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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Ke'rl O131'1 DATE: 6/18/2019 P. I. Supervisor FROM: Adam Earl SUBJECT: Location Clearance Petroleum Inspector PBU 02-37 BPXA PTD 1961750; Sundry 318-492 6/2/2019: PBU 02-37 was deemed abandoned effective 5/15/2019. 1 inspected the well site which is located on PBU DS2, an active producing pad. The location is clean — no trash, no sheen or stained gravel. The abandoned well was marked by red delination , markers. Attachments: Photos (2) 2019-0602_Location_Clear_PBU_02-37_ae. docx Page 1 of 2 L W Q L O U N CL U Q V op LO Q co a rn 0) N � p O 0 N 00, tN da co STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECENEU 111N 9 1 nnin 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned M Suspended ❑ 20AAC 25.105 20AAC 25.718 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 1b. Well Classs, ,� p•� Develo 6[ Iii Ecmoralnrv. ❑ 4d is1, V V.Y IService ❑ Stratigraphic Test ❑ 2. Operator Name: BP Exploration (Alaska), Inc 6. Date Comp., Susp., or Abend.: 5/15/2019 . 14. Permit to Drill Number/Sundry 196-176 318-492 ' 3. Address: P.O. Box 198612 Anchorage, AK 99519-6612 T Date Spudded: 11/7/1996 15, API Number: 60-029.22717-00-00 ^ Is. Location of Well (Governmental Section): Surface: 4600' FSL, 3579' FEL, Sac. 36, T11N, R14E, UM Top of Productive Interval: 2423' FSL, 2117 FEL, Sec. 25, T11 N, R14E, UM Total Depth: 4127' FSL, 2606' FEL, Sec. 25, T1114, R14E, UM S. Date TO Reached: 12/3/1995 16. Well Name and Number: PBU 02-37 9 Ref Elevations KB 61.10 . GL 30.90 BF Surface 17. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): Surface / Surface 18. Property Designation: ADL 028308 4b. 41d. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 688444 . y- 5950542 . Zone - ASP 4 TPI: x- 689832 y- 5953681 Zone - ASP 4 Total Depth: x- 689254 y- 5955371 Zone - ASP 4 11. Total Depth 111 , 11617'/ 8806' ^ 19. DNR Approval Number: 74-017 12. SSSV Depth (MD/TVD): None Y0 Thickness of Permafrost MD)TVD. 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/1VD: N/A 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of comple0on, 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 recerd. Acronyms may be used. Attach a separate page if necessary MWD, GR, RES, CNL 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 -K) Surface 112' Surface 112' 30" 260 sx Arctic Set (Approx.) 7" 26# L-50 Surface 3579' Surface 3536' 8-1/2" 2000 sx CS III, 567 sx Class'G' 5"x4-1/2" 18111/12.60 L-010 3410' 9968' 3382' 8855' 6" 350 sx Class'G' 2-7/8" 6.16# L -e0 9947' 11615' 8855' 8806' 3-3/4" Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No 0 If Yes, list each interval open (MD/IVD of Top and Bottom; Perforation Size and Number; Date Perfd): ,, (//�4-112" JQ^,Q`m ID7)AE ' IFIE 1 25, TUBING RECORD GRADE DEPTH SET (MD) PACKER SE7 (MD/TV 12.6# L-80 3424' 3376'/ 3351' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion?Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printetle4 information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Surface 42 Bible Class'G' 27. PRODUCTION TEST Date First Production: Abandoned Method of Operation (Flowing, gas lie, etc.): WA Date of Test: Hours Tested: Production for Test Period y Oil-Bbt: Gas -MCF: Water-Bbl Choke Sive Gas -Oil Ratio: Fim Tubing preSe Casing Press: Calculated 24 Hour Rate Oil -Bbl: Ges-MCF: Water -Bbl: Oil Gravity- API (cor): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only A0�1 M&P-'vT--�tJly RBDMS-W-&,JUN 131019 s-�' C 1Y'ff 28. CORE DATA Conventional Core(s) Yes ❑ No IZ 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 m ' Permafrost - Base If yes, list intervals and formations tested briefly summarizing test results. Attach Top of Productive Interval 9826' 8838' separate sheets to this fore, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9056' 8283' Shublik 9105' 8324' Sadlerochit - Zone 4 9171' 8380' CGL - Zone 3 9342' 8526' Base of CGL - Zone 2 9424' 8595' TDF - Zone 1 9826' 8838' Kavik - Base Sadlerochit 10510' 8846' Formation at total depth: Base Sadlerochit 10510' 8846' 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 Title: SIMS is t Contact Email: Katherine.O'connor@bp.com / Authorized Signature: �(�'r 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 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 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item ib. Well Class Service wells: Gas Injection, Water Injection, Water-Aftemating-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 panted 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 forth: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only Daily Report of Well Operations 02-37 ACTIVITYDATF CI IAARAARV 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 re Ine regwre o omp ete*** Th = SSV/0. Temp = SI. PT balance & 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 complete. 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 bbls 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/I-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 9.8Ib 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 returning to continue. T/1/0=5/vac Temp=S/l (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 1 FWHP's= 120/125 Daily Report of Well Operations 02-37 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 bbis 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 bbis 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 bbis pumped, sample=9.8 ppg brine. Pumped 4 bbis neat meth to flush surface lines to open top. Pumped 4 bbis 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/I/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 bbis Freshwater wl F103 & U067 5 bbis Freshwater 42 bbls 15.8 g Class G Cement. (Clean returns observed at surface) ***Top of Cement in Both Tub-in-g-& IA @Surface (0' MD/0'ND) *** 3/12/2019 FWH = T/I = VAC/0+. Temp = Sl. 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/0+. 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 TWO = 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 Initial Inspection Notify AOGCC 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: 50-029-22717-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 6/8/2018 Surface Location: Section: 36 Twsp: 11N Range: 14E Nearest active pad or road: DS -02 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: Fac or location surface: Clean Location cleanup needed: None Pits condition: N/A Surrounding area condition: Clean Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: 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/treetvalve description, condition: Cellar description, condition, fluids: Rat Hole: N/A 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/A Work Required: None Operator Rep (name and signature) AOGCC Inspector: Adam Earl Inspection Date: 6/2/2019 Time of arrival: 1:00 PM Site access method: Acce AOGCC Notice Date: 6/1/2019 Time of Departure: 1:10 PM :.:.�... •---- ,,,M�,..,.,�. ... Ar 9[ i • � of ..F'is-'. .�...a..�. -�5.' `' ra._.....` _ - .'r. r✓AN Oi9-Y��t� ,. rt r. Mhb, >• • r j'' - ; ' �..'y; ,;tea .�C /� �.,,-, :. • - � .�� ,(�'�� � it L; � .} -�,�• ��'. Se_ .. hC43ifi � .�� ,(�'�� � it L; � .} -�,�• ��'. I TREE= CW WELFEAD= FMC ACTUATOR = BAKERC OKB. EPB7 = 61.1' BF. ELEV = SURFACE KOP= 2880' Max Angle = 94' @ 1007Y Datum MD= 9985' DatumTVD= 8800'SS ABANDONED Minimum ID = 2.0- @ 9937' 4-112" WFD WS -R -B PACKER 1_4-12' TBG, 12.6#, L-80 0152 bpf. D = 3.958' 1 7' CSG, 26#. L-80 NSCC. ID = 6.276' I PERFORATION SUMMARY REP LOG: GLS ON 03/07/96 ANGLE AT TOP PERF: WA Note: Refer to Rodmikin DB for historical pert date SIZE I SPF WER2VAL OW—Sgz SHOT I SOZ 02-37 2-7/8' 6 9880-9905 S 10/30/02 0526/18 2-7/8' 6 9905-9930 S 10/30/02 0526/18 2-71W SLTD 9964-11613 S 12/07/96 0526118 02.37L7 2-718' I SLTD 9974 - 11037 S 1224/03 0526/18 1 4-1/2' LNR, 12.6#, L-80 BTC -M, .0152 bpf, ID = 3.958' I Tim 02-37 L1 RILLAHANWNMEN1 -WH I HEADCUF3' BELOW TUNDRA, MARKER CAP INSTAL I AND BACKFILLED (05115119) 582'RESTRICDONLUNABLE TO PASS w/2.55' CENT (5/25/13)BUT ONLY w/ 1.5' TOOL STRING (A WGRS 1121/12 & 525/13) —535' TBG & W CMT TO SURFACE (03/121191 Y CAM BAL-O SSSV I GASUFTMANDRELS 7"X 4-1/2' BKR S-3 PKR, D = 3. 4-1/2' HES X NIP, ID 5- X 7- BKR ZXP LTP PKR. HMC HGR W/ 6' PBR D = 4.437' BKR 5' TR®ACK STEM w / SEAL D = 3.937' 3.75' MLL0UT WINDOW (02-37 L7) 9918'-9923' ;i�]3.525' BKR DWLOY SLV, ID=3.00' 9937' 3-12' X 2-7/8' XO. ID = 2.380' 2-7/8' LNR 6.16#, L-80 STL, .0053 W, ID = 2.377' 9937 4-12' WFD WS -R -B PKR ID = 2.0' (1. CA 9947' J14-12' X 2-7/8' TW S-6 HI -PRESSURE PKR w/ HOLD DOWNS & LNR HGR D = 2.37' PRUDHOE BAY UNIT WRL 02-37/L1 PERMITNo: 1961750/2030980 AHNo: 50-029-22717-00/60 SEC 36, T11 N, R14E 1701' FWt. & 680' FNL DATE REV BY I COMMENTS DATE REV BY I COMMENTS 12/06/96 N2PS NITIALCOMPLE ION 06/12/18 MWJMD C0RRECTEDT0CTBG OEPfH 1225/03 NORDIC 1 CTD LATERAL (02-37 LI) 03/18/19 MRRO/JMD CEMENTED TBG & N (03/12/19) 1126/12 MSS/JMD RESTRICTION (1121/12) 05/23/19 0527/13 CJWPJC RESTRCTION UPDATE O6111/19 JNL/JMD ADDED OKB & BF LLEV I 06/16/13 PJC LINER / GLV CORRE:TIONS BP Exploration (Alaska) O6/07/18 GPUJMD SUSPENDED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEINED la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended m ' UUQ Well Class: 20AAC 25.105 20AAC 25.170 11EI11WINJ WAG WDSPL ❑ No. of Completions: Zero 11b. DeveloprA10 C1cd 930 rC 11GINJ (❑ Service Stratigrephicc T(estt ❑ 2. Operator Name. 6, Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 6/8/2018 196-175 • 318-205 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 11/7/1996 50-029.22717-00-00 4a. Location of Well (Governmental Section): B. Date TO Reached: i6. Well Name and Number: 12/3/1996 PBU 0247 ' Surface: 4600' FSL, 3579' FEL, Sec. 36, T1 IN, R74E, UM 9 Ref Elevations KB 61.10 • 17. Field/Pcol(s): Top of Productive Interval: 2423' FSL, 2112' FEL, Sec. 25, T71 N, R74E, UM GL 30.90 . BF 31.96 , PRUDHOE BAY. PRUDHOE OIL Total Depth: 4127' FSL, 2646' FEL, Sec. 25, 71 IN, R14E, UM 10. Plug Back Depth(MD/TVD): 18, Property Designation: ' 4600'14425' - ADL 028308 . 4b. 41b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 688444 • y- 5950542 • Zone - ASP 4 11617'/8806' • 74.017 TPI: x- 689832 y- 5953681 Zone - ASP 4 12. SSSV Depth (MD/TVD): Y0 Thickness of Permafrost MD7TVD Total Depth: x- 689254 y- 5955371 Zone - ASP 4 None 1900' (Approz.) 5. Directional or Inclination Survey: Yes ❑ (attached) No EI 13, Water Depth, if Offshore: 21. Re-drill/Lateral Top Wlndov Submit electronic and printedMD/TVD: ntetl information per 20 AAC 25.050 N/A (ft MSL) N/A 22_ Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma my, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD, GR, RES, CNL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT.� GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZERD CEMENTING RECO PULLED AMOUNT TOP BOTTOM TOP BOTTOM 20" 94# Hop 31' 112' 31' 112' 30" 260 sx Arctic Set (Approx.) 7" 26# L-90 31' 3579' 31' 3536' 8-1/2" 2000 sx CS III, 567 sx Class'G' 5"x4 -1/Z' 18#/12.6# L-80 3410' 9968' 3382' 8855' 6" 350 sx Class 'G' 2-7/8" 6.76# x-80 9947' 11615' 8855' 8806' 3-3/4" Uncemented Sloded Liner 24. Open to production or injection? Yes ❑ No RI 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number, Date Perftl): GRADE DEPTH SET (MO) PACKER SET (MD/TV 41/2" 12.6# L-80 3424' 3376'13351' 5� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. D E / _ / Y Was hydraulic fracturing used during completion? Yes 11 No 8 Per 20 AAC 25.283 (i)(2) attach electronic and printed V! { information VERIFIED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Tl� 4600' 125 Bbls Class'G' 27. PRODUCTION TEST Date First Production: Not on Produdion Method of Operation (Flowing, gas lift, etc.): WA Date of Test: Hours Testetl: Production for Test Period —I Oil -Bbl : Gas -MCF: Water -Bbl: Choke S've Gas -Oil Ratio Flow Tubing Press Casing Press: Calwlaled 24 Hour Rete �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API(com: Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RIBM1471 JUL 0 3 2018 Mc-RO G 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sldewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071, 29, GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 8 Permafrost - Base ' 4yy tPoo T/h 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. Sag River 9056' 8283' Shublik 9105' 8324' Sadlerochit - Zone 4 9171' 8380' CGL - Zone 3 9342' 8526' Base of CGL - Zone 2 9424' 8595' TDF - Zone 1 9826' 8838' Kavik - Base Sadlerochit 10510' 8846' Formation at total depth: Base Sadlerochit 10510' 8846' 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 true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hibbert, Michael Authorized Title: SI cialist Contact Email: Michael.Hibbert@BP.com Authorized Signature: ate: I V Contact Phone: +1 907 564 4351 INSTRUCTIONS General: This form is tlesignetl 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 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 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-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 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 teats as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only ****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 bbis 1 % KCL, 38 bbis Geovis, 10 bbls 1 % KCI and 103 bbls of Crude. After 150 bbis 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 Ste #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 = Vac/Vac. 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 bbis 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 1 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 = Sl. T & IA FL (post L&K). TFL @ 100' (2 bbls). 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 bbis away. WV,SW,SSV= C MV= O IA= OTG ** IA on VAC upon departure**** 5/22/2018 Final WHP's=VacNac 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 = VactVac. 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 = VacNac. Temp = Si. IA FL (post L&K). No AL. Hardline rigged up to TBG. IA FL @ near surface. WHPs unchanged overnight. 5/24/2018 SV, WV, SSV = C. MV = O. IA = OTG. 17:00 T/I = VacNac. 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 SV, WV, SSV = C. MV = O. IA = OTG. 1700 hrs. Daily Report of Well Operations 02-37 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 1 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 SWOP 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 ISV, WV, SSV = C. MV = O. IA = OTG. 11:00 m aw SUSPENDED WEUJ-FAD= FMC ACTUATOR= BAKERC NfWLKB.HEV 6/' OF. BPI = 6 KOP= 28W Max Angle = 94° Q 10073' MWn MD= 9985' Datum TVD = 8800'SS 1 4-12" 20" CONDUCTOR 9411, H-40, D = 19.124" I� Minimum ID = 2.0" @ 9937' 4-112" WFD WS -R43 PACKER 1.4-2" 0D1=2.69#L80 0C 152T 1 3679' 1 PERFORATION SUNtJARY Rff LOG: GLS ON 03/07/96 ANGLE AT TOP PR3iF. WA Note: Refer to Production 08 for historical pert data SIZE I SPF I WaRWAL I OpNSgz I SHOT I SW 02.37 2-718" 6 12125103 NORDIC 1 CTD LATERAL (02-37 Lt) S 10/30/02 052611 W 2-718" 6 �9=-%051 9905-9930 S 10/30102 0526118 2-78" SLTD 9964-11613 S 121(17!96 0526118 02-37L7 2-7/8" SLTD 9974 - 11037 S I 1224!03 05/26/18 1 2-7/8" LNR B.S#. L-80 STL..00W bof. D = 2.441" I SAFETY NOTES: ELL ANGLE> TO- 02-37 LNR TOP @ 3492'WSEEE HISTORY). WHHIIPSTOC WASE L 1 RETRIEVED 0 9937. Tr582' f4ESTRICfDN-UNABLETO PASS w/2.55" CBOT (5125/13)BUT ONLY w 11.5' TOOL STRING (AWGRS 1121/12 8 525/13) GAS LFT MANDRELS I 341W 114-1rz"1fSXNP,O=3.813" I 3410' S• X 7' BKR ZXP LTP PXFZ. MAC FRGR WI6' PER, D= 4.437- 3417' BKR V TEBACK ST94 w / SEALS, ID- 4.408• -3L'10' S• X 4-12• XO D = 3.937' 3.75- MLLOUT WINDOW (02-37 LI) 9918' - 9923' 347 3.525" BKR DEPLOY SLV, D = 3.00" 1 2-7/8" LNR 6.18p, L -BO STL, .0053 bpf, D - 2.377• DATE RB/ BY COMMENTS DATE REV BY COMMBJTS 12108198 N2FR INITIALCOMPLETION 11/26112 MSSUMD RESTRIMIDN(1121112) 12125103 NORDIC 1 CTD LATERAL (02-37 Lt) 05/27/13 CJWPJC RESTFM'"UPDATE 08104/04 JLVILP GLV d0 06/16113 PJC LP62/GLV COR(;ECiDNS 1220109 SV LATERAL NAMING FORMAT 06/07118 GPL/JMD SUSPIED® 03126111 GJF/PJC RESTRICTION (03124111) 06/12118 MWJMD ooRREcT®TOCTBGOEPRH 03126111 PJC LNRODRITH.'ms 4-12" X 2-7IW TW S-6 HLPRPaSURE PKR w / HOLD DOWNS 8 LNR FGR D = 2.37" PRUDHOE BAY LMT WELL- 02.37 / L1 PEFWT No: 196175012030980 AR No: 504)29-22717-00 160 M1N,R14E, 1701'FWL8680'FFL BP Exploration (Alaska) • pro J9 - 17S Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,June 05, 2018 1:30 PM To: 'Worthington,Aras J' Subject: RE: Reservoir Abandonment for Well 02-37 Aras, CMIT TxIA approval granted. Please include this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska SCANNED JUN 1 $'20ig 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:Worthington,Aras J<Aras.Worthington@bp.com> Sent:Tuesday,June 05,2018 1:27 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Hibbert, Michael<Michael.Hibbert@BP.com> Subject: Reservoir Abandonment for Well 02-37 Good Afternoon Victoria, We have executed the cement job already. We tried to get a tag of the TOC but the restriction at—580' MD would nit pass even a 1" OD SL toolstring. The TOC is estimated to be at—4600' MD based on the fill-up volume required to lo.d the tubing prior to the Pressure Test. As for the pressure test,we mistakenly submitted the Sundry prescribing an MITT to test the cement plug. Because t is well has TxIA communication,an MITT will almost certainly fail (communicating to the IA). A CMIT T-xlA is therefore he appropriate test for the cement plug. We are asking that you approve an AOGCC witnessed CMIT TxIA in place of th- originally proposed MITT. Thanks for your consideration and apologies for the confusion on our end. Aras Worthington Well Interventions& Integrity Engineer BP Alaska Inc. Office: (907) 564-4102 1 hinum or 711 • 0,1",i', 1///>1,v, THE STAT Alaska Oil and Oas ti��►��� A� ofA ASKA Conservation Commission *Pt _ _= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 �Q. Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska'igov Michael Hibbert Well Interventions Engineer ��� ���� BP Exploration(Alaska), Inc. P.O Box 196612 scow Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool,PBU 02-37 Permit to Drill Number: 196-175 Sundry Number: 318-205 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 DATED this day of June,2018. RBDIAS'4.0 JUN 4 w► ECEWED STATE OF ALASKA R , . • ALASKA OIL AND GAS CONSERVATION COM ON 1 / APPLICATION FOR SUNDRY APPR S �sA 20 AAC 25.280 MAY s, U 2018 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shut old Suspend lI • Perforate 0 Other Stimulate 0 Pull Tubing 0 Chang Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other la 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 196-175 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p. 6. API Number 50-029-22717-00-00 • 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No IRI PBU 02-37 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028308 ` PRUDHOE BAY,PRUDHOE OIL ` 11. PRESENT WELL CONDITION SUMMARY I Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11617 • 8806 ` 11615 8806 None 9941 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 31-112 31-111 1530 520 - - Surface 3548 7" 31-3579 31-3536 7240 5410 Intermediate Liner 6558 5"x 4-1/2" 3410-9968 3382-8855 10140/8430 10490/7500 Liner 1668 2-7/8" 9947-11615 8855-8806 13450 13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9880-11613 8848-8806 4-1/2"12.6# L-80 30-3424 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 3376/3351 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary II Wellbore Schematic p 13.Well Class after proposed work: : Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development RI Service 0 14.Estimated Date for Commencing Operations: May 19,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended IZI 16.Verbal Approval: Date: 5/18/2018 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.HibbertOBP.com Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions En ine Authorized Signature: ���\�^(s\1 . Date: 6/!�i IIB. V"_ ,lam COMMISSION USE ONLY I Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3I -2- 2®S' Plug Integrity Ev7 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: 5vrfGEc c pif/7 h?vs¢ 6e Sz'/ 1,7 /213/ / /67 Post Initial Injection MIT Req'd? Yes 0 No I / Spacing Exception Required? Yes 0 No le Subsequent Form Required: /i2— 40 3 APPROVED BYTHE I I Approved by: Ca35.-1,_____ COMMISSIONER COMMISSION Date: ( L{It p. V r77-. 5/3//J'1 ORIGINAL .0!� RBDMSSb JUN 0 4 2016 , c--2*, lb Submit Form ar�d Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplice e bp• •0 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 .,!--at fC kr y 1--1/11 S S ➢ MIT-T to 2500 psi ➢ SL tag cement 2t. 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 010 IRE'. (7110 WH1t6AD= FMC 02-37 SAFETY NOTE: WELL ANGLE>70'el 97W. DAMAGED UR TOP 42 3432'(SEE HISTORY). WIWSTOCKWAS ACTUATOR= EtAKFR C Ll RETRIEVED pl 993T. 14TL'L KB.ELEV 61 0 17 tpp 0 582 I- i 'TRICTIIXNBLVEOwASSwTDOIs" Datum MD= 9985' STRING(A WGRS 11121/12&5/25/13) Datum TVO= 8800'S5 I 2079' H4-1/7 CAM BAL-O SSSV NP,D=3.812' 2D-GCM LkL tA...Bok,1440,D-19.124- 110- GAS LJ-I MANLkdiS ST MD TVD DEV TYPE VLV LATCH PORT DATE L . 1 3350 3326 21 KBG-2LS DMY M 0 04/22/07 Minimum ID=2.0"@ 9937' 4-112"WFD WS-R-6 PACKER x' /.._.3376' -Ir x 4-1/7 BKR S-3 WA D=3.875" I ____ _.. 3410' I--14-1/2'ITS XMP,ID=3.813" 4-112'TEG 12 6S,L-80 BTC, 341 T 0152 6pf,Q 3.958' - MI'.I •► I 3410' I .5'X 7'BKR ZXP LTP Fi<R • �" HMC I13R VW 6'FUN,D=4,43r 3417' lolvt 7 111:D4C1(3T1:101w/3tALO D-4-400' 3430' -5'X4-172'X0, D-3.937' 7'CSG,260,L-80 f43CC,D=6.276' -I 367W —4 k 3.75"MILOUT WNDOW(92.32'L1) 9910'-9923' - PERFORATION SLUMRY 9937 3-1/2'X 2-7/8"XO,D=2.380" RFT LOG.GLS ON 03107/96 ANGLE AT TOP FEFF NIA T 11069' FBTD Note:Refer to Production DB for hatoncal pert data AI SEE j SPF INTERVAL I0pri1 SHOT I SO2 --- --- - - - 02-37 2-718' 6 9880-9905 0 1013002' E-7/8'LNR,616#,L-80 STI, 0053 epf,0-2 377' -I. 11070' J 2-718' 6 9905-9930 O 10/311002' 2-718' SLID 9964-11613 SLOT 12107196 K71 gr—f- 993r H--I4-112'1 WFD WS-R-B.ACF;D=2.0'(12/18/03) 02-37L7 Ihr1 9841' HF151+CATCHER SUB)CAP,SIPS(5/18/03) 2-718' SLTO 9074.11037 SLOT 12/24/03 li 11'... 9947' I-4-18'X 2-7/8'TIW S-6 HI-PRESSURE R(R w/HOLD DOWNS&LNR I-GR,D=2 37' 4-112"L ,12 60,L-80 Bit-M..0152 bpi,0=3.958" - 9985 1-40 I 1 i I' F I 1 I M I 1 I 1 i 1 1 1 1 1 1 1 NOV O ft) 2.7/8w LNR 6.54,L=80 ST05 L,.06 bpf,D=2.441 [ 11616 !I4�1 !! TDiiseir DATE REV BY COMMENTS DATE FEV BY COMMENTS PR DHOE BAY LRVT 12/11,/,4 NaES IPf71AL CoMPLETK-41 1//26112 Mew/ V PGSTFI:'TYYl(11 121'12) 1AG L. 02-371 LI 1286/03 NORVIC 1 CTD LATERAL (02-37 LI) 05/27/13 C.R*PJC RESTRICTION LI1WTE PERAT No 1961750/2030980 08/04+04 J11/TLP GLV 00 06/16/15 PJC 'L1'E R/GLV CORRECTIONS AFI P . 50-029-22717-00160 12/2089 SV -LATERAL MIMING FORIAkT SEC 36,T11 N,R14E 1701'FWL&600'FAC 03/26/11 al/NC RESDacr10N(03/24/11) - 03/26/11 PJC LNR CORRECTIONS BP Exploration(Alaska( 2 fir ost Reservoir Abandonrt TREE= aW= F`A'D SAFETY NOTES: WELL ANGLE>70° 9756'. DAMAGHI WELLHAGITATOR- BAKl 2 G 37 LNR TOP 3432'(S�HISTORY). WI*STOGK WAS _ T _ Ll R EVIDa •. NT1AL KB.a.Ey 61' , 1 OP - 288(/ , 582' 'RESTRICTION-UNABLE TO PASS w/2.55" Max Angle= 94", 10073' > ---%"- CENT (5/25113)81.11 ONLY w 11.5"TOOL Datum MD- 9985 STRING(A WC,RS 11)21/12&5/25/13) Datum TVD' 8800'SS { 2079' H4-1/2"CAM BAL-O SSSV N?D=3.812" I 20-oats]UG1Orl,941x,1'1-40,ID-19.124- -j 1 to- CTAS LI-I MArN.NELS ST KO TVD OEM TYPE VLV LATCH PORT DATE ' 1 3350 3326 21 KBG-2LS LIMY NT 0 04/22/07 Minimum ID=2.0"@ 9937" ��. 4-1/2"WFD WS-R-B PACKER �� ► ,� TIr J L;- X4-1/2'BKR S-3FKRU=3.875'—I III3410' H4-112"HES x NF'.0.3.813" 4112"TEOG,12 6#,L-8013TC, H 3417' _— 0152 bpf,D=3.958" lam/ --j 3410' I-5'X 7'BKR ZXP LTP FKR, '..— 14CHICO VW 6'MR.D=4,437' j 3417' 104017 TCDAON 3112.1 vr I OCALO,0-4.400' 3430' —5"X4-1 r2"XID, D=3.937" -r CSG.2611,L-80 USCG.0.6276" 367W —44 Proposed TOC in Tubing—9380' MD ►.: 3.75"MLLOUT WINDOW(02-37 L1) 9918'-9923' P87F[)ftATIDN SUMMARY :::'' 9937' -13-12"X 2-71-8'XO,13=2.380" REF LOG GLS ON 03/07196 ..::::: ANGLE AT TOP P131 NA .i: i:c....:. 11069' - PBTC) Note:Refer to Production DB for historical pert data :::: I SZE I SPF 1 INTERVAL IOpnr SHOT ( saz 7 ■ 2-7/8" 6 9 880-9905 O 10/30/02 `..` C2-7B'LM 6 16# 1 30 STI.. 0053. bpf =2 377" ) 11070' 2-7/8* 6 91905 9930 O 1 0/3010'7 2-718` SLTD 9964-11613 SLOT 12/07/96 ..:::: 9937' H4-112' WOWS-R-8PKR,ID=2.0"(12/16631 02-37L1 9941' HF>sl+CATCHER SLE BSD CAP SIPS(5118/03) 2-718" 9974 11037 SLOT 1224/(X3 „ : ,:, :: 9947' I—4-1.12.x2-7/8"TIN 5-6 hI-PRES3t1RE PKR w 1 HOLD DOWNS&LIC I-GR,13=2.37" 4-1/2"LMR,12.6#,L-80 BTC-M, 0152 bpf,D=3.958" - 996W '0'4'0'4 10 2-7/8"LMR,6.5#,L-80 SR,.0058 W.13=.2.441' 1-- 11615' I f Il i R L 'D J 11617` DATE , REV BY COAA1�E34TS D4lE FEV BY CQARIBNT3 R IOEBAY INT 12/46105meg �NIITlALCOMPLETION ' 11/2&/12 kb-Si/kV i TP'YTK�!(1I/21A2) MALL 02 371 LI 12125/113 NO14131C 1 GTO LATERAL (0247 L1) 05/27/13 CJN'PJC RESTRICTION URATE 113,61T Pb: 1961 750 12030980 08/04/04' .1L.1ITLP'GLV 00 06/16113 PJC LNER f GLV CORREC1101,15 AR Pb. 50-029-22717-00/60 12/20/09 SV LATERAL NAMING FORMAT SEC 36,T11N,R14E, 1701'FW &680'FNL 0326/11 GJF/PJC RESTMTION(03124/11) 03120111 PJC LNRCORRECTIONS i BP Exploration(Alaska) 3 TIO Plot • • a sots • 190 '''500 • 180 3403 1 170 3203 1 160 I O 150 ` {{ 14 0 TIO r 26001 180 2SDP 120 t� --a—IA 110; —A—ON 2 YC lopU0A 1.9a J 90 ■ Bleed lin{ 30 Ope a ,4t0.' -0 + Not o • Under vel 12301 Tan Mute e0 30 tX 20 .'3;7 .'k.`^,? 07.',3 072- :3:,,' ^I2+',' 4`3•',.y ', 2 •,.52?' ;,:'6?' ??11017c '2iia;?i 183N17 .`1318 7..1 25.10 fi2:18,13 v22'B ,.r,S$18 �"..'.4ei:. .:s'?ryl8 _ 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 • • Loepp, Victoria T (DOA) From: Roby, David S (DOA) Sent: Thursday, May 24, 2018 1:15 PM To: 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) Works for me. Dave Roby (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.roby@alaska.gov. From: Loepp,Victoria T(DOA) Sent:Thursday, May 24, 2018 12:48 PM To: Roby, David S(DOA)<dave.roby@alaska.gov>; Davies,Stephen F(DOA)<steve.davies@alaska.gov> Subject: Re:Sundry applications to suspend PBU 02-37 (PTD 196-175)and PBU 02-37L1 (PTD 203-098) We can make that a condition on the sundry to complete abandonment within 6 months.We've done that before.Th s reservoir plug was needed immediately. Sent from my iPhone On May 24, 2018, at 12:33 PM, Roby, David S(DOA)<dave.roby@alaska.gov>wrote: So, if there's no future utility for the well why don't they go ahead and set the surface plug now? Dave Roby (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. From: Hibbert, Michael [mailto:Michael.Hibbert@BP.comj Sent:Thursday, May 24, 2018 8:39 AM To: Roby, David S(DOA)<dave.roby@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Davies,Stephen F(DOA) <steve.davies@a laska.gov> Subject: RE:Sundry applications to suspend PBU 02-37 (PTD 196-175)and PBU 02-37L1 (PTD 203-098) Dave, 1 This well has no future ui. With the descoped well design and resion at—580'there is no potential to work-over or sidetrack this well. Thanks, Michael Hibbert BP Alaska—Intervention&Integrity Engineer <image001.png> Email: Michael.HibbertPbp.com From: Roby, David S(DOA)<dave.roby@alaska.gov> Sent:Wednesday, May 23, 2018 5:10 PM To: Hibbert, Michael<MichaeLHibbert@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.roby@alaska.gov. 2 • • 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 Conservati.n 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 Abandonm:nt 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.Loepp(cilalaska.gov 1 CONFIDENTIALITY NOTICE:This e-mail age,including any attachments,contains inforlikn from the Alaska Oil and Gas Conservati n 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.Loeop@alaska.gov 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 pumpi g a reservoir abandonment tomorrow due to the TxIA communication that has developed recently and the single casin: design of this well. Please reply with your approval. Thanks, Michael Hibbert BP Alaska—Intervention& Integrity Engineer VIN O L`a'L53g .ot'�IC';, , Email: Michael.Hibbert@bp.com 2 • • Loe. •, 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 318-20.)) 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.Loeppalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservat on 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 i to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 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 pumpiig 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 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 0 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 46 W W <0# 4 t 1 40 ' Mr. Tom Maunder r aise Alaska Oil and Gas Conservation Commission r. 333 West 7 Avenue 4Ntit, Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 1 q7- I '7 Dear Mr. Maunder, 0 9-" 37 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • r BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 02-37Ll (PTD #2030980) Classified as Problem Well 02-- ~7-? (>st) 4- lq~-l7 S' ~ All, Well 02-37L 1 (PTD #2030980) has been found to have sustained casing pres7ure on the IA. The TI pressures were 2300/2180 on 04/18/07 when a TIFL failed on build up rate. v The plan forward for this well is as follows: 1. D: TIFL - FAILED on BUR 2. S: Dummy OGL V 3. D: Re-TIFL post DGLV P"'/Iu"c¡ '- C ,/1 U~ Lw r~ ,'5j_ I ~f-:. 7 Z-'tOfs\ <SCP '" 2-{ fDpsì => 30, { '2c A well bore schematic has been included for reference. «02-37L 1.pdt» The well has been classified as a Problem well. Please call if you have any questions. Thank you, )fnna (})u6e, œ. P.. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 .---' òl.L- f€r Cò~z-- ," #\~NED ~?R s () '2.007 tiC,., Content-Description: 02-37Ll.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 4/23/2007 11 :48 AM TREE = WELLHE'A D = AClUA TOR = Kß, B..EV = BF, B..EV - KOP= Max Angle - D3tum 1\¡1) = D3tum lV D- FMC crw BAKER C 61' . 02-37L 1 SAFETY NOTES: DAMAGED LNR TOP @ 3432' (SEE HISTORY). WHIPSTOCK WAS RETRIEVED @ 9937', 2880' 94 @ 10870' 9985' 8800' SS . 2079' 7" CSG, 26#, L-80, 10 = 6.276" 7" X 4-1/2" BAKERS-3 PKR, D =3.875" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" , 15" CSG, 18#, L-BO, 10 = 4.276" I 4-1/2" HES X NP, ID-3.813" 5" X 7" BKR ZXP L TP A<R, HIIIC HGR W/6' PBR, 10 = 4.437" - 5" X 4-1/2" XO, ID = 3,937" I Minimum ID = 2.0" @ 9937' 4-1/2" WEATHERFORD WS-R-B PACKER PERF ORA llON SLMMl\ RY REF LOG: GLS ON 03/07I'J6 A NGLEA TTOP PERF: 80 @ 9880' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz DL\TE 2-718" 6 9880-9905 0 10/30/02 2-718" 6 9905 - 9930 0 10/30/02 9964- 11613 SLOTTED 12/07/96 02·37 L1 SLOTTED LINER 9974- 11037 0 12/24/03 I MlLOUTWINDOW 9918' - 9923' 14-1/2" WFDWS-R-B PKR, ID - 2.0" (12/18/03) I FISH - CATCHER SUB END CA P, SLIPS LlH 05/18/03 4-1/2" X 2-7/8" 11W S-6 PKR W/ HOLD DOWNS, D = 2.37" - 3.525" BKR DEPLOYMENTSLV, ID= 3.0" -i3-1/2" X2-7/8"XO,ID- 2.380"1 I 3-314" OPEN HOLE , , , , , 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID: 3.958" 2-7/8" LNR, 6.16#, L-80, .0053 bpf, ID :2.337" 12-7/8" SLOTTED LNR, 6.5#, L-80, ID: 2.441" I 12-7/8" LNR, 6.5#, L-80, .0579 bpf, ID = 2.441'" 11615' 11613' 11617' DATE 12/06/96 12/25/03 01/15/04 06/15/04 07/19/04 08/04/04 REV BY CO MrÆNTS ORIGINAL COMPLETION TMNlKK CTDSIDETRACK(02-37 L1) KSBlKK GL V C/O SRBIKAK rv1N D CORRECTION RMI-VKAK GL V C/O JLJfTLP GLV C/O DL\ TE REV BY COrv'MENTS PRUDHOE BAY UNIT 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 BP Exploration (Alaska) ( ( )9{o-115 WELL LOG TRANSMITTAL ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7lhStreet Suite # 700 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 BP Exploration (Alaska), Inc. ProActive Diagnostic Services, Inc. Petrotechnical Data Center LR2-1 P. O. Box 1369 900 E. Benson Blvd. Stafford, TX 77497 Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 1 1 1 Res. Eva!. CH 1 1 1 OS 02-37 1 2-1 8-03 Mech. CH 1 i i i~ ~(n'-\ , Caliper Survey Signed: ~\~ ~ ~,Q ~~íÝÌ DateRE6EIVEÐ- Print Name: , /~. f..! 0L (..'1 2004 ~j \¡iI .,"'" i~aska Oil & Gas Cons. Commision Anmorage PltoAcTivE DiAGNOSTic SERViCES, INC., PO Box 1 }b9 SlAHORd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~(Cj~~¡ME.C rEB ij 2 2004 ~~\~,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X MCNL / ADD PERFS Pull tubing_ Alter casing_ Repair well_ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 61 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 680' FNL, 3579' FEL, Sec. 36, T11 N, R14E, UM (asp's 688445, 5950542) 02-37 At top of productive interval 9. Permit number / approval number 3273' FNL, 2204' FEL, Sec. 25, T11 N, R14E, UM (asp's 689751, 5953263) 196-175 At effective depth 10. APl number 1156' FNL, 2645' FEL, Sec. 25, T11 N, R14E, UM (asp's 689256, 5955368) 50-029-22717-00 At total depth 11. Field / Pool 1152' FNL, 2627' FEL, Sec. 25, T11 N, R14E, UM (asp's 689254, 5955372) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11617 feet Plugs (measured) true vertical 8806 feet Effective depth: measured 11613 feet Junk (measured) true vertical 8806 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx Arctic Set (Aprox) 141' 141' Surface 3548' 7" 2000 sx CS III, 567 sx 3579' 3536' Class 'G' Intermediate 6558' 4-1/2" 350 sx Class 'G' 3410'- 9968' 3382'- 8855' Slotted Liner 1668' 2-7/8" Uncemented 9947' - 11615' 8855' - 8806' Perforation depth: measured Open Perfs 9880'-9930'. Slotted Liner 9964'-11613'. true vertical Open Peals 8848'-8854'. Slotted Liner 8855'-8806'. RECEIVED Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 3424' MD. ~0~ 3-1/2" 9.3#, L-80 Tubing @ 9001'. , Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 3376. 5" x 7" PKR W/6" P~.~ 4-1/2" CAM BAL-O SSSV Nipple @ 2079' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or I niection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10/19/2002 484 11377 0 213 Subsequent to operation 11/01/2002 599 11444 0 187 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~.,~t~,~ ~~~ Title: TechnicalAssistant Date November08, 2002 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 o SUBMIT IN DUPLICATE I O/2O/2OO2 1 O/21/2OO2 I O/24/2OO2 I O/27/2OO2 I O/28/2OO2 I O/28/2OO2 10/29/2002 10/29/2002 10/30/2002 11/01/2002 10/20/02 10/21/02 10/24/02 10/27/02 I O/28/O2 I O/28/O2 1 O/29/02 10/29/02 02-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS HOT OTL TBG WASH: HOT OIL TREATMENT TESTEVENT--- BOPD: 572, BWPD: 0, MCFPD: 11,877, AL Rate: 0 PERFORATING: PERFORATING: PERFORATING: PERFORATING: PERFORATING: PERFORATING: PERFORATING: TESTEVENT --- DRIFT/TAG PERFORATING; RST / CNL / PNL PERFORATING; RST / CNL / PNL PERFORATING HOT OIL TREATMENT HOT OIL TREATMENT; PERFORATING PERFORATING BOPD: 599, BWPD: 6, MCFPD: 11,444, AL Rate: 0 EVENT SUMMARY PUMPED 125 BBLS CRUDE DOWN TUBING @ 190 DEGREES, 15 BBLS CRUDE DOWN FLOWLINE @ 190 DEGREES. TESTEVENT --- BOPD: 572, BWPD: 0, MCFPD: 11,877, AL Rate: 0 DRIFTED TBG W/3.50" GAUGE RING TO 9810' WLM, (HAW). (TARGET 9930). GAVE WELL BACK TO DSO (FLOWING). MIRU CTU #9. MU MHA. MHA PLUGGED DURING PT. PUMP 1.25" BALL AND FLUSH COIL. PUMP 1.25" BALL THROUGH CT TO CLEAN UP. MU 2 3/8" WEATHERFORD MHA AND SLB MEM CNL IN CARRIER. KILL W/1% KCL. RIH WITH SWS MCNL, LOG 2 UP & I DOWN PASSES FROM 9000' TO 2 7/8" LINER TOP AT 9947' MD WHILE PUMPING 1% KCL 1 BPM. MU/RIH W/GUN #1. TAG ASPHALTINES @ 1523'. POOH. PUMP 50 BBL 180F DIESEL @ 1.5 BPM. MU/RIH W/GUN #1, 25' 2 1/8", 6 SPF. RIH TO ASHPALTINES @ 3456', WORK DOWN TO 3658'. POOH. RIG UP HOT OILERS. ASSIST CTU - PUMP 55 BBLS DIESEL @ 180 DEG F. DOWN BACK SIDE OF COIL. ASSIST CTU #9 - PUMPED 232 BBLS HOT CRUDE / 20 BBLS HOT DIESEL / 54 BBLS HOT CRUDE / 50 BBLS DIESEL - XYLENE / 15 BBLS CRUDE (TO SPOT DSL-XYL) / SOAK / 7 NEAT FREEZE PROTECT. JET HOT CRUDE FROM SURFACE. TAG @ 9552'. CAN'T JET THROUGH. JET 20 BBL DIESEL PILL. NO PROGRESS. JET 50/50 DIESEL/XYLENE PILL AT OBSTRUCTION, POOH. TAGGED UP @ -434' DUE TO COUNTER SLIPPAGE. DETERMINED WELL IS CLEAR TO LINER TOP. RIH WITH GUN #1 - 25' x 2 7/8". PERFORATE 9905' TO 9930'. RIH W/GUN #2 - 25' X 2 7/8". PERFORATE 9880' TO 9905'. POOH. Page I 02-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS I O/3O/02 POOH TO SURFACE W/GUN # 2. LAY DOWN GUNS. RIG DOWN. TURN WELL OVER TO PAD OPERATOR TO POP. JOB COMPLETE. 11/01/02 TESTEVENT --- BOPD: 599, BWPD: 6, MCFPD: 11,444, AL Rate: 0 Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL 14 NEAT METHANOL 115 60/40 METHANOL WATER 100 METHANOL WATER 95 DIESEL 96 50/50 DIESEL-XYLENE 659 CRUDE 326 1% KCL WATER TOTAL ADD PERFS 10/29/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" PJ, 6-SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9880'-9930' Page 2 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 96-175 MWD SRVY ~-11617 96-175 BHC/SL --~600-9972 96-~75 CN/LD~ ~600-9972 96-175 SSTVD ~/8600-9972 96-175 QC ~8600-9972 96-175 CN ~-~'8600-9972 96-175 BHP ~F/8600-9972 96-175 7610 ~CHLUM BHC 96-175 NGP-TVD ~685-8806 96-175 NGP-MD ~8369-11617 96-1~5 GAs L=~ ~3000-9750 SPERRY GR Page: 1 Date: 11/25/98 RUN RECVD 02/12/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 FINAL 02/14/97 02/14/97 FINAL 03/26/97 FINAL 03/26/97 FINAL 04/04/97 04/16/97 lO-4O7 ~eO~E~ON DA?E $/~ /~$/ DAILY WELL OPS R ,~/ , /~/ TO .~/~ /f6/. Are dry ditch samples required? yes ~d received? Was the well cored? yes ~-~lysis & description received? Are well tests required? ~s ~eezved. Well is in compliance Initial COlVllVlE~TS spenn t-sur. CI !::! I I__!__ I i~J G S E F:I ~./I r- I:::: S WELL LOG TRANSMITTAL To: State of Alaska April 16, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 02-37, AK-MW-60162 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22717-00. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W, International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10904 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 4/2/97 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Disk D.S, 2-21 PRODUCTION PROFILE 970204 I 1 D.S. 2-37 GAS LIFT SURVEY 970309 1 1 D.S. 5-12 PRODUCTION PROFILE 97021 4 I 1 D.S, 6-22A PRODUCTION PROFILE 97031 9 I 1 D.S. 9-51 PRODUCTION PROFILE W/DEFT 97031 9 I 1 D.S. 13-26 PRODUCTION PROFILE 970205 I 1 D.S. 14-3A GAS LIFT SURVEY 970209 1 1 , , SIGNED: DATE: APR 0 4 ]997 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. AJ,~ska (:;it & Gas Co,Is. C;ommissior~ tv!r, hom, g.'. e 0 !:! I I--I--I IM G S I~ I=! ~/I r' I:: S WELL LOG TRANSMITTAL To: State of Alaska March 26, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs DS 02-37, AK-MW-60162 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 02-37: 2"x 5" MD Gamma Ray Logs: 50-029-22717-00 2"x 5" TVD Gamma Ray Logs: 50-029-22717-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company .... STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION CL,,,,iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-175 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6~61_2 ....... 50-029-22717 4. Location of welt at surface ~ w.,~,,.~.~;..,~ [ 9. Unit or Lease Name 4600' NSL, 3579' WEL, SEC. 36, T11N, R14E~ii/J/CZ' ':'~?~',~(~ i~i ~,::: .,. ~,.:~.. ........ .... ~ Prudhoe Bay Unit At top of productive interval .._. ~. ~ .~. yLr~F~ ! 10. Well Number 2007' NSL, 2204' WEL, SEC. 25, T11N, R14E ~ ~;:;7£~ ' 02-37 At total depth ....... ~ ....... ~.~---~- ....... ~- 11. Field and Pool 4128' NSL, 2649' WEL, SEC. 25, T11 N, R14E !' ~~ ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sbht~rN-6: ~ ' Pool KBE - 61.10'I ADL 028308 12. Date Spudded11/07/96 113' Date T'D' Roached I 14' Date C°mp" Susp" °r Aband'115' water depth' if °ffsh°r° 16' N°' °f C°mploti°nsl 2/03/96 12/06/96 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 19. Directional Surveyl20. Depth where SSSV set121. Thickness of Permafrost 11617 8806 FTI 11617 8806 FT [] Yes [] NO I (Nipple) 2079' MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SE-II'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 31' 3579' 8-1/2" 2000 sx CS III, 567 sx Class 'G' 4-1/2" 12.6# L-80 3410' 9968' 6" 350 sx Class 'G' 2-7/8" 6.5# L-80 9947' 11615' 3-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Liner 4-1/2", 12.6#, L-80 3424' 3376' MD TVD MD TVD 9964' - 11613' 8857' - 8806' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 75 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) December 16, 1996 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure ~,ALCULATED ~ OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marke. 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 9057' 8283' Shublik 9103' 8322' Top of Sadlerochit 9167' 8376' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that tbe'fbTegoing i¢~true~nd~oj'rect to the best of my knowledge . s, ne ...... Title Senior Drilling Engineer Date -Z_ ~ Dan Stoltz ? ,~ Prepared By Name/Number: Terrie Hub~le,- 564'-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM :27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 FEE] 2 1 199! .Alaska 0il & Gas Cons, Comm~i0n SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ ARCO Well Name: 02-37 Rig Name: Nabors 2ES AFE' 4J0332 Accept Date: I 1/06/96 Spud Date: I 1/07/96 Release Date: 1 2/06/96 Nov 7 1996 (1) Rigged up Flowline. Held safety meeting. Rigged up Kelly. Circulated at 79 ft. Circulated at 79 ft. Drilled to 349 ft. Held safety meeting. Drilled to 742 ft. Nov 8 1996 (2) Drilled to 1265 ft. Held safety meeting. Drilled to 2029 ft. Circulated at 2029 ft. Pulled out of hole to 600 ft. Washed to 622 ft. Pulled out of hole to 215 ft. Held safety meeting. Pulled out of hole to 0 ft. R.I.H. to 1987 ft. Drilled to 2186 ft. Nov 9 1996 (3) Drilled to 2728 ft. Held safety meeting. Drilled to 2792 ft. Circulated at 2792 ft. Pulled out of hole to 0 ft. Pulled BHA. Downloaded MWD tool. R.I.H. to 2792 ft. Drilled to 3240 ft. Held safety meeting. Drilled to 3601 ft. Circulated at 3601 ft. Nov 10 1996 (4) Pulled out of hole to 0 ft. R.I.H. to 3205 ft. Reamed to 3238 ft. R.I.H. to 3545 ft. Reamed to 3601 ft. Circulated at 3601 ft. Held safety meeting. Pulled out of hole to 1000 ft. Pulled BHA. Rigged up Casing handling equipment. Ran Casing to 3579 ft (7 in OD). Held safety meeting. Rigged up Cement unit. Mixed and pumped slurry - 72O bbl. Nov 11 1996 (5) Rigged down Additional services. Rigged down Additional services. Rigged up Well control. Rigged up BOP stack. Held safety meeting. Rigged up BOP stack. Tested All functions. Laid out 3.5 in drill pipe from derrick. Serviced Block line. Laid out 3.5 in drill pipe from derrick. Made up BHA no. 3 . Held safety meeting. Made up BHA no. 3. R.I.H. to 3458 ft. Held drill (Kick (well kill)). Tested Casing - Via annulus and string. Drilled cement to 3601 ft. Drilled to 3621 ft. Nov 12 1996 (6) Drilled to 4166 ft. Held safety meeting. Drilled to 4612 ft. Circulated at 4612 ft. R.I.H. to 3600 ft. Drilled to 4963 ft. Held safety meeting. Drilled to 5218 ft. Circulated at 5218 ft. FEB 2 1 1997 Alaska Oil & Gas Cons, Commission Ant, borage Operations Summary for: 0._ .~7 Nov 13 1996 (7) Pulled BHA. Made up BHA no. 4. R.I.H. to 5218 ft. Drilled to 5286 ft. Held safety meeting. Drilled to 6182 ft. Held safety meeting. Circulated at 6214 ft. Pulled out of hole to 5117 ft. Drilled to 6500 ft. Nov 14 1996 (8) Drilled Pulled Drilled to 6722 ft. Held safety meeting. Drilled to 7199 ft. Circulated at 7199 ft. out of hole to 6108 ft. R.I.H. to 7199 ft. Drilled to 7295 ft. Held safety meeting. to 7750 ft. Nov 15 1996 (9) Drilled Pulled Drilled to 8084 ft. Held safety meeting. Drilled to 8212 ft. Circulated at 8212 ft. out of hole to 7156 ft. R.I.H. to 8212 ft. Drilled to 8324 ft. Held safety meeting. to 8368 ft. Circulated at 8368 ft. Pulled out of hole to 7000 ft. Nov 16 1996 (10) Pulled out of hole to 1013 ft. Pulled BHA. Made up BHA no. 5 . Held safety meeting. Pulled BHA. Made up BHA no. 5. R.I.H. to 3585 ft. Serviced Block line. Serviced Fluid system. R.I.H. to 8330 ft. Washed to 8368 ft. Drilled to 8395 ft. Held safety meeting. Drilled to 8427 ft. Circulated at 8427 ft. Pulled out of hole to 7200 ft. Nov 17 1996 (11) Pulled out of hole to 1008 ft. Pulled BHA. Made up BHA no. 6 . R.I.H. to 4500 ft. Held safety meeting. Drilled to 8650 ft. Held safety meeting. Drilled to 8807 ft. Nov 18 1996 (12) Drilled to 8876 ft. Circulated at 8876 ft. Pulled out of hole to 5000 ft. Held safety meeting. Pulled out of hole to 1008 ft. Pulled BHA. Tested BOP stack. Made up BHA no. 7 . R.I.H. to 8876 ft. Drilled to 8901 ft. Held safety meeting. Drilled to 9015 ft. Nov 19 1996 (13) Drilled to 9015 ft. Held safety meeting. Drilled to 9481 ft. Circulated at 9481 ft. Pulled out of hole to 7601 ft. Held safety meeting. Pulled out of hole to 1008 ft. Pulled BHA. Made up BHA no. 8. Singled in drill pipe to 1008 ft. R.I.H. to 3579 ft. Nov 20 1996 (14) Serviced Block line. R.I.H. to 9481 ft. Drilled to 9531 ft. Held safety meeting. Drilled to 9815 ft. Held safety meeting. Drilled to 9861 ft. Page 2 Operations Summary for: 0,_ 57 Nov 21 1996 (15) Drilled to 9915 ft. Held safety meeting. Drilled to 9868 ft. Circulated at 9968 ft. Pulled out of hole to 8960 ft. R.I.H. to 9968 ft. Circulated at 9968 ft. Pulled out of hole to 1008 ft. Held safety meeting. Pulled BHA. Held safety meeting. Ran electric logs. Nov 22 1996 (16) Ran electric logs. Held safety meeting. Ran electric logs. Rigged down sub- surface equipment - Formation logs. Made up BHA no. 9. R.I.H. to 3550 ft. Serviced Block line. R.I.H. to 9968 ft. Circulated at 9968 ft. Held safety meeting. Circulated at 9968 ft. Pulled out of hole to 858 ft. Pulled BHA. Nov 23 1996 (17) Rigged up Casing handling equipment. Held safety meeting. Ran Casing to 3200 ft (4.5 in OD). Held safety meeting. Ran Casing to 3550 ft (4.5 in OD). Circulated at 3550 ft. Ran Casing to 6558 ft (4.5 in OD). Ran Drillpipe in stands to 9968 ft. Circulated at 9968 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry - 129 bbl. Displaced slurry - 121 bbl. Reverse circulated at 3410 ft. Tested Casing. Tested Casing. Held safety meeting. Circulated at 3410 ft. Pulled Drillpipe in stands to 0 ft. Worked on BOP - BOP stack. Nov 24 1996 (18) Worked on BOP - BOP stack. Tested BOP stack. Rigged up Drillstring handling equipment. Held safety meeting. Rigged up Drillstring handling equipment. Singled in drill pipe to 270 ft. Made up BHA no. 10. Singled in drill pipe to 3800 ft. Held safety meeting. Singled in drill pipe to 9000 ft. Nov 25 1996 (19) Singled in drill pipe to 9842 ft. Washed to 9877 ft. Drilled installed equipment - Landing collar. Drilled to 9990 ft. Held safety meeting. Circulated at 9990 ft. Serviced Mud shakers. Drilled to 10009 ft. Pulled out of hole to 2500 ft. Held safety meeting. Pulled out of hole to 131 ft, Pulled BHA. Nov 26 1996 (20) Made up BHA no. 11 . R.I.H. to 3300 ft. Pulled out of hole to 114 ft. Pulled BHA. Held safety meeting. Made up BHA no. 11 . R.I.H. to 3300 ft. Pulled out of hole to 114 ft. Pulled BHA. Made up BHA no. 11. R.I.H. to 3300 ft. Serviced Block line. R.I.H. to 6000 ft. Held safety meeting. R.I.H. to 10009 ft. Drilled to 10120 ft. Nov 27 1996 (21) Drilled to 10190 ft. Held safety meeting. Drilled to 10418 ft. Held safety meeting. Drilled to 10470 ft. Page 3 Operations Summary for: 0,_ ,~7 13. ft. Nov 28 1996 (22) Drilled to 10482 ft. Circulated at 10482 ft. Pulled out of hole to 9968 ft. R.I.H. to 10482 ft. Drilled to 10764 ft. Circulated at 10764 ft. Pulled out of hole to 9500 ft. Nov 29 1996 (23) Pulled out of hole to 150 ft. Pulled BHA. Retrieved Bore protector. Installed Bore protector. Made up BHA no. 12. R.I.H. to 10583 ft. Reamed to 10626 ft. Pulled out of hole to 9968 ft. R.I.H. to 10250 ft. Drilled to 10260 ft. Nov 30 1996 (24) Drilled to 10260 ft. Singled in drill pipe to 10519 ft. Reamed to 10764 ft. Drilled to 10782 ft. Circulated at 10782 ft. Pulled out of hole to 150 ft. Pulled BHA. Dec I 1996 (25) Pulled BHA. Retrieved Bore protector. Installed BOP test plug assembly. Tested All functions. Repaired Annular preventor. Tested Annular preventor. Made up BHA no. Tested Kelly cocks. R.I.H. to 10739 ft. Reamed to 10782 ft. Drilled to 10891 Dec 2 1996 (26) Drilled to 10907 ft. Circulated at 10907 ft. Pulled out of hole to 100 ft. Made up BHA no. 14. R.I.H. to 10907 ft. Drilled to 11105 ft. Dec 3 1996 (27) Drilled to 11223 ft. Circulated at 11223 ft. Pulled out of hole to 100 ft. Made up BHA no. 15. R.I.H. to 11223 ft. Drilled to 11415 ft. Dec 4 1996 (28) Pulled BHA. Pulled BHA. Drilled to 11617 ft. Circulated at 11617 ft. Pulled out of hole to 9968 ft. Serviced Block line. R.I.H. to 11617 ft. Circulated at 11617 ft. Pulled out of hole to 106 ft. Pulled BHA. Rigged up Casing handling equipment. Ran Casing to 300 ft (2.875 in OD). Dec 5 1996 (29) Ran Casing to 11617 ft (2.875 in OD). Set Tie back packer at 9947 ft with 3200 psi. Rigged down sub-surface equipment - Setting tools. Circulated at 9947 ft. Retrieved Drillpipe landing string. Page 4 Operations Summary for: 6..~7 Dec 6 1996 (30) Retrieved Drillpipe landing string. Ran electric logs. Worked on BOP - Variable ram. Tested Variable ram. Laid out 3.5 in drill pipe from derrick. Retrieved Bore protector. Rigged up Tubing handling equipment. Ran Tubing to 3410 ft (4.5 in OD). Dec 7 1996 (31) Ran Tubing to 3410 ft (4.5 in OD). Tested Completion equipment. Set packer at 3376 ft with 4000 psi. Tested Tubing. Tested Completion equipment - Via annulus. Rigged down BOP stack. Installed Adapter spool. Installed Xmas tree. Tested Permanent packer. Circulated at 3350 ft. Installed Hanger plug. Page 5 SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -61.10 128.25 128.25 67.15 187.70 187.69 126.59 215.64 215.62 154.52 247.30 247.28 186.18 277.30 277.28 216.18 305.30 305.27 244.17 336.79 336.76 275.66 366.50 366.47 305.37 397.45 397.42 336.32 ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA COURS INCLN DG MN 0 0 0 36 1 12 0 48 1 0 0 43 0 34 0 36 0 21 0 9 428.30 428.27 367.17 0 1 457.61 457.58 396.48 0 30 487.46 487.43 426.33 0 58 518.33 518.29 457.19 1 30 548.81 548.75 487.65 2 12 578.83 578.74 517.64 2 609.47 609.33 548.23 3 639.66 639.42 578.32 4 670.07 669.70 608.60 5 700.46 699.91 638.81 6 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA INC PAGE 61.10 FT. COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N .00 E .00 .00N .00E N 78.00 E .47 .14N .66E N 78.00 E 1.01 .33N 1.57E N 86.20 E 1.52 .41N 2.05E S 85.10 E .76 .40N 2.55E S 84.80 E .93 .36N 3.00E N 72.60 E 1.05 .38N 3.30E N 89.50 E .55 .43N 3.62E N 40.00 E 1.54 .51N 3.83E N 71.90 E .77 .59N 3.94E S .30 E .55 .60N 3.98E S 88.50 W 1.71 .59N 3.85E N 83.10 W 1.64 .62N 3.47E N 81.10 W 1.69 .71N 2.81E N 79.10 W 2.31 .88N 1.84E 59 N 77.10 W 2.65 1.17N .51E 55 N 75.50 W 3.05 1.61N 1.29W 56 N 75.10 W 3.38 2.20N 3.54W 55 N 74.70 W 3.22 2.95N 6.32W 21 N 74.30 W 1.45 3.82N 9.45W 730.13 729.39 668.29 6 40 759.52 758.58 697.48 6 47 790.07 788.92 727.82 6 37 818.55 817.21 756.11 6 26 851.20 849.66 788.56 6 19 N 73.90 W 1.06 4.74N 12.69W N 73.70 W .42 5.70N 16.00W N 74.30 W .58 6.69N 19.43W N 74.90 W .68 7.55N 22.55W N 75.50 W .42 8.48N 26.07W 880.66 878.95 817.85 911.36 909.49 848.39 939.08 937.06 875.96 969.16 966.98 905.88 1001.24 998.89 937.79 N 76.10 W 1.01 9.26N 29.14W N 76.70 W .93 10.00N 32.21W N 73.30 W 1.57 10.74N 34.96W N 69.90 W 1.26 11.72N 37.91W N 66.80 W 1.00 12.92N 40.96W N 66.40 W .33 14.14N 43.76W N 67.00 W .54 15.42N 46.75W N 66.90 W .81 16.57N 49.44W N 66.80 W 1.80 17.72N 52.14W N 66.30 W 1.26 18.77N 54.55W 6 2 5 45 6 1 5 52 5 49 1031.12 1028.61 967.51 5 55 1063.05 1060.38 999.28 5 45 1092.80 1089.98 1028.88 5 31 1125.02 1122.07 1060.97 4 56 1156.88 1153.82 1092.72 4 32 VERT. SECT. .00 -.07 -.17 -.25 - .42 -.60 - .67 -.72 -.72 - .67 - .67 -.65 -.50 -.20 .26 .95 1.93 3.20 4.78 6.58 8.47 10.42 12.42 14.22 16.20 17.90 19.57 21.13 22.99 25.08 27.11 29.27 31.20 33.14 34.89 SPi .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 1188.88 1185.73 1124.63 1222.60 1219.35 1158.25 1254.34 1250.99 1189.89 1289.38 1285.94 1224.84 1319.12 1315.61 1254.51 16 28 24 55 45 N 63.20 W 1.10 19.82N 56.78W N 62.00 W .65 21.00N 59.06W N 60.80 W .37 22.18N 61.22W N 55.70 W 1.75 23.51N 63.39W N 55.40 W .58 24.64N 65.03W 36.58 38.42 40.21 42.15 43.74 1353.36 1349.78 1288.68 3 37 1385.20 1381.55 1320.45 3 50 1417.25 1413.53 1352.43 3 52 1448.30 1444.50 1383.40 4 17 1480.13 1476.23 1415.13 4 43 N 53.10 W .57 25.92N 66.82W N 55.20 W .81 27.14N 68.49W N 57.40 W .48 28.33N 70.29W N 57.60 W 1.32 29.52N 72.16W N 58.10 W 1.39 30.85N 74.27W 45.51 47.19 48.89 50.60 52.53 1512.17 1508.15 1447.05 5 20 1544 . 14 1539 . 99 1478 . 89 5 7 1576 . 28 1572 . 00 1510 . 90 5 3 1607.30 1602.89 1541.79 5 10 1639.37 1634,84 1573.74 4 46 N 52.50 W 2.47 32.46N 76.58W N 53.00 W .73 34.23N 78.90W N 54.20 W .38 35.92N 81.20W N 57.60 W 1.05 37.47N 83.49W N 59.70 W 1.37 38.92N 85.87W 54.78 57.18 59.50 61.69 63.81 1671.32 1666.70 1605.60 4 1703.31 1698.60 1637.50 4 1734.50 1729.72 1668.62 3 1762.82 1757,98 1696.88 3 1798.57 1793.67 1732.57 3 8 7 50 32 2 N 69.40 W 3.09 39.99N 88.09W N 66.00 W .77 40.87N 90.23W N 67.60 W .94 41.72N 92.22W N 71.50 W 1.41 42.36N 93.92W N 75.20 W 1.49 42.96N 95.89W 65.53 67.03 68.46 69.61 70.78 1830.49 1825.55 1764.45 2 29 1862.49 1857..52 1796.42 2 25 1894.64 1889.64 1828.54 2 22 1926.56 1921.54 1860.44 2 13 1953.88 1948.84 1887.74 1 52 N 79.90 W 1.89 43.29N 97.39W N 84.50 W .65 43.48N 98.75W N 84.20 W .19 43.61N 100.09W S 87.20 W 1.17 43.65N 101.37W S 82.50 W 1.45 43.57N 102.34W 71.58 72.18 72.72 73.16 73.38 2083.20 2078.06 2016.96 2 36 2177.37 2172.16 2111.06 1 49 2273.14 2267.88 2206.78 1 36 2368.83 2363.54 2302.44 1 17 2402.20 2396.90 2335.80 1 27 S 86.30 W .58 43.10N 107.37W S 81.10 W .86 42.73N 110.99W S 81.90 W .23 42.31N 113.82W S 82.60 W .32 41.98N 116.21W S 84.10 W .52 41.89N l17.00W 74.51 75.29 75.77 76.21 76.37 2433.54 2428.24 2367.14 2465.13 2459.82 2398.72 2497.21 2491.89 2430.79 2527.87 2522.51 2461.41 2559.97 2554.51 2493.41 1 5 0 55 2 9 3 39 4 56 S 85.90 W 1.19 41.83N 117.70W N 18.20 W 3.94 42.05N 118.08W N 24.30 E 4.98 42.84N 117.91W N 35.50 E 5.24 44.16N l17.10W N 41.50 E 4.22 46.03N 115.59W 76.53 76.86 77.56 78.56 79.86 SP~ .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2591.98 2586.37 2525.27 6 11 2625.40 2619.58 2558.48 6 42 2656.92 2650.88 2589.78 6 42 2688.71 2682.45 2621.35 6 55 2722.54 2716.01 2654.91 7 26 N 42.90 E 3.96 48.33N 113.50W N 43.80 E 1.56 51.06N 110.92W N 45.30 E .55 53.68N 108.34W N 40.60 E 1.87 56.44N 105.77W N 30.50 E 4.03 59.88N 103.34W 81.39 83.18 84.87 86.69 89.19 2752.66 2745.86 2684.76 7 49 2784.88 2777.76 2716.66 8 22 2816.92 2809.42 2748.32 9 13 2848.46 2840.54 2779.44 9 37 2880.68 2872.28 2811.18 10 4 N 26.80 E 2.08 63.39N 101.42W N 27.40 E 1.73 67.43N 99.35W N 28.90 E 2.75 71.76N 97.04W N 30.90 E 1.61 76.23N 94.46W N 31.30 E 1.44 80.95N 91.61W 91.92 95.12 98.50 101.94 105.54 2912.62 2903.72 2842.62 10 15 2944.65 2935.22 2874.12 10 39 2976.58 2966.57 2905.47 11 14 3008.52 2997.87 2936.77 11 44 3040.44 3029.09 2967.99 12 11 N 30.40 E .75 85.79N 88.72W N 31.30 E 1.35 90.78N 85.74W N 32.60 E 1.97 95.93N 82.53W N 31.80 E 1.64 101.31N 79.14W N 33.00 E 1.64 106.90N 75.59W 109.23 113.04 116.92 120.98 125.18 3072.45 3060.35 2999.25 3104.44 3091.50 3030.40 3136.70 3122.80 3061.70 3168.85 3153.89 3092.79 3201.09 3184.93 3123.83 12 13 14 15 16 43 33 24 10 4 N 33.20 E 1.63 112.69N 71.82W N 32.50 E 2.67 118.80N 67.87W N 31.90 E 2.67 125.39N 63.72W N 30.80 E 2.55 132.41N 59.45W N 29.50 E 3.00 139.92N 55.09W 129.49 134.06 139.03 144.36 150.13 3232.88 3215.42 3154.32 16 3256.23 3237.71 3176.61 17 3298.01 3277.36 3216.26 18 3330.06 3307.59 3246.49 19 3361.76 3337.29 3276.19 20 49 5O 51 57 57 N 29.70 E 2.34 147.74N 50.65W N 29.80 E 4.37 153.78N 47.19W N 31.60 E 2.79 165.09N 40.47W N 32.30 E 3.48 174.12N 34.84W N 32.00 E 3.17 183.50N 28.95W 156.17 160.83 169.47 176.29 183.35 3393.82 3367.14 3306.04 3424.76 3395.78 3334.68 3456.56 3425.07 3363.97 3488.60 3454.43 3393.33 3520.39 3483.38 3422.28 21 50 22 37 23 13 23 57 24 51 N 30.40 E 3.32 193.50N 22.89W N 31.00 E 2.66 203.57N 16.91W N 30.20 E 2.10 214.23N 10.61W N 29.90 E 2.31 225.33N 4.19W N 30.10 E 2.87 236.70N 2.38E 190.96 198.65 206.81 215.34 224.09 3637.87 3589.29 3528.19 26 24 3670.33 3618.26 3557.16 27 8 3702.66 3646.93 3585.83 27 57 3733.56 3674.10 3613.00 28 53 3765.09 3701.60 3640.50 29 42 N 29.90 E 1.32 280.72N 27.79E N 28.90 E 2.67 293.46N 34.96E N 28.20 E 2.70 306.60N 42.11E N 27.70 E 3.11 319.59N 49.00E N 28.70 E 3.00 333.18N 56.30E 257.95 267.81 278.06 288.24 298.88 SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3862.20 3785.90 3724.80 3957.10 3868.26 3807.16 4052.30 3950.85 3889.75 4145.18 4031.35 3970.25 4242.12 4115.29 4054.19 29 49 29 45 29 53 29 57 30 4 N 28.20 E .29 375.57N 79.26E N 27.70 E .27 417.22N 101.36E N 27.00 E .39 459.27N 123.11E N 27.50 E .28 500.45N 144.32E N 29.60 E 1.09 543.04N 167.49E 331.96 364.61 397.75 430.24 463.44 4337.18 4197.43 4136.33 4434.30 4281.24 4220.14 4528.46 4362.63 4301.53 4622.81 4444.25 4383.15 4718.07 4526.61 4465.51 30 22 30 19 3O 4 3O 7 30 12 N 30.00 E .37 584.57N 191.28E N 29.80 E .12 627.10N 215.73E N 29.80 E .27 668.19N 239.27E N 29.60 E .12 709.30N 262.71E N 29.40 E .13 750.96N 286.28E 495.45 528.21 559.88 591.59 623.80 4815.06 4610.66 4549.56 4909.80 4693.30 4632.20 5004.57 4776.23 4715.13 5100.29 4859.56 4798.46 5164.99 4915.76 4854.66 29 28 29 29 29 4O 51 1 55 28 N 30.40 E .74 792.92N 310.41E N 30.60 E .87 832.83N 333.92E N 31.00 E .27 872.23N 357.40E N 31.60 E .98 912.47N 381.87E N 31.60 E .68 939.77N 398.67E 656.11 686.67 716.75 747.32 768.00 5259.48 4998.09 4936.99 5356.45 5082.57 5021.47 5450.88 5164.29 5103.19 5548.34 5247.74 5186.64 5643.85 5329.56 5268.46 29 29 30 31 30 18 28 38 33 32 N 32.50 E .50 979.08N 423.28E N 32.20 E .23 1019.29N 448.75E N 30.30 E 1.60 1059.73N 473.27E N 29.20 E 1.10 1103.44N 498.25E N 30.60 E 1.31 1146.15N 522.80E 797.65 827.88 858.62 892.33 925.22 5740.16 5411.78 5350.68 5834.83 5492.08 5430.98 5930.07 5573.32 5512.22 6024.86 5654.28 5593.18 6121.72 5736.38 5675.28 32 12 31 45 31 9 31 31 32 34 N 31.90 E 1.87 1189.00N 548.82E N 35.00 E 1.80 1230.83N 576.44E N 30.80 E 2.38 1272.52N 603.43E N 29.40 E .86 1315.17N 628.15E N 28.80 E 1.14 1360.08N 653.14E 957.79 988.88 1020.05 1052.83 1087.68 6217.58 5817.12 5756.02 6312.73 5896.17 5835.07 6408.77 5975.03 5913.93 6501.87 6052.34 5991.24 6597.18 6132.65 6071.55 32 38 34 58 34 36 33 5 32 3 N 28.40 E .23 1405.44N 677.87E N 27.40 E 2.53 1452.22N 702.62E N 25.00 E 1.48 1501.38N 726.82E N 25.10 E 1.62 1548.37N 748.78E N 23.10 E 1.57 1595.20N 769.74E 1123.03 1159.73 1198.86 1236.62 1274.55 6693.84 6215.15 6154.04 6788.96 6296.86 6235.76 6885.34 6379.34 6318.24 6980.83 6461.09 6399.99 7074.81 6541.96 6480.86 3O 45 30 49 31 27 30 46 30 28 N 27.20 E 2.59 1640.78N 791.10E N 27.00 E .14 1684.12N 813.28E N 24.70 E 1.40 1728.98N 835.00E N 28.30 E 2.07 1773.13N 857.00E N 26.80 E .88 1815.57N 879.14E 1311.16 1345.40 1381.21 1416.27 1449.66 f-SUN DRILLING SERVICES ANCHO~GE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2 / 7/97 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7169.42 6623.93 6562.83 7263.45 6706.12 6645.02 7357.63 6788.86 6727.76 7451.89 6872.05 6810.95 7546.33 6955.90 6894.80 29 26 28 40 28 22 27 43 27 3 N 28.90 E 1.55 1857.34N 901.20E 1482.44 N 27.90 E .96 1897.51N 922.92E 1513.81 N 27.70 E .33 1937.30N 943.90E 1545.04 N 26.10 E 1.06 1976.82N 963.96E 1576.31 N 23.70 E 1.36 2016.21N 982.26E 1608.01 7643.41 7042.34 6981.24 7739.00 7127.66 7066.56 7833.15 7211.42 7150.32 7927.62 7294.54 7233.44 8024.67 7380.00 7318.90 27 5 26 31 27 46 28 57 27 36 N 27.30 E 1.69 2056.08N 1001.27E 1639.93 N 26.40 E .72 2094.54N 1020.75E 1670.37 N 28.00 E 1.54 2132.75N 1040.40E 1700.52 N 30.10 E 1.64 2171.97N 1062.20E 1730.96 N 29.40 E 1.44 2211.88N 1085.02E 1761.74 8119.91 7464.00 7402.90 8215.26 7548.16 7487.06 8308.41 7631.21 7570.10 8347.95 7666.84 7605.74 8378.32 7694.39 7633.29 28 27 26 24 24 38 24 26 53 51 N 28.30 E 1.23 2251.21N 1106.68E 1792.32 N 27.40 E 1.37 2290.82N 1127.61E 1823.40 N 29.70 E 1.53 2327.87N 1147.75E 1852.29 N 29.90 E 3.90 2342.73N 1156.27E 1863.75 N 30.20 E .45 2353.79N 1162.66E 1872.25 8444.54 7753.85 7692.75 8473.67 7779.63 7718.53 8506.39 7808.36 7747.26 8538.27 7835.96 7774.86 8600.78 7889.46 7828.36 27 21 28 8 29 4 30 56 31 21 N 28.80 E 3.90 2379.15N 1176.99E 1891.86 N 29.40 E 2.84 2391.00N 1183.59E 1901.06 N 30.30 E 3.13 2404.59N 1191.39E 1911.52 N 30.60 E 5.88 2418.33N 1199.47E 1922.05 N 32.10 E 1.40 2445.94N 1216.29E 1943.01 8664.49 7944.22 7883.12 8726.76 7998.11 7937.01 8790.80 8053.76 7992.66 8822.74 8081.71 8020.61 8855.48 8110.34 8049.24 3O 3O 29 28 29 6 2 16 37 22 N 33.60 E 2.30 2473.28N 1233.94E 1963.47 N 33.80 E .19 2499.24N 1251.25E 1982.71 N 35.10 E 1.55 2525.37N 1269.17E 2001.93 N 35.70 E 2.26 2537.97N 1278.13E 2011.10 N 36.10 E 2.40 2550.83N 1287.43E 2020.40 8887.33 8137.92 8076.82 8919.24 8165.36 8104.26 8951.40 8192.94 8131.84 8983.45 8220.37 8159.27 9012.96 8245.62 8184.52 30 38 30 46 31 8 31 7 31 14 N 35.20 E 4.20 2563.78N 1296.72E 2029.80 N 36.00 E 1.34 2577.02N 1306.20E 2039.41 N 36.10 E 1.16 2590.40N 1315.94E 2049.07 N 37.00 E 1.45 2603.71N 1325.80E 2058.63 N 35.00 E 3.53 2616.07N 1334.78E 2067.57 9043.79 8271.93 8210.83 9075.84 8299.14 8238.04 9108.02 8326.38 8265.28 9139.78 8353.31 8292.21 9170.65 8379.54 8318.44 31 31 32 15 32 8 31 51 31 46 N 33.70 E 2.39 2629.33N 1343.84E 2077.33 N 30.20 E 6.20 2643.69N 1352.79E 2088.17 N 26.70 E 5.81 2658.76N 1360.96E 2099.93 N 27.90 E 2.19 2673.72N 1368.68E 2111.72 N 26.00 E 3.26 2688.22N 1376.05E 2123.20 SP~ Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SH3LRED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 MWD SURVEY JOB NI/MBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9202.41 8406.54 8345.44 9233.44 8432.94 8371.84 9265.40 8460.17 8399.07 9329.58 8514.83 8453.73 9393.59 8569.31 8508.21 31 47 31 34 31 34 31 37 31 42 N 26.00 E .00 2703.26N 1383.39E N 25.80 E .81 2717.92N 1390.51E N 26.10 E .50 2732.97N 1397.83E N 26.00 E .12 2763.19N 1412.60E N 26.10 E .13 2793.38N 1427.36E 2135.19 2146.89 2158.89 2182.98 2207.04 9423.62 8594.88 8533.79 9469.49 8634.03 8572.93 9501.80 8661.34 8600.25 9532.83 8686.68 8625.58 9564.73 8711.36 8650.26 31 31 N 25.80 E .80 2807.53N 1434.25E 31 19 N 25.60 E .49 2829.07N 1444.62E 33 16 N 20.60 E 10.23 2844.95N 1451.36E 37 15 N 15.40 E 16.06 2861.98N 1456.86E 41 24 N 10.70 E 16.01 2881.67N 1461.38E 2218.33 2235.55 2248.52 2262.98 2280.26 9596.71 8734.49 8673.39 9628.14 8755.35 8694.25 9659.39 8774.09 8712.99 9692.19 8791.63 8730.53 9723.88 8806.32 8745.22 45 5O 55 59 64 57 49 27 53 51 N 7.10 E 16.21 2903.48N 1464.77E N 5.20 E 16.17 2926.83N 1467.27E N 3.50 E 15.44 2951.76N 1469.15E N 1.40 E 14.55 2979.44N 1470.33E N .60 E 15.84 3007.50N 1470.81E 2299.92 2321.32 2344.41 2370.34 2396.84 9755.77 8818.56 8757.46 9787.40 8828.42 8767.32 9819.38 8836.46 8775.36 9851.01 8842.81 8781.71 9882.74 8848.36 8787.26 69 73 77 79 8O 58 N .80 W 16.56 3036.94N 1470.75E 40 N 4.10 W 15.33 3066.95N 1469.46E 12 N 7.80 W 15.72 3097.73N 1466.24E 38 N 10.60 W 11.59 3128.31N 1461.29E 11 N 11.30 W 2.80 3158.98N 1455.35E 2424.82 2453.73 2483.97 2514.57 2545.56 9913.44 8852.62 8791.52 9929.72 8854.01 8792.91 9977.90 8855.05 8793.95 10009.50 8854.31 8793.21 10041.38 8853.00 8791.90 83 86 91 91 93 51 19 11 30 11 N 11.70 W 11.99 3188.77N 1449.29E N 11.80 W 15.12 3204.65N 1445.99E N 12.00 W 10.14 3251.77N 1436.06E N 13.70 W 5.46 3282.56N 1429.04E N 16.60 W 10.54 3313.30N 1420.71E 2575.75 2591.86 2639.72 2671.17 2702.97 10073.26 8851.14 8790.04 10105.24 8849.22 8788.12 10136.15 8847.50 8786.40 10167.84 8846.09 8784.99 10206.60 8844.88 8783.78 93 30 93 23 92 58 92 6 91 28 N 12.40 W 13.19 3344.11N 1412.75E N 12.70 W 1.00 3375.27N 1405.81E N 13.40 W 2.62 3405.33N 1398.84E N 13.00 W 3.02 3436.15N 1391.61E N 17.10 W 10.70 3473.56N 1381.55E 2734.73 2766.49 2797.23 2828.76 2867.44 10230.74 8844.23 8783.13 10262.25 8843.64 8782.54 10289.53 8843.74 8782.64 10319.32 8844.26 8783.16 10350.96 8844.65 8783.55 91 35 90 33 89 0 88 58 89 37 N 16.50 W 2.53 3496.66N 1374.58E N 17.10 W 3.84 3526.82N 1365.47E N 15.40 W 8.41 3553.00N 1357.84E N 18.30 W 9.73 3581.50N 1349.21E N 18.30 W 2.02 3611.54N 1339.28E 2891.56 2923.05 2950.31 2980.09 3011.72 SP~ Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2 / 7 / 97 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10382.07 8844.96 8783.86 10412.11 8845.46 8784.36 10443.07 8845.94 8784.84 10476.82 8846.06 8784.96 10508.44 8845.79 8784.69 89 13 N 18.50 W 1.41 3641.06N 1329.46E 88 53 N 18.90 W 1.75 3669.51N 1319.83E 89 19 N 19.90 W 3.52 3698.71N 1309.54E 90 16 N 19.10 W 3.70 3730.52N 1298.28E 90 40 N 18.40 W 2.55 3760.46N 1288.12E 3042.83 3072.87 3103.81 3137.55 3169.17 10540.08 8845.52 8784.42 10571.43 8845.39 8784.29 10602.70 8845.09 8783.99 10633.48 8844.70 8783.60 10665.50 8844.10 8783.00 90 18 N 19.80 W 4.58 3790.35N 1277.76E 90 10 N 19.50 W 1.04 3819.88N 1267.22E 90 53 N 18.50 W 3.92 3849.44N 1257.04E 90 34 N 18.20 W 1.40 3878.65N 1247.35E 91 34 N 17.80 W 3.33 3909.10N 1237.46E 3200.80 3232.14 3263.41 3294.18 3326.20 10696.61 8843.21 8782.11 10729.27 8842.29 8781.19 10741.67 8841.94 8780.84 10774.04 8840.66 8779.56 10805.19 8838.84 8777.74 91 43 N 16.80 W 3.25 3938.79N 1228.21E 91 28 N 18.20 W 4.35 3969.92N 1218.40E 91 48 N 16.10 W 17.14 3981.76N 1214.74E 92 42 N 17.10 W 4.15 4012.76N 1205.50E 93 59 N 15.70 W 6.08 4042.59N 1196.72E 3357.29 3389.93 3402.32 3434.65 3465.73 10836.13 8836.68 8775.58 10869.67 8834.28 8773.18 10899.82 8832.11 8771.01 10931.46 8830.57 8769.47 10962.72 8829.55 8768.45 94 1 N 17.00 W 4.19 4072.20N 1188.04E 94 10 N 17.10 W .51 4104.18N 1178.23E 94 3 N 18.00 W 3.00 4132.86N 1169.16E 91 32 N 16.80 W 8.82 4163.01N 1159.71E 92 12 N 15.20 W 5.55 4193.04N ll51.10E 3496.57 3530.02 3560.09 3591.69 3622.90 10994.13 8828.16 8767.06 11025.63 8826.86 8765.76 11057.74 8825.96 8764.86 11089.25 8825.58 8764.48 11120.78 8825.73 8764.63 92 50 N 16.30 W 4.03 4223.24N 1142.58E 91 54 N 16.80 W 3.35 4253.41N 1133.62E 91 17 N 16.80 W 1.93 4284.13N 1124.34E 90 5 N 20.10 W 11.14 4314.02N 1114.37E 89 21 N 20.60 W 2.81 4343.58N 1103.41E 3654.25 3685.71 3717.80 3749.30 3780.81 11152.21 8825.99 8764.89 11183.96 8825.78 8764.68 11214.52 8824.84 8763.74 11246.24 8823.44 8762.34 11277.71 8821.98 8760.88 89 41 N 20.20 W 1.65 4373.03N 1092.45E 91 4 N 21.90 W 6.92 4402.66N 1081.05E 92 25 N 19.50 W 9.01 4431.23N 1070.25E 92 39 N 19.70 W .94 4461.08N 1059.62E 92 40 N 19.30 W 1.27 4490.72N 1049.13E 3812.21 3843.92 3874.43 3906.11 3937.54 11309.12 8820.43 8759.33 11340.81 8818.79 8757.69 11372.69 8817.12 8756.02 11404.82 8815.39 8754.29 11436.76 8813.66 8752.56 92 57 N 19.80 W 1.82 4520.28N 1038.63E 92 59 N 19.40 W 1.26 4550.09N 1028.02E 92 59 N 19.90 W 1.57 4580.07N 1017.31E 93 11 N 20.90 W 3.18 4610.14N 1006.13E 92 59 N 20.20 W 2.29 4640.01N 994.93E 3968.90 4000.54 4032.36 4064.42 4096.29 SP1 Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 MWD SURVEY JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11467.84 8812.14 8751.04 92 37 N 20.10 W 1.23 4669.15N 984.24E 11499.35 8810.75 8749.65 92 27 N 20.70 W 1.97 4698.65N 973.27E 11530.99 8809.36 8748.26 92 33 N 20.60 W .42 4728.23N 962.12E 11562.14 8808.04 8746.94 92 18 N 21.40 W 2.68 4757.29N 950.97E 11617.00 8806.04 8744.94 91 52 N 22.81 W 2.69 4808.08N 930.34E 4127.31 4158.77 4190.35 4221.44 4276.13 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4897.26 FEET AT NORTH 10 DEG. 57 MIN. EAST AT MD = 11617 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 341.78 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 11,617.00' MD SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -61.10 .00 N .00 E .0 1000.00 997.66 936.56 12.87 N 40.84 W 2.3 2000.00 1994.94 1933.84 43.37 N 103.84 W 5.0 3000.00 2989.52 2928.42 99.84 N 80.05 W 10.4 4000.00 3905.50 3844.40 436.07 N 111.26 E 94.5 2.34 2.72 5.41 84.02 5000.00 4772.24 4711.14 870.33 N 356.26 E 227.7 6000.00 5633.09 5571.99 1303.85 N 621.77 E 366.9 7000.00 6477.56 6416.46 1781.77 N 861.65 E 522.4 8000.00 7358.14 7297.04 2201.93 N 1079.41 E 641.8 9000.00 8234.54 8173.44 2610.57 N 1330.93 E 765.4 133.26 139.15 155.53 119.42 123.61 10000.00 8854.56 8793.46 3273.33 N 1431.28 E 1145.4 11000.00 8827.87 87-66.77 4228.87 N 1140.94 E 2172.1 11617.00 8806.04 8744.94 4808.08 N 930.34 E 2810.9 379.98 1026.69 638.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -61.10 61.10 61.10 .00 161.11 161.10 100.00 261.12 261.10 200.00 361.13 361.10 300.00 .00 N .00 E .00 N .01 E .22 N 1.03 E .38 N 2.78 E .48 N 3.81 E .00 .00 .00 .01 .01 .02 .02 .03 .01 461.13 461.10 400.00 561.17 561.10 500.00 661.43 661.10 600.00 762.06 761.10 700.00 862.71 861.10 800.00 .59 N 3.82 E .98 N 1.36 E 2.71 N 5.46 W 5.79 N 16.28 W 8.79 N 27.29 W .03 .00 .07 .04 .33 .26 .96 .63 1.61 .65 963.25 961.10 900.00 1063.78 1061.10 1000.00 1164.18 1161.10 1100.00 1264.48 1261.10 1200.00 1364.70 1361.10 1300.00 11.51 N 37.35 W 15.45 N 46.81 W 19.01 N 55.07 W 22.56 N 61.88 W 26.35 N 67.40 W 2.15 .54 2.68 .52 3.08 .41 3 .38 .29 3.60 .22 1464.95 1461.10 1400.00 1565.34 1561.10 1500.00 1665.71 1661.10 1600.00 1765.95 1761.10 1700.00 1866.07 1861.10 1800.00 30.20 N 73.23 W 35.35 N 80.41 W 39.85 N 87.71 W 42.42 N 94.11 W 43.50 N 98.90 W 3.85 .25 4.24 .39 4.61 .37 4.85 .24 4.97 .12 1966.15 1961.10 1900.00 2066.22 2061.10 2000.00 2166.31 2161.10 2100.00 2266.35 2261.10 2200.00 2366.39 2361.10 2300.00 43.51 N 102.74 W 43.15 N 106.60 W 42.79 N 110.64 W 42.33 N 113.63 W 41.99 N 116.15 W 5.05 .07 5.12 .08 5.21 .08 5.25 .05 5.29 .03 2466.41 2461.10 2400.00 2566.58 2561.10 2500.00 2667.21 2661.10 2600.00 2768.05 2761.10 2700.00 2869.33 2861.10 2800.00 42.06 N 118.08 W 46.48 N 115.19 W 54.55 N 107.50 W 65.30 N 100.45 W 79.27 N 92.63 W 5.31 .02 5.48 .17 6.11 .63 6.95 .84 8.23 1.28 2971.01 2961.10 2900.00 3073.22 3061.10 3000.00 3176.33 3161.10 3100.00 3280.82 3261.10 3200.00 3387.31 3361.10 3300.00 95.02 N 83.11 W 112.83 N 71.73 W 134.09 N 58.45 W 160.36 N 43.39 W 191.41 N 24.12 W 9.91 1.68 12.12 2.21 15.23 3.10 19.72 4.50 26.21 6.49 SP. _Y-SUN DRILLING SERVICES ANCHOR3kGE ALASKA PAGE 11 SHARED SERVICES DRILLING PBU/2-37 500292271700 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3495.90 3461.10 3400.00 3606.40 3561.10 3500.00 3718.72 3661.10 3600.00 3833.62 3761.10 3700.00 3948.86 3861.10 3800.00 227.90 N 2.71 268.58 N 20.81 313.26 N 45.67 363.04 N 72.54 413.60 N 99.46 34.80 8.59 45.30 10.50 57.62 12.32 72.52 14.90 87.76 15.24 4064.12 3961.10 3900.00 4179.51 4061.10 4000.00 4295.08 4161.10 4100.00 4410.97 4261.10 4200.00 4526.70 4361.10 4300.00 464.52 N 125.78 515.66 N 152.24 566.14 N 180.65 616.88 N 209.88 667.43 N 238.83 103.02 15.26 118.41 15.39 133.98 15.57 149.87 15.88 165.60 15.73 4642.29 4461.10 4400.00 4757.97 4561.10 4500.00 4873.03 4661.10 4600.00 4987.26 4761.10 4700.00 5102.07 4861.10 4800.00 717.80 N 267.54 768.44 N 296.14 817.54 N 324.88 865.03 N 353.08 913.22 N 382.34 E E E E E 181.19 15.59 196.87 15.68 211.93 15.05 226.16 14.24 240.97 14.80 5217.06 4961.10 4900.00 5331.79 5061.10 5000.00 5447.17 5161.10 5100.00 5564.02 5261.10 5200.00 5680.48 5361.10 5300.00 961.56 N 412.13 1009.02 N 442.28 1058.10 N 472.32 1110.61 N 502.25 1162.17 N 532.27 255.96 14.99 270.69 14.72 286.07 15.38 302.92 16.85 319.38 16.45 5798.40 5461.10 5400.00 5915.79 5561.10 5500.00 6032.86 5661.10 5600.00 6151.06 5761.10 5700.00 6270.00 5861.10 5800.00 1215.11 N 565.45 1266.17 N 599.64 1318.81 N 630.20 1373.93 N 660.75 1430.57 N 691.37 337.30 17.92 354.69 17.39 371.76 17.07 389.96 18.20 408.90 18.94 6391.84 5961.10 5900.00 6512.32 6061.10 6000.00 6630.75 6161.10 6100.00 6747.32 6261.10 6200.00 6863.95 6361.10 6300.00 1492.67 N 722.76 1553.54 N 751.20 1611.59 N 776.73 1665.11 N 803.59 1718.84 N 830.34 430.74 21.84 451.22 20.48 469.65 18.42 486.22 16.57 502.85 16.63 6980.84 6461.10 6400.00 7097.01 6561.10 6500.00 7212.08 6661.10 6600.00 7326.07 6761.10 6700.00 7439.52 6861.10 6800.00 1773.13 N 857.00 1825.62 N 884.22 1875.68 N 911.30 1924.02 N 936.93 1971.65 N 961.43 519.74 16.89 535.91 16.17 550.98 15.07 564.97 13.99 578.42 13.45 SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 12 SHARED SERVICES DRILLING DBU/2-37 5oo2922717oo NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/97 DATE OF SURVEY: 120396 JOB NUMBER: AK-MW-60162 KELLY BUSHING ELEV. = 61.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 7552.17 6961.10 6900.00 2018.64 N 983.32 E 591.07 7664.48 7061.10 7000.00 2064.60 N 1005.67 E 603.38 7776.38 7161.10 7100.00 2109.49 N 1028.17 E 615.28 7889.40 7261.10 7200.00 2155.96 N 1052.93 E 628.30 8003.34 7361.10 7300.00 2203.27 N 1080.17 E 642.24 12.65 12.31 11.90 13.02 13.94 8116.61 7461.10 7400.00 2249.82 N 1105.93 E 655.51 8229.84 7561.10 7500.00 2296.78 N 1130.70 E 668.74 8341.62 7661.10 7600.00 2340.42 N 1154.94 E 680.52 8452.71 7761.10 7700.00 2382.45 N 1178.81 E 691.60 8567.60 7861.10 7800.00 2431.30 N 1207.20 E 706.50 13.27 13.23 11.78 11.08 14.89 8684.00 7961.10 7900.00 2481.43 N 1239.35 E 722.90 8799.21 8061.10 8000.00 2528.74 N 1271.54 E 738.11 8914.29 8161.10 8100.00 2574.97 N 1304.72 E 753.19 9031.09 8261.10 8200.00 2623.84 N 1340.13 E 769.99 9148.95 8361.10 8300.00 2678.01 N 1370.91 E 787.85 16.40 15.22 15.07 16.81 17.86 9266.49 8461.10 8400.00 2733.48 N 1398.08 E 805.39 9383.94 8561.10 8500.00 2788.82 N 1425.13 E 822.84 9501.53 8661.10 8600.00 2844.84 N 1451.30 E 840.43 9637.45 8761.10 8700.00 2934.13 N 1467.88 E 876.35 11617.00 8806.04 8744.94 4808.08 N 930.34 E 2810.96 17.54 17.45 17.59 35.92 1934.61 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS GeoQuest 500 W, International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10789 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, Al( 99501 2/10/97 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape D.S. 2-37 96384 PEX & BHC 961121 I -Z~ ~'~/o/~ D.S. 2-37 96384 PEX-QUALITY CONTROL LOG 961121 I 1 D.S. 2-37 96384 iPEX-COMP NEUTRON-LITHODENSITY 961121 I 1 D.S. 2-37 96384 PEX-COMPENSATED NEUTRON 961121 I 1 D.S. 2-37 96384 PEX-BHC 961121 I 1 D.S. 2-37 96384 PEX-BOREHOLE PROFILE 961121 I 1 D.S. 2-37 96384 SUBSEA TVD-SONIC-DEN-NEUTRON 9611 21 I 1 D.S. 2-39 96396 PEX & BHC 961223 I .3~--- '~ ~/'/' D.S. 2-39 96396 PEX-MCFL W/MICROLOG 961223 I 1 D.S. 2-39 96396 PEX-COMP NEUTRON-LITHODENSITY 961223 I 1 D.S. 2-39 96396 PEX-COMPENSATED NEUTRON 961 223 1 1 D.S. 2-39 96396 BHC 961 223 1 1 D.S. 2-39 96396 BOREHOLE PROFILE 961 223 1 1 D.S. 2-39 96396 PEX-SSTVD 961223 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. spenn -sur, I-II:iII_lING ~: I::: I=! ~/I r' I~ c: February 11, 1997 AOGCC Loft Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 2-37 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-37 MWD survey Tie-In point at 0'and a Projected survey at 11,617.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, ..... ,;-:.?----/ / William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM TO: David John~ Chairman THRU: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 10, 1996 Blair Wondzell, ¢~,,,,.~ P. I. Supervisor FROM: ~~ SUBJECT: Bobby Foster, Petroleum Inspector FILE NO: AEMIKJDD.doc BOPE Test- Nabors 2ES ARCO - PBU - DS 2-37 PTD # 96-0175 Prudhoe Bay Field Sunday, November 10, 1996: I traveled this date to ARCO's PBU DS 2-37 and witnessed the bope test on Nabors dg 2ES. As the attached AOGCC BOPE Test Report shows there were no failures. The crew did a very good job and was well trained on the testing procedure. The rig was clean and all equipment seemed to be in good working order. The location was clean and there was good access to all areas of the rig. I spoke with Jessie New, SSD Drilling Foreman, concerning the cement job on the surface casing and he told me that a 8.5' hole had been drilled to TD and they had run 7" casing. Jessie said they puumped 683 bbls. of lea~cement and 37 bbls. of ~'l.~_ement. ~e also said that during the displacement ~lost returns when they -tik-L=fl 30 bblsk bumping the plugj but they had good cement returns ( 30 bbls.+) to the surface. Summary: ! withessed the BOPE test on ARCO's DS 2-37 being drilled by Nabors 2ES - test time 2.5 hours - No failures. Attachment · AEMIKJDD.XLS __X UNCLASSIFIED STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: , . Drlg Contractor: NABORS Rig No. Operator: ARCO Well Name: DS2-37 Casing Size: 7" Set @ 3579' Test: Initial X Weekly Other 2ES PTD # .. , Rep.: Rig Rep.: Location: Sec. DATE: '11/10/96 96-0175 Rig Ph.# 659-4836 JESSIE NEW ROD KLEPZIG 36 T. 11N R. 14E Meridian Urn. , . Test Well Sign OK Drl. Rig OK MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Hazard Sec. YES" FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly / IBOP 1 i 500/5,000 I P Lower Kelly ! IBOP ~I 500/5,000 I P Ball Type I 500/5,000 P Inside BOP I 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 500/5,000 2 500/5,000 N/A PIF P P P P P P P MUD SYSTEM: Visual Alarm TdP Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES !-12S Gas Detector YES YES .. . CHOKE MANIFOLD: No. Valves ~4 No. Flanges ' 3~. · ,, Manual Chokes 1 Hydraulic Chokes 1 ,. ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 ~2100 Test Pressure 500/5,000 500/5,000 Functioned Functioned 3,000 P 1,600 P PIF P P P P 0 minutes 3~ sec. minutes 41 sec. YES Remote: YES Equipment will be made w{thin 0 days. Notify the Inspector and follow with'~"~'en or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 ifyour call is not returned bythe inspector within 12 hours please contact the P. i. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - OperJRig c - Database c - Tdp Rpt File c - Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W~essed By: AEMIKJDD.XLS BOBBY D. FOSTER TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 4, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stolz, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 02-37 ARCO Alaska, Inc. Permit No. 96-175 Surf Loc 4600~SL, 3579'WEL, Sec 36, T1 IN, R14E, UM Btmhole Loc 4096%ISL, 2652'WEL, Sec 25, T1 IN, R14E, UM Dear Mr Stoltz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~hyai~maRl~ER OF ~H~E MMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - ~v/o encl STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL REVISED: 11/01/96 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE - 60.3' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028308 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20/LAC 25.025) 4600' NSL, 3579' WEL, SEC. 36, T11N, R14E Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2542' NSL, 2141' WEL, SEC. 25, TllN, R14E 02-37 At total depth 9. Approximate spud date Amount $200,000.00 4096' NSL, 2652' WEL, SEC. 25, T11 N, R14E 11/06/96 12. Distance to nearest property Iine113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028307, 1184'I No Close Approach 2560 11565' MD / 8760' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 2o AAC 25.035 (e)(2)} Kick Off Depth 2500' Maximum Hole Angle 94 ° Maximum surface 3300 psig, Attotal depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 94# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 8-1/2" 7" 26# L-80 NSCC 3600' 29' 29' 3600' 3555' 950 sx CS, 180 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 6480' 3450' 3420' 9930' 8845' 2.80 sx Class 'G' 3-3/4" 2-7/8" 6.5# L-80 EUE-8rd 1783' 9780' 8695' 11565' 8820' 70 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) · true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Productionintermediate ~..:, ¥~, .¢.~ ~..~ ~.\.,f ~.¢~. ~ - Liner ~'~-' !~ Perforation depth: measured .~,~,,,.~.. 0,1 true vertical ,,.u ~,;,,-'--,,,:,.~,.~ r~ .,..b~-. ~'~.-. . 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Ddlling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/~umber: W~inton Aubert, 564-4825 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that Ce fCegoin t~~:~,~C~~~he best of my knowledge Signed DanStoltz /~//~,f ~¢,/~ ,.,,.,,., Title Senior Drilling Engineer Date /////// Commission Use Only .-- for other requirements Conditions of Approval: Samples Required [] Yes I~ No Mud Log Required [] Yes 1~ No Hydrogen Sulfide Measures J:ii[IYes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; 1~5M; [] 10M; [] 15M (;~t~lJq0? '/~/~ P!Ae0 by order of Approved By F~R DaU[~!q I~UlS!.tP Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BP EXPLORATION Post-It"' brand fax trar ~ ' "tal memo 7671 {# of pages To: Blair Wondzell AOGCC From' Winton Aubert Shared Services Drilling RECEIVED Alaska Oil & Gas Cons. commission Anchorago Date: Mon, Nov 4, 1996 Subject: DS 2-37 Micro Bore Design Per our telephone conversation of 1415 hrs., 11/4/96, please include the following design details in the DS 2-37 Micro Bore Permit to Drill: 1. X nipple profile in the 4-1/2" intermediate liner @ __.9760' MD to fa- cilitate liner pressure testing; 2, 635 sk Ci G cement for the 4-1/2" intermediate liner, bringing the TOC into the 7' surface casing. Thank you for your patience and your attention to this matter. Sincerely, Winton G. Aubert CC: D. Stoltz D. Nims ~ALASKA~ Date To: At'~: From: Subject: November 1, 1996 Alaska Oil & Gas Conservation Commission Blair Wondzeli Kathy Campoamor DS 02-37, Permit revision ehared rvices ~, rilling BP Exploration / Arco Alaska The Permit To Drill (10-401) for Drill Site #02-37 is being revised due to a correction in the surface casing setting depth. I am also submitting a new directional profile and additional information requested by the AOGCC. Thank you. Kathy Campoamor Technical Assistant Cons. BP EXPLORATION RECEIVrED Memorandum To' Blair Wondzeli From: Dan Stoltz Winton Aubert AOGCC Date: November 1, 1996 Shared Services Drilling Subject: Micro-Bore Well Design Integrity This document is an addendum to the resubmitted DS 2-37 Permit to Drill, in which the PBU micro-bore well design integrity will be discussed in relation to well DS 2-37 and to the upcoming well DS 5-38. The micro-bore design will utilize 7" or 7-5/8" surface casing set in the range of 3,500' md to 5,000' md, 4-1/2" or 5-1/2" intermediate liner, and 2-7/8" or 3-1/2" production liner. The well will be completed with 4-1/2" or 5-1/2" tubing which will tie-back the intermediate liner to surface. See the attached proposed completion schematic for well DS 2-37 for reference. The following information addresses concerns regarding the integrity of the proposed micro-bore design. CORROSION Although there is evidence of corrosion in some areas of the PBU, corrosion should not be relevant to the micro-bore wells in-PBU for the following reasons. · EXTERNAL CORROSION - The PBU EOA Casing Failure Update (Dec. 6, 1994) identified and classified failed intermediate casings to date. Of 597 wells, intermediate casing failed 72 times (12%) due to all causes. Corrosion failures occurred in only 7 (1%) wells and all of these wells utilized non- modified BTC connections. To eliminate the possibility of corrosion failure in the connections of the micro- bore design, an IBT modified connection is planned for the intermediate liner connection and a NSCC premium connection is planned for the surface casing. · INTERNAL CORROSION -Internal corrosion in the PBU is caused by a combination of high produced water volumes and carbon dioxide to form the corrosive carbonic acid. This combination is associated with waterflood area wells where deep gas lift is required. Because the micro-bore only has shallow gas lift by design, this type of well is not currently targeted for waterflood area wells. It is however, a fit for purpose design for the gravity drainage area of the PBU where water cut volumes are Iow and a corrosive environment does not exist. LONGEVITY and WELL INTEGRITY Micro-bore wells will usually target relatively small hydrocarbon accumulations in the gravity drainage area of the PBU. As a result, the well's estimated production life is approximately 10 to 15 years, as opposed to the normal PBU well life of 30 years. The following will insure the micro-bore design will provide adequate integrity over the production well's lifetime. · ZONAL ISOLATION -Currently, the PBU is achieving a 96% cement success rate for zonal isolation in the intermediate and production casings. This gives a high level of assurance that the cement sheath and premium casing connections will maintain well integrity for the duration of well life. Also, the micro-bore well design will include liner top production packers at all overlaps for pressure isolation below the tubing string and surface casing. · MONITORING and TESTING -Periodic monitoring of the well annuli will assure the integrity of the micro-bore design. Because the micro-bore is not a tubingless well design, an annulus exists to monitor and evaluate the integrity of the upper section of the well. Scheduled MIT's will evaluate well bore integrity. Routine operational procedures will include regular production rate monitoring to provide early indication of liner failure. Regularly planned casing evaluation logs to E-line depth will assure intermediate liner integrity. As summarized above, the micro-bore design will be targeting the smaller reserve accumulations of the gravity drainage area of the PBU where a corrosive environment does not exist. Given the Iow risk of corrosion coupled with the premium connections of the tubulars, the integrity of the micro-bore wells is assured. If there are any other questions or concerns please call 564-4922 or 564-4825. Dan i~toltz ~ Senior Drilling Engineer, PBU Winton Aubert ;~ ;-- r~; ~-;; Operation Drilling En~rieb~r,"'N2ES ,~;: ~, Gas Co:~s. C'3'rf~ff"~ssi°n DS 02-37 Drilling Prognosis The DS 02-37 is planned as a new horizontal producer into a lowermost Zone 1 target. Plans are to drill vertically to a nudge point at 400', then build angle at 1°/100, to a maximum inclination of 6© at 1000'. Inclination will then be nudged back to vertical at 1840' with a kick off point at 2500' MD (2496' TVD). Inclination angle will be built and the well path turned at a maximum dogleg of 2.5°/100' to a surface casing point at +3600' MD (+3555' TVD). A tangent sec- tion follows to 9490' MD (8632' TVD) on a heading of N28°E. The well path will again be turned and angle built to horizontal at 16°/100, to a heading of N18°W through the target. Drill pipe conveyed logs will be run and an intermediate liner set at 9930' MD (8845' TVD). The production section will be drilled hori- zontally to TD at 11,565' MD (8820' TVD) and a production liner run cemented and perforated. The completion will tie the production liner to surface with tub- ing. DS 2-37 TREE: FMC Gen VI ~;)~.io~(~)~(~ WELLHEAD: FMC Gert VI Micro Bore Horizontal Well ~.~l~J I 2o', ~4 ~ I ?~ 0 SSSV Landing Nipple ;~ ~ Proposed Gas Li~ Design ~-~ GAS LI~ MANDRELS :,.;:~ -. ~ No. MD ~Dss DEV ~ :4 1 ~3550' ~3500' Jl, 1~6 ~ J DATE REVISED BY COMMENTS PRUDHOE BAY UNIT 11-3-96 W. Aube~ Micro Bore HoHzontai ~mpletion WELL: DS 2-37 APl NO 50-02g-~ SEC. 36; T11N; R14E I WellName: IDS 02-37 Well Plan Summary [Type of Well (producer or injector): ]Producer Surface Location: 4600' FSL, 3579' FEL, S36, T1 iN, R14E, UM Target 1 Location: 2542' FSL, 2141' FEL, S25, T1 iN, R14E, UM Bottom Hole Location: 4096' FSL, 2652' FEL, S25, T1 IN, R14E, UM ['AFE Number: [4J0332.0 [ _ ]Estimated Start Date: ]Nov. 6, 1996 I i IT VD: Well Design (conventional, slimhole, etc.): I Rig: I Nabors 2ES Operating days to complete: I 27 [ 8760' ss I IKB Elev. 161.1' Horizontal Micro Bore Objective: Well DS 02-37's objective is to establish long-term, profitable, Romeo production. Well 02-37 is expected to encounter an 80' GLOC with an NLOC of 60'. The target interval, in lowermost Zone 1 (13P ICL, Razor 7200 - 7300), is an outer mouth bar deposit. The drainage area for the new Io- cation is considered to be 118 acres. Associated black-oil reserves, net to the field, are estimated to be 1265 MBO. The average black-oil rate, net to the field, during the first six months of produc- tion is expected to be 2000 bopd. Primary risks associated with this sidetrack are early gas breakthrough or poor quality sand, both of which would reduce the oil production significantly. Both of these risks are managed by planning a horizontal interval in the deepest, good quality sand. Geosteering of the well during implementa- tion and a cemented liner completion are also planned to further manage these risks. The 02-18A results have proven that a horizontal completion can successfully develop Zone 1 in this area. . Formation Markers Formation Tops MD TVD (SS) T-5 3589' 3485' Surface casing set in T-5 K-15 4951' 4660' Ugnu 5821' 5410' K-10 7498' 6855' K-5 8218' 7475' Sag River 9052' 8194' Shublik 9100' 8235' Top Sadlerochit 9169' 8295' Intermediate liner in Sadlerochit TD of Well 11,565' 8760' Solid, cemented production liner Directional I KOP: 12500' MD Maximum Hole Angle: 91° through targets Surface Close Approach Wells: DS 02-lA (29.98' N), DS 02-01 (29.56' S), DS 02-38 (59.95' S). Drilling Close Approach Wells: None R -CEiVED ,,,~.,! 0 '4 1996 Alaska 0il & Gas Cons. Commission Mud Program Surface (8-1/2" hole) Section: Spud Mud or MAXDRILr~ I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel 9el Loss Initial 9.0 _+ 300 35-50 25-45 50-80 9-10 15-20 Final 9.8 150-200 20-40 15-30 30-50 9-10 15-20 , Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning. Intermediate (6" hole) Section: Low Solids Non-Dispersed I Density Yield 10 sec 10 rain pH Fluid (PPG) PV Point gel 9el Loss Initial 9.8 6-10 6-8 3-6 8-10 9.0-9.5 8-12 Cretaceous 9.8 10-12 8-12 4-8 8-12 9.0-9.5 <8 Final 10.0 16-20 12-15 6-8 10-15 9.0-9.5 <6 Hazards/Concerns Possible Cretaceous overpressure, MW should be +9.8 ppg. Be prepared for gas below 6000'. Put River may require 10.3 ppg MW to suppress gas. Potential high torque could require lubricant use. Reduce AP! fluid loss to <6 cc before drilling Kingak. Be alert for lost circulation, differential sticking due to higher MW. Production (3-3/4" hole) Section: Sheardril or Baradriln I Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity . Point gel gel Loss Initial 8.9-9.0 50-60 20-24 8-10 10-124 8.5-9.0 <6 Final 9.0-9.2 50-60 20-24 8-10 10-12 8.5-9.0 <6 Hazards/Concerns Lost circulation, differential sticking due to overbalance in Sadlerochit. Perform and report daily checks on KCL concentrations in system. .,~ High torque may be encountered and should be treated with lubricants. Casing/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfTVD MD/TVD 30" 20" 94~ H-40 Welded 80' 30'/30' 110'/110' 8-1/2" 7" 26# L-80 NSCC 3600' 29?29' 3600?3555' 6" 4-1/2" 12.6# L-80 BTC-MOD 6480' 3450'/3420' 9930?8845' Lower Lateral 3-3/4" ! 2-7/8" 6.5# L-80 EUE-8rd 1783' 9780'/8695' 11565'/8820' Production Tubing NA J 4-1/2" 12.6# L-80 BTC-MO D 3450' 26'/26' 3450'/3420' Cement Ca culations Lead Cement Tail Cement Casin~/Liner Sk/Wt / Yield Sk / Wt / Yield Comments Cold Set Lead to surface (may require 400% ex- 7" 950/12.2/1.92 180/15.8/1.15 cess);ClassGTail;Pumptime=4+hr.;TOC= Surface Cl G; Tail FW=0; 4-1/2" N/A 200 / 15.8 / 1.14 30% excess; Pump time=4+ hr.; TOC = +7780' MD (+_1,000' above Put River) 2-7/8" N/A 70/15.7 / 1.19 Class G: 30% excess; Pump time = 4 hr.; TOC = 150' above TOL Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. Well Control Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pres- sures. Diver[er, BOPE and mud fluid system schematics on file with AOGCC. Hazards · Put River Sand, if encountered, may contain hydrocarbons at 4200 psi @ 8100' TVD (10.3 ppg EMW. · Sadlerochit pressure is 3490 psi @ 8300' TVD ss (7.6 ppg EMW). · Sag River Sand is in communication with Sadlerochit and will have same BHP of 3490 psi at 8215' TVD ss (8.2 ppg EMW). Operations Summary 1. Pre-rig: Set and cement 80' of 20" conductor. Install cellar ring. Secure surface close approach wells. MIRU Nabors 2ES. NU and function test diverter. , , , ! 6, , . Drill an 8-1/2" hole to +3600' MD (_+3555' TVD) per directional plan. Hold diver[er drill while drilling surface hole. RU and run 7", 26#/ft, L-80 casing to TD. Cement casing by circulating lead ce- ment to surface before mixinD and pumping tail cement. This may require as much as 400% excess, or 1807 ft3 (322 bbls) lead slurry. Lead cement volume is based on 3600' of 8-1/2" gauge surface hole (361 ft3 or 64 bbls), plus necessary excess to reach surface. Tail cement volume is based on 750' of 8-1/2" hole plus 100% excess and an 80' shoe joint (207 ft3 or 36.9 bbls). NU BOPE. Install test plug and test rams, choke manifold, standpipe manifold, kelly and all floor valves to 250 psi Iow and 5,000 psi high (annular to 250 psi iow and 2,500 psi high). Chart all tests. Remove test plug. PU 6" bit, 4-3/4" directional BHA, and MWD on 3-1/2" drillpipe. TIH and tag TOC. WOO a minimum of 12 hrs. Test 7" casing to 3,000 psi for 30 minutes. Record and graph (pressure vs. vol- ume) the casing test and use for baseline for the LOT. 9. Drill shoe joint and 20' of new formation. Perform a LOT. 10. 11. Directionally drill a 6" hole to the 4-1/2" liner point (+9930' MD, +8820' TVD) per di- rectional plan. POOH. Log well from TD to +8000' with DPC GR/CN/BHCA.- RECEIVED r'-~0'l 0 4 1996 ~ n'~ C0mmJssion Alasx~, ,,:, & Gas Cons. 12. RU and run 4-1/2", 26 #/ft L-80 liner from _+9930' MD (+8845' TVD) to 150' inside 7" surface casing. 13. Cement the 4-1/2" liner with 223.5 ft3 (39.8 bbls) CIG cement, based on 1940' of 6" hole x 4-1/2" liner annulus + 30% excess (216.6 ft3 or 38.6 bbls) plus an 80' shoe joint (6.8 ft3 or 1.2 bbls). 14. Test BOPE to 250 psi Iow / 5000 psi high. 15. PU 3-3/4" bit, directional BHA, and MWD. TIH on 2-3/8" DP. Carry out well kill _ drill. Drill out +___20' with existing MW (drill-out FIT). 16. Displace well with new +9.0 ppg Baroid Sheardril or Baradriln mud. Directionally drill to TD at +11,565' MD (8,820' TVD.) POOH. 17. Run a 2-7/8", 6.5#/ft, L-80, EUE-8rd (USED if available from stores) liner with 2- 7/8" x 4-1/2" L-80 packer/hanger to bottom in the 3-3/4" hole. Run liner with 1- 11/16" inner wash string from below the packer/hanger to bottom. Space out for about 150' of lap. Reciprocate liner 20' - 30' during circulation and cementing. 18. Cement the 2-7/8" liner with 84.0 ft3 (15 bbls) CIG cement, based on 1633' of 3- 3/4" hole x 2-7/8" liner annulus + 30% excess (67.1 ft3 or 12 bbls), plus an 80' shoe joint (2.6 ft3 or 0.5 bbis), plus 150' liner lap (6.1 ft3 or 1.1 'bbls), plus 150' excess on top of liner with drill pipe (8.2 ft3 or 1.5 bbls). Set liner hanger/packer with 4200 psi. 19. Reverse out clean through the 1-11/16" inner string. Pressure test the liner lap to 3500 psi for 30 min. Displace the hole with filtered seawater. POOH. 20. MU 1-11/16" drill pipe conveyed perforating guns with 3.2 gram charges, 4 spf, on 2-3/8" drill string. Include tools as follows: Absolute pressure firing head Perforating guns & blanks, as per enclosed production specs. ~ Firing Head Adapter ~ Primary Firing Head (Annulus Pressure) ~> x/o 1-11/16" EUE to 2-3/8 DP --- 2-3/8" DP (approx. 12 joints) ,,,_u x/o and Below Packer Safety Joint L...) Bypass Port ~ 4-1/2" Champ Packer (To be set @ xxx' MD / xxxx' TVD) Jar PR FAS-FIL Valve to be set at @ xxx' MD / xxx' TVD to achieve xxx psi underbalance. 2-3/8" DP to surface Note: Once logs have been analyzed and the perforation intervals are known the packer depth, fluid height for underbalance, and clean up period will be de- termined. Detailed perforating procedure will be sent to the rig as soon as above values are known. Note: Refer to Standard Completion Running Procedure as well as Proposed comple- tion diagram for more details. 21. Run a 4-1/2", L-80 BTC-MOD completion assembly (used tbg if available from stores). (WLEG to be spaced inside the 4-1/2" tie-back receptacle.) Tubing detail as follows: (Refer to Proposed Completion Diagram for more details.) Note: fol- low EOA completion guidelines, · 4 1/2" WLEG · 4 · 4 · 4 · 4 · 4 · 4 . 4 · 4 · 4 · 4 · 4 · 4 G · 4 · 4 · 4 1/2", 1/2", 1/2", 1/2", 1/2", 12.6#, L-80 BTC-MOD 10 ft pup joint 12.6#, L-80 BTC-MOD 10 ft pup joint L-80 Otis "X" Nipple (3.813" ID) 12.6¢, L-80 BTC-MOD 10 ft pup joint 12.6¢, L-80 BTC-MOD full joint 1/2", 12.6¢, L-80 BTC-MOD 10 ft pup joint 1/2" x 7" packer 1/2", 12.6¢, L-80 BTC-MOD 10 ft pup joint 1/2", L-80 Otis "X" Nipple (3.813" ID) 1/2", 12.6¢, L-80 BTC-MOD 10 ft pup joint 1/2", 12.6#, L-80 BTC-MOD tubing joint 1/2", 12.6#, L-80 BTC-MOD tubing with ultra slim hole GLM's LM depths to be determined later. 1/2", L-80 Tubing Retrievable SSSV ~ + 2,200' MD 1/2", 12.6¢/ft, L-80 BTC-MOD tubing to surface 1/2" tubing hanger. 22. 23. Space out, test the SSSV and circulate with corrosion inhibitor prior to setting packer. Drop the packer setting ball. Pressure the tubing to 4000 psi and set the packer. (NOTE: The Packer must be set priOr to ND BOP and NU Tree be- cause the well is perforated). Close the SSSV, install a TWC, and test to 1000 psi. Remove BOPE. 24. Install and test the production tree to 5000 psi. Pull the TWC valve. 25. While holding 1500 psi on the tubing, pressure test the annulus to 3500 psi for 30 minutes. First bleed off the annulus, then the tubing to 0 psi. 26. Open the SSSV and shear the RP on the upper GLM.with 2900 psi'annulus pres- sure. Bleed off pressure and freeze protect with diesel to 2200' MD. 27 Set a BPV. Close the SSSV and secure the well. Release rig. 28. Complete appropriate documentation and hand-over to Production. REC":IVED Alask.-?. 0il & Eas C0as. Commission Anadrill Schlumberger Alaska District 11il East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL P/~ for SHARED SERVICES DRILLING i,t, jt,. l ;;,: i . .,.' Well ......... : DS02-37 (Pll) Field ........ : Prudhoe Bay, Drill Site 02 Co~putation.,; Minimum Curvature Units ........ : FEET Surface Lat..: 70.26965820 N Surface Long.: 148.47592735 W Legal Description Surface ...... : 4599 PSt 3579 FEL TARGET ....... : 2542 FSL 2i41 FEL BHL .......... : 4096 FSL 2652 FEL Prepared ..... : 0l Nov 1996 Vert sect az.: 28.36 KB elevation.: 60.30 ft Magnetic Dcln: +28.446 (E) Scale Factor., 0.99994034 LOCATIONS - ALASKA Zone: X-Coord $36 TIIN R14E UM 68'8444,49 S25 TllN 'R14E UM 689800.00 S25 TllN R14E UM 689250.00 4 Y-Coord 5950541.54 595aeob.eo S955340.00 Convergence,.: +1.43463589 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY ..... ~ , PROPOSeD.WELL PROEIL~ .. '" .. , : . . ~.....: .,; j. ,,. ,L~.. , .. ....... ". ............. ~" , ........ _Z..:L'..,'i .... . ,:~;:: ........ : ......... .,.:C.'~:--: ........... '...;i:.'..;.t~ .................... ' . STATION MEASURED INCLN DIRECTION VERTICAL-DEPT]{S sECTIoN COORDINATES-FROM IDENTIFICATION DEPTH ANGLE A2~IMUTH T%/D SUB-SEA DRPART WELLHEAD ma.mmam~mmm~ammmmlmm mmmmmmmm mmmmmm mmmmmmmmm mmmmlmmm mmmmmmmm mmmmmmmm lammmemmmm umlmm~mmmm 0.00 0.00 0.00 0.00 ~60.30' ' 0.00 0.00 N 0.00 m~mmmmmmmmm ALASKA Zone 4 TOOL X Y FACE m~mm.~mm~ mmmmmmmmmm mmmm 688444,49 5950541.54 80L NI/DGE BUILD 1/100 400.00' 0.00 280.00 400.00 339.70 0.00 0.00 N 0.00 E 500.00 1,00 280.00 499.99 439.69 -0,27 0.15 N 0.86 W 600,00 2,00 280,00' 599.96 539,66 -1il0 0.61 N 3.44 W 688444.49 5950541.54 80L 688443.63 5950541.67 80L 688441.04 5950542.06 80L 700.00 3.00 280.00 699.86 639.56 -2.47 1.36 N 7.93 W 688436.73 5950542.71 80L END BUILD 1/100 KUDGE DROP 1/100 800.00 4.00 280.00 799.68 739.38 -4.40 900.00 5.00 280.00 899.37 839,07 -6.87 1000.00 6.00 280.00 .998.90 938.60 -9.89 1240.00 6.00 280.'00 1237.59 1177.29 -17.79 1300.00 5.40,. 28~.00 .._129,7,29 -1236,97 "l~ ~6- DL/ lO0 0.00 0.00 1.00 1.00 1.00 1400.00 4.40 280.00 1396.93 1336.63 -22.35 1500.00 3.40 280.00 1496.69 1436.39 -24.49 2.42 N 13.74 W 688430.69 5950543.62 80L 1.00 3.79 N 21.47 W 688422.93 5950544.79 80L 1.00 5.45 N 30.91 W 688413.45 5950546.21 HS 1.00 9.81 N 55.62 W 688388.65 5950549.95 LS 0.00 1Q..$4 N. _.-.~-l.~8.W 688382.76 5950550.84 ,,LS 1.00 (Anadrill (c)96 0237911 3.0b.07 11:51 AM P) 12,32 N 69.90 W 688374,31 5950552.11 80L 1.00 13.51 N 76.59 W 688367,59 5950553.12 80L 1.00 0 < O DS02-37 {Pll) 01 Nov 1996 PROPOSED WELL PROFILE mmmmmmmmmmmmm~=~=~ STATION IDENTIFICATION mmmmmmmmmmmmm~==~=mm ~ND DROP 1/100 BASE PERMAFROST mml~mmm! nmm~mm MEASURED INCLN DEPTH ~%NGLE 1600.00 2.40 1700.00 1.40 1800.00 0.40 1840.00 0.00 1913.81 0.00 mmmmmmmmm mm~m~mmm~mm~mmmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA , . 280.00 1596.56 1536.26 280.00 1696.51 1636.21 280.00 1796.49 1736.19 280.00 1836.49 1776.19 . 280.00 1910,30 1850.00 SECTION DEPART m~mmmm~ -26.0'9 -27.1] -27.63 -27,.67 -27.67 COORDINATES-FROM WELLHE/~ 14.38 N 14.96 N 15.23 N 15.26 N 15.26 N 81.58 W 84.84 w 86,39 W 86.53 W 86.53 W ALASKA Zone 4 TOO1, DL/ X Y FACE 100 688362.58 595055].88 80L 1.00 688359.30 5950554.37 80L 1.00 688357.75 5950554.60 80L 1.00 6883'57.61 5950554.63 28R 1.00 688357.61 5950554.63 28R 0.00 lOP / BUILD 2.5/100 2500.00 0.00 28.36 2496.49 2436.19 2600.00 2.50 28.36 2596.46 253~'.16 2700.00 5.00 28.36 2696.24 2635.94 2800.00 7.50 28.36 2795.64 2735.34 2900.00 10.00 28.36 2894.47 2834.17 3000.00 12.50 28.36' 2992.54 3100.00 15.00 28.36 3089.66 · 3200.00 17.50.," ..."~8:36 :'. 3185.66 . ' .... 3300.o0 ' '20.00.: '~a':36 ,~...~.:_ ,.......,.. ...~Xo,-oX...:.:2.~,.~.5.~.: 86.53 W 6~83'57.61 5950564.63 28R 0.00 85.49 W $88358.60 5950556.57 28R 2.50 82.38 W 688361.56 5950562,40 HS 2.50 77.21 W 688366.49 5950572.11 l'{5 2.50 69.99 W 688373.38 5950585.67 }~S 2.50 -27'.67 15.26 N -25.49 ' 17.18 N -18.95 , 22.93 N -8.06 32.51 N 7.~5 45.90 N · 26.65 '63.06 N 50.42 83.98 N 78.40.- 108.60 N' . 293'2.24 60.92 W 688382.21 5950603.06 HS 3029.36 .49.44 W 688392.97 5950624,25 HS 3125.36 36,15 W 688405.64 5950649.20 ~S .3220.0'5 '"' '110,54' 1~6:89 N '~0'7% w ~8842o':19 595o677,85 : '.'.,'{28 }]6 I;..33~3,. ~'$i. :33~'J ~:24:;'- ?: '14'6'~.B": .: . 168'278 N ..3j'~:; W 68~'436.60".' 5)5.0710 .!6 T-S SURFACE C3%SING PT 3500.00 25.00 3589.37 27.23 3~00.00 27.50 3600.63 27.52 3700.00 30.00 28.36 3465.06 3404~76 28.36 3545.30 3485'.00 28.36 3554'.74 3494.44 28.36 3555.30 3495.00 28.36 3642.41 3582.11 2.50 2.50 2.50 2.50 ".~, .,2 .SO, END BUILD 2.5/100 3719.80 30.50 K-15 4950,88 30.50 TOP UGNU 5821.28 30.50 TOP WEST SAK 6703.28 30.50 K-10 7498.25 30.50 28.36 3659.51 3599.21 28.36 4720.30 4660.00 28.36 5470.30 5410.00 28.36 6230.30 6170.00 28.36 6915.30' 6855.00 187.06 204.22 N 15.46 E 688454.83 5950746.07 NS 2.50 226.39 238.83 N 34.15 ~ 688472.64 5950781.14 }IS 2.50 231~28 24'3.14 N 36.47 E 688474.86 5950785.50 HS 2.50 231.57 243'.39 N 36.61 E 688474.99 5950785.76 ~S 2.50 279,38 285.46 N 59.31 E 688496.63 5950828.38 ~S 2.50 289.35 294.24 N 64.05 E 688501.15 5950837.27 ]iS 2.50 914.08 844.00 N 360.77 E 688784.00 5951394.26 BS 0.00 1355.77 1232.69 N 570.57 E 688983.98 5951788.06 HS 0.00 1803.36 1626.57 N 783.15 E 689186.63 5952187.11 MS 0.00 2206.78 1981.58 N 974.76 E 689369.28 5952546.78 HS 0.00 0 < o J. G O K-5 - 8217,78 30..50 LCU 8954.72 30.50 JUR~SIC A 8983.73 30.50 (Anadrill (c) 96 0237P11 3.0b.07 11:51 AM P) 28.3.6 28.36 28.36 753.5 . 30 7:75 . 00 2571 . 9'1 8170.30 8110.00 2945.88 8195.30 8135.00 2960.60 .... i.: (.i [:IV [! il} :~o2.9o N ~%~8.19 E 2631.99 N 1325.82 E 2644.95 N 689534.60 5952872.32 HS. 0.00 689703.92 5953205.74 }IS 0.00 ANAD~li.[ AKA-DPC APP£O¥£D FOR PERMITTING ONLY DS02-37 (Pll) STATION IDENTIFICATION SAG RIVE]{ SHUBLIK TSAD / TZ4B TZ2C c~vE :t/~Oo TZ2A TZ1B ,,. END: C%fRVE 516/100 ..' TARGET INTERMIDIATE LNR PT PRODUCTION LINER PT TD ~SAD / KAVI× m~{ammmm MEASURED DE PTH 9052.20 9099.78 9169.42 9343.50 9418.93 PROPOSED WELL PROFILE INC~ ~N~LE 30,50 30.50 30.50 30.50 30.50 mmmmmmm~ mm.mm~mmmmmm~mmm~ DIRECTION VERTIUAL-DEPTHS AZIMUTH ~ SUB-SEA 2B.36 B25¢.30 B194.00 28.36 8295.30 8235.00 28.36 8355.30 8295.00 28,36 8505.30 8t45.00 28.36 ~570.30 '8510.00 9,1d9.99 30.50 28.36 8631.53 8591.23 9500.00 31.54 26.00 8640.11 8579.81 9600.00 43.65 8.62 8719.42 8659.12 96i5.30 45.68 6.68 8730.30 8670.00 9686.16 55.{4 '359.18 8775.30 8715.00 9695.12 9700.00 9800.00 9900'~00 :.'9929593 9929.93 9930.00 11565.49 11565.49 56.71 358.36 8780.30 8720.00 57.40 .357.93 ,8782.95 8722.65 71.80,,-.: V:350~1.91,. 8,825.79 8765.49 86.47 ,'343166.'t8'8~4.61' 8784.31 '90.88".'~'~,3'417T'8'~ 01 Nov 1996' SECTION DEPART Page 3 2995.35 3019.50 3054.83 3143,17 3181.45 COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 2675.52 N 1349.31 E 689726.32 5953249.85 HS O.O0 2696.77 N 1360.78 E 689737.25 5953271,38 RS 0.00 2727.87 N 1377 5~ E 689753.25 5953302.88 HS O.00 2805.61 N 1419.52 E 689793.24 5953381.64 ~S 0.00 2839.29 N 1437.71 E 689810.58 5953415.77 HS 0.00 3217.51 3222.67 3281.67 3291.72 3340.92 33*?,38 2871.03 N 1454.83 E 689826.90 5953447.92 SOL 0.00 2875.62 N 1457.19 E 689829.14 5953452.57 48L 16.00 2933.62 N 1473.93 B ~689844.43 5953510.97 35L 16.00 2944.28 H 1475.36 g 689845.5) 5953521.66 33L 16.00 2998.81 N 1477.90 E 689846.76 5953576.23 28L 16.00 3006.24 N '1477.74 3350.92 3o~o.~4 ~ la?V.~o 3425.06,:,., 3099.82:N.. 1467.92 ":3519'~27': 3223Y, ggN/£~1436.'?5 90.88 341.78 8845.30 8785.00 3519.27 3223.69 N 1436.75 E 90.88 341.78 8845.30 8785.00 3519.32 3223.76 N 1436.73 E 90.88 341.78 8820.30 8760.00 4643.40 4777.07 N 925.45 E 90.88 341.78 8820.30 8760.00 4643.40 4777.07 N 925.45 E 8855.30 8795.00 689846.41 5953583,66 28L 16.00 689846.18 5953587.75 28L 16.00 '689834.26 59536~6.95 24L 16.00 689809.60 5'953771.67 23L.~..'~.60 689800.00 5953800.0.0 .HS' 5~6.00 689800.00 5953800.00 689799.98 5953800.07 689250.00 5955340.00 689250.00 5955340,00 HS 16.00 0.00 0.00 0.00 {~nadrill (c996 0237Pll 3.0b.07 11:51 AM P) , d,,..,~L L-- AKA-DPC ANADRILL APPROVED -" }:OR 'PERMITTING ONLY PLAN Z 0 <, I 0 0 Nov-01-96 12:58P Anadrill DPC 907 344 2160 P-C5 ._ 1 ! : VERTICAL SECTION VIEW icc .... I ...... ~: 7 ' .._ ..?.,i_.~ , , Section at: 28.36 · TVD Scale.' ! inch = t000 fee~ ,oo-- c ..... Dep Scale.' ~ ~nch = ~000 feet : i ' , O-- Brawn 01 Nov 1996 I ,.. · ~na~lr i l l O0 ~ ..... ~I 'l - [ ~ 7 ~ ..... r ...... ~~S? ' ~ Marker Identification HO BK8 SECTN INCLN ~ A) K~ 0 0 0 0.00 J j _ BI NUDGE BUILD t/~00 400 400 0 0.00 : ' C) ENO BUILD J/JO0 1000 9gg, -10 6.00 go--. ~ '-'F ............... -,-- D} NUO~E OROP ~/~00 ~240 ~238' -~B 6.00 . j -' E) ENO ~OP ~/~00 ~8~0 ~836 -28 0.00 ~ : F) KOP / BUILD 2.5/100 2500 2496 -28 0.~ ...... Gl SURFACE ~SING PT 360[ 3555 232 27.52 )0- - ~ HI END BUILD 2.5/J00 3720 3660 2Bg 30.50 ' Il CURVE ~6/t00 9~90 8632 3218 30.50 :1 J} END 'CURVE 16/JO0 9930 8845 3519 90.88 : ~ K} TARGET 9930 8845 35~9 90.88 )0 ............ , ''4=~-=~ .... r'r'~%'~ LJ INTERMIDIATE LNR PT 9930 B845 3519 90.88 N) PRODUCTION LINER PT J~565 8820 4643 90.88 ~0-- ! N) TD t~565 8820 4643 90.'88 , .: O'..... :~-- - .. ..-- . :... ~:~'~-' ~ ........ ' .............. ANI~DRILL AKA-DPC " o- ' , ..... ..... .... ...... ........ ... : '--:::::~: ..... : ....... j .. ,~,~ j I ! I i i i !~ ~~-~:~ ~ ~ :::::::::::::::::::::: )o -5oo o soo tooo ~o0 acco 2500 3000 3~oo 4oo0 45oo 5ooo .5500 6000 Section 0epantune :1~ 023~II 3.00.07 1~ 17 --- .............. SHARED" SERV'T' 'ES '"R"'T"L'LI'N6 ...... i1 i i i 1111 Hill, lift iii ii ii i , i I I i! ' iii11 i __ I iii i i i ii i ' _" 1. .............. · ...... , ...... _ - ~ i i i iiii i i i i ii i i iii i I I iii i ii i ~_1 _ i i ii i ~ 85~ 87O( Anad/'J ] ] S£h]umberger DS02'-37 (PI1) VERTICAL SECTION VIEW Section at: 34! 78 ; i I ! ePS lB': ' inch = 300 teet . ; !D ca ' .......................... t"., .. . DP awn. .... :' O~Nov ~996 , , ......... ' .... HaPker' Iden[ification MD BK8 SECTN I~CL ' '" -- " ' ~ " ' : -', ' ~-- ~ ~ · - ~-¢-~t ' A) .~RVE 16/~00 9490 8632 ~272 30.5 : ' B) END CUR~ JG/~O0 9930 8"45 ~6[3 90." : ..... i m c) TARGET 9930 8845 ~613 90.6 m .' ............ D) INTERMIDIATE LNR PT 9930 8845 ~613 ,90.6 ' , E) PRODUCTION LINER PT ~565 8820 4248 90.6 , : F) lO (~565 8820 4248 90.E ~ ~ "!" : , ' 'I , ' ' ' ~' ' ' 1' I '' ' ' ' m11 ' ' ' ' '.': ' . '":"L ,,,,..'; :'"'.. ' ~ ' ' :~" ~,DPC .... . :.~. ...... ,:~¢...,..,: ...... .. ~?.. ~.... ...... ...,.., ~- ..~,,.~.,..¢,....~.,,:.~ :....;~,... i.:, ~ ...... A F~RO~E.b.. ~¢:.. . ... , ....... , ' " '" - .... ~ · 'm~ "- ' ~ .... ~ ' . i ..... : . , ...... I .. ~.~:n ~ ~ ,---- .... ~ PLAN ~~..~-~,.. .. ..- . ..... ._ ~~.~~; ~ . : ' ~ ...... , ......... ',,. I · : i - I l',.j 0 .,/ () ",. i9 ~, & , i.,. " , ; ~l-,t ),;) F"t~{ l~ r~... ; - I , . , -,.s.--.,- ........... Fr-~' . ............ · I ...' ...Anch:m¢c ........ ! . ~ - ~a~.. .... .... ~ *~..~ [~'~ '~ .-. ': '~-."'~. ~ "i "' t . ' ' ~.~ .... ,._ 1 ,,, ,,i - .... $950 2100 2250 ~400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4200 4350 4500 Sect ion Departure Z O, <. I 0 I Nov-01-96 01:01P Anadrill DPC _ _ 907 344 2160 P.11 SHARED .SER VIC'ES DRILLING "': Narker Identifi2ation HO N/S E/W A) KB 0 0 N 0 E 8) NUDGE BUILD 1/100 400 0 N 0 E C] ENO BUILD I/I00 1000 5 N 31 N O) NUDCq~ DROP t/tO0 1240 10 N 56 W E) END DROP 1/100 1840 15 N 87 W F) KOP / BUILD 2.5/100 2500 15 N 87 W G) SU~ACE CASING PT 3601 243 N 37 E HI END BUILD 2.5/100 3720 294 N 64 E I) CURVE 16/100. 9490 2871 N 1455 E d) ENO CURVE 16/100 9930 2224 N 1437 E K) TARGET 9930 3224 N 1437 E L) INTEt~[DIATE LNR PT 9930 3224 N 1437 E M) PROOUCTION LINER PT 11565 4777 N 925 E N) TD 11565 4777 N 925 E -. 2800 DS02-37 (P 1..1) PLAN VIEW ~JCLOSURE ..... : 4866 feet at Azimuth 10.96 { '~DECLINATION.: +28.446 (E) ., ~SCALE ....... : ! inch- 800 feet DRAWN. · 01 Nov 1996 II · /nadri ] ] $chlumb'erger i! 200( 1600 1200 800 400 0 400 800 1200 1600 2000 -2400 2800 <- WEST j EAST -> .i (Ana~rzl! (cJ~ 0237Pli ].Ob.07 ll: ,iii ~ P) Client; .............. : ARCO ALASKA INC Well Name ....... : DS02.-37(P11 ) Field ................ : PRUDHOE BAY County / State..: BEECHEY POIlMT, ALASKA APl# ................ : 50-029-96049-00 Alaska District Directional Well Planning [:)epar~meflt NORMAL PLANE TRAVEELIN,G CYLINDER RESULTS INCLUDING ELLIPSES ~F UNCERTAINTY Planned W~I S~r~ey Program Start E~ ~ Ty~ lateral 0 11566 '~EWD 93 · Anadrill ID# ...... : 500299604900P1103 'i Grid Zone ............. : ASP ZONE 04 Date Calculated ..... : I 1/01/96 10:33 Date Plotted .......... ; 11/01/96 10:36 KaL ..................... : , 60,30 Grid X .................. : 688444.49 Grid Y .................. : 5950541.54 ' I i FLOWING PLUQQED ENTER ENTER F. XIT EXIT CLOSE MIN' i - OFFSET WELL I FLOWING ELLIPSE SURVEY SAFETY SAFETY PLU(3 'NO DRILL NO DRILL; PLUG APPROACH SAFETY' SEP. SEP. MD 1'VD DIST. DISTo ZONE ZONE ZONE ZONE STATUS SEP. MD MD MD MD " Page 1 of 2 ~ I .... ;- · : - 02-31 i I 7.2 60.0 94.4 3281 ' 3262 42.8 8.2 ] ~ FLOW 02-O1A I 8.3 21.3 29.8 870 870 .- 1-3.1 2,2 FLOW 02-01 17.0 27.0 [ 33.5 671 671 10.1 ; 1,7 . FLOW· DS02-38(D01) [ ~.3.4 53.9 ~ 57.6 'i 698 698 10.5 ; 1.7 { FLOw 02-09 273.8' I 348.6 r 696.6 7945 7300 ;: -..?~.7 19.9 ;: FLow . ~ 698 ~ - 1~).5 1.7 i ; FLOW . E:)SO2-38(P08) ' 46.9 57.4 61.1 699 ; ,, . . DS02-36(P06) :1 50.7 i 59.71 62.9 600 600 ~'; ~;I;'.0 1.6 FLOW 02.0_~iA , 438.7612.6687.777837161 '- -7-".919,5 , FLOW 02-O9APB1li438.7 512.6 687.7 7783 7161 [ :-:-;~ '7_~..9 19.5 ' FLOW 02-O9AP82 438.7 512.6 687.7 7783 7161 ': ;:',7,~_.8 . .19.5 ; FLOW 0502-39(P04) ; 77.6 ; 88.1 91.8 ' 698 698 :~-' . ;.Ii.Q,.6 '= 1.7 ' [ L '. FLOW 16-02 ~ 670.0 i 759.5 ~ 1368.6 10898 8830 ~,J';"t~'5,.-., . 27.2 ; FLOW 02-04 370.6 .I 406.2! 431.7 2544. 2541 ,.~' .:3J5.4. 6.4 ' FLOW 02-02 136.4 146.5 : 153.0 669 669 '$0.0 1.7 '~ i FLOW . i FLOW 02-06 613.3 ! 648.7 I 674.2 2541 2538 r 3~5.4 6.4 o2.11 651.1! 687.8 713.4 2676 . 2672 -, .~36.8 6.7 [ i FLOW , - ' .j U ; ' .. FLOW 02-29A 197.1 207.8 j 212.9 I 716 716 .-.:t~).7 1.8 ' 02-33 ; 683.0:' 7;20.8 748.4, 2793 2779 ~3.7,8 7.0 |' C;:3 F ; FLOW 02-12 : 666.1 : 701.6 727.3 i 2569 2566 . ':'3'5.7 ' 6.4[ v~ {'~.~ , FLOW 02-13 ~ 680.8 71G.7 742.4 I 2586 "~ 2582 i'" ''~:~.935'9' 6.56'5 <~ [ FLowFLOW ''02-13A 680.9 716.7 742.4 ~ 2586 -2582 'Z~' 02-12A 677.3 712.8 ( 727.0 I 2548 2548 · '35.5 8.4 ~ ... ! FLOW 02-12AST 677.3 712.8 727.0 ' 2548 2545 "~5..5 6.4.1 ~ ~ " FLOW- 02-14. 704..,7 : 740.8 i 766.7 : 2611 2607 36.1 6.5 i O i ' FLOW ' 02-27 757-~ I 796.4 816.8 I 285TM 2852 . :. '~ ;~".6 7.1 02-1SA 7~1.S : 789.4.i 816.4.[ 2753 2749 ii""' ": .5 6.9 ~ ' FLOW 751.8; 769.4; 816. ; 7.3 2749 :,-.,. 6.9 2: ,=,.ow 02-15 751.9 789.4 816.5 i 2753 274-.q !.~ !;.'~7.5 6.9 ~ ~ FLOW 02-28 ~ 831.9 873.0 895.0 : 3109 .. 3098 i. :::~.].1 7.6 ~ FLOW 02-17 ; 859.2 898.2 926.4 ] 2900 ; 2896 .:-:' ' :.~'9.0,. .... 7.3 , :7<Z: ; ' ', FLOW DS02-17A(D01i 859.9 898.9 ; 927.1 ' 2903 ~ 2897 . .,~,~.~.0 7.3 <~ ,, : FLOW OS02-17A(P05} 867.5 906.6 ; 927.1 I 2903 2897' i!i"'~9.0 7.3 ] I FLOW 02-32 1011.2 1056.8 1076.~, 3555 3515 .5 8.9 FLOW 02-18 912.6 952..0 i 980.6 = 2939 2933 ~.,4. 7.3 .. i 'FLOW , 02-18A 913.0 ~ 952.4 : 980.8 2939 2933 .;39.4. 7.3 J FLOW 02-leAST 913.0 [ 952.4I 9ao.a 2939 2933 ~3~...~.. 7.3 .. ' I FLOW 02-1BAST2 913.0 : 962.4 ' 980.8 2939 2933 ..- .-,.;i..9.:4 7.3 !' i ~-- "." :-'FLOW - 02-1BAST3 913.0 ! 952.4 i 980.8 i 2939 2933 [ .~,[9.4' : 7.3 ~ ; ~' .~ ' FLOW '" ' - 02-08A 889.0 924.5 ] 950.0 ~ 2543 2539 ~ 35.4 6.4 ; ~ .~,~ : FLOW 02-08 889.6 - 925.0 ~ 950.5 ! 2540 2536 I -' 35.4 ~ 6.3 ~ ::~ 9: [ FLOW , . ;;_, OS02-08A(P03}, 900.0 935.2 949.5 2522 2518 35.2 6.3 ; ~ (.O ~ FLOW ' '~" ' ~ ~:~ ! FLOW 02.03 256.5 i 266.2 272.4 ! 64.2 i 642 :' :'-*.j9.6 1.6 · 02-03A : 257.8 267.5 273.7 I 642 :, 642 ?i~.6.,.. 1.6 "-' i 02-07 1015.8 1051.2 1076.7 . 2538 ; 2534. ' '367.4 6.3 ,~ ~ c;~ i FLOW 18-0lA I 2734.1 2819.6 3290.8 ! 10113 i 8843 I.,! 85.6 25.3 I -.~ O ~ .c~ ] FLOW 18-01 2984;'6 , 3070.7 3643.0 10342; 8839 'iJ i''~'·'''7~9 25.9 ~ ~'~ FLOW 02-16A ! 882.3 , 901.6 I 913.9 1289 '- 1287 .'.:'~.3 3.2 ~ : . ~-""~ '~<-~ FLOW 02-16 882.1 901.4 ] 913.8 1285 ' 1282 .. - .3 3.2 ..... J C__~,i c~ FLOW 02-34 : 441.4. 451.0 454.4 636 636 ~ "9.5 1.6 --"~ -~ 2::-~ : --- FLOW 02-22 1945.7 i 1987.6 2029.9 3184 ! 3170 i-'' a, 1.8 8.0 c; FLOW 02-26 [ 1795.4 - 1830.5 ! 1855.7 2515 ' 2511 ' ' '~5.1 6.3I ---~ FLOW 02-26 . 1829.8 · 1866.3 1891.1 2568 [ 2564 ;-;'' :'~5.6 6.4. : ; c-; FLOW i 1916.0 1942.0 2571 ' 2567 i ':~5.7 6.4 - ~ FLOW 02-24 : 1880.3 ! 02-23 1931.5 ; 1966.5 1991.5 2500 i 2496 i :' ~,~.0 6.2 ..i I i. FLOW 02-23ST 1931.6 i 1966.6 1991.6 2500 2496 j ~15.0. 6.2 ; FLOW O2-21 i 2072.1 : 2108.8 2136.5 2671 i 2667 i 36.7 i 6.7 J FLOW 02-20 ] 2134..3 ] 2169.6 2195.0 2526 2522 ~ 35.3 i 6.3 I FLOW NOTES: All deptha & dlm, taflcem -,re in FEET ," All dep~he ,ere ref~.er~cmd from well DS02-37(P11) .' .. ~r 111 I East 80th Avenue - Anchorage, Alaska 99618 - Telephone: (907} 3¢9-4511 - FAX: (907) 344-2160 :J FIELD & POOl WELL PERMIT CHECKLIST COMPANY /,"~ INIT CLASS Z~--~/ ,/-,:::~,~ '// , ADMINISTRATION D -ENGINEERING ..... 14. 15. 16. 17. 18. 19. 20. 21. 22. 24. 5. 29. ' GC=OLOGy 1. Permit fee mtached ....................... 2_ Lease number appropriate ................... ,3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well Iocmed proper distance from ddg unit boundary ..... 6. Well Iocat~ proper distance from offer wells ......... 7. Sufficient acreage available in drilling unit. ......... 8. If deviated, is wellbore plat included ............. 9. Operator only a~fected party .................. 10. Operator has appropriate bond in force ........... 11. Permit can be issued without conservation order ..... 12_ Permit can be issued without administrative approval... 13. Can permit be approved before 15-day wail ........ ....... - .... WELL NAME,/~.~ -~-¢27 GEOL AREA ~:~.~' ~ . N Y N YN Y N .Y N .Y N ,Y N .Y N Y N Y N YN Y N N PROGRAM: exp O dev'l~ reddl [] serv O wellbore seg [] ann. disposal para req [] UNIT# ./'/~---~,¢'0 ON/OFF SHORE ~ ,,,t.J REMARKS APPR D ,TE ., Conductor string provided ................... { ~ N Surface ca~ng protects all known USDWs ......... !,~N CMTvoladequatetocirculateonconductor&surfcsg...,~¥,~...~ .,~.. _ CMT vol adequate to fie-in long string to surf csg ..... CMT will cover ail known productive horizons ......... i.~N Casing designs adequate for C, T, B & permafrost. ..... i~,~ N . Adequate tankage or reserve pit. ............... i,.y~ N , ~ ~)~ ~ ~-/'-- If a re-drill, has a 10403 for abndnmnt been approved .... -~--N Adequate wellbore separation proposed ............ If diverter required, is it adequate ................ Drilling fluid program schematc & equip list adequate .... /~N BOPEs adequate ....................... BOPE press radng adequate; test to ~'-¢~'L~ psig.~ N ~'-'~'¢ ~ Choke manifold complies w/APl RP-53 (May 84) ....... Y~N r,~ Work will occur without operaton shutdown .......... ~N Is presence of H2S gas probable ............... 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ , 31. Data presented on potenfiai overpressure zones ....... Y/~ ,/-'¢_~, ~"~. 32. Seismic analysis of shailow gas zones ............ .//¢ N ' ' ' ' 33. Seabed condition survey (if off-shore) ........... //. Y N 34. Contact name/phone for weekly progress repo~,... ,/I... Y N lex~oratory omyj GEOLOGY: RP. ENGINEERIN¢2: COMMISSION: JDH~ JDN l) TAB Comments/Instructions: I ~'A'4FOR~ rev 4/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-$~-n Drilling Services LIS Scan Utility Thu Apr 10 15:36:04 1997 Reel Header Service name ............. LISTPE Date ..................... 97/04/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/04/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW- 60162 RAY FRENCH G.W. CRAIG DS 02-37 500292271700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 10-APR- 97 MWD RUN 6 AK-MW-60162 RAY FRENCH G.W. CRAIG MWD RUN 7 AK-MW-60162 RAY FRENCH G.W. CRAIG JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 AK-MW- 60162 RAY FRENCH G.W. CRAIG MWD RUN 9 AK-MW-60162 RAY FRENCH G.W. CRAIG MWD RUN 12 AK-MW-60162 RAY FRENCH G.W. CRAIG JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 13 AK-MW-60162 RAY FRENCH GENE BECK MWD RUN 14 AK-MW-60162 ERIC CRIBBS GENE BECK MWD RUN 15 AK-MW-60162 ERIC CRIBBS GENE BECK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 16 AK-MW-60162 ERIC CRIBBS GENE BECK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header 36 liN 14E 4600 3579 61.50 60.10 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 30.000 7.000 3601.0 8.500 4.500 9968.0 6.000 2.875 11617.0 3.750 11617.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 4 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUNS 5 THROUGH 9 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 5. NO FOOTAGE WAS ACCOMPLISHED DURING MWD RUNS 10 AND 11. 6. MWD RUNS 12 THROUGH 16 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 7~ THIS WELL REACHED A TOTAL DEPTH (TD) OF l1617'MD, 8806'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8319.5 11570.0 ROP 8370.5 11617.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASbKED DEPTH) ~:~' - EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 8319.5 8580.5 8582.5 8591.5 8594.5 8597.5 8599.0 8600.5 8604.0 8605.5 8618.5 8623.0 8627.0 8628.5 8633.0 8634.5 8638.5 8640.0 8642.5 8645.0 8648.0 8649.5 8651.5 8654.0 8658.0 8660.5 8662.5 8664.0 8666.5 8671.5 8673.0 8675.0 8677.5 8680.0 8682.0 8684.5 8686.5 8690.0 8692.0 8695.5 8699.0 8703.0 8705.0 8709.0 8711.5 8713.0 8717.0 8721.0 8724.5 8728.0 8730.5 8733.0 8735.5 8739.5 8741.5 8743.5 8746.0 8747.5 8750.5 8752.5 8754.5 GR 831'8.0 8579.0 8580.5 8589.5 8593.0 8597.0 8598.5 8600.0 8603.5 8604.5 8616.5 8621.0 8625.0 8626.5 8630.5 8632.5 8637.0 8639.0 8641.5 8643.5 8646.0 8648.0 8651.0 8652.5 8658.0 8660.0 8662.5 8663.5 8666.0 8671.0 8673.0 8674.5 8677.5 8679.0 8681.5 8684.5 8686.5 8690.5 8692.0 8694.5 8697.0 8701.5 8703.5 8707.0 8709.5 8711.0 8715.0 8719 0 8723 0 8726 0 8729 0 8731 5 8734 0 8737 0 8740 0 8742.0 8744.5 8746.5 8748.5 8751.5 8753.5 8757.0 8759.5 8761.5 8763.0 8764.0 8766.5 8773.0 8775.0 8776.0 8777.0 8782.5 8786.5 8793.0 8796.5 8801.0 8810.5 8812.0 8816.0 8818.5 8821.5 8823.0 8825.0 8827.0 8830.5 8833.0 8842.5 8844.5 8848.0 8855.5 8857.0 8860.0 8861.5 8864.0 8865.5 8866.0 8869.0 8871.0 8874.0 8877.0 8895.0 8901.0 8908.5 8911.0 8912.5 8915 5 8919 0 8923 5 8939 0 8957 0 8961 0 8964 0 8967.5 8969.0 8975.5 8993.0 8999.0 9006.0 9007.5 9008.5 9013.0 9015.0 9022.5 9024.5 9026.0 ~755.5 8758.0 8760.5 8761.5 8763.0 8765.5 8772.5 8773.5 8774.5 8776.5 8782.0 8785.5 8791.5 8795.5 8800.5 8810.5 8812.0 8816.5 8818.5 8820.5 8822.0 8824.5 8825.5 8827.0 8832.0 8842.0 8844.0 8847.0 8853.5 8855.0 8858.0 8859.5 8862.0 8866.0 8866.5 8868.0 8869.0 8871.5 8875.5 8893.0 8899.0 8907.5 8910.5 8912.0 8914.5 8916.5 8920.5 8936.5 8955.5 8959.5 8964.0 8966.0 8967.5 8974.5 8998.0 9002.0 9007.0 9008.0 9009.0 9010.5 9012.5 9020.0 9022.5 9023.5 9032. 9043. 9047. 9053. 9056. 9059. 9061. 9063. 9066. 9070. 9101. 9106. 9109. 9114. 9123. 9125. 9129. 9137. 9145. 9147. 9152 9165 9169 9173 9185 9189 9192. 9196. 9203. 9208. 9210. 9211. 9220. 9224. 9230. 9232. 9233. 9244. 9250. 9279. 9282. 9283. 9298. 9315. 9317. 9331. 9336. 9366. 9369. 9433. 9493. 9510. 9512. 9523. 9544. 9546. 9548. 9580. 9584. 9617. 9623. 9639. 9646. 9661. '9:029.5 9040.5 9046.0 9051 0 9054 5 9057 5 9059 5 9061 5 9065 5 9069 0 9101 0 9103 0 9107 0 9111 5 9121 0 9123 0 9126.5 9135.0 9143.5 9146.0 9150.5 9164.5 9166.5 9171.0 9183.5 9187.0 9190.5 9195.0 9201.0 9205.0 9206.5 9208.5 9218.0 9221.5 9230.0 9231.0 9233.0 9241.0 9247.0 9277.0 9279.0 9280.5 9295.5 9312.0 9314.5 9328.0 9333.5 9364 0 9367 0 9431 5 9495 5 9511 5 9514 5 9525 0 9546 0 9547.5 9550.0 9583.0 9586.5 9619.0 9625.0 9640.0 9646.5 9663.0 9665. 9667. 9695. 9696. 9717. 9743. 9752. 9756. 9758. 9765 9775 9800 9802 9824 9830 9844 9848 9853. 9860. 9873. 11617. $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: '9~66.5 9668.5 9693.5 9694.5 9717.0 9742.5 9751.5 9756.0 9758.0 9766.5 9777.5 9803.5 9805.5 9822.5 9828.0 9843.0 9847.5 9852.5 9859.5 9872.5 11616.5 DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP MERGE BASE 5 8369.0 8427.0 6 8427.0 8876.0 7 8876.0 9480.0 8 9480.0 9968.0 9 9968.0 10009.0 12 10009.0 10764.0 13 10764.0 10781.0 14 10781.0 10907.0 15 10907.0 11223.0 16 11223.0 11617.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8319.5 11617 9968.25 6596 8319.5 ROP 3.64 519.79 55.3411 6494 8370.5 GR 14.83 649.87 99.6869 6502 8319.5 Last Reading 11617 11617 11570 First Reading For Entire File .......... 8319.5 Last Reading For Entire File ........... 11617 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8318.0 8376.5 ROP 8369.0 8427.0 $ LOG HEADER DATA DATE LOGGED: 16-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74/2.041 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8427.0 TOP LOG INTERVAL (FT) : 8369.0 BOTTOM LOG INTERVAL (FT): 8427.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.8 MAXIMUM ANGLE: 24.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER NGP 320 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD MUD 9.90 50.0 9.3 700 4.0 .000 .000 .000 .000 · 6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 9.6 First Name Min Max Mean Nsam Reading DEPT 8318 8427 8372.5 219 8318 GR 121.22 228.59 177.447 118 8318 ROP 6.34 57.24 19.805 117 8369 Last Reading 8427 8376.5 8427 First Reading For Entire File .......... 8318 Last Reading For Entire File ........... 8427 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8375.5 ROP 8427.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8825.0 8876.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 17-NOV-96 1.32 5.74/2.041 MEMORY 8876.0 8427.0 8876.0 27.4 31.4 TOOL NUMBER NGP 320 6.000 6.0 SPUD MUD 10.00 43.0 9.2 700 4.0 .000 .000 .000 .000 12.2 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth 'units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 ,liN Max frames per record ............. Undefined Absent value ...................... -999,25 Depth Units .................... .,,, Datum Specification Block sub-type,,,0 ,6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8375,5 8876 8625,75 1002 8375,5 GR 96,75 409,16 192,096 900 8375,5 ROP 17,53 297,24 34,8863 899 8427 Last Reading 8876 8825 8876 First Reading For Entire File .......... 8375,5 Last Reading For Entire File ........... 8876 File Trailer Service name ............. STSLIB,003 Service Sub Level Name,.. Version Number ........... 1,0,0 Date of Generation ....... 97/04/10 Maximum Physical Record,.65535 File Type ................ LO Next File Name ........... STSLIB,004 Physical EOF File Header Service name ............. STSLIB,004 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 97/04/10 Maximum Physical Record,,65535 File Type ................ LO Previous File Name ....... STSLIB,003 Comment Record FILE HEADER FILE NUMBER: 4 ~ - . RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8813.0 ROP 8865.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9429.5 9480.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 18-NOV-96 1.32 5.74/2.041 MEMORY 9480.0 8876.0 9480.0 29.4 32.3 TOOL NUMBER NGP 320 6.000 6.0 SPUD MUD 10.00 46.0 9.0 700 4.0 .000 .000 .000 .000 12.2 .6 Data Reference PoinL~. ............. Undefined 'Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 8813 9480 9146.5 1335 8813 GR 14.83 649.87 90.8669 1234 8813 ROP 6.78 242.06 51.6587 1231 8865 Last Reading 9480 9429.5 9480 First Reading For Entire File .......... 8813 Last Reading For Entire File ........... 9480 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 9414.5 9920.0 9463.0 9967.5 20-NOV-96 SURFACE SOFTWARE"VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.32 5.74/2.041 MEMORY 9968.0 9480.0 9968.0 33.3 86.3 TOOL NUMBER NGP 94 6.000 6.0 LSND 10.00 43.0 9.5 700 3.8 .000 .000 .000 .000 16.1 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam DEPT 9414.5 9967.5 9691 1107 GR 17.03 138.96. 36.2781 1012 ROP 8.26 2927.14 80.2981 1010 Reading 9414.5 9414.5 9463 Reading 9967.5 9920 9967.5 First Reading For Entire File .......... 9414.5 Last Reading For Entire File ........... 9967.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Con~nent Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9851.0 9955.5 ROP 9885.5 10008.5 $ LOG HEADER DATA DATE LOGGED: 24-NOV-96 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74/2.041 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10009.0 TOP LOG INTERVAL (FT): 9968.0 BOTTOM LOG INTERVAL (FT): 10009.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 323 'BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 LSND 8.70 44.0 8.5 29500 15.5 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 -17.7 First Name Min Max Mean Nsam Reading DEPT 9851 10008.5 9929.75 316 9851 GR 27.22 96.78 43.3417 210 9851 ROP 18.94 116.44 64.909 247 9885.5 Last Reading 10008.5 9955.5 10008.5 First Reading For Entire File .......... 9851 Last Reading For Entire File ........... 10008.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical R6d~ord..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HF~ADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9939.0 ROP 9980.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10724.5 10764.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 28-NOV-96 1.32 5.74/2.041 MEMORY 10764.0 10009.0 10764.0 88.9 93.5 TOOL NUMBER NGP 163 3.750 3.8 BARADRI L-N 8.80 51.0 8.7 28500 6.8 .000 .000 63.3 MUD FILTRATE '~-r MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STTkNDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point ............... Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9939 10764 10351.5 1651 9939 GR 41.71 187.52 93.0096 1572 9939 ROP 3.64 519.79 54.8328 1569 9980 Last Reading 10764 10724.5 10764 First Reading For Entire File .......... 9939 Last Reading For Entire File ........... 10764 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name.'~.=~....STSLIB.007 ...... Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 10183.0 GR 10700.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10781.5 10737.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING 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 29-NOV-96 1.32 5.74/2.041 MEMORY 10781.0 10764.0 10781.0 .0 .0 TOOL NUMBER NGP 323 3.750 3.8 BARADRI L-N 8.90 57.0 8.7 30000 5.7 .000 .000 .000 .000 65.6 .3 Data Record Type ...... ~ ............. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10183- 10781.5 16482.2 1198 10183 GR 162.41 190.04 177.664 75 10700.5 ROP 6.71 19116 2395.39 1198 10183 Last Reading 10781.5 10737.5 10781.5 First Reading For Entire File .......... 10183 Last Reading For Entire File ........... 10781.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10739.0 10863.5 ROP 10782.5 10907.5 $ 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 01-DEC-96 1.32 5.74/2.041 MEMORY 10907.0 10781.0 10907.0 91.8 94.2 TOOL NUMBER NGP 163 3.750 3.8 BARADRI L-N 9.00 60.0 8.9 31000 5.6 .000 .000 .000 .000 18.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 AAPI 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 10739 10907.5 10823.2 338 GR 32.27 409.08 124.843 250 ROP 28.68 194.76 91.4242 251 First Reading 10739 10739 10782.5 Last Reading 10907.5 10863.5 10907.5 First Reading For Entire File .......... 10739 Last Reading For Entire File ........... 10907.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10864.5 11179.5 ROP 10908.5 11222.5 $ LOG HEADER DATA DATE LOGGED: 02-DEC-96 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74/2.041 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11223.0 TOP LOG INTERVAL (FT): 10907.0 BOTTOM LOG INTERVAL (FT): 11223.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.4 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO-~OTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25- Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP 163 3.750 3.8 BARADRI L-N 9.00 61.0 8.8 30000 5.3 .000 .000 .000 .000 20.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 AAPI 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10864.5 11222.5 11043.5 717 10864.5 GR 54.23 115.94 73.4665 631 10864.5 ROP 21.21 190.93 65.0163 629 10908.5 Last Reading 11222.5 11179.5 11222.5 First Reading For Entire File .......... 10864.5 Last Reading For Entire File ........... 11222.5 File Trailer Service name ....... ~ ..... STSLIB.010 'Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB. 010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11176.0 11569.5 ROP 11223.5 11616.5 $ LOG HEADER DATA DATE LOGGED: 03-DEC-96 SOFTWARE SURFACE SOFTWARE VERSION: 1.32 DOWNHOLE SOFTWARE VERSION: 5.74/2.041 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11617.0 TOP LOG INTERVAL (FT): 11223.0 BOTTOM LOG INTERVAL (FT): 11617.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 92.3 MAXIMUM ANGLE: 93.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): TOOL NUMBER NGP 323 3.750 3.8 BARADRI L-N 9.00 69.0 8.7 29500 FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 AAPI 4 1 68 4 2 ROP MWD 16 FT/H 4 1 68 8 3 20.0 First Name Min Max Mean Nsam Reading DEPT 11176 11616.5 11396.2 882 11176 GR 71.7 164.57 104.061 788 11176 ROP 20.34 343.73 96.0067 787 11223.5 Last Reading 11616.5 11569.5 11616.5 First Reading For Entire File .......... 11176 Last Reading For Entire File ........... 11616.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/04/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/04/10 ,Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/04/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File .............................. * ALASKA COMPUTING CENTER * ****************************** * ....... ~CHL~BRGBR ....... * ~ ............................ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS2 - 37 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API N[IMBER : 500292271700 REFERENCE NO : 96384 MJ CROFI L E g Date /" ,_7~,''' 6)/' LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/02/ 6 ORIGIN : FLIC REEL NAME : 96384 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS2-37, PRUDHOE BAY, API #50-029-22717-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/02/ 6 ORIGIN ' FLIC TAPE NAME : 96384 CONTINUATION # : 1 PREVIOUS TAPE : COF~qENT : ARCO ALASKA INC, DS2-37, PRUDHOE BAY, API #50-029-22717-00 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING DS2 - 37 500292271700 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 5-FEB-97 RUN 1 96384 CARLO A. YON D. STEARNS RUN 2 RUN 3 36 liN 14E 4599 3579 61.50 60.15 30. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 3579.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 3RD STRING PRODUCTION REMARKS: STRING CONTAINED HEREIN IS THE DATA ACQUIRED ON ARCO WELL DS2-37. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. TOOLS WERE LOGGED USING TLC SYSTEM. TOOLS USED WERE: PLATFORM EXPRESS (PEX) WITHOUT RESISTIVITY; AND BHC SONIC. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIA~BER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE SDN CNT BCS $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9669.0 8590.0 9956.0 8577.0 9940.0 8580.0 BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: NO DEPTH SHIFTS WERE APPLIED TO THIS DATA. THIS FILE CONTAINS CLIPPED AND EDITED DATA DECIMATED TO .5 ' SAMPLE RATE. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNT BCS RUN NO. PASS NO. ............... MERGE TOP MERGE BASE ................... LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 1 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 TEND SDN LB O0 000 O0 0 1 1 1 4 68 0000000000 I~RES SDN OBT~I O0 000 O0 0 1 1 1 4 68 0000000000 MTEMSDN DEGF O0 000 O0 0 1 1 1 4 68 0000000000 DEVI SDN DEG O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-S O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F O0 000 O0 0 1 1 1 4 68 0000000000 CALI SDN IN O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN OHI~I O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN OP~4M O0 000 O0 0 1 1 1 4 68 0000000000 ~VOR SDN OH~M O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: ** DATA ** DEPT. 9969.000 GR.SDN -999.250 TENS.SDN 952.000 TEND.SDN MRES.SDN 0.543 MTEM. SDN 176.571 DEVI.SDN -999.250 CNTC. CNT CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 NPHI.CNT -999.250 CPHI.CNT -999.250 DT. BCS CALI.SDN 5.815 DRHO.SDN 0.016 PEF. SDN 2.694 RHOB.SDN MSFL.SDN 34.298 MINV. SDN 0.609 ~INOR.SDN 0.578 DEPT. 8577.000 GR.SDN -999.250 TENS.SDN -999.250 TEND.SDN ~4~ES.SDN -999.250 MTEM. SDN -999.250 DEVI.SDN -999.250 CNTC. CNT CFTC. CNT 958.513 FCNT. CNT 850.347 NCNT. CNT 2618.984 CRAT. CNT N-RAT. CNT 3.357 NPHI.CNT 33.982 CPHI.CNT 34.597 DT. BCS CALI.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN MSFL.SDN -999.250 MINV. SDN -999.250 ~iNOR.SDN -999.250 583.416 -999.250 -999.250 -999.250 2.375 -999.250 2741.253 2.964 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: DEPTH INCREMENT: FILE SUMMARY 0.5000 VENDOR TOOL CODE START DEPTH LDT 9974.0 BHC 9974.0 CN~f 9974.0 $ LOG HEADER DATA STOP DEPTH .......... 8576.0 8576.0 8576.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDT LITHO. DENSITY CNT COMP. NEUTRON GR GAI~IA RAY BHC BHC SONIC AMS AUX. ~EAS. SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~k~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: 21-NOV-96 8B0-538 1300 20-NOV-96 1200 21-NOV-96 9972.0 9972.0 8600.0 9972.0 1800.0 TOOL NUMBER ........... HRMS-B 842 HCNT HGNS-H 840 SDT-C AMS-A 6.000 3579.0 SALT WATER BASED 10. O0 43.0 9.3 2. 460 60.0 2.360 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 5 REMARKS: This run is depth referenced to a logging strip provided b Mr. David Stearns - Anadrill GR log. Deviation at TD is 92 DEG. Platform Express ran without Array induction tool, at clie Hole finder run, two tool turners to orient density sonde. Four 1.5" standoffs run on BHC sonic. THIS IS THE RAW LDT/BHC/CNT DATA AT .5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NTJMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 2 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 2 1 1 4 68 0000000000 HTEN SDN LB O0 000 O0 0 2 1 1 4 68 0000000000 MRES SDN OH~ O0 000 O0 0 2 1 1 4 68 0000000000 MTEM SDN DEGF O0 000 O0 0 2 1 1 4 68 0000000000 GDEVSDN DEG O0 000 O0 0 2 1 1 4 68 0000000000 CNTC PEX CPS O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CFTC PEX CPS O0 000 O0 0 2 1 1 4 68 0000000000 RCFT PEX CPS O0 000 O0 0 2 1 1 4 68 0000000000 RCNT PEX CPS O0 000 O0 0 2 1 1 4 68 0000000000 TNRA PEX O0 000 O0 0 2 1 1 4 68 0000000000 RTNR PEX O0 000 O0 0 2 1 1 4 68 0000000000 CPHI PEX PU O0 000 O0 0 2 1 1 4 68 0000000000 NPHI PEX PU O0 000 O0 0 2 1 1 4 68 0000000000 NPOR PEX PU O0 000 O0 0 2 1 1 4 68 0000000000 DT BHC US/F O0 000 O0 0 2 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 2 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 HDRA PEX G/C3 O0 000 O0 0 2 1 1 4 68 0000000000 PEFZ PEX BN/E O0 000 O0 0 2 1 1 4 68 0000000000 I~4IN PEX OHT~4 O0 000 O0 0 2 1 1 4 68 0000000000 H~NO PEX 0t4~4~ O0 000 O0 0 2 1 1 4 68 0000000000 RXOZ PEX OH~M O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9974.000 GR.SDN 54.758 TENS.SDN 717.000 HTEN. SDN ~!RES.SDN 0.543 MTE~.SDN 176.571 GDEV. SDN -999.250 CNTC. PEX CFTC. PEX 2329.979 RCFT. PEX 2083.998 RCNT. PEX 4165.283 TNRA.PEX RTNR.PEX 1.970 CPHI.PEX 19.243 NPHI. PEX 19.559 NPOR.PEX DT.BHC 123.100 HCAL.PEX 5.740 RHOZ.PEX -999.250 HDRA. PEX PEFZ. PEX -999.250 H~IN. PEX 0.551 H~4NO. PEX 0.545 RXOZ.PEX DEPT. 8576.000 GR.SDN 130.567 TENS.SDN 996.000 HTEN. SDN ~ES. SDN 0.716 MTE~.SDN 152.804 GDEV. SDN 31.481 CNTC. PEX CFTC. PEX 958.513 RCFT. PEX 841.144 RCNT. PEX 2583.247 TNRA.PEX RTNR.PEX 2.793 CPHI.PEX 34.597 NPHI.PEX 35.553 NPOR.PEX DT. BHC 87.400 HCAL.PEX 6.801 RHOZ.PEX 2.483 HDRA.P~ PEFZ.PEX 4.516 H~4IN. PEX 0.583 HNiNO.PEX 0.471 RXOZ. PEX 4513.022 4317.481 1.862 19.072 -999.250 33.484 1090.795 2741.253 2.964 33.982 0.043 3.425 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE '. FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: **** FILE H~ER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH LDT 9974.0 8576.0 CNT 9974.0 8576.0 BHC 9974.0 8576.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDT LITHO. DENSITY CNT COMP. NEUTRON GR GAMMA RAY BHC BHC SONIC AMS AUX. MEAS. SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) 21-NOV-96 8B0-538 1300 20-NOV-96 1200 21-NOV-96 9972.0 9972.0 8600.0 9972.0 1800.0 TOOL NUMBER HRMS-B 842 HCNT HGNS-H 840 SDT-C AMS - A 6.000 3579.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHN~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : SALT WATER BASED 10. O0 43.0 9.3 2. 460 60.0 2.360 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: This run is depth referenced to a logging strip provided b Mr. David Stearns - Anadrill GR log. Deviation at TD is 92 DEG. Platform Express ran without Array induction tool, at clie Hole finder run, two tool turners to orient density sonde. Four 1.5" standoffs run on BHC sonic. THIS IS THE RAW LDT/CNT DATA AT .1667' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 19 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 10 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 RHOZ PEX G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 HDRA PEX G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEFZ PEX BN/E O0 000 O0 0 3 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 3 1 1 4 68 0000000000 H~IN PEX OHMM O0 000 O0 0 3 1 1 4 68 0000000000 H~VO PEX OH~4 O0 000 O0 0 3 1 1 4 68 0000000000 RXOZ PEX OH~I O0 000 O0 0 3 1 1 4 68 0000000000 DPHZ PEX PU O0 000 O0 0 3 1 1 4 68 0000000000 TT1 BHC US O0 000 O0 0 3 1 1 4 68 0000000000 TT2 BHC US O0 000 O0 0 3 1 1 4 68 0000000000 TT3 BHC US O0 000 O0 0 3 1 1 4 68 0000000000 TT4 BHC US O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9974.000 RHOZ.PEX -999.250 HDRA.PEX -999.250 PEFZ.PEX DPHZ.PEX 60721.211 HMIN. PEX 0.551 H~VO.PEX 0.545 RXOZ.PEX DPHZ.PEX 60721.211 TT1.BHC 527.200 TT2.BHC 199.200 TT3.BHC TT4.BHC 345.200 -999.250 33.484 509.600 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE . FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 11 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE · 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9974.0 8576.0 LDT $ LOG HEADER DATA DATE LOGGED: 21 -NOV-96 SOFTWARE VERSION: 8B0-538 TIME CIRCULATION ENDED: 1300 20-NOV-96 TIME LOGGER ON BOTTOM: 1200 21-NOV-96 TD DRILLER (FT) : 9972.0 TD LOGGER (FT) : 9972.0 TOP LOG INTERVAL (FT) : 8600.0 BOTTOM LOG INTERVAL (FT) : 9972.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... LDT LITHO. DENSITY CNT COMP. NEUTRON GR GAMMA RAY BHC BHC SONIC AMS AUX. MEAS. SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : TOOL NUMBER ........... HRMS-B 842 HCNT HGNS-H 840 SDT-C AM$-A 6.000 3579.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 12 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : SALT WATER BASED 10. O0 43.0 9.3 2.460 60.0 2.360 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. $ REMARKS: This run is depth referenced to a logging strip provided b Mr. David Stearns - Anadrill GR log. Deviation at TD is 92 DEG. Platform Express ran without Array induction tool, at clie Hole finder run, two tool turners to orient density sonde. Four 1.5" standoffs run on BHC sonic. THIS IS THE RAW LDT DATA AT .0833' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 13 TYPE REPR CODE VALUE .............................. 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9974.000 HCAL.PEX 5.740 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE . 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 14 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH LDT 9974.0 CNT 9974.0 BHC 9974.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) '. TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 9620.0 9620.0 9620.0 21-NOV-96 8B0-538 1300 20-NOV-96 1200 21-NOV-96 9972.0 9972.0 8600.0 9972.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDT LITHO. DENSITY CNT COMP. NEUTRON GR GAM~A RAY BHC BHC SONIC AMS AUX. M~AS. SONDE $ TOOL NUMBER HRMS-B 842 HCNT HGNS-H 840 SDT-C BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 3579.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): SALT WATER BASED 10. O0 43.0 9.3 2. 460 60.0 2.360 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 15 MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 5 REMARKS: This run is depth referenced to a logging strip provided b Mr. David Stearns - Anadrill GR log. Deviation at TD is 92 DEG. Platform Express ran without Array induction tool, at clie Hole finder run, two tool turners to orient density sonde. Four 1.5" standoffs run on BHC sonic. THIS IS THE RAW REPEAT DATA AT .5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 5 1 1 4 68 0000000000 GR SDN GAPI O0 000 O0 0 5 1 1 4 68 0000000000 TENS SDN LB O0 000 O0 0 5 1 1 4 68 0000000000 HTEN SDN LB O0 000 O0 0 5 1 1 4 68 0000000000 MRES SDN OHMM O0 000 O0 0 5 1 1 4 68 0000000000 MTEMSDN DEGF O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUAiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GDEV SDN DEG O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PEX CPS O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PEX O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PEX O0 000 O0 0 5 1 1 4 68 0000000000 CPHI PEX PU O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PEX PU O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PEX PU O0 000 O0 0 5 1 1 4 68 0000000000 DT BHC US/F O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9974.000 GR.SDN 70.217 TENS.SDN 1596.000 HTEN. SDN MRES. SDN 0.539 MTEM. SDN 177.359 GDEV. SDN -999.250 CNTC. PEX CFTC.PEX 2258.580 RCFT. PEX 2020.881 RCNT. PEX 3900.990 TNR~.PEX RTNR.PEX 1.907 CPHI.PEX 18.295 NPHI.PEX 18.765 NPOR.PEX DT. BHC 85.400 DEPT. 9619.500 GR.SDN 45.532 TENS. SDN 1699.000 HTEN. SDN MRES.SDN 0.569 MTEM. SDN 173.663 GDEV. SDN 50.553 CNTC. PEX CFTC. PEX 1895.445 RCFT. PEX 1876.606 RCNT. PEX 4184.041 TNRA.PEX RTNR.PEX 2.273 CPHI.PEX 24.171 NPHI. PEX 24.160 NPOR.PEX DT.BHC 92.300 3150.970 4041.902 1.802 18.117 486.745 4132.688 2.179 25.152 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 17 **** FILE H~ER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE · 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.1667 FILE SUMMARY VENDOR TOOL CODE START DEPTH LDT 9974.0 CNT 9974.0 BHC 9974.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH .......... 9620.0 9620.0 9620.0 21 -NOV-96 8B0-538 1300 20-NOV-96 1200 21 -NOV-96 9972.0 9972.0 8600.0 9972.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LDT LITHO. DENSITY HRMS-B 842 CNT COMP. NEUTRON HCNT GR GA~IARAY HGNS-H 840 BHC BHC SONIC SDT-C AMS AUX. MEAS. SONDE AMS-A $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6.000 3579.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 18 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~ff) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CA2CE AT (BHT) : SALT WATER BASED 10. O0 43.0 9.3 2.460 60.0 2.360 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THE~ SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: This run is depth referenced to a logging strip provided b Mr. David Stearns - Anadrill GR log. Deviation at TD is 92 DEG. Platform Express ran without Array induction tool, at clie Hole finder run, two tool turners to orient density sonde. Four 1.5" standoffs run on BHC sonic. THIS IS THE RAW REPEAT DATA AT .1667' SAMPLE RATE. $ LIS FO~T DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 21 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 19 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) DEPT FT RHOZ PEX G/C3 HDRA PEX G/C3 PEFZ PEX BN/E DPHZ PEX PU HMIN PEX OIff4~ Pff4NO PEX TT1 BHC US TT2 BHC US TT3 BHC US TT4 BHC US RXOZ PEX O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9974.000 RHOZ.PEX DPHZ.PEX 60721.211 HMIN. PEX TT2.BHC 349.600 TT3.BHC DEPT. DPHZ.PEX TT2.BHC 8576.135 RHOZ.PEX -999.250 HMIN. PEX -999.250 TT3.BHC -999.250 HDRA.PEX 0.281 HMNO.PEX 510.000 TT4.BHC -999.250 PiDRA.PEX -999.250 H~iNO.PEX -999.250 TT4.BHC -999.250 PEFZ.PEX 0.363 TT1.BHC 345.200 RXOZ.PEX -999. 250 PEFZ. PEX -999. 250 TT1 . BHC 420. 400 RXOZ. PEX -999.250 527. 200 29. 069 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION · O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE 2O **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NTJMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.0833 FILE SUT~MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9974.0 9620.0 LDT $ LOG HEADER DATA DATE LOGGED: 21 -NOV- 96 SOFTWARE VERSION: 8B0-538 TIME CIRCULATION ENDED: 1300 20-NOV-96 TIME LOGGER ON BOTTOM: 1200 21-NOV-96 TD DRILLER (FT) : 9972.0 TD LOGGER (FT) : 9972.0 TOP LOG INTERVAL (FT) : 8600.0 BOTTOM LOG INTERVAL (FT) : 9972.0 LOGGING SPEED (FPHR) : 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE LDT LITHO. DENSITY CNT COMP. NEUTRON GR GA~4MA RAY BHC BHC SONIC AMS AUX. MEAS. SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER HRMS-B 842 HCNT HGNS-H 840 SDT-C 6.000 3579.0 SALT WATER BASED LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 21 MUD DENSITY (LB/G): 10. O0 MUD VISCOSITY (S) : 43.0 MUD PH: 9.3 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 460 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2.360 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): O. 5 REMARKS: This run is depth referenced to a logging strip provided b Mr. David Stearns - Anadrill GR log. Deviation at TD is 92 DEG. Platform Express ran without Array induction tool, at clie Hole finder run, two tool turners to orient density sonde. Four 1.5" standoffs run on BHC sonic. THIS IS THE RAW REPEAT DATA AT . 0833' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 22 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NOlv~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 HCAL PEX IN O0 000 O0 0 7 1 1 4 68 0000000000 * * DA TA * * DEPT. 9974. 000 HCAL. PEX 5. 627 DEPT. 9619. 584 HCAL. PEX 5.916 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE . 97/02/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/02/ 6 ORIGIN : FLIC TAPE NAME : 96384 CONTINUATION # : 1 PREVIOUS TAPE : CO~k4ENT : ARCO ALASKA INC, DS2-37, PRUDHOE BAY, API #50-029-22717-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-FEB-1997 10:23 PAGE: 23 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/02/ 6 ORIGIN · FLIC REEL NAME : 96384 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, DS2-37, PRUDHOE BAY, API #50-029-22717-00
