Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout207-048STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Is, Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® • Suspended ❑ 20AAC 25.105 20AAC 25.110 [I WIN! ❑ WAG ❑ WDSPL ❑ No, of Completions: Zero 1b. Well Class: c Development ® Exploratory EIGIN! Service ❑ Stretigraphic Teat ❑ 2. Operator Name: 6. Date Comp., Susp., orAband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 12/3/2019 207-040 • 319-226 3. Address: 7, Date Spudded: 15. API Number. P.O. Box 196812 Anchorage, AK 99518.8812 12/23/2008 50.029-20078-02-00 ' 4a. Location of Well (Govemmental Section): 8. Date TO Reached- 16. Well Name and Number: 1/13/2009 PBU 0145B Surface: 47W FSL, 3856' FEL, Sec. D8, TiON, RISE, UM r g Ref Elevations KB 67.80 17. FieldrPool(s): Top of Productive Interval: 1535' FSL, 577' FEL, Sec. 08, T10N, RISE, UM GL 39.30 • BF Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 41' FNL, 2905' FV&, Sec. 16, TION, RISE, UM 10, Plug Back Depth(MD/TVD): Surface f Surface 18, Property Designation: Z AOL 028329, 2 028331. (- 4b- 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/fVD): 19, DNR Approval Number. Surface: x- 698749 y- 5940379 Zone - ASP 4 - 14296'19712' - 79-179 TPI: x- 702122 y- 5937268 Zone- ASP 12. SSSV Depth(MD/TVD): 20 Thickness of Pamre#oat MD/rVD: Total Depth: x-705650 y- 5935788 Zone- ASP None 1900'(Approx.) 5. Directional or Inclination Surrey: Yes ❑ (attached) No m 13. Water Depth, B Offshore: 21. Re A11/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (B MSL) MDrrVO: - 4690' / 4434' - 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, fomlatiion tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record, Acronyms may be used. Attach a separate page if necessary DIR/GR/RES /PWD, DIR/GR/ABI RES I NEU/DEN, AZI DENS 23' CASING, LINER AND CEMENTING RECORD CASING Wr. PER Fr. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 30'• 157.5# a Surface 111' Surface 111' 39" 20" 94#/133 H40nc-55 Surface 1210' Surface 1210' 26" Fondu to Surface 13-3/8" 72# N-00 Surface 2704' Surface 2704' 17-1/7 950 ax Fond. 9-5/8" 471940# Ld0/500.95 Surface 46g0' Surface 4434' 12-114": 1175 sx Class 'G', 448 sx AS 7" 26# L -e0 Sudace 10381' Surface 11853' B-1/2" 547 sx UleCreth, 169 sz Cleaa'G•, 179 ex Claes'G' 4-1/2" 12 ti# t3creo 10217' 14282' 8550' 8712' &1/8" Unmmented Slotted Liner 24. Open to production or injection? Yes ❑ No ® 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER BET (MDliVD) 4-1/712.60 13Cr80 10223' 10147'18506' 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC, ��A��bp,�gArK�.O+yAr�1y h OVK:lzl.lCJn� D¢ (2 r zaq Was hydmulicfmctudng used during completion? Yes ❑ No El Per 20 AAC 25.283 (1)(2) attach eleclronk: and printed Information DEPTHINfTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED See Attached 27 PRODUCTION TEST Data First Production: Not on Production Method of Operation (Flowing, Sae IHI, etc.): WA Data MTest:Production Hours Tested: for Teel Period OII-IIIA. Gae-MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press Caelnp Areca: I Calculated 24 Hour Rab y Oil -Bbl: Gas.MCF: Webr--Bbl: Oil GreviN-API (cord: Foran 10.407 Revised 5/2017 CONTINUED ON PAGE 2 Subma ORIGINAL ony Ka-P,caa�,D 9BDMSW^1 JAN 2 7 2020 IC -1 28. CORE DATA Conventional Corefs) Yes ❑ No ® Sidewall Cores Yes ❑ No 2 , If Yes to either question, list formations and intervals cared (MD+TVD of top and bottom of each), and summarize Ilthology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips. photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost -Top Well Tested? Yes ❑ No m Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive: Interval 10384' 8587' separate sheets to this form, If needed, and submit detailed test information par 20 AAC 25.071. Ugnu 5093' 4732' West Bak 69746157' Colville Mudstone 7678' 6693' HRZ 9746' 8256' Base of HRZ 10085' 8467' LCU / Kingak 10128' 8494' Sag River 10384' 8655' Shublik 10434' 8684' Sag River (Invert) 12683' 8688' Formation at total depth: Seg River (From Bess) 12683' 8888' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, par 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Authorized Name: Lestufka, Joseph N Contact Name: Worthington, Area Authorized Title: SI pecialis Contact Email: Ams.Worthinton@BP.mm Authorized Signature: I M I I Dam: 1 & Contact Phone: +1 907 5644102 INSTRUCTIONS General: This form is cl lgned for submitting a complete and correct Well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design Is changed All laboratory analytical reports regarding samples Of tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item to 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-Altemeting-Gas Injection, Sag 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), m state in item 1, and in Rem 23 show the producing Intervals for only the interval reported In Item 25. (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 LIR, 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 desalption in this box. Submit detailed deso ipllon 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 dally well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, produc0on or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WELL NAME: 01-05B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 2500'- 2510' Punch Tubing 2261' 111 Bbls Class'G' 1489'- 1492' Punch Tubing 966' 49 Bbls Class'G' 950'- 960' Perforate Tubing & Casing 250'- 260' Perforate Tubing & Casing 909' Set Cement Retainer Surface 36 Bbls Class'G' TWO = Vac/190Nac. Temp = SI. WHPs (WIE request). No wellhouse or flowline. Dry hole tree. Rig scaffold around well. IAP increased 10 psi since 5/2/19. 5/16/2019 SV, MV = C. IA, OA = OTG. 03:40 T/1/0= Vac/190Nac. Temp = SI. WHPs (WIE request), No wellhouse, flowline or AL. Dryhole tree installed. Rig scaffolding installed. No change in the WHPs since 5-16-19. 5130/2019 SV, MV = C, IA, OA = OTG. 15:00 TWO =VAC/190NAC. Temp = SI. WHPs (WIE request). Dryhole tree installed. Wellhouse & scaffold removed. WHPs unchanged from 5/30/19. 6/14/2019 SV, MV = C. IA, OA = OTG. 15:00 TWO = ??/180Nac. Temp = SI. WHP's. (WIE request). Well house, flow line & scaffold removed, no access to tree cap. Dry hole tree. No change in IAP or OAP since 6-14-19. 6/29/2019 SV, MV = C. IA, OA = OTG. 14:50 T/1/0=0/150/0. Pre P&A. RD IA, IA companion Flange and OA. RU integral flanges on both sides of IA and on OA. Torqued to API soecs. 188 FT/LBS. Install block valves and 1502 6/30/2019 caps with jewelry. ***JOB COMPLETE*** See log for details. Final WHP's 0/0/0. ***WELL SHUT IN ON ARRIVAL"*" PERFORATE INTERVAL 2500'-2510', W/ 3-1/8", 10 SPF, MIRAGE, 36 DEG PHASED CCL TO TOP SHOT = 16.7, CCL STOP DEPTH = 2483.3'. CONFIRM T-IA-OA COMMUNICATION LOG TIED INTO TUBING TALLEY DATED 01/16/09 7/7/2019 *** JOB COMPLETE, READY FOR FULLBORE *** SLB Fullbore Pumping Crew. Job Scope: Plug & Abandonment cement down 4-1/2" tbg & up OA/IA to surface. LRS pumped 5 bbls 50/50, 50 bbls of surfactant down the TBG taking returns from the OA to OTT. Shut down for 1 hr then followed with 94 bbls of 9.8 ppg NaCl. SLB pumped 5 bbls FW spacer, 111 bbls 15.8 ppg Class G cement taking returns from OA. Swapped to start take returns from the IA but IA locked up. Attempted to get cement moving but unsuccessful. Cut cement and pumped 2 bbls of FW. Launched 6" foam wiper ball down TBG. LRS displaced CMT with 33 bbls 9.8 ppg NaCL and 2 bbls 50150 LRS flush surface lines to OOT. Job Incomplete" 15.8 ppg Class G Cement 7/8/2019 Cement in OA: 9025' MD to surface 2Saa Le, o" %m'Ia T/1/0= 0/601260. Temp=Sl Assist Cement Pumpers (PLUG AND ABANDONMENT). Bled the OA to OTT (gas plus 20 bbis of fluid). Pumped 50 bbls of 150* F surfactant into the TBG while taking OA returns to OTT (50 bbls of returns). Pumped 94 bbls of 9.8 ppg NaCl down the TBG while taking OA returns to OTT (94 bbls of returns). Standby while SLB pumps cement. Drop the ball. Pump 33 bbls of NaCl and 2 bble of 50/50 McOH behind the ball. Pumped 38 bbls FW to flush CT and dead legs. DSO notified of well status per LRS 7/8/2019 departure. SV,WV,SSV=C MV=O IA,OA=OTG TWO = ?/20Nac. Temp = SI. WHPs (WIE Req). Well houuse, flow line —&scaffold removed, no access to tree cap. Dry hole tree. 7/25/2019 SV, MV = C. IA, OA = OTG. 15:00 *"WELL SHUT-IN ON ARRIVAL*** (SLB E-LINE TUBING PUNCH) INITIAL T/I/O = 8/8/2019 RIG UP, PT LUBRICATOR TO Daily Report of Well Operations PBU 01-05B **"WELL SJI ON ARRIVAL*** TAG TOC AT 2261' PUNCH TUBING 1489' - 1492' WITH TITAN 2" CIR-210 50 HMX, 4 SPF, 0 DEG PHASING 8/10/2019 CONFIRM TAA COMMUNICATION T11/O = 20/60Nac. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. IAP increased 40 psi since 07/25/19. 8/11/2019 SV, MV = C. IA, OA = OTG. 03:30 SLB Fullbore pumping crew Objective: Plug and Abandon TAX MI/RU/PT LRS and SLB cementers. Pumped the following down TBG with IA returns to OTT: LRS Pumped 2 bbls 50/50 to verify circulation. SLB Pumped 2 bbls FW spacer, 49 bbls 15.8 ppg class G CMT, 2 bbls FW spacer, drop 7" foam ball, displaced with 15 bbls 9.8 ppg NaCl, verified clean cement returns. SV/MV/QTR turns = C, IA/OA = OTG. DSO notified "Continued on 08/14/19 WSR** 15.8 ppg class G cement TBG TOC = 1 100'MD 11100' TVD 8/13/2019IA TOC = surface T/I/0= 0/0/0 Temp= 9/1 (Assist Schlumberger Cement Crew w/ Plug & Abandon) Pumped 1.5 bbls 50/50 down TBG, through perfs, up IA, then taking returns to open top 8/13/2019 tank to confirm flowpath for cement crew. ***WSR continued on 08-14-19*** "Continued from 08/13/19 WSR** SLB Fullbore pumping crew Objective: Plug and Abandon Tx1A SLB finished equipment wash up. LRS finished flushing choke trailer. Release WS 8/14/2019 equipment. Order grease service. **Job Complete"* ***WSR continued from 08-13-19*** (Assist Schlumberger Cement Crew w/ Plug & Abandon) Flushed cement and freeze protected surface lines with 10 bbls 50/50 meth/water. Cement crew in control of well upon LRS departure. All hardline and tubing valves closed, Annulus 8/14/2019 valves open to gauges. "*WELL SHUT IN ON ARRIVAL*** TAG TOP OF CEMENT AT 966' ELMD. PERFORATE 950'-960' ELMD WITH 2.875" MAXFORCE, 60 DEG PHASE, 6 SPF. PERFORATE 250'-260' ELMD WITH 2.875" MAXFORCE, 60 DEG PHASE, 6 SPF. 8/15/2019 ***CONT ON 8/16/2019 WSR*** CTU#8 1.75" CT. Job Scope: P&A MIRU CTU. Perform Weekly BOP Test. 8/16/2019 ***job coninued on 8/17119** T/l/O= 0/0/0/0 (LRS Unit 46 - Assist Coiled Tubing: Heat & Pump Fluids) Road unit to 8/16/2019 location. Standby for CTU. *** WSR continued on 08117/19 *"CONT FROM 8/15/2019 WSR*** SET BAKER HUGHES 4.5" CAST IRON CEMENT RETAINER MID ELEMENT AT 910' ELMD (TOP OF RETAINER AT 909' ELM). 8/16/2019 ***JOB COMPLETE, WELL TURNED OVER TO DSO*** ***WSR continued from 08/17/19*** (LRS Unit 46 - Assist Coiled Tubing: Hot Fluids) Pumped 5 bbl meth spear down Coil to establish a base line rate and psi.. Pumped a total of 103 bbls diesel in attempt to establish an injectivity rate. (SEE LOG FOR DETAIL). CTU still on well at LRS departure. 8/17/2019 FWHP= 0/CTU/CTU/CTU/CTU Daily Report of Well Operations PBU 01-05B CTU#8 1.75" CT. Job Scope: P&A MU BKR Cement stinger. Stung in to cement retainer @ 867' CTM. Appear to have some communication into OOOA. Attempt to establish circulation keeping Coil pressure below - 1000psi to prevent overpressuring the OOOA. Get -6 bbls of Antic Pack returns then OOOA plugged up. Return Micromotion had gone up to-17ppg. Unable to pump hard enough to push out OOOA Artic pack - limited on OOOA rating. Cycle pressures to try and get communication. After multiple attempts to establish communication, while attempting to pressure up down backside was able to pump freely. 1 bpm @ 175psi. Appears Surface Csg has lost integrity. Still unable to circulate thru retainer pumping down Coil. Discuss with APE. Pressure up to 1200psi down Coil, no circulation into OOOA. Unsting & circulate hot diesel to stinger ( got 1:1 returns). Sting back into retainer & attempt to sqz hot diesel into COCA. Able to circulate into OOOA at - 0.2 - 0.3 bpm at 1200psi. Cycle pressures trying to get diesel into OOOA. Attempt again to pump down backside and is pressuring up to 1000psi - suspect arctic pack is plugging up circulation path. Quit making any progress pumping into OOOA. Unsting from retainer. Circulate Surfactant Wash & 9.8ppg Brine to surface in Tbg. 8/17/2019 CTU#8 1.75" CT. Job Scope: P&A RIH w/BKR Cement stinger, cementers on line w/15.8ppg cement, stung in to cement retainer @ 867' CTM. Attempt to pump out through OOOA, no luck OOOA pressures & locks up, saw no returns. Unstung PUH laying in 15.8 ppg cement. Park at 200' and close choke. Push - 2.5 bbls behind pipe into SC -Leak to get a 1000psi bump. Open choke & continue laying in cement to surface. Close lower tree gate valve on cement. Displace coil to tanks and cleanout down to the closed lower gate valve. Install JSN and Jet Lub/BOP's/Tree. Rig Down CTU. Instruct Well Support to suck out water from tree down to lower gate valve. ***TOC in Tbg @ Surface*** ""Note - Well has SC -Leak. Estimate - 2.5 bbls of cement was pumped into OOOA'"* 8/18/2019 TWO = 30Nac/60. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. TP increased 10 psi, IAP decreased 60 psi to a Vac and OAP increased from a Vac to 60 psi since 08/11/19. 8/25/2019 SV, MV = C. IA, OA = OTG. 00:30 T/I/O = 50/Vac/90. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. TP increased 20 psi, IAP unchanged and OAP increased 30 psi since 08/25/19. 9/10/2019 SV, MV = C. IA, OA = OTG. 09:00 Job Scope: P&A NES - Start excavating for P&A. Excavate to 11'. Tundra elevation visible 11/29/2019 at 6.5' below pad grade. ***Excavation in progress*** Job Scope: P&A NES - Complete excavation, install can, backfill, install railings on can, 11/30/2019 and set up ventilatioEM equipment. ***In progress*** Job Scope: P&A NES. Remove snow from can. Cut windows in 30, remove good quality 12/1/2019 cement, cut windows in 20" and exposed good quality cement. ***Job in progress*** Job Scope: P&A NES- L;ontinue cutting wellhead. Windows cut in 30" condcutor yesterday. Remove cement from 20", Cut windows and remove good quality cement from 13-3/8, 9-5/8, and 7". Cut 4-1/2" tbg. Fly out tree and wellhead. Good cement in 4-1/2 tbg. Good cement in all strings. AOGCC inspection scheduled for tomorrow morning. Wellhead 12/2/2019 cut 55 below tundra grade. ***In Progress*** Daily Report of Well O erations PBU 01-05B Job Scope: P&A NES - AOGCC inspection (Brian Bixby) Weld on marker cap @ 5.5' below tundra grade and take final photos. Backfill and pull shoring can. Pics sent to AOGCC 12/3/2019 inspector and @ U:\Wells\Interventions WellWork\Well Pictures Info\01\01-05. ***Job STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOC ii��IVED RBDMS94v DEC 3 0 2019 Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ 11WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero DIA �m9G R FI E o tOfy ❑ �/ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Camp., Susp., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 12/4/2019 207-048 319-226 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 12/23/2008 50-029-20076-02-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 1/13/2009 PBU 01-088 Surface: 4735' FSL, 3856' FEL, Sec. 08, T10N, R15E, UM g Ref Elevations KB 67.80 17, Field/Pool(s): Tap of Productive Interval: 1535' FSL, 577' FEL, Sec. 08, T10N, R15E, UM GL 39.30 BE Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 41' FNL, 2905' FWL, Sec. 16, T10N, R15E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface / Surface ADL 028329, 028330 8 028331 4b. 41b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 698749 y- 5940379 Zane - ASP 4 14296'/ 8712' 79-179 TPI: x- 702122 y- 5937268 Zone- ASP4 12. SSSV Depth(MD/TVD): 20 Thickness rmafrost MDT/D: Total Depth: x- 705650 y- 5935788 Zone - ASP 4 None 19 (Appy x.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: Re-dnll/LaI I Top Wndow Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) D ND: 4690; / 434' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and pri JI within 90 ays of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud g, taneous p ential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing co r I t jewelry, d perforation r�d. e Acronyms may be used. Attach a separate page if necessaryr. �_ife 71 DIR/GR/ RES /PWD, DIR/GR/ABI RES/NEU/DEN,AZI DENS 23. CASING, LINER AND CEMENTING REGOR CASING WF. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 30" 157.5# B Surface 111' Surface 111' 39" 20" 94#/133 H40/K-55 Surface 1210' Surface 1210' 26" Fondu to Surface 13-3/8" 72# N-00 Surface 2704' Surface 2704' 17-1/2" 950 sx Fondu 9-5/8" 47#/40# L -so 1 spa95 Surface 4690' Surface 4434' 12-1/4": 1175 sx Class'G', 448 sx AS 7" 26# L-80 1 Surface 10381' Surface 8653' 8-1/2" 547 sx UteCrete, 168 sx Class'G', 179 sx Class'G' 4-1/2" 12.6# lscrao 10217' 1 14292' 8550' 8712' 6-1/ Uncemented Slotted Liner 24. Open to production or injection? Yes ❑ No 2 TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/ND) 4-1/2" 12.6# 13Cr80 10223' 10147'/ 8506' ,1 ttu,,,,,�,,/� ` /I/'1N"'F 6141 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic antl printed information V DEPTHINTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2801'- 2806' Puhch Tubing Surface 224 Bbls Class'G' Surface 10 Gal AS 1 27, PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Productio for Test Peri d � Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press Casing Press: Calcula d 24 Hou Rate �y Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (cow): Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS94v DEC 3 0 2019 28. CORE DATA Conventional Cores) Yes ❑ No RI Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10384' 8587' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 5093' 4732' West Sak 6974' 6157' Colville Mudstone 7678' 6693' HRZ 9746' 8256' Base of HRZ 10085' 8467' LCU / Kingak 10128' 8494' Sag River 10384' 8655' Shublik 10434' 8684' Sag River (Invert) 12683' 8688' Formation at total tlepth: Sag River (From Base) 1 12683' 8688' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hibbert, Michael Authorized Title: SI p ialist Contact Email: Michael.Hibbert@BP.com A Authorized Signature: Date: �2 �h Contact Phone: +1 907 564 4351 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 41b. 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 forth for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only T/I = VACNAC. Temp = SI. W Ps (WI request). No wellhouse, AL or flowline. n, Temporary scaffolding installed. OqLbofe tree. (`7� 5/3/2019 SV, MV = C. IA(X2) = OTG. 02:30. ****WELL S/I UPON ARRIVAL**** (Plug and abandonment) R/U SLICKLINE SWCP #4522 FOR AOGCC D&T TOC 5/4/2019 ****CONT JOB ON 5/5/19**** T/I/O=0/0 Temp=S/1 (LRS Unit 76 - Assist Slickline: Plug and Aban nment) Spotted Unit. 5/4/2019 **Continued on 05-5-19 WSR** ****CONT. JOB FROM 5/4/19**** (Plug and abandonment) DRIFTED W/ 2.25" CENT, S-BAILER TO TOC @ 6,745'S (Good sample, AOGCC witnessed Bob Noble) LRS PERFORMED PASSING CMIT-TxIA TO 2,500 i (Passed per AOGCC criteria, witnessed Bob Noble) LRS PERFORMED PASSING CMIT-TxIA TO , 00 psi (Passed per BP criteria) 5/5/2019 ****DSO NOTIFIED OF STATUS UPON DE RTURE**** **Continued from previous WSR** (LRS it 76 - Assist Slickline: AOGCC CMIT-xIA) AOGCC CMIT-TxIA PASSED @ 26501 87 psi Perr AOGCC Criteria Witnessed by Bob Noble. Max applied=2750 psi. Target res 'ure= 2500 psi. Pressured up T/IA to 2730/2743 psi with 4.6 bbls 60/40. 1st 15 minT A lost 33/59 psi. 2nd 15 min T/IA lost 20/38 psi, 3rd 15 T/IA lost 12/27psi for a total loss of 80/156 psi in 60 min. min T/IA lost 15/32 psi, 4th 15?684 (Per BP Criteria). Repressuered T/IA with .06 bbls CMIT-TxIA PASSEDyellupon 60/40. 1st 15 min T/I5 psi. 2nd 15 min T/IA lost 7/21 psi. 3rd 15 min T/IA lost 6/17psi for a total los3 psi in 45 min. Bled pressures to 5/30 psi and recovered -3 bbls. 5/5/2019 Slickline in control of departure. Tags hung T/1=32/55. Temp SI. WHPs (WIE request). No wellhouse or flowline. Dry hole tree. Temp scaffold ins Iled. 5/16/2019 SV, MV = C. IA OTG. 04:00 ***WELL SHU IN ON ARRIVAL*** RIG UP HES LINE UNIT 4863. 5/30/2019 ***JOB CO INUED ON 31-MAY-2019*** T/I = Vac/ 0. WHPs (WIE request). No wellhouse or flowline. Dryhole tree installed. Tempor9fyscaffolding installed. The TP decreased 32 psi and the IAP decreased 45 psi 5/30/2019 since 5/16-19. ***JOF CONTINUED FROM 30-MAY-2019*** (Plug and Abandonment) PU H TBG 2801'- 2806' MD W/ 2" x 5', 4 SPF, 0 DEG PHASE, TITAN 4C501 TUBING PU CH. (good txia pressure response) AVL LOGS TIED INTO TUBING TALLY DATED 26-OCT-2013 5/31/2019 *JOB COMPLETE ON 31-MAY-2019*** /I = 130/150. Temp = SI. WHPs (WIE request). Dryhole tree installed. Circ out rigged up. Temporary scaffold installed. 6/14/2019 SV, MV = C. IA = OTG. 15:30 Initial T/I/O = 0/150/150 ***SLB Fullbore Pumping Crew*** Job Scope: Place TxIA Surface Cement Plug. SLB Pumped 5 bbls FW spacer, 224 bbls 15.8 ppg Class G CMT down TBG with IA returns to OTT. Flushed surface lines to OTT. SV / MV = C, IA CSG = C, OA CSG = OTG FWHPS = 98/49/49 15.8 ppg Class G CMT in Tx IA Est TOC in T x IA = Surface 6/17/2019 jEst BOC in T x IA = 2801' MD / 2801' TVD Daily Repo Well O er tions 01-04B TWO = 0/0/0. Temp = SI. A sis s teed No well house or flowline. FLP = 40 psi. Bled FLP from 33 psi to 0 psi 0.5 hrs. stored for 30 minutes. During monitor flow line pressure increased to 5 psi. Job e. 6/21/2019 SV, WV = C. MV = O. IA, OA = OTG. 13:00 T/I = VacNac. Temp = SI. WHPs. (WIE request). Mono bore w . Sca old installed. Dry hole tree. No change in WHP's since 6-21-19. 6/29/2019 SV, MV = C. IA = OTG. 15:29 T/I = VacNac. Temp = SI. WHPs (WIE Req). Mono bore we . Sca old installed. Dry hole tree. No change in WHPs since 6-29-19. 7/25/2019 SV, WV = C. IA = OTG. 15:10 T/I = VacNac. Temp = SI. WHPs (WIE Req). Mono ore well/.Dry hole tree. No well house, flow line or scaffold. Temporary scaffold in alled.W Ps unchanged since 8/11/2019 07/25/19. T/I = Vac/Vac. Temp = SI. WHPs (WIE Req)/Dry hole trek. No well house, flow line or scaffold. Temporary scaffold installed.W s unchanged since 08/11/19. 8/25/2019 SV, MV = C. IA = OTG. 01:00 T/I = Vac/Vac. Temp = SI. WHPs (WIg Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold install . WHPs unchanged since 08/25/19. 9/10/2019 SV, MV = C. IA = OTG. 08:15 12/2/2019 Job Scope: P&A NES - Excavat surface to 14'. ***In Progress*** Job Scope: P&A NES - Comp to excavation to 15'+. Tundra level transition obvious and photo documented @ 7' bel pad grade. Set and backfill shoring can. IH and Fire Dept approved ventilation pland ERRP. Cut windows in 30, 20, 13-3/8, and partially into 9-5/8" 12/3/2019 casing. Job Scope: P&A NES - Fete cutting off wellhead, Cement to surface in all strings except 4-1/2 Tbg. TO in 4-1/2 @ 15'. Top off w/ 10 gal cement. WOC. AOGCC inspection completed by Ada arl. Weld on marker plate. Wellhead stub 6'below tundra grade. Take 12/4/2019 final pics and bac ill shoring can. ***In Progress*** 12/5/2019 Job Scope: Re ve shoring can. Complete backfill. Demobe ***Job Complete*** max = 104 10673 OOOA TOC (8/18119) 260' Datun Datum TVD = 8800'35 NA TBG PUNCH 260'-260' N = BKR CMT RET 909' TBGCMT(8/18/19) I SURF- 0 TBGPUNCH 960'-960' 9-5/8' CSG, 47#, L�0 TCII, ID = 6.681' 114]' 20' CSG, 94#, H-40, ID = 19.124' 1216- 1489'-1492- FEST 216'1469'-1492'EST TOC N TBG (07/08/19) -2434' 13-3/8' CSG, 72#, 11-80, D = 12.347' 2709' 4-12' TBG X 7- PROD CSG 2500' ELM - 2510' ELK EL PERF® (07/07/19) EST CMT N IA. THIS IS THE DEPTH OF 2500' ELM - 2510' THE PHiF W HEI3 .. CMT CRCU.AT® FROM TBG TO OA & w. b LOC{® ( NOT CMTD TO Stiff AS RAN (7/8/19) TXIA CMT PLUG (04/08/19) 2761' -101: SL TAGGED TOP (04/17/19) 7 LNR 26#, L-80, TCII, .0383, ID = 6.276' 4662 ALL STRINGS CUT 5.5' BELOW TUNDRA GRADE. CEMENTED TO SURFACE & MARKER CAP WELDI ON. 12/03/19 9-5/8' MILLOUT WINDOW (01-05) 10000'- 10070' 93/8- CSG, 40# /43.5#, 47#, S0055, ID = 8.881' 10000' Minimum ID = 3.725" @ 10211' 4-1/2" HES XN NIPPLE MR) 1 4-12" TBG, 12.6#, 13 -CR .0152 bof. 113=21.958"I 0383, ID = PERFORATDNSUMMARY REF LOG: BHCS ON 3/10/1992 ANGLEATTOPPERR 1'@2500' Note: Refer to Production DB for Nstorical perf data SIZE I SPF I R% L Opn/S� DATE 3-1/8' 1 10 1 2500-2510 O 07/07/19 SLOTTED LNR 10293 -14269 1 O 01/13/09 1 SAFETY NOTES: *"CHROME TUBING•" 30', 20', & 13-3/8' CUT BELOW GRADE (05/19/07) El NE TAGGED TBG TOC (08!15/19) 9-5/8' HES ES CFMENTH2 TIEBACK, ID = 8.681' 4-1/2' HES X NP (9CR), I 9-5/8' FOC 9-518' CP GAS I IFT MANnRR S ST MD DRY HOLE I DEVI TYPE I VLV LHEAD= FMC WCMT suRFACE-,a9z• ABANDONED IATOR= REMOVED (08/13!19) 01/16/09 4 5463 ELEV = 47 OA CMT SURFACE - 2600' 01-0 5 B 02/05/09 $VIRE ' 6268 50 KBG-2 .LEV :LEV = 43.01' (07/08119) 2 8751 � - 3089' 30' COND 116' 01116/09 max = 104 10673 OOOA TOC (8/18119) 260' Datun Datum TVD = 8800'35 NA TBG PUNCH 260'-260' N = BKR CMT RET 909' TBGCMT(8/18/19) I SURF- 0 TBGPUNCH 960'-960' 9-5/8' CSG, 47#, L�0 TCII, ID = 6.681' 114]' 20' CSG, 94#, H-40, ID = 19.124' 1216- 1489'-1492- FEST 216'1469'-1492'EST TOC N TBG (07/08/19) -2434' 13-3/8' CSG, 72#, 11-80, D = 12.347' 2709' 4-12' TBG X 7- PROD CSG 2500' ELM - 2510' ELK EL PERF® (07/07/19) EST CMT N IA. THIS IS THE DEPTH OF 2500' ELM - 2510' THE PHiF W HEI3 .. CMT CRCU.AT® FROM TBG TO OA & w. b LOC{® ( NOT CMTD TO Stiff AS RAN (7/8/19) TXIA CMT PLUG (04/08/19) 2761' -101: SL TAGGED TOP (04/17/19) 7 LNR 26#, L-80, TCII, .0383, ID = 6.276' 4662 ALL STRINGS CUT 5.5' BELOW TUNDRA GRADE. CEMENTED TO SURFACE & MARKER CAP WELDI ON. 12/03/19 9-5/8' MILLOUT WINDOW (01-05) 10000'- 10070' 93/8- CSG, 40# /43.5#, 47#, S0055, ID = 8.881' 10000' Minimum ID = 3.725" @ 10211' 4-1/2" HES XN NIPPLE MR) 1 4-12" TBG, 12.6#, 13 -CR .0152 bof. 113=21.958"I 0383, ID = PERFORATDNSUMMARY REF LOG: BHCS ON 3/10/1992 ANGLEATTOPPERR 1'@2500' Note: Refer to Production DB for Nstorical perf data SIZE I SPF I R% L Opn/S� DATE 3-1/8' 1 10 1 2500-2510 O 07/07/19 SLOTTED LNR 10293 -14269 1 O 01/13/09 1 SAFETY NOTES: *"CHROME TUBING•" 30', 20', & 13-3/8' CUT BELOW GRADE (05/19/07) El NE TAGGED TBG TOC (08!15/19) 9-5/8' HES ES CFMENTH2 TIEBACK, ID = 8.681' 4-1/2' HES X NP (9CR), I 9-5/8' FOC 9-518' CP GAS I IFT MANnRR S ST MD I ND I DEVI TYPE I VLV I LATCH I PORT DATE 5 3168 3261 14 KBG-2 DOME BK 16 01/16/09 4 5463 5208 47 KBG-2 80 BK 20 02/05/09 3 7422 6268 50 KBG-2 DMY BK 0 01/16/09 2 8751 7090 52 KBG-2 DMY BK 0 01116/09 1 10081 7303 48 KBG-2 DMY BK 0 03/05/19 DATE REV BY COMMENTS DATE REV BY COMMENTS 10103176 ORIG4NAL COMPLETION 07/10/19 EPD/JMD ADPERFS (07/07/19) 03M7/92 RIG SIDETRACK 01-WST7 07/10/19 MSS/JMD OA, 41,&TBG CMT (07108/19) 0527117 N7ES ABORTED SIDETRACK SUS 08/12/19 BTWJMD TBG PUNCH (08/10/19) 01/18109 N2ES SIDETRACK (01-056) 08/14/19 JJUJMD TBG & N CMT (08/13/19) 0421/19 THH/.MID+7x41 CMT 04.09/19 08/28/19 NXW/JMD TBG PUNCHES & CEMENT 04/30/19 JNUJMD ADDED SL TAGGED TOG (041 12/05/19 AB/JMD ABANDONED(1211N19) V- R I EU I EBACK SEAL ASSY,D=6.170' 95/8'x7 -BKR ZXP LT PKR,D=628- W/FLEX LOCK LNR HGR, D = 6.31' 93/8' MILLOUT WINDOW (01-0573) 4690'- 4708' 10116' 4-1/2' HES X NIP (9CR), ID = 3.813' 10147' T X 4-1/2' BKR S-3 PKR, D = 3.87' 10180 4-1/2' HES X MP (SCR), ID = 3.813' 10211' 4-12' HES XN NP (9CM, D = 3.725' 1 10240' 1 14-1/2" WLEG, D=3.958" 7' X 5' BKR ZXP LT PKR �ID=4.40' 7• X 5- BKR HMC LNR HGR, D = 4.44' 5' X 4-12' XO. D = 3.96' PRUDHOE BAY UNIT WELL: 01 -OSB PERMIT No: 2070480 API No: 50-029-20076-02 T10N, R15E, 546' FNL & 1423' BP Exploration (Alaska) y, I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �Q� IzJq (� y. DATE: P. I. Supervisor FROM: Brian Bixby SUBJECT: Petroleum Inspector December 4, 2019 Surface Abandonment PBU 01-05B -' BP Exploration. PTD 2070480; Sundry 319-226 12/03/19: 1 met with the BP Well Site Leader Arvell Bass and looked over all the paperwork for the surface P&A. I verified the correct information was on the marker plate including the correct PTD and API numbers. I then confirmed there was hard cement to surface on all strings. The marker plate was welded on. Attachments: Pictures (2) 2019-1203_Surface_Abandon_PBU_ 01-05B_bb.docx Page 1 of 2 0 co a 0 0 N H CL THE STATE °fALAS- A GOVERNOR MIKE DUNLEAVY Katherine O'Connor Integrity & Interventions Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 995519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 01-05B Permit to Drill Number: 207-048 Sundry Number: 319-226 Dear Ms. O'Connor: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 10 Daniel T. Seamount, Jr. Commissioner DATED this6_Iday of May, 2019. ABDMSL±� MAY 0 9 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC ac 220 REGLIVLU MAY 0 3 mq e- 101 1"" ORIGINAL Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. W�Wmwli "o Il Submit Form and Attachments in Duplicate $.Io -/g. 1. Type of Request: Abandon m . Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Op¢r�fi0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved ro Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ After -Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development IZ 5. Permit to Drill Number. 207-048 3. Address: P.O. Boz 198612 Anchorage, AK 6. API Number: 50-029-20076-02-00 99519-6612 Stratigraphic ❑ Service ❑ 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? S. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 01-058 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028329 8 028330 L UZ�O .Y& S b -(`/ PRUDHOE BAY. PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): 14296 8712 10211 8546 0211 Casing Length Sim MD ND Burst Conductor 79 30" 32-111 32-111 880 Surface 1174 20" 31 - 1210 31 - 1210 2320, 1530 Intermediate 2674 13 30-2704 30 - 2704 5380 Intermediate 4663 9-5/8" 27-4690 27-4434 6870 / 8150 / 6820 Tieback Liner 10357 7" 25 - 10381 25 - 8653 7240 Liner 4075 4-1/2" 10217 - 14292 8550 - 8712 8430 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing M 10293 - 14269 8597 - 8711 4-1/2" 12.6# 13Cf80 23-102234 Packers antl SSSV Type: 4-1/2' Baker S-3 Packer Packers antl SSSV MD (ft) antl ND (ft): 10147 / 8506 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 � Service ❑ 14. Estimated Date for Commencing Operations: May 15, 2019 15, Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 51 ' 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Conrad Name O'cennor, Katherine be deviated from without prior written approval. Contact Email: Katherine.0'cennor0bomm Authorized Name: O'cennor, Katherine Contact Phone: +1 9075644640 Authorized Title: Integrity 8 Interventions Engineer Authorized Signature: AlIQ-1 Date: i q,ill" COMMISSION USE ONLY Conditions of approval: Notify Commission W that a representative may witness r �IL Sundry Number.SM-22(a— II ' ^J — / Plug Integrity ❑ BOP Test ❑ JJ Mechanical Integrity Test ❑ Location Clearance Iy I Other. Other: A Ye yCo C U yl^,e w i AS &6k17Tz-- /I Post Initial Injection MIT Req'tl? Yes No ❑/ 3BDMS�MAY 091019 Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: 10 —5/0 yy Approved by. APPROVED BYTHE I ^ COMMISSIONER COMMISSION Dater "11 e- 101 1"" ORIGINAL Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. W�Wmwli "o Il Submit Form and Attachments in Duplicate $.Io -/g. bp O•}i or 01-05B Full Abandon Well - 10 403 Intervention Engineer Katherine O'Connor (214) 684-7400 Expected Start Date: May 15, 2019 Well: 01-05B Date: 5/2/19 History GPB Well 01-05B was initially drilled and completed in October 1976. The initial completion was in Zone I and the well was sidetracked in June 2009. The well has had very little off time from 2009-2017 when the well was shut in for 02-03 similarities. During its life time the well maintained good integrity. The well was suspended in 2007 due to encountering fresh water to surface during drilling — this was remediated during the next sidetrack attempt in 2009 with a top job. The well was determined to be not operable due to its similar well design to 02-03 (Gen 1 well head, 3 casing string design and casing shoe set in the permafrost). This well has been not operable with a plug downhole since this time, and we are now proceeding with the full abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Place a lateral cement plug at 2500' MD, place surface cement plug. Fully excavation to abandon well. v History • Cemented 20"00" annulus with combo top job/downsqueeze. • Top job on 13-3/81'x20" from 161' MD • Cemented 9-5/8" tieback to surface • MIT -T to 2452 psi in June 2017 • CMIT-TxIA passed 3/5/19 • Lateral cement plug w/ TOC @ 2761'. PT to 2500 psi. SL tag on 4/17/19. AOGCC Witness. • IA repressurizing to about 200 psi Eline/Relay & Fullbore or DIM —Perforate for 1" stage of surface plug L Perforate through tubing and 7" at 2500' MD 2. Confirm circulation and note in AWGRS. Fullbore — Circ Hydrocarbons from well 3. Circulate hydrocarbons out of OA (9-5/8"x7" annulus) Fullbore — Placing cement plug 4. Rig up to take returns from the IA (4-1/2"x7" annulus) and OA (9-5/8"x7" annulus). Pump cement down the tubing and up the OA, once there are clean returns at surface, shut in OA then begin taking returns up the IA until clean returns are seen at surface, cementing the IA and OA to surface. 6. Chase cement with 17 bbls 9.8 brine, leaving TOC in tubing @ —1100' MD. Well: 01-05B Cement Calculations — Surface Cement Plug Stage One Total cement to um + 20% 160 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss --Compressive 40-200cc Stren h 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickenine time: Mix on the flv Activity Time hours Shearing time, quality.control, PJSM 0 Cement displacement 3 Cement contamination I Safety 2 Minimum required thickening time: 6 Eline/Relay/SL & Fullbore — Tag TOC, Perforate for 2"d Stage Surface Cement Plug, Pump Surface Plug 7. Tag TOC and note in AWGRS. 8. Perforate through tubing, 7", 9-5/8", and 13-3/8" casing —150 ft above TOC (target 950' MD), 9. Attempt to pump down the tubing and up the OOOA. • If able to pump from tubing to surface, flush hydrocarbons out of well, and then pump cement down tubing and up the OOOA surface to surface and skip to step 16 (excavation). • If unable to pump from tubing to surface, move to step 10 (perforation). 10. Perforate through tubing, 7", 9-5/8", and 13-3/8" casing at —250 ft MD. 11. Set cement retainer at —900' MD. Coiled tubing — Placing 2"d stage surface cement plug 12. Sting into retainer and confirm circulation down CT and up the CTxTBG backside and note in AWGRS. • If unable to establish circulation, unsting from retainer and lay cement in the tubing to surface. 13. Circulate hydrocarbons (ArcticPack) out of well 14. Pump cement through retainer, into OOOA, taking returns out of the CTxTBG backside. 15. Once OOOA is fully cemented, unsting from retainer, laying cement in the tubing to surface. Cement Calculations — Surface Cement Plug Stage One Well: 01-05B Total cement to pump 200------] *total cement volume hacPli nffePn.Pofinn nnnn C.,...- n<n+ ._ --- P--- Cement Type / Weight - aUl l4VG - IV UUIJ Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 pp Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time- Mir .,.. tho n.. Special Projects — Final Excavation 16. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 17. Photo document all steps. 18. Cut off all casings and wellhead 3' below tundra. 19. Top off tubing and annuli with cement if needed. 20. Weld marker cap on outermost casing string. The marker plate will have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 2070480 c. Well Name — 01-05B d. API # — 50-029-20076-02 3 Tim716 uali control, PJSM ment MI nation ired thickenin time: Special Projects — Final Excavation 16. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 17. Photo document all steps. 18. Cut off all casings and wellhead 3' below tundra. 19. Top off tubing and annuli with cement if needed. 20. Weld marker cap on outermost casing string. The marker plate will have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 2070480 c. Well Name — 01-05B d. API # — 50-029-20076-02 3 by o"Aliff I TRE= a_lerr VMAD= FRC ACR1AlOR= UM IB. 91V = 73.0' BF. 8 -FV = NA KOP= 3065 Mu An9@ = 104° Q 10673' mlM w= NA LL1�m TVD= 88WSS rs ., oa_L1b. 7cL to = e.66r 1147' 1.216• 1 .N6• C.sc'S 720. 480. n-12.14!• H 2TOs' Min um(m ID = 3.726•' @10211' 4-02" HES XN NIPPLE (SCR) NR, 288, L50. TM W D • S2W des 'rol 6f 9-1b' GCN I W1eP31CLK j-�- 19516" E25V (TAGGED 19'21Poe) j 4714' 4KWMILMTWNDOW(910) 10000 1 7V 01 -05E3 Well: 01-05B SAFETY NOTES: •"CHROME TUBING 6 LINER... 1' W 20', 8,1318' CMBELOW I 1143' i-Js5'6•TF9AIXD=8.601' I Si MD t 8 TVD 32-61 DEV 14 TWE KBG2 VLV •�LP.1CH BK _PORT_JDAPE1 162 V 06707/17'-rAI r0 WL MN RLJ3(OE/02717) DOME 5,83 5208 47 KBG4I $O BK 20 0111006 p1n4aJ 7472 SM 50 KBG-2I OMY OK 0 0751 7000 W KOG2 OCK 6K 0 10081 LM] 45 KOG2 OMY OK 0 illy TBG. 12.86, 116"..015 W D = 3.866' 10223- I cure. 2Ap, tlw. B,c M. oJq, rD = 6 276• �� 70361' PEi}ORA710N Sum"RY REF LOG- 8R 1 3.1011982 j ANGLEATTOPPEr 22M11Nr 4p: ReM b POTctxn p8 br h'sbncal peR tlata E $PFI W2ERVAL Op-Srp, DATE j 1TEp WRI 10293-µ2W O O1IY3/09' j (bll2$LTJ LNR 12.6A,13C1L, 16T.M, 015210=7956' j (._1429Y' 4651' 7' PORTED 71EBACK SEAL ASSY, D= B.iAY 466E 9518'z TBKR DP LT PKR D=628' �1atlF� FY LOCK lRR NGR Ip = 8.31' &YS'MLLODi 1V4VOOW pta�14690'-{/]6' ID=3e1T I I DATE REV BY lIM0fM5 fYL7F ifiV BY lI7MAT1fS 1003"8 1OHMMALCOMPLET1,011 V 06707/17'-rAI r0 WL MN RLJ3(OE/02717) 0317812 RIG SIDETRACK (01-NSTi) 0712511) AJHllkO 30•, 20'813378' cufaa3mim 06R7AT7 N70 ABORTED SEE, RACK(5173PI 0111006 p1n4aJ IGS 7iLH SIDEfRACK101-0SB) lommmom - - QSIZ— 9 kffSV- l f&G DRAF10pI� tp223'_ J�4-121WLEG`R1. 3_8%'_� 1U22T 1 z S BKR7W LT PKR, M=4.411 I, 10240• _ —T z 5' $KR HMC LNR HGR, j 1024T 'r-5'. a112•m,D=3.%" j j Ij P'4 IDE BAY LM VVE L 01056 FBYMW 2OM480 AR NP: 56029-2007602 11UN RI5✓; 54E FNL 81423' FWL BP &plonWi" (AMska) 4 by IT1€T_: L.aY 1N = FAC- ...'F I 076 �— 770--. I iN_..— _ 71709 134A CAf, 72I NOD, D• 12 Nrri I 2 r 1&• M 10ri73 _� GASL TtWNOMIs IQ wl 1 MOO!:S rirr,,.m,1 It�� Well: 01-05B 01_05B n(=:TY MOTFS'••CHROME TI1B1N01lBSFR'^ /'� 70+, 20', i iSN6' (Xlr 9FL01Y D•6 �I VK f'4la_I>Rl It l=h. ab111' 1141 / ...'F I B SG, •4dD I J 9Y q. ,8 1N �4 �•M'flCR1 134A CAf, 72I NOD, D• 12 Nrri I 2 r _� GASL TtWNOMIs _ MIninum 1D - 3I -- � 10211 ITU wl 1 M-U�—MY 4H -Y ,YYf yL.V LIIGP PQRi. pR)� ' 31GO t 3281 1. I Rna 1 DOME' OK '' 1 54631 tow 41'Ka42 50 SK m 'mvzmJf X N NIPPLE (9CR)� 7422]j8269 SO IR6G2 LWY OK 0 OtliW0R1 f7_ NR 2TM_L{0• Tp• 0-627S ! 4842-- l 4 -`_:.1006117003 BT51I1090 D21Rtlf32i OEK - BK C GIA500 441KA0-2I 9MY 6K D DVJa 4531• I fT IWTI:O TIE Wil. SEAL A55v, q+6.170'—j — -LrPKX DPZ1:1995'-7680' MD ''" +� '• 4Ya' r -%KR 7W v=s] R E€KLocKLNRNr;<eo�e:3r 4xa i_tsv I.rNr;r:-n..4711'.. C B Ya- MLLtnft WN11%YN 1o•+1Nr Up' - U19' . I -� 10116' � •-•',��7 nw!r�nc,eT, U lots r 10147.., ^T • ti,n' eK6 65 mcrt 10-3ar i 1011RT --K-��•' Fp+ANm lrxi. ID = 16)Y LSa M3!(y7 Wai0^1Y fat-0Si +aoay.lromr I ! {0211' T� 4VY if YIN M'(t6R1 '. O - 1725' 9' S!• CSG401,41tu, aia. :PA 95. IU+ Gini° --{ 10007 -- _ - - .-10211 i {qr2 PKN Ir __ R .1060^:; •b1 I 10217' T 6KN LPIR itiBACl+. Siv tU}L1—� 4112• WIEG, D+ 5.050' bf r iBG,, 12 BR {SCR Bf 5] bP( O . ] V!a• TO -22T __ - 10223' -- - " 1 W2p •-(r 15' MR DP LT aKR. r ; NK, Trlr Lop, 6Tf M. 0163. IU n 81+',7' -103{1' i D=Ifp . IOW PE!ifVPA rR7V SiIMMAi{v I _ RFT LAG 6!GS ON 3110'1682 K7rr�ErrroPPear' a151,ur i ' nw.-IbR+aPMcaon [6 hnislwcal BOKasa i I I Sff 9VF', W'r[—TTtASK oons�_ 'R SLOi7EEI LNR � 10QP!-�1Q%J I I I I DPZ3: 10383' MD I �l I - tr2sx fx4LD OF MY rNT nB.L 0,-056 R3M 1b: 2070160 An Nr 50IONLM A2 UP &ObnKaa (AW w( 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 3 0 2019 1. Operations Performed � y� Abandon ❑ Plug Perforations RI Fracture Stimulate ❑ Pull Tubing ❑ Operations shAOCCC Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Omer: Secure Reservoir 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit io Drill Number 207-048 3. Address: P.O. Box 196612Anchorage, AK 99519-6612 Str4tigraphic ❑ Service ❑ 1 S. API Number: 50-029-20076-02-00 7. Property Designation (Lease Number): ADL 028329 & 028330 8. Well Name and Number: PBU O1 -05B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 14296 feet Plugs measured 2761, 10211 feet true vertical 8712 feet Junk measured None feet Effective Depth: measured 2761 feet Packer measured 10147 feet true vertical 2761 feet Packer true vertical 8506 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 79 30" 32-111 32-111 880 Surface 1179 20" 31-1210 31 -1210 2320 / 1530 15001520 Intermediate 2674 13-3/8" 30-2704 30-2704 4380 2670 Intermediate 4663 9-5/8" 27-4690 27-4434 6870 / 8150 / 6820 4760 / 5080 / 3330 Tieback Liner 10357 7" 25-10381 25-8653 7240 5410 Liner 4075 4-1/2" 10217 - 14292 8550-8712 8430 7500 Perforation Depth. Measured depth: 10293 - 14269 feet True vertical depth: 8597 - 8711 feet feel Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 23-10223 23-8554 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10147 8506 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-Bbi Casing Pressure Tubing Pressure Prior to well operation: Shut -In Subsequent to Operation: Shut -In 14. Attachments: fmaaimd par 20nnc 25 070.25. W1, & 25.201 15. Well Class after work: Daily Report of Well Operations a Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work. Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 herebycertify that the foregoing y g Sundry Number or N/A if C.O. Exempt: fy regoin is true and correct to the best of m knowledge 319-036 Authorized Name: Worthington, Area J Contact Name: Worthington, Aras J Authorized Title: Interventions & Integnty gineer Contact Email: Ares.WorthingtonAbri.com Authorized Signature: Date: Y� el/�% 9 Contact Phone: +1 907 564 4102 /,"m"0%& Form 10404 Relnsetl 04/2017 Jf'�e�p �'m"0 BSMS�✓ MAY 0 12019 Submit Original Only Daily Report of Well Operations 01-05B ACTIVITYDATE SUMMARY T/1/0=0/250/0 Set 4" CIW "H" BPV #254. R/D existing production tree, R/U Dryhole tree Temp #13. PT'd dryhcle tree against shut Master. see "Field Charted Tests" Pulled 4" CIW 2/20/2019 "H" BPV #254. FWP's 0/250/0 see log for details. T/I/O = 41230/Vac. Temp = SI. WHPs (WIE request). No AL, flowline, wellhouse, or scaffold. Dryhole tree installed. 3/1/2019 SV = C. MV = O. IA, OA = OTG. 1515 hrs. ***WELLS/[ ON ARRIVAL***`(P&A) SET 4 1/2" WCS ON PXN AT 10,211' MD. 3/4/2019 ***CONT ON 3-5-19 WSR*** T/I/O=vac/280/0 Temp=S/I (LRS Unit 46 -Assist Slickline: Circ Out / AOGCC CMIT-TxIA) Pumped the following down the tubing, taking returns up the IA to 01-36's flowline: 7 bbls 60/40 followed by 72 bbls 140* surfactant, 440 bbls 9.8 brine and 5 bbls 60/40. U- tube 5 bbls 60/40 TxIA to 100' for FP. Hardline FP'd to 01-36 FL SL set DGLV in St #5. AOGCC (Bob Noble) witnessed CMIT-TxIA to 2449/2470 psi ***PASSED*** Target pressure=2200 psi Max applied=2500 psi Pumped 2.89 bbls 60/40 down TxIA to achieve test pressur of 2495/2501 psi. 15 min loss of 31/18 psi, 30 min loss of 15/13 psi, for total loss of 46/31 psi in 30 mins. Bleed TxIA to 100 psi Bled back —2.6 bbls Hang tags on IA/WV SL on well upon departure. CVs OTG Hardline SI 3/5/2019 FWHP=100/100/0 ***CONT FROM 3-4-19 WSR***(P&A) PULLED DMY-GLV FROM STA#5 AT 10,081' MD LRS CIRC'D WELL W/ 75 BBLS OF SURFACTANT & 425 BBLS OF 9.8 BRINE. SET BK-DGLV IN ST#5 @ 10,081' MD. PULLED 4-1/2" WHIDDON CATCHER SUB FROM 10,211' MD.(empty) LRS PERFORMED PASSING CMIT-TxIATO 2200psi.(aogcc witnessed by Bob Noble) TAGGED PXN PLUG W/ 3.50" LIB @ 10,211' MD.(good impression, aogcc witnessed) 3/5/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** T/I/O = 120/140/Vac. Temp = SI. WHPs (WIE Req). Dry hole tree and drilling scaffold installed. No well house or flowline. 3/15/2019 SV, MV = C. IA, OA = OTG. 14:00 TWO = 110/140NAC. Temp = SI. WHPs (WIE request) No wellhouse, AL or flowline. Drill scaffolding on well. Dry hole tree. 4/2/2019 SV, MV = C. IA, OA = OTG. 23:59 ***WELL S/I ON ARRIVAL*** (Plug and Abandonment) HES RELAY UNIT #46 INITIAL T/I/O = 200/120/0. BEGIN RIGGING UP. 4/3/2019 ***JOB CONTINUED ON 04 -APR -2019*** ***JOB CONTINUED FROM 03 -APR -2019*** (Plug and Abandonment) HES RELAY UNIT #46 PUNCH TBG 10,125'- 10,130' MD W/ 2", 0 DEG PHASE, 4 SPF, TITAN 4C631 CHARGE PUNCHER (txia pressure response). RAN 40 ARM PDS CALIPER FROM 2200' MD TO SURFACE (good data). ALL RUNS TIED INTO TUBING TALLY DATED 16 -JAN -2009 4/4/2019 ***JOB COMPLETE ON 04 -APR -2019*** Daily Report of Well Operations 01-05B T/I/0= 0/0/0 Temp= SI (LRS Unit 42 Assist Schlumberger Cement Van: Tubing & IA Balance Cement Plug) Pump the following down the tubing, taking returns up the IA, to 01-36's Flowline: 5 bbls 60/40 SLB Cementers pumped cement and FW Down TBG. Cementers launched ball. 40 bbls 9.8 Brine 5 bbls 60/40 meth down TBG and U -tubed with IA for 30 min. Freeze protected surface lines with 2 bbis 60/40 meth to FL of well 36. RDMO. SLB pumpers in control of well upon LRS departure. IA/OA=OTG, SSV/MV=Shut. 4/8/2019 FWHP's=200/200/0 SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (place lateral cement plug in TBG and IA). LRS pumped 5 bbls 60/40 to verify flow path down the TBG taking returns from the IA to 01-36 FL and OTT. SLB pumped 5 bbls FW spacer, 241 bbls 15.8 ppg Class G cement and 2 bbls FW spacer. Launched 6" foam wiper ball down TBG. LRS displaced CMT with 0 bbis 9.8 ppg NaCL and 5 bbls 60/40. U -tubed TxIA for 30 min to FP TxIA to —150'w/60/40. LRS flush surface lines to 01-36 and OTT w2 bbls 60/40. **Job Complete** 15.8 ppg Class G cement in TxIA Est. TOC in TBG and IA @ 3,000' MD/2 999' TVD 4/8/2019 st. BOC in TBG and IA @ 10,125' MD/8,491' TVD T/1/0= 28/-14/-15 Temp= SI MIT -T Plug and Abandonment (State witness MIT -T) PRE AOGCC State Witness CMIT TxIA ***PASSED*** to 2668/2677 psi with target pressure ot 2500 and max a ie ressure o st 15 min I xIA losT72721TIl5si. 2nd 15 min I x ost 23/23 psi for a total loss of 75/72 psi in 30 Min. AOGCC state witness test MIT -T ***PASSED*" to 2661 psi. with target psi 2500 and max applied psi of 2750. 1st 15 min TBG lost= 27 bbls. 2nd 15 min TBG lost= 18 psi. total loss in 30 min= 45 psi. STATE WITNESSED BY BRIAN BIXBY. Pumped 2 bbls 60/40 to reach max applied psi. Bled back 1.7 bbls. SSL in control of well on 4/17/2019 departure. FWHP= 30/-8/-15 T/I/O = O+NACNAC. Temp = SI. WHPs (WIE request). Dryhole tree installed. Wellhouse & scaffold removed. Rig scaffold installed. 4/17/2019 SV, WV = C. IA, OA = OTG. 16:00 ***WELL S/I ON ARRIVAL***(plug and abandonment) DRIFT W/ 3.00" CENT, 2-1/2" SAMPLE BAILER, TAG TOC @ 2,761' SLM LRS PERFORMED PASSING CMIT-TxIA 4/17/2019 ***WELL S/I ON DEPARTURE*** TREE= DRY HOLE WTiLF64D= FMC ACTUATOR= REMOVED OKB. E -EV = 73.0' REF B -EV = 67M BF. ELEV = 43.01' KOP= 3089' Max Angle = 104' @ 10673' Os1um MD= NA Datum TVD= 8800'SS _ 80, TCB, D = 8.681' 1147• 1216• 2709' CMT PLUG (04/08/19) 2761' - Minimum ID =3.725" @ 10211' 4-1/2" HES XN NIPPLE I CR) 95/8' MB -LOUT WINDOW (0105) 100W -1007(r Ht / 43.5#, 47#, SOO-95, D = 8.681' 10000• 01-053OTY SAFENOTES: —CHROME 7UBINQ'•• F ---v —�30•, 20', & 13-3/8' CUT BROW 1 4-12' TBG. 12.60. 13-CR..0152 bol. D = 3.958'1 s = 6.276 PERFORATION SUMMARY REF LOG: BHCS ON 3/10/1992 ANGLE ATTOP PERF: 22 @ 1114T Note: RakwW Prodlcfon DB for hsbdcal dale SIZE SPF INTERVAL OwOS� DATE 13-3/8' J 4-1/2' HIS X NP f9CR1. D = ST MD TVD DEV TYPE VLV LATCHI PORTI DATE 5 3168 3261 14 KBG-2 DOME BK 1 16 01/16/09 4 5463 5208 47 KBG-2 SO BK 20 02/05/09 3 7422 6268 50 KBG-2 DMY BK 0 01/16/09 2 8751 7090 52 KBG-2 OMY BK 0 01/16/09 1 10081 7303 48 KBG-2 DMY SK 0 03/05/19 DATE RE/ BY I COMMENTS DATE REV BY OOMP E TS 10/03176 ORIGINAL COMPLETION 02126/19 KPIJMJ DRY HOLE TREE 03/17/92 ISG SIDETRACK (01-85ST1 03/13/19 Mf1JMD GLV C/O (03105/19) 05/27/07 MFS ABORT® SIDETRACK (SUS 04/09/19 MF;DJMD4 TBG RINCH(04/04/19) 01/18/09 N2ES SIDETRACK(Ot-058) 04@1119 TFWJ TXIA CNR(041=19) 0725117 RIWJMD 30", 20" & 13-3/8" 04/30/19 JNJJM) ADDEDSL TAGGEDTOC(04/17/19) 0128119 JNJJM) ADDED REF, BF LLEV - EDIT TO LNR TY PE -/- KJRJLU IB3IACK SEAL ASSY, D =6.170' 95/8• s T BKR 2XP LT PKR, ID =6.28' w/FLEX LOCK LNR HGR, D = 6.31' "ll- MILLOUT WINDOW (01068) MW -47W 10116' 41 JY HES X NIP (9CR), ID = 3.813• 1612x•-10130' TBG PUNCH (04/04/19) 1014r 7'X4-110• BKR S-3 R(R, D = 3.87 101811' 411Y HES X NIP (9CR), ID = 3.813' 10211' j 4-1/2' HES XN NP (9CR), D = 3.725• D = 4A0• 7"X5"B1 D = 4.44' PR(AFIOE BAY UVfT WELL: 01-05B PEFW No: 2070480 AF1 Na: 50-029-20076-02 SEC8, TION, R15F, 546' FNL& 1423' FWL BP EWkwation (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 17th 2019 SUBJECT: Well Bore Plug & Abandonment PBU 01-05B BP Exploratign Alaska PTD 207-048; Sundry 319-036 Section: 8 Township: 10N Range: 15E Meridian: Umiat 2761ftMD-1 Drilling Rig: N/A Rig Elevation: N/A Total Depth: 14296 It MD Lease No.: ADL 028329 Operator Rep: Lee Grey Suspend: P&A: XXX Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 30" O.D. Shoe@ 111 Feet Csg Cut@ Feet Surface: 20" O.D. Shoe@ 1210 Feet Csg Cut@ Feet Intermediate: 13 3/8" O.D. Shoe@ 2704 Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 4960 Feet Csg Cut@ Feet Liner: 7" x 4 1/2" O.D. Shoe@ 14292 Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 10223 Feet Tbg Cut@ Feet Plugging Data: Test Data: Tvoe Pluo Founded on De th Btm Denth To MW Above Verified Fullbore - Bridge plug 2761ftMD-1 9.8 Brine Wireline tag OA 0 0 0 Initial 15 min 30 min AS min RPeiilf Tubing 2706 2679 2661 " IA 15 15 15 P v OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I witnessed the top -of -cement tag with slickline at 2761 It MD (Slickline measurement. Good hard cement. I witnessed the MIT -T for a good 30 minute test. Attachments: none rev. 11-28-18 2019-0417_Plug_Verification_PBU_01-05B_bb MEMORANDUM TO: Jim Regg P/ 51Zi ,° P. 1. Supervisor z / FROM: Bob Noble Petroleum Inspector Section: 8 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Mike Harris Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" O.D. Shoe@ Intermediate: 9 5/8" O.D. Shoe@ Liner: 7"x41/2" -O.D. Shoe@ Tubing: 41/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 5, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 01-056 BPXA PTD 2070480; Sundry 319-036 10N Range: 15E Meridian: Umiat - NA Total Depth: 14296 ft MD Lease No.: ADL 028329 Suspend: P&A: X 111 Feet 1210 Feet 2704 Feet 4690 Feet 14292 Feet 10223 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing 10196 ft MD Wireline tag Initial 15 min sn min as min Rcc,ar Tubing 2495 2464 - 2449 IA 2501 2483 2470 P OA 3 3 3 Remarks: I traveled to PBU 01-05B to witness a plug tag and a combination MIT-TxIA. I met with BP rep. Mike Harris and we discussed what they were going to do. Hot Oil was rigged up to do the MIT first. I inspected their rig up. They were tied into the tubing with a✓ jumper line to the IA; pumped 2.9 bbls for test and bled back 2.6 bbls fluid - PASS. Schlumberger slick line rigged up with a 3.5 - inch lead inpression block and ran into the well to tag the 4.5" PXN plug. Slick line pulled out of the hole and there was a strong impression of a fish neck on one of the blocks. ✓ Attachments: none rev. 11-28-18 2019-0305_Plug_Verification PBU_01-05B_bn THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Katherine O'Connor Integrity and Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-05B Permit to Drill Number: 207-048 Sundry Number: 319-036 Dear Mr. O'Connor: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Www. a ogc c.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, �AP-1 Cathy P. Foerster Commissioner DATED this Z day of February, 2019. FiECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 iiTC 2 lfY/ i o 1. Type of Request. Abandon 0 ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Pemlit to Drill Number. 207-048 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 S[retigrephic ❑ Service ❑ 6. API Number: 50-029-20078-02-00 ' 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No ® PBU 01-05B 9, Property Designation (Lease Number): 10, Field/Pools: ADL 028329 8 028330 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MO): • 14296 8712 10211 8546 10211 None Casing Length Size MD TVD Burst Collapse Conductor 79 30" 32-111 32-111 860 Surface 1179 20" 31-1210 31-1210 2320 / 1530 15001520 Intermediate 2674 13-3/8" 30-2704 30-2704 5380 2670 Intermediate 4663 9-5/8" 27-4690 27 - 44346870181 50 / 6820 4760 / 5080 13330 Tieback Liner 10357 7" 25-10381 25- 8853 7240 5410 Liner 4075 4-1/2" 10217 - 14292 8550-8712 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10293 - 14269 8597 - 8711 4-1/2" 12.6# 13Cr80 23-10223 Packers and SSSV Type: 412" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 10147/8506 No SSSV Installed No SSSV installed 12. Attachments: Proposal Summary ® Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service ❑ 14. Estimated Date for Commencing Operations: March 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 ❑ Abandoned 21 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: O'connor, Katherine be deviated from without prior written approval. Contact Email: Katherine.O'connorabp.com Authorized Name: O'Connor, Katherine Contact Phone: +1 9075644640 Authorized Title: Integrity, & Interventions Engineer Authonzed Signature: �iJ/` �/7iz/ Date: I jZ rJ / I CI COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness J Sundry Number: 7 FJ-' Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test SK— Location Clearance 1/1/ Other: � M `tea oc—" %e.j CL�G- -O t7C KJeOl( Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacng Exception Required? Yes ❑ No Subsequent Form Required: I — 4 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: RBDMS""*FFR 0 8 1019 �%��q ORIGINAL ,/:�zell -jitnozaeog S bmit Form and Form 10-403 Revised D4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate tbp Z Well: 01-05B 01-05 Abandon Well -10 403 — REV 1 Intervention Engineer Katherine O'Connor (214) 684-7400 Expected Start Date: March 1, 2019 History GPB Well 02-05A was initially drilled and completed in October 1976. The initial completion was in Zone IA and the well was sidetracked in June 2009. The well has had very little off time from 2009-2017 when the well was shut in for 02-03 similarities. During its life time the well maintained good integrity. The well was suspended in 2007 due to encountering fresh water to surface during drilling — this was remediated during the next sidetrack attempt in 2009 with a top job. The well was determined to be not operable due to its similar well design to 02-03 (Gen 1 well head, 3 casing string design and casing shoe set in the permafrost). This well has been not operable with a plug downhole since this time, and we are now proceeding with the full abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Place a lower lateral cement plug above the plug at 1021 P MD, place surface cement plug. History • Cemented 20"00" annulus with combo top job/downsqueeze. • Top job on 13-3/8"x20" from 161' MD • Cemented 9-5/8" tieback to surface • MIT -T to 2452 psi in June 2017 SL/Relay w/ FB — GLV c/o, circ brine; PT; Tag 1. Pull dummy valve out of St. 5 at 10,081' MD 2. Circulate tubing and IA to 9.8 brine, leading with surfactant wash 3. CMIT-TXlA to 1 psi — AOGCC witness 4. Tag plug at 10,221 ft — AOGCC witness 5. Punch tub'n at bottom of pump joint 10,127' MD. �.-� t�%a G -t -v , A3 ST-+-"�j-�5������ Full ore—Interme iateCement lug �/trd lj /`er,�ra,/-rn+ilS fa! Cement IA to surface down the tubing and up the IA. 1, ?.' Chase cement with 9.8 brine leaving TOC at 3000' MD. Cement Calculations — Lower Cement Plug by 0 Total cement to pump 310 bbls Well: 01-05B Cement Type /Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickening time: Mix on the Fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination 1 Safct, 2 Minimum required ihickeningtime: 6 Cement Ramp for Blend Time Volume Pumped (bbls) Temperature (°F) Pressure (psi) 0:00 0 100 0 0:30 0 120 0 1:00 400 120 5000 2:00 500 100 5000 3:00 533 80 5000 4:00 533 70 5000 5:00 533 60 1000 6:00 533 60 1000 by Well: 01-05B Eline/Relay & Fullbore or DHD - Tag TOC, Pressure Test, Perforate for V stage of surface plug 8. Drift and tag TOC with sample bailer. tAe G Lt; -1b 4� -7,; 0;C j0� 9. MIT -T to 2,500 psi. 10. Perforate through tubing and 7" casing 300' above tag depth. 11. Confirm circulation and note in AWGRS. Fullbore - Circ Hydrocarbons from well 12. Circulate hydrocarbons out of OA Fullbore - Placing cement plug 13. Rig up to take returns from the OA. 711 14. Pump cement down the tubing and up the OA, cementing the OA to surface. 15. Chase cement with 9.8 brine, leaving TOC in tubing @ -1100' MD. ' Cement Calculations - Surface Cement Plug Stage One Total cement to pump I 100 bbls C .ment Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Tein erature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 Ins Thickening Time Minimum 6 hours Cement thickening time: Mix on the fl Activit Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Ramp for Blend Time Ternp Pressure 0:00 90 0 1:00 70 1500 2:00 60 1000 3:00 50 500 4:00 1 40 0 7:00 1 40 0 1 15:00 1 30 0 Well: 01-05B Eline/Relay/SL & Fullbore — Tag TOC, Perforate for 2"" State Surface Cement Plug; Pump Surface Plug 16. Tag TOC and note in AWGRS. 17. Perforate through tubing, 7", 9-5/8", and 13-3/8" casing —150 ft above TOC (target 950' MD). 18. Attempt to pump down the tubing and up the OOOA. • If able to pump from tubing to surface, flush hydrocarbons out of well, and then pump cement down tubing and up the OOOA surface to surface and skip to step 25. • If unable to pump from tubing to surface, move to step 21. 19. Perforate through tubing, 7", 9-5/8", and 13-3/8" casing —250 ft. ✓ 20. Set cement retainer at —900' MD. Coiled tubing — Placing 2" stage surface cement plug 21. Sting into retainer and confirm circulation down CT and up the CTxTBG backside and note in AWGRS. • If unable to establish circulation, unsting from retainer and lay cement in the tubing to surface. 22. Circulate hydrocarbons (AreticPack) out of well 23. Pump cement through retainer, into OOOA taking returns out of the tbg. 24. Once OOOA is cemented, unsting from retainer, laying cement in the tubing to surface. Cement Calculations — Surface Cement Plug Stage One Total cement to pump 170 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 plig Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Com ressive Strength 2000 psi in 48 hrs Thickenin Time Minimum 6 hours Cement thickening time: Mix an the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 bpi 0 Well: 01-05B Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Rama for Blend Time Temp Pressure 0:00 90 0 1:00 70 500 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Special Projects —Final Excavation 25. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 26. Photo document all steps. 27. Cut off all casings and wellhead 3' below tundra. 28. Top off tubing and annuli with cement if needed. 29. Weld marker cap on outermost casing string. The marker plate will have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 20704811 c. Well Name -01-0513 d. API # — 50-029-20076-02 5 TRE. 4-1/a' OW Wfl11fAD=--- FAC AC TOR= OTIS KB aEv - 73.0' BF. B.EV . NA KDP= 30&9' Atex AnOk • 104" 0 10673' Datun AU= NA Calm TVD = daOD'SS arras. 414,14q. K:I. x1. n6nr -- 1147' i V CSG. 9x6, HJO, 0 - 19,124• 1216• t.T %6' f'if, 77k N 110. A 17 347- H 27011• 1 Minimum ID = 3.726" @ 10211' 4-112" HES XN NIPPLE (OCR) rsR 2 , LAO. TCI..O3 0=627e TOP 0�6816'G('MI WHW 3702%I EMV &516' Mx I MR WINDOW 1014157 NM0 1-m" I MUC3.5q, 4lN.30bD5. Ipea.661' I -I 10000' 01-05B ' FIR' TBG. 12.8x, 13LR..5152 �' O = 3.856' 1D223• 'r I NR, 7xx, 1 d , RTC44. O.W. 19 - a, 7m' IJ ..10381•, I -- j PERFC An SUMMARY REF LOG B1CS ON 3!1011992 Et{ ANGLE AT TOP PERF: 22 Q 1114r Nate: Re4• to P V4tClbn OB br Nxb%ea,Petltlia SIME I SPF IN MAI IOPNSw MTF SLOTTEOLNR 10203 14M i O 101113/09 i Well: 01-05B SAFFTV NOTES: '•• CHROME TUBING B UNER•'• TIBACK O=8,681' I 4it NPpCp.D=3813' GAA 1x MAYr6xP1A at MUiVn n[ -V TYv[ 7 VLV LATCH PORT M 1 3105 3261 I41KB(i$I ROME 6K 16 (1110"D 5453 U2[56 47 KBG2I $O BK 20 07/OtiIOD 7422 EM 5D"' OIAY OK 0 01/16'08 4 6/Si AM S3 `KI 02� OCK BK 0 Ot11NOD t IM91 7303 40 XB DW 15 0 Ov16'W � 4631' I -Ir IroareD tx:tlA>rK SEAL Assr, n = 5.1ro• 492- & w.I-BKR210' LTPKR. W -52r WFLEx LOCK LNR HGP, ID • 8.31' &4,x'YLLOUi WWWW1014x4a14xao'-l/90' iG716' I 9 tYY YFA %NT {Miry. -- -- %ID.3513' 10147' -/'14117' MR5-3 PNP, 1D=sar 10180' ice.-„<- e n Nlr P -P . ID=Tats '.. ( 40211• 'f4.Ill'IU5%NNP 6CR7 - 10=3725' I PIIS SLID LNR I2.M.13CR. IBT�. 0152. x) = 3.555' i I 14NX 4.42 l?211NOE BAY LINT WB.L: 01-05B PEFW Na: 2010400 ARNb: 5002920D76-02 BP Fx01orAGM (AH6K6) 1 Z Olt T4I= L 4 6Lri1�Ao= -- - ACRMTOR- KORW- BF nfV= ': lm [Y1hT �-� 116• i- .•,.a[-rse:, u4.tm, rt:e, in. Kfs1• I 1147- M CSF _?1f, Ha4 ID • 14 t74' _1276•.._ 1 ] ex ca. 774 N Sn n 17 u 2705• Minimum ID = 3.725 16211' 41/2" HES kN NIPPLE PBCRj_ r LNK. 7KK, 44tt, N:R a j u • , 2,w -_ I � ...4567 DPZ1: 1995'-7680'MD i 46w' 1 xve-rnvil,u,ao-o tzmmsll 4714' 444' MS l(k)f W WVV 1614% 160111 . IWO '650'CX3.4Jilisa tlR, 4tf, stal.[41. n+av',` i 9(6}00' 01-05B 4`.,r,lw�_v es. lsol mueep• u.aser P;AR 7KK.t40. 91uM. 0aK\10sK]JS I— 10361' Well: 01-05B SArCTV NOTES- '•'CIIRONL. TUBING S 1JNCR"' 1' i 31]',iY i 1b7+'e•WfHFIOW 4'1AIY1ViAK-tc �VONI fIm lifN 0l 105d1O„®/1 14'KD2DOMtj OK411KNt.7- IO277- � f 1143 I s.5�e•muaco=a.$ar I 2181' =4tiY AP.SZIP(6cw.D]alSl 64 'i; Mll I 4'1AIY1ViAK-tc �VONI fIm 60Y1N' 14'KD2DOMtj OK411KNt.7- IO277- -, P UKN LNR t66,LGc 51v' SO OK A WWW _. .4 1Ir WLED. ri - 3.wwl Ib227• 1310 53 Kna? D4Y OK 0 01116" I S2KOG2 OCK OK 4 DUMW �KI107 IMM LaK_La—.OIr1M6Of f!'+'tYtRUIt¢.W:.K SIAL AS§r. D-6.,AP \4531' ,2 sve-[r6KN nw I, rKN.n=Kalr �1vaT qE%D7G'K LNH tIGR k,=611' 9L6'MKLUJt NANUDVl m14®14Ap0 4!)s`' { 10116' la s.a fa :+KNr ?ptp. ID- J01Y �I PL R'Ofi?TL?\ $114tMAHY rarrinv n-yr�aAamlas2 I j AN:tieAllcwNtas. r1B„ur j I I Nll�f f&•l-tnN de.':w•. Cp 1Y NHi9IFA1 pHN9ii:1 Q [sPr. wIL Z]'AI—IA+�.'Sq+Tm4xf I $LOiIED LNR � 90.363 14289 i - O ;nu,31m I I I I DPZ1:10383' MD J 4.ifY SI.TD LNR t2111.11CR, Ip4.M, .01$2, lD • 3 f9]C I I „fir 1014T -F[4 V7 MR 53 NKR I 0-361• j 10160' —=-ut ._.aare•IwNR 10211' i s,"4-flT lass KNNPpGpa ' 60Y1N' - �44,7•IT(N R,F.6uNozn 71 IO277- -, P UKN LNR t66,LGc 51v' t0m _. .4 1Ir WLED. ri - 3.wwl Ib227• -qr [ Y aKR bp`—T NKV, I —/-[� ppp M/G LNR NGP p1 _ 444' 134bi0E NAY LUT Y'Ri.L: 01DSt1 RlMI W. 20MW AH W: 50424.2017602 110h, M* 566'"1 A 1427 M 0P B1p16nOn61ANek61 by 2 Well: 01-05B 01-05 Abandon Well - 10 403 Intervention Engineer Katherine O'Connor (214) 684-7400 Expected Start Date: March 1. 2019 History GPB Well 02-05A was initially drilled and completed in October 1976. The initial completion was in Zone I and the well was sidetracked in June 2009. The well has had very little off time from 2009-2017 when the well was shut in for 02-03 similarities. During its life time the well maintained good integrity. The well was suspended in 2007 due to encountering fresh water to surface during drilling — this was remediated during the next sidetrack attempt in 2009 with a top job. The well was determined tr be not to 02-03-(6en I well head, 3 casine strine desen and het m'Tie permafrost . This well has been not operable with a plug downhole since this time, and we are now proceeding with the full abandonment. Objective Remove hydrocarbons from all well annuli and tubing. Place a lower lateral cement plug above the plug at 1021 P MD, place surface cement plug. (� \ History e� • Cemented 20"x30" annulus with combo top job/downsqueeze. f t✓ • Top job on 13-3/8"x20" from 161' MD • Cemented 9-5/8" tieback to surface • MIT -T to 2452 psi in June 2017 SL/Relay w/ FB — GLV c/o, circ brine; PT; Tag 1. Pull dummy valve out of St. 5 at 10 081' M 2. Circulate tubing and IA to 9.8 brine, le ng with surfactant wash 3. CMIT-TxIAto z psi —AOGCC mess 4. Tag plug at 10,221 11— AOGCC mess 5. Punch tubing at b/brine joint 10,127'MD. s I MV 6 -LV a , _4 4� Fullbore— Intermediate - Ct�c�u a, 6. Cement IA to surubing and up the IA. 7. Chase cement witing TOC at-4500'MD. Cement Calculations — LPlug Total cement to pump 280 bbls Well: 01-05B Cement Type /Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +{- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours r (� A Cement thickening time: Mix on the Fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Ramp for Blend Time Volume Pumped (bbls) Temperature (°F) Pressure (psi) 0:00 0 100 0 0:30 0 120 0 1:00 400 120 5000 2:00 500 100 5000 3:00 533 80 5000 4:00 533 70 5000 5:00 533 60 1000 6:00 533 60 1000 LV 0 Well: 01-05B Eline/Relay & Fullbore or DHD — Tag TOC, Pressure Test, Perforate for 1" stage of surface plug (� 8. Drift and tag TOC with sample bailer. p (r G� �4 e "'s -5 &' T 9. MIT -T to 2,500 psi. 10. Perforate through tubing and 7" casing 200' above tag depth. 11. Confirm circulation and note in AWGRS. Fullbore — Circ Hydrocarbons from well✓ ,\ 12. Circulate hydrocarbons out of OA (� Fullbore — Placing cement plug r7 13. Rig up to take returns from the OA. /„ 14. Pump cement down the tubing and up the OA, cementing the OA to rfac . 15. Chase cement with 9.8 brine, leaving TOC in tubing @ —1100' Cement Calculations — Surface Cement Plug Stage One Total cement to pump 1 /80 bbls Cement Type / Weight Class G 15.8 p g mixed on the fly Field blend V by equal to lab +/- 0.1 ppg Slurry Tempe ure 800 to 110° Fluid Loss 40-200cc Compressive Strength 2000 psi 'h 48 hrs Thickening Time Minim 6 hours Cement thickening time: Mix on the flv Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 3 Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Ramp for Blend Time Ternp Pressure 0:00 90 0 1:00 70 1500 2:00 60 1000 3:00 50 500 4:00 40 0 7:00 40 0 15:00 30 0 Well: 01-05B Eline/Relay/SL & Fullbore— Tag TOC, Perforate for 2" State Surface Cement Plug, Pump Surface Plug 16. Tag TOC and note in AWGRS. 17. Perforate through tubing, 7", 9-5/8", and 13-3/8" casing —150 ft above TOC (target 950' MD). 18. Attempt to pump down the tubing and up the OOOA. • If able to pump from tubing to surface, flush hydrocarbons out of well, and then pump cement down tubing and up the OOOA surface to surface and skip to step 25. • If unable to pump from tubing to surface, move to step 21. 19. Perforate through tubing, 7", 9-5/8", and 13-3/8" casing —250 ft. 20. Set cement retainer at —900' MD. Coiled tubing — Placing 2"" stage surface cement plug V� 21. Sting into retainer and confirm circulation down CT and up e TxT G backside and note in AWGRS. • If unable to establish circulation, unsting fr/cement er and lay cement in the tubing to surface. 22. Circulate hydrocarbons (ArcticPack) out of well 23. Pump cement through retainer, into OOOA taking ref the tbg. 24. Once OOOA is cemented, unsting from retainer, layi in the tubing to surface. Cement Calculations — Surface Cement Plug Stage I Total cement to uumo 1 170 bbls I Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 6 hours Cement thickenin¢ time: Mix on the tiv Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement 1 4 by Well: 01-05B Cement contamination I Safety 2 Minimum required thickening time: 6 Cement Ramn for Rlend Time Temp Pressure 0:00 90 0 1:00 70 500 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 1 0 Special Projects - Final Excavation P a fi d r- V W -SL k Q-s�e y� S 25. Notify AOGCC Inspector of wellhead removal. (24-hour mi mum notice) 1 26. Photo document all steps. ✓ 27. Cut off all casings and wellhead 3' below tundra. 28. Top off tubing and annuli with cement if needed. 29. Weld marker capon outermost casing string. The arker plate will have the following information bead welded onto it: a. BP Exploration Alaska b. PTD # - 2070480 c. WellName-0I-056 d. API # - 50-029-20076- 5 m6E= 4.1AT C VWELLHFAD- FAC ACTUATOR- KB G -EV = OTIS - - -- 73.0 - BE 9" = N4 KOP= 3088' Mu Aegis - 100• ® 10673' Dawn LAD = 14A [Wm TVD = 880aw tWR^ C-11, IX. L.A1. TCP. ID - 6 461 J 1147' 247' CSG, 94R, Ha(1, p = 19.124' - 1218' � 1331A• frf:, 7M. N80, A 19 34T I--� 270!' h -` Minimum ID = 3.726" 10211' 1412` HES XN NIPPLE (9CR) T INR. 28p. LA0. TCK xV*a. D = 517& 4562' TOP 7f i Y6• G[N 1 NM1A'BTCiC%, I I 4KU, Ls -!f E25V RAGGED lmll 6) ] -I 4714• A4M M4.LOUT W64DOW 01461 IWU - 10070 Well: 01-05B 01--05B j SAFETY NOTES: '-CHROME TUBING a LINER - 4-117• TBG. 1266, 13 .0152 6P: O - 3.— 10223' 2 LT Ller. . I An. RT(..0333.m . a5, : 6_iTe• PERFORAT SUMMARY ttt REFLOG' SW-3DN3,1N/982 ANGLE AT TOP PERT: 22 11141 We RCM b P'6MC6M OB M incblical peritlrta SIZE SPF iNTERl'AL Opv 041E SLOTTEDLNR 10293-14260 I O 011131W 1143' s518'TC3AIX o=8.681' 1169' 13-318' � 21H' 4-11Y FES "NP (eGp.0=3.81]^ � -� 2184' 3Y8' F 2223' s-s1a• W GAS LIFT MANDRELS STI1 MD TVD DEV "PE VLV LATCH PORT_ DATE 1 01847 18 NUG¢ DOME BK 16 02j 47 KSG2 SO BK 2007105lW 103 50 KBG-2 DMY UK aOD181Wb I51 52 KBG2 OCK BK 0 Ot116/Wt 1008146 KOG2 DMY OK i 0 0111NW 4531- _ - jT P(N M1J OEBACK SEAL ASSY. D • 611T] 'Z' 9Al8' TBKR ZJD' LTPKR, 0=628• JMFLEX LOCK U81 MGIC. D 5.31- 3�� S-Wa n MOUT WNOOW A$ 1 10116' :v. �,Eee -f {1. JI .) I 161 TO3 R S-3 PKR, '. 180" nlr 10211' e.v2'OESXNNP*(PCRI KI=3135' ,10211'._.' a1rz•PKN WTG IDSICO�gI x 5• BKR➢ LT =a.4v z 3• MR MAC LI =4N^ z 4-1Q• m. V= R4114CE BAY LUT ' V16_L 01-O5B PB218f Na 2070480 AHNa: 50.0232007&02 110r, R15E, 546 R& 81423 FAL BP EtplorMlon (Alaska( 6 4112• SLID V+R, 12.er.13CR, R3TJA, 0152, 10"3.9%• � -� 14262' 10211' e.v2'OESXNNP*(PCRI KI=3135' ,10211'._.' a1rz•PKN WTG IDSICO�gI x 5• BKR➢ LT =a.4v z 3• MR MAC LI =4N^ z 4-1Q• m. V= R4114CE BAY LUT ' V16_L 01-O5B PB218f Na 2070480 AHNa: 50.0232007&02 110r, R15E, 546 R& 81423 FAL BP EtplorMlon (Alaska( 6 1Ri= L1M'fTV WH11610= FW_ ACRAMR• 0"16 BF GIV= KOP- MIK 701. OQ 1067$ OrleOTVn 1N OMvn ND= '88SD!>S 74.47 I -IG. 4l/,1.x1 TV's "I • / MI' ._ ...A .., 1147. _.f IY48'CBQ 7T/,NM, D_ 17 yr F 270' i Minimum ID = 3.725" Q 10211' 4-112" HES XN NIPPLE 19CRi 4tA DPZ1:1995'-7680' MD swan �nvlrA ,r,Fo la Tuonl-{ 4714' 4 VW MtL" W/4DCV•' (/144) 18008'.. 10076" 63+!• 4WI43W 41/, Y.J(t99,U•e nnl' �- _ Well: 01-05B SAFETY NOTE3OM � "'CHRE T1IBINO t 11NE V 01 -05B 10'. 2 O•.6111a8•LYJf BELOW PI/ Fq. 6- 3613. 1, GAS Ln IMNDREIs SI-. MB , I OFY iYVF ' Wv IIA FT PLW l (NF . - 1 3108•MI 14 KBG2!D C BK 16 �O2105M 5183 3208 S] KBG3 SU BK M 0-JUSN 7422 0184 60 KOG21 DAA UK L. 01119+ae 4. 8]51 ]OW S2 KBG2,UCK UK U UtlibgU IOOBt r3W 48 KBG71_D11Y `RK J 0 �01I1 _ 4621• 1 jr e(HR,O I1aMCK S64 ASSY, D - 6.117 I.IPKR 0=6M f na A LOCK LRR IK;R, D. 8.31' sU[f1 ISS'n•MILWIMlO1V----�� t. -„-•,M K R.T\ D •3dAS n, n i-a.iir lfiG, �z xe, rata ofv ep', o=amr- y0�y�� t'tA1R 2e/.IA6. BIGM, 039:. ID. 41]S• i- 10361' I PtFitNYAiSq'Sc1MMAk! � I I I ReT Lac e+cs oR vtallxlz i I I Anse Ar roP PERF 2z� 111+r NdcRrl'W P,10V:tln, U61:KMWIK,I W11 Jltd 3g SPF _IIRLR.'A1_�[LNS®`. d,7F I I SLOiIFU 1118 104W - M2Q4 O O1l138A I DPZ1: 10383'MD {LVr SaTp WR,128/.1b1iR. IRT•Al• 0152 ID -3.958' I.I 14207.., 1014r, 1Q7 '•Yfll nn:f ANIY Ly1:RI. 10t2r _ r496KR DP LT PKR, ID - 4.40• 102,40' —r. V11KR MAC LNRW D =441• 1nDl QrSAY WI vwW_ 01 ow PERW(W MGM ARW 5G02S-2*07T.02 SW 6, 1IW. R1*_ 516' Fi4. L 1423 FV.L aP BIPIWAOON fAr.Kp 7 o=Sens Nr I+as Kw w•Ixrl. ID = ] 723' a.Irz•PtNRliaOe4)2H11{ 70217 T BKR aNR IEHAGK AV luzzi' { � ur wasc, D - a43r� 1nDl QrSAY WI vwW_ 01 ow PERW(W MGM ARW 5G02S-2*07T.02 SW 6, 1IW. R1*_ 516' Fi4. L 1423 FV.L aP BIPIWAOON fAr.Kp 7 Il l .a Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 0 7- O Lt` 8 Well History File Identifier Organizing (done) Two -sided III IIIIII II III II III ❑ Rescan Needed II 11111 7 6CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. r� ❑ Maps: Greyscale Items: Other, No/Type: C.7 No. � ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Aft Date: ob /s/ _ • Project Proofing IIIIIIIIII II III BY: _ Maria Date: ` i /0,7 ii a /s/ 01 i Scanning Preparation x 30 = / . b + 1 = TOTAL PAGES 1 c2. 1 7 (Count does not include cover sheet) if yi BY: Maria Date: ` (l / a is, Production Scanning I Stage 1 Page Count from Scanned File: 1.. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: f I !7 ' a /s/ rvif Sta 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11111111111 I III ReScanned I 111111110 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11 I 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 9/6/2012 Permit to Drill 2070480 Well Name /No. PRUDHOE BAY UNIT 01 -05B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20076 -02 -00 MD 14296 TVD 8712 Completion Date 1/18/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surrey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES / PWD, DIR / GR / ABI / RES / NEU / DEN, AZ1 DENS (data taken from Logs Portion of Master Well Data Maint Well Log information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / • Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 4305 14296 Open 4/6/2009 I ED� Lis 17788 Induction/Resistivity 4305 14296 Open 4/6/2009 GR, FET, RPX, RPM, RPD, ROP, PEF, NPHI, DRHO, RHOB, NCNT, FCNT Log .— Induction /Resistivity 25 Col 4434 8712 Open 4/6/2009 TVD DGR, EWR, CTN, ALD Lo g Induction /Resistivity 25 Col 4434 14296 Open 4/6/2009 MD ROP, DGR, EWR, CTN, ALD ED 1.,,e Pdf 17789 Induction /Resistivity 4690 14296 Open 4/6/2009 EWR Logs in CGM, PDS, �"'`� and CGM graphics te ED l: Asc Directional Survey 28 14296 Open 2/11/2009 Rpt Directional Survey 28 14296 Open 2/11/2009 Well Cores /Samples Information: Sample Interval Set ill Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / 1 Daily History Received? el N Chips Received? `1.1.11`1.1.`1.1.11., ,� Formation Tops N Analysis 44* Received? --- -- Comments: DATA SUBMITTAL COMPLIANCE REPORT 9/6/2012 Permit to Drill 2070480 Well Name /No. PRUDHOE BAY UNIT 01 -05B Operator BP EXPLORATION (ALASKA) INC API No. 50 -029- 20076 -02-00 MD 14296 TVD 8712 Completion Date 1/18/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N Compliance Reviewed By: _ Date: 'P ),) l Z III 1 I • • bp BP ExpOoration (Alaska) Inc. Attn: We Integrity Coordinator, PRB-20 r Post Office Box 196612 V Anchorage, Alaska 99519 -6612 9 t May 11,2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue a 0 7- 0 T -8' Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB S -01 ear Ir. Regg, Enclosed please find multiple copies of a spreadsheet with a last of wells from GPB ?i S- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent ater 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 IPT© 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 .axle or my alternate, Gerald Murphy, at 659 -5102. Sincerely, --7 Mehreen Vazir BP , Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbis ft NA gal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA •._ _ 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01-10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -178 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA _ NA NA NA 01 -19B 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -228 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 _ NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029218090100 Sealed conductor NA NA NA NA NA • • NOTE TO FILE PBU DS 01 -05 and DS 01 -05B t— ► l'1 ©- 0%4 BP has made applications to plugback and redrill a well on DS 01. The original well DS 01 -05 (170 -040) drilled in 1970. However in the application, it is noted that the well had already been plugged back and redrilled to a new bottomhole location in 1992. The file was examined and it appears that in early 1992 ARCO applied for a sundry to plugback the well and replace the then producing bottomhole location due excessive water production. ARCO provided a new well name DS 01 -05 ST on the sundry and included all the proposed operational steps including plugging back the original reservoir penetration and redrilling to the new BHL. The new BHL was within a 500' radius of the old BHL. On the basis of the sundry approval, ARCO proceeded to accomplish all the work described in the sundry application. An examination of other files indicates that there were at least 10 wells, all in the Eastern Operating Area, where new penetrations were drilled on the basis of sundry approvals beginning 2nd Q 1992 through 1 Q 1993. It is interesting to note that a sundry and new permit to drill were issued by the Commission for other plugback and redrill operations performed at the same time. The text of today's applications for such operations is pretty similar to those of 1992. In our current protocol, all activities in the original wellbore are authorized by the sundry and new drilling is authorized by the permit to drill. For a redrill, the API number is incremented by 1 in digits 11 and 12 and the name has a letter appended to it A for the first sidetrack B for the 2 etcetera. For the present situation, it is recommended that the new penetration planned by BP be named DS 01 -05B and the API number have -02- in digits 11 and 12. For this well family, there will be no A penetration or —01- API number. It is not recommended that any revision be made to any of the records for DS 01 -05. A copy of this document should be placed in each well file with appropriate notations in '. :DMS. 04-e-vAl-Noiodyj--4 ar■-■••=4 4011111■4' Tom Maunder, PE c,l 1,s-o- 1 Steve Davies Sr. Petroleum Engineer Sr. Petroleum Geologist , d,e . 1(feee-04(44 1 CJW LtA-- scss. s\oze4 API number revised . • Subject: API number revised From: Elaine Johnson < elaine r johnson @admin.state.ak.us> Date: Mon, 23 Apr 2007 09:48:27 -0800 To: Robert J Fleckenstein < bob_ leckenstein @admin.state.ak.us>, Stephen E M cmains < steve _mcmains @admin.state.ak.us> CC: Thomas E Maunder <tom maunder@admin.state.ak.us>, Stephen F Davies < steve _davies@admin.state.ak.us>, Arthur C Saltmarsh <art sahtmarsh @admin.state.ak.us>, Cynthia. 13 Mciver <bren mciver@adrnin.state.ak.us> Bob & Steve, The api number and well number for Pending permit 2070480 have been changed.. Previous: 207 - 048 -0, 50- 029 - 20076- 01 -00, Prudhoe Bay Unit 01 -05A. Revised to: 207 - 048 -0, 50- 029 - 20076- 02 -00, Prudhoe Bay Unit 01 -05B. There should not be a well record with api 50- 029 - 20076 -01 -00 or well number (PBU) 01 -05A. Elaine 1 of 1 4/23/2007 7:10 PM Re: FW: Renaming 01 -05A to 01 -05B • • Subject: Re: FW: Renaming 01 -05A to 01 -05B From: Thomas Maunder <tom_maunder@a admin.state.ak.us> Date: Mon, 23 Apr 2007 08:17:20 -0800 To: "Nigh, Jim" ‹im.Nigh_ .comma Jim, There is no need to edit anything on your part. What is in the ground will still be called 01 -05. Steve and I have made the recommendation not to go back and attempt to edit nearly 15 years of records. When you do the casing exit, then the new wellbore will be named 01 -05B. Does that answer your question? Tom Nigh, Jim wrote, On 4/23/2007 8:04 AM: Tom, Will we edit the API number on this approved Sundry or will you send us out an updated one? Thanks, -Jim From: Nigh, Jim Sent: Monday, April 23, 2007 7:58 AM To: Hubble, Terrie L; Stewman, Sondra D; Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Dean, James A; Wooster, Chris E (TSA); Maraj, Priya; Seltenright, Ana Maria; Ortmann, Ken A Subject: Renaming 01 -05A to 01 -05B All, Per the state's recommendations, of which I concur, we will be re- naming 01 -05A to 01 -05B. I am working on changing the documentation for which drilling is responsible for. Please let me know if you have any questions or issues with this. Thank you, -Jim Jim Nigh Alaska Drilling & Wells BP Exploration, Inc. 907 - 564 -5220 Office 907 - 441 -2591 Mobile 1 of 1 4/24/2007 1:41 PM RE: 01 -05 P &A • Subject: RE: 01 -05 P &A From: "Nigh, Jim" <Jim.Nigh @bp.com> Date: Fri, 13 Apr 2007 07:38:31 -0800 To: Thomas Maunder <tom_mauttder@Admin.state.ak.us This just in. 01 -05A (or B) spud date pushed back to approximately June 1. FYI. Thanks, -Jim From: Nigh, Jim Sent: Wednesday, April 11, 2007 12:40 PM To: 'Thomas Maunder' Subject: RE: 01 -05 P&A Thanks, Tom. I intentionally sat on this email reply until now (post planning meeting) in hopes that I would have some more concrete info /dates for you. Unfortunately, the best I can do is tell you that worst case scenario spud date is April 20th. Possibly as late as June 1. The most probable date is still May 1. Sorry about that. P &A cement issue. Thanks for catching that. I have adjusted my pre -rig work request accordingly: RIH with coil tubing, P&A with -45 (assuming no losses) to -155 bbls of cement. Cement calculations: • 7" liner (to 9-5/8 shoe) 11,220' - 10,000' ( '-45 bbls) IQ = 6.184" • 7" liner & 5-1/2" tbg 10,000' - 5,500' (-110 bbls) ID's = 6.184" & 4.892" Need cement to at least 10,000'. Highest TOO allowable: 5,500'. Plan for losses. FYI - We have also decided to tie our 7" scab liner back to surface vice only running it to 100' below the 13 -3/8" casing shoe. -Jim Original Message From: Thomas Maunder [niailto:tom maunderOadmin.state.ak.us] Sent: Tuesday, April 10, 2007 3:52 PM To: Nigh, Jim Subject: Re: 01 -05 P &A Hi Jim, Welcome back. Steve Davies and I are working through this matter. It is likely that the name should be 1 -05B. There are still a few things to work through. Is the May 1 spud date firm? Tom Maunder, PE AOGCC Nigh, Jim wrote, On 4/10/2007 3:30 PM: >Regarding well name - We can rename to 01 -05B. Please just let me know >what you want and I will make it happen. >Thanks, > -Jim > Original Message >From: Thomas Maunder mailto:tom maundertdadmin.state.ak.us >Sent: Thursday, April 05, 2007 10:39 AM >To: Smith, Phil G (ASRC) >Cc: Hobbs, Greg S (ANC) 1 of 2 4/24/2007 1:42 PM Re: 01 -05 P &A • Subject: Re: 01 -05 P &A From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 10 Apr 2007 15:52:10 -0800 To: "Ni h, Jim" <,Iini Ni h @bp.com> Hi Jim, Welcome back. Steve Davies and I are working through this matter. It is likely that the name should be 1 -05B. There are still a few things to work through. Is the May 1 spud date firm? Tom Maunder, PE AOGCC Nigh, Jim wrote, On 4/10/2007 3:30 PM: Regarding well name - We can rename to 01 -05B. Please just let me know what you want and I will make it happen. Thanks, -Jim Original Message From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] ------------------ ....._.._..------- - - - - -- .._._..._........___._ - - -- Sent: Thursday, April 05, 2007 10:39 AM To: Smith, Phil G (ASRC) Cc: Hobbs, Greg S (ANC) Subject: 01 -05 P &A Phil, As you know, I am reviewing the sundry. The possibility of significant losses is mentioned and the cement volume is planned at 27 bbls which will give an estimated top of 10500'. This is still about 500' below the 9 -5/8" casing shoe. The drawing shows that a lot more cement will be pumped potentially filling up the remainder of the liner and some portion of the tubing. Since the plan is to cut the tubing at about 5000', it is appropriate to place sufficient cement to fill the liner to above the casing shoe. Also, I need to look at the original files on 01 -05 and "01- 05ST1 ". In our name listing, I don't show the ST1. This is not surprising given the 1992 date. That was way early in the sidetrack /redrill days. Where this could lead is, to catch up with current naming, the new penetration might be more properly named 01 -05B. Some food for thought. I will get back to you. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 4/24/2007 1:41 PM • WELL LOG TRANSMITTAL To: State of Alaska March 24, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 01 -05B AK -MW- 6247167 01 - 05B: 1 LDWG formatted CD rom with verification listing. API #: 50- 029 - 20076 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Office: 907 -273 -3536 Fax: 907- 273 -3535 Bryan.Burinda @halliburton.com _ - Date: Signed: _ro, 1 WELL LOG TRANSMITTAL To: State of Alaska March 24, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 01 -05B AK -MW- 6247167 01 -05B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 029 - 20076 -02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50- 029 - 20076 -02 Digital Log Images: 1 CD Rom 50- 029 - 20076 -02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907 - 273 -3536 Fax: 907 - 273 -3535 Bryan.Buri o a @halliburton.com - Date Signed: (90 ? '')-- 3 . • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Monday, March 09, 2009 12:00 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU 01 -05B / PTD # 207 -048 Hi Art, Please reference the following well: Well Name: PBU 01-05B Permit #: 207 -048 API #: 50- 029 - 20076 -02 -00 Top Perf MD: 10293' Bottom Perf MD: 14269' This well began Production on March 6, 2009 Method of Operations is: Gas Lifted Date of Test: 03/07/09 Hours Tested: 8 24 -Hour Rate / Oil -Bbl: 2,670 24 -Hour Rate / Gas -Mcf: 28,874 24 -Hour Rate / Water -Bbl: 85 Test Rate / Oil -Bbl: 890 Test Rate / Gas -Mcf: 9,625 Test Rate / Water -Bbl: 28 Choke Size: 56 Gas -Oil Ration: 10,816 Flow Tubing Pressure: 1,091 • Casing Pressure: 825 Oil Gravity -API: Unavailable 3/9/2009 RGV I-1 v L_ J- 9' to \ STATE OF ALASKA FEB 1 8 2009 �' ` ALAS IL AND GAS CONSERVATION COM ` WELL COMPLETION OR RECOMPLETION REPORT AI �1€ 1 & G a s Co Commission Anchorage 1 a. Well Status: ®Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 0 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or AkarAc 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/18/2009 207 -048 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519 -6612 12/23/2008 i 50- 029 - 20076 -02-00 ' 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1/13/2009- PBU 01 - 05B 4735' FSL, 3856' FEL, SEC. 08, T1ON, R15E, UM Top of Productive Horizon: 8. KB (ft above MSL): 67.8' 15. Field / Pool(s): 1535' FSL, 577' FEL, SEC. 08, T1ON, R15E, UM Ground (ft MSL): 39.3' Prudhoe Bay Field / Prudhoe Bay Depth: 9. Plug Back Depth (MD+TVD) Oil Pool Total De P 9 P ( 41' FNL, 2905' FWL, SEC. 16, T1ON, R15E, UM 14296 8712' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 698749 y- 5940379 Zone- ASP4 14296' 8712' ADL 028329 TPI: x- 702122 y- 5937268 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 705650 y- 5935788 Zone- ASP4 None 18. Directional Survey 0 Yes ❑ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR / RES / PWD, DIR / GR / ABI / RES / NEU / DEN, AZI DENS `✓ /NDotyve 1670% 13•/ '1/,)) 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE To BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 30" 137.5# B Surface 114' Surface 114' 39" 20" 94# / 133.5# H-40 / K -55 Surface 1216' Surface , 1216' 26" Fondu to Surface 13 -3/8" 72# N -80 Surface 2709' Surface 2709' , 17-1/2" , 950 sx Fondu 9 -5/8" 47# / 43.5# / 40# L - 80 / S0095 Surface 4690' Surface 4434' 12-1/4" 1175 sx Class 'G'. 448 sx AS 7" 26# L -80 Surface 10381' Surface 8653' 8 -1/2" 547 sx LiteCrete, 168 sx 'G', 179 sx 'G' 4 -1/2" 12.6# L -80 10217' 14292' 8550' 8712' 6-1/8" Uncemented Slotted Liner 23. Open to production or injection? C4 Yes ❑ No 24. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2" Slotted Section 4 -1/2 ", 12.6#, 13Cr80 10223' 10147' MD TVD MD TVD 10293' - 14269' 8598' - 8711' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected w/ 75 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test: Hours Tested: P RODUCTION FOR OIL -BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD 4 Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER -BBL: OIL GRAVITY-API (CORR): Press. 24 -HouR RATE♦ 27. CORE DATA Conventional Core(s) Acquired? ❑ Yes 0 No Sidewall Core(s) Acquired? ❑ Yes 0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None 2' / -r,i I 4,i S L v'Eb' E L�� Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE iV 28. GE&OGIC MARKERS ( LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested Yes No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 4 5093' 4732' Ugnu 3 5365' 4939' None Ugnu 1 6324' 5664' West Sak 2 6974' 6157' West Sak 1 7316' 6418' Colville Mudstone 3 7678' 6693' Colville Mudstone 2 8298' 7166' Colville Mudstone 1 9600' 8151' Top HRZ 9746' 8256' Base HRZ 10085' 8467' LCU / Kingak 10128' 8494' Sag River 10384' 8655' Shublik A 10434' 8684' Shublik B 10479' 8704' Sag River (revert) 12683' 8688' Formation at Total Depth (Name): Sag River 12683' 8688' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. tj uJ&6?.... Signed Terrie Hubble 1Q, Title Drilling Technologist Date PBU 01 -05B 207 -048 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling engineer: Mehrdad Nadem, 564 -5941 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TP1 (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029- 20123 -00 -00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). ITEM 27: 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 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak -Off Test Summary Legal Name: 01 -05 Common Name: 01 -05 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 12/22/2008 LOT 4,720.0 (ft) 4,441.0 (ft) 9.40 (ppg) 700 (psi) 2,869 (psi) 12.43 (ppg) 1/1/2009 FIT 10,401.0 (ft) 8,652.0 (ft) 8.40 (ppg) 600 (psi) 4,375 (psi) 9.73 (ppg) • • Printed: 1/19/2009 4:14:27 PM • • BP EXPLORATION Page 1 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/7/2007 06:00 - 08:00 2.00 MOB P PRE Rig released from DS 03 -36 @ 06:00 hrs 05/07/2007 08:00 - 08:30 0.50 MOB P PRE Prepare to lay over derrick. Lay over derrick. 08:30 - 09:30 1.00 MOB P PRE Prepare pits to move. Move pits away from Sub @ 09:30. 09:30 - 12:00 2.50 MOB P PRE Move Rig to edge of Pad. Prepare to move to DS 01 -05. 12:00 - 19:00 7.00 MOB P PRE Work on Rig hydraulic drive system. Move Rig off location @ 14:00 hrs. Move Rig from DS 03 -36 to Ice road over Sag river. 19:00 - 20:30 1.50 MOB N WAIT PRE Wait for equipment to move snow from road at top of river for Rig passage. 20:30 - 00:00 3.50 MOB P PRE Move Rig to DS 01 -05. Arrive on location at 00:00 hrs 5/8/2007 00:00 - 05:00 5.00 MOB P PRE Sub arrived on location@ 00:00 hrs. Pits and rig camp arrived @ 05:00 hrs. Roads and Pads still building up location for proper Rig elevation. 05:00 - 00:00 19.00 MOB N WAIT PRE Sub, Pits, on location ready for rig up at 05:00. Waiting on site ' preparations to elevate pad to accomodate rig/wellhead. Rig on standby f /05:00 to 00:00. C/O brushes on drawworks motor, c� change pump liners f /5" to 5.5 ". Check and replace hydraulic Q�� 0 ���.(� hoses as needed on derrick ram, upper pipe skate. Replace electrodes on #1 boiler. Remove all but 4 bolts between bcA CrzSc,,,�.�rs 5 / �S � � bottom rams and mud cross for BOP adaptation to DS 1 -05. ��VV !j Kuskokwim camp start move f /DS -03 to G -Pad summer location at 20:00. 5/9/2007 00:00 - 12:00 12.00 MOB N WAIT PRE Sub, Pits, on location ready for rig up. Waiting on dirtwork to elevate pad in front of 1 -05 to accomodate rig/wellhead. Attempted to move rig up on elevated pad. Too small to turn rig on. Call for more gravel and extend elevated pad. Rig on standby. Moving Kuskokwim Camp to G -Pad. Held pre spud meeting w/WSL, tower pusher, all hands. CIO steam valves on cuttings box. Spot and level Kuskokwim camp on G pad. 12:00 - 16:30 4.50 MOB N WAIT PRE Wait on dirtwork to extend and elevate pad. Hold prespud meeting w/WSL, toolpusher,directional driller, all hands. 16:30 - 18:00 1.50 RIGU P PRE PJSM. Set mats on top of gravel 1 -05 pad extension /riser. Lay double layer of herculite and line cellar area. 18:00 - 22:00 4.00 RIGU P PRE Move and set rig 7ES over DS 1 -05B. 22:00 - 23:00 1.00 RIGU P PRE PJSM. Raise derrick. 23:00 - 00:00 1.00 RIGU P PRE RU: cattle chute, kelly hose, hang lower section of rear cellar doors. 5/10/2007 00:00 - 02:00 2.00 RIGU P PRE Spot pits to rig. Level pits. Tie in lines. Prepare pits to take on hot seawater. RU in cellar. 02:00 - 04:00 2.00 RIGU P PRE RU berms and liners for cuttings tank and spot tank. Ready to take on fluids. Accept rig at 04:00. 04:00 - 07:00 3.00 WHSUR P DECOMP RU berms and liners for additional 400 bbl. open top tiger tank for displacement of diesel and Arctic Pac. Take on 8.5 ppg 120 deg. F seawater. 07:00 - 10:00 3.00 WHSUR P DECOMP Pressure test lines t/tiger tank to 1500 psi. RU to reverse circulate 51 bbls diesel f /tubing. RU DSM lubricator. Pull BPV. RD DSM. 10:00 - 10:30 0.50 WHSUR P DECOMP Reverse circulate 51 bbls. diesel out of tubing pumping 70 bbls. 120 deg. seawater 3 bpm, 200 psi. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 2 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/10/2007 10:30 - 13:30 3.00 WHSUR P DECOMP RU and circulate down tubing and up IA. Take all returns to tiger tank, 3 bpm, 120 psi, pumping 1 drum Safe Surf 0 surfactant sweep. Follow w/398 bbls of hot seawater surface to surface. Shipped 290 bbls w /52 % diesel, 48% seawater f /tiger tank to FS1 for recycling. 13:30 - 14:30 1.00 WHSUR P DECOMP RD. BD circulating lines to tiger tank. 14:30 - 15:45 1.25 WHSUR P DECOMP RU DSM lubricator. Set TWC. RD lubricator. 15:45 - 17:00 1.25 WHSUR P DECOMP Test TWC f /below and 9 -5/8" x 5 -1/2" IA to 1000 psi and record on chart for 30 min. TWC /IA test good. See diesel /crude rising slowly (estimate 1/2 bbl in 1 hr.) f /20" x 30" annulus. Remove directly to tiger tank w /cellar pump. 17:00 - 18:30 1.50 WHSUR P DECOMP Put gage and double valve on 9 -5/8" x 13 -3/8" annulus and see 1400 psi. Bleed down to 0 psi and get 1 bbl. flow back to tiger tank. Test OA to 1150 psi f /30 mins and record on chart. Bled down to 1000 psi. in 30 mins. 18:30 - 19:00 0.50 WHSUR P DECOMP RD and BD test lines and lines to tiger tank. 19:00 - 21:00 2.00 WHSUR P DECOMP PJSM w /Cameron and hands. Cameron hand bled adapter void and control lines. Remove clamps and ND McEvoy Gen 1 tree. hanger threads. 70% han ected 21:00 - 22:00 1.00 WHSUR P DECOMP Cameron cleaned and inspected g corroded away. 22:00 - 00:00 2.00 WHSUR P DECOMP NU adaptor spool and modified BOP stack w/3 -1/2" x 6" variables on top, blind shear rams on bottom w /no mud cross or second set of rams on bottom to accomodate height of wellhead. Note: Diesel still rising slowly (estimate 1/2 bbl./hr.) up 20" x 30" annulus. Pumping to tiger tank w /cellar pump. 5/11/2007 00:00 - 12:00 12.00 WHSUR P DECOMP Continue to NU BOP stack. PJSM/THA w /welder and establish fire watch in truckshop. Add 4' to BOP riser in truckshop to reach KB height of rig floor w /modified BOP stack. Install riser on BOP stack. Pressure 13 -3/8" X 20" annulus to 300 psi. Took 1.5 bbls fluid. Hold 5 min. and pressure dropped to 230 psi. Pressure 230 psi to 500 psi with 1/4 bbls fluid. Hold 5 mins. Pressure dropped to 430 psi. No increased flow noted f /20" x 30" annulus resulting f /test. 12:00 - 13:30 1.50 WHSUR P DECOMP NU BOP stack. Run 1/2" conduit down 20" x 30" annulus and found ice plug at 12'. Connect steam line and melt ice to 50'. 20" x 30" annulus flowing slowed to f /1.5 bbls /hr to .75 bbls /hr. 13:30 - 20:00 6.50 WHSUR P DECOMP Test BOP. 250 psi low pressure, 4000 psi high pressure on choke manifold valves, upper and lower IBOP, floor valves. AOGCC presence at test waived by AOGCC representative Bob Noble. 20:00 - 22:00 2.00 WHSUR P DECOMP Test BOP. 250 psi low pressure, 2000 psi high pressure on blind /shear rams, choke and kill HCR valves and manual valves, top pipe rams, annular preventer. 2000 psi test approved by Jim Regg AOGCC 5 -11 -07 as requested by ODE due to poor conditon of 5 -1/2" hanger body. Test witnessed by Duncan Ferguson /Lowell Anderson BP WSLs and Larry Wurdeman /Gene Gibson Nabors tool /tower pushers. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 3 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/11/2007 22:00 - 23:30 1.50 WHSUR N WAIT DECOMP Wait on Drill Site Maintenance crew to complete other work before arriving to RU lubricator and pull TWC. Bring Camco cable spooling unit to floor and spot. 23:30 - 00:00 0.50 WHSUR P DECOMP RU Drill Site Maintenance lubricator and pull TWC. 5 -1/2" x 9 -5/8" annulus and 9 -5/8" x 13 -3/8" annulus = 0 psi. 5/12/2007 00:00 - 01:00 1.00 FISH P DECOMP PU Baker double spear for 5 -1/2" 17# and engage spear in 5 -1/2" tubing below 7" hanger. PU 105K # and pull hanger free. Pull hanger to floor w /100K #. Control lines attached and in good shape. Cut control lines and crimp ends. RU control line to spooling unit. 01:00 - 05:00 4.00 PULL P DECOMP Spool control line and POH w/5 -1/2" 17# 13Cr Fox tubing f /5100'. LD 1 SSSV. Retrieved total of 57 SS bands. 05:00 - 07:00 2.00 PULL P DECOMP POH with 116 joints 5 -1/2" 17# 13 CR tubing. -LD 1 GLM -Cut joint 23.91' 07:00 - 07:30 0.50 PULL P DECOMP Clear floor of tubing handling equipment 07:30 - 10:00 2.50 CLEAN P DECOMP Pickup Baker Fishing equipment from outside -M /U - 8 1/2" bit, 9 5/8" Casing Scraper, 2 x Boot Baskets, XO, Bumper jar, Oil Jar, XO and 9 x DC's 10:00 - 14:30 4.50 CLEAN P DECOMP RIH picking up 5" Drill pipe 1 x 1 to 5125' and tag up on top of 5 -1/2" tubing at 5125'. OA = 0 psi. OOA = 150 psi. 20" x 30" annulus fluid returns = 1.6 bbls /hr., 3/4" line steamed down to 70'. 14:30 - 15:30 1.00 CLEAN P DECOMP CBU. 548 gpm, 1142 psi. 15:30 - 16:15 0.75 CLEAN P DECOMP Spot 290 bbls. 9.8 ppg brine to well bore. 232 gpm, 80 psi. Monitor well. OK. 16:15 - 17:15 1.00 CLEAN P DECOMP Slip and cut 130' drilling line. BD topdrive. 17:15 - 19:15 2.00 CLEAN P DECOMP POI-Ito BHA. 19:15 - 20:45 1.50 CLEAN P DECOMP LD boot baskets, scraper, bit, jars, bumper sub, recovered 1 SS control line band in boot basket for a total lof 58 bands. 20:45 - 21:30 0.75 CASE N WAIT DECOMP Wait on E -line unit to complete work on other well. 21:30 - 23:30 2.00 CASE P DECOMP PJSM w/WSL, Schlumberger, tourpusher, all hands on E -line safety. RU e-line for USIT. 23:30 - 00:00 0.50 CASE P DECOMP RIH w /Eline. Run USIT 9 -5/8" casing f/5100' to surface. 5/13/2007 00:00 - 05:00 5.00 CASE P DECOMP Run USIT log f/5100' to surface. Top of cement in 9 -5/8" x 13 -3/8" 1220'. 9 -5/8" showing extensive external corrosion f/5100' to 2700'. Identified 47# casing bottom at 2020' to surface with 40# casing f/2020' to 5100'. 9 -5/8" casing backoff point picked at 1145'. 05:00 - 06:00 1.00 CASE P DECOMP POH and prepare to run stringshot. 06:00 - 09:00 3.00 CASE P DECOMP RIH w/4 strand stringshot and fire at 1145'. 09:00 - 10:00 1.00 CASE P DECOMP POH w /stringshot tools. 10:00 - 11:30 1.50 CASE P DECOMP RU and RIH w/9 -5/8" EZSV w /bridging plug. 11:30 - 14:45 3.25 CASE N DFAL DECOMP POH to troubleshoot GR/CCL. Can't get reading to surface. POH and disarm setting tool and find water inside GR/CCL upper adaptor. Found bad 0-ring. Hotshot backup adapters from Schlumberger shop Deadhorse. 14:45 - 15:45 1.00 CASE P DECOMP RU backup GR/CCL unit and Run 9 -5/8" EZSV w /bridging plug. Log in place and set at 4720'. 15:45 - 17:00 1.25 CASE P DECOMP POH and RD E -line. 17:00 - 18:00 1.00 CASE P DECOMP Test 9 -5/8" casing to 3500 psi f /30 min. and record on chart. Printed: 1/19/2009 4:14:33 PM 41) 111 BP EXPLORATION Page 4 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/13/2007 18:30 - 22:45 4.25 CASE P DECOMP PJSM. RIH w /5" drill pipe and 8 -1/4" multistring casing cutter. Locate 9 -5/8" collar at 1105' w /collar locator on casing cutter. Move down and locate collar at 1147'. PU to 1127' and cut casing, 55 rpm, 2K tq., 217 gpm, 660 psi, 45K PU, 45K SO, thru valve and au 50K ROT. RU and monitor OA u gauge in cellar. g g Casing jump at cut through. Pressure on OA went f/0 psi to 80 psi. 30 psi on drill pipe. Bleed pressure through choke to tiger tank. Pump 5 bbls. seawater down drill pipe. 0 psi on IA, 0 psi on OA, 0 psi on drill pipe. 22:45 - 00:00 1.25 CASE P DECOMP PJSM. RU Little Red Hot Oil Svc., Test lines to 3000 psi. Pump 120 bbls. 130 deg. diesel down drill pipe, and through casing cut up 9 -5/8" x 13 -3/8" annulus at 2.5 bpm, 1000 psi. 5/14/2007 00:00 - 00:30 0.50 CASE P DECOMP Continue pumping 120 bbls. 130 deg. diesel down drill pipe through cut in 9 -5/8" casing at 1127', and up 9 -5/8" x 13 -3/8" annulus 2.5 bpm, 1000 psi. 00:30 - 01:00 0.50 CASE P DECOMP Diesel in place. Let soak for 30 mins. RD /Release Hot Oil Svcs. 01:00 - 02:00 1.00 CASE P DECOMP Switch to rig pumps for displacement. Displace 9 -5/8" x 13 -3/8" annulus w/140 bbls. 8.5 ppg seawater, 126 gpm, 110 psi. 80% diesel, 20% crude in returns. No Arctic Pac. Pump and overboard to tiger tank until clean seawater back to surface. Shut down and clean all diesel out of tiger tank. Pump another 150 bbls of 8.5 ppg seawater to surface, 5 bpm, 330 psi. Total of 290 bbls. seawater pumped. Return fluid to flow station 1 for recycling. 02:00 - 03:00 1.00 CASE P DECOMP Switch pumps to drill pipe x 9 -5/8" annulus and circulate surface to surface x 2 w/140 bbls. 8.5 ppg seawater until clean. 03:00 - 03:30 0.50 CASE P DECOMP RD hoses, BD, and clear floor. Monitor well. OK. 8.5 ppg seawater in and out. 03:30 - 04:30 1.00 CASE P DECOMP POH. LD casing cutter. 04:30 - 07:00 2.50 WHSUR P DECOMP Install test plug. CO to 9 -5/8" rams. Test door seals to 2000 psi. 07:00 - 08:00 1.00 CASE P DECOMP MU 9 -5/8" spear assy. Stab into 9 -5/8" below hanger. Back out lock down screws. 08:00 - 09:00 1.00 CASE P DECOMP PU 250K. Work pipe. Circulate at 3 bpm, 45 psi. Could not pull hanger free. 09:00 - 09:30 0.50 CASE P DECOMP LD spear assembly. 09:30 - 11:00 1.50 CASE P DECOMP Mobilize and MU packoff pulling J tool. Pull 7" hanger spacer w /no overpull. 11:00 - 12:00 1.00 CASE P DECOMP PU 9 -5/8" spear. Attempt to pull casing. PU 250K. Failed. LD spear. 12:00 - 13:30 1.50 CASE P DECOMP MU 8.25" multi- string casing cutter and position 25' below rig floor in 9 -5/8" casing. Make cut w/325 gpm, 325 psi, 60 rpm, 1K tq. LD casing cutter. Knives showed evidence of good cut. LD casing cutter. 13:30 - 14:30 1.00 CASE P DECOMP MU 9 -5/8" spear. Latch spear in casing slips /hanger /pack -off and attempt to pull 9 -5/8" stub. Pull 125K several times and workpipe. Failed to pull free. Release and lay down spear. 14:30 - 15:00 0.50 CASE P DECOMP MU 9 -5/8" packoff assy. on 5" drill pipe and set at 32' below cut at 25'. 15:00 - 16:00 1.00 CASE P DECOMP Circulate and displace 8.5 ppg seawater w/260 bbls. 9.8 ppg brine through casing cut at 1127'. 220 gpm, 37 psi. Brine wt. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 5 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2007 15:00 - 16:00 1.00 CASE P DECOMP 9.8 ppg in and out. 16:00 - 16:30 0.50 CASE P DECOMP LD packoff assembly. Blow down top drive. 16:30 - 21:30 5.00 CASE P DECOMP PJSM. ND BOP. Remove choke, kill line, HCRs and related 1 adaptor flanges. Remount all to mud cross. 21:30 - 23:00 1.50 CASE P DECOMP PJSM. ND Cameron 5 -1/2" x 7" x 13 -3/8" Unihead and adaptor flange packoff and 3.90' stub of 9 -5/8" casing. 23:00 - 00:00 1.00 CASE P DECOMP MU Cameron 20" x 13 -3/8" 5K casing spool. 5/15/2007 00:00 - 04:00 4.00 CASE P DECOMP NU BOP stack to mud cross. Replace blind flanges on rams. NU BOP stack to Cameron adaptor flange. 04:00 - 06:30 2.50 WHSUR P DECOMP RIH w /test plug to test flanges 250 psi low and 2000 psi high. Test plug would not seat in profile. Mobilize new test plug f /Cameron. Have welder adjust bell nipple. Pull test plug and test bottom flanges w /1000 psi against 13 -3/8" casing. Casing spools leaking. Tighten bolts and stop leaks. 06:30 - 08:30 2.00 BOPSUF N SFAL DECOMP Install 2nd test plug f /Cameron. Test BOP door seals to 2000 psi. Tighten gland nuts on 13 -3/8" adaptor flange. Repair fitting on Koomey line. RD test equipment. 08:30 - 09:00 0.50 CASE P DECOMP MU wear bushing to run tool and install bushing. PU 9 -5/8" spear assy. 09:00 - 10:00 1.00 CASE P DECOMP PU and pull casing w/70K. No overpull. CBU. 210 gpm, 35 psi. 10:00 - 10:30 0.50 CASE P DECOMP LD spear. MU casing running equipment. 10:30 - 16:00 5.50 CASE P DECOMP POH laying down 9 -5/8" casing 1 x 1. Breakout tq. average 50K. LD total of 28 jts. + 21.81' stub. Clean cut on stub end w /multistring cutter w /1/2 moon mark from casing dropping back to stub when second cut made at surface allowed casing to drop back on top of stub. Casing in good condition. 16:00 - 17:00 1.00 CASE P DECOMP RD casing running equipment. 17:00 - 19:00 2.00 BOPSUF P DECOMP Pull wear bushing. Set test plug, change top rams to 3 -1/2" x 6" variables. test door to 1000 psi. RD test equipment. Install wear bushing. 19:00 - 22:45 3.75 BOPSUF P DECOMP MU 12" drag tooth shoe, 1 jt. 11 -3/4" washover pipe, w/8 -1/2" internal mill to dress inside of 9 -5/8 ", double pin sub, 4 -1/2" IF Box x 6 -5/8" Pin, 11 -3/4" boot basket, double pin sub, 13 -3/8" casing scraper, bit sub, float sub, lubricated bumper sub, oil jar, XO, nine 6 -1/4" drill collars, XO to 5" drill pipe. 22:45 - 00:00 1.25 BOPSUF P DECOMP RIH washover BHA assy. and tag top of 9 -5/8" cut jt. at 1127' and wash down to 1156', 238 gpm, 222 psi, 30 rpm 1K tq, 65K ROT, 65K PU, 67K SO. No problem getting over cut jt. 5/16/2007 00:00 - 00:30 0.50 CASE P DECOMP Circulate Hi -Vis Sweep around 235 gpm, 250 psi. See fine mill cuttings back on ditch magnets. 00:30 - 01:00 0.50 CASE P DECOMP POH and rack back 6 -1/4" drill collars. 01:00 - 02:00 1.00 CASE P DECOMP LD washover /scraper BHA. 02:00 - 03:00 1.00 CASE P DECOMP Clear rig floor. 03:00 - 05:00 2.00 CASE P DECOMP PU 9 -5/8" backoff BHA w/4 -1/2" bullnose, XO sub, nine 6 -1/4" drill collars, XO sub, 6 -5/8" blanking sub, 8" lower anchor, back off power section, 8" upper anchor, XO sub, 4 -1/2" pump out sub. 05:00 - 05:30 0.50 CASE P DECOMP RIH w /backoff BHA. 05:30 - 07:00 1.50 CASE P DECOMP Locate backoff tool w /upper anchor above and lower anchor below collar at 1147'. RU test pump and backoff stub 6 turns. 07:00 - 08:00 1.00 CASE P DECOMP RD test pump, release anchors, drop ball. Pressure to 1400 psi and open circ sub. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 6 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/16/2007 07:00 - 08:00 1.00 CASE P DECOMP Circulate surface to surface x 2. 550 gpm, 230 psi. 08:00 - 09:30 1.50 CASE P DECOMP POH. LD back off assembly. Rack back drill collars. 09:30 - 10:00 0.50 CASE P DECOMP PU spear and RIH to 1127'. Engage top of stub. 10:00 - 10:30 0.50 CASE P DECOMP Backoff fish. POH to 511'. 10:30 - 11:00 0.50 CASE P DECOMP Pressure test 20 x 13 -3/8" annulus to 500 psi. OK. 11:00 - 12:00 1.00 CASE P DECOMP Continue to POH and LD spear and stub. Stub = 19.35' w /pin down. 12:00 - 15:30 3.50 CASE P DECOMP MU mule shoe, xo, nine 6 -1/4" drill collars, xo, 1 stand 5" drill pipe and 13 -38" RTTS storm packer and RIH to 36'. Monitor 13 -3/8" x 20" annulus. OK. Set storm packer at 36' and pressure test over top of packer to 500 psi. Chart for 5 mins. Release f /storm packer and P01-1w/running tool. 15:30 - 18:45 3.25 CASE P DECOMP RU 13 -3/8" Baker multistring cutter f/13 -3/8 ", RIH and cut casing at 25.59'. 180 gpm, 1026 psi, 2K tq., 27K ROT. PON and LD cutter. Knives indicate cut occurred. 18:45 - 21:30 2.75 BOPSUE P DECOMP Pull and inspect wear bushing. Blow down top drive and kill line. PJSM. ND BOP. to bottom rams. 21:30 - 23:00 1.50 WHSUR P DECOMP Remove Cameron hub flange adaptor. ND Gen 1 Permafrost split head. Suck out all fluid possible. Expected release of 10 gal. diesel /water mixture to cellar inside of herculite containment. Had vac truck hose ready and sucked it up. Notified 5700. 23:00 - 00:00 1.00 WHSUR P DECOMP ND 30" x 20" casing alignment bracket. Prep cellar to cut 30" casing. 5/17/2007 00:00 - 02:00 2.00 WHSUR P DECOMP Discover that 30" casing has flanges welded on it on two sides. Can not rig up Wachs cutter. PJSM w /tool pushers, WSLs, crew and consult ODE. Decision made to use torch to cut 30 ". Mobilize welder. 02:00 - 02:30 0.50 WHSUR P DECOMP PJSM w /welder, all hands, WSL, tourpusher. Task Hazard Assessment. Establish firewatch. Monitor LEL in both annuli. 02:30 - 05:00 2.50 WHSUR P DECOMP Cut 30 ". Remove 30" casing head f /cellar. Build and install gussets to centralize 20" in 30" and 13 -3/8" in 20" and weld in place. 05:00 - 06:00 1.00 WHSUR P DECOMP RU Wachs cutter and cut 20 ". 06:00 - 08:30 2.50 WHSUR P DECOMP Recentralize 13 -3/8" in 20" and weld temporary gusset. Install one piece herculite cellar box barrier f /cement job. 08:30 - 10:30 2.00 WHSUR P DECOMP RIH w/192' of 1 -1/4" CS Hydril in 20" x 13 -3/8" annulus. 10:30 - 11:00 0.50 WHSUR P DECOMP RU to cement. 11:00 - 14:00 3.00 WHSUR N WAIT DECOMP Waiting on cementers /cement. 14:00 - 15:00 1.00 WHSUR P DECOMP RU to cement 20" x 30" and 13 -3/8" x 20" annuli. 15:00 - 16:30 1.50 WHSUR P DECOMP PJSM w /Schlumberger, WSL, Toolpusher, all hands. Cement 20" x 30" annulus down welded jts of previously installed 3/4" pipe set at 70' w/32 bbls. 15.7 ppg cement. 60 gpm, 500 psi. Take returns to super suckers and vac trucks. CIP at 16:30. Let 3/4" pipe fall into cement below surface at end of job. 16:30 - 18:00 1.50 WHSUR P DECOMP Cement 13 -3/8" x 20" annulus at 161' down 1 -1/4" CS Hydril tubing. Pump 47 bbls. of 15.7 ppg cement, 84 gpm, 200 psi. Take returns to super suckers and vac trucks. CIP at 18:00. 18:00 - 18:30 0.50 WHSUR P DECOMP RD cementers. LD 1 -1/4" CS Hydril tubing. 18:30 - 19:00 0.50 WHSUR P DECOMP Monitor well. Water channeling up through cement in 20" x 30" annulus. Annulus flowing 1.8 bbls /hr. 19:00 - 20:30 1.50 WHSUR C DECOMP RIH w/65' of 1 -1/4" CS Hydril. Wash cement f /20" x 30" Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 7 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/17/2007 19:00 - 20:30 1.50 WHSUR C DECOMP annulus to 70' until returns are clean H2O. 126 gpm, 182 psi. Work pipe every 15 minutes after pumps shut down. 20:30 - 00:00 3.50 WHSUR C DECOMP Consult w /town team. Mobilize GBR welders and fabricate plate to cover 20" x 30" annulus to cement downsqueeze through 1 -1/4" CS Hydril. Consult w /Schlumberger and mobilize accelerated cement blend f /squeeze job. 5/18/2007 00:00 - 02:00 2.00 WHSUR C DECOMP Fabricate 30" conductor pipe flange plate and attempt to circulate to test f /leaks. Put 50 psi pressure test on 20" x 30" annulus before squeeze cement job. 02:00 - 03:00 1.00 WHSUR C DECOMP Weld leaking at surface shut down and repair. Retest. 50 psi. Water begins seeping up alongside 30" into cellar. Bleed off pressure and blow down. 03:00 - 03:30 0.50 WHSUR C DECOMP RD cement line. Consult w /town team. 03:30 - 08:00 4.50 WHSUR C DECOMP Decision made to locate bottom ends of bolt on flanges. Fabricate plates to weld and cover flange sections over. Dig down determined flanges to be 48" x 8 ". Pressure test to 45 psi to verify flanges as leak points. Mobilized welder to fabricate flange plate cover sections. 08:00 - 09:00 1.00 WHSUR C DECOMP Consult w /town team, continue fabrication of repair sections for 30" flanges. Dig cellar down. Find old cellar box and verify safety specifications for working at depths in enclosed area w /ADW HSE advisor. 09:00 - 15:00 6.00 WHSUR C DECOMP Weld 1/2" plate on 30" casing flange sections. RU lines, circulate lines down 30" back to cuttings box. 15:00 - 16:00 1.00 WHSUR C DECOMP PJSM w/WSL, toolpusher, Schlumberger, Veco drivers, all hands. Test lines to 500 psi. Pump 7 bbls H2O to cuttings box to verify conductor full. Attempt to test conductor to 100 psi. Established injection rate of .10 bbl /min at 75 psi. 16:00 - 16:30 0.50 WHSUR C DECOMP See 3 pinhole leaks in plate welded on top of conductor. Inspect welds f /cracks. Weld pinholes. 16:30 - 17:30 1.00 WHSUR P DECOMP Mix and circulate 15.7 ppg AS1 accelerated cement down 1 -1/4" CS Hydril set at 60' and welded in place on 30" flange plate w/1502 thread up. Circulate at 84 gpm, 175 psi. Take returns via cementing hose tied to 1502 thread on nipple welded to top of 30" flange. Send returns to cuttings box. Check wt of cement in returns at cuttings box: with returns of 29 bbls = 14.0 ppg, 36 bbls. = 15.2 ppg, 39 bbls = 15.2 ppg, 41 bbls = 15.5 ppg, 57 bbls = 15.5 ppg. 17:30 - 18:30 1.00 WHSUR P DECOMP Shut in valve on on 1 -1/4 CS Hydril side of 30 ". Switch to discharge side valve and squeeze cement away from top of 30" conductor pipe at .10 bbls. /min 75 psi and pump a total of 1.5 bbls during this segment of squeeze job. 18:30 - 20:00 1.50 WHSUR P DECOMP Clear lines and mix 1.5 bbls of 15.7 ppg AS1 accelerated blend cement. Pump .10 bbl /min at 90 psi for 2 minutes. Shut in and hold. Steady slow bleed off occurring. Bring pumps back on. Pump .7 bbls at 80 psi and shut in f /10 min. Bled down 20 psi. Pressure up to 90 psi and unable to move cement. Shut in and bled down to 60 psi in 15 min. Pressure up to 95 psi and cement locked up. Shut in valves at wellhead on injection and discharge side of 30 ". RD and BD lines. 20:00 - 21:30 1.50 WHSUR P DECOMP RU and and stand back 20" x 13 -3/8" riser in cellar. Fill cellar box to grade w /gravel to avoid fall hazard during installation of riser. Printed: 1/19/2009 4:14:33 PM 1 BP EXPLORATION Page 8 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/18/2007 21:30 - 00:00 2.50 WHSUR P DECOMP Weld 20" x 13 -3/8" riser in place. Note: during welding process clear water began to seep into cellar box f /alongside 30 ". Pump out w /cellar pump to cuttings box to determine flow rate at 1.0 bbls /hr. 5/19/2007 00:00 - 02:00 2.00 WHSUR P DECOMP Continue welding 20" x 13 -3/8" riser to stub. 02:00 - 03:00 1.00 CASE P DECOMP PU running tool, RIH, pull RTTS stormpacker set at 36'. No pressure below noticed at release. LD stormpacker and rack back 3 stands of drill collars and 1 stand of 5" drill pipe. 03:00 - 04:30 1.50 CASE P DECOMP RU to run 9 -5/8" 47" TCII L -80 tieback string to 1147' w / /torque turn equipment. Mobilize welder to repair leak in riser at original weld point. Fill riser and check same. Ok. 04:30 - 07:30 3.00 CASE P DECOMP RIH w/ 9 -5/8" tieback casing w /Baker tieback triple thread w /cutlip guide to 1148'. PU 73K, SO 70K, tq. 1.5K. Optimum makeup torque 17.5K ft. lbs. Triple thread dressed w /pin down to screw in to collar looking up after backoff operation. 07:30 - 08:30 1.00 CASE P DECOMP Begin slow rotation and work cut lip guide shoe down over box end looking up. Rotate 15 turns w/1.5 K tq. and torque built to 10K. Work pipe up and down to get torque down to connection point. Pull test to 250K. OK. 08:30 - 10:30 2.00 CASE P DECOMP RU cement head. Test to down 9 -5/8" casing to 1500 psi and hold f/5 min. Test to 2000 psi and hold f/25 mins. Both tests f /ES Cementer plug at 1137' to surface. Pressure test limited to 2000 psi to avoid premature opening of ES Cementer. PJSM w /service companies, WSL, toolpusher, hands while waiting on pressure test. After 30 min test increase pressure to 3250 psi to open ES cementer f/9 -5/8" casing to 9 -5/8" x 13 -3/8" annulus. Circulating pressures too high, ES cementer not completely open. RD cement head and drop mechanical opening "bomb ". RU cement head. CBU x2, 10 bpm, 645 psi. 10:30 - 11:30 1.00 CASE P DECOMP Pump 5 bbls. fresh H2O. Pump leak. Repair leak. Test lines to 4500 psi. 11:30 - 12:00 0.50 CASE P DECOMP Pump 74.2 bbls. 15.7 ppg Articset cement and additives. Drop ES cementer closing plug. Follow w /10 bbls. fresh H2O displacement. Switch to rig pumps for rest of displacement. Pump 72.5 bbls 9.8 ppg brine at average rate of 252 gpm. Slow pumps to 2 bpm w /displacement at total of 73.5 bbls away. Bump plug and pressure up w/83.1 bbls away. Calculated volume for displacement = 83.97 bbls. FCP = 400 psi. Increase pressure to 1200 psi and see ES cementer close. 12:00 - 12:30 0.50 CASE P DECOMP Increase pressure to 1700 psi. Hold 5 min. Bleed back and check f /backflow. No backflow through ES cementer. 12:30 - 13:00 0.50 CASE P DECOMP RD cement head and lines. BD lines, RD casing equipm,ent. 13:00 - 18:30 5.50 CASE P DECOMP Maintain string wt. + 100K # overpull on casing. WOC to reach 500 compressive strength. Prep cellar for Wachs cutting operations. 18:30 - 00:00 5.50 CASE P DECOMP PJSM w /FMC, cut 13 -3/8" riser and raise up 2' to make 1st cut on 9 -5/8 ". SO on 9 -5/8" casing. RU Wachs external casing cutter. Make top cut on 9 -5/8" casing. Remove stub. Remove and LD 20" riser. Prepare Wach's cutter to make bottom cut on 13 -3/8" casing. 5/20/2007 00:00 - 02:30 2.50 WHSUR P DECOMP RU Wach's casing cutter and cut lower cut on13 -3/8" casing as Printed: 1/19/2009 4:14:33 PM 1 BP EXPLORATION Page 9 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/20/2007 00:00 - 02:30 2.50 WHSUR P DECOMP close as possible to 20" casing stub below. RU cutter on 9 -5/8" per measurements requested by DS 1 pad operator to match adjacent wells. Make final cut on 9 -5/8" to position and weld on bell nipple adaptor. 02:30 - 08:30 6.00 WHSUR P DECOMP Prepare 9 -5/8" bell nipple /casing for welding per procedures established in pre -work process meeting, QW -482 Welding procedure specification and preheat/postheat instruction WPS MWP -24 -1 PWHT. QC inspector on location as requested in procedure. Heat stress unit failed. Had to replace. Generator went down at 08:30. 08:30 - 12:00 3.50 WHSUR N SFAL DECOMP RU new generator. Temperature dropped under heat blanket f/480 deg. to 300 deg. Troubleshoot Cooper heat machine, damaged from generator, swap out Cooper heat machine. 12:00 - 13:30 1.50 WHSUR P DECOMP New generator on line at 12:00. Begin preheat process. Progress very slow. 13:30 - 15:30 2.00 WHSUR N SFAL DECOMP Remove insulating blanket while tacking bell nipple in place, noted inside blanket not shutting off. QC checked temperature w /Fluke meter, 9 -5/8" casing temperature at 807 deg. Trouble shoot and find heating blanket failure. Consult w /BP QA/QC, & mech. engr., WSL, electricians, welders. Remove inner blankets f /heat stress unit at 15:00. 15:30 - 20:30 5.00 WHSUR P DECOMP Begin pre heat with 2 blankets on transition nipple only. Heat rising as follows: 17:15 = 307deg./412 deg. pipe /bellnipple, 18:30 357 deg/434 deg. pipe /bellnipple. Thermocouple failed. Repair. Reposition heat stress unit lower on 9 -5/8" casing and open heat passage by arranging heat blanket. Rapid improvement. 18:50 = 360 deg. /460 deg. pipe /bellnipple, 19:50 = 460 deg/470 deg. pipe to bellnipple., 20:15 = 457 deg. /515 deg. 20:30 - 00:00 3.50 WHSUR P DECOMP Begin welding process with inspector and electricians maintaining heat limits per procedure. Finished welding lower /external weld at 00:00. Check heat levels. Temperature within required limits. 5/21/2007 00:00 - 02:00 2.00 CASE P DECOMP Temperatures holding within limits of 450 -650 F. Begin weld on upper internal weld. 02:00 - 11:00 9.00 CASE P DECOMP Begin post weld heat up and cool down per MWP -24 -1 PWHT. 11:00 - 12:00 1.00 CASE N SFAL DECOMP Water dripped on wellhead. Shutdown. 12:00 - 13:00 1.00 CASE N SFAL DECOMP Replaced heat blanket. Per mechanical engineer, bring temperature up and resoak at 1250 deg. 13:00 - 16:30 3.50 CASE N SFAL DECOMP Thermocouple failed. Per mechanical engineer, bring temperature up and resoak at 1250 deg. 16:30 - 20:00 3.50 CASE N SFAL DECOMP Bring temperature back up to 1250 and begin heat soak process. 20:00 - 21:00 1.00 CASE P DECOMP Soak at 1250 deg f/1 hr. 21:00 - 00:00 3.00 CASE P DECOMP Start cooldown process f/1250 deg. with no more than 200 deg. cool down /hr. to 800 deg. Heat blanket and recording equipment functioning as expected on circuits 1 and 4. Circuit #3 nonfunctional w /thermocouple disconnected. Temperature cooling within range prescribed in procedure. Rig manintenance f/24 hrs: Replace traction motor brushes, check bearing tolerances on draw works gears. Service Printed: 1/19/2009 4:14:33 PM 1 • BP EXPLORATION Page 10 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2007 21:00 - 00:00 3.00 CASE P DECOMP topdrive and iron roughneck. Drain oil and change out chains on #1 and #2 mud pumps. Install DSA to casing spool and tubing spool. Flow of water from outside 30" drive pipe slowed f /1.0 bbls /hr to .7 bbls /hr (16 bbls f /day). 23:15 # 4 thermocouple readout = 857 F # 1 thermocouple readout = 696 F 5/22/2007 00:00 - 12:00 12.00 CASE P DECOMP Cool down process on Bell Nipple. 00:15 # 4 Thermocouple readout = 754 F # 1 Thermocouple readout = 599 F 01:15 # 4 Thermocouple readout = 663 F # 1 Thermocouple readout = 462 F 02:20 # 4 Thermocouple readout = 585 F # 1 Thermocouple readout = 386 F 04:10 # 4 Thermocouple readout = 489 F # 1 Thermocouple readout = 385 F 07:20 # 4 Thermocouple readout = 280 F # 1 Thermocouple readout = 230 F 12:00 # 4 Thermocouple readout = 195 F # 1 Thermocouple readout = 160 F NOTE: # 4 Thermocouple readout is on the Bell Nipple. # 1 Thermocouple readout is on the 9 5/8" casing. All changes / failures of Thermocouplers are recorded on Veco QC log (Jim Wiederrich). 12:00 - 18:00 6.00 CASE P DECOMP Continue to cool down Bell Nipple. Remove DP from pipe shed. Load shed w/ Kill string. 18:00 - 00:00 6.00 CASE P DECOMP 18:00 # 4 Thermocouple readout = 150 F # 1 Thermocouple readout = 100 F Remove heating blankets. Grind and dress two weld areas for NDE Hardness test to be performed tonight. Rig crews on cellar watch and general maintenance duties. Brine (NaCI) weight = 9.8 ppg. 5/23/2007 00:00 - 01:15 1.25 CASE P DECOMP Century Inspection services perform NDE hardness tests on Bell Nipple. BP -Mech Eng on location Brian Van Dorn inpects weld - OK. Will contact BPQA (Ed Pechacer) ASAP. 01:15 - 01:30 0.25 CASE P DECOMP Ed Pechacer gives go ahead. Welds are good. 01:30 - 02:45 1.25 WHSUR P DECOMP Mobilize FMC service hand to location for N2 testing of Bell Nipple. 02:45 - 05:00 2.25 WHSUR P DECOMP PJSM w/ FMC, Rig crew & BP rep on N2 test on Bell Nipple. Rig up N2 kit. Test Bell Nipple to 1450 psi f/ 15 minutes - Pass. N/U Well head. Test seals to 1000 psi f/ 15 minutes - Pass. 05:00 - 07:00 2.00 BOPSUF P DECOMP N/U BOPE. 07:00 - 08:00 1.00 BOPSUF P DECOMP R/U to test BOPE. 08:00 - 14:30 6.50 BOPSUF P DECOMP Test BOPE. ( Wiitness of test waived by Jeff Jones- AOGCC). On site witnesses - BP- Chris Clemens & NAD- Chris Weaver. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 11 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/23/2007 08:00 - 14:30 6.50 BOPSUF P DECOMP Test BOPs @ 250 psi- Lo / 4000 psi- High. Attempt to test Annular w/ 3 1/2" DP. Function Bag several times - Fail. Brine wt (NaCI) = 9.8 ppg. 14:30 - 20:30 6.00 BOPSUF N SFAL DECOMP PJSM. Mobilize tools & seals. Change out Bag element. Pull piston and replace seals. 20:30 - 22:30 2.00 BOPSUF P DECOMP R/U test equipment. On sie witnesses BP- Dan Shearer, NAD- Biff Perry. Test Annular to 250 / 3500 psi w/ 3 1/2" & 5" test joints - Pass. Test Koomey - Pass. R/D & Blow down test equipment. Instal wear bushing. 22:30 - 00:00 1.50 CLEAN P DECOMP P/U & M/U 8 1/2" bit & BHA. RIH t/ 415' md. 5/24/2007 00:00 - 00:30 0.50 CLEAN P DECOMP RIH t/ 1,075' md. 00:30 - 01:00 0.50 CLEAN P DECOMP Break circulation. Brine (NaCI) wt = 9.8 ppg Chain slap in both pumps (both just had chains replaced). Inspect pumps and adjust. 01:00 - 02:00 1.00 CLEAN P DECOMP Tag cement @ 1,100' md. Wash down to ES- Cementer CO 1,135' md. Drill out ES- Cementer. P/U = 63K, S/O = 63K 250 gpm, 50 RPM, 15K -20K WOB, 1.5K Tq. 02:00 - 03:00 1.00 CLEAN P DECOMP Circulate brine for cement cleanout. Pump high viscosity sweep (20 bbls @ 300 vis) & circulate clean. 281 gpm / 250 psi 03:00 - 04:00 1.00 CLEAN P DECOMP RIH to 4,656' and and wash down to EZSV Bridge plug CO 4,720' md. Tag EZSV @ 4,721 'md (witness AOGCC - Bob Noble & BP rep Dan Shearer). 04:00 - 05:30 1.50 CLEAN P DECOMP Pump high viscosity sweep (30 bbls © 270 vis) & circulate clean while working junk baskets. 280 gpm / 370 psi. P/U wt = 125K, SO wt = 120K. 05:30 - 06:30 1.00 CLEAN P DECOMP R/U to test 9 5/8" casing to 3500 psi. (Witness AOGCC -Bob Noble & BP rep Dan Shearer). Test 9 5/8" casing to 3500 psi. / f/ 30 minutes w/ 9.8 ppg Brine (NaCI). 06:30 - 08:30 2.00 CLEAN P DECOMP PJSM. Pump dry job & POH. 08:30 - 09:30 1.00 CLEAN P DECOMP UD 9 5/8" casing Scraper BHA. Clean & clear floor. 09:30 - 10:00 0.50 CLEAN P DECOMP PJSM. R/U wireline equipment, P/U tools. 10:00 - 16:30 6.50 CLEAN P DECOMP Run temperature log on E -line down to 4,721' and © 30 ft / min- Inconclusive. Log up from 4,721' and © 80 ft/min to 1,700' and then at 30 ft/min to surface POH to surface, monitor, Relog down to 1,700' and © 30 ft/min. POH.- Inconclusive. 16:30 - 17:00 0.50 DHB P DECOMP FI/U 3 1/2" Tbg handling equipment. 17:00 - 18:30 1.50 DHB P DECOMP PJSM w/ BP rep & crew. M/U plug catcher. P/U 484' of 3 1/2" NSCT. Printed: 1/19/2009 4:14:33 PM 110 BP EXPLORATION Page 12 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 5/24/2007 18:30 - 19:00 0.50 DHB P DECOMP R/D 3 1/2" Tbg handling equipment. 19:00 - 21:00 2.00 DHB P DECOMP RIH w/ 5" DP out of derrick to 4,720' md. Tag EZSV @ 4,721' md. P/U 2 feet off tag depth. 21:00 - 21:30 0.50 DHB P DECOMP R/U cement head. PJSM w/ BP rep, NAD TP, SLB, drivers & rig crew. 21:30 - 22:30 1.00 DHB P DECOMP Circulate hole to balance mud weight. 9.8 ppg in - 9.8 ppg out. 315 gpm / 500 psi. 22:30 - 23:00 0.50 DHB P DECOMP Pump balanced P & A plug w/ tail pipe @ 4,719' md. -Pump 3 bbls water to PT lines to 4000 psi. -Pump 10 bbls of 12.5 ppg Mud Push. -Pump 7.5 bbls of 15.8 ppg Cement. -Pump 2.8 bbls of 12.5 ppg Mud Push. 23:00 - 23:30 0.50 DHB P DECOMP Displace cement w/ 73.5 bbls of 9.8 ppg Brine (NaCI). 23:30 - 00:00 0.50 DHB P DECOMP R/D cement line. POH slowly for 5 stands to 4,257' md. 5/25/2007 00:00 - 00:30 0.50 DHB P DECOMP Continue to POH slowly for 5 stands to 4,257' md. 00:30 - 01:30 1.00 DHB P DECOMP Drop wiper dart. Circulate out residual cement. 450 gpm / 530 psi. NaCI / Brine wt = 9.8 ppg. Pump dry job. 01:30 - 06:30 5.00 DHB P DECOMP UD 5" & 3 1/2" DP. Pull wear ring. 06:30 - 07:30 1.00 DHB N RREP DECOMP Skate drive relay failed. Repair same. 07:30 - 08:30 1.00 RUNCOMP RUNCMP PJSM. w/ BP rep and crew. M/U 4 1/2" WLEG. Run 4 1/2" NSCT, 12.6 #, L -80 Kill String. M/U Tq 4000 ft / lbs. 08:30 - 10:30 2.00 RUNCOMV RREP RUNCMP Upper skate extension sensor eye failure. Repair same. 10:30 - 13:30 3.00 RUNCOMP RUNCMP Continue to run 4 1/2" tbg to 2,997' md. 13:30 - 14:30 1.00 RUNCOMP RUNCMP M/U TCII landing jt to hanger. Land kill string @ 25.15' RKB. PU wt= 57K, SOW= 55K. RILDS and torque. 14:30 - 15:30 1.00 WHSUR P RUNCMP FMC to Install TWC. Test from below to 1000 psi. f/ 5 minutes. Blow down lines. 15:30 - 19:30 4.00 WHSUR P RUNCMP N/D BOPE, N/U Dry hole tree. and test same to 5000 psi. for 10 minutes. 19:30 - 20:30 1.00 WHSUR P RUNCMP DSM to Pull TWC w/ lubricator.. 20:30 - 23:00 2.50 WHSUR P RUNCMP R/U Little Red and reverse in 152 bbls of diesel and U -tube. Install BPV w/ DSM and test from below to 1000 psi. 23:00 - 00:00 1.00 WHSUR P RUNCMP Secure wellhead and tree with proper flanges,valves and gauges. Q l -O s Wes,` \gcs�,� Off load all rig fluids. Release rig at Midnight. 12/19/2008 04:00 - 05:00 1.00 RIGD P PRE PJSM. Rig down pit module and sub base. 05:00 - 08:30 3.50 MOB P PRE PJSM. Move cuttings box and pits. Jack up sub and move from 01 -34 to 01 -05. Line up sub and pull ahead. Lay down herculite. Spot sub and close cellar doors. 08:30 - 14:00 5.50 RIGU P PRE Spot pits and set cuttings box. Rig up interconnect. Move and spot truck shop, welding shop, rig camp, MWD shack and Mud ©t - O c- shack. Continue to rig up. Go over pre -spud checklist. Bring seawater into pits. 14:00 - 14:30 0.50 RIGU P PRE PJSM. Hold pre -spud meeting. Rig accept at 1400 hours. 14:30 - 17:30 3.00 WHSUR P DECOMP PJSM. Hig up seconaary annulus valve and test lines. Test annulus to 3500 psi for 30 minutes. Lost 100 psi in the first 15 minutes, 40 psi in the second 15 minutes - PASS. Blow down Printed: 1/19/2009 4:14:33 PM • BP EXPLORATION Page 13 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2008 14:30 - 17:30 3.00 WHSUR P DECOMP and rig down lines. 17:30 - 18:30 1.00 WHSUR P DECOMP PJSM. Riq up DSM lubricator. Test to 500 psi - OK. Pull BPV. RD. 18:30 - 22:00 3.50 WHSUR P DECOMP PJSM. Reverse out freeze protect until clean at 3 bpm with 220 psi. Swap lines and pump long way at 4 bpm with 100 psi until clean of diesel. Verify well is dead. Blow down lines. 22:00 - 23:30 1.50 WHSUR P DECOMP Run in TWC. Test from above and below to 1000 psi - OK. Blow down and rig down lines. 23:30 - 00:00 0.50 WHSUR P DECOMP PJSM. Nipple down tree. 12/20/2008 00:00 - 02:30 2.50 WHSUR P DECOMP PJSM. Nipple down tree. Check threads on hanger. Threads in good shape. Took 7 -1/2 turns to make up. 02:30 - 03:30 1.00 WHSUR N WAIT DECOMP Waiting on Double Stud Adapter. 03:30 - 08:00 4.50 BOPSUF P DECOMP PJSM. Nipple up BOP stack and equipment. 08:00 - 16:00 8.00 BOPSUF P DECOMP PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Lou Grimaldi with AOGCC. Test witnessed by WSL's Dick Maskell and Joey LeBlanc and Toolpusher Cleve Coyne. Test upper rams with 4" and 4 -1/2" test joints. Test Hydril with 4" test joint. Lower rams to be tested after pulling kill string. 16:00 - 18:00 2.00 DHB P DECOMP PJSM. Riq up DSM lubricator. Test to 500 psi - OK. Pull TWC. RD. 18:00 - 23:30 5.50 PULL P DECOMP PJSM. RU tubing equipment. Run in landing joint. MU top drive. Verify annulus is dead. Back out lock down screws. Pull hanger to the rig floor with 58k. Break out and lay down. POOH laying down 4 -1/2" NSCT kill string. Rig down handling equipment. Clear and clean floor. 23:30 - 00:00 0.50 BOPSUF P DECOMP Rig up 4" test joint and test plug. RIH. Line up to test lower rams. 12/21/2008 00:00 - 02:00 2.00 BOPSUF P DECOMP 'JSM. Rig up and test lower rams with 4" test joint. Test to 250 psi low, 3500 psi high as per AOGCC. Test witness waived by Lou Grimaldi with AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Ken Helf. Run in wear ring. 02:00 - 03:30 1.50 CLEAN P DECOMP PJSM. Rig up handling equipment. PU cement drill out assembly. 03:30 - 05:30 2.00 CLEAN P DECOMP RIH with drill out assembly: 8 -1/2" mill tooth bit, 9 -5/8" casing scraper, bit sub, float sub, drill collars, jars and HWDP to 769'. Up and down weight 67k. 05:30 - 07:30 2.00 CLEAN P DECOMP RIH picking up 4" drill pipe to 1981'. Up weight 87k, down 85k. Fill pipe. 07:30 - 09:30 2.00 CLEAN N RREP DECOMP Skate buggy not working properly. Adjust photo cell sensor. 09:30 - 12:00 2.50 CLEAN P DECOMP RIH picking up DP to 4490'. Up weight 115k, down 105k. Install blower hose. 12:00 - 12:30 0.50 CLEAN P DECOMP Wash down to 4521'. 12:30 - 13:30 1.00 CLEAN N SFAL DECOMP Remove and clean suction screens. 13:30 - 16:00 2.50 CLEAN P DECOMP Wash down to 4582' pumping at 250 gpm with 500 psi. Tag cement stringers at 4491'. Drill up stringers to hard cement at 4600'. Drill cement and tag top of EZSV at 4714'. Pump at 500 gpm with 1412 psi. Rotate at 50 rpm with 4k torque. WOB 13 -15k. Up weight 120k, down 100k. 16:00 - 18:00 2.00 CLEAN P DECOMP PJSM. Displace well to 9.4 ppg LSND milling fluid. Circulate at 500 gpm with 850 psi. Rotate and reciprocate. Pump dry job. Mud weight in and out 9.4 ppg. 18:00 - 21:00 3.00 CLEAN P DECOMP PJSM. POOH to BHA at 769'. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 14 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2008 21:00 - 00:00 3.00 CLEAN P DECOMP POOH with clean out BHA. Stand back HWDP and drill collars. Clear and clean floor. 12/22/2008 00:00 - 01:00 1.00 STWHIP P WEXIT PJSM. Pick whipstock tools up beaver slide. 01:00 - 03:00 2.00 STWHIP P WEXIT PJSM. Make up whipstock slide, mills and MWD tools. Orient and scribe. 03:00 - 03:30 0.50 STWHIP P WEXIT Hook up MWD. Function test connection. Upload MWD. 03:30 - 04:15 0.75 STWHIP P WEXIT RIH with whipstock BHA, drill collars and HWDP to 861'. 04:15 - 04:30 0.25 STWHIP P WEXIT Shallow test MWD. Good test. 04:30 - 09:30 5.00 STWHIP P WEXIT PJSM. RIH with whipstock assembly picking up 4" drill pipe to 4674'. 09:30 - 10:00 0.50 STWHIP P WEXIT Fill pipe. Test casing to 1000 psi for LOT correlation - OK. 10:00 - 10:30 0.50 STWHIP P WEXIT Run in to top of plug at 4714'. Up weight 120k, down 112k. Orient whipstock face to 54 RHS. Set down 20k to set anchor. Pull 10k to confirm set. Set down 50k and shear brass pin from slide. 10:30 - 17:30 7.00 STWHIP P WEXIT Mill window to 4720'. Pump at 500 gpm with 1230 psi on bottom, 1200 psi off bottom. Rotate at 70 rpm with 6k torque on O bottom, 5k torque off bottom. Up weight 120k, down 112k, RT - 4� 115k. TOW - 4690' BOW - 4708' 17:30 - 18:00 0.50 STWHIP P WEXIT Perform LOT at 4720' MD, 4441' TVD, Achieve LO of 12.4 ppg_ EMW with 700 psi and a 9.4 ppg mud in the hole. 18:00 - 20:30 2.50 STWHIP P WEXIT Continue to mill new formation to 4733'. Pump at 500 gpm with 1250 psi. Torque 4 -5k. Up weight 120k, down 110k. 20:30 - 21:30 1.00 STWHIP P WEXIT Circulate super sweep surface to surface at 500 gpm with 1200 psi. Work window. Work through with pumps and rotation. Work window with pumps Dff and no rotation. Window had no hang ups. Total metal recovered 200 lbs. Mud weight in and out 9.4 ppg. 21:30 - 23:30 2.00 STWHIP P WEXIT Perform MAD pass from 4733' bit MD to 4378' bit MD. Pull at 350 FPH in record mode. 23:30 - 00:00 0.50 STWHIP P WEXIT PJSM. Pump dry job. POOH to 3536'. 12/23/2008 00:00 - 01:00 1.00 STWHIP P WEXIT PJSM. POOH with milling assembly to 861'. 01:00 - 03:45 2.75 STWHIP P WEXIT PJSM. Stand back HWDP. Lay down drill collars. 03:45 - 04:30 0.75 STWHIP P WEXIT Hook up and down load MWD. Upload and set battery timer. 04:30 - 05:00 0.50 STWHIP P WEXIT Stand back MWD. Break out milling assembly. Upper mill snug on gauge ring. Lay down mills and flex joint. 05:00 - 06:30 1.50 STWHIP P WEXIT Rig up stack jetting tool. Funtion rams to clear debris. Clear and clean floor. Clean out under shakers and trough. Run in wear ring. 06:30 - 07:30 1.00 STWHIP P WEXIT PJSM. Pick drilling tools up beaver slide. 07:30 - 10:00 2.50 STWHIP P WEXIT PJSM. Pick up drilling BHA, including Hycalog DTX619, 7" SperryDrill Lobe 7/8 -6.0 stg, DM, RLL with DGR, EWR, PWD and TM to 733'. 10:00 - 13:00 3.00 STWHIP P WEXIT PJSM. RIH picking up drill pipe to 2780'. 13:00 - 14:00 1.00 STWHIP P WEXIT RIH with stands to 4640'. 14:00 - 16:00 2.00 STWHIP P WEXIT PJSM. Cut and slip 96' of drilling line. Service top drive and rig. 16:00 - 17:00 1.00 STWHIP P WEXIT Hook up blower hose. Orient to 60 degrees RHS. Slide through window with 8k down. Wash from 4720' to 4730'. Pump at 500 gpm with 1450 psi. 17:00 - 00:00 7.00 DRILL P INT1 PJSM. Directional drill ahead to 5385' MD, 4954' TVD. Pump at 520 gpm with 1775 psi off bottom, 1925 psi on bottom. Rotate Printed: 1/19/2009 4:14:33 PM • BP EXPLORATION Page 15 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/23/2008 17:00 - 00:00 7.00 DRILL P INT1 at 80 rpm with 4 -5k torque on bottom, 3k torque off bottom. WOB 3 -12k. Up weight 120k, down 107k, RT 115k. AST - 1.33, ART - 2.11. Mud weight in and out 9.5 ppg. ECD 10.07 ppg. Calculated clean hole ECD 10.0 ppg. 12/24/2008 00:00 - 00:00 24.00 DRILL P INT1 PJSM. Directional drill ahead to 6700' MD. Pump at 534 gpm with 2330 psi off bottom, 2550 psi on bottom. Rotate at 90 rpm with 5k torque off bottom, 10k torque on bottom. WOB 5 -10k. Up weight 140k, down 120k, RT 127k. Mud weight out 9.5 ppg, in 9.4 ppg. ECD - 10.06 ppg, calculated 10.09 ppg. Pump hi -vis sweep at 5700' with no increase of cuttings to surface. Continue drilling ahead to 8028' MD, 6960' TVD. Pump at 540 gpm with 2800 psi off bottom, 3100 psi on bottom. Rotate at 90 -100 rpm with 6 -7k torque off bottom, 7 -8k torque on bottom. WOB 5 -15k. Up weight 163k, down 133k, RT 145k. Mud weight in and out 9.4 ppg. AST - 2.33, ART - 11.53. ECD - 10.18 ppg, calculated 9.91 ppg. Begin to loose pump pressure at end of tower. 12/25/2008 00:00 - 02:00 2.00 DRILL N DPRB INT1 PJSM. Pull slowly out of hole. Check surface equipment for leaks and failures. Check lines, pump suctions, pump screens and cellar. While checking cellar, notice water bubbling up the outside of the 30' conductor at 1 bph. Notify town. GPB Environmental advised no need to report as spill and to haul water to Pad 3. No surface equipment Teaks or failiiras.. 02:00 - 06:00 4.00 DRILL N DPRB INT1 PJSM. POOH looking for washout in drill assembly. Overpull of 40k at 6967', attempt to wipe. Make up drop drive and back ream, pumping at 100 gpm, from 6967' to 6786'. Break out top drive and continue to pull out of hole with overpulls of 20k, wiping clean with no problems. Pull through window at 4708' with no problem. Mud weight in and out 9.4 ppg. Found washout at 3944', 1.5' below tool joint. Replace joint. P pare to RIH. 06:00 - 09:30 3.50 DRILL N DPRB INT1 RIH to 7898'. Wash down to 8028'. 09:30 - 00:00 14.50 DRILL P INT1 Drill ahead to 9053' MD, 7738' TVD. Pump at 540 gpm with 3400 psi off bottom, 3650 psi on bottom. Rotate at 90 rpm with 7k torque off bottom, 10k torque on bottom. WOB 5 -15k. Up weight 180k, down 143k, RT 160k. Mud weight in and out 9.4+ ppg. Calculated ECD 10.01 ppg, actual ECD 10.25 ppg. AST - 3.68, ART - 4.64. 12/26/2008 00:00 - 00:00 24.00 DRILL P INT1 PJSM. Drill ahead to 9519' MD. Pump at 475 gpm with 3650 psi off bottom, 3950 psi on bottom. Rotate at 80 rpm with 7 -8 torque off bottom, 9 -11k torque on bottom. WOB 12 -17k. Up weight 185k, down 135k, RT 162k. Spike system with shale stabilization products and bring weight to 11.3 ppg in and out. Calculated ECD 11.77 ppg, ECD 11.83 ppg. Continue to drill ahead to 9783' MD, 8281' TVD. Pump at 482 gpm with 3500 psi off bottom, 3650 psi on bottom. Rotate at 80 rpm with 6 -8k torque off bottom, 9-11k torque on bottom. WOB 5 -15k. Up weight 185k, down 137k, RT 162k. Mud weight in and out 11.3 ppg. AST - 9.83, ART - 4.3. Calculated ECD 11.67 ppg, ECD 11.71 ppg. 12/27/2008 00:00 - 08:30 8.50 DRILL P INT1 PJSM. Drill ahead to 10190' MD. Pump at 473 gpm with 3600 Printed: 1/19/2009 4:14:33 PM • BP EXPLORATION Page 16 of 26 r Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/27/2008 00:00 - 08:30 8.50 DRILL P INT1 psi off bottom, 3700 psi on bottom. Rotate at 80 -100 rpm with 8 -9k torque off bottom, 9-11k torque on bottom. WOB 10 -15k. Up weight 195k, down 140k, RT 160k. Weight in and out 11.3 ppg. Calculated ECD 11.6 ppg, ECD 11.74 ppg. Notice severe drop in pump pressure. Check surface equipment - OK. 08:30 - 11:30 3.00 DRILL N DPRB INT1 POOH to 6315' MD. Monitor well. Pull 30k over in 2 spots, wipe clean. Found washed out drill pipe at 6284' MD on pin end of joint. Lay down and PU replacement joint. 11:30 - 14:30 3.00 DRILL N DPRB INT1 RIH to 10127'. Wash down to 10190' MD. Took 30k down in 1 spot, wash through - OK. 14:30 - 19:00 4.50 DRILL P INT1 Directional drill ahead to 10381' MD, 8652' TVD. Pump at 470 gpm with 3420 psi off bottom, 3600 psi on bottom. Rotate at 90 -100 rpm with 9 -10k torque off bottom, 10 -12k torque on bottom. WOB 5 -15k. Up weight 195k, down 140k, RT 163k. Mud weight in and out 11.3 ppg. Calculated ECD 11.51 ppg, ECD 11.71 ppg. AST - 3.28, ART - 6.42. 19:00 - 20:00 1.00 DRILL P INT1 Circulate bottoms up for samples. Samples positive for bottom of Kingak, top of Sag. Call intermediate TD of 10381' MD. 20:00 - 22:00 2.00 DRILL P INT1 Pump weighted sweep surface to surface at 465 gpm with 3200 psi. Rotate at 110 rpm and reciprocate. No increase in cuttings to surface. Shut down, monitor well, static. 22:00 - 23:00 1.00 DRILL P INT1 Perform wiper trip to top of HRZ at 9754' MD. No problems, hole appears in good condition. Function test BOP rams and Hydril. 23:00 - 00:00 1.00 DRILL P INT1 Circulate and condition mud for 7" liner run. Pump at 465 gpm with 3500 psi. Reciprocate and rotate at 110 rpm with 8k torque. Lower ECD to 11.59 ppg with a calculated clean hole of 11.51 ppg. Prepare to open circ sub and pump dry job. 12/28/2008 00:00 - 01:00 1.00 DRILL P INT1 PJSM. Drop CCV operating ball. Open circ sub. Pump dry job. 01:00 - 04:30 3.50 DRILL P INT1 PJSM. POOH to 4574'. No problems. Hole appears in good condition. 04:30 - 06:30 2.00 DRILL N RREP INT1 PJSM. Make repairs to Iron Roughneck. 06:30 - 08:00 1.50 DRILL P INT1 POOH to BHA at 733'. 08:00 - 12:30 4.50 DRILL P INT1 PJSM. Lay down HWDP, Jars, MWD and Motor. Download MWD. Clean and clear floor. 12:30 - 13:00 0.50 BOPSUF P INT1 Remove wear bushing. Run in test joint. 13:00 - 14:30 1.50 BOPSUF P INT1 PJSM. Change upper rams to 7 ". 14:30 - 15:30 1.00 BOPSUF P INT1 PJSM. Test upper rams with 7" test joint to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Bill Decker and Toolpusher Cleve Coyne. 15:30 - 16:00 0.50 BOPSUF P INT1 Pull test plug. Run in wear ring. 16:00 - 17:00 1.00 CASE P INT1 Rig up casing handling equipment. 17:00 - 00:00 7.00 CASE P INT1 PJSM. Run 7 ", 26 #, L -80, BTC -M liner to 4666'. Make up float equipment. Check floats - OK. Fill on the fly and top off every 10 joints. Average torque 7K. Up weight 120k, down 110k. 12/29/2008 00:00 - 01:00 1.00 CASE P INT1 PJSM. Circulate 1 -1/2 times BU, (190 bbls), at the window. Stage up to 5 bpm with 310 psi. 01:00 - 04:00 3.00 CASE P INT1 Run liner to 5803'. Make up hanger and packer, drill pipe single and 2 pups. Make up stand and RIH to 5982'. Average torque 7k. Loose 9 bbls running in hole. 04:00 - 04:30 0.50 CASE P INT1 Circulate 1 liner volume of 75 bbls. Stage pumps up to 4 bpm with 570 psi. Start loosing mud, cut pump rate to 3 bpm with 460 psi. Loose 59 bbls. Printed: 1/19/2009 4:14:33 PM 1 • BP EXPLORATION Page 17 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/29/2008 04:30 - 10:00 5.50 CASE P INT1 RIH with liner to 10381' MD. Fill on the fly and top off every 10 stands. Make up cement head. Lost a total of 112 bbls RIH. 10:00 - 10:30 0.50 CEMT P INT1 PJSM. Stage pumps up to 5 bpm with 1450 psi. Minimal returns. Work pipe stretch without pulling off bottom. Hold PJSM with all personnel. 10:30 - 14:30 4.00 CEMT P INT1 Pump 5 bbls, 11.6 ppg, Mudpush II with 1 ppb CemNET. Shut down pressure test lines to 4500 psi - OK. Pump remaining 45 bbls Mudpush II with 1 ppb CemNET at 5 bpm with 1100 psi. Pump 164 bbls, 11.8 ppg, LiteCRETE lead slurry at 5 bpm with 1050 psi. Pump 35 bbls, 15.8 ppg, Class G tail slurry at 5 bpm with 720 psi. Continue to work pipe stretch. Swap over to rig and chase with 11.3 ppg mud. Pressure at start 130 psi. With 15 bbls away psi at 173. With 35 bbls away psi at 710. Latch up at 44 bbls with 850 psi 1 With 60 bbls away psi at 1000 psi. With 115 bbls away psi at 1400 psi. Returns of 13% through 115 bbls, then tapering off. Lost returns for last 151 bbls. Continue pumping and bump plug at 266 bbls with 2200 psi. Last weight up 245k. Bring pressure up to 2500 psi and set hanger. Continue to pressure up to 3500 psi and hold for 10 minutes. Bleed off and check floats - OK. Pressure up to 4000 psi pick up with no release. Continue to pressure up to 4500 psi and successfully release. Bleed pressure. Slack off and weight set packer with 40k down. Pressure up to 1000 psi. Slowly pull up and unsting. Begin circulating hole clean. Lost a total of 753 bbls during cement job. CIP 1315 hours. 14:30 - 15:30 1.00 CEMT P INT1 Circulate out at 500 gpm with 2700 psi. Some high pH back but no trace of Mudpush II or cement back to surface. 15:30 - 16:30 1.00 CEMT P INT1 PJSM. Rig down and lay down cement head. Blow down lines. Rack back 3 stands. 16:30 - 18:30 2.00 CEMT P INT1 PJSM. Cut and slip 112' of drilling line. Service top drive and drawworks. 18:30 - 21:00 2.50 CEMT P INT1 Pump dry job. POOH. Lay down liner running tool. 21:00 - 22:00 1.00 CEMT P INT1 Pull wear ring. Clear and clean floor. 22:00 - 00:00 2.00 CASE P INT1 PJSM. Rig up casing running equipment. Change out to long bales. Rig up torque turn tongs. 12/30/2008 00:00 - 01:00 1.00 CASE P TIEB1 PJSM. Finish rigging up to run 7 ", 26 #, NT- 80/L -80, NSCC/TCII casing to PBR. 01:00 - 02:00 1.00 CASE P TIEB1 PJSM. Rig up and test liner lap and casing to 3500 psi for 30 charted minutes. Lost 16 psi in first 15 minutes, 4 psi in second 15 minutes - PASS. Hold PJSM, while holding pressure test, Printed: 1/19/2009 4:14:33 PM ■ •► BP EXPLORATION Page 18 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/30/2008 01:00 - 02:00 1.00 CASE P TIEB1 for running tieback. 02:00 - 11:30 9.50 CASE P TIEB1 Run 7 ", 26 #, NT- 80/L -80, NSCC/TCII casing tieback. 3540' of 7 ", 26# NSCC (TQ -6500 ft/lbs) and 945' of 7 ", 26# TCII (TQ 10,000 ft/lbs). Space Out for the cement job, no go @ 4572'. 11:30 - 14:00 2.50 CEMT P TIEB1 PJSM. Install the cement lines and space out the circulating ports, then establish circulation. 14:00 - 16:30 2.50 CEMT P TIEB1 PJSM with NAD rig crew, Schulmberger Cement crew, NAD Toolpusher Cleve Coyne, and BP WSL Bill Decker. -Pump 40 bbls. Hi -Vis Spacer with dye -Pump 5 bbls of H2O in order to pressure test the lines to 4500 psi -Pump 120 bbls of diesel followed by 20 bbls. of 13# mud push -Drop the bottom plug -Pump 37 bbls of 15.8# Class G Cement -Drop the top plug -Wash up with 2 bbls of H20. -Pump 170 bbls of 11.3# Mud with the rig pumps @ 5 bbls /min at 200 psi. -When Diesel to surface; closed the top rams opened the OA and took returns to the cuttings box. -Bump the plug at 2930 stks. - Pressure up to 800 psi, insert ports into the polished bore recepticle, then bled the OA pressure to 0. - Continued down and spot pipe 1.5' above No Go mark, Cement was in place @ 16:30. 16:30 - 18:30 2.00 CEMT P TIEB1 Laydown the cement head, blow down the lines, rinse and clear the stack of any debris. 18:30 - 00:00 5.50 WHSUR P TIEB1 PJSM. Split the stack and rigged up to cut the 7" casing with the Wachs Cutter. After setting the slips with 85k, the driller slacked off the wt. indicator to 400 Ibs over to hold tension on the 7" while cutting with a Wach's Cutter. After the 7" was halfway cut the wellhead subsided approx. 2 inches. While slumping 2 inches, an additional 30,000 Ibs was shown on the wt. indicator. Cut was finished and while sitting the wt. of the BOP stack on the wellhead , the wellhead sunk an additional 1 inch. 12/31/2008 00:00 - 01:00 1.00 WHSUR P TIEB1 Evaluating the situation with the wellhead and discussing the options with the town ODE and Senior Drilling Engineer. While discussing the situation with town, the rig crew was cleaning out the cellar of snow and ice in order to be able to view complete wellhead. 01:00 - 05:00 4.00 WHSUR P TIEB1 After discussing the situation with town, the decision was made to place the weight of the stack back on the wellhead and monitor to make sure no more subsidence was taking place. After 2 hours of constant monitoring with no movement the decision was made to nipple up and test the 7" packoff to 4300 psi for 30 minutes. Good Test. 05:00 - 06:00 1.00 BOPSUF P PROD1 Change out the upper pipe rams to 3 1/2" x 6" VBR 06:00 - 07:30 1.50 BOPSUF P PROD1 Test the top 3 1/2" x 6" VBR to 250 psi / 3500 psi. Good Test -Rig down testing equipment and clean and clear the floor. 07:30 - 08:00 0.50 DRILL P PROD1 Install wear bushing and prepare to make up the clean out BHA. Printed: 1/19/2009 4:14:33 PM • BP EXPLORATION Page 19 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 12/31/2008 08:00 - 09:30 1.50 DRILL P PROD1 Make up clean out clean out BHA to 381'. 09:30 - 13:30 4.00 DRILL P PROD1 Run in the hole from 381' to 3350'. -Up Wt. 95k / Down Wt. 80k -Fill pipe 250 gpm @ 820 psi 13:30 - 16:30 3.00 DRILL P PROD1 Install the blower hose and establish parameters. Continue in the hole form 3350' to 4530' where we tagged up. Drilled out the plugs and float collar. -300 gpm @ 1250 psi / RPM 90 -TQ 2k -2.5k / WOB 2 -12k - Encounter cement stringers from 4570' to 4795' 16:30 - 19:30 3.00 DRILL P PROD1 Continue in the hole from 4795' to 8752'. -Up Wt. 190k / Down Wt. 120k 19:30 - 21:30 2.00 DRILL P PROD1 PJSM. Performed a stripping drill with the BP WSL Chris Kobuck, NAD Tour Pusher Ken Helf, and NAD Rig Crew. 21:30 - 22:30 1.00 DRILL P PROD1 Continue in the hole from 8752' to 10,058'. 22:30 - 23:30 1.00 BOPSUF P PROD1 Pressure test the 7" casing to 3500 psi for 30 minutes. Good Test. Witnessed by BP WSL Chris Kobuck and NAD Tour Pusher Ken Helf. 23:30 - 00:00 0.50 BOPSUF P PROD1 PJSM. Begin to change out 3 1/2" x 6" VBR to 4" Rams. 1/1/2009 00:00 - 01:30 1.50 BOPSUF P PROD1 Finish changing out the 3 1/2" x 6" VBR to 4" Rams. Rig up and test the rams to 250 psi / 3500 psi. Good Test. 01:30 - 03:30 2.00 DRILL P PROD1 PJSM. Performed a stripping drill with crew that just came on tour at midnight. All hands performed the choke duties. Test performed with BP WSLf Ray Platt, NAD Tour Pusher Ken Helf, and NAD rig crew. 03:30 - 05:00 1.50 EVAL P PROD1 PJSM. Applied 92k to wellhead to check if the stack was subsiding. While applying the weight, the well head subsided approx. 1/2" and while slacking off it rose 1/4 ". 05:00 - 05:30 0.50 DRILL P PROD1 Rigging up stack to bridge crane and preparing to drill out cement in 7" liner. 05:30 - 06:00 0.50 DRILL P PROD1 RIH from 9686' to 10289' and tag the cement @ 10289'. 06:00 - 08:00 2.00 DRILL P PROD1 Attempt to drill up the cement but due to high torque could not rotate. Pumped a steel lube sweep and still no rotation. Decision was made to displace over to 8.4 ppg Flo -Pro. 08:00 - 11:00 3.00 DRILL P PROD1 Drill up cement and float equipment from 10289' to 10381'. Drill new formation from 10381' to 10401'. -Up Wt. 160k / Down Wt. 140k / ROT Wt. 150k - RPM100 /TQ5k -264 gpm @ 1200 psi 11:00 - 11:30 0.50 DRILL P PROD1 Circulate bottoms up at 470 gpm @ 2280 psi. 11:30 - 12:00 0.50 DRILL P PROD1 Perform a FIT test at 10401' to a EMW of 9.7 ppg. 12:00 - 12:30 0.50 DRILL P PROD1 Pump a dry job, blow down the Top Drive, install the air slips and prepare to TOH. 12:30 - 17:00 4.50 DRILL P PROD1 Trip out of the hole from 10401' to 381'. -Up Wt. 185k / Down Wt. 150k -Mud In and Out 8.4 ppg 17:00 - 19:00 2.00 DRILL P PROD1 PJSM. Laydown BHA and rack back 2 stands of HWDP, Laydown collars, boot basket, bit, and clean and clear the floor. 19:00 - 20:30 1.50 BOPSUF P PROD1 Remove the wear bushing and set test plug and change out the 4" rams to 3 1/2" x 6" VBR. Printed: 1/19/2009 4:14:33 PM BP EXPLORATION Page 20 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2009 20:30 - 00:00 3.50 BOPSUF P PROD1 PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Jeff Jones with AOGCC. Test witnessed by WSL's Chris Kobuck and Ray Platt and Tourpusher Ken Helf. Test upper and lower rams with 4" test joints. Test Hydril with 4" test joint. 1/2/2009 00:00 - 02:00 2.00 BOPSUF P PROD1 Continued testing the BOPE. Tested the upper and lower rams with the 4.5" test joint. All tests were charted for 5 minutes and were passing tests. 02:00 - 05:30 3.50 DRILL P PROD1 Make up the 6 1/8" drilling assembly to 376'. -BHA consists 2.12 bend motor, MWD tools, flex DC's, Circ sub, HWDP, Jars. - Uploaded the MWD tools and shallow test. Good Test. 05:30 - 10:30 5.00 DRILL P PROD1 Run in hole from 376' to 10381' filling the pipe every 3000'. -Up Wt. 180k / Down Wt. 140k 10:30 - 12:00 1.50 DRILL P PROD1 Wash down from 10381' to 10401'. Orient the tool to high side. -Mud Wt. In and Out 8.4 ppg 12:00 - 00:00 12.00 DRILL P PROD1 Slide drill ahead from 10401' to 10528'. -Up Wt. 170k / Down Wt. 135k -WOB 20k -1600 psi Off / 1750 psi On -Mud Wt. In and Out 8.4 ppg 1/3/2009 00:00 - 13:00 13.00 DRILL P PROD1 Continue to slide ahead to 10638'. -Up Wt 175k / Down Wt. 135k -WOB 12 -15k -240 gpm @ 1675 psi -Mud Wt. In and Out 8.4 ppg -Began encountering background gas at 10608'. Circulated a BU and monitored the well. Gas peaked at 5600 u, then went back to 40 -60u range after BU. Continually monitored well without any further signs of gas. 13:00 - 13:30 0.50 DRILL P PROD1 Circulate bottoms up at 240 gpm @ 1650 psi and monitor the well for 10 minutes. Static -Mud Wt. In and Out 8.4 ppg 13:30 - 14:30 1.00 DRILL P PROD1 Pump out of the hole from 10638' to 10334'. -240 gpm CO 1500 psi -Up Wt. 170k / Down Wt. 140k 14:30 - 20:30 6.00 DRILL P PROD1 Dropped the ball and opened the CCV sub @ 2430 psi. Pumped a dry job and pulled out the hole from 10334' to 376'. Closed the CCV @ 2200psi. 20:30 - 23:30 3.00 DRILL P PROD1 Lay down the BHA and stand back HWDP and Jars. Flush out the MWD tools, Laydown the CCV, motor and break out the bit. Clean and Clear the floor. 23:30 - 00:00 0.50 DRILL P PROD1 Pick up the 3rd party tools and pick up the MWD tools. 1/4/2009 00:00 - 04:30 4.50 DRILL P PROD1 PJSM. P/U BHA. Adjust motor to 1.22 bend. Upload MWD. M/U to Top Drive and shallow pulse test @ 200 GPM/750 psi. Good test. Load radioactive sources. 04:30 - 12:00 7.50 DRILL P PROD1 RIH from 396'- 2927'; CBU and saw 29 bbls of gas -cut mud at surface w/1 bbl loss. - Continued in hole to 5067'; CBU and saw 58 bbls of gas -cut mud at surface w/3 bbl gain - 1657u gas - Continued in hole to 7578'; CBU and saw 88 bbls of gas -cut mud w/2 bbl gain - 7833u gas 12:00 - 13:30 1.50 DRILL P PROD1 Slip /cut drilling line; slipped 65' and adjusted brakes Printed: 1/19/2009 4:14:33 PM • • BP EXPLORATION Page 21 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/4/2009 12:00 - 13:30 1.50 DRILL P PROD1 - Serviced top drive and crown. 13:30 - 15:00 1.50 DRILL P PROD1 RIH from 7578' to 10371' 15:00 - 17:00 2.00 DRILL P PROD1 Dropped ball to open and circulate through the CCV; circulated 2450psi - Drop BHA close -off ball - Pump steel lube sweep @260GPM/1160psi - Saw 46 bbls of gas -cut mud at surface - 9267u gas - - Dropped ball to close CCV and verified closed at 2500psi 17:00 - 17:30 0.50 DRILL P PROD1 RIH from 10371' to 10638' 17:30 - 00:00 6.50 DRILL P PROD1 MAD pass from 10638' to 10435' - RIH to 10604' w /rotational survey - POH to shoe @ 10378' and CBU - 5220u gas - RIH to 10551' w /rotational survey - POH to shoe @ 10378' and CBU -5742u gas - Up weight 180K, down weight 135K - Gained 8 bbls of gas -cut mud during MAD pass - 2900u gas - Saw very little gas during CBUs - MW in and out 8.4ppg 1/5/2009 00:00 - 01:30 1.50 DRILL P PROD1 RIH from 10381' to 10638' - CBU 240 GPM @ 1980 PSI 01:30 - 12:00 10.50 DRILL P PROD1 Drill ahead from 10638' to 10800' - Up wt 175K/Down wt 130K/Rot wt 150K - WOB 10 -15K - TQ on 6 -7K/off 5 -6K - RPM 40 - MW in and out 8.5ppg -AST- 5.06hrs / ART .58hrs 12:00 - 00:00 12.00 DRILL P PROD1 Drill ahead from 10800' to 11218' - Up wt 165K/Down wt 135K/Rot wt 150K - WOB 5 -10K - TQ on 6K/off 5K - RPM 100 - MW in and out 8.5ppg -AST - 3.32hrs / ART - 4.26hrs 1/6/2009 00:00 - 08:30 8.50 DRILL P PROD1 Continue to drill ahead from 11218' to 11,354'. - Up wt 170K/Down wt 135K/Rot wt 150K - WOB 10 -15K - TQ on 5 -6K/off 6 -7K - AST 2.16; ART 1.06. - Having issues sliding ahead. - Pumping Lo -Torq to minimize wall sticking. 08:30 - 09:30 1.00 DRILL P PROD1 TOH from 11354' to 10378' 09:30 - 12:00 2.50 DRILL P PROD1 CBU - Drop ball and open the CCV - Drop ball and isolate BHA - Pump steel tube sweep @ 350GPM /1400psi - Drop ball to close the CCV 12:00 - 13:30 1.50 DRILL P PROD1 TIH from 10378' to 11354' - Up wt 165K, Down wt 135K - Rotate from 10930' to 11354' at 100 RPM and TQ 5K 13:30 - 17:30 4.00 DRILL P PROD1 Drill from 11354' to 11379' - Up wt 165K, Down wt 135K, Rot wt 150K - AST 1.04 Printed: 1/19/2009 4:14:33 PM • • BP EXPLORATION Page 22 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/6/2009 13:30 - 17:30 4.00 DRILL P PROD1 - MW 8.5ppg - Continued difficulty sliding - Cannot hold tool face - Discussed with Anchorage; preparing to POH to change bit and BHA configuration 17:30 - 19:00 1.50 DRILL P PROD1 TOH from 11379' to 10930' - RPM 100 - TQ 5K - Up wt 150K, Down wt 145K 19:00 - 20:00 1.00 DRILL P PROD1 CBU - Drop ball and open the CCV - Drop ball and isolate BHA - Pump dry job - MW 8 . 5 ppg 20:00 - 00:00 4.00 DRILL P PROD1 TOH from 10378' to 684' - Monitor well for 5 minutes @ 7492' and 4979' - Drop ball to close the CCV 1/7/2009 00:00 - 03:30 3.50 DRILL P PROD1 POH and LD BHA; remove upper stabilizer and kick pad - Changed bit to Hughes MX -18HDX tri -cone roller bit 03:30 - 07:30 4.00 DRILL P PROD1 PU modified BHA and RIH to 2500' - Uploaded MWD and it pressure tested good 07:30 - 08:30 1.00 DRILL P PROD1 CBU - MWD again tested good 08:30 - 10:00 1.50 DRILL P PROD1 RIH from 2500' to 7500' - Fill pipe at 5000' and 7500' 10:00 - 11:00 1.00 DRILL P PROD1 CBU - Tested MWD and indications were of a weak signal - Decision was made to continue ahead in order to test modified BHA in slide run in open hole 11:00 - 13:00 2.00 DRILL P PROD1 RIH from 7500' to 10373' - Fill pipe - Up wt 165K, Down wt 130K 13:00 - 13:30 0.50 DRILL P PROD1 CBU at the shoe - MWD Tool Failure. Tool was pulsing, but no detection 13:30 - 14:00 0.50 DRILL P PROD1 RIH from 10373' to 11379' 14:00 - 14:30 0.50 DRILL P PROD1 Slide drilled from 11379' to 11389' - Up wt 165K, Down wt 135K - WOB 10 -15K - AST .24 - MW 8 . 5 ppg 14:30 - 16:30 2.00 DRILL P PROD1 POH from 11389' to 10373' - Up wt 170K, Down wt 130K 16:30 - 18:30 2.00 DRILL P PROD1 POH while "backreaming" from 10373' to 10000' (to polish casing) - RPM 90 -TQ4K - Up wt 150K, Down wt 140K, Rot wt 145K - Opened CCV and pumped dry job 18:30 - 20:00 1.50 DRILL P PROD1 POH from 10000' to 5000' 20:00 - 22:00 2.00 DRILL N DFAL PROD1 POH from 5000' to 398' - Close CCV at 680' 22:00 - 00:00 2.00 DRILL N DFAL PROD1 POH while LD BHA 1/8/2009 00:00 - 04:00 4.00 DRILL N DFAL PROD1 Rack back DCs and change out MWD tool. Printed: 1/19/2009 4:14:33 PM • • BP EXPLORATION Page 23 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/8/2009 00:00 - 04:00 4.00 DRILL N DFAL PROD1 - PJSM before downloading and uploading radioactive sources - Make up BHA to 386' 04:00 - 06:00 2.00 DRILL N DFAL PROD1 RIH from 386' to 5000' - Shallow test MWD. Good test - Fill pipe at 3000' - CBU at 5000' 06:00 - 09:30 3.50 DRILL P PROD1 RIH from 5000' to 10381' (shoe) - Fill pipe at 7500' - CBU at 10381' 09:30 - 12:00 2.50 DRILL P PROD1 RIH from 10381' to 11389' - Rotational surveys taken at 11113' and 11300' - Upwt170K, Down wt135K 12:00 - 00:00 12.00 DRILL P PROD1 Directionally drilled from 11389' to 11768' - TVD 8686' - Up wt 165K, Down wt 125K, Rot wt 150K - WOB 15K - GPM 280, PSI 2340/2520 - RPM 100 - TQ up 5K, TQ down 6 -7K - ART 3.71, AST 2.88 - MW 8 . 5 ppg 1/9/2009 00:00 - 12:00 12.00 DRILL P PROD1 Drilled from 11768' to 12234' - TVD 8690' - AST 2.61, ART 4.99 - Up wt 170K, Down wt 120K, Rot wt 150K - WOB 17K - GPM 280, PSI 2300/2490 • - RPM 80 - TQ on 6K, TQ off 7K - MW 8.6ppg 12:00 - 00:00 12.00 DRILL P PROD1 Drilled from 12234' to 12674' - TVD 8689' - AST 1.74, ART 5.14 - Up wt 170K, Down wt 120K, Rot wt 150K - WOB 15 -18K - GPM 274, PSI 2450/2650 - RPM 80 - TQ on 7 -8K, TQ off 6K - MW 8.6+ppg 1/10/2009 00:00 - 09:00 9.00 DRILL P PROD1 Drilled from 12674' to 12932' - TVD 8690' - GPM 279; PSI 2510 off, 2750 on - WOB 15 -18K - TQ off 6 -7K, on 7 -8K - Up wt 175K, Down wt 125K, Rot wt 150K - AST 2.21, ART 2.51 - MW 8.6 +ppg - Currently drilling in the transition zone between the Sag and, the Kingak, due to a change in formation structure. 09:00 - 10:00 1.00 DRILL P PROD1 Due to having trouble sliding and dropping angle; we drilled into the transition zone between the Sag and the Kingak. Due to this and the possiblity of drilling into the Kingak, the decision was made to trip for a new bit and motor with a more Printed: 1/19/2009 4:14:33 PM 1 • BP EXPLORATION Page 24 of 26 Operations Summary Report • Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/10/2009 09:00 - 10:00 1.00 DRILL P PROD1 aggressive bend in order to drop angle. CBU - GPM 279, PSI 2507 - RPM 85 - TQ 5 -6K - MWD surveys - Up wt 200K, Down wt 135K 10:00 - 12:00 2.00 DRILL P PROD1 POH from 12932' to 10187' - Monitor well for 5 minutes at 10187' (right above shoe) -Mud Wt In and Out 8.6+ 12:00 - 14:30 2.50 DRILL P PROD1 Slip /cut 144' of drilling line and service top drive 14:30 - 15:00 0.50 DRILL P PROD1 CBU and open CCV to pump dry job 15:00 - 19:30 4.50 DRILL P PROD1 POH from 10187' to 398' 19:30 - 20:00 0.50 DRILL P PROD1 CBU and close CCV 20:00 - 23:30 3.50 DRILL P PROD1 TOH while LD BHA from 398' 23:30 - 00:00 0.50 DRILL P PROD1 MU /PU modified BHA (new bit and motor) 1/11/2009 00:00 - 03:00 3.00 DRILL P PROD1 RIH with new bit/BHA to 399' - Circulated to test MWD; tested good - Loaded radioactive sources 03:00 - 08:00 5.00 DRILL P PROD1 RIH from 399' to 10374' - Filled drill pipe and checked MWD every 20 stands 08:00 - 13:00 5.00 DRILL P PROD1 RIH from 10374' to 12930' - Rotational surveys and check shots @I 11299', 11386', 11421', 11517', 12235', 12510', and 12930' - MW 8.6+ ppg - CBU to get trip gas out of wellbore @ 11299'. RIH to bottom at 12932'. Saw some additional gas off bottom but cleaned up quickly. 13:00 - 00:00 11.00 DRILL P PROD1 Drilled ahead from 12932' to 13185'. Dump -450 bbls old mud and add 290 bbls new Flo -Pro while drilling ahead. - TVD 8698' - TQ on 7 -8K, off 7K - WOB 15 -18K - RPM 80 - MW 8.6 ppg in and out - GPM 282, PSI on 2550, off 2410 - AST2.81,ART1.43 - At 12968' we re- entered the Sag R. sand and at 13121' drilled to within 5 feet of the South edge of the drillers polygon without going out. 1/12/2009 00:00 - 12:00 12.00 DRILL P PROD1 Drilled from 13185' to 13671' - TVD 8706' - GPM 280; PSI 2500 off, 2710 on - RPM 80 - WOB 15 -18K - TQ off 5 -6K, on 7 -8K - Up wt 173K, Down wt 120K, Rot wt 147K - AST 1.25, ART 7.06 - MW 8.6+ ppg in and out 12:00 - 00:00 12.00 DRILL P PROD1 Continue drilling ahead in Sag R sand from 13671' to 14130' - TVD 8709' - GPM 274; PSI 2640 off, 2750 on - RPM 60 Printed: 1/19/2009 4:14:33 PM • • BP EXPLORATION Page 25 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2009 12:00 - 00:00 12.00 DRILL P PROD1 - WOB 15 -20K - TQ off 6K, on 7 -8K - Up wt 173K, Down wt 115K, Rot wt 147K - AST 1.35, ART 4.73 - MW 8.6 ppg in and out 1/13/2009 00:00 - 05:00 5.00 DRILL P PROD1 Drilled from 14130' to 14296' - noted a drop in pump pressure of -250 psi. PU off bottom and inspect all surface equipment. Pump pressure continues to drop a total of 500 psi suspe washout in drilipipe. 05:00 - 08:00 3.00 DRILL N DFAL PROD1 POH to 10,497' looking for washout in DP. Found in DP around slip area on middle single of stand #41 out. LD bad jt. 08:00 - 09:00 1.00 DRILL P PROD1 Pull 1 stand up into shoe. Service Top Drive. 09:00 - 11:00 2.00 DRILL N DFAL PROD1 PU single and RIH to 14183'. TD called at 14296'. RIH to TD. 11:00 - 13:30 2.50 DRILL P PROD1 Circulate & Condition hole. Circulate Hi -Vis sweep @ 304 gpm, 2900 psi. 100 RPM. Circ out trip gas. 13:30 - 16:00 2.50 DRILL P PROD1 POH from 14296' to 7" shoe at 10281'. Monitor well. 16:00 - 17:00 1.00 DRILL P PROD1 Circulate and Condition hole. Drop ball and open CCV. Pump dry job. 17:00 - 21:00 4.00 DRILL P PROD1 POH from 10,281' to top of BHA @ 399'. 21:00 - 00:00 3.00 DRILL P PROD1 Lay Down BHA to CCV. Shut CCV. LD BHA to top of nukes. PJSM to unload nukes. 1/14/2009 00:00 - 03:00 3.00 DRILL P PROD1 Lay down BHA #9. Bit Grade 2 - 2 - WT - A - E - I - ER - TD. Clean and Clear rig floor. 03:00 - 05:00 2.00 CASE P RUNPRD RU to run 4 -1/2 ", 12.6 #, IBT -M, slotted liner. PJSM. 05:00 - 11:00 6.00 CASE P RUNPRD MU 4 -1/2" shoe track and RIH with 100 jts of slotted liner, 1 jt of solid liner, and hanger assembly. 11:00 - 15:00 4.00 CASE P RUNPRD XO to 4" DP and RIH from 4086' to 10,339'. 15:00 - 16:00 1.00 CASE P RUNPRD Circulate at shoe. 1.5x CBU @ 220 gpm; 850 psi. No gas in returns. 16:00 - 18:30 2.50 CASE P RUNPRD RIH to TD. Start taking weight @ 12,290' - work down to 13,000' then improved. Tag bottom and pull up to put shoe at 14,292'. PU - 200k; SO - 125k 18:30 - 20:00 1.50 CASE P RUNPRD Circulate and drop ball. Pressure up to 1800 psi to set hanger. Slack off to 120k. Pressure up to 3000 psi to set liner top packer. Pressure up to to 3800 psi to release running tool. Bleed off and PU to 180k to verify tool release. Circulate at 130 gpm; 830 psi. 20:00 - 20:30 0.50 CASE P RUNPRD Pressure up annulus to 1500 psi for 10 min to test packer. Good test. 50 psi drop in Z minutes, next - 3 - minutes, 0 psi drop last 5 minutes. Bleed off. 20:30 - 22:00 1.50 CASE P RUNPRD Displace well to 8.5 ppg seawater. 22:00 - 00:00 2.00 CASE P RUNPRD PJSM. POH LDDP from 10221' to 7773'. PU - 140k; SO - 120k. 1/15/2009 00:00 - 08:00 8.00 CASE RUNPRD Laying down drilipipe from 7773' to liner running tool. 4" x 3" x 1/2" piece of the rubber is broken /ripped off the swab cup on btm of running tool. Possibly got pulled off when unstinging from liner but could also have been pulled off when pulling up thru tieback assembly. 08:00 - 09:00 1.00 CASE N DFAL RUNPRD Wait on orders. Discuss situation with ODE and SDE in Anch. Agree to run slickline to try and fish piece of rubber or push down to 4.5" liner top. 09:00 - 10:30 1.50 CASE RUNPRD RIH with 4651' of DP from derrick. Printed: 1/19/2009 4:14:33 PM • i BP EXPLORATION Page 26 of 26 Operations Summary Report Legal Well Name: 01 -05 Common Well Name: 01 -05 Spud Date: 8/1/1970 Event Name: REENTER +COMPLETE Start: 12/19/2008 End: 1/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2009 Rig Name: NABORS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase Description of Operations 1/15/2009 10:30 - 12:00 1.50 CASE RUNPRD Slip and cut drilling line. Service top drive. 12:00 - 17:30 5.50 CASE RUNPRD P01-1 laying down drillpipe from derrick. 15 joints of pipe with bad (severely galled) connections taken out of service. 17:30 - 21:00 3.50 CASE N DFAL RUNPRD Wait for slickline to arrive off another job. 21:00 - 00:00 3.00 CASE N DFAL RUNPRD MIRU SWS and RIH with 6.05" OD gauge ring junk basket. I 1/16/2009 00:00 - 01:30 1.50 CASE N DFAL RUNPRD RIH, tag liner top at 10,224 (SWS MD). POH. 01:30 - 03:30 2.00 CASE N SFAL RUNPRD 2 slip dies (1" x 1" x .5 ") from DC clamp on lubricator fell downhole with slickline 90' from surface and hanging up toolstrinq in up direction. Worked tool string and got it moving again. POH. Inspect toolstring and surface equipment for subsequent gauge ring run. 03:30 - 05:30 2.00 CASE N SFAL RUNPRD RIH with slickline. Tag top of liner. POH with slickline. Empty junk basket. One keeper pin from slip dies retrieved but dies are still in hole and pushed down to liner top. 05:30 - 06:30 1.00 CASE N DFAL RUNPRD RDMO SWS. 06:30 - 12:00 5.50 BOPSUF P RUNPRD Test BOPE to 250/3500 psi per permit. Test annular to 2500 psi. Good test - no failures. AOGCC witness waived by Jeff Jones. 12:00 - 14:30 2.50 RIGU P RUNCMP RU to run 4 -1/2" chrome completion. 14:30 - 00:00 9.50 RUNCOIVP RUNCMP RIH with 120 joints to 5232'. LD & replace jt #5 and change coupling on jt #4 because of thread galling during make -up. 1/17/2009 00:00 - 08:00 8.00 RUNCOM RUNCMP RIH with completion and tag bottom of SBR at 10,227' x3. Top of tieback receptacle at 10217'. PU - 135k, SO - 115k. 07:00 - 10:30 3.50 RUNCOMP RUNCMP Space out. LD jts #235 - 237. PU 3 pups. 19.89', 9.83', 3.80', jt #235 and tubing hanger. Land tubing at 10223', 6 feet inside of SBR. 10:30 - 15:00 4.50 RUNCOI'P RUNCMP Displace well to completion fluid. Reverse in 155 bbls seawater, 133 bbls seawater with corrosion inhibitor, 59 bbls seawater. 15:00 - 16:30 1.50 RUNCOAP RUNCMP Drop ball and rod. Pressure up to 3500 psi and set packer. Test tubing for 30 minutes. Good test. Bleed tubing pressure to 1500 psi. Pressure up annulus to 3500 psi and test packer for 30 min - good test. Shear DCK valve. Good shear, pump both ways @ 73 gpm with 270 psi and 310 psi. 16:30 - 20:00 3.50 BOPSUF P RUNCMP Install TWC. Test above and below. Good test. ND BOP. 20:00 - 00:00 4.00 WHSUR P RUNCMP NU adapter flange. Test void to 5000 psi for 30 minutes. Good test. NU tree and fill with diesel. Test tree to 5000 psi for 5 minutes. Good test. 1/18/2009 00:00 - 02:00 2.00 WHSUR P RUNCMP RU DSM and pull TWC. 02:00 - 05:00 3.00 WHSUR P RUNCMP PJSM. RU LRS and pump 75 bbls diesel down annulus @ 3 bpm. Allow diesel to U -tube over to tubing. 05:00 - 06:30 1.50 WHSUR P RUNCMP Install BPV and test to 1000 psi from below. RD DSM.. 06:30 - 08:00 1.50 WHSUR P RUNCMP Secure well. Pump out cellar. Release rig from 01 -05B at 08:00 hrs for move to 07 -08B. Printed: 1/19/2009 4:14:33 PM r &perry Drilling Service Survey Report Company: BP Amoco Date: 1/21/2009 Time: 10:41:04 Page: 1 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01 -05, True North Site: PB DS 01 Vertical (TVD) Reference: 01 -058 67.8 Well: 01 -05 Section (VS) Reference: Well (0.00N,0.00E,125.18Azi) Wellpath: 01 -05B Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 01 -05 Slot Name: 01 -05 Well Position: +N / -S - 1592.56 ft Northing: 5940378.70 ft Latitude: 70 14 28.240 N +E / -W 1470.64 ft Easting : 698749.33 ft Longitude: 148 23 41.253 W Position Uncertainty: 0.00 ft Wellpath: 01 -05B Drilled From: 01 -05PB1 500292007602 Tie -on Depth: 4690.00 ft Current Datum: 01 -05B Height 67.80 ft Above System Datum: Mean Sea Level Magnetic Data: 12/26/2008 Declination: 23.02 deg Field Strength: 57701 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft ft ft deg 28.50 0.00 0.00 125.18 Survey Program for Definitive Wellpath Date: 1/16/2009 Validated: Yes Version: 11 Actual From To Survey Toolcode Tool Name ft ft 95.50 4650.50 1 : Camera based mag multi sho CB- MAG -MS Camera based mag multi shot 4650.50 14232.97 01 -05B MWD +SAG +IIFR +MS (4650.5 MWD +IFR +MS MWD + IFR + Multi Station Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.50 0.00 0.00 28.50 -39.30 0.00 0.00 5940378.70 698749.33 TIE LINE 95.50 0.58 7.00 95.50 27.70 0.34 0.04 5940379.04 698749.36 CB- MAG -MS 195.50 0.33 18.00 195.50 127.70 1.11 0.19 5940379.82 698749.49 CB- MAG -MS 295.50 0.17 22.00 295.49 227.69 1.52 0.34 5940380.23 698749.63 CB- MAG -MS 395.50 0.33 127.00 395.49 327.69 1.49 0.62 5940380.20 698749.91 CB- MAG -MS 495.50 0.42 189.00 495.49 427.69 0.95 0.79 5940379.67 698750.10 CB- MAG -MS 595.50 0.50 194.00 595.49 527.69 0.17 0.63 5940378.88 698749.96 CB- MAG -MS 695.50 0.58 225.00 695.48 627.68 -0.61 0.17 5940378.09 698749.51 CB- MAG -MS 795.50 0.33 257.00 795.48 727.68 -1.04 -0.47 5940377.65 698748.89 CB- MAG -MS 895.50 0.17 313.00 895.48 827.68 -1.00 -0.86 5940377.68 698748.50 CB- MAG -MS 995.50 0.25 39.00 995.48 927.68 -0.73 -0.83 5940377.95 698748.52 CB- MAG -MS 1095.50 0.75 110.00 1095.48 1027.68 -0.78 -0.08 5940377.91 698749.27 CB- MAG -MS 1195.50 0.25 133.00 1195.47 1127.67 -1.16 0.70 5940377.56 698750.06 CB- MAG -MS 1295.50 0.25 103.00 1295.47 1227.67 -1.35 1.07 5940377.37 698750.43 CB- MAG -MS 1395.50 0.42 99.00 1395.47 1327.67 -1.46 1.64 5940377.28 698751.01 CB- MAG -MS 1495.50 0.50 113.00 1495.47 1427.67 -1.69 2.41 5940377.08 698751.78 CB- MAG -MS 1595.50 0.50 143.00 1595.46 1527.66 -2.21 3.07 5940376.57 698752.46 CB- MAG -MS 1695.50 0.33 147.00 1695.46 1627.66 -2.80 3.49 5940376.00 698752.89 CB- MAG -MS 1795.50 0.50 139.00 1795.46 1727.66 -3.37 3.93 5940375.44 698753.35 CB- MAG -MS 1895.50 0.33 25.00 1895.46 1827.66 -3.44 4.34 5940375.38 698753.76 CB- MAG -MS 1995.50 0.33 11.00 1995.45 1927.65 -2.89 4.52 5940375.93 698753.92 CB- MAG -MS 2095.50 0.67 327.00 2095.45 2027.65 -2.12 4.25 5940376.69 698753.64 CB- MAG -MS 2195.50 0.50 347.00 2195.45 2127.65 -1.20 3.84 5940377.60 698753.20 CB- MAG -MS 2295.50 0.25 93.00 2295.44 2227.64 -0.79 3.96 5940378.01 698753.31 CB- MAG -MS 2395.50 0.92 145.00 2395.44 2327.64 -1.46 4.64 5940377.36 698754.00 CB- MAG -MS 2495.50 0.92 157.00 2495.43 2427.63 -2.86 5.41 5940375.99 698754.81 CB- MAG -MS 2595.50 0.83 143.00 2595.42 2527.62 -4.17 6.16 5940374.69 698755.60 CB- MAG -MS 2695.50 1.42 110.00 2695.40 2627.60 -5.18 7.76 5940373.73 698757.22 CB- MAG -MS 2704.50 1.17 137.00 2704.39 2636.59 -5.28 7.93 5940373.63 698757.39 CB- MAG -MS *perry Drilling Service* Survey Report Company: BP Amoco Date: 1/21/2009 Time 10:41:04 Page: 2 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01 -05, True North Site: PB DS 01 Vertical (TVD) Reference: 01 -0518 67.8 Well: 01 -05 Section (VS) Reference: Well (0.00N,0.00E,125.18Azi) Wellpath: 01 -058 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2705.70 1.17 137.18 2705.59 2637.79 -5.30 7.94 5940373.61 698757.41 13 3/8" 2795.50 1.25 150.00 2795.37 2727.57 -6.82 9.06 5940372.12 698758.56 CB- MAG -MS 2898.50 4.25 106.00 2898.25 2830.45 -8.85 13.29 5940370.21 698762.85 CB- MAG -MS 2991.50 7.25 104.00 2990.77 2922.97 -11.22 22.30 5940368.08 698771.91 CB- MAG -MS 3084.50 10.25 103.00 3082.68 3014.88 -14.50 36.06 5940365.16 698785.76 CB- MAG -MS 3255.50 14.25 110.00 3249.76 3181.96 -25.12 70.67 5940355.45 698820.64 CB- MAG -MS 3558.50 20.75 115.00 3538.60 3470.80 -60.60 154.46 5940322.19 698905.32 CB- MAG -MS 3865.50 30.25 120.00 3815.41 3747.61 - 122.40 271.00 5940263.50 699023.44 CB- MAG -MS 4169.50 39.75 124.00 4064.18 3996.38 - 215.26 418.25 5940174.55 699173.08 CB- MAG -MS 4386.50 47.00 125.00 4221.81 4154.01 - 299.69 540.93 5940093.40 699297.94 CB- MAG -MS 4650.50 44.75 111.00 4406.07 4338.27 - 388.60 707.21 5940008.90 699466.50 CB- MAG -MS 4690.00 44.83 111.11 4434.10a 4366.30 - 398.60 733.18 5939999.59 699492.73 MWD +IFR +MS 4700.00 44.69 112.16 4441.20 4373.40 - 401.19 739.73 5939997.17 699499.34 9 5/8" 4741.10 44.21 116.55 4470.55 4402.75 - 413.05 765.94 5939986.01 699525.85 MWD +IFR +MS 4783.10 42.57 121.17 4501.08 4433.28 - 426.96 791.20 5939972.77 699551.47 MWD +IFR +MS 4833.57 42.14 126.88 4538.39 4470.59 - 445.96 819.36 5939954.52 699580.12 MWD +IFR+MS 4876.39 41.97 131.81 4570.19 4502.39 - 464.13 841.53 5939936.94 699602.76 MWD +IFR +MS 4969.48 41.99 132.52 4639.39 4571.59 - 505.93 887.68 5939896.38 699649.99 MWD +IFR +MS 5063.54 41.28 129.99 4709.70 4641.90 - 547.14 934.65 5939856.43 699698.02 MWD +IFR +MS 5157.66 40.68 132.77 4780.76 4712.96 - 587.92 980.96 5939816.88 699745.39 MWD +IFR +MS 5250.80 40.31 135.29 4851.59 4783.79 - 629.95 1024.44 5939776.01 699789.96 MWD +IFR +MS 5343.80 40.30 137.88 4922.52 4854.72 - 673.64 1065.78 5939733.43 699832.44 MWD +IFR +MS 5437.22 41.00 140.85 4993.40 4925.60 - 719.82 1105.39 5939688.31 699873.25 MWD +IFR +MS 5529.90 40.49 141.17 5063.62 4995.82 - 766.83 1143.45 5939642.32 699912.54 MWD +IFR +MS 5623.40 40.78 141.41 5134.57 5066.77 - 814.35 1181.53 5939595.83 699951.85 MWD +IFR +MS 5715.34 41.57 141.37 5203.78 5135.98 - 861.65 1219.30 5939549.54 699990.86 MWD +IFR +MS 5809.27 41.47 141.79 5274.10 5206.30 - 910.43 1257.99 5939501.80 700030.82 MWD +IFR +MS 5901.16 41.29 142.12 5343.05 5275.25 - 958.27 1295.43 5939454.97 700069.50 MWD +IFR +MS 5994.73 41.44 141.86 5413.28 5345.48 - 1006.99 1333.51 5939407.27 700108.85 MWD +IFR +MS 6089.09 40.79 139.91 5484.37 5416.57 - 1055.13 1372.64 5939360.18 700149.24 MWD +IFR +MS 6180.29 40.24 140.51 5553.71 5485.91 - 1100.65 1410.56 5939315.68 700188.34 MWD +IFR +MS 6273.44 39.77 140.27 5625.06 5557.26 - 1146.79 1448.74 5939270.57 700227.72 MWD +IFR +MS 6366.67 38.95 140.18 5697.14 5629.34 - 1192.23 1486.57 5939226.14 700266.73 MWD +IFR +MS 6459.29 40.08 139.67 5768.59 5700.79 - 1237.32 1524.51 5939182.07 700305.84 MWD +IFR +MS 6551.51 40.28 139.46 5839.05 5771.25 - 1282.61 1563.10 5939137.82 700345.61 MWD +IFR +MS 6644.44 41.56 140.32 5909.27 5841.47 - 1329.16 1602.31 5939092.32 700386.03 MWD +IFR +MS 6737.86 41.20 140.32 5979.37 5911.57 - 1376.69 1641.74 5939045.85 700426.70 MWD +IFR +MS 6832.82 40.98 140.37 6050.93 5983.13 - 1424.74 1681.57 5938998.86 700467.78 MWD +IFR +MS 6925.40 41.20 139.18 6120.71 6052.91 - 1471.20 1720.86 5938953.46 700508.28 MWD +IFR +MS 7017.81 40.77 138.94 6190.47 6122.67 - 1516.98 1760.58 5938908.75 700549.19 MWD +IFR +MS 7111.00 40.38 139.00 6261.25 6193.45 - 1562.71 1800.37 5938864.09 700590.17 MWD +IFR +MS 7204.99 39.95 138.60 6333.08 6265.28 - 1608.32 1840.30 5938819.54 700631.29 MWD +IFR +MS 7298.78 40.56 139.67 6404.66 6336.86 - 1654.15 1879.95 5938774.77 700672.13 MWD +IFR +MS 7392.42 40.53 140.41 6475.81 6408.01 - 1700.81 1919.04 5938729.17 700712.44 MWD +IFR +MS 7485.26 40.40 140.42 6546.45 6478.65 - 1747.24 1957.43 5938683.76 700752.04 MWD +IFR +MS 7578.02 40.55 141.02 6617.01 6549.21 - 1793.85 1995.55 5938638.18 700791.37 MWD +IFR +MS 7671.06 40.22 140.36 6687.88 6620.08 - 1840.49 2033.74 5938592.56 700830.77 MWD +IFR +MS 7762.79 40.66 141.25 6757.69 6689.89 - 1886.61 2071.34 5938547.46 700869.57 MWD +IFR +MS 7857.13 40.61 141.14 6829.29 6761.49 - 1934.49 2109.84 5938500.62 700909.32 MWD +IFR +MS 7950.77 39.71 141.19 6900.85 6833.05 - 1981.53 2147.71 5938454.59 700948.42 MWD +IFR +MS 8044.10 40.62 139.96 6972.17 6904.37 - 2028.02 2185.94 5938409.13 700987.86 MWD +IFR +MS 8136.84 40.62 140.15 7042.57 6974.77 - 2074.31 2224.71 5938363.88 701027.83 MWD +IFR +MS • 'Sperry Drilling Service • Survey Report Company: BP Amoco Date: 1/21/2009 Time: 10:41:04 Page: 3 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01 -05, True North Site: PB DS 01 Vertical (TVD) Reference: 01 -05B 67.8 Well: 01 -05 Section (VS) Reference: Well (0.00N,0.00E,125.18Azi) Wellpath: 01 -05B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 8230.62 39.51 140.32 7114.34 7046.54 - 2120.71 2263.32 5938318.52 701067.65 MWD +IFR +MS 8323.54 41.27 141.93 7185.11 7117.31 - 2167.59 2301.09 5938272.65 701106.64 MWD +IFR +MS 8415.00 39.94 141.78 7254.54 7186.74 - 2214.40 2337.86 5938226.83 701144.63 MWD +IFR +MS 8508.57 40.45 142.60 7326.02 7258.22 - 2262.11 2374.88 5938180.11 701182.89 MWD +IFR +MS 8600.59 40.76 141.89 7395.88 7328.08 - 2309.46 2411.55 5938133.75 701220.79 MWD +IFR +MS 8692.28 41.46 140.71 7464.96 7397.16 - 2356.50 2449.24 5938087.71 701259.71 MWD +IFR +MS 8785.32 41.22 140.84 7534.82 7467.02 - 2404.11 2488.11 5938041.15 701299.81 MWD +IFR +MS 8877.80 41.46 139.97 7604.25 7536.45 - 2451.18 2527.04 5937995.13 701339.97 MWD +IFR +MS 8971.21 40.57 139.90 7674.74 7606.94 - 2498.10 2566.49 5937949.27 701380.65 MWD +IFR +MS 9062.86 41.21 138.81 7744.02 7676.22 - 2543.61 2605.57 5937904.80 701420.91 MWD +IFR +MS 9155.89 39.71 139.19 7814.80 7747.00 - 2589.17 2645.18 5937860.31 701461.71 MWD +IFR +MS 9248.45 41.11 139.64 7885.28 7817.48 - 2634.74 2684.21 5937815.79 701501.92 MWD +IFR +MS 9340.58 40.59 140.16 7954.97 7887.17 - 2680.83 2723.03 5937770.74 701541.94 MWD +IFR +MS 9433.42 40.34 140.30 8025.60 7957.80 - 2727.14 2761.57 5937725.46 701581.69 MWD +IFR +MS 9526.10 41.00 137.42 8095.90 8028.10 - 2772.61 2801.31 5937681.06 701622.61 MWD +IFR +MS 9619.95 42.19 136.34 8166.09 8098.29 - 2818.08 2843.90 5937636.73 701666.38 MWD +IFR +MS 9712.28 45.74 133.73 8232.54 8164.74 - 2863.39 2889.21 5937592.64 701712.87 MWD +IFR +MS 9805.87 48.98 132.47 8295.93 8228.13 - 2910.40 2939.49 5937546.96 701764.36 MWD +IFR +MS 9898.21 53.27 129.51 8353.88 8286.08 - 2957.49 2993.76 5937501.32 701819.86 MWD +IFR +MS 9932.59 53.14 129.49 8374.47 8306.67 - 2975.01 3015.01 5937484.38 701841.55 MWD +IFR +MS 9991.46 52.70 129.20 8409.96 8342.16 - 3004.78 3051.33 5937455.57 701878.64 MWD +IFR +MS 10085.52 51.74 129.11 8467.59 8399.79 - 3051.72 3108.97 5937410.17 701937.50 MWD +IFR +MS 10177.53 50.85 129.15 8525.12 8457.32 - 3097.04 3164.67 5937366.34 701994.37 MWD +IFR +MS 10271.45 51.27 129.38 8584.15 8516.35 - 3143.27 3221.23 5937321.62 702052.13 MWD+IFR +MS 10340.16 51.01 129.87 8627.26 8559.46 - 3177.39 3262.44 5937288.60 702094.22 MWD +IFR +MS 10364.80 50.79 130.05 8642.80 8575.00 - 3189.67 3277.10 5937276.71 702109.20 7" 10382.07 50.64 130.17 8653.73 8585.93 - 3198.29 3287.32 5937268.37 702119.64 MWD +IFR +MS 10402.08 51.56 130.69 8666.30 8598.50 - 3208.38 3299.17 5937258.58 702131.76 MWD +IFR +MS 10415.81 54.85 132.27 8674.52 8606.72 - 3215.67 3307.41 5937251.52 702140.18 MWD +IFR +MS 10446.67 62.15 132.76 8690.64 8622.84 - 3233.44 3326.79 5937234.27 702160.02 MWD +IFR +MS 10474.73 68.52 132.27 8702.34 8634.54 - 3250.66 3345.57 5937217.55 702179.25 MWD +IFR +MS 10507.44 75.40 133.81 8712.46 8644.66 - 3271.88 3368.29 5937196.94 702202.52 MWD +IFR +MS 10539.04 81.07 132.73 8718.90 8651.10 - 3293.08 3390.80 5937176.34 702225.58 MWD +IFR +MS 10566.51 86.72 133.24 8721.82 8654.02 - 3311.69 3410.78 5937158.26 702246.04 MWD +IFR +MS 10589.21 92.02 131.64 8722.07 8654.27 - 3327.00 3427.52 5937143.40 702263.18 MWD +IFR +MS 10607.20 95.85 130.57 8720.84 8653.04 - 3338.80 3441.04 5937131.96 702277.01 MWD +IFR +MS 10641.82 102.85 130.33 8715.22 8647.42 - 3360.95 3467.02 5937110.51 702303.56 MWD +IFR +MS 10672.77 103.50 126.44 8708.16 8640.36 - 3379.66 3490.64 5937092.43 702327.66 MWD +IFR +MS 10702.87 102.93 125.26 8701.28 8633.48 - 3396.82 3514.39 5937075.90 702351.85 MWD +IFR +MS 10733.95 100.42 126.85 8694.99 8627.19 - 3414.73 3538.99 5937058.64 702376.92 MWD +IFR +MS 10767.20 97.91 126.82 8689.70 8621.90 - 3434.41 3565.26 5937039.66 702403.70 MWD+IFR +MS 10795.08 96.53 126.94 8686.19 8618.39 - 3451.01 3587.38 5937023.66 702426.25 MWD +IFR +MS 10826.19 95.54 127.43 8682.92 8615.12 - 3469.71 3612.03 5937005.61 702451.38 MWD +IFR +MS 10856.65 93.93 127.02 8680.41 8612.61 - 3488.07 3636.20 5936987.90 702476.02 MWD +IFR +MS 10887.43 91.02 127.05 8679.08 8611.28 - 3506.59 3660.75 5936970.03 702501.05 MWD +IFR +MS 10918.73 90.47 127.58 8678.67 8610.87 - 3525.56 3685.64 5936951.72 702526.43 MWD +IFR +MS 10980.07 90.03 127.68 8678.40 8610.60 - 3563.01 3734.22 5936915.57 702575.98 MWD +IFR +MS 11073.85 89.97 128.19 8678.40 8610.60 - 3620.67 3808.18 5936859.89 702651.43 MWD +IFR +MS 11166.23 89.36 127.77 8678.94 8611.14 - 3677.52 3881.00 5936804.98 702725.71 MWD +IFR +MS 11258.75 88.74 127.75 8680.48 8612.68 - 3734.16 3954.13 5936750.29 702800.31 MWD +IFR +MS 11332.37 88.56 127.48 8682.21 8614.41 - 3779.08 4012.43 5936706.92 702859.77 MWD +IFR +MS 11351.01 88.40 126.50 8682.71 8614.91 - 3790.29 4027.31 5936696.11 702874.95 MWD +IFR +MS 11380.60 87.54 125.08 8683.75 8615.95 - 3807.59 4051.30 5936679.45 702899.38 MWD +IFR +MS &perry Drilling Service* Survey Report Company: BP Amoco Date: 1/21/2009 Time: 10:41:04 Page: 4 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01 -05, True North Site: PB DS 01 Vertical (TVD) Reference: 01 -05B 67.8 Well: 01 -05 Section (VS) Reference: Well (0.00N,0.00E,125.18Azi) Wellpath: 01 -05B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 11412.87 88.02 123.08 8685.00 8617.20 - 3825.66 4078.01 5936662.09 702926.55 MWD +IFR +MS 11445.02 88.22 120.28 8686.06 8618.26 - 3842.53 4105.35 5936645.95 702954.33 MWD +IFR +MS 11476.53 87.94 119.45 8687.11 8619.31 - 3858.21 4132.66 5936630.99 702982.04 MWD+IFR +MS 11508.68 87.97 120.02 8688.26 8620.46 - 3874.15 4160.56 5936615.80 703010.35 MWD +IFR +MS 11538.49 88.92 119.73 8689.07 8621.27 - 3888.99 4186.40 5936601.64 703036.57 MWD +IFR +MS 11631.97 90.36 119.84 8689.66 8621.86 - 3935.42 4267.52 5936557.37 703118.89 MWD +IFR+MS 11724.78 89.08 120.52 8690.11 8622.31 - 3982.08 4347.75 5936512.85 703200.31 MWD +IFR +MS 11818.19 89.17 120.53 8691.54 8623.74 - 4029.52 4428.20 5936467.55 703281.98 MWD +IFR +MS 11912.53 89.67 120.70 8692.49 8624.69 - 4077.56 4509.39 5936421.67 703364.40 MWD +IFR +MS 12005.34 89.76 121.06 8692.96 8625.16 - 4125.19 4589.04 5936376.15 703445.28 MWD +IFR +MS 12099.23 90.10 119.98 8693.07 8625.27 - 4172.87 4669.92 5936330.62 703527.38 MWD +IFR +MS 12130.04 90.09 116.91 8693.02 8625.22 - 4187.55 4697.01 5936316.67 703554.85 MWD +IFR +MS 12161.30 90.67 114.28 8692.81 8625.01 - 4201.05 4725.20 5936303.91 703583.38 MWD +IFR +MS 12191.79 91.07 112.40 8692.35 8624.55 - 4213.13 4753.19 5936292.58 703611.68 MWD +IFR +MS 12222.49 90.86 110.74 8691.83 8624.03 - 4224.41 4781.73 5936282.05 703640.51 MWD +IFR +MS 12253.38 92.12 109.99 8691.03 8623.23 - 4235.16 4810.68 5936272.07 703669.73 MWD +IFR +MS 12284.65 91.50 109.66 8690.04 8622.24 - 4245.76 4840.08 5936262.25 703699.40 MWD +IFR +MS 12378.42 90.24 109.84 8688.62 8620.82 - 4277.44 4928.33 5936232.91 703788.44 MWD +IFR +MS 12470.06 89.75 110.25 8688.62 8620.82 - 4308.85 5014.42 5936203.78 703875.32 MWD +IFR+MS 12564.18 89.70 110.90 8689.08 8621.28 - 4341.93 5102.53 5936173.04 703964.27 MWD +IFR +MS 12657.75 90.94 111.59 8688.55 8620.75 - 4375.83 5189.74 5936141.45 704052.34 MWD +IFR +MS 12750.97 90.83 109.61 8687.11 8619.31 - 4408.62 5276.98 5936110.97 704140.41 MWD +IFR +MS 12843.77 88.89 110.37 8687.34 8619.54 - 4440.35 5364.19 5936081.56 704228.42 MWD +IFR +MS 12890.04 89.27 110.62 8688.08 8620.28 - 4456.54 5407.52 5936066.51 704272.16 MWD +IFR +MS 12936.73 88.70 113.03 8688.91 8621.11 - 4473.90 5450.86 5936050.31 704315.94 MWD +IFR +MS 12969.93 86.19 112.43 8690.39 8622.59 - 4486.71 5481.44 5936038.30 704346.85 MWD +IFR +MS 13001.55 86.21 112.39 8692.49 8624.69 - 4498.74 5510.61 5936027.05 704376.32 MWD +IFR +MS 13029.22 86.04 111.53 8694.36 8626.56 - 4509.06 5536.21 5936017.41 704402.19 MWD +IFR +MS 13091.58 87.61 107.34 8697.81 8630.01 - 4529.78 5594.92 5935998.25 704461.41 MWD +IFR +MS 13121.31 88.90 104.42 8698.72 8630.92 - 4537.90 5623.50 5935990.88 704490.20 MWD +IFR +MS 13153.23 88.34 103.15 8699.49 8631.69 - 4545.51 5654.49 5935984.09 704521.37 MWD +IFR +MS 13186.26 89.06 103.12 8700.24 8632.44 - 4553.01 5686.64 5935977.44 704553.72 MWD +IFR +MS 13214.35 90.13 103.02 8700.43 8632.63 - 4559.36 5714.00 5935971.81 704581.23 MWD +IFR +MS 13307.44 88.99 102.72 8701.15 8633.35 - 4580.10 5804.75 5935953.48 704672.49 MWD +IFR +MS 13399.16 88.91 103.19 8702.83 8635.03 - 4600.66 5894.12 5935935.29 704762.37 MWD +IFR +MS 13491.81 88.93 102.58 8704.58 8636.78 - 4621.31 5984.42 5935917.02 704853.18 MWD +IFR +MS 13584.09 89.40 102.26 8705.92 8638.12 - 4641.16 6074.53 5935899.56 704943.77 MWD +IFR +MS 13677.04 90.33 101.91 8706.14 8638.34 - 4660.62 6165.42 5935882.50 705035.14 MWD +IFR +MS 13768.96 89.07 101.34 8706.62 8638.82 - 4679.14 6255.45 5935866.36 705125.62 MWD +IFR +MS 13862.88 90.64 101.34 8706.86 8639.06 - 4697.61 6347.54 5935850.33 705218.15 MWD +IFR +MS 13956.04 89.32 101.24 8706.89 8639.09 - 4715.85 6438.89 5935834.51 705309.95 MWD +IFR +MS 14047.75 89.10 100.56 8708.16 8640.36 - 4733.19 6528.94 5935819.55 705400.42 MWD +IFR +MS 14140.79 89.82 100.35 8709.03 8641.23 - 4750.07 6620.43 5935805.08 705492.32 MWD +IFR +MS 14232.97 88.51 98.74 8710.38 8642.58 - 4765.35 6711.32 5935792.20 705583.58 MWD +IFR +MS 14296.00 88.51 98.74 8712.01 8644.21 - 4774.93 6773.59 5935784.27 705646.08 PROJECTED to TD , TRE I 5 r =' 4 -1/8" CIW • WELLHEAD = FMC SAFI/ NOTES: ** *CHROME TUBING & LINER * ** A CTUATOR = OTIS 01-05B KB. ELEV = 73.0' BF. ELEV = NA KOP = 3089' • 1� .. Max Angle = 104° @ 10673' �� � ■�y 1135' J HES ES CEMENTER Datum MD = NA I !: " Datum TVD = 8800'SS ( ( 1143' 1-19-5/8" TIEBACK, ID = 8.681" I 30" CONDUCTORI — 116' 0/ � 1169' J CP I9 5/8" CSG, 47 #, L 80, TCII, ID = 8.681" H 1147' 0j • 11 ' 1 2181' H4-1/2" HES X NIP (9CR), ID = 3.813" I j' '∎ 2184' I- -I9 - 5/8" FOCI 120" CSG, 94#, H-40, ID = 19.124" I-1 1216' �/ !� 2223' I - 19 - 5/8" CP I 1 o n GAS LIFT MANDRELS 13-3/8" CSG, 72 #, N -80, ID = 12.347" H 2709' - ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" 9753 1 3168 3261 14 KBG -2 DOME BK 16 02/05/09 2 5463 5208 47 KBG -2 SO BK 20 02/05/09 4 -1/2" PARKER SWN NIPPLE '51 3 7422 6268 50 KBG-2 DMY BK 0 01/16/09 Fi 4 8751 7090 52 KBG -2 DCK BK 0 01/16/09 1 LNR, 26#, L -80, TCII, .0383, ID = 6.276" 1-I 4562' - I I 5 10081 7303 48 KBG -2 DMY BK 0 01/16/09 4531' H 7" PORTED TIEBACK SEAL ASSY, ID = 6.170" I 4552' _1 9 -5/8" x 7" BKR ZP LT PKR, ID = 6.28" TOP OF 9 -5/8" GEN I WHIPSTOCK H 4690' w /FLEX LOCK LNR HGR, ID = 6.31" V '°: :", . WINDOW -. 9 - 5/8" MILLOUT WIND 4690' - 4708' 19-5/8" EZSV (TAGGED 12/21/08)i-1 4714' ( ) 1 1 10116' 1 — 4 -1/2" HES X NIP (9CR), ID = 3.813" OH 10147' I — 7" x 4 -1/2" BKR S -3 PKR, ID = 3.87" F - 1 10180' 141/2" HES X NIP (9CR), '��'�1�'1W ID= 3.813„ 4 -5/8" MILLOUT WINDOW (01 -05) 10000'- 10070' ••••••r ' 10211' (14 -1/2" HES XN NIP (9CR), •••••41- ID = 3.725" • 19 -5/8" CSG, 40# / 43.5 #, 47 #, SOO -95, ID = 8.681" I-I 10000' • 0 ".44 '� 4��� ' � • ••∎ 10217' . 1 - 17" BKR LNR TIEBACK SLV I 10223' 1--14 WLEG, ID = 3.958" 1 4 -1/2" TBG, 12.6 #, 13-CR, .0152 bpf, ID = 3.958" I-I 10223' 10227' 1 — 7" x 5" BKR zXP LT PKR, ID = 4.40" 17" LNR, 26#, L-80, BTC-M, .0383, ID = 6.276" H 10381' 10240' 1 7" x 5" BKR HMC LNR HGR, I I ID = 4.44" PERFORATION SUMMARY I I 10247' 1-15" x 4-1/2" XO, ID = 3.96" I REF LOG: BHCS ON 3/10/1992 1 ANGLE AT TOP PERF: 22 @ 11147 Note: Refer to Production DB for historical perf data 1 I SIZE j SPF INTERVAL Opn/Sgz DATE SLOTTED LNR 10293 - 14269 0 01/13/09 1 1 4 -1/2" SLTD LNR, 12.6#,13 -CR, IBT - -M, .0152, ID = 3.958" I 14292' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/03/76 ORIGINAL COMPLETION WELL: 01 -05B 03/17/92 RIG SIDETRACK (01 -05ST1) PERMIT No: 2070480 05/27/07 N7ES ABORTED SIDETRACK (SUSP) API No: 50- 029 - 20076 -02 01/18/09 N2ES SIDETRACK (01 -05B) SEC 8, T1ON, R15E, 546' FNL & 1423' FWL 01/24/09 /TLH CORRECTIONS 02/12/09 _ MN/SV DRLG DRAFT CORRECTIONS BP Exploration (Alaska) i • • HALLIBURTON Drilling and Formation Evaluation 10 - Feb - State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 01 -05B Dear Christine Mahnken Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie -on Survey: 4,650.50' MD Window / Kickoff Survey 4,690.00' MD (if applicable) Projected Survey: 14,296.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. Anchorage, AK 99508 , / (1\* I Date / ( / 4 , b 9 Signed (An e-mail confirmation, citing the well, to James.Durand @Halliburton.com would be an additional courtesy.) Please call me at 273 -3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) 01 -05B • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, January 14, 2009 11:22 AM To: ' Nadem, Mehrdad' Subject: RE: 01 -05B (207 -048) Mehrdad, Stopping short is not an issue. The "shorter" td will be captured on the completion report. Call or message with any questions. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM @BP.com] Sent: Wednesday, January 14, 2009 9:08 AM To: Maunder, Thomas E (DOA) Subject: 01 -05B Tom, 01 -05B had a permitted TD of 14,966' MD. The Gravity Drainage Group however decided to call the TD at 14,296' MD. The reason for this decision was the potential of entering into water saturated reservoir. Please let me know if there are any actions needed on my part for this change. Best Regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564 -5941 CeII: 907/440 -0213 Email: nademm@bp.com 1/14/2009 01 -05B BOP and Casing testin, Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 19, 2008 2:56 PM To: 'Nadem, Mehrdad' Cc: NSU, ADW DrIg Rig 2es Subject: RE: 01 -05B (207 -048) BOP and Casing testing Reducing the test to 3500 psi is acceptable. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM @BP.com] Sent: Friday, December 19, 2008 2 :48 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW DrIg Rig 2es Subject: 01 -05B BOP and Casing testing Tom, 01 -05B is a producer. The permit to Drill application for this well requested testing the BOPs to 4,000 psi. The permit to drill also requites the testing to be performed at 4,000 psi. This is to request permission to pressure test the BOPs and the casing /liners in this well to 3,500 psi. Today is a flex Friday for us. As such, please contact me at 696 -6649 if you have any questions regarding this request. Best Regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907 /564 -5941 CeII: 907/440 -0213 Email: nademm @bp.com 12/19/2008 01 -05B Variance Page 1 of 2 Maunder, Thomas E (DOA) From: Nadem, Mehrdad [NademM @BP.com] Sent: Thursday, October 23, 2008 2 :40 PM To: Maunder, Thomas E (DOA) Subject: RE: 01 -05B Variance you are correct, it is a side track. 0 1-1 Ogg Thank you. Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440 -0213 Email: nademm @bp.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, October 23, 2008 2:38 PM To: Nadem, Mehrdad Subject: RE: 01 -05B Variance Mehrdad, The ram exception really doesn't require a variance since the MASP is < 3000 psi. Regarding removing the paddle, does that apply for this well? I did not think that you will be drilling any surface hole. Could you clarify? I have not checked the file. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM @BP.com] Sent: Thursday, October 23, 2008 2:35 PM To: Maunder, Thomas E (DOA) Subject: 01 -05B Variance Tom, 01 -05B permit was issued last year. Since then we have been asking for variance requesting for approval to test the lower rams after the tubing and the tubing hanger is out of the hole. Would you please consider the following variances for 01 -056. Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path - forward de- completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. 10/24/2008 O1 - O5B Variance • Page 2 of 2 • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. While the flow paddle is removed from the flow line, PVT alarms will be used and the pit levels accurately monitored for any pit gain. Also, a visual check will be made during connections by returned lookin g down the riser to ensure the well is not flowing. After ft eturn debris that could plug the flow line diminishes the flow paddle will be reinstalled. Thank you, Mehrdad Nadem Operations Drilling Engineer Phone: 907 /564 -5941 Cell: 907/440 -0213 Email: nademm@bp.com 10/24/2008 01 -05B - AOGCC.doc Page 1 of 1 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 15, 2008 10:42 AM To: 'Nadem, Mehrdad' Subject: RE: 01 -05B (207 -048) - AOGCC.doc Thanks Mehrdad. I will place a copy of these documents in the well file. Call or message with any questions. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM @BP.com] Sent: Wednesday, October 15, 2008 7:11 AM To: Maunder, Thomas E (DOA) Subject: 01 -05B - AOGCC.doc Tom: attached is the information that you have requested. The only other well that did not pass the major close approach criteria was 12 -02. The close approach occurs in the production section, and we have minor risked this well. Please let me know if you need any additional information. Regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564 -5941 Cell: 907/440 -0213 Email: nademm @bp.com «01 -05B - AOGCC.doc» «01 -05A WP16 Report draft.pdf» 10/15/2008 0 1 01 -05B Wel!plan Summary Well Sidetrack / Tar et Well 01 -05B Type Horizontal Objective Sag River Producer AFE Number: 1 PBD4P2527 API Number: 1 50- 029 - 20076 -02 Surface Northing Easting Offsets TRS Location 5940376 698745 4732' FSL / 3860' FEL Sec 8, T10N, R15E Target X Y Township Range Section FSL FEL Surface As -built 698,745 5,940,376 10N 15E 8 4,732' 3,860' Target 1 702,119 5,937,265 10N 15E 8 1,531' 581' Target 2 703,970 5,936,152 10N 15E 9 369' 4043' Target 4 : BHL 706,352 5,935,791 10N 15E 8 5,223' 1,673' Planned KOP: 4,700' MD Planned Lateral TD: 15,010 Planned Spud: 10/15/2008 Planned Lateral TVD: 8695' TVD Rig: Nabors 2ES GL: 33.4' Top of Casing: 1 39.30' RTE: 67.80' Directional Program Approved Well plan: WP16 Exit point: 4,700' MD / 4,441' TVD Maximum Hole Inclination: -105° from 10,651' through the horizontal interval down to -90° at TD Proximity Issues: All proximity issues will be minor risked (1:200) Survey Program: Gyro orientation will not be required for the initial kick -off (since > 7 degrees). Standard MWD +IIFR +MS. Nearest Well: 630' (12 -02 Ivishak Injector) & 1740' (03 -15A Sag Producer) Nearest Property Line 15,840' • 0 Logging Program Hole Section: Required Sensors/Service 9 -5/8" Cased hole USIT logging to determine cut point: DONE 8 -1/2" Intermediate: DIR /GR /RES /PWD 6 -1/8" Production: DIR /GR /ABI /RES:, Den /Neu in the horizontal segment and Mud Logging Comments: *Azimuthal Density may be picked up after the invert/belly has been drilled in the production hole, but should be picked up before entering the base of the Sag. Mud Program Intermediate Interval Fluid Properties Plastic API Fluid HTHP Fluid Drill Depth MD Mud Wt. Viscosity Yield Point Loss Loss CO 200 Solids (ft) (lb/gal) (cp) (Ib /100ft (m1 /30min) (m1 /30min) pH ( %) MBT 4,700 Milling 9.4 15 -22 30 - 40 6 - 8 N/C 9 -9.5 < 6.0 <20 4,700 — 9,645' (150' from top 9.4 -9.8 10 -18 18 -28 4.0 -7.0 N/C 9 -10 <6.0 <20 HRZ at 9,845' MD) 11.3 12 -22 18 -28 4.0 -6.0 < 10.0 9 -10 <6.0 <20 9,645 — 10,358' Production Interval Fluid Properties Plastic API Fluid Low Shear Depth MD Mud Wt. Viscosity Yield Point Loss Rate (ft) (lb/gal) (cp) (Ib /100ft (m1/30min) Viscosity (CP) pH MBT 10,358'- 15,010 8.5 -8.6 6 -12 22 -28 6 -8 > 20,000 9.0 -9.5 <4 Casing / Tubing Program Hole Size Casing/Tubing Wt. Grade Connection Length Top (MD) Bottom (MD) Size 9 Csg 7" Tieback Liner 26# L -80 TC -II -4550' Surface 4,550' 8 -1/2" 7" Drlg Liner 26# L -80 BTC -M -5,808' 4,550' 10,358' 4- 6-1/8" 4 -1/2" Slotted Liner 12.6# L - 80 IBT -M - 4,802' 10,208' 15,010' 4- Tubing 4 -1/2" 12.6# 13Cr _ VamTop -10,208' Surface _ 10,208' * - There is a contingency to run a solid liner and cement and perforate if the formation is found to be water wet. Cementing Program Casing String: 7 ", 26#, L -80, BTC -M Intermediate Liner Lead slurry: Remainder of 8 -1/2" x 7" annulus with 40% excess, plus 150' of 9 -5/8" X 7" liner lap. Slurry Design Basis: Tail slurry: 500' of 8 -1/2" x 7" annulus with 40% excess, plus 80' of 7 ", 26# shoe track plus 200' DP x 9 -5/8 ". Pre -Flush None planned Fluids Sequence 1 Volume: Spacer 50 bbls Mud Push 11 3 Lead Slurry 179.8 bbl / 599.20 sks, 11.8 ppg CRETE; 1.68 ft /sk. 4- Tail Slurry 18.9 bbl / 91.28 sks, Class 'G', 15.8 ppg; 1.16 ft' /sk. Casing String: 7 ", 26#, L -80, TC -II Tieback Liner Lead slurry: None planned. Slurry Design Basis: Tail slurry: 1,350' of 9 -5/8" x 7" annulus — TOC: 3,200' MD. Pre -Flush None planned Fluids Sequence / Volume: Spacer -'20 bbls Mud Push 11 Lead Slurry None planned. Tail Slurry 38.3 bbl / 214.6 ft / 183.5 sks Class `G', 15.8ppg; 1.17 ft' /sk. 2 4 \ \ \ ( ) ) ! 24 I ) \ \ BP Amoco } \ Prudhoe Bay }\ PS DS 01 { ƒ 01-05 ƒ)} Plan 01-05A i ; \ Plan: 01-05A Wp 16.0 • $ © f } a / \ } } } Standard :Proposal Report -- 16 September, 2008 } \ } } } } $ } f 3 # } \ \ 1 \ \ 4 } > } « }\� � y/} \ \ } { { ¥ > ( ) ! \ ` � \ _ , ' I t - HALLWBURTQN f } } Sperry Drilling Services / : } - SURVEY PROGRAM Project: Prudhoe Bay Site: PB DS 01 bp 1- 4ALL.IBURTDN Date: 2008-09-16T0000.00 Validated: Yes Version: 22 - Well: 01 -05 - - Depth From Depth To Survey /Plan Tool Wellbore: Plan 01 -05A Sperry Clrilling Services 4700.00 15009.40 01-05A Wp 16.0 (Plan01-05A) ho (01 -05P81) CWD IFR MS Plan: 01 -05A Wp 16.0 (01 -05 /Plan 01 -05A) 0 4000 4500 5000 5500 6000 95.50 4700.00 1 : Camera .. --- - - - - -- ti WELLBORE TARGET DETAILS (MAPCO -ORDINATES) - - Start Dir 12 °/100' : 4700' MD, 4441.19'TVD : 85° RT TF DDI = 6.54 Name TVD +W -S +E/ -W Northing Easting Shape - 1 -05A T1 revised 8662.80 - 3201.88 3286.43 5937264.75 702118.85 Point 0 01-05A T2 8684.80 - 4363.11 5107.70 5936152.00 703970.00 Point Start Dir 4 ° /100' :4721.2' MD, 4456.19'TVD 01-05A T3 8692.80 - 4799.23 7001.97 5935766.00 705875.00 Point - _ _ _ 01 -05A Driller's Poly - 95% Confidence 8694.80 - 4687.82 7519.33 5935891.00 706389.22 Polygon _ 01 -05A Geo Poly 8694.80 - 4619.38 8224.20 5935978.00 707092.00 Polygon -- - ..`b 01 -05A T4 8684.80 - 4786.81 7479.49 5935791.00 706352.00 Point - 500 - '` __ - - End Dir : 5171' MD, 4788.29' TVD L- i -1000- _ - __- _ -.. -- _.__ WELL DETAILS: 01 05 ._ - -. ____ .__ __. -- - - '. Ground Level: 39.30 - +N/ - , i - PJ - Northing Easting Letittude Longitude Slot - Start Dir 4 °1100' :9491.19' MD. 8067.13'TVD 0 00 0.00 5940378 70 698749 33 70° 14' 28.240 N 148° 23' 41.253 W - -1500- �p r -15w - - -1 - REFERENCE INFORMATION - End Dir : 9789.73' MD, 8277.13' TVD - Coordinate (N /E) Reference: Well 01 -05, True North 2-2000- Vertical (TVD) Reference: 39.3TC +28.5'KB @67.8' © 67.80ft (39.3TC +28.5KB @67.8') - Measured Depth Reference: 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3TC +28.5'KB@67.8') _ - Calculation Method: Minimum Curvature O r r- 1 O 01- 05/01 -05 L COMPANY DETAILS: BP Amoco -2500- + - 01- 05/01 -05PB1 i Calculation Method: Minimum Curvature L _ 9 5/8" j Error System: ISCWSA O - O Scan Method: Tray. Cylinder North Z -3000- � � Error Surface: Elliptical Conic - Start Dir 21 °/100' : 10389.73' MD, 8662.8'TVD blaming Method: Rules Based O 7" - Start Dir 4.99 °/100' : 10651.63' MD, 8717.34'TVD 0 -3500- Start Dir 6 °/100' : 10952.31' MD, 8678.2'TVD Start Dir 4 °/100' : 14128.38' MD, 8691.12' _3500 - 1 -05A T1 revised - - End Dir : 11073.46' MD, 8678.45' 7VD CASING DETAILS 44 ; t:.° t` Start Dir 4 °/100' : 12089.22' MD, 8682.72'TVD End Dir : 14531.79' MD, 8692.8' TVD TVD MD Name Size _ 1211.47 1211.50 20" 20 Co - - End Dir : 12625.51' MD, 8684.97 TVD -4000 2704.39 2704.50 133/8" 13-3/8 '�' - "a - 8642.80 10358.69 7^ 7 " ._ - , ,- z ' 01 -05A Driller's Poly - 95% Confiden e 8694.80 15009.54 4 -112" 4 -12 I . ' �cnn_ -- - _. - -4500 SECTION DETAILS � - -- " '- u Sec MD Inc Ali ND +N/-5 +E / -W DLeg TFace VSec Target � ^ _ _ _ - - � - - Total Depth : 15009.55' MD, 8694.8' TV 3 1 4700.00 44.85 111.14 4441.19 - 400.97 739.78 0.00 0.00 839.24 . - . i , \ - -- - 2 4721.20 45.13 114.71 4456.19 - 406.81 753.58 12.00 85.00 854.01 . I ■ - 01- 05/01 -05A Wp 16.0 --5000 3 5171.04 40.63 140.46 4788.31 - 587.89 993.59 4.00 113.68 1153.77 - 4 9491.26 40.63 140.46 8067.13 - 2757.43 2784.32 0.00 0.00 3831.55 01 -05A T2 - - -- -- - -- - -- r -- - - -- - -� - 5 9789.80 50.00 130.00 8277.13 - 2906.43 2934.34 4.00 -42.25 4038.23 1 \ 4_1/2" - 6 10389.80 50.00 130.00 8662.80 - 3201.88 3286.43 0.00 0.00 4494,05 1-05A T1 revised i ` - 7 10651.71 105.00 130.00 8717.34 - 3360.00 3474.87 21.00 0.00 4738.00 1 �� - -5500 8 10952.39 90.00 130.00 8678.20 - 3551.07 3702.59 4.99 180.00 5032.80 01 -05A T3 - 9 11073.53 89.76 122.74 8678.45 - 3622.86 380007 6.00 -91.90 5153.60 01 -05A T4 _ 10 12089.30 89.78 122.74 8682.72 - 4172.14 4654.50 0.00 000 6169.35 - 11 12583.55 89.76 102.97 8684.80 -4363.11 5107.70 4.00 -90.03 6654.02 01-05A T2 - 12 12625.59 89.77 104.65 8884.97 - 4373.15 5148.53 4.00 89.95 6693.81 6000 13 14128.46 89.77 104.65 8691.12 -4753.16 6602.54 0.00 0.00 8123.34 i i i' i s i i i i r i r i r i i i i i r i i i i i i i l i i i i i i r i i i i i r i i i i i i i r i r - i --- 14 14531.86 89.76 88.51 8692.80 -4799.23 7001.97 4.00 -90.05 8484.60 01 -05A T3 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 15 15009.55 89.76 88.51 8694.80 - 4786.81 7479.49 0.00 0.00 8880.11 01 -05A T4 West( -) /East( +) (1000 ft/in) Project: Prudhoe Bay /'l f t I B / f N SURVEY PROGRAM Site: PB DS 01 bp H i ��l�arirlGi�rihf l DrsRTD / Date: 2008-09-16700.00:00 validated Yes Version: 22 Well: 01 -05 Sperry Drilling S � � Depth From Depth To Survey /Plan Tod Wellbore: Plan 01 -05A 95.50 4700.00 1 : Camera based mag multi sho (01- 05PB1) CB- MAG -MS Plan: 01 -05A Wp 16.0 (01 -05 /Plan 01 -05A) 4700.00 15009.40 01 -05A Wp 16.0 (Plan 01 -05A) MWD +IFR +MS WELL DETAILS: 01 - 05 WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Ground Level. 39.30 , Name TVD +N / -S +E / -W Northing Easting Shape +N / - +E/ -W Northing Easting Latittude Longitude Slot 1-05A T1 revised 8662.80 - 3201.88 3286.43 5937264.75 702118.85 Point 0. 0.00 5940378.70 698749.33 70 14' 28.240 N 148° 23' 41 253 W 01 -05A T2 8684.80 -4363.11 5107.70 5936152.00 703970.00 Point - - -- -- -i 01 -05A T3 8692.80 -4799.23 7001.97 5935766.00 705875.00 Point 01 -05A Dnller's Poly - 95% Confidence 8694.80 - 4687.82 7519.33 5935891.00 706389.22 Polygon Vertical Section ai 01 -05A Geo Poly 8694.80 - 4619.38 8224.20 5935978.00 707092.00 Polygon 01 -05A T4 8694.80 - 4786.81 7479.49 5935791.00 706352.00 Point 500 1000 1500 2000 2500 3000 3500 4000 4500 5G.... - _ __ 4000- 1 1 1 1 1 1 1 1 1 l 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 - 1 .. L1 -I _L__ IL 1 1 I J 1 1LLI_ l I I I L_.--1 I I__- REFERENCE INFORMATION Start D ir 12 °/100' : 4700' MD, 4441.19'TVD : 85° RT TF Co- ordinate (N /E) Reference: Well 01 -05, True North - _ _ - - - -- " Vertical (TVD) Reference: 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.5'KB (§67.8') - _ - - - - Measured Depth Reference: 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.5'KB @67.8') 4500 Sta rt Dir 4 °/100' : 4721.2 MD, 4456.19'TVD D D I =6 Calculation Method: Minimum Curvature _ III - UG3 End Dir : 5171' MD, 4788.29' TVD SECTION DETAILS Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target 5000 -- 1 4700.00 44.85 111.14 4441.19 - 400.97 739.78 0.00 0.00 839.24 2 4721.20 45.13 114.71 4456.19 -406.81 753.58 12.00 85.00 854.01 - Start Dir 4°1100' :9491.19' MD, BOli7.13'ND 3 5171.04 40.63 140.46 4788.31 - 587.89 993.59 4.00 113.68 1153.77 4 9491.26 40.63 140.46 8067.13 - 2757.43 2784.32 0.00 0.00 3831.55 1 5 9789.80 50.00 130.00 8277.13 - 2906.43 2934.34 4.00 -42.25 4038.23 5500- UG1_ _ 1 6 10389.80 50.00 130.00 8662.80 - 3201.88 3286.43 0.00 0.00 4494.05 1 -05AT1 revised - - - End Dir . 9789.73' MD, 8277.13' TVD 7 10651.71 105.00 130.00 8717.34 - 3360.00 3474.87 21.00 0.00 4738.00 - I 8 10952.39 90.00 130.00 8678.20 - 3551.07 3702.59 4.99 180.00 5032.80 - - 1 9 11073.53 89.76 122.74 8678.45 - 3622.86 3800.07 6.00 -91.90 5153.60 1 10 12089.30 89.76 122.74 8682.72 - 4172.14 4654.50 0.00 0.00 6169.35 '6000- WS2 - _ r 11 12583.55 89.76 102.97 8684.80 - 4363.11 5107.70 4.00 - 90.03 6654.02 01-05A T2 _ _ _ Start Dir 21'/100' : 10389.73' MD, 8662.8'T\ 12 12625.59 89.77 104.65 8684.97 - 4373.15 5148.53 4.00 89.95 6693.81 1 1 1 13 14128.46 89.77 104.65 8691.12 - 4753.16 6602.54 0.00 0.00 8123.34 o - 1 1 14 14531.86 69.76 88.51 8692.80 - 4799.23 7001.97 4.00 - 90.05 8484.60 01 -05A T3 o - WS1" 1 , 15 15009.55 89.76 88.51 8694.80 - 4786.81 7479.49 0.00 0.00 8880.11 01 -05A T4 'Z.6500- 1 t I _ CM3' " ; Start Dir 4.99 °/100' :10651.63' MD, d717.34'TJD f -8 7000- � 1 1 Start Dir 6 °1100' : 10952.31' MD, 8678.2'TVD -7000 E 1 , 1 cu CM2 - 1 / 1 End Dir : 11073.46' MD, 8678.45' TVD 1 F- � 7500 - / , , ' Start Dir 4 °/100' : 12089.22 MD, 8682.72'TVD 1-7500 COMPANY DETAILS: BP Amoco 1 1 1 ' I - End Dir : 12625.51 MD, 8684.97' TVD Calculation Method: Minimum Curvature . Start Dir 4 °/100' : 14128 MD, 8691.12'ND Error System: ISCWSA 1 / 8000 Scan Method: Tray. Cylinder North CM1 1 End Dir : 14531.79' MD, 8692.8' TVD Error Surface: Elliptical Conic - 1 • Wamin Method Rules Based - ,' 9 I THRZ - - Total Depth : 15009.55' MD, 8694.8' TVD FORMATION TOP DETAILS BHRZ -- - - - - - - - - - - ' , ,/ ' 1 . • . -- 8500 = TVDPaU MDPaIh Formation TJC- - - , - , i i _ -r_ , 4924.80 5350.88 UG3 ' 5681.80 6321.96 UG1 - � / 8181.80 8980.77 WS2 TJB , - , 01 - /01 - 05A 18.0 8407.80 7304.90 WSt / Wp 8861.80 7839.58 CM3 TJA / ' 1119000 7167.80 8308.29 CM2 TSGR 7° � ,� / 8123.80 9567.25 CM1 TSHA ` ,' 4 - 1/2" �- 8309.80 9840.63 THRZ 1 ■ 8455.80 10067.77 BHRZ - 01 - 05/01 - 05PB1 ■ 8495.80 10130.00 TJC 1 - 05A 11 revised 01 05/01 - 05 01 T2 01 - 05A T3 01 - 05A T4 850410 10144.00 TJB 8546.80 10209.34 TJA 8842.80 10358.69 TSGR - 1 - '; 1 I I r J I - 1 - r I 1 1 !- TT T I - �1 T7 T r I I Tl I I I I i I I I I I I I I I ! I I I I ! I 1 1 1 1 1 1' I I FF - TT TT 1 I f T i - I I - I 1 - -" 9500 8872.80 10405.94 TSHA 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section at 122.62° (1000 ft/in) 8694.80 15009.54 4-1/2" 4-1/2 • Halliburton Company HALLIB1. RTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference: 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.: Project Prudhoe Bay MD Rofomnce: 39.3'TC +28.5'KB @67.8' © 67.80ft (39.39 +28.: Site; PB DS 01 North Reference: True Well: 01 -05 Survey Cakulation Method: Minimum Curvature Weiibore: Plan 01 - 05A Design: 01 -05A Wp 16.0 Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 01, TR -10 -15 Site Position: Northing: 5,941,932.14 ft Latitude: 70° 14' 43.905 N From: Map Easting: 697,237.60ft Longitude: 148° 24' 24.004 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 1.50 ° Well 01 - 05, 01 -05 Well Position +NI 0.00 ft Northing: 5,940,378.70 ft Latitude: 70° 14' 28.240 N 1 +E/ - 0.00 ft Easting: 698,749.33 ft Longitude: 148° 23' 41.253 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 39.30ft Weiffiore Plan 01 - 05A [Magnetics Model Name Sample Date Declination Dip Anger Field Strength r) ( (nT) bggm2007 5/29/2007 23.89 80.90 57,658 Design 01 -05A Wp 16.0 Audit Notes: Version: 22 Phase: PLAN Tie On Depth: 4,700.00 Vertical-Section: Depth From (TVD) +NI-S +EI-W Direction (a) (ft) (ft) (*) 0.00 0.00 0.00 122.62 Plan Sections Measured Verbal TVD Dogleg Build Turn Depth inclination Azimuth Depth System +N/-S +E-W Rate Rate Rate - Toot Face (ft) r) r) oft) ft oft (ft) rrtftftft). rnoott) r/(Of) r) 1 4,700.00 44.85 111.14 4,441.19 4,373.39 - 400.97 739.78 0.00 0.00 0.00 0.00 4,721.20 45.13 114.71 4,456.19 4,388.39 - 406.81 753.58 12.00 1.31 16.87 85.00 5,171.04 40.63 140.46 4,788.31 4,720.51 - 587.89 993.59 4.00 -1.00 5.72 113.68 9,491.26 40.63 140.46 8,067.13 7,999.33 - 2,757.43 2,784.32 0.00 0.00 0.00 0.00 9,789.80 50.00 130.00 8,277.13 8,209.33 - 2,906.43 2,934.34 4.00 3.14 -3.50 -42.25 10,389.80 50.00 130.00 8,662.80 8,595.00 - 3,201.88 3,286.43 0.00 0.00 0.00 0.00 10,651.71 105.00 130.00 8,717.34 8,649.54 - 3,360.00 3,474.87 21.00 21.00 0.00 0.00 10,952.39 90.00 130.00 8,678.20 8,610.40 - 3,551.07 3,702.59 4.99 -4.99 0.00 180.00 11,073.53 89.76 122.74 8,678.45 8,610.65 - 3,622.86 3,800.07 6.00 -0.20 -6.00 -91.90 12,089.30 89.76 122.74 8,682.72 8,614.92 - 4,172.14 4,654.50 0.00 0.00 0.00 0.00 12,583.55 89.76 102.97 8,684.80 8,617.00 - 4,363.11 5,107.70 4.00 0.00 -4.00 -90.03 12,625.59 89.77 104.65 8,684.97 8,617.17 - 4,373.15 5,148.53 4.00 0.00 4.00 89.95 1 14,128.46 89.77 104.65 8,691.12 8,623.32 - 4,753.16 6,602.54 0.00 0.00 0.00 0.00 I 14,531.86 89.76 88.51 8,692.80 8,625.00 - 4,799.23 7,001.97 4.00 0.00 -4.00 -90.05 15,009.55 89.76 88.51 8,694.80 8,627.00 - 4,786.81 7,479.49 0.00 0.00 0.00 0.00 9/162008 2:18:36PM Page 2 COMPASS 2003.16 Build 428 • • Halliburton Company HALLI URTON Standard Proposal Report Database: EDM 2003.16 Single User Db local Co-ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference: 39.3'TC +28.5'KB@67.8' @ 67.80ft (39.3'TC +28.: Project Prudhoe Bay MD Reference: 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.: Site: PB DS 01 North Reference: True Well: 01 -05 Survey Caiculaton.Method: Minimum Curvature Weflbore: Plan 01 -05A Desk: 01 -05A Wp 16.0 I Planned Survey Measured Vertical Map Map Depth Inclination Azkmuth Depth TVDss +NI-S +E PA/ Northing 000 , DLS Vest Seckton (ft) (1 C) NO ft On (ft) (t) OQ ttin.39 4,700.00 44.85 111.14 4,441.19 - 4,373.39 - 400.97 739.78 5,939,997.40 699,499.39 0.00 839.24 Start Dir 121100' : 4700` MD, 4441.19'7VD : 85° RT TF 4,721.20 45.13 114.71 4,456.19 - 4,388.39 - 406.81 753.58 5,939,991.93 699,513.33 12.00 854.01 Start Dir 4 1100' : 4721.2' MD, 4456.191VD 4,800.00 43.94 118.87 4,512.37 - 4,444.57 - 431.69 802.90 5,939,968.35 699,563.29 4.00 908.96 4,900.00 42.65 124.40 4,585.18 - 4,517.38 - 467.59 861.25 5,939,934.00 699.622.57 4.00 977.47 5,000.00 41.65 130.17 4,659.35 - 4,591.55 - 508.18 914.62 5,939,894.83 699,676.98 4.00 1,044.30 5,100.00 40.94 136.14 4,734.51 - 4,666.71 - 553.26 962.73 5,939,851.04 699,726.26 4.00 1,109.12 5,171.00 40.63 140.46 4,788.28 - 4,720.48 - 587.87 993.57 5,939,817.27 699,758.00 4.00 1,153.75 1 End Dir : 5171' MD, 4788.29' TVD 5,171.04 40.63 140.46 4,788.31 - 4,720.51 - 587.89 993.59 5,939,817.25 699,758.01 4.00 1,153.77 5,200.00 40.63 140.46 4,810.29 -4,742.49 - 602.43 1,005.59 5,939,803.02 699,770.40 0.00 1,171.72 5,300.00 40.63 140.46 4,886.19 -4,818.39 - 652.65 1,047.04 5,939,753.92 699.813.15 0.00 1,233.70 5,350.88 40.63 140.46 4,924.80 - 4,857.00 - 678.20 1,068.13 5,939,728.94 699,834.91 0.00 1,265.24 UG3 5,400.00 40.63 140.46 4,962.08 -4,894.28 - 702.87 1,088.49 5,939,704.81 699,855.91 0.00 1,295.69 5,500.00 40.63 140.46 5,037.98 - 4,970.18 - 753.08 1,129.94 5,939,655.71 699,898.67 0.00 1,357.67 5,600.00 40.63 140.46 5,113.87 - 5,046.07 - 803.30 1,171.39 5,939,606.60 699,941.43 0.00 1,419.65 5,700.00 40.63 140.46 5,189.76 - 5,121.96 - 853.52 1,212.84 5,939,557.50 699,984.18 0.00 1,481.63 5,800.00 40.63 140.46 5,265.66 - 5,197.86 - 903.74 1,254.29 5,939,508.39 700,026.94 0.00 1,543.62 5,900.00 40.63 140.46 5,341.55 - 5,273.75 - 953.96 1,295.74 5,939,459.29 700,069.70 0.00 1,605.60 6,000.00 40.63 140.46 5,417.45 - 5.349.65 - 1,004.18 1,337.19 5,939,410.18 700,112.46 0.00 1,667.58 6,100.00 40.63 140.46 5,493.34 - 5,425.54 - 1.054.39 1,378.64 5,939,361.08 700,155.21 0.00 1,729.56 6,200.00 40.63 140.46 5,569.24 - 5,501.44 - 1,104.61 1.420.09 5,939,311.97 700,197.97 0.00 1,791.55 6,300.00 40.63 140.46 5,645.13 - 5,577.33 - 1,154.83 1,461.54 5,939,262.87 700,240.73 0.00 1,853.53 6,321.96 40.63 140.46 5,661.80 - 5,594.00 - 1,165.86 1,470.64 5,939,252.08 700,250.12 0.00 1,867.14 UM 6,400.00 40.63 140.46 5,721.03 - 5,653.23 - 1,205.05 1,502.99 5,939,213.76 700,283.49 0.00 1,915.51 6,500.00 40.63 140.46 5,796.92 - 5,729.12 - 1,255.27 1,544.44 5,939,164.65 700,326.24 0.00 1,977.49 6,600.00 40.63 140.46 5,872.82 - 5,805.02 - 1.305.49 1,585.89 5,939,115.55 700,369.00 0.00 2,039.48 6,700.00 40.63 140.46 5,948.71 - 5,880.91 - 1,355.70 1,627.34 5,939,066.44 700,411.76 0.00 2,101.46 6,800.00 40.63 140.46 6,024.61 - 5,956.81 - 1,405.92 1,668.79 5,939,017.34 700,454.52 0.00 2,163.44 6,900.00 40.63 140.46 6,100.50 - 6,032.70 - 1,456.14 1,710.24 5,938,968.23 700,497.27 0.00 2,225.43 6,980.77 40.63 140.46 6,161.80 - 6,094.00 - 1,496.70 1,743.72 5,938,928.57 700,531.81 0.00 2,275.49 WS2 7,000.00 40.63 140.46 6,176.39 - 6,108.59 - 1,506.36 1,751.69 5,938,919.13 700,540.03 0.00 2,287.41 7,100.00 40.63 140.46 6,252.29 - 6,184.49 - 1,556.58 1,793.14 5,938,870.02 700,582.79 0.00 2,349.39 7,200.00 40.63 140.46 6,328.18 - 6,260.38 - 1,606.80 1,834.59 5,938,820.92 700,625.55 0.00 2,411.37 7,300.00 40.63 140.46 6,404.08 - 6,336.28 - 1,657.01 1,876.04 5,938,771.81 700,668.30 0.00 2,473.36 7,304.90 40.63 140.46 6,407.80 - 6,340.00 - 1,659.48 1,878.08 5,938,769.40 700,670.40 0.00 2,476.39 WS1 7,400.00 40.63 140.46 6,479.97 - 6,412.17 - 1,707.23 1,917.49 5,938,722.71 700,711.06 0.00 2,535.34 7,500.00 40.63 140.46 6,555.87 - 6,488.07 - 1,757.45 1,958.94 5,938,673.60 700,753.82 0.00 2,597.32 7,600.00 40.63 140.46 6,631.76 - 6,563.96 - 1,807.67 2,000.39 5,938,624.50 700,796.57 0.00 2,659.30 9/16/2008 2 :18 :36PM Page 3 COMPASS 2003.16 Build 428 0 • Halliburton Company HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference: 39.3'TC +28.5'KB @67.8' © 67.80ft (39.3'TC +28.: Project: Prudhoe Bay MD Reference: 39.3'TC +28.5'KB @67.8' © 67.80ft (39.3'TC +28.: Site: PB DS 01 North Reference: True Weth 01 -05 Survey Calculation Method: Minimum Curvature Wefibore: Plan 01 - 05A Design: 01 - 05A Wp 16.0 ■ Planned Survey I Measured Map Map 1 Depth M ton Cfinat Azimuth Vertical DPP* TVDss 4441 +E1-W Northing Mina DLS Vert Section 1 (N) ( °) (°) (ft) ft (ft) (ft) (ft) MI suiscoo 7,639.58 40.63 140.46 6,661.80 - 6,594.00 - 1,827.55 2,016.80 5,938,605.06 700,813.50 0.00 2,683.83 CM3 7,700.00 40.63 140.46 6,707.66 - 6,639.86 - 1,857.89 2,041.84 5,938,575.39 700,839.33 0.00 2,721.29 7,800.00 40.63 140.46 6,783.55 - 6,715.75 - 1,908.11 2,083.29 5,938,526.28 700,882.09 0.00 2,783.27 7,900.00 40.63 140.46 6,859.45 - 6,791.65 - 1,958.33 2,124.74 5,938,477.18 700,924.85 0.00 2,845.25 8,000.00 40.63 140.46 6,935.34 - 6,867.54 - 2,008.54 2,166.19 5,938,428.07 700,967.60 0.00 2,907.23 I ' 8,100.00 40.63 140.46 7,011.24 - 6,943.44 - 2,058.76 2,207.64 5,938,378.97 701,010.36 0.00 2,969.22 8,200.00 40.63 140.46 7,087.13 - 7,019.33 - 2,108.98 2,249.10 5,938,329.86 701,053.12 0.00 3,031.20 8,300.00 40.63 140.46 7,163.03 - 7,095.23 - 2,159.20 2,290.55 5,938,280.76 701,095.88 0.00 3,093.18 8,306.29 40.63 140.46 7,167.80 - 7,100.00 - 2,162.36 2,293.15 5,938,277.67 701,098.57 0.00 3,097.08 CM2 8,400.00 40.63 140.46 7,238.92 - 7,171.12 - 2,209.42 2,332.00 5,938,231.65 701,138.63 0.00 3,155.16 8,500.00 40.63 140.46 7,314.81 - 7,247.01 - 2,259.64 2,373.45 5,938,182.55 701,181.39 0.00 3,217.15 8,600.00 40.63 140.46 7,390.71 - 7,322.91 - 2,309.85 2,414.90 5,938,133.44 701,224.15 0.00 3,279.13 8,700.00 40.63 140.46 7,466.60 - 7,398.80 - 2,360.07 2,456.35 5,938,084.34 701,266.91 0.00 3,341.11 1 8,800.00 40.63 140.46 7,542.50 - 7,474.70 - 2,410.29 2,497.80 5,938,035.23 701,309.66 0.00 3,403.09 I . 8,900.00 40.63 140.46 7,618.39 - 7,550.59 - 2,460.51 2,539.25 5,937,986.13 701,352.42 0.00 3,465.08 9,000.00 40.63 140.46 7,694.29 - 7,626.49 - 2,510.73 2,580.70 5,937,937.02 701,395.18 0.00 3,527.06 1 9,100.00 40.63 140.46 7,770.18 - 7,702.38 - 2,560.95 2,622.15 5,937,887.91 701,437.94 0.00 3,589.04 9,200.00 40.63 140.46 7,846.08 - 7,778.28 - 2,611.16 2.663.60 5,937,838.81 701,480.69 0.00 3,651.03 9,300.00 40.63 140.46 7,921.97 - 7,854.17 - 2,661.38 2,705.05 5,937,789.70 701,523.45 0.00 3,713.01 9,400.00 40.63 140.46 7,997.87 - 7,930.07 - 2,711.60 2,746.50 5,937,740.60 701,566.21 0.00 3,774.99 9,491.19 40.63 140.46 8,067.07 - 7,999.27 - 2,757.40 2,784.30 5,937,695.82 701,605.20 0.00 3,831.51 Start Dir 4 °! L 9491.19` Mti 67.A3'1VD 9,491.26 40.63 140.46 8,067.13 - 7,999.33 - 2,757.43 2,784.32 5,937,695.79 701,605.23 0.00 3,831.55 1 9,500.00 40.89 140.10 8,073.75 - 8,005.95 - 2,761.82 2,787.97 5,937,691.49 701,608.99 4.00 3,836.99 9,567.25 42.92 137.46 8,123.80 - 8,056.00 - 2,795.58 2,817.57 5,937,658.52 701,639.47 4.00 3,880.13 Mill 9,600.00 43.93 136.25 8,147.59 - 8,079.79 - 2,812.01 2,832.97 5,937,642.51 701,655.29 4.00 3,901.95 I 9,700.00 47.09 132.80 8,217.67 - 8,149.87 - 2,861.97 2,883.84 5,937,593.92 701,707.46 4.00 3,971.73 9,789.73 50.00 130.00 8,277.08 - 8,209.28 - 2,906.40 2,934.29 5,937,550.83 701,759.07 4.00 4,038.17 EndRik : 9783E,3` MD, 8277.13g YD 9,789.80 50.00 130.00 8,277.13 - 8,209.33 - 2,906.43 2,934.34 5,937,550.80 701,759.11 4.00 4,038.23 9,800.00 50.00 130.00 8,283.68 - 8,215.88 - 2,911.45 2,940.32 5,937,545.93 701,765.22 0.00 4,045.97 9,840.63 50.00 130.00 8,309.80 - 8,242.00 - 2,931.46 2,964.17 5,937,526.56 701,789.59 0.00 4,076.84 THRZ 9,900.00 50.00 130.00 8,347.96 - 8,280.16 - 2,960.70 2,999.00 5,937,498.26 701,825.18 0.00 4,121.94 10,000.00 50.00 130.00 8,412.24 - 8,344.44 - 3,009.94 3,057.69 5,937,450.59 701,885.14 0.00 4,197.91 , 10,067.77 50.00 130.00 8,455.80 - 8,388.00 - 3,043.31 3,097.45 5,937,418.28 701,925.77 0.00 4,249.40 BHRZ 10,100.00 50.00 130.00 8,476.52 - 8,408.72 - 3,059.18 3,116.37 5,937,402.91 701,945.09 0.00 4,273.88 i 10,130.00 50.00 130.00 8,495.80 - 8,428.00 - 3,073.95 3,133.97 5,937,388.61 701,963.08 0.00 4,296.67 TJC 10,144.00 50.00 130.00 8,504.80 - 8,437.00 - 3,080.84 3,142.19 5,937,381.94 701,971.47 0.00 4,307.31 TJB j 9/16/2008 2:18 :36PM Page 4 COMPASS 2003.16 Build 42B • • Halliburton Company LLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.: Project Prudhoe Bay MD Reference: 39.3TC +28.5'KB @67.8' © 67.80ft (39.3'TC +28.: Site: PB DS 01 North Reference: True Welt: 01 -05 Survey Calculation Method: Minimum Curvature Welibore: Plan 01 -05A Design: 01 -05A Wp 16.0 1 , Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVOss +NI-S +E/ W Northing gbilila DLS Vert Section Eft) el el fiat ft (ft) (ft) flit) tai SSA73,00 10,200.00 50.00 130.00 8,540.80 - 8,473.00 - 3,108.42 3,175.05 5,937,355.24 702,005.05 0.00 4,349.85 10,209.34 50.00 130.00 8,546.80 - 8,479.00 - 3,113.02 3,180.53 5,937,350.79 702,010.65 0.00 4,356.95 TJA 10,300.00 50.00 130.00 8,605.08 - 8,537.28 - 3,157.66 3,233.73 5,937,307.57 702,065.01 0.00 4,425.82 10,358.69 50.00 130.00 8,642.80 - 8,575.00 - 3,186.56 3,268.17 5,937,279.59 702,100.20 0.00 4,470.41 TSGR - 10,389.73 50.00 130.00 8,662.75 - 8,594.95 - 3,201.84 3,286.39 5,937,264.79 702,118.81 0.00 4,493.99 I Start Dir 21 °1100' : 10389.73' MD, 8662.81VD 10,389.80 50.00 130.00 8,662.80 - 8,595.00 - 3,201.88 3,286.43 5,937,264.75 702,118.85 0.00 4,494.05 1 - 05A 11 revised 10,400.00 52.14 130.00 8,669.21 - 8,601.41 - 3,206.97 3,292.51 5,937,259.82 702,125.06 21.00 4,501.91 10,405.94 53.39 130.00 8,672.80 - 8,605.00 - 3,210.01 3,296.13 5,937,256.88 702,128.76 21.00 4,506.60 TSHA 1 10,500.00 73.14 130.00 8,714.91 - 8,647.11 - 3,263.74 3,360.16 5,937,204.86 702,194.18 21.00 4,589.50 10,600.00 94.14 130.00 8,725.92 - 8,658.12 - 3,327.27 3,435.87 5,937,143.35 702,271.54 21.00 4,687.51 10,651.63 104.98 130.00 8,717.36 - 8,649.56 - 3,359.95 3,474.82 5,937,111.71 702,311.33 21.00 4,737.92 Start Dir 4.99 °1100' : 10651.63' M2DET17.341V 10,651.71 105.00 130.00 8,717.34 - 8,649.54 - 3,360.00 3,474.87 5,937,111.67 702,311.38 21.00 4,738.00 10,700.00 102.59 130.00 8,705.82 - 8,638.02 - 3,390.14 3,510.80 5,937,082.48 702,348.09 4.99 4,784.51 1 10,800.00 97.60 130.00 8,688.30 - 8,620.50 - 3,453.40 3,586.19 5,937,021.23 702,425.12 4.99 4,882.11 10,900.00 92.61 130.00 8,679.39 - 8,611.59 - 3,517.41 3,662.47 5,936,959.26 702,503.05 4.99 4,980.86 I 10,952.31 90.00 130.00 8,678.20 - 8,610.40 - 3,551.02 3,702.53 5,936,926.72 702,543.98 4.99 5,032.72 1 Start Dir 6°I100' : 10952.3 8671tirrygi 1 10,952.39 90.00 130.00 8,678.20 - 8,610.40 - 3,551.07 3,702.59 5,936,926.67 702,544.04 4.99 5,032.80 11,000.00 89.91 127.15 8,678.24 - 8,610.44 - 3,580.75 3,739.80 5,936,897.98 702,582.03 6.00 5,080.14 11,073.46 89.76 122.74 8,678.45 - 8,610.65 - 3,622.82 3,800.01 5,936,857.52 702,643.32 6.00 5,153.52 E (, �bir •Ail rhs,. • MD, 843' TVD 11,073.53 89.76 122.74 8,678.45 - 8,610.65 - 3,622.86 3,800.07 5,936,857.48 702,643.38 6.00 5,153.60 11,100.00 89.76 122.74 8,678.57 - 8,610.77 - 3,637.17 3,822.33 5,936,843.77 702,666.01 0.00 5,180.06 11,200.00 89.76 122.74 8,678.99 - 8,611.19 - 3,691.24 3,906.45 5,936,791.93 702,751.52 0.00 5,280.06 11,300.00 89.76 122.74 8,679.41 - 8,611.61 - 3,745.32 3,990.57 5,936,740.09 702,837.03 0.00 5,380.06 11,400.00 89.76 122.74 8,679.83 - 8,612.03 - 3,799.39 4,074.68 5,936,688.26 702,922.54 0.00 5,480.06 11,500.00 89.76 122.74 8,680.25 - 8,612.45 - 3,853.47 4,158.80 5,936,636.42 703,008.05 0.00 5,580.06 1 11,600.00 89.76 122.74 8,680.67 - 8,612.87 - 3,907.55 4,242.92 5,936,584.59 703,093.55 0.00 5,680.06 11,700.00 89.76 122.74 8,681.09 - 8,613.29 - 3,961.62 4,327.03 5,936,532.75 703,179.06 0.00 5,780.06 11,800.00 89.76 122,74 8,681.51 - 8,613.71 - 4,015.70 4,411.15 5,936,480.91 703,264.57 0.00 5,880.06 11,900.00 89.76 122.74 8,681.93 - 8,614.13 - 4,069.77 4,495.27 5,936,429.08 703,350.08 0.00 5,980.06 12,000.00 89.76 122.74 8,682.35 - 8,614.55 - 4,123.85 4,579.38 5,936,377.24 703,435.59 0.00 6,080.05 12,089.22 89.76 122.74 8,682.72 - 8,614.92 - 4,172.09 4,654.43 5,936,330.99 703,511.88 0.00 6,169.27 Start Dir 4 °1100' : 12089.22' MD, 8682.TTTVD 12,089.30 89.76 122.74 8,682.72 - 8,614.92 - 4,172.14 4,654.50 5,936,330.95 703,511.95 0.00 6,169.35 12,100.00 89.76 122.31 8,682.77 - 8,614.97 - 4,177.89 4,663.52 5,936,325.44 703,521.12 4.00 6,180.05 12,200.00 89.76 118.31 8,683.19 - 8,615.39 - 4,228.34 4,749.84 5,936,277.28 703,608.73 4.00 6,279.95 12,300.00 89.76 114.31 8,683.61 - 8,615.81 - 4,272.65 4,839.46 5,936,235.35 703,699.48 4.00 6,379.32 12,400.00 89.76 110.31 8,684.04 - 8,616.24 - 4,310.60 4,931.96 5,936,199.86 703,792.94 4.00 6,477.69 9/16/2008 2 :18 :36PM Page 5 COMPASS 2003.16 Build 42B • • Halliburton Company H LLI B U TD N Standard Proposal Report I I Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference: 39.37C +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.' Project: Prudhoe Bay MD Reference: 39.3'TC +28.5'KB @67.8' © 67.80ft (39.37C +28.: Site: PB DS 01 North Reference: True Welt: 01 - 05 Survey Calculation Method: Minimum Curvature Weticore: Plan 01 - 05A Design: 01 - 05A Wp 16.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Ni 4.E/ W Northing wing DLS Vert Section (ft) 41 4°) (tt) ft (ft) Oft) (ft) 4I ,,f` 16.65 12,500.00 89.76 106.31 8,684.45 - 8,616.65 - 4,342.01 5,026.88 5,936,170.97 703,888.65 4.00 6,574.56 12,583.55 89.76 102.97 8,684.80 - 8,617.00 - 4,363.11 5,107.70 5,936,152.00 703,970.00 4.00 6,654.02 01 - 05A T2 12,600.00 89.76 103.62 8,684.87 - 8,617.07 - 4,366.90 5,123.71 5,936,148.64 703,986.10 4.00 6,669.54 12,625.51 89.77 104.64 8,684.97 - 8,617.17 - 4,373.13 5,148.45 5,936,143.07 704,011.00 4.00 6,693.74 End Dir : 12625.51' MD, 8684.97' TVD i l 12,625.59 89.77 104.65 8,684.97 - 8,617.17 - 4,373.15 5,148.53 5,936,143.05 704,011.07 4.00 6,693.81 12,700.00 89.77 104.65 8,685.28 - 8,617.48 -4,391.96 5,220.52 5,936,126.14 704,083.53 0.00 6,764.59 12,800.00 89.77 104.65 8,685.69 - 8,617.89 - 4,417.25 5,317.27 5,936,103.41 704,180.91 0.00 6,859.71 12,900.00 89.77 104.65 8,686.09 - 8,618.29 - 4,442.53 5,414.02 5,936,080.69 704,278.29 0.00 6,954.83 13,000.00 89.77 104.65 8,686.50 - 8,618.70 - 4,467.82 5,510.77 5,936,057.96 704,375.66 0.00 7,049.95 13,100.00 89.77 104.65 8,686.91 - 8,619.11 -4,493.11 5,607.52 5,936,035.24 704,473.04 0.00 7,145.07 13,200.00 89.77 104.65 8,687.32 - 8,619.52 - 4,518.39 5,704.26 5,936,Q12.51 704,570.42 0.00 7,240.19 13,300.00 89.77 104.65 8,687.73 - 8,619.93 - 4,543.68 5,801.01 5,935,989.79 704,667.79 0.00 7,335.31 13,400.00 89.77 104.65 8,688.14 - 8,620.34 -4,568.96 5,897.76 5,935,967.06 704,765.17 0.00 7,430.43 13,500.00 89.77 104.65 8,688.55 - 8,620.75 - 4,594.25 5,994.51 5,935,944.34 704,862.55 0.00 7,525.55 13,600.00 89.77 104.65 8,688.96 - 8,621.16 - 4,619.54 6,091.26 5,935,921.61 704,959.93 0.00 7,620.67 13,700.00 89.77 104.65 8,689.37 - 8,621.57 - 4,644.82 6,188.01 5,935,898.89 705,057.30 0.00 7,715.79 13,800.00 89.77 104.65 8.689.78 - 8,621.98 - 4,670.11 6,284.76 5,935,876.16 705,154.68 0.00 7,810.91 13,900.00 89.77 104.65 8,690.18 - 8,622.38 - 4,695.39 6.381.51 5,935,853.43 705,252.06 0.00 7,906.03 14,000.00 89.77 104.65 8,690.59 - 8,622.79 - 4,720.68 6,478.26 5,935,830.71 705,349.43 0.00 8,001.15 1 14,100.00 89.77 104.65 8,691.00 - 8,623.20 - 4,745.97 6,575.01 5,935,807.98 705,446.81 0.00 8,096.27 14,128.38 89.77 104.65 8,691.12 - 8,623.32 - 4,753.14 6,602.47 5,935,801.53 705,474.45 0.00 8,123.27 Start Dir 4 °14128.38` MI1:1691.1PPrVQ 14,128.46 89.77 104.65 8,691.12 - 8.623.32 - 4,753.16 6,602.54 5,935,801.52 705,474.52 0.00 8,123.34 1 14,200.00 89.76 101.79 8,691.41 - 8,623.61 - 4,769.52 6,672.18 5,935,787.00 705,544.57 4.00 8,190.81 14,300.00 89.76 97.79 8,691.83 - 8,624.03 - 4,786.51 6,770.71 5,935,772.62 705,643.50 4.00 8,282.96 14,400.00 89.76 93.79 8,692.25 - 8,624.45 - 4,796.59 6,870.18 5,935,765.17 705,743.19 4.00 8,372.17 14,500.00 89.76 89.79 8,692.67 - 8,624.87 - 4,799.70 6,970.11 5,935,764.69 705,843.17 4.00 8,458.02 ' 14,531.79 89.76 88.51 8,692.80 - 8,625.00 - 4,799.23 7,001.89 5,935,766.00 705,874.93 4.00 8,484.53 Dir :141,31.79' MD, 8692TVD 14,531.86 89.76 88.51 8,692.80 - 8,625.00 - 4,799.23 7,001.97 5,935,766.00 705,875.00 4.00 8,484.60 01- 5iR 14,600.00 89.76 88.51 8,693.09 - 8,625.29 - 4,797.46 7,070.08 5,935,769.57 705,943.04 0.00 8,541.01 14,700.00 89.76 88.51 8,693.50 - 8,625.70 - 4,794.86 7,170.04 5,935,774.80 706,042.89 0.00 8,623.81 I 14,800.00 89.76 88.51 8,693.92 - 8,626.12 - 4,792.26 7,270.01 5,935,780.03 706,142.75 0.00 8,706.60 14,900.00 89.76 88.51 8,694.34 - 8,626.54 -4,789.66 7,369.97 5,935,785.27 706,242.61 0.00 8,789.40 15,000.00 89.76 88.51 8,694.76 - 8,626.96 - 4,787.06 7,469.94 5,935,790.50 706,342.46 0.00 8,872.20 15,009.54 89.76 88.51 8,694.80 - 8,627.00 -4,786.81 7,479.48 5,935,791.00 706,351.99 0.00 8,880.10 Total Depth : 15009.55' MD, 8694.8' TVD - 4 15,009.55 89.76 88.51 8,694.80 - 8,627.00 - 4,786.81 7,479.49 5,935,791.00 706,352.00 0.00 8,880.11 01 - 05A T4 9/16/2008 2 :18 :36PM Page 6 COMPASS 2003.16 Build 42B • • t� �t Halliburton Company H L L 1 B U R TO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference; 39.3'TC +28.5'KB @67.8' @ 67.80ft (39.3'TC +28.! Project: Prudhoe Bay MD Reference: 39.3'TC +28.5'KB@67.8' © 67.80ft (39.3'TC +28.! Site: PB DS 01 North Reference; True Welk 01 - 05 Survey Calculation Method: Minimum Curvature %inborn: Plan 01 -05A Design: 01 -05A Wp 16.0 Targets I Target Name j Dip Angle Dip Dir. TVD +Nl-S T-W NordiJirg Fasting ' 1 • Shape O (°) (f) (ft) tftf (ft) . Oft 11 T1 revised 0.00 0.00 8,662.80 - 3,201.88 3,286.43 5,937,264.75 702,118.85 ■ - Point 01 -05A Driller's Poly - 95% Confidence 0.00 0.00 8,694.80 - 4,687.82 7,519.33 5,935,891.00 706,389.22 - Polygon Point 1 8,694.80 - 4,687.82 7,519.33 5,935,891.00 706,389.22 Point 2 8,694.80 -4,726.28 8,116.25 5,935,868.29 706,986.91 Point 3 8,694.80 - 4,825.70 8,105.73 5,935,768.64 706,979.02 Point 4 8,694.80 - 4,925.53 8,085.80 5,935,668.32 706,961.73 1 Point 5 8,694.80 - 5,024.33 8,057.43 5,935,568.81 706,935.97 Point 6 8,694.80 - 5,046.20 7,610.10 5,935,535.16 706,489.40 Point 7 8,694.80 - 5,046.28 7,546.46 5,935,533.40 706,425.79 Point 8 8,694.80 - 5,046.37 7,482.82 5,935,531.63 706,362.18 Point 9 8,694.80 - 5,046.46 7.419.18 5,935,529.86 706,298.57 Point 10 8,694.80 - 5.046.56 7,355.54 5,935,528.09 706,234.95 Point 11 8,694.80 - 5,046.65 7,291.90 5,935,526.32 706,171.34 Point 12 8.694.80 - 5,046.74 7,228.26 5,935,524.55 706,107.73 Point 13 8,694.80 - 5,046.83 7,164.62 5,935,522.78 706,044.12 Point 14 8,694.80 - 5,046.92 7,100.98 5,935,521.02 705,980.51 Point 15 8,694.80 - 5,047.01 7,037.35 5,935,519.25 705,916.90 1 Point 16 8,694.80 - 5,047.10 6,973.71 5,935,517.48 705,853.29 Point 17 8,694.80 - 5,047.19 6,910.07 5,935,515.71 705,789.68 Point 18 8,694.80 - 5,047.28 6,846.43 5,935,513.94 705,726.07 Point 19 8,694.80 - 5,047.38 6,782.79 5,935,512.17 705,662.46 Point 20 8,694.80 - 5,047.47 6,719.16 5,935,510.40 705,598.85 Point 21 8,694.80 - 5,047.55 6,655.52 5,935,508.64 705,535.24 Point 22 8,694.80 - 5.047.64 6,591.87 5,935,506.87 705,471.62 Point 23 8,694.80 - 5,047.74 6,528.23 5,935,505.10 705,408.01 Point 24 8,694.80 - 5,047.83 6,464.59 5,935,503.33 705,344.40 Point 25 8,694.80 - 5,047.92 6,400.96 5,935,501.56 705,280.79 Point 26 8.694.80 - 5,048.01 6,337.32 5,935,499.79 705,217.18 Point 27 8,694.80 - 5,048.11 6,273.68 5,935,498.02 705,153.57 Point 28 8,694.80 - 5,048.19 6,210.04 5,935,496.26 705,089.96 1 Point 29 8,694.80 - 5,048.28 6,146.40 5,935,494.49 705,026.35 Point 30 8,694.80 - 5,048.37 6,082.77 ' 5,935,492.72 704,962.74 Point 31 8,694.80 - 5,048.00 6,019.66 5,935,491.43 704,899.65 Point 32 8,694.80 - 5,042.06 5,935.44 5,935,495.15 704,815.31 Point 33 8,694.80 - 5,030.39 5,857.35 5,935,504.75 704,736.94 1 Point 34 8,694.80 - 5,018.07 5,780.27 5,935,515.04 704,659.57 Point 35 8,694.80 - 5,005.74 5,703.21 5,935,525.33 704,582.21 Point 36 8,694.80 -4,993.42 5,626.13 5,935,535.61 704,504.84 Point 37 8,694.80 - 4,981.09 5,549.05 5,935,545.90 704,427.47 Point 38 8,694.80 - 4,968.77 5,471.99 5,935,556.19 704,350.11 . Point 39 8,694.80 - 4,956.45 5,394.91 5,935,566.47 704,272.74 Point 40 8,694.80 - 4,944.12 5,317.84 5,935,576.76 704,195.37 Point 41 8,694.80 - 4,931.81 5,240.77 5,935,587.04 704,118.01 Point42 8,694.80 - 4,919.48 5,163.69 5,935,597.33 704,040.64 Point 43 8,694.80 -4,907.15 5,086.62 5,935,607.62 703,963.27 Point44 8,694.80 - 4,894.84 5,009.55 5,935,617.90 703,885.91 Point 45 8,694.80 - 4,882.51 4,932.48 5,935,628.19 703,808.54 Point 46 8,694.80 -4,870.18 4,855.40 5,935,638.48 703,731.17 Point 47 8,694.80 - 4,857.87 4,778.33 5,935,648.76 703,653.81 Point 48 8,694.80 - 4,849.65 4,726.95 5,935,655.62 703,602.23 Point 49 8,694.80 - 4,792.44 4,378.42 5,935,703.62 703,252.33 Point 50 8,694.80 - 4,722.19 4,402.12 5,935,774.46 703,274.17 Point 51 8,694.80 - 4,652.35 4,472.75 5,935,846.14 703,342.93 9/16/2008 2 :18 :36PM Page 7 COMPASS 2003.16 Build 428 • • u Halliburton Company HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 01 - 05 Company: BP Amoco 1111) Reference: 39.3'TC +28.5'KBQ67.8' © 67.80ft (39.3'TC +28.: Project Prudhoe Bay MD Reference: 39.3'TC +28.5'KB ©67.8' © 67.80ft (39.3'TC +28.: Site: PB DS 01 North Reference; True Well: 01 - 05 Survey Calculation Method: Minimum Curvature Wellbor+s: Plan 01 - 05A Design: 01 -05A Wp 16.0 Point 52 8,694.80 -4,582.49 4,543.38 5,935,917.83 703,411.69 Point 53 8,694.80 - 4,512.64 4,614.01 5.935,989.52 703,480.45 Point 54 8,694.80 - 4,452.19 4,726.16 5,936,052.90 703,590.96 Point 55 8,694.80 - 4,543.42 5,359.33 5,935,978.40 704,226.28 Point 56 8,694.80 -4,551.28 5,413.39 5,935,971.97 704,280.53 Point 57 8,694.80 - 4,559.31 5,468.63 5,935,965.39 704,335.96 Point 58 8,694.80 - 4,567.35 5,523.88 5,935,958.81 704,391.40 Point 59 8,694,80 -4,575.39 5,579.12 5,935,952.23 704,446.83 Point 60 8,694.80 - 4,583.43 5,634.37 5,935,945.65 704,502.27 Point 61 8,694.80 - 4,591.47 5,689.61 5,935,939.07 704,557.70 Point 62 8,694.80 - 4,599.51 5,744.85 5,935,932.49 704,613.13 Point 63 8,694.80 - 4,607.55 5,800.10 5,935,925.91 704,668.57 Point 64 8,694.80 -4,615.59 5,855.34 5,935,919.33 704,724.00 Point 65 8,694.80 - 4,623.63 5,910.59 5,935,912.75 704,779.44 Point 66 8,694.80 - 4,631.67 5,965.83 5,935,906.17 704,834.87 Point 67 8,694.80 - 4,639.71 6,021.08 5,935,899.59 704,890.31 Point 68 8,694.80 - 4,647.75 6,076.33 5,935,893.01 704,945.74 Point 69 8,694.80 - 4,655.79 6,131.57 5,935,886.43 705,001.17 Point 70 8,694.80 - 4,663.83 6,186.82 5,935,879.85 705,056.61 Point 71 8,694.80 - 4,671.60 6,241.95 5,935,873.54 705,111.93 Point 72 8,694.80 - 4,677.40 6,297.29 5,935,869.20 705,167.40 Point 73 8,694.80 - 4,679.41 6,335.86 5,935,868.21 705,206.00 Point 74 8,694.80 - 4,680.22 6,398.79 5,935,869.06 705,268.93 Point 75 8,694.80 -4,680.29 6,461.84 5,935,870.65 705,331.96 Point 76 8,694.80 - 4,680.26 6,524.97 5,935,872.34 705,395.06 Point 77 8,694.80 - 4,680.23 6,588.10 5,935,874.04 705,458.16 Point 78 8,694.80 - 4,680.20 6,651.23 5,935,875.73 705,521.27 Point 79 8,694.80 - 4,680.17 6,714.36 5,935,877.43 705,584.37 Point 80 8,694.80 - 4,680.14 6,777.48 5,935,879.12 705,647.47 I Point 81 8,694.80 - 4,680.11 6,840.61 5,935,880.81 705,710.57 Point 82 8,694.80 - 4,680.08 6,903.75 5,935,882.51 705,773.68 Point 83 8,694.80 - 4,680.08 6,909.48 5,935,882.66 705,779.41 Point 84 8,694.80 - 4,680.07 6,981.27 5,935,884.56 705,851.17 Point 85 8,694.80 - 4,679.95 7,056.36 5,935,886.66 705,926.23 Point 86 8,694.80 -4,679.90 7,133.83 5,935,888.75 706,003.67 Point 87 8,694.80 - 4,679.94 7,213.71 5,935,890.82 706,083.52 Point 88 8,694.80 - 4,680.34 7,293.83 5,935,892.53 706,163.61 Point 89 8,694.80 - 4,682.07 7,365.47 5,935,892.69 706,235.27 Point 90 8,694.80 - 4,684.51 7,431.66 5,935,892.00 706,301.50 Point 91 8,694.80 - 4,686.99 7,497.41 5,935,891.25 706,367.29 Point 92 8,694.80 - 4,687.82 7,519.33 5,935,891.00 706,389.22 01 -05A T4 0.00 0.00 8,694.80 - 4,786.81 7,479.49 5,935,791.00 706,352.00 - Point 01 -05A Geo Poly 0.00 0.00 8,694.80 - 4,619.38 8,224.20 5,935,978.00 707,092.00 - Polygon Point 1 8,694.80 - 4,619.38 8,224.20 5,935,978.00 707,092.00 Point2 8,694.80 - 5,144.82 8,119.31 5,935,450.00 707,001.00 Point 3 8,694.80 - 5,148.01 5,888.32 5,935,388.00 704,771.00 Point4 8,694.80 - 4,867.68 4,135.01 5,935,622.00 703,011.00 Point 5 8,694.80 - 4,342.46 4,666.07 5,936,161.00 703,528.00 Point 6 8,694.80 - 4,586.83 6,345.30 5,935,961.00 705,213.00 Point 7 8,694.80 -4,586.36 7,351.72 5,935,988.00 706,219.00 Point 8 8,694.80 - 4,619.38 8,224.20 5,935,978.00 707,092.00 101-05A T2 0.00 0.00 8,684.80 - 4,363.11 5,107.70 5,936,152.00 703,970.00 I - - Point 01 -05A T3 0.00 0.00 8,692.80 - 4,799.23 7,001.97 5,935,766.00 705,875.00 - Point 1 9/1612008 2 :18 :36PM Page 8 COMPASS 2003.16 Build 42B • • Halliburton Company HAL LIBU TON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co- ordinate Reference: Well 01 - 05 Company: BP Amoco TVD Reference: 39.3TC +28.5'KB@67.8' © 67.80ft (39.3'TC +28.: Project Prudhoe Bay MD Reference: 39.3'TC +28.5'KB@67.8' © 67.80ft (39.3'TC +28. Site: PB DS 01 North Reference: True Weil 01 - 05 Survey Calculation Method: Minimum Curvature 1 Welibore: Plan 01 - 05A I Design: 01 - 05A Wp 16.0 Casing Points Measured Vertical Di mater 00 On Name b (1 1,211.50 1,211.47 20" 20 26 2,704.50 2,704.39 13 3/8" ' 13-3/8 17 -1/2 10,358.69 8,642.80 7" 7 8 -1/2 15,009.54 8,694.80 4 -1/2" 4 -1/2 6 -1/8 1 Formations Measured Vertical Vertical Diradflon 1 00 tit) Depth ft SS Name I N. O rl 8,306.29 7,167.80 CM2 0.00 0.00 9,840.63 8,309.80 THRZ 0.00 0.00 10,144.00 8,504.80 TJB 0.00 0.00 5,350.88 4,924.80 UG3 0.00 0.00 I 10,209.34 8,546.80 TJA 0.00 0.00 10,130.00 8,495.80 TJC 0.00 0.00 9,567.25 8,123.80 CM1 0.00 0.00 10,358.69 8,642.80 TSGR 0.00 0.00 I 10,405.94 8,672.80 TSHA 0.00 0.00 7,639.58 6,661.80 CM3 0.00 0.00 6,321.96 5,661.80 UG1 0.00 0.00 6,980.77 6,161.80 WS2 0.00 0.00 7,304.90 6,407.80 WS1 0.00 0.00 10,067.77 8,455.80 BHRZ 0.00 0.00 I Plan Annotations Waled vettliiti vocal deltdinates t tee Depth +Nttn +W W an itt) Eft) Pt} Comment 4,700.00 4,441.19 - 400.97 739.78 Start Dir 12° /100' : 4700' MD, 4441.19'TVD : 85° RT TF 4,721.20 4,456.19 - 406.81 753.58 Start Dir 4 °/100' : 4721.2' MD, 4456.19'TVD 5,171.00 4,788.28 - 587.87 993.57 End Dir : 5171' MD, 4788.29' TVD 1 9,491.19 8,067.07 - 2,757.40 2,784.30 Start Dir 4°/100' 00 ' : 9491.19' MD, 8067.13'TVD 9,789.73 8,277.08 - 2,906.40 2,934.29 End Dir : 9789.73' MD, 8277.13' ND 10,389.73 8,662.75 - 3,201.84 3,286.39 Start Dir 21 °/100' : 10389.73' MD, 8662.8'TVD 10,651.63 8,717.36 - 3,359.95 3,474.82 Start Dir 4.99 °/100' : 10651.63' MD, 8717.34'TVD 10,952.31 8,678.20 - 3,551.02 3,702.53 Start Dir 6 °/100' : 10952.31' MD, 8678.2'TVD 11,073.46 8,678.45 - 3,622.82 3,800.01 End Dir : 11073.46' MD, 8678.45' TVD 12,089.22 8,682.72 - 4,172.09 4,654.43 Start Dir 4 °/100' : 12089.22' MD, 8682.72TVD 12,625.51 8,684.97 - 4,373.13 5,148.45 End Dir : 12625.51' MD, 8684.97' ND 14,128.38 8,691.12 - 4,753.14 6,602.47 Start Dir 4 °/100' : 14128.38' MD, 8691.12'ND 14,531.79 8,692.80 -4,799.23 7,001.89 End Dir : 14531.79' MD, 8692.8' ND I 15,009.54 8,694.80 - 4,786.81 7,479.48 Total Depth : 15009.55' MD, 8694.8' ND I 9/16/2008 2:18:36PM Page 9 COMPASS 2003.16 Build 42B REFERENCE INFORMATION ANTI - COLLISION SETTINGS SURVEY PROGRAM Co-ordinate (WE) Reference: Well Centre 01 -05, True North Vertical(TVD) Reference'. 39.37C.28.5'8B@67.8'67.80 Interpolation MethodMD Interval: 25.00 Section (VS) Reference: Slot- (0. 39.3'1 I Depth Fm Depth To Survey/Plan Tool Measured Depth Reference' 628.5758807.8' 67.80 Depth Range From: 4700.00 'fn: 15009.48 Calculation Method: Minimum Curvature Max int tint Range: 1698.10 Reference: Plan: 01 -05A Wp 16.0 4700.00 15009.48 Planned: 01 -05A Wp 16.0 V23 MWD 4AMND 01-01 -04 Mpw 171,11 - :n VIZ)), From Colour To MD - 01 -05 (Ol -030 Mew RiA - 0I- 02A(01 -02 a, Major RI, 0 4700 01-04 - -0 M9gw.k 4700 • 4800 WELI,PA7H DETAILS 0I -05(01- u51, NOeRRORS 4 800 4900 Plan 01-05A 01- 0 Ma NOERROHS a1 - (01-0 6), A,, MM. 500292007601 4900 • 5000 01 -07101 -07),MewFla* - � � 01- 07(01.0 „ ; «w1.M.+ 5000 5100 Pa,entwcu of -osPRt 01 -07 (01-07.V01). elaHn Rak 1 01 -0e ( •MVw' •,..‘ •,..‘ r5100 5200 Tie on MD: 4700.00 'w" VI- 06(01 -0601. M Na - 01-09 (01-0 M M 10h �- 01 -090(01 -09.1 M„w w.6 0 5200 5300 Rig: Nabobs 7ES - 12500 011(01- 10• Ruh I1x(1 Mpw Ruh .� 500 • 5400 Ref Datum: 39.3TC +285'KBz67.8' 67.808 - 26( 1 x6 11611a,jw of z ( /Ma r i '^ ► 5400 5500 1 1 M,lw 11. k '� 5500 5750 V + N / -S 0.118116 Fr 246( Mew •.6.‘ { t ` A- Angle +N / -S +F/ -W Fmm'1'VD I _4511 1611 0,29 WI-2M Ma, Ittsk 2 (01-10,. .M,' lb. ,.,;- R 0 5750 60()0 - 01-20 fl 01-30.1 Map/1MA + e , r�� _' 6 ''' , + , • * 6000 62511 122.62° 0.00 0.00 28 ' 01 -21 ( wW ',Al. rj; . �„. �. i From Colour To MD 01-21(01-M), Ml 'wa a�,' � �* ���� 6250 6500 x111 was .I, nl.iw 124,1 \ a ° �1 ?.6, /� Win► 750 4700 • 4800 w.m. UI lalfl 0 360) M.iw'Rw � • ' ` A.. ,,,--, . - . - - _ ( p�� p�ccppp .».... 1 ( 1 .. 1200 w V I "wy •.� "°� -w �i �� 1 All @Y.�a6.YJ• 1 (2-1.)Mum -- . 1 (02-1Y/, Ma, wr 240 .v '� ' Uiem r ✓.+/% X1 / ��� ` ' 000 4800 • 4900 • --- 0124 ( z Mb 1,200 �,- : 1 1 1 - / 000 7250 5 ( 0 4900 • 5000 ^.-..' 224( 24 )M,w1 =aaz RY^-*'"Att.�'7`�,,,, � i �� 'Ij -- - .1" . ...000 0 7, - ..0.„, •• •• I"�I.I� �5; .,.,. -s� rte' 5000 • 5100 ■ 132( 2B nF .tea' ?<�.., \ 1,0 t 0x1 • Mow 1200 �,,'. i-' ' ".a .ii�� � • SO 750 5100 5200 12-23 oz ) , N RI, � rw;/� _ � r � � i 7600 331 _ p ^- 12-211A (lanMajor %A z.,., ...•. - . j 7 •aa 7 ' I..rn - r .666.,1 5200 5300 fln01 -use t ."` ' ° I��'>3.,'.. a^; ' "'�"'r'^-air= r /......--16•••%60.%)//,_. -- - : 7700 - 5300 • 5400 01 -05A sup 16 0 � 3 �. _ - • 71 1 7800 5400 5500 ����� Well 0! -26 ' • 1 1 • 7900 T. 00 • 5750 20.0 Range: 76• t MD to 7800' MD 7t 11 800(1 -, / 10.0 la4_ . .0 • 6000 - -� l '/ 6tf: • 6250 -15.0 t •.� . ! 1 8250 3t t 6254 ,D 6500 �� ����� �� ��� 82 ( 8500 650011 6750 ':5 I 8750 -, 6750 7000 -to.0 '' 411 ' 7 ` /l�R 181 SI 9000 s o s p 7000 7250 -5.0 ■ � YIiA 111 92511 4 � /, 7700 ..' 7250 7500 I ` 7500 7600 r 50 9500 7 600 0 271 " I . _i 9750 OAS r , 7700 7800 • ' ; 7800 7900 -5.0 roA • ,'7� ( 'I [ I ���✓� _ ] 1 1 I 1 I 10500 -0 270 , - :: 8010 8250 111 i 8000 - 10.0 v 1111 ' ' `J�/ell I - I I , 11 _ ! 1 110 622-0 8500 Range: 90 00' MD to 100 My 1 11 500 • 888°52:5 500 8750 - ls.o � I 1 0 1200 Well 01 -11 r. 8750 9000 ( rikt » I 1 1 ! 13 2-. /Range. 9000' MD to 10000" MD 9250 92-00 i t - 20.0 1 c 1 1 1 141H10 9500 ,' 50 - 25 -o �� i 101 11000 1 1 1 15000 zao l oo 1614".... L1614".... 9711°0000 241 f _ 1 20 .3 -30.0 � � � ` ° 0 ° _ 10 0 1' '10 11500 500 • 12000 - 35.0 - • - 12000 , 1 .111 k,4,4, 40.0 I °'""°°'�°""" el 12500 • 13000 - 211 � t - 50 13000 15000 14000 - 14000 55 pp 1.. - 45.0 0,411 i -i �Sb 181 f., 150 -50.0 21 \ ` i '•6 =5819 18 Travelling Cylinder Azimuth (TFO +AZI) [deg] vs Centre to Centre Separation [lOftlin] SECTION DETAILS WELL DETAILS Sec MD Inc Azi TVD +N /-S +E / -W DLeg TFace VS. Target Name +N / - +H / - Northing Easting Latitude Longitude Slot 1 471000 44.85 III14 444119 -40114 73976 000 000 83932 g 8 8 2 4721 20 45 13 114 71 4456 19 - 406.97 753 56 12.00 85.00 854 08 3 517101 40 63 140 46 4788.29 -58803 993.55 400 113 68 1153 82 COMPANY DEI'AII 01 - - 1592.56 1470.64 5940378.70 698749.33 70 ° 14'28.240N 148 °23'41.253W N/A 4 949119 40.63 14046 806713 - 275744 2784.32 000 0.00 383156 5 9789 73 5000 130 W 8177.13 - 290.44 2934.33 400 -42 24 4038 23 RF Amoco 6 1038973 5000 130.00 866280 - 320188 3286.43 000 000 449405 1 -05A T1 revised 7 10651.63 105 0 130.00 8717.34 - 3360.00 3474 87 2100 0 00 4738.00 Calculation Method: Minimum Curvature 8 10952.32 90.00 13000 8678.20 - 3551.08 3702 58 4 99 180.00 5032 80 Error S \00m: ISCWSA 9 11073 46 89 76 122.74 8678.45 - 3622 86 38170.06 6 00 -91 90 5153 60 Scan Method. Tray Cylinder North 10 12089.22 89 76 122 74 8682 72 - 4172 15 4654 49 0 00 0 00 6169. Error Surface. EIIlptical +Casmg Travelling Cylinder Azimuth (TFO+AZI) [ deg] vs Centre to Centre Separation 125ft/in] 11 12583 47 89 76 102 97 8684 80 -4363.13 5107 70 4.00 -9003 6654 02 01.05A T2 Warning Method' Rules Based 12 12625 52 89 77 104.65 8684.97 - 4373.16 5148.53 4 00 89 95 6693 82 13 14128.38 8977 104.65 8691.12 - 4753.18 6602.54 000 000 8123.34 14 14531.79 89.76 88.51 8692 SO - 4799 24 7001 96 4 00 -90.05 8404 01.05A T3 15 15009 48 89 76 38 51 8694.80 -4786 83 7479 48 0 00 0 00 8880 11 01-05A T4 • II Halliburton Company Anticollision Report Company: BP Amoco Date: 9/16/2008 Time: 12:17:57 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 01 Co- ordinate(NE) Reference: Well: 01 -05, True North Reference Well: 01 -05 Vertical (TVD) Reference: 39.37C +28.5'KB@67.8' 67.8 Reference Wellpath: Plan 01 -05A Db: Oracle GLOBAL SCAN APPLIED: All welipaths within 200'+ 100 /1000 of reference - There are 1 N 1 IleYells in thisF1tiMipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse ' Depth Range: 4700.00 to 15009.48 ft Scan Method: Tray Cylinder North Maximum Radius: 1698.10 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/16/2008 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ft if 95.50 4700.00 1 : Camera based mag multi sho CB- MAG -MS Camera based mag multi shot 4700.00 15009.48 Planned: 01 -05A Wp 16.0 V22 MWD +IFR +MS MWD + IFR + Multi Station 1 Casing Points i MD TVD Diameter Hole Size Name ft ft in in 1212.70 1212.67 20.000 26.000 20" 2705.70 2705.59 13.375 17.500 13 3/8" 4700.70 4441.69 9.625 12.250 9 5/8" 10358.61 8642.80 7.000 8.500 7" ' 15009.47 8694.80 4.500 6.125 4-1/2" Summary <--------- --- - -- Offset Wellpath --------------> Reference Offset Ctr -Ctr No -Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft if ft 01-05,Plan 01 -05A,01 -0 15002.92 15000.00 0.00 298.04 - 298.04 FAIL: Major Risk PB DS 01 01 -01 01 -01 V2 4708.48 4950.00 717.25 161.99 555.25 Pass: Major Risk PB DS 01 01 -02 01 -02 V2 Out of range i PB DS 01 01 -03 01 -03 V2 Out of range P8 DS 01 01 -03A 01 -03A V1 Out of range PB DS 01 01 -04 01 -04 V2 4703.12 5575.00 1595.40 101.60 1493.80 Pass: Major Risk PB DS 01 01 -04 01 -04A V7 4703.12 5575.00 1595.40 101.60 1493.80 Pass: Major Risk PB DS 01 01 -05 01 -05 V3 4769.65 4775.00 3.28 200.57 - 197.29 FAIL: Major Risk PB DS 01 01 -05 01 -05PB1 V2 4769.65 4775.00 3.28 200.69 - 197.41 FAIL: Major Risk PB DS 01 01 -05 Plan Cont 01 -05A V7 PI 7699.30 4700.00 0.00 277.01 - 277.01 FAIL: Major Risk ' PB DS 01 01 -06 01 -06 V1 4700.00 5075.00 918.22 176.03 742.19 Pass: Major Risk PB DS 01 01 -06A 01 -06A V1 4700.00 5075.00 918.22 176.14 742.08 Pass: Major Risk PB DS 01 01 -07 01 -07 V5 Out of range PB DS 01 01 -07 01 -07A V1 Out of range PB DS 01 01 -07 01- 07APB1 1/1 Out of range PB DS 01 01 -08 01 -08 V5 4712.88 4575.00 255.20 131.90 123.30 Pass: Major Risk PB DS 01 01 -08 01 -08A V3 Out of range PB DS 01 01 -09 01 -09 V2 4863.77 4600.00 352.95 146.08 206.87 Pass: Major Risk PB DS 01 01 -09A 01 -09A V1 4863.77 4600.00 352.95 146.08 206.87 Pass: Major Risk PB DS 01 01 -11 01 -11 V2 9524.00 9650.00 795.66 698.17 97.49 Pass: Major Risk PB DS 01 01 -12 01 -12 V3 5005.69 5500.00 480.55 232.96 247.59 Pass: Major Risk PB DS 01 01 -12 01 -12A V3 5005.69 5500.00 480.55 232.96 247.59 Pass: Major Risk PB DS 01 01 -26 01 -26 V1 7348.72 7825.00 559.38 512.46 46.92 Pass: Major Risk PB DS 01 01 -26 01 -26A V2 7353.96 7825.00 561.05 514.14 46.91 Pass: Major Risk P8 DS 01 01 -28 01 -28 V1 4711.23 4650.00 377.95 179.73 198.22 Pass: Major Risk P8 DS 01 01 -29 01 -29 V7 4732.77 5025.00 869.29 96.10 773.19 Pass: Major Risk PB DS 01 01 -30 01 -30 VI 5191.50 5300.00 1560.79 156.55 1404.23 Pass: Major Risk PB DS 01 01 -30 Plan 01 -30a V3 Plan: 0 5198.58 5300.00 1567.00 156.93 1410.07 Pass: Major Risk PB DS 01 01 -31 01 -31 V1 4717.38 4750.00 551.85 127.40 424.45 Pass: Major Risk PB DS 01 01 -34 01 -34 V1 4753.87 4825.00 798.17 119.78 678.39 Pass: Major Risk PB DS 01 01 -34 01 -34A Rig Surveys VO 4757.90 4825.00 799.13 119.70 679.43 Pass: Major Risk PB DS 01 01 -34 Plan 01 -34A VO Plan: 0 4757.90 4825.00 799.13 119.76 679.37 Pass: Major Risk P8 DS 03 03 -16 03 -16 V3 15006.68 12275.00 444.62 0.00 444.62 Pass: Minor 1/200 PB DS 03 03 -16 03 -16A V2 15006.69 12275.00 444.64 0.00 444.64 Pass: Minor 1/200 PB DS 03 03 -19 03 -19 V1 Out of range PB DS 03 03 -24 03 -24 V1 12716.65 12875.00 345.21 0.00 345.21 Pass: Minor 1/200 1 ' PB DS 03 03 -24A 03 -24A V1 12567.53 13200.00 206.75 0.00 206.75 Pass: Minor 1/200 PB DS 12 12 -02 12 -02 V8 13486.07 12825.00 1220.32 72.16 1148.16 Pass: Minor 1/200 PB DS 12 12 -28 12 -28 V1 11545.27 12075.00 853.35 559.80 293.56 Pass: Major Risk PB DS 12 12 -28A 12 -28A V2 11209.64 12000.00 789.67 331.40 458.27 Pass: Major Risk • • Halliburton Company Anticollision Report Company: BP Amoco Date: 9/16/2008 Time: 12:17:57 Page: 2 j Field: Prudhoe Bay Reference Site: PB DS 01 Co- ordinate(NE) Reference: Well: 01-05, True North Reference Well: 01-05 Vertical (TVD) Reference: 39.37C +28.5'KB@67.8' 67.8 J ' Reference Wellpath: Plan 01-05A Db: Oracle Summary ■ <---------- --- - -- Offset Wellpath -------- ---- -> Reference Offset Ctr -Ctr No -Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 12 12 -32 12 -32 V3 14447.15 12975.00 684.60 376.92 307.68 Pass: Major Risk ! Site: Well: Rule Assigned: Major Risk Wellpath: 01- 05,PIan 01- 05A,01 -05A Wp 15.0 Inter -Site Error: 0.00 ft • Reference Offset Semi -Major Axis Ctr -Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CaslngtHatistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 4749.89 4476.51 4750.00 4477.20 27.31 1.20 220 104 8.500 4.06 117.91 - 113.85 FAIL 4774.95 4494.39 4775.00 4495.28 27.34 1.38 223 105 8.500 4.92 118.07 - 113.15 FAIL 4800.03 4512.39 4800.00 4513.46 27.37 1.59 224 105 8.500 5.78 118.41 - 112.63 FAIL 4825.12 4530.52 4825.00 4531.73 27.38 1.81 226 105 8.500 6.65 118.79 - 112.14 FAIL I 4850.23 4548.75 4850.00 4550.10 27.39 2.04 227 105 8.500 7.51 119.26 - 111.75 FAIL 4875.35 4567.10 4875.00 4568.54 27.39 2.28 228 105 8.500 8.37 119.80 - 111.43 FAIL 4900.49 4585.55 4900.00 4587.06 27.40 2.53 228 104 8.500 9.24 120.40 - 111.16 FAIL , 4925.65 4604.09 4925.00 4605.66 27.38 2.77 229 103 8.500 10.09 120.93 - 110.84 FAIL 4950.82 4622.73 4950.00 4624.32 27.36 3.02 230 103 8.500 10.95 121.50 - 110.55 FAIL i 4976.00 4641.45 4975.00 4643.04 27.34 3.28 230 102 8.500 11.81 122.14 - 110.34 FAIL 1 5001.21 4660.25 5000.00 4661.82 27.32 3.53 231 101 8.500 12.66 122.80 - 110.14 FAIL 5026.42 4679.13 5025.00 4680.65 27.28 3.78 232 100 8.500 13.50 123.38 - 109.87 FAIL 5051.65 4698.07 5050.00 4699.52 27.23 4.03 232 99 8.500 14.35 123.96 - 109.62 FAIL , 5076.90 4717.08 5075.00 4718.42 27.19 4.29 232 98 8.500 15.19 124.56 - 109.38 FAIL 5102.16 4736.15 5100.00 4737.36 27.14 4.54 233 97 8.500 16.02 125.16 - 109.14 FAIL 5127.44 4755.26 5125.00 4756.33 27.07 4.78 233 96 8.500 16.82 125.69 - 108.87 FAIL 5152.73 4774.43 5150.00 4775.30 27.00 5.03 234 94 8.500 17.26 126.24 - 108.98 FAIL 5177.95 4793.56 5175.00 4794.26 26.96 5.27 234 94 8.500 17.28 126.89 - 109.61 FAIL 5202.95 4812.54 5200.00 4813.23 26.98 5.53 234 94 8.500 17.18 127.73 - 110.55 FAIL 5227.95 4831.51 5225.00 4832.20 27.01 5.78 234 94 8.500 17.08 128.58 - 111.50 FAIL , 5252.95 4850.48 5250.00 4851.17 27.04 6.03 234 94 8.500 16.98 129.43 - 112.45 FAIL 5277.95 4869.46 5275.00 4870.14 27.06 6.29 234 94 8.500 16.88 130.28 - 113.39 FAIL 5302.95 4888.43 5300.00 4889.11 27.09 6.54 234 94 8.500 16.79 131.13 - 114.34 FAIL 5327.95 4907.41 5325.00 4908.08 27.12 6.79 234 94 8.500 16.69 131.98 - 115.30 FAIL 5352.95 4926.38 5350.00 4927.05 27.14 7.05 234 94 8.500 16.59 132.84 - 116.25 FAIL 5377.95 4945.35 5375.00 4946.01 27.17 7.30 234 94 8.500 16.49 133.70 - 117.20 FAIL 5402.95 4964.33 5400.00 4964.98 27.20 7.56 234 94 8.500 16.39 134.55 - 118.16 FAIL 5427.95 4983.30 5425.00 4983.95 27.23 7.81 234 94 8.500 16.29 135.42 - 119.12 FAIL 5452.95 5002.28 5450.00 5002.92 27.26 8.07 234 94 8.500 16.20 136.28 - 120.08 FAIL 5477.95 5021.25 5475.00 5021.89 27.29 8.32 234 94 8.500 16.10 137.14 - 121.04 FAIL 5502.95 5040.22 5500.00 5040.86 27.32 8.58 234 93 8.500 16.00 138.01 - 122.01 FAIL 5527.95 5059.20 5525.00 5059.83 27.35 8.83 234 93 8.500 15.90 138.88 - 122.98 FAIL 5552.95 5078.17 5550.00 5078.80 27.39 9.09 234 93 8.500 15.80 139.75 - 123.94 FAIL 5577.95 5097.14 5575.00 5097.76 27.42 9.34 234 93 8.500 15.70 140.62 - 124.91 FAIL 5602.95 5116.12 5600.00 5116.73 27.45 9.60 234 93 8.500 15.60 141.49 - 125.88 FAIL 1 5627.95 5135.09 5625.00 5135.70 27.48 9.85 234 93 8.500 15.51 142.36 - 126.86 FAIL 5652.95 5154.07 5650.00 5154.67 27.52 10.11 234 93 8.500 15.41 143.24 - 127.83 FAIL 5677.95 5173.04 5675.00 5173.64 27.55 10.37 234 93 8.500 15.31 144.12 - 128.81 FAIL 5702.95 5192.01 5700.00 5192.61 27.59 10.62 234 93 8.500 15.21 145.00 - 129.79 FAIL 5727.95 5210.99 5725.00 5211.58 27.62 10.88 234 93 8.500 15.11 145.88 - 130.77 FAIL 5752.95 5229.96 5750.00 5230.55 27.66 11.13 234 93 8.500 15.01 146.76 - 131.75 FAIL 5777.95 5248.93 5775.00 5249.51 27.69 11.39 234 93 8.500 14.92 147.65 - 132.73 FAIL 5802.95 5267.91 5800.00 5268.48 27.73 11.65 234 93 8.500 14.82 148.53 - 133.72 FAIL 5827.95 5286.88 5825.00 5287.45 27.77 11.90 234 93 8.500 14.72 149.42 - 134.71 FAIL • Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, October 14, 2008 9:30 AM To: 'Nadem, Mehrdad' Subject: RE: 1 -05B Wp 9 VS wp 16 Mehrdad, It is probably best to send updates for pages 2 (casing details) and 3 (cementing details) and the new directional plan. Are there any changes in the anti - collision? You can send these via email and I will put them in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM @BP.com] Sent: Monday, October 13, 2008 3:02 PM To: Maunder, Thomas E (DOA) Subject: FW: 1-05B Wp 9 VS wp 16 Tom, Attached plot shows the two different plans for 01 -05B, We plan to execute 01 -05B Wp16. WP16 replaced P9. Regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564 -5941 Cell: 907/440 -0213 Email: nademm @bp.com From: Goff, Bart A Sent: Monday, October 13, 2008 2:55 PM To: Nadem, Mehrdad Subject: 1 -05B Wp 9 VS wp 16 Mehrdad here are the two views that you requested. Please let me know if you require any thing further. Bart Goff Well planning Cell 240 -1324 Sperry Office 273 -3563 BP Office 564 -5045 goffba @bp.com bart.goff @halliburton.com 10/14/2008 1 -05B Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 24, 2008 8:06 AM To: 'Nadem, Mehrdad' Subject: RE: 1 -05B (207 -048) Mehrdad, There is no issue optimizing the mud /pressure plan for the well. I will place a copy of this message in the file. Good luck on the well. Tom Maunder, PE AOGCC From: Nadem, Mehrdad [mailto:NademM©BP.com] Sent: Wednesday, September 24, 2008 7:50 AM To: Maunder, Thomas E (DOA) Subject: 1 - 05B Tom, We plan to spud 01 -05B in a next two to three weeks. I have made a few changes to the program as follows: The mud program has slightly changed. The mud weight in the intermediate will range from 9.4 -11.3 ppg. The existing plan is perform a LOT in the intermediate section. The permit to drill lists FIT of 11.8 ppg EMW. FIT in the production section will be 9.7 ppg EMW rather than 10.0 ppg EMW. I will implement these changes if approved by AOGCC. I am available to provide additional information at your request. Alternatively, I am available to discuss over the phone. Regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564 - 5941 Cell: 907/440 -0213 Email: nademm @bp.com 9/24/2008 1,-. v i v_ v nLI4uc�i nn u■r 111CJJUIC iaiILC t Subject: Re: 01 -05B Request for BOP pressure test variance From: James Regg <jim regg @admin.state.ak.us> a©) — C3 R c Date: Fri, 11 May 2007 13:14:48 -0800 To: "Hobbs, Greg S (ANC)" <Greg.Hobbs @bp.com> CC: Thomas E Maunder < tom_maunder @admin.state.ak.us >, "Nigh, Jim" <Jim.Nigh @BP.com> Thank you for the information; your request to reduce the BOPE test pressure from 3500 psi to 2000 psi is approved. Jim Regg AOGCC Hobbs, Greg S (ANC) wrote: Jim, Also. the abandonment plug across the perforations of the wel1 tested to 3.500 psi prior to the rig moving on the well. Thank you for the consideration. Greg Hobbs From: Nigh, Jim Sent: Friday, May 11, 2007 11:21 AM To: jim regq ©admin.state.ak.us Cc: Thomas E Maunder; Hobbs, Greg S (ANC) Subject: 01 -05B Request for BOP pressure test variance Importance: High Jim, Per our phone conversation, I have attached the current well configuration schematic and picture of the tubing hanger threads. The MAASP on this well is, in essence, 0 with the P&A. Basically we are just using the BOP stack as a conduit to pull the cut tubing. Post P&A the well tested to 3500psi. Tom called us back, immediately after we got off the phone with you. He agreed with our plan forward to reduce the BOP test to 2000psi, but implied that the decision still ultimately remained up to you. Please email or call me on my cell as soon as you have made your decision. Apologize for the short fuse. Thank you for your help. -Jim 1 of 2 5/14/2007 7:44 AM o1 -off pre -rig status.nmp I13 .v1r Image, b .)lx /`Ib pixels) mailbox: t' email tauit ,N1all'ancmalll.state.ak.us (nbox''numbeJ .. III ' . TREE- y IKEVOY 01 05 T1 UU LH L3E34D I.GE4'Ov � S,4FETYNOTES: TROUBLE' ;WELL- RAPIDW. ;g, Op, ACTUATOR OTS COM M: LEAKS ON AIL, OA X OOP COM M.,20" KB.ELEV - 7TO' SURFCSO RILURE,GAS LEA Kg 20 HGR BF. ELEJ - N4 CLAMP 08I ;36.x13- CRTBG3LNR k0P- 3139' Lt7:! A I g 2 - . ¢ M35' Dadra MD- 11643 \ 22 I - 1 7' XS- 1,211GRXO, ID- 4.892 I D3dm TVD - 531317 SS 956' FOC I-I 11'. ' 1 — -- ' 1=3C113 - TOC from down squeeze Iff a; r, 94P, H D - 19.12e I — 1216' I k : -,I 1 1S3' H 13-3 6- CP I 956' FOC —I 2181' I--- 27IIT' - 5 - 1/7 CA1.IC0 BAL-0 SVN, O -4562' I 1 956' CP 1— 22?3' I 1>P .4 GAS LIFT MANDRELS 13 -3.6' ■CS3, 720 N-.30, ID- 12.317' HI 27128 I '°,, ST MD ND 0EV TYPE VLV LATCH PORT DATE 1 3267 3261 14 FLIHO RK ?w 2 5501 6263 17 FUHO RK Minimum ID = 3.725" @ 9753' 4. 3 7425 UT 513 FLIHO RK 4 -1.2' PARKER SWN NIPPLE 1 a7 17 7090 52 FLIHO RK 0 9077 7303 45 FUHO RK 6 9451 7515 52 FLIHO RK Pre - rig tubing out - 5,1217 7 9610 6614 51 FLIHO RK I 5 - V T TBG, 1104, 13-CR, Fox, 0Z3'' L p Y . ID- 4 2 ) , I 364 5 -117 0T6 X NP, ID- 1.562 9 — 9-5 X5- 112'TLNHBBPPKR,U :9: - 4.71' _ . ' I 9715 I— 5- 1l7 17 x4- 1X0,D -39 ' BAKER C- 2TEBACKSLV,17- 7.500' H 9737 I - 9?'29 JmI- 1 1f2 PXN PLIX; GET N IINNIP 0NOiA4.95 I 9-5,6 X7 BM LNRICR,ID- 6.250' I-1 97:0'3 I � ` I 7 1 97 }'3' I- — P NP, ID- 3513 1 I 9- 5k3'X7' BAKER HPKR,D -6 2`0' H 9745' I Dr i I I 97,' H l 4 -U7 PARKERSUIN NP, ID -3.725 I 4- 1.27BG, 12640, O-CR,.0152tpl, ID- 3368' — 97E4 I I t 373 - 4 IA LEG, ID -3_a3 I 1356'C,45P OAS, 5.681' H '100010 I— I 9746' H ELMD TT LOGO ED 1.0. I � 956 CS W W ' G LILLOUT "%y s - tram 0717 '- 10 @ECTDN 11.111) TO from PEA- 10,408' r � gol ; A ,, °� y, I 107354' H 7- UARK i1) a mz ,!.*,,,,,";=, E f, a ri „ * ;, a �. _ 1'133 H PBTD 81.RIBPONBTIL- 03.11.93 r LNR, 295, 13 -CR, .¢371 bpi, D -6.134' H 11443' I DATE REV BY COMUEN1S DATE REV BY QOLILIENIS PRUDHOE BAY UNIT 10M3,71 ORIGINAL COMPLETION 113.1:14M ftP PERF INTERVAL CORRECTIO WELL: 0 1-06ST1 0311F,92 RIG SIDETRACK (01-05STI1 03.22+134 TLP FIX CA INAS PIiDBLEM PERLJFTNo:1714130 07.13453 GET PXN PLUG 09723 11l?9u04 OFFITLP at AND 956CSG API No: 60029-23076-01 02 TP CORRECTIONS D5r11.17i JN 01 -05B PRE-RG CONFI3 SEC 3, TION, R15E, 517' FNL Al 11217 FOUL 044133E2 CIiITP OOR RECTO NS 06434.e2 VIIKAK PERFCORRS2TDN EP Etplor9 ion (JJ a Om) 1 of 1 5/14/2007 7:44 AM • I 0 \ . --.0 C --, '.... at e* b c--, P — 0 ... , a . .., ... ------- .,..4 ...-.... ... ' -7„,.,-.4 -...,,,,...... . -. .....4.„,, ,,, . .:, . ,-„r. , ','. . '''-',.' , ,,,,,,, ....:, ••,„,Z,""«, - .4 7. .....74 . 0.t. „OC:,„; - , ' . . '4: " ' -,,, . . . ,.. , ', • .....i.e0. .0414 - ,,,*_„,,, ": 4,,, 11 440, •- . ' . .- „,,, I. 00 ,,,,,%. ' '''' Aper, 407 `,.. , 74...„,„,•41..,„ ''`, - de#:•pr,,,00i„,,,,,,..'''-..„,, .. 4. .0.0*.....- ......,,...,11 jr.. ' 44 .4, 4 4,..... ..„., . •-• : , ,,,,..",„ , 4 4 . %" 4 4" , ..,,......... , . * N7' , ... - . .- "..,, . •• '' -..- - AP:" A sir5, ••••••'` . . ..,, . - - • ' . ' ''''''':" ' - ' ...,''. . '''' -'• - . , , '', di ' ' '''' . ..k. \ - -.07"'; - • "-"" /1°°°.... ' ' .. •- • , .----"- . . , . .. ..... , - . . . N , . . . „e" . • , •.--. ,.. /0 -- .' ,. . / . , '.. , '..• . .. ' IP' • ' ''' " -",, ! ''‘' ' . • 4"4-t;: . . ''' , • 'to,. ..., ' ' ' '! ' 4 .ri:*ir,. - A • , / ' .`..,.. .i:' *. a . . ' ' , ' .• ' ;,:, , ' . ' a ' k 45* ''' ';0 ., ' ; ••", ' , . 1 .• '..‘1.4 y., „., , • .,...,4 ' • - ,-i' '. - '- ..--; - .?.":-."; -4'1,47.:. ' --'''' ":!, '. P. :" .; .'it4 • , • to, i ii■• , ' - ' , :-*:',:,.• 'AI ,•..., N,., - -•7'.-: , ', : :::: .1 .' • ..A1.s •., . . , , . . •. .. — .• . ... . . . . . "" . • '. •,'• , • • . . . • - • ‘ •-,- . „ . . , • -*, . . • • .. . - . - -• • • . • to sTiol Li; SARAH PALIN, GOVERNOR ALASKA OII, AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 isf7sfi�` ii i` PHONE (907) 279 -1433 FAX (907) 276 -7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 01 -05B BP Exploration (Alaska) Inc. Permit No: 207 -048 Surface Location: 547' FNL, 1420' FWL, SEC. 08, T1ON, R15E, UM Bottomhole Location: 67' FNL, 3578' FWL, SEC.09, T1ON, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The well name in your application was 01 -05A, however examination of the record has determined that 01 -05 was plugged back and redrilled in 1992. According to the naming nomenclature, this third reservoir penetration should properly be named 01- 05B. No revision of the past records of 01 -05 is necessary. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum fi = or at (907) 659 -3607 (pager). 1 10 1 11 "'nK.►o .1 Ch.' an DATED this 26day of April, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. y � R ECEIVED STATE OF ALASKA 04/14 A L A S D I L A N D G A S C O N S E R V A T I O N C O M M I ON i � W y ,� 0 4 2007 PERMIT TO DRILL /� 20 AAC 25.005 Alaska Oil & Gas Cons. Commission la. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas 1 c. Specify if well is propoa e ❑ Drill ® Redrill ❑ Service ❑ Multiple Zone ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re - Entry ❑ Stratigraphic Test ® Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 - 01 -051 Z 4 - 2 9)11 3. Address: 6. Proposed Depth: 12. Field / Pool(s): l a3 P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 14966 TVD 8700 Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028328 547' FNL, 1420' FWL, SEC. 08, T1ON, R15E, UM / Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 5104' FNL, 555' FWL, SEC. 09, T1ON, R15E, UM , May 1, 2007 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 67' FNL, 3578' FWL, SEC. 09, T1ON, R15E, UM - 2560 / 15,840' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool: Surface: x- 698746 y- 5940378 Zone -ASP4 (Height above GL): 61.9 feet 630' 16. Deviated Wells: Kickoff Depth: 4700 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 97 degrees Downhole: 3250 Surface: 2380 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement. c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) N/A 9 -5/8" 40# L -80 BTC -M TBD TBD TBD TBD TBD Tieback: 725 sx Class 'G' N/A 7" 26# L -80 TC -II / BTC -M 4550' Surface Surface 4550' 4336' Tieback: 184 sx Class 'G' 8 -1/2" 7" 26# L -80 BTC -M 6798' 4550' 4336' 11348' 8705' 1017 sx Class 'G'. 91 sx Class 'G' 6 -1/8" 4-1/2" 12.6# 1 -80 IBT -M 3768' 11198' 8624' 14966' 8700' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 11452 9215 9727 11220 9000 11220 Casing Length Size Cement Volume MD TVD Conductor / Structural 1216' 20" Fondu to Surface 1216' 1216' Surface 2709' 13 -3/8" 950 sx Fondu 2709' 2709' Intermediate 10000' 9 -5/8" 1175 sx Class 'G' 10000' 7910' Production Liner 1706' 7" 345 sx Class 'G' 9737' - 11443' 7725' - 9206' Perforation Depth MD (ft): 11165' - 11212' Perforation Depth TVD (ft): 8949' - 8992' 20. Attachments ® Filing Fee, $100 ❑ BOP Sketch ►_' Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission,` epresentative: Date: 22. I hereby certify that the f• e'oi• • is true and correct. Contact Phil Smith, 564 - 4897 Printed Name Greg jj '. i Title Senior Drilling Engineer Jim Nigh, 564 - 5220 ,_ - jor Prepared By Name /Number: Signature / Phone 564 -4191 Date �/zl r Terrie Hubble, 564 - 4628 / Commission Use OM Permit To Drill API Number: O? nom, Permit Nproval I See cover letter for Number: p?O7O4,O 50 - 029 - 20076 - - ■-■1 Date: "4 'Cr\ otherreauirements Conditions of Approval: / 14K313° If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: c''` ` �� V � G_ D�he Samples Req'd: ❑ Yes pQ No Mud Log Req'd: ❑ Yes No `` HA Measures: } ❑ No Dir�-'- al Survey Req'd: WYes ❑ No Other: n `N Vktvzrf-C.X, \S cotc_ adRkCa -S ,e3 s c\(%)cc,) Q1 \\ / / � 7 t PPROVED BY THE COMMISSION Date Gf , COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate ORIGINAL To: Alaska Oil & Gas Conservation Commission b p From: Jim Nigh Date: March 27, 2007 Re: 01 -05A Sidetrack Permit to Drill The 01- 05sidetrack is scheduled to be drilled by Nabors Rig 7ES in May. Prior to sidetrack operations, the wellhead will be replaced, requiring the 9 -5/8" casing to be cut, pulled, and replaced from a depth determined post USIT run. The sidetrack plan is to exit the parent 01 -05 well bore from the 9 -5/8" casing at -4,700' with an 8 -1/2" BHA. An 8 -1/2" hole will then be drilled to the Sag River. A 7" drilling liner will be run from the 9 -5/8" kick -off point down to the Sag. A 1740' long, 7" scab liner will be stung into the top of the 7" drilling liner at -4,550' and cemented. After top setting the Sag, a 6 -1/8" hole will be drilled horizontally for approximately 3,618' in the Sag River formation to a final TD of 14,966' MD. A slotted 4 -1/2" production liner will be run from TD to 11,348' MD back into the 7" liner. A 4 -1/2" chrome tubing string is the planned completion for this well. 01 -05/ well plan Summary (3/13/07) Well Sidetrack / Target Well 01 -05A Type Horizontal Objective Sag River Producer AFE Number: 1 PBD4P2527 1 I API Number: 1 50- 029 - 20076 -01 Surface Northing Easting Offsets TRS Sec 8, T1ON, Location 5940378 698746 547' FNL / 1420' FWL R15E _ Northing Easting Offsets TRS TVDSS Target 5104' FNL / 555' Sec 9, Location 5935940 703294 FWL T1ON, -8631 R15E Northing Easting Offsets TRS TVDSS Bottom 67' FNL / 3578' Sec 16„ Location 5935780 706324 FWL T1ON, -8628 R15E Planned KOP: 4700' MD Planned Lateral TD: 14966' Planned Spud: 05/01/07 Planned Lateral TVD: 8700' TVD Rig: Nabors 7ES GL: 33.4' RTE: 61.9' 01 -05A Sidetrack Page 1 0 0 Directional Program Approved Well plan: WP07 1 Exit point: 1 4700' MD / 4443' TVD Maximum Hole Inclination: -97° from 11524' through the horizontal interval down to -90° at TD Proximity Issues: Pre -rig gyro required for 12 -02 to clear up uncertainty issues Survey Program: Gyro orientation will not be required for the initial kick -off (since > 7 degrees). Standard MWD +IIFR +MS. Nearest Well: 630' (12 -02 lvishak Producer) & 1740' (03 -15A Sag Producer) Nearest Property Line 15840' Logging Program Hole Section: Required Sensors / Service 9 -5/8" Cased hole USIT logging to determine cut point 8 -1/2" Intermediate: DIR /GR /RES /PWD 6 -1/8" Production: DIR /GR /ABI /RES /NEU /DEN Comments: *Azimuthal Density may be picked up after the invert/belly has been drilled in the production hole, but should be picked up before entering the base of the Sag. Mud Program Hole Section / operation: 8 -1/2" Intermediate Hole Type: Fresh Water LSND Depth (ft) Density PV YP API MBT pH (PPM ( ) 4700 -10557 9.5 -9.8 10 -18 18 -28 4.0 -7.0 <20 9 -10 10557 -11348 11.6 12 -22 18 -28 4.0 -.60 <20 9 -10 Hole Section / operation: 6 -1/8" Production Interval Type: FloPro SF Depth (ft) Density PV YP LSRV MBT pH (PPg) 11348 -14699 8.5 6 -12 22 - 28 > 20,000 < 4 9.0 - 9.5 Casing / Tubing Program Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size (MD) (MD) 13 -3/8" 9 -5/8" 40# L -80 BTC -M TBD fm Surface TBD from casing USIT USIT 9-5/8" 7" Tie back 26# L -80 TC -II -3700' Surface 3700' casing 9-5/8" 7" Tie back 26# L -80 BTC -M -1000' 3700' 4550' casing 8-1/2" 7" 26# L -80 BTC -M -6798' 4550' 11348' 6 -1/8" 4 -1/2" Slotted 12.6# L -80 IBT -M -3768' 11198' 14966' Liner Tubing 4 -1/2" 12.6# 13Cr VamTop -11198' Surface 11198' 01 -05A Sidetrack Page 2 Cementing Program Casing String: 9 -5/8 ", 47 #, L -80, BTC -M, Tie -Back Casing Lead slurry: None Planned. Slurry Design Basis: Tail slurry: -2200' of 72 #, 13 -3/8" Casing x 47 #, 9 -5/8" annulus with 10% excess. Pre -Flush TBD Fluids Sequence / Volume: Spacer TBD Lead Slurry None planned Tail Slurry 150 bbls / 840 ft3 / 725 sx Class 'G', 15.8ppg; 1.16 ft /sk. Casing String: 7 ", 26 #, L -80, BTC -M Intermediate Liner Lead slurry: Remainder of 8 -1/2" x 7" annulus with 40% excess, plus 150' of 9 -5/8" X 7" liner lap. Slurry Design Basis: Tail slurry: 500' of 8 -1/2" x 7" annulus with 40% excess, plus 80' of 7 ", 26# shoe track. Pre -Flush TBD Spacer Fluids Sequence /Volume: Lead Slurry 21 bbl / 1180 ft' / 1017 sx Class '0', 12.5 ppg; 1.16 ft' /sk. Tail Slurry 19 bbl / 106 ft' / 91 sx Class `G', 15.8 ppg; 1.16 ft' /sk. Casing String: 7 ", 26 #, L -80, TC -II & BTC -M Tie -back Liner Lead slurry: None planned. Slurry Design Basis: Tail slurry: 1350' of 9 -5/8" x 7" annulus. Pre -Flush TBD Fluids Sequence / Volume: Spacer TBD Lead Slurry None planned. Tail Slurry 38 bbl / 213 ft3 / 184 sx Class `G', 15.8ppg; 1.16 ft' /sk. Casing / Formation Integrity Testing Test Test Point Test Type Test pressure 9 -5/8" Tie -Back Prior to Drill -Out ES Cementer Casing Test 4000 psi surface (30 min recorded) 9 -5/8" Casing Prior to Mill Window Casing Test 4000 psi surface f/Whipstock Departure (30 min recorded) 9 -5/8" Window 20' beyond mid - window FIT 11.8 ppg EMW 7" Liner to Surface Landing collar to surface Casing Test 4000 psi surface (30 min recorded) 7" Shoe 20' beyond shoe FIT 10.0 ppg EMW 4 -1/2" Liner Landing collar to surface Casing Test 4000 psi surface (30 min recorded) 01 -05A Sidetrack Page 3 Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind /shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8'/2" intermediate interval Maximum anticipated BHP: 3250psi at 8705' TVD Maximum surface pressure: 2380psi (based upon BHP and a full column of gas from TD @ 0.10 psi /ft) Calculated kick tolerance: Infinite with 10.5 ppg EMW FIT Planned BOPE test pressure: 250psi low / 4000psi high — 7 day test cycle until a window is milled in 9 -5/8" casing. Once a window is milled a 14 day test cycle can commence. BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams Liner while running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This configuration provides two sets of employable rams, rather than one. Planned BOPE function test - _ ' reques . riance to the provisions of 2! . • --° _ 5.035 (e)(10)C regarding the function • sure test require.' -nt after the use of BOP ram hd��F type equipment for other tha ell; ontr- or equivalent purposes, except �` when the routine use of BOP equl -nt may have compromised their M j / effectiveness. (Example would • - whe • rams are inadvertently �J L \� closed on a tool joint duri • . tine operatio The activities associated • this re_ of compromise the integrity • - BOP equipment. Well Interval: 6 -1/8" production liner section Maximum anticipated BHP: 3250psi at 8745' TVD Maximum surface pressure: 2380ps1 (based upon BHP and a full column of gas from TD @ 0.10 psi /ft) Calculated kick tolerance: Infinite with 10.0 ppg EMW FIT Planned BOPE test pressure: 250psi low / 4000psi high Planned com letion fluid: 8.4ppg seawater / 7.0 Diesel Planned BOPE test pressure: 250 Lsi mow / 3,500psi high — 14 da cycle. Planned BOPE function test 'BPXA requests a varianc- • - provisions of 20 AAC 25.035 (e)(10)C regarding the function pres • re equirement after the use of BOP ram type equipment for other an well con sr equivalent purposes, except IND when the routine use : BOP equipment ma • -ve compromised their f� vA-t, effectiveness. ( -mple would be when pipe ram re inadvertently � closed on a . joint during routine operations.) The .. •vities associated with t. -quest will not compromise the integrity of the Be - : • •1 ent. Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject stat at DS -04. Any metal cuttings should be sent to the North Slope Borough. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS -04 for injection. All Class I wastes are to be hauled to Pad 3 for disposal. 01 -05A Sidetrack Page 4 • • Geologic Prognosis Commercial Hydrocarbon Est. Formation Tops Uncertainty Bearing Formation (TVDss) (feet) (Yes /No) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells SV4 -2850 10' SV3 -3514 10' SV2 -3715 10' SV1 -4146 10' UG4 -4670 10' UG3 -4857 10' KOP @ 4700MD (4442tvd) UG1 -5594 10' WS2 -6094 10' WS1 -6340 10' CM3 -6594 10' CM2 -7100 20' CM1 -8056 20' THRZ -8242 20' No BHRZ -8388 20' No TJC -8428 20' No TJB -8437 20' No TJA -8509 20' No TSGR @ landing -8605 20' Yes TSHA @ landing -8635 20' Yes TSGR @ PTD -8614 20' Yes TSHA @ PTD -8641 20' Yes PTD @ 14966MD (8700tvd) TD Criteria TD Criteria Approx. 3618' Sag Horizontal. Need 2500' reservoir sand to TD. (horizontal): 01 - 05A Sidetrack Page 5 • Fault Prognosis The proposed 01 -05A well is not expected to cross any mapped faults. There are no mapped faults in the immediate vicinity of this well. According to the Lost Circulation database there have been no significant LC incidents in the immediate area of this proposed location. Based on this history the LC risk would be considered low. The closest LC events are detailed below. However, Sag wells located -2 -3 miles further west along this trend (06 -06B and 13- 02BL1) had serious LC issues. Therefore LC risk should be considered moderate for the 01 -05A proposed well. Well Type Loss (bbl) MD SSTVD Formation X Y 03 -15A rig 22 12768 9102 ZONE 2 706950 5934182 12 -26 rig 158 8700 6925 Above SAG RIVER -LCU 701392 5932816 01 -04 Operations Summary Pre -Riq Work Test 9 -5/8" packoff to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lockdown screws. Repair or replace as needed. Bleed pressures to zero. Plumb bob TOC in surface x conductor & report depth below flutes to ODE. RU slickline and pull the PXN plug from the tailpipe at 9727' MD. Drift through 4 -1/2" tubing tail, tag TD. Replace all live gas lift valves with dummy valves. RIH with coil tubing, P &A with -27 bbls of cement. Cement calculations: • 7" liner 11,220'- 10,500' = 720' ( -27 bbls) ID= 6.184" Only need cement to 11,047' (100' above top pert in order to satisfy state requirements). Highest TOC allowable: 5,500'. Plan for TOC at approx 10,500' in order to allow for significant losses. RIH with E -line and cut the 5 -1/2" tubing with a jet cutter at 5,100 MD. Circulate the well to seawater through the cut, freeze protect the tubing and IA to -2,200'. Combo pressure test TxIA to 3,500 psi for 30 min. Pressure test the OA to 2,000 psi. Set a BPV. Test to 1000 psi from IA. Remove the well house and the flow line. If necessary, level the pad. Please provide total well preparation cost on the handover form 01 -05A Sidetrack Page 6 • • Riq Operations: 1. MI / RU Nabors 7ES. 2. Pull BPV. Circulate out freeze protection fluids and displace to seawater. 3. Set TWC. Nipple down tree and adaptor. Nipple up and test BOPE to 3,500 psi. Pull TWC. 4. Back out Iockdown screws, pull hanger. 5. Pull the 7" X 5 -1/2" tubing from the pre -rig cut at - 5,100' and above. 6. P/U drill pipe, MU 9 -5/8' mills assembly. RIH picking up DP and circulate the well bore with 9.8 ppg brine. 7. RU E -line, run USIT. 8. MU a 9 -5/8" CIBP on DP, RIH and set at - 4,925' MD, test to 4000 psi. 9. Determine the depth of the proposed 9 -5/8" cut based on USIT interpretation of TOC. 10. Change out to 9 -5/8" rams, and test. 11. MU a Baker 9 -5/8" cutting assembly. RIH picking up DP. Cut the 9 -5/8" casing per Baker representative instructions. Cut -4' above a casing collar. POOH, VD assembly. 12. BOLDS, MU casing spear assembly, and unseat the 9 -5/8 ". Circulate the Arctic Pack from the annulus with warm diesel followed by seawater and detergent sweeps. Pull the 9 -5/8" casing from the cut point. 13. RU E -line. Run string shot to collar to be backed off. 14. RU Baker back -off assembly, RIH, and back off the 9 -5/8" casing joint. POOH, UD assembly. 15. RIH with spears and recover the cut joint. 16. Make scraper run to the casing stub. Wash over the 9 -5/8' stub. POOH, UD the assembly. 17. PU 9-%" Baker screw -in sub w /ES cementer on 47# 9 -5/8" casing & TIH and screw in to csg stub. 18. RU Schlumberger cement and cement OA to surface using ES Cementer (lead cement job 1 annular volume of 9.8 ppg brine). ‘.\ 19. ASAP after cementing, PU BOPE, split stack, install casing slips, RILDS, make 9 -5/8" casing cut w/ �'1 WACHS cutter. L e} 20. PU 8 -1/2" clean -out BHA on 4" drill pipe and clean -out the 9 -5/8" casing to the top of the baffle adapter in the "new" 9 -5/8" casing and test well to 4000 psi. (NOTE: Drill -out the ES cementer per HES procedure.) 21. With the well successfully tested, continue the 9 -5/8" clean -out down to -4,800' MD (just above CIBP CO 4,935' MD). 22. RU, MU 9 -5/8" whipstock assembly with bottom trip anchor with an 8 -1/2" window milling assembly. Run directional tools for whipstock orientation. Swap mud to 9.5 ppg LSND based milling fluid. 4 23. RIH to CIBP, orient and set the whipstock. POOH. 24. Mill window in 9 -5 -8 "casing at - 4,700' MD plus 20' from mid window. 1 1 25. CBU, perform FIT to 11.8 ppg. Contact ODE if FIT not achieved. 26. POOH, UD milling assembly. ,-c 27. MU 8 -1/2" drilling assembly -BHA with Dir /GR /RES /PWD. RIH to window. ��,S , 28. Drill ahead to Top of Sag at 11,295' MD. Circulate bottom up, short trip- circulate and condition the hole for 7" liner run. 29. POOH, UD the BHA assembly. 1 7 30. Change out to 7" rams, and test. `- .` " ,\ 31. Rig up, MU 7" liner. 32. RIH to bottom on drill pipe. Circulate and condition the hole. 4 33. Cement the entire 7" liner through the 8 -1/2" hole and 150' into the 9 -5/8" casing at 4,700' MD. Set the hanger and packer, displace cement with mud. 34. Circulate bottoms up, POOH, UD liner running tool (LRT). 35. Make up 4,600' of 7" liner tieback. 36. Sting in and establish seal, P/U to expose ports. 37. Cement the tieback to surface, bury the seal. 38. Split stack, set slips. 39. Cut casing, set back stack. 40. Install pack -off and test. 41. Nipple up spool and BOPE stack, install variable bore rams, and test. 42. Pick up drill pipe and stand back. 43. Pressure test casing and liner. 44. MU build assembly. 45. RIH to liner float equipment. 46. Drill up cement and float equipment. 47. Displace to 8.5 flo pro fluid. 01 -05A Sidetrack Page 7 • 48. Make up 6 -1/8" drilling directional; assembly. RIH to shoe. Drill out of shoe plus 20' of new formation, and FIT to 10.0 ppg. Notify ODE if FIT not achieved. 49. Drill ahead at approx. 20 ft per hour to landing at 13,183. 50. Circulate bottom up, POOH for horizontal assembly. 51. Make up 6 -1/8" horizontal drilling assembly. Azimuthal density logging tool will be added to the BHA which includes Dir /GR /ABI /Res and SLB's geosteering. 52. Geosteer drill per directional plan to TD at 14,966'. 53. Circulate bottom up, short trip, circulate and condition the hole for 4 -1/2" slotted liner run. 54. POOH, UD BHA assembly and excess drill pipe. 55. Make up 4 -1/2 ", 12.6 #, L -80 slotted liner, plus 150' of 4 -1/2" 12.6 #, L -80, BTC -M for overlap into the 7" liner. 56. RIH to bottom. Set liner hanger and packer. 57. Release and displace to clean seawater. 58. POOH, UD drill pipe, LRT. 59. Make up 4 -1/2" chrome tubing. Space and land the tubing into the 4 -1/2" liner top, RILDS. 60. Reverse circulate to seawater and corrosion inhibitor. 61. Drop ball and rod, set packer. 62. Test tubing and annulus separately test to 3500 psi each, record the tests. 63. Install and test TWC. 64. Nipple down BOPE. 65. Nipple up adaptor flange and tree, and test the tree to 5,000 psi. Pull the TWC. 66. Shear the DCK valve. Reverse in diesel freeze protect to - 2,200' -U -tube. Install BPV. 67. Secure Well, Release the rig. Post -Rig Work: 1. Install well house and flowlines. New S -riser will be manufactured. 2. MIRU slick line. Pull the ball and rod / RHC plug from `XN' nipple. 3. Install gas lift valves. I 01 -05A Sidetrack Page 8 • 01 -05 "Potential Drilling Hazards (Post on Rig) • Pre -job HAZOP's and Safety meetings are recommended when there is a clear change in work scope. If at any time things don't feel or look right, STOP the job and discuss the situation before making the next move. • Flash Points o Dead Crude= <40degF o Methanol (neat)= 52degF o Diesel= 100degF • Hydrogen Sulfide o DS -01 is a high level H2S drill site. Use extra caution while working. Standard Operating Procedures for H2S precautions should still be followed at all times. o Closest SHL Well: 12 -13B -10 ppm on 1/15/06 o Max H2S reading: 01 -34 - 40 ppm on 12/31/05 • Bottom Hole Pressure o 3250 psi @ 8745 TVD • Maximum anticipated wellhead pressure: o 2380 psi w/ full column of gas • Potential for Toss circulation o Low O The proposed 01 -05A well is not expected to cross any mapped faults. There are no mapped faults in the immediate vicinity of this well. • Close Approaches O 03 -16 - 494' ctr - ctr -14,884' MD O 03 -24 - 803' ctr - ctr -12,823' MD O 03 -24A - 622' ctr - ctr -12,409' MD O 12 -02 - 631' ctr - ctr -12,673' MD 01 -05A Sidetrack Page 9 McEVOY WELLHEAD = 6 McEVOY 0 1 -05 S NOTES: TROUBLE WELL -RAPID IA OA ACTUATOR = OTIS CO M; LEAKS ON A/L, OA X OOA COMM., 20" KB. ELEV = 73.0' (originally named 01- 05ST1) SURF CSG FAILURE, GAS LEAK @ 20" HGR BF. ELEV = NA - CLAMP 08/18/96.* 13 -CR TBG &LNR. KOP = 3089' Max Angle = 53 @ 8286' Datum MD = 11083 \ / ( 22' H 7" X 5 -1/2" HGR XO, ID = 4.892" I Datum TV D = 8800'SS I 9 -5/8" FOC H 1133' 1 A - — 120" CSG, 94 #, H-40, ID = 19.124" I-1 1216' I I — I 1169' H 13 -3/8" CP I 9 -5/8" FOC H 2184' I - - 9 -5/8" CP H 2223' 1 I ' I 2242' H 5 -1/2" CAMCO BAL -O SSSVN, ID = 4.562" I GAS LIFT MANDRELS 13 -3/8" CSG, 72 #, N 80, ID = 12.347" H 2709' I , ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3267 3261 14 FMHO RK 2 5801 5208 47 FMHO RK Minimum ID = 3.725" @ 9753' 3 7425 6268 50 FMHO RK 4 -1/2" PARKER SWN NIPPLE 4 8747 7090 52 FMHO RK 5 9077 7303 48 FMHO RK 6 9451 7545 52 FMHO RK 7 9610 51 FMHO _ RK 5 -1/2" TBG, 17 #, 13 -CR, .0232 bpf, ID = 4.892" I ' ' I 9642' H 5 -1/2" OTIS X NIP, ID = 4.562" I E 1 9705' H 9 -5/8" X 5 -1/2" TIW HBBP PKR, ID = 4.750" I / 1 9716' II 5 -1/2" X 4 -1/2" XO, ID = 3.958" I I BAKER C-2 TIEBACK SLV, ID = 7.500" H 9737' I l 9729' slm J -14 -1/2" PXN PLUG SET IN SWN NIP ON 07/04/98 I I 9 -5/8" X 7" BKR LNR HGR, ID = 6.250" H 9749' 1 9739' 1-I 4 -1/2" PARKER SWS NIP, ID = 3.813" I 19 -5/8" X 7" BAKER H PKR, ID = 6.250" H 9745' 1 1 4 -1/2" PXN PLUG SET ON 07/04/98 I 9727'slm ..a'..1 1 9753' H 4 -1/2" PARKER SWN NIP, ID = 3.725" I 14 -1/2 "TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" H 9764' 1 ♦ I 9765' H 4 -1/2" WLEG, ID = 3.958" I I9 -5/8" CSG, 40# / 43.5 #, 47 #, SOO -95, ID = 8.681" H 10000' (-- 1 9746' H ELMD TT LOGGED 03/23/92 I 9-5/8" CSG MILLOUT WINDOW 10000' - 10070' (SECTION MILL) PERFORATION SUMMARY REF LOG: BHCS ON 3/10/1992 ANGLE AT TOP PERF: 22 @ 11147' 1 10954' I--I 7" MARKER JT (21') I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 11147 - 11157 S 10/28/96 I 3 -3/8" 6 11165 - 11180 0 11/05/96 ` 3 -3/8" 2 11201 - 11202 S 10/28/96 3 -3/8" 6 11202 - 11212 0 11/05/96 ` 3 -3 /8" 4 11232 - 11237 S 10/28/96 3 -3/8" 6 11246 - 11256 S 10/28/96 I 11220' H PBTD I 3 -3/8" 4 11256 - 11265 S 10/28/96 ;; ; 4 ; •. ` 4: ''; BKR IBP ON BTM - 08/14/93 I N I 7" LNR, 29 #, 13 -CR, .0371 bpf, ID = 6.184" 1-1 11443' 0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/03/76 ORIGINAL COMPLETION 10/07/02 /TP PERF INTERVAL CORRECTION WELL: 01 -05ST1 03/17/92 RIG SIDETRACK (01- 05ST1) 08/22/04 TLP FIX CANVAS PROBLEM PERMIT No: 1700400 07/04/98 SET PXN PLUG @ 9729' 11/29/04 DFR/TLP 20" AND 9 -5/8" CSG API No: 50- 029 - 20076 -01 02/16/01 TP CORRECTIONS SEC 8, T1 ON, R15E, 547' FNL & 1420' FWL 04/03/02 CH/TP CORRECTIONS 06/04/02 KB /KAK PERF CORRECTION BP Exploration (Alaska) TREE = , 6" McEVOY 01-05f( WELLHEAD = McEVOY • S� NOTES: TROUBLE WELL -RAPID IAX OA ACTUATOR = OTIS O riginally named 01 -05ST1 CO M; LEAKS ON A/L, OA X OOA COMM., 20" KB. ELEV = 73.o' Proposed Completion SURF CSG FAILURE, GAS LEAK @ 20" HGR BF. ELEV = NA a CLAMP 08/18/96. * 13 -CR TBG & LNR. KOP = Max Angle = Datum MD = 11083 22' I-i 7" X 5-1/2" HGR XO, ID = 4.892" Datum TVD = 8800'SS I 9 -5/8" FOC H 1133' I j -.• 120" CSG, 94 #, H -40, ID = 19.124" H 1216' I I I 1169' H 13 -3/8" CP I 9 -5/8" FOC H 2184' I - - 12,200' - 4 -1/2" X Nipple (3.813" ID) 9 -5/8" CP H 2223' I I ST MD 1VD DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2709' I , 1 10214 2 86555 ----------- 3 7097 TOO 3209' (500'below surface csg) 4 5171 5 3164 Minimum ID = 3.725" @ 11,158' 1 4,550` 9 -5/8" X 7" BKR ZXP PKR /HGR 4 -1/2" BAKER XN NIPPLE 1 11,098' - 4 -1/2" X Nipple (3.813" ID) I I4 -1/2" TBG, 12.6 #, 13CR -80 I I 11,118' - 7" X 4 -1/2" BKR S3 Packer I I KOP - 4,700' I ;; 1 11,138` -4-1/2"X Nipple (3.813" ID) I CIBP - 4,925' 1 11,158` 4 -1/2" XN nipple (3.725" ID) I Tubing Cut - 5,100' 4'. 11,178` - 4 -1/2" WLEG :D I TOC No shallower than 5,500 1 4 -1/2 "TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" H 9764' I S g 11,198' - 7" X 4-1/2" BKR ZXP Pkr ��` 11,348' - 7 ", 26 #, L -80 liner 19 -5/8" CSG, 40# / 43.5 #, 47 #, SOO -95, ID = 8.681" H 10000' J ■ ■ 1 14,966` - 4 -1/2 ", 12.6# L -80 Slotted liner I L' :, I ' • A a ' PERFORATION SUMMARY LOG: BHCS ON 3/10/1992 ANGLE AT TOP PERF: 22 @ 11147' Note: Refer to Production DB for historical pert data \ I 11220' H PBTD SIZE SPF INTERVAL Opn /Sqz DATE " 4,, , ���� 3 -3/8" 4 to 6 11147 - 11265 _ 10/28- 11/5/96 `�`�� ∎w^ `; x` 6`` 1" BKR IBP ON BTM - 08/14/931 I 7" LNR, 29 #, 13 -CR, .0371 bpf, ID = 6.184" I-I 11443' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/03/76 ORIGINAL COMPLETION 10/07/02 /TP PERF INTERVAL CORRECTION WELL: 01 -05A 03/17/92 RIG SIDETRACK (01 -05ST1) 08/22/04 TLP FIX CANVAS PROBLEM PERMIT No: 07/04/98 SET PXN PLUG @ 9729' 11/29/04 DFR/TLP 20" AND 9 -5/8" CSG API No: 50- 029 - 20076 -02 02/16/01 TP CORRECTIONS 03/12/07 JN UPDATE FOR RIG ST SEC 8, T1ON, R15E, 547' FNL & 1420' FWL 04/03/02 CH /TP CORRECTIONS 06/04/02 KB /KAK PERF CORRECTION BP Exploration (Alaska) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: I -05A Wp07 (01 -05 /Plan 1 -05A) BP Amoco Co-ordinate (N /E) Reference' Well Centre' 01-05, True North Depth Fm Depth To Survey /Plan Tool Created By: Troy Jakabosky (jakat00;bp.co0)te: 5/16/2006 Vertical (TVD) Reference. 8.05 3/7/1992 00 0 7300 171.7 Calculation Method: Minimum Curvature Section (VS) Reference Slot -115 PI 00N,0 00E) 470000 14966.23 Planned -05A Wp07 V63 MWD +IFR +MS Checked: Date: Minimum Error System: ISCWSA Measured Depth Reference' 8 05 Minimum 3/7/1992 00011 731g1 Scan Method Tray Cylinder North Calculation Method Mmum Curvature Error Surface: Elliptical +Casing Reviewed: Date: Wammg Method' Rules Based _ WELL DETAILS TARGET DETAILS Name +N / -S +E/ -W Northing Eutmg Latitude Longitude Slot Name TVD +N / - S +E / - W Northing Easting Shape 01 - 05 - 159444 146707 594037673 69874581 70"14'28222N 148'23'41356W 05 1 -058 T3 8678.00 - 4877.05 5702 90 5935651.99 704575.00 Point CASING DETAILS 1 -058 T2 8694.00 - 4821.71 4932.05 5935686.99 703803.00 Point 1 -058 T5 8700.00 - 4784.95 7483.05 5935790.98 706352.00 Point - No. TVD MD Name Size 1 -05B T4 8702.00 - 4838.83 6605.28 5935713 99 705476.00 Point - 1 -0511 TI 8705.00 - 4574.96 4452.36 5935920.99 703317.00 Point - 1 8705.00 11348.12 7" 7.000 - 2 8700.00 14966.00 4 1/2" 4.500 SECTION DETAILS - Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 3300 1 4700.00 44.84 111.12 4442.50 - 399.99 736.80 0.00 0.00 836.23 2 4720.00 45.18 114.48 4456.64 - 405.48 749.84 12.00 83.00 850.16 - 3 5189.97 50.08 139.16 4775.95 - 612.76 1021.82 4.00 83.60 1190.98 4 10507.13 50.08 139.16 8188.41 - 3697.87 3688.16 0.00 0.00 5099.33 - 5 10510.80 50.00 139.00 8190.77 - 3700.00 3690.00 4.00 - 120.84 5102.03 - 6 10531.61 50.82 138.85 8204.03 - 3712.09 3700.53 4.00 -8.24 5117.42 - , . 7 11118.69 50,82 138.85 8574.90 - 4054.76 4000.04 0.00 0.00 5554.35 . . 8 11348.12 60.00 139.00 8705.00 - 4197.00 4124.00 4.00 0.84 5735.41 - Start Dir 12/100' : 47 )0' MD, 4442.5'TVb 9 1 1368.12 60.00 139.00 8715.00 - 4210.07 4135.36 0.00 0.00 5752.03 10 11524.10 97.44 139.02 8744.98 - 4323.50 4233.92 24.00 0.04 5896.16 • II 11796.65 97.44 139.02 8709.71 - 4527.52 4411.14 0.00 0.00 6155.38 4400 12 11859.70 91.13 139,00 8705.00 - 4574.96 4452.36 10.00 - 179.80 6215.67 1 -05B Ti Start Dir 4 /100' : 4720' MD, 4456.641TVD 13 12158.28 91.14 109.14 8698.95 - 4740.30 4696.86 10.00 -89.68 6510.72 t k 15 12407.22 91.19 108.00 8694,00 - 4821.71 4932.05 6.00 -87.58 6752.73 1 -05B T2 - 5000 16 12683.64 91.28 91.41 8688.02 - 4868.14 5203.50 6.00 -89.51 7006.43 - End pit : 5189.97' MD, 4775.95' TVD 17 13082.20 91.28 91.41 8679.13 - 4877.95 5601.84 0.00 0.00 7347.32 - UG3 18 13183.29 90.00 87.57 8678.00 - 4877.05 5702.90 4.00 - 108.39 7431.98 1 -05B T3 - 19 13223.32 88.40 87.61 8678.56 - 4875.37 5742.89 4.00 178.89 7464.76 _ 20 14037.99 88.40 87.61 8701.32 - 4841.34 6556.54 0.00 0.00 8131.91 21 14086.80 90.00 86.49 8702.00 - 4838.83 6605.28 4.00 -34,93 8171.62 1 -05B T4 - 22 14090.07 90.13 86.49 8702.00 - 4838.63 6608.53 4.00 0.00 8174.26 5 6000 23 14966.23 90.13 86.49 8700.00 - 4784.95 7483.05 0.00 0.00 8882.11 1 -058 T5 g 5500 - vol . .g - art Dir 4/100' : 10507.13' MD, 8188.41'TVD a CS' - - ' 7000 ' End Dir : 10531.61' MD, 8204.03' TVD .9 _ WS2 "'\ , Start Dir 4/100' : 11118.69' MD, 8574.9'TVD End Dir - 11348.12' Mp, 8705' TVD , - WS1 • . ,. - . F' 6600 ---^ Cwt Start Jir 24/100' : 11368.12' MD8715'TVD. . - Ear Dir : 11524,1' MD, 8744.58' TVD FORMATION TOP DETAILS CM2 ;tart Dir 10 /100' : 11796.65 MD, 8709.71'TVD • No. TVDPath MDPath Formation 9000 End Dir : 12158.28' MD, 8698.95' TVD. ' I 4930,00 5430.00 UG3 Start Dir 6 /ICY : 12388.27' MD, 8694.3R'TVD 2 5667.00 6578.37 UGl '^^ - 3 6167.00 7357.45 WS2 End Dir 12683.64' MD, 8688.02' TVD 4 6413.00 7740.75 WSI 5 6667,00 8136.53 CM3 10000 St .rt Dir 4/100' : 13082.2' MD, 8679.13'TVD 6 7173.00 8924.96 CM2 CMI End Dir : 13223.32' MD, 8678.56' TVD 7 8129.00 10414.56 CM! / Start Dir 4 /1C0' : 14037.99' MD, 8701.3. "TVD ' 8 8315.00 10707.27 THRZ TFI' 2. h . 9 84 10938.39 BHRZ BI-IRZ End Dir : 14090.07 MD, 8702' TVD I 10 8501.00 11001,71 TJC 1I 8510,00 11015.96 TJB T TJB '. ]llte - :1 r1. ' 12 8582,00 11129.99 TJA , _ �,� .._ ,,, , 1 -OSBTS 13 8678.00 11295.77 TSGR , ' . TI4 - - 41.7 , a„ ' 0 12000 \~\ 13000 'n 14000 o ff „ -- 14 8708.00 11354.12 TSHA TSt..R `\ 1-05A Wp07 7 S A 1 -05B TI t -OSB T4 \\ • 1 -05B T2 1 -05B T3 4 1/2" 01 -05 (01 -05) Total Depth : 14966.23 MD, 8700' TVD I . '_' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I 1 1 1 1 1 1 1 11 -is 3300 4400 5500 6600 7700 8800 9900 11000 „i'.' - -- .. Vertical Section at 122.60° [1100ft/in] COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan' 1 -05A Wp07 (01 -05 /Plan 1 -05A) BP Ammo Co-o,dmate (N /E) Reference Well Centre 01 -05, True North Depth Fm Depth To Survey/Plan Tool Created By: Troy Jakabosky 6akal0@bp.colOte. 5/16/2006 i 0 Vertical (TVD) Reference. 8 • 05 3/7/1992 10 00 73 00 3 £[ ! Wlculatro M rlrn, Mmrmum Curvature Section (VS) Re Calculation Slot- 3/7/10 00E1 47181181 14966.13 Planned. l -05A Wp07 V63 MWD+IFR�MS Checked' Date: Error System IS CWSA Measured Depth Reference 8 OS tl/ /1992 00'00 73.110 Scan Method. Tray Cylinder North Calculation Method. Minimum Curvature WELL DETAILS Error Surface. Elliptical + Casing Warning Method Rules Based Name +N / -S +E / -W Northing Forting Latitude Longitude Slot 01 -05 - 159444 146707 5940376,73 69874581 70'14'28 222N 148 05 TARGET DETAILS - Start Dir 4/100' ; 4720' MD, 4456.64'TVD Name TVD +N / -S +E / -W Northing Easting Shape 0 1 -05B T3 8678.00 - 4877.05 5702.90 5935651.99 704575.00 Point 1 -05B T2 8694.00 - 4821.71 4932.05 5935686.99 703803.00 Point 1 -05B T5 8700.00 - 4784,95 7483.05 5935790.98 706352.00 Point _ Start Dir 12/100' :4710' MD, 4442,5'TVD 1 -05B T4 8702.00 - 4838.83 6605.28 5935713.99 705476.00 Point 1 -050 TI 8705.00 - 4574.96 4452.36 5935920.99 703317.00 Point - 45( - SECTION DETAILS .------- _ End Dir : 5189.97' MD, 4775.95' TVD Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target -1000 " ' - - - - _ 1 4700.00 44.84 111.12 4442,50 - 399.99 736.80 0.00 0.00 836.23 2 4720.00 45.18 114.48 4456.64 - 405.48 749.84 12.00 83.00 850.16 - 3 5189.97 50.08 139.16 4775.95 - 612.76 1021.82 4.00 83.60 1190.98 4 10507.13 50.08 139.16 8188.41 - 3697.87 3688.16 0.00 0.00 5099.33 - 5 10510.80 50.00 139.00 8190,77 - 3700.00 3690.00 4.00 - 120.84 5102.03 5500 6 10531.61 50.82 138.85 8204.03 - 3712.09 3700.53 4.00 -8.24 5117.42 7 11118.69 50.82 138.85 8574.90 - 4054.76 4000.04 0.00 0.00 5554.35 - 8 11348.12 60.00 139.00 8705.00 - 4197.00 4124.00 4.00 0.84 5735.41 - 9 11368.12 60.00 139.00 8715.00 - 4210.07 4135.36 0.00 0.00 5752.03 10 11524.10 97.44 139.02 8744.98 - 4323.50 4233.92 24.00 0.04 5896.16 _ 6000 • II 11796.65 97.44 139.02 8709.71 - 4527.52 4411.14 0.00 0.00 6155.38 I l i -2000 ` • ." 13 12158.28 109.14 8698.95 1 859. 7 0 91.13 139.0 - 4574.96 4452.36 10.00 - 179.80 6215.67 I -05B TI - 4740.30 4696.86 10.00 -89.68 6510.72 14 12388.27 91.14 109.14 8694.38 - 4815.68 4914.10 0.00 0.00 6734.35 - 15 12407.22 91.19 108.00 8694.00 - 4821.71 4932.05 6.00 -87.58 6752.73 1 -05B T2 6500 16 12683.64 91.28 91.41 8688.02 - 4868.14 5203.50 6.00 -89.51 7006.43 9 - - 17 13082.20 91.28 91.41 8679.13 - 4877.95 5601.84 0.00 0,00 7347.32 - 18 13183.29 90.00 87.57 8678.00 - 4877.05 5702.90 4.00 - 108.39 7431.98 1 -05B T3 c _ 19 13223.32 88.40 87.61 8678.56 - 4875.37 5742.89 4.00 178.89 7464.76 01. o ' ( 20 14037.99 88.40 87.61 8701.32 - 4841.34 6556.54 0.00 0.00 8131.91 + - 7000 21 14086.80 90.00 86.49 8702.00 - 4838.83 6605.28 4.00 -34.93 8171.62 I -05B T4 22 14090.07 90.13 86.49 8702.00 - 4838.63 6608.53 4.00 0.00 8174.26 t L 23 14966.23 90.13 86.49 8700.00 - 4784.95 7483.05 0.00 0.00 8882.11 1 -05B T5 o -3000 - CASING DETAILS - 7500 Start Dir 4/100' : 10507,13' MD 8188.4I'TVD o - No. TVD MD Name Size as - and Dir : 10531.61' MD, 8204.03' TVD ' I 8705.00 11348.12 7" 7.000 - S t a r t Dir 4/100' : 11 1 18 69' MD, 8574.9'TVD 2 8700.00 14966.00 4 1/2" 4.500 8000 / FORMATION TOP DETAILS Dir End Dir : 11348 - 2' MD, 8705' TVD - -4000 / Start D 24 100' : 1 1368.12' MD, 8715 VD - No. TVDPath MDPath Formation ` 85 /-- End Dir : 11524.1' MD, 8744.98' TV ► 1 -05A Wp07 - 1 4930.00 5430.00 UG3 /! Start Dv 10 /100' : 11796.65' MD, • 709.71'TVD PI in 1 -05A - 2 5667.00 6578.37 UG1 3 6167.00 7357.45 WS2 E Dir : 12I58.28' MD, 86'8.95' TVD " - 4 6413.00 7740.75 WSI 7„ ...' / Start Did 6 / 0 0126838 . 4' MD, 8688902' TVDD 1 4 ll2 - 6 7173.00 8924.96 CM2 S - 5 6667.00 8136.53 CM3 // 4 .. _ .,, _, 7 8129.00 10414.56 CMI -. 8 8315.00 10707.27 THRZ 1 050 TI I 1 "'otal Depth :14966.23' ML, 8700' TVD.. . - -5000 8461.00 10938.39 BHRZ I It 1 -05B T3 I -05R T4 10 8501.00 11001.71 TJC . - I l 8510.00 11015.96 TJB I -05B T2 • d Dirt I4090.07'_MD, 8732' TVD - 12 8582.00 11129.99 TJA - 13 8678.00 11295.77 TSGR Start I ir 4/100": 14037.99' MD, 8701.32'TvD - 14 8708.00 11354.12 TSHA End Dir : 13223. 2' MD, 8678.56' TVD - - i . .tart Dir 4 /t00,' : 13082. D , 8679.13'TVD , - -6000 - T 1 T 1 1 1 1 T r T 1 I 1 1 1 1 I I 1 T 1 1 r l l 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 II _ ,. 1000 2000 3000 4000 5000 6000 7000 .s . - " -' West( -) /East( +) [I000ft/in] • Sper ry-Sun -Sun • P Y BP Planning Report Company: BP Amoco Date: 5/16/2006 Time: 14:34 :20 Page: 1 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01-05, True North Site: PB DS 01 Vertical (TVD) Reference: 8:05 3/7/1992 00:00 73.0 Well: 01 -05 Section (VS) Reference: Well (0 60Azi) Weilpath: Plan 1-05A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 1 -05A Wp07 Date Composed: 3/29/2006 Version: 63 Principal: Yes Tied -to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 01 TR -10 -15 UNITED STATES : North Slope Site Position: Northing: 5941932.14 ft Latitude: 70 14 43.905 N From: Map Easting: 697237.60 ft Longitude: 148 24 24.004 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 01 -05 Slot Name: 05 01 -05 Well Position: +N / -S - 1594.44 ft Northing: 5940376.73 ft Latitude: 70 14 28.222 N +E / -W 1467.07 ft Fasting : 698745.81 ft Longitude: 148 23 41.356 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 11348.12 8705.00 7.000 8.500 7" 14966.00 8700.00 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 5430.00 4930.00 UG3 0.00 0.00 6578.37 5667.00 UG1 0.00 0.00 7357.45 6167.00 WS2 0.00 0.00 7740.75 6413.00 WS1 0.00 0.00 8136.53 6667.00 CM3 0.00 0.00 8924.96 7173.00 CM2 0.00 0.00 10414.56 8129.00 CM1 0.00 0.00 10707.27 8315.00 THRZ 0.00 0.00 10938.39 8461.00 BHRZ 0.00 0.00 11001.71 8501.00 TJC 0.00 0.00 11015.96 8510.00 TJB 0.00 0.00 11129.99 8582.00 TJA 0.00 0.00 11295.77 8678.00 TSGR 0.00 0.00 11354.12 8708.00 TSHA 0.00 0.00 Targets Map Map <-- Latitude ----> <- Longitude -> Name Description TVD +N /-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1 -05B T3 8678.00 - 4877.05 5702.90 5935651.99 704575.00 70 13 40.235 N 148 20 55.682 W 1 -05B T2 8694.00 - 4821.71 4932.05 5935686.99 703803.00 70 13 40.785 N 148 21 18.075 W 1 -05B T5 8700.00 - 4784.95 7483.05 5935790.98 706352.00 70 13 41.126 N 148 20 3.964 W 1 -05B T4 8702.00 - 4838.83 6605.28 5935713.99 705476.00 70 13 40.604 N 148 20 29.466 W 1 -05B T1 8705.00 - 4574.96 4452.36 5935920.99 703317.00 70 13 43.214 N 148 21 32.006 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/16/2006 Time: 14:34:20 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-05, True North Site PB DS 01 Vertical (TVD) Reference: 8:05 3/711992 00:00 73.0 Wets: 01-05 Section (VS) Reference: Well (0.00N,0_00E,12260Azi) Wellpath: Plan 1 -05A Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Intl Azim TVD +N /-S +E/ -W DLS Build Turn TFO Target ft deg deg ft ft ft deg /100ft deg/100ft deg/100ft deg 4700.00 44.84 111.12 4442.50 - 399.99 736.80 0.00 0.00 0.00 0.00 4720.00 45.18 114.48 4456.64 - 405.48 749.84 12.00 1.71 16.80 83.00 5189.97 50.08 139.16 4775.95 - 612.76 1021.82 4.00 1.04 5.25 83.60 10507.13 50.08 139.16 8188.41 - 3697.87 3688.16 0.00 0.00 0.00 0.00 10510.80 50.00 139.00 8190.77 - 3700.00 3690.00 4.00 -2.05 -4.48 - 120.84 10531.61 50.82 138.85 8204.03 - 3712.09 3700.53 4.00 3.96 -0.74 -8.24 11118.69 50.82 138.85 8574.90 - 4054.76 4000.04 0.00 0.00 0.00 0.00 11348.12 60.00 139.00 8705.00 - 4197.00 4124.00 4.00 4.00 0.07 0.84 11368.12 60.00 139.00 8715.00 - 4210.07 4135.36 0.00 0.00 0.00 0.00 11524.10 97.44 139.02 8744.98 - 4323.50 4233.92 24.00 24.00 0.01 0.04 11796.65 97.44 139.02 8709.71 - 4527.52 4411.14 0.00 0.00 0.00 0.00 11859.70 91.13 139.00 8705.00 - 4574.96 4452.36 10.00 -10.00 -0.03 - 179.80 1 -05B T1 12158.28 91.14 109.14 8698.95 - 4740.30 4696.86 10.00 0.00 -10.00 -89.68 12388.27 91.14 109.14 8694.38 - 4815.68 4914.10 0.00 0.00 0.00 0.00 12407.22 91.19 108.00 8694.00 - 4821.71 4932.05 6.00 0.25 -6.00 -87.58 1 -05B T2 12683.64 91.28 91.41 8688.02 - 4868.14 5203.50 6.00 0.03 -6.00 -89.51 13082.20 91.28 91.41 8679.13 - 4877.95 5601.84 0.00 0.00 0.00 0.00 13183.29 90.00 87.57 8678.00 - 4877.05 5702.90 4.00 -1.26 -3.80 - 108.39 1 -05B T3 13223.32 88.40 87.61 8678.56 - 4875.37 5742.89 4.00 -4.00 0.08 178.89 14037.99 88.40 87.61 8701.32 - 4841.34 6556.54 0.00 0.00 0.00 0.00 14086.80 90.00 86.49 8702.00 - 4838.83 6605.28 4.00 3.28 -2.29 -34.93 1 -05B T4 14090.07 90.13 86.49 8702.00 - 4838.63 6608.53 4.00 4.00 0.00 0.00 14966.23 90.13 86.49 8700.00 - 4784.95 7483.05 0.00 0.00 0.00 0.00 1 -05B T5 Survey MD Inca Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co went ft deg deg ft ft ft ft ft deg/100ft ft ft 4700.00 44.84 111.12 4442.50 4369.50 836.23 - 399.99 736.80 0.00 5939996.32 699492.87 Start Dir 1 ' 0 4720.00 45.18 114.48 4456.64 4383.64 850.16 - 405.48 749.84 12.00 5939991.19 699506.04 Start Dir 4/' C 0 4800.00 45.63 118.93 4512.83 4439.83 906.80 - 431.07 800.70 4.00 5939966.94 699557.55 MWD +IFR +MS 4900.00 46.42 124.38 4582.29 4509.29 978.70 - 468.83 861.89 4.00 5939930.81 699619.72 MWD +IFR -MS 5000.00 47.46 129.67 4650.59 4577.59 1051.49 - 512.82 920.17 4.00 5939888.37 699679.13 MWD +IFR -MS 5100.00 48.74 134.76 4717.39 4644.39 1124.83 - 562.83 975.23 4.00 5939839.84 699735.49 MWD +IFR -Iy1S 5189.97 50.08 139.16 4775.95 4702.95 1190.98 - 612.76 1021.82 4.00 5939791.16 699783.38 End Dir : 51 39 5200.00 50.08 139.16 4782.39 4709.39 1198.34 - 618.58 1026.85 0.00 5939785.47 699788.56 MWD +IFR +MS 5300.00 50.08 139.16 4846.57 4773.57 1271.85 - 676.60 1076.99 0.00 5939728.80 699840.21 MWD +IFR +MS 5400.00 50.08 139.16 4910.74 4837.74 1345.35 - 734.62 1127.14 0.00 5939672.12 699891.87 MWD +IFR +NIS 5430.00 50.08 139.16 4930.00 4857.00 1367.41 - 752.03 1142.19 0.00 5939655.12 699907.37 UG3 5500.00 50.08 139.16 4974.92 4901.92 1418.86 - 792.64 1177.29 0.00 5939615.45 699943.52 MWD +IFR +MS 5600.00 50.08 139.16 5039.10 4966.10 1492.36 - 850.66 1227.43 0.00 5939558.77 699995.18 MWD +IFR +MS 5700.00 50.08 139.16 5103.28 5030.28 1565.87 - 908.69 1277.58 0.00 5939502.09 700046.83 MWD +IFR +fy1S 5800.00 50.08 139.16 5167.46 5094.46 1639.37 - 966.71 1327.72 0.00 5939445.42 700098.49 MWD +IFR +ly1S 5900.00 50.08 139.16 5231.64 5158.64 1712.88 - 1024.73 1377.87 0.00 5939388.74 700150.14 MWD +IFR -MS 6000.00 50.08 139.16 5295.81 5222.81 1786.38 - 1082.75 1428.02 0.00 5939332.06 700201.80 MWD +IFR +MS 6100.00 50.08 139.16 5359.99 5286.99 1859.89 - 1140.77 1478.16 0.00 5939275.39 700253.46 MWD +IFRTMS 6200.00 50.08 139.16 5424.17 5351.17 1933.39 - 1198.80 1528.31 0.00 5939218.71 700305.11 MWD +IFR +MS 6300.00 50.08 139.16 5488.35 5415.35 2006.90 - 1256.82 1578.45 0.00 5939162.03 700356.77 MWD +IFR +1111S 6400.00 50.08 139.16 5552.53 5479.53 2080.40 - 1314.84 1628.60 0.00 5939105.36 700408.42 MWD +IFR +MS 6500.00 50.08 139.16 5616.71 5543.71 2153.90 - 1372.86 1678.75 0.00 5939048.68 700460.08 MWD +IFR +1111S 6578.37 50.08 139.16 5667.00 5594.00 2211.51 - 1418.33 1718.04 0.00 5939004.26 700500.56 UG1 6600.00 50.08 139.16 5680.88 5607.88 2227.41 - 1430.88 1728.89 0.00 5938992.00 700511.73 MWD +IFR -ly1S 6700.00 50.08 139.16 5745.06 5672.06 2300.91 - 1488.91 1779.04 0.00 5938935.33 700563.39 MWD +IF - ly1S 6800.00 50.08 139.16 5809.24 5736.24 2374.42 - 1546.93 1829.18 0.00 5938878.65 700615.04 MWD +IFR +fy1S 6900.00 50.08 139.16 5873.42 5800.42 2447.92 - 1604.95 1879.33 0.00 5938821.97 700666.70 MWD +IFR +MS 7000.00 50.08 139.16 5937.60 5864.60 2521.43 - 1662.97 1929.47 0.00 5938765.30 700718.35 MWD +IFR +MS 7100.00 50.08 139.16 6001.78 5928.78 2594.93 - 1720.99 1979.62 0.00 5938708.62 700770.01 MWD +IFR +MS 7200.00 50.08 139.16 6065.95 5992.95 2668.44 - 1779.01 2029.77 0.00 5938651.94 700821.66 MWD +IFR +ly1S • Sperry-Sun i BP Planning Report Company: BP Amoco Date: 5/16/2006 Time: 14 :34:20 Page: 3 Field: Prudhoe Bay Co- ordinate(NE) Reference: Weil: 01 -05, True North Site: PB DS 01 Vertical (TVD) Reference: 8 : 05 3/7/1992 00:00 73.0 Well: 01-05 Section(VS) Reference: Well (0.00N,0.00E,122.60Azi) Weilpath: Plan 1 -05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Ind Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Com - nent ft deg deg ft ft ft ft ft deg/100ft ft ft 7300.00 50.08 139.16 6130.13 6057.13 2741.94 - 1837.04 2079.91 0.00 5938595.27 700873.32 MWD +1FR +MS 7357.45 50.08 139.16 6167.00 6094.00 2784.17 - 1870.37 2108.72 0.00 5938562.71 700902.99 WS2 7400.00 50.08 139.16 6194.31 6121.31 2815.45 - 1895.06 2130.06 0.00 5938538.59 700924.97 MWD +IFR +PIS 7500.00 50.08 139.16 6258.49 6185.49 2888.95 - 1953.08 2180.20 0.00 5938481.91 700976.63 MWD +IFR +411S 7600.00 50.08 139.16 6322.67 6249.67 2962.46 - 2011.10 2230.35 0.00 5938425.24 701028.29 MWD +IFR +MS 7700.00 50.08 139.16 6386.84 6313.84 3035.96 - 2069.12 2280.50 0.00 5938368.56 701079.94 MWD +IFR +MS 7740.75 50.08 139.16 6413.00 6340.00 3065.92 - 2092.77 2300.93 0.00 5938345.46 701100.99 WS1 7800.00 50.08 139.16 6451.02 6378.02 3109.47 - 2127.15 2330.64 0.00 5938311.89 701131.60 MWD +IFR +MS 7900.00 50.08 139.16 6515.20 6442.20 3182.97 - 2185.17 2380.79 0.00 5938255.21 701183.25 MWD +IFR +MS 8000.00 50.08 139.16 6579.38 6506.38 3256.47 - 2243.19 2430.93 0.00 5938198.53 701234.91 MWD +IFR +MS 8100.00 50.08 139.16 6643.56 6570.56 3329.98 - 2301.21 2481.08 0.00 5938141.86 701286.56 MWD +IFR +MS 8136.53 50.08 139.16 6667.00 6594.00 3356.83 - 2322.41 2499.40 0.00 5938121.15 701305.43 CM3 8200.00 50.08 139.16 6707.74 6634.74 3403.48 - 2359.23 2531.23 0.00 5938085.18 701338.22 MWD +IFR -MS 8300.00 50.08 139.16 6771.91 6698.91 3476.99 - 2417.26 2581.37 0.00 5938028.50 701389.87 MWD +IFR +MS 8400.00 50.08 139.16 6836.09 6763.09 3550.49 - 2475.28 2631.52 0.00 5937971.83 701441.53 MWD +IFR +MS 8500.00 50.08 139.16 6900.27 6827.27 3624.00 - 2533.30 2681.66 0.00 5937915.15 701493.18 MWD +IFR -1S 8600.00 50.08 139.16 6964.45 6891.45 3697.50 - 2591.32 2731.81 0.00 5937858.47 701544.84 MWD +IFR -MS 8700.00 50.08 139.16 7028.63 6955.63 3771.01 - 2649.34 2781.96 0.00 5937801.80 701596.49 MWD +IFR +MS 8800.00 50.08 139.16 7092.81 7019.81 3844.51 - 2707.36 2832.10 0.00 5937745.12 701648.15 MWD +IFR +MS 8900.00 50.08 139.16 7156.98 7083.98 3918.02 - 2765.39 2882.25 0.00 5937688.44 701699.80 MWD +IFR -MS 8924.96 50.08 139.16 7173.00 7100.00 3936.36 - 2779.87 2894.76 0.00 5937674.30 701712.70 CM2 9000.00 50.08 139.16 7221.16 7148.16 3991.52 - 2823.41 2932.39 0.00 5937631.77 701751.46 MWD +IFR +MS 9100.00 50.08 139.16 7285.34 7212.34 4065.03 - 2881.43 2982.54 0.00 5937575.09 701803.12 MWD +IFR +MS 9200.00 50.08 139.16 7349.52 7276.52 4138.53 - 2939.45 3032.68 0.00 5937518.41 701854.77 MWD +IFR +MS 9300.00 50.08 139.16 7413.70 7340.70 4212.04 - 2997.47 3082.83 0.00 5937461.74 701906.43 MWD +IFR +MS 9400.00 50.08 139.16 7477.88 7404.88 4285.54 - 3055.50 3132.98 0.00 5937405.06 701958.08 MWD +IFR +MS 9500.00 50.08 139.16 7542.05 7469.05 4359.04 - 3113.52 3183.12 0.00 5937348.38 702009.74 MWD +IFR -MS 9600.00 50.08 139.16 7606.23 7533.23 4432.55 - 3171.54 3233.27 0.00 5937291.71 702061.39 MWD +IFR -MS 9700.00 50.08 139.16 7670.41 7597.41 4506.05 - 3229.56 3283.41 0.00 5937235.03 702113.05 MWD +IFR -MS 9800.00 50.08 139.16 7734.59 7661.59 4579.56 - 3287.58 3333.56 0.00 5937178.36 702164.70 MWD +IFR -MS 9900.00 50.08 139.16 7798.77 7725.77 4653.06 - 3345.61 3383.71 0.00 5937121.68 702216.36 MWD +IFR +MS 10000.00 50.08 139.16 7862.94 7789.94 4726.57 - 3403.63 3433.85 0.00 5937065.00 702268.01 MWD +IFR +MS 10100.00 50.08 139.16 7927.12 7854.12 4800.07 - 3461.65 3484.00 0.00 5937008.33 702319.67 MWD +IFR +MS 10200.00 50.08 139.16 7991.30 7918.30 4873.58 - 3519.67 3534.14 0.00 5936951.65 702371.32 MWD +IFR +MS 10300.00 50.08 139.16 8055.48 7982.48 4947.08 - 3577.69 3584.29 0.00 5936894.97 702422.98 MWD +IFR +MS 10400.00 50.08 139.16 8119.66 8046.66 5020.59 - 3635.71 3634.44 0.00 5936838.30 702474.63 MWD +IFR +MS 10414.56 50.08 139.16 8129.00 8056.00 5031.29 - 3644.16 3641.74 0.00 5936830.05 702482.15 CM1 10500.00 50.08 139.16 8183.84 8110.84 5094.09 - 3693.74 3684.58 0.00 5936781.62 702526.29 MWD +IFR -MS 10507.13 50.08 139.16 8188.41 8115.41 5099.33 - 3697.87 3688.16 0.00 5936777.58 702529.97 Start Dir 4/' f 0 10510.80 50.00 139.00 8190.77 8117.77 5102.03 - 3700.00 3690.00 4.00 5936775.50 702531.87 MWD +IFR +MS 10531.61 50.82 138.85 8204.03 8131.03 5117.42 - 3712.09 3700.53 4.00 5936763.70 702542.72 End Dir : 1053 10600.00 50.82 138.85 8247.23 8174.23 5168.32 - 3752.01 3735.43 0.00 5936724.71 702578.65 MWD +IFR -MS 10700.00 50.82 138.85 8310.40 8237.40 5242.74 - 3810.38 3786.44 0.00 5936667.71 702631.18 MWD +IFR +MS 10707.27 50.82 138.85 8315.00 8242.00 5248.16 - 3814.62 3790.15 0.00 5936663.57 702635.01 THRZ 10800.00 50.82 138.85 8373.58 8300.58 5317.17 - 3868.74 3837.46 0.00 5936610.71 702683.72 MWD +IFR +MS 10900.00 50.82 138.85 8436.75 8363.75 5391.59 - 3927.11 3888.47 0.00 5936553.71 702736.25 MWD +IFR +MS 10938.39 50.82 138.85 8461.00 8388.00 5420.16 - 3949.52 3908.06 0.00 5936531.83 702756.42 BHRZ 11000.00 50.82 138.85 8499.92 8426.92 5466.01 - 3985.48 3939.49 0.00 5936496.71 702788.78 MWD +IFR +MS 11001.71 50.82 138.85 8501.00 8428.00 5467.29 - 3986.48 3940.36 0.00 5936495.74 702789.68 TJC 11015.96 50.82 138.85 8510.00 8437.00 5477.89 - 3994.80 3947.63 0.00 5936487.62 702797.17 TJB 11100.00 50.82 138.85 8563.09 8490.09 5540.44 - 4043.85 3990.50 0.00 5936439.71 702841.32 MWD +IFR -MS 11118.69 50.82 138.85 8574.90 8501.90 5554.35 - 4054.76 4000.04 0.00 5936429.06 702851.14 Start Dir 4/'. C 0 11129.99 51.28 138.85 8582.00 8509.00 5562.78 - 4061.38 4005.82 4.00 5936422.60 702857.09 TJA Sperry-Sun BP Planning Report Company: BP Amoco Date: 5/16/2006 Time: 14:3420 Page: 4 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01 -05, True North Site: PB DS 01 Vertical (TVD) Reference: 8:05 3/7/1992 00:00 73.0 Well: 01 -05 Section (VS) Reference: Well (0.00N,0.00E,122.60Azi) Wellpath: Plan 1-05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Iuel Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Corment ft deg deg ft ft ft ft ft deg/100ft ft ft 11200.00 54.08 138.90 8624.44 8551.44 5616.22 - 4103.31 4042.43 4.00 5936381.64 702894.79 MWD +IFR - 11S 11295.77 57.91 138.97 8678.00 8605.00 5692.38 - 4163.16 4094.56 4.00 5936323.20 702948.48 TSGR 11300.00 58.08 138.97 8680.24 8607.24 5695.83 - 4165.86 4096.92 4.00 5936320.55 702950.91 MWD +IFR *MS 11348.12 60.00 139.00 8705.00 8632.00 5735.41 - 4197.00 4124.00 4.00 5936290.14 702978.80 7" 11354.12 60.00 139.00 8708.00 8635.00 5740.40 - 4200.92 4127.41 0.00 5936286.31 702982.31 TSHA 11368.12 60.00 139.00 8715.00 8642.00 5752.03 - 4210.07 4135.36 0.00 5936277.38 702990.50 Start Dir 24/' 0 11400.00 67.65 139.01 8729.05 8656.05 5779.45 - 4231.65 4154.12 24.00 5936256.30 703009.82 MWD +IFR +MS 11500.00 91.65 139.02 8746.89 8673.89 5873.13 - 4305.36 4218.17 24.00 5936184.31 703075.79 MWD +IFR +MS 11524.10 97.44 139.02 8744.98 8671.98 5896.16 - 4323.50 4233.92 24.00 5936166.60 703092.01 End Dir : 11 52 11600.00 97.44 139.02 8735.15 8662.15 5968.35 - 4380.31 4283.27 0.00 5936111.10 703142.84 MWD +IFR +MS 11700.00 97.44 139.02 8722.21 8649.21 6063.46 - 4455.17 4348.30 0.00 5936037.99 703209.81 MWD +IFR -MS 11796.65 97.44 139.02 8709.71 8636.71 6155.38 - 4527.52 4411.14 0.00 5935967.32 703274.54 Start Dir 10/10 11800.00 97.10 139.02 8709.28 8636.28 6158.58 - 4530.03 4413.32 10.00 5935964.87 703276.79 MWD +IFR -MS 11859.70 91.13 139.00 8705.00 8632.00 6215.67 - 4574.96 4452.36 10.00 5935920.99 703317.00 1 -05B T1 11900.00 91.15 134.97 8704.20 8631.20 6254.69 - 4604.42 4479.84 10.00 5935892.27 703345.24 MWD +IFR -MS 12000.00 91.17 124.97 8702.17 8629.17 6353.72 - 4668.56 4556.37 10.00 5935830.17 703423.43 MWD +IFR i 1S 12100.00 91.16 114.97 8700.12 8627.12 6453.46 - 4718.43 4642.88 10.00 5935782.60 703511.21 MWD +IFR -MS 12158.28 91.14 109.14 8698.95 8625.95 6510.72 - 4740.30 4696.86 10.00 5935762.16 703565.75 End Dir : 1215 12200.00 91.14 109.14 8698.12 8625.12 6551.29 - 4753.97 4736.27 0.00 5935749.54 703605.50 MWD +IFR +MS 12300.00 91.14 109.14 8696.14 8623.14 6648.52 - 4786.75 4830.72 0.00 5935719.26 703700.78 MWD +IFR+ S 12388.27 91.14 109.14 8694.38 8621.38 6734.35 - 4815.68 4914.10 0.00 5935692.54 703784.89 Start Dir 6/' C 0 12400.00 91.17 108.43 8694.15 8621.15 6745.74 - 4819.45 4925.20 6.00 5935689.06 703796.09 MWD +IFR +MS 12407.22 91.19 108.00 8694.00 8621.00 6752.73 - 4821.71 4932.05 6.00 5935686.99 703803.00 1 -05B T2 12500.00 91.23 102.43 8692.04 8619.04 6841.22 - 4846.05 5021.53 6.00 5935665.02 703893.08 MWD +IFR +MS 12600.00 91.26 96.43 8689.87 8616.87 6933.09 - 4862.42 5120.11 6.00 5935651.25 703992.05 MWD +IFR +MS 12683.64 91.28 91.41 8688.02 8615.02 7006.43 - 4868.14 5203.50 6.00 5935647.74 704075.56 End Dir : 12 58 12700.00 91.28 91.41 8687.65 8614.65 7020.43 - 4868.54 5219.86 0.00 5935647.76 704091.92 MWD +IFR +MS 12800.00 91.28 91.41 8685.42 8612.42 7105.96 - 4871.00 5319.80 0.00 5935647.94 704191.89 MWD +IFR -MS 12900.00 91.28 91.41 8683.19 8610.19 7191.48 - 4873.46 5419.75 0.00 5935648.11 704291.86 MWD +IFR +MS 13000.00 91.28 91.41 8680.96 8607.96 7277.01 - 4875.93 5519.69 0.00 5935648.29 704391.83 MWD +IFR -MS 13082.20 91.28 91.41 8679.13 8606.13 7347.32 - 4877.95 5601.84 0.00 5935648.43 704474.00 Start Dir 4/1 C 0 13100.00 91.05 90.74 8678.77 8605.77 7362.49 - 4878.28 5619.64 4.00 5935648.56 704491.80 MWD +IFR -MS 13183.29 90.00 87.57 8678.00 8605.00 7431.98 - 4877.05 5702.90 4.00 5935651.99 704575.00 1 -05B T3 13200.00 89.33 87.59 8678.10 8605.10 7445.66 - 4876.35 5719.60 4.00 5935653.13 704591.67 MWD +IFR +MS 13223.32 88.40 87.61 8678.56 8605.56 7464.76 - 4875.37 5742.89 4.00 5935654.72 704614.92 End Dir : 13 ?2 13300.00 88.40 87.61 8680.70 8607.70 7527.55 - 4872.17 5819.48 0.00 5935659.94 704691.39 MWD +IFR +MS 13400.00 88.40 87.61 8683.49 8610.49 7609.45 - 4867.99 5919.35 0.00 5935666.75 704791.12 MWD +IFR +MS 13500.00 88.40 87.61 8686.29 8613.29 7691.34 - 4863.82 6019.22 0.00 5935673.56 704890.84 MWD +IFR +MS 13600.00 88.40 87.61 8689.08 8616.08 7773.23 - 4859.64 6119.10 0.00 5935680.37 704990.56 MWD +IFR +MS 13700.00 88.40 87.61 8691.88 8618.88 7855.12 - 4855.46 6218.97 0.00 5935687.18 705090.29 MWD +IFR +MS 13800.00 88.40 87.61 8694.67 8621.67 7937.01 - 4851.29 6318.85 0.00 5935693.98 705190.01 MWD +IFR +MS 13900.00 88.40 87.61 8697.46 8624.46 8018.91 - 4847.11 6418.72 0.00 5935700.79 705289.73 MWD +IFR +MS 14000.00 88.40 87.61 8700.26 8627.26 8100.80 - 4842.93 6518.59 0.00 5935707.60 705389.46 MWD +IFR +MS 14037.99 88.40 87.61 8701.32 8628.32 8131.91 - 4841.34 6556.54 0.00 5935710.19 705427.34 Start Dir 4/1( 0 14086.80 90.00 86.49 8702.00 8629.00 8171.62 - 4838.83 6605.28 4.00 5935713.99 705476.00 1 -05B T4 14090.07 90.13 86.49 8702.00 8629.00 8174.26 - 4838.63 6608.53 4.00 5935714.27 705479.25 End Dir : 14 )9 14100.00 90.13 86.49 8701.97 8628.97 8182.28 - 4838.02 6618.45 0.00 5935715.14 705489.14 MWD +IFR 14200.00 90.13 86.49 8701.75 8628.75 8263.07 - 4831.89 6718.26 0.00 5935723.90 705588.75 MWD +IFR +MS 14300.00 90.13 86.49 8701.52 8628.52 8343.86 - 4825.77 6818.07 0.00 5935732.65 705688.36 MWD +IFR+ S 14400.00 90.13 86.49 8701.29 8628.29 8424.65 - 4819.64 6917.88 0.00 5935741.41 705787.97 MWD +IFR +MS 14500.00 90.13 86.49 8701.06 8628.06 8505.44 - 4813.51 7017.70 0.00 5935750.16 705887.58 MWD +IFR +MS 14600.00 90.13 86.49 8700.83 8627.83 8586.23 - 4807.39 7117.51 0.00 5935758.92 705987.19 MWD +IFR +MS Sperry -Sun • BP Planning Report Company: BP Amoco Date: 5/16/2006 Time: 14:34:20 Page: 5 Field: Prudhoe Bay Co- ordinate(NE) Reference: Well: 01-05, True North Site: PB DS 01 Vertical (TVD) Reference: 8:05 3/7/1992 00:00 73.0 Well: 01 -05 Section (VS) Reference: Well (0.00N,0.00E,122.60Azi) Wellpath: Plan 1 -05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Ind Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft ft deg/100ft ft ft 14700.00 90.13 86.49 8700.61 8627.61 8667.02 - 4801.26 7217.32 0.00 5935767.67 706086.80 MWD +IFR +MS 14800.00 90.13 86.49 8700.38 8627.38 8747.81 - 4795.13 7317.13 0.00 5935776.43 706186.41 MWD +IFR +MS 14900.00 90.13 86.49 8700.15 8627.15 8828.60 - 4789.01 7416.94 0.00 5935785.19 706286.02 MWD +IFR +MS 14966.00 90.13 86.49 8700.00 8627.00 8881.92 - 4784.96 7482.82 0.00 5935790.96 706351.77 4 1/2" 14966.23 90.13 86.49 8700.00 8627.00 8882.11 - 4784.95 7483.05 0.00 5935790.98 706352.00 1 -05B T5 • • . Sperry-Sun err Sun P Y Anticollision Report Company: BP Amoco Date: 5/16/2006 Time: 14:37:21 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 01 Co- ordinate(NE) Reference: Well: 01 -05, True North Reference Well: 01 -05 Vertical (TVD) Reference: 8:05 3/7/1992 00:00 73.0 Reference Welipath: Plan 1 -05A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100 /1000 of reference - There are Taiiidiiieezlls in this fi2lillcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 4700.00 to 14966.23 ft Scan Method: Tray Cylinder North Maximum Radius: 1693.32 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 3/29/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 100.00 4700.00 1 : Camera based mag multi sho (100.00- 987EBEly1(®G -MS Camera based mag multi shot 4700.00 14966.23 Planned: 1 -05A Wp07 V63 MWD +IFR +MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 11348.12 8705.00 7.000 8.500 7" 14966.00 8700.00 4.500 6.125 4 1/2" Summary < Offset Wellpath > Reference Offset Ctr -Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 01 01 -01 01 -01 V2 4700.00 4925.00 712.97 161.71 551.26 Pass: Major Risk PB DS 01 01 -01A Plan 1 -01C VO Plan: 01 7890.29 8950.00 192.05 172.94 19.12 Pass: Major Risk PB DS 01 01 -01B Plan 01 -01C VO Plan: 1 14888.38 16125.00 632.38 358.83 273.54 Pass: Major Risk PB DS 01 01 -02 01 -02 V2 Out of range PB DS 01 01 -03 01 -03 V2 Out of range PB DS 01 01 -03A 01 -03A V1 Out of range PB DS 01 01 -04 01 -04 V2 4700.00 5550.00 1574.13 101.41 1472.72 Pass: Major Risk PB DS 01 01 -04 01 -04A V7 4700.00 5550.00 1574.13 101.41 1472.71 Pass: Major Risk PB DS 01 01 -05 01 -05 V1 4700.00 4700.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 01 01 -05PB1 01 -05PB1 V3 4700.00 4700.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 01 01 -06 01 -06 V1 4703.98 5075.00 917.12 175.02 742.10 Pass: Major Risk PB DS 01 01 -06A 01 -06A V1 4703.98 5075.00 917.12 175.02 742.10 Pass: Major Risk PB DS 01 01 -07 01 -07 V3 Out of range PB DS 01 01 -07A 01 -07A V1 Out of range PB DS 01 01 -08 01 -08 V4 4700.51 4550.00 253.16 128.85 124.30 Pass: Major Risk PB DS 01 01 -08 01 -08A V3 Out of range PB DS 01 01 -08 1- 08APB1 V14 Out of range PB DS 01 01 -09 01 -09 V2 4907.82 4625.00 347.32 140.43 206.88 Pass: Major Risk PB DS 01 01 -09A 01 -09A V1 4907.82 4625.00 347.32 140.43 206.88 Pass: Major Risk PB DS 01 01 -11 01 -11 V2 7718.88 7875.00 993.42 467.85 525.56 Pass: Major Risk PB DS 01 01 -12 01 -12 V3 4839.55 5325.00 455.94 195.11 260.83 Pass: Major Risk PB DS 01 01 -12 01 -12A V3 4839.55 5325.00 455.94 195.11 260.83 Pass: Major Risk PB DS 01 01 -26 01 -26 V1 7395.21 7975.00 901.15 443.85 457.30 Pass: Major Risk PB DS 01 01 -26A 01 -26A V3 7395.21 7975.00 901.15 443.85 457.30 Pass: Major Risk PB DS 01 01 -28 01 -28 V1 4701.38 4625.00 371.95 176.77 195.18 Pass: Major Risk PB DS 01 01 -29 01 -29 V7 4705.54 5000.00 849.41 95.64 753.77 Pass: Major Risk PB DS 01 01 -30 01 -30 V1 4764.08 5325.00 1577.48 142.41 1435.07 Pass: Major Risk PB DS 01 01 -30 Plan 01 -30a V3 Plan: 0 4764.08 5325.00 1577.48 142.52 1434.96 Pass: Major Risk PB DS 01 01 -31 01 -31 V1 4723.65 4750.00 548.29 127.08 421.21 Pass: Major Risk PB DS 01 01 -34 01 -34 V1 4750.13 4825.00 793.56 119.29 674.26 Pass: Major Risk PB DS 03 03 -16 03 -16 V1 14894.51 12400.00 488.22 1477.55 - 989.33 FAIL: Major Risk PB DS 03 03 -16A 03 -16A V1 14888.85 12400.00 501.32 1493.70 - 992.39 FAIL: Major Risk PB DS 03 03 -19 03 -19 V1 Out of range PB DS 03 03 -24 03 -24 V1 12812.14 12850.00 804.64 1887.66 - 1083.02 FAIL: Major Risk PB DS 03 03 -24A 03 -24A V1 12406.45 13225.00 627.93 1755.04 - 1127.10 FAIL: Major Risk PB DS 12 12 -02 12 -02 V5 12672.63 12225.00 630.72 1333.13 - 702.41 FAIL: Major Risk PB DS 12 12 -05 Plan 12 -05A VO Plan: 1 12124.17 12425.00 1076.14 398.42 677.72 Pass: Major Risk PB DS 12 12 -28 12 -28 V1 11447.73 12125.00 557.93 300.00 257.93 Pass: Major Risk PB DS 12 12 -28A 12 -28A V2 11279.71 12075.00 674.18 420.34 253.84 Pass: Major Risk PB DS 12 12 -32 12 -32 V1 14307.62 12925.00 658.19 373.24 284.95 Pass: Major Risk • Terri L. Hubble 89- 6/1252 328 BP Exploration AK Inc. "Mastercard Check" PO Box 196612 MB 7 -5 Anchorage, AK 99519 O�f -0 7 DATE PAY TO THE ORDER OF I � i • Al_ • ' • 1110 1....,11401ANSW D • " First National Bank Alaska Anchorage, AK 99501 MEMO 01 • VS f } /4 L r .11 %,„,11# 1:L252000601:99L4622?L5560 0 328 Alaska Department of Natural Resources Land Administration System Page 1 of 2 MPet Land Records/Status Plats Recorders Search State Cabins Natural Resources Alaska DNR Case Summary File Type: FADL File Number:1 28328 a Printable Case File Summary See Township, Range, Section and Acreage? New Search r■ Yes r No LAS Menu 1 Case Abstract Case Detail 1 Land Abstract Fite: ADL 28328 Fitie, Search for Status Plat Updates As of 04/05/2007 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA ASSIGNMENT APPROVED Meridian: U Township: 01 ON Range: 015E Section: 03 Section Acres: 640 Search Plats Meridian: U Township: 010N Range: 015E Section: 04 Section Acres: 640 Meridian: U Township: 01 ON Range: 015E Section: 09 Section Acres: 640 Meridian: U Township: 010N Range: 015E Section: 10 Section Acres: 640 Legal Description 05-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14-158 T1ON-R15E-UM 3,4,9,10 2560.00 U- 3- 7 07-06-1987 * * * LISB URNE PARTICIPATING AREA LEGAL DESCRIPTION * * * T 10N., R. 15E., UM SECTION 3: ALL 640 ACRES SECTION 4: ALL 640 ACRES http://wvvw.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber= 4/5/2007 • TRANSMITTAL LETTER CHECKLIST WELL NAME / OA 05; PTD# v?D 704 ✓ Development Service Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK i ADD -ONS ! TEXT FOR APPROVAL LETTER WHAT ! (OPTIONS) APPLIES I , � I MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- API number are ; " between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE i In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both ! well name ( PH) and API number I ' ( - - ) from records, data and logs acquired for well , f SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ! 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the- Commission must be in ! ! SAMPLE i no greater than 30' sample intervals from below the permafrost or ! I from where samples are first caught and 10' sample intervals through target zones. Please note the following . special condition of this permit: i Non - Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the ! Commission to obtain advance approval of such water well testing program. Rev: 115/06 C: ` jody'transmittal_checkl ist f ., i Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 01 -05B Program DEV Well bore seg PTD #: 2070480 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached - - Yes - - - - 2 Lease number appropriate - Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes PRUDHOE BAY FIELD - PRUDHOE BAY POOL 5 Well located proper distance from drilling unit boundary - Yes 6 Well located proper distance from other wells Yes - - - - - 7 Sufficient acreage available in drilling unit - Yes 8 _If deviated, is wellbore plat included - - Yes 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes #6194193 BLANKET BOND 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval - Yes - - - - ACS 4/5/2007 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre- production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1_.A),(j.2.A -D) No Engineering 18 Conductor string provided NA - - Conductor set_ in original well, DS 01 -05 (170 -040). - - - 19 Surface casing protects all known USDWs NA - - Surface casing set in DS 01 -05. 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set in DS 01 -05. 21 CMT_vol adequate to tie -in long string to surf csg NA Production casing set in DS 01 -05. 22 CMT will cover all known productive horizons No Slotted liner completion planned. i23 Casing designs adequate for C, T, B & permafrost Yes - 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well(s). 25 If a re- drill, has a 10-403 for abandonment been approved Yes 307 -116 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Close approaches identified. 27 If diverter required, does it meet regulations NA BOP stack will already be in place. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected formation pressure 7.2 EMW. Planned MW up to 11.6 ppg in 8.5" hole and 8.5 ppg in zone. TEM 4/24/2007 29 BOPEs, do they meet regulation Yes Ighti 30 BOPE press rating appropriate; test to (put p$ig in comments) Yes MASP calculated at 2380 psi. 4000 psi proposed due to planned casing tests. • 31 Choke manifold complies w /API RP -53 May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes DS 1 is and H2S site. Mud should preclude H2S on rig. Rig is equipped with sensors and alarms._ 34 Mechanical condition of wells within AOR verified (For service well only) NA Geology 35 Permit can be issued w/o hydrogen sulfide measures No DS -01 IS A HIGH LEVEL H2S SITE WELL 12- 13B= 1OPPM;WELL 01- 34= 40PPM. - '36 Data_presented on potential overpressure zones NA_ Appr Date 37 Seismic analysis of shallow gas zones NA ACS 4/5/2007 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] Yes Phil Smith-564-4897, Jim N_igh -564 -5220. Geologic Engineering P •lic Commissioner: Date: Commissioner: Date i-. • of Date Or er • • 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. r + 411 S 01- 05b.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 19 14:23:51 2009 Reel Header Service name LISTPE Date 09/03/19 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 09/03/19 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD /MAD LOGS WELL NAME: 01 -05B API NUMBER: 500292007602 OPERATOR: BP Exploration (Alaska) LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 19- MAR -09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW- 000624716 MW- 000624716 Mw - 000624716 LOGGING ENGINEER: T. ONYEKWELU T. ONYEKWELU J. PEREZ OPERATOR WITNESS: D. MASKELL B. DECKER B. DECKER MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: Mw 000624716 Mw 000624716 MW 000624716 LOGGING ENGINEER: J. PEREZ J. PEREZ J. PEREZ OPERATOR WITNESS: B. DECKER B. DECKER D. MASKELL MWD RUN 7 JOB NUMBER: MW- 000624716 LOGGING ENGINEER: T. ONYEKWELU OPERATOR WITNESS: D. MASKELL SURFACE LOCATION SECTION: 8 Page 1 S 01- 05b.tapx TOWNSHIP: 10N RANGE: 15E FNL: FSL: 4732 FEL: 3860 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 67.80 GROUND LEVEL: 39.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 4690.0 2ND STRING 6.125 7.000 10381.0 3RD STRING .000 .0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 4690 FT MD, 4434 FT TVD. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND A BIT OF RAT HOLE DRILLED DURING MWD RUN 1. TIE -IN GAMMA RAY DATA PRESENTED. EWR PHASE -4 DID NOT EXIT CASING - NO EWR DATA PRESENTED. 4. MWD RUN 1 -2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGERMUELLER TUBE DETECTORS, DRILLSTRING DYANMICS SENSOR (DDSr), PRESSURE WHILE DRILLING (PWD), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR PHASE -4). 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGERMUELLER TUBE DETECTORS, DRILLSTRING DYANMICS SENSOR (DDSr), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR PHASE -4). 6. MWD RUN 4 -7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4, DRILLSTRING DYNAMICS SENSOR (DDSr), COMPENSATED THERMAL NEUTRON (CTN), AND AZIMUTHAL LITHO DENSITY (ALD). 7. POROSITY AND DENSITY DATA FROM 10381 FT MD, 8653 FT TVD TO 10638 FT MD, 8714 FT TVD ACQUIRED ON A MEASUREMENT AFTER Page 2 ! • 01- 05b.tapx DRILLING (MAD) PASS PRIOR TO DRILLING ON MWD RUN 4. 8. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E -MAIL FROM DOUGLAS DORTCH (SIAC /BP) DATED 06- MARCH -2009, QUOTING AUTHORIZATION FROM PRIYA MARAJ (BP). MWD DATA ARE CONSIDERED PDC1 FOR WELL 01 -058. 9. MWD RUNS 1 -7 REPRESENT WELL 01 -058 WITH API #: 50- 029 - 20076 -02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14296'MD, 8712'TVD. SROP = RATE OF PENETRATION WHILE DRILLING. SGRC = GAMMA RAY COMBINED. SEXP = PHASE SHIFT - DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = PHASE SHIFT- DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = PHASE SHIFT- DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = PHASE SHIFT - DERIVED RESISTIVITY (DEEP SPACING). SFXE = FORMATION EXPOSURE TIME FOR RESISTIVITY SENSOR. TNPS = THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = BULK DENSITY- COMPENSATED (LOW -COUNT RATE BIN). SCO2 = STANDOFF CORRECTION (LOW -COUNT RATE BIN). SNP2 = PHOTOELECTRIC ABSORPTION FACTOR (LOW -COUNT RATE BIN). LOG MARKERS: DENSLIDE = INDICATES INTERVALS OF NON - DRILLSTRING ROTATION REFERENCED TO DENSITY SENSOR DEPTH. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED 6 1/8" NOMINAL MUD WEIGHT: 8.4- 8.6 PPG MUD SALINITY: 1,200 - 5,000 PPM CHLORIDES MUD TYPE: WATER BASED FORMATION WATER SALINITY: 11,500 PPM CHLORIDES FLUID DENSITY: 1.0 G /CC MATRIX DENSITY: 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record Page 3 I 01- 05b.tapx 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 4305.0 14233.5 FET 4680.5 14241.0 RPX 4680.5 14241.0 RPM 4680.5 14241.0 RPD 4680.5 14240.5 ROP 4690.0 14296.5 PEF 10371.5 14221.0 NPHI 10371.5 14206.0 DRHO 10371.5 14221.0 RHOB 10371.5 14221.0 NCNT 10371.5 14206.0 FCNT 10371.5 14206.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 4305.0 4733.0 MWD 2 4733.0 10382.0 MWD 3 10382.0 10639.0 MWD 4 10639.0 11379.0 MWD 5 11379.0 11389.0 MWD 6 11389.0 12932.0 MWD 7 12932.0 14296.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name service Order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CPS 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPX MWD OHMM 4 1 68 28 8 Page 4 III 111 01- 05b.tapx FET MWD HR 4 1 68 32 9 GR MWD API 4 1 68 36 10 PEF MWD B/E 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 NPHI MWD PU 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4305 14296.5 9300.75 19984 4305 14296.5 FCNT MWD CP30 133.14 2389.99 627.354 7670 10371.5 14206 NCNT MWD CPS 500.26 45292.3 26596.4 7670 10371.5 14206 RHOB MWD G /CC 1.462 3.405 2.35482 7700 10371.5 14221 DRHO MWD G /CC -1.284 0.887 0.0707681 7700 10371.5 14221 RPD MWD OHMM 0.23 2000 16.4209 19035 4680.5 14240.5 RPM MWD OHMM 0.07 2000 12.6483 19036 4680.5 14241 RPX MWD OHMM 0.11 2000 9.69886 19036 4680.5 14241 FET MWD HR 0.16 138.85 2.42492 19036 4680.5 14241 GR MWD API 5.86 549.96 100.074 19858 4305 14233.5 PEF MWD B/E 1.48 14.59 2.25158 7700 10371.5 14221 ROP MWD FPH 0.03 976.31 135.504 19214 4690 14296.5 NPHI MWD PU 7.71 132.73 23.6853 7670 10371.5 14206 First Reading For Entire File 4305 Last Reading For Entire File 14296.5 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 4305.0 4663.0 SROP 4690.0 4733.0 Page 5 411 411 $ 01- 05b.tapx LOG HEADER DATA DATE LOGGED: 23- DEC -08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 4733.0 TOP LOG INTERVAL (FT): 4305.0 BOTTOM LOG INTERVAL (FT): 4733.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 253600 EWR4 EWR -Phase 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4690.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 10.50 MUD VISCOSITY (5): 50.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.810 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.510 87.8 MUD FILTRATE AT MT: 1.950 65.0 MUD CAKE AT MT: 1.980 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel Page 6 . . 01- 05b.tapx DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 2 ROP MWD010 FPH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4305 4733 4519 857 4305 4733 GR MWD010 API 23.96 67.68 47.0001 717 4305 4663 ROP MWD010 FPH 1.03 33.42 6.85908 87 4690 4733 First Reading For Entire File 4305 Last Reading For Entire File 4733 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 4663.5 10334.5 SEXP 4680.5 10327.0 SEDP 4680.5 10327.0 SEMP 4680.5 10327.0 SFXE 4680.5 10327.0 SROP 4733.5 10381.5 LOG HEADER DATA DATE LOGGED: 27 - DEC - SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory Page 7 • 01- 05b.tapx TD DRILLER (FT): 10382.0 TOP LOG INTERVAL (FT): 4733.0 BOTTOM LOG INTERVAL (FT): 10382.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.0 MAXIMUM ANGLE: 53.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 253600 EWR4 EWR -Phase 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4690.0 BOREHOLE CONDITIONS MUD TYPE: Fresh water Gel MUD DENSITY (LB /G): 10.50 MUD VISCOSITY (S): 50.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 1700 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.810 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .952 143.0 MUD FILTRATE AT MT: 1.950 65.0 MUD CAKE AT MT: 1.980 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .1IN Max frames per record undefined Absent value -999 Depth Units Datum specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 FET MWD020 HR 4 1 68 16 5 GR MWD020 API 4 1 68 20 6 ROP MWD020 FPH 4 1 68 24 7 Page 8 01- 05b.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4663.5 10381.5 7522.5 11437 4663.5 10381.5 RPD MWD020 OHMM 0.52 2000 6.05959 11294 4680.5 10327 RPM MWD020 OHMM 0.24 2000 4.50232 11294 4680.5 10327 RPX MWD020 OHMM 0.11 2000 3.32303 11294 4680.5 10327 FET MWD020 HR 0.16 32.07 1.20606 11294 4680.5 10327 GR MWD020 API 5.86 448.91 106.232 11343 4663.5 10334.5 ROP MWD020 FPH 0.22 976.31 184.975 11297 4733.5 10381.5 First Reading For Entire File 4663.5 Last Reading For Entire File 10381.5 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 10335.0 10573.5 SEXP 10370.5 10580.5 SESP 10370.5 10580.5 SEMP 10370.5 10580.5 SFXE 10370.5 10580.5 SEDP 10370.5 10580.5 SROP 10382.0 10639.0 LOG HEADER DATA DATE LOGGED: 03- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 Page 9 • 01- 05b.tapx DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 10639.0 TOP LOG INTERVAL (FT): 10382.0 BOTTOM LOG INTERVAL (FT): 10639.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 50.6 MAXIMUM ANGLE: 92.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 948045 EWR4 Slim EWR -Phase 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10381.0 BOREHOLE CONDITIONS MUD TYPE: Fresh water Gel MUD DENSITY (LB /G): 8.50 MUD VISCOSITY (S): 55.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 7000 FLUID LOSS (c3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .650 85.0 MUD AT MAX CIRCULATING TERMPERATURE: .389 146.8 MUD FILTRATE AT MT: .800 85.0 MUD CAKE AT MT: .700 85.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record undefined Absent value -999 Depth units Datum specification Block sub- type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 Page 10 . III 01- 05b.tapx ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10335 10639 10487 609 10335 10639 RPD MWD030 OHMM 0.23 2000 230.276 421 10370.5 10580.5 RPM MWD030 OHMM 0.07 1845.38 145.904 421 10370.5 10580.5 RPS MWD030 OHMM 0.16 1367.2 94.7523 421 10370.5 10580.5 RPX MWD030 OHMM 1.24 1848.24 77.9837 421 10370.5 10580.5 1 FET MWD030 HR 3.21 138.85 13.8599 421 10370.5 10580.5 GR MWD030 API 58.64 535.41 157.1 478 10335 10573.5 ROP MWD030 FPH 0.9 828.87 43.7845 515 10382 10639 First Reading For Entire File 10335 Last Reading For Entire File 10639 File Trailer Service name STSLIB.004 Service sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 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: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SNP2 10371.5 11299.5 CTFA 10371.5 11284.5 CTNA 10371.5 11284.5 SBD2 10371.5 11299.5 SCO2 10371.5 11299.5 TNPS 10371.5 11284.5 SGRC 10574.0 11312.5 SEXP 10581.0 11319.5 SFXE 10581.0 11319.5 SEMP 10581.0 11319.5 SEDP 10581.0 11319.5 Page 11 . 110 411 01- 05b.tapx SESP 10581.0 11319.5 SROP 10639.5 11379.0 LOG HEADER DATA DATE LOGGED: 15 - JAN - SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 11379.0 TOP LOG INTERVAL (FT): 10639.0 BOTTOM LOG INTERVAL (FT): 11379.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 103.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 948045 CTN Thermal Neutron 10603684 EWR4 Slim EWR - Phase 4 148579 ALD Azimuthal Litho -Den 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10381.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.50 MUD VISCOSITY (S): 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .710 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .440 122.0 MUD FILTRATE AT MT: .540 73.0 MUD CAKE AT MT: .900 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record undefined Absent value -999 Page 12 411 411 01- 05b.tapx 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 FCNT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 RHOB MWD040 G /CC 4 1 68 12 4 DRHO MWD040 G /CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MWD040 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10371.5 11379 10875.3 2016 10371.5 11379 FCNT MWD040 CP30 133.14 2389.99 727.847 1827 10371.5 11284.5 NCNT MWD040 CP30 500.26 45292.3 23759.3 1827 10371.5 11284.5 RHOB MWD040 G /CC 1.462 3.405 2.43946 1857 10371.5 11299.5 DRHO MWD040 G /CC -1.284 0.887 0.0775708 1857 10371.5 11299.5 RPD MWD040 OHMM 9.57 229.79 29.7163 1478 10581 11319.5 RPM MWD040 OHMM 7.31 197.65 23.4558 1478 10581 11319.5 RPS MWD040 OHMM 6.84 280.42 23.3256 1478 10581 11319.5 RPX MWD040 OHMM 6.62 184.47 19.906 1478 10581 11319.5 FET MWD040 HR 0.82 43.33 5.70686 1478 10581 11319.5 GR MWD040 API 42.71 549.96 100.765 1478 10574 11312.5 PEF MWD040 B/E 1.58 14.59 2.96214 1857 10371.5 11299.5 ROP MWD040 FPH 0.03 138.16 61.705 1480 10639.5 11379 NPHI MWD040 PU 7.71 132.73 22.8213 1827 10371.5 11284.5 First Reading For Entire File 10371.5 Last Reading For Entire File 11379 File Trailer Service name STSLIB.005 Service Sub Level Name version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 Maximum Physical Record 65535 File Type LO Page 13 . • 01- 05b.tapx 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 11285.0 11299.0 CTNA 11285.0 11299.0 CTFA 11285.0 11299.0 SCO2 11300.0 11314.0 SBD2 11300.0 11314.0 SNP2 11300.0 11314.0 SGRC 11313.0 11327.0 SFXE 11320.0 11332.0 SEMP 11320.0 11332.0 SEXP 11320.0 11332.0 SESP 11320.0 11332.0 SEDP 11320.0 11332.0 SROP 11379.5 11389.0 LOG HEADER DATA DATE LOGGED: 07- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 11389.0 TOP LOG INTERVAL (FT): 11379.0 BOTTOM LOG INTERVAL (FT): 11389.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 88.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 948045 CTN Thermal Neutron 10603684 EWR4 Slim EWR - Phase 4 148579 ALD Azimuthal Litho - Den 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10381.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.50 MUD VISCOSITY (S): 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 5000 FLUID LOSS (c3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .680 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .311 172.0 Page 14 • i 01- 05b.tapx MUD FILTRATE AT MT: .620 80.0 MUD CAKE AT MT: .880 75.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .AIN Max frames per record undefined Absent value -999 Depth units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RHOB MWD050 G /CC 4 1 68 12 4 DRHO MWD050 G /CC 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 B/E 4 1 68 44 12 ROP MWD050 FPH 4 1 68 48 13 NPHI MWD050 PU 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11285 11389 11337 209 11285 11389 FCNT MWDO50 CP30 536.67 641.49 594.993 29 11285 11299 NCNT MWD050 CP30 884.56 973.01 933.825 29 11285 11299 RHOB MWD050 G /CC 2.295 2.358 2.31614 29 11300 11314 DRHO MWD050 G /CC -0.016 0.14 0.0205172 29 11300 11314 RPD MWD050 OHMM 12.65 13.65 12.9804 25 11320 11332 RPM MWD050 OHMM 10.29 11.44 10.6012 25 11320 11332 RPS MWD050 OHMM 8.75 9.79 9.004 25 11320 11332 RPX MWD050 OHMM 8.44 9.19 8.66 25 11320 11332 FET MWD050 HR 16.23 35.06 32.0028 25 11320 11332 GR MWD050 API 58.38 70.34 65.8003 29 11313 11327 PEF MWD050 B/E 1.93 2.14 2.02069 29 11300 11314 ROP MWD050 FPH 3.65 92.28 47.9265 20 11379.5 11389 NPHI MWD050 PU 22.42 25.91 23.7538 29 11285 11299 First Reading For Entire File 11285 Page 15 01- 05b.tapx Last Reading For Entire File 11389 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 11299.5 12842.5 CTNA 11299.5 12842.5 CTFA 11299.5 12842.5 SCO2 11314.5 12857.5 SNP2 11314.5 12857.5 SBD2 11314.5 12857.5 SGRC 11327.5 12871.0 SEMP 11332.5 12877.5 SFXE 11332.5 12877.5 SEDP 11332.5 12877.5 SESP 11332.5 12877.5 SEXP 11332.5 12877.5 SROP 11389.5 12932.5 LOG HEADER DATA DATE LOGGED: 10- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 12932.0 TOP LOG INTERVAL (FT): 11389.0 BOTTOM LOG INTERVAL (FT): 12932.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 92.1 Page 16 . + 01- 05b.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 948045 CTN Thermal Neutron 10603684 EWR4 Slim EWR - Phase 4 148579 ALD Azimuthal Litho - Den 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10381.0 BOREHOLE CONDITIONS MUD TYPE: Fresh water Gel MUD DENSITY (LB /G): 8.60 MUD VISCOSITY (S): 46.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.300 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .571 165.8 MUD FILTRATE AT MT: .860 69.0 MUD CAKE AT MT: 1.200 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame spacing 60 .11N Max frames per record undefined Absent value -999 Depth units Datum specification Block sub- type...0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD060 CP30 4 1 68 4 2 NCNT MWD060 CP30 4 1 68 8 3 RHOB MWD060 G /CC 4 1 68 12 4 DRHO MWD060 G /CC 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 FET MWD060 HR 4 1 68 32 9 GR MWD060 API 4 1 68 36 10 PEF MWD060 B/E 4 1 68 40 11 ROP MWD060 FPH 4 1 68 44 12 NPHI MWD060 Pu 4 1 68 48 13 Page 17 110 111 01- 05b.ta x p RPX MWD060 OHMM 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11299.5 12932.5 12116 3267 11299.5 12932.5 FCNT MWD060 CP30 496.92 822.81 591.767 3087 11299.5 12842.5 NCNT MWD060 CP30 25118.2 31144.5 27655.6 3087 11299.5 12842.5 RHOB MWD060 G /CC 2.176 2.526 2.33999 3087 11314.5 12857.5 DRHO MWD060 G /CC -0.072 0.248 0.0597911 3087 11314.5 12857.5 RPD MWD060 OHMM 11.92 22.39 16.5469 3091 11332.5 12877.5 RPM MWD060 OHMM 9.55 20.42 15.1713 3091 11332.5 12877.5 RPS MWD060 OHMM 8.47 21.58 14.9399 3091 11332.5 12877.5 FET MWD060 HR 0.65 57.44 3.1994 3091 11332.5 12877.5 GR MWD060 API 50.82 388.03 90.8785 3088 11327.5 12871 PEF MWD060 B/E 1.48 4.43 2.07944 3087 11314.5 12857.5 ROP MWD060 FPH 0.08 297.1 68.1438 3087 11389.5 12932.5 NPHI MWD060 PU 19.03 27.15 24.0513 3087 11299.5 12842.5 RPX MWD060 OHMM 8.41 21.44 14.0172 3091 11332.5 12877.5 First Reading For Entire File 11299.5 Last Reading For Entire File 12932.5 File Trailer Service name STSLIB.007 Service sub Level Name version Number 1 0 0 Date of Generation 09/03/19 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 09/03/19 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: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 12843.0 14206.0 CTNA 12843.0 14206.0 CTFA 12843.0 14206.0 SNP2 12858.0 14221.0 SCO2 12858.0 14221.0 Page 18 411 411 01- 05b.tapx SBD2 12858.0 14221.0 SGRC 12871.5 14233.5 SEMP 12878.0 14241.0 SFXE 12878.0 14241.0 SEXP 12878.0 14241.0 SEDP 12878.0 14240.5 SESP 12878.0 14241.0 SROP 12933.0 14296.5 LOG HEADER DATA DATE LOGGED: 11- JAN -09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 14296.0 TOP LOG INTERVAL (FT): 12932.0 BOTTOM LOG INTERVAL (FT): 14296.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.0 MAXIMUM ANGLE: 90.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 948045 CTN Thermal Neutron 10603684 EWR4 Slim EWR -Phase 4 148579 ALD Azimuthal Litho -Den 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10381.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB /G): 8.60 MUD VISCOSITY (5): 46.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 3000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.500 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .597 181.2 MUD FILTRATE AT MT: 1.800 68.0 MUD CAKE AT MT: 1.900 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Page 19 . • 01- 05b.tapx Logging Direction Down optical log depth units Feet Data Reference Point undefined Frame Spacing 60 .11N Max frames per record Undefined Absent value -999 Depth units Datum specification Block sub- type...0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD070 CP30 4 1 68 4 2 NCNT MWD070 CP30 4 1 68 8 3 RHOB MWD070 G /CC 4 1 68 12 4 DRHO MWD070 G /CC 4 1 68 16 5 RPD MWD070 OHMM 4 1 68 20 6 RPM MWD070 OHMM 4 1 68 24 7 RPS MWD070 OHMM 4 1 68 28 8 RPX MWD070 OHMM 4 1 68 32 9 FET MWD070 HR 4 1 68 36 10 GR MWD070 API 4 1 68 40 11 PEF MWD070 B/E 4 1 68 44 12 ROP MWD070 FPH 4 1 68 48 13 NPHI MWD070 PU 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 12843 14296.5 13569.8 2908 12843 14296.5 FCNT MWD070 CP30 479.29 874.25 600.656 2727 12843 14206 NCNT MWD070 CP30 964.57 32545.3 27571.2 2727 12843 14206 RHOB MWD070 G /CC 2.193 2.56 2.3144 2727 12858 14221 DRHO MWD070 G /CC -0.073 0.323 0.0790961 2727 12858 14221 RPD MWD070 OHMM 15.64 23.1 19.0013 2726 12878 14240.5 RPM MWD070 OHMM 13.88 20.95 17.1141 2727 12878 14241 RPS MWD070 OHMM 12.38 20.08 16.3796 2727 12878 14241 RPX MWD070 OHMM 11.21 19.58 15.1454 2727 12878 14241 FET MWD070 HR 0.78 31.21 2.77972 2727 12878 14241 GR MWD070 API 54.76 406.58 88.8131 2725 12871.5 14233.5 PEF MWD070 B/E 1.49 3.84 1.96505 2727 12858 14221 ROP MWD070 FPH 0.25 774.49 68.9604 2728 12933 14296.5 NPHI MWD070 PU 18.49 27.66 23.849 2727 12843 14206 First Reading For Entire File 12843 Last Reading For Entire File 14296.5 File Trailer Service name STSLIB.008 Service Sub Level Name Version Number 1 0 0 Date of Generation 09/03/19 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.009 Physical EOF Tape Trailer Page 20 S 01- 05b.ta x p Service name LISTPE Date 09/03/19 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 09/03/19 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 21