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179-041
STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 12-03 JBR 10/16/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Testing the bop's and the unit. DS 12-03 is a suspended well and cemented above the perforations and that is also why the MASP is 0 PSI. Tested with 1-1/2" coil no failures had a small problem with the flange on the stump when getting started but from there the test went well. Due to gas alarms all personnel had personal H2S monitors. Accumulator precharge was 5 @ 1315 psi. Test Results TEST DATA Rig Rep:Zach J. / Jeff H.Operator:Hilcorp North Slope, LLC Operator Rep:Cody F/ Mark S. Rig Owner/Rig No.:Little Red Services 1 PTD#:1790410 DATE:8/27/2023 Type Operation:WRKOV Annular: Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopKPS230828000834 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 0 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 0 NA Inside BOP 0 NA FSV Misc 0 NA 6 PNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 1 1-1/2 P Annular Preventer 0 NA #1 Rams 1 1-1/2" Blind S P #2 Rams 1 1-1/2 Pipe slip P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 0 NA HCR Valves 0 NA Kill Line Valves 0 NA Check Valve 1 2"P BOP Misc 2 EQ Ports P System Pressure P2765 Pressure After Closure P1695 200 PSI Attained P2 Full Pressure Attained P25 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)NA0 ACC Misc NA0 NA NATrip Tank NA NAPit Level Indicators NA NAFlow Indicator NA NAMeth Gas Detector NA NAH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer NA0 #1 Rams P3 #2 Rams P3 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke NA0 HCR Kill NA0 9 9 9 9999 9 9 6HSDUDWHUHSRUWIRU5LJ,QVSHFWLRQDQGSKRWRV-5HJJ Testing the bop's and the unit. DS 12-03 is a suspended well and cemented above the perforations and that is also why the MASP is 0 PSI. T STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 2 4 gmq I . Operations Performed e� /-. Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations gl�taov� ' �l Suspend ❑ Perforate ❑ Other Stimulate ❑ Atter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work5. Development 0 Exploratory ❑ Permit to Dnll Number: 179-041 3. Address: P.O. Box 196612 Anchorage, AK 99519-0612 Stretigraphic ❑ Service ❑ 6. API Number 50-029-20377-00-00 7. Property Designation (Lease Number): ADL 028330 8. Well Name and Number: PBU 12-03 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 9765 feet Plugs measured 8710 feet true vertical 9536 feet Junk measured None feet Effective Depth: measured 8710 feet Packer measured 8203 feet true vertical 8482 feet Packer true vertical 7977 feet Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20" 35-115 35-115 1530 520 Surface 2699 13-3/8" 35-2734 35-2734 5380 2670 Intermediate 8840 9-5/8" 33-8873 33-8644 8150/6870 5080 / 4760 Production Liner 1228 7" 8532-9760 8304-9531 8160 7020 Perforation Depth. Measured depth. None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 4-1/7'12.6# 13Cr80 31 -8295 31 -8068 Packers and SSSV (type, measured and 4-1/2• Baker S-3 Perm Packer 8203 7977 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: Suspended Subsequent to operation: 14.Attachments. (required per 20 MC 25.070.25.071,&25.253) 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 ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ EGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 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: NIA Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: ecialist I Contact Email: Travis. Montgomery(Mbp.com Authorized Signature: Data I /1+ 1 A Contact Phone: +1 907 564 4127 Form 10-404 Revisetl 04/2077 RBDMSUL 2 5 2019 Submit Original Only TWO = LOTO/40/450. Temp = SI. Pre AOGCC SU well inspection. No AL or flowline. Wellhouse, wellhead and cellar are clean and dry. Surface area around well is clean, dry and clear of debris. Well ID sign on wellhouse. 6/30/2019 SV, SSV = C. MV = LOTO C. IA, OA = OTG. 03:55 TWO = SSV/50/475. Temp = SI. AOGCC SU well inspection (Witnessed by Bob Noble). No AL, flowline. 7/6/2019 SV, SSV, MV = C. IA, OA = OTG. 11:30 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 12-03' Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1790410 API Number: 50-029-20377-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: efttf2el o Surface Location: Section: 18 Twsp: 10N Range: 15E Nearest active pad or road: DS -12 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: t`1 EC. r1 Location cleanup needed: Pits condition: NJA Surrounding area condition: r ) '01., n Water/fluids on pad: AAA/ ' Discoloration, Sheens on pad, pits or water: A/ p Samples taken: None Photographs taken (# and Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Cellar description, conditio. Rat Hole: Wellhouse or protectiv ba Well identification sign: Tubing Pressure (or casinc Annulus pressures: Wellhead Photos taken (# Work Required: None Operator Rep (name AOGCC Inspector: _ Inspection Date: _ Time of arrival: Site access method fluids:�rtl r Josh Prowant AOGCC Notice Date: Time of Departure: ► w. T` _ :_ n 01-24A i 01-25 IO&18A 01-18A C0 0610A 7 " 01-07APB1 L_ 00-,00 01-0 01-07A 4 01-13 e12 -12A 1219 io-acnrw 12-20A } 13-02B �. 13-03 ^ 12-12 01-18 H 12-17 y 13 -ORA � 18 12- I 01-34A8 12 I M-229 L01-34 09-f1�� 03-24R- 13-06APB1 7 01"05PB1_. 4 01-10 V 01-11 ? RP201015XX 2-28h-_-:03-24 -... ' L 03-24_A 0136 13-06A 12-14a.Li 12-138PB2 12 29 . , 12-138 12-01 y 12.05AL10�1 12-02 12-138P81 G 12-13 1 + Al2-05APB1 12-1'31(2 12-27A �15AL1 '-I �1 12-23 1�1 12 12-05A� 17 Z 12-25 12-27' -i 013-06 = 42 -ass C 12-08A 13-07 G 12-15 13-081 — 12-34 12-15A PR PR191015�, �. `��R191 15 J PR191015B PR17�1015 12-07A 12-t0 _ 12-o-7 i,J 12 -it _12-33 19 12-08C 13-12A 12-35PB1 L. PR1810t 13-21A. 12-10A - 1231 72-06 13-06APB1 13-21 1= t4 i• ? RP201015XX 712-042.(19 (1 12- 04A ' 1806APB9 13-06A 12-14a.Li 12-03 13-05 <_-03A 4 17-12A �` 12-OBA �1 12-23 3 12-22 17=13'1 Z 12-25 013-06 = 42 -ass C 12-08A 13-07 G 12-15 13-081 — 12-34 12-15A PR PR191015�, �. `��R191 15 J PR191015B PR17�1015 12-07A 12-t0 _ 12-o-7 i,J 12 -it _12-33 19 12-08C 13-12A 12-35PB1 Q 17-02 7 12 30 17-19 iii t � y�0 72-14A I i G 17-03 17-03A 17-0ae (1 17-04:M f - 17-03APB1 17 12-10A - 1231 II 20 1= t4 i• ? RP201015XX _ 12- t4AL1PI 12-14PB y ` 12-14a.Li �.7 ' {y140�•�'�.L. �t`F7 Q 17-02 7 12 30 17-19 iii t � y�0 72-14A I i G 17-03 17-03A 17-0ae (1 17-04:M f - 17-03APB1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG JUL 2 4 2018 la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well Class: DevelopmA Service ❑ Stretigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry r BP Exploration (Alaska), Inc 6/302018 179-041 317576 3. Address: 7. Date Spudded: 15. API Number: . P.O. Box 196612 Anchorage, AK 99519-6612 8/14/1979 50-029-20377-00-00 4a. Location of Well (Governmental Section): 8. Date TO Reached 16, Well Name and Number: 9/13/1979 PBU 12-03 ' 9 Ref Elevations KB 73 17. Field/Pool(5): Surface: - 936 FSL, "'FEL, Sec. 18, T1014, RISE, UM Top of Productive Interval: 1136' FSL, 131 1'FWL, Sec. 17, T10N, R1 5E, UM GL 39.36 BF 40.11 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 1110' FSL, 1294' FWL, Sec. 17, T10N, RISE, UM 8710'/ 8482' ADL 028330 4 41d. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MDrrVD): 19. DNR Approval Number: Surface: x- 697552 . y- 5931268 Zone - ASP 4 9765'/ 9536' 78-71 12. SSSV Depth(MD/TVD): PO Thickness of Permafrost MD/TVD: TPI: x- 698900 y- 5931500 Zone- ASP Total Depth: x- 698884 y- 5931475 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21, Re-drill/Lateral Top NAndow MDfrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma my, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and Perforation record. Acronyms may be used. Attach a separate page if necessary Cal, DIL / SP I FL / OR. Acoustic GR, CDL / CNL / GR, DIL / SP / BHCS / GR, SPC / CNL / Cal / OR. TOT I GR 23' CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94# H40 35' 115' 35' 115' 30" 312 sx Permafrost II 13-3/8" 72# L-80 35' 2734' 35' 2734' 17-1/2" 600 sx Permafrost II 9-5/8" 47# L -MRS -95 IN -80 33' 8873' 33' 8644' 12-1/4" 500 sx Class'G' 7'' 29# N-80 8532' 9760' 8304' 9531' 8-1/2" 250 sx Class'G', 120 sx Class'G' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD I1 Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MDrry 4-1/2" 12.6# 13Cr80 8295' 8203' / 7977' SV`S� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. --L9A4 ATE hydraulic I83 (IpYes ❑ No 0 Per 20AAC25.2)(2) attach electronic and printed information VER DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8710' 19 Bible Class'G' 27, PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas In, etc.): WA Date of Test : Npurs Tested: Production for 011 -Bbl'. Gas -MCF: Water -Bbl: Choke Sive Gas -Oil Ratio: Test Period ► Flow Tubing Casina Press: I Calculated Oil -Bbl: Gas -MCF: Water -B51: Oil GrawN-API toon): Press 24 Hour Rale --► Form 10.407 Revised 52017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMSSLh JUL 2 5 2018 M e 4111 V G 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sldewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summanzing test results. Attach Top of Productive Interval 8985' 8756' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 8985' 8756' Shublik 9009' 8780' Sadlerochit-Zone 4 9082' 8853' Kavik - Base Sadlerochit 9656' 9427' Formation at total depth: Kavik 1 9656' 9427' 31. List of Attachments: Summary of Daily Work, Wellbore Schematic Diagram, Initial Suspension Inspection Report Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Bronga, Jaime Authorized Title: SIM S nst Contact Email: Jaime. Bronga@bp.com Authorized Signature: Date. I� Contact Phone: 9075644151 INSTRUCTIONS General. This form is designed or submitting a complete aniMmect well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item Ia. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item ib. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate forth for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the comesponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071, Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only WELLHEAD= GRAY ACTUATOR= I DEV OIB. ELEV = 73' REF BEV = 73' BF. H3EV = 40.11' KOP= 4000' Max Angle = 108' Q 9572' Datum AO= 9104' Datum TVD= 8800'SS SUSPENDED 12-03 SAFETYNOTES: 4-1/2' CHROME TUBING"'W ELL 12-03A ABANDONED ANGLE> -70" @ 92531. MAX OLS: 40° @ 9302'. 2018'H 9-518' Hf3 Es CEMf3VT82 20-COPDIX.TOR 113' # 2109' 4-12• HES X NP, D = 3.813' D- 2148' 9-5/8' FOC CSG, 47#, L-80 HY D 563, D = 8.681' H_20 ' BOVVEN CSG PATCH, K)= 8.681 • 2029' - 8' CSG, 720, L-80 BTC, D = 12.347'..,, — Minimum ID = 3.813" @ 2109- 4-1/2" HES X NIPPLE 4-12' TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958" ITOP OF7-LNR I 1 9-58• CSG 47#, RS -95/ N-80 BTG D = 8.681' I 4-1/2' BKR DELTA WHPSTOCK w 2 RA PPTAGS (0629/17) 1 7- LNR 29#, N�80 BTG .0371 bpf, D = 6.184' I FEF FORATION SUFAMARY REF LOG: BHC 9 ON 09/09!/9 ANGLE AT TOP PERF: 2- @ 8984' We Refer to production DB for historical perf data SIZE SPF NTERVAL Opn/Sgz SHOT I SOZ 3-38' 6 8984-9009 S 0822/94 0622/18 3-38' 6 8992-9009 S 08/22/94 0622118 3-318' 0.5 8992-9004 S 10/04191 0622118 GAS LFT MANDRR S ST MD I TVD I DEV I TYPEI VLV I LATCHI FORT1 DATE 4 3409 3408 0 MMG RK ""17/18 3 5866 5740 22 MMG DAM RK 0 04/17/18 2 7145 6944 18 MIG OMY I R( 0 06/29/18 1 7967 7743 8 MMG CWRK 0 06/29/08 8179' 4-/2" FES 8200' 9-SIW X 4-1/2' BKR S-3 R0Z D = 3.875' 822W 4-12' HES X NP. D = 3.813' 1 8281' —14-12' HES XN NP, D= 3. 8291' 4-1/2' VYLEG, D = 3.958' ELMD IT NOT LOGGE 1 9-5/8" X 7- BOT TEBA?K D = ? 9-5/8' X 7" BOT LNR HGR BENND CT LNR MLLOUT WNDOW (12-03A( 9018'- 9026' DATE REV BY I COMMBJTS DATE HEV BY 00LOA94TS 0921/79 PKR 176 ORIGINAL COMPLETION 07ro3/85 MES RWO 07/02108 D14 RINO 07110117 N-CDR2 CTDSIDETRACK-OPSS0(12-03A) 06!30118 JNLJJMC SUSPENDED WELL 14-1/4' OPENHOLE I 14-12' OPENHOLE PRAHDE BAY UNT VVflL: 12-03 PERMIT No: 179-041 API No: 50-029-20377-00-00 SEC- 18, T10K R15E, 938' FSL 8 44' R3 BP Exploration (Alaska) Daily Report of Well Operations 12-03 Ar`TI\/ITVnATC RI IMMARV T/I/O=Vac/0/300. Post CDR2. Set 4" TWC #438 at 125", N/D CDR Tree #3 and NIU Temp #16 as dryhole, PT Tree to 5000 psi. Pass. Pulled 4" TWC #438 at 90". PT tree cap to 500 7/12/2017 psi. Pass. ***Job Complete*** See log. Final WHP's Vac/0/300. T/1/0= 0/0/500. ASV Install. R/D tree cap assembly. Installed ASV #02. PT'd ASV against 11/17/2017 SV low 300psi, high 5,000psi. (Passed). RDMO. *** Job Complete*** FWHP 0/0/500 T/I/O = SSV/20/210. Temp = SI. IA FL (SL Req). No AL. IA FL @ 620' (33 bbis). 4/16/2018 SV, WV, SSV = C. MV=O. IA, OA = OTG. 12:30 T/1/0= 230/40/240 Temp =SI (LRS Unit 42 -Assist Slickline: Load & Test) Pumped 5 bbls of 60/40 followed by 200 bbls crude down IA to load. SL set DGLV in station # 4. Pressure up IA to 1500 psi w/ 3.4 bbls crude. IA lost 45 psi in first 15 min and 15 psi in second 15 min for a total loss of 61 psi in 30 min. Bleed IAP. 4/17/2018 **Job continued on 4/18/18 WSR** ***WELL S/I ON ARRIVAL, MASTER VLV LOCKED OUT*** (P&A) SET 4-1/2" X - CATCHER @ 8179' MD PULLED RK-S/O @ 5866' MD PULLED RK-LGLV @ 3409' MD SET RK-DGLV @ 5866' MD LRS LOAD IA W/ 200 BBLS CRUDE SET RK-DGLV @ 3409' MD GOOD PRESSURE TEST ON IAAGAINST DGLV's ***CONT. ON 04/18/2018 WSR*** 4/17/2018 **Job continued from 04/17/18 WSR** (LRS Unit 42 - Assist Slickline: Load & Test) Finished bleeding IAP. Bled back — 3 bbls RDMO. SL in control of well upon LRS 4/18/2018 departure. IA/OA=OTG. Hung info tags on IA/MV. FWHP's=400/180/340. ***CONT. FROM 04/17/2018 WSR*** (P&A) PULLED 4-1/2" X -CATCHER @ 8179' MD 4/18/2018 ***JOB COMPLETE, LEAVE WELL S/I*** 6/22/2018 Heat DSL transport T/I/0= 390/122/439 (Fullbore - SLB Reservior Cement Plug and Abandonment) Proposed TOC= 8870 Pumped the following down the Tbg: 10 bbls Methanol 260 bbls 1% KCI 19 bbls 15.8 ppg Class G Cement 2.0 bbls Fresh Water Dropped Foam Balls 5.5 bbls Fresh Water 148.5 bbls Diesel (156 bbls Total Displacement) (See Log for Details) Calculated TOC = 8,870' WV, SV and SSV = Closed, MV = Oeen, IA/OA = OTG 6/22/2018 T/l/O = 50014/454 = 500/129/465. Assist slickline (P&A) with pre AOGCC MIT T **PASSED** to 2605 Pumped 3.17 bbls down tbg to reach test pressure. 15 min T lost 87 psi. 30 min T lost LFinal si. Bleed TP back to 9 psi/Bled back 3.6 bbls. AOGCC witnessed by Jeff Jones. MIT T SSED** to 2542 psi. Pumped 3.82 bbls of diesel to reach test pressure. 1st 15 min tbg 120 psi, 2nd 15 min tbg lost 44 psi, total loss of 164 psi in 30 min. Bleed back 6/30/2018 *WSR continued on 7-1-18** Daily Report of Well Operations 12-03 'WELL S/I ON ARRIVAL'**(P&A) TAGGED TOC AT 8677' SLM (8710' MD) RECOVERED CEMENT. AOGCC WITNESSED 6/30/2018 LRS PERFORMED MIT -T TO 2500#. AOGCC WITNESSED. **WSR continued from 6-30-18** Assist slickline (P&A) Finished bleeding tbg down. Bled 7/1/2018 back 3.3 bbls. FWHP=20/121/466 Slickline still on well upon departure. ***CONT FROM 6-30-18 WSR***(P&A) RIG DOWN SWCP 4522 7/1/2018 *'*WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** TWO = SSV/100/450. Temp = SI. Pre AOGCC SU well inspection. No flow line. Temporary scaffolding installed around well head. Trash removed from well house. Old piping, tree cap, angle iron & insulation for piping in well house. 7/5/2018 SV, SSV = C. MV = O. IA, OA = OTG. 05:10 OF TMJ • 40-„ THE STAT• . -v s Alaska Oil and Gas �.s-ar�„1 of/\ /�, Conservation Commission sKA : - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®F �, Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Jaime Bronga Well Interventions Engineer BP Exploration(Alaska), Inc. N�� PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-03 Permit to Drill Number: 179-041 Sundry Number: 317-576 Dear Mr. Bronga: 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, deD)-Qc Hollis S. French Chair DATED this 2-V day of December,2017. �-• � �`'L _ z t talar" FriiMkoCillMIJ STATE OF ALASKA DEC0LASKA OIL AND GAS CONSERVATION COMM! C 0 7 2017 APPLICATION FOR SUNDRY APPROVA 20 AAC 25.280 A,03 CC 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend II 1 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 179-041 ' 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p- 6. API Number 50-029-20377-00-00 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No RI PBU 12-03 - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028330 . PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9765 • 9536 • 9012 8783 9012' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 35-115 35-115 1530 520 Surface 2700 13-3/8" 35-2735 35-2734 4930 2670 Intermediate 8840 9-5/8" 33-8873 33-8644 6870/8150 4760/5080 Production Liner 1228 7" 8532-9760 8304-9531 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8984-9004 8755-8775 4-1/2"12.6# 13Cr80 31 -8295 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and ND(ft): 8203/7977 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary I7I Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® Service 0 14.Estimated Date for Commencing Operations: December 31,2017 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended Il 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Bronga,Jaime be deviated from without prior written approval. Contact Email: Jaime.Bronga©bp.com Authorized Name: Bronga,Jaime Contact Phone: 9075644151 Authorized Title: Well Interventions Engineer Authorized Signature:6,, ...„.....„,--" Date: /a-- A,6�, COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test E Location Clearance 0 1 1 — 7 Other Post Initial Injection MIT Req'd? Yes—1 NoL"J Spacing Exception Required? Yes 0 No LV' Subsequent Form Required: /Q — 40 A 77 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: 01-- (2‘I 1 l (''TL /2/2o1)7 1\ ORIGINAL REDms aa /� � T ,,,\ s Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • Well: 12-03& 12-03A 12-03 Suspension and 12-03A Abandonment Intervention Engineer Jaime Bronga 907-564-4151 Production Engineer Finn Oestgaard 907-564-5026 Geologist Josh McFarland 907-564-5015 History 12-03A was drilled out from 12-03 from 9026-9400'md. The 12-03A did not find hydrocarbon producing , stratas and was left as an open hole sidetrack. Plans to fish the WS and push it downhole to make room for setting an expandable plug at 9012'md were unsuccessful. A back up of setting a cement plug will be executed with a TOC of 8870'md. In the future, Sag adperfs may be pursued in 12-03. The estimated effective volume of the 12-03A lateral is 12bbls. The KOP of 12-03A was in 65'TVD of the Shublik. Objective This cement job is to abandon 12-03A and suspend 12-03. Expected Start Date: December 31, 2017 Post-Job Evaluation A drift and tag of TOC with SL. Procedure Slickline 1. Dummy GLVs. MIT-T. Fullbore 2. Fullbore cement job with 18 bbls of Class G cement, target TOC at 8870'md. 3. WOC 5 days. MIT-T to 2500psi. fnr s_5 Slickline 4. Drift and Tag TOC. • 0 Current Schematic: 1AF11 1 FAD= GRAY i 1 2-0 3A SAFETY NOTES: 4-1/2-CHROME 11.83ING""W ELL ACILIA FOR= OPS ANGLE>-70°Etg 9253.MAX DLS:40*fig 9 302". CAB EIEV= 73' REF ELEV= 77 SHUTDOWN I F rt,- zoir 1-19-sder HES E5 CE#113.1031 ) R 1.1 Pi 40 11' KOP= 4000 20"oorcumou, — 113' / Ix A rul IOW a 95/7 0 . I I 2100' 1 14-14.IICA X Pin A7-7 04.1" 1 lion in,Lt.. 91,14 '' 2148' —'9-541"FOC] 19 5,6"r-.3G 47#,., EYJ I-1 i 1,', ' i k r 2un. 1.; .... , ---- ---. 2443 1 "9- FOCI 19-5,0"00.404 C5G PA Tri• i ' •,," 2 0 29' 2013 ^ A I• I 13.-vr cs4 726,L 80£1 I, ,I, I ,i' ,.(::.' 7 GAS LFT PILLS Sr KO ND CEV TY FE VLV LATCH PORT- CATE. 4 1409 3408' 0 1AL43 DOME RK 18 02117115 5866 5740' 22 10.13 SO RK 28 01/26117 7 145 6044, 1 WAG; CAW M 0 06r29.438i Minimum ID =3.813"04-: 21 0 9 i :44..'? :4:4- 4,s 1GA OW RK .0 06129/08.1 4-1/2" HES X NIPPI F I • d 1; ' • I,..."147.5 X NIP,ND.3 813' I 5200' H9-5.93^x 4-1/7 RKF1 5-3 RIR.V ,—,-....--........--, I 9224' . t:" is•xpaP,o=3.81r 1 I • 112 01; 1 in i,`2'i.f...F.'01 n.r. in-)77`..58410 CT 4515 j „ I 4,1ir 10(1,17//4„isCn-so V AIM 1()P, --1iiii` - --, a 2 91' 114-I)r WLEG,11=3 958' 1 1 0157 bp!,0-3 958' ' ; ,,,; ;,hia y ii,730•3E5--1 _ I. <I CIL ,,:(1' 1 1,/V5;6 7.BO!k Nii I Ki14615646413 CT LN1t re-5,5 .._,.G.476 175-95)N-80 STC.D-.9 681' 1--ET:/169' 4,ler SKR DELTA WI II .••10(21{v.riKA-1 904 2* -1 "N %%LOUT WNDOVY;12-03A).90,8' 9026' PP IA 05 4135171N1 t 1 i '\,. iii. -,•'....; -LM;294.04-50 BIC, 0371 93-6or/CE104' 9032 'AI \\ PERFORATION SLPA1AARY FET LOG.BHCS ON 09/00/79 11026" 9400J--14 1/4AT NE/,'111 AP4ra I-Al TOP PH* 2"40 saw '; , PAble•Reef to Prcx1m60,1(Ii for hatonc al pert data St& SR PITIRVAL OpntSq z SHOT SQL ( a 318. 6 8984 9009' 0 15122194 3-31r 6 8992-90091 0 C18/22)84 3-316' 0.5 8992-9004 0 10(04191 i i 9400'-1036T I-14-1,7 OE ' LA II I IV:b., '[...tASENTS F LA f i ',itV ti v 0D1.81ENTs PRIMO-BAY UNIT . i 09/21179 PKR 176 ORIGINAL COMPLETION MIL: 12 03A 07301435 N1115 RINO MIMI-N3 217-074 _ 07P02105 1)14 RIN0— AR NI: 90-029-20377-01 orii Oil 7 N-COR2 crosiccr—RAcK-OPS so(12-84AE, ' ' SEC 18,MA,R15E,gut FSL 6 44'FE ! 107,11/17 -1010 CR_GT-15-COFFEC--TION --- —--- t — __1St/12111 IEI.U2 FhAL OLE AKHOVAL ,, BP Explorstio II As kap 2 Post Cement Job Schematic $- µ_ 1> _ WULFEAD- GMT e" ),r._. , fAFEfY WEE S= 4-U2Cf�D�1usG-*-wa.� AC1<1IL70R- Proposed ' ANGLE}^-M'a 123 r_11X1 DILS:or p 7 Sar. OWL BEV••• Ti' HIEY= 2S L J 101f -l- Ca`_F3EV- 113'11' - 9t-F®®calsis' IIP- em' 21W C ONOILI-1014, H 11r r W1A1gb- IIS'�MIT *. - 2109' -4-11T FEB XFt U-311 T O dom ID- !IDI' D- ' O're1YD- &MUSSr -- I nu. I-3-9rrFOCI —1ir-JFD C ,ax„LAB HYO So,o ----L Leer NM' 5-54-BOWEN®PAMH,o-«r -tDa'-3033'' ----I � 91-9r11-Fac 13-314'®.l2#L-12 B1E,•1-1294T H my I.- GEIS LR I PEFELS ST 111 1YD OPv 1PPE VIV LAWN FONT C]RE 4 31E1 MS D .--. DOSE FE IS DIA D15 L3 SEA 37413 22 ISM SO DK 24 131114117 2 71 is iMI III I116 BM FE D WM= 111frIkIwnm =3.313'IN 2113 1 76Cd 7749 s I!6 OHC RC D COMM 4-10"HES XSIPPLE M F117r H 4-1/2'MEI KM;0-3113- r`x ry"111F-1 IMF -9-Yrx#-1f-HERB-9 PRS.o-3275' 0 ✓"VMr I-I4-1iFell xl�O-3113- I I ■ !$ ITI JO 1- -4-1I 75'IMAM-37M Ci LMF 4-irr1BG.12. ISC NYJYI(iGP. H !Err' , M1' -1F-1a-w-En.o-3 95r I D132 W.LI-311S1' HELEN rr110i LOBBED 70P OF TLM'f� Z532' -- =i3T -I-STAT uI1 n.II-r _.. , -I Ear I-1x T ME UMFO RF171111O LT L 1111 I 19-5',a-®.43P,11B-95/11-e1 sic.0-sir H SI0' I-A IL a-112-IBM OBA7B<BIOIaLi12Rik - 901r . ruOl1I11MF1IfR1174311]:.r-� 4 PP MHO 118171117J .:{,'',*+�1' 7-LOCK 7%1,1-1■X 1371 ere,13-a_1 W -I -Mir ' }� I 1131=OfirDONSOLDIUT< FEF LOG_BEES 00112142171I lin r •-s...•H EBao 1-1PP OLE AAGLEAITOPPURR r Eat' I I PAW Fieferts P1MueaF■®ltirIkl.dlpef am j mzE SPF ■MERVAL Op1sFg SHIT SOZ 3-3R' a as+l-MS Da@eu I'+I 3-air i a!!2-EMI 0 131117261 1 3-3s BEI 0 10101111I f 44- a13C! 1 -- IWei'-NSCT I-14-iir UP3010LE di7E WI(Br COf 5'@7 S 1951E WV Hr OOIS@!B PFLEME HAT LW DE2E/1 PATS OCL COUP CHIO■ 11131: 12—WA a>a213 FTEs BM MEE1i=211-D74 ass DSL WAD AA PE: SD-Ws-®f7-131 S TREW Wain CID 9CET 11>ECE-OP1SD(I2-ISA SEC 1%MEL IaSEA 9a'ra&41111 D IA 1/17 ID OFLG Ifl C70 BON D 7/1 2/17 IIMMEll FTMLOOEAPRIOYAL d'F3pllraim(Alaska) 3 • • x ,. Thousand Cubic Feet of Gas ("MCF") per Month 06 o o N W O O `"i N O O n i O 0 O O O O O O O N O o O 0 0 .i 0 N y -I- _..._..._ __ (i1 .__.. OrO -... 1 I 1 . �44� pl G l I ..0e 0 > P I ., 1 0 3 ail v N a 0 o _ v 0 a 00 0 •- t.I OIO� 2 �I 0. o - o -z o o --411 VOif o Z V .°11II ! 4 ill I ! 4111t ' Hi t 1 o s w' g� w Q *' o 00 V o L. V�4 2 P Q 0 ° cc W a, <i° t1�� .. w I Ce M n d 3 "as o }} 24P� 2g. '2') a o 6 m O p cP i , I .o ▪ co 0 1 �PC J Se 0 • o 1. V O -43 C 0. ( [�C '1�r a o li 1 6"t a` P Q12. = re Ii 44 O t/1 0Jilln T,� ® I 1 I t 6. Q =—po.- _ 4 M lit` _: fi r. 11i $oo °" ° �• ° 6861.44 a � '� ��''° Ilia ' ° � _ a _ � ° 13 ..."-i IL a a. 086�44� a X t W W O O O O Qo O ,-1s`6r (et, O O O O O r4 O O O O ri O O O .1 O O .-1 O .i rl ypuow lad aa}em;o siaaaee Jo y}uoW aad Ho Jo spina • • P7 /79 - 04/ Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday,August 09, 2017 10:43 AM To: Loepp,Victoria T(DOA) Subject: 12-03 (PTD#179-041)and 12-03A(PTD#217-074)Conundrum Follow Up Flag: Follow up Flag Status: Flagged Victoria, SCO WQ `` 41( : j Just want to clarify about what was decided: The current sundry(10-403)out for approval on 12-03A will change from plug perforations to Abandon once the plug is set. I'll send in a Completion Report(10-407)for 12-03 as Suspended now,and a Completion Report for 12-03A as Abandoned once the plug is set. I'll need to send a sundry(10-403)for Re-enter Suspended Well for 12-03—a cover letter with a brief explanation will be needed. I will then send another sundry(10-404)with the status after setting the plug as"Development"well,changing the status of Suspended to Development for 12-03. The final wellbore will remain as 12-03, NOT 12-03A. Please let me know if I'm missing anything or have not understood properly. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 w iiiiMei a BP Exploration Alaskal900 E. Benson Blvd.lRoom: 788DIAnchorage, AK 1 STATE OF ALASKA WE�ALASKA OIL AND GAS CONSERVATION COM N OMPLETION OR RECOMPLETION REP T AND LOG 1a. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned hJ'(' Suspended L., lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ®*Exploratory 0 1 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 7/5/2017 • 179-041 • 317-176 3. Address: 7. Date Spudded: 15' API Number. P.O.Box 196612 Anchorage,AK 99519-6612 8/14/1979 50-029-20377-00-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number. 9/13/1979 PBU 12-03 - Surface: 938'FSL,44'FEL,Sec.18,T10N,R15E,UM ` 9 Ref Elevations KB 73 17. Field/Pool(s): Top of Productive Interval: 1134'FSL,1311'FWL,Sec.17,T10N,R15E,UM GL 39.36 i BF 40.11 PRUDHOE BAY,PRUDHOE OIL• Total Depth: 1110'FSL,1294'FWL,Sec.17,T10N,R15E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9012'/8783' ADL 028330 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/IVO): 19. DNR Approval Number: Surface:x- 697552 • y- 5931268 • Zone - ASP 4 . 9765'/9536' • 78-71 TPI: x- 698900 y- 5931500 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/TVD: Total Depth:x- 698884 y- 5931475 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ® 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary Cal,DIL/SP/FL/GR,acoustic GR,CDL/CNL/GR,DIL/SP/BHCS/GR,SPC/CNL/Cal/GR,TDT/GR 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 35' 115' 35' 115' 30" 312 sx Permafrost II 13-3/8" 72# L-80 35' 2735' 35' 2734' 17-1/2" 600 sx Permafrost II 9-5/8" 47# L-80/RS-95/ 33' 8873' 33' 8644' 12-1/4" 500 sx Class'G' 7" 29# N-80 8532' 9760' 8304' 9531' 8-1/2" 250 sx Class'G',120 sx Class'G' 24. Open to production or injection? Yes 0 No ® 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#13Cr80 8295' 8203'/7977' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Y83 0 No ® ' C I t� Per 20 AAC 25.283(iX2)attach electronic and printed i information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED AUG 0 9 2017 9064' Set Posiset Plug j"y 9054' Cement w/15 Gallons Cement ,,/GCC 9012' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period —► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate """r Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only V'-rt- I/2//6 �/ K RBDMS a/ AUG 1 0 2017 4 G r-e/v 28. CORE DATA Conventional Core(s) Yes 0 No ® .• Sidewall Cores Yes 0 No El IfY s to either question,list formations and inte als cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8985' 8756' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 8985' 8756' Sadlerochit-Zone 4 9082' 8853' Kavik-Base Sadlerochit 9656' 9427' Formation at total depth: Kavik 9656' 9427' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Ciolkosz,Ryan R Authorized Title: Info ati n and Da on Iler Contact Email: Ryan.Ciolkosz@bp.com Authorized Signature: A. Date: j/�Jf Contact Phone: +1 907 564 5977 vvv ��` INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 MC 25.071. Item 31.Pursuant to 20 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only . • Daily Report of Well Operations 12/3/2017 ACTIVITYDATE SUMMARY ***WELL SHUT-IN ON ARRIVAL. JOB STARTED 17-JUNE-2017*** (SLB ELINE MILL XN / POSISET PLUG SETTING) MIRU. PT. RIH W/ HEAD/XO-GO/CCL/WELLTEC 3.807" MILL. OAL= 37', OAW=620 LBS, MAX OD = 3.807" (MILL). TIE INTO BP TUBING SUMMARY DATED 6/29/2008. MILL XN NIP AT 8281". MILL MEASURED 3.804" OD AT SURFACE AFTER MILLING. RIH W/ HEAD/CCL/MPBT/POSISET PLUG. OAL = 34'; OAW=280 LBS; MAX OD = 2.125". CORRELATED TO SLV SBHPS DATED 15-JUNE-2009. SET POSISET PLUG ME AT 9065'. TOP OF PLUG AT 9063.5'. CORRELATED TO SLV SBHPS DATED 15-JUNE-2009. 6/17/2017 ***JOB CONTINUED 18-JUNE-2017*** T/I/O= 1512/1479/611 Assist E-Line Load & Kill (CTD) Pumped 2 bbls 50/50 spear followed with 290 bbls 120* 1% KCL, 38 bbls diesel down TBG, Tags hung on well, E-Line 6/17/2017 on well @ departure, FWHP= -16/1446/676 ***JOB CONTINUED FROM 17-JUN-2017***(SLB ELINE POSISET PLUG/CEMENT DUMP) SET POSISET PLUG ME AT 9065'. TOP OF PLUG AT 9063.5'. CORRELATED TO SLB SBHPS DATED 15-JUN-2009. CEMENT RUN 1: RIH W/HEAD/CCL/DBA/40' x 2.125" BAILER LOADED WITH 5 GAL 15.8 PPG CEMENT. OAL =48'; OAW= 300 LBS; MAX OD = 2.125". TAG TOP OF POSISET PLUG AT 9063.5'. DUMP 3.2' OF 15.8 PPG CEMENT ON TOP OF PLUG. CURRENT ESTIMATED TOC = 9060.3'. CEMENT RUN 2: RIH W/SAME TOOLS. DUMP 3.2' OF 15.8 PPG CEMENT. CURRENT ESTIMATED TOC = 9057.1'. CEMENT RUN 3: RIH W/SAME TOOLS. DUMP 3.2' OF 15.8 PPG CEMENT. FINAL 6/18/2017 ESTIMATED TOC = 9053.9'. T/I/O =VAC/1370/640. Temp = SI. T FL (fullbore request). Wellhouse, flowline, AL, grating, floor disconnected. Rig scaffold installed. T FL @ 1280' (20 bbls). 6/21/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 06:00 T/I/O=vac/1375/649 Temp=Sl (LRS Unit 70 -CTD Screen: Load IA, Perform Injectivity Test) Load IA with 5 bbls of 50*50/50 meth spear followed by 271 bbls of 50*diesel. Load TBG with 2 bbls of 50*50/50 meth followed by 135 bbls of 50*diesel to top perf. Pumped 40 bbls of 50*diesel to perform injectivitvity test 1,2 &5 bpm for 5 min each: 1 bpm @ 1854 psi 2 bpm @ 1959 psi 6/21/2017 5 bpm @ 2206 psi T/I/O = 180/900/640. Temp = SI. Bleed WHPs to 0 psi (Pre CTD). No AL, flowline, wellhouse or well scaffolding. Rig scaffolding installed. OA cemented to surface. Initial TBG FL = near surface. Initial IA FL @ 1790' (96 bbls). Bled the IAP from 900 psi to 200 psi in 2.75 hours (BT, mostly gas). During the IA bleed the TP decreased 20 psi. Bled the OAP from 640 psi to 50 psi in 5 minutes (Gas/fluid). Monitored the WHPs for 30 minutes. The IAP increased 70 psi and the OAP increased 150 psi. FWPs = 160/270/200, 6/27/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 1700 hrs. • • Daily Report of Well Operations 12/3/2017 ***WELL SHUT-IN ON ARRIVAL*** (SLB E-LINE WHIPSTOCK SETTING) INITIAL T/I/O = 150/100/240 PSI. MIRU, LPT/HPT= PASS. RIH W/ HEAD/ERS/SWIVEL/CENT/WPMOT/WPTET/WPGRT/WPST/GYRODATA GYRO (MEMORY MODE). OAL= 53', OAW=250 LBS, MAX OD = 1.8". TIE INTO DRESSER ATLAS COMPENSATED NEUTRON LOG DATED 9/23/79. PERFORM STOPS AT 2000'; 4000'; 6000',AND 8000'WHILE RIH. PERFORM STOPS AT 9017', 9007', 8997',AND 8987'. PERFORM THREE STOPS AT 8670.75' (9012 GYRO DEPTH) IN ORDER TO CHECK ACCURACY AND REPEATABILITY OF WPP TOOLS RELATIVE BEARING. PERFORM STOPS AT 8000', 6000', 4000', AND 2000'WHILE POOH. GYRO CHECK DATA AT SURFACE. MU WHIPSTOCK AND STANDBY FOR UPDATED SETTING ORIENTATION FROM TOWN. RIH W/ HEAD/ERS/SWIVEL/CENT/WPMOT/WPTET/WPGRT/WPST/BAKER-10/4.5"x7" 6/28/2017 TT BAKER WHIPSTOCK W/(2) RA TAGS. OAL= 51', OAW=650 LBS, MAX OD = 3.62". T/I/O = SSV/390/240. Temp= SI. Bleed WHPs to 0 psi (Pre CTD). No AL, flowline, wellhouse or well scaffolding. Rig scaffolding installed. OA cemented to surface. Initial IA FL @ 1790' (96 Bbls). Bled the IAP to BT from 390 psi to 100 psi in 2.75 hrs (gas). Monitored during RD. During monitor WHPs unchanged. Final WHPs = SSV/100/240. 6/28/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 11:20 T/I/O = 200/200/150. (Pre CDR2). Set 4" H TWC#438 @128", Performed LTT on TWC (Pass). RD upper tree, RU CDR Tree#3 assembly, PT'd 5000 PSI (Pass). RD Companion IA, Installed VR Plug and blind flange to Companion IA, PT'd 3500 PSI (Pass). Moved OA to Pit side of well head, PT'd 300 PSI (Pass). Bled IA to 6 PSI. RDMO. ***Job Complete***. 6/29/2017 FWPs=TWC/6/0. See log for details. ***JOB CONTINUED FROM 28-JUN-2017***(SLB ELINE MEMORY GYRO AND WHIPSTOCK) CONTINUE RIH W/HEAD/ERS/SWIVEL/CENT/WPMOT/WPTET/WPGRT/WPST/BAKER- 10/4.5"x7"TT BAKER WHIPSTOCK W/(2) RA TAGS. OAL = 51', OAW=650 LBS, MAX OD = 3.62". TIE INTO DRESSER ATLAS COMPENSATED NEUTRON LOG DATED 9/23/79. SET TOP OF WHIPSTOCK AT 9012' ORIENTED 28° LOHS, CCL TO TOWS = 14.1'; CCL STOP DEPTH = 8997.9'. LOST-630 LBS NORMAL TENSION ON SETTING. T/I/O = 140/250/100; STABLE BEFORE AND AFTER SHOOTING. SET DOWN APPROX 150 LBS ON WS TO CONFIRM SET. LOG UP FROM WHIPSTOCK. POOH, RDMO. 6/29/2017 WELL SI ON DEPARTURE. FINAL T/I/O = 150/250/150. T/I/O = TWC/10/10. Temp = SI. IA FL. (FB request). No AL. IA FL @ 2208', (119 bbl). Wellhouse,AL line, Flow line&scaffold removed. 6/30/2017 SV, SV, WV, WV= C. MV= O. IA, OA= OTG. (SSV removed). 00:50 T/I/O=TWC/12/23, Temp=S/I, (LRS Unit 72 - Load IA with Diesel Pre CTD) Pumped 102 bbls 45*f diesel down IA. IA went on Vac. DSO notified of well condition upon deprture. Hung Tag on IA casing valve, AFE sign already on wellhead. 6/30/2017 FWHP's=TWCNac/25. T/I/O =TWCNac/130. Temp = SI. Bleed OAP to 0 psi (Pre CTD). Well prepped for CTD. OA cemented to surface. Bled OAP from 130 psi to 0 psi in 30 seconds and held open bleed for 1 hr. Monitored for 30 min, OAP increased 5 psi. Final WHPs =TWCNac/5. 7/2/2017 SV, SV, WV= C. MV= O. IA, OA= OTG. 11:30 hrs. • • North America-ALASKA-BP Page 1 cat- Operation Summary Report Common Well Name:12-03 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/2/2017 End Date:7/10/2017 X3-018HM-C:(1,915,702.00) Project:Prudhoe Bay Site:PB DS 12 Rig Name/No.:CDR-2 Spud Date/Time:8/14/1979 12:00:00AM Rig Release:7/10/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001443 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT Total Depth Phase Description of Operations (h`)) { (usft) 7/2/2017 03:00 - 07:30 4.50 CONS P PRE -RELEASE FROM 2017 MAINTENANCE EVENT UNHOOK SLINGS FROM REEL.- INSTALL SADDLE CLAMPS-INSTALL SHIMS AND SECURE REEL. - PREP TO REMOVE I SHIPPING BAR AND PULL CT ACROSS.-PULL CT ACROSS. 07:30 - 09:30 2.00 CONS P PRE PJSM.STAB COIL.-RIG DOWN STABBING EQUIPMENT.-INSTALL COUNTERS 09:30 - 11:00 1.50 CONS P PRE PJSM.RIG UP COIL CUTTER.-CUT 23'OF COIL,FIND E LINE.-MEG TEST E LINE,GOOD TEST. 11:00 - 17:00 6.00 CONS P PRE PJSM.INSTALL INNER REEL IRON.-INSTALL BULK HEAD. -MODIFY PLUMBING AROUND INNER REEL VALVE DUE TO REEL DIFFERENCE. 17:00 - 17:30 0.50 RIGU P PRE CONDUCT PJSM FOR MOVING RIG OVER TO 12-03 AND PULLING OVER THE WELL. DISCUSS USE OF STOP BLOCKAND STOP SIGNAL. 17:30 - 18:30 1.00 RIGU P PRE MOVE RIG FROM PEAK LIGHT DUTY YARD TO DS-12. ROUTE OF TRAVEL IS LEFT ON SPINE,RIGHT ON CH2 ROAD,RIGHT PAST BOROUGH BUILDING TO DS-12 ACCESS ROAD. 18:30 - 21:00 2.50 RIGU P PRE BOTH MODULES ARRIVE DS-12. PULL PIT MODULE PAST MATTED AREA. PREP TO PULL OVER WELL,TAKE LEAD SOW AND TOW CABLE OFF. BACK UP CLOSE TO WELL,TREE HEIGHT OF 13'2"IS CLOSE TO MAXIMUM HEIGHT RIG CAN PULLOVER. NEED TO PULL THE TREE CAP OFF PRIOR TO SETTING DOWN. 21:00 - 22:30 1.50 RIGU P PRE !CONDUCT PJSM FOR REMOVING TREE CAP. PERFORM LEAK TIGHT TEST ON SWAB AND !MASTER VALVES,GOOD TEST. REMOVE TREE CAP. PULL BOPS UP TO MAX HEIGHT AND PULL I OVER WELL,SET RIG DOWN. PULL PIT MODULE INTO POSITION NEXT TO DRILLING MODULE. 22:30 - 00:00 1.50 RIGU P PRE TRIG UP BOTH MODULES. I SPOT AUXILLIARY EQUIPMENT. 7/3/2017 00:00 - 02:30 2.50 RIGU P PRE ** ACCEPT RIG 00:01 *** SET STACK DOWN. RIG UP MPD LINE AND CHOKE AND KILL LINE. 02:30 - 05:15 2.75 BOPSUR P PRE INSTALL BOP STACK AND SECURE INSTALL RISER. LOAD PITS,PREP FOR BOP TEST. 05:15 - 05:30 0.25 BOPSUR P PRE FRIG EVACUATION DRILL...H2S. -H2S RELEASE IN THE CELLAR,ALARM SOUNDED,DRILL SITE OPERATOR NOTIFIED PRIOR TO DRILL. -ALL HANDS MUSTERED TO SIGN IN TRAILER.PAD SECURED BY LOADER.3 MINUTES. -HEAD COUNT,ALL ACCOUNTED FOR.AAR CONDUCTED.GOOD DRILL. Printed 8/1/2017 3:05:54PM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 2 vi Operation Summary Report`< Common Well Name:12-03 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/2/2017 End Date:7/10/2017 X3-018HM-C:(1,915,702.00) Project:Prudhoe Bay Site:PB DS 12 Rig Name/No.:CDR-2 Spud Date/Time:8/14/1979 12:00:00AM Rig Release:7/10/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001443 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase I Description of Operations (hr) (usft) 05:30 - 15:30 10.00 BOPSUR 1 P PRE PJSM.CONDUCT INITIAL BOPE TEST. -AOGCC REP BOB NOBLE WITNESSING ALL TESTS. -TEST ALL RAMS AND CHOKE VALVES @ 250 /3500 PSI. -TEST ANNULAR PREVENTOR @ 250/2500 PSI. -(2)FAILURES,2 3/8"X 3 1/2"VBRS AND UPPER BLIND/SHEAR RAMS. -CONDUCT DRAWDOWN TEST ON ACCUMULATOR. 15:45 - 21:00 5.25 BOPSUR N PRE PJSM.REMOVE/REPLACE 2 3/8"X 3 1/2" VARIABLE BORE RAMS,UPPER BLIND SHEAR RAMS AND 3"PIPE/SLIP RAMS. 3"PIPE/ SLIP RAMS WERE CHANGED OUT DUE TO BEING CLOSE TO CYCLE LIFE. 20:45 - 00:00 3.25 BOPSUR N PRE PRESSURE TEST BOP DOORS AND BLIND/ SHEAR RAMS. GOOD TEST. TEST VBRS WITH 3-1/2"TEST JOINT,HELD IN PLACE WITH LOWER 2-3/8"PIPE/SLIP RAMS. GET GOOD LOW PRESSURE TEST. TRY FOR HIGH PT ON RAM LOCK TEST,JOINT SLIPS UPWARDS ABOUT 1 FT. SHUT DOWN AND BLEED OFF PRESSURE. PULL JOINT OUT TO INSPECT. VERTICAL SCRATCHING ON THE JOINT. NOTIFY WSUP,NABORS DAY PUSHER AND NABORS ANC MGMT. DISCUSS PLAN TO RE-TEST VBRS. I RE-TEST VBRS WITH THE ADDED STEP OF LOCKING IN THE MANUAL LOCKS ON THE 2-3/8"PIPE/SLIPS. GET GOOD LOW PT. ON HIGH PT,JOINT SLIPS AGAIN. DISCUSS WITH WSUP AND BOTH NABORS PUSHERS,DECIDE TO CHANGE OUT THE 2-3/8"PIPE/SLIP RAMS AND CHANGE OUT THE 2-3/8"SECTION OF TEST JOINT. 7/4/2017 00:00 - 01:00 1.00 BOPSUR N PRE CONTINUE TO CHANGE OUT LOWER 2-3/8" PIPE/SLIP RAMS,INSTALLA NEW SET. CHANGE OUT 2-3/8"TEST JOINT SECTION TO A NEWER PIECE. 01:00 - 03:15 2.25 BOPSUR N PRE RETEST VBRS WITH 3-1/2"TEST JOINT,HOLD WITH LOWER 2-3/8"PIPE/SLIP RAMS. TEST 250/3,500 PSI FOR 5 MIN,GOOD. TEST VBRS WITH 2-3/8"TEST JOINT,GOOD. TEST 3"PIPE/SLIP RAMS,GOOD. EACH TEST TO 250/3,500 PSI FOR 5 MIN. 03:15 - 04:00 0.75 BOPSUR P PRE PREPARE TO TEST 2 CHOKE VALVES FROM THE BACKSIDE. INSTALL BOOT ON ELINE.TEST VALVES ON CHOKE MANIFOLD,(REVERSE FLOW). -TEST @ 250/3500 PSI,GOOD TESTS. 04:00 - 05:45 1.75 RIGU P PRE PJSM ON PUMPING BACK THRU COIL,(SLACK MANAGEMENT). -PUMP BACKWARDS THRU COIL. 05:45 - 07:00 1.25 RIGU P PRE PREP TO CUT COIL. -PJSM.CUT 485'OF COIL FIND ELINE. Printed 8/1/2017 3.05:54PM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 3 ce- Operation Summary Report Common Well Name:12-03 I AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/2/2017 End Date:7/10/2017 X3-018HM-C:(1,915,702.00) Project:Prudhoe Bay Site:PB DS 12 Rig Name/No.:CDR-2 Spud Date/Time:8/14/1979 12:00:00AM Rig Release:7/10/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001443 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) (hr) (usft) Phase Description of Operations Date From-To Hrs Task Code NPT ', Total Depth I 07:00 - 10:15 3.25 RIGU P PRE PJSM.MAKE UP COIL CONNECTOR,(DIMPLE). -SOME TROUBLE INSTALLING,PULL TEST TO 50K. -CONNECTOR MOVED APPROXIMATELY 1/4'. 10:15 - 13:15 3.00 RIGU P PRE PJSM.CUT COILAND RE INSTALL CONNECTOR. -PULL TEST TO 50K,OK. 13:15 - 16:00 2.75 RIGU P PRE INSTALL UQC AND MEG TEST,OK. -PRESSURE TEST COIL CONNECTOR AND UQC CONNECTIONS. -PRESSURE TEST @ 250/4700 PSI,OK. -STAB ON AND PRESSURE TEST INNER REEL IRON AND PACK OFFS. -PRESSURE TEST TO 250/3500 PSI,OK. BREAK OFF AND INSTALL CHECK VALVES. -PRESSURE TEST CHECKS TO 250/3500 PSI, OK. 16:00 - 18:00 2.00 RIGU P PRE VALVE CREW CHECK TORQUE ON TREE BOLTS BRING ON BOARD BPV LUBRICATOR. PJSM WITH ALL INVOLVED 18:00 - 21:00 3.00 RIGU P PRE RU BPV LUBRICATOR, PURGE THROUGH WITH METHANOL PRESSURE TEST TO 3500#. PASSED PULLED TWC, WELL HAS 95# SHUT WELL IN. PURGE THROUGH TO TIGER TANK TO EVACUATE LUBRICATOR. RD. OFFLOAD BPV LUBRICATOR 21:00 - 00:00 3.00 RIGU N PRE HAVE DISCUSSIONS WITH WELL SUPERINTENDENT REGARDING REEL WEIGHT CALCULATIONS. • WAIT ON DECISION AFTER ALL INVOLVED PARTIES DISCUSSED. DECISION TO REDUCE REEL LENGTH. CUT OFF BHI AND CTC. MAKE UP HYDRAULIC COIL CUTTER CLEAR FLOOR. PREP TO CUT COIL 7/5/2017 00:00 - 04:30 4.50 RIGU N PRE CUT TOTAL OF 1230'OF PIPE/E-LINE TEST E-IINE. PREP PIPE FOR CTC. INSTALL CTC. 04:30 - 06:00 1.50 RIGU N PRE MAKE UP UQC TO COIL CONNECTOR. -PRESSURE TEST TO 250/4700 PSI,5 MIN EACH,GOOD TEST. -MAKE UP FLOATS AND TEST @ 250/3500 I PSI,GOOD. 06:00 - 07:30 1.50 RIGU P PRE PJSM.DISPLACE COIL W/KCL -LINE UP AND PUMP 15 BBLS MEOH FOLLOWED BY SLICK 1%KCL. -PUMPING @ 2.25 BPM/1100 PSI. Printed 8/1/2017 3:05:54PM *AII depths reported in Drillers Depths* • • Page 4 North America-ALASKA-BP gar Operation Summary Report Common Well Name:12-03 1AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/2/2017 End Date:7/10/2017 X3-018HM-C:(1,915,702.00) Project:Prudhoe Bay Site:PB DS 12 Rig Name/No.:CDR-2 Spud Date/Time:8/14/1979 12:00:00AM Rig Release:7/10/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001443 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Firs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 07:30 - 12:00 4.50 STWHIP P WEXIT PJSM.P/U BAKER WINDOW MILLING BHA. -M/U PDL,PRESSURE TEST TO 3500 PSI/ MIN/OK. - LEAVE 100 PSI ON LUBRICATOR TO EQUALIZE PRESSURE. -OPEN MASTER MALVE AND SEE TAG ON STOP RING EARLY. -X/O IN BHA IS 3.28"OD,CLOSE MASTER AND LOWER SWAB. BREAK OFF AND CHANGE OUT X/O,MAKE BACK UP. -RETEST LUBRICATOR,EQUALIZE PRESSURE AND OPEN SWAB AND MASTER VLV. TAG STOP RING W/NO GO AND SPACE OUT. -CLOSE 2 3/8"PIPE SLIPS,BLEED PRESSURE AND BREAK OFF. -SPACE OUT IS 1'TOO HIGH,REPEAT PROCESS AND LOWER 1' - WITH PIPE SLIPS CLOSED ON BHA,BREAK OFF,SPACE OUT IS GOOD. -ON WELL @ 12:00 HRS. 12:00 - 16:30 4.50 STWHIP P WEXIT CREW CHANGE AND PJSM. -TABLE TOP H2S/RIG EVACUATION DRILL WITH CREW COMING ON. -TEST TOOLS,TEST QTS @ 3500 PSI,OK. TAG UP MOVING UP 0.2' -RIH W/WINDOW MILLING BHA ON 2 3/8" HS-90 4.45 PPF COIL. PUMPING 1 BPM,TAKING RETURNS THRU CHOKE TO TIGER TANK. -ANOUNCEMENT MADE AND DRILL SITE OPERATOR AND BP SECURITY NOTIFIED OF GAS VENTING OP. -SEEING DIESEL RETURNS INITIALLY.STOP @ 1000'AND CHECK SPINDLE ON REEL. -TIGHTEN SADDLE BOLTS ON REEL,ENSURE ALL IS OK. -CONTINUE IN HOLE,SEEING GASEOUS RETURNS. -STOP @ 3500'TO ALLOW WHP TO DROP AND SEE FLUID RETURNS. -CHECK REEL AND GREASE SPINDLE WHILE STOPPED. -CONTINUE IN HOLE,PUMPING 1.5 BPM, TAKING RETURNS THRU CHOKE TO TIGER TANK. -SEEING GASEOUS RETURNS,KEEPING PRESSURE DOWNSTREAM OF CHOKE BELOW 150 PSI. -STOP AGAIN AT 6500'AS WHP CLIMBING, CIRCULATE OUT GAS.CHECK REEL,OK. -CONTINUE IN HOLE,80 FPM,CIRCULATING @ 1.5 BPM,375 PSI. -OBSERVE FLUID RETURNS WHILE RIH @ 7700'.CONTINUE IN HOLE. -RIH TO 8650' Printed 8/1/2017 3:05:54PM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 5 Phi. Operation Summary Report r Common Well Name:12-03 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/2/2017 End Date:7/10/2017 X3-018HM-C:(1,915,702.00) Project:Prudhoe Bay 7 Site:PB DS 12 Rig Name/No.:CDR-2 Spud Date/Time:8/14/1979 12:00:00AM Rig Release:7/10/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00001443 Active datum:Kelly Bushing/Rotary Table @73.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) J (usft) 16:30 - 18:00 1.50 STWHIP P WEXIT LOG TIE IN. -LOG DOWN @ 3 FPM F/8650'. -MINUS 11'CORRECTION. -CLOSE CHOKE, CONTINUE TO RIH WHILE TIGER TANK IS EMPTIED -DRY TAG WHIPSTOCK AT 9014' -BOTTOM KILL OPERATION. 18:00 - 21:00 3.00 STWHIP P WEXIT ONLINE FOR BOTTOM KILL 'ONCE CLEAN RETURN, PURGE LUBRICATOR. 21:00 - 21:30 0.50 STWHIP P 8,990.00 WEXIT CIRCULATE ACROSS TOP TO GET A LOSS RATE 0.40 BPM IN/0.36 BPM OUT LOSS RATE OF 2.4 BPH. 8.41 PPG IN /8.41 PPG OUT COME OFFLINE. PERFORM 10 MINUTE PUMPS OFF FLOW CHECK.WELL STATIC 21:30 - 23:00 1.50 STWHIP P 9,019.00 WEXIT CIRCULATE WELL OVER TO MILLING SYSTEM 9.06 PPG IN/8.43 PPG OUT 3.06 BPM IN/2.94 BPM OUT(7.2 BPH LOSS RATE) CIRC PRESSURE=2161# MUD CIRCULATED SURFACE TO SURFACE. COME OFFLINE. CLOSE EDC. DRY TAG WHIPSTOCK TAG AT 9014' COME ONLINE AT 2.70 BPM WENT BY DRY TAG DEPTH. PICK BACK UP AND DRY TAG AGAIN AT 9019' •STK �� 23:00 - 00:00 1.00 STWHIP_ P 9,020.70 WEXIT MILL 3.80"WINDOW IN 7.0"LINER PER BAKER \v' REP FROM 9019'MD 11- `U�A -RATE:2.50 BPM IN,2.48 BPM OUT '-MUD WEIGHT:8.97 PPG IN,9.07 PPG OUT -DWOB:1.5-2.0 KLBS -CIRC PRESSURE:3293 PSI 7/6/2017 00:00 - 05:30 5.50 STWHIP P 9,025.00 WEXIT CONTINUE MILLING 3.80"WINDOW IN 7.0" LINER PER BAKER REP FROM 9020.7'MD -RATE:2.48 BPM IN,2.47 BPM OUT -MUD WEIGHT:8.98 PPG IN,9.01 PPG OUT -DWOB:2.25-4.5 KLBS -CIRC PRESSURE:3300 PSI 05:30 - 07:30 2.00 STWHIP P 9,026.00 WEXIT I LOOKS LIKE WE EXITED @ 9026.7 -MILL RAT HOLE TO 9036' 07:30 - 08:30 1.00 STWHIP P 9,036.00 WEXIT BACK REAM WINDOW @ 1 FPM.UP AND DOWN. DRY DRIFT WINDOW,WINDOW IS CLEAN. 08:30 - 08:45 0.25 STWHIP P 9,036.00 WEXIT PICKUP AND PERFORM 10 MIN FLOW CHECK. -8.9 PPG MUD IN AND OUT,WELL BORE IS STABLE. -NO LOSSES TO FORMATION. 08:45 - 10:30 1.75 STWHIP P 9,036.00 WEXIT PJSM.OPEN EDC AND POOH. - 10 MIN FLOW CHECK AT SURFACE. -8.9 PPG MUD IN AND OUT,WELL BORE IS STABLE. -PITWATCHER SHOWING 1.9 BBLS LOST TO FORMATION W/POOH. 10:30 - 11:30 1.00 STWHIP P 9,036.00 WEXIT PJSM.TAG UP,OPEN BLEED VALVE AND BREAK OFF INJECTOR. -INJECTOR OFF @ 11:00 HRS.STAND BACK WINDOW MILLING BHA. -RIH W/BUILD SECTION BHA.TEST QTS @ 3500 PSI,OK..SET DEPTH. Printed 8/1/2017 3:05:54PM *AII depths reported in Drillers Depths* WELLFEAD= GRAY ACTUATOR= BAKERY • 1 2_0 3NOTES: 4-1/2"CHROME TUBING*** 1 OKB.ELEV= 73' • BF ELEV= I i I�. 2016' H9-5/8'HES ES CEMENTER KOP= 4000" Max Angle= 23°@ 4500' 20"CONDUCTOR H 113" Datum MD= 9102' ;#, , ' ' 2109' --14-1/2"HES X NP,D=3.813" D= " 9-518"CSG,47#,L-80 HYD 563,D=8.681" — 2029' 2148' H9-5/8"FOC �� 2443' H9-5/8"FOC F6-518-BOWEN CSG PATCH,D=8.681" —1_2029'-2033' ' ' 13-3/8'CSG,72#,L-80 BTC,D=12.347:1-1 2729' GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT DATE 4 3409 3408 0 G DOW RK 16 02/17/15 Minimum ID =3.804" @ 8281 MG 5866 5740 22 MMG SO RIC 28 01/26/17 MILLED 4-1/2" XN NIPPLE 2 7145 6944 18 MMG DMY RK 0 06/29/08 1 7967 7743 8 MMG DMY RK 0 06/29/08 8179' —14-1/2"HES X NP,ID=3.813" Z 8200' j--19-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" •--j 8224' H4-1/2"HES X NP,D=3.813" ' 8281' -j4-1/2"HES XN NP MILLED TO 3.804"(6/17/17) , 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, —1 8291' I---' `--I 8291' —14-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" HELM TT NOT LOGGED 8632` H9-5/8-X 7"BOT TACK,D=? TOP OF 7"LNR —1 8532' 8538' H9-5/8"X 7"BOT LNR HG .D=? 9-518"CSG,47#,RS-95/N-80 BTC,ID=8.681" 8869' - PERFORATION SUMMARY REF LOG:BRCS ON 09/09/79 ' ANGLE AT TOP PERF:2°@ 8984' Note:Refer to Production DB for historical perf data 1 9012' 4-1/2"BKR DELTA WHIPSTOCK SIZE SPF ME2VAL Opn/Sqz SHOT SQZ ' -#113-3/8" 6 8984-9009 S 08/04/89 06/20/91 w/2 RA PP TAGS (06/29/17) II 3-3/8" 6 8984-9009 0 08/22/94 15 /,„ I ,...4, j- TOC(06/18/17)] 3-3/8" 6 8992-9009 0 08/22/94 :.:.y:,:,:,y:l 3-3/8" 0.5 8992-9004 0 10/04/91 9064' —17"SLB POSISET PLUG(06/17/17) i 3-3/8" 4 9086-9106 S 12/12/85 06/20/91 3-3/8" 4 9106-9116 S 10/04/91 3-3/8" 4 9123-9160 S 03/11/80 06/20/91 3-1/8" 4 9180-9219 S 03/11/80 06/20/91 3-1/8" 4 9229-9242 S 03/11/80 06/20/91 3-1/8" 0 9296-9298 S 09/16/79 06/20/91 �.�.�.�.t.�.�.i PBTDj 9718` 11111111 7"LNR,29#,N-80 BTC,.0371 bpf,ID=6.184" — 9760' 1111111111/1/1• 111111111111111 TD H 9765' .4.4.4.1.4.4.4.1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY uar 09/21/79 PKR 176 ORIGINAL COMPLETION 02/20/15 NXW/JME GLV C/O(02/17/15) WELL. 12-03 07/03/85 N1ES RWO 02/01/17 JMG/JMD GLV C/O(01/26/17) PERMIT No: 1790410 07/02/08 D14 RWO 06/22/17 BTWJMD/vL.LED XN MP,SET PLUG&CMT API Pb: 50-029-20377-00 09/18/08 I B/JMD DRLG DRAFT CORRECTIONS 07/03/17 KFS/JMD SET WFPSTOCK(06/29/17) SEC 18,T1 ON,R15E,938'FSL&44'FEL 10/20/08 PJC DRA1MdG CORRECTIONS 02/18/15 PJC ADD CONDUCTOR DEPTH BP Exploration(Alaska) OF to • S g91 I//7:.• THE STATE Alaska Oil and Gas ti�..� ���, LAsKA A Conservation Commission,,,.:_=_ ! 333 West Seventh Avenue I GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O �Q, Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna Egbejimba Engineering Team Lead BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-03 Permit to Drill Number: 179-041 Sundry Number: 317-176 Dear Mr. Egbejimba: 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, Cathy . Foerster Chair DATED this I( ay of May, 2017. RBDMS IA/MAY 1 6 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM•N • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well El Operations shutdown El Suspend 0 Perforate ❑ Other Stimulate El Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 • Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 179-041• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory El Development 0• 99519-6612 Stratigraphic 0 Service El 6. API Number: 50-029-20377-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Il PBU 12-03 RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: MAY 0 2 2017 O17 ADL 028330' PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Ju k 9765 • 9536 9718 9489 2398 None None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 35-115 35-115 1530 520 Surface 2700 13-3/8" 35-2735 35-2734 4930 2670 Intermediate 8840 9-5/8" 33-8873 33-8644 6870/8150 4760/5080 Production Liner 1228 7" 8532-9760 8304-9531 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8984-9009 8755-8780 4-1/2"12.6# 13Cr80 31-8295 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 8203/7977 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Et Service ❑ 14.Estimated Date for Commencing Operations: May 15th,2017 15. Well Status after proposed work: Oil ❑ WINJ El WDSPL El Suspended ® • 16.Verbal Approval: Date: GAS El WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned El 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkosz,Ryan R be deviated from without prior written approval. Contact Email: Ryan.Ciolkosz@bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 5977 Authorized Title: Engineering Team Leader-CTD y&&R•'�WO G Authorized Signature: �J 1L. C�7)N lE' 1 ,� Date: J/ r1 I s`C)17 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number:--/ PlugRe Integrity / 1 ` -`� 9 ty ❑ BOP Test L� Mechanical Integrity Test 0 Location Clearance ❑ _ 4__ r 11 U icq. Other: 15A ..1-2,- /- 71_c, 31'o„7, fist A1-1 /I cAaV j'I tvz'vi tt/ j-r.7t±' 25-vv/25 ,y Post Initial Injection MIT Req'd? Yes El No 0 / L Y-2-re,..t.1-e-,J`v9�J lel Ct 14" t� ' tiP 1-12�e- Spacing Exception Required? Yes 0 No Cd/ /Subsequent Form Required: /a— 40 pe-,- „20A f-Cz ..i!2..(z) I 1 APPROVED BYTHE / ‘7?-44/1 _Approved by: `� COMMISSIONER COMMISSION Date:3-_//_/7 1i`1Z 5/8/'z ORIGINAL RBDMS MAY 1 6 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • To: Alaska Oil & Gas Conservation Commission by From: Ryan Ciolkosz CTD Engineer Date: May 1, 2017 Re: 12-03 Sundry Approval Sundry approval is requested to plug the 12-03 wellbore as part of the drilling and completion of the proposed 12-03A CTD sidetrack. Well was initially perf'd in Ivishak and then in Sag in 1989. No remaining opportunity in parent bore. Parent bore is currently setting the facility marginal WOR and therefore has zero remaining value. Proposed plan: Drill a through tubing sidetrack with the CDR 2 Coiled Tubing Drilling rig on or around July 1st, 2017. E-line unit will set a CTD whipstock. CDR 2 will mill a 3.80"window in the 4-1/2" liner and drill an Ivishak Zone 4 well. The lateral will be completed with a 3-1/2" x 3-1/4' x 2-7/8" L-80 liner which will be cemented and perforated. This Sundry covers plugging the existing 12-03A perforations via the 12-03A liner cement job or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)) and via posi-set plug. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack istattached for reference. 1. Coil cur, P C14je U hai q water car �f 4V4 O' �J` s/ prodvcio ,- e PQd 4�c Aqf 4n Ga n�, ' (4? ���� I ower r1,G h %�e OI I e- 4i 4le V " C � ar fav ,�pPO � ��1 ti�ti oil fate fur/ rec�r,71 fAw/ce 0/1A., At /i„we (0 ptfro.$), vvet �o d orrioq Of rAe --1�7 re[o.�rry ��o& 7'�isj� • CTD Drill and Complete 12-03A program: Pre-Rig Work(scheduled to begin May 15st, 2017) E 1 Mill XN. Set Posi-Set Plug, Set Whipstock F 2 Perform lnjectivity test on Sag perfs C 3 Squeeze Cement perforation depending on results of Injectivity test. S 4 Set DMY GLM Design ✓ 5 Set TWC Rig Work: 1. MIRU and test BOPE. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,398 psi. 2. Mill 3.80" window plus 10' of rathole. Swap the well to 8.5-9.5 ppg drilling fluid. 3. PU drilling BHA with GR/Resistivity 4. Drill 4.25" hole to TD 5. Run 3-1/2" x 3-1/4" x 2-7/8" L-80 liner. 6. Pump primary cement bringing TOC to TOL, 44 bbls of 15.3 ppg liner cmt planned* 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: Install LTP if necessary.*, SBHPs 3. F: Pressure test Liner top packer 4. D: No Flow test 5. S: Pull gauges after minimum of 5 days of production *Approved alternate plug placement per 20 AAC 25.112(i) Ryan Ciolkosz CTD Engineer 564-5977 CC: Well File Joe Lastufka • I Rtt_= 4-1/165M •WHL-EAD= GRAY 1 2_0 3 SA NOTES: 4-1/2"CHROME TUBING""" ACTUATOR= BAKER C OKB.ELEV= 73' I ►l• I BF.H-EV= • 2016' H9-5/8"HES ES CEMENTER KOP= 4000' 20"CONDUCTOR, 113'# Max Angle= 23°@ 4500' , ' ' 210W H4-1/2"HES X NP,D=3.813" Datum MD= 9102' D_ 9-5/8"CSG,47#,L-80 HY D 563,D=8.681" H 2029' - 2148' H9-5/8"FOC 9-5/8"BOWEN CSG PATCH,ID=8.681" —{2029'-2033' I 2443' H 5/8"FOC ' 13-3/8'CSG,72#,L-80 BTC,D=12.347' H 272W GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" @ 828111 4 3409 3408 0 MMG DOME RK 16 02/17/15 3 5866 5740 22 MMG SO RK 28 02/17/15 4-1/2"X N NIPPLE 2 7145 6944 18 MAG EM' RK 0 06/29/08 1 7967 7743 8 MMG DAY FE 0 06/29/08 I I 8179' --14-1/2"I-E5 X NP,D=3.813" Z 8200' -19-58"X 4-1/2"BKR S-3 PKR,10=3.875" ' ' 8224' —14-1/2"NES X fes,D=3.813" I t • 8281' H4-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, —{ 8291' 1---' `- 1 8291' —14-1/2"WLEG,D=3.958" .0152 bpf,ID=3.958" H ELMD TT NOT LOGGED 8532' —I 9-5/8"X 7"BOT TRACK,D=? TOP OF 7"LNR — 8532' 8538' H 9-5/8"X 7"BOT LNR HGR,D=? [9-5/8"CSG,47#,RS-951 N-80 BTC,D=8.681" 1--. 8869' PERFORATION SIM4kRY REF LOG:BHCS ON 09/09/79 , ANGLE AT TOP PERF:2°@ 8984' Nbte:Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 8984-9009 S 08/04/89 06/20/91 , 3-3/8" 6 8984-9009 0 08/22/94 3-3/8" 6 8992-9009 0 08/22/94 ' 3-3/8" 0.5 8992-9004 0 10/04/91 3-3/8" 4 9086-9106 S 12/12/85 06/20/91 3-3/8" 4 9106-9116 S 10/04/91 3.318" 4 9123-9160 S 03/11/80 06/20/91 3-1/8" 4 9180-9219 S 03/11/80 06/20/91 3-1/8" 4 9229-9242 S 03/11/80 06/20/91 3-1/8" 0 9296-9298 S 09/16/79 06/20/91 �.�.�.�.*.�.*.�.1 FBTD H 9718' .11111111111/11 7"LNR,29#,N-80 BTC,.0371 bpf,D=6.184" —{ 9760' 411111111/11/11f TD — 9765' DATE REV BY COMMENTS DATE REV BY COMMENTS PR UHOE BAY UNIT 09/21/79 PKR 176 ORIGINAL COMPLETION 08/04/14 PJC CSG,GLV,PERF CORRECTIONS WELL: 12-03 07/03/85 N1ES RWO 02/17/15 WC/PJC SSSV NOT REQUIRED PER WIC FERMIT No:'1790410 07/02/08 D14 RWO 02/18/15 PJC ADD CONDUCTOR DEPIH AR Pb: 50-029-20377-00 09/18/08 HB/JMD DRLG DRAFT CORRECTIONS 02/20/15 N XW/JMC GLV C/0(02/17/15) SEC 18,T10N,R15E,938'FSL&4-4'FEL 10/20/08 PJC DRAWING CORRECTION 11/18/08 /JMD ADM)20"CONDUCTOR BP Exploration(Alaska) . TREE- 41/16 SM WELLHEAD= GRAY 12-183A Proposed SA NOTES: 4-1/2"CHROME TUBING"*" ACTUATOR= BAKER C OKB.ELEV= 73' f BF.ELEV-=- i 0, 2016' H9-5/8'H ES CEMENTER •KOP= 4000' Max Angle= 23"@ 4500' 20'CONDIJGI'OR, H 113' 2109' —4-1/2"HES X NP D=3.813" Datum M3= 9102' —#, , D= " /1/—9-5/8"CSG,47#,L-80 HYD 563,1D=8.681" H 2029' 2148' —19-5/8"FOC 2443' H9-5/8'FOC 9-5/8"BOWEN CSG PATCH,D=8.681' H 2029'-2033' I\13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2729' GAS LFT MAM)RELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" @ 8281 (..I ?MG 3409 3408 0 G DOME RK 16 02/17/15 3 5866 5740 22 11M3 SO RK 28 02/17/15 4-1 12"X N NIPPLE 2 7145 6944 18 MMD DMY RK 0 06/29/08 1 7967 7743 8 MAG DM/ RK 0 06/29/08 PERFORATION SUMMARY REF LOG:BHCS ON 09/09/79 ' , 8179' —{4-1/2"FSSX NIP,D=3.813" ANGLE AT TOP PERF:2"@ 8984' Note:Reser to Production O8 br historical pert data SIZE SPF INTERVAL Opn/Sqz pnJ qzSHOT SQZ X'- - 8200' —+9-5/8"X 41/2"BKR S-3 RR,ID=3.875" 3-3/8" 6 8984-9009 S 108/04/89 06/20/91 3-3/8" 6 8984-9009 0 (08/22/94 8 H41/2'HES X NP D=3.813" 3-3/8" 6 8992-9009 O 08/22/94 3-3/8' 0.5 8992-9004 0 1 10/04/91 8253'-3.70 BakerD epbym entS beve 3-3/8' 4 9086-9106 0 12/12/85 06/20/91 3-3/8' 4 9106-9116 S 1 10/04/91 I I 8281' --141/2"HES XN NP,D=3.725' 3-3/8' 4 9123-9160 S 03/11/80 06/20/91 3-1/8' 4 9180-9219 S 03/11/80 06/20/91 3-1/8" 4 9229-9242 S ;03/11/80 06/20/91 8291' H41/2"MEG,D=3.958' 3-1/8" 0 9296-9298 S 1 09/16/79 06/20/91 HELM TT NOT LOGGED 4-1/2'TBG,12.6#,13CR 80 YAM TOP, —1 8291' .0152 bpf,D=3.958" 8632' H9-5/8"X 7"BOT 11 ACK,D=? TOP OF 7"LNR H 8632' 9-5/8"CSG,47#,RS-95/N-80 BTC,D=8.681" —1 8869' 863W --19-5/8-X7"BOT LNR HGR D=? ' 3-1/2"6.4# L-80 STL -9000'M D A;, vii 4.4t. 7"x4-1/2"Dela W hipstpck-9014'MD '4444* `1. 7"PosiSetPlig -9050'M D I .m=. w 3-1/4 6.4# L-80 TC II-10787'M D 7"LW,29#,N-80 BTC,.0371 bpf,D=6.184' H 9760' pg7D 9718' TD H 9766• DATE REV BY COMVBNITS DATE REV BY COMMENTS PRU HOE BAY UNIT 09/21/79 PKR 176 ORIGINAL COMPLETION 08/04/14 PJC CSG,GLV,PERF CORRECTIONS WELL: 12-03 07/03/85 NIES RWO 02/17/15 MJC/PJC SSSV NOT REQUIRED PER WIC PERMIT No:'1790410 07/02/08 D14 RHO 02/18/15 PJC ADD CONDUCTOR DEPTH AR No: 50-029-20377-00 09/18/08 I-B/JWD CRLG DRAFT CORRECTIONS 02/20/15 NXW/JP C GLV C/O(02/17/15) SEC 18,T10N,R15E,938'FSL&44'Fa. 10/20/08 PJC DRAW NG CORRECTIONS 11/18/08 /MD ADDED 20"CONDUCTOR BP Exploration(Alaska) Well Blank •DR2-AC BOP Schematic /fate _ Quick Test Sub to Otis I -1.1 ft — — — —-— Topof7"Otis I x" 1 4 CDR2 Rig's Drip Pan Distances from top of riser I Excluding quick-test sub i-":"iTop of Annular ( 0.0 fit . ► I0 E��I \ 7-1/16"5k Flange X 7"Otis Box C 7 Hydril 7 1/16" Top Annular Element 0.7 ft Annu1.11Fil lar Bottom Annular 2.0 ft ► `„m„„ Blind/Shear CL Blind/Shears ( 3.3 ft ► ooll 2-3/8"Pipe/Slips $141CL 2-318"Combi's 4.1 ft ► ; �" " B5 B6 """""rr yy 67 I Brr8 Deployment Line B6 "'1571-,1m116,1" C11?._4 �1CIF 1 C ossa_ Ill III ' Choke Line 3"Pipe/Slips CL 3"Pipe/Slips 6.6 ft 2-3/8"x 3-1/2" CL 2-318"x3-1/2"VBRs 7.4 ft ► VBR gni B1 11 B2 r B3 I 1 B4� Choke Line nIr ri10ff 1�1`: .r 1-4ki` � ' t III III Blind/Shear CL Blind/Shears 10.0 ft Millralea 2-3/8"Pipe/Slips CL 2-3/8"Combi's 10.7 ft ► _.... • CL of Top Swab 13.3 ft �4,0 1'—Swab 2 Test Pump Hose ♦^ 4/Swab 1 CL of Bottom Swab 14.8 ft T1 i T2 St CL Flow Tee 16.2 ft .. • •� -„ = BOP2 CL of SSV 17.5 ft 1 _ l�� Master 2 IA Fusable CL of Master Valve 19.0 ft BOP1 tel Master 1 LDS 20.5 ft 1-------►._ _ II 11 /1 11 II II II II II II Gound Level ...ii II II II ii ii ` • • N. o Thousand Cubic Feet of Gas ("MCF") per Day or Gas-Oil Ratio (MCF per Barrel) jLn O O O O O O 0 0 0 0 0 0 0 vi o vi6 ui o 0 m m N N .i e-i lA O I L_ cc 4•2be I E UN O -��.rrrr__-ss�s----__ __ -6 U c 4P a 1 ^M^ co `+1 0 :_r - - ---- --- lOO�4PP = MI J . l'i C7 m v q-1 _- To sOO�4ie o TL ▪ Q1ro I _ r (C , o C O -,• m m =_--' 14, — �, .; root O = I a v E -..=-- __CD — o --0 0 0 �`� . . !6 0 cu a U a a a = et4P — E E E ____�__ r 0 O o 3 3 7 __ 4,6,6:0,. 6 Q L u v U - _z 6r v v .= a -__ _ 4�� o 13 W ------ -_ F6 CUo _<__ 6 0 __ r'Ott, a a -2s -� 1'66 a CL > �_ y r. 686r ii L �°/' Y z ..---v- _.5 - 1 186r 4 .. S8 . 1. U -:- -a a s 4P o Iv . iiiiiL T., e 1 :6›. 1 ; r <5.,. 0 o O o 0 0 0 0 0 0 0 o P r r. O 00 D N i .-i /lea Jad aale/y�to slams io Aea . ad HO Jo siaiiee o 0 a Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist / in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist 411, work)the initial reviewer will cross out that erroneous entry and initial the it on both copies of the Form 10-403 (AOGCC's and operator's copies). +/ Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. e e yorTb 44,Iy/ms's, THE STATE Alaska Oil and Gas hti -sem , o ALAS <:A f Conservation Commission 333 West Seventh Avenue " 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS P. Fax: 907.276.7542 www.aogcc.alaska.gov October 24, 2016 Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration (Alaska) Inc. P.O. Box 196612ctaltE® Y` s J x.317 Anchorage,AK 99519-6612 RE: No-Flow Verification PBU 12-03 PTD 1790410 Dear Ms. Cocklan-Vendl: On September 14, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-03. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-03. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank,the tubing pressure monitored at the production tree bled to zero within 2 minutes. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-03 demonstrates an ability to flow unassisted to surface. Any cleanout,perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, Janke/ 1 e James B. Regg Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com AKDCWellIntegrityCoordinator@bp.com Ryan Daniel, BPXA • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg tc(zt/u.r. DATE: September 14, 2016 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector PBU 12-03 - BP Exploration PTD 1790410 ' 9/14/16: Got on location and met with Ryan Moore and Rick Houlton (BPXA representatives). We looked at the rig up and confirmed all gauges had current , calibration stickers. Got all wellhead pressures and shut well in for 3 hours, recording wellhead pressures every hour. After 3 hours opened well to a tank via 2" hardline and - witnessed well bleed to ZERO in 2 minutes. ; The following table shows test details: 10:00 2/47/718 11:00 4/47/713 12:05 6/47/709 12:07 6/47/709 Start bleed to tank (ALL GAS) - 12:09 0/47/709 ' ZERO Pressure 1 Pressures are T/IA/OA Summary: Witnessed a successful no-flow test of PBU 12-03 following the criteria of 20 AAC 25. 265(I)(1)(B) — "well pressure discharged not later than 5 minutes after a three- hour charted pressure build-up period." Attachments: NONE SCANNED APR 0 r 2017 17 2016-0914_No-F lowPBU_12-03_bb.docx Page 1 of 1 STATE OF ALASKA 4111/L.ASKA OIL AND GAS CONSERVATION COMMIS! REPORT OF SUNDRY WELL OPERATIORS 1. Operations Performed 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:Well Lock Treatment I1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 179-041 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20377-00-00 7. Property Designation(Lease Number): ADL 0028330 8. Well Name and Number: PBU 12-03 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 9765 feet Plugs RECEIVED measured feet true vertical 9536 feet Junk measuredp feet FEB 0 5 2016 Effective Depth: measured 9718 feet Packer measured 8198 feet U true vertical 9489 feet Packer true vertical 7972 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 31 -111 31 -111 1530 520 Surface 2699 13-3/8"72#L-80 30-2729 30-2729 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1228 7"29#N-80 8532-9760 8304-9531 8160 7020 Perforation Depth: Measured depth: 8984-8992 feet 8984-8992 feet 8992-9004 feet 9004-9009 feet 9086-9106 feet 9123-9160 9106-9116 feet 9123-9160 feet 9180-9219 feet 9229-9242 feet True vertical depth: 8755-8763 feet 8755-8763 feet 8763-8775 feet 8775-8780 feet 8857-8877 feet 8894-8931 8877-8887 feet 8894-8931 feet 8951-8990 feet 9000-9013 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 26-8289 26-8062 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8198 7972 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): OA at surface. Treatment descriptions including volumes used and final pressure: t� cci r:j \k, k ' )b 7 Gallons Well Lock,1400 psi. troRN�f ••' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 381 484 5167 1521 268 Subsequent to operation: 458 500 5250 1497 266 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-535 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,de. a, - Phone +1 907 564 4424 Date 2/4/16 Form 10-404 Revised 5/2015 1/7-1- 2 /J q I`t, > 0r �� RBDMS Lt- FEB 0 5 2016 Submit Original Only • C) • o• 0 0 CD 0 0 0 0 co N I,- CO 00 C0 CO N O (D co O N O O CC) O N V Ln • Ln r- r- U N o D 0 0 0 0 0 0 L co co N- 10 N. 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O Q p Q c? a p 0 < 0 _0,.� Q 7 Q N Q Q Q L Q O 0 tft L Y N Y Y C O o p co O o f 0� U N O- U U U O O N U L . > a) O Q p 0 > U p pp c >>p O >p Y > -'a' >>O O O • - 2 ° — .-� .0 N > p > Cl) > mN ..... ,c O > d 0 o O 0 0 a o O p- D a cn O 0 = • cn O c O EiNi in 0 C, a. 0.5 N a-Q c -C00 fa `Or a Cly ao Q OM 0- � 0d a) Na j • 0 2 2 p E _a _1 / / O \_ % - .% / w / - � k / / E / 6 / > c e E / > 7e) ƒ // / / c # . . _ca e t ) -co- �� --E p ® � I 0 \ = e o = 1-- 0 o - � .§ E $ p an ® qa ' � � = § % 2j A\ f / o 0 0- / E P Cr) E / k % \ / k k U) E g n/ A a) \ ± © ± \ $ 0 e _c 7 c 0 = 0 0cam o 5 0 5 - 2 \ c 9 Co i - \ \ E ® 2 \ E Q 0 / f 0 \ \ R / a b 0 _o Ni-- $ o to = _ cn � oo � ) � ��\ ƒ m 2 � N ƒ / / % \ / / f \ / / _1 ƒ E C $ O » / ii o / 5 ƒ o M _2 " • L " --- C 0 < 2 ta. \ \ 0 � k / 6 � .§ \ \ \ 2k 0. , 2 _ / ccm< /pR¥ / « / \ a) 0 \ - c I- a - / / / \ R �� $ 0 7 m G= . > a -a » d n > 12 $ p U)< CDC $ U) 2 o � � � / $ m E w / _ .2 $ f f > / g ° a" om 6 .g o % = ? > 61 > / / < $ ® -® / / $ / < $ / O \ .. o o O > e o � / $ O , / d i - O \ > e \ eL OE11O .c " Odo " O ± 0 e > - a > - _ C » - o < m / & m 6 o m & m m m & a t m © © © Co m / \ d / / CO 55 N e 9 co o 2 / % » & I HEE.= 4-1/16 5M • 1 2-03 SY NOTES: 4-1/2"CHROME TUBING' WELLFEAD= GRAY ACTUATOR= BAKER C OKB.ELEV= 73 • I • • BF.ELB/= 07 2016' —9-518°HES ES caveTrut KOP= 4000' 20"conoucToR, —1 113' Max Angle= 23°Q 450(7 / 1 ' 2109' —14-1/2'FES X NP, =1813" Datum MD= 9102' = 2118' —9-5/8"FOC 9-5/8"CSG,47#,L-80 HY D 563,D=8.681' H 2029' — 2443' —9-5/8°FOC 9-5/8'BOWEN CSG PATCH,ID=8.681" H 2029'-2033' A 13-3/8"CSG,72#,L-80 BTC,ID=12.347" — 2729' KGAS LIT MANDRELS ST TVD DEV TYPE VLV LATCH FORT DOTE 4 3409 3408 0 WAG DOW RK 16 02/17/15 Minimum ID =3.725" @ 8281 3 5866 5740 22 WAG SO RK 28 02/17/15 4-1/2"XN NIPPLE 2 7145 6944 18 MAG CMY RK 0 06/29/08 1 7967 7743 8 PIG [NY RK 0 06/29M8 I I 8179' —4-1/2"HES X NP,D=3.813" 8200' H9-5/8"X 4-1/2"BKR S-3 PKR,C=3.875' 1--1 8224' —14-1/2"HES X NP, =3.813" • 1--1 8281' H4-1/2"HES XN MP,D=3.725" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, — 8291' j—' 8291' —14-1)71M_EG,C=3.958" .0152 bpf, =3.958" Hawn NOT LOGGED 8632' —9-5/8"X 7'BOT TIEBACK,11)=? TOP OF 7^LMH 8532' " = 9-5/8"CSG,47#,RS-95/N-80 BTC,ID=8.881' — 8638' —9-5/8X 7"BOT LNR HGR,D ?8869' 11 PERFORATION SUNMARY FEF LOG:BHCS ON 09/09/79 ANGLE AT TOP PERE:2°,.• 8984' Nbte:Refer to Roduction[13 for historical perf data SIZE SW INTER'VAL Opn/Sqz SHOT SQZ 3-3/8" 6 8984-9009 S 08/04/8906120/91 3-3/8" 6 8984-9009 0 08/22/94 3-3/8" 6 8992-9009 0 08/22/94 3-3/8° 0.5 8992-9004 0 10/04/91 3-3/8" 4 9086-9106 S 12/12/85 06/20/91 3-3/8° 4 9106-9116 S 10/04/91 3-3/8" 4 9123-9160 S 03/11/80 06/20/91 3-1/8° 4 9180-9219 S 03/11/80 06/20/91 3-1/8° 4 9229-9242 S 03/11/80 06/20/91 3-1/8" 0 9296-9298 S 09/16/79 06/20/91 FBTD H 971r 0111'frt'fl 4/1..1S.44.4.4 11 7"LNR,29#,N-80 BTC,.0371 bpf, =8184" — 9760' .../.I.. 0.....1.4 ....../. — 9766' DATE REV BY COM DATE REV BY COMENTS FRUCHOE BAY (K 09/21(79 PKR 176 ORIGINAL COMPLETION 08104/14 PJC CSG,GLV,FERE CORRECTIONS WH.L: 12-03 07103/85 N1 ES RWO 02/17/15 RIC/PJC SSSV NOT REQUIRED PER WC FERMI No:'1790410 07/02/08 D14 RWO 02/18/15 PJC ADO(X)PCUCTOR DEPTH AR Pb: 50-029-20377-00 09/18/08 FE/JM) DRLG DRAFT CORRECTIONS 02/20/154,4XWIJMLIGLV C/O(02/17/15) SEC 18,T10N R15E,938 FSL 8 44'FEL 10/20/08 PJC DRAWF4G CORRECTIONS 11/18/08 /.M) ADDED 20"COMUCTOR BP Exploration(Alaska) r.or Tk 1/7„.'s� THE STATE Alaska Oil and Gas ��—'� of T Conservation Commission �-�� Al .ASI�:A ttit x- _ = 333 West Seventh Avenue 4 ” GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ti'' Main 907 279 1433 OF ALASICQ' Fax 907.276 7542 www aogcc alaska gov Jessica Sayers SCANNED Well Integrity Engineer O / BP Exploration(Alaska), Inc. iri P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-03 Sundry Number: 315-535 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a"--4 /614"N Cathy P. Foerster ,�_ Chair DATED this c day of September, 2015 RBDMS C, SEP 0 9 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM 1N APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 /",�/ ,Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well ijRe-enter Susp Well 0 Other Well Lock ® ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 179-041 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development [JI- . 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-20377-00-00 7. If perforating: 8. Well Name and NtigtF,1,--.7,,, ,,v� ti E D What Regulation or Conservation Order governs well spacing in this pool? Yes 0 Nom L. I � Will planned perforations require a spacing exception? PBU 12-03 • 9. Property Designation(Lease Number): 10. Field/Pools: ;AN) lO�� 4 S �i 1�`l (s ADL 0028330• PRUDHOE BAY,PRUDHOE OIL A ���� 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9765 • 9536 • 9718 9489 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"94#H-40 31 -111 31-111 1530 520 Surface 2699 13-3/8"72#L-80 30-2729 30-2729 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1228 7"29#N-80 8532-9760 8304-9531 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8984-9298 8755.4-9069.21 4-1/2"12.6#13Cr80 13Cr80 26-8289 Packers and SSSV Type. See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program m Exploratory 0 Stratigraphic 0 Development m' Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil m • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: e7/4 I f S WINJ 0 GINJ 0 WAG 0 Abandoned ❑ Commission Representative: I Op Shutdown 0 GSTOR 0 SPLUG 0 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer /15.Signature 'hone +1 907 564 4281 Date I Z COMMISSION USE ONLY Conditions of approval:N. I ommission so that a rep -sentative may witness Sundry Number: 3�5 - 53� Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No Ld Subsequent Form Required: /6 - ¢c 4.. APPROVED BYTHE /� Approved by: � �(L,,`� COMMISSIONER COMMISSION Date:g-,/r v-r, q/4/15 4 ORIGINAL RBDMS SEP 09 2015 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval Attachments in Duplicate /t' .Y/../,i / :7> '' 3I'/S as a,00000000 - NCONONOOO G N 1 V ON- N- CO 0000 4iCC') MN- 10N- 1CDCO') = 100) D '– CO – ' v CON—V00000COOCO CAS f- - O – N NMCOM V MW ' N- 0 .4- 0) 0100 NNNNCOO) CO c %-. 00MCOM000 M M M O t CAM N N N N- CO 4+ CD Q) ' ti N- O) O CA � N M CO LO CO CD CO I. O C CO N- N L N N N CD CO Q) CD M 2 < C4) MCOV) CO() OWL° ON N N CD CO CO o Q O O 10rn co O) O Pe A' C9 °i) g02 C0 024k tZ N *k � *k r-- 4k co •(/� _ I•••• • N CA _ QO N r CA . O i e- 0') 0) .c V". CD COM 0) a)C � NNNO � NCND W W W W CA « « Q Q C W 0 0 0 0 .- o V W W W W 0• OLLWWW Z Z w W W W W W m ODHHHF- ZD owZZZZJF-, Packers and SSV's Attachment ADL0028330 SW Name Type MD ND Depscription 12-03 PACKER 8198 7971.75 4-1/2" Baker S-3 Perm Packer 12-03 PACKER 8278 8051.13 5-1/2" Baker SAB Packer by To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 08-28-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 12-03 WeIlLock OA Treatment • Objective This program is for treating the annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, nitrogen should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Under Evaluation — PAL Previous Test: 06-12-08 CMIT-TxIA passed to 3000psi Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas) Well Operation Detail (Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 750-800 F throughout the entire job Relevant History: > 10/05/13: LLR OA — ..51 gpm @ 3000 psi > 09/12/14: Shell Test MIT-OA Failed, post well lock treatment > 12/15/14: Pump 3.3 gallons of WeIlLock into OA > 12/23/14: OA PT to 1200 psi Passed with diesel (criteria: 10 psi/min for 5 min) > 01/29/15: NFT Passed witnessed by Bob Noble > 02/17/15: Set LGVL in sta#4, OGLV in sta# 3 > 05/20/15: OA BUR —105 psi/day Well Program: 1 D Heat well externally using heater trunks. 2 D Strap TOC or WeIlLock in OA and fill to bottom of VR profile. Squeeze WeIlLock with 2200 psi of Nitrogen. 3 D Blow nitrogen path across valves and leave 800 psi cap of nitrogen during cure period. 4 D Leave crystal gauge on well and take pressure and temperature readings on _ casing, twice daily. Record in AWGS. 5 D After 14 days, put well under-eval to check for OA pressure stability 2 oft TREE= 4-1/16 5M 1 2-03 _p3 S Y NOTES: 4-12"CHROME TUBING*** WELLHEAD= GRAY ACTUATOR= BAKER C OKE.ELEV= 73' I �• BF.ELEV= 2016' -I 9-518"I-ES ES CEMENTER • KOP= 4000' 20"CONDUCTOR, MEM2109' —4-1/2-HES X NP,D=3.813" Max Angle= 23° 4500' _#, 1 Datum MD= 9102' D= " /0/1/ 9-5/8"CSG,47#,L-80 HYD 563,D=8.681" H 2029' - 2148' ~9518'FOG 9-5/8'BOWEN CSG PATCH,ID=8.681' --i 2029'-2033' I 2' ' H 9-5/8"FOC ' 13-3/8'CSG,72#,L-80 BTC,D=12.34r H 2729' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" 8281 4 3409 3408 0 MMG DOME RK 16 02/17/15 I„ 3 5866 5740 22 MMG SO RK 28 02/17/15 4-1/2"XN NIPPLE 2 7145 6944 18 MMG DMY RK 0 06/29/08 1 7967 7743 8 MMG DMY RK 0 06/29/08 ' '---I 8179' E--4-112"HES X NP,D=3.813" Z 8200' H9-5/8"X 4-1/2'BKR S-3 PKR,D=3.875" r---I 8224' —14-1/2"HES X NP,D=3.813" ' rI 8281' —14-1/2"FES XN NP,D=3.725' 4-12"TBG,12.6#,13CR-80 VAM TOP, — 8291' 1--' ` 8291' —14-1/2"WLEG,ID=3.958- .0152 bpf,D=3.958" _1 aMD TT NOT LOGGED 8632' —I9-5/8"X r BOT TACK,ID=? TOP OF 7"LNR H 8532' 9-5/8"CSG,47#,RS-95/N-80 BTC,D �- =8.681" -- -- 8869' 'hi 8638' --19-518'X 7"BOT LNR HGR,D=? FERFORAT ON S1.MARY REF LOG:BHCS ON 09/09/79 , ANGLE AT TOP PERF:2°@i 8984' Note:Refer to Reduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ ' 3-3/8' 6 8984-9009 S 08/04/89 06/20/91 ' 3-3/8' 6 8984-9009 0 08/22/94 3-3/8" 6 8992-9009 0 08/22/94 ' 3-3/8" 0.5 8992-9004 0 10/04/91 3-3/8" 4 9086-9106 S 12/12/85 06/20/91 3-3/8' 4 9106-9116 S 10/04/91 3-3/8' 4 9123-9160 S 03/11/80 06/20/91 3-1/8" 4 9180-9219 S 03/11/80 06/20/91 3-1/8" 4 9229-9242 S 03/11/80 06/20/91 3-1/8" 0 9296-9298 S 09/16/79 0620/91 I'V f4.•.•. 1"1 PBTD -1 9718' 7"LNR,29#,N-80 BTC,.0371 bpf,0=6.184" H 9760" .�.�.�.�.�.�.�. 00.0.0 TD — 9765. 4...........0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRLIDHOE BAY LHT 09/21/79 PKR 176 ORIGINAL COMPLETION 08/04/14 PJC CSG,GLV,PEW F TIONS WELL: 12-03 07/03/85 NIPS RWO 02/17/15 MJC/PJC SSSV NOT REOI.I ED PER WIC PERMIT No:'1790410 07/02/08 1114 RWO 02/18/15 PJC ADD CONDUCTOR DEPTH API No: 50-029-20377-00 09/18/08 1-18/JM) DRLG DRAFT CORRECTIONS 0220115 NXW/JMC GLV C10(02/17/15) SEC 18,T10N,R15E,938'FSL&44'FE. 10/20/08 PJC DRAWING CORRECTIONS 11/18/08 /JMD ADDED 20"CONDUCTOR BP Exploration(Alaska) • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, September 03, 2015 3:30 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Pettus, Whitney; Sayers, Jessica Subject: OPERABLE: Producer 12-03 (PTD#1790410) Outer Annulus Pressure Manageable by Bleeds Attachments: Producer 12-03 (PTD #1790410) TIO Plot.docx All, Producer 12-03 (PTD#1790410)outer annulus pressure did not display a stabilization trend below the well's engineered safe operating pressure of 1280 psi. However,following a bleed from 1260 psi to 100 psi on August 11, 2015, the outer annulus pressure was monitored and determined to be manageable by bleeds.The well has been reclassified as Operable. An updated TIO plot has been included for reference. Please call with any questions or concerns. Thank you, MAY ® 2 2016 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: D&C Well Integrity Coordinator Sent: Monda , August 10, 2015 4:51 PM To: AK, OPS GC1 OSNF;AK,OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C W I SServices Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK,'RES.GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'Regg, James B (DOA)'; Pettus, Whitney; Sayers, Jessica Subject: UNDER EVALUATION: Producer 12-03 (PTD #1790410) Sustained Outer Annulus Casing Pressure above MOASP All, 1 . • 0 Producer 12-03 PTD#1790410 TIO Plot September 03, 2015 Well 12-03 <0, 3.000 t TEG -f IA ►( f 00A Or 1.CU. l 0703'1'_ 0710'15 07^7.15 0724+15 0731 15 0007115 2210'15 0221 15 052215 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, August 10, 2015 4:51 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA); Pettus, Whitney; Sayers, Jessica Subject: UNDER EVALUATION: Producer 12-03 (PTD #1790410) Sustained Outer Annulus Casing Pressure above MOASP Attachments: 12-03 Final Annular Pressure Limit Analysis.pdf; Producer 12-03 (PTD# 1790410) TIO Plot.docx All, Producer 12-03 (PTD# 1790410) was reported to have sustained outer annulus casing pressure above MOASP on August 08, 2015.The pressures were reported to be TBG/IA/OA= 250/1480/1015 psi. At this time, the well has been reclassified as Under Evaluation for further diagnostics. The outer annulus pressure will be monitored to determine the stabilization trend before evaluating if the pressure is manageable by bleeds. After reviewing the well's engineering specs, it was determined that the OA pressure is safe to manage below 1280 psi. Should the outer annulus pressure exceed this determined engineered limit, it will be bled off and evaluated for another Well-lock treatment. Please do not bleed the well until an OA stabilization pressure can be determined unless 1280 psi is exceeded. Plan Forward: 1. Downhole diagnostics: Monitor outer annulus for stabilization pressure (minimum once daily) 2. Downhole diagnostics: Perform outer annulus repressurization test 3. Well Integrity Engineer: Additional diagnostics as needed A TIO plot and copy of the annular pressure limit analysis have been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED AUG 20 (Alternate:Kevin Parks) �� BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 Producer 12-03(PTD #1790410) TIO Plot August 10, 2015 • :.o,.an,a nvm e<xn mm.avnn sr...ax..avxn x>x src,s rams awm mmx mam or.+em mnam mxx a.xm mn,.mzri aax ax�.r r�acu a»u amm aax wn wa+e aa,,e rwix • STATE OF ALASKA i KA OIL AND GAS CONSERVATION COMP, ION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon li Repair Well ❑ Plug Perforations U Perforate❑ Other LJ Well Lock Technology Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development CI Exploratory 179-041-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20377-00-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028330 PBU 12-03 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s)• PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary RECEWED Total Depth measured 9765 feet Plugs measured None feet true vertical 9535 85 feet Junk measured None feetMAR 1 8 2015 Effective Depth measured 9718 feet Packer measured 8198 feet AOG VC true vertical 9488 89 feet true vertical 7971 75 feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 31 -111 31 -111 1530 520 Surface 2699 13-3/8"72#L-80 30-2729 30-2728 64 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1228 7"29#N-80 8532-9760 8303 93-9530 86 8160 7020 Perforation depth Measured depth 8984-8992 feet 8992-9004 feet 9004-9009 feet 9086-9106 feet 9106-9116 feet 9123-9160 feet 9180-9219 feet 9229-9242 feet 9296-9298 feet True Vertical depth 8755.4-8763 4 feet 8763 4-8775 4 feet 8775 4-8780 39 feet 8857 35-8877 34 feet 8877.34-8887 33 feet 8894 33-8931.3 feet 8951 29-8990 27 feet 9000 26-9013 25 feet 9067 21-9069.21 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 26-8289 26-8062 06 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker S-3 Perm Packer 8198 7971 75 Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Micro-Annulus of Outer-Annulus Near Surface ANNE 1)descriptions including volumes used and final pressure )l i�l�6at��� 9/4/14.2 87 Gallons Well Lock,23 Gallons Musol Solvent, 1430 psi, 12/15/14 3 3 Gallons Well Lock,2500 psi 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 278 6863 4663 1533 362 Subsequent to operation 824 926 5486 1659 343 14 Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 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 0 Exempt 314-452 Contact Garry Catron Email Garrv.Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature /I 44.4.11/ Phone 564-4424 Date 3/18/2015 1, 'Ti- 4 Oa/ /, RBDMSik APR - 3 2015 , 0 Form 10-404 Revised 10/2012 Submit Original Only w o• OOOOOOO CSN CD 00 CO 00N � O 0DCn - N- ON- 00 U � MNLLNCDCOCC) • 1.0 Co — CO 0) CO CD CO CO CO CO - Co vv � C�) C.0V CD . 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TOP OF 7"LN2 —{ 8632' f 8638' 9-5/8"X 7"BOT LNR HGR D=? 9-5/8"CSG,47#,RS-95/N-80 BTC,D=8.681' —{ 8869' PERFORATION SUMMARY REF LOG:BHCS ON 09/09/79 , ANGLE AT TOP PEFF:2"@I 8984' Note:Refer to Rod uction OB for historical perf data ' S7F SPF INTERVAL Opn/Sgz SHOT SOZ 3-3/8" 6 8984-9009 S 08/04/89 06/20/91 ' 3-3/8" 6 8984-9009 0 08/22/94 3-3/8" 6 8992-9009 0 0822/94 I 3-3/8' 0.5 8992-9004 0 10/04/91 3-3/8' 4 9086-9106 S 12/12/85 0620/91 3-3/8' 4 9106-9116 S 10/04/91 3-3/8" 4 9123-9160 S 03/11/80 06/20/91 3-1/8" 4 9180-9219 S 03/11/80 06/20/91 3-1/8" 4 9229-9242 S 03/11/80 06/20/91 3-1/8' 0 9296-9298 S 09/16/79 06/20/91 ,.1.#•#- -#-�-#•t FBTD H 9718' 11111111 7'MR,29#,N-80 BTC,.0371 bpf,D=6.184" —{ 9760' .111111111111111 411/11111111111 TD 9765' /.1.1...1.....•.1 DATE REV BY COM ENTS DATE REV BY COMMENTS PRUDHDE BAY IJNTf 09/21/79 PKR 176 ORIGINAL COMPLETION 08/04/14 PJC CSG,GLV,FERE CORRECTIONS WELL: 12-03 07/03/85 N1 ES RWO 02/17/15 MJCI PJC SSSV NOT R EDUIR )PER WIC PERMIT No:'1790410 07/02/08 D14 RWO 02/18/15 PJC ADD CONDUCTOR DEPTH AR No: 50-029-20377-00 09/18/08 HB/JM) DRLG G DRAFT CORRECTIONS 02/20/15 NXW/JMC GLV C/O(02/17/15) SEC 18,T1 ON,R15E,938'FSL&44'FEL 10/20/08 PJC DRAWING CORRECTIONS 11/18/08 /JM) ADDED 20"CONDUCTOR BP Exploration(Alaska) v OF TSF 0,1,A11/j,,s� THE STATE Alaska Oil and Gas , �i—7,, n Conservation Commission ALAIc:A it - _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS*Q. Fax. 907.276.7542 www.aogcc alaska.gov March 4, 2015 Mary Cocklan-Vendl Pipeline Compliance & Conformance Manager BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612 RE: No-Flow Verification PBU 12-03 SCANHEU MAR 0 6 20� PTD 1790410 Dear Ms. Cocklan-Vendl: On January 29, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit 12-03. The AOGCC Inspector confirmed that the proper test equipment was rigged up to evaluate Prudhoe Bay Unit 12-03. The test methodology used by BPXA was designed to demonstrate the well was incapable of unassisted flow of hydrocarbons to surface as allowed by 20 AAC 25.265(l)(1)(B): (B) well pressure is discharged not later than five minutes after a three-hour charted pressure build-up period. Tubing, inner annulus, and outer annulus pressures were monitored and recorded during a continuous three-hour well shut in period. Upon opening the production tubing to the test tank, the well demonstrated the discharge of well pressure within one minute. Liquid and gas flow rates were unmeasurable. A subsurface safety valve is not required to be installed in this well based on the no-flow test result. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit 12-03 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Sincerely, James B. Regg KIT 1 Supervisor, Petroleum Inspections ecc: P. Brooks AOGCC Inspectors AKOPSFFWellOpsCompRep@bp.com P (77o4(o Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> ,- Sent: Friday,January 30, 2015 1:57 PM I` zi To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC / S EOC TL; AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 DS12 Operator;Vohra, Prachi; Dos Santos, Higino W; Sayers, Jessica; Sternicki, Oliver R;AK, OPS FS1 Field OTL; Regg,James B (DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan; Redmond, Randy; Cocklan-Vendl, Mary E; AK, D&C DHD Well Integrity Engineer Subject: Permission to Continue Flowing Producer 12-03 (PTD #1790410) Post NFT All, Per a conversation with Jim Regg at the AOGCC, BP has been given verbal permission to continue flowing Producer 12-03 (PTD# 1790410) post a successful No Flow Test (NFT) performed January 29, 2014.The test was witnessed by an AOGCC representative, and demonstrated the well was incapable of unassisted flow to surface per 20 AAC 25.265(1) (1) (B) criteria. Please call with any questions. Thank you, Laurie Climer SCANNED y}/ (Alio-nate. Jack l)a//y) ) /B'P►Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinatorPBP.com 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg "\-?ett 4415 DATE: 1-29-2015 P. I. Supervisor FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector PBU 12-03 BPXA PTD 1790410 1/29/15: I arrived at PBU 12-03 at 11:30 am to witness a no flow. I met with BPXA rep Leighton Grey and we went over BPXA's no flow procedure. The well had been opened , to atmospheric pressure to bleed down at 5:00 am. I inspected the rig up and had them shut the tubing in at 12 noon for their 3 hour build up test. At 1500 (after a 3 hour build up time) the pressure on the tubing was 13 psi. The tubing was opened up and in 51 sec it had bled to 0 psi on their gauge. There was a slight gas flow to bleed tank. At 4 min 5 sec there was 0 flow to tank. The following table shows test details: Time Pressures Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 1200 0/0/720 • 0 0 Shut well in 1300 5/0/720 0 0 Well still shut in 1400 8/0/720 , 0 0 Well still shut in 1500 13/0/720 - 0 0 Open tubing up to bleed off 1500+51s 0/0/720 unmeasurable 0 Pressure bled to zero in 51 sec 1504+5s 0/0/720 0 0 zero flow at 4 min 5sec after opening to atmosphere 1 Pressures are T/IA/OA Summary: PBU 12-03 meets the criteria for a no flow determination. Attachments: none SCANNED ,n 2015-0129_No-FlowPBU_12-03_bn.docx Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT 0 1 29'.4: 1. Operations Abandon - Repair WellLj Plug Perforations El Perforate L Othe !a We Lock Treatment Performed: Alter Casing ❑ Pull TubinCl Stimulate - Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdowr❑ Stimulate -Other ❑ Re-enter Suspended We❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work: Developmen0 Stratigraphi❑ Exploratory El Service 5. Permit to Drill Number: 179-041-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20377-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028330 PBU 12-03 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9765 feet Plugs measured None feet true vertical 9535.85 feet Junk measured None feet Effective Depth measured 9718 feet Packer measured 8198 feet true vertical 9488.89 feet true vertical 7971.75 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 31 - 111 31 - 111 1530 520 Surface 2699 13-3/8" 72# L-80 30-2729 30-2728.64 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1228 7" 29# N-80 8532-9760 8303.93 - 9530.86 8160 7020 Perforation depth Measured depth 8984-8992 feet 8992-9004 feet 9004-9009 feet 9086-9106 feet 9106-9116 feet 9123-9160 feet 9180-9219 feet 9229-9242 feet 9296-9298 feet True Vertical depth 8755.4 - 8763.4 feet 8763.4 - 8775.4 feet 8775.4 - 8780.39 feet 8857.35 - 8877.34 feet 8877.34 - 8887.33 feet 8894.33 - 8931.3 feet 8951.29 - 8990.27 feet 9000.26 - 9013.25 feet 9067.21 - 9069.21 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 26-8289 26-8062.06 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer 8198 7971.75 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): S 0 JAN 0 2 2015 e� 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: 278 6863 4663 1533 362 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratcr❑ Developments Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSP❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCI 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: 314-452 Contact Garry Catron Email Garry. Catron EBP.Com Printed Name Garry Catron Title PDC PE Signature c/,*V - Phone 564-4424 Date 10/1/2014 M lz/z1fl4- Form 10-404 Revised 10/2012 ! // fl1 ibm�gi�ly- 6 2014 Casing / Tubing Attachment ADL0028330 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 31 - 111 31 - 111 1530 520 INTERMEDIATE 2001 9-5/8" 47# L-80 30 - 2031 30 - 2030.64 6870 4760 INTERMEDIATE 437 9-5/8" 47# R -S-95 2030 - 2467 2029.64 - 2466.64 8150 5080 INTERMEDIATE 5690 9-5/8" 47# N-80 2467 - 8157 2466.64 - 7931.1 6870 4760 INTERMEDIATE 712 9-5/8" 47# R -S-95 8157 - 8869 7931.1 - 8640.43 8150 5080 LINER 1228 7" 29# N-80 8532 - 9760 8303.93 - 9530.86 8160 7020 SURFACE 2699 13-3/8" 72# L-80 30 - 2729 30 - 2728.64 4930 2670 TUBING 8263 4-1/2" 12.6# 13Cr80 26 - 8289 26 - 8062.06 8430 7500 Daily Report of Well Operations ADL0028330 DSUMMARY _.0. 9/2/2014 pulled VR plug. RDMO Job Complete see log for details Final T/I/O=S1/200/0 T/1/0=367/92/226, Temp=S/I, Assist DHD, Hot Backside to warm up OA (Welllock) Pump 5 bbls 9/3/2014 meth, 272 bbls 180*f crude down IA. Job continued on 9-4-14 WSR T/1/0= 445/160/490. (OA Micro annulus Wellock treatment). Bleed OA pressure off until gas negligible did not obtained zero gas break out. Bled IA to 105 psi, would not bleed down any further. Flush OA with 2% KCL, still seeing some gas during flush. Pumped 1.5 gallons Wellock and displace to OA with 2% KCL water. Shut in return line and pump additional 1.37 gallons to reach 1160 psi, shut down and monitor the pressure for 15 minutes. The pressure slowly increased due to thermal expansion to 1430 psi, pumped an additional 2L water and the pressure came up to 1430 but appeared to be squeezing away. After two hours pressure at 1250 psi, pumped 1/2 bbl of Musol solvent pause for 10 minutes and pumped additional '/z bbl Musol solvent. After another 10 minutes flushed OA with methanol all to 55 gallon drums for disposal with the WOA Env Waste Coord. Had some gas initially when we started pumping the Musol but quickly went to all fluid, maintained the 9/4/2014 treating pressure during the flush. T/I/O = SSV/105/2335 T/I/O = SSV/140/1213. Temp = SI. WHPs (Well lock). AL disconnected. Heater working properly. Crystal gauge on OA working properly (recording). 9/5/2014 SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 00:30 T/I/O = SSV/140/955. Temp = SI. WHPs & Temp (Post Wellock treatment). AL spool dropped. Casing temp @ OA is 108*. OAP decreased 60 psi since 0900 today. Crystal gauge on OA recording. 9/6/2014 SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 22:35 T/I/O = SSV/90/900. Temp = SI. WHPs & Temp (Post Wellock treatment). AL spool dropped. Casing temp @ OA is 96*. OAP decreased 115 psi since 09:00 on 9/6/14. Crystal guage on OA recording. 9/8/2014 SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00. T/I/O=SSV/49/761. Temp =S1. WHP's & Temp (post wellock treatment). AL spool dropped. Casing temp @ OA is 70°. OAP decreased 139 psi since 05:00 on 09-08-2014. Crystal gauge on OA recording. 9/9/2014 SV, WV, SSV =C. IA, OA =OTG. 18:00. T/I/O = SSV/100/730. Temp = SI. WHPs & Temp. (Post Wellock treatment). AL spool dropped. Casing temp @ OA is 66°, adjusted heater trunks to heat OA casing more (Temp reading taken from SC just below OA casing spool @ 7 o'clock position). Crystal gauge on OA recording, battery @ 2 bars. Depressured tree cap & flow cross voids. 9/11/2014 SV, SSV = C. WV = LOTO. MV = O. IA & OA = OTG. 21:15 Daily Report of Well Operations ADL0028330 TWO=SSV/100/831. Temp =S1. MIT-OA to 3000 psi with suitcase pump **FAIL** (post well lock). AL spool dropped. Pumped OAP to 3000 psi 16 times using a total of 3.62 gallons of diesel. On final pressure up lost 298 psi in 1 st 15 min & 110 psi in the 2nd 15 min for a total of 408 psi in 30 min. See log for details. Job complete. Final WHP's =SSV/100/1000. 9/12/2014 SV, WV, SSV =C. MV=O. IA, OA =OTG. 18:00. T14E= " 41/165M l W t tfAD: GRAY' 'ACnATOR = BAltljt C' KB. B.Ei% _ �M T3 BF. B.1=V = 8984 - 9D09 S 4000" Max Angie = 23.6 4500" Dat= MD= 9102' Da b;: 8800' SS •, v r rlama -i Id Minimum ID = 3.725" @ 8281 4-1C2"XN NIPPLE 4-12• TBG,12.8#, 13CR•$C VAM TOP, H Bm' 0152 bpi, D = 3.958' 1TOPOF 7• LNR 9-5/8' CSG, 478, FiS W N-80 BTC, D= 8.681• PERORATION SUIM ARY FEV LOG BRCS ON 09/09/79 ANGLE AT TOP PERF: 2• a 8964' NDb: Rafer b RWtw on OB for Wabrical perf data SIZE SPF I MERVAL OpVSgz SEDT St3Z 06/20/91 3-3/6' 6 8984 - 9D09 S MOM 3-3/8"' 6 8984-9009 O 06J22/94 3.3/8" 6 8992-9009 0 0&22194 3-3/8" 0.5 8992 - 9004 O 10/OM9l 3-3/8' 4 9086-9106 S 12/12/85 0620191 3-3/8• 4 9106-9116 S 10/04/91 3-3/8• 4 9123-9160 S 03f11/80 0620191 3-118' 4 9180-9219 S 03111180 06/20/91 3-116• 4 9229 - 9242 S 03/11/80 06/201'91 3-1fi• 0 9296-9298 S 09M6f79 0620191 T' LNC 290. N-80 BTC, .0371 bpf, D = 6.184" 9780' -f-876s' 'SAFETY NOTES:• •.,• r /I �•�� =MEM NO 2 817V w ia: �• �� qtr®�r�� ra t : �i:•irrri/ • •• • • •• • • __ rrrn r R,,- Ma"m 911.- 4112' FES X NP, D = 3.813• 8200' 9-518• X 4-112" mm 5-3 Pw D = 3-575- V 4 - 3.832ESD j 8281' rj41R• FES XN N ; D = 3.725' j $ • 412' vw EGy D = 3.958" SMD Tf NOT LOGG� 8632' &518'X7" SQT TESAM D = ? NW- 9.518•X7' 90T LNR FIGK D a ? ta—f-M PF UDHOE BAY UW VALL' 12.03 PERMIT W.-'1790410 API Ab: 504029-20377-00 SO-- 18, T10N, R15E. 938" F& 8 44' FT3 BP Bt l ratba (Alaska) w ia: �• �� qtr®�r�� ra t : �i:•irrri/ • •• • • •• • • __ PF UDHOE BAY UW VALL' 12.03 PERMIT W.-'1790410 API Ab: 504029-20377-00 SO-- 18, T10N, R15E. 938" F& 8 44' FT3 BP Bt l ratba (Alaska) ~ge Project Well History File' Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [3 Diskettes, No. D Maps: [] Grayscale items: D Other, No/Type [3 Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds [] Other Project Proofing .. BY: ~ BREN VINCENT SHERYL MARIA Scanning Preparation , ~'~ LOWELl_ BY: BRENVINCENT SHERYL MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: / q6 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,/~ YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY BREN VINOENT~ARIA LOWELL DATE:/¢ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.w~l • • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~~ ~ c~~ FILE # ~ ~/.,~.e~ ~d G- To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission =333 W. 7th Ave., Ste. 100 + Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 oF 71 THE STATE Alaska Gil ani V1ALA31.1" GOVERNOR SEAN PARNELL Higino Dos Santos Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-03 Sundry Number: 314-452 Dear Mr. Santos: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 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, t93;tq_'� Cathy P. erster Chair DATED this e—day of August, 2014. Encl. SCONEV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 2f30 RECEIVED AUG 0 1 2814 07---s T/ 4//f- 1. Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well[E - Change Approved Program❑ Form Suspend❑ Plug Perforations❑ Perforate ❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp. Well❑ Stimulate ❑ Alter Casing❑ Other: Well Lock Technology . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Exploratory ❑ Development [] Stratigraphic ❑ Service ❑ 179-041-0 3. Address: 6. API Number: P.O. Box 196612, Anchorage, AK 99519-6612 50-029-20377-00-00 7. If perforating: 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 12-03 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0028330 PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9765 9536 - 9718 9489 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# H-40 31 - 111 31 -111 Surface 2699 13-3/8" 72# L-80 30-2729 30-2728.64 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1228 7" 29# N-80 8532-9760 8303.93 - 9530.86 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4-1/2" 12.6# 13Cr80 13Cr80 26-8289 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work. Commencing Operations: Oil 2 Gas ❑ WDSPL ❑ Suspended ❑ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: 7 GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Higino Dos Santos Email Higino.Dos Santos@BP.Com Printed Name / Higino Dos Santos Title Production Engineer Signature Phone 564-4342 Date -0/ Prepared by Garry Catron 564-4424 COMMISSION USE ONLY (� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ` Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: yt T — Q P4 rr q V { Y� y Spacing Exception Required? Yes ❑ No Subsequent Form Required: `f APPROVED BY _ Approved by: COMMISSIONER THE COMMISSION Date: Z?— Form 10-403 Revised 10/2012 0AR4QIij\8 o vLid for 12 months from the date of approval. Submit Form and Attachments in Duplicate IRM30I lS AUG 11 2N //4 � /�b y Casing Summary ADL0028330 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 94# H-40 31 111 31 111 1530 520 H-40 INTERMEDIATE 712 9-5/8" 47# R-S-95 8157 8869 7931 8640 8150 5080 R-S-95 INTERMEDIATE 437 9-5/8" 47# R-S-95 2030 2467 2030 2467 8150 5080 R-S-95 INTERMEDIATE 2001 9-5/8" 47# L-80 30 2031 30 2031 6870 4760 L-80 INTERMEDIATE 5690 9-5/8" 47# N-80 2467 8157 2467 7931 6870 4760 N-80 LINER 1228 7" 29# N-80 8532 9760 8304 9531 8160 7020 N-80 SURFACE 2699 13-3/8" 72# L-80 30 2729 30 2729 4930 2670 L-80 TUBING 8263 4-1/2" 12.6# 13Cr80 26 8289 1 26 1 8062 8430 7500 13Cr80 AB ABANDONED Perforation Attachment MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED ADL0028330 BRIDGE PLUG PULLED MLK Well Date Perf Code MD Top MD Base TVD Top TVD Base 12-03 7/7/08 BPP 8984 8992 8755 8763 12-03 7/7/08 BPP 8992 9004 8763 8775 12-03 7/7/08 BPP 9004 9009 8775 8780 12-03 7/7/08 BPP 9086 9106 8857 8877 12-03 7/7/08 BPP 9106 9116 8877 8887 12-03 7/7/08 BPP 9123 9160 8894 8931 12-03 7/7/08 BPP 9180 9219 8951 8990 12-03 7/7/08 BPP 9229 9242 9000 9013 12-03 7/7/08 BPP 9296 9298 9067 9069 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028330 Well Facility Type MD Top I Description TVD Top 12-03 PACKER 8198 4-1/2" Baker S-3 Perm Packer 7972 12-03 PACKER 8278 5-1/2" Baker SAB Packer 8051 Well Name: API Number: Activity Description: Field/ Reservoir: Job Type: AWGRS Job Scope: Sundry Form 10-403 Required? Sundry Form 10404 Required? Engineer: Well Intervention Engineer: Lead Engineer: Date Created: Revisions (date, who, what changed): ALASKA WELL ACTIVITY STA TL:MENT OF REQUIREMENTS (VIS, DBR, LHO, EAZ 04/11/14) General Information 12-03 Well Type: Well Activity Classification: Cost Code/ AFE: 12 Month Avg IOR, bopd: Estimated Cost, $M: Other regulatory requirements? AC 50-029.20377-00 WeIlLock MicroOA Treatment PRUDHOE IVISHAK NOT OPERABLE NEW TECHNOLOGY PROJECT HIGINO DOS SANTOS (Contact numbers: JESSICA SAYERS Contact numbers: BERNHARD STECHAUNER Contact numbers: Conventional 4 Primary Secondary 907-56443421W) 713-269-3879(M) 907-5644281(W) 907-602-8715(M) 907-564-4594(W) 907-360-7485(M) in wellhead pressure 900 psi Known mechanical integrity problems (specifics) 10/31/09: MITOA Failed, —0.36 10/05/13: LLR OA — 0.5100 c Dom ®300000 m 0: Last downhole operation (date, operation) SL -06/08/10 Static Pressure Survey Most recent TD tag (date, depth, toolstring OD) SL - 06/08/10 Tagged Bottom 0 9,142' MO Comments, well history, 12-03 exhibits OA repressurization when on production and is not manageable by bleeds (Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all background information, etc: gas), highest observable pressure 2400 psi). The liquid leak rate has been established at 0.510 gallons per minute at 3000 psi This program is for treating the micro -annular leaking in the fully cemented OA. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro -annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A should be flushed across the OA valves to keep WeIlLock from setting up. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic -like material. The viscosity has been tested at 60 cP. Well Intervention Details Suspected Well Problem 10A breaks MOASP, unmanageable by bleeds when on-line (all gas) Specific Intervention or Well Objectives: 1 To treat the micro -annular leak in the fully cemented OA. Key risks, critical issues: Mitigation plan: 1 Inability to produce the well below MOASP for a minimum of 3 days before Increase IA pressure treatment --Summary St Jt Service Line Activity 1 V IService tree & annulus valves and install companion valve on OA 2 D lProduce well for a min of 3 days, and pump WeIlLock into void taking 2% KCI returns to open top tank Current Well Status Information 1 V Oil Rate Water Rate or Gas Rate or Gas GOR 2 D FTP or Injection Pressure Date (bopd) Injection Rate Injection Rate (scf/sthol Choke Setting Gas Lift Rate (Mscf/Day) (psi) Pump 1.6 gallons of WeIlLock into void taking 2% KCI returns to open top tank; once WeIlLock pill has been pumped, close companion valve 2 (bwpd) (Mscf/Day) Using diaphragm pump chase WeIlLock pill with 2% KCI to maintain pressure at 3000 psi, 2 1/6/2009 278 4,663 6,863 24,729 86 2,503 362 2 D Musol A that has been flushed through valves and purge lines to ensure returns are 1:1, it is critical to ensure Musol A is not contaminating WeIlLock and that valves are being OA re -pressurization coming from shallow external gas Current Status: Not Operable If not operable or under evaluation, why? source. Allow WeIlLock to develop 1500 psi of compressive strength, remove needle valve on return line 2 D Rapid BUR due to small void in the micro -annulus. Recent H2S (date, ppm) 7/15/2005 200 ppm Maximum Deviation (angle and depth) 23• 4,500' MD Datum depth, It TVDss 8,800' TVDssMinimum ID and Depth 3.725' 0 8,281' MD 4-1/2' XN Nipple Reservoir pressure (date, psig) 6/8/2010 1 3,436 psi Reservoir temperature, F 1 198• F in wellhead pressure 900 psi Known mechanical integrity problems (specifics) 10/31/09: MITOA Failed, —0.36 10/05/13: LLR OA — 0.5100 c Dom ®300000 m 0: Last downhole operation (date, operation) SL -06/08/10 Static Pressure Survey Most recent TD tag (date, depth, toolstring OD) SL - 06/08/10 Tagged Bottom 0 9,142' MO Comments, well history, 12-03 exhibits OA repressurization when on production and is not manageable by bleeds (Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all background information, etc: gas), highest observable pressure 2400 psi). The liquid leak rate has been established at 0.510 gallons per minute at 3000 psi This program is for treating the micro -annular leaking in the fully cemented OA. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro -annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A should be flushed across the OA valves to keep WeIlLock from setting up. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic -like material. The viscosity has been tested at 60 cP. Well Intervention Details Suspected Well Problem 10A breaks MOASP, unmanageable by bleeds when on-line (all gas) Specific Intervention or Well Objectives: 1 To treat the micro -annular leak in the fully cemented OA. Key risks, critical issues: Mitigation plan: 1 Inability to produce the well below MOASP for a minimum of 3 days before Increase IA pressure treatment --Summary St Jt Service Line Activity 1 V IService tree & annulus valves and install companion valve on OA 2 D lProduce well for a min of 3 days, and pump WeIlLock into void taking 2% KCI returns to open top tank Performance Expectations (may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD: 200 MMSCFD: 7 BWPD: 4600 FTP (psi(: 250 Choke setting: 87 Post job POP instructions: Notify engineer for plan forward Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form, well test chart, annotated mini log, annotated log section, tubing/casing tallies, Wellhead info, etc Approvals Management Approval: Date: Wells Approval: Date: Detailed work scope (H no RP/SOP exists for the intervention type, a well -specific procedure is required in addition to the SOR): 1 V Service tree & annulus valves and install companion valve on OA Produce well for a minimum of three days before treatment 2 D • Ensure OA pressure stays within MOASP limits; increase IA pressure to 1000 psi Flush OA void with 2% KCI 2 D • Measure the vol of diesel flushed out of void -notify engineer of vol of diesel flushed as this will be verification of the pill size of WeIlLock pumped Pump 1.6 gallons of WeIlLock into void taking 2% KCI returns to open top tank; once WeIlLock pill has been pumped, close companion valve 2 D • Bleed off IA pressure to 100 psi Using diaphragm pump chase WeIlLock pill with 2% KCI to maintain pressure at 3000 psi, 2 D • Pump until pressure falloff less than 0.005 gpm in observed 2 D Install needle valve on end of line to open top tank, switch T valve to triplex and maintain 3000 psi; rig down/clean up diaphragm pump & hose with Musol A Maintain 3000 psi with triplex and open needle valve to flush 1 bbl Musol A across OA valves; taking returns through the needle valve to the open top tank; verify volume of 2 D Musol A that has been flushed through valves and purge lines to ensure returns are 1:1, it is critical to ensure Musol A is not contaminating WeIlLock and that valves are being thoroughly flushed; 2 D Allow WeIlLock to develop 1500 psi of compressive strength, remove needle valve on return line 2 D Pump 2 bbls of Musol A through triplex maintaining high flow rate and 1000 psi; pump until diesel is noticed in return lines. 2 D Allow WeIlLock to set up to 3500 psi (approximately 8 hours) Rig up suitcase pump and pressure test to 3000 psi observing any minute pressure fall off; if pressure test passes -rig down triplex; if pressure test does not pass -notify 2 D engineer for plan forward, most likely involving pumping another pill of WeIlLock 2 D MIT -OA to 1000 psi Nitrogen Performance Expectations (may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD: 200 MMSCFD: 7 BWPD: 4600 FTP (psi(: 250 Choke setting: 87 Post job POP instructions: Notify engineer for plan forward Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form, well test chart, annotated mini log, annotated log section, tubing/casing tallies, Wellhead info, etc Approvals Management Approval: Date: Wells Approval: Date: UP 0 Minilog for Well Techl®g 12-03 Propel RBU_wR A,J o- LAURAJ.LARSAON E.Cale 1 860 o.:ne 21W2012 Pr*dumr Well: 12-03 Usv I. 500292037100 EMvahotr: 73 099694.07farat STUD Oab: 1979-061600100[00 - ant—USA :>n x,rt crams: -03ENvtra0 ALturvL' r. 5931075.13 %M C4NQM — ft.: 1579-0t 2100:00:00 irb. PFOMOE La.y na ms: OImlB[fE 12 IID 03 Total aP,n'. 9765 Lonla Ws. -119.106395 5[atus: State Abalu �oNneta : '�. HAD27 "T 0".—BMA C.—,SP" DI 2 SAL, TVD55 (*) 1:850 MD M 1:850 PE Info ' + C - O)N SW Ga 4 a'af.�aam. tVDf3 O O TfdL1 Yt++G a)f5 3100 p 9100 f0a aafl M a119 MSS uv a1S9 a00 9109 p f0r w Q56 Ia9 Il► 1116 9ppp /100 no 106E glpp 4aW as 9200 9f00 nn 1t+) 7n9 + ca90 701 Sapp 9700 O"D IPI 100 by 000, 0, To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 07-29-2013 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 12-03 WeIlLock MicroOA Treatment AFE: APBRISKMOT IOR: 130 Objective This program is for treating the micro -annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.510 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic -like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro -annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 07-01-08 MIT -IA (Rig) passed to 3500psi 10-05-13 OA Shell Test: 1.75 gal @ 3000 psi, LLR 0.05 gpm Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 2400 psi; Seal-tite repair for microannular treatment was no successful Last H2S Reading: 07-15-2005 200 ppm vveii operation uetau Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: OA Companion Valve DHD Diaphragm Pump Triplex T valve for pump lines Hard line/hose to open top tank Needle valve for hose/hard line to open top tank Volumetric containers to verify return volumes Relevant History: 07/01/08: Rig MITIA Passed to 3500 psi 07/08/08: Pulled TTP, set LGLV#3,4 08/05/08: DSO call in high OAP 08/10/08: Gas sampling indicates that IA and OA gas are not identical -methane or CO2 09/13/08: MITOA Failed, LLR —0.25 gpm 11/25/08: Seal-tite treatment for OA re -pressurization unsuccessful 06/29/13: LLR OA 0.005 gpm @ 2000 psi 10/05/13: LLR OA —0.510 gpm @ 3000 psi 1 V Service tree & annulus valves 2 V Install companion valve on OA 3 D Produce well for a minimum of three days before treatment, ensuring OA ressure stays within MOASP limits; increase IA pressure to 1000 psi 4 D Rig up hose and tee to diaphragm (suitcase) and triplex pumps to OA valves, taking returns on companion valve too en top tank 5 D Flush OA void with 2% KCI being sure to measure the volume of diesel flushed out of void -notify engineer of volume of diesel flushed as this will be verification of the pill size of WeIlLock pumped; pump 1.6 gallons of WeIlLock into void taking 2% KCI returns to open top tank; once WeIlLock ill has been pumped, close companion valve 6 D Bleed off IA pressure to 100 psi 7 D Using diaphragm pump chase WeIlLock pill with 2% KCI to maintain pressure at 3000 psi, pump until pressure falloff less than 0.005 gpm in observed 8 D Install needle valve on end of line to open top tank; switch T valve to triplex and maintain 3000 psi; rig down/clean up diaphragm pump and hose with Musol A 9 D Maintain 3000 psi with triplex and open needle valve to flush 1 bbl Musol A across OA valves; taking returns through the needle valve to the open top tank; verify volume of Musol A that has been flushed through valves and purge lines to ensure returns are 1:1, it is critical to ensure Musol A is not contaminating WeIlLock and that valves are being thoroughly flushed; 10 D Allow WeIlLock to develop 1500 psi of compressive strength; remove needle valve on return line 11 D Pump 2 bbls of Musol A through triplex maintaining high flow rate and 1000 psi-, pump until diesel is noticed in return lines. 12 D Allow WeIlLock to set up to 3500 psi (approximately 8 hours) 13 D Rig up suitcase pump and pressure test to 3000 psi observing any minute pressure fall off; if pressure test passes —rig down triplex; if pressure test does not pass -notify engineer for plan forward, most likely involving pumping another pill of WeIlLock 14 D MIT -OA to 1000 psi Nitrogen 2 of 6 TT{L 4-1!?5 SM WELLHLAD = CTPAY ACTUA tU R BAKH?:.: KB. ELEV 20M Hq-wHL-',LS:-UALNttR UK EiLV I KC)' 4'.... Mali A mg* .. 23. 445 UaWi MU - g- i Uabm f V U = 88047 S'. 4 r_ JD, 8.681- 13-36' CSW, M. L-80BTC, D= 12.34r 2729' Minimum ID = 3.725" @ 8281 4-1,2"XN NIPPLE 4-10 T80, 12b AWA48 VAM T'.,i' 8291' 0152 Oaf. D= 3969' 9 -SW CSG, 479, L-80. D = 8.681- H a869' TDN StM M%W la+ LOG Slim ON 09/09/79 A NLA.LAT TOP I-Ut 1' S, Tctiw�t Note. MEdee b Piadaelmrr. j:: ' , - SIL.t 51t fNTT3iW'AL '�«� UA' 20M Hq-wHL-',LS:-UALNttR I I I TM 3-368' 0.5 8992 - 900 O 1010421 33fir 4 9086 - 2106 O 1010691 3-3x8' 4 9106-9116 S 1010191 33'8" 4 9123-9160 S 03/11660 3-118" 4 9180-9219 S 03111420 3-tf8' 4 9229 -9242 S 0311190 DMY 0 92% 9298 S 4 WIW79 -'V , - = A3T1 apf, D = 6.' "A' 9765' 2148' H9-5.,Ir 3C 2442' H75orFW GAS LET MAMM:LS ST SAFETY NOTES WELL REQUIRES A SSS V. 12-03 4 1!2 CFf20METUBNG— NiES RWO VLY 20M Hq-wHL-',LS:-UALNttR I I I TM 2148' H9-5.,Ir 3C 2442' H75orFW GAS LET MAMM:LS ST MDlrMICV'-VlrYMI 09121!79 PW 176 ORIGINALCCU PLEIIOM 12/17/10 MT31.lMD ADOWSSSVSAfETYNOTE 0710395 NiES RWO VLY ILATCHIPORT1 0%1MA DA 4 3409 3408 0 L%G DOW RK 16 06r-VUB 3 5866 5140 22 MMD SO RK 22 OTir1W08 2 7145 6"4 18 MkG We RK 0 0629108 1 7957 x143 8 AMG DMY RK 0 06x19108 8179' H4- Vr HLS x NlV K) = 3.813- I 82D0' 9 -SV x4-1,7' GMS -3 PMD = 822,V [ j4-1xr HM x NlR D = 3.813" 8281' 4-1P2 mm xN NP, D = 3.125' 8291' I--{4-1,2 v&fG, D = 3.958•' file rr TOT L060® 8532' ;ZFX- r 71MACK D= 7 853a-5rXrLfseHWD=7 UATE HLV U' CCNVAE TS DATE HEV BY COMTA34TS 09121!79 PW 176 ORIGINALCCU PLEIIOM 12/17/10 MT31.lMD ADOWSSSVSAfETYNOTE 0710395 NiES RWO 07/0208 014 f vO 0%1MA HELUMD DMGDRARCCARECnCHS 10r10,O8 lx UHAWTYG CONVICTONS 11/1848 :UM) AVOW 2W CONDUCTCR 3 of 6 PRUDH E BAY WT YELL: 12-03 PHt6NT Na fI790410 API Nx 50-029.20317-00 SBC 18. T10N. R15E, 3984.28" Fa- d 4166.76' FP BP Exploration 4AlaskaE Table 1: B Annulus Components. SDL. Testina COMPONENT SDL(psi) TESTING(psi) Starting Head • Vetco Gray 20" SOW x 20 2,000 2,000 3/4n Part # 20274 Test pressure determined by the type of surface casing MIT -OA: Pass Pre-RWO hanger 06/14/08 Casing Spool • Gray "TSM -A" 20 3/4"' 2M 5,000 3,800 Studded Bottom x 13 5/8"5M Flanged Top w/ 3" LPO PPPOT-IC: Pass RWO 06/26/08 Production Casing Hanger 5,000 3,800 • Gray Gen II 13" x 9 5/8" emergency slips Test pressure determined by collapse psi of production PPPOT-IC: Pass casing RWO 06/26/08 Secondary Pack -Off • Gray 20" x 13 3/8" Type 5,000 3,800 CWC -P PN: 76576 Test pressure determined by API 5000 flange on bottom of PPPOT-IC: Pass tbg spool RWO 06/26/08 Surface Casing • 13 3/8" Burst: 5,380 2,000 • 72 ppf Pre-RWO:Pass • L-80 6/14/08 Production Casing • 9 5/8" Burst: 6,870 3,500 RWO - • 47 ppf Collapse: 4,760 Pass • L-80 06/21/08 4 of 6 Oak ,NOW 0 07/14/09 ~'9~~I~~~~~~e~ NO. 5310 ~laska Data &~onsuiting Services ;,, . Company: State of Alaska 2525 Gambell Street, Suite 400 ,,:~ iA`~, ~»' a•~ ~~~w~„~ a~ F~ ~r~~, Alaska Oil & Gas Cons Comm Anchorage, ,4PL 99503-2838 '` 4 -~~~ ~~ t Attn: Christine Mahnk~an n~'YN: Beth 333 West 7th Ave, Suite~ 100 Anchorage, AK 99501 Ull~91 Job # Log Description Date BL Color CD Z-20 AP3Q-00043 SBHP SURVEY 06/17/09 1 1 P2-31 AZCM-00029 LDL L/ > 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 0 06/15/09 1 1 Z-14~ AYQQ-00036 TEMP SURVEY & BHP . O6/23/09 1 1 B~I-96 AP3Q-00042 SBHP SURVEY ` °~ ~ O6/16/09 1 1 V~Q6_.,: 11999053 USIT - 10/12/08 1 1 ;' N-11G AP3Q-00042 SBHP SURVEY O6/16/09 1 1 `"'-~3-92 AY3J-00030 LDL ._ 06/12/09 1 1 !_1-30 AVYS-00049 PRODUCTION PROFILE -~j (jd ~ 06/22/09 1 1 17-076 AYQQ-00031 SBHP SURVEY "~ / t5 06/11/09 1 1 OS-256 AP3Q-00040 SBHP SURVEY 06/11/09 1 1 ~-27A AXBD-00028 MEM INJ PROFILE 06/12/09 1 1 11-36 6146-00066 CROSSFLOW & IBP ~ 06/23/09 1 1 _ ~-2i~4 B14B-00065 SBHP SURVEY 06/21/09 1 1 X-17 AYTU-00043 PROD PROFILE -/ 06/08/09 1 1 _ ~-25 AWLB-00018 LDL 1~~~ (j'~ - 05/28/09 1 1 02-338 AYTU-00033 USIT ''~ ~ 05/19/09 1 1 P2-07 AVY5-00051 PRODUCTION PROFILE ~ t 06/25l09 1 1 13-03 AWL8-00020 LDL 06/01/09 1 1 3-17F/K-30 62NJ-00008 MEM INJ PROFILE (J 06/15/09 1 1 MPS-08 AYS4-00080 LDL 06/15/09 1 1 13-1~ AV1H-00019 LDL 07/05/09 1 1 01-25 AYTU-00046 USIT ~ ~fp 06/28/09 1 1 W-39A AWLS-00023 STATIC TEMP SURVEY ~~ , O6/26/09 1 1 ~-35 AYTO-00022 SBHP SURVEY ~ '~'j' 06/29/09 1 1 Z-16 AV1H-00017 SBHPSURVEY t (~~j O6/29l09 1 1 18-20 B581-00004 LDL ~ , ~ 06/27l09 1 1 Z-29 AVYS-00053 SBHP SURVEY "' ~``a ° ()k~,) v (~ _ ~ 07/03/09 1 1 L5-09 AY~Q-00032 , , RST °- ~ C- ~ 06/13/09 1 1 07-70A f]I CI~L+~ anV~lAl~i~ rr~~~ e~e- B1JJ-00022 w~~r~t ~~i w.w... MCNL -- Q( .... ...~ ~~~..~.....~ ~_._ 05/26/09 1 .--°,-•^••~^•-^-_+~~..~~+r.. .... v~v~~~~e~a~~~vn~~vn~a~~aVVItlGVVrI CNlifl IV: BP Expioration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. i ~ S1 i 1 ~,~ , _. - .. \,', Alaska Data & Consuiting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ \J • • ~ ~ ~' SARAH PAL/N GOVERN OR CO1tTL+Ltri~O n ~~+~-~ 333 W 7th AVENUE, SUITE 100 •~-7i1i1 1.~~~`~~•~~~111~~'iii ----777 Qjt ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Chivvis Production Engineer BP Exploration Alaska Inc. PO Box 196612 ~~~; ~ ~ ~ ~~ `~ ZQ~~ h t Anchorage, AK 99519-6612 ~ ~ ` V 1 Re: Prudhoe Bay FYeld, Prudhoe Bay Oil Pool, PBU 12-03 Sundry Number; 308-345 Dear Mr. Chivvis: 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 thisZ~ day of September, 2008 Encl. r • • 8 n .^. n STATE OF ALASKA ~ `~ ~ ~ `"" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROtVAL ~n AAC ~~ ~Rn 9~~ 0 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe ~ Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ SEALTITE Change approved program^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmeni0 - Exploratory ^ 179-0410 , 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612. 50-029-20377-00-00- 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 12-03 _ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): , ADLO-028330' 73 KB - PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9765 - 9535.85 - 9286 9057.22 NONE NONE Casing Length Size MD TVD Burst Collapse Gonductor 80' 20" Surface 80' Surface 80' 1530 520 Surface 2729' 13-3/8" 72# L-80 Surface 2729' Surface 2729' 4930 2670 Intermediate 8869' 9-5/8" 47# L-80 Surface 8869' Surface 8640' 6870 4760 Liner 1228' 7" 29# N-80 8532' 9760' 8304' 9531' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 26 - 8290 - - 4-1/2" 12.6# N-80 8290 - 8413 Packers and SSSV Type: 4-1/2" BKR S-3 PKR Packers and SSSV MD (ft): 8200 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development 0 - Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/7/2008 OIL Q _ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Katrina Cooper Printed Name Robert Chivvis Title Production Engineer Signature Phone 564-5412 Date 9/23/2008 COMMISSION USE ONLY y,~j ~~~ J ~`-~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~"~' ~~~~,~~~'~ Pluglntegrity ^ BOP Test ^ MechanicallntegrityTest ^ Location Clearance ^ Other: ~~~~ Subsequent Form Required: " ~' ~~e~~,.,/+/ APPROVED BY ~ ~ ~ ~ COMMISSIONER THE COMMISSION Date: Approved b I " I~ Form 10-403 Revised 06/2006 ~~. ~~r~ ~ 2008 Submit in Duplicate 12-03 179-041 PFRF ~TT~C:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-03 9/16/79 PER 9,296. 9,298. 9,067.21 - - - 9,069.21 12-03 3/11/80 APF 9,123. 9,160. 8,894.3 3 8,931.3 12-03 3/11/80 APF - ----- - 9,180. 9,219. _ 8,951.29 --- 8,990.27 12-03 3/11/80 APF 9,229. _ _ 9,242. 9,000.26 9,013.25 12-03 12/12/85 APF 9,085. __ 9,106. 8,857.35 8,877.34 12-03 8/4/89 APF 8,984. 9,009. 8,755.4 8,780.39 12-03 6/20/91 SQZ 8,984. 9,298. 8,755.4 9,069.21 12-03 10/4/91 APF _ 9,106. 9,116. 8,877.34 8,887.33 12-03 10/4/91 RPF 8,992. 9,004. 8,763.4 8,775.4 12-03 ___ 10/4/91 RPF _ 9,086. _ 9,106. 8,857.35, __ 8,877.34 12-03 8/22/94 RPF 8,984. 9,009. 8,755.4 8,780.39 12-03 10/21/05 BPS 9,286. 9,298. 9,057.22 9,069.21 12-03 6/10/08 BPS 8,254. 9,298. 8,027.3 9,069.21 12-03 6/12/08 SPS 8,254. 8,984. 8,027.3 8,755.4 12-03 7/7/08 BPP 8,254. 8,984. 8,027.3 8,755.4 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP _ BRIDGE PLUG P ULLED SL SLOTTED LINER _ _B_PS 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 P ACK, OPEN OH OPEN HOLE _ _ _ _ ~ • by To: C. Olsen/J. Bixby, GPB Well Ops TL Date: Sept 19, 2008 From: Trina Cooper, DS 12 PE Subject: 12-03 Seal-Tite Cost Code: PBD12WL03-N Est. Cost: $100 M IOR: 140 Please perform the attached Seal-Tite procedure to repair the cemented OA on 12-03. Step Type Procedure 1 O Pump Seal-Tite into OA per attached procedure Current Status: Shut-In Producer, Not Operable Last well test: 203 bopd, 96% WC, 16,288 GOR on 7/23/08 Max Deviation: 23° @ 4500' MD. Min. ID: 3.725" through 4-1/2" XN nipple @ 8281' MD. Last TD tag: 07/07/08 Tag TD at 9100' SLM Last Downhole Ops: 07/07/08 Set gas lift valves and tag TD post RWO Latest H2S Level: 200 ppm on 7/15/2005 12-03 is a gas lifted producer with a history of TxIAxOA communication. A RWO was done in July 2008 to repair the TxIAxOA communication. This RWO cut, pulled, and replaced the top 2033' of the 9-5/8" production casing and then cemented it to surface. An old packer was milled and new chrome tubing was installed. When the well was POP'd after the RWO the cemented OA was pressuring up. The OA would bleed rapidly then build up to as high as 1510 psi. Wellhead gas samples concluded that the OA gas was not IA gas lift gas but was instead coming from a different, perhaps external, source. This could be hydrate or biogenic gas from the surface casing shoe traveling up through small cracks or amicro-annulus in the new cement. This Seal-Tite procedure is recommended to repair the cracks and micro-annulus in the OA cement, so the well can be returned to an operable status. If you have any questions or comments regarding this procedure, please call Trina Cooper at (Work) 564-4212 or (Cell) 230-4212 or (Home) 279-2667. cc: w/a: Well File Seal-Tite International Advanced Sealant Technology Proposed Procedure BP Alaska, 12-03 Microannulus Leak Repair September 19, 2008 Seal-Tite International 500 Deer Cross Drive Madisonville, LA 70447 Telephone: 985-875- 1292 Facsimile: 985-875-0687 http://www. seal-cite. net Objectives Repair a microannulus cement leak in the OA in order to restore OA integrity Mechanical Considerations The 12-03 well has a history of IA/OA communication. To attempt a repair the 9 5/8" casing was cut at +- 2033' and pulled, then replaced and cemented to surface. However the OA pressure continues to build due to a suspected microannulus channel in the OA cement. Casing pressure diagnostics have shown a characteristic rapid bleed off of pressure (440 psi bled to 0 psi in 15 seconds, all gas) followed by a buildup to 170 psi in 30 minutes. At times the well would even build up 560 psi over 30 minutes and would build up as high as 1510 psi over 24 hours. After the well was shut in, the OA was able to be bleed off and has stayed below 1000 psi. Current OA pressure is 120 psi. Additional diagnostics recently performed verified the ability to inject fluids into the annulus. Diesel was injected into the OA and filled with 10 gallons, indicating a probable cement top of 3-4'. Continued injection resulted in a sustained diesel injection rate of 0.25 gal/min at 2000 psi for 30 minutes. This is considered sufficient to allow sealant injection. Intended Repair Procedure This procedure employs the following major steps: - Displacing and activating the sealant - Allowing the sealant to cure under pressure for a period of several days - Cycling the pressure at the surface to finalize the seal The sealant volume design will be based on filling a microannulus with diameter of 0.0075 inches, from the wellhead to at least 500 feet below the wellhead (estimated 3.5 liters per 100').. This will provide sufficient sealant to ensure isolation of the pressure source from the surface once the casing has been cut below the mud line and the well abandoned. The outer casing is 13 3/8" 72 Ib/ft L-80 with a burst of 5380 psi. The inner casing is 9 5/8" 7 Ib/ft L-80 with a collapse of 4750 psi. Page 2 Using 80% of the lower pressure provides a maximum injection pressure of 3800 psi; however, the well has only had previous MIT-OA pressure tests up to 2400 psi. For the purposes of this procedure we will use a maximum pressure of 2400 psi. 1. Perform Job Safety Analysis with all concerned personnel. 2. Take pressure readings as follows: - Tubing Pressure - 9 5/8" casing (IA) - 13 3/8" casing (OA) 3. R/U Seal-rite injection equipment to OA casing valve. Test all equipment to 200 psi low and 3500 psi high. 4. Install a chart recorder on the OA casing with a 2400 psi spring and 24 hour clock. Calibrate chart recorder against test gauge. (Or substitute with similar pressure measurement /recording device) 5. Bleed the OA to zero, record effluent and time to bleed. 6. Fill OA with diesel. Record volume required to fill up. 7. Increase OA pressure with diesel to establish stable injection rates for 5 minutes at 1000 psi, 1500 psi, 2000 psi, and 2200 psi. 8. Begin brine injection into annulus at 2000 - 2200 psi. Continue injection until a total of 100 liters has been injected. 9. Begin injection of water-based sealant (Gly-Flo 1 M) into OA at 1400 psi. Continue injection until a total of 10 liters has been injected. 10. Begin injection of Gly-Flo 3M into OA at 1400 psi. Continue injection until a total of 10 liters has been injected. 11. Begin injection of Gly-Flo 5M into OA at 1400 psi. Continue injection until a total of 10 liters has been injected. 12. Begin injection of Gly-Flo 7M into OA at 1400 psi. Continue injection until a total of 10 liters has been injected. 13. Begin injection of Gly-Flo 9M into OA at 1400 psi. Continue injection until a total of 10 liters has been injected. 14. Begin injection of Gly-Flo 9MV into OA at 1400 psi. Continue injection until a total of 5 liters has been injected. a Page 3 l~ 15. Increase injection pressure to 2000 psi. Continue with Gly-Flo 9MV until an additional 3 liters has been injected. 16. Increase injection pressure to 2200 psi. Continue with Gly-Flo 9MV until an additional 3 liters has been injected. 17. Increase injection pressure to 2400 psi (maximum allowable pressure). Continue with Gly-Flo 9MV until an additional 3 liters has been injected. 18. Bleed pressure to zero -measure returns. Allow to bleed for 3 minutes, then increase injection pressure to 2400 psi. 19. Repeat the above pressure cycling sequence an additional 10 times - monitoring returns each time. Once flowback begins to reduce, increase flowback times but do not allow more than 3 liters of returns. 20. Allow sealant to cure overnight. 21. Repeat the above pressure cycling sequence an additional 10 times - monitoring returns each time. Continue to increase flowback times as flowrate reduces until flow is reduced to zero. 22. Shut OA in and monitor for buildup overnight to ensure buildup is within allowable limits. 23. Rig down all equipment. Secure well and clean work location. Turn well over to operator. 24. End of procedure. DNC 9/18/08 STATE OF ALASKA 9-~Od~ ` ~ f~^~,°°,~ ~--» AL~ OIL AND GAS CONSERVATION COM~ION k "~"" ~ ` '~ REPORT OF SUNDRY WELL OPERATIONS ~~1,~~~ ~ 2~~~~ 1. Operations Performed: ' ^ Abandon ®Repair WeN ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~ 179-041 3. Address: ^ Service ^ Stratigraphic '~ 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20377-00-00 7. KB Elevation (ft): ~ 73, 9. Well Name and Number: - ~ PBU 12-03 8. Property Designation: ~ 10. Field /Pool(s): ` ADL 028330 Prudhoe Bay Field !Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9765' feet true vertical 9536' feet Plugs (measured) None Effective depth: measured 9286' feet Junk (measured) None true vertical 9057' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2729' 13-3/8" 2729' 2729' 4930 2670 Intermediate 8869' 9-5/8" 8869' 8640' 6870 4760 Production Liner 1228' 7" 8532' - 9760' 8304' - 9531' 8160 7020 Perforation Depth MD (ft): 8984' - 9106' Perforation Depth TVD (ft): 8755' - 8877' 4-1/2", 12.6# 13Cr80 8291' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-518" x 4-1/2" Baker'S-3' packer 8200' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pulled Tubing. Cut and pull 9-5/8" casing from 2030'. Run 9-5/8" (47#, L-80) tieback to surface. Cement w/ 135 bbls Class 'G' w/ Gas-Blok 758 cu ft / 648 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 300 188 Subsequent to operation: 470 11042 5182 1550 320 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 308-206 Printed Name Sondra Stewman Title Drilling Technologist / Prepared By Name/Number: ~` ~ Sig ture - Phone 564-4750 Date~ z5 ~ ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ ~ ~ ~ /{ ~ Vii`/ 1.9~," ~~~ ~~ y ~(~ Submit Origi al Only [f-,1 1 1 ~~~i~Ca TREE _ WELLHEAD = ACTUATOR = KB. ELEV = 73 BF. ELEV KOP = _ ........4000' .. Max Angle = ......... 23 @ 4500' Datum MD = 9102' Datum TVD = 8800' SS 2L 034' ~~ 9 5f8" casing Patch 13-3/8" CSG, 72#, N-80, ID = 12.347" 2729' 1 ~ -O ~ SA OTES: *"`4-1/2" CHROMETBG*** Surface Top of Cement I ^~2~ ')~ 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3409 3408 0 MMG DCR RKP 0 06/29/08 3 5866 5740 22 MMG DMY RK 0 06/29/08 2 7145 6944 18 MMG DMY RK 0 06/29/08 1 7967 7743 8 MMG DMY RK 0 06/29/08 ~ 4-1/2" TBG, 12.6#, 13CR-8Q .0152 bpf, ID = 3.958" GRAY GEN 2 GRAY AXELSON TOP OF4-1/2"TBG-PC (-) 8290' TOP OF 7" LNR ( 8532' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8869' PERFORATION SUMMARY REF LOG: BRCS ON 09/09/79 ANGLE AT TOP PERF: 2 @ 8984' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 8984 - 9009 O 08/22/94 3-3/8" 0.5 8992 - 9004 O 10/04/91 3-3/8" 4 9086 - 9106 O 10/04/91 3-3/8" 4 9106 - 9116 S 10/04/91 3-3/8" 4 9123 - 9160 S 03/11/80 3-1/8" 4 9180 - 9219 S 03/11/80 3-1/8" 4 9229 - 9242 S 03/11/80 3-1/8" 0 9296 - 9298 S 09/16/79 PBTD 9286' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 9760' 9765' 817_-14-1/2" HES X NIP, ID = 3.813" $200' -{9 5/8" X 4-112" BKR S-3 PKR 824' 1 4-1/2" HES X NIP, ID = 3.813" ,?0%~~ 3 1,'$„ set ot~ ti-1f~-{O8 $28'1' 4 1/2" "XN" wr RHC-M $2g0' 4-112" 9cr TCII WLEG ELMD TT NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 09/21/79 ORIGINAL COMPLETION 02/14/06 RRD/PAG BKR IBP DEPTH CORRECTION 07/03/85 LAST WORKOV ER 07/02108 D14 RWO 10/08/05 KDC/PAG GLV C/O 07/06/08 /TLH CORRECTIONS 10!13/05 RPH/TLH WANERSFTY NOTE DELETED 10/21/05 RWL/PJC SET IBP@ 8752' 02/06/06 JYJ/PJC SAFETY NOTE (PATCH) PRUDHOE BAY UNIT WELL: 12-03 PERMff No: 1790410 API No: 50-029-20377-00 SEC 18, T10N, R15E, 3984.28' FEL & 4166.76' FNL BP Exploration (Alaska) • • Well History Well Date Summary 12-03 6/4/2008 T/IA/OA= SSV/280/240 Terre=cold PPPOT-T (PASS) FFFnT-iC (PASS) (R-e fZWO) PPR7T-T RU high pressure bleed tool onto THA test void 0 pressure on void. Cycle and torque LD6 2 row's "Standard" all moved free w ith no bent pins. Pressure void to 5000 psi for 30 rrinute test, 4950/ 15 rrinutes, 4950/ 30 rrinutes. Bleed THA void to 0 psi. RD test equipment re-installed Alerrite cap. Alerrite R&R PPPOT-IC RU 2 high pressure bleed tool onto IC test void 0 psi, flushed void until clean returns achieved. Cycle and torque LDS "Standard" all moved free w ith no bent pins. Pressure void to 3500 psi for 30 rrinute test, 3500/ 15 rrinutes, 3500/ 30 rrinutes. Bleed IC void to 0 psi. RD test equipment re- installed Alerrite caps. 2 Alerrite fittings R&R 12-03 &/9/2008 `**V1/B_L SHUT IN ON ARRIVAL*** DRIFT W/ 4.50" GAUGE RING TO M3~LA TBG PATCH AT 2,99T ND DRIFT W/ 3.70" GAUGE RING,3.50"LIB TO IBP AT 9,128'SLM ( IBP SlJPPOS® TO BEAT 8752'NDl RAN 10'x3" RBAILER TO IBP (a? 9,128'SLM(RECOVER 2 CUPS OF PARAFFIN) PULL 3-3/8" IBP FROM 9128'SLM(MSSING ONE RUBBER ~BV1BVTl_ RAN 4-1/2"BLB,3.70" 3-PRONG WIRE GRAB TO M3~LA PATCH AT 2997'ND. (RECOV E}2® MISSING Rl A3BER ELEM3~1T1 ***CONT WSR ON 6/10/08'""` 12-03 6/10/2008 *****1NELL SHUT IN ON ARRNAL INITIAL T/VO = 250/370/240 PSI ***"" SEf BAKff2 IBP, PT PLUG, JET CUT TUBING. SET BAK~2 3.38" IBP CBVTff2 ELEM3VT AT 8268'. PLUG DATA: 1.75" IXT~L FISHING NECK, 1840# DOWN TO EQUALIZE, 5500# TO PULL RELEASE TWO 6" SEALNVG ELBVBYfS, ONE 1" STIFFHV9~ RING, 11.6' TOTAL PLUG LENGTH FINAL T/VO = 300/350/250PSI LEFT W~L SHUT IN ALL VALVES IN SAME (EDITION AS PER ARRNAL, DSO NO11FI® THAT LRS IS PRESSURE TESTING PLUG. WILL CONE BACK TO JET CUT TUBING AFT~2 PRESSURE TEST OF PLUG. ****JOB NOT OONPLETE"**" IBP PULL® 6/20/08 DURING DOYON 14 PoG RWO 12-03 6/10/2008 ***CONT WSR FROM 6/9/08*** PULL® RK DGLV FROM STA# 10 AT 8182'ND ***NOTE STA. 10, OPHV POCKEf*** ***RDMD,L~T W~L SHUT IN AND TURN® OVER TO OPffiATOF2'*" 12-03 6/10/2008 Stby for E-Line to set IBP 12-03 6/11/2008 T/V0=110/410/250. Terre=Sl. T & IA FL's (pre-RWO). T FL NS (<5 bbls). A/LP=Open to wellhead. IA FL @ 130' (<10 bbls). **Note: IA has a 1502 installed w/a threaded sw edge. Wellhouse floor is separating. Flagged & tagged @ door for tripping hazard. 12-03 6/11/2008 T/VO = 400/680/240 Terre = S/I -Assist Slickline w/CMT TxIA PASSED to 3000 psi (PI•e RWO) - PI•essured up TxIA to 2660/3000 psi w/3 bbls neat meth followed by 16.6 bbls 90* crude. (2nd test) TxIA lost 20/20 psi in 1st 15 min and 10/20 psi in 2nd 15 rrin for a total loss of 30/40 psi in 30 rrin test. Bled WHPs. *** Job continued on 06/12/08 WSR **" 12-03 6/11/2008 ***VV~LS/IONARRNAL*** TAGG® IBP Cad 8254' SLM W/ 3.50" CENT & 3.25" LIB ( IMPRESSION OF F-NECK) LRS CMT TO 3000# (PASS) CONFORMATION CMT TO 3000# (PASS) ""*CONIINU® ON WSR 06/12/08**" 12-03 6/11/2008 T/V~ 200/360/240 Assist RLine CMT TxVa FAIL® to 3500 (RWO Prep) ELine set IBP. PUnped 43 bbls crude down tbg to reach test 3000 psi Established LLRof 3.5 BPMfor 5 bbls before running out of fluid. Ressures fell rapidly after shutting dow n. Tags hung, Casing valves open to gauges 12-03 6/12/2008 *** Job continued from06/11/08 WSR*** Fbst CMT TxIA bleed and rig down. FWPs =400/660/250 *** Casing valves open to guages, tags hung, DSO notrfied of w ell status '"'* 12-03 6/12/2008 ***CONIINUED FROM WSR 06/11/08*** DUMP BAIL® 10' OF SLUGGfTS ON TOP OF IBP ~ 8254' SLM (TOTAL OF 4 - 50# BAGS) ***LEFT W~L S/I, NOl1FY DSO*** Print Date: 7/242008 Page 1 oft • Well Date Summary 12-03 6/13/2008 Load and transport diesel 12-03 6/13/2008 T/VO = 550/880/240 Temp = S/I - CNTf TxIA 3500 psi (RWO ore~l Rmped 12.3 bbls of 90* crude dow n IA to reach 3280 psi TBG 3500 psi on IA Job canceled bleed TxIA psi dow n bleed back aprox. 12 bbls Fnal Whp's~40/860/240 12-03 6/14/2008 T/V0= 650/S40/240 Glrc Out Well (RWO Prep) H.imped 3bbls meth, 870bb1s 1%Kq, 150bb1s diesel dow n tubing, through STA#10, up IA, dow n to 12-05's flow line. U-tube freeze protect. Bleed IA and T to zero. ***MffOA PASSED to 2000psi*** Ramped 9.9bbls diesel to pressure up. OA bst 100psi 1st 15min, 30psi 2nd 15min, for a total of 130psi in 30rrin. Bled OA to 0+. FWHPs = 0/0/0+ Annulus valves tagged and open to gauges. 12-03 6/14/2008 ***VV~L SHUT IN ON ARRIVAL 1NfIlAL T/VO = 0/0/OPSI *'"' CUT 5.5" TUBING WffFi 4.15" POWl3~ CUTT~2 AT 2980'. ***JOB IN RESS AND CON1lNU® ON 15-JUN-2008 WSR*** 12-03 6/14/2008 T/V0=1000/980/240 Terry= SI Circ-Out TxIA (pre RWO). Called to another location. Fnal WI-P5 1000/980/240 (IA/OA casing valves open to gauges at tirre of departure) 12-03 6/15/2008 T/V0= 0/0/0; Set 5-1/8 Grav "K" BP/ #&01 thru tree ore-ria: 1-2' ext. used, tagged @ 108"; *"*Corrplete*** (BestNVortham) 12-03 6/15/2008 ***CONTINU® FROM 14-JUN-2008 *** RIG DOWN E~LINE FINAL T/VO = 0/0/0 WELL LET SHUT-IN, ALL VALVES LET AS FOUI~ID. DSO NOl1Fl® '"'*JOB COMPLEf~`*' 12-03 6/18/2008 T/VO=Vac/0/0. PUII 5-1/8" Grav "K" BPS/ thru tree. for rip to Trove on, 1-2' ext used, tagged @ 108". No problems. Set 5-1/8" Grav "tC' BFV #601 trhi~ trey to nnnn 11-2' ext used, tagged @ 108". No problerrs. 12-03 6/19/2008 T/VOA/0/0; FLlled 5-1/8" Grav "K" BPV #601 thru tree for Duyon 14 De-corroletion: RKB=27.50, 4-5' ext. & Centralizer used, tagged @ 78"; ***Complete*** (Best/Wortham) 12-03 7/1/2008 T/V0.~cx/xx/xx 12-03 7/2/2008 T/VO ~/0/0 Balled 4-1/16" CNV"H" TWC #276 ~ 108".1-2 ext..... Seto-1/16" CNV"H' BPS/ #105 @ 108" 1-2" ext..... for Doyon 14 to complete. 12-03 7/5/2008 T/V0=175/175/0 pull 4" ciw bpv thru tree post rig work 12-03 7/7/2008 '"'1NELL S/I ON ARRNAL***(post rig) PULL B&R IN XN NIP lad 8281' MD PULL®DGLV'S FROM ST. 3 & 4 SET LGLV (16/64" PORTS, 1500 TRO) ~ STA #4 @3409' MD SET S/O (22/64" PORTS) IN STA #3 @ 5866' MD Pll L® RHC PLUG BODY IN XN NIP (a) 8281' MD RAN DRIFT W/ 3.25" CHVT, S. BAIL~2 (NO SAMPLE), S/D @ 9100' SLM ***VV9_L LET S/I ON D~ARTURE, DSO NOTIFI~'** 12-03 7/11/2008 T/V0= 400/1500/0. Terry= Hot. IA FL (GLE). A/L online @ 1500 psi. IA FL @ 5769' (above sta # 3). GLR= 2.5 12-03 7/12/2008 T/V0= 400/1560/0. Terry= Hot. IA FL (for GLE). IA FL @ 5866' STA # 3 SO. GLR= 5.4M Print Date: 7/24/2008 Page 2 of 2 • BP EXPLORATION Operations Summary Report Page 1 of 14 ~ Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours .Task Code NPT Phase Description of Operations 6/15/2008 03:00 - 12:00 9.00 RIGD P PRE -Hang blocks. Slip drilling line to LD derrick -Break off IBOP. -RD stand pipe, cement line and mud manifold. -Install front boosters. -LO tongs, mud bucket and short mouse hole. ', -Remove yoke and torque tube. -Remove kelly hose. Remove electrical service lines. -Remove stand jump rams. Install bale lock. Remove top ODS roller assy. -LD top drive NOTE: move camp f/ Price Pad to Mukluk Yard in Deadhorse 12:00 - 15:00 3.00 RIGD P PRE -Hang bridle line -Skid rig floor to moving position -Pull rig off well C-196 and position on pad. Skid rig floor to LD derrick position. 15:00 - 21:00 6.00 RIGD P PRE -LD wind walls -LD derrick and A legs -Remove BOP stack from cellar and install rear boosters 21:00 - 00:00 3.00 MOB P PRE -Move rig f/ C pad down access road -Move rig down K pad road. Rig between E pad and K pad at report closing time 6/16/2008 00:00 - 07:30 7.50 MOB P PRE Cont. moving rig f/ E pad to West Dock Rd. and down to CCP 07:30 - 08:30 1.00 MOB P PRE Wait on Security 08:30 - 14:00 5.50 MOB P PRE Cont. moving rig f/ CCP to East Check Point 14:00 - 15:30 1.50 MOB P PRE Mobilize rig mats around check point and to Peak Yard 15:30 - 16:30 1.00 MOB P PRE Move rig f/ East Check Point to Schlumberger Yard 16:30 - 18:00 1.50 MOB P PRE Re-mobilize rig mats down Borough Road. 18:00 - 20:30 2.50 MOB P PRE Move rig f/ Schlumberger Yard to DS 12. Position rig on pad. 20:30 - 00:00 3.50 RIGU P PRE -Raise derrick -Raise windwalls -Remove rear boosters 6/17/2008 00:00 - 04:00 4.00 RIGU P PRE -LD mats on location. -Remove front boosters and frames. -Cont. RU rig on DS 12. -Skid rig floor forward. 04:00 - 09:30 5.50 RIGU P PRE Position rig over well 12-03. Remove Swab valve from tree. -Lower "C" section. Shim Rig in place. 09:30 - 10:30 1.00 RIGU P PRE Skid Rig floor into position. -Spot & berm rockwasher. 10:30 - 12:00 1.50 RIGU P PRE Extend & bolt up conveyor. Hang bridle lines & Tie back. -LD Carriage. -Test Gas alarms. 12:00 - 15:00 3.00 RIGU P PRE PU Top drive & install rollers. -Mobilize Rig floor equipment. 15:00 - 16:00 1.00 RIGU P PRE Connect electric service loop. 16:00 - 20:00 4.00 P DECOMP RU Mud manifold, Kelly hose, hang Tongs & Mud bucket. -RU Rail stabilizer. -Acce t Ri ~ 17:00 hrs. 20:00 - 23:00 3.00 RIGU P DECOMP Nipple up Swab valve. RU circulating lines. -C/O Saver sub to 4 1/2" IF. 23:00 - 00:00 1.00 RIGU P DECOMP RU Lubricator. _Tast R rhart hihriratnr Tn 5M nsi f/ r, minutac - Pacc Printed: 7/23/2008 2:25:41 PM • BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ----- -- _1-- 6/18/2008 00:00 - 00:30 0.50 PULL P DECOMP DSM continue to pull BPV. -LD lubricator. 00:30 - 01:00 0.50 RIGU P DECOMP Test lines to Circ-out tank to 3500 psi / 5 minutes -Pass 01:00 - 04:30 3.50 RIGU P DECOMP Circulate out diesel freeze protection: -Pump 60 bbls of Seawater down annulus up Tbg. -Take returns to Tiger tank. -Pump rate 126 gpm / 280 psi. Blow down, swap hoses. -Pump 190 bbls of Seawater down Tbg up annulus. -Take returns to Tiger tank. -Pump rate 126 gpm / 200 psi. Blow down lines. -Wait 30 minutes for diesel to migrate. -Pump an additional 30 bbls down Tbg. -Take returns to Tiger tank. -Pump rate 126 gpm / 200 psi. -Take returns to pits 04:30 - 06:30 2.00 RIGU P DECOMP RU Lubricator and test to 500 psi / 5 minutes -Pass. Set "K" lu and test from below to 1000 si / 10 minutes - Pass. -LD DSM Lubricator. 06:30 - 09:30 3.00 PULL P DECOMP ND Tree & Adaptor flange. Remove same from cellar. 09:30 - 10:00 0.50 PULL P DECOMP Cameron install Dart in "K" plug. -Attempt to start ACME XO to count turns for make up. -No-Go, threads damaged. 10:00 - 12:00 2.00 PULL P DECOMP Remove Spacer spool from Choke hose. -Install double valve on IA. -Hang Stack 18" over Hanger spool. -Check Choke hose alignment. 12:00 - 17:30 5.50 PULL P DECOMP NU Spacer spool & BOP stack. -Install Flowline, Pitcher nipple and hoses. 17:30 - 20:00 2.50 PULL P DECOMP C/O lower VBR Rams from 2 7/8" X 5" to 4 1/2" X 7". 20:00 - 21:30 1.50 PULL P DECOMP RU BOP test equipment. 21:30 - 00:00 2.50 PULL P DECOMP ---BOP Configuration. -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -4 1/2" X 7" Variables. Test BOP and related a ui m nt. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3500 psi high x 5 min each on chart. -Test w/ 5" test jt. Test bottom Rams. -Test Hydril, valves 12, 13, 14 & HCR Kill, w/ Mud pump. -Tests witnessed by T.P & W.S.L. -John Crisp of AOGCC waived witness of testing. 6/19/2008 00:00 - 04:30 4.50 PULL P DECOMP ---BOP Configuration. -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -4 1/2" X 7" Variables. Continue to Test BOP and related equipment. Printed: 7/23/2008 2:25:41 PM • • BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: ~~ ' Date '. From - To Hours Task ~ Code i NPT , Phase Description of Operations 6/19/2008 00:00 - 04:30 4.50 PULL P DECOMP -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3500 psi high x 5 min each on chart. -Test Top Rams, valves 9,11 & TIW Floor valve. -Test valves 5, 8, 10 & Dart valve. -Test valves 4, 6, 7 & Hydraulic IBOP. -Test valve 2 & manual IBOP. -Test HCR Choke valve. -Test manual Choke & Kill valve. -Perform Accumulator test: 32 secs for 200 psi increase. -2 minutes 25 secs for final total system pressure. -Test Blind Rams & valve 3. -Test with 5 1/2" test joint. -Test Top Rams & Hydraulic IBOP. -Test manual IBOP. All tests are a PASS. -Tests witnessed by T.P & W.S.L. -John Crisp of AOGCC waived witness of testing. 04:30 - 05:00 0.50 PULL P DECOMP RD test equipment. 05:00 - 07:30 2.50 PULL P DECOMP RU Lubricator and ext -Test & chart to 500 si for 5 minutes - OK. -Cameron Rep pull Dart from "K plug". -DSM ull "K lu ". -RD DSM and lubricator extension. 07:30 - 09:30 2.00 PULL P DECOMP PU spear w/ 4.805" nominal grapple and packoff. -Engage hanger at wellhead -BOLDS. -Pull on hanger and work 100k to 300k. -Hanger pulled free w/ 200k over. -Pull hanger and tubing to surface w/ 100k up wt. 09:30 - 11:00 1.50 PULL P DECOMP Break circulation and pump: -40 bbl "Safe Surf O" and 40 bbl "Safe Scav" pill. -Pump surface to surface ~ 8 bpm / 450 psi. -SIM-OPS -Change elevators - RU casing tongs. -RU Schlumberger control line spool. 11:00 - 11:30 0.50 PULL P DECOMP LD spear and hanger w/ pups. -(Control line broke free from hanger). 11:30 - 17:00 5.50 PULL P DECOMP LD 5 1/2" 17# L-80 tubin and'ewel -(Recovered control line after pulling 2 jts). -Recovered: 70 joints of tubing. -Cut jt (33.60') w/ 6 7/16" flare at cut. -2 Pup jts -Camco "Ball valve" - 2 Camco flow couplings. -Recovered 4 S.S. bands and 26 metal clamps. 17:00 - 19:00 2.00 PULL P DECOMP RD Csg equipment. Clear Rig floor. Clean Rig floor. -PU Fishing BHA: Overshot Dressoff guide, Overshot, Extention, -Drive sub, Bumper sub, Crossover, (9) 6 1/2" D.C's., & Crossover. 19:00 - 20:30 1.50 PULL P DECOMP Attempt to install Wear ring- No-go. Drain stack & observe. -Fish out 20+ ft of control line from Stack. -Install Wear ring. 20:30 - 22:30 2.00 PULL P DECOMP MU BHA: Overshot DresGOff q ~iydP; Overshot, Extention, -Drive sub, Bumper sub, Crossover, (9) 6 1/2" D.C's., & Crossover. 22:30 - 00:00 1.50 PULL P DECOMP PU 5" D. P. and RIH w/ BHA to 1,397' md. 6/20/2008 00:00 - 02:00 2.00 PULL P DECOMP Continue to PU 5" D. P. from 1,397' to 2,973' md. Printed: 7/23/2008 2:25:41 PM • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date 'From - To ~ Hours Task Code II NPT Phase Description of Operations 6/20/2008 00:00 - 02:00 2.00 PULL P DECOMP -Establish parameters: -PUW 125k, SOW 125k, ROT wt 125k. 02:00 - 02:30 0.50 PULL P DECOMP Polish over Stub from 2 981' to 2 987' md. -En a e Fish work free with 245k over ull 02:30 - 04:30 2.00 PULL P DECOMP F' i throw h Kill line. -Establish loss rate ~ 5.5 bpm. -Fluid used is 8.5 ppg Seawater. -Monitor well. 04:30 - 06:30 2.00 PULL P DECOMP POH with Fish on 5" D.P. from 8,277' to 5,310' md. -PUW 220k. -Stand back D.C's. 06:30 - 07:30 1.00 PULL P DECOMP Release overshot - LD same. -RU casing tongs -Change elevators. 07:30 - 13:30 6.00 PULL P DECOMP LD 5 1/2" 17# LTC tubing and jewelry. -Recovered cut jt on top (7.40'). -120 jts tubing, 10 GLM assemblies, -Pup jt (13.33') & seal assembly (16.35'). -Total joints 5 1/2" recovered from well = 191. -Seal assembly OD = 6.125" -Total Seawater lost to hole ~ 12:00 = 1.218 bbls 13:30 - 14:00 0.50 PULL P DECOMP Monitor well. Fill hole w/ 103 bbls seawater. -Wait 15 minutes. -Fill hole w/ 67 bbls = 268 bbls / hr losses. -Continue to fill hole w/ 15 obis every 15 minutes. 14:00 - 15:00 1.00 PULL P DECOMP LD Csg equipment. Clean Rig floor. 15:00 - 16:30 1.50 PULL P DECOMP Service break overshot assembly. -MU 9 5/8" Csg scraper assembl~v. 16:30 - 18:00 1.50 PULL P DECOMP RIH w/ 3 stds of D.C's & 29 Stds of 5" D.P. f/derrick to 3,297' md. 18:00 - 22:30 4.50 PULL P DECOMP Continue to RIH picking up singles from pipe shed. -Single in from 3,297' to 8,200' md. -RIH and li htl to to of Fish ~ 8 258' m . P t -Obtain parameters: PUW 255k, SOW 210k, 317 gpm / 300 psi. -Work scraper from 8,253' to 8,150' md. -Pump Hi Vis pill (56-YP). -Circulate D.P. volume and put pill up above Boot basket. -Pumped 181 bbls away while circulating Pill & D.P. volume. -Fill hole on backside. 22:30 - 00:00 1.50 PULL P DECOMP POH with 9 5/8" Cs scra er BHA from 8,150' to 6,247' md. -Fill hole w/ 20 bbls every 15 minutes. -Total seawater losses for tour = 1,213 bbls. -Total seawater losses to well = 2.431 bbls. 6/21/2008 00:00 - 02:00 2.00 PULL P DECOMP Continue to POH w/ 9 5/8" Csg scraper BHA. -POH from 6,247' to BHA ~ 300' md. 02:00 - 03:00 1.00 PULL P DECOMP Stand back D.C's. Break off Bit. -Clean & LD Boot baskets (scale inside +/- 1 cup). -LD Scraper, Bit sub & bumper sub. 03:00 - 04:00 1.00 PULL P DECOMP Monitor well: fill hole w/ 98 bbls. -Wait 15 minutes. Hole fill = 70 bbls = 280 bbls / hr losses. -PJSM on PU & run RBP. 04:00 - 10:00 6.00 PULL P DECOMP PU & MU HES RBP. Fill hole w/ 80 bbls seawater. -RIH w/ RBP on 5" D.P. to 7976' md. Printed: 7/23/2008 2:25:47 PM • BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ', Task Code NPT .Phase Description of Operations 6/21/2008 04:00 - 10:00 6.00 PULL P DECOMP -PU 5" DP f/ shed to 8,229' md. 10:00 - 10:30 0.50 PULL P DECOMP Obtain parameters -PUW 240k -SOW 195k. -Spot RBP at 8,220' and (Center of element) -Top at 8,215' md_. -Set RBP per HES Rep. w/ 3 L.H. turns. -PU to 10k over -Set down w/ 10k to ensure set. -Stand back 1 stand to 8,130' md. 10:30 - 12:00 1.50 PULL P DECOMP RU test equipment. -Test 9 5/8" casing to 3500 psi f/ 15 min. -Good test; -Bleed off - RD test equipment. -Blow down lines. -Total seawater losses for tour = 973 bbls. -Total seawater losses to well = 3 404 bbls. 12:00 - 13:30 1.50 PULL P DECOMP RU to cut drilling line. -Slip & cut 120' of 1.25" drilling line. 13:30 - 16:00 2.50 PULL N RREP DECOMP Trouble shoot Top drive. -Top drive Bales would not rotate. -Pressure relief tattle tail leaking. 16:00 - 20:00 4.00 PULL P DECOMP POH w/ RBP runnin t of on 5" D.P. from 8,130' md. -LD running tool. 20:00 - 20:30 0.50 PULL P DECOMP Clear and clean Rig floor. 20:30 - 21:30 1.00 PULL P DECOMP Spot SLB Whale & E-line tools. -PU E-line USIT tools. 21:30 - 23:30 2.00 PULL P DECOMP PJSM w/ SLB, T.P. W.S.L. & crew. -Hang sheaves. -Install lubricator & Pump-in sub w/line wiper. -RU E-line. 23:30 - 00:00 0.50 PULL P DECOMP RIH w/ SLB -USIT logging tools. 6/22/2008 00:00 - 03:00 3.00 CLEAN P DECOMP Run USIT Lo from 2,980' and to surface. -F.O's noted ~ 2,445' & 2,150' md. -Cement to noted C~ 2,216' md. 03:00 - 05:00 2.00 CLEAN P DECOMP PJSM: Discuss line handling and rigging down. -RD SLB E-line. -LD E-line tools. 05:00 - 06:00 1.00 CLEAN P DECOMP PU HES 9 5/8" RBP. -MU RBP running tool. 06:00 - 07:30 1.50 CLEAN P DECOMP RIH w/ RBP on 5" D. P. to 2,330' md. -RIH ~ 100 seconds per stand. 07:30 - 08:30 1.00 CLEAN P DECOMP Obtain parameters: PUW 98k, SOW 95k. -Set RBP per HES rep w/ 3 LH turns. -RBP - Top ~ 2,316' md. Mid element ~ 2,321' md. 08:30 - 09:30 1.00 CLEAN P DECOMP Stand back 2 Stds of 5" D.P. to 2,128' md. -RU & test RBP to 1500 si f/ 15 minutes - PA -RD test equipment. 09:30 - 10:30 1.00 CLEAN P DECOMP Pump Hi Vis Spacer (38-YP). -Displace to 9.8 ppg NaCI ~ 294 gpm / 200 psi. 10:30 - 12:00 1.50 CLEAN P DECOMP Dump 2200 Ibs of 20/40 sand down the D.P.. -Allow to settle 30 minutes. 12:00 - 12:30 0.50 CLEAN P DECOMP Pump 1/2 D.P volume to push sand to bottom. -Allow sand to settle out. 12:30 - 14:00 1.50 CLEAN P DECOMP PJSM- RIH and Ta to of sand ~ 2,266' md. -POH,Std back 5" D.P. -LD RBP running tool. Printed: 7/23/2008 2:25:41 PM • • BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: i I Date ~ From - To ~,~ Hours Task ;Code NPT ; Phase ~ Description of Operations 6/22/2008 14:00 - 00:00 10.00 CLEAN N RREP DECOMP PJSM. -Disassemble Top Drive & Rotating Link adaptor assembly. -Wait on VARCO personnel & parts. -SIM-OP's: Paint Rig & remove De-Gasser. 6/23/2008 00:00 - 03:00 3.00 CLEAN N RREP DECOMP Wait on Varco parts & personnel. -SIM-OP's: Paint Rig & remove De-Gasser. 03:00 - 04:00 1.00 CLEAN N RREP DECOMP Varco Tech's assess Top Drive. -Consult with Varco Tech's. 04:00 - 14:00 10.00 CLEAN N RREP DECOMP Reassemble Top Drive. -Hook up lines. 14:00 - 15:00 1.00 FISH P DECOMP PU BHA. -8 1/4' mutistring cutter for 9 5/8" casing. -XO - 8 1/2" OD stabilizer. 15:00 - 16:30 1.50 FISH P DECOMP tter a embl on 5" DP to 2,000' md. -Screw in T.D. -Obtain parameters -Break circulation. -RIH, Locate casing collar w/ knives at 2,041' md. -PU ands of knives at 2 030' md. -Begin rotating w/ 70 RPM. -Bring on pumps w/ 35 spm / 300 psi (Observe torque increase). -Stage pumps up to 65 spm / 1020 psi - 5-10k torque. -Observe 200 psi pressure drop & torque drop to 1-2k 16:30 - 17:30 1.00 FISH P DECOMP Close annular preventer. -Establish circulation through 13 3/8" X 9 5/8" annulus to tiger tank. -84 gpm / 800 psi. 17:30 - 18:30 1.00 FISH P DECOMP Rack back 1 std of 5" D.P. -RU Hot Oil. MU circulating lines to cellar & Rig floor. 18:30 - 19:30 1.00 FISH P DECOMP PJSM w/ LRS Hot Oil, CH2MHILL, TP, WSL & crew. -Test lines to 3000 psi - OK. 19:30 - 21:30 2.00 FISH P DECOMP Pump 108 bbls of 160 degree diesel down D.P. -Take returns up 13 3/8" X 9 5/8" annulus. -ICP = 1250 psi. FCP = 350 psi. 21:30 - 22:00 0.50 FISH P DECOMP Pump 40 bbl Hi Vis Sweep (49 YP) to spot diesel in annulus. 22:00 - 00:00 2.00 FISH P DECOMP Shut annulus valve. -Allow diesel to soak and heat Arctic Pac for 2 hours. -SIM-Ops -painting Rig & removing De-Gasser. 6/24/2008 00:00 -.02:00 2.00 FISH P DECOMP Pump 128 bbls of 9.8 ppg NaCI brine down D.P. -Take returns up 13 3/8" X 9 5/8" annulus to Tiger Tank. -Pump rate 210 gpm / 1050 psi. -Pump Hi Vis Sweep (60 YP), 170 bbls 9.8 ppg NaCI. -Take returns to Tiger Tank. -Pump rate 210 gpm / 1360 psi. 02:00 - 03:00 1.00 FISH P DECOMP - 03:00 - 03:30 0.50 FISH P DECOMP Clear floor of vendor tools. -PU Spear assembly tools to Rig floor. 03:30 - 04:00 0.50 FISH P DECOMP Pull Wear ring. 04:00 - 05:00 1.00 FISH P DECOMP M and 5" pup. -PU 1 jt of 5" D.P. -Engage Hanger. BOLDS. 05:00 - 05:30 0.50 FISH P DECOMP Work Fish. -Hanger / Packoff broke free ~ 150k. Printed: 7/23/2008 2:25:41 PM • • BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 6/24/2008 05:00 - 05:30 0.50 FISH P DECOMP -At 265k Fish broke free = 115k overpull. -Pull Hanger to floor w/ 140k PUW. 05:30 - 06:30 1.00 FISH P DECOMP RU & circulate hole clean -Pump rate 336 gpm / 130 psi. 06:30 - 07:30 1.00 FISH P DECOMP Release Spear. Make sevice breaks on Tools. -LD Tools. 07:30 - 08:00 0.50 FISH P DECOMP Clear Rig floor of Vendor Tools. -PU Csg pulling Tools. 08:00 - 08:30 0.50 FISH P DECOMP RU to pull 9 5/8" 47 Ib Csg. 08:30 - 12:00 3.50 FISH P DECOMP PJSM - POH LD 9 5/8" Csg from 2,030' to 1,550' md. -Steam and hammer on each connection. -Breakout Tq is 35k to 45k ft/Ibs. 12:00 - 20:00 8.00 FISH P DECOMP PJSM -continue to POH LD 9 5/8" Csg from 1,550' to surface. -Steam and hammer on each connection. -Breakout Tq is 35k to 45k Wlbs. -Total LD = 49 full jts. 1 pup jt & 1 cut jt ~ 29.98' - aximum are on cut = -Recovered 3 centralizers; 1 on each jt # 37, 41 & 46. 20:00 - 21:00 1.00 FISH P DECOMP RD Csg equipment. Clean & clear Rig floor. 21:00 - 22:00 1.00 FISH P DECOMP PU 9 5/8" Cs scra er / Dressoff BHA to Ri floor; 22:00 - 00:00 2.00 FISH P DECOMP MU BHA: Dress off shoe, Extention, Drive sub, Inside dress off Mill, -Double Pin sub, 13 3/8" Csg scraper, Bit sub, XO, Bumper sub, -To 308' and 6/25/2008 00:00 - 02:30 2.50 CASE P TIEB1 Stage in the hole with Csg scraper /Dress off BHA. -Stage from 300' to 2,015' md. -Circulate out Arctic Pac ~ 700' & 1,400' md. 02:30 - 04:00 1.50 CASE P TIEBi -At 2,015' and obtain parameters: -PUW 105k, SOW 105k, ROT wt 105k. -294 gpm / 120 psi. Tq 1 k ~ 60 RPM. -PU 1 jt of 5" D.P. -Taa Csa Stub ~ 2.030' md. -Work over stub w/ no rotatry & 2 bpm 50 psi. 04:00 - 05:00 1.00 CASE P TIEB1 Circulate and displace from 9.8 ppg NaCI to 8.5 ppg Seawater. 05:00 - 06:00 1.00 CASE P TIE61 POH to BHA ~ 301' md. 06:00 - 07:30 1.50 CASE P TIE61 Stand back D.C's. -LD Shoe, Extension, Washover B.B., Scraper. -Inside Mill shows good wear pattern. 07:30 - 08:00 0.50 CASE P TIE61 Clear floor of vendor tools. 08:00 - 09:00 1.00 CASE P TIEB1 Mobilize casing equipment to floor: -Centralizers, cement head, ES Cementer, -Casing patch assembly, etc. 09:00 - 11:00 2.00 CASE P TIEB1 Change Bales & Elevators -RU casing tongs and Torque Turn equipment. 11:00 - 15:30 4.50 CASE P TIEB1 PJSM - PU: Bowen 9 5/8" casin atch -10' pup, HES ES Cementer and XO joint. -Baker Lok all connections below XO joint. -Run 51 'ts 9 5/8 47# H dril 563 casin . -Torque Turn all jts - No rejections. Printed: 7/23/2008 2:25:41 PM U BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: 1 2-03 Common W ell Name: 1 2-03 Spud Date: 8/14/1979 Event Nam e: WORKO VER Start : 6/16/2008 End: Contractor Name: DOYON DRILLI NG INC . Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: ~ Date From - To Hours ~, Task Code NPT Phase Description of Operations 6/25/2008 11:00 - 15:30 4.50 CASE P TIEB1 -PU 2 pups, XO to 4 1/2" IF and 5" pup jt. 15:30 - 16:00 0.50 CEMT P TIEBi Screw in Top Drive. -Obtain parameters - PUW 135k, SOW 135k, ROT wt 135k. -Break Circulation ~ 189 gpm / 40 psi. -Rotate down ~ 10 rpm w/ 1.5k Tq. -Tag 9 5/8" stub at 2,030' md- Observe pressure increase. -Stop pumps, swallow 3' and stack out w/ 25k down. -PU and ull test casin to 350k 215k over 16:00 - 17:30 1.50 CEMT P TIE61 RU cement equipment. -PU to 200k. - si / 30 minutes on chart -PASS. -Continue to pressure up to 2550 psi. -Shear open cement port ~ 2550 psi. 17:30 - 18:30 1.00 CEMT P TIEB1 Break circulation ~ 168 gpm / 80 psi. -Stage up pumps to 336 gpm / 300 psi. -Circulate 85 degree F Seawater surface to surface. 18:30 - 20:30 2.00 CEMT P TIEB1 PJSM w/SLB, HES, CH2MHILL,TP, WSL & Crew. -Batch up Cmt. Test lines to 4000 psi -OK. -Pump Cmt per plan: -135 bbls of 15.8 PPG class "G" w/ Gas blok. -Drop plug, SLB chase w/ 10 bbls of H2O. Turn over to Rig. -Displace w/Rig pumps: -Stage up to 252 gpm / 800 psi until 1266 stks. -Stage down to 105 gpm / 750 psi. -Red dye back ~ 1117 stks. `Bump plug ~ 1361 stks.* -Received 2.5 bbls of ood Cmt returns to surfac -Pressure up, shear pins ~ 1550 psi. -Maintained 100k overpull throughout job. -CIP ~ 20:30 hrs. 20:30 - 22:00 1.50 CEMT P TIEB1 Check float equipment -OK. -RD CMT head. Flush stack. Clean out drip pan. 22:00 - 00:00 2.00 CEMT P TIE61 PJSM- ND BOP stack. -Remove studs on flanges. 6/26/2008 00:00 - 01:00 1.00 CEMT P TIEB1 Remove double valve. Break stack. 01:00 - 02:00 1.00 CEMT P TIEB1 Set emergency slips w/ 125k on slips. -Use WACHs cutter to cut 9 5/8" Csg. -Cut jt = 35.04' (3 pups & 1 cut jt ~ 2.74'). 02:00 - 03:00 1.00 CEMT P TIE61 Break off Tbg spool. -Stand back stack. Remove Spool from cellar. 03:00 - 05:00 2.00 CEMT P TIEB1 -Dress cut on Csg. Install Pack off. -NU Gray "New Standard" Tubing Spool. -Test Pack off to 3800 psi / 30 minutes -PASS. -Install double valve on IA. 05:00 - 07:30 2.50 CEMT P TIEB1 Drop spacer spool. -NU BOPE, Choke line, flowline. 07:30 - 08:30 1.00 CEMT P TIEB1 Install test plug. -RU to test BOPE. 08:30 - 14:00 5.50 CEMT P TIE61 Test BOP and related eouioment. -Test per BP / AOGCC procedures and regulations. -Test to 250 psi low - 3500 psi high X 5 min each on chart. -Annular to 250 psi low - 3500 psi high x 5 min each on chart. Printed: 7/23/2008 2:25:41 PM • • BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date ~~ From - To '~ Hours Task Code ! NPT Phase ~, Description of Operations 6/26/2008 08:30 - 14:00 5.50 CEMT P TIEB1 -Test w/ 5" test joint. -Test upper and lower rams with 5" & 4 1/2" test jts -Perform Accumulator test: 40 secs for 200 psi increase. -2 minutes 59 secs for final total system pressure. -Test witnessed by WSL and Toolpusher. -Chuck Scheve, AOGCC rep, waived witness of test. ----BOP Configuration. -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -4 1/2" X 7" Variables. 14:00 - 15:30 1.50 CEMT P TIEB1 PJSM- Install Wear ring. -PU Cleanout BHA: -8 1/2" bit, (3) - 7" Boot baskets, 9 5/8" Csg scraper, Bit sub, -Bumper sub,XO, (9) - 6 1/4" D.C's. & XO. 15:30 - 16:30 1.00 CEMT P TIE61 MU cleanout BHA to 303' md. 16:30 - 18:00 1.50 CEMT P TIE61 RIH with cleanout BHA on 5" D.P. to 1,845' md. -Break circulation. Wash down to 2,010' and (hit Cmt stringer). -Ta lu ~ 2 016' md. -Obtain parameters: 336 gpm / 120 psi. 1 k Tq ~ 60 RPM. 18:00 - 20:30 2.50 CEMT P TIE61 Drill out plug & ES cemeter from 2,016' to 2,019' md. - 336 gpm / 120 psi. 3k Tq ~ 60 RPM. -Ream through ES cementer 3 times. -Slide through area 3 times w/ no rotation. -PUW 110k, SOW 105k. -Continue to wash down to 2,212' md. -Tag Junk & sand. Rotate down to 2,266' md. -210 gpm / 110 psi 3k Tq ~ 50 RPM. -Slack off W/O pumps, Tag sand ~ 2,275' md. 20:30 - 21:00 0.50 CEMT P TIE61 Pump 40 bbl Hi Vis Sweep (47 YP) ~ 2,255' md. -Work pipe 60 ft. -594 gpm / 500 psi. 30 RPM. 21:00 - 22:30 1.50 CEMT P TIEB1 POH w/ Cleanout BHA on 5" D.P. Stand back collars. 22:30 - 00:00 1.50 CEMT P TIEB1 Break off Bit. Clean Boot baskets (1/2 of 5 gal bucket of metal pieces). -LD Boot baskets, Scraper, Bit sub & Bumper sub. 6/27/2008 00:00 - 02:00 2.00 CASE P TIEB1 RU & test 9 5/8" Cs to 3500 si f/ 30 minutes -PASS. -Clean Rig floor. 02:00 - 03:00 1.00 CASE P TIE61 Clear & clean Rig floor. 03:00 - 06:00 3.00 CASE N RREP TIEBi Repair Top Drive. Replace Bottom end of Top Drive. 06:00 - 07:00 1.00 CASE P TIEB1 Clear /Clean floor. -Mobilize Baker Tools to rig floor. 07:00 - 08:30 1.50 CASE P TIEB1 P w 3- 7" boot baskets, -bumper sub, pumpout sub and 3- 6 1/4" D.C's. 08:30 - 09:30 1.00 CASE P TIEB1 RIH w/ 5" DP. -Taking weight at 2,016' and (ES Cementer), 09:30 - 10:00 0.50 CASE P TIEB1 Screw in T.D. -Obtain Parameters: -PUW 98k -SOW 98k -ROW 98k. Printed: 7/23/2008 2:25:41 PM f ' ~ • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/27/2008 09:30 - 10:00 0.50 CASE P TIEB1 -Break circulation w/ 189 gpm / 280 psi. -Ream through Cementer w/ 60 rpm, -1-3k WOB f/ 2,016' to 2,019' md. -Backream and ream through several times. -Work through w/ no rotary -Clean up good 10:00 - 10:30 0.50 CASE P TIEB1 Continue RIH to 2,215' md. -Tag top fill /sand at 2,274' md. 10:30 - 12:00 1.50 CASE P TIE61 Screw in Top Drive. -Dry drill f/ 2,274' - 2,276' md. -Engage pumps w/ 315 gpm / 2200 psi. -Attempt to wash/ ream down further w/ no success. -Pump H.V. Sweep (51 YP) -(Recovered small rubber and sand w/ sweep). 12:00 - 13:30 1.50 CASE P TIEB1 POH. -Break and clean RCJB. -Packed full w/ cement cuttings. -Recovered several 2-3" diameter alluminum, - 6" long rubber, 3- 1 1/8" shear bolts from ES Cmtr. -MU RCJB. 13:30 - 14:30 1.00 CASE P TIEB1 RIH - Ta fill/sand at 2 276' md. 14:30 - 16:00 1.50 CASE P TIEB1 Screw in • "dry drill" to 2,277' md. -Engage pumps w/ 315 gpm / 2900 psi -Rotate down to 2,295' md. -Stop rotary -Wash down easily to 2,300' md. -Circulate Hi Vis Sweep (45 YP) surface to surface. 16:00 - 17:00 1.00 CASE P TIEB1 POH w/ RCJB assembly on 5" D.P. 17:00 - 18:00 1.00 CASE P TIEB1 Stand back BHA. Clean out Junk basket. -Recovered 7 pieces of metal 2" in diameter. -Also recovered approximately 1 cup of metal shavings. 18:00 - 18:30 0.50 CASE P TIEB1 RIH to too of sand ~ 2,300' md. 18:30 - 19:30 1.00 CASE P TIEB1 Wash down to 2,310' and 320 gpm / 2700 psi. -Noted sticking while working through ES cementer. -Washed and reamed same. -Washed down to RBP top ~ 2,316' md. -Circulate Hi Vis Sweep (48 YP). 19:30 - 20:30 1.00 CASE P TIE61 POH w/ RCJB assembl on 5" D.P. 20:30 - 22:00 1.50 CASE P TIE61 LD RCJB. -Recovered approximately 1/2 cup of metal shavings. -Clear Rig floor. -MU HES retrieval Tool. 22:00 - 23:30 1.50 CASE P TIEB1 RIH w/HES retrieval tool on 5" D. P. to 2,280' md. 23:30 - 00:00 0.50 CASE P TIE61 Obtain parameters: PUW 97k, SOW 97k. -Wash down to RBP ~ 2,316' md. -Set down 25k, turn 1/2 RHT to release R_BP. 6/28/2008 00:00 - 00:30 0.50 CASE P TIEB1 Circulate surface to surface 378 gpm / 170 psi. -Noted sand back w/ returns. 00:30 - 01:30 1.00 CASE P TIEBi Rack back 1 Std, blow down Top Drive. -Observe well -static. -POH w/ RBP f/ 2,280' to 2,100' md. -Observed Bad spot on Drlg line. 01:30 - 03:00 1.50 CASE P TIEB1 Cut & slip 1,100' of 1 1/4" Drlg line. -4 rows of 37 wraps of drilling line cut to remove bad spot. 03:00 - 04:30 1.50 CASE P TIEB1 POH f/ 2,100' and to surface w/ RBP on 5" D.P. Printed: 7/23/2008 2:25:41 PM • • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/28/2008 04:30 - 05:00 0.50 CASE P TIEB1 LD HES 9 05:00 - 08:00 3.00 CASE P TIE61 RIH w/ RBP retrieval tool on 5" D.P. to 8,156' md. 08:00 - 08:30 0.50 CASE P TIEB1 MU Top Drive. -Establish circulation and wash down to 8,215' md. -Pump rate: 378 gpm / 170 psi. -Latch RBP. Pull 5k overoull. 08:30 - 09:00 0.50 CASE P TIEB1 Allow hole to drink, let fluid level balance. 09:00 - 10;00 1.00 CASE P TIEB1 Establish circulation: 252 gpm / 100 psi. -Fluid caught up at 60 bbls away to pump pressure 200 psi. -Received returns at 70 bbls away. -Continued to circulate f/ 15 minutes. -D namic losses = 11 b Is hr. 10:00 - 10:30 0.50 CASE P TIE61 Pulled 25k over on RBP. set down 20k. -Worked RBP loose. Rack back 1 Std to 8,125' md. -Blow down Top Drive. ', 10:30 - 16:00 5.50 CASE P TIEB1 POH w/ RBP on 5" D.P. f/ 8,125' and to surface. 16:00 - 17:00 1.00 CASE P TIEB1 LD HES 9 5/8" RBP &RBP running tool. 17:00 - 18:30 1.50 CASE P TIEB1 PU PBR S ear assembl . -MU Spear & 6 1/4" D.C's. to 301' md. -Top off well, 75 bbls to fill. -Obtain 15 minute loss rate of 37 bbls = 148 bbls / hr. 18:30 - 21:00 2.50 CASE P TIE61 RIH w/ Spear assembly on 5" D.P. from 301' to 8,240' md. 21:00 - 22:30 1.50 CASE P TIEB1 Obtain parameters: PUW 250k, SOW 205k, ROT wt 230k. -En a e Fish PBR er Baker re :Slack off set down 15k -PU to neutral spot. Unseat "K" anchor: -Turn 5 RHT's -PU to 285k- trip jars open. -Slack off to 250k, apply 7 RHT's Tq ~ 15k stalled out. -Increase Tq range & break over C~3 17k Tq. -Apply a total of 12 rounds of RHT's. -Continue rotating, Tq dropped down to 5-6k ~ 20 total RHT's. -Slowly PU w/ rotating PU 10'. -Slack off to 8,250' and to check Spear engagement. -Circulate Hi Vis Sweep (YP 51) ~ 210 gpm / 170 psi. -Flow check well ~ 130 bbls / hr losses. 22:30 - 00:00 1.50 CASE P TIE61 POH w/ PBR /latch on 5" D. P. from 8,240' and to 5,300' md. -Total losses since Pullin PBR is 953 bbls. 6/29/2008 00:00 - 02:00 2.00 CASE P TIEB1 Continue to POH w/ PBR /latch on 5" D. P. -POH f/ 5,000' to 318' and / BHA depth. 02:00 - 03:00 1.00 CASE P TIE61 LD Accelerator Jars, rack back 3 Stds of 6 1/4" D.C's. -LD Fish (PBR /latch 19.26'), Bumper sub & jars. 03:00 - 03:30 0.50 CASE P TIEB1 Clear & clean Rig floor, LD Spear assembly. 03:30 - 04:30 1.00 CASE P TIEB1 Calibrate TOTCO block height for Rig instrumentation. -Mob packer milling assembly to rig floor. 04:30 - 06:00 1.50 CASE P TIEB1 MU Packer millin assembly: Mill, Grapple, Tripple conn, Jars, -Bumper sub, 3 Stds of D.C's & Accelerator jars to 337' md. 06:00 - 10:00 4.00 CASE P TIEB1 RIH on 5" D.P. from 337' to 8,196' md. 10:00 - 11:30 1.50 CASE P TIEB1 Screw in T.D. -Obtain parameters: -Fill hole - 45 bbls to fill. -PUW 258k, SOW 297k, ROW 230k w/ 80 rpm, 7-8k tq. -PU single DP -Wash down and enter packer w/ PRT. -Taa Dacker w/ mill at 8.278' md. Printed: 7/23/2008 2:25:41 PM • • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: i ~ NPT Phase ': Description of Operations Date From - To Hours Task ; Code 6/29/2008 10:00 - 11:30 1.50 CASE P TIEB1 -Stop pumps, PU w/ 15k overpull to ensure catch. -Milling on packer w/ 100 rpm, 5-20k WOB, 147 gpm / 120 psi. -Packer fell -Push to 8,320' md. 11:30 - 12:30 1.00 CASE P TIEB1 CBU - 294 gpm / 250 psi. -Losses for tour = 885 bbls. -Total losses = 2,065 bbls. 12:30 - 13:00 0.50 CASE P TIEBi Chase 9 5/8" acker down to 7" liner to at 8,532' md. -Circulate f~ 126 gpm / 350 psi. 13:00 - 13:30 0.50 CASE P TIEB1 Rotate on packer w/ 10k WOB, Tq 10k. -294 gpm / 590 psi. 13:30 - 20:00 6.50 CASE P TIEB1 Monitor well:Hole taking fluid ~ 88 bbls / hr. -POH w/9 5/8" packer on 5" D.P. -Packer dragging w/ 10-120k over 20:00 - 00:00 4.00 CASE P TIEB1 Stand back collars. -LD BHA. Packer & Tail pipe assembly. -Rig Tongs will not brake Tbg connections (egging tubes). -RU Tbg Tongs, break connections & LD Tail pipe. -Recovered (1) 5 gal bucket of metal pieces from Boot Baskets. -Losses for tour = 836 bbls -Total losses to well = 2,901 bbls of Seawater. 6/30/2008 00:00 - 00:30 0.50 CASE P TIEB1 Clear and clean Rig floor. 00:30 - 01:30 1.00 CASE P TIEB1 PU & MU cleanout / Csg scraper BHA: -8 1/2" used Bit (no jets), (3) 7" Boot baskets, -9 5/8" Csg scraper, Bit sub, Bumper sub, -6 1/4" Oil jar, XO, (9) 6 1/4" D.C's., XO. to 315' md. 01:30 - 04:00 2.50 CASE P TIEBi RIH w/ cleanout BHA on 5" D. P. to 8,150' md. 04:00 - 04:30 0.50 CASE P TIE61 Work 9 5/8" Csg scraper from 8,150' to 8,270' and - 4 times. -20k overpull noted on pass #1. -15k overpull noted on pass #2. -5k overpull noted on pass #3. -Zero overpull noted on pass #4. -Continue in hole 8,530' md. -Tag T.O.L ~ 8,530' md. -PUW 265k, SOW 210K. 04:30 - 06:30 2.00 CASE P TIEB1 Establish circulation 210 gpm / 140 psi. -Returns noted C~ 40 bbls away. -Pump Hi Vis Sweep (47 YP) surface to surface. 06:30 - 08:30 2.00 CASE P TIEB1 Rack back 1 Std. Blow down Top Drive. -POH w/ Csg Scraper BHA from 8,453' to 4,760' md. -Rack back 40 Stds for move. 08:30 - 13:00 4.50 CASE P TIEB1 POH from 4,760' to 315' md. - LD 5" D. P. to pipe shed. -Fluid losses for tour = 895 bbls -Total losses = 3 796 bbls. 13:00 - 14:30 1.50 CASE P TIEB1 LD Csg scraper BHA: -8 1/2" used Bit (no jets), (3) 7" Boot baskets, -9 5/8" Csg scraper, Bit sub, Bumper sub, Printed: 7/23/2008 2:25:41 PM ~, BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/30/2008 13:00 - 14:30 1.50 CASE P TIEB1 -6 1/4" Oil jar, XO, (9) 6 1/4" D.C's., XO. - 2 cups of metal slivers recovered. 14:30 - 15:00 0.50 CASE P TIEB1 Pull Wear ring. -Fill hole with 40 bbls Seawater. 15:00 - 16:30 1.50 BUNCO RUNCMP -RU to run: 4 1/2", 12.6#, 13Cr80, Vam Top - R2 Tbg. -RU Torque Turn equipment. 16:30 - 00:00 7.50 BUNCO RUNCMP Run 4 1/2 Vam Top Tbg and jewelry to 4,000' md.: -4 1/2" WLEG, XN nipple w/ RHC-M , X nipple, -Baker S-3 packer,X nipple, GLM, GLM, GLM, GLM, X nipple. -Utilize "Jet Lube Seal Guard" Thread compound. -Optimum Tq 4,440 ft/Ibs. -Continue to pump 15 bbls of Seawater every 15 minutes. -Fill hole ~ Tbg jt # 100. w/ 96 bbls. -Fluid losses for tour = 894 bbls. -Total Seawater losses = 4,690 bbls. 7/1/2008 00:00 - 05:30 5.50 BUNCO RUNCMP Continue to run: 4 1/2" 12.6# 13Cr80 Vam Top - R2 Tbg. -Run Tbg from 4,000' md. -Torque turn Vam Top Tbg. -Utilize "Jet Lube Seal Guard" Thread compound. -Optimum Tq 4,440 ft/Ibs. -Continue to pump 15 bbls of Seawater every 15 minutes. -Fill hole ~ Tbg jt # 200. w/ 112 bbls. -Run Tbg to 8,261' md. 263 jts. -PUW 150k /SOW 133k (blocks weight 50k) 05:30 - 07:00 1.50 BUNCO RUNCMP MU Gray New Standard Hanger w/ 4 1/2" MCA threads on top -PU & MU XO and joint of 5" DP -Fill hole w/ 70 bbls -Land completion 07:00 - 07:30 0.50 BUNCO RUNCMP RU to reverse circulate 07:30 - 11:30 4.00 BUNCO RUNCMP -Reverse circulate 140 bbls clean seawater, returns ~ 100 bbls pumped away. -Cont. reverse circulating 440 bbls seawater w/ corrosion inhibitor. -3 bpm / 190 psi 11:30 - 13:30 2.00 BUNCO RUNCMP -RU to pump down tubing. -Drop ball-and-rod. Pressure up tubing to 3500 psi and set acker. Hold 3500 si in tubin x 30 min on chart. MIT-T OK. -Bleed off pressure in tubin to 1500 si. Pressure u IA to 3500 si and hold x 30 min on chart. IT-IA -Bleed off pressure in tubing and observe DCR valve shear. Bleed off all pressures. -Verify circulation through DCR valve ~ 3 bpm / 430 psi 13:30 - 15:00 1.50 WHSUR P RUNCMP -LD 5" DP jt and XOs. -lest i vv~. a uuuum w iuuu usi x iu lion uii wean. i~si u above to 3500 psi x 10 min on chart. 15:00 - 16:00 1.00 BOPSU P RUNCMP -Blow down lines to stack. -Suck out stack w/ rig vac. 16:00 - 17:00 1.00 BOPSU P RUNCMP ND BOP 17:00 - 19:30 2.50 WHSUR P RUNCMP -NU adapter flange and tree -Test adapter flange to 5000 psi x 30 min per Cameron rep. -Fill tree w/diesel and test to 5000 psi x 10 min. Printed: 7/23/2008 2:25:41 PM ~.{ BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: 12-03 Common Well Name: 12-03 Spud Date: 8/14/1979 Event Name: WORKOVER Start: 6/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/2/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT ~ .Phase Description of Operations 7/1/2008 19:30 - 20:30 1.00 WHSUR P RUNCMP -RU lubricator. Test to 500 psi. -Pull TWC. -RD lubricator 20:30 - 21:30 1.00 WHSUR P RUNCMP -RU lines to tree and Little Red for freeze protect. -Test lines to 3500 psi w/ Little Red 21:30 - 22:30 1.00 WHSUR P RUNCMP Pump 140 bbls of diesel down IA, taking returns out tubing, for freeze protect. -3 bpm / 450 psi 22:30 - 23:30 1.00 WHSUR P RUNCMP Jump IA to tubing and allow diesel to U-tube 23:30 - 00:00 0.50 WHSUR P RUNCMP }~U lubricator and test to 500 psi -Install BPV. 7/2/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP -Finish installing BPV. -RD lubricator -Test BPV w/ Little Red f/ below to 1000 psi x 10 min on chart. 01:00 - 02:00 1.00 WHSUR P RUNCMP -RD lines. Remove pump in flanges -Install blanks and gauges on tree. Secure well -OA= 0 psi / IA= 0 psi / TBG= 0 psi Release riq ~ 02:00 Printed: 7/23/2008 2:25:41 PM 07/03/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N/PII .Inh !t ~;~.~i~ JVL ~ ~ LUUU 1 .,.Y ne ..w..., NO.4768 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n..~-, 01 MPB-50 11999019 RST WFL L 06/13/08 1 1 M-04 11962601 PRODUCTION PROFILE 06/21/08 1 1 P7-24 12066527 MEM LDL (,p6° ~ 06/18/08 1 1 04-11A 11975778 LDL l°6 ~- / 06/24/08 1 i M-04 11962601 PRODUCTION PROFILE _ 06/21/08 1 1 12-03 12071857 USIT ~ j . `(p 06/21/08 1 1 GNI-03 12066530 MEM PRESS/TEMP LOG ~~ G 06/20/08 1 1 E-10B 40016750 OH MWD/LWD EDIT 04/05/08 2 1 18-13B 11972960 MCNL v'~r (o ~ 12/07/07 1 1 18-13B 12021159 MCNL V"~.- 05/18/08 1 1 ra.a..~1.~G My nlYV VV L.c1J~.1G nGV Gir 1 O1 JI17 rv11Y17 NIVV RCI UrS1V11VU VIVC ~.VYT CHlirt I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~(,`I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ATTN: Beth Received by: ~ ._ ~J • • • ~ a ~ a S ARAN PALlN, GOVERNOR ~~ ~~ ~ vd-7 333 W. 7th AVENUE, SUITE 100 COI~TSER~A~'I019T COMI~II5SIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. ~~~N JUN ~. 3 200 PO Box 19661.2 Anchorage, AK 99519-6612 ~ ~ ~, 1 ~~ t Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBLJ 12-03 Sundry Number: 308-206 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 Corrunission'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 1 Z day of June, 2008 Encl. ,~ STATE OF ALASKA~~~ ~ . e ~~ ~ OD b ALA OIL AND GAS CONSERVATION COM 0~ 1 $ ~' APPLICATION FOR SUNDRY APPROVAL `o`ff 20 AAC 25.280 Alaska 4i6 & Gas ~~°~~_ ~mrnissi0. 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforat c `~]~`Tr'ni~ Extension ® 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 179-041 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20377-00-00' 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 12-03 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028330 ~ 73" Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENTWELLCONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9765' - 9536' - 9286' 9057' 8752' None asin en th Size MD TVD Burst Colla se Structural nd or 80' 20" 8 ' 80' 1530 520 Surface 2729' 13-3/8" 2729' 2729' 4930 2670 Intermediate 8869' 9-5/8" 8869' 8640' 6870 4760 Pro uction Liner 1228' 7" 8532' - 9760' 8304' - 9531' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below IPB: 8984' - 9106' 8755' - 8877' 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 8413' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 8278' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for IIcl 16. Well Status after proposed work: Commencin O erations: June ~0', 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed Nam David Reem Title Engineering Team Leader A~teS o 1~gr p.~ bN-yl~ Prepared By Name/Number: Signature Phone 564-5743 Date ~ ~p D Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: a? Conditions of approval: Notify Commission so that a representative may witness Wc~.l~ ~~ ic7 (~_~~ ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance 1 Other: 3~Qp S c 3~~ ~~~- Subsequent Form Required: ~Q APPROVED BY ~ (C ZJ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06'/2006 ~ ° ` ! (~ /~ j ~~ ~~~~~ ~ ( i ~ ~ ~~.~ ~ Submit In Duplicate by c,,~,~ 12-03 Expense Rig Workover • PLEASE NOTE: This work is scheduled for Doyon 14. Doyon 14 is well ahead of schedule and may finish the current well (C-19B) as soon as June 14th. BP therefore requests that the AOGCC expedite the processing of this Sundry application to allow Doyon 14 to proceed with rigging up for the rig workover on 12-03 as soon as June 14tH Scope of Work: Pull 5-~h" completion, cut and pull 9-6/a" casing, run and cement 9-s/8" casing to surface, (contingency plan is to mill and retrieve Baker SAB-3 packer), run 4-'/z" 13Cr-80 tubing with Baker S-3 packer set at --8125' MD. MASP: 2470 psi Well Type: Ivishak Producer Estimated Start Date: June 20, 2008 Production Engineer: Olivia Bommarito Intervention Engineer: Paul Chan Pre-ri re work• S 1 Drift thru 5-'/z" tubing to the top of the patch for the tubing cut. Dump 10' sluggits on top of IBP. Pull dummy in Station #10. Leak pocket open. CMIT T x IA to 1500 psi. Circulate well with kill weight fluid thru the GLM. If the well does not pass the CMIT, the tubing cut will be done Burin the RWO. E 2 Tubing punch 5-1/2" tubing at 8224' MD, in the middle of the first full joint above the Baker SAB packer if the dummy could not be pulled during the slickline work. Power Jet cut 5-~h" L-80 tubing at 2980' MD, in the lower half of the full joint above the Teledyne Merla patch at 2997' MD. Reference tubing tally dated 07/03/85. Jet cut will be cancelled if the well does not have a assin CMIT. F 3 Freeze rotect well with diesel throu h the cut. W 4 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 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU workover rig. ND tree. NU and test BOPE pipe rams to 3500 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater throu h the cut. 2. Retrieve 5-'h" tubing string down to the packer. ~••~ qk ~ o--+c~.5~ ~ s,~~-~'+a~. ~, 'rM,~ ~ r 3. Run USIT log to determine top of cement in the 9-5/8" casing. ~~~~[~~~ 4. Set and test 9-5/8" RBP approximately 100' below estimated TOC. Note: The VBRs in the BOPs will ~~ ! "I NOT be changed over to 9 5/8" pipe rams as the barriers to the reservoir will be the tested 9-5/8' RBP and IBP in the 7" liner. ~, ~` ,~ 5. Cut and pull 9 5/e' above TOC. S ;~ 6. Run and fully cement 9 5/8" casing to surface. ~~~ ~ ~~ ~~-~y'ti 7. Drillout 9 s/8" shoe track. _~ ~~'~~ 8. Retrieve 9-5/8" RBP. 9. Contingent -Mill and retrieve Baker SAB-3 packer at 8278' MD. 10. Run 4-~/z" 13Cr-80 tubing with Baker S-3 packer set at8125' MD. 11. Displace the IA to packer fluid and set the packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 13. Set BPV. ND BOPE. NU and test tree. RDMO. • ~- r.Rnv r.F WELLHEAD = GRAY ACTUATOR = ~ AXELSON KB. ELEV = 73' BF. ELEV = KOP = 4000' Max Angle = 23 @ 4500' Datum MD = 9102' Datum TV D = 8800' SS • ~ 2 ~0 3 SAN ANENT PAETLCmYNE M ERLA PATCH @ 2997 2213' S-1/2" CAM BAL-O SSSV NIP, ID = 4.562" 2997' 5-1/2" TELEDYNE MERLA TBG PATCH, ID = 3.75" 13-3/8" CSG, 72#, N-80, ID = 12.347" ~-~ 2729' Minimum ID = 3.75" @ 2997' 5-1/2" Teledyne Merla TBG Patch 5-1 /2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8290' ~, TOP OF 4-1/2" TBG-PC 8290' 4-1l2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ 8413' TOP OF 7" LNR $532' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8869' PERFORATION SUMMARY REF LOG: BHCS ON 09/09/79 ANGLE AT TOP PERF: 2 @ 8984' Note: Refer to Production DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 8984 - 9009 C 08/22/94 3-3/8" 0.5 8992 - 9004 C 10/04/91 3-3/8" 4 9086 - 9106 C 10/04/91 3-3/8" 4 9106 - 9116 S 10/04/91 3-3/8" 4 9123 - 9160 S 03/11/80 3-1/8" 4 9180 - 9219 S 03/11/80 3-1/8" 4 9229 - 9242 S 03/11/80 3-1/8" 0 9296 - 9298 S 09/16/79 PBTD -~ 9286, 7" LNR 29#, N-80, .0371 bpf, ID = 6.184" 9760' TD 9765' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3000 3000 1 MMG RK 2 4026 4022 10 MMG DMY RK 0 10/08/05 3 5083 5014 22 MMG DMY RK 0 10/08/05 4 6150 6005 21 MMG DMY RK 0 10/08/05 5 6863 6676 19 MMG DMY RK 0 10/08/05 6 7020 6825 18 MMG DMY RK 0 7 7471 7256 14 MMG DMY RK 0 10/08/05 8 7630 7411 12 MMG DMY RK 0 9 8028 7803 8 MMG DMY RK 0 10 8182 7956 8 MMG DMY RK 0 10/08/05 "` PATGFi GOV ERS STA iF1 8258' 5-1/2" BOT PBRASSY 8278' 9-5/8" X 5-1/2" BAKER SAB PKR 8290' S-1/2" X 4-1/2" XO 8351' 4-1/2" CAM DB-6 LANDING NIP, ID = 3.813" 8412' 4-1/2" BKRSHR OUT SUB WNVLEG 8413' 4-1/2" TUBING TAIL 8401' ELMD TT LOGGED 10/02/85 8752' 3-3/8" BAKER IBP (10/21/05) DATE REV BY COMMENTS DATE REV BY COMMENTS 09/21179 ORIGINAL COMPLETION 02/14/06 RRD/PAG BKR IBP DEPTH CORRECTION 07/03/85 LAST WORKOVER 10/08/05 KDGPAG GLV GO 10/13/05 RPHITLH WANERSFTY NOTE DELETED 10/21/05 RWUPJC SET IBP@ 8752' 02/06/06 JYJ/PJC SAFETY NOTE (PATCH) PRUDHOE BAY UNff WELL: 12-03 PERMIT No: 1790410 API No: 50-029-20377-00 SEC 18, T10N, R15E, 3984.28' FEL & 4166.76' FNL BP Exploration (Alaska) _ = GRAY GI WELLHEAD = GRAY ACTUATOR = _ AXELSON KB. ELEV = ~ 73 BF. ELEV = KOP = 4000' Max Angle = 23 @ 4500' Datum MD = 9102' Datum TVD = 8800' SS 12-~ Proposed Commotion Surface Top of Cement -2100 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS 13-3/8" CSG, 72#, N-80, ID = 12.347" ~~ 2729 ~4-1/2" TBG, 12.6#, 13CR 80, .0152 bpf, ID = 3.958" ~TOPOF4-1/2"TBG-PC 11 8290, 4-1 /2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8413' TOP OF 7" LNR $532' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8869' PERFORATION SUMMARY REF LOG: BHCS ON 09/09/79 ANGLE AT TOP PERF: 2 @ 8984' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 8984 - 9009 C 08/22/94 3-3/8" 0.5 8992 - 9004 C 10/04/91 3-3/8" 4 9086 - 9106 C 10/04/91 3-3/8" 4 9106 - 9116 S 10/04/91 3-3/8" 4 9123 - 9160 S 03/11/80 3-1/8" 4 9180 - 9219 S 03/11/80 3-1/8" 4 9229 - 9242 S 03/11/80 3-1/8" 0 9296 - 9298 S 09/16/79 PBTD 1 9286, 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 9760 TD 9765 2 3 4 DATE I 1 114-1/2" HES X NIP, ID = 3.813" 8125 7" X 4-1/2" BKR S-3 PK-~ 4-1/2" HES X NIP, ID = 3.813" 8258 5-1/2" BOTPBRASSY 8278' 9-5/8" X 5-112" BAKER SAB PKR 8290 5-1/2" X 4-1l2" XO 8351' 4-1/2" CAM DB-6 LANDING NIP, ID = 3.813" 8412 4-1/2" BKR SHR-OUT SUB WNVLEG 8413 4-1/2" TUBING TAIL 8401' ELMD TT LOGGED 10/02/85 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/21/79 ORIGINAL COMPLETION 02/14/06 RRD/PAG BKR IBP DEPTH CORRECTION 07/03/85 LAST WORKOVER 10/08/05 KDGPAG GLV GO 10/13/05 RPHITLH WA V ER SFTY NOTE DELETED 10/21/05 RWL/PJC SET IBP @ 8752' 02/06/06 JYJ/PJC SAFETY NOTE (PATCH) PRUDHOE BAY UNIT WELL: 12-03 PERMff No: 1790410 API No: 50-029-20377-00 SEC 18, T10N, R15E, 3984.28' FEL & 4166.76' FNL BP Exploration (Alaska) . STATE OF ALASKA I ALA Oil AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 13125 5982 600 SHUT-IN 15. Well Class after proposed work: Exploratory Development !;?i 16. Well Status after proposed work: Oil !;?i Gas WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowtedge. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 73 KB 8. Property Designation: ADl-028330 11. Present Well Condition Summary: Total Depth measured 9765 true vertical 9535.85 Effective Depth measured 9286 true vertical 9057.22 Casing Conductor Surface Production Liner length 80 2700 8841 1228 Size 20" 94# H-40 13-3/8" 72# N-80 9-5/8" 47# l-80 7" 29# N-80 Perforation depth: Measured depth: Closed True Vertical depth: Closed Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl 605 x Contact Sharmaine Vestal Signat Form 10-404 Revised 04/2004 RECEIVEB NOV 2 3 2009 Stimulate 0 OthŸfj~l WaiverD Time ExAlØM[!JI. Re-enter Suspended Well 0 Anchorege 5. Permitto Drill Nw¡ber: 1fØ1ìf· ~ D . API Number: 50-029-20377-00-00 9. Well Name and Number: Plug Perforations [2] Perforate New Pool D Perforate 0 4. Current Well Class: Development !;?i Stratigraphic D "iön Exploratory Service 12-03 1 O. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool feet feet Plugs (measured) Junk (measured) 8475 None feet feet MD 30 - 110 29 . 2729 28 - 8869 8532 - 9760 TVD Burst Collapse 30 - 110 1530 520 29 - 2728.64 4930 2670 28 - 8640.43 6870 4760 8303.93 - 9530.86 8160 7020 5-1/2" 17# 4-1/2" 12.6# l-80 N-80 26 - 8290 8290 - 8413 5-1/2" Baker SAB Packer 8278 SCANNED DEC () F 2005 Tubing pressure 1520 Service GINJ D WINJ WDSPl Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 11/22/2005 , - g-ßD ;;.S" ~ Original Only Ñ e e 12-03 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY _'~11t.TEI SUMMARY 10/19/2005 OBJECTIVE: SET 3 3/8" IBP AT 8738' (SECURE WELL) TIED INTO DRESSER ATLAS 9-23-79 (COMPENSATED NEUTRON) UNABLE TO SET PLUG DUE TO PLUG NOT DRAWING CURRENT, PLUG RETURNED TO SURFACE **NOTIFIED DSO OF WELL STATUS** 10/21/2005 OBJECTIVE: SET 3 3/8" IBP AT 8752' (SECURE WELL) 6.50' FROM CENTER OF ELEMENT TO TOP, OVERALL LENGTH = 11.59' , 1.75" EXTERNAL FISHING NECK TIED INTO DRESSER ATLAS 9-23-79 (COMPENSATED NEUTRON) **PAD OPERATOR NOTIFIED UPON DEPARTURE** FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisorr'"~' ~i~13 DATE: May 7, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit Drill Site 12 Monday. May 7, 200!' I traveled to BPXs Drill Site 12 and witnessed the semi annual safety valve System testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 21 wells and 42 components with 1 failure. The surface safety valve on well 12-12 had a slow leak when pressure tested. This valve was serviced and retested by the operator on this date. Bill Preston (lead DS operator) performed the testing today; he demonstrated good test procedures and was a pleasure to work with. A walk through inspection of the well houses on this pad was performed during the SVS testing with no problems noted. All well houses inspected were reasonably clean and all equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at BPXs Drill Site 12. PBU DS 12, 21 wells, 42 components, 1 failure 2.3% failure rate 29 wellhoUse inspections Attachment: SVS PBU DS 12 5-7-01 CS X Unclassified Confidential (Unclassified if doc. removed ) Confidential SVS PBU DS 12 5-7-01 CS Alaslm Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / DS 12 Separator psi: LPS '160 " H1;S 5/7/01 i WeB Permit Separ Set L/P Test Test Test Date Oil, WAG, GII~IJ, Number Numbe~ PSI PSI Trip Code Code Code Passed GAS orCYCLE 12-01 17902301 12-02 1790320 ~¢~?~- 1790410: 160~ 150] 150 P P' OIL ~A~ 1811870!' 'i60 150 150 V' p OIL1 , , 12-05 1790550 12-06A 1920540!' 160i 150 150 P P ' OI~' 12-07A 18117~01' 160 150 140 P P OI~' 12'08B 18116'70 160 150 140 P P OIL: 12-09 18009301 160 150 125 P P OIL! 12-10A 1920890 160 150 150 P P OIL 12-11 1810730 12-12 1810830 160 " 150 90 P 4 OIL 12-t3B 1960170 160 150 '150 P P OIL 12-14A 1981460 160 150 150 p p OIL i 12-15 1830320 160 150 150 P P OIL , 12-16A 1931480 160 150 150 P P OIL 12-17 1830040 160 150 150 P P OIL , 12-18 1822060 160 150 150 P P OIL , , , 12-19 1821980 , . 12-20 1821910 12-21 1840480 ' " 12-22 1840600 160 150 125 P P OIL 12-23 1840580 12-25 1831660 12-26 1840140 ''160 150 '125 P P 'O~L ,, 12-27A 1990390 , , 12-28A 1990330 160 150 170] P P OIL 12-29 1840320 12-30 188'1420 12-31 1890010 12-32 1890110 160 150 150 P P OIL , 12-33 1890100 :12-34 1941370 i60 150 150 ' P' P OIL 12-35 1951300 160 ' 150 100 '~2-36 1951580' 160 150 150 P P 0IL , , RJF 1/16/01 Page 1 of 2 SVS PBU DS12 5-7-p4~C~S Well Permit Number Number Wells: 21 Separ Set PSI PSI Components: LIP Test Trip Code 42 Failures: Code] Code] Passed ]GAS or CYCLE] 1 Failure Rate: 2.38% I-I 00 var Remarks: Surface,,Safety Valve on well 12-12 had slow leak when pressure tested. RJF 1/16/01 Page 2 of 2 SVS PBU DS12 5-7-01 CS STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC ;~ISSION REPORT UF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 938' FSL, 44' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 1130' FSL, 1309' FWL, Sec. 17, T10N, R15E, UM At effective depth At total depth 1108' FSL, 1293' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED OCT - 4 1994 ~!~s[~ 0ii & 6as C0n~. Commission Anchor[ :~e 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-3 9. Permit number/approval number 79-41 10. APl number 50 - 029-20377 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9765 feet 9536 feet Plugs(measured) PBTD Tag @ 9141' MD (8/13/94) Effective depth: measured 9141 feet true vertical 8912 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 312 sx PF II 80' 80' Sudace 2656' 13-3/8" 600 sx PF II 2729' 2729' Production 8796' 9-5/8" 500 sx CIG 8869' 8640' Liner 1228' 7" 9760' 9532' Perforation depth: measured 8984-9009'; 9086-9106'; 9106-9116' ORIGINAL true vertical 8755-8780" 8857-8877'; 8877-8887' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @8290' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8413' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8278' MD; 5-1/2" Camco BaI-O SSSV @ 2213' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 562 2813 4883 615 ~ 2898 5055 Tubing Pressure 266 248 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended...._. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~0v0,.~ ~ ~ Title Sr. Op. Engineer Form 10-404 Rev 06' A..-., A./15/88 Date 1218/14 cc: KZ. JWP SUBMIT IN DUPLICAT~.~ 12-03 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/13/94' RIH & tagged PBTD at 9141' MD. 8/22/94: MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 25' of reperforations as follows: 8984 - 9009' MD (Sag) Ref. Log: BHCS 9/9/79. Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing, at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. NO. 8923 ~uest ~0 W. International Aiq~ort Road Company: Alaska Oil & Gas Cone Comm Anchorage, AK 99618-1199 ~ Atth: LaiTy Grant ATTN: Shenie I 3001 Porcupine Ddve Anchorage, AK 99501 9/12/94 Field: Prudhoe Bay Well Log De~cdption BL RR Sepia RF Sepia Mylar r-/,~ ~ (~ D.$. 1-6 PROD PROFILE (8-20-94)'... 1 1 ~6-c>'~iD.S. 2-13 " PERF RECORD (8-21-94) 1 1 ~"?'~ D.S. 3-1 PROD PROFILE (8-19-94) ~ 1 1 ~ D.S. 4-4 'PROD PROFILE (8-25-94) 1 1 ~'3- [~'~. D.S. 4-5A PROD PROFILE (8-19-94) 1 1 ~ ~'~3___.~ D.S. 4-29 .INJEC PROFILE (8-19-94) 1 I ~e-?~ D.S. 6.10 PROD PROFILE (8-20-94) 1 1 26 -~- D.S. 6-15 PERF RECORD (8-20-94) 1 1 _.~'~ 9-26 LEAK DETECTION (8-23-94) 1 1 v- 7 D.s. ~3 -2~ D.S. 11-24A DUAL BURST TDT-P (8-19-94) ! I ~. D.S. 11-33 DUAL BURST TDT-P (8-25-94) 1 1 ~, · ~ r" ! ~ ID.$. 12-3 PERF RECORD (8-22-94) I 1 ~ ' ~ ~ J ¥ D.S. 14-15 PERF RECORD (8-20-94) 1 1 ~/_.__~ D.S. 14-20 PROD PROFILE (8-24-94) 1 1 S !~ (~ ~' ~ Ai~lm ~11& Gas Cons, ]94 Plec~e ~ign and return o py of this transmittal to Sherrle at the above address. Thank you. DATE: Anchorage Commission GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Shenie NO. 8911 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant 1 3001 Porcupine Drive Anchorage, AK 99501 9~6~94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar -~ ' ' ~' ~ D.$. 18-11 E~RIDGE PLUG RECORD (8-14-94) 1 1 ~ {'. il- D.$. 16-03 IN,IEC SURVEY (8-13-94) 1 '" 1 ~ ~_.~__~ C~_D.S. 16-01 INJEC SURVEY (8-13-94) 1 1 ' ~/~ 3 ! - D.S. 12-28 PERF RECORD (8-10-94) 1 1 ~,2 -..~ _D.S. 12-10A PROD PROFILE (8-1~-94) 1 1 ~ -~ D.S. 12-~A ~PROD L~ ~8-12-94~ 1 1 ~V[ D.S. 12-3 PROD PROFILE(8-13-94) 1 . 1 ~ ~ ' ~ D.S. 12-1 PERF RECORD (8-10-94) 1 1 '~ ' ~Y D.S. 6-19 PROD PROFILE (8-12-94) 1 1 ~- ~ I D.S. 01-14 P~ S~NG RE,RD (8-11-94) 1 1 ~-~'~ D.S. 01-14 TUBING PUN~ER R~RD (8-11-94) 1 1 ~-~ D.S. 01-~ P~ S~NG RECORD (8-14-94) 1 1 UG O, 1994 SIGN E x'// .... _ DATE: ~ Please ~ ~d ream o~ copy of ~i~ ~n~al to S~e ~ ~e a~ve adding. ~k you. ~ ~ ~ ~ _ & Cons E-Vi~LVE DE.SI .Sat May 08 08:15:42 1993 DO_M~ .SET PRE.S.S__t/B~_ ,- FTP @ CLOSE .fP$IG): E-VALVE CLA.S._s .fA.,B., C.) ,' 200 PSIG @ _60 DEG F 150 P.SIG C COMM~_.NT.S.-. New_ .k-valve design_ post gas lift redestg~_~, CC..' ENGINEERING FILE / COORDINATOR PRB 24 (.WITH ATTA¢~.S) J.C..SMART / M.G. SHOEMAK~ PRB 2 0 (.WITS_oUT ATTA _C!!M~.__N~.~ ~ .( COVER. ONLY.) K,L, HUDSON ATO 1566 [.WITHOUT ATTACHMENT.S) STATS OF ALASKA .f COVER ONLY.) DESIUNED BY: R. T. BUBNO ~r6 RECEIVED MAY 1 0 199~ Alaska 011 & Gas Cons. Commis~ion Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. gOO East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 05/04/93 T# 84544 BP/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. _ A-11 . /,,,INJ/TEMP 04/29/93 #1 ~A-32 ~'~ULEAK DET 04/21/93 #1 PFC 04/28/93 #1 ~B-34~--' PROD-F 04/27/93 #1 ~.C-08-73'~3PRODUCTION nOG 04/30/93 #1 ~'C-l[79o~PRODUCTION LOG 04/30/93 #1 6 ~./AoPFC 04/28/93 #1 E-0275-.~3 PRODUCTION LOG 04/28/92 ~1 E-29 ~7-~3 PROD-F 04/28/93 %1 G-06 ~.1~ LEAK DET 04/23/93 %1 H-19g2-~I3PRODUCTION LOG 04/27/93 ~1 H-20~.O7 PDK-100 04/23/93 %1 N-12 ~/-/~ PRODUCTION LOG 05/01/93 %1 S-34 ~-i3~PFC 04/29/93 ~1 Information Control ~ell Records 9350.00-10062.00.ATLAS 5 " 2200.00-10332.00 ATLAS 2+5" 11414.00-11768.00 ATLAS 5 " 11500.00-12054.00 ATLAS 5 " 11500.00-12054.00 ATLAS 5 " 9800.00-10232.00 ATLAS 5 " 9500.00- 9970.00 ATLAS 5 " 1'i500~00-11680.00 ATLAS 5 " 9600.00- 9994.00 ATLAS 5 " 11950.00-12214.00 ATLAS 5 " 9350.00- 9590.00 ATLAS 5 " 11100.00-11525.00 ATLAS 5 " 9600.00-10225.00 ATLAS 5 " 9500.00- 9842.00 ATLAS 5 " 10230.00-10511.00 ATLAS 5 " Drill Site: 12 Well: 3 K-VALVE DESIGN Fri Jul 17 22:14:07 1992 DOME SET PRESSURE: 220 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 185 PSIG K-VALVE CLASS (A,B,C): C COMMENTS: · K-VALVE DESIGN TO REFLECT NEW WELL C~%RACTERISTICS SUCH AS LOWER FTP AND HIGHER PI. CC: C.P. FARMER / W.D. COOPER J.C. SMART / M.G. SHOEMAKE C.B. HURST / E.A. CAMPBELL ENGINEERING WELL FILE PRB 24 PRB 20 PRB 15 . .-. K.L. HUDSON ATO 1566 STATE OF ALASKA (COVER) DESIGNED BY: R. T. BURNO RECEIVED AUG 0,5 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O~Box 100360 Anchorage, Alaska 99510 DATE: 4-29-92 REFERENCE: ARCO CASED HOLE FINALS ~}"~/ 3-26 3-9-92 Prod Profile R~_m 1, 5" ~co Z-~ 3-34A 4-23-92 PFC/GR R~m 1, 5" Atlas ¥/-fz/ 5-34 4-24-92 PDK-IOO/GR/CCL R~m 1, 5" Aths ~-f~r 9-45 4-21-92 Perf Record R~m 1, 5" Sch ~?-~/ 12-3 3-15-92 CSN/GR Run 1, 5" HLS ~/-/~/ 13-6 4-20-92 PerfRecord Run 1, 5" Sch ~l,-z~ 13-23A 4-20-92 CCL/Perl R~_m 1, 5" Atlas Please sign and return the~ttached copy as receipt of data. E CEI V E D RECEIVED BY ._~~ ~ Have A Nice Day! Al~as C0~s. C0mmlssl0, Sonya Wallace APPROVED ATO-1529 Trans# # CENTRAL FILES ..-: # CHEVRON - --- D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PtHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO /g ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS 3-2 1-23-92 1-18-92 1-24,92 1-18-92 2-8-92 1-26-92 1-26-92 1-20-92 2-7-92 2-3-92 12- 12-18 1-26-92 13-16 13-19 2-94~2 17-1 1-~ Production Profile lam Static Temperatm'e Prod Profile Iai Pro~e Run Jeweh~ Run Prod Profile Prod Profile Prod Profile Run lnJ ProfUe ~m InJ Profile InJ Profile InJ Profile l~m InJ Profile Prod Profile Run 1, [~' C=mco L 5' Camco 1, ~' Camco 1, ~'~' ~co 1, ~ ~co 1, ~' ~mco 1, ~'&lO' Camco 1, [~' C~mco 1, [~' Camco 1, 5~ Cs_ taco 1, [~' Camco 1, ~, ~m~ 1, ~' ~co 1, ~' ~co 1, ~' ~co 1, ~ ~mco 1, ~' ~co Please sign and return the attached copy u receipt of data. RECEIVED RECEIVED BY Have A Nice Day! Sonya Wallace ATO- 1529 /APR O 1 1992. /~011 & Gas Cons. Commission APPROVED _-,~_~'__ Anchorage Trans# 9205,~-r .... # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # -EXXON MARATHON # MOBIL ' * The R~m Date on this log is 1-23-92. # PHILIJPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO Drill Site: 12 Well: 3 K-VALVE DESISN Fri Jan 03 21:07:43 1992 DOME SET PRESSURE: 260 PSIS @ 60 DES F FTP @ CLOSE (PSIS): 250 PSIS K-VALVE CLASS (A,B,C): C COMMENTS: K-Valve design to reflect increasing ~OR. Design also allows flexibility for well to produce in either LP commonline. Bench test K-Valve. CC: C.P. FARMER / W.D. ER PRB 24 J.C. SMART / M.S. SHOEMAKE PRB 20 J. M. Ralph / T. J. Brass field PRB 15 ENSINEERING WELL FILE K.L. HUDSON ATO 1566 STATE OF ALASKA (COVER) DESIGNED BY: Kara ~ Printing contents of current screen - wait for message to clear RECEIVED Alaska Oit& Bas Guns. (;on]mission Anchorage STATE OF ALASKA ALASKA ~'_ AND GAS CONSERVATION C£ '---AISSIO_.N_ ~ REPORT UF SUNDRY WELL OPERATIOBSI ; ! a 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing __ Alter casing __ Repair well Perforate X Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 938' FSL, 44' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 1130' FSL, 1309' FWL, Sec. 17, T10N, R15E, UM At effective depth At total depth 1108' FSL, 1293' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-3 RECEIVED Nov 2 § 1991 Alaska Ofl & Gas Cons. Commission ;Anchorage feet 9. Permit number/approval number 79-41 10. APl number 50 - 029-20377 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9765 feet Plugs(measured) 9536 feet Effective depth: measured 9286 feet true vertical 9057 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 312 sx PF II 80' 80' Surface 2656' 13-3/8" 600 sx PF II 2729' 2729' Production 8796' 9-5/8" 500 sx Cl "G" 8869' 8640' Liner 1228' 7" 9760' 9532' Perforation depth: measured 8992-9004'; 9086-9106'; 9106-9116' true vertical 8763-8775'; 8857-8877'; 8877-8887' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8290' MD; 4-1/2", 12.6~, N-80, PCT tail @ 8413'MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8278' MD; 5-1/2" Camco Bal-0 SSSV @ 2213' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaqe production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 0 -- 1 O52 2129 5105 Tubing Pressure 0 339 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the for~correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 77zt/R RI W/Bi:IR ~-~_' .qW .IWP DS 12-3 DESCRIPTION OF WORK COMPLETED TUBING PATCH, CTU CEMENT SQUEEZE, & REFRACTURE TREATMENT 6/15/91: RIH & set a 5.5" OD tubing patch assembly from 2997' to 3018' MD, across GLM #1. POOH. RD. 6/20/9 I: MIRU CT & Cementing Equipment. PT equipment to 4500 psi. w/seawater. Acid washed the open perforations at: RIH w/CT and fluid packed the wellbore 8984 - 9009' MD (Sag) 9086 - 9106' MD (Z4) 9123 - 9160' MD (Z4) 9180 - 9219' MD (Z4) 9229 - 9242' MD (Z4) Ref. Log: BHCS 9/9/79. Pumped 48 bbls of 12% HCI, followed by a seawater/freshwater displacement, then pumped 85 bbls of acid resistive cement. Placed a total of 61 bbls of cement behind pipe at 2500 psi, held for 1 hour. Had several breakbacks over 2500 psi. Contaminated cement & jetted cement from wellbore. RD. 10/5/91 .' Reperfo rated: 8992 - 9004' MD (Sag) 9086 - 9106' MD (Z4) Ref. Log: BHCS 9/9/79. Added perforations: 9106 - 9116' MD (Z4) I 0/7/9 I: RIH w/CT to tag bottom, then pumped 5 bbls of sand slurry containing 1900 lbs of 20/40 mesh sand, to isolate the lower squeezed perforation intervals in the well. Tagged top of sand plug at 9140' MD. RD. I 0/8/9 I: RIH & tagged the top of the sand plug at 9127' MD. 10/11/91: MIRU & PT to 9000 psi. Pumped a Propped Fracture Treatment, using 12/18 mesh & resin coated proppants, through the open perforations above the sand plug (listed above). Pumped: a) 423 bbls Pre Pad, followed by b) Shutdown. ISIP @ 1966. Resumed pumping: c) 360 bbls Crosslinked Pad, @ 45 bpm, followed by d) 410 bbls Cross Linked Slurry, w/proppant concentrations of 1 - 10 ppg, followed by e) Shutdown. Placed a total of 77,000 lbs of proppant into the formation. Rigged down. 10/14/91: Performed a proppant fill cleanout to 9183' MD. RECEIVED Placed well on production & obtained a valid production test. Iq OV 2 5 3991 Alaska 0il .& Gas C0[ s. Commissi0 A ch0rage P ~ O. BOX i ~-~1_ ~ ~ K A. ANCHORAGE: · ...... ~79~i DATE' i 6,-9-9i REFERENCE' ARCO CASED HOLE FINALS-' ~i-'~i~1- o ?'_-Z2 9-~.~-9i GR RUN ~.o13~/. o ~.-~a '7-i S-9i DSN RUN ~1- o~ ~-oS-3(~, S;'--3~,--?~ SEGMENTED BOND/'Gi.</CCL RUN ~5-~-o9-33 9-24-9t VERTILOG (9 5/8' CASING) F:UN ~. ~a5~'¢9-S5: i6,-3-9i VERTiLOO (9 5/8' CAS1Mb) KUr~ a~%.o/ t .-i 9-28-9t F'ERF I<UN i i ,~..,~2-9t . COLLAR-PERF RUN ~o_ oo~'oi i-')~ 9-28-9i COLLAR-PERF RUN dq ao~;-oi '-S i6~-4-9i F'ERF RUN PLEASE SIGN AND REi'UF,'N T~E ATi'ACHED COF'Y_A,S_F~CEIF. i'iC..OF DATA, HAVE A NICE~I)AY!// / Alaska Oil & Gas Cons. Com, ~)f~.R~_.~ Anchorage ,..~ ATLAS HI_S ATLAS Al A'TL. AS $ C iq A TI_AS ;~' CI..I DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON F'B WELL FI:LES D & M R & D EXTENSION EXPLORATION $ BPX EXXON ~- STATE OF ALASKA MARATHON TEXACO MOBIL ARCO ALASKA, INC. F',O, BOX ANCHORAGE, ALASKA 995.¢ "'DATE' 9-6-9t REFERENCE' ARCO CASED HOLE FINALS i-9- 8-i7-9t PROD F'ROF:ILE 2-5- 8-8-9t TEMPERATURE 2-n6 8-8-9t PROD PROFILE 8~\ "'u~q~ --'5-35.-. 8-5-9t GR-COLLAR 4-2%- 8-i e-9i F' T_ l'S ,,~\ .0,-~\--5-~2- 8-i e-gl JEWELRY vv." '~ 7-7A-- 8-9-9t PROD F'ROFILE 7-t 6'-- 8-4-9t TEMPERATURE 7-2'? 8--t 8-9t PROD F'ROFILE 7-28- 8-t -9i TEMPERATURE 7-29- 8-S-9t F'ERF BREAKDOWN/HF'FM/TEMP 9-6- 8-2-9i LEAK DETECT 9-9' 8-t 9-9t PITS 9-t7-- 8-4-9i INJ PROFILE tt-2- 8-9-9t INJ PROFILE t t-9-"' 8-4-9t LEAK DETECT t t-24-' 8-4-9t PIT~/FIF'FM t2-S.., 8-t4-9i LEAK DETECT i ,~.-8B" 8-9-9t PROD PROFILE * tS-S- 8-tt-9i PROD PROFILE iS-tt-' 8-ii-9i PROD F'ROFILE !S-i2- 8-i5-9i PROD F'ROFILE tS-i4- 8-i6-9i PROD F'ROFILE t4-2S"- 8-it-9i PROD PROFILE t~-25;'-- 8-t4-9i F'ERF BREAKDOWN TREATMENT I6-i- 8-i6-9t INJ PROFILE t8-3-- 8-i6-9i LEAK DETECT RLJN i RUN RUN i RUN RUN t RUN RUN i RUN RUN t RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN t RUN RUN i RUN i RUN t PLEASE SIGN AND RETURN THE ATTACHED HAVE A NICE DAY! SON'fA WALLACE ATO-t ,o COF'Y AS RECEIF'¥ OF DATA APPROVED 'I'RANS~ 9 , 5' CAHCO ~' CAMCO , 5" CAMCO , 5' CAMCO , 5' CAMCO , 5' CAMCO ~' CAMCO , 5' CAMCO ~ ' CAMCO , 5' CAMCO , 5" CAMCO , t'&5' CAMCO , 5' CAMCO , 5' CAMCO , 5' CAMCO , 5' CAMCO , 5' CAMCO ~' CAMCO , 5' CAMCO , 5' CAMCO , 5' CAMCO ~'&5' CAMCO , ~. CAMCO , 5' CAMCO , 5' CAMCO , 5' CAMCO ~' CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D - BF,~. '" STATE OF ALASKA '11' TEXACO * "['FIE CORRECTED AF'I~ FOR i3-3 IS 5~')-(~29--2¢,''°~,3.._, ARCO ALASKA, INC. F'.O· BOX t00360 ANCHORAGE, ALASKA 995t DATE- 7-26-9t REFERENCE: ARCO CASED HOLE FINALS 2-t2 6-29-9i PROD PROFILE 3;-33: 6-26-9t PROD F'ROFI'LE 9-2 6-t 9-9t LEAK DETECT ~:w/~9- 38 7-i-9t INJ PROFILE t2-:5 6-i5-9t COLLAR LOCATOR i 4-:5i 6-t 5-9i F'ERF LOG i 4-:5-/ 6-i 0-9i PITS i 5-6 6-28-9i PITS t 8-i 4 6-24-9i PITS RUN i, RUN t, 5' RUN t, 2"&5" RUN t, 5" RUN t, RUN t, 5" RUN t, RUN t, 5" RUN i, 5' RUN i, 5' RUN i, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. HAVE A NICE DAY! SONYA WALLACE AT0-t529 AF, F, ROVED__~/''~'~ TRANS~ 9t~27 CAMCO CAMCO CAMCO CAMCO CAMCO HLS HLS HLS HRS CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FII. ES R & D BF'X STATE OF ALASKA TEXACO 8£CEIvED JUL 2 $1991 41aaka 0il ~, Gas Cons. AnChorage Commission ARCO ALA:¢KA, INC. F'.O. BOX i~}OS60 ANCHOR'AGE, ALASKA 995t 0 DATE' ~J--9-90 REFERENCE' ARCO CASED HOLE FINALS J-8 ~O-J7-90 INJECTION PROFILE 4-J J~5-28-90 PERF RECORD 6-t 6 ~ i -4-90 COLLAR/PERF 6-24 i O-i 7-90 F' I T.? ~2-3 t~-t8-90 PRODUCTION F'ROFILE i2-8B ~¢,-25-9~ LEAK DETECTION i.~-~ i ~-i 8-96, F'M I'EMP i 4-S i i O-i 7.-9,:.~ TEMF' i5-2 i0-i7-9~, F'RE-FRAC PITS i 5-2 i i -i -9~ CCL/PERF i5-2i i~-i6-9¢, F'RE-FRAC. SURVEY PLEASE SIGN AND RETUR RECE]]VED BY HAVE A NiCE DAY! SALLY HOFFECKER ATO- ~ ~.~o RUN i, RUN t, RUN i, RUN i, RUN i, RUN t, RUN i, RUN t, RUN i, RUN t, RUN ~, N THE A'FTACHED COP'¥ AS RECEIP[ OF DATA. APF'F;:.O VE I) ~ . !"RAN2.':-~ 9"-.")~:39 I 5 ' 5' 5' 5' 5" 5' 5' 5' CAMCO $CH ATLAS CAMCO CAMCO CAMCO C A ~q C 0 CAMCO C A M C O Al'LAS CAMCO DISTRIBUTION · CENTRA~ FILES CHEYRON DaM EXTENSION EXFLORmTION EXXON MARA]'HON MOBIL · "~ F'FIILLIPS F'B WELL. FI;LES R & D ~- BPX STATE OF AI_ASI<A TEXACO RECEIVED NOV 1 1990 Alaska Oil & Gas Cons. Commission Anchorage PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drillsite-Well: 12-03 Date: 1 2/2/89 Comments: Liquid rate has been decreasing since running the last design. Gas lift behavior had become more unstable and was causing the previous K-valve to dump. Previous K-valve Settings: Production Data: ROR = 650 BOPD CFR = BOPD Swing Well (very high or Iow GOR) .............. No Design Parameters: Design parameters are based on (Mark one of these) XXX Oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR Flowing Tbg. Pressure Flow. Wellhead Temp. Set Pressure, psig Date 250 9/24/89 270 1 0/4/88 @ 90 deg. choke @ deg. choke Choke Priority Well ..................... N3 Actual Well Test ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... Theoretical Rates used with Hydraulics Program If hydraulics program was used of the parameters, mark which program... 650 BOPD 8 6 percent 2525 scf/stbo 3000 mscfpd 900 scf/stbl 250 psig 160 deg. F Temp. @ SSSV ............. Pressure @ SSSV ....... Pressure Adjustmen to get some xxx PH2 PH3 PRUDHYD Other 1 73 deg. F 400 psig 75 psig Calculated Dome Set Pressure = 189.0 psig @ 60 deg. F IActual Dome Set Press. 190 FTP at K-valve Closure = 175 psig @ 60 deg. F psig @ surface cc: Fem~son / Farmer ~i~le~=~Kennedy (2 copies) State of Alaska cc: D.$. Engnr. Dan Kara ATO 1562 D.S. Supvsr. Montgomery / Hurst Prepared by Scheidt 1 t 19 9 Nas~ Bit & Gas Cons. Comm~so,J~ Anchorage ARCO Alaska, Inr' Prudhoe B.. Jngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 5, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-3, Approval No. 9-498 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/TPA/jp Attachment CC: J. Gruber, ATO-1478 PI(DS 12-3) Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK "')IL AND GAS CONSERVATION C'-"',IMISSION , REPOR'i OF SUNDRY WELL OF,-'RATION, 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 938' FSL, 44' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 1130' FSL, 1309' FWL, Sec. 17, T10N, R15E, UM At effective depth At total depth 1108' FSL, 1293' FWL, Sec. 17, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-3 9. Permit number/approval number 79-41/9-498 10. APl number 50 - 029-20377 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9765 feet Plugs(measured) 9536 feet Effective depth: measured 9286 feet true vertical 9057 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 312 sx PF II 80' 80' Surface 2656' 13-3/8" 600 sx PF II 2729' 2729' Production 8796' 9-5/8" 500 sx CI 'G' 8869' 8640' Liner 1228' 7" 9760' 9531' Perforation depth: measured 8984-9009'; 9086-9106'; 9123-9160'; 9180-9219'; 9229-9242' true vertical 8755-8780'; 8857-8877'; 8894-8931'; 8951-8990'; 9000-9013' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8290' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8413' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8278' MD; 5-1/2" Cam~)I~1~.,, :1~'S~~'~3' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 714 3291 5741 1092 5009 5990 Tubing Pressure 268 261 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x..~. Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 P~R T P AIInn PRR-4RR7 Title Operations Engineering Manager~ TREATMENT: OBJECTIVE: INTERVALS: TREATMENT DATE: . . . . . . . . 11. 12. Drill Site 12-3 Description of Work Performed Sag River Fracture Treatment To Stimulate the Sag River Formation 8984-9006' MD (Ref. BHCS 9/9/79) August 2 to August 28, 1989 Perforated Sag River interval 8984'-9009' MD referenced to BHCS log dated 9/9/79. Replaced gas lift valves with dummy valves. Loaded annulus with fluid. Tested annulus to 2500 psig. Isolated Ivishak perfs 9086'-9106', 9123'-9160', 9180'-9219', 9229'-9242' MD with an inflatable bridge plug and 6' of calcium carbonate pill. Tagged top of pill at 9051' MD. MIRU fracturing service company Pressured annulus to 2500 psig. Pumped propped fracture treatment for Sag River interval from 8984' to 9009' MD using gelled water and Carbolite proppant at 20 BPM. a. 100 bbl formation breakdown and shutdown for ISIP b. 39 bbl pump-in/ shut-in c. 250 bbl Pad d. 184 bbl Slurry at 2-14 PPG (42,000# of proppant was pumped into the well and 40,300# was placed into the formation) e. 215 bbl Flush RDMO fracturing service company. MIRU slickline unit and tagged fill at 8977' MD. Cleaned-out proppant and sand with CTU and spotted 10 bbls of HCL to dissolve calcium carbonate pill on top of inflatable bridge plug. Pulled inflatable bridge plug. Returned well to production and obtained a valid test. ARCO ALASKA, INC. F'.O. BOX t~(:':')36~ ANCHORAGE, ALA%'KA 995t0 DATE' 8'-tl-89 REFERENCE' ARCO CASED HOLE FINAL~ 7-i 7--29-89 PRODUCTION PROFILE RUN i, 5" 7-i2 7-28-89 PRODUCI'ION F'ROFILE RUN t, 5' 7-23 7-30-89 PRODUCTION PROFILE RUN i, 9-8 7-26-89 INJECTION PROFILE RUN t, 5 i2-3 8-4-89 PERF' RECORD RUN i, 5' t2-7A 8-4-89 PERF RECORD RUN i 4-36 7-29-89 INJECI'ION PROFILE RUN ~5-~t 7-3t-89 PRODUCTION PROFILE RUN ~, 5' t7-8 7-27-89 INJECTION F'ROF'ILE RUN i, 5' PLEASE ~$IGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. CAMCO CAMCO CAMCO CAHCO SCH SCH CAMCO CAMCO CAMCO RECEIVED BY _ HAVE A NICE DAY! C ~ ATO-~ Anchorage DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXI'ENS I ON EXF'LORAT I ON ~.,. BF'X EXXON ~ ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager June 9, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-3 Permit No.79-41 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/RAC/jp Attachment J. Dietz, BP J. Gruber, ATO-1478 PI(DS 12-3W1-3 ConS. Com~'m~'ton ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA · ALASKA _AND GAS CONSERVATION CC ,,IlSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 938' FSL, 44' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 1130" FSL, 1309' FW, Sec. 17, T10N, R15E, UM At effective depth At total depth 1108' FSL, 1293' FWL, Sec. 17, T10N, R15E, UM Operation shutdown Plugging ~ Pull tubing Vadance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate Other X 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-3 9. Permit number 79-41 10. APl number 50 - 029-20377 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Surface 80' Intermediate 2656' Production 8796' Liner 1228' 9765 feet Plugs(measured) 9536 feet 9286 feet 9057 feet Junk(measured) Size Cemented 20" 312 sx PF II 13-3/8" 600 sx F II 9-5/8" 500 sx CI 'G' ,, rr.D Uaska 0il & Gas ConS. c0mmiss n Me~~pth True vedical depth 80' 80' 2729' 2729' 8869' 8640' 9760' 9531' Perforation depth: measured 9086-9106'; 9123-9160'; 9180-9219'; 9229-9242' true vertical 8857-8877'; 8894-8931'; 8951-8990'; 9000-9013' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8290' MD; 4-1/2", 12.6#, N-80, PCT tail @ 8413' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8278' MD; Camco Bal-0 SSSV @ 2213' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved Oil ~ Name of approver Date approved Service 17. I hereb~certify that).~e foregoing is true and correct to the best of my knowledge. Signed 2~::~ ~~~ Title Operatiorls ErlgineerJrlg Manager FOR COMMISSION USF ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Date ~///'~'/~"~' 15. Status of well classification as: Gas Suspended Approval No. ~ ~~-,~;;~ ~-,'~/-/- _~o,~,,a 009'/ Commissioner Date Form 10-403 Rev 06/15/88 004 R. A. Clatmen. 2RR-4BRR SUBMIT IN TRIPLICATE . 9. 10. 11. , Drill Site 12-3 Proposed Hydraulic Fracture Treatment ARCO Alaska Inc. proposes the following hydraulic fracture Procedure. 1. Perforate Sag River interval 8984'-9009, MD referenced to BHCS log dated 9/9/79. 2. Replace gas lift valves with dummy valves. Load annulus With fluid. Isolate Ivishak Perfs 9086'-9106,, 9123'-9160,, 9180'-9219,, 9229'-9242, With sand slurry PUmped fullbore. Tag top of sand with wireline. MD MIRU fracturing service COmpany Pressure annulus to 2500 psig. Pump ProPPed fracture treatment for Sag Riv using gelled water and 16/20 :,~.~, ,,.,_.,_ _,. er zone from m~o, ',-,a~uoli~e ProPPant. 8984' to 9009' a. 100 bbl formation breakdown b. 40 bbl Pump-in/ shut-in c. 250 bbl Pad d. 180 bbl Slurry at 2-14 PPG e. 215 bbl Flush MIRU slickline unit and tag fill. ~JUg J. 2 ]gS~ Cleanout proppant and sand With CTU to 9280' MD. Alaska 0il & Gas Cons. Commission ''. /~nchorage Return Well to Product/on and run spinner log to determine Sag River contribution. 6 5 4 3 2 COILED TUBIN9 UNIT BOP EOU 1P~EN~ 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 2 IdIREL]NE BOP EOU]PMENT 1. 5000 PSI ?" WELLHEAD OONNECIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF PRUDHOE BAY FIELD K-VALVE DOME SE'ri'lNG PRESSURE DATA SHEET Drillsite-Well: 12-03 Date: 11/1/88 Comments: Well would shut in at just above commonline pres with the design dome pressure of 270 psi. Tubinq pressure is swin~incj 200#,. well heads severely due to malfunctioning of ~aslift design, This K-valve design will work temporarily until gaslift design is replaced, Previous K-valve settings: Set Pressurer psig Date 270 1 0/4/88 Production Data: ROR = 900 CFR = Swing Well (very high or Iow GOR) ........... Oesi~3n Parameters: Design parameters are based on (Mark one of these) XXX oil Rate Watercut Formation GOR Gas Lift Gas Rate Total GLR FlOwing Tbg. Pressure Flow. Wellhead Temp, 991 85 800 3000 634 288 160 90 .deg. clx)ko deg. clx~e Choke Priority Well .................. Actual Well TeSt ..... Date of Test ...................... Flowing Press. Survey ...... Date of Survey ...... TheOreticai Rates Used with Hydraulics Program If hydraulics program was used to get some of the parameters, mark which program ... percent scf/stbo mscfl:x:l scf/Stbl psig dsg. F XXX PH2 PH3 PRUDHYD Other Temp.@SSSV ..... i ....... 171 deg. F Pressure @ SSSV ....... 515 psig PreSsure Adjustment 1 90 psig Calculated Dome Set Pressure = 1 89.0 Psig @ 60 deg.F IA~tUai Dohte Set Press. FTP at K.valve Cl'osur'e 190 180 psig @.60 deg. F I psig ~. surface I cc: Sennett / Zibell Wilder / Kennedy (2 copies) State of Alaska · cc: D.S, Engnr, John Scheidt ATO 1566 D,S. Supvsr, Collins / Hurst PRB #15 Prepared by:M, Brown/R, Krause ~ '. ,. ~. , .'., ~.~ ~ - ARCO ALASKA, INC. P.O. BOX i0G36'9 ANCHORAGE, ALASKA ¥~5t0 DATE' i~-i0-88 REFERENCE: ARCO PRESSURE DATA i-i i(}-24-88 BHP--$TATIC GRADIENT t-t9 ~(9-2B-88 BHP--3TATIC GRADIENT 2-4 ~q)-24-88 BHP--$TATIC GRADIENT 4-~7 ~0-~2-88 BHP--PRES'SURE FALL-OFF 4-3~. 9-2~ -88 BHF'--$TATI C GRADIENT 4-32 9-2~ -88 BHP--$TATIC GRADIENT 5-~ ~ t0-i~-88 BHF'--$TAI'IC GRADIENT 5-~J t"'J-~9-88 BHP--$TATIC GRADIENT 5-~'3 ~0-~9-88 BHP--~'TATIC GRADIENT 6-~7 ~,:3-~(}-88 BHF'--~TATIC GRADIENT 7-2 ~(3-9-88 BHP--$TATIC GRADIENT 7-8 ~-9-88 BHP--$TATIC GRADIENT ~ '~ ,.--, ~ 9-~ i ~D-~-o_ BHF'--FLOWING GRADIENT 9-2? 8-28-88 BHP--$TATIC GRADIENT 9-3~ 8-28-88 BHP--$TATIC GRADIENT i2-7 i~:)-i4-88 BHF'--FLOWING GRADIENT i2-6_4 tG-i:3-88 BHP--FLOWING GRADIENT i 2-i (-) i (:)-i :2-88 BHF'--F'LOWING GRADIENT i°-°~. - . i~'-i9-88 BHP--$TAI'IC GRADIENT i ._'3-i i i (9-6-88 BHF'--$TATIC GRADIENT i3-26 I~-6-88 BHP--$TATIC GRADIENT i3-28 i~-6-88 BHP--~TATIC GRADIENT i4-i~-J 7-tG-88 BHP--F'LOWING GRADIENT i4-'13 6-3(9-88 BHP--$TATIC GRADIEN]' i 4-~ '7 i ~-'2~3-88 IJHP--~I-A'[IC GRAD!~_NT i 4-t 8 i £:'-~' F-:~' ~-~o BHF .... ~'TAi" I C GRADIENT i 4-32 i '9-7'-88 BHP--I{TATIC GRADIENT i 5-7 i (9-8-88 BHF'--~'TATIC GRADIENT t5-i'9 iG-9-88 BHP--I~TATIC GRAD£ENT i5-i5 i(9--8-88 BHF'--&'TATIC GRADIENT i5-i9 iF)-8-88 BHP--~TATIC GRADIENT i5-22 t(9-i7-88 BHF'--&-'TATIC GRADIENT ~5-25 i(9-2G-88 BHP--~TATIC GRADIENT 16-7 i0-22-88 BHF'--FLOWING GRADIENT F'WDW3-i i(9-i3-88 BHP--~TATIC GRADIENT I-~_EM~E SIGN AND RETURN THE ATTACHED COPY A~' RECEIF'T 01::' I VED BY__ . ATO-t 529 , ,~: ~l~i~,lc~orage TRAN$ ~88642 gF'F'~OVE~__ O I ~7'FR ! BU'I- ION u,...,-~ I RAL F iLE;~' f- ;::'HII._I...]:F'.? D & M -~ R ~ D EXTENZION EXPLORATION ~$ ~AF'C EXX;]N .~ ~'i'ATE OF AI_A:;KA MARATHON ~ TEXACO MOBIL CAMCO CAMCO CAMCO CAMCO OTIS OTI~ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DATA~ ARCO At_A,S-'KA, INC. F' 0 BOX .,, ~. Ai,.~C:HC)RAGE , ALA~:KA DATE' 'i 'i -~ '3,-88 RE"FEF;.:ENCE' ARCr2, CA:g'ED HOi..E i-':'iNAL3' m 2-.3 '~. '~. ....... ,_, ,._,,.., CNL-6-Ai'~MA "2-4 ! ;.:;,-24-88 CCi.. · '? 9 i '~ "~ '='"": F.'NL-[;AHMA · 2-i 8 ? !--3-E:8 CNi_-(.:,-AHi'iA · 4 ..... i i ¢- 'i 4- i~'.- 8 F' F.: 0 D U C T i 0 N F' R C) F i L. E '' 4-i i i--5-;:38 CNL-GAHHA ...,..,; .... .a. i i ._~:_, ,.......°°:.: C NL- C-A H H R ~' 4---i 5: i 0-i :.3-.--F35 INJECTIOi".-!.' F'F;:.r3F'ZLE: '~ - i .... i ,"-", --- 4 2 - S 8 i i',.i, i [ii r':-[' T 0 N F' F;-: 0 F' T i ~ "",' i" -,..- ~ -.,,- -. 4. 4. 1.. ~.. · 4--':2'? 'i 'i-4-88 CNL.--L,-AHH;:'~, · 5-..7.:: i 'i-- 2.-- 8iii CNL---:''' ': '.4'' '*. :.~ r~ r, r'i ~.~ ' "'-'i 3: i i-2-::38 ,-'-:,.i~ :..,l-,:_- G Ai-"iH A . ~ '-'.:-:' .... 25 i 'i -.5-88 TUi=.-~INC- CUTTER ~ ,..;, ._.-z ,--._, ..., .~,n_,i,, ...... A.-R8 F' t:;.'. O"Z:, U C ]" l ["~~,i F' i:;:~ ~= '[ E E- (:.7, A H N A 'i '2->'; I (-}-i.' .4--8L:~ F'F.".C)DUCTI_'Oi'.,!. F'ROFILE ,S'LJi:;.'."',;E"i"' · i 2-.6 'i (:;,-i ,3-88 F'F.'.ODUCT!:.r-~N F'RUF'iLP: · ~ 2-'i (-) i (')- i 2---8 r-'i: F" :[ T ii..' · i 4-i 3 'i ,3,-'i 5---Ei::3 iNJECTiON F'RUF']'-LE · !-4--.7,7 i (:;,-~ 'i ---E'..8 CBT · i, 4-:37 i -9-3i ---88 C.E"i' ~' i 4---:38 i ()---L=', i -..:f.-.'~Ei; CBT · i ,,'~ .--",". -'.:' ,i ;:; - :3 ,i'-- 8 :.-3 .,"-i::' "1- ._. -r .., .-._, , .~. . , ,-... · 'i 5:-25: ~ ,:.:.:,- 2C:,....88 CCL-GAHHA I1! 6-7 i ;3 ~-2':2-RC.: F'R-"/] DUC; f' :1: ON F'RUF' :!; LE ~ i 8-2 i ;.-:;_.,::,--z._..::::.c:.. r'["-~ · ..- ¢... -.-. ;. --.~,; ,.~- ~ '"~ '-- I I '"2 ...- I ............. · t-[A-IL:'wo-i i ;:i .... ..i :5'-8'..d L-,A~f'IA I:;.:AY RECE I F'T I:,:UN i , i:,..' U N i , RUN i, I:;:.U N i , I:;,'tJN i, R t.J i'.4 i, R (J i:J. i, F;..'tJ N i , F;.'.tJN i , F;.: LJix.I i , F:..'tJN i , I:;.'. LJ iq i, RtJN i , F;.:UN i, R UN i, RUN i , i-,,'tJN i, I:;..' lJ i'-,! i, RtJN i , 17U N '~ , i';.'.UN i, F.:tJ Ni, F(Uf'.ii, R. UN t , I:;.'.[JN i, DA"f'A ,. R E C !-'-'; ! V E D B Y HAVE A NiCE DAY'! ;TAL..LY HOFFECi<'. lei;.'. ~;' ,4. 7 A F:' F' i:;.'. 0 ".-" E D D I ~?'i"R :i: B U 'F 11'.3 ix! ~ CEN. TF::A L. F' I L E,:7 · 11: C H E V F,.: 0 N EX-i-E?-.'.;;,'." .[ t"JN EXF'i_(]i:,.'.A i" i ON E: X X r3 N H A R A T i40 N :',l: H 0 5 :[ l.. ¢,: F'H I I.. L. I Fl ,? F'E: WEI_L F'l.[ki::,~' F:.: & .[:' :~',: ;~ A F' C :i ~-/TA'i"F iii;-' f::ii....A,?i<.f;:'i -ii: 'f'E X A C (] bATF. ?-~9-RR Fcr.:FFR'FNr:F' ~l:~'r:l'l I': ¢, .'<,' F' "f:, FIRI F:' F'l'ig¢~l.. ~-74 '-/- t ~-RR Fi. Fll I ~R / F' F R F F'IF;."¢, T T FIN F¢IIN '7-R '7-~ %-AR £1'111 ¢~R'/F'FF-,.'FI1E'ATTFIN ?-.'"4 -/-'i A-RR F'F-,."FIDIIF:TTFIN I Fir; R'IIN ?-'S ?-'i A-RR F'R'FI'DIIRTTFIN I F1F, ['lin .4-'~. ?-'! ~-RR F"F,'flDIlCTTflN I FIR F;.'IIN F'I .F.C~.~F RTF~N ¢,NI'D R'FTIIF-..'N THF ,~TTC, F'.HF'D RF1F'Y ¢,.~' R'I--Fi. FTF'T I"IF'- R'FRFT VF'D ~.Y__ __ F'F¢;RY :'NNF-. TT ' , ............... .-: ....... _ ~,Tfl-t ~79 DTRTRT~llTTn~ !:;.' I l i:.! 'i ':;" AI-~'.C(] A I..A,:~ I. A, ]' NC. '~'-- ' P.,O, -BRX ~-.O(-~:z. 60 A N C I-I 0 I:~.'. A .G IZ, A l.. A 2 K A' 9 9 .?; t 0 .R C I..I I:;,' E C E I V E D .t-.'.: Y .............................................. · H A V I'.E A N ! C I!i: D ~.:-, Y ! F:' E G I':; Y ~ I...-. N N Iq T '1" ATO ....I '.:.!;29 & Gas Cons. C, ommisslO~' F'~O~ ~,ox i Anchorage, 995~ DATE: May ~4, ~987 I~£FERF--NCE: ~RCo. Fres$.re Data 2-iA 4-~8-87 Static [,radient " Camco 2-ti 4-i8-87 Static Grad;ertl Ce~o 2-3 4-.~9-87 Static Gradient Camco ~~-8 4-9-87 Static Gradient Camco ~t4-t6 4-17-87 ~tatic Gradient Camco 5-.~S 4-26-87 Static Gradient Ca~o F'l. ea:~e ~:ign and return the attached copy a~' receipt of data, Received By ~.,~~~, ~A...,,'~~, ~.,. ~- ~/. ~-.~=~ L'~,. '~ ~ HAVE A NICEr. DAY! ~~~ Rosa nne F' laslm Oil & Ga~ C0~. c0mmiss~0~ A'Ffl- i 529 ~nchqr~no Approved DI,.~TRI BU'FION · '~ F'h i I. [ i p~ Central. Fi I.e~' ~,. Chevron "~ .... '.'-:', ~ F:'} l.e$ :U: I) & M '"'~.R & I) Exten:s i on Exp [o;-a'l: i on .~ Sohio =I;: Exxon ..- $.ate of AI.a~ka Herathon ~ Texaco · ,.'"' Hob i [ ARCO ALmskm, inc F'~O. Box t00360 Anchormge, A[mska 995i 6., DATE' August ii, i986 L.u L:a sed 3-i 6 7-.-4~ _o~ I'n i ~c ,-!:-. i o',:'-., P'.,-o'" i 1 ,=, r,'u-n " "-" -- :,--' '--' I'4 _ i _ . _ ! .,.. 6-i i I '~ '~ ,-'c-'- ,_-- I Log pi-~ sq. ueeze o ,'-, --" ~:'-- ~-, Ui'~ ---' - F'erfr, ra* l!lq nl-d i ~ ' i~'-'~. ._. ~2-i2,_.._-~' ' ,~'~r ~' -- - : _ _ _ .r~ u. i ! . .5' i2-I0 i2-I" '~ - - . .---o_:- F'e'r to'fa f i nq Record ,q..'un i 2;" · - , ,' i "' t ,~_o=: --- [e* ,q,'~,r ,q,'un · "- . ~ -'..:-, ¢-Oi~/p : ; 01] Of-ri I r..- · ~ '-:,._~.4 '! "-' ~ .'- ,...- , ~- ,~-,.j Cnmpletion Recnrd Pun i '=" 1 2--28 I.-'~-i_:--or ~'5 Cnmp Le*; i on Reco'r d Run I :'" i~-i5 i'*-I~-°~'.- - ~,-, Perfora*i'ng R_~co'rd,- Run 2 ~-" -.-- I 3-~. ? i ,_?-?n-°~'~- ,_,_, ,°-='-._, f . and RFF'er_ i--, Run I S · i6-7 ii,_.~-85 CET ~og Ce.,.'~en+. Eva[ log Run. I _,~". I:' !._~:.~ si:.~ nd i('rrr' er '~j-~/'=~'' ' h~d .............. mo- *= i-mreiof of d-*a .-- , ................ .... Linda Hu[ce TRANS-. SR6a~-'8_ ..-,~. ,'!,' (: h Sc h ."': c h .";-'ch Sch ?ch L," c h Sch S (: h C,=nf. i-a F i I '..-- i i :_~.' ".-: '_-' F--x~ens o'..--., Exp~o',.-atior, ' '" XOi] ~a'ra +.hon Hob i [ F'"-'.: ~e :.'_ i. ---"-' ! ."-~ F-.' L T': ~ S:oh ia '-~--'$tnt8 of Alaska ~ ~ E' X .a C 0 ARCO Alaska, Inc. Prudhoe Bay ,..,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 13, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-3 DS 12-4A DS 12-5 DS 12-7A DS 12-9 DS 12-10 DS 12-14 DS 12-16 DS 12-17 DS 12-21 DS 12-28 Permit No. 79-41 Permit No. 81-187 Permit No. 79-55 Permit No. 81-175 Permit No. 80-93 Permit No. 81-53 Permit No. 81-138 Permit No. 83-11 Permit No. 83-4 Permit No. 84-48 Permit No. 84-31 Enclosed are the "Subsequent" Sundry Notices and Completion reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/TAB/vh Enclosure cc: SOHIO Alaska Petroleum Co. File PI(DS 12-3)Wl-3 Pi(DS 12-4A) W1-3 Pi(DS 12-5) Wl-3 PI(DS 12-7A) W1-3 PI(DS 12-9) Wl-3 Pi(DS 12-10) W1-3 PI(DS 12-14)W1-3 PI(DS 12-16)W1-3 PI(DS 12-17)Wl-3 Pi(DS 12-21)W1-3 PI(DS 12-28)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE L~3~] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 Su£f~e: 4. Location of Well 938' FSL, 44' FEL, Sec. 18, T10N, R15E, UM At Top Producing Interval: 1130' FSL, 1309' FWL, Sec. 17, T10N, R15E, UM At Total Depth: 1108' FSL, 1293' FWL, Sec. 17, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 73' RKB 6. Lease Designation and Serial No. ADL 28330 7. Permit No. 79-41 8. APl Number 50-- 029-20377 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-3 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~X Altering Casing [] Stimulate [] Abandon [] Stimulation [] Aba ndonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating, operation 12-12-85. RU perforating unit, pressure tested surface equipment RIH with Gun #1. Shot 9086-9106. 4 spf flowed well to clean up. RD. 12-12-85. Ref: BHCS 9-9-79 14. I hereby,~certify that the foregoing is true and correct to the best of my knowledge. Signed ....... . _ _ Title The space below for Commission use Conditions of APproval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 ---7-',, ,~ -~, ,,- / ~,~-~ / "'~. STATE OF ALASKA "~- ALASKA (~ _ AND GAS CONSERVATION CO:. AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG __ 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-41 3. Address 8. APl Number Post Office Box 100360, Anchorage, AK 99510 50- 029-20377 4. Location of well at surface 9. Unit or Lease Name 938' FSL & 44' FEL, Sec.18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1130' FSL & 1309' FWL, Sec.17, T10N, R15E, UM DS 12-3 At Total Depth 11. Field and Pool 1108' FSL & 1293' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet {indicate KB, DF, etc.} 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 73' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 116. No. of Completions 8/14/79 9/13/79 9/21/79' (3/11/80 perf]' N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9765'MD,9536'TVD 9286'MD,9057'TVD YES ~( NO []I 2213 feet MDI 1900' (aoorox.)_. 22. Type Electric or Other Logs Run Cal, DIL/SP/FL/GR~ accoustic GR~ CDL/CNL/GR, DIL/SP/BHCS/GR, SPC/CNL/Cal/Gr, TDT/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 9M~ H-40 Surface 80' 30" t19 ,w Pe_rm_._afre_~t II te surface 13-3/8" 72~ N-80 Surface 2729' 17~,' 60~ .~× Pprm~rm.~ TI 9-5/8" 47# L-80/ Surface 8869' 12~" SOd .~ c1~.~ ,,c.,, S-95 7" 29# 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9123-9160'MD 8821-8858'SS @ 4 spf 5~" 8/'1~' 8278' 9180-9219'MD 8878-8917'SS @ 4 spf 9229-9242'MD 8927-8940'SS @ 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED '9086-9106'MD 8784-8804'SS @ 4 spf N/A * added on 12-12-85 Ref: BHCS 9-9-79 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 3/19/80 Flowing Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO 3/31/80 5.4 TEST PER IOD ~ 2036 1449 ~ n~ 29° 712 Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 832 -- 24-HOUR RATE 9047 64,39 4,66 ?7 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED N/A ~ ~; iki ~ Z~ '~98(~:' · Alaska Oil m Gas Cons. Corn.m..tssiu~ Form 10-407, Note: Well was recompleted 7/5/gEo~iTiNUEDON REVERSE SIDE Rev. 7-1-80 ~ ~,?~.~dr~,7/ Submit in duplicate : " ' Gi=OLOGIC MA~'KI~Rs' - ..... ' ..... - :: "FORMATION 'I2ES'~"S ' ' NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and 'time of each phase. Top Sadlerochit 9082' ~853' ~/A Base Sadlerochit 9656' 9427 ' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed __ . Title Oper.En_~r.Mg~o Date ¢ / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injectiOn, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supPlemental records for this well should show the details of any multiple stage cement- lng 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". Form 10-407 ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 2, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-3 Dear Mr. Chatterton: Enclosed is a copy of the DS 12-3 Workover Well History to include with the Well Completion Report, dated 8/9/85. If you have any questions, please call me at 263-4944. Sincerely, Associate Engineer JG/tw GRU12/L96 Enclosure cc: DS 12-3 Well File RECEIVED Alaska Oil & Gas. Carls. Anchora,go Conunission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Prudhoe Ba~ _.,lgineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 6, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-3 Permit No. 79-41 DS 12-4A Permit No. 81-187 DS 12-5 Permit No. 79-55 DS 12-7A Permit No. 81-175 DS 12-9 Permit No. 80-93 DS 12-10 Permit No. 81-53 DS 12-11 Permit No. 81-73 DS 12-14 Permit No. 81-138 DS 12-16 Permit No. 83-11 DS 12-17 Permit No. 83-4 DS 12-21 Permit No. 84-48 DS 12-28 Permit No. 84-31 Attached are the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:vh Attachment cc: SOHIO Alaska Petroleum Co. File PI(DS 12-3)W1-3 PI(DS 12-4A) W1-3 PI(DS 12-5)W1-3 PI(DS 12-7A) W1-3 Pl (DS 12-9)Wl-3 P1 (DS 12-10) Wl-3 C E i E D ,'~laska Off & ~_~ C,.,-~- PI(DS 12-11)W1-3 PI(DS 12-14)Wl-3 Pi(DS 12-16)W1-3 Pi(DS 12-17)Wl-3 Pi(DS 12-21) Wl-3 PI(DS 12-28)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L~E] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 79-41 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well Surface: 938' FSL, 44' FEL, Sec. 18, T10N, R15E, UM At Top Producing Interval: 1130' FSL, 1309' FWL, Sec. 17, T10N, R15E, UM At Total Depth: 1108' FSL, 1293' FWL, Sec. 17, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 73' RKB 6. Lease Designation and Serial No. ADL 28330 8. APl Number 50-- 029-20377 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-3 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [X]X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate well 12-3 at selected, intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 9086-9106' MD Ref: BHCS 9-9-79 REC[IVED 1985 Alaska 0ii & Gas C,:,,ns, C0uJmissi0n Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~~~ Title Operations Engineering Mgr. The space below for Commission use Date · / Conditions of APproval, if any: ~,,~, ~. GLER By Order of Approved by COMMISSIONER the Commission ~pproved Copy Retyrn~cl Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length el time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWoll no. Prudhoe Bay ADL #28330 12-3 Auth. or W.O. no. ~Title AFE 804991 I Recompletion Nabors 1ES API 59-029-20391 Operator { A.R.Co. W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begun IDate Workover I 6 / 28/85 Date and depth as of 8:00 a,m. 7/04/85 thru 7/05/85 7/06185 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. 0300 hrs. 7" @ 9760' 9286' PBTD, POH w/WL bailer Crude/Diesel Fin CBU, POH, LD DP. LD BHA, chg pipe rams to 5½" & tst to 5000 psi; OK. RU to rn 5½" compl string. Chg tbg tongs. HU contrl lns& tst to 5000 psi. Rn 191 jts 5½", 17#, 8rd, LTC-ABM, IPC tbg. Set SSSV @ 2213', GLM's @ 3000', 4026', 5083', 6130', 6863', 7020', 7471', 7630', 8028', 8182'. Set PBR @ 8258'; SAB pkr @ 8278'; DB-6 nipple @ 8351'. Tbg tail @ 8431'. Two att's @ latch'g on K-Anchor. ND BOPE. NU & tst tree. Displ well w/30 bbls diesel, followed by 490 bbls crude, + 30 bbls diesel. RU Camco WL, tst BOPE/Lub. POOH, LD same. RIH to 8351' w/bailer, POOH. Set BPV. RR @ 1300 7" @ 9760' 9286' PBTD, RR Crude/Diesel Rn bailer. Att to pull prong w/o success. hfs, 7/5/85. Old TD New TD PB Depth 9286' PBTD Released rig Date Kind of rig 1300 hrs. 7/5/85 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no, Date Reservoir Producing Interval Oil orgas Test ~E' ) l' P~p size, SP~ X length Oho~ ~i~ T.P. 6.P. Water % ~0~ ~r~il~ ' I~11~ EIl~li~ date Signature I Date ITille For form ;reparation an~ distribution. see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company,~," Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. DaiJy work prior to spudding should be summarized on the form giving inclusive dates only. IState District Alaska Prudhoe Bay I County, parish or borough I North Slope Borough ILease or Unit Pie,d I ADL #28330 ! Auth. or W.O. no. ITitle AFE 804991 I Recompletton Nabors 1ES API 50-029-20377 Operator ARCO Alaska, inc. Alaska Well no. 12-3 W/O Spudded or W.O. begun IDate ]Hour Workover 6/28/85 Date and depth as of 8:00 a.m. 6/28/85 6/29/85 thru 7/01/85 7/02/85 7/03/85 Complete record for each day reported ^Rco w.,. 21.66% Pr or status if a W.O. 0300 hrs. 7" 9760' 9286' PBTD , Prep to Tst DA LUB & BOPE 7.2 Crude Accept Rig @ 0300 hfs, 6-28-85. RU Dresser & prep to tst Lub & BOPE. 7" @ 9760' 9286' PBTD, 9675' TD, RIH w/Cemco Flow Bskt Brine Tst lub & BOPE. TIH & perf tbg f/8233'-8235' WLM. Displ well w/9.1 ppg brine. Well dead. Set BPV. ND tree, NU BOPE & tst. PU tbg spear, shear pins in PBR @ 250K, LD tbg. RU Camco "E" in, RIH w/8.5" gauge ring & ink bskt. Tst 9-5/8" csg t/2000 psi. Rn 138 its 5-½" tbg. MU Camco SSSV, tst contrl lns t/5000 psi; OK. Fin rn'g a total of 191 its 5½" tbg. PU & MU Gray Gen II hgt. Tst B & C ins to 5000 psi; OK. Set dn on PBR & turn string w/power tongs. Lnd hgr, press tbg to 400 psi, press slowly bled off. RIH w/flow bskt. 7" @ 9760' 9286' PBTD, 9675' TD, POOH & LD 5½" Compl String 9.1 Brine FTIH w/bskt flow meter. POOH, press bleed'g off t/700 psi. POOH w/hgt. PU new hgr. Lnd tbg. Press up tbg t/1000 psi, bleeds thru open ann @ 800 psi. RU Camco, RIH w/bskt flow meter, found leak below 8273'. POOH. RU & pull 5½" compl string & LD 176 jts. 7" @ 9760' 9286' PBTD, 9675' TIH w/Bit & JB, Circ 9.1 Brine FTOH w/5½" compl string. Chg & tst rams. PU & MU fsh'g BHA. Latch PBR @ 8239', POH & LD PBR. Chg BHA & LD fsh'g ts. PU bit/JB, TIH w/same. The above is correct For form preparation~and distribufl31n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date I Title 10/9/85 Drilling Superintendent ARCO Alaska, Inc .... Post Office E' 100360 Anchorage. &laska 99510 Telephone 907 276 1215 Date: October 23, 1955' Reference: AECO Pressure Data ~V:~12-3-~--~'S~atic Gradient 10-2-85 Otis 17-6 PFO 9-18-85 ARCO Please .sign as receipt of data. ~ *",/aska Oi~ ~ gas Cor~s. Commiss~or~ Pam Lamber t AnChorage ATO 1429C Trans 37 0 Chevron Ph~illips ~ ~'~ M PB Well Files Expl. Services R:'&- D ~ Ext. Exploration Sohio Exxon Marathon ~. Mobil ARCO Alaska, Inc. Post Office t' 100360 Anchorage. A,~ska 99510 Telephone 907 276 1215 Date: October 23, 1985 Reference: ARCO CH Finals 3.-27 ~emPerature 4-31/CBL 6-10 ~Collar 9-5/Collar/Perf 9_31~. CBL 11-4/D'i f f T emp 13-98 DIL~ 13-98 DIL~ 13-98 ~;L~ 13-98 ~L ~ 13-98 CNL / 13-98 ~L ~ 13~98 ~L ~ 13-98 DIL ~ 10-13-85 Run 1 5" Otis 9-6-1~5' 2 5" GO 8-30-85 1 5" GO 9-2-85 1 5" GO 8-13-85 1 5" GO 9-7 -85 1 5" GO 10-2-85 1 5" Otis 4-5-85 20 5" Sch 8-14-85 23 5" Sch 5-1-85 13 5" Sch 5-1-85 13 5" Sch 4-5-85 12 5" Sch 4-5-85 12 5" Sch 6-28-85 14 5" Sch 5-1-85 21 5" Sch Epithermal Thermal Epithermal The rrna 1 Epithermal Please sign as receipt of data~~' ~D Received by- ~/ ~.f~~L0~~-c~ ;~:~:,:~ o;:- & bas Coils. Cor~rrlJssiorl Para Lambert ATO 1429C Chevron Trans 372 -E~p~-. Sez-wices Ex~:t Exploratioz~ Exxon-- Marathon PB Well Files R&D Sohio-- ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 12-3 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU10/L122 Enclosure If RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Na~i~co~ Ql~erator 7. Permit No. /~'l asKa, Inc. 79-41 8. APl Number 3'Ad~lr. es~). Box 100360, Anchorage, AK 99510 50- 029-20377 4. Lor,,ation of Well 9. Unit or Lease Name ~uFface: 938' FSL, 44' FEL, Sec.18, TION, R15E, UN Prudhoe Bay Unit OTHER [] 5. Ele~No~jn~ feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 28330 10. Well Number 12-3 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing ~ Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig @ 0300 hrs, 6/28/85. Perf'd tubing f/8233' - 8235' & killed well. ND tree. NU BOPE & tstd - ok. Pulled tubing. Tstd 9-5/8" csg to 2000 psi - ok. Ran 5-1/2" completion assy w/tail ~ 8413', pkr ~ 8279', & SSSV ~ 2241'. Ran temp log. Found leak. Pulled 5-1/2" tubing & repaired leak. Reran 5-1/2" completion assy w/tail ~ 8413', pkr @ 8278', & SSSV ~ 2213'. Tstd tubing to 2000 psi - ok. ND BOPE. NU tree & tstd - ok. Secured well & released rig @ 1300 hrs, 7/5/85. RECEIVED AUG 2 0 1985 Alaska 0il & Gas Cons. Commission Anchc~rage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. ,)(_~ ~ Associate Engineer Signed Title The space bel for Commission use Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 12-3 Dear Mr. Chatterton' Enclosed is the Well Completion Report for DS 12-3. received the Workover Well History. When I do, I will copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L123 Enclosure I have not yet forward a RECEIVED AIJG 2 0 ]98,5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-. ' ALASKA~, .AND GAS CONSERVATION CG 'AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-41 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20377 4. Location of well at surface 9. Unit or Lease Name 938' FSL, 44' FEL, Sec.18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1130' FSL, 1309' FWL, Sec.17, T10N, R15E, UM 12-3 At Total Depth 11. Field and Pool 1108' FSL, 1293' FWL, Sec.17, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 73' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/14/79 09/13/79 09/21/79~( 3/11/80 perf) N/A feet MSL 1 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9765'ND,9536'TVD 9286'ND,9057'TVD YES r3,X NO [] 2213 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run Cal, DIL/SP/FL/CR, accoustic GE, CDL/CNL/CR, DIL/SP/BHCS/GR, SPC/CNL/Cal/Gr, TDT/CR "23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ZU" 94.0# U-40 Surf 80' 30" 312 sx Permafrost 13-3/8" 72.0# N-80 Surf 2729' 17-1/2" 600 sx PF II .. 9-5/8" 47.0# L-80/S-95 Surf 8869' 12-1/4" 500 sx Class G 7" 29.0# L-80 8532' 9760' 8-1/2" 525 sx Class G 24. Perforations open to Production (MD+TVD o~ Top and BOttom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9242' - 9229' 5-1/2" 8413' 8278' 9219' - 9180' w/4 spf 9160' - 9123' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 03/19/80J F1 owing Date of Test Hours Tested .PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 03/31/80 5.4 !TEST PERIOD I~ 2036 1449 105 29°I 712 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 832 -- 24-HOUR RATE I1~, 9047 6439 466 27 28. apparent dips presenceCOREDATAoil, gas or water, cor~[sCEi VE Brief description of lithology, porosity, fractures, and of Submit None Form 10-407 * NOTE: Well was recompleted 7/5/85. DRH/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ -''''' 30~ ' ' ' ? .. · '" GEoLo(~'IC MARKERS -' '~ - " ' :.'F~ORMATION TES'TS ' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl e rochi t 9082' 8853 ' N/A Base Sadl erochit 9656' 9427' · . : · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed___ ~ ~~ ~ Title Associate Engineer Date ~' ~ ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 'and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng 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". ~nrrn I n_~n~ ARCO Alaska, Inc. Post Office Bt 00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are the July monthly reports for the following wells' 2A-13 3C-10 2Z-11 WSP-20 11-11 2A-14 1R-10 2Z-12 9-31 12-3 (workover) 3B-12 1R-11 2Z-13 9-32 12-5 (workover) 3C-8 1R-12 2Z-WS#1 9-33 14-3 (workover) 3C-9 1R-13 WSP-9 (2) 11-10 14-5 (workover) L1-14 L2-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L120 Enclosures RECEIVED AUG Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichlieldCompany STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION CO~, ZllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation ~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 79-41 8. APl Number 50-- 029-20377 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 938t FSL, ~+4' FEL, Sec.18, T10N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 73' RKB ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 12-3 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of. July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig @ 0300 hfs, 6/28/85. Killed well. ND tree. NU BOPE & tstd. Pulled 5-1/2" tubing. Ran 5-1/2" completion assembly. Tubing leaked. Pulled 5-1/2" completion string & repaired leak. Ran 5-1/2" completion assembly. ND BOPE. NU tree & tstd. Disp well w/crude oil (w/30 bbl diesel cap in annulus). Tstd tubing to 2000 psi - ok. Secured well & released rig @ 1300 hfs, 7/5/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None A.~aska Oil & Gas ConS. Cornmtss;on 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repor4on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ~nrrn I n~n~ TEMP/MR96 Submit in duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 28, 1985 I Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: DS 3-5, 9-11, 9-13, 11-5, 11-6, 12-3, and 12-5 Dear Mr. Chatterton: Enclosed are Sundry Notices for the subject wells. We propose to workover the above wells installing new gas lift equipment and tubing. This work is scheduled beginning May, 1985. If you have any questions, please call me at 263-4610. Sincerely, Ar~e~ Drilling Engineer TLF/ELC/tw SN/L011 Enclosures ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 938' FSL, 44' FEL, Sec.18, T10N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 73' 12. 7. Permit No. 79-4! 8. APl Number 50- 029-20377 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-3 I 6. Lease Designation and Serial No. ADL 28330 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perform a workover on 12-3 in August, 1985, to install gas lift mandrels. workover will be executed in the following manner: The 1. Install blanking plug in packer tailpipe assembly. 2. Circulate well to brine workover fluid. 3. MIRU workover rig. 4. ND tree. NU BOP stack and test. 5. Pull 5-1/2" completion assembly. 6. Run back wi th new 5-1/2" tubing string wi th gas lift mandrels. 7. ND BOP stack. NU tree and test. 8. Displace we~-I to crude oil, leaving diesel cap on annulus. 9. Pull blanking plug and install SSSV. 0. Secure well and release rig. RECEIVED Alaska 0ii & Gas Cons. Commission Anchorage A subsequent sundry will be submitted following the completion of this workover detailing the new completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 ing Engi n~.~.r Thes,~bel~'~or Com.~ se Co~nditions of Approval, if any: Date Approved by Form 10-403 (ELC) SN/024 Cop'; ~eturned By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate .-.;... 'i: . ,~ .' ARCO Alaska, Inc? ~ -¥: - - -' .... Post office.E-~x 100360 Anchorage~-: :..~ska 99510 .- Telephone 907' 276 1215 Date: February '4, 1985 Reference: ARCO Pressure Reports o. · 16-11 Pressure Data 12-1-84 GO 15-2 Pressure Data 11-29-84 GO 12-25 Pressure 'Data 12-10-84 GO 16-4 Pressure Data 1-24-85 Camco · ...... ~: ~" "~: Pressure Data 1-19-85 Camco 15-7 Pressure Data 1-25-85 Camco 14-28 Pressure Data 1-23-85 Camco 14-5 Pressure Data 1-23-85 Camco _ ~ sign and return the attached copy as receipt of data. : Received by Pam Lambert ATO 1429C Trans 017 Chevron D & M Exploration Services Extension Exploration Texaco Marathon ! AI~s~,~ Oil ~ i.~.?~$ ,:~'6:~:s. ,'.,. - . Anchorage uU4h~lS,SlOri Mobil Mabil- E & P Phillips Prudhoe Bay Well Files R & D Sohio State of Alaska ,0 .. ARCO Alaska, Inc. la a Sub,ldiary of Allanllcl:llchlleld¢omp,,n¥ A F:..' C 0 A L a :ii: I-:: a, I n c. P ,. 0 ~ i'.:',n x i () ,".:':, .S 6 :. i) A 'n c 1"~ c, r a g ,::...'., A L a s' k a ,'D ,'-, I:' , fTi '/ '.Y ..;' ] Ikt ...... t\t ............. i":: a 't' a ,':.i: 4... a t i c: :ii: u. r v,:'-7, ".:.,' {ii:-'-' 7¢ ---' 8 ,:% !...,. ',...i {;i; -:':'l ffl (:: C) f'" .:':'1 ,'TI i" .01 .':¢ T I:;,' I B U ".'." 11; 0 N }i'~ a y t.,.,I e I. I. F i I. e ARCO Alaska, inc. Post Office 3:~_.~x 360 Anchorage. .~ska 99510 Telephone 907 277 5637 February 2, 1984 Reference' Arco Pressure Data D.S. 2-lA '-- 1-7-84 ._-1-7-84 D.S. 2-8 ~-- 1-8-84 ~ 1-8-84 ]J.S. 2-10/'- 11-4-8 D.S. 2-15 ~/ ll-10- D.S. 2-16'~ ll-10- D.S. 12-12 f 12-23- m.s. 3 83 83 83 83 z~12-23- 12-3 ~-~ 1-15-84 --1-15-84 D.S. 13-32~'~ 1-5-84 -D.S. 14-7/~ 12-22-83 D.S. 14-8/ 1-12-84 D.S. 14-17-~12-2'2-83 D.S. 14-33 fl-6-84 D.S. 15-2 ''~ 12-23-83 D.S. 15-5 ~ 12-23-83 D.S. 15-6 ~-- 1-13-84 / 1-13-84 D.S. 15-13 J12-24-83 D.S. 18-7 ~-~ 9-17-83 Kelly McFarland ATO-1429F Chevron Trans. # 042 D & M Dallas Drilling Exxcn Getty Build-up PBU Data Sheet Build-up PBU Data Sheet Static Static Static Build-up PBU Data Sheet Build-up PBU Data Sheet Fall-Off Static Static Static Static Static Static Build-up PBU Data Sheet Static Build-up DISTRIBUTION Camco Camco GO Camco GO GO Otis GO Camco GO DA Camco Camco Camco Camco Camco Camco North Geology Phillips Prudhoe Bay _ ' e ' h Sohio f~;~ '. , .. -.~.._~, , -. . Marathon State of Alaska e Mobil ase s~gn and return the attached copy as receipt of data. ARCO Alaska. Inc. "-'"st Olfice Box 360 ,-.,ichoraae. Alaska 99510 'T'e ~ch~'~. ?C, 7 ?7.". August 29, 1983 Reference' Arco Pressure Data D.S. 1-9 7-20-83 7-20-83 D.S. 1-20 7-17-83 7-17-83 D.S. 11-3 8-13-83 D.$. 12-3 7-15-83 7-15-83 Pressure Build-up GO Pressure Build-up Survey Report Pressure Build-up GO Pressure Build-up Survey Report Pressure Build-up Otis Pressure Build-up Camco Pressure Build-up Survey Report Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 486 Chevron D&M Dallas Drilling ~xxon Getty Marathon Mobil DISTRIBUTION North Geoloqy Phillips Prudhoe Bay R&D Caroling Smith Sohio State of Alaska Anchorage. Alaska 99510 Telephone 9-c~--"?? .5637 February 3, 1983 Reference: Arco Pressure Data , D.S . 7-11 12-1-82 12-1-82 Pressure Build-up Camco Pressure Build-up Survey Report D.S- 12-3 /1-12-83 1-12-83 Pressure Build-up Otis Pressure Build-up Survey Report D.S. 14-3/12-10-82 Pressure Build-up Camco 12-9/12-82 Pressure Build-up Survey Report D.S. 14-17 f 11-12-82 Static Survey Camco D.S. 14-26 ~1-1-83 Static Survey Camco D.S. 14-29 12-27-82 Static Survey 12-27-82. Static Pressure Survey Data Ca/nco D.S. 14-30~ 12-28-82 Static Bottom Hole Pressure Survey 12-28'82 Static Pressure Survey Data D.S. 15-11/12-30-82 Pressure Build-up Camco 12-30-82. Pres. sure Build-up Survey Report Please sign and return the attached copy as receipt of daka. DA Kelly McFarland DISTRIBUTION AFA-403 Trans. # 11~0RTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompan-' EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Post Office Box .360 Anchorage.-"~aska 99510 Telephone , 277 5637 December 3, 1982 RE': ARCO Pressure Surveys D.S D.S D.S D.S D.S ~"'D. S --"'r D.s -- D.S O.S . 2-14 .. 4-8 . 4-5 · 4-11 · ll-3 . 12-3 · 14-12 · 14-21 · 16-9 D.S. 16-11 ~ ~~l~e'sign 9-5/6-82 Pressure Build-Up Camco 11-12-82 Pressure Build-Up (Water Injection Well) Schlumberger 11-15-82 Static Survey Dresser Atlas 10-17/-18-82 Pressure Build-Up Camco 11-11-82 Static Survey 'Gearhart 11-13-82. Pressure Build-Up Dresser Atlas 10-9-82 Pressure Bui ld-Up Gearhart 11-14-82. Static Survey ~ Gearhart 9-15-82 Static Survey Camco 10-8/11-82 Pressure-Build-Up and return the attached copy as receipt of data. Becky Benedict AFA-403 Trans. #636 DISTRIBUTION NORTHGEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA ,~ r-/'~, ~ , ,'r~' [.,;-. ,.'; 0 7 AI.~,,I~.,~_, ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieldComl3anv ARCO Alaska, Inc. Post Olfice ~' 360 Anchorage, ~,,.,ska 995'10 Telephone 907 277 5637 April 15, 1982 Reference: ARCO PRESSURE DATA D.So4-11 3/27/82 D.S.4-14 3/28/82 DOS.14-3 3/14/82 D.S.9-6 3/5/82 D.S.12-3 3/5/82 D.S.13-1 3/13/82 pressure Survey Pressure Survey I! I! I! /~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 102 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY sTATE OF ALASKA ARCO AI3S~... :n~. iS a Sd~'i,~Ji Ir'If OI AIl.lnhCR~Chhe!,;SOmp3ny ARCO Alaska, Inc. Post Office "360 Anchorage, ~,aska 99510 · Telephone 907 277 5637 February 18, 1982 Reference: ARCO PRESSURE DATA Gas 'Cons. D.S.12-3 10-28/29-81 Pressure Survey Please sign and return the attached copy as receipt of data.' Mary F. Kellis Norht Engineering Transmittal # 974 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO' GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Alaska. Inc. is a suo~,iE~ary ol AHanticRichfieldCo,"n0any ARCO Oil and Gas Company North Alas' "~ist rict Post Qffice vox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 20, 1981 Reference: ARCO Magnetic Tapes and Listings D.S. 3-18 D.S. 5-12 D.S. 6-3 4-12-81 4-22-81 _ 4-30-81 D.S. 12-3 12-7-80 * D.S. T-3 4-25-81 Magnetic tape and listing Magnetic tape ans listing Magnetic tape and listing Magnetic tape and listing : Magnetic tape and listing run 2 # 61616 #::61571 run 4 # 61604 # 51237 run 1,2,3 # 61547 ase sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #293 * Please note that this is a replacement tape. DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ~U:Y,'.,NF,, 0il & Ga'; Cons. Anc'h0rm2o ARCO Oil and Gas Company is a Diwsion of AllanlicRichlieldCompany ARCO Oil and Gas Company North Ala sk'-"-'qist rict Post O[lice ,( 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 8, 1981 Reference: ARCO Pressure Data D. S. 2-5 4-6/7-80 D.S.2-1A 9/10/80 D.S:2-8 10-27/28-80 D.S.2-13 8/31/80 D. S. 12-2 7-6/7~80 D. S. 12-5 7-16/17-80 Pressure Survey Pressure Survey Pressure Survey Pressure Survey Pressure Survey Pressure Survey Pressure Survey Please- ' sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #174 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALAS~ EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division ol AtlanlJcRichlieldCompany ARCO Oil and Gas Company Al~sk~ t.~.--', ..... ' ~ · Post Of;lc{ ;x 380 ', ._ Anchorage. Alaska 995']0 'Telephone 907 277 5637 June 6, 1980 Reference' ARCO Pressure Surveys /--- D~S',.['~2:~?: 4/26/80 Pressure Buildup p.s. 12-5 5/8/80 " " D.s~~ 5/lO/8O " " ~.L6-;" 2 4/14-15/80 Pressure Buildup and return the attached copy as receipt of data. ___/_1 ~G "1 __./.__ 3 .r..Jo ....... _/ 4 ~,;,~------- I I G~OL -- ~.. _ / 3 G,EO[/~- _. I STAT TcC FILF: K. J. Sahlstrom North Engineering TRANSMITTAL #369 DISTRIBL~ION North Geology ~2~x o n R & D Hobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology Marathon State of Alaska ©~e~on ~'iC0 Oil and G.15 Company ~$ ;i Division ol Allanh¢ ~lchl~eldCompan¥ AFICO Oil and Gas C :]pany !' North Alaska'. .'lrict Post Oflice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 2, 1981 Reference: ARCO PRESSURE DATA ~.S.2-6 3-28/29-81 Pressure Analysis Pressure Survey Please sign and return the attached copy as receipt of data. Marv F. Kellis North Engineering Transmittal ~/316 '._. ~ .,.-,_ ~J- ~,,~' DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON A~.CO O~1 and Gas Company ~s a Dl'.,Ision oJ AllanhcR~chheldCompany ARCO Oil and Gas Company Nortja Al,l,~ District Posl~ Offi ox 360 Anchorage, Alaska 99510 T, elephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 2, 1980 Reference: ARCO Cased Hole Finals D.S.12-2 8/19/80 f--~""~ 7/i2/80 D.S. 12=3 12/7/80 TDT Run 1 5" CNL Run 1 5" EPL Run 1 5" ' ~ [__ -i,,I - / I -'~ 3 I" t I STAT TEC ~ STAT TEC I CONFER: FILF: sign and return the attached copy as receipt of data. Mary F. Keliis North Engineering transmittal #940 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Di¥is~on ol AllanlicRichlieldCompan¥ EXXON MOB I L GETTY PHILLIPS SOH I 0 . ,,~,..~; MARATHON ' CHEVRON 'J'"~' ~;!,,.k-, 0il ,.. .... ARCO Oil and Gas Company North Ala/-'~'Dist rict Post Offic~ .,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 2, 1980 Reference: ARCO Pressure data ~.S. 12-3 D.S. 5-17 12/5/80 12/3/80 Pressure Pressure l'ease sign and return the attached copy survey survey as receipt of data. 1 F_'F' ': _]_2 5TAT T~C STAT TEC CONFER: FILFi ......... Mary F. Kellis North Engineering transmittal #939 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG: MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL . SOH I 0 ~ka Oil & G~ns Cons. Commission l\ MARATHON CHEVRON ARCO Oil and Gas Company is a Division ol AllanlicRichlieldCompany ARCO Oil and Gas Company Al~s k.~ Pos: Of~, LSc~x Anc:'.orcc:e. Alaska TCe3honu ~;07 277 5537 AugUst 22, 1980 Reference' ARCO Cased Hole Logs D.S. 3-15 6/28/80 CCL/O}rro D.S. 7-2 6/30/80 Caliper 6/30/80 Caliper 4/27/80 Spinner D.S. 12-5 7/19/80 D.S. 12-8A 6/25/80 Spinner " " 6/25/80 D.S. 12-8A 6/26/80 Nun 2 Nun 1 Run 1 Run 1 .; -' Run 2 Diff Temperature Run 1 Fluid Density Run i Sonan Run 1 2 ~-~ 5" (same log) 5" 5" 5" 5" - 5" 5" 5" //~please sign and return the attached copy as receipt o£ data, K. J. Sahlstrom North Engineering TPJ~NSMITTAL #553 DISTRiBUFION North Geology Exxon R ~ D blob/1 lh'illing Getty Eng. .,~ana~er. ~ Philli~)s D & ~I Sohio Geology ~.larathon State of ~aska Get.on ARCO Oil and Oas Comp,Jny ~s 3 2~v,s.on ol AH,~nhCR~ChfmlJCgm;;any ARCO Oil and ,~'~'"~mpany__ Post Office Box 350 Anchorage. Alaska 995'i0 Telephone 907 277 56;37 June 6, 1980 Reference: ARCO Pressure Surveys / .... ?~[~-3_'~ 4/26/80 Pressure Buildup - ~ "~.s. 12-5 5/8/80 " D.S. 12-6 5/10/80 " " D.S. 13-2 4/14-15/80 Pressure Buildup se sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #369 DISTRIBLrrlON North Geology Exxon R & D Mobil Drilling Getty Eng,< Manager Phillips D & M Sohio Geology ~Iarathon State of Alaska Chevron ARCO Oil and Gas Company is ,3 Division of AtlanlicRlchfieldCompany ARCO Oil and Gas .~mpany North Slope District Post Office Bo× 360 Anchorage, Alaska 995'10 -Felephone 907 277 5637 May 16, 1980 · Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 4 ~N('5 I~ I GECL 3 STAT TEC STAT TEC -~ · t--r- r ........ l?OlX! r'- Fl [ F: Subject' DS 3-11, Permit No. 79-47 DS 3-14, Permit No. 79-82 DS 12-1, Permit No. 79-23 DS 12-2, Permit No. 79-32 DS 12-3, Permit No. 79-41 Dear Sir- Enclosed please find Completion Reports reporting Production Information for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer sp Enclosures '>I' '" " ~,. f/. W/OM Form SUBMIT IN DUr._ ..,-TE* STATE OF ALASKA (see other In- structions on OIL AND GAS CONSERVATION COMMITTEE reverse side) WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: ~IELLLP~ GAS ~ WELLI I DRYE~ Other b. TYPE OF COMPLETION: NEW ~ WORK DEEP-I~) PLUG [---1 DIFF. WELL IAI OVER r'-I EN I I BACKI I RESER. I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360~ Anchoraqe~ Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface · 938'N & 44'W of SE cr Sec 18, T10N, R15E, UM At top prod. interval reported below l130'N & 91'E of SW cr Sec 17, T10N, R15E, UH At total depth l108'N & 1293'E of SW cr Sec 17, T10N, R15E, UH 13. DATE SPUDDED 8/14/79 18. TOTAL DEPTH, MD&TVD ~19. PLUGBACK MD&TVDI20. IF MULTIPLECOMPL., 9765'MD 9536'TVDI 9~r~AJ~MD 9057'TVD I HOWMAN¥' Single 22. PRODUCING INTERVAL(S), OF THiS COMPLETION -- TOP, BOTTOM, NAME (MD & TVD)* Top Sadler0chit 9082 'MD 8853'TVD Base Sadler0chit 9656'HD 9426'TVD 5. APl NUMERICAL CODE 50-029-20377 6. LEASE DESIGNATION AND SERIAL NO. ADL 28330 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 12-3 (33-17-10-15) lO_FIELD AND P~OL, OR,_~IL~C~T Prudhoe ~a.v rle~ Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 17, T10N, R15E, UM 12. PERMIT NO. 79-41 114.DATET'D'REACHED 'SS'DATE cOMP' sUSP' OR ABAND'9/13/79 I9/21/79 (3/11/80 perfl J16. ELEVATIONS (DF, RKB, RT, GR, ETC,' 117. ELEV. CASlNGHEAD73,RKB INTERVALS DRILLED BY 21. ROTARY TOOLS CABLE TOOLS A11 123. WAS DIRECTIONAL SURVEY MADE 24. TYPE ELECTRIC AND OTHER LOGS RUN C^L, DIL/SP/FL/GR, accoustic 25. CASING SIZE WEIGHT, LB/FT. 20" 94# Welded 13-3/8" 9-5/8" 72# Butt 47# Butt GR, CDL/CNL/GR, DIL/SP/BHCS/GR, SPC/CNL/CAL/GR, TDT/GR CASING RECORD (Report all strings set in well) 26. GRADE I DEPTH SET (MD) HOLESlZE I H-40I 80' I N-40I 2729' 17~." 6000 SIZE TOP (MD) 7" 8532' LINER RECORD IBOTTOM (MD) 9760' ISACKS CEMENT* 525 sx (;1~ G ~mt CEMENTING RECORD 30" 312 sx Permafrost sx Permafrost II 12~" 500 sx Class G cmt I I 27. .TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) 5~" 8414' AMOUNT PULLED PACKER SET (MD) 8284 28. PERFORATIONS OPEN TO PRODUCTION 30. 9242'-9229' 9219'-9180' 9160'-9123' w/4 SPF (interval, size and number) 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) JAMOU~ITAND'KINDOF MATERIAL USED N/^ ., - PRODUCTION .... ~ DATE FIRST PRODUCTION IPRODUCTION METHOD (flowing, gas lift, pumping--size and type of pump) 3/19/80 I Flowing DATE OF TEST. IHOURS TESTED ICHOKE SIZE IPROD'NTEST PERIoDFOR OIL-BBL. 3/31/80 I 5 4 I29 I ~ } 2036I FLOWTUBING CASING ;RESSURE, CALCULATED OIL-BBL. GAS--MCF. I "RE~§2 _ )9047 I 6439 31, DISPOSITION OF GAS (Sold, used ior fuel, vented, etc,) Reinjected 32. LIST OF ATTACHMENTS / ..:.; ~: IWELL STA'TUS (Producing or I shut.,n) Produci nq GAS--MCF. WATER--BBL. GAS-OI L RATIO 1449 I 105. 712 WATER--BB L. I OIL GRAVITY-APl (CORR.) [ 466 I 27 ITEST WITNESSED BY 33. I hereby certify that the_foregoin'g ~nd attajT~ed information is coynplete and correct as determined from all available records. SIGNED .... TITLE ~{~ ~/~ ~//~-~ *(See instructions and Spaces for Additional Data on Ro~orso Side) DATE ,~/~ ~ /~'OCO · INSTRUCTIONS General' This form is. designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item' 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTI None Top Sadl erochit 9082~ 8853' Base Sadlerochit 9656' 9427' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWSOF OIL, GASOR WATER. Sent under a separate cover letter by our Geology Department ARCO Oil and Gas .npany Ancho;',:g,::-..A[nsk;~ 99510 ~ ' ...... ~ 907 i e:uf.,r~.,,~e 2'FT 5635' April 11, 1980 Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 12-1, Permit No. 79-23 DS 12-2, Permit No. 79-32 DS 12-3, Permit No. 79-41 Dear Sir- Enclosed please find Completion Reports with attached Perforating Histories for the above-mentioned wells. Production Information for these wells will be sent as soon as it is available. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/Is Enclosure F~rm P--7 SUBMIT IN D! .... .~,,TE* STATE OF ALASKA (see other In- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE ,~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL GAS I---'1 WELL E~] WELLI I DRY r'-I Other b. TYPE OF COMPLETION: NEW WORK F--I DEEP- r--I PLUG [--I DIFF. WELL~--] OVER L-J EN I I BACKI I RESER.~I Other 2. NAME OF OPERATOR Atl anti c Ri chfi el d Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 938'N & 44'W of SE cr Sec 18, TiON, R15E, UM At top prod, interval reported below 1130'N & 91'E of SW cr Sec 17, T10N, R15E, UM At total depth l108'N & 13, DATE SPUDDED 8/14/79 18. TOTAL DEPTH, MD & TVD 119. PLUG BACK MD & TVDI20. IF MULTIPLE COMPL., - IDEPTH ' ~.=.~nnl e 9765'HD 9536'TVD I 9286'HD 9057'TVD I HOW MANY* 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* Top Sadlerochit 9082'MD 8853'TVD Base Sadlerochit 9656'MD 9426'TVD . 5. APl NUMERICAL CODE 50-029-20377 6. LEASE DESIGNATION AND SERIAL NO. ADL 28330 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 12-3 (33-17-10-15) 0. FJ,ELD&ND pOCtI OR ~vruqpoe ~0}/~{~c~c~ Fruanoe Ul/ i-'oo I 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 17, TION, R15E, UM 12. PERMIT NO. 1293'E of SW cr Sec 17, TION, R15E, UM 79-41 9/13/79 9/21/79 (3/11/80 peri~) 73'RKB 21. ROTARY TOOLS INTERVALS DRILLED BY CABLE TOOLS All 23. WAS DIRECTIONAL SURVEY MADE :24. TYPE ELECTRIC AND OTHER LOGS RUN C^L, DIL/SP/FL/GR, accoustic GR 25. CASING SIZE 20" 13-3/8" , 9-5/8" 26, SIZE 7" 28. PERFORATIONS OPEN WEIGHT, LB/FT. ! GRADE 94# WeldedI H-40 72# Butt I N-401 47# Butt I L-B0 1&-~-95 CDL/CNL/GR, DIL/SP/BHCS/GR, SPC/CNL/CAL/GR, TDT/GR 30. :ASING RECORD (Report all strings set In well) LINER RECORD TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 8532' 9760' 525 SX TO PRODUCTION Class G cm' (Interval, size and number) 9242' - 9229' ~ ~..~ 9219' - 9180' ,'~ 9160' - 9123' w/4SPF 27. TUBING RECORD 29. 5~" 8414' ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. 8284 DEPTH INTERVAL (MD) N/A PRODUCTION AMOUNT AND KIND OF MATERIAL USED DATE FIRST PRODUCTION N/A DATE OF TEST. HOURS TESTED CHOKE SIZE FLOW TUBING CASING PRESSURE CALCULATED PRESS. 24-HOUR RATE 31. DISPOSITION OF GAS (Sold, used for fuel vented, etc.) IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of puml~) PROD'N FOR OIL--BBL. TEST PERIOD OIL--BBL. GAS--MCF. IWE LL STATUS (Producing or shut-In] ....... GAS--MCF. , ','.'.WA~.ER-BBL. IGAS--OIL RATIO I i I iWATER--BBL. I OIL GRAVITY-APl (CORR.) I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Perforating Hi story 33. I herebySIGNED certify "~~ that the forego~~ attached information is co~n plete TITLE and correct DiaSstri determined ct from Dri]7 all available ing records. Engi neet *(See instructions and Spaces for Additional Data on Reverse Side) DATE 4/11/80 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, Item: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement"' Attached supplemental records 'for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28- Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME NONE MEAS. DEPTH TRUE VERT. DEPT: 'Top Sadlerochit 9082' 8853' Base Sadlerochit 9656' 9427' ., 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Sent under a separate cover letter by our Geology Department Perforating History DS 12-3 (33-17-10-15) API 50-029-20377, ADL 28330, Permit No. 79-41 Began perf operation @0730 hrs 3/11/80. Tstd tree, csg, & wireline BOP's. Perf's intervals 9242' - 9229', 9219' - 9180', & 9160' - 9123' w/4SPF. Ran Amerada press bomb. Flowed well. Ran & set SSSV. Tstd balance and control lines to 5000 psi. Ok. Tstd valve w/500 psi diff across valve for 30 min, ok. Installed & tstd tree cap to 5000 psi. Released well to Pro- duction Dept. @ 1600 hrs. 3/11/80. ARCO Oil and Gas/~'~mPany Al=sk¢ Po-~t Office B:--x Anchorage. Aiask~ 93510 Telephone 90; 277 5537 April 3, 1980 Reference-: ARCO Pressure Surveys D.S. 4-1 9/2-3/79 Camco D.S. 4-5 11/7-8/79 " P.S. 4-9 9/18/79 Camco Dresser 3/12/80 Atlas ~Please sign return the attached cop>' as receipt and of data. 'K.' J. Sahlstrom North Fmgineering TRANSMITTAL # 254 DISTRIBL~ION North Geology R & D Ih-illing Eng. ~k~nager Geology State of Alaska bIobil Getty Phillips Sohio Marathon O~ex~on Januax~' 29 1980 Reference' Enclosed are Magnetic Tapes for the following ARCO wells' D.S. 5-6 11/10/79 Tape #60020 D.S - 11/17/79 Tape #60031 ~.~ 8/26/79 Tape, #57010 ~ ?~- ~-r .... r~,~ " of data. and return the attached copy as receipt K. J. Sahlstrom North Engineering TR-kNS3IITFAL" .049 A;'~::h(':,~ngr..-,/'.!.~":k..'l -2-'.35 ]0 Tci.--:2 -...:,r;,..,.,.~z./277 5537 November 7, 1979 Re£erence' · Enclosed are Cased IIole Logs for the following ARCO wells ' D.S.. 3111 10/6/79 CNI, .Run R S" ' - ':/' 10/16/79 CNL Run 1 5" ~"~"~ 9/16/79 CNL Run 1 5"" Please sign and return the attached copy as receJ.1)t of data, : K. J, Sahlstrom North' Engineering TRJtNSMITTAL # 459 ]') Norti~ Geology .... o~ Gott)- Ceo ]og)' State of hla~;ka t~hill I) ~ ~I Chevro~ October 26, 1979 ?.e:[erence · Enclosed are Magnetic TaPes for the following ARCO wells' D. ' ' 11/12/79 ? Tape # 681 Dresser Atlas -' ...... 10/6/79 Tape # 672 " " -~ ~ 10/6/79 Tape # 673 " " /~/PPlease sign and return the attached cop)' as receipt L/ of data. t" J, Sahlstrom North Engineering TRANSMITTAL fi 439 North ~'--',- ~'-' ' - Post O~fJce ' 380 'r~l~-~ .... 0%~ 277 ~53Y October 30, 19.79 Enclosed ~re Open Nolo LoSs- £or the £ollowin~ ARCO ~%;a;ign. 8/mnS'l/;:turn the attached copy as ze'ceipt t COMa ~__~.~i~'~'-'~ I ~ES ENG. ' "q I = ENG -' .~ 3 EHG - I 4- --1 GEOL ?-I s O~OL i_ , J ---I STAT TEC _--"[STAT TEC' ! i CONFER: FII F: K-. J.. Sahlstrom North ~ngineering TP&NSMITYAL # 444 Gott), . t;h:[llips Chevron '~cl'~ra~e ~'"" '°'"" North A!asRa D!s~,rict Post O~;ic~' '"..'. 3~0 Anchor2ge, ~ ,.';' ~, ...... a. -33510 Telephone 907 277 5637 October 19, 1979 Reference· . ~nclosed is a Directional Survey for the following · ARCO well- D,S. ~o±?a ~ 9/24/79 Eastman ~ipstock ~~P!ease sig~. and return the attached copy as receipt. of data. K, J. Sahlstrom . North ~ngineering TR&NSMI?TAL # 420 D!STRI BUT ION North r:,~-] .... l)ri ! 1 ing Mol)il Eng. Manager Getty R & D . Sohio Geology Marathon State of Alaska Phillips D & M Chevron ARCO Oil and Gas.~:~ompany ~q i.~ska Reg !-'o:st Office c,:_,( 360 /3~ choral_cie, A!as!..:a 995'!0 T,riephone C. 07 277 5637 October 17, 1979 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 ~ 1 970L I'~'c'? *,T T'-C -6-! _s?.,T ;r':.c. FILF:'- ' Subject:~_P~rmit No. 79-22 DS 3-10, Permit No. 79-21 ~ .... DS 12-3'· ~rmit No. 79-41 WGI #2, Permit No. 79,43 ~~~mi t No. '79-49 Dear Sir: Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Attachments ,ARCO Oil and Gas Cc, top,ny is a Div;sloq o! Allanl.:cRichfieidCompar]y Form P--7 SUBMIT IN DL .'E* STATE OF ALASKA (s~. other In- structions on reverse side) el L AND GAS CONSERVATION COMMITTEE WELL COiMPLETION OR-RECOIViPLETION REPORT AND LOG* la. TYPE OF WELL: OIL GAS [~ WELL ~--] WELLI I DRYS] Other b. TYPE OF COMPLETION: NEW g WORK [--J DEEP- PLUG ~ DIFF. ~ WELL OVER I I EN J~ BACKI I RESER.I I Other 2. NAME OF OPERATOR ARCO 0il and Gas Company 2. ADDRESS OF OPERATOR .P.O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* '~-' ' ~ ~ "~ ? v , At surface 938'N & 44'W of SE cr Sec 18, T10N, R15E, UM At top prod. interval reported below ll30'N & 91'E of SW cr Sec 17, T10N, R15E, UM At total depth - ll08'N & 1293'E of SW cr Sec 17, T10N, R15E,/UM.. ~.: 18. TOTAL DEPTH, MD & TVD 19. PLUG BACK MD & TVDI20. IF MULTIPLE COMPL., TOOLS 9765'MD 9536'TVD 9~MD 9057'TVDii HOWMAN¥~ingle 1 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOTTOM, NAME (MD & TVD)* Top Sadleroch5t 9082'ND 8853'TVD Base Sadlerochit 9656'MD 9427'TVD ORIGINAL 5. APl NUMERICAL CODE 50-029-20377 6. LEASE DESIGNATION AND SERIAL NO. ADL 28330 7. IF INDIAN, ALLOTTEE OR TRIBE NAME B. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. [~ 12~3~)(33-1 7-10-1 5) 10~_AN'D'POOL, OR WI LDCAT ?rudhoe Bay F5 el d-Prudhoe 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 17, T10N, R15E, UM 2. PERMIT NO. 79-41 G'F~-,'"~TC)* 117. ELEV. CASINGHEAD INTERVALS DRILLED BY · CABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN CAL,' DI[/SP/FL/GR, accoustic GR, CDL/CNL/GR, DIL/SP/BHCS/GR, SPC/CNL/CAL/GR, TDT/GR 25. CASING RECORD (Report all strings set in well) 0il Pool CASING SIZE 20" rWE,GHT, LB FT. ]GRADE I 94# Wel de~l H-40 I 13-3/8" 72# Butt / N-801 2729' I :,8o I8a6c ' 9-5/8" 47# ButtI S95 J LINER RECORD DEPTH SET (MD) HOLE SIZE 80' 30" CEMENTING RECORD AMOUNT PULLED I312 sx Permafrost 17-1/2" 6000 sx Permafrost II cm 12-1/4" J 5fill ~× Cla~s P, cmt I 27. TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) B-l~?" R414' 26. SIZE TOP (MD) BOTTOM (MD) PACKER SET (MD) 82R4i 11 8532' 9760' JSACKS CEMENT* 525 s× £1ass fi nmt 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) N/A 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 30. PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) DATE OF TEST. HOURS TESTED[[CHOKE SIZE J PROD'N FOR TEST PERIOD FLOWTUBING CASING PRESSURE ,CALCULATED OIL--BBL. PRESS. 124-HOUR RA~TE I- 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) Re injected WELL STATUS (Producing or shut-In) OIL--BBL. GAS--MCF. I GAS--MCF. WATER--BBL. I GAS-OIL RATIO WATER-BBL. GRAVITY-APl (CORR.) ITEST WITNESSED BY 32, LIST OF ATTACHMENTS Drilling History and Gyroscopic Survey 33. I hereby certify that the foregoing and attached information is cornplete and correct as determined from all available records. SIGNED~ TITLE District Drilling Engineer i DATE 10/15/79 *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26' "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See. instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD NAME MEAS. DEPTH TRUE VERT. DEPTI None Top Sadl erochi t 9082' 8853' 3ase Sadlerochit 96561 9427' 3G, CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. To be sent at a later date under a separate cover letter by Geology Department. Drilling History DS 12-3 (33-17-10-15) AP150-029-20377, ADL 28330, Permit No. 79-41 Spudded well @ OlO0 hrs 8/14/79. Drld 17-1/2" hole to 2751'. Ran CAL, DIL/SP/FL/GR, accoustic GR, & CDL/CNL/GR logs. Ran & cmtd 13-3/8" 72# N-80 csg @ 2729' w/6000 sx Permafrost II cmt. Did 250 sx top job. Installed & tstd pkoff. NU & tstd BOP. Drld shoe + 12' new hole. Performed form leakoff tst. Form held 11.8 ppg equiv. Drld 12-1/4" hole to_~8894'. Ran DIL/SP/BHCS/GR, SPC/CNL/CAL/GR logs. Ran 9-5/8" 47# L-80 & S-95 csg to 8869'. Cmtd csg w/500 sx Class G cmt. Installed & tstd pkoff. Tstd csg to 3000 psi. Ran TDT/GR log. Pumped 500 sx Permafrost II cmt dwn 9-5/8" x 13-3/8" annulus followed by 132 bbls Arctic Pack. Ran TDT/GR log. Tstd 13-3/8" x 9-5/8" annulus @ 1000 psi. Tstd csg to 3000 psi. Drld cmt, shoe & 10' of new hole. Performed leakoff tst w/12.5 ppg equiv MW. Drld 8-1/2" hole f/ 8894'-9041'. Cored intervals 9041 '-9081', 9081'-9148', 9148'-9184', 9184'-9247', 9247'-9320', 9320'-9357' 9357'-9414', 9414'-9483', 9483'-9492' '9492'- 9566', 9566'-9632', 9632'-9646I, 9646'-9691'. Drld 8-1/2" hole to 976~'. Ran DIL/SP/BHCS/GR, FDC/CNL/CAL/GR, DM, RFT. Ran 7" lnr w/shoe @ 9760', top @ 8532', cmtd l nr w/525 sx Class G cmt. Tstd 7" l nr & shoe. Would not hold. Set RTTS pkr @ 8577'. Tstd lnr lap to 3000 psi TIH to 9696' & set pkr. Tstd LC to 4000 psi, tstd DP 7" csg annulus to 3000 ~si. Reset RTTS @ 9706' & tstd to 3000 psi. Drld LC, pumped into form 3.6 BPM @ 2200 psi. Drld & cleaned out to 9765'. Ran CBL/VDL/GR/CCL from 9751 '-8500'. Set cmt ratainer @ 08' to w/097400' Attempted breakdwn form w/3000 psi. Unsuccessful. Attempted again psi. No bleed off. Drld thru cmt ret. Reamed f/9708'-9765'. Pumped into form 3.5 bbls/min. Ran g~ge ring & jnk bskt. Set cmt ret @ 9705'. Pumped into form @ 2 bbls/min. Pumped 250 sx Class G cmt. Ran CBL/VDL/CCL/GR f/9678'- 8500'. P~erfd f/92~6'-9298' w/4~_E~ Set cmt ret on wireline @ 9286'. Pumped 120 sx Class cm. an og f/4000' - surf. Re-Arctic Packed as part of improved Arctic Pack Test Evaluation. Ran GR/CCL inside DP from 4000'-sur. Reversed out mud w/wtr & wtr w/CaCl~. Ran 5-1/2" tbg set @ 8414'. Tstd contrl lns to 5000 psi. Dsipl CaC12 in 5-?/2" x 9-5/8" ann w/390 bbls diesel. Set & tstd pkr @ 3000 psi on tbg, 200 psi on ann f/1 hr. Ran 2-3/8" tbg to btm. Reversed out CaC12 in tbg w/280 bbls diesel. POH w/2-3/8" tbg. Installed & tstd X-mas tree to 5000 psi. Performed 3 hr tbg (pre-move) tst. Released riq @ 1200 hrs 9/21/79. Eastman/ Whipstock lC) A PETROLANE COMPANY REPORT of SUB-SURFACE D IREC TI ON,4 L SURVEY ARCO OIL & GAS COMPANY D.S. 12-3 WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUMBER A979G0035 TYPE OF SURVEY GYROSCOPIC SURVEY BY Grady Hickman OFFICE Alaska DATE 9-24-79 I"i I!:' A S U I:( iii: :0 :[:1 I:;: I F:' l" i') R I F:' 'l' .0 iii: F:' 'i' 1--IA i'.! G [_ ti!: ][) I R E C T I 0 F:' E l:i: "l' i) H 0 ~ C' 0 0 :1. ()00 () ]. 5 '.:i:; S 1. 200~ 0 30 S 65 W :!!:00, 0 :.30 S :36 LJ 4()0, 0 45 S :'IS W ~":' () 0, 1 0 S 48 I,J /, o_ 0 ~ I 15 c.~o ~.~'"' "'~ W 7()0.~ 1 0 S -'35 W ii.;: 00. I 0 S '~0 U 900., 1 1,..,'::'S. 44 W 1000 o 1 ~'; ...... !:~ ':-".,o"' U '1.:1.00, 1 1.5 S 6:1. W 1200, '1 0 S 4 ? W :]. 300 ~ I .4 *,:.: S :3:3 W ]..:iC, C,., 1 SO S 15 14 150 C,., 1 30 :1. 60 C:, ~ I 45 1700 ~ 1 15 180 (), :t. 0 ! 900 · 0:30 20. () 0, r,._. 1 ,.., 2:1. 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DEPTH A~'.IG L E DEPTH .SEA DIREC DISTANCE' ANGLE DEr21 ].OOFT ~ J: S 1'Ai'.~CE D M D E G · D 1.4 S · 474:0 '15 47.3,99 1113 0 45 1112,9'7 1039,97 .... 1692 2751 3~.! ] 3544 3780 2 0 1691 0 30 2750 1 0 3210 0 45 3543 2 45 36;37 5 15 3779 ,79 1618,79 S 5.00E 14,07 .S 6,66 W 15,55 S 25 19 bO W 0.2t7 ,51 2677,51 S47,00E 34,37 S 3,24 E 34,52 S 5 23 13 i 0,142 -6,oU ,43 3470,43 553,OOE 40,00 S 12,74 E 41,98 S 17'40 40 E 0,075 C:.?,3 · 35 3614,35 N61,OOE ~0,29 S 16,89 E 43,69 S 22 45 5 E 1,393 4.72 ,12 3706,12 N67,OOE 37,48 S 22,66 E 43,80 S 31 9 31 E 2,"fl~ il,Ob 3871 8 15 3~69.48 3796,4e .N70,OOE 33,56 S 32,61 i 46,79 $ 44 10 37 E 3.297 21.- ) 3930 9 45 3927,75 3854,75 N66.GOE 30,10 S 41,16 E 51.00 S 53 49 1~ E 2.~bO 30.c. __._~22 !._!E...._3_ g .... ~_!..9_&~5 ~__ ~!.!. 9,6 K_J'J ~ 3, .0. r2.g ................. !...,. 2 ~._.~ ............ ~_Q ,. Q.~ .... ~ ................... ~ Q. ,. ! Q ...~. ~ ~_i! ~_.... ~ ~. ~ .......... !, 774 ........ t:. P, 99 .... 4414 21 0 4395,38 4322.38 N56.OOE 36.39 4513 23 0 4487,17 4414,17 N6].,OOE 55,76 N 174,53 E 183,22 N 72 16 48 E 2.162 lo3.i5 5134 5692 6417 6~07 7320 76 45 7926 .:~ 4 7 ,P c 8 4 h -..'?.Z. O 4614,66 454__1,6!__tj~_7.1,00£ 77,22 N Z2.2__,..7_..1.__~ ......... ~._3..5',_7..2=_:',1,.?'.O. %.2~ ..... ~_..? .... ~ .......... !..F-.:4':-) ........... ;'.~574:c.'.. ..... 22 f3 5062.49 49~t9,49 N7C).O0~-; 137,61 N 3~;3.27 E a16.65 N 70 42 49 E O,L)Tt~ ~15,i-/ 2.1 a5 54.37,52 5414,52 N73,0Ui 191,75 N 555,07 ') 0 t ' 4 / ,.~-: , 21_!5__.!7__~.%_27__IZ2,_6_,.20__!'i_72,':-)~)E .................................. 2~.,~.[;7~:~ ...... ~7..';..., 17 ................ [5_ 71u,o0 ,",1 '71 ].Z 41 F :~,~. "~ .... 20 15 6257.41 618a,41 N72.OOE 2.92.32 lg 837.27 E 883.59 i.l 71 21 5~i ~' 0,2_04 19 15 6624,47 6551,47 N74,OOE 320.85 N 963,29 E 1015,32 i'~ 71 34 42 E 0.262 i:? C) 7a24.92 7351,C~2 N77.CCC 3e6;.65 i'.: IlC;9,90 E i261,27 ['.; 72 3 8 E 1,77'~ iz6o.ov ,~ .... 8 ~5 7701.'29 -/624.29 N83.'3o~. 39'/.~ ~ !249,7C E i~i1.36 q 72 21 Zb E 1.15d i~1i.1 fi 1= q24~,14 6ii-/0.1', S~S~,OOt; ~O0,9P fi ...... !~.~::~9 F: ...... ~3TM "' "'" ~ '~- t ' 1 45 2614,3P ~541,38 S'/4.0CE ~9-/,5'7 ,'., 1338.48 L~ 1396,28 h 73 2.7 24 ~ C.94i AP.,CO O/G Dc`"` 12-3 MACiF~ETIC ~' T r,', u [: "i: CO~...F MEASUR['D VERTICAL TOTAL C(~O[~I~'~ATE:S C t G S U .~ [-'. Sd~:~ ': AIA?~E . DEPTH D. EpT~i 'DISTANCL. ANGLE SEA , ::'i~t!AStjRED DEPTH A"]D OTHER DATA MAGNETIC SIF!GLE-SHOT SURVEY EVERY ~:VEN 100 FEET OF SU~, SEA DEP TH, t i S E P '? 9 T R U E ' , t , VERTICAL'SUB MD-TVD ' VERTICAL '. DEPTH ,::,~A DIFFEF~,ENCE CORRkCTIOF, ' TOTAL , . , ., COORDINATES . , 173 273 173, 100 0 0 273, 200 0 0 0,12 N 0,25 N 0.04 E 0,16 :. 573 373 ': 473 57'3 4 o 0 50.0 Ij. ,/.+3 N 53 N 30 N 0.70 . 1,1.5 673 773 873 97 107 117 673. 600 0 773, 700 0 873, 800 0 9 73 1073 1173 · 1100 16 S 85 S 70 S 58 $ 35 $ 87 $ 1.57 E 1,~4 E 1,57 E ................... ~,-..~,:. ::: ................................................................................................ 1.59 ~ 0.99 E 0'12 W 127 137 147 1573 1673 1773 I- '7 3 1973 2073 2173 2273 1273 1373 1473 1200 1300 1400 1573 1673 1773 1500 1600 1700 187'3 1973 2073 1800 0 0 1900 0 0 2000 0 0 2173 2273 2373 6, 8 · 71 S O9 S 03 S 10,52 13.47 16 · 80 19.91 22,74 2~,26 2100 0 0 27,49 S 2200 0 0 29.40 S 2300 0 0 31.01 S 1,62 3,18 4,64 6..67 6,34 5,77 ..... 5.04 4.16 2,10 0.98 247 2 5 'l 267 2473 2573 2673 2400 2500 2600 277 287 297 2773 2S73 2973 2700 2800 2900 0 0 32.31 S 0,15 E 0 0 33.31S 1.30 E 0 O 34.01S 2,41 E 0 0 34,5U $ 3,38 E O 0 35.15 S 4.16 E 0 0 35e~4 S 5.14 g -- 307 317 327 337 347 357 3073 3173 3273 3000 3100 32O0 0 0 36.56 S 6.33 E 0 O 37.2~ S 7,73 E 1 1 ........... !! .......... ,__'.!:L _ g 1 0 38.66 S 10,73 E 1 O 39.43 S 11,97 E 0 -1 40.25 S 13.1'7 E 3373 3473 3573 3300 35OO ':.ARCO 016 DS 12-3 MAOF]ETiC $.INGLE-SHOT 'S~RVEY !], 5EP 79 DEPTH AN[)oTi'tER DATA FOR FVERY EVEN 100 FEET OF'" .SUB SEA DEPTH, "' TRUE DEPTH , , · VERTICAL SUB ND-TVD DEPTH SEA DIFFERENCE . VERT ! CAL CORRECTION 'TOTAL COORDINATES · 3574 3774 3875 3976 4078 3673, 3600 0 3773, 3700 0 40.45 5 16.28 37.70 S 22..1~..._i_: :53,38 $ 33.09 26,66 S 48.51 16,98 S 66.30 3873, :: 3800 4073, 4000 4181 4285 4390 4498 4506 4714 4173. 4100 4273, 4200 4373. 4300 7 11 17 4473. 4573,: 4673' 4400 4500 4600 24 33 41 7 9 8 4.18 S 86,02 E 12.27 Iq 108,48 E 52.83 N 169.34 E 71,26 N 206'82 E 84,91 N 244.99 E 4822 4930 5(.)37 4773 4873 4973 4700 4800 4900 5145 5253 5361 5073 5173 5273 5000 5 !00 5200 5469 5576 5584 5373 5473 5573 5300 540O 5500 5791 5899 60O6 5673 5773 5873 5600 5700 5800 6113 6220 6327 6434 6540 664& 5973, 6073. 6 62'73 · 6373, 6473, 5900 6000 6100 6200 630O 6400 6752 6859 6954 6573 6673 6773 6500 6600 6700 7070 7175 7280 6873 6973 7073 68OO 6900 7000 q9 8 98,2.3 N 283,13 E 57 8 111.69 N 321,23 64 7 125.25 N 359,10 E 72 8 139,02 N 397.14 E 80 8 152,55 N 435,20 E 88 8. 165.57 N 473,31 E 96 8 178.07 N 511.40 103 7 190,01 N 549.40 E 111 8 201.77 ~' ~'87.55 E ................ D, ............... ,." 118 7 213,53 N 625,02 E 126 8 225,52 N 6~2,46 E 13 3 7 2__3!,_.5.._0___~ ............. 6_ ~.9__.._3.~. _E ............................................ 140 7 249.35 N 735.81 E 147 7 261,07 N 771,87 E 1.5.~ ............................ .7_ ............................. g..7.~. ,.0.5..~ ......... _8 P. 7_._ _~. _], .... _E. ............................... 161 7 167 6 _]_ _L3. ................. 6 179 6 185 6 197 6 202 5 207 5 284.09 N 842.73 E 295.16 N 877.55 E 3Q.~.~]..~_~ ........ ~!.!.~...~_..E ................. 315.79 N 9~5.81 E 325.48 N 979.39 E 335.09 ~j 1012,~..~...~ ....................... 344.62 N 1044.~3 E 354.09 N 1076.57 [ 363,51 N 1107,70 L ARCO O/G DS 12-3 HAGNETIC SINGLE-SHOT SURVEY 11 SEP 79 ',:? F'IEASURED VERTICAL ~SUB ~D-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION .TOTAL COORDINATES ................................................................................................... 7385 7173. 7100 7489 7273. 7200 7.592 7373. ::7300 '7694 7473, 7400 7796 7573.7500 212 5 372.56 N 1137.74 E ~ 216 4 38 .... 8 N llb4 81 E ~ ............................................................................... ~!._,_.o.'. ............................ ,_ 219 3 386.09 N 1188'72 E 22.1 2 390,81 N 1209,63 E 223 2 394.41 N 1228'45 E · 7897 7673. 7600 7998 7773. 7700 8099 7873. 7800 224 1 396,90 N 1245,23 E 225 1 398,64 N 1260,30 E 226 1 39;,90 N 1274,24 E 8200 7973. · 7900 8301 8073. 8000 · 8402 8173. 8100 227 228 229 8502 8273. 8200 229 400.71 N 1287.1.2 401,09 N 1298,81 401.10 N 1309,37 400,~4 N 1318.76 F 860P_ 8373, 8300 229 8702 8473, 8400 229 400.25 N 1326,58 E 399,27 N 1332,70 E 8803 8573, 8500 230 398,08 N 1337,15 E ..) ARCO O/G DS 12-3 I4AGNETIC SINGLE'SHOT SURVEY 11 &EP 79 , - ~ · I INTERPOLATED VALUES FOR EVEN 1000 Fr:'-ET OF MEASURED DEPTH. ~ 1000 999, 926. 2,80 S 1,46 E 2000 1999, 1926, 23,45 S 4,81 W 4000 3923, '24,65 S ' 52.51 E ':'' 5000 4938' 120,56 N':~'' '~ti6'06 E''''~'''''' :.." 6000 5867, 5794, 236,82 N .Z~ 697,25 E¢'~''! ...................................................................... 7000 6806, 6733, 338,33 N z.~"'1023,54 E / .... 8000 7774, 7701, 398.67 N /~.-- 1260,59 E 400 800 1200 1600 2OOO 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 8400 VERTICAL SECTION SCALE I"=1000' ARCO OIL 8 GAS MAGNETIC SINGLE-SHOT RADIUS OF CURVATURE DRILL SITE 12-5 SEPT. I0~ 1979 ALL DEPTHS SHOWN ARE TVD. TVD = 8614' TMO = 8844' HORIZONTAL VIEW SCALE 1"=500' ARCO OIL & GAS MAGNETIC MULTI-SHOT RADIUS OF CURVATURE DRILL SITE 12-3 SEPT. I0, 1979 · , .. ALL DEPTHS SHOWN ARE TVD. TVD=8614' TMD=8844' LOCATED IN THE APPENDIX [21 WFL ~ IPR LOG ~ CALIPER SURVEY UI VOLAN UI CURVE DATA iZ[ STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER: $It I P PED TO' il, :~d O;:s ¢ '-,party ". ,,! ©ffice Ec'.x T,.l,_-isl;cao 507 277 5637 SAMPLE TRA NSM I TTA L State of Alaska Division of Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, Ak. 99510 Attn: Mr. Wm. VanAllen OPERATOR: ARCO NNME' DATE: October 15, 1979 Drill site 12-3 OM~" ' ' LCO~ I 1 GE~ -' I stATTE~ I CONFER: -- FILF: S~MPLE TYPE' dry ditch & core chips S,kMPLES SENT' Dry Ditch: Core Chips: NUHBER OF BOXES: 17 2751 - 4500 45O0 - 6540 6540 - 8550 8550 - 9765 8991 - 9038 9039 - 9075 9081 - 9122 9123 - 9137 & 9148 - 9173 9184 - 9237 9247 - 9316 9320 - 9354 9357 - 9407 9414 - 9481 9483 - 9540 9541 - 9557 & 9566 - 9590 9591 - 9638 9646 - 9691 ARCO OIL & GAS CO. P. O. BOX 360 ANCIIORAGE, ALASKA 99510 ATTN: DICK BROOKS RECEIVED BY- f% DATE North Alaska District Post Office ~'~" 360 AnchoraGe, ,.,.~s',<a 995'I 0 Telephone 907 277 5637 October 16, 1979 Reference: Fmciosed are Open Hole Logs for the' following ARCO wells' D.S? !Z-3 8/26/79 ONL/FDC t~,an i 2" " ': 9/9/79 CNL/FDC Run 1,2 " " 8/26/79 FDC/GG Run 1 " " 9/9/79 FDC/GG ~ 1,2 5" " ': " DIL Run 1,2 2" & 5" ': " " BHCS Run 1,2 2" & 5" S... 12~-3 9/9/79' Continuous'Ilipmeter P~m 1 5" ~-/ Please sign a~nd return the attached copy as receipt v of data, K. J. Sahlstrom North Engineering TP'-&NS~.-'ATI'AL # 409 North Geology ~xxon ~' Dr J. 11 ing Mob i 1 ~"%-r, ''":' Eng. Manager Getty ' z~t~.. R & D Sohio. Geology Marathon State of Alaska Phillips D & M Chevron '" ~" ¢,.-'>:7330 POS: O,~tC AnChOr¢~- aska 09.510 Te!3ph'3.q~ ' 7;7 277 .%3'~' October 16, 1979 Reference' ~nclosed are Cased Hole Logs for the following ARCO wells' 8/29/79 TDT Run D.S. 12--3 8/29/79 TDT Run 2 5" D,S. 12-3 9/9/79 CBL Run 1 5" D.S. 12-3 9/9/79 CBL Run.2 5" ,~# 1 7/27/79 ~4L ~ &/Please sign and return the attached copy as receipt of data. K. J, Sahlstrom ,North Engineering TR&NS\!ITFAL # 410 DIS'TRI};.~ iTl'OX ~Xlobi] (;~ .~ Sohio Maratt Ph 5.11 Ci:evron Posi O ffice~'~-~× Anchorage- ~-'- 99510 Telephone ~072775537 Oatober 16, 1979 Reference' Enclosed are Open Hole Logs for the following .ARCO wells' WGr #5 '9/20/79 CNL/FDC 5'-" " " FDC/GG 5"' " " BHCS 2"' & 5" " -- " DIL 2" & 5" D S l?-- 9/9/79 CPL 5'r , //~lease sign and return the attached copy as receipt of data. K. J. Sahlstrom North -Engineering T~NSB'IITTAL # 407 ]¢] S'i'R'113[J'i'JOX North ,-,,_.o_1 ])s-:i 11 i.ng R& D Ceo'lo:{? State of Alaska Post O~flce Box 380 Anchora,:.~ .!3ska 9~310 Telephon{: ::.;07 277 503? October 15, 1979 Reference' EnclOsed are Cased Hole Logs for the following ARCO wells' D.S. 1-!5 9/20/79 Spinner 5" D.S. 2-11 9/25/79 " 5" D.S. 5-6 5/19/79 " 5"' D.S. 5-17 9/28/79 " 5" 7/5/79 " 9/23/79 CNL 5" -WGI-3 9/26/79 " 2 & 5" ~ease sign and return the attached copy as receipt ~~a~ . K. J. Sahlstrom North Engineering TK&NS;qI~iTAL # 398 ])ISTI(I l;l.J'l'] OX ~', lob i ] Cettv Sohio Ph i I 1 Chevron Norlh American Producin9 Division N or?.h Alas?'~istrict Post Office ,~..x 3S0 Anchora..ge, AMska 99.5!0 Telephon~ 907 277,5837 September 17, 1979 Reference: SOL ~1 3 oeo --'1 STAT T~, Enclosed are Cased Hole Logs for the follmVingARCO wells' ~ 8/16/79 4-Arm Caliper ..,~. 13-3 : 8/23/79 SPinner 5'~ Please sign and return the attached copy as receipt of data, Very truly yours, K. J. Sahlstrom North Engineering TR~NS~'IlTTAL # 342 4nchoraLre ·.... DISTRIBUTION North Geology ~xxon Dri 11 ing 3.!ob il Eng. Manager Getty R & D Sohio Ceo log}; ~,[aratho n State of Alaska Phillips D & bi Chevron Norlh American Producing Division North Alaska '~'qrict Post Office B-' _ ,~$0 Ap, chorage, Alaska 99510 Telephone ~r,-~.., ~,o~7, 5837 September 17, 1979 Reference· Enclosed is a directional survey for the following AP, CO well' pi.!2,3 9/11/79 b~gneti~Single-.sh0t ase sign and return the autached copy as receipt of data. Very truly yours, _1 coM 4' _ L _-_ I ~ ..1 J 3 GEOL / ! STAT [ STAT T~C ................. CONFER: FII_F: .K, J. Sahlstrom North ~ngineering TRAN~ffT~AL # 340 DISTRIBUTION Nort:h Geology Drilling Ens. Manager Geology State of Alaska ]~[XOll Mobil ¢;etty Sohio Marathon Phillips - Chov roi1 Nor[h Americ-~=...Producing Division North Alaska .~trict Post Office Bo× 360 Anchorags, Alaska 995 !0 Telephone 9307 277 5637 SePtember 12, 1979 -Reference- Enclosed are Open Hole logs for the following ARco wells' I I' I 3 1 ' J STAT TSC ~ I CONFER: 'FILF: D.S. 12-3 8/16/79 BHCAcoustilog 2" " " Dual Induction Focused Log "//"" " COmpensated Densilog Compensated Neutron ~/p1a e se sign and return the attached copy as receipt '- of data. 11 Very. t_~aly yours, K. J. Sahlstrom North Engineering TR~N~.IITTAL # 330 DISTRIBUTION North G~',~. o,~,v ..... '-'-aa F~KXOrl I)ri]ling blobil -.Eng ' Manager Getty R & D Sohio Geology blarathon State of Alaska Phillips D & M 'Chevron ARCO Oil and G,~-,,Company Alaska Re~. , Post Office Box 360 Anchorage, Alaska g95'10 Telephone 907 277 5637 September 4, t979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine'Drive Anchorage, AK- 99501 Subject' WGI #2, Permit No. ~DS 3-10, Permit No. Permi t No . Dear Sir' 79-43 79-21 79-41 DS 14-6, Permit No. 78-65 DS 14-8, Permit No. 78-67 CPF-1-'23, Permit No. 79-42 Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned wells. .Very truly yours, P. ^. VanDusen District Drilling Engineer PAV'jh Enclosures i~RCO Oil and Gas Company Is a Division of AllanlicRichfieldCompany Form No. P-4 "~ REV. 3- !-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE [;. API NUMERICALCODE MONTHLY REPORT OF DRILLING LEASE DESIGNATIONANDSERiALNO. ,. AND WORKOVER OPERATIONS OIL wG~LL ~ OT~ER ----------' WELL ~] . ~NAME 2. NAME OF OPERATOR -------- ARC00~1 and Gas Company i~.UNIT FARM OR LEASE NAME 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 99501 4. LOCATION OF WELL I so. rlI~LD AND POOL, OR WILDCAT lPrudhoe Bay Fiel hoe Oil d-Prud 938'N & 44'W of SE cr Sec 18, TION, R15E UM I II. SEC. T.R.M.(,OTrOM ~ HOLE OBJECTIVE) lSec 17, TION, RI5E, UM I 12. PERMIT NO. [79-41 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND S/DE-TRACKED HOLE AND ANy OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Pool R~eport of Operations for the Month of August, 1979 Spudded well @ OlO0 hrs 8/14/79. Drld 17-1/2" hole to 2751'. Ran CAL DIL/SP/FL/GR, accoustic GR, & CDL/CN/GR logs. Ran & cmtd 13-3/8" 72// N-80 csg @ 272~' w/6000 sx Permafrost II cmt. Did 250 sx top job. Installed & tstd pkoff. NU & tstd BOP. Drld shoe + 12' new hole. Performed form leakoff tst Form held ll.8 ppg equiv. Drld 12 1/4" · - hole to 8894'. Ran DIL/SP/BHCS/GR, SPC/CNL/CAL/GR logs. Ran 9-5/8" 47# L-80 & S-95 csg to 8869'. Cmtd csg w/500 sx Class G cmt. Installed & tstd pkoff. Tstd csg. Ran TDT/GR log. Pumped 500 sx Permafrost II cmt dwn 9-5/8" x 13-3/8" annulus followed by 132 bbls Arctic Pack. Ran TDT/GR log. Tstd 13-3/8" x 9-5/8" annulus @ 1000 psi. Tstd csg to 3000 psi. Drld cmt shoe & 10' of new hole. Preparing to run leakoff tst as of 8/31/79. ' 14. I he,eby ~(~,~ the f~or~ing is ~ and correct SIGNED / . , ~ ~ ~_ TITLE [}i r' ' ' ' BATE MOTE-Report on this form is req ch calendar month, regardlesa of the status of operatiom, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month.unless otherwise directed. Alaska Oil and Gas Conservation Commission Hoyle H. Hamilton /~~/ Chairman of the Commissio~' Commissioner " August 20, 1979 Bobby D. Petroleum Inspector Witness BOPE test on ARCO's D.S.12, well #3 Sec. 18, T10N, R15E, UM Permit #79-41 Thursday, August..!6, .19,79 I departed Anchorage at 6:30 PM via Wien flight 19 for Deadhorse where I arrived at 9:10 PM. I was picked up at the airport by Mr. Mark Major, ARCO Drilling Foreman, and driven to the location, where I stoodby for the BOPE test. Fri.day, .August ~7..., 1979 The BOPE test began at I:00 PM and were concluded at 4:15 PR. The results of the test is attached to this report. I departed Deadhorse via SOHIO's Charter Flight #4 at 6:00 PM and arrived in Anchorage at 7:40 PM. In smnomary I witnessed the satisfactory BOPE test on ARCO's D.S.12 well #3. · , Alaska Oil and Gas Conservation Commission Field. Inspection.of Blowout Prevention Equipment Loca D~i! LOCR Wel 1 Cene tio.n-:' Sec '/~ -T/~/~R/.~C,-~fdT~ ' /~ Casing Set @ ~Y.~'~,.~ ft. ling Contractor~.~,~'~ -Rig #/'~J' Representi~tiv~./~ tion~ Ce. hera] :~/- - ACCUMULATOR SYSTEM_ Sign--%¢~- ~/'~..~ '' Full Charge Pressure~~O psig ral Housekeeping C)/~ ' Pressure After Closure/--y-m ~ psig Reserve pit Rig /~'~ Test Pressure o ..... BOPE S.tack Annular Prevente Pipe Rams B1 iud Rams Choke .Line Valves H.C.R.. Valve Kill Line Valves Check Valve Full Charge Pressure Attain in:~?, min-f'-5- sec. N2./~',/O~ ~%,:?,J-O ~oo_, /~o . psig Remote Controls 0'~" Psig Kelly and Floor Safety Va'lye's U~per'Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure C')~O Inside BOP, / Test Pressure, H ni o d// No.-Valves. No. flanges ~ ~ Adjustable Chokes, Hydrauically operated choke Test Results' Failures /~/O,~jC... Test T.~me. ,~ hrs. Repair or Replacement of failed equipment tO be made witl~tn ~.5//'~ daTs and Inspector/Commission office notified. . Distribution orig. - AO&U(;C cc - Operator cc - Supervisor ,~ A1 ~a Oil and Gas Conservation Comm~ pe Field Inspection Report Drlg. PermiJ~ N~o~L~/ /~,.~].~ Well/Platfm ...Sect'S. T/~)/~/l.~J~, Operator ~Z~/~]O Represented bb~.'/, .' /~ Name & Number....~), ~-~.':L~_.'-~='~ ~i.]~ ..... Satisfactory Type/Inspecti on Sati s Factory Type .Inspecti on Yes No Item (~)//Location,General Yes No Item (~q~OPE Tests ( ) (--)'~ 1. Well Sign (~/ ( ) 15. ~asing set @~..:~ (-~/~ ( ) 2. General Housekeeping (~)' ( ) '16 Test fluid-(~/i~cr.--]-~- )mud~( ) oil (~)~'~() 3 Reserve Pit-(/~l~pen( )filled (~)~" ( ) 17 Master Hyd. Control S.ys.~lOo..~:>.psig ( ) 4. Rig (~<?~ ( ) 18. N? btls.~/~.~,_~,~_~_~_?~2~'>_~psig ( ) Safety Valve Tests (,~/" ( ) 19 R~mote Controls ( ) ( ) 5. Surface-No. Wells (~ ( ) 20. Drilling spool-__j__I'outlets ( ) ( ) 6. Subsurface-No. Wells (~ ( ) 21. Kill Line-(~.~Check valve ( ) Well Test Data (,~)* ( ) 22. Choke Flowline (~)~HCR valve ( ) ( ) 7. Well Nos. , , , (~.. ( ) 23. Choke Manifold No. valvs~L~_flgs~' ( ) ( ) 8. Hrs. obseSS--~ ~ , (N~W ( ) 24 Chokes-(~,~R'emot~e( )Pos.(,L~Adj ( ) ( ) 9. BS&W ,--, ,-- (-.) ( ) 25 Test Plug-(-~)~/~llhd( )csg( )none ( ) ( ) 10. Gr. Bbls. , , , I~F ( ) 26. Annular Preventer~:~:~,psig ' ( ) Final A~andonment -- ,~ ( ) 27. Blind Rams~o~ ps~g ( ) ( ) 11. P&A Marker (,~)~' ( ) 28. Pipe Rams~ psig ( ) ( ) 12. Water well-( )capped( )plugged (~ ( ) 29. Kelly & Kelly-cock,$~._psi.q ( ) ( ) 13. Clean-up (~" ( ) 30. Lower Kelly valve,$'~.~ psig ( ) ( ) 14. Pad leveled (~)' ( ) 31 Safety Floor valves-~V (~-)q~rart Total inspection observation time hrs/days Total number leaks and/or equip, failures Remarks ~/~,~ ' ~ ' Notify in days or when ready July 18, 1979 Re: Prudhoe Bay Unit DS 12-3 Atlantic Richfield Company Permit No. 79-41 Sur. Loc.: 938'N & 44'W of SE cr Sec 18, T10N, R15E, UM. Bottomhole Loc.: 1320'N & 1320'E of SW cr Sec 17, T10N, R15E, UM. Mr'. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the abOve referenced well. Well samples, core chips and a mud log are not required. A direc- tional survey is required. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa_wning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. PollUtion of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. P. A. VanDusen Prudhoe Bay Unit DS 12-3 -2- July 18, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We'would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adeqUate advance notification so that we may have a witness present. 'Very truly yours, ~oyle ~.. Hamilton Chairman of Alaska Oil & Gas Conservation Commission Enc 1 osure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and'Gas ~'"'"3pany Alaska Regior, Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 16, 1979 Mr. Hoyle Hamilton State of Alaska A1 aska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 12-3 Dear Mr. Hamilton: Enclosed is our Application for Permit to Drill filing fee, and the required survey plat. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:jh Enclosures 12-3, the $100.00 RECFIVFD JUL Alaska 1;til ~. U.~s ~.,,~,~. uu~mnlssion ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401' REV. 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN TRIi ,TE (Other instructions on reverse side) PERMIT TO DRILL OR DEEPEN AP1 50-029-20377 $. 6. LEASE DESIGNATION AND SERIAL NO. ADL 28330 7. IF INDIAN, ALLOTTEE OR TRIBE NAME la~ TYPE OF WORK b. TYPE OF WELL OIL WELL ~'~ DRILL [] GAS WEI.L r~ DEEPEN [-~ 2. NAME OF OPERATOR SINGLE MULTIPLE OTHER ZONE [~ ZONE Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 560 Anchoraqe, AK 99510 4. LOCATION OF WELL At surface 938'N & 44'W of S/E cr Sec 18, TION, R15E,.UM At proposed prod. zone 1320'N & 1320'E of S~/cr Sec 17, T1ON, R15E, UM 13. DISTANCE IN MILES AND DIRECq~ON FROM NEAREST TOWN OR POST OFFICE* 2 Miles NE of Deadhorse 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO, DS ]2-3 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe ii. SEC.,T.,R.,M,,(,OTTOM Oil Pool HOLE OBJECTIVE) Sec 17, TION, R15E, UM 12. 14. BOND INFORMATION: nE Statewid~e~and/orNo. Federal Insurance Co. #8011-38-40 Amount $100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 73' RKB 1320' 2640' 16. :No. OF ACRES IN LEASE 2560 19. PROPOSED DEPTH 9521'TVD, 9749'MD 17. NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Ro ta ry 22. APPROX. DATE WORK WILL START 8/9/79 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 H-40 80 250 sx PF II to surface 17-1/2" 13-3/8" 72 MN-80 2700 Circ to surface--approx 5500 sx 12-1/4" 9-5/8 47 80&95 8891 1500' cmt column on 1st stage (a lO00 sx) plus 300 sx on 2nd sta.c. 8-1/2" 7" 29 N-80 9749 Approx 350 sx. pprox ;e. Atlantic Richfield Company proposes to directionally drill this well to 9749'MD (+9521'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# L-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. Well will be flowed to production facilities during perforating & testing. The downhole safety valve will be installed and tested upon conclusion of the job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dire6tionally, give pertinent data on sub~face locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certif~that the Foregoes is True~ud Correct DAr~ District Drilling Engineer roLE 7/2/79 (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: i SAMPLES AND CORE CHIPS REQUIRED I MUD LOG [] ~s 1~o [ [] YES ~No DIRECTIONAL SURVEY REQUIRED ~ LNO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE q APPOVED BY C/ v _ _ ,. . TITLE f *See Instruction On Reverse Side ~Y O~D~ O~~ ~-~ .-rv, 1 xr I ~ I G'/G DATE 7/18/79 T. ION.,R. L5 E. U.M. i 1 i .4, i I- I~ ~ t8, IZ 19 20 CFRTI FIC P, TE 0¢' .-- -j~...,f. , "¢ .,..... ! HERESY CERTiEY TH.aT I AM PROPERLY REGISTERED AND LICENSED TO PRA....T, E ,_A,,D SURVEYING iN THE STATE OF ALASKA At'JO THAT THIS PLAT /?EPRESENTS .-~ LOCATION SIJRVEY MADE B'r' hie OR UNDER MY SUPERVISION,AND ALL OIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE 0~ SURVEY SURVEYOR ;,~ '-'.. _. i --: 70 L '.;: P~ G. ?, -.'.. A T. } ,! ',l ;; t....,. ;/I 7.< L L_ L. AT. 70''-~ ,,- '?' 58.9-/£" ;_O;'.;O. ','; ;:': '" WELL . LAT. 70° 12'57.796" Y 5 9"1 14..8.'76 LONG. i4_2° 24-'22.729" X 697 563..31 Y 5 3}! 50%~.90 70° 17,' (]i) i5()" V '.-,9!'*! ~0-'_,.., ~ . 54 .... ~o 2q-'1'.3 "-'"¢"" X ~-i'~f - ~ f_, .:. ~..¢ . Y 5 c,..,', !08.00 ;4 69 -." 5 51 . S 3 0 EX!STING WELLOR CONDUCTOR PIPE RE '/I SIO bi [2,,AT E ARCO No. I ']1 ATLANTIC RICHFIELO CO. il DRILL 'SITE No.12 , ii WELLS No. I thru 4- ,' II LOCATED IN PROTRACTED SECTIONS 17 ~ 18,T. ION.,R.15E.~U.M. PREPARED _,BY HEWITT V. I._OU NS BURY 8~ ASSOC. 723 W. 6TM AVE., ANCHORAGEs. ALASKA DATE MAY 23,19Z'9 [SCAt. Z 1": 200' I ,"~n R'/ ,':. F.'. FIF'I D RK _OO::Sc_ LEAl':' . .. ' I ., '..:.?:.: .- e 7. 8. 9. 10. 3.' Is'. a registered .' - · 4. · Is l~a~ s~ce ........... , .' ...... ~ ..z:', .. -v ~', ~-..~ -_ 5. ~ mi1 l~a .: '~m ~ls .... - .............. __ ~, .~ . Is mi1 ~'~ "' ' · .... .,~ , . . . ~t ap~~ ~f0re ~ay' mit . . ~ ~ force ~S eee~eeeeeeeee eeeeeeee*eeeeeeeeeee 11. Is a conservation order needed ...................................... 'ac]ministrative appr~ needed 12. Is ................................... 13. Is conductor string ........................................ .. (2) Lcx~'...~. (3) / 14. 15. 16. 17. 18. 19. Is enough c~nent ussd' to circulate on conductor'and surface ......... ~. . W~l cement tie in.-surface and intermediate or production, strings ... _~~ Will csment cover all known productive horizons ..................... ~ ._ Will surface 'casing protect fresh ~ater zones ....................... ~_ Will all casing give adequate safety in collapse, tension and burst..~ Does BOPE have sufficient pressure rating -.Test to ~-0~<3 psig . .~ Approval Recoumended: Additional Requirements: · . . (4) (5) BOPE ~ Geology: Engineering: ' Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No 'special *effort has been made to chronologically organize this category of information. * SCHI, UMBERGER , HIGH RESOLUTION DIP~ETEI~ CLUSTER LISTING ATLANTIC RICNFIEbD CO. PRUDHOE BAY NORTH SbOPE , ALASRA 12-3 BUN NO. ONE JOB NO. CLU~TER RESULT8 ONI~Y 3516 4 FT. CORR. - ;2. FT. STEP ,RO DEG. X2 SEARCH ANGLE ATLANTIC RICHFIELD CO. 12-3 PAGE i-FILkl ~ FORMfiTION * BOREHOLE # OllAL. - . ............... ---. ................................. . ]NDE DEPTH * DIP DIP ~ AZI. . 8872 8874 8876 8878 8880 8882 8884 8886 8888 8890 8892 8894 8896 8~98 8900 8902 8904 8906 8908 8910 8912 8914 8916 89!8 8920 8922 8924 8926 8928 8930 8912 8934 8936 8940 8942 8944 894b 8948 8950 2.4 ]13 i .7 258 I .7 236 8.2 16 3.3 4.i 5.1 6.9 6.8 6.5 5.8 5.3 5.1 4.0 2.6 4.3 6.3 6.7 3.7 5.0 5.9 5.0 7.5 4.1 5.0 5.0 21.1 16.4 141 161 158 174 i73 169 173 163 t65 162 t80 154 14t 142 1:5 3 165 171 144 170 191 179 154 150 166 251 107 108 3.5 156 2.3 2.2 1.6 1.2 1.3 1.3 1.2 1.3 1.4 1.4 1.4 1.4 1.4 !.5 1.6 1.7 t.8 1.8 1.7 i.7 1.,7 1,,6 1.5 1.7 1,.9 io9 1.8 t.6 1.3 1.3 1.4 1.4 1.6 1.5 1.2 i.0 0.9 0.9 1.0 . DEV. DIA~ DIA~ * BEST AZI. 1'3 2-4 ~ :A 119 16.9 13.1 C 118 16.5 13.3 a 110 16.9 la.~ A 107 1~.0 ~5.6 106 17.6 15.7 C 103 15.6 13.5 103 14.5 11.4 105 15.6 12.! 105 15.8 12.7 A 105 15.~ 12.8 ~ 107 16.0 12.4 b 108 16.0 12.0 ~ 109 16.0 12.0 h Ili 15.8 11.9 A 112 15.4 11.6 C 1.12 lb.0 12.0 ~ 110 16.6 12.? C 109 16.4 11.9 A 107 17.0 13.3 A 107 17.5 14.5 C 109 17.~ 12.7 A 106 17.5 11.6 A 105 17.5 11.7 A 106 17.0 11.8 ~ t07 17.0 12.5 A !il 17.4 i2.6 A 113 17.4 12.6 A 115 17.3 13.1 A 115 16.9 12.7 a 115 15.2 12.0 112 14.4 11.9 111 15.6 11.9 A 114 16.5 11.8 a 116 17.0 11.7 C 115 16.9 12.2 C 115 17.1 13.3 1) 1i9 17.4 13.7 B 124 15.9 12.7 130 13.1 11.1 131 12.1 10.4 D ATLANTIC RICHFIELD CO. 12-3 PAGE 2-FILE: 2 DEPTH 8952 2.9 214 8954 2.2 223 :8956 8958 1.9 137 8960 1.9 166 8962 1.2 121 8964 0.9 251 8966 2.3 199 8968 8970 7.9 143 8972 5.5 t55 8974 8976 29.8 129 8978 23.0 132 8980 22.8 151 8982 25.5 161 8984 3.1 293 8986 3.1 288 8988 8.:7 127 8990 3.0 268 8992 10.6 88 8994 2.9 296 8996 2.2 ~29 8998 4.9 168 9000 6.1 141 9002 5.1 !31 900,4 3.8 116 9006 4.1 155 9008 4.0 152 9010 1.9 268 9012 8.1 t55 9014 5.9 146 9016 1.3 106 90t8 3.9 158 9020 6.5 146 9022 5.9 152 9024 5.2 153 9026 4.? 153 9028 8.0 173 9030 8.3 156 * FORMATION * BOREHOLE , , .................. , .................................. , DIP DIP * DEV. DEV. DIAM DIAM ~ AZI. * AZI. 1-3 2-4 1.0 0.9 1.1 1.3 1.1 0.9 t.1 0.9 0.7 0.8 0.8 0.8 0.8 0.8 0.8 0.8 0.9 0.9 1.0 1.0 1.0 1.0 1.0 1.1 t.2 1.P 1.2 i.2 1.2 1.2 1.4 1.4 1.4 t.5 1.5 1.6 1.6 1.7 1.8 128 14.2 12.0 178 16.0 t4.0 134 16.0 14.3 138 15.2 13.3 139 t4.9 12.3 143 14.9 11.9 155 14.4 12.0 157 14.0 12.2 155 14.9 13.3 160 15.7 14.1 158 15.0 13.5 153 14.2 13.~ 159 12.5 I 1.7 165 11.4 Il.1 167 11.4 11.3 167 10.5 10.1 t67 9.5 9.2 171 8.9 8.9 173 8.7 8.6 174 8.7 177 8.7 8.6 181 8.7 8.6 184 8.7 8.6 186 8.7 ~.6 187 8.7 8.6 185 8.8 8.6 184 8.9 8.8 187 9.1 9.1 192 9.3 9.4 192 9.2 9.4 191 9.2 9.3 191 9.1 9.3 192 9.1 9.4 193 9.2 9.6 193 9.2 9.7 191 9.0 9.7 189 9.0 9.9 188 0.1 9.8 190 9.2 9.7 192 9.1 9.5 ATLANTIC RICHFIELD CO. i2-3 PAGE 3-FILE , FORMATION , BOREHOLE * OIIAL. · .................. , .................................. # INDEX DEPTH ~ DIP DIP ~ DEV. DEV. DIAM DIA~ * BFST m AZIo * AZIo 1-3 2-4 # =A 9032 9034 9036 9038 9040 9042 9044 9046 9048 9050 9052 9054 9056 9058 9060 9062 9064 9068 9068 9070 9072 9074 9076 9078 9080 9082 9084 9086 9088 9090 9092 9094 9096 9098 9100 9102 9104 9106 9i08 9110 10.2 4.0 4.3 3,6 3.5 5.9 4.3 4.1 4,1 5.4 5.5 2,9 2.6 1.4 1.1 7.! 9.7 1.5 1.7 3.3 3.4 3.9 4.0 3.1 6.0 4.6 3.7 4.3 3.7 6.0 9.4 13.5 I1.8 i0.5 3.2 18i 225 165 189 132 155 174 52 !60 157 133 153 177 168 268 149 175 282 255 234 1i4 337 200 223 _232 248 192 194 156 112 172 151 119 161 146 190 186 147 t.8 193 9.1 9.2 C I .8 193 9.1 9.1 i.8 195 9.2 9.1 C 1.8 196 9.2 9.1 A I ,8 198 9.4 9.1 1,8 201 9.6 9.0 A t .8 202 9.6 9.0 A l.B 200 9.4 9.0 A 1.8 200 9.3 9.0 A ! .8 201 9.3 9.0 h 1.8 201 9.3 9.0 A I .8 203 9.3 9.0 A 1.8 205 9.2 9.0 A 1.8 200 9.2 9.0 A 1.8 203 9.0 9.0 A I .8 209 ~.9 9.0 1,8 209 8.9 9.0 A 1.8 200 8.9 q.O i .8 205 8.9 9.1 C 1.8 202 8.9 9.1 A 1.8 i99 9.0 9.1 1.8 198 8.9 9.1 1.8 197 8.9 8.9 C I .8 198 8.7 8.7 C 1.8 198 _8.5 8.6 A 1 .8 197 8.5 8.6 A 1.8 197 8.5 8.6 a I .8 198 8.5 8.6 C 1.8 199 8.4 8.6 A I .8 202 8.4 8.6 A 1.8 204 8.4 8.6 1.8 204 8.4 ~.6 t .8 205 8.4 ~.6 a 1.8 206 O.4 ~.~ C I .8 206 8.4 8.6 A 1.~ 206 8.4 8.6 A 1.8 205 8.4 8.6 C I .8 204 8.4 8.6 C I .8 204 8.4 8.6 A 1 .~ 204 8.4 8.6 2 ATLANTIC ~ICMFIELO CO. 12-3 PAGE 4-FIL~: 2 ******************************************************** ~** .#*****~ ~.~ *** ~ ~ FORMAT ION ~ BOREHOLE ~ OUAI,. ~ ~ .................. ~ .................................. ~ INI)~:% ~ DEPTH ~ DIP: DIP ~ DEV. DEV. D I i}~ Ola~ * BEST * ~ AZI. ~ ' bZI. 1-] 2-4 ~ =~ ~ 9112 18.8 9114 5.5 91t6 9ii8 5.9 9120 6.2 9122 3.5 9124 1.6 9126 1.1 9128 1.5 9130 9132 5.4 9134 9136 9138 9140 9t42 9144 9146 9148 9150 9152 9154 10.6 9156 2.8 9158 0.8 9160 2.6 9162 6.9 9t64 2.6 9166 3.8 9168 4.3 9170 7.6 9172 5.7 9174 4.0 9176 4.3 9178 2.9 9180 3.1 9182 11.5 9184 4.7 9186 7.3 9188 24.=7 9190 i .1 11 1.8 205 8.4 8.6 D 257 1 .lq 205 8.4 8.6 C t .8 205 8.4 8.6 257 1.8 205 ~.4 ;~.6 A 244 1.8 206 8.4 8.6 A t02 I .8 208 8.4 8.6 A 214 1.8 ~09 8.4 8.6 128 1.9 209 B.,~ 8.6 113 2.0 207 8.5 ~.6 A * 2.0 208 8.5 8.6 227 2.0 211 8.4 8.6 C 2.0 213 8.4 8.6 * 2.0 214 8.4 8.6 2.0 217 8.4 8.6 2.0 218 8.4 8.6 2.0 219 8.4 8.6 2.0 220 8.4 8.6 2.0 219 8.4 8.6 2.0 207 8.4 8.6 2.0 208 8.4 8.6 2.0 220 8.4 8.6 130 2.0 220 8.4 8.6 A 128 2.0 219 8.4 8.6 A 65 2.0 217 8.4 8.6 A 93 2.0 215 8.4 8.6 92 2.0 215 8.4 B.6 C * 180 2.0 215 8.4 8.7 C 220 2.0 215 f~.4 ~.7 g 245 2.0 217 8.4 8.6 A , 222 2.0 215 ~.4 8.6 C 150 2.0 208 8.5 8.7 A 173 2.0 206 8.9 9.0 a . 178 2.0 204 9.2 9.4 161 2.0 204 8.9 9.0 A , 130 2.0 204 8.5 8.5 A . 2!5 2.0 203 8.4 g.4 A 178 2.0 201 8.4 8.4 C 78 2.0 201 8.3 ~.4 C 172 2.0 203 8.3 8.4 i63 2.0 205 8.3 8.4 C , ATbANTIC RICHFIEbD CO. 12-3 PAGE * FORMATION # MOREHObE DEPTH * DIP DIP . DEV. DEV. DIAM ~ AZI. * AZI. 1-3 919~ 9194 9196 9t98 9200 9202 9204 9206 9208 9210 9212 92i4 9216 92i~ 9220 9222 9224 9226 9228 9230 9232 9234 9236 9238 9240 9242 9244 9246 9248 9250 9252 9254 9256 9258 9260 9262 9264 9266 9270 3.~ 1~9 6.9 I45 20.2 164 4.7 5.~ 6.1 7.9 5.8 8.? 4.7 2.3 2.4 6.1 7.9 15.0 7.3 5.1 17.7 17.6 6.8 2.5 8.6 7.0 5.5 5.7 4.2 2.8 5.8 6.3 5.5 5.5 166 155 162 132 28t 272 322 246 200 178 172 164 109 107 207 203 182 240 226 228 235 221 t80 182 141 i44 155 140 , OIAM * BEST 2-4 * :A 2.0 204 8.3 8.4 A 2.0 204 8.3 8.4 A , 2.0 204 8.3 8.4 B 2.0 206 8.4 8.4 * 2.0 209 8.4 8.4 A 2.0 212 8.4 8.4 A 2.0 217 8.4 8.5 C 2.0 219 8.4 8.S C 2.0 219 8.4 8.5 D 2.0 217 8.4 8.5 . 2.0 215 8.4 8.5 B 2.0 214 8.4 8.5 * 2.0 211 8.5 8.6 2.0 207 8.5 8.6 2.1 204 8.5 8.6 b 2.1 198 8.7 8.~ s , 2.2 196 9.2 9.1 B 2.2 206 9.0 8.9 D * 2.2 214 8.5 8.5 B 2.2 215 8.4 8.4 D 2.2 2t7 8.4 8.4 2.2 217 8.4 8.4 D 2.2 216 8.4 8.4 2.2 215 8.4 8.4 2.2 216 8.4 8.4 D 2.2 215 8.4 8.4 D 2.2 216 8.4 8.4 B 2.2 217 8.4 8.4 2.2 217 8.4 8.4 A 2.2 217 8.4 8.4 A * 2.2 217 8.4 8.4 A 2.2 216 8.4 8.4 C 2.2 215 8.4 8.5 A 2.2 213 8.4 8.5 C * 2.2 211 8.5 8.6 C * 2.2 209 8.5 8.6 * 2.2 205 8.4 8.5 2.2 202 8.4 8.4 A . 2.1 198 8.4 8.4 2.0 197 8.4 8.3 ATLANTiC RICHFIEhD CO. 12-3 PAGE 6-FII,E ~ ................. -, .............................. , DEPTH * DIP DiP ~ DEV. DEV. D ~ , AZI. * AZI. ************************************************** 9272 9274 9276 9278 9280 9282 9284 9286 9288 9290 9292 9294 9296 9298 9300 930~ 9304 93O6 9308 9310 9312 9314 9316 9318 9320 9322 9324 9326 9328 9330 9332 9334 9336 9338 ~340 93q2 934~ 9346 934~ 9350 6.9 i65 2.0 200 8.4 8.3 A 6.4 148 2.0 204 8.4 8.3 A 6.6 95 2.0 204 8.4 8.4 C 5.9 ~t5 2.0 20t 8.4 ~.4 17.4 285 2.0 203 8.~ 8.6 R * 18.9 28i 2.1 204 9.0 9.5 i2.4 225 2.2 207 9.1 9.6 D 13.7 215 2.2 213 8.6 ~.7 9.4 132 2.2 212 8.3 8.3 D 9.8 107 2.2 207 8.3 8.~ D . 4.2 t53 2.2 208 8.4 ~.3 4.5 150 2.2 214 8.4 8.3 2.8 57 2.2 217 8.5 8.3 B 3.5 ' ~3 2.2 217 8.7 S.7 b 5.3 1t3 2.2 218 8.8 8.7 D 4.9 112 2.2 219 8.5 8.4 b 7.0 133 2.2 222 8.3 8.2 11.9 120 2.2 223 8.3 8.2 I1.~ 123 2.2 220 8.3 8.2 10.! 154 2.2 214 8.3 8.2 8.5 .157 2.2 21I 8.3 8.2 b * 5.7 255 2.2 209 8.3 8.3 8.1 208 2.2 206 8.3 8.2 D 2.2 204 8.3 8.2 , 2.2 206 8.3 8.2 2.2 208 8.3 ~.2 10.7 248 2.2 207 8.4 S.2 O , 7.1 257 2.2 207 ~.4 8.2 5.9 318 2.2 203 8.4 8.2 D 6.9 339 2.2 206 8.4 8.2 D 4.1 2-63 2.2 215 8.4 8.2 5.t 182 2.2 210 ~.3 ~.3 b 2.2 203 8.3 8.3 10.3 153 2.2 208 8.4 8.3 A ii.3 169 2.2 216 8.4 8.3 C 7.7 204 2.2 2~6 8.4 8.3 C , 14.1 230 2.2 216 8.4 8.3 C , 2.2 216 ~.4 ~.3 * 0.0 0 2.2 216 8.4 ~.3 C * 1.6 130 2.2 2t7 8.4 ~.3 ATLANTIC RICHFIibD CO. 12-3 PAGg 7-FII,~ , ........... .=--.=., .................................. , INDEX DEPTH ~ DiP DIP # DEV. DEV. DIAM DIAM # BEST . # AZ1. * AZI. 5.4 7.3 3'5 5.9 7.6 6.4 14.6 3.0 t0.3 7.6 10.0 11.8 6.3 28.0 18.6 28.4 9352 9354 9356 9358 9360 9362 9364 9366 9368 9370 9372 9374 9376 9.378 9380 9382 9384 938b 9388 9390 9392 9394 9396 9398 9400 9402 9404 9406 ~408 9410 94t2 9414 9416 9418 9420 9422 9424 9426 9428 9430 201 202 154 i59 187 188 146 140 153 186 169 211 210 206 196 198 188 1:7.8 3.5 1.5 3.1 5.9 1.7 3.3 4.9 13.6 16.5 9.8 11.2 9.1 4.5 4.2 4.1 9.6 9.5 1.9 2.3 6.3 5.7 198 28 262 189 202 3O2 199 232 165 166 I56 160 193 288 274 269 287 360 293 84 235 190 2-4 * cA 2.2 217 8.4 8.3 fi . 2.2 217 8.4 8.3 C 2.2 218 8.4 8.3 A 2.2 218 8.4 8.3 A 2.2 219 8.3 8.3 A 2.2 218 8.3 8.3 A 2.2 217 8.3 8.3 A 2.2 215 8.3 8.3 C 2.2 214 8.3 8.4 A 2.2 214 8.3 8.4 C 2.2 214 8.3 8.4 C 2.2 213 ~a.3 8.4 C 2.2 213 8.3 8.4 C 2.3 214 8.4 8.4 $ 2.2 213 8.4 8.5 B 2.2 2t3 8.4 8.8 D 2.3 214 8.4 9.0 D 2.4 214 8.4 8.9 2.4 215 8.4 8.6 P 2.4 218 8.4 8.5 D 2.4 221 8.4 8.3 D 2.4 221 8.4 8.3 D 2.4 221 8.3 8.3 B 2.4 221 8.4 8.3 ~ 2.4 221 8.4 8.4 A 2.4 220 R.4 8.4 A 2.4 219 8.4 8.5 A 2.4 218 8.4 ~.4 A 2.4 218 8.4 8.5 A P..4 219 8.4 ~.4 A 2.4 219 8.4 8.4 ;% 2.4 218 8.4 8.4 C 2.4 216 8.4 8.5 A 2.4 220 8.4 u.5 A 2.4 224 8.4 {3.6 A 2.4 222 8.4 R.5 C 2.4 ~22 8.4 8.4 A 2.4 223 B .4 8.5 ~ 2.4 225 8.4 8.5 C 2.4 223 8.4 8.4 A 2 AThANTIC RICHFIELD CO. 12-3 PAGE 8-FILE ~ ~ FORNAT ION ~ BOREHOLE ~ QUAL. ~ ~ .................. ~ .................................. ~ INDFX * D~PTH * DIP DIP . DE~. DEV. DIAM DIAM , BEST ~ AZI, ~ AZI. 1-3 ~-4 ~ :A 943~ 9434 9436 943~ 9440 9442 9444 944b 9448 94.50 9452 9454 9456 9458 9460 9462 9464 9466 9468 947O 9472 9474 9476 94'/8 9480 9482 9484 948b 9488 9490 9492 9494 9496 9498 9500 9502 9504 9506 9508 95i0 2.1 8.3 1,2 1.7 6.7 6.2 5.2 17.6 7.1 1.I 1.5 3.¢ 3.0 5.1 6.3 6.2 10.1 10.0 3.3 7.9 7.1 8.9 2.5 2.2 1.4 1.9 2.4 2.3 2.8 3.0 21.2 20.7 19.9 95 274 165 200 149 102 i62 167 47 107 62 143 Ii0 144 146 152 181 164 162 16t !-54 164 i97 180 194 182 176 179 52 39 60 7:.5 I i0 3.9 109 8.2 89 5.7 87 2 2.4 216 8.4 8.4 A 2.4 209 8.5 8.4 C 2.4 206 8.5 8.3 A 2.4 205 8.5 ~.3 A 2.4 203 8.5 8.3 C , 2.4 2,00 8.5 8.3 C 2.4 198 8.5 8.4 C 2.4 196 8.6 8.5 B , 2.4 196 8.6 8.4 A * 2.4 197 8.5 8.3 a 2.4 199 8.5 8.3 A * 2.4 199 8.5 8.3 A . 2.4 199 8.5 B.3 A 2.4 199 8.5 8.3 C 2.4 200 8.5 8.3 a * 2.4 202 8.5 8.4 ;% , 2.4 204 8.5 8.5 /~ , 2.4 203 8.4 8.5 a 2.4 203 8.6 8.5 2.4 205 8.6 ~.6 C 2.4 209 8.5 8.6 A . 2.4 217. 8.~ 8.g A 2.4 215 9.1 9.2 A 2.4 215 9.1 9.2 A , 2.4 216 9.1 9.2 2.4 217 9.2 9.4 2.4 216 9.1 0.2 2.4 213 8.9 9.1 A , 2.4 211 8.9 9.0 A ~.4 208 9.0 9.0 A 2.5 206 9.0 9.1 A * 2.6 206 9.0 9.0 A 2.6 208 8.8 8.8 '2.6 210 8.5 8.6 a 2.6 212 8.5 8.6 C 2.6 213 8.5 8.6 2.6 210 8.5 8.5 C 2.6 207 8.5 8.5 2.5 201 8.5 ~.6 A , 2.4 196 8.5 ~.6 A -. / ATLANTIC RICHFIELD ,CO. 12-3 PAGE 9-FILl: . . FORMATIO~ * DEPTH ~ DIP DIP . DEV * ~ .~ZI. 95t2 9514 95!6 9518 9520 9522 9524 9526 9528 9530 9532 9534 9536 9538 9540 9542 9544 9546 9548 9550 9552 9554 9556 9558 9560 9562 9564 9566 9568 9570 9572 9574 9576 9578 9580 9582 9584 9586 95~8 959O 3~9 7.0 1.8 5.9 3.4 1.0 I.'4 0.8 1.9 !.0 3.5 4.6 7.7 10.5 7.0 6.4 2.4 1.0 $.0 5.8 4.5 9.0 8.0 10.1 10.9 8.0 4.9 0.5 2.2 8.5 6.8 8.2 10.5 8.8 10.3 11.4 11.5 187 60 3O 189 179 193 296 158 172 127 47 39 71 68 253 2i2 185 145 170 71 7O 176 247 139 143 51 209 117 ~0~ 215 29O 299 299 132 118 BO~EHOi, E # QUAL. ............................ , INDEX . DEV. DIA~ DIAM ~ BEST AZI. J'3 2-4 2.4 20t 8.5 8.6 A 2.4 208 8.5 8.6 A 2.4 213 8.5 8.6 C 2.4 213 8.5 8.6 A 2.4 215 8.8 9.0 A 2.4 219 9.2 9.3 C 2.4 219 9.2 9.4 C 2.4 216 9.1 9.2 ~ 2.4 217 8.9 8.9 ~ 2.4 219 8.9 8.R ~. 2.4 217 8.8 8.7 ~ 2.4 216 8.6 8.6 A 2.4 217 8.5 8.6 a 2.4 218 8.5 8.6 a 2.4 219 8.5 8.6 A 2.5 218 8.5 8.5 C 2.6 2.16 8.5 8.6 A 2.5 216 8.5 8.5 A 2.5 216 8.5 8.5 A 2.4 217 8.5 8.4 A 2.4 216 8.5 8.5 A 2.4 213 8.5 8.5 ~ 2.5 207 8.5 8.6 a 2.6 205 8.5 8.5 C 2.6 210 8.5 8.5 C 2.6 215 8.5 8.5 A 2.6 2-17 8.5 8.4 C 2.6 219 B.5 8.4 C 2.6 223 8.5 8.4 A 2.6 224 8.5 8.4 A 2.6 221 8.5 8.4 ~ 2.6 219 8.5 8.4 A 2.6 217 8.5 8.3 1~ 2.6 215 8.5 8.3 A 2.6 211 8.5 8.4 A 2.6 208 8.6 8.5 A 2.6 209 8.6 8.5 C 2.6 209 8.5 !~.3 ~ 2.5 205 8.5 8.4 B 2.4 199 8.4 8.4 B ATLANTIC RICHFIELD 'CO. 12-3 *************************************************** ~ FORMATION , BOREHOL ~~wwm~t~~~~~~~~ DEPTH ~ DIP DIP 9592 4.9 9594 3.6 9596 9598 12.5 9600 13.3 9609 3.3 9604 4,0 9606 2.7 9608 1.3 9610 6.1 9612 2.2 9614 2,0 9610 2.3 9618 1.2 9620 2.5 9622 ~.7 9624 11.4 9526 9.4 9628 3.3 9630 3.2 9632 2.7 9634 9636 5.0 9638 4.2 9640 6.3 9642 2.2 9644 4.5 9646 9648 9650 9652 3.3 9654 3.8 9656 6.4 9658 9660 i.8 9662 2.1 9664 4.6 9665 10.4 9668 6.7 9670 5.1 DEV. DEV. DI AZI. 106 2.4 199 67 2.4 204 256 2.4 211 204 2.4 214 206 2.4 215 109 2.4 216 84 2.4 215 27 2.4 2].3 90 2.5 212 117 2.6 213 49 2.6 213 32 2.6 4 2.6 211 43 2.6 211 345 2.6 212 308 2.6 214 257 2.6 214 234 2.6 ~18 199 2.6 223 1~7 2.6 222 165 2.6 216 2.6 211 262 2.6 210 223 2.5 205 ~24 2.4 200 61 2.4 198 161 2.4 20O 139 2.4 204 2.4 2O5 2.'4 207 114 2.4 212 102 2.4 211 66 2.4 209 127 2.4 210 133 2.4 211 157 2.4 212 1~8 2.4 211 212 2.4 2i0 t06 2.5 210 90 2.6 2~1 PAGE lO-FILE ********************** E , QUAL. DIA~ ~ BEST -3 2-4 * :A ********************** 8.4 8.4 A 8.4 8.4 8.4 8.4 8.4 8.5 8.4 8.5 8.4 8.6 ,~, 8.5 8.6 A 8.5 8.6 A 8.5 8.6 a , 8.5 ,8.6 9.5 8.6 A 8.5 8.6 A * 8.5 8.6 A .8.5 8 · 6 A 8.7 8.7 A * 8.8 .8.9 A 8.9 8.9 A 8.9 9.0 A , B .9 9.0 A 8.,q 8.9 A * 8.6 8.7 A H.5 8.7 8.7 8.8 A 8.8 8.8 A 8.6 8.6 A B.8 8.8.. A 8.9 8.9 8.8 8.c~ A 8.7 8.9 * 8.7 8.~ 8.6 8.7 A 8.6 8.7 A , 8.7 ~. 8 A 8.9 8.9 8.9 9.0 8.9 9.0 A 9.0 9.0 A 9.0 9.1 C 9.0 9.1 C 8.9 9.0 A , ATLANTIC RICHFIELD CO. 12'3 PAGE Il-FILE ~ FOR~A~'ION ~ BOREHOLE * OUAL. ~ .......... ' ....... ~ .................................. ~ INDEX DEPTH * DIP DIP ~ DEV. DEV. DIAM DIAN * BEST ~ hZI. ~ hZI. 1-3 2-4 ~ =~ 9672 0.8 t91 ~.6 212 9.0 9. ~ A 9674 0.6 183 2.5 211 9.1 9. I A 9676 0.7 216 : 2.5 212 9.3 9.2 a 967B 2.2 ~94 2.5 2~ 9.4 9,3 A 9680 0.4 ~28 2.6 2~5 9.2 9.2 C 9682 ~ .4 204 2.6 214 9.1 9.0 ~. 9684 1.1 206 2.5 212 9.0 9.0 A 9686 1.0 204 ~.4 205 8.9 9.0 A 9688 1.3 180 2.4 207 ~.9 9.0 ~ 9690 ~ ,3 ~99 2.4 214 8.9 9.0 ~ 9692 i .8 214 2.3 215 8.9 9.0 A 9694 1 .3 189 2.3 215 9.0 9.0 A 9696 0,4 229 2.3 2t4 9.0 9.0 a 9698 I .1 210 2.3 213 a.9 9.0 a 9700 2.2 !88 2.3 210 8.9 8.8 a 9702 1.7 179 2.2 210 8.9 8.7 b 9704 ~ .6 178 2.2 210 8.9 ~.7 a 9706 1.4 194 2.2 210 8.~ 8.7 a 9708 2.2 ~i4 2,3 21~ 8.7 8.7 a 9710 0.6 150 2.3 211 8.8 ~.8 ~ 9712 3:.! 230 2.2 208 8.9 8.9 a 9714 2.8 218 2.2 206 ~.9 8.9 A 97~6 2.2 202 2.1 206 8.9 8.9 A 9718 2.7 197 2.0 204 8.9 8.9 f~ 9720 2.8 194 2.0 202 8.9 9.0 a 9722 2,6 181 2.0 204 8.9 9.0 A 9724 2.5 186 2.0 207 8.9 9.0 A 9726 3.1 202 2.0 207 8.8 9.0 A 9728 3.5 191 ~.9 ~06 8.7 9.0 g 9730 2.3 166 I .9 ~12 8.7 9.0 A 9732 1.7 I65 2.0 212 8.8 9.0 A 9734 i .9 175 2.0 207 8.~ 9.0 g 9736 1.6 166 2.0 2~0 ~.8 9.0 A 9738 I .4 164 1.9 211 8.8 9.0 A 9740 I .7 160 1.9 ~11 B.9 B.g a 9742 2.0 170 1.g 211 8.9 ~.9 ~ 9744 3.2 195 1.8 208 8.9 9.0 A gTLANTiC RICHFIEbD CO. 12-3 PAGF 1.-VILE 1 ~ DEPT~ ~ DIP DIP * * hZI. 8962 8964 8966 8968 8970 8972 8974 8976 8978 8980 8986 8988 8990 8992 8994 8996 8998 9000 9002 9004 9006 9008 9010 9012 901:4 9016 9018 9020 9022 9024 9026 9028 9030 9032 9034 9036 9038 90qO 2.1 i73 6.6 162 t8.2 174 t3.5 176 il.6 174 6.7 175 24,1 153 27.6 162 29.9 162 10.3 311 6.2 311 ~.6 283 2.3 98 3.4 203 6.6 t54 5.7 146 2.5 188 2.0 141 6.8 145 6.7 130 3.1 190 6.3 146 3.9 149 1..5 153 6.2 177 7.6 i54 6.8 146 7.o 154 5.8 128 4.6 178 9.3 180 4.6 221 7.3 200 3.O 156 3.-7 t80 3.8 125 BOREHOLE * QUAD. ............................... , INDEX DFV. DEV. DIAM DIASJ . BEST AZI. I -3 2-4 * 0.8 144 12.2 16.5 0.8 146 12.3 16.1 0.8 153 12.3 15.7 0.9 159 11.8 14.4 1.0 165 11.7 14.3 1.1 169 12.? 15.1 ! .I 169 12.6 14.5 1.0 1'11 11.7 12.7 1.0 178 11.0 11.5 1.0 183 11.1 11.5 I .0 190 9.9 10.6 I .I 195 9.2 9.7 1.2 i96 8.8 9.2 1.2 193 8.6 9.0 1.2 192 8.5 8.9 I .2 196 8.5 8.9 1.2 199 8.5 8.9 1.2 199 8.5 8.9 1.2 197 ~,.5 8.9 1.2 197 8.5 8.9 1.3 196 8.6 8.9 1.3 192 8.7 9.1 1.3 188 9.0 9.3 I .4 ]88 9.2 9.4 1.4 190 9.2 9.3 t .4 192 9.2 9.2 1.4 193 9.2 9.2 I .4 194 9.2 9.2 I .4 1_94 9.4 9.4 I .4 193 9.5 1.4 192 9.6 9.2 1.4 192 9.7 9.2 1.4 193 9.6 9.3 I. 4 1 q 2 9.7 9.3 1.4 t91 9.7 9.2 i .4 191 9.4 1.4 186 9.2 9.2 i .4 183 9.0 9.2 I .4 186 8.9 9.0 1.4 188 8.9 ~.S ATbANTIC RICHFIELD CO. 12-3 PAGE 2-FILE 1 ~ * FORMATION · DEPTH * DIP DIP ~ DEVo 9042 9044 9046 9048 9050 9052 9054 9056 9058 9060 9062 9064 9066 9068 9070 9072 9074 9076 9078 9080 9082 9084 9086 9088 9090 9092 9094 9096 9098 9100 9102 9104 9106 9i0~ 9i10 9112 9114 9ii6 9ii8 9120 8.0 163 3.6 94 5 .-7 23 5.3 155 4.4 144 6.0 133 5.5 14i 2.6 167 2.2 176 I .6 260 4.1 261 6.5 147 6.3 57 5.8 64 1.3 242 ! .7 247 2 .,I 259 3.1 86 2.9 52 4.1 218_ 5.1 246 7.I 265 3=.6 260 7.0 2i0 7.5 211 0.4 104 3.1 70 29.1 230 29.4 224 8.9 129 7.4 i33 6.8 1i7 14.2 i33 3.0 228 6.0 183 I1.0 132 7.5 251 6.9 255 6.7 239 1.4 1.4 1.5 1.6 1.6 1.6 1.7 1.8 1.8 1.8 1.8 1.8 1.9 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 2.0 1.9 1.8 1.8 1.8 1.8 1.7 1.6 1.6 1.6 1.5 1.4 1.4 1.4 1.4 1.5 1.5 BOREHOLE . QUAL. ....................... * INDEX DEV. DIAE DIAM , BEST AZI. 1-3 2-4 ~ :A 193 8.9 8.7 C 193 8.9 8.5 189 8.8 8.2 C 1.91 8.8 8.2 A * 193 8.8 8.6 A * 194 8.9 8.8 196 8.9 8.5 A 199 8.9 8.3 A 202 8.9 8.2 A 206 8.9 8.1 A 209 8.9 8.1 A 210 8.9 8.1 212 8.9 8.1 C * 214 8.9 8.1 C 215 8.9 ~.1 A , 213 8.9 8.2 A * 210 8.9 8.1 214 8.8 8.0 A * 221 8.6 7.9 223 8.5 7.8 ~ * 221 8.5 7.8 A 219 8.5 7.8 C 217 8.5 7.8 A 216 8.5 7.8 C 213 8.5 7.8 A 210 8.5 7.8 A , 211 8.5 7.9 211 8.5 7.9 D , 208 8.5 7.9 203 8.5 7.9 A 194 8.5 7.8 191 8.5 7.8 C 198 8.5 7.8 C 199 8.5 7.8 C 199 8.5 7.8 C * 199 8.5 7.8 C 198 8.5 7.8 C 197 8.5 7.~ * 200 8.5 7.9 206 3 8.5 8. ATLANTIC RICHFIELD CO, 12-3 PAGF 3-P'ILE ************************************************************************* * FORMATION , BOREHOLE , OUAI,. ~ .................. , .................................. * INDEX DEPTH , DIP DIP , DEV. DEV. D . AZI. * AZI. 9122 9124 9~26 9198 9130 9132 9134 9136 9i38 9140 9142 9144 9146 914~ 9150 9t52 9154 9156 9!58 9100 9162 9164 9166 9168 9170 9172 9174 9176 9178 9180 9182 9t84 9186 9!88 9190 9192 9194 9196 9198 9200 3.5 ti t .4 210 1.4 44 I .5 211 0.7 63 1.6 210 i.0 82 1.6 210 1.7 213 2.0 252 l.B 215 5.7 203 1.8 216 1.8 221 6.1 205, 1.9 227 2.0 228 !3.0 192 2.0 228 2.0 22~ 7.3 220 2.0 215 4.8 212 2.0 215 2.0 228 7.8 172 2.0 227 ~0.4 144 2.0 227 2.-5 128 2.0 226 3.5 145 2.0 224 1.0 133 2.0 223 9.0 52 2.0 224 2.7 181 2.0 294 -4.3 225 2.0 222 5.3 229 2.0 223 2.0 223 6.3 162 2.0 219 4.4 174 2.0 213 4.1 181 2.0 210 4.4 164 2.0 208 4.0 140 1.9 206 t2.6 218 1.8 203 7.1 i19 1.8 201 3.2 350 1.8 199 1.7 200 7.6 148 1.6 205 5.9 135 1.6 204 8.0 125 1.6 ~01 1.6 202 1.6 204 4.3 167 1.6 207 1AM DIAM 1-3 2-4 * =A *********************** 8.5 8.5 A 8.5 8.4 C 8.5 8.4 ;~ 8.5 8.4 8.5 8.4 8.5 8.s A 8.5 ~.6 D 8.5 8,5 8.6 D 8.5 8.5 8.6 D 8.5 8.5 8.6 D 8.5 8.6 8.5 8.6 8.5 8.6 r) 8.5 8.6 A 8.5 8.6 8.5 8.6 C 8.5 8.6 A 8.5 8.6 C 8.5 8.7 A R.5 ~.7 A ~,.5 8.7 8.5 8.5 8.6 A ~.9 9,0 A 9.2 9.3 ;l 8.9 9.1 A 8.6 R.7 A 8.5 8.6 h 8.5 8.6 ~ 8.5 8.6 C 8.5 ~.6 8.5 8.6 8.5 8.6 A 8.5 8,6 A 8.5 ~ .6 8.5 _B .6 8.5 ~. 6 A *********************** ATbANTIC RICHFIELD CO. 12-3 PAGE 4-FILE ~ FORMATION ~ BO~EHOhE DEPTH * DiP DIP * 'DEV. DEV. DIAM D · aZl. , azI. 1-3 9202 4.9 157 1.6 2i2 8.5 9204 5.5 123 1.6 21b 9206 2,7 134 1,6 218 8.5 9208 io5 48 1.6 218 9210 1.? 216 ~.5 9212 1.8 213 8.5 9214 I1.0 ]57 1.9~ 211 8.5 92i6 2.0 210 8.5 9218 2.0 207 8.5 9220 5.1 320 2.1 207 ~.5 9222 1.2 228 2.2 211 8.0 9224 2.0 165 2.2 210 0.2 9226 1.8 287 2.2 213 9.0 9228 7.6 17b 2.2 220 8.6 · 9230 2.2 222 B.5 9232 11.2 332 2.2 222 8.5 9234 2.9 73 2.2 222 8,5 9236 8.5 337 2.2 222 8.5 9238 12,4 334 2.2 222 8.5 9240 15.7 223 2,2 221 8.5 9242 15,4 219 2.2 221 8.4 92q4 6.0 !~O 2.2 221 8.4 9246 1.9 197 2.2 220 8.4 9248 4.4 205 2.2 220 8,5 9250 6.9 198 2.2 220 8.5 9252 7.6 200 2.2 220 9254 7,0 200 2.2 222 8.5 9256 6,1 192 2.2 221 8.5 9258 5.5 178 2.2 221 8.5 9260 4.0 128 2,2 218 8.5 9262 2.2 212 8.5 9264 2.2 207 92~6 5.6 159 2.2 202 8.5 926~ 8.2 137 2.1 199 8.4 9270 6.0 141 2,1 199 8.4 9272 7.1 169 2.2 202 8.4 9274 3.5 125 2.2 204 8.4 92~6 6.9 99 2.1 204 8.5 9278 4.5 30i 2.2 204 8.5 9280 18.8 283 2.2 204 8.5 ..... 1 AN 2-4 8.6 ~.6 C 8.6 g 8.6 C 8.6 B.6 8.6 C 8.6 8.6 8.6 8.9 a 9.2 9.0 P, 8.7 ~ 8.6 8.6 B. 6 l) 8.6 I) 8.6 D 8.6 P 8.6 F~ 8.6 A 8.6 8.6 A A 8.6 C 8.6 C 8.6 8.6 B 8.6 8.6 8.6 8.6 B. 6 f) 8.6 D 8.7 **** ~****~**~, ~TLANTIC RICHFIELD CO. 12-~ PAGE ~ FORMATION * BOREHOLE .... DEPTH * DIP DIP , DEV. DEV. D]AM DIAN ~ AZI. ~ AZI. 1-3 2-4 9282: 18.0 279 2.1 206 9.0 9.6 9284 i5.5 204 2.1 204 9.2 9286 2.2 206 8.7 9.0 9288 9.6 ~16 2.2 206 8.5 8.6 9290 2.2 199 8.5 9292 4.2 ~41 2.2 200 8.5 9294 4,5 140 2.2 209 8.5 8.7 9296 4.] 50 2.~ 2~0 ¢.6 9298 2,4 47 ~,0 ~0 8.8 9.~ 9300 2.5 85 2.0 2J5 8.7 9.0 9302 6,6 ~04 2,0 2~9 8.3 8.6 9304 2.0 222 8.J 8.4 9[]06 ~,5 104 2.0 224 8.~ 9.~08 ~.5 ~07 2,0 . 223 8.J 93~0 2.0 2~9 R. ~ 8.4 9]~2 9.8 ~44 2.0 2J7 8.~ B.4 9316 2.2 213 8.1 9.t18 19.9 156 2.2 2~1 8.1 9320 21.0 150 2.2 211 B.l 9322 20.2 144 2.3 212 8.1 '~324 2.3 21i B.1 8.4 9326 6.6 256 2.4 210 B.1 9328 7.4 172 2.4 199 8.1 8.4 9130 4'7 I67 2.4 205 8.1 8.4 9332 4.8 242 2.4 220 ~.1 8.4 9~34 ].1 183 2.4 219 8.1 8.4 9336 10.6 135 2.4 21~ ~.~ 9318 10.7 1.56 2.4 217 8.~ 8.4 9340 6.] I64 2.4 217 ~.1 9342 8.3 206 2.4 219 8.1 8.4 9-~44 10.9 21} 2.4 218 8.1 9~46 i5.3 i80 ~.4 219 8.1 ~.5 9~48 2.6 ~3 2.4 223 8.1 8.6 9~50 6.5 i50 2.4 225 8.1 8.5 9352 8.7 161 2.4 224 8.1 8.5 9354 8.9 ~53 2.4 ~3 B.i 8.6 9356 8.6 139 2.4 223 8.1 B.5 9358 15.3 142 2.4 223 8.~ 9360 4.8 199 2.4 223 8.t 6.4 # FORMATION . BOREHO DEPTH # DIP DiP # DEV. DEV. D * AZI. * AZI. 9362 t0.3 180 2.4 221 9364 7.1 134 2.3 217 9366 3.6 114 2.2 200 9368 4.7 153 2.1 183 9370 2.0 ~87 9~72 2.0 200 937~ 5.7 ~74 ~.! 202 9376 4.5 241 2.2 201 9378 1.4 195 2.2 203 9380 2.2 203 9382 2.2 203 9384 2.2 205 PAGE 6-FILE hE ~ OURL. .............. # INDEX lAM DIR~ # BEST 1-3 2-4 ~ cA. 8.1 8.4 8.1 _~.4 8.1 8.5 D 8.0 8.5 D 7.8 8.3 8.0 8.3 8.2 8.3 D 8.? 8.3 8.2 8.3 D # 8.3 8.4 8.6 8.4 8.7 8.4 8872.0 2.4. 3i3. 2.3 llq. 16.9 ~ BOTTON ~- 9144.0 3.2 195. t .8 208. t¢ .9 8962.0 2o! 173. 0.8 144. 17.2 16.5 ~- 9384.0 18.4 150. 2.2 205. 8.? ~.4 DRESSER ATLAS 716 TAPE FORMAT ? ~/ L)'-"~ '"' ~' © ~ gAT16 T~ FORMAT CONSISTS OF A HEADER REC~_RD~_CONTA!N~..NG PERTINENT ('SEE ~_LOW:) :~LLouED_ BY ._THE DATA.' RECORDS. ---~- OA~G_POI_N_T _SAMPLES ( AS .DEFINED BY . THE HEA~R RECORD) OF EACH CURVE. THE DATA FOR CUR~E 1 IS FOLLOWED BY THE DATA RD'... TH~R-~6~'~Z-~E_.'~A-~ BE -C'O,PUTEO' B y THE' . FOLLOU~N~N: WHERE ~~ NUMBER OF SARPLES OF EACH CURVE PER RECQRD(I.E~ ~25) ********************************************************************************** ,FIELD FIELD DESCRIPTION POSIT~N ..... CHAR, N.OF BYTEs* --,5 :~2-~-- .... ~ .:' {' · .': '~- '.. : ~ .~..' ."' :..~ ..~...~' .':.v. 2.... :. START ...... STOP _ * 1 EPILOG CORPUTATION NURBER i 4 FP.. . ~ ..... * 3 WELL NAME 85 184 AN 80 ._* , 5 F~LLER 1~7 ~68 ...................... 2 ..... , 7 TAPE STARTING DEPTH 249 ..... 2~2 ........... FP ..... ~.__ * --~ F...... .'~-=: ~ ~ 253 __25~ FP 4 * , 9 DATA LEVEL SPACING 257 2GO _Fp ........ 4 __., ARCO OIL AND GAS .... DRILLSITE 12-~5 '716 L~BRAR'Y DCC#672 LEVEL SPACING 0.5000 ................................ PAGE ._ · PR_LJDHOE BAY .... 18-'10N-15E .... NORTH SLOPE, ALASKA GR CCL CNL LSN SSN 625~__. 50 ,___ 0 . 00 _ 0.00 -0.13 -3,00 _- 7_,_0_0 .............. .~o ~~ .7. o~-~---~-_]i~.' i']i'i'- . . __._ 6_~z~ ,50 07~.~ .... 0~.97 . ~0,73. -3.00 _-_7_.o_.__o ............................... 6252°50 0o00 . .0..~00 -0°13 -3,00 -7 0 ................................. ~o :--~?_. o~ ........... 625~ ..... o.oo ....o.07 ~0.~ . -~,oo -7:00 ................... ~! ~._..,7 · o o ~.~.~o ~:~:~ , 7___.~o_o ........................... 62s.~.so o.oo o.oo -o.~.~s -3.00--z. oo 6256.50 0.00 0.00 -0.13 -3.00 -7.00 ............... ,0~i::~7.00 ~s_~so o -o.~ ~.oo ~,.oo i - ~.._~.5o_ o.oo ..o..oo ~o.~.~_____~.oo ~z_._oo .................... · o.o ~ ?.oo ~259.50 0.00 0.00 -0.13 -3.00 -7.00 "'~s~oo:: ~ -?. o o ...................... o"o . ...... ~ ~ ~=~:Oo~::?i~.. ~u~ :' :-: .... ~'-~- ......... ~ - =~z ::. ~ ~ ....... ~_';~o o ~ .~ ~:..~ ..... - ..... ~ "]-- - ]-]~]---- ~oo.' ~] ~ ::?~ : ..................... ..... ~e~s.5o o.oo o.oo -o.~ -~.oo -7.oo · .-~. ~-~- 7.00 ~2~6.50 0.00 0.00 -0.13 -3.00 -7.00 ' 7' 00 6268,50 0.00 0,00 -0.13 -3,00 -7,00 6269.50 0.00 0.00 -0.1~ -~.00 -T.O0 ~00 ~ ~-?.__00 62T0,50 0.00 0.00 -0.1~ -~.00 -7.00 · ~0~ '?' O0 6271.50 0.00 0,00 -0.15 -5.00 -T.O0 6e~e.~o o.oo o.oo -o.~ -~.oo -~.oo 62T~.50 0.00 0,00 -0.1~ -~.00 -7,00 62T~,50 0,00 0,00 -0,15 -5,00 -7.00 PAGE 2 ._ PRUDHOLBAY .... 18-!O,N-15E .... NORTH S L _O_P_E --~---- : ¢~~--- ::.,;,,: : ,~ ~ : ................... GR CCL CNL LSN SSN :~ ~~oo o.ooo.oo-o.~-z.oo ~7.oo 6~. oo o. oo o. oo -o. z3 ~3. oo -- '~'~o o ~279~00 0.00 0,00 -0.13 -3.00 -7.00 ........................... 6280.00 0.00 0,00 -0.13 -3,00 -7,00 _~:~ 62:8 '."-.:0:. i 3..'~' 3~_.00 62B1.00 0,00 0.00 -0.13 -3.00 -7.00 6282.00 0~00 0.00 -0.13 -3.00 -7.00 ~283.00 0.00 0.00 -0.13 -3.00 -7,00 628~.oo o.oo o.oo -o.~s -~.oo -?,oo . ~o: '~, o o ....................... . ............ 6285.oo o.oo o.oo -o.~ -3.oo -~.oo ' ~:...~Oo: .... ~..~ ::: - .............. 6291,00 0,00 0,00 -0.~3 -3,00 -7,00 . ~292,00 0.00 0,00 -0,~3 -3,00 -7,00 ~::. · oo __ _ ~29~00 0,00 0,00 -0,13 -5,00 -7,00 ~.oo o.oo o.oo -o.z~ -~.oz -7.oz 6~s,oo o,oo o.o~ ~s.~o -~.oz -7.oz 62'95 0.'0:-'." .'. ":.. ~5 -3'-0~ :: ' 7 · 01 6296,00 0,00 0.09 ~5,30 -3,0~ -7,01 6297,00 0,00 0,09 ~5,30 -3,01 -7,01 ::::: ::::'7 ,:01 _ . ' ....................... 6298,00 0,00 0,09 ~5,~0 -$~0! -7,01 6299,00 0,00 0,09 ~5,~0 2,~6 -G.9~ _ 6300,00 ~0,25 0,05 ~.55 2.25 2,15 PAGE PRUDHO_OE BAY .... 18-10N-15E .... NORTH SLOPE, ALASKA eR CCL CNL LSN SSN ............. .... 6~_~5o ~.~6 ~ o.o~ ~ ~5,70. i.s5 i.75 ................... 630~.50 50,~5 0,06 36,~ 1,6~ 1~ 6505.50 q7.80 0.06 39.00 1.66 1. 63o~.so s~.G3 O.OS ~7.~5 ~.73 ~. 6305.50 50.75 0.06 37,57 1,68 1. ........................... 6~06.50 ~9,96 0,06 58,52 1,58 1, 6507.50 47,51 0.06 39.63 1,6~ 1 0~:.' · .' "0.7 1. 6308.50 ~8,59 0,06 38.59 1,75 6sog.so s~.6~~ o.o~ ~.ss ~.6~ --- '. . {~.'5~:;: :z.sG 63Z0.50 50.65 0.06 39.63 1.58 Z.57 ~0 :..' :0 :: :~ 2,55 ___ ~ .... ~~ 0~06 S~,78 ~'6~ .... i --:.:: . ........................ ~_ .~L:.~ ....... ~ ................ 6~16.50 51.24 0.06 41.~8 1.26 1.14 ....................... ..... ~ .,% '. ~ ~ 6317,50 53.30 0.05 42.1! 1,51 1.21 ................ 6s~8.uo u~.mo o.o6 vo.78 ~.qo m.mv ................................... 6~29~50 5~.~8 0,06 39.~7 2.~6 2.20 ...................................... 6321,50 50,~6 0,05 q0,78 1,~5 1,22 .................................. ~:<:: 1.~6 .... 6522.50 qB.lO 0.04 ql.45 1.51 1.52 23,00 5: ~: :1'58 .... 6323,50 q7,80 -0,31 ~3.30 1,~5 1.39 .......... .-- ?--~ ciL-~-~- ...................... __. 6s~v.so v~.~o -o.~o qs.s~ ~.~ ~.~ ........................ 6525.50 ~5,55 0,11 ~1,56 1,~2 1.27 ..9.~. ' '-"-~~:: :77: ~i-,--~-2 ................... . ' 51 51 51 51 50 5~ 1.54 :1,57 1.59 > . PAGE 4 PRUDHOE BAY .... 18-10N-15E .... NORTH SLOPE, ALASKA -"- L~, GR CCL CNL LSN SSN G~.oo ,+4.9~, o.o~, ~.~ ._I.D~ ....... ~__~_~X'.~'~-._~ '_'_.~. '~' . ......... ~~i~-_~ ..... ~'- 2 ~ ................ 6~_.oo ~.5~ 0.06 ~.~__ ~.~5 ___~,~z ..................... : _~.~ .......... 6~29.00 50.36 0.06 ~2.04 1.~2 1.2B ~f=~~ .... ]~/-/-~-~.-.-~ .-~..~.~ ~ ~~ .......... - ............................... O~ :0: ~, 27 ...... 6530.00 50.65 0.06 ~1.30 1.53 1.29 '..~. ~.~5 ..... -'~ ........... ~~Q 4~.39 o.o ~.76 ~.~ ~ ~ ~6 ....... _.-~--.' ' . --.~'-_~-L----.--- 6~32,00 ~8.69 0,06 36,85 2,0~ 1,81 ~~:-:-~-,~-~ .......... ~-_.. ....................... 633~,00 ~9,87 0,06 36,~1 2,31 2,19 633~.00 46.15 0,06 3~.55 2.37 2.28 '~;~:;~- ~: 2.32 __ ~ ................................. ~'~ G~s. oo ~.7G o. oG ~4.~2 2. ~o 2. G336.00 Q4.27 0.06 35.85 2.~0 ~.3G :~ a.3~ ........................... 63~2.00 ~9,85 0,06 $8,07 2,23 2.28 63g~.00 52.20 0.06 55.03 2.~2 2.29 63~,00 ~2,60 0,06 ~,89 2.6~ 2.6I . 65~5.00 ~5.8~ 0.05 ~.~7 2,76 2.68 :~ 2.71 ............................ _ 6346.00 ~0,83 0.06 33.07 2.8~ 2,75 65~7.00 ~9,66 0,06 ~2.0~ 2,~0 2,79 ~ ~:. ;.~ : ~ ~ · .............................. ~ .:':; 5 : :: 2 83 63~8,00 38,58 0,06 32.36 2,80 65~9.00 ~4.26 0.05 33.03 2,85 '/ 7; 2.85 ........................... II II 111.1 11,11 ,I 1 II I 1 11 II 11 11 11 1111 111,1. 000000 000000 00 00 00 00 00 0000 00 0000 00 00 00 00 00 00 0000 00 0000 00 00 00 00 00 000000 000000 777'7777777 7 '7 '7777 'l 777 77 77 77 77 77 77 77 77 7'7 77 '77 0o0000 000000 O0 00 00 00 00 000C) 00 000() 00 0o 00 O0 00 00 0000 00 0000 00 00 00 00 00 000000 0 00000 7777'177'777 '1 '? 7 '7177 'l 'l 7 '77 '17 77 77 17 77 7'1 77 17 77 7 '7 'l 7 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 77'777'77'7'77 77'7'77'77'7'/7 7'7 '7'7 77 77 7'7 77 77 '77 7'7 '77 77 000000 000000 O0 00 O0 O0 00 0000 O0 0000 O0 00 O0 00 00 00 0000 O0 OOOO oO 00 00 O0 00 000000 000000 1,¸1 11 1111, 1111 1,1, 11 11 11, 11 11 11 11, 111.1,11 111111 000000 000000 00 O0 O0 O0 00 0000 00 0000 00 00 O0 00 O0 00 0000 00 0000 O0 00 00 00 00 000000 000000 SSSS ~'~?f L f b ,fi' L SSS fffF' L S F ~ s f L SSSS F bbbhL PPPP ?RRR P P R R PPPP RRRR P R R P R R u u D P D D I,t H U U D D Id H U U [) D 14 H U U D D HI-iHHH U U O D Id H U U D D Id ri UUUUU DDI.)D H H U [] 1~ u r3 ~ U ILl E., *STAR?* USE:R PCAI, [10707~ MUNiTUR SwS F~blOg3~ dub-?9. MUNlr[.'R 8w$ KLIOE34 JUL'?9. 57010J dub *START* 57010] job *START* SHIP Sk~. 7858 6HiP SEG. 7858 DAT ~ lO-dAN-80 I O-JAN-80 22:34:59 22:34:59 0 1 66 0 DATUM 8P,E:Ci~ IC,ATI[]N E~LO(2~: BNTRY 1C TOUb SV£]RD~ UNITS API, AP,[ AP1 APl FIhglt L~1%~ gXP PlqOC SAM RgP DBPT SHI, FT F T 0 0 0 0 0 4 0 0 I 68 0 0 M V 7 1 0 0 0 4 0 0 1, 68 0 0 OHMM 7 12 46 0 0 4 0 0 I 68 0 0 Of,iMM 7 1, 2 44, 0 0 4 0 0 1 68 0 0 [,1H M ~ '7 2 '2 8 0 0 4 0 0 I 68 0 0 G A P .1 7 31 32 0 0 4 0 0 1. t~ 8 0 0 O S / 1" 7 52 32 0 0 4 0 0 I O 8 0 0 G A P 1. 42 31 32 0 0 4 0 0 1. O 8 0 0 IN 42 28 1 0 0 4 0 0 1 68 0 0 (; / C ,~ 42 44 0 0 0 4 0 0 1 08 0 0 P O 42 68 3 0 0 4 0 0 1 O 8 0 0 G / C .~ 42 ,35 1. 0 0 4 0 0 1 68 0 0 C: / C 42 42 1 0 0 4 0 0 1 68 0 0 C P S 42 34, 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1. 08 0 0 D E P [l~' H 9798.000 9700.000 96,00.000 9500.000 9qO0.O00 9300.000 9200.000 9100.000 900O. 000 8900.000 88O0.000 (V~ N E F~ 0 N I C GR D ? H O N C N L DRHU N C N L L) R H 0 SP GR D R H 0 SP DRHI3 NCNb SP GR DRHU NCNb, SP GR DRHO NCNL St:' DRHD NCNb SP DRH£J NCNb SP GR DRH[J NCNb GR DF, HO NCNb V Al, -999 -999 0 2464, 81. 0. 2408. -63. 44. '0. 3166. -63. 26. 3060. -70. 25. 2842. -34. 152. O. 23'72. -72. 20. 2762. -69. 29. '0. 2984. 62. '0. 2628. -15. 86. O. 1.385. -10. 89. 0. 1701. UE .250 .250 . I 4 '7 .000 156 000 006 000 '719 813 013 000 650 4:84 013 000 500 391 015 000 656 8 '75 052 000 625 391 014 000 375 922 003 000 406 531 007 000 641 O63 053 000 031 313 044 000 E ,~ 0 N I C iLD DT N P it I ~C N b i LD OT NPHi F'C N [J I L D DT NPHi P'CNL ILD DT NPEI t~'CNL 1 LD DT NPHi F'CNL ILL DT NPHi FCNL UT N P H 1 ~ CNh ILD DT NPHi ~CNL ILD DT NPHi FCN6 iLD UT NPHi FC NL ILL DT NPHI PCNL V ALU -999. -999. 136. 848. . 72. 23. 1.061. m 92. 26. 1276. 87. 26. 1200. 250 250 1.82 000 820 188 535 000 1,41 56,3 025 000 258 563 855 () 00 1.839 9,4.563 28.516 104'7.000 8 74 25 953 20 96 2'7 1097 3b 87 25 1266 14 80 25 1095 .992 .188 .830 .500 .750 .000 .686 .000 .063 .188 .53'7 .000 .313 .750 .049 .000 . 111. 50. 354. . 106. 40. 411. 464 375 244 500 '783 188 582 250 ~ N E M 0 N 1 C ILM G,R t~HOS I. LM GR, R H (] b G R R H U B IbM GR RHOB GR IbM UR R HO ~ ibm GR RHOD GR RHO~ IbM GR I.LM GR IbM V ,A L U E -999.250 110.563 2.510 8,36 4 3 8 ~ 2 '7 2.332 50.281 2.248 2.500 24.5,31 2.252 2,158 22.909 2.252 9.11'7 155.'150 2.580 1,6.(~25 28. 875 2.287 27.906 25.641 2.297 14.1Lq 05.500 2.387 1.5~8 86.438 1.978 1.865 ~O.125 2.459 M N E ,M O N 1 C 668 U C .AL i N R A T bb8U CALl NRAT LLSU CALl, N R A T bb8U CAb,l, NRAT bb8O CALl NRAT bbSU CAbi NRAT bbSO CALl NRAT UbSU CALl NRA'r LDSU CALl NRAT LLSU CALl NRAT bbSO CALl NRAT -999.250 8.500 2.9'11 9.898 8.719 2.320 4.918 8.54'1 2.~'79 4.141 8.523 2.535 4.625 8.688 2.050 11.992 ~.9'l'l 2.502 18.063 8.531 2.588 32.844 8.594 2.449 1b.~53 8.930 2.445 2.344 16.859 4.215 2.bll 13.104 3.91o DI:,,,PTkt 700. 000 600. 000 8500,000 8,4 0 0.0 0 0 8300.000 8200.000 8100,000 8000.000 /90U.O00 78O0.000 7700.000 ~ 1'4 E, MONIC SP D lq H 0 NCNb GR D R H 0 NCNb SP GR DRHU NCNL D R H 0 NCNb SP GR DRHO N C, N L GR DRHU NCNb DRag NC NL GR DRHU NCNb SP GR DRHO NCNb DRH[J NCN~ SP G~ DRHtJ NC N b V A L U E -13.813 94.81,] 0.021 1638.000 -12.742 182.875 -0. 005 .1.736,000 -14. J 88 119.500 00'5 179.310~0 -9.914 109.625 - 0.006 1872.000 -11,. ,438 149.625 - 0.005 20o4. 000 -11.750 71.813 0,011 2090,000 -11.4 '7 '7 '71. 188 0.039 198'7,000 -14.219 O3.969 -0.00b 2064.000 -14.094 lbl .375 0.030 2192.000 -14.969 b1.344 O.OOO 2047.000 -13.500 18. 250 -0.001 2192.000 M N 1~,; M O N i C i LD DT ,N P ,H i FCNL 1, L D DT ,N P a i F'C N,L ILl) DT ,NPHI ILD DT ,NPHI P'CNL ILD DT NPHI FCNL iLD DT NPH I iLD DT NPHI fCNL ILD DT NPHI ?CNL ILD UT NPHI PCmL ILD DT NPHI ~CNI, ihD DT V A L U E 1.854 98.563 ,. .46 729 381:500 2,924 110.000 47,314 409.000 2.215 109.()00 41.162 442.000 2.381 105.750 42.725 448.500 1.961 101.375 42.432 50'7.750 2.795 82.563 29.688 629.500 2.391 86,56:] 35.791 528.000 2.3'77 8'7.188 34.229 5'73.000 2.641 85.563 31.641 b09.500 1.905 93.000 32.32~ 610.000 2.119 88.188 29.053 688.000 1 L M GR GR H H O ~ 1 LM GR RHOB 16M GR GR R,H[JB 1 L GR 1 LM GR RHOB IbM RHOB IbM i'<MUb 1 LM GR VALUE I .9,61 93,938 2.46'7 2.934 169,3'75 2.459 2.264 132.125 2.482 2.4'73 111 . .3 '75 2.414 1.846 140.125 2.447 2.904 73.438 2.492 2,375 01.813 .~38 2.395 62.531 2.400 2.627 66.125 2.434 1.974 '72.250 2.410 2.217 77.813 2.418 M N IL MUN lC bL8U CALl N R A T ,bhSU CALl NRAT LLSU CALl NRAT LL8U' CALl NRAT LbSU CAPI NRAT 6680 CALl NRAT bhSU CALl N R A T LbSU CAb1 NRAT 668U CALl NRAT hbSU CALl NRAT bbSU CALl NRAT VAbU5 2.750 1,3.531 3. 936 4.965 1.3,313 3.9~1 3.019 13.461 4.164 1'2.95:] 3.09'7 2.752 13.401, 3,693 3.b09 13.336 2.971, 2.752 13.50~ 3.32 2.684 13.83b 3.250 3.059 13.938 3.113 2.533 14.914 3.180 2.805 1~.83b 2.965 D k P '1" H 7600. 000 "/500.000 ? 400. 000 7 3O0. 000 7 200. 000 7 l 00.000 7000.000 6990.000 6800. 000 6,?00.000 6600.000 M N E M ti N I C GR DP, HO NCnb DRH[j ~C N ~ 8P GR DRHU N C N b 8P GR DRH O NCNb SP DRHO NCNb 8P G~ DRH(.t NCNb SP GR DRHU NCNL DRHO NCNb SP GR DRHD NCNb DRhU NCN~ 8P NC[,~ b V A L U E -14,953 77,813 0.000 2172. 000 -14.219 77.00 () 0.032 2492. 000 -1,5.656 70,188 0.053 25'7,1.000 -18.844 93,125 0.019 2368.000 -21.422 102.1.88 0. 020 23 '12. 000 -20.688 79.750 0.020 2356.000 -20 ..438 8b.188 0.015 2412.000 -18.047 72,563 0.021 2900,000 -45.56 ~ 01.563 0.008 2~88.000 -54.900 53.344 -0.001 2684.000 -50.875 58.875 -0.005 2358.000 M.N~;MON lC 1LD 13 T NPHI ["'C N h 1 h D DT NPH l IUD DT NPH 1 F'C NL DT NPHI ~'CN6 I bD OT, NPHI FCNb NPHI ~CNb 1LD DT NPH1 F'CN6 i b D OT NPHI ~'CNb ibD OT NPH I ~CN6 II~D OT NPH I ["C N6 i 6D DT NPHI ~C~L VAbUE 2.215 89.375 30.273 073. 500 2.176 80. 375 31,. 738 716.000 2.691 88.000 28.564 810,500 2.459 95.375 34. 082 652.000 3. 299 90. 750 28.271 730.000 2.908 '91. 000 32.959 697. 000 2,816 90.750 30.908 715.500 3.223 91.750 20.953 945. 000 ~.252 93.000 30.322 708.000 3.008 97.750 32.764 752.500 2.904 153.1,25 28.900 O81.500 IbM R H O b GR I, LM GR RHO~ I, LM GR R H ti B GR ~,HOD GA ~HUB RHOB ~HUD I bM GR kNOB IbM VALUE 2.280 78.188 2.418 2,275 ~4.000 2.447 2.9,34 60.125 2.428 2. ,~87 97.438 2.480 3 8'1 2.500 :2. 906 73. 125 2,486 2.795 75. 375 2.461 3 · 45.:t 09.000 2.414 3,313 05.500 2.352 2.959 46.81 3 2.248 3.000 01.219 2. 357 MN EMON I C L6BU CALl NRAT ,b68 U CAbI N l-t A T hbo U CALl NRAT 668U C A L, i N RAT 668U CALl N R,A T' 668U CALl NRA,I~ LbSU CA6I N R A'I'" 668U CA6£ N RA'I' bb8U CALl NRA'£ bbSU CALl NRAT bbb U CALl N RAT VALUE 2. "7~9 14.992 3.053 2,943 14.859 3- l'4b 3.5'70 15.289 2.943 3. 207 1 'l. 00.3 3.324 3.799 10.8'75 2. 907 3,822 16.563 3.270 3.311 15.81,3 3.115 4.052 15.391 2.8~2 3.670 15.43~ 3.000 5.00~ 14.289 ~.199 4.310 14.503 2.94/ 1,) ~.,~' I d 6500.000 6,400,000 6300.000 6200. 000 6100. 000 60O0. 000 5900,000 5800,000 5100.000 SBU0.000 5500.000 E lVi {i N I C SP GR D R H 0 N C ,N b SP GR D R H O f,t C N b GR DRHO NCNb SP GR D R H O NCNL DRHU NCNb SP Gt>, DRHO NCNb SP D R H O NCNb SP GR DRHU NCNb SP I.)RHU NCNL, GR DRHO NCNb Si:' DRHU N C N L VAL -35 60 0 2390 -94 31 -0 3038 '6'7 57 -0 2680 -106 )2 -0 2962 -51 69 0 2852 -90 43 -0 2748 -46 0 2428 -79 35 - 0 2'742 -96 28 -0 2710 - 27 52 0 2150 -lb b2 0 UE .250 .,313 .030 .00 () .438 .719 . 01,3 ,000 .125 · ,31 3 .002 ,000 .4.38 .563 .012 .000 .875 .563 .004 .000 .500 .313 .003 .000 .844 .000 .004 .000 .063 .406 .003 .000 .000 .172 .005 .000 .375 .813 .033 .000 .844 .969 .036 .000 M N EMON iCy, I. LD DT NPH i ~CNL 1 LiD DT N P,H I .~"C N l,J DT NPHi b'C N b ILD DT NPH, I ILD DT NPHI. t"C ,N b 1, la D DT FCNb IbD DT NPHI FCNb ILD DT NPHi FCNb lbD DT NPHI ~CNb IbD DT ~CNL ILD DT L~PMi FCNL V A L U E 3.2 96.1. 30,7 652.0 1 .3 26.1 1040.0 2 o 3 96.5 25.3 918,5 1 93 2'7 948 3 91 30 817 1 9,3 28 896 2 98 3 t~ O98 1 101 32 8:32 0 102 34 78~ 2 1.03 44 521 3 99 :l 9 53O '7 '7 88 62 00 65 63 23 00 55 6,3 4 2 O0 .229 ,563 .246 .500 .137 .750 .322 .500 .365 .750 .369 .000 .715 .750 .670 .500 .615 .188 .568 .000 ,981 .750 .717 .500 .590 .375 .189 .500 .139 .750 .111 .500 M 1~ E,M [)N 1 C IbM R,H,O~ i L M IbM /-',HOP, IbM GR ILM GR R H 0 B ILM GR Rki, U~ ILM GR ibm 614 RHLJB IbM IbM G~ ibm GR VA b U E 3.13 '7 bl .531 2.383 1.51 3 29.29'7 2.2,i6 2.910 56,81.3 2,355 1.502 33.3'75 2.258 3.51,4 b'2.'750 2.439 1.69'2 4'7.5,~1 2.334 3.141 62.938 2.309 1.796 33.125 2.301 1.215 25.281 2.174 2. b:17 58.938 2.373 3.119 54,719 2.365 M N E; M O i~ 1 C bbSU CALl N R A T bL8O CALl N RAT' LLSU CALl NRAT bbs U CALl N RAT 15,580 CALl NRA'I' bbSU CALl N R A T ,bb8U CALl NRAT bbBU CALl NRAT hbSU CALl NRAI' bLSU CALl bbSU CALl NRAT V A.,U U5 3.254 1, "l .031 3.135 3. b 72 14.008 2. '750 6.594 1~.820 2.719 6.449 13.836 2.820 5.3'32 15.1,17 3.05'7 5.152 13.883 2.893 3.941 14.883 3.410 q.508 13.219 3.150 3.994 13.0'70 3.254 2.814 10.672 3.871 3.037 lo.bl2 3.594 D L P T 54-OO. 000 5 3O0,000 5200.000 5100.000 5000. 000 4900.000 48O0. 000 4700.000 4600.000 4500.000 4~90.000 E M 0 N 1 C GR DRHO N C N b V A b U E -75.3'1 39.34 0.00 2650.00 8F' -19.0'78 GR 76.000 DRHO 0 013 NCNb 2090:000 SP GR DRHO NCNb SP GR DRHO NCNb SP GR DRHO NCNb SP GR D R H 0 NCNb SP GR DRHO NCNL SP Gl4 DRHU NCNb Gk DP, HO NCNb SP GR DRId t.) NCNb SP GR DRHO NCNb -33.219 '71.500 0.023 2206.000 -29.109 o:'o 1974.000 -6'7.188 35.094 0.01,4 2912.000 -41.188 59.281 0,004 2002.000 -54.906 42.344 -0.004 2674.000 -25.484 44.000 -0.008 1413.000 -11.320 08.563 0.028 1879.000 -44.000 48.3~4 0.140 1080.000 -16.891 61.875 -0.004 2000.000 M N g M O N I C D T NPHi ILD DT bid DT C N L DT N P H I ILD DT NPHi ILD DT ~ICNb iLO DT NPHI kCNb II,D DT NPHi ~ CN6 I bD DT NPHI ILD DT NPHI ~CNL ILO DT NPHI ~CNb 1.444 102.000 31.299 810.000 3.3171 10 :~. 563 39. 453 541. 000 3,404 101,563 4.3,457 55b,000 3.1 82 105.563 39.453 549.000 1.552 1.1,1.375 34.3'75 822.000 3.525 103.1,88 33.20.3 602.000 1.788 119.563 35.30.3 764.000 8.570 144..~75 62.158 252.875 4. ~09 114.3'75 31.939 4'74.250 2.154 100.5o3 41.895 431.250 4.156 113.503 40.869 4~4.250 MNEMONIC GR k H 0 ~ GR RHOB 1 LM GR IbM kHO~ J.,LM GR gHOB I bM EHOb GR IbM GR IbM GR 1 L M GR VALUE 1.705 39.469 2.2i~2 3.215 ,5.525 ~6..313 2.354 3.320 bT.O00 2.369 i1.642 30.203 2.221 3.664 53.500 2.354 1.'75~ 43.688 2,141 8.807 38.875 1.504 3.941 62.281 2.289 2.2 ~2 41.125 4.109 57.544 '2.318 M N E M [.) N I C CALL1 NRAT bbSO CALl NRAT bbSU CALL NRAT ill 8 U ALI RAT 6b8U CALl NRAT bbSO C A6,1 N R/4 T b68U CADi N RAT l,bSU CALl N R A T bbSU CALL NRAT 668U CA6I NRA1 6L, SO CA61 NRA'i' 4.395 13.8~'1 3.092 3.~80 15.852 3.592 4.0'74 15.21,9 ,3.7 9 I7 3 . 4 I77 15.5'78 3.584 3.503 14.281 3.268 4.313 14.656 3.238 3.957 13.875 3.311 1,4.54'7 15.422 4.~40 4.117 14.398 3.q69 3.B81 13.9'17 3.07~ 4.520 15.758 D k: p T H ,4 ;~ 00.000 4 2 0 0,0 0 0 41 O0. 000 4000. 000 3900.00() ]700.000 3600.000 3500.000 3400.000 3300.000 MN L FI U iq i C DRttO NCNb SP DR}iCi NCNb SP GR D R 1~t 0 NCNb SP DRHO N C N h SP DRHO NCNb SP GR DRHO NCNL SP GR DRHU NCNb SP DRHU NCNI.j SP GR DRtlO NCNL GR DRHU NCnb SP Gl( DRHU NCNL VA 187 5 196 -4 5 188 -4 6 'I 179 '-2 6 163 -4 5 m~ '" 4 5 150 5 156 -4 4 162 -4 lbl -3 1,63 LUE 1.000 5.81 0.014 5. 000 8. 609 5.844 0.028 0.000 0,156 e. 8'75 0,013 4,000 2.3'75 ,4.563 0.004 5.000 5.$75 5.938 0.066 0.000 5.375 2.469 O.O05 3.000 3. 063 8.750 0.012 3. 000 6.344 9.375 0.012 7.000 2.875 9.000 0.016 b. O00 2.500 0.125 0.013 4.000 9.688 1.469 0.024 2.000 EMON iC DT NPH1 F'CNL ,1. b i) OT t~'CNL 1. L D DT ,NPbti e'C N L 1 LD DT NPttl F C N L ILD DT NPBI t"CNb OT NPHI FCNL ILD DT NPMi FCNb iLD DT NPH1 F'CNb DT aPHI t'CNL OT NPHi 1LO OT t~i PHI FCNb VALUE 3.2 1.21.1. 44.3 430.7 4.0 107.7 .38.7 549.0 6.3 11-2.0 4,1.5 454.7 5.8 11, 0.0 40.8 456.7 4.5 1,32.] 4,i. 8 399.0 6.8 1,08.7 42.0 41 0.7 6.3 116.3 47.5 350.5 11.8.7 45.1 324.7 5.4 110.3 45.2 38 b. '7 3.8 133.3 49.4 365.5 3.2 133.7 4'7.1 403.5 99 88 36 50 82 50 21 O0 '71, 00 O4 5O 01 O0 69 50 55 75 24 00 83 50 2'1 50 75 75 10 00 48 50 66 50 61 75 64 5O 07 75 14 00 36 50 68 O0 GR 1 LM ibm 1 L,M R H 0 ~ I bM GR I, bM GR ibm GR ibm k,HO B IbM GR V A b U Ii 3.215 58.938 2.256 4.055 49.5,31 2.373 b . 324 58.71,9 2.3,36 5.918 53.844 2.289 4.125 b3.000 2,186 7.008 513.156 2.297 0.545 49.031 2.210 0.402 54.500 2.202 5.017 41.~75 2.285 3.713 61.000 2.26'2 3.285 56.150 2.252 bLSU CAb 1 i'4 H A T bhSU CALl NRAT bb8U C A L 1 N iR A T LbSU CALl Nl(AT ,hbSU CALl, Nl(AT LLSU CALl N R AT nbSO CALl NRAT LLSU CALl NRAT bbSO N lq A '1' LbBU CALk NRAI' LLSO CALl NRAI' V A ,h lJ E 3.416 15.34,4 3.850 4.9 '1 '? :15.219 3.563 1.594 15.'750 3.703 b."l 11 13. 750 3.613 '4.852 10.641 3.910 8.055 15.78i, 3.766 7. 559 14.742 4.008 b.875 i0.672 3.930 7.098 12.828 3.B34 q.q~O 13.503 4.0Ub 4.258 13.7'13 3.905 DLPTH 3200.000 3 I, 00. 000 3000.000 2900. 000 2800.0O0 2700.000 2688.000 MNE;HON lC SP NCNL Gl.{ DRHU NC NL SP GR D R h U NCNb GR DRHO SP GR DRNO NCNL, SP GR N C N b SP GR DRHO NCNb VALUE] -8.508 58.063 0.021 1553.000 -54.8'75 5.13.500 0. 006 i630.000 -55.063 51,..438 0.00 3 15,44. 000 -57.156 ,4,4.'750 0.005 1569.000 -68.503 35.'719 .001 158..000 79.688 40.563 -0.795 1396.000 81.500 20.891 -0.795 1390.000 ~tN ~M(JN lC 1 h D DT ILD DT NPH 1 ~'C,NL 1 LD DT N P i't I FC N L I. ,bD DT NPBi ILD DT N P H i 1:'" C NL ILD DT NPHI FCNb I, LD DT NPH1 ~CNL VALUE 2.406 145.000 51.514 328.500 1.940 1,41.125 52.637 365.00O 1.854 1.,37.000 52.002 359.000 2. 223 1 35. 500 ,45.41,0 34 '7.750 2.629 135.125 52.734 ,321.250 2000.000 5'1.000 57.813 279.250 2000.000 59.594 57.813 279.250 IL~ l bM GR HHOB 1, GR R H [J ~ i L~ GR RHOt5 VALUE 2.11,'7 52.906 2.~82 1.99'7 50.156 2.152 1.803 48.900 2.094 2.273 44.531 2.152 2.82,4 30.406 1.850 39.500 30.438 1.863 3,4.750 30.438 1.863 MNEMUNIC bbSO CALl NRAT bLSU CA,,bl bbSU CALI NRAT bb8U CALl NRA'].' b,bSU CALl NRAT LbSU CAbI. NRAT LLSU CALl N HA T V A b O Ir:., 2.77,1 14.969 4.2;38 2.96'1 14.109 4.2 '7 '? 3.111 1.3.555 4.22/ 3.535 13.4~5 3.859 3.705 1,0.109 4.330 1.0'76 12.766 q.531 0.991 12.766 4.531 ,L E N G T l--~ O F L A,S !117 P, EC O R D: ? 8 6 ,B Y 'I, ,E $ LENGTPI: 62 b~'Tg$ P'ILE NAME: EDIT ,001 NAX1NUM Pt.I~fSICAL RECURD LENGTH: NEXT ~'ILE NAN,,',: 1024 BX'i'B~ I.,ENGIt~: ti2 BX'TE,S TAPE NAME: 5'7010 DA'.].'[~;: 80/ 1/10 SERV 1Ck~ NAMe.: h[)IT TAPE CtJNTiNUAT1ON NtJMBfJR: O1 N~.;XT TAPE N.A~E: COMME, NT6: UNIQUE W~;bb 1DEN'.[i~"ICAI~ION NUMBER IS 50-029-20377 ~mmmmmmmmmmm~mmmmm~m~ * .... SCHLUMBERGER .... ~ LIS ~P5 YERIFICATION LISIING LVP 009.;~02 VERIFICATION ~]STI~'G P~(.E 1 ~* REEL HEADER ** SERV ICE NAME :SERVIC DATE :81/05/13 ORIGIN : REEL NAME :REEL ID CONTINUATION # :Cl PREVIOUS REqL : COMMENTS :REEL C(]~MENTS ~ TAPE HEADER ** SERV1CE NAME :SEBVlC DATE :81/05/13 TAPE NAME : CONTINU.~.TION ~ :01 PREVIOUS TAB~' : COMMENTS :T~PE 2~]~MENTS EOF ~* FILE HEADER F1LE NAME :SERVIC.0C 1 SERVI2E NAMe} : VERSION # : DATE : MAX1MUM LENGTH : 1024 FILE TYPE : PREVIOUS ** INFORMATION RECORDS MNEM CONTENTS CN : ~gTLAh~iC RICHFIELD C mN : DS 12-3 FN ,: PRUDEOE BAY RANG: RANGE TO~N: TOWNSHIP SECT: SECTION COUN: N. SLOPE STAT: ALASKA CTRY: USA MNEM CONTENT5 PRES: FDNO01F *~ RECORD TYPE 047 ** ** R~CORD tYPE 047 ** UNIT T~PE CATE SIZE CODE 000 000 020 065 000 000 010 065 000 000 015 065 000 000 005 065 000 000 008 065 000 000 007 065 000 000 010 065 000 000 010 065 000 000 005 0~5 UNIT ~YP~ CATE SIZE CODE 000 000 007 065 LVP 009,H02 VERI~' ICA'] ION LISTING PAGE RECORD TYPE 047 ~ ~ COMMENTS ~ CNL C/~ RUN # 1, LOGGED 7-DEC-81 EIT SiZE CASING .~ECORD Il 8,50"/ 8869 TO 9766 FT 7,0" / 8524 5,5" / SURF' ;30 8423 BOT, bO.~. INTERVAL : 9760 TOP LOG INTERVAL : 8~.50 FLUID iN TH£{ HOLE : CRUDE OIL POROSITY MATRIX -' 8~NfSTONE PASS #1 WELL FLOWING PASS #2 iMMEDIAtELY AFTER SHUT-IN PASS #3 45 MINUTES AFTER SHUT-IN PASS #4 90 ~]NUTES AFTER SkUTH]N ~* DAtA FORMAT RECORD ~* ENTRY BLOCES TYPE SIZE REPR .'DDE EN2'RY 4 1 66 8 4 73 60 9 4 65 ,llN 0 ~ 66 0 DATUM SPECIFICATI,ON BLOCKS ~NEM SERVICE SERVICE UNIT API AFI API API F1LE SIZE PROCESS SAMPLE REPR ID ORDER # LOG TYPE CLASS MOD NO, LEVEL CODE DEPT F2 0 0 0 0 0 4 0 GR FDN GAPI 42 31 32 0 0 4 0 NRAT FDN 42 42 1 0 0 4 0 NPHI FDN PU 42 68 2 0 0 4 0 NCNb FDN 42 34 92 0 0 4 0 FCNL FDN 42 3~ :~3 0 0 I~ 0 GR FDN GAPI 42 31 32 0 0 4 0 NRAT E'DN 42 42 1 0 0 4 0 NPHI FDN PU 42 68 2 0 0 4 0 NCNb FDN 42 34 '~2 0 0 14 0 1 1 1 1 1 1 1 1 68 68 68 68 68 6[ 68 68 68 6{ bVP O09.H02 FCNL FDN GR FDN NRAT FDN NPHI FDN NCNb FDN ~'CNL FDN GR E'DN NRAT FDN NPHI FDN NCNb FDN FCNL FDN DATA DEPT NCNb NPHI NRAT GR f"CNb OEPT NCN~i NPHI NRAT GR FCNb DEPT NCNb NPH1 NRAT GR FCNL DEPT NCNb NPHI NRAT GR FCNL DEPT NCNb NPHI NRAT GR FCNL DEPT NCNb NPHI NRAT GB , V CRII~ ICATION GAPI GAPI PU 9266.5C0 -999.250 28.2(4 -999.250 -999.250 -999.250 9200.000 2'79.219 29.004 3.344 29.826 79.998 9100.000 339.430 22.467 2.896 42.033 108.981 90(0.000 323.517 28.284 3.032 53.440 92.110 89(0.000 197.075 -999.250 -999.250 -999.250 -999.250 8897.000 198.795 -999.250 -999.250 -999.250 GR FCNL NCNb NPHI NRA~ GR ~'CNL NCNb NPHI NRAT GR FCNL NCNb NPHI GR FCNL NCNb NPHI NR~ GR FCNL NCNb NPHI NR~'I GR FCNL NCNb NPHI LISTIN2[ 42 42 42 42 42 42 42 42 42 42 42 34 31 42 68 34 68 34 34 32 1 2 93 32 1 2 92 93 -999.250 -999.250 -999.250 -999.250 -999.250 31.427 103.790 266.747 31.582 3.338 42.633 127.581 315.345 23,467 2.858 ~. 7.236 120.66~ 300.2c. 3 27.065 3.~c. 0 ,~2.145 51.448 -999.250 -999.250 -999.250 -9S9.250 52.313 -999.250 -999.250 -999.250 NRAT GR NCNb NPHI GR F:CNL NCNb NPHI NB~T GR FCNL NCNb NP~I NRAT GR [CNL NCNb NP~I NRAT G~ fCNL NCNb NFEI NRAT GR :~CNL NCNb NP. hI 4 4 4 4 4 4 4 4 4 -999.250 23.022 -999.250 -999.250 -999.250 2.714 27.024 84.324 259.006 32.202 2.712 42.333 114.604 324.377 23.786 2.780 47.837 :S6.868 307:.604 29.403 3.912 -999.250 -9S9.250 -99:3.250 -9c. 9.250 4.0C2 -999.250 -9S9.250 -999.250 -9c. 9.250 NPHI NRAT GR FCNL NCNL NSf I GR FCNL NCNL NRA~ 'fir FCNL NCNL NPHI NRA~ fir FCNL NCNL NPHI NRA~ fir FZNL NCNL NPHI NRA~ FCNL NCNL 1 1 1 1 1 1 1, 1 1 PAGE 68 68 6~ 68 68 68 68 68 68 -999.250 -999.250 -999.250 -999.250 -999.250 22.287 3.152 29.525 79.998 257.716 21.448 2.750 42.934 11B.065 304.163 22.887 3.10~ 50.238 103.357 289.971 42.836 -999.250 -9~9.250 -~99.250 -999.250 -999.250 -999.250 -9~9.250 -~99.250 -999.250 LVP 009.H02 VERIFICATION LISTING FCNL -999.250 ** FILE TRAILER ** FILE NAME :SER~IC.O01 SERVICE N~M,C~ : VERSION ~ : DATE : MAXIMUM LENG~:H : 1024 ~'~ILE TYPE : NEXT FiLE NAME : ~* TAPE TRAILER SERVICE NAM,~] DA~E :81/05/13 T~PE~NAME : CONTINUATION # :01 NEXT TAPE N~ME : COMMENTS :TAPE C£MMENTS ~ REEL TRAILER ** SERVICE NAME :~EERVIC DATE :81/05/13 ORIGIN : REEL NAME :REEL 1D CONTINUATION # f(1 N~XT RE~L NAME : COMMENTS :R~L C[NMENTS PAGE V 'V V V ir_, [':';.; t.'.., B E E E E E.; ~; VV V ¥ VV VV V V V V E'; E: V V V V [.; V V V V VV V V VV VV V V V V g t~,: H H R R R R RR. i I, I 1 1 1, 000000 000000 44 44 000000 000000 44 O0 O0 O0 O0 44 O0 O0 O0 O0 44 000000 000000 44 000000 000000 44 7858 OA'I'P,...; I O-dAN-80 lO-JAN-80 22:28:29 22:34:59 SCHLUMBERGER CUMPUT1NG CENT~.;t~ 10707,5701.0 L E; N G T Fi: 13 REE;L ,NAi~tE: P.C.A b. SERV1CE NAME: ~[)iT REEL CUNTiNUAT1UN PR~ViOU5 REEL NA~E: C(~MaEN'I'8: LIS f'UR~iAT CUS'?,I.'~OME~ TAPE DAT~',: 80/ 1/i0 TAPE HEADER LENGTtt: 1.:12 TAPE NAME: 57010 DAIE: 80/ 1/10 SIr.~R V I,C E NAME: EDIT TAPE CONTINUATION NUMBEN: PREVIOUS TAPE: NAME: C[iMMEN"I'8: UN,[QUE WELh IDENTI~;ICATIUN ,NUMBER i8 50-029-203/7 TAPE CASING-DRI~bER 13.31[a2'729/'BiI DEN8 IO.3/VISC 40/Pa il.O/FLUID-LOS8 RMF' 2.00067 F'/RMC 2.42060 HEADER LENGTtt: 62 SYTES FILE NAME.: EDIT .001 MAXI. MU~ PHYSICAL RECURD LENGTtt: PRkVIOUS FILE NAME; 1024 B~'rEs WkI.,L 81'I'E iNi~UR~qATI. ON RECURO LENGTIt: 1.81 B~Tt~8 C(']~PAN Y: WELL: ~'i~LD: RANGE: TOWN: C [) U a 'l ~: STATE: ATLANTIC RICHfiELD CUMPANY 12-3 PRUDHOE BAt' 15E I ON 18 N. SLUPE ALASKA
