED 11,270' MD) * ** WELL S/I ON DEPARTURE, PAD OP NOTIFIED * ** 10/22/10 T /I /0= 1780/0/0 Temp =SI PPPOT-T (PASS) (Pre CTD) PPPOT -T : RU 2 HP BT onto THA 50 psi bled to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 4950/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, cycle and torque LDS "ET style" all functioned with no problems. RD test equipment, re- installed Alemite caps. 10/22/10 T /I /O = 1780/360/20. Temp = SI. MIT -OA 2000 psi - PASSED (pre ctd). AL SI @ casing valve, ALP 1950 psi. Used 4 bbls of diesel to pressure OA from 0 psi to 2000 psi. IAP decreased 40 psi in 1st 15 min, and 20 psi in 2nd 15 min for a total loss of 60 psi in 30 min. Bled OAP from 1940 to 0+ psi in 1 hr. (3 bbls) Bled IAP from 410 to 0+ psi in 1 hr 30 min. Monitored for 30 min, IAP unchanged. Job complete. Final WHPs = 1780/0 + /0+ SV, WV = C. SSV, MV = 0. IA, OA = OTG. NOVP. 10/24/10 T /I /0= 1800/160/200 Performed leak tight test on swab, SSV, and master. All valves bled to 0 PSI. Torqued all studs on tree to specs. except THA X Master on this date.(see log). Pressure tested against swab 300 low /Pass 3500 high/ Pass SSV/Wing 300 low / Pass 3500 high/ Pass Master 2100 low /Pass 5000 high /Pass (See graph results in TRP folder.) Page 1 of 2 • • 04 -22AL1 Wall History (Pre Rig Lateral Leg) Date Summary 11/03/10 T /I /O= 1750/260/0 Load and Kill (CTD Prep) Pump 5 bbls meth and 270 bbls 1% KCL down TBG to load and kill. Freeze protected TBG with 40 bbls diesel. FWHPs= 0 +/340/0 Valve positions at time of departure: SV, WV, SSV, MV shut. IA, OA open. 11/04/10 T /I /O =0 +/460/140. Temp =SI. Bleed IA & OA to 0 psi. (pre -CTD). IA FL near surface. OA FL near surface. Bled IAP to 0 psi in 45 min (gas). Bled the OA to 0 psi in 30 min (gas). Monitor 30 min. IAP unchanged. OAP unchanged. Final WHPs= 0 +/0/0. Job complete. SV, WV, SSV =C. MV =O. IA &OA =OTG. NOVP 11/05/10 T /I /O = 225/0/0 Bled off SSV and Swab valve to verify barriers.(225 psi on tubing) Removed tree cap and installed lubricator with running tool and TWC. Tested lubricator to 300 psi low and 3500 psi high (passed) Set 4" CIW H TWC @ 114" w/ 1 -1' ext. Leak tight test on TWC failed. (rolled body seal on TWC) Removed and reinstalled lubricator with pulling tool. Tested lubricator to 300 psi low and 3500 psi high. (passed) Pulled 4" CIW H TWC. Removed lubricator and reinstalled with running tool and new TWC. Tested lubricator to 300 psi low and 3500 psi high. (passed) Set 4" CIW H TWC. Tested and charted TWC to 300 low and 3500 psi high (passed) Charted test results in TRP folder. Removed lubricator and installed tree cap. Torqued MV x THA flange to API specs. (see log for details) Shell tested tree to 5000 psi 5 min. (passed) Chart for this test in TRP folder. Drained fluid from tree through wing. Tree is 90% fluid packed. ** *job complete*** 11/07/10 T /I /0= 225/0/0; Barriers tested (passed); Tested Lubricator against SSV to 300 low and 3500 high for 5 min. (passed); Pulled 4- 1/16" CIW "H" TWC # 258 thru tree and stack for Nordic 1 post move on well and BOP test; 4 -5' exts. used, tagged © 96 "; No problems Page 2 of 2 • NQifh Am rlca ALASKA BP Page 1 of 11 p� rQn mr"�na �pQ� • Su Common Well Name: 04 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/5/2010 End Date: 11/16/2010 X3- 00W1L -C (1,835,667.00 ) Project: Prudhoe Bay Site: PB DS 04 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/17/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292145400 Active Datum: 31 : 22 8/4/1994 00:00 ©55.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/5/2010 00:00 - 04:30 4.50 MOB P PRE PREPPING RIG FOR RIG MOVE. STAGING TRAILERS FOR EQUIPMENT. WAITING ON REEL FROM SLB YARD. TRUCKING DELAYS DUE TO WEATHER, DRIFTING SNOW, HIGH WINDS. WEATHER IMPROVED SIGNIFICANTLY AFTER 0200 HOURS. 04:30 - 06:00 1.50 MOB P PRE PJSM ON SWAPPING OUT REELS. SWAP OUT REELS. WIND AT 8 -10 MPH, NO BLOWING SNOW. 06:00 - 12:00 6.00 MOB P PRE CONTINUE PREPPING RIG FOR RIG MOVE. DISCONNECT LINES FROM SATELLITE CAMP. OFFLOAD FRESH WATER. INSPECT HYDRAULICS AND MOVE SYSTEM. 12:00 - 00:00 12.00 MOB P PRE MOVE OFF OF K -11A AND BEGIN MOVE TO DS 04. CONDUCT PERIODIC CHECKS OF HYDRAULICS," TIRE PRESSURE. 11/6/2010 00:00 - 03:00 3.00 MOB P PRE RIG MOVE FROM K -11 TO DS-04. MOVE ONTO DS'04 -22. SPOTTED ON WELL, RIG ACCEPTAT_0300 HRS. 03:00 - 06:00 3.00 MOB P PRE BEGIN RU ON 04- 22AL1. RU 4 1/16" SPACER SPOOL FOR BOP SPACE OUT DUE TO TREE HEIGHT. MOBILIZE TIGER TANK, SATELLITE CAMP, CU1TINGSBOX, BLEED TRAILER, HEATERS TO DS 04. 06:00 - 08:40 2.67 MOB P PRE SWAP OUT LUBRICATOR FOR PROPER WORK FLOOR HEIGHT. RU HOT TUB. SECURE STACK. 08:40 - 16:00 7.33 BOPSUR P PRE FILL STACK WITH WATER. SHELL TEST BOPE, 250PSV3500PSI. PRESSURE TEST BOPE PER AOGCC REGS, 250PSV3500PSI. CHUCK SCHEVE WAIVED WITNESS TO TEST. TEST PASSED. 16:00 - 17:00 1.00 RIGU P PRE PU DERRICK SCOPING RAM & SECURE IN DERRICK 17:00 - 18:00 1.00 RIGU N RREP PRE CONTINUE TO INSTALL SCOPING RAM IN DERRICK. WORK ON BLIND SHEAR PANEL LIGHTS. 18:00 - 19:00 1.00 RIGU P PRE CHANGE OUT CREWS, CONDUCT PJSM ON RU CABLE BUNDLE, PU AND STAB INJECTOR HEAD. RU CABLE BUNDLE. MU INJECTOR TO WELL 19:00 - 22:30 3.50 RIGU P PRE PULL COIL INTO INJECTOR. DIFFICULTY WITH COIL MEMORY, GETTING COIL THROUGH ROLLERS. ADJUST ROLLERS AND GOOSENECK. COMPLETE PULLING COIL INTO INJECTOR. 22:30 - 00:00 1.50 RIGU P PRE PREPARE COIL FOR OPERATIONS. LUBRICATE ROLLERS. PRESSURE TEST TREE BODY AGAINST TWC TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. CLEAR AND CLEAN RIG FLOOR, CONTINUE PREPPING FOR PULLING TWC. 11/7/2010 100:00 - 00:30 0.50 RIGU P PRE PUMP METHANOL INTO COIL. FILL COIL WITH KCL. Printed 2/7/2011 3:46:32PM s>� Amerl�a A4�S P 1 G iperation Report Common Well Name: 04 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/5/2010 End Date: 11/16/2010 X3- 00W1L -C (1,835,667.00 ) Project: Prudhoe Bay Site: PB DS 04 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/17/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292145400 Active Datum: 31 : 22 8/4/1994 00:00 ©55.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 02:30 3.00 RIGU P PRE PJSM ON PULLING TWC. PRESSURE TEST LUBRICATOR AGAINST SSV TO 500 PSI LOW, 3500 PSI HIGH. PULL TWC. CONDUCT AAR WITH NORDIC AND DSM CREW ON JOB. MONITOR WELL. 150 PSI WHP. 02:30 - 03:45 1.25 RIGU P PRE PJSM ON BULLHEADING TO KILL WELL. STAGE PUMPS UP TO 5 BP ICP 150 PSI, FCP 204. IWHP 0 PSI (PUMPING AWAY), FWHP 57 PSI. 315 BBLS 8.4 PPG KCL FLUID PUMPED AWAY. IA 0 PSI, OA 0 PSI. 03:45 - 04:15 0.50 RIGU P PRE MONITOR WELL FOR 30 MINUTES. WELL ON VACUUM. SHUT IN MASTER & SWAB. 04:15 - 05:15 1.00 RIGU P PRE PU INJECTOR & STAB ONTO WELL. PRESSURE TEST INNER REEL VALVE AND PACKOFFS TO 250 LOW AND 3500 PSI HIGH PER AOGCC REGS PASS. BOP LIGHT PANEL IS WORKING (PRESSURE SWITCH). RETEST BLIND SHEAR RAMS 250PSV3500PSI - FAILED (FAILED DUE TO REPEATBLY FUNCTIONING THEM). 05:15 - 07:15 2.00 RIGU P PRE MAKE UP COIL CONNECTOR TO COIL. PULL TEST CTC TO 35K - GOOD. PRESSURE TEST CTC TO 4000PSI - GOOD. SIMULTANEOUSLY, LOTO KOOMEY UNIT, INSPECT & REPAIR BLIND RAMS. BOT REP BENCH TESTED CHECK VALVES 250PSV1500PSI - PASS. 07:15 - 08:00 0.75 BOPSUR P PRE PRESSURE TEST BLIND RAMS, 250PSV3500PSI PER AOGCC REGS - PASS. 08:00 - 08:50 0.83 PERF P WEXIT INSTALL NIGHT CAP. OPEN MASTER & SWAB. PUMP 2OBBLS OF 120K LSRV 8.6PPG PERF PILL TO HELP LOCK UP PERFS. FILL WELL ACROSS THE TOP WITH 8.4PPG SLICK 2 %KCL AT 6BPM AT 110PSI PUMP PRESSURE. AT 9OBBLS, CAUGHT PARTIAL RETURNS. CLOSE CHOKE & BULLHEAD REST AWAY, PUMP TOTAL OF 190BBLS. MAX WHP OF 350PSI. 08:50 - 09:00 0.17 PERF P WEXIT FLOW CHACK WELL - HEAVY VAC. 09:00 - 09:10 0.17 PERF P WEXIT PLACE 1JT OF 2 -3/8" PH6 TUBING IN WELL. PU INJECTOR & MU TO PH6 TUBING. STAB ONTO WELL. 09:10 - 09:30 0.33 PERF P WEXIT PUMP SLACK OUT OF WELL. CIRCULATE 3BPM/2000PSI, PUMPED 4OBBLS, FLUID LOSS RATE — 4.5BPM. 09:30 - 09:50 0.33 PERF P WEXIT POP OFF WELL. STAND BACK INJECTOR OVER BUNG & BREAK CIRCULATION. LD 2 -3/8" PI-16 TUBING. INSTALL NITE CAP - STARTING TO BUILD PRESSURE, 1 HR SWAP OUT TIME FROM LOSS TO GAIN. SHUT IN MASTER, WAIT FOR FLUID & BETTER PAD PREP FOR VAC TRUCKS ON DRILLERS SIDE OF RIG. 09:50 - 10:15 0.42 PERF P WEXIT CUT OFF 274FT OF E -LINE. BOOT E -LINE. PU INJECTOR & MU NOZZLE. STAB ONTO WELL. 10:15 - 11:10 0.92 PERF P WEXIT CIRCULATE 3/4" DRIFT BALL INTO REEL USING 8.3PPG 2% KCL AT 2.9BPMR80PS1. 11:10 - 11:20 0.17 PERF P WEXIT POP OFF WELL. RECOVERED 3/4" DRIFT BALL. STAB ONTO WELL WITH INJCETOR. Printed 2/7/2011 3:46:32PM Ofth ArT1 rIC8 ALASKA BP Page 3 of 11 )peration Summary Report Common Well Name: 04 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/5/2010 End Date: 11/16/2010 X3- 00W1L -C (1,835,667.00 ) Project: Prudhoe Bay Site: PB DS 04 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/17/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292145400 Active Datum: 31 : 22 8/4/1994 00:00 ©55.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:20 - 11:55 0.58 PERF P WEXIT KILL WELL WITH 200BBLS OF 2% KCL AT 3BPM DOWN COIL - 817PSI CTP & 3BPM DOWN BACKSIDE - 579PSI WHP. SIMULTEANEOUSLY, HOLD PJSM FOR PU LOGGING BHA & ADJUST SLB GOOSENECK. 11:55 - 12:15 0.33 PERF P WEXIT FLOW CHECK - VAC. POP OFF WELL & STAND BACK INJECTOR. THIS TIME FLUID WAS AT SURFACE BUT FLUID LEVEL FELL FAST. 12:15 - 12:45 0.50 PERF P WEXIT MU LOGGING BHA. CTC, XO, SWIVEL, XO, 4 JTS OF 2 -3/8" PH6 TUBING, XO, CHECK VALVE,. DISCO 3/4" BALL, XO, SLB MEM, NOZZLE. PU INJECTOR & MU TO BHA. STAB ONTO WELL. 12:45 - 15:30 2.75 PERF P WEXIT RIHWITH LOGGING BHA. CIRC 8.4PPG 2% KCL AT 4BPM DOWN`BACKSIDE. RETURNS AT 75BBLSAWAY, LOSS RATE OF — 2.5BPM. WT CK AT5100FT,1 OK PUW, 7K RIW. WT CK AT-= 10000FT, 34K PUW, 14K RIW. SET DOWN AT 11665FT: 15:30 - 17:05 1.58 PERF P WEXIT LOG UP AT 45FT /MIN, PUW = 40K. CONTINUE TO CIRCULATE AT 4BPMI33PSI WHP — 2.5BPM LOSS RATE. PAINT YELLOW FLAG AT 10500FT. CONTINUE TO LOG UP, PUW = 37K. STOP LOGGING AT 10300FT. 17:05 - 18:45 1.67 PERF P ` WEXIT POH, PUW = 38K. BULLHEAD USED 8.6PPG QUICKDRIL -N FLUID INTO WELL AT 4BPM/480PSI WHP, MAX WHP 640PSI. STOP & FILL PITS WITH USED DRILLING MUD. 0.2BPM LOSS RATE. CONTINUE TO POH. 18:45 - 19:15 0.50 PERF P WEXIT MONITOR WELL. CALCULATE 30 BPH LOSS RATE. FILL HOLE. CONTINUE TO POH. 19:15 - 20:15 1.00 PERF P WEXIT BREAK OFF INJECTOR FROM WELL. FILL HOLE. LD LOGGING BHA. DISPLACE KCL FROM COIL WITH 8.6 PPG. 20:15 - 21:45 1.50 PERF P WEXIT PJSM ON BRINGING GUNS TO PIPE SHED. MOBILIZE GUNS INTO SHED. CLEAR AND CLEAN FLOOR TO RUN GUNS. 21:45 - 22:15 0.50 PERF P WEXIT PJSM ON MU OF PEFORATING GUNS, HANDLING GUNS, CONTINGENCY FOR WELL CONTROL WITH PERF GUNS IN TABLE. 22:15 - 23:30 1.25 PERF P WEXIT MU 2 7/8" PERF ASSEMBLY. CONDUCT UNANNOUNCED KICK DRILL WITH PERF GUNS IN TABLE. CREW RESPONSE TIME 2 MIN 30 SEC. CONDUCT AAR AFTER DRILL. RESUME MU OF PERF ASSEMBLY. 23:30 - 00:00 0.50 PERF P WEXIT MU TWO JOINTS OF PH6 TO PERF ASSEMBLY. MONITORING WELL, KEEPING HOLE FULL WITH CHARGE PUMP. 11/8/2010 00:00 - 01:15 1.25 PERF P WEXIT COMPLETE MAKING UP 2 7/8" PERFORATION BHA. KEEPING HOLE FULL WITH CHARGE PUMP. 20 BPH LOSS RATE. 01:15 - 04:15 3.00 PERF P WEXIT _RIH WITH PERF ASSEMBLY. MAINTAINING 30 BPH LOSS RATE. STOP COIL AT FLAG AT 10,351'. CORRECT EOP TO 10,784'. MONITOR WELL FOR 30 MINUTES WHILE FILLING PITS BEFORE PERF JOB. CONTINUE TO RIH TO 11,585'. CONFIRM DEPTH. PUMP 5/8" BALL DOWN COIL AT 1.9 BPM, 1633 PSI. LOSSES STILL AVERAGING 25 -30 BPI-I. Printed 2/7/2011 3:46:32PM •O Pf1I8rICB AL B Pr Psge 4 of 1 Aeration Sum ,Report Common Well Name: 04 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/5/2010 End Date: 11/16/2010 X3- 00W1L -C (1,835,667.00 ) Project: Prudhoe Bay Site: PB DS 04 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/17/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292145400 Active Datum: 31 : 22 8/4/1994 00:00 @55.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:15 - 06:00 1.75 PERF P WEXIT PU STRING TO 11,580'. ATTEMPT TO PUMP BALL ON SEAT. PUMP 88 BBLS AT 1.5 BPM, 1164 PSI WITHOUT SEATING. DROP SECOND 5/8" BALL. PUMP THROUGH COIL AT 2.4 BPM, 1900 PSI UNTIL CLEAR OF GOOSENECK. PUMPING BALL DOWN TO SEAT AS OF 0600 HRS. 06:05 - 06:10 0.08 PERF P WEXIT PERFORATE WELL DRIVE BY STYLE FROM 11300FT- 1.1575FT USING 2.88" 6SPF 2906PJ OMEGA PERF GUNS . GOOD INDICATION OF FIRING. 06:10 - 09:15 3.08 PERF P WEXIT SLOWLY POH PUMPING 1.5BPM/1400PSI. LOST 17BBLS ON TRIP OOH. UPON 100FT FROM TAGGING :SURFACE, LOST OUT MICRO MOTION & HAD GAS ALARM. DIVERT TO TIER TANK. STOP MOVING COIL. FILL HOLE, SLIGHT- LOSSES, 1 :5BPM/1200PSI DOWN COIL & 1.37BPM "RETURN RATE — 3BBLS TO FILL HOLE. CBU - NOTHING INTERESTING. STOP & MONITOR WELL. 09:15 - 09:30 0.25 PERF P WEXIT FLOW CHECK - NO FLOW. 09:30 - 09:45 0.25 PERF P WEXIT "" FILL HOLE, 1.5BPM DOWN COIL & 1.37BPM RETURNS RATE — 3BBLS TO FILL HOLE CBU - SLIGHT BURP OF GAS THAT SMELLS LIKE GUN POWDER. NOTIFY TOWN ENGINEER OF PLAN FORWARD. 09:45 - 10:15 0.50 PERF P WEXIT RIH FROM 500FT, CIRCULATE 1.51BPM DOWN COIL AT 1245PSI, 0.15BPM LOSS RATE WHILE RIH. 8BBLS LOSS ON TRIP IN HOLE. 10:15 - 10:50 0.58 PERF P WEXIT STOP AT 3000FT & CBU 1.5 VOLUMES, 1.5BPM/1260PSI DOWN THE COIL, 1.45BPM OUT. STONG ODOR OF PERF GUN MATERIAL. LOST 3BBLS WHILE CBU. 10:50 - 11:05 0.25 PERF P WEXIT FLOW CHECK - NO FLOW. 2BBLS TO FILL HOLE. 11:05 - 11:50 0.75 PERF P WEXIT POH FROM 3000FT. CIRCULATE 1.6BPM/1260PSI. LOST 1 BBL ON TRIP OOH. 11:50 - 12:10 0.33 PERF P WEXIT FLOW CHECK WELL - NO FLOW. PJSM REGARDING LD PERF BHA/GUNS. 12:10 - 13:10 1.00 PERF P WEXIT POP OFF WELL. CUT OFF 67FT ORE -LINE. PLACE INJECTOR OVER BUNG HOLE. TEST E -LINE- GOOD. BOOT E -LINE. RU 250T FLAT TOP ELEVATORS. LD 4 JTS OF 2 -3/8" PH6 TUBING. RU SAFETY JT. LD FIRING HEAD, RECOVER TWO BALLS. FILL HOLE WITH C -PUMP — 8- 10BBLS/HR LOSS RATE. 13:10 - 13:20 0.17 PERF P WEXIT RU FARR TONGS. 13:20 - 14:45 1.42 PERF P WEXIT LD PERF GUNS. ALL SHOTS FIRED. 14:45 - 16:00 1.25 CLEAN P WEXIT FILL HOLE — 2BBLS. INSTALL NIGHT CAP. RD FARR TONGS. RD 250T ELEVATORS. RD SAFETY JT. CLEAN RF. LOWER DOWN PERF GUN HANDLING EQUIPMENT. BENCH TEST CHECK VALVES, 250PSV3500PSI - GOOD TEST. 16:00 - 16:10 0.17 CLEAN P WEXIT PJSM REGARDING MU WS DRIFT BHA. Printed 2/7/2011 3:46:32PM rfh America ALASKA B? age OL I 1 aeration Summary Report Common Well Name: 04 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/5/2010 End Date: 11/16/2010 X3- 00WIL -C (1,835,667.00 ) Project: Prudhoe Bay Site: PB DS 04 Rig Name /No.: NORDIC 1 Spud Date/Time: 10/17/1985 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292145400 Active Datum: 31 : 22 8/4/1994 00:00 ©55.60ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:10 - 17:00 0.83 CLEAN P WEXIT MU WS DRIFT BHA- CTC, XO, SWIVEL, XO, 4JTS OF 2 -3/8" PH6 TUBING (ALL DRIFTED), XO, CHECK VALVES, DISCO 3/4" BALL, DUMMY WS DRIFT. PU INJECTOR & MU TO BHA. STAB ONTO WELL. 17:00 - 17:20 0.33 CLEAN P WEXIT FILL HOLE WHILE FILLING PITS. 2.5BBLS TO FILL HOLE. 17:20 - 19:30 2.17 CLEAN P WEXIT RIH WITH DUMMY WHIPSTOCK BHA, CIRCULATE 8.5PPG USED /NEW QUICK DRILL -N MUD AT 0.8BPM/920PSI. 19:30 - 20:15 0.75 CLEAN P WEXIT COMPLETE DRIFT TO 11,350' WITH NO PROBLEMS NOTED. MONITOR WELL, NO FLOW. AVERAGE OF 9 BPH LOSSES DURING DRIFT DOWN. 20:15 - 23:30 3.25 CLEAN P WEXIT POH AT 1.6 BPM WITH 1.1 BPM RETURNS. CALUCALATED LOSS - RATE OF .25 -.4 BPM WHILE.POH STOP AT 10,000', 5,000', AND 2,000' TO MONITOR WELL. NO FLOW, SLIGHT LOSS. FLOW CHECK AT SURFACE WITH .6 BPM LOSS RATE, NO FLOW. 23:30 - 00:00 0.50 CLEAN P. WEXIT. DRIFT BHA AT SURFACE. CONDUCT KICK DRILL WHILE LAYING DOWN BHA. VERY GOOD CREW RESPONSE. CONDUCT AAR. POSITIVES: REACTION BY NEW MEMBER, COMMUNICATION. TO IMPROVE: SLAM VALVE CLOSED FASTER INSTEAD OF SLOW. 22 BBLS 8.6 PPG QUIKDRILL MUD LOST TO FORMATION DURING DRIFT RUN. 11/9/2010 00:00 - 00:30 0.50 CLEAN P WEXIT COMPLETE LAYING DOWN DRIFT BHA. CLEAR AND CLEAN RIG FLOOR. 00:30 - 05:56 5.43 STWHIP P WEXIT PUMP BACK SLACK INTO ELINE. CONDUCT COIL MAINTENANCE (CUT 330' COIL). PUMP ELINE FORWARD. MAKE UP CTC TO COIL. 05:56 - 06:00 0.07 STWHIP P WEXIT MOBILIZE WHIPSTOCK MATERIALS TO PIPE SHED, RIG FLOOR. PJSM ON RUNNING WHIPSTOCK. 06:00 - 06:23 0.38 STWHIP P WEXIT STAB ONTO WELL. PUMP 1 COIL VOLUME FORWARD TO COMPLETE SLACK MANAGEMENT. 6BBLS TO FILL HOLE. 06:23 - 08:10 1.78 STWHIP P WEXIT POP OFF WELL & STAND BACK INJECTOR. HOIST WS & SETTING TOOLS TO RF. MU WS TO SETTING TOOLS, SCRIBE SAME. PU COIL TRACK TOOLS & MU TO WS SETTING TOOL & WS. PU INJECTOR & MU TO BHA. STAB ONTO WELL. POWER UP & TEST TOOLS. 08:10 - 08:35 0.42 STWHIP P WEXIT FILL HOLE,10BBLS TO FILL HOLE. RIH WITH WS BHA, CIRC THROUGH EDC AT 1.4BPM/1000PSI. STOP AT 1200FT. 08:35 - 09:00 0.42 STWHIP N DFAL 1,200.00 WEXIT POH FOR TOOL FAILURE. 09:00 - 10:15 1.25 STWHIP N DFAL 1,200.00 WEXIT POP OFF WELL, FILL HOLE. CHECK JUCTION BOX - OK. REMOVE UQC. FLOW SUB FAILED. REPLACE E -LINE BOOT. WIRE TESTED OK. MU COIL TO BHA. STAB ONTO WELL. POWER UP & TEST TOOLS. FILL HOLE - 2BBLS. 10:15 - 12:55 2.67 STWHIP N WEXIT RIH, CIRC THROUGH EDC AT 1.4BPM /1000PSI. 12:55 - 13:50 0.92 STWHIP P WEXIT LOG TIE -IN. CORRECT -4'. LOG CCL INTERVAL FROM 11250' TO 11050'. REPEAT PASSES AND SEND LOG DATA TO TOWN. POOR CCL QUALITY. Printed 2/7/2011 3:46:32PM STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMIV~ION REPORT OF SUNDRY WELL OPERATIONS ..~~if~l ~~~~~~~C.~~''~ ~1J~ a~ ~ ZQ~~ 1. Operations PerFormed: -~ia~~a i7;, ~ ~~~ ~~~$ ~~~m ^ Abandon ~ Repair Well , ^ Plug Perforations ^ Stimulate ^ Re-Enter S~ ed Well ~ ~~~~ . ~. E~~ ~ Alter Casing ~ Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 194-097 - 3. Address: , ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21454-01-00~ 7. KB Elevation (ft): 55 6' - 9• ~Nell Name and Number: . PBU 04-22A - 8. Property Designation: . 10. Field / Pool(s): ADL 028324, 028322 & 028323 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 12460' - feet true vertical 8696'~ feet Plugs (measured) None Effective depth: measured 12460' feet Junk (measured) None true vertical 8696' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 20" 114' 114' 149Q 470 Surface 2521' 13-3/8" 2521' 2498' 3450 1950 Intermediate 7700' 9-5/8" 7700' S797' 6870 4760 Production liner 4131' 7" 7553' - 11684' 5712' - 8737' 8160 7020 Liner 873' 4-1/2" 11587' - 12460' 8734' - 8696' 8430 7500 Scab Liner 3401' 4-1/2" 7394' - 10760' 5618' - 8387' 8430 7500 Perforation Depth MD (ft): siotted sectio~: ~ ~s~s' - 1243T -~~ ~ r r, , ~~i:: ~t t i ~~:'~'~~" .., ,._ ~: , _ .. Perforation Depth TVD (ft): 8736' - 8698' 4-1/2", 12.6# 13Cr80 7456' & Tubing Size (size, grade, and measured depth): ~0748' - ~0869' Packers and SSSV (type and measured depth): 9'5/8" x 4-1/2" Baker'S-3' packer 7325' 7" x 4- 1/2" Baker'SABL-3' packer 10795' 12. Stimulation or cement squeeze summary: Interoals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 10748'. Run 4-1/2" (12.6#,13Cr-80 / L-80, BTC-M) scab liner. Cement w/ 73 bbls Class'G' w/ Gas-Blok, 1.16 Yield 410 cu ft/ 353 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram -~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt: Contact David Bjork, 564-5683 309-157 Printed Name Sondra Stewman Titfe Drilling Technologist ~ Prepared By Name/Number: gnature Phone 564-5743 Date(~~' p°O Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ ~~ A`~G 1 i 2Q0~ Submit Original Only ~'~6 ~ ~i ~ ~' '/ 1 l-'~ ~'~' ~ ' ~!` 3SIt1ti TREE = CNV WELLHEAD = FMC P~CTUATOR = BAKER C KB. ELEV = 56' BF. E1EV = KOP = 2100' Max Angle = 96° @ 11937' batum Datum MD = NA 20" COND, ND = 8800' SS 91.5#, H-40, ID = 19.124" 13-3/8" CSG, 72#, L-80 BTC, ~ ID = 12.347" 2521' ~ 04-22A ? Minimum ID = 3.00" @ 12110' 4-1/2" TIW NO-GO SUB 4-112" TBG, 12.6#, 13CR-80 VAM TOP, --~ 7 .0152 bpf, ID = 3.958" TOP OF 7" LNR ~-~ 7553' TOC (08/04/94 9-5/8" BRIDGE PLUG (O8/02/94) S~TES: **'`CHROME TBG & LNR*** WELL GLE> 70° @ 11376' 1982~ I~a-~~2" HES X NIP, ID = 3.813" ~ GAS LIFT MANDRELS ST MD TV D DEV N PE V LV LATCH PORT DATE 2 1 3776 7215 3509 5512 51 54 MMG MMG DOME SO RK RK 16 20 07J07/09 07/07/09 7296~ 4-1/2" HES X NIP, ID = 3.813" 7325~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 7360~ 4-1/2" HES X NIP, ID = 3.813" 7456~ 4-1/2" WLEG, ID = 4.00" 7394~ 9-5/8" X 7" G2 ZXP L1P w! HMC LNR HGR, ID = 6.20" 7502' 7" X 4-1/2" XO, ID = 3.93" ~ 9-5/8" CSG, 47#, L-80, Id = 8.681" ~ 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" ~--~ 10745~ 4-1/2" TBG STUB (06/28/09) ~-{ 10748~ I4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" ~ PERFORATION SUMMARY REF LOG: tJ/R ANGLE AT TOP PERF: 88° @ 11676' Note : Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1 /2" 32 11676 - 11914 SLTD 08/26l94 4-1/2" 32 11953 - 12032 SLTD 08/26/94 4-112" 32 12070 - 12110 SLTD 08/26/94 4-1/2" 32 12120 - 12437 SLTD O8/26/94 TOP OF 11587' 4-1/2" LNR ~ i ~ 7" LNR, 29#, NT-80/13CR, ID = 6.276" 11684~ ~ i 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ ~~«~~ J MILLOUT WINDOW 7700' - 7750' ~ 0760~ ~-17" X 4-1/2" UNIQUE OVERSHOT 10795~ -{7" x 4-1/2" BKR SABL-3 PKR, I I ID = 3.875„ 10857~ 4-1/2" HES X NIP, ID = 3.813" 10869~ 4-1/2" WLEG, ID = 3.958" 10862~ ELMD Tf LOGGED ??/??/?? 11587~ 7" X 4-1/2" TIW SS HA PKR ; 11635' 4-1/2" PORTm PUP (41.50') ' 11914~ 4-1/2" TNV MLAS ASSY XO , COMPOSITE JT PORTAL SUB ~ AT 11920', ID = 3.871" ~ 12032~ 4-1l2"TNV MLAS ASSY XO COMPOSffE JT PORTAI SUB ~ AT 11938', ID = 3.871" ~ 12110~ 4-1/2" TNV NO-GO SUB ID = 3.0" DATE REV BY COMMENTS DATE REV BY COMMEMS 01/26/86 ORIGINAL COMPLETION 08/26/94 N28E SIDETRACK(04-22A) 07/04/09 D14 RWO 07/23/09 DB/JMD DRLG DRAFf CORRECTIONS PRUDHOE BAY UNff WELL: 04-22A PERMff No: 1940970 API No: 50-029-21454-01 SEC 26, T11 N, R15E, 1089' FSL & 217' FWL BP F~cploration (Alaska) ~ ~ ' BP EXPLQRATf 4N Page 1 of 1~ Operatians Summary Repc~rt Legal Well Name: 04-22 Common Weil Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: , Date From - To Hours Task Code NPT Phase ' Description Qf Operations 6/22/2009 12:00 - 16:00 4.00 RIGD P PRE Prep Rig floor for skidding. Clean out drip pans. -Remove links in conveyor #2. 16:00 - 17:00 1.00 RIGD P PRE PJSM. -Skid Rig floor into moving position. 17:00 - 20:00 3.00 MOB P PRE Resurface Iron Roughneck rail. -Remove front stairs. Remove Cellar doors. -Move Rock Washer, Slop tank & Enviro Vac. -Build gravel ramp for Rig. 20:00 - 22:00 2.00 MOB P PRE PJSM. -Move Rig off of Well. Stage on Pad. 22:00 - 00:00 2.00 MOB P PRE Wait on Boosters from Rig # 16. -Clean up around well. -Adjust Skate pull back cable. -Review Post-Jarring inspection procedure. -Remove hydraulic lines from Stack. 6/23/2009 00:00 - 12:00 12.00 MOB P PRE Rig down. Prep moving system for move. -Prepare for Star Wars and Boosters. -Clean Rig. Remove BOP Stack from Cellar. -Complete rubber hose inspection. -Wait on Boosters from Doyon Rig # 16. 12:00 - 13:00 1.00 MOB P PRE Install Fast line cover. -C/O check valve on #1 charge pump suction line. -Repair weather stripping on ODS stairway. 16:30 - 18:00 1.50 MOB P PRE Attach front Booster bracing. -Attach front Boosters. 18:00 - 19:00 1.00 MOB P PRE Set BOP Stack on cradle & secure. Move Rig over Stack. 19:00 - 20:00 1.00 MOB P PRE Attach rear Boosters. 20:00 - 21:00 1.00 MOB P PRE Move Rig around corner next to 9ES. 21:00 - 21:30 0.50 MOB P PRE Lay Mats around front of 9ES. 21:30 - 22:00 0.50 MOB P PRE Move around 9ES to DS # 13 access road. 22:00 - 23:00 1.00 MOB P PRE Lay Mats on road & around guard shack. 23:00 - 00:00 1.00 MOB P PRE Move Rig from DS # 13 to West guard shack 6/24/2009 00:00 - 03:00 3.00 MOB P PRE Move Rig from West guard shack to Oxbow road. 0:00 - 04:00 1.00 MOB P PRE Travel across Oxbow road. 04:00 - 12:00 8.00 MOB P PRE Turn right onto West Dock road and travel to PBOC. -Travel PBOC to Endicott "Y". 12:00 - 14:00 2.00 MOB P PRE Travel from Endicott "Y" to DS # 4. 14:00 - 15:30 1.50 MOB P PRE Remove rear Boosters. PU Stack. -Drive up on Mats. PU Mouse hole & hang Cellar doors. 15:30 - 16:30 1.00 MOB P PRE Position Rig over well & shim in place. -T/I/O = 0/0/0 16:30 - 17:30 1.00 RIGU P PRE PJSM on Skid Rig floor. -Skid floor into drilling position. 17:30 - 19:00 1.50 RIGU P PRE Hook up lines under Rig floor. -E~end conveyor # 2. ~ - Bring on290 bbis of 9.8 ppg NaCI brine into Pits. 19:00 - 00:00 I 5.001 RIGU I P PRE Spot & berm Rock washer. Spot Slop tank. -Hook up lines on BOP Stack. -InstaA double valve on IA and 1502 flange on Wing valve. -Hook up lines to circulate out freeze protection. Printed: 7/16/2009 4:49:17 PM • ~ BP EXPLQRATIfJN Page 2 of 1 Q Operafions Summary R~port Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: Date: From - To Hours Task Gode NPT Phase Description of Operations 6/24/2009 19:00 - 00:00 5.00 RIGU P PRE -Test lines to 3000 psi - Pass. 6/25/2009 00:00 - 01:30 1.50 RIGU P PRE Finish blowing down lines. -PU XO's. MU Floor valve. -PU Wear ring running TooL -Hook up lines to the Rock washer. 01:30 - 02:30 1.00 WHSUR P DECOMP PJSM w/ DSM on PU Lubricator. -PU Lubricator and test to 500 psi on chart - Pass. -Pump open BPV to confirm no pressure under BPV. - u . R Lubricator. 02:30 - 05:00 2.50 WHSUR P DECOMP PJSM on circulating out freeze protection. -Pump 20 bbls of 9.8 ppg NaCI down Annulus 84 gpm / 280 psi. -Blow down lines. RU to circulate down Tbg. -Pump 40 bbls of 9.8 ppg NaCI down Tbg. -Let migrate for 30 minutes. -Pump an additional 20 bbls down Tbg to clean up. -Blow down lines. RD circulating equipment. 05:00 - 06:30 1.50 WHSUR P DECOMP Set ISA BPV. -.,` -Test from below to 1000 psi. - -Keep pumps rolling C~ 84 gpm to keep PSI C~ 1000 psi. -Pumped away 26 bbls. 06:30 - 07:00 0.50 WHSUR P DECOMP Allow well to bleed back. 07:00 - 12:00 5.00 WHSUR P DECOMP ND Tree and Ada tor flan e. -NU: 11" X 13 5/8" XO Spool, 18" Spacer Spool. -NU: 13 5/8" 5M BOP Stack, Turn buckles, Riser & Flow line. Calibrate and test Rig Gas alarms. 12:00 - 13:00 1.00 WHSUR P DECOMP Install Flow line covers in Drip pan. 13:00 - 15:30 2.50 WHSUR P DECOMP RU to test BOP's. 15:30 - 22:30 7.00 WHSUR P DECOMP Test BOP's Choke & associated valves: 29 components. ---BOP Configuration: p -Hydril GK 13 5/8" 5000. ~ -3 1/2" X 6" Variables. -Blind Rams. ~Z -Drilling Spool. -2 7/8" X 5" Variables. ~ -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. `~ -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Hydril to 250 low psi, 3500 high psi. -Test Hydril with 4 1/2" & 2 7/8" test Jts. -Test all valves w/ 4 1/2" test Jt. -Test lower Rams w/ 4 1/2" & 2 7/8" test Jts. -Test 250 low psi & 3,500 psi High psi. -Hold each test for 5 charted minutes. All test Pass. Note: 28 seconds for 200 psi build up 164 seconds for full PSI 4 bottles X 2200 psi. -Test witnessed by T.P. & WSL. -Test witness waived by Jeff Jones AOGCC. Printed: 7/16/2009 4:49:17 PM ~ • BP EXPLORATION Operations Summary Report Legal Well Name: 04-22 Common Well Name: 04-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 i : ~ f i ~ 6/25/2009 15:30 - 22:30 7.00 WHSUR P 22:30 - 23:00 0.50 WHSUR P 23:00 - 00:00 1.00 WHSUR P 6/26/2009 00:00 - 02:00 2.00 WHSUR P 02:00 - 02:30 0.50 WHSUR P 02:30 - 04:00 1.50 PULL P 04:00 - 10:00 I 6.001 PULL I N 10:00 - 10:30 I 0.501 PULL ~ N 10:30 - 11:30 1.00 PULL N 11:30 - 12:30 1.00 PULL N 12:30 - 14:30 2.00 PULL N 14:30 - 16:00 1.50 PULL N 16:00 - 16:30 0.50 PULL N 16:30 - 18:00 I 1.501 PULL I N 18:00 - 23:00 I 5.001 PULL I N 23:00 - 00:00 I 1.001 PULL I N Start: 6/19/2009 Rig Release: 7/4/2009 Rig Number: , Spud Date: 10/17/1985 End: DECOMP DECOMP LD Test Jt. RD test equipment. DECOMP RU & pull Blanking plug. DECOMP RU Dutch system & DSM Lubricator. -Test Lubricator to 500 si / 5 minutes - Pass. -Pull ISA BPV. -LD DSM Lubricator. RD Dutch system. DECOMP Hang Bales and Elevators. DECOMP RU XO's & 1 Jt of 4" DP, screw into Tbg hanger. -PU Tbg hanger broke loose ~ 185k. -Staged up to 320k in 5k increments. Slack off to 150k. -Pulled up to 320k & turned pumps on. -Returns noted after 30 bbls. Pumped 386 gpm / 470 psi. -Slack off to 150k. PU to 300k, slack off to 280k. -Continue to circulate 386 gpm / 530 psi. Engineer was contacted: -Decision to continue workinq pipe with circulation. t r t. DPRB DECOMP Wait on E-line unit. -Continue to circulate 540 gpm / 920 psi. -Work pipe up to 290k maximum (80% yield). DPRB DECOMP Land hanger in wellhead. -RILDS. -B.O. landing jt. - LD same. DPRB DECOMP RU Dutch system lubricator extension. -RU on IA w/ gauge and injection line. DPRB DECOMP Spot E line unit. -PJSM w/ all involved. -PU & hang sheaves. -Mobilize wireline pressure equipment to rig floor. -Fluid loss for tour 95 bbls. DPRB DECOMP RU: Pump in sub. Wireline BOP's . -Quick disconnect test sub. Lubricator & Grease head. DPRB DECOMP PU wireline tools. -CCL, ERS, Shock sub, Firing head. DPRB DECOMP Fill lubricator w/ fluid. -Test all components to 500 psi f/ 5 min on chart - Pass. -Bleed pressure. RD test equipment. DPRB DECOMP PJSM on Jet cutter. Break test sub. -Test fire cutter. -PU 3.5"Jet cutter. DECOMP RIH w/ Jet cutter to 10 806' md. Lost abilit to correlate C~ 9 000' md. -Make several attempts up and down to tie-in. -Can not locate collars. -PON w/ cutter. DECOMP PJSM on LD Jet cutter. -Break SLB Tools at quick test sub. -Pull e~ension up. -Disarm Jet cutter. Test Tools. Printed: 7/16/2009 4:49:17 PM • ~ BP EXPLURATIONi Page 4 of 10 ' Operations Summary Report Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Gode NPT Phase Deseription of Operations 6/26/2009 23:00 - 00:00 1.00 PULL N DECOMP Fluid loss for tour 16 bbls. Total daily brine loss = 111 bbls. Total dail losses = 111 bbls. 6/27/2009 00:00 - 04:30 4.50 PULL N DPRB DECOMP Run diagnostics on Wireline Tools. -Found a short in the R.S. due to a wet connection. -C/O Tools, Rehead tool. Install new O-rings throughout Tool. -~ 03:00 held a PJSM to Arm & run Jet cutter. -Stab into wellhead. 04:30 - 06:30 2.00 PULL N DPRB DECOMP RIH w/ Jet cutter & taq FasDrill pluq at 10,820' md. ' -Log up and observe top of first full jt at 10,738' md WLM. -Observe first 'et cut at 10 748' md WLM. -Continue log up to 10,500' md. -RIH and tag FasDrill at 10,820' md. -Log up and spot Power jet cutter at 10,754' md. -(CCL at 10,742.5' md). 06:30 - 08:00 1.50 PULL N DECOMP Fire jet cutter at 10,754' md. -Good indication of firing. -Log up to 10,490' md. -POH w/ SLB E-line. 08:00 - 09:00 1.00 PULL N DECOMP PJSM on LD Jet cutter and RD pressure control. -LD cutter (fired). -RD SWS equipment and "Dutch system". 09:00 - 10:30 1.50 PULL P DECOMP PU 1 jt 4' DP w/ 9" LH ACME XO. -Engage hanger at wellhead - Confirm no pressure on IA. -BOLDS. -Pull hanger free w/ 180k. -Pull tubing - 10-12' free travel at 200k. -Pulling tight w/ 250k. -Engage pumps and fill hole w/ 26 bbls. -Circulate w/ 368 gpm / 400 psi. -Pull tubinq to floor w/ 185k. 10:30 - 12:00 1.50 PULL P DECOMP Continue to circulate w/ 368 gpm / 400 psi. -While circulating, RU tubing tongs and control line spool. -Sand and crude observed at bottoms up. Losses for this tour = 56 bbls 12:00 - 12:30 0.50 PULL P DECOMP Continue to circulate. -While circualting, Inspect & service Top Drive & Drawworks. -Circulate a total of 1 1/2 BU. 12:30 - 13:00 0.50 PULL P DECOMP PJSM on laying down Tbg. -LD 4" DP & XO. LD tubing hanger. -Change elevators to 4 1/2". -Well out of balance. 13:00 - 14:00 1.00 PULL P DECOMP RU Head pin and XO's. Mix and pump dry job. -Blow down Top Drive and cement line. 14:00 - 15:30 1.50 PULL P DECOMP LD: 4 1/2", 12.6#, 13Cr-80, Fox Tbq from 10,754' to 8,528' md. 15:30 - 16:00 0.50 PULL P DECOMP RD & LD: Control line spool, spool sheave & XO's. 16:00 - 23:00 7.00 PULL P DECOMP Continue to LD 4 1/2" Tbg from 8,528' to surface. -Recovered: 55 of 56 Stainless steel bands. -257 Jts + 1 cut Jt of 4 1/2" Tbg. 2- GLM's. -Cut Jt = 16.42'. Flare OD 4.75° -Attempted cut flare (bulge) apparent 7.21' above cut. 23:00 - 00:00 i 1.00 PULL P DECOMP RD & clean Tbg pulling equipment. Printed: 7/16/2009 4:49:17 PM • • C~perat Legal Well Name: 04-22 Common Well Name: 04-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 ~ ~ ~ ~ , ~ummary Report Spud Date: 10/17/1985 Start: 6/19/2009 End: Rig Release: 7/4/2009 Rig Number: 6/27/2009 23:00 - 00:00 1.00 PULL P DECOMP -Demob Tbg puliing equipment. OAP = 0 psi. Losses for tour = 30 bbls Total dail losses= 86 bbls 6/28/2009 00:00 - 01:00 1.00 CLEAN P DECOMP Clear & clean Rig floor. 01:00 - 01:30 0.50 CLEAN P DECOMP Lubricate Rig. Service Top Drive, Drawworks & Blocks. ~I 01:30 - 02:00 0.50 CLEAN P DECOMP Set Wear ring. Break down safety valve. -Blow down Choke & Kill line. ' 02:00 - 02:30 0.50 CLEAN P DECOMP PJSM on picking up BHA. -Mob BHA to Rig floor. 02:30 - 06:30 4.00 CLEAN P DECOMP M BHA #1: -Wash over shoe (3) Wash pipe extensions, Boot basket, -Double pin sub, 7" Csg scraper, Bit sub, Bumper sub, Oil jars, -Pump out sub, XO, (6) 4 3/4" D.C's, DP, XO, Double pin sub, -9 5/8" Csg scraper, Bit sub & XO to 3,284' md. 06:30 - 12:00 5.50 CLEAN P DECOMP PU 4" DP from pipe shed f/ 3,284' to 8,785' md. -Drift all DP w/ 2 3/8" drift. -Enter 7" Liner at 7,553' md w/ no issues. 12:00 - 12:30 0.50 CLEAN P DECOMP Inspect & service Top Drive, Blocks & Crown. 12:30 - 14:30 2.00 CLEAN P DECOMP Continue to PU 4" DP f/ 8,785' to 10,715' md. 14:30 - 16:00 1.50 CLEAN P DECOMP Screw in Top Drive. -Obtain parameters: PUW 225k - SOW 130k - ROW 168k. -Break circ. w/ 147 gpm / 400 psi. -Tag fill / sand at 10,747' md. -PU and wash & rotate down w/ 252 gpm / 1100 psi - 60 rpm 7k tq. -Tag top of 4 1/2" stub at 10,748' md. -Milling on top of stub w/ 2-3k WOB. -Work over stub and rotate down to 10,767' md (Shoe depth). -Tag stub w/ internal dressoff mill & dress top. -Backream & ream over stub several times. -Work over stub w/ no rotary - OK. 16:00 - 18:30 2.50 CLEAN P DECOMP Pump Hi Vis Sweep S.S. w/ 441 gpm / 3300 psi. -Observed heavy sand returns with sweep._ -LD 1 single, PU 2 Pups, spot Inner Mill 1.5' above Stub C 10,746' md. -RU to Reverse circulate. Reverse circulate 1.5 bottoms up. -Stand back 1 Std to 10,695' md. Blow down Top Drive. 18:30 - 19:00 0.50 CLEAN P DECOMP Pull tight / ratty due to solids build up C~ Csg scraper. -Mix Hi Vis Sweep. 19:00 - 20:30 1.50 CLEAN P DECOMP Pump Hi Vis Sweep surface to surface 441 gpm / 3200 psi. -Noted sand back with swee . -Rack back 1 Std. Blow down Top Drive. 20:30 - 00:00 3.50 CLEAN P DECOMP POH w/ 4" DP from 10,695' to the BHA 3,283' md. Fluid losses for tour = 93 bbls Dail fluid losses = 105 bbls 6/29/2009 00:00 - 00:30 0.50 CLEAN P DECOMP LD: XO's, Double pin sub, Bit sub & 9 5/8" Csg scraper. 00:30 - 01:00 0.50 CLEAN P DECOMP Service Rig. Inspect & service Top Drive & Blocks. 01:00 - 02:00 1.00 CLEAN P DECOMP POH w/ 4" DP & D.C's from 3,283' to 54' md 02:00 - 02:30 0.50 CLEAN P DECOMP Break & LD Baker BHA: -P.O.S., Oil Jars, Bumper sub, Bit sub, 7" Csg scraper, Printed: 7/16/2009 4:49:17 PM . • BP EXPLORATIQN Page s af 10 Operations Summary Report Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: ' Date From - To Hours Task Code NPT Phase Description of aperatit~ns 6/29/2009 02:00 - 02:30 0.50 CLEAN P DECOMP -Double pin sub, Boot basket, (3) Wash over extensions & Dressing Mill. -Mill showed good wear pattern. 02:30 - 03:30 1.00 CLEAN P DECOMP Clear Rig floor of all Tools not needed for upcoming operations. 03:30 - 04:00 0.50 CLEAN P DECOMP PU & MU 9 5/8" RTTS to 20' md. 04:00 - 07:00 3.00 CLEAN P DECOMP RIH w/ 9 5/8" RTTS on 4" DP from 20' to 7 506' md. 07:00 - 07:30 0.50 CLEAN P DECOMP Obtain parameters w/ pumps on: PUW 145k, SOW 112k. -147 gpm / 200 psi. Circulate 1 DP volume. 07:30 - 08:30 1.00 CLEAN P DECOMP Pumps off: PUW 145k. -Put 2 RH turns to catch Torque. -Slack off until String takes Wt (110k). -Release Tq. Slack off 20k to 90k String Wt. -Test 9 5/8" Csq to 3500 psi / 30 minutes - Pass. -OA pressure = 320 nsi durinp test. -Blow down Choke & Kill line. 08:30 - 11:30 3.00 CLEAN P DECOMP Release RTTS. Monitor well -< 1/4 bbl/hr losses. -POH w/ RTTS on 4" DP from 7,506' to 20' md. -LD RTfS. 11:30 - 12:00 0.50 CLEAN P DECOMP Mobilise 4 1/2" Scab liner running equipment to Rig floor. Fluid losses for tour = 22 bbls 12:00 - 12:30 0.50 CLEAN P DECOMP Inspect & service Top Drive, Blocks & Crown. i 12:30 - 14:30 2.00 CLEAN P DECOMP Continue to mobilise & RU: ~~, -RU 4 1/2" Scab liner running equipment. 14:30 - 19:00 4.50 CLEAN P DECOMP PJSM on running 4 1/2" Scab Liner. -RIH w/ 4 1/2", 12.6#, 13Cr-80, Van Toq Scab liner. -RIH from 0 to 3,259' md. Fill liner every 25 Jts. -Utilize "Jet Lube Seal Guard" thread compound. -Optimum torque = 4440 ft/Ibs. 19:00 - 20:00 1.00 CLEAN P DECOMP RD 4 1/2" UHT power tongs. -LD Long Bales & 4 1/2" Elevators. -Install Short Bales & Elevators. -Mob 7 5/8" power tongs. 20:00 - 21:00 1.00 CIEAN P DECOMP MU 4 1/2" X 7"- XO, RIH w/ 2 Jts of 7" BTC-M. -Buck off 7" collars and Baker Lok same. 21:00 - 22:00 1.00 CLEAN P DECOMP C/O Elevators to 2 7/8". RD 7 5/8" power tongs. -RU 4 1/2" UHT power tongs. Fill 7" Csg. 22:00 - 22:30 0.50 CLEAN P DECOMP MU: -3 Jts of 2 7/8" Fox, Pump down plug & EUE XO's. 22:30 - 00:00 1.50 CLEAN P DECOMP C/O Elevators to 5". -PU Hanger / Packer assembly. -MU assembly on Inner work string. 6/30/2009 00:00 - 00:30 0.50 CLEAN P DECOMP C/O Csg Tongs. -MU & Baker Lok 9 5/8" X 7" HMC Hanger. 00:30 - 01:00 0.50 CLEAN P DECOMP PU 1 Std of 4" DP & XO. -Pump 1 Liner volume 168 / 100 psi. PUW 90k, SOW 90k. 01:00 - 05:00 4.00 CLEAN P DECOMP RIH w/ Liner on 4" DP. -Run 1 minute per Std from 3,359' to 10,740' (8' above tubing stub) 05:00 - 06:00 1.00 CLEAN P DECOMP Mousehole single -MU Baker cement head to single -MU cement lines -Screw in TD 06:00 - 06:30 0.50 CASE P DECOMP Obtain parameters - PUW 180k, SOW 130k Printed: 7/16/2009 4:49:17 PM s • BP EXPLORATION' Page 7 of 1a Operations Summary R~port Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: ' Da#e From - To Hours Task Gode NPT Phase Description of Operations 6/30/2009 06:00 - 06:30 0.50 CASE P DECOMP -Ta to 4 1/2" cut at 10,748' -Slack off and observe 1 st shear w/ 12k down wt -Cont. down and shear 2nd set pins w/ 7k down wt -Bottom out on 4 1/2" cut at 10,762' O.S. depth - Set down 20k 06:30 - 07:00 0.50 CASE P DECOMP PU above cut -Break circ. w/ 6 bpm, 1000 psi -Observe pressure increase when going over cut at 10,748' Stop pumps - Continue down and bottom out to verify -PU to up wt +2' -Break circ. w/ 3 bpm, 1500 psi 07:00 - 07:30 0.50 CASE P DECOMP PU above cut -Circ. w/ 7 bpm, 1350 psi -PJSM on upcoming cementjob -Brine temp - In 90 de F- Out 88 de F 07:30 - 08:00 0.50 CASE P DECOMP Give to Schlumberger -Pump 5 bbls H20 -Pressure test lines to 4500 psi -Pump 73 bbls Class "G" cement at 15.8 ield 1.16 -Drop DP wiper plug and kick out w/ 5 bbis H20 08:00 - 08:30 0.50 CASE P DECOMP Displace w/ 9.8 ppg brine using rig pumps ' -Caught up w/ cement at 27 bbls away -Continue displace w/ 5 bpm, 1000 psi -Observe wiper latch up at 72 bbis away (400 psi increase) -Contnue displacement and bump plug w/ 1200 stks (122 bbls) -Pressure to 3500 psi to set hanger -Set down 50k to verify hanger set - OK Bleed pressure - Check floats - CIP at 08:30 hrs 08:30 - 09:30 1.00 CASE P DECOMP RD circ. lines -Turn 15 R.H. turns to release running tool -Pressure 1000 psi - PU and observe pressure drop -Circulate 25 bbls w/ 7 bpm, 900 psi -Slow to 1.5 bpm, 130 psi -Set liner top packer w/ 55k down weight -PU - Rotate down w/ 20 rpm - Set down 55k to confirm -Circulate cement out of hole w/ 10.5 bpm, 1500 psi -Approx. 10 bbls contaminated cement to surface 09:30 - 10:30 1.00 CLEAN P DECOMP Break off single w/ Baker cement head -LD head, PU single -Stand back 1 stand of DP 10:30 - 12:00 1.50 CLEAN P DECOMP Pump H.V. Nut Plug sweep to facilitate cleaning cement f/ DP 12:00 - 12:30 0.50 CLEAN P DECOMP Stand back 1) stand and blow down Top Drive. 12:30 - 13:00 0.50 CLEAN P DECOMP Inspect and service Top Drive, blocks, crown, and Draworks. 13:00 - 14:30 1.50 CLEAN P DECOMP POOH from 7,500' to 3,223'. 14:30 - 16:30 2.00 CLEAN P DECOMP PJSM - Cut and slip 59.5' of Drilling line and change out deadman brass. 16:30 - 20:30 4.00 CLEAN P DECOMP L/D 4" DP 1x1 to pipeshed from 3,223' to 100'. Service break and UD running tooL Rig up power tongs and L/D 3) Jts. 2-7/8" FOX. 20:30 - 21:00 0.50 CLEAN P DECOMP Pressure test casin to 1,000 si for 30 charted minutes. 21:00 - 21:30 0.50 CLEAN P DECOMP Rig up test jt. and pull wear bushing, blow down the kill, choke, and hole fill bleeder. Pump out stack. Printed: 7/16/2009 4:49:17 PM ~ • ~1~~. l1P1 A~:TIl1A 1'.... . Operations ; Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hc~urs Task Code NPT Phase Description Qf Operatians f 6/30/2009 21:30 - 00:00 2.50 CLEAN P DECOMP PJSM, N/D BOP'S. R/D flow line, riser, hole fill, kill, and choke lines. Break bolts and lift BOP'S and L/D 11 "x13" tubing spool. 7/1/2009 00:00 - 07:30 7.50 BOPSU P DECOMP PJSM Remove 13"x11" tubing spool and packoff. -Install new P/O and energize LDS's. -Install new 13"x13" tubinp spool and set BOP'S in place. -Test mandrel P/O to 5000 psi for 30 min. -Change out choke line e~ension. -Install turnbuckles, riser, flowline 07:30 - 08:30 1.00 BOPSU P DECOMP RU to test BOPE w/ 4 1/2" & 2 7/8" test jts 08:30 - 13:00 4.50 BOPSU P DECOMP Test 80P and related equipment to BP & AOGCC procedures & regulations -29 components. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. ', -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Hydril to 250 low psi, 3500 high psi. -Test Hydril with 4 1/2" & 2 7/8" test Jts. -Test all valves w/ 4 1/2" test Jt. -Test lower Rams w/ 4 1/2" & 2 7/8" test Jts. i -Test 250 low psi & 3,500 psi High psi. ~ -Hold each test for 5 charted minutes. All test Pass. ` Note: 33 seconds for 200 psi build up 156 seconds for full PSI 4 bottles X 2175 psi. -Test witnessed by T.P. & WSL. -Test witness waived by Lou Grimaldi, AOGCC. 13:00 - 13:30 0.50 BOPSU P DECOMP RD test equipment I 13:30 - 14:00 0.50 BOPSU P DECOMP Install wear ring ' 14:00 - 15:00 1.00 CLEAN P DECOMP PJSM ' -Mobilize 2 7/8" equipment to rig floor -RU tubing tongs -Change elevators 15:00 - 19:00 4.00 CLEAN P DECOMP PU BHA for liner cleanout run -3 3/4" MM mill, bit sub, B.S., oil jar and 2 7/8" PAC pump out sub -PU XO's, 3 1/2" IF pump out sub -RIH w/ 2 stds 4 3/4" DC's f/ derrick 19:00 - 20:30 1.50 CLEAN P DECOMP Continue RIH with 4" DP from 3719' to 7225' 20:30 - 22:00 1.50 CLEAN P DECOMP CBU Sor casing test ~ 7225' with 6 BPM C~ 3050 psi. 22:00 - 23:00 1.00 CLEAN P DECOMP R/U and test casinq and liner to 3500 psi for 30 charted min. Printed: 7/16/2009 4:49:17 PM • • BP EXPLORATION Page 9 af 10 ` Operations Summary Report Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: Qate From - To Haurs Task Code NPT Phase Description af Operations 7/1/2009 23:00 - 00:00 1.00 CLEAN P DECOMP Continue RIH from 7225' to 8050' with 4" DP from derrick to drill out cement and plugs. 7/2/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Service blocks, top drive, and draworks. 00:30 - 02:00 1.50 CLEAN P DECOMP Continue to RIH from 8050' to 10639' and M/U TD. 02:00 - 06:00 4.00 CLEAN P DECOMP Screw in TD -Obtain parameters - PUW = 192 - SOW = 126 - ROT WT = 154 -FREE TQ. = 4K - 200 GPM = 2620 PSI - RPM = 40-60 -Taaqed cement C~ 10.685'., -Drill out cement to L.C. -Mill L.C. and clean out cement to F.C. -Mill F.C. and clean out cement to 10,735' -Wash down to 10,790' 06:00 - 08:30 2.50 CLEAN P DECOMP Pump H.V. sweep -Displace well w/ warm 8.5 ppg seawater -5.5 bpm, 3250 psi 08:30 - 09:00 0.50 CLEAN P DECOMP Obtain new parameters and SPR -PUW 202k - SOW 122k - ROW 150k - 50 rpm, 6k torque -Wash & rotate down. Ta com osite ri 09:00 - 11:00 2.00 CLEAN P DECOMP Mill on plu - 15 min lu fell -Well takinp fluid - Able to maintain minimal flow w/ 4.5 bpm 11:00 - 12:00 1.00 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 16:30 4.00 CLEAN P 16:30 - 20:00 3.50 CLEAN P 20:00 - 21:00 1.00 CLEAN P 21:00 - 21:30 0.50 CLEAN P 21:30 - 22:30 1.00 RUNCO P 22:30 - 23:00 I 0.50 I RU 23:00 - 00:00 I 1.00 I RU 7/3/2009 I 00:00 - 09:30 I 9.50 I RU -Wash down and taa 7" x 4 1/2" XO in new liner to verifv depth 7 1' . DECOMP UD 4" DP from 11,025' to 10,020' -Filling hole with 60 BPH + pipe displacement DECOMP Service Top drive, blocks, crown, and draworks DECOMP Continue to 4" UD DP from 10,020' to 3,712' -Filling hole with 60 BPH + pipe displacement DECOMP UD 6) 4-3/4" DCS and X-O -C/O elevators and R/U power tongs -UD 111) 2-7/8" HT PAC -UD BHA #2 DECOMP Clear and clean rig floor of 2-7/8" Equip. -C/O Elevators and R/D short bails DECOMP BOLDS and pull wear bushing RUNCMP P/U Torque turn and Tbg equip. -Install long bails -R/U TQ. turn and tbg. equip. RUNCMP Hold PJSM with rig crew, T.P., WSL, and Baker rep. -Runnin 4.5" 12.6# 1 compensator. RUNCMP Replaced dump valve on double stacked tongs. -M/U Jewlery per program -Bakerlok all connections below packer -Use Jet Lube seal Guard on all connections -Torque all connections to 4440 ft-Ibs -Fill hole @ 60 BPH with 8.5 ppg seawater RUNCMP Run 4.5" 13CR VamTop completion per running order. -Use Jet Lube seal Guard on all connections -Torque all connections to 4440 ft-Ibs Printed: 7/16/2009 4:49:17 PM • ~ BP EXPLORATION; Page ~0 af iQ Operations Summary R~port Legal Well Name: 04-22 Common Well Name: 04-22 Spud Date: 10/17/1985 Event Name: WORKOVER Start: 6/19/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/4/2009 Rig Name: DOYON 14 Rig Number: Date Fram - To Hours Task Code NPT PY~ase Deseription of Operations 7/3/2009 00:00 - 09:30 9.50 RUNCO RUNCMP -Fill hole @ 60 BPH with 8.5 ppq seawater -PU Jt # 170 to 7422' -Obtain parameters - PUW 135k - SOW 100k -PU jts. # 171,172, 173 -Tag 7" x 4 1/2' XO in liner at 7503' -LD Jts. # 173, 172,171 09:30 - 10:30 1.00 RUNCO P RUNCMP PU hanger & landing joint -Land tubin WLEG at 7455' -RILDS 10:30 - 13:00 2.50 RUNCO P RUNCMP RU and reverse circulate 3 bpm, 80 psi -190 bbls seawater w/ corrosion inhibitor -202 bbls seawater -Obtained returns w/ 120 bbls away 13:00 - 15:00 2.00 RUNCO RUNCMP Dro ball & rod -Work air out of tubing -Pressure u on tubin to 3500 si to set acke -Hold ressure f/ 30 min on chart - Good test -RU & fill IA -Pressue IA to 3500 psi - Hold for 30 min on chart - Good test -Bleed tubing and shear DCR valve w/ 900 psi on tubing (2600 psi differential) -Break circ. through DCR valve - IA to tbg = 2 bpm, 180 psi - 3 bpm = 350 -Tbg to IA = 2 bpm 100 psi, 3 bpm = 210 psi 15:00 - 17:00 2.00 RUNCO RUNCMP R/D circ. lines -P/U "T" bar and set TWC with d rod -R/U and test TWC from above to 3500 psi and below to 1000 psi for 10 charted min. each 17:00 - 19:00 2.00 BOPSU P WHDTRE PJSM on N/D BOP'S -Blow down and Rig down all lines -Set BOP'S on carrier and remove spacer spool 19:00 - 22:00 3.00 WHSUR P WHDTRE Install SBMS seal, adapter, and tree -Torque all studs -Test adapter void to 5000 psi for 30 min. (Good test) 22:00 - 23:00 1.00 WHSUR P WHDTRE Test tree to 5000 psi for 10 charted minutes. (Good test) 23:00 - 00:00 1.00 WHSUR P WHDTRE R/U DSM lubricator and test with diesel to 500 si for 5 min. -Pull TWC 7/4/2009 00:00 - 00:30 0.50 WHSUR P WHDTRE R/D DSM lubricator , 00:30 - 04:00 3.50 WHSUR P WHDTRE PJSM with LRS and Rig crew on freeze protecting well I -R/U LRS and pressure test lines to 3000 psi ~~ -Freeze rotect well to 2 000' with 140 bbls of diesel ~~ -Pumped down ann. taking returns up tubing to pits C~ 84 GPM I ~ 800 psi FCP I, -Allow to U-Tube 1.5 hrs I 04:00 - 05:00 1.00 WHSUR P WHDTRE Install BPV and test from below to 1000 psi for 10 charted, minutes 05:00 - 06:00 1.00 WHSUR P WHDTRE RD LRS. -RD: Secondary IA valve, Pump in flange. -Install Blank flanges. Install gauges. -Secure well. -Tub/IA/OA = 0/0/0 psi. "'R~ released C~3 0600 hrs on Printed: 7/16/2009 4:49:17 PM ~ , 04-22A Well History Date Summary 06/01/09 PULLED 4-1/2" WFD WRP all sliqs & elements recoveredLFROM 10.814' SLM. PULLED P- PRONG FROM 4-1/2" PX PLUG BODY @ 10 830' SLM RAN 4-1/2" GR AND SD HIGH AT 10,831' SLM, UNABLE TO LATCH PLUG BODY,CURRENTLY IH W/ 2.25" x 10' PUMP BLR @ 10,830' SLM 06/02/09 BAILED ~1/2 GALL (~ O.F~',,RF]'ACEOUS SAND / SCALE OFF PLUG BODY @ 10 831' SLM 10 857' MD. ANY HOLE THAT IS GAINED IS THEN LOST FROM POSSIBLE CRETACEO~ LEAK (see log). NOTE: PRESSURING PCE UP TO WELL OVER TUBING PSI EACH TIME BEFORE RIH. CURRENTLY RIH W/ 3.00" x 5' PUMP BLR, MULE SHOE FLAPPER TO 10,830' SLM 10,857' MD. 06/04/09 BAILED --12 CUPS CRETACEOUS SAND/SCALE OFF OF PLUG BODY C«3 10 857' MD. UNABLE TO GAIN ENOUGH HOLE TO PULL PLUG BECAUSE POSSIBLE CRETACEOUS LEAK. NOTE: JOB NOT COMPLETE, 4-1/2" PX PLUG BODY STILL IH C«3 10,857' MD. (P-prong is out) 06/07/09 CTU #6 w/1.75" OD CT. (( Job Scope: Pre RWO Fish PX Plug / Set Composite Bridge Plug )) MIRU. MU and RIH with Baker fishing bha w/4" GS Spear. Tag at 10845' ctmd. Jet fishing neck. with FloPro and attempt to latch PX pluq. Reqeat 3 times. POOH, Did not recover fish. Inspect fishing tools. RIH w/ BHA # 2 w/ 4" GS, Latch fish @ 10839' pull free @ 5k over, POH , 06/08/09 CTU #6 w/1.75" OD CT. (( Job Scope: Pre RWO Fish PX Plug / Set Composite Bridge Plug )) Continued from 06/07/09 POH, Did not recover fish/~lug. Stic y sand in fishinq tools. RIH w/ BHA #3, Circ 100k LSRV GeoVis around top of fish and circ clean bttms up. LAtch and POH w/ oluq from 10838' ctm Plua recovered(3 sets of packing missing). MU and RIH with 4.5" Baker Quickdrill. Correct at flag to bottom of Baker Quick Drill. Set Baker Quick Drill @ 10820' MD. POOH. OOH. Secure well. Notify DSO of well status. RDMO. 06/10/09 T/I/0=550/520/40 Temp= SI CMIT TxIA to 3500 psi FAILED Established LLR of -4.2 bpm Q 3200 psi for 60 bbls, MIT OA PASSED to 1000 psi (RWO Prep) Pumped a total of 103 bbls of 125'F crude down Tbg in attempt to reach test pressure for CMIT TxIA & LLR, Established a LLR of -4.2 bpm C~ 3200 psi for 60 bbls, Monitored pressure for 30 min and T/IA fell from 3150/2620 to 700/700 psi. Pumped 3.8 bbls 75'F crude down OA to reach test pressure for MITOA. OA lost 40 psi in the 1 st 15 mins and 20 psi in the 2nd 15 mins for a total pressure loss of 60 psi in 30 min test. Bled OAP, Bled back - 1 bbls. Final WHP's=600/560/80. Valve position at departure: Swab, Wing= SI. SSV, Master, IA & OA= Open. 06/11/09 SET 4-1/2" SLIP STOP CATCHER C«~ 7550' SLM PULLED RK-OGLV ST #1 FROM 7,463' SLM ( 7,474' MD). POCKET LEFT OPEN. PULL EMPTY SLIP STOP CATCHER FROM 7,550' SLM. 06/13/09 CUT 4.5" TUBING AT 10748' WITH 3.65' SLB POWER CUTTER FINAL T/I/O - 500/ 540/ 0 PSI. WELL LEFT SHUT-IN, TURNED OVER TO DSO. SWAB CLOSED, MASTER OPEN, SSV OPEN. 06/17/09 P~~`` ~ 06/19/09 07/07/09 ~5~~` 5 T/I/0=550/540/0 Double Truck Kill with LRS #42 and LRS #70. (Pre RWO~ Pumped a total of 2 bbls meth, 551 bbls 9.8# ppg brine down IA into PC leak. Pumped a total of 288 bbls 9.8# ppg brine down Tbg, through cut, into PC leak. Pumped 350 bbls brine into IA, then reduced rate to 0.5 bpm. Tubing online at 4.5 bpm with145 bbls brine, then reduce rate to 3 bpm. IA increase rate to 2 bpm untill 400 bbls away, then reduce rate to 0.5 bpm. Tubing increase rate to 4.5 bpm untill vac truck MT (288 bbls.) IA increase rate to 4.5 bpm untill uprights MT (551 bbls.) Swab, Wing, Grove = closed. Master, SSV, IA, OA = open. FWHP's =20/0/0 T/i/0=0/0/0. Set 4-1/16 CIW H BPV thru tree, pre Doyon 14. 1-2' ext used, tagged @ 98". No problems. T/I/O = 0/0/0 Pull 4" CIW H BPV @ 102" w/1-2' ext. Post RWO PULLED BALL & ROD FR~VII 7350' SLM. ~PULLED STA #2 RK- DGLV FROM 7208' SLM( 7215' MD) & STA #1 RKP- CIRC VALVE FROM 3762' SLM ( 3776' MD). SET RK- LGLV AT STA #1 AT 3762' SLM (3776' MD). SET RK- OGLV AT STA #2 AT 7208' SLM (7215' MD). PULLED RHC PLUG BODY FROM 7353' SLM (7360' MD)= (+ 7' CORR). DRIFTED TO DEV C~ 11353' SLM W/ 3.5" CENT, SAMPLE BAILER( 1/4 CUP METAL SHAVINGS). RAN SBHPS PER PROGRAM. Page 1 of ~ /~ • • ~~ ~ ~ ~~~ ~~ ~~ ~ ('~ SARAH PALIN, GOVERNOR ~__.., ~ ~~--_~ Ll~l.a L~ ,r ALASSA OIL A1~D ~~ ! 333 W 7th AVENUE, SUITE 100 COj~T5ERQA`1'IOI~T COM11'II55IO1~T F ANCHORAGE, ALASKA 99501-3539 J PHONE (907) 279-1433 ~ FAX (907) 276-7542 David Reem Engineering Team Leader ~~ BP Exploration Alaska Inc. ~ PO Box 196612 Anchorage AK 99519-6612 ~,~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-22A Sundry Number: 309-157 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of May, 2009 Encl. ?'~ STATE OF ALASKA ''~ ALA~OIL AND GAS CONSERVATION COMIViION ~-1 ~ APPLICATION FOR SUNDRY APPROVAL ~n aac ~s 2a~ ~J~ ~,~~ ~ ~~09 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ 1`ime Extension Anchorage ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 194-097' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21454-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04-22A- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028324, 028322 & 028323 55.6' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12460' - 8696'- 12460' 8696' 10839' & 10857' None in L n h i M TVD r C II S ructural n r 114' 2 1 114' 1490 4 S rface 2521' 13-3/8" 2 21' 2498' 345 1950 In rm di 77 0' - / " 77 S7 7' 6870 4760 Pr i n Liner 4131' 7" 7 3' - 11684' 5712' - 8737 816 7 2 Liner 87 ' 4-1/2" 115 7' - 12460' 87 4' - 8696' 843 750 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotted section: ~~s~s' - ~zas~' 8736' - 8698' 4-1/2", 12.6# 13Cr80 10869' Packers and SSSV Type: 7" x 4-1/2" Baker'SABL-3' packer Packers and SSSV MD (ft): 10795' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 10, 2009 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564-5683 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564-5743 Date ~z3~a Terrie Hubble, 56a-4628 Commission Use OM Sundry Number: Conditions of approval: Notify Commission so that a representative may witness S~ ,~ ~~~L~f7=~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~' Other: ` ~S~' r~ " P ~. ~ ~ ~,~ t ~v St 'h~'~~~V ~cah~v~mc S Sti Td,vw. ~~~ . ~ ~1P~ 2 7 ~~1~9 ~~fetaka (lit ~ ~~iZ ~OE15. CO~~a~ Subsequent Form equired: Anohofp~d APPROVED BY A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 Submit In Duplicate C~ 04-22a Expense Rig Workover • Scope of Work: Repair Cretaceous leak. Pull 4-~/z" 13Cr-80 completion, dress the tubing stub, run and fully cement 4-~/z" scab liner. Test the liner and casing, change 9-5/8" pack offs, clean out the shoe tract and run a new 4-'/2" 13Cr-80 completion. MASP: 2,520psi Well Type: Producer Estimated Start Date: July 10, 2009 Production Engineer: Bob Chiwis Intervention Engineer: David Bjork Pre-Rip Work Request: S 1 Pull WRP from 10,839' MD, Pull PX lu from 10,857 E 2 Set Composite Bridge plug in the top of the first full joint below the packer at 10,820' MD reference tubin tall 08/24/94 F 3 CMIT-TxIA to 3,500psi through open GLM at 8,567' MD record LLR then attempt a 500 si test, MIT-OA 1000 si, record LLR if necessar . E 4 Power Jet cut 4-'/z" 13Cr-80 tubing at 10,745' MD, 10ft from the top of the first full joint above the acker Reference tubin tall dated 08-24-94 . F 5 CMIT-TxIA to 500 si. Circulate well with 9.8 brine and freeze rotect ca . W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 7 Set a BPV in the tubin han er. O 8 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU three preventer BOP stack with 2-7/8" x 5" VBR pipe rams, blind rams and annular preventer. Pressure test to 3500psi. Circulate out freeze protection fluid and circulate well to clean 9.8ppg brine through the cut. 2. Pull and LD 4-'/z" tubing string to the cut. 3. RIH and dress tubing stub. 4. Run and fully cement a new 4-'/z" chrome scab production liner from 10,745 MD to --7450' MD. Pressure test liner and casing to 3,500psi. 5. Change the 9-5/8" casing pack offs. 6. Cleanout the 4-~h" shoe tract and mill up the composite bridge plug. 7. Run 4-'/z" chrome completion (production packer setting depth at 7,385' MD). 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2000' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = 4-1116" CNV WELLHEAD = FMC ACTUATOR = BAK KB. ELEV - 56' BF. E~EV = KOP = 2100' Max Angle = 96° @ 11937 Datum MD =. NA Datum TV D = 8800' SS • 0 ~ -~ ~ ~ S OTES: ***CHROME TBG &LNR*** 20" CONDUCTOR 91.5#, H-40, ID = 19.124" - 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 2521' Minimum ID = 3.00" @ 12110' 4-1 /2" TIW NO-GO SUB TOP OF 7" LNR ~-~ 7553• TOC (08/04/94) 7697' 9-5/8" BRIDGE PLUG (08/02/94) ~-{ 7900' TOP OF 7" LNR ~~ 11848' 10795' 7" x 4-1/2" BKR SABL-3 PKR, ID=" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~- 12201' ~ I ~ 7" LNR, 29#, L-80, ID = 8.681" 12888' ` 10839` 4-1/2" WRP (07/27/08) 10857' 4-1/2" HES X NIP, ID = 3.813" 10857' 4-1/2" PX PLUG (07/14/08) 10869' 4-1/2" WLEG, ID = 3.958" 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 10869' 10862' ELMD TT LOGGED ??/??/?? TOP OF 4-1 /2" LNR ~ 11587' PERFORATION SUMMARY REF LOG: WA ANGLE AT TOP PERF: 88° @ 11676' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 32 11676 - 11914 SLTD 08/26/94 4-1/2" 32 11953 - 12032 SLTD 08/26/94 4-1/2" 32 12070 - 12110 SLTD 08/26/94 4-1/2" 32 12120 - 12437 SLTD 08/26/94 L 7" LNR, 29#, NT-80/13CR ID = 6.276" 11684' 4-1/2" SLTD LNR 12.6#, L-80, .0152 bpf, ID = 3.958" 12460' 7" X 4-1/2" TM/ SS HA PKR 11635' ~- ~4-1/2" PORTED PUP (41.50') 11914' 4-1/2" TM! MLAS ASSY XO i COMPOSffEJT PORTAL SUB AT 11920', ID = 3.871" 12032' 4-1/2"TIW MLAS ASSY XO ' COMPOSITE JT PORTAL SUB AT 11938', ID = 3.871" 12110' ~ a-1/2" TIW NO-GO SUB ID = 3.0" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/26/88 ORIGINAL COMPLETION 07/19/08 JLJ/SV SET PX PLUG (07/14/08) 08/26/94 N28E SIDETRACK (04-22A) 09/20/08 ?/SV SET WRP (07/27/08) 01/02/01 SIS/MW CONVERTED TO CANVAS 01/17/01 SIS/CL FINAL 02/18/01 TP CORRECTIONS 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNIT WELL: 04-22A PERMIT No: 1940970 API No: 50-029-21454-01 SEC 26, 711 N, R15E, 1089' FSL & 217' FWL BP Exploration (Alaska) 2187' ~4-1/2" CAM TRDR4A SSSV, ID = 3.812" LOCK® OUT 05/29/08 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4111 7474 3706 5665 55 54 MMGM MMGM DCK DMY BEK BK 0 0 08/24/94 08/24/94 MILLOUT WINDOW (04-22A) 7700' - 7750' TREE= 4-1/16"CM/ WE]..LHEAD = FMC ACTUATORS BAKER KB. E1EV = 56' BF. EIEV = KOP = 2100' Max Angle = 96° @ 11937' Datum MD = NA Datum TV D = 8800' SS 20" CONDUCTOR 91.5#, H-40, ID = 19.124" - 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 2521' Minimum ID = 3.00" @ 12110' 4-1/2" TIW NO-GO SUB 4-112"TBG, 12.6#, 13CRVamTop, -7,430' TOP OF 7" LNR 7553' TOC (08/04/94) 7697' 9-5/8" BRIDGE PLUG (08/02/94) 7900' 9-5/8" CSG, 47#, L-80, ID = 8.681" 12201' 4-1/2"TBG, 12.6#, 13CRVamTop, 7,450' - 10, 745' 14-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" I 10.745' 1~7" x 4-1/2" UMI Overshot 10795' 7" x 4-1/2" BKRSABL-3 PKR, 14-1/2" HES X NIP, ID = 3.813" II 10869' 4-1/2" WLEG, ID = 3.958" TOP OF4-1/2" LNR PERFORATION SUMMARY REF LOG: N/A ANGLE AT TOP PFRF: 88° @ 11676' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 32 11676 - 11914 SLTD 08/26/94 4-1/2" 32 11953 - 12032 SLTD 08/26/94 4-1/2" 32 12070 - 12110 SLTD 08/26/94 7" LNR, 29#, NT-80/13CR, ID = 6.276" I 11684' i 4-1/2" SLTD LNR 12.6#, L-80, .0152 bpf, ID = 3.958" 12460' 11587' I-I7" X 4-1/2" TNV SS HA PKR 11635' ~~ 4-1 /2" PORTED PUP (41 11914' 4-1/2" TNV MLAS ASSY XO COMPOSf1EJT PORTAL SUB AT 11920', ID = 3.871" 12032' 4-1/2"TM/ MLAS ASSY XO ~ COMPOSITEJT PORTAL SUB AT 11938', ID = 3.871" 12110' 4-1/2" TNV NO-GO SUB ID = 3.0" l DATE REV BY COMMENTS DATE REV BY COMMENTS 01/26/86 ORIGINAL COMPLETION 07/19/08 JLJ/SV SET PX PLUG (07114/08) 08/26/94 N28E SIDETRACK (04-22A) 09/20/08 ?/SV SET WRP (07/27/08) 01/02/01 SIS/MW CONVERTEDTOCANVAS 01/17/01 SIS/CL FINAL 02/18/01 TP CORRECTIONS ';~30~~~~ LTti1 W~~~HEADCORRECTION PRUDHOE BAY UNIT WELL: 04-22A PERMIT No: 1940970 API No' S0-029-21454-01 SEC 26, T11 N, R15E, 1089' FSL & 217' FWL BP Exploration (Alaska) O 4 ~2 2 A S NOTES: ***CHROME TBG ~ LNR*** Proposed 2,000' 4-1/2" HES X NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3762 7280 3500 5550 50 54 MMG MMG 7,350' 4-1/2" HES X NIP, ID = 3.812" 7,385' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 7430' 4-1/2" HES X NIP, ID = 3.812" 7,450' 9-5/8" x 7" Liner Top crossed over to 4-1/2" scab liner I 11587' I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wnil hti u 04/06/09 N0.5162 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPS-08 AY3J-00016 -~ ~~ LDL /qa6 03/23/09 DV VVIVf (,.U 1 04-22A BiJJ-00003 MEM LDL 03/24/09 1 1 15-15C BOOR-00004 MEM PROD & INJ PROFILE _ ,'~- 1 03/15/09 1 1 4-04/T-25 AP3O-00028 _ USIT _ 03/21/09 1 1 P-O66 AY3J-00016 INJECTION PROFILE 03/30/09 1 1 E-05A B1JJ-00003 CH EDIT PDC-GR (JEWELRY LOG) /nj Q _ 02/08/09 1 08-14A BOOR-00004 CH EDIT PDC-GR (JEWELRY LOG) '"-'-}- 02/21/09 1 F-33A 40018553 OH MWD/LWD EDIT - a(o 01/25/09 2 1 F-33A PB1 40018553 _ OH MWD/LWD EDIT _ ~ j ~- 01/14/09 2 1 OI CACG AfaVAlnae/a 1~11I+r nr i.rarar jai naw~.. ~.w ..... ...~~........... ~..~ ~~~.. ~. ~.. _~ BP Exploration (Alaska) Inc. _ _ . _........,. v.-~ vv. ~^va a ~ v~ Petrotechnical Data Center LR2-T 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Str et, Suite 400 Anchorage, AK -2838 ATTN: Beth -~~°"~ Received by: 08/05/08 S~hb~rgcr Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Y~.,Y~YV ~ll,lta ~~ '.La. ~UUU ~y' wpu _i.,ti ~ i .,.. ne ..~:.. NO.4812 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n~~e of r..~... nn P1-03 12021163 MEMORY SBHPS 06/11/08 1 MPC-15 12066534 MEM INJ PROFILE -- l 07/19/08 1 1 L-205 12061697 MDT (SUMMARY PRINT) 05/26/08 1 1 L-205 12061697 MDT 05/26/08 1 1 04-22A 12005220 MEMORY LDL ~ - 07/26/08 1 1 H-22A 11968956 SBHP SURVEY ~ 07/28/08 1 1 C-37A 12005221 MEMORY CBL 07/28!08 1 1 rr.-....r ........v....w..a.~ ...-v ~~r . rr . v.aa. v.~~a nnv nG ~ vn~9~~w vP~c ~rvr 1 CFN.n ~ v: BP Exploration (Alaska) Ina °~° >. Petrotechnicat Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ i~ ~, ~ },,~~ Alaska Data & Consulting Services 2525 Gambell Stre t, Suite 0 Anchorage, AK 9 3-283 ATTN: Beth Received by: • • 01'4' OR BEF ORE c:LOi~MFI~M.DOC AOGCC Ind'¥ v'i'ciua i b'ei i ,..~,~,og'¥cai h'later"¥a'i s Irlventor'y F'.L{ RN I T DATA T DATA.._F' L U S 10580--i 1667 OH/FINALS CONP DATE~ 08/26/9a. 07/30'~08/27/94- 7697-.- 12a. 60 94.-~09'? ~VEY 9a.~....-097 ~S,D R '7697~12a60 8F'ERRY SUN L. 1 t 260--' i 2a50 91,'-~-097 ~OP/S,SAC ga. ---.' 097 ~c,/SGAC L 614-5~-8695 GR L 61a. 5---8695 HD/'GR . ~ r '~ ' 96 13, a'!:e 0 61' .)d/ , RI..IN [) AT E.._F-;: [.!:, C",/D 'i 0 8 / 'i !'!i / 9/.~ 'i 0/" 28/94 10 / 28/' 9 !, 09/'02/' 94 10/' 28 / 9 ~, 1 0 i/'24/95 I 09/' 19/' 9~.~ 1 09//9/94 Ar'e dr"y d'i'tch sarnp'ies r'equ'i'r'ed? yes r~~d r'ece'¥ved? yes no Was the. ~ei 'i cor'ed; yes ysi's E. descr'"iption r'ecei'ved©; Ar'e ~,~e'i J 'tests r'eciu'¥ r'ed? ye~ Receivect? ~ We i J ~ s ~' i~ c~p J ~1' alice ~ Zn~'t:ia I C OM N E N T S February 15, 1995 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: Survey Data- 18-3A, 5-5A, 7-13A, 4-22A Dear Mr. Grant, At the request of ARCO Alaska Inc., the following data is once again being re-distributed. On February 3rd 1995, BP Exploration requested we change the data on 5-5A, 7-13A and 4-22A and redistribute it to you. This was done and you were requested to destroy the previously distributed data. However, AAI did not agree with this data and requested I return the data to its original information and distribute to you once again. Enclosed are two hard copies of each of the MWD surveys. Page 2 was previously missing. Tied in at 8810' to 12060' - destroy previously distributed data Tied in at 10000' to 12458' - destroy previously distributed data Tied in at 7697' to 12460' - destroy previously distributed data Please call me at 563-3256 if you have any questions. Sincerely, Sandr~Lufkin Region Assistant Enclosures. RECEIVED FEt3 ? ~ I995 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company February 3, 1995 ARCO Alaska, Inc. AOGCC, Larry Grant PO Box 100360 Anchorage, AK 99510-0360 Re: Survey Data- Re-distribution of 4-22A, 5-5A and 7-13A Dear Mr. Grant, Enclosed are two hard copies (each) of the revised MWD surveys. We~74-22A q-o7b Well 5-5A 1st revision - destroy any previous data received. The tie in point and kelly bushing elevation were incorrect. 1st revision - destroy any previous data received. The tie in point was incorrect. 1st revision - destroy any previous data received. The tie in point, window point and kelly bushing elevation were incorrect. Please call me at 563-3256 if you have any questions. Sincerely, ! Sandra Lufkin Region Assistant Enclosure. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company GeoQuest T-,? 500 W. International Airport Road .,' Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED 2 1995 ~ka 0il &AnchomgeGas Cons. Commission NO. 9211 Company: 1/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description BL RR Sepia RF Sepia Mylar D.S. 1-3 POGLM SETTING RECORD (12-23-94) ~,,'1 ~'1 D.S. 1-3 POGLM RECORD (1-3-95) vl vl D.S. 1-25 LEAK DETECTION (1-3-95) v'l ~' 1 D.S. 3-27 BAKER IBP RECORD (12-31-94) ,~1 ~-'~1 D.S. 4-7 ST I PERF RECORD (12-30-94) ,,~1 ,,'1 D.S. 4-22A PROD PROFILE (12-26-94) v'l ~' 1 D.S. 6-4 PERF RECORD (12-25-94) ,,,1 --'1 D.S. 8-14A PERF RECORD (12-26-94) ~ ,,'1 D.S. 9-4A PERF RECORD (12 23-94) ~-I , D.S. 9-30 ST PERF RECORD (1-2-95) v/1 D.S. 9-32 PERF RECORD (12-25-94) ~1 ,-'1 D.S. 11-16 ST 1 LEAK DETECTION (12-31-94) ,,-1 D.S. 11-23A PERF RECORD (12-21-94) ~1 D.S. 13-15 SBHPS & INJEC PROFILE (12-29-94) ,,-1' D.S. 13-33 LEAK DETECTION (12-30-94) I 1 D.S. 13-33 BAKER INFLAT BRIDGE PLUG RECORD (1-3-95) -'1 D.S. 14-21 SBHPS & INJEC PROFILE (12-23-94) ~1 '"'1 D.S. 15-7A DUAL BURST TDT-P (1.2-27-94) v,1 D.S. 15-30 LEAK DETECTION (12-27-94) v,-I ~-'1 D.S. 15-30 DUAL BURST TDT-P (CT/E-LINE) (12-30-94) ,,,1 D.S. 18-9A DUAL BURST TDT-P (12-22-94) ,,'1 ,/1 D.S. 18-27 .DUAL BURST TDT-P (CT/E-LINE) (12-29-94) ¢1 SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEI',DED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 94-97 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21454-01 4. Location of well at surface i~ (~i.ii~ii: ii-~! ". g. Unit or Lease Name 1089'NSL, 217'EWL, SEC. 26, T11N, RI[E '~.":~ . ~ ] ~----------'""~--~ Prudhoe Bay Unit At Top Producing Interval~c-~i ....~,~ 10. Well Number 1552' NSL, 31' WEL, SEC. 22, T11N, R15~~~"F;:;;":::~i i 4-22A At Total Depth ~~ Prudhoe Bay Field/Prudhoe Bay Pool 3051' NSL, 164' EWL, SEC. 23, T11N, R15E 5. Elevation in feet (indicate KB, DF, etc.) ~. Lease Designation and Serial No. KBE = 55.6' J ADL 28323 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 8/4/94 8/20/94 8/26/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey p0. Depth where SSSV set 121. Thickness of Permafrost 12460' MD/8695' TVD 12460' MD/8695' TVD YES [] ~ []! 2187' feet MDI 1900' (Approx.) [22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SE'ri'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED .... 20" 91.5# H-40 Surface 114' 30" 1800 # Polyurethane 13-3/8" 68#/72# K-55/L-80 Surface 2521' 17-1/2" 3000 sx CS 111/400 sx CS I 9-5/8" 47# L-80 Surface 7700' 8-1/2" 350 sx Class "G" 7" 29# NT80/13CR 7553' 11684' 8-1/2" 310 sx Class "G" 4-1/2" 12.6~ L-80 11587' 12460' 6" Uncernented slotted liner 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MD) None Slotted liner ~l-1/2", NT13CR8~ 10869' 10795', 11587' MD TVD 11676'-11914' 8736'-8729' 11955'-1£05£' 8729'-8718' 2~. ACID, Fmc'rUR~,CEMENTSOUE~E, ETC. 12120'-12437' 8714'-8697' ~ · ~-'\~ ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED _ 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 9/4/94 J Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SITF IGAS-OIL RATIO I TEST PERIOD 'Flow Tubing Casing Pressure ,?,ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol oil, gas or water. ,Submit core chips. R[C£1V D OOl' 28 1994 ~iaska. LiiI & Gas Cons. Commission Anchor[ ........ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOL~ MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top Sadlerochit 10874' 8472' Zone 3 10874' 8472' Zone 2 10890' 8483' GOC 11225' 8645' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed J~'~ ¢~J~%-- TitleOr#/irl~_En~_ineerSuoerv[sor Date~''7~ 7-'~ I'~] INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Form 10-407 OE'f 28 1994 Gas Cons. Corrlmissiop Anoh0r2 .,; BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 4-22A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/31/94 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 07/30/94 ( 1) TD: 0 PB: 0 PAD T/PAD RIG MOVE PAD T/PAD MOVE TIME. MW: 8.5 Seawater 07/31/94 ( 2) TD: 0 PB: 0 08/01/94 (3) TD: 0 PB: 0 08/02/94 (4) TD: 0'( 08/03/94 (5) TD: 0 PB: 0 0) TEST WELL CONT. EQUIP MW: 0.0 Seawater MOVE RIG. RAISE DERRICK & RU. NU TREE/STACK. RU LUBRI. PULL BPV BLEED CRUDE & GAS. REV. CIRC. OUT CRUDE & GAS. TOOL BROCK WHILE PULLING BPV. LD LUBRI. & MONITOR HOLE. CRUDE & GAS COMING T/SURF. CLOSE BLIND RAMS & REV. CIRC. OPEN RAMS/RETRIVE PIECES OF BPV W/MAGNET. RU LUBRI & SET TEST PLUG. PRESS TEST BOPE. LD 4.5"TBG MW: 0.0 Seawater NU BOP STACK. TEST BOPE PULL TEST PLUG W/LUBRI. PULL SINGLE COMP. 4.5" OD. MU LNDG JT. PULL 230 K ON TBG-UNABLE T/PULL SEALS FREE. RU E-LINE & CUT TBG @11814 W/JET CUTTER. RD E-LINE. CIRC WELL CLEAN OF CRUDE & GAS @ 9BPM. LD TBG T/11814. LD 4.5" TBG. MAKE UP BHA MW: 0.0 VIS: 0 PULL SINGLE COMPLETION, 4 1/2" O.D. TEST WELL CONTROL EQUIPMENT.RUN DRILLPIPE. PERFORM INTEGRITY TEST. [RESSURE TEST COMPLETED SUCCESSFULLY. CIRCULATED. HOLE DISPLACED WITH WATER BASE MUE. PULLED DRILLPIE IN STANDS TO 7600' MADE UP BHA %1. PULL DRILLPIPE MW: 0.0 Seawater CUT CASING @7700' MILL WINDOW IN 9 5/8" CASING F/ 7700-7750'. CIRCULATED. HOLE SWEPT WITH SLUG. POH. PULLED BHA. SERVICE BOP STACK. RUN DRILLPIPE, WASHED TO 7847'. COMPLETED PRECAUTIONARY MEASURES. CIRCULATED @7850' MIXED AND PUMPED SLURRY. PUMPED 5 BBL H20, TEST LINE. PULLED DRILLPIPE IN STANDS TO 6700'. CIRCULATED. OBTAINED CLEAN RETURNS. HESITATION SQUEEZE. PULLED DRILLPIPE IN STANDS. R[CEIV[D OCT 2 8 1994 ~,. & Gas Cons. 6ornmissior, AnchorL. ,,: WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 2 08/04/94 ( 6) TD: 7870' (7870) 08/05/94 (7) TD: 9049' (1179) 08/06/94 (8) TD: 9865' ( 816) 08/07/94 ( 9) TD:10560' ( 695) 08/08/94 (10) TD:10880' ( 320) 08/09/94 (11) TD:l1069' ( 189) DRILLING MW: 9.5 VIS: 62 PULLED DRILLPIPE IN STANDS. SERVICED MUD SHAKERS. CLEAN SHALE SHAKERS AND FLOW LINE. MADE UP BHA #1. RIH TO 7268'. DRILLED CEMENT 7697' START KICKOFF. CIRCULATED AT 7779'. HOLE DISPLACED WITH WATER BASED MUD. CHANGE OUT MILLING FLUID TO NEW MUD. DRILLED TO 7870'. CIRC BOTTOMS UP MW: 9.5 VIS: 47 DRILLING T/ 8700'. STARTED SCHEDULED WIPER TRIP. POH TO 7660'. RIH TO 8700' DRILLING T/ 9049' REACHED PLANNED END OF RUN. CIRCULATED. OBTAINED BOTTOMS UP. DRILLING MW: 9.7 VIS: 54 CIRCULATED @9049'. PULLED OUT OF HOLE TO 844' PULLED BHA. SERVICED BOP STACK. SERVICED WEAR BUSHING. CHANGE OUT JARS AND MWD PROBE. ORIENT. SERVICED BLOCK LINE. CUT DRILLING LINE. RIH TO 8969'. BEGAN PRECAUTIONARY MEASURES. REAMED TO 9049' DRILLED TO 9865'. DRILLING MW: 9.7 VIS: 47 DRILLED TO 9865'_ STARTED SCHEDULED WIPER TRIP. PULLED OUT OF HOLE TO 8825'. AT TOP OF CHECK TRIP INTERVAL. RIH TO 9865'. NO PROBLEMS ENCOUNTERED O WIPER TRIP. DRILLED F/ 10415'. SURVEY WIRELINE UNIT FAILED, WORK STRING. CIRCULATED. SURVEY WIRELINE UNIT FAILED AGAIN. CIRCULATED. CHANGE LINE CONDITIONERS ON SPERRY SUN COMPUTERS. DRILLED TO 10560'. REAM ON BTTM MW: 9.7 VIS: 49 DRLG T/10885. REACHED PALNNED END OF RUN CBU 100% ANNUL. VOL. POOH T/628. PULL BHA LAID OUT. RETRIEVE WEAR BUSHING TEST BOP STACK PRESS TEST T/5000, TEST WITNESS WAIVED BY DOUG AMOS - AOGCC REP. INSTALL WEAR BUSHING, MU BHA #3. RIH T/10795. BEGIN PRECAUTIONARY REAM T/10885. MAKE UP BHA MW: 9.8 VIS: 53 DRILLED TO 10795'. LAID DOWN DRILL PIPE. REAMED TO 10972'__ DRILLED TO 11069'_ BUILD RATE UNACCEPTABLE. CIRCULATED. OBTAINED BOTTOMS UP. POH TO 935' PLULLED BHA. CHANGE OUT MOTOR. CHANGE BIT. MADE UP BHA #4. RIH TO 5000' RECEIVED ,.:,.~,s.~a. O~l & Gas Cons. Cornrnissior,' Anchor~ .~ WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 3 08/10/94 (12) TD:l1059' ( 0) 08/11/94 (13) TD:11298' ( 239) 08/12/94 (14) TD:10400' ( 0) BHA #6 MW: 9.9 VIS: 49 R.I.H. TO 11021 FT. BEGAN PRECAUTIONARY MEASURES. WASHED TO 11069 FT. MUD MOTOR FAILED - CIRC. MUD MOTOR LOCKED UP. CIRC AT 11069 FT. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POH TO 935 FT. AT BHA. PULLED BHA. BHA LAID OUT. LAID DOWN MUD MOTOR & BIT. MADE UP BHA NO. 5. PICKED UP NEW MOTOR & BIT. BHA NO. 5 MADE UP . RIH TO 2000 FT. STOPPED: TO SERVICE DRLG EQUIPMENT. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. R.I.H. TO 10981 FT. BEGAN PRECAUTIONARY MEASURES. WASHED TO 11059' OBSERVED 50000 LBF DRAG ON CONNECTIONS. POOH TO 10981'. NO FURTHER RESISTANCE. MUD MOTOR FAILED. LOCKED UP. CIRC AT 10981'. HOLE SWEPT WITH SLUG - 100 % HOLE VOLUME. POOH TO 933'. AT BHA. PULLED BHA. BHA LAID OUT. MUD MOTOR LAID OUT. MADE UP BHA NO. 6. NEW MUD MOTOR. BHA NO. 6 MADE UP. R.I.H. TO 10957' BEGAN PRECAUTIONARY MEASURES. WASHED TO 10095'. NO FURTHER RESISTANCE. BHA #6 MW: 9.7 VIS: 51 2 BENT HOUSING MOTOR. WASHED TO 11069' ON BOTTOM. DRLD TO 11167'. ADT-.25 HRS, AST=2.5 HRS. ROP DROPPED FROM 35'/HR TO O'/HR. STRING HUNG UP. APPEARED TO BE HUNG U0P ON STABILIZER ON MOTOR. CIRC AT 11167' CIRC SWEEP. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 0'. POOH. PUMPED OFF BOTTOM. AT WELLHEAD. 2 BENT HOUSING MOTOR, MOVED HWDP 6 STDS UPHOLE. MADE UP BHA #7. P/U BIT #6, NEW MWD, ORIENT. SERVICE WEAR BUSHING. BHA #7 MADE UP. R.I.H. TO 11167' NO HOLE PROBLEMS. ON BOTTOM. DRLD TO 11298'. AST=5.75 HRS. DRLG MW: 9.8 VIS: 44 DRILLED TO 11337'_ ADT = 1.25 HRS, AST-1 HRS. REACHED DEPTH PRIOR TO SIDE-TRACK. CIRC AT 11337' CIRC B/U SWEEP. HOLE SWEPT WITH SLUG - 125% HOLE VOLUME. POOH TO 0' L/D MWD & DOWNLOAD DATA. AT WELLHEAD. RUN DP IN STANDS TO 11337'. AT SETTING DEPTH. CEMENT: KICKOFF PLUG. CIRC AT 11337'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). CIRC B/U WHILE BATCH MIX CMT. MIXED AND PUMPED SLURRY - 85 BBL. PMP 5 BBLS HW0 & TEST LINES TO TO 3500 PSI. PMP 15 BBLS H20 SPACER AND CLASS "G" CMT @ 17.0 PPG. DISPLACED WITH RIG PUMPS. CEMENT BUMPED. RIGGED DOWN DRILLSTRING HANDLING EQUIPMENT. PULLED 15 STDS DP. CIRC AT 9942' CIRC TO CLEAR DP. OBTAINED CLEAN RETURNS - 100% HOLE VOLUME. PULL DP, 5IN O.D. POH 2/5" DP. L'C 3-1/2" STINGER. PULLED DP IN STANDS TO 0 FT. AT WELLHEAD. P/U 1.5 BH MOTOR, MWD, & ORIENT. MAD UP BHA NO. 8 BHA NO. 8 MADE UP. RIH TO 7600'. STOPPED: TO SERVICE DRLG EQUIP. SERVICED BLOCK LINE. RECEIYED OC'l" 2 8 '/99 ~i.~ska oil & Gas Cons. Commission: Anchor~ ,~ WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 4 08/13/94 (15) TD:l1074' ( 674) 08/14/94 (16) TD:l1370' ( 296) 08/15/94 (17) TD:11864' ( 494) CEMENT: KICKOFF PLUG MW: 9.8 VIS: 50 CEMENT: KICKOFF PLUG. WAIT ON CEMENT. RESUMED OPERATIONS. 1-1/2 BH MOTOR. RIH TO 10000'. BEGAN PRECAUTIONARY MEASURES. WASHED TO 10439'_ AT TOP OF CEMENT. DRILLED CEMENT TO 10700' ACT 1.5 HRS. TAGGED OTHER SUB-SURFACE EQUIP. REACHED KOP ON CEMENT PLUG FOR SIDETRACK. DRILLED TO 10742'. CONTROL DRILL FOR KICKOFF. AST=.5 HRS. ROP DROPPED FROM 35'/HR TO 10/HR. BIT QUIT. CIRC AT 11074' HOLE SWEPT WITH SLUG - 150% HOLE VOLUME. POOH TO 7700' AT CSG WINDOW. OBSERVED 65000 LBF OVERPULL. WORKED TOOLSTRING AT 7700'. ROTATE TO WORK BHA INTO CSG WINDOW. BHA #1 MW: 9.7 VIS: 49 POOH TO 0'. PLANNED MAINTENANCE. SERVICED DRILLSTRING HANDLING EQUIP. PULLED WEAR BUSHING. EQUIP WORK COMPLETED. RAN WEAR BUSHING. BHA RUN #2. MADE UP BHA #2. 1.5 BH MOTOR. BHA #2 MADE UP. RIH TO010880'_ RIH SLM. STOPPED @ TIGHT SPOT IN TOP OF SADLEROCHIT. 30.8' (1 JT) DEPTH CORSLECTION. BEGAN PRECAUTIONARY MEASURES. REAMED TO 11043' PRECAUTIONARY REAM TO BOTTOM. ON BOTTOM. DRILLED TO 113~0'. ADT=4.25 AST=4.25. ROP DROPPED FROM 30FT/HR TO 2FT/HR. BIT QUIT. COULD NOT SLIDE IN ANGLE BUILD SECTION. CIRC AT 11370' OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POH TO 6720' NO HOLE PROBLEMS. PULLED INTO SCG OK. CONT POH. BHA #2 MW: 9.8 VIS: 45 FINISH POH. NO HOLE PROBLEMS. POOH TO 0' AT BHA. DOWNLOAD MWD DATA. 1.75 BH MOTOR. MADE UP BHA #3. ADJUST MOTOR, CHECK MWD, ORIENT. RIH TO 11370' NO HOLE PROBLEMS. WASHED LAST THREE SINGLES TO BOTTOM. ON BOTTOM. DRILLED TO 11684'. DRILLED TO TD 8.5" HOLE IN LOWER ROMEO INTERVAL. ADT=l.75 HRS, AST=4.5 HRS. REACHED PLANNED END OF RUN - SECTION / WELL T.D. CIRC AT 11684'. HOLE SWEPT WITH SLUG - 100% HOLE VOLUME. POOH TO 10289' NO HOLE PROBLEMS. AT TOP OF CHECK TRIP INTERVAL. RIH TOOl1684' NO HOLE PROBLEMS. ON BOTTOM. CIRC AT 11684' HOLE SWEPT WITH SLUG - 100% HOLE VOLUME. POOH TO 215'. NO HOLE PROBLEMS. AT BHA. PULLED BHA. BHA LAID OUT. WIRELINE WORK. R/U ATLAS WL FOR DP CONVEYED LOGS. RIGGED UP DRILLSTRING HANDLING EQUIP. WORK COMPLETED - SERVICE LINES IN POSITION. 0(}1 2 8 i,99~ ,a~.s,ka 0il & 6as Or,ns. 6ommissie~' Anchor~_ ' WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 5 08/16/94 (18) TD:11684' ( 0) 08/17/94 (19) TD:11684' ( 0) WIRELINE WORK MW: 9.8 VIS: 43 RAN DP CONVEYED LOGS W/ATLAS WIRELINE. RAN ELECTRIC LOGS. P/U AND TST LOGGING TOOLS. (CHT-TEMP-GR-CN-AC-DIFL). COMPLETED CALIBRATION CHECKS ON DIFL-AC-GR. RAN ELECTRIC LOGS. RIH W/LOGGING TOOLS ON DRILL PIPE. COMPLETED RUN WITH DRILLPIPE FROM 0.00FT TO 10171 FT. AT PUMPIN SUB DEPTH. RAN ELECTRIC LOGS. P/U SIDEENTRY SUB AND RIH W/WIRELINE. PUMP WET CONNECT. COMPLETED RUN WITH OTHER SUB-SURFACE EQUIPMENT FROM 0' TO 10171' RAN ELECTRIC LOGS. RIH LOGGING DOWN F/10650'-11669' LOGGED UP 5 STS FOR REPEAT PASS. RIH. LOG UP POH. UNLATCH AND POH W/WIRELINE. RAN ELECTRIC LOGS. POH W/LOGGING TOOLS ON DRILLPIPE. COMPLETED LOGGING RUN WITH DIFL-AC-GR FROM 10650' TO 11669'. OUT OF HOLE W/LOGGING TOOLS. RAN ELECTRIC LOGS. RIG DOWN WL TOOLS & EQUIP. WORKED DIFL-AC-GR FREE AT 0'. L/D TOOLS AT SURFACE_ TEST WELL CONTROL EQUIP. TESTED BOP STACK. TESTED PIPE RAMS, BLIND RAMS, CHOKE MANIFOLD, CHOKE AND KILL LINES, SURFACE VALVES TO 250/5000 PSI. TESTED ANNULAR TO 250/3000 PSI. TESTED ACCUMULATOR. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. TEST WITNESSED BY B. FOSTER AOGCC. MADE UP BHA #4. P/U BULLNOSE HOLE OPENER FOR CLENAOUT RUN. BHA NO 4 MADE UP. RIH TO 2350' BEGAN PRECAUTIONARY MEASURES. SERVICED BLOCK LINE. BEGAN PRECAUTIONARY MEASURES. BHA #4 MW: 9.8 VIS: 43 MADE A CONDITIONING RUN PRIOR TO RUNNING 7" CSG. RIH TO 10917'. BEGAN PRECAUTIONARY MEASURES. REAMED TO 11684'. PRECAUTIONARY REAM TO TD. NO HOLE PROBLEMS. ON BOTTOM. CIRC AT 11684'. DROPPED HALLIBURTON CIRC TEMP GAUGE AND CIRC SWEEP. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 90' L/D 105 JTS DP. NO HOLE PROBLEMS. PULLED BHA. BHA LAID OUT. RAN 7" LINER. RAN CSG TO 4139'. R/U & RAN 7" CSG. STOPPED: TO CHANGE HANDLING EQUIPMENT. RD CSG EQ. RAN DRILLPIPE IN STANDS TO 10935'. CSG STRING STARTED TO TAKE WEIGHT. AT LOSS ZONE. 7" LINER WOULD NOT GO DOWN. SET 40000 ON LINER. R/U & CIRC PARTIAL RETURNS, SOME PACKING OFF. CIRC AT 10997' DEEP WILL NO ALLOW CHANGING THE OPERATION. RAN CASING TO 10997' WORKING SINGLES DOWN WHILE CIRC @ 4 BPM. CANNOT PULL UP. HOLE SWEPT WITH SLUG - 100% HOLE VOLUME. DEEP APPLICATION WILL NOT ALLOW CHANGING THE EVENT RECEIVED 0(11' 2 8 1994 Aisska (.iii & Gas Co¢~s. Cornmissior' Anchor~_ .' WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 6 08/18/94 (20) TD:11564' ( 0) 08/19/94 (21) TD:11564' ( 0) 08/20/94 (22) TD:12150'( 586) 08/21/94 (23) TD:12460' ( 310) TESTING CSG - POH MW: 9.6 VIS: 40 RAN DRILLPIPE IN STANDS TO 11648'. CEMENTING 7" LINER. CIRCULATED. OBTAINED BOTTOMS UP. DISPLACED SLURRY. PLUG BUMPED. REVERSE CICR ON TOP OF LINER. NO CMT IN RETURNS. CIRCULATED TO CLEAR DRILLPIPE. PULLED DRILLPIPE IN STANDS. POH. LD 64 JTS DRILLPIPE AND LINER RUNNING TOOL. MADE UP BHA #5. PU 6" BIT, MUD MOTOR, MWD/GR AND ORIENT. PULSE TEST MWD TOOLS. FAILED. CHANGED OUT MWD. RIH TO 5100' PU 3 1/2" DP. RIH TO 11517'_ FINISH RIH W/ 5" DP. TAGGED CMT STRINGER @11517'_ DRILLED SOFT CEMENT STRINGER TO LANDING COLLAR @11564'. STOPPED TO TEST CASING. CIRCUALTED. OBTAINED BOTTOMS UP. TESTED CASING. PRESS TEST CASING, LINER AND LINER HANGER PACKER. SUSPANDED PRESSURE TEST ON CASING, OBSERVED LEAK. POH TO 3000' POH F/ RTTS TO FIND LEAK. PLANNED MAINTENANCE MW: 9.8 VIS: 48 POH. STAND BACK BHA. RIH TO 1376' PU 9 5/8" RTTS AND TIW SEAL ASSEMBLY AND RIH TO 1376' SET RTTS AND TESTED CASING BELOW. LEAKED OFF @1200 PSI. SET RTTS @7513' TESTED 7" LINER AND LINER LAP TO 1200 PSI. BLED OFF. TESTED 9 5/8" CASING. TESTED OK. SET TIW SEAL ASSEMBLY IN LINER HANGER @7553'. TESTED LINER TO 3500 PSI. LINER TESTED OK. LINER LAP IS LEAKING. POH. LD RTTS AND TIW SEAL ASSEMBLY. PU TIW 7" X 9 5/8" SNA LINER TOP PACKER. TIH TO LINER HANGER TOP @7553' SET PACKER. STAB SEAL ASSEMBLY INTO TIEBACK RECEPTICAL. SLACK OFF 60 K TO SET SLIPS AND PACKER. ROTATE TO RELEASE PACKER. PRESS TEST CASING. LINER LAP REPAIRED. POH AND LD PACKER RUNNING TOOL. MAKE UP BHA #6. SERVICED BLOCK LINE. LINE SLIPPED. DRILLING MW: 9.0 VIS: 50 PLANNNED MAINTENANCE SERV. BLOCK LINE. SLIP & CUT LINE. RIH T/11564. T/LANDING COLLAR. DRILLED FLOAT EQUIP & CMT T/FLT SHOE @11684. DRILLED FLT. SHOE + 10' OF NEW HOLE T/11694' CIRC @11694. PUMPED 70 BBLS SAFEKLEAN + 100 BBLS/3PPB XANVIS & DSPLCE THE HOLE T/FLOPRO MUD SYSTEM. DRLG T/12150. RIH MW: 9.1 VIS: 55 DRLG T/12460. REACHED SECTION TD. CBU. 100% HOLE VOL. POOH T/l1623-SHORT TRIP 9 STNDS. RIH T/12460. CBU - 100% HOLE VOL. POOH LD MUD MOTOR MWD MONELS. CLEANOUIT SCRAPPER RUN MU BA #7 RIH T/8400. RECEIVEE) 0C'1 2. 8 i99~ Amska (Jil & Gas Cons. Cornrnismor. Ar~chor~ WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 7 08/22/94 (24) TD:12460' ( 0) 08/23/94 (25) TD:12460' ( 0) SERV. BLOCK LINE MW: 9.1 VIS: 56 RIH T/11730. OBSERV 5000 LBF RESISTANCE. REAM T/12160-LITTLE RESISTANCE. 5000LB MAX WT ON BIT. HAD CHANGE IN TRQ F/21000FP# T/25000FP#. STRING HUNG UP. AFTER MAKING CONNECTION KICKED IN ROTARY & IT STALLED DUE T/TRQ. PU - PIPE WOULDN'T MOVE. JAR UP W/430K PULL. ADD 8 DRUMS LUBTEX & MIX HI/LO SWEEP. CLEAN RETURNS. CIRC W/NO PK'G OFF. 40 MIN/425K PULL ON PIPE. SLACKOFF & JAR UP-PIPE CAME FREE. POOH T/11684. LD SINGLES W/KELLY T/7" CASG SHOE. NO EXTRA DRAG. CIRC @11684. TRACE SAND IN BU. 100% ANNUL. VOL. POOH LD XO & 3.5" DP F/INSPECTION. HAD 1 CRACKED BOX+ 2 SWOLLEN BOXES. SERV. CONNECTIONS ON 3.5" HWDP. SERV. WEAR BUSHING. SINGLE IN DP T/SURF. LOAD & STRAP DP IN PIPE SHED. PULL WEAR BUSHING, WORKED TOOLSTRING @30'. RAN WEAR BUSHING. MU BHA #8. PU NEW BHA & 92 JTS OF 3.5" DP. SERV. BLOCK LINE-SLIP & CUT. PLANNED MAINT. MW: 9.1 VIS: 62 NO ACCIDENTS, NO SPILLS, UNDER BUDGET. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 11684'. AT 7" CSG SHOE. REAMED TO 12460'. NO HOLE PROBLEMS. REDUCED DRAG & TORQUE AFTER ADDITION OF LUBEX. ON BOTTOM. NO FILL. CIRC AT 12460' OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). CIRC SWEEP. POOH TO 11664'. AT 7" CSG SHOE. MADE SHORT TRIP, NO HOLE PROBLEMS. RIH TO 12460' NO HOLE PROBLEMS, NO FILL. CIRC AT 12460'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). CIRC SWEEP & SPOT XANVISC PILL IN OPEN HOLE. POOH TO 0'. L/D 5" HWDP & 3-1/2" BHA. AT BHA. L/D BHA. RU CSG HANDLING EQUIP. WORK COMPLETED - CSG HANDLING EQUIP IN POSITION. RAN CSG 59 888' HANGER ASSY INSTALLED. RAN 4-1/2" SLOTTED LINER WITH COMPOSITE JTS AND 2-1/16" CIRC STRING. RAN DP IN STANDS TO 7543'. RUNNING IN HOLE WITH SLOTTED LINER ON DP. Anchora WELL : DS 4-22A OPERATION: RIG : NABORS 28E PAGE: 8 08/24/94 (26) TD:12460 PB: 0 08/25/94 (27) TD:12460 PB: 0 08/26/94 (28) TD:12460 PB: 0 08/27/94 (29) TD: 0'( 0) RUN CSG MW: 0.0 Seawater RUN CSG, 4-1/2" O.D. NO ACCIDENTS, NO SPILLS, UNDER BUDGET. RAN CSG TO 12460' RAN 4-1/2" SLOTTED LINER ON STDS OF DP. RAN TO TD WITHOUT PROBLEMS. AT SETTING DEPTH. TESTED STRADDLE/PACK OFF TOOL. PUMP DOWN BALL AND SET PACKER W/3500 PSI. TEST ANNULUS TO 3000 PSI. RELEASED F/HANGER AND SHEAR BALL @ 4700 PSI. BLEED OFF TEST COMPLETED OK - FROM 3000 PSI TO 2940 PSI. 20 MIN TEST OK. CIRC XANVIS FROM SLOTTED LINER. DISPLACE WELL TO SEA WATER. SPOT LIOCL BLEACH IN OPEN HOLE. PULL DP TO TOP OF LINER AND CIRC CLEAN SEA WATER TO SURFACE. CIRC AT 12460' POOH TO 11570' L/D DP TO GET ABOVE SLOTTED LINER. AT TOP OF LINER. CIR~ AT 11570'. CIRC HOLE VOLUME OF CLEAN SEAWATER. HOLE DISPLACED WITH SEAWATER - 130% DISPLACED. PULL DP, 3-1/2" O.D. 3-1/2" X 5" DP. LAID DOWN DP TO 0' COMPLETED OPERATIONS. L/D LINER RUNNING TOOL & 2-1/16" CIRC STRING. RETRIEVED WEAR BUSHING. EQUIP WORK COMPLETED. RU TBG HANDLING EQUIP. WORK COMPLETED - TBG HANDLING EQUIP IN POSITION. RAN TBG TO 2400'. RUN SINGLE COMPLETION MW: 8.4 Seawater RUN SINGLE COMPLETION, 4-1/2" O.D. RAN TBG TO 10868'. HANGER LANDED. HAD BAD THREADS ON TOP OF LANDING JT. COULD NOT MAKE CROSS OVER HOLD. WILL CIRC CORREXIT IN TO WELL & SET PACKER AFTER TREE IS INSTALLED. RD COMPLETION STRING HANDLING EQUIP. WORK COMPLETED, EQUIP LAID OUT. LAID DOWN LANDING JT & SET 2 WAY CHECK VALVE. RD BOP STACK. EQUIP WORK COMPLETED. INSTALL XMAS TREE. EQUIP WORK COMPLETED. TESTED SSSV CONTROL LINE TO 5000 PSI/15 MIN. TESTED ADAPTER FLANGE & TREE TO 5000 PSI. RIG RELEASED MW: 8.4 Seawater RUN SINGLE COMLETION 4.5". CIRC @10868. HOLE DISPLACED W/SEAWATER 100% USING 625 BBLS COREXIT TREATED SEAWATER @3PBPM. SET PACKER @10795. W/4000 PSI. UNABLE T/GET A GOOD TBG TEST DUE T/LEAKAGE PAST SETTING BALL. THERE WAS NO COMMUNICATION T/ANNUL SEEN WHILE PRESS WAS ON TBG. THE CASG/PKR TEST BLED F/3500 T/3000PSI IN 30 MIN. FREEZE PROTECT WELL - 131 BBLS OF DIESEL. RAN SINGLE COMP, INSTALLED HAGR PLUG. RELEASED RIG @ 18:00 HRS ON 8/25. MW: 0.0 VIS: 0 SIGNATURE: (drilling superintendent) DATE: RECEIVED OCT 2_ 8 1994 011 & Gas Cons. Commission Anchor;. ,. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTAT I ON DATE: 8 / 22 / 94 DATE OF SURVEY: 082094 MWD SURVEY JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 54.90 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORD DEGREES DG/100 NORTH/SOUTH EAST INATES /WEST VERT. SECT. 7697 5795.03 5740.13 7772 5840.63 5785.73 7804 5861.65 5806.75 7836 5883.51 5828.61 7868 5906.09 5851.19 55 16 49 47 48 5 45 42 44 30 N 3.00 W .00 4059.78N 166 N 1.84 W 7.40 4119.23N 169 N 1.29 W 5.47 4143.35N 169 N .70 W 7.62 4166.71N 170 N 1.10 E 5.47 4189.37N 170 .59W .12W .79W .19W .12W 4060.89 4120.36 4144.48 4167.84 4190.50 7900 5929.35 5874,45 7931 5952.56 5897,67 7963 5977.15 5922.25 7993 6000.83 5945.93 8024 6025.91 5971,01 42 17 40 42 38 54 36 47 35 12 N 4.09 W 13.09 4211.33N 170 N 2.00 W 6.83 4231.84N 171 N 4.00 W 6.90 4252.29N 172 N 5.00 W 7.29 4270.64N 174 N 2.30 W 7.27 4288.81N 175 .67W .77W .83W .27W .44W 4212.47 4232.98 4253.44 4271.80 4289.98 8052 6049.41 5994.51 8118 6104.50 6049,60 8150 6131.56 6076.67 8244 6211.52 6156.62 8339 6293.01 6238.11 33 42 32 30 32 42 31 12 30 42' N .30 W 6.59 4304.93N 175 N 6.30 E 5.78 4340.73N 173 N 6.80 E 1.04 4357.93N 171 N 5.20 E 1.83 4407.52N 166 N 1.00 E 2.33 4456.28N 164 .81W .97W .99W .77W . llW 4306.10 4341.89 4359.07 4408.62 4457.36 8436 6376.01 6321.11 8531 6458.06 6403.17 8627 6540.85 6485.96 8722 6623.44 6568,54 8818 6707.16 6652.26 30 36 30 17 30 12 29 47 29 23 N 1.60 W 1.38 4505.45N 164 N 2.50 W .57 4553.65N 166 N 3.60 W .59 4601.86N 168 N 5.00 W .85 4649.41N 172 N 4.60 W .46 4696.80N 176 .37W .09W .66W .23W .21W 4506.53 4554.75 4602.97 4650.54 4697.96 8914 6790.65 6735.75 8973 6842.20 6787.30 9052 6910.83 6855.93 9148 6994.14 6939.24 9240 7073.26 .7018.36 29 12 29 17 29 0 30 23 31 0 N 4.60 W .21 4743.50N 179 N 5.70 W .93 4772.25N 182 N 5.70 W .38 4810.34N 186 N 3.60 W 1.82 4857.70N 190 N 2.80 W .79 4904.60N 192 .97W .56W .36W .20W .82W 4744.69 4773.46 4811.57 4858.96 4905.88 9334 71.54.48 7099.58 9428 7235.32 7180.42 9522 7317.06 7262.16 9617 7399.28 7344.38 9711 7480.48 7425.58 30 23 30 12 29 30 30 23 30 17 N 3.40 W .71 4952.76N 195 N 3.20 W .24 4999.91N 198 N 3.70 W .79 5046.74N 200 N 1.30 W 1.58 5094.06N 203 N 1.30 W .11 5141.59N 204 .42W .14W .96W .01W .09W 4954.05 5001.23 5048.07 5095.40 5142.94 9807 7563.19 7508.29 9901 7644.33 7589.44 9995 7725.65 7670.75 10090 7807.16 7752.26 10184 7888.13 7833.23 RECEIVED FEB 1 t97 Alaska Oil & Gas Cons. Commission ^ nnhnron~ 29 47 30 53 30 12 31 6 29 47 N 1.10 W .53 5189.43N 205 N 2.00 W 1.27 5236.92N 206 N 1.60 W .77 5284.89N 207 N 3.20 W 1.28 5333.14N 209 N 3.90 W 1.43 5380.65N 212 M-ICROFILMED · i0W .39W .90W .93W .87W 5190.79 5238.29 5286.27 5334.53 5382.06 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/4-22A 5oo2921454o1 NORTH SLOPE COMPUTATION DATE: 8/22 /94 DATE OF SURVEY: 082094 MWD SURVEY JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 54.90 OPER~ATOR: ARCO ALASKA INC FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10279 7971.01 7916.11 10374 8054.38 7999.48 10468 8135.78 8080.88 10561 8216.95 8162.05 10656 8299.31 8244.41 28 36 N 4.80 W 1.35 5426.84N 216.38W 29 0 N 4.40 W .47 5472.52N 220.05W 30 42 N 3.90 W 1.83 5519.12N 223.43W 29 12 N 5.70 W 1.87 5565.71N 227.32W 29 23 N 5.00 W .42 5611.73N 231.63W 5428.28 5473.98 5520.60 5567.22 5613.27 10669 8310.61 8255.71 10687 8326.78 8271.88 10719 8353.62 8298.71 10752 8380.43 8325.53 10783 8405.13 8350.23 29 30 N 4.42 W 2.36 5618.09N 232.15W 30 53 N 7.20 W 10.54 5627.45N 233.11W 33 24 N 9.00 W 8.44 5644.15N 235.50W 36 12 N 9.00 W 8.57 5662.56N 238.41W 39 5 N 8.20 W 9.43 5681.40N 241.26W 5619.63 5629.00 5645.72 5664.15 5683.01 10814 8428.45 8373.55 10847 8452.70 8397.80 10879 8475.21 8420.30 10909 8495.37 8440.46 10941 8515.71 8460.81 41 35 N 7.80 W 8.21 5701.02N 244.01W 44 12 N 4.50 W 10.38 5723.41N 246.41W 46 35 N 3.20 W 8.03 5746.18N 247.94W 49 30 N 2.00 W 10.06 5768.59N 248.95W 53 5 N 3.60 W 11.71 5793.95N 250.20W 5702.65 5725.06 5747.84 5770.25 5795.63 10972 8533.10 8478.20 11002 8549.08 8494.18 11033 8563.79 8508.89 11066 8578.35 8523.45 11096 8591.54 8536.64 56 17 N .20 W 14.08 5818.48N 251.00W 59 42 N .00 W 11.28 5844.06N 251.04W 63 17 N .10 E 11.68 5871.16N 251.02W 64 24 N 2.50 E 7.32 5900.80N 250.34W 64 48 N .50 E 6.02 5928.56N 249.62W 5820.16 5845.74 5872.84 5902.47 5930.23 11128 8605.09 8550.19 11160 8618.16 8563.26 11193 8631.81 8576.91 11219 8642.84 8587.94 11252 8657.18 ~8602.28 65 18 N 1.50 E 3.22 5957.67N 249.11W 65 35 N .60 W 6.15 5986.28N 248.88W 65 35 N .90 W .83 6016.38N 249.28W 64 11 N 2.00 E 11.45 6039.91N 249.06W 64 30 N 5.30 E 9.03 6069.69N 247.16W 5959.33 5987.94 6018.04 6041.57 6071.33 11283 8670.43 8615.53 11315 8683.60 8628.70 11347 8696.77 8641.87 11376 8707.20 8652.30 11408 8716.98 8662.08 65 24 N 2.00 E 9.98 6097.98N 245.35W 65 11 N 2.90 E 2.67 6126.58N 244.13W 67 5 N 2.10 E 6.25 6156.34N 242.83W 70 0 N 4.30 E 12.44 6182.86N 241.34W 74 11 N 4.00 E 13.23 6213.05N 239.15W 6099.60 6128.20 6157.95 5184.45 6214.63 11440 8724.49 8669.59 11470 8729.38 8674.48 11502 8732.22 8677.32 11535 8733.50 8678.60 11566 8734.05 8679.15 78 35 N 4.00 E 13.78 6244.00N 236.99W 82 54 N 4.40 E 14.19 6273.95N 234.79W 86 54 N 6.30 E 13.82 6305.69N 231.82W 88 35 N 7.70 E 6.75 6338.03N 227.85W 89 24 N 5.70 E 6.92 6368.95N 224.21W 6245.57 6275.49 6307.22 6339.52 6370.42 SPERRY-SIIN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING DBU/4-22A 500292145401 NORTH SLOPE COMPUTATION DATE: 8/22 /94 DATE OF SURVEY: 082094 MWD SURVEY JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 54.90 FT. OPERATOR: ARCO ALASKA INC TRUE SI/B-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COl/RS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11598 8734.35 8679.45 11630 8734.91 8680.01 11651 8735.53 8680.63 11683 8736.41 8681.51 11714 8737.01 8682.11 89 30 N 6.20 E 1.60 6400.66N 220.91W 88 30 N 6.20 E 3.13 6432.43N 217.46W 88 11 N 6.04 E 1.58 6453.81N 215.16W 88 35 N 5.82 E 1.45 6485.19N 211.91W 89 11 N 5.60 E 2.03 6516.47N 208.78W 6402.11 6433.85 6455.21 6486.56 6517.82 11744 8737.28 8682.38 11775 8737.28 8682.38 11810 8736.79 8681.89 11841 8735.40 8680.50 11872 8732.90 8678.00 89 48 N 8.90 E 11.14 6546.34N 204.98W 90 11 N 7.00 E 6.42 6576.30N 200.79W 91 24 N 6.90 E 3.45 6610.96N 196.57W 93 41 N 10.20 E 12.84 6641.88N 191.92W 95 30 N 8.80 E 7.31 6672.49N 186.80W 6547.66 6577.59 6612.22 6643.10 6673.67 11902 8729.94 8675.04 11937 8726.38 8671.48 11968 8723.23 8668.33 11999 8720.56 8665.66 12032 8718.14 8663.24 95 48 N 8.30 E 1.93 6702.07N 182.35W 96 0 N 11.10 E 8.06 6736.05N 176.54W 95 35 N 10.70 E 1.81 6766.49N 170.68W 94 11 N 12.00 E 6.10 6797.04N 164.55W 94 18 N 9.30 E 8.28 6828.93N 158.55W 6703.22 6737.16 6767.55 6798.06 6829.90 12063 8715.97 8661.07 12094 8714.52 8659.62 12127 8713.84 8658.94 12158 8713.50 8658.60 12190 8713.37 8658.47 93 41 N 12.60 E 10.74 6859.45N 152.65W 91 35 N 12.90 E 6.74 6890.09N 145.71W 90 48 N 13.50 E 3.09 6921.62N 138.32W 90 24 N 14.30 E 2.82 6952.35N 130.71W 90 5 N 14.00 E 1.35 6982.72N 123.06W 6860.38 6890.97 6922.44 6953.12 6983.44 12223 8713.05 8658.15 12239 8712.58 8657.68 12254 8711.82 8656.92 12286 8709.77 8654.87 12304 8708.57 8653.67 91 0 N 14.70 E 3.47 7014.52N 114.92W 92 18 N 14.80 E 7.99 7030.29N 110.77W 93 24 N 14.40 E 7.65 7045.08N 106.92W 93 54 N 15.00 E 2.42 7076.19N 98.76W 93 48 N 16.10 E 6.19 7093.31N 93.99W 7015.17 7030.91 7045.67 7076.72 7093.81 12317 8707.73 8652.83 12349 8705.35 8650.45 12381 8702.63 8647.73 12402 8700.67 8645.77 12460 8695.39 8640.49 93 41 N 15.60 E 3.92 7105.76N 90.46W 94 48 N 16.00 E 3.65 7136.54N 81.75W 95 5 N 15.40 E 2.12 7166.75N 73.25W 95 18 N 15.00 E 2.06 7187.52N 67.61W 95 18 N 15.00 E .03 7242.50N 52.88W THE CALCULATION PROCEDURES ARE BASED THREE-DIMENSION MINIMUM CURVATURE ON THE USE OF METHOD. 7106.23 7136.95 7167.10 9187.82 7242.69 HORIZONTAL DISPLACEMENT = 7242.69 FEET AT NORTH 0 DEG. 25 MIN. WEST AT MD = 12460 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 359.58 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTAT I ON DATE: 8 / 22 / 94 DATE OF SURVEY: 082094 JOB NI3MBER: AK-MW-40066 KELLY BUSHING ELEV. = 54.90 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR· COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7697 5795.03 5740.13 4059.78 N 166.59 W 8697 6601.32 6546.42 4636.79 N 171.13 W 9697 7468.01 7413.11 5134.31 N 203.93 W 10697 8334.56 8279.66 5632.13 N 233.73 W 11697 8736.74 8681.84 6498.79 N 210.52 W 1901.97 2095.68 193.71 2228.99 133.31 2362.44 133.46 2960.26 597.81 12460 8695.39 8640.49 7242.50 N 52.88 W 3764.61 804.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMIIM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-22A 5o02921454o1 NORTH SLOPE COMPUTATION DATE: 8/22/94 DATE OF SURVEY: 082094 JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 54.90 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR'COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 7697 5795.03 5740.13 4059.78 N 166.59 W 1901.97 7793 5854.90 5800.00 4135.76 N 169.60 W 1938.94 7934 5954.90 5900.00 4233.85 N 171.84 W 1979.18 8059 6054.90 6000.00 4308.57 N 175.79 W 2004.19 36.97 40.24 25.01 8178 6154.90 6100.00 4372.81 N 170.22 W 2023.20 8295 6254.90 6200.00 4433.64 N 164.56 W 2040.40 8411 6354.90 6300.00 4492.97 N 164.02 W 2056.68 8527 6454.90 6400.00 4551.81 N 166.01 W 2072.72 8643 6554.90 6500.00 4610.02 N 169.17 W 2088.48 19.01 17.20 16.28 16.04 15.76 8758 6654.90 6600.00 4667.35 N 173.80 W 2103.84 8873 6754.90 6700.00 4723.58 N 178.37 W 2118.66 8988 6854.90 6800.00 4779.34 N 183.27 W 2133.26 9102 6954.90 6900.00 4834.79 N 188.72 W 2147.74 9218 7054.90 7000.00 4893.58 N 192.28 W 2163.80 15.36 14.81 14.60 14.47 16.06 9335 7154.90 7100.00 4953.00 N 195.44 W 2180.16 9450 7254.90 7200.00 5011.29 N 198.78 W 2195.96 9565 7354.90 7300.00 5068.16 N 202.28 W 2211.06 9681 7454.90 7400.00 5126.65 N 203.75 W 2226.91 9797 7554.90 7500.00 5184.68 N 205.01 W 2242.54 16.37 15.80 15.10 15.86 15.63 9913 7654.90 7600.00 5243.24 N 206.61 W 2258.44 10029 ~ 7754.90 7700.00 5301.91 N 208.37 W 2274.40 10145 7854.90 7800.00 5361.66 N 211.58 W 2290.94 10260 7954.90 -7900.00 5418.09 N 215.64 W 2305.84 10374 8054.90 8000.00 5472.81 N 220.07 W 2319.92 15.90 15.96 16.54 14.90 14.08 10490 8154.90 8100.00 5530.44 N 224.20 W 2335.42 -10605 8254.90 8200.00 5586.83 N 229.41 W 2350.35 10721 8354.90 8300.00 5645.04 N 235.64 W 2366.27 10850 8454.90 8400.00 5725.64 N 246.55 W 2395.4.0 11014 8554.90 8500.00 5854.40 N 251.04 W 2459.15 15.50 14.93 15. 2 29.13 63 .75 11247 8654.90 8600.00 6064.96 N 247.51 W 2592.37 11277 8667.58 8612.68 6091.78 N 245.61 W 2609.42 133.22 17.05 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPL_.AY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTATION DATE: 2/ 2 DATE O~ SURVEY: 082094 MWD SURVEY JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 55.60 OPERATOR: ARCO ALASKA INC /95 PAGE FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7695 5824.23 5768.63 7700 5827.08 5771.48 7772 5870.48 5814.88 7804 5891.49 5835.89 7836 5913.35 5857.75 55 16 55 17 49 47 48 5 45 42 N 3.00 W .00 4062.20N 166.70W N 2.50 W 8.24 4066.31N 166.90W N 1.84 W 7.74 4122.92N 169.05W N 1.29 W 5.47 4147.05N 169.72W N .70 W 7.62 4170.40N 170.12W 4063.31 4067.41 4124.05 4148.17 4171.53 7868 5935.94 5880.34 7900 5959'.19 5903.59 7931 5982.41 5926.81 7963 6006.99 5951.39 7993 6030.67 5975.07 44 30 42 17 40 42 38 54 36 47 N 1.10 E 5.47 4193.06N 170.05W N 4.09 W 13.09 4215.03N 170.60W N 2.00 W 6.83 4235.53N 171.70W N 4.00 W 6.90 4255.98N 172.76W N 5.00 W 7.29 4274.33N 174.20W 4194.19 4216.16 4236.67 4257.13 4275.49 8024 6055.75 6000.15 8052 6079.25 6023.65 8118 6134.34 6078.74 8150 6161.41 6105.81 8244 6241.37 6185.77 35 12 33 42 32 30 32 42 31 12 N 2.30 W 7.27 4292.51N 175.37W N .30 W 6.59 4308.62N 175.74W N 6.30 E 5.78 4344.43N 173.90W N 6.80 E 1.04 4361.62N 171.92W N 5.20 E 1.83 4411.21N 166.70W 4293.67 4309.79 4345.58 4362.76 4412.31 8339 6322.85 6267.25 8436 6405.86 6350.26 8531 6487.91 6432.31 8627 6570.70 6515.10 8722 6653.28 6597.68 30 42 30 36 30 17 30 12 29 47 N 1.00 E 2.33 4459.97N 164.04W N 1.60 W 1.38 4509.14N 164.30W N 2.50 W .57 4557.35N 166.02W N 3.60 W .59 4605.56N 168.59W N 5.00 W .85 4653.10N 172.16W 4461.05 4510.22 4558.44 4606.66 4654.23 8818 6737.01 6681.41 8914 6820.50 6764.90 8973 6872.04 6816.44 9052 6940.67 6885.07 9148 7023.98 6968.38 29 23 29 12 29 17 29 0 30 23 N 4.60 W .46 4700.50N 176.14W N 4.60 W .21 4747.20N 179.90W N 5.70 W .93 4775.95N 182.49W N 5.70 W .38 4814.03N 186.29W N 3.60 W 1.82 4861.39N 190.13W 4701.65 4748.38 4777.15 4815.26 4862.65 9240 7103.11 7047.51 9334 7184.33 7128.73 9428 7265.16 7209.56 9522 7346.90 7291.30 9617 7429.12 7373.52 31 3O 3O 29 3O 0 23 12 30 23 N 2.80 W .79 4908.30N 192.75W N 3.40 W .71 4956.45N 195.35W N 3.20 W .24 5003.61N 198.07W N 3.70 W .79 5050.43N 200.89W N 1.30 W 1.58 5097.75N 202.94W 4909.57 4957.74 5004.92 5051.76 5099.09 9711 7510.32 7454.72 9807 7593.04 7537.44 9901 7674.18 7618.58 9995 7755.50 7699.90 10090 7837.00 7781.40 30 17 29 47 30 53 30 12 31 6 N 1.30 W .11 5145.28N 204.02W N 1.10 W .53 5193.13N 205.03W N 2.00 W 1.27 5240.62N 206.32W N 1.60 W .77 5288.59N 207.83W N 3.20 W 1.28 5336.84N 209.86W 5146.63 5194.48 5241.98 5289.96 5338.23 RECEIVED FEB 0 199 Alaska Oil & Gas Cons, Ooramissiorl Anchorage MICROFILMED' SPF~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTATION DATE: 2/ 2/95 DATE OF SURVEY: 082094 MWD SURVEY JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10184 7917.97 7862.37 10279 8000.86 7945.26 10374 8084.22 8028.62 10468 8165.63 8110.03 10561 8246.79 8191.19 29 47 N 3.90 W 1.43 5384.34N 212.80W 28 36 N 4.80 W 1.35 5430.54N 216.31W 29 0 N 4.40 W .47 5476.22N 219.98W 30 42 N 3.90 W 1.83 5522.81N 223.36W 29 12 N 5.70 W 1.87 5569.41N 227.25W 5385.75 5431.97 5477.67 5524.29 5570.92 10656 8329.15 8273.55 10669 8340.45 8284.85 10687 8356'.62 8301.02 10719 8383.46 8327.86 10752 8410.27 8354.67 29 23 N. 5.00 W .42 29 30 N 4.42 W 2.36 30 53 N 7.20 W 10.54 33 24 N 9.00 W 8.44 36 12 N 9.00 W 8.57 5615.42N 231.56W 5616.96 5621.78N 232.08W 5623.33 5631.14N 233.04W 5632.69 5647.84N 235.43W 5649.41 5666.25N 238.34W 5667.84 10783 8434.97 8379.38 10814 8458.30 8402.70 10847 8482.54 8426.95 10879 8505.05 8449.45 10909 8525.21 8469.61 39 5 N 8.20 W 9.43 41 35 N 7.80 W 8.21 44 12 N 4.50 W 10.38 46 35 N 3.20 W 8.03 49 30 N 2.00 W 10.06 5685.09N 241.19W 5686.70 5704.71N 243.94W 5706.34 5727.11N 246.34W 5728.75 5749.87N 247.87W 5751.53 5772.28N 248.88W 5773.94 10941 8545.56 8489.96 10972 8562.94 8507.34 11002 8578.92 8523.32 11033 8593.64 8538.04 11066 8608.20 8552.60 53 5 N 3.60 W 11.71 56 17 N .20 W 14.08 59 42 N .00 W 11.28 63 17 N .10 E 11.68 64 24 N 2.50 E 7.32 5797.65N 250.13W 5799.32 5822.17N 250.93W 5823.85 5847.75N 250.97W 5849.43 5874.85N 250.95W 5876.53 5904.49N 250.27W 5906.16 11096 8621.39 8565.79 11128 8634.93 8579.33 11160 8648.00 8592.40 11193 8661.66 8606.06 11219 8672.68 8617.08 64 48 N .50 E 6.02 65 18 N 1.50 E 3.22 65 35 N .60 W 6.15 65 35 N .90 W .83 64 11 N 2.00 E 11.45 5932.26N 249.55W 5933.92 5961.37N 249.04W 5963.02 5989.98N 248.81W 5991.63 6020.07N 249.21W 6021.73 6043.60N 248.99W 6045.26 11252 8687.02 8631.42 11283 8700.27 8644.67 11315 8713.44 8657.84 11347 8726.61 8671.01 11376 8737.04 8681.45 64 30 N 5.30 E 9.03 65 24 N 2.00 E 9.98 65 11 N 2.90 E 2.67 67 5 N 2.10 E 6.25 70 0 N 4.30 E 12.44 6073.38N 247.09W 6075.02 6101.67N 245.28W 6103.29 6130.28N 244.06W 6131.89 6160.03N 242.76W 6161.64 6186.55N 241.27W 6188.14 11408 8746.82 8691.22 11440 8754.33 8698.73 11470 8759.22 8703.62 11502 8762.07 8706.47 11535 8763.35 8707.75 74 11 N 4.00 E 13.23 78 35 N 4.00 E 13.78 82 54 N 4.40 E 14.19 86 54 N 6.30 E 13.82 88 35 N 7.70 E 6.75 6216.74N 239.08W 6218.32 6247.70N 236.92W 6249.26 6277.64N 234.72W 6279.19 6309.39N 231.75W 6310.91 6341.72N 227.78W 6343.22 SPr~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTATION DATE: 2/ 2/95 DATE OF SURVEY: 082094 MWD SURVEY JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11566 8763.89 8708.29 89 24 N 5.70 E 6.92 11598 8764.20 8708.60 89 30 N 6.20 E 1.60 11630 8764.75 8709.15 88 30 N 6.20 E 3.13 11651 8765.37 8709.77 88 11 N 6.04 E 1.58 11683 8766.25 8710.65 88 35 N 5.82 E 1.45 6372.64N 224.14W 6374.11 6404.36N 220.84W 6405.80 6436.13N 217.39W 6437.54 6457.50N 215.09W 6458.90 6488.88N 211.84W 6490.25 11714 8766.86 8711.26 89 11 N- 5.60 E 2.03 11744 8767.12 8711.52 89 48 N 8.90 E 11.14 11775 8767.12 8711.52 90 11 N 7.00 E 6.42 11810 8766.63 8711.03 91 24 N 6.90 E 3.45 11841 8765.24 8709.64 93 41 N 10.20 E 12.84 6520.16N 208.71W 6521.51 6550.03N 204.91W 6551.35 6579.99N 200.72W 6581.28 6614.66N 196.50W 6615.91 6645.57N 191.85W 6646.79 11872 8762.74 8707.14 95 30 N 8.80 E 7.31 11902 8759.78 8704.18 95 48 N 8.30 E 1.93 11937 8756.22 8700.62 96 0 N 11.10 E 8.06 11968 8753.07 8697.47 95 35 N 10.70 E 1.81 11999 8750.40 8694.80 94 11 N 12.00 E 6.10 6676.18N 186.73W 6677.36 6705.76N 182.28W 6706.91 6739.74N 176.47W 6740.85 6770.18N 170.61W 6771.25 6800.73N 164.48W 6801.75 12032 8747.99 8692.39 94 18 N 9.30 E 8.28 12063 8745.81 8690.21 93 41 N 12.60 E 10.74 12094 8744.36 8688.76 91 35 N 12.90 E 6.74 12127 8743.68 8688.08 90 48 N 13.50 E 3.09 12158 8743.35 8687.75 90 24 N 14.30 E 2.82 6832 . 62N 158 . 48W 6833 . 60 6863 . 15N 152 . 58W 6864 . 08 6893 . 78N 145 . 64W 6894 . 66 6925 . 31N 138 . 25W 6926 . 13 6956 . 05N 130 . 64W 6956 . 82 12190 8743.21 8687.61 90 5 N 14.00 E 1.35 12223 8742.90 8687..30 91 0 N 14.70 E 3.47 12239 8742.43 8686.83 92 18 N 14.80 E 7.99 12254 8741.67 8686.07 93 24 N 14.40 E 7.65 12286 8739.61 8684.01 93 54 N 15.00 E 2.42 6986.42N 122.99W 6987.13 7018.21N 114.85W 7018.86 7033.99N l10.70W 7034.61 7048.77N 106.85W 7049.36 7079.88N 98.69W 7080.42 12304 8738.42 8682.82 93 48 N 16.10 E 6.19 12317 8737.57 8681.97 93 41 N 15.60 E 3.92 12349 8735.19 8679.59 94 48 N 16.00 E 3.65 12381 8732.47 8676.87 95 5 N 15.40 E 2.12 12402 8730.51 8674.92 95 18 N 15.00 E 2.06 7097.00N 93.92W 7097.50 7109.45N 90.39W 7109.92 7140.23N 81.68W 7140.64 7170.45N 73.18W 7170.79 7191.21N 67.54W 7191.51 12460 8725.23 8669.63 95 18 N 15.00 E .03 7246.19N 52.81W 7246.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7246.38 FEET AT NORTH 0 DEG. 25 MIN. WEST AT MD = 12460 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 359.58 DEG. SPF--~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTATION DATE: 2/ 2/95 DATE OF SURVEY: 082094 JOB NI/MBER: AK-MW-40066 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7695 5824.23 5768.63 4062.20 N 166.70 W 1871.37 8695 6629.95 6574.35 4639.79 N 171.00 W 2065.65 194.28 9695 7496.65 7441.05 5137.29 N 203.84 W 2198.95 133.30 10695 8363.21 8307.61 5635.10 N 233.56 W 2332.39 133.44 11695 8766.55 8710.95 6501.10 N 210.59 W 2929.05 596.65 12460 8725-.23 8669.63 7246.19 N 52.81 W 3734.77 805.72 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPr~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/4-22A 500292145401 NORTH SLOPE COMPUTATION DATE: 2/ 2/95 DATE OF SURVEY: 082094 JOB NUMBER: AK-MW-40066 KELLY BUSHING ELEV. = 55.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7695 5824.23 5768.63 4062.20 N 166.70 W 1871.37 7748 5855.60 5800.00 4104.66 N 168.42 W 1892.83 21.46 7895 5955.60 5900.00 4211.74 N 170.40 W 1939.52 46.69 8023 6055.60 6000.00 4292.40 N 175.37 W 1968.21 28.69 8143 6155.60 6100.00 4357.92 N 172.36 W 1987.87 19.65 8261 6255.60 6200.00 4419.80 N 165.92 W 2005.65 17.78 8377 6355.60 6300.00 4479.41 N 163.72 W 2022.11 16.46 8493 6455.60 6400.00 4538.48 N 165.20 W 2038.27 16.16 8609 6555.60 6500.00 4596.79 N 168.04 W 2054.06 15.79 8725 6655.60 6600.00 4654.42 N 172.28 W 2069.56 15.50 8840 6755.60 6700.00 4710.94 N 176.98 W 2084.52 14.96 8954 6855.60 6800.00 4766.77 N 181.58 W 2099.14 14.62 9069 6955.60 6900.00 4822.27 N 187.12 W 2113.65 14.51 9184 7055.60 7000.00 4879.91 N 191.29 W 2129.16 15.51 9301 7155.60 7100.00 4939.63 N 194.35 W 2145.67 16.51 9417 7255.60 7200.00 4998.05 N 197.76 W 2161.54 15.87 9532 7355.60 7300.00 5055.34 N 201.21 W 2176.84 15.30 9648 7455.60 7400.00 5113.28 N 203.30 W 2192.44 15.60 9763 7555.60 7500.00 5171.67 N 204.61 W 2208.25 15.80 9879 7655.60 7600.00 5229.50 N 205.93 W 2223.78 15.53 9995 7755.60 7700.00 5288.65 N 207.83 W 2239.98 16.20 10111 7855.60 7800.00 5348.04 N 210.48 W 2256.32 16.34 10227 7955.60 7900.00 5405.79 N 214.28 W 2271.87 15.55 10341 8055.60 8000.00 5460.40 N 218.76 W 2285.90 14.03 10456 8155.60 8100.00 5516.87 N 222.95 W 2300.83 14.93 10571 8255.60 8200.00 5574.31 N 227.74 W 2316.26 15.44 10686 8355.60 8300.00 5630.60 N 233.01 W 2331.14 14.88 10810 8455.60 8400.00 5702.39 N 243.62 W 2354.89 23.75 10959 8555.60 8500.00 5811.55 N 250.72 W 2403.50 48.60 11178 8655.60 8600.00 6006.72 N 249.00 W 2523.17 119.67 11447 8755.60 8700.00 6254.92 N 236.40 W 2691.95 168.78 11475 8759.81 8704.21 6282.56 N 234.33 W 2715.79 23.84 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS CI I::! I I--I_ I IM G S~I:IL~I C E S WELL LOG TRANSMITTAL To: ARCO Alaska Inc. Attn: Larry Grant, AOGCC P.O. Box 100360 Anchorage, Alaska 99510-0360 MWD Formstion Evaluation Logs - DS 4-22A September 15, 1994 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Gamma Ray Logs: 1 Blueline 1 Folded Sepia 2" x 5" TVD Gamma Ray Logs: 1 Blueline 1 Folded Sea~ ' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Date: Subject- From/Location: Telephone: To/Location: P.O. Box 100360, ,chorage, AK September 2, 1994 Transmittal #: ARCO Directional Surveys Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution 94104 99510~ ~, Number '3f Records: Well Number 04-22A Log Date i Tool Type (M-D-Y)1 08-20-94 ~ MWD Survey 05-01A 07-23-94 05-05A 11-23A 08-19-94 07-06-94 11-33 07-22-94 11-33 07-18-94 15-41 08-05-94 MWD Survey MWD Survey MWD Survey Multi-Shot Survey MWD Survey ! MWD Survey *The correct APl number for 05-05A is 5002920170~01. **The correct APl number for 11-23A is 5002921610-01. Karla Zuspan Distribution: Central Files Henry/Touchstone DeDe Schwartz ANO-8 Geology State of Alaska BPX Exxon i Contractor !Sperry-Sun Sperry-Sun Sperry-Sun Sperry-Sun Sperry-Sun Sperry-Sun Sperry-Sun Please ackn~Cccledge by signing and returning a copy of transmittal. ~.~~¢/¢ _~~ Date: ARCO Alaska, Inc. Is a Subsidiary of AtlanUcRIchfleldCompany MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David JohnsOn, Chairm~~_~ Blair Wondzell, P. I. Supervisor DATE: August 16, 1994 FILE NO: AFRIHPBD.doc FROM' Bobby Foster ~ r~. SUBJECT: Petroleum Inspector BOPE Test- Nabors 28E ARCO - PBU - DS 4-22A PTD # 94-97 Prudhoe Bay Field Tuesday, .August 16, 1994: I traveled this date to ARCO's DS 4-22A being redrilled by Nabors 28E and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows there were no failures. The rig was clean and in good shape. The location was clean and there was good access to ali areas of the rig. Summary: I witnessed the BOPE test on Nabors 28E on ARCO's DS 4-22A. Test time 2 hours - no failures. Attachment: AFRIHPBD:XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial Workover: RD DATE: NABORS Rig No. 28E PTD # 94-97 Rig Ph.# ARCO Rep.: JOHN RALL DS4-22A Rig Rep.: Set (~ 7700' Location: Sec. Weekly X Other 8/16/94 659-4864 Laverne Linder 26 T. 11N R. 15E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Test Quan. Pressure P/F 1 300/3,000 P I 500/5,000 P I 500/5,000 P f 500/5,000 P I 500/5,000 P 2 500/5,000 P I 50015,000 P N/A MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure I 500/5, 000 I 500/5, 000 I 500/5,00O I 500/5, 000 CHOKE MANIFOLD: No. Valves '/8 No. Flanges 46 Manual Chokes 2 Hydraulic Chokes I ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Test Pressure 500/5,000 500/5,000 Functioned Functioned P/F P/F Blind Switch Covers: Master: Nitgn. Btl's: 8 @ 2000 2,850 I P 1,450 P 0 minutes 22 sec. I minutes 55 sec. YES Remote: YES Psig. Number of Failures: 0 ,Test Time: 2.0 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I' II I II REMARKS: GOOD TEST. Distribution: orig-Well File c - Oper./Rig c - Database c -Tdp Rpt File c- Inspector STATE WITNESS REQUIRED? YES NO X 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/19) AFRIHPBD.XLS Date: Subject: From/Location' Telephone: To/Location: Number of Records: August 15, 1994 Transmittal #: 94090 ARCO Open hole Magnetic tape(s) Karla Zuspan/ATO- 1529 (907) 263-4310 ~~)fi~ Distribution ~ Well i Log Date Number i (M-D-Y) 4-22A 8-15-94 Tape Type Run, Footage DIFL/AC/CN/GR 1,10580- 11 667 Contractor Atlas Karla Zuspan Distribution: Bob Ocanas Phillips BPX Exxon State of Alaska Please ackn signing and returning a copy of tr~/j.ttal. L~' Date: /~/,, '.- ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 22, 1994 Terry Jordan, Drlg Engr Supv ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 4-22A ARCO Alaska Inc g4-97 1089'NSL, 217'EWL, Sec 26, T11 N, R15E, UM 2255'SNL, 236'EWL, Sec 23, T11N, R15E, UM Dear Mr Jordan: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to ddlling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David V~ohnston ) . Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrillt'-Illb. Type of well. Exploratoryl-i Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE =55.6' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P, O. Box 196612. Anchorage. Alaska 99519-6612 ADL 28323 4. Location of well at surface 7. Unit or property Name 11. Type Bond(sBa 2o ^^c 25.025) 1089' NSL, 217' EWL, SEC. 26, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2281' NSL, 132' EWL, SEC. 23, T11N, R15E 4-22A U-630610 At total depth 9. Approximate spud date Amount 2255' SNL, 236' EWL, SEC. 23, T11N, R15E 7/20/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MDandTVD) property line ADL 28322-236' feet No close approach feet 2560 12468' MD/8735' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 Kickoff depth ZTOO feet Maximum hole anglego, z6 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole" Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 8-1/2" 7" 29# NTCO/ NSCC 4166' 7550' 5710' 11716' 8745' 305 sx Class "G" 13CR 6" 4-1/2" 12.6# 13CR80 NSCT 868' 11600' 8745' 12468' 8735' Uncemented slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured 12893 feet Plugs (measured) JUL 1 8 1994 true vertical 8783 feet Alaska 0il & Gas Cons. Commission Effective depth: measured 12852 feet Junk (measured) Anchorage true vertical 8764 feet . Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 114' 20" 1800 # Poly 1 I4' 114' Surface 2521' 13-3/8" 3000 sx CS III & 2521' 2521' Intermediate 400 sx CS I1 Pro d u ct io n 12201' 9-5/8" 500 sx -c-/~oo sx cs / 12201' 8446' Liner - - 990' 7" 350 sx Class "G" 11898'-12888' 8295'-8781' Perforation depth: measured 12626'-12670', 12686'-12692'(Open) 12612'-12616'(Squeezed) true vertical 8657'-8677', 8685'-8688' (Open) 8651'-8652' (Squeezed) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed reportF'] 20 AAC 25.050 requirements• 21. I hereby certify that the joregoing J,s true and correct to the best of my knowledge Signed ~,//,,/ Title Drilling Engineer Supervisor Date , ~, . ' Commission Use Only Permit Number IAPI number Approval date See cover letter ,,~.~._~ ~ t50_ o2_~_.2._//:¢Z4'._,(~/,_~::~,2 ¢"~ ,-- 2., ~- ~/' for other requirements Conditions of approval Samples required [] Yes ,1~ No Mud Icg required []Yes ,E~ No Hydrogen sulfide measures [] Yes 1~ No Directional survey required [] Yes [] NO Required working pressure for BOPE []2M; I-]3M; .[~5M; I-I10M; ~15M; Other: Original Signed By by order of Approved by David W..Inhnqfnn Commissioner ;ne commission --orm 10-401 Rev. 12-1-85 Submit in triplic~ I WellName: IDS 4-22A Redrill Plan Summary I Type of Redrill (producer or injector): I Producer ISurface Location: Target Location: Bottom Hole Location: 1089' FSL, 217' FWL, SEC 26, T11N, R15E, UM 2281' FSL, 132' FWL, SEC 23, T11N, R15E, UM 2255' FNL, 236' FWL, SEC 23, T11N, R15E, UM I AFE Number: 14J0275 I I Rig: I Nabors 28E I Estimated Start Date: 17/20/94 I I Operating days to complete: 130 IMD: I 12,468' I ITVD: 18,735' I IKBE: I55.6' I Well Design (conventional, slimhole, etc.): I Sidetrack to a Horizontal Completion I Objective: I The proposed horizontal sidetrack is planned to restore production from the I I I DS 4-22 drainage area. I Mud Program: A 9.6 - 9.8 ppg low solids/non-dispersed water based mud will be used in the 8-1/2" hole section. ISpecial design considerations The 6" horizontal hole section will be drilled with a 9.0-9.2ppg Xanvis [ polymer system. I Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) 5797' 9.6 10 15 5 10 15 0 5 to to to to to to to to to 8735' 9.8 20 30 15 30 <8 0 8 Directional'. I KOP: I 7,700'md / 5,797' tvd Maximum Hole Angle: I 90'76° through horizontal section Close Approach Well: I None There are no wells to be secured during the drilling of 4-22a. Redrill Plan Summary RECEIVED JUL 1 8 1994 Alaska Oil & Gas Cons. Commission Anchora,j. o Page 1 Casing/Tubing Program: Hole Sizd Csg/ Wt/Ft' Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29// NT80/13cr nscc 4166' 7550'/5710' 11716'/8745' 6" 4.5" slot 12.64/ 13CR80 nsct 868' 11600'/8745' 12468'/8735' Tubing 4.5" 12.6// 13CR80 nsct 10880' 32/32' 10912'/8513' Cement Calculations: Liner Size: 1 4166' of 7" 29#/ft Basis:1 50% open hole excess, 80' shoe joint, to 1000' above the shallowest hydrocarbon zone- I Sag River Formation @ + 10,912' md Total Cement Volume: I 30~ I s× o~¢la~s ~ ~e,d ~ 1.~8 e~,/~x Well Control-. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVED JUL. 1 8 1994 Alaska Oil & Gas Cons. Commission Anchora~i(~ Redrill Plan Summary Page 2 20. 21. 22. 23. 24. 25. 26. 27. DS 4-22A Operational Summary .... 1. Pre-rig work. 2. Move in drilling rig. 3. Test tree plug. Remove the production tree. 4. Install BOP's and test to 5,000 psi. Remove the test plug and BPV. 5. Circulate diesel freeze protection cap from well and recover for future use if possible. Pull and lay down the 4-1/2" tubing. Tubing should pull out of PBR at 11,844' md. 6. Change 9-5/8" packoff. Set 9-5/8" bridge plug at 7,900' md. Test casing to 3,500 psi 7. Change over to milling fluid & spot a 18 ppg pill on bottom prior to cutting a 50' section in the 9-5/8" casing starting from about 7,700' md. 8. Spot a balanced cement kick-off plug through open-ended drillpipe from 100' below the base of the section to 200' above the toP of the section. (Assume no cement behind the 9-5/8" casing.) 9. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the target with 90° hole angle at 8.692' ss as per the attached directional plan. (Sample catchers should be rigged up by 8,400' TVD.) 10. Run a 7" 29# 13cr / L-80 liner assembly to bottom in the 8-1/2" hole. (Chrome pipe should be run from bottom up to 200' md above the top of Sadlerochit followed with L-80.) Ensure a 150' of liner lap inside the 9-5/8" casing. 11. Cement the liner in place with the total cement volume based upon 50 % open-hole enlargement to 1,000' md above the Sadlerochit plus the 80' shoe volume. (Cement may be calculated based on open hole caliper volume +-20% if caliper was ran.) 12. Re-test BOP's as needed. 13. Run in with 6'-- steerable drilling assembly with GR / MWD on 5"x 3-1/2" drillpipe. Test casing to 3,500 psi for 30 min. before drilling out float shoe and 10' of new hole. 14. Displace well with FIo-Pro Xanvis polymer drilling fluid. 15. Drill approximately .750' of 6" hole to TD as per Geologist / Operations Engineer onsite. 16. CONTINGENT as per O/A engineer: Perforate the future 4-1/2" slotted liner lap via drillpipe conveyed guns. Use 100' of Atlas Wireline's perforating guns @ 5 spf starting from 5' above the bottom of the 7" liner 17. Make a conditioning trip with a 6" hole-opener for the open hole section with a 7" casing scraper spaced to clean the liner. ( Please make sure that the 7" casing scraper is spaced out to 'scrape' where the TIW 'SS' packer will be placed - +120' from 7" liner shoe.) 18. Install a 4-1/2" 13CR80 slotted liner with 4-1/2"X 7" packer / hanger. Run in on drilllSipe with a 2-1/16" wash string inside the slotted liner. Space packer / hanger to be set as close to 7" liner shoe as practically possible. (If the liner lap has been perforated, place the packer 50' above the top perf.) 19. Position packer above the 7" liner shoe and circulate. Set packer and test. Release from the packer / hanger and displace the drilling fluid with filtered seawater but no corrosion inhibitor. After circulating clean with seawater, spot a Xanvis mud breaker in the horizontal hole section. Pull the wash string up just above the hanger and circulate out Xanvis mud above the slotted liner with filtered seawater. Pull out of the hole and lay down the wash string. Run the 4-1/2" 13CR80 completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. After the corrosion inhibitor is in place drop the ball pressure up to 4,000 psi to set the packer. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5,000 psi. Pull tree test plug and BPV. Test the tubing x casing annulus to 3,500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production VHH July 15, 1994 RECEIVED JUL. I 8 1994 Alaska f¢~i & 6as Cons. Commission Anchora~(~ Prudhoe Bay Prudhoe Bay Drill Si[e 04 04-22A Wp1.1 UniL £7 I~URT~N 7114194 9,28 om ]IORIZON2'AL VIEW (!'RUE NORTH) SCALF. 200 rt. ~ I)t-VlSmN SURVEY REF: t',ELGTIEAD VERTICAL VIEW SCALE 500 fL. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD __ 5000 0738 . 6.88' ~?08 - 5.83' 8662 - 4.66' - 2.~5' 550C -- ~3 - 0.09' ,9 - 0. 09' 5797 ~-~--~55.30' ~ 7700 ~b KDP / TIE :N / SIARF [OF CURVE ~ 6.0O'/l(;0 Ft JUL 1 8 1994 ~ "k ~ Alas~ Oil & Gas Cons. Commission 7OOn~ ~ 7269 7500 ---n 7833 8000~ 850.0,,.~ 8334t 874S? 6749- 9000 5088 5359 58 57 I - 0.09' 7 - 358. 16' ]8 - 357.56' P7 357 06 0.34" ¢ 10124 HD K-5 . ~ ~ ~30.34' ~ 10910 MD START OF CURVE ~ 18.00'/100 at %/./20.57' ~ 10912 MD LCU / Sadterochlt / TSAD / Ivishak / Z2 / 2C 57~ E7E7 .... ~_33.52' ~ 10937 MD ZSB / Tango ~ ~48.56' e i1063 ~D Z2A / Romeo 4 ~ ~ I li5 H 1 Iowep Romeo 50535003 SOSO %'"~4~.'9~' ~ 1111~ ~ ~0~ bl/0.6472 7?]7 '--~ ~O o 90.76' 8 18468 HO ESL .76' e ~1716 MD BSL / START OF CURVE e 0.00'/I00 ¢~ 0.75' e 114~5 M~ E~ OF CURVE 5500 6000 6500 7000 7500 I I 4000 4500 5000 VERTICAL SECTION PLANE: 0.08 .-7500 --7250 --7000 ---6750 ~500 ---6250 ---6000 --5750 --5500 --5250 ~75 ---450 --485 ---400O --3750 --3500 ~3250 ---3000 750 CRITICAL POINT D~TA MD KOP /TiE IN / 7700 STARTDr CURVEB 6.00'/!00 ¢¢ END DF CURVE 8117 K-10 9586 K-5 10184 START Or 10910 CURVE 8 18,00'/100 ¢¢ LCU / 1091E TSAD / I¥ish:k / Z8 / 8C ZSA / Rc~eo ZIB / L~-er ROMEO PGOC END DF CURVE BSL / START DF CURVE 8 0.00'/lOO Ft E~L 18468 Inc az;. TVD 55.30' 357.06' 5797 30.34' 0.09' 6101 30.34' 0.09' 7359 30.34' 0.09' 7833 30.34' 0.09' 8511 30.57' 0.17' 8513 10937 33-5~' 1.03' 8534 I]063 48.56' 2.84' . 8629 11115 54.7~' 4.63' 8661 11116 54.93' 4.66' 8662 11416 90.76' 7.89' 8749 11716 90.76' 7.89' 8745 90.76' 7.89' 8735 N/S E/W 4065 N 167 w 4346 N 176 W 5088 N 174 W 5360 N 174 W 5757 N 173 W 5758 N 173 w 5771N !73 w 5852 N 169 w 5894 N 165 V 5895 N 166 w 6175 N ]35 w 6472 N 94 V 7817 N I0 E Taroet Name TVD NS EW Orid X Gr;d Y BSL 8745 6472 N 94 ~ 712738 5959433 ESL 8735 7217 N 10 E 712820 5960180 FauLt 8707 6472 N 94 W 712738 5959433 PoLygon 8717 6585 N 307 ~ 712522 5959540 CASING POINT DATA OD MD Inc Az; TVD N/S E/W PROPOSED BI{L TVD 8734.80 MD 12467.54 VS 7216.54 N/S 7216.53 E/W 9.65 Date PLotted Created By Checked By Apppoved By Date 7/14/94 WELL PERMIT CHECKLIST COMPANY GEOL F ?o UNIT# PROGRAM= exp [] dev~ redrll~ serv [] //~JO ON/OFF SNORE d~ ~J ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool .............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............... Operator has appropriate bond in force .......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING APPR D%TE. er 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. tY~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~ N 23.22. Adequate wellbore separation proposed .......... If diverter required, is it adequate ........... Drilling fluid program schematic & equip list adequate .~ N 24. 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~7~ psig.~Y/ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... .~ N 29. Is presence of H2S gas probable ............. Y GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~/_ 31. Data presented on potential overpressure zones ..... Y/N ~/ ~ 32. Seismic analysis 9f shallow gas zones .......... / N /~'~" I · 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./J . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~ 7/~S~:~~ ~.~~ Comments/Instructions: O '"':~MS~cheklist rev 03/94 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAlW~E : ARCO ALASKA, INC. WELL NAME : D.S. 4-22A FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292145401 REFERENCE NO : 98051 MiC OFILMED LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14: 06 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/30 ORIGIN : FLIC REEL NAME : 98051 CONTINUATION # : PREVIOUS REEL : CO~IENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-22A, API# 50-029-21454-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/30 ORIGIN . FLIC TAPE NAM~ : 98051 CONTINUATION # : 1 PREVIOUS TAPE : CO~4~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-22A, API# 50-029-21454-01 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4 -22A API NUMBER: 500292145401 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 30-JAN-98 JOB NUMBER: 98051 LOGGING ENGINEER: J Maj cher OPERATOR WITNESS: K Neupert SURFACE LOCATION SECTION: 2 6 TOWNSHIP: 1 iN RANGE: 15E FNL: 1089 FSL : FEL : FWL : 217 ELEVATION(FT FROM MSL O) KELLY BUSHING: 54.90 DERRICK FLOOR: 53.40 GROUND LEVEL: 20.40 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.675 7700.0 47.00 7.000 11684.0 29.00 4.500 12460.0 12.60 4.500 10869.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 15-AUG- 94 LOGGING COMPANY: ATLAS WIRELINE BASELINE DEPTH 88888.0 11370.5 11368.0 11363.0 11362.5 11356.5 11352.5 11347.0 11337.0 11329.0 11317.0 11316.0 11310.5 11309.5 11305.5 11303.5 11294.5 11294.0 11292.0 11291.5 11286.0 11285.5 11280.0 11273.0 11266.0 11254.5 11253.5 11249.0 11237.0 11236.5 11233.5 11230.0 11222.5 11221.5 11216.5 11216.0 11208.5 11200.0 11199.0 11197.0 11196.5 11192.0 11191.5 11182.5 11175.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.0 88887.0 11369.5 11369.5 11365.5 11365.5 11362.5 11362.5 11355.0 11355.0 11351.0 11351.0 11344.5 11344.5 11336.5 11336.5 11329.0 11329.0 11319.5 11319.5 11310.0 11309.5 11303.5 11300.0 11300.0 11295.0 11295.0 11292.0 11292.0 11287.5 11287.5 11279.5 11279.5 11272.0 11272.0 11264.0 11264.0 11253.5 11253.5 11247.5 11247.5 11237.0 11237.0 11235.0 11235.0 11231.0 11231.0 11224.0 11223.5 11218.5 11218.5 11207.0 11207.0 11202.5 11202.0 11199.0 11199.5 11193.0 11191.5 11183.0 11183.0 11175.0 11175.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11167.0 11166.5 11163.5 11157.5 11157.0 11154.5 11154.0 11151.5 11151.0 11145.0 11144.0 11141.5 11135.0 11130.0 11126.0 11125.5 11121.0 11120.5 11114.5 11105.0 11098.5 11094.0 11092.5 11089.5 11083.5 11081.0 11072.0 11064.0 11060.0 11056.5 11049.5 11048 0 11047 5 11046 5 11042 0 11040 5 11039 5 11037 5 11035 5 11026 0 11025 5 11024.5 11020.5 11012.0 10991.5 10990.5 10987.5 10973.0 10970.0 10968.0 10957.0 10944.0 10935.5 10930.0 10928.0 10922.5 11166.0 11166.0 11163.5 11163.5 11158.5 11158.5 11155.0 11152.0 11144.5 11155.0 11152.0 11144.5 11141.0 11141.0 11135.5 11135.5 11130.0 11130.0 11125.0 11125.0 11119.5 11119.5 11115.5 11115.5 11108.0 11108.0 11099.0 11099.0 11094.5 11094.5 11091.5 11091.5 11087.5 11082.5 11080.0 11080.0 11073.0 11073.5 11062.5 11059.0 11059.0 11055.0 11055.0 11050.0 11050.0 11047.5 11047.5 11039.0 11027.0 11024.0 11044.0 11039.0 11036.0 11034.0 11032.5 11024.0 11020.5 11020.5 11011.5 11011.5 10995.0 10995.0 10989.5 10989.5 10974.0 10974.0 10969.0 10969.0 10964.5 10964.5 10954.0 10954.0 10941.5 10941.5 10933.5 10933.5 10928.0 10928.0 10927.0 10927.0 10922.5 10922.5 30-JAN-1998 14:06 PAGE: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 10915.0 10910 0 10907 5 10905 5 10903 5 10899 5 10895 5 10891 5 10888 0 10884 0 10882 0 10874 0 10873 5 10871 5 10870 0 10864 5 10862 0 10856.5 10856.0 10848 0 10845 5 10845 0 10837 5 10835 5 10834 5 10827.0 10826.5 10826.0 10820.0 10819.5 10818.5 10816.5 10816.0 10813.0 10809.0 10806.5 100.0 $ REMARKS: 10916.0 10914.0 10912.0 10906.0 10902.5 10899.5 10889.0 10882.5 10874.5 10871.5 10860.5 10852.5 10846.5 10844.5 10839.0 10835.5 10828.5 10826.0 10821.5 10820.0 10817.0 10916.0 10914.0 10912.0 10906.0 10902.5 10899.5 10896.0 10891.5 10889.0 10884.0 10882.5 10875.0 10871.0 10865.0 10860.5 10852.5 10846.5 10844.5 10839.5 10835.5 10828.5 10826.0 10821.5 10820.0 10817.0 10814.0 10810.0 10810.5 10807.5 10807.5 101.0 101.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 4-22A WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GANflv~A RAY, ALSO NPHI PASS #1 AND THE BCS G~RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE . 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11371.0 10805.0 CNTG 11377.0 10805.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 ATRAT CNTG 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1094425 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11450.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG AFRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS DEPT. 10775.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS -999.250 -999.250 -999.250 49.999 -999.250 -999.250 -999.250 317.108 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS N73M~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUMPIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11388.5 10804.0 CNTG 11397.5 10804.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASSNUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.5 88891.5 11371.0 11374.5 11366.5 11369.5 11365.5 11366.0 11363.5 11366.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 8 11358.0 11352.0 11349.5 11348.0 11346.0 11344.5 11341.0 11337.0 11329.5 11327.5 11324.0 11320.5 11316.5 11312.0 11306.0 11305.0 11303.5 11302.0 11300.5 11296.0 11295.5 11294.5 11289.5 11287.0 11284.0 11282.5 11281.0 11280.5 11278.0 11277.0 11273.5 11273.0 11269.0 11268.5 11264.0 11260.0 11259.5 11253.5 11252.5 11250.5 11249.5 11247.5 11246.5 11239.5 11238.0 11229.0 11225.0 11221.0 11219.0 11214.0 11213.5 11209.5 11207.0 11206.5 11200.0 11358.0 11354.0 11351.0 11350.0 11347.0 11345.0 11344.5 11341.0 11336.5 11336.5 11329.0 11329.0 11325.5 11326.5 11323.5 11316.0 11311.5 11310.5 11307.5 11304.0 11305.0 11301.5 11300.0 11298.5 11295.0 11295.0 11291.5 11290.5 11287.5 11287.5 11285.5 11281.0 11278.0 11272.5 11266.0 11285.5 11282.0 11276.5 11272.5 11270.5 11262.5 11262.5 11260.0 11261.0 11253.5 11252.0 11247.5 11253.5 11251.0 11249.0 11239.5 11239.5 11237.5 11236 5 11231.0 11231 0 11227 5 11223 5 11222.0 11221 0 11217 5 11218.5 11210.5 11210.0 11206.0 11207.0 11202.0 11203.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 11197 5 11195 5 11192 5 11191 0 11188 0 11187 5 11186 5 11185 0 11179 5 11178 5 11172.5 11166.0 11164.5 11159.5 11158.5 11154.0 11152.5 11148.0 11145.5 11145.0 11143.5 11140.5 11138.0 11137.0 11135.5 11131.0 11126.0 11125.5 11120.5 11120.0 11110.0 11105.5 11101.5 11099.5 11098.5 11092.0 11091 5 11090 0 11087 5 11083 0 11077 0 11074 5 11071 0 11069 5 11067 5 11065 0 11064 0 11061 5 11061 0 11058 0 11057.0 11055.5 11053.5 11052.0 11050.0 11199.0 11195.5 11191.0 11189.5 11186.5 11179.0 11171.0 11166.0 11164.0 11159.5 11155.0 11146.0 11144.5 11141.0 11138.0 11135.5 11125.0 11119.5 11111.5 11107.5 11103.0 11098.5 11091.5 11087.5 11086.0 11080.0 11075.0 11073.0 11066.5 11063.5 11060.5 11059.0 11055.5 11052.5 11050.0 11198.0 11187.5 11183.0 11178.5 11171.0 11166.0 11164.0 11159.5 11155.0 11153.0 11147.0 11144.5 11141.0 11137.0 11135.5 11132.0 11124.5 11119.5 11111.5 11107.5 11103.0 11099.0 11092.0 11081.5 11075.0 11073.0 11070.5 11067.0 11063.5 11061.0 11056.5 11052.5 11051.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 10 11048 5 11044 0 11042 5 11040 0 11036 5 11030 0 11027 5 11024 5 11022 5 11021 5 11020 5 11019.0 11014.5 11012.5 11009.5 11002.5 10998.0 10997.5 10996.0 10994.0 10992.5 10990.0 10989.0 10988.5 10987.5 10986.5 10980.0 10977.0 10976.0 10971.5 10969.0 10967.5 10965.5 10960.0 10957.5 10954.5 10954.0 10952.5 10947.5 10945.5 10942.0 10941.5 10931.0 10929.5 10929.0 10916.5 10907.0 10905.0 10903.0 10900.5 10696.5 10889.0 10887.5 10885.0 10884.0 11047.5 11044.0 11041.5 11038.5 11027.0 11024.0 11020.5 11008.5 11000.0 10998.0 10995.0 10991.0 10988.0 10974.0 10968.5 10964.5 10956.0 10954.5 10943.5 10941.5 10932.5 10931.0 10911.5 10906.0 10902.5 10889.0 10886.0 11047.5 11042.0 11038.0 11034.5 11026.5 11024.0 11022.0 11021.0 11020.0 11016.0 11012.0 11008.5 11003.5 10998.0 10995.0 10993.0 10991.5 10989.0 10981.5 10979.5 10970.0 10965.0 10962.0 10952.5 10950.5 10946.0 10942.0 10932.5 10930.0 10915.0 10906.0 10902.5 10895.0 10890.0 10884.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 11 10873.5 10875.0 10875.0 10870.5 10870.5 10867.5 10869.0 10864.0 10865.0 10863.0 10863.0 10861.5 10860.5 10860.0 10861.0 10858.0 10854.5 10855.5 10852.5 10853.0 10851.5 10850.0 10849.0 10846.5 10846.5 10845.5 10845.5 10844.0 10844.0 10842.5 10844.5 10841.0 10841.0 10838.0 10838.5 10834.0 10834.5 10833.0 10833.5 10830.0 10830.0 10829.5 10830.0 10825.5 10826.0 10824.0 10824.5 10821.5 10822.5 10820.0 10821.5 10818.0 10820.0 10816.0 10820.0 10815.5 10817.0 10814.0 10814.0 10815.5 10810.5 10814.0 10809.0 10810.5 10807.0 10807.0 10807.5 100.0 100.0 100.5 $ ~KS: CONTAINED HEREIN IS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BE~gEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 12 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB IvTJMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) DEPT FT 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1094425 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11397.500 NPHI.CNTG 33.204 ENPH. CNTG 29.826 CPHI.CNTG NRAT. CNTG 3.058 CRAT. CNTG 3.224 ENRA.CNTG 4.643 NCNT. CNTG FCNT. CNTG 611.648 CNTC. CNTG 1968.269 CFTC. CNTG 668.695 CNEC. CNTG CFEC. CNTG 602.915 GRCH. CNTG -999.250 TENS.CNTG 1500.000 DEPT. 10804.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC.CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 66.500 TENS.CNTG -999.250 25.332 1942.615 2799.358 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 13 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION · O01CO1 DATE · 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION . O01CO1 DATE · 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11392.0 10800.0 CNTG 11397.0 10801.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88888.0 88887.0 11370.5 11369.5 11366.5 11366.5 11366.5 11361.5 11360.0 11361.0 11362.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 14 11356.0 11356.5 11352.0 11351.0 11350.0 11350.0 11345.5 11344.5 11340.5 11341.5 11339.5 11341.0 11337.0 11336.5 11335.0 11336.0 11332.5 11334.0 11325.5 11326.0 11324.0 11327.0 11318.5 11321.5 11318.0 11319.5 11315.5 11319.5 11314.0 11316.0 11311.5 11311.5 11310.0 11310.5 11306.5 11305.5 11302.5 11302.0 11301.5 11303.5 11299.0 11300.0 11297.0 11296.0 11294.0 11294.5 11290.5 11292.0 11289.5 11291.0 11286.5 11287.5 11281.0 11282.0 11279.0 11281.0 11278.0 11276.5 11276.5 11278.0 11276.0 11272.0 11272.5 11272.0 11267.0 11264.5 11264.5 11262.5 11260.5 11260.0 11256.5 11257.5 11253.5 11253.5 11252.0 11252.5 11249.0 11249.5 11247.5 11249.0 11247.0 11247.5 11242.0 11242.0 11240.0 11241.0 11237.0 11237.0 11236.5 11236.5 11230.0 11231.0 11225.5 11227.5 11222.5 11222.0 11222.0 11223.5 11216.5 11217.5 11210.5 11210.5 11206.0 11206.0 11201.5 11203.5 11200.5 11203.0 11199.0 11202.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 15 11196.5 11194.0 11191.5 11190.0 11185.0 11184.5 11180.5 11177.5 11176.5 11172.5 11170.5 11169.0 11167.5 11166.0 11164.5 11163.0 11160.0 11159.0 11152.5 11149.0 11145.5 11143.5 11141.0 11136.5 11135 5 11132 0 11128 0 11125 5 11123 5 11121 0 11120 5 11112.0 11111.5 11109.5 11103.0 11099.5 11098.5 11095.5 11093.0 11092.5 11090.0 11087.5 11084.0 11083 5 11081 0 11079 0 11075 5 11074 5 11070 0 11068 0 11065 0 11060.0 11058.5 11055.5 11052.5 11199.0 11191.5 11183.5 11175.0 11171.0 11168.5 11166.0 11164.0 11159.0 11152.0 11141.0 11135.5 11130.0 11125.0 11118.5 11110.0 11107.5 11098.5 11091.5 11086.0 11080.0 11078.5 11073.0 11066.5 11062.0 11059.0 11197.5 11187.0 11183.0 11180.5 11176.0 11173.0 11168.0 11162. 0 11161. 0 11150.5 11148.0 11144.5 11137.0 11132.0 11124.5 11119.5 11113.5 11105.5 11098.5 11096.0 11092.0 11088.5 11081.5 11077.5 11073.5 11062.5 11058.0 11054.0 11051.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 1 6 11051.5 11052.5 11048.0 11050.0 11047.5 11047.5 11046.5 11047.5 11046.0 11045.0 11045.5 11044.0 11044.5 11043.5 11041.0 11037.5 11040.5 11038.5 11033.0 11035.0 11027.0 11026.5 11025.5 11024.0 11024.5 11024.0 11021.5 11020.5 11020.0 11014.0 11012.0 11012.5 11011.5 11010.5 11010.5 11009.0 11003.0 11007.5 11009.0 11004.0 10999.5 11001.5 11000.0 10999.5 10998.5 10996.0 10997.5 10996.0 10992.0 10991.0 10990.0 10992.5 10987.0 10988.0 10981.5 10982.0 10978.5 10980.5 10975.0 10976.0 10974.5 10974.0 10970.5 10969.5 10963.5 10963.5 10955.5 10954.5 10953.0 10953.5 10946.5 10946.0 10946.0 10943.5 10943.0 10942.0 10939.0 10938.5 10936.5 10936.5 10934.0 10933.0 10932.5 10930.5 10927.5 10925.5 10922.5 10922.5 10915.5 10911.5 10914.5 10914.5 10907.5 10905.5 10903.0 10902.5 10897.5 10896.5 10896.0 10893.5 10893.0 10889.5 10890.5 10892.5 10888.5 10890.0 10885.0 10884.5 10882.0 10882.5 10876.5 10878.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 1 7 10876. 10872. 10870. 10867. 10866. 10863 10860 10859 10857 10855 10854 10851 10851 10847 10844 10843 10842 10838 10834 10833 10830 10829 10828 10826. 10821 10820 10819 10818 10817 10812 10811 10807 10806. 10805. 100. $ 0 10878.0 5 10874.5 5 10870.5 5 10866.5 0 10865.0 0 10862.5 5 10861.0 5 10860.5 5 10857.5 5 10856.0 5 10854.0 5 10851.5 0 10849.0 0 10846.5 0 10844.5 0 10844.0 0 10842.0 0 10836.0 10840.0 0 10834.0 5 10830.0 0 10830.5 5 10828.5 0 10826.0 0 10826.0 5 10820.0 5 10822.5 5 10817.0 0 10820.0 5 10814.0 0 10814.0 0 10810.5 0 10807.5 0 10807.5 5 10805.5 0 100.0 101.5 REMARKS: CONTAINED HEREIN IS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 1094425 NPHI CNTG PU-S 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1094425 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11397.000 NPHI. CNTG 29.477 ENPH. CNTG 35.852 CPHI.CNTG NRAT. CNTG 3.055 CRAT. CNTG 3.020 ENRA.CNTG 5.238 NCNT. CNTG FCNT. CNTG 706.798 CNTC. CNTG 2018.719 CFTC. CNTG 673.941 CNEC. CNTG CFEC. CNTG 500.792 GRCH. CNTG -999.250 TENS. CNTG 1470.000 26.106 2077.353 2623.283 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14: 06 PAGE: 19 DEPT. 10800.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 65.563 TENS.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE : 98/01/30 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG $ REMARKS: THIS FILE CONTAINS THE ARITHNETIC AVERAGE OF PASSES 1,2~ &3.THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1094425 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11377.000 NPHI.CNAV 29.956 NRAT. CNAV 2.995 CPHI.CNAV CRAT. CNAV 3.046 ENPH. CNAV 34.785 ENRA.CNAV 5.125 NCNT. CNAV FCNT. CNAV 646.421 CNTC. CNAV 1971.783 CFTC. CNAV 674.514 CNEC. CNAV CFEC. CNAV 530.318 GRCH. CNTG -999.250 27.244 2077.080 2698.508 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 21 DEPT. 10805.000 NPHI. CNAV 42.074 NRAT. CNAV CRAT. CNAV 3.710 ENPH. CNAV 28.472 ENRA.CNAV FCNT. CNAV 422.479 CNTC. CNAV 1607.913 CFTC. CNAV CFEC. CNAV 824.058 GRCH. CNTG 61.656 3.897 CPHI.CNAV 4.501 NCNT. CNAV 463.458 CNEC. CNAV 33.459 1619.223 3707.965 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE · 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH CNTG 11390.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) : STOP DEPTH 10803.5 06-NOV-97 CP 44.2 2055 06-NOV-97 11400.0 11400.0 10800.0 11400.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14: 06 PAGE: 22 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlVk4A RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER SGTL 479 CNTG H 67 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12460.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude 30.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 ArEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: CORRELATION LOG: ATLAS BHCA 15-AUG-94. PUMPING CRUDE AT 6.5 BBLS/MIN REQUIRED TO REACH 11400. GR SPIKES SEEN FROM STOPS. Estimated GOC @ 11240' THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1094425 NPHI PS1 PU 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PSI 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PSI PU 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1094425 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 11390. 500 NPHI. PS1 TNRA. PS1 3. 145 RTNR . PS1 CNEC. PS1 2809. 373 RCEF. PS1 RCFT. PS1 663 . 949 CNTC. PSi GR. PS1 28. 703 TENS. PS1 DEPT. 10803.500 NPHI.PS1 TN-RA.PS1 3.543 RTNR.PS1 CNEC. PS1 3747.145 RCEF. PS1 RCFT. PS1 471.798 CNTC.PS1 GR.PS1 44.000 TENS.PSI 30-JAN-1998 14:06 31.772 ENPH. PS1 3.212 ENRA.PS1 562.626 RCEN. PS1 2072.214 CFTC.PSi 1565.000 39. 025 ENPH. PS1 3. 933 EIVRA. PS1 808. 277 RCEN. PS1 1613.540 CFTC. PS1 1625. 000 33.306 TNPH. PS1 4.993 CFEC. PS1 2632.954 RCNT. PS1 672.219 NPOR.PS1 27.575 TNPH. PS1 4.407 CFEC. PS1 3453.171 RCNT. PS1 456.414 NPOR.PS1 PAGE: 24 33.660 562.631 2168.833 33.660 34.505 850.366 1740.079 33.279 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION . O01CO1 DATE . 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE · 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SOY4MARY VENDOR TOOL CODE START DEPTH CNTG 11410.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH 10803.5 06-NOV-97 CP 44.2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 25 TIME LOGGER ON BOTTOM: TD DRILLER (FT) '. TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 2055 06-NOV-97 11400.0 11400.0 10800.0 11400.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAM~A RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER SGTL 479 CNTG H 67 BOREHOLE A1VD CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12460.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Crude 30.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: CORRELATION LOG: ATLAS BHCA 15-AUG-94. PUMPING CRUDE AT 6.5 BBLS/MIN REQUIRED TO REACH 11400. GR SPIKES SEEN FROM STOPS. Estimated GOC @ 11240' THIS FILE CONTAINS THERAW DATA FOR PASS #2. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 26 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 RTArR PS2 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1094425 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 27 ** DATA ** DEPT. 11410.000 NPHI.PS2 TNRA.PS2 2.880 RTNR.PS2 CNEC. PS2 2748.594 RCEF. PS2 RCFT. PS2 685.971 CNTC. PS2 GR.PS2 14.391 TENS.PS2 26.935 ENPH. PS2 2.941 E1VRA.PS2 614.800 RCEN. PS2 1957.090 CFTC.PS2 1635.000 28.179 TNPH. PS2 4.471 CFEC. PS2 2575.992 RCNT. PS2 694.515 NPOR.PS2 23.488 614.805 2048.341 23.488 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE .FLIC VERSION .O01CO1 DATE : 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE · 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH ........................... CNTG 11413.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 10799.0 06-NOV-97 CP 44.2 2055 06-NOV-97 11400.0 11400.0 10800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 28 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 11400.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER SGTL 479 CNTG H 67 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12460.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G) : SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATYIRE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOF~E (DEG) : Crude 30.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: CORRELATION LOG: ATLAS BHCA 15-AUG-94. PUMPING CRUDE AT 6.5 BBLS/MIN REQUIRED TO REACH 11400. GR SPIKES SEEN FROM STOPS. Estimated GOC @ 11240' THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 29 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 7 1 1 4 68 0000000000 DEPT FT 1094425 NPHI PS3 PU 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 RCENPS3 CPS 1094425 O0 000 O0 0 7 1 1 4 ~8 0000000000 RCNT PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1094425 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-JAN-1998 14:06 PAGE: 3O DEPT. 11413.500 NPHI.PS3 TNRA.PS3 3.280 RTNR.PS3 CNEC. PS3 2493.624 RCEF. PS3 RCFT. PS3 633.525 CNTC.PS3 GR.PS3 22.563 TENS.PS3 DEPT. 10799.000 NPHI.PS3 TNRA.PS3 3.574 RTWR.PS3 CNEC. PS3 3777.190 RCEF. PS3 RCFT. PS3 472.891 CNTC.PS3 GR.PS3 50.688 TENS.PS3 34.219 ENPH. PS3 3.349 ENRA.PS3 562.626 RCEN. PS3 2062.191 CFTC. PS3 1540.000 39.580 ENPH. PS3 3.660 ENRA.PS3 902.255 RCEN. PS3 1743.269 CFTC.PS3 1590.000 27.815 TNPH. PS3 4.432 CFEC. PS3 2337.033 RCNT. PS3 641.416 NPOR.PS3 25.781 TNPH. PS3 4.212 CFEC. PS3 3503.114 RCNT. PS3 519.399 NPOR.PS3 29.443 562.631 2158.342 29.443 31.646 896.751 1778.492 32.657 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION . O01CO1 DATE : 98/01/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE . 98/01/30 ORIGIN · FLIC TAPE NA~!E : 98051 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-22A, API# 50-029-21454-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/30 ORIGIN · FLIC REEL NAME · 98051 CONTINUATION # : PREVIOUS REEL : COM~IENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-22A, API# 50-029-21454-01 l'ape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWS/MAn LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 AK MW 40066 R. JACKSON J. RALLS D.S. 4-22A 500292145401 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 15-AUG-96 MWD RUN 9 R. JACKSON J. RALLS MWD RUN 10 R. JACKSON J. RALLS MWD RUN 12 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD R. JACKSON J. RALLS 26 lin 15E 1089 217 54.90 53.40 20.40 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 1ST STRING 2ND STRING 3RD STRING 8.500 7.000 PRODUCTION STRING 6.000 4.500 REMARKS: MICROFILM[I) DRILLERS t l: AI _ 11684.0 12460.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY. NO DATA IS PRESENTED. THIS WELL, D.S. 4-22A, WAS DRILLED WITH RUNS 8 - 12. NO FOOTAGE WAS DRILLED ON RUN 11. MWD RUNS 8, 9, 10, & 12 WERE DIRECTIONAL & GAMMA RAY (NGP/SGRD) . A 4 3/4" DGWD GAMMA RAY LOGGED THE 6" HOLE FROM 11684 - TD (RUN 12) . A PRE-POST GAMMA RAY SAMPLE WAS TAKEN PRIOR TO MUD DISPLACEMENT TO XANVIS: PRE AVERAGE OF 30 SAMPLES = 30.2 AAPI POST AVERAGE OF 30 SAMPLES = 34.1 AAPI DIFFERENCE = +3.9 AAPI. '~OH~O~ SIHI HO~ H£d~G ~HI SI ©0~ SIH£ S~ G~Iqdd~ ~H~M S£~IHS Hid~G FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10606.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 10607.5 10608.0 10628.5 10628.5 10636.5 10636.5 10653.0 10653.0 10662.0 10662.0 10679.5 10679.5 10679.5 10680.5 10689.0 10690.0 10704.0 10705.0 10708.5 10708.0 10713.5 10712.5 10716.5 10716.0 10718.5 10718.0 10720.5 10720.0 10723.5 10723.0 10725.0 10724.5 10727.0 10726.5 10731.0 10731.0 10733.0 10732.5 10735.0 10735.0 10759.5 10760.5 10764.0 10763.5 10765.5 10766.5 10773.0 10773.0 10774.5 10774.5 10776.0 10777.0 10779.5 10779.5 10784.0 10784.5 10786.5 10787.0 10788.0 10788.0 10792.0 10792.5 10795.5 10795.5 10797.0 10797.5 10803.5 10803.5 10807.5 10807.0 10814.0 10813.5 10817.0 10816.5 10819.5 10818.5 10821.5 10820.5 10839.5 10839.0 10843.5 10843.5 10844.5 10844.0 10862.5 10862.0 10865.0 10865.0 all bit runs merged. STOP DEPTH 12399.0 EQUIVALENT UNSHIFTED DEPTH (f9 #.~dX,T.) G~OD.~ ,T,¥N~O.~ ~ ~d0qS Hi~ON : NiIOD X~ ~OHCEI~d : ~SE-~ 'S'~ : NM 'tf~S~ OD%{tf : .T,aO ',T,, IHS / 0'09~I 0'589II 0'04£II 0'£~0II 'HD HIIM QH£~IHS SWM 'SSWd NItfI4 0'~89II ~I 0'0L£II 0I 0'£~0II 6 0'8990I 8 dOi ~DH~ ON Nfl~ iI~ fi'0I~IT 0'96£IT S'IL£II fi'0L£II 0'9S£II 0'~££II 0'L0£II 0'06git S'S~EII S'8£~II S'9£EII S'££EII 0'66III '0'S6III S'I6III 0'09III 0'9EIII 0'~60II 0'£80II S'980II S'E90II 0'L~0II S'I~0II 0'9EOII 0'~EOII 0'I00II 0'~660I 0'~860I S'9£60I S'9060I 0'E680I 0'~£80I CIMN CIMN (/MN ,~CIOD ~iO0,T, fl~tcI .~D%IflOS tf, T,lf~ 0'80~II- 0'£6£II S'EL£II 0'89£II S'L9£II 0'£~£II 0'8££II S'LE£II S'~0£II S'68EII 0'9SEII 0'9~EII 0'6£EII S'66III 0'~6III ~'16III 0'09III 0'£~III 0'EEIII 0'£60II 0'980II 0'980II 0'Ig0II 0'8~0II S'I~0II S'SEOII 0'~EOII 0'6660I S'0660I 0'I860I S'SL60I 0'S060I S'0680I 0'££80I ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 45 Tape File Start Depth = 12465.000000 Tape File End Depth = 10600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary:- Rep Code: 68 11194 datums Tape Subfile: 2 224 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 O' : (ZH) xoM.wn0,wH,~ ~M,w : (MI) ,~,~0GNtf£S ~IOOi 000 ' 00' : (MI) NOIIDZ~HOD ZqOH :XIISM~G XIHItfM ~OOi MOMLfl~M O, 0' 6' PEI 0' 000 ' 000 ' 000 ' 000 ' . 008 6'0I 0' 08'6 GNS~I . 00~'8 : (i,~) HZdZG DMISIfD S : (NI) ZZIS ,l,I~ Z~IOH ~f.I,~fG DMISIfD GNIf Z~IOHZ%{O~{ ~Z~NflN ,, 0 0'£P0II 0'8990I 0'£P0II ~£'S ~9I'~ lIMN ,~dXi ~IOOi Z(IOD ~IOOi ~IOGM~LA_ (NOi.T,Of5 Oi dOi) DMIMLS ~IOOi 0'I860I 's@II~ s~Pdss uT un~ ~Iq qo~ ~o~ ~p ~ap~sq 5oi pu~ SSA~nO :~Z~NflN Z~I~ ~ZGIfZH Z~I~ SIq :eclK~ sT £ eIT~qn$ edei CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 4-22A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File Start Depth = 11050.000000 Tape File End Depth = 10600.000000 .. Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2704 datums Tape Subfile: 3 74 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS. FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10984.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: MAXIM UMANGLE: STOP DEPTH 11309.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 14 -AUG- 94 MWD 2.16A 5.74 MEMORY 11370.0 11043.0 11370.0 0 .0 .0 TOOL NUMBER NGP 223 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.70 .0 10.8 8OO .0 .000 .000 .000 .000 .0 129.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 9. s~Aq ~IOI :q~BusI pxoos~ mnmyx~M s~Aq E9 :q~Bu~I p~oms~ · ''sp~oo~ ££ 9 :~IYgqns smn~p 89~£I 89 :spoD :A~mmns 6uypoo~p ~poo uoy~uss~ds~ SI% 00000~'0 = 6u~D~ds I~AS~ ~I~ ~d~ 000000'0860I = q~d~G pu~ sI~ ~d~i 000000'g££II = q~d~ ~x~S sI~ ~d~i 0I I0 018 06 9 I0 0I£ 06 ~ P HHd~ I 89 GMI4 dOE P Idtflf I 89 (IM/4 ~ pon SlO cL{i clAi U~6u~ ~z!s AxO A~D s~!u~ ssIdm~S ~poD Iool sm~M :ssA~nD g (P9 #,qdA,T,) GMOD,~H ,~,kq6HOZ . kr~ S k~f : MdOqS H,T,MOM : A~f~ ,~OH~/lMd : ~fgg-P 'S'G : · OMI 'k~Sk~f OOk~f : N/iOD NM ND 0 O' : (ZH) XDblZfl~JZ%{.4 : (NI) .~.~0GbKfiS ~I00,1, 000 ' 00' : (NI) NOILDZ~OD Z~OH :XLISNZ~ ~OOi NO~LflZN O. O' E'££I O' 000 ' 000 ' 000 ' 000 ' O, 00£ I'0I 0' 08'6 GNS~ , 00S'8 ~Z~WnN ~OOi . 0 0'~89II 0'0££II 0'~89II ~9I'~ GMBI ~6-DD~-SI : (LZ) HLdZG DNIS~D : (NI) ZZIS LIE HqOH NZdO ~G ONIS~D GN~ ZqOHZ~O~ ZdX,l, ~I00J, ZGOD ~IO0,1, ~O~ZA (NOLLOS 03, ~0£) DNI%tiS 0'EE9II HLdZG dOLS 'S@IT~ ~qez~dss uT un~ ~lq qo~a zo~ eqPp ~ap~q BoI pu~ GM~ M¥~ :~Z~Wi1N Z~I~ ~Z(I~ZH SI~ :aclKq sT S ~II~qns sdP£ ss~Aq ~IOI :q~BusI p~oo~ mnm!xeM ss~Aq E9 :q~BusI p~om~ mnmiuiM '''sp~oD$x EL S :sIygqns sdeL smn~p 8~0~ 89 :spoD dsH 000000'00[II = q~ds~ pu~ sI!~ sd~I 000000'069II = q~dsG ~S sIY~ ~d~ 0I I0 018 06 5 I0 0I£ 06 ~ ~ Idlf~f I 89 GMI4 ~O pox sIO clAi clAi q26us% ~zys s~Tug ssIdm~S ~poD Ioo£ amen (~9 #~dAi) QHOD~H i~,qN%IO~ ~ k~MSlfqlf : ~dOqS H£HON : X~ ~OHClflHd : ~E~-~ 'S'G : 'OMI 'tfMStfq~ ODHtf : N_qOD NM ND Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 12 DEPTH INCREMENT: .5000 FILE SUMMARY \~NDOR TOOL CODE START DEPTH GR 11501.0 $ 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) MINIM UMANGLE: MAXIMUM ANGLE: STOP DEPTH 12400.0 TOOL STRING (TOP TO BOTTOM) ~ VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 19-AUG-94 MWD 2.16A 5.74 MEMORY 12460.0 11684.0 12460.0 0 .0 .0 TOOL NUMBER NGP 95 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 11684.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTR3~TE AT MT: MUD CAKE AT MT: XANVIS 9.00 .0 10.2 38500 .0 .000 .000 .000 .000 .0 129.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 12. ss~Aq PIOI :q~6u~I p~oo~ mnm!x~M ss~Aq g9 :q~6usI p=oos~ mnm!u!M · ''sp~oo~ 98 9 :~I!gqns smn~p ~9£6I 89 ~poo 000000'00~II = q~dsG pu~ sIY~ 000000'S9~EI = q~d~G ~x~S ~IY~ I0 018 06 ~ I0 0I£ 06 ~ ~ HH6~ I 89 GM/4 ~0~ ~ ~ Idk~f I 89 ~ H~ I pox sIO dA£ cIAi q~Bus% szys A~D A~D Boq IdV Id~ Id~ Id~ s~u~ s~Idm~S ~poD IOO£ ~m~N :ssA~nD E (99 #.~6X~L) fIHOD~t ,L~4HO.4 ~ k~S~ : ~dOqS HIHON : A~ ~OHCH/Hd : ~EE-~ 'S'~ : 'DNI '¥HSk~F~ OOH~f : NflOD NM ND Tape Subfile 7 is type: LIS O1 **** REEL TRAILER **** 96/ 8/15 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 15 AUG 96 11:38a Elapsed execution time = 1.21 seconds. SYSTEM RETURN CODE = 0 qd o4V Tape Subfile 2 is hype:' LIS TAPE HEADER PRUDHOE BAY I/NIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK MW 40066 R. JACKSON J. CARLILE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: D.S. 4-22A PB1 500292145470 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 15-AUG-96 MWD RUN 6 R. JACKSON J. RALLS MWD RUN 7 R. JACKSON J. RALLS 26 liN 15E 1089 217 54.90 53.40 20.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 11337.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY. NO DATA IS PRESENTED. A 6 3/4" DGWD GAMMA RAY WAS STARTED ON RUN 3 AT 10821' NO FOOTAGE WAS DRILLED ON RUNS 4 & 5. MWD RUNS 6 & 7 WERE DIRECTIONAL & GAMMA RAY (NGP/SGRD). NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS BOREHOLE. MICROFILMED 000000' SI80I = 000000' S~£II = I0 0!8 06 ~ I0 0I£ 06 9 EI :sp~oma~ ~ Iw~o~ ~ S~IX~ fIOI (0 #~dXi) G~OD~ ~i~ ~ pox SID dK£ clKi q~Bua% azIs 89 ~MM dO~ 89 ~M~ ~© :ssAxnD E ~ :GI q~dsp ~dPi ~Z S~f : ZdOqS Hi%tON : X~f~ ZOHfK1Hd : I~d ~f~E-~ 'S'~ : · OMI '~S~F~ OOk~f : NM ND 'SS~d NI~q~ ~ZD~ZN 0'£££II 0'£9III 0'£9III 0'690II 9 0'690II 0'S880I £ ZS~S ZDHZM dOL ZD~ZM ON NiI~ LI~ HLdZ~ ~ZL~IHSNi1 LNZ~I~fAIfl~Z Z~OD ~OOL Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3184 datums Tape Subfile: 2 95 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE S~Y VENDOR TOOL CODE START DEPTH GR 10821.0 $ 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: STOP DEPTH 11006.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 3. 09-AUG-94 MWD 2.16A 5.74 MEMORY 11069.0 10885.0 11069.0 0 .0 .0 TOOL NUMBER NGP 547 8.500 .0 LSND 9.80 .0 8.9 1000 .0 .000 .000 .000 .000 .0 129.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 4-22A PB1 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 11075.000000 Tape File End Depth = 10815.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1564 datums Tape Subfile: 3 70 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 0' : (ZH) ADM,~fl~,~M,~ : (HI) ,4,~O~NIf,LS ~IO0,L 000 ' 00' :(MI) MOI~D~HHOD ~qOH :AIISM~G XIHI~I4 :XIHIIu~ ~OOi MOHJYi~M · 0' 6' 0' 000 ' 000 ' 000 ' 000 ' . 000I I'6 0' 06'6 gNSq , 00S'8 O· 0 0'L9III 0'690II 0'L9III V9I'E ~M~ P6-D~V-0I : (.L4) H.l.d.qG 9MISVD S ,HH~I~IIHG :(MI) HZIS V.I.VG 9MISVD tINY .~IOH.~HO~ H6A.I. qO0.1. HCIOD ~IO0.1. %tO~MMA (P~O.I..I.O~t O.l. dO.l.) ~MIH.I.S ~IO0.1. 0'90III 'seIl~ eqe~edes uT un~ qlq qoe~ zo~ eqep zepe~q BoI pue SeA~nO £ :~klflN HqI~ ~C~fgH ~qI~ SIq :~cL{~ s! p Slygqns sd~i · CN WN FN COON STAT : ARCO ALASKA, INC. : D.S. 4-22A PB1 : PRUDHOE BAY : NORTH SLOPE : ALAS~ * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 11175.000000 Tape File End Depth = 11000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4238 datums Tape Subfile: 4 68 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 0 O' 000 ' 00' : (NI) ~,~O(INlf,~,S %00J, : (~T) ~OZ,T.O~O0 ,~OH : X.LISN,~ XI%I.I,IfN : ~O0,T, NO~I,LD_~N . O' ~' ££I O' 000 ' 000 ' 000 ' 000 ' , 00L 6'8 O' 0L'6 O. 00S'8 · 0 0'L££II 0'L9III 0'L££II PL'S ~9I'g : (LM) HidZ~ DMISWD S,MZ~IH~ : (MI) ZZIS LIS H~OH NZdO ~i~ ~MIS~O ~N~f ZqOHZMOM · (NO,l,,T, Of 5 O.l. cIOd5) DNI%{£S ~IOOJ5 0 ' 9LEII Hid.q(/ dOLS SI~ :scL{~ sT ~ aiT~qnS sde£ CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 4-22A PB1 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) 1014 BYTES * 4 90 310 01 1 4 90 810 01 1 Total Data Records: Tape File Start Depth = 11345.000000 Tape File End Depth = 11100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3038 datums Tape Subfile: 5 69 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes 0 = ~OD N-HflI~ · spuomss £8'0 = ~my~ uoy~nosxs p~sd~i~ ~80:II 96 D~ SI nq~ :uoy~nD~x~ ~o pu~ s~Aq ~I :q~Bu~I p~oD~ mnm~x~x s~Xq.E£I :q~Bu~I p~oD~ mnm~u~ · ''sp~oD~ E 9 :sIy~qns I0 /96 I0 s /8 SI% :acL{~ sT 9 @ITgqns sd~i ARCO ALASKA INC D.S. 4- PRUDHOE BAY !994 FILMED Run 1' 15 - August - 1994 DIFL/AC/CN/GR Pipe Conveyed WESTERN ATLAS 10680 1667 Atlas Wireline Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6256.00 R. ECK J. VERSTEEG D.S. 4 - 22A 500292145401 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 18-AUG-94 RUN 2 RUN 3 26 liN 15E 1089 217 54.90 53.40 20.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 7700.0 PRODUCTION STRING 8.500 11684.0 REMARKS: DIFL/AC/CN/GR PIPE CONVEYED. CIRCULATION STOPPED AT 00:30, 15-AUG-94. PCL SPIKES WERE CAUSED WHEN MAKING A DRILL PIPE CONNECTION WHILE LOGGING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, BOREHOLE CORRECTION = 8.5", CHISM FILTERING ACTIVE, NO CASING CORRECTIONS, SALINITY = 0.00 PPM. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (8.5"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DIL 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA .500O START DEPTH STOP DEPTH 10577.0 11600.0 10614.0 11638.0 10637.0 11667.0 10647.0 11603.0 GR (MEASURED DEPTH) BASELINE DEPTH LL8 10565.0 10627.0 10638.0 10651.5 10652.0 10660.5 10665.5 10676.0 10679.0 10679.5 10680.5 10687.5 10690.0 10697.5 10701.5 10709.5 10710.5 10711.0 10722.5 10732.5 10750.5 10753.0 10761.0 10763.0 10763.5 10764.0 10773.0 10784.0 10786.0 10814.0 10817.5 10824.5 10825.5 10826.5 10828.5 10832.0 10833.5 10852.0 10852.5 10859.5 10852.5 all runs merged; EQUIVALENT UNSHIFTED DEPTH ILD DT NPHI 10565.0 10627.5 10637.5 10651.5 10652.0 10660.0 10660.0 10665.0 10675.5 10678.5 10679.5 10680.5 10687.5 10690.0 10696.5 10702.0 10708.5 10709.0 10710.0 10764.0 10773.5 10824.0 10826.0 10829.0 10832.5 10833.0 10733.0 10753.5 10763.5 10723.0 10733.0 10751.0 10761.0 10763.0 10784.5 10813.5 10817.0 10784.5 10786.0 10825.5 10852.0 10852.5 10860.5 no case 10868.0 10870.0 10871.0 10872.0 10872.5 10877.0 10889.0 10892.0 10905.5 10906.0 10919.0 10937.5 10942.0 10955.0 10979.5 10980.0 10983.5 10994.5 10995.0 10996.0 11008.5 11015.0 11024.0 11037.0 11039.0 11042.5 11043.5 11045.0 11045.5 11046.0 11047.5 11052.5 11060.0 11061.0 11063.0 11080.0 11082.0 11082.5 11083.5 11086.0 11090.5 11094.0 11094.5 11096.0 11119.5 11124.5 11125.0 11130.0 11135.5 11136.0 11136.5 11141.0 11142.5 11144.5 11145.0 11147.5 11158.5 11164.0 11175.0 11187.5 10906.0 10981.5 10996.5 11024.5 11038.5 11094.5 11141.0 11159.0 10866.0 10869.0 10870.0 10870.5 10871.0 10937.0 10954.5 10980.0 10983.0 10994.5 11007.0 11024.5 11038.0 11043.5 11044.0 11044.5 11045.5 11046.0 11052.0 11058.5 11059.0 11080.0 11080.5 11081.0 11095.0 11119.5 11124.5 11128.5 11135.0 11135.5 11142.0 11144.5 11145.5 11163.0 11187.0 10892.5 10905.5 10918.5 10994.5 11024.0 11047.5 11080.0 11090.5 11095.0 11135.5 11141.5 11175.0 10876.5 10888.5 10918.5 10942.0 11015.5 11024.0 11047.0 11063.0 11079.0 11085.5 11094.0 11124.5 11130.0 11135.5 11141.0 11145.5 11159.0 11188.0 11199.0 11199.5 11202.0 11202.5 11203.0 11220.0 11220.5 11222.0 11224.0 11224.5 11228.5 11230.5 11231.5 11237.0 11253.0 11254.5 11255.0 11257.0 11257.5 11266.5 11270.0 11271.0 11272.0 11274.5 11275.5 11276.0 11279.5 11282.0 11286.0 11287.0 11287.5 11289.0 11289.5 11298.5 11307.0 11307.5 11319.0 11319.5 11327.5 11336.5 11337.5 11339.0 11348.5 11351.5 11355.0 11369.0 11369.5 11370.0 11380.5 11385.0 11387.5 11391.5 11396.0 11397.0 11404.5 11422.0 11677.0 $ 11199.0 11202.5 11272.0 11279.5 11319.5 11369.5 11386.5 11398.0 11187.5 11200.5 11218.0 11219.0 11220.5 11231.0 11232.5 11255.0 11255.5 11269.5 11270.0 11274.0 11275.0 11281.0 11285.0 11285.5 11286.0 11306.5 11320.0 11327.0 11337.0 11370.0 11391.0 11395.5 11677.0 11199.5 11202.0 11224.5 11236.5 11253.0 11256.0 11266.5 11273.0 11275.5 11279.5 11307.0 11335.5 11339.5 11348.5 11355.0 11369.0 11380.0 11385.0 11387.0 11391.0 11404.0 11422.0 11202.5 11224.5 11228.5 11253.0 11258.0 11266.5 11285.5 11289.0 11298.5 11351.0 11392.0 996 O~I :sp~ooa~ ~$~G I~$OA 9~ £E IIE 86 ~ gE IIE 86 ~ 9£ 9~£ 0§ ~ 9£ 9~£ 0§ ~ 9£ 9~£ 0§ ~ 9A 9~£ O§ P 9£ 9~£ O~ P 9£ 9~£ O~ P 06 68£ 0E P 06 69£ 0E ~ IL £§9 ~8 P 90 §9~ £9 ~ S-Rd AN M/4HO Nk~O a/sa Id~D I 89 §C~g IH~N I 89 ~I~ dS 0I I 89 ~IQ IQ 6 I 89 ~IG A~ 8 I 89 ~IG GqI I 89 qIG ~qI 9 I 89 ~IG 8qq I 89 SD~ SNH~ I 89 SD~ GNI~ I 89 SD~ AG I 89 SOM MD I poM SlO dAi dKi q~bua% azTs s~IuQ seId~es aPOO IooA em~N :S~AlnO ~I M :GI q~dep ~S~f : VEE- 9 'S'G : &no' &no' EHO~ZZ / &no' ~HO,T,~X&Z / NnOD NM MM ND 0'£09II 0'£99II 0'8C9II 0'009II MS~ ~DM~N 'IHdN H~IM GlO,IHS HHHM AD~N ~ 'GqI H~IM GMAMIHS MHHM IG ~ 'AH 'k~II '8~q H~IM GlO,IHS HHHM SNH~ ~ 'GNH~ 'dS 'SS~6 NIYP~ HqOH NHdO 0'£~90I C I 0'££90I g O'~I90I C I 0'££GOI £ I ~0~ ~DHIN 'OM SS~d 'ON N/iH Tape File Start Depth = 11677.000000 Tape File End Depth = 10565.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 33376 datums Tape Subfile: 2 403 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH GR 10576.5 AC 10614.0 DIFL 10637.0 2435 10583.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH 11601.0 11638.0 11667.0 11608.0 TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE HEAD SWIV CHT MIS TEMP GR CN PCM KNJT KNJT AC DIFL $ PCL HEADSUB SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 15-AUG-94 FSYS REV. J001 VER. 1.1 30 15-AUG-94 1753 15-AUG-94 11684.0 11669.0 10580.0 11667.0 1200.0 TOOL NUMBER 3944XA 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 3923NA 3923NA 1609EB/1603MA 1503XA 8.500 7700.0 .0 LSND 9.80 45.0 10.5 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA 5.0 164.0 1.840 .860 2.380 .000 2.290 .000 THERMAL SANDSTONE .00 8.500 1.5 77.0 164.0 72.0 .0 78.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Name Tool Code Samples Units GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN CILD DIFL 68 1 MMHO VILD DIFL 68 1 MV VILM DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 04 903 06 0 4 06 213 78 0 4 34 704 23 6 4 04 522 10 6 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 371 1014 BYTES * 80 Tape File Start Depth = 11677.000000 Tape File End Depth = 10565.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 93430 datums Tape Subfile: 3 454 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11150.0 11591.0 AC 11187.0 11628.0 DIFL 11210.0 11657.0 2435 11156.0 11598.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE HEAD SWIV CHT MIS TEMP GR CN PCM KNJT KNJT AC DIFL $ PCL HEADSUB SWIVEL SUB CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT BHC ACOUSTILOG DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 15-AUG-94 FSYS REV. J001 VER. 1.1 30 15-AUG-94 1621 15-AUG-94 11684.0 11669.0 10580.0 11667.0 1200.0 TOOL NUMBER 3944XA 3974XA 3967XA 2806XA 1309XA 2435XA 3506XA 3923NA 3923NA 1609EB/1603MA 1503XA 8.500 7700.0 .0 LSND 9.80 45.0 10.5 5.0 164.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA 1.840 .860 2.380 .000 2.290 .000 THERMAL SANDSTONE .00 8.500 1.5 77.0 164.0 72.0 .0 78.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O GR AC 68 1 GAPI AC AC 68 1 US/F CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN CILD DIFL 68 1 MMHO VILD DIFL 68 1 MV VILM DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 06 969 49 6 4 4 48 852 89 1 4 4 95 558 30 1 4 4 95 558 30 1 4 4 61 094 30 1 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 06 213 78 0 4 4 34 704 23 6 4 4 04 522 10 6 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 80 * DATA RECORD (TYPE# 0) Total Data Records: 177 1014 BYTES * Tape File Start Depth = 11667.000000 Tape File End Depth = 11139.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 77750 datums Tape Subfile: 4 258 records... Minimum record length: Maximum record length: 44 bytes 1014 bytes Tape Subfile 5 is type: LIS 94/ 8/18 01 **** REEL TRAILER **** 94/ 8/19 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 19 AUG 94 8:39a Elapsed execution time = 10.60 seconds. SYSTEM RETURN CODE = 0
