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Home My WebLink About203-098STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG U R Vit i� 1 r.c:: 111N 1 1 on1n la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned m Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG 11WDSPL ❑ No. of Completions: Zero I DevelopRl®1116�C (3I ra� ❑ jP %—f Service ❑ Stratigraphic Test ❑ 2 Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 5/15/2019. 203-098 318.491 3. Address: T Date Spudded 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 12/222003 50-029-22717-60-00 4a. Location of Well (Governmental Section): B. Date TO Reached: 16, Well Name and Number: 12/24/2003 POU 02-37L7 ' Surface: 4600' FSL, 3579' FEL, Sec. 36, T11 N. R14E, UM 9 Ref Elevations KB 61.10 17. Field/Pool(s)' Top of Productive Interval: 2423FSL, 2112' FEL, Sec. 25, T11N, R14E, UM GL 30.90 - BF Surface PRUDHOE BAY, PRUDHOE OIL ' Total Depth: 3501' FSL, 2042' FEL, Sae. 25, T11N, R14E, UM 10. Plug Back Depth(MD/TVD): 18, Property Designation: Surface / Surface ADL 028308 ' 4b. 41b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD). 19. DNR Approval Number Surface: x- 688445 - y- 5950542 - Zone - ASP 4 11071'18812' - 74-017 TPI: x- 689832 y- 5953681 Zone - ASP 4 Total Depth: x- 689874 y- 5954760 Zone - ASP 4 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MD/TVD 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/rVD: 9918'/ 8853' 22_ Logs Obtained List all logs run and, pursuant to AS 31,05 030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary SGRC Combined OR 8 BAR. MGR / CCL / GR 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZETOP CEMENTING RECORD AMOUNT PULLED BOTTOM TOP BOTTOM 20" 94# H-40 32' 112' 32' 112' 30" 260 as Arctic Set (Approx.) T 26# L -as 31' 3579' 31' 3536' 9-1/2" 2000 s: CS IIL 567 sx Class'G' 5"x4-1/2" 18#112.6# L-00 3410' 9918' 3382' 8853' 6" 350 sx Class'G' 2-7/8" 6.16# L -m 9934' 11070' 8855' 8812' 3-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Pend): GRADE DEPTH SET (MD) PACKER SET (MDTI V 4-1/2" 12.6# L-80 3424' 3376'/ 3351' /( /{ " '� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE, e -( Was hydraulic fracturing used during completion? Yes ❑ No 10 Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Surface 42 Bbls Class'G' T 27. PRODUCTION TEST Date First Production: Abandon ud Method of Operation (Flowing, gas lit, etc.): N/A Date of Test: Hours Tested Production for Test Period y Oil-Rbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: Flow Tubing Casing Press: Calculated Oil -Bbl: Gas MCF. Water -Bbl: Oil GraWN-API from: Press 24 Hour Rata �► Form 10.407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only .4l r RBDMS juN 13 2019 ,,xb VU 28. CORE DATA Conventional Corals) yes ❑ No 0 Sidewall Cores Yes ❑ No 0 , If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize Ihhology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29, GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 ' Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9826' 8838' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 1 9826' 8838' Kicked of/ from Parent Well (02- 9918' 8853' 37) Formation at total depth: , Zone 1 9826' 8838' 31. List of Attachments. Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: O'Connor, Katherine Authorized Tifle: SIM p ialist Contact Email: Katherine.O'connon@bp.com Authorized Signature: Dale: WI I I Contact Phone: +1 9075644640 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are Conducted. Item la. Multiple Completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated is a Completion. pool Item lb. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-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 o/ 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 coretl 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. Forth 10-407 Revised 512017 Submit ORIGINAL Only T/I = Vac/Vac. Temp = SI. TBG & IA FLs (WIE request). No AL. TBG FL @ near surface. IA FL @ near surface. 12/22/2018 SV, SSV, MV = C. WV = LOTO. IA = OTG. 16:15. T/I SSV/0 Mono bore. Temp = SI. Job Objective: Cement Control & Balance line with SqueezeCrete ultra fine cement. Injected 2.2 gallons of SqueezeCrete cement down Balance line and 2.3 gallons down the Control line Wait 48 hours before pressure testing. 1/2/2019 No red line required. ***JobComlaplete*** T/I = SSV/0. Temp = SI. PT bance & control lines. PT control line to 2650 psi, lost 20 psi in 15 min (PASS). PT balance line to 2900 psi, lost 167 psi in 15 min (PASS). Job 1/5/2019 com lete. T/1/0-20/20 Temp=Sl (LRS Unit 42 - Circ Out Hydrocarbons from Wellbore) Configure choke trailer to pump down IA, up Tubing, to Open Top Tank Pumped 20 bbls Brine, 1 bbl dsl to FP surface lines. Let brine swap with diesel for 30 minutes. Repeat 20 bbl iteration. 3/2/2019 ***WSR continue on 03-03-2019*** **WSR Continued from 03-03-2019*** (LRS Unit 42 - Circ Out Hydrocarbons from Wellbore) Pumped 180 bbls 9.8 Brine down IA taking returns up TBG to open top tanks in 20 bbl batches, waiting 30 minutes inbetween iterations. Obtained 9.8 lbs brine sample from TBG returns. Obtain IA sample reading 6.8 ppg. Re -configure choke trailer to pump Tubing, taking returns up IA to Surface Pumped 20 bbis 9.8 brine, still getting 6.8 ppg brine. Discuss with town. Pump an additional 56 bbls 9.8 ppg brine, waiting 1 hour between 20 bbl batches. 3/3/2019 *"WSR Continued on 03-03-2019*** T/1-5/0 **No OA** Temp=S/I (LRS Unit 42 - Circ Out Hydrocarbons from Wellbore) Flush diesel out of surface lines to open top tank w/ 4 bbls 9.8 brine. Pumped 20 bbls 9.8 brine down TBG taking returns out the IA to open top. IA sample = 9.4 lbs. Freeze protected surface lines with 3 bbls diesel. SSV/Swab=Shut, MV=Open, IA=OTG. 3/4/2019 FWHP's= 10/5 ***WSR Continued from 03-03-2019*** (LRS Unit 42 - Circ Out Hydrocarbons from Wellbore) Pump an additional 4 bbls (20 total) 9.8 ppg brine. Freeze Protect Surface lines w/ 5 bbls DSL. Let wellbore fluids swap for 5 hours. Pumped 20 bbls 9.81b brine down TBG taking returns up IA to open top tank. Freeze protect surface lines with 3 bbls diesel. Surface lines left diesel packed as a pump truck will be 3/4/2019 returnin to continue. T/I/O=5/vac Temp=S/I (LRS Unit 70 -Circ Out Hydrocarbons from Wellbore/Plug and Abandonment) Initial IA sample appears to be diesel. Flush diesel out of surface lines to open top tank w/ 4 bbls 9.8 brine. Pumped 20 bbls 9.8 brine down TBG taking returns out the IA to open top. No final sample (Scale unavailable) Freeze protected surface lines with 3 bbls diesel. SSV/Swab=Shut, MV=Open, IA=OTG. 3/5/2019 FWHP's= 120/125 Daily Report of Well Operations 02-37LI T/1/0=80/85 Temp=S/I (LRS Unit 70 -Circ Out Hydrocarbons from Wellbore/Plug and Abandonment) Initial IA sample 7.3 lbs. (Taken from IA companion valve). Flush diesel out of surface lines to open top tank w/ 4 bbls 9.8 brine. Pumped 20 bbls 9.8 brine down TBG taking returns out the IA to open top. IA sample 9.1 lbs. Let wellbore swap for 6 hrs and take another sample. 3/7/2019 ***Continued on 03-08-19 WSR*** ***Continued from 03-07-19 WSR*** (LRS Unit 70 - Circ Out Hydrocarbons from Wellbore/Plug and Abandonment) IA sample after 6 hr fluid swap was 6.8 lbs. Pumped 20 bbls 9.8 brine down TBG taking returns out the IA to open top. Let wellbore fluid swap for 6 hrs. IA sample was 6.8 ppg diesel. Pumped 5 bbls of 70* 9.8 ppg NaCl. IA Sample weighed 6.8 ppg diesel, but cleared up after -5 gal & weighed 9.8 brine Pumped .1 bbl of 9.8 against closed IA hard line & psi up TxIA to 300/300 & Waited 1 hour. Sample of 9.8 ppg brine. Wait an additional 5 hours. IA sample weighed 9.8 ppg brine. TBG sample weighed 6.8 ppg diesel. Established LLR of 2 bpm @ 2400 psi down IA taking returns out the TBG to open top w/ 20 bbls 70* 9.8 ppg brine. TBG cleared of diesel after 1 bbl brine pumped. Got another TBG sample after 18 bbls pumped, sample=9.8 ppg brine. Pumped 4 bbls neat meth to flush surface lines to open top. Pumped 4 bbls neat meth down IA and let U-tube. Refreeze protect surface lines to open top w/ 3 bbls neat meth. SV WV SSV= closed MV= open IA=OTG 3/8/2019 FWHPS=0/0 T/1/0= 0/0/0 Temp=S/I (SLB Unit - Surface Plug & Abandon) Pump the following down the IA, up to Tubing, to Surface Tanks 12 bbls Freshwater w/ F103 & U067 5 bbls Freshwater 42 bbls 15.8 ppg Class G Cement. (Clean returns observed at surface) ***Top of Cement in Both Tubing & IA @ Surface (O' MD/0'TVD) *** 3/12/2019 FWHP=0/0/0 T/I = VAC/O+. Temp = SI. Bleed WHPs to 0 psi, Strap TOC (P&A). AL disconnected. Tubing cement is @ 2" below tree cap, IA cement is @ surface to IA jewelry. SV = 6.5 turns, SSV = 7/8 stroke open and will not close, MV = full open 23.5 turns, Both IA CV's full open 13 turns. FWHPs = 0/0. 4/22/2019 SV, WV = C. SSV = stuck open. MV = O. IA = OTG. 11:00 T/I = VAC/O+. Temp = SI. AL disconnected. SSV = 7/8 stroke open and will not close. WHPs unchanged since 4/22/19. 4/24/2019 SV, WV = C. SSV = stuck open. MV = O. IA = OTG. 12:30 T/I/O = 0/0/0. RD Upper tree, RU tree cap to MV (cement to surface). RD IA (cement to 4/28/2019 surface). RD Companion OA (cement to surface). RDMO. ***Job Complete*** Job Scope: Excavate around Wellhead / Install Shoring Box (Permanent Plug and Abandon) Used an excavator to dig -12'x12' hole around wllhead to -13' deep. Assembled Engineered Modular Shoring Box and placed in excavation hole for wellhead cut. Cut wellhead 40" below tundra, Welded Top Cap and AOGCC inspection by Jeff Jones, pulled Shoring Box. Backfilled excavtion hole with gravel (-150 yds), deliniated around excavation around hole footprint. 5/15/2019 **Job Complete" T/I/O = N/A. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 SV, WV = C. IA, OA = OTG. 13:00 Suspended Well Site Inspection Form Notify AOGCC Ins nitial Inspection Inspectors at least 10 days prior to inspection to allow witness Well Name: 02-37' Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1961750 API Number: 50-029-22(17-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended. 6/8/2018 Surface Location: Section. 36 Twsp: 11N Nearest active pad or road: DS -02 Range: 14E Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Pad or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: None Photographs taken (# and Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Cellar description, condition, fluids: N/A Rat Hole: N/A Wellhouse or protective barriers: Cattle Guard Well identification sign: No Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description): N/q Operator Rep (name and signature): AOGCC Inspector: Adam Earl Inspection Date: 6/2/2019 Time of arrival: 1 00 PM Site access method a , - Josh Other CbserJers: AOGCC Notice Date: Time of Departure: 6/1/2019 1.10 PM RAF*' !y. M v• a n I TREE= CMV W3IHEAD= FMC ACTUATOR= BAKBTC 0103. aW = 61.1' BF. R LV = SURFA KOP= 2880' Mia Angb = 94" @ 10073' Datum MD= 9985' Datum TVD= 8800'SS ABANDONED 20" CONDUCTOR 94#, H-40, ID = 79.124' 710' Minimum ID = 2.0" @ 9937' 4-1/2" WFD WS -R -B PACKER 1.4-12" TBG. 1 477 2.69, L-80 BTC, 3' 0152 bOf. D = 3.958' 17- CSG, 26#. L-80 NSOC. ID = 6.276" 1-4 u2o• I PERFORATDN SLMMARY REF LOG. GLS ON 03/07/96 ANGLE AT TOP PERR WA NOL-: Refer to Rroduct on DB for h-stoncal pert data S¢E SPF NTERVAL OpNS� SHOT SOZ 02-37 2-7/8' 6 9880-9905 S 10/30/02 0526/18 2-71W 6 9905-9930 S 10130/02 0526/18 2-7/8" SLTD 9964-11613 S 12/07/96 0526/78 02-37L7 2-7/8" SLTD 9974 - 11037 S 1224/03 0526/76 L -BO 1 2-7/e" LNR 6.5#. L -BO STL, .0058 bpf. ID = 2.44 1�1 A 7 Ow -� I SAFETY NOTES: WELL ANGLE> 70° 0 9756'. DAMAGEDLNR TOP 1 @ 3432'(SEE HISTORY). WHIPSTOCK WAS RETRIEVED @9937'. Ll FULL ABANDONMENT - W EL HEAD CUT 3- BELOW TINIDRA, MARI—R TCAP INSTALL® AND BACKFlLLED (OM 5)19) 582' RESTfWMN-IRNABLETO PASS w/2.55• CENT (5/25/13)BUTONLY w/ 1.5' TOOL STRING (A WGR51121/12 &525/13) r ji "F� —535' TBG & W CMT TO SURFACE (03/12/191 BAL-O SSSV 1 FTMANOREFS 1 33/6" -j7-X 4-1/2"BKR S-3 PKR D=3.875' 3470' 4-7/2' HES X NP, D = 3613' 3470' DATE REV BY I COMMENTS DATE REV BY COMMENT!(03/12/1L9) 5"X7-BKR ZXP LTP PIOi, 06112tlB MWJMD CORRBCTEDTOCTBWELL: HMC HGR W 6- PBR D = 4.437" 03/18/19 MR YJMD CUAWTEDTBG & bPERWTNo: 3477' BKR 5' TIEBACK STEM w/SEA LS. ID=4.408" 3430' 5" X 4-1/2" XO. ID = 3.937- 3.75" MLLOUT WIND OW (02-37 L1) 9918'-9923- IV -]-I3525" BKR DE LOY SLV, ID = 3.00' 9937' 3-12" X 2-7/8" XO, ID = 2.380" 6.16#, L-80 STL, .0053 bpf, ID = 2.377 I� 4-12" WFD WS -R -e R(R, ID = 2.0" (12/1 f FlSH- CATCHER SUB END CAP, SLIPS (5/ 4-12' X 2-7/8" TINS -6 HFPRESSURE PK W/ HOLD DOVIM,S & LNR HGP, D = 2.37' PRUDiOE BAY L#IT 02-371 Lt 1961750/2030980 50-029-22717-00/60 T71 N, R14E, 1701' FW. & 660' F L DATE REV BY I COMMENTS DATE REV BY COMMENT!(03/12/1L9) 12MGMJ6 N2BS MTIALCONPLETION 06112tlB MWJMD CORRBCTEDTOCTBWELL: 1225/03 NOTiDC 1 CTD LATERAL (02-37 L7) 03/18/19 MR YJMD CUAWTEDTBG & bPERWTNo: 1126/12 MSSIJMD RESBaMlON(I lal/12) 0527/13 CJN/PJC REffi T1DFl UPDATE 0523/19 JAM FULL ABANDON EARNO: 06/11/19 JNUJMD AD ED OKB & BF B6, 06/16/13 PJC L14ER/ GLV CORRECTDNS BP Fiq)bration (Alaska) 06/07/18 GPUJMD SUSPENDED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED 11 11 n ? ')nto la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well Class: n Developm'7Po aty�❑ v..,, 6✓ Service ❑ Stratigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp., or Abend.: 6/8/2018 14. Pennit to Dnll Number/Sundry 203-098 • 318-206 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 12/22/2003 15. API Number: 50-029-22717-60-00 4a. Location of Well (Governmental Section): Surface: 4600' FSL, 3579' FEL, Sec. 36, T11N, R14E, UM Top of Productive Interval: 2423' FSL, 2112' FEL, Sec. 25, T11 N, R14E, UM Total Depth: 3501' FSL, 2042' FEL, Sec. 25, T11N, R14E, UM 8. Date TO Reached: 12/24/2003 16. Well Name and Number. PBU 02-371-1 9 Ref Elevations KB 61.10 GL 30.90 BF 31.96 17. Fleld/Pcol(s): PRUDHOE BAY, PRUDHOE OIL ' 10. Plug Back Depth(MOrfVD): • 4600'14425' 18. Property Designation: AOL 028308 4b, 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 688445' y- 5950542 • Zone - ASP 4 TPI: x- 689832 y- 5953681 Zone - ASP 4 Total Depth: x- 689874 y- 5954760 Zone - ASP 4 11. Total Depth (MD/TVD): • 11071'18812' 19. DNR Approval Number: 74-017 12. SSSV Depth (MD/TVD): None PO Thickness of Permafrost MD/TVD: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 Submit electronic and pooled information per 20 AAC 25.050 13_ Water Depth, if Offshore: MSL) N/A (it MSL) 21, Re-dd6/Lalerel Top Wndow . 9918'/ 8853, 22, Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma my, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary SGRC Combined GR & EWR, MGR / CCL / GR 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 94# H-40 32' 112' 32' 112' 30" 260 ax Arctic Set (Approx.) 7" 26# L'80 31' 3579' 31' 3536' 8-1/2" 2000 sx CS III, 567 sx Class'G' 5"x4-1/2" 18#/12.6# L-80 3410' 9918' 3382' 8853' 6" 350 sx Class *G' 2-7/8" 8.16# L-ro 9934' 11070' 8855' 8812' 3-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No 0 - If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number, Date Perfd): S c'Se-v� D, , aTE { ER�IJFIIED ' - 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# 1--80 3424' 3376r/ 3351' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed Yes ❑ No m information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4600' 125 Bbls Class'G' 27, PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas In, etc.)N/A Date of Test::: Hours Tested:. Production for Test Period y Oil-Bhl Gas -MCF: Water -Bbl: Choke Sive' Gas -Oil Ratio Flow Tubing Press Casing Press: Calculated 24 Hour Rate •y Oil -Bbl: Gas -MCF: Water atil: Oil Gravity - API (cer): Forty 10-407 Revised 512017 CONTINUED ON PAGE 2 Submit ORIGINAL only K[J1JM5-T4*)l JUL 0 31018 ,t jf/f�//q l /l-!9 VG 28. CORE DATA Conventional Cores) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9626' 8838' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kicked off from Parent Well (02- 9918' 8853' 37) 9826' 8838' Zone 1 Formation at total depth: Zone 1 9826' 8838' 31. List of Attachments: Summary of Daily Work, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is We and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hibbert, Michael Authorized Titie: SIM fe.7,it Contact Email: Michael.Hibbert@BP.com Authorized Signature: D 1 a Contact Phone: +1 907 564 4351 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 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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. Forth 10-407 Revised 5/2017 Submit ORIGINAL Only Daily Report of Well Operations 02-37L1 ACTIVITYnATF SUMMARY ****WELL FLOWING UPON ARRIVAL**** (Gas lift -Integrity) DRIFTED W/ 20'x 1-3/4" DD BAILER, S/D @ 577' SLM (Unable to work past) DRIFTED W/ 10' x 1-3/4" DD BAILER, S/D @ 577' SLM (Unable to work past) DRIFTED W/ 5'x 1.69" TUNGSTEN STEM, S/D @ 575' SLM (Unable to work past) 5/18/2018 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** T/1=2300/30 SI (LRS Unit 46 - Load & Kill) DHD finish bleeding IA. Hardline rigged up. Pump the following down the tubing: 280 bbls 1% KCL, 38 bbls Geovis, 10 bbls 1% KCI and 103 bbls of Crude. After 150 bbls away (Wellbore volume to perfs), lower pump rate to 2 bpm per program. DHD shot fluid level at 3000' (IAP=200 psi). DHD started open bleed on IA. 5/18/2018 **** Job continued on 05/19/18 **** T/I = 2330/1210. Temp = SI. Bleed IAP to 0 psi (Pre Load and Kill). AL spool removed, integral installed. IA FL @ 3000' (53 bbls, 350' above Sta #1). Bled IAP to OT from 1210 psi to 20 psi in 1 hr 35 mins. Currently bleeding while LRS pumps L&K. 5/18/2018 Cont on WSR 5/19/18 T/I = VacNac. Temp = SI. WHPs (post L&K). No AL. TP & IAP on Vac. 5/19/2018 SV, WV, SSV = C. MV = O. IA = OTG. 17:30 *** WSR continued from 05/18/18 *** (LRS Unit 46 - Load & Kill) Pumped a total of 32 bbls of Crude down TBG (135 total). DHD shot IA FL at 2910'. At end of job, DHD shot fluid level at 2910' (0 psi on IA) VALVES= SV/SSV=CLOSED MV/IA=OPEN 5/19/2018 FWHP= 230/3/na Cont from WSR 5/18/18. Bleed IAP to 0 psi (Pre Load and Kill). Initial IA FL @ 3000' (350' above sta # 1 DMY). Bled IAP to flowback tank from 220 psi to 0 psi in 2 hrs 30 min while LRS pumped on tubing. IA FL @ 2910' (440' above sta # 1 DMY). Monitored for 30 min. IAP unchanged. Final WHPs = 200/0. 5/19/2018 LRS in control of valves upon departure. 01:30 T/I = VACNAC. Temp = SI. T & IA FL (post L&K). T FL @ 100'(2 bbis). No AL. Hardline rigged up to T & IA. IA FL @ 2710' (640' above sta # 1, SO, 48 bbls). WHPs unchanged from 5/19/18. 5/21/2018 SV, WV, SSV = C. IA = OTG. 05:00 T/1= Vac/Vac (LRS Unit 76 - Load IA Pre Cement Job) Pumped 2 bbls of 50/50 for spear, followed by 45 bbls of amb DSL down IA for pre cement job. IA gained pressure at 45 bbls away. WV,SW,SSV= C MV= O IA= OTG ** IA on VAC upon departure"" 5/22/2018 Final WHPs=Vac/Vac T/I = VACNAC. Temp = SI. T & IA FL (post L&K). No AL. Hardline rigged up to T & IA. T FL @ 90'(2 bbls). IA FL @ 2710' (640' above sta # 1 SO, 48 bbls). WHPs unchanged overnight. 5/22/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 T/I = Vac/Vac. Temp = SI. TBG & IA FL (post L&K). No AL. Hardline rigged up to TBG & IA. TBG FL inconclusive due to P&A R/U on tree. IA FL @ near surface. WHPs unchanged overnight. 5/23/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 T/I = Vac/Vac. Temp = SI. IA FL (post L&K). No AL. Hardline rigged up to TBG. IA FL @ near surface. WHPs unchanged overnight. 5/24/2018 1 SV, WV, SSV = C. MV = O. IA = OTG. 17:00 T/1 = Vac/Vac. Temp = SI. IA FL (Post L&K). No AL. Hardline rigged up to tree cap. IA FL @ near surface. WHPs unchanged overnight. 5/25/2018 1 SV, WV, SSV = C. MV = O. IA = OTG. 1700 hrs. Daily Report of Well Operations 02-37L1 T/I = 0/0 (Fullbore - SLB Reservior Cement Plug and Abandonment) Purposed TOC = 9380' MD Pumped the following down the Tubing: 10 bbls Fresh Water 125 bbls 15.8 ppg Class G Cement 2 bbls Fresh Water Dropped/Pumped Foam Ball 5 bbls Fresh Water 45 bbls Diesel Cement displaced to -3400'. TOC to be determined after MIT-T. WV, SV and SSV = CLOSED. MV = OPEN 5/26/2018 Final T/I = Vac/Vac T/I = Vac/Vac. Temp= SI. WHP's. (Post P & A). AL spool removed. 5/28/2018 SV, WV LOTO), SSV = C. MV = O. IA = OTG. 20:20 T/I = Vac/Vac. Temp = SI. WHP's. (Post P &A). No change in WHP's in 3 days. 5/31/2018 SV, WV, SSV = C. MV = O. IA = OTG. 04:00 T/1/0=0/0 Temp=Sl (PLUG AND ABAN DOM ENT-RESERVOI R) CMIT TxIA ***PASSED*** to 2533/2552 Target pressure=2500 psi Max applied=2750 psi. Pumped 28.92 bbls diesel down TBG and IA to achieve test pressure. 15 min loss of 39/40 psi., 30 min loss of 24/25 psi., 45 min loss of 18/19 psi., for a total loss of 81/84 psi in 45 minutes. Bled TxIA to 0/7 psi. Bled back 2 bbls. Notify WSL. AFE sign on MV ***FLUID PACKED WELL*** Valve positions=SV,WV,SSV closed MV open CV's OTG 6/2/2018 1 FWHP=O/7 psi T/1/0=- 0/8/na Temp= S/I Assist Slickline with AOGCC CMIT-TxIA (Plug & Abandon) Job 6/4/2018 postponed to next day to accommodate AOGCC Rep ***WELL S/I ON ARRIVAL SWCP 4517***(plug & abandon) RAN 1-1/2" S-BAILER TO 572' SLM, UNABLE TO PASS RESTRICTION. RAN 1.375" BULL NOSE TO @ 576' SLM UNABLE TO PASS RESTRICTION. RAN 1-1/4" S-BAILER TO @ 576' SLM, UNABLE TO PASS RESTRICTION. RAN PDS CALIPER FROM 567' SLM TO SURFACE(good data). 6/4/2018 ***WELL LEFT S/I ON ARRIVAL SWCP 4518*** 6/5/2018 Loadfluids, road to locstion, Job cancelled, travel to LRS yard. No fluids pumped. T/I = 280/260. Temp = SI. T & IA FL (WIE req). No AL. T FL @ near surface. IA FL @ surface. 6/6/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00 T/I = 200/200. Temp = SI. AOGCC CMIT TxIA ***PASSED*** to 2660/2668 psi (Witnessed by Jeff Jones). Target pressure = 2500 psi, Max applied = 2750 psi. TBG FL @ surface, IA FL @ surface. Pumped 2 bbls diesel down IA to achieve test pressure. CMIT TxIA: 1st 15 min loss of 60/60 psi, 2nd 15 min loss of 30/30 psi for a total loss of 90/90 psi in 30 minutes. Bled TxIA to 60/60 psi. Bled back -2 bbls. Final WHPs = 150/150. AFE sign and Tags hung. 6/8/2018 SV, WV, SSV = C. MV=O. IA = OTG. 11:00 TREE= aw SUSPENDED WFp-HEAD= FMC ACRJATDR= BAKERC MNL KB. E -EV 61' BF. BEN = 6 I(OP= 2880' Mex Angle = 94" @ 10073' Ltatum MD= 9985' Datum TVD= 88M. SS 19.124" Minimum ID as 2.0" @ 9937' 4112" WFD WS -R -B PACKER 14-1012.6#,12.6A', L-80 BTC, 0152b:1=3.958" 1 3679' I PERFORATION SUMMARY REF LOG: GLS ON 03107/96 ANGLE AT TOP PERF: NA Note: Refer to Production DB for tislwical pert data SIZE SPF INTENAL I OprJSgz I SHOT I SQZ 02-37 2-718" 6 9880 - 9905 i S 10130/02 0526118 2-718" 6 9905 - 9930 1 S 10130/02 0526/18 2-7/8" SLTD 9964-11613 S 12107196 0526118 0'1-371-1 2-718' SLTD 9974-11037 S 1224/03 0.526118 1 4-112" LMR. 12.6X, L-80 BTC -K .0152 bpf, D= 3.958" 2-7/8" LNR 6.511, L-80 STL, .0058 bpf, D - 2.441' TO 02-37 SAFETY NOTES: WELL ANGLE> 70" @2756% DAMAGE I LNR TOP @ 3432' (SEE HISTORY). WHIPSTOCK WAS L 1 RETRIEVE 0 993r. �IM (5/25/13)BUT ONLY w/ 1.5" TOOL STRING (AWGRS 1121112 8 525/13) r CAM BAL-O S5SV NP, D - 3.1 GAS LIFT MANDRELS TYPE IVLVILATCHIPOT KBG-2LS DMY M 1 0 4-12" BKR S3 RtR D = 3.875' 3410" )-14-12" IES X NP, D = 3.813- 341"5"X 7"BKRZXP .813"3410' 5"X7"BKRZXP LTPPI02. MAC HGR W/ 6' PBR D= 4.437" 341r BKR 5' TACK Sim w/ SFAL7 3.75' MLLOUT WINDOW (02-37 Lt) 9918' - 9923' 3.525- BKR DEPLOY SLV, D= 3.00- 222r -4 3-12" X 2-71W XO. ID = 2.380' 2-78' LNR 6.16X, L-80 571-..0053 bpf, D - 2.377- 9110-117- 4-12" WFD WS -R -B PKIk D = 2.0" (1: DATE REV BY COMMENTS DATE REV BY COMMENTS 12106196 N2133 INMAL COMPLERON 11126/12 MiSIJM) RESTRICTION (1121/12) 12125/03 NORDIC 1 CTD LATERAL (02-37 L1) 05/27/13 CJNPJC RESTRICTION UPDATE 08104104 AAfTLP GLV 00 06/16113 PJC LINER/GLV CORR13,7DNS 12/20/09 SV LATERAL NAMING FORAAAT 06/07/18 GPIJJMD SUSPENDED 03126111 GFIPJC RESTRICTION(0324111) 05/72/18 MIJAD ODFaT2CT®TOCTBGDEEIH 0326111 PJC LNR CORREGMNS 4-12" X 2-718' TINY S6 HFFRESSIIRE PKR w / HOLD DOWNS 8 LNR HGR D = 2.37" PRUDHOE BAY UNIT WELL' 02-37/ Lt PERMIT No: 1961750 12030980 ARNo: 50.029-22717-00160 THINK R14e 1701' rWL 8 6B0' FNL BP Brploration (Alaska) yoF rkt THE STA Alaska Oil and Gas F74 4 ,, Conservation Commission 15 } 2_. !„ ALAsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \ M Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer SCANNED JUN 0 6 2018 BP Exploration(Alaska), Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool,PBU 02-37L1 Permit to Drill Number: 203-098 Sundry Number: 318-206 Dear Mr. Hibbert: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair `{k DATED this dayof June, 2018. RBDMJUN 0 4 [U'8 • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPR S 20 AAC 25.280 1. Type of Request: Abandon IDPlug Perforations 0 Fracture Stimulate 0 Repair Well 0 •r- - i S'U•V I• i Suspend I� _ Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change�•.r . tp-C Plug for Redrill 0 Perforate New Pool 12 Re-enter Susp Well 0 Alter Casing 0 Other ,A 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 203-098 ' 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p- 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-22717-60-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU 02-37L1 .- 9. 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028308 , PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11071 • 8812 - 11071 8812 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 32-112 31-111 1530 520 - Surface 3548 7" 31-3579 31-3536 7240 5410 Intermediate Liner 6508 5"x 4-1/2" 3410-9918 3382-8853 10140/8430 10490/7500 Liner 1136 2-7/8" 9934-11070 8855-8812 10570 11160 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9974-11037 8855-8813 4-1/2"12.6# L-80 30-3424 Packers and SSSV Type: 4-1/2"Baker S-3 Penn Packer Packers and SSSV MD(ft)and TVD(ft): 3376/3351 No SSSV Installed No SSSV Installed 1 12.Attachments: Proposal Summary IVJ Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 . Service 0 14.Estimated Date for Commencing Operations: May 19,2018 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended RI • ' 16.Verbal Approval: Date: 5/18/18 GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: Victoria Loepp GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. - Contact Email: Michael.Hibbert@BP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engineer I •Authorized Signature: Date: �/10® _ lioMMISSION USE ONLY Conditions of approval:alNotify Commission so that a representative may witness Sundry Number: 3 I J( 'zoco Plug Integrity L9 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ �l Other: jl. r-ra <Z p L vq v>°► 1/5 f b t 5e b 7 12/ 3 ,/l g Post Initial Injection MIT Req'd? Yes 0 No Er- Spacing Exception Required? Yes 0 No Er Subsequent Form Required: /Q — 4 (' (t'a2r-2APPROVED BYTHE /� l Approved by: COMMISSIONER COMMISSION Date: ID I lie) 1/-n 5/3111 g 4201 , oRIGINAL r RBDMs LiuN o Submit Form a Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachmgn n Du lica e • r bp • Well: 02-37 02-37 Reservoir Abandonment Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Chris Stone (907) 564-5518 Estimated Start Date - 5/20/2018 History Well 02-37 was completed in 1996 with a slotted liner, in 2003 a second slotted liner lateral was added. The production of the well did not have any noticeable change thus a HCI acid stimulation was pumped in 2004, also without benefit. On 4/30/18 the IA pressure was observed tracking the tubing pressure. DHD subsequently went out and obtained an IA FL @ 3040' (310' above station #1 - 53 bbls). The IAP was bled from 1130 psi to 160 psi in 20 minutes, the IA pressure then rose by 140 psi in 30 minutes prior to DHD's departure. There is a history of a restriction in the tubing at -582' (gauges on 2/12/10 to be between 1.90" & 3.00"). This restriction was noted to occurred between 2007-2009 and many WSR's have shown - attempts to pass with varying tool strings. Current Status > The well currently has 1200 psi on the IA and -2200 psi on the tbg. The well will be killed on 5/18/18 and the cement job will follow as soon as possible. Objective The proposed plan is to pump a well kill followed by a cement plug to abandon the reservoir. The proposed top of cement will be 9,380' MD. Post-Job Evaluation ➢ MIT-T to 2500 psi S -1--a/f--c tn/ f 1---in z 5 5- > > SL tag cement 2 d4 k crZAA Ino L C--€. Summary of Procedure Fullbore 1. Pump well kill. 2. Pump cement plug to abandon reservior. 3. WOC. MIT-T Slickline 4. Tag TOC. • Current Schematic 0 IREWE. C4C SAI-ti 1/02-37 LAR TOP aT3432'(SEED ISSORY).�WF�STOC a 975r. DAMAGED TR= FMC RETI�EY��Sl13T. ACTUATOR= BAKER C L *VIAL KB.Ei.EV 61' 13F.ELEV = -- ---KCP2 I I 582' I-ITPSTRICT1ON-1 J4BLE TOY*17,87 1.PASS5'W 1TOOL 2.555 Ma1c Angle= 94° _ 10073' I> CEM (5/25073)807 ON Datum MD= 9985' STRP/G(A WGRS 11!21112 d 5/25113) Datum TVD- 8807 SS 1 I 2079' H4-1/7'CAM BAL-O SSSV NP,D=3 812' 20-CO111J1.L1 A9.94F,11-40,o- 19 124- I IOr GAS Lt I MANDRELS ST MD ND Del/ TYPE VLV LATCH KIRT DATE 1 3350 3326 21 KBG-21S OW NT 0 04)22107 Minimum ID=2.0"@ 9937' 1" 4-1/2"WFD WS-R-B PACKER _ I 33T6' -rX4-lt?BKRS-3PIRtD=3.875- - 3410' I--I41/7 FES X MIP.ID=3.613' I 4-1/2'TBG,12 611 1.-80 BTC, - 3417 ' .0152 I7pf,D..3,958' 7.,1". • .. 3410' „5'X 7'BKR ZXP LIP FKR HOC NGHVV/6'PER,ID=4.437 N3417 I twit 3 TrOACH 3701.,OCAL O D-4.100• 3430' -5"X 4-12'XU,D-3.937' r CSG,26e.L-80 f4r,CC,D-6.276' - 357W —A 6. 3.75'MLLO(JT V4'IXIW(02.37 L1) 9918'-9923' 99V-1---[ .525'8141111110e SLV.CI-3_OO' — PERFORADDN Slau1AARY 9937' 3-112'7(2-7/6'XO,D'2.380' REF LOG:GLS ON 03007/96 ANGLE AT TOP F'31F NA T 11069' FBTD Foote:Kiefer to Production DB for hatoncal pert data - - SEE 1 SFF 1 INTERVAL IOpniSg2 SHOT I SCZ --- - 0237 --- --- - - - 2-718'' 6 9880-9905 O 10131)+02 7B'LW 6 16e,L-80 STD, 0053 6pf,D 2.377' H 11070' J 2-718' 6 91905-9930 O 10130'D2 2-718' SLID 9964-11613 SLOT 12107/96 2 gT 9937 H 4a-iir WFO WS-R-8.PKR D=2.0'(12116/03) 02-7751 9941' H FEST-1-CATCFE32 S1J3 BU CAP,&FS(5118/03) 2.718' SLID 9974 11037 SLOT 1224/03 — ii----H 9947' I-4-1/2"X 2-7/8'TIN S-8 HI-PF�ES°SUiE PKR w/HOLD DOWNS 8 LW I-GR,13=2.37' 4-112"LHR,12.60.L-80 BTC-M,.0152 bpi.D=1958' 9985 1--41 : : , `Ri414i1 14414411 2 7/8"LPR 8.54,L-80 STD,.0058 bpf,D 2.441'44REmil +,4,,4y, La,.",J .....11617,... DATE REV BY COMENTS DATE FEV BY COMMBJfS RAJDHOE BAY UNIT 12/4119.1 N2E5 INITIAL COMPLETION 11/26112 MLS)AID PSSTPY:T}W(11/21'12) %AUL: 02 37l Li 12125103 NOFOIC 1 CTD LATERAL (02-37 L1) 05/27113 CJN PJC RESTRICTION UTE FERIA T Pb: 1961750/2030980 08/0004 .LVTLP'GLV CO '06/16/13 PJC LI432 f GLV CORREICT1DNS AR Pb. 50-02322717-00/60 12/20/09 SV LATERAL M1MNG FORMAT SEC 36,Tilt{R14E 1701'FAL&680'FNL 03/26/11 GJF/PJC REST}&T[N(03124/11) 03/26/11 PJC LNC ODRRECDONS BP Exploration(Alaska) 2 .ost Reservoir Abandonneit i- TREE= CW WELLHEAD= FWD 02-37 SAFETY NOTES: WELL AN1ra.LE>79756". I19118A6133 - LNR TOP 6 3432'(SEE HISTORY), WHP'JTOCK WAS ACTUATOR= BAKER C Ll RETRIEVED in 993r. INITIAL KB.ELEV 61' — BF ELEV= 1/1 587 —RESTRICTION-LPIABLE TO PASS w I'2.55" 2860' / ../D1.5:3812 TOOL 1 Mu Angle= 94"a:, 10073' > Datum ND= 9985' STRNG(ARS 11121/12&5/25/13) 'Datum IVO.; 81300/SS 21:1 GalinucTort,944,,M-40,ID-t9 124- .1 I I 0- ST 20"FAO. TVDH4:1r2-1;AC:12TYM:IPEBA113IVALIEV?"*LLN/SSSV°OI .LuksLATCH:1-1 PORT DATE 1 3350 3326 21 KBG-2LS CUT PIT 0 04/22f0? Minimum ID=2.0"@ 9937' 4-1/21'VVFD WS-R-B PACKERMIN L 33711" —17*X4-1/7 BKR S-3 FKR,10=3.875" 1 _dal _ ........ 1111 3410' H4-1/2"MS X NP,1D=3 817 4-1/2"-roc,12 6#.1-ao sic, H MIT I] - .0152 bpf,1)=3958 71:t Pil 3410' 5"X7"SKR ZXPLTP PKR, •111:9-11 I-M HGR W/6'1143R 13=4.43r 411 . .... 0 ‘ -- 341r 113e01 V TEDACIt ortm*/OCALO,0 4.400' 1 3430' —15*X 4-1/2'X0,U"3.937' r 26a,L-80 MCC,ID-6.2/6' --1 3579" A Proposed TOC in Tubing-9380' MD ?.::::•:.:::::::::: ...•:....::::.i.::::::a 3 75"149_LOLIT lAINDOW(112-37 LI) 9818'-9923' i:.::.••::.: -. : ...,:::•, ::•,....*::.:•,:.:::.:::: 99 ' H akft DEPLOY sLv.ir).looi ?.?.?.?.?2•2::::•:•••:: PERFORATION SUMMARY 9837' 3-1/2X 2-7113.X0,13=2.380* REF LOG GLS ON 03/07796 ..•:...:.-.-2. ANGLE AT TOP RIF NA •:•:•:•:•:-::::::: 11069' —I PB110 Mtn:Rater to Production DB for historical pert data :::::::::::::::::I SIZE SPF INTERVAL 10pSHOT I SOZ :::::::::::::::::::::::::: :::::::::::::::::::::.**:**:::**::iff.'::::.•••:]:]*]: ::•::::•::::::•:]::.*:•:::K*]:]**:::•::.:::::::::::::::::::: 02-37 _ 2_7/8*INR 6 16/k 1 80 STL 0053 bpf ID=2317" 1 11070' 7 2-718* 6 91905-9930 0 10/3092 2-7/8 SLID 9964-11613 SLOT 12/07196 •••••,::::::::::•.".: 993T H4-112-INTI3WS-R-B FKR,ID=2 xr(12(16/03) I ...•.•.•.•.. 02-37L1 ::.•:?.::•:::::::•.:: 9941" FIFER CATURBR SUB EN)CAP,SUES(5/181433) II 2-7/6' SOD 9974 11037 SLOT 12/24/03 .;:r:::::::::.:. 9947 1--4-1/2"X 2-718"TAN S-611-PRESSUREFKR :•:•:•:•:•:•: ar/FOLD DOWNS&LNR I-OR,13=2 37' :::•:•:•:.,:•: :;*•::::::::: 4-112 LINR,12.61.L-80 BTOM, 0152 bpf,ID=3.958" — 9968' :•:::.:::-:.: •:::::::::::: ?•::::::::::::.: 1114 1.4.1,44 2 7/8"LNR,6.51t,L-80 STL._0058 bpf,ID=2 441" — 11616' koAti ID 1161? DATE RS/BY COMMBITS DATE REV BY CONS43113 PRUDHOE BAY uNrr I2/IN/NI 14205 ItMTIAL COMPLETION 11/2E/12 WV/MDRESTRICTr. .,..14(11/21'12) WELL. 02 371 L1 121251113 NORDIC 1 CTD LATERAL (0247 LI) 05127/13 CJNPJC RESTRICTION UPDATE PERNFT No: 1961750/2030980 08/04104 JU/TLP'GLV 00 C*116/13-. PJC Lt' (GLV CORRECTIONS ARM:, 50-029-22717-00/60 12120/09 SV LATI3iAL NIANING FORMAT SEC 36,T11N.IR14E, 1701'PM.&6847 FTC . 03726111 GJ/PJC RESIFOCTION(03124111) 03/26/11 PJC LI CORRECTIONS BP Exploration(Alas ka) 3 TIO Plot • • P.LAl -0 zx 1 'm 150 COC '� 010 Plot 20 —s—me a,,J 11G - 1A 1€; —•--OA o0A 1.300 sea ■ Bleed ,€00= 00 + operable t70 7o + Not Opel • under Eval ,.:; +, m - -Temperature SD D.DVr- r am Job Notes • BHCT is estimated to be 150 F. • BHST 180 F. • New TOC in the tbg will be 9,380' MD Cement Calculations Volume Cement 35 bbls Total cement to pump 35 bbls KeyParameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-120cc (20-100 cc/30 min) 2 Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours 1 Cement thickening time: Mix on the fly Activity Time(hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Temp Pressure • 0:00 90 0 1:00 150 3000 5:00 180 3400 4 • • • Roby, David S (DOA) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent Thursday, May 24,2018 8:39 AM To: Roby, David S(DOA) Cc: Loepp,Victoria T(DOA); Davies, Stephen F(DOA) Subject: RE:Sundry applications to suspend PBU 02-37(PTD 196-175)and PBU 02-37L1 (PTD 203-098) Dave, This well has no future utility.With the descoped well design and restriction at^'580'there is no potential to work-over or sidetrack this well. Thanks, Michael Hibbert BP w Alaska—Intervention&Integrity Engineer nG ��t e E7 ga at Ci Email: Michael.Hibbert@bp.com From:Roby, David S(DOA)<dave.roby@alaska.gov> Sent:Wednesday, May 23,2018 5:10 PM To:Hibbert,Michael<Michael.Hibbert@BP.com> Cc:Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject:Sundry applications to suspend PBU 02-37(PTD 196-175)and PBU 02-37L1(PTD 203-098) Michael, What,if any,future utility do you see for this wellbore? Thanks, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 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 Dave Roby at(907)793-1232 or dave.robv(alaska.gov. 1 • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, May 23, 2018 10:11 AM To: 'Hibbert, Michael' Cc: Worthington,Aras J (Aras.Worthington@bp.com) Subject: RE: PBU 02-37, PBU 02-37L1(PTD 196-175(Sundry 318-205), PTD 203-098(Sundry 318-206))Reservoir Abandonment Verbal Approval Michael, The tag and pressure test must be State witnessed. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Loepp,Victoria T(DOA) Sent: Friday, May 18,2018 3:07 PM To: 'Hibbert, Michael'<Michael.Hibbert@BP.com> Subject: PBU 02-37, PBU 02-37L1(PTD 196-175(Sundry 318-205), PTD 203-098(Sundry 318-206))Reservoir Abandonment Verbal Approval Michael, Verbal approval is granted to proceed with the reservoir abandonment procedure as outlined in the two submitted sundries referenced above. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCu�alaska.gov 1 ' I • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, May 18, 2018 3:07 PM To: 'Hibbert, Michael' Subject: PBU 02-37, PBU 02-37L1(PTD 196-175(Sundry 318-205), PTD 203-098(Sundry 318-206)) Reservoir Abandonment Verbal Approval Follow Up Flag: Follow up Flag Status: Flagged Michael, • Verbal approval is granted to proceed with the reservoir abandonment procedure as outlined in the two submitted sundries referenced above. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a?.alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.aov From: Hibbert, Michael [mailto:Michael.Hibbert@BP.com] Sent: Friday, May 18, 2018 2:59 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:02-37 Reservoir Abandonment Hi Victoria, Just to follow-up to our conversation.We are currently on well 2-37 performing a well kill and are planning on pumping a reservoir abandonment tomorrow due to the TxIA communication that has developed recently and the single casing design of this well. Please reply with your approval. Thanks, Michael Hibbert BP Alaska—Intervention&Integrity Engineer 1 • e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~03 - D q¡~ Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 R~CAN lØ Color 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: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: BY: ~ Date *-' C) &, D Other:: Isl M:P Dated-/~00 I "D 1111111111111111111 rnP Project Proofing BY: é9 Isl Scanning Preparation + .3 = TOTAL PAGES lj-;3 (Count does not include cover sheet) Isl BY: Date: 11111111111111 111/1 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in sc~nÎing Preparation: ~ YES ~ Dated- '¿jO(¡; If NO in stage 1 page(s) discrepancies were found: YES Maria 'bate: BY: Isl NO Vìt f Stage 1 NO BY: Isl 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned III II 1/1111 1111111I BY: Maria Date: Isl Comments about this file: Quality Checked III "111I111 II 1/11I 1016/2005 Well History File Cover Page.doc ~ • °~- ;~` -°, m g' :.t -L ~ • t 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm_Mazker.doc - e WELL LOG TRANSMITTAL &D3 '-[;L'j g !35c¡q To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 02-37 Ll, 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 02-37 Ll: LAS Data & Digital Log Images: 50-029-22717-60 1 CD Rom Q/-~ ;¡:;:f,J Ä ~J~V\ DATA SUBMITTAL COMPLIANCE REPORT 1/3/2006 Permit to Drill 2030980 MD 11071 ,/ -~_.,~- Well Name/No. PRUDHOE BAY UNIT 02-37L 1 Operator BP EXPLORATION (ALASKA) INC TVD 8812 ,/ Com pletion Date 12/26/2003 ~ Current Status 1-01L Completion Status 1-01L ~..~ ~J.-~~:1 A1lf No. 50-029-22717-60-00 UIC N REQUIRED INFORMATION w ~ !Dt D Lis pt ~-~ Samples No Directional su~ ___, Mud Log No -~_. DATA INFORMATION Types Electric or Other Logs Run: SCRC Combined GR & EWR, MGR I CCL / GR Well Log Information: Logl Electr Data Digital Dataset Type MedlFrmt Number Name rCLaS~ç>).. Production- (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No ---~._- 15 Slu Interval Start Stop 9710 9950 OH/ CH Received Case 6/25/2004 Production Directional Survey Directional Survey 12550 Gamma Ray LIS Verification 9712 9947 Case 6/25/2004 9883 11071 1/13/2004 9883 11071 1/13/2004 9813 11043 Open 4/16/2004 0 0 4/16/2004 Sample Set Number Comments ---- Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? Y -Ð Chips Received? ¥"rN-- Analysis Received? Daily History Received? GIN lbN Formation Tops ~ Comments: -^~_.._--_._,_._~-~ ----~_._- . Comments Includes CGM, TIF, & PDF I Graphics DSN 12532 GR ROP DSN 12550 ~ . Compllan,e Rev;ewod By, - ~-=~ ~-~ Date: '7 J:: ~--c:. - -~-~ --'-~--~-^~'-'----'----------'-~-----~--'----'~~" ~ __ STATE OF ALASKA e RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION 0 REPORT OF SUNDRY WELL OPERATIONS\UG 272004 1. Operations Performed: Repair Well 0 PluQ PerforationsD Slim"'." j¡J Alaska Bif,§f~S Cons. COlll11Ìssion Abandon D Alter Casing 0 Pull TubingD Perforate New Pool D WaiverO Time Extension chorage Change Approved ProgramO Operation ShutdownD Perforate D Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryO 203-0Q80 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceO 50-029-22717-60-00 7. KS Elevation (ft): 9. Well Name and Number: 61.10 02-37L 1 8. Property Designation: 10. Field/Pool(s): ADL-028308 Prudhoe Bay Field I Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11071 feet true vertical 8812.2 feet Plugs (measured) None Effective Depth measured 11071 feet Junk (measured) None true vertical 8812.2 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 33 - 113 33.0 - 113.0 1530 520 Liner 20 5" 18# L-80 3410 - 3430 3382.2 - 3400.7 10140 10490 Liner 6488 4-112" 12.6# L-80 3430 - 9918 3400.7 - 8853.5 8430 7500 Liner 3 3-112" 9.3# L-80 9934 - 9937 8854.7 - 8854.9 10160 10530 Li ner 1133 2-7/8" 6.16# L-80 9937 - 11070 8854.9 - 8812.3 13450 13890 Surface 3547 7" 26# L-80 32 - 3579 32.0 - 3536.4 7240 5410 Perforation depth: Measured depth: 9974 -11037 True vertical depth: 8854.55 - 3988.41 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 30 - 3424 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 3376 5" Baker ZXP Liner Top Packer @ 3410 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9967' - 11030' Treatment descriptions including volumes used and final pressure: 70 bbls HCL @ 532 psig 13 Representative Dailv Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water~Bbl Casing Pressure Tubing Pressure Prior to well operation: 463 10.4 1 1950 272 Subsequent to operation: 480 10.8 1 0 225 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ Service 0 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations. ~ OilŒ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature )jÚAAA1 Ct L_ Phone 564-4657 Date 8/24/04 ORIGlr~AL j~i 30 1IV"4 .' .~ t,ii,i:Ü < RSDMS Bf- AUG Form 10-404 Revised 4/2004 e e 02-37L 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/14/04 CTU #5, FCO/ACID; CONT' FROM WSR 6/13/04... POOH W/ NOZZLE ASSY. INSPECT TOOL STRING. TOOLS IN GOOD CONDITION. SIGNIFICANT MEMORY IN COIL. STRAIGHTEN COIL. MU AND RIH WITH 'LATERAL ENTRY GUIDE ASSY' (BHA #2). LATCH 'LATERAL ENTRY GUIDE' INTO WFD "WS-R" PACKER AT 9937' MDBKB. POOH WITH RUNNING TOOLS. CHANGE PACK-OFFS. RIH W/ 1.75" JSN. FLUID PACK IA W/ CRUDE AND KILL WELL W/ FILTERED 1% KCL. OIL SAMPLE SLUDGE TESTING COMPLETED AT DOWELL LAB. JET 70 BBLS 7% HCL FROM 9937' - 11,000' CTMD. FLUSH W /50 BBLS FILTERED 1 % KCL. POOH. RIH WITH WFD FISHING TOOLS W /4" HYD GS. LATCH AND POOH WITH LATERAL ENTRY GUIDE. 06/14/04 WHP=850/600. PUMPED 75 BBLS CRUDE DOWN IA FOR COIL WELL KILL. WHP=1 00/500 FLUIDS PUMPED BBLS 354 1 % KCL 59 1% XS KCL 5 50/50 Methonal 70 7% HCL 75 Crude 563 TOTAL .. Page 1 lREE= WELLHEAD = ACTUA TOR = KB. B.EV = BF. B.EV - KOP- rvlax Angle - Datum tvÐ = Datum lV D = FMC OW BAKER C 61' 02-37L 1 SAFETY NOTES: DAMAGED LNR TOP @ 3432' (Sæ HISTORY). WHIPSTOCKWAS RETRIEVB> @ 9937'. 2880' 94 @ 10870' 9985' 8800' SS . 2079' 4-1/2" CAMBAL-OSSSV NIP, ID= 3.812" 7' CSG, 26#, L-80, ID = 6.276" 7' X 4-1/2" SAKERS-3 PKR, D = 3.875" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 5" CSG, 18#, L-80, ID = 4.276" S' X 4-1/2" XO, ID = 3.937" Minimum ID = 2.0" @ 9937' 4-1/2" WEATHERFORD WS-R-B PACKER PERFORA TlON SLMflAARY REF LOG: GLS ON 03107/96 ANGLEATTOP PffiF: 80 @ 9880' Note: Refer to A"oduction DB for historical erf data SIZE SPF INlERVAL OpnlSqz DA TE 2-718" 6 9880 - 9905 0 10130/02 2-718" 6 9905 - 9930 0 10130/02 9964-11613 SLOTTED 12107/96 02-37 L 1 SLOTTED LINER 9974 - 11037 0 12/24/03 I MLLOUTWINDOW 9918' - 9923' FISH - CATCf-ER SLB END CAP, SLIPS LlH 05118/03 3.525' BKR DEPLOYMENTSLV, ID = 3.0" 3-1/2" X 2-7/8" XO, ID = 2.380" , , , I 3-314" OPEN HOLE 4-1/2" WFDWS-R-B PKR,ID = 2.0" (12/18/03) ... ... 4-1/2" X 2-7/8" TlW S-6 PKR W/ HOLD DOWNS, D = 2.37" , , , , ... ... , 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 2-7/8" LNR, 6.16#, L-80, .0053 bpf, ID = 2.337' 2-7/8" LNR, 6.5#, L-80, .0579 bpf, ID = 2.441" 11615' 11617' 2-7/8" SLOTTffiLNR,6.5#, L-80, ID=2.441" 11613' DATE REV BY OOMIv'ENTS 12/06/96 ORIGINAL COMPLETION 12/25/03 TM N'KK CTD SIDETRACK 02-37 L 1 01/15/04 KSBlKK GLV C/O 06/15/04 SRBIKAK MN D OORRECfION 07/19/04 RMH'KAK GLV C/O 08/04/04 JLJITLP GL V C/O DA TE REV BY OOIvMENTS FRUŒiOE SAY UNT WB.L: 02-37L 1 ÆRMIT No: 2030980 API No: 50-029-22717-60 SEe 36, T11 N, R14E, 2645.56' FB. & 1151.48' FNL 8P Exploration (Alaska) 02-37 (PTD #2030980) Notice ofSCP ~ß«. 02- - 37 L1 Subject: 02-37 (PTD #2030980) Notice ofSCP From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 25 Ju12004 18:38:32 -0800 To: "OPB, FSl TL" <OPBFS 1 TL@BP.com>, "OPB, FS 1 DS2 Operator" <OPBFSIDS20perator@BP.com>, "OPB, Wells Opt Eng" <OPBWellsOptEng@BP.com>, "OPB, Ops Mgr" <OPBOpsMgr@BP.com>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "AOOCC - Jim Regg (E-mail)" <jimJegg@admin.state.ak.us>, "AOOCC - Winton Aubert (E-mail)" <winton_aubert@admin.state.ak.us>, "OPB, Fld TL" <OPBFldTL@BP.com>, "Dean, James A" <deanja@BP.com>, "OPB, FSl DS Ops Lead" <OPBFSIDSOpsLead@BP.com>, "Julian, Jennifer Y" <JulianJY@BP.com> CC: "Reeves, DonaldF" <ReevesDf@BP.com> e ~t:l(11 (Z$\cfr All, Well 02-37 (PTD #2030980) has sustained pressure on the IA and has been classified as a Problem Well. Current plans are to: 1. SL: DGLV wi oversized packing 2. FB: MITIA, LLR if fails Attached is a TIO plot. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com «02-37 TIO Plot.jpg» Content-Description: 02-37 TIO Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 7/28/20049:08 AM 02-37 no Plotjpg (JPEG Image, 915x281 pixels) 1 of 1 7/28/2004 9:08 AM e . _':<0 3_0 98' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 07, 2004 RE: MWDFormation Evaluation Logs 2-37 Ll, AK-MW-2836875 1 LDWG formatted Disc with verification listing. llPI#: 50-029-22717~0 -# \ ~\) J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: \] J", ~ l\\"()'1 Signed: L~JLJ ProActive Diagnostic Services, Inc. e WELL LOG TRANSMITTAL e To: State of Alaska AOGCC Atten: Robin Deason 333 W. 7thStreet Suite # 100 Anchorage, Alaska 99501 RE: Distribution - Final Print[s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 loG Electronic BLUE LINE REPORT WELL DATE TyPE Data PRINT(S) OR Images COLOR Open Hole 1 1 ? CJ3 - QO(ð I J . 5' J 1- 02-37 L 1 5-17-04 Res. Eva!. CH 1 1 Signed: <.'} I 1! I~J ~NGtV'J Print Name: o L¿~J o kJQ/V\¿ Date: q JwL1 2ü'V y PRoACTivE DiAGNOSTic SERvicES, INC., PO Box 1 "569 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com . STATE OF ALASKA ALASK.AJ AND GAS CONSERVATION COMNAION WELL COMPLETION OR REcOMPLETION REPORì'JND LOG 1a. Well Status: IS! Oil OGas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 IS! Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 12/26/2003 203-098 3. Address: 6. Date Spudded 13. API Number , P.O. Box 196612, Anchorage, Alaska 99519-6612 12/22/2003 50- 029-22717-60-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 12/24/2003 , PBU 02-37L 1 4600' NSL, 3579' WEL, SEC. 36, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2425' NSL, 2113' WEL, SEC. 25, T11 N, R14E, UM 61.1' Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3502' NSL, 2042' WEL, SEC. 25, T11 N, R 14E, UM 11071 . + 8812 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: 688444 . 5950542 Zone- ASP4 11071 + 8812 . Ft ADL x- y- TPI: x- 689831 y- 5953682 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 689874 y- 5954761 Zone- ASP4 (Nipple) 2079' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IS! Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: T7 a).w.&"~ all I~/' /J/£) SGRC Combined GR & EWR, MGR/CCL/GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HbLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 31' 3579' 31' 3536' 8-112" 2000 sx CS III, 567 sx Class 'G' 5" x 4-1/2" 18#/12.6# L-80 3410' 9918' 3382' 8853' 6" 350 sx Class 'G' 2-7/8" 6.16# L-80 9934' 11070' 8855' 8812' 3-3/4" Uncemented Slotted Liner 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Section 4-112", 12.6#, L-80 3424' 3376' MD TVD MD TVD 9974' - 11037' 8855' - 88R. E C "','": ¥'. IF 25. ACID, FRACTURE, CEMENT SOUEEZI;, ETC. . " b_I\. ~". JAN 2; 7 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2004 9937' Set Retrievable Packer Alaska Oi! ¿? (. Whipstock was set on top of this packer, but, it was retrieved prior to Rig Release Änchmage 2000' Freeze Protected with 30 Bbls of MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 22, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL -BBL GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO 1/24/2004 6.1 TEST PERIOD .. 296 13,316 7.85 90° 45,052 Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 213 24-HoUR RATE 1,165 52,391 31 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". fE8\} GO'f>H.FnnN __~~b !"-),<iT~ None 11. ·I:.~.~~Æ -,;, nD'("~,Ô.1 )j) . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. ,RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". (Zone 1A from Original Wellbore) 9826' 8838' None REC~ JAN ~' 7 . I~ " 2004 Alaska Oil i~{ 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 0 {'~fo·OL{ PBU 02-37L 1 Well Number 203-098 Permit NO.1 A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 n r ,/^"'.! " ! . . Well: Field: API: Permit: 02-37L 1 Prudhoe Bay Unit 50-029-22717 -60 203-098 Accept: Spud: Release: Rig: 12/21/03 12/22/03 12/26/03 Nordic #1 ~~,==., PRE-RIG WORK 06/07/03 MIRU, TO FISH BROKEN SLIP STOP CATCHER SUB AND SET WHIPSTOCK. RIH WI WEATHERFORD 3 1/8" VENTURI AND FISHING ASSY WI 3.68" BARREL. TAG UP ON XO @ 3414' CTM. UNABLE TO WORK THRU, POOH. COLLET BENT (LOST 1" X 3/8" X 1/8" CHUNK). MODIFY TOOLS AND ADD KNUCKLE (OAL= 13.95', MAX OD 3.68"). STILL UNABLE TO WORK PAST 3414'. MARKS ON TOOLS SEEM TO INDICATE THAT THE C- SUB SLIPS LOST BY SIL MAY BE LODGED INIAROUND THE PBR AT 3414', CREATING AN ALIGNMENT PROBLEM TRYING TO DESCEND INTO TO 5 1/2"X 4 1/2" XO. JOB SUSPENDED...S/L TO CONTINUE TO EV AL. 06/08/03 ATTEMPTING TO CLEAR OBSTRUCTION @ 3397'SLM. RAN 3.80" LIB INCONCLUSIVE MARKS. RAN 4-1/2" WIRE BRUSH 13.725 GAUGE RING TO 3397' SLM, SITTING DOWN BUT ABLE TO WORK. RAN LIB'S, CENT & MAGNET IN ATTEMPTS TO DISLODGE OBSTRUCTION. RAN 3.625" X 10' 4" DUMMY WHIP SAT DOWN @ 3397' BEAT DOWN TO 3400', ATTEMPTING TO SWAGE OUT TIGHT SPOT. JOB IN PROGRESS. 06/09/03 ATTEMPTING TO SWAGE OPEN TIGHT SPOT @ 3397' SLM. RAN 3.625" X 10'4" DUMMY WHIPSTOCK. WOULD NOT PASS THROUGH. RAN 6'6" DUMMY WI 3.7" UPSET SECTIONS AND BODY OF 3.5". BEAT DOWN AND PASSED THROUGH 3397' TO 3401'. ATTEMPT WI 3.625" DMY DRIFT AGAIN, FAILED. RDMO. WELL LEFT SHUT IN. NOTIFY DSO. 06/1 0/03 RAN DHV VIDEO LOG. IDENTIFIED SCALE AND MECHANICAL DAMAGE TO SEAL BORE ASSY IN PBR @ 3415' VIDEO DEPTH. (3430' CORRECTED TUBING TALLY) ALL GAS APPEARS TO BE ENTERING WELLBORE FROM TUBING TAIL, NO GAS SEEN IN LINER. 08/14/03 FLUID PACK WELL W/5 BBL MEOH FOLLOWED BY 155 BBL 1% KCL. RIH WI MILLING MHA WITWO 3.80" DIAMOND STRING MILLS WI 3.80" DIAMOND PARABOLIC MILL. TAG OBSTRUCTION AT 3423' CTMD, MILL THROUGH TIGHT SPOTS TO DRESS OFF. BACK REAMED THROUGH TIGHTS SPOTS AT 3414' TO 3418' AND 3425' CTMD. WORKED AREA CLEAR AND MADE DRY CHECK RUN TO 3434' AND THEN 3443' CTMD. SET DOWN BUT POPPED THROUGH BOTH SPOTS. SHORT TRIPPED THROUGH THIS AREA WIO PROBLEMS. MADE DRY CHECK RUN WIMHA TO 5000' AND POOH WIO ANY TIGHT SPOTS. RIH WITH 3.125" VENTURI W/3.68" MULE SHOE BASKET WIB-LlNE WICKERS. START HOVERING AT 9800' CTMD, TAGGED FISH AT 9973' CTMD, HOVERED OFF TOP OF FISH AT MAX PUMP RATE, POOH. 08/15/03 POOH FROM VENTURI BASKET RUN. DID NOT RECOVER ANY OF THE SLIP STOP PARTS THE MULE SHOE HAS A DING ON THE SHORT SIDE. LOOKS LIKE AT LEAST ONE OF THE SLIPS IS LAYING ON TOP OF THE BOTTOM SUB. TURN MULE SHOE 180 DEGREE. TAG FISH AT SAME, HOOVER WITH CRUDE DOWN THE COIL AND SWAP HOLE OVER TO CRUDE. POOH. MARKS ON BOTTOM SUB ARE SIMILlAR TO FIRST RUN. MAKE MODIFIED WIRE BASJŒT GRAB FOR BOTTOM OF VENTURI, MU AND RIH. SET DOWN AT 9977'. ATTEMPT TO SHOVEL SLIP 1j>tr0 BASKET BY VARYING SPEED AND SET DOWN WEIGHT. POOH. RECOVERED 13" SECTION OF TUBING W/8" SPLIT DOWN MIDDLE. RIH WITH SAME MHA TO SAME, REPEAT PROCESS FROM LAST RUN, POOH. RECOVERED 5 METAL PIECES OF TBG DEBRIS, LARGEST 3" X 2". RIH WITH SAME MHA. 08/16/03 RIH WITH VENTURI BASKET TO 9971' CTMD, POOH. DID NOT RECOVER ANY MORE METAL DEBRIS. MAKE UP SPEAR SUB TO THE VENTURI BASKET & RIH TO SAME. HIT ONE DOWN JAR AND CREW NOTICED A LEAK ON THE INNER REEL PLUMBING. NO LONGER ABLE TO PUMP DOWN THE COIL WE WERE UNBLE TO COCK THE JARS, POOH. DID NOT RECOVER FISH. REPAIR INNER REEL VALVE, PERFORMED WEEKLY BOP TEST, CUT PIPE, MU TOOLS AND RIH WIVENTURI BASKET WISLlP STOP BODY. HOOVER 02-37L 1, Pre-Rig Work for Coil .g Drilling Page 2 . DOWN TO FISH AND MAKE REPEATED TAGS AT -9979' CTMD, VARYING SPEEDS, PUMP RATES, AND SET DOWN WEIGHTS TO ENGAGE FISH. MADE A TOTAL OF 5 JAR LICKS AND POOH. DID NOT RECOVER THE FISH. NOT SO MUCH AS A DING ON THE LEADING EDGE OF THE SPEAR GRAPPLE. THE VENTURI SCREEN WAS PACKED OFF WITH FINE METAL SHAVINGS (LOOKS LIKE STEEL WOOL). IT APPEARS THERE IS MORE OF THESE SHAVINGS ON TOP OF THE FISH THAT WILL NEED TO BE CLEANED OUT BEFORE ATTEMPTING TO SPEAR THE FISH. FREEZE PROTECT THE TBG TO 2500' W/50/50 MIW. RIG DOWN. 09/12/03 DRIFT WI 3.70 DUMMY WHIPSTOCK, 20' 9' LONG, SD @ 579' WLM, WORKED DOWN TO 584' SLM. TROUBLESHOOT OBSTRUCTION. DRIFT TO 9450' SLM WI (BARBELL) 3.80" CENT, 10' 17/8" STEM & 3.79" G- RING TO 9450' WLM (TOOLS SET DOWN @ 3390' SLM BUT ABLE TO WORK THRU). 09/25/03 SET 2-1/8" BAKER IBP WI CENTER ELEMENT @ 9400' MD. NO PROBLEMS RIH OR POOH. TAGGED UP ON PLUG AFTER SETTING. SAW NO TENSION ANOMALIES NEAR SUSPECT AREA (3390-3460). 09/28/03 T/I= VAC/620. (MONOBORE COMPLETION) TBG FL FOR FB. TBG FL @ 500' (6 BBLS). 10/02/03 T/I= 0/600 (WELL ALREADY SI) MIT-T PASSED TO 2500 PSI. RU TO TBG & PUMP 9 BBLS CRUDE TO PRESSURE TBG UP TO 2500 PSI, START 1ST TEST, TBG LOST 40 PSI IN 1ST 15 MIN, TBG LOST 140 PSI IN 2ND 15 MIN, BUMP UP TO 2500 PSI WI <.1 BBL CRUDE, START 2ND TEST, TBG LOST 40 PSI 1 ST 15 MIN, TBG LOST 20 PSI 2ND 15 MINUTES FOR A TOTAL OF 60 PSI LOST IN 30 MINUTES. BLEED TBG DOWN. FINAL T/I=0/600. 10/11/03 PULL 2 1/8" IBP FROM 9384' WLM, ALL PARTS & PIECES ACCOUNTED FOR. (POST PRESSURE TEST) 11/04/03 MIRU, MU AND RIH WITH (3.650" OD X 8.5') WHIPSTOCK DUMMY AND (22' X 3.125" OD) RUNNING TOOLS. DRIFT TO 9941' (LINER TOP) CTMD. SAW 500# WT DROP AT 650' ON FIRST PASS, CLEAN ON SECOND PASS. CLEAR TO 9941'. WEIGHT WAS ERRATIC LIKE RIH THRU HEAVY PARRAFIN. RECOMMEND TUBING HOT OIL TREATMENT BEFORE SETTING WHIPSTOCK. FL TEMP = 42 DEG F. POOH WITH NO TIGHT SPOTS. LEAVE WELL FLOWING. RDMO. JOB COMPLETE. 11/07/03 T/I/= 850/1950. Pump 128bbls 190*F Crude down Tbg for HOT OIL treatment. Final WHP; T/I= 0/2000. 12/05/03 T/I=1100/1900. PUMP 130 BBLS CRUDE AT 180* DOWN TBG FOR HOT TREATMENT.T/I=0/2000 12/17/03 DRIFT COIL WITH 1 1/4" BALL. PERFORM WEEKLY BOP TEST. 12/18/03 MU & RIH WITH PDS MEMORY GRICCL. LOG FROM 9935' TO 9600' CTM. FLAG PIPE AT 9800.7'. TIED LOG INTO SLB SONIC LOG DATED 21-NOV-1996. MADE 11' DEPTH CORRECTION. EOP AT FLAG = 9799.2' CORRECTED. TAGGED FISH AT 9946' CORRECTED. POOH. MU AND RIH WITH 4 1/2" WFD WS-R-BB PACKER WITH INCLINOMETER. SET PACKER AT 9937' CENTER OF ELEMENT. POOH. INCLINOMETER INDICATES PACKER IS 63.2 DEG R. MU WS AT SHOP FOR 30 DEG R ORIENTATION. 12/19/03 RIH WITH WEATHERFORD 41/2" WHIPSTOCK ASSY. LOCATED AND LATCHED WS TRAY INTO PACKER AT 9935'. SHEARED OFF OF TRAY AND POOH WI RUNNING TOOLS. FREEZE PROTECTED WELL TO 2500' WITH 60/40 METHANOL. TOP OF WS @ 9914' ELMD. RA TAG @ 9921.5' ORIENTATION 30 DEG ROHS. RDMO. JOB COMPLETE. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..., .A ..... Page 1 of6 BP EXPLORATION Operations Summary Report 02-37 02-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 n_............ _ From - To Hours t Task ----.-... I I I l~ode, NPT N WAIT Date 12/16/2003 08:00 - 00:00 12/17/2003 00:00 - 06:00 06:00 - 18:00 18:00 - 00:00 12/18/2003 00:00 - 00:00 12/19/2003 00:00 - 00:00 12/20/2003 00:00 - 10:00 10:00 -10:15 16.00 MOB 6.00 MOB 12.00 MOB 6.00 MOB 24.00 MOB 24.00 MOB 10.00 MOB 0.25 MOB N WAIT PRE N WAIT PRE N WAIT PRE N WAIT PRE N WAIT PRE N WAIT PRE P 12/15/2003 12/26/2003 N1 Spud Date: 11/6/1996 End: 12/26/2003 Start: Rig Release: Rig Number: Phase I Description of Operations i ...u~ ...... __ .._.... .. .,_ Rig released from K-19AL1 @ 08:00Hrs on 12/16/2003. RID gooseneck, injector & CT. W. 0 wind/weather to UD windwall/derrick & move to DS#02-37. Meanwhile carryout general rig maintenance - Work on #2 Gen & inspect/service injector. GPB in Phase 1 on the main roads and Phase 2 (convoy only) on the access roads & all pads. Continue W. 0 wind/weather to RID rig & move to DS#02-37. Meanwhile slip & cut 43' of drilling line & carryout general rig maintenance. Still in Phase 1 on the main roads and Phase 2 on the access roads & all pads. WOW, wind 22-35 MPH. Wind slowly dropping. Store injector in stabbing box. ._--. ... PRE Nordic: Replace Motor #2 heads. Pull heads and wait on Cat Mechanic to install new ones. Do maintenance on rig forklift at tool service building. SWS: Pull reel stand plates. Continue WOW - 15-35mph. GPB currently in Phase 1 driving conditions. Nordic: Repaired butterfly valve in pill pit. Paint boiler room floor. SWS: Install ODS CT reel drive plate. Continue WOW - 15-35mph. Meanwhile carried out general rig maintenance & housekeeping. GPB currently in Phase 1 driving conditions. Nordic: Replace Hydril regulator on koomey. Rebuilt pump#1. Reassemble #2 motor. Rebuilt turbos. Miscellaneous chipping & painting around the rig. SWS: Install DS CT reel drive plate. Work on CT reel & wash reel house. Continue WOW - 21-35mph. Meanwhile carry out general rig maintenance & housekeeping. Rebuid pump#2 & install shock hose on #1 pump. Finish reassembling #2 motor & test OK. Held standown with both crews to review the GBP reflection & focus on safety. PRE Phase 2 driving conditions declared in GPB by 23:45hrs with 26-60mph wind. Continue W. 0 wind/weather to R/D rig & move to DS#02-37. Meanwhile carrying out general rig maintenance. Currently in Phase 1 on the main roads and Phase 2 on the access roads & all pads. Winds @ 26-35mph. Off Weather Standby at 1000 hrs, winds below 20 MPH. SAFETY MEETING. Wind dropping to 10-15 mph. Review procedure, hazards and mitigation for laying down windwalls and mast. Printed: 12/29/2003 9:48:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I .__.~~t=-_I From - T~ 12/20/2003 10: 15 - 11 :30 ,., .a BP EXPLORATION Operations Summary Report 02-37 02-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page 2 of 6 Start: Rig Release: Rig Number: Phase 12/15/2003 12/26/2003 N1 Spud Date: 11/6/1996 End: 12/26/2003 Hours Task Code NPT -.- .. ,".-- 1.25 MOB P Description of Operations ...... ." ___h_o"___._ .--. .....--- ---..... ......... PRE Disconnect lines, wires and hardline. Check Rig tires. Found leak in one front tire of rig when trying to inflate it. Call for tire truck and get spare wheel! tire from booster in storage on Price pad. Wind at 10-15 mph, lay down windwalls and mast. Jack-up rig. Change out DS front tire with spare wheel/tire from rig booster. PJSM. Pull rig off well. Clean up location & conduct post operations pad inspection. Held pre-move safety meeting with crew, security, tool services & CPS. CPS to reconfirm rig height prior to crossing powerline. Moving rig from K-19AL 1 to DS#02. Move rig from K-19AL 1 to DS#02 & position rig in front of well. Conduct pre-operations pad inspection with DSO. PJSM. Review procedure, hazards & mitigation for raising mast. Raise mast. Crew change & PJSM. Review procedure, hazards & mitigation for raising windwalls. Raise windwalls. Rig on Standby, waiting on location preparation. Equipment and men not available to grade and level location. 11 :30 - 14:00 2.50 MOB P PRE 14:00 -19:30 5.50 MOB N RREP PRE 19:30 - 20:00 0.50 MOB P PRE 20:00 - 20:30 0.50 MOB P PRE 20:30 - 00:00 3.50 MOB P PRE 12/21/2003 00:00 - 05:00 5.00 MOB P PRE 05:00 - 05:15 0.25 MOB P PRE 05:15 - 05:30 0.25 MOB P PRE 05:30 - 06:15 0.75 MOB P PRE 06: 15 - 06:30 0.25 MOB P PRE 06:30 - 08:00 1.50 MOB P PRE 08:00 - 17:30 9.50 MOB N WAIT PRE 17:30 - 17:40 0.17 MOB P PRE 17:40 - 18:00 0.33 MOB P PRE 18:00-18:15 0.25 BOPSUF P PRE 18:15 - 22:00 3.75 BOPSUF P PRE 22:00 - 22:30 0.50 BOPSUF P PRE 22:30 - 00:00 1.50 BOPSUF P PRE 12/22/2003 00:00 - 04:30 4.50 BOPSUF P PRE 04:30 - 05:30 1.00 STWHIP P WEXIT 05:30 - 06:00 0.50 STWHIP P WEXIT 06:00 - 07:15 1.25 STWHIP N SFAL WEXIT Swap reels of CT with Peak crane while rig on standby. Pick up injecter head & M/U guide arch. Stab CT into injecter head. M/U hardline inside reel. Rig ready to back over well. Pad equipment on location at 1500 hrs. Location level and prep done at 17:30 hrs. SAFETY MEETING. Review procedure, hazards and mitigation to back rig over well. Raise rig and back over well & set down. Accept rig @ 18:00 Hrs on 12/21/2003. PJSM. Review procedure, hazards & mitigation for N/U BOPE. N/U BOPE - 8' (short) tree - thus had to align/realign BOP stack to avoid contact with cellar stairs. Meanwhile spot outside tanks & trailers. RIU & PIT hardline to flowback tank to 4k. PJSM & RIU for BOPE testing. Perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Meanwhile fill rig pits with 2% KCL bio-water. Continue BOPE PIT. Open up well & observe Opsi WHP (on vac). lAP is 73psi & FL is disconnected. Cut coil & install WFD CTC. Pull test to 21 k. Load WFD tools to floor. Install dart catcher. Load wiper dart. Launch & chase with 2% KCL. Circulate to fill coil. Seal failure and spill at 0600 hrs. 4" in-line HP fluid screen, 1504 seal failed in reel house, while pumping 2% KCL water with 2 PPB Biozan. 20 gal spill to containment inside reel house and 1 gal spill to ground. Called non-emergency spill response, ACS tech and CTD Printed: 12/29/2003 9:48:58 AM ..... BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: I p~~s~J WEXIT manager. Rig crew cleaned up spill to ice on location. 100% recovered. Replaced 1504 seal and pressure tested new seal. OK. Circulate dart thru coil. 2.3 bpm, 1200 psi. recovered dart, part of rubber missing, pump second dart. Dart on seat 57.4 bbls. Recover 100%. SAFETY MEETING. Review procedure, hazards and mitigation for M/U Milling BHA. M/U 3.80" Mill, string reamer, straight motor, MHA, 2 jts PH6 and CTC. Length = 82.13'. RIH with Milling BHA #1. RIH clean thru 640 ft and top of liner at 3430ft. RIH clean to Whipstock. 0.2 bpm, 1000 psi, take returns to cuttings tank. Up wt at 9850' = 45K. Tag whipstock at 9926 ft. correct depth to 9914'. [-12ft]. Start milling window at 9914 ft. Flag CT. Milling with 2.8 bpm, 2200-2400 psi. Milled to 9916 ft. Milling window. 2.7/2.7 bpm, 2100 - 2400 psi, 3K wob, Milled to 9917 ft. Milling window. 2.7/2.7 bpm, 2100 - 2400 psi, 3K wob, Milled to 9918.5 FT. Milling window. 2.7/2.7 bpm, 2100 - 2400 psi, 3K wOb, Milled to 9919 FT. Exit liner at 9919 ft. Top of window at 9914 ft. Bottom of window at 9919 ft. RA tag at 9921.5 ft. Mill formation to 9930 ft. 2.6/2.6 bpm, 2200 - 2400 psi, 3k WOB. Phase one declared in GPB on the all main roads & pads. Swap wellbore to 8.6ppg new flopro mud. Meanwhile backream/ream window/rat hole & make several dress/drift passes with & without pumping. Window looks clean. Paint EOP flag @ 9800' & POOH window milling BHA#1. PJSM. LID BHA#1 & inspect mills. Window mill gauge 3.80" go /3.79" no-go & string mill gauge 3.77" go /3.76" no go. Wear on window mill face indicates center crossed the liner wall. Rehead & M/U DS CTC. Pull & pressure test CTC - OK. Held pre-spud safety meeting. Reviewed well plan, potential hazards & drilling BHA M/U procedures. M/U drilling BHA#2 with 1.37 deg bend motor, GRlMWD & new 3-3/4" HYC DS49 Bit#2. RIH BHA#2. SHT MWD & orienter 800' - OK. RIH & correct -14.5' @ the flag. Continue RIH thru window with pumps down & tag btm @ 9926'. Correct CTD to 9930'. Up wt @ 39k. Orient TF to 1 OR. Drill to 9964' with HS TF, 2.6/2.6bpm, 3000/3350psi, 70fph ave ROP. See RA PIP Tag @ 9921.5'. Orient TF to 40R. Drill to 9968' with 30R TF, 2.6/2.6bpm, 3000/3250psi, 50fph ave ROP. Orient TF to 80R. Drill to 10000' with 80-90R TF, 2.6/2.6bpm, 3000/3350psi, 85fph ave ROP. PUH above window to 8840' for tie-in log. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-37 02-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date I Task_~_~de I NPT STWHIP N SFAL From - To Hours 1------.--.-. -..' -.. .-.--- 12/22/2003 06:00 - 07: 15 1.25 07: 15 - 08:30 1.25 STWHIP P WEXIT 08:30 - 08:45 0.25 STWHIP P WEXIT 08:45 - 09:30 0.75 STWHIP P WEXIT 09:30 - 11 :30 2.00 STWHIP P WEXIT 11 :30 - 13:45 2.25 STWHIP P WEXIT 13:45 - 15:30 1.75 STWHIP P WEXIT 15:30 - 17:20 1.83 STWHIP P WEXIT 17:20 - 17:50 0.50 STWHIP P WEXIT 17:50 - 19:15 1.42 STWHIP P WEXIT 19:15 - 20:30 1.25 STWHIP P WEXIT 20:30 - 22:30 2.00 STWHIP P WEXIT 22:30 - 23:20 0.83 STWHIP P WEXIT 23:20 - 00:00 0.67 DRILL P PROD1 12/23/2003 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 00:30 0.25 DRILL P PROD1 00:30 - 01 :15 0.75 DRILL P PROD1 01:15-03:15 2.00 DRILL P PROD1 03: 15 - 03:25 0.17 DRILL P PROD1 03:25 - 03:55 0.50 DRILL P PROD1 03:55 - 04:00 0.08 DRILL P PROD1 04:00 - 04:05 0.08 DRILL P PROD1 04:05 - 04:10 0.08 DRILL P PROD1 04: 10 - 04:35 0.42 DRILL P PROD1 04:35 - 04:45 0.17. DRILL P PROD1 Page 3 of 6 12/15/2003 12/26/2003 N1 Spud Date: 11/6/1996 End: 12/26/2003 Description of Operations .. _. ..... .. nnn ..-........--. ___un Printed: 12/29/2003 9:48:58 AM .- ,., BP EXPLORATION Page 4 of6 Operations Summary Report Legal Well Name: 02-37 Common Well Name: 02-37 Spud Date: 11/6/1996 Event Name: REENTER+COMPLETE Start: 12/15/2003 End: 12/26/2003 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2003 Rig Name: NORDIC 1 Rig Number: N1 I I · Code NPT i Phase Description of Operations Date From - T~_i_~~~~~_l_~~Sk -..-.- , .. --- --. - .". --...---. -.--..--- 12/23/2003 04:45 - 05:30 0.75 DRILL P PROD1 Log down GR in 4-1/2" Lnr & tie-into Gelogy PDC log. Had +5' correction. Orient TF to HS. 05:30 - 05:35 0.08 DRILL P PROD1 RIH thru window with pumps down to 9940'. 05:35 - 05:40 0.08 DRILL P PROD1 Log RA PIP tag & add 5' to CTD. Corrected window depths are: TOWSITOW - 9917.5'; BOW - 9922.5'; RA PIP TAG - 9925'. 05:40 - 05:50 0.17 DRILL P PROD1 RBIH to btm. 05:50 - 06:00 0.17 DRILL P PROD1 Orient & drill to 10015' with 90R TF, 2.6/2.6bpm, 3000/3250psi, 80fph ave ROP. 06:00 - 06:50 0.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3400 psi, 50 fph, 94 Incl, 130R, Drilled to 10,042 ft. 06:50 - 07: 1 0 0.33 DRILL P PROD1 Orient TF to 11 OR. 07:10 - 07:30 0.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 92 incl, 120R, Drilled to 10,066'. 07:30 - 07:50 0.33 DRILL P PROD1 Orient TF to 100R. 07:50 - 09: 10 1.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 92 incl, 100R, Drilled to 10,150'. 09:10 - 09:30 0.33 DRILL P PROD1 Wiper trip to window. Clean hole. 09:30 - 10:45 1.25 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 93 incl, 100R, Drilled to 10,210'. 10:45 - 12:00 1.25 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 94 incl, 130R, Drilled to 10,280'. 12:00 -12:10 0.17 DRILL P PROD1 Orient TF to 100R. 12:10 -12:30 0.33 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 93 incl, 100R, Drilled to 10,300'. 12:30 - 13:30 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. Made wiper trip up to 9600' inside 4-1/2" liner to ensure the liner was clean. C/O Baker choke on rig floor. RIH clean. 13:30 - 13:50 0.33 DRILL P PROD1 Orient TF to 100R. 13:50 -14:15 0.42 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 91 incl, 100R, Drilled to 10340'. 14:15 - 14:25 0.17 DRILL P PROD1 Orient TF to 100L. 14:25 - 15:00 0.58 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 91 incl, 100L, Drilled to 10,370'. 15:00 - 16:50 1.83 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3800 psi, 100 fph, 91 incl, 100L, Drilled to 10,450'. 16:50 - 17:30 0.67 DRILL P PROD1 Wiper trip to window. 17:30 - 20:20 2.83 DRILL P PROD1 Orient and drill at 70 - 90L at 2.6 / 2.7 / 3450 psi. Bleed IA from 600 psi to 100 psi. 20:20 - 21 :45 1.42 DRILL P PROD1 Wiper trip to 9,600' into 60 deg hole. Tie in to RA tag. Corrected =5ft, RIH, lost MWD pulse RIH and tagged bottom to try and activate MWD Tagged botton at 1063.8' Rebooted Sperry-Sun software and same results. 21 :45 - 23:30 1.75 DRILL N DFAL PROD1 POOH with MWD failure 23:30 - 00:00 0.50 DRILL N DFAL PROD1 OOH, Changed out MWD Probe and DCV 12/24/2003 00:00 - 00:22 0.37 DRILL N DFAL PROD1 Changed out MWD probe, checked Bit and motor (ok) 00:22 - 02:00 1.63 DRILL N DFAL PROD1 RIH and tagged bottom at 10621' Corrected to 10604' 02:00 - 02:20 0.33 DRILL P PROD1 Orient TF to 70L 02:20 - 03:45 1.42 DRILL P PROD1 Drilling w/70L TF, ROP 90 to 120 FPH Drilled to 10700' MD 03:45 - 04:00 0.25 DRILL P PROD1 Orient TF to 100L 04:00 - 04:46 0.77 DRILL P PROD1 Drilling w/90 to 100L TF, Drilling through shale stringer. Drilled to 10750' MD 04:46 - 05:25 0.65 DRILL P PROD1 Wiper trip to window (9917') 05:25 - 06:00 0.58 DRILL P PROD1 Tagged btm, Orient TF and Drilling Printed. 12/29/2003 9ARS8 AM - ...,. BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: 02-37 Common Well Name: 02-37 Spud Date: 11/6/1996 Event Name: REENTER+COMPLETE Start: 12/15/2003 End: 12/26/2003 Contractor Name: NORDIC CALISTA Rig Release: 12/26/2003 Rig Name: NORDIC 1 Rig Number: N1 Date From - To I Hours I Task ,Code I NPT; Phase Description of Operations ¡ 12/24/2003 06:00 - 08:00 2.00 DRILL P PROD1 Drilling at 78L TF to 10,900'. 08:00 - 09: 15 1.25 DRILL P PROD1 Wiper trip to 9,600'. RIH. Hole in good condition. 09:15 - 09:30 0.25 DRILL P PROD1 Orient to 90L. 09:30 - 12:15 2.75 DRILL P PROD1 Drill at 2.7 /2.7 /3,620 psi. TF=92L, Pit vol.=291, IA=166 psi, OA=O. TD well at 11,065' uncorrected. 12:15-13:30 1.25 DRILL P PROD1 Wiper trip to 9,600'. Tie in to RA marker. Correct depth, +9.0'. 13:30 -14:15 0.75 DRILL N WAIT PROD1 Circulate and wait on liner running pill. 14:15 -15:00 0.75 DRILL P PROD1 RIH. Tag bottom at 11,071', corrected TD. 15:00 - 17:35 2.58 DRILL P PROD1 Lay in 12 bbls of new mud for liner running pill. POOH. Paint EOP flags at 9,910' and 8,700'. 17:35 - 17:50 0.25 DRILL P PROD1 Stand back injector. 17:50 - 19:00 1.17 DRILL P PROD1 LD BHA and load out 19:00 - 19:30 0.50 CASE P COMP PJSM on PU slotted liner and associated HARARDS 19:30 - 22:30 3.00 CASE P COMP PU 2-7/8"predrilled liner, MGRlCCL and 5 jts 1-1/4" CSH as per programme. PU and stab Injector head 22:30 - 00:00 1.501 CASE P COMP RIH with Liner/MGR BHA @ Qp = 0.3 bpm. Corrected back to flag at 8800' to 9845.7' (-23.7') Wt check =41k. 12/25/2003 00:00 - 00:30 0.50 CASE P COMP RIH with liner in Open Hole section. Corrected to flag at 11055'. Tagged at 11065' CTMD. PUH , Reel banked hard, Checked reel. PU weight = 46k. Re-tagged (hard) at 11065' CTMD. Drilled orginally to 11065. After tie-in was made, corrected TD to 11071' 00:30 - 03:25 2.92 CASE P COMP Lanched 5/8" ball. Pumped 71.2 bbl flo-pro ball not on seat. (Calculated CT vol = 58.5 bbl) SD ,checked reel cap for ball. No ball. Pumped 50 bbl and sheared seat 03:25 - 03:40 0.25 CASE P COMP PUH logging liner top location at 30fpm to 9600 ft 03:40 - 05:00 1.33 CASE P COMP POOH 05:00 - 06:00 1.00 CASE P COMP OOH, LD CSH and SWS MGR/CCL 06:00 - 06:45 0.75 CASE P COMP Downloading data from SWS MGRlCCL for liner top depth conformation. Top of liner from corrected MGR @ 9934'. 06:45 - 08:00 1.25 CLEAN P COMP Cut off DS CTC. Grind coil and 08:00 - 08:30 0.50 CLEAN P COMP MU 3.5" OD side jetting nozzle w/1 joint of 2 3/8" PH6 to jet whipstock. 08:30 - 10:25 1.92 CLEAN P COMP RIH. 10:25 -11:00 0.58 CLEAN P COMP Tag up on liner top at 9,946'. Correct depth to 9,934'. Jet whipstock at 3.25 bpm w/ side jetting nozzle. Make 4 passes. 11 :00 - 13:00 2.00 CLEAN P COMP POOH pumping at 3.25 bpm. 13:00 - 13:45 0.75 FISH P COMP LD nozzle and DS MHA. PU box tap overshot, and whipstock fishing BHA. 13:45-15:15 1.50 FISH P COMP RIH. Correct depth to 9,810 EOP flag. -11.85' correction. 15:15 - 16:20 1.08 FISH P COMP Base line parameters 9,903'. PU=45,500 Ibs, SO=24,000 Ibs dry. 0.5 bpm, 1,200 psi, PU=42,000 Ibs. 0.75 bpm, 1,360 psi, 42,000 Ibs. 1 bpm, 1,600 psi RIH#1: SO=23.5K at 5 fpm while pumping at .5 bpm, 1,270 psi. Started taking weight at 9,919'. Pressure increased to 2,300 psi. SO to 19K. Bring pump up and pressure up to 3,500 psi attempting to work box tap overshot on to whipstock. Pick up w/o pump and weight is 49.6K. Not much overpull, only 4.6K and no jar licks. Bring up pump to 1 bpm and pressure is 770 psi, about 1/2 of the pressure before going over the fish?? RIH#2. Bring pump up to 1 bpm then slow to .57 bpm, 740 psi. Printed, 12/29/2003 9:48;58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: / ,., - BP EXPLORATION Operations Summary Report 02-37 02-37 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Page 6 of 6 Start: Rig Release: Rig Number: Spud Date: 11/6/1996 End: 12/26/2003 12/15/2003 12/26/2003 N1 Date From - To i Hours Task ¡ Code I NPT I Phase ----- _____________ ___m ___.__u__..._ 12/25/2003 15:15 -16:20 16:20 - 18:30 18:30 - 19:00 19:00 - 20:15 1.08 FISH P COMP 2.17 FISH 0.50 FISH 1.25 FISH P P P COMP COMP COMP 20:15 - 21 :15 1.00 WHSUB P COMP 21:15 - 22:35 1.33 CLEAN P COMP 22:35 - 00:00 1.42 CLEAN P COMP 12/26/2003 00:00 - 00:45 0.75 CLEAN COMP 00:45 - 01 :00 0.25 DEMOB POST 01 :00 - 02:30 1.50 DEMOB POST 02:30 - 02:40 0.17 DEMOB POST 02:40 - 05:30 2.83 RIGD POST 05:30 - 06:30 1.00 DEMOB POST 06:30 - 06:45 0.25 DEMOB POST 06:45 - 11 :00 4.25 DEMOS POST Description of Operations SO at 5 fpm, SO=26.kK. Pressure started to increase and started to stack weight at 9,919', same spot. SO to 10K. Bring pump up to 3,500 psi. Jar hit down. SO to 9,700 Ibs. Press up to 3,500 psi. Pick up and weight is 46K, no overpull or jar lick. RIH#3 RIH at 5 fpm w/o pump. Started taking weight at 9,920'. SO to 7,900 Ibs. Jar down. Weight came back to 12K. Pressure up to 3,500 psi. Pick up and weight is 46.5K, no overpull. Will come out of the hole and see what we've got. Line up to flill across the top. POOH. OOH, recovered WS, Crew change and PJSM on LD WFT WS LD WS, top of WS showed lots of wear, 4-colletts were flat, the WS was not correctly latch into packer. Lug/skate oriention was correct and all pieces were recovered. SWS personnel pulled RA marker from WFT's whipstock. Transported as per SWS SOP. PU wash nozzle BHA. PT BOP body to 350/3500 psi. BHA = 12.86' RIH to turn well over to 2%KCL to 9920 ft POOH laying in 2% KCL at 2 bpm and FP top 2000 ft with 30 bbl MEOH. Cir at 1: 1 ratio MEOH at surface at 500' POOH, OOH, Close MV (23.5 turns) PJSM on blowing down CT and rig with N2 Blow down CT and suface lines PJSM on unstabbing CT, RD injector and stab in box ND BOP, PT tree cap to 3500 psi Rig Released at 0400 hrs 12-26-2003 Make rig ready to move off PJSM on moving rig off well Move rig off well. Lower wind walls and derrick. Move to edge of Pad. Started waiting on NordiC#2 to move from W-Pad to DS15 Printed: 12/29/2003 9:48:58 AM TREE = WB.LHEAD = AGrU\TOR = KB. ELEV = BF. ELEV = KOP= Max Ange = Datum MD = DatumTVD = FMC CrN BA KER C 61' 2880' 94 @ 10870' 9985' 8800' SS I 4-lI2"lBG, 12.6#, L-80, M3TC, 10.0152 bpf, ID = 3.958" ITOPOF5" CSG I 5" CSG, 18#, L-80, ID = 4.276" I TOP OF 4-1/2" LNR I T' CSG, 26#, L-80, ID = 6.276" I Minimum ID = ÆRFORA TION SUrvMARY REF LOG: GLS ON 03/07/96 A NGLE AT TOP PERF: 91 @ 9964' Note: Refer to Production DB for historical perf data SIZE SFF NTERVAL Opn/Sqz DATE 2-7/8" 6 9880 - 9905 0 10/30/02 2-7/8" 6 9905 - 9930 0 10/30/02 2-7/8" 0 9964 - 11613 SL TD 12/07/96 FISH: CATCHER SUB END CAP, SLIPS UH 5/18/03 1 TOP OF 2-718" LNR 12-718" LNR, 6.5#, L-80, .00579 bpf,lD = 2.441" H ITOPOF2-7/8"SLTDLNR H / . ..... 02-37 L 1 :'"t-ETY NOTES: DAMAGED LNRTOP @ 3432' (SEE HSTORY) CTD Lateral Sidetrack From Orl . 2079' 4-1/2" CAMBAL-OSSSV NIP,ID= 3.812" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 1 3350 3326 21 CA-KBG-2LS BK-INT ~ I..2S. I 3376' T' X 4-1/2" BAKERS-3 PKR, D - 3.875" I . . 3410' 4-1/2" rES X NP, ID = 3.813" Xk: ~ 3410' 5' x 7" BAKERZXPL TP FKR, HMC HNGR I ~ W/6' PBR, ID = 4.437" 3430' 5' x 4-1/2" XO, ID - 3.937' I 3424' 3410' 3430' 3430' I 3579' ~ ... Top of W'ndow : 9,918'. Bottom of Window: 9,923' I Weatherford WS-R~BB Iî H 9937' Retrlevahle Packer [ EJTOP of 2-7/f)'liner (ouJsideof 9934' window) , J ! .O""j· VP"" Hole .J '2-718" L-80 Pre-drilled Line! 1- 110170'1 9947' - 4-1/2" X 2-7/8" TIW S-6 PKR W/HOLD DOWNS, ID = 2.37" 9941' - COIL I DRIFT 11/4/03 9947' ~ 9964' I 9964' I 14-1/2" LNR, 12.6#, L-80, MBTC, 0.0152 bpf, ID = 3.958" H 9968' 1-->11III ~ DATE 12/06/96 02/21/01 OS/28/01 08102/01 10/09/01 10/30102 12-718" SL m LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" I TOP OF 2-7/8" LNR 12-7/8" LNR, 6.5#, L-80, STL, 10.00579 bpf, ID = 2.441" ~ REV BY 00 MrvENTS ORIGINAL OOrvPLETION SIS-LG REVISION RNlTP OORREGrIONS BYITP WOVE GL MANDRJEWELRY ??IKAK SAFETY NOTE KB/DM/1F ADD PERFS 11613' ~ ~~ ),\ 11613' 11615' 11617' [)A. TE 11/24102 04/22103 12/15/03 12/2 5/03 RBI BY OOMMENTS by/daclkk CORRECTDNS BY/TLH PERF OORREGrION Iv1SE PROPOSED cm SIDETRACK SK CTDSIDE1RAO< FRUDHOE BAY UNIT WB.L: 02-37 L 1 ÆRMIT No: 203~098 API No: 50-029-22717-00 SEC 36, T11 N, R14E, 2645.56 FB. 1151.48 F\L BP Exploration (Alaska) . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well 2-37 L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,883.54' MD 9,917.50' MD 11,071.01'MD (if applicable) ~03-0c¡g" 09-Jan-04 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED IN.,! 13 20Q4 ß\iamœ Oìl & Gas Cons. Commission .~. ",ÑtftII'iIftA rr~f1t'~MII.V Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 02 02-37 - 2-37L 1 Job No. AKMW0002836875, Surveyed: 24 December, 2003 Survey Report 8 January, 2004 Your Ref: API 500292271760 Surface Coordinates: 5950541.54 N, 688444.49 E (70016' 10.7695" N, 148028' 33.3385" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 950541.54 N, 188444.49 E (Grid) Surface Coordinates relative to Structure Reference: 1721.09 N, 847.61 E (True) Kelly Bushing Elevation: 61. 10ft above Mean Sea Level Kelly Bushing Elevation: 61.10ft above Project V Reference Kelly Bushing Elevation: 61. 10ft above Structure Reference SpE!r'r'Y-SUï'! DRILLING SeRVICES A Halliburton Company DEFINITIVE . . Survey Ref: svy4148 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 02 - 02-37 - 2-37L 1 Your Ref: API 500292271760 Job No. AKMW0002836875, Surveyed: 24 December, 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) 9883.54 80.200 348.700 8788.27 8849.37 3159.05 N 1455.25 E 5953736.03 N 689820.19 E 3293.86 Tie On Point 9917.50 83.830 348.300 8792.99 8854.09 3192.00N 1448.55 E 5953768.81 N 689812.67 E 10.752 3325.93 Window Point 9946.82 89.160 353.670 8794.78 8855.88 3220.88 N 1443.97 E 5953797.57 N 689807.37 E 25.776 3354.17 9971.17 93.130 358.100 8794.29 8855.39 3245.15 N 1442.22 E 5953821.79 N 689805.01 E 24.424 3378.13 10020.38 93.860 7.050 8791.29 8852.39 3294.17 N 1444.43 E 5953870.84 N 689805.99 E 18.214 3427.11 . 10051.64 90.840 7.560 8790.01 8851 .11 3325.15 N 1448.40 E 5953901.91 N 689809.18 E 9.797 3458.33 10106.42 92.160 13.900 8788.57 8849.67 3378.92 N 1458.59 E 5953955.92 N 689818.02 E 11.818 3512.88 10137.12 91.720 19.890 8787.53 8848.63 3408.27 N 1467.50 E 5953985.48 N 689826.20 E 19.553 3542.99 10169.40 92.070 24.650 8786.46 8847.56 3438.12 N 1479.72 E 5954015.63 N 689837.67 E 14.778 3573.96 10199.45 93.220 29.760 8785.07 8846.17 3464.80 N 1493.44 E 5954042.65 N 689850.72 E 17.412 3601.93 10234.82 94.180 35.930 8782.79 8843.89 3494.44 N 1512.57 E 5954072.76 N 689869.10 E 17.618 3633.41 10272.16 92.420 42.980 8780.64 8841.74 3523.21 N 1536.25 E 5954102.10 N 689892.05 E 19.429 3664.49 10302.79 91 .450 47.380 8779.60 8840.70 3544.78 N 1557.96 E 5954124.21 N 689913.21 E 14.702 3688.21 10333.00 91.450 51.610 8778.84 8839.94 3564.39 N 1580.91 E 5954144.39 N 689935.67 E 13.998 3710.11 10364.38 90.480 47.910 8778.31 8839.41 3584.66 N 1604.86 E 5954165.25 N 689959.10 E 12.188 3732.77 10398.12 93.830 44.390 8777.04 8838.14 3608.00 N 1629.17 E 5954189.20 N 689982.82 E 14.396 3758.53 10434.01 93.480 37.520 8774.75 8835.85 3635.04 N ·1652.63 E 5954216.82 N 690005.59 E 19.128 3787.87 1 0465.47 92.420 31.350 8773.13 8834.23 3660.94 N 1670.39 E 5954243.15 N 690022.70 E 19.874 3815.49 10496.31 92.510 27.650 8771.80 8832.90 3687.75 N 1685.56 E 5954270.34 N 690037.19 E 11 .990 3843.74 10528.68 89.690 22.540 8771.18 8832.28 3717.05 N 1699.28 E 5954299.97 N 690050.17 E 18.027 3874.31 10565.46 88.900 17.960 8771.63 8832.73 3751.54 N 1712.00E 5954334.77 N 690062.03 E 12.635 3909.94 10598.22 89.690 12.490 8772.04 8833.14 3783.14 N 1720.60 E 5954366.57 N 690069.84 E 16.869 3942.27 . 10635.24 90.840 7.210 8771.87 8832.97 3819.60 N 1726.93 E 5954403.18 N 690075.25 E 14.597 3979.19 10667.74 92.420 1.570 8770.94 8832.04 3851.98 N 1729.42 E 5954435.61 N 690076.93 E 18.015 4011.65 10698.58 94.410 358.280 8769.10 8830.20 3882.76 N 1729.38 E 5954466.38 N 690076.12 E 12.451 4042.25 10738.86 91.190 349.760 8767.13 8828.23 3922.73 N 1725.19 E 5954506.23 N 690070.93 E 22.586 4081.57 10776.85 93.300 344.480 8765.64 8826.74 3959.72 N 1716.73E 5954543.00 N 690061.55 E 14.956 4117.47 10808.65 94.270 339.010 8763.54 8824.64 3989.84 N 1706.80 E 5954572.86 N 690050.86 E 17.432 4146.39 10842.15 94.100 333.550 8761.10 8822.20 4020.41 N 1693.36 E 5954603.09 N 690036.66 E 16.263 4175.39 10878.54 92.420 327.910 8759.02 8820.12 4052.09 N 1675.60 E 5954634.31 N 690018.12 E 16.147 4205.04 10908.62 93.040 322.450 8757.59 8818.69 4076.75 N 1658.46 E 5954658.53 N 690000.36 E 18.248 4227.77 10939.65 92.330 317.520 8756.14 8817.24 4100.48 N 1638.53 E 5954681.76 N 689979.85 E 16.034 4249.29 10969.98 91.540 313.460 8755.11 8816.21 4122.09 N 1617.29E 5954702.83 N 689958.07 E 13.630 4268.56 11000.79 91.720 308.880 8754.23 8815.33 4142.36 N 1594.11 E 5954722.51 N 689934.39 E 14.871 4286.30 11040.45 92.070 301.480 8752.92 8814.02 4165.18 N 1561.73 E 5954744.52 N 689901.45 E 18.669 4305.61 8 January, 2004 - 9:54 Page 2 of 3 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU _EOA DS 02 - 02-37 - 2-37L 1 Your Ref: API 500292271760 Job No. AKMW0002836875, Surveyed: 24 December, 2003 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) / 11071.01 92.070 301.480 8751.82 8812.92 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 4181.13 N 5954759.81 N 689875.02 E 1535.69 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 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 and calculated along an Azimuth of 6.000° (True). Magnetic Declination at Surface is 25.533° (22-Dec-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 11 071.01ft., The Bottom Hole Displacement is 4454.23ft., in the Direction of 20.168° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9883.54 9917.50 11071.01 8849.37 8854.09 8812.92 3159.05N 3192.00 N 4181.13 N 1455.25 E 1448.55 E 1535.69 E Tie On Point Window Point Projected Survey Survey too/prOgram for 02-37 - 2-37L 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 11071.01 8812.92 MWD Magnetic (02-37) Dogleg Vertical Rate Section Comment (o/100ft) 0.000 4318.75 Projected Survey BPXA . . 8 January, 2004 . 9:54 Page 3 of 3 DritlQuest 3.03.05.005 . ~~ . æ FRANK H. MURKOWSKI, GOVERNOR AIfASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Robert Mielke CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 02-37L1 BP Exploration (Alaska), Inc. Permit No: 203-098 Surface Location: 4600' NSL, 3569' WEL, Sec. 36, TllN, R14E, UM Bottomhole Location: 3486' NSL, 2012' WEL, Sec. 25, TUN, R14E, UM Dear Mr. Mielke: 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, k1:J~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this r:.-- day of June, 2003 ~ cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section VJGA- lP/3jZ. OC,J Aa STATE OF ALASKA . ALAS~AND GAS CONSERVATION COM ' ON PERMIT TO DRILL 20 AAC 25.005 Multilateral 1 a. Type of work o Drill III Redrill 11 b. Type of well o Exploratory o Stratigraphic Test III Development Oil ORe-Entry o Deepen o Service 0 Development Gas 0 Single Zone o Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 61.10' Prudhoe Bay Field I Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface x = 688444, Y = 5950542 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4600' NSL, 3579' WEL, SEC. 36, T11 N, R14E) vÞ\ (Jt-I- Prudhoe Bay Unit At top of productive interval x = 689753, Y = 5953265 8. Well Number / 2009' NSL, 2201' WEL, SEC. 25, T11 N, R14E I vM .()~ 02-37L 1 Number 2S 100302630-277 At total depth x = 689905. Y = 5954746 9. Approximate spud da~. 3486' NSL, 2012' WEL, SEC. 25, T11N, R14E,V1I1 ßC'v 06/10103 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well/ 14. Number of acres in property 15. ProRosed depth (MD and TVD) ADL 028307,1794' MD No Close Approach 2560 --11000' MD I 8761' TVDss 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9900' MD Maximum Hole Angle 95 Maximum surface 2219--psig, At total depth (TVD) 8800' 13275 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantitv of Cement Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD ' rI::It::l\ 3-3/4" 2-718" 6.16# L-80 ST-L 1090' 9910' 8791' 11000' 8761' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary RECEIVED Total depth: measured 11617 feet Plugs (measured) true vertical 8806 feet Effective depth: measured 11617 feet Junk (measured) MAY 2 9 2003 true vertical 8806 feet Casing Length Size Cemented Alaska Oil & Gas W$. Comr.lissíOITVD Structural Anchorage Conductor 80' 20" 260 sx Arctic Set (Approx.) 110' 110' Surface 3571' 7" 2000 sx CS III, 567 sx Class 'G' 3600' 3555' Intermediate Production Liner 6480' 5-1/2" x 4-1/2" 350 sx Class 'G' ("" 3450' - 9930' 3419' - 8854' 1785' 2-7/8" Uncemented Slotted Liner 9780' - 11565' 8826' - 8808' Perforation depth: measured 9880' - 9905', 9905' - 9930', 9964' - 11613' true vertical 8848' - 8852', 8852' - 8854', 8855' - 8806' 20. Attachments III Filing Fee o Property Plat II BOP Sketch o Diverter Sketch II Drilling Program III Drilling Fluid Program o Time vs Depth Plot o Refraction Analysis o Seabed Report III 20 AAC 25.050 Requirements Contact Engineer NamelNumber: Robert Mie/ke, 564-5238 Mary Endacott, 564-4388 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby certify that the.z¡~Fe and correct to the be~t of my kn.o~ledge . 5/ø.q/,r~ Signed Robert Mielke ·:tl) ~ Title CT Drilling Engineer Date " '. ,. Com,rtission Use Q.nh ,> ". ." Permit Number ~ 'i? I API Number ~P1t~ib I See cover letter 20 ;>~. 0 ç 50- 029-22717-60 for other reauirements Conditions of Approval: Samples Required o Yes ~ No Mud Log Åequi~ed DYes p,g No Hydrogen Sulfide Measures ~Yes DNo Directional Survey Required ~Yes DNo Required Working Pressure for BOPE 0 2K D3K D4K D5K o 10K o 15K o 3.5K psi for CTU Other: T-e>t -g" P £: fc ŠS"CO ps. 1', ¿,j¿/t;<. Ie L- ~- lit _/~ - -4 by order of Approved Bv ~ ] - .... Commissioner the commission Date Form 10-401 Rev. 12-01-85 ,/ Submit In Tri licate ORIGINAL p -- -- BPX 02-37Ll CTD Lateral Sidetrack Summarv of Operations: A CTD sidetrack is planned for Prudhoe production well 02-37. The preparatory (Prep Work) and drilling (Mill Window, Drill and Complete) procedures are outlined below. Anchor and whipstock used to kickoff will be retrieved upon completion; care will be taken to leave original wellbore and completions intact. Prep Work: Planned to commence June 7, 2003. /' · MIT -inner annulus / · PPPOT -tubing hanger seals · MIT -outer annulus /' · Install anchor and mechanical whipstock (off of which window is to be milled at 9900'). These are to be retrieved post-completion. Mill Window, Drill and Complete: Planned to commence June 10,2003. Drilling coil will be used to mill the window, then drill and complete the directional hole according to attached plan. Maximum hole angle is planned for 94 degrees. /' Mud Program: · Prep Work: Seawater · CTD: Seawater and Ao-Pro (8.6 ppg) /' Disposal: /" · All Class II wastes (drilling fluids, completion fluids, etc.) will go to Grind & Inject · All Class I wastes will go to Pad 3 for disposal Casing Program: .. ~. p. The production liner consists of a 2 7 /YL-8. redrilled slotted liner. The top of this liner is to be placed outside window, with top of liner at 9,910' m~91' ssTVD) run to 11,000' md (8,761 ssTVD) in order to retain access to parent wellbore, preserving the option for future sidetracking with full access to 4 Y2" liner. Well Control: · BOP diagram is attached /" · Pipe rams, blind rams and the CT pack off will be pressure tested to 300psi and to 3,500psi · The annular preventer will be tested to 400 psi and 2,200 psi Directional: · Please refer to attached directional plan. · Magnetic and inclination surveys will be taken every 30 feet. No gyro will be run. Logging: · An MWD Gamma Ray log will be run in build and horizontal sections. Memory CNL will be run inside the liner prior to perforating. Hazards: / · Maximum H2S on pad recorded as 100 ppm (recorded on well2-29A in 1992). · Risk of problematic shales. Will geosteer to avoid BSAD, keeping Klagard in mud. · Lost circulation medium to low risk based on offsets. Reservoir Pressure: Reservoir pressure is estimated to be 3,275 psi at 8800 feet ssTVD. Maximum surface pressure with gas (.12 psilft) is 2,219 psi. /' : DAMAGED LNR TOP @ 3432' RY.) DATE Minimum ID :::::: 2.37" 4-1/2" x 2-7/8" TIW 9947' PKR w/hold downs PERFORA TION SUMMARY REF LOG: GLS ON 03/07/96 A T TOP PERF: 91 @ 9964' Note: Refer to Production OS for historic,,1 perf d"ta SIZE INTERVAL Opn/Sqz 2-7/8" 6 9880 - 9905 0 2-7/8" 6 9905~9930 0 2-7/8" 0 9964 - 11613 SLTD 9947' 10/30/02 10/30/02 12/07/96 TOPOF 2-7/8" LNR I 11613' 2-7/8" SL TO LNR, 6.5#, L~80, .00579 bpf, 10::: 2.441" 2~7/8" LNR, 65#, L-80, .00579 bpf, 10::: 2.441" I [2£] 11615' 11617' COMMENTS PRUDHOE SA Y UNIT WELL: 02~37 PERMIT No: 1961750 API No: 50~029-22717-00 SEe 36, T11 N, R14E. 2645.56 FEL 1151.48 FNL PERF CORRECTION SP Exploration (Alaska) BP Amoco LEGEND Azimuths to True North Magnetic North: 25,94" Plan: Plan #6 (02~37jPlan#6 02-37L 1) Created By: Brij Potnìs Date: 5/21/2003 WE1.I.PATH DETAII.S Plan#6 02-31f..1 500292271760 Pal'81'tt W.lfpillth: 02·37 Tkf on MD: 9a83.54 Rig: Ref. Datum: V.Soetio" Aøglø ;. ',,- ~ ~ -. --y- - ~l-;--· 4500 4400 , 4300~ ' , 4200~" , , "oo;~~_~~_=~ ~ "uw 0~VV " , , :'00VV :¡0"N \ 'vvu \ ! , \ ,voW \ I \ 330 320 3" ~"'" .. 3100- .... .. 3000-' 29 : I 2800 1100 1200 1300 1400 1500 16 JO 17 )0 1800 it 00 2000 2100 2200 2300 2400 2500 2600 2700 500 600 700 800 2900 3000 3100 O.':1~ ~~~ ~=::i~O ~'I.OO' 0.00 REFERENCE INFORMATION 11>(,-C1"I014 ÐIITAI.$ 80.20 341:1.7-0 82.16 34&.48 83.72 34&,39 tIO,æ 353.*, S'U4 33.23 90,41 .t;l.28 it:5 ~:i! Ðt.ðg T'Fa<::.. 1455.25 1ft G,,," 1452.UA -'I /. 353.65 14411.23 .00 30.00 1442.25 0.00 3t).OO 1-48'1.16 20,00 83..50 1517.71 20.00 113,00 1$45.73 12.00 Ø7.00 1668.68 1"2.$ no.GO 150S.51 12.00 211.00 Targ..t STð8.:n 8'11:«"'1'9 ð19J.25 8195.21 ~:~: 87/12.35 :rn:~~ 315!:UJ5 3174.99 æ!~5 !~~~ 3293.86 ~~~:~~ 3366;98 3S1it,;3 ~:g~:¡~ 1~~::~ TVO 81'U.Z7 8790.79 8193.25 419$.21 8.185.&1 81.83.2. 1$7.82:;35 1111.fJ4..:91 11I'181.10' ANNOTATIONS MO AnøotatlOtl TI. KO. , 4 · · 7 · TO .... r:: i 8350' 08400 !!!. ;¡ 8450 Co &850 ¡¡ Co) :e GI > GI i! ... 885 8900 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700 3750 3800 3850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 Vertical Section at 6.00' [50ft/in] BP Baker Hughes INTEQ Planning Report ObP -- Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: --.. - .- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948800.37 ft 687638.44 ft Latitude: 70 15 Longitude: 148 28 North Reference: Grid Convergence: -- ... SAK_ IIUGIIIS INI'EQ Page: Well: 02-37, True North , System: Mean Sea Level JI Well (0.00N,O.00E,6.00Azi) Minimum Curvature Db: Oracle - -----:-:::-:=:-_-===.===-=-=:..=.:=::-_-:-~=...:....::.:..:::_::.:.:..:..:::..:..:.::..-__=:_7':"... Alaska, Zone 4 Well Centre BGGM2002 53.847 N 58.060 W True 1.43 deg Well: 02-37 Slot Name: 37 J 02-37 Well Position: +N/-S 1720.66 ft Northing: 5950541.56 ft Latitude: 70 16 10.770 N +E/-W 849.25 ft Eastlng : 688444.49 ft Longitude: 148 28 33.338 W Position Uncertainty: 0.00 ft Wellpath: Plan#6 02-37L 1 500292271760 Current Datum: 02-37 Magnetic Data: 5/21/2003 Field Strength: 57552 nT Vertkal Section: Depth From (TVD) ft 0.00 Height 61.10 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Targets 02-37 9883.54 ft Mean Sea Level 25.94 deg 80.83 deg Direction deg 6.00 Name Description Dip. Dir; 02-37L 1 Polygon6.1 0.00 -Polygon 1 0.00 -Polygon 2 0.00 -Polygon 3 0.00 -Polygon 4 0.00 02-37L 1 T6.3 8762.00 02-37L 1 T6.2 8766.00 02-37L 1 T6.1 8784.00 3275.00 1744.15 5953859.00 690106.00 70 16 42.977 N 148 27 42.544 W 3275.00 1744.15 5953859.00 690106.00 70 16 42.977 N 148 27 42.544 W 4174.01 1477.56 5954751.00 689817.00 70 16 51.820 N 148 27 50.303 W 4192.05 1676.08 5954774.01 690015.00 70 16 51.997 N 148 27 44.521 W 3356.94 2027.31 5953948.00 690387.00 70 16 43.782 N 148 27 34.297 W 4170.51 1577.51 5954750.00 689917.00 70 16 51.785 N 148 27 47.392 W 3988.83 1641.98 5954570.00 689986.00 70 16 49.998 N 148 27 45.515 W 3467.69 1519.89 5954046.00 689877.00 70 16 44.873 N 148 27 49.074 W Annotation MD ft 9883.54 9900.00 9920.00 9960.00 10160.00 10210.00 10250.00 10800.00 11000.00 8788.27 8790.79 8793.25 8795.21 8785.51 8783.29 8782.35 8764.97 8761.10 TIP KOP 3 4 5 6 7 8 TO ObP -- BP -- II.. BAKU ....... Baker Hughes INTEQ Planning Report Company: BP AmOco Dåte: .. 5/21/2003 Tillie: 14:35:12 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-37, True North Site: PB DS 02 Vertical (TVD) Reference: System: Mean Sea Level Well: 02-37 Section (VS) Reference: Well (0.00N,0.00E,6.00Azi) Wellpath: Plan#6 02-37L 1 Survey Calculation Method: Minimum Curvature Db: Oracle ~._..._._._..- b: Plan #6 Date Composed: 5/21/2003 l Similar to Lamar's Plan #6 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Inçl Azirn ft deg deg 9883.54 80.20 348.70 8788.27 3159.05 1455.25 0.00 0.00 0.00 0.00 9900.00 82.16 348.48 8790.79 3174.99 1452.04 11.98 11.91 -1.34 353.65 9920.00 83.72 349.39 8793.25 3194.47 1448.23 9.00 7.80 4.53 30.00 9960.00 90.66 353.38 8795.21 3233.94 1442.25 20.00 17.34 9.98 30.00 10160.00 94.68 33.23 8785.51 3424.44 1487.16 20.00 2.01 19.93 83.50 10210.00 90.41 42.28 8783.29 3463.88 1517.71 20.00 -8.53 18.11 115.00 10250.00 92.28 46.70 8782.35 3492.40 1545.73 12.00 4.68 11.05 67.00 10800.00 90.93 340.69 8764.97 3997.45 1668.68 12.00 -0.25 -12.00 270.00 11000.00 91.25 316.68 8761.10 4167.03 1565.51 12.00 0.16 -12.00 271.00 Survey MD Tool ft 9883.54 80.20 348.70 8788.27 3159.05 1455.25 5953735.86 689820.12 3293.86 0.00 0.00 TIP 9900.00 82.16 348.48 8790.79 3174.99 1452.04 5953751.72 689816.50 3309.38 11.98 353.65 KOP 9920.00 83.72 349.39 8793.25 3194.47 1448.23 5953771.09 689812.20 3328.35 9.00 30.00 3 9925.00 84.59 349.89 8793.76 3199.36 1447.33 5953775.96 689811.19 3333.13 ~O.OO 30.00 MWD 9950.00 88.92 352.38 8795.18 3224.02 1443.49 5953800.51 689806.73 3357.24 20.00 29.95 MWD 9960.00 90.66 353.38 8795.21 3233.94 1442.25 5953810.40 689805.24 3366.98 20.00 29.81 4 9975.00 91.00 356.36 8795.00 3248.88 1440.90 5953825.29 689803.52 3381.70 20.00 83.50 MWD 10000.00 91.55 1.33 8794.44 3273.86 1440.40 5953850.25 689802.39 3406.49 20.00 83.54 MWD 10025.00 92.10 6.30 8793.64 3298.78 1442.06 5953875.21 689803.43 3431.45 20.00 83.65 MWD 10050.00 92.63 11.28 8792.61 3323.46 1445.88 5953899.97 689806.63 3456.39 20.00 83.81 MWD 10075.00 93.14 16.26 8791.35 3347.70 1451.81 5953924.36 689811.96 3481.12 20.00 84.02 MWD 10100.00 93.63 21.24 8789.87 3371.33 1459.83 5953948.17 689819.38 3505.45 20.00 84.27 MWD 10125.00 94.09 26.23 8788.19 3394.15 1469.87 5953971.24 689828.84 3529.20 20.00 84.56 MWD 10150.00 94.52 31.23 8786.32 3416.01 1481.85 5953993.39 689840.27 3552.19 20.00 84.90 MWD 10160.00 94.68 33.23 8785.51 3424.44 1487.16 5954001.95 689845.37 3561.13 20.00 85.27 5 10175.00 93.41 35.95 8784.46 3436.76 1495.66 5954014.47 689853.55 3574.27 20.00 115.00 MWD 10200.00 91.27 40.47 8783.44 3456.38 1511.10 5954034.47 689868.50 3595.40 20.00 115.19 MWD 10210.00 90.41 42.28 8783.29 3463.88 1517.71 5954042.14 689874.92 3603.55 20.00 115.38 6 10225.00 91.11 43.94 8783.09 3474.83 1527.96 5954053.34 689884.89 3615.51 12.00 67.00 MWD 10250.00 92.28 46.70 8782.35 3492.40 1545.73 5954071.35 689902.21 3634.84 12.00 67.02 7 10275.00 92.28 43.70 8781.35 3510.00 1563.45 5954089.38 689919.49 3654.19 12.00 270.00 MWD 10300.00 92.27 40.70 8780.36 3528.50 1580.23 5954108.30 689935.80 3674.35 12.00 269.88 MWD 10325.00 92.26 37.70 8779.37 3547.86 1596.02 5954128.05 689951.09 3695.25 12.00 269.76 MWD 10350.00 92.23 34.69 8778.39 3568.01 1610.77 5954148.57 689965.33 3716.84 12.00 269.64 MWD 10375.00 92.21 31.69 8777.43 3588.92 1624.44 5954169.80 689978.48 3739.06 12.00 269.53 MWD 10400.00 92.17 28.69 8776.47 3610.51 1637.00 5954191.70 689990.49 3761.84 12.00 269.41 MWD 10425.00 92.13 25.69 8775.53 3632.73 1648.42 5954214.20 690001.35 3785.13 12.00 269.29 MWD 10450.00 92.09 22.69 8774.61 3655.51 1658.65 5954237.23 690011.01 3808.87 12.00 269.18 MWD 10475.00 92.03 19.68 8773.71 3678.81 1667.68 5954260.74 690019.45 3832.97 12.00 269.07 MWD 10500.00 91.98 16.68 8772.84 3702.54 1675.47 5954284.66 690026.65 3857.39 12.00 268.96 MWD 10525.00 91.91 13.68 8771.99 3726.65 1682.02 5954308.93 690032.58 3882.06 12.00 268.86 MWD 10550.00 91.85 10.68 8771.17 3751.07 1687.29 5954333.47 690037.24 3906.89 12.00 268.76 MWD 10575.00 91.77 7.68 8770.38 3775.74 1691.27 5954358.23 690040.61 3931.84 12.00 268.66 MWD 10600.00 91.70 4.68 8769.62 3800.58 1693.96 5954383.13 690042.68 3956.83 12.00 268.56 MWD 10625.00 91.6'1 1.68 8768.90 3825.53 1695.35 5954408.10 690043.44 3981.78 12.00 268.47 MWD 10650.00 91.53 358.68 8768.21 3850.51 1695.43 5954433.08 690042.89 4006.64 12.00 268.39 MWD 10675.00 91.44 355.68 8767.57 3875.47 1694.20 5954458.00 690041.04 4031.34 12.00 268.30 MWD 10700.00 91.34 352.68 8766.96 3900.33 1691.67 5954482.79 690037.88 4055.80 12.00 268.23 MWD _.~--~-- -~~-,-- ObP -- BP Baker Hughes INTEQ Planning Report -- B.. BA.øLs IN-IRQ Company: Field: Site: Well: Wellpath: BPAmoco Prudhoe Bay PB DS 02 02-37 Plan#6 02·37L 1 Page: Tool 12.00 MWD 12.00 MWD 10775.00 91.04 343.68 8765.40 3973.65 1676.33 5954555.69 690020.71 4127.11 12.00 268.02 MWD 10800.00 90.93 340.69 8764.97 3997.45 1668.68 5954579.29 690012.47 4149.97 12.00 267.97 8 10825.00 90.98 337.69 8764.55 4020.81 1659.80 5954602.42 690003.01 4172.28 12.00 271.00 MWD 10850.00 91.03 334.69 8764.12 4043.68 1649.71 5954625.02 689992.35 4193.97 12.00 270.95 MWD 10875.00 91.07 331.69 8763.66 4065.98 1638.43 5954647.04 689980.52 4214.97 12.00 270.90 MWD 10900.00 91.12 328.69 8763.18 4087.67 1626.01 5954668.40 689967.56 4235.24 12.00 270.84 MWD 10925.00 91.16 325.69 8762.68 4108.67 1612.46 5954689.06 689953.49 4254.71 12.00 270.79 MWD 10950.00 91.19 322.68 8762.17 4128.94 1597.84 5954708.95 689938.37 4273.34 12.00 270.73 MWD 10975.00 91.23 319.68 8761.64 4148.41 1582.17 5954728.03 689922.22 4291.07 12.00 270.66 MWD 11000.00 91.25 316.68 8761.10 4167.03 1565.51 5954746.23 689905.10 4307.85 12.00 270.60 TO All Measurements are from top of Riser iddle of flow cross BAG 7 1/16" 5QQOpsi top of bag bttm of bag middle of slips middle of pipes TOTs .....·······7 1/16" 5000psi ,,~.......*............ Mud Cross 7 1/16" 5000psi iddle of blind/shears middle of pipe/slips TOTs .....·······7 1/16" 5000psi .......................... Flow Tee DATE CHECK NO. P055061 .. -- 4/4/2003 055061 VENDOR DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 4/4/2003 INV# CK0401 03K PERMIT TO DRILL EE D~-37L\ TOTAL ~ HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 .NATIONAL CITY BANK Ashland, Ohio 56'389 412 NO~P 055061 CONSOLIDATED COMMERCIAL ACCOUNT PAY: **"''''***$1.d0 .00****** NOT VALID AFIEH .~20 ~AY~ _ .._.. " .. _~..__"._ ~~:,i:~~~f.~~~:h;0::, l!<07~~\~~~;~~~;/i:;;':;::~:;<?~~:'; ! AMOUNT TO THE ORDER OF: 1110 5 SOb . III I: 0... . 2 0 :\ B ~ 5 I: 0 . 2 ? B ~ bill .. -- TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNOTTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~ Permit No, API No. . (If API number Production should continue to· be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) 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). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 07/10/02 C\jody\templates fWELL ÞI;:RMIT CHEG~IST Company BP EXPLORATION (ALASKA) INC ~"',,:~. ¡ØMi1'I. .", PTD#:2030980 Field & Pool PRUDHOE BAY PRUDHOE OIL - 640150 Initial ClasslType Administration 1 P~Hmit fee attaçhejj Y~s 2 _Leas~ _number _apRrOPJiate _ Yes 3 _U_nlque weltllam~_a[ld lJumb_er ~ ~ _ _ _ ~ _Y~s _ ~ ~ ~ _ ~ _ _ 4 We-"JQcat~d [n a d_efil1e_d_ppol_ Y~s 5 WeJIJQcated prpper _dlstance_ from driJling ul1itb_oUl1d_a[y_ Y~s 6 WellJQcated prpper _dlstance_ from QtlJer wells_ Yes 7 _S_utfiçiel1taçreage_ayailable in_dJilJilJg unjt Y~s 8 Rdeviated, js weJlbQre platil1cJu_ded Yes 9 _Qperator ol1ly: affected party _ Yes 10 _Oper_ator lJas_apprpprlate_Qond lnJQrce _ _ _ _Y~s ~ ~ _ _ _ _ _ _ _ _ _ 11 Permit ~[l be lssued wjtlJQut co_nserva_tiOI1 order _ Yes 12 P~rmitca[l be lssued wjtlJQut admil1istratille_apprpval Yes 13 Can permit be approved before 15-day wait Yes 14 WellJQcated wlthil1 area alld_strata _authorlzed by l[ljectiPIJ Order # (puUOtl hcpmmeotSJ-{For NA 15 AJI we IJsJlvith In JI4_ruile_area_of reyiew jdeotlfied (FprseNjc_e-"v_eU ol1lY:L ~ _ _ _ _ _NA _ ~ ~ ~ 16 PJe-prpdu_ced i[ljector; jjurationof pre-projjuctipl1 tess thall 3 mOl1tlJs_ (For_ser:.vlce well QnJy)NA 17 _AÇMPJ::¡l1djng pf Con_si,ste[lcy_h_as bee_nissued_ fortbis pr_ojeçt NA 18 _Cp[ldu_ctor stril1gpJQvided NA 19 _S_urface _casil1g pJote~ts all_knowll USQWs NA 20 _CMTvoladeQuateto çirc_ulate_o-"_cOl1d_uçtor_& SUJfCJ>g _NA 21CMT v_ol adeQuate_ to tie-i-" JQng _string to _surf csg NA 22 _CMTwill coYeraJll<l1own_pro_ductiYe bQrizon_s_ NA 23 _C_asiog desig[ls ad_equa_te fpr C,T" B_&perruafr_ost Y~s 24 _MequateJankageoJ re_ser:.ve pit Yes CTQU. 25 Ita re-jjrill" bas_a_ to:403 fQr abandollme_nt beelJ ¡¡PPJQvedNA Multilater_at. . 26 Adequate_weUbore separatjo-" proposed _ _ _ ~ Yes _ ~_ (pI J I ~~ 27 Rdjverter Jequired, dQes jt meet regulatiol1s _NA Date 28 _DJitliog flujd_ program s~hematic_& equip Jistadequale _ Y_es 29BQPEs,dp _they meet regulatiol1 Yes 30 _BQPE_press raiiog appropriate; _test to_(pui psig i-"_commel1ts)_ Yes 31 _C_hoke_ruanjfold cQmplies w/APt RF'-53 (May 84) Yes 32 WQrk will occur withputoperatjo-"_sbutdQwn_ Y~s 33 Is presence_ of H2S gas_ RrOQable _ Y~s 34 Meçha_nlcal_cPlJdJt[o[l pfwells wlthil1 ,ð.OR yerified (fo(s_ervice welJ onJy)NA Appr Date Vf/lG 0q'Q3 Engineering WGA- Appr Geology Appr Date ;fit 0~3 Well Name: PRUDHOE BAY UNIT DEV /1-0IL GeoArea 890 02-37L 1 Program DEV 11650 On/Off Shore On Well bore seg Annular Disposal ~ D Unit e . Geologic Commissioner: I öTS _ Slotted, - - - - - Max MW_8.Q RP9.- Test l03500_ Rsi. MSF' 22_19 psk - - - 35 Permit ~a[l be lssued wlo_ hydrogen_ sulfide measures 36D_ata_PJeselJted Oil Rote_ntial PveJRressure _zones_ 37 _Selsmic_analysjs Qf slJallow gas_zpoes_ 38 Seabed _col1djtiOIJ survey _(if off-shpre) 39 _ CQntact namelphOlleJor_weekly prpgreSHeRorts [explorato[yonly] No NA NA _NA NA Date: o 6/ o~/03 Engineering Commissioner: Public cR Commissioner ~ G Dat~ ~ ~ Date e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this 1ature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drtlting Services LIS Scan Utility e $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 01 08:22:28 2004 o .1\ 1 ~ fÇ-() C\ß fG~~ Reel Header Service name.... . . . . . . . . .LISTPE Date.................... .04/04/01 Origin.................. .STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name.... . . . . . . . . .LISTPE Date.................... .04/04/01 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 2-37L1 500292271760 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 01-APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002836875 J. PANTER R. WHITLOW/J MWD RUN 2 MW0002836875 J. PANTER D. HILDRETH/ # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 11 14 4600 3579 MSL 0) 61.10 # 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 9918.0 # REMARKS: e e 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL LATERAL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9917.5' MD AND THE BOTTOM WAS AT 9922.5' MD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN 2-37 ON 21 NOVEMBER 1996. THIS PDC LOG WAS PROVIDED TO SSDS BY K. COONEY (SIS/BP) ON 3/29/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 & 2 REPRESENT WELL 2-37 L1 WITH API#: 50-029-22717-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11071'MD/8752'TVDSS. SROP SGRC $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED GAMMA RAY COMBINED. File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/01 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9813.0 9935.5 STOP DEPTH 11043.5 11070.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9813.0 9814.0 9819.0 9822.0 9824.0 9831. 0 9842.0 9848.5 9850.5 GR 9815.0 9816.0 9820.5 9823.0 9824.0 9831.0 9839.5 9849.5 9850.5 9853.0 9862.0 9866.5 9871.0 9874.5 9876.0 9909.0 9911.5 9916.0 9918.0 11070.5 $ 9853._ 9864.5 9867.5 9872.0 9874.0 9876.0 9907.5 9911. 5 9916.0 9918.0 11070.5 e # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 9815.0 10603.5 MERGE BASE 10603.5 11070.5 # REMARKS: MERGED MAIN PASS. $ # 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 DEPT ROP GR MWD MWD Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Service Order units FT FT/H API Size 4 4 4 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9813 11070.5 10441. 8 2516 9813 11070.5 ROP MWD FT/H 0.46 642.34 82.9291 2271 9935.5 11070.5 GR MWD API 35.73 131.29 71.0417 2402 9813 11043.5 First Reading For Entire File......... .9813 Last Reading For Entire File.......... .11070.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/01 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......... .4IÞ.O.O Date of Generation...... .04/04/01 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 e header data for each bit run in separate files. 1 .5000 START DEPTH 9815.0 9935.5 STOP DEPTH 10575.5 10603.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE 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 23-DEC-03 Insite 4.3 Memory 10604.0 9935.0 10604.0 83.8 93.8 TOOL NUMBER 72829 3.750 9917.5 Flo Pro 8.60 60.0 9.0 25000 16.0 .000 .000 .000 .000 .0 130.8 .0 .0 Data Record Type....... .4IÞ.......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 e Service Order Units FT FT/H API Size 4 4 4 Rep 68 68 68 Name DEPT Rap GR MWD010 MWD010 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9815 10603.5 10209.3 1578 9815 10603.5 Rap MWD010 FT/H 0.78 642.34 82.6685 1337 9935.5 10603.5 GR MWD010 API 35.73 131.29 67.2684 1465 9815 10575.5 First Reading For Entire File......... .9815 Last Reading For Entire File.......... .10603.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/01 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 Rap $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10576.0 10604.0 STOP DEPTH 11043.5 11070.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE 24-DEC-03 SURFACE SOFTWARE VERS4It: 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 $ BOTTOM) TOOL TYPE 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 Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 Insite 4.3 Memory 11071.0 10604.0 11071.0 89.7 94.4 TOOL NUMBER 78012 3.750 9917.5 Flo Pro 8.70 65.0 8.5 22000 7.2 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 141. 4 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10576 11070.5 10823.3 990 10576 11070.5 ROP MWD020 FT/H 0.46 371.94 83.3023 934 10604 11070.5 GR MWD020 API 55.93 109.34 76.881 936 10576 11043.5 , .. e e First Reading For Entire File......... .10576 Last Reading For Entire File.......... .11070.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/04/01 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .04/04/01 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .04/04/01 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