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195-210
RECEIVED - STATE OF ALASKA NnV 0 7 2014 • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG IGCU la. Well Status: 0 Oil 0 Gas ❑SPLUG ❑ Other ®Abandoned 0 Suspended 1b. Well Class 2DAAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑Other No.of Completions Zero - ® Development 0 Service 2. Operator Name: 5. Date Comp., Susp.,'br Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/10/2014 • 195-210 • 313-633 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage, Alaska 99519-6612 1/17/1976 50-029-20287-01-00- 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 1/21/1996 PBU 01-15A • 426' FNL,690' FWL, Sec. 08,T1ON, R15E, UM ' Top of Productive Horizon: 8. KB(ft above MSL): 65.2' • 15. Field/Pool(s) 1394' FNL, 1223' FWL, Sec. 08,T1ON, R15E, UM GL(ft above MSL): 40' . Prudhoe Bay Field/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) Oil Pool 1597' FNL, 1229'FWL, Sec. 08,T1ON, R15E, UM • 8833' 8651' ' 4b. Location of Well(State Base Plane Coordinates, NAD 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 698013 y- 5940478 Zone- ASP4 • 9420' 9197' • ADL 028329 TPI: x- 698575 y- 5939525 Zone- ASP4 11. SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 698587 Y- 5939322 Zone- ASP4 None 18. Directional Surve Y. ❑Yes ® No ' 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: GR, CN, DAL, DLC 8105' • 7970' ' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 32 112' 32' 112' 30" 225 sx Arctic Set 13-3/8" 72# N-80 31' 2693' 31' 2692' 17-1/2" 5800 sx Permafrost II 9-5/8" 47# L-80/RS-95/N-80 29' 8105' 29' 7970' 12-1/4" 830 sx Class'G', 708 sx Class'G' . 7" 29# NT-80S 7910' 9420' 7783' 9197' 8-1/2" 287 sx Class'G' 24. Open to production or injection? 0 Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD (MD+TVD of Top&Bottom; Perforation Size and Number): ) 5-1/2", 17#x 4-1/2",12.6#,13Cr80 8774' 8655'/8488' '_ I ,,. 26. ACID, FRACTURE,CEMENT SQUEEZE,ETC. fi- 41Q11Y. ' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No 2 25 '��J14 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED soleFEB 0 *' tom= 8838' Set Whipstock 8833' 20 Bbls Class'G' 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No • Sidewall Core(s)Acquired? 0 Yes ® No 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 250.071. None Form 10-407 Revised 10/2012 v 7 - 7--/&//5 CONTIN ED l REVERSE S, Z �� Submit Original Only�� 2� � RROMs JAN - 6 2015 29. GEOLOGIC MARKERS(List all formations ani 'cers encounter 30. FORMATION TESTS NAME TVD Well Tested? u Yes ®No • Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25 071. Sadlerochit 8866' 8681' None Sadlerochit Zone 3 9082' 8881' Sadlerochit Zone 2C 9142' 8936' Sadlerochit Zone 2B 9207' 8997' Sadlerochit Zone 1B 9406' • 9184' Formation at Total Depth: • 31 List of Attachment Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Travis.Boltz@bp.com Travis Boltz,564-5750 Printed Name: Title Drilling Technologist Joe Lastu I / Signature. ,, 1 b Phone 564-4091 Date: i( f'�f �4• INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation 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 13: 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 28. 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 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. Form 10-407 Revised 10/2012 Submit Original Only 01 -15A, Well History (Pre-Rig Sidetrack) Date Summary 03/26/14 RAN IN W/WELLTEC MILLING TOOLS (3.804" O.D. MILL)AND MILLED XN NIPPLE AT 8751'W/NO ISSUES (POST MIC OF MILL=3.80"). RAN IN W/ELINE LOGGING TOOLS (PRESS/TEMP)AND PERFORMED SBHPS (TIED INTO SLB HSD GUN/CCL/GR DATED 22-SEPT-2007). WELL LEFT SHUT IN - NOTIFIED PAD OP OF WELL STATUS. FINAL T/I/0=1030/300/0. 03/27/14 TROUBLE SHOOT LEAKING VALVES. VALVES HELD. 6"CIW-SI-VALVES NOT HOLDING UPON ARRIVAL. OPEN SSV AND GREASE SV, WV, SSV. CLOSE SSV AND TURN WELL BACK OVER TO E- LINE. VALVES STILL WOULD NOT PASS. FLUSHED SSV&SWAB VALVE W/HYDRAULIC FLUID. REGREASED VALVES. PASSED. 03/28/14 RIH WITH BAKER GEN II 4.5"X 7"29#TT WHIPSTOCK. SET TOP OF WHIPSTOCK AT 8838'AT 163.2 DEG ROHS. CONFIRMED WHIPSTOCK SET AT SURFACE. FINAL T/I/O = 1100/300/0 PSI WELL LEFT SI ON DEPARTURE. 03/29/14 Attempt injectivity test, but pressured up to 3880psi. RIH and tag whipstock @ 8857' CTM, corr. depth to 8838'ELM and circ 1% KCL w/Safelube BU. Lay in 20bbls of 15.8ppg Class G cement. Hold 1419psi WHP for 30 min. RIH, drop 3/4" ball and contaminate cement down, up, down, and chased out of the hole at 80%. FP the well with 113 bbls of 60/40. Wash BOPs up/down/up to clear residual cementing debris. 04/03/14 T/I/O = SSV/300/200.Temp =SI. IA FL. (Eval glaciation). IA FL @ surface.ALP = 1740 psi,AL SI © casing valve. No glaciation noted in cellar, cellar has some snow/ice. SV, WV, SSV=C. MV= 0. IA& OA=OTG. 23:10. 04/04/14 T/I/0=100/300/185 SI Perform MITT(CTD) MITT to 2500 psi*"*PASSED*** Pumped 2.6 bbls DSL down TBG to achieve test pressure of 2500 psi. 15 min loss of 20 psi, 30 min loss of 11 psi,for total loss of 31 psi in 30 mins. Bleed TBG pressure to 400 psi. Valve positions=SV WV SSV closed MV open CVs OTG AL closed FWHP=400/300/180. 04/09/14 T/I/O = SSV/300/279. Temp =SI. MIT-OA to 1200 psi w/DSL***FAILED***/MIT-OA to 500 psi w/N2 ***PASSED***(Eval glaciation). Used .1 bbls DSL to increase OAP from 290 to 1200 psi. On 1st test, OA lost 430 psi in 15 min. FAIL. Established LLR of.25 gpm @ 1200 psi for 30 min, used 5.5 bbls of DSL. Bled off OAP to 200 psi. Increase OAP w/N2 from 200 psi to 500 psi. OA lost 6 psi in 1st 15 min and 3 psi in the 2nd min for a total loss of 9 psi in 30 min. H2S =0.00 ppm, LEL's=0%, CO=0.00 ppm, 02= 20.9%vol. Bled off OAP to 200 psi. Final WHP's =SSV/302/200. SV, WV, SSV= C. MV=0. IA&OA= OTG. NOVP. 08:30 hrs. 04/10/14 T/I/O = SSV/290/220.Temp =SI. LEL readings (eval glaciation). No AL. Heater in cellar. LEL's=0%. No ice or fluid in cellar. SV, WV,SSV= C. MV= 0. IA, OA= OTG. 0320. 04/18/14 T/I/O =288/312/231. Temp= SI. MIT- IA to 2500 psi PASSED (eval glaciation). AL closed ©casing valve. ALP =340 psi. Increased IAP using 4.7 bbls diesel to 2504 psi. MIT- IA lost 64 psi in the first 15, and lost 24 psi in the second 15 min,for a total loss of 88 psi in 30 min test. Bled ALP to 100 psi. Bled IAP to 100 psi (4.4 bbls). Tags hung on casing valve and wing valve. Job complete. See log for details. Final WHPs 290/100/230. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 11:10. 04/20/14 T/I/O = SSV/180/230. Temp= SI. LEL readings(Eval gas leak on 1-33 cellar).AL SI @ casing valve(290 psi).Tested for LEL's ©the 12, 3, 6, @ 9 o'clock positions-2"above the snow covering the cellar(0% LEL's detected). IAP increased 80 psi and the OAP remained unchanged since 4/18/14. SV, WV, SSV= C. MV=0. IA, OA= OTG. 1100 hrs. Page 1 of 6 01 -15A, Well History (Pre-Rig Sidetrack) Date Summary 04/21/14 T/I/O = SSV/200/230.Temp =SI. LEL readings (Eval gas leak on 1-33 cellar).AL SI @ casing valve (290 psi). LEL's @ the 12, 3, 6, @ 9 o'clock positions in cellar=0%. IAP increased 20 psi and the OAP unchanged overnight. SV, WV, SSV=C. MV=O. IA, OA=OTG. 07:50. 04/22/14 T/I/O = SSV/190/230.Temp =SI. LEL readings (Eval gas leak on 01-33 cellar).AL SI @ casing valve. ALP =340 psi. LEL's=0% in cellar. IAP decreased 10 psi and OAP unchanged overnight. SV, WV, SSV=C. MV=O. IA, OA=OTG. 0845. 04/23/14 T/I/O = SSV/200/230.Temp =SI. LEL readings. (Eval gas leak on 01-33 cellar).ALP=320 psi,AL SI @ casing valve. LELs =0%. IAP increased 10 psi overnight. SV, WV, SSV= C. MV=0. IA, OA= OTG. NOVP. 09:00 hrs. 04/24/14 T/I/O=SSV/200/230.Temp=Sl. LEL readings(Eval gas leak on 01-33 cellar).AL SI ©casing valve, ALP=340 psi. LELs=0%. IAP&OAP unchanged overnight. SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 0845. 04/25/14 T/I/O=SSV/200/230. Temp=SI. LEL readings. (Eval gas leak on 01-33 cellar).AL SI @ casing valve (320 psi). LELs=0%. No change in WHPs overnight. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 08:20. 04/26/14 T/I/0 =SSV/200/230. Temp= SI. LEL readings. (Eval gas leak on 01-33 cellar).ALP =300 psi,AL SI @ casing valve. LELs=0% in wellhouse and cellar. SV, WV, SSV= C. MV= 0. IA&OA=OTG. 09:25. 04/27/14 T/I/0 =SSV/200/230. Temp= SI. LELs readings. (Eval gas leak on 01-33 cellar).ALP =320 psi,AL SI @ casing valve. LELs=0%. IAP& OAP unchanged. SV, WV, SSV=C. MV= 0. IA, OA= OTG. NOVP. 09:15 hrs. 04/28/14 T/I/O =SSV/200/230. Temp= SI. LEL readings. (Eval gas leak on 01-33 cellar).ALP =300 psi,AL SI © casing valve. LELs=0% in wellhouse and cellar. SV, WV, SSV= C. MV= 0. IA& OA= OTG. 09:30. 04/29/14 T/I/O = SSV/200/230.Temp=SI. LEL readings. (Eval gas leak on 01-33 cellar). ALP =320 psi, AL SI @ casing valve. LELs= 0%. WHPs unchanged overnight. SV, WV, SSV= C. MV=0. IA, OA= OTG. NOVP. 08:45 hrs. 04/30/14 T/I/O= SSV/200/240. Temp=SI. LEL readings. (Eval gas leak on 01-33 cellar). ALP=340 psi,AL SI © casing valve. LELs =0%. TP& IAP unchanged, OAP increased 10 psi overnight. SV, WV, SSV=C. MV = 0. IA, OA= OTG. NOVP. 08:45 hrs. 05/01/14 T/I/O=SSV/200/240.Temp= SI. LEL readings. (Eval gas leak on 01-33 cellar).ALP =350 psi,AL SI @ casing valve. LELs=0%. TP, IAP&OAP unchanged. SV, WV, SSV=C. MV= 0. IA, OA=OTG. NOVP. 10:00. 05/02/14 T/I/O= SSV/200/250. Temp=SI. LEL readings. (Eval gas leak on 01-33 cellar). ALP=340 psi, AL SI @ casing valve. LELs=0%. No change in WHPs overnight. SV, WV, SSV=C. MV=0. IA&OA=OTG. 08:40. 05/03/14 T/I/O =SSV/200/250. Temp= SI. LEL readings. (Eval gas leak on 01-33 cellar).ALP =340 psi,AL SI @ casing valve. LELs=0%. No change in WHPs overnight. SV,WV, SSV= C. MV=0. IA, OA= OTG. NOVP. 08:45 hrs. Page 2 of 6 01 -15A, Well History (Pre-Rig Sidetrack) Date Summary 05/04/14 T/I/O=SSV/200/250. Temp=SI. LEL readings(Eval gas leak on 01-33 cellar). AL SI @ casing valve. ALP=340 psi. LELs=0%. WHPs unchanged over night. SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1340. 05/05/14 T/I/O = SSV/200/250. Temp= SI. LEL readings(Eval gas leak on 01-33 cellar).AL SI @ casing valve, ALP =340 psi. 0% LEL's. IAP& OAP unchanged overnight. SV, WV, SSV= C. MV=0. IA, OA=OTG. 15:20. 05/06/14 T/I/O=SSV/210/240.Temp=Sl. LEL readings(Eval gas leak on 01-33 cellar). AL SI @ casing valve. ALP=340 psi. LELs=0%. IAP increased 10 psi & OAP decreased 10 psi overnight. SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1440. 05/07/14 T/I/O= SSV/210/240. Temp= SI. LEL readings(Eval gas leak on 01-33 cellar).AL SI @ casing valve (340 psi). LEL's=0%.WHP's remain unchanged overnight. SV,WV, SSV=C. MV= 0. IA, OA=OTG. NOVP. 1550 hrs. 05/09/14 T/I/O=SSV/210/240. Temp=Sl. LEL readings(Eval gas leak on 01-33 cellar).AL SI @ casing valve. ALP=340 psi. LELs=0%. WHPs unchanged overnight. SV,WV, SSV=C. MV=O. IA&OA=OTG. 1330 hrs. 05/10/14 T/I/O= SSV/210/240. Temp=Sl. LEL readings(Eval gas leak on 01-33 cellar).AL is connected, SI @ casing valve. ALP=340 psi. No LEL readings in well house or cellar. SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. (1600 hrs). 05/11/14 T/I/O = SSV/210/240.Temp=SI. LEL readings (Eval gas leak in 01-33 cellar). AL is disconnected. LEL readings=0%. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1355 hrs. 05/12/14 T/I/O =SSV/210/250.Temp= SI. LEL readings (Eval gas leak in 01-33 cellar).AL is disconnected. LEL readings=0%. OAP increased 10 psi overnight. SV, WV, SSV=C. MV= 0. IA, OA=OTG. NOVP. 1030 hrs. 05/13/14 T/I/O=SSV/210/240.Temp=Sl. LEL readings(Eval gas leak on 01-33).AL spool is dropped. LEL readings=0%throughout well house and cellar. SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. (1600 hrs). 05/14/14 T/I/O=SSV/200/250.Temp= 112°. LEL readings(Eval gas leak on 01-33 cellar). No AL. 02=20.9%& LEL readings =0%. IAP decreased 10 psi, no change in OAP overnight. SV, WV&SSV=C. MV=0. IA &OA=OTG. NOVP. 09:30. 05/15/14 T/I/0= SSV/210/260. Temp= SI. LEL readings (Eval gas leak on 01-33 cellar). No AL. 02=20.9% LEL readings= 0%. IAP increased 10 psi &OAP increased 10 psi overnight. SV= C. WV, SSV, MV=0. IA, OA=OTG. 10:22. 05/15/14 T/I/O = SSV/210/240.Temp =SI. LEL readings (Eval gas leak on 01-33).AL disconnected. LEL=0%. SV, WV, SSV=C. MV= 0. IA, OA=OTG. 0500. 05/16/14 T/I/O = SSV/200/240.Temp=SI. LEL readings(eval gas leak on 01-33 cellar).AL spool dropped. LEL= 0%. SV, WV, SSV=Closed. MV=Open. IA&OA= OTG. 08:50. 05/17/14 T/I/O = SSV/200/240.Temp=SI. LEL readings (eval gas leak on 1-33 cellar).AL spool dropped. LEL's= 0%. SV,WV, SSV=Closed. MV=Open. IA&OA= OTG. NOVP. (12:30 hrs). Page 3 of 6 01 -15A, Well History (Pre-Rig Sidetrack) Date Summary 05/18/14 T/I/0 = SSV/200/240. Temp= SI. LEL readings(eval gas leak on 01-33 cellar). AL spool dropped. LEL= 0%. No change in WHP's in 2 days. SV, WV, SSV= Closed. MV= Open. IA& OA=OTG. 10:42. 05/19/14 T/I/O = SSV/200/260.Temp =SI. LEL readings (eval gas leak on 01-33 cellar).ALP @ 380 psi&SI @ IA casing valve. LEL=0%. No change in IAP, OAP increased 20 psi overnight. SV, WV, SSV= Closed. MV = Open. IA& OA= OTG. 09:10. 05/20/14 T/I/O = SSV/220/260. Temp= SI. LEL readings (eval gas leak on 01-33 cellar).ALP @ 380 psi&SI © IA casing valve. LEL=0%. IAP increased 20 psi, no change in OAP overnight. SV, WV, SSV=Closed. MV = Open. IA&OA=OTG. 09:34. 05/21/14 T/I/O=SSV/220/260. Temp=Sl.. LEL readings (Eval gas leak on 01-33 cellar).AL SI @ casing valve. WHPs unchanged over night. LEL's=0%. SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 0920. 05/22/14 T/I/O = SSV/220/240.Temp=SI. LEL readings (Eval gas leak on 01-33 cellar).AL SI @ CV.ALP= 160 psi. LEL's=0%. SV, WV, SSV= C. MV=0. IA, OA=OTG. 1530. 05/23/14 T/I/O = SSV/220/240.Temp=SI. LEL readings (Eval gas leak on 01-33 cellar).AL SI @ casing valve. ALP = 160 psi. LEL's=0%. SV, WV, SSV=C. MV= 0. IA, OA=OTG. 08:27. 05/25/14 T/I/O=SSV/220/240. Temp= SI. LEL Readings (Eval gas leak on 01-33 cellar).AL SI @ CV.ALP= 120 psi. LEL's=0%. SV, WV, SSV=C. MV=0. IA, OA=OTG. 1525. 05/26/14 T/I/O = SSV/220/250.Temp =SI. LEL Readings(Eval gas leak on 01-33 cellar).ALP @ 160 psi&SI @ IA casing valve.No change in IAO, OAP increased 10 psi overnight. LEL's=0%. SV,WV, SSV=C. MV = 0. IA, OA=OTG. NOVP 08:30. 05/27/14 T/I/O=SSV/220/240.Temp=Sl. LEL readings(Eval gas leak on 01-33 cellar).AL SI @ casing valve. ALP=100 psi. IAP unchanged, OAP decreased 10 psi over night. LEL's=0%. SV,WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1500. 05/28/14 T/I/O=SSV/220/240. Temp=Sl. LEL readings(Eval gas leak on 01-33 cellar).AL SI @ casing valve, ALP=100 psi. WHP's unchanged over night. LEL's=0%. SV, WV, SSV=C. MV=O. IA, OA=OTG. 08:30. 05/29/14 T/I/O= SSV/220/240.Temp=SI. LEL readings(Eval gas leak on 01-33).AL SI @ casing valve,ALP= 100 psi. WHP's unchanged. LEL's=0%. SV, WV, SSV= C. MV=0. IA, OA= OTG. NOVP. 1615. 05/30/14 T/I/O = SSV/220/240.Temp=SI. LEL readings(Eval gas leak on 01-33).AL SI @ casing valve,ALP= 100 psi. WHP's unchanged. LEL's=0%. SV, WV, SSV=C. MV=0. IA, OA= OTG. NOVP. 1950 hrs. 05/31/14 T/I/O = SSV/220/240.Temp =SI. LEL readings (Eval gas leak on 01-33).AL SI @ CV,ALP=80 psi. WHP's unchanged. LEL's=2%. LEL's increased 2% overnight. SV, WV, SSV= C. MV=0. IA, OA= OTG. 1730. 06/01/14 T/I/O = SSV/230/240 Temp= SI. LEL Readings. (Eval gas leak on 01-33 cellar).ALP =80 psi,AL SI @ casing valve. IAP increased 10 psi overnight, LELs =0%. SV, WV, SSV=C. MV= 0. IA, OA= OTG. NOVP. 15:45 hrs. Page 4 of 6 01 -15A, Well History (Pre-Rig Sidetrack) Date Summary 06/02/14 T/I/O = SSV/230/240 Temp= SI. LEL Readings. (Eval gas leak on 01-33 cellar).ALP =80 psi,AL SI @ casing valve. WHP's unchanged. LELs=0%. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1630. 06/03/14 T/I/O = SSV/230/230 Temp= SI. LEL Readings. (Eval gas leak on 01-33 cellar). AL SI @ CV.ALP=70 psi. OAP decreased 10 psi overnight.. LELs=0%. SV, WV, SSV=C. MV=0. IA, OA=OTG. 1315. 06/04/14 T/I/O = SSV/230/230. Temp= SI. LEL readings (eval gas leak on 01-33 cellar).AL SI @ casing valve (120 psi). LEL=0%. SV, WV, SSV=C. MV= 0. IA, OA=OTG. 1230. 06/05/14 T/1/O =SSV/230/230. Temp= SI. LEL readings (eval gas leak on 01-33 cellar). AL SI @ casing valve (120 psi). LEL=0%. SV, WV, SSV= C. MV=0. IA, OA= OTG. 1530. 06/06/14 T/I/O = SSV/230/230. Temp =SI. LEL readings (eval gas leak on 01-33 cellar).AL SI @ casing valve (120 psi). LEL=0%. SV, WV, SSV=C. MV= 0. IA, OA=OTG. 0800. 06/07/14 T/1/O=SSV/230/240. Temp= SI. LEL readings (eval gas leak on 01-33) once per day.AL SI @ casing, ALP= 110 psi. OAP increased 10 psi overnight. SV, WV,SSV=C. MV=0. IA, OA=OTG. NOVP 09:40 Hrs. 06/10/14 T/I/O = SSV/240/240.Temp=SI. LEL readings(Eval gas leak on 01-33).AL SI @ casing valve(120 psi). LEL's=0% in cellar. SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 16:15. 06/11/14 T/I/O = SSV/240/240.Temp =SI. LEL readings (Eval gas leak on 01-33 cellar).AL SI @ casing valve, ALP = 120 psi. LEL's=0%. Job complete. SV,WV, SSV= C. MV=0. IA, OA= OTG. NOVP 15:10 Hrs. 06/13/14 T/I/O = SSV/250/280.Temp=SI. LEL readings (Eval gas leak on 01-33 cellar).AL SI @ casing valve, ALP = 120 psi. LEL's=0%. SV, WV, SSV= Closed. MV=Open. IA&OA= OTG. NOVP. 19:35. 06/24/14 T/I/O =SSV/250/280.Temp=SI. LEL readings (eval gas leak on 01-33 cellar). AL SI @ casing valve, ALP = 1900 psi. LEL's=0%. SV,WV, SSV=C. MV=0. IA, OA=OTG. 03:05. 07/01/14 T/I/O = SSV/270/260 Temp= SI°. LEL readings(eval gas leak on 01-33 cellar). AL closed @ casing valve.ALP = 1670 psi. LEL=0%. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:10. 07/08/14 T/1/O=SSV/280/260, Temp=SI. PPPOT-T(PASS), pre tree replacement. PPPOT-T: Stung into test port (2100 psi), bled to 0 psi (gas). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 07/27/14 AOGCC suspended well inspection with Bob Noble. Site and well in good condition. Well sign indicates old name and bore, new sign will be installed during CTD in 4Q 2014. 10/05/14 T/1/O =980/440/240. Temp= SI.Tbg, IA, &OA FL's (pre MIT).AL SI @ casing valve, ALP =0+ psi.Tbg, IA, &OA FL @ surface. SV,WV, SSV= Closed. MV=Open. IA& OA=OTG. NOVP. 05:00. Page 5 of 6 01 -15A, Well History (Pre-Rig Sidetrack) Date Summary 10/05/14 T/I/O = 980/440/230. Temp= SI. MIT-T to 2500 psi *PASSED*, MIT-IA to 2500 psi*PASSED*, MIT-OA to 500 psi w/N2*PASSED*(CTD prep).AL SI @ CV,ALP =0 psi. T& IA FLs @ surface, OA cemented to surface. Used 1.2 bbls diesel to pressure TBG to 2525 psi,TP lost 14 psi in 1st 15 min and 4 psi in 2nd 15 min for a total loss of 18 psi in 30 min, bled TP to 200 psi (1.7 bbls). Used 4.9 bbls diesel to pressure IA to 2500 psi, IAP lost 63 psi in 1st 15 min and 24 psi in 2nd 15 min for a total loss of 87 psi in 30 min, bled IAP to 0 psi (6 bbls). Used N2 to pressure OA to 500 psi, OAP lost 20 psi in 1st 15 min and 11 psi in 2nd 15 min for a total loss of 31 psi in 30 min. Bled OAP to 0 psi (gas/fluid). Fluid packed tags hung. Job complete. Final WHPs = 150/5/20. Page 6 of 6 North America-ALASKA-BP Page 1r#? Operation SU011trarYi Report Common Well Name:01-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/6/2014 End Date:10/14/2014 X3-014RD-C:(2,200,999.00) Project.Prudhoe Bay Site:PB DS 01 Rig Name/No.:NORDIC 2 Spud Date/Time:1/27/1978 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292028700 Active datum:26.15 5/30/1996 11:09 @65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) - (usft) - 10/6/2014 00:00 02:00 2.00 MOB P PRE MOVE RIG OFF DS 18. 02:00 - 05:00 3.00 MOB P PRE MOVE RIG FROM DS 18 TO LPC ACCESS ROAD TO WEST DOCK.MOVE RIG TO DS 1. '05:00 - 06:00 1.00 MOB P PRE SPOT RIG ONTO BACKSIDE WELL ROW CENTER OF PAD. -CONTINUE MOVING RIG EQUIPMENT TO DS 1. -MOVE SAT OFFICE AND SPOT NEXT TO RIG -WAIT ON PRE-RIG WORK. 06:00 - 00:00 18.00 MOB N WAIT PRE WAIT ON PRE-RIG WORK FOR DS 01-15B. -CREW WORKING AS DIRECTED BY TOUR PUSHER 10/7/2014 00:00 - 12:00 12.00 MOB N WAIT PRE WAIT ON PRE-RIG WORK FOR DS 01-15B. CREW WORKING AS DIRECTED BY TOOLPUSHER -PERFORM MAINTENANCE AND CLEAN RIG CLEAN AND VARIOUS PAINTING AROUND THE RIG. CLEAN AND ASPHO DS CANTILEVER ROOM. 12:00 - 00:00 12.00 MOB N WAIT PRE WAIT ON PRE-RIG WORK FOR DS 01-15B. -CREW WORKING AS DIRECTED BY TOOLPUSHER -PERFORM MAINTENANCE AND CLEAN RIG CLEAN AND VARIOUS PAINTING AROUND THE RIG. PAINT DS CANTILEVER ROOM PAINT EXCLUSION ZONE IN BACK OF PIPE SHED. NEEDLE GUN PREP FRONT OF PIPE SHED FOR PAINT. 10/8/2014 00:00 22.30 22.50 MOB N WAIT PRE WAIT ON PRE-RIG WORK FOR DS 01-15B. CREW WORKING AS DIRECTED BY TOOLPUSHER -PERFORM MAINTENANCE AND CLEAN RIG PAINT PIPE SHED AND CHANGE ROOM FLOORS. PU 2-3/8"REEL AND RU IRON IN REEL HOUSE. HANG NEW 2"STAND PIPE HOSE. 22:30 - 00:00 1.50 MOB P PRE PAD PREP COMPLETE.MIRU. STAGE RIG MATS AROUND WELLSITE. -PREP RIG TO MOVE.ROLL TIRES TO WARM UP HYDRAULICS. -WSL OPEN WWT WITH PAD OPERATOR.IA= 0 PSI.OA=0 PSI. 10/9/2014 00:00 - 01:30 1.50 MOB P PRE PJSM AND PULL OVER WELL -WSL,NORDIC SUPERINTENDENT,NORDIC TOURPUSHER WITNESS OPERATION -VERIFY IA=0 PSI,OA=0 PSI -PULL OVER WELLAND SET RIG DOWN -ACCEPT RIG AT 01:30 ON 10/09/2014 Printed 10/20/2014 10:13:24AM North America-ALASKA-BP Page 2 47- Operation Summary Report Common Well Name:01-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/6/2014 End Date:10/14/2014 X3-014RD-C:(2,200,999.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:NORDIC 2 Spud Date/Time:1/27/1978 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292028700 Active datum:26:15 5/30/1996 11:09©65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 03:00 1.50 MOB P PRE RU WELLSITE AND SUPPORT EQUIPMENT -STAGE SATELLITE OFFICE,CUTTINGS BOX, TIGER TANK,PARTS TRAILER,WELDING SHOP -BERM SNOW AROUND CELLAR 03:00 - 03:30 0.50 MOB P PRE PERFORM H2S EVAC DRILL WITH AAR 03:30 - 05:00 1.50 BOPSUR P PRE PJSM AND ND TREE CAP -LEAK TIGHT TEST TREE VALVES PER WELLPLAN AND CRT-AK-10-45 ND TREE CAP 05:00 - 07:30 2.50 BOPSUR P PRE PJSM AND NU BOPS. NU SLB CROSSOVER AND INSTALL CT RISER. 07:30 - 10:30 3.00 BOPSUR P PRE PULL COIL ACROSS TO INJECTOR -HELD PJSM FOR PULLING COIL ACROSS -PULL COIL ACROSS TO INJECTOR -STABBED COIL INTO INJECTOR -TEST E-LINE CONNECTIVITY(OHM TEST) 10:30 - 11:00 0.50 BOPSUR P PRE PERFORM H2S RIG EVAC DRILL&CONDUCT AAR. 11:00 - 13:00 2.00 BOPSUR P PRE SHELL TEST BOP -FILL STACK WITH WATER -SHELL TEST 250 PSI/4500 PSI 13:00 - 18:30 5.50 BOPSUR P PRE 24 HR NOTICE FOR BOP TEST GIVEN 18:00 ON 10/07/2014 BOP TEST WAS WITNESSED BY AOGCC INSPECTOR MATTHEW HERRERA. PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER -LOWER 2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -VBR TESTED WITH BOTH 2-3/8"AND 3-1/2" TEST JOINT -UPPPER 2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -ANNULAR TESTED WITH BOTH 2-3/8"AND 3-1/2"TEST JOINT -TEST FULL OPENING SAFETY VALVE -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS -PERFORM DRAW DOWN TEST OF ACCUMULATOR -ALL TESTS WITNESS OR REVIEWED BY TOOLPUSHER,WSL,AND AOGCC INSPECTOR MATTHEW HERRERA -1 FAILURE:METHANE ALARM VISUAL INDICATOR ON RIG FLOOR.REPLACE BULB, PASS. 18:30 - 20:00 1.50 BOPSUR P PRE PJSM AND PRESS TEST INNER REEL VALVE, PACKOFFS,AND INJECTOR LUBRICATOR -PU INJECTOR AND BOOT E-LINE -GET ON WELL,LINE UP TO REVERSE CIRCULATE -PRESS TEST TO 250/3500 PSI FOR 5/5 MIN Printed 10/20/2014 10:13:24AM North America-ALASKA-BP Page 3 g7•J Operation Summary Report Common Well Name:01-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/6/2014 End Date:10/14/2014 X3-014RD-C:(2,200,999.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:NORDIC 2 Spud Date/Time:1/27/1978 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292028700 Active datum:26:15 5/30/1996 11:09 @65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 20:30 0.50 BOPSUR P PRE OPEN INNER REEL VALVE. REVERSE CIRC TO PUMP BACK SLACK POP OFF WELL AND STAND BACK INJECTOR. 20:30 - 23:30 3.00 BOPSUR P PRE PJSM AND PRESS TEST BOP LOCKDOWNS -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -LOWER 2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -VBR TESTED WITH BOTH 2-3/8"AND 3-1/2" TEST JOINT -UPPPER 2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -BLIND RAMS TESTED ON EMPTY HOLE 23:30 - 00:00 0.50 BOPSUR P PRE PJSM AND CUT 30'COIL. 10/10/2014 00:00 - 01:00 1.00 BOPSUR P PRE CONTINUE CUT 30'COIL INSTALL SLB CTC.PULL TEST SAME TO 35K#. '01:00 02:00 1.00 BOPSUR P PRE PJSM AND HEAD UP BHI -INSTALL UQC W/O CHECKS -PRESS TEST SAME TO 250/3500 PSI 02:00 - 03:30 1.50 BOPSUR P PRE PJSM AND FLOW CHECK WELL -INSTALL NIGHT CAP.PRESS TEST SAME TO 250/3500 PSI. OPEN WELL TO CLOSED CHOKE.BUILD 75 PSI. -BLEED OFF PRESSURE TO TIGER TANK CLOSE IN CHOKE. -FLOW CHECK FOR 30 MIN.NO PRESSURE BUILD. -VALVE SHOP CREW TIGHTEN TREE BOLTS DURING FLOW CHECK. 03:30 - 05:00 1.50 STWHIP P WEXIT PJSM AND PU MILLING BHA -PU BTT MOTOR,MILL,AND STRING REAMER -PU 1 JT 2-3/8"PH6 -PU 3"COILTRACK -STAB INJECTOR AND PRESS TEST QTS 05:00 - 05:30 0.50 STWHIP P WEXIT CIRCULATE COIL VOLUME FOWARD AT 2.82 BPM IN/OUT THROUGH OPEN EDC. TAKE RETURNS TO THE TIGER TANK 05:30 - 08:15 2.75 STWHIP P WEXIT RIH WITH MILLING ASSEMBLY -70'/MIN WITH 1.55/1.93 BPM IN/OUT -TAKE RETURNS TO TIGER TANK -LOG GR TIE-IN W/-24'CORRECTION 08:15 - 09:30 1.25 STWHIP P WEXIT DISPLACE WELL FROM 8.4 PPG KCL TO 9.5 PPG POWERPRO. -2.31/2.28 BPM IN/OUT -1300 PSI CIRC PRESSURE -TAKE RETURNS TO CUTTINGS BOX -RIH W/MILLING BHA F/8800'TO 8838'MD. -TAG TOWS AT 8838'W/PUMPS ON. -PU AND TAG TOWS AT 8838.7'MD W/PUMPS OFF. 09:30 - 18:00 8.50 STWHIP P WEXIT MILL CEMENT F/8838'TO PINCH POINT AT 5i. - 8842'MD. CONTINUE TO MILL WINDOW F/8842'TO ui-fib 8846.0'MD. -DHWOB:0.5-1.0 K-LBS -BPM IN/OUT:2.75/2.74 -MW IN/OUT:9.42/9.39 PPG -CIRC PRESSURE:2650 PSI Printed 10/20/2014 10:13:24AM North America-ALASKA-BP Page 4i.7 Operation Summary Report Common Well Name:01-15 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:10/6/2014 End Date:10/14/2014 X3-014RD-C:(2,200,999.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:NORDIC 2 Spud Date/Time:1/27/1978 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292028700 Active datum:26:15 5/30/1996 11:09 @65.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 22:00 4.00 STWHIP P WEXIT MILL 3.80"WINDOW F/8,846.0'-8,849.6'MD. -BPM IN/OUT:2.75/2.75 -CIRC PSI:2450 -ECD:10.10 PPG -MW IN/OUT:9.51 PPG/9.45 PPG -IA/OA/PVT:210 PSI/76 PSI/396 BBLS -WOB:0.5-2.0K# -NO STALLS,NO PICK UPS -FIRST SEE LIMESTONE IN SAMPLE FROM 8,846.5'MD 22:00 - 00:00 2.00 STWHIP P WEXIT MILL RATHOLE F/8,850'-8,852'MD -BPM IN/OUT:2.75/2.75 CIRC PSI:2350 -ECD:10.10 PPG -MW IN/OUT:9.48 PPG/9.44 PPG -IA/OA/PVT:225 PSI/76 PSI/396 BBLS -WOB:0.5-1.0K# -TIME MILL FIRST FOOT TO GET STRING REAMER THROUGH WINDOW 10/11/2014 00:00 - 03:00 3.00 STWHIP P WEXIT MILL RATHOLE F/8,852'-8,860'MD -BPM IN/OUT:2.75/2.75 -CIRC PSI:2475 -ECD:10.10 PPG MW IN/OUT:9.48 PPG/9.44 PPG IA/OA/PVT:245 PSI/76 PSI/394 BBLS -WOB:2.0-3.0K# PUMP 20 BBL HI-VIS SWEEP FROM 8,860'MD 03:00 - 04:30 1.50 STWHIP P WEXIT DRESS WINDOW -REAM DOWN AND UP 3X AT 1'/MIN -DRY DRIFT WINDOW,WINDOW SMOOTH 04:30 - 05:00 0.50 STWHIP P WEXIT POOH WITH MILLING ASSEMBLY -FLOW CHECK OFF BOTTOM,NO FLOW -80'/MIN WITH 2.95/2.50 BPM IN/OUT 05:00 - 07:45 2.75 STWHIP N SFAL 7,015.00 WEXIT WHILE POOH AT 7015'MD,HORSE'S HEAD ON REEL STOP TRACKING TO LEFT ON LEVELWIND AND MAKES GRINDING NOISE. STOP AND REPLACE THE BRASS PAWL ON THE LEVELWIND.ATTEMPT TO CONTINUE POOH,ISSUE NOT RESOLVED.CALL OUT CTS MECHANIC. LEVEL WIND TRACK WAS SCORED DUE TO WEDGED BRASS PAWL BUFFED OUT LEVEL WIND TRACK. TESTED- OK. 07:45 - 09:00 1.25 STWHIP P WEXIT POOH WITH MILLING ASSEMBLY -FLOW CHECK AT 500',NO FLOW -80'/MIN WITH 1.45/0.84 BPM IN/OUT -TAG UP. -POP OFF AND STAND BACK INJECTOR. 09:00 - 09:15 0.25 STWHIP P WEXIT PJSM.LID MILLING BHA. -GAUGE MILLS. -WINDOW MILL:3.80"GO/3.79"NO-GO -STRING MILL:3.80"GO 09:15 - 09:30 0.25 DRILL P PROD1 PJSM.M/U 4-1/4"BUILD BHA. -PU 2-7/8"ULS MOTOR. -MU USED 3.75"X 4-1/4"HYC SRH3211 M-C3 BIT SN:A172729\ -RIH W/MOTOR AND BIT. -M/U MWD/LWD STRING TO TOP OF MOTOR, AND RIH. 09:30 - 12:30 3.00 DRILL P PROD1 STAB COIL.GET ON WELL.TEST QTS 250/3500 PSI.RIH W/4-1/4"BUILD BHA F/71' TO 8860'MD. -90'/MIN WITH 0.79/1.24 BPM IN/OUT. -LOG TIE-IN W/-22'CORRECTION Printed 10/20/2014 10:13:24AM TREE= 5-1/8"GRAY 0/E3LFEAD= GRAY 1 -15A St 'NOTES: ***CHROME TUBING*** ACTUATOR= OTIS-BB OKB.ELEV= 73' BF.ELV= NA 1 V ►1 11 KOP- 8797' •CONDUCTOR. ? 1111 111 2164' H 5-1/2"HE'S X NP,D=4.562" Max Angle= 24"@ 8797' — H 1111 1 11� J Datum MD= 9065 —#, 1111 �1� Datum TVD= 8800'SS D= " 1 �7% 2234' 95/8"ES CBNB�ITS2 14 4.4 2329' —9-5/8"FOC 9-5/8"TIEBACK CSG,47#, H 2241' , L-80 HYD 563,D=8.861' 9-5/8"BOWEN PATCH,D=10.750" H 2243' GAS LFT MANDRELS ST P.O TVD DEV TYPE VLV LATCH FORT DATE 13-3/8'CSG,72#,N-80 BTRS,D=12.347' —1 2693' 4 3393 3392 1 MAG DMY RK 0 11/16/13 Minimum ID =3.725" 8751' 3 5589 5586 10 MMG DMY RK ' 0 11/16/13 2 7157 7068 20 MAG CMY RK ' 0 11/16/13 4-1/2" HES XN NIPPLE I 1 8553 8394 23 KBG2 MY BK ' 0 11/16/13 5-1/2"TBG, 17#,13CR-80 VAM TOP, 7894' " 1 7894' —15-1/2"X 4-1/2"XO,D=3.958' .0232 bpf,D=4.892" L—I 7910' _$9-5/8"X 7"JM TIEBACK PKR,D=6.187" * f____. [ 7926' —9-5/8"X 7"BKR TEBAC K SLV,D=7.50" 0 7936' H 9-5/8"X 7"BKR PKR,D=6.313" TOP OF CMT FLOG H 8105' a R.D 7961' —{9-5/8"X 7"BKR HND HG =6.125" 9-5/8'BRDGE PLUG 8249' ',/ 9-5/8'FLOUT WINDOW(01-15A) 8105'-8150' 1 9-5/8"CSG,47#,RS-9504.80 -r 9538' $0/$0 BTRS,D=8.681' 11/4 ,�0°00:�' 8634' —4-1/2"HES X NP,D=3.813" WOO '�i* i 8665' r7"X4-1/2'BKR S-3PKR,D=3.875' 1; 8689'_—{41/2"HES X NP,D=3.813" •` 1i 8751" 14-12'HES XN NP, MLLED TO 3.80"(03/26/14) 4-1/2"TBG,12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958' —I 8774' 8774' H4-1/2"WLEG,D=3.958' TOP OF CEMENT(03/29/14) —1 8833' 8768' H EIND LOGGED(09/15/07) 4-1/2"X 7"BKR FLOW-1142U W1-PSTOCK(3/28/14) 8838' 8819' 1--17"MARKER JOn1T 4.. PERFORATION SUIVMARY REF LOG: ACOUSTLOG ON 01/22/96 ++ . *Yr •r.> 9217' �t'STTCWCCxutT(12110/12) ANGLE AT TOP PERE: 21' @ 9211' 'y�. Note:Refer to Production DB for historical pert \ data ; 9221' y 7"POSISET PLUG SIZE SPF .ITERVAL Opn/Sgz SHOT SQZ (12/09/12) 3-3/8" 6 9211-9216 S 01/01/13 03/28/14 3-3/8' 6 9226-9229 C 12/17/02 2-7/8' 6 9226-9236 S 02/20/96 02/24/02 - ! 9262 FLL-N7E S RWO 3-3/8" 4 9229-9236 C 03/26/02 (08/03/07) 3--3/8" 6 9242-9246 S 03/26/96 02/24/02 FWD 9323' 3-3/8" 6 9268-9270 S 03/26/96 02/24/02robAlkiAS� • 7'LNF2 29#,NT 80S NSOC,.0371 bpf,D=6.184' 9420' {i► DATE REV BY COMENTS DATE REV BY COMVEN S PRUDHOE BAY IK 02/18/78 ROWAN 35 INTIAL COM PLET1ON 03/29/14 GTW/PJC SET WHIPSTOCK(328/14) WELL: 01-15A 02120/96 D16 RIG SIDETRACK(01-15A) 03/30/14 TTRI PJC CMT WHIPSTOCK(3/29/14) PERMIT Na:'1952100 08/03/07 NOES RWO 04/02/14 11R/PJC CMT CORRECTIONS AR No: 50-029-20287-01 11/25/13 RKT/JM3 GLV CIO(11/16/13) 04/07/14 PJC WS CORRECTION SEC 8,T10N,R15E 427'FNL 8 690'FWL 03/27/14 JCMPJC MLL XN N'(3/26/14) 03/27/14 PJC REFORMAT FOR PROPOSAL BP Exploration(Alaska) XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ! ¢.~"'~,~/('~ File Number of Well History File / PAGES TO DELETE Complete RESCAN Color items - Pages' Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by ianna TO RE-SCAN Vincent Nathan Lowell Date'.~ ~ /,, Oc~_ lsl g-'/jl/ ~ Notes: Re-Scanned by: Be,~edy Dianna Vincent Nathan Lowell Date: Is~ • ' RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMMON JAN 1 8 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon L] Repair Well U Plug Perforations U Perforate U Other LJ Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc I Development IS Exploratory III - 195 -210 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20287 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028329 PBU 01 -15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): e , To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9420 feet Plugs measured 9217 feet true vertical 9196 feet Junk measured None feet Effective Depth measured 9217 feet Packer measured See Attachment feet true vertical 9006.28 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 39 - 119 39 - 119 1530 520 Surface 2655 13 -3/8" 72# N -80 38 - 2693 38 - 2692.46 4930 2670 Intermediate None None None None None None Production 8068 9 -5/8" 47# N -80 37 - 8105 37 - 7970.42 6870 4760 Liner 1495 7" 29# NT8OS 7925 - 9420 7797.38 - 9196.95 8160 7020 Perforation depth Measured depth 9211 - 9216 feet 9226 - 9229 feet 9229 - 9236 feet 9242 - 9246 feet 9268 - 9270 feet True Vertical depth 9000.67 - 9005.34 feet 9014.69 - 9017.5 feet 9017.5 - 9024.05 feet 9029.67 - 9033.41 feet 9054.03 - 9055.9 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: SCANNED LIAR 0 2013 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 97 0 ' . . - "1300 11 215 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development p Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil-' 131 Gas ❑ WDSPIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUd J 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays ( bp.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatur A / _ _�. /A._ Phone 564 -4035 Date 1/16/2013 RBDMS 2 8 201 1/L,- , 2/J 7 Form 10-404 Revised 10/2012 Submit Original Only . • Daily Report of Well Operations ADL0028329 ACTIVITYDATE I SUMMARY ** *WELL SHUT IN ON ARRIVAL * * *(ELINE PLUG AND CEMENT) INITIAL T /I /O = 180/1440/200 RAN IN & SET 7" SLB POSISET PLUG, TOP OF PLUG SET @ 9221' (USED SLB CNL LOG DATED 08/FEB/2002 & SLB DEPTH DETERM LOG DATED 22 /SEPT /2007 FOR TIE IN) SLB CNL LOG DOESN'T HAVE THE RIGHT COLLARS IN TBG AREA SINCE TBG WAS REPLACED ON 8/2007 AND CNL LOG WAS RAN ON 2002, BUT BOTH LOGS ARE ON DEPTH TO GAMMA RAY LAYED DOWN EQUIPMENT FOR THE NIGHT AND WILL RETURN IN AM TO DUMP CEMENT 12/9/2012 ** *JOB CONTINUED ON 10- DEC -12 * ** ** *JOB CONTINUED FROM 9- DEC -12 * ** ARRIVE BACK ON LOCATION & RIG UP ELINE UNIT MADE TWO POSITIVE DISPLACEMENT DUMP BAILER RUNS DUMPING 4' CEMENT ON TOP OF POSISET PLUG (a, 9221', PUTTING EST TOP OF CEMENT @ 9217' FINIAL T /I /O = 240/1440/200 12/10/2012 ** *JOB COMPLETE * ** ** *WELL SHUT IN ON ARRIVAL * ** (perforating) 2' 1 -7/8" STEM, 3.50" CENT,4 -1/2" TEL, 3.25" LIB, LOC TT @ 8759' SLM, 8768' ELMD(9' CORRECTION) TA G CEMENT @ 9233' SLM, 9242' ELMD 12/16/2012 ** *JOB COMPLETE, WELL TURNED OVER TO DSO * ** ** *WELL SHUT IN UPON ARRIVAL * ** INITIAL T /I /O = 200/1450/200 PSI INITIAL VALVE POSITIONS: WING /SWAB /SSV = CLOSED, MASTERNALVES TO CASING = OPEN RIGGING UP 12/31/2012 ** *JOB CONTINUED ON 1- JAN - 2013 * ** ** *JOB CONTINUED FROM 31 -DEC- 2012 * ** RIH WITH GR /CCL/5'x3.375" PJ HMX GUN. OAL= 16' /OAW= 275 # /MAX OD= 3.66" (GUN SWELL) CCL TO TOP SHOT = 4.17', CCL STOP DEPTH = 9206.83' PERFORATED INTERVAL = 9211' - 9216', GOOD INDICATION OF GUNS FIRING CORRELATED TO SLB CNL LOG DATED 8 -FEB -2002. PERFORM JEWELRY LOG TO GLM #1 AT 8552' TREE CAP ON AND TESTED, SSV CLOSED, WING CLOSED, SWAB CLOSED. FINAL T /I /0= 215/1450/200 1/1/2013 ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 4 DIESEL 4 TOTAL • • • Packers and SSV's Attachment ADL0028329 SW Name Type MD TVD Depscription 01 -15A PACKER 7910 7717.81 7" Baker JM Packer 01 -15A PACKER 7935 7741.76 7" Baker Packer 01 -15A PACKER 8655 8423.11 4 -1/2" Baker S -3 Perm Packer Casing / Tubing Attachment ADL0028329 Casing Length Size M D TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 39 - 119 39 - 119 1530 520 LINER 1495 7" 29# NT8OS 7925 - 9420 7797.38 - 9196.95 8160 7020 PRODUCTION 8068 9 -5/8" 47# N -80 37 - 8105 37 - 7970.42 6870 4760 SURFACE 2655 13 -3/8" 72# N -80 38 - 2693 38 - 2692.46 4930 2670 TUBING 7858 5 -1/2" 17# 13Cr80 36 - 7894 36 - 7767.68 7740 6280 TUBING 880 4 -1/2" 12.6# 13Cr80 7894 - 8774 7767.68 - 8597.33 8430 7500 • • 1 ice= aw • V4BLt6AD= qW • S� NOTES: ** *5 -1 CHROME TUBING*** ACTUATOR= OTIS 01 -15A KB. ELEV = 65.2 BF. e-EV = NA I* * M Angle = 24° , 5600' '4 1 /' 1-1_-1/2" 2164' S u2• x NP, D = 4.562" 1 1G ►1 I I flit= AO= 9065 11 4/ 2234 H9-5/8" ES CEMENTER lit= TVD = 8800' SS 1 * ''i / 9-5/8" CSG, 47 #, L-80 1-K D 563 XO TO —I 2244' I ♦ r • I 23211 H9-5/8" FOC I L -80 BTC-M 2458• H9-5/8" FOC I 19 -5/8" CSG, 47#, L -80 BTC -M, D = 8.681" H 2243' GAS LFT MANDRELS ST ND ND DEV TYPE VLV LATCH PORT DATE 1 13 -3/8" CSG, 72#, N-80 BTRS, D= 12.347" H 2593' 4 3393 3392 1 MMG DONE RK ' 16 12/10/10 3 5589 5586 10 144G DONE RK ' 16 12/10/10 5-1/2" TBG, 17#, 13CR-80 VAM TOP —1 7894' 2 7157 7068 20 WAG DONE RK ' 16 12/10/10 0232 bpf, D = 4.892' 1 8553 8394 23 KBG2 SO BK ' 24 12/10/10 \ i I 7894' (—f 5-1/2" X 4-1/2" XO, D= 3.958" I 7910' H9-5/8" X 7" JM TEBACK PKR, D = 6.187" I Minimum ID = 3.726" @ 8761' -I 7925 H9 -5/6" X 7" BKR TESACK SLV, D = 7.500" 1 4 -1/2" HES XN NIPPLE j 7936' H9 -5/8" X 7" BKR PKR, ID= 6.313" I 7951' H9-5/8" X 7" BKR RAC HGR, ID= 6.125" I I 9-5/8" MLLOUT WINDOW (01 -16A) 8100' - 8150' I I TOP OF CMT PLUG H 8105 1 19 -5/8" BRIDGE PLUG H 8249' ( ♦ ��i1 1 1 \ . 8634' H4 -1/2" FES X NP, D= 3.813" I ♦•11/1 111111 � ' 8656' 7" X 4-12" BKR S-3 PKR, D = 3.875" 11111111111 4 111111141 4 BT CSG, RS, D = 8.681 \, RS-95%1-80 9538' N4::•••••••••••••••!.. li NSW H4-1/2" FE;S X MP D = 3.813" 1 A \ 4 8751' H4 -1/2" FMS XN NP, D= 3.725" 1 ■ AI Alla ��•• • ` 877 H4-12" VVLEG, D = 3.958" 1 .••. 'n n. •••• ■ 1 8768' Haw LOGGED (09 /15/07) 1 • •••• 8819 H7" MARKER JotNT FE FORATION SUMARY 9217* H EST TOP OF CMT (12/10112) I FIEF LOG: ACXXJSTLOG ON 0122/96 OA* � i 9221' 7" POSISET PLUG ANGLE AT TOP PrE F: 21 ° a 9211' � * J (12/09/12) Note: Refer to Roduction DB for historical pert data 4-1/2" TBG, 12.6#, —I 8774 L ' 13CR -80 VAM TOP, 3 3/ " 9211 9216 O 01/01/13 .0152 bpf, D= 3.958" = I 9262 I— F LL- NIES RWO -38 6 p��6.� 1 C'�#4l (08103/07) 2 -7/8" 6 9226 - 9236 S 02/20196 0224/02 PBTD 8323' h �l�k 3-3/8" 4 9229 -9236 C 03126/02 _ 3-3/8" 6 9242 - 9246 S 03/26/96 0224/02 `i111111111i4 3-3/8" 6 9268 9270 S 0326196 0224/02 7" LNR, 29#, NT-80S NSCC, --I 9420' )1111;∎ .0371 bpf, 13= 6.184" 1 i DATE REV BY COM ENTS DATE REV BY COAMENTS PRUDHOE BAY UNIT 02/18/78 ROWAN 35 ORIGINAL COMPLETION 05/10/11 K B / P J C FULL ROCK SO 4 (5/7/11) MIL: 01 -15A 01/26/96 D16 RIG SIDETRACK (01 -15A) 05/16/11 JGB/ PJC SET ROCK SCREEN (05/11/11) PERMIT No: 1 952100 08/03/07 N4E3 F81VO 11/05/12 GJB/JNU PILL ROCK SCREEN (11/01/12) AR No: 50-029- 20287 -01 12/11/10 LT /PJC PILL ROCK SCRN (11/25/10). 12/14/12 JCINJND SET POSISET & CMT (12/09. 10/12) SEC 8, T1ON, R15E 427' FM_. & 690' ANL 12/12/10 WE ./PJC SET ROCK SC $ 1 (12/12/10) 01/16/13 RWIiMJND ADPERFS (01/01/13) 12/12/10 WEC/PJC GLV C/O (12/10/01) BP Bcptoratioe (Alaska) OPERABLE: 01-15A (PTD #2100) Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] I Sent: Thursday, February 26, 2009 2:26 PM ~ Q " i ~' ~~~ To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, EOC Specialists; Seltenright, Ana Maria; Holt, Ryan P (ASRC); GPB, Wells Opt Eng; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: OPERABLE: 01-15A (PTD #1952100) Tubing Integrity Restored Well 01-15A (PTD #1952100) passed an MITIA to 3000 psi on 02/26/09 after dummy gas lift valves were set. The passing test confirms that tubing Integrity has been restored. Thus, the well has been reclassified as Operable and may be put on production when convenient. Please take caution when putting the well online as the IA is now liquid packed. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~; ~, ~~ <~ ~~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, February 15, 2009 8:18 PM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; GPB, EOC Specialists; Seltenright, Ana Maria; Holt, Ryan P (ASRC); GPB, Wells Opt Eng; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Ol-15A (PTD #1952100) TxIA communication All, Well 01-15A (PTD #1952100) has been confirmed to have sustained casing pressure due to TxIA communication. The well failed a TIFL on 02/15/09 when the wellhead pressure were tubing/IA/OA equal to 2160/2440/140. The caused of the TxIA communication is thought to be hydrates across a gas lift valve. The well has been reclassified as Under Evaluation and may be placed on production. The plan forward is: 1. Operations: Place the well on production 2. DND: Repeat TIFL to clear possible hydrates and confirm TxIA communication 3. Well Integrity Engineer: Evaluate TIFL results for possible gas lift valve change out if needed A TIO plot and wellbore schematic have been included for reference. 4/16/2009 OPERABLE: Ol-15A (PTD #12100) Tubing Integrity Restored ~ Page 2 of 2 Please let me know if there are any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/16/2009 PBU 01-15A PTD #1952100 2/15/2009 TIO Pressures 4.0001 ..... .......................... ........................................ 3,000 • -~- Tbg ^ ~ ^ IA 2,000 r --~- OA - __ -- - ~~ ~~--~f~~ ~^ a~wse OOA ',,~ OODA 1,000 ~ ~ Dn ~- - 12106/0$ 12113!0$ 12iZ0i0$ 1212710$ 01!03109 01110!09 01117!09 01i2d/09 O1f31109 02!07109 02i14f09 i TREE = CIW WELLHEAD = CNV ACTUATOR= OTIS KB. ELEV - 65.2' BF. ELEV...- NA KOP = 5600' Max Angle = 24° @ 8797 Datum MD = 9065' Datum TVD = 8800' SS J MD DFT SA NOTES: ***5-1 /2" CHROME TUBING'`** 01-15A 9-5/8" CSG, 47#, L-80 HYD 563, ID = 8.681" I-1 2224' ~9-5/8" BOWEN EXT CSG PATCH ~~ 2244• 13-3/8" CSG, 72#, N-80, ID = 12.347" 2693' 5-1/2" TBG, 17#, 13CR-80 VAM TOP, 7894' .0232 bpf, ID = 4.892" 2164' -~ 5-1 /2" HES X NIP, ID = 4.562" 2234' 9-5/8" ES CEMENTER, ID = 8.619" 2329' 9-5/8" FOC 2458' 9-518" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3393 3392 1 MMG DOME RK 16 12/31 /07 3 5589 5586 10 MMG DOME RK 16 12/31/07 2 7157 7068 20 MMG DOME RK 16 12/31 /07 1 8553 8394 23 KBG2 SO BK 24 12/31/07 Minimum ID = 3.725" @ 8751' 7894' 5-1/2" X 4-1/2" XO, ID = 3.958" 4-1 /2" HES XN NIPPLE 7910' 9-5/8" X 7" JM TIEBACK PKR, ID = 6.187" 7925' 9-5/8" X 7" BKR TIEBACK SLV, ID = 7.500" 7935' 9-5/8" X 7" BKR PKR, ID = 6.313" 7951' 9-5/8" X 7" BKR HMC HGR, ID = 6.125" 9-5/8" CSG MILLOUT WINDOW 9-5/8" CSG, 47#, RS-95\N-80 9538' BTRS, ID = 8.681" 8100' - 8150' (SECTION MILL) 8634' 4-112" HES X NIP, ID = 3.813" 8655' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8689' I~ 4-1 /2" HES X NIP, ID = 3.813" 8751' 1~4-1/2" HES XN NIP, ID = 3.725" PERFORATION SUMMARY REF LOG: ACOUSTILOG ON 01/22/96 A NGLE AT TOP PERF: 20° @ 9226' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9226 - 9229 O 12/17/02 2-7/8" 6 9226 - 9236 O 10/18/07 3-3/8" 4 9229 - 9236 O 03/26/02 3-3/8" 6 9242 - 9246 S 02/24/02 3-318" 6 9268 - 9270 S 02/24/02 8774' ~4-1/2" WLEG, ID= 3.958" \ 8768' ELMD LOGGED (09/15/07) 4-112" TBG, 12.6#, 8774' 8819' 7" MARKER JOINT 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 9262 FILL (08103/07 RWO) ? 9323' PBTD 7" LNR, 29#, NT-80S NSCC, 9420' .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 02/18/78 R35 ORIGINAL COMPLETION 02!06/09 ?/JMD DRLG DRAFTCORRECTIONS 01/26/96 D16 RIG SIDETRACK(01-15A) 08/03!07 N4ES RWO 10/18/07 BSE/PJC ELMD LOGGED (09/15/07) 10/20/07 JMF/PJC RE-PEKE 01/15/08 DAV/PJC GLV C/O (12/31!07) PRUDHOE BAY UNfI- WELL: 01-15A PERMfT No: 1952100 API No: 50-029-20287-01 SEC 8, T10N, R15E 42T FNL & 690' FWL BP Exploration (Alaska) ~. ~~~ ~~. ~~ STATE OF ALASKA ~"~~~ ~. F ~ ~, i ~.OD~ ALASKA OIL AND GAS CONSERVATION COMNRSSION ~~ REPORT OF SUNDRY WELL OPERATfOIX~,a Oil & Gas Cons. C0~'~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development '' EXploratory ~ 195-2100 3. Address: P.O. Box 196612 Stratigraphic ~' ServiCe (~~ 6. API Number: Anchorage, AK 99519-6612 50-029-20287-01-00 7. KB Elevation (ft): 9. Well Name and Number: 65.2 KB - PBU 01-15A ' 8. Property Designation: 10. Field/Pool(s): ADLO-028329 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9420 r feet Plugs (measured) None true vertical 9196.95 feet Junk (measured) None Effective Depth measured 9323 feet true vertical 9106 feet Casing Length Size MD TVD Burst Collapse Conductor 119' 20" Surface - 119' Surface - 119' 1530 520 Surface 2693' 13-3/8" 72# n-80 Surface - 2693' Surface - 2692' 4930 2670 Intermediate 8100' 9-5/8" 47# n-80 Surface - 9538' Surface - 9308' 6870 4760 Liner 1510' 7" 29# nt-80s 7910' - 9420' 7783' - 9197' 8160 7020 Perforation depth: Measured depth: O 9226 - 9229 S 9226 - 9236 O 9229 - 9236 S 9242 - 9246 S 9268 - 9270 True Vertical depth: 9015 - 9018 9015 - 9024 9018 - 9024 9030 - 9033 9054 - 9056 Tubing: (size, grade, and measured depth) 5-1/2" 17# 13CR80 SURFACE - 7896' 4-1/2" 12.6# 13CR80 7894' - 8772' Packers and SSSV (type and measured depth) 7" BKR JM TIEBACK PKR 7910 7" BAKER PKR 7933 4-1/2" BKR S-3 PKR 8655 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~~~, MAR ~ "~ 2008 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 332 7129 251 192 Subsequent to operation: 388 10905 667 205 14. Attachments: 15. Well Class after oroposed work' Copies of Logs and Surveys Run Exploratory ~ Development Service Vim' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~`i Gas WAG ~' GINJ ' WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 2/27/2008 i~l~~A~ ~~-~ BAR 71QOE Form 10-404 Re 'sed 04/2006 Submit Original Only • 01-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY 2/13/2008 CTU #6 w/ 1.75" OD CT. Objective: acid stimulation. Daylight coil. MIRU CTU #6. Perform weekly BOPE test. Unstab, cap BOPs and PT, and standby until ;..tomorrow. Job continued on WSR 02/14/08. 2/13/2008 ASRC Unit #3, S/B for CTU (daylight crew),'`*job in progress** 2/14/2008 T/I/0= 1526/700/400 Assist Coil #6 -pump as directed- Pumped 10 bbls neat, ;100 bbls diesel, 248 bbls crude with a 15 bbl neat cap down the IA. Final WHP's= 2410/1700/470 2/14/2008!!CTU #6 w/ 1.75" OD CT. Daylight coil. Continued from WSR 02/13/08. ``Objective: acid stimulation. RIH w/ 2.0" OD JSN. Tag TD at 9255' ctmd. Pick up "'-into tubing tail and have LRS load inner annulus with crude/diesel. Begin loading ';wellbore with 3% ammonium chloride + F103. Develop leak in choke trailer, with ;.approximately 30 gallons of ammonium chloride released outside of secondary `.containment. Call to have choke trailer emptied and replaced. Pull to surface and ;.freeze protect well with 60/40 methanol/water. Unstab, cap and PT BOPs, and ''standby until tomorrow. Continued on WSR 02/15/08. Note: During well kill, IAP was responsive to changes in applied WHP. 2/14/2008ASRC Unit #3, standby for acid stimulation **job in progress"" 2/15/2008!'CTU #6 w/ 1.75" OD CT. Daylight coil. Continued from WSR 02/14/08. 'Objective: acid stimulation. Replace and pressure test choke trailer. RIH w/ 2.0" OD JSN. Pump 60/40 methanol/water down inner annulus to confirm liquid pack. `:Load wellbore with 1.5x wellbore volume of 3% ammonium chloride + F103. Spot .15 bbls 12%HCI across perfs and let soak for 30 minutes. Pump remainder of €acid job down coil as follows: 38 bbls 3% ammonium chloride + F103, 15 bbls 12% HCI, 13 bbls 9:1 mud acid, 30 bbls 3% ammonium chloride + F103. POOH 'land freeze protect coil with 60/40 methanol/water. Leave well capped with 30 bbls ';60/40 methanol/water. Unflange BOPs. Cap well and PT cap. Standby to finish ',rig-down tomorrow. Pre-acid injectivity: 1 bpm at 1120 psi. Post acid injectivity: 1 ';bpm at 840 psi. Release well to ASRC to POP. Job complete. -Note: Throughout job, IAP was responsive to changes in applied WHP. 2/15/2008'',ASRC Unit #3, standby for CTU, acid stimulation 2/15/2008''~T/I/O=COIU20/450. SI. IA FL (for CTU). IA FL @ surface. Bled 1 gal of fluid into 'bucket. 2/16/2008';ASRC Unit #3, acid flowback "*job in progress*" • 2/16/2008 r CTU #6 w/ 1.75" OD CT. Daylight coil. Continued from WSR 02/15/08. RDMO CTU #6. Job complete. FLUIDS PUMPED BBLS 98 60/40 METH 380 3% AMMONIUM CHLORIDE + F103 30.4 12% HCL 12.6 9:1 MUD ACID 521 Total 09/28/07 ~chlumb~r~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~M~~~&J ~QV ~ ~ ~~~7 Well Job # Lnn Dnsrrintien NO. 4440 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay f]ata RI Cnlnr CA 15-39A 11661174 MEMORY PROD PROFILE 09/23/07 1 W-42 11745235 MEM SBHPS/TEMP 09/14/07 Z-07A N/A SBHP SURVEY - 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04/07 1 L5-28A 11855810 PRODUCTION PROFILE ~ 08/31/07 1 X-33 11849931 SBHP SURVEY ~ - GjG 08/31107 1 E-14A 11686784 LDL --~ ~ 09123/07 1 01-15A 11855509 DDL ~ - ~ (~ 09/22/07 1 D-21 11626119 PRODUCTION PROFILE '~fa - d 09/11107 1 K-07D 11745234 MEM PROD PROFILE C - 09/06/07 1 11-32 11630498 PRODUCTION PROFILE ~ L _ 09/03/07 1 L-01 11745233 MEM LDL a (~ ~ - ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ~_ 09/05/07 1 Z-16 N/A SBHPS/JEWELRY / a 09/13/07 1 14-26 11676959 LDL -/j 09/09/07 1 04-02A 11630504 LDL j 09/11/07 1 14-37 11695075 LDL 09/13/07 1 3-35/L-36 11630502 PRODUCTION PROFILE 09/09/07 1 I'LCAJC Hl.r\nIVWLCUUG Ktl.C1Y1 C- JIl71VIN19 AlVV Kt1UKMtN("~`G;tVt IiUYY tAliFt IU: i, BP Exploration (Alaska) Inc. ~ ~'' ~ " h~`"-' n~ t ~. , Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ ~a ~tlffd k '~ d.a, Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth Received by: • · STATE OF ALASKA . /1!ft!7 l"J::.C€/\/~D ALASKA OIL AND GAS CONSERVATION COM SION OCr 2 5 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & 11 2001 o Stimulate 0 Other 0 o Waiver 0 Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: 195-2100 ,. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 65.2 KB 8. Property Designation: ADLO-028329 - 11. Present Well Condition Summary: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development pc Stratigraphic 'Ssio Exploratory Service 6. API Number: 50-029-20287-01-00 ' 9. Well Name and Number: PBU01-15A / 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Total Depth measured 9420 / feet Plugs (measured) None true vertical 9196.95 / feet 5i~NED OCT 3 J1m~OO7asured) None Effective Depth measured 9323 feet true vertical 9106 feet Casing Length Size MD TVD Burst Collapse Conductor 119' 20" Surface - 119' Surface - 119' -<',.......-.. ~ 1530 520 Surface 2693' 13-3/8" 72# N-80 Surface - 2693' Surface - 2692' 4930 2670 Intermediate 8100' 9-5/8" 47# N-80 Surface - 9538' Surface - 9308' 6870 4760 Liner 1510' 7" 29# NT -80S 7910' 9420' 7783' - 9197' 8160 7020 15. Well Class after oroposed work: Exploratory Development 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Perforation depth: Measured depth: 9226 - 9229 ' True Vertical depth: 9014.69 - 9018 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 132 shut-in x Contact Gary Preble Signature Form 10-404 Revised 04/2006 9229 - 9236 ' SOZ 9242 - 9246 SOZ 9268 - 9270 - - 9018 - 9024 9030 - 9033 9054 - 9056 - - 5-1/2"x 17# 13CR80 Surface - 7896' 4-1/2" 12.6# 13CR80 7894' - 8772' 9-5/8"x7" baker pkr 7933' 7"x4-1/2" bkr s-3 8655' 0 0 0 0 iRBOMS 8ft (1 n 3 ij 2Ð07 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 6049 153 Tubing pressure 197 Service WINJ WDSPL Title Data Management Engineer Phone 564-4944 Date 10/23/2007 k \0 ~..,,0 Submit Original Only . . Ol-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY WELL SHUT IN UPON ARRIVAL INITIAL WHP 1700 I 1700 I 300 PERFORATED INTERVAL 9226-9236' GUN DATA: 2-7/8" HSD 2906 PJ HMX GUN, 6 SPF, 60 DEG PHASING. WELL LEFT SHUT IN. TURNED OVER TO DSO. FINAL TI 1/0= 1700/1700/300 PSI. ****JOB COMPLETE**** FLUIDS PUMPED BBLS I 1 Diesel 1 Total ~ Kt:.lit:.'''t::.U . STATE OF ALASKA _ - p..~o., ALA1fA OIL AND GAS CONSERVATION CO~SION AUG 2 8 2007 REPORT OF SUNDRY WELL OPERA TIONSAlaska Oil & Gas Cons. Commission 1. Operations Performed: o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing - o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 195-210 - 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20287 -01-00 ~ 7. KB Elevation (ft): 65.2' , 9. Well Name and Number: PBU 01-15A ~ 8. Property Designation: 10. Field I Pool(s): . ADL 028329 . Prudhoe Bay Field I Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9420 / feet true vertical 9197 ' feet Plugs (measured) None Effective depth: measured 9323 feet Junk (measured) None true vertical 9106 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 119' 20" 119' 119' 1530 520 Surface 2693' 13-3/8" 2693' 2692' 4930 2670 Intermediate 8100' 9-518" 8100' 7966' 6870 4760 Production Liner 1510' 7" 7910' - 9420' 7783' - 9197' 8160 7020 SCANNED SEP 1 1 2007 Perforation Depth MD (ft): 9226' - 9236' Perforation Depth TVD (ft): 9015' - 9024' 5-1/2",17# x 4-1/2",12.6# 13Cr80 8774' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer 8655' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Recovered tubing. Cut 9-5/8" casing at -2239', dressed stub to 2242'. Run 9-5/8" tieback to 2244'. Cement wI 145 Bbls of Class 'G' GASBLOK (814 cu ft 1708 sx). Clean out to 9262'. Run new tubinç¡. 13. ReDresentative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinç¡ Pressure Tubina Pressure Prior to well operation: 592 11,900 30 1,500 204 Subsequent to operation: 378 3,603 34 1,720 198 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after work: o Exploratory 181 Development o Service 181 Daily Report of Well Operations 16. Well Status after work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or r:i.1 if C.O. Exempt: Contact Bryan McLellan, 564-5516 307 -192 Printed Name Terrie Hubble Title Technical Assistant prepared~~J~~~rV7 Signature~J\f\ìo ~.... Phone Date 564-4628 Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ORIGINAL RBDMS Bfl SEP 1 0 200~'{~ Submit Original Only Digital Well File . Page 1 of 1 . Well: 01-15 Well Events for SurfaceWell - 01-15 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> 01 -> 01-15 Date Range: 10/ Apr/2007 to 07/Ju1/2007 Data Source(s): AWGRS Events Source Well Date A WG RS 01-15A 07/07/2007 AWGgS 01-15A 07/07/2007 AWGRS 01-15A 07/06/2007 AWGRS o 1-15A 07/04/2007 p."WGRS 01-15A 07/04/2007 A WGßS o 1-15A 06/20/2007 AWGRS 01-15A 06/18/2007 A WGRS 01-15A 06/17/2007 AWGRS 01-15A 06/16/2007 Description PULL 5" GRAY BPV THRU BOPS RIG WORK API VALVE SHOP SET 5" GRAY BPV THRU TREE RIG WORK API VALVE SHOP PULL 5" GRAY THRU TREE RIG WORK API VALVE SHOP T/I/O=10/0/50. Temp=S1. Bleed TBG & IA to 0 psi (pre rig). TBG FL near surface. Bled TBG from 10 psi to 0 psi. OA FL near surface. Bled OAP from 50 psi to 5 psi, (fluid & gas mix). SI monitored for 30 min, OAP increased 10 psi. Final WHP's=0/0/15. SET 5" GRAY BPV THRU TREE PRE RIG WORK API VALVE SHOP T/I/O = SSV/Vac/65. Temp = . T & IA FL (post L & K). No well house or scaffolding. IA has integral. IA FL @ 678'(30 BBL) T/I/O=Vac/Vac/40. Temp=S1. T & IA FL. (post L & K). TBG FL near surface. IA FL @ 24'. T/I/O = VAC/VAC/30. Temp = S1. TBG & IA FL (post L&K). AL line disconnected. TBG FL @ 612' (14 BBL). IA FL @ 636' (46 BBL). T/I/O=0/0/20 Load and Kill, MITOA PASSED to 2500 psi (RWO Prep) Load IA w/ 2 bbls neat & 96 bbls bbls diesel. Load tbg w/ 5 bbls meth, 225 bbls 2% kcl, 2 bbls meth, & 51 bbls diesel. MIT OA to 2500 psi...Pump 4 bbls diesel to reach test pressure. OA lost ~i 1st 15 min, OA lost 1Q..Esi 2nd 15 min. Monitored for an additional 15 mins, OA loss of 1Q..psi 3rd 15 mins for a total of 120 psi in 45 mins. FWHP's=O/O/O ~b.. ð\Ú"o'\ ~o....,> -\ct~~ k~?)v']~ AWGRS 01-15A 06/16/2007 T/I/O=0/VAC/10. Temp S1. Monitor WHP's (RWO prep). TBGP unchanged. lAP from 0 psi to ',\ VAC. OAP increased 10 psi from 0 psi to 10 psi, overnight. AWGRS 01-15A 06/15/2007 T/I/O = 850/420/290. S1. Bleed WHPs to 0 psi pre-L&K (RWO prep). AL spool disconnected, IA with integral, companion valve with integral. TBG FL @ 2978' (69 bbls), IA FL @ 1068' (47 bbls), OA FL @ 30', Bleed WHP's to 0 psi ( 5.5 hrs) all gas. Monitor 30 min. Final WHPs = 0+/0+/0+ 8WGRS 01-15A 06/15/2007 T/I/O = 70/15/30. S1. AL spool removed. IA has integral installed. Monitor WHP,s (RWO prep). TBGP increased 70 psi, lAP increased 15 psi, OAP increased 30 psi overnight. AWGRS 01-15A 06/11/2007 T/IA/OA= 0/550/200 Temp SI PPPOT-T (PASS) PPPOT-IC (PASS) (RWO Pre rig) PPPOT-T (PASS) RU high pressure bleed tool onto THA test void 150 psi bled to 0 psi. Pressure void to 5000 psi for 30 minute test, 4900/ 15 minutes, 4850/ 30 minutes. Bleed THA void to 0 psi, cycled and re torqued all LDS " Standard" all moved free with no broke or bent pins. RD test equipment re installed Alemite cap. PPPOT-IC (PASS) RU high pressure bleed tool onto IC test void, flushed void until clean returns achieved. Pressure void to 3000 psi for 30 minute test, 2950/ 15 minutes, 2900/ 30 minutes. Bleed IC void to 0 psi, cycled and re torqued all LDS "Standard" all moved free with no broke or bent pins, RD test equipment re installed Alemite cap. 8WGBS 01-15A 04/10/2007 *** WELL S/I ON ARRIVAL.*** DRIFT W/ 4.5" CENT SD @ 2728' SLM. RUN 4.5" LIB SD @ 2728' SLM. LIB SHOWS WHAT APPEARS TO BE PARTED TUBING. ***WELL S/I ON DEPARTURE*** ( NOTIFIED DSO ) http://digitalwellfile.bpweb.bp .com/W ellEvents/Home/Default. aspx 8/22/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 Start: Rig Release: Rig Number: 02:00 - 04:00 04:00 - 06:00 06:00 - 14:00 14:00 - 18:00 18:00 - 19:30 19:30 - 21 :30 21 :30 - 22:30 1.00 DHB P 22:30 - 23:00 0.50 KILL P 23:00 - 00:00 1.00 KILL P 7/7/2007 00:00 - 00:30 0.50 KILL P 00:30 - 05:15 4.75 KILL P 05:15 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 09:00 09:00 - 10:30 10:30 - 13:30 13:30 - 20:00 20:00 - 21 :00 21 :00 - 22:00 22:00 - 23:30 7/8/2007 23:30 - 00:00 00:00 - 00:30 00:30 - 02:00 0.75 KILL P 0.50 WHSUR P 0.50 WHSUR P 2.00 WHSUR P Rig equip. Scope down & lower derrick. Con' t to RD equip. Move from Ds 2-30 to Ds 1-15. Move distance 14.2 miles. Layout matting boards & spot rig & equip over well. R/U equip. PJSM. Raise and scope up derrick. R/U circulating lines to tree for killing well. Load 450 bbls of 8.5 ppg 120 deg seawater into pits. Accept rig @ 20:00 hours. DECOMP P/U DSM lubricator and pull BPV. TBG Pressure- 0 psi, Annulus Pressure- 0 psi. UD BPV and DSM equipment. DECOMP Spot and R/U Tiger tank after SWS move from well 16. R/U i lines to tiger tank. í DECOMP PJSM with rig crew and LRHOS. Spot LRHOS and rig up circulating lines to TBG. Pressure test lines to 2000 psi. Good test. DECOMP Continue R/U LRHOS circulating lines and test to 2000 psi. Good test. DECOMP Start Bullhead Killing operations. Pump wI LRHOS on TBG @ 1 BPM wi 100 psi, increase rate to 2 BPM wi 700 psi. Bring rig pump on line to Annulus at 2 BPM wi 200 psi. Caught fluid at 18 bbls. Increase annulus pump rate to 3 BPM wI 1500 psi. Decrease pump rates on both TBG and Annulus to stay under 1800 psi WHP, average pump rate at 1 BPM on both TBG and Annulus. Finished up bull heading rate at 1.3 BPM on TBG and .4 BPM on Annulus with 1500 psi. Pumped a total of 220 bbls on TBG and 260 bbls on Annulus. DECOMP I Shut down bull heading operations and monitor well for flow. I DECOMP i Crew Change. Inspect derrick & check PVT alarms. I DECOMP P/U T-bar &. install TWC. UD T-bar. DECOMP R/U & pressure test TWC. Pressure up from bottom by pumping 1.75 BPM @ 1000 p[si for 10 min. Pressure test from top to 3500 psi for 10 min. Charted same. RID test equip. N/D tree & adapter flange. N/U test spool, BOP, Choke & kill lines. Install 2nd annular valve. DECOMP Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Tested VBRs wi 3 1/2" & 5 1/2" test jts. BOP test witnessing waived by Chuck Sheve wI AOGCC. DECOMP P/U T-bar and pull test dart from BPV. DECOMP R/U DSM lubricator extension and lubricator. Pull BPV. Bleed gas from TBG and monitor well. DECOMP R/U and circulate well down to parted TBG @ 2728'. ICP-60 ,psi @ 3 BPM. Caught fluid at 93 bbls. FCP- 160 psi @ 3 ! BPM. Returns contaminated wI crude. Dynamic losses at 45 IBPH. POOH wi BPV. UD BPV, lubricator and extension. RID DSM. Fill and monitor well. Pump 28 bbls to fill hole. MIU landing joint with double spear pack off assembly and RIH. Engage TBG HGR and pull 25,000 Ibs. BOLDS. R/U Schlumberger control line spooler. Continue working to free TBG HGR by pulling 25,000 Ibs overpull. R/U and steam heat TBG spool. Continue working TBG HRG. HGR pulled free with 50,000 Ibs overpull. Pull HGR to rig floor. P/U weight 50,000Ibs. UD HGR, spear and landing joint. 1.50 WHSUR P 3.00 BOPSU P DECOMP I DECOMP I I 1.00 BOPSU 1.00 BOPSU DECOMP DECOMP DECOMP 6.50 BOPSU 1.50 BOPSU 0.50 BOPSU 0.50 BOPSU 1 .50 PULL Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 7/8/2007 02:00 - 03:00 1.00 PULL P DECOMP R/U and circulate hole volume to TBG part @ 2728'. ICP- 100 psi @ 4.3 BPM. Hole took 20 bbls to catch fluid. FCp· 150 psi @ 5.4 BPM. Monitor well. RID circulating equipment. 03:00 - 06:00 3.00 PULL P DECOMP POOH and UD 5-1/2" LTC TBG. Using constent hole fill while POOH. 06:00 - 06:30 0.50 I PULL P DECOMP Crew Change. Inspect derrick. Check PVT Alarms. 06:30 - 09:30 3.00 PULL P DECOMP Con't to POOH wI completion. Pulled & recovered 55 jts of 5 1/2" tubing wI SS control line. Recovered 1 SSSV assy. RID Spooling unit. Con't to pull additional 14 jts. of 5 1/2" tubing. The last jt had a collar attached to pin end. Recovered total of 69 jts & 52 SS bands. Final 5 jts showed pin corrosion. I Discussed recovery wi engineer & revised new plan fwd. Plan to drift tubing stub wi PAC DP. 09:30 - 10:00 0.50 PULL P DECOMP Clear & clean rig floor. 10:00 - 11 :00 1.00 PULL P DECOMP Wait on BHA tools. Pac DP & handling tools for new BHA. 11 :00 - 12:00 1.00 PULL P DECOMP R/U floor, handling equip & tools for BHA. Load & tally BHA. 12:00 - 13:00 1.00 PULL P DECOMP MIU BHA #1 as follows: 4-3/4" OD Tapered Mill, Double Pin Sub, Shear Thru Bit Sub, 6 * 2 7/8" PAC DP, XO, Pump Out Sub. TL = 194.05'. RIH wi Same. 13:00 - 15:00 2.00 PULL P DECOMP PIU 3 1/2" DP 1 x1 & RIH wi BHA #1 to drift tubing. RIH wi 78 Jts + BHA. 15:00 - 15:30 0.50 PULL P DECOMP P/U Singles & slowly con't in hole. Tagged up @ 2782',23.5' in on jt# 82'. Did not see top of tbg stub except for increase in drag. PIU & re-tag @ same depth. Turn string 2 turns wi tongs, no downward movement. PIU & S/O Wts = 46K. 15:30 - 18:00 2.50 PULL P DECOMP POOH & stand back 31/2" DP. 18:00 - 19:00 1.00 PULL P DECaMP Check pit volume indicators and inspect derrrick. Fill hole with 64 bbls seawater. 19:00 - 19:30 0.50 PULL P DECOMP PIU BHA #2 consisting of a 3.75" aD Tapered Mill, Bit Sub, 2 stands of 2-7/8" Pac Drill Pipe from derrick and PIU 6 more joints, XIO Sub, and Pump Out Sub. Total length of BHA #2- 374.88'. 19:30·21 :00 1.50 PULL P DECOMP RIH with BHA #2 on 3-1/2" Drill Pipe from Derrick to 2703'. Establish parameters of 46,000 Ibs up weight and 46,000 Ibs down weight. Pasted through 5-1/2" TBG stump with out take weight except for slight increase in drag. Continued in hole and tagged up at 2782'. PIU and re-tag @ same depth. Turned string with power tongs without success of getting deeper. 21 :00 - 22:00 1.00 PULL P DECOMP Circulate one hole volume for hole to clean up at 4.5 BPM with 950 psi. Some crude in bottoms up returns. 22:00 - 23:00 1.00 PULL P DECOMP POOH standing back 3-1/2" Drill Pipe in derrick. 23:00 - 23:30 0.50 PULL P DECOMP I POOH with BHA #2. Stand back 4 stands of 2-7/8" Pac Drill Pipe. UD Mill and XIOs. 23:30 - 00:00 0.50 PULL P DECOMP Clear and clean rig floor. 7/9/2007 00:00 - 01 :30 1.50 PULL P DECOMP Bring Overshot Assembly to rig floor. PIU BHA #3 consisting of 8-1/8" Overshot for 5-1/2" TBG, Overshot Extension, Drive Sub, Bumper Sub, Jars, XIO, 3 joints 6-1/4" Drill Collars, XIO, 6-1/4" Intensifires, XIO to 3-1/2" IF Drill Pipe, 3-1/2" DP Pup Jt. Total Length of BHA #3- 144.36' 01 :30 - 03:00 1.50 PULL P DECOMP RIH with BHA #3 on 3-1/2" Drill Pipe from Derrick to 2709'. 03:00 - 04:00 1.00 PULL P DECOMP PIU kelly and establish parameters of 57,000 Ibs up weight, 57,000 Ibs down weight. PIU on single and RIH. Tag at 2742'. Slide over TBG stub to 2744'. Set 5000 Ibs on TBG stub. PIU Printed: 8/14/2007 4:23:53 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 Start Rig Release: Rig Number: 3.00 CLEAN P with no extra weight. S/O to 2742', rotate on TBG stub to 2744 with 100 ft·lbs torque. Set 5000 Ibs on stub. Repeat procedure twice more with same results. CBU at 5 BPM wlith 320 psi. Took 30 bbls to catch fluid. POOH standing back 3-1/2" Drill Pipe in derrick. Pull 24 stands. Crew Change. Service rig. Inspect derrick & check PVT alarms. Finish POOH & stand back BHA. No recovery. Inspect Overshot. Discuss operations wi town & develop new plan forward. UD Overshot Assy, BHA #3 & MIU 51/2" Spear assy BHA #4 as follows: Bull Nose, Spear, Bumper Sub, Jars, XO, 3 * 6 1/4" DCs, XO, Accelerator, XO. TL = 136.46'. RIH wI BHA #4 on 27 stands of 31/2" DP. PIU 2 singles. RIH & tag @ 2742'. Took weight. Rotate string wi tongs & Spear fell inside tbg. Con't down 7+' & bottom out. S/O 10K, PIU & weight indicator bobbled After BS opened.. PIU to tool jt. Go back down & S/O wi 15K. & insure good bite. PIU to POOH. PIU &S/O Wts = 55K. POOH & stand back 3 1/2" DP. Stand back DCs. No recovery. Grapple intact wi 2 stiations on 1 side. review wi town enginner & formulate plan Forward. UD Spear assy. MIU BHA #5 to wash over tubing as follows: Mill Shoe, 4 Jts Wash Pipe, W/O Boot Baskets, XO, Bit Sub wi Float, Bumper Sub, Jars, XO, 6 * 61 14" DCs, XO. TL = 339.55'. RIH wI BHA #5 on 31/2" DP. Ran 27 stands. PIU Kelly. Establish parameters of 63,000 Ibs up weight, 63,000 Ibs down weight, 63,000 rotating weight at 40 RPM and 800 free torque, Pump pressure- 220 psi at 4 BPM. Tag top of TBG stub @ 2742'. Mill over TBG stub to 2749' @ 18:00 hrs. Work over TBG to 2769' by 20:45 hrs. TBG seemed to be cork screwed and would work into wash pipe with considerable work. At 2769', TBG quit working into washpipe without milling on TBG. Torque ranged form 2000 to 4500 ft-Ibs with 0 to 5000 Ibs WOB. Continue milling on TBG to 2779' at midnight. Pump rate 4 BPM wi 390 psi. No metal noticed over shakers. Pumped 2 high vis sweeps with out any increase in cutting to surface. Small metal shaving on magnets. DECOMP Continue milling over TBG from 2779'. 5000 to 10,000 Ibs WOB, Pump Pressure 390 psi at 4 BPM. Make connection at 2781' @ 00:30 hrs. Milling ROP slowed down and torque became erratic ranging from 2000 to 8500 ft-Ibs with 5000 to 10,000 Ibs WOs. Continue milling to 2783'. ROP stopped, mill torquing up to 8500 to 9000 ft-Ibs. POOH to change out mills. Stand back 3-1/2" drill pipe in derrick. POOH wi BHA #5. Stand back 2 stand of Drill Collars in derrick. Crew change. Service rig. Check PVT alarms & inspect derrick. UD shoe & 1 jt of wash pipe. Recovered 2 small pcs of 5 1/2" tbg junk + 1 pc, 1.22' long. Inside 1 jt of washpipe is a portion of a jt of tbg 19.54' long. Total recovery = -21 '. Could not 04:00 - 05:00 1.00 PULL P DECOMP 05:00 - 06:00 1.00 PULL P DECOMP 06:00 - 06:30 0.50 PULL P DECOMP 06:30 - 07:00 0.50 PULL P DECOMP 07:00 . 08:00 1.00 PULL P DECOMP 08:00 - 09:30 1.50 PULL P DECOMP 09:30 - 10:30 I P DECOMP 1.00, PULL 10:30 - 11 :00 0.50 PULL P DECOMP 11:00-12:30 1.50 PULL P DECOMP 12:30 - 13:30 1.00 PULL P DECOMP 13:30 - 15:30 2.00 CLEAN P DECOMP 15:30 - 17:00 1.50 CLEAN P DECOMP 17:00 - 00:00 7.00 CLEAN P DECOMP 7/10/2007 00:00 - 03:00 03:00 - 05:00 2.00 I CLEAN P DECOMP 05:00 - 06:00 1.00 CLEAN P DECOMP 06:00 - 06:30 0.50 CLEAN P DECOMP 06:30 - 07:00 0.50 CLEAN P DECOMP Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 7/10/2007 06:30 - 07:00 0.50 CLEAN P DECOMP remove fish from inside washpipe. Wait on new shoe & 1 jt of wash pipe. Photos of fish sent to town. 07:00 - 08:30 1.50 CLEAN P DECOMP MIU BHA #6, new jt of washpipe & new shoe + existing BHA. RIH wI same. 08:30 - 09:30 1.00 CLEAN P DECOMP RIH wI BHA #6. 09:30 - 12:00 2.50 CLEAN P I DECOMP P/U singles & kelly. RIH & tag @ 2781 '. Mill from 2781 to 2785', then washed down to 2899'. P/U over tight spot & ream interval 2781 to 2785' until able to go over wlo rotation. P/U, S/O & Rot Wt = 65K. 4 BPM @ 230 psi, 60 RPMs, WOB 2-4K, Free Torq = 1500ft-lbs. Rot Torq = 1500·4000 ft-Ibs. 12:00 - 13:30 1.50 CLEAN P DECOMP Set back kelly & UD 3 jts. POOH & stand back 31/2" DP. 13:30 - 14:00 0.50 CLEAN P I DECOMP Stand back DCs & 1 jt of wash pipe. Break out mill shoe. i Inspect same. 14:00 - 15:00 1.00 CLEAN P i DECOMP MIU Cut lip Guide & cutter assy. M/U on wash pipe & RIH wI I BHA #7. 15:00 - 16:30 1.50 CLEAN P DECOMP RIH wI BHA #7 on 27 stands of 31/2" DP. Tag up @ 2781'. P/U kelly & rotate down to 2899'. 16:30 - 17:30 1.00 CLEAN IP DECOMP P/U & locate collar. set knives & cut tubing @ 2864'. P/U, S/O i & Rot Wt = 65K 30 RPMs, Torque 1500 ft-Ibs. P/U & had -1 k additional wt. 17:30 - 18:00 0.50 CLEAN P DECOMP Set back kelly & blow down lines. Prep to POOH. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew Change. Service rig. Inspect derrick & check PVT alarms. 18:30 - 20:00 1.50 CLEAN P DECOMP POOH & stand back 31/2" DP. 20:00 - 21 :00 1.00 CLEAN P DECOMP Stand back collars. Break out wash pipe & recover fish. ~~ Recovered -2' pc of twisted collapsed junk metal +2 full jts of ~\"-\ ~ + 2' cut off pc on bottom of 2nd jt. Cut was good & (~ clean. Recovered tubes appeared to be in very good shape wI no external damage. UD same & BHA. 21 :00 - 21 :30 0.50 CLEAN P DECOMP Clear & clean rig floor. 21 :30 - 22:00 0.50 CLEAN P DECOMP MIU BHA #8 to drift tbg as follows. 4.75" Tapered Mill, P xp Sub, Shear thru Bit Sub, 12 . 2 7/8" PAC DP, XO, Pump Out Sub. TL = 380.29'. RIH wI Same. 22:00 - 23:00 1.00 CLEAN P DECOMP RIH wI BHA #8. Tagged up @ 3223'. Attempt to work deeper I wI 20K down .... No Joy. 23:00 - 00:00 1.00 CLEAN ip DECOMP Reverse circulate well. took 26 bbls to fill hole. Pump 5 BPM @ 370 psi. Pumped total of 240 bbls. Had 12 bblloss during circulation. 7/11/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP POOH & stand back 31/2" DP. Stand back PAC DP in derrick. 01 :30 - 02:00 0.50 CLEAN P DECOMP U.D 4.75" Tapered mill assy. MIU BHA #9 as follows: 3.75" Tapered Nose Mill, Bit Sub, 16' 2 7/8" PAC DP, XO, Pump Out Sub. TL = 499.07'. RIH wI same. 02:00 - 03:30 1.50 CLEAN P DECOMP RIH wI BHA #9. Tag stump @ 2864' & con't in hole. Bottom out @ 3350'. P/U & S/O wts = 55K. 03:30 - 04:30 1.00 CLEAN P DECOMP R/U & reverse circulate well. Took 3 bbls to fill hole. pump 4 BPM @ 1020 psi. Pumped total of 240 bbls w/16 bblloss. RID circ equip. 04:30 - 05:30 1.00 CLEAN P DECOMP POOH & stand back 31/2" DP. 05:30 - 06:00 0.50 CLEAN P DECOMP POOH & stand back 2 7/8" PAC DP in derrick. 06:00 - 06:30 0.50 CLEAN P DECOMP Crew Change. Service Rig. Check PVT alarms & inspect derrick. 106:30 - 07:30 1.00 I CLEAN P DECOMP NID flow nipple. NIU shooting flange. 07:30 - 09:30 2.00 CLEAN P DECOMP R/U SWS equip & full Lubricator & BOPs. Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 7/11/2007 09:30 - 11 :30 2.00 CLEAN [Test lubricator to 500 psi, Ok. RIH wI 3.75" junk basket & gauge ring. Tagged up @ 2910'. Could not get deeper. POOH & UD tools. 11 :30 - 14:30 3.00 CLEAN DECOMP MIU 3.5" drift, RIH to 8900'. POOH & UD drift. 14:30 - 16:30 2.00 FISH IP DECOMP PJSM. MIU 3.71" swedge, RIH on E line to 8700', no obstructions, POOH wI swedge. 16:30 - 19:30 3.00 FISH P DECOMP PJSM. MIU tubing punch, RIH on E line to 8635'. Corolate & fire tool @ 8635-37'. Punched 9 holes in 4 1/2" tubing. 19:30 - 20:00 0.50 FISH P DECOMP POOH & UD tubing punch. All shots fired. Fill hole wi 30 bbls. MIU 12' string shot. 20:00 - 23:00 3.00 FISH P DECOMP MIU lubricator. RIH wI string shot. Correlate & space out tool from 8669-57'. fire string shot. POOH & UD string shot. 23:00 - 00:00 1.00 FISH P DECOMP Break out lubricator & UD string shot. Fill hole wi 34 bbls. 7/12/2007 00:00 - 02:00 2.00 FISH P DECOMP Hold PJSM. MIU Chemical cutter & load into lubricator. RIH, correlate & space out cutter. Fire cutter @ 8668'. Good indication on surface. Cutting tool stuck in tbg. 02:00 - 04:30 2.50 FISH P DECOMP Jar on cutter wI E-line. Start @ 2000 Ibs. Work up incrementally to 2600 Ibs. where line parted @ weak pt. POOH wi E-line. Left tools inhole. 04:30 - 05:00 0.50 FISH P I DECOMP RID E-line. equip. Set back lubricator. 05:00 - 06:00 1.00 FISH P ¡ DECOMP RID shooting flange & install flow nipple. 06:00 - 06:30 0.50 FISH P DECOMP Service rig, derrick inspection, check PVT system, crown 0 matic, OK. 06:30 - 08:00 1.50 FISH P DECOMP PJSM. Make up BHA to fish 5 1/2" tubing stub. 08:00 - 09:30 1.50 FISH P DECOMP PJSM. RIH wI fishing BHA on 31/2" DP, 27 stands & (2) ! singles. 60K up wt, 60K down wt. 09:30 - 10:30 1.00 FISH P I DECOMP PJSM. Kelly up. Tag top of fish 19' in on kelly @ 2874' DPM. (Should have tagged closer to 2864', so there may be bad tubing where the cut was made and it slid inside itself or something beautiful like that). Swallowed approximately 6' of stub with kelly 25' in. Set down 5K, picked up & observed overpull. Pulled to 95K & let jars bleed off. Straight pulled to 200K, tubing not coming loose. Brought on pump @ 4 bpm I 310 psi & pulled to 220K, tubing came free. Pulled up to get tool jOint above rig floor. New up wt, 145K. 10:30 - 13:00 2.50 FISH P ! DECOMP PJSM. Circulate bottoms up @ 4 bpm I 250 psi, losing approximately 2 bbls every 10 minutes while circulating. Circulate all oil I gas out of well bore down to cut @ 8668'. Rig down Eline. 13:00 - 16:00 3.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP, lay down (2) jts, stand back 27 stands. NOTE: Overpulled to 200K on 1 st joint out, worked free, next joint showed some drag along with first 5 stands out, up to 40K over up wt, spaced out about every 40'. Stand back drill collars, lay down jars, accellerators, bumper sub & I overshot assembly. 16:00 - 23:00 7.00 PULL P DECOMP POOH & UD 51/2" x 41/2" completion. Recovered 5 GLMs, 120 jts 51/2" , 1 cut off 5 1/2" jt, 19 jts 41/2" & 1 19.92' cut off jt. 4 1/2" cut off jt was split 84'" up the side of the jt. the cut looked ragged. Also 1 piece of junk was in BOP stack, attempted to fish & it fell down hole. 23:00 - 00:00 1.00 PULL P DECOMP Clear & clean rig floor. RID tubing tools. Formulate new plan forward wi engineer. 7/13/2007 00:00 - 01 :00 1.00 CLEAN C DECOMP MIU & RIH wi BHA #11 as follows: Magnet, Csg Scraper, BS, Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 DECOMP Bumper Sub, Jars, XO, 6 * DCs, XO. TL = 213.40'. DECOMP RIH wi BHA #11 on stands of 3 1/2" DP. Ran 30 stands in hole. DECOMP Held meeting: Introduction to Well Control wI all hands. DECOMP P/U 31/2" DP 1x1 & RIH wI BHA #11.243 jts total, 125K up ! wt, 113K down wt. Tag top of liner @ 7910' DPM. Work & rotate pipe a bit at TOL to ensure no junk there. 07:30 - 10:00 2.50 CLEAN C DECOMP PJSM. POOH w/3 1/2" DP & cleanout I magnet BHA. 10:00 - 11 :00 1.00 CLEAN C DECOMP PJSM. Stand back collars, UD magnet & scraper assembly. Recovered (3) very small, insignificant, thin pieces of metal. 11 :00 - 12:30 1.50 CLEAN C DECOMP Clear I clean rig floor, bring new BHA I tools to floor. 12:30 - 13:30 1.00 CLEAN C DECOMP PJSM. P/U tubing I. packer milling BHA. 13:30 - 16:30 3.00 CLEAN C DECOMP PJSM. RIH wI milling BHA on 31/2" DP. Tag TOL @ 7910', tag hard @ 7918'. Unable to work through obstacle. 125K up wt, 116K down. 16:30 - 00:00 7.50 CLEAN C I DECOMP PJSM. Pick up kelly, establish parameters. Mill on junk from 8660 to 8664' Lots of torq at first until a track was established then smoothed out wI occasional torq. P/U 140K, S/O 130K, Rot 139K. 65 RPMs, 4-7K WOB, 4 BPM @ 700 psi. From 2200 hrs to 2300 hrs completed Introduction to Well Control Course wI crew. 7/14/2007 00:00 - 06:00 6.00 CLEAN C DECOMP Con't to mill up tubing from 8664 to 8671' No losses. Pump sweeps. Very small amount of metal in returns. Vis up system to -60 vis. to clean hole. P/U 140K, S/O 130k, Rot 139K. 65 RPMs, WOB 4-8K, Torq 6-9K. 5.8 BPM @ 1125 psi. 06:00 - 12:00 6.00 CLEAN C DECOMP PTSM. Continue milling on junk tubing above packer. Establish parameters: Up wt 130K, Down wt 121 K, Rotating wt 125K. Circulating @ 5 bpm 11000 psi. Off bottom torque = 2000 ft/lbs, on bottom torque averaging 5000 ft/lbs. Average weight on mill = 5000 - 7000 Ibs. Mill from 8670' - 8674'. Stall once while milling @ 9000 ft/lbs. Seeing very small metal shavings across shaker and recovered from ditch magnets. 87 stands in the hole, (2) singles & 29' of kelly. 12:00 - 14:00 2.00 CLEAN C DECOMP PJSM. Stand back kelly. Pick up (1) jt & RIH to 8673'. Close bag & reverse circulate to clean hole @ 4 bpm I 1600 psi, pressure gradually decreasing to 1300 psi as hole cleans up. (3) bottoms up total. Significant amount of very fine metal returns over shaker. 14:00 - 15:00 1.00 CLEAN C DECOMP PJSM. Drop bar, circulate down @ 4 bpm I 1000 psi, open pump out sub. 15:00 - 18:00 3.00 CLEAN C DECOMP PJSM. POOH wI 3 1/2" DP & milling BHA. 18:00 - 18:30 0.50 CLEAN C DECOMP Crew Change. Service rig. Inspect derrick & check PVT alarms. 18:30 - 19:00 0.50 CLEAN C DECOMP Con't to POOH & stand back 31/2" DP. Stood back 87 stands. 19:00 - 20:00 1.00 CLEAN C DECOMP Break out & UD BHA #12. FB MM mill totally shot. See pictures. Clean out boot baskets. Boot baskets full of pcs of tubing. 20:00 - 20:30 0.50 CLEAN DECOMP Clear & clean rig floor. 20:30 - 21 :30 1 .00 CLEAN DECOMP Drain stack. P/U & install test plug. R/U test equip. 21 :30 - 00:00 2.50 BOPSU DECOMP Perform weekly BOP test as per BP/AOGCC requirements. Test rams wi 3 112" test jt. LP 250 psi, HP 3500 psi. Test witnessing waived by Lou Grimaldi wi AOGCC. 7/15/2007 00:00 - 01 :30 1.50 BOPSU P DECOMP Finish testing BOPE as per BP/AOGCC requirements. Lp 250 Printed: 8/14/2007 4:23:53 PM . . Start: 7/5/2007 Rig Release: 8/3/2007 Rig Number: DECOM~'t;" 2~ 3:~'" No f,ilo,,, Te" w'me,,'o, w"'ed by Lo" Grimaldi wI AOGCC. DECOMP ,Drain stack. NID test equip. Pull & UD Test plug. DECOMP I PIU & MIU BHA #13 as follows: MM Shoe, 3- WP extensions, finger section, Bushing, Reverse Head, XO, 3-Boot baskets, Bit I Sub, Bu~per Sub, Oil Jar, Pump Out Sub, 9 * 4 3/4" DCs. TL 1= 337.19. DECOMP RIH wI BHA #13 on stands of 31/2" DP. DECOMP PIU kelly & tag up on junk @ 8672'. Break circulation & Mill from 8672'. DECOMP PTSM. Establish parameters. Up wt 130K, down wt 118K, rotating wt 125K. Off bottom torque = 2500 ft/lbs. Mill from 18672' - 8675' in (2) hours. Last 1 1/2 hrs made no hole and tried various techniques with no success. Opt to POOH & go back in wI flat bottom junk mill. DECOMP PJSM. Stand back kelly, pump dry job, POOH wI 31/2" DP, 60 stands. DECOMP Secure well. Safety stand down to review well control workbook lessons 3 & 4. Well control lessons completed on this crew. DECOMP PJSM. Continue OOH. DECOMP PJSM. Stand back collars, break down BHA. Recovered approximately 3' of tubing in shoe & washpipe. Looks like top of I tubing previous to this run had been "wallered" out by the junk mill. This section was recovered in the wash pipe. The shoe got over the beginning of the next section, snapped it off due to the thinness of the wall, was pressed out against the ID of the shoe, the snapped off end being flush with the end of the shoe and was only able to spin on the tubing stub looking up at us @ 8675'. (That's our story). Opt to rerun same BHA. Recovered approximately 4 Ibs of iron from junk baskets.... biggest pieces the size of potato chips. M/U BHA & re-run same assy. Crew Change. Srvice rig. Inspect derrick & check PVT alarms. RIH wI BHA on 42 stands of 3 1/2" DP. Cit & slip 217' of drilling line. Adjust brakes & rollers. Repair grease line. Con't to RIH wI BHA on stands of drill pipe. P/U kelly & btreak circulation. Tag up @ 8676'. Mill w/2-4K down to 8682'. Con't to mill 8682 to 8684' w/6-10K. P/U = 145KI, S/O = 125K, Rot Wt = 135K. 4.1 BPM @ 750 psi. 70 RPMs. Torq 3000 ft-Ibs. Mill torq = 5000 ft-Ibs. DECOMP Con't to mill @ 8684'. No progress. Increased wt to 15K down & had no torq. Mix 10 ppg dry job. Lost 200 psi pump pressure. Monitor well. DECOMP Circulate bottoms up. V. small amount of gas. Monitor well. Pump dry job. Set back kelly. UD 2 singles. 4.8 BPM @ 880 psi. DECOMP POOH & stand back 3 1/2" DP. DECOMP Break out BHA. Inspect shoe & extension pipe. Nothing in junk subs, shoe wear indicates milling on tubing collar. DECOMP Rig service, check crown 0 matic, PVT system, OK. Conduct derrick inspection, OK. DECOMP PJSM. M/U overshot assembly dressed to catch 4 1/2" tubing Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 01 :30 - 02:00 02:00 - 03:00 03:00 - 05:30 05:30 - 06:00 2.50 CLEAN C 0.50 CLEAN C 06:00 - 10:00 4.00 CLEAN C 10:00 - 13:00 3.00 CLEAN C 13:00 - 14:30 1.50 CLEAN C 14:30 - 15:30 1.00 CLEAN C 15:30 - 17:00 1.50 CLEAN C 17:00 - 18:00 1.00 CLEAN C 18:00 - 18:30 0.50 CLEAN C 18:30 - 19:30 1.00 CLEAN C 19:30 - 21 :30 2.00 CLEAN C 21 :30 - 22:30 1.00 CLEAN C 22:30 - 00:00 1.50 CLEAN C DECOMP DECOMP DECOMP DECOMP i DECOMP I DECOMP 7/16/2007 00:00 - 01 :00 1.00 CLEAN C 01 :00 - 02:30 1.50 CLEAN C 02:30 - 05:30 3.00 CLEAN C 05:30 - 06:00 0.50 CLEAN C 06:00 - 06:30 0.50 CLEAN C 06:30 - 08:00 1.50 CLEAN C Spud Date: 1/27/1978 End: 8/3/2007 Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: Spud Date: 1/27/1978 End: 8/3/2007 7/5/2007 8/3/2007 DECOMP stub. DECOMP I PJSM. RIH wI overshot assembly on 3 1/2" DP. DECOMP PJSM. Kelly up. Establish parameters. Up wt 143K, down wt 125K. Rotate over tubing stub, swallow 9'. APIU to 200K & set off jars, tubing not free. Jar up @ 230K. Jar down. 14:30 - 16:30 2.00 CLEAN C DECOMP PJSM. Consulted town, opt to do blind back off on 4 1/2" tubing. Pull 1 OK over up wt. rotate to the left, max left hand torque = 8500 ft/lbs, observe break, pick up, up wt 143K. Total of 47 turns to the left made during operation, break observed wI 28 turns made, torque oscillated back up to 7000 ft/lbs after initial break observed. Picked up wI 143K & free. 16:30 - 17:30 1.00 CLEAN C DECOMP PJSM. Stand back kelly. Pull (1) stand, pulling wet, pump dry job, still pulling wet. Drop bar to shear pump out sub, pumped down @ 5 bpm I 600 psi, did not observe shear, (uh oh). 17:30 - 18:00 0.50 CLEAN C DECOMP PJSM. POOH w/3 1/2" DP. Pulling wet. 18:00 - 18:30 0.50 CLEAN C DECOMP Crew change. Service rig. Inspect derrick & check PVT alarms. 18:30 - 19:30 1.00 CLEAN C DECOMP Mix 18 bb19.9 ppg dry job & pump same. RIU to POOH. 19:30 - 23:30 4.00 CLEAN C DECOMP POOH & stand back 31/2" DP. Check & tighten each I connection while POOH. 23:30 - 00:00 0.50 CLEAN C DECOMP POOH & stand back 4 3/4" DCs, Pump out sub, Jars & bumper Sub. Left from Top Drive down in hole. Fish in hole = 10.64' long. 7/17/2007 00:00 - 00:30 0.50 CLEAN C DECOMP Clear & clean rig floor. 00:30 - 01 :00 0.50 CLEAN C DECOMP MIU BHA #16 to screw into fish as follows: Screw in Sub, Bumper Sub, Jars, 9 * 4 3/4" DCs. TL = 302.98'. 01 :00 - 03:30 2.50 CLEAN C DECOMP RI H wI BHA #16 on 3 1/2" DP. Ran in hole wI 87 stands. 03:30 - 04:00 0.50 CLEAN C DECOMP PIU 3 singles & kelly. RIH & tag fish @ 8673'. PIU & Kick in pump @ 1 BPM. Slowly lower to fish, pressure increased from 250 to 325 psi. Rotate & screw into fish 6 turns. PIU & fish is on. Con't to PIU to 225K & jar 1 time. Pull to 250K. Screw in good. Release & rotate off tbg stub. PIU Wt = 143K, SIO Wt = 127K, Rot Wt = 135K. 04:00 - 05:00 1.00 CLEAN C DECOMP Mix & pump dry job. Set back kelly. UD 3 singles. 05:00 - 06:00 1.00 CLEAN C DECOMP POOH & stand back 3 1/2" DP. 06:00 - 06:30 0.50 CLEAN C DECOMP Service rig, derrick inspection, check PVT system, crown 0 06:30 - 08:30 I matic, OK. 2.00 CLEAN C DECOMP PJSM. Continue to POOH wI fishing BHA. 08:30 - 09:30 1.00 CLEAN C DECOMP PJSM. Stand back collars, lay down BHA. Recovered fish from top sub to overshot, no damage or anomolies. 09:30 - 10:30 1.00 CLEAN C DECOMP Clear I clean rig floor. 10:30 - 11 :30 1.00 CLEAN C DECOMP PJSM. Pick up 6 bladed, flat bottom junk mill & associated BHA components. 11 :30 - 14:30 3.00 CLEAN C DECOMP PJSM. RIH wI milling BHA on 3 1/2" DP. 87 stands, (2) singles & a 24' pup. 14:30 - 00:00 9.50 CLEAN C DECOMP PJSM. Kelly up & establish parameters. 141 K up wt, 127K down wt, 137K rotating wt. Pumping 6 bpm @ 950 psi. 3000 ft/lbs of free spin torque, 4000 - 5000 ft/lbs of on bottom milling torque @ 80 RPM. Tag @ 8674', WOB = 2 - 5K. Milled collar @ 8683', milled tbg pup to 8694' DPM. Rotated on packer. 7/18/2007 00:00 - 02:00 2.00 CLEAN C DECOMP Continued milling at 8694' DPM, estimated to be about 6" into top of packer. Milled with 70-80 RPM, 10k Ib - 15k Ib WOB, 5-6 BPM. Attempted dry rotation. Made no additional footage. Made decision to trip for new mill. Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 7/18/2007 02:00 - 03:00 1.00 CLEAN C DECOMP ,Mixed and pumped 20 bbl, 9.9 ppg slug (dry job). 03:00 - 06:00 3.00 CLEAN C DECOMP Held PJSM. Set back kelly. POH with junk mill assembly (BHA #17). 06:00 - 06:30 0.50 CLEAN C DECOMP Service rig, check crown 0 matic, PVT system, OK. Derrick inspection, OK. 06:30 - 09:00 2.50 CLEAN C DECOMP PJSM. Continue to POOH wi 31/2" DP. 09:00 - 11 :00 2.00 CLEAN C DECOMP PJSM. Stand back collars, UD mill. Mill shows excessive wear along outside diameter. Pick up new mill, (packer mill wi pilot mill. 11 :00 - 14:00 3.00 CLEAN C DECOMP PJSM. RIH wI milling BHA on 3 1/2" DP, 88 stands. 14:00 - 15:30 1.50 CLEAN C DECOMP Kelly up & establish parameters. Tagged 22' in on kelly @ 8694'. Up wt 139K, down wt 127K, rotating wt 132K. Pumping @ 5 bpm, 775 psi. Milling wi 5-10K WOB. 2500 ft/lbs of off bottom torque, 3500 ft/lbs on bottom milling torque. 15:30 - 20:30 5.00 CLEAN C DECOMP PJSM. Continue milling, showing signs of being through the rubbers on the packer, pump (20) bbls high vis sweep & chase wI clean seawater, displacing well bore to seawater, 5 bpm 775 psi while milling. Packer milled free. Pushed packer about 10' to kelly down @ 8708'. 20:30 - 21 :00 0.50 CLEAN C DECOMP Monitored well - Static. 21 :00 - 23:30 2.50 CLEAN C DECOMP Held PJSM. POH with BHA #18. Filled hole continuously. 23:30 - 00:00 0.50 CLEAN C DECOMP Held PJSM. Lay down BHA #18. 7/19/2007 00:00 - 01 :00 1.001 CLEAN C DECOMP Cleared boot baskets. Held PJSM. PUMU packer retrieval ass'y (BHA #19). 01 :00 - 03:00 2.00 CLEAN C DECOMP RIH with BHA #19. 03:00 - 03:30 0.50 CLEAN C DECOMP PU kelly and pup jt. Established parameters: PU 137k Ib; SO 130k lb. RIH to 8733', did not tag packer. 03:30 - 05:00 1.50 CLEAN C DECOMP Continued RIH, PU DP singles. Pushed packer to 9154'. 1.00 I CLEAN Engaged fish; PU 185k lb. 05:00 - 06:00 C DECOMP Stood back kelly. Dropped ball and rod to open circ sub. CBU. 06:00 - 06:30 0.50 CLEAN C DECOMP Service rig, check crown 0 matic, PVT system, OK. Derrick inspection, OK. 06:30 - 07:00 0.50 CLEAN C DECOMP PJSM. POOH 14 Stands, Packer now in 9 5/8" casing. 07:00 - 09:00 2.00 CLEAN C DECOMP PJSM. CBU 5 bpm @ 1025 psi. No gas to surface. 09:00 - 11 :30 2.50 CLEAN C DECOMP PJSM. POOH with 31/2" DP and Fishing BHA. 11 :30 - 12:30 1.00 CLEAN C DECOMP PJSM. Slip & cut 84' of drilling line. 12:30 - 15:00 2.50 CLEAN C DECOMP Continue to POOH w/3 1/2" DP. 15:00 - 16:30 1.50 CLEAN C DECOMP PJSM. Stand back collars, UD packer & tail pipe, tail pipe is clear, no chemical cutter assembl 16:30 - 17:00 0.50 CLEAN P DECOMP Clear I clean rig floor. 17:00 . 18:00 1.00 CLEAN P DECOMP LD PAC DP from derrick. 18:00 - 18:30 0.50 CLEAN P DECOMP Held crew change. Performed pre-tower checks of PVT's. Inspected derrick. 18:30 . 19:30 1.00 CLEAN P DECOMP PU & MU 7" and 9-5/8" tandem scraper assembly (BHA #20). 19:30 - 22:30 3.00 CLEAN P DECOMP RIH with tandem scrapers to 8684' bit depth, 7" scraper @ 8672'. Entered liner with no resistance. 22:30 - 00:00 1.50 CLEAN P DECOMP Held PJSM. POH with tandem scraper assembly. 7/20/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP Continued POOH with tandem scraper assembly (BHA #20). 01 :30 - 02:30 1.00 CLEAN P DECOMP LD BHA #20. 02:30 - 03:30 1.00 CLEAN P DECOMP Clean & clear Rig floor. 03:30 - 04:00 0.50 DHB P INTERV Held PJSM. PU 7" RBP & Setting tool. 04:00 - 06:00 2.00 DHB P INTERV RIH with 7" RBP. 06:00 - 06:30 I 0.50 DHB P INTERV Held PJSM. Crew change. Service Rig. Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 Continue RIH with 7" RBP. Set 7" RBP @ 8680'.88 stands & (2) singles, up wt 140K, down wt 11 OK. Confirm set with pull test. Install TIW valve, circulate from IA through valve to confirm fluid packed. 10:00 - 10:30 0.50 DHB P INTERV Pressure test RBP & casing to 3500 psi. OA maintained 0 psi. I Good test. 10:30 - 14:00 3.50 DHB P INTERV PJSM. Bleed off all pressure, POOH w/3 1/2" DP. 14:00 - 15:00 1.00 DHB P INTERV PJSM. Stand back collars, UD running tool. 15:00 - 16:30 1.50 EVAL P INTERV PJSM. N/D flow nipple. RU shooting flange. 16:30 - 18:00 1.50 EVAL N WAIT INTERV Wait on Schlumberger Eline. 18:00 - 18:30 0.50 EVAL P INTERV Changed crews. Performed pre-tour checks, all OK. 18:30 - 22:00 3.50 EVAL N WAIT INTERV Continued to wait on Schlumberger E-line. RD shooting flange. 22:00 - 00:00 2.00 EVAL P INTERV Held PJSM. MI and spotted E-line equipment. RU for USIT logging. 7/21/2007 00:00 - 06:00 6.00 EVAL P INTERV RIH to 7850' with US IT in 9-5/8" casing. Logged up to surface. Log indicates good casing (no wall loss <30%). TOC @ 2448'. Log shows 2 FO. Top FO -2330'. Bottom FO @ TOC. 06:00 - 07:00 1.00 EVAL P INTERV RIH to 2500' with US IT in 9 5/8" casing. Logged up to surface. 07:00 - 08:30 1.50 RIGD P INTERV RDMO e-line unit. 08:30 - 1 0:00 1.50 DHB P INTERV PJSM with Halliburton. PU 9 5/8" RBP. 10:00 - 11 :00 1.00 DHB P INTERV RIH with 9 5/8" RBP on 3 1/2" DP, 28 stands & 60'. Set RBP @ 13010' DPM. 11 :00 - 13:30 2.50 DHB P INTERV PJSM. POOH (2) stands. Test RBP @ 2500 psi / 5minutes, good test. Dump 2500# of 20/40 river sand, let fall, pump to clear DP. Tag sand top @ 2947'. 13:30 - 15:30 2.00 DHB INTERV PJSM. POOH w/3 1/2" DP, UD running tool. UD 4 3/4" DCs. 15:30 - 18:00 2.50 BOPSU INTERV PJSM. Set test plug, rig up test equipment, conduct weeklv test of all BOPE. Witnessing of test waived by AOGCC rep John Crisp, 24 hour notice given. 18:00 - 18:30 I 0.50 BOPSU INTERV Changed crews. Performed pre-tour checks, all OK. 18:30 - 23:00 4.50 BOPSU INTERV Continued testing BOPE to 250 psi I 3500 psi. 23:00 - 00:00 1.00 FISH INTERV Pulled test plug. PUMU 9-5/8" casing cutter assembly (BHA #21). 7/22/2007 00:00 - 01 :30 1.50 FISH P INTERV Continued PUMU 9-5/8" casing cutting assembly (BHA #21). 01 :30 - 03:00 1.50 FISH P INTERV RIH to 2850', one stand above sand depth. 03:00 - 04:30 1.50 FISH P INTERV RU to circulate. Displaced well to 9.8 ppg brine. Heated brine to 120 deg with LRS. Displaced @ 4 bpm, 700 psi. 04:30 - 06:00 1.50 FISH P INTERV POH 7 stands. PU pup joint and single. MU kelly, locate top and bottom collars of joint to be cut. 06:00 - 06:30 0.50 FISH P INTERV Service rig, check PVT system, crown 0 matic, OK. Derrick inspection, OK. 06:30 - 09:00 2.50 FISH P INTERV PJSM. Establish parameters, 54K up wt, 54K down. In hole w/ 22 stands, 10' pup & (1) single. Unable to locate out on collar @ 2216' wI pumping 2 bpm 1250 psi. Located collar @ 2257', 34' in on the kelly. Pick up to 2239', 16' in on kelly. Kick in rotary table @ 20RPM, bring on pump @ 2 bpm / 225 psi, 1000 ftllbs of torque. Rotate there for a few minutes, bring pump to 3 bpm / 425 psi & increase RPMs to 30, 1500 ftllbs, ..5 minutes there. Then bring up pump to 4 bpm / 720 psi, 40 RPM 13000 ftllbs of torque, 5 minutes there. Increase pump rate to 5 bpm I 1500 psi, maintain 40 RPM on rotary table. Downhole torque eventually achieved 9500 ftllbs, stalling out rotary table. Killed pump & rotary table reengaged, indication cutter blades Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 Phase 7/22/2007 106:30 - 09:00 2.50 FISH P pinched. Repeat this several times. After 1 1/2 - 2 hrs total cutting time, verified cut with increase in pressure on the OA. Killed pump & rotarty table. Picked up to 80K, observed cutter blades pull free. Picked up 3' & observed over pull to 130K & pulled free. Suspect 9 5/8" casing shifted to the side after the cut. Oh my. 09:00 - 10:30 1.50 FISH P INTERV PJSM. Close annular preventor, line up & pump 9.8 ppg brtine down DP, taking returns up 9 5/8" x 13 3/8" annulus thru choke to open top tank to verify able to pump up OA, OK. Line up with Little Red Hot Oil unit & pump 130 degree diesel down DP @ 2 bpm 11600 psi ICP, taking returns thru choke to open top. Spot 140 bbls diesel in 95/8" x 13 3/8" annulus. Significant amount of arctic pack back. Saw diesel returns at surface. 10:30·11:30 1.00 FISH P INTERV Let diesel soak for (1) hour. 11 :30 - 12:30 1.00 FISH P INTERV PJSM. Line up & displace out diesel wI heated 9.8 ppg brine @ 5112 bpm I 1450 psi. Observe clean brine returns wI 110 bbls pumped. Mostly diesel w I some arctic pack back. 12:30 - 13:00 0.50 FISH P INTERV PJSM. Bleed all pressure, open annular preventor, circulate wellbore to clean brine returns, 4 1/2 bpm 1850 psi, 82 bbls pumped. 13:00 - 14:00 1.00 FISH P INTERV PJSM. Stand back kelly, POOH w/3 1/2" DP & cutter BHA. 14:00 - 15:00 1.00 FISH P INTERV PJSM. UD multi string cutter BHA. No visible damage to cutter, nothing lost down hole. 15:00 - 15:30 0.50 FISH P INTERV Clear I clean rig floor. 15:30 - 17:30 2.00 FISH P INTERV PJSM. P/U spear assembly. RIH with spear to 9 5/8" casing. PU 10K over string weight to engage spear. 17:30 - 18:00 0.50 FISH P INTERV Changed crews. Performed pre-tour checks, all OK. 18:00 - 18:30 0.50 FISH P INTERV B.O.L.D.S - Pull 95'8" casing hanger. Pull CSG HGR @ 140K, fell to 107K @ floor. 18:30 - 20:00 1.50 FISH P INTERV Release spear from hanger. LD spear & CSG HGR. All 3 elements on packer in good condition. CSG HGR in good overall condition. CSG connection broke out @ 47,700 ftllbs. 20:00 - 00:00 4.00 FISH P INTERV I Filled hole with 22 bbl of 120 degree brine. CBU - Arctic Pac I returns, 70 spm @ 170 psi. Loss 1/2 bbl in 5 min. Gas back @ 1100 strokes - continue to circulate gas & arctic pac - 3 bpm @ 85 psi. Alternated mud pump and charge pump to circulate. Shut down pump several times to monitor. Bubbling gas to i surface gradually decreased to slow spill over. 3 annular volumes pumped. 7/23/2007 00:00 - 03:30 3.50 FISH P INTERV POH with 9 5/8" casing. 20 joints pulled @ 0330 (Bow Spring Centralizer between 16th & 17th joints). CSG covered in AP , but general condition is good with no visible external corrosion or cement. 03:30 - 04:30 1.00 FISH P INTERV Circulate to displace @ 1450'. Flush AP & gas - 85 spm @ 200 psi (1975 total strokes). Alternate to charge pump to I continue slow circulation. RD circulation equipment. 04:30 - 06:00 1.50 FISH P INTERV I Continue to POH & LD 9 5/8" CSG. 06:00 . 06:30 0.50 FISH P INTERV Service rig, check crown 0 matic, PVT system, OK. Derrick inspection, OK. 06:30 . 07:00 0.50 FISH P INTERV PJSM. Continue to POOH w/9 5/8" casing. 07:00 . 09:30 2.50 FISH P IINTERV Rig tongs damaged breaking out 9 5/8" casing connection. I Some connections as tight as 46,000 ftllbs. Remove tongs from floor, order out set of tongs from Baker Fishing & rig up Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES I 7/23/2007 07:00 - 09:30 I 2.50 FISH P INTERV 09:30 - 15:30 6.00 FISH P INTERV 15:30 - 17:00 1.50 FISH P INTERV 17:00 - 18:00 1.00 FISH P TIEB1 18:00 - 18:30 0.50 FISH P TIEB1 18:30 - 19:00 0.50 FISH P TIEB1 19:00 - 20:30 1.50 FISH P TIEB1 20:30 - 23:30 3.00 FISH P TIEB1 23:30 - 00:00 0.50 FISH P TIEB1 7/24/2007 00:00 - 01 :00 1.00 FISH P TIEB1 01 :00 - 02:00 1.00 FISH P TIEB1 02:00 - 03:30 1.50 FISH P TIEB1 03:30 - 04:30 1.00 FISH P TIEB1 04:30 - 05:00 0.50 FISH P TIEB1 05:00 - 06:30 1.50 FISH P TIEB1 06:30 - 07:00 0.50 FISH P TIEB1 07:00 - 09:30 2.50 CASE P TIEB1 09:30 - 10:00 0.50 CASE P TIEB1 I 10:00 - 16:15 6.25 CASE P TIEB1 16:15 -17:30 1.25 CASE P TIEB1 17:30 - 18:30 1.00 CASE P TIEB1 18:30 - 19:00 0.50 CASE P TIEB1 I I Start: Rig Release: Rig Number: Spud Date: 1/27/1978 End: 8/3/2007 7/5/2007 8/3/2007 e same. PJSM. Continue to POOH w/9 5/8" casing, cleaning arctic pack off pipe wi POOH. Clear I clean rig floor. Hold PJSM with Baker fishing hand. PU 9-5/8" dress-off ass'y (BHA #22). Changed crews. Performed pre-tour checks, all OK. Continue PU BHA #22 & 13 3/8" scraper. Held PJSM. RIH with 12" burn shoe (7' of swallow) and 133/8" scraper. RIH with DP in stages. Circulate out AP every 5 stands - 21 total stands. Circulate @ 5/6 bpm - 200 to 450 psi (6794 total strokes). MU Kelly. Circ @ 6 bpm - 450 psi (6125 strokes). AP & gas returns. Clean Pit-1 to tiger tank. Continued CBU @ 6 bpm - 450 psi (6125 strokes). AP & gas returns. Clean Pit-1 to tiger tank. Tagged casing stub @ 2240'. Swallowed stub 7' to 2247'. Established parameters (6 bpm @ 460 psi & 25 RPM). Up and down weight 57K. Marked Kelly to record milling progress. Began milling, torque increased from 600 to 2000 ft/lbs during the first 2' of stump swallow. Increased to 45 rpm and maintained 2000ft/lbs down to inner shoe mill @ 2240'. Increased to 60 rpm with 1250 ft/lbs while applying 2000 WOB. I Milled for 5 min to see string weight return. Milled total of 2' to 2249' (including 7' swallow). Made several passes over stump @ 60 rpm with no complication. Made single pass over stump without rotation, clean pass. Appears stump is dressed off. Final tag @ 2242' DPM. . CBU @ 6 bpm, 460 psi. Returns initially had significant gas and Arctic Pack, then cleared. Stood back kelly. POH with BHA #22. At drill collars, circ to clear BHA of solids. Stood back collars. Broke out and LD BHA #22. Service rig, check crown 0 matic, PVT system, derrick inspection, OK. Clear clean rig floor, prep to run tie back string. Bring tools to floor, rig up torque turn equipment. Pre job safety meeting with all parties involved regarding running 9-5/8" tie-back casing string. 18,000 ft/lbs agreed upon torque for 9 5/8" Hydril 563 thread make up. PUMU 9-5/8" casing tie-back BHA and RIH w/9-5/8" 47#/ft., L-80 Hydril 563 casing. 49 jts. RIH @ 13:15·hrs. 55 jts. RIH @ 16: 15-hrs. Sting over casing stub with Bowen overshot. Tagged top of ,stub @ 2242' casing measurement. PUW = 97K, SOW = 97K. 'I Worked pipe bewteen 50K and 97K to ensure good 3' swallow and seals in overshot energized. Pulled 250K and slacked off I to set in rig slips. Performed pre-tour checks of PVTs and inspected derrick. Serviced cementing head valves and tested same to 3500 psi. Sheared open ES cementer with 3000 psi. Circulated through ports 4 bpm, 120 psi. Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 PJSM. Drained BOP stack. ND tubing spool and raised [p BOPE. Set emergency slips and energized with 125k Ib SO. 21 :30 - 23:00 1.50 CASE TIEB1 I NU and tested BOPE break to 350 psi. 23:00 - 00:00 1.00 CASE I: TIEB1 Circulated well with 9.8 ppg brine, warming well to 80 deg F. RU cementing service. 7/25/2007 00:00 - 01 :30 1.50 CASE ·TIEB1 Loaded wiper plug in cementing head. Continued circ well with REMct warm 9.8 ppg brine. RU cementing lines. 01 :30 - 03:30 2.00 TIEB1 Held PJSM with all personnel. Tested cementing lines to 3500 psi. Pumped 5 bbls fresh water spacer. Mixed and pumped 145 bbls 15.8 ppg cement plus additives @ 4-5 bpm. Held 250 psi back pressure with choke. Dropped plug. Cementing pump displaced cement with 9.8 ppg brine @ 7 bpm. Slowed pump rate when plug neared seat. Bumped plug @ 168 bbls displacement (calculated 163 bbls). About 20 bbls cement returned to surface. Increased pressure to 2000 psi (about 900 psi over final displacement pressure) to close ES cementer. Released pressure, bled about 3/4 bbl. Caught cement samples for UCA. 03:30 - 05:00 1.50 REMCM P TIEB1 RD cementing service. Flushed and RD surface lines. RD cementing head. 05:00 - 07:30 2.50 BOPSU P TIEB1 Suck out casing stump, ND BOPE and pick up stack. 07:30 - 09:30 2.00 WHSUR P TIEB1 Cut 9-5/8" casing with Wachs cutter, pull and lay down cut jt. Cut joint length", 23.03' 09:30 - 12:00 2.50 WHSUR P TIEB1 Remove old tubing spool and makeup new tubing spool with casing packoff. 12:00 - 12:30 0.50 WHSUR P TIEB1 PIT casing packoff to 3800-psi for 30-minutes. 12:30·15:00 2.50 BOPSU P TIEB1 NU BOPE. PIT BOPE break to 250-psi Lo, 3500-psi Hi. Pull test plug and install wear ring. 15:00·15:45 0.75 REMCM P TIEB1 PJSM - PUMU BHA & RIH w/DP. 15:45 - 17:00 1.25 REMCM P TIEB1 PUMU BHA #23 - 8-1/2" bit, 2 x 7" boot baskets, jars, bumper sub, pumpout sub and DC's. 17:00 - 18:30 1.50 REMCM P TIEB1 RIH with BHA #23. Crew changed, pre tower checks - OK. 18:30 - 19:00 0.50 REMCM P TIEB1 Tag TOC in CSG patch @ 2225' DPM - 21 stands. Kelly up & TIEB1 establish circulation. 19:00 - 21 :30 2.50 REMCM P Established drilling parameters (6 bpm @ 460 psi - 60 rpm). Up & down weight 57K. Drilled top layer of cement without a problem. Began drilling top plug @ 2232' DPM, applied 4K-10K WOB with a max torque of 2000 ftJlbs. Pumped 20 bbl high viscosity sweep. Had rubber and metal in returns. Reduced WOB to 2K for final punch thru bottom plug @ 2242' DPM. Made several passes thru CSG patch @ 60 rpm. One pass thru patch without rotation, all passes clear of obstruction. Shut down pump, Kelly down. 17153 total strokes. 21 :30 - 22:30 1.00 REMCM P TIEB1 RIH with 8 more stands to TOS @ 2947' DPM. Kelly up & begin pumping @ 3 bpm - 140 psi. Rotate @ 60 rpm down thru 5' of sand without any obstruction. Appears bottom of plug is drilled up. Make several passes while circulating to 2952' DPM. Pull up and swap pits to high viscosity sweep. 22:30 - 00:00 1.50 REMCM P TIEB1 Pump 20 bbl of high viscosity sweep. Loaded sea water in rig pits. Swap to sea water to chase sweep, CBU & displace 9.8 brine. 7/26/2007 00:00 - 00:30 0.50 REMCM P TIEB1 Continue to CBU & displace 9.8 brine to sea water. Stood back kelly, PU 1 jt. Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 1.00 REMCMTP POOH with BHA #23. 1.00 REMCMtp LD BHA #23. I 1.251 REMCMTP Tested 9-5/8" tieback casing to 3500 psi for 30 minutes. Cleared junk baskets, recovered 2-1/2 gal cement and sand. 'REMct Cleared and cleaned rig floor. 03:45 - 05:00 1.25 TIEB1 PUMU RCJB ass'y #1 (BHA #24). 05:00 - 06:00 1.00 REMCM P TIEB1 RIH with BHA #24. Tag @ 2952'. 06:00 - 07:30 I 1.50 REMCM P TIEB1 Rig up circulating lines. Drop ball. Break circulation @ 5-6 I BPM. Wash down to 2965'. PU off sand and circulate 30-Bbl. I i I hi-vis sweep surface to surface @ 5-6 BPM. Recovered sand and small amount of debris across shaker. 07:30 - 09:30 2.00 REMCM P TIEB1 POH and break down RCJB/Scraper BHA. LD 9-518" casing scraper. Recovered what appears to be major pieces of baffle plate in RCJB. 09:30 - 12:30 3.00 REMCM P TIEB1 Service rig, check PVT's and derrick inspection. Clear and clean rig floor. 12:30 - 13:30 1.00 REMCM,P TIEB1 RIH w/BHA #25: 8-1/4" mill shoe, 2 x 7" boot baskets, jar, I bumper sub, pumpout sub and DC's to top of sand @ 2965'. I 1.50' REMC1P Drop ball. 13:30 - 15:00 TIEB1 Kelly up and establish parameters. Wash down to 2690' @ 5.0-BPM @ 1350-psi. Circulate 30-Bbl. hi-vis sweep surface to surface @ 5.0-BPM. Recovered river sand across shaker 15:00 - 17:00 screen. Set kelly back. 2.00 REMCM P TIEB1 POH LD BHA #25. Clean out boot baskets. Recovered small I I amount of sand and debris in boot baskets. RCJB was clean 2.00 I REMCM of any foreign material. 17:00 - 19:00 P TIEB1 PUMU Halliburton 95/8" pulling tool. RIH with 3 1/2" DP. Tag TOS @ 2985' DPM (28 stands & 1 single). 19:00 - 19:30 0.50 REMCM P TIEB1 Reverse circulate & wash - 4 bpm @ 500 psi from 2985' to top of plug @ 3005' DPM. Up and down weights 61 K. 19:30 - 20:30 1.00 REMCM P TIEB1 Engage RBP & apply 20k up and down to confirm latch. Pulled RBP and made pass thru set depth to confirm pulled free. 20:30 - 22:30 2.00 REMCM P TIEB1 PJSM. POOH with 3 1/2" DP. 22:30 - 23:00 0.50 REMCM P TIEB1 LD 95/8" RBP. All elements and components intact on plug. Break down 6 1/4" DC. Clear rig floor. 23:00 - 00:00 1.00 REMCM P TIEB1 PJSM. PUMU 7" Halliburton pulling tool. MU 43/4" DC. 7/27/2007 00:00 - 00:30 I 0.50 REMCM P TIEB1 Held crew change and PJSM. Performed pre-tour PVT checks and inspected derrick. 00:30 - 04:00 3.50 REMCM P TIEB1 RIH with 7" RBP retrieving tool. Worked through liner top @ 7913' DPM. PU 2 singles, tagged 7" RBP @ 8676'. 04:00 - 04:30 0.50 REMCM P TIEB1 PU 135k Ib, SO 125k lb. Engaged RBP, pulled free. SO to confirm RBP is unset. 04:30 - 06:30 I 2.00 REMCM P TIEB1 LD 1 jt DP. CBU with seawater, 5 bpm and 1100 psi. No fluid losses to formation noted or gas returned to surface during circulation. 06:30 - 10:30 4.00 REMcip TIEB1 POH LD 7" Halco RBP and retrieving overshot. Maintaining well control with double steel displacement while POH. 10:30 - 12:30 2.00 REMCM C TIEB1 Clear & clean rig floor. Remove flow nipple and install shooting flange to top of BOP stack. Prep to MIRU SWS slickline unit. I Spot SWS slickline unit. I 12:30 - 13:00 0.50 REMCMtC TIEB1 PJSM - Review Nabors 4ES "Guiding Principles" and "Rigging I Up Wireline" procedure will all rig and wireline personnel. I I Made special note of Golden Rule - "Lifting and Rigging" and Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 7/5/2007 Rig Release: 8/3/2007 Rig Number: Spud Date: 1/27/1978 End: 8/3/2007 0.50 REMCM, C communicated requirements around lifting unusually shaped I items to rig floor. 13:00 - 15:30 2.50' REMCMfc TIEB1 Rigging up SWS slickline tools. 15:30 - 17:00 1.50 REMCM C TIEB1 RIH w/5.5" LIB on 0.125" slickline tool string. Tag @ 7919' WLM w/LlB. POH w/5.5" LIB. Marks on LIB appear to be from i I possible junk on low side of liner top @ 7910' DPM. 17:00 - 18:00 1.00 REMCMf DPRB TIEB1 Waiting on slickline tools to arrive. 18:00 - 19:30 1.50 REMCM C TIEB1 RIH with 4.5" LIB. Tagged at 9218' WLM. POH. Similar marks as on previous 5.5" LIB. Photos on S-Drive. 19:30 - 21 :30 2.00 REMCMTX DPRB TIEB1 Waited on slickline tools. Day tour completed PETEX Well REMct Control Training. 21 :30 - 00:00 2.50 TIEB1 RIH with slickline bailer. Tagged @ 9218'. POH. Recovered small amount of fine solids. Similar marks on bailer rim as on LlBs. Tapered 10 of bailer shoe had small nicks and dings. ì Night tour completed PETEX Well Control Training. 7/28/2007 00:00 - 01 :00 1.00 REMCM!C TIEB1 RIH with JU tool and OS on slickline. Engaged fishing neck. Sheared up and off fishing neck, POH. 01 :00 - 03:30 2.50 REMCM C TIEB1 Re-pinned tools, RIH with JD tool and OS on slickline. I Engaged fishing neck. Jarred up without success for 1+ hour. REMCMtC Sheared down and off fishing neck, POH. 03:30 - 05:00 1.50 TIEB1 Slipped and cut slickline and re-headed. Added 125 Ib weight ! bar to tool string. 05:00 - 06:30 1.50 REMCMr TIEB1 PJSM. RIH with JD tool on slickline. Tag TOF @ 9214'. Latch up fish and jar up to capacity of 0.125" wire. Jar down and release from fish @ 06:30-hrs. Unable to move fish. POH to I slip and cut wire and develop new plan forward. Notified AOGCC @ 05:55-hrs. of impending weekly BOPE test due by midnight on 7/28/07. 06:30 - 09:30 3.00 REMCMtC TIEB1 RDMO SWS slickline tools and unit. 09:30 - 12:00 2.50 REMCM X DPRB TIEB1 Formulate new plan forward with town engineer. 12:00 - 13:30 1.50 REMCM C TIEB1 PJSM - PUMU BHA. PUMU RIH BHA #26: 5-3/4" Crippled Washover Shoe, XO, 5-3/4" JB, XO, 5-3/4" Washpipe, 5-3/4" RCJB head, 4-3/4 Boot Basket, 4-3/4" LBS, 4-3/4" Oil Jar, 3-1/2" P~S & 9 * 4-3/4" DC's. Ttllength = 349.13 13:30 - 16:30 3.00 REMCM C TIEB1 RIH w/BHA #26. 16:30 - 18:00 1.50 REMCM C TIEB1 PUMU Halco 9-5/8" RTTS packer wlstorm valve. Set same @ , 97' below wellhead. PIT packer to 1000-psi. REMCMtc Held change and PJSM. Performed pre-tour checks. 18:00 - 20:00 2.00 TIEB1 Drained stack. BOLDS. Pulled wear ring, installed test plug. RU BOPE test equipment. 20:00 - 00:00 4.00 REMCM C TIEB1 PJSM. Tested all BOPE components to 250 psi low 13500 psi high. BOPE test witnessed by C. Scheve, AOGCC. Test plug failed. 7/29/2007 00:00 - 03:00 3.00 REMCM X SFAL TIEB1 Pulled and replaced test plug. Cycled LDS on tubing spool. Opened pipe ram door and recovered test plug debris. Replaced valve #12 in choke manifold. 03:00 - 07:30 4.50 REMCM C TIEB1 Continued testing BOPE to 250 psi low 13500 psi high. 07:30 - 11 :00 3.50 REMCM C ITIE81 POH w/Halco 9-5/8" RTTS packer w/storm valve. Unable to sting into storm valve and open same. PUMU RCJB w/8-1/2" mill shoe and attempt to Hoover off top of packer. Nothing I recovered. PU packer retrieving tool and w/storm valve stinger removed. RIH and screw into packer. Close annular preventer and release packer. Observed O-psi on IA. Open annular Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 preventer and POH w/packer. Hang packer in rotary table. Break out packer retrieving tool and clean piece of rubber approximately the size of a cantaloupe from inside of storm I valve bore. Makeup packer retrieving tool wlstorm valve stinger attached and closed TIW valve in top of tool. Screw into packer and open storm valve. Open TIW valve. O-psi trapped in DP. POH LD packer and storm valve. No fluid lost to formation. 11 :00 - 11 :30 0.50 REMCM C TIEB1 RIH w/DP and tag TOF @ 9217'. Drop ball and kelly up. Establish fishing parameters - SOW = 132K, PUW = 143K. 11 :30 - 16:00 4.50 REMCM C TIEB1 Break circulation @ 5.0·BPM @ 1300-1400 psi. RIH and tag @ 9217'. Wash down to 9222'. Work BHA on and off of 9222' w/max overpull of 2000#. Unable to penetrate further. Commence rotating w/free torque @ 1500 ft-Ibs. and 12-17 RPM's. Wash down to 9238' w/max. torque @ 2500 ft-lbs. Max. weight on mill shoe = 7000#. PU BHA off of fish to 9212'. I Ease down on fish without rotating to 9238' and unable to penetrate further. Pump 30-Bbl. hi-vis sweep @ 5.0-BPM @ 1200-1400 psi. Recover sweep to surface and noted arctic pac only across shaker screen. No fluid losses to formation during washing/milling or circulating sweep. Set back kelly. Prep. to POH w/DP and BHA #26. 16:00 - 18:00 2.00 REMCM C TIEB1 POH w/BHA #26 standing DP in derrick. 18:00 - 19:30 1.50 REMCM C TIEB1 Performed pre-tour checks. S&C 84' of drill line. Adjusted brakes. 19:30 - 22:00 2.50 REMCM C TIEB1 Continued POH with BHA #26. No seawater losses to formation. 22:00 - 00:00 2.00 REMCM C TIEB1 Stood back DC. LD BHA #26. 7/30/2007 00:00 - 01 :00 1.00 REMCM C TIEB1 PJSM. Continued LD BHA #26. Recovered all but about 3' of chemical cutter fish; 3-5/8" 00 severing head and bottom nose with centralizer left in hole. Laid Herculite barrier on ground, on which to dismantle fish. Cleared wash pipe and shoe; recovered about 4 gal metal shavings and what appears to be pieces of casing. No seawater losses to formation. 01 :00 - 02:00 1.00 REMCM X RREP TIEB1 ND lower flow nipple and riser. Inspected annular BOP element and NU. 02:00 - 03:00 1.00 REMCM C TIEB1 Cleared and cleaned rig floor. 03:00 - 05:00 2.00 REMCM C TIEB1 Replaced junk basket traps, MU crippled washover shoe and RCJB ass'y (BHA #27). 05:00 - 09:00 4.00 REMCM TIEB1 RIH with BHA #27. 09:00 -11:15 2.25 BOPSU TIEB1 I Formulated decision to replace annular preventer sealing element. Waiting 9-5/8" Halco RTTS packer with storm valve to arrive. 11: 15 - 12:00 0.75 BOPSU C TIEB1 PUMU RIH w/9-5/8" RTTS packer w/strom valve and set same @ 20' below wellhead with DP suspended below it. PIT packer to 1 OOO-psi. 12:00 - 18:00 6.00 BOPSU TIEB1 Replace annular preventer element. 18:00 - 18:30 0.50 BOPSU TIEB1 Held crew change, PJSM. Performed pre-tour checks. 18:30 - 19:30 1.00 BOPSU TIEB1 RU hydraulic lines; prepared flow nipples; leveled rig. 19:30 - 22:00 2.50 BOPSU TIEB1 NU upper and lower flow nipples; installed riser; secured BOP stack. Worked and flexed new annular element. RU BOPE test equipment. 22:00 - 00:00 2.00 BOPSU C TIEB1 Tested annular BOPE to 250 psi low / 3500 psi high with 3-1/2" Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 7/30/2007 TIEB1 and 5-1/2" test joints. 7/31/2007 TIEB1 PJSM. Pulled test plug and installed wear ring. TIEB1 MU RTTS retrieving tool. RIH, engaged RTTS, PU 150k Ib to unset. POH, LD RTTS. Filled well bore with 13 bbls seawater. 01 :30 - 03:00 1.50 FISH C TIEB1 RIH 1 stand plus single. PU kelly, tagged @ 9234' DPM. PU, ;established parameters: PU 146k Ib, SO 136k Ib, Rot 142k Ib, 20-30 rpm, 2k-3k Ib-ft, 5 bpm, 1200 psi. Rotated and washed with 5k-8k WOB to wash pipe limit @ 9262'. Saw minor torque increases during first 6' of progress. No seawater losses to formation. 03:00 - 05:00 2.00 FISH C TIEB1 CBU 5 bpm, 1400 psi. No seawater losses. 05:00 - 06:00 1.00 FISH C TIEB1 POH with BHA #27. Pre-tour meeting from 05:30-hrs. to 06:00-hrs. wldaylight crew. 06:00 - 06:45 0.75 FISH C TIEB1 Service rig and crew changeout. 06:45 - 09:30 2.75 FISH C TIEB1 POH w/BHA #27. 09:30 - 10:30 1.00 FISH C TIEB1 BO/LD BHA #27. Recovered bottom bow spring centralizer and severing head from chemical cutter tool string. Also recovered -2-gallons of fine scale and fine metal mill shavings in boot baskets and -15 gallons of fine scalelmill shavings from washpipe. 10:30-11:15 0.75 FISH C TIEB1 Clear and clean rig floor and prep to run BHA #28. 11: 15 - 12:00 0.75 FISH C TIEB1 PUMU BHA #28: 6" bit, 2 . 4-3/4" boot basket, P~S, oil jar, LBS, 9' 4-3/4" DC's. 12:00 - 15:00 3.00 FISH C TIEB1 RIH w/BHA #28 on DP. 15:00 - 17:30 2.50 FISH C TIEB1 Washed without rotation until resistance @ 9262' DPM . Reverse circulate at 4 BPM with 850 psi. No seawater losses to formation. Caught bottoms up solids sample for laboratory analysis. Attempt to wash down further without success. Pump another BU reversing at 4 BPM with 850 psi. 17:30 - 00:00 6.50 FISH C TIEB1 POH, LD DP and BHA #28. 8/1/2007 00:00 - 01 :00 1.00 FISH P TIEB1 Continue POOH UD 3-1/2" Drill Pipe. 01 :00 - 03:00 2.00 FISH P TIEB1 POOH and UD 4-3/4" Drill Collars. UD BHA #28. 03:00 - 05:00 2.00 FISH P TIEB1 P/U Kelly and break down same. Remove Kelly hose, swivel, and kelly bushings. UD Kelly and components. 05:00 - 06:00 1.00 FISH P TIEB1 Clear and Clean Rig Floor. 06:00 - 06:30 0.50 FISH P TIEB1 Crew change. Rig Service. Inspect derrick & check PVT alarms. 06:30 - 07:30 1.00 FISH P TIEB1 Clean rig floor RID tools. 07:30 - 09:00 1.50 RUNCO RUNCMP RIU to run completion. RIU Torq Turn equip & compensator. 09:00 - 09:30 0.50 RUNCO RUNCMP Hold PJSM wI all hands. Review completion running order. 09:30 - 11 :00 1.50 RUNCO RUNCMP RIH wI Tail pipe assys & Packer assy. Revised running order as per town enginner. Baker Lok all connections below pkr. 11 :00 - 14:00 3.00 RUNCO RUNCMP Con't to RIH wI 4 1/2" completion Torq turn all connections to 4440 ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. Ran 17 jts of 41/2" 12.6#, 13Cr-80 VamTop tubing. MIU X-over assy to 5 1/2" tubing. Change out handling tools. 14:00 - 00:00 10.00 RUNCO P RUNCMP Con't to RIH w/5 1/2" 17#, 13Cr-80 Vam Top tubing completion. Torq turn all connections to 6580 ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. Ran in hole wI 144 jts. 8/2/2007 00:00 - 03:30 3.50 RUNCO P RUNCMP Con't to RIH w/5 1/2" 17#, 13Cr-80 Vam Top tubing completion. Torq turn all connections to 6580 ft-Ibs. Use Jet Printed: 8/14/2007 4:23:53 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-15 01-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 7/5/2007 8/3/2007 Spud Date: 1/27/1978 End: 8/3/2007 8/2/2007 Lube Seal Guard thread compound on all connections. Ran in hole wi total of 186 jts 5-1/2" and 17 jts 4·1/2" TBG. 0.50 RUNCMP RID Compensator and Equipment. 0.50 RUNCMP P/U Landing Joint and MIU HGR. RIH and land HGR in TBG spool. Landing Parameters: PU weight- 144,000 Ibs; SO weight- 132,000 Ibs with 12,000 Ibs block weight. 04:30 - 05:00 0.50 RUNCMP Drain Stack and make sure HGR in proper position. RILDS. 05:00 - 06:00 1.00 RUNCMP R/U circulating lines to reverse circulate new 120 deg Seawater in TBG and Inhibited Seawater on Annulus. 06:00 - 06:30 0.50 RUNCMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 06:30 - 08:30 2.00 RUNCMP Displace IA wi 200 bbls of 120 degree seawater. Pump 3 BPM @ 60 psi. 08:30 - 11 :30 3.00 RUNCMP Con't to reverse down IA & displace wi 365 bbls of 120 degree inhibited seawater. Pump 3 BPM @ 70 psi. 11:30 -12:00 0.50 RUNCMP Drop Ball/Rod & allow to fall on seat. R/U lines to set & test Pkr & IA. 12:00 - 14:30 2.50 RUNCMP Pressure up 3500 psi. & set packer. Con't to hold for 30 min & test tubing. Bleed off tubing to 1500 psi & SI. Pressure up on IA to 3500 psi & hold for 30 min. Bleed off tubing & shear out DCR-SV. Pump thru DCR-SV both ways & insure good shear. RID & blow down lines & test equip. 14:30 - 15:00 RUNCMP P/U T·bar & set TWC. Pressure test from top to 1000 psi & from below to 1000 psi. Held each test for 10 min. Tested good. Charted same. 15:00 - 18:00 3.00 RUNCMP N/D BOPE. Remove VBRs & Shear rams. N/D choke & kill ¡lines. Remove all hydraulic lines & label same. 18:00 . 18:30 0.50 RUNCMP Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 22:30 RUNCMP Finish N/D BOPE & set back stack. 22:30 . 00:00 RUNCMP NU adaptor flange. Test hanger seals to 5000 psi f/30 min. RD test equipment. 8/3/2007 00:00 - 02:00 2.00 WHSUR P RUNCMP NU tree & test to 5000 psi - OK. 02:00 - 03:00 1.00 WHSUR P RUNCMP RU lubricator & pressure test to 500 psi. Pull TWC. LD lubricator. 03:00 - 07:00 4.00 WHSUR P RUNCMP RU to freeze protect. PJSM. Test lines to 3000 psi. Pump 155 bbls diesel down IA. Allow diesel to u-tube f/1-hr. 07:00 - 07:30 0.50 WHSUR P RUNCMP Install BPV. Pressure test from below to 1000 psi. Tested good. 07:30 - 09:00 1.50 WHSUR P RUNCMP Blow down lines. RID lines. Secure tree & clean cellar. RELEASE RIG @ 0900 hrs 08/03/07. Printed: 8/14/2007 4:23:53 PM ~ 105--/)/6 07/27/07 Scblum~epgep R.ECEíVE\J Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth NO. 4346 JUL. 3 0 zam Company: . ,~,¡r~t\1'J~\:ï::.f) AUG () 1 2007 A.læka Oil & Gas Coos. Commlss'IIIJ~_n~ Anchorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job# LOll Description Date BL Color CD 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07111/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: SP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Received by: glo . ~1f&\1fŒ rnJ~ &\~&\~[ß&\ . AI,ASIiA. OIL AND GAS COlWSBRVA.TlOlW COMMISSIOlW SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-15A Sundry Number: 307-192 st;A,NNEt) JUN 1 4 L007 \qf/ð-\D Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this .!Jday of June, 2007 Enc!. ~~ ~ ~ fI1 ~'I~';~ATEOFALASKA ~~ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION ~lC~JUN 072007 APPLICATION FOR SUNDRY APPROVAL Ajaska Oil & Gas Cons. Commission 20 MC 25 280 . 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension - o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 195-210 / 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20287 -01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 01-15A ¿- Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): - ADL 028329 < 65.2' ./ Prudhoe Bay Field / Prudhoe Bay Pool 12. '.' ............... ...... .... .. \A/¡::I r ~I""" ~ü ... . .... ....... .<y /> .. ,I Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9420 ( 9197 9323 9106 None None Casina Lenath Size MD TVD Burst CollaDse Structural Conductor 119' 20" 119' 119' 1530 520 Surface 2693' 13-3/8" 2693' 2692' 4930 2670 Intermediate 8100' 9-5/8" 8100' 7966' 6870 4760 Prnduction Liner 1510' 7" 7910' - 9420' 7783' - 9197' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9226' - 9236' 9015' - 9024' 5-1/2",17# x 4-1/2",12.6# L-80 8753' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer I Packers and SSSV MD (ft): 8698' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 24, 2007 ~Oil o Gas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG OGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na~ David .Reem Title Drilling Engineer Bryan McLellan, 564-5516 Prepared By Name/Number: Signature iJ-(ß~ Phone 564-5743 Date ('/7/0'¡- Terrie Hubble, 564-4628 Commission Use Only I Sundry Number: ,1J.f)'7 -- Ie¡ d.. Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~BOP Test D Mechanical Integrity Test D Location Clearance Other: ~<;,OO ~\ ~ Þ -\<t <7-\- Subsequent Form Required, '-\0 \.- ( 74 r~.Å COMMISSIONER APPROVED BY Date 6-/3..ð:¡- Approved Bv: THE COMMISSION Form 10-403 Revised 06/2006 V" ~/ '---' Submit In Duplicate ORtG\NAL RBDMS 8FL JUN 1 4 20D7 . . G 01-15A Rig Workover Scope of Work: Pull 5-%" x 4-%" completion (parted tubing at -2700' md), cut and pull 9-5/S" casing above top of cement, run new 9-5/S" casing and cement to surface, run 5- %" x 4- %" 13CrSO completion. MASP: 2420 psi Well Type: Producer Estimated Start Date: June 24, 2007 P k re-nCl I: reD wor : 0 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is secured at this time with PX plug. PPPOT-T. 0 2 Shoot tubing and IA fluid level. F 2 Kill well by pumping down tubing and IA simultaneously at max rate (max WHP after catching fluid is 1S00 psi). Freeze protect tubing and IA. Release pumpers, but monitor tubing and IA pressure for two hours after kill. Have DHD check tubing and IA fluid levels and pressures one day after the kill. The goal is to get an idea of how quickly the perfs will drink seawater and swap out with gas. 0 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the riQ. F 6 L&K IA JUST PRIOR TO RIG MOVING ONTO WELL Proposed Procedure 1. MIRU. Circulate out freeze protection fluid and bullhead kill the well. 2. ND tree. NU BOPE. Pressure test to 3500 psi. 3. Pull and LD 5-%" tubing to the part at -2700' md. 4. Fish remainder of collapsed tubing to -S66S' md. 5. Install a retrievable bridge plug in the production casing. 6. Run a cement evaluation log to determine top of cement in the 9-5/S" x 13-3/S" annulus. 7. Cut and puIl9-5/S" casing to just above the top of cement. S. Tie back 9-5/S" casing. 9. Cement 9-5/S" x 13-3/S" annulus to surface. 10. Pull RBP. 11. Run new 5-1/2" x 4-1/2" 13CrSO completion. 12. Displace IA to packer fluid and set the packer. 13. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 14. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = -5-1/8" GRAY GEN II WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP" Max Angle = Datum MD" DatumìVD" GRAY AXELSON 65.2' NA 5600' 24 @ 8797' 9065' 8800' SS 13-3/8" CSG, 72#, N-BO, ID" 12.347" I Minimum ID = 3.725" @ 8732' 4-1/2" HES XN NIPPLE I 5-1/2" TBG, 17#, L-80, .0232 bpf, ID" 4.892" I 9-5/8" X 7" BKR JM TIEBACK PKR, ID " 6.187" BAKER TIEBACK SLEEVE, ID" 7.500" I 9-5/8" X 7" BAKER PKR, ID = 6.313" 9-5/8" X 7" BKR HMC HGR, ID = 6.125" 9-5/8" CSG, 47#, N-80, ID = 8.681" I TOP OF CMT PLUG I 19-5/8" BRIDGE PLUG , . ÆRFORA TION SUMMARY REF LOG: ACOUSTILOG ON 01/22/96 ANGLE AT TOP ÆRF: 21 @ 9226' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9226 - 9229 0 12/17/02 3-3/8" 4 9229 - 9236 0 03/26/02 3-3/8" 6 9242 - 9246 S 02/24/02 3-3/8" 6 9268 - 9270 S 02/24/02 01-15A ~NOTES: . 2217' -i 5-1/2" HES HRQ SSSV NIP, ID = 4.562" , ST MD 1 3215 2 4732 3 6211 4 7316 5 7875 GAS LIFT MANDRELS ìVD DEV TYÆ VLV LATCH PORT DATE 3214 2 LB DMY T-2 0 03/17/07 4731 2 LB DMY T-2 0 09/20/02 6180 21 LB DMY T-2 0 03/17/07 7218 19 LB DMY T-2 0 01/26/96 7749 17 LB DMY T-2 0 01/21/07 7895' -i 5-1/2"X4-1/2"XO,ID=3.958" I 9-5/8" CSG MILLOUT WINDOW 8100' - 8150' (SECTION MILL) 7" X 4-1/2" BKR S-3 PKR. ID = 3.875" -i 4-1/2" HES XN NIP, ID = 3.725" I I 9-5/8" CSG, 47#, N-80, ID 8.681" 9538' 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" I Q£) DATE 02/18/78 01/26/96 03/29/02 09/20/02 12/17/02 11/11/05 REV BY COMMENTS ORIGINAL COM PLETION RIG SIDETRACK (01-15A) CH/KA K CORRECTIONS DTRlKK GL V C/O CAO/KK ADÆRF RPHlPJC WAIVER SFTY NOTE DELETED DATE 12/07/06 01/21/07 03/17/07 REV BY COMMENTS JLJ/TLH GL V C/O JRP/PAG GLV C/O CJNlPA G GL V C/O PRUDHOE BA Y UNrr WELL: 01-15A ÆRMrr No: '1952100 API No: 50-029-20287-01 SEC 8, T10N, R15E 4852' NSL & 4589' WEL BP Exploration (Alaska) : rna= = -5-1/8" GRAY GEN II . 01-15A ~NOTES: I WB..LHEAD = GRAY ACTUA TOR = AXB..SON Proposed KB. B..EV = 65.2' BF. B..EV = NA KOP= 5600' Max Angle = 24 @ 8797' Datum MD = 9065' Datum 1VD = 8800' SS I 2200' - 5-1/2" HES X-Nipple, ID = I I 9-5/8" CSG, 47#, L-80, ID = 8.681" I -2200' -2200 - 9-5/8" ES CEMENTER I I 13-3/8" CSG, 72#, N-80, ID = 12.347" I 2693' GAS LIFT MANDR8...S ST MD 1VD DEV TYÆ VLV LA TCH PORT DATE 4 3401 1.5" OCR Minimum ID = 3.725" @ 8732' I. 3 5603 1.5" DMY 4-1/2" HES XN NIPPLE 2 7191 1.5" DMY 1 8250 1" DMY I 5-1/2" TBG, 17#, 13Cr80, .0232 bpf, ID = 4.892'~ 7894' I I 7895' - 5-1/2" X 4-1/2" XO, ID= 3.958" I I 9-5/8" X 7" BKR JM TIEBACK PKR, ID = 6.187" I 7910' ~~ x~ 9-5/8" CSG MILLOUT WINDOW I BAKER TIEBACK SLEEVE, ID = 7.500" I 7925' -- 8100' - 8150' (SECTION MILL) I 9-5/8" X 7" BAKER PKR, ID = 6.313" I 7933' -- ~ I 9-5/8" X 7" BKR HMC HGR, ID = 6.125" I 7941' r- I 9-5/8" CSG, 47#, N-80, ID 8.681" I I TOP OF CMT PLUG I I 8552' H 4-1/2" HES X NIP, ID = 3.813" I 8105' r- ~ I 8572' H 7" X 4-1/2" BKR S-3 PKR, ID - 3.875" I 8668' I 4-1/2" TBG,12.6#,13Cr,.0152 bpf,lD 3.958" .J 8642' H 4-1/2" HES X NIP, ID = 3.813" I I 8668' 11 UNIQUE MACHINE I OVERSHOT I 8752' I 4-1/2" TBG,12.6#,L80,.0152 bpf,lD =3.958" k 9-5/8" BRIDGE PLUG 8249' 8698' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" ÆRFORA TION SUMMARY '- \\ 8732' 4-1/2" HES XN NIP, ID = 3.725" REF LOG: ACOUSTILOG ON 01/22/96 8753' H 4-1/2" WLEG, ID = 3.958" I ANGLEATTOPÆRF: 21 @ 9226' 8: :8 8810' 1-1 7" MARKERJT (21') I Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 6 9226 - 9229 0 12/17/02 ~ 3-3/8" 4 9229 - 9236 0 03/26/02 3-3/8" 6 9242 - 9246 S 02/24/02 ~ 3-3/8" 6 9268 - 9270 S 02/24/02 .J 9323' H PBTD I I I ~ .-.. 9-5/8" CSG, 47#, N-80, ID = 8.681" 9538' I IT .". I 7" LNR, 29#, NT-80S, .0371 bpf, ID = 6.184" I 9410' I ", ~ 9420' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 02/18/78 ORIGINAL COMPLETION 06/06/07 BJM PROPOSED RWO WB..L: 01-15A 01/26/96 RIG SIDETRACK (01-15A) ÆRMIT No: "1952100 03/29/02 CHlKAK CORRECTIONS API No: 50-029-20287-01 09/20/02 DTRlKK GL V C/O SEe 8, T10N, R15E 4852' NSL & 4589' WB.. 12/17/02 CAO/KK ADÆRF 11/11/05 RPHlPJC WAr-JER SFTY NOTE DB..EfED BP Exploration (Alaska) RE: 01-15 Return to Normal (list of 17) e e PTD~ ¡q6- 210 òl-I5'A Subject: RE: ()..1.ct5 Retum to Normal (list of 17) From: "NSLJ, ADW Well Integrity Engineer" <NSlJ^DWWelllntcgrityEnginccr(á~BP.com> Date: Fri, II No\' 2005 20:25:43 -0900 To: "Rossberg, R Steven" <.RossbeRS@BP.com>, "Engel, Harry R" <EngcIHR@BP.com>, NSUADWWcIlOpcratiol1sSupervisor@ßP.com, "GPB, FS 1 DS Ops Lead" <GPBFS I DSOpsLead(Z~}BP.com>, "GPB, FS I/SIP/STP Area Mgr" <GPBFSITL(q)BP.col11>, "GPB, W~lIs Opt.EJ~g" ~G~BW~lIs()ptEng@BP.com>, "GPB, Optimization ~~gr" -0\ . r; It!IS/·tÇ <CJPBOptll11lzatlOnEngr@BP.com>, "Yancey, Alex N" <Alcx.Yanccy(q3BP.com>, \\élf..1 j i m_ rcgg(ij)admi n.statc.ak. us, wi nton.__ aubcrt(q}adm in.state.ak. us CC: "Hughes, Andrea (VECO)" <hugha4@ßP.eom>, "Frazier, Nicholas B" <fraznb@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.col11>, "Reeves, Donald F" <ReevesDf@BP.com> Hello all. O!-16A Well ~has been reclassified from Waiver to Normal. Both the recent NFT leak rate of 0 SCFPH and wellhead pressure trends indicate the well does not appear to have a communication issue. FS1 Lead: would you please ensure any waiver related signage has been removed from the wellhouse. Please call if you have any questions. Joe 1-907-659-5102 SCANNEl") DEC 1 t) 2005 From: Reeves, Donald F Sent: Thursday, November 10, 2005 3:42 PM To: NSU, ADW Well Integrity Engineer Cc: Hughes, Andrea (VECO); Frazier, Nicholas B; Holt, Ryan P (VECO) Subject: 01-15 Return to Normal (list of 17) Hi Joe, ol-I-GA Well ~ passed a NFT-IA for waiver compliance on 10/21/05 with a final gas rate of 0 seth. Since the NFT, the lAP has remained at 10 psi with the well online. Since the well is currently waivered for TxlAxOA communication it is on the list of 17 wells to be mitigated by 12/31/05. I recommend we cancel the waiver and return the well to Normal status, what do you think? Donald 1 of 1 11/18/20052:43 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFORATION Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 428' FNL, 4589' FEL, Sec. 08, T10N, R15E, UM At top of productive interval 1395' FNL, 4052' FEL, Sec. 08, T10N, R15E, UM At effective depth 1539' FNL, 4052' FEL, Sec. 08, T10N, R15E, UM At total depth 1597' FNL, 4050' FEL, Sec. 08, T10N, R15E, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic__ Service__ (asp's 698014, 5940477) (asp's 698579, 5939525) (asp's 698583, 5939381) (asp~ 69858~ 5939323) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 01-15A 9. Permit number / approval number ',,,I 195-210 10. APl number 50-029-20287-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 119' Surface 2662' Intermediate 8069' Liner 1487' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 9420 feet 9197 feet Plugs (measured) TD Tagged @ 9248' (12/17/2002) 9248 feet Junk (measured) 9035 feet Size Cemented 20" 225 sx Arctic Set 13-3/8" 5800 sx Permafrost II 9-5/8" 830 sx Class 'G' 7" 287 sx Class 'G' Measured Depth True VerticalDepth 150' 150' 2693' 2692' 8100' 7966' 7933'-9420' 7805'-9197' measured Open Perfs 9226'-9236', true vertical Open Peris 9015'-9024', 5-1/2", 17# L-80 TBG @ 7894'; Sqzd Peris 9242'-9246',9268'-9270' Sqzd Peris 9030'-9033',9054'-9056' :. -, 5-1/2" x 4-1/2" XO @ 7895'; 4-1/2" 12.6# k-80 TBG @ 8753'. 9-5/8" x 7" BKR JM Tieback PKR @ 7910'. 9-5/8" x 7" BKR PKR @ 7933'. 7" x 4-1/2" BKR S-3 PKR @ 8698'. 5-1/2" HES HRQ SSSV Nipple @ 2217' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 12/09/2002 Subsequent to operation 01/28/2003 Representative Daily Averaqe Production orlniection Data OiI-Bbl Gas-Ma Water-Bbl 1018 4653 67 1716 24588 60 Casing Pressure Tubin.q Pressure 170 794 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 6. Status of well classification as: Oil _X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowlecLge. DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · EIDMS BFL Title: Technical Assistant Date February 12, 2003 Prepared by DeWayne R Schnorr 564-5174 SUBMIT IN DUPLICATE 01-15A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/02/2002 SECURE WELL: AC-FLUID LEVEL 11/05/2002 SECURE WELL: AC-FLUID LEVEL; AC-HONTTOR 11/12/2002 ANN-COMrvl (AC-EVAL AND REPAIR): AC-MONITOR 12/11/2002 PERFORATING: DRIFT/TAG 12/17/2002 PERFORATING: PERFORATING 01/28/2003 TESTEVENT --- BOPD: 1,716, BWPD: 60, MCFPD: 24,588, AL Rate: 0 EVENT SUMMARY 11/02/2002 T/I/O = 220/1490/1330 TEMP = WARM. (WEEKLY OA FL FOR WC). OA FL NEAR SURFACE. 11/05/2002 TIO= 1700/1550/1100 OA FL NEAR SURFACE. (WEEKLY OA FL FOR WC). WELL IS SHUT-IN. 11/12/02 TIO= 200/1500/1350 TEMP= HOT. OA FL @ 60' (4.5 BBLS) (WEEKLY OA FL). 12/11/02 DRIFT ANDTAG W/3 3/8" DUMMY GUN. CORRECTED TAG DEPTH OF 9268'. (TARGET DEPTH 9236') (RECOVER SAMPLE OF PARAFIN.) TURN WELL BACK OVER TO DSO. DSO TO BRING WELL BACK ON. 1 2/17/02 PERFORATE 9226'-9236', WITH 3 3/8" POWERJET 6 SPF, EH 0.45", PENETRATION 38.6", 22.7 GRAMS..CORRELATE TO ATLAS ACOUSTILOG DATED 22-JAN-96 & SWS PERF RECORD DATED 20-FEB-96. TD 9248'. <<< POP WELL >>> 01/28/03 TESTEVENT --- BOPD: 1,716, BWPD: 60, MCFPD: 24,588, AL Rate: 0 Fluids Pumped BBLS 2 DIESEL USED TO PRESSURE TEST PRESSURE CONTROL EQUIP 2 TOTAL ADD PERFS 12/17/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" HMX HSD PJ, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 9226'-9236' SCANNED i~l,Al~ ~ ? Z00~ Page I TREE= 5-1/8" GRAY GEN II WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 65.2' BF. ELEV = NA KOP = 6800' Max Angle = 24 @ 8797' Datum MD = 9065' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, N-80, ID: 12,347" H 2693' 01-15A SAFETY NOTES: ***T X IA X OA COMM. OPERATING PRESSURE OFTHE 13-3/8" ANNULUS MUST NOT EXCI=I=D 2000 PSI (10/24/02 WAIVER)*** 2217' H 5'l/2"HESFRQSSSVNIP'ID=4'562" I GAS LIFT MANDRELS iMinimumID = 3.725" @ 8732' I 4-1/2" HES XN NIPPLE I I I 5-1/2"TBG, 17#,L-80, .0232 bpf, ID=4.892" H 7894' I 9-5/8" X7" BKRJMTIr::RACK PKR, ID= 6.187" H 7910' I BAKERTIFRAC~ SLEEVE ID= 7.500" H 7925' I 9-5/8" X 7" BAKER PKR, D=6.313" H 7933' 9-5/8"X7"BKRI-IVlCHGR, ID=6.125" H 7941' 9-5/8" CSG, 47#, N-80, ID = 8.681 ]TOP OF CMT PLUG H 8105' ]9-5/8" BRIDGEPLUG H 8249' PEF~ORATION SUMMA RY REF LOG: ACOUSTILOG ON 01/22/96 ANGLEATTOPPERF: 22 @ 9226' Note: Refer to Production D~ for historical perf data SIZE SPF INTERVAL Opn~Sqz DATE 3-3/8" 6 9226 - 9229 S 02/24/02 3-3/8" 6 9226 - 9236 O 12/17/02 3-3/8" 4 9229 - 9236 O 03/26/02 3-3/8" 6 9242 - 9246 S 02/24/02 3-3/8" 6 9268 - 9270 S 02/24/02 9-5/8" CSG, 47#, N-80, ID = 8.681" H 9538' I 7" LNR, 29#, NT-80S, .0371 bpf, ID= 6.184" H 7895' H 5'1/2"X4-1/Z'XO'ID=3'958" I I9-5/8" CSG MILLOUT WINDOW 8100'- 8150' (SECTION MILL) 8698' H 7"X4-1/2"BKRS-3PKR'ID=3'875"I 8732' H 4'l/2"HESXNNIP'ID=3'725"I &1/2" TBG, 12.6#,L80,,0152 bpf,ID =3,958" 8753' H 4-1/2" VVLEG' ID = 3'9'58" I I 8740' H ELMD 'ir LOGGED 02/20/96 8810' H 7"MARKERJT (21~ 9323' ~ 9410' 9420' i DATE REV BY COMMENTS DATE REV BY COIv~ENTS 02/18/78 ORIGINAL COMPLETION 09/20/02 DTPJKK GLV 01/26/96 R~G SIDETRACK(01-15A) 10/08/02 JAL/KK WAIVERSAFErY NOTE 04/29/01 RNfrP CORRECTIONS 11/11/02 BrVVtlh WAIV ER SAFETY NOTE 03/26/02 CVVS/KK ADPERFS 12/17/02 CAO/KK ADPERF 03~29~02 CH/KAK CORRECTIONS 06/22/02 KB/TLH PERF CORRECTIONS PRUDHOE BAY UNIT WELL: 01-15A PERIVIT No: 1952100 APl No: 50-029-20287-01 SEC 8, T10N, R15E 4852' NSL & 4589' WEL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair ~ THRU: Tom Maunder \~ f~(C~ P.i. Supervisor DATE: October 7, 2002 SUBJECT: Mechanical Integrity Tests BPX PBU DS '01-15A PTD 1952100 FROM: John Crisp Petroleum Inspector Prudhoe Bay Field NON~ CQNFIDENTtAL Packer Depth Pretest Initial 15 Min. 30 Min. We, J 01-15A I TYpe~nj.!'L' I~:v.~.'l' I Tub'i~gl 675 [" 640I 640 I" 640' I lntervall P, iT':D'I 1952100 ITy,pe'{estl'ITest PSil IA ! casingI, 0, I','0 , ,J ~ , I 0 ,, J PIF J ,. Notes: Pressure on OAbefore startin~ test was 340 :psi;Test OA to 3000 psi. for 30 minutes. WellI -' ' I 'i')~p~'l'r~J'. !'" ' ! T.V.D.'i .... I Tubin~'l I.... I ' I'"l lntervall 'P-T-D-I ' ITypetestl, ' [Testpsil I, Casi,n?'l , f ,", I ,' I .... I p/F I'" Notes: ..... Welq Typelnj-I IT:V-D- I I'Tubingl "'I ' I I ' IIntervall >-T:D-~ ! ...... ! , ! I, I I I .... I, I ,I , . , Type,testI ' Test'Psi ' ' 'casing ' ' 'PiE Notes: . ', Weiil" , P.T.D.I Notes: ' Welq P:T.D'.I Notes: ITyp~ Inj. I I ~.V.'D. I' I 'l:~bing I ' I ' I I ' l lnte~'all ' T,y. pe'{e4tl,. , '. ,. I Test p~i] ., "'[ C, asing'.l ' [, I . ' I.'.'i' I PIE I Typelnj.I" [ T.v.o. I I' :r~bing"l ' I .... 1 I' [idterva'l 'Type testI I Test'psiI' "I'Casing I ' I ' I ' !' ' I P)F '1 Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVariance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: Attachments: Test'$ Detaii~ I witnessed the pressure test on DS01-15A producers O,~A. The test pressure was 3000 psi., after 15 minutes the test pressure was observed ~. 2960 psi., final pressure observed ~ 2940 psi. The 13 3/8" OA casing shoe is 2693'. The pressure on the IA was verified ~ 0 psi. positive during test by removing gauge & opening IA to atmosphere. Tubing pressure during test was 640 psi. Number of Failures: 0 Tdtal Time during tests: 2, hm,.. MIT report form 5/12100 L.G. MIT PBU 01-15A 10-07-02 JC.xls 10/10/2002 PERMIT 95 -210 DATA DIRECT SURV 95-210' DLL 95-210 CN 95-210 DAC 95-210 SSVD 95-210 7253 95 - 210 PROD PROF 95 - 210 PERF AOGCC Individual Well Geological Materials Inventory 95-210 CNTG T DATA PLUS 95-210 8080 /~05- 9420 ~W~SEPiA ,~?f- '7~. SEPIA ~ i' ~ - SEPIA ~DLL/DAC/CN/GR ~ ~SEPIA 8696-9297 ~9000-9265 ~CHL~ CNTG Page: 1 Date: 02/25/98 RUN RECVD 03/01/96 1 02/08/96 1 02/08/96 I 02/08/96 1 02/08/96 1 02/08/96 1 06/07/96 1 07/12/96 FINAL 08/22/97 1 08/22/97 10-407 ~OMPLETION DATE ~-/2OJr-"/~ / DAILY WELL OPS R ) /~/ /~/ TO //~,~ / ~ / Are dry ditch samples required?~ yes ~_~_And received? Was the well cored? Are well tests required? /yes ~Received? Well is in compliance ~ I~itial COMMENTS ~ Analysis & description received? yes T i GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11270 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 8/2O/97 0%" Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 1-15A 97356 CNTG ~ '~:~0'~'0 970516 1 1 1 D.S. 1-11 97357 C__NTG ':Fic-. x~(~-~,l 970515 I 1 1 D.S. 2-4A 97314 TDTP ~ ~O~'~ 970502 1 1 1 D.S. 15-27 97310 TDTP ~ ~~ 970530 1 1 1 I' , , , ..... , , , , SIGNED: .~~'~~ DATE: AU6 22 1997 AJa,~a ()il & Ga~ ,~{~lS .,.,ul~!r~i~.,:.,.u~ ,, Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 10286 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 7/12/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter [D.S. 1-3A c" PERF RECORD 960227 1 I .. '"' ID.S. 1-:~A cJ JEWELRY LOG 960227 1- 1 ........ D.S. 1-15A ~'" PERF RECORD 960326 I 1 D.S. 1-22A.. £/' .. PERF.RECORD 960312 I 1 . . D.S. 2-05 ,- -"' PERFRECORD 960326 1 1 ..... D;S. 2-10 -, PERFRECORD 960417 I I ........ D.S. 2-22 'c " PERFRECORD 960227 1 1 D.S. 2-22 ' '" INFLATABLE BRIDGE PLUG 960405 I 1 D.S. 3-10 c '/ PERFRECORD 960225 1 1 D.S.. 3-33 ~ .-- PERFRECORD .. 960225 1 1 ...... D.S. 3-36 ~, '/ PERFRECORD 96041.. 1 1 1 D.S. 4-36 ~ "" PERFRECORD 960325 1 1 D..S.. 5-8 --'"' TUBING PAT.C.HSE.TI'ING'REcORD 960414 I 1 D.S. 6-12A ,.-" PERFRECORD 96031 8 1 1 ........... D.S. 6-12A ~-' . PERF RECORD 960414 I 1 ,,, ---'~ D~S. 6-13 '""' PERFRECORD 960318 I 1 D.S. 6-14A '--/' ! PERF RECORD 960317 I 1 D.S. 9-01 ~' CHEMCIAL TUBING CUT RECORD 960303 I 1 ' .D.S. 9-10 '" PERF RECORD 960409 I 1 .D.S. 9-29 t,/ INFLATABLE BRIDGE PLUG .9.60410 I 1 o;- ~/~ _D.S. 16-12 - ~. TUBING PUNCHER RECORD 960321 1 1 D.S. 16-16 '" PERF RECORD 960226 I 1 D.S. 17-1 ,./' PERFRECORD 960312 1 1 ~.s. 17-~' . .~ ~ET CUttER RECORD 960 ~ 69 1 ~ D.S. 18-1A ~' ~ PACK OFF GAS LIFT. MANDRE.L. 960224 I 1 .D.S. 18-11 // PERFRECORD 960404 I 1 _D.S. 15-39 ~ 9_6136 DUAL BURST TDT-P (BORAX) .. 960429 I ~ JUL 1 2 199; Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Alaska 0il & Gas Cons. Commission Anct~orage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 10276 Company: Alaska Oil & Gas Cons Comm Attn: Howard Oakland 3001 Porcupine Drive Anchorage, AK 99501 7/3/96 Field: Prudhoe Bay Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Disk Calculation JUL 05 3996 Please sign and return one copy of this transmiEal.to Sherrie at the above address. Thank you. N~l&Gas ~S. ~mBi~ion An~0mge D:S. 1'3 "'"' JET CUTTER RECORD 960i0:~ 1 1 ............................ D.S. 1-6A ./ PERFORATION RECORD 960204 1 1 ..................... D.S. 1-7A '" 'PERFORATING RECORD 9 6 01 1 6 I 1 ......................... D.S. 1-9A / PERFORATING RECORD 9601 25 I 1 D.S. 1-12 "' v"' TUBING'~I. IT~R RECORD ...... 9 6 01'1' 1' I ~' ' D.S. 1-15A ' ..2 PERFORATINGRECORD-GR 960220 I 1 .... ............ D.S. 3-4 / PERFORATING RECORD 9 6 01 2 4 I 1 ........ , ....... ID.S. 3-28 J CHEMICAL CUTTER/PIPE RECOVERY '96021 9 I 1 ...... D.S. 4-26 -/ PATCH SETTING RECORD 9 6 0 2 2 4 I 1 D.S. 6-7 ~ PERFORATING RECORD 9 6 01 2 8 I 1 ....... D.S. 6-08A ~ PERFORATING RECORD 960206 1 1 ,D.S. 6-~)i~A ,/,' GR/CCL " 96011 8 I I ............ ...... D.S. 6-08A ~ COMPLETION RECORD 96011 8 1 1 D.S. 6-17 -'/ PERFORATING RECORD 960206 1 1 ,, D.S. 7-6A ~' PERFORATING RECORD 9601 06 1 1 D.S. 7-6A '~ POGLM SET RECORD 960115 1 1 ,, -- D.S, 11-18 ~'~ PERFORATION RECORD 96021 7 1 1 D.S. 14-15 '"" PERFORATION RECORD 960215 I 1 D.~i 15-25 '""' ITUBING'PA'I;(~HsETI'iNG RECORD ~)1~0~1 ~2 I 1 ...... D.S.' 7-03A ~'961 45 DUAL BURST TDT-P (BORAX.) 960504 . 1 'D.S. 7-15 ,~¢~61 1 2 , DUAL BURSTTDT-P (BORAX) 960406 1 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10228 Company: Alaska Oil & Gas Cons Corem Attn: Howard Oakland 3001 Porcupine Drive Anchorage, AK 99501 6/6/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter !D'.s. 11-13A~'"~iJj ' 96144 ''CNT-D 960506 ...................................... 1 D.S. 3-33 # '~/~ 96056 . CNT-D . .. 960214 ........... .: 1 D.S. 1-15A ----' PROD PROFILE 960515 1 1 D.S. 1-17A :~-" TEMPERA'I~JRE 960505 I 1 D.S. 1-19 ,-/' PROD PROFILE 960425 I 1 D.S. 2-2 ........ PERF RECOI:iD 96051 I 1 1 D.S. 2-4 ~- .... rPERF~{ECORD 960507 I 1 D.S. 2-10....... P~F RECORD 960507 I 1 ......................... D.S. 2-25 ~.-~' PROD I~ROFiLE 960427 1 1 ........ D.S. 3-12 ~" I~EC PRC~FiLE 960501 I 1 .............................................. D.S. 3-17 .... INJEC PR(~F~LE 960501 I 1 ~ , , D.S. 4-30 ST . .... -' CNT-D 960510 I 1 .............................. D.S. 5-16A ~ ..... ' TBGPAT(;tl &POGLM ~960426 I 1 ..... - . _ ............. D.S. 5-25 - · DUAL ~ui{s"r T[)T-P 960425 I 1 D.S. 6-08A ..... PROD PR(,~ii_E 960424 I 1 ............................. D.S. 6-23 '--' .... PROD PR(,F~LE 960424 I 1 ............................ D.S. 11-13A ..... CNT-D 960506 I 1 D.S. 11-23/[ ~-' LEAK [)E~ ECTIOH 960506 I 1 ......................... I .... D.S. I 1-30 ..... PERF I:~EC, ~t ~D 960510 1 1 ............. -- ...... D.S. 15-39 ~ PROD PR( ;~:iI.E 960430 1 1 ...... ~D.S. 16-5 ...... ' __~ PERFRECd~ 960504 .~ 1 . - .~" :~'~. ~ ;.-'; ~ ' _ ~ , ..,. D.S. 18-01A ~/ P~FRECOr{D 960501 I 1 ..... D.S. 18-34 ~' PRODPRC,FtLE 960427 1 1 '. ~ ~ ' ' / ............. . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,I/ELL COMPLETION OR RECOMP LETION 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. 95-210 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20287-01 4. Location of well at surface ~"~r' 9. Unit or Lease Name ! Prudhoe Bay Unit 4852' NSL, 4589' WEL, SEC. 8, TION, R15E : ..:..:... ':- ~ lO. Well Number At Top Producing Interval 3885'NSL, 4052' WEL, SEC. 8, TION, R15E. 11. Field and Pool . At Total Depth : :" ........ ':i-;I '! Prudhoe Bay Field/Prudhoe Bay Pool 3682' NSL, 4046' WEL, SEC. 8, TION, R15E::; : 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65.20 ADL 028329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 01/17/96 01/21/96 02/20/96I N/A feet MSLI One 117. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDi 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 9420'MD/9197'TVD 9323'MD/9106'TVD YES [] NO []I 2217 feet MDI 1900'(Approx.) 22. Type Electric or Other Logs Run GR, CN, DAL, DLC 23. CASING, LINER AND CEMENTING RECORD SE'I-RNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 119' 30" 225 sx Arctic Set 13-3/8" 72# N-80 Surface 2693' 17-1/2" 5800 sx Permafrost II 9-5/8" 4 7# N-80 Surface 8100' 12-1/4" 830 sx Class 'G' 7" 29# NTSOS 7935' 9420' 8-1/2" 287 sx Class 'G' 241 Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 7894' 3-3/8" Gun Diameter, 6 spf 4-1/2" 8753' 8698' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9226'- 9236' 9015'- 9024' Freeze Protect w/160 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) .February 20, 1996 Gas Lift Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO ]'EST PERIOD 1 Flow Tubing Casing Pressure 3ALCULATED,~ DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Al~ska 0]] & Gas Cons. Commission Anchora,~e Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sadlerochit 8866' 8682' Sadlerochit Zone 3 9082' 8881' Sadlerochit Zone 20 9142' 8936' Sadlerochit Zone 2B 9207' 8997' Sadlerochit Zone lB 9406' 9184' RECEIVED At~ska 0il & Gas Cops. Commission Anchorage 31. LIST OF A'FFACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -,'Lt-/~/-¥ ¢ ~ ', Title Senior Drilling Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: 01-1 5A Rig Name: Doyon 16 AFE: Accept Date: 01/1 2/9 6 Spud Date: 01/1 7/9 6 Release Date: 4J8032 01/26/96 Jan 12 1996 (1) Repaired Drillfloor / Derrick. Rig moved 100 %. Rigged up High pressure lines. Removed Hanger plug. Jan 13 1996 (2) Removed Hanger plug. Held safety meeting. Circulated at 8310 ft. Circulated at 8310 ft. Installed Hanger plug. Removed Xmas tree. Rigged up BOP stack. Tested BOP stack. Jan 14 1996 (3) Held safety meeting. Tested BOP stack. Rigged down High pres- sure lines. Retrieved Hanger plug. Pulled Tubing on retrieval string to 8310 ft. Circulated at 8230 ft. Installed Emergency hang off assembly. Tested BOP stack. Held safety meeting. Re- trieved Emergency hang off assembly. Circulated at 8230 ft. Laid down Tubing to 8230 ft. Rigged down Tubing handling equipment. Jan 15 1996 (4) Held safety meeting. Singled in drill pipe to 8358 ft. Drilled installed equipment - Bridge plug. Held safety meeting. Ser- viced Block line. Pulled out of hole to 8349 ft. Pulled BHA. Made up BHA no. 1. R.I.H. to 8349 ft. Circulated at 8349 ft. Jan 16 1996 (5) Circulated at 8349 ft. Pulled out of hole to 8100 ft. Milled Downhole equipment at 8100 ft. Circulated at 8150 ft. Pulled out of hole to 8150 ft. Pulled BHA. Pulled BHA. RECEIVED Jan 17 1996 (6) Alaska 0il & Gas Cons. Commissior] Anchorage Held safety meeting. Ran Drillpipe in stands to 8250 ft. Circu- lated at 8250 ft. Mixed and pumped slurry- 32 bbl. Held 2000 psi pressure on 32 bbl squeezed cement. Pulled out of hole to 7134 ft. Held safety meeting. Pulled out of hole to 0 ft. Ser- viced BOP stack. Made up BHA no. 2. Tested M.W.D. tool - Via string. R.I.H. to 7700 ff. Washed to 7864 ft. Drilled cement to 8105 ft. Operations Summary for: 01-. _,-t Jan 18 1996 (7) Drilled cement to 8105 ft. Drilled to 8150 ft. Drilled to 8160 ft. Drilled to 8168 ft. Circulated at 8168 ft. Serviced Draw works. Pulled out of hole to 723.66 ft. Pulled BHA. Made up BHA no. 3. Jan 19 1996 (8) Held safety meeting. R.I.H. to 8105 ft. R.I.H. to 8160 ft. Drilled to 8218 ft. Circulated at 8218 ft. Pulled out of hole to 8100 ft. Serviced Fluid system. Circulated at 8218 ft. Ser- viced Mud shakers. Drilled to 8570 ft. Jan 20 1996 (9) Drilled to 8872 ft. Circulated at 8872 ft. Pulled out of hole to 8100 ft. Circulated at 8100 ft. Pulled out of hole to 0 ft. Tested BOP stack. Pulled BHA. Made up BHA no. 4. Jan 21 1996 (10) Held safety meeting. R.I.H. to 1500 ft. Pulled BHA. Made up BHA no. 4. R.I.H. to 8100 ft. Serviced Block line. R.I.H. to 8800 ft. Drilled to 9244 ft. Jan 22 1996 (11) Drilled to 9266 ft. Pulled out of hole to 8100 ft. Serviced Main engine. R.I.H. to 9266 ft. Drilled to 9420 ft. Circulated at 8420 ft. Pulled out of hole to 197 ft. Pulled BHA. Rigged up Wireline units. Ran electric logs. Jan 23 1996 (12) Ran electric logs. Rigged down Logging/braided cable equipment. Rigged up Casing handling equipment. Ran Casing to 1486 ft (7 in OD). Circulated at 1486 ft. Ran Casing on landing string to 8100 ft. Circulated at 8100 ft. Ran Casing on landing string to 9410 ft. Circulated at 9410 ft. Mixed and pumped slurry - 61 bbl. Circulated at 7924 ft. Pulled Drillpipe in stands to 7924 ft. Made up BHA no. 5. RECEIVED ~/~R 2 ~ I99~ Alaska 0il & Gas Cons. Commission Anchorage Page 2 Operations Summary for: 01-. _A Jan 24 1996 (13) Held safety meeting. Made up BHA no. 5. R.I.H. to 9230 ft. Washed to 9253 ft. Drilled cement to 9323 ft. Circulated at 9323 ft. Circulated at 9323 ft. Tested Casing - Via string. Pulled out of hole to 8200 ft. Held safety meeting. Pulled out of hole to 7927 ft. Circulated at 7927 ft. Pulled out of hole to 0 ft. Rigged up sub-surface equipment- Mechanical packer. Pulled Drillpipe in stands to 7924 ft. Tested Mechanical packer - Via annulus and string. Jan 25 1996 (14) Tested Mechanical packer- Via annulus and string. Laid down Drillpipe to 0 ft. Rigged up Tubing handling equipment. Held safety meeting. Held drill (H2S). Ran Tubing to 7000 ft (5.5 in OD). Jan 26 1996 (15) Held safety meeting. Ran Tubing to 8753 ft (5.5 in OD). Re- trieved Hanger plug. Rigged down BOP stack. Pulled Hanger plug. Held safety meeting. Circulated at 8753 ft. Set Permanent pack- er at 8698 ft with 4000 psi. Circulated at 2200 ft. Retrieved Hanger plug. Rig moved 70 %. Page 3 RECEIVED MAR 2 6 1996 Alaska Oil & t3as Oons. Oommission Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10044 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 2/23/96 ~/~'"' ~/ ~) Field: Prudhoe Bay '~ Floppy Well Job # Log Description Date BL RF Sepia Survey Performance Disk Calculation Letter D.S. 1-15A MWD DIRECTIONAL SURVEY 9601 22 . . 2 ! ~ , ,, , ., , ..... , ., , ...... ... .. , . SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Aschorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 February 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 DLL FINAL BL+RF 1 CN FINAL BL+RF 1 DAC FINAL BL+RF ~-~ 1 SSVD FINAL BL+RF~ 1 DIFL FINAL BL+RF~'~ 1 CN FINAL BL+RF c-~ 1 DAC FINAL BL+RF C--/ 1 SSVD FINAL BL+RF---~ Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6581.00 6584.00 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 A Or FAXzto (907) 563-7803 ~n-~/ ~~/ Date: 1996 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 29 January 1996 Transmittal of Data ECC #: 6581.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: 1-15A NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Received by: ~_ Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 0r~(907) 563~7803 ~ Date: Cu V.ED FEB O O iS~ Alaska Oil & Gas Cons. Commission Anchorage - . 1111 E. 80th Ave. Anchorage, Alaska 99518 TEL (907) 349-4511 FAX (907) 349-2487 Shared Service Drilling P.O. Box 196612 Anchorage, AK. 99519-6612 ATTN: Mr. Mark Johnson Here is a summary of Anadrill's Performance on 01-15A. JANUARY 23, 1996 SERVICES PROVIDED: Anadrill's 6-3/4" Directional Survey Service (DSS) was picked up on 1-16-96 at the cement plug at 7865'. DSS was utilized for the kick-off and the tangent section to TD on 1-21-96. Surface sensors used to monitor ddlling parameters throughout the side track included surface weight on bit (SWOB), pump pressure, pump stroke, and depth. OPERATING STATISTICS: MWD operating time for the well totaled 71.76 hours. MWD footage totaled 1555 accomplished in 4 MWD runs. There was 1 MWD failures recorded. The Anadrill crew assigned to the well worked over 123 man hours with no LTA's, minor injuries, or near misses. JOB PERFORMANCE: The well was kicked off at approximately 8105' MD. Magnetic interference from the original well rendered our magnetic readings unusable until 8521' MD at which point the interference had ceased. The well was directionally drilled to target. Anadrill's final MWD survey station calculation yielded: MD 9386.95' TVD 9165.81 INC 19.67 LAT 1158.44 S AZM 176.11 DEP 541.79E DISP 1278.87 at AZM: 154.94 SHOCK Anadrill continually measures and monitors downhole shock in the excess of 50 g's on the MWD tool. By providing an indication of the adverse downhole conditions MWD tool life is prolonged and BHA fatigue is minimized. Moderate shocks were encountered throughout the kick off. Anadrill appreciates the opportunity to provide Shared Services Drilling with MWD services. As always Anadrill is seeking to improve on the service quality and welcomes any comments or suggestions you may have to serve you better in the future. ,~.incere, ly/ Martin Varco Alaska District Manager Field Service Manager Craig urown Cell Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend . Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging. X Time extension ~ Stimulate ~ Change approved program Pulltubing Variance . . Perforate Other · Plugback for Sidetrack 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development x Plan RTE = 65.2 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4852' NSL, 4589' WEL, SEC. 8, TION, R15E At top of productive interval 1330'SNL, 1272' EWL, SEC. 8, TION, R15E At effective depth At total depth 1543' SNL, 1266' EWL, SEC. 8, TION, R15E DUPLICATE 1-15 9. Permit number 78-07 10. APl number 50- 029-20287 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical 9570 feet Plugs (measured) 9376 feet Effective depth: measured true vertical 9495 feet Junk (measured) 9306 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 119' 20" 225 sx Arctic Set 119' 2693' 13-3/8" 5800 sx Permafrost fl 2693' 9537' 9-5/8" 830 sx Class 'G' 9537' True vertical depth 119' 2693' RECEIV measured Squeezed: 9085'o 9100', 9115'- 9165', 9180'- 9190', 9190'- 9210' Open: 9220'- 9230', 9246'- 9256' IDEC 1 8 1995 true vertical Open: 9045'- 9055', 9070'- 9080' Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 to 8535'MD; 4-1/2" 12.6# L-80 8535'to 8652'MD Packers and SSSV (type and measured depth) 5-1/2" Camco BAL-O SSSV Nipple at 2189~ 9-5/8" x 5-1/2" Baker SAD Packer at 8524' 13. Attachments Description summary of proposal × Detailed operations program . BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: December 27, 1995 16. If proposal was verbally approved Oil X Gas ~ Suspended ~ Name of approver Date approved Service 17.1hereby ~at the fo~7/d correct to the best of my knowledge. ~,~,,,~,~/,~:/fC,~r'K;,, O. ~ J,"'~_.¢.~ ,.¢~.¥"~'~;>~ Title Senior Od/ling Engineer Date Signed , FOR COMMISSION USE ONLY Conditions of approval: Notify. Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Approved Co~'pprOval IA No. Mechanical Integrity Test Subsequent form required 10- .~O"7 Retl~rned, Approved by order of the Commission David W. Johnston Commissioner Date .... Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ALASI A OIL AND GAS CONSERVATION COMMISSION December 21, 1995 TONY KNOWL£$, GOVERNO?t 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stoltz Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 1-15A ARCO Alaska, Inc. Permit No: 95-210 Sur. Loc. 4852'NSL, 4589'WEL, Sec. 8, T10N, R15E, UM Btmhole Loc. 3682'NSL,. 4013'WEL, Sec. 8, T10N, R15E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE C ISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-]llb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II 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 = 65.2 fe et Prudhoe Bay Field/Prudhoe 3. Address 16. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028329 4. Location of well at surface ~7. Unit or property Name 11. Type Bond(see 2o ^AC 25.025) 4852' NSL, 4589' WEL, SEC. 8, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3735'NSL, 4016' WEL, SEC. 8, TION, R15E 1-15A U-630610 At total depth 9. Approximate spud date Amount 368ff: NSL, 4013' WEL, SEC. 8, TION, R15E 12/27/95 $200,000.00 12. Distance to nearest [13. Distance to nearest well 14. Number of acres in propertY115. Proposed depth (MD and TVD) property line ADL 028330 3681' feet No Close Approach feet 2560 9390' MD/9165' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o ^AC 25.035 (e)(2)) Kickoff depth 8~o5 feet Maximum hole angle 23 o Maximum surface 2570 psig At total depth (TVD) 8800'/3450 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 B TC-M 1440' 7950' 7822' 9390' 9165' 245 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 Measured depth True Vertical depth Structural Conductor RECEIVbu Surface Intermediate Production OEO 18 1995 Liner Perforation depth: measured Alaska Oil & Gas Cons, Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid prog~.rn [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby c~rf[fl///that~rue_ and correct to the best of my knowledge I.?~,r,o~u,: ,~.,4~14 To~.l.,~so~v Signed ,,(~t,,,~.~_,,¢,,,7 .~~,~~ Title Senior Drilling En~Tineer Date / Commission Use Only Permit Number IAPI number IApproval date_, See cover letter ¢~'-~_.,/4::~ 150-~'2'-~ - 2'~"~'~'-~! I [,¢~ c~,/ f~)~for other requirements Conditions of approval Samples required [] Yes ~No Mud Icg required []Yes [] No Hydrogen sulfide measures ~)' Yes [] No Directional survey required ~ Yes [] No Required working pressure for BOPE [] 2M; FI3M; ~5M; I-I10M; I-I15M; Other: -,~?~glr~al Signed By by order of Approved by 0avid W. Johnston Commissioner me commission Date/,.~, Form 10-401 Rev. 12-1-85 Submit in triplicate I Well Name: ]DS 01-15A Redrill Plan Summary Type of Redrill (producer or injector): I Producer Surface Location: Target Location: 4852' FSL 4589' FEL S08 T10N R15E UM 3735' FSL 4016' FEL S08 T10N R15E UM Bottom Hole Location: 3682' FSL 4013' FEL S08 T10N R15E UM [AFE Number: 14J8032 I Estimated Start Date: I Rig: I Doyon 16 12/27/95 [ I Operating days to complete: I 15 I MD: 19,390 [ I rrvD: 19165' [ [KBE: 165.2' Well Design (conventional, slimhole, etc.): Conventional Sidetrack Objective: I Repair tubing integrity, gain access to lower GOR/WC production Mud Program: Special design I Gel-free 6% KC1Biozan Fluids considerations I Density PV YP INT 10MIN FL OIL SOLIDS (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP 9.9-10 14 55 30 40 7 0 7 to to to to to to to to to TD 9.9-10 15 LSR 5 20 30 5 0 7 Directional: I KOP: 18~0~ M~ [ Maximum Hole Angle: 1 23° Close Approach Well: NONE Casing/Tubing Program: RECEIV't:L~ I ~laska ~i & ~as Cons. ~mm~ion ~r~e Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfrVD MD/TVD 8.5 7" 29# L-80 BTC-M 1440 7950/7822 9390/9165 Tubing 5.5" 17# L-80 BTC-M 8800' 0/0 8800/8620 Cement Calculations: Liner Size: 1 7" [ Basis:] Calculate cement ~,olume to bring top of cement to 7" liner top hanger using 50% open hole excess, 80' shoe joint. Total Cement Volume: @ 245 sxs of Class G Blend @ 1.19 ft3/sx I I I Basis:] Total Cement Volume: Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Hazards: H2S: DS-1 is not an H2S pad. Last reading on 1-15 was 4 ppm (10/28/94). Highest reading on pad was from 1-07 at 60 ppm on 1/1/95. Pore Pressure: Sadlerochit pore pressure is expected to be -3450 psi at 8800' TVDSS or equivalent mud weight of 7.6 ppg. The maximum anticipated surface pressure assuming 0.1 psi/ft gas gradient is 2570 psi. Lost Circulation: Potential LC when cutting through the Sag/Shublik interfaces. SUMMARY REDRILL PROCEDURE: 1. Move in drilling rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. 2. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. 3. Install a BPV and test dart. Test to 1000 psi from below. Remove the production tree. 4. Install BOP's and test to 250 psi/5000 psi. Remove test dart & BPV. 5. Pull and lay down the 5-1/2" tubing from the cut to surface. Inspect for NORM prior to moving off the location. 6. Set mechanical set bridge plug at 8335' DPM. 7. Displace to milling fluid. 8. Section 9-5/8" casing starting @ +8100'. RECEiV't::t Alaska 0il & Gas Cons. Commission Anchorage , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Spot a balanced cement kick-off plug (190 cubic feet minimum) through open- ended drillpipe from 150' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the target per the attached directional plan. At TD run triple combo logs. Run a 7" 29# L-80 liner assembly to bottom in the 8-1/2" hole and space the liner hanger about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon bringing cement to the top of 7" liner and using 50% open-hole enlargement plus the 80' shoe volume. Estimated cement volume is 245 sx using 1.19 yield. P/U 6" bit and clean-out 7" liner to TD. Run the 5-1/2" L-80 completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. Test tbg to 4000 psi. Install a BPV and test dart. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test dart and BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production RECEI'VEL 0EC 1 8 1995 AJask~ Oil & Gas Cons, Commission Anchorage 18 1995 Cons, Commission Anadrill Schlumberger Alaska District 1111 East 80th Avenue Allchorage, AK 99518 (907) 349-4511 Fax 344-2160 Anchorage DIRECTIONAL WELL .PLAN for SHARED SERVICES DRILLING Well ......... : DS 01-15A (P3) Field ........ : PRUDHOE BAY, DS 01 Computation..: Minimum CurvatUre Units ........ :.FEET Surface Lat.,: 70.24150195 N Surface Long.: 148.40071947 W LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 4853 FSL 4590 FEL S08 T10N R15EUM 698012.50 5940477.95 Tie-in/KOP...: 4165 FSL 4061 FEL S08 T10N R15E UM 698561.90 5939805.00 TARGET ....... : 3735 FSL 4016 FEL S08 T10N R15E UM 698620.00 5939376.00 BElL .......... : 3682 FSL 4013 FEL S08 T10N R15E UM 698624.51 5939323.21 Prepared ..... : 12/15/95 Vert sect az.: 176.62 KB elevation,: 65.20 ft Magnetic DCln: +28.674 (E) Scale Factor.: 0.99994454 Convergence..: +1.50516908 ANADRILL AKA-DPC APPROVED DEO 1 5 1995 STATION IDENTIFICATION TIE-IN SURVEY TOP OF WINDOW KO~ CURVE 4/100 PROPOSED WELL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTH ANGLE AZIFFOTH. TVD SUB-S DIST 8036 15.75 8100 15.57 8105 15.56 8200 17.72 8300 20.50 150.00 7904 7839 717 152.76 7966 7900 733 152.98 7970 7905 734 163.93 8061 7996 760 172.74 8156 8091 792 COORDINATES-FROM WELI/iEAD STATE-PLANE TOOL DL/ X Y FACE 100 687.19 S 531.56 E 698561.90 5939805.00 105R <TIE 702.30 S 539.81 E 698570.54 5939790.11 102R 1,20 703.50 S 540.42 E 698571.18 5939788.93 61R 1.20 728.74 S 550.21 E 698581.63 5939763.95 50R 4.00 760,75 S 556.64 E 698588.90 5939732.13 42R 4.00 END 4/100 CURVE 8355 22.18 BASE HRZ 8530 22.18 TOP SAG RIVER 8763 22.18 SHUBLIK 8800 22.18 TSAD/IVISHAK / Z4/48 8878 22.18 176.62 8207 8142 812 176.62 8369 8304 878 176.62 8585 8520 966 176.62 8619 8554 980 176.62 8691 8626 1010 780.58 S 558.46 E 698591.24 5939712.36 846.59 S 562.36 E 698596.87 5939646.47 934.48 S 567.55 E 698604.37 5939558.75 948.31 S 568.37 E 698605.55 5939544.94 977.61 S 570.10 E 698608.05 5939515.70 4.00 0.00 0.00 0.00 0.00 0 $ O I I '0 (3 tOP ZONE 4A/X-RAY 8991 22.18 176.62 8796 8731 1052 1020.34 S 572.63 E 698611.70 5939473.06 0.00 :Anadrill (c)95 0115AP3 2.5b.04 1:00 PM P) DS 01-15A (~3) sTATION IDENTIFICATION MEAS DEPTH INCLN ANGLE TOP ZONE 3 9095 22.18 TOP ZONE 2/2C 9139 22.18 TZ 2B/TANGO / PGOC 9206 22.18 TARGET-50 FTRADIUS 9249 22.18 TOP ZONE '2B/TANGO 9249 22.18: P°WC 9274 22.18 TOP HOT 9293 22.18 OOWC 9316 22.18 TOP ZONE 2A/ROMEO 9342 22,18 TZONE lB~LOWER ROMEO· 9385 22.18 9390 22,18 BASE SAD / KAVIK DIRECTION AZ IMUTH PROPOSED WELL PROFILE VERT-DEPTHS SECT TVD SUB-S DIST 176.62 8892 8827 176.62 8933 8868 176.62 8995 8930 176.62 9035 8970 176.62 9035 8970 176.62 9058 8993 176.62 9076 9011 176.62 9097 9032 176.62 9121 9056 176.62 9161 9096 176.62 COORDINATES-FROM WELLHEAD 1091 1059.40 S 574.93 E 1108 1076.08 S 575.92 E 1133 1101.31 S 577.41 E 1150 1117.58 S 578.37 E 1150 1117.58 $ 578.37 E 11'59 1126.94 S 578.93 E 1166 1134.27 S 579.36 E 1175 1142.81 S 579.86 E 1185 1152.58 S 580,44 E 1201 1168.85 S 581.40 E 9165 9100 9242 9177 1203 1170.48 S 581,50 E 12/15/95 Page 2 STATE-PLANE TOOL X Y FACE 698615.03 5939434.08 698616.45 5939417.43 698618.61 5939392.25 698620.00 5939376.00 698620,00 5939376.00 698620.79 5939366.66 698621.42 5939359.35 698622.15 5939350.83 698622.98 5939341.08 698624.37 5939324.84 698624.51 5939323.21 DL/ lOO 0.00 o.oo 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0 I I O Rur"EIVkV 18 1995 klaa.~ u, a ua~ Cons. Commission Anchorage APPRO'.'FD. DEO 1 5 !99 Anadrill (c)95 0115AP3 2.5b.04 l:00 PM P) Dec-15-95 15:22 'Anadrill DPC 907 344 2160 P .04 SHARED 'SERVICES DRILLING OS O - SA (P3) VERTICAL SECTION VIEW Section at: J76.62 TVD Scale.: 1 inch = 1200 feet Der Scale.: J inch = ~200 feet Drawn ..... : ~2/15/95 ,4nadrJ 1] Sch]uf~berger' Marker Identification MD BKB SECTN INCLN Al TIE-IN SURVEY 8036 7904 7t7 ~5.75 B) TOP OF WINDON 8100 7966 733 15.57 C) KOP CURVE 4/~00 8105 7970 734 15.56 O) ENO 4/100 CURVE 8355 8207 8J2 22.~8 EJ TARGET-50 FT RADIUS 9249 9035 J150 2~,~8 FI TD 9390 9~65 ~203 22. ~8 AK, )PC i 10200- 10800 0 600 t200 $800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Section Departure /madrJ]] (c)95 0II5AP3 ~.5~.03 1; 0~ PM PI Dec-15-95 15:23 Anadrill DPC 907 344 2160 P.05 ! - SHAi~ED SERVICES DRILLING · Ul i i ii i i ,~oo-- ,"" I ' ~ DS 01- ~SA (P3) ,, , i VERTICAL SECTION VIEW 7900 ............................ A- .......... Section st: ~76.62 . . m TVD Scale.: J inch = 200 feet 8ooo-- Dep Scale.: ! inch : 200 feet Drawn ..... :. ~2/J5/95 8~oo .......... \\ ....... , .. ~ :~ ~nadr~ 11 SchYumb~rger 82oo-L ~ ~~ ~~ ~t .... FRM INC 15 66' TO I I~ ......... · · N .... 'mo , ~M ~ 152.98' ..... ~ ..... ' '~'k"- ......... 836, 9036 "~LL TANGENT TO TARGa. 0'~D ~ 8400- ?~ ~' ~ , , TO AZ 176.62, FRM 7970' ~ TO 82 ' K , , ~ , HOLD lNG 22.18', ON M 1~.. - B 8500-~ ........ HOLD INC 22.18', ON ~ 178.62', ......... FRM 9036' ~ TO 9165' ~D (9100' 8600 ~m~rv 8700- ~/r~n r~F ~j,~ ~ .... .. .. , ~ . '~ .. . .... 9000-h7-~~ '~ ~ ,~ ........................... .... . · '~ ~ ~3 - ~! J ..... , - ~ ~ ...... - .......... '~,::~;::::~:::::; .-~--- 'm~ ~ ~¢~ ' ~', : -~ ...... .~ .......... 9200-- ., , $ ; , 'e~r ~¢/~vl~ ~4~ ...... ~........................ · ........... ~ ..... AN, qDRILL AKA-DPC ~ 9300 ,t~:R'~~,_E[) ~ ~~CEiV', E'u .... ! .... k 9400- ~ ~ ~ "~ : ~ ; ; ', DEC 1 8 ~99~ - '--~'--~ -' ~.. 400 500 600 700 800 900 JO00 ~ ~00 ~200 J300 J40O ~500 ~600 ~700 ~800 Section Depa¢tu¢e Dec-15-95 15:23 Anadrill DPC 907 344 2160 P.06 -SHARED SERV:[dES DRiLLIN$ '1 · i · iii i · i i [ i i i i i 8) TOP OF WINDO, 8,00 702 540 ~o~ cu.v~ ~/~oo . ~,os 703 s~o PLAN VIEW ~I END 4/'00 CURVE 8355 78'' 558 " ' El TARGET-50 FT RADIUS '92~9 1118 578 CLOSURE · 1307 feet at Azimuth 153,58 Fl TO 9390 1170 5B1 DECLINATION.' +28.674 (E) SCALE ' ~ inch = 200 feet . DRA~N · ~2/15/95 Anadri ]] Sch]umberger ¢ ~00 ............ r .......... ~ ................. ~ - '' 0~ ~~ - ' - - ~ . · ' _. 9 too-- ~-. ~ .~ _. ....... ~ ........... cOO- - ! " ~NADR~LL j , A (A-DPC aoo- - -vvJAA- -- ~l , : ' "" 500 ................ ~- . ; ............... 600-- ,, 1 700 ............. · ~ - . ~oo-- ' ~ ~ .u~,. , ~ ..~ ' goo .... ) ] Na: ;ka Oil & (;m ~ns. ~mm~s on ............ I ) I t000 , ' . ~ ' ~ 5( FT RADI[IS ~00 ................... ¢ , , . 100 0 100 200 300 400 500 600 7'00 800 900 1000 1100 1200 1300 <- WEST · EAST -> Dec-15 95 15:23 Anadrill DPC 907 344 2160 P.O7 · SH"ARED SERVICES DRILLING 'I ii ii i · i i S A' (P3) ,.r.,,.,-,,,,..,,,,~.,:,o. ,,:, ,,s PLAN VIEW ~I ~o, co.v[ ./~oo ~o~ m 5,0 " D) ENO 4/~00 CURVE 8355 78t 558 CLOSURE.. .... : J307 feet at AZimuth ~53.58 E) TARGET-50 FT RADIUS 9249 1~8 578 F) TD 9390 1170 5B$ DECLINATION.' +28.674 ' (E) SCALE · I inch : 100 feet DRAWN ' $2/~5/95 i i! ii ~nadri 11 Sch] 600 ., -.. ~ .~, ..... fifiO ......... ~ --~ ~ ..... ~ ............ .~ 700 ~,NADRI.L j ' 'AX~-DPC ~t .., ~ pP,~VE'D X , i b 750 ...... I .... { ....... ~ .......................... ~Nff~,~~,~ ' ~ .... , / . I I ' ....................... 850- ...................... ~ ~ ..... } .. · I 900- · ~ ~ ' I I I ~ I 950-- ~ ........ i , I I ~ ', .' ~ . . '1050 ..... ' ........... , .... __ .... ~ ..... 11oo .I ,E , ,,50 ........................ ' ............ , ~ ~ ~ ,~i~i_= jVt :'U-' ,--' i 1200 ' ., ' - ~ ~ , ~ . .~~ .-: ....... ~ .... / : I 200 250 300 350 400 450 500 550 600 650 700 750 800 850 gOO EAST -> II (~aOrj]) (c}65 0~i5AP3 2,5D.03 1:04 ~4 P) Anaari I I DPC 907 344 2160 P. O~, Anadrill Alaska District Directional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS INCLUDING ELLIPSES OF UNCERTAINTY Client .............. : ARCO ALASKA INC Well Name ....... : DS01-15A{P03) Field ................ : PRUDHOE BAY County/state..: BEECHEY POINT, ALASKA APl# ................ :50-029-20287-01 Anadrill ID# ......: 500292028701P0303 Planned W~l Survey Program Sta~ End Type Interval 0 8105 GCTG 8105 9390 MEWD 93 Date Calculated ..... : 12/14/95 16:05 Date Plotted ..........: 12/14/95 16:07 KBE ..................... : 65.20 Grid X .................. : 69801 2.50 Grid Y .................. : 5940477.95 Grid Zone .............: ASP ZONE 04 i MIN. i FLOWING i PLUGGED ENTER ENTER EXIT EXIT CLOSE OFFSET WELL FLOWING ! ELLIPSE SURVEY SAFETY j SAFETY PLUG I NO DRILL NO DRILL PLUG APPROACH 'SAFETYI SEP. SEP. MD TVD DIST. i DIST. ZONE ZONE ZONE ZONE STATUS ,{ SEP. MD MD MD MD 01-1 5 -174,1 : -97.3 16.1 8341 8194 76.7 20.9 i -8 -8 i NO DRILL 01-02 -71.8 -15.1 60.6 4668 4667 56.7 ~ 11.7I 4463 4553 4773 ' 4877 NO DRILL 01-22A -9.0 44.9 101.6 4384 ; 4383~ 53,8 i 11,0 4290 '! i 4472 PLUG 01-22 ~ -5.4 48.5 ' 101,8 4384 i 4383 I 53.8[ 11.0 4307 = 4451 PLUG 01-32 ! 9.5~ 44.7 73.4 2519 2519 35.2I 6.3 ! ' FLOW 01-33 ~ 11.4 ! 46.9 75.9 2545 2545 35.5 I 6.4 FLOW 01-16 ; 56.7 : 101.4 141.1 ~ 3466 3465 I 44.7I 8.7 I [FLOW , 01-14 i 83.5 ' 118.2 146.4 i 2468 2468 34.7i 6.2 i I FLOW , 01-17 } 126.0 ! 176.4 222.5i 4041 4040 50.4i 10,1' FLOW 01-03 ~ 204,8- 256.9I 327.8 ~ 4202 4201 52.0 10.5; FLOW 01-13 : 167.0 204.4 235.7 . 2743 ! 2743 37.4 6,9 i I ' FLOW DS 01-03A(P01) 234.8 - 286.5 326.4 4172 4171 51,7 . 10.4 I " FLOW 01-21 146.9 176.7 i 199.3 1986 1986 29.8 ! 5.0I ' ' · FLOW 01-23 ' 201.8 : 239.1 270.4 i 2734~ 2734 37.3 : 6.8 ! FLOW 01-20 211.6 241.7 264.6I 20141 20141, 30.1 i 5.0 ~ ;FLOW 01-12 297,0 334,4I 365.7 2744 2744 37.4 I 6.9 · ' :FLOW 01-19 302.6 338.4 ', 367.9 2585 J 2584i 35.8 i 6.5 FLOW 01-24 299.3. 333.7i 361.5 2436I 2436, 34.4 6.1 ,FLOW 01-24A 299.6I 334.0I 361.8 2436j 2436! 34.4 6.1 : FLOW 01-04 516.3/ 572.4 , 625.1 4609J 4608' 56.1 11.5I I iFLOW 01-11 406.9 I444.6 476.1~ 2769 j 2769 i 37.7 6.9 01-25 397.2 433.1 462.6 2586 - 2586: 35.9 6.5 i J FLOW I FLOW 01-29 715.9 783.4 863.7 6517 i 6465 ~= 67.6 16.3 I ~ FLOW 01-26 499.1 541.7 579.1 3262 i 3261 ! 42.6 8.2 01-01 624.3 664.2 698.2 2989 ; 2988 i 39.9 7.5 I FLOW : ' FLOW 01-07 762.4 809.9 861.8 3756 , 3755~ 47.6 9,4 j i FLOW 01-05 635.8, 674.8, 707.5 2894 2893 38.9 7.2 ;FLOW 01-01A 633,8, 671,4 i 702.6 27611~' 2760i 37.6 6.9, FLOW 01-06 697.7 739.1 774.7 3140 ! 3139 : 41.4 7.81 ~ I ~FLOW 01-07A 786,1 r 833.0 : 859.5: 3693 3692: 46.9 9.2 i/ i FLOW 01-018 641.1 678.7 702.7 2760' 2760i 37.6 i 0.9 I J FLOW 01-18 551.4 581.6 604.6 2020' 2020, 30.2I 5.1 I!, , FLOW 01-34 1125.5 1179.7 1230.0 4423- 4422! 54.2I 11.1 ' I , FLOW 01-31 1032,0 1079.1 ' 1121.2 3708 37071 47,1 ,, 9.3 I FLOW 01-30 1014.3 1059.9 1101.3 3554 · 3553!. 45.5 ' 8.9 I FLOW 01-28 889.2 925.7 955.8 2655 , 2655i 36.6 i 6.6 I I FLOW 01-08 970.9 1008.9 1040.6 2800i 2800 38.0: 7,0 , { , FLOW 01-09 1120,8 1159.6 1192.1 2874 i 2873 38.7 ' 7.2/ J FLOW 01-09A 1120.0 ~ 1158.5I 1190.7 ~ 2856/ 2855 38,6 : 7,1 I~1 · ' FLOW 01-10 1257.2 i 1297,0 ' 1330.6 ! 2973 I 2972 39.7 i 7.4 ' I FLOW ' ! ' i J i ' AKA-DP , . I ' . . I I , RECEI'V L ' ,, i Anchoi'~ige NOTES: All depths & distances are in FEET All depths ere referenced from well DS01-15A(P03) Min Flowing Safety Sap. is amount of additional clearance from flowing safety line. . 1 1 11 East 80th Avenue · Anchorage, Alaska 99518 * Telephone: (907) 349-451 1 * FAX: (907) 344-2160 ~5 15:25 Anadrill DPC 907 344 2160 P .O9 ~~m~z~u~., J Anadrill Alaska District Directional Well Planning Department NORMAL PLANE TRAVELLING CYLINDER RESULTS INCLUDING ELLIPSES OF UNCERTAINTY Client .............. : ARCO ALASKA INC Well Name ....... : O501-1 SA(P03) Field ................ : PRUDHOE BAY County/state..: BEECHEY POINT, ALASKA APl # ................ : 50-029-20287-01 Anadrill ID# ......: 500292028701P0303 Planned Well Survey Program Start End Type Interval 0 8105 GCTG 8105 9390 MEWD 93 Date Calculated ..... : 12/14/95 16:05 Date Plotted ..........: 12/14/95 16:06 KBE ..................... : 65.20 Grid X .................. : 698012.50 Grid Y .................. : 5940477.95 Grid Zone .............: ASP ZONE 04 0 z 0 1 I )1-22A 01 -O2 60( AKA-DP,C \lED 6600 9000- 9389.53 -20 40 50 60 70 80 90 100 NORMAL PLANE SEPARATION {1" = 20 ft) 1111 East 80th Avenue · Anchorage, Alaska 99518 · Telephone: (907) 349-4511 * FAX: (907) 344-2160 :WELL PERMIT CHECKLIST Poo , WELL NAME GEOL AREA PROGRAM: exp [] dev ~ redrll ~ serv [] / ON/O~ s~o~ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. -/ ~ 2. Lease number appropriate ............... 3. Unique well name and number .............. % Y 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... Y 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected 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 wait ....... REMARKS 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N 22. Adequate wellbore separation proposed .......... % N 23. If diverter required, is it adequate .......... ~=.~Y-----N--~J~ 24. Drilling fluid program schematic & equip list adequate . Y~ N 25. BOPEs adequate ................... si .~.~/~ N 26. BOPE press rating adequate; test to ~OZ~t~ p 'g.~ N 27. Choke manifold complies w/API RP-53 (Ma~ 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N APPR GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition su~ey (if off-shore) ......... /Y N 34. Contact name/phone for weekly progress reports . . ~ Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: TAB Comments/Instructions: HOWlljb - A:~FORMS~cheklist rev 11/95 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. RECEIVED .............................. AUG 22 1991 -k ...... SCHLUMBERGER ....... COMPANY NA24E : ARCO ALASKA, INC. r,'/ELL :'ff,~i']E ; D. S. 1 - 1SA FIELD z~:~-'.'"iE: PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API i,.TC~'~BER : 500292028701 REFE:~,ELrCE NO : 97356 LIS Tape Ve~£ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 ~ 35 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/08/19 ORIGIN : FLIC REEL NAME : 97356 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-1SA, API# 50-029-20287-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC 'TAPE NAME : 97356 CONTINUATION # : 1 PREVIOUS TAPE : CO~_~¥ENT : _a~CO rAI~SKA INC., PRUDHOE BAY, D.S. 1-1SA, APi# 50-029-20287-01 TAPE HEADE~ PRUDHOE BAY CASED HOLE WiRELii, IE LOGS WELL NA~,~E : D. S . 1 - 15A API NUMBER: 500292028701 OPEP~.TOR: ARCO ALASKA, INC. LOGGING COMP_A=~,F£: SCHLU?~BERGER ?/ELL SERVICES TAPE CREATION DATE: 19-AUG- 97 JOB ~?,IBER : 97356 LOGGING Ei.!G!i?EER ; G. JOHNSON OPEP~TOR ~:~ITi?ESS : K. St. GEt,~.iE SURFACE LOCATiO!,i TO~?iSi~iP : ! 0 i~L : 4590 2~',~L : ELEVATiOi? FT FROi¥ MSL O) ~ELL Y 5USHiZ,~S: 65.20 .gSC~i'?i L.E~L: 3~. 73 OPEi'.i HOLE CASi£.iG EP, ILLE_u.S CASiL~S HiT SiZE (I:V) SIZE (IN) DEPTH ~'FT] ~,:"EiGHT ,L5/':=¥' !S~ STP, iZ?G 9. 625 ~lO0.0 47. O0 29...'~~ ST_~.i~.iG 5. 500 7994. O l 7. O0 3RD STHI~IG 4 . 500 8753 . 0 12 . 60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Ve~Jication Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DAS LDWG CURVE CODE: GR RUN NUFiBER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 9246.0 9237.5 9209.0 9206.0 9205 5 9193 5 9189 5 9187 0 9179 5 9170 0 9i62 0 9160 5 9157 5 9141.0 9127.0 9112.0 91il.0 9079.5 9073.0 9061.0 9043.0 9042.0 9033.~ 9027.5 9025.5 9012.5 105.5 $ 19-AUG-1997 23~5 22-JAN-96 ATLAS WIRELINE .......... EQUIVALENT UNSHIFTED DEPTH GRCH NPHI 88888.0 88888.0 9246.0 9246.0 9238.5 9238.5 9209.5 9206.5 9194.0 9189.5 9188.0 9161.0 9141.5 9113.0 9206.5 9194. 0 9189.5 9188. 0 9179. 0 9170. 0 9161.0 9156.0 9141.5 9127.0 9113.0 9080.0 9080.0 9072.5 9072.5 9062.0 9062.0 9043.0 9043.0 9026.5 9021.0 9034.5 9028.0 9022.0 9000.0 9000.0 20!.0 lO!.O files, an average =~ss fiie ~n5 u3:z-ee ra~..- :~Ca f~Zes. ~ecr~a adjustments sho~..~ s~er Ci,7TG curves ~:ere c~z-rie~ ~.;irh the i'.?Hi shifus. Eassiine GR provided by the PAGE: LIS Tape Ve~£ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 ;~5 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~,,IBER: ! EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NO?~BER : ! DEPTH II,ICRE24ENT : 0.5000 FILE LDWG TOOL CODE ST_~T DEPTH STOP DEPTH GRCH 9266.0 8994.0 NPHI 9266.0 8994.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LD?IG CURVE CODE: NONE PASS i,.rO?,:rBER : BASELINE DEPTh- $ ......... EQUIVALENT UNSHIFTED DEPTH .......... l~ :~ CH NPHi RE!ff~KS: This fi2e ccn~ains Ci,!TG Pass sSnifus :..-~re spplied to this 5aEa. LIS FOPJ'.~T DATA TYPE REP;~ CODE ~i~L. UE i 66 0 2 66 0 3 73 64 4 66 1 LIS Tape Vez~£'ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23:35 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 t 4 65 FT 15 66 68 16 66 t 0 66 0 * * SET TYPE CHD3! * * i,!A~4E SERV ~ffIT SERVICE APi API API API FiLE i,!~.]B I,!O?.iB SIZE REPR PROCESS ID OP~ER # LOG TYPE CLASS MOD Z,I~iB S.~2.]P ELE;~ CODE (tfEX) DEPT FT 500758 O0 000 O0 0 1 1 1 4 68 0000000000 NPHi CNTG PU-S 500748 O0 000 O0 0 ! ! 1 4 6S 0000000000 ENPH CNTG PU-S 500755 O0 000 O0 0 ! i i 4 68 0000000000 CPHI C£,iTG PU-S 500755 NRAT CNTG 50074~ CP~AT CNTG 500758 EI, IRA CNTG S00748 OS 000 O0 0 1 i i 4 68 O000000OC, O NCNT Ci, ITG CPS 500748 O0 000 O0 0 ! ! I 4 68 O0000000C~ FCNT Ci~ITG CPS 500748 O0 000 O0 0 ! 2 i 4 68 O000000CCC CIffTC C~,ITG CPS 500748 O0 000 O0 0 ! i 2 4 68 O0000SO00t CFTC C~¥TG CPS 500748 O0 000 O0 0 i 2 ! 4 68 030000000.'5 CiffEC CNTG CPS 50 ~ 748 00 000 00 0 ! 2 ! 4 68 0.900009'? 0 .? CFEC C~,ITG CPS 50574~ GRCH C?ffTG GAPI 50074~ TENS CZv'TG £,,~ 59C74g '3.0 000 O0 0 i 7_ ' 4 68 09,3o~ ":,.'" ESL CZ,ZT:g V 5097z_~ * * DA TA * * SEPt. 92c~¥. 9GZ :7-z_"~Z. CZ'ITG !9.62- E:.-_~i~. 2_,'.'F.2: 26,. C,74 CP!:'ff . .."ex" -' /'.E~A T. CiiT,E 2.5 77 CRA T. SZ?TG 2.45 ~ E;75:A. E~'77'~5. d; :-'5 _'.'.7/.'¥. ~ ';'..~7' ': FSi.iT. Si.iTC 25C0.2~7 CZTS. Ci,ITG ~7~3. ~45 .EFTS. Z'/.~TZz1559. ~ U3 2U.~S., ','..".' .: DEPT. 5995. 20C ;_.iPHI. Ci,ITG16. 401 Et. iPH. CZT.S £?RA T. CiffTG 2.522 JP~ T. C~,!TG 2.240 Ei~.L~A. Si.riG FSi,IT. CWTG 2199. 755 Si.iTC. C~¥TG 2672. S68 CFTC. Ci,iTG CFEC. CNTG 932.250 GRCH. C~¥TG 21.1~8 TE~.CfffTG i S. 979 CPH!. 3 . 425 i,!C~VT. 2244. 429 Ct,.rEC. 3005. 000 CCL. CNTG 52;2.056 0.045 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 97/08/19 MAX REC SIZE : ! 024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE AL~k. IE : EDIT .082 SERVICE : FLiC VERSIOn? : OOl COl EATE : 97/05/29 .,_v,lAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FiLE HEA~DER FILE ~!O?,]BER: 2 EDITED CURVES Depth shifted and clipped zur-..res for eaclu pass in separaSe files. PASS HOY~BER: DEPTH iNCR~ENT: FiLE LE[~G TOOL CODE S~%~g gEgTJ~ STOP DEPTH ~,!PHi 92 7j . 3 8994 . 0 ....... E;UIi~L~,/T ~,~HiFTEE DEPTH 5ASELi~ DEPT~ ~3C~ $8558.0 88889.5 88588.5 9256.0 9257.5 9254.0 9254.5 9242.5 9244.0 9226.0 9227.5 LIS Tape Ve__zication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23:35 PAGE: 9225.0 9227.5 9220.5 9221.5 9206.0 9207.0 9205.0 9206.5 9198.0 9198.0 9189.0 9189.5 9178.5 9179.0 9169.0 9170.0 9162.0 9161 . 5 9155.5 9156.0 9152.5 9151.5 9147.5 9148.5 9140.0 9141.0 9131.5 9132.5 9126.5 9127.5 9118.0 9120.0 91i2.0 9113.0 9107.5 9109.5 9099.0 9i00.5 90~2.5 9~3.5 9079.5 9080.0 9063.5 9064.5 9061.0 9062.0 9050.5 9D52.5 9042.5 9043.5 9042.0 9043.5 9027.0 9028.0 9025.0 9026.5 9010.0 9021.5 9000.5 9002.5 ~997.5 S998.5 i00.0 i0!.0 102.0 P,E£.£a,~C<S: Th_is file ccnuains C>!TG Pass #2. The dep~3c s3:ffrs LIS FOPJ,LAT DA?A i ~d 0 2 66 0 3 73 64 4 66 1 5 66 LIS Tape Ve~_zication Listing Schlumberger Alaska Computing Center 19-AUG-i997 23:35 PAGE: TYPE REPR CODE VALUE 6 73 7 65 8 68 O.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CH~4N ** >i>~,iE SERV r~?IT SERVICE APi APi API APi FILE i?t~4B A~J~.IB SIZE REPR PROFESS iE O:~'ER # LOg TYPE EL, ASS Z.!OD >!~.iB S~uYP ELEM CODE (HEX) DEPT FT 500748 O0 0'50 03 0 2 i I 4 6'S 0000000000 :¥PH! CNTG PU-S 500748 O0 000 O0 0 2 1 ! 4 ~8 0000000000 ENPH CNTG PU-S 500748 O0 000 O'Z, C' 2 i 1 4 6~ 0000000000 CPHI CNTG PU-S 500748 O0 009 03 0 2 1 1 4 68 0000000000 ~'.~AT C>!TG 500748 O0 005 0.5 0 2 i 1 4 6~ 0000000000 CROAT C~,!TG 500748 O0 OOO 03 0 2 1 1 4 6~ 0000000000 E>iP~% CPTG 500748 O0 000 ,50 ~ 2 1 1 4 6~ 0000000000 igC>iT Ci'!TG CPS 500748 O0 FC~¥T C~iTG CPS 500748 CZ'iTC SiffTG CPS 500748 O0 OEO 0~ 0 2 I i 4 ~;S 0000000000 CFTC C>/TG CPS 500748 O0 C?,~HS C>~TG CPS 500748 gFES C>!TE CPS 500748 9272.50C '_:~>_-2. E£. 7-255:. 252 EZ.FP_E-. SIFTS .:):>. i :7 ~ '_:~:~. ':.'.'7; -999. 250 ZR>:T. EL:Z: 5)5.2EZ El:EA. C:.'T.2 ..:55.255' _': ':':7'. ':.-_ . -995.25Z S::Tt. :5.'7: 559. :5: ~:': ~. d'L:T: ~ ::). 2: .:.'.'.:..':'. ':'.': -: -999.25:2 GEE:. C:.:75 :5. 594 TEL?. 2;:7,S ->95. :5: JUL. '_':.':',:; ** El..: ZF DATA LIS Tape Ve~_Jication Listing Schlumberger Alaska Computing Center i9-AUG-1997 23:35 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE Nk~4E : EDIT .003 SERVICE : FLIC VERSION : O0!COi DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HE2~ER FILE NIJ?,IBER : 3 EDITED CURVES Depth shifted aha ciz~pe~ surves fsr each pass in separate PASS iff~4BER : 3 DEPTH ii,!C~Ei,]E~,iT: 0.50 O 0 FiLE SOY,E~qY LD~ TOOL EODE ST~? DEPTH STC'P DEPTH GHCH 9265. 5 ~994. 0 i,!PHi 9265. 9 ~994. PASS i',~J~ER : 2 92~3.5 9243..3 923~. 5 922 7.0 ~22i. 0 9206.5 9205.5 9193.0 ........ EQU£V.%LE:'CT O?'!SHiFTED DEPi2~ ........ 3244. 9239. 9222. 9207. 9194. 9244. 2242. 9227. 9206.5 LIS Tape Ve',~ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23~ PAGE: 9188 9182 9170 9161 9154 9152 5 9144 5 9138 5 9127 5 9112 5 9108.0 9099.5 9083.0 9080.0 9069.5 9061 . 0 9046.5 9046.0 9034.0 9028.0 90i2.0 90!7 . 0 9003.0 8999.0 8998.0 lO0.C $ · 0 9188.5 0 5 5 9162.0 5 9138.5 9113.0 9080.0 9047.5 9028.5 9012.5 9003.5 8998.5 100.5 9188.0 9182.5 9170.0 9154.5 9151.0 9144.5 9127.5 9109.5 9100.0 9083.0 9069.0 9062.0 9046.5 9034.5 9011.5 8999.5 i00.5 RE~,i%Ri¥S: This file conUains C~_VTG Pass ~£. T?.e de~th shifts sho:.~ above relect GRCH rass ~5 r3 GECH pass #! and i'.!PHi pass ~3 Co i,!PHI pass $ LiS FOSJ.£%~ ** E_%TA Ff':~.fA? SPECiFISATIO~V RECORD 3 73 4 66 ~ 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 2~ ~ ~ PAGE: 10 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ! ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NU~,IB NUMB SIZE REPR PROCESS ID ORDER #LOG TYPE CLASS MOD ~Fu?.IB SAMP ELEM CODE (HEX) DEPT FT 500748 O0 000 O0 0 3 NPHI CNTG PU-S 500748 O0 000 O0 0 3 ENPH CNTG PU-S 500748 O0 000 O0 0 3 CPHI CNTG PU-S 500748 O0 000 O0 £ 5 i,.L'P~.T CA~TG 500748 O0 000 O0 5 3 CP=AT CArTG 500748 O0 000 O0 0 5 ENP~ C~VTG 500748 O0 000 O0 9 ~ NCi,!T C!ffTG CPS 500748 O0 000 O0 0 3 FO-¥T OVTG CPS 500748 00 000 00 0 3 CNTC Ci',!TG CPS 50074~ O0 000 O0 0 5 CFTC CiffTG CPS 500748 O0 030 OS ~ 3 ClffEC CiffTG CPS 500748 O0 000 O0 G 5 CFEC CA~TG CPS 50074S O0 000 O0 ~ 3 GRCH C!VTG GAPi 50074~ O0 000 O0 C 3 TEWS Ct. IT'S LB 500746 O0 000 O0 C 5 CC;-, Ci~IT,E V 500748 O0 000 O0 f 3 I 1 4 68 0000000000 I 1 4 68 0000000000 2 I 4 68 0900000090 2 i 4 68 0000000000 2 i 4 68 0900000000 2 1 4 68 O00000000O i 1 4 68 CO00000000 i 1 4 68 0000000000 i i 4 68 0000000000 ! I 4 68 0000000000 £ i 4 68 OOO0000000 2 1 4 68 0000000000 £ i 4 60 DATA DEPT. 92~5. 500 1,7Y:~Z, ?ITS ?gF. 25 Z E::P:~. C!.?g -599.25E '~ .::'.' . ".'.-7': Z,.L~AT. S2,iTG-995.250 CS.AT, 3?~Tg 999.255 ELL~A. Si.'TG -999.2~7 :.',"L'¥ . .7.'7 : FC~,iT. Ci,iTG 959. 250 CA?C. Ci,~TG 955. 255 ZFTC. C?.iTG - 399. k5,5E?,U~'C. ,7.'.:75 CFEC. C!'!TG 999. 250 GRCH. Ct, ITS 55 . 225 iE?S. 3i,iTG -999. 250 i'd7 . .?.'7'? DEPT. 5994. 500 A?HI. Ci,ITG 2 ~. 4,?(: EiiPH. CiiTG 2! . 3_~6 ['.~P.:i'Z. ~7,.~'."S ~:~Ai. _~5!5 2. 252 S~AT. J;/i~ 2.5 4 - E;/~_%. gL-CS .:, [' .' ~ _'.' .".'7. ',','.";: 99'9.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 ~ PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O0iCO! DATE : 97/08/!9 MA~ REC SIZE : 1 024 FILE TYPE : LO LAST FILE : FILE HEADER FILE i~oYurBER : 4 AVEP~GED CURVES Compensaned ~?~uurcn: Aritb~,.etic average cf e~iueJ u~sses for all curves. DEPTH ii,ICREiJEi,iT 0.5000 z~SSES !~iCLUDEE 53~ AVEi~GE LD?IG TOOL COEE P~SS iff~¥IBERS ........................ 2, 2, 3, Ci,!TG $ Tine aritbm:euic average of passes 2,2 :-~ 5 ::-~s co~.npu~ed after ail dspth shifts and $ 2 73 56 4 66 i 5 66 6 73 7 65 LIS Tape Ve~_~'ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23~o5 PAGE: 12 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * i,I'P~,iE SERV UiffIT SERVICE APi API API API FILE iffL?.!B Nr~,fB SIZE REPR PROCESS iD ORDER # LOG TYPE CLASS Z~:OD i,.%?_r~ S.~'.iP ELEN CODE (HEX) DEPT FT 5007~6 O0 OOO CO 0 4 - 2 4 6~ 30000.99000 £ffPHi CI,!AV PU-S 500748 O0 000 O0 S 4 2 2 4 ~8 O0000CO000 NRAT CNAV 500748 O0 000 O0 0 4 ~ Z 4 68 0000000000 CPHI CNAV PU-S 500748 O0 000 O0 0 4 2 2 4 6~ 0000000000 C~T CNAV S00748 O0 000 O0 0 4 i 2 4 68 0000000900 E?,!PH CNAV PU-S 50074S O0 000 O0 0 4 2 2 4 6~ 0000000000 ENP~. Cf,IA V 50074 E ~ 0 000 00 C 4 2 4 68 0 .... O ~ u ~ 0 .... !ffCfffT CNAV CPS 500748 O0 000 O0 0 4 ~ 2 4 68 00.90000009 FCi!T C~.IAV CPS 50074~ 30 000 O0 0 4 - i 4 ~5 0000000000 C;?TC Ci,LqV CPS 500748 O0 CFTC C~ffAV CPS 5007~ 09 0,90 O0 C 4 - - 4 ~ OO.3~OC 57.3.9 CFEC C~IAV CPS 50074~ O0 000 O0 0 4 i 2 4 ~8 0020099.900 GRCH CNTG GAPI 500748 O0 000 O0 9 4 - 2 4 6S 0030050209 ** DATA ** CP~AT. ~"I_%V ~°°°. z~ -'~ EHPH. Ci,iP~V -999. 252 _u~': :, ....... gH.%%- -999. 250 L'Ji.;7'. J':'L-%~.' JFEC. f/'/AV 999.25.D 'SRCH. CI.iTG 32. 453 JFEC. CHAV -~95. 252 G~ZH. CZFTG 22,2 ~E 2:~'?. 2£d' ** EZ,~ OF DATA ** LIS Tape Vea~£ication Listing Schlumberger Alaska Computing Center .... 19-AUG-1997 23 :~5 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT . 004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT . 005 SERVICE · FLIC VERSION · O0!CO! o~ ?o DATE : J//08/_~ ~,£~C~ REC SIZE : !024 FILE TYPE : LO LAST FILE : FiLE HEA_OER FILE ~%F'o?JBER 5 P~Af'.~ COLRVES Curves and lo3 ineader daua ,for each pass in se_~az'z~_e fi3 ~.~'; :x:..' background pass in i~.~ file PASS A~TJ?._rBER : DEPTi~ 1,2ffCREME,.'_ffT : FiLE sr~i~E,~2~y VET, iD©'R YO~L CODE CHTG TE ESiLLES ..'Fi~ : ~C LOGGER (FT} : DEPTH STOP 2 LIS Tape Ve~£ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 PAGE: 14 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8100.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : r, ffATER CUTS (PCT): GAS~OiL RATIO: CHOKE (DEG) : PUMPED IN CRUDE 28.0 !JEUTROi'! TOOL TOOL TYPE (EPiTHEP~,£AL OR ~-E~_qYAL? : i~_:.% TRiX: NATR!X D~NSITY: HOLE CORRECTION (IN): E P i T:CEP. MA£ ~LUELINE COUNT P~ATE NOPJ.£ALIZATIOA~ It,! OiL ZOt,ZE TOP NOP~.£'ALIZING r',~I~_IDON (FT) : ._~ l~..~.~,~i~ , .... ~..~,, ~LUE£,iA?E COUNT P-ATE SCALES SET BY FIELD E3'i. Ei£JEEP. :~ CObb,IT RATE LON SCALE (CPS) : F.~ COCa,iT ~TE HiGH SSALE (CPS): 7J.23 N.~A~ COOT,iT P~%TE HIGH SCALE (CPS,~ : 2C.25,3 ?SSA. ST_~,~OFF (IN): CORRELACEE TO AiL,AS :'iEUTR~i.i L~2 £ATEi Z '22 2~ $ SET TYPE 64EH ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape V= _/ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23:35 PAGE: 15 TYPE REPR CODE VALUE 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 13 66 0 ! 4 65 FT 15 66 68 16 66 0 66 ! * * SET TYPE - CPL~J,I * * !'./~J~fE SERV LWIT SERVICE APi AP-_, APi API FILE i,/07.3B '_,,ICi'.:H SiZE ~P~ PROCESS ID OP~ER ~ LOG TYPE CLASS i~OD I,!5?~fB S~IP EL. EM UggE (HEX) ~EPT FT 500745 30 000 O0 0 5 ! i/??£ _~Si PU 500745 03 503 Ei.TpH PSI PU 5007~8 O0 000 O0 0 5 1 ~.~m~ ....... PSi PU 50074~ O0 300 '~'~ Z57~_ PS! 500748 05 ZOO OO O 5 2 ~7!.~ ~S2 5007~E fO 320 C5 C 5 2 TFEC PS! CPS 5007~5 O0 00~ ~2EF PSi CPS 50074E O0 535 03 0 5 2 SS PSi GAPi 50074E .DO 35J 5G O 5 1 GO00000000 3000-.000000 .-? 0000000000 22C0000000 :' 200~;03000C ~ 7572000000 ~ 0020000000 - : 0000000000 - - - .; i'' ': ,..' 5 :; ,) 0 S: · ?,; ' '; ',3'C 77 ' 7'iOOC 2,7 77); 2; ;2,2 '5 d ,20 9000000000 g~--=. 9283. 500 !'/P~i. PSi 22. 041 EYPi~. PSZ i>2~&. PSi 2. 550 R?.%~. 5S2 2. 592 Ei,/P_%. PSi C/.'EC. PSi 4595. 534 RC~F. PSi 2467. 042 ~CE2i. PSi RCFT. PSi 1446.28S C?¥TC. PS1 3964. 501 CFTC. PSi GR. PSi 29. 266 TENS. PSI 2570. 000 CCL. PS1 / _ . i ~ .: '_:'//Pii. £567. !24 i'.?OR. PS! -0. 009 2i. 67i' !562. 2~:47. 55,5 21. 677 LIS Tape V=_ _Jication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23:35 PAGE: 16 DEPT. 8988.500 NPHI.PS1 TNRA.PS1 2.107 RTNR.PS1 CNEC. PS1 3326.789 RCEF. PS1 RCFT. PS1 1208.015 CNTC. PS1 GR.PS1 17.406 TENS. PSI 14.543 ENPH. PS1 2.083 ENRA.PS1 871.899 RCEN. PS1 2695.014 CFTC. PSi 3020.000 CCL.PS1 19.287 TNPH. PS1 3.463 CFEC. PS1 2829.972 RCNT. PS1 1291.586 NPOR.PS1 -0.078 15. 492 960. 784 2713. 563 14. 551 ** E~VD OF DATA ** * * * * FILE TRAILER * * * * FiLE NA2qE : EDIT .005 SERVICE : FLIC VERSIO~¥ : 00i CO1 DATE : 97/08/19 ;~S~ ;~EC SiZE : 1024 FT~.~ TYPE : LO £.ASi FiLE : * * * * FiLE HE_~ER * * * * z',_LE :-.~.~'CE : EDIT .006 SERViSE · F£,iC DATE : 97/08/29 FE LR!LLER (FT) : TD LOGGER (FT) : TOP LOG INTERV~ (FT) : BOTTOM LOG I~ERV~ (FT) : 2,5 C? ~2.2 9273. 9271. 9000. 9265. LIS Tape V=_ _/ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23:35 PAGE: 17 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG CNTG TELEMETRY CARTRIDGE CNTG G~ RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AA'~ CASIATG DATA ©PEN HOLE BIT SIZE (IN) : D:RiLLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 1800.0 YES TOOL NUMBER CAL Y TCC B 0290 SGH-K 664 CNC-GB-125 $! O0. 0 50~EHOLE 3C~\T~iTiOiffS FLUiE EEA~iTY (LB/G): SL~F.%CE TE?UPEP~T~qE (DEGF) : ~iT~.3 HOLE T~¥PEP~T~%~E (DEGF) : FLUID SALilgiTY (PPM) : FLUiE LEVEL (FT) : FLUiE P~ATE AT WELLHE~ (BP~¥) ; ?Z% TE~ RUTS (PCT) : GAS,/CiD RATIO: PO¥~iPED IiV CRUE'S 25.0 SAZ~S TONE 2. 65 :=~ ZDCY,iZ RATE LOW SCALE :CPS _'.'EAF ZZLUZi ~_~ 25%: SZALE Z?.5 if Zl /L_%Z.ZZFz ii,Z, : WELL WAS LOADED WiTPZ DEAD CRUDE $ LIS FORMAT DATA LIS Tape Ve~_fication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 ~5 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 $ 68 0.5 oo FT £1 66 13 Z2 6~ 0 Z4 65 FT 25 66 68 l~ 66 ! * * SET TYPE - CHA2,1 * * i,.L%¥E SERV ~.-iF SErViCE APi APl APi AP! FiLE 13~4H £.3~E.lE SiZE i-i.~U ii ; ~-i_ "A'.~.g ii ZP~iER ~ LOG TYPE CLASS £.3CE 331S¥5 S.~'.iP E£~.i Y/TL' .:L¥.¥' DEPT iT 53G748 O0 000 O0 0 ~ - ~ 4 ~.~ ~S2 L9 509745 O0 000 OO 0 ......................................................... ** DATA ** LIS Tape Vez~£ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 PAGE: 19 DEPT. 9286.000 NPHI.PS2 TNRA.PS2 2.529 RTNR.PS2 CNEC. PS2 4638.441 RCEF. PS2 RCFT. PS2 1392.681 CNTC. PS2 GR.PS2 35.594 TENS.PS2 DEPT. 8985.000 NPHI.PS2 TN~A.PS2 2.229 RTNR,PS2 CNEC. PS2 3407.556 RCEF. PS2 RCFT. PS2 1256.169 CNTC. PS2 GR.PS2 17.703 TENS.PS2 20.700 ENPH. PS2 2.569 ENRA.PS2 1413.380 RCEN. PS2 3779.732 CFTC. PS2 2515.000 CCL.PS2 16.238 ENPH. PS2 2.286 ENRA.PS2 925.362 RCEN. PS2 2849.749 CFTC. PS2 3015.000 CCL.PS2 16.213 TNPH. PS2 3.082 CFEC. PS2 4148.673 RCNT. PS2 1509.029 NPOR.PS2 -0.009 19.106 TMPH. PS2 3.441 CFEC.PS2 3100.455 RCNT. PS2 1325.909 NPOR.PS2 -0.081 21.318 1505.195 3667.759 21.318 16.345 990.410 2787.362 16.135 ** EA~ OF DATA SErViCE : FLiC VE~SiCT,i · DATE : 97/0a/29 i.£%X REC SiZE : 2024 FiLE TYPE : LC: LAS? ~imE : SE.~lh-CE : FL, LC FiLE TYPE ' : ~ LOG H~ER DATA DATE LOGG~: 16-~Y- 97 LIS Tape Ve~zication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23; j~ PAGE: 2O SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): CP 42.2 1008 17-MAY-97 9273.0 9271.0 9000.0 9265.0 1800. 0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL. CODE TOOL TYPE CNTG CNTG TELE~_.FETRY CARTRIDGE CNTG "SAi~.!A RAY CNTG SO:>ffPENSATED NEUTRON $ TOOL ~Ft~4BER CALY TCC B 0290 SGH-K 664 Ci,!C - GB - 125 Ei 25. 0 BOREHOLE EC,:_,igZ Ti S:£?S FLUID TYPE: FLUID EE'/SECY LE.'g, : SOL, FAC-_-. TE"_dPESA!Uz~E (DEGF) : FLUID F~&TE AU ::~LLHSP~' ;'~Pi.]) : GAS,lC'iL SA755: CHCKE - un : 2 ~..2 32% ~? _'-X: 'J.£~ C~iX CE:JiF F-:-: H~'~: 2.7_Z_ZZFCZi?j. iii : S_z_: .C .? i"7 _' .'E 5AZ gZtU;F FACE High SCALE .'CPS; : Z:EA~ ZZLU.? SAFE LZ?.- SCALE 'CPS; : L-EA~ JZL-J:;i SAFE HZgJff SSALE (CPS, : 25525 TCOL SF_~iEJFF ZJ; : R~VIARKS: This file contains the raw data from pass #3. CORRELATED TO ATLAS NEUTRON LOG DATED 1/22/96 LIS Tape Vez-zication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23 PAGE: 21 MADE 3 PASSES AT 1800 FPH GOC AT WELL WAS LOADED WITH DEAD CRUDE $ 44 rr LIS FORMAT DATA DATA FOPJ4AT SPECIFICATION RECORD ** SET TYPE 64EB ** TYPE REPR CODE VALUE 3 73 76 7 65 ...................... 2'~HZ PS$ PU 5227¥£ fC 000 GO ~ 7 ~CEF ~02 2~S Z-~-4£ ^2 .22C 00 5 7 ~.i? PS5 ~t 55'£7¥S ~C OCO GO S 7 ~CFT PS3 CPS 50074~ DS 000 O0 0 7 CNTC PS3 CPS 50074~ O0 000 O0 0 7 CFTC PS3 CPS 500748 O0 000 O0 0 7 NPOR PS3 PU 500748 O0 000 O0 0 7 · _ . . . ,~ ~CJC_.' 0000CDC,5.7,~ 000000000~ 0000000000 0000000000 LIS Tape Ve~__ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23; PAGE: 22 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) GR PS3 GAPI 500748 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 500748 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 500748 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA DEPT. 9285. 500 A?HI. PS3 19. 807 ENPH. PS3 14. 968 T;,IPH. PS3 TA~P~A.PS3 2.471 RTZ'Z~.PS3 2.510 ENRA.PS3 2.922 CFEC. PS3 CNEC. PS3 4786. 102 P, CEF. PS3 i537. 800 RCEN. PS3 ~280. 741 RC~VT. PS3 RCFT. PS3 1454 . 81 0 CZ~iTS. PS3 3858 . 218 CFTC. PS3 ! 576. 349 Z,ZPOR. PS3 GR. PS3 29.2i 9 FE~,!S. PS3 2405 . 000 CCL. PS3 - O. 009 DEPT. 8982. C, O0 ?.P:~i. PS3 I~. 0~! EATpH. PS3 19. 995 17?P.::~. PS3 T!.TP~%. PS3 2.356 Rg:.7~. PS3 2.409 E?,iP~. PS3 3.547 CFEL'. PS ~ Si'ZEE. PS3 332~. 629 SZEF. PS3 ~54. 609 RCEi'!. PS3 3.324. 202 i~'ZT.r~'. !:gE ~CFT. PS3 2036. 550 S?iS. PS5 2705. 705 CFTC. PS3 l~ 55.24~ fL~Of{ . PSJ G~. PS3 27. 063 TEi,iS. PS3 2925. 000 CCL. PS3 - C. 038 20.502 1637.69~ 37~3.920 22.532 ** E:VD OF EATA ** * * * * FiLE iR~.!LEP_ ~ * ~ ~ FiLE J,i~E : EDiT .737 SERVICE · FDiC EA TE : 9 7/2 F ,"i 5 Z.22~: ~EC SiZE : Z22~ ~2LE ?YPE : LC ~ * '~ TAPE SESViCE Z,Z~J,ZE : 2257 : ~-. T2_2~ Z 7~ZCE : Z'2ZCSZFi : LIS Tape Ve~__ication Listing Schlumberger Alaska Computing Center 19-AUG-1997 23.~ PAGE: 23 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC REEL NAME : 97356 CONTINUATION # : PREVIOUS REEL : CO~,~ENT : ~CO ALASKA INC. , PRUDHOE BAY, D.S. !-15A, API# 50~029-20287~01 I ~ ~4RCO ALASKA INC l D.S. 1- 15A PRUDHOE BAY Run 1' 22 - ,January - 1996 D/UDAC/CN/GR 8612 9392 R.~C~IVED ~~I ~B o a ~; ATLAS Alaska 0il & GatCqns_. _C,o/nmi~sloA . ~~mg seduces _ape Subfile 2 is type .... .LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6581.00 R. ECK K. ST. GEMME D.S. 1-15A 500292028701 ARCO ALASKA INCORPORATED WESTERN ATLAS LOGGING SERVICES 26-JAN-96 RUN 2 RUN 3 8 10N 15E 4853 4590 65.20 65.20 38.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8100.0 9420.0 1ST STRING 2ArD STRING 3RD STRING PRODUCTION STRING 8.500 REMARKS: DLL/DAC/CN/GR. CIRCULATION STOPPED AT 2200, 21-JAN-96. SP WAS VERY NOISY, POSSIBLY FROM EQUIPMENT WORKING CLOSE TO THE RIG. SP IS NOT INCLUDED. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, BOREHOLE CORRECTION = 8.5", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NLTMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH GR 8612.0 DAS 8647.0 DLL 8666.0 2438 8671.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) depth shifted and clipped curves; .5000 STOP DEPTH 9338.0 9368.0 9392.0 9341.0 BASELINE DEPTH LLD 8668.0 8772.5 8790.0 8789.5 EQUIVALENT UNSHIFTED DEPTH DT NPHI 8667.5 8772.0 8790.0 all runs merged; 8790.5 8790.5 8795.5 8795.5 8796.0 8796.0 8798.5 8798.5 8799.0 8803.5 8803.5 8804.0 8804.0 8804.0 8821.5 8821.5 8822.0 8821.5 8832.0 8831.5 8833.5 8833.5 8841.5 8841.0 8841.5 8843.0 8843.0 8855.5 8855.0 8858.5 8858.5 8858.0 8859.0 8859.0 8860.5 8860.5 8861.0 8861.0 8861.5 8864.0 8863.5 8864.5 8864.0 8866.0 8866.0 8877.0 8877.0 8878.5 8877.5 8879.0 8878.5 8889.0 8888.5 8899.5 8899.0 8903.0 8903.0 8912.0 8911.5 8911.0 8914.0 8913.5 8920.5 8920.5 8920.0 8926.0 8925.5 8929.0 8929.0 8946.5 8946.5 8950.5 8950.0 8958.5 8958.5 8970.0 8970.0 8972.0 8971.5 8981.5 8981.5 8981.5 no case 8993.0 8999.0 9010.5 9011.0 9023.5 9024.0 9026.5 9034.0 9043.0 9051.5 9052.0 9061.5 9071.0 9076.5 9077.0 9080.0 9081.0 9085.5 9097.0 9110.5 9111.0 9112.5 9113.0 9127.0 9131.5 9134.5 9136.5 9161.0 9170.0 9192.0 9194.0 9196.0 9206.0 9206.5 9213.0 9213.5 9221.5 9236.5 9238.0 9238.5 9243.0 9252.5 9255.0 9255.5 9261.0 9282.0 9293.5 9307.0 9308.0 9316.5 9317.5 9333.0 9351.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DAS DLL ~-~-92 . 5 9010.5 9023.5 9025.5 9033.5 9042.0 9052.0 9061.0 9076.5 9085.5 9110.0 9112.5 9134.0 9194.0 9213.5 9220.5 9238.5 9253.0 9283.0 9307.5 9316.5 RUN NO. 1 1 1 8999.0 9011.5 9034.5 9061.0 9071.0 9077.0 9081.5 9085.0 9097.0 9110.5 9112.5 9131.5 9136.0 9160.0 9170.0 9191.5 9196.0 9206.0 9213.0 9221.0 9238.0 9255.5 9294.0 9317.5 9333.0 9351.0 PASS NO. 5 5 5 9010.0 9021.5 9033.5 9042.5 9050.5 9079.5 9085.5 9112.5 9126.5 9160.0 9193.5 9206.0 9236.0 9243.0 9254.5 9261.5 9308.0 MERGE TOP 8612.0 8647.0 8666.0 MERGE BASE 9338.0 9368.0 9392.0 2438 $ REMARKS: OPEN HOLE MAIN PASS. LL3, MTEM, TEND, & TENS WERE SHIFTED WITH LLD. FUCT & NUCT WERE SHIFTED WITH NPHI. 9341.0 CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ? MATCH2. OUT / ? ?MATCH3. OUT $ : ARCO ALASKA INC. : D.S. 1 - 15A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Lo9 Crv Crv Size Length Typ Typ Cls Mod 1 GR DAS 68 1 GAPI 2 DT DAS 68 1 US/F 3 TEND DAS 68 1 LB 4 TENS DAS 68 1 LB 5 LL3 DLL 68 1 OHMM 6 LLD DLL 68 1 OHMM 7 MTEM DLL 68 1 DEGF 8 NPHI 2438 68 1 PU-S 9 FUCT 2438 68 1 CPS 10 NUCT 2438 68 1 CPS 4 4 59 310 01 1 4 4 59 530 16 1 4 4 59 995 99 1 4 4 59 995 99 1 4 4 17 995 99 1 4 4 17 995 99 1 4 4 17 995 99 1 4 4 36 995 99 1 4 4 36 995 99 1 4 4 36 995 99 1 4O * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 73 Tape File Start Depth = 9416.000000 Tape File End Depth = 8580.000000 Tape File Level Spacin9 = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18404 datums ~ape Subfile: 2 Minimum record length: Maximum record length: 259 records... 62 bytes 1018 bytes Tape Subfile 3 is type. LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 5 .2500 VENDOR TOOL CODE START DEPTH GR 8612.0 DAC 8643.0 DLL 8666.0 2438 8620.0 $ 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 9354.0 9388.0 9408.0 9365.0 22-JAN-96 ECLIPS 2.1 2200 900 9420.0 9406.0 8658.0 9392.0 1800.0 21-JAN-96 22-JAN-96 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP COMR GR CN KNJT KNJT DAC SLAM ISO DLL FTS $ CABLEHEAD TENSION TEMPERATURE WTS COMMON REMOTE GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE LOINT DIGITAL ACOUSTILOG SLAM ADAPTER ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB TOOL NUMBER 3054ZZ 3981XA 3510XA 1329XA 2438XA 3923XA 3923XA 1667EA/1680MA 3516XA 3967XB 1229XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT): 8.500 8100.0 .0 BOREHOLE COND I T IONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PM: GEL/FREE KCL 9.90 59.0 9.5 FLUID LOSS (C3) MAXIMUM RECORDED .¢.MPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 1 - 15A : PRUDHOE BAY : NORTH SLOPE .125 .048 .138 .000 .090 .000 THERMAL SANDSTONE .00 8.500 .0 71.0 185.0 72.0 .0 71.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 GR DAC 68 1 GAPI DT24 DAC 68 1 US/F SFA1 DAC 68 1 US SFA2 DAC 68 1 US SFA3 DAC 68 1 US SFA4 DAC 68 1 US CHT DAC 68 1 LB TTEN DAC 68 1 LB TEN DAC 68 1 LB SPD DAC 68 1 F/MN RS DLL 68 1 OHMM RD DLL 68 1 OHMM WTBH DLL 68 1 DEGF CNC 2438 68 1 PU-S CNCF 2438 68 1 PU-S CN 2438 68 1 PU-L LSN 2438 68 1 CPS SSN 2438 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 56 310 01 1 4 56 520 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 635 99 1 4 56 635 99 1 4 56 635 99 1 4 56 636 99 1 4 17 220 09 1 4 17 220 10 1 4 17 995 99 1 4 36 995 99 1 4 36 995 99 1 4 36 890 01 1 4 36 334 31 1 4 36 334 30 1 72 * DATA RECORD (T~-~S# 0 ) Total Data Records: 258 994 BYTES * Tape File Start Depth = 9416.000000 Tape File End Depth = 8580.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 63556 datums Tape Subfile: 3 340 records . . Minimum record length: Maximum record length: 62 bytes 994 bytes Tape Subfile 4 is type: ~IS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN ~ER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH GR 8629.0 DAC 8660.0 DLL 8683.0 2438 8637.0 $ 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 9355.0 9389.0 9409.0 9366.0 22-JAN-96 ECLIPS 2.1 2200 300 9420.0 9406.0 8658.0 9392.0 1800.0 21-JAN-96 22-JAN-96 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP COMR GR CN KNJT KNJT DAC SLAM ISO DLL FTS $ CABLEHEAD TENSION TEMPERATURE WTS COMMON REMOTE GAMMARAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE LOINT DIGITAL ACOUSTILOG SLAM ADAPTER ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB TOOL NUMBER 3054ZZ 3981XA 3510XA 1329XA 2438XA 3923XA 3923XA 1667EA/1680MA 3516XA 3967XB 1229XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 8.500 8100.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PM: FLUID LOSS (CB): MkXIMUM RECORDED TEMPERATURE (DEGF): GEL/FREE KCL 9.90 59.0 9.5 3.8 185.0 RESISTIVITY (OHM~~ AT TEMPERATURE (DEGF) MUD AT MEASURE~ TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 1 - 15A : PRUDHOE BAY : NORTH SLOPE .125 .048 .138 .000 .090 .000 THERMAL SANDSTONE .00 8.500 .0 71.0 185.0 72.0 .0 71.0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DAC 68 1 GAPI 4 2 DT24 DAC 68 1 US/F 4 3 SFA1 DAC 68 1 US 4 4 SFA2 DAC 68 1 US 4 5 SFA3 DAC 68 1 US 4 6 SFA4 DAC 68 1 US 4 7 CHT DAC 68 1 LB 4 8 TTEN DAC 68 1 LB 4 9 TEN DAC 68 1 LB 4 10 SPD DAC 68 1 F/MN 4 11 RS DLL 68 1 OHMM 4 12 RD DLL 68 1 OHMM 4 13 WTBH DLL 68 1 DEGF 4 14 CNC 2438 68 1 PU-S 4 15 CNCF 2438 68 1 PU-S 4 16 CN 2438 68 1 PU-L 4 17 LSN 2438 68 1 CPS 4 18 SSN 2438 68 1 CPS 4 4 56 310 01 4 56 520 99 4 56 995 99 4 56 995 99 4 56 995 99 4 56 995 99 4 56 635 99 4 56 635 99 4 56 635 99 4 56 636 99 4 17 220 09 4 17 220 10 4 17 995 99 4 36 995 99 4 36 995 99 4 36 890 01 4 36 334 31 4 36 334 30 72 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Record' 253 Tape File Start Depth = 9417.000000 Tape File End Depth = 8597.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 80744 datums Tape Subfile: 4 333 records... Minimum reCord length: Maximum record length: 62 bytes 994 bytes Tape Subfile 5 is type: LIS 96/ 1/26 01 **** REEL TRAILER **** 96/ 1/29 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 29 JAN 96 9:22a Elapsed execution time = 2.69 seconds. SYSTEM RETURN CODE = 0
