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RECEIVEDSTATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned RI Suspended ❑ 1b. Well Class: 20MC 25.105 20AAC 25.110 Development El Exploratory ❑ GINJ ,Ao N WAG ❑ WDSPL ❑ No. of Completions: Zero Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 10/30/2019 197-168 • 319-219 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 1/20/1998 50-029-20074-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 211/1998 PBU 02-OZA Surface: 828' FNL, 1727' FWL, Sec. 36, T11 N. R14E, UM ' g Ref Elevations KB 64.00 17. Field/Pool(s): Top of Productive Interval: 1192 FSL, 1175' FVvL, Sec. 30, T11N, R15E, UM GL 30.50 BF Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 1403' FSL, 92' FEL, Sec. 25, T71N, R14E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface / Surface ADL 028308 & 028326• 4b, 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number' Surface: x- 688475 *y- 5950395 Zone - ASP 4 12309'/ 8866' 74-017 TPI: x- 693149 y- 5952534 Zone- ASP 12, SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/ND: Total Depth: x- 691877 y- 5952712 Zone - ASP 4 None 1 900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-dnll/Laterel Top Window MD/rVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 10606'/ 8626' 22. Logs Obtained List all logs run and, pursuant to AS 31 .05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD, GR, Cement Evaluation 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE AMOUNT CEMENTING RECORD PULLED FT. TOP BOTTOM TOP BOTTOM 30" 157.5# B 34' 114' 34' 114' 39" Fondu to Surface 20" 94#/133 H40/K-55 65' 1464' 65' 1464' 26" 930 sx Fondu 32' 13-3/8" 72# N-80 68' 2691' 68' 2691' 17-1/2" 139 ax Fondu, 545 sx Class'G', 103 sx Fondu 37' 9-5/8" 47#/43.5# 11115 1335' 10606' 1335' 8626' 12-1/4" 1680 sx Class'G' 1306' /40# 3-1/2"x3-3/16" 9.2#!6.2# L 8 9978' 12309' 8165' 8866' 4-1/4"x3-3/4" 15 Bbls Class'G' X2-7/8" /6.4# 24. Open to production or injection? Yes ❑ No ® 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation GRADE DEPTH SET (MD) PACKER SET (MD/TVD Size and Number, Date Perfd): 4-1/2" 12.6# L-80 1269' AD -An17# L-80 x 4-1/2" 12.6# N-80 2060'-10039 9905'/ 8112' A D -An 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. Tr Was hydraulic fracturing used during completion? Yes 13 No Q Per 20 AAC 25.283 (i)(2) attach electronic and printed 1(i -7&-f ' information VERIFIED DEPTHINTERVAL(MD) AMOUNTAND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas Ziff, etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbi: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio' Test Period -111- Flow Tubing Casing Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API(com: Press 24 Hour Rate __111. Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only ,G�����j #%&9_24AZ09 3BOMStf-�NOV 2 6 2019 4 28. CORE DATA Conventional Core(s) Yes ❑ No 8 Sidewall Cores Yes ❑ No 8 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize litholcgy and presence of oil, gas or water (submit separate sheets with this form, if needed), Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Tap Well Tested? Yes ❑ No D Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 8822 separate sheets to this form, if needed, and submit detailed test information per 20 110978' AAC 25.071, Zone 1 10978' 8822' Formation at total depth: Zone 1 10978' 8822' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Reports, Summary of Post -Rig Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production orwell test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Worthington, Ares J Authorized Title: SIMpeciall Contact Email: Ams.Worthington@bp.mm Authorized Signature: �I �, Contact Phone: +1 907 564 4102 INSTRUCTIONS General: This form is designed for submitting a complete and cemectwell completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and othertests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only '55, D =19.124' 4 SPF (0727/191 13-3/8" CSG, 72#, NAO, ID =12.347' 2691' 2' TBG & 9-5/8' CSG RJNCH, 9000' - 9010' POWER FLOW GUN (1226/18) 2" TBG & 9-5/8' CSG PUNCH, 9734' - 9744' SLM POWER FLOW GUN (12/17/18) Minimum ID = 2.375" @ 10734' 34116" x 2-7/8" XO 2' TBG -PC, 17#. L-80..0232 bof. D = 4.892' --F 9912' 3-1/2- LNK 9.29, L -BO FL45, .0987 bpf, D=2-992' 1—I 1 QQ72' TOP OF 3-3/16' LNR 10012' 4-12" TBG-PC,12.6#, N-80_0152 bpf, D = 3.958" 10014' FULLY ABANDONED NELL IS CUT OFF 6' 81' BELO% TUNDRA (10/30/19) D = 8.681' PERFORATION SL&WRY REFLOG: MWDONOM1198 ANGLEAT TOP PE RF: 71-@11040' Note: Refer to Production DB for historical pert data FMC SPF LHEAD= MCEVOY SHOT JATOR= BAKER 20'CSG CUT ELEV = 64' 0525/03 :LEV = SURFACE 13-3/8' CSG CU1 - 3800' 30' COND \ogle = 98-011858. 6 n MD = 11148' TBG PUNCH —I 1308 '55, D =19.124' 4 SPF (0727/191 13-3/8" CSG, 72#, NAO, ID =12.347' 2691' 2' TBG & 9-5/8' CSG RJNCH, 9000' - 9010' POWER FLOW GUN (1226/18) 2" TBG & 9-5/8' CSG PUNCH, 9734' - 9744' SLM POWER FLOW GUN (12/17/18) Minimum ID = 2.375" @ 10734' 34116" x 2-7/8" XO 2' TBG -PC, 17#. L-80..0232 bof. D = 4.892' --F 9912' 3-1/2- LNK 9.29, L -BO FL45, .0987 bpf, D=2-992' 1—I 1 QQ72' TOP OF 3-3/16' LNR 10012' 4-12" TBG-PC,12.6#, N-80_0152 bpf, D = 3.958" 10014' FULLY ABANDONED NELL IS CUT OFF 6' 81' BELO% TUNDRA (10/30/19) D = 8.681' PERFORATION SL&WRY REFLOG: MWDONOM1198 ANGLEAT TOP PE RF: 71-@11040' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz SHOT SQZ 2" 6 11040 - 11090 C 0525/03 11/14/19 2" 6 11210 - 11235 C 1027/02 2' 6 11325 - 11350 C 1027/02 1-11/16' 4 11492 - 11630 C 02/04/98 1-11/16" 4 11700 - 11820 C 02/04/98 1-11/16' 4 12225-12275 C 02/04/98 3-3/16' LNR, 6.211, L-80, .0099 bpf, D = 2.75' 1 9978' 1 CM1 2" OTIS ROM SSSV NIP, ID = 4.562" 2" TBG CUT (0625/19) TBG & CSG CMT LAD N FROM PINCHES (12/28/18) SL TAGGED CSG I5-112' OTIS SLIDING SLV. D = 4.562' 5-12' BOT PBR ASSY I 9-5/8"X 5-12' BAKER SAB PKR 54/2"X 4-12" XO, D = 3.958" 13-12" BAKER SETTING SLV, ID = 3.000' 4-12- BAKER R NIP, ID = 3.759" 10024' ELMD TT LOGGED 01/11/89 9-5/8' MILLOUT WINDOW 10606'- 10612' DATE REV BY COMMENTS DATE REV BY COMMENTS 02107199 LAST WORKOVER 09/09/19 P-272 CSG RECOVERY 09103!19) 11/04/19 JA/JMD FULLYABANDONED WELL 10/!0119 11/14/19 JNUJMD ADDED BF I CIBP I D = 2.441' PRUDHOE BAY UNIT WELL: 02-02A PERMIT NO: 91 971680 API No: 50-029-20074-01 T11 N, R14E, 827' FNL & 172E BP Explombon (Alaska) LYNCH SHOE WELL NAME: 02-02A 26. 1 Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 2300' Cut Tubing 2060' Cut & Pull Tubing 1848' - 1853' Punch 9-5/8" Casing 1800' Set Cement Retainer 1351' 59 Bbls Class'G' 1335' Cut 9-5/8" Casing 1330' Cut & Pull 9-5/8" Casing 1268' Cut 13-3/8" Casing 68' Cut & Pull 13-3/8" Casing 89' Cut 13-3/8" Casing 65' Cut & Pull 20" Casing Surface 507 Bbls Class'G' Surface 30.5 Gal Arctic Set I Surface .5 Bbls Arctic Set I 4/28/2019 (LRS Unit 42 - Weekly OOT Thaw) MIRU, Job Postponed due to SIM -OPS 4/28/2019 LRS Unit 76 - Weekly OOA Thaw) Move In Rig Up ***WSR continued from 04-28-19*** (LRS Unit 76 - Weekly ODA Thaw) Pumped 104 bbls 9.8 brine @ 200*F down OA taking returns up IA, down hardline to open top tank. Pumped 5 bbls 60/40 down OA then U -tubed with IA to freeze protect. Pumped 3 bbls 60/40 down hardline to freeze protect surface lines. Returns to OTT were taken in 25 bbl increments, all weighing -9.7-9.8 ppg brine All casing valves open to gauges. 4/29/2019 FWHP's 8/8/0 T/1/0/00 = Vac/Vac/VacNac. Temp = SI. WHP's (WIE Req). No wellhouse, AL, or flowline. Temporary scaffold installed. Kelly hoses/hardline rigged up for circ -out. WHP's unchanged from 4/23/19. Well was circed out on 4/29/19. 5/1/2019 SV, MV, ASV = C. IA, OA, OOA = OTG. 20:00. T/1/0=0/0/0 (LRS Unit 42 - Weekly Thaw OOA) Rigged up and PT'd. ***Continued on 5/5/2019 5/6/19 WSR*** ***Continued from 5/5/19 WSR*** (LRS Unit 42 - Weekly OOA Thaw) Pumped 100 bbls of recycled 9.8 Brine @ 200*F down OA taking returns up the IA and out to OT tank. Pumped 5 bbls 60/40 down OA then U -tubed with IA to freeze protect. Returns to OTT were taken in 25 bbl increments as follows: 25 bbls -9.7 ppg, 50 bbls -9.7 ppg, 75 bbls -9.6 ppg, 100 bbls - 9.7 ppg 5/6/2019 FWHP's=0/0/10 T/I/O/DO = VacNacNacNac. Temp = SI. Monitor. (WIE request). No well house, AL or Flow line. Temp Scaffold installed. Kelly hoses rigged up for circ out. No change in WHP's since 5-1-19. 5/9/2019 SV, MV, MV, SSV = C. IA, OA, OOA = OTG. 15:30 5/13/2019 LRS unit 46, (PLUG AND ABANDONMENT) Job postpone due to day activity. No fluids T/I/O/00= 0/0/0/0 Temp= S/I Weekly OOA Thaw (PLUG AND ABANDONMENT) Spot unit & Sign onto RAP, RU and PT surface lines, Review pump template ***WSR 5/14/2019 Continued on 05-15-19*** ***WSR Continued from 05-14-19*** Temp= S/I Weekly OOA Thaw (PLUG AND ABANDONMENT) Pumped 100 bbls 200 * recycled 9.8 brine down OA taking returns up IA to OT tank, Returns to OT tank were taken in 25 bbls increments as follows 25 bbls- 9.6 ppg, 50 bbls- 9.5 ppg, 75 bbls- 9.4 ppg, 100 bbls- 9.4 ppg 5/15/2019 FWHP= 0/0/10/0 T/I/O/00 = VacNac/Vac/0. Temp = SI. WHPs (WIE Req). No flow line, well house or scaffold. Dry hole tree w/ ASV and temporary scaffold installed. Kelly hoses rigged up for circ out. TP, IAP & OAP unchanged, OOAP went off a Vac since 05/09/19. 5/17/2019 ASV, SV = C. MV = 0. IA, OA, OOA = OTG. 02:45 T/I/O = 0/0/0 TEMP = SI, Function LDS Function LDS: Stung into test void 1,800 psi on test void bled to 0 psi. Monitored for 10 min, no change in pressure. Unable to functions LDS, gland nuts would move but pins are extreamly hard to function while holding backup on gland nuts. R/U test pump onto THA 5/18/2019 test void. Pump 1 gallon Aerokroil in test void, leave 1,000 psi on THA to soak LDS. T/1/0=0/0/0 R/D existing 5" FMC Dryhole tree w/ ASV Temp #11. Installed tree cap 5/21/2019 bonnet with jewelry, for upcoming PnA. FWP's 0/0/0 see log for details. Daily Report of Well Operations PBU 02-02A T/1/0/00 = Vac/Vac/Vac/0. Temp = SI. WHPs (WIE Req). No flow line, wellhouse, or scaffold. Dry hole tree installed with temporary scaffold installed. Kelly hose rigged up for circ out. WHPs unchanged since 5/17/19. 5/23/2019 MV = C. IA, OA, OOA = OTG. 16:00 T/1/0= vac/vac/0 Temp= S/I (LRS Unit 70 - Weekly OOA Thaw) Travel / Spot In / PJSM / 5/23/2019 Start RU to well / Pressure test. ***WSR continued on 05-23-19*** ***WSR continued from 05-22-19*** (LRS Unit 70 -Weekly OOA Thaw) Pumped 100 bbls of recycled 9.8* brine @ 200*F down OA taking returns up IA to open top tank. 5/24/2019 Collected 4 samples of brine intermittinly though out job. Mud scale weight averaged - T/1/0/00=0/0/0/0, Temp=91. Repair stuck LDS. 5 stuck LDS on TBG hanger (pre P & A). Stung into TBG hanger test void (2600 psi), 5/25/2019 bled to 0 psi. Broke free and functioned 5 stuck LDS, all the rest functioned normally. T/1/0= 5/5/3 (LRS Unit 70 - Weekly OOA Thaw) Pumped 90 bbls of recycled 9.8* brine @ 200*F down OA taking returns up IA to open top tank. 5/30/2019 Collected 4 samples of brine intermittinly though out job. Mud scale weight averaged - ***WSR continued from 05-30-19*** (LRS Unit 70 -Weekly OOA Thaw) Pumped 10 bbls of recycled 9.8* brine @ 200*F down OA taking returns up IA to open top tank. Pumped a total of 100bbis of 200*f brine down well. Mud scale weight averaged - 9.7 ppg. Final water level was 6' from conductor. Tree grew 3/4 of a inch through out job. Returns of brine appeared to be 1 for 1. 5/31/2019 FWHP's 5/5/7 . T/1/0/00 = 0/Vac/6/0. Temp = SI. WHPs (WIE Req). No flow line, wellhouse, or scaffold. Dry hole tree installed with temporary scaffold installed. Kelly hose rigged up for circ out. OAP increased 6 psi since 05/23/19. 5/31/2019 MV = C. IA, OA, OOA = OTG. 02:30 T/1/0=0/0/10, LRS Unit 46 *** Weekly OOA Thaw*** (PLUG AND ABANDONMENT) Pumped 25 bbls of recycled 9.8* brine at 200*F down OA taking returns up IA to open top 6/7/2019 tank. Collecsamples of brine. Mud scale weight (see log for details) ***WSR continued it 4ted WSR continued from 06/07/19 LRS un6 *** Weekly OOA Thaw *** (PLUG AND ABANDONMENT) Pumped additional 75 bbls It00bbl total) of recycled 9.8* brine at 200*F down OA taking returns up IA to open top tank. Collected samples of brine at 10, 25, 50, 75 bbls, Mud scale weight averaged - 9.5 ppg, Well head at start of job was 26 3/4", At end 28" at Measured area of possible tree growth, Vac truck strap -10 bbls from conductor, -80 bbls Bine in open top, Valve positions IA/0 OA/0 Hardline SI to open top 6/8/2019 DSO in control of well at departure, FWHPS 0/0/0 T/1/0/00 = O/VAC/6/0. Temp = SI. WHPs (WIE Req). No flow line, wellhouse, or scaffold. Dry hole tree installed with temporary scaffold installed. Kelly hose rigged up for circ out. WHPs unchanged since 05/31/19. 6/8/2019 MV = C. IA, OA, OOA = OTG. 04:40 T/I/O/00 = 0/Vac/Vac/0. Temp = SI. WHPs (WIE Req). Has MV only installed with temporary scaffold installed. Kelly hose rigged up for circ out. TP, IAP and OOAP unchanged OAP went on a vac since last monitor on 06/08/19. 6/13/2019 MV = C. IA, OA, OOA = OTG. 16:00 Daily Report of Well Operations PBU 02-02A T/I/O/00 = Vac/Vac/Vac/0. Temp = SI. NFT -T- PASSED, NFT -IA - PASSED (Pre decompletion). Has MV only installed with temporary scaffold installed. Kelly hose rigged up for circ out. T FL @ near surface, IA FL @ near surface. Open TP to BT, -11 psi to 0 psi with no observable flow for 1 hr. OAP increased to 3 psi, bled OAP from 3 psi to 0 psi in < 1 min, all gas. Open IAP to BT, -2 psi to 0 psi with no observable flow for 1 hr. Monitor for 1 hr. TP, IAP and OAP all went on a vac. Final WHPs = -0/-1/-1/0. 6/14/2019 MV = C. IA, OA, OOA = OTG. 14:00 T/I/0=0/0/4/0 SI (LRS Unit 70: Weekly OOA Thaw) Pumped 50 bbls of 180* 9.8 Brine off of pump truck followed by 50 bbis of 200* 9.8 Recycled Brine from Open Top tank down the OA, taking returns up the IA, back into Open Top tank. -120 bbls in Open Top tank. Fluid level 234" from top of conductor upon leaving location. NaCl samples @ 9.5 ppg. ***Repeated job to add NaCl to system 6/15/2019 and measure return density*** T/1/0=0/0/4/0 SI (LRS Unit 46: Weekly OOA Thaw) Pumped 100 bbls of 200* recycled 9.8 brine down the OA taking returns up the IA to OTT.( Mud scale not available). Vac truck recovered - /bbl and Tree grew 1 1/2" through out job. Returns 1:1. 6/15/2019 FWHP's 1/1/14/0 T/I/0/00-0/0/0/0. Plug and Abandonment Tubing hanger removal. Removed 5" FMC MV and McEvoy Gen 1 THA. Pulled 13" tubing hanger with 10' tubing pup. Further inspection shows tubing threads pulled though at the collar 10' down. Installed 13" hub clamp x 13 - 5/8" flange crossover on tubing head with clamp. Installed 13- 5/8" x 7 -1/16" flange cross 6/21/2019 over with a 6 -3/8" x 7 -1/16" tree cap assembly and jewelry. ***Job Complete. 6/21/2019 Pre -P&A - Install temporary herculite liner to pull tubing hanger. T/1/0/00 = ?/0/Vac/0. Temp = SI. WHPs (WIE Req). No wellhouse or flowlines. Temporary scaffold installed. Tree removed. Fluid in conductor -4' from the top. 6/21/2019 IA, OA, OOA = OTG. 01:25 ***WELL S/I ON ARRIVAL*** (Tbg Cut) HES ELINE UNIT 4863 CUT 5-1/2" TBG AT 2300' MD W/ 3.80" O.D. JET CUTTER. 6/25/2019 ***JOB COMPLETE ON 25 -JUN -2019*** T/1/0=0/0/4 Temp=S/I (LRS Unit 70 - Weekly OOA Thaw) Pumped 100 bbls of recycled 9.8* brine at 200*F down OA, taking returns up IA, to Open Top Tank. Collected IA return samples every 25 bbls of 9.5 ppg brine. 6/26/2019 FWHP 3/3/12 6/27/2019 Pre -P&A. Removed Temporary herculite liner from arround wellhead. T/1/0 = 0/0/0 LRS Unit 46 *** Weekly OOA Thaw *** (PLUG AND ABANDONMENT) Pumped 107 bbls of 9.8* brine at 200*F down OA taking returns up IA to OTT. 1:1 ratio. OTT= -107 bbls Collected samples of brine. Mini vac, vac'd out - 1 bbl. Fluid level = 198" 7/4/2019 to top of conductor. Mud scale weight(see log for details) FWHP= 0/0/6/OOA=O 7/10/2019 T/1/0= 0/0/0 Temp= NON OP Scheduled HOT(OOA Thaw) Job cancelled T/I/O/00 = ?/?/?/0. Temp = SI. WHPs (WIE Req). No wellhouse or flowlines. Temporary scaffold removed. Well is prepped for rig. Unable to obtain TP , IAP, OAP 7/12/2019 due to no scaffolding. T/1/0=2/2/35 ****Weekly thaw**** Pumped 101 bbls of 200*F 9.8 brine down OA taking 7/13/2019 returns out IA to tank. IA/OA-OTG. Well has no swab or SSV FWHP-2/2/23 T/1/0=0/0/0 Pre All American. Installed non working side 3" IA valve Temp #18, with blind, PT'd against VR plug. Removed VR plug. Removed 2" piggyback OA valve, installed 7/15/2019 integral with jewelry. FWP's 0/0/0 see log for details. Released rig from R-02 to DS 02-02 @ 18:00 hrs 7-17-19 Rig down floor, PJSM pick roof 7/17/2019 panels with crane, pick dog house, fuel tank and HPU units and load out with crane. T/1/0=0/0/0. Pre AAO Pulling Unit. Removed tree cap bonnett and 13 5/8" x 7 1/16" Crossover from THA. Tubing Head Hub to 13 5/8" flange adapter still installed. AAO WSL 7/18/2019 notified of wellhead status. ***Job Complete*** See log. Final WHP's 0/0/0. Daily Report of Well Operations PBU 02-02A PJSM Scope derrick down, lay derrick over on headache rack, place ramps in place, drive carrier off sub base load onto Peak transport, load sub base onto float, remove sub bases off well, move equipment from R-02 to DS 02-02, Spot sub over 02-02, spot pump and 7/18/2019 ramps, wait on carrier to arrive on location after transmission replacement in yard. 2 hrs 24 hr Summary: 2 hrs NPT Carrier arrived on location @ 02:00, back carrier onto sub base, pin carrier inplace, remove ramps, prepare to raise derrick. Accept rig @ 1600 hrs. RU Doyon casing, Evac drill / AAR.P/U M/U overshot, run in and tag fish @ 28', attempt to engage overshot, unable to engage grapple, L/D overshot. P/U M/U spear, run in and engage spear, pull on fish, tbg wold not come free, pulled 65K over string weight, no give or movement.Called wireline and ODE, started discussions of recutting tbg, tracking down 7/19/2019 correct cutter. Working tbg up too 65K over while discussing options. 24 hr summary: Work tbg while tracking down correct size cutter to recut tbg below SSV. Release spear and LD SLB fishing. Housekeeping and organization. Rig up Halliburton for Bond log. Top of cement @2140' small stringers higher, POH lay down logging tool, rig up Jet cutter, unalbe to get into tubing with 4.75 Jet cutter due to angle and slight egging observed from surface. 7/20/2019 24 hr forecast: Pick cut depth. If above SSSV, cut w/ Halliburton. Gage ring run, pick up **AAO -111 *** RAN CEMEN G TO 2300' ELMD FOUND TOC IN IA @ 2130' ELMD ATTEMPT TO RUN 4.75" JET CUTTER BUT UNABLE TO PASS 5.5" TBG STUB 7/20/2019 ***CONT. ON 07/21/19 WSR*** ***SWCP 4516 RIG SUPPORT FOR AAO -1 11*** (P&A) RIG UP SWCP 4516 TO DRIFT 9-5/8" CASING W/ 8.52" JUNK BASKET. 7/21/2019 ***JOB IN PROGRESS, CONTINUED ON 7/22/19 WSR*** 24 HR Summary: Rig up 4.75 gage ring, gage ring had to be tapped into tubing top, made gage ring run to SSSV 2196' no issues. POH with gage ring, electric spang jars not conducting current, redress jars, rig up Jet cutter and RIH with and cut @ 2060'. Unable to engage spear. Dress stub w/ 4.75" tapered mill Spear tbg and pull to floor 35k over. Recovered control lines after 1st full joint and PU Wt normal @ 35k. spoo ing control lines filling displacement w/ 9.8 brine. Inspecting tbg for subsidence related damage an numbering. Number jts as pulled and well number on the jts. Recovered 21 clamps. R/D Doyon casing and SLB spooling unit, Break out fishing tools and lay down F/T's, clear catwalk, Rig up SLB slick line unit for 9 5/8" casing gage ring run. 7/21/2019 Forecast: Complete 8.52 gage ring run, rig SLB down, release rig for move to DS 04 -111 ***(cont. from 7/20/2019 wsr) WITH 4.75" G -RING TO SSSV NIPPLE @ 2196' ELMD -1/2" TUBING WITH 4.75" JET CUTTER AT 2060'. [LOG 7/21/2019 COMPLETE*** 0/0/0. Install 13" x 7" Otis X -Over and Hot Bolt. RDMO ***Job Complete*** SEE 7/22/2019 OR DETAILS Final T/I/O = 0/0/0. CP 4516 RIG SUPPORT FOR AAO -111 *** (P&A) UNABLE TO PASS 61' SLM W/ 8.52" JUNK BASKET (Recovered 1 rubber c/I band). DRIFT TO 1,915' SLM W/ 8.52" JUNK BASKET (Recovered 1.5" x 26" piece of rubber). RE -DRIFT CLEAN TO 1,915' SLM W/ 8.52" JUNK BASKET (3 gallons of thick paraffin substance recovered). ***WELL TURNED BACK OVER TO AAO -111, NOTIFIED DSO OF WELL STATUS*** NOTE: THICK PARAFFIN SUBSTANCE ALL OVER WIRE, TOOLS, & IN JUNK BASKET 7/22/2019 EACH RUN. Daily Report of Well Operations PBU 02-02A 24 HR Summary: Complete rigging up SLB slick line, make 8.52 gage ring run. restricted at 52' to 61' worked through, pulled to surface retrieved 1 clamp in junk basket, RIH with gage ring to 1915', POH pieces of control line sheathing in junk basket, longest pieces 25", rerun junk basket, Tagged @ 1915'w/ second junk basket/8.52" GR. Recovered no junk but —1 gal paraffin? Sample to lab. RD slickline. Notify town and EL of paraffin. Release pulling Unit for move to DS 04-01 @ 0900 hrs. Stopped moving loads to DS 4 until site control established there. Cont. RD @ DS 2, Transport Carrier, sub and pony subs to DS - 04, stage away from the well, Fullbore rigging up to circulate 04-01. 5-1/2" tbg to Greive Pad for storage. 51 full joints (Jt #51 includes 4' cut from #52 left in 7/22/2019 hole) and 13' pup from below hanger. T/I/O = 0/0/0. Temp = SI. WHPs (WIE Req). No Flow line or wellhouse. Scaffold installed around tree. Hardline circ out rigged up to IA/OA. 7/25/2019 IA, OA = OTG. 13:30 ***WELL SHUT IN ON ARRVAL*** (Drift/Caliper/CAST/Gyro/Casing Punch) BEGIN RIGGING UP HES E -LINE 4863. 7/26/2019 ***JOB CONTINUED ON 27-JUL-2019*** T/1/0=0/0/0 (LRS Unit 70 - HOT OA) HOT OA, taking returns up IA to Surface Tanks w/ 5 bbls 50/50 meth, 60 bbls 160*F Hot Surfactant Water, and 207 bbls 160*F 9.8 ppg NaCl Brine. Well has no swab, SSV or FL. Casing valves open to gauges 7/26/2019 Final Whp's=vac/2 *** JOB CONTINUED FROM 26-JUL-2019*** (Drift/Caliper/CAST/Gyro/Casing Punch) DRIFT W/ JUNK BASKET& 8.52" GAUGE RING TO TAG AT 1943' ELMD (recovered 3.5" x 4" rubber debris) RUN PDS 40 ARM CALIPER FROM 1941' TO SURFACE. LOG CAST -M IN CEMENT INSECTION MODE FROM 194 ' TO SURFACE. PERFORMED GYRO SURVEY TO 1940' MD. PUNCH 9-5/8" CASING 1848'- 1853'W/ 2" 4 SPF 0 DEG PHA - TOP HOT = 97, CCL STOP DEPTH = 1838.3'. 7/27/2019 ***JOB COMPLETE ON 27-JUL-2019*** CTU#9 1.75" CT. Job Scope: Set Retainer / Pump Cement Plug MIRU CTU. Perform Weekly BOP Test. MU & RIH w/ Baker 3-3/8" Inflatable Cement Retainer. Set Retainer at 1800' ctm. Circulate 9.8ppg Brine, Surfactant Wash & 9.8ppg Brine taking OA returns. Pump 59 bbls 15.8 Class G Cement down Coil taking OA returns. Pump 29.8 bbls below retainer 26.1 bbls in OA + 3.7bbls between retainer & punch holes . Unsting & Jay in remaining cement in 9-5/8" casing up to 1400' ctm. Lay in 9.apgg Brine to surface. Close surface gate valve. Break down tools. Recover 1/2" ball. Install nozzle & Jet BOP's taking returns to tanks. Rig Down CTU. 7/28/2019 ***Continue job on 7/29/19 WSR*** T/I/O = 0/0/0. Removed THA x Crossover. Check and clean ring groove and Re -install THA x Crossover and Torque to API specs. Install 6" Temp valve #59 and Torque to API 7/28/2019 specs. *** Job Complete*** (See log for details) Well turned over to Rig crew for rigging CTU#9 1.75" CT. Job Scope: Set Retainer / Pump Cement Plug Finish Rig Down CTU. 7/29/2019 ***Job Complete*** T/I/O = N/A/0/0 TEMP = SI, Function IC LDS Bleed both upper and lower pack -off void though (SBS). Hold open bleed for 15 min, no change in pressure. Function all LDS on upper and lower pack -off. Full out is 4-3/4" and full in 3-5/8" on upper pack -off. Lower pack -off is 4-3/4" out and 3-1/2" in. torque all LDS to 7/30/2019 300 ft/lbs. (One LDS on top marked in RED tape will only function gland nut and pin at the Daily Report of Well Operations PBU 02-02A T/I/O = 0/0/0. Pre E -Line. Removed THA and 6" Temp valve #59 and staged next to well . 8/7/2019 *** Job Complete*** See log. Final WHP's 0/0/0 ***WELL DEAD ON ARRIVAL*** RIH w/ HES RBT LOG TO FIND TOC IN 9-5/8" ANNULUS TAGGED TOC OF CEMENT IN 9-5/8" CASING AT 1351' ELMD, NO VISIBLE TOC IN 9- 5/8" ANNULUS with RBT TOOL. RIH w/ HES 95/8" (8.1875" OD) JET CUTTER JET CUT 9-5/8" CASING AT 1,335'. CCL TO CUT 5.5'. CCL STOP 1329.5'. GOOD CUT. 8/7/2019 ***JOB COMPLETE*** TWO = 0/0/0. Install 13" x 7" Otis X -Over and Hot Bolt. RDMO ***Job Complete*** SEE 8/8/2019 LOG FOR DETAILS Final TWO = 0/0/0. T/1/0/0 = 0/0/0/00. Temp = SI. WHPs (WIE Req). No Flow line or wellhouse. Scaffold installed around tree. All WHPs unchanged since 7/25/19. 8/10/2019 SV = C. IA, OA, OOA = OTG. 17:15 T/1/0= 0/0/0. LRS Unit 46 - Weekly OA HOT) (Fluid in conductor is 67" down) Pumped the following down the OA, taking returns up the IA/TBG, to OTT: 2.3 bbls 9.8 ppg NaCl Brine. OA reached max pressure. (See log for details). Suspect ice plug, swap to meth. Pumped a total of 6.5 bbls of 50/50 meth to clear obstruction. 8/15/2019 *** WSR continued on 08/16/19*** *** WSR continued from 08/15/19*** (LRS Unit 46 - Weekly OA HOT) Pumped 100 bbls 200*F 9.8 ppg NaCl brine down the OA, taking returns up the Tubing/IA, to OTT: ****After 88.5 bbls brine, Return line to OTT clogged up (appears to be arctic pack). Cycle throttle valve while intermitently pumping until 100 bbls away. Returns cleared up 8/16/2019 after 95 bbls*** TxIA/O/OOA= 0/0/0. (LRS Unit 46 - Weekly OOA Thaw) . No fluids pumped. Unit called to 8/21/2019 another job T/1/0/00=0/0/0/0 (LRS Unit 46 - Weekly OOA Thaw) Road unit to location/ Spotted 8/21/2019 equipment/ Rigged up/ Prssure tested. *** WSR continued on 08/22/19*** *** WSR continued from 08/21/19*** (LRS Unit 46 - Weekly OOA Thaw) Pumped 5 bbls 50/50 followed by 100 bbls of 200* NaCl brine down the OA taking returns up the TBG/IA 8/22/2019 to OTT. Tank returns appear to be 1 to 1 and clean . CV's=OTG FWHP's=0/0/0/0 T/1/0/00 = Vac/Vac/??/0. Temp = SI. WHPs (WIE Req). No Flow line or wellhouse. Temporary scaffold installed around tree. Unable to safely access OA with current 8/24/2019 scaffolding configuration. T/1/0=vac/vac/vac, Temp=Sl. Install compression tool. Verified 0 psi in IC test void. Removed 4" dry hole tree and cross over from well head. Verified depth from flange to spacer bushing top (24"). RU compression tool onto well head. Verified TBG hanger LDS, and LDS for 7" hanger are backed out. Verified support bushings were fully backed out. Slowly backed out the LS for the 9 5/8" hanger/PO. No movement whitnessed. Monitored for 30 min, still no movement. RD compression tool, 8/25/2019 and ran in 2 LDS on casing head. 3 and 900 positions. ***JOB STARTED ON 29 -AUGUST -2019*** (cement log and caliper) LOG JUNK BASKET FROM 1,328' ELMD TO SURFACE. LOG USIT FROM 1,315' ELMD TO SURFACE. LOG READ 60 -ARM MEMORY CALIPER FROM 1,318' ELMD TO SURFACE. 8/29/2019 ***JOB COMPLETE ON 29 -AUGUST -2019*** Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths** North America - ALASKA - BP Page 1 of 11 Operation Summary Report Common Well Name. 02-02 AFE No Event Type: PLUG AND ABANDON(PXA) Start Date: a/27/2019 End Date: 9/3/2019 H-S4CW00022K-EX-JO(1,600,000.00) Project: PBU - - Site:02 — — --- Rig Name/No.: PARKER 272 'Spud Date/Time: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. _ BPUOI: USA00000973 Active datum: PARKER 272 Q77.65usft (above Mean Sea Level) Data From - To i Hrs Task Code NPT Total Depth Phase Description of Operations (hr)-_—��. (usft) 8/27/2019 06:00 - 09:00 3.00 _..__ RIGD P _�_ ABAN GENERAL RIG DOWN OPERATIONS -CLEAN ARCTIC PACK FROM RIG FLOOR -SECURE TOP DRIVE AND BRIDLE UP '-SECURE PIPE IN PIPE SHED �- RIG DOWN RIG FLOOR ,- REMOVE HANDRAILS FROM ROOF TOP -PERFORM DERRICK INSPECTION - PERFORM PRE -SKID CHECKLIST - SKID FLOOR AND LAY OVER DERRICK (370K 09:00 - 11:00 2.00 --_- RIGD P ABAN - `_ iSEPARATE MODULESAND AND MOVE TO END OF TARMAC ACCESS ROAD 11:00 - 13:00 2.00RIGD P _ _ ABAN _ MOVE RIG FROM TARMAC TO DS02 13:00 - 14:00 1.00 RIGU TP ABAN SPOT DRILL MOD OVER 02-02 ' '',- MARRY MUD MOD AND UTILITY MOD TO __--" _. — ! _L_— _.I..__ DRILL MOD L...._ 5, 14:00 - 19:00 5.00 RIGU IF P ABAN GENERAL RIG UP - HOOK UP INTERCONNECTS - RAISE DERRICK (514K OFF RACK) ! - SKID FLOOR AND HAUNCH --RIASE PIPE SKATE '- RIG UP ON THE RIG FLOOR AND IN THE MUD PITS -PERFORM DERRICK INSPECTION -COMPLETE PRE -SPUD CHECKLIST 19 00 —ACCEPT RIGAT 19:00"' 20: - 00 1.00 RIGU P ABAN BRIDLE DOWN AND HANG BRIDLE IN DERRICK -ATTACH BLOCKS TO TOP DRIVE — CALIBRATE BLOCKS AND PERFORM CROWN CHECK ABAN PERFORM PRESPUD WITH CHRIS 2000 - 21:00 1.00 RIGU P __-. - L.—. YEAROUT'S CREW �- PERFORM TABLE TOP EVAC DRILL 21:00 - 23:30 2.50 _� _�._..._�._. CUT P ABAN — — _ TAKE ON 9.8 PPG BRINE TO PITS -STRAP DP - HOIST CASING CUTTER ASSEMBLY TO RIG FLOOR - CHANGE OUT WASH PIPE ON TOP DRIVE - PRESSURE TEST SURFACE LINES TO 2000 PSI (VISUAL LEAK TIGHT) 23:30 - 00:00 0.50 CUT P ABAN _ RIG UP VAC HOSE ON ANNULUS VALVE TO PREVENT BRINE FROM SPLASHING OUT OF CONTAINMENTAS IT CASCADES DOWN THE WELLHEAD HOLD PRESPUD MEETING WITH JAMES II �. HUNDLEY'S CREW DURING PRETOUR MEETING ! - - 8/28/2019 00 00 02:30 2.50 —r- CUT P _... _ ABAN CUT 9-5/8" CASING 2' BELOW 9-5/8" CASING HEAD -RIG UP CURTAIN WITH HERCULITE AROUND WELLHEAD TO PREVENT BRINE SPLASHING OUT OF CONTAINMENT .- CUT WITH 320 GPM, 1000 PSI I -PULL AND LAY DOWN CASING CUTTER ------ �_�--_ (ASSEMBLY Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths** North America - ALASKA- BP Page 2 of 11 Operation Summary Report Common Well Name: 02-02 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 8/27/2019 End Date: 9/3/2019 H-S4CW00022K-EX-JO (1,600,000,00) - Project: PBU Site: 02 Rig Name/No.: PARKER 272 Spud Date/Time: 8/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 _ Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From -To I Hrs Task Code NPT Total Depth Phase Description of Operations (hr) 'usft) 102:30 - 03:30 1.00 CUT P ABAN NIPPLE DOWN UNI HEAD WITH 9-5/8 CUT JOINT - PULL WITH TREE CRANE AND LAY DOWN j 0330 - 05:30 2.00 BOPSUR P ABAN OUT THE BACK OF THE BOP DECK rNIPFLE UP RETRO-FIT CASING HEAD PER CAMERON AND TORQUE BOLTS ON CLAMP. 1 iSIMOPS -INSTALL BLIND/SHEAR RAMS AND UPPER PIPE RAMS 2 7/8X5" VBR _ 05:30 - 08:00 2.50 BOPSUR P ABAN NIPPLE UP HIGH PRESSURE RISERS AND 'BOP STACK - NIPPLE UP CHOKE HOSE j- NIPPLE UP HIGH PRESSURE SPACER I SPOOLAND BOP STACK -TORQUE ALL BOLTS - LABELAND LOG BOP BOLTS/NUTS BY 'SERIAL# INSTALL TURNBUCKLES AND FILL LINES - INSTALL FLOW NIPPLEAND FLOW LINEAND .AIR UPALLAIR BOOTS ' - OBTAIN IRKS MEASUREMENTS AND INSTALL _IIMOUSEHOLE 08:00 - 11:00 3.00 PXA i P ABAN MAKE UP 95/8" CSG SPEARANDATTEMPT TO PULL 9-5/8" CASING ENGAGE SPEAR IN 9 5/8" CSG AS PER SLB FISHING - PICK UP IN 20 KLB INCREMENTS TO 300 KLBS. - WORK UP TO 300 KLBS SEVERAL TIMES STAGE TO PUMP 8 BPM, 450 PSI AND CONTINUE TO WORK TO 300 KLBS WITHOUT SUCCESS '— CIRCULATE SOAP PILL SURFACE TO ISURFACE SIMOPS: BUILD 4" DP STANDS OFFLINE 11:00 - 11:30 0.50 PXA P-r_ ABAN DISENGAGE AND LAY DOWN SPEAR + _ 11.30 - 12:00 OSD PXA P ABAN MAKE UP 9-5/8" CASING CUTTER ASSY PER + SLB FISHING REP 12:00 - 14:30 2.50 PXA PABAN RUN IN THE HOLE WITH 9-5/8" CUTTER ASSEMBLY FROM 21'MD TO 1379'MD i- PU 54 KLBS, SO 54 KLBS AT 1351' MD - TAG CEMENTAT 1379'MD - PICK UP 40'AND LOCATE COLLARAT 1346' MD -PLACE CUTTERS AT 1332' MD. PICKUP 2' TO MAKE CUT ' 14 30 15:30 1.00 PXA P II I ABAN CUT 9-5/8" CSG AT 1330' MD PER SLB FISHING _ REP _1_5:3_0_ _ _..... .� __ 8.5 BPM, 935 PSI, 80 RPM, 2-7 KFT-LBS TQ ABAN I ..._—_ PULLOUT OF THE HOLE ON ELEVATORS 15:30— - 16:00_0.50 PXA P I _L_ _„_,__ ___ROM 1344' MD TO 11 5'MD ABAN ' LAY DOWN 3 SINGLES AND 9-5/8” CASING 16'00 - 16:30 0.50 PXA P CUTTERASSEMBLY GOOD INDICATIONS OF CUT ON KNIVES 16:30 - 17:30 1.00 I PXA P ABAN i MAKE UP 9-5/8" SPEARASSEMBLY WITH --_ i I BUMPER SUB PER SLB FISHING REP Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths" Printed 11/2512019 10:33:20AM **All depths reported in Drillers Depths** North America - ALASKA - So Page 3 of 11 Operation Summary Report Common Well Name: 02-02 --- AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 8/27/2019 End Date: 9/3/2019 H-S4CW00022K-EX-J0 (1,600,000.00 ) Project: PBU Site 02 - - Rig Name/No.. PARKER 272 Spud Date/Time: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUO1: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level Date From - To Him Task Code NPT Total Depth i Phase Description of Operations (hr) (usft) 17:30 - 18:00 0.50PXA P ABAN RUN M THE HOLE WITH SPEARASSEMBLY AND ENGAGE 9-5/8" CASING I- PULL 9-5/8" CASING TO RIG FLOOR, PULLED I FREE AT 96 KLBS 118:00 - 18:30 0.50 PXA P 1,330.00 ABAN _ CIRCULATE 2X BOTTOMS UP AND SPOT SOAP PILL IN 9-5/8" x 13-3/8" ANNULUS 118:30 - 19:00—II 0.50 PXA—fir - 10 BPM, 130 PSI P 1 "', 1,330.00 ABAN DISENGAGE AND LAY DOWN SPEAR 18 00 - 23:00 ! 4.00 PXA F 1,330.00 ABAN PULLAND LAY DOWN 9-5/8" CASING FROM iCUT AT 1330'MD 1 '1- LAY DOWN 2 CUT JTS AND 31 FULL JTS OF (CASING - NO ISSUES LAYING DOWN CASING I SIGNIFICANT AMOUNT OF SLUDGE ON BACK SIDE OF PIPE ,123:00 - 23:30 1 0.50 PXA P 1 1,330.00 ABANABAN ISE _ -- SIMOPS i- RIG DOWN 9-5/8" CASING HANDLING i� 'EQUIPMENT ,23.30 - 00:00 0.50 PXA P ,330.00 ABAN MAKE UP 13-5/8" CLEAN OUTASSEMBLYAND ATTEMPT TO RUN IN THE HOLE TAG OBSTRUCTION AT -50' MD 1- 5' BELOW 'GROUND LEVEL) 8/29/2019 '100'00 - 00:30 0.50 PXA P 1' 1,330.00 ABAN ATTEMPT TO WORK CLEAN OUT ASSEMBLY THROUGH OBSTRUCTION AT^50 MD WITHOUT SUCESS .PULL AND STAND BACK CLEAN OUT _ 100:30 - 08:00 7.50 _ 1 PXA P 1,330.00 . ABAN ASSEMBLY RUN IN THE HOLE WITH BORE SCOPE CAMERATO ATTEMPT TO GET VISUAL ON OBSTRUCTION IN 13-3/8" CASING - UNABLE TO SEE ANYTHING DUE TO 1 SIGNIFICANT AMOUNT OF SLUDGE ON CASING WALLS RIG UP STACK FLUSHING TOOL, RUN IN AND FLUSH STACK -PUMP OUT RISER - RUN BACK IN WITH BORE SCOPE - UNABLE TO SEE ANY OBVIOUS SIGNS OF I DAMAGE TO CASING SIMOPS: - DISCUSS SITUATION WITH ODE, ATTEMPT TO LOCATE SMALLER OD CLEAN OUT TOOLS -MOBILIZE 13-3/8" CASING SCRAPER ';ASSEMBLY FROM BAKER FISHING 08:00 - 0830 0.50 PXA i P 1,330.00 ABAN I MAKE UP 13-3/e" CASING SCRAPER CLEAN _ ___... OUTASSEMBLY 08'.30 - 09:30 1.00 _I __ PXA � P I1,330.00 - __ ABAN .RUN IN THE HOLE WITH 13-3/8" CASING SCRAPER - TAG STUMPAT 1330'MD - PU 50 KLBS, SO 50 KLBS - MONITOR WELL WITH TRIP TANK AN D HOLE FILL: GOOD DISPLACEMENT -�i TAG OBSTRUCTION AT 1003' MD WITH ^5 KLBS AND WIPE CLEAN Printed 11/2512019 10:33:20AM **All depths reported in Drillers Depths** North America - ALASKA - BP Operation Summary Report Common Well Name: 02-02 Lvent type: t'LIJUANVAUANUUN(FXA) Start Date: 8/27/2019 End Date: 9/3/2019 Page 4 of 11 AFE No H-S4CW00022K-EX-JO (1,600,000.00) �t=... sne: uz Rig Name/No.: PARKER 272 Spud Date/Time: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From - To HM_ Task Code NPT Total Depth Phase Description of Operations (hr) usft) 09:30 - 10:00 0.50 PXA P 1,330.00 ABAN CIRCULATE WELL CLEAN WITH HIGH VIS SWEEP AND SOAP PILLAT 1330' MD -16 BPM, 500 PSI — SIGNIFICANT AMOUNT OF ARCTIC PACK BACK AT BOTTOMS UP 10:00 - 10:30 0.50 PXA P 1,330.00 ABAN PULL OUT OF THE HOLE WITH CLEAN OUT li ASSEMBLY ON ELEVATORS FROM 1330' MD TO SURFACE 1030 - 1130 1.00 PXA P 1,330.00 ABAN CLEAN AND CLEAR RIG FLOOR OUT 13-3/8" CASING SCRAPER AND (SEND CLEAN OUTASSEMBLY TOOLS - CLEAR RIG FLOOR - MOBILIZE E -LINE TOOLS TO RIG FLOOR FOR LOGGING RUNS 11:30 - 13:30 2.00 PXA P 1,330.00 ABAN _ RIG UP E -LINE �- HOLD PRE JOB SAFETY MEETING WITH SLB 'E -LINE AND RIG CREW -RIG UP E -LINE SHEAVES - RUN IN THE HOLE WITH 9.5" GAUGE RING ON E -LINE LAY DOWN GAUGE RING 13:30 - 17:00 3.50 PXA P 1,330.00 ARAN MAKE UP SLB USIT LOG TOOLS AND LOG _FROM 1315' MD TO SURFACE. _ PERFORM A REPEAT RUN IN HIGH RESOLUTION FROM 1315' MD TO 1000' MD. j NO INDICATION OF CEMENT BEHIND PIPE FROM 1315' MD TO SURFACE. 1.00 PXA P 1,330.00 ARAN RIG DOWN USIT TOOLS. REHEAD E FOR 60 ARM CALIPER 17:00 - 18:00 -- -LINE RUN 18:00 - 22:00 It 4.00 PXA P 1,330.00 ABAN _ MAKE UP READ 60 ARM CALIPER LOG ASSEMBLYAND RUN IN THE HOLE. - LOG FROM 1314'MD TO SURFACE - LAY DOWN CALIPER TOOLS RIG DOWN E -LINE CALIPER LOGS INDICATE: - OVAL DEFORAMTION AT 52' WITH ID RESTRICTED TO 11.94". -I NTERMITTANT SLIGHT BUCKLING FROM _ _ __ _ - 290' TO 750' :22:00 - 23:00 1.00 PXA P 1,330.00 ABAN MAKEUP 13-3/8" CASING CUTTER ASSEMBLY I PER SLB FISHING REP — MAKE UP PORTED SUB TO 8-1/4" BODY 23 00 - 00:00 1.00 PXA P 1,330.00 _._ ABAN MULTI -STRING CUTTER DRESSED TO CUT 13_3/8" CASING RUN IN THE HOLE WITH 13-3/8" CASING 00:00 - 00:30 0.50 PXA L_ P - 1,330.00 ABAN CUTTER ASSEMBLY TO 878'MD CONTINUE TO RUN IN THE HOLE WITH 13-3/8" 8/30/2019 j CASING CUTTER ASSEMBLY FROM 878'MD - TO 1270' MD j - PU 48 KLBS, SO 48 KLBS - MONITOR WELL WITH TRIP TANKAND HOLE FILL: GOOD DISPLACEMENT Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths— North America - ALASKA - BP Page 5 0111 Operation Summary Report - - Common Well Name: 02-02 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: B/27/2019 End Date: 9/3/2019 H-S4CW00022K-EX-JO(1,600,000.00) Project: PBU — - Site. 02 ___ �_ __ _ Rig Name/No.: PARKER 272 Spud DatelTime: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 _ Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From -To Hrs Task I Code I NPT Total Depth Phase Description of Operations (hr) (usft 00:30 - 03:30 3.00 PXA P 1,330.00 ABAN CUT 13-3/8" CASING PER SLB FISHING REP - ATTEMPT TO LOCATE COLLARAT 1272' MD WITH 1 AND 2 BPM: UNABLE TO GET POSITIVE INDICATION. - PICK UP AND PLACE CUTTER AT 1270' MD PER ODE PLAN - VERIFY CALIPER LOG DATA WITH READ PRIOR TO BEGINNING CUT - 13 BPM, 1020 PSI 80 RPM, 1-2 KFT-LBS TORQUE - ROTATED FOR FULL 2HRS PER SLB ! PROCEDURE, DID NOT SEE ANY DEFINITIVE __'SIGNS OF CUT. 03 .:30 - 04:00 0.50 I PXA P I 1,330.00 I, ABAN PULL OUT OF THE HOLE ON ELEVATORS WITH 13-3/8" CASING CUTTING ASSEMBLY I MONITOR WELL FOR 10 MIN PRIOR TO PULLING: STATIC 04:00 - 05:00 1.00 PXA P 1,330.00 ABAN LAY DOWN 13-3/8" MULTI-STRING CUTTER PER SLB FISHING REP KNIVES ON CUTTER DO NOT SHOW GOOD INDICATION OF CUT, LEADING EDGE HAS MINIMAL WEAR. i ! DISCUSS WITH ODE AND ACTING WSUP' ',- DECISION MADE TO RUN IN THE HOLE WITH LARGER BODIED (11.75") MULTI-STRING '.. CUTTER DRESSED TO CUT 13-3/8" CASING AND RE-CUTAT 1268'MD _.I�_ 0500 - 06:00 1.00 PXA P 1,330.00 ABAN MAKE UP 11.75" OD MULTI-STRING CUTTER DRESSED TO CUT 13-3/8" CASING AND RUN IN THE HOLE TO 1268' MD. 06:00 - 07.30 1.50 PXA P 1,330.00 ABAN CUT 13-3/8" CASING AT 1268' MD PER SLB FISHING REP -9 BPM, 730 PSI -� ._-----� - 80 RPM, 1-3.5 KFT-LBS TORQUE 07:30 - 08:30 1.00 PXA P 1,330.00 ABAN �—� �i PULL OUT OF THE HOLE AND LAY DOWN CASING CUTTER - �I- GOOD INDICATION OF CUT ON CUTTER ;KNIVES 06:30 - 1000 1.50 PXA P 1,330.00 ABAN NIPPLE DOWN AND STAND BACK BOP STACK i -DE-ENERGIZE ACCUMULATOR - I- CLEAN OUT FLOW BOX - PULL MOUSE HOLE, FLOW BOX AND FI LL UP LINES •I- NIPPLE DOWN BOP STACK AND RACK BACK ON STUMP � _- __. NIPPLE DOWN HIGH PRESSURE RISERS 10 00 - 12:00 2.00 PXA P 1,330.00 ABAN MAKE UP 13-3/8"CUTTER AND CUT 13-3/e" CASINGAT 59' MD j -LOCATE COLLAR AT 61'MDAND PICKUP 2' -CUT 13-3/8" CASING PER SLB FISHING REP -6 BPM, 625 PSI - M, 3-5 KFT-LBS TORQUE 12:00 - 14.00 2.00 PXA P 1,330.00 ABAN LAY DO EAD WITH 14' CUT JOINT I OF 13-3/8" AND BROKEN 20" STUB - RIG UP TOP DRIVE AND 7/8" CABLE TO WELL .HEAD ' - PULL WELLHEAD AND CASING STUBS UP _..— ANDTAILOUTWITH TREECRANE Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths" Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths** North America -ALASKA - BP Page 6 of 11 Operation Summary Report -- - Common Well Name: 02-02 AFE No Event Type: PLUG ANDABANDON (PXA)', Start Date 8/27/2019 End Dale: 9/3/2019 H-S4CW00022K-EX-JO (1,600,000,00) Project: PBU Site: 02 _ 1 Rig Name/No.: PARKER 272 Spud Date/Time: e/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From - To Ars Task I Code NPT Total Depth Phase Description of Operations (hr)_ (usft) 114:00 - 15:00 1.00 PXA P 1,330.00 ABAN MAKE UP SPEAR ASSEMBLY WITH GRAPPLE TO CATCH 13-3/8" CASING PER SLB FISHING - RUN IN AND ENGAGE SPEAR INTO 13-3/8" 15:00 - 00:00 9.00 PXA P 1,330.00 ABAN CASING ATTEMPT TO PULL 13-3/8" CASING FROM CUT AT 1268' MD - PULL 120 KLBS AND WORK PIPE �- STAGE UP TO 350 KLBS OVER 9 HRS ATTEMPT TO BREAK CIRCULATING WITH NO SUCESS, PERIODICALLY KICK ON PUMPS IN AN ATTEMPT TO HELP PULL PIPE: 1-5 BPM -- - _ 1,330.00 ABAN WORKED CASING UP 24' OVER 9 HRS CONTINUE TO ATTEMPT TO PULL I3 -3/e" 8/31/2019 1,00:00 - 02:30 2.50 PXA Pte- _ CASING FROM CUT AT 1268' MD - WORKING PIPE WITH UP TO 350 KLBS 1 - WORKED CASING UP 24' OVER 11 HRS WITH 1 NO FORWARD PROGRESS MADE OVER LAST 2 HRS. DISCUSSED LACK OF PROGRESS WITH ACTING WSUP AND ODE. �- DECISION MADE TO MAKE A CUTAT^120' AND CHANGE TO 5" BEFORE ATTEMPTING TO - PULL AGAIN 02:30 - 03:30 1.00 PXA 1,330.00 ABAN DISENGAGE AND LAY DOWN SPEAR P ASSEMBLY 03 30 04:30 1.00 PXA P I 1,330ABAN PERFORM DERRICK INSPECTION INSPECT TOP DRIVEAND DRILL LINE 0430 06:00 1.50 PXA P 1,330.00 ! ABAN MAKE UP MULTI -STRING CUTTER AND CUT 13-3/8" CASING - PUMP AT 5 BPM AND LOCATE CASING COUPLING AT 102'MD - PICK UP TAND CUT CASING AT 100'MD � :-7 l BPM, 880 PSI 80 RPM, 1-3 KFT-LBS TORQUE —i- ._- .'06:00 - 06:30 0.50 _ PXA �P 1,330.00 ABAN PULLAND LAY DOWN CASING CUTTER TO PIPE SHED 06:30 - 08:00 1.50 PXA 1,330.00 ABAN I CHANGE OUT SAVER SUB FROM HT -38 TO NC50 —P� - CHANGE ELEVATORS TO S" T8:00 - 09:301.50 PXA P 1,330.00 ABAN MAKE UP SPEAR ASSEMBLY TO CATCH i 13-3/e" CASING PER SLB FISHING !_ - RUN INAND ENGAGE 13-3/8" CASING 0930 - 12:00 2.50 PXA P 1,330.00 ABAN ATTEMPT TO WORK 13-3/8" CASING FREE - JAR ON FISH AT 140 KLBS AND WORK STRAIGHT PULL TO 450 KLBS _ -___.._FIRE JARS 55 TIMES 11200 - 12:30 0.50 PXA P'_ 1,330.00 ABAN HOLD SAFETY ENGAGEMENT CHECK-IN__ MEETING WITH ALL HANDS TO DISCUSS RECENT INCIDENTS AND DISTRACTIONS 12:30 - 13.00 _ 0.50 PXA P j 1,330.00 ABAN CONTINUE TO ATTEMPT TO WORK I3-3/8' CASING FREE - JAR ON FISH AT 140 KLBS AND STRAIGHT "PULL TO 450 KLBS - - _-FIRE JARS B TIMES 1 13.00 - 4:00 1.DO PXA P 1,330.00 ABAN PERFORM POST JARRING DERRICK 14'00 - 14:30 0.50 173 L70 -..INSPECTION 1 PXA ! P 1,330.00 ABAN DISENGAGE SPEAR AND CHANGE OUT 5" DRILL PIPE JOINT FOR 2 JTS FO 5" HWDP Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths** NorthAmerica- ALASKA - BP - Page 7of11 Operation Summary Report Common Well Name. 02-02 AFE No Event Type: PLUG AND ABANDON (PXA) ! Start Date. 8/27/2019 End Date: 9/3/2019 H-S4CW00022K-EX-JO (1,600,000.00) Project: PBU I Site: 02 Rig Name/No.: PARKER 272 Spud Daterl-ime: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 Active datum: PARKER 272 @77.65usR (above Mean Sea Level) Date - From - To HIM I Task Code NPT Total Depth Phase Dewnptioncf Operations (hr) _ (usft) 2O0 PXA -., P 1,330.00T ABAN ENGAGE SPEAR AND ATTEMPT TO WORK j 14:30 - 1630 13-3/8" CASING FREE -JAR ON FISH AT 140 KLBS AND WORK STRAIGHT PULL TO 450 KLBS _ I- FIRE JARS 47 TIMES _ ' 100 PXA P 1 —� 1,330.00 ABAN PERFORM POST JARRING DERRICK 111630 - 1730 INSPECTION .17.30 18:00 0.50 PXA P x1,330.00 ABAN DISENGAGE SPEAR AND LAY DOWN SPEAR ASSEMBLY. I ,I MAKE -STRING CUTTER DRESSED TO CUTT 1 13-3/8"-3/8" CASING. 18:01 a _- 19:00 1.00 PXA p 1,330.00 ABAN !CUT 13-3/e" CASING ABOVE FIRST COUPLING - PUMP AT 5 BPM AND LOCATE CASING COUPLING AT fig' MD BELOW ROTARY TABLE (-35' OF 13-3/8" CASING) - PICKUP V AND CUT CASINGAT68' MD ' I - 7 BPM, 800 PSI -80 RPM, 1-5 KFT-LBS TORQUE ABAN PULLAND LAY DOWN MULTI -STRING CUTTER '.19:00 - 19:30 0.50 PXA P i 1,330.00 ASSEMBLY 19:30 - 20:30 7.00PXA _ P _ _ 1,330.00 ABAN MAKEUP SPEAR AND BUMPER SUB ASSEMBLY TO JOINT OF DRILL PIPE AND ENGAGE CASING. �I- ATTEMPT TO PULL CASING, WORKING UP TO 250 KLBS WITHOUT SUCESS DISENGAGE SPEAR AND ADD 6-1/2" JARS, I ACCELERATORAND 2JINTS OF S"HWDP TO 1 _ i +3 — _ — ASSEMBLY 20:30 22:00 1.50 PXA 1,330.00 ABAN '.ENGAGE SPEAR AND JAR 13-3/8" CASING FREE -JAR ON FISHAT 140-230 KLBSAND WORK STRAIGHT PULL TO 320 KLBS '.- FIRE JARS 20 TIMES FISH CAME FREE WITH 320 KLBS 2200 - 23:00 1.00 PXA P _ - 1,330.00 ABAN PERFORM POST JARRING DERRICK _�' INSPECTION BEFORE MOVING TOP DRIVE 23.00- 0000 1.00 PXA P 1,330.00 ABAN LAY DOWN SPEAR ASSEMBLY AND FISH TO IPIPE SHED - CUT WAS 34.92' FROM TOP OF COUPLING ON JOINT. '- NO SIGNIFICANT DAMAGE TO JOINT I � PULLED ! -GOOD CUT ON BOTTOM OF JOINT - SEND PHOTOS OF CUT JOINT TO ODE 9/1/2019 00:00 - 00:30 0.50 PXA P 1,330.00 ABAN _ HOLD SAFETY ENGAGEMENT CHECK-IN I MEETING WITH ALL HANDS TO DISCUSS 0 _ --- __ I RECENT INCIDENTS AND DISTRACTIONS. _ 00'30 - 01:30 T PXA P j 1,33000 ABAN PERFORMPOST DERRICK AND EQUPMENT INSPERRIN 01:30 - 02:30 1.00 PXA P 1,330.00 ABAN I SLIPAND CUT DRILL LINE. 65'O ---—�—� — =CUT CALIBRATE ATE BLOCKS AND AMPHION SYSTEM Printed 11/25/2019 10:33:20AM "All depths reported in Drillers Depths** North America - ALASKA - BP Operation Summary Report Page 8 of 11 Common Well Name'. 02-02 AFE No Event Type. PLUG AND ABANDON (PXA) Start Date: 8/27/2019 'End Date: 9/312019 H-S4CW00022K-EX-JO(1,600,000,00) Project. PBU Site: 02 - - — - - - -- - ' Rig Name/No.. PARKER 272 Spud Date/Time: 6/9/1970 12:00:OOAM j Rig Release' 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level) -- Date From - To His Task Code ' NET Total Depth Phase Description of Operations (usft) 02:30 - 08:30 6.00 PXA N 1,330.00 _ f ABAN O ON STATEAPPROVALTO MILL20"PIPE 1 TO TOP OF 13-3/8" COLLAR (-10') ' &MOPS'. 1- GENERAL HOUSE KEEPING THROUGHOUT RIG - CHANGE OUT WASHPI PE '- GENERAL MAINTENANCE ON PIPE SHED EQUIPMENT - CHANGE OUT ELEMENT ON ANNULAR PREYENTER ,08:30 - 10:00 1.50 PXA P - 1,330.00 ABAN 'MAKE UP 20" CASING MILLING ASSEMBLY PER SLB FISHING -PICK UP 18" OD TAPER MILL, BIT SUB AND —1(2) 8" DRILL COLLARS 10:00 - 17:00 7.00 PXA P 1,330.00 ABAN MILL20"CASING FROM 55.4'MDTO 57.4'MD -TAKE ON FRE H WATER TO MILL WITH -40 RPM, 1-3 KFT-LBS TORQUE -4 BPM, 40 PSI RUNNING CHARGE PUMP, TAKING RETURNS 1 IN CELLAR BOX TO VAC TRUCKS AND TRASH _PUMP BACK TO POSSUM BELLY. 17,00 - 19:30 2.50 PXA P 1,330.00 ABAN SHUT DOWN AND OFFLOAD FULL VAC TRUCKS BACK TO PITS OVER SHAKERS - RIG UP ADDITIONAL HOSE TO 3" RISER BACK TO POSSUM BELLY. 19:30 - 22:00 2.50 PXA P1 1,330.00 ABAN CONTINUE TO MILL 20" CASING FROM 57.4' 'MD TO 60.4'MD -40 RPM, 1-3 KFT-LBS TORQUE '., - 4 BPM, 40 PSI RUNNING CHARGE PUMP, TAKING RETURNS IN CELLAR BOX TO VAC TRUCKS AND TRASH PUMP BACK TO POSSUM BELLY 22:00 - 23:00 1.00 PXA P 1,330.00 ABAN STAND BACK MILLING ASSEMBLYAND SUCK OUT CONDUCTORAND 20" CASING TO INSPECT MILLING PROGRESS -TOP COLLAPSED SECTION OF 20" CASING IS SPLINTERED BUT OPENED UP ENOUGH TO — L _ AND PULL 13-3/8" CASING 23:00 - 00:00 1.00 PXA P 1,330.00 ABAN -tbFEAR LAY DOWN MILLING ASSEMBLY PER SLB FISHING REP - BREAK OUT AND LAY DOWN 18" OD TAPER MILLAND DRILL COLLARS 9/2/2019 00'.00 - 01100 1.00 PXA P 1,330.00 ABAN MAKE UP SPEAR ASSEMBLEY DRESSED TO CATCH 13-3/8" CASING PER SLB FISHING Printed 11/25/2019 10:33.20AM "'All depths reported in Drillers Depths'" North America - ALASKA - BP Page 9 of n Operation Summary Report Common Well Name: 02-02 AFE No Event Type: PLUGANDABANDON (PXA) Start Date: 8/27/2019 End Date: 9/3/2019 H-S4CW00022K-EX-J0 (1,600,000.00) Project: PBU - - Site: 02 -- - Rig Name/No.: PARKER 272 Spud Date/Time: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. _ BPUOI: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From - To Hrs Task I Code ! NPT Total Depth I Phase Description of Operations (hr 1, usR) 01:00 - 06:30 5.50 PXA P ! 1,330.00 ABAN ENGAGE I3-3/8"CASINGANDATTEMPT TO IPULL FREE - JAR ON FISH AT 140 KLBS AND STRAIGHT PULL TO 300 KLBS ! - FIRE JARS 25 TIMES - ATTEMPT TO PUMP AT 2 BPM WITH NO ;RETURNS ! CONTINUE TO JAR ON FISH AT 140 KLBS AND STRAIGHT PULL TO 300 KLBS - ON 26TH JAR, FISH APPEARED TO PULL FREE FOR U THEN PULLED TIGHTAGAIN - CONTINUE TO JAR ON FISH AT 140 KLBS AND STRAIGHT PULL TO 350 KLBS -GRAPPLE ON SPEAR PULLED FREE FROM FISH, MEASURED TOP OF FISH AND DETERMINED THAT THE -6'OF OBSERVED PROGRESS WAS ACTUALLY GRAPPLE SLIPPING INSIDE FISH. 06:30 - 08:00 1.50 PXA P 1,330.00 ABAN PULL SPEAR TO RIG FLOOR, REPLACE GRAPPLE I ON SPEAR AND LAY DOWN SPEAR 08:00 - 09:30 1.50 T PXA P +1,330.3 _ ASSEMBLY TO PIPE SHED. ABAN MAKE UP MULTI -STRING CUTTER DRESSED I TO CUT 13-3/8" CASING PER SLB FISHING ._00 09:30 - 11:001.50 i 1 1. X--, PXA I P 1,330.00 ABAN CUT 13-3/8" CASING AT 89' FROM RIG FLOOR -7 BPM, 720 PSI ----- _-L !-80 RPM, 1.5-3.5 KFT-LBS TORQUE .,'11.00 - 11:30 -- --i--..—_- 0.50I PXA ���1,330.00 _ _ ABAN PULL OUT OF THE HOLE AND RE -DRESS _ KNIVES ON CUTTER FOR 20" CASING 11:30 - 12:00 0.50 PXA P �- 1,330.00 ABAN RUN IN THE HOLEAND CUTTHE20"CASING - 7 BPM, 655 PSI _�—_. _ _= 60 RPM, 2-5 KFT-LBS TORQUE _ ..._ 12:00 - 13:00 1.00 PXA P 1,330.00 ABAN PULL AND LAY DOWN 20" CASING CUT - TIE OFFAND REMOVE CUTTERASSEMBLY ! AND PULL TO FLOOR �I -L/D CUT20" OUTSIDE: 12.32'OAL - PUMP OUT FLUID LEVEL DOWN TO I3-3/8" 73:00 - 13:30 ,CASING STUMP 0.50 ~PXA � P 1,330.00 ARAN 'LAY DOWN MULTI -STRING CUTTER ASSEMBLY PER SLB FISHING REP 0.50 PXA P 1,330.00 ABAN MAKE UP SPEAR ASSEMBLEY DRESSED TO 113:30 - 14:00 ! II CATCH 13-3/8" CASING PER SLB FISHING 11400 - 00:00 10.00 PXA P 1 1,330.00 ABAN ENGAGE I3-3/8" CASING AND ATTEMPT TO IPULLFREE -JAR ON FISH FROM 135-210 KLBSAND STRAIGHT PULL FROM 325-400 KLBS j - STOP AND PERFORM JARRING . INSPECTIONS EVERY 25-30 HITS ON THE JARS - TOTAL JAR HITS FOR LAST 24 HRS =216 I ABLE TO MOVE FISH UP THE HOLE TAT 140 ! KLBS STRING WEIGHT BEFORE PULLING 1 TIGHTAND FIRING JARS EACH TIME. FISH I MOVED BACK DOWN HOLE EVERY TIME I WHEN RE -COCKING JARS. UNABLE TO MOVE FISH BEYOND THAT 5' WITH JAR HITS UP TO 1, 210-220 KLBS AND STRAIGHT PULLS UP TO 400 KLBS. 1.00 PXA 11 P 1,330.00 ABAN RELEASE SPEAR AND LAY DOWN SPEAR 9/3/2019 100'00 - 01:00 ASSEMBLY Printed 11/25/2019 10:33:20AM "All depths reported in Drillers Depths"' Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths" North Amenca - ALASKA - BP Page 10 of 11 Operation Summary Report Common Well Name: 02-02 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 8/27/2019 Eno Date: 9/3/2019 H-S4CW00022K-EX-JO (1,600,000.001 Project: PBU-- -- - -- Site: 02 -- Rig Name/No.: PARKER 272 ! Spud Date/Time: 6/9/1970 12:OO:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From - To. Hrs Task Code NPT' Total Depth Phase Description of Operations (hr) (usft) 01:00 - 02:30 1.50 PXA _ p— 1,330.00 ABAN MAKE UP MULTI -STRING CUTTER DRESSED — ' I TO CUT 13-3/8" CASING 02:30 - 03:00 1 O50 PXA 1'330 00 I CUT CASING AT 89' MD !-80 612 P" -6 BPM, 612 PSI .------ ! RPM, 1.5-3.5 KFT-LBS TORQUE - 03:00 03:30 0.50 PXA P I 1,330.00 ABAN LAV DOWN MULTI -STRING CUTTER —; _ _� _ASSEMBLY 0330 - 04:30 1.00 PXA P 1,330.00 ABAN MAKE UP SPEAR ASSEMBLY DRESSED TO ------CATCH —� �i 1 13-3/8" CASING ,04:30 06:00 3.50 PXA P—T_ 1,330.00 ABAN !ENGAGE I3-3/8" CASING AND ATTEMPT TO _ PULLFREE - JAR ON FISH FROM 135-210 KLBS AND STRAIGHT PULL FROM 325-350 KLBS ' ! -TOTAL JAR HITS SINCE MIDNIGHT =90 ;DECISION MADE TO CEASE JARRING OPERATIONS, RUN A KILL STRING AND RDMO 1 _08:30 --1_�_ 08:00 - 0830 0.50 PXA p 1.330.00 ABAN I PERFOOI-37. _—_ PERFORM POST -JARRING INSPECTIONS __..._.- �—� 08:30 - 09:30 1.00 PXA P ABAN I 1,330.00 —_.- — RELEASE SPEAR AND LAY DOWN SPEAR �---ASSEMBLY FISHING PER SLB REP 0830 10:0� _ - 0.50 PXA P 1,330.00 i ABAN I, CLEAN ANDOLEAR RIG FLOORROFOF LOOSE LOOSE I i —p�_ ~ ITEMS AND SLB FI SHING TOOLS 10:00.00 3.00 PXA 1,330.00 ABAN LAY DOWN DRILL STANDS FROM DERRICK USING OFF-LINE STAND BUILDING EQUIPMENT - - SUCK OUT CONDUCTOR TO 13-3/8" AND ! - DOCUMENTFORAOGCC - RIG DOWN DOYON CASING TONGS AND ------ -...._—_ .._. -� _�- _ _--_- _— 13-3/8" HANDLING EQUIPMENT 13:00 - 14:00 1.00 PXA P 1 1,330.00 N RIG UP TO RUN 4-1/2",12.6 NET NSCT KILL STRING i -RIG UP 4-1/2" HANDLING EQUIPMENT - RIG UP DOYON CASING TONGS 14:00 1630 2.50 — —�--- PXA P 1,330.00 ! ABAN RUN 4-1/2', 12.6 #/FT NSCT KILL STRING TO 1269' MD (FROM RIG FLOOR), 1227' FROM TOP OF CONDUCTOR 1 - USE BEST -OF -LIFE PIPE DOPE - TORQUE CONNECTIONS TO 4 KFT-LBS - INSTALL MODIFIED HANGER BEAM AND LAND ON CONDUCTOR ' 18:30 - 18:30 2.00 PXA P 1,330.00 ABAN 'CIRCULATE 9.8 BRINE SURFACE TO SURFACE - RIG UP SECONDARY KILL LINE TO TOP OF KILL STRING - 8.5 BPM, 1500 PSI - BLOW DOWN LINES AND RIG DOWN FROM TUBING j 2 BBLS OF $AND AND SOME ARCTIC PACK BACKTO CELLAR BOXAT BOTTOMS UP Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths" Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths** North Arnenra - ALASKA - BID Page 11 of 11 Operation Summary Report - Common Well Name: 02-02 AFE No Event Type: PLUGANDABANDON(PXA) Start Date: 8/27/2019 End Date: 9/3/2019 iH-S4CW00022K-EX-JO(1,600,000.00) Project: PBU Site 02 I Rig Name/No.: PARKER 272 Spud Date/Time: 6/9/1970 12:00:OOAM Rig Release: 9/3/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000973 Active datum: PARKER 272 @77.65usft (above Mean Sea Level) Date From - To Hrs ! Task Cade NPT , Total Depth Phase Description of Operations (h r) ! 1 (usft) j 18:30 - 23:00 4.50PXA j p 1 1,330.00 li ARAN RID DOWN AND PREP FOR MOVE TO OSO1-37 -EMPTY CLEAN PITS i- ARCTIC PACKAND SAND IN ACTIVE 1 AND 2 SIMOPS: i- BRIDLE UP AND RIG DOWN RIG FLOOR 'EQUIPMENT - SKID RIG FLOOR TO MOVE POSITION 1 I,- LAY DERRICK ON HEADACH RACK; 360 KLBS ON THE RACK FINISH OFFLOADING FLUIDS FROM PITS AT 23:00 HRS - i RIG RELEASE FROM 02-02AAT 23:00 HRS Printed 11/25/2019 10:33:20AM **All depths reported in Drillers Depths** (LRS Unit 42 - Hot Oil Treatment) Road to location and spot equipment 9/13/2019 ***WSR Continued on 09/14/2019*** ****WSR Continued from 09/13/2019*** (LRS Unit 42 - Hat Oil Treatment) Pumped 207 bbls of 190* 9.8 ppg Brine down TBG while taking returns up the conductor which was being sucked out by the vac truck Capped well with a LRS 1502 cap 9/14/2019 Final WHP= 3 T/IA=O. (Circ out OOA) Pumped 206 bbls 200* 9.8 brine down TBG w/returns up OOA 9/27/2019 to vac truck. Vac truck vac out 193 bbls 9.8 brine from OOA. FWHP= 0 T/1/0= 0/0/0. (LRS Unit 46 - Weekly OA Thaw) HOT wellbore w/ 3 bbls 60/40, folowed by 100 bbls of 180* 9.8 brine down tbg taking returns up 13-3/8" to vac truck. ***Vac truck was getting 1 for 1 returns. *** Flush heating coils and Freeze Protect Surface Lines w/ 6 bbls 60/40. 10/13/2019 FWHP= 0/0/0 (SLB Cement Crew - Surface Cement Plug) Pump the following down the tubing, taking returns up the Conductor to Vac Truck: 5 bbls 60/40, 5 bbls Freshwater, 507 bbls 15.8 ppg Class G Cement. TOC in TBG and conductor at Surface. 10/14/2019 ***Job continued on 10/15/19*** 10/15/2019 (SLB Cement Crew - Surface Cement Plug) Finish Wash Up. Rig Down *** 02-02 P&A *** De-completed well. Tubing dropped out approximately 44.5'. AS1 Cement used to fill void in tubing. Approximately 30.5 gal. used for cement top job. 10/19/2019 *** Job In Progress *** *** Permanent P&A. *** Excavate around wellhead to 17'. Cut wellhead 12' 10" below pad grade. 20" X 30" conductor annulus full of gravel. Removed T of gravel and topped with AS-1 cement. Pad elevation 31.2', tundra elevation 25.0'. Wellhead cut = 6' 8" below tundra grade. AOGCC witness of TOC and marker plate install is Guy Cook. *** P&A In Progress unable to pull shoring box and backfill excavation with gravel due to high winds*** 10/30/2019 *** 02-02 P&A *** Job Continued *** Pulled shoring box and rig mats. Backfilled and compact excavation above pad grade. 11/2/2019 *** Job Complete *** I lk 'Alit, E• MEMORANDUM TO: FROM Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: 10/31/19 Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector PBU 02-02A - BPXA PTD 1971680; Sundry 319219 10/30/19: 1 arrived on site and met with Jon Arend (BPXA) who was over -seeing the surface abandonment of PBU 02-02A. I witnessed hos confirmation of good hard cement to surface and confirmed the cut-off depth was 6 feet 8 inches below ground level. I confirmed the correct information was on the identification plate. The plate was completely welded on the outermost casing string and photo documented. I told Mr. — Arend he could carry on with burial operations. Attachments: Photos (3) 2019-1030_Surface_Abandon_PBU _ 02-02A_gc.docx Page 1 of 3 ae M., �l MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg i 2 «loAI iq DATE: 10/10/19 P. I. Supervisor FROM: Matt Herrera SUBJECT: PBU 02-02A Well Decomplete Petroleum Inspector Inspection of Recovered Tubulars PBOC Grieve Pad BPXA PTD 1971680; Sundry 319.219 10/10/19: Traveled out to Prudhoe Bay Operations Center "Grieve" Pad with BPXA rep Josh Prowant to observe and take photos of tubing and casing strings removed from PBU 02-02A (PTD 1971680) de -completion process after a well failure incident. I spoke with BPXA Engineering Group rep Andy Ogg and got information on the de -completion process recently completed with Parker Rig 272. The 5 -inch tubing was removed from cutoff point for P&A along with 9 5/8" casing. The well head was pulled with a small amount of conductor and surface casing attached. The conductor and surface casing show substantial damage although unclear if result of rig work or wellhead incident. Production casing and tubing appeared to be in relatively good condition. Attachments: Photos 2019-1010_ Casing_Decomplete Tubulars PBU_02-02A_mh.docx Page 1 of 3 ~ PZ � - Am i �-- 2019-1010_Casing_Decomplete_Tubulars _ PBU_02-02A_mh.docx Page 3 of 3 19 16� 31305 WELL LOG TRANSMITTAL #905898410 To: Alaska Oil and Gas Conservation Comm. October 2, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 02-02A Run Date: 8/7/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 02-02A Data in LAS format, Digital Log Image files 1 CD Rom 50-029-20074-01 RECEIVED OCT 0 7 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS ANC@halliburton.com and GANCPDC@USAANC.hou.xwh.BP.com Date: In 0 1 P Signed: 197158 by Date: 8/23/2019 3 1 15 3 010 Transmittal Number: 93703. 6 Z BPXA WELL DATA TRANSMITTAL Enclosed are two (2) discs containing the information listed below. If you have any questions please contact Merton Kendall: 907-564-5216; merion kendall(&.bmcom. SW Name API 02-02 500292007400 Date 7/27/2019 Com an BPXA Descri tion COMPOSITED GYROSCOPIC SURVEY Disk Number 1 02-02A 500292007401 7/27/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 03-28 500292111400 7/24/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 04-01 500292007800 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 04-01A 500292007801 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 09-44 500292208700 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44A 500292208701 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44APB1 500292208770 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 V-227 500292341700 7/20/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 Please Sign and Email a copy of this transmittal to. GANCPDCgbp365 onmicrosofl com Thank you, .filer Xendaff Subsurface Information Management AOGCC Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska 1 Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Date: 8/23/2019 *4tl1�t' Transmittal Number: 93703 d i CY BPXA WELL DATA TRANSMITTAL Enclosed are two (2) discs containing the information listed below. 197138 Date 7/27/2019 Com an BPXA Descri tion COMPOSITED GYROSCOPIC SURVEY 31152 02-02A 500292007401 7/27/2019 BPXA If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bD.com. SW Name API 02-02 500292007400 Date 7/27/2019 Com an BPXA Descri tion COMPOSITED GYROSCOPIC SURVEY Disk Number 1 02-02A 500292007401 7/27/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 03-28 500292111400 7/24/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 04-01 500292007800 8/3/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 1 04-01A 500292007801 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 09-44 500292208700 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44A 500292208701 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44APB1 500292208770 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 V-227 500292341700 7/20/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 Please Sign and Email a copy of this transmittal to. GANCPDCkbp365 onmicrosoftcom Thank you, .Ater .7Cendaff Subsurface Information Management AOGCC Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Sean M. McLaughlin Engineering Team Lead - CTD BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 995519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 02-02A Permit to Drill Number: 197-168 Sundry Number: 319-219 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 vvvvw.aogc c.aloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Lf-x:!!5� Daniel T. Seamount, Jr. Commissioner -141 DATED this 'T day of May, 2019. RBQMS fi/ MAY 0 9 2919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 2 9 2019 1. Type of Request: Abandon 0 • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Oil t�5 ¢hylrg((pr y,�nnA`tC�7,-, tdP%AXq' Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change A{pf3,rd9EjtlIM• Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ After -Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0. 5. Permit to Drill Number: 197-168 ' 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service ❑ 6. API Number: 50-029-20074-01-00 7. If perforating: What Regulation or Conservation Order govems well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 02-02A 9, Property Designation (Lease Number): 10. Field/Pools: ADL 028308 & 028326 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ff): Total Depth TVD(ff): Effective Depth MD: Effective Depth TVD:MPSP (psi): Plugs (MD): Junk (MD): 12309 • 8666 2362, 9217,11fi69900 0, 2362 2362 87 10776 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 34-114 34-114 880 Surface 1431 20" 33-1464 33-1464 1530/2320 520/1500 Intermediate 2660 13-3/8" 31-2691 31-2691 4930 2670 Intermediate 10577 9-5/8" 29-10606 29 _8626 8150 / 7510 / 6820 5080 / 4130 / 3330 Liner 2331 3-1/2" x 3-3/16" x 2-7/8" 9978-12309 1 8165-8866 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace:Tubing MD (ft): 11040- 12275 8844 - 8866 5-1/2" 17# x 4-1/2" 12.6# L-80 / N-80 26-10039 Packers and SSSV Type: 5.12• Baker SAB Pecker Packers and SSSV MO (ft) and TVD (ft): 9905 / 8112 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class afterro p posetl work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: June 1, 2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abantloned 0 - 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Mclaughlin, Sean M be deviated from without prior written approval. Contact Email: Sean.McLaughlin@bp.com Authorized Name: Mclaughlin, Sean M Contact Phone: Authorized Title: Engineering Team Lead - CTD Authorized Signature: Mr ✓� Date: � It COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3101- 21 q Plug Integrity 13 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: 0_9 40--q--rI'C J �YV=0.1 �AiLYSrwVl WbriRY of 6QGR 14T7e.usTa 140GCL RBDMSI�MAY 0 9 ?019 Post Initial Injection MIT Req'd? Yes ❑ No ❑/ Spacing Exception Required? Yes ❑ No l7 Subsequent Form Required: 16 _yds APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:51711171 Form 10-403 Revised 04/2017 ORIGINAL I "&f~ ' / Submit Fonn antl Approved application is valid for 12 months from the date of approval. L /,rAttachments in Duplicate Sundry request for 02-02 Final Abandonment Well: 02-02A Date: 4/25/19 Engineer: Sean McLaughlin MASP: 87 psi (for DPZ 1 and water flow- no gas) Well Type: Producer Estimated Start date: June 1512019 History: The 02-02A reservoir was abandoned under Sundry 318-585. There is a deep cement plug from 9734' to 9227'. Another cement plug was placed from 9000' to 2362'. The tubing, production and surface casings have been perforated at 1300'. This Sundry request is to perform final abandonment for 02-02 and fill the obligations of 00 149. Scope of Work: The objective of the remainer of the P&A is to gather surveillance information on the casing strings and then perform the final P&A at surface. - All recovered casing will be numbered and saved for study. All casing will be tested for NORM. AOGCC will be notified to inspect the casing strings. Proposed P&A Procedure: 1. Tool Service- Excavate and line the cellar with an impenetrable barrier 2. Valve Shop- ND upper tree. Pull master valve and THA. BOLDS and pull hanger. Pull tubing bushing 3. Projects- (Contingent if not able to pull hanger with crane) NU 13-5/8" hub x flange, RU Wfd casing jacks. Spear and pull 5-1/2" tubing hanger. Pull tubing bushing 4. Valve shop- NU dry hole tree to secure well with old hub and 7-1/16" master. 5. Eline- Cut 5-1/2" tubing at 2300' 6. Tool Service- Prepare pad for AAO 111 pulling unit (no elevation change, NO BOPE installed) 7. AAO- ND dry hole tree and tubing head adapter. Spear tubing and circulate the well to 9.8 ppg brine taking returns to IA and cellar. LD 5-1/2" tubing. Freeze protect to 500'. 8. AAO- RU Eline. Make gauge run. Cleanout 9-5/8" if necessary. NU THA and master valve. 9. Eline- If necessary, ND THA and master valve. Caliper and Gyro log of 9-5/8" casing to 2300' 10. Eline- Punch 9-5/8" csg at 1850' 11. Eline- Set cmt retainer at 1800' 12. Coil- Stab into retainer and fill 9-5/8" x 13-3/8" annulas w/ cement to 1400'. Unstab and fill 9-5/8" csg w/ cmt to 1400'. 13. Projects- Verify no surface compression in the 9-5/8" by working LDS. If compression is expected utilize Cameron compression release flange. 14. Eline- Cmt log the 9-5/8" casing 15. Eline- Cut 9-5/8" above TOC (-1400') 16. Projects- Cut off wellhead. Use Crane to stabilize while cutting. Recover 20" stub if possible. 17. Projects- Install 13-3/8" landing ring x flange top (may need to recut 30" and 20" to get clean 13- 3/8" top), NU flow cross 18. Tool Service- Prep pad for Parker 272 19. Parker- NU 13-5/8" Annular (Use as flow diverter, No bell nipple) 20. Parker- Spear 9-5/8", reciprocate and circulate to tank and cellar, Lay down 9-5/8" casing. Need 14" high torque tongs 21. Parker- RU eline to caliper 13-3/8" casing 22. Parker- Internal cut of 13-3/8" at 1250' and 100' 23. Parker- Set down landing ring and stub 24. P- Spear 13-3/8", reciprocate and circulate to cellar, Lay down 13-3/8" casing. Be prepared to cut casing apart 01 25. Parker- Install hole cover, RDMO 26. Eline- Caliper and GR/CCL/Hi-Res Temp Log 20" 27. Projects- Use junk string to cement to surface Fill all unfilled annuli to surface with cement. Excavate and cut all casings 3' below Tundra Notify Inspector of opportunity to witness cut off prior to welding plate. Take picture once the wellhead is cut off. 28. Bead wel an a andonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. 02-02 PTD#1971680 \1 API No. 50-029-20074 w 29. Backfill excavation with gravel/fill to ground level. 30. Obtain Site Clearance Approval from AOGCC. IM FMC DRY HOLE TREE MCE1/DY 02-02A WALPEAD = SIZE ACTLIATOR= BAKl3RC 0103. HEV SHOT BF. HEV = 2" KOP= 30 00' Max Angle = 9B' @ 11858' Datum M)= 11148' Datum TVD= 88W SS (01/30/19) 1 1464' 1 13-3/8" CSG, 72A, N-80, D =12.347" H 2691' �- >• TBG 8 9-58' CSG PINCH, 90001- 901W — POWHR FLOW GUN (1226118) 2- TBG 8 9-5/8" CSG PNCH, U 9734' - 9744' SLM POWER FLOW GUN (12/17/18) Minimum ID = 2.376" @ 10734' 3-1/16" x 2-7/8" XO Y TBG -PC, 17#, L -8O, .0232 bpf, D = 4.882" 9918' TOP OF 4-12" THC PC 9918' (TOP OF 3-12' LMR 1—j 9982' 3-12' LMR 9.29, L-80 RAS, -0087 bpf, D= 2.992' 10012' TOP OF 3-3/18" LNR 10012' 4-12' TBG-PC,12.69. N-80, .0152 bpf, D = 3.958• 10014' 1 9-5/8' PERFORATION SLMWIRY FEFLOG: WOON01/31/98 ANGLEATTOPPHRF 71'@11040 We: Refer to Production DB for Wtorical perf data SIZE SPF NIHRVAL OpnISgz SHOT SQZ 2" 6 11040- 11090 C 05125103 1227/18 NXVWJI#U R1NCH D TBG 8 CSG (12126/1 8) 2' 6 11210- 11235 C 1027/02 4-12" BAKER R NP, D= 3.759" 2" 6 11325 - 11350 C 1027102 1-11/16" 4 11492- 11630 C 02/04/98 EMDTTLOoGECoi 11/89 1-11/16" 4 11700- 11820 C 02AW98 1-11116' 4 12225-17175 C 02/04198 3-3/16' LIVR 6.29, L-80, .0099 bpf, D = 2.75' 2-7/8• LNR, 6.5#, L-80 SAFETY NOTES: W ELL ANGLE> 70' @ 10892' 8002' TBG 8 CSG CMF LAD N FROM PINCHES (1228118) SL TAGGED { 9776' 1—x5-12" OTS SLIDING SLV, 1)=4.562" REV BY OOMARM 02/07!88 5-12" BOT PBR ASSY 9677' 9906' RIWJMD ADDED 30"ODrD 01/23/19 9.5/8' X 5-12" RAKH25AB RQ2 12/20/18 JTC/JND PBA STAGE I(SL 80DL) 02/05/19 8918' 1227/18 NXVWJI#U R1NCH D TBG 8 CSG (12126/1 8) 5-12' X 4-12" XO, D = 3.956' - 8978' KR'JMD TREEC/O 3-12" BAKER SETING SLV, D=3.001 9979' 4-12" BAKER R NP, D= 3.759" 10012' 3-12• X 3-3/16" XO, D = 2.750' 10014' 4-12• Tl16NG TAIL (BBiJD Ci LMR) 10024' EMDTTLOoGECoi 11/89 LMR 9-5/8' &&LOUT WINDOW 10606'- 10612' 10734' 3-3/16' X 2-7/8" XO, D - 2. 10776' 2-71W BKR Cl3P (0 DATE REV BY COMVBJlS DATE REV BY OOMARM 02/07!88 LAST WOMMER 01/07/19 JLIJMD SL TAGGED TOC (01103/19) 07/25/17 RIWJMD ADDED 30"ODrD 01/23/19 KF/JNID PROD TREE C/O TO DRY HOLE TREE 12/20/18 JTC/JND PBA STAGE I(SL 80DL) 02/05/19 BTNJMD TBG RNCI-M(01/30/19) 1227/18 NXVWJI#U R1NCH D TBG 8 CSG (12126/1 8) 1227/18 KR'JMD TREEC/O 12/31/18 JTRNJMD LAD N CMF FROM TBG RINCFES SYNCH HOE RRUDHOE BAY LW WELL: 02-02A PERMT No: 9971680 AH No: 50-029-20074-01 SEC 36, T11 H RUE, 827' FNL 6 1728' BP Exploration (Alaska( F1,ec�wie MCEVOY K�c PROPOSED WELLHEAD= TBG amsa-I 1300'-1310' REFLOG: WID ON 01/31/98 ACTUATOR= BA OKB. EEV = 64' BF. EV = B SHOT KOP= 30 00' Max Angle = 98' @ 11858' Datum MD= Datum TVD 11148' 8800 'SS — (o1/3oH9) LO" CSG, 94# / 133#, H440 / K-55, D =19.124" 1464' I 13-318" CSG, 72#, PF80, D =12.347' 2691' — 5-12" TBG & 9-5/8" CSG PUWJ H, 9000'- 9010' — 2.5" POWER FLOW GUJ (1226/18) 5-12RM H, TBG & 9-5/8" CSG RH, 9734' - 9744' SLNI 2.5" POWER FLOW GUN (12/17110) Minimum ID =2.375" 10734' 34116" x 2-7/6" XO 5-1/2" TBG -PC, 17#, L-80, .0232 bpf, D 92 =4.0" 9' 991 TOPOF4-12"TBGPC 9916' 3-12" LN2 13-12" O2—O2A SAFETYNO` WELL ANGLE >70"@10892' L Fully cement to surface 13-3/8" Tubing Stub - -1250' 9-5/8" Tubing Stub - -1400' Cement in 9-5/8" x 13-3/8" - -1400'- 1850' 5-1/2" tubing stub at 2300' 2362' - 9002' TBG & CSG CMf LAD N FROM RNCHM (1228118) SL TAGGED 1 BKR a3P (12/18/18) BOT PBR ASSY 5-12" X 4-12" XO, D =3-958" 1 3-12" BAKER SETTNC SIV, D = 3.000" 4-12" BAKER R NP, D= 3.759" = 2.750" 1412" IBGPC,12.6#, N-80, .0152 bpf, D = 3.950' 1--1 10014' i \ 10014' 4-12" TIBNG TAIL (BERND C 10024' EMJ TT LOGG®01/11/69 10096' TOP--�� I19 -51W CSG. 40#. 43.5#.47#. SOO-95_ID=8681" I PERFORATION SLAM1ARY REFLOG: WID ON 01/31/98 ANGLEAT TOP PERF: 71-@110400 Note: Refer to Production DB for historical pert date SIZE SPF NIERVAL OpNSgz SHOT SQZ 2" 6 11040 - 11090 C 0525/03 2" 6 11210- 11235 C 10/27/02 JTWJMD LAD N CMT FROM TBG PUNCHES 2" 6 11325 - 11350 C 1027/02 1-11/16" 4 11492-11630 C 02/04/98 1-11/16" 4 11700- 11820 C 02/04/98 1-11116" 4 12225- 12275 C 02AW98 3-3/16" LNR, 6.2#, L-80, .0099 bpf, D = 2.75" ITOP OF 2-7/8" LNi 1 2-7/8" LNR 9-5/8' FLOUT WINDOW 10606'- 10612' ij 10734' 3-3/16' X 2-781" XO, D = 2.375- DATE REV BY 00MMENTS DATE MB REV BY COMNfS 02/07/98 LASTWORKDVH2 01/07/19 JUJMD SL TAGGED TOC(01/03/19) 07/25/17 RIWJMD ADDED 30"OOND 0123/19 KPVJMD PROD THEE C/O TO DRY HOLE TREE 12/20/18 JTCGMD P&A STAGE 1 (SL & ODL) 02105/19 BTNJMD TBG PUNCHES (01130/19) 1227118 NXW/J PIUNK>M TBG & CSG (1226/18) 12/27118 KRJMD TREE CJO 12/31/18 JTWJMD LAD N CMT FROM TBG PUNCHES 1 12306' 1 PRUDHOE BAY UNIT WELL: 02-02A PERMIT No: 91971680 AR No: 50-029-20074-01 SEE 36, T11 P1 R14E; 82T F'PL & 1728' FWL BP Exploration (Alaska( OP ROWN BEAM w Y i tiit Em C/L WELL 3E' DN PIPE SEAL WIIDFD ro IFN BDTfG1 DP INE ROWBOK �3ro. .—..__... INNER DM TRIPLE INMTABLE RUBBW SELL WELL t - Rf11 qM LI 18' DN WFILL IW' DM LN O 3' GSING ? $ OUNEI (Ott OF Z) 1 I3 5/W' SM MYOY M FLANGE I/ tY NEWER A. M. GRP (1 G) 3' Otl SID. OUREf (1 G) Y DIA M. OIIREi 1 CWCH LOG( DOWN FIANCE ANI BOP } - 13-5/8' 5M MVST R LWT I.YS/W' SN SIUODED TUP _ - 1}5/8' SM f1INGED 8011GL -_ RAM ME BCP: 13 5/W' W NW W10 OWBIE BOP 13 5/B' 5M Si WED POP CELVR WCK PIAIPORIII 13 5/9' SM III BORgI W/ 3-1/2' VWUAL LOIM W/ 11' B005TER 0111LI NG CR055: -r 13 5/8' W MDDEO TOP 13 5/8' SY WGED mm I _ W (3) 3 1/88 SY SIOE WHETS III I � qLL NNE Y9h W A MDSE itlb 1 111 . n 2-1/18' SM K 3-1/8' SM D.SA. FIANGED GC }1/6.5M "IGTE VALVE GIVA SM RANGED M'DWAWC ,TE vI1vE RAM ME BW: 111 41_I_� ili 13 5/6' 511 NW W12 SINGI£ BOP IL 13 5/8' SM MEDED TDP �1 13 5/6' 5M RHIGED W70M NIPPLE W: ! w SPACER SPOOL 13 5/W' SM FLANGE TOP LLE IS 5/8' SM Fl.VIGFD 80110M DND J-,/8' 3FI RANGCED WWG1E N. VALVE BPAIDER SPOOL SM RANGED NIC GTE VALVE Y'a• 13 5/8 51A RANGE TOP J -1/8111/w SN RIX NOSE 13 5/e' SM FIARCED WOTIDV WUBIE SRNNIED ADAPTER IJ 5/8' 5M III TDP Ir SM RANGED BOTTOM CGLIM ANO WELL HEAD CONRGURATIO GSgC SPOOL �SEN�Y ARE FM REFERENCE ONLY 6: ARE ,1 SM RANGED NOP DEPENOFIR ON DPEP.00R'S MQUIREMENIS 11' SM FI BOROM CASN6 HEAD .ASSEAWLY W SM RANGED TOP 6012 BOP STACK (DRAFT 8.3.17 L. C.) BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 02-02A (197-168) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 1,000,000 t c O a 100,000 LL u g o H M 10,000 ro_ L 'o o O M v (7 ri c 1,000 u Z 3 u v M 100 0 z 10 1 Jan -1995 •1,200 Cum. Prod Gas (mcf): 44,899,826 Jan -2010 Jan -2015 �— Produced Gas (MCFM) • GOR Produced Water (BOPM) Produced Oil(BOPM) SII (�■� 'YIIII It�I �(MII',� 1 I���� �������� a�aaal•aaaalaaaaalaaaa��aaaalaaaa�aaaaalaaaaa�aaaaal Jan -2000 Jan -2005 Jan -2010 Jan -2015 �— Produced Gas (MCFM) • GOR Produced Water (BOPM) Produced Oil(BOPM) 10,000,000 Co w 1,000,000 0 O 100,000 0 0 0 3 10,000 S 0 1 Jan -2020 SP READSH EET_1971680_PBU_02-02A_Prod-I nject_Cuwes_W e II_Oi I_V120_20190501.x1sx 5/1/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WFLL nPFRATIntuC •rvv■ w 111.111.0 APR 2 5 2019 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 11Operations shutdown --74 C C❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir 0 2. Operator Name: BP Exploration (Alaska), Inc Well Class Before Work [Otevelopment0 Exploratory ❑ 5. Permit to 0611 Number: 197-168 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 tigraphic ❑ Service ❑ e. API Number: 50-029-20074-01-00 7. Property Designation (Lease Number): ADL 028308 8 028326 8. Well Name and Number: PBU 02-02A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: 2362, 9217, 9900 Total Depth: measured 12309 feet Plugs measured 10776, 11660 feet true vertical 8866 feet Junk measured None Leet Effective Depth: measured 2362 feet Packer measured 9905 feet true vertical 2362 feet Packer true vertical 8712 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 30" 34-114 34-114 880 Surface 1431 20" 33-1464 33-1464 1530 / 2320 52011500 Intermediate 2660 13-3/8" 31 -2691 31 -2691 4930 2670 Production 10577 9-5/8" 29-10606 29-8626 8150 / 7510 / 6820 5080 1413013330 Liner 2331 3-1/2" x 3-3/16" x 2 9978-12309 8165-8866 Perforation Depth: Measured depth: 11040 - 12275 feet True vertical depth: 8644-8866 feet Tubing (size, grade, measured and true vertical depth) 5-1/7'17# x 4-1/2" 12.6# 26-10039 26-8210 Packers and SSSV (type, measured and 51/2" Baker SAB Packer 9905 8112 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-in Subsequent to operation: Shut -In 14. Attachments: (requires per20 MC 2s 070.25.071, a 25.2eal 15, Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: 0 Oil Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ iGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318547 & 318585 Authorized Name: Worthington, Area J Contact Name: Worthington, Area J Authorized Title: Interventio 8 Integnty, Engineer Contact Email: Area. Worthington0bp.com Authorized Signature: Date: Contact Phone: +1 907 564 4102 Form 10-404 Revised 04/2017 A W(f 1^ G� Kcf rtmri ((_r( RBDI111S10-WAPR 2 6 2019 Submit Original Only Daily Report of Well Operations 02-02A Ar.TIVITVnATF ci innnnn0V Standby on Pad 10, for DS2-02 12/7/2018 **** Job continued on 12/08/28 **" 12/8/2018 ****SWCP 4518 CONTINUE STANDBY TO ASSIST ON DS2-02*** T/I/O=SI Assist as directed (WELLHEAD OR TREE MAINT) LRS 46 standby 12/8/2018 End ticket, *** Job continued on 12/09/18 **. T/I/O = SSV/ 80/0. Temp = SI. Bleed IAP. Hold open bleed on IA, down flowline of 02-01. All gas. 12/8/2018 ***' Continued on 12/09/18 WSR**** T/1/0/00=SSV/200/0/0, Temp=Sl. 12/8/2018 12-7-18: Respond to DS02-02 incident. Standby to assist as needed. 12/8/2018 LRS unit 72 standby for 02-02 Conten enc 12/9/2018 ***SWCP 4518 CONTINUE STANDBY TO ASSIST ON DS2-02*** ***Continued from 12-8-18*** T/I/O = 150/150/. Temp = SI. Assist with well head repair. Wellhouse and wellhead scaffolding is removed. Hardline is rigged up to wing valve for pumping operations. TBG, & IA FL @ 1190'(1 007'above sssv. TBG = 27 bbl, IA = 52 bbls). Bled TP, & IAP to OT from 1600 psi to 1000 psi in 10 min. ***WSR CONT ON 12/10/2018***. Current WHPs = 1024/1041 Nac SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 12/9/2018 T/I/O = 0/0/0. Removed damaged SV platform. Cycled MV 32 turns (Pass), Cycled SSV Full stroke (Pass), Cycled WV 22 turns (Pass), Cycled SV 22 turns (Pass). Measured gap THAxMV, Tightened THAxMV studs movement on all studs, remeasured gap 12/9/2018 3/16") @ 3-6-9-12 o'clock positions. ***Job continued from 12/08/18 WSR*** T/1/0=900/900/0 SI Assist with Well Control (WELLHEADITREE MAINT) Pumped a total of 60 bbls of 60/40 down TBG. TBG and IA continue to come up. Standby and monitor pressures. 12/9/2018 **** Job continued on 12/10/18 ***Job continued from 12/09/18 WSR*** Monitor/record pressures as directed, Continue 12/10/2018 WSR to 12/11/18 T/l/O = 1024/1041Nac. Temp = SI. Assist with well head repair. Wellhouse and wellhead scaffolding is removed. Hardline is rigged up to wing valve for pumping operations. Monitored TP, & IAP post bleed. Current WHPs = 1194/1209NAC. ***WSR CONT ON 12/11/2018*** SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59. 12/10/2018 ***Job continued from 12/10/18 WSR*** Monitor/Record pressures as directed. ***Continue 12/11/2018 job to 12/12/18*** ***Continued from 12-10-18*** T/l/O = 1194/1209Nac. Temp = SI. Assist with well head repair. Wellhouse and wellhead scaffolding is removed. Hardline is rigged up to wing valve for pumping operations. 12/11/2018 Monitored TP, & IAP post bleed. ***Contrinued on WSR 12-12-18*'* T/I/O = SSV/1070Nac. Temp = SI. Assist with well head repair. Wellhouse and wellhead scaffolding is removed. Hardline is rigged up to wing valve for pumping operations. DHD CNG hose bleed lines left rigged up to tank. WV left open to hardline block valve. 50'x 1/4" hose rigged up to SSV, & placed in containment @ base of scaffolidng for remote operation of SSV. 12/12/2018 ISV, SSV = C. WV, MV = O. IA, OA = OTG. 21:00 Daily Report of Well Operations 02-02A ***Continued from WSR 12-11-18*** T/I/O = 1195/1213Nac. Temp = SI. Assist with well head repair. Wellhouse and wellhead scaffolding is removed. Hardline is rigged up to wing valve for pumping operations. Monitored TP, & IAP post bleed. HES, LRS rigged down and off location. DHD CNG hose bleed lines left rigged up to tank. WV left open to hardline block valves. FWHP's = 12/12/2018 1050/1060Nac. ***WELL S/I ON ARRIVAL*** (plug and abandonment- reservoir) DRIFT W/ 4.3" CENT, 4.1" LIB, SD 21' SLM, PICTURE OF 5-1/2" TUBING STRING TAGGED PARTED PIPE @ 21' SLM W/ 4.5" LIB (picture of parted pipe) TAGGED PARTED PIPE @ 21' SLM W/ 5-1/2" BLB, 4.1" LIB (picture of parted pipe) TAGGED PARTED PIPE @ 21' SLM W/ 5-1/2" BLB, 4.125" LIB (picture of parted pipe) TAGGED PARTED PIPE @ 21' SLM W/ 5-1/2" BLB, 3.25" LIB (picture of parted pipe) TAGGED PARTED PIPE @ 21' SLM W/ 5-1/2" BLB, 2.50" LIB (picture of parted pipe) DRIFTED TO SSD @ 9775' MD W/ 2.50" CENT TAGGED PARTED PIPE @ 21' SLM W/ 2.85" SWAGE 12/12/2018 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** ***Job continued from 12/11/18 WSR*** Monitor/Record pressures as directed LRS 12/12/2018 released SL on well upon departure. CVs OTG FWHP=1055/1058/vac TWO = SSV/1070/Vac. Temp = SI. IA FL. (Pre -P&A). No AL. IA FL @ 1617' using Acoustic velocity of 1200 FPS. Wireless gauge used for OAP, Scaffold needs to be modified or added to for gauge access. Wireless IAP showing 1071 psi in Palantir. 12/13/2018 SV, SSV = C. WV, MV = O. IA, OA = OTG. 21:40 T/I/O = SSV/1070Nac. Temp = SI. WHPs (Pre- P & A). Wellhouse and wellhead scaffolding is removed. Hardline is rigged up towing valve for pumping operations. DHD CNG hose bleed lines rigged up to open top tank. WV left open to hardline block valves. 50' x 1/4" hose rigged up to SSV, & placed in containment @ base of scaffolidng for remote operation of SSV. DHD digital gauge confirms same readings as the WPG gauges. Wirelesss IAP showing 1070 psi in Palantir. 12/13/2018 SV, SSV = C. WV, MV = O. IA, OA = OTG. 17:00. CTU 9 1.75".156" WT Blue Coil ***Continued from 12/13/18*** Job Objective: P&A Continue rig up. 12/14/2018 *"Job in Progress"* T/I/O = SSV/1071/0. Temp = SI. WHP's. (Pre -P&A). Verified IA & OA wireless gauges are reading correct, wireless gauges exactly match readings from DHD calibrated gauges. IAP reading 1070 psi in Palantir. 12/14/2018 CTU in control of all wellhead valves. 19:45 CTU 9 1.75" coil 0.156WT Blue Coil Objective: P&A Standby for wellsupport and scaffolders. MIRU 12/14/2018 ***In progress*** Daily Report of Well Operations 02-02A CTU 9 1.75" coil 0.156WT Blue Coil Objective: P&A Finish rig up. Make up and RIH with 2.75" DJN. Unable to pass 52' CTM. POOH and swap to 2.5" JSN, able to get past same depth. Tagged at 894', jetted as hard as we could with big hole JSN, to no avail. Trip OOH for a proper DJN to eliminate ice plug theory. RIH with 2.5" DJN. Tagged something at 894', jetted hard for -5bbls and it seems like we are pushing something, continue in hole till 1203', jetting hard/stacking close to max wt. Unable to gain any footage. Got whatever is there moving. Tagged a few more spots down to 1687' which, coincidentally were at collars (-40' increments). Decision to mu a larger OD nozzle due to speculation of being beside the 5.5" x 9.625" casing. MU/RIH with 2.75" BDN, sat down at 52', tried several times to no avail. POOH, MU 3.5" BDJSN, rih. Tag down at 41'. POOH for 3.05" jousting nozzle and knuckle joints. Tagged down at 50'. Reconfigure knuckle joints and try again, tag down at 50'. Appears top of tubing stub to be at 40' CTM and first collar creating a tag at 50', as coil was outside of the 5.5" TBG. 12/15/2018 ***Job in Progress*** ***COIL IN CONTROL OF WELL UPON ARRIVAL' (plug and abandon) STANDBY FOR COIL 12/15/2018 ***CONT WSR ON 12/16/18*** ***CONT WSR FROM 12/15/18*** (plug and abandonment) RAN 5 1/2" BRUSH, 3.50" LIB TO 24' SLM (impression of tubing stub) RAN 8.6" BRUSH, 4.5" LIB TO 24' SLM (impression of tubing stub) RAN 5 1/2" BRUSH (stiff), 2.25" LIB TO 24' SLM (impression of tubing stub) RAN 5 1/2" BRUSH (stiff), 2.50" CENT, B.NOSE TO 34' SLM (behind tubing) 12/16/2018 ***CONT WSR ON 12/17/18*** CTU 9 1.75" coil 0.156WT Blue Coil Objective: P&A Make up and RIH with 3.05" jousting nozzle and 3.800" centralizers. Tagged tubing stub at 38' CTM. Could not get past. Turn well over to slickline. 12/16/2018 ***Job in Progress*** T/I/O = SSV/1083/0+. Temp = SI. WHP's. (Pre -P&A). Verified IA & OA wireless gauges are reading correct, IA wireless gauge exactly match readings from CTU calibrated gauge, OA wireless gauge reading .9 psi, CTU gauge reading 7" of vac. Unable to access gauges to check with DHD gauges due to ongoing work on the well at this time by SL. 12/17/2018 SL in control of WH valves. 00:25 CTU 9 1.75" Blue Coil Objective: P&A Stand by for slickline. Slickline shoots 10' pert gun. Begin rigging coil back up. 12/17/2018 ***Job Continued on 12/18/18** ***CONT WSR FROM 12/16/18*** (plug and abandoment-reservoir) RAN 8.6" BRUSH, 2.50" CENT, B.NOSE TO 9,757' SLM (possible ibp) MADE 3 RUNS W/ 11' x 2 1/2" DUMMY GUN (2.66" max od), 8.6" BRUSH, B.NOSE TO 9,761' SLM (possible ibp) RAN SLB EFIRE, 10'2 1/2" PERF GUN W/ 8.6" BRUSH, B.NOSE. PERF FROM 9,743' SLM TO 9,734' SLM SLICKLINE STEP COMPLETE. 12/17/2018 ***COIL IN CONTROL OF WELL, STANDBY ON EDGE OF PAD FOR ASSIST*** Daily Report of Well Operations 02-02A CTU 9 1.75" Blue Coil Objective: P&A Rig coil back up. Make up and RIH with EV video 2.375" shrouded camera. Circulate well over to neat methanol and reciprocate pipe. Tagged TBG stub at 39' CTM and got 9' beside the 5-1/2" TBG. Reciprocate pipe. OOH with camera and no video, due to crude on the lense that was picked up when begining in hole. Makeup same BHA and RIH. Begin circulation prior to RIH. Make camera passes while pumping. POP off to check camera data. Good camera data. Tubing stub appears to be in good condition/not deformed. observed severed control line as well. MU/RIH with mimicked SL drift (see log for details) able to enter tubing stub first time with no issues. Circulate well to 9.8ppg brine. Pump 37 bbl cement job. ***DRIFT BHA THAT MADE IT INTO 5.5" TBG STUB`**: ctc 3" x 0.93'+TJ disco 3.12"x 2.28'(7/8"ball) +DACS w/no burst (3/4"ball)+ xover reg to 1.5MT 3.08"x 0.73'+ sealed KJ 2.13"x 0.83'+ wt bar 2.10"x 4.33'+ xover reg to .75 SR 2"x 0.66'+slickline 15deg KJ 1.85"x 0.75'+ wt bar 1.87"x 2'+ braided line brush (8.68"length wire) 1.875"x 2.1'+bull nose 1.5"x 0.3' OAL: 15.96' 12/18/2018 ****Job Continued on 12/19/18`** 12/18/2018 ***SWCP 4516 SLICKLINE UNIT COIL ASSIST*** (plug and abandonment-reservoir TWO = SSV/29/Vac. Temp = SI. WHP's. (Pre-P & A). IA wireless gauge is showing Failure (no light blinking on gauge, suspect dead batt). OA gauge showing -4/ -1.3 (Vac), DHD calibrated gauge reading -1. 12/19/2018 SV, WV, MV, SSV = C. IA, OA = OTG. 19:55 12/19/2018 *"SWCP 4516 SLICKLINE UNIT COIL ASSIST*** (plug and abandonment-reservoir CTU 9 1.75" Blue Coil Objective: P&A Continue laiyng in cement. Lay in 37bbl of cement with no losses. Estimated TOC 9217'. Reverse circulate with 9.8ppg brine starting at 9000'. Return density in reverse circulation never got above 10ppg. POOH. Freeze protect tree and well down to 56' CTM (tubing stub) with 60/40. While popping off the well it was noticed that some crude (-1-2 pints) had leaked out of the THA flange during the cement job. Valve shop notified. FP coil, roll tanks to 60/40. 12/19/2018 ***Job Complete*** T/I/O = SSV/30/Vac. Temp = SI. Casing Measurements (P&A). No wellhouse or flowline. Video of parted casing taken. Removed -2' of fluid to expose lower half of the parted casing. Video and measurements taken from -5 o'clock position. 17' 1" to the upper part of the parted casing. 21' to the lower part of the parted casing. Distance between parted casing = 3' 1 V. Measurements taken from the top of the clamshell clamp that connects the THA to the IA spool (slickline zero measurement). IA wireless gauge replaced. No leaks around the THA adapter found using a gas meter, snoop or by listening, (shut down equipment on location to decrease background noise). 12/20/2018 SV, WV, SSV, MV = C. IA, OA = OTG. 15:00 T/I/O = SSV/0/0. Tightened THAxMV with modified Hammer wrenches. Achieved 1/12 of a turn on 3 and 9 o'clock positions, could not adequatly reach or tighten 12 and 6 o'clock 12/21/2018 positions without scaffold modifications. VSC notified of suggested modifications. T/I/O = SSV/5/Vac. Temp = SI. WHPs (P&A). No well house and flow line. IAP decreased 5 psi during the day. Verified IA Wireless gauge is working correctly. 12/21/2018 SV, WV, SSV, MV = C. IA, OA = OTG. 19:30 12/21/2018 T/1/0=0/0/0 Torqued THA x Master valve flange to specs. FWP's 0/0/0 see log for details. Daily Report of Well Operations 02-02A TWO = SSV/10/Vac. Temp = SI. WHPs (P&A). No well house and flow line. IAP decreased 20 psi overnight. Verified IA Wireless gauge is working correctly. 12/21/2018 SV, WV, SSV, MV = C. IA, OA = OTG. 13:30 T/1/0=10/12/vac (LRS Unit 76 - CMIT-TxIA) CMIT TxIA PASSED to 1588/1605 psi. 1650 MAX, 1500 target. Pumped 5 bbls 60/40 down IA to reach test pressure Loss of 27/28 PSI 1st 15 min, Loss of 12/12 psi 2nd 15 min. ***No Visible Leaks on Tubing Head Adaptor. Notice Tree grew -0.25" *** 12/22/2018 FWHP=10/10/0 SV/WV,SSV shut MV,IA,OA Open. T/I/O = SSV/10/Vac. Temp = SI. WHP's. (Pre -P&A). No change in WHP's overnight. Wireless gauge for IA reading 7 psi (3 psi difference), wireless OAP gauge reading same as DHD calibrated gauge. 12/22/2018 SV, WV, MV, SSV = C. IA, OA = OTG. 19:50 TWO = 0/0/0. Temp = SI. WHPs (P&A). No well house and flow line, temporary scaffolding 12/23/2018 installed on well. SL on Well in control of well upon departure. 16:00 ***WELL S/I ON ARRIVAL*** (Plug & abandon) TAG TOC AT 9,227' SLM W/ 2.50" x 11' DUMMY GUN, 5-1/2" BRUSH State witnessed by Lou Laubenstein). LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 1612 PSI (State witnessed by Lou Laubenstein). 12/23/2018 ***JOB IN PROGRESS, CONTINUED ON 12/24/18 WSR*** T/1/0=0/0/0. Tree change out. Replaced 5x7 FMC with new 5x7 FMC tree. Little Red to do 12/23/2018 MIT test on tree. Job Complete see log. Final WHP's 0/0/0. T/1/0=0/0/0 (LRS Unit 76 - CMIT-TxIA Post Tree Change Out) CMIT TxIA PASSED to 1585/1605 PSI. 1650 Max, 1500 Target. Pumped 3.8 bbls 60/40 down IAto reach test pressure Loss of 31/31 psi 1st 15 min, Loss of 11/12 psi 2nd 15 min. SV,WV,SSV shut MV,IA,OA Open 12/23/2018 FWHP=0/0/0 T/1/0=vac/vac/vac (LRS Unit 46 -Assist Slickline: AOGCC CMIT-TxIA) AOGCC CMIT-TxIA PASSED to 1612/1615 psi Max Applied Pressure= 1650 psi Target Pressure= 1500 Psi. Pressured TxIA to 1643/1646 psi with 2.9 bbls of 60140 M x A lost 21/21 psi in the first 15 min and 10/10 psi in the 2nd 15 min for a total of 31131 psi during 30 min test. 12/23/2018 *** WSR continued on 12/24/18 *** ***CONTINUED FROM 12/23/18 WSR*** (Plug & abandon) DRIFT TO 100' SLM W/ 2.50" x 11' DUMMY GUN, 5-1/2" BRUSH (4 x 8.60" Bristles). MADE FIVE PASSES FROM 0' SLM TO 100' SLM (No issues entering 5-1/2" tbg stub). 12/24/2018 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** ***JOB STARTED ON 24 -DECEMBER -2018*** (SLB ELINE: ADPERF) WELL SHUT IN ON DEPARTURE. INITIAL TWO = 50/0/0. RU. PT TO 3100 PSI. RIH W/ 10' POWERFLOW 2506, HMX. 61 SHOT, 6 SPF, 60 DEG PHASED. TOOL SHORTED WHEN SHOOTING ATTEMTED. POOH AND INVESTIGATE. DISCOVERED A SHORT IN THE XO AT JARS. RDMO DUE TO WINDS OVER 30 MPH. CONTINUE JOB AFTER WINDS DIE DOWN. WELL SHUT IN ON DEPARTURE. FINAL TWO = VAC/0/0. 12/24/2018 ***JOB TO BE CONTINUED*** *** WSR continued from 12/23/18 *** (LRS Unit 46 - Assist Slickline: AOGCC CMIT-TxIA) Bled TBG x IA down to starting psi recovering - 2.9 bbls. Rigged down, SSL in control of well upon LRS departure 12/24/2018 Final WHP's 0/0/0. Daily Report of Well Operations 02-02A T/I/O = 0/0/0. Temp = SI. WHPs (P&A). No well house or flow line, temporary scaffolding installed on well. 12/25/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 01-00. T/I/O = 0/0/0. Temp = SI. WHPs (Eval TxIA). No wellhouse or flowline. Temporary scaffolding installed around well. Wireless gauges are reading correctly. 12/26/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 20:30 CTU 9 1.75" Blue Coil Job Objective: P&A Perform weekly BOP test on edge of pad. MIRU on well. 12/26/2018 ***Job in Progress*** ***JOB CONTINUED FROM 24 -DECEMBER -2018*** (SLB ELINE: PERF) WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 0/25/0. RU. PT TO 3050 PSI. RUN 2: PERFORATE 9000'- 9010' W/ 2.5" X 10' POWERFLOW, 6 SPF, 60 DEG PHASED, CCL TO TOP SHOT = 55, CCL STOP DEPTH = 8994.5 RDMO. NOTIFY PAD OP ON DEPARTURE. FINAL T/I/O = 25/75/0. 12/26/2018 ***JOB COMPLETE ON 26 -DECEMBER -2018*"* CTU 9 1.75" Blue Coil ***Continue from 12/26/18*** Job Objective: P&A MIRU. Make up and RIH with braided line brush BHA and make an AOGCC witnessed tag of the top of cement at 9226CTM. PUH and circulate 78bbl of hot freshwater with F103 and UO67, chased by 630 bbls 9.8ppg NaCl. 12/27/2018 *`*Job in Progress*** CTU 9 1.75" Blue Coil ***Continue from 12/27/18*** Job Objective: P&A 12/28/2018 Lay in ***""'***** bbls 15.8 ppg Class G Unislurry cement from 9002' to ******** CTU 9 1.75" Blue Coil ***Continue from 12/27/18*** Job Objective: P&A _ Lay in 469 bbls 15. 9002' to 1996'. TOC in TBG and IA =1996'. TOC based upon 448.4bbl returned. Reverse circulated 9.8ppg NaCl from 1980' and then circulated in 60/40 methanol from 100'. RDMO. 12/28/2018 ***Job Complete*** T/I/O = 0/0/0. Temp = SI. WHPs (Eval TxIA). No wellhouse or flowline. Wireless gauges are reading correctly. 12/29/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. ### T/I/O = O+/Vac/Vac. Temp = SI. WHPs (eval TxIA). Temporary scaffold installed. No well house or flowline. Wireless gauges are reading correctly. 12/30/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 T/I/O = ONac/Vac. Temp = SI. WHPs (eval TxIA). Temporary scaffold installed. No well house or flowline. Unable to access OA to verify pressure with transmitting gauge. TBG/IA Wireless gauges are reading correctly. 12/31/2018 ISV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00. T/I/O = ONac/Vac. Temp = SI. WHPs (Eval TxIA). Temporary scaffold installed. No well house or flowline. Wireless gauges are reading correctly. 1/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:30 T/I/O = VACNAC/VAC. Temp = SI. WHPs (eval TxIA). Wellhouse, flowine, and tree scaffold removed. Temporary scaffold installed. 1/4" SSV hose disconnected from SSV attached to scaffold. Tree gauges reading correctly. 1/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00 Daily Report of Well Operations 02-02A T/1/0=0/0/0 SI Perform CMIT TxIA/SL tag cement (PLUG AND ABANDONMENT - RESERVOIR) CMIT TxIA to 2505/2504 psi ***PASS*** PER ENG REVIEW. Target pressure=2500 psi Max applied=2600 psi Pumped 1.85 bbls 60/40 down IA to achieve test pressure of 2600/2599 psi on TxIA. 15 min loss of 58/58 psi, 30 min loss of 37/37 psi, for total loss of 95/95 psi in 30 mins. Bled back -1.4 bbls. Bled TxIA to 0 psi. See Log for 1/3/2019 Details SL on well upon departure. Tags hung on WV/IA CVs OTG FWHP=0/0/0 ****WELL 5/1 ON ARRIVAL**** (Post Coil P&A) RAN 9-5/8" BRUSH & & 2-1/2" SAMPLE BAILER, TAG TOC @ 2362' SLM (recovered 3 cups wet cement) LRS PERFORMED CMIT-TxIA TO 2346psi RE TAGGED TOC W/ 9-5/8" BRUSH & & 2-1/2" SAMPLE BAILER @ 2362' SLM (No change indepth) LRS MADE 4 ATTEMPTS TO GET PASSING CMIT-TxIA TO 2500psi (Inconclusive) 1/3/2019 ****WELL S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS**** TWO = 75/8/VAC. Temp = SI. WHPs (eval TxIA). No AL. Wellhouse, flowline, scaffold removed. Integral installed on IA =inspection current. Wireless gauges reading correctly. 1/4/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 TWO = 56/15/0. Temp = SI. WHPs (eval TxIA). No AL, Wellhouse, flowline, & tree scaffold removed. Temp scaffolding is installed. TP decreased 19 psi, IAP increased 7 psi, & OAP unchanged, since 1/4/2019. Integral installed on IA. Wireless gauges reading correctly. 1/7/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 TWO = 49/23/0. Temp = SI. WHPs (eval TxIA). No AL, Wellhouse, flowline, & tree scaffold removed. Temp scaffolding is installed. TP decreased 7 psi, IAP increased 8 psi, & OAP unchanged, since 1/07/19. Integral installed on IA. Wireless gauges reading correctly. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 1/11/2019 T/l/O = 42/37/0. Temp = SI. WHP's. (Eval T x IA). No AL. Wellhouse, flowline & scaffold are removed. Temp scaffold installed. TP decreased 7 psi, IAP increased 14 psi, no change in OAP in 3 days. OPS gauges reading 36/Vac/0. Wireless TBG & IA gauges not matching DHD calibrated gauges, OPS going to call to get gauges checked out. SV, WV, SSV = C. MV = O. IA, OA= OTG. 10:30 1/14/2019 TWO = 42/37/0. Temp = SI. WHPs. (Eva[ T x IA). No AL. Wellhouse, flowline & scaffold are removed. Temp scaffold installed. TP decreased 7 psi, IAP increased 14 psi, no change in OAP in 3 days. OPS gauges reading 36/Vac/0. Wireless TBG & IA gauges not matching DHD calibrated gauges, OPS going to call to get gauges checked out. 1/17/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 T/1/0=0/0/0. Set FMC 5" ISA/BPV #537 with CIW lubricator #839. @ 145".Set good..***JOB 1/21/2019 IN PROGRESS*** see log for details. Final WHP's=BPVO/O T/I/O = 0/0/0. Temp = SI. WHPs (eval TxIA). Wellhouse, flowline, and scaffold removed. Temporary scaffold installed. Dryhole tree installed w/ ASV. Gauges reading correctly. WHPs unchanged after API tree c/o overnight. 1/22/2019 ASV, SV, MV = C. IA, OA = OTG. 15:00 T/I/O=BPV/0/0 R/D production tree, R/U Dryhole tree with ASV #11. Pulled BPV #537 1/23/2019 throw h tree. FWP's 0/0/0 see log for details. —Temp= T/I/O = 0/0/0. Sl. WHPs (eval TxIA). Wellhouse, flowline, and scaffold removed. Gauges reading correctly. WHPs unchanged overnight. 1/24/2019 ASV, SV, MV = C. IA, OA = OTG. 22:30 TWO = 0/0/0. Temp = SI. WHPs (eval TxIA). Wellhouse, flowline, and scaffold removed. Gauges reading correctly. WHPs unchanged since 1/24/19. 1/29/2019 ASV, SV, MV = C. IA, OA = OTG. 04:00 Daily Report of Well Operations 02-02A ***WELL S/I ON ARRIVAL*** (P&A) RIG UP HES RELAY UNIT 046 1/29/2019 ***CONT. ON 01/30/2019 WSR*** ***JOB CONTINUED FROM 29-JAN-2019*** (P&A) HES RELAY UNIT #46 RUN 1: LOG 40 ARM PDS CALIPER FROM 2352' SLM (top of cmt) TO SURFACE (good data). RUN 2: PUNCH TBG FROM 1300'- 1310' MD W/ 2-7/8" MAXFORCE HMX 60 DEG PHASE 6 SPF GUN. 1/30/2019 ***JOB COMPLETE ON 30-JAN-2019*** T/I/O/OO= SSV/0/0/0. (LRS Unit 72 - Assist Special Projects: Attempt to Circ Out Arctic Pack) Pumped 21.5 bbls of 180* F diesel into the OA. Reached max applied pressure of 1200 psi with no OOA returns to surface. Pumped 170 bbls of 180* F diesel into the IA while taking OA returns to tank. Returned 165 bbls. Returns were 125 bbls of clean brine up to 60 *F. and 40 bbls of brine and diesel mix up to 72 *F. Pumped 30 bbls of diesel into the OA. Ramped up to 5 bpm at 930 psi with no returns from OOA. Appears to be leaking into formation. Pressure fell back upon shut down. Can still see snow/ice in conductor. SSV closed. MV open. IA/OA/ODA OTG DSO notified of well 2/8/2019 status. T/I/O/OO= SSV/0/0/0. (LRS Unit 72 Assist Special Projects: Attempt to Circ Out Arctic Pack) Pumped 5 bbls of 60/40 Meoh and 427 bbls of 200* F. Fresh Water into the OA while taking 2/9/2019 returns from the IA to a surface tank. ***Job Cont to 02-10-2019 WSR*** ***Job Cont from 02-09-2019 WSR*** (LRS Unit 72, Assist Special Projects: Attempt to Circ Out Arctic Pack) Warming well to circ out Arctic Pack. Pumped 371 bbls (799 bbls total) 200* FW down OA into IA with returns to open top tank. Return volume slowly degraded to 5 bbls for every 25 bbls pumped. Stopped pumping when fluid started to rise up the conductor (water). Freeze protected IA valve and return line with 7 bbls of 60/40 Meoh. Pumped 28 bbls of FW down the OA while taking 4 bbls of OOA returns (water) to the conductor. Fluid loss is too large to displace the OOA to surface. Decide to FP well and plan LCM treatment. Freeze protected the OA to 1300' with 80 bbls of 180* F diesel. Taking any returns up 20" to conductor. Pressure increasing from 490 to 1100 psi (losses to formation healing) Little increase in rate of returns as pressure increased. Only clear water returns. 85 bbls diesel away. Continue trying to squeeze hot diesel into OOA by pumping 2 bbls of warm diesel at max allowable pressure. OOA returns rate falling after 2 hours. Warm the OOA back up by pumping 130 bbls of 180* F diesel into the OA while taking IA returns to open top tank. Pump 157 bbls 180* DSL down OA to try and pressure up on ODA. Shut in OA returns, line up to TBG/IA, Bull head freeze protect Tbg/IA with 115 bbls 180* DSL. Injectiivity still @ 1.2 bpm @ -400 psi DHD and Vac truck staying on location to monitor/recover ODA returns. Total losses to the formation 615 bbls since starting to pupm 2/8/19 Wellhead moved upward 5" since starting to warm the well @ 14:30 2/9/18. Landing ring 2/10/2019 46.5" above seat T/I/O = SSV/220/210/0. Temp = SI. Assist/Monitor Vac truck w/ inflow to conductor. 2/11/2019 Continued on WSR 2-12-19. Daily Report of Well Operations 02-02A ***WSR continued from 02/11/19*** TWO = SSV/OTG/OTG/OTG. Temp = SI. Assist/Monitor Vac truck w/ inflow to conductor. 126 total bbls returned today, 512 total bbls returned from well. Fluid samples obtained @ 1800 (90% water, 10 % diesel/non-freezable emulsion) and 2359 (45% water, 55% diesel/non-freezable emulsion). 2/12/2019 ***WSR continued on 02/13/19*** T/I/O/00= SSV/0/0/0. LRS unit 72 Assist Special Projects: Circ -out Arctic Pack. (PLUG AND ABANDONMENT) Heat UR #077 (brine) and #087 (surfactant) to 160* F. Circ out well down OA up IA/Tbg to tanks. Pumped 152 bbls surfactant and 316 bbls 9.8 NaCl brine w/ -55% losses. Pumped 468 bbls total/ 210 bbls returns/ 258 bbls losses. 4 to 7 bpm @ 350 psi average pump pressure. No increase in rate of returns while pumping. OOA return rate remained @ 4 - 5 bbls/hr. Pump 1 bbls 60/40 into Tbg/IA to FP surface. SI returns and pump 272 bbls of brine down OA while monitoring returns up OOA. Return rate from OOA increased to 10 bbls per hour while bullheading. T/1/0/00= SSV/0/115/98 Total losses to formation 265 while circulation + 272 bbls bullheading = 537 bbls. Plus 615 2/13/2019 bbls lost prviously = total losses 1152 bbls ***WSR continued from 02/12/19*** T/I/0 = SSV/OTG/OTG/OTG. Temp = SI. Assist/Monitor Vac truck w/ inflow to conductor. 2/13/2019 Continued on WSR 2-14-19. Continued from WSR 2-13-19. TWO = SSV/OTG/OTG/OTG. Temp = Sl. Assist/Monitor Vac truck w/ inflow to conductor. 71 bbls returned @ midnight over last 24 hrs 3 bbls/hr. Fluid samples taken @ 11:00 (fairly clear water with small amount of emulsions) and 17:00 (dark gray fluid that appears to be water mixed with arctic pac). 2/14/2019 Total losses since 2/8/19 1152 bbls. Total recovered 741 bbls Job Scope: Monitor OOA returns to vac truck 00:001 - 12:00 hrs Recovered 36 bbls. 3 bbls/hr 12:00 - 2359 recovered 33 bbls 2.75 bbls/hr Total losses since 2/8/19 1152 bbls. Total recovered 810 bbls 2/15/2019 T/1/0/00 = SSV/30/40/0. Temp = Sl. Monitor conductor inflow. No Flowline or wellhouse Temporary saffolding installed. Kelly hoses & hardline off of the TBG, IA & OA to a choke trailer & tanks. See cellar returns in Special Projects AWGRS report. 2/16/2019 SSV, upper master = SI. Lower master = O. IA, OA, OOA = OTG. 14:00 Job Scope: Track OOA returns to vac truck 00:001 - 12:00 hrs Recovered 33 bbls. 2.75 bbls/hr 12:00 - 2359 recovered 36 bbls 3 bbls/hr Total losses since 2/8/19 1152 bbls. Total recovered 879 bbls 2/16/2019 Job Scope: Track OOA returns to vac truck 00:001 - 12:00 hrs Recovered 33 bbls. 3 bbls/hr 12:00 - 2359 Recovered 33 bbls 3 bbls/hr 2/17/2019 Total losses since 2/8/19 1152 bbls. Total recovered 945 bbls T/1/0/00 = 18/18/21/0. Temp = SI. Monitor conductor inflow. No wellhouse or flowline. Temporary scaffolding installed. LRS finishing pumping on arrival, WHPs taken from LRS transducers. Special Projects to report on volumes returned. LRS in control of all wellhead valves. 12:30 2/1 712 01 9 Daily Report of Well Operations 02-02A T/I/O/00= 0/0/0/0. LRS unit 72: Verify 9.8# Brine in the IA and OA. (PLUG AND ABANDONMENT) Pumped 30 bbls of 160* F 9.8# Brine into the OA while taking IA returns to the OT tank. Got back 27 bbls of returns (gained 6" in the tank while pumping brine). Took samples of fluid pumped and fluid returned. Lab verified both samples as 9.8# Brine. Freeze protected the IA and OA with 1 bbis of diesel in each. Freeze protected the surface equipment with 3 bbls of 60/40 Meoh. Final T/1/0/00=114/114/117/0. SSV, SV, WV closed. MV open. IA/OA/OOA OTG. Open top tank has —60 bbis in it. UR tank 4471 has 45 bbis of 2/17/2019 34* F Brine left in it. DSO notified of well status upon departure. Job Scope: Track OOA returns to vac truck 00:001 - 12:00 hrs Recovered 43 bbls. 3.6 bbls/hr 12:00 - 2359 Recovered 44 bbls 3.7 bbls/hr 2/18/2019 Total losses since 2/8/19 1152 bbls. Total recovered 1032 bbls Job Scope: Track OOA returns to vac truck 00:001 - 12:00 hrs Recovered 40 bbls. 3.3 bbls/hr 12:00 - 2359 Recovered 41 bbls 3.4 bbls/hr 2/19/2019 Total losses since 2/8/19 1152 bbis. Total recovered 1113 bbls Job Scope: Track OOA returns to vac truck 00:001 - 12:00 hrs Recovered 44 bbls. 3.3 bbls/hr 12:00 - 2359 hrs Recovered 32 bbls. 2.67 bbls/hr 2/20/2019 Total losses since 2/8/19 1152 bbls. Total recovered 1185 bbls Job Scope: Track OOA returns to vac truck Took sample from OOA (1000 ml) dropped at MI for fluids composition testing. 00:001 - 12:00 hrs Recovered 32 bbls. 2.667 bbls/hr 12:00 - 23:59 hrs Recovered 40 bbls 3.33 bbls/hr Total losses since 2/8/19 1152 bbls. Total recovered 1257 bbls 2/21/2019 Job Scope: Track OOA returns to vac truck. Sample #2 taken from OOA (1000 ml) composition testing results. Weight 8.34ppg Cl- 1500 mgl/I brackish Ca++ 400 mg/I Retort: Solids tr Oil 1% Water 99 % Conclusion: sample of water 00:001 - 12:00 hrs Recovered 40 bbls. 3.33 bbl/hr 12:00 - 23:59 hrs Recovered 44 bbls 3.67 bbl/hr 2/22/2019 lTotal losses during pumping ops on 2/8/2019 1152 bbls. Total recovered 1341 bbls Job Scope: Track OOA returns to vac truck 00:001 - 12:00 hrs Recovered 36 bbls. 3.0 bbls/hr 12:00 - 2359 hrs Recovered 35 bbls. 2.9 bbls/hr 2/23/2019 Total losses since 2/8/19 1152 bbls. Total recovered 1412 bbls Job Scope: Track OOA returns to vac truck Took sample from OOA (1000 ml) dropped at MI for fluids composition testing. 00:001 - 12:00 hrs Recovered 38 bbls. 3.18 bbls/hr 12:00 - 2359 hrs Recovered 37 bbls. 3.08 bbls/hr 2/24/2019 jTotal losses since 2/8/19 1152 bbls. Total recovered 1491 bbls Daily Report of Well Operations 02-02A Job Scope: Track OOA returns to vac truck Took sample from ODA (1000 ml) dropped at MI for fluids composition testing. 00:001 - 12:00 hrs Recovered 37 bbls. 3.08 bbls/hr 12:00 - 2359 hrs Recovered 35 bbls. 2.916 bbls/hr 2/25/2019 Total losses since 2/8/19 1152 bbls. Total recovered 1563 bbls Job Scope: Track OOA returns to vac truck. Sample #3 taken from OOA (1000 ml) composition testing results. Weight 8.34 ppg Cl —1200 mg/I Ca++ 440 Solids 2 % Oil tr Water 98% Analysis indicates : Brackish water. 00:001 hrs - 12:00 hrs Recovered 36 bbls. 3 bbl/hr 12:00 hrs - 18:00 hrs Recovered 18 bbls 3 bbl/hr Decision to let it go all night to see if it will level off. 2/26/2019 Total losses during pumping ops on 2/8/2019 1152 bbls. Total recovered 1466 bbls Job Scope: Track OOA returns to vac truck. Decision to let it go all night to see if it will level off. Continued watching throughout day shift. Fluid level rose 6 inches in 12 hours. Released vac unit with fluid level at 8'4" Continue monitors with DHD once a shift, every 12 hrs 2/27/2019 T/I/O = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL 2/28/2019 (WIE Req). 7' 11" from top of conductor to top of fluid @ the 6:00 o'clock position. 05:00 TWO = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). Fluid level unchanged, 7' 11" from top of conductor to top of fluid @ the 6:00 o'clock position. Fluid in conductor is starting to ice over. 16:30 2/28/2019 TWO = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL 3/1/2019 (WIE Re ). 7' 11" from top of conductor to top of fluid @ the 6:00 o'clock position. 08:30 T/I/O = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). Fluid level rose 3" overnight. 7'8" from top of conductor to top of fluid @ the 3/1/2019 6:00 o'clock position. Fluid in conductor is iced over. 02:30 TWO = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). T6" from top of conductor to top of fluid @ the 6:00 o'clock position. Fluid in 3/2/2019 conductor is iced over. 16:30 T/I/O = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). Fluid level unchanged since 4 AM, T6" from top of conductor to top of fluid @ the 6:00 o'clock position. Fluid in conductor is iced over. 04:00 3/2/2019 T/I/O = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). Fluid level rose 2" overnight. 7'6" from top of conductor to top of fluid @ the 3/2/2019 6:00 o'clock position. Fluid in conductor is iced over. 04:00 TWO = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). Fluid level rose 1" overnight. T7" from top of conductor to top of fluid @ the 3/3/2019 6:00 o'clock position. Fluid in conductor is iced over. 05:00 Daily Report of Well Operations 02-02A TWO = 0/vac/8 Strap Conductor FL (WIE Req). Scaffolding signed off. Fluid level unchanged. TT' from top edge of conductor. Fluid in conductor slushed over. Dryhole tree installed with ASV. ASV, Upper Master & Lower Master = C. IA, OA = OTG, 3/3/2019 13:30. TWO = 0/vac/8 Strap Conductor FL (WIE Req). Scaffolding signed off. WHPs & Fluid level unchanged. 7' 7" from top edge of conductor. Fluid in conductor slushed over. Dryhole tree installed with ASV. ASV, Upper Master & Lower Master = C. IA, OA = OTG, 3/4/2019 12:30. TWO = Vac/0/4 Strap Conductor FL (WIE Req). Harness required to obtain IA/OA pressures until top rail on scaffolding is replaced.. 7'7" from top edge of conductor to ice in conductor. Dryhole tree installed with ASV. ASV, Upper Master= C. Lower Master = O. IA, OA = 3/4/2019 OTG, 16:30. TWO = Unable to get WHP's due to Scaffold out of inspection. TY from top of ice in conductor to top lip of conductor. Fluid in conductor is frozen. 04:20 3/5/2019 TWO = Vac/O/3. Strap Conductor FL (WIE Req). TY from top of ice in conductor to top lip of conductor in the 12 o'clock position. Dryhole tree installed with ASV. ASV, Upper Master = C. Lower Master = O. IA, OA = 3/5/2019 OTG. 16:00 TWO = Unable to get WHP's due to Scaffold out of inspection. T5" from top of ice in 3/6/2019 conductor to top lip of conductor. No change overnight. Fluid in conductor is frozen. 04:30 TWO = Unable to obtain WHPs due to scaffolding needing inspection. Strap Conductor FL (WIE Req). 7'5" from top of conductor to top of fluid @ the 6:00 o'clock position. Fluid in 3/6/2019 conductor is iced over. 20:00 T/1/0/00 = Vac /0/0/0. Strap Conductor FL (WIE Req). Top rail deficiency on IA/OA platform has been corrected and no harness is needed for Tbg/IA/OA pressure reads. T5" from top edge of conductor to ice in conductor. Dryhole tree installed with ASV. ASV, Upper Master = C. Lower Master = O. IA, OA = 3/7/2019 OTG, 16:00. T/I/O/00 = Vac/Vac/Vac//0. WHPs (WIE Req). Hardline circ out rigged upon tree. 7,5" from top edge of conductor to ice in conductor @ the 6:00 O'clock position Dryhole tree installed with ASV. ASV, Upper Master = C. Lower Master = O. IA, OA = 3/8/2019 OTG, 21:00. Temp=S/I (LRS Unit 70 - Weekly OOA Thaw) Spotted Unit, Rigged Up, and Pressure Test 3/8/2019 Surface lines. ***Continued on 03-09-19 WSR*** T/I/O = Unable to get WHP's due to hardline circ rig up on well, LRS on location to pump. 7' 5" from top of ice in conductor to top lip of conductor. No change overnight. Fluid in 3/8/2019 conductor is frozen. 14:30. T/1/0/00 = O/Vac/Vac/0. Temp = SI. WHPs (WIE request). No AL, flow line or well house. Dryhole tree installed with ASV. OAjewelry appears to not be frozen at this time. 3/9/2019 ASV, Upper Master = C. Lower Master = O. IA, OA, OOA = OTG, 20:00. ***Continued from 03-08-19 WSR*** T/1/0/00=0/0/0/0 (LRS Unit 70 - Weekly OOA Thaw) HOT OA w/ 100 bbls of 200* 9.8 ppg NaCL down OA taking returns out the TBG/IA to open top tank. Got back 1/1 returns, No noticeable gain in conductor. Pumped 5 bbls 60/40 down OA and U-tube over to IA for freeze protect. Pumped 3 bbls 60/40 to freeze protect surface lines to OT tank. ASV, Upper Master= C. Lower Master= O. IA OA OOA= OTG. 3/9/2019 Final whp's= 8/8/8/0 Daily Report of Well Operations 02-02A T/I/O/00 = VacNac/Vac/Vac. Temp = SI. WHPs. (WIE request). No change in WHP's overnight. Dry hole tree. 3/10/2019 SV, SSV = C. MV = O. IA, OA, ODA = OTG. 21:46 T/1/0=0/0/0/0 Temp=Sl (LRS Unit 70 - Weekly ODA Thaw) Spear into OA with 2 bbls 60/40 and HOT OA w/ 100 bbls of 200* 9.8 ppg NaCL down OA taking returns out the TBG/IA to open top tank. Got back 1/1 returns, No noticeable gain in conductor. Pumped 5 bbls neat meth down OA and U-tube over to IA for freeze protect. Pumped 3 bbls neat meth to freeze protect surface lines to OT tank. ASV, Upper Master= C. Lower Master= O. IA OA OOA= OTG. 3/16/2019 Final whp's= 0/0/0/0 T/l/O/00 = VacNac/Vac/0. Temp = SI. WHPs (WIE Req). Dry hole tree (w/ ASV) and temporary scaffold installed. No well house or flowline. Fluid is 75" from top of conductor. TP, IAP & OAP unchanged, OOAP increased from Vac to 0 psi since 03/10/19. 3/17/2019 ASV, SV = C. MV = O. IA, OA, ODA = OTG. 16:30 T/I/O/00 = Vac/Vac/0/0. Temp = SI. WHPs (WIE request). Dry hole tree w/ ASV. Temporary scaffolding installed. No wellhouse or flowline. 3/23/2019 ASV, SV = C. MV = O. IA, OA, ODA = OTG. 21:10 T/I/O/00=-4/-4/-15/1 (Circ hot brine) Pumped 3 bbls 60/40 meth spear down OA w/returns up IA, followed by 107 bbls Brine. Pumped 5 bbls 60/40 for FP. U tube OA and IA for 30 mins. Pumped 3 bbls 60/40 thru choke skid to FP surface line. Total fluids pumped = 115 bbls, the return tanks indicators read 110 bbls returned, potential fluid losses may be due to voids in well strings due to being on a vac, and strap markings in open top are vage. 3/25/2019 FWHP's= -7/-7/-10/2 Well shut in upon departure. T/I/O/00 = VACNACNAC/0. Temp = SI. WHPs (WIE Request). No wellhouse, AL or flowline. Temporary scaffolding installed. Hardline rigged up for circ -out. 3/30/2019 ASV, SV, MV = C. IA, OA, ODA = OTG. 23:00 T/l/O/00= 0/0/0/0. Temp= SI. (LRS Unit 42 - Weekly OOA Thaw) HOT ODA w/ 3 bbls 60/40 meth followed by 104 bbls of 200* F 9.8 brine down OA taking returns out the IA to OT tank. Obtain 1 to 1 returns with no visible gains in conductors. Freeze Protect w/ 5 bbls 60/40 meth into OA and U -tubed into IA for 30 mins. Freeze protected surface lines to OT tank with 3 bbls 60/40 meth. ASV, Upper Maste-C. Lower Master= O. IA OA OOA= OTG. 4/2/2019 FWHP's= 0/0/0/0 T/I/O/00 = VACNACNACNAC. Temp = SI. WHPs (WIE Req). No wellhouse, AL, or flowline. Temporary scaffold installed. Hardline rigged up for circ -out. 4/6/2019 ASV, SV, MV = C. IA, OA, ODA = OTG. 16:35 T/1/0/00=0/0/0/0 LRS unit 70 circ brine HOT (PLUG AND ABANDONMENT) Pumped 2 bbls of 60/40 meth followed by 106 bbls of 200* 9.8 brine down OA taking returns up IA to OTT.Obtain 1 to 1 return's with no visible gain in conductor. Freeze protect, pumped 5 bbls 60/40 down OA and U -tubed into IA for 40 mins. freeze protected surface lines W/3 bbls 60/40 meth. 4/10/2019 ASV, Upper Master= C. Lower Master= O. IA OA OOA= OTG. Final WHP's=12/12/0/0 T/I/O/00 = VACNACNACNAC. Temp = SI. WHPs (WIE Req). No wellhouse, AL, or flowline. Temporary scaffold installed. Hardline rigged up for circ -out. TP decreased 12 psi , IAP decreased 12 psi, OA unchanged, ODA unchanged since 4/10/19. 4/15/2019 ASV, SV, MV = C. IA, OA, ODA = OTG. 01:15 T/1/0= 0/0/-5/0. (Weekly brine circ -out). Pumped 3 bbls 60/40 down OA w/returns up IA, followed by 100 bbls 200* 9.8 brine, with a 1 for 1 return to flowback tank. Pumped 5 bbls 60/40 down OA and U -tubed FP into IA for 1 hour., Pumped 1 bbl 60/40 to FP surface lines. 4/20/2019 FWHP's 8/8/-3/0. Well shut in upon departure. 4/23/2019 IASV,unch SV, MVo C4/15 19. Well OOA was ed out 0 n 4/20/19.up)foNcirc-olut� WHp'S or TRS= FMC DRY HOLE TREE Max Angle = 98' @ 11858' Datum M)= 11148' WELL -FAD MCLVOY BAKERC 02.02A SPF ACTUATOR= BTWJMD TBG PUNUAM(01Ki0/19) OKB. ELEV = 64' 2" 6 BF. ELEV C 30' GOND 114' KOP= 3000' 11210 - 11235 Iwmm.rU= eow� 20" CSG, 94#/1339, "O/K-55, ID= 19.124• 14W 13-318• CSG, 72#, N-00, D = 12.347" 2681 5-1/2• TBG & 9-5/9' CSG PUNCH, 9000' -9010' 2.5' ROWER FLOW GUN (1226/18) 5-12' TBG & 9-5/8" CSG PUNCH, 9734' - 9744' SL 2.5' POWER FLOW GUN (12117/18) Minimum ID = 2.375" @ 10734' 3-1116" It 2-7/8" XO 5-12.7BG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9918' TOP OF 4-12• TBG -PC 9918' STOP OF 3-1/7 LNR — 9982' 3-12" LNR, 9.2#, L-80 FL4S, .0087 bpf, D = 2.992' 10012' TOP OF 3-3/16- LNR 10012' 4-12' TBGPC,12.6#, "0_01 bpf, D = 3.958' 10014' a -WB- CSG, 40#, 43.5#, 47#, SOO-95, D = 8.681' 1-� 10608' PERFORATION S(NMARY Max Angle = 98' @ 11858' Datum M)= 11148' TBG PUNCH (01/30/79) 1300'-1311 SIZE Iwmm.rU= eow� 20" CSG, 94#/1339, "O/K-55, ID= 19.124• 14W 13-318• CSG, 72#, N-00, D = 12.347" 2681 5-1/2• TBG & 9-5/9' CSG PUNCH, 9000' -9010' 2.5' ROWER FLOW GUN (1226/18) 5-12' TBG & 9-5/8" CSG PUNCH, 9734' - 9744' SL 2.5' POWER FLOW GUN (12117/18) Minimum ID = 2.375" @ 10734' 3-1116" It 2-7/8" XO 5-12.7BG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9918' TOP OF 4-12• TBG -PC 9918' STOP OF 3-1/7 LNR — 9982' 3-12" LNR, 9.2#, L-80 FL4S, .0087 bpf, D = 2.992' 10012' TOP OF 3-3/16- LNR 10012' 4-12' TBGPC,12.6#, "0_01 bpf, D = 3.958' 10014' a -WB- CSG, 40#, 43.5#, 47#, SOO-95, D = 8.681' 1-� 10608' PERFORATION S(NMARY Fill LOG: MWD ON 01131/98 ANGLE AT TOP PERF. 71-@1104(Y Note: Refer to production DA for historical pert data SIZE SPF I INTERVALOpNSgz BTWJMD TBG PUNUAM(01Ki0/19) SEDT SQZ 2" 6 11040- 11090 C 0525/03 2' 6 11210 - 11235 C 1027102 2" 6 11325 - 11350 C 1027/02 1-11/16" 4 11492-11630 C 02/04/98 1-11/16" 4 11700-11820 C 02/04/98 1-11/16" 4 12225-12275 C 02/04/98 3-3/16' LNR, 6.2#, L .0099 bpf, D = 2.75' I TOP OF 2-7/8" LNR I 2-7/8" LNR. SAFETY NOTES: WELLANGLE> 70' @ 10892' parm: Pawed LIU�"`q®'��rM� 21975-12. OT73 ROM SSSV NP, D=4.56: 362' - 9002' H TBG & CSG CMr LAD N FROM PUNCFES (7228178) SL TAGGED TOC (01103119) —9217' 5-1/2'TBG TOC (12/79/18) —9217' 9-5/8'CSG TOC (12/19178) '6T SLM 3-318'BKR BP(12/18/18) 9776' 5-12" 0715 SLDNG SLV, D = 4.562' 5877 5-12' BOT PBR ASSY B806' 9-518" x 5-12' BAKBR SAB PKR 9918' 8-72' X4-12' XO, D = 3.958' 9978' 3-12"BAKER SETTING SLV, D=3.00 88� 4-12'BAKERRNP, ID=3.759' 0012' 0014' 4-12" TUBING TAL (BF}f�D Cr LNR) 0024' FiM1D TT LOGG®01/17/89 0090' TOP OF CBu113Yr 9-5/8' MLLOUT WINDOW 10606'- 70612' 10734' 3-3/18' X 2-7/8' XO. D= 2 3 1 10734' I .00579 bpf. MTE F2E1/ BY COR M39S DATE REV BY COMMENTS 02(07)95 07/25/17 LAST WORKOVER 01/07/19JL/JMD RIW® JMD ADD30'COND 0123/19 SL TAGGTOTOC(01/03119) KWJM RRODTREE00 TO DRY FDLE TREE 1220/18 JTCJJND P&A STAGE I (SL & OOL) 102IM19 12/27/18 NXW/J PUNQED TBG & CSG (1226/18) BTWJMD TBG PUNUAM(01Ki0/19) 1227/18 KP/JMO TREE C/O 12/31/18 JTWJND LAD N CMr FROM TBG PU4()FES 11660' CF3P 12306'—[60VLS LYNCH FLOAT SHOE Fitt DHOE BAY (Hr WELL: 02-02A PERMT No: 91971680 API No: 50-029-20074-01 T11 K R14E, 827' FTL & 1728' BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-02A Permit to Drill Number: 197-168 Sundry Number: 318-585 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of January, 2019. RBDM�,AN 09 1019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations. shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approv P gram E? Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory 11 Development 0 5. Permit to Drill Number: 197-168 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 13 6. API Number: 50-029-20074-01-00 7. If perforating: & Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 02-02A 9. Property Designation (Lease Number): 10. Field/Pools. ADL 028308 & 028326 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): PIUg3 fMD1: Junk (MD): 12309 8866 1996 1996 109778 121168021 9900, None Casing Length Size MD TVD Buret Collapse Structural Conductor 80 30" 34-114 34-114 880 Surface 1431 20" 33-1464 33-1464 1530 / 2320 520/1500 Intermediate 2660 13-3/8" 31-2691 31-2691 4930 2670 Production 10577 9-5/8" 269-10606 29-8626 8150 / 7510 / 6820 5080 / 4130 / 3330 Liner 2331 3-12" x 3-3/16" x 2-7/8" 9978-12309 8165-8866 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 1 Tubing MD (ft): 11040- 12275 8844 - 8686 5-1/2" 17# z 4-1/2" 12.6# 80 26-10039 Packers and SSSV Type: 5-12" Baker SAB Packer Packers and SSSV MD (ft) and TVD (ft): 9905/8112 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: January 7, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wormington, Area J be deviated from without prior written approval. Contact Email: Aras.WorthingtontgMbp.com Authonzed Name: Worthington, Area J Contact Phone: +1 907 564 4102 Authorized Title: Interventions & Integri y En Meer oe/ Authonzed Signature: 4 Date: s COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,1 n x BOPTest ❑ Mechanical Integrity Test ❑ Location Clearance ti li U Plug Integrity ❑11 \ Other. � h V-6 © C L) W\- e Lf�T ,E: h O C — C--oll,-c+ 2b" Cas/ �5 �er w.��'GIfvrS t� -ie�� t -spw Post Initial Injection MIT Req'd? Yes ❑ No ❑ /, Spacing Exception Required? Yes ❑ No 13 Subsequent Form Required: i APPROVEDBYTHE O9 Approved by: COMMISSIONER COMMISSION Date: l I Form 10403 Revised 04/2017 ORIGINAL RBDMS S�JAN 0 9 2019 Submit Form and Approved application is valid for 12 months from the date of approvalAt . �7/.mc�ntDuplicate �caatj� 02-02 Surface P&A Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Paulina Meixueiro (907) 564-5971 Expected start date: January 7'h 2019 History Well 02-02 was originally drilled in 1970, worked over and completed in 1975 and a tubing change -out RWO was performed in 1980. In 1998 the well was CTD sidetracked to become 02-02A. Well 02-02 has 3 casing strings, and the surface casing shoe set in the permafrost. All such wells were shut in and secured following the 14th April 2017 Well 02-03 release, due to the potential for sudden upward wellhead movement. However, 02-02 had been shut in since 2006, and two downhole plugs set, due to tubing x IA communication. Slickline attempted to drift the well on 12/12/18 and found that the tubing had parted at surface and left roughly an 8 -foot gap between the hanger and the tubing stub. It was successfully drifted down to 9765' MD with a 2.85" drift. Two cement plugs have been laid into the tubing and IA with CT. The lower cement plug is from 9734' MD to 9227' SLM and the upper cement plug is from 9000' MD to —2000' MD. Event Summary 7th December 2018 At 14:15, while performing daily well checks, the Drill Site 02 Operator observed gas and oil mist venting from Well 02-02. He observed the wellhead and tree had moved upwards, causing the uppermost scaffold platform to strike the wellhouse roof. He initiated emergency response immediately. The IA pressure was bled off and the severity of the leak lessened such that the leak location could be definitively identified. Leak location is the tubing head adapter x master valve flange. It was visually confirmed that the 20" surface casing had failed approximately 4' below the top of the conductor. Several attempts to re -torque the studs on the tree stopped the leak. Objective Circulate Arctic Pack out of the wellbore annuli and place surface abandonment cement plugs in all annuli from —1300' MD to surface. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps E -Line 1. Run GR log and gyro survey from TOC to surface (log all the way into the Tree - this log is for future subsidence surveillance/analysis). 2. MU 3-3/8" x 10' Hyperjet 3406 RDX (or equal penetration charges), 60 deg 6 SPF. Run the exact same BHA with braided line brush as was run on the previous SL perforation to ensure the ability to get into the tubing stub at surface. 3. Perforate -1300' MD through 5-1/2" tubing, 9-5/8" casing, and 13-3/8" casing. Fullbore/Special Projects 1. RU to pump down the OA and take returns from the OOA. The OOA returns will be to a KatchKan or cellar liner due to the 20" casing having parted at surface. Have a vac truck rigged up to suck out the OOA returns. 2. Pump the following down the OA with all returns from the OOA (KatchKan/cellar). Maximum OA pressure is 1200 psi. ➢ 100 bbls hot (160F) diesel ➢ 30 bbls hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and OOA and loosen Arctic Pack ➢ 80 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 ➢ 350 bbls hot (160F) 9.8 ppg brine 3. Once clean brine is consistently returned from the OOA indicating that all hydrocarbons have been circulated out of the annuli, pump surface (lateral) cement plug as follows down the OA: ➢ 5 bbls MEOH (Pump down OA, take returns from cellar/KatchKan ➢ 5 bbls freshwater spacer (Pump down OA, take returns from cellar/KatchKan )0, 420 bbls 15.8 ppg cement per design I_--7jii. Swap to taking returns from tubing/IA after clean cement returns are observed at the cellar/KatchKan (expected at -310 bbls of cement away) jv. SD and wash up without pumping any wash up water downhole after all cement is away. / _--> � k'o `ro 9,© C- es OX -,e 7 C.e w. e..` �-- 4-0 Volume Calculations: Q') ` "o- v� v\- U l 'S 1, to -T'/TA '�-n e CawiewA-r¢ r+� S �t owt 0©(� ! top MD bot MD Size ID bbls! S � r— �a_ C-2 L �Ph ©1A 1 r r N 3 (-'--A-0 r VL u<o v.wte volume ft. Ft. bbls 19.124" 20" x 13-3/8" annulus to 20" 94# x x 859' Surface 859' 13-3/8" 13.375" 0.182 859' 156 18.73" 20" x 13-3/8" annulus to 20" 133# x x 1300' 859' 1300' 13-3/8" 13.375" 0.167 441' 74 12.347" 13-3/8" 72# x 13-3/8" x 9-5/8" Surface 1300' x 9-5/8" 9.625" 0.0581 1300' 76 8.681" 9-5/8" x 5-1/2" annulus Surface 1300' 9-5/8" 47# x 5-1/2" 0.0438 1300' 57 5-1/2" tubing Surface 1300' 5-1/2" 17# 4.892" 1 0.0232 1 1300' 30 Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Shearing time, quality control, PJSM Slurry Temperature: between 800 and 110°F 5 Fluid Loss: 40-200cc (20-100cc/30 min) Safety Compressive Strength: 2000 psi in 48 hrs. 5 Thickening Time: Minimum 5 hours 0 Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 5 Cement contamination 0 Safety 0 Minimum required thickening time: 5 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 1000 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. — Sa_ � Z pit CSS 1� q 2. AOGCC witness cement tops in all annuli �m r {tn e - u r99 c ,ta i tis.5` 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follbl. BP Exploration Alaska, Inc. 02-02A PTD # 197-168 API # 50-029-20074-01 N 1 o `,J i d B C_t1 IM, e v�J � lm VVIGu Q eS I v�- � L - C -.e M WELLHEAD= 4cRtn MCEVOY - — BAKER C OKB. ELEV = 64' BF. R _ SHOT KOP= 3000' Max Angle =_ Dahsn MD= -- 98" @ 11856 --- 11146' Dab nND= BOW SS H-40 / K-55, D = 19.124' 1-1 1464' o- uc � rw a e wm nl"�.n, -i VUUU- - NUIY- � - 2.5" FOWF3T FLOW GUN (12/26/18) 5-1/2' TBG & 9-5/8" CSG PUNCH, 9734' - 9744' SEM 2.5" POWER FLOW GUN (12/17/18) Minimum ID = 2.375" @ 10734' 3-1/16" x 2-7/r XO 5-12' TBG -PC, 17#, L-80, .0232 bpf, D = 4.892" 9918' TOP OF 4 -12 - TBG- PC 9918' ITOPOF3-12'LNR -1 9982' 3-12" LNR 9.2#, L-80 FL4S, .0067 bpf, D = 2.992" 10012' 7OP OF 3-3/16' LNR 10012' 4-12" T13G-PC,12.6#, N-80-0152 bpf, D = 3.958- 10014' 9-6B' CSG, 409,43.5#, 47#, SOO-95, D = 8.681" 10608' PETFORATDN SUMMARY FEF LOG: MIM) ON 01131198 ANGLEATTOPPERR 71'@11040' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2" 6 11040-11090 C 0525/03 0623/14 2" 6 11210-11235 C 10127/02 12131/18 2' 6 11325-11350 C 1027/02 RJWJMD ADD®30'COPD 1-11/16" 4 11492 - 11630 C 02/04/98 1-11/16" 4 11700-11820 C 02/04/98 1-11/16' 4 12225-12275 C 02/04/98 02-02A SAFETY NOTES: W ELL ANGLE> 70° @ 10892' 3-3/16" LNR, 6.2#, L-80, 10734' .0099 bpf, D = 2.75' TOP OF 2-7/8' LNR 2-7/8' LNR 6-5#, L-80 FL -4S, 1996'-9002* ITBG&CSGCKrLAI PUNCHES (12/28/18) 15-1/2" TBG TOC (12/19/181 I 977-J5-112" OT1S SLIDING S 9877- 5-1/2"BOTPBRASSY 9918' I� 5.1/2' X 4-12" XO, D = 3-958- "7W 3-1/2' BAKER SETING SLV, D=3.000" 10024' ELFWD Tr LOGGED 01/11189 9-518" FALLOUT WINDOW 10606'- 10612' i '10� 736' 3-3116' X 2-718' XO_ D= 2 DATE Fitt/ BY CORNAEN S DATE REV BY CONTABIfrS 02/07198 LAST WORKOV ER 12/20/18 JTCIJMD P&A STAGE 1 (SL & COL) 0429107 RRD'TLH 13P SET (04/20/07) 1227/18 N(WJ R#VCI-EDTBG&CSG(12fM18) 0623/14 LEGMIAD PULLED 8F3'SET W% -(06/2D-21 12/27/18 KP/JND TREE CFO 12/27/16 ZV/JAD FULL®VVFDVWB(12/20/16) 12131/18 JTWJbD LADNCMrFROMTBGFNCFES 02/27/17 NLVWAD SET BKR 13P(02rM17) 0725/17 RJWJMD ADD®30'COPD 2-7/8' FLOATSHOE I I PRUDHOE BAY UNIT WELL: 02-02A PERIAT No: '1971680 AFI No: 50-029-20074-01 SEC 36, TI IN R14E, 827' FTL & 1728' FWL BP Exploration (Alaska) ft: 4MMMMMM`10;MOyKr_cSl 1AELLFEAD= MCEVOY ACTUATOR= A)M SON OKB. BEV = 64' BF. ELEV = 2' KOP= 3004 Max Angle = 98-0 11658' Dawn MD= 1114V Dban ND= 8800'SS D = 12.347' DS 02-02 P&A Status Minimum ID = 2.375" 0 10734' 3-1116' x 2-7/8" XO Fc➢6Y 3-12' LN7, 9.2#. L-80 FUS, .0087 bpf, D = 2.892' TOP OF 3-3/16' LNi 4-12' TBG-PC,12.6#. N40..0152 bot. D = 3.958' FERFORATDN SL#*MRY REFLOG: MMD ON 01/31196 ANGLEAT TOP FSZF: 71-@11040F Note: Refer to Rodwfion DB for Worical perf data SIZE SFF KFERVAL OprVSgz SHOT SOZ 2' 6 11040 - 11090 C 0525103 0525103 2' 6 11210- 11235 C 10127/02 0227/17 N-VWJMD SET BW 13P(02/22J17) 2' 6 11325 -11350 C 1027102 1-11116' 4 11492 - 11630 C 02/04198 1-11116' 4 11700- 11920 C 02/0/198 1-11/16' 4 12225-12275 C 0210499 LW 6.20. L-80. f. D= 2.75' WELL ANGLE> 70'0 10892' Surface Cement Plug Surface - -1300' MD Second Cement Plug 2000' — 9000' MD First Cement Plug 9227' — 9734' MD X 5-12' BAKER SAB PKR 9-5/8' MLLOl1T VITDOVV 10806' - 10612' DATE REV BY COMMENTS DATE REV BY COKUMS 02107188 LAST WORKOVER 04/29/07 FiPDITLH BP SET(04120/07) 1027102 MBIP FEFW COR TCnONS, CBP ON23H4 LECJJMD MILLED IBRSET VOW (0620-21114) 0525103 BJM`W AMPEW 17/27116 ZV/AD RA.L®WFDWRP(1220/16) 11/29/04 OFPALP 20'89-5/8'CSG 0227/17 N-VWJMD SET BW 13P(02/22J17) 03/04/06 RCTIPJC PULL RCP PKR@9974' 07/25117 RIWJMD ADDED 30'CON7 06/04/06 RRDVAG SET CEP@ 10776' 2-718' L FRLCHOE BAY LW WELL 02-02A PEFUT M: 1971680 AR No: 50-029-20074-01 BP Bcploratbn (Abaka) Pages NOT Scanned in this Well History File XHVZE 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. [ ?/7"/~ ~ File Number of Well History File PAGES TO DELETE Complete RESCAN n Color items- Pages: Gray.scale, halftones, pictures, graphs, charts - Pages: Poor Quality Original'- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. n Other, No/Type 'OVERSIZED .Logs of various kinds Other COMMENTS: Scanned by~i~md, Damtha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 I 19q34 n ry August 22, 2011 \°6 i v RECEIvED Mr. Tom Maunder l IJG 31 21111 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Alaska Oft & Gas Cons. Commission Anchorage, Alaska 99501 Aacfaerage Subject: Corrosion Inhibitor Treatments of GPB DS -02 Dear Mr. Maunder, - ` Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02 -01 B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -356 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 SEP 1 9 2006 REPORT OF SUNDRY WELL OPERA TIQn~~¡:>!. r."" I~nn~. Commission 1. Operations Performed: AbandonD Alter CasingD Change Approved ProgramD STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . /<.k-- '1/2.Jlo & . RECEIVED , Repair Well[&! Pull TubingD Operation ShutdownD Pluç PerforationsD Perforate New Pool 0 Perforate 0 Stimulate 0 waiverD Anc~{ftJsecure Well Time ExtensionD Re-enter Suspended wellD 5. Permit to Drill Number: 197-1680 6. API Number 50-029-20074-01-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development [!) ExploratoryD 64.00 8. Property Designation; ADL-028326 11. Present Well Condition Summary: StratigraphicD 9. Well Name and Number: 02-02A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ServiceD Total Depth measured 12309 feet true vertical 8800.0 feet Plugs (measured) CIBP @ 10776 (06/04106) & IBP @ 9933'(06/13/06) Effective Depth measured 10776 feet CIBP@11660 true vertical 8740.8 feet Junk (measured) None Casing Length Size MD TVD Burst Collapse CONDUCTOR 114 30"157.5# B Grade 30 - 144 30.0 · 144.0 880 SURFACE I 1434 20" 94# H-40 30 . 30.0 · 1530 520 SURFACE 20" 133# K·55 - 1464 - 1464.0 2320 1500 SURFACE 2662 13-3/8" 72# N·80 29 - 2691 29.0 - 2691.0 4930 2670 PRODUCTION 9-5/8" 47# 500-95 28 - 28.0 · 8150 5080 PRODUCTION 10578 9·5/8" 43.5# 500-95 - · 7510 4130 PRODUCTION 9·5/8" 40# 500·95 - 10606 · 8626.0 6820 3330 LINER 30 3·1/2" 9.2# L·80 9978 - 10012 8165.0 - 8190.0 7240 5410 LINER 724 3·3/16" 6.2# L-80 10012 - 10734 8190.0 · 8716.0 8520 7660 LINER 1573 2·7/8" 6.4# L-80 10734 - 12307 8716.0 · 8866.0 10570 11160 Perforation depth: Measured depth: 11040-11080,11210-11235,11325-11350, 11492-11630, 11700-11820, 12225-12275 True vertical depth: 8844-8855,8868·8868,8869-8869,8864-8868, 8870-8866, 8866·8866 Tubing ( size, grade, and measured depth); Packers & SSSV (type & measured depth): 5·1/2" 17# L-80 @ 26 4-1/2" 12.6# L-80 @ 9918 9·5/8" Baker SAB Packer @ 9905 5-1/2" Otis RQM SSSV Nipple @ 2197 9918 5CAÑ~ SEP 2 (5 2005 - 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure; RBDMS BFt SEP 25 2DD6 Prior to well operation: Subsequent to operation; Oil-Bbl 51 51 ReDresentative Dailv Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure o 0 .-- o 0 --- Tubinç Pressure 746 1874 13 ~ 15. Well Class after proposed work; ExploratoryD 16. Well Status after proposed work; OilŒJ GasD DevelopmentŒ ServiceD 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 1SUndry Number or N/A if C.O. Exempt N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr . .h ..,¡ ~V ~ f) Title Petroleum Engineer Signature J Phone 564·5174 Date 9/18/06 Form 10-404 Revised 4/2004 J t-< I b II\J A L . . 02-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/24/2006 ***well si on arrival*** (pre ctd) drift tbg to ibp w/ 3.5" cent. & lib to 9901' slm Impression of ibp fn. (ibp @ 9933' elm) ***well left si, turned well over to dso*** 06/23/2006 T/I/O/OO = 1750/1100/0/0. WHPs post bleed (pre- CAM pre CTD). TBGP increased 470 psi, lAP increased 320 psi overnight. 06/22/2006 TII/O/OO = 1100/900/0/0+. SI. Bleed WHPs to 0 psi (pre CAM pre CTD) Bleed TBGP & lAP & to bleed trailer # 94-601 simultaneously, IA FL to surface in 1 hr (500 psi), TBGP (980 psi), shut-in IA for 30 min and continue bleed. Bleed additional 1 hr, fluid at surface TBG & lA, shut-in and monitor 1 hr. TBGP increased 300 psi, lAP increased 280 psi. Final WHPs = 1280/780/0+/0+ . 06/16/2006 TIO= 1100/900/0/0. Monitor WHPs Post Bleed (pre-rig). Overnight TBGP increased 250 psi, lAP increased 200 psi. 06/15/2006 T/I/O= 1050/840/0. Temp= SI. Bleed WHP's to 0 psi, (pre-RWO). Tubing FL @ 2504' (58 bbls). IA FL @ 1092' (48 bbls). Bled lAP to slop trailer from 840 psi to 490 psi in 2 hours (fluid to surface). SI and rigged up to tubing. Bled tubing pressure from 1050 psi to 690 psi in 2 hours. During bleed lAP increased 120 psi. Monitored for 30 minutes. Tubing pressure increased 160 psi. lAP increased 90 psi. Final WHP's= 850/700/0. 06/13/2006 SET IBP IN 4.5" 12.6# TUBING BELOW THE 9 5/8" x 51/2" BAKER SAB PACKER. SECURE WELL WITH LINER TOP LEAK. IBP SET AT 9933' CORRELATED TO TUBING TALLY DATED 8-NOV-1980. Job complete... 06/13/2006 T/I/0=2350/460/0/0 Load TBG, Injectivity test (CTD Prep) Pumped 50 bbls DSL and 187 bbls 1% KCL down TBG. ***Note: After 143 bbls 1% pumped IA started tracking w. TBG pressure. *** Final WHP's=1500/1780/0/0 06/12/2006 TII/O/OO= N/A/490/0/0. Temp= SI. Bleed IA to 0 psi (pre rig). Unable to obtain tubing pressure (no ladder to swab platform). Integral installed on IA. Wellhouse and scaffolding removed. fA FL @ 336' (15 bbls). Bled lAP to slop trailer from 490 psi to 150 psi in 5 hours (gas for 4 hours then fluid to surface). Continued to bleed at 150 psi for 1 hour (167 gallons returns). Monitored for 30 minutes. lAP increased 80 psi. Tubing FL @ 9656'. IA FL @ 96'. OA FL near surface. Final WHP's= 2310/230/0/0. 06/10/2006 T/I/O/OO= 2300/450/10/0. Temp=SI. Bleed IA & OA (pre CTD). IA FL near surface. Bled lAP from 450 psi to 270 psi in 5 hrs, returned 19 bbls to slop trailer. OA & OOA FL near surface. Bled OAP from 10 psi to 0 psi in 2 min. Monitored lAP & OAP for 30 min no increased. Final WHP's 2300/270/0/0. 06/04/2006 SET BAKER 27/8" CIBP @ 10776'. PAD OPERATOR NOTIFIED UPON DEPARTURE 05/31/2006 T/I/O/OO = 2350/480/0/0. Load Tubing. Pumped 5 bbls meoh, 280 bbls 1% kcl, and 90 bbls diesel down the Tubing. Final WHP's = 100/720/0/0. OS/27/2006 TIO = 2350/500/0+/0+. Temp = SI. TBG FL (for EL). TBG FL @ 10500' (236 bbls). Page 1 . . , . 02-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS OS/23/2006 CTU #9 w/1.75" CT. WS Drift. MIRU. MU WFRD MHA w/2.5" Aluminum LSX WS Drift. Kill well with 60/40 meth spear, 270 bbls 1 % KCL and 60/40 cap while RIH. Drift well to 10,710' ctm with 2.50 Drift. Clean running in and clean pickups. POOH and FP well with 60/40 to 2500'. Hang freeze protect tag on tree, release equipment and contact DSO with final well status. RDMO.*** JOB COMPLETE *** FLUIDS PUMPED BBLS 3 Diesel --- PT Surface Equipment 18 Methanol 46 Diesel 216 Crude 399 1 % KCL Water 682 TOTAL Page 2 tREE: MCEVOY GEN 1 WELLHEAD: MCEVOY ACTUA TOR = AXELSON ¡(B. ELEV = 64' SF. ELEV = KOP : 3000' Max Angle: 98@ 11858' Datum MD = 11148' Datum TVD: 8800' SS 120" CSG, 94# /133#, H-40 / K-55, ID = 19.124" 02-02A . 113-3/8" CSG, 72#, N-80, ID = 12.347" , Minimum ID = 2.375" @ 10734' 3-1/16" x 2-7/8" XO I 5-1/2" TBG-PC, 17#. L-80, .0232 bpf, ID: 4.892" I I TOP OF 4-1/2" TBG-PC I 1 TOP OF 3-1/2" LNR I 13-1/2" LNR, 9.2#, L-80 FL4S, .0087 bpf, ID = 2.992" I I TOP OF 3-3/16" LNR I 14-1/2" TBG-PC,12.6#, N-80, .0152 bpf, ID = 3.958" , 19-5/8" CSG, 40#. 43.5#, 47#, SOO-95, ID: 8.681" ~ ÆRFORA TION SUMMA RY REF LOG: MlNO ON 01/31/98 ANGLE AT TOP ÆRF; 71 @ 11040' Note; Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11040 - 11090 C OS/25/03 2" 6 11210 - 11235 C 10/27/02 2" 6 11325 - 11350 C 10/27/02 1-11/16" 4 11492 - 11630 C 02/04/98 1-11/16" 4 11700 -11820 C 02/04/98 1-11/16" 4 12225 - 12275 C 02/04/98 3-3/16" LNR, 6.2#, L-80. .0099 bpf, ID = 2.75" SAFETY NOTES: 2197' - 5-1/2" OTIS RQM SSSV NIP, ID: 4.562'" 9775' - 5-1/2" OTIS SLIDING SL V, ID : 4.562" I 9877' -15-1/2" BOT PBR A SSY I 9905' -j 9-5/8" X 5-1/2" BAKER SAB PKR 9918' -15-1/2" X 4-1/2" XO, ID = 3.958" I 9933 ELM -12-1/2" BKR IBP(06/13/06) I 9978' 9979' -13-1/2" BAKER SEITING SLY, ID: 3.000" -14-1/2" BAKER R NIP, ID = 3.759" I 10012' -13-1/2" X 3-3/16" XO, ID = 2.750" I 10014' -14-1/2" TUBING TAIL (BEHIND CT LNR) 10024' HELMDTTLOGGED01/11/89 I 10090' -j TOP OF CEMENT I I 9-5/8" MILLOUTWINDOW 10606' - 10612' , 2-7/8" LNR, 6.5#, L-80 FL-4S, .00579 bpf, 10= 2.441" , DATE 02107198 10/27/02 OS/25/03 11/29/04 03/04/06 06/04/06 REV BY COMMENTS LAST WORKOVER MElTP ÆRF CORRECTIONS; CIBP BJMTP ADD PERF DFRlTLP 20" & 9-5/8" CSG CORRECTIONS RCT/PJC PULL RCP PKR @ 9974' RRO/PAG SETCIBP@ 10776' DA TE REV BY COMMENTS 06/13/06 GJB/PJC SET IBP @ 9933' ELM PRUDHOE BA Y UNfT WELL: 02-02A PERMfT No: "1971680 API No: 50-029-20074-01 SEC 25. T11 N, R14E, 94.49' FEL & 3870.96' FNL BP Exploration (Alaska) ~üL%üŒ e lill·ñl,~.", " " ~ "I "!,, i I ¡ ""'" e AI4ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 . Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 tq1- ~ro ~ Re: Prudhoe Bay Field, PBU 02-02A Sundry Number: 306-044 '^j (;¡ "'~,. Iii '\~~~'~W':\ .." \' "- ~~5-~~~\!t,¡¡¡.· Dear Ms. Endacott: 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 fonn. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ Daniel T. Seamount Jr. f7 Commissioner DATED this ~ day of February, 2006 Enc!. - " Cfl} -¿,.,~4J¡' \.,...H:¡Â- -t- { 1.# ( ~ u'""" 'STATE OF ALASKA e RECEIVED ALASKA 0 AND GAS CONSERVATION COMMISSION FEB 072006 APPLICATION FOR SUNDRY APPROV4&skaoil&Gascons Cornniuion 20 AAC 25.280 Anchor~ 1. Type of Request: a Abandon o Suspend o Operation Shutdown o Perforate o Other --------------+------- o Alter Casing o Repair Well o Plug Perforations o Stimulate [J Re-Enter Suspended Well [J Change Approved Program [J Pull Tubing [J Perforate New Pool [J Waiver [J Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ./.. 197·168 ,/ a Development D Exploratory 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20074-01-00./' 7, KB Elevation (ft): 64' 9. Well Name and Number: PBU 02-02A ,../" 8. Property Designation: 1 O. Field / Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12309 8866 11660 8869 11660 None Casing Length Size MD ./ TVD Burst CollaDse Structural 114' 30" 114' 114' 880 . 1464' 20" 1464' 1464' 1530 520 2691' 13-3/8" 2691' 2691' 5380 2670 1 0606' 9-5/8" 10606' 8626' 6820 3330 Liner 2327' 3-1/2' x 3-3116' x 2-7/8' 9982' - 12309' 8168' - 8866' 8520 7660 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I: Tubing Size: Tubing Grade: I Tubing MD (ft): 11040' - 12275' ,/ 8844' - 8866' 5-1/2"17# x 4-1/2", 12.6# L-80 / N-80 10014' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer Packers and SSSV MD (ft): 9905' / 12. Attachments: 13. Well Class after proposed work: / a Description Summary of Proposal D BOP Sketch D Exploratory a Development D Service D Detailed Operations Program /\ 14. Estimated Date for FebrUaryÄ,)006 15. Well Status after proposed work: Commencing Operations: DOil DGas D Plugged a Abandoned 16. Verbal Approval: Datè;/ DWAG DGINJ DWINJ D WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott J Title CT Drilling Engineer .f/I/¡)J. A Ad A "NI1/Pfi'¡¡¡-' Date z./(g!tJ(¡; Prepared By Name/Number: Sianature Phone 564-4388 Terrie Hubble, 564-4628 '1 J , Commission Use Only /l " I Sundry Number: 30(0 -('>'44 Conditions of approval: Notify Commission so that a representative may witness , D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance Other: At> f 1-\11.1 e,d F&VIAA.. lC?~40l ~~~d ~~ Ç.~iY~ t,U..lL( O'L-D'L ß . Sub"'".~Forrn~d' \"~ RBDMS 8Ft {} 9 2006 APPROVED BY zl cf IÞ Approved By: if r y , COMMISSIONER THE COMMISSION Date Form 10-403 Revis1)tJ 0~20Cf5 /' Submit In Du licate p OR1G\NAL ,,"-' e e bp To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission . ~ From: M.S, Endacott, BPXA CTD Engineer; 564-4388 "--t Date: February 2, 2006 Re: Prep Prudhoe 02-02A for CTD sidetrack Sundry approval is requested to prepare 02-02A for a sidetrack 02-02B. This well was originally sidetracked in January, 1998 as a horizontal Zone 1 producer. During the cement job, the wiper dart did not sdrop and 7bbls of / cement were eft in the liner with 8bbls of cemnt placed behind pipe. Aliner top packer was installed, The well began cycling in 6 months. A borax CNL run in September 1999 detected a small 50' channel in the middle of the well but no channelling in the heel. After cycling for 4 years a cmp was set to isolate the toe and reduce gas production. Heel perforations were added. This increased production but within 1 year, the well reached marginal GOR and additional heel perforations were shot in april2003. /' Since 2003 the well has continued to cycle with decreasing on time. The 02-02A demonstrates minimal healing when shut in and had minimal uptime in 2005. No intervention options exist for this well. Pre-Rig Work Summary: The pre CTD work is slated to begin approximately Feb, 10,2006. UJ. Pull RCP liner top packer@9974'(incl.42deg);DriftforCmP,driftforwhipstock. 2. Set cmp in 2 7/8" liner at +/-10,800' (59deg inclination) 3. Set 3 3/16" whipstock high side toolface at 10640' l Ril! ork Tk c;. lO - 4-0 ~ ~ p k:) l/ A..- , 1. MIRV Nordic 1 and test BOPE, 2. Mill 2.74" window in Zone 2, 3. Drill sidetrack into Zone 1A1IB target. 4. Run and cement 2 3/8"liner. 5. Clean out liner and run cased-hole MCNL log, 6. Run tie back and liner top packer. 7. Freeze protect well and RDMO. Post- Ril! Work 1, N2 lift. 2. Install well house, Hook up flow line. CC: Well File Sondra Stewmanfferrie Hubble TREE: MCEVOY GEN 1 Wa.LHEAD;= MCEVOY ÃCTUATO'R';ÃxECšo'N KB. ELEV : 64' BF, ELEV : KOp: 3000' Max Angle: 98 @ 11858' Datum MD: 11148' Datum TVD : 8800' SS 120" CSG. 94# 1133#. H-40 1 K-55. ID: 19.124" e 02-02A . 113-3/8" CSG, 72#, N-80. ID: 12.347" I Minimum ID = 2.350" @ 9974' 4-1/2" HES RCP PKR (WIREUNE SET) 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID: 4.892" I TOPOF 4-1/2" TBG-PC I TOPOF 3-1/2" LNR I 1 3-1/2" LNR, 9.2#, L-80 FL4S. .0087 bpf, ID = 2.992" I I TOP OF 3-3/16" LNR I 14-1/2" TBG-PC.12.6#. N-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 40#. 43.5#. 47#. SOO-95, ID = 8.681" I~ ÆRFORA TION SUMrv1Þ..RY REF LOG: MIND ON 01/31/98 ANGLEATTOPÆRF: 71 @ 11040' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11040 - 11090 0 OS/25/03 2" 6 11210 - 11235 0 10/27/02 2" 611325-11350 0 10/27/02 1-11116" 4 11492 - 11630 0 02/04/98 1-11116" 4 11700 - 11820 0 02/04/98 1-11/16" 4 12225 - 12275 0 02/04/98 3-3/16" LNR, 6.2#, L-80, .0099 bpf, ID = 2.75" e I SAFETY NOTES: 2197' -i 5-1/2" OTIS RQM SSSV NIP, ID = 4.562"1 9775' -i5-1/2" OTIS SLIDING SLV, ID=4.562" I 9877' -i 5-1/2" BOT PBR A SSY I 9905' -i 9-5/8" X 5-1/2" BAKER SAB PKR 9918' -i5-1/2" X 4-112" XO. ID = 3.958" I 9974' 9978' 9979' -i4-1/2" HES RCP PKR. ID = 2.350" -i3-1/2" BAKER SEITING SLY. ID = 3.000" -i4-1/2" BAKER R NIP, ID = 3.759" I 10012' -i3-1/2" X 3-3116" XO, ID = 2.750" I 10014' -i4-1/2" TUBING TAIL (BEHIND CT LNR) 10024' HELMDTTLOGGED01/11189 I 10090' -i TOP OF CEMENT I 9-5/8" MILLOUTWINDOW 10606' - 10612' 10734' H3-3/16" X 2-718" XO. ID = 2.375" I 12-7/8" LNR. 6.5#. L-80 FL-4S, .00579 bpf, ID = 2.441" I DATE 02/07/98 03/30101 10/27/02 05/25/03 08/17/03 11/29/04 REV BY COMMENTS REV BY COMMENTS LAST WORKOVER RNlTP CORRECTIONS MEfTP ÆRF CORRECTIONS; CIBP BJrwTP ADD ÆRF CMO/TLP DATUM MD CORRECTION DFRlTLP 20" & 9-5/8" CSG CORRECTIONS DATE PRUDHOE BA Y UNrr WELL: 02-02A ÆRMrr No: 1971680 API No: 50-029-20074-01 SEC 25. T11 N, R14E, 94.49' FEL & 3870.96' FNL BP Exploration (Alaska) TREE = tV'/.::;fNOY GEN 1 LI-EA¡;) = f./CfNOY ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP= Max Angle Datum M) = Datum lVO D~2-02B Proposed crD Com PleA M 4- 3000' = 98 @ 11858' . 219T -15-1/2" OTIS ROM SSSV NIP, 11148' = 8800' SS # /133#, H-40 / K-55, 10 = 19.124" I 1464' -µ ~ 113-3/8" CSG, 72#, N-80, [) = 12.347" 2691' ~ ~ inimum 10 = 2.350" @ 9974' I I 9775' - 5-1/2" OTIS SLIDING SL V, [) = 1/2" HES RCP PKR (WIRELlNE SET) l I 9877' -15-1/2" BOT PElR A SSY I ) }.....~ ~ 9905' -i9-5/8" x 5-1/2" BAKER SAB G-PC, 17#. L-80, .0232 bpf, ID = 4.892"1 9918' I TOP OF 4-1/2" TBG-PC I ~ 9918' -15-1/2" x 4-1/2" XO, ID = 3.958' 9918' i:8 ~ Liner Top Packer 9970' "'! 2 3/8" extension for liner top packer .. 9978' -13-1/2" BAKER SETTING SLY. I . 9979' -14-1/2" BAKER R NIP. ID = 3.75 I TOP OF 3·1/2" LNR 9982' 9.2#. L-80 FL4S. .0087 bpf. ID = 2.992" 10012' I--- I"-- TOPOF 3-3/16" LNR 10012' 10012' - 3-1/2" x 3-3/16" XO,ID = 2.75 PC,12.6#. N-80. .0152 bpf, ID = 3.958" 10014' 10014' - 4-1/2" TUBING TAIL (BEHIND .40#.43.5#,47#. SOO-95. ID = 8.681" l-i 10608' 1 10024' [-i8..MD TT LOGGED 01/11/89 I I .} ) 10090' H TOP OF CEMENT I -5/8" MIlLOUTWINOOW 10606' - 10612' I Top of 23/8" Tubing 10,400' 1,3-3/16" LNR. ~.2#, ~-80, 1-1 10734' ~ / Mech. Whipstock @ 10,640' .0099 bpf. D - 2.75 ~"'- J PERFORA TION SUMlAARY I RET LOG: MoNO ON 01/31/98 2 318" cemented liner 12.667' NGLEATTOPPERF: 71 @ 11040' 8 "i -J3-3/16" X 2-7/8" XO, 10 = 2.375" \ er to Production DB for historical perf data 10734' PF NTERV AL Opn/Sqz DATE 6 11040 - 11090 0 OS/25/03 -I -J CIBP I 6 11210 -11235 0 10/27/02 B 11660' 6 11325 - 11350 0 1 0/27/02 4 11492 - 11630 0 02104/98 4 11700 - 11820 0 02/04/98 4 12225 - 12275 0 02/04/98 .........- 12306' DAVIS LYNCH I ID = 4.562"\ 120" CSG. 94 4.562" I PKR I 5·1/2" TB '\ ID = 3.000" 9"\ I 3-1/2" LNR. O· I I 4-1/2" TBG- I 9-5/8" CSG CT LNR) I 9 A Note: Ref SIZE S 2" 2" 2" 1-11/16" 1-11/16" 1-11/16" 1230T I DATE 02/07/98 03/30/01 10127/02 05125103 08117/03 11129104 RE:V BY COf.M3\ITS LAST WORKOVER Rt¥rP CORRECTIONS ÞIE/TP PERF CORRECTIONS; CElP BJM'TP ADD PERF CMOITLP DATUM M:> CORRECTION DFR/TLP 20' & 9-5/8" CSG CORRECTIONS DATE RE:VBY COWMNTS PRUDHOE BAY UNIT WELL: 02-02A ÆRMIT No: 1971680 API No: 50-029-20074-01 see 25, T11 N, R14E. 94.49' FEI.. & 3870.96' FNL BP exploration (Alaska) I PRUDHOE BAY, PRUDHOE OIL PBU_DS2 PRUDHOE BAY 50 02-02A Oil Rate (CD) ( Mbbl/d ) - W:iter Rate (CD)( Mbbl/d ) Gas Rate (CD) ( MMcfld ) Cum Oil Prod ( MMbbl ) Gas/ Oil Ratio (Mcf/bbl ) W:iter Cut ( % ) 100 5 05 0,1 0.05 0.01 1998 99 2000 01 02 03 04 05 Date 1!:R3 99 2J1XJ 01 02 03 04 05 œ 50 100 ~ 15500 â £ m m a::: ð 1(D) 500) QI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE~] Suspendr-] Operation Shutdownr'-~ Perforate. Variancer-] Annuar Disposalr-] After Casin¢][--i Repair Well[--I Pluc~ Perforations[~3 Stimulate[--] Time Extension~] Otherr-I Change Approved Programr'-] Pull Tubing~--] Perforate New Poolr'-~ Re-enter Suspended Wellr"l ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement [ Exploratoryr'~ 197-168 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic ~] Service E~ 50-029-20074-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 64.00 02-02A ,8. Property Designation: 10. Field/Pool(s): 028308 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12309 feet true vertical 8805 feet Plugs (measured) CIBP set @ 11660' (10/25/2002). Effective Depth measured 11660 feet Junk (measured) true vertical 8869 feet Casing Length Size MD TVD Burst Collapse Conductor 114' 30" 144' 144' 40K ( --- ) Surface 1434' 20" 1464' 1464' 40K 520 Intermediate 2661' 13-3/8" 2691' 2691' 80K 2670 Production 10576' 9-5/8" 10606' 8626' 95K 5080 Liner 1030' 3-1/2" 9982'-10012' 8168'-8190' 80K 10530 Liner 724' 3-3/16" 10012'-10736' 8190'-8717' 80K 10744 Liner 1573' 2-7/8" 10736'-12309' 8717'-8866' 80K 11160 Perforation depth: Measured depth: Open Perfs 11040'-11080', 11210'-11235', 11325'-11350', 11492'-11630', Open Perfs 11700'-11820', 12225'-12275'. True vertical depth: Open Perfs 8844'-8855', 8868'-8868', 8869'-8869', 8864'-8868', Open Perfs 8870'-8866', 8866'-8866'. Tubing: ( size, grade, and measured depth) 5-1/2" 17# L-80 TBG-PC @ 9918'. 5-1/2" x 4-1/2" XO @ 9918'. 4-1/2" 12.6# L-80 TBG-PC @ 10014'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BKR SAB PKR @ 9905'. 4-1/2" HES PCP PKR @ 9974'. 5-1/2" Otis RQM SSSV Nipple @ 2197'. ~,~,~ 12. Stimulation or cement squeeze summary: Intervals treated (measured):JUN ! 6 2003 Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaqe Production orJ~j~r'~J~a~ OiI-Bbl Gas-Mcf Water-Bbl Casin~l Pl~:~lr, era~jB Tubin~l Pressure Prior to well operation: 1166 51437 0 709 Subsequent to operation: 1184 26380 0 618 14. Attachments: 15. Well Class after proposed work: Exploratory[--] Development~ Service r"'~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oil[] Gas[~ WAGr"] GINJE~ WINJE-] WDSPLr' Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A~E_xempt: Contact DeWa)/ne R. Schnorr I N/A Printed Name,, ,, _... ,O .~DeWayne R. Schnorr . Title Techical Assistant Signature ~"~..~~~~~,...~.~,~ Phone 907/564-5174 Date Ma¥30,2003 Form 10-404 Revised 2/2003 02-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/17/2OO3 05/19/2OO3 05/2O/2OO3 O5/24/2OO3 05/25/2003 05/25/20O3 05/29/2003 TESTEVENT --- BOPD: 1,166, BWPD: 0, MCFPD: 51,437, AL Rate: 0 PERFORAT]:NG: DR]~FT/TAG PERFORATING: DR]:FT/TAG PERFORAT]:NG: PERFORAT]:NG PERFORAT:[NG: PERFORAT]:NG PERFORATING: PERFORAT]:NG TESTEVENT --- BOPD: 1,004, BWPD: 0, MCFPD: 26,932, AL RATE: 0 EVENT SUMMARY 04/17/03 TESTEVENT --- BOPD: 1,166, BWPD: 0, IVlCFPD: 51,437, AL Rate: 0 05/19/03 WELL SHUT IN AND FREEZE PROTECTED ON ARRIVAL. RIGGING UP SLICKLINE UNIT TO DRIFT FOR ADPERFS. 05/20/03 DRIFT 2" DUMMY PERF GUN TO 9960' SLM AND SAT DOWN ON HES RCP PACKER, ***NOT ABLE TO WORK PAST****. DRIFTED W/2" DG W/1.85" CENT ON BOTTOM TO 11,112' SLM (STOPPED DUE TO DEVIATION) ***NO PROBLEMS GOING THRU RCP***. ***WELL LEFT SHUT IN***. 05/24/03 ASSIST E-LINE PUMPING PERF GUNS DOWN DEVIATED HOLE. 05/25/03 T/I/O/O = 2200/900/0/0 ADD PERF. ASSIST SWS BY PUMPING PERF GUNS DOWN DEVIATED HOLE. PUMPED A TOTAL OF 45 BBLS OF CRUDE DURING SIX TIMES TO GET GUNS DOWN TO ZONE TO BE PERFORATED. FINAL T/I/O/O = 1900/900/0/0. 05/25/03 PERFORATED INTERVAL 11040'-11080', CORRELATED TO SWS MEMORY CNL LOG DATED 25-OCTOBER-2002, WITH TWO 20 FOOT x 2 IN HSD GUNS LOADED W/P J-2006 HMX CHARGES 6-SPF. UNABLE TO FALL WITH GRAVITY PAST 10880'. PUMPED CRUDE DOWN TUBING @ 2.5 BPM TO FALL. LOGGED ALL PASSES W/PUMPS OFF. ON SECOND RIH, HUNG UP ON PACKER @ 9974'. FELL THROUGH ON SECOND ATTEMPT. DID NOT TAG TD. STOPPED DUE TO DEVIATION @ 11112. LEFT WELL SHUT IN. DSO NOTIFIED OF WELL STATUS. 05/29/03 TESTEVENT --- BOPD: 1,004, BWPD: 0, MCFPD: 26,932, AL RATE: 0 FLUIDS PUMPED BBLS 2 PRESSURE TEST LUBRICATOR WITH DIESEL (2 TESTS). 135 CRUDE 137 TOTAL Page 1 02-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 05/25/2003 THE FOLLOWING INTERVAL WAS PERFORATED WITH 2" HMX HSD, POWERJET-2006 GUN, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11040'-11080' Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X ClBP/ADD PERFS Pull tubing_ Alter casing_ Repair well_ Other_ ClBP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 829' FNL, 3552' FEL, Sec. 36, T11N, R14E, UM At top of productive interval 3996' FNL, 4264' FEL, Sec. 30, T11 N, R15E, UM At effective depth 3960' FNL, 4446' FEL, Sec. 30, T11 N, R15E, UM At total depth 3872' FNL, 95' FEL, Sec. 25, T11N, R14E, UM 5. Type of Well: "% Development __X Exploratow__ Stratigraphic__ Service__ (asp's 688475, 5950394) -\ (asp's 692696, 5952614) (asp's 692513, 5952645) ~ (asp's 691874, 5952717) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 02-02A 9. Permit number / approval number 197-168 10. APl number 50-029-20074-01 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 Conductor Surface Length 114' 1434' 2661' 10576' 1030' 724' 1573' Intermediate Production Liner Liner Liner 12309 feet Plugs (measured) 8805 feet 11660 feet Junk (measured) 8869 feet CIBP set @ 11660' (10/25/2002) Size Cemented Measured Depth True Vertical Depth 30" Cemented 144' 144' 20" 930 sx Fondu 1464' 1464' 13-3/8" 242 sx Fondu, 545 sx 2691' 2691' Class 'G' 9-5/8" 1680 sx Class 'G' 10606' 8626' 3-1/2" 15 bbls Class 'G' 9982' - 10012' 8168'-8190' 3-3/16" 15 bbls Class 'G' 10012' - 10736' 8190'-8717' 2-7/8" 15 bbls Class 'G' 10736' - 12309' 8717'-8866' Perforation depth: measured Open Peris 11210'-11235', 11325'-11350', 11492'-11630', 11700'-11820', 12225'-12275' true vertical Open Peris 8868'-8868', 8869'-8869', 8864'-8868', 8870'-8866', 8866'-8866' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 5-1/2", 17#, L-80 PCTBG @ 9918' MD; 5-1/2" x 4-1/2" XO @ 9918'. 4-1/2" 12.6#, L-80 PC TBG @ 10014' MD. 5-1/2" Otis RQM SSSV Nipple @ 2197' MD. EIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) OCT Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injectio .¢~0ii'& OiI-Bbl Gas-Mci Water-Bbl Cas' .~¢~'~e Tubing Pressure Prior to well operation 10/02/2002 499 20584 0 671 Subsequent to operation 10/27/2002 2627 29188 0 195 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ J",k~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 knowledge. ~'/~,~~ ,~r~~~;~¢-'~' Title: Technical Assistant DeWayne R. Schnorr Date October 281 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 02-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/18/2002 10/19/20O2 10/25/2OO2 1 O/26/2OO2 1 O/27/2OO2 1 O/27/2OO2 PERFORATING: DRIFT/TAG PERFORATING: DRIFT/TAG PERFORATING: CAST IRON BRIDGE PLUG; PERFORATING; RST / CNL / PNL PERFORATING: N2 LIFT; PERFORATING PERFORATING: N2 LIFT TESTEVENT --- BOPD: 2,627, BWPD: 0, MCFPD: 29,188, AL Rate: 0 EVENT SUMMARY 10/18/02 (WELL SHUT IN ON ARRIVAL ) --- START DRIFT W/2" DMY GUN & SAMPLE BAILER. (JOB IN PROGRESS). 10/19/02 DRIFT TBG W/10' LONG 2" DMY GUN & SAMPLE BAILER TO 11,108' WLMD. TOOL STOPPED DUE TO DEVIATION. PERF TARGET DEPTH, 11,210' MD - 11,350' MD. <<< WELL LEFT SHUT IN >>> 10/25/02 MAKE DRIFT RUN TO 12200' WITH 2.25 JS NOZZLE. NO PROBLEMS. POH. KILL WELL. RIH WITH SWS MCNL, LOG 2 UP & 1 DOWN PASSES AT 60 FPM PUMPING 1% KCL @ I BPM. FLAGGED PIPE @ 11600'. POOH. RIH WITH ClBP. SET ClBPAT 11660. RETAG. GOOD. POH. JOB IN PROGRESS. 10/26/O2 OOH. MU AND RIH WITH GUN #1,25'. TIED IN AND PERFORATED 11325'- 11350'. MU AND RIH WITH GUN #2, 25'. TIED IN AND PERFORATED 11210'- 11235'. (2" P J2005 GUNS LOADED AT 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. LIFT W/N2 @ 500 SCF/M RATE TO 9100'. 1 O/27/O2 N2 LIFT @ 500 SCF/M TO 9100' & 9900'. SD N2 MONITOR FLOW, PULL TO 8000', PUMP N2 @ 500 SCF/M WHILE POOH TO 5000'. PARK, SD N2, MONITOR. POOH TO SURFACE. MONITOR WELL IN TEST SEPARATOR AT 85 DEG. CHOKE, CUT CHOKE BACK TO 50 DEG, WELL FLOWING AT (26.5 mmscf, 3000 bopd, 8415 GOR, 350 WHP). RIG DOWN, <<<JOB COMPLETE >>> 10/27/02 TESTEVENT --- BOPD: 2,627, BWPD: 0, MCFPD: 29,188, AL Rate: 0 Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( --- TEST) 116 METHANOL ,,,, 124 60/40 METHANOL WATER 662 1% ECL WATER 97 NITROGEN (4080 GALLONS) 999 TOTAL NOV 0 5 2002 Page 1 02-02A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 1 O/26/2OO2 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2" P J2006, 6-SPF, 60 DEGREE PHASIING, RANDOM ORIENTATION. 11210'- 11235' 11325' - 11350' Page 2 197-168-0 MD 12273 PRUDHOE BAY UNIT 02-02A 50- 029-20074-01 ARCO TVD 08800 o~mpletion Date: 46/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D C 9411 D 9338 D 9339 L MCNL L NGP-MD L NGP-MD L NGP-TVD L NGP-TVD R GYRO MULTI SHOT R MWD SRVY R MWD SRVY R MWD SRVY Daily Well Ops /,~/?f Was the well cored? yes Comments: ~ SCHLUM MCNL CH 12/14/99 12/29/99 /A~7 SPERRY GR .,,~-12' SPERRY GR PB1 C4~AL 9960-12220 9/30/99 L 10512-12309 ~L 10512-11844 PB1 LFI~A L 8474-8784 F~L 8544-8786 PB1 tT, B~ SCHLUM 0-9900 OH 9/2/99 9/14/99 OH 9/2/99 9/14/99 CH 2 12/8/99 12/29/99 OH 9/14/99 9/14/99 OH 9/14/99 9/14/99 OH 9/14/99 9/14/99 OH 9/14/99 9/14/99 CH 6/24/98 6/25/98 {,~I:~E'RRy 11124.79-12,309 OH 3/5/98 3/5/98 ~RY 10600.-11844.PBI OH 3/5/98 3/5/98 z~gPE~RY 10600.00-11844.00 OH 3/13/98 3/13/98 Are Dry Ditch Samples Required? yes ~' And~~o~ Ana[ysis-Des~Yiption Rece~Fe'~..-D, es--no-~--"S~mple-Set~ Thursday, February 03, 2000 Page t of 1 Scblmberger NO. 121005 12/8/99 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-TN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-02A 99406 MCNL ~4~ II 990930 I I 1 D.S. 6-10A 99416 RST ~'~ lO 991020 I I 1 D.S. 15-33A 99342 MCNL -~ 5'~/~,-- 990811 I I 1 ,~,-.% i~~:~ ~ I · ~ ~"~'~ Pta -o~,o SIGNE~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fa× to {907) 561-8317. lhank you. r) j, ;~.. (; ,- 9 1999 WELL I_X)G TRANSMITYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Alaska 99501 Anchorage, September 14, 1999 RE: MWD Formation Evaluation Logs D.S. 2-02A & 2-02A PB 1, AaK-MW-80098 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 2-02A: 2" x 5" MD Gamma Ray Logs: 50-029-20074-01 50-029-20074-0 1 DS 2-02A PBI: 2" x 5" MD Gamma Ray Logs: 50-029-20074-70 2" x 5" TVD Gamma Ray Logs: 50-029-20074-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cotton. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~ ~' September 2, 1999 RE: MWD Formation Evaluation Logs - 2-02A & 2-02A PB 1, AK-MW-80098 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted Disks with verification listing. API#: 50-029-20074-01 & 50-029-20074-70. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company --- STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I1 Status of Well Classification of Service Well Oil_X Gas__ Suspended_ Abandoned__ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-168 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20074-01 4 Location of well at surface ~"'~ "... :~' '. 7' -. ~ -'.;..~ .-~,-~-~:~T.'._~-~r 9 Unit or Lease Name ~ ?-~-~.:~_~*j~ PRUDHOE BAY UNIT 828' S & 1727' E of NW cr Sec 36, T11N, R14E, U,. At Top Producing interval .~,.;.~..~_~.._~-~,.;.~.~. · 10 Well Number 1284'N&724'EofSWcrSec30, T11N, R15E, UM. ! :,,.; ....... ~ ~.-~ 2-02A 3873' FNL, 6' FEL, Sec 25, T11N, R14E, UM .... . :.. :.,;- PRUDHOE BAY FIELD ,5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 64' RKB ADL 28326 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 1/20/98 2/1/98 2/6/98 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12309' MD / 8800' TVD 12273' MD / 8800' TVD YES_X NO__ 2197' feet MD 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP DO'FI-OM HOLE SIZE CEMENTING RECORD AMT PULLED 30" 157# B Surf 114' 39" Cemented 20" 94# & 133# H & K Surf 1464' 26" 930 Sx Fondu 13-3/8" 72# N-80 Surf 2691' 17.5" 242 Sx Fondu & 545 Sx Class G 9-5/8" 47/43.5/40# S00-95 Surf 10606' 12.25" 1680 Sx Class G 3-1/2" 9.2# L-80 9982' 10012' 4.25- 3.75" 15 Bbls Class G 3-3/16" 6.2# L-80 10012' 10736' 4.25 - 3.75 ......... 2-7/8" 6.4# L-80 10736' 12309' 4.25 - 3.75 ......... 24 Perforations open to Production (MD+TVD of Top and Boltom and 2,5 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 5-1/2" Tbg 9918' 9905' 11492 - 11630' MD (Z1); 8798- 8801' TVD (Z1); at 4 spf. 4-1/2" Tbg 10014' 11700 - 11820' MD (Z1); 8803- 8799' 'I'VD (Z1); at 4 spf. 12225 - 12275' MD (Z1); 8799 - 8800' TVD (Z1); at 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 3/4/98 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 3/5/98 '7°8 TEST PERIOD_I 814 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 350 24 HOUR RATE __ 4300 3500 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. · This 10-407 submitted as directed per the 10-401 form approved 10/14/97 (issued Permit # 97-168). ~.. ~; ~ .. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME GEOLOGIC MARKERS MEAS DEPTH TRUE VERT DEPTH FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase. 31 LIST OF ATTACHMENTS Summary of 2-02A Coil Tubing Sidetrack Drilling Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge 3- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. :-~'::: i::-. :.~'~' :~ Item 28: If no cores taken, indicate "none". Form 10-407 2-02A DESCRIPTION OF WORK COMPLETED COILED TUBING HORIZONTAL SIDETRACK DRILLING 1/18/98: Began milling 3.8" pilot hole through the cement plug from 10090' MD. 1/19/98: Milled pilot hole to 10550' MD. POOH w/BHA. RIH w/BHA & resumed milling pilot hole to 10606' MD. 1/20/98: POOH w/milling BHA. RIH w/window milling BHA. Started milling a window through the 9-5/8" casing at 10606'. Completed milling window at 10612' MD, then drilled formation to 10615' MD. POOH w/BHA. RIH w/window dressing BHA. 1/21/98: Reamed window smooth. POOH w/BHA. RIH w/drilling BHA. Could not get below 10585' top of pilot ramp. POOH w/BHA. RIH w/pilot hole BHA & cleaned out pilot hole to 10590' MD. 1/22/98: Dressed pilot hole to 10617' MD. POOH w/BHA. RIH w/drilling BHA. Circulated well to FIo Pro, then drilled sidetrack build section to 10626' MD. Performed a leak off test w/50 bbls 9.5 ppg FIo Pro out of the bit at 10626'. 625 psi - OK; EMW 10 ppg. Resumed drilling 10629'. POOH w/BHA. RIH w/drilling BHA & drilled to 10700'. 1/23/98: Continued drilling 3.75" hole to 10760' MD. POOH w/BHA. POOH w/BHA. RIH w/BHA & resumed drilling build to 11105' MD. 1124198: RIH w/drilling BHA. Drilled to 11203', then circulated in new FIo Pro, and drilled to horizontally to 11390' MD. 1/25/98: POOH w/BHA. Tested BOPE. RIH w/BHA. Drilled to 11641' MD. POOH w/BHA. 1126198: RIH w/drilling BHA. Drilled to 11728' MD. POOH w/BHA. RIH w/drilling BHA. Drilled to 11810' MD. POOH. 1127198: RIH w/drilling BHA. Drilled to 11844' MD. PUH & decided to OH Sidetrack at 11150' MD. Started sidetrack w/troughing passes from 11135' to 11150', then attempted drilling sidetrack. Drilled 11150' to 11200'; no sidetrack. POOH w/BHA. RIH w/cementing nozzle & cleaned hole from 11700' to 10000' prior to cement plugback. 1128198: Pumped 16 bbls Class G cement to plugback from 11625' to 11125'. Displaced cement w/biozan & POOH w/nozzle. WOC. RIH w/drilling BHA & tagged TOC at 11134' MD. Washed & reamed cement at 11134' to 11150', then kicked off at 11150' & drilled to 11290' MD. 1129198: Drilled to 11305' MD. Circulated in new FIo Pro. Drilled to 11687' MD w/periodic short trips to window. 1130198: Drilled to 11700' MD. POOH w/BHA. RIH w/drilling BHA. Resumed drilling to 11880' MD. POOH w/BHA. 1/31/98: RIH w/drilling BHA. Drilled to 12069'. Tripped to window & circulated in new FIo Pro. RIH & drilled to 12162' MD. 2/1/98: RIH & resumed drilling to TD at 12309' MD. POOH w/BHA laying in Hi Vis pill, and displaced to water at top of well. 2-02A DESCRIPTION OF WORK COMPLETED COILED TUBING HORIZONTAL SIDETRACK DRILLING 2/2/98: MU & RIH w/3-3/16 x 2-7/8" liner assembly. Landed liner at 10309' MD. Class G cement to set the liner at 9978 - 12309' MD. Released from liner. Pumped 15 bbls of 2/3/98: POOH w/cementing assembly & found wiper plug & pump down dart in launcher bushing. PT BOPE. RIH w/milling BHA & taqged TOC at 11115' MD. Estimated 7 bbls cement in liner; 8 bbls cement behind pipe. Milled cement in liner from 11115' to 11280' MD w/FIo Pro. 2/4/98: Milled liner cement from 11280' to 11416' MD. PT liner lap; failed w/1725 psi @ 0.5 bpm & 1825 psi @ 1.0 bpm. Milled cement to landing collar at 12273' MD. Pumped 20 bbl biozan sweep, followed by 33 bbls of new FIo Pro. POOH w/BHA circulating to 1% KCI Water. PU perforation guns & RIH. 2/5/98: Shot the initial perforations in the liner at: 12225'- 12275' MD (Z1) POOH w/perf guns. Noted ASF. PU perforation guns & RIH. Shot additional initial perforation intervals at: 11492 - 11630' MD (71) 11700 - 11820' MD (Z1) POOH w/perf guns. Noted ASF. Used 1-11/16" carriers to perf all 3 intervals at 4 spf at random orientation. 2/6/98: RIH w/2-3/4" milling BHA & drifted to 10716' MD. POOH displacing well to filtered 1% KCI Water. RIH to TOL w/stinger/seal assembly. Stung into TOL. Liner held 1200 psi; no leak-off. Bled coil, then PU on CT x tubing annulus to 1500 psi. No bleed off or returns up CT. Bled annulus & POOH while FP tubing to 2000' w/Meth-Water. RD CTU. Set plub & lock in SSSVRQM nipple at 2197'. ND BOP, NU master, & MOL. Placed the well on initial production & obtained a valid well test. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC. PBU / 2-02APB1 500292007470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/28/98 DATE OF SURVEY: 012698 MWD SURVEY JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10600.00 8554.59 8490.59 42 30 N 77.00 E .00 1764.38N 4734.16E -4194.91 10610.00 8561.98 8497.98 42 13 N 73.28 E 25.21 1766.11N 4740.67E -4200.84 10650.80 8592.23 8528.23 42 24 N 58.00 E 25.17 1777.37N 4765.53E -4222.41 10680.57 8613.58 8549.58 46 7 N 46.75 E 29.15 1790.07N 4781.89E -4235.37 10713.99 8636.03 8572.03 49 28 N 41.54 E 15.31 1807.84N 4799.10E -4247.98 10737.64 8651.16 8587.16 51 3 N 35.04 E 22.16 1822.11N 4810.35E -4255.61 10777.19 8674.70 8610.70 55 59 N 25.02 E 23.86 1849.62N 4826.15E -4264.59 10800.67 8687.24 8623.24 59 30 N 18.69 E 27.25 1868.04N 4833.51E -4267.47 10833.79 8703.22 8639.22 62 55 N 8.50 E 28.87 1896.20N 4840.28E -4267.51 10863.04 8715.72 8651.72 66 31 N .29 W 29.82 1922.55N 4842.t4E -4263.21 10891.72 8726.30 8662.30 70 13 N 7.50 W 26.67 1949.12N 4840.31E -4255.25 10919.17 8735.54 8671.54 70 29 N 15.76 W 28.35 1974.41N 4835.10E -4244.31 10952.27 8746.69 8682.69 70 13 N 24.55 W 25.02 2003.64N 4824.38E -4227.09 10985.09 8758.03 8694.03 69 25 N 33.16 W 24.74 2030.59N 4809.53E -4206.39 11011.47 8767.42 8703.42 68 54 N 41.25 W 28.73 2050.21N 4794.64E -4187.35 11040.04 8777.27 8713.27 70 50 N 49.69 W 28.54 2069.00N 4775.53E -4164.40 11069.32 8785.69 8721.69 75 45 N 57.07 W 29.40 2085.69N 4753.03E -4138.64 11097.84 8791.60 8727.60 80 19 N 61.82 W 22.85 2099.85N 4729.02E -4111.99 11124.79 8795.29 8731.29 83 56 N 64.45 W 16.52 2111.91N 4705.21E -4086.03 11153.37 8797.21 8733.21 88 19 N 65.51 W 15.80 2123.97N 4679.37E -4058.11 11197.82 8797.46 8733.46 91 3 N 67.62 W 7.74 2141.64N 4638.60E -4014.34 11225.97 8797.11 8733.11 90 20 N 67.44 W 2.57 2152.40N 4612.59E -3986.54 11248.34 8797.08 8733.08 89 49 N 67.62 W 2.50 2160.95N 4591.91E -3964.45 11265.99 8797.16 8733.16 89 39 N 66.74 W 5.08 2167.80N 4575.65E -3947.04 11329.12 8799.48 8735.48 86 7 N 68.50 W 6.23 2191.81N 4517.32E -3884.73 11376.64 8802.93 8738.93 85 33 N 67.47 W 2.48 2209.58N 4473.39E -3837.87 11436.89 8807.02 8743.02 86 39 N 65.68 W 3.49 2233.47N 4418.24E -3778.68 11500.57 8809.86 8745.86 88 14 N 63.13 W 4.71 2260.95N 4360.87E -3716.50 11528.82 8810.36 8746.36 89 44 N 61.46 W 7.94 2274.08N 4335.87E -3689.13 11570.49 8809.97 8745.97 91 19 N 62.77 W 4.93 2293.57N 4299.05E -3648.79 11605.34 8809.20 8745.20 91 13 N 62.52 W .76 2309.58N 4268.10E -3614.97 11629.29 8808.85 8744.85 90 25 N 65.46 W 12.72 2320.08N 4246.58E -3591.60 11659.47 8808.36 8744.36 91 24 N 65.51 W 3.25 2332.60N 4219.13E -3561.99 11695.22 8807.76 8743.76 90 31 N 66.21 W 3.15 2347.22N 4186.51E -3526.87 11743.37 880?.67 8743.67 89 41 N 67.38 W 2.99 2366.19N 4142.26E -3479.42 ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC. PBU / 2-02APB1 500292007470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/28/98 DATE OF SURVEY: 012698 MWD SURVEY JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11804.99 8805.80 8741.80 93 46 N 67.27 W 6.64 2389.93N 4085.44E -3418.64 11844.00 8803.23 8739.23 93 46 N 67.27 W .00 2404.97N 4049.54E -3380.23 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4709.84 FEET AT NORTH 59 DEG. 17 MIN. EAST AT MD = 11844 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 283.43 DEG. TIE-IN SURVEY AT 10,600.00' MD WINDOW POINT AT 10,610.00' MD PROJECTED SURVEY AT 11,844.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA. PAGE 3 ARCO ALASKA INC. PBU / 2-02APB1 500292007470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/28/98 DATE OF SURVEY: 012698 JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10600.00 8554.59 8490.59 11600.00 8809.31 8745.31 11844.00 8803.23 8739.23 1764.38 N 4734.16 E 2307.11 N 4272.84 E 2404.97 N 4049.54 E 2045.41 2790.69 745.28 3040.77 250.08 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE'METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC. PBU / 2-02APB! 500292007470 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/28/98 DATE OF SURVEY: 012698 JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10600.00 8554.59 8490.59 10612.73 8564.00 8500.00 10758.67 8664.00 8600.00 11001.92 8764.00 8700.00 1764.38 N 4734.16 E 1766.25 N 4742.59 E 1836.21 N 4819.19 E 2043.31 N 4800.28 E 2045.41 2048.73 3.32 2094.67 45.94 2237.92 143.25 11844.00 8803.23 8739.23 2404.97 N 4049.54 E 3040.77 802.85 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ! ARCO ALASKA INC PBU / 2-02A 500292007401 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 3/98 DATE OF SURVEY: 013198 MWD SURVEY JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11124.79 8795.29 8731.29 83 56 N 64.45 W .00 2111.91N 4705.21E -4086.04 11135.00 8796.23 8732.23 85 30 N 64.86 W 15.89 2116.26N 4696.02E -4076.09 11157.99 8797.94 8733.94 85 57 N 65.16 W 2.35 2125.95N 4675.24E -4053.63 11180.87 8799.87 8735.87 84 22 N 68.85 W 17.49 2134.85N 4654.26E -4031.15 11209.32 8801.61 8737.61 88 35 N 71.66 W 17.78 2144.44N 4627.54E -4002.94 11242.27 8801.66 8737.66 91 13 N 76.93 W 17.89 2153.36N 4595.84E -3970.03 11268.17 8801.26 8737.26 90 31 N 82.91 W 23.24 2157.89N 4570.35E -3944.19 11300.97 8801.62 8737.62 88 14 N 88.36 W 18.02 2160.38N 4537.66E -3911.81 11327.84 8802.36 8738.36 88 35 S 89.36 W 8.58 2160.62N 4510.81E -3885.64 11353.82 8802.50 8738.50 90 47 S 86.90 W 12.70 2159.77N 4484.85E -3860.58 11380.04 8801.63 8737.63 92 59 S 83.73 W 14.71 2157.63N 4458.73E -3835.68 11410.59 8799.76 8735.76 94 2 S 79.69 W 13.64 2153.23N 4428.57E -3807.36 11437.49 8798.40 8734.40 91 45 S 75.82 W 16.68 2147.54N 4402.32E -3783.15 11469.92 8797.65 8733.65 90 52 S 80.57 W 14.89 2140.91N 4370.59E -3753.84 11497.79 8797.62 8733.62 89 15 S 83.70 W 12.65 2137.09N 4342.99E -3727.87 11531.82 8798.70 8734.70 87 5 S 87.60 W 13.10 2134.51N 4309.08E -3695.49 11560.27 8800.14 8736.14 87 5 N 89.06 W 11.72 2134.15N 4280.68E -3667.95 11586.87 8800.93 8736.93 89 28 N 85.72 W 15.39 2135.36N 4254.12E -3641.84 11627.69 8801.44 8737.44 89 7 N 80.62 W 12.52 2140.21N 4213.61E -3601.30 11648.19 8801.82 8737.82 88 45 N 78.63 W 9.86 2143.90N 4193.45E -3580.84 11676.34 8802.49 8738.49 88 30 N 73.94 W 16.68 2150.57N 4166.12E -3552.71 11708.92 8803.57 8739.57 87 42 N 73.94 W 2.43 2159.58N 4134.83E -3520.18 11727.17 8804.06 8740.06 89 12 N 74.30 W 8.45 2164.57N 4117.28E -3501.95 11754.72 8803.80 8739.80 91 50 N 73.94 W 9.64 2172.11N 4090.79E -3474.43 11787.34 8802.08 8738.08 94 13 N 72.72 W 8.20 2181.45N 4059.58E -3441.91 11834.37 8797.78 8733.78 96 16 N 74.19 W 5.37 2194.79N 4014.70E -3395.16 11857.54 8794.88 8730.88 98 4 N 74.12 W 7.77 2201.06N 3992.59E -3372.20 11898.12 8789.94 8725.94 95 53 N 79.04 W 13.19 2210.41N 3953.42E -3331.93 11928.42 8787.42 8723.42 93 41 N 80.10 W 8.05 2215.87N 3923.73E -3301.79 11956.72 8786.24 8722.24 91 4 N 80.00 W 9.23 2220.76N 3895.89E -3273.57 11982.69 8785.95 8721.95 90 10 N 81.15 W 5.62 2225.01N 3870.27E -3247.66 12023.82 8785.82 8721.82 90 10 N 85.37 W 10.26 2229.83N 3829.43E -3206.82 12052.82 8786.07 8722.07 88 51 N 83.26 W 8.58 2232.71N 3800.58E -3178.09 12079.22 8787.20 8723.20 86 13 N 84.67 W 11.33 2235.48N 3774.36E -3151.94 12119.09 8790.22 8726.22 85 5 N 88.56 W 10.13 2237.83N 3734.68E -3112.80 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA iNC PBU / 2-02A 500292007401 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 3/98 DATE OF SURVEY: 013198 MWD SURVEY JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12147.47 8793.00 8729.00 83 40 S 89.53 W 8.36 2238.07N 3706.45E -3085.28 12175.52 8795.96 8731.96 84 11 N 89.94 W 2.67 2237.97N 3678.55E -3058.18 12198.54 8798.00 8734.00 85 40 N 89.45 W 6.73 2238.09N 3655.62E -3035.85 12227.82 8799.55 8735.55 88 14 S 89.36 W 9.67 2238.06N 3626.39E -3007.42 12258.54 8799.74 8735.74 91 3 S 89.00 W 9.22 2237.62N 3595.68E -2977.65 12271.54 8799.53 8735.53 90 48 S 87.58 W 11.09 2237.24N 3582.68E -2965.10 12309.00 8799.53 8735.53 89 11 S 84.30 W 9.74 2234.58N 3545.32E -2929.38 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4190.79 FEET AT NORTH 57 DEG. 46 MIN. EAST AT MD = 12309 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 283.43 DEG. TIE-IN SURVEY AT 11,124.79' MD WINDOW POINT AT 11,135.00' MD PROJECTED SURVEY AT 12,309.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC PBU / 2-02A 500292007401 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 3/98 DATE OF SURVEY: 013198 JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11124.79 8795..29 8731.29 12124.79 8790.71 8726.71 12309.00 8799.53 8735.53 2111.91 N 4705.21 E 2329.50 2237.97 N 3729.00 E 3334.08 1004.58 2234.58 N 3545.32 E 3509.47 175.39 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA~ INC PBU / 2-02A 500292007401 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/ 3/98 DATE OF SURVEY: 013198 JOB NUMBER: AKMW80098 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11124.79 8795.29 8731.29 11164.79 8798.45 8734.45 2111.91 N 4705.21 E 2329.50 2128.74 N 4669.06 E 2366.34 36.84 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO ALASKA INC. DRILLSlTE 2, WELL NO. 2-02~ PRUDHOE BAY, E.O.A., ALASKA Gyro Continuous Multishot Survey Inside 4.5" TUBING Survey date · 30 - APRIL, 1998 Job number' AK0498GCE459 jU¢~ 2,5 19~8 /~aska ~t & Gas Cons. CONTENTS JOB NUMBER · AK0498GCE459 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' AK0498GCE459 Tool 772 was run in WELL# 2-02 on SCHLUMBERGER 7/32" wireline inside 4.5" TUBING. The Survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER' AK0498GCE459 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK0498GCE4591 CLIENT: ARCO ALASKA INC. RIG: SCHLUMBERGER LOCATION: DRILLSITE 2 WELL: 2-02 LATITUDE: 70.28 N LONGITUDE: 148.3 W SURVEY DATE: SURVEY TYPE: 30 - APRIL, 1998 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 64.00 MAX. SURVEY DEPTH: 9900' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-9900' APl NUMBER: 050-029-20074 TARGET DIRECTION: N/A GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gy r o da t a D i r e c t i o na i Survey for ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2, PRUDHOE BAY, E.O.A., ALASKA Job Number: AK0498GCE459 Run Date: 30-Apr-98 09:07:05 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.280000 deg. N Sub-sea Correction from Vertical Reference: 64 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i o na I Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459 E.O.A., ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. Page HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.00 100.0 .63 116.83 .63 200.0 1.47 271.28 2.06 300.0 .21 204.38 1.40 400.0 .22 26.82 .44 0.0 -64.0 0.0 0.0 0.0 100.0 36.0 -.2 .6 116.8 200.0 136.0 -.5 .6 212.2 300.0 236.0 -.6 1.8 249.7 400.0 336.0 -.6 1.8 249.8 0.0 N 0.0 E .2 S .5 E .5 S .3 W .6 S 1.7 W .6 S 1.6 W 500.0 .36 18.12 .14 600.0 .15 21.06 .21 700.0 .39 105.72 .40 800.0 .21 117.05 .19 900.0 .01 63.29 .21 500.0 436.0 -.1 600.0 536.0 .3 700.0 636.0 .3 800.0 736.0 .1 900.0 836.0 .1 1.5 264.7 1.3 282.1 1.0 288.4 .5 286.8 .3 281.0 .1 S 1.5 W .3 N 1.3 W .3 N .9 W .1 N .4 W .1 N .3 W 1000.0 .18 135.63 .18 1100.0 .06 351.92 .23 1200.0 .08 242.41 .11 1300.0 .19 65.75 .28 1400.0 .15 180.82 .29 1000.0 936.0 -.1 1100.0 1036.0 -.1 1200.0 1136.0 -.1 1300.0 ' 1236.0 -.1 1400.0 1336.0 -.1 .2 249.8 .1 203.3 .2 229.8 .1 204.0 .2 136.0 .1 S .2 W .1 S .1 W .1 S .1 W .1 S .0 W .1 S .1 ~, 1500.0 .08 119.06 13 1600.0 .08 292.11 .16 1700.0 .09 331.30 .06 1800.0 .03 294.28 .06 1900.0 .25 316.28 .23 1500.0 1436.0 1600.0 1536.0 1700.0 1636.0 1800.0 1736.0 1900.0 1836.0 -.3 .3 147.9 .4 148.7 .2 158.2 .1 169.5 .2 282.7 .3 S .2 E .3 S .2 E .2 S .1 E .1 S .0 E .0 N .2 W 2000.0 .31 341.70 .13 2100.0 .28 82.24 .45 2200.0 .55 83.46 .26 2300.0 .42 315.48 .87 2400.0 .47 274.86 .31 2000.0 1936.0 2100.0 2036.0 2200.0 2136.0 2300.0 2236.0 2400.0 2336.0 .4 .7 .8 1.1 1.4 .6 319.1 .8 342.7 1.0 30.7 1.3 31.6 1.4 1.4 .4 N .4 W .7 N .2 W .8 N .5 E 1.1 N .7. E 1.4 N .0 E A Gyro d a t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Loca{ion: DRILLSITE 2, Job Number: AK0498GCE459 PRUDHOE BAY, E.0.A., ALASKA MEASURED I DEPTH feet N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. Page HORIZONTAL COORDINATES feet 2500.0 2600.0 2700.0 2800.0 2900.0 .67 91.34 .95 78.95 .80 95.64 .75 110.98 .73 34.65 1.14 2500.0 2436.0 1.5 1.5 8.3 .33 2599.9 2535.9 1.6 2.3 45.1 .30 2699.9 2635.9 1.7 3.6 61.5 .21 2799.9 2735.9 1.4 4.6 72.5 4.61 2899.8 2835.8 4.6 8.7 58.3 1.5 N .2 E 1.6 N 1.6 E 1.7 N 3.1 E 1.4 N 4.4 E 4.6 N 7.4 E 3000.0 3100.0 3200.0 3300.0 3350.0 8.39 41..32 11.33 57.70 12.74 58.82 15.09 59.73 15.91 59.86 3.74 2999.1 2935.1 13.4 19.8 47.3 4.04 3097.7 3033.7 24.2 36.7 48.9 1.43 3195.5 3131.5 35.1 57.4 52.3 2.36 3292.5 3228.5 47.4 81.3 54.4 1.64 3340.7 3276.7 54.1 94.7 55.1 13 .4 N 14. 5 E 24.2 N 27.7 E 35.1 N 45.4 E 47.4 N 66.1 E 54.1 N 77.7 E 3400.0 3450.0 3500.0 3550.0 3600.0 16.96 60.34 18.27 61.19 19.35 61.96 20.20 62.39 21.52 62.85 2.11 3388.7 3324.7 61.2 108.8 55.8 2.67 3436.3 3372.3 68.6 123.8 56.4 2.22 3483.6 3419.6 76.2 139.9 57.0 1.72 3530.7 3466.7 84.1 156.8 57.5 2.67 3577.4 3513.4 92.3 174.5 58.1 61.2 N 89.9 E 68.6 N 103.1 E 76.2 N 117.3 E 84.1 N 132.3 E 92.3 N 148.1 E 3650.0 3700.0 3750.0 380O.O 3850.0 22.77 63.47 24.00 63.89 25.04 64.62 26.15 64.88 27.29 65.23 2.53 3623.7 3559.7 100.8 193.3 58.6 2.48 3669.6 3605.6 109.6 213.0 59.0 2.17 3715.1 3651.1 118.6 233.7 59.5 2.22 3760.2 3696.2 127.8 255.2 59.9 2.31 3804.9 3740.9 137.3 277.6 60.4 100.8 N 164.9 E 109.6 N 182.7 E 118.6 N 201.4 E 127.8 N 220.9 E 137.3 N 241.3 E 3900.0 3950.0 4000.0 4050.0 4100.0 28.75 65.36 30.06 65.51 31.31 65.70 32.82 66.19 34.21 66.69 2.92 3849.0 3785.0 147.1 301.0 60.7 2.62 3892.6 3828.6 157.3 325.5 61.1 2.52 3935.6 3871.6 167.9 350.9 61.4 3.07 3977.9 3913.9 178.7 377.4 61.7 2.83 4019.6 3955.6 189.7 404.9 62.1 147.1 N 262.6 E 157.3 N 285.0 E 167.9 N 308.2 E 178.7 N 332.4 E 189.7 N 357.7 E A Gy r o d a t a D i r e c t i o n a i Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Loca{ion: DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459 E.O.A., ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. Page HORIZONTAL COORDINATES feet 4150.0 35.35 67.25 2.37 4200.0 35.94 67.51 1.21 4250.0 36.39 67.46 .90 4300.0 36.66 67.59 .57 4350.0 36.58 67.69 .20 4060.7 3996.7 4101.3 4037.3 4141.7 4077.7 4181.9 4117.9 4222.0 4158.0 200.9 212.1 223.4 234.8 246.1 433 .4 62 .4 462.4 62 .7 491.8 63 .0 521.5 63 .2 551.2 63 .5 200.9 N 384.0 E 212.1 N 410.9 E 223.4 N 438.1 E 234.8 N 465.6 E 246.1 N 493.2 E 4400.0 36.81 67.75 .46 4450.0 37.15 68.02 .75 4500.0 37.68 68.08 1.05 4550.0 37.88 68.36 .53 4600.0 38.06 68.61 .47 4262.1 4198.1 4302.0 4238.0 4341.7 4277.7 4381.3 4317.3 4420.7 4356.7 257.4 268.8 280.1 291.5 302.8 581.0 63.7 611.0 63.9 641.3 64.1 671.9 64.3 702 .6 64 .5 257.4 N 520.9 E 268.8 N 548.7 E 280.1 N 576.9 E 291.5 N 605.4 E 302.8 N 634.0 E 4650.0 38.11 68.76 .21 4700.0 38.63 68.78 1.04 4750.0 39.26 68.80 1.26 4800.0 40.21 69.00 1.93 4850.0 41.28 69.10 2.14 4460.0 4396.0 4499.2 4435.2 4538.1 4474.1 4576.6 4512.6 4614.4 4550.4 314.0 325.2 336.6 348.1 359.8 733.3 64.6 764.3 64.8 795.6 65.0 827.5 65.1 860.1 65.3 314.0 N 662.7 E 325.2 N 691.6 E 336.6 N 720.9 E 348.1 N 750.7 E 359.8 N 781.2 E 4900.0 42.10 69.15 1.64 4950.0 42.96 69.25 1.71 5000.0 43.58 69.25 1.25 5050.0 44.04 69.18 .92 5100.0 44.20 69.16 .31 4651.8 4587.8 4688.6 4624.6 4725.0 4661.0 4761.1 4697.1 4797.0 4733.0 371.6 383 .6 395.8 408.1 420.4 893.3 65.4 927.0 65.6 961.2 65.7 995.8 65.8 1030.5 65.9 371.6 N 812.3 E 383.6 N 843.9 E 395.8 N 875.9 E 408.1 N 908.3 E 420.4 N 940.8 E 5150.0 44.40 69.16 .41 5200.0 44.45 69.17 .10 5250.0 44.49 69.14 .09 5300.0 44.66 69.21 .35 5350.0 45.30 69.12 1.30 4832.8 4768.8 4868.5 4804.5 4904.2 4840.2 4939.8 4875.8 4975.2 4911.2 432.9 1065.4 66.0 445.3 1100.3 66.1 457.8 1135.3 66.2 470.2 1170.3 66.3 482.8 1205.6 66.4 432.9 N 973.5 E 445.3 N 1006.2 E 457.8 N 1038.9 E 470.2 N 1071.7 E · 482.8 N 1104.7 E A Gyro da t a D i r e c t i o na i Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2, Job Number: AK0498GCE459 PRUDHOE BAY, E.O.A., ALASKA MEASURED DEPTH feet I N C L AZIMUTH deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. Page HORIZONTAL COORDINATES feet 5400.0 45.74 69.11 5450.0 45.96 69.02 5500.0 46.06 68.93 5550.0 46.52 68.92 5600.0 46.65 68.70 · 88 5010.2 4946.2 495.5 1241.3 66.5 · 46 5045.0 4981.0 508.3 1277.1 66.5 .22 5079.8 5015.8 521.3 1313.1 66.6 · 92 5114.3 5050.3 534.3 1349.2 66.7 .41 5148.7 5084.7 547.4 1385.5 66.7 495.5 N 1138.1 E 508.3 N 1171.6 E 521.3 N 1205.2 E 534.3 N 1238.9 E 547.4 N 1272.7 E 5650.0 46.85 68.50 5700.0 47.41 68.64 5750.0 47.39 68.49 5800.0 47.42 68.54 5850.0 47.21 68.55 .49 5182.9 5118.9 560.7 1421.9 66.8 .15 5216.9 5152.9 574.1 1458.5 66.8 .22 5250.8 5186.8 587.5 1495.3 66.9 .08 5284.6 5220.6 601.0 1532.1 66.9 · 41 5318.5 5254.5 614.4 1568.8 66.9 560.7 N 1306.7 E 574.1 N 1340.8 E 587.5 N 1375.0 E 601.0 N 1409.3 E 614.4 N 1443.5 E 5900.0 47.95 68.57 5950.0 48.00 68.55 6000.0 48.21 68.51 6050.0 48.19 68.43 6100.0 48.59 68.55 .47 5352.3 5288.3 627.9 1605.7 67.0 .12. 5385.7 5321.7 641.5 1642.8 67.0 .42 5419.1 5355.1 655.1 1680.0 67.0 .12 5452.4 5388.4 668.8 1717.3 67.1 .83 5485.6 5421.6 682.5 1754.7 67.1 627.9 N 1477.8 E 641.5 N 1512.4 E 655.1 N 1547.0 E 668.8 N 1581.7 E 682.5 N 1616.5 E 6150.0 48.72 68.57 6200.0 48.77 68.60 6250.0 48.83 68.66 6300.0 48.88 68.64 6350.0 48.59 68.70 .25 5518.7 5454.7 696.2 1792.2 67.1 .12 5551.6 5487.6 710.0 1829.8 67.2 .14 5584.6 5520.6 723.7 1867.4 67.2 .12 5617.5 5553.5 737.4 1905.0 67.2 .59 5650.5 5586.5 751.0 1942.6 67.3 696.2 N 1651.4 E 710.0 N 1686.4 E 723.7 N 1721.5 E 737.4 N 1756.5 E 751.0 N 1791.5 E 6400.0 48.92 68.73 6450.0 48.96 68.66 6500.0 49.03 68.57 6550.0 49.07 68.53 6600.0 49.04 68.55 .66 5683.4 5619.4 764.7 1980.2 67.3 .14 5716.3 5652.3 778.4 2017.9 67.3 · 19 5749.1 5685.1 792.1 2055.6 67.3 .10 5781.8 5717.8 806.0 2093.4 67.4 .06 5814.6 5750.6 819.8 2131.1 67.4 764.7 N 1826.6 E 778.4 N 1861.7 E 792.1 N 1896.8 E 806.0 N 1932.0 E 819.8 N 1967.1 E A Gyro d a t a D i r e c t i o n a I Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Loca{ion: DRILLSITE 2, Job Number: AK0498GCE459 PRUDHOE BAY, E.O.A., ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. Page HORIZONTAL COORDINATES feet 6650.0 49.08 68.65 6700.0 49.30 68.66 6750.0 49.55 68.67 6800.0 49.78 68.72 6850.0 49.51 68.60 · 16 5847.4 5783.4 833.6 2168.9 67.4 .45 5880.0 5816.0 847.3 2206.7 67.4 .50 5912.6 5848.6 861.1 2244.7 67.4 .45 5944.9 5880.9 875.0 2282.8 67.5 .56 5977.3 5913.3 888.9 2320.9 67.5 833.6 N 2002.3 E 847.3 N 2037.6 E 861.1 N 2072.9 E 875.0 N 2108.4 E 888.9 N 2143.9 E 6900.0 49.58 68.51 6950.0 49.48 68.47 7000.0 49.34 68.40 7050.0 49.20 68.33 7100.0 49.43 68.26 .19 6009.7 5945.7 902.8 2358.9 67.5 .21 6042.2 5978.2 916.7 2397.0 67.5 .31 6074.7 6010.7 930.7 2434.9 67.5 .29 6107.4 6043.4 944.6 2472.8 67.5 · 48 6140.0 6076.0 958.7 2510.7 67.6 902.8 N 2179.3 E 916.7 N 2214.7 E 930.7 N 2250.0 E 944.6 N 2285.3 E 958.7 N 2320.5 E 7150.0 49.55 68.24 7200.0 48.75 68.13 7250.0 49.06 68.07 7300.0 49.77 68.12 7350.0 49.04 68.09 .24 6172.4 6108.4 972.8 2548.7 67.6 1.62 6205.1 6141.1 986.8 2586.5 67.6 .63 6238.0 6174.0 1000.9 2624.2 67.6 1.42 6270.5 6206.5 1015.0 2662.2 67.6 1.47 6303.1 6239.1 1029.2 2700.2 67.6 972.8 N 2355.8 E 986.8 N 2390.9 E 1000.9 N 2425.9 E 1015.0 N 2461.1 E 1029.2 N 2496.3 E 7400.0 48.66 68.16 7450.0 48.65 68.26 7500.0 48.63 68.36 7550.0 48.68 68.34 7600.0 48.89 68.51 · 75 6336.0 6272.0 1043.2 2737.8 67.6 .16 6369.0 6305.0 1057.1 2775.3 67.6 .15 6402.0 6338.0 1071.0 2812.9 67.6 .10 6435.1 6371.1 1084.9 2850.4 67.6 .50 6468.0 6404.0 1098.7 2888.0 67.6 1043.2 N 2531.3 E 1057.1 N 2566.1 E 1071.0 N 2601.0 E 1084.9 N 2635.9 E 1098.7 N 2670.9 E 7650.0 49.08 68.56 7700.0 48.19 68.80 7750.0 47.22 68.79 7800.0 46.48 68.70 7850.0 46.55 68.78 . 40 6500 . 8 6436 . 8 1112 . 5 2925 . 7 67 · 7 1 · 83 6533 · 9 6469 . 9 1126 . 1 2963 · 2 67 · 7 1.94 6567.5 6503.5 1139.5 3000.2 67.7 1.49 6601.7 6537 · 7 1152 · 7 3036.7 67.7 · 19 6636 . 1 6572 . 1 1165 . 9 3073 · 0 67 . 7 1112.5 N 2706.0 E 1126.1 N 2740.9 E 1139.5 N 2775.4 E 1152.7 N 2809.4 E 1165.9 N 2843.2' E A Gy r o d a t a D i r e c t i o na i S u rve y ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2', PRUDHOE BAY, Job Number: AK0498GCE459 E.O.A., ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. Page HORIZONTAL COORDINATES feet 7900.0 45.39 7950.0 45.22 8000.0 45.14 8050.0 44.83 8100.0 44.54 68 58 68.60 68 62 68.58 68 49 .35 6670.9 6606.9 1179.0 .33 6706.0 6642.0 1191.9 .18 6741.3 6677.3 1204.9 .61 6776.7 6712.7 1217.8 .59 6812.2 6748.2 1230.6 3108.9 67.7 3144.4 67.7 3179.9 67.7 3215.2 67.7 3250.4 67.8 1179.0 N 2876.7 E 1191.9 N 2909.8 E 1204.9 N 2942.8 E 1217.8 N 2975.7 E 1230.6 N 3008.4 E 8150.0 44.95 8200.0 44.25 8250.0 44.47 8300.0 44.80 8350.0 44.31 68 47 68.64 68 66 68.90 69 10 .81 6847.7 6783.7 1243.5 .41 6883.3 6819.3 1256.4 .44 6919.1 6855.1 1269.1 .74 6954.6 6890.6 1281.8 .02 6990.3 6926.3 1294.4 3285.6 67.8 3320.7 67.8 3355.7 67.8 3390.8 67.8 3425.9 67.8 1243.5 N 3041.2 E 1256.4 N 3073.9 E 1269.1 N 3106.4 E 1281.8 N 3139.2 E 1294.4 N 3171.9 E 8400.0 44.50 69.03 8450.0 44.11 69.00 8500.0 44.23 68.97 8550.0 43.79 68.96 8600.0 43.89 68.92 .40 7026.0 6962.0 1306.9 · 80 7061.8 6997.8 1319.4 .25 7097.6 7033.6 1331.9 .88 7133.6 7069.6 1344.4 .22 7169.7 7105.7 1356.8 3460.8 67.8 3495.8 67.8 3530.6 67.8 3565.3 67.8 3599.9 67.9 1306.9 N 3204.6 E 1319.4 N 3237.2 E 1331.9 N 3269.7 E 1344.4 N 3302.1 E 1356.8 N 3334.5 E 8650.0 43.82 69.07 8700.0 43.83 69.05 8750.0 43.94 69.08 8800.0 44.04 69.16 8850.0 44.17 69.32 . 26 7205 . 7 7141 · 7 1369 · 2 .05 7241.8 7177.8 1381.6 . 21 7277 · 8 7213 . 8 1394 . 0 . 22 7313 . 8 7249 . 8 1406 · 4 · 35 7349.7 7285 · 7 1418.7 3634.6 67.9 3669.2 67.9 3703.8 67.9 3738.6 .67.9 3773.3 67.9 1369.2 N 1381.6 N 1394 . 0 N 1406.4 N 1418 . 7 N 3366.8 E 3399.1 E 3431.5 E 3464.0 E 3496.5 E 8900.0 44.36 69.41 8950.0 44.23 69.55' 9000.0 44.07 69.61 9050.0 43.79 69.78 9100.0 44.20 69,97 .40 7385.5 7321.5 1431.0 .33 7421.3 7357.3 1443.2 .34 7457.2 7393.2 1455.4 .60 7493.2 7429.2 1467.4 .86 7529.2 7465.2 1479.4 3808.2 67.9 3843.1 67.9 3877.9 68.0 3912.6 68.0 3947.3 68.0 1431.0 N 1443 . 2 N 1455.4 N 1467.4 N 1479.4 N 3529.1 E 3561.8 E 3594.5 E 3627.0 E 3659.6 E A Gy r o da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Location- DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459 E.O.A., ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. Page HORIZONTAL'COORDINATES feet 9150.0 44.00 70.29 9200.0 44.19 70.39 9250.0 44.42 70.58 9300.0 44.48 70.87 9350.0 44.49 71.12 .60 .40 .54 .42 .35 7565.1 7501.1 1491.2 3982.1 68.0 7601.0 7537.0 1502.9 4016.9 68.0 7636.8 7572.8 1514.6 4051.8 68.0 7672.4 7608.4 1526.1 4086.7 68.1 7708.1 7644.1 1537.6 4121.7 68.1 1491.2 N 3692.4 E 1502.9 N 3725.1 E 1514.6 N 3758.0 E 1526.1 N 3791.1 E 1537.6 N 3824.2 E 9400.0 44.60 71.29 9450.0 44.12 71.34 9500.0 43.68 71.59 9550.0 43.96 72.02 9600.0 43.37 72.22 33 96 95 82 19 7743.8 7679.8 1548.9 4156.8 68.1 7779.5 7715.5 1560.1 4191.7 68.1 7815.5 7751.5 1571.1 4226.3 68.2 7851.6 7787.6 1581.9 4260.8 68.2 7887.8 7823.8 1592.5 4295.3 68.2 1548.9 N 3857.4 E 1560.1 N 3890.5 E I571.1 N 3923.4 E 1581.9 N 3956.3 E 1592.5 N 3989.1 E 9650.0 43.21 72.45 9700.0 42.79 72.67 9750.0 42.52 72.75 9800.0 42.33 73.08 9850.0 42.64 73.44 .46 .89 .54 .59 .78 7924.2 7860.2 1602.9 4329.5 68.3 7960.7 7896.7 1613.1 4363.5 68.3 7997.5 7933.5 1623.2 4397.2 68.3 8034.4 7970.4 1633.1 4430.9 68.4 8071.3 8007.3 1642.8 4464.5 68.4 1602.9 N 4021.8 E 1613.1 N 4054.3 E 1623.2 N 4086.7 E 1633.1 N 4118.9 E 1642.8 N 4151.3 E 9900.0 42.72 73.80 .52 8108.0 8044.0 1652.4 4498.3 68.4 1652.4 N 4183.8 E Final Station Closure: Distance- 4498.28 ft Az: 68.45 deg. A Gyro d a t a D i r e c t i o na i Survey for ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2, PRUDHOE BAY, E.O.A., ALASKA Job Number: AK0498GCE459SS Run Date: 30-Apr-98 09:07:05 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.280000 deg. N Sub-sea Correction from Vertical Reference: 64 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o da t a D i r e c t i o n a i S u rve y ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. E.O.A., ALASKA VERTICAL DEPTH feet VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. Page HORIZONTAL COORDINATES feet -64.0 0.00 0.00 0.00 0.0 .41 74.77 .41 100.0 1.17 215.69 1.55 200.0 .67 228.45 1.64 300.0 .22 90.70 .78 0.0 64.0 164.0 264.0 364.0 0.0 0.0 0.0 .6 74.8 .6 177.9 1.8 236.2 1.8 249.8 0.0 N 0.0 E .2 S .3 E .4 S .4 W .6 S 1.2 W .6 S 1.6 W 400.0 .31 21.25 .25 500.0 .22 20.00 .18 600.0 .30 75.26 .33 700.0 .28 112.97 .26 800.0 .08 82.63 .20 464.0 564.0 664.0 764.0 864.0 -.3 .1 .3 .2 .1 1.5 259.3 1.3 275.8 1.0 286.1 .5 287.4 .3 283.1 .3 S 1.5 W .2 N 1.4 W .3 N 1.1 W .2 N .6 W .iN .3 W 900.0 .12 109.61 .19 1000.0 .10 274.11 .21 1100.0 .07 281.80 .16 1200.0 .15 129.30 .22 1300.0 .17 139.43 .29 964.0 1064.0 1164.0 1264.0 1364.0 -.0 .2 261.1 .1 220.1 .2 220.3 .1 213.3 .2 160.5 .iS .2 W .1 S .1 W .1 S .1 W .1 S .1 W .1 S .1 E 1400.0 .11 141.27 .19 1500.0 .08 229.86 .15 1600.0 .08 317.20 .09 1700.0 .05 307.59 .06 1800.0 .17 308.36 .17 1464 · 0 1564 · 0 1664.0 1764 .0 1864.0 -.2 .3 143 .6 .4 148.4 .2 154.8 .1 165.4 .2 242.0 .2 S .2 E .3 S .2 E .2 S .1 E .2 S .0 E .1 N .1 W 1900.0 .29 332.55 .17 2000.0 .29 175.57 .34 2100.0 .45 83.02 .33 2200.0 .47 232.03 .65 2300.0 .45 289.47 .51 1964 . 0 2064.0 2164 .0 2264.0 2364.0 .3 .6 .8 1.0 1.3 .6 306.0 .8 334.2 1.0 13.4 1.3 31.3 1.4 12.3 .3 N .3 W .6 N .3 W .8 N .4 E 1.0 N .6 E 1.3 N .3 E A Gyro d a t a D i r e c t i o n a i Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Loca{ion: DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. E.O.A., ALASKA VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. Page HORIZONTAL COORDINATES feet 2400.0 .60 157.34 .84 2500.0 .85 83.41 .62 2600.0 .86 89.64 .31 2700.0 .77 105.47 .24 2800.0 3.30 62.02 3.03 2464 . 0 2564.0 2664.0 2764.0 2864 . 0 1.5 1.6 1.7 1.5 3.4 1.5 5.8 2.3 31.9 3.6 .55.6 4.6 68.6 8.7 63.4 1.5 N .1 E 1.6 N 1.1 E 1.7 N 2.6 E 1.5 N 4.0 E 3.4 N 6.3 E 2900.0 7.10 38.96 4.05 3000.0 10.33 52.10 3.93 3100.0 12.29 58.46 2.27 3200.0 14.40 59.46 2.09 3300.0 16.42 60.09 1.87 2964.0 3064.0 3164.0 3264.0 3364 . 0 10.3 20.5 31.6 43.8 57.5 19.8 51.2 36.7 48.3 57.4 51.2 81.3 53.7 108.8 55.4 10.3 N 12.0 E 20.5 N 23.2 E 31.6 N 39.7 E 43.8 N 60.0 E 57.5 N 83.6 E 3400.0 18.90 61.64 2.41 3500.0 21.14 62.72 2.39 3600.0 23.85 63.84 2.49 3700.0 26.24 64.90 2.23 3800.0 29.20 65.41 2.81 3464 . 0 3564 . 0 3664 . 0 3764.0 3864 . 0 73.0 90.0 108.5 128.6 150.7 139.9 56.7 174.5 57.9 213.0 59.0 277.6 60.0 325.5 60.9 73.0 N 111.4 E 90.0 N 143.5 E 108.5 N 180.5 E 128.6 N 222.6 E 150.7 N 270.3 E 3900.0 32.33 66.03 2.89 4000.0 35.40 67.27 2.27 4100.0 36.54 67.53 .72 4200.0 36.83 67.76 .48 4300.0 37.79 68.23 .76 3964.0 4064.0 4164.0 4264.0 4364.0 175.1 201.8 229.7 258.0 286.5 377.4 61.6 462.4 62.4 521.5 63.1 611.0 63.7 671.9 64.2 ,175.1 N 324.5 E 201.8 N 386.2 E 229.7 N 453.4 E .258.0 N 522.2 E 286.5 N 592.9 E 4400.0 38.16 68.76 .30 4500.0 39.90 68.93 1.71 4600.0 42.39 69.18 1.66 4700.0 44.05 69.18 .87 4800.0 44.44 69.17 .14 4464.0 4564.0 4664.0 4764.0 4864.0 315.1 764.3 64.7 344.3 827.5 65.1 375.6 927.0 65.5 409~0 1030.5 65.8 443.7 1100.3 66.1 315.1 N 665.6 E 344.3 N 741.0 E 375.6 N 822.8 E 409.0 N 910.9 E · 443.7 N 1002.1 E A Gy r o d a t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Loca{ion: DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459SS SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. E.O.A., ALASKA VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. Page HORIZONTAL COORDINATES feet 4900.0 45.10 69.15 1.00 5000.0 46.01 68.97 .33 5100.0 46.74 68.61 .45 5200.0 47.40 68.51 .16 5300.0 47.97 68.57 .99 4964 · 0 5064.0 5164.0 5264 · 0 5364.0 478.8 515.4 553 .3 592.8 632 .7 1205.6 66.4 1313.1 66.6 1421.9 '66.7 1532.1 66.9 1642.8 67.0 478.8 N 1094.3 E 515.4 N 1189.9 E 553.3 N 1287.9 E 592.8 N 1388.4 E 632.7 N 1490.0 E 5400.0 48.33 68.47 .37 5500.0 48.79 68.63 .13 5600.0 48.73 68.72 .62 5700.0 49.05 68.56 .15 5800.0 49.19 68.65 .31 5464 . 0 5564.0 5664.0 5764.0 5864 . 0 673.6 715.1 756.7 798.4 840.6 1754.7 67.1 1867.4 67.2 1980.2 67.3 2093.4 67.3 2206.7 67.4 673.6 N 1593.8 E 715.1 N 1699.6 E 756.7 N 1805.9 E 798.4 N 1912.9 E 840.6 N 2020.2 E 5900.0 49.62 68.65 .51 6000.0 49.38 68.42 .28 6100.0 49.52 68.24 .30 6200.0 49.63 68.11 1.26 6300.0 48.65 68.25 .25 5964.0 6064.0 6164 . 0 6264.0 6364.0 883.2 926.1 969.1 1012.2 1055.0 2320.9 67.5 2434.9 67.5 2548.7 67.6 2662.2 67.6 2775.3 67.6 883.2 N 926.1 N 969.1 N 1012.2 N i055.0 N 2129.3 E 2238.4 E 2346.6 E 2454.0 E 2560.8 E 6400.0 48.86 68.49 .45 6500.0 47.32 68.80 1.93 66'00.0 45.62 68.62 1.92 6700.0 44.94 68.60 .46 6800.0 44.63 68.55 1.09 6464.0 6564.0 6664.0 6764.0 6864.0 1097.0 1138.1 1176.4 1213.2 1249.4 2888.0 67.6 3000.2 67.7 3108.9 67.7 3215.2 67.7 3320.7 67.8 .1097.0 N 1138.1 N 1176.4 N 1213.2 N 1249.4 N 2666.6 E 2771.8 E 2870.1 E 2963.9 E 3056.1 E 6900.0 44.67 68.95 .81 7000.0 44.11 69.00 .76 7100.0 43.88 68.92 .32 7200.0 43.90 69.07 .15 7300.0 44.24 69.36 .37 6964.0 7064.0 7164.0 7264.0 7364.0 1285.1 1320.2 1354.9 1389.2 1423.6 3425.9 67.8 3530.6 67.8 3599.9 67.9 3703.8 67.9 3808.2 67.9 ,1285.1 N 1320.2 N 1354.9 N 1389.2 N 1423.6 N 3147.8 E 3239.2 E 3329.4 E 3419.1 E 3509.5 E A Gy r o da t a D i r e c t i ona I Survey ARCO ALASKA INC. WELL: 2-02, 4.5" Location: DRILLSITE 2, PRUDHOE BAY, Job Number: AK0498GCE459SS E.O.A., ALASKA SUBSEA I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg./ feet 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. Page HORIZONTAL COORDINATES feet 7400.0 44.01 69.64 7500.0 44.01 70.28 7600.0 44.47 70.80 7700.0 44.33 71.32 7800.0 43.76 72.09 .39 .61 .45 .69 .95 7464.0 7564.0 7664.0 7764.0 7864.0 1457.7 1490.9 1523.4 1555.2 1585.5 3912.6 68.0 3982.1 68.0 4086.7 '68.1 4191.7 68.1 4295.3 68.2 1457.7 N 3600.6 1490.9 N 3691.4 1523.4 N 3783.3 1555.2 N 3876.2 1585.5 N 3967.5 7900.0 42.77 72.68 8000.0 42.58 73.37 8044.0 42.72 73.80 .86 .75 .52 7964.0 8064.0 8108.0 1614.0 1640.9 1652.4 4397.2 68.3 4464.5 68.4 4498.3 68.4 1614.0 N 4057.2 1640.9 N 4144.9 1652.4 N 4183.8 Final Station Closure: Distance: 4498.28 ft Az: 68.45 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER' AK0498GCE459 ' ., TOOL NUMBER' 772 MAXIMUM GYRO TEMPERATURE ' 80.48 C MAXIMUM AMBIENT TEMPERATURE · 75.07 C MAXIMUM INCLINATION' 49.78 AVERAGE AZIMUTH · 68.45 WIRELINE REZERO VALUE ' REZERO ERROR / K ' N/A CALIBRATION USED FOR FIELD SURVEY' 2020 CALIBRATION USED FOR FINAL SURVEY' 2020 PRE JOB MASS BALANCE OFFSET CHECK: -.45 POST JOB MASS BALANCE OFFSET CHECK1 · USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.45 UPON ARRIVAL AT RIG ' OK UPON COMPLETION OF SURVEY' OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FINAL SURVEY 9900 42.72 73.80 MWD SURVEY 9900 43.50 73.00 8108.00 1652.40 4183.80 8041.74 N/A N/A FUNCTION TEST JOB NUMBER :: AK0498GCE459 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 3300 15.03 15.03 15.03 15.03 15.03 AZIMUTH M.D. ft 1 2 3 4 5 3300 59.88 60.50 60.92 59.70 60.87 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK0498GCE459 - DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 772 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0162 POWER SUPPLY C0111 PRINTER C0083 INTERFACE A0433 A0085 A0079 A0143 BACKUP TOOL No. 758 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0147 POWER SUPPLY C0089 PRINTER C0086 INTERFACE A0349 A0107 A0029 A0055 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.5" HOUSING W/CENTRALIZERS AND ECCENTRIC BAR TOTAL LENGTH OF TOOL: 27' MAXIMUM O.D.: 2.5 INCHES TOTAL WEIGHT OF TOOL: 250 POUNDS CHRONOLOGICAL REPORT JOB NUMBER' AK0498GCE459 THURSDAY, 4/30/98 08:00 10:00 10:30 12:30 14:30 15:00 16:00 TO LOCATION MU TOOL, RU SCHLUMBERGER PICK UP GYRO, RIH SURVEY TO 9900'. SURVEY OUT LD TOOL. RETURN TO ATLAS, CHECK TOOLS, PROCESS SURVEY. 0 I::! I I--I-- I I~1G S E I:! ~./I C I:: S 05-Mar-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2-02A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 11,124.79' MD Window / Kickoff Survey: 11,135.00' MD Projected Survey: 12,309.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, Wil m . Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL ~ GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 24. 1997 Erin Oba Engineering Supervisor ARCO Alaska. inc. P O Box 100360 Anchorage, AK 99510-0360 Re' Prudhoe Bay Unit 2-02A ,ARCO Alaska. Inc. Permit No. 97-168 Sur. Loc. 828: S & 1727' E ofNW cr. Sec. 36, TI IN. R14E. UM Btmnhole Loc. 3957'FNL & 559'FEL. Sec. 25. T1 IN, R14E. UM Dear Ms. Oba: 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 r on the North Slope pager at 659-3607. Chairman '~ ) BY ORDER OF T MMISSION dlffEnclosures 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 X lb. Type of Well Exploratory_ Stratigraphic Test_ Development Oil X__ Re-Entry__ Deepen _ Service_ Development Gas__ Single Zone X~ Multiple Zone_ 2. Name of Operator I 5.Datum Elevation (DF or KB) i 10. Field and Pool ARCO Alaska, Inc. I RKB 64' I 3. Address I 6. Properly Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28326 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 828' S & 1727' E of NW cr, Sec 36, T11N, R14E, UM. Prudhoe Bay Unit ' Statewide At top of productive interval 8. Well number Number t284' N & 724' E of SW cr, Sec 30, T11N, R15E, UM 2-02A, #U-630610 At total depth , 9. Approximate spud date I Amount (Proposed) ! 3957' FNL & 559' FEL, Sec 25, T11N, R14E, UM. , November, 1997 ,$200,000 12. Distance to nearest 13. Distance to nearest well ! 14. Number of acres in property I 15. Proposed depth (MD and TVD) property line I No Close Approach I 12870' MD / 8825' TVD 116. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10600' MD Maximum hole angle 90° Maximum surrac~ 2800 psig At total depth Ct'VD) 8825' i18. Casing program I Se, ing Depth Size SpecificationI Top Bottom I Quantity of cement Hole Casing Weight Grade Coupling Len~lth I MD I TVD ] MD I TVD I (include stalJe data) 4-1/2" 3-1/2" 9.3 L-80 FL4S 2900' I 9970'i 8092'I 12870' 8825' 30 bbls [ , 10. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11125 feet Plugs(measured) true vertical 9004 feetORIGIN/I,L Effective depth: measured 10945 feet Junk (measured) true vertical 8807 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 1464 20" 930 Sx Fondu 1464' 1 464' Surface 2627' 13-3/8" 242 Sx Fondu & 545 Sx Class G 2691' 2691' Production 11028' 9-5/8" 1680 Sx Class G 11092' 8913' Perforation depth: measured 10926 - 10952' true vertical 8793-8812' o~P0 1997 20. Attachments Filing fee X__ Property plat _ BOP Sketch X Diverter Sketch _ Drilling p~:~)~dt~ Drilling fluid program __ Time vs depth pict ~ Refraction analysis Seabed report 20 AAC 25.050 requirements_ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (~e_5'~o~-,,,,'~ ? %t~,J~ k,,.,Jo~--,,~" Signed ~AX~ "']4'1 · I~'~ Titlle Enoineedn~! Supervisor Date '~ --- a '" ¢ '7 - Commission Use Only Permit Number ~ ~ APl number '" C:)/' Approval date '¢ I See cover letter for 4:~_ ~,~2¢~' 50-O1.7-...¢- ~ ~(::3 ,~'~4' /~--'-c~-~'I other requirements Conditions of approval Samples required _Yes ,z~'No Mud Icg required _ Yes Hydrogen sulfide measures ~Yes _ No Directional survey required '~ Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M X 3500 psi for CTU Other: drlglrlal Signed By byorder of Approved by_ ~_ .n.~,:id W. J_nhnst.n.n Commissioner the commission Date Submit in triplicate DS 2-2A CT Sidetrack and Completion Intended Procedure Objective: Cut off existing 4-1/2" tubing tail Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 3-1/2" cemented liner. Perforate and produce. Intended Procedure: · Cut/mill off existing 4-1/2" tubing tail at -- 9918'md. · Cement squeeze and plugback the existing completion to - 10570 md. Mill window in 9-5/8" casing at -10600' md. Drill 10' of formation with 8.9 ppg Flopro fluid and perform Leak off test to 9.4 ppg. Directionally drill 4.5" x 2100' horizontal well to access Lower Romeo reserves. Build angle to -90° at TI). · Run and cement3-1/2" liner to TD. · Perforate selected intervals. · Place well on production. September 2, 1997 DS 2-2A Proposed CT Sidetrack Horizontal 5-1/2" Packer 9905' 2197' 9775' 5-1/2" RQM SSSV Nipple ID --- 4.562" 5-1/2" XA Sliding Sleeve ID = 4.562" TT Cut off @ 9918' Top of 3-1/2" Liner in 5-1/2" Tbg. tail. Initial Perfs- 1200' 9-5/8" shoe @ 11 Window cut in 9-5/8" at - 10600 - 10605' 4.5" Open hole Current perforations cement squeezed 3-1/2" liner TD @ - 12900' -"'~"" ""~ 2.02A REV. 0 AR~O 2-02A SI[SEYRACK Aug. 28, 1~97 Revision 0 ~ M0i Jnc. ' .... 6i'~ ..... igbi:PT~i VS ~.s ......... i~7:~ ............ ~&i~d ' ?%. Dog~ee: ASP Y ASP X C~ents It fl 8.'2~:97 2 31 P..*,/ .........................................105~J O0 42 ,8 DO 8465.40 19.50 . ............ ..... tg~0. b~ ...... 4250 7~'.d0 6531.70'! ..... -'~15~: ........ i762 ~: 47,~,., O "" -' ' "i6~'.c0 ..... ~";i'i' 7~ 6bi ~'~'id- ' -53 10~ ' ' 1767.~: 4747.~ .79 ~ .......... {~'~ 4778 ' 10880.00 ...... 35.981 46.44 ~J01 '70 i~0710 03 ..... -~?,,~l .... a~is'~ ....... 7~J6~'~JTo ....... -8'7.00'" 17~.~ 4789.~ '~"i6 ...... -~.3o ~.~ ' ' ', ..... ' .............. ~T ............................................ 5,~2.313 ~ 6~,217 ....... . ......... ' ' . ..................... · ...... .- .... .... .moo 10770.~: ~.18 5 63. 8873.50~ L91.30 '1~.50 ~2.10~ 9 1O~ ........ ~.~i~ ................... 26.~' ...... 5.9a2.~.00 :~ ~.229.~ ....... 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CK) -3.2C 3.20:5,952,606 50. 2113'~'J .... 45,',253 0'50 ...... .3~ .3 20 5957,827.3a 21295o 4548.93 O.00: -3.20 ] 20 5,952,§37'.50 2~2~4~0 ~i~.ii~c; 'O.o0: I I L'~'.~{~-'- 3 20 5,952,652.00 z' ~.~b -¥~§5;f ...... 8.o~ .... ~ ........... ,-)98 19 8795.3/3. 3;2.~0 2:74.00 '.~68.70 0 CO ~7.77 8795 30: 341.'0 2187 9C .'442 20 0.00. 9795 30 370.20 22'31 40 44!5 40 O.C~ 2o~'? ' -16.~0 .. 2600 s.~S2.s,io~fi ...... ~§i'i'~g:~ ............................................ 2050, -15.90 26100 5.952.545.50 693.111.50 4, LANDING PT. 3,1t~'!il30' DL TO I~ID PT. o~66' ...... :~-.~6 ............ ~i ~' '% ~S2.§57 so i~93,'~'.'~ .............. 693,oc~ .oo ~.018 4O; FT'~, .992 ?o ~.u~8o -3 20 3, 20 5952 6~=-,OD 692.914.10 .a.~ 3.zc' s .~z.~o ~. o~z,~? 4o' -3.20' 3 20 5.952, T00 2,3 6.92.~33 4C -3.20 3 20 5.952,7; 6.50 6~2,805 10 2 z-oz~ ,,s 2.02A REV. 0 ~,,m~7 ~ ~ ~,. ~ a~ d~: fl ~ ~ ~ ~n~ d*o~ ....... ~)q~6 ........ ~ ............ *fi" ...... 11 ~ 05 ~ O0 294 32 8"?~ ~ 429.~,. ~ 13 ~1 10: 0.~: -S.20 S ~ ~.~2 7~ 00': ~92 '~ ~E"T ............ : ~ *.~ ............................. ........ ~-~"~ ............ ~0.~ 29~.36 ~.~ .......... ~.~' ' 2239.23': ~3.70. C ~J' ~320 ~ 20:; 5.S~2.741 ~ ~50.~ .......... ~1~.~*~ ....... 90.~3' 2~2.3~ ~7~.~6 .......... ~8. t'O ' '~.'~ ....... ~ ............... ~:~ ............ :~';fd ......... 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[ ' : .................................................................................................. 7~.90 2334.~' ~.6~ O.~ -3.20 3.~ 5.952.~.50 ~2.~40 7~.90" 2341.~ ~20.~ 0 00 '" -~90 ........ 3.'~ ' '~.'~'2',8~.'~0' ' ' ~2.~ 00[ 28! 36 87~c~-3.30 ! 616 2~.aO 8795.30 ~ ...... b~ 901 e769oi "~.~6'" i~iooo~ .... ~o.o---o ....~8.87! S?g5 3o .... f~4~! ~06 .... 277.~! "':~79550 ~36.?o --i~.~ ........~o.~ .....~.53' a7~5.':o 94elo 11970(:;0 12DL~O0 2O30. 12120 O0 906.8O · 12180C0 12210 00' ~ 22?0 3o ;~3~;~:~J ...... :~i :~ ............. 0.00 -~.ZO 3.20 J-' '~:~52.846.~J~ ....... 69'2.37~J. b2: ......... 3932.!0 0 O0 -3 20: 3.20:5,~2 ~I ~69~,~.~:~ "~: ............... 3~.~ .......... 6:'~:" ' -j. ~ j ~.26" ~,~,~:~ ..... 8~Z,316.60 .............. ....................................... 3872 ~: ...... ~ .... o.~: :~ 3.20 ~j.~ o.~l ':s.~' ....... ~.~ "~.'~:.~'d. OT' e~.275.~ ~, ~OPT.~.~"n.o',,~C -' 275 20 87.(,5.40: 99620 ' Z~7~.O0 3813.20" .020 a984 273.77i 8795.50 '~- ..... 27~.~ .... sgr~'¥ ~Y~i~' ~795.7o 69.65J 26~45 8795.90; 1055.40 ?,364.70 1113.90 2~'F7, .40 3763.30 -C 20 23,79 O0 3753/-0 ' -~ 20 2379.80: 3723.40 -0 20: 2379.9~ i 36~3.40: -0 29; 2330 OG 2360.0,3 89.: 6 257 9z 8798.40 ! 339 ~ 2~..60 ~"~: CTj" JJ9 1 o :56 50 ..... 8'fgS: ~,~. ............ i'.366. ~ ...... ~7 00 24~ O0 89. ~4 :55 ~' E;79~ ~: ~ 392:~ ......... ~3g- ~0 -0 2'd' -4 80 4 80. 5 952.860 30: 692 017 40 89 4~: ~%"369 8796.92, ,r 228.70i 2372.70 3573 30 -0.20 G9 25 '" ~'~B~ ...... ~"~3 1284.70 ~364 ~: '~i~ ~ -0 ~ 8~.22 ~-.'~ ......~97.90 13~ 2 ~ 2359.~ ~4.70 :9 ~. ...... ~5.~ .0.26~ ..... 342~.~0 ~39~.9o -4.8~ 4.80: 5.952.856.50: .~1.967.60 -4 80' 4.80' 5.952 852.00 ~.8e 4.80 's:~;~ s4?.O0 : .0.20 -4.80 -C 20 -4 80 4 80 5.952.64' 50 691,~98DC - ............... :".'.. ::.'..'.': ..' .................................. 4E~- 5.952,82750 6D1,840.60 4.~0 5 952.8195C 6~.811 60 Z Ill 2-OZA REV. 0 9.'2.g.:97 2 3; PM I'--- I--- I--- o MD I~c.. Dir SS DEPIH :. V$ N;.$. .... L ............ !i. Li....L ...... ~.~:..'.' ........ ~ ........... ": .... , ........................ ,: ' ' E!'W ........... .B.u. !1~ .............. T..u? ........... D_..~)..I.e~ ........... .~.~.P....Y., ........... ASP X ..C,~ents ft dL.~!lO0 d~']O0 del~'lOO fl: . .... fl ...... 12480. ..... 12,515.~J' ...... 12540.~ 12~TO (I0 12600.00: ....... 12630.00 ............................. 1266O O0 8~,.60 ~' .... ~.~i~*i~- ............... t 2720. O0 &q 50 ........................ 12750.~ 88 ............ 126~.~' ................. 12~ 00 VER~CAL SECT~O~ ~[ .... ~ ..... . ....... 8799 8,3 1419.10'. 2331.50 3368.00 -0 20 -4.80 4 80; 5.952,811 .,3~ '~ 691,787.90 ...... 3310g0 -0.~.1: -480' ¢.~ 5:952. Z91.50 691,726 11:) 3:382 S0 -Q~-- ............ :4.1~! 4.~ 5,952.781 OO 6~i'.~ ! O' 3254 80 -e.20 ....... :4.~: ' ,180 5,952.769 50 69'..§70 3227.201 .~.:2-~ ........ -~:~(jT ............ '4:81~ .... ~:~I~. ~S7 Sb ~i' 7~ ''~' ~ i ............ ~ .................................................. ~'~.9o: -o.:~o ~.~ .......... ~.~ s.gu2,z~.so ~'9i NO~ ' ' ............... m .... ~ :Relative C3o,dlnates are off of'true NJ~[-,7'A-~-[~'F~i;;iive ic grid No~P eRi~'~[~GEN~'..- ~:1 ~' ] .... ~ ........... '~URFACE Y ............ ~5~394.67 ............................ · . . 'nE tPd X ~ ' .~-:-,~.2 TIE IN ¥ .............. ~ i¥"~ ~ ~ .... i : - · . . ...... .... : ......................................... ................................................................................................ o -1- Z Z .... L LI I I I I I I I I I IIIIIII =1, , I .... I I I I ARCO ALASKA INC 2-O2AT 2-[)2OR TR =1 &N~: ,O; "2ER- .'3E(~:Tn ~93 42- :~ELA-~VE 7'0 -RL~ N,ORTh~ _ "C T Drilling Wellhead Detail ~ CT Injector Head , .=.?~--~~ 7"StuffingRiser Box (Pack-Off), 10,000 psi Working Pressure Methanol Injection 45~ I_ Otis 7" WLA Quick I~ ' I Connect - I I Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool7-1/16", 5M by 7-1/16', 5M Ram Tvoe Dual Gate BOPE Manual bver Hydraulic 7-1/16" ID with PipeiSlip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-G/8" Annulus Shop Fuel Boilers Mu Tanks Water Pump Ext. I 60/40 i I TrplxI Pipe ra~/~ Fire Ext. Ext. Dowell Drilling I Equipment Trailer Preferred Major Equipment Layout for CT Drilling · WELL PERMIT CHECKLIST COMPANY //"-¢_~ WELL NAME ,~_Z~,,,'3,// ..~___-(:~2_~ FIELD & POOL ~ ¢--/'O,/,~' ~ INIT CLASS ~ /-' ,~.~ ? GEOL AREA .. PROGRAM: exp [] dev,,,~redrll,,,~'se~ [] wellbore seg EJ ann. disposal para req C U N IT# '///'~",~"'O ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool ................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 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 ........... ENGINEERING APPR DA)rE 14. Conductor string provided ................... Y N) ~ 15. Surface casing protects all known USDWs ........... Y N i A ~- · 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N N/ 17. CMT vol adequate to tie-in long string to surf csg ........ (~"~ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. N 21. Ifa re-drill, has a l0-403 for abandonment been approved. . . ,~Y N IA""~~ 22. Adequate wellbore separation proposed ............. ~ N 23. If diverter required, does it meet regulations .......... ~ 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation .... :.__. ,~, ......... N 26. BOPE press rating appropriate; test to ~,~r-O psig. ~:)~_.~ . 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. REMARKS GEOLOGY ,~,,~R D/~,TE/ 30. Permit can be issued w/o hydrogen sulfide measures ..... ~Y I~,'"',,/,~,j7"-//'7 31. Data presented on potential overpressure zones ........ 32. Seismic analysis of shallow gas zones .............. -- ~ 33. Seabed condition survey (if off-shore) ............ .// Y N 34. Contact name/phone for we,ekly,pro~ress re@qrts ..... /. Y N lexp/ora~ory on/y] / GEOLOGY: ENGINEERING: COMMISSION: JDH ~ R N C_~____~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist re,,' 07~97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Aug 30 11:06:42 1999 Reel Header Service name ............. LISTPE Date ..................... 99/08/30 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/08/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNB/~OWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: D.S. 2-02A PB1 500292007470 ARCO ALASKA, INC SPERRY-SUN DRILLING SERVICES 30-AUG-99 MWD RUN 1 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 2 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 4 AK-MW-80098 A. WORTHINGT GARY GOODRIC JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 8 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 9 AK-MW-80098 A. WORTHINGT A. BASS JOB NUMBER: LOGGING ENGINEER: MWD RUN 10 AK-MW-80098 A. WORTHINGT MWD RUN 11 AK-MW-80098 A. WORTHINGT MWD RUN 12 AK-MW-80098 A. WORTHINGT OPERATOR WITNESS: A. BASS A. BASS A. BASS 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 MWD RUN 13 AK-MW-80098 A. WORTHINGT A. BASS MWD RUN 14 AK-MW-80098 A. WORTHINGT A. BASS liN 14E 828 1727 64.00 .00 .00 MWD RUN 15 AK-MW-80098 A. WORTHINGT A. BASS SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 10612.0 PRODUCTION STRING 3.750 11844.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 1-15 ARE DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. MWD RUNS 3, 5, AND 6 MADE NO FOOTAGE AND ARE NOT PRESENTED. 5. DIGITAL MWD DATA IS SHIFTED TO THE FDN GR OF 07/21/70. A PDC LOG MAY BE RUN SUSEQUENT TO PROCESSING THIS DATA. 6. MWD RUNS 1,2,4,AND 7-15 REPRESENT WELL 2-02APB1 WITH API#: 50-029-20074-70 THIS WELL REACHED A TOTAL DEPTH (TD) OF 11844'MD, 8787'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. Comment Record FILE HEAl)ER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10488.5 11819.0 ROP 10513.0 11848.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 10488 5 10488 0 10489 5 10489 0 10491 0 10490 5 10492 0 10491 5 10508 5 10508 5 10515 10531 10544 10549 10589 10596 11848 $ 10514 5 10529 5 10543 0 10545 5 10585 5 10593 0 11844 5 BIT RUN NO MERGE TOP EQUIVALENT UNSHIFTED DEPTH -- MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 4 MWD 7 MWD 8 MWD 9 MWD 10 MWD 11 MWD 12 MWD 13 MWD 14 MWD 15 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record 10512 0 10607 0 10615 0 10618 0 10629 0 10760 0 11105 0 11303 0 11391 0 11641 0 11728 0 11811 0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined MERGE BASE 10607 0 10615 0 10618 0 10629 0 10760 0 11105 0 11303 0 11391 0 11641 0 11728 0 11811 0 11844 0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT PT 4 1 68 0 1 ROP MWD FT~H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10488.5 11848 11168.2 2720 10488.5 ROP 0.22 4708.19 131.706 2671 10513 GR 0 414.85 65.6715 2608 10488.5 Last Reading 11848 11848 11819 First Reading For Entire File .......... 10488.5 Last Reading For Entire File ........... 11848 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10488.0 10582.5 ROP 10512.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ 10606.5 NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 19-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10607.0 10512.0 10607.0 42.5 42.5 TOOL NUMBER NGP SPC 258 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10488 10606.5 10547.2 238 10488 GR 17.92 26.96 21.4732 190 10488 ROP 12.81 85.73 33.9056 189 10512.5 Last Reading 10606.5 10582.5 10606.5 First Reading For Entire File .......... 10488 Last Reading For Entire File ........... 10606.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3tW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10583.5 10591.5 ROP 10607.0 10614.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 19-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10615.0 10607.0 10615.0 42.5 42.5 TOOL NUMBER NGP SPC 258 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10583.5 10614 10598.8 62 10583.5 GR 22.88 24.79 23.7047 17 10583.5 ROP 0.22 56.43 17.3333 15 10607 Last Reading 10614 10591.5 10614 First Reading For Entire File .......... 10583.5 Last Reading For Entire File ........... 10614 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10450.0 10593.0 ROP 10614.5 10618.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 20 -JAN- 98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10618.0 10615.0 10618.0 42.5 42.5 TOOL NUMBER NGP SPC 302 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10450 10618 10534 337 10450 GR 20.53 26.33 23.4136 73 10450 ROP 17.78 575.35 126.517 8 10614.5 Last Reading 10618 10593 10618 First Reading For Entire File .......... 10450 Last Reading For Entire File ........... 10618 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10586.5 10601.0 ROP 10618 . 5 10626 . 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 21-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10629.0 10618.0 10629.0 .0 .0 TOOL NUMBER NGP SPC 302 4.250 4.3 FLO-PRO 9.50 .0 9.0 .0 .000 .000 .000 .000 .0 .3 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10586.5 10626.5 10606.5 81 10586.5 GR 23.53 40.4 28.2338 30 10586.5 ROP 10.78 34.66 23.33 17 10618.5 Last Reading 10626.5 10601 10626.5 First Reading For Entire File .......... 10586.5 Last Reading For Entire File ........... 10626.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10608.0 10732.5 ROP 10627.0 10759.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 22-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10760.0 10629.0 10760.0 46.1 49.5 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 9.40 .0 10.0 .0 .000 .000 .000 .000 70.5 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10608 10759.5 10683.8 304 10608 GR 25.52 79.07 38.9743 250 10608 ROP 10.84 1048.19 80.4741 266 10627 Last Reading 10759.5 10732.5 10759.5 First Reading For Entire File .......... 10608 Last Reading For Entire File ........... 10759.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NTJMBER: 7 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10661.5 11077.5 ROP 10760.0 11104.5 $ LOG HEADER DATA DATE LOGGED: 22-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NAT~ GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11105.0 10760.0 11105.0 51.1 75.8 TOOL NUMBER NGP SPC 302 3.800 3.8 FLO-PRO 9.50 .0 10.0 .0 .000 .000 .000 .000 70.5 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10661.5 11104.5 10883 887 10661.5 GR 21.8 129.3 43.5802 727 10661.5 ROP 16.93 2606.2 101.063 690 10760 Last Reading 11104.5 11077.5 11104.5 First Reading For Entire File .......... 10661.5 Last Reading For Entire File ........... 11104.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10945.0 11274.5 ROP 11105.0 11303.5 $ LOG HEADER DATA DATE LOGGED: 23-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11303.0 11105.0 11303.0 80.3 91.1 TOOL NUMBER PCG 76 4.250 4.3 FLO-PRO 9.50 .0 9.0 .0 .000 .000 .000 .000 65.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 10 API 4 1 68 ROP MWD 10 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 10945 11303.5 11124.2 718 GR 31.58 261.52 85.3892 520 ROP 17.28 2188.33 110.611 398 First Reading 10945 10945 11105 Last Reading 11303.5 11274.5 11303.5 First Reading For Entire File .......... 10945 Last Reading For Entire File ........... 11303.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10646.5 11362.0 ROP 11304.0 11391.0 $ LOG HEADER DATA DATE LOGGED: 24-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 NGP 5.74, DEP 2.042 MEMORY 11391.0 11303.0 11391.0 86.1 89.6 TOOL NUMBER PCG 76 3.750 3.8 FLO-PRO 9.50 .0 8.5 .0 .000 .000 .000 .000 65.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 API 4 1 68 ROP MWD 11 FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 10646.5 11391 11018.8 1490 GR 30 178.25 71.9899 365 ROP 26.37 482.47 94.6555 175 First Last Reading Reading 10646.5 11391 10646.5 11362 11304 11391 First Reading For Entire File .......... 10646.5 Last Reading For Entire File ........... 11391 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11368.0 11614.0 ROP 11391.5 11641.0 $ LOG HEADER DATA DATE LOGGED: 25-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: MSC 1.32 NGP 5.74, DEP 2.042 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 11641.0 11391.0 11641.0 85.6 91.3 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 9.50 .0 9.0 6.5 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 API 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11368 11641 11504.5 547 GR 24.25 151.01 81.8922 493 ROP 36.88 1302.61 100.404 500 First Last Reading Reading 11368 11641 11368 11614 11391.5 11641 First Reading For Entire File .......... 11368 Last Reading For Entire File ........... 11641 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11626.5 11701.0 ROP 11641.5 11728.0 $ LOG HEADER DATA DATE LOGGED: 25-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MSC 1.32 NGP 5.74, DEP 2.042 MEMORY TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NAT~ GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAi~DOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11728.0 11641.0 11728.0 90.5 91.4 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 9.40 .0 8.5 6.5 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 API 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11626.5 11728 11677.2 204 GR 0 142.29 83.9575 150 ROP 24.73 4708.19 651.189 174 First Last Reading Reading 11626.5 11728 11626.5 11701 11641.5 11728 First Reading For Entire File .......... 11626.5 Last Reading For Entire File ........... 11728 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NLIMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11701.5 11779.5 ROP 11728.5 11809.0 $ LOG HEADER DATA DATE LOGGED: 26-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11811.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP_ATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11728.0 11811.0 89.7 89.7 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 9.50 .0 9.0 .0 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 API 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 11701.5 11809 11755.2 216 11701.5 11809 GR 15.4 151.01 97.9489 127 11701.5 11779.5 ROP 23.32 2054.7 131.536 162 11728.5 11809 First Reading For Entire File .......... 11701.5 Last Reading For Entire File ........... 11809 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11780.0 11815.5 ROP 11809.5 11844.5 $ LOG HEADER DATA DATE LOGGED: 26-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11844.0 11811.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPER3~TURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11844.0 92.1 96.8 TOOL NUMBER NGP SPC 74 3.750 3.8 FLO-PRO 9.50 .0 9.5 .0 .000 .000 .000 .000 58.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 API 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11780 11844.5 11812.2 130 GR 78.99 414.85 147.29 72 ROP 16.91 840 96.6234 71 First Reading 11780 11780 11809.5 Last Reading 11844.5 11815.5 11844.5 First Reading For Entire File .......... 11780 Last Reading For Entire File ........... 11844.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/08/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/08/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 31 09:27:06 1999 Reel Header Service name ............. LISTPE Date ..................... 99/08/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/08/31 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Date A ka. Oil & C-,-ms C, ommiml DS 2- 024 500292007401 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 31-AUG-99 MWD RUN 1 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 2 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 4 AK-MW-80098 A. WORTHINGT GARY GOODRIC JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 8 AK-MW-80098 A. WORTHINGT GARY GOODRIC MWD RUN 9 AK-MW-80098 A. WORTHINGT A. BASS JOB NUMBER: LOGGING ENGINEER: MWD RUN 10 AK-MW-80098 A. WORTHINGT MWD RUN 16 AK-MW-80098 W. JACKSON MWD RUN 17 AK-MW-80098 W. JACKSON OPERATOR WITNESS: A. BASS A. BASS A. BASS 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 MWD RUN 18 AK-MW-80098 W.JACKSON A. BASS MWD RUN 19 AK-MW-80098 W. JACKSON A. BASS 36 liN 014 828 1727 64.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.675 10612.0 3RD STRING 3.500 12309.0 PRODUCTION STRING 3.750 12309.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 1-19 ARE DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. MWD RUNS 3, 5, AND 6 MADE NO FOOTAGE AND ARE NOT PRESENTED. 5. THIS WELL KICKS OFF FROM 2-02A PB1 AT ll133'MD, 8780'SSTVD IN THE RUN 10 INTERVAL OF THAT WELL. 5. DIGITAL MWD DATA IS SHIFTED TO THE FDN GR OF 07/21/70. A PDC LOG MAY BE RUN SUSEQUENT TO PROCESSING THIS DATA. 6. MWD RUNS 1,2,4,7,8-10,16-19 REPRESENT WELL 2-02A WITH API~: 50-029-20074-01 THIS WELL REACHED A TOTAL DEPTH (TD) OF 12309'MD, 8784'SSTVD. SROP = SMOOTHED HATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH' GR 10488.5 12282.0 ROP 10513.0 12300.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10488.5 10489.5 10491.0 10492.0 10504.0 10507.5 10508 5 10515 0 10516 0 10531 0 10544 5 10546 0 10549 0 10554 0 10589 5 10596 0 12311 0 $ GR 10488 0 10489 0 10490 5 10491 5 10504 5 10507 0 10508 5 10514 5 10516 0 10529 5 10543.0 10544 5 10545 5 10551 0 10585 5 10593 0 12308 0 MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 4 MWD 7 MWD 8 MWD 9 MWD 10 MWD 16 MWD 17 MWD 18 MWD 19 $ REMARKS: MERGED MAIN PASS. $ EQUIVALENT UNSHIFTED DEPTH -- BIT RUN NO MERGE TOP 10512 0' 10607 0 10615 0 10618 0 10629 0 10760 0 11105 0 11133 0 11310 0 11700 0 11880 0 MERGE BASE 10607 0 10615 0 10618 0 10629 0 10760 0 11105 0 11133 0 11310 0 11700 0 11880 0 12309 0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT~H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10488.5 12311 11399.8 3646 10488.5 ROP 0.22 2606.2 93.5159 3597 10513 GR 18.92 188.76 55.175 3588 10488.5 Last Reading 12311 12311 12282 First Reading For Entire File .......... 10488.5 Last Reading For Entire File ........... 12311 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10488.0 ROP 10512.5 $~ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10582.5 10606.5 19-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10607.0 10512.0 10607.0 42.5 42.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 258 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.800 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEFT 10488 10606.5 10547.2 238 10488 GR 17.92 26.96 21.4732 190 10488 ROP 12.81 85.73 33.9056 189 10512.5 Last Reading 10606.5 10582.5 10606.5 First Reading For Entire File .......... 10488 Last Reading For Entire File ........... 10606.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10583.5 ROP 10607.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH' 10591.5 10614.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record 19-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10615.0 10607.0 10615.0 42.5 42.5 TOOL NUMBER NGP SPC 258 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10583.5 10614 10598.8 62 10583.5 GR 22.88 24.79 23.7047 17 10583.5 ROP 0.22 56.43 17.3333 15 10607 Last Reading 10614 10591.5 10614 First Reading For Entire File .......... 10583.5 Last Reading For Entire File ........... 10614 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10411.5 ROP 10614.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10593.0 10618.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AN/] CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3~TURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 20-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10618.0 10615.0 10618.0 42.5 42.5 TOOL NUMBER NGP SPC 302 3.800 3.8 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 10411.5 10618 10514.8 414 GR 20.53 28.52 23.6465 81 ROP 17.78 575.35 126.517 8 First Reading 10411.5 10411.5 10614.5 Last Reading 10618 10593 10618 First Reading For Entire File .......... 10411.5 Last Reading For Entire File ........... 10618 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10586.5 ROP 10618.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10601.0 10626.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 21-JA/~- 98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10629.0 10618.0 10629.0 .0 .0 TOOL NLIMBER NGP SPC 302 .250 4.3 FLO-PRO 9.50 .0 9.0 .0 .000 .000 .000 .000 77.3 .3 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10586.5 10626.5 10606.5 81 10586.5 GR 23.53 40.4 28.2338 30 10586.5 ROP 10.78 34.66 23.33 17 10618.5 Last Reading 10626.5 10601 10626.5 First Reading For Entire File .......... 10586.5 Last Reading For Entire File ........... 10626.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMM3LRY VENDOR TOOL CODE START DEPTH GR 10608.0 ROP 10627.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10732.5 10759.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 22-J~N-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 10760.0 10629.0 10760.0 46.1 49.5 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 9.40 .0 10.0 .0 .000 .000 .000 .000 70.5 .3 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10608 10759.5 10683.8 304 10608 GR 25.52 79.07 38.9743 250 10608 ROP 10.84 1048.19 80.4741 266 10627 Last Reading 10759.5 10732.5 10759.5 First Reading For Entire File .......... 10608 Last Reading For Entire File ........... 10759.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10661.5 ROP 10760.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11077.5 11104.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3~TURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 22-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11105.0 10760.0 11105.0 51.1 75.8 TOOL NUMBER NGP SPC 302 3.800 3.8 FLO-PRO 9.50 .0 10.0 .0 .000 .000 .000 .000 70.5 .3 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10661.5 11104.5 10883 887 10661.5 GR 21.8 129.3 43.5802 727 10661~5 ROP 16.93 2606.2 101.063 690 10760 Last Reading 11104.5 11077.5 11104.5 First Reading For Entire File .......... 10661.5 Last Reading For Entire File ........... 11104.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11078.5 ROP 11105.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 11133.0 11133.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUPJLL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/qDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 23-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11303.0 11105.0 11303.0 80.3 91.1 TOOL NUMBER PCG 76 4.250 4.3 FLO-PRO 9.50 .0 9.0 .0 .000 .000 .000 .000 65.9 .3 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 API 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11078.5 11133 11105.8 110 11078.5 GR 51.86 108.58 75.4162 110 11078.5 ROP 19.78 117.95 52.8718 57 11105 Last Reading 11133 11133 11133 First Reading For Entire File .......... 11078.5 Last Reading For Entire File ........... 11133 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11133.5 11276.0 ROP 11133.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ 11303.5 NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3ITURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .lin 28 -JAN- 98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11310.0 11135.0 11310.0 84.4 91.2 TOOL NI/MBER PCG 74 3.750 3.8 FLO-PRO 9.50 .0 10.5 .0 .000 .000 .000 .000 56.2 .3 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 API 4 1 68 4 2 ROP MWD 16 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11133.5 11303.5 11218.5 341 11133.5 GR 35.06 175.34 59.4508 286 11133.5 ROP 10.22 474.85 91.4719 341 11133.5 Last Reading 11303.5 11276 11303.5 First Reading For Entire File .......... 11133.5 Last Reading For Entire File ........... 11303.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 P_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11276.5 ROP 11308.0 STOP DEPTH 11671.0 11700.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 29-JAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11700.0 11310.0 11700.0 87.1 94.0 TOOL NUMBER PCG 74 3.750 3.8 FLO-PRO 9.50 .0 9.0 6.3 .000 .000 .000 .000 60.9 .3 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 17 API 4 1 68 4 2 ROP MWD 17 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11276.5 11700 11488.2 848 11276.5 GR 38.76 177.94 73.9751 790 11276.5 ROP 12.73 1671.22 93.2155 785 11308 Last Reading 11700 11671 11700 First Reading For Entire File .......... 11276.5 Last Reading For Entire File ........... 11700 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 18 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11671.5 11851.5 ROP 11706.0 11878.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NAT~ GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAlqDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 30-jAN-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 11880.0 11700.0 11880.0 11727.0 11857.0 TOOL NUMBER PCG 76 3.750 3.8 FLO-PRO 9.50 .0 9.0 6.0 .000 .000 .000 .000 63.3 .3 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 18 API 4 1 68 4 2 ROP MWD 18 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11671.5 11878 11774.8 414 11671.5 GR 30.56 181.23 47.4059 361 11671.5 ROP 18 1029.91 96.1192 345 11706 Last Reading 11878 11851.5 11878 First Reading For Entire File .......... 11671.5 Last Reading For Entire File ........... 11878 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 19 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11852.0 12279.0 ROP 11878.5 12300.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 01-FEB-98 MSC 1.32 NGP 5.74, DEP 2.042 MEMORY 12309.0 11880.0 12309.0 83.7 95.9 TOOL NUMBER PCG 76 3.750 3.8 FLO-PRO 9.50 .0 9.2 6.4 .000 .000 .000 .000 63.3 .3 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 19 API 4 1 68 4 2 ROP MWD 19 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam ,Reading DEPT 11852 12308 12080 913 11852 GR 33.7 188.76 60.1316 855 11852 ROP 8.16 691.57 100.919 860 11878.5 Last Reading 12308 12279 12308 First Reading For Entire File .......... 11852 Last Reading For Entire File ........... 12308 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/08/31 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/08/31 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKI~OWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/08/31 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
