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210-160
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 8 2019 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 21 . Suspended ❑ - 20AAC 25.105 20AAC 25.110 I GRADE SETTING DEPTH MD 11b.Well Development m Exploratory ❑ GINJ ❑ WINJ 11WAG ❑ WDSPL ❑ No. of Completions: Zero CEMENTING RECORD AMOUNT PULLED Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 5/8/2019 210-160 r 318-401 3. Address: 7. Date Spudded 15' API Number. P.O. Box 196612 Anchorage, AK 99519-6612 11/28/2010 50-029-22567-02-00 4a. Location of Well (Governments[ Section): B. Date TO Reached: 16. Well Name and Number: NT -80 12/2/2010 PBU E -35B Surface: 1187' FNL, 501' FEL, Sec. 06, T1 1N, R14E, UM Ref Elevations 17. Field/Pool(s): 1175 sx CS III, 375 sx Class'G' 9 KB 65.29 7-5/8" Top of Productive Interval: 2049' FNL, 71' FWL, Sec. 05, T71N, R14E, UM GL 30.50 BF 31.51 PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation. Total Depth: 2042' FNL, 101' FM, Sec. 05, T11N, R14E, UM 9-7/8" 8551'/8531' � ADL 028304 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 664470 y- 5975877 Zone - ASP 4 11202'/9248* ' 89-111 TPI: x- 665064 y- 5975028 Zone - ASP 4 12. SSSV Depth (MD/TVO): 20 Thickness of Permafrost MD/WD: Total Depth: x- 665094 y- 5975035 Zone - ASP 4 None 1900' (Approx.) ' 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window 8642' 8819' MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 9351'/ 8819' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary OR, ROP, RES, Multi Express GR, CCL, AND, Memory CNL, GR, CCL 23. CASING, LINER AND CEMENTING RECORD CASING WT, PER I GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEFT. CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 35' 115' 35' 115' 30" 260 sx Arctic Set (Approx.) 10.3/4" 45.5# NT -80 35' 3627' 35' 3622' 13-1/2" 1175 sx CS III, 375 sx Class'G' 7-5/8" 29.7# L-ap 33' 9123' 33' 8800' 9-7/8" 485 sx Class'G' 4-1/2" 12.6# L-80 8862' 9123' 8736' 8800' 6-3/4" Uncemented Slotted Liner 3-3/16" 6,2# L-00 8692' 9351' 8642' 8819' 3-3/4" 102 sx Class'G' 2-3/8" 4.7# L-ap 8642' 1 11200' 8605' 9246' 3" 50 sx Class'G' 24. Open to production or injection? Yes ❑ No RI . If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number, Date Perfd): 25. TUBING RECORD GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# L-80 8750' 8703-18650' 27. Date First Production: Date of Test: Flow Tubing Press Form 10407 Ablodc 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydrauliciractunng used during completion? Yes ❑ No DATE Per 20 AAC 25.283 (i)(2) attach electronic and printed , --"L0 o1 information i'{� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached Not on Production Hours Tested: Production for Test Period Casino Press: Calculated 24 Ebur Rate Method of Operation (Flowing, gas lift, etc.): NIA Oil -Bbl: Gas -MCF: Water -Bbl: y Oil -Bbl: Gas -MCF. Waler-Bbl: CONTINUED ON PAGE 2 Choke SiveI Gas -Oil Ratio: Oil Gravity - API (corn: Submit ORIGINAL -.11l, mci2alrwt? -4BDMSi-6_1w MAY 291019 )my I 11 28. CORE DATA Conventional Core(s) Yes ❑ No 21 Sidewall Cores Yes ❑ No IZZ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology, and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost -Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 11078' 9129• separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. ShublikA 9390' 8838' Shublik B 9427' 8860' Shublik C 9483' 8894' Sadlerochit -Zone 4B 9525' 8915' CGL - Zone 3 10841' 8971' Base of CGL - Zone 2C 10944' 9024' Zone 2B 11078' 9129' 21TS-Zone 2A 11126' 9174' ' Formation at total depth: Zone 2A 11126' s 9174' 31. List of Attachments: Summary of Pre-Rig Work, Summary of Daily Drilling Reports, 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: Browning, Zachary H Authorized Title: SI pe "alist Contact Email: Zachary.Browning@bp.com Authorized Signature: ate: 5/� ' Contact Phone: +1 907 564 5220 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are Conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a Completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the Cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only WELL NAME: E -35B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8605' Set CIBP 8583' Set Cast Iron Cement Retainer 8583' 37 Bbls Cement 8551' Set Whipstock T/1/0= 2367/197/113 temp=Sl Assist E -line (Load and test) Pumped 5 bbls of 60/40 meth followed by 59 bbls of 10* dsl down TBG to load. Remaining volume pumped on next day. 1/21/2019 *** WSR continued on 01/22/19 *** ***WELL S/I ON ARRIVAL*** (ctd) HES RELAY UNIT 046 TAG COIL FISH W/ 10'x 3-3/8" DUMMY GUN & 3.70" LIB @ 8632' ELMD LRS BEGIN LOADING TBG W/ DIESEL 1/21/2019 ***CONT. ON 01/22/2019 WSR*** ***CONT. FROM 01/21/2019 WSR*** (ctd) HES RELAY UNIT 046 SET PLUG @ 8606' M.E. ELMD, CCL TO M.E. 13.1', CCL STOP @ 8592.9' ELMD LRS PERFORMED PASSING MIT -T PUNCH TBG FROM 8594'- 8599' ELMD, CCL TO TOP SHOT 11.4', CCL STOP @ 8582.6' ELMD 1/22/2019 ***CONT. ON 01/23/2019 WSR*** *** WSR continued from 01/21/19 *** Pumped 86 bbls of 10* DSL down TBG to load for a combined 2 day total of 145 bbls MIT -T PASSED to 2605psi Max applied pressure= 2750 psi Target pressure= 2500 psi. Pressured TBG to 2721 psi with 4 bbls diesel to test. MIT -T lost 105 psi in the 1st 15 min and 11 psi in the 2nd 15 min. for a total losss of 116 psi during 30 min test. Bled down TBG pressure to 580 psi recovering —1.5 bbls. HEL in control of well upon 1/22/2019 LRS departure. Tags hung, Final WHIPS 580/119/0 ***CONT. FROM 01/22/2019 WSR*** (ctd) HES RELAY UNIT 046 PERFORMED PASSING CMIT-TxIA SET 3.66" CAST IRON RETAINER @ 8584' M.E. ELMD, CCL TO M.E. 13.1', CCL STOP @ 8570.9' ELMD, TOP OF PLUG @ 8583' ELMD PERFORMED PASSING MIT -T 1/23/2019 ***JOB COMPLETE, WELL S/I ON DEPARTURE, DSO NOTIFIED**' CTU 9 1.75" coil 0.156WT HT110 blue coil Objective Pre CTD cement annulus MIRU. Standby for cement crew and inclement weather. 1/25/2019 ...Continued on WSR 1-26-19... CTU #9 - 1.75" Coil x 0.156" wt Blue Coil ***Cont. from WSR 1-26-19*** Job Objective: Pre -CTD IA Cement Return to work after weather. Finish rig up CTU and pump 1 3/16" drift ball through Coil. 1/26/2019 1 ...Continued on WSR 1-27-19... CTU #9 - 1.75" Coil x 0.156" wt Blue Coil ***Cont. from WSR 1-26-19*** Job Objective: Pre -CTD IA Cement Pump 1 3/16" drift ball through coil. Make up Cement Stinger BHA with single knuckle joint, RIH. Swap well to 56deg 60/40 methanol at 8500'. Sting into retainer, PT down CTBS to 1000psi, good PT. Pump 37 bbls of cement into retainer, unstung with —4bbls left in coil, picked up out of retainer and reversed all cement out of coil. Pooh pumping pipe displacement. TOC in IA 7200'. RDMO 1/27/2019 ***Job Complete*** Daily Report of Well Operations E -35B T/I/0= 7/30/102 Temp= S/I (LRS Unit 70 - AOGCC MIT -T, MIT -IA) State Witness by Matt Herrera AOGCC MIT -T PASSED @ 2659 psi (Target 2500 psi Max Applied 2750 psi) Pumped 1 bbl of amb. diesel down TBG to reach test psi 1 st test 1 st 15 min TP lost 62 2nd 15 min lost 18 psi for a total of 80 psi in 30 min bleed TP down bleed back -1.5 bbis AOGCC MIT -IA INCONCLUSIVE per State @ 2605 psi (Target 2500 psi Max applied 2750 psi) Pumped 3.3 bbls of amb. diesel down IA to reach test psi 1st test 1st 15 min IA lost 51 psi 2nd 15min lost 26 psi for a total of 77 psi in 30 min run test another 15 min IA lost 17 psi run test another 15 min IA lost 15 psi for a total of 109 psi in 1 hour bleed IAP down bleed back -2.9 bbls 2/1/2019 Final Whp's=450/27/95 ***WELL S/I ON ARRIVAL*** (Pre CTD) DRIFT TO HES CEMENT RETAINER W/ 3.70" x 20' DUMMY WHIPSTOCK, 3.25" L.I.B. (No issues). RAN SLB MEMORY SCMT LOG FROM 8,555' TO 5,950' SLM (Two passes & Good data). 2/16/2019 ***JOB IN PROGRESS, CONTINUED ON 2/17/19 WSR*** ***CONTINUED FROM 2/16/19 WSR*** (Pre CTD) RIG DOWN SWCP 4516 AFTER RUNNING SLB MEMORY SCMT LOG. 2/17/2019 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** T/I/O = 500/90/20. Temp = SI. MIT -IA PASSED to 2667 psi (Pre CTD). IA FL @ Surface. Max applied = 2745 psi, Target pressure = 2500 psi. Pumped 2.75 bbls of diesel to pressure IA from 28 psi to 2745 psi. IAP decreased 55 psi in 1st 15 min and 23 psi in 2nd 15 min for a total loss of 78 psi in 30 min. Bled IAP from 2667 psi to 50 psi in 10 min (2.5 bbls). Tags hung. Final WHPs = 65/50/120. 2/24/2019 ISV, SSV, MV = C. MV = O. IA, OA = OTG. 12:00. ***WELL S/I ON ARRIVAL*** (SLB E -LINE WHIPSTOCK SETTING) INITIAL T/I/O = 0/25/100. MIRU & PT TO 3300 PSI. SET 4-1/2" BAKER MONOBORE WHIPSTOCKAT 8558' TOWS, 178 DEG ROHS. ALL LOGS TIED INTO SLB MCNL DATED 05 -DEC -2010. RDMO. WELL LEFT S/I ON DEPARTURE. FINIAL T/I/0 = 0/25/100. 2/27/2019 ***JOB COMPLETE 27 -FEB -2019*** T/I/O=TWC/0/0. Pre CDR2 RD 4" tree cap and install 4" 5000 blind flange. PT TWC to low 300psi and high 3500psi for 5min. ea. Passed. PT CDR2 upper tree #3 and Target 90 #2 to low 300psi and high 5000psi for 5min. ea. Passed. Job Complete. See log. Final WHP's 4/17/2019 TWC/0/0. T/1/0=0/50/150. Pre CDR2. Set 4" CIW "H" TWC #292 @ 135" with CIW #839 lubricator. TWC LTT (PASSED). Installed CDR tree #3, torqued to API specs.573 FT/LBS***JOB IN 4/17/2019 PROGRESS***. See log for details. Final WHP's TWC/50/150. T/I/O = TWC/100/170. Temp = SI. Bleed WHPs (Pre CTD). No AL, flowline, scaffolding, or wellhouse. Did not bleed (winds @ 50+ MPH). 5/2/2019 SV = ?. WVs = C. MV = C. IA, OA = OTG. 1215 hrs. T/I/O = TWC/100/170. Temp = Sl. Bleed WHPs (Pre Rig). No AL, flowline or wellhouse. IA FL @ near surface. OA FL @ surface. Bled OAP to BT from 170 psi to 0 psi in 5 min (Fluid, 1/4 bbl). Bled IAP to BT from 100 psi to 0+ psi in 30 min (Gas/fluid, -5 gal). OAP went on a Vac. Monitored for 30 min. IAP increased 10 psi, OAP increased 2 psi. Final WHPs = TWC/10/0+. 5/3/2019 SV, WV = C. MV=O. IA, OA = OTG. 01:00 T/I/O = TWC/60/20. Temp = SI. WHPs (pre RIG). No AL, flowline, or wellhouse. IAP increased 50 psi & OAP increased 20 psi overnight. 5/4/2019 SV, WV = C. MV = O. IA, OA = OTG. 14:30 Daily Report of Well Operations E -35B TWO = TWC/60/20. Temp = SI. Bleed IAP & OAP to 0 psi (Pre Rig). No AL, flowline or wellhouse. IA FL @ near surface. OA FL @ surface. Bled OAP to BT from 20 psi to 0 psi in <1 min (Fluid, 0.25 gal). Bled IAP to BT from 60 psi to 0 psi in 1 min (Gas). Held open IA bleed for 3.5 hrs. Monitored 30 min for BUR. IAP increased 5 psi. Bled IAP to 0 psi in 1 min. Final WHPs = TWC/0/0. 5/4/2019 SV, WV = C. MV = O. IA, OA = OTG. 23:59 TWO = TWC/30/0+. Temp = SI. Bleed IA & OAP (Pre Rig). No scaffolding, wellhouse or flowline. Kill line rigged up to flow cross. IA FL @ near surface. OA FL @ surface. Bled the IAP from 30 psi to 0 psi in 1 minute (all gas). Bled the OAP from 0+ psi to 0 psi in 5 seconds (all fluid, 1/2 cup). Maintained an open bleed on the IA for 5 hours. Monitored for 30 minutes, during monitor IAP increased 4 psi & OAP remained at 0 psi. Final WHPs = TWC/4/0. 5/5/2019 SV, WV = C. MV = O. IA, OA = OTG. 16:20 T/1/0=0/0/0 PULL TWC FOR CDR2. R/U CIW Lubricator # 840 with 3 - 5'& 1- 3' extensions, & H plug pulling tool. PT'd Lubricator low 300psi, High 3500psi. Pulled 4" H TWC #292 5/7/2019 @110". R/D CIW lubricator & Ext. RDMO ***Job Complete*** FWHP= 0/0/0 North America - ALASKA - BP Operation Summary Report Page t cM Common Well Name. E-35 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/5/2019 End Date: 5/13/2019 X3 -0199H -C: (3,513,240 00 ) Project: PBU Site: E Rig Name/No.: CDR -2 Spud DateRime: 6/27/2001 12:00 OOAM Rig Release: 5/13/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPJOI: USA00000707 Active datum: KB (Q65.29 sit (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) 5/5/2019 1800 - 2030'. 2.50 MOB P PRE FINISH RIG DOWN PULL RIG OFF WELL. INSTALL JEEPS 2030 - 00:00 3.50 MOB P PRE MOVE RIG FROM DS15 TO E -PAD. 11.6 MILE _MOVE 5/6/2019 00:00 - 0300 3.00 MOB P PRE REMOVE JEEPS. 'PJSM. SPOT SUBAND MUD MODULE "'RIG ACCEPTED AT 03:01 03:00 - 0800 5.00 RIGU P PRE BEGIN RU OPS - OPEN TREE VALVES TO MONITOR THERMAL EXPANSION ON TREE. -- PERFORM PASSING LTT TO 351 - REMOVE TREE CAP, INSTALL BOPS. 08:00 - 11:30 3.50 BOPSUR P PRE MAKE UP TEST JOINT, PREP FOR BOP TEST. FINISH RIG UP CHECKLISTS. GREASE CREW SERVICES TREE VALVES AND TORQUED TREE BOLTS 11:30 - 1330 2.00 BOPSUR P PRE FLUID PACK LINES. REVIEW PROCEDURE FOR BOP TEST. REVIEW VALVE ALIGNMENT. 'FLUSH AND FLUID PACK LINES. GET GOOD SHELL TEST TO 4500 PSI. 13:30 - 20:30 7.00 BOPSUR P PRE _ TEST BOPS AS PER BP AND AOGCC REGS. TEST IS WITNESSED BY WSLAND TOOLPUSHER, AOGCC BOB NOBLE DECLINES WITNESS. ANNULAR TESTED WITH 2" AND 3.5" TEST JOINT. VARIABLES TESTED WITH 2.375" AND 3.5" TEST JOINT ALL TESTS TO 250 / 3500 PSI. TEST t: IRV, STRIPPER, C9, C10 BACKWARDS - PASS. TEST 2: BLIND ISHEARS, RI,BLIA,BI,B4- FAIL ON St. BLEED OFFAND GREASE Bt. RETEST 2 -PASS. FAIL/PASS ON St. TEST 3: ANNULAR (2"), TIW 1, B3, B2, BL7 - PASS TEST 4: UPPER 2" PIPE / SLIPS, TIW 2, BI -2, T2, C15 -PASS TEST S: C16, T1, C11- PASS TEST 6: VARIABLES (2-3/8"), C7, C9, C10, TV2 -PASS TEST 7: LOWER 2" PIPE / SLIP, C5, C6, C8, TV1-PASS TEST B: CHOKE A, CHOKE C- PASS PERFORM ACCUMULATOR DRAW DOWN. TEST 9: ANNULAR (3-1/7), Cl, C4 PASS TEST 10: VARIABLES (3-1/2"), C2, C3 PASS 20:30 - 22:30 2.00 SOPSUR P PRE RIG DOWN TEST EQUIPMENT. REMOVE TEST RISERS AND INSTALL DRILLING RISERS VALVE CHECKLIST. TAKE RKB MEASUREMENTS FOR STACK DRAWING Printed 5/28/2019 10:33:27AM **All depths reported in Drillers Depths" 10:33:27AM **All depths reported in Drillers Depths** NorthAmerica- ALASKA - BP Page 2o j Operation Summary Report Common Well Name. E-35 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 5/5/2019 End Date. 5/13/2019 X3 -0199H -C (3,513,240.00 ) Project: PBU Site: E Rig Name/No.: CDR -2 Spud Date/Time. 6/27/2001 12,00:OOAM Rig Release: 5/13/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000707 Active datum: KB @65.29usft (above Mean Sea Level) Date From - To Ars Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft) - _ _ 22:30 - 00:00 1.50 BOPSUR N PRE PJSM, BRING VALVE CREW LUBRICATOR ON TO RIG. EVACUATE STACK TAKE MEASUREMENT TO CLOSED SWAB RIG UP EXTENSIONS /PULLING TOOL STAB LUBRICATOR, 517/2019 00:00 - 02:30 2.50 WHSUR P PRE PJSM, REVIEW COMMAND AND CONTROL FOR TESTING LUBRICATOR FLUID PACK TO TIGER TANK WITH METHANOL. PRESSURE TEST LUBRICATOR TO 3500#. TOOK EXTENDED AMOUNT OF TIME FOR PRESSURE TO STABILIZE DUE TO PRESSURE RISING. (THERMAL) TEST PASSED. PULL TWC WITH O# ON WELL. WELL WAS STATIC CLOSE MASTER/SWAB. LTT. BLOW LUBRICATOR DOWN TO TIGER TANK RECOVER TWC WITH SEAL INTACT. OFFLOAD VALVE CREW EQUIPMENT. NORMALIZE MAST _ 02:30 - 03:00 0.50 RIGU P PRE INSTALL FLOATS IN UQC. STAB INJECTOR. 03:00 - 04:30 1.50 RIGU P PRE PRE SPUD WITH WARDS CREW, LINE UP TO PUMP FORWARD AND CHECK MICROMOTIONS. 04:30 - 07:00 2.50 RIGU IN PRE WHILE TRANSFERRING MUD FROM ACTIVE SYSTEM TO STORAGE PITS, PERSONAL H2S MONITORS DETECT 1-12S IN THE PUMP ROOM. 0 READINGS SEEN ON RIG SENSORS. SWEEP THE RIG WITH 4 -GAS HANDHELD DETECTORS, A MAX READING OF 42 PPM IS SEEN IN THE PUMP ROOM JUST ABOVE THE STORAGE PIT. EVACUATE RIG, ALL CREWS MUSTER AND ACCOUNTED FOR. MAKE NOTIFICATIONS TO CT SUPT, PAD OP AND WOS. DISCUSS PLAN FOR RE-ENTERING RIG WITH HSE AND BP, NABORS SUPT 07:00 - 09:30 2.50 RIGU N PRE ASST FIRE CHIEF+ FIRE CREWARRIVE FROM BOC TO SWEEP RIG. MAX READING OF 7 PPM 112S JUSTABOVE STORAGE PIT, ZEROS EVERYWHERE ELSE. DISCUSS PLAN FORWARD WITH CTD SUPT, AGREE TO OFFLOAD ALL MUD FROM RIG AND FLUSH ALL LINES AND PITS. 09:30 - 11:30 2.00 RIGU N PRE VAC TRUCKS ARRIVE WITH H2S SCAVENGER PILLABOARD. HOOKUPTRUCKSAND REMOVE ALL MUD FROM RIG. WHILE REMOVING MUD FIRE CHIEF AND 1 FIRE CREW STANDBY TO ASSIST. AFTER MUD IS OFF RIG SWEEP PIT AREA AGAIN WITH HANDHELD 4 -GAS MONITOR ALL CLEAR. RECEIVE APPROVAL TO RE-ENTER RIG WITH CREWS. 10:33:27AM **All depths reported in Drillers Depths** Printed 5/28/2019 10:33.27AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 cm Operation Summary Report Common Well Name: E-35 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 5/5/2019 End Date: 5/13/2019 X3 -0199H -C. (3,513,240.00 ) Project: PBU Site: E Rig Nama/No.: CDR -2 Spud DateTme: 6/27/2001 12:00:OOAM Rig Release: 5/13/2019 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI: USA00000707 Active datum: KB @65.29usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr_) _ — __._. _ (usft) 11:30 - 14:00 2.50 RIGU N PRE CREW CHANGE ANOVALVECHECKUST. REVIEW INCIDENT WITH ONCOMING CREW AND PLAN FORWARD. GET MORE NO-SULF (H2S SCAVENGER) OUT _ AND MIX IT WITH 130 BBLS FRESH WATER. 14:00 - 22:00 8.00 RIGU N PRE REVIEW PROCEDURE FOR FLUSHING PITS AND LINES WITH RIG CREW. FLUSH PITS AND LINES WITH NO-SULF+ CAUSTIC THEN WITH FRESH WATER. SIMOPS- HYDRA RIG TECHNICIAN INSPECT I INJECTOR WHILE FLUSHING PITS. SIMOPS - PT LUBRICATORS AND FLOATS TO 3500#. MAKE UP LOWER PORTION OF BHA. 22:00 - 00:00 2.00 RIGU N PRE CIRCULATE PIT TO PIT TO VERIFY MICROMOTIONS. SWAP COIL OVER TO 1% KCL 5/8/2019 00:00 - 01:00 1.00 RIGU N PRE 'FINISH CIRCULATING COIL TO KCL. 01:00 - 02:30 1.50 RIGU N PRE PERFORMAAR WITH WARDS CREW. 02:30 - 03:00 0.50 STWHIP P WEXIT PERFORM FLOW CHECK. STATIC. PJSM _ FOR BHA MAKEUP 03:00 - 09:00 6.00 STWHIP P 8,553.00 WEXIT MAKE UP BHA#1 RIH WITH MILLING BHA#1 .- RATE: 0.50 BPM IN, 0.45 BPM OUT. CIRC PRESSURE: 500 PSI - MUD WEIGHT: 8.39 PPG IN, 8.25 PPG OUT - INJECTOR ON 03:45 - RIH, DISPLACE PUMP KCL MIN RATE TAKE RETURNS OUT TO TIGER TANK. -TIE IN DEPTH FROM 81501, CORRECT -8'. - LIGHT TAG AT 8553'. - PICK UP AND CLOSE EDC, PUMP 10 BBLS THEN OPEN EDC AGAIN FOR FLUID SWAP. (EDC CIRC PORTS ARE 103 FT ABOVE BIT) - SWAP WELL TO WATER THEN TO MUD. PURGE RISER. - AFTER MUD ALL THE WAY AROUND 10 MIN FLOWCHECK IS GOOD, NO FLOW. ,r 09:00 - 14:30 5.50 STWHIP P 8,553.00 WEXIT BRING PUMPS TO 2.4 BPM, START CLOSING UL CHOKE FOR 10.55 PPG AT WINDOW. �'��� EASE DOWN TO 8551' AND START TIME MILLING. MILL 3.80' WINDOW IN 4-1/2" X 7-5/8" CASING/LINER PER BAKER REP FROM 8551' MD TO 8554' MD - RATE: 2.39 BPM IN, 2.40 BPM OUT - MUD WEIGHT: 8.60 PPG IN, 8.51 PPG OUT - DWOB: 2 - 3 KLBS - CIRC PRESSURE: 3800 - 3900 PSI - KEEP ECDAT 10.55 PPG WHILE MILLING WINDOW - STARTADDING BAROID BLACK PRODUCTS TO MUD TO HELP WITH KINGAK EXIT Printed 5/28/2019 10:33.27AM **All depths reported in Drillers Depths" TRM= 4-1/16"CW Wfl1FFAD= 5MFMC ACTUATOR= BAKER KB. E EV = 65.29 BF. EJ -V = 31.51' KOP= 8349 Max Angle = 97" 0 9194' Datum MD= 9442' Datum TVD = 8800'SSI 20" OONDl1CTOR, 115' D= 19.124" 10-3/4- CSG, 3627 45.5#, NT -80 BTC, D = 9.950" 14-12" HES CAST RON CMT RETAINER (01/23/191 1 'G BAB SUB 3.70" X .62',- 8833' CTM 3.63' X 220', OAL = 2.82' (526/18) TOP OF 2-39" LNR - 8848' OF 2-7/8' LNR 1-1 8691' Minimum ID = 1.780" @ 8648' 2.70" BTT DEPLOY SLEEVE LNR D = 6.875" (OLD SDTRK WINDOW) 4-12" LNR 12.69, L-80 NSCr, D = 3.958" -9128 2-79" WHIPSTOCK (111 9360' CSG, 6.2#, L-80 TCS .0076 bpf, D = 2.80' -9362 PBffORATIO N SUIN AW REF LOG: SLB MULTEXP KESS (RIX) GR TIES( NBY DEN ON 12/03/10 ANGLEAT TOP PERF: 24-@11080' Note: Refer to Production DB for historical cert data 1-11/16" 1 6 111080-111101 S E -35B w SAFETY NOTES: WELL ANGLE> 700 @ 8926'*** 8551' H4-12"BKRMONOBORE STI MD I TVD I DEV I TYPE I VLV ILATCHI PORT DATE 3 4053 4046 0 MER DW BK 0 0825/17 2 6731 6726 0 MER DMY BK 0 0825/17 1 8126 8120 0 MER DMY BK 0 0825/17 CTM FISH: TOOLS LEFT N HOLE- SEE REDLINE FOLDER FOR TOOL DRAW4NGS (04/10/18) 97--l-42-70- BTT DEPLOY SLV. D = 1780 - rt. 2 FULL 45KB PKR SLIPS, 2 HALF PE 45KB PKR SLIPS - UNKNOWN DEPTH (' 3-12" BKR DEPLOY SUB. D = 3.00" 3-12" X 3-3/16" XO, D = 2.786^ 7-5/8" X 4-12" BKR SABL-3 PKR Dar K ANCH D = 3.87" 14-12" HES XN NP. D = 3.725" I 8760' 1-j4-12" WLEG, D= 3.958- -d .958" GMD TT LOGGED 4/1897 7-59" X 4-12" TW HBBP TGR, W/ SCP TOP, D = 3.920" 4-1/2" MLLOUT WINDOW (G35A) 9123' - 9128' 9100' TOP OF CEMENT 3-3/16" MLLOUT WINDOW (E -35B) 9351' - 9357- \ -10880' TOC(09/11117) FISH: BKR FISHING BHA I - L108 -6-T-1 1423' LONG (09/12/17) 2-3/8" LNR, 4.7#, L-80 S"1L, . W 39 bpf, D = 1.992" 11200' DATE I REV BY COMN6JTS 06111/95 N28E ORIGINAL COMPLETION DATE I REV BY I COMMENTS 0124/19 1 NKW/JMD SET REr, PLUG & TBG RMCH 07/05101 NDRDICI CTD SIOETRACK(E35A) 0129/19 JCF/JMD W CMTTOP(0127/19) 12107/10 NDROIC I CTD SIDETRACK(635B) 03/07/19 MBUMD SETIMPSTOCKw/RA TAGS 04116/18 JUJMD SET FISH & JETCUT LNR 05131/18 MS/JMD LEFT FISH(0526/18) 09112/18 JNJJMD ADDED BF ELEV & ADDED FISH DEPTH PRLDHOE BAY UNIT WELL E35B P1EFWr Nr. 2101600 AH No: 50-029-22557-02 SEC6, T11K R14E, 1187- RNL & 501' FEL BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 10, 2019 SUBJECT: Well Bore Plug & Abandonment PBU E -35B - BP Exploration Alaska PTD 2101600 / Sundry 318-401 Section: 6 Township: 11N Range: 14E Meridian: Umiat " Drilling Rig: NA Rig Elevation: NA Total Depth: 11202 ft MD Lease No.: ADL 028304 " Operator Rep: Feet Suspend: P&A: X Casing/Tubing Data (depths are MD): Conductor: 20" O.D. Shoe@ 115 Feet Surface: 10 3/4" O.D. Shoe@ 3627 Feet Intermediate: 7 5/8" O.D. Shoe@ 9123 Feet Liner 1: 4.5 O.D. Shoe@ 9123 Feet Liner 2: 3 3/16" - O.D. Shoe@ 9351 Feet Liner 3: 2 3/8" - O.D. Shoe@ 11200 Feet Tubing: 4.5" O.D. Tail@ 8750 Feet Plugging Data: Test Data: Type Plug Casing Removal: Csg Cut@ Feet 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 Annulus Retainer 8703 ft MD 7000 ft MD 2596 -2556 - P OA 340 463 435 408 Initial 15 min 30 min 45 min Raciilt Tubing 1 340 1 299 1 265 1 232 IA 2744 2646 " 2596 -2556 - P OA 340 463 435 408 Initial 15 min 30 min 45 min Rasult Tubing 1 252 1 221 1 192-1 165 IA 2741 - 2700- 2665 - 2635 P OA 414 388 365 341 Remarks: IA cement squeeze plug verification test. Well is being plugged back for redrill as E -35C. The Pretest pressures are T/I/O 31/719/320. Used 2.2 Bbls to pressure up and bled back 2.1 Bbls. Attachments: none - rev. 11-28-18 2019-0509_Plug_Verfication_PBU_E-35B_bb MEMORANDUM TO: Jim Regg 2 l alb 119 P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Section: 6 Township: Drilling Rig: Operator Rep: NA Rig Elevation: Travis Hallifax ' Casing/Tubing Data (depths are MD): Conductor: 20 O.D. Shoe@ Surface: 10 3/4" O.D. Shoe@ Intermediate: 7 5/8" O.D. Shoe@ Liner: 3 3/16" x 4.5" O.D. Shoe@ Liner: 2 3/8" O.D. Shoe@ Tubing: 4.5" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 3, 2019 SUBJECT: Plug Verification - IA Squeeze PBU E -35B . BPXA - PTD # 2101600; Sundry # 318401 11N Range: 14E Meridian: Umiat NA Total Depth: 117-00' M 6 Lease No.: ADL 028304 Suspend: NA P&A: NA 115 - Feet 3627 Feet 9123 Feet 9351 Feet 11200 Feet 8750 Feet Type Plug 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 venfled Tubing Retainer 8584 ft MD 1 15.8 ppg Wireline tag Annulus Retainer 8700 ft MD 7000 ft (est.)- 15.8 ppg - N/A Initial '15 min In min 45 min Result Tubing 738 744 747 745 IA IA 2714 2663 2637 2620 P OA 393 388 - 382 383 Initial 15 min 30 min 45 min Result Tubing 2739 2677 2659 IA 33 36 36 P ✓ OA 106 104 107 Remarks: Bridge plug set in tubing; holes punched in tubing and cement retainer set above. Cement pumped down tubing, squeezed into the annulus (bottom on packer at approx. 8700 ft MD; top est. at 7000ft in annulus). Preparing well for CTD redrill. Attachments: None rev. 11-28-18 2019-0201_Plug Verification_IA-Squeeze_PBU_E-35B_mh Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC A..: Natural Resources L333 MW. 7th Ave, Suite 100 Anchorage, AK r SERVICEORDER SERVICE COLOR WELL NAME API # # FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED PRINTS CDs 21 01 60 ilY1fL-i�i'� TRANSMITTAL DATE TRANSMITTAL# ��specitic A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Xpackage have been verified to match the media noted above. The Print Nam Sgnatreate content of the CDs and/or hardcopy prints may or may IL not have been verified for correctness or quality level at this Please return via courier or sign/scan and email a copy t oth Schlumberger and BP point. Schlumberger -Private THE STATE °fALASKA GOVERNOR BILL WALKER John Egbejimba Engineering Team Leader — CTD & RWO BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU E -35B Permit to Drill Number: 210-160 Sundry Number: 318-401 Dear Mr. Egbejimba: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.olaskc.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, Cay . Foerstei� Co ssioner DATED thisV d y of September, 2018. RBDMS<�UtT 0 2 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 a✓ / Operation s utd 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change�Approved Program ❑ Plug for Retlrill EI Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other IA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Cu ant Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 210-160 3. Address: P.O. Box 196612 Anchorage, AK 6. qpl Number. 50-029-22557-02-00 99519-6612 Stratigrephic ❑ Service ❑ 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU E-3513 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028304 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVDD(ft): Effective Depth MD: E6ecWe Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): /ZO%7�j1200A 19246 pZ1e 10880 8988 2456 10880 6633, 8636, 8691, 10863 Casing •r7 Length, y,/ •(� Size MD TVD Burst Collapse Conductor 80 20" 35-115 35-115 1490 470 Surface 3592 10-3/4" 35-3627 35-3622 4560 1730 Intermediate 9090 7-5/8" 33-9123 33-8800 6890 4790 Liner 261 4-1/2" 8862-9123 8736-6800 8430 7500 Liner 659 3-3/16" 8692-9351 8642-8819 Liner 2558 2-3/8" 1 8642-11200 8605-9246 11200 1 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): Noi 1 4-1/2"12.6#L-80 L-80 31-8750 Packers and SSSV Type: 4-12" Baker SABL3 Packer Packers and SSSV MD (ft) and TVD (ft)'. 8703/8650 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: October 1, 2018 15. Well Status after proposed work'. Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative. GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning, Zachary H be deviated from without prior written approval. Contact Email: Zachary.BrowningQbp.com Authorized Name: Egbejimba, John Contact Phone: +1 907 564 5220 Authorized Title: Engineering Team Leader- CTD 8 RIND O. Authorized Signature: Date: 9 !2 — O COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witnessSundry Number' .y fo C '2- . 0Cz+) fp a//t��v 0e, tpackrY.cr�lvo� ^� I $ - q0 VCyr/'a 17e t 20.41f If Location Clearance Plug Integrity ❑ BOP Test;/ Medhanical Integrity Test; ❑ CGrier�ci & C0736 allow/r7 /A as Othe"90P te- f 70 3500 P s l ✓<v�foc r/ Vl tvb" av,cf'oe k -n it fJnn� gr�r Vz v/ i2'r r5 Ge v/ /A (crn r � t J�L/Y T w th /fz2 / Post Initial Injection MIT Req'tl? Yes ❑ No 6 ✓R l fD / �qdj rairy 6 rCq lr/jfC% f f�r�l1C7��Ya �Jro—"'e" S- , / l M T— All T-% ���/q l Tom' Spacing Exception Required? Yes ❑ No bent Form Required: �(/ — g Q� I " k 1rrrf'7a tr- t�lvJf p/aer`nrv),ta/J vel ridvy7tc r ` APPROVED BYTHE 2S. /1 Z Approved by: COMMISSIONER COMMISSION Date: 9/26 fg ORIGINAL RBDMSSOC T022018 ��fJ , Submft Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Aftachm nts in Duplicate 7Z y/7/k' To: Alaska Oil & Gas Conservation Commission From: Zach Browning i by CTD Engineer t0*0 Date: September 12, 2018 Re: E -35B Sundry Approval Sundry approval is requested to plug the E-358 wellbore and perform a packer squeeze to prep the well for the drilling and completion of the proposed E -35C CTD sidetrack. History of E-358: E -35B was drilled and completed in 2010. It performed strongly until higher MGOR led to less time online. Then recently during an intervention job a BHA became stuck and left down hole restricting access to the liner and to any i further wellwork options. The best use of this wellbore is to sidetrack. �04ui� Proposed plan for E -35C: Drill a through tubing sidetrack on or around April 1't, 2019. The coil sidetrack E -35C will be a 2 string sidetrack targeting oil resource under the HOT in Zone 2. Currently the well has integrity with a good IA test to 2634 psi on 6-5-18. Pre -rig the IA will be cemented to provide for the dual string kickoff as well as provide the cement packer above the sidetrack location. A 4-1/2" whipstock will be set on a -line at 8575'. The rig will move in, test BOPE and kill the well. A 3.80" window + 10' of rathole will be milled. The intermediate section kicks off in the Kingak (good cement is expected outside casing, with the primary 7-5/8" TOC = 5045' MD based on volumetrics and 40% washout). The 4.25" hole section (-250') will be drilled to the TSGR and a 3-1/4"L-80 protection string will be run across the Kingak and top set in the Sag. A liner hanger is planned to hold this liner, but no cement will be pumped. The shoe will be milled with slimhole tools, and the well will be drilled down below the HOT and land in Zone 2 where the horizontal will be drilled before toeing up above the HOT at TD. The total lateral length in the production hole section is planned for ^2500' MD. The proposed sidetrack will be completed with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated. IA Cement Detail: To perform the IA squeeze a CIBP will be set, the tubing will be punched and above that a cement retainer will be set, on Eline. Service coil will sting into the retainer and pump 47.0 bbls of 15.8 Flog Class G cement taking returns from the IA. The proposed cement top will be 7,000' MD (6930' TVDss). Surface casing shoe is at 3627' MD (3557' TVDss). The Cretaceous stratigraphy in this well starts at the base Permafrost at 1930' MD (1860 TVDss) and its base is the top CM3 at 6423' MD (6323' TVDss). Top of UG4 is 4663' MD (4593' TVDss). The proposed top of Schematic). will be 2337' and 3373' TVD below the casing shoe. (See Pre -rig Work J This Sundry covers plugging the existing E -35B production via the CIBP, cement, and retainer: as well as the liner cement lob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. Schematic diagrams of the current wellbore, the proposed pre -rig work and proposed sidetrack are attached for reference. Pre -Rig Work (scheduled to begin October V, 2018) 1. SL Dummy GLMs. Drift for Whipstock. 2. E Set CIBP. Perforate. Set Retainer. 3. C Cement Annulus. _ 4. S Drift for Whipstock. Memory SCMT.C' S. E Set WS. 6. V Pre -CTD tree work. Rig Work (scheduled to begin April V, 2019) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2456 psi). 2. Mill 3.80" Window + 10' of rathole 3. Drill intermediate section: 4.25" OH, —256'(8 deg DLS in lateral planned). 4. Run 3-1/4" protection string. Hang off NS liner hanger. 5. Mill Aluminium shoe. 6. Drill production section: 3.25" OH, 2486' (20 deg DLS build, 12 deg DLS lateral) 7. Run 2-3/8" L-80 solid liner to TD. 8. Pump primary cement job: 20.7bbls, 15.3 ppg Class G, TOC at TOL (8390 MD)". 9. Perforate —500' on the rig, 60' planned post rig (1.56" Perfecta guns, 6 spf). 10. Freeze protect well to a min 2,200' TVDss. 11. Close in tree, RDMO. ' Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Tree work as necessary 2. S: SBHPS, set LGLVs, set LTP if necessary. RU DPGL 3. F: assist SL in PT LTP if set 4. T: Portable test separator flowback if pert >500' on rig (3-5 days) S. C: RPM. Perforate above HOT ('60') Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 Tom= • 4-1116" CfW VYELLI-EAD=5M 'KG A7C=R FMC ___ BAKBRC KB. ELBA/ = BF. B_La/.=.31.51' KOP= - 65.29' 6349' Mac Angle = 97' @ 9194' Datum MD= 9442' Datum TVD= 8800'SS SAFETY NOTES: WELL ANGLE> 70" LID 8925'*** 20' CONDUCTOR 115' T I O —f4 H6 HXO SSSv NP, D = 3.813' 91.5#, FMO, D= 19.124' GAS LFT MANDRELS 10-3/4' CSG, 45.5#, NT -80 BTC, D = 9.950' 3627' Minimum ID =1.780" @ 8648' 2.70" BTT DEPLOY SLEEVE >H: BKR 4'G BAR SUB 3.70'X .62', 8633' CTM /ERSHOT 3.63" X 2.20', OAL =2.82' (5/26/16) Wim' 1 8691' 1 4-12" TBG, 12.69, L-80 NSOC, .0152 bpf, D = 3.958' --L 8750' TOC CTD LNR (SCMT 10/09) 875W I 8862' I 1-5/8' CSG, 29.7#, L-80 NSCC, ID = 6.875' (OLD SDTRK WINDOW) .0076 bpf, D = 2.00' I—L-9352 PERFORATION SLRAMRY FEF LOG: SLB MULTEXPRESS (FLB0 GR/ RES/ NRY OBJ ON 12103/10 ANGLEATTOPPERR 24'@11080' N nte: Refer to Production DB for tlstorical pert data SIZE SPF INTERVAL I Opn/Sgz I SHOT I SQ 2"6 8981 - 9386 1 C 12/13/08 1-11116" 6 11080-11110 S 1206/1009/It/17 ST MD TVD DB(I TYPE VLV LATCH PORT DATE 3 4053 4048 0 07/05101 NORDIC 1 CTD SIDETRACK (E -36A) DMY BK 0 08125/17 2 6731 6726 0 MBR DMY BK 0 08125/17 1 8126 8120 0 W82 DMY BK 0 08/25/17 OLS LET N HOLE - SEE REDLINE FOR TOOL DRAWINGS (04110/18) DEPLOY SLV, D= 1.780' SUR/SFAL ASSY. D = 2 39" FISH 2 FULL 45KB PKR SLIPS, 2 HALF PIECES OF 45KB PKR SLFS - LWNOWN DB -M (11/17/17) 3-1/2' BKR DEPLOY SUB, D = 3.00' /2' X 3-3/18' XO, D = 2.71 /8" X 4-1/2" BKRSABL-3 K ANCH, D = 3.87- 12' HES X NP. D = 3.813" 8747' ELMD TT LOGGED 4/18/97 NKR, W/ SCP TOP, D = 3.920' 9033' CTM 2-3/B' JET CUT TBG (04/09/7 B) 4-1/2' MLLOIIT WNDOW (E -35A) 9123' - 9128' 9100' TOP OF mw—,a 3-3/16' MLLOUT WINDOW (E -35B) 9351'- 9357' FISH: BKR FISHING BHA�10863� 14.23' LONG (09/12/17) 2-3/8" LNR 4.7#, L-80 STL, .0039 bpf, D =1.992' PRUDHOE BAY UNIT WELL E35B PERM T N0: 2101600 API No: 50-029-22557-02 SEC 6, T11 N, R14E, 1187' FNL 8 501' FEL DATE RLQ/ BY CONV EJTS DATE REV BY COtiTiBJTS 06111/95 N28E ORIGINAL COMPLETION 04/16/18 JUJND SET FISH 8 JE7 CUT LNR 07/05101 NORDIC 1 CTD SIDETRACK (E -36A) 05/31/18 MSIJMD LB= F FISH (05126(1 8) 12/07/10 NOFDIC 1 CTD SIDETRACK (E-356) 09/12M O JNUJMO ADDED BF ELB/ 8 ADDED FISH 05/27/14 PJC LM/ CSG/ TBG C.ORAECTDNS 08/2&17 MOM MD GLV C/O (08/25/17) BP Exploration (Alaska) 0220118 JC4JbD CORR6MMT0GLV TABLE TFlff = 4-1/16' CM/ WELLHEAD = ACIWTOR= 5M FMC — --- 6AK62C KB. REV = 65.29' BF. t3J=l/ = _ 34.79' KOP= 8349' M3X Angle = _ Datum M)= 97-679-19C 9442' Datura TVD = 8800 SS Proposed PRE -RIG 20' COFDDCTOR 115' 91.5#, H-40, D= 19.124' BTC, o = 9.950' K 3627' TOC 7000' 1/2' Bkr Whipstock 8575' elront Retainer 8610' 1 112- CIIAP RSH: BKR 4- G BAR SUB 3.70' X .62', OVERS HOT 3.63' X 2.20', DAL = 2.82'(5126/18) TOP OF 2-3/8' LW Minimum ID = 1.780" @ 8648' 2.70" BTT DEPLOY SLEEVE 1 8862' I ID = 6.875' (OLD SDTRK WINDOW) 4-1/2"LW 12.6#, L-80 NSCT, D = 3.958' 2-7/8' WHIPSTOCK (11/261100 CSG, 6.2#, L-80 TC1, .0076 bpf, D = 2M- PERFORATION SMMR7 REF LOG: SLB NL VU(P LESS (FLEX) GW Fib/ FEY DEN ON 12/03/10 ANGLE AT TOP PEW: 24" Q 11080' Note: Refer to Production 178 for historical pert data SIZE JSPFJ INTERVAL Opn/Sqzj SHOT I SO L O 0.Y01 - `JJOO li 1-11/16' 6 11080 - 11110 5 E —3 5 B SAFETY NOTES: WELL ANGLE > 70" @ 8926' • ' 2206' -14-1/2-I$ Hxo sssv W 0 o��a . .'9 �" GAS LFT MANDRELS ST I MD I ND I DEV TYPE I VLV LATCHPORT DATE 3 4053 4048 0 M62 DMY BK 0 0825/17 2 6731 6726 0 M6i DIVY BK 0 0825/17 1 8126 8120 0 M92 DMY BK 0 0825/17 8636' CTM FISH: TOOLS LEFT N HOLE- SEE REDLM FOLDER FOR TOOL DRAWINGS (04/10/18) 8648' 2.70' OTT DEPLOY SLV, D = 1.780' 8689' BKR LOC SUB/SEAL ASSY, F6H 2 FULL 45KB R(R SLIPS, 2 HALF FECES OF 45KB PKR SLIPS - UWQNOWN DEPTH (11/17/17) 8691' H 3-12' BKR DEPLOY SUB, D = 3.00' 8691' 4-12' HES X NP, D = 3.813' 8703' 1 7-5/8'x4-12' Blot SABL-3 Plat WI K ANCFI D = 3.87' $727' 4-12' HES X NP, D = 3.813' 14-1/2- HES XN NP, D=3.725' ( 8760' H4-12' WLEG, D=3.958' I 8747' ELMD TT LOGGED 4/18/97 PKR W/ SCP TOP, D = 3.920' _I oaa 2-3/8' JET CETT TBG (04/09/18) 4-1/2' MLLOl7T WINDOW (E -35A) 9123'- 9128' 9100' HTOPOFceAENr 3-3/16' MLLOUT WINDOW (E -35B) 9351' - 935T 142Y LONG (09112J17) 2-3/8' LNR, 4.7#, L-80 STL, .0039 bpf, 1D= 1.992' 11200' DATE REV BY COMu 34IS DATE PCV BY CDMuB'RS 06/11195 N28E ORIGINAL COMPLETION 04/16/18 JL/JMJ SET FISH 8 JET CUT LNR 07/05/01 NORDIC/ CTD SIDEMACK(635A) 05/31/18 WJND LIS=T FISH (05/M18) 12107110 NORDIC I CTDSIDETHACK(E35B) 0527/14 PJC LM CSG/ TBG CDM97TIONS 0828/17 W-,VJND GLV CIO (08/25/17) 0220118 JOIJND COF*EL?IDN TO GLV TABLE PRUDHOE BAY LNT WELL: E35B PEF MT W: 41101600 AR W: 54029-22557-02 SEC 6. T1 1K R14E. 118T FTL & 501' FEL SP Exploration (Alaska) VT VMEL JIM= 5MFAC ACTIIATDR= KB. BEY = 65.29' OF. HEV = 34.79' KOP= 8349 Mw Angle 4048 Detun KV Mf3t Dslun7VD= S—S11 PROPOSED 191.5#, H40, D= 19.124' 10-3/4* CSG, 45.5#, NT -80 BTC, C= 9.950' 3827' Minimum ID = " @ TOP OF 2-3/8' LN28��— TOP Tt:1.1j&�1 ,29.7#, L-80 NSCC, D = 4-1/2' TBG, 12.6#, L-80 0152 bpf, D = 3.958' FERFORATION SUMMARY SLOG: ON ANGLE AT TOP f$iF: Note: Refer to Production DB for historical perf data F9TD — 2-3/8' LNR #, L-80 SIL. ._.- bpf, D = 17318' E -35C SAFETY NOTES: WELL ANGLE >704@__— MAX DLS: I 2206' —I4-12' FIES FIXO SSSV NP, D = 3.813' GAS LIFT MANDRELS ISTI MD TVDIDEVITYPEJ 07/05101 NDRDIC I CTD SIDETRACK (E -35A) VLV ILATCHIPORT DATE 3 4053 4048 0 Mf3t OM7' BK 0 0825/17 2 6731 116726 0 M132 DMV BK 0 0825/17 1 8126 120 0 M(32 DMY SK 0 0825/17 a 15-00' ','IQ DATE REV BY CONFANTS DATE REV BY COMMENTS 06111195 N28E ORIGINAL COMPLETION 07/05101 NDRDIC I CTD SIDETRACK (E -35A) 12/07110 NDRDIC I CTD SIDETRACK(E46B) I_I_ CTO SIDETRACK(E-35C) 0827/18 JUD BUILT FRDFO5® 13.70'. 2.70' DEFLOY SLV, D= . I MILOUT V44DOW (E -35C) 8575' - 8585' 12-3/8' PLPJT w At TAO I PR UDHOE BAY UNIT WALL E35C PEFUT N7: API No: 50-02322557-0:3 SRC 6, T11 K R14F 1187' FTL 8 501' FEL BP Exploradon (Alaska) = 5MFMC _WELLHEAD ACTUATOR= I TYPE KB. EEV = 65.29' BF. ESV = 34.79' KOP= 6349 MBx Angle= —"@—' Datum MD= _ Datum TVD= 8800'SS E_35C PROPOSED P&A s"`E"'"°TF WELL ANGLE>70°@_. MAX DLS: _" COPD(1CTOR 115' .5#. H-40, =19.124' 1 3627' 1 Minimum ID = " @ I 839W I 4-112' TBG. 12.60. L-80 NSCC, 0152 bof. D = 3.958" 13-1/4' LW #. L-80 TCL . bof. D= i PERFORATION SUMIARY Rff LOG: ON / / ANGLEATTOPPSRf. _"@__ Note: Refer to Production DB for historical p m 12-3/8'LW _#, L-80 STL, _ bp1, D = 11318' GAS LFT MANDRELS STI MD I ND I DEV I TYPE I VLV I LATCH I PORTDATE 3 4048 0 ME2 OM1' BK 08125/17 2 147053 631 6726 0 ME2 DMY BK 0 06125117 1 8126 8120 0 ME2 OM1' BK 0 OBI25117 1 7000' 1 DATE REV BY COW434M DATE REV BY CONVENTS 06111195 N28E OFBGINALCOMPLETON 07/05101 NORDIC 1 CTD SIDETRACK(E-35A) 12107110 NDRDIC 1 CTD SIDETRACK(E-358) _I_I_ CTD SIDETRACK(E35C) 08/27/18 JbD BUILT P ROPOS13D 13.70' x 2.70" DEPLOY SLV . D = " I MLLOUT WIDOW (E -35C) 8575' - 8565' w PRUDHOE BAY WT WELL E-35(: PERIW ND: AR ND: 50-029-22557-0:; 1`11N. R14E 1187' FFL 8 501' FE_ BP Exploration (Alaska) Well Slimhole 4 Ram BOP Schematic (example) Date *Note: Updated schematic will be submitted once rig contracts are final. Quick Test Sub to Otis 1.1 ft Top of 7" Otis O.Oft — —----------------- ........... �C0112 Rig's Drip Pan Distances from top of riser Excluding quick -test sub 7-1116" 6k Flange x 7" Otis Box Top of Annular 6.0 ft —k— Top of Annular Element 6.7 ft Bottom Annular B.Oft CL Blind/Shears CL 2" Pipe/Slips a1 B2 Kill Line CL 2-318" x 3-112" VBRS CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft CL of Flow Cross 17.4 ft CL of Master 18.8 ft LDS LDS 0 Ground Level 0 B3 Swab 1 T1 f T2 f Master IA OA Choke Line Test Pump Hose Loepp, Victoria T (DOA) From: Browning, Zachary H <Zachary.Browning@bp.com> Sent: Wednesday, September 26, 2018 3:50 PM To: Loepp, Victoria T (DOA) Cc: Worthington, Aras J Subject: RE: PBU E-35B(PTD 210-160, Sundry 318-401) IA Cement Squeeze/Plug for redrill Attachments: E -35C CTD PROPOSED PBtA.PDF Victoria, Please see attached. Thanks, Zach From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, September 26, 2018 2:06 PM To: Browning, Zachary H <Zachary.Browning@bp.com> Cc: Worthington, Aras J <Aras.Worthington@bp.com> Subject: RE: PBU E-35B(PTD 210-160, Sundry 318-401) IA Cement Squeeze/Plug for redrill Please include wellbore schematic showing proposed well abandonment. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Tuesday, September 25, 2018 3:24 PM To:'Browning, Zachary H' <Zachary.Browning@bp.com> Cc: Worthington, ArasJ (Aras.Worthington@bp.com) <Aras.Worthington@bp.com> Subject: RE: PBU E-35B(PTD 210-160, Sundry 318-401) IA Cement Squeeze/Plug for redrill Zach, CO 736 outlines rules for repair of packer leaks, tubing leaks and production casing leaks using inner annulus remedial cement squeezes. The AOGCC has approved an IA packer squeeze for a leak followed by drilling a CT lateral with a cement packer above the sidetrack location. I believe the IA TOC was - 700' above the leaking packer. And the cement packer was -200' above the sidetrack location. In this sundry, no leaks are present but 1700' of IA cement and a cement packer is proposed. Before the cement placement is verified through the SCMT, running a whipstock is planned. It is a new proposal that further pushes the limit of what has been approved. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeop(o7alaska. oov CONFIDENTIALfrY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo4'alaska aov From: Browning, Zachary H <Zachary. Browning@bp.com> Sent: Tuesday, September 25, 2018 2:33 PM To: Loepp, Victoria T (DOA) <victoria loepD alaska gov> Cc: Lastufka, Joseph N <Joseph Lastufka bp.com> Subject: RE: PBU E-35B(PTD 210-160, Sundry 318-401) IA Cement Squeeze/Plug for redrill Victoria, See the highlighted verbiage below from the submitted Sundry for E -35B. The TOC height is targetted to give us the most cement above the KOP without compromising more than one GLM. Let me know if you have any further questions. Proposed plan for E -35C: Drill a through tubing sidetrack on or around April 1", 2019. The coil sidetrack E -35C will be a 2 string sidetrack targeting oil resource under the HOT in Zone 2. Currentty the well has integrity with a good IA test to 2634 psi on 6-5-18. Pre -rig the IA will be cemented to provide forthe dual string kickoff as well as provide the cement packer above the sidetrack location. A 4-1/2" whipstock will be set on B-line at ^8575'. The rig will move in, test BOPE and kill the well. A t heduled to begin October 1°.2018) GLMs. Drift for Whi stock IBP. Perforate. Set Retainer. nt Annulus. WESet for Whipstock. Memory SCMT. S. Thanks, Zach Zach Browning t CTD & RWO Engineer BP Alaska 0:(907)564-5220 C:(907)351-7941 Zachary.browningl5lop.com The fastest horses don't always win, but you should still bet on them. From: Loepp, Victoria T (DOA) <victoria loepp@alaska.aov> Sent: Tuesday, September 25, 2018 2:02 PM To: Browning, Zachary H <Zachary Browning bp.com> Subject: PBU E-35B(PTD 210-160, Sundry 318-401) IA Cement Squeeze/Plug for redrill Zachary, What type of IA leak? Is it a leaking packer? What diagnostics have been performed? MIT -IA results? What post IA squeeze diagnostics are planned? Would like to see the IA squeeze under a separate sundry than the plug for redrill. That is, results of the IA squeeze including the SCMT before setting the whipstock. If this is a packer squeeze, why is TOC -1700' MD above packer? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 71h Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(ialaska.goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loepo`alaska=gov BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT E -35B (210-160) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 1,000,000 t 0 0 CL 100,000 u. v N 10,000 o m v � LL o 1,000 u 3 10 10,000,000 v 1,000,000 0 O 100,000 0 3 rs s 10,000 0 1 1 Jan -2010 Jan -2011 Jan -2012 Jan -2013 Jan -2014 Jan -2015 Jan -2016 Jan -2017 Jan -2018 Jan -2019 Jan -2020 SPREADSHEET—Prod-Inject Curves_W ell_V 115_2101600_P BU_E-35B_20180917.xlsx 9/17/2018 d �1 CCS ■ uM��� ■I� ■■■■ ON NONE ■■■_■■ 10,000,000 v 1,000,000 0 O 100,000 0 3 rs s 10,000 0 1 1 Jan -2010 Jan -2011 Jan -2012 Jan -2013 Jan -2014 Jan -2015 Jan -2016 Jan -2017 Jan -2018 Jan -2019 Jan -2020 SPREADSHEET—Prod-Inject Curves_W ell_V 115_2101600_P BU_E-35B_20180917.xlsx 9/17/2018 0 � • ! ooW ( _Cr1-- >- W T Q" <- : o j ''''2 0 `' ~ ? n 'z N h0 a'' M T f6 O Y o a E cc O . 0 O n N i V a c C +J — O N 6 T �' yu (0 ++ N 'C ' -6 O 6 6 Q SC . U T a Q Z Z Z Z m C t Lu o v c•-, o o U - v Z CCCl v E U v > 6 v 73 CC p p p p c v > W_ _W W W L U O LL LL LL LL 0 -i J J J O. .Q > N Q Q Q Q n Qzzzz U v 'L _ o RN p Q 4.5. t O a' a v U > (13 Q U U 0 z--.. d c,1 < C O Q v a a o a C.> � LL CL d N U .. d LL m W \ *'�9 at «,2: co U a a o. N t0 cu VJ U \ ""> ss,,,�1 U sU +� a W O > CO o �!! °° �f '� r c W 2, c0 to .2 ets d so �' '> E E 3 y `4YZ in zap 22 U t 4-011ir i'' I I I I I I i I I I I I I I I �, � aaa r cc Ca CO m Q a W W W a .. 00 (:) ° S S S O w co o p p p a+ F » > Q >. IX d' Q' co O. 2 1� !Q.) o YI uj y H 7 0.1 X (!S r lVJ CO N N p� 'fC0 V ( 1 + p O 02 O p c _ N V • o 0 0 o C1 N rV�R j 0 'O -LLI V z x Cl O O too dl z O w p p p p coO [w I .. no -' O O O O I I I I ICC ct rn CNA CY R CI CD I I I I I I I I I I I 0o 0 0 0 0 O O O O '3 i Com 0�0 6 N N YY (f1 4-, V gal r- ch fp �.,. 1 i C. Z m oof�' (.51 w Q d ii w z m m ' lIIIHIIIIIIHIII1IIII 11111111111111111111111111 r\ Al z N Y STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown D Suspend 0 Perforate 0 Other Stimulate 0 Atter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Mill Out Failure iI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 210-160 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22557-02-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU E-35B 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 11200 feet Plugs measured 10880 feet true vertical 9246 feet Junk measured 10863 feet Effective Depth: measured 10880 feet Packer measured 8705 feet true vertical 8988 feet Packer true vertical 8651 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 36-114 36-114 1490 470 Surface 3592 10-3/4"45.5#NT-8 35-3627 35-3622 4560 1730 Intermediate 9270 7-5/8"29.7#L-80 34-9304 34-8804 6890 4790 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11080-11110 feet pp DEC 2y True vertical depth: 9130-9158 feet feet % �E® 4 ZU! a Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 31-8752 31 -8682 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11080'-11110'. Treatment descriptions including volumes used and final pressure: 25 Bbls 1%Slick KCL,290 Bbls PowerVis,20 Bbls HighVis Gel,140 Bbls 1%KCL,100 Bbls Diesel,32 Fresh Water,25 Bbls SqueezeCrete,2970 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 281 23101 17 560 1019 Subsequent to operation: Shut-In 260 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Pi Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Derrick,Laurie R Contact Name: Derrick,Laurie R Authorized Title: Petroleum Engineerl� Contact Email: Laurie.Derrick(a�bp.com Authorized Signature: �� OAA A Date: /if�'/Z_D 17 Contact Phone: +1 907 564 5952 .11 Form 10-404 Revised 04/2017 VVV��` VTL, 111 I 1 7-1 1 a Submit Original Only 10/717 C DrS l/ �.^ ({ J2017 S E-35B Failed Cement Squeeze On 9/11/2017,during a cement squeeze to repair a channel behind pipe on well E-35B the service coil milling BHA was lost at 10863' ctmd. We attempted to fish the milling BHA until 9/13/17 when coil rigged down to formulate a plan forward. Service coil returned on 10/12/17 to attempt to retrieve the fish and complete the squeeze job by milling out the remaining cement to reach and reperforate the original perforation interval at 11080- 11110' md. During that intervention, we retrieved part of the original milling BHA fish, but subsequently lost the fishing spear that we were using to recover the remaining fish section.At that point, it was determined that the milling BHA was likely stuck in the remaining cement and further attempts to retrieve it would fail. Coil rigged down on 10/14/17.The top of the fish is located at 10863' ctmd.The fish includes the following: TJ disconnect 1.69" x 1.03', Rupture Disk 1.69" x 0.44',TJ Fishing GS 1.69" x 1.20', (TJ disconnect 1.69" x 1.03', Circ sub 1.69" x 1.01',Tempress 1.69" x 3.04',X-treme motor 1.69" x 7.64', Reverse clutch mill 1.76" x .72') Max OD =1.76" OAL= 16.11' There is an estimate 200' of cement below the fish obstructing access to the top perforation.The tubing pressure was bled to zero and has remained stable at that pressure indicating that there is no communication with the reservoir. • S p 0 0 co 0 0 co p O O N- N- U N o 0 o pO p i C) CO CA O CO CO • if) CO N V' m Cr (D co c0 N CO 0) 0) O N N O O CO CO CO N (0 CO c0 CO CO CO CA CO CO CO 00 H N- O) N- CO LO O M V' CO CO CO CO p CO CO ti CO CO CO CO CO Q� f" V Q CO N M ON O (O N LO p CO ti CO f� CO CA CO CA (A CO a +• + Q M CO Lo V V CO O CO co co co CC O COCO00 CO CO IN- CO C• W • MM W Q. M O O p 0 0 O CO00 CO CO CO co co Z J J J J J J • N CO c.0 00 N N O M CO , i � t CO C)00 6N) O� LLO N O O N- CO N CO (O a) M Co N M N c0 J W • W• 0 '• U U 0 LLcC cc cc c Q Z Z W W W W W O D H Z_ Z_ Z_ Z_ D (n Z J J J J E-- • S Packers and SSV's Attachment PBU E-35B SW Name Type MD TVD Depscription E-35B PACKER 8684 8636.67 3-1/2" Baker 45 KB Packer E-35B TBG PACKER 8705.19 8651.49 4-1/2" Baker SABL-3 Packer E-35B PACKER 8862.56 8736.6 4-1/2" SSH Packer • 0 T a O �� 7 \ ONI- O _a 7 — o C N c m o p -O O in M cn 0 OU Q) CO O .- co a N N o •( j a".0 Q 0, p N co w ca s c (-) v t a N- a- > M a,- a) N- E O L N U �,�` UN O O 3 M >," U o - 3 aci 0 - 7 0 a) 3 2 a o co all- - D • Q `) 1. 0 �0 m ami E a) t C fn 10 = c`a C N 0 - 3 i0c 230 2 cu .c L O 0 = ❑ a) O 0 c i C.. o O 0 V' a) ❑ +. Q- .0 a c cn N Y H c - o -o o Y = N •v o f m oo c0 > w as -0 c ami -0 _ E 0 awiQ Z @ Ti) LT_ 0 .0 •� � cn c2 O Q* N- IY H . co Q c) +U . 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T. 2 W c o; U L a) 0 o To; y a) �° 1.3 li 3 > Era 1° ° o LI , _ - 2 3Ql* 2L°_, o Q °-* 3 3N. cab 0 I- ° (U CO O)U 1 N I- 2 I'- [Y L a) (U c I L a) CO c O U U Ce E L a•c 1 U) r` 0 CL t. U ° CC o)+ 0 c 3 , a) N N- N. N. r` o O o O N N N N N (h N CO -83 ari O O ei • • • U w CD C L C a) O > U a) N.: O x N _ .-- O) C Co O x E b.) O 0 co 0 0 E C a) ii � X LT C o o 0 _ (-i cu 0 co_o ' x a) C) -) o co r) a o a Orn Lo cou) N T a L GD M Y wo � oa) C W. ▪ n. a� ,-- 0. a E ° c[ x 2 a)W &,-) > a)a) OO -o o (U co a) A D E W E r .Q -p J .Q II J — L CU C C O " x C N J m o O o (U = M • u) h < U OW z � m x0 « (12o o - v .- - W H O I- co Zo I- o _ o W 6 Op T T J 0 co -711) -I 0 (13 int - C cT = II � O Cn 4-4- % OU x C 0 0 U > .N c_n U _ L _ % �CO C - 0 � - CO 0 � Cn o � > cn a) o ♦- O i p co Q O Z L o O O o O 00 ' H HT U2 I UTa = J Dcn r-- '-- CD O N CO O) T 1-0 ,--, O) t LU .Q CO T N CO N T m Co Cr a)O) V N O TREE • E =!WE�LFEA° 4-1116M' J !3 SAFETY MDTES: WELL ANGLE>70°@ 8826°*•• 1.---- ACTUATOR= BAKE C I KB.ELEV= 65.29' I/ BE E.EV= 34.79' KOP= 8349', 20"COM)UCTOR, H 115" ® ¢ 2206' j—t4-1/2"Hom' ES HXO SSSV t ,I)=3.813" I Max Angie= 97°@ 9194'! 1 91.5#,H-40, Datura MD= 9442' Datura N D= 8800'SS ?=19.124" GAS LET MANDRELS ST IAD TV° DEV I'TYPE VLV "LATCH PORT DATE {{10-3/4"CSG,45.5#,NT-80 BTC,0=9.950" -- L_______—_----- — -_� �._3GZT__ 3 4053 4048. 0 °A141 BK 0 08/25./17 2 6731 6726 0 A,IiR DOME BK 0 08/25/17 1 8126 8120 0 AER SO BK 0 108/25/171 Minimum ID = 1.780" @ 8 2,70" BTT DEPLOY SLEEVE -I3.70"BKR GUIDE SLEEVE aw/XO,rD=1.810" 8644.* —14-1/2"KB LW,ID=2.37" TOP OF 2-3/8"LW --I 8648' i 2.70'BIT DEPLOY&V,D=1.780" j 9' IH BKR LOC SUB/SEAL ASSY,0=2.39" 8691° H 3-1/2"BKR aEpLoy au,U=3.00' TOP OF 2-7/8'LPR H •. i° 1° —{4-1/2"HES XMP,ID=3.813" ------------ 8702' H3-1/2"X 3-3/16'XO,D=2.786" M >,<- 8703' 1—7-5/8"X 4-1/2"BKR SABL-3 PKR WIKA1U=3.87" I 8727' HI4-1/2"HES X MP,D=3.813" I 8738' --14-1/2"HES XN NP,D=3.725' 4-1/7 TBG,12.6#,L-80 NSDC,.0152 bpf,tD=1958" H 8750' .. ••• 8750' H4-1/2'WLEG,D=3.958' ♦�♦ ♦• I TOC( !U UV(SOA/IT 10/09) — 8754' i ::::: •••�• 8747' HI ELM°TT LOGGED 4/18/97 •♦♦ ♦•• 4+ [TOP OF 4-1/2'LNR 1--i, ---.- ♦—f.. .. --I 8862' —7-5/8"X 4-1/2"TM/F43BP O4 o PKR,W/SCP TOP,D=3.920" II • 4;4 4 . 4-1/2"MLLOUf W (E-36A)9123'-9128' I !7-5/8"CSG,29.7#,L-80 NSCC, -- 04a/ i I ID=6.875'(OLD SDTRK WINDOW) , t•� • [4-1/2'LMR.,12.6#,L-80 NSCT,ID=3.958" EE —9128 :::411 1� 1 1\: I 9100° --I TOP OF C13.4aff 2-7/8"WF*'STOCK(11126/100 —1 9360' a a [3-3/16'CSG,6.2#,L-80 TLS,.0076 bpf,0=2.80" —9362 3-3116'MLLOUT WE°/DOW(E-358)9351'-9357' FERFORATION S&LA+fa+iARY RIF LOG: SLB Ma#ATIEXRRESS(FLEX) '4P.4 --i®880' TOC(09/11/17) Ga/RES/NE3Y DEN ON 12/03/10 ANGLE AT TOP PERF: 24°@ 11080' L PBTD i— 11163' Note:Refer to Production DB for historical pert data ��4�������* SIZE 92' 6 898386 AL C qZ SHOT SO 12/13/008 RSH BKR B/-/A — 10863' ,•'♦'•,4 40,001.01,1,,.� 1-11/16" 6 11080-11110 S 12/06/10 09/11/17 14.23'LONG(09/12/17) 4��i�'�'0�.,.., •x.00 2-3/8"LIAR,4.71#,L-80 STL,.0039 bpf,ID=1.992" --I 11200' •j t DATE REV BY COMMENTS DATE REV BY COMIAWTS FRLDHOE BAY LWT 06/11/95 L COMPLETION 02112/11 AK/PJC*MAL DRLG CORRECTIONS WELL E35B 07106101 NORDIC 1 CTD SIDETRACK(E-354) 02/27/11 AK/PJC DRLG CORRECTON4S PET4u1T No:r2101600 12/07/10 NORDIC 1 CTD SIDETRACK(E-358) 05/27/14 PJC LIAR/CSG/TBG CORRECTIONS-TIONS API No: 50-029-22557-02 12/09/10 PJC 'DRLG DRAFT CORRECTIONS 08/28/17 AIGS/JMD GLV 00(08/25/17) SEC 6,T11 N,R14E,1187'FNL&501'F13 01/09/11 ET/PJC GLV C/0(01/05/11) 09/18/17 MSS/..IND GMT SQZ&SET FISH 01/09/11 E17 PJC P. 0 CORRECTION 10/16/17 M+JM) OORRECTED FISH 087TH BP Exploration(Alaska) RECEIV D 2N0-wz,0 WThill BAKER JUN 15 2Uk, PRINT DISTRIBUTION LIST HUGHES A'"1OG C( Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc BP Exploration (Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED (0 WELL NAME E-35B 900 E.Benson Blvd. ra/2o1't �I K. BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit ,to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE May 16,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares anbakerhughes.com TODAYS DATE June 7,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF, META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF I'KIN IS #OF COPIES #OF COPIES #OF COPIES N,7 v v v v + 1 Baker Hughes,Inc. 0 0 795 E.94th Ave. Anchorage,AK 99515 Attn: Arelys Carolina Martinez Patrick Rider 2 ConocoPhillips Alaska Inc. 1 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 1 1 Attn:James Hyun 550 West 7th Avenue,Suite 802 SCANNED JUN 2 7 2017, Anchorage,Alaska 99501 ,+�" **Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Gerardo Cedillo TOTALS FOR THIS PAGE: 0 0 TOTALS FOR ALL PAGES: 0 3 4 0 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o2 L 0 - / L 0 Well History File Identifier Organizing (done) ❑ Two-sided III HIJII 1111(fill ❑ Rescan Needed III 111111111 111 111 RES AN DIGITAL DATA OVERSIZED (Scannable) C or Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: X her, No/Type: CP NO. ,,, Other Items Scannable by a Large Scanner Loq$ ❑ Poor Quality Originals: �J OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: CM:.ri Date: 4/7)1/4. ,s, re Project Proofing 11111111111111111 BY: C.Maria Date: 14 /9- /s/ niP Scanning Preparation I x 30 = 3 0 + o2, 4k. = TOTAL PAGES 6 (Count does not include cover sheet) BY: 40, Date: 14-.17/ /4 /s/ fyi Production Scanning I IIIIIIIIM IIIII Stage 1 Page Count from Scanned File: '7. (Count does include cover heet) Page Count Matches Number in Scanning Preparation: ES NO BY: �� -- Date: 41 /s/ rvp J/L/ Stage 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. 111111111111111111 ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 1111111 III I 0 j c Li >, >, O z O N O U U O < < O - h ;o Zr‘ it ain ti Z X rt ''a) �'a) N Z O ~ Z O O JIll Ea)� -IE N = W 0 X Q-'a a Q- CC O 5 a)O c �L O C o) U aNi c J c Q 0 N �.grn torn o ) >- I a) Z 0 0p 00 ce -- aNi mJ s_1 ai J J N ,I CO E,U8TO C7 �� y� Cl- t w o c N W o c N o I Z ! 2 U E > a >tn >� p U a w.w 6 m 3 ..w m 3 z 7 1 w0 i a)CC (n O (A Q w Q a >> a N ='a a) O O ='a a) 7 0 E. 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O Cl) Cl) N o 0 j n (n CC °3 aaa0MaCZ U N CD C C CO 0 0 w O 0 0 O) (0 0 O CO 'iI (Ea > > ED_ > > > > E E > > c rn Z a) N c U c c c CO CO c c Z Z a a C7 C7 , 0 i a E o a , Z o "j d 0) N 0) o O J ,o 0) co 7 0 co IS 0 Co co v c O Q Z y c W O Z N N N w Q O o a) N O Q0 CO� .+ d y F. U. Z r V 0 .5 ti N co N y j R E Q' O Z a' ..- w O)- J J J J I N Z Wr LL a) 01 i Q ir, 2 \ � .0 .� U v\ \ 0 , .- m w Q a y o)c a 0 p n p p a D 0 0 0 0 0 u d Q. G H 5 J o I-I J W a' W W a' W J J J J J W O O o 1 I N Z I: 1 N N U I , O , N Z Q /')i ✓I _1 n U O r_- Z r" • N I °3 R F— a in 0 Q Zz CL • U }17-• U J g 1 Ce a v 1 W w U Q. m o Z - CY o j .:(a z Q U) ° ` j m 7 C0 0H mewl °. o , II C p/i GO 0 u N 11 O p E I U ^ U J m Q N M W F- E O Z o N /� Q N W m r W • a) O `° 0 Q cc • a) Q Z E 0! D o TO U Z • M N H O 11 Z 1I1 O Hs Z m 1 t 1 „a O a) d N 0 Z 1• a5) F. N J Q' D N Q a) 1 i6 V Z 13 U P• C 1 as - H Q U a > 0 E a 0 0 t c O O a) a) a)2 ¢ 0 <cc 0 0 ,i , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 12/7/2010 Sly) 210-160 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 11/28/2010 50-029-22557-02-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 12/2/2010 PBU E-35B 1187'FNL,501'FEL,SEC.06,T11 N,R14E, UM 8. KB(ft above MSL): 65.29' 15.Field/Pool(s): Top of Productive Horizon: 2043'FNL,5215'FEL,SEC.05,T11 N,R14E, UM GL(ft above MSL): 30.50' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 2037'FNL,5185'FEL,SEC.05,T11 N,R14E, UM 11163' 9205' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 664470 y- 5975877 Zone- ASP4 11202' 9243' ADL 028304 TPI: x- 665057 y- 5975033 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 665087 y- 5975040 Zone- ASP4 N/A 18.Directional Survey: ®Yes 0 No 19.Water depth,if offshore: 20. Thickness of Permafrost(ND): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: GR, ROP, RES, Multi Express GR,CCL,AND, Memory CNL, GR,CCL 9351' 8815' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 117' Surface 117' 30" -260 sx Arctic Set 10-3/4" 45.5# NT80 35' 3627' 35' 3622' 13-1/2" 1175 sx CS III.375 sx Class'G' 7-5/8" 29.7# L-80 33' 9123' , 33' 8795' 9-7/8" 485 sx Class'G' 4-1/2" 12.6# L-80 8862' 9123' 8736' 8795' 6-3/4" Uncemented Slotted Liner 3-3/16"x 2-Ire" 6.2#/6.16# L-80 8684' 9351' 8637' 8815' 3-3/4" 1017 sx(1180 cu ft) 'G'/Uncemented Slotted Liner 2-3/8" 4.7# L-80 8642' 11200' 8605' 942' 3" 50 sx Class'G' 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 1-11/16"Gun Diameter,6 SPF 4-1/2", 12.6#, L-80 8750' 8703'/8650' MD ND MD ND 11080' 11110' 9126'-9154' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. x,0 i , ti Iu,, : DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED s 2500' Freeze Protected with 38 Bbls Diesel 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): Not On Production N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(coRR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laborant I per C 250.071. None iAN 21 2011 RBDMS JAN 2 0 201Vg ;a Cafis.C -,Ii i SioA Alaska � Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 74._ 3 bri� a��; ft�,nge Submit Original Only (� !9. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? 0 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 MC 25.071. Shublik A 9390' 8833' Shublik B 9427' 8855' None Shublik C 9483' 8890' Top Sadlerochit/Zone 4B 9525' 8910' TCGL/Zone 3 10841' 8966' BCGL/Zone 2C 10944' 9019' 22TS/Zone 2B(Lower Unit) 11078' 9124' 21TS/Top Zone 2A 11126' 9169' PGOC 10970' 9036' HOT 11000' 9058' OWC/POWC 11143' 9185' TD 11202' 9243' Formation at Total Depth(Name): 31.List of Attachments: Summary of Daily Drilling Reports,Well work summary,Well Schematic Diagram and Surveys. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. (� 1 Signed: Sondra ur?)\` -_ Title: Drilling Technologist Date: C)t PBU E-35B 210-160 Prepared By Name/Number. Sondra Stewman, 564-4750 Well Number Permit No./Approval No. Drilling Engineer: Sean McLaughlin,564-4387 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 la: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 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 MC 25.071. Form 10-407 Revised 12/2009 Submit Original Only TREE= 4-1/16" E 3 5 B WELLHEAD= 5MM FMC MC � SAFETY NOTES: WELL ANGLE>70°@ 9560'*** ACTUATOR= BAKER PJC DRAFT KB. ELEV = 65.29' ri L BF. ELEV = 34.79' KOP= 8349' 20"CONDUCTOR, 115' Max Angle= 97°@ 9194' 2205' —4-1/2"HES HXO SSSV NIP,ID=3.813" 91.5#, H-40, Datum MD= 9442' Datum TVD= 8800'SS ID=19.124" GAS LIFT MANDRELS 10-3/4"CSG,45.5#, NT-80 BTC, ID=9.950" — 3627' L ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4053 4048 0 MER DOME BK-5 16 01/05/11 2 6731 6726 0 MER DOME BK-5 16 01/05/11 Minimum ID = 1.780" @ 8648 ' 1 8126 8120 0 MER SO BK-5 20 01/05/11 2.70" BTT DEPLOY SLEEVE 8642' —3.70"BKR GUIDE SLEEVE w/XO,ID=1.810" TOP OF 2-3/8"LNR --1 8648' 1-4 L ' 8648' —2.70"BTT DEPLOY SLV,ID=1.780" rl / 8689' —BKR LOC SUB/SEAL ASSY,ID=2.39" 8691' —3-1/2"BKR DEPLOY SUB, ID=3.00" TOP OF 2-7/8"LNR 8691' I--- .1-1 8691' J— 4-1/2"HES X NIP, ID=3.813" / _----1 8702' I—3-1/2"X 3-3/16"XO, ID=2.786" R Cillr — 8703' —7-5/8"X 4-1/2"BKR SABL-3 PKR W/K A NCH,ID=3.87" ' , 8727' —4-1/2"HES X NIP, ID=3.813" ' ' 8738' —14-1/2" HES XN NIP, ID=3.725" 4-1/2"TBG, 12.6#,L-80 NSCC, .0152 bpf, ID=3.958" —{ 8750' I---/ \ 1 8750' —14-1/2"WLEG, ID=3.958" 8747' —ELMD TT LOGGED 4/18/97 TOP OF 4-1/2" LNR --I 8862' HE . 8862' I—7-5/8"X4-1/2"11W HBBP PKR,W/SCP TOP, ID=3.920" 7-5/8"CSG, 29.7#, L-80 NSCC, — 8998' I 4-1/2"MILLOUT WINDOW (E-35A)9123'-9128' ID=6.875"(OLD SDTRK WINDOW) 4-1/2"LNR, 12.6#, L-80 NSCT, ID=3.958" —I —9128 I 2-7/8"WHIPSTOCK(11/26/100 —1 9350' / 3-3/16"MILLOUT WINDOW(E-35B)9352'-????' 3-3/16"CSG,6.2#,L-80 TON, .0076 bpf, ID=2.80" —93521.\\11 T I PERFORATION SUMMARY REF LOG: MEM CNL,-GR/CCL ON 77777? ANGLE AT TOP PERF: 24°@ 11080' / PBTD — 11163' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 8981 -9386 0 12/13/08 1-11/16" 6 11080- 11110 0 12/06/10 2-3/8"LNR,4.7#, L-80 STL, .0039 bpf, ID=1.992" — 11200' i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/11/95 N28E ORIGINAL COMPLETION WELL: E-35B 07/05/01 NORDIC 1 CTD SIDETRACK(E-35A) PERMIT No: 2101600 ! 12/07/10 NORDIC 1 CTD SIDETRACK(E-35B) API No: 50-029-22557-02 12/09/10 PJC DRLG DRAFT CORRECTIONS SEC 6,T11 N,R14E, 1187'FNL&501'FEL i 01/09/11 ET/PJC GLV C/O(01/05/11) 01/09/11 ET/PJC MIN ID CORRECTION BP Exploration(Alaska) North America ALASKA-BP Page 1 of 10 Operation Summary Report Common Well Name:E-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site: PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292255700 Active Datum: E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/23/2010 18:00 - 19:00 1.00 MOB P PRE RIG RELEASE FROM 04-22AL1 AT 18:00. 19:00 - 19:30 0.50 MOB P PRE PJSM TO PULL OFF WELL. 19:30 - 20:30 1.00 MOB P PRE PULL OFF WELL. 20:30 - 00:00 3.50 MOB P PRE MOVE RIG FROM DS 4 TO E PAD. 11/24/2010 00:00 - 10:30 10.50 MOB P PRE MOVE FROM DS-4 TO E-PAD. 10:30 - 12:00 1.50 MOB P PRE R/U T MATS AND SPILL CONTAINMENT AROUND E-35B.CLOSE ALL VALVES ON TREE.PREP WELL TO SPOT RIG OVER. 12:00 - 18:00 6.00 MOB P PRE WAIT ON NORDIC CAMP TO ARRIVE AT E-PAD TO GET PAST E-35B BEFORE SPOTTING RIG OVER WELL. 18:00 - 19:00 1.00 MOB P PRE PJSM FOR BACKING OVER WELL.REVEIW NORDICS BACKING OVER WELL PROCEEDURE. SPOT RIG OVER E-35B. RIG ACCEPTED ON E-35B AT 19:00 HRS. 19:00 - 20:00 1.00 MOB P PRE R/U OUTSIDE EQUIPMENT. 20:00 - 00:00 4.00 MOB P PRE PJSM.R/U AND LOWER 2 3/8"REEL. FOUND CRACKED WELDS ON REEL DRIVE PINS. CALL OUT SLB WELDER TO REPAIR. 11/25/2010 00:00 - 00:30 0.50 MOB N RREP PRE REPAIR CRACKED WELDS ON REEL DRIVE PINS. 00:30 - 01:30 1.00 MOB P PRE PJSM. P/U AND SECURE 2"REEL. 01:30 - 08:30 7.00 BOPSUR P PRE PJSM.N/U BOPE.C/O RAMS FOR 2"CTB. SERVICE BOP VALVES.SERVICE MASTER AND SWAB VALVES. 08:30 - 09:00 0.50 BOPSUR P PRE FUNCTION BOPE. 09:00 - 11:00 2.00 BOPSUR P PRE PJSM.TEST BOPE TO 250 PSI AND 3500 PSI. BOPE TEST WHITNESS WAVIED BY JOHN CRISP.AOGCC SIMULTANEOUS TO BOPE TEST,PERFORM TOP END JOB ON GENERATOR. FIND A CAMSHAFT THAT NEEDS REPLACED. CONFER W/TOWN NORDIC AND TOWN BP- AGREE TO CONTINUE WITH WELLWORK OPERATIONS WITH ONLY ONE GENERATOR UNTIL WINDOW IS MILLED. 11:00 - 11:30 0.50 BOPSUR P PRE GREASE CREW OPENED SSV. 11:30 - 18:00 6.50 BOPSUR P PRE CONTINUE TESTING BOPE. ALL BOPE TESTED AGAINST THE SWAB VALVE. TESTED MASTER VALVE AND TWC TO 250 PSI AND 3500 PSI. 18:00 - 00:00 6.00 BOPSUR P PRE PJSM.C/O ROLLERS ON GOOSENECK. INSTALL PRESSURE BULKHEAD. PULL 2"COIL TO RIG FLOOR. 11/26/2010 00:00 - 01:30 1.50 BOPSUB P PRE C/O PACK OFF FOR 2"CTB. STAND BACK INJECTOR. Printed 1/20/2011 12:58:29PM North America-ALASKA-BP Page 2 of 10 Operation Summary Report Common Well Name:E-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site: PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 03:00 1.50 BOPSUB P PRE PJSM.VERIFY CERTS.R/U LUBRICATOR AND TEST TO 250 PSI AND 3500 PSI. PULL TWC,CLOSE MASTER VALVE AND SSV FOR TWO BARRIERS ON WELL. R/D LUBRICATOR AND LOAD OUT. 03:00 - 03:30 0.50 BOPSUB P PRE PJSM.ISOLATE CHOKE, M'U BOP CAP. PUMP OPEN SSV. OPEN MASTER VALVE. 90 PSI ON WELL. 03:30 - 06:00 2.50 BOPSUB P PRE SPEAR INTO WELL W/5 BBLS NEAT MEOH. KILL WELL PUMPING 8.4 PPG KCL W/0.5% "CFS-520"METAL-TO-METAL FRICTION REDUCING AGENT. RAMP PUMP UP TO 4.5 BPM AT 2500 PSI. PUMP 206 BBLS KCL TOTAL. DOWN ON PUMP. FLOW CHECK WELL FOR 30 MINUTES- GOOD. FILL UP WELL AFTER FLOW CHECK W/—2 BBLS. BLEED OAP FROM—500 PSI TO—130 PSI. 06:00 - 11:00 5.00 BOPSUB P PRE SHIFT CHANGE. KEEP WELL FULL PUMPING ACROSS THE TOP,TAKING—10 BPH KCL. PJSM. CHECK ELINE-1100 MEG AND 51 OHM GOOD. STAB ONTO PUMP SLACK BACK. PT INNER REEL VALVE AND PO AND CHART TESTS-BOTH PASSED. CUT 275'CT TO FIND WIRE. TEST WIRE-1000 MEG AND 52 OHM-GOOD. 11:00 - 14:30 3.50 BOPSUB P PRE OPEN TO WELL. FILL HOLE W/15 BBLS KCL. HEAD-UP BHI AND TEST CONNECTIVITY-420 MEG AND 51 OHM-GOOD. PT AND CHART CTC,GOOD. PT AND CHART CHECKS(FROM BELOW)-GOOD. STAB ON W/NOZZLE, PUMP SLACK FORWARD. 14:30 - 16:00 1.50 WHIP P WEXIT BEGIN MU WHIPSTOCK SETTING BHA (CHANGE FROM"PRE"PHASE TO"WEXIT' PHASE. MU BHI BHA W/GR/CCL/HOT W/BTT WS SETTING ASSEMBLY(SCRIBE WS TO HOT). HOLE STILL DRINKING AT—10 BPH. STAB ON W/WHIPSTOCK. 16:00 - 18:20 2.33 WHIP P WEXIT OPEN EDC. ONLINE DOWN CT W/2%KCL W/ 0.5%CFS-520 THROUGH OPEN EDC AT 550 PSI AT 0.65 BPM W/—80%RETURNS. BEGIN RIH W/3-3/16"BTT MONOBORE WHIPSTOCK ON BAKER 10 HYDRAULIC SETTING TOOL. 17:20-RIH AT 4775'MD PUMPING AT 0.66 BPM AT 590 PSI THROUGH OPEN EDC W/5% LOSSES(ACCOUNTING FOR CT DISPLACEMENT). PVT:266 BBL. 18:20 - 19:30 1.17 WHIP P WEXIT LOG GR TIE IN 9130'-9168'.NEGATIVE 2' CORRECTION. LOG CCL TO DOUBLE CHECK COLLAR LOCATION 9100'-9320'.MATCHES PDC LOG. 19:30 - 19:45 0.25 WHIP P WEXIT PICK UP TO WS SETTING DEPTH TO 9350'AT 240 DEG.CLOSE EDC. RESSURE UP TO 3000PSI AND SHEAR OFF WS. PVT 265 @ 19:30.SAT DOWN 2K.PICK UP EASY. Printed 1/20/2011 12:58:29PM North America-ALASKA-BP Page 3 of 10 Operation Summary Report Common Well Name:E-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project: Prudhoe Bay Site: PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292255700 Active Datum: E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:45 - 21:00 1.25 WHIP P WEXIT PULL OUT OF HOLE AT 65 FPM. PUMPING 1.25BPM. 21:00 - 22:15 1.25 WHIP P WEXIT GRAYLOC FITTING ON HARDLINE BETWEEN MUD PUMP AND REEL, FOUND DRIPPING IN THE PIPE SHED. BLEED DOWN PRESSURE AND ATTEMPT TO TIGHTEN. STILL DRIPPING. POOH AT 95 FPM. FILL HOLE 1.31 BPM DOWN BACKSIDE THROUGH KILL LINE WHILE POOH. PVT 239 BBL @ 21:00.LOOSING 4 BPH. 22:15 - 22:30 0.25 WHIP P WEXIT PJSM TO LD WS SETTING BHA. 22:30 - 22:45 0.25 WHIP P WEXIT POP OFF WELL AND LD WS BHA. 22:45 - 23:00 0.25 WHIP P WEXIT FP REEL WITH METHONAL. 23:00 - 00:00 1.00 WHIP N RREP WEXIT PJSM TO CHANGE OUT GRAYLOC FITTING. CHANGE OUT GRAYLOC FITTING ON HARDLINE BETWEEN MUD PUMP AND REEL. PRESSURE TEST,STILL LEAKING. 11/27/2010 00:00 - 00:30 0.50 WHIP N RREP WEXIT PJSM TO CHANGE OUT HARD LINE. 00:30 - 06:00 5.50 WHIP N RREP WEXIT CHANGE OUT HARD LINE IN PIPE SHED FROM REEL HOUSE TO MANIFOLD. DUE TO CORROSION IDENTIFIED WHILE REPLACING FAILED GRAYLOC FITTING. REPLACING W/2"IRON. NOTE:CORROSION ISSUE MAKES THIS BP DOWNTIME,NOT NORDIC DOWNTIME. 06:00 - 13:00 7.00 WHIP N RREP WEXIT KEEP HOLE FULL BY PUMPING 2%KCL ACROSS THE TOP DURING HARDLINE REPLACEMENT WORK. WELL TAKING—10 BPH. CALL FOR ADDITIONAL HARDLINE TO BE DELIVERED FROM CH2MHILL. CONIRM CERTIFICATION OF SAME. INSTALL HARDLINE AND PREPARE TO PRESSURE TEST REPLACED IRON. NOTE:THIS HARDLINE RUN IS 2"IRON. 13:00 - 14:30 1.50 WHIP N RREP WEXIT TEST NEW INSTALLATION TO 250 PSI/5000 PSI AND CHART TESTS. GOOD. 14:30 - 15:00 0.50 WHIP P WEXIT END BP NPT. REGROUP,DEBRIEF HARDLINE WORK. PJSM FOR MU MILLING ASSEMBLY. 15:00 - 16:45 1.75 STWHIP P WEXIT INSTALL CHECKS IN BHA. TEST CHECKS FROM BELOW 250 PSI/1500 PSI. MU WINDOW MILLING ASSEMBLY W/2 JTS CSH ABOVE MOTOR,2.70"SPIRAL CENTRALIZER ABOVE MOTOR,BTT 2-1/8" EXTREME MOTOR,STRING REAMER AND HCC WINDOW MILL. REAMER AND MILL BOTH GAUGED AT 2.74"GO/2.73"NO-GO. 16:45 - 18:00 1.25 STMILL P WEXIT RIH W/WINDOW MILLING ASSEMBLY. 17:00-RIH AT 3000'PUMPING KCL AT 0.66 BPM AT 930 PSI W/—10 BPH LOSSES. 18:00 - 18:30 0.50 STMILL P WEXIT RIH W/MILLING BHA. PVT 158BBLS AT 9,000'PUMPING KCL AT 0.66BPM AT 800PSI 18:30 - 19:45 1.25 STWHIP P WEXIT LOG A TIE IN RUN FROM 9020' 2.0 FPM,0.65 BPM,820 PSI Printed 1/20/2011 12:58:29PM North America-ALASKA- BP Page 4 of 10 Operation Summary Report Common Well Name:E-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project: Prudhoe Bay Site: PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum: E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:45 - 20:00 0.25 STMILL P WEXIT LITTLTE MOTOR WORK-PRESSURE UP FROM 802 TO 1600 PSI, IN AND OUT RATES DROPPED AND CT WT DROPPED AT 9,162'. BHA JUST OUTSIDE OLD WINDOW,3-3/16" LINER COULD HAVE A DOG LEG THERE. 20:00 - 20:20 0.33 STMILL P WEXIT LOG TIE IN RUN TO 9,240'. NO CORRECTION,ON DEPTH. 20:20 - 23:15 2.92 STMILL P WEXIT SWAP WELL TO USED QUIKDRIL(GEOVIS)AT 9300'. CAN ONLY PUMP 1.5 BPM 23:15 - 23:50 0.58 STMILL P WEXIT WITH MUD CIRCULATED ALL THE WAY AROUND.PVT 335 @ 23:50 POWER PACK AT IDLE CAN ONLY PUMP 1.15 BPM THROUGH EDC WITH ONE GENERATOR ON LINE. 23:50 - 00:00 0.17 STMILL P WEXIT CLOSE EDC.MAX PUMP RATE.92 BPM WITH EDC CLOSED. 11/28/2010 00:00 - 00:45 0.75 STMILL P WEXIT TAG TOWS AT 9,350'. PAINT FLAG ON COIL. 0.92 BPM,FS 2450 PSI. WOB.97K, DIFF PRESS 100PSI. 00:45 - 01:00 0.25 STWHIP P WEXIT BLEED OA FROM 500 PSI-90 PSI. MOSTLY CRUDE/DIESEL BLED FOR 9 P-LctMINUTES. PVT 330 BBL. • a_35 B 01:00 - 03:00 2.00 STWHIP P WEXIT MILLING WINDOW AT 9351.9'. .93 BPM,PVT 329 BBLS,WOB 1.76K, DIFF PRESS 238 PSI 03:00 - 05:00 2.00 STWHIP P WEXIT MILLING WINDOW AT 9354.1'. 0.92 BPM,PVT 328 BBLS,WOB 1.64K,DIFF /� PRESS 62 PSI F-35 Q 05:00 - 05:30 0.50 STWHIP _ P WEXIT BLEED IA FROM 678 PSI-71 PSI. MOSTLY CRUDE/DIESEL BLED FOR 9 MINUTES. BLEED OA FROM 279 PSI-87 PSI. MOSTLY CRUDE/DIESEL BLED FOR 4 MINUTES. PVT 328 BBL. 05:30 - 06:30 1.00 STWHIP P WEXIT MILLING WINDOW AT 9355.2'. 0.92 BPM,PVT 328 BBLS,WOB 1.36K, DIFF PRESS 100 PSI 06:30 - 11:00 4.50 STWHIP P WEXIT CHANGEOUT. WEEKLY RIG SAFETY MEETING. WEEKLY RIG SAFETY LEADERSHIP TEAM MEETING. 10:30-MILLING OPEN HOLE AT 9363'MD AT 0.1 FPM AT 1.0 BPM AT 2650 PSI(500 PSI DIFFERENTIAL PRESSURE AT THE MOTOR) W/2.2K LB WOB AND 1:1 RETURNS. BHP/ECD/PVT:4374 PSI/9.65 PPG/325 BBL. IAP: 190 PSI. OAP:210 PSI. NOTE: BTT'S NOTES INDICATE: TOWS= TOW=9350.3'MD. BOW=9355.6'MD. MILL OPEN HOLE TO 9365.5'MD. Printed 1/20/2011 12:58:29PM North America -ALASKA- BP Page 5 of 10 Operation Summary Report Common Well Name: E-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site: PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 14:00 3.00 STWHIP P WEXIT PULL INTO CASED HOLE. WAIT TO START RECIP PASSES WHILE NORDIC ATTEMPTS TO START SECOND GENERATOR. GENERATOR OVERHEATING. DRESS WINDOW W/RECIPROCATION PASSES. 13:00-SECOND PASS,RUNNING/PULLING AT 0.6 FPM AT 1.05 BPM AT 2590 PSI(FREESPIN) W/FULL RETURNS. BHP/ECD/PVT:4380 PSI/ 9.67 PPG/324 BBL. 14:00 - 18:30 4.50 STWHIP P WEXIT POH WITH WINDOW MILL. OPEN EDC AT 8,660'. POH. TEST#2 GENERATOR. 18:30 - 19:00 0.50 STWHIP P - WEXIT PJSM.POP INJECTOR OFF WELL. 19:00 - 19:30 0.50 STWHIP P WEXIT LD WINDOW MILLING BHA. 19:30 - 19:45 0.25 DRILL P PROD1 PJSM TO MU DRILLING BUILD BHA. 19:45 - 20:00 0.25 DRILL P PROD1 MU DRILLING BUILD BHA. 20:00 - 20:10 0.17 DRILL P PROD1 STAB,INJECTOR ON WELL. 20:10 - 22:20 2.17 DRILL P PROD1 RIH @ 3,000'WITH.57BPM,95FPM,1765 PSI, PVT 300 BBL. BOTH GENERATORS ON LINE AND TESTED GOOD. 22:20 - 22:40 0.33 DRILL P PROD1 TIE IN RUN FROM 9,140'-9,160'. CORRECTION -2'. 22:40 - 23:10 0.50 DRILL N SFAL PROD1 ELECTRICITY TO SATALITE CAMP SHUT DOWN.NO POWER TO BAKER INTEQ. 23:10 - 00:00 0.83 DRILL P PROD1 ON BOTTOM 9366'DRILLING.FS 3500PSI. ECD 9.75, 1.5 BPM,3685 PSI, ROP 46 FPH, PVT 320 BBLS, IA 32 PSI,OA 68 PSI. AFTER LOGGING ACROSS THE RA TAG THE CORRECTED TOWS=TOW=9351.2'.RA TAG =9356.4'.BOW=9356.5'. 11/29/2010 00:00 - 04:00 4.00 DRILL P PROD1 DRILLED TO 9,477'. 04:00 - 04:10 0.17 DRILL P PROD1 SHORT TRIP TO WINDOW FROM 9,477'. 04:10 - 04:30 0.33 DRILL P PROD1 BACK ON BOTTOM DRILLING. PUMPING 1.6BPM,3800 PSI. 04:30 - 07:30 3.00 DRILL P PROD1 POOH FOR BALLED BIT OR MOTOR FAILURE. WILL NOT STALL OR DRILL. 1.65 BPM,93FPM,3040PSI. 07:30 - 08:00 0.50 DRILL P PROD1 PJSM.BHA,C/O MUD MOTOR.SET 2.3 DEGREE MOTOR BEND. INSPECT BIT, FOUND A PIECE OF RUBBER IN BIT,1/4"X 3/4"STUCK IN NOSE. BIT HAD 2 CHIPPED CUTTERS ON WING.BIT IN GAUGE RR BIT. 08:00 - 10:15 2.25 DRILL P PROD1 RIH,TIE IN AT 9365',-3'DEPTH CORRECTION. 10:15 - 13:50 3.58 DRILL P PROD1 DRILLING BUILD SECTION FROM 9.477'. TIE IN AT 9,365',-3'DEPTH CORRECTION. 3,550 PSI,3K-3.5K BIT WT.PUMPING AT 1.51 BPM. PIT VOLUME 323 BBLS. DRILL TO 9650'. 13:50 - 16:15 2.42 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 9650' 16:15 - 18:20 2.08 DRILL P PROD1 DRILLING BUILD SECTION FROM 9650' Printed 1/20/2011 12.58:29PM • 0 North America -ALASKA- BP Page 6 of 10 Operation Summary Report Common Well Name: E-35 AFE No Event Type: RE-ENTER-ONSHORE (RON) Start Date: 11/23/2010 End Date: 1X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site: PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:20 - 20:50 2.50 DRILL P PROD1 LANDED WELL AT 9750'. POOH FOR LATERAL BHA. PVT 314,IA 131,OA 115. 20:50 - 21:00 0.17 DRILL P PROD1 PJSM TO LD AND PU BHA. 21:00 - 21:15 0.25 DRILL P PROD1 TAGGED UP AND POP INJECTOR OFF WELL. LD BUILD BHA#4.HYC TREX BIT CAME OUT 2,3. 21:15 - 22:00 0.75 DRILL P PROD1 MU LATERAL BHA#5 WITH USMPR, 1.1 BEND MOTOR AND NEW BIT. 22:00 - 00:00 2.00 DRILL P PROD1 STAB INJECTOR ON WELL AND RIH. 0.5 BPM,PVT 274. 11/30/2010 - DRILL P PROD1 DRILL LATERAL SECTION FROM 10.654'TO 1.52 BPM IN,1.54 BPM OUT,3915 PSI ON MW IN 8.71 PPG,MW OUT 8.80 PPG WOB 1.84 K,ECD 10.08 PPG 00:00 - 00:10 0.17 DRILL P PROD1 CONTINUE TO RIH WITH LATERAL DRILLING BHA. 00:10 - 00:50 0.67 DRILL P PROD1 LOG A TIE IN FROM 8,940'TO 9,022'. -4'CORRECTION. 00:50 - 04:30 3.67 DRILL -P PROD1 MAD PASS DOWN FROM 9,022'TO 9,750'. -3.2FPH,.51 BPM,1780 PSI,IA AND OA=0 PSI, PVT 276. 04:30 - 05:30 1.00 DRILL` P PROD1 ON BOTTOM DRILLING AT 9750'.FS 3340PSI. PUMPING 1.5 BPM,3800 PSI,PVT 304BBLS, DWOB 2.25K,ROP 127 FPH. 05:30 - 05:45 0.25` DRILL P PROD1 DRILLING LATERAL SECTION AT 9878'.1.54 BPM,3900 PSI,DWOB 2.5 K,ROP 151 FPH, PVT 303 BBLS. IA 22 PSI,OA 0 PSL DRILLING TO 9901' 05:45 - 06:30 0.75 DRILL P PROD1 WIPER TRIP FROM 9901TO SHOE. 06:30 - 08:50 2.33 DRILL P PROD1 DRILLING LATERAL SECTION FROM 9901'TO 10,050'. 08:50 - 09:45 0.92 DRILL P PROD1 WIPER TRIP FROM 10,050'TO SHOE. 09:45 - 12:00 2.25 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,050' TO 10,200' 12:00 - 13:10 1.17 DRILL P PROD1 WIPER TRIP FROM 10,200'TO SHOE. 13:10 - 14:40 1.50 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,200' TO 10,354' 14:40 - 15:40 1.00 DRILL P PROD1 WIPER TRIP FROM 10,354'TO SHOE. 15:40 - 18:00 2.33 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,354' TO 10,500' 18:00 - 19:30 1.50 DRILL P PROD1 WIPER TRIP FROM 10,500'TO SHOE. 19:30 - 21:00 1.50 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,500 TO 10,654' 1.52 BPM IN,1.54 BPM OUT,3915 PSI ON MW IN 8.71 PPG,MW OUT 8.80 PPG WOB 1.84 K,ECD 10.08 PPG 21:00 - 21:55 0.92 DRILL P PROD1 WIPER TRIP TO WINDOW. CONDUCT TIE IN WITH RA TAG,+1 CORRECTION. 21:55 - 22:30 0.58 DRILL P PROD1 RIH TO 10,654' 22:30 - 00:00 1.50 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,654' TO 10,752' 1.47 BPM IN,1.49 BPM OUT,3660 PSI ON MW IN 8.71 PPG,MW OUT 8.74 PPG WOB 1.44 K, ECD 10.08 PPG Printed 1/20/2011 12.58:29PM 1 North America -ALASKA- BP Page 7 of 10 Operation Summary Report Common Well Name: E-35 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project: Prudhoe Bay Site: PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum: E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/1/2010 - DRILL P PROD1 00:00 - 01:15 1.25 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,752' TO 10,800' 1.47 BPM IN,1.52 BPM OUT,3840 PSI ON BOTTOM. MW IN 8.71 PPG,MW OUT 8.80 PPG WOB 1.23 K,ECD 10.08 PPG 01:15 - 04:30 3.25 DRILL P PROD1 WIPER TRIP TO WINDOW. PREPARE FOR MUD SWAP,CLEAN INACTIVE PITS. 04:30 - 05:15 0.75 DRILL P PROD1 RIH TO 10,800' 05:15 - 07:00 1.75 DRILL P PROD1 DRILL AHEAD,SWAP TO NEW 8.5 PPG • QUIKDRIL MUD SYSTEM. 1.61 BPM IN,1.61 BPM OUT,3480 PSI ON MW IN 8.5 PPG,MW OUT 8.7 PPG WOB.95-1.55 K, ECD 10.08 PPG DRILL TO 10,880' 07:00 - 08:00 1.00 DRILL P PROD1 WORK PIPE,FINISH MUD SWAP. PVT 340 BBLS. 08:00 - 10:05 2.08 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,880' TO 10,906' ROP GRADUALLY DROPPED FROM 45 FPH TO 3-5 FPH. 1.52 BPM IN. 1.5 BPM OUT.3340 PSI ON BOTTOM WOB2-3K, ECD 10.08 PPG MW IN 8.51 PPG.,MW OUT 8.56 PPG., 10:05 - 13:10 3.08 DRILL P PROD1 POH FOR BIT. HOLE CLEAN TO WINDOW. POH TO 9332',OPEN EDC. CONT.POH 13:10 - 14:00 0.83 DRILL P PROD1 PJSM.SET BACK INJECTOR.PVT 298 BBLS. INSPECT BHA,UD BIT. BIT-RUNG OUT ON SHOULDER,2-8,WORN TEETH, IN GAUGE. 14:00 - 14:30 0.50 DRILL P PROD1 INSPECT INJECTOR CHAINS. 14:30 - 15:00 0.50 DRILL P PROD1 M/U LATERAL BHA#6,T-REX BIT RR2, USMPR,1.1 MOTOR BEND. M/U INJECTOR.SURFACE TEST COIL TRAC. 15:00 - 18:00 3.00 DRILL P PROD1 RIH,TIE IN AT 9389', 1/2'CORRECTION. 18:00 - 19:45 1.75 DRILL P PROD1 DRILLING LATERAL SECTION FROM 10,906' TO 11,050' 1.54 BPM IN, 1.52 BPM OUT, 3340 PSI ON BOTTOM WOB 2-3 K, ECD 9.08 PPG MW IN 8.52 PPG.,MW OUT 8.56 PPG 19:45 - 21:40 1.92 DRILL P PROD1 WIPER TRIP TO WINDOW WITH NO PROBLEMS. 21:40 - 23:30 1.83 DRILL P PROD1 DRILLING LATERAL SECTION FROM 11,050' TO 11,200';COLLECT GEO SAMPLES EVERY 25'. 1.52 BPM IN, 1.51 BPM OUT,3585 PSI ON BOTTOM WOB 1.43-1.89 K, ECD 9.98 PPG MW IN 8.53 PPG.,MW OUT 8.57 PPG 23:30 - 00:00 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW 12/2/2010 00:00 - 01:45 1.75 DRILL P PROD1 WIPER TRIP TO WINDOW AND BACK TO TD OF 11,200'. NO ISSUES NOTED UP TO WINDOW,BACK DOWN TO TD. Printed 1/20/2011 12:58:29PM North America -ALASKA- BP Page 8 of 10 Operation Summary Report Common Well Name: E-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:45 - 05:00 3.25 DRILL P PROD1 POH FROM 11,200'. NO PROBLEMS AT WINDOW. CONTINUE TO POH. OPEN EDC ABOVE 3 1/2"LINER TOP,INCREASE FLOW TO 1.80 BPM,3060 PSI. TAG UP,JOG BACK DOWN TO 500'. POH BACK TO SURFACE. PJSM ON BREAKING DOWN BHA. 05:00 - 05:20 0.33 DRILL P PROD1 BREAK DOWN BHA. NOTICEABLE RINGOUT ON BIT. 05:20 - 05:35 0.25 EVAL P PROD1 FUNCTION TEST BOP. 05:35 - 07:15 1.67 DRILL P PROD1 'CLEAN HIGH PRESSURE SCREENS. CLEAR AND CLEAN RIG FLOOR. CONDUCT SAFETY BRIEF WITH LOGGERS. STAGE LOGGING UNIT ON SITE. 07:15 - 09:15 2.00 EVAL P PROD1 MONITOR WELL.WELL TAKING 1/2 BPH. PVT 274 BBLS. PJSM.PUMP BACK 3 BBLS METHANOL IN COIL. REMOVE BAKER TOOLS AND COIL CONNECTOR. CUT 10'COIL AND REHEAD WITH KENDAL CTC. PULL TEST CTC TO 30K AND PRESSURE TEST TO 3300 PSI. 09:15 - 18:00 8.75 EVAL P PROD1 PJSM.SLB WIRE IN I-FEX TO ELINE. SHORT IN PIN CONNECTION.PIN DAMAGED. REPAIR PIN CONNECTION. TROUBLE SHOOT LOGGING TOOLS. 18:00 - 19:00 1.00 EVAL P PROD1 PJSM ON PICKING UP LOGGING TOOLS. PUMP ACROSS THE TOP,MONITOR PRESSURES. 19:00 - 21:15 2.25 EVAL P PROD1 PICK UP,MU LOGGING TOOLS. TEST ELECTRONIC SIGNALS THROUGH TOOL. GOOD COMMUNICATION. BREAK APART TOOL,INSTALL NUCLEAR SOURCES. COMPLETE TOOL MU. STAB ON,MU INJECTOR HEAD TO LUBRICATOR. 21:15 - 23:00 1.75 EVAL P PROD1 RIH WITH LOGGING BHA TO 145'. CALIBRATE INJECTOR AND SLB LOGGING DEPTH READINGS. CONTINUE TO RIH TO 9000'. �N PUW 28K 23:00 - 23:10 0.17 EVAL P PROD1 BEGIN TRIPLE COMBO LOGGING AT 30 FPM CT`k DOWNHOLE. LOST SIGNAL AT 9261'. 23:10 - 00:00 0.83 EVAL N DFAL 9,259.98 PROD1 TROUBLESHOOT SIGNAL,SUSPECT SHORT. CHECK SURFACE EQUIPMENT. CANNOT FIND FAILURE. POH TO 9130'. 12/3/2010 00:00 - 01:10 1.17 EVAL N DFAL 9,259.98 PROD1 POH WITH LOGGING BHA TO TROUBLESHOOT SIGNAL LOSS FROM 9130'. PJSM ON BREAKIND DOWN BHA. 01:10 - 01:50 0.67 EVAL N DFAL 9,259.98 PROD1 BHA AT SURFACE. CLEAR FLOOR. POP OFF OF WELL. BREAK DOWN BHA. 01:50 - 02:45 0.92 EVAL N DFAL 9,259.98 PROD1 TROUBLESHOOT TOOLS,FIND SHORT IN KNUCKLE OF ONE OF THE CONNECTIONS. REPLACE KNUCKLE WITH SPARE. RE-TEST AND GET GOOD COMMUNICATION. 02:45 - 03:15 0.50 EVAL N DFAL 9,259.98 PROD1 MU INJECTOR HEAD TO WELL. RIH, CALIBRATE DEPTHS BETWEEN COIL OPERATOR AND LOGGING OPERATOR. CONTINUE TO RIH TO 200',VERIFY DEPTHS. Printed 1/20/2011 12:58:29PM North America -ALASKA- BP Page 9 of 10 Operation Summary Report Common Well Name: E-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:15 - 05:00 1.75 EVAL N DFAL 9,259.98 PROD1 RIH WITH LOGGING BHA TO 8900'FOR WEIGHT CHECK. PUW 28K. CONTINUE TO RIH TO 9,000'AT 65 FPM. 05:00 - 06:25 1.42 EVAL P PROD1 LOG DOWN FROM 9000'AT 30 FPM,.2 BPM, 1530 PSI. LOG DOWM TO 11,180'. 06:25 - 08:00 1.58 EVAL P PROD1 LOG UP FROM 11,180'AT 30 FPM,.3 BPM, 1550 PSI. LOG UP TO 9400'CLOSE CALIPER. PUH TO 9221'. 08:00 - 09:10 1.17 EVAL P PROD1 RIH FOR REPEATOR LOG PASS TO 11,180',30 FPM PUMPING 34 BBL 8.53 PPG LINER RUNNING PILL,.6 BPM,2130 PSI. OPEN CALLIPER.PVT 289 BBLS. 09:10 - 09:30 0.33 EVAL P PROD1 LOG UP FROM 11,180'AT 30 FPM,.6 BPM, 2095 PSI. LAYING IN LINER RUNNING PILL WHILE LOGGING UP. LOG UP TO 10,825' 09:30 - 10:30 1.00 EVAL P PROD1 CONTINUE POH PAST WINDOW TO 9300'. LAYING IN LINER PILL. 30 FPM,.58 BPM,1970 PSI. 10:30 - 12:30 2.00 EVAL P PROD1 POH WITH LOGGING BHA. PAINT FLAG ON PIPE AT 8462'FOR LINER TD. AND AT 6562'FOR TOL. HOLD DETAILED PJSM WITH SLB FOR UD LOGGING TOOLS. 12:30 - 14:00 1.50 EVAL P - PROD1 STAND BACK INJECTOR.MONITOR WELL. PVT 245 BBLS. REMOVE RADIOACTIVE SOURCE,UD • LOGGING TOOLS. R/D SLB LOGGING EQUIPMENT AND LOAD OUT.CLEAR RIG FLOOR. WELL CONTINUES DRINKING 1/2 BPH. HOLD AFTER ACTION JOB REVIEW. 14:00 - 18:00 4.00 EVAL P PROD1 PJSM.PUMP SLACK.CUT 210'E-LINE. INSTALL BAKER COIL CONNECTOR.PULL TEST TO 20 K,PT TO 3500 PSL PUMP 3/4 BALL, RECOVER BALL. SET BACK INJECTOR. 18:00 - 19:00 1.00 CASING P RUNPRD CREW CHANGE OUT,CLEAR AND CLEAN RIG FLOOR FOR RUNNING LINER. MOBILIZE AND RU LINER RUNNING TOOLS. 19:00 - 19:15 0.25 CASING P RUNPRD PJSM ON RUNNING LINER. 19:15 - 19:45 0.50 CASING P RUNPRD MU SHOE TRACK ASSEMBLY,1 JT 23/8"STL TUBING,FLOAT COLLAR ASSEMBLY,STAGE COLLAR AND FIRST FIVE JOINTS OF 2 3/8" STL TUBING. AVERAGE MU TORQUE 700 FT/LBS. DRIFT EACH CONNECTION FOR FIRST FIVE CONNECTIONS. 19:45 - 22:30 2.75 CASING P RUNPRD CONTINUE MU LINER PER LINER RUNNING PROGRAM. TOTAL 83 JTS 2 3/8"4.7# L-80 WITH CEMENTRALIZERS. MU SELRT BHA TO LINER ASSEMBLY. MU COIL CONNECTOR. 22:30 - 23:20 0.83 CASING P RUNPRD CLEAR AND CLEAN FLOOR OF LINER RUNNING EQUIPMENT. STAB INJECTOR ONTO WELL. 23:20 - 23:40 0.33 CASING P RUNPRD AAR ON MU.RIH WITH LINER Printed 1/20/2011 12:58:29PM • North America -ALASKA- BP Page 10 of 10 Operation Summary Report Common Well Name: E-35 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 11/23/2010 End Date: X3-00Y24-C(1,613,705.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:40 - 00:00 0.33 CASING P RUNPRD BREAK CIRCULATION TO FILL PIPE,GAIN POSITIVE RETURNS. BEGIN RIH WITH LINER ASSEMBLY. Printed 1/20/2011 12:58:28PM North America -ALASKA- BP Page 1 of 5 Operation Summary Report Common Well Name: E-35 AFE No Event Type: COM-ONSHORE(CON) Start Date: 11/30/2010 End Date: 12/7/2010 X3-00Y24-C(991,295.00) Project:Prudhoe Bay Site: PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: 500292255700 Active Datum: E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/4/2010 00:00 - 02:00 2.00 CASING P RUNPRD RIH WITH 2 3/8"4.7#STL LINER ASSEMBLY ON COIL. PUWATWINDOW 28K. CONTINUE TO RIH. SLB READING WHEN TAG BOTTOM IS AT 11,266.8'. 02:00 - 04:00 2.00 EVAL P RUNPRD CHECK MATH,COUNT PIPE AND THREAD PROTECTORS IN SHED, ENSURE FLAG DEPTHS WERE CORRECT,ENSURE CORRECT BHA LENGTH WAS PLACED BEFORE RUNNING IN ON COIL. POH TO FLAG DEPTH,VERIFY CORRECT MARK. -CONSULT WITH DAY WSL,TOWN ENGINEER. DISCUSS 2.99"ID OF 3 V2" CROSSOVER TO 2.80"ID OF 3 3/16" • MONOBORE LINER. OD OF CENTRALIZER FOR DEPLOYMENT SLEEVE ASSEMBLY IS 3.50". -DECISION IS THAT DEPTH READING IS MOST LIKELY OFF AND TO PROCEED WITH ORIGINAL PLAN TO CEMENT LINER 04:00 - 06:00 2.00 CASING P RUNPRD OBTAIN BREAKOVER WEIGHT AT 32K,SET - BACK DOWN INTO 10K COMPRESSION. DROP 5/8"BALL. PUMP DOWN AT 1.4 BPM, 3800 PSI. SLOW TO.5 BPM,2300 PSI AT 25 BBLS AWAY. INCREASE RATE TO.75 BPM, 2575 PSI. NO LUCK ON SEATING BALL. SHUT DOWN AND BRING ON PUMPS TO"SURGE" AND POSSIBLY SEAT BALL. CONTINUE VARYING PUMP RATES TO SEAT BALL. PU TO BREAKOVER OF 35K TO CONFIRM LINER IS STILL ON RUNNING TOOL. 06:00 - 06:45 0.75 CASING P RUNPRD CREW CHANGE,CONTINUE TO TRY AND GET 5/8"BALL ON SEAT. MIX AND PUMP 10 BBL BIO PILL. .85 BPM, 2600 PSI. BALL ON SEAT AT 06:35HRS.SHEAR AT 3300 PSI. CONFIRM LINER RELEASE, P/U FROM 11,202' TO 11,194"., BREAKOVER WT,21 K. WITH 4'DIFFERENCE,SET BACK DOWN TO 11,202' CALL FOR CEMENTERS. 06:45 - 09:30 2.75 CEMT P RUNPRD DISPLACE WELL WITH 8.4 PPG,80 DEGREE DOUBLE SLICK KCL. 1.5 BPM,2600 PSI. PVT 333 BBLS. 09:30 - 10:30 1.00 CEMT P RUNPRD PJSM. R/U CEMENTERS. 10:30 - 12:45 2.25 CEMT P RUNPRD _PJSM. REVIEW LINER CEMENTING PROCEEDURE. BYPASS REEL FILTERS. ESTABLISH CIRCULATION RATE 1.5 BPM, 2450 PSI.PRIME CEMENT UNIT. (>1'1 BATCH 15 BBLS 15.8 PPSzLINER SLURRY AI 1200 HRS.SEND SAMPLE TO LAB. PUMP 5 BBLS KCL, PT LINES TO 6300 PSI. PUMP 9.4 BBLS CEMENT,ZERO MM. 1.3 BPM, 3600 PSI. CLEANUP CEMENTLINE WITH BIOZAN FROM RIG. Printed 1/20/2011 12:59:36PM North America -ALASKA- BP Page 2 of 5 Operation Summary Report Common Well Name: E-35 AFE No Event Type: COM-ONSHORE (CON) Start Date: 11/30/2010 End Date: 12/7/2010 IX3-00Y24-C(991,295.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35©65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:45 - 13:50 1.08 CEMT P RUNPRD LINE UP RIG PUMP AND PUMP 100 BBLS 2#/BBL BIOZAN,1.3 BPM,3550 PSI. PUMP 26 BBLS,SLOW DOWN PUMP TO.57 BPM.CEMENT AT TOOL. SPEED PUMP TO 1.5 BPM,3450 PSI.PUMP 35.6 BBLS. P/U 13',BREAKOVER WT 2500 AT 11,194'PER BAKER HAND. EXHAUST 2BBLS CEMENT FROM COIL,PUMP 5 BBLS,1.5 BPM. OPEN BAKER CHOKE,STACK 10 K INTO LINER DEPLOYMENT SLEEVE. CLOSE BAKER CHOKE.PRESSURE UP TO SHEAR WIPER PLUG.3000PSI AT.4BPM, PUMP 10 BBLS.7 BPM,2815 PSI TO BUMP WIPER PLUG. PRESSURE UP TO 3500 PSI. SLOWLY BLEED OFF,OPEN BAKER CHOKE, CHECK FLOATS. FLOATS HOLDING. PRESSURE UP 500 PSI,UNSTING.CIP @ 13:40 HRS. R/D CEMENTERS. 13:50 - 16:00 2.17 CEMT - P RUNPRD PUMPING 2#/BBL BIOZAN,SLOWLY POH CONTAMINATING CEMENT TO 7640' CONTINUE TO PUMP BIOZAN POH. 16:00 - 17:00 1.00 CEMT P RUNPRD UD AND LOAD OUT LINER RUNNING TOOLS. / 17:00 - 18:00 1.00 CEMT P RUNPRD PJSM.C/O DIES ON LITTLE JERK TONGS.M/U 2 3/8"LINER CLEANOUT BHA. 1.75 MILL,1"MUD MOTOR. 18:00 - 22:00 4.00 CEMT P RUNPRD CREW CHANGE OUT. CONTINUE MU OF 2 3/8"LINER CLEANOUT BHA. DRIFT DISCONNECTS. 22:00 - 00:00 2.00 CEMT P RUNPRD RIH WITH CLEANOUT BHA TO 8600'. WAIT ON CEMENT TO REACH 500 PSI COMPRESSIVE STRENGTH. UCA ANALYSIS SHOWS 11 HRS, 33 MIN TO REACH 500 PSI. 12/5/2010 00:00 - 02:30 2.50 CEMT P RUNPRD RECIPROCATE COIL WITH CLEANOUT BHA SLOWLY AT 2 FPM,.38 BPM,710 PSI,WHILE WAITING ON CEMENT TO REACH 500 PSI COMPRESSIVE STRENGTH. 02:30 - 04:15 1.75 CEMT P RUNPRD CEMENT AT 500 PSI COMPRESSIVE STRENGTH. RIH TO TOP OF DEPLOYMENT SLEEVE AT 8641', BEGIN CLEANOUT RUN WITH 1.75"MILL AT 30 FPM,.98 BPM,2495 PSI. NO PRESSURE INCREASE NOTED WHILE RUNNING PAST CALCULATED TOP OF DEPLOYMENT SLEEVE OR THROUGH BUSHING ON LOWER DEPLOYMENT SLEEVE. INITIAL TAG AT 11,144'. PU,ATTEMPT TO DRILL PAST OBSTRUCTION AT.98 BPM, 2780-2900 PSI,150 LBS OF MOTOR WORK. ABLE TO DRILL TO 11,146'. -PBTD AT 11,146' 04:15 - 06:45 2.50 CEMT P RUNPRD POH WITH CLEANOUT BHA. 06:45 - 09:30 2.75 CEMT P RUNPRD STAND BACK INJECTOR. DROP 1/2"BALL PUMP OPEN CIRC SUB.R/U FOR 1"CSH. PJSM.POH WITH 86 STANDS 1"CSH. UD CLEANOUT BHA.PVT 256 BBLS. 09:30 - 10:00 0.50 CEMT P RUNPRD PJSM.SECURE WELL,WELDER INSTALLED NEW INJECTOR LEG STORAGE RACK. Printed 1/20/2011 12:59:36PM North America -ALASKA- BP Page 3 of 5 Operation Summary Report Common Well Name: E-35 AFE No Event Type: COM-ONSHORE (CON) Start Date: 11/30/2010 End Date: 12/7/2010 X3-00Y24-C(991,295.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.:NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 13:15 3.25 EVAL P OTHCMP PJSM WITH LOGGING CREW. REVIEW PROCEDURE. P/U MEMORY CNL LOGGING BHA. PJSM. RIH WITH 43 STANDS 1"CSH,4 JTS 2 L 1/16"PH6. L.. ,v I- M/U INJECTOR. 13:15 - 14:45 1.50 EVAL P OTHCMP RIH WITH LOGGING BHA.CALIBRATE LOGGING TOOLS AT 4000,AND 5000' RIH TO 8496' 14:45 - 16:40 1.92 EVAL P OTHCMP LOG DOWN AT 30 FPM FROM 8496'TO 11,162'PBTD UNCORRECTED. .35BPM,600 PSI.PVT 288 BBLS. 16:40 - 17:00 0.33 EVAL P OTHCMP'LOG UP 60 FPM FROM 11.162' UNCORRECTED DEPTH,.57 BPM,1320 PSI. LAY IN 30 BBL 120K LSRV 8.6 PPG PERF PILL WHILE LOGGING UP. PAINT YELLOW FLAG AT 10,963", LOG UP TO 8,500' 17:00 - 18:15 1.25 EVAL P OTHCMP POH WITH LOGGING BHA. PJSM FOR 1"CSH WHILE POH. 18:15 - 20:30 2.25 EVAL P OTHCMP STAND BACK INJECTOR.L/D 4 JTS 2 1/16" PH6. POH,STAND BACK 43 STDS 1"CSH 20:30 - 21:15 0.75 EVAL P OTHCMP ""PJSM ON PULLING NUCLEAR SOURCE TO FLOOR. PULL SOURCE. CLEAR AND CLEAN RIG FLOOR. 21:15 - 23:00 1.75 PERFOB P OTHCMP MU JETTING ASSEMBLY TO JET STACK CLEAN. CONCURRENT OPS:MOBILIZE PERFORATION TOOLS TO FLOOR, CORRELATE MCNL LOGS WITH GEOLOGICAL PDC LOG. GEOLOGIST CONFIRMS PERFORATION AREA GOOD. BREAK OFF INJECTOR FROM WELL,BREAK DOWN JETTING BHA. 23:00 - 23:30 0.50 PERFOB P OTHCMP PJSM ON MU PERF GUNS,WELL CONTROL 23:30 - 00:00 0.50 PERFOB P OTHCMP MU PERF ASSEMBLY TO 1"CS HYDRIL WORK STRING 12/6/2010 00:00 - 01:45 1.75 PERFOB P OTHCMP MU PERFORATION BHA 01:45 - 04:00 2.25 PERFOB P OTHCMP RIH WITH PERFORATING BHA ON COIL. TAG TD, PU AND RE-TAG. PU TO BREAKOVER. RESET DEPTH TO LOG. 04:00 - 04:10 0.17 PERFOB P OTHCMP RUN THROUGH CIRCULATION SEQUENCE TO OBTAIN PRESSURES. 04:10 - 04:50 0.67 PERFOB P OTHCMP PULL UP HOLE TO 11,112'. INITIATE FIRING SEQUENCE. BEGIN TO PU SLOWLY WHILE ON LAST SEQUENCE. CONTINUE TO PU TO 11,070'. NO POSITIVE INDICATION OF FIRING. CONDUCT 1000 PSI POSITIVE PRESSURE TEST, PRESSURE DID NOT BLEED OFF. BLEED PRESSURE,RIH TO FIRING DEPTH ,04 AGAIN. REPEAT FIRING SEQUENCE. PERFORATE ON DEPTH AT 11,080'TO 11.110'. 04:50 - 05:50 1.00 PERFOB P OTHCMP POH TO ABOVE TOP OF DEPLOYMENT SLEEVE AT 8600' 05:50 - 06:05 0.25 PERFOB P OTHCMP FLOW CHECK WELL. NO FLOW. 06:05 - 07:25 1.33 PERFOB P OTHCMP COTINUE TO POH. Printed 1/20/2011 12:59:36PM North America -ALASKA- BP Page 4 of 5 Operation Summary Report Common Well Name: E-35 AFE No Event Type: COM-ONSHORE (CON) Start Date: 11/30/2010 End Date: 12/7/2010 X3-00Y24-C(991,295.00) Project:Prudhoe Bay Site:PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:25 - 07:55 0.50 PERFOB P OTHCMP AT SURFACE WITH BHA. FLOW CHECK. NO FLOW. SET BACK INJECTOR.R/U AND CIRC.COIL. 07:55 - 10:00 2.08 PERFOB P OTHCMP PJSM. L/D BHA. POH AND STAND BACK 42 STAND 1"CSH WORK STRING. POH 1 STAND FROM E-FIRING HEAD 10:00 - 10:50 0.83 PERFOB P OTHCMP PJSM. PULL TO E-FIRING HEAD. LID E-FIRING HEAD AND 2 PERF GUNS. FLOW CHECK, WELL DRINKING 1/3 BPH PVT 249 BBLS. AFTER ACTION REVIEW.MONITOR WELL. • 10:50 - 11:50 1.00 PERFOB P OTHCMP PJSM. UNLOAD PERF GUNS FROM PIPESHED,R/D AND CLEAR RIG FLOOR. CONTINUE TO MONITOR WELL. 11:50 - 12:30 0.67 ZONISO P RUNPRD PJSM.LOAD 4 1/2"KB LTP AND RUNNING EQUIPMENT ONTO RIG FLOOR. • C/O DIES ON LITTLE JERK TONGS TO 3 1/2" CLOSE MASTER VALVE ON TREE. 12:30 - 14:30 2.00 ZONISO P RUNPRD M/U 4 1/2"LTP BHA, MULE SHOE,3"SEAL ASSY.,L000ATOR,10'PUP,LTP,RUNNING TOOL,X/O, HYD.DISC.,X/O. OPEN MASTER VALVE ON TREE. M/U 2 JOINTS 2 1/16"PH6,X/O,BAKER DISC. CREW CHANGE. M/U INJECTOR. DISCUSS WELL CONTROL FOR SHEARING COIL IN THE EVENT OF A PINHOLE. 14:30 - 17:00 2.50 ZONISO P RUNPRD ESTABLISH CIRCULATION.PVT 249 BBLS. RIH WITH LTP 80 FPM.23 BPM,170 PSI. RIH TO8500'P/U WT26K,S/OWT18K RIH 25 FPM TO 8645' 17:00 - 18:00 1.00 ZONISO P RUNPRD STING INTO DEPLOYMENT SLEEVE AT 8645 SEE PRESSURE INCREASE. STACK 10K TO 8651',PRESSURE UP ON BACKSIDE 500 PSI. LINE UP TO PUMP DOWN COIL.P/U TO 8644, UNSTING P/U WT 26 K. P/U TO BALL DROP DEPTH 8628.8', LAUNCH 5/8"BALL. PUMP 2 BPM,2100 PSI UNTIL BALL OVER GOOSENECK. PUMP.45 BPM 250 PSI,BALL ON SEAT. STING BACK IN TO 8651'STACKING 10K, P/U TO 8644',P/U WT 30K. STING BACK IN TO STACKING WEIGHT AND PU11/2' 18:00 - 18:05 0.08 ZONISO P RUNPRD PRESSURE UP TO SET LINER TOP PACKER. PACKER SET. BLEED OFF. 18:05 - 18:40 0.58 EVAL P RUNPRD RIG UP TO PRESSURE TEST PACKER. PRESSURE UP BACK SIDE TO 250 PSI LOW FOR 5 MIN. GOOD TEST. CONTINUE TO PRESSURE UP TO 2480 PSI. GOOD PRESSURE TEST. 18:40 - 18:45 0.08 ZONISO P RUNPRD RELEASE FROM LINER TOP PACKER WITH GH RUNNING TOOL. PU,CONFIRM RELEASED. 18:45 - 20:45 2.00 ZONISO P RUNPRD POH. PJSM ON LD OF LINER TOP PACKER RUNNING BHA. RU LITTLE RED HOT OIL SERVICES WHILE POH. Printed 1/20/2011 12:59:36PM TNorth America -ALASKA- BP Page 5 of 5 Operation Summary Report Common Well Name:E-35 AFE No Event Type:COM-ONSHORE (CON) Start Date: 11/30/2010 End Date: 12/7/2010 X3-00Y24-C(991,295.00) Project: Prudhoe Bay Site:PB E Pad Rig Name/No.: NORDIC 1 Spud Date/Time:6/27/2001 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292255700 Active Datum:E-35 @65.29ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:45 - 21:15 0.50 ZONISO P RUNPRD LD LINER TOP PACKER RUNNING BHA. 5/8" BALL RETRIEVED. LD BHA. 21:15 - 21:45 0.50 WHSUR P POST CLEAR AND CLEAN RIG FLOOR. MU NOZZLE BHA FOR FREEZE PROTECT. PJSM ON FREEZE PROTECTING. 21:45 - 23:30 1.75 WHSUR P POST RIH WITH FREEZE PROTECT BHA TO 2500'. LAY IN 38 BBLS DIESEL FREEZE PROTECT FROM 2500'TO SURFACE. 23:30 - 00:00 0.50 WHSUR P POST LD NOZZLE BHA. CLEAR AND CLEAN RIG FLOOR. PREP FOR STAGING LUBRICATOR TO RIG FLOOR TO SET BPV. 12/7/2010 00:00 - 00:30 0.50 WHSUR P POST MU LUBRICATOR TO WELL. 00:30 - 01:00 0.50 WHSUR P POST RU TEST EQUIPMENT. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. RD TEST EQUIPMENT 01:00 - 02:00 1.00 DHB P POST INSTALLBPV 02:00 - 02:45 0.75 WHSUR P POST RIG DOWN LUBRICATOR FROM WELL. MOBILIZE LUBRICATOR AND TOOLS OFF OF RIG FLOOR. 02:45 - 04:15 1.50 WHSUR P POST RU EQUIPMENT TO FREEZE PROTECT COIL. FREEZE PROTECT COIL WITH 5 BBLS METHANOL. RD FREEZE PROTECT EQUIPMENT. 04:15 - 06:00 1.75 RIGD P POST DRAIN STACK TO ND BOP. DRAIN PITS, BEGIN CLEANING PITS. 06:00 - 12:00 6.00 RIGD P POST CONTINUE WITH SECURING WELL. NU TREE CAP,TEST WITH METHANOL. WELL SECURED AND RIG RELEASED AT 1200 HRS. 12/8/2010 00:00 - RIGD POST Printed 1/20/2011 12:59:36PM E-35B, Well History Date Summary 12/07/10 T/I/O=0/0/0 Verified Barriers. Rigged up lubricator with BPV and running tool.Tested lubricator to 300 psi low and 3500 psi high.(passed) Set 4" CIW H BPV @ 108"w/3-5'& 1-2'ext. RKB=23.95'+ 1.0' Nordic 1 RDMO. 12/22/10 T/I/O=Vac./0/0 Torqued all flanges to specs. Post CTD...(see log.) 01/03/11 T/I/O=Vac/0/250;Tested SV to 500 psi for 5 min. (passed); Shut in SSV, removed tree cap and installed lubricator with pulling tool and tested to 300 and 3500 psi for 5 min. ea. (passed); Pulled 4-1/16"CIW "H" BPV#149 thru tree; 1-1'ext. used,tagged @ 112"; Installed running tool w/TWC#257 and reinstalled lubricator on tree, re-tested to 300 and 3500 psi against SV(passed); Set TWC and tested tree to 300 and 5000 psi for 5 min.ea.and charted (passed); Pulled TWC, RDMO and installed tree cap,tested to 500 psi for 5 min. (passed) No problems 01/03/11 ***WELL SHUT IN ON ARRIVAL*** ASSIST VALVE CREW IN REMOVING BPV, INSTALLING TWO WAY CHECK, & PRESSURE TESTING TREE. ***JOB CONITNUED ON 1/4/11*** 01/04/11 ***JOB CONTINUED FROM 1/3/11*** VALVE CREW TEST TREE TO 5,000 PSI & REMOVE TWO WAY CHECK. SET 4-1/2"WHIDDON CATCHER @ 8593'SLM. PULL BK-DGLV FROM STA.#1 @ 8126' MD. ***JOB CONTINUED ON 1/5/11*** 01/05/11 ***JOB CONTINUED FROM 1/4/11*** PULL BK-DGLV's FROM STA#2 (6731' MD)&STA#3 (4053' MD). SET BK-LGLV's IN STA#3(4053' MD) &STA#2 (6731' MD). SET BK-OGLV IN STA#1 (8126' MD). PULL 4-1/2"WHIDDON CATCHER. ***WELL TURNED OVER TO DSO*** Page 1 of 1 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB E Pad E-35 500292255700 E-35B Survey: MWD Survey Report - Geographic 02 December, 2010 A. R ® BAK HUGHES Survey Report- Geographic r 1NTEQ s$St Company: North America-ALASKA-BP Local Co-ordinate Reference: Well E-35 Project: Prudhoe Bay TVD Reference: E-35 @ 65.29ft(Nabors 28E) Site: PB E Pad MD Reference: E-35 @ 65.29ft(Nabors 28E) Well: E-35 North Reference: True Wellbore: E-35B Survey Calculation Method: Minimum Curvature Design: E-35B Database: EDM .16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB E Pad,TR-11-14 Site Position: Northing: 5,973,160.88ft Latitude: 70° 19'59.134 N From: Map Easting: 662,538.97ft Longitude: 148°40'53.054 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.24° Well E-35 API No 500292255700 Well Position +N/-S 0.00 ft Northing: 5,975,877.21 ft Latitude: 70°20'25.430 N +E/-W 0.00 ft Easting: 664,470.46 ft Longitude: 148°39'54.924 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 30.00ft Wellbore E-35B API No 500292255702 Magnetics Model Name ' Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 11/20/2010 21.96 80.97 57,711 Design E-35B Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,349.08 Vertical Section: Depth From(TVD) +N/-S. +E/-W Direction (ft) (ft) (ft) (°) 35.29 0.00 0.00 144.90 Survey Program Date: 12/2/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 302.15 9,103.78 E-35PB1 Survey 1 MWD-Standard(E-35PB1) MWD MWD-Standard 9,123.00 9,349.08 E-35A Survey 3 MWD Standard(E-35A) MWD MWD-Standard 9,351.20 11,202.00 MWD(E-35B) MWD MWD-Standard 12/2/2010 1:21:55PM Page 2 COMPASS 2003.16 Build 73 • KC kW kiodo nik gHUGHES Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well E-35 Project: Prudhoe Bay TVD Reference: E-35 @ 65.29ft(Nabors 28E) Site: PB E Pad MD Reference: E-35 @ 65.29ft(Nabors 28E) Welll: E-35 North Reference: True Wellbore: E-35B Survey Calculation Method: Minimum Curvature Design: E-35B Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting 1 (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,349.08 66.80 235.51 8,813.86 -592.09 -712.43 5,975,269.68 663,771.24 70°20'19.607 N 148°40'15.733 W TIP 9,351.20 66.42 235.77 8,814.70 -593.18 -714.04 5,975,268.55 663,769.66 70°20'19.596 N 148°40'15.780 W KOP 9,382.40 58.68 226.75 8,829.09 -610.41 -735.63 5,975,250.85 663,748.45 70°20'19.426 N 148°40'16.410 W 9,415.54 51.06 221.78 8,848.16 -629.76 -754.57 5,975,231.10 663,729.94 70°20'19.236 N 148°40'16.963 W 9,447.04 50.73 204.10 8,868.12 -650.12 -767.77 5,975,210.45 663,717.19 70°20'19.036 N 148°40'17.349 W 9,479.08 55.22 191.95 8,887.45 -674.39 -775.58 5,975,186.02 663,709.91 70°20'18.797 N 148°40'17.577 W 9,509.30 60.76 180.64 8,903.50 -699.79 -778.31 5,975,160.56 663,707.75 70°20'18.547 N 148°40'17.656 W 9,539.24 71.90 178.05 8,915.51 -727.16 -777.97 5,975,133.21 663,708.69 70°20'18.278 N 148°40'17.646 W 9,569.46 81.46 170.22 8,922.47 -756.35 -774.93 5,975,104.09 663,712.36 70°20'17.991 N 148°40'17.558 W 9,599.20 83.94 163.63 8,926.25 -785.07 -768.25 5,975,075.53 663,719.66 70°20'17.709 N 148°40'17.363 W 9,629.36 83.17 150.71 8,929.65 -812.63 -756.65 5,975,048.23 663,731.87 70°20'17.438 N 148°40'17.024 W 9,659.38 85.05 139.80 8,932.74 -837.13 -739.66 5,975,024.12 663,749.39 70°20'17.197 N 148°40'16.527 W 9,689.42 85.45 128.24 8,935.24 -857.89 -718.17 5,975,003.83 663,771.33 70°20'16.992 N 148°40'15.900 W 9,719.26 86.34 116.78 8,937.38 -873.86 -693.11 5,974,988.42 663,796.73 70°20'16.835 N 148°40'15.168 W 9,748.73 87.58 106.23 8,938.95 -884.63 -665.77 5,974,978.25 663,824.30 70°20'16.729 N 148°40'14.369 W 9,780.57 87.42 101.61 8,940.34 -892.28 -634.90 5,974,971.28 663,855.33 70°20'16.654 N 148°40'13.467 W 9,810.29 87.02 98.09 8,941.78 -897.36 -605.66 5,974,966.84 663,884.67 70°20'16.604 N 148°40'12.613 W 9,840.99 87.21 93.49 8,943.33 -900.45 -575.16 5,974,964.42 663,915.23 70°20'16.574 N 148°40'11.723 W 9,876.05 87.27 88.06 8,945.02 -900.92 -540.16 5,974,964.72 663,950.23 70°20'16.569 N 148°40'10.700 W 9,905.01 87.79 83.72 8,946.27 -898.85 -511.31 5,974,967.42 663,979.03 70°20'16.590 N 148°40'9.858 W 9,934.55 89.08 79.83 8,947.07 -894.63 -482.09 5,974,972.29 664,008.14 70°20'16.631 N 148°40'9.004 W 9,964.63 90.28 74.23 8,947.24 -887.88 -452.79 5,974,979.67 664,037.29 70°20'16.698 N 148°40'8.149 W 9,994.95 91.50 70.18 8,946.77 -878.62 -423.93 5,974,989.57 664,065.94 70°20'16.789 N 148°40'7.306 W 10,024.83 90.71 67.05 8,946.19 -867.72 -396.12 5,975,001.07 664,093.50 70°20'16.896 N 148°40'6.493 W 10,055.11 90.64 71.44 8,945.84 -857.00 -367.81 5,975,012.41 664,121.56 70°20'17.001 N 148°40'5.667 W 10,084.83 89.91 76.96 8,945.69 -848.91 -339.22 5,975,021.12 664,149.96 70°20'17.081 N 148°40'4.832 W 10,114.85 89.63 82.16 8,945.81 -843.47 -309.71 5,975,027.21 664,179.35 70°20'17.135 N 148°40'3.970 W 10,145.31 90.03 87.62 8,945.90 -840.76 -279.38 5,975,030.58 664,209.61 70°20'17.161 N 148°40'3.084 W 10,174.93 89.51 92.67 8,946.02 -840.83 -249.77 5,975,031.16 664,239.21 70°20'17.160 N 148°40'2.219 W 10,204.97 88.86 97.60 8,946.45 -843.52 -219.87 5,975,029.13 664,269.16 70°20'17.134 N 148°40'1.346 W 10,235.33 89.42 102.45 8,946.91 -848.80 -189.98 5,975,024.50 664,299.16 70°20'17.082 N 148°40'0.473 W 10,265.23 90.00 107.18 8,947.06 -856.45 -161.09 5,975,017.49 664,328.21 70°20'17.007 N 148°39'59.629 W 10,295.15 88.34 113.14 8,947.49 -866.75 -133.01 5,975,007.81 664,356.50 70°20'16.906 N 148°39'58.809 W 10,324.83 88.25 113.00 8,948.38 -878.38 -105.72 5,974,996.79 664,384.04 70°20'16.791 N 148°39'58.012 W 10,358.13 89.63 108.21 8,948.99 -890.09 -74.57 5,974,985.76 664,415.44 70°20'16.676 N 148°39'57.102 W 10,384.91 91.35 104.89 8,948.76 -897.72 -48.90 5,974,978.70 664,441.27 70°20'16.601 N 148°39'56.352 W 10,414.99 92.18 101.02 8,947.84 -904.46 -19.61 5,974,972.60 664,470.70 70°20'16.535 N 148°39'55.497 W 10,444.89 92.33 97.50 8,946.66 -909.26 9.88 5,974,968.44 664,500.28 70°20'16.488 N 148°39'54.635 W 10,472.77 91.20 95.19 8,945.80 -912.34 37.57 5,974,965.97 664,528.03 70°20'16.457 N 148°39'53.827 W 10,505.05 90.12 92.02 8,945.43 -914.37 69.78 5,974,964.65 664,560.28 70°20'16.437 N 148°39'52.886 W 10,534.73 91.14 87.12 8,945.10 -914.15 99.45 5,974,965.53 664,589.93 70°20'16.439 N 148°39'52.019 W 10,565.33 91.90 82.13 8,944.29 -911.29 129.89 5,974,969.06 664,620.30 70°20'16.468 N 148°39'51.130 W 10,595.59 91.50 77.62 8,943.39 -905.97 159.66 5,974,975.02 664,649.94 70°20'16.520 N 148°39'50.261 W 10,625.27 91.16 72.74 8,942.70 -898.38 188.34 5,974,983.24 664,678.44 70°20'16.595 N 148°39'49.423 W 10,653.75 91.56 77.20 8,942.03 -891.00 215.83 5,974,991.22 664,705.76 70°20'16.667 N 148°39'48.620 W 10,685.11 90.55 81.74 8,941.45 -885.27 246.65 5,974,997.62 664,736.45 70°20'16.723 N 148°39'47.720 W 10,714.95 87.64 84.91 8,941.92 -881.80 276.27 5,975,001.74 664,765.99 70°20'16.758 N 148°39'46.855 W 10,747.33 83.73 84.76 8,944.36 -878.90 308.42 5,975,005.35 664,798.07 70°20'16.786 N 148°39'45.916 W 10,784.77 78.17 84.44 8,950.24 -875.42 345.22 5,975,009.63 664,834.77 70°20'16.820 N 148°39'44.841 W 10,812.49 73.57 84.83 8,957.01 -872.91 371.98 5,975,012.73 664,861.47 70°20'16.845 N 148°39'44.060 W 10,841.75 67.43 85.93 8,966.77 -870.68 399.45 5,975,015.56 664,888.89 70°20'16.867 N 148°39'43.257 W 10,863.78 64.26 86.49 8,975.78 -869.35 419.51 5,975,017.33 664,908.91 70°20'16.880 N 148°39'42.671 W 10,894.60 58.39 86.05 8,990.57 -867.60 446.48 5,975,019.68 664,935.83 70°20'16.897 N 148°39'41.884 W 12/2/2010 1:21:55PM Page 3 COMPASS 2003.16 Build 73 BAKER HUGHES Survey Report-Geographic 40. 1NTEQ '004 Company: North America-ALASKA-BP Local Co-ordinate Reference: Well E-35 Project: Prudhoe Bay TVD Reference: E-35 @ 65.29ft(Nabors 28E) Site: PB E Pad MD Reference: E-35 @ 65.29ft(Nabors 28E) Well: E-35 North Reference: True Wellbore: E-35B Survey Calculation Method: Minimum Curvature Design: E-35B Database: EDM .16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (0) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,925.10 53.81 85.65 9,007.57 -865.77 471.72 5,975,022.06 664,961.03 70°20'16.915 N 148°39'41.146 W 10,960.34 48.12 85.82 9,029.76 -863.73 499.01 5,975,024.69 664,988.26 70°20'16.935 N 148°39'40.349 W 10,995.08 41.35 85.99 9,054.42 -861.98 523.38 5,975,026.97 665,012.59 70°20'16.952 N 148°39'39.637 W 11,024.12 35.41 84.69 9,077.18 -860.53 541.34 5,975,028.82 665,030.51 70°20'16.967 N 148°39'39.113 W 11,052.52 29.85 81.77 9,101.09 -858.76 556.54 5,975,030.93 665,045.67 70°20'16.984 N 148°39'38.669 W 11,078.98 24.02 80.15 9,124.67 -856.89 568.38 5,975,033.05 665,057.46 70°20'17.002 N 148°39'38.323 W 11,106.14 18.98 79.48 9,149.93 -855.14 578.17 5,975,035.02 665,067.21 70°20'17.020 N 148°39'38.037 W 11,139.10 13.62 78.22 9,181.55 -853.37 587.25 5,975,036.99 665,076.25 70°20'17.037 N 148°39'37.772 W 11,164.14 9.06 74.61 9,206.10 -852.24 592.04 5,975,038.22 665,081.01 70°20'17.048 N 148°39'37.632 W 11,202.00 9.06 74.61 9,243.48 -850.66 597.79 5,975,039.93 665,086.72 70°20'17.064 N 148°39'37.464 W TD 12/2/2010 1:21:55PM Page 4 COMPASS 2003.16 Build 73 U 0 1 W.E e. E 0 �. 0 U d « ^ NLi i C .c 7 CO O y o• tO dm J •Z L Q O)v ao C3 om_ N A d .5—. 0 rn Q 0co -c 1 A 10 j N N ij C w V d C U Co d 0 .. ( N QQOQ Q ! l0 a T (0 d C C O EO) CO dm m r G .. s,.. U m N e N Z 0 Q N cr mr y- e- 1- 111 Y)41 N N h h N N h O r « O O N O N N N E. 0 0 s. 1; N N N N N N O O co ttOM O 04UNai „)) <M .- N 0 F C 0 O Q a W T. >- O a ▪ F 0 0 v 0 F F J• 0 0 0 0 3p3 ,_ 3 2 c? d Z a 0 d N 0 0 a m a a m a W wa � Z � LL � H_ F- W 1-•0w000 ODu. Z 2222re2 � 1_ W W _ Q (U2iti U2a20X000 2 i1 )n N h 40 t0 C) P O In 00 C ((D O N 0 N el O) 0 Co 0 C 55 it Op8pOO OOOp OO O 0 0 0 0 0 0 0 0 p Q O 0 h -1 h CO a C3 0:1 h cc m N -1UJ0J30NJ JO () 0 > (j0a cm m m m Q m Q m m CO m W Z 0 re (% o 01 W C C dC 7 0 N W or d U on V d N ,-- ' N G d " N W N C _ A ) Q g m CD 00 N ¢ • Vo(47ct LU c) • Cf0C tit ti cim i ici ill' ,i.2 O E a m ^ w m Q ow 'cam oin in x z .'� w• w N ANu � amac a N a a a v INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage,Alaska 99501 Attention: Christine Mahnken Reference: E-35B 1 Contains the following: ' 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print—GR Directional Measured Depth Log (to follow) 1 color print—MPR/Directional TVD Log (to follow) 1 color print—MPR/Directional Measured Depth Log (to follow) pl J LAC Job#: 3511139 Sent by: Lauren VeronieDate: 4/12/21 , Received by: a5 Date: APR 13 2Th PLEASE ACKNOWLEDGE RECEIPT BY SWICANEI ` '" i l�T °L ` OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ BMI 7260 Homer Drive 1# Anchorage,Alaska 99518 c2,0 —/6.6 Direct: (907)267-6612 INTEQ FAX: (907)267-6623 ���� BAKER MY6MES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION(ALASKA)INC COUNTY NORTH SLOPE BOROUGH WELL NAME E-35B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 4/12/2011 THIS DISTRIBUTION LIST AUTHORIZED BY: LAUREN VERONIE SO#:3511139 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION(ALASKA)INC 1 Company DNR-DIVISION OF OIL&GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE,AK 99508 ANCHORAGE,AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON,TX 77002 1 Company STATE OF ALASKA-AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W.7TH AVE Address SUITE 100 ANCHORAGE,AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv:BAKER ATLAS-PDC 17015 Aldine Westfield,Houston,Texas 77073 This Distribution List Completed By: ? . , . op ;asna,.-40.,;;;;CmleR'4%. Page 1 of 1 bp Date 03-14-2011 0 Transmittal Number:93185 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions,please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 07-09A g/ --16--d 0ofii E-35B a/ 046j Please S. and Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 2 2Cl AtilehCrica Petrotechnical Data Center LR2-1 900 E. 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Y 106 3 3 ........,3 ,......,v PiiV N N ca Saltmarsh, Arthur C (DOA) From: Barker, Elizabeth R(SAIC) [Elizabeth.Barker@bp.com] Sent: Tuesday, February 01, 2011 4:13 PM To: Saltmarsh, Arthur C(DOA) Cc: Stewman, Sondra D; Hubble, Terrie L; Barker, Elizabeth R(SAIC) Subject: Well is on Production: PBU E-35B/PTD#210-160 Hello Art, Well Name: PBU E-35B Permit#: 210-160 API #: 50-029-22557-02-00 This well began Production on January 21, 2011 Method of Operations is: Flowing Date of Test: January 22, 2011 Hours Tested: 10 24-Hour Rate/Oil - Bbl: 2438 24-Hour Rate/Gas- Mcf: 8619 24-Hour Rate/Water-Bbl: 800 Test Rate/Oil - Bbl: 1016 Test Rate/Gas - Mcf: 3591 Test Rate/Water- Bbl: 333 Choke Size: 96 Gas-Oil Ratio: 3535 Flow Tubing Pressure: 300 Casing Pressure: 1320 Oil Gravity-API: Unavailable Thank you, Liz Barker SAIC,Projects Analyst BP,ADW Support 564-5674 1 "WM, 11 [F ALASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-35B BP Exploration (Alaska), Inc. Permit No: 210-160 Surface Location: 1187' FNL, 501' FEL, SEC. 06, T11N, R14E, UM Bottomhole Location: 2040' FNL, 5070' FEL, SEC. 05, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to drill the above referenced service 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. 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. Sincerely, Daniel T. Seamount, Jr. 7.4 Chair DATED this- day of November, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM 'ON r'7s � V A44/0 PERMIT TO DRILL _� 20AAC25.005 ;11•-r 2 7 2010 1 a.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj 0 Single Zone lc. Specify if well is •ropo--•__., e ❑ Drill ®Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone fairefekiliii5 it 1, 11, ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp Apetilr a Gas 2. Operator Name: 5.Bond: ® Blanket ❑Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU E-35B 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11255' TVD 9040'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028304 1187'FNL,501'FEL, SEC.06,T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1810'FNL, 1516'FEL, SEC.06,T11N,R14E, UM November 20,2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2040'FNL,5070'FEL,SEC.05,T11N,R14E, UM 2560 11250' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 65.29 feet 15.Distance to Nearest Well Open Surface: x- 664470 y-5975877 Zone- ASP4 GL Elevation above MSL: 30.50 feet to Same Pool: 596' 16.Deviated Wells: Kickoff Depth: 9370 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3270 Surface: 2390 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) 3" 2-3/8" 4.7# L-80 STL 2605' 8650' 8612' 11255' 9040'ss 44 sx 15.8 DDO Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 10501' 90 ' 10030' 10464' 9069' None Casing Length Size Cement Volume MD TVD Conductor/Structural 117' 20" 260'sx Arctic Set(Approx.) 117' 117' Surface 3592' 10-3/4" 1175 sx CS Ill.375 sx Class'G' 3627' 3622' Intermediate 9090' 7-5/8" 485 sx Class'G' 9123' 8800' Production Liner 261' 4-1/2" Uncemented Slotted Liner 8862'-9123' 8736'-8800' 1817' 3-3/16"x 2-7/8" 118 cu ft'G'/Uncemented Slotted Liner 8684'-10501' 8637'-9066' Perforation Depth MD(ft): 8981'-9865' Perforation Depth ND(ft): 8777'-9084' 20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fo'•-•o'•• 's true --• correct. Contact Printed Name •,A ,0 4,1 Title Engineering Team Leader Sean McLaughlin,564-4387 .-/ „_/ • / Prepared By Name/Number Signaturf Phone 564-4711 Date ,1()/26 i'J Elizabeth Barker,564-4628 Commission Use Only Permit To Drill API Number: Permitprova Date: See cover letter for Number: oZIO/E,�Q 50-029-22557-02-00 11 �� )b other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbr)d methane,gas hydrates,or gas contained shales:�� BOP7;s14' 11e No Mud Log Req'd: ❑lies I?s No Other: 'v. 3500 rs` Samples Req'd: ❑ es -•K' 2,506 psi. A"'�J'/`_�" 1- L."‘""i) H2S Measures: Er Yes 0 No Directional Survey Req'd: ErYes 0 No APPROVED BY THE COMMISSION / S 10 Date '• / ' ,COMMISSIONER Form 10-401 evis 07/2009 This permit is valid for 24 onths frgmlhe date of approval(20 AAC 25.005(g)) Submit In Duplicate ORIGINAL ''y.," . / , ,, To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin 0 bp CTD Engineer Date: October 25, 2010 Re: E-35B Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well E-35A.E-35A is a 2001 horizontal CST in Zone 2 in the E-K Graben. During drilling,the HOT was encountered-13' high and as a result more of the wellbore is in the MHO/HOT transition zone than had been planned. The well initially had problems flowing but eventually came online.The well began to cycle in Feb 2002 when it hit MGOR. In March 2002,a stimulation job of 450 bbls microbe mixture was pumped. Marginal oil production benefits were seen. In May 2003,50' of Zone 2 perforations were shot. These perfs were below the HOT and little benefit was seen. A MCNL/PPROF was logged in Dec 2003 and indicated 100% of production was from the initial perforations. In Dec 2008, a CIBP was set to isolate most of the lateral and 405' of Sag perfs were shot. Production was uncompetitive, so the well was shut in for high GOR. The proposed plan for well E-35B is to sidetrack out of the E-35A 3-3/16"production liner with a Coiled Tubing Drilling rig on or around November 20,2010. The existing perforations will be isolated by the primary cement job after drilling and running liner. The sidetrack will exit the 3-3/16" liner in the Sag River perforations and drill a 3"hole in the target zone 2 sands. CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin November 07, 2010). 1. W AC-LDS; AC-PPPOT-T 2. C Dummy WS drift to 9400' MD. 3. C MCCL/GR log for depth control. 4. C Set 3-3/16" CIBP at 9400' 5. V PT MV, SV,WV 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove wellhouse, level pad. 8. V Set TWC -24hr prior to rig arrival. Rig Work: (scheduled to begin on November 20, 2010) P£A 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. 2. Set 3-3/16"WS at 9350' MD 3. Mill 2.8" window at 9350' and 10' of rathole. • 4. Drill Build: 3.0" OH, 500' (32°/100). ' 5. Drill Lateral: 3.0" OH, 1400' (12°/100). • (,tis PTP 6. Run 2-3/8" solid cemented completion leaving TOL at 8650' MD. • 7. Pump primary cement leaving TOC at 9100', 9 bbls of 15.8 ppg liner cmt planned. 8. Cleanout run. 9. Run MCNL/GR/CCL log. 10. Perforate 250. 11. Run 4-1/2"liner top packer and test liner lap to 2,400 psi. 12. Freeze protect well, set BPV and RDMO. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Run generic GLV's. Mud Program: • Well kill: 8.6 ppg brine. • Milling/drilling: 8.6 ppg Geo Vis for milling window and drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: Bonzai completion • • 2-3/8" L-80 solid liner- 8650' MD to 11255' MD. • A minimum of 9 bbls 15.8 ppg cement will be used for liner cementing. • • TOC planned at 9100' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property— 11,250 ft. • • Distance to nearest well within pool—596 ft to E-26A • Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. . Anti-Collision • No close approaches Hazards • One mapped fault crossings at 9,450' in the Sag/Shublik. Well plan is parallel to an E-W trending regional fault with >500 ft. standoff. • The maximum recorded H2S level on E pad was 130 ppm on well E-102 on 9/25/2009. • Lost circulation risk is considered medium for this well due to the planned fault crossing Reservoir Pressure • The reservoir pressure on E-35B is expected to be 3270 psi at 8,800'TVDSS. (7.2 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft)to surface is 2390 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble TREE= 4-1/16"CMJ WELLHEAD= 5M FMC SE 'NOTES: WELL EXCEEDS 700 @ 8925' ACTUATOR= BAKER E 3 5A KB. ELEV= 65.3' - ANL,,.1OES HORIZONTAL @ 9100'. BF. ELEV= 34.79' KOP= 8349' Max Angle= 97°©9194' Datum MD= 94 38 O 2205' 4-112"HES HXO SSSV NIP, ID=3.813" Datum TVD= 8800'SS GAS LIFT MANDRELS !ST MD TVD DEV TYPE VLV LATCH FORT DATE 10-314"CSG, 45.5#, NT-80 BTC, ID=9.950' 3627' 3 4053 4048 0 MER DMY BK-5 0 08/27/09 I 2 6731 6726 0 MER DMY BK-5 0 08/27/09 1 8126 8120 0 MER DMY BK-5 0 04/23/01 Minimum ID = 2.37" @ 9998' 3-3/16" X 2-7/8 XO 8689' HBKR LOC SUB/SEAL ASSY, ID=2.39" 8691' —4-1/2"HES XNIP, ID=3.813" 8702' —3-1/2"FL4S LNR X 3-3/16" TC11 LNR XO, ID=2.80" .X ►� 8703' —7-5/8"X4-1/2" BKR SABL-3 PKR W/KANCH, ID= 3.93" ' 8727' {4-1/2"HES X NIP, ID= 3.813" ' 8738' —4-1/2" HES XN NIP, ID= 3.725" 4-1/2"TBG, 12.6#,L-80 NSCT, .0152 bpf, ID=3.958" H 8750' / 8750' --,4-1/2"WLEG,ID=3.958" 8747' ---IELMD TT LOGGED 4/18/97 TOP OF 4-1/2"LNR — 8862' K 4 �� � 8862' —7-5/8"X4-1/2"TM/HBBP �1, PKR,W/SCP TOP, ID=3.920" H . 0/4 7-5/8"CSG,29.7#,L-80 NSCC, 8998' .. ►� ID=6.875" (OLD SDTRK WINDOW) A I �. 4-1/2"MILLOUT WINDOW (E-35A)9123'-9128' '1 ♦1 ,A 1,4 4-1/2"8KR HIPSTOCKw/RA RAG -) 9122' / 1�4 W PERFORATION SUMMARY ,• � REF LOG: SPERRY MWD ON 05/30/95 4..V ANGLE A T TOP PERF: 76°@ 8981' .�4.4) 9998' —3-3/16" X 2-7/8"X0, ID= 2.37" Note:Refer to Production DB for historical perf data . �,,;, SIZE SPF INTERVAL Opn/Sqz DATE ������ 4Sip 10030' H2-7/8"CIBP(12/12/08) 2" 6 8981 -9386 0 12/13/08 4 2" 4 9815-9865 0 05/12/03 ���� 4 ` 2" 4 10200- 10440 C 07/03/01 ���� 4 A. 0..•AAA 4,4.v PBTD H 10464' 4-1/2"LNR, 12.6#, L-80 NSCT, ID=3.958" H 9600' 2-7/8"LNR,6.16#, L-80,STL, .0058 bpf, ID=2.37" H 10501' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/11/95 KSB ORIGINAL COMPLETION 02/04/04 CMO/TLP PERF SUMMARY CORRECTIONS WELL: E-35A 06/11/95 KSB SIDETRACK COMPLETION 01/12/09 JGM/SV SET CIBP/ADPERF(12/13/08) PERMIT No:K2011190 07/05/01 CTD SIDETRACK 10/02/09 BSE/PJC GLV GO&PULL LTP(08/26-27/09 AR No: 50-029-22557-01 07/21/01 C}-I/TP CORRECTIONS SEC 6,T11 N, R14E, 1187'FNL&501'FEL 05/12/03 JLGIKK ADPERFS 07/12/03 CMO/TLP KB ELEVATION CORRECTION BP Exploration (Alaska) TREE= 4-1116'CIW WELLHEAD= 5M FMC E-3 5 B ACTUATOR= BAKER S NOTES: WELL EXCEEDS TO @8925' , KB.ELEV 65.3' P=posed CTD SBetrack_ A ES HORIZONTAL 9100'. BF. ELEV= 34.79' KOP= 8349' Max Angle= 97°al 9194' Datum MD= 9438_ 2205' —14-1/2" HES HXO SSSV NIP, ID=3.813" Datum ND= 8800'SS GAS LIFT MANDRELS !ST ND TVD DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.5#, NT-80 BTC, ID=9.950" 3627' 3 4053 4048 0 I)/ER DIVY BK-5 0 08/27/09 ' 2 6731 6726 0 NDMY BK-5 0 08/27/09 y ER 1 8126 8120 0 PER DMY BK-5 0 04/23/01 Minimum ID = 2.375" @ 8640' 8640' H4-1/2"KB LTP 4-1/2" BKR KB LTP _-- 8650' — TOL 2-3/8"FLUTED 8689' —IBKR LOC SUB/SEAL ASSY,ID=3.0" ' $691' —I4-112"HES XNIP, ID=3.813" 8702' -1 3-1/2"FL4S LNR X 3-3/16" TC11 LNR XO, ID=2.80" Tt Z 8703' -17-5/8"X4-1/2" BKR SABL-3 PKR WI K ANCH,ID=3.93" I 8727' H4-1/2"HES X NIP,ID=3.813" I 8738' H4-112" HES XN NIP,ID milled to=3.80" 4-1/2"TBG, 12.6#, L-80 NSCT, .0152 bpf, ID=3.958" --I 8750' \ 8750' —14-1/2"WLEG, ID=3.958" • 1414141 1 1141414 8747' �ELMD TT LOGGED 4/18/97 TOC CTD LNR 8750' (SCMT M T 10/b 9)- o1144 TOP OF 4-1/2'LNR H 8862' MA44 /lr� 8862' —7-5/8"X4-112"TNV HBBP , 1 ,' '. PKR,W/SCP TOP, ID=3.920" 7-5/8"CSG,29.7#,L-80 NSCC, — 8998' —i �� ,•i 65° TO 2-3/8" ^9100' 8973' TSG R ID=6.875" (OLD SDTRK WINDOW) 1g .. 4-1/2"MILLOUT WINDOW (E-35A)9123'-9128' 4-1/2" slotted liner 9076'-9158' i. i,-. 9350' H3-3/16"monobore w hipstock 4-1/2"BKR WHIPSTOCK w/RA TAG H 9122' o :7 4 0 9400' H3-3/16"CIBP PERFORATION SUMMARY �� \ 66 f REF LOG: SPERRY MM/D ON 05/30/95 14*4i\ ANGLE AT TOP PERF: 76"(g 8981' •.' Note: Refer to Production DB for historical perf data - , 2-3/8"L-80 LINER,Cemented&Perfor d —I 1125. 111111 SIZE SPF INTERVAL Opn/Sqz DATE 4.1..0 0 \ 2" 6 8981 -9386 0 12/13/08 �414111411�, 9998' H3-3/16"X2-7/8"XO,ID=2.37" 2" 4 9815-9865 0 05/12/03 .414111411.' Al'" % 2" 4 10200- 10440 07/03/01 4414111411.' •411141414• ••1.1.1.1.1, A0O . PBTD H 10464' 4-1/2"LNR, 12.6#, L-80 NSCT,ID=3.958" H 9600' 2-7/8"LNR,6.16#, L-80,STL, .0058 bpf, ID=2.37" H 10501' DATE REV BY COMMENTS DATE REV BY I I COMMENTS PRUDHOE BAY UNIT 06/11/95 KSB ORIGINAL COMPLETION 02/04/04 CMO/TLP PERF SUMMARY CORRECTIONS WELL: E-35 06/11/95 KSB SIDETRACK COMPLETION 01/12/09 JGMISV SET CIBP/ADPERF(12/13/08) PERMIT No: 07/05/01 CTD SIDETRACK 10/02/09 BSE/PJC GLV GO&PULL LIP(08/26-27/09 AR No: 50-029-22557-0 07/21/01 CH/TP CORRECTIONS 10/20/10 MSE PROPOSED CTD SIDETRACK SEC 6,T11 N, R14E, 1187'FNL&501'FEL 05/12/03 JLG/KK ADPERFS 07/12/03 CMO/TLP KB ELEVATION CORRECTION BP Exploration(Alaska) U YICD U) 0 0 0 0 0 0 n 0 0 LU 00 N. MI a) N. 0 0 0 0 0 o a) o o co 0) Magi n n o 0 0 0 0 0 0 0 0 0 v `I o CO W In N CO M N CD 00 m m i=w LL.r CO E., 0 r N co 7 O a) a) CO N N CO N- In a) RCO CO O) co ,— co N 4- M co co CO a) N. Q O O a) a) 4 6O . O M a W ❑ N N N CO 7 4 co co a) N N Z CO V M M (.) C'�) C.? M M M C) C'�) N N p NU N y Nd > �. 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(uiB 00 i0d0u lzoivan aru,L BPPASSPORT 0 B h HUGHES i Travelling Cylinder Report bp 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well E-35 Project: Prudhoe Bay TVD Reference: E-35 @ 65.29ft(Nabors 28E) Reference Site: PB E Pad MD Reference: E-35 @ 65.29ft(Nabors 28E) Site Error: 0.00ft North Reference: True Reference Well: E-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore E-35B Database: EDM .16-ANC Prod-WH24P Reference Design: Plan 4 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB E Pad E-01 -E-01 -E-01 Out of range E-01 -E-01A-E-01A Out of range E-01 -E-01A-Plan#7 Out of range E-01 -E-01APB1 -E-01APB1 Out of range E-02-E-02-E-02 Out of range E-02-E-02A-E-02A Out of range E-02-E-02APB1 -E-02APB1 Out of range E-02-E-02B-E-02B 9,800.00 11,800.00 1,248.95 122.81 1,136.34 Pass-Major Risk E-02_DO NOT USE-E-02-E-02 Out of range E-02_DO NOT USE-E-02A-E-02A Out of range E-02_DO NOT USE-E-02APB1 -E-02APB1 Out of range E-02_DO NOT USE-Plan 4, E-02B-Plan 4 9,850.00 11,300.00 1,312.00 150.19 1,166.37 Pass-Major Risk E-03-E-03-E-03 Out of range E-03-E-03A-E-03A Out of range E-03-E-03A-Plan#14 Out of range E-03_DIMS-E-03-E-03 Out of range E-03_DIMS-E-03A-E-03A Out of range E-04-E-04-E-04 Out of range E-04A-E-04A-E-04A Out of range E-05-E-05-E-05 Out of range E-05-E-05A-E-05A Out of range E-05-E-05APB1 -E-05APB1 Out of range E-05-E-05B-E-05B Out of range E-05_DIMS-E-05-E-05 Out of range E-05_DIMS-E-05A-E-05A Out of range E-05_DIMS-E-05APB1 -E-05APB1 Out of range E-05_DIMS-E-05B-E-05B Out of range E-06-E-06-E-06 Out of range E-06A-E-06A-E-06A Out of range E-101 -E-101 -E-101 Out of range E-13-E-13-E-13 Out of range E-13A-E-13A-E-13A Out of range E-14-E-14-E-14 Out of range E-14A-E-14A-E-14A Out of range E-15-E-15-E-15 Out of range E-15-E-15 D-E-15D Out of range E-15-E-15A-E-15A Out of range E-15-E-15APB1 -E-15APB1 Out of range E-15-E-15APB2-E-15APB2 Out of range E-15-E-15B-E-15B Out of range E-15-E-15BPB1 -E-15BPB1 Out of range E-15-E-15C-E-15C Out of range E-16-E-16-E-16 10,713.42 8,925.00 417.95 101.97 324.75 Pass-Major Risk E-26-E-26-E-26 11,250.00 8,950.00 763.98 141.74 668.33 Pass-Major Risk E-26-E-26A-E-26A 10,843.56 9,725.00 159.61 120.17 90.69 Pass-Major Risk E-28-E-28-E-28 Out of range E-28A-E-28A-E-28A Out of range E-28APB1 -E-28APB1 -E-28APB1 Out of range E-29-E-29-E-29 Out of range E-29-E-29A-E-29A Out of range E-29-E-29A-Plan#2 Out of range E-31 -E-31 -E-31 Out of range E-31 -E-31A-E-31A Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 10/25/2010 3:58:47PM Page 3 of 19 COMPASS 2003.16 Build 73 BAR■ BPPASSPORT HUGHES Travelling Cylinder Report 0 by LNTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well E-35 Project: Prudhoe Bay ND Reference: E-35 @ 65.29ft(Nabors 28E) Reference Site: PB E Pad MD Reference: E-35 @ 65.29ft(Nabors 28E) Site Error: 0.00ft North Reference: True Reference Well: E-35 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore E-35B Database: EDM .16-ANC Prod-WH24P Reference Design: Plan 4 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB E Pad E-33-E-33-E-33 9,630.00 8,525.00 1,320.16 77.27 1,255.18 Pass-Major Risk E-33-E-33A-E-33A 9,630.00 8,525.00 1,320.16 77.40 1,255.14 Pass-Major Risk E-33-E-33B-E-33B 9,630.00 8,525.00 1,320.16 77.53 1,255.10 Pass-Major Risk E-35-E-35-E-35 9,358.71 9,375.00 59.92 30.50 31.35 Pass-Major Risk E-35-E-35A-E-35A 9,374.99 9,375.00 0.79 2.63 -1.31 FAIL-Major Risk E-35-E-35PB1 -E-35PB1 9,366.03 9,375.00 36.50 20.75 31.24 Pass-Major Risk E-35_DIMS-E-35-E-35 Out of range E-35_DIMS-E-35A-E-35A Out of range E-35_DIMS-E-35PB1 -E-35PB1 Out of range E-36-E-36A-E-36A Out of range CC-Min centre to center distance or covergent point,SF-min separation factor, ES-min ellipse separation 10/25/2010 3:58:47PM Page 4 of 19 COMPASS 2003.16 Build 73 a; 1 p u x : IL . g 0 I LI:',,T. n c� 1 'i S g �r s" _` 4 I. :._. c ,„ K ��� ilia" a €b II II 11 1 e 111 ni : f 0, 146.� 1 - R g 1� 5 II II _ lui 8 m i11111- L s, U x ` C = 84 Q i `U ~UM mEv`LiIli. i ,1 2 o a�� 1 4 Q o s U .i a. - I o _ IIII : J 1 Z I : 2 ® v v Z I 1 g I I I Z 41 ow . ';'- s•L jr. U 7 P m -1 1 1...41 ..J ...0 a III Wa 4 2 • U U /—" �_ I=III . — v = ■ 1�` 141 , c.)-- I cc � I t w +� �� .. y w � II Bio 0 ;he 4 1 tel 1 MO ' I I1 ._ [ MN J 8Q Q I n U ' i I . 0 I . z O S i , zr I I1 a C 111 nnl : ill ¢ II $0 • I i'i II 1 2011 z i 8 ri'I=I' I'I El'. Alaska Department of Natural pesources Land Administration System Page 1 of/ i Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I Alaska DNR Case Summary File Type: ADL File Number: 28304 Printable Case File Summary See Township, Range, Section and Acreage? New Search Yes 0 No LAS Menu l Case Abstract I Case Detail I Land Abstract File: ADL 28304 ''#aJ_ Search for Status Plat Updates As of 11/04/2010 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 ISSUED Status Date: 09/14/1965 Total Acres: 2469.000 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-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 05 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 014E Section: 06 Section Acres: 593 Meridian: U Township: O11N Range: 014E Section: 07 Section Acres: 596 Meridian: U Township: O11N Range: 014E Section: 08 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-125 11 N 14E UM 5, 6, 7, 8 2469.00 U-3- 7 End of Case Summary Last updated on 11/04/2010. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=283 0... 11/4/2010 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME ef4/ SSS ' PTD# o?Ic/60 ✓ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: , ,El/ dE y POOL: ..x'1/1 10E,..3;t?J/t Z., Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES 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 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 (50- - - ) from records, data and logs acquired for well . 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 no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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. 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No special effort has been made to chronologically organize this category of information. tapescan.txt **** REEL HEADER **** MWD 11/04/06 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 10/12/02 3511139 01 2.375" CTK *** LIS COMMENT RECORD *** 1111111111111111111 Remark File Version 1.000 11111 II11111111111 Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 8900.5000: Starting Depth STOP.FT 11202.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska) , Inc. WELL. WELL: E-35B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 20' 25.430"N 148 deg 39' 54.924"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 02 Dec 2010 API . API NUMBER: 500292255702 -Parameter Information Block #MNEM.UNIT Value Description SECT. 06 Section TOWN.N T11N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . KB Log Measured from FAPD.F 65.29 Feet Above Perm. Datum DMF . KB Drilling Measured From EKB .F 65.29 Elevation of Kelly Bushing EDF .F 0 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 —Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well . (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit) , a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth shifted to a Primary Depth Control (PDC) log provided by well Schlumberger GR CNL dated 05 Dec 2010 per waiter Tifental with BP Exploration (Alaska) , Inc. (8) The sidetrack was drilled from E-35A through a milled window in a 3 3/16 inch liner. Top of window 9351 ft.MD (8749.4 ft.TVDSS) Bottom of window 9356 ft.MD (8749.5 ft.TvDSS) (9) Tied to E-35A at 9349 feet MD (8748.6 feet TVDSS) . (10) The interval from 11170 ft to 11202 ft MD (9146.3 ft. to 9178.2 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8912.25, 8911.84, ! -0.411133 8929.9, 8931. 54, ! 1.64258 8969.31, 8969. 52, ! 0.205078 8972.18, 8972.6, ! 0.411133 8975.06, 8974.65, ! -0.411133 8980.6, 8979.98, ! -0.616211 8986.17, 8987, ! 0.821289 8999. 52, 9000.13, ! 0.615234 9024. 53, 9024.74, ! 0.205078 9035.62, 9035.82, ! 0.206055 9038.7, 9038.49, ! -0.205078 9049.37, 9050.19, ! 0.820312 9054. 5, 9054.29, ! -0.205078 9062.83, 9062.01, ! -0.821289 9132.95, 9131.92, ! -1.02637 9174.68, 9173.45, ! -1.23145 9182.69, 9180.84, ! -1.84668 9206.91, 9203.01, ! -3.89941 9329.4, 9325.3, ! -4.10449 9343.36, 9340.08, ! -3.2832 9354.65, 9351.36, ! -3.28418 9356.7, 9352.8, ! -3.89941 9357.73, 9354.65, ! -3.0791 9363.45, 9359.34, ! -4.10547 9375.56, 9371.45, . -4.10547 Page 2 tapescan.txt 9381. 51, 9377.82, ! -3.69434 9392.8, 9389.93, ! -2.87402 9394.65, 9391.98, ! -2.66797 9401.22, 9398.96, ! -2.25781 9412.16, 9407.64, ! -4. 51562 9413.6, 9409.08, ! -4.51562 9415.24, 9411.34, ! -3.90039 9418. 52, 9416.47, ! -2.05273 9422.01, 9418.73, ! -3.28418 9425.91, 9422.63, ! -3.28418 9427.35, 9424.68, ! -2.66797 9428.79, 9426.53, ! -2.25781 9431.04, 9428.17, ! -2.87402 9433.1, 9430.02, ! -3.07812 9435.97, 9433.1, ! -2.87402 9439.05, 9436.79, ! -2.25781 9443.36, 9439.87, ! -3.48926 9446.64, 9443.15, ! -3.48926 9450.54, 9447.87, ! -2.66895 9455.47, 9452.39, ! -3.0791 9462.65, 9458.96, ! -3.69434 9466.14, 9462.86, ! -3.2832 9474.57, 9471.28, ! -3.28418 9477.03, 9474.16, ! -2.87402 9482.78, 9479.7, ! -3.0791 9484.42, 9481.34, ! -3.0791 9495.09, 9491.4, ! -3.69434 9499.2, 9496.94, ! -2.25781 9504.53, 9500.43, ! -4.10547 9506.59, 9503.51, ! -3.0791 9510.69, 9507.41, ! -3.28418 9513.77, 9510.49, ! -3.28418 9517.67, 9513.97, ! -3.69434 9520.13, 9517.26, ! -2.87305 9529.98, 9526.91, ! -3.0791 9534.29, 9530.81, ! -3.48926 9537.78, 9534.71, ! -3.0791 9545.65, 9542.37, ! -3.28418 9561.86, 9557.76, ! -4.10449 9564. 53, 9560.84, ! -3.69434 9578.08, 9573.97, ! -4.10547 9595.24, 9591.54, ! -3.69434 9608.79, 9604.89, ! -3.90039 9627.46, 9623.36, ! -4.10547 9639.61, 9638.58, ! -1.02539 9668.14, 9667.11, ! -1.02539 9675.65, 9672.57, ! -3.07812 9710.54, 9707.67, ! -2.87402 9714.03, 9711.57, ! -2.46289 9735.5, 9734.68, ! -0.821289 9739.4, 9739.4, ! 0 9758.93, 9759.14, ! 0.205078 9807.23, 9803.75, ! -3.48926 9811.34, 9807.44, ! -3.89941 9820.37, 9816.27, ! -4.10449 9847.67, 9844. 59, ! -3.07812 9850.95, 9847.87, ! -3.0791 9862.24, 9855.88, ! -6.36328 9867.17, 9862.24, ! -4.92578 9896.94, 9892.01, ! -4.92578 9956.73, 9952.83, ! -3.89941 9962.28, 9958.79, ! -3.48926 9965.35, 9961.66, ! -3.69434 Page 3 tapescan.txt 9968.84, 9965.15, ! -3.69531 9970.49, 9967.2, ! -3.28418 9975.21, 9970.69, ! -4.51562 9978.7, 9974.59, ! -4.10449 9981.98, 9978.29, ! -3.69434 9985.88, 9984.65, ! -1.23145 10009.5, 10003.7, ! -5.74707 10019.3, 10014.4, ! -4.92578 10024. 5, 10019.8, ! -4.7207 10029, 10025.9, ! -3.0791 10035.8, 10031.5, ! -4.31055 10043.6, 10040.1, ! -3.48926 10097.8, 10093.7, ! -4.10449 10121, 10115.7, ! -5.33691 10124.1, 10118.6, ! -5.54102 10129.7, 10125.4, ! -4.31055 10136.8, 10132.5, ! -4.31055 10149.2, 10145.3, ! -3.89941 10157.8, 10152.8, ! -4.92578 10161.7, 10156.7, ! -4.92578 10163. 5, 10159.6, ! -3.90039 10166.6, 10162.3, ! -4.31055 10177.9, 10174, ! -3.89941 10189.5, 10185.2, ! -4.31055 10197. 5, 10192, ! -5. 54199 10206.3, 10201.2, ! -5.13184 10222.5, 10216.2, ! -6.36328 10237.5, 10233, ! -4. 51562 10275.7, 10267.3, ! -8.41504 10283, 10276.8, ! -6.1582 10288.9, 10282.6, ! -6.3623 10293, 10285.9, ! -7.18457 10296.1, 10290, ! -6.15723 10300.6, 10294.1, ! -6.56738 10321.2, 10314.4, ! -6.77344 10389.5, 10383.1, ! -6.36328 10414.8, 10406.2, ! -8.62012 10482.8, 10476.5, ! -6.36328 10488, 10481.4, ! -6.56836 10494.5, 10488.4, ! -6.1582 10501.7, 10497, ! -4.7207 10596.4, 10589, ! -7.38867 10601.9, 10594.3, ! -7. 59375 10669.7, 10661.7, ! -8.00488 10684.2, 10677.1, ! -7.18359 10687.1, 10679.5, ! -7.59473 10745.4, 10738.4, ! -6.97852 10750.3, 10744.5, ! -5.74707 10772. 5, 10766.3, ! -6.15723 10780.3, 10774.9, ! -5.33691 10787.9, 10782.2, ! -5.74707 10792.8, 10786.7, ! -6.1582 10809.5, 10804.1, ! -5.33691 10823.6, 10818.3, ! -5.33594 10832.1, 10824.9, ! -7.18457 10839. 5, 10834.1, ! -5.33691 10853, 10844, ! -9.03125 10856.9, 10848.9, ! -8.00488 10880, 10873.7, ! -6.36328 10885.4, 10878.2, ! -7.18359 10954.4, 10946.6, ! -7.79883 10965.4, 10960.9, ! -4.51562 10971, 10966.3, ! -4.7207 Page 4 tapescan.txt 10976.3, 10970.2, ! -6.1582 10988.2, 10982.3, ! -5.95215 11000.5, 10994, ! -6.56836 11005.1, 10997.9, ! -7.18457 11019.6, 11014.3, ! -5.33594 11022.9, 11016.9, ! -5.95215 11047.9, 11041.8, ! -6.15723 11055.4, 11050.1, ! -5.33691 11060, 11054.4, ! -5.54199 11076.6, 11069.6, ! -6.97949 11082.7, 11077.2, ! -5.54199 11119.2, 11112.2, ! -6.97852 11135.6, 11128.4, ! -7.18359 11142.8, 11136.4, ! -6.36328 11147.7, 11143.4, ! -4.31055 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 240 records. . . Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** IIIIIIIIII II 111111 Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 05 Dec 2010 per Walter Tifental with BP Exploration (Alaska) , Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Loci Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F Page 5 tapescan.txt 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 128 Tape File Start Depth = 8900.500000 Tape File End Depth = 11197.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 141 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** LIS COMMENT RECORD *** 1111111111111111111 Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F Page 6 tapescan.txt 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 256 Tape File Start Depth = 8900.750000 Tape File End Depth = 11202.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape subfile: 3 269 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 10/12/02 3511139 01 **** REEL TRAILER **** MWD 11/04/06 BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes a Tape Subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS Page 7 tapescan.txt DEPTH GR ROP RAD RAS RPD RPS 8900.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8901.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11197. 5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8900. 500000 Tape File End Depth = 11197.500000 Tape File Level Spacing = 0. 500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8900.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8901.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11202.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8900.750000 Tape File End Depth = 11202.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS Page 8
