The URL can be used to link to this page

Home My WebLink About203-0821a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 203-082 5/21/2003 5/31/20 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 1182' FNL, 1793' FWL, Sec. 36, T11N, R14E, UM 1261' FSL, 4113' FEL, Sec. 26, T11N, R14E, UM 1294' FSL, 49' FEL, Sec. 27, T11N, R14E, UM Surface: x- y- Zone -688550 5950043 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 4/16/2020 15. 50-029-20081-01-00 16. PBU 02-05A Well Name and Number: Surface / Surface 35.08 17. TPI:y- Zone -682583 ASP 4x-5952339 Total Depth: x-y-Zone -681367 ASP 45952342 13409' / 8959' None DNR Approval Number:19. 74-017 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD, GR, ROP, Memory CNL, GR, CCL CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 13-3/8" 9-5/8" 3-1/2"x 3- x2-7/8" 157.5# 94#/133 72# 47#/40 8.81#/6. 6.16# H-40/K-55 N-80 S00-95/N- L-80 Surface Surface Surface 10296' 2697' 11180' 13409' Surface Surface Suface 8268' 8821' 2695' 8859'3-3/ 12-1/4" 17-1/2" Fondu to Surface 1355 sx Fondu, 425 sx Class 'G' 1480 sx Class 'G', 100 sx Fondu 196 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. [110392' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: See Attached Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): B 111'39"30" 20"Surface 1205'26"750 sx Fondu, 280 sx FonduSurface1204' 10253' / 8241' Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 111' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028308 & 028309 319-272 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 64 Water Depth, if Offshore:13. N/A Zero API Number: 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 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 11180' / 8821' 1900' (Approx.) 5 Submit within 30 days of Completion, Suspension, or Abandonment G By Samantha Carlisle at 7:42 pm, May 14, 2020 Abandonment Date 4/16/2020 HEW RBDMS HEW 5/15/2020 MGR18MAY20 SFD 5/20/2020 DSR-5/18/2020 xG If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Worthington, Aras J Contact Email:Aras.Worthington@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 907 564 4102 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 1a. 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 1b. 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 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. 11376' 11788' 12152' Zone 2A Zone 1B Zone 1A Zone 1A 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 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. Well Tested? Yes 12152'8978' Top of Productive Interval 12152'8978' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList of Attachments: 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. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.05.14 18:18:41 -08'00' TOC in OA ~2097'MD from cementing rpt 21-21-70 ACTIVITYDATE SUMMARY 5/31/2019 T/I/O/OO = VAC/7/0/12. Temp = SI. WHPs (WIE Req). No flowline, wellhouse, or AL. Temporary scaffolding installed. Dry hole tree installed. IAP decreased 3 psi and OOAP increased 2 psi since 05/23/19. SV = C. MV = O. IA, OA, OOA = OTG. 01:30 6/8/2019 T/I/O/OO = VAC/9/0/12. Temp = SI. WHPs (WIE Req). No flowline, wellhouse, or AL. Temporary scaffolding installed. Dry hole tree installed. IAP decreased 2 psi, OAP unchanged, and OOAP unchanged since 05/31/19. SV = C. MV = O. IA, OA, OOA = OTG. 03:45 6/13/2019 T/I/O/OO = 0/14/0/12. Temp = SI. WHPs (WIE Req). Dryhole tree installed. IAP increased 5 psi, OAP unchanged, and OOAP unchanged since 06/08/19. SV = C. MV = O. IA, OA, OOA = OTG. 03:35 6/21/2019 T/I/O/OO = 1/18/1/14. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Temporary scaffold installed. Dry hole tree. TP increased 1 psi, IAP increased 4 psi, OAP increased 1 psi and the OOAP increased 2 psi since 6/13/19. SV = C. MV = O. IA, OA, OOA = OTG. 01:50 6/27/2019 T/I/O/OO = 0/13/1/15. Temp = SI. WHP's. (WIE request). WH & Flow line removed. Dry hole tree installed. TP decreased 1 psi, IAP decreased 5 psi, no change in OAP, OOAP increased 1 psi in 6 days. SV = C. MV = O. IA, OA, OOA = OTG. 14:40 7/12/2019 T/I/O/OO = 0/10/1/20. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Temporary scaffold installed. Dry hole tree. TP decreased 1 psi, IAP decreased 3 psi, OAP unchanged and the OOAP increased 5 psi since 06/27/19. SV = C. MV = O. IA, OA, OOA = OTG. 00:30 7/25/2019 T/I/O/OO = 0/6/1/17. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Temporary scaffold installed. Dry hole tree. IAP decreased 4 psi, OAP unchanged, & OOAP decreased 3 psi since 7/12/19. SV = C. SV = O. IA, OA, OOA = OTG. 14:00 8/10/2019 T/I/O/OO = 0/5/1/17. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Temporary scaffold installed. Dry hole tree. TP unchanged, IAP decreased 1 psi, OAP & OOAP unchanged since 7/25/19. SV = C. SV = O. IA, OA, OOA = OTG. 17:00 8/25/2019 T/I/O/OO = Vac/3/1/18. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. TP went on a Vac, IAP decreased 2 psi, OAP unchanged and OOAP increased 1 psi since 08/10/19. SV = C. MV = O. IA, OA, OOA = OTG. 02:15 9/10/2019 T/I/O/OO = Vac/0/0/20. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged since 8/23/19. SV = C. MV = O. IA, OA, OOA = OTG. 12:25 10/6/2019 T/I/O/OO = Vac/1/1/20. Temp = SI. Conductor Fluid Sample (Ops Call in). No well house or flow line. Dry hole tree and temporary scaffold installed. Dark, viscous fluid exiting the conductor around the centralizer from the 11 - 7 o'clock (fluid sample obtained and dropped off @ Lab). IAP & OAP increased 1 psi since 09/10/19. SV = C. MV = O. IA, OA, OOA = OTG. 17:00 10/9/2019 T/O/O/OO = Unknown. Temp = SI. Installed secondary containment around conductor. Unable to check WHPs due to insufficient scaffold. Dry hole tree and temporary scaffold installed. SV, MV, IA, OA = Unknown. OOA = O. 09:00 Daily Report of Well Operations PBU 02-05A Daily Report of Well Operations PBU 02-05A 10/14/2019 T/I/O/OO = ?/?/?/20. Temp = SI. Bleed OOAP (mitigate leaking conductor). No well house or flow line. Dry hole tree and temporary scaffold installed. OOA FL @ surface. Unable to obtain TP, IAP & OAP due to insufficient scaffold. Dark, viscous fluid exiting the conductor around the centralizer from the 11 - 7 o'clock position, additional fluid exiting the conductor appears to be snow melt (Sample obtained from conductor and dropped off at the Lab). Attempted to bleed OOAP to 0 psi, bled to BT for 10 min and OOAP would not bleed <14 psi (0.77 bbls fluid). OOAP increased from 14 psi to 20 psi in <1 min. Final WHPs = ?/?/?/20. SV, MV, IA, OA = ?. OOA = OTG. 15:30 12/22/2019 T/I/O/OO = VAC/0+/0+/20. Temp = SI. WHPs (LTSI). Wellhouse removed. Dryhole tree & temporary scaffold installed. SV = C. MV = LOTO. IA, OA, OOA = OTG. 16:30 2/18/2020 T/I/O/OO=0/0/0/0+ N/D IA and OA valves, installed integrals and torqued to API specs. Installed block valves and jewelry. FWP's 0/0/0/0+ IA=OTG, OA=OTG. 2/19/2020 ***WELL SHUT-IN ON ARRIVAL*** SPOT IN EQUIPMENT AND PREP FOR TUBING PUNCH ***JOB CONTINUES ON 02-20-20 WSR*** 2/20/2020 ***CONTINUED FROM 19-FEB-20*** (P&A) PUNCHED TUBING 7106' - 7111' W/ 5' 2" TITAN TUBING PUNCH, 4 SPF, 0 DEGREE PHASED, CCL TO TS = 3.8, CCL STOP @ 7102.2'. ESTABLISH COMMUNICATION FROM TUBING TO IA. LOG CORRELATED TO TUBING TALLEY DATED 1-26-77 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 2/21/2020 T/I/O/OO=0/70/0/0 (LRS Unit #72 PLUG AND ABANDONMENT) Communication verified between TBG/IA. Pumped 2 BBL's of 60/40 methanol and 30 BBL's of diesel down TBG at 5 BPM taking returns up the IA to OTT. 1 for 1 returns to tank. Pumped 30 BBL's of diesel down IA at 5 BPM taking returns up the TBG to OTT. 1 for 1 returns to tank. RDMO. DSO notified of well status upon LRS departure. Swab/MV=Shut, IA/OA/OOA=OTG. FWHP=20/50/0/0. 2/23/2020 T/I/O=385/70/15. (LRS Unit #76 Assist SLB CMT P&A) Pumped 10 BBL's of 60/40 and 280 BBL's of 120 deg 1% KCL down TBG. Pumped 41 BBL's of DSL down TBG to displace cement. Freeze protected surface lines with 60/40. Pressured up TBG to 1500 psi. Final valve positions = SV/IA = closed OA OOA = open. FWHP = 1320/27/23. 2/23/2020 SLB Cementing Services Job Scope: T x IA cement P&A from 7106' to surface. RU SLB cement pump and LRS pump truck. Pump the following down the tbg taking returns from the IA:: 280 bbls of 1% KCL at 140 degrees to condition the well, 5 bbls FW spacer, 470 bbls of neat 15.8 ppg Class G cement and 3 bbls of fresh water to flush the lines. Shut down. Launch 7" foam ball. Displace cement w/ 3 bbls of 60/40 spacer and 41 bbls of diesel. Good cement at surface in IA. Block in casing valve at IA and leave 1320 psi on tbg. Wash up surface lines. RDMOL **Job Complete** 15.8 ppg Class G Cement in TBG and IA TOC in TBG = ~2000' MD TOC in IA = Surface BOC in T/ IA = 7100' MD See reservoir abandonment plug. Dated 04-Mar-2019 Daily Report of Well Operations PBU 02-05A 3/6/2020 T/I/O/OO = 0/?/0/23. Temp = SI. Inflow test on TBG & IA. (pre P&A). No flowline, AL or wellhouse. TP is showing exactly 0 psi at this time. Block valve on IA casing is either cemented or frozen in the closed position. Unable to complete job at this time. Job Postponed. SV, SV, SV = C. MV = O. IA = C. OA, OOA = O. 20:30 3/7/2020 T/I/O/OO = Vac/0/0/23. Temp = SI. Inflow test PASSED on TBG & IA (pre P&A). No flowline, AL, or wellhouse. TP on a vac. Was able to open IA block valve. Performed 30 minute inflow test getting 0 returns and no flow. Final WHPs = Vac/0/0/23. SV, SV, SV = C. MV = O. IA, OA, OOA = OTG. 09:00 3/7/2020 LRS Unit 72 Heat Up Right Tank of 160 bbls of Brine from 30* to 160* 3/9/2020 ***WELL SHUT IN ON ARRIVAL*** HES E-LINE 3030 RIH w/ 10' x 2-1/2" MILLENIUM GUN SYSTEM - UNABLE TO PASS 4' RIH w/ 2" SAMPLE BAILER TO 12' - NO RECOVERY ***JOB INCOMPLETE TOOL TAGGED AT 12 FT FROM THE BOTTOM FLANGE *** DSO NOTIFIED 3/11/2020 ***WELL S/I ON ARRIVAL*** (p&a) SWCP 4521 SPOT UP & STBY FOR LOW TEMP ***CONT ON 3/12/20 WSR*** 3/12/2020 ***CONT FROM 3/11/20 WSR*** (p&a) DRIFT W/ 4-1/2" BRUSH, 3.80" G.RING TO 2,010' SLM DRIFT W/ 11' x 2.78" DMY GUN TO 2,010' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 3/16/2020 ***WELL SHUT IN ON ARRIVAL***(perf for p&a) STANDBY FOR WEATHER (SUSTAINED WINDS OVER 30 MPH) STANDBY FOR CRANE REGEN ***JOB CONT ON 03/17/20*** 3/16/2020 LRS unit 72 Assist E-Line (TxIAxOA pressure test P&A) Heated UR of 9.8 Brine to 160* 3/17/2020 ***JOB CONTINUED FROM 3/16/20 *** HES E-LINE 4863 SHOT 10' GUN WITH 11G MILLENNIUM CHARGES 6SPF 60 DEG PHASING FROM 1,770' - 1,780', CCL TO TOP SHOT 2.8', CCL STOP DEPTH 1,767.2' UNABLE TO GET COMMUNICATION TO OA. DECISION MADE TO RIG DOWN FOR NOW. STATE APPROVAL NEEDED FOR HIGHER PERFS. ***WELL S/I ON DEPARTURE. DSO NOTIFIED.*** 3/17/2020 T/I/O= 68/0/0. OOA=0. LRS Unit #70 Assist HES E-Line (PLUG AND ABANDONMENT) Pumped 6 BBL's of DSL down TBG attempting to verify TBG x OA communication after E-line punched. After 6 BBL's, TBG = 575 psi, no response on the OA. S/D and monitor pressures. Pumped a total of 36 BBL's of 0* DSL down TBG with no communication on the OA. Bullhead .89 BBL's of DSL down OA to reach 526 psi, OOAP = 0 psi. Bullhead .41 BBL's of diesel down OA to reach 988 psi, OOAP = 0 psi, still no communcation with TBG. Bleed TBG pressure down to 0 psi with no significant change on OAP, bleed OAP. Line up to pump down TBG up OA to open top tank. Pumped 10 BBL's of 40* crude @ 4.5 BPM, TBG pressure @ ~1444 psi, still no communication w/OA & no returns to open top tank. S/D, TBG lost ~ 1112 psi in 1 minute. Bleed down TBG, stabilizes out @ 135 psi. S/I hardline valves. Casing valves open to gauges E-line on well on departure. Final WHP's = TBG 135, OAP 16, OOAP 0. 3/18/2020 Road to location to stand-by for E-line. Job postponed due to wind. Daily Report of Well Operations PBU 02-05A 3/19/2020 ***WELL SHUT IN ON ARRIVAL*** (p&a) PERFORATE 1,300-1,310' WITH 2.5" HSC, 11G MILLENIUM CHARGES, 6 SPF, 60 DEG PHASE SET BAKER 5.5" CIBP AT 1,000' PERFORATE 500' - 510' WITH 2.75" HSC, 15G MILLENIUM CHARGES, 6 SPF, 60DEG PHASE. ***WELL SHUT IN ON DEPARTURE, DSO NOTIFIED*** 3/19/2020 T/I/O/OO=226/7/67/20 LRS Unit #76 Assist HES E-Line (PLUG AND ABANDONMENT) After E-line perfed TBG x OA, pumped 8 BBL's of diesel and 30 BBL's of 60/40 down TBG to establish a LLR of ~ 5 BPM @ 1000 psi (no response on the OA). TBG pressure dropped off immediatly after shut down, see log for details. Pressure OA to 900 psi w/ 0.36 BBL's of crude (no response on the TBG).E-line set plug. Pumped 0.26 BBL's of 60/40 down TBG to test plug to 900 psi. E-line shot perfs through TBG to OOA and got TBG/OA communication, no change to OOA psi. Pumped 2 BBL's of 60/40 down TBG to pressure upTBG/OA to 500 psi. Pressures fell off after shut down. Pumped 1 bbl diesel down OOA and got an approx LLR 0.5 BPM @ 30 psi. Pumped 1.3 bbls diesel down TBG taking returns up the OOA to OTT with no chang in flow to OTT. RDMO. E-line in control of well upon LRS departure. FWHP=100/5/75/20 3/20/2020 T/I/O= Temp=SI Circ Post ELine Perf (PLUG AND ABANDONMENT) Pumped 50 bbls 30* DSL down Tbg taking returns from OA to open top tank.(SEE LOG) Pumped 3.5 bbls 30* DSL down Tbg taking returns from OOA to open top tank. (SEE LOG) Pumped 12 bbls 9.8 brine down Tbg and out OA. Pumped 10 bbls 9.8 brine down Tbg taking returns from OOA to tank. Pumped 326 bbls of 180*DSL down Tbg taking returns from OA and OOA or just OOA. (SEE LOG) Bled OOA to OTT (SEEE LOG) *** WSR continued on 03/21/20*** 3/21/2020 *** WSR continued from 03/20/20***Circ Post ELine Perf (PLUG AND ABANDONMENT) . Bled OOA to OTT, returns did not stop (SEE LOG). Capped OOA with 10 bbls of DSL. Freeze protected surface lines with 3 bbls DSL. Pumped 59 bbls 100° 9.8 brine down Tbg taking returns from OA to tank. Pumped 11.8 bbls 9.8 Brine down OOA. Conductor started having fluid come to surface. Pumped 4 bbls 60/40 meth to FP choke trailer and hardline. DSO notified of well status per LRS departure. SV,SV,MV=C IA,OA,OOA=OTG FWHP's=-20/-20/-10/-5 3/27/2020 T/I/O/OO = VAC/VAC/VAC/16. Temp = SI. Remove centralizer (P&A). Temporary scaffolding, no wellhouse, AL, or flowline. Put heater on wellhead to thaw ice around the centralizer. When ice thawed, pried centralizer out of surface casing. Leave heater on wellhead to keep fluid in surface casing thawed. Final WHPs = VAC/VAC/VC/16. SV, MV = C. IA, OA, OOA = OTG. 23:30 3/29/2020 Initial T/I/O/OO= VAC/0/VAC/13, LRS 72 assist SLB (P&A) Pumped A total of 35 bbls 60/40 and 30 bbl FW Surfactant to assist with P&A. See log for details. Valve positions= MV, SV, IAC, OAC, OOAC= Closed. FWHP= 58/0/-10/-9 Daily Report of Well Operations PBU 02-05A 3/29/2020 Initial T/I/O/OO= VAC/0/VAC/13 SLB Cementers - OOA Downsqueeze, TxO Surface Cement Plug (PLUG AND ABANDONMENT) Pumped Down OOA: LRS pumped 8 bbls 60/40, SLB pumped 5 bbls freshwater spacer, 100 bbls of 15.8 ppg class G cement. Pumped Down TBG w/ OA returns to OTT: LRS pumped 12 bbls 60/40, 30 bbls surfactant, SLB pumped 5 bbls freshwater spacer, 65 bbls 15.8 ppg class G cement. Clean cement returns at surface. Valve positions= MV, SV, IAC, OAC, OOAC= Closed. FWHP= 0/0/-10/-9 TxIxOxOO TOC @ Surface. Ready for excavation. 4/1/2020 T/I/O/OO=0/0/0/0. P&A job. Bleed 00/A to 0psi. Monitor for 1hr. RD 3" McVoy OO/A valve. RU 3" plug with needle valve. Job Complete. See log. Final WHP,s 0/0/0/0. 4/10/2020 ***02-05 P&A*** Excavated to a depth of 14'. Set shoring box. Set Wach Saw @ 30" above bottom of excavation. Pad elevation @ 31' 2". Tundra elevation @ 25'. Cut WH @ 19' 7"below pad grade (5' 3" below tundra elevation). Found 28' void in tubing & 5' 10" void in OOA. ***JOB IN PROGRESS*** 4/11/2020 ***02-05 P&A*** Completed cement top job. Added approximately 76 gal. of AS1 cement to voids in OOA & tubing. Left to set up for state inspection. ***JOB IN PROGRESS*** 4/16/2020 ***02-05 P&A*** State witness Guy Cook. State verified cement top job and marker plate. Welded on marker plate. Pulled shoring box. ***JOB IN PROGRESS*** 4/17/2020 ***02-05 P&A*** Back filled & compacted excavation. Deliniated excavation footprint. ***JOB COMPLETE*** WWEL L NA ME:02-05A 226.Ac i d , Fr ac t u r e, Cem en t Sq u eeze, Et c . Depth Interval (MD) Amount & Kind of Material Used 7106' - 7111' Tubing Punch ~2000' 470 Bbls Class 'G' 1770' - 1780' Tubing / Casing Punch 1300' - 1310' Tubing / Casing Punch 500' - 510' Tubing / Casing Punch Surface 165 Bbls Class 'G' Surface 76 Gal Arctic Set I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg� 4I �7�ti DATE: 4/16/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector PBU 02-05A BPXA PTD 2030820; Sundry 319-272 4/16/2020: 1 arrived on site for the redo of BP's surface abandonment of PBU 02-05A. Inspection by AOGCC Inspector Jeff Jones on 4/12/2020 found contaminated cement in the Intermediate by Production casing annuls requiring them to dig out as deep as possible and re -cement. I met with Jon Arend (BP) and we talked about the job. I went into the cellar to inspect the cut-off casing. The cement was to the top of the casing and was good, cured cement in all pipe spaces. I used a 5 -foot steel bar to confirm the cement was cured and hard. After measuring I concluded the cut-off casing depth is 5.3 feet below tundra. I witnessed the installation of the identification plate and all the welds looked good with no obvious cracks or gaps in the bead. All the information on the identification plate was correct. I told Jon Arend they were okay to proceed with burying the well. - Attachments: Photos (4) 2020-0416_ Surface_Abandon_PBU_02-05 A_gc. docx Page I of 3 Surface Abandonment — PBU 02-05A (PTD 2030820) Photos by AOGCC Inspector G.Cook 4/16/2020 2020-0416_ Surface—Abandon _PBU_02-05 A_gc. docx Page 2 of 3 2020-0416_Surface_Abandon PBU_02-05A_gc.docx Page 3 of 3 rA 4 Ir'i �r -yr <I; �kf� `t✓> 2020-0416_Surface_Abandon PBU_02-05A_gc.docx Page 3 of 3 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Katherine O'connor Integrity and Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU02-05A Permit to Drill Number: 203-082 Sundry Number: 319-272 Dear Ms. O'connor: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, re 'ce r DATED this day of February, 2020. IBDMSI� FEB 0 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAY 2 8 20tg Pi's W a 1. Type of Request: Abandon 0 ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 • p 5. Permit to Dnll Number: 203-082 ' Addmss. P.O. Box 196612 Anchors a AK 3. g 6. API Number: 50-029-20081-01-00 9951 M612 Stratigraphic ❑ Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No m PBU 02-05A , 9. Property Designation (Lease Number).10. Field/Pools: ADL 028308 8 028309 ' PRUDHOE BAY, PRUDHOE OIL 11 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(fl): Effective Depth MO Effective Depth TVD: MPSP (p$): Plugs (MD): Junk (MD)'. 13409 8959 7223 6207 7223.10091.10138 10117, Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 31 - 111 31 - 111 880 Surface 912 20" 31 -1206 31-1204 1530 / 2320 520/1500 Intermediate 2668 13-3/8" 29-26971 29 - 2695 4930 2670 Production 11153 9-5/8" 27-11180 27 - 8821 8150 / 6870/6820 5080 14760 13330 Liner 3113 3-1/7'x 3-3/16" x 2-7/8" 10296 - 13409 8268-8859 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12220- 1 8988 - 8958 5-1/2" 17# x 4-1/2" 12.6# N-80 24-10392 Packers and SSSV Type: 5-1/2" Baker SAB Packer Packers and SSSV MD (ft) and TVD (ft): 10253/8241 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary ® Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: July 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 ' IT 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: O'connor, Katherine be deviated from without prior written approval. Contact Email: Kathenne.0'cOnnorflbp.cOm Authorized Name: O'connor, Katherine Contact Phone: +1 9075644640 Authorized Title: Integrity 81nlnteryent/iioons Engineer Authorized Signature: -1 '? / �! 87! Date: L7' Z- "�/ 1 C COMMISSION USE ONLY Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -/ Plug Integrity nttegnry Test ❑ ocation Clearance IN y ❑ ///� BOP Test ❑ Mechanical Other: Ie�LO �QCI�EC-I7'a`zW � 6�S (�4f./� �� ,/ -IBDMS & FF8 0 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? No 1 Subsequent Form Required: 146 - q,� r; APPROVED BYTHE �J{ Approved by: COMMISSIONER COMMISSION Date: ✓ (/l/ ME ORIGINAL 9- o"v -2"l a1Submit Form and IVI.Crft. to ^�L��"' / Form 10-403 Revised 0412017 Approved application is valid for 12 months from the date of approval. Attachments In Duplicate .•t�� /-� S: 3v /i1 by Cz 02-05 Fully Abandon Well - 10_403 Intervention Engineer Katherine O'Connor (214) 684-7400 Expected Start Date: July 1, 2019 Well: 02-05A History GPB Well 02-05A was initially drilled and completed in December 1970. The initial completion was in Zone I and the well was sidetracked in June 2003. Until 2009, the well was operable and produced with very little off time until 2009 when a tubing leak was discovered. There were many attempts to set patches, but none of them brought the well back to operable. In 2017 was the final attempt to set a patch. During the patch setting operation, the tool did not release from the patch and the fish was left in hole. Simultaneously, the well was determined to be not operable due to its similar well design to 02-03 (Gen 1 well head, 3 casing string design and casing shoe set in the permafrost). This well has been not operable with a plug downhole since this time, and we are now proceeding with the full abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Place a intermediate and surface plug in well, then cut 3' below tundra to fully abandon the well. History • Made not operable in 2009 due to TxIA leaks • Long history of setting patches & failing pressure tests (history attached in appendix). • 2010 LDL showed leaks at sliding sleeve (10,133' MD) and 10,189 MD and a caliper in 2009 showed a hole at 10,179' MD. • The well remained shut in after 2010's attempt to set a patch • In 2017 SL attempted to set a long patch, but in the final piece, the setting tool did not release. Fishing operation was unsuccessful and the well has been shut in since. • CMIT-TxIA to 2603 psi in March 2017 • TxIA communication noted in FB AWGRS 3/21/17 — IA tracked tubing • Attempted a lube and bleed well kill on 1/1/2019 and determined that the plugs in the well are not holding and leak fluid/gas. A flow test yielded —1 cup of fluid returns in 20 minutes. The well is gradually swapping over back to gas. • Cement plug placed 2/25/19. TOC tagged @ 7233' MD 3/4/19 and pressure tested — witness.' Valve Shop 1. Drop all annulus gate valves and install integral valves. EL/Relay— Punch tbg for intermediate plug 1. Punch tubing at — 7109' MD Fullbore — Intermediate Cement plug Well: 02-05A 2. Pump 470 bbls of cement down the tubing and up the IA. Once clean returns are seen at surface, chase the cement with diesel, leaving the TOC at 2000' MD. EL/Relay & Fullbore —Perforate for I" stage of surface plug 3. Perform an inflow test on tubing by bleeding pressures to zero and waiting for 30 min to determine if there is fluid flow. 4. Perforate through tubing and 9-5/8" casing at 1770' MD. Fullbore — Circ Hydrocarbons from well 5. Circulate hydrocarbons (ArcticPack) out of OA Fullbore — Placing cement plug 6. Rig up to take returns from the OA. 7. Pump — 155 bbls of cement down the tubing, taking returns from the OA. Once clean returns are seen at surface, chase cement with brine, leaving TOC at 630' MD Eline & Fullbore — Tag TOC, Pressure Test, Perforate for 2"" State Surface Cement Plug 8. Tag TOC and note in AWGRS. 9. Pull up —150 ft from tag depth to perforate through tubing, 9-5/8" casing and 13-3/8" casing at —500' MD. Fullbore — Circ Hydrocarbons from well (20"x13-3/8" annulus) 10. Circulate hydrocarbons (ArcticPack) out of well using the following pump schedule (pump schedule in table form in the appendix): Fullbore — Placing 2"" stage surface cement plug 11. Rig up to take returns from the OOA. 12. Pump -125 bbls of cement down the tubing, taking returns from the OOA pump until clean returns are seen at surface then shut in the OOA & tubing. Special Projects — Final Excavation 13. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 14. Photo document all steps. 15. Cut off all casings and wellhead 3' below tundra. by 2 Well: 02-05A 16. Top off tubing and annuli with cement if needed. �> t 6cL ,,,ip.,,. 4 C'� Y� �w Since 17. Weld marker cap on outermost casing string (conductor, if present). The marker plate should have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 2030820 c. Well Name — 02-05A d. API # — 50-029- 081-01 r &-. P1�— actrw.e..�¢ wapy—l.er �a>ic i�S7�JGe� Cement Calculations — Intermediate Cement Plug Total cement to pump 470 bb(s Cement Type /Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the Fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination l Safety 2 Minimum required thickening time: 6 Cement Calculations — Surface Cement Plug Stage One Total cement to pump 155 bbls 3 by 2 Well: 02-05A Cement Type /Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 1 Safety 2 Minimum required thickening time: 6 Cement Calculations — Surface Cement Plug Total cement to pump 125 bbls Cement Type /Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110' F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 by Well: 02-05A Cement contamination 1 Safety 2 Minimum required thickening time: 6 I TREE= DRY HOLE WELLHEAD= MCEVOY ACTUATOR= REMOVED KB. E -EV = 64' BE E -E/ = 37.18' KOP= 3159' Max Arg* = 100" (912644' Datum MD= 11288' DatumTVD= 8800'SS 3( CONDUCTOR -119 9-5/8" CSG. 47#, —120 S0095 BTRS, D = 8.681' 20' CSG, 133#, 293' K55, ID =18.750' 720, N-80 BTPS, ID =12.347' 40#,S0095 BTRS, ID = 8.835" L 47#. N-80 BTIRS. ID = 8.681" Minimum ID = 2.313" @ 10138' 2-7/8" X NIPPLE PROFILE IN PTSA 2-7/8"X NIP IN PATCH ASSY, D=2.313'(03/20/17) 1019 KB LOWER STRDL PKR D 1 13-12' LNR, 8.81#, L-80_0081 bpf, ID=2.88( ) 4-12' TBG. 12.6#. N-80..0152 bot. ID = 3.958' PERFORATION SIIMIMARY REF LOG: MWD ENR -GR ON 05/17/03 TO 05131/03 ANGLE AT TOP PERF: 82 @ 12220' Note: Refer to Production DB for historical pert data SIZE SPFJ INTERVAL jOprVSqz SHOT SOZ 2' 6 12220 - 12310 O 06/02/03 2' 6 12340 -12380 O 06/02/03 2" 6 12470 -12500 O 06/020)3 2' 6 12600 -12670 O 06/02/03 2' 4 12690-12900 O 06/02/03 2" 4 12950 -13190 O 06/02103 2' 4 13290 -13380 O 06/02103 SAFETY NOTES: REDUCED COLLAPSE RATING ON 02-05A 9-518'. 20' CLAMPED TO 30" DUE TO WELLHEAD '`\ `I ' MOVEMENT 1993. WELL ANGLE 11333'. 7233' SLM TAG TOC STATE WITNESS SL (03104119) TX#1 TOC -7941' (0225/19) FAILED TO RELEASE FROM 5-12' ER HCR ;1-3/4' EXTERNAL FISH NEMQ (03/22117) 5-12" WFT ER UPPER STRDL PKR w /PISA D = 2.313' (0320/17) 5-1/2' BKR SLIDING SLV, D = 4.31' BEHIND PATCH w 10 91- 5-x3" BND PATCH ==109) A/09) BEHINDD PATCH 9-m- X 5-12' BKR SAB PKR 107W 3-3/16' LNR 620, L-80, .0057 bpf, D=2.805' DATE REV BY COMMENTS DATE REV BY COMMENTS 1222770 ORIGINAL COM PLENON 03/18/19 JJIJJMD TX#\ TOC (0225/19) 0126777 LAST WORKOVER 03/18/19 KFVJMD DRY HOLETREE(0227/19) 06103103 DAVAM CTO SIDETRACK(02-05A) 03/18/19 MKJMD SL TAGGED TOCw/STATEWiTNESS(3 03/30/17 EDLYJAD CLEANED UP J AIELRY BEHIND 0523/19 JNJJMD UPDATED BF El 04/13/17 ETJ/JMD MINOR EDIT" TO SBR 01/31/19 BTNVJIMID SET C13P&TBG PUNCHES 0151LOY SLV, 10= X NIP, II) =2.813" D CT LH" X 3-3/16' XO, D = WLED, D = 3.958' D CT LNR) FISH: EXTRUSION RING & PARML E-EMEN T FROM WFT ER STRADDLE PKR(09/16/15) 11236' 3-3/16' X 2-78' XO, 1 2.372 PRUDHOE SAY UNIT WB -L: 02-05A PERMIT No: 2030820 AR No: 50-02920081-01 SED 36, T11 N, 1114E, 3636' FB- & 4301' FNL SP Exploration (Alaska) 2 e*#& 2 A�"e Traff- AC = Lateral surface cement Ks e.EV: plug in TBG and OOAOF ELEV j 3p•�q 13y TOC est. 630' �. �sc,1 MD, cement Ai svFCGa4?e,soom OAtosurface+i%=rsc.` TOC est 2170' MID `s se TOC est 2945' MD sesr TOC est 6961' MD 10138' 12-718^ X NIPPLE PROP LE IN PTSA r7-74t•X NFN PAI Q4 A..1Y. 11.136'!91i]pi1/1 �'-j 10111 3061 w- D= 91wm n- AF4LCATTOPFUFA2@ 12SM Nob. fifer b MWwwon M far NM"" W 6r- SLEISPF 190200; OMMLCONKETgN Wr6WAL OPrAU SHOT j SW 7 16 17x10-12310 0 OSMM 7 6 12310 -1239(3 O C64M 7 16 12470-1211X1 0 O&MM 7 6 12900 - 12670 0 O&wM 2• 4 INN - 12600 o O64Yd00 7 4 /29W 13190 O 0641203 7 4 t329C - 133W O 09412M Well: 02-05A 02-05A ( SAFENUDYFS:$M"-,'1"zxlA PATNGCN %Yr. 20• C AMM 1030.OLE 10 VWLU"D ICNF1BJi t990 WB.L A)YYE% N®'1I33T. � i n• s1rrBlyiFsy196.9Vw.D-i6ez• TOC est. 660' MO TOC est. 1830' MD DATE FVW OY OOMMMS ATE FV/6Y RM&NIb 190200; OMMLCONKETgN 17 OU CLEAf&DuPJMT3- 60"FRTCH 3RR77f 1237 r90fi00YBt 13117EVOLM MMOR ELKS 10 SM 64163413 Dwaoc cmaraalcKixa6AF Oy17116', S'1N.2,V CUMRLV W l AHi 07f111fti N!9lfl 567 EVOf�VE0.UOw 17Cw NT]C 07790'17 Q9'.W SET MTQiw IPT"uARP6 0.lG - rU1 FLOG Est TOC 2000' K MD intubing [A 7�"KR 0322117] cement to surface a y mmn: IF) -231r!Ce'20u17) .__ .._ .—_._. S1T 6KR 5L[WD SLV, O=< 31' OOaND MTCN t24V X NP N RM. 0-Z 313• (0312&11{ l 2.395• abe�l.w ol;/a.41s71aaarorArcN I MMMw.o-3612.1 OCTLIMr _I X5306'XO,O=ZW XTR4FiYfltifilG A Pe V PROM WFT FR CLEPKR(OY/I&/S) 36. 1 lye 0-2172* MDA tkky NII MIL 02052 PEW No 1203DM AS tb 50aM2O061 01 T11R R14F 3636' 18 i 4301 UP 5wiWasoR Wwkel 7 Pt :to"1-0VC STATE OF ALASKA pp , �. ALASKA OIL AND GAS CONSERVATION COMMISSION r"(Vi 2 `) REPORT OF SUNDRY WELL OPERATIONS 1 9 Form 10-404 Revised 04/2017 / rV%fJ mr-R *29- - %MMS � MAY 2 9 2019 Submit Original Onty 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ';❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 203-082 3. Address. P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service ❑ 1 6. API Number: 50-029-20081-01-00 7. Property Designation (Lease Number): ADL 028308 & 028309 8. Well Name and Number: PBU 02-06A 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 13409 feet Plugs measured 7223, 10091, 10138 feet true vertical 8959 feet Junk measured 10117, Unknown feet Effective Depth: measured 7223 feet Packer measured 10253 feet true vertical 6207 feet Packer true vertical 8241 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 30" 31 - 111 31 - 111 880 Surface 912 20" 31 -1205 31 - 1204 1530/2320 520/1500 Intermediate 2668 13-3/8" 29-2697 29-2695 4930 2670 Intermediate 11153 9-5/8" 27-11180 27-8821 8150 / 6870 / 6820 5080 / 4760 / 3330 Liner 3113 3-1/2" x 3-3/16" x 2-7/8" 10296 - 13409 8268-8959 Perforation Depth: Measured depth: 12220 - 13380 feet True vertical depth: 8988-8958 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6# N-80 24-10392 24-8326 Packers and SSSV (type, measured and 5.1/2" Baker SAB Packer 10253 8241 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: Shut -In Subsequent to operation: Shut -In 14. Attachments: (reawren per 20 MC 25 070 s 25.2a3) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigrephic ❑ 16. Well Status after work: oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-006 Authorized Name: Worthington, Ares J Contact Name: O'connor, Katherine Authorized Tii Interventions & Integrity Engineer Contact Email: Katherme.O'connor0bp.wnn Authorized Signature: Date: S Contact Phone: +1 9075644640 Form 10-404 Revised 04/2017 / rV%fJ mr-R *29- - %MMS � MAY 2 9 2019 Submit Original Onty T/1/0/00 = 1330/500/10/10. Temp = SI. Lube & Bleed (assist FB). No flowline or well house. Temporary scaffold installed. Initial TBG FL @ 3680'(86 bbls). Bleed TP for LRS 1/20/2019 as need for lube & bleed. Continued on 1/21/19 AWGRS. T/I/0=1330/504/6/6 Temp= S/I (LRS 70- Assist FB w/ Lube & Bleed/ Injectivity test) Pumped, over the coarse of 10 Iterations a total of 103 bbls 50/50 MW down tbg to lube 1/20/2019 and bleed. ***Continued on 01-21-19 WSR*** Continued from 1/21/19. Temp = SI. Lube & bleed (Assist FB). No wellhouse or flowline. Temporary scaffolding installed. FLs & bleed TP for LRS as needed for lube & bleed. Final 1/21/2019 WHPs = 200/380/10/0+. LRS in control of valves upon DHD departure. 02:00. ***Continued from 01-20-19 WSR*** (LRS 70- Assist FB w/ Lube & Bleed/ Injectivity test) Injectivity test results as followed, Pumped 147 bbls 50/50 MW at 2.3 bpm @ 2700-2750 psi. IA slowly gained 605 psi while pumping down TBG. Freeze protected hardline from choke skid to open top tank with 5 bbls 60/40 MW. SV WV SSV= closed MV IA OA OOA= 1/21/2019 open. DSO notified. FWHPS=75/565/5/5 T/I/O = 170/380/VAC. Temp = SI. T FL (eval FL dropout). Wellhouse, flowline, and scaffold removed. Temporary scaffold installed. T FL @ 960'(23 bbls). TP decreased 30 psi, IAP unchanged, OAP decreased <10 psi overnight. 1/22/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 T/1/0/00 = 310/410/VAC/0+. Temp = Sl. Confirm Clearances on Wells/ T FL.(Eval fluid drop out). No wellhouse, AL, or flowline. Temporary scaffolding installed. WV is 34" below scaffold platform. IA hardline & jewelry is 28" below scaffold railing. TBG FL @ 1160' (27 bbls). TP increased 140 psi, IAP increased 30 psi, OAP unchanged overnight. OOAP unchanged. 1/23/2019 SV,WV, SSV = C. MV=O. IA, OA, OOA = OTG. 24:00. T/1/0/00 = 390/430/VAC/0+. Temp = SI. T FL.(Eval fluid dropout). No wellhouse, AL, or flowline. Temporary scaffolding installed. TBG FL @ 1260' (29 bbls). TP increased 80 psi, IAP increased 20 psi, OAP & OOAP unchanged overnight. 1/24/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 22:00 T/I/0/00 = 510/510/VAC/0+. Temp = SI. T FL (Eval fluid drop out). No wellhouse, AL, or flowline. Temporary scaffolding installed. TBG FL @ 1320' (31 bbls). TP increased 120 psi, IAP increased 80 psi, OAP & OOAP unchanged overnight. 1/25/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 17:00 ***WELL S/I ON ARRIVAL*** (secure) RIG UP HES RELAY UNIT 046 1/27/2019 ***CONT. ON 01/28/2019 WSR*** T/1/0 = 20/520/0. Temp = SI. IA FL (Eline request). No AL, flowline, or wellhouse. Temp scaffold installed. IA FL @ 640'(28 bbls). 1/28/2019 Halliburton ELine in control of well on departure. 1700 hrs. ***CONT. FROM 01/27/2019 WSR*** (secure) RELAY UNIT 046 SET 4.35" SVB EZ DRILL @ 10,092' M.E. TOP OF PLUG @ 10,091'. CCL- M.E. = 15.3' STATE WITNESS TAG OF CIBP. PASSED NEGATIVE PRESSURE TEST LOGGED PDS CALIPER FROM 2100' TO SURFACE @ 50'/ MIN... GOOD DATA ATTEMPT TO PUNCH TBG, CONFIRMED GUN DID NOT FIRE 1/28/2019 ***CONT. ON 01/29/2019 WSR*** ***CONT. FROM 01/28/2019 WSR*** (secure) RELAY UNIT 046 PUNCH TUBING FROM 10,076' MD - 10,081' MD, 11.3' CCL TO TOP SHOT, CCL STOP @ 10,064.7' ELMD...GOOD COMMUNICATION TAX 1/29/2019 ***JOB COMPLETE, DSO NOTIFIED OF WELL STATUS.*** Daily Report of Well Operations 02-05A T/I/0= 60/520/7/7 (LRS Unit 70 - Circ Out Tubing & IA) Pumped the following down the tubing, taking returns up the IA to 02-34's flowline: 5 bbls neat methanol followed by 60 bbls surfactant followed by 715 bbls 9.8 brine followed by 34 bbls 60/40 methanol down TBG, back up IA, taking returns down flowline 02- 34. Attempted to U-tube freeze protect between TBG and IA but results were inconclusive. Freeze Protect IA w/ 14 bbls 60/40. All tree valves closed except casing valves. 1/30/2019 FWHP's vac/vac/13 T/I/0 = SSV/0/0 Temp = SI. Job Objective: Cement Control & Balance line with SqueezeCrete ultra fine cement. Injected 2.3 gallons of SqueezeCrete cement down Balance line and 2.3 gallons down the Control line Wait 48 hours before pressure testing. 2/2/2019 No red line required. ***Job Complete*** T/I/O = Vac/35/0. Temp = SI. TBG & IA FL (WIE Req), No AL, flowline, or well house. Tbg FL @ near surface. IA FL @ 1730' (76 bbls). Temp scaffolding installed around tree. Hardline R/U on IA & TBG for circ -out w/ secondary swab vlv. 2/3/2019 SV, SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:30 T/I/O = Vac195/0. Temp = SI. TBG & IA FL (WIE Req), No AL, flowline, or well house. Tbg FL @ near surface. IAP increased 60 psi & IA FL dropped 50' to 1780'(78 bbls) overnight. Temp scaffolding installed around tree. Hardline R/U on IA & TBG for circ -out w/ secondary swab vlv. 2/4/2019 SV, SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 T/I/0=0/235/0/0 SI (LRS Unit 46 - Remedial Circ Out, CMIT-TxIA, LLR) Pumped the following down the tubing, up the IA, to surface tanks: 3 bbls 60/40 followed by 252 bbls 120* 9.8 brine down TBG up IA taking returns to tank. Well is fluid packed, Shut in IA returns, pump 39 bbls 20* 60/40 down TBG thru leak in well to establish a LLR of —1.7 bpm @ 1045 psi.. Swap to IA, shut-in tubing returns, pump 22 bbls 20* 60/40 down IA thru leak in well. LLR —1.7 bpm — 1130 psi. See log for details. Valve positions=SVs WV SSV closed MV open CVs OTG 2/5/2019 FWHP=50/100/20/3 T/I/O = Vac/78/0. Temp = SI. TBG & IA FL (WIE Req), No AL, flowline, or well house. Tbg FL @ near surface. IA FL @ 1775'(78 bbls). Temp scaffolding installed around tree. Hardline R/U on IA & TBG for circ -out w/ secondary swab viv. 2/6/2019 SV, SV, WV, SSV = C. MV = O. IA, OA = OTG. 9:00 T/I/0 = VAC/78/0. Temp = SI. PT Balance & control lines to 2500 psi (pre P&A). Line @ the 12 o'clock position failed (attempted 8 times). Line @ the 6 o'clock position passed to 2440 psi. 2/7/2019 SV, SV, WV = C. SSV, MV = O. IA, OA = OTG. 16:45 TWO = Vac /67/0. Temp = SI. TBG/IA FL (WIE Req), No AL, flowline, or well house. Tbg FL @ near surface. IA FL @ 1995' (88 bbls). Temp scaffolding installed around tree. Hardline R/U on IA & TBG for circ -out w/ secondary swab viv. 2/7/2019 SV, SV, WV, = C. SSV, MV = O. IA, OA = OTG. 14:00 T/I/O/00 = Vac/100/0/5. Temp = SI. TBG & IA FL's. (WIE request). No AL, well house or flow line. Unable to get TBG FL due to strong Vac (need N2, or AL gas). IA FL @ 2043', (90 bbl). ***Note*** Informed by the WS foreman that there was a foam ball between the 2 swab valves, when the WS crew removed the second swab valve the foam ball was gone (down the tubing). 2/10/2019 SV, WV = C. MV, SSV = O. IA, OA, OOA = OTG. 01:40 T/1/0/00 = Vac/120/0/5. Temp = SI. IA FL (WIE req). IA FL @ 2060'(90 bbls). IAP increased 20 psi overnight. 2/11/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 01:00. Daily Report of Well Operations 02-05A ***WELLS/] ON ARRIVAL'"* (Plug & Abandonment) HES RELAY UNIT #46 INITIAL T/I/0/00 = VAC/125/0/0. MIRU HES & LRS. DRIFT TO 10,059' SLM W/ 3.85" CENT, 1-3/4" SAMPLE BAILER (recover sample of foam ball). PERFORM BASELINE PASS AT 100 FPM FROM SURFACE TO TOP OF CIBP AT 10,091' MD. LRS PUMP 90 BBL'S OF 9.8 PPG BRINE AT 3 BPM DOWN IA. REDUCE RATE TO 1 BPM FOR LOGGING. PERFORM STATION STOP ABOVE PLUG AT 10,091' MD, AND THEN LOG OOH AT 100 FPM. SEE LOG FOR DETAILS. ALL LOGS CORRELATED TO TUBING TALLY DATED 26 -JAN -1977. 2/12/2019 ***JOB CONTINUED ON 13 -FEB -2019*** T/1/0= Temp=S/I (LRS Unit 42 -Assist E -line: Leak Detect Log) Load IA w/ 2 bbls 60/40 meth followed by 295 bbls of 9.8 Brine while E -line to performed LDL. Freeze protected the IA with 25 bbls 60/40 meth. RDMO. Hung FP tag on IA. E -line in control of well upon LRS departure. IA/OA=OTG. 2/12/2019 FWHP's=500/600/50 T/I/0 = SSV/0/0 Temp = SI. Job Objective: Cement Balance line with SqueezeCrete ultra fine cement. Injected -1 cup of SqueezeCrete cement down balance line increasing pressure to 4000 psi. Monitored for 30 min gauge on balance line read 4000 psi. No red line required. 2/13/2019 Halliburton S/L on well upon departure. 12:30 ***CONT FROM 2/12/19 WSR*** (plug & abandonment) RIGDOWN HES RELAY UNIT 046 2/13/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/1/0/00 = Vac/150/0/0. Temp = SI. IA FL (WIE Request). No flowline or wellhouse. Temporary scaffolding iinstalled. Hardline running from the IA & flow cross to a choke trailer. IA FL @ 1980' (87 bbls). TP decreased 500 psi. IAP decreased 450 psi, and the OAP decreased 50 psi since 2-12-19. 2/14/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 12:45 T/I/O/00 = Vac/150/0/0. Temp = SI. IA FL (WIE request). Temp scaffolding installed. IA FL @ 1950' (85 bbls). WHPs unchanged overnight. 2/15/2019 SV, SV, SSV = C. MV = O. IA, OA, OOA = OTG. 10:10 T/I/O/00 Vac/1540/0. Temp = SI. IA FL (WIE Request). No wellhouse or flowline. Temporary scaffolding installed. IA FL @ 1980' (87 bbls). Hardline rigged from TBG flow cross and IA to a choke trailer. 2/16/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 13:30 T/I/O/00 = Vac/140/0/0. Temp = SI. IA FL (WIE Req). No wellhouse or flowline. Temporary scaffolding installed. IA FL @ 1980' (87 bbls). Kelly hoses/ Hardline rigged up to the flow cross and IA to a choke trailer. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 13:20 2/17/2019 T/1/0/00 = Vac/170/0/10. Temp = SI. IA FL (WIE Req). Nowell house or flowline. TFL inconclusive. IA FL @ 2030'(89 bbls). Kelly hoses/ Hardline rigged up to flow cross and IA to choke trailer. 2/19/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 05:30 T/I/O/00 = Vac/230/0/10. Temp = SI. IA FL (WIE Req). No well house or flow line. Temporary scaffold installed. IA FL @ 2080' (92 bbls). IAP increased 60 psi overnight. Kelly hoses/ hardline rigged up to flow cross and IA to choke trailer. 2/20/2019 SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 03:15 Daily Report of Well Operations 02-05A T/I/O/00 = Vac/350/0/10. Temp = SI. IA FL (WIE Req). No well house or flow line. Temporary scaffold installed. IA FL @ 2120'(93 bbls). IAP increased 120 psi since 03:15 yesterday. Kelly hoses/ hardline rigged up to flow cross and IA to choke trailer. SV, WV, SSV = C. MV = O. IA, OA, ODA = OTG. 08:00 2/2112019 T/1/0/00 = SSV/380/0/10. Temp = SI. IA FL (WIE Request). No well house or flow line. Temporary scaffold installed. Wiper ball loaded in between swab valves. IA FL @ 2215' (97 bbls). IAP increased 30 psi overnight. Kelly hoses/ hardline rigged up to flow cross and IA to choke trailer. 2/22/2019 SV, SV, WV, SSV = C. MV = O. IA, OA, ODA = OTG. 15:00 T/I/O/00 = SSV/380/0/10. Temp = SI. IA FL (WIE request). No wellhouse or flowline. Temporary scaffolding installed around well. Wiper ball loaded between swab valves. IA FL @ 2215'(97 bbls). IA FL and WHPs unchanged overnight. Kelly hoses and hardline rigged up to flow cross and IA choke trailer. 2/23/2019 SV, SV, WV, SSV = C. MV = O. IA, OA, ODA = OTG. 16:45 T/1/0/00 = SSV/380/0/10. Temp = SI. IA FL (WIE request). No wellhouse or flowline. Temporary scaffolding installed around well. Wiper ball loaded between swab valves. IA FL @ 2215' (97 bbls). IA FL and WHPs unchanged overnight. Kelly hoses and hardline rigged up to flow cross and IA choke trailer. 2/24/2019 SV, SV, WV, SSV = C. MV=O. IA, OA, OOA = OTG. 16:30 T/I/0/00= vac/370/6/4. (LRS Unit 46 -A/SLB Cementers w/ Balance Plug) ***REFER TO SLB AWGRS FOR COMBINED SUMMARY AND SLB SPECIFIC DETAILS*** Bleed down IA to 0 psi prior to pumping. Pumped 5 bbls 60/40 meth followed by 169 bbls 9.8 PPG NaCl brine down TBG taking returns up IA to open top tank. Got returns to tank at 140 bbls away. Waited for SLB to pump spacer, cement, and drop balls. Chased cement at max rate with 158 bbls of NcA1 down TBG taking returns up the IA after cement pumped. Able to catch pressure temporarily with 10 bbls to go before reducing rate and opening choke to minimize losses. Pumped 3 bbls 60/40 down TBG to freeze protect. Pumped 5 bbls 60/40 down IA to freeze protect. Pumped 3 bbls 60/40 down surface lines to flush and freeze protect. WV/SV/SSV= closed MV=open IA/OA/OOA= OTG DSO/WSL notified of well 2/25/2019 status. FWHP's 0/167/32/3. T/1/0/0 = Vac/370/613 (SLB Cementing - Plug and Abandonment - Tx IA Balance Plug) SLB pumped the following down TBG taking IA returns to Open Top Tank: 205 BBLS 15.8 PPG Class G unislurry Cement 7 BBLS freshwater / 2 x 7" Foam Balls ***Refer to LRS AWGRS for LRS details*** FWHPS = Vac/1 67/32/4 2/25/2019 ESTIMATED TBG x IA TOC = 7941' MD / 6690' TVD T/I/0/00 = SV/90/4/6. Temp = SI. IA FL (WIE Req). No wellhouse or flowline. SV has sign saying wiper ball is loaded do no operate. IA FL @ 140'(6 bbls). 2/26/2019 SV, SV, WV, SSV = C. MV = O. IA, OA, ODA = OTG. 17:00 T/1/0/00 = VAC/80/0/7. Temp = SI. (WIE Req). No wellhouse or flowline. Dry hole tree installed. IAP decreased 10 psi overnight. IA FL @ 140' (6 bbls). 2/27/2019 SV = C. MV=O. IA, OA, OOA = OTG. 17:00 T/1/0/00=0/100/0/0. Dry Hole conversion. RD FMC 5x7 Crown Valve, RD FMC 5x7 Upper tree. RU FMC 5x7 Crown Valve SN# 2009-06-19065. Torque to API specs. PT to 2/27/2019 350/3500psi (PASS) RDMO ***Job Complete*** SEE LOG FOR DETAILS T/I/O/00 = Vac/80/1/8. Temp = SI. T & IA FL (WIE Req). No AL, flowline, or wellhouse. Temp scaffold installed. Dryhole tree installed. T FL @ 330'(8 bbls). IA FL @ 150' (5 bbls). 2/28/2019 ISV = C. MV = O. IA, OA, ODA = OTG. 1645 hrs. Daily Report of Well Operations 02-05A T/I/O/00 = Vac/80/1/8. Temp = SI. TBG/ IA FL (WIE Req). No AL, flowline, or wellhouse. Temp scaffold installed. Dryhole tree installed. TBG FL @ 330' (8 bbls). IA FL @ 150' (5 bbls). TP, IAP, OAP, OOAP, & FL unchanged since 02/28/2019 3/2/2019 SV = C. MV = O. IA, OA, OOA = OTG. 04:30 hrs. ***WELL S/I ON ARRIVAL***(P&A) TAGGED TOC W/ 2.50" SAMPLE BAILER @ 7233' SLM.(aogcc witnessed) LRS PERFORMED x psi.(aogcc witnessed, state cri eria-passed/bp criteria -failed) 3/4/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** T/1/0/00-0/55/7/10. (LRS Unit 42 -Assist Slickline: AOGCC CMIT-TxIA) AOGCC CMIT TAA to 2424psi ***INCONCLUSIVE**** (PASS per AOGCC standards) per Mike Harris (SL WSL). AOGCC witness -Bob Noble. Pumped 12.1 bbls 60/40 methanol to reach test pressure. 1st 15 min. TBG/IA lost 29/89 psi, 2nd 15 min. TBG/IA lost 23/77 psi for ttl losses of 52 /166 psi in a 30 min. test. Log shows 45 min. test, AOGCC decision reflects 2nd and 3d segments. Bled back 6.5 bbls. AOGCC Rep left. Conducted additional CMIT-TxIA to 2500 psi for BP Criteria*****FAIL***** (Mike Harris). 1st 15 min. os psi, 2nd 15 min. segment, T/IA lost 28/87 psi and in 3d segment, T/IA lost 24/77 psi. pumped 4.5 bbls 60/40 methanol to reach test pressure. Bled back 5.8 bbls. AFE sign hung on well, caution tags hung. IA/OA/OOA-OTG. SL in control of well at LRS departure, 3/4/2019 FWHP-21/21/7/10 T/l/O/00 = 34/27/0/8. Temp = SI. TBG & IA FL's. (WIE request). No AL, flow line or well house. Dry hole tree. TBG & IA FL's @ Surface. TP increased 13 psi, IAP increased 6 psi, OAP decreased 7 psi, OOAP decreased 2 psi overnight. 3/5/2019 SV, MV = C. IA, OA, OOA = OTG. 04:05 T/1/0/00 = 0/27/0/9. Temp = SI. TBG & IA FL's. (WIE request). No AL, flow line or well house. Dry hole tree. TBG & IA FL's @ Surface. TP decreased 34 psi & OOAP decreased 1 psi overnight. 3/6/2019 SV, MV = C. IA, OA, OOA = OTG. 21:00 T/1/0/00 = Vact30/0/9. Temp = Sl. TBG & IA FL's. (WIE request). No AL, flow line or well house. Dry hole tree. TBG & IA FL's @ near surface. IAP increased 3 psi overnight. 3/7/2019 SV, MV = C. IA, OA, OOA = OTG. 16:45. T/I/O/00 = Vac/30/0/9. Temp = Sl. TBG & IA FL's. (WIE request). No AL, flow line or well house. Dry hole tree. TBG & IA FL's @ near surface. WHP's unchanged overnight. 3/8/2019 SV, MV = C. IA, OA, OOA = OTG. 13:30. T/I/O/00 = Vac/30/0/9. Temp = Sl. TBG & IA FL's. (WIE request). No AL, flow line or well house. Dry hole tree. TBG & IA FL's @ near surface. WHP's unchanged overnight. 3/9/2019 SV, MV = C. IA, OA, OOA = OTG. 07:30. T/I/O/00 = Vac/17/0/9. Temp = SI. TBG & IA FL's. (WIE Request). No change in TP, IAP decreased 13 psi, no change in OAP or OOAP. TBG & IA FL's @ Near surface. Dry hole tree. SV, MV = C. IA, OA, OOA = OTG. 21:18 3/10/2019 Daily Report of Well Operations 02-05A TWO = 30/30/Vac. Temp = SI. CMIT-TxIA **FAILED** (eval secure). No well house or flow line. Dry hole tree and temporary scaffold installed. TBG & IA FL @ near surface. Pumped 5.3 bbls diesel to increase TP/IAP from 30/30 psi to 2750/2750 psi. 3rd CMIT- TAA attempt - TP/IAP lost 75/75 psi in 1st 15 min, 72/72 psi in 2nd 15 min and 61/61 psi in 3rd 15 min for a total loss of 208 psi in 45 min. Bled TP/IAP to BT from 2500/2500 psi to 10/10 psi, returned 4.2 bbls. Monitored for 30 min. WHPs unchanged. Tags hung. Final WHPs = 10/10IVac. 3/14/2019 SV = C. MV = O. IA, OA = OTG. 16:30 T/1/0/00 = 33/15/0/9. Temp = SI. TBG & IA FL's. (WIE request). TBG & IA FL's @ Surface. No AL, flow line, well house. Dry hole tree.TP increased 23 psi, IAP increased 5 psi, no change in OAP or OOAP in 7 days. 3/17/2019 SV = C. MV = O. IA, OA, OOA = OTG. 04:35 T/1/0/00 = 18/22/0/10. Temp = SI. T & IA FL (WIE request). Dry hole tree. Temp scaffold installed. No wellhouse or flowline. T FL @ surface. IA FL @ near surface. OOA FL @ surface. TP decreased 15 psi, IAP increased 7 psi since 03/17/19. 3/23/2019 SV = C. MV = O. IA, OA, OOA = OTG. 21:40 T/1/0/00 = 10/25/0/10. Temp = Sl. TBG & IA FL (WIE request). No wellhouse, AL or flowline. Temporary scaffolding installed. TBG FL @ near surface. IA FL @ near surface. ODA FL @ surface. TP decreased 8 psi and IAP increased 3 psi since 03/23/19. 3/30/2019 SV = C. MV = O. IA, OA, OOA = OTG. 23:30 T/1/0/00 = 6/28/0/10. Temp = SI. TBG & IA FL (WIE request). No wellhouse, AL or flowline. Temp scaffold installed. TBG & IA FL @ near surface. 4/6/2019 SV = C. MV = O. IA, OA, OOA = OTG. 20:20 T/1/0/00 = 1/30/0/11. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Dry hole tree installed. TP decreased 5 psi, IAP increased 2 psi, ODA increased 1 psi since 4/15/2019 4/6/19. T/1/0/00 = 0/27/0/9. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Dry hole tree installed. TP decreased 1 psi, IAP decreased 3 psi, OOA decreased 2 psi from 4/23/2019 4/15/19. T/1/0/00 = 1/32/0/8. Temp = SI. WHPs (WIE Req). No wellhouse or flowline. Dry hole tree installed. TP increased 1 psi, IAP increased 5 psi, OOA decreased 1 psi from 5/1/2019 4/23/19. T/1/0/00 = 1/32/0/9. Temp = SI. Monitor. (WIE request). No well house or flow line. Dry Hole tree installed. No change in TP, IAP or OAP, OOAP increased 1 psi in 8 days (Since 5-1-19). 5/9/2019 SV = C. MV = O. IA, OA, OOA = OTG. 14:50 T/1/0/00 = 0/32/0/11. Temp = SI. WHPs (WIE Req). No flow line, well house or scaffold. Dry hole tree and temporary scaffold installed. TP decreased 1 psi, IAP & OAP unchanged and OOAP increased 2 psi since 05/09/19. 5/17/2019 SV = C. MV = 0. IA, OA, OOA = OTG. 02:15 WELLHEAD= McBtOY ACTUATOR— RB.tOVD KB. EEV = 64' I INTERVAL 37.16' KOP= 3159' Max Angle: 700° 12644' Datum MD= 11266' DatumTVD= 8800'SS 30'CONWCTOR, -119 —r 9-58' CSG, 47#, -120 50095 BTPS, / ID = 8.681' 20' CSG, 133#, 293' K-55, ID - 18.750' Iit, H40 , D = 19.124' 1204' 5 XO N-80 BTRS, D = 8.861' 1916' SG, 72#, N-80 BTRS, ID = 12.3477- 2697' SG, 40#,S0095 BTPS, ID = 8.835' 6647' CSG, 47#, N-80 BTRS, ID = 8.681' 7854' TBG PUNCH, 4 SPF (01/29/19) 10076'-10081' Minimum ID = 2.313" @ 10138' 2-7/8" X NIPPLE PROFILE IN PTSA X MP IN PATCH ASSY. ID = 2.313- (03/20/171 1—F InIg KB LONER STRDL PCR. ID PE FORATDN SUMMRY REF LOG: MWD BNR-GR ON 05/17/03 TO 05/31/03 ANGLE AT TOP PERF: 82 @ 12220' Note: Refer to Production DB for historical perf data SIZE SP= I INTERVAL I Opn/Sqz SHOT SITZ 2' 6 12220- 12310 O 06/02/03 5-12' WFT ER UPPER STRDL PKR w /PISA, 2' 6 12340 -12380 O 06/02/03 2" 6 12470- 12500 O 06/02/03 2' 6 12600 -12670 O 06/02/03 2' 4 12690 - 12900 O 06/0283 2' 4 12950- 13190 O 06/02/03 2' 4 13290 - 13380 O 06/02/03 50095 BTRS, ID = 02-05A SAFETY NOTES: REDUCED COLLAPSE RATING ON 9-5/8'. 20' CLAMPED TO 30' DUE TO WELLHEAD NM SOVE.IENTT 1993. N73L ANGLE> -70" 0 113331. I I 5-12' RKR PFVE SSSV NIP ID=4562' 7233' SLM_� - _ X NP IN PISA, ID = 2.313- (0320/17) TAG TOC STATE WITNESS SL (03/04/19) 2-7/8' XX RUG (03/2011 TO 10196' TXM TOC -7941'(02/25119) 10091' 5-12' HES EZ DRILL OBE (0128/19) -10117' RSH: NEST EMERG DISCONLTNVIAK 03/18/19 MN/JMD SL TAGGED TOCw/STATEWITNESS (314 FAILEDTO RELEASE FROM 5-12' ER PKR \ / (1-3/4" EXTERNAL RSH NECK) (03/22/17) 10119' 5-12' WFT ER UPPER STRDL PKR w /PISA, 0181/19 BTNVJMD SET CBP&TBG PINCHES ID = 2.313' (03/20/17) 10133' 5-1/2'BKR SLIDING SLV, ID=4.31' BEHIND PATCH 10�-12-718- X NP IN PISA, ID = 2.313- (0320/17) 10138' 2-7/8' XX RUG (03/2011 TO 10196' 5-w12' BKR R NIP, ID= 4.31' 10700' CEEMENT TOP (ESTIMATED) /NOGG ID =4 223' BEHIND PATCH B TOP OF CEMF NT RAMP 10202' 5-12'BKR SBR ASSY (PDS Calper Log 04/14/09) BEHIND PATCH 10263' 9-58' X 5-12' BKR SAB PICR 10264' 5-12' X 4-12' XO, D = 3.958' 1n1� 3-3/4'RKRD PLOY SLV. ID=30' t 10346' -j3-12" X 3-3116- XO, D = 2.880' 10392' 4-12"IALED, D=3.958- .958'(BE DATE REV BY COMMENTS (BEHIND IND CT LNR) 10700' CEEMENT TOP (ESTIMATED) 10912' TOP OF CEMF NT RAMP 03/18/19 MN/JMD SL TAGGED TOCw/STATEWITNESS (314 0 RSH: EXTRUSION RING f \ / EXEMBNT FROM WFT ER 3-3/16' LHR, 62#, L-80, .0057 hof. D = 2.805' 3-3/16' X 2-7/8' XO, D = 2.372' 13394' H PBTD I PRUDHOE BAY UNIT W13L 02-05A PERMIT No '2030820 APNo: 50-029-20081-01 SED 36, T11 N. R14F, 3636' FE & 4301' FNL DATE REV BY COMMENTS DATE REV BY COMMENTS 122270 ORIGINAL COMPLETION 03/18/19 UIJJMD Tx IA TOC (0225/19) 0126fT7 LAST WORKOVER 03/18/19 KPJMD DRY HOLE TREE (02/27/19) 0693A3 DAVMK CTD SIDETRACK (02-05A) 03/18/19 MN/JMD SL TAGGED TOCw/STATEWITNESS (314 0380/17 E'DUMD CLEANED LP JEWRY BEOND 0523/19 JMJJMD UPDATED BF B -EV 04/13/17 EPD/JMD MINOR EDITS TO SBR BP Exploration(Alaaka) 0181/19 BTNVJMD SET CBP&TBG PINCHES MEMORANDUM TO: Jim Regg "�j 31Uf l `l P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Bob Noble Petroleum Inspector Section: 36 Township: 11N Drilling Rig: NA Rig Elevation: NA Operator Rep: Michael Harris Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" O.D. Shoe@ Production: 9 5/8" O.D. Shoe@ Liner: 3 1/2" x 2 7/8" O.D. Shoe@ Tubing: 5 1/2" x 4 1/2" O.D. Tail@ Plugging Data: Test Data: DATE: March 4, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 02-05A BPXA PTD 2030820; Sundry 319-005 Range: 14E Meridian: Umiat Total Depth: 13409 ft MD - Lease No.: ADL 028038 111 Feet 1205 Feet 2697 Feet 11180 Feet 13409 _ Feet 10392 Feet Suspend: P&A: X - Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Tvoe Plua Founded on Depth Btm Depth To MW Above Verified Fullbore Bridge plug 10091 ft MD'I 7233 ft MD' Wireline tag 2424 P OA 10 10 9 9 Initial 1S min sn min d5 min Romdr Tubing 1 2690 1 2649 2620 2597 IA 2697 2590 2501 2424 P OA 10 10 9 9 Remarks: I traveled to PBU 02-05A to witness a tag and test on a cement plug. On arrival I met with BP rep. Michael Harris and we went over the tag and test procedure. Michael told me that the cement had been pumped on 2/25/19, set on a bridge plug. Tubing was punched from 10076 ft to 10081 ft (MD) for the plug. Schlumberger slick line was rigged up and run into the well to tag top of cement. The bailer can back full of very firm cement. Hot Oil's pump truck was then rigged up to the tubing with a jumper line to the IA to perform a combo MIT TAX Attachments: none rev. 11-28-18 2019-0304_Plug_Verification_PBU_02-05A_bn.docx THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Katherine O'Connor Integrity and Interventions Engineer BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 02-05A Permit to Drill Number: 203-082 Sundry Number: 319-005 Dear Ms. O'Connor: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.olasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Z Daniel T. Seamount, Jr. Commissioner DATED this'L Bay of January, 2019. RBDMSe JAN 3 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JAN 0 8 2019 1. Type of Request. Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ A 8 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved rogram Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0• 5. Permit to Drill Number. 203-082 3. Address: P.O. Box 196612 Anchorage, AK 6. qpl Number: 50-029-20081-0i-00 ' 99519-6612 St2tigrephic ❑ Service ❑ 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 02-06A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028308'& 028309• PRUDHOE BAY. PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVDffb Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13409 8959 10138 8170 10138 10117, Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 31 - 111 31 - 111 880 Surface 1174 20" 31-1205 31-1204 1530/2320 520/1500 Intermediate 2668 13-3/8" 29-2697 29-2695 4930 1 2670 Intermediate 11153 9-5/8" 27-11180 27-8821 8150 / 6870 / 6820 5080 / 4760 13330 Liner 3113 3 -112"x3 -3/16"x2-7/8" 10296-13409 8268 - 8959 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12220 - 13380 8988 - 8958 5-1/2" 17# x 4-1/2" 12.6# N-80 24-10392 Packers and SSSV Type: 5-12" Baker SAB Packer Packers and SSSV MD (ft) and TVD (ft): 10253/8241 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ _—] 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative. GINJ ❑ Op Shutdown ❑ Abandoned 0 ' 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: O'connor, Katherine be deviated from without prior written approval. Contact Email: Katherine.O'connorLtilbp.com Authorized Name: O'connor, Kamenne Contact Phone'. +1 9075644640 Authorized Title: Integrity & Interventions Engineer Authorized Signature: rte/ Date: 11 Yj 2alq COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: in Plug Integrity 111BOP Test ❑ Mechanical Integrity Testt°� Location Clearance Other: fl o&u-_T-o W I TNs s'5c-Ii C T X'xAr { F Mite oais c�escn be� J Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ o Subsequent Form Required: 16-'-1407 APPROVEDB Approved COMMISSIONER COMMISSION Date. by: ORIGINAL RBDMS'�'�SmAN 3 11019 Submit Form and Attachments in Duplicate jy(.¢./PWI? Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. by 0 02-05 Abandon Well -10 403 Rev 1 Intervention Engineer Katherine O'Connor (214) 684-7400 Expected Start Date: February 20, 2018 Well: 02-05A History GPB Well 02-05A was initially drilled and completed in December 1970. The initial completion was in Zone I and the well was sidetracked in June 2003. Until 2009, the well was operable and produced with very little off time until 2009 when a tubing leak was discovered. There were many attempts to set patches, but none of them brought the well back to operable. In 2017 was the final attempt to set a patch. During the patch setting operation, the tool did not release from the patch and the fish was left in hole. Simultaneously, the well was determined to be not operable due to its similar well design to 02-03 (Gen 1 well head, 3 casing string design and casing shoe set in the permafrost). This well has been not operable with a plug downhole since this time, and we are now proceeding with the full abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Place a lower lateral cement plug above the patch at 10,119' MD. Place a lateral surface cement plug in the well. History • Made not operable in 2009 due to TxIA leaks • Long history of setting patches & failing pressure tests (history attached in appendix). • 2010 LDL showed leaks at sliding sleeve (10,133' MD) and 10,189 MD and a caliper in 2009 showed a hole at 10,179' MD. • The well remained shut in after -2010's attempt to set a patch • In 2017 SL attempted to set a long patch, but in the final piece, the setting tool did not release. Fishing operation was unsuccessful and the well has been shut in since. • CMIT-TxIA to 2603 psi in March 2017 • TxIA communication noted in FB AWGRS 3/21/17 - IA tracked tubing • Attempted a lube and bleed well kill on 1/1/2019 and determined that the plugs in the well are not holding and leak fluid/gas. A flow test yielded -1 cup of fluid returns in 20 minutes. The well is gradually swapping over back to gas. • Fluid packed well and performed injectivity test on 1/21/19, well has injectivity of -2-2.5 bpm at 2700 psi. DHD - Cement control and balance lines 1. Cement control line and balance line. EL/SL/Relay - Set plug, punch 1. Set cast iron bridge plug above the fish at about 10,100' MD. r2.n GR log and caliper from 2000' MD to surface for subsidence monitoring/anal sis. �N. rr `r�x=f� `;'� Z zoo Psi. z 14, r� > � 3O /h "f-- i 2TE4 -7-21�, 3. Tag plug, pull up & punch —10 ft above the plug. 4. Confirm circulation in AWGRS Fullbore — Circulate tbg & cement IA Well: 02-05A 1. Circulate tbg and IA to 9.8 brine, leading with a surfactant wash. 2. Pump 640 bbls of cement down the tubing up the IA, MD. Note: this is 20 bbls of excess cement. 3. Chase cement with diesel leaving TOC in the tubing at —2100' MD. 4. TOC in tubing should be 2100' MD and IA cemented to surface. Cement Calculations — Lower Cement Plug Total cement to pump 640 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the Fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 1 Safety Minimum required thickening time: 6 Cement Ramp for Blend Time Volume Pumped 'Temperature Pressure Well: 02-05A Eline & Fullbore or DHD — Tag TOC, Pressure Test, Perforate for V stage of surface plug 2. Drift and tag TOC with sample bailer. ho!`� T m 7oG 3. CMIT-TxIA to 2,500 psi. 4. Inflow test on tubing 5. Perforate through tubing and 9-5/8" casing at 1769' MD (tbg joint). (subject to change based on tag depth). 6. Confirm circulation and note in AWGRS. Valve Shop 7. Drop 13-3/8" OA gate valve and install integral valve. Fullbore — Circ Hydrocarbons from well 8. Circulate hydrocarbons (ArcticPack) out of well Fullbore — Placing cement plug 9. Rig up to take returns from the OA. 10. Pump roughly 140 bbls of cement down the tubing taking returns from the OA until clean returns are seen at surface. Chase cement with brine to leave TOC in tubing @—630'MD. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 1140 bbls Cement Type / Weight (bbls) (°F) (psi) 0:00 0 100 0 0:30 0 120 0 1:00 400 120 5000 2:00 500 100 5000 3:00 533 80 5000 4:00 533 70 5000 5:00 533 60 1000 6:00 533 60 1000 Eline & Fullbore or DHD — Tag TOC, Pressure Test, Perforate for V stage of surface plug 2. Drift and tag TOC with sample bailer. ho!`� T m 7oG 3. CMIT-TxIA to 2,500 psi. 4. Inflow test on tubing 5. Perforate through tubing and 9-5/8" casing at 1769' MD (tbg joint). (subject to change based on tag depth). 6. Confirm circulation and note in AWGRS. Valve Shop 7. Drop 13-3/8" OA gate valve and install integral valve. Fullbore — Circ Hydrocarbons from well 8. Circulate hydrocarbons (ArcticPack) out of well Fullbore — Placing cement plug 9. Rig up to take returns from the OA. 10. Pump roughly 140 bbls of cement down the tubing taking returns from the OA until clean returns are seen at surface. Chase cement with brine to leave TOC in tubing @—630'MD. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 1140 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 firs Thickening Time I Minimum 6 hours Cement thickening time: Mix on the fly Well: 02-05A Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement i Cement contamination 70 Safety 2:00 Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 1500 2:00 60 1000 3:00 50 500 4:00 40 0 7:00 40 0 15:00 30 0 Eline & Fullbore — Tag TOC, Pressure Test, Perforate for 2nd State Surface Cement Plug 11. Tag TOC and note in AWGRS. 12. Perforate through tubing, 9-5/8" casing and 13-3/8" casing at —500 MD (subject to change based on tag depth). 13. Confirm circulation and note in AWGRS. Fullbore — Circ Hydrocarbons from well (20"x13-3/8" annulus) 14. Circulate hydrocarbons (ArcticPack) out of well Fullbore — Placing 2"" stage surface cement plug 15. Rig up to take returns from the OOA. 16. Pump roughly 140 bbls of cement down the tubing taking returns from the OOA. Do this until clean returns are seen at surface. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 140 bbls Well: 02-05A Cement Type /Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickenin time: Mix on the fl 12 Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 70 Safety 2:00 Minimum required thickening time: 6 Cement Ramn for Blend Time Tem Pressure 0:00 90 0 1:00 70 500 2:00 60 0 :00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Special Projects — Final Excavation 17. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 18. Photo document all steps. 19. Cut off all casings and wellhead 3' below tundra. 20. Top off tubing and annuli with cement if needed. 21. Weld marker cap on outermost casing string. The marker plate will have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 2030820 c. Well Name — 02-05A d. API # — 50-029-20081-01 Well: 02-05A Well: 02-05A by -0 2 ALILK10 Lateral surface cement KS ELLv plug in TBG, IA, O.A and BIT. n-Ev OCA Kop_ ;. s:n'v:�a,, us. ffiN�•n 1n;c. a -Hent I- ..7$p.._,) 26° , laa Cement IA & U - m. caa. i OA to surface 1 i LC csn,4/a.80DB N00 a1A3,0-8161•- TOC est 2170' MD ' 6_51-1 � TOC est 2945' MD a nel•�I—(-71 TOC est 6961' MD ta13l, 12-78- X NIPPLE PROFILE IN PTSA I) -/R'% AFM 1CN waaY. C1.131T xmga l of C IL{�®" fDf JDD f 19 SA° can. 416 10003 alRw D - a dal° I-+, Well: 02-05A Tc� -6 so ` � an�TrwoTEs� PFDLCi7COLLAP.�PA/H30ta 9.518°. 20" EXAWW 10 30" ULE to YM.UMU rkMtMNT 1981 VWU ANGLE > -IW O 113XY TOC est. 660' MD TOC est. _1830' MD -1a1�,1�� teral ANGLEATTOPFUV:132 Q 127111' Nob. R f. b R6dudw M to, h k..d PrY dd. WE SA' KrEWAL Oonr= SI -VT SO2 Y 6 L= - 12310 O 0 w_m 7 6 12W - 12360 O o6vzw 7 6 17AN -12500 O DIUMM Y 6 12600 - 12670 O 0600/031 4 12660 12900 O oomm, T 4 12650 131W O ofim 3'i T 0 13260 133M O 06=ffl, 19 SA° can. 416 10003 alRw D - a dal° I-+, Well: 02-05A Tc� -6 so ` � an�TrwoTEs� PFDLCi7COLLAP.�PA/H30ta 9.518°. 20" EXAWW 10 30" ULE to YM.UMU rkMtMNT 1981 VWU ANGLE > -IW O 113XY TOC est. 660' MD TOC est. _1830' MD -1a1�,1�� teral CT K =4 intermediate plug isArlmP rrr,} - - est TOC 2100' MD [XII ro3rzv11) — - ------. 101 O11Y jj — ry FMR.,p11A, {C ° 7 3U' 10b20'I I) - 1013' - X119"%Fl1N PISA, Ds21tY (ObJbla : Tolls, 1"{3116"%Y RLY-.10]/1N111' 10195'T 1 �7,FF aKRRN>C=:3!=:3! -� -w AVOCA) D -4 223' aR6MO PATCH i 10207 S1.7 &(RiaR wS_tY .... - (PCO Cape, LWOYUW)aBiIOPATCR ; 1021{S - 9-5A1° %S V)' RwR SAa NCR 1. - l low 102N' l-'+SN°61(R LUV-YLV.D�3.D" tour' .•-In°wcanNv,C-salt"; ltmatloer LlaO M � Lt.4311-IOP(LSI6Mi2i4 T(IPOF QAFiR PAM' RFA~FR VA1FR Smoak FMN OW1605F 2780%0, �D•2312' OOS7 bpl. D=2.aW' (i -TV &ft -6 fOF, L -011U. 00.^8601, D-2441" 13809' SW 36. MOA►A,!MY WI 3'wA I 02 OFA ARM 5O M 20061 OI aP B*orolm WNW 8 02-05 Abandon Well Intervention Engineer Katherine O'Connor (214) 684-7400 Expected Start Date: February 15, 2018 Well: 02-05A History GPB Well 02-05A was initially drilled and com eted in December 1970. The initial completion was in Zone IA and the well was sidetracked in June 003. Until 2009, the well was operable and produced with very little off time until 2009 when a tubin eak was discovered. There were many attempts to set patches, but none of them brought the we back to operable. In 2017 was the final attempt to set a patch. During the patch setting operation, the of did not release from the patch and the fish was left in hole. Simultaneously, the well was determ' ed to be not operable due to its similar well design to 02-03 (Gen 1 well head, 3 casing string design a d casing shoe set in the permafrost). This well has been not operable with a plug downhole since this 'me, and we are now proceeding with the full abandonment. Objective Remove hydrocarbons fro all well annuli and tubing. Place a lower lateral cement plug above the patch at 10,119' MD. Place a lateral surface cement plug in the well. History • Made not operable in 2009 due to TxIA leaks • Long history of setting patches & failing pressure tests (history attached in appendix). • 2010 LDL showed leaks at sliding sleeve (10,133' MD) and 10,189 MD and a caliper in 2009 showed a hole at 10,179' MD. • The well remained shut in after 2010's attempt to set a patch • In 2017 SL attempted to set a long patch, but in the final piece, the setting tool did not release. Fishing operation was unsuccessful and the well has been shut in since. • CMIT-TxIA to 2603 psi in March 2017 • TxIA communication noted in FB AWGRS 3/21/17 — IA tracked tubing • Attempted a lube and bleed well kill on 1/1/2019 and determined that the plugs in the well are not holding and leak fluid/gas. A flow test yielded —1 cup of fluid returns in 20 minutes. The well is gradually swapping over back to gas. Fluid level in the tubing as of this time (1/7/2019) is 1450' MD and —600 psi. Fullbore — Attempt to abandon reservior 1. Fluid pack well to kill it with 9.8 brine 167 2. Pump 25 bbls of cement to attempt a res. abandonment. • If well locks up when the cement reaches the plug @ 10,138' MD and leave the cement where it is. Worst case TOC is —9040' MD.'S e�\ ao3� Slickline/Fullbore — Tag & PT 3. Wait on cement 3 days 4. CMIT-TxIA to 1500 psi, AOGCC witness. Well: 02-05A 5. Notify AOGCC inspector of the timing of the cement plug tag and pressure test (24 hr minimum notice). DRD — Cement control and balance lines 6. Cement control line and balance line. E -Line — Punch tubing for intermediate plug 7. Punch tubing —8800' MD (subject to change based on tag depth/) 8. Confirm TxIA circulation and note in AWGRS. Fullbore — Cement intermediate plug 9. Circulate tubing and IA with surfactant wash to 9.8 taking returns from the IA. 10. Once clean brine is consistently returned at surface. This should put TOC in tbg and IA —2100' MD. Cement Calculations — Lower Cement pumping down the tubing and — 450 bbls for a balanced cement plug. I Total cement twbumo 1 450 bbls I Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickenin¢ time: Mix on the Flv Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination Safety 2 Minimum required thickening time: 6 Cement Ramp for Blend Time I Volume Pressure 2 ti Well: 02-05A Eline & Fullbore — Tag TOC, Pressure Test, Perforate for V stage of surface plug 11. Drift and tag TOC with sample bailer. 12. CMIT-TxIA to 2,500 psi. 13. Inflow test on tubing 14. Perforate through tubing and 9-5/8" casing at 1769' MD (tbgjoi tag depth). 15. Confirm circulation and note in AWGRS. Valve Shop 16. Drop 13-3/8" OA gate valve and install integral Fullbore — Circ Hydrocarbons from well 17. Circulate hydrocarbons (ArcticPack) out of well Fullbore — Placing cement plug 18. Rig up to take returns from the OA. (subject to change based on 19. Pump roughly 252 bbls of cement down the tubing taking returns from the OA until clean returns are seen at surface, then the IA until clean returns are seen at surface. Chase cement with brine to leave TOC in tubing @—600'MD. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 1252 bbls Cement Type / Weight (bbls) (°F) (psi) 0:00 0 100 0 0:30 0 120 0 1:00 400 120 5000 2:00 500 100 5000 3:00 533 80 5000 4:00 1 533 70 5000 5:00 1 533 60 1000 6:00 1 533 1 60 1000 Eline & Fullbore — Tag TOC, Pressure Test, Perforate for V stage of surface plug 11. Drift and tag TOC with sample bailer. 12. CMIT-TxIA to 2,500 psi. 13. Inflow test on tubing 14. Perforate through tubing and 9-5/8" casing at 1769' MD (tbgjoi tag depth). 15. Confirm circulation and note in AWGRS. Valve Shop 16. Drop 13-3/8" OA gate valve and install integral Fullbore — Circ Hydrocarbons from well 17. Circulate hydrocarbons (ArcticPack) out of well Fullbore — Placing cement plug 18. Rig up to take returns from the OA. (subject to change based on 19. Pump roughly 252 bbls of cement down the tubing taking returns from the OA until clean returns are seen at surface, then the IA until clean returns are seen at surface. Chase cement with brine to leave TOC in tubing @—600'MD. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 1252 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours 3 by 000,0 Cement thickeninv time: Mix on the flv Well: 02-05A Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Ramn for Blend Time Ternp Pressure 0:00 90 0 1:00 70 1500 2:00 60 1000 3:00 50 500 4:00 40 1 0 7:00 1 40 1 0 15:00 1 30 1 0 Eline & Fullbore — Tag TOC, Pressure Test, Perforate for 2" 20. Tag TOC and note in AWGRS. Surface Cement Plug 21. Perforate through tubing, 9-5/8" casing and 13/9alus)ing at —500 MD (subject to change based on tag depth). 22. Confirm circulation and note in AWGRS. Fullbore — Circ Hydrocarbons from well (20"x13- 23. Circulate hydrocarbons (ArcticPack) out of well Fullbore — Placing 2" stage surface cement plug 24. Rig up to take returns from the OOA. 25. Pump roughly 150 bbls of cement down the tubing taking returns from the OOA. Do this until clean returns are seen at surface. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 150 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 1 80° to 110° F 4 Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the flv Well: 02-05A Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 500 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Special Projects — Final Excavation 26. Notify AOGCC Inspector of wellhead 27. Photo document all steps. 28. Cut off all casings and wellhead 3' below, minimum notice) 29. Top off tubing and annuli with cement ' needed. 30. Weld marker cap on outermost casin tring. The marker plate will have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 2030820 c. Well Name — 02-05A d. API # — 50-029-20081-01 5 13-12^ LNR 8.81#, L-80, .0081 bpf, D = 2.880' �- 4-12' TBG_ 12.6#. "O..0152 hof. D = 3.958• PERFORATION SMAWRY TTS=FMC02-05A Wfl.LFFAD= LbEVOY _—..------ -- ACTUATOR= BAKERC KB. ELEV = - (A, > BF. 9F/ _ -_- 35.5• 30000NDUCTOR -119 ANGLE AT TOP PEW: 82 Q 12220 Note: Refer to Production DB for historical pert data SIZE SPFJ SAFETY NOTES: REOl1C®COLLAPSE RATING ON 9-5/8". 2(r aALFED TO 30• DUE TO WELLHEAD MDVEMBdf 1993. WELL ANGLE> -70" @ 11333'. Opnl34t SHOT > 7 KOP= 3157 # Max Angk: = 100" Q 12644' D = Oah1m MD= 11266' 12220 - 12310 O 06/02/03 2207' 812' BKR PFV E SSSV NP, D = 4.562" Q 6 12340 - 12380 O DatumTVD= 8800 SS 9-5/8^ CSG, 47#, S0095 BTRS, D = 8.681" -•120 T 6 2406' & 6964' 9-5/6^ BKR STAGE COLLAR 20" CSG, 133#, K-55,10 =18.750• 293' 06/02/03 T 6 20" CSG, 94#, K40 , D = 19.124" 1204' O 06/02/03 2' 9-5/6" CSG, 47#,SO095 XO N-80 BTRS, D = B. • 1916' 12690 - 12900 O 06/02103 '10117 FISH: NEST E MERG DLSCONCTMLAK 7 4 12950 - 13190 O FAILED TO RELEASE FROM 5-1/2' ER PKR 13-3/8' CSG, 72#, "0 BTRS, U=- 12.347' 269T T 4 13290 - 13380 (1-3/4' IXTEiNAL FISH NECK) (03122/17) 9-5/8" CSG, 40#,S0095 BTRS, D = 8.835" 6647' 10119' 5-1/2• WFT ER UPPER STRDL PKR w /PISA, 9-5/8' CSG, 47#, N-80 BTRS, D = 8.681" 7854' D = 2.313' (03/20/17) I I 10133' 5-12"BKRSL1DNGSLV,D=4.31^ BEHINDPATCH Minimum ID =2.313" @ 10138' 2-7/8" X NIPPLE PROFILE IN PTSA 10138' 2-7/6'XNPgJPfBA.D=2.313"(0320/17) 2-7/8^ X NP N PATCH ASSY, D = 2.313' (0320/17) 10190' 10136' 10196' 2-7/8" XX RAX'' (0320/17) 5-1/2' BKR R NP, D = 4.31' w /NOGG D =4.223' BEHIND PATCH 45 KB LOWERSTRDL PKR D = 2.37' (0320/17) 10212• 10202' 5-1/2" BKR SBR ASSY (PDS Caliper Log 04/14109) BEHIND PATCH S 12^ TBG, 17#, f4.80, .0232 bpf, D = 4.892' 10263•10253' 9-5/8• X 5-7/2" BKR SAB RCR 10284' 812• -X,!,,1/7 XO, D= 3.958• ■ 10296' 3-3/4' BKR DELOY SLV, D = 3.0' 13-12^ LNR 8.81#, L-80, .0081 bpf, D = 2.880' �- 4-12' TBG_ 12.6#. "O..0152 hof. D = 3.958• PERFORATION SMAWRY REF LOG: LVAD EAR --GR ON 05/17103 TO 05/31/03 ANGLE AT TOP PEW: 82 Q 12220 Note: Refer to Production DB for historical pert data SIZE SPFJ KIERVAL Opnl34t SHOT SOZ 7 6 12220 - 12310 O 06/02/03 7 6 12340 - 12380 O 06/02/03 T 6 12470- 12500 O 06/02/03 T 6 12600- 12670 O 06/02/03 2' 4 12690 - 12900 O 06/02103 7 4 12950 - 13190 O 06102/03 T 4 13290 - 13380 O 06102103 9-5/8" CSG, 47#, 50095 BTRS, 0 - 8.681" 10327' 4-12' BKR R NP, D = 3.812 - (BEHIND CT LNR) 10345' 3-12^ X 3-3/16' XO, D = 2.880^ 10392' 4-112^ WLEG, D = 3.958^ IBEBND CT LNR) 10917 F 3-3/16" LPR, 6.2#, L-80, .0057 bpf, D=2.805• L-80, DATE REV BY COMAENTS GA70DAV 12!22!10 ORIGINAL COM PLEnON 03/3E I D PATCH012687 LAST WORIMER 04/1 06103103 DAVIM CTDSIDETRACK(02-05A) MUP"AIRV 03/17/16 SW/,MD CORRECTED MAX ANGLE 07119/16 ZV/JLD SET EVOTRIEVEFLUGw IFISH<�C 03!30/17 EFD'JMJ SET PATCH w /PISA/W & FLUG - PU FISFL EXTRUSION RING nPARTAL FTB-BVB4T FROM WESTRADDLE PKR (09/161 11236' 3-3/16^ X 2-7/8' XO, D = 2.372• 1 13384' 1—j P13TU Dose bpf. D = 2.44 r 13409' PRUDHOE BAY UNIT WELL 02 -OSA FERIJT No: `2030820 AFI 10,1: 5D-029-20081-01 SFC 36, TIM RI4F- 363V FEL & 4301' FN - BP Exploration (Alaska) by 2 S+. Well: 02-05A JJEAO- 1R£Fw 02-05A S�APEw MOWS: FBDI=COLLA15E11A1lC ON Ni = 9L W 20• W. CLAYlll 107rt 'lrowiL]EAO IJA I _OR�, HANBiC ----- I KNEI M 1691 Kte LAW. -i0• Q 11333. 30•WdJC(OIz --ttf [z•.ir�rs><1r>Esin4.u.-�+an,ir�u�cf�a �I�Ii�y��'4i�i��ii�l� rilm LHRBte4. L-aO. ABOa Dpl,O.2 N1' 1340t' 04m , RLV BY cokaff 6 bra rE Fw/ BY -{ 1032T ,-N2•e1fNNN•.D-S BIZ' TOC est. 1019' MD .70'17 fad (®aDCi LWs-t^'IHd_ .— .. ...__.- _J 70340' 11.7X lYla XO,D=2460• Seto_ I. -ho. 0m%tv+,D=2a60• 1034V TOC est. 1830' MD resG.4n. 30086 OINi.D=ae4r X120 _ -�- -- �_- 10307 4.I/T LKF)i Q=)47Y _.__ DPZ 3 - 10,503' MD �� I20,®c. 7334. Kgo. D*11.)40' -'r6;- n uwsFew2�rt�rr�r o tonins —..-_ M1.4N'MINaTACf f%kIARI ^10117" JFI�BNEW C6CO14CTMLAK FAt B1TO 1HEA4E FfiP115.1fY B2 MR AKA.LATTOP(ETS.B2{117121710013' C6(' 474,60081 %ONM 11R5•D-4161' 1 _-{TOPOF Q]RIFMM'_' I]J.0•[ 724, N BOBTRS.D-1 7- T 7 FF4l F%Tt6"F*4 PAPTWI BF7FM f:K111wFT AR S7TfA170.EFlOt(0~5j (i 34' IX1B4r/LL FBR 1'E7.3!} (07717//j ` 1nt9'�}-sirr In4-1 eie uprfR STRr2 MR NOMA. •e - TOC est 2255' MD _ -eee+•�j�eea• _ TOC est 29-45' MD 9tlT :AZ ----- D•2alrronalTl TOC est 6961' MD 0 asmom /0133 - 114•5RASIMK'sLY, 6=4ar 0138' 12)40 - 12]80 0 eD4N04ATCN 2-718' % NIPPLE PROFILE IN PTSA �____.._. _ _ _. 2. 16'k0,` l-+)D-7=rt24.'3%Tr0 - ---- -- 10113" �--2.rAt•xewHlaSA.wx)ir tevaarr7 1013! �-�1� INM-12500 }-' 'kff'N PAiW ASBY.O:}s�S �odrlOr%!r 10100" O&WAP3 v--3,----- tot9r s1.z61LNRw.o=,)+• 1127T I w • 8E4b p►TCN --{10212' -.10247 j1 ZbT BKRS ASSY l - 4 %2eW 12NO 0 tP06Ib8per Lap OY/i711B91110►ATCN � [z•.ir�rs><1r>Esin4.u.-�+an,ir�u�cf�a �I�Ii�y��'4i�i��ii�l� rilm LHRBte4. L-aO. ABOa Dpl,O.2 N1' 1340t' 04m , RLV BY cokaff 6 bra rE Fw/ BY -{ 1032T ,-N2•e1fNNN•.D-S BIZ' 12aVM! ON0IYLLCONPLF'IOM .70'17 fad (®aDCi LWs-t^'IHd_ .— .. ...__.- _J 70340' 11.7X lYla XO,D=2460• Seto_ I. -ho. 0m%tv+,D=2a60• 1034V _..._�__.>,e V 1 r 1 ti 1l FP Nw 01ST Dol L> ]BSIF 193A2' - eflYdFflf$ro9g2 _ -�- -- �_- 10307 4.I/T LKF)i Q=)47Y _.__ DPZ 3 - 10,503' MD �� 1e11wBC1 1.14rry -'r6;- n uwsFew2�rt�rr�r o tonins t0? � Ne iov esl irrn ' AKA.LATTOP(ETS.B2{117121710013' _-{TOPOF Q]RIFMM'_' Nov. N+f., b nwW , nTS hr lv,6Dle tpxf did 7 FF4l F%Tt6"F*4 PAPTWI BF7FM f:K111wFT AR S7TfA170.EFlOt(0~5j SeE. SM 14TEFWAL QrN50c 9tlT :AZ r-6 17187 )2310 0 asmom 7 . 6 12)40 - 12]80 0 OWWA3 _ _ _. 2. 16'k0,` l-+)D-7=rt24.'3%Tr0 B INM-12500 O O&WAP3 1127T I AiZ ..--•� 4 %2eW 12NO 0 0owm r 4 12000 12100 0 0102A1 L 4 13 13380 0 0KWA3j [z•.ir�rs><1r>Esin4.u.-�+an,ir�u�cf�a �I�Ii�y��'4i�i��ii�l� rilm LHRBte4. L-aO. ABOa Dpl,O.2 N1' 1340t' 04m , RLV BY cokaff 6 bra rE Fw/ BY tl1NiF.111] — 12aVM! ON0IYLLCONPLF'IOM .70'17 fad CLFANW Lpier&L080" FAICH nrnrFr' usT r)alloov� 13Hr Fab eflYdFflf$ro9g2 44W2103 BAYlgt CTD3DEI1MLK1�•nA YvnBisw�ocawFtTwl4AxANrat -------- -- -- 47/19118� 7VU1D 6Pf kV O11E)/ER UGr rt91N[�L OYlUv17FPIY,W SET MITN r fP'ISIH/F6 PLUG • RA.l0.UG -----_ ___---- R4AJAXdAf WI V*:LL. 02 01A ftwv to, 100.[1120 ARNO 5DW92OWIVI SFC 3e, R 1N R14E 3631• RL 4 4]01' ML ® OpINOWSn (Alq1,01 7 i l;, Lateral surface cement (LEV plug inTBG, IA, OAand COA Cement IA & OA to surface TOC est 2170' MD TOC est 2945' MD TOC est 6961' MD LP^ Well: 02-05A SMMMOM: FfDU=CCLLAPWMNC0N 0 05A -,S 12"6"ESM NP -0 -4W -A TOC est. 660' MD TOC est- 1830' MD >'. 240V & 9W- WV MMqVACCr CAI CAN Lateral CTro K intermediate plug W.' FR FAAR est TOC 21W MD r1 (IVni) 10187 1t kbcd"Irma, 12340-173W 0 IN FATS —WM� OWS= SHOT ' SM Y 6 12720 12310 0 OMM 71 6 12340-173W 0 *,ft)GO 0-4MY aEHMO CN T 6 124M -12300 _n Mir 5KR -�ASSY TOTi Qplpv Lw Wlaa9) al34RO P ATCH 065 6 IM - IM70 ;_10265...Fww X-.v7;j;S A7FkR DOWM Z' 4 12600 128-00 0 *Swjw 2' 4 12960 13190 0 l"ir --,"r"'MVXKWOFIIV� , AWAEEATTOPP6*;a29D1222V t&E `41 —WM� OWS= SHOT ' SM Y 6 12720 12310 0 OMM 71 6 12340-173W 0 %TJZW T 6 124M -12300 0 065 6 IM - IM70 o DOWM Z' 4 12600 128-00 0 *Swjw 2' 4 12960 13190 0 O&MM 2 4 13290 133W 0 I iour !(#MIVWCT LM) 10740 7"T --FTiFx -3vir-PT� W -u -G. -L ennot -LOW4 orrr, PAW RFj~PWWVWTM V 4 2 372' xlUcxsa 13W .�, MAAL tlny M I VM 1 02 UbA PL41W M 02OXM AH M 50 We XMI 0 1 Tt1N. fO*. XX H14 43W OPaKPWON" tMokol BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 02-05A (203-082) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 1,000,000 L Y C a 100,000 10 1 Jan -2000 Jan -2005 Jan -2010 Jan -2015 10,000,000 W d 1,000,000 CD O 100,000 m 0 7 S 10,000 O W Ol 1,000 F O 100 a N 3 O 3 10 S 1 Jan -2020 SPREADSHEET_Prod-Inject_Curves_Well_V117_PBU 02-05A_20190110.xlsx 1/10/2019 Cum. Prod Gas (mcf) 39,631,074 ww�--_-_r .. wwwwwwww wwwJqx ��iil�llJ J'.■ MM ___i�w•• �.� wwwwwww ��wwwwwwwwwww www�:��.��r� wwwww�,�� ww�wwwwwww wwww�w � www �wwww�� wwww�www�� ------'I■ __��---------- ww _ --IMM - :.• .. ... :.• Jan -2005 Jan -2010 Jan -2015 10,000,000 W d 1,000,000 CD O 100,000 m 0 7 S 10,000 O W Ol 1,000 F O 100 a N 3 O 3 10 S 1 Jan -2020 SPREADSHEET_Prod-Inject_Curves_Well_V117_PBU 02-05A_20190110.xlsx 1/10/2019 STATE OF ALASKA • RECEIVED .ALASKA OIL AND GAS CONSERVATION COMMISSION FEBREPORT OF SUNDRY WELL OPERATIONS D 2018 • 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations AGGCO Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well CIOther: Patch Tubing/Liner Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-082 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: , 50-029-20081-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 02-05A 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 13409 feet Plugs measured 10138 feet true vertical 8959 feet Junk measured 10117/10155 feet Effective Depth: measured 10138 feet Packer measured 10254.55 feet true vertical 8170 feet Packer true vertical 8242.13 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 30" 32-112 32-112 880 Surface 1174 20" 32-1206 32-1205 1530/4930 520/2670 Intermediate 2681 13-3/8" 27-2708 27-2706 4930 2670 Production 10885 9-5/8" 27-10912 27-8649 6920/6870/8150 3330/4760/5080 Liner 3285 2-7/8"X3-1/2"X3-3/16" 10124-13409 8161-8959 Perforation Depth: Measured depth: 12220-13380 feet SCANNED „ ;.' ') True vertical depth: 8988.42-8957.67 feet Tubing(size,grade,measured and true vertical depth) 5.5"N-80 4.5"L-80 22-10394 22-8327 Packers and SSSV(type,measured and 9-5/8"X5-1/2"BKR SAB PKR 10254.55 8242.13 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: 692 19350 174 2100 781 Subsequent to operation: Shut-In 600 0 14.Attachments:(required per 20 AAC 25.07025.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations EI Exploratory 0 Development ® Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stone,Christopher Contact Name: Stone,Christopher Authorized Title: DS 18 PE �/ Contact Email: Christopher.Stone(a�bp.com Authorized Signature: Date: 2(Zil re, Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017j>tc V +i.n, 3/! /g RBIDMS ut, rr4 n .- 1 7018 Submit Original Only • • o-w Yf x Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) February 27, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Patching Tubing/Liner for Well PBU 02-05A, PTD #203-082. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 . (/) _ 0 I 2F- u 9 \ ® 0 / = / \ U m W LL-1 E (N 0 C \ / . tI S E � ƒ / @ \ \ e _ \ ; o ® / -J D 2 »o % Q F b U < / _c D = p q m U)C / co \ \ // 0 \ f o >- \ § co E / O E & cL. ƒ ('[ = I / ± \ \ Q _ < 3 0 \ O 0 m » l \ / $ 0~ ^ g@ O o fI- 0 O � m m § / CD.E 0 \ \ w $ 5 � 2 \ \ ) -' CC / \ / 2 + 4 E / / / co b CO o D | [ \ \3 6 9 2 O O ƒ \ i < 5 / / W \ \ / z \ 6 / ƒ Co04 / -t-,6 $ \ < / / [ ± \ \ m a / k / f / gym \ G & ƒ a = o § 9 R I / 2 2 22u & m c .§ �/ ZHO f \ / ® 2z ¥ / - ± O I I 2 \ DCZWW � � / / E -1 < § \ \ i \ \ i \ i ƒ a % i 0 ± / w w / / \ / « 5 \ \ CO (C) 0 CO CO < 1REE.= FMC • 02-05A SAFETY NOTES: REDUCED COLLAPSE RATING ON WELLHEAD'-l• MDEVOY I 'ACTUATOR= BAKER C 1 9-5/8".20"C1AMFi3D TO 30'DUE TO LHEAD KB.EL_EV= 64' _....----11 >< >.< MOVEMENT 1993.WELL ANGLE>-70'to 11333'. BF.REV= 30"CONDUCTOR, - -119 1 i 35.5 KOP= 3158' -#, Max Ant*= 100*•A 12644' ID= " I 0 1 2207 j---I 5-1/2^BKR FFVE SSSV NIP,ID=4.562" Datum MD= 11266' >.< Datum1VD= 8800'SS 9-5/8"CSG,47#,50095 SIRS,D=8.681* H ~120 E3--, , 20"CSG,133#,K-55,ID=18.750" H 293' 111 I 2406.& 6984'1-19-5/8"BKR STAGE COLLAR I 3IL 20"CSG,94#,H-40,ID=19.124' -H 1204' 9-5/8"CSG,47#,S0095 XO N-80 BTRS,ID=8.861" H 1916' 7'< >.< -10117' -ASH:NEST BERG DISCONCTANLAK FAILED TO RELEASE FROM 5-1/2"Bi PKR 13-3/8"CSG,72#,N-80 MRS,ID=12.347" - 2697' 1 f< ).< (1-3/4"EXTERNAL FISH PECK)(03/22/17) 9-5f3"CSG,40#,S0095 MRS,0=8.835" ---{ 6647" I 10119' 5-1/7 WET BR UPPER STROL PKR w iFTSA, 9-5/8"CSG,47#,N-80 BiRS,0=8.681" -{ 7854' _ D=2.313"(03/20/17) I I f 10133' 5-1/2'BKR SLIDING SLV,0=4.31" Minimum ID =2.313" @ 10138' IBIND PATCH 2-7/8" X NIPPLE PROFILE IN PTSA 10138' -12-7/8"X MP IV FTSA,ID=2.313"(03/20/17) 1PLUG 2:7/8"X NIP IN PATCH ASSY,D=2.313"(03/20/17) 10138' --I2-7/8"XX (03/20/17d I- 10190' 1 i I 10196' -5-1/2"BKR R NW',ID=4.31" I w/NOGO 0=4.223" ; IND PATCH - [45 KB LOVVER STRDL PKR D=2.37"(03/20/17)j- 10212' 10202' 6-1/2"BKR SBR ASSY 2)- ____ - (PDS Caliper Log 04/14/09) :z ND PATCH 5-1/2"TBG,17#,N-80,.0232 bpf,ID=4.892" H 10263' ?<-----1 10253' -19-5/8"X 5-1/2"BKR SAB FKR IX \ 10264* -15-1/2"X 4-1/2"XO,D=3,958' 10296' H 3-3/4"BKR DEIPLOY SLV,13=3.0" 1 L 10316' H3-1/2'HES X MP, 10327' -4-1/2*BKR R NIP,0=3.812" 3-1/2"LM ,8.81#,L-80,.0081 bpf,0=2.880" - 10346' I I (Bail NO CT LNR) 10346' -13-1/2"X 3-3/16"XO,ID=2.880" [4-1/2-TBG,12.6#,N-80,.0152 bpf,D=3.958' - 1039.2" 1 10397 -4-1/2"WLEG,ID=3.958' (BEHIND CT LNR) PERFORMION SUMMARY REF LOG:WA)ER-GR ON 05/17/03 TO 05/31/03 W1" *I. ...I 1111 10700' -ICEMNT TOP(ESTIMATED) .1. ANGLE AT TOP FERE:82 0 12220 .1' .4 ‘ ..,... .4. 44 10912' --I TOP OF CEMENT RAMP .444 Note:Refer to Production DB for historical perf data *** ? -ASH:BORWION RIVG&PARTIAL ****• SIZE SIT INTERVAL Opn/Sqz SHOT SQZ 11•••• ...11.0. ELEMENT FROM WET ER 2" 6 12220-12310 0 06)02/03 ....14.11* ' STRADDLE PKR(09/16115) 2' 6 12340-12380 0 06/02/03 .4...4.... 2" 6 12470-12500 0 06/02/03 I 11236' I-3-3/16"X 2-7/8'X0, 1..1**,1** 2' 6 12600-12670 0 06/02/03 4..4..1.11 D=2.372" 2' 4 12690-12900 0 06/02/03 .1.4.1.... 4..41...4* '•al 2" 4 12950-13190 0 06/02/03 .........* .......... -NI'ii 2" 4 13290-13380 0 06/02/03 /$411.11••• 1......**** 1.....1.4.4 - II OM 0 1.0 1 lvvv.v.vv**1164 9-5/8"CSG,47#,S0095 BTR3-3/16*LNR,6.2#,L-80, 11236' 11.1....**/ Ailk.mr S,ID=8.681" -I 6' ' 1,...,11... .1114.1.4. -0057 bP7.0=2-005 "%AL"' 4......... 'w 13394' -1 PBTD [2-7/8"LNR,6.16#,L-80,.0058 bpf,ID=2.44r -I 13409' DATE REV BY COMENTS - DATE REV BY COMMENTS I PRUDHOE BAY UNIT 12/22/70 ORIGINAL COMPLETION 03/30/17 EFDIAD Cl PAINED LIP.E1MEIRY BB-IND PATCH WELL: 02-05A 01/26/77 LAST WORKOVER 04/13/17 ERYND MINOR EDITS TO SHR PERMIT tib:'t030820 06/03/03 DAV/KK CTD SIDETRACK(02-05A) API ND: 50-029-20081-01 03/17/16 SW/AID CORRECTS)MA X ANGLE ' SEC 36,T11N,R14E,3636'FEL&4301'FM... 07/19/16 ZV/JND SET EVOTREVE R_UG w/FISH NECK 03/30/17 AD/JM)SET PATCH w/PTSA/NIP&RUG-PULL PLUG BP Exploration(Alaska) 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,July 20, 2016 5:54 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; Stone, Christopher;AK, OPS FS1 DS2 Operator; Regg,James B (DOA) Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J Subject: NOT OPERABLE: Producer 02-05A (PTD#2030820) Economic Evaluation Complete All, Producer 02-05A(PTD#2030820) Economic Evaluation is complete.The 3-day well test was completed on 07/12/16.The well is reclassified as Not Operable, and has been secured with a downhole plug. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 � � C:(907)943-0296 �t •.��E® 6 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, GW• PT Well Integrity Sent: Wednesday, 06, 2016 6:30 PM To: AK, OPS FS1 OSM; A OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB t Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Stone, Christopher; AK, OPS FS1 DS2 Op- ator; 'Regg, James B (DOA) (jim.reogOalaska.gov)' Cc: AK, GWO SUPT Well Integrity; A , WO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov'; Hi::-rt, Michael; Janowski, Carrie; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, • 'ver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer 02-05A ' #2030820) Economic Evaluation All, Producer 02-05A(PTD#2030820) passed a CMIT-TxIA on 07/04/16, demon ating competent production casing and packer.The well has known TxIA communication via holes in the tubing at 1013 & 10189', identified during leak detection logging. The well is reclassified as Under Evaluation,and may flow through the portable test separato or up to 14 days to ISI evaluate economics for repair. Plan Forward: 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellInte rit Coordinator@b .com> Sent: Wednesday,July 06, 2016 6:30 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OIL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; Stone, Christopher;AK, OPS FS1 DS2 Operator; Regg,James B (DOA) Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J Subject: UNDER EVALUATION: Producer 02-05A(PTD#2030820) Economic Evaluation All, Producer 02-05A(PTD#2030820) passed a CMIT-TxIA on 07/04/16,demonstrating competent production casing and packer.The well has known TxIA communication via holes in the tubing at 10133' & 10189', identified during leak detection logging. The well is reclassified as Under Evaluation,and may flow through the portable test separator for up to 14 days to evaluate economics for repair. Plan Forward: 1. Well Testers: POP well, perform well tests once stable 2. Slickline:Set tubing tail plug 3. Fullbore: MIT-T and CMIT-TxIA Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 �� DEC �� H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: ., . DW Well Integrity Engineer Sent: Wednesday, : -mber 02, 2009 8:21 PM To: GPB, Area Mgr East(F •TU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations I •=+ isor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Williams, Carrie; NSU, ADW WL&Comple is servisor; NSU, ADW Tree Wellhead PE; NSU, ADW Wells Slickline Scheduler; Diller, Carl (Northern Solutions); Allely, Josh •.'); Rico Hernandez, Claudia; NSU, ADW Well Integrity Engineer; Holt, Ryan P(ASRC) Subject: NOT OPERABLE: 02-05A(PTD #2030820) Secured with L& . • ' ready to repair 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday,July 05, 2016 9:25 AM To: 'AK, GWO SUPT Well Integrity'; Regg,James B (DOA) Subject: RE: Producer 02-05A(PTD#2030820) Economic Evaluation Ryan, Thanks for the discussion on this well today. With the receiving well shut in and 02-05A production being recorded by the portable test separator,the metering allocation looks to be taken care of. AOGCC can approve this well up to 14 days for economic evaluation. If additional time is required please get back to me. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer � � �1 Alaska Oil and Gas Conservation Commission %AWED 6 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: AK, GWO SUPT Well Integrity [mailto:AKDCWellIntegrityCoordinator(abp.com] Sent: Monday, July 04, 2016 4:00 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA) Subject: Producer 02-05A (PTD# 2030820) Economic Evaluation Jim, Producer 02-05A(PTD#2030820) is a natural flowing development well with known tubing x inner annulus communication. Leak detect log identified tubing leaks at 10133'& 10189' MD on June 24th 2010.Subsequent tubing patches were unsuccessful. Recently vertical support members on the well line and artificial lift line have become unstable. Prior to repairing well lines and re-attempting a tubing patch,we would like to flow the well through a portable test separator to an adjacent well to obtain updated well tests for economic evaluation. A CMIT-tubing x inner annulus passed to 2700 psi on July 4th 2016 confirming integrity of the production casing and production packer. Please reply at your earliest convenience or call anytime with questions/concerns. • Thanks, Ryan Holt BP Alaska-Well Integrity GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 2 /Image ~ )oject Well History File C~ ~er 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. ~œ - OßcQ.. Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 ~scan Needed 1- RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: BY: Helen ~ D Other:: Date:<6 ~O OS- 151 ýY\-0 NOTES: Scanning Preparation BY: Helen {M;;) ~ x 30 = qo + 1111 Date:s? ~ oS Isl m-P = TOTAL PAGES 0 () (Count)t<>es not in--:lude cover sl'eet) V\J1 1/Ì Date: ~ ~~ 0$ 151 I '~r I Project Proofing BY: Helen ..~ Production Scanning Stage 1 Page Count from Scanned File: q J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO Heie~ Date:~,~è ()S Is! VV\ 0 If NO in stage 1 page(s) discrepancies were found: YES NO BY: Stage 1 BY: BY: Helen Maria Date: 151 1111111111111I 1111I 11I1111111111111111 I Date: 151 Quality Checked 1111111111111111111 Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 AUG ; 1 21111 August 22, 2011 Alaska Off & Gas Cos. Commission Anchorage Mr. Tom Maunder 0S9-- S Alaska Oil and Gas Conservation Commission V)-Y 333 West 7 Avenue Anchorage, Alaska 99501 a d Subject: Corrosion Inhibitor Treatments of GPB DS -02 S {{{[ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 0 0 WELL LOG TRANSMITTAL PROACTIVE DAAGNOSTIC SERVICES, INC. To: DNR Division of Oil & Gas Corazon Manaois 550 West 7th Avenue, Suite 800 Anchorage, Alaska 99501 RE: Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 900 Benson Blvd. Anchorage, Alaska 99508 )63 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road NGO! Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 23- Jun -10 02 -05A 1 BL/ EDE 50 -029- 20081 -00 iT Y r Signed : Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E-MAIL: pdsanchoracie@memortioci.com om WE13SITE : imww.memoryloa.Com C: \Documents and Settings \Diane Williams \Desktop \Transmit_BP.docx STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~, ~_ 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate^ - v °` `a,.~ *~ Performed: Alter Casing ^ Pull Tubing^ Pertorate New Pool ^ Waiver^ Time Extension ^ ` "' I~-TC Change Approved Program ^ Operat. Shutdown ^ Pertorate ^ Re- ter Suspended Well ^ ~,t ((e ~y 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development 0 Exploratory 203-0820 J.~.~v 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-20081-01-00 8. Property Designation (Lease Number) : Well Name and Number: ~•. ADLO-028309 PBU 02-05A 10. Field/Pool(s): \, PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13409 feet Plugs (measured) None feet true vertical 8958.59 feet Junk (measured) None feet Effective Depth measured 13396 feet Packer (measured) 10253 true vertical 8958.16 feet (true vertical) 8241 Casing Length Size MD TVD Burst Collapse Structural Conductor 119 30" 157# SURFACE - 119 SURFACE - 119 Surtace 1204 20" 94#/133# SURFACE - 1204 SURFACE - 1203 Intermediate 2696 13-3/8" 72# N-80 SURFACE - 2696 SURFACE - 2630 4930 2670 Production 11180 9-5/8" 47# N-80 SURFACE - 11180 SURFACE - 8821 6870 4760 Liner 891 3-1/2" 8.81# L-80 10345 - 11236 8298 - 8851 Liner 2173 3-3/16X2-7/8" L-80 11236 - 13409 8851 - 8959 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 8.81# L-80 SURFACE - 10264 SURFACE - 8248 4-112" 12.6# N-80 10264 - 10392 8248 - 8326 Packers and SSSV (type, measured and true vertical depth) 9-5/8" X5-1/2" BKR SAB PKR 10253-° 8241 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: 632 37698 43 727 Subsequent to operation: SI 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12/31/2009 Form 10-404 Re ised 7/2009 RBDMS JaN ~ 5 ZO'~1 Cam' ~ f Submit Original Only / •~•/D 02-05A 203-082 ~G~G ATT A!`Li11A G1~IT • Sw Name Operation Date Perf Operation Code ~Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 02-05A 6/2/03 PER 12,220. 12,310. 8,988.42 8,991.74 02-05A 612/03 PER 13,291. 13,380. 8,957.67 8,957.63 02-05A 6/2/03 PER 12,690. 12,900. 8,971.76 8,959.3 02-05A 6/2/03 PER 12,950. 13,190. 8,958.85 8,956.79 02-05A 6/2/03 PER 12,470. 12,500. 8,985.74 8,986.62 02-05A 6/2/03 PER 12,340. 12,380. 8,990.79 8,989.11 02-05A 6/2/03 PER 12,600. 12,670. 8,984.26 8,974.16 02-05A 4/15/09 BPS 10,278. 13,380. 8,256.58 8,957.63 02-05A 6/19/09 BPP 10,278. 13,380. 8,256.58 8,957.63 02-05A 11/7/09 BPS 10,191. 13,380. 8,202.9 8,957.63 02-05A 11/21/09 BPP 10,191. 13,380. 8,202.9 8,957.63 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 02-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/16/2009 T/I/0= 300/160/0 Temp= S/I Assist Slick Line; CMIT-TxIA to 3000 psi (Eval TxIA comm) Pumped 82 bbls crude down TBG to reach test pressure. TBG and IA pressure fell off immediately. Pumped additional 22 bbls of crude to repressure TBG and IA to 3000 psi. Pressure fell off immediately again. Pumped 8 bbls I crude at 1.5 bpm at 2900 psi. Slick line pulled plug. Pumped 50 bbls crude to I E flush debris from nipple. Plug reset. Pumped 10 bbls crude while slick line tapped plug into nipple ***Job continued on 17 Nov 09 WSR*** 11/16/2009*** CONT FROM 11/15/09 WSR*** i 'PULLED 2 7/8" XXN PLUG FROM 10196' SLM /~ SET CAT STANDING VALVE @ 10196' SLM :LRS PERFORM C-MIT-FAIL, 1.5bpm @ 2900psi LLR s (PULL CAT STANDING VALVE FROM 10196' SLM PULLED BAKER LOWER PATCH ASSEMBLY FROM 10185' SLM (missing all packing) =RAN 5-1/2 BRUSH AND 4.0 G. RING (recovered -5 pieces of packing) SET RKH LOCK, PBR BTM ASSY W/ 2 7/8" XN NIPP W/ 2.205" NO GO IN BTM 19' FROM RKH LOCK) (OAL 21') W/2 7/8" XXN PLUG ON SEAT. ~ ***CONT ON 11/17/09 WSR*** 11/17/2009***Job continued from 16 Nov 09 WSR*** Assist Slick Line; CMIT-TxIA to 3000 jpsi. Called off job. FWHPs= 140/200/0/0 Valve positions at time of departure; I,SV shut, WV shut, SSV open, MV open, IA open, OA open. ~~ ~ e~; 11/17/2009kT/I/0=200/140/0/0 Assist Slick Line; CMIT Tx IA to 3000 psi (Eval T xIA comm). QStand by for slick line to set plug ***Job continued on 18 Nov 09 WSR ' 11 /17/2009 *** CONT FROM 11/16/09 WSR** SET BAKER LOWER PACKER ASSEMBLY ON RKH LOCK @ 10176' ~'' _ SLM/10196' MD (3.99" OD, 2.205" ID, 21' OAL, 7 pieces of 4.31 packing) C-MIT FAILED, LLR OF .8bpm @ 2700psi PULLED BAKER LOWER PACKER ASSEMBLY FROM 10176' SLM (20' ABOVE~ "` R-NIPPLE 10,196' MD), POOH W/ BAKER LOWER PACKER ASSY, HANG UP IN SSD @ 10133' MD, SHEAR OFF,*** ASSY SHEARED IN SSD*** ***CONT ON 11/18/09 WSR*** 11/17/2009T/I/0=200/100/0 Assist SLB w/ a failing CMIT Tx IA to 3000 psi (eval T x IA comm). Pumped 40 bbls crude down TBG to establish a LLR of .8 bpm @ 2700 psi (10 bbls). ** IA & OA valves open to gauges upon departure** E FW P's=600/600/0 11/18/2009***CONT FROM 11/17/09 WSR*** =PULLED BAKER LOWER PKR ASSY FROM 10158' SLM (CENT ON BTM OF SASSY TO BIG) SET BAKER LOWER ASSEMBLY @ 10176' SLM/10196' MD (4.0" OD, 2.205" ID, a21' OAL, 7 pieces of 4.31 packing, cent btm milled to 4.0") 'LRS PERFORM C-MIT, LLR OF 1.9bpm @ 2700psi PULLED BAKER LOW ER ASSEMBLY FROM 10176' SLM/10196' MD ;CURRENTLY RUNNING 4 1/2" GS, M-PROBE, PRKH PLUG BODY **"CONT ON 11-19-09 WSR**" 11/18/2009:*"*Job continued from 17 Nov 09 WSR*** Assist Slick line (eval T x IA comm. ~ Pumped 41 bbls crude down TBG to establish a LLR of 1.9 bpm @ 2500 psi. *'` IA & OA valves left open to gauges upon departure** FWP's=200/200/0 11 /19/2009 11/19/2009***CONT FROM 11-18-09 WSR*** ~~ ~m~~ ~.m SET PRKH PLUG BODY @ 10176' SLM, 10196' MD, SET PRONG @ 10173' SLM LRS PERFORMED CMIT Tx IA 3000# (FAILED) PULL PRONG FROM 10173' SLM, PULL PRKH PLUG BODY FROM 10176' SLM, 10196 MD :SET 3 1/2 "XX PLUG @ 10322' SLM, 10315' MD ***CONT ON 11-20-09 WSR""* m mem m.m®~~ ~.m~~ ~.aa ~~m~ 11/20/2009=T/I/O=140/140/0 OOA=O Assist slickline. CMIT TxIA ***xxxxxx*** 3000 psi. (Obj. ~Eval TxIA comm, Tree c/o to Address leaks at SSV & MV) Pumped 45 bbls crude gdown tbg pressure at 2000 psi at 2 bpm shut down pump pressure dropped off ;rapidly, SL to RIH and pull plug, redress and rerun. Plug did'nt set. SL to RIH with ;LIB, no impression when LIB back on surface. SL to RIH with brush and brush nipple. SL to RIH and set plug. Pumped a total of 51.67 bbls of crude at up to 4 bpm. never could get over 2700 psi. rig down (wireline still on well has control all annulus valves open to gauges operator notified of departure) FWHP=400/460/0 T/I/O/OOA=80/80/40/40 Assist slickline (Obj. Eval TxIA Comm) CMIT TXIA ***FAILED*''* to 3000 psi. On 5 attempts. Pumped a total of 22.5 bls of crude down TBG to reach test pressure. Test 1 15 min TxIA loss of 120 psi/120 psi. 30 min TxIA loss of 100 psi/100 psi. Test 2, 15 min TxIA loss of 100/100 30 min TxIA loss of 100/100. Test 3, 15 min TxIA loss of 100 psi/100 psi. 30 min TxIA loss of 60 psi/60 psi. Test 4, 15 min TxIA loss of 80 psi/80 psi. 30 min TxIA loss of 80 psi/80 psi. Test 5, 15 min TxIA loss of 80 psi/60 psi. 30 min TxIA loss of 80 psi/100 psi. After sitting for 2 hrs, and before bleeding back pressures, TxIA lost 560 psi/560 psi. (see log) Bled TxIA back to normal. Bled back 9 bbls. SL still on well at LRS departure. DSO notified of well status. Final WHP = 0/120/40/40 11/20/2009~T/I/O=140/140/0 OOA=O Assist slickline. CMIT TxIA to 3000 psi. (Obj. Eval TxIA Icomm, Tree c/o to Address leaks at SSV & MV) Pumped 45 bbls crude down tbg pressure at 2000 psi at 2 bpm shut down pump pressure dropped off rapidly, SL to RIH and pull plug, redress and rerun. Plug did'nt set. SL to RIH with LIB, no impression when LIB back on surface. SL to RIH with brush and brush nipple. SL Ito RIH and set plug. Pumped a total of 51.67 bbls of crude at up to 4 bpm. never could get over 2700 psi. rig down (wireline still on well has control all annulus valves open to gauges operator notified of departure) FWHP=400/460/0 j T/I/O 140/140/0 OOA=O Assist slickline. CMIT TxIA to 3000 psi. (Ob'. xIA Z°e Tree c/o to Address leaks at SSV & MV) Pumped 45 crude down tbg pressure 000 psi at 2 bpm shut down pump pre ropped off rapidly, SL to RIH and pull plu ress and rerun. Plu ' ' set. SL to RIH with LIB, no impression when LIB ba surf to RIH with brush and brush nipple. SL Eto RIH and set plug. Pum o 1.67 bbls of crude at up to 4 bpm. never could get over 27 i. rig down (wireline s ell has control all annulus Ivalves ope gauges operator notified of departure) =400/460/0 .. ~_.._ ~w . ~ ~ _ _._ _ _ ____.~__ 11/20/2009&***CONT FROM 11-19-09WSR**" =LRS PUMPED 45 BBLS OF CRUDE, LLR OF 2 BBLS MIN @ 2000#'s. PULLED 3 1/2" XX PLUG FROM 10322' SLM (10315' MD). IRAN W/ 3.80" CENT, 3.65" LIB, UNABLE TO PASS 10226, (no impression). RAN W/ 2.80" SWAGE, 3 1/2" BRUSH, CONCENTRATING FROM 10200' SLM ~TO 1035T SLM. 'SET 3 1/2" XX PLUG (24" OAL, 4 ea. 1/8" ports, 4 ea. 3/16" ports) @ 10330' SLM(10315' MD). LRS PERFORMED CMIT (failed). CURRENTLY PULLING OUT OF HOLE W/ 3 1/2" PLUG FROM 10330' SLM(10315' MD). ***WSR CONT ON 11/21/09*"* _.~~. _. ~... ~ ... ~.._.. ~v. ~ ~.... 11/21/2009 T/i/0= 180/50/0 Temp= SI Assist slickline pump as directed- Cnn1 PASSED to 3000 psi (Eval TxIA Comm) Pressured up T/IA to 3000 psi with 21.2 bbls crude. 2nd test results- 1st 15 min T/IA lost 20/20 psi, 2nd 15 min T/IA lost 0/0 psi with a total loss of 40 psi in 30 min test. Bled back 16 bbls crude. Final ~WHP's= 320/360 "slickline has control of well on departure" S~3,e rJx ~//~~//yp~/~ ~ y~s~, c.u. K Tr~ ~ Sr32 , N~ r-~~-~~n ~ ~,~.rn 11/21/2009 ***WSR CONT FROM 11/20/09*'"* (secure) PULLED 3 1/2" XX PLUG FROM 10330' SLM (10315' MD). DRIFT TO DEPLOYMENT SLEEVE W/ 3.77 DRIFT @ 10310' SLM (10296' MD) 14' CORR. SET 4 1/2" WFD WRP @ 10294' SLM (10280' MD W/ 14' CORRECTION) CMIT T x IA PASSED( see Irs wsr for details) **** WELL S/I ON DEPARTURE. DSO VERIFIED ALL TREE VALVES*""'' FLUIDS PUMPED BBLS 4 diesel 4 Total TREE= McEVOY GEN 1 _WELLHEAD=" McEVOY ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = 35.5' KOP = 3159' Max Angie = 53 @ 10400' Datum MD = 11266' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" Minimum ID = 2.372" @ 11236' 3-3/16" X 2-7/8" XO ~ ~ L~"~ 5~ ~' ~,G./o 5-1/2" TBG, 17#, N-80, .0232 bpf, ID = 4.892" 10264' 3-112" LNR, 8.81#, L-80, .0081 bpf, ID = 2.880" ~ 10345' 4-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 10392' PERFORATION SUMMARY REF LOG: MWD EWR-GR ON 05117/03 TO 05!31/03 ANGLE AT TOP PERF: 82 @ 12220' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 12220 - 12310 O 06/02/03 2" 6 12340 - 12380 O 06!02/03 2" 6 12470 - 12500 O 06/02/03 2" 6 12600 - 12670 O 06102!03 2" 4 12690 - 12900 O 06/02(03 2" 4 12950 - 13190 O 06/02/03 2" 4 13290 - 13380 O 06/02!03 9-518" CSG, 47#, N-80, ID = 8.681" 11645' n 11660' DATE REV BY COMMENTS DATE REV BY COMMENTS 12122!70 ORIGINAL COMPLETION 07101109 MBM/TLH SLD SLV ID UPDATE (06/19/09) 01/26/77 LAST WORKOVER 06103!03 DAV/KK GTD SIDETRACK (02-05A) 08/17(03 CMO/TL P DATUM MD (PEKE ANGLE 04/28/09 JCM/PJC SET WRP (04/15!09) 06/27!09 SEWITCH PULL WRP (06/19!09) O ~~ SAFETY ES: REDUCED COLLAPSE RATING ON 9-5i8". 20" CLAMPED TO 30" DUE TO WELLHEAD MOVEMENT 1993. 220-- j 5-112" BKR PFV E SSSV NIP, ID = 4.562" 2405' 9-5i8" BKR STAGE COLLAR 5984' 9-5/8" BKR STAGE COLLAR 10133' 5-1/2'" BKR SLIDING SLV, ID = 4.31" (SUSPECTED IDPER OB/19109 AWGRS} 10196' 5-1/2" BKR R NIP, ID = 4.472" 10203, I" 15-112" BKR SBR ASSY 10253' 9-5/8" X 5-1/2" BKR SAB PKR 10264' 5-1/2" X 4-1/2" XO, ID = 3.958" 10296' --) 3-314" BKR DEPLOY SLV, ID = 3.0" 10315' -{3-1i2" HES X NIP, ID = 2.813" 10327' 4-112" BKR R NIP, 1D = 3.812" (BEHIND CT 10345' 3-1/2" X 3-3/16" XO, ID = 2.880" 10392' 4-112" WLEG (BEHIND CT LNR) 10700' -~CEMENTTOP(ESTIMATED} 10912' --{TOP OF CEMENT RAMP, 11236' 3-3116" X 2-7/8" XO, ID = 2.372" ( 13394' I 3-3116" LNR, 6.2#, L-80, .0057 bpf, ID = 2.805" ~--' 11236' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I 13409' I PRUDHOE BAY UNIT WELL: 02-05A PERMIT No: 2030820 API No: 50-029-20081-01 SEC 36, T11 N, R14E, 3635.76' FEL & 4300.96' FNL BP Exploration (Alaska) • • _-~ MICROFILMEa 03/01/2008 DO NOT PLACE ..:``; " '~ -."`~ 1' ,; fi- ~: ._~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Miicrofilm Marker.doc ) ) WELL LOG TRANSMITTAL dO 3-03 d- 13[003 February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 02-05A + PB1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 02-05A + PBI: LAS Data & Digital Log Images: 50-029-20081-01, 70 ~ÇANNE~.,)ì ~~AH (} ~~ 2,0(\5 1 CD Rom /t//ì~() L¡, UÁ(.~cu.-i~ (b9! c'327! 0(, ) ) <1J 2. ~ \\ >- DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030820 -"" Well Name/No. PRUDHOE BAY UNIT 02-05A Operator BP EXPLORATION (ALASKA) INC ~~ c:L .2/ IV¡~ ~j- API No. 50-029-20081-01-00 MD 13409 TVD 8959 ,,/ Completion Date 6/3/2003 r Completion Status 1-01L Current Status 1-01L UIC N ------ ---- . - -- ---- - REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -------------- ------ --- -- -----. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Rpt (data taken from Logs Portion of Master Well Data Maint) Name Start Stop ~- Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments -- ------ 14 10073 13376 Open 7/24/2003 7 10073 12391 Open 7/24/2003 PB1 14 10073 13376 Open 7/24/2003 11292 13409 Open 6/12/2003 11150 12435 Open 6/12/2003 PB1 7 10073 12391 Open 7/24/2003 PB1 10019 13368 Case 7/23/2003 2 10019 13368 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL ~ 2 10019 13368 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL 2 Blu 10019 13368 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL 2 Blu 10019 13368 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL ____________ _____ J Sample Set Sent Received Number Comments Name LIS Verification Rpt LIS Verification ED D 11813 LIS Verification Rpt Directional Survey Rpt Directional Survey ED D 11812 LIS Verification ED C Tf 12130 LIS Verification ED C Pds 12130 Neutron ED C Pds 12130 Casing collar locator cOg ~/ I Neutron Casing collar locator Well Cores/Samples Information: Interval Permit to Drill 2030820 MD 13409 TVD 8959 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? .~ Analysis Received? ¥+t(' Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Well Name/No. PRUDHOE BAY UNIT 02-05A Operator BP EXPLORATION (ALASKA) INC Completion Date 6/3/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? ÐN (VN Formation Tops \JÕ Date: API No. 50-029-20081-01-00 UIC N - ---- -- ------ -- - -- - -- ;h J uJ~)- h:~ \, ------ ~. ?-D3-D8~ \t3l3 "'TELL LOG TRANSMITTAL To: State of A1aska A1aska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage,AUaska July 18, 2003 RE: MWD Formation Evaluation Logs 02-05A, AK-MW-2454192 1 LDWG formatted Disc with verification listing. API#: 50-029-20081-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-SunDri11ing Services Attn: Rob Kalish 6900 Arctic Blvd. AnChORÈCEi\ìËo JUL 24 2003 Date: . Si!,rned: AJasfta a·¡ & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 0~ <\ [' ~" :LD2> ·DB1-> I \ ßl2 WELL LOG TRANSMlTIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska July 1 8, 2003 RE: MWD Formation Evaluation Logs 02-05A PB1, AK-MW-2454192 1 LDWG formatted Disc with verification listing. API#: 50-029-20081-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 An~SVE" JUL 24 2003 Date' .,,' . Atalka'œ &: Gas Cons. ~mmlSØ)n Anctlorage Signed: ~~d Sc~lullbepge.. Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well D.S. 2-05A~O. ~-j'"fJf?~ H-27A -çt~I1:1 E-02A 'í ~.,!} NK-62A fj(~~. "-::f E-01A ~ -~~? P2-54A . ß....O ::" D-22B .. -1(7) - D.S. 2-088 )cr~ -:09 ~ J-26 D.S. 2-29A D.S. 15-28 D.S. 12-20 J-08 D.S. 2-25 PSI-01 PSI-06 PSI-09 K-317B C-04A Job# 23376 23319 23275 23277 23280 23274 23348 07/02/03 NO. 2890 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 06/02/03 1 Ja. )?J[( 05/09/03 1 Jr~~ 03/15/03 1 04/27/03 1 04/12/03 1 03/27/03 1 ~ ~'~se OS/22/03 1 )fJ-j,. ~ 05/31/03 1 06/20/03 1 06/22/03 1 06/21/03 1 06/03/03 1 06/26/03 1 06/07/03 1 06/09/03 1 06/13/03 1 06/19/03 1 04/05/03 1 06/26/03 1 MCNL MCNL MCNL MCNL MCNL MCNL MCNL MEM PROD PROFILE LDL LDL LDL LDL LDL PRODUCTION PROFILE TEMPERATURE WARMBACK LOG TEMPERATURE WARMBACK LOG TEMPERATURE WARMBACK LOG SBHP SURVEY SBHP SURVEY PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth RECEIVED JUldLô 2003 Received ;mt ~ .l j~~ t.. G ()~ ~r:/::-/'f'.-. AJã~a Q¡1 & Gas Cons. CammÌlliOn Anchorage ,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG (' ( 1. Status of Well aD Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1182' SNL, 1793' EWL, SEC. 36, T11 N, R14E, UM At top of productive interval 1034' NSL, 3839' WEL, SEC. 26, T11 N, R14E, UM X = 682862, Y = 5952119 10. Well Number At total depth 1294' NSL, 49' WEL, SEC. 27, T11 N, R14E, UM X = 681367, Y = 5952342 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool RKB = 64' ADL 028309 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 5/21/2003 " 5/31/2003 / 6/312003 ;- 17. Total Depth (MO+TVO) 18. Plug Back Depth (MO+TVD) 19. Directional Survey 13409 8959 FT 13396 8958 FT aD Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, Memory CNL, GR, CCL Classification of Service Well 7. Permit Number 203-082 8. API Number 50- 029-20081-01 9. Unit or Lease Name X = 688550, Y = 5950043 Prudhoe Bay Unit 02-05A 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2207' MD 1900' (Approx.) 23. CASING SIZE 30" 20" 13-3/8" 9-518" WT. PER FT. 157# 94# 1133# 72# 47# 140# 8.81# /6.2# / 6.16# GRADE B H&K N-80 S&N L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 119' 39" Surface 1204' 26" Surface 2696' 17-1/2" Surface 11180' 12-1/2" 1 0296' 13409' 3-3/4" CEMENTING RECORD Fondu Neat to Surface 750 sx Fondu Flyash/ 280 Fondu Neat 1355 sx Fondu Flyash, 425 sx 'G' 1480 sx Class 'G', 100 sx Fondu Flyash 196 sx Class 'G' * 3-1/2" x 3-3116" x 2-7/8" AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 6 spf 2" Gun Diameter, 4 spf MD TVD MD TVD 12220' - 12310' 8988' - 8992' 12690' - 12900' 8972' - 8960' 12340' - 12380' 8991' - 8989' 12950' -13190' 8959' - 8957' 12470' -12500' 8986' - 8987' 13290' -13380' 8958' - 8958' 12600' - 12670' 8984' - 8974' 25. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, N-80 10264' 4-1/2", 12.6#, N-80 10392' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 35 Bbls of MeOH PACKER SET (MD) 10253' t~ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 9, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl 6/23/2003 6.1 TEST PERIOD 1,993 2,556 118 Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl Press. 177 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. F? ~= f~\o E·· '. No core samples were taken. ~.:'ëD;;~,oìi1 . . ",- J:-, : k-~.:J'5f.:' JUN ~~ '7 7003 :1 VF..flIj;".Œþ ~ L~ 0 RIG I N A L I\la5k~ CHOKE SIZE GAS-Oil RATIO 49° Oil GRAVITY-API (CORR) Form 10-407 Rev. 07-01-80 RBDMS 8Ft (P(v JUt 0 ~ 2mr~ Submit In Duplicate (' ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. Zone 2A 11376' 8903' 21N 11666' 8929' 21P 11706' 8933' Zone 18 /14N 11788' 8944' 14P 11815' 8947' Zone 1A 113N 12152' 8978' 13P 12220' 8988' 12N (Inverted) 12600' 8984' 13P (Inverted) 12662' 8975' Zone 1 A 113N (Inverted) 12720' 8969' 31 . List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ J ~ Title Technical Assistant Date O!o· ~lo -03 02-05A 203-082 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Mary Endacott, 564-4388 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 { , ( BP EXPLORATION Operations Summary Report Page 1 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/17/2003 00:00 - 02:45 2.75 MOB P PRE Rig released from 18-14B @ 24:00Hrs on 5/16/2003. 9mph wind speed. Prep to move rig off well. Raise tarps & warm up move system. 02:45 - 03:00 0.25 MOB P PRE PJSM for moving rig off well. 03:00 - 03:30 0.50 MOB P PRE Move rig off well & set down on pad. 03:30 - 04:00 0.50 MOB P PRE Remove X/Over spool from BOPs. Conduct post operations pad inspection with DSO. Remove guy wires. 04:00 - 06:00 2.00 MOB P PRE PJSM. LD windwalls. Scope down and LD derrick. 06:00 - 07: 15 1.25 MOB P PRE Secure end of CT. Close pipeshed roof. 07:15 - 08:00 0.75 MOB P PRE PJSM. Jack-up & move rig to pad entrance. 08:00 - 08:15 0.25 MOB P PRE Held pre-move safety meeting with all personnel. 08:15 - 10:30 2.25 MOB P PRE Move rig from 18-14 to DS#2 & set down adjacent to 02-05. Meanwhile Tool Services leveling pad. 10:30 - 10:45 0.25 MOB P PRE Conduct pre operations pad inspection with DSO. Meanwhile prep to raise derrick & windwalls. 10:45 - 11 :00 0.25 MOB P PRE PJSM for raising derrick. 11 :00 - 11 :45 0.75 MOB P PRE Raise & scope up derrick. 11:45 - 12:00 0.25 MOB P PRE PJSM for raising windwalls. 12:00 - 13:00 1.00 MOB P PRE Raise windwalls. 13:00-13:15 0.25 MOB P PRE Secure guy wires. Secure tilt rams in storage frame. 13:15 - 13:30 0.25 MOB P PRE Align rig in front of well 02-05. 13:30 - 16:00 2.50 MOB P PRE Standby while TS lay double mats in front of well. Meanwhile P/U BOPs. 16:00 - 16:30 0.50 MOB P PRE PJSM. Back rig over well & set down. 16:30 - 18:30 2.00 BOPSUR P PRE PJSM. N/U BOPE. Meanwhile spot outside tanks. Accept rig at 1830 hrs 5/17/2003 18:30 - 20:30 2.00 RIGU P PRE Pull injector out of box. RU gooseneck. Stab CT 20:30 - 00:00 3.50 BOPSUR P PRE Initial BOPE test. Witness waived by AOGCC. Stem packing leak on MV had to be greased by grease crew 5/18/2003 00:00 - 04:15 4.25 BOPSURP PRE Finish BOPE test. One valve on manifold failed-found a chunk of cement and retested 04:15 - 06:30 2.25 BOPSUR P PRE RU DSM and pull 6" BPV. Open up well & observe Opsi WHP. 06:30 - 07:00 0.50 BOPSUR P PRE R/D DSM. 07:00 - 07:30 0.50 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & BHA M/U procedure. Meanwhile pressure test well bore & cement plug to 11 OOpsi ""' leaked down to 990psi after 30mins. 07:30 - 10:00 2.50 STWHIP P WEXIT Cut coil & install Weatherford CTC. Pull test to 35k. Install dart catcher. Load wiper dart. Launch & chase/fill CT with 1% KCL. Dart hit @ 58.9bbls. Press test CTC & inner reel valve to 3500psi ""' OK. 1 0:00 - 1 0:30 0.50 STWHIP P WEXIT M/U cement milling BHA #1 with 3.80" HC D331 mill, 2-7/8" WII motor with 1.25deg ABH, GR-DIR MWD, 20 degs orienter & MHA (OAL = 61.36'). Scribe tools. 10:30 - 12:30 2.00 STWHIP P WEXIT RIH cement milling BHA #1. SHT @ 700' ""' OK. Continue RIH. Wt check @ 9000', up""' 40k & down""' 20k. Meanwhile held MR on rig move from DS#18 & MIRU on DS#02-05. 12:30 - 13:15 0.75 STWHIP P WEXIT Continue RIH. Wt check @ 10750', up""' 47.5k & down - 20k. RIH & tag TOC @ 10898'. Correct to 10912' ELM. PUH to 10570' diverting gassy returns to the tiger tank. 13:15 -14:20 1.08 STWHIP P WEXIT Log down GR from 10544' to 10650' @ 120-160fph. Tie-in with SWS CNLlGR of 1-27-77. No correction. 14:20 -15:15 0.92 STWHIP N DFAL WEXIT Attempt to orient TF ""' not getting clicks. Troubleshoot without Printed: 6/9/2003 12:00:07 PM ( I( Page 2 of 19 BP EXPLORATION Operations Summary Report success. RBIH to TOC tagged @ 10912'. POOH for orienter logging up memory GR @ 240fph. POOH with milling BHA#1. Change orientor. Download memory data. Replace bleed sub with #11 jet. Add NRJ RIH w/ BHA #2 Log tie-in down from 10670' 2.6/2650/113R and had spurious data RIH and tag at 10903', corr to 10912' PUH 43.5k DIMS cost quirk - geo standby charge Log tie-in down from 10660' 2.5/2420/113R. Add 4.0' RIH, get one click Drill hard cement from 10912' 2.5/2430/155-170R w/400-600 diff at 25-40'/hr 11077' 2.6/2540/150-170R 25-35'/hr. Mill hard cement to 11106'. Mill cement to 11113' with 137R, 2.7/2.7bpm, 3000/3220psi & 36fph ave ROP. Wiper trip clean to TOC @ 10912'. RBIH. Mill LS pilot hole to 11168' with 165R, 2.7/2.7bpm, 3000/3180psi, 2k WOB & 27fph ave ROP. Stall3x @ 11158' casing collar. Orient TF to HS. Mill HS cement ramp with 13L, 2.7/2.7bpm, 3000/3130psi, 2k WOB & 27fph ave ROP. Hit csg wall @ 11179.9'. Backream cement ramp & pilot hole with HS TF. Flag pipe @ 10900' bit depth & POOH cement milling BHA. OOH. LID 2-7/8" W1I1.25deg ABH motor & 3.80" HC 0331 mill. M/U window milling BHA #3 with 3.80" HC DP0088 DSM, 2-7/8" WII motor with 3deg FBH, GR-DIR MWD, 20 degs orienter & MHA (OAL = 63.8'). Scribe tools. WEXIT RIH window milling BHA #3. Meanwhile close choke & allow WHP to increase to 1000psi. PiT well bore @ 1000psi - dropped to 950psi @ 5mins & 938psi @ 10mins. Bleed off & open up choke. WEXIT RIH window milling BHA #3. Set down @ TT collar - roll pumps & fall thru. Continue RIH. Added 5' to CTD @ the flag. RIH & tag csg collar 11116' - roll pumps, fall thru & set down @ 11125'. PUH above TOC. Up wt check @ 10900' - 45.5k. DFAL WEXIT Check TF - MWD not pulsing. Observe high circ pressure of 4000psi @ 2.7bpm. Looks like a pulser lock-up. Surge & free pulser. SID pumps. WEXIT RIH & tag @ 11164'. Rolls pumps several times & attempt to work past tight spot - no success. PUH to 11143' & orient 1 click to 33L. SID pumps & retag @ same 11164'. Decide to log GR tie-in. PUH to 10660'. Log down GR tie-in from 10650'. Add 4' RIH w/o pump to set down at 11168'. PUH and check TF at 180L. Orient to HS. 2.5/3460 Fine tune TF to 15L. RIH to tag at 11181 '. Pull stretch out l' and flag at 11180' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 5/18/2003 From - To Hours Task Code NPT Phase 14:20 -15:15 0.92 STWHIP N DFAL WEXIT 15:15 - 18:30 3.25 STWHIP N DFAL WEXIT 18:30 - 20:00 1.50 STWHIP N DFAL WEXIT 20:00 - 21 :15 1.25 STWHIP N DFAL WEXIT 21 :15 - 23:05 1.83 STWHIP N DFAL WEXIT 23:05 - 23:40 0.58 STWHIP N DFAL WEXIT 23:40 - 23:50 0.17 STWHIP N DFAL WEXIT 23:50 - 23:59 0.15 STWHIP N DFAL WEXIT 23:59 - 00:00 0.02 N PROD1 00:00 - 00:20 0.33 STWHIP N WEXIT 00:20 - 00:30 0.17 STWHIP P WEXIT 00:30 - 05:45 5.25 STWHIP P WEXIT 05:45 - 06:40 0.92 STWHIP P WEXIT 06:40 - 06:55 0.25 STWHIP P WEXIT 06:55 - 07:05 0.17 STWHIP'P WEXIT 07:05 - 09:25 2.33 STWHIP P WEXIT 09:25 - 09:35 0.17 STWHIP P WEXIT 09:35 - 10:20 0.75 STWHIP P WEXIT 10:20 - 13:30 3.17 STWHIP P WEXIT 13:30 - 14:10 0.67 STWHIP P WEXIT 5/19/2003 14:10 - 14:40 0.50 STWHIP P 14:40 - 17:00 2.33 STWHIP P 17:00 - 17:20 0.33 STWHIP N 17:20 - 17:55 0.58 STWHIP P 17:55 -18:10 0.25 STWHIP P WEXIT 18:10 -18:40 0.50 STWHIP P WEXIT 18:40 - 19:00 0.33 STWHIP P WEXIT 19:00 -19:15 0.25 STWHIP P WEXIT Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Description of Operations Printed: 6/9/2003 12:00:07 PM ( ,G' ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/19/2003 5/20/2003 Continue time milling by schedule at 11181.0' 2.4/3140/7L 11185.1' 2.4/3140/39L Near end of schedule. Start to 'wing it' after getting 150 psi motor work, 4k WOB, extra reactive and G totals out Mill to 11187.5' with 33L TF, 2.4/2.4bpm, 3110/3220psi, 4k WOB & 6fph aye ROP. TF walking right. Seems like we went out @ 11185.3'. P/U 48k & establish freespin @ 2.5/3250psi, run-in wt = 14k. WEXIT Saw MW @ btm of window @ 11185.3. Mill from btm of window into formation @ 11186' with HS TF, 2.5/2.5bpm, 3250/3350psi, 2k WOB & 25fph aye ROP. Window depth taken as 11180' - 11186'. Mill?' to 11193' with 7R TF, 2.5/2.5bpm, 3250/3410psi, 2k WOB & 18fph aye ROP. PUH & drift window without pumping & tag up @ 11193'. Window looks clean. PUH to 10670'. Log down GR tie-in from 10670'. Added 2' to CTD. Flag EOP pipe @ 10620' & POOH window milling BHA. OOH. LID & inspect milling BHA#3. Window mill gauge 3.80" go /3.79" no go. Wear on mill face indicates center crossed the casing wall. Observe tight MWD pulser - will changeout. M/U window dressing BHA #4 with 3.78" Crayola mill, 2-7/8" WII motor with 2.25deg ABH, GR-DIR MWD with new pulser, 20 degs orienter & MHA (OAL = 64.13'). Scribe tools. RIH window dressing BHA #4 to 3400'. SHT - OK. Continue RIH. Added 5' to CTD @ the flag. Continue drifting in hole to 11140'. Orient TF to HS & RIH @ min rate & stack out @ 11173'. P/U heavy. PUH to 10670' to tie-in. Log tie-in down from 10670', then 10660' 2.5/3375/16L. Add 11.0' RIH and tag at 11184' Ream window area 2.5/3180/4R from 11182' while swap to used Flo Pro mud Stall at btm of window at 11186.6' 2.5/331 0/4R 11186.8', Continue reaming down thru window. IAP=5 psi, OAP=34 psi. Pit vol=165 bbls. Still taking new mud on from vac trucks. No motor work observed after stall at 18:00. Backream up thru window at TF=5L. Pit vol=270 bbls, all trucks unloaded. Repeat up ream thru window at 25R. Orient around to 16L. Backream up thru window. Orient to 45L. Backream up at 45L. IAP=O psi, OAP=37 psi. Pit vol=271 bbls. No motor work observed on any of the backreaming passes. SI pumps after last up reaming pass. Dry drift window. No drag observed. POH to pick up drilling BHA. DIMS cost quirk, geo stand by 02-05 02 -05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task Code NPT Phase 19:15 - 23:59 4.73 STWHIP P WEXIT 23:59 - 00:00 0.02 P PROD1 00:00 - 05:35 5.58 STWHIP P WEXIT 05:35 - 06:35 1.00 STWHIP P WEXIT 06:35 - 07:10 0.58 STWHIP P WEXIT 07:10 - 07:50 0.67 STWHIP P 07:50 - 08:40 0.83 STWHIP P WEXIT 08:40 - 08:55 0.25 STWHIP P WEXIT 08:55 - 09:10 0.25 STWHIP P WEXIT 09:10 -11:00 1.83 STWHIP P WEXIT 11 :00 - 11 :30 0.50 STWHIP P WEXIT 11 :30 - 12:00 0.50 STWHIP P WEXIT 12:00 - 14:40 2.67 STWHIP P WEXIT 14:40 - 15:30 0.83 STWHIP P WEXIT 15:30 - 15:45 0.25 STWHIP P WEXIT 15:45 - 18:00 2.25 STWHIP P WEXIT 18:00 - 18:30 0.50 STWHIP P WEXIT 18:30 -19:50 1.33 STWHIP P WEXIT 19:50 - 21 :30 1.67 STWHIP P WEXIT 21 :30 - 21 :45 0.25 STWHIP P WEXIT 21 :45 - 22:30 0.75 STWHIP P WEXIT 22:30 - 22:40 0.17 STWHIP P WEXIT 22:40 - 23:30 0.83 STWHIP P WEXIT 23:30 - 23:59 0.48 STWHIP P WEXIT 23:59 - 00:00 0.02 P PROD1 Page 3 of 19 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Description of Operations Begin time milling from 11180.0' 2.5/3420/25L-1 OL Mill to 11181.0' 2.4/3170/7L PVT 268 DIMS cost quirk, geo stand by Printed: 6/9/2003 12:00:07 PM ( {' BP EXPLORATION Operations Summary Report Page 4 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2003 00:00 - 01 :15 1.25 STWHIP P WEXIT Continue POH with window dressing BHA. 01: 15 - 01 :50 0.58 STWHIP P WEXIT Tag up at surface. Lay down window dressing BHA. (BHA #4). Window mill gauges at 3.79" - Go, 3.78" No-Go. Minor wear observed on window mill. If it was a bit, it would have been graded a 1,1. 01 :50 - 02:20 0.50 DRILL P PROD1 Pre Spud safety meeting. Discuss Safety points relevant to this well, including; 2 known WH problems, also tall tree. The history of lost circulation and shale problems on DS 2 were addressed. The plan forward, hazards and mitigation were all reviewed. 02:20 - 03: 15 0.92 DRILL P PROD1 Cut WF CTC, and install SWS CTC. PT CTC to 3500 psi, Pull test to 35 klbs. 03:15 - 04:45 1.50 DRILL P PROD1 Pick up first OH build section BHA. (BHA #5). Read/program Sperry resistivity tool. Check orienter to ensure it is free of debris and functional. 04:45 - 06:30 1.75 DRILL P PROD1 RIH with BHA #5. 3.75" x 4.25" Hycalog bi center bit, BH11.04 deg mud motor, Sperry RES tool and standard MWD package. Shallow hole test of MWD passed at 500'. Orienter worked ok at 3400'. 06:30 - 07: 15 0.75 DRILL N SFAL PROD1 Work to toggle SS tool to logging mode 07:15 - 07:30 0.25 DRILL P PROD1 Log tie-in down from 10685' 2.6/2650/4R. Add 2.0' 07:30 - 07:40 0.17 DRILL P PROD1 RIH clean, thru window at 10R. Tag at 11193.6' 07:40 - 08:50 1.17 DRILL P PROD1 Drill from 11193' 2.5/2560/25L w/200-500 psi diff70-100'/hr in 22B. Drill to 11245' 08:50 - 09:40 0.83 DRILL P PROD1 Work to toggle SS 'on' from 11245'. Sperry claims window is bending their tool. Drill ahead blind and try to restart every so often. Drill to 11265' and restart Fire drill and rig evacuation drill, then discuss 09:40 - 10:10 0.50 DRILL P PROD1 Drill from 11265' 2.5/2660/2L to 11280' and orientor wants to go lowside 10:10 - 10:30 0.33 DRILL N DFAL PROD1 Work w/ orientor 10:30 - 11 :00 0.50 DRILL P PROD1 Drill from 11280' 2.6/2760/1 OR to 11300' 11:00 -12:15 1.25 DRILL P PROD1 Drill from 11300 2.6/2800/80R to 11350'. Survey (first good one) 12:15 - 12:30 0.25 DRILL P PROD1 Wiper to window 12:30 - 12:50 0.33 DRILL P PROD1 Orient to left side 12:50 -13:30 0.67 DRILL P PROD1 Drill from 11350' 2.7/2850/70L to 11368' 13:30 - 14:00 0.50 DRILL P PROD1 Orient around (twice) 14:00 - 15:15 1.25 DRILL P PROD1 Drill from 11368' 2.7/2850/70L-16L to 11420' 15:15 -15:35 0.33 DRILL P PROD1 Orient around 15:35 - 16:50 1.25 DRILL P PROD1 Drill from 11420-502' 2.5/2600/90L 16:50 - 17:00 0.17 DRILL P PROD1 Wiper to window 17:00 - 17:20 0.33 DRILL P PROD1 Log up from 11235' 2.6/2800/124R-no good marker 17:20 - 17:30 0.17 DRILL P PROD1 Wiper to original tie-in point at 10650' in 9-5/8" 17:30 - 17:40 0.17 DRILL P PROD1 Log tie-in down from 10685' 2.5/2600/74R. Add 2.0' 17:40 - 18:10 0.50 DRILL P PROD1 RIH, clean thru window at 124R to TD tagged at 11504', get one click 18:10 - 18:30 0.33 DRILL P PROD1 Drill from 11504' 2.6/2600/60L 18:30 - 19:15 0.75 DRILL P PROD1 11530', Continue drilling ahead. 2.5/2.5/2850 psi. IAP=O, OAP=46 psi. Pit vol=264 bbls. 19:15 - 19:25 0.17 DRILL P PROD1 11575', Orient to 36R. 19:25 - 20:45 1.33 DRILL P PROD1 Resume drilling. 20:45 - 21 :45 1.00 DRILL P PROD1 11645', Weight transfer getting poor. Make wiper trip to Tubing Printed: 6/9/2003 12:00:07 PM ( ¡ \ BP EXPLORATION Operations Summary Report Page 5 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2003 20:45 - 21 :45 1.00 DRILL P PROD1 tail. Clean PU off bottom, clean thru window. 21 :45 - 22:15 0.50 DRILL P PROD1 Orient to 65R. 22: 15 - 23:30 1.25 DRILL P PROD1 Resume drilling. Still having weight transfer issues. Having to snub to drill. Mix 1/2 drum of Flo-Iube in pill pit with mud from active system. 23:30 - 23:50 0.33 DRILL P PROD1 11680', Pickup off bottom for surveys. Pump slick 30 bbl sweep. Pit vol=250 bbls. Do not appear to be loosing mud to cuttings box. We appear to have 2.5-3 bbl/hr seapage losses to formation. 23:50 - 00:00 0.17 DRILL P PROD1 Orient to 40L. 5/22/2003 00:00 - 00:40 0.67 DRILL P PROD1 11680', resume drilling ahead. 2.7/2.7/3340 psi. Free spin=2650. Weight transfer improved when we drilled thru the shale at 11675', possibly had a bit balled up with clay. No improvement observed from slick sweep. 00:40 - 01 :00 0.33 DRILL P PROD1 11713', Short wiper to give geo a chance to evaluate logs. Unexpected clay at 10630-10675' may indicate we have crossed a fault. 01 :00 - 03:00 2.00 DRILL P PROD1 Geo's conclusion is that we have crossed a fault, and the structure is 28' higher than expected. Will need to trip for a bigger bend motor to land well above BSAD. POOH. Smooth in open hole, no problems at the window. 03:00 - 03:45 0.75 DRILL P PROD1 Tag up, stand back injector. Adjust motor to 1.37 deg. Check bit, found it to be ringed on the pilot section, with several chipped cutters. Bit graded as 6,2,RO. 03:45 - 06:30 2.75 DRILL N SFAL PROD1 SWS hands inspected coil reel during BHA swap. They found damage to main CT reel support axle. Axle is sheared in half. Repair to axle must be made prior to being able to run back in the hole. Standby on repairs. 06:30 - 07:15 0.75 DRILL N SFAL PROD1 MU new plate with support pin to reel drive plate on drillers side. Install bushing. Connect to reel 07: 15 - 08:00 0.75 DRILL P PROD1 MU drilling BHA while fin repairs to reel support system 08:00 - 08:40 0.67 DRILL P PROD1 Upload res tool 08:40 - 09: 15 0.58 DRILL P PROD1 Fin MU BHA, then wo repairs to reel 09:15 -11:15 2.00 DRILL P PROD1 RIH w/ BHA #6 (1.37 deg motor, 4.25" bi Hycalog) SHT Kick while trip drill 11 : 15 - 11: 35 0.33 DRILL N SFAL PROD1 Park at tie-in depth and adjust reel bushing 11 :35 - 11 :45 0.17 DRILL P PROD1 Log tie-in down from 10685' 2.5/2730/36L. Add 2.0' 11:45-12:10 0.42 DRILL P PROD1 RIH, clean thru window at 90R. Precautionary ream to TD 2.5/2800/132L, clean. Tag at 11705'. PVT 310 12:10 - 12:20 0.17 DRILL P PROD1 Orient to HS 12:20 - 13:25 1.08 DRILL N SFAL PROD1 Slow ream last 100' while WO SS to reboot PC and then reinstall software 13:25 - 13:55 0.50 DRILL P PROD1 Drill from 11705' w/ neg wt 2.6/2800/19-39RR to 11718'. Need fresh mud 13:55 - 14:20 0.42 DRILL P PROD1 Orient around 14:20 - 15:40 1.33 DRILL P PROD1 Drill from 11718' 2.6/2800/2R and tough to make hole. Drill to 11732'. PVT 309 15:40 - 16:40 1.00 DRILL P PROD1 Start new mud. Drill from 11732' 2.6/2900/1 OR to 11737' w/ definitely better wt transfer, but poor penetration rate 16:40 - 17:30 0.83 DRILL P PROD1 Drill from 11737' 2.6/2870/22R and penetration rate up to 40'/hr w/ full string wt. Start seeing a shale from 11700' 17:30 -18:15 0.75 DRILL P PROD1 Wiper to window (11250') 18:15-18:50 0.58 DRILL P PROD1 Resume drilling. Hole conditions sticky. Having trouble getting Printed: 6/9/2003 12:00:07 PM f (' BP EXPLORATION Operations Summary Report Page 6 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02 -05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/22/2003 18:15 -18:50 0.58 DRILL P PROD1 back to bottom. IAP=O, OAP=40 psi. Night Geo reports that the shale we encountered at 11700' may be the Kavik shale (BSAD). If that is the case, we need to go to max Kla-gard, and drill up out of it. 18:50 - 19:00 0.17 DRILL P PROD1 11768', Orient around to left side to hold build angle. Predicted angle at the bit is 92 deg. Mud man has begun adding more Kla-gard to system to bring it up to maximum. (14#/bbl). 19:00 - 19:20 0.33 DRILL P PROD1 Resume drilling. ROP-50 fph. 19:20 - 19:30 0.17 DRILL P PROD1 11790', Orient to high side to get up out of shale quicker. Shooting for 93 deg build angle. 19:30 - 20:30 1.00 DRILL P PROD1 Resume drilling. Finished taking on mud. Pit vol=287 bbls. 20:30 - 20:40 0.17 DRILL P PROD1 11810', Orient to left side. 20:40 - 22:40 2.00 DRILL P PROD1 Resume drilling. 22:40 - 23:20 0.67 DRILL P PROD1 11900', Wiper trip to shoe. Clean PU off bottom at 37 klbs. 23:20 - 23:55 0.58 DRILL P PROD1 Resume drilling. 23:55 - 00:00 0.08 DRILL P PROD1 11925', PU, orient to high side. Geo wants to build even quicker. Wants to come up 8 TVD ft in next 75' MD. Shooting for 97 deg INC. 5/23/2003 00:00 - 01 :30 1.50 DRILL P PROD1 11925', Drilling ahead. 2.6/2.6/3000 psi, 281 bbls pit vol. 01 :30 - 01 :50 0.33 DRILL P PROD1 11960', Angle at the bit is 97 deg. Orient around to 90l to hold angle. 01 :50 - 02:25 0.58 DRILL P PROD1 Resume drilling. 02:25 - 03:45 1.33 DRILL P PROD1 11973', Wiper trip to tubing tail. 03:45 - 04:55 1.17 DRILL P PROD1 Resume drilling. 2.6/2.6/3220 psi, Pit vol=276 bbls. 04:55 - 05:10 0.25 DRILL P PROD1 12002', Geo wants to continue to hold a somewhat agressive build. Orient to 70L to hold 94 deg build angle. 05: 1 0 - 05:30 0.33 DRILL P PROD1 Resume drilling. 05:30 - 05:45 0.25 DRILL P PROD1 12029', Need 1 click to left. Can't go left, so PU and orient around. 05:45 - 06:50 1.08 DRILL P PROD1 Drill from 12029' 2.6/2900/70L to 12062' (8940' TVD). Geo feels we are in/near target 13P with 2 deg dip up PVT 270 06:50 - 07:20 0.50 DRILL P PROD1 Orient around 07:20 -11:10 3.83 DRILL P PROD1 Drill from 12062' 2.7/2920/150L-90L to level out at 92 deg. Drill to 12126' Kick while drilling drill 11 :10 - 12:10 1.00 DRILL P PROD1 Wiper to 11260'. Set down at 12030' 12:10-13:00 0.83 DRILL P PROD1 Drill from 12126' 2.6/2900/36L to 12133' and still in shale/clay and miserably slow penetration rate 13:00 - 13:30 0.50 DRILL P PROD1 Wiper to EOT 13:30 -15:15 1.75 DRILL P PROD1 POOH for bit 15:15 -17:00 1.75 DRILL P PROD1 Change bit (no wear/one lost cutter), motor. Download SS resistivity data 17:00 - 19:05 2.08 DRILL P PROD1 RIH w/ BHA #7 (1.37 deg motor) SHT 19:05 - 19:35 0.50 DRILL P PROD1 Log tie in pass down from 10685' bit depth. Make -4' correction. 19:35 - 20:25 0.83 DRILL N DPRB PROD1 Continue RIH. SD pumps going thru the window. Set down at 11196', 10' outside the window. PU, set down again, outside the window. Probably cuttings/clay ball from previous run. Kick on the pumps, and washed right thru it. Ran in smooth to 12054', set down. PU, ratty running in, set down at 12098'. PU, got thru it, but weight continued ratty to bottom. 20:25 - 20:40 0.25 DRILL N DPRB PROD1 Tag bottom at 12135', PU and getting overpulls and packing off. 2.4 in, 2.1 out. Slack off, pump to clean out debris. Printed: 6/9/2003 12:00:07 PM { (, BP EXPLORATION Operations Summary Report Page 7 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/23/2003 20:25 - 20:40 0.25 DRILL N DPRB PROD1 Returns back to 100%. Work up hole slowly. Getting motor work and partial packing off. Finally got free at 12070'. 20:40 - 21 :45 1.08 DRILL N DPRB PROD1 Wiper trip to window to clean up hole. Clean to window, while RIH got motor work and weight bobble at 11700' (shale). Motor work and weight bobble at 11970' (shale). Weight bobbles last 200' to TD. 21:45 - 22:10 0.42 DRILL N DPRB PROD1 Hole conditions continue to be poor from 11950' to bottom. Make 300' wiper to clean up problems. Did not get any packing off on this short trip. Some motor work and overpulls, but better than last trip off bottom. Better back to bottom. Ream 1 additional pass to help clean it up. 22: 1 0 - 22:20 0.17 DRILL P PROD1 Orient to high side tool face. 22:20 - 23:25 1.08 DRILL P PROD1 12135', Resume drilling. High side tool face. Pit Vol=252 bbls. Free spin=3050 psi. 2.7/2.7/3300 psi. ROP=60 fph. Going to 97 deg INC as per geo. Want to get up out of this shale asap. 23:25 - 23:35 0.17 DRILL P PROD1 12176', Orient to 90R to hold 97 degs. 23:35 - 00:00 0.42 DRILL P PROD1 Continue drilling. Midnight depth = 12200'. 5/24/2003 00:00 - 00:45 0.75 DRILL P PROD1 Continue drilling ahead from 12200'. 00:45 - 00:50 0.08 DRILL P PROD1 Take 1 click. 00:50 - 01 :30 0.67 DRILL P PROD1 Resume drilling. 01 :30 - 01 :40 0.17 DRILL P PROD1 Orient to 85R, trying to hold 94 deg INC. Pit vol=246 bbls. 01 :40 - 02:40 1.00 DRILL P PROD1 Resume drilling. Still in shale. Still drilling slow. No hole problems recently. 02:40 - 03:55 1.25 DRILL P PROD1 12285', Wiper trip to the window. Clean PU off bottom. Motor work and slight overpulls at 12140', 12095', 11680' while PUH. Motor work and set downs at 11700',12046',12086',12114', 12177' while RIH. Ratty from 12046' to TD. 03:55 - 04: 1 0 0.25 DRILL P PROD1 Orient to high side. 04:10 - 05:00 0.83 DRILL P PROD1 Drill ahead slowly in shale. 2.7/2.7/3050 free spin. Drilling at 3300 psi. Pit vol=241 bbls. IAP=2 psi, OAP=42 psi. 05:00 - 05:05 0.08 DRILL P PROD1 12321', PU to orient to hold angle. 05:05 - 05:35 0.50 DRILL P PROD1 Resume drilling. 05:35 - 05:45 0.17 DRILL P PROD1 12349', Take 1 click to the left. (Orient all the way around). 05:45 - 05:55 0.17 DRILL P PROD1 Resume drilling. Pit vol=235 bbls. 05:55 - 06:05 0.17 DRILL P PROD1 Drilling break. ROP picked up to 150 fph. Probably entering target sand at 97 deg. Orient to drop angle. 06:05 - 06:20 0.25 DRILL P PROD1 Resume drilling. 06:20 - 06:40 0.33 DRILL P PROD1 Orient to 70R. 06:40 - 07:30 0.83 DRILL P PROD1 Drill from 12391' w/ neg 10-15k wt 2.7/3060/75R and hold 94 deg. Drill to 12435' in 40-70 api sand from 12360'. PVT 233 07:30 - 08:30 1.00 DRILL P PROD1 Wiper. 6-10k overpulls at 12299',12147',12122'. Hung up at 12103' and work free going down. Backream w/ MW from 12150-12000' (this is in 4.25" hole). More overpulls in all shale intervals to 11630'. Hole is getting bad. Also, main objectves of perfable pay can not be met. So, Anchorage team convenes to decide how to get to the sweet spot now that they know where it is 08:30 - 08:50 0.33 DRILL P PROD1 Log tie-in down from 10685' 2.4/2700/169R. Add 6.0'. Flag at 10600' EOP 08:50 - 10:20 1.50 STKOH C PROD1 POOH for OH WS 10:20 - 12:00 1.67 STKOH C PROD1 LD drilling BHA. Download res data 12:00 - 12:15 0.25 STKOH C PROD1 MU WI! 3.5" OH WS assy 12:15 -14:10 1.92 STKOH C PROD1 RIH w/ BHA #8 Printed: 6/9/2003 12:00:07 PM { f BP EXPLORATION Operations Summary Report Page 8 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/24/2003 14:10 - 14:20 0.17 STKOH C PROD1 Corr at flag -7.8', RIH 14:20 - 15:20 1.00 STKOH C PROD1 Set down 6k at 11073', PUH 50' w/1 Ok over and lost whatever was grabbing. RIH, clean to 11095' and 6k set down. PUH clean. Set down at 11106',11107',11113', etc on assumed clay. Work to 11167' (bottom of lows ide ramp) and no more progress 15:20 - 17:10 1.83 STKOH X DPRB PROD1 POOH w/ WS filling from BS PVT 220 17:10 - 17:40 0.50 STKOH X DPRB PROD1 LD WS assy. Slips and other recesses were packed with clay. Load out to WII shop for inspection 17:40 - 18:45 1.08 BOPSURC PROD1 Weekly BOPE test. Witness waived by AOGCC, Chuck Sheve. 18:45 - 18:50 0.08 BOPSURX SFAL PROD1 Master valve leaking. Call for EOA grease crew to grease master valve. 18:50 - 19:10 0.33 BOPSURC PROD1 Safety meeting to discuss mechanical work and pressure testing during night tour. 19:10 - 19:40 0.50 BOPSURX SFAL PROD1 Wait on grease crew. 19:40 - 23:25 3.75 BOPSURC PROD1 Grease crew greased master valve. Holds pressure fine. Continue with BOP test. 23:25 - 00:00 0.58 BOPSURC PROD1 MU swizzle stick nozzle to coil tubing. Jet stack to clean debris, cement cuttings, etc from stack. 5/25/2003 00:00 - 01 :00 1.00 STKOH X DPRB PROD1 Make up BHA #9 for cleanout run prior to setting whipstock. BHA; DS 49 bit, 1.04 deg mud motor, Sperry GR-Directional package. 01 :00 - 02:55 1.92 STKOH X DPRB PROD1 RIH with BHA #9, C/O BHA. Check orienter and MWD at 3200', 02:55 - 03:10 0.25 STKOH X DPRB PROD1 Make tie in pass down from 10670'. Make -5.5' correction. 03:10 - 04:00 0.83 STKOH X DPRB PROD1 RIH slowly looking from mud balls and junk left from the first whipstock attempt. The first run with the WS left a 1/2 bagel sized chunk of hard rubber in the hole. RIH from 10912', top of pilot hole at 20 fpm, pumping 2.7 bpm. Slow to 10 fpm at 11155', set down at 11182'. PU clean, set down again same depth. Drop pumps to 1.4 bpm to prevent damaging ramp. RIH, tagged up at 11186', PU and fell thru. Outside window bring pumps up to 2.7 bpm, RIH at 10 fpm. Set down at 11247' (shale), 11260', 11385'. Constant weight bobbles below 11247', like we are pushing junk ahead of us. 04:00 - 04:50 0.83 STKOH X DPRB PROD1 Backream to the tubing tail, chasing any clay ahead of us OOH. 04:50 - 05:40 0.83 STKOH X DPRB PROD1 RIH, to confirm clean out. Tag up solid with motor work at 11015' (???). PU clean, RIH again and got thru it. Tag up at 11015',11028',11039',. We appear to be pushing some sort of junk down hole. Cement from pilot hole cement sheath perhaps? Continue RIH at 10 fpm. Dropped pump rate thru window, went thru slick. Continue RIH at 10 fpm. Clean in open hole to 11500'. 05:40 - 06:20 0.67 STKOH X DPRB PROD1 Cleanout back to tubing tail. Clean PU off bottom in open hole and to tubing tail. 06:20 - 07: 1 0 0.83 STKOH X DPRB PROD1 Run back in hole at 1 OL at min rate thru pilot hole. Set down at 11034' and work to 11058' before stacking 10k. Backream to top of pilot, clean. RIH at 10L at min rate, clean thru pilot and window. Ream OH to 11450', clean 07: 10 - 07:45 0.58 STKOH X DPRB PROD1 Backream to EOT, clean Printed: 6/9/2003 12:00:07 PM (- ( BP EXPLORATION Operations Summary Report Page 9 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/25/2003 07:45 - 08:15 0.50 STKOH X DPRB PROD1 RIH at 90R at min rate thru pilot hole and window, clean. Ream OH to 11450' 2.7/3080/90R 08: 15 - 08:45 0.50 STKOH X DPRB PROD1 Backream to EOT, clean 08:45 - 09: 15 0.50 STKOH X DPRB PROD1 RIH at 100L at min rate thru pilot hole and window, clean. Ream OH to 11450' 2.7/3150/90L 09: 15 - 09:45 0.50 STKOH X DPRB PROD1 Backream to EOT, clean. Flag CT 09:45 - 11 :25 1.67 STKOH X DPRB PROD1 POOH chasing solids to surface 11 :25 - 12:00 0.58 STKOH X DPRB PROD1 LD drilling BHA 12:00 - 12:15 0.25 STKOH X DPRB PROD1 MU WI! 3.5" OH WS assy 12:15 -14:15 2.00 STKOH X DPRB PROD1 RIH w/ BHA #10 14:15 -14:45 0.50 STKOH X DPRB PROD1 Corr -6.0' at 10685', RIH. Clean thru pilot and window. Set down on shale/sand ledge at 11363'. Make 6 attempts to get by and solid. PUH 42k to alternate spot at 11310' (which keeps us above all shales and between cherty areas. Also allows for a 1.69 deg motor vs 2.0 deg. However, first good survey wasn't seen until 11325') 14:45 - 15:30 0.75 STKOH C PROD1 Load 1/2" steel ball. Circ to seat with mud 2.0/2820. Ball on seat at 51.6 bbls. Pressure to 4000 psi to stroke and start set. PUH til free and circ. RIH and stack 6k, solid. TOWS @ 11310' 15:30-17:15 1.75 STKOH C PROD1 POOH w/ setting tool 17:15 -17:35 0.33 STKOH C PROD1 LD/load out WI! setting tool 17:35 - 18:05 0.50 STKOH C PROD1 MU drilling BHA (1.69 deg motor) 18:05 - 18:45 0.67 STKOH C PROD1 RIH w/ BHA #11 18:45 - 20:00 1.25 STKOH C PROD1 Shallow hole test of MWD and orienter at 3200', passed ok. Continue RIH. IAP=O, OAP=27 psi. Pit vol=150 bbls. 20:00 - 20: 15 0.25 STKOH C PROD1 Log tie in pass down from 10670'. Make -7' correction. 20:15 - 20:35 0.33 STKOH C PROD1 RIH. Slick in pilot section and thru window. Tag up at top of whipstock right on depth. 20:35 - 20:45 0.17 STKOH C PROD1 Orient to 20L tool face. 20:45 - 00:00 3.25 STKOH C PROD1 Sidetrack off of open hole aluminum whipstock billet at 11309'. Free spin 3170 psi @ 2.6 bpm. Sidetracking at 2.6/2.6/3250 psi. Pit vol=202 bbls. TF=31 L. Time drilling at 2 f/hr to get off. Midnight depth = 11312.5'. 5/26/2003 00:00 - 02:05 2.08 STKOH C PROD1 11312.5', Continue OH sidetrack from 11312.5'. Free spin=3160 @ 2.6 bpm. Sidetracking @ 2.6/2.6/3300 psi. TF=31 L. Pit vol=202 bbls. 02:05 - 02:45 0.67 STKOH C PROD1 11315.5', Drilling break, Exited ramp of OH whipstock. Drill ahead at 15 fph. Ramp of whipstock is 11309'-11315.5' for a 6.5' ramp. Drill ahead until sidetrack is confirmed on MWD. 02:45 - 02:50 0.08 STKOH C PROD1 11327', Get a click. 02:50 - 02:55 0.08 STKOH C PROD1 Resume drilling. TF=20L, Pit vol=203 bbls. 02:55 - 03: 15 0.33 STKOH X SFAL PROD1 11330', Swivel on SWS coil failed. Bearing appears to be coming apart. PUH to safety. Call Deadhorse shop for parts. 03:15 - 04:20 1.08 STKOH X SFAL PROD1 Park at 10860', wait on repairs to coil tubing swivel. 04:20 - 04:30 0.17 STKOH X SFAL PROD1 Replace reel swivel. PT to 4500 psi. Passed ok. Run back in hole to complete sidetrack. 04:30 - 04:35 0.08 STKOH C PROD1 Orient to 20L. 04:35 - 05:00 0.42 STKOH C PROD1 RIH to start drilling. Set down at 11315'. PU, RIH pumps down. Set down again same depth. PU, RIH slowly pumps down. Set down again. Kick pumps on. TF= 20L. RIH slow and ream out tight spot. Continue to bottom. Free spin 3200 Printed: 6/9/2003 12:00:07 PM ( ( BP EXPLORATION Operations Summary Report Page 10 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/26/2003 04:35 - 05:00 0.42 STKOH C PROD1 psi at 2.6 bpm. Pit vol = 202 bbls. 05:00 - 06:55 1.92 STKOH C PROD1 11335', DD confirms that we have exited the old wellbore. Back ream sidetrack at 20L, 13R, 70L, from TD to 11300'. Backream thru window and pilot 06:55 - 08:45 1.83 STKOH C PROD1 POOH for bi bit. Grease swivel during trip 08:45 - 09:20 0.58 STKOH C PROD1 Change bit, chk motor and orientor 09:20 - 11 :20 2.00 DRILL C PROD1 RIH w/ BHA #12 (1.69 deg motor) 11 :20 - 11 :40 0.33 DRILL C PROD1 Log tie-in down from 10670' 2.4/2960/1 OL. Corr -6' 11:40 - 12:05 0.42 DRILL C PROD1 RIH and tag TD at 11336.2' 12:05 - 14:15 2.17 DRILL C PROD1 Drill from 11336' 2.6/3000/20L to 11400' 14:15 - 14:35 0.33 DRILL C PROD1 Orient around 14:35 - 15:20 0.75 DRILL C PROD1 Drill from 11400-479' 2.6/3040/90L in a good sand 15:20 - 15:35 0.25 DRILL C PROD1 Wiper to 11190' 15:35 - 15:55 0.33 DRILL C PROD1 Orient around 15:55 - 16:55 1.00 DRILL C PROD1 Drill from 11479' 2.6/3050/128L to 11527' 16:55 - 17:25 0.50 DRILL C PROD1 Wiper to EOT 17:25 - 18:55 1.50 DRILL C PROD1 POOH for motor bend (1.69 deg requires too much orienting and will give too many zig/zags) 18:55 - 19:45 0.83 DRILL C PROD1 Tag up at surface with BHA #12. PU, inspect bit. Bit in good shape, graded 1,1. Adjust motor to 1.37 deg. 19:45 - 21 :45 2.00 DRILL C PROD1 RIH with BHA #13. Hughes 3.75"x4.125" bi center bit, 1.37 deg motor. GR-Directional MWD package. Shallow hole test of orienter and MWD at 3200' passed ok, continue RIH. 21:45 - 21 :55 0.17 DRILL C PROD1 Log tie in pass in down. Make -8' correction. 21 :55 - 22:15 0.33 DRILL C PROD1 RIH 22: 15 - 22:30 0.25 DRILL C PROD1 Orient to 85R. 22:30 - 23:50 1.33 DRILL C PROD1 11529', Begin drilling. Free spin=31 00 psi at 2.7 bpm. Drilling at 2.7/2.7/3360 psi. Pit vol=116 bbls, currently swapping to new 9.2#/g mud, with 14#/bbl Kla-gard. Drilling to hold angle of 83 deg as per latest drilling plan for sidetrack. IAP=O, OAP=24 psi. ROP=56 fph. 23:50 - 23:55 0.08 DRILL C PROD1 11598', Orient to straight down. 23:55 - 00:00 0.08 DRILL C PROD1 Drill ahead. Midnight depth = 11610'. 5/27/2003 00:00 - 00:15 0.25 DRILL C PROD1 11613', Orient around to 90R. 00:15 - 01 :20 1.08 DRILL C PROD1 Resume drilling. IAP=O, OAP=24 psi. Pit vol=Taking on mud, Drilling at 2.7/2.7/3300 psi. Free spin is 3200 psi (New thick, heavy mud) 01 :20 - 01 :25 0.08 DRILL C PROD1 11682', TF walking up to the left. Take a couple of clicks. 01 :25 - 01 :45 0.33 DRILL C PROD1 Resume drilling TF=90R, ROP=120 fph. 01 :45 - 02:20 0.58 DRILL C PROD1 11700', Wiper trip to shoe. Clean PU off bottom. Did not ream thru OH whipstock area. Weight bobble when running back down with pumps down. 02:20 - 03:20 1.00 DRILL C PROD1 Resume drilling. 2.7/2.7/3560 psi. 306 bbls pit vol, still taking on fluid. 03:20 - 04:35 1.25 DRILL C PROD1 Fluid transfer is completed, pit volume=327 bbls. Continue drilling ahead according to current plan. 04:35 - 04:45 0.17 DRILL C PROD1 11825', Orient to 90L. 04:45 - 05:05 0.33 DRILL C PROD1 Resume drilling. 2.7/2.7/3400 psi. Pit vol=324 bbls. 05:05 - 05:30 0.42 DRILL C PROD1 Wiper trip. Clean PU off bottom. Did not ream thru OH whipstock area. Clean to shoe. RIH tagged up at top of OH whipstock with pumps down. PU, set down at bottom of WS this time. PU again above WS and orient 05:30 - 06: 15 0.75 DRILL X DPRB PROD1 RIH, tagged up on top of OH whipstock with pumps down. PU, Printed: 6/9/2003 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ," ~ ( Page 11 of 19 BP EXPLORATION Operations Summary Report 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 5/27/2003 05:30 - 06: 15 From - To Hours Task Code NPT Phase DPRB PROD1 06:15 - 06:35 06:35 - 06:45 06:45 - 07:00 07:00 - 07:15 07:15 - 07:30 07:30 - 09:05 09:05 - 09:25 09:25 - 10:20 10:20 - 10:50 10:50 -11:10 11:10-11:30 11 :30 - 12:35 12:35 -13:10 13:10 - 13:35 13:35 - 14:15 14:15 - 14:55 14:55 -15:15 15:15 -15:35 15:35 - 15:45 15:45 - 16:05 16:05 -16:15 16:15 -16:40 16:40 - 16:45 16:45 - 17:05 17:05 - 17:50 17:50 - 18:10 18:10 - 19:00 0.75 DRILL X 0.33 DRILL X 0.17 DRILL C 0.25 DRILL C 0.25 DRILL C 0.25 DRILL C 1.58 DRILL C 0.33 DRILL C 0.92 DRILL C 0.50 DRILL C 0.33 DRILL C 0.33 DRILL C 1.08 DRILL C 0.58 DRILL C 0.42 DRILL C 0.67 DRILL C 0.67 DRILL C 0.33 DRILL C 0.33 DRILL C 0.17 DRILL C 0.33 DRILL C 0.17 DRILL C 0.42 DRILL C 0.08 DRILL C 0.33 DRILL C 0.75 DRILL C 0.33 DRILL C 0.83 DRILL C DPRB PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Description of Operations set down at bottom of WS this time. PU above WS, kicked pumps on and found TF=O deg. (Original side track was made at a TF from 21 L to 30L). Set down again with pumps down. Hung up at top, them bounced thru, but hung up at bottom of WS. PU, orient to 59L. RIH with pumps at 0.5 bpm to hold tool face. Hung up at top, bounced thru, then hung up at the bottom. PU, repeat still hung up. PU, kick pumps on, take one more click. TF=39L. RIH at 0.5 bpm. Set down 4 times at varous speeds. Some times hang up at top, sometimes make it thru, but never past bottom of WS. PU, take another click. TF now at 43R. Orient back around to 20L. Try it again and set down at 11315' (assume a clayball below WS) Wiper to tie-in Log tie-in down from 11370' 2.5/2860/55R. Add 6.0' RIH. Chk TF at 11300' and 14R Orient around RIH at min rate at 24L and set down at 11321'. Ream from stall at 11316' at 24L to get by. Stall at 11317.5'. RIH clean from 11319' to TO tagged at 11854' 72R Orient around to left Drill from 11854' 2.7/3150/11 OL to 11900' Slow wiper while wo geo to decide to continue at 81 deg or level out. Orient to HS Drill from 11900-938' 2.7/3130/7L Orient around Drill from 11938' 2.7/3130/90L at 88 deg. Drill to 12005' Wiper to window. 10k overpull at 11430' and at OH WS at 11305' RBIH to 11300' at 109L. Orient to 45L. RIH at min rate by WS and a little rough. Precautionary ream from 11330'. Set down at 11550' at 11 OL. Orient to drilled TF of 90R and ream by w/ no motor work. RIH to TO Orient around (twice) Drill from 12005' 2.7/3150/90L 12056', Encountering shale. Some uncertainty of where the 13N is expected. Want to cut the 13N sharply to minimize exposure to it. Orient to low side to achieve this. Resume drilling. 2.7/2.7/3533 psi. Free spin 3100 psi. Pit vol=312 bbls. IAP=O, OAP=27 psi. 12075', Orient to 90L. Resume drilling. Orient to hold angle. Resume drilling. 2.7/2.7/3430 psi. Pit vol=310 bbls. 12137', Take a click. Resume drilling. 12158', Wiper trip to shoe. Motor work and overpull coming thru whipstock. On way back down set down on OH whipstock at 11311'. (top of the whipstock.) Set down a couple of times. Then PU to orient. Orient to 45L. Ream down thru whipstock area using same technique as on last wiper. Made it thru easily. Printed: 6/9/2003 12:00:07 PM ( ,I" ~ BP EXPLORATION Operations Summary Report PROD1 RIH to TD with no problems. PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 82 deg inc, 50 fph. Drilling shales. Drilled to 12,200'. PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 82 deg inc, 50 fph. Orient to 10L at 12,220'. Drilled to 12274' with high side TF. Est. 90 deg incl at bit. PROD1 Orient TF to 80L. Clean pick up off bottom. PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 91 deg inc, 30-100 fph. Drilling shales / sand. Drilled to 12,310'. PROD1 Wiper trip up to 10650'. Motor work at 12010'. Clean up thru OH whipstock and window. PROD1 Log tie-in with GR at 10651'. Added 6 ft to CTD. PROD1 RIH. Went thru window with no weight loss. Stacked wt at OH whipstock. Orient TF to 50L and RIH. Reamed from 12050-12100'. RIH OK to TD. PROD1 Drilling, 3000-3500 psi, 2.5/2.5 bpm, 75L TF, 92.5 deg incl, Drilled to 12,407'. Stacking wt. Start swap to new 9.3# FloPro system at 12,407'. Had 880' on old FloPro. Drilling, 3100-3500 psi, 2.5/2.5 bpm, 80L TF, 92 deg incl, Up WT. = 39K, Dwn WT. = 18K. Drilled to 12,448'. Orient TF. Drilling, 3200 - 3600 psi, 2.6/2.6 bpm, Orient to hold horizontal. IAP=O, OPA=O, Pit vol=Taking on mud. Drilling ahead. 12500', POOH to pick up DS49, and to cut pipe to move wear spot on coil. Tag up at surface. Hughes bit graded 7,2. It was ringed out on the pilot section. Lay down drilling BHA. Change out motor. Motor would not drain when blown down with air. One jet on bit was plugged with rubber. PJSM prior to cutting coil tubing. Cut 300' of coil tubing. Change packoffs, Rehead. Pull test CTC to 35000 Ibs, PT to 3500 psi. MU BHA #14. New Hycalog DS49 bit, New motor, New orienter. Same MWD - GR as BHA #13. RIH with BHA #14. Shallow hole test of orienter and MWD at 3200' passed ok. Log tie in pass down from 10670'. Make -5' correction. RIH. RIH made it thru window slick. Checked tool face below window, found at 20R. Pumps to minimum rate. Try running thru OH whipstock. Bounced at the top and bottom, but fell thru ok. continue RIH. Orient to 90R. IAP=O, OAP=22, Pit vol=306 bbls. Free spin=3000 psi. Begin drilling. TF=85R, ROP=84 fph. 12511', Check shot to repeat survey from previous run. Orient to high side to correct dip in INC. Trying to hold horizontal as per plan. Drilling, 2.6/2.6 bpm, 3100 - 3700 psi, 60R TF, 89 deg incl, Stacking wt. Slow drilling, Drilled to 12,538'. Not finding any Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase 5/27/2003 18:10 - 19:00 19:00 - 20:40 0.83 DRILL C 1.67 DRILL C 20:40 - 22:50 2.17 DRILL C 22:50 - 23:20 0.50 DRILL C 23:20 - 00:00 0.67 DRILL C 5/28/2003 00:00 - 01 :00 1.00 DRILL C 01 :00 - 01 :20 0.33 DRILL C 01:20 - 02:10 0.83 DRILL C 02:10 - 04:00 1.83 DRILL C 04:00 - 05:40 1.67 DRILL C PROD1 05:40 - 06:00 0.33 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 06:45 0.25 DRILL P PROD1 06:45 - 07:05 0.33 DRILL P PROD1 07:05 -10:15 3.17 DRILL P PROD1 10:15-11:10 0.92 DRILL P PROD1 11:10-11:25 0.25 DRILL P PROD1 11 :25 - 13:30 2.08 DRILL P PROD1 13:30 - 14:55 1.42 DRILL P PROD1 14:55 - 16:45 1.83 DRILL P PROD1 16:45 - 17:00 0.25 DRILL P PROD1 17:00 - 17:45 0.75 DRILL P PROD1 17:45 - 18:00 0.25 DRILL P PROD1 18:00 -18:10 0.17 DRILL P PROD1 18:10 -18:30 0.33 DRILL P PROD1 18:30 - 18:40 0.17 DRILL P PROD1 18:40 - 20:20 1.67 DRILL P PROD1 Page 12 of 19 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Description of Operations Printed: 6/9/2003 12:00:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/28/2003 5/29/2003 ( ( BP EXPLORATION Operations Summary Report Page 13 of 19 02 -05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 From - To Hours Task Code NPT Phase Description of Operations 18:40 - 20:20 1.67 DRILL P PROD1 sand in last 150', Geo's decided to drill at 98 deg incl. looking for sand. 20:20 - 23: 15 2.92 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3100 - 3700 psi, 5L TF, 95 deg incl, Stacking wt in shales. Drilled to 12,625'. 23: 15 - 00:00 0.75 DRILL P PROD1 Wiper trip to 11325'. Clean trip out. Hole in good condition. 00:00 - 01 :00 1.00 DRILL P PROD1 RIH to TD. Stacked wt at one spot at 12,270'. RIH OK to TD. Good hole conditions. 01 :00 - 03:00 2.00 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100-3400 psi, 80R TF, 99 deg incl, Stacking wt in shales, very slow drilling before and after wiper trip. Drilled to 12,655'. 03:00 - 04:45 1.75 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000-3400 psi, 120R TF, 96 deg incl, Stacking wt in shales, Drilled to 12,698'. 04:45 - 05: 1 0 0.42 DRILL P PROD1 Orient around to 85R. 05:10 - 06:00 0.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000-3400 psi, 80R TF, 96 deg incl, Stacking wt in shales, Drilled thru 250 API shale at 12670', 1 OK overpull in shale. Ream shale at 12.670'. Drilled to 12,703'. 06:00 - 06:55 0.92 DRILL P PROD1 12703', Make 70' wiper. Can't get back to bottom. Setting down at 12670', motor work. Yuck. Decide to do wiper trip while Geo's talk to town. Overpull coming thru OH sidetrack at 11305'. 06:55 - 07:05 0.17 DRILL N STUC PROD1 Stuck at OH whipstock at 11305'. Work up and down. Finally got free going down. Orient to 45L. Work up hole slowly. Finally go thru OH whipstock. Definately starting to talk to us. 07:05 - 07:50 0.75 DRILL P PROD1 Continue wiper trip to Tubing tail. 07:50 - 08:10 0.33 DRILL P PROD1 Log tie in pass down over GR charecter at 10651'. Make +10' correction. 08: 1 0 - 08:20 0.17 DRILL P PROD1 RIH to resume drilling. Try running thru window at 20R, with pumps at minimum. Can't get thru. 08:20 - 09: 15 0.92 DRILL N DPRB PROD1 Tag up 2 times on OH whipstock at 20R. Orient around to 59L. RIH dry. Can't get thru it 2x. Orient 1 more time. TF=45L. Try it at minimum rate. Can't get thru. Orient to 18L, Ream down slowly thru it. Tag up at 11311', and stall at top of whipstock. PU, ream down slow. Stall at 11310'. Repeated a total of 7 times, stalling each time. PU, SI pumps, made it past the top at 11310', set down at 11317'. PU weight and slingshot back in w/o picking up past WS top. Set down 3 times, finally got thru on 3rd attempt. Wooooeeee, getting hard to get thru here. We are going to have to clean this up before tripping OOH to have any chance at all of getting liner to bottom. 09:15 - 09:50 0.58 DRILL P PROD1 Continue trip in hole. Clean down to 12675', set down. 09:50 - 10:00 0.17 DRILL P PROD1 Ream shale from 12670' to TD at 12704'. 10:00 - 10:05 0.08 DRILL P PROD1 Orient to 45R to maintain our build up into the 14P. 10:05 - 11 :00 0.92 DRILL P PROD1 12704', Drill ahead. 2.7/2.7/3330 psi. Pit vol=277 bbls. Free spin=3100 spi at 2.6 b/m. 11 :00 - 11 :05 0.08 DRILL P PROD1 11729', Orient to 85R. 11 :05 - 11 :40 0.58 DRILL P PROD1 Resume drilling. 11 :40 - 11 :45 0.08 DRILL P PROD1 Orient to drop angle to 92 degrees. Plan to hold angle in this 14P sand for as long as possible. 11 :45 - 12:00 0.25 DRILL P PROD1 12764', Try to resume drilling. Having to snub to maximum to get back to drilling. Have mud man add 4 more drums, 0.75% Printed: 6/9/2003 12:00:07 PM ( ( BP EXPLORATION Operations Summary Report Page 14 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/29/2003 11 :45 - 12:00 0.25 DRILL P PROD1 lubetex to system. Now at 3% lubetex and 2.25% Flo-Lube in system. Make mini wiper to clean up hole 12:00 - 12:35 0.58 DRILL N DPRB PROD1 Attempt to drill ahead. Can't get a bite. Having trouble getting weight to bit. May be time for the agitator tool. Work with it 12:35 - 12:40 0.08 DRILL N DPRB PROD1 Tool face flopped over to 90L. Orient around. 12:40 - 12:50 0.17 DRILL N DPRB PROD1 Attemp to drill ahead. Can't get it to drill. Not getting any overpull, just can't enough push. Note - Geo reports aluminum chips in the last cuttings sample. Probably were generating them when we made that like wiper trip. 12:50 - 14:15 1.42 DRILL N DPRB PROD1 Can't get weight transfer. Wiper trip up to the OH WS. Clean PU off bottom. Ratty up thru the shales at 12670', gradually better above there. Cleaned up at about 12000'. On way back in hole clean until 12685'. Set down several times, had problems getting to bottom. 14:15 - 14:20 0.08 DRILL N DPRB PROD1 12764', attempt to resume drilling. We are at coil lock up. Need to reduce friction to be able to drill ahead. 14:20 - 17:15 2.92 DRILL P PROD1 POOH to pick up agitator tool. TF=23R, went pumps to minimum, and pulled thru OH whipstock slick. 17:15-18:30 1.25 DRILL P PROD1 Tag up at surface. Stand back injector. Check bit, graded 1,1. Check orienter, looked ok. Install Agitator tool. Cut coil connector. Install Baker CTC. Pull test to 35 klbs, PT to 3500 psi. 18:30 - 20:30 2.00 DRILL P PROD1 RIH with 1.37 deg motor, DS49 Bit and Andergauge Vibration tool. 20:30 - 21 :00 0.50 DRILL P PROD1 Log tie-in at 10651'. [-5 ft CTD] 21 :00 - 21 :20 0.33 DRILL P PROD1 RIH thru window with no wt loss. Orient TF to get past OH Whipstock. Went thru OHW with small wt loss at 45R. 21 :20 - 22:10 0.83 DRILL P PROD1 RIH to TD at 40 fpm, 2.0 bpm, 2700 psi. Clean hole. Stacked some wt at shales at 12600 and 12680'. Tagged Td at 12,760'. 22: 1 0 - 22:40 0.50 DRILL P PROD1 Drilling, 2.4/2.4 bpm, 3670 - 4500 psi, 135L, Good wt transfer, 17K dwn wt off bottom, 39 K up wt. Drilling with agitator tool in BHA. 60-100 fph, Positive 14K wt while drilling. Drilling very well. Drilled to 12,798'. 22:40 - 22:45 0.08 DRILL P PROD1 Orient to 90L. 22:45 - 23:00 0.25 DRILL P PROD1 Drilling, 2.4/2.4 bpm, 3670 - 4500 psi, 80L, Good wt transfer, 100 fph. Drilled to 12,819'. 23:00 - 23:20 0.33 DRILL P PROD1 Orient to 90L. 23:20 - 00:00 0.67 DRILL P PROD1 Drilling, 2.4 / 2.4 bpm, 3670 - 4500 psi, 80L, Good wt transfer, 80-100 fph. Drilled to 12,862'. 5/30/2003 00:00 - 00:20 0.33 DRILL P PROD1 Orient TF to 100L. 00:20 - 01:10 0.83 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3750 - 4600 psi, 100L, 40-80 fph, 92 deg incl. Drilled to 12,915' 01:10 - 04:00 2.83 DRILL P PROD1 Wiper trip to 11325'. Some overpulls and motor work th ru shales. RIH. Stack full wt at 12670'. RIH past shale with no pump and back ream. RIH and Stack wt again. Ream shale. RIH to TD OK. 04:00 - 04:50 0.83 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3750 - 4600 psi, 120L, 40 fph, 91 deg incl. Drilled to 12,940'. Swap to new 9.3# FloPro at 12,940', 533' drilled with old FloPro. Printed: 6/9/2003 12:00:07 PM ) ) BP EXPLORATION QperationsSu mmaryReport Page 15 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/30/2003 04:50 - 05:30 0.67 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3750 - 4600 psi, 90L, 40 fph, 88 deg incl. 14K up wt while drilling. Drilled to 12,960'. 05:30 - 06:30 1.00 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3750 - 4600 psi, 40L, 80 fph, 88 deg incl. 12K up wt while drilling. Drilled to 12,990'. 06:30 - 06:45 0.25 DRILL P PROD1 13005', Orient to 90R for a right side wigwag. 06:45 - 07:35 0.83 DRILL P PROD1 Drill ahead. Good weight transfer with the Agitator tool. Free spin = 3700 @ 2.5 bpm.. Drilling at 2.5/2.5/3950 psi. TF=90R. 07:35 - 07:45 0.17 DRILL P PROD1 13073', PU for off bottom survey. 07:45 - 09:30 1.75 DRILL P PROD1 13073', Wiper trip to Tubing Tail. Slight overpulls at 12670'. Slight overpull at OH WS when running thru with pumps down. No problem thru window to tubing tail. 09:30 - 09:50 0.33 DRILL P PROD1 Log tie in pass down over GR charecter at 10651'. Make +19' correction. 09:50 - 10:05 0.25 DRILL P PROD1 Orient to 45L to run thru OH WS. Dropped pump rate to minimum and ran thru WS ok. 10:05 - 11 :00 0.92 DRILL P PROD1 Continue back in hole. Set down at 12680', PU and tried it dry. Made it thru on second attempt. 11 :00 - 11 :20 0.33 DRILL P PROD1 13084', Resume drilling. Free spin 3650 psi at 2.5 bpm. Drilling at 2.5/2.5/3870 psi. TF=173 left to adjust INC to 90 deg. Drilling agead at 100 fph, The Agitator tool is continuing to work very well! String weight = positive 10,000 Ibs. 11:20-11:30 0.17 DRILL P PROD1 13100', Orient to 80R to maintain INC at 90 deg. 11:30-12:00 0.50 DRILL P PROD1 Resume drilling. 12:00 - 12:05 0.08 DRILL P PROD1 13129', take a click. 12:05 - 12:45 0.67 DRILL P PROD1 Resume drilling. 12:45 - 12:55 0.17 DRILL P PROD1 13149', Loosing mud 0.2 bbl/min. Pit vol=311 bbls. Driller reported large reactive tool faces at 13040'. Possibly crossed a fault. PU and take 2 clicks. 12:55 - 13:30 0.58 DRILL P PROD1 Resume drilling. 13:30 -14:05 0.58 DRILL P PROD1 13165',2.5/2.3/3960 psi. Pit vol=301 bbls. 14:05 - 14:25 0.33 DRILL P PROD1 13187', Orient around, and make a 100' wiper trip. 14:25 - 14:55 0.50 DRILL P PROD1 Resume drilling. 14:55 - 15:00 0.08 DRILL P PROD1 13,192', PU off bottom. Stuck. Work pipe. Pulled max and got free. 15:00 - 15:45 0.75 DRILL P PROD1 Wiper trip to OH WS. Ratty thru shale at 12670'. Pit vol=293 bbls. 15:45 - 16:15 0.50 DRILL N DFAL PROD1 12270', while POH the MWD tool shut down. Cycling pumps can't get it to restart. 16:15 - 18:25 2.17 DRILL N DFAL PROD1 POOH to replace MWD tool. Pumps down thru OH WS, and no overpulls. Slick thru window. 18:25 - 19:30 1.08 DRILL N DFAL PROD1 Tag up at surface. Change out MWD probes. Check bit, motor, and orienter, all OK. Bit had no chipped cutters. [1,1,1]. 19:30 - 22:00 2.50 DRILL N DFAL PROD1 RIH with MWD / Vibrator BHA, 1.37 deg motor and DS49 Bit. Shallow test MWD and Vibrator - OK. RIH. 22:00 - 23:00 1.00 DRILL P PROD1 Ran thru window and OH whipstock with no wt loss. RIH. Sat down in shale at 12680' and fell thru OK. RIH. Tag TD at 13200 ft and correct depth to 13,192 ft. 23:00 - 23:20 0.33 DRILL P PROD1 Orient TF to 90R. 23:20 - 00:00 0.67 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3700 - 4500 psi, 89 deg incl, 80R TF, Drilled to 13,220'. 5/31/2003 00:00 - 00:45 0.75 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3750 - 4500 psi, 80R, 88 deg incl, Drilled to 13,245 ft. Stacking wt. Printed: 6/9/2003 12:00:07 PM ) ) BP EXPLORATION Operations Summary Report Page 16 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From- To Hours Task Code NPT Phase Description of Operations 5/31/2003 00:45 - 02:45 2.00 DRILL P PROD1 Wiper trip to 12650'. Back reamed shale at 12670' with minimal motor work. RIH and stack wt on shale with several TF. Finally bounced thru at 170R TF. RIH stack wt on shale at 13150'. Ream down. Stack wt on shale at 13,200'. Ream down. RIH to TO. Sliding CT at this depth is getting very difficult. 02:45 - 03:30 0.75 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3900 - 4500 psi, 80R, 91 deg incl. Drilled to 13,274'. 03:30 - 04:50 1.33 DRILL P PROD1 Drilling, 2.5 / 2.5 bpm, 3900 - 4600 psi, 110R, 91 deg incl. Drilled to 13,346'. 04:50 - 05:45 0.92 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3900 - 4600 psi, 120R, 90 deg incl. Drilled to 13,392'. Called TO at 13,392'. 05:45 - 06:55 1.17 DRILL P PROD1 POH. Back ream shales at 5-10 fpm. 39K up wt. 06:55 - 07:25 0.50 DRILL P PROD1 12500', had overpulls on last ream up thru shales 12500-12800. RIH thru shales and back ream them again. 07:25 - 08:45 1.33 DRILL P PROD1 Wiper up to OH WS, no problems. Pumps down, TF=17R. Pull up thru WS no problems coming up. RIH with pumps at minimum, no problems. Pull up thru it, no problems. Continue wiper trip. No problems thru window, PUH to TTail at 80%. 08:45 - 09: 1 0 0.42 DRILL P PROD1 Log tie in pass down over GR character at 10651 '. Make at +17' correction. This adjusts TO to 13409'. 09: 1 0 - 11 :45 2.58 DRILL P PROD1 Both Co men confer and agree on advisability of making another trip to bottom, or just POH to pick up pipe. Hole is as clean now as we can expect it to get. Further wipers will not improve situation. POH to pick up liner. Painted EOP flags at 1 0200', 8000'. 11:45 - 12:00 0.25 DRILL P PROD1 Tag up at surface. Hold safety meeing prior to laying down BHA and installing new CTC. 12:00 -12:15 0.25 DRILL P PROD1 Lay down BHA. No apparent damage or flat spotting on BHA from Agitator tool run. Bit was recovered at 1,2,1. 12:15 - 14:00 1.75 DRILL P PROD1 Cut CTC off. Install new CTC. Pull test to 35klbs, PT to 3500 psi. Passed ok. Pump dart thru coil. Landed at 58.5 bbls. Current coil length is 15200'. 14:00 - 14:20 0.33 CASE P COMP Safety meeting with all rig hands, Baker rep, 2 BP Co Reps. Discuss running liner. Safety joint, hazards, mitigation. 14:20 - 14:50 0.50 CASE P COMP Arrange rig floor. PU Baker eq. Prep to run liner. 14:50 - 18:00 3.17 CASE P COMP Run 2-7/8" x 3-3/16" liner as per revised procedure. 18:00 - 18:20 0.33 CASE P COMP Shut down for crew change and pre tour safety meeting. Fill pipe while holding meeting. 18:20 - 19:45 1.42 CASE P COMP Continue running liner 19:45 - 20:00 0.25 CASE P COMP SAFETY MEETING. Review procedure, hazards and mitigation to M/U BKR CTLRT. 20:00 - 20:30 0.50 CASE P COMP M/U BKR CTLRT. Liner length = 3113 ft. Liner running tools = 9.2 ft. Total length = 3,122.2 ft. 20:30 - 21:45 1.25 CASE P COMP RIH with Liner on CT. RIH to 11,100'. Up Wt = 44.5K, Own wt = 21 K. Ran thru window and past open hole Whipstock with no wt loss. 60 FPH, 0.3 bpm, 120 psi. 21 :45 - 23:00 1.25 CASE P COMP Sat down at 11,805', RIH, Sat down full wt at 12,680 ft, in trouble shale. Work liner thru shale. RIH, sat down at 12970', 13160', 13,220', 13,269'. Correct to flag on CT, [-10ft CTD. ] 23:00 - 23:45 0.75 CASE P COMP Landed liner shoe at correct TO, at 13,409'. Tagged 3 times at Printed: 6/912003 12:00:07 PM ') ') BP EXPLORA TrON Operati.ons Summary Report Page 17 of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/31/2003 23:00 - 23:45 0.75 CASE P COMP same depth. Circ. 5/8" steel ball. Ball on seat at 49 bbls. Sheared at 4000 psi, Pick up free from liner at 34K. Stack 15K on liner. Circ. with FloPro. Full returns. 23:45 - 00:00 0.25 CEMT N WAIT COMP Wait on vac trucks, no trucks available. 6/1/2003 00:00 - 00:30 0.50 CEMT N WAIT COMP Wait on vac trucks with 2% KCL water. Delay due to shortage of drivers. 00:30 - 03:45 3.25 CEMT P COMP Circ. well to 2% KCL water, 80F, double slick. 2.6 bpm, 2500 psi, 7% fluid loss with KCL water on formation. R/O SWS Cementing equipment. 03:45 - 04:00 0.25 CEMT P COMP SAFTY MEETING. Review procedure, hazards and mitigation for cement job. 04:00 - 04:30 0.50 CEMT P COMP Press test cement line w/ 4000 psi. Batch mix 15.8 ppg, G cement. Cement at weight at 0430 hrs. 04:30 - 05:00 0.50 CEMT P COMP Stg 40.0 bbls, 15.8 ppg, G, Cement at 2.1 bpm, 2200 psi. Pump 40.0 bbls cement. 05:00 - 05:45 0.75 CEMT P COMP Insert BKR dart. Clean lines. Pump 0.5 bbls 2# biozan. Check for Dart. Dart went. Displace cement with 2# biozan water. 3.2 bpm, 1250 psi at 10 bbls, 3.5 bpm, 1000 psi at 20 bbls, 3.2 bpm, 2300 psi at 30 bbls displacement. full returns. 3.1 bpm, 2400 psi at 40 bbls displacement, full returns, cement out shoe at 37.6 bbls displ. 2.9 bpm, 2350 psi at 50 bbls, swab to 2% KCL water. Slow to 1.8 bpm at 53 bbls. Dart on liner wiper plug at 57.8 bbls, sheared LWP at 3200 psi. Displace LWP at 3.2 bpm, 2900 psi, full returns at 26 bbls cement out, then out micromotion meter partially plugged. Full returns seen on shaker for complete job. Slow displacement to 1.0 bpm at 74 bbls. 1.0 bpm, 850 psi, Bumped plug at 77.0 bbls, [calc = 77.4 bbls], Hold 1500 psi. OK. Check floats OK. 05:45 - 07:30 1.75 CEMT P COMP Sting out of top of liner at 34K. Top of Liner at 10,295 ft. POH pumping to replace CT volume only. 07:30 - 07:40 0.17 CEMT P COMP Tag up with cementing BHA. Stand back injector. 07:40 - 08: 1 0 0.50 CEMT P COMP Safety meeting to review laying down the BHA, and plan forward, including the BOP test. Discuss hazards and mitigation. 08:10 - 09:20 1.17 BOPSURP COMP Weekly BOP test. Send test report to AOGCC. 09:20 - 10:30 1.17 BOPSURN WAIT COMP Master valve leaking. Call for grease crew to come and grease it. 10:30 - 15:45 5.25 BOPSUR P COMP Resume weekly BOP test. 15:45 - 16:15 0.50 EVAL P COMP Safety meeting prior to picking up SWS CNL logging tool in carrier for C/O logging run. 16:15 -16:45 0.50 EVAL P COMP Pick up mill, motor, SWS BHA. 16:45 - 18:00 1.25 EVAL P COMP PU 104 joints of 1-1/4" CSH work string in singles. 18:00 - 18:30 0.50 EVAL P COMP SO operations for crew change, and PJSM. 18:30 - 21 :45 3.25 EVAL P COMP Resume PU 1-1/4" CSH workstring. Circ. at 50 jts to ensure motor not plugged. Continue M/U CSH workstring. M/U DS MHA. BHA = 3267 ft. Printed: 6/9/2003 12:00:07 PM ) ') BP EXPLORATION Operatiol1sSummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date Page 180f 19 Start: 5/17/2003 Rig Release: 6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 6/1/2003 1.25 EVAL P From- To Hours Task Code NPT Phase Description of Operations 21 :45 - 23:00 23:00 - 00:00 1.00 EVAL P 6/2/2003 00:00 - 01 :00 1.00 EVAL P 01 :00 - 02:15 1.25 EVAL P 02: 15 - 04:00 1.75 EVAL P 04:00 - 04: 15 0.25 EVAL P 04: 15 - 05:45 1.50 EVAL P 05:45 - 06:00 0.25 EVAL P 06:00 - 06:20 0.33 EVAL P 06:20 - 07: 1 0 0.83 EVAL P 07: 1 0 - 09:30 2.33 PERF N 09:30 - 10:15 0.75 PERF P 10:15 - 10:35 0.33 PERF P 10:35 - 12:00 1.42 PERF P 12:00 - 12:20 0.33 PERF P 12:20 - 13:05 0.75 PERF P 13:05 - 13:20 0.25 PERF P 13:20 -14:15 0.92 PERF P 14:15 -14:35 0.33 PERF P 14:35 - 16:30 1.92 PERF P 16:30 -17:10 0.67 PERF P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP WAIT COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP RIH with SWS CNLlGR with motor and 2.30" mill, 0.3 bpm, 500 psi. Circ. in 25 bbls high vis FloPro perf pill while RIH. Log down with CNLlGR from 10,050' at 30 FPM. 0.3 bpm, 500 psi. Logging down at 11,800 ft at 24:00 hrs, Clean liner. Log down with SWS Memory CNLlGR at 30 fpm, Clean liner with 2.30" mill and motor. Tag PBTD at 13,394 ft. Same as completion PBTD. Log up at 60 FPM while laying in25 bbls of new FloPro at 0.5 bpm, 600 psi. Log up to 10,050'. POH. circ. 1.2 bpm, 1000 psi. Drop 5/8" steel ball and open circ sub. SAFETY MEETING. Review procedure, hazards and mitigation for standy back CSH. Stand back CSH in doubles. Held kick drill while POH. Stabbed TIW valve. SAFETY MEETING. Review procedure, hazards and mitigation for recovery of SWS CNLlGR tool. Layout memory CNLlGR. Down load information Pressure test liner lap to 2000 psi, 30 min. chart test. Bring pressure up in steps, monitor for bleed off each time. Start final 2000 psi test at 07:40. Start pressure=2013 psi. Final pressure=1982 psi, for a loss of 31 psi over 1/2 hour. Wait on Geologist to confirm perf picks after looking at logs in town, prior to picking up perf guns. Recieved new perf intervals. We can manipulate the guns we now have on location to achieve the new perf spacing. Good job on the part of town crew to resolve this so that it does not require loading new guns back in Deadhorse. This saves significant rig time. Thank you. SWS re calculates gun intervals, rearranges guns on pipe rack to achieve proper spacing. Safety meeting prior to picking up perf guns. PU SWS perf guns. Safety meeting with full crew to brief the 2 Nordic hands that changed out on safety aspects of job and discuss plan forward. Run remainder of SWS perf guns and firing head. Safety meeting re: running CSH. RIH with 33 stands of CSH drillpipe. Make up SWS MHA and Injecter. RIH with perf guns on coil tubing. Tag bottom. PU and set depth to ELM tag from last run of 13382'. Make correction of -4 based on up weight. PU into ball drop spot. Pump 7 bbls of perf pill. Drop 5/8" steel ball to fire perf guns. Pump remainder of pill, then chase with KCL water, while running back into position. Position gun nose at 13381', PUH slowly as ball lands. Coil vol=58.8. Ball on seat at 52.2 bbls away, good indication of fire. Intervals perforated as follows; 12220-12310,6 spf Printed: 6/9/2003 12:00:07 PM ') BP EXPLORATION Operations Summary Report Page 190f 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-05 02-05 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/17/2003 Rig Release: ,6/3/2003 Rig Number: N1 Spud Date: 11/7/1970 End: 6/3/2003 Date From - To Hours Task Code NPT Phase Descri ption of Operations 6/2/2003 16:30 - 17:10 0.67 PERF P CaMP 12340-12380,6 spf 12470-12500,6 spf 12600-12670,6 spf 12690-12900,4 spf 12950-13190,4 spf 13291-13380,4 spf 17:10-19:00 1.83 PERF P CaMP POH with fired guns. 19:00 - 19:15 0.25 PERF P CaMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out CSH in singles. 19: 15 - 21 : 30 2.25 PERF P CaMP Layout 66 jts of CSH. 21 :30 - 21:45 0.25 PERF P CaMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out 2" perf guns. 21:45 - 00:00 2.25 PERF P CaMP Layout SWS 2" perf guns. 6/3/2003 00:00 - 02:00 2.00 PERF P CaMP Layout SWS 2" perf guns. All shots fired. 02:00 - 03:30 1.50 PERF P CaMP RIH with 16 stds CSH. Layout in singles for DD rig move. 03:30 - 04:45 1.25 WHSUR P CaMP RIH 2250'. Pump 35 bbls MEOH and Freeze protect to surface. Stop at 100 ft and circ. 100% MEOH to surface. Close master valve. 04:45 - 05:00 0.25 RIGD P POST Rig up N2 unit and cool down. 05:00 - 05: 15 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2 to purge coil. 05: 15 - 06:00 0.75 RIGD P POST Pressure test hardline. Pump N2 and displace fluid from coil for rig move, 1500 SCFPM for 12 minutes. Bleed down N2 pressure in CT. 06:00 - 07:00 1.00 RIGD P POST Set BPV. 07:00 - 07:15 0.25 RIGD P POST Safety meting prior to unstabing pipe. 07:15 - 08:15 1.00 RIGD P POST Stab injector back on well. Unstab pipe. Secure back on reel for transportation to F pad on the WOA. 08:15 - 10:15 2.00 RIGD P POST Nipple down stack. Can not install tree cap yet, due to high tree. 10:15 - 10:30 0.25 RIGD P POST Safety meeting prior to moving rig. 10:30 - 11 :00 0.50 DEMOB P POST Move rig forward 2' to pick up stack and secure tree cap. Released Rig at 11 :00 AM. 11 :00 - 0.00 DEMOB P POST Secure BOP stack. Install tree cap. PT tree cap. Move rig to F-10B. Printed: 6/9/2003 12:00:07 PM Well: Field: API: Permit: Date ) ) 05/17/03 OS/21/03 06/03/03 Nordic #1 06/08/03 MU/RIH WI 2" JET SWIRL NOZZLE. BEGIN JETTING OUT FLOPRO ACROSS PERFS WI CRUDE FROM 12200'. MAX DEPTH OBTAINED WAS 12900' (UP). APPEARS HOLE ANGLE AND DOG LEGS DO NOT ALLOW RUNNING TO BOTTOM WI 1.75" CT. JET OUT. MAKE REPEAT PASS ACROSS DEPLOYMENT SLEEVE. POOH. MU/RIH W/2 7/8" MHA WI ALS JET PUMP AND BAKER 3" SEAL ASSEMBLY. STING INTO DEPLOYMENT SLEEVE @ 10321' CTM. ONLINE WITH CRUDE DOWN COIL TO POWER JET PUMP. 16+ HOURS OF RUNNING JET PUMP @ 1.1 BPM. 02-05A Prudhoe Bay Unit 50-029-20081-01 203-082 Accept: Spud: Release: Rig: 06/09/03 RUNNING ALS JET PUMP @ 10321' WI CRUDE @ 1.1 -1.2 BPM. PUMPED 1824 BBLS OF CRUDE THRU PUMP. LAST WELL TEST PRIOR TO UNSTINGING FROM DEPLOYMENT SLEEVE & POOH: 192 BWPD, 1000 BOPD (NET), 1-2M GAS. AT SURFACE, WELL APPEARS TO BE FLOWING. .. -_._~--- POST RIG WORK ) ) 09-Jun-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 02-05 A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 11,292.97' MD Window / Kickoff Survey: 11,309.50' MD (if applicable) Projected Survey: 13,409.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, d.D3-D~;;" RECEIVED JUN 1 2 2003 William T. Allen Survey Manager "\ Gas Cons. Cornmiseion Anchorage/) - ~~ Attachment(s) Sperry-Sun Drilling Services -- North Slope Alaska BPXA PBU_EOA DS 02 02-05 - 2-05A Job No. AKMWOO02454192, Surveyed: 31 May, 2003 Survey Report 6 June, 2003 Your Ref: API 500292008101 Surface Coordinates: 5950042.00 N, 688550.00 E (70016'05.8318" N, 148028'30.6321" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 950042.00 N, 188550.00 E (Grid) Surface Coordinates relative to Structure Reference: 1219.06 N, 940.59 E (True) Kelly Bushing: 64.00ft above Mean Sea Level Elevation relative to Project V Reference: 64.00ft Elevation relative to Structure Reference: 64.00ft SI=h=I- ·....y-sUl'1 DRILLING seRVices A Halliburton Company DEFINITIVE -- -- Survey Ref: svy4040 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 02 . 02-oS . 2-oSA Your Ref: API 500292008101 Job No. AKMWOO02454192, Surveyed: 31 May, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11292.97 64.41 0 305.230 8812.22 8876.22 1999.98 N 5209.48 W 5951910.86 N 683292.06 E 5566.58 Tie On Point 11309.50 64.970 306.060 8819.29 8883.29 2008.69 N 5221.62 W 5951919.26 N 683279.70 E 5.664 5580.74 Window Point 11354.57 74.420 302.270 8834.92 8898.92 2032.36 N 5256.57 W 5951942.05 N 683244.17 E 22.397 5621.09 11385.49 81.940 301.900 8841.24 8905.24 2048.42 N 5282.19 W 5951957.47 N 683218.15 E 24.349 5650.29 11418.42 86.260 297.320 8844.63 8908.63 2064.59 N 5310.66 W 5951972.92 N 683189.29 E 19.063 5682.24 11456.09 88.370 289.740 8846.40 8910.40 2079.60 N 5345.13 W 5951987.06 N 683154.45 E 20.865 5719.59 -- 11500.12 86.870 279.700 8848.23 8912.23 2090.77 N 5387.63 W 5951997.16 N 683111.69 E 23.036 5763.49 11528.99 83.700 278.110 8850.60 8914.60 2095.22 N 5416.05 W 5952000.90 N 683083.17 E 12.275 5791.97 11559.47 85.290 281.460 8853.53 8917.53 2100.38 N 5445.94 W 5952005.30 N 683053.16 E 12.120 5822.07 11589.39 85.290 287.980 8855.99 8919.99 2107.95 N 5474.76 W 5952012.15 N 683024.15 E 21.718 5851.85 11629.54 82.640 292.380 8860.21 8924.21 2121.72N 5512.23 W 5952024.98 N 682986.36 E 12.740 5891.70 11658.39 82.200 298.020 8864.02 8928.02 2133.89 N 5538.09 W 5952036.49 N 682960.19 E 19.438 5919.99 11692.99 84.410 305.420 8868.06 8932.06 2151.94 N 5567.30 W 5952053.82 N 682930.54 E 22.179 5953.20 11722.17 82.820 308.770 8871.30 8935.30 2169.43 N 5590.43 W 5952070.72 N 682906.99 E 12.643 5980.43 11755.74 82.560 315.990 8875.58 8939.58 2191.86 N 5615.01 W 5952092.52 N 682881.85 E 21.346 6010.49 11785.34 82.200 321.990 8879.51 8943.51 2213.99 N 5634.25 W 5952114.16 N 682862.06 E 20.128 6035.37 11817.57 83.520 326.570 8883.52 8947.52 2239.94 N 5652.91 W 5952139.64 N 682842.75 E 14.683 6060.80 11847.42 83.000 321 .460 8887.02 8951.02 2263.92 N 5670.32 W 5952163.18 N 682824.75 E 17.090 6084.47 11885.97 81 .150 316.520 8892.34 8956.34 2292.73 N 5695.37 W 5952191.35 N 682798.99 E 13.568 6116.83 11916.47 84.410 315.290 8896.17 8960.17 2314.45 N 5716.42 W 5952212.54 N 682777.40 E 11.413 6143.32 11943.49 87.400 313.530 8898.10 8962.10 2333.31 N 5735.67 W 5952230.91 N 682757.68 E 12.832 6167.24 11972.79 87.750 310.000 8899.34 8963.34 2352.80 N 5757.50 W 5952249.85 N 682735.37 E 12.096 6193.82 12014.99 89.160 307.010 8900.48 8964.48 2379.06 N 5790.51 W 5952275.27 N 682701.72 E 7.831 6233.06 12054.52 85.990 301.020 8902.16 8966.16 2401.15 N 5823.22 W 5952296.53 N 682668.46 E 17.130 6270.81 -- 12087.92 82.730 298.200 8905.44 8969.44 2417.57 N 5852.11 W 5952312.22 N 682639.16 E 12.878 6303.23 12124.34 81 .850 293.970 8910.33 8974.33 2433.43 N 5884.52 W 5952327.27 N 682606.37 E 11.760 6338.86 12153.67 81.940 289.210 8914.46 8978.46 2444.12 N 5911.51 W 5952337.27 N 682579.12 E 16.070 6367.80 12182.39 81.230 285.510 8918.67 8982.67 2452.59 N 5938.62 W 5952345.07 N 682551.81 E 12.982 6396.20 12212.42 80.970 282.160 8923.32 8987.32 2459.69 N 5967.43 W 5952351.44 N 682522.83 E 11.055 6425.82 12242.62 85.640 281.810 8926.84 8990.84 2465.91 N 5996.76 W 5952356.93 N 682493.35 E 15.506 6455.69 12279.19 90.220 280.050 8928.16 8992.16 2472.84 N 6032.63 W 5952362.95 N 682457.32 E 13.415 6492.02 12316.14 91.540 275.820 8927.59 8991.59 2477.94 N 6069.21 W 5952367.13 N 682420.62 E 11.991 6528.50 12345.02 92.420 271.770 8926.59 8990.59 2479.85 N 6098.01 W 5952368.32 N 682391.79 E 14.342 6556.59 12374.32 92.420 266.480 8925.35 8989.35 2479.40 N 6127.27 W 5952367.14 N 682362.55 E 18.038 6584.44 12405.42 92.510 261.370 8924.01 8988.01 2476.11 N 6158.15 W 5952363.08 N 682331.75 E 16.418 6613.02 6 June, 2003 - 13:51 Page 20f4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 02 . 02-05 . 2-05A Your Ref: API 500292008101 Job No. AKMWOO02454192, Surveyed: 31 May, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 12440.24 92.950 256.790 8922.35 8986.35 2469.53 N 6192.30 W 5952355.64 N 682297.79 E 13.199 6643.74 12474.02 88.900 255.380 8921.81 8985.81 2461.41 N 6225.07 W 5952346.70 N 682265.23 E 12.695 6672.71 12505.53 87.220 253.440 8922.88 8986.88 2452.94 N 6255.40 W 5952337.48 N 682235.12 E 8.142 6699.24 12534.08 90.840 252.560 8923.36 8987.36 2444.60 N 6282.70 W 5952328.46 N 682208.04 E 13.049 6722.90 12573.73 92.690 258.550 8922.14 8986.14 2434.72 N 6321.06 W 5952317.62 N 682169.94 E 15.804 6756.70 12611.86 96.740 265.770 8919.00 8983.00 2429.53 N 6358.67 W 5952311.49 N 682132.47 E 21.651 6791.15 ~ 12644.06 100.260 266.660 8914.24 8978.24 2427.43 N 6390.44 W 5952308.59 N 682100.76 E 11.268 6820.92 12676.63 97.180 272.120 8909.30 8973.30 2427.09 N 6422.61 W 5952307.45 N 682068.61 E 19.077 6851.59 12707.46 94.540 270.000 8906.15 8970.15 2427.66 N 6453.27 W 5952307.25 N 682037.94 E 10.959 6881.07 12743.03 96.650 273.350 8902.68 8966.68 2428.69 N 6488.65 W 5952307.40 N 682002.55 E 11.092 6915.21 12775.96 93.300 280.050 8899.82 8963.82 2432.52 N 6521.21 W 5952310.41 N 681969.91 E 22.676 6947.46 12805.36 91.100 277.050 8898.70 8962.70 2436.89 N 6550.26 W 5952314.05 N 681940.76 E 12.647 6976.52 12830.98 91.100 272.290 8898.20 8962.20 2438.97 N 6575.78 W 5952315.49 N 681915.19 E 18.576 7001.54 12862.31 92.690 267.890 8897.17 8961 .17 2439.02 N 6607.08 W 5952314.76 N 681883.90 E 14.925 7031.49 12891.61 93.040 266.480 8895.70 8959.70 2437.58 N 6636.31 W 5952312.59 N 681854.71 E 4.952 7059.02 12954.43 88.280 259.080 8894.98 8958.98 2429.70 N 6698.57 W 5952303.14 N 681792.67 E 14.003 7116.25 13008.13 89.780 245.160 8895.89 8959.89 2413.25 N 6749.54 W 5952285.43 N 681742.13 E 26.067 7160.18 13038.33 90.660 255.730 8895.78 8959.78 2403.16 N 6777.96 W 5952274.62 N 681713.98 E 35.120 7184.41 13068.33 92.330 259.610 8894.99 8958.99 2396.75 N 6807.25 W 5952267.49 N 681684.85 E 14.076 7210.55 13100.36 91.370 258.020 8893.96 8957.96 2390.54 N 6838.65 W 5952260.49 N 681653.62 E 5.796 7238.76 13132.78 92.160 269.120 8892.96 8956.96 2386.92 N 6870.80 W 5952256.07 N 681621.57 E 34.308 7268.45 13164.01 90.040 272.120 8892.36 8956.36 2387.26 N 6902.02 W 5952255.62 N 681590.35 E 11.761 7298.40 13191.51 87.930 276.520 8892.84 8956.84 2389.33 N 6929.43 W 5952257.01 N 681562.90 E 17.742 7325.22 13220.03 87.670 278.640 8893.94 8957.94 2393.09 N 6957.68 W 5952260.06 N 681534.56 E 7.484 7353.33 -- 13251.83 90.400 289.030 8894.48 8958.48 2400.68 N 6988.50 W 5952266.87 N 681503.56 E 33.774 7385.03 13271.61 91.540 290.970 8894.14 8958.14 2407.44 N 7007.09 W 5952273.17 N 681484.81 E 11.375 7404.78 13317.83 90.840 297.490 8893.18 8957.18 2426.40 N 7049.20 W 5952291.06 N 681442.23 E 14.184 7450.60 13349.38 89.960 303.840 8892.96 8956.96 2442.48 N 7076.33 W 5952306.46 N 681414.71 E 20.318 7481.24 13369.88 88.110 303.480 8893.31 8957.31 2453.84 N 7093.39 W 5952317.39 N 681397.37 E 9.194 7500.87 13409.00 88.110 303.480 8894.60 8958.60 2475.41 N 7126.00 W 5952338.14 N 681364.23 E 0.000 7538.36 Projected Survey 6 June, 2003 - 13:51 Page 3 0'4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for P8U_EOA OS 02· 02.oS - 2.oSA Your Ref: AP/500292008101 Job No. AKMWOO02454192, Surveyed: 31 May, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 287.000° (True). ~ -,-. Magnetic Declination at Surface is 25.950°(17 -May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13409.000., The Bottom Hole Displacement is 7543.70ft., in the Direction of 289.156° (True). ~_. Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11292.97 11309.50 13409.00 8876.22 8883.29 8958.60 1999.98 N 2008.69 N 2475.41 N 5209.48 W 5221.62 W 7126.00 W Tie On Point Window Point Projected Survey Survey tool proøram for 02-05 - 2-05A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11150.00 0.00 11150.00 8802.07 13409.00 8802.07 BP High Accuracy Gyro - AK-1 BP _HG (02-05) 8958.60 MWD Magnetic (2-05APB1) 6 June, 2003 - 13:51 Page 4 of4 DrillQuest 3.03.02.005 ) ) 09-Jun-03 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 02-05 A PB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 11,150.00' MD Window / Kickoff Survey: 11,180.00' MD (if applicable) Projected Survey: 12,435.00' MD Please call me at 273-3545 if you have any questions or concerns. .. 'Q 6LD3-Do~ Regards, ~+-1 0-- DS9 - RECEIVED JUN 1 2 2003 William T. Allen Survey Manager AJ~. '.' ç. 1-:': ".c:: ,-, - ," ,: ,,' \ ", (',1'"'\: .~,.: . ... :î ~ \Jet... \"IÎJ;¡~, ~.iv.t..:.i,,.'~n ,r'.~iiCft';Gf'~' . i"i.I" .ù.tL~ Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 02 02-05 - 2-05APB1 Job No. AKMWOOO2454192, Survey Report 6 June, 2003 Your Ref: API 500292008170 Surface Coordinates: 5950042.00 N, 688550.00 E (70016'05.8318" N, 148028'30.6321" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 950042.00 N, 188550.00 E (Grid) Surface Coordinates relative to Structure Reference: 1219.06 N, 940.59 E (True) Kelly Bushing: 64.00ft above Mean Sea Level Elevation relative to Project V Reference: 64.00ft Elevation relative to Structure Reference: 64.00ft SpE!r'r-"Y-!5UI"1 DRILLING SERViCeS A Halliburton Company DEF-N -IVE ~ '-----' Survey Ref: svy4039 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 02 . 02-05 - 2-05APB1 Your Ref: AP/S00292008170 Job No. AKMWOOO2454192, BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11150.00 50.080 305.110 8738.07 8802.07 1929.91 N 5110.21 W 5951843.30 N 683393.05 E 5451.17 Tie On Point MWD Magnetic 11180.00 50.100 305.230 8757.32 8821.32 1943.16 N 5129.02 W 5951856.08 N 683373.92 E 0.314 5473.03 Window Point 11200.59 58.950 305.230 8769.26 8833.26 1952.82 N 5142.70 W 5951865.39 N 683359.99 E 42.982 5488. 94 11235.82 62.220 305.230 8786.56 8850.56 1970.52 N 5167.77 W 5951882.46 N 683334.50 E 9.282 5518.09 11292.97 64.4 1 0 305.230 8812.22 8876.22 1999.98 N 5209.48 W 5951910.86 N 683292.06 E 3.832 5566.58 ~ 11326.97 65.530 306.870 8826.61 8890.61 2018.11 N 5234.38 W 5951928.36 N 683266.71 E 5.473 5595.70 11354.47 65.730 308.770 8837.95 8901.95 2033.47 N 5254.17 W 5951943.22 N 683246.55 E 6.335 5619.11 11393.47 66.260 305.070 8853.83 8917.83 2054.86 N 5282.64 W 5951963.90 N 683217.54 E 8.772 5652.60 11425.84 69.430 305.070 8866.03 8930.03 2072.09 N 5307.18 W 5951980.50 N 683192.58 E 9.793 5681.10 11456.59 68.990 302.250 8876.95 8940.95 2088.02 N 5331.10W 5951995.83 N 683168.27 E 8.692 5708.64 11484.74 69.160 300.140 8887.00 8951.00 2101.64 N 5353.59 W 5952008.88 N 683145.44 E 7.027 5734.13 11512.47 69.780 298.200 8896.73 8960.73 2114.29 N 5376.27 W 5952020.96 N 683122.46 E 6.923 5759.51 11546.22 71.370 296.790 8907.95 8971.95 2128.98 N 5404.50 W 5952034.94 N 683093.87 E 6.141 5790.80 11580. 17 72.420 295.730 8918.50 8982.50 2143.26 N 5433.44 W 5952048.49 N 683064.58 E 4.286 5822.65 11614.89 75.630 299.220 8928.06 8992.06 2158.66 N 5463.04 W 5952063.14 N 683034.60 E 13.373 5855.46 11654.94 77.440 302.610 8937.39 9001.39 2178.67 N 5496.45 W 5952082.31 N 683000.71 E 9.390 5893.26 11682.52 77.710 304.720 8943.32 9007.32 2193.60 N 5518.86 W 5952096.67 N 682977.92 E 7.535 5919.06 11712.97 79.470 302.070 8949.35 9013.35 2210.03 N 5543.78 W 5952112.47 N 682952.60 E 10.304 5947.69 11743.87 88.110 301.370 8952.69 9016.69 2226.16 N 5569.89 W 5952127.95 N 682926.10 E 28.052 5977.37 11771.12 89.690 303.660 8953.21 9017.21 2240.81 N 5592.86 W 5952142.01 N 682902.77 E 10.208 6003.62 11802.62 91.720 301.900 8952.82 9016.82 2257.86 N 5619.34 W 5952158.39 N 682875.87 E 8.529 6033.93 11835.47 91.810 297.840 8951.81 9015.81 2274.21 N 5647.80 W 5952174.02 N 682847.00 E 12.356 6065.94 11867.42 92.510 295.910 8950.61 9014.61 2288.64 N 5676.28 W 5952187.74 N 682818.17 E 6.422 6097.39 -- 11895.99 92.600 290.270 8949.33 9013.33 2299.83 N 5702.53 W 5952198.26 N 682791.66 E 19.724 6125.76 11922.42 92.780 286.210 8948.09 9012.09 2308.09 N 5727.59 W 5952205.90 N 682766.39 E 15.359 6152.15 11953.84 97.890 285.160 8945.17 9009.17 2316.54 N 5757.70 W 5952213.60 N 682736.08 E 16.600 6183.41 11983.74 94.270 281.990 8942.00 9006.00 2323.52 N 5786.60 W 5952219.84 N 682707.02 E 16.053 6213.08 12012.69 93.570 276.700 8940.02 9004.02 2328.21 N 5815.08 W 5952223.82 N 682678.42 E 18.390 6241.69 12052.49 94.630 273.180 8937.18 9001.18 2331.62 N 5854.63 W 5952226.24 N 682638.80 E 9.215 6280.51 12081.72 90.750 271.240 8935.80 8999.80 2332.75 N 5883.80 W 5952226.64 N 682609.62 E 14.837 6308.73 6 June, 2003 - 13:46 Page 2 0(4 Dri/lQuest 3.03.02.005 Sperry-Sun. Drilling Services Survey Report for PBU_EOA DS 02 - 02-oS - 2-0SAPB1 Your Ref: API 500292008170 Job No. AKMWOO02454192, BPXA North Slope Alaska Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12111.59 91.010 267.360 8935.34 8999.34 2332.38 N 5913.66 W 5952225.52 N 682579.78 E 13.017 6337.18 12143.12 93.830 265.950 8934.01 8998.01 2330.55 N 5945.10 W 5952222.90 N 682548.39 E 9.998 6366.71 12173.69 98.150 270.180 8930.82 8994.82 2329.52 N 5975.47 W 5952221.11 N 682518.05 E 19.723 6395.46 12206.22 97.800 276.170 8926.31 8990.31 2331.30 N 6007.62 W 5952222.09 N 682485.87 E 18.267 6426.72 12235.72 96.210 280.580 8922.71 8986.71 2335.57 N 6036.58 W 5952225.63 N 682456.81 E 15.786 6455.67 12263.97 94.270 283.920 8920.13 8984.13 2341.54 N 6064.07 W 5952230.90 N 682429.18 E 13.629 6483.70 -' 12293.99 93.740 286.740 8918.03 8982.03 2349.45 N 6092.95 W 5952238.09 N 682400.12 E 9.536 6513.63 12324.04 97.270 289.920 8915.14 8979.14 2358.85 N 6121.33 W 5952246.78 N 682371.50 E 15.777 6543.52 12360.84 97.000 296.440 8910.57 8974.57 2373.22 N 6154.88 W 5952260.30 N 682337.61 E 17.595 6579.80 12390.87 94.180 301.190 8907.64 8971.64 2387.62 N 6181.05 W 5952274.05 N 682311.08 E 18.329 6609.05 12412.67 93.740 303.840 8906.14 8970.14 2399.31 N 6199.39 W 5952285.27 N 682292.45 E 12.294 6630.00 12435.00 93.740 303.840 8904.68 8968.68 2411.72 N 6217.90 W 5952297.21 N 682273.64 E 0.000 6651.33 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 287.000° (True). Magnetic Declination at Surface is 25.951°(17-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12435.00ft., The Bottom Hole Displacement is 6669.23ft., in the Direction of 291.200° (True). ..- r 6 June, 2003 - 13:46 Page 3 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 02 - 02-05 - 2-OSAPB1 Your Ref: API 500292008170 Job No. AKMWO002454192, BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11150.00 11180.00 12435.00 8802.07 8821.32 8968.68 1929.91 N 1943.16 N 2411.72 N 5110.21 W 5129.02 W 6217.90 W Tie On Point Window Point Projected Survey .~ Survey tool program for 02-05 - 2-05APB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11150.00 0.00 11150.00 8802.07 12435.00 8802.07 BP High Accuracy Gyro - AK-1 BP _HG (02-oS) 8968.68 MWD Magnetic (2-0SAPB1) ~~ 6 June, 2003 - 13:46 Page 4 0'4 D,iIIQuest 3.03.02.005 $)~:~IA\~E :\11A\~1A\~~~1A\ /) ALASKA. OIL AND GAS / CONSERVATION COlWllSSIOlV FRANK H. MURKOW5KI, GOVERNOR 333 W. -¡rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 02-05A BP Exploration (Alaska), Inc. Permit No: 203-082 Surface Location: 1182' SNL, 1793' EWL, Sec. 36, TIIN, RI4E, UM Bottomhole Location: 1360' NSL, 103' WEL, Sec. 27, TIIN, RI4E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, If -.-{J'7 fL'-4lt - :~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this--L day of May, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section .. STATE OF ALASKA ALASKA C._kND GAS CONSERVATION COMMI~__bN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool RKB = 64' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028309 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 02-05A 9. Approximate spud date 05/20103 ,./ Amount $200,000.00 14. Number of acres in property 15. P~osed depth (MD and TVD) 2560 . 13420' MD 18875' TVDss o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 102 Maximum surface 2219 psig, At total depth (TVD) 8800' I 3275 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD TVD (include staCJe data) 3160' 10260' 8175' 13420' 8875' 123 sx Class 'G' 1 a. Type of work 0 Drill II Redrill ORe-Entry D' Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 688550, Y = 5950043 1182' SNL, 1793' EWL, SEC. 36, T11N, R14E, UM At top of productive interval x = 683717, Y = 5951635 530' NSL, 2998' WEL, SEC. 26, T11 N, R14E, UM At total depth x = 681311, Y = 5952407 1360' NSL, 103'WEL, SEC. 27, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028308,103' MD No Close Approach / 16. To be completed for deviated wells Kick Off Depth 11150' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Hole Casina Weight Grade CouDlina 3-3/4" 3-3/16" x 2-7/8" 6.2#/6.16# L-80 ST-L 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11660 feet Plugs (measured) true vertical 9122 feet Effective depth: measured 11549 feet Junk (measured) true vertical 9053 feet Casing Length Size Cemented Structural Conductor Surface Intermediate' Production Liner 119~ 1204' 2696' 11645' 30" 20" 13-3/8 " 9-518" Circ Fondu Neat 750 sx Fondu Flyash, 280 Fondu Neat 1355 sx Fondu Flyash, 425 sx 'G' 1480 sx Class 'G', 100 sx Fondu Perforation depth: measured 20. Attachments ~GA- 5/5/2..005 ...)) (I ~u 6' ~·,'O? ~I 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 REcelVCD APR 3 0 Z003 Alaska Oi\ & Gas·Cons. Commission Anchorage MD TVD 119' 1204' 2696' 11645' 119' 1204' 2694' 9113' Open: 11268'-11280', 11392'-11412', 11434'-11442', 11449' -11473', 11498'-11514' Sqzd: 11315' - 11392', 11420' - 11434' true vertical Open: 8878' - 8885', 8956' - 8968', 8982' - 8987', 8991' - 9006', 9022' - 9032' Sqzd: 8907' - 8956', 8973' - 8982' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 21. I hereby certify that the f~rf~.,oin.g. 'is, ' tr,u. e a,nd corr~ct. tor~r.':' st Of, m. y k, n~~ledge . Signed Ma~ Endacod /1; t~ lé'1¡a'acß~!II:~:i;T :I::nglneer Date f 3QIO 3 Permit Number API Number ABQ~'í:9?1.e See cover letter ..2.~.3 - c:> ,Ç .z.-. 50- 029-20081-01 .) I ,)) l7 J for other requirements Conditions of Approval: Samples Required 0 Yes ]Sf No Mud Log e uired 0 Yes B No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required M Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T -e Ç. 1- ""EO} E tv ~ÇCO ,:>~l. Approved By ~. ,;£-~ ~"'~ptl,. t"'"1-. ~ Form 1 0-40 1 Rev. 12-01-85 J Prepared By Name/Number: Terrie Hubble, 564-4628 by order of ú1'rGfN At commission Date S/5--1 ð3 šZb;:;¡-ln Triplicate ') ) BP 02-05a CrD Sidetrack Summary of Operations: Phase 1: Prep work - integrity testing, cement Phase 2: Mill window Phase 3: Drill and Complete sidetrack Mud Program: · Phase 2: Viscosified Seawater / · Phase 3: Flo-Pro (8.6 - 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will be 3 3/16"'f~l. 2 718" ST-L from TD to approx. 10260'MD (-8175'ss). The liner will be cemented with a minimum O~IS to bring cement up to ,..,250ft above the window. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 108 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray and resistivity will be run in the open hole section. Memory CNL will be run inside the liner. Hazards / . The maximum recorded H2S at DS 2 is 100 ppm. . No mapped faults will be crossed. Reservoir Pressure Res. press. is estimated to be 3275 psi at 8800'ss (7.2ppg emw). / Max. surface pressure with gas (0.12 psi/ft) to surface is 2219 psi. · TREE= I WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = McEVOY GEN 1 McEVOY I AXELSON: 64' Y2-05A PROPOSED CTD SIDETRACK 3159' 53 @ 10400' 11247' 8800' SS 113-3/8" CSG, 72#, N-80, ID = 12.347" 1-1 2696' ..J Minimum ID = 2.377" @ 11,800' 2 7/8" liner ST -L pin ID TOPOF 33/16" x 27/8" liner 1-1 5-1/2" TBG, 17#, N-80, AB mod, - 0.0232 bpf, ID = 4.892" TOPOF 4-1/2" TBG-NPC - 10260' 10264' 10264' 4-1/2" TBG-NPC, 12.6#, N-80, BTC, \- 10392' 0.0152 bpf, ID = 3.958" ÆRFORA TION SUMMARY REF LOG: BHCS ON 12/15/70 ANGLEATTOPÆRF: 50 @ 11250' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 4 11250 - 11280 S 06/23/89 3-3/8" 6 11265 - 11280 0 09/19/99 3-1/8" 4 11315 - 11345 S 06/23/89 3-1/8" 4 11360 - 11408 S 06/23/89 3-3/8" 6 11392 - 11404 0 08/22/99 3-3/8" 6 11392 - 11412 S 02/24/99 3-3/8" 2 11404 - 11412 0 06/18/99 3-3/8" 4 11420 - 11440 S 02/24/99 3-3/8" 2 11434 - 11442 0 06/18/99 3-3/8" 6 11449 - 11434 0 06/18/99 3-1/8" 4 11449 - 11473 S 06/23/89 3-1/2" 4 11453 - 11473 0 04/25/99 3-3/8" 6 11498-11514 S 02/24/99 3-1/2" 4 11504 - 11514 0 04/25/99 I PBTD 1-1 11549' 19-5/8" CSG, 40# & 47#, N-80 & S-95, BTC, ID = 8.681" 1-1 11645'1 DATE 12/22/70 01/26/77 12/11/00 03/15/01 09/04/01 03/03/03 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-SLT CONVERTED TO CANVAS SIS-MD FINAL RN/TP CORRECTIONS MSE ADD DRLG DETAILS DATE 03/20/03 \SAFETY NOTES: Reduced collapse ,J'ating on 95/8", 20" clamped to 30" due to wellhead movement 1993 2207' 1-15-1/2" BAKER PFYE SSSV NIP, ID = 4.562" - - 1 2405' 1-19 5/8" Baker Stage Collar I ~ 5984' 1-19 5/8" Baker Stage Collar I 1 1 10133' 1-1 5-1/2" BA KER SLIDING SL V I I 10196' 1-15-1/2" BAKER R NIP, ID = 4.472" I l J 10203' 1-15-1/2" BAKER SBRASSY I Z Z 10253' 1-19-5/8" X 5-1/2" BAKER SAB PKR n 10260' - Baker Liner Deployment Sub 3.70" 00, 3.0" ID 10270' - X nipple 2.813" ID 1 . . 1 10327' 1-14-1/2" BAKER R NIP, ID = 3.812" 1 I " 10392' - 4-1/2" TUBING TAIL I 10362' - ELMD TT LOGGED 01/27/77 I? 41.0 1 133/16" 6.2# TCII x 2 7/8" 6.5# ST-L L-80 cmtd & perfd I~'I \, ".".."'.,.."...,.', ,.".."., I ..'."......'.,.'..,.'.':..,'.,.""'.,,....,.,'.',"'...,.'...,.",.....'..,.:"',.',,"....'..'_.~ . 1,1," I "",' I i?~(1 10800' 10900' 11150' 11800' [§]-I 11660' 1 REV BY COMMENTS MSE PROPOSED CTD SIDETRACK 1-1 Top of liner cement I 1-1 Top of P&A cement/cement ramp I 1-1 KOP, cement ramp I 1-133/16" x 2 7/8" XO I I Þn PRUDHOE BA Y UNIT WELL: 02-05A ÆRMrT No: API No: 50-029-20081-01 SEC 36, T11 N, R14E, 3635.76 FEL 4300.96 FNL BP Exploration (Alas ka) Plan: Plan #7 (02-05/Plan#7 02-05A) Created By: Brij Potnis Date: 3/26/2003 í90n 267-6613 b rij. potn is@inteq.com (907) 267-6600 Ccntact information' Direct· E-mail: INTEQ: Azimuths to True North Magnetic North: 26.00° Magnetic Field Strength: 57550nT Dip Angle: 80.83° Date: 3/26/2003 Model: BGGM2002 T ^M é LEGEND 02-05 (02-05) Plan#7 02-o5A Plan #7 -~-I ..... BflLs ObP BP Amoco WlLLPATH D&TAlLS "..on ð2-45A fOð212Dð'101 02-45 11100.00 11f7it170 00:00 ::::';t,o ~-------- i I -.' '- 3/26/2003 11 : 11 AM BaKer Hughes 3000 i -~-- 2900 : ! 2800 I ~: ~ ~7 i-- -; -:--1 2700: !~-L -" J PIan#7 02-05A¡---- I" I ;-- ~ i . 'ë2600 i--i ---trrrn- - -- - ------'.- : , , +---i~--i----c' -1----1-- æ'- ~ -~' I J..o2-OS~3-- 02-oST72L ¡ I } ! Î "\ I I.' ! I I I!' I o 2500 , 14 ~ , , I -'--: : .." .: .' : I 0:2 ~02-OST741 13 "il 111 10 ¡ l,W'. -, i i :::a400 -i I . m:J -, ~ : i .L' ¡ : ¡ ~ ~ - ; -t- - L-_ --- I ~- ,_----L_ - - -~ -·----¡--=--f:~ ¡ + --j I I ' I ' ~3001 ' , ' . .c t==:J 02 'olygon7.1 ' ¡ i .. -", - I ! "2200: i' I ' Oil' I ~2100 l-¡~-i:! :- I r ¡-, r "20001 I: . , [I, :::I ! . I , --J- o ::; ! I : IK~PI . i en 1900 I: : . I ! I : ",-:U!!'J-:-- :::1~J-!_1_¡-: i-r _L~:'_~=-ic:~~_i l--¡-,~, --r [í--,I~' .~ 1600 ~, I I I I 1 ,!' , I t I i f i ' ,'. i i r ---.l . ~ -t- ! ::: ~ ,--! ! u~-l-:~ "~ !~-! I, T,! "', i, .~:,' I ,,;:~,¡~ .:~.. ,-" ¡"'~ -7500 -7400 -7300 -7200 -7100 -7000 -6900 -6800-6700 -0000 -6500 -6400-6300 -6200-6100 -6000-5900 -5800 -&00 -5600-5500 -5400-5300 -5200 -5100 -5Ûoo -4900 West(-)/East( +) [100ftlin] 6400 6500 6600 6700 6800 6900 7000 7100 7200 Vertical Section at 287.00° -------¡- L'\1TEQ T_IIe1 S>øpe ~ 5500 5600 5700 5800 5900 MAOft INFORMATION Well Centre: 02-05. True North System: Mean Sea level ~I~ÒŠ ~~J?A~i!;%o()(til 64.00 Minimum Curvature .aCTlON DIITAlLS TVD +tt'-S ..... DL.. nee. vSec :~!ti~ ~æ:i~ :5~rrl ~ ~= æt~ 17."" tlÞMA8 -5181.22 12.00 0.00 6545.2. ''It.ST 2041.21 -S2f4,'U 12.00 80.00 5828.33 '.'0.37 2153.18 .54OQ.U 12.00 -100.00 st02.4l ::::::: fJ:::; ::=:~ ~t: -::: :=::: ..u.n 23a2.0J -ene.n 12.00 ..eo.OO esatÞ.83 '.1'1.17 z.ao..... .....2.14 12.00 1G.00 NIO.tI3 ..t"~ 2AU." -eH&.U 12.00 ..sS.OO eNO.22 ....,.... 24U.7D -ee"'71 12..00 ·71.00 7101.57 :=~ :s":::~ ::1t:: ~~= '::: ~~; U7A.14 ZUS.11 -71n." 12.00 ....00 7801.04 TARGET œr ~L5 N.~ TVD ."'-5 .EJ..JN gmf~'1 M1~~ rei~ :~:~: g~~fl~ !m~ ~1!~ =~ 5100 5200 5300 ~~ 0.00 5400 ,.,...t W..paUII Tie OB MDI ...., A.'. Datunu V.se<tloa ....... 217.00' REFERENCE Co-ordinate (NlE! Reference: Vertical (TVD Reference: Section (VS Reference: Measured Depth Reference: Calculation Method' O"'J~ ANNOTATIONS TVD ND Aa-.otatlH nO'.n 111Dð.OO TI" 1721.07 11t1O.00 KOJt n4e..2 111"-00 ) .7IJ.l711:tM.eO .. "31.17 11 Hot.OO . "10.31 11 SM.OO . '''U' 1177...Dð 7 ._... 1107...00 . ''''.1. 1U7...Dð . '127"7 1In"--O 10 ..1.M 1In",Dð 11 ...7... 12....00 12 ....A. 1207.&.00 13 ....,:ta t:lt·· ðtI ..f. .n..... uuo.oo TO "'C YD 1ft(: bl ~ H~!i= a:~ 5:!! i He: ::n !!!::! 7 11"4.00 H.81 213.70 ~o ~m~= ß:: :::i! ji jffi~H t~~ m~ ë8100 ~ 8200 ~ o - ... 8300 - - ~ 8400 =. a. GJ- Q 8500--:: ëi 8 -. U 600"· i 8700- > GJ 8800 - i! - ~ 8900 :-. .- 9000 9100 9200 7900 8000 7800 ) ') _,&..1 IIIUGHIS IN''"(, EQ bp BP Baker Hughes INTEQ Planning Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 02 Well: 02-05 Wellpath: Plan#7 02-05A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB OS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Date: . 3/26/2Q03 .. Time: 11 :.13:46 Page: co-ordinate(NE) Reference: Well: 02~05, True North Vertical (TVD) Referellce: System:.. Mean Sea· Level Sedioo(VS) Reference: Well (0.00N,O.OOE,287.00Azi) SurveyCalculåtion Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5948800.37 ft 687638.44 ft Latitude: Longitude: North Reference: Grid Convergence: 70 15 53.847 N 148 28 58.060 W True 1 .43 deg Well: 02-05 Slot Name: 05 02-05 Well Position: +N/-S 1218.90 ft Northing: 5950042.29 ft Latitude: 70 16 5.835 N +E/-W 941.92 ft Easting : 688549.63 ft Longitude: 148 28 30.643 W Position Uncertainty: 0.00 ft WeUpath: Plan#702-05A 500292008101 Current Datum: 9 : 05 11/7/197000:00 Magnetic Data: 3/26/2003 Field Strength: 57550 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description Dip. Dir. 02-05A Polygon7.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 02-05 T7.4 02-05 T7.3 02-05 T7.2 02-05 T7.1 Annotation MD TVD ft ft 11100.00 8705.95 TIP 11150.00 8738.07 KOP 11164.00 8746.52 3 11264.00 8793.87 4 11364.00 8831.57 5 11564.00 8910.37 6 11774.00 8953.65 7 11974.00 8949.59 8 12374.00 8935.19 9 12674.00 8927.57 10 12774.00 8919.40 11 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8875.00 8888.00 8921.00 8953.00 Height 64.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 02-05 11100.00 ft Mean Sea Level 26.00 deg 80.83 deg Direction deg 287.00 +N/-S ft 0.00 l~laR .... Map. :<¡:.,....,.- Latitude.,.--> ~__ I..olIgitude :---> +Nl-S +E/-W Northing Easting Deg· Min See Deg··Min Sec ft ft ft ft 2250.04 -7165.95 5952112.00 681330.00 70 16 27.930 N 148 31 59.292 W 2250.04 -7165.95 5952112.00 681330.00 70 16 27.930 N 148 31 59.292 W 2884.87 -7389.13 5952741.00 681091.00 70 16 34.172 N 148 32 5.808 W 2784.02 -6598.36 5952660.00 681884.00 70 16 33.187 N 148 31 42.779 W 2453.73 -5194.11 5952365.00 683296.00 70 16 29.950 N 148 31 1.882 W 1947.51 -5352.85 5951855.00 683150.00 70 16 24.970 N 148 31 6.494 W 2341.48 -6503.41 5952220.00 681990.00 70 16 28.836 N 148 31 40.003 W 2528.37 -7174.98 5952390.00 681314.00 70 16 30.668 N 148 31 59.563 W 2488.46 -6739.82 5952361.00 681750.00 70 16 30.279 N 148 31 46.891 W 2471.40 -6538.17 5952349.00 681952.00 70 16 30.113 N 148 31 41.019 W 2260.55 -5589.10 5952162.00 682906.00 70 16 28.047 N 148 31 13.379 W ) BP ) ... bp BAK.. IIU.... Baker Hughes INTEQ Planning Report I,N''I"EQ Company: BP Arnoco Date: ,3/26/2003 Time:, ",' 11 : 13:46 Page: 2 Field: Prudhoe Bay Co-ordlnate(NE) Reference: WeU:02-05, True North Site: PB OS 02 Vertical (TVJ:}) Refere~ce: System: Mean Sealevel Well: 02-05 Sectiön{VS) Reference: Well (0.00N.0.00E,287.00Azi) Wellpath: Plan#7 02-05A Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 12899.00 8897.84 12 12974.00 8888.49 13 13149.00 8882.19 14 13420.00 8874.54 TO Plan: Plan #7 Date Composed: 3/26/2003 New targets Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +Nl~S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ftdegl100ft degl100ft deg 11100.00 49.97 304.91 8705.95 1907.92 -5078.83 0.00 0.00 0.00 0.00 11150.00 50.08 305.11 8738.07 1929.91 -5110.21 0.38 0.22 0.40 54.40 11164.00 55.68 305.11 8746.52 1936.32 -5119.34 40.00 40.00 0.00 0.00 11264.00 67.68 305.11 8793.87 1986.86 -5191.22 12.00 12.00 0.00 0.00 11364.00 68.19 318.05 8831.57 2048.21 -5260.34 12.00 0.51 12.94 90.00 11564.00 66.11 292.07 8910.37 2153.16 -5409.33 12.00 -1.04 -12.99 -100.00 11774.00 89.97 283.70 8953.65 2215.09 -5603.45 12.00 11.36 -3.99 -20.00 11974.00 92.33 307.59 8949.59 2300.97 -5782.41 12.00 1.18 11.95 84.20 12374.00 91.56 259.56 8935.19 2392.03 -6159.72 12.00 -0.19 -12.01 -90.00 12674.00 91.26 295.57 8927.57 2430.88 -6452.14 12.00 -0.10 12.00 90.00 12774.00 98.09 285.67 8919.40 2465.96 -6545.24 12.00 6.83 -9.91 -55.00 12899.00 101.67 270.88 8897.84 2483.70 -6666.71 12.00 2.86 -11.83 -75.00 12974.00 92.67 270.88 8888.49 2484.84 -6741.04 12.00 -12.00 0.00 180.00 13149.00 91.42 291.85 8882.19 2519.12 -6911.54 12.00 -0.72 11.99 93.00 13420.00 91.73 259.32 8874.54 2545.15 -7177.53 12.00 0.12 -12.00 -89.00 Survey MD Incl Azim SSTVD N/S E/W MapN MapE VS D.LS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 11100.00 49.97 304.91 8705.95 1907.92 -5078.83 5951822.29 683424.91 5414.73 0.00 0.00 TIP 11125.00 50.02 305.01 8722.02 1918.90 -5094.52 5951832.86 683408.95 5432.95 0.38 54.40 MWD 11150.00 50.08 305.11 8738.07 1929.91 -5110.21 5951843.48 683392.99 5451.17 0.38 54.33 KOP 11164.00 55.68 305.11 8746.52 1936.32 -5119.34 5951849.66 683383.70 5461.77 40.00 0.00 3 11175.00 57.00 305.11 8752.61 1941.59 -5126.83 5951854.74 683376.08 5470.48 12.00 0.00 MWD 11200.00 60.00 305.11 8765.68 1953.85 -5144.26 5951866.56 683358.35 5490.73 12.00 0.00 MWO 11225.00 63.00 305.11 8777 .60 1966.48 -5162.23 5951878.74 683340.07 5511.61 12.00 0.00 MWD 11250.00 66.00 305.11 8788.36 1979.46 -5180.69 5951891.25 683321.29 5533.06 12.00 0.00 MWD 11264.00 67.68 305.11 8793.87 1986.86 -5191.22 5951898.38 683310.58 5545.29 12.00 0.00 4 11275.00 67.69 306.54 8798.05 1992.82 -5199.47 5951904.13 683302.18 5554.92 12.00 90.00 MWD 11300.00 67.75 309.78 8807.53 2007.11 -5217.66 5951917.96 683283.65 5576.49 12.00 89.46 MWO 11325.00 67.87 313.02 8816.97 2022.41 -5235.02 5951932.82 683265.91 5597.57 12.00 88.23 MWD 11350.00 68.06 316.25 8826.36 2038.69 -5251.51 5951948.68 683249.02 5618.10 12.00 87.01 MWD 11364.00 68.19 318.05 8831 .57 2048.21 -5260.34 5951957.98 683239.95 5629.33 12.00 85.79 5 11375.00 67.97 316.65 8835.68 2055.72 -5267.26 5951965.31 683232.85 5638.14 12.00 260.00 MWD 11400.00 67.51 313.45 8845.15 2072.09 -5283.60 5951981.27 683216.10 5658.55 12.00 260.52 MWD 11425.00 67.11 310.22 8854.80 2087.47 -5300.78 5951996.21 683198.54 5679.48 12.00 261.74 MWD 11450.00 66.77 306.98 8864.59 2101.82 -5318.75 5952010.11 683180.22 5700.86 12.00 262.98 MWD 11475.00 66.51 303.73 8874.51 2115.10 -5337.47 5952022.91 683161.17 5722.64 12.00 264.25 MWD 11476.24 66.50 303.57 8875.00 2115.73 -5338.42 5952023.52 683160.21 5723.73 12.00 265.54 02-05 T7 11500.00 66.31 300.46 8884.51 2127.27 -5356.88 5952034.59 683141.47 5744.76 12.00 265.61 MWD 11508.67 66.26 299.33 8888.00 2131.23 -5363.75 5952038.37 683134.50 5752.49 12.00 266.85 02-05 T7 11525.00 66.18 297.19 8894.59 2138.30 -5376.92 5952045.11 683121.16 5767.15 12.00 267.31 MWD 11550.00 66.12 293.91 8904.70 2148.16 -5397.54 5952054.45 683100.29 5789.76 12.00 268.17 MWD 11564.00 66.11 292.07 8910.37 2153.16 -5409.33 5952059.15 683088.39 5802.49 12.00 269.49 6 11575.00 67.35 291.58 8914.71 2156.92 -5418.71 5952062.67 683078.92 5812.56 12.00 340.00 MWD ) BP ) R..I bp BAKE. HUGHlfS Baker Hughes INTEQ Planning Report IN'l' E~Q Company: BP Amoco Date: 3/26/2003 Time: 11 :13:46 Page: 3 Field: Prudhoe Bay Co~rdinåte(NE) Reference: Well: 02-05, True. North Site: PB OS 02 Vertical (TVD) Reference: System: Mean Sea Level Well: 02-05 Section (VS) Reference: Well (O.OON ,O.00E,287.00Azi) Wellpath: Plan#7.02-05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg ------.... 11592.01 69.28 290.84 8921.00 2162.63 -5433.45 5952068.02 683064.04 5828.32 12.00 340.19 02-05 T7 11600.00 70.18 290.50 8923.77 2165.28 -5440.46 5952070.49 683056.97 5835.80 12.00 340.47 MWO 11625.00 73.01 289.46 8931.66 2173.38 -5462.75 5952078.03 683034.48 5859.49 12.00 340.58 MWO 11650.00 75.85 288.45 8938.37 2181.20 -5485.52 5952085.28 683011.52 5883.55 12.00 340.91 MWO 11675.00 78.69 287.46 8943.88 2188.71 -5508.72 5952092.21 682988.15 5907.93 12.00 341.19 MWO 11700.00 81.54 286.49 8948.17 2195.90 -5532.27 5952098.80 682964.42 5932.56 12.00 341.40 MWD 11725.00 84.38 285.54 8951.23 2202.75 -5556.12 5952105.05 682940.41 5957.36 12.00 341.57 MWD 11750.00 87.23 284.60 8953.06 2209.23 -5580.19 5952110.92 682916.19 5982.28 12.00 341.69 MWD 11774.00 89.97 283.70 8953.65 2215.09 -5603.45 5952116.20 682892.79 6006.24 12.00 341.75 7 11775.00 89.98 283.81 8953.65 2215.33 -5604.43 5952116.42 682891.81 6007.24 12.00 84.20 MWD 11800.00 90.28 286.80 8953.59 2221.93 -5628.54 5952122.41 682867.54 6032.22 12.00 84.20 MWD 11825.00 90.58 289.78 8953.40 2229.77 -5652.27 5952129.66 682843.62 6057.21 12.00 84.21 MWD 11850.00 90.89 292.77 8953.08 2238.84 -5675.56 5952138.14 682820.11 6082.14 12.00 84.23 MWD 11875.00 91.18 295.75 8952.63 2249.11 -5698.35 5952147.83 682797.08 6106.93 12.00 84.27 MWD 11900.00 91.48 298.74 8952.05 2260.55 -5720.56 5952158.72 682774.58 6131.52 12.00 84.32 MWD 11925.00 91.77 301.73 8951.34 2273.14 -5742.15 5952170.75 682752.69 6155.85 12.00 84.39 MWD 11950.00 92.06 304.72 8950.50 2286.82 -5763.05 5952183.91 682731.45 6179.84 12.00 84.48 MWD 11974.00 92.33 307.59 8949.59 2300.97 -5782.41 5952197.57 682711.74 6202.49 12.00 84.58 8 11975.00 92.33 307.4 7 8949.55 2301.58 -5783.21 5952198.16 682710.93 6203.42 12.00 270.00 MWD 12000.00 92.32 304.46 8948.53 2316.25 -5803.42 5952212.31 682690.36 6227.05 12.00 270.00 MWD 12025.00 92.31 301 .46 8947.52 2329.84 -5824.38 5952225.37 682669.07 6251.06 12.00 269.87 MWD 12050.00 92.30 298.46 8946.51 2342.31 -5846.02 5952237.30 682647.13 6275.40 12.00 269.75 MWD 12075.00 92.27 295.46 8945.52 2353.63 -5868.28 5952248.06 682624.59 6300.00 12.00 269.63 MWD 12100.00 92.25 292.45 8944.53 2363.77 -5891.11 5952257.62 682601.52 6324.79 12.00 269.51 MWD 12125.00 92.21 289.45 8943.56 2372.71 -5914.43 5952265.97 682577.97 6349.71 12.00 269.39 MWD 12150.00 92.17 286.45 8942.60 2380.41 -5938.20 5952273.07 682554.03 6374.69 12.00 269.28 MWD 12175.00 92.12 283.45 8941.67 2386.85 -5962.33 5952278.91 682529.74 6399.65 12.00 269.16 MWD 12200.00 92.07 280.45 8940.75 2392.02 -5986.77 5952283.46 682505.18 6424.54 12.00 269.05 MWD 12225.00 92.01 277 .45 8939.86 2395.90 -6011.45 5952286.73 682480.41 6449.27 12.00 268.94 MWD 12250.00 91.95 274.44 8939.00 2398.49 -6036.30 5952288.69 682455.51 6473.79 12.00 268.83 MWD 12275.00 91.88 271.44 8938.16 2399.77 -6061.25 5952289.35 682430.54 6498.02 12.00 268.73 MWD 12300.00 91.80 268.44 8937.36 2399.75 -6086.23 5952288.70 682405.56 6521.91 12.00 268.63 MWD 12325.00 91.73 265.44 8936.59 2398.42 -6111.18 5952286.74 682380.66 6545.38 12.00 268.53 MWD 12350.00 91.64 262.44 8935.86 2395.78 -6136.03 5952283.48 682355.89 6568.37 12.00 268.44 MWD 12374.00 91.56 259.56 8935.19 2392.03 -6159.72 5952279.14 682332.30 6589.93 12.00 268.35 9 12375.00 91.56 259.68 8935.16 2391.85 -6160.70 5952278.94 682331.32 6590.82 12.00 90.00 MWD 12400.00 91.55 262.68 8934.48 2388.02 -6185.40 5952274.49 682306.73 6613.31 12.00 90.00 MWD 12425.00 91.55 265.68 8933.80 2385.49 -6210.25 5952271.33 682281.94 6636.34 12.00 90.08 MWD 12450.00 91.54 268.69 8933.13 2384.26 -6235.21 5952269.48 682257.03 6659.85 12.00 90.17 MWD 12475.00 91.52 271.69 8932.46 2384.34 -6260.20 5952268.94 682232.04 6683.77 12.00 90.25 MWD 12500.00 91.50 274.69 8931.80 2385.73 -6285.15 5952269.70 682207.07 6708.04 12.00 90.33 MWD 12525.00 91.48 277.69 8931.15 2388.42 -6309.99 5952271.77 682182.17 6732.58 12.00 90.41 MWD 12550.00 91 .45 280.69 8930.51 2392.41 -6334.66 5952275.14 682157.41 6757.34 12.00 90.48 MWD 12575.00 91.42 283.69 8929.89 2397.69 -6359.09 5952279.81 682132.86 6782.24 12.00 90.56 MWD 12600.00 91.38 286.69 8929.28 2404.24 -6383.20 5952285.75 682108.59 6807.22 12.00 90.64 MWD 12625.00 91.35 289.69 8928.68 2412.04 -6406.95 5952292.95 682084.66 6832.20 12.00 90.71 MWD 12650.00 91.30 292.69 8928.10 2421.07 -6430.25 5952301.40 682061.14 6857.13 12.00 90.78 MWD 12674.00 91.26 295.57 8927.57 2430.88 -6452.14 5952310.65 682039.01 6880.93 12.00 90.85 10 12675.00 91.33 295.47 8927.54 2431.31 -6453.04 5952311.06 682038.10 6881.92 12.00 305.00 MWD 12700.00 93.05 293.01 8926.59 2441.57 -6475.82 5952320.74 682015.07 6906.70 12.00 305.00 MWD 12725.00 94.76 290.54 8924.89 2450.82 -6498.98 5952329.42 681991.69 6931.55 12.00 304.90 MWD 12750.00 96.46 288.06 8922.44 2459.05 -6522.46 5952337.05 681968.02 6956.41 12.00 304.74 MWD 12774.00 98.09 285.67 8919.40 2465.96 -6545.24 5952343.38 681945.07 6980.22 12.00 304.49 11 ObP 'ì~ BP ) ...1 ) ... .' , ' Baker Hughes INTEQ Planning Report IN'IEC) Company: BP Amoco Date: 3/26/2003 Time: 11 :13:46 Page: 4 FIeld: Prudhoe Bay Co..ordinate(NE)" Reference: Well: 02-05, True North Site: PB DS 02 Vertical (TVD) Reference: System: M~an Sea Level Well: 02~05 Section· (VS)' Reference: Well (O.00N.0.00E~287.00Azi) Wellpath: Plan#7 02-05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 12775.00 98.12 285.55 8919.26 2466.22 -6546.19 5952343.63 681944.11 6981.21 12.00 285.00 MWD 12800.00 98.89 282.62 8915.56 2472.24 -6570.17 5952349.04 681919.99 7005.90 12.00 284.98 MWD 12825.00 99.63 279.67 8911.54 2477.01 -6594.37 5952353.20 681895.67 7030.44 12.00 284.55 MWD 12850.00 100.34 276.71 8907.21 2480.52 -6618.74 5952356.10 681871.23 7054.77 12.00 284.08 MWD 12875.00 101.03 273.74 8902.57 2482.75 -6643.20 5952357.72 681846.72 7078.81 12.00 283.56 MWD 12899.00 101.67 270.88 8897.84 2483.70 -6666.71 5952358.08 681823.20 7101.57 12.00 283.01 12 12900.00 101.55 270.88 8897.64 2483.72 -6667.69 5952358.07 681822.22 7102.51 12.00 180.00 MWD 12925.00 98.55 270.88 8893.28 2484.09 -6692.30 5952357.83 681797.61 7126.16 12.00 180.00 MWD 12950.00 95.55 270.88 8890.21 2484.4 7 -6717.11 5952357.59 681772.80 7149.99 12.00 180.00 MWD 12974.00 92.67 270.88 8888.49 2484.84 -6741.04 5952357.36 681748.87 7172.99 12.00 180.00 13 12975.00 92.66 271.00 8888.45 2484.86 -6742.04 5952357.35 681747.87 7173.95 12.00 93.00 MWD 13000.00 92.50 274.00 8887.32 2485.94 -6766.99 5952357.81 681722.90 7198.12 12.00 93.01 MWD 13025.00 92.33 276.99 8886.27 2488.34 -6791.85 5952359.58 681697.99 7222.59 12.00 93.14 MWD 13050.00 92.16 279.99 8885.29 2492.02 -6816.55 5952362.65 681673.20 7247.30 12.00 93.27 MWD 13075.00 91.98 282.99 8884.38 2497.00 -6841.03 5952367.01 681648.61 7272.16 12.00 93.38 MWD 13100.00 91.79 285.98 8883.56 2503.25 -6865.22 5952372.65 681624.27 7297.12 12.00 93.49 MWD 13125.00 91.60 288.98 8882.82 2510.76 -6889.05 5952379.55 681600.26 7322.11 12.00 93.59 MWD 13149.00 91.42 291.85 8882.19 2519.12 -6911.54 5952387.36 681577.58 7346.05 12.00 93.68 14 13150.00 91.42 291.73 8882.16 2519.49 -6912.46 5952387.70 681576.64 7347.05 12.00 271.00 MWD 13175.00 91.47 288.73 8881.53 2528.14 -6935.91 5952395.76 681552.99 7372.00 12.00 271.00 MWD 13200.00 91.52 285.73 8880.88 2535.54 -6959.78 5952402.56 681528.94 7396.99 12.00 270.92 MWD 13225.00 91.56 282.73 8880.21 2541.68 -6984.00 5952408.09 681504.58 7421.95 12.00 270.84 MWD 13250.00 91.59 279.73 8879.52 2546.55 -7008.51 5952412.34 681479.95 7446.81 12.00 270.76 MWD 13275.00 91.63 276.73 8878.82 2550.13 -7033.24 5952415.30 681455.14 7471.50 12.00 270.68 MWD 13300.00 91.66 273.73 8878.10 2552.40 -7058.12 5952416.95 681430.21 7495.97 12.00 270.60 MWD 13325.00 91.68 270.73 8877.37 2553.38 -7083.09 5952417.30 681405.23 7520.13 12.00 270.51 MWD 13350.00 91.70 267.73 8876.64 2553.04 -7108.07 5952416.34 681380.26 7543.92 12.00 270.42 MWD 13375.00 91.72 264.72 8875.89 2551.39 -7133.00 5952414.07 681355.38 7567.28 12.00 270.33 MWD 13400.00 91.73 261.72 8875.14 2548.45 -7157.82 5952410.50 681330.65 7590.15 12.00 270.24 MWD 13420.00 91.73 259.32 8874.54 2545.15 -7177.53 5952406.71 681311.03 7608.04 12.00 270.15 TD "~ ¡ ) NOKD( c~ All Measurements are from top of Riser 4/29/2003 :.... Q) en -- a: top of bag \'1 ",1 --r" ~! II I I , L H BAG 7 1/16" 5000psi bttm of bag middle of pipe/slips B lind/Shears ...".,.........,.... I / TOTs 2 3/8" combi ram/slips .-....--.-....-....... 7 1/16" 5000psi ,...--. r- Mud Cross Mud Cross ~ 7 1/16" 5000psi '-- variable bore pipe 3 1/2"-2 7/8" ,.........,..,.,..... I / TOTs 2 3/8" combi ram/slips ...-..-..-.-.......... 7 1/16" 5000psi middle of slips middle of pipes middle of flow cross middle of blind/shears Flow Tee p055053 DATE 4/4/2003 INV# CK040103C INVOICE I CREDIT MEMO /~"'" THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK995J9·6612 PAY: ~'- TO THE ORDER OF: 8. DESCRIPTION TOTAL ... GROSS PERMIT TO DRILL FEE ?~~) ,~ - () S f-) NATIONAL CITY BANK Ashland, Ohio r:...9.·........ ..f..· .'. !~I~......,.. ..,II.".I.·.I..·..() .tW.;)' fl~:,··...·.·...··,.··· .... .-"·llo<, ,., It'·. \., ".'. uJ $1o__."..:_:__'J(la --lt~1 "..:-::!.HIHt "'UII,'_'1I1I" .-.-:- . - ", . .' .'. .-:.-- -."".. ... -.- -. .. .. '.. .' . -." "-,--' -- - - . "n·.·.· .'n _ _ _ ,'." :. '.: "'." ...-.-......::. ..:...:.;...~:.-... - :;;.~-.;~.-.:;;;:.::.'- -' -."."::::-.' .' '. ~-./.::,.._:..- :.;::.... ÄLASKA ~IL ~GAS CQNSER\lÂTION CÇ)tv1MISSION '. 333 W 7TH A\l-ENl.JE SUITE 100·...·) . ANCHORAGE:, AK 91:)501-3539 DATE DATE CHECK NO. 4/4/2003 055053 1110 5 50 5 :I 1/1 I: 0 ~ . 2 0 :I 8 G 5.: O. 2 7 a G b III VENDOR DISCOUNT NET H 56-389 412 No. p 0550.53 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT April 4, 2003 .. ******~$1_9"Q_,9?**~**~~ _-:~~ ~. '. ...... " ., .,'''' ".( -- '. ._\,..... ".... t N()TVAL$:A'ft'~~~1~"2~Ö: ~s:~~:: ::.:- ... ,:,,:,:}~,::: '.:.::/~-..::: :-:')\ . .. JAf . .....~............ ...... ............ .:\.:~:~·::··~0fi 'r . . '. ~::". ::.... :.\ .:.._~\,.. I r .J l''f9,jI. .... .. ." .... . i:./:\.~.·:: ::;:.:':'~::< '. .<t:~¡~~ ;.\:~.~':..:'~;~ ~::~\~..::) :·(-~:::··:":·Ù:'~ Rev: 07/10/02 C\jody\templates \ J TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJPARAGRAPHS TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception.. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY IfjJ)( WELL NAME /ðc.¡ 02.-05/1 PROGRAM: Exp _ Dev;zL Redrll X Re-Enter _ Serv _ Wellbore seg_ FIELD & POOL c.. 'i () I ~ (> INIT CLASS IJ ~ / - ð~1 GEOL AREA r¡' ?,..; UNIT# /1 ç. _ç r\ ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . f0, N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N /~~ 0 <.. - c.J S.4 6. Well located proper distance from other wells.. . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N /Jt?.; // __ / 8. If deviated, is we II bore plat included.. . . . . . . . . . . . . . Y N I1ß:.- ~o3 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Y p( ft/."q, (Service Well Only) 14. All wells wlin X mile area of review identified. KN ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . \UN 16. Surface casing protects all known USDWs. . . . . . . y' N 17. CMT vol adequate to circulate on conductor & surf csg. . . . N ':1/~ 18. CMT vol adequate to tie-in long string to surf csg. . ~ ,,,,(It- 19. CMT will cover all known productive horizons. . . . . . . . . N . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N G-TJD U 22. If a re-drill, has a 10-403 for abandonment been approved. . . . NN ~'I 0 ~ . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . . . -¥-N- NIÆ- A A I. I ~ 7 25. Drilling fluid program schematic & equip list adequate. . . . . NN M &vK; (VI v-t íJ' P PI · 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . P 27. BOPE press rating appropriate; test to "35'00 psig. N )./l $. -¿ 'Z-lq P ~ .. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥--N N/It- ~~ (bD . Y )J~A.. Y N N APPR DATE APPR DATE W'íA- sisio"S (Service Well Only) GEOLOGY APPR DATE /t¿ çhjð3 (Exploratory Only) ~~~~v I .JI /99'- 0/_( ~/,)I,-,..-,,~ £~ ~ ~// (I..h", p-el ø<J'~"'.j bi;. r.l,jj..J he ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISS~ Commentsllnstructions: RP¿ TEM JDH JBR (.0. . DTS /' MJW ~~ SFD - WGA Rev: 07/12/02 32. 33. 34. 35. 36. Permit can be issued wlo hydrogen sulfide measures. . . . . Data presented on potential overpressure zones. . . . . . . . Seismic analysis of shallow gas zones. . . . . . . . . . . . . Seabed condition survey (if off-shore). . . . . .. ...... Contact namelphone for weekly progress reports. ...... G:\geology\perm its\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding infonnation, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Thu JulIO 14:43:57 2003 ) ao a -D~d-. II ~("6 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.. ... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name....... ........ . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments...... .......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002454192 B. JAHN J. EGBEJIMBA MWD RUN 5 MW0002454192 S. LATZ SARBER/SEVCI MWD RUN 11 MW0002454192 S. LATZ SARBER/SEVCI MWD RUN 14 MW0002454192 S. LATZ SARBER/WHITL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 02-05A 500292008101 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 10-JUL-03 MWD RUN 2 MW0002454192 B. JAHN J. EGBEJIMBA MWD RUN 9 MW0002454192 S. LATZ SARBER/SEVCI MWD RUN 12 MW0002454192 S. LATZ SARBER/WHITL 36 11N 14E 1182 1793 64.00 MWD RUN 3 MW0002454192 B. JAHN J. EGBEJIMBA MWD RUN 10 MW0002454192 S. LATZ SARBER/SEVCI MWD RUN 13 MW0002454192 S. LATZ SARBER/WHITL ) ) GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 10392.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELLBORE WAS EFFECTED BY SIDETRACKING OFF OF AN OPEN-HOLE WHIPSTOCK POSITIONED AT 11309.5'MD, WITHIN THE RUN 5 INTERVAL. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THIS WAS A TIE-IN RUN - THE SGRC DATA AND SROP (ACTUALLY RUNNING SPEED) DATA WERE ACQUIRED WHILE POOH. 5. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DGR. A CEMENT 'RAMP' WAS DRILLED DURING RUN 2. THE WINDOW WAS MILLED ON RUN 3, AND 7' OF NEW HOLE WERE ALSO DRILLED. THE TOP OF THE WINDOW WAS 11180' MD AND THE BOTTOM WAS 11186'MD. THE PURPOSE OF RUN 4 WAS DRESS THE WINDOW - NO DATA WERE ACQUIRED. 6. MWD RUN 5 COMPRISED DIRECTIONAL WITH DGR, AND SUPER-SLIM ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (SSEWR). 7. MWD RUN 8 COMPRISED DIRECTIONAL WITH DGR. THIS WAS A CLEAN-OUT RUN PRIOR TO ATTEMPTING THE OPEN-HOLE SIDETRACK IN RUN 9. NO DATA WERE ACQUIRED. 8. MWD RUNS 9 - 14 COMPRISED DIRECTIONAL WITH DGR. 9. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER MCNL GAMMA RAY LOG RUN IN 2-05A ON 2 JUNE 2003. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED VIA E-MAIL BY DEWAYNE SCHNORR ON 2 JULY 2003. 10. MWD RUNS 1 - 5, 9 - 14 REPRESENT WELL 2-05A WITH API#: 50-029-20081-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 13409'MD/8895'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY ( SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ ) File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number...... ... ..1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 ) clipped curves; all bit runs merged. .5000 START DEPTH 10073.5 10105.5 11181.0 11181.0 11181.0 11181.0 11181.0 STOP DEPTH 13376.0 13403.0 11310.5 11310.5 11310.5 11310.5 11310.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10073.5 10076.0 10087.5 10094.0 10107.5 10112.5 10131. 0 10135.5 10144.0 10151. 0 10168.5 10172.5 10175.0 10183.5 10192.5 10218.5 10226.0 10243.0 10247.5 10255.0 10310.0 10328.0 10347.5 10357.0 10366.0 10382.0 10384.5 10388.5 10394.5 10412.0 10422.5 10436.0 10441. 0 10463.5 10469.0 10505.5 10514.0 10567.5 10599.0 10608.0 10613.0 10617.5 10640.5 10651. 0 GR 10076.5 10079.0 10087.0 10095.0 10107.5 10112.0 10131.0 10135.5 10141. 5 10151. 5 10166.5 10170.0 10173.0 10182.0 10190.5 10218.5 10225.5 10245.5 10250.5 10256.0 10310.5 10326.5 10346.0 10354.0 10360.5 10376.0 10379.0 10384.5 10389.5 10405.5 10415.0 10429.5 10434.0 10458.5 10463.0 10504.0 10514.5 10567.5 10598.0 10607.5 10612.5 10616.0 10641.0 10650.5 ) ) 10656.5 10698.0 10707.0 10716.0 10734.5 10741.0 10763.0 10768.5 10788.5 10793.0 10797.0 10802.0 10812.0 10825.0 10830.0 10846.0 10860.0 10875.0 10879.0 10897.0 10902.0 10905.5 10908.5 10927.0 10939.5 10974.0 11014.5 11038.5 11059.5 11089.0 11100.0 11103.5 11117.0 11131.0 11161. 5 11165.5 11173.5 11206.5 11216.5 11230.5 11243.5 11251.5 11260.5 11273.0 11275.5 11284.0 11310.5 11322.0 11328.0 11337.0 11354.5 11365.5 11373.0 11384.0 11410.0 11416.5 11426.5 11478.0 11499.5 11519.0 11521.0 11528.5 11539.0 11544.5 11552.5 11587.0 11601.0 11614.0 11634.5 11643.0 11665.5 11673.0 11679.0 11689.5 11694.5 11714.0 10656.5 10699.0 10707.5 10714.0 10734.0 10740.5 10760.5 10768.5 10787.5 10794.0 10798.0 10803.5 10813.0 10826.5 10831. 0 10843.5 10857.5 10876.0 10879.5 10897.5 10906.0 10908.5 10911.0 10927.5 10939.0 10972.5 11011. 5 11036.0 11058.0 11086.0 11097.0 11102.0 11116.5 11128.5 11160.0 11164.0 11171.5 11208.5 11217.5 11229.0 11242.5 11251.0 11260.0 11275.5 11277.5 11285.0 11309.5 11323.0 11328.5 11338.0 11355.5 11366.0 11373.0 11382.0 11408.0 11415.5 11425.5 11477.5 11497.0 11518.5 11521.0 11529.5 11539.5 11545.5 11554.0 11587.5 11601.0 11613.5 11635.0 11644.0 11666.0 11672.0 11679.0 11687.5 11694.0 11713.0 ) ) 11724.5 11755.5 11760.5 11783.5 11789.0 11805.0 11811.5 11820.0 11821.0 11827.5 11843.5 11852.5 11854.5 11869.5 11881.5 11894.5 11904.5 11913.0 11948.5 11968.5 11976.0 11995.0 12024.0 12031.0 12047.0 12050.5 12054.5 12069.0 12080.0 12096.5 12101. 5 12110.0 12126.5 12148.0 12154.5 12164.5 12196.0 12208.5 12215.5 12228.0 12242.0 12249.5 12267.5 12278.0 12286.5 12309.5 12315.0 12323.0 12328.0 12336.0 12368.5 12371. 0 12385.0 12398.5 12404.0 12409.0 12434.0 12438.0 12449.5 12465.0 12510.5 12531. 5 12541. 0 12548.5 12572.5 12599.5 12626.0 12652.0 12664.5 12674.5 12686.5 12705.5 12710.0 12718.5 12727.0 12740.5 11723.5 11759.5 11 765.0 11786.5 11794.0 11807.5 11815.5 11823.0 11824.0 11826.5 11845.0 11854.0 11856.5 11871.0 11884.5 11896.0 11906.5 11915.5 11949.0 11971.0 11978.0 11999.0 12028.5 12039.5 12057.5 12061. 5 12064.5 12077.5 12087.0 12104.5 12110.0 12118.0 12132.0 12151.5 12154.5 12165.0 12197.5 12210.0 12216.0 12230.0 12243.0 12250.0 12270.5 12279.5 12289.0 12310.5 12316.5 12326.0 12332.0 12339.5 12371. 0 12373.0 12392.5 12405.5 12410.5 12415.0 12441. 5 12445.0 12457.0 12472.5 12515.5 12535.0 12546.5 12554.0 12577.0 12608.0 12634.0 12660.5 12678.0 12686.5 12693.5 12711. 5 12714.5 12725.0 12730.5 12745.0 12743.0 12748.0 12750.5 12757.5 12766.0 12770.5 12774.5 12791. 0 12803.0 12810.5 12812.5 12822.0 12842.5 12865.5 12873.0 12880.5 12918.5 12924.0 12935.5 12951.0 12953.0 12966.5 12987.5 12994.0 13010.0 13019.0 13023.5 13037.0 13051.5 13060.5 13071.5 13093.0 13095.0 13113.5 13119.5 13127.0 13146.5 13159.5 13163.0 13168.5 13176.0 13180.0 13189.5 13210.5 13223.5 13226.0 13250.5 13253.5 13259.5 13310.0 13334.5 13344.5 13403.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: ') 12747.5 12751. 5 12754.5 12760.0 12770.0 12775.5 12780.0 12798.0 12809.0 12816.5 12820.5 12831. 0 12850.0 12869.0 12873.0 12883.0 12917.0 12923.0 12938.0 12959.0 12960.5 12972.0 12993.0 12999.5 13013.5 13023.0 13028.0 13044.0 13057.5 13066.0 13077.0 13097.5 13099.5 13118.0 13122.0 13127.5 13147.5 13165.5 13169.5 13175.0 13183.5 13187.0 13196.0 13221.0 13235.5 13236.5 13260.0 13263.5 13268.0 13319.0 13341.5 13350.5 13409.0 BIT RUN NO 1 2 3 5 9 10 11 12 13 14 MERGED MAIN PASS. $ MERGE TOP 10076.5 10912.0 11180.0 11193.0 11309.5 11335.0 11527.0 12500.0 12760.0 13197.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down ) MERGE BASE 10912.0 11180.0 11193.0 11309.5 11335.0 11527.0 12500.0 12760.0 13197.0 13409.0 ) ) Optical log depth units. ........ ..Feet Data Reference Point........... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..... ......... ....... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10073.5 13403 11738.3 6660 10073.5 13403 ROP MWD FT/H 0.01 1873.1 121. 089 6596 10105.5 13403 GR MWD API 14.77 453.36 54.3346 6606 10073.5 13376 RPX MWD OHMM 1. 52 2000 84.147 260 11181 11310.5 RPS MWD OHMM 2.11 2000 99.0973 260 11181 11310.5 RPM MWD OHMM 0.16 1936.75 67.9462 260 11181 11310.5 RPD MWD OHMM 0.07 2000 95.2207 260 11181 11310.5 FET MWD HOUR 0.49 45.77 3.73062 260 11181 11310.5 First Reading For Entire File......... .10073.5 Last Reading For Entire File....... ....13403 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/07/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10076.5 10105.5 STOP DEPTH 10885.0 10912.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 18-MAY-03 Insite ) DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type. ....0 Logging Direction...... ..... ..... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................. ... .60 .1IN Max frames per record....... ..... .Undefined Absent value..................... .-999 Depth Units......... . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 4.3 Memory 10912.0 10100.0 10912.0 3.7 50.3 TOOL NUMBER 827 58 3.750 2696.0 Brine 8.50 20.0 8.0 13000 10.0 .000 .000 .000 .000 .0 169.0 .0 .0 Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10076.5 10912 10494.3 1672 10076.5 10912 ROP MWD010 FT/H 187.35 909.26 269.846 1614 10105.5 10912 GR MWD010 API 14.77 453.36 55.4777 1618 10076.5 10885 First Reading For Entire File......... .10076.5 Last Reading For Entire File.......... .10912 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... ') Version Number........ ...1.0.0 Date of Generation... ... .03/07/10 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type.... ........... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 10885.5 10912.5 STOP DEPTH 11153.0 11180.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 19-MAY-03 Insite 4.3 Memory 11180.0 10912.0 11180.0 3.7 50.3 TOOL NUMBER 82758 3.750 2696.0 Brine 8.30 .0 .0 20000 .0 .000 .000 .000 .000 .0 141.4 .0 .0 ) \ j" # REMARKS: $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing......... ........... .60 .1IN Max frames per record............ .Undefined Absent value........ ............. .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10885.5 11180 11032.8 590 10885.5 11180 ROP MWD020 FT/H 0.04 487.5 33.8703 536 10912.5 11180 GR MWD020 API 17.86 47.49 25.4381 536 10885.5 11153 First Reading For Entire File........ ..10885.5 Last Reading For Entire File......... ..11180 File Trailer Service name....... ..... .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. .... ..03/07/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 11153.5 11180.5 STOP DEPTH 11167.0 11193.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 20-MAY-03 Insite 4.3 Memory ) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.... ...... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 \ 11193.0 11180.0 11193.0 50.0 51.0 TOOL NUMBER 82758 3.800 10392.0 Water 8.50 .0 8.0 13000 10.0 Based .000 .000 .000 .000 .0 166.1 .0 .0 Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11153.5 11193 11173.3 80 11153.5 11193 ROP MWD030 FT/H 0.08 50.22 9.435 26 11180.5 11193 GR MWD030 API 20.96 34.73 25.6632 28 11153.5 11167 First Reading For Entire File......... .11153.5 Last Reading For Entire File..... ..... .11193 File Trailer Service name............ .STSL1B.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 ,) Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 5 \ ,I header data for each bit run in separate files. 5 .5000 START DEPTH 11167.5 11180.0 11180.0 11180.0 11180.0 11180.0 11193.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11276.0 11309.5 11309.5 11309.5 11309.5 11309.5 11309.5 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: 22-MAY-03 Insite 4.3 Memory 11309.0 11193.0 11309.0 50.1 77.7 TOOL NUMBER 93091 126589 4.125 10392.0 Flo Pro 8.70 65.0 8.5 23200 5.2 .160 .070 .330 .180 68.0 160.0 68.0 68.0 ) ") HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ . . . . . . . . . .0 Data Specification Block Type... ..0 Logging Direction........... ..... . Down Optical log depth units.......... .Feet Data Reference Point. ............ .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. ................... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11167.5 11309.5 11238.5 285 11167.5 11309.5 ROP MWD050 FT/H 4.08 94.34 53.9406 233 11193.5 11309.5 GR MWD050 API 20.09 122.68 36.4779 218 11167.5 11276 RPX MWD050 OHMM 1. 52 2000 88.3451 260 11180 11309.5 RPS MWD050 OHMM 2.11 2000 104.231 260 11180 11309.5 RPM MWD050 OHMM 0.16 1936.75 73.6607 260 11180 11309.5 RPD MWD050 OHMM 0.07 2000 105.588 260 11180 11309.5 FET MWD050 HOUR 0.49 45.77 4.02265 260 11180 11309.5 First Reading For Entire File......... .11167.5 Last Reading For Entire File.... ...... .11309.5 File Trailer Service name......... ... .STSLIB.005 Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation..... ..03/07/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name...... .... .STSLIB.006 Physical EOF File Header Service name..... ....... .STSLIB.006 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 ) DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ .5000 START DEPTH 11276.5 11310.0 STOP DEPTH 11307.0 11335.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units..... .... ..Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .1IN Max frames per record. .......... ..Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ) 26-MAY-03 Insite 4.3 Memory 11335.0 11309.0 11335.0 65.0 65.0 TOOL NUMBER 82758 3.750 10392.0 Flo Pro 8.70 65.0 8.5 23146 4.8 .000 .000 .000 .000 .0 149.0 .0 .0 Name Service Order DEPT ROP MWD090 GR MWD090 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam First Reading Last Reading ) ) DEPT ROP GR FT MWD090 FT/H MWD090 API 11276.5 0.01 22.68 11335 47.22 32.66 11305.8 15.3857 27.4947 118 51 62 11276.5 11310 11276.5 11335 11335 11307 First Reading For Entire File...... ... .11276.5 Last Reading For Entire File....... ... .11335 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/07/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name........... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 header data for each bit run in separate files. 10 .5000 START DEPTH 11307.5 11335.5 STOP DEPTH 11498.5 11527.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 26-MAY-03 Insite 4.3 Memory 11527.0 11335.0 11527.0 74.4 88.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10392.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) Flo Pro 8.70 65.0 8.5 23146 4.8 ) ) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 145.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............... ...0 Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units... ....... .Feet Data Reference Point..... ........ .Undefined Frame Spacing. .................. ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD100 GR MWD100 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11307.5 11527 11417.3 440 11307.5 11527 ROP MWD100 FT/H 0.5 244.14 94.4083 384 11335.5 11527 GR MWD100 API 20.89 175.54 57.7245 383 11307.5 11498.5 First Reading For Entire File......... .11307.5 Last Reading For Entire File.......... .11527 File Trailer Service name......... ... .STSLIB.007 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.... ...03/07/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name..... .... ..STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/07/10 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name..... ..STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 8 header data for each bit run in separate files. 11 .5000 ) FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 11499.0 11527.5 STOP DEPTH 12472.5 12500.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction..... ..... ...... . Down Optical log depth units... .... ....Feet Data Reference Point..... .... .... .Undefined Frame Spacing... ....... ..... ..... .60 .1IN Max frames per record. ......... ...Undefined Absent value............. ........ .-999 Depth Units....................... Datum Specification Block sub-type...O 28-MAY-03 Insite 4.3 Memory 12500.0 11527.0 12500.0 80.6 93.0 TOOL NUMBER 82758 3.750 10392.0 Flo Pro 9.20 65.0 9.0 78000 9.6 .000 .000 .000 .000 Name Service Order DEPT ROP MWD110 GR MWD110 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD110 FT/H Min 11499 0.27 Max 12500 1873.1 Mean 11999.5 87.1976 Nsam 2003 1946 } .0 159.0 .0 .0 First Reading 11499 11527.5 Last Reading 12500 12500 ) GR MWD110 API 14.92 190.67 First Reading For Entire File......... .11499 Last Reading For Entire File.......... .12500 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type........ ....... .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 9 56.2361 1948 header data for each bit run in separate files. 12 .5000 START DEPTH 12473.0 12500.5 STOP DEPTH 12731. 5 12760.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 29-MAY-03 Insite 4.3 Memory 12760.0 12500.0 12760.0 87.2 100.3 TOOL NUMBER 82758 3.750 10392.0 Flo Pro 9.30 65.0 9.5 88000 504.0 .000 .000 .0 163.0 ) 11499 12472.5 ') MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .............. ...0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units. ......... .Feet Data Reference Point............. .Undefined Frame Spacing........... ......... .60 .1IN Max frames per record... ......... .Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD120 GR MWD120 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD120 FT/H GR MWD120 API Min 12473 0.12 30.02 Mean 12616.5 59.9889 91.3598 Nsam 575 520 518 Max 12760 1323.65 229.24 First Reading For Entire File......... .12473 Last Reading For Entire File.......... .12760 File Trailer Service name............ .STSLIB.009 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.010 Physical EOF File Header Service name.... ........ .STSLIB.010 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 10 ) .0 .0 First Reading 12473 12500.5 12473 Last Reading 12760 127 60 12731. 5 header data for each bit run in separate files. 13 .5000 START DEPTH STOP DEPTH ) GR ROP $ 12732.0 12760.5 13169.5 13197.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ...... ......0 Data Specification Block Type.....O Logging Direction........ ....... ..Down Optical log depth units....... ....Feet Data Reference Point.. ........... .Undefined Frame Spacing............... ..... .60 .1IN Max frames per record........... ..Undefined Absent value........... ........ ...-999 Depth Units....................... Datum Specification Block sub-type...O ') 30-MAY-03 Insite 4.3 Memory 13197.0 12760.0 13197.0 88.3 93.3 TOOL NUMBER 82758 3.750 10392.0 Flo Pro 9.30 65.0 9.5 88000 6.8 .000 .000 .000 .000 .0 169.6 .0 .0 Name Service Order DEPT ROP MWD13 0 GR MWD13 0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12732 13197 12964.5 931 12732 13197 ROP MWD130 FT/H 6.01 397.79 77.1119 874 12760.5 13197 GR MWD130 API 21. 83 149.77 50.9259 876 12732 13169.5 ) First Reading For Entire File......... .12732 Last Reading For Entire File.......... .13197 File Trailer Service name............ .STSLIB.OI0 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.Oll Physical EOF File Header Service name............ .STSLIB.Oll Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OI0 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 11 ) header data for each bit run in separate files. 14 .5000 START DEPTH 13170.0 13197.5 STOP DEPTH 13382.0 13409.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 31-MAY-03 Insite 4.3 Memory 13409.0 13197.0 13409.0 87.7 91. 5 TOOL NUMBER 93091 3.750 10392.0 Flo Pro 9.30 65.0 9.0 105000 11.8 .000 .000 .000 .000 .0 170.0 .0 .0 '~ / # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ......... ...0 Data Specification Block Type.....O Logging Direction... ............. . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing. ................... .60 .1IN Max frames per record........... ..Undefined Absent value. ................... ..-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD140 GR MWD140 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD140 FT/H GR MWD140 API Min 13170 0.27 22.46 Max 13409 179.17 158.97 Mean 13289.5 65.2945 59.5427 Nsam 479 424 425 First Reading 13170 13197.5 13170 Last Reading 13409 13409 13382 First Reading For Entire File......... .13170 Last Reading For Entire File.......... .13409 File Trailer Service name......... ... .STSLIB.011 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/10 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.012 Physical EOF Tape Trailer Service name.... ..... ... .LISTPE Date.................... .03/07/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name..... .......... . UNKNOWN Continuation Number.... ..01 Next Tape Name........ ...UNKNOWN Comments. ............ ....STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........ ..... ...UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Physical EOF End Of LIS File Physical EOF ) ) Sperry-Sun Dr. )ing Services LIS Scan Utility ) aD 3 -D 8;1.. ,\~\?- $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 09 15:28:02 2003 Reel Header Service name.. . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/07/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te . . . . . . . . . . . . . . . . . . . . . 03/07/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 02-05Apb1 500292008170 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 09-JUL-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002454192 B. JAHN J. EGBEJIMBA MWD RUN 2 MW0002454192 B. JAHN J. EGBEJIMBA MWD RUN 3 MW0002454192 B. JAHN J. EGBEJIMBA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002454192 S. LATZ SARBER/SEVCI MWD RUN 6 MW0002454192 S. LATZ SARBER/SEVCI MWD RUN 7 MW0002454192 S. LATZ SARBER/SEVCI # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 11N 14E 1182 1793 64.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. ) (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 11180.0 4.125 4.500 11193.0 ) # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THIS WAS A TIE-IN RUN - THE SGRC DATA AND SROP (ACTUALLY RUNNING SPEED) DATA WERE ACQUIRED WHILE POOH. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL WITH DGR. A CEMENT 'RAMP' WAS DRILLED DURING RUN 2. THE WINDOW WAS MILLED ON RUN 3, AND 7' OF NEW HOLE WERE ALSO DRILLED. THE TOP OF THE WINDOW WAS 11180' MD AND THE BOTTOM WAS 11186'MD. THE PURPOSE OF RUN 4 WAS DRESS THE WINDOW - NO DATA WERE ACQUIRED. 5. MWD RUN 5 - 7 COMPRISED DIRECTIONAL WITH DGR, AND SUPER-SLIM ELECTRO- MAGNETIC WAVE RESISTIVITY - PHASE 4 (SSEWR). 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER MCNL GAMMA RAY LOG RUN IN 2-05A ON 2 JUNE 2003. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED VIA E-MAIL BY DEWAYNE SCHNORR ON 2 JULY 2003. 7. MWD RUNS 1 - 7 REPRESENT WELL 2-05A PB1 WITH API#: 50-029-20081-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12435'MD/8904'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name. . . . . . )SLIB.OOO ") Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10073.5 10105.5 11181.0 11181.0 11181.0 11181.0 11181.0 STOP DEPTH 12391.5 12436.0 12405.0 12405.0 12405.0 12405.0 12405.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 10073.5 10076.0 10087.5 10094.0 10107.5 10112.5 10131.0 10135.5 10144.0 10151.0 10168.5 10172.5 10175.0 10183.5 10192.5 10218.5 10226.0 10243.0 10247.5 10255.0 10310.0 10328.0 10347.5 10357.0 10366.0 10382.0 10384.5 10388.5 10394.5 10412.0 10422.5 10436.0 10441.0 10463.5 10469.0 10505.5 10514.0 10567.5 10599.0 10608.0 10613.0 10617.5 10640.5 10651.0 GR 10076.5 10079.0 10087.0 10095.0 10107.5 10112.0 10131.0 10135.5 10141.5 10151.5 10166.5 10170.0 10173.0 10182.0 10190.5 10218.5 10225.5 10245.5 10250.5 10256.0 10310.5 10326.5 10346.0 10354.0 10360.5 10376.0 10379.0 10384.5 10389.5 10405.5 10415.0 10429.5 10434.0 10458.5 10463.0 10504.0 10514.5 10567.5 10598.0 10607.5 10612.5 10616.0 10641.0 10650.5 10656.5 10698.0 10707.0 10716.0 10734.5 10741.0 10763.0 10768.5 10788.5 10793.0 10797.0 10802.0 10812.0 10825.0 10830.0 10846.0 10860.0 10875.0 10879.0 10902.0 10905.5 10908.5 10927.0 10939.5 10974.0 1101.4.5 11038.5 11059.5 11089.0 11100.0 11103.5 1111.7.0 11131.0 11161.5 11165.5 11173.5 11206.5 1121.6.5 11230.5 11243.5 11251.5 11260.5 11273.0 11275.5 11284.0 1131.0.5 12436.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: ) 10656._ 10699.0 10707.5 10714.0 10734.0 10740.5 10760.5 10768.5 10787.5 10794.0 10798.0 10803.5 10813.0 10826.5 10831.0 10843.5 10857.5 10876.0 10879.5 10906.0 10908.5 10911.0 10927.5 10939.0 10972.5 11011.5 11036.0 11058.0 11086.0 11097.0 11102.0 11116.5 11128.5 11160.0 11164.0 11171.5 11208.5 11217.5 11229.0 11242.5 11251.0 11260.0 11275.5 11277.5 11285.0 11309.5 12435.0 BIT RUN NO 1 2 3 5 6 7 MERGED MAIN PASS. $ ) MERGE TOP 10076.5 10912.0 11180.0 11193.0 11707.0 12133.0 MERGE BASE 10912.0 11180.0 11193.0 11707.0 12133.0 12435.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined \ . } Frame Spaclng........... ~...... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O ) Service Order Units FT FT/H API OHMM OHMM OHMM OHMM HOUR size 4 4 4 4 4 4 4 4 Nsam 1 1 1 1 1 1 1 1 Code Offset o 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 Name DEPT ROP GR RPX RPS RPM RPD FET MWD MWD MWD MWD MWD MWD MWD Rep 68 68 68 68 68 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10073.5 12436 11254.8 4726 10073.5 12436 ROP MWD FT/H 0.04 2501.69 132.99 4662 10105.5 12436 GR MWD API 14.77 453.36 64.7246 4637 10073.5 12391.5 RPX MWD OHMM 1.52 2000 30.3259 2449 11181 12405 RPS MWD OHMM 2.11 2000 34.5534 2449 11181 12405 RPM MWD OHMM 0.16 1936.75 32.1976 2449 11181 12405 RPD MWD OHMM 0.07 2000 36.8916 2449 11181 12405 FET MWD HOUR 0.37 45.77 2.22657 2449 11181 12405 First Reading For Entire File......... .10073.5 Last Reading For Entire File.......... .12436 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name...... ...... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10076.5 10105.5 STOP DEPTH 10885.0 10912.0 $ ') # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 18-MAY-03 Insite 4.3 Memory 10912.0 10100.0 10912.0 3.7 50.3 TOOL NUMBER 82758 3.750 2696.0 Brine 8.50 20.0 8.0 13000 10.0 .000 .000 .000 .000 .0 169.0 .0 .0 Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 , ) ) _1rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10076.5 10912 10494.3 1672 10076.5 10912 ROP MWD010 FT/H 187.35 909.26 269.846 1614 10105.5 10912 GR MWD010 API 14.77 453.36 55.4777 1618 10076.5 10885 First Reading For Entire File......... .10076.5 Last Reading For Entire File.......... .10912 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type........ . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit ruri in separate files. 2 .5000 START DEPTH 10885.5 10912.5 STOP DEPTH 11153.0 11180.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 19-MAY-03 Insite 4.3 Memory 11180.0 10912.0 11180.0 3.7 50.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 82758 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEP1. ')FT) : # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 2696.0 ) Brine 8.30 .0 .0 20000 .0 .000 .000 .000 .000 .0 141.4 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10885.5 11180 11032.8 590 10885.5 11180 ROP MWD020 FT/H 0.04 487.5 33.8703 536 10912.5 11180 GR MWD020 API 17.86 47.49 25.4381 536 10885.5 11153 First Reading For Entire File......... .10885.5 Last Reading For Entire File...... .... .11180 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation. ..... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF ) File Header Service name............ .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type....... . . . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 11153.5 11180.5 STOP DEPTH 11167.0 11193.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 8M Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 20-MAY-03 Insite 4.3 Memory 11193.0 11180.0 11193.0 50.0 51.0 TOOL NUMBER 82758 3.800 10392.0 Water 8.50 .0 8.0 13000 10.0 Based .000 .000 .000 .000 .0 166.1 .0 .0 REMARKS: ') ) $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame spacing.................... .60 .1IN Max frames per record.... ....... ..Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11153.5 11193 11173.3 80 11153.5 11193 ROP MWD030 FT/H 0.08 50.22 9.435 26 11180.5 11193 GR MWD030 API 20.96 34.73 25.6632 28 11153.5 11167 First Reading For Entire File......... .11153.5 Last Reading For Entire File.......... .11193 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET 5 header data for each bit run in separate files. 5 .5000 START DEPTH 11167.5 11180.0 11180.0 STOP DEPTH 11661.5 11675.5 11675.5 RPD RPM RPS ROP $ 11180. 11180.0 11180.0 11193.5 ) 11675.5 11675.5 11675.5 11707.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........... .......0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.......... . . . . . . . . . . . . -999 Dep th Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 22-MAY-03 Insite 4.3 Memory 11713.0 11193.0 11713.0 50.1 77.7 TOOL NUMBER 93091 126589 4.125 10392.0 Flo Pro 8.70 65.0 8.5 23200 5.2 .160 .070 .330 .180 68.0 160.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H :1 1 68 4 2 ) GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11167.5 11707 11437.3 1080 11167.5 11707 ROP MWD050 FT/H 0.57 211.88 68.8673 1028 11193.5 11707 GR MWD050 API 17.11 168.8 49.7571 989 11167.5 11661.5 RPX MWD050 OHMM 1.52 2000 45.6978 992 11180 11675.5 RPS MWD050 OHMM 2.11 2000 54.308 992 11180 11675.5 RPM MWD050 OHMM 0.16 1936.75 47.3564 992 11180 11675.5 RPD MWD050 OHMM 0.07 2000 57.5166 992 11180 11675.5 FET MWD050 HOUR 0.37 45.77 1.85126 992 11180 11675.5 First Reading For Entire File......... .11167.5 Last Reading For Entire File.......... .11707 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 11662.0 11676.0 11676.0 11676.0 11676.0 11676.0 11707.5 STOP DEPTH 12089.0 12102.5 12102.5 12102.5 12102.5 12102.5 12133.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.... ........ .Undefined Absent value........... ...... .....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 23-MAY-03 ) Insite 4.3 Memory 12133.0 11713.0 12133.0 79.5 97.9 TOOL NUMBER 93091 126589 4.125 10392.0 Flo Pro 8.70 65.0 9.0 23000 8.8 .290 .070 .420 .210 68.0 156.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 , ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11662 12133 11897.5 943 11662 12133 ROP MWD060 FT/H 0.74 1268.26 52.332 852 11707.5 12133 GR MWD060 API 33.84 202.29 90.4404 855 11662 12089 RPX MWD060 OHMM 10.66 35.01 22.5076 854 11676 12102.5 RPS MWD060 OHMM 11.37 39.79 24.0811 854 11676 12102.5 RPM MWD060 OHMM 12.19 55.92 24.9806 854 11676 12102.5 RPD MWD060 OHMM 15.27 51.27 26.3454 854 11676 12102.5 FET MWD060 HOUR 0.63 16.63 2.78033 854 11676 12102.5 First Reading For Entire File......... .11662 Last Reading For Entire File.......... .12133 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 7 header data for each bit run in separate files. 7 .5000 START DEPTH 12089.5 12103.0 12103.0 12103.0 12103.0 12103.0 12133.5 STOP DEPTH 12390.5 12404.0 12404.0 12404.0 12404.0 12404.0 12435.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 24-MAY-03 Insite 4.3 Memory 12435.0 12133.0 BOTTOM LOG INTERVAL (FT) BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: ) # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 12435.0 '} 93.7 97.3 TOOL NUMBER 93091 126589 3.750 10392.0 Flo Pro 8.70 65.0 8.5 22800 5.8 .120 .070 .250 .140 68.0 159.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD070 FT/H Min 12089.5 0.16 Max 12435 2501.69 Mean 12262.3 85.9253 Nsam 692 604 First Reading 12089.5 12133.5 Last Reading 12435 12435 GR MWD070 API 39.4_ ) 202.76 114.708 603 12089.5 12390.5 RPX MWD070 OHMM 5.55 28.49 17.9202 603 12103 12404 RPS MWD070 OHMM 6.62 30.82 19.0996 603 12103 12404 RPM MWD070 OHMM 6.92 39.47 19.9447 603 12103 12404 RPD MWD070 OHMM 10.49 30.63 22.3673 603 12103 12404 FET MWD070 HOUR 0.43 12.16 2.18565 603 12103 12404 First Reading For Entire File......... .12089.5 Last Reading For Entire File... ....... .12435 File Trailer Service name........... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.008 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/07/09 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/07/09 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File