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Home My WebLink About196-121 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 10, 2012 Mr. Jim Regg t 3 Alaska Oil and Gas Conservation Commission RECEINI 333 West 7 Avenue 5 7:3\1 Anchorage, Alaska 99501 NOG 1 Subject: Corrosion Inhibitor Treatments of GPB DS -13 AOGOG Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator II • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -13 Date: 10/31/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13-028 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13-03A 2090480 50029203250100 Sealed conductor NA NA NA NA NA 13-04 1780630 50029203260000 Sealed conductor NA NA NA NA NA 13-05 1811030 50029206260000 Sealed conductor NA NA NA NA NA 13 -06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13 -07 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13 -08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13 -09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13 -10 1811650 50029206780000 Sealed conductor NA NA NA NA NA 13-11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 13 -12 1801420 50029205380000 Sealed conductor NA NA NA NA NA 13-13A 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13 -14 1821710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 -15 1821570 50029208310000 Sealed conductor NA NA NA NA NA 13-16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 -17 1820260 50029207180000 Sealed conductor NA NA NA NA NA 13-18 1820350 50029207240000 Sealed conductor NA NA NA NA NA 13 -19 1811800 50029206900000 Sealed conductor NA NA NA NA NA 13 -20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13 -21 1820530 50029207890000 Sealed conductor NA NA NA NA NA 13 -22 1820770 50029207490000 Sealed conductor NA NA NA NA NA 13 -23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13 -24A 2042430 50029207390100 Sealed conductor NA NA NA NA NA 13 -25 1820910 50029207610000 Sealed conductor NA NA NA NA NA 13 -26 1820740 50029207460000 Sealed conductor NA NA NA NA NA --al' 13-27 1961210 50029209490200 17.0 NA 17.0 NA 130.9 11/22/2009 13 -28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 -29L1 2020690 50029209286000 Dust Cover NA NA NA NA NA 13 -30C 2080870 50029207680300 Sealed conductor NA NA NA NA NA 13 -31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 13 -32A 2012350 50029207980100 0.0 NA 0.0 NA 10.2 10/31/2011 13-33 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 13 -34 1821360 50029208110000 0.3 NA 0.3 NA 11.1 10/31/2011 13-35 1940410 50029224600000 0.9 NA 0.9 NA 5.1 11/17/2009 13 -36 1951670 50029226130000 0.0 NA 0.0 NA 4.3 10/31/2011 13 -37 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 50029208780000 1.0 NA 1.0 NA 5.1 10/6/2009 • STATE OF ALASKA ALASKA OIL ND GAS CONSERVATION COMMISAL WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other in Abandoned ❑ Suspended 1 b. Well Class: 2OAAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 7/2/2011 196 - 121 311 -108 3. Address: 6. Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 05/21/1997 50 029 20949 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 05/30/1997 PBU 13 -27A 526' FSL, 1185' FEL, SEC. 14, T1ON, R14E, UM 8. KB (ft above MSL): 83' 15. Field / Pool(s): Top of Productive Horizon: 3318' FNL, 672' FWL, SEC. 24, T1ON, R14E, UM GL (ft above MSL): 49.63' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 4892' FNL, 598' FEL, SEC. 23, T1ON, R14E, UM 3404' 3386' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 686068 y - 5930564 Zone- ASP4 12672' 9057' ADL 028315 TPI: x- 688022 y- 5926768 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 686792 y- 5925162 Zone- ASP4 N/A 18. Directional Survey: 0 Yes No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: GR, MWD 10453' 9023' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMO UNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 91.5# H Surface 80' Surface 80' 30" 2115 # Poleset 13 -3/8" 72# L -80 Surface 2633' Surface 2633' 17 -1/2" 2700 sx Coldset III. 400 sx Coldset II 9 -5/8" 47# L -80 Surface 10322' Surface 8905' 12 -1/4" 500 sx Class 'G'. 300 sx Coldset 1 7" 29# L -80 10038' 10453' 8648' 9023' 8 -1/2" 265 sx Class 'G' 2 -7/8" 6.5# L -80 10044' 12672' 8654' 9057' 3-3/4" 102 sx Class 'G' 7" 26# L -80 3949' 9935' 3888' 8555' Scab Lnr 847 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6#, 13Cr80 3622' - 9869' 9750' / 8389' MD TVD MD TVD 9985' / 8600' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. �j i Z� i� DEPTH INTERVAL (MD)1 AMOUNT AND KIND OF MATERIAL USED � " 7990' Plug w/ 34.8 Bbls Class 'G' -roc- yam` Attu 3423' Set EZSV 3404' Set Whipstock 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? ❑ Yes No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS JUL 1 2011 (7_01 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ‘ ubmit Original Only 1 - 7 - k3 - I( "Oe246 G 29. GEOLOGIC MARKERS (List all formations and mark countered): 30. IiRATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 10421' 8994' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Terrie Hubble ��j�� 41: { Title: Drilling Technologist Date: 771/ i( PBU 13 - 27A 196 - 121 311 -108 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Jacob Thompson, 564 -5579 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • 13 -27A, Well History (Pre Rig Sidetrack) Date Summary 5/4/2011 T /I /O =SSV /300/0, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS). Pre RST. PPPOT -T: Stung into test port (300 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0 psi). Functioned LDS (standard), one LDS is broke (5:00 position), all the rest moved freely (1 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 5/30/2011 MIRU, Change out WS choke trailer due to MM not working. RIH w/1.75" BDN cmt assembly, no checks. Thru liner to Cmt depth + 20', PU thru 4 1/2 ", circ out & prep for cmt job. Circ well w/ 125 bbl KCL, 75 bbl diesel, 51 bbls of KCI. RU SLB cementers. La in 34.8 bbls of 15.8 • • • class G cemen from 1 • •' • 7,990'. PUH_to safety. Bumped plug up to 500 psi. Monitor WHP. Solid. POOH pumping 60/40 FP for pipe displacement. 5/31/2011 POOH while pumping 60/40 pipe dipslacement as FP. RDMO. JOB COMPLETE. 6/5/2011 T /I /0= 0/500/0 MIT Tubing to 3000 psi. ( Inconclusive) Pumped 1.3 bbls crude down tubing to pressure up tubing to 3000 psi on 3 attempts. On 3rd attempt Lost 12 psi in 1st 15 minutes. Lost 9 psi in 2nd 15 minutes. Bleed pressure down to 600 psi. FWHP= 600/500/0 Slickline in control of well upon departure. 6/5/2011 WELL S/I ON ARRIVAL. DRIFT TO 7,856' SLM W/ 3.70" CENT, S -BLR (No sample, 3.70" cent used for tbg cut drift, target — 4,000'). TAG TOP OF CEMENT @ 7,857' SLM W/ 2.50" CENT, S -BLR (Bailer full of cement). LRS PERFORMED AN INCONCLUSIVE MIT -T TO 3000 PSI (Lost 12 psi in 1st 15 min & 9 psi in the 2nd). 6/6/2011 PULLED BK -DGLV FROM ST #4 (6,421' MD, Pocket left open for fullbore circ out). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 6/7/2011 T /I /0= 300/540/0 Temp= SI Circ out (pre RWO) Pump 5 bbls meth spear down 13 -29 flowline. Pump 5 bbls meth spear down tbg, verify TxIA communication. Pump 658 bbls of 100*f 1% KCL down tubing taking returns up the IA and down the flowline of well 13 -29. Pump 172 bbls of 90 "f diesel down IA taking returns up tubing. Freeze protect hard line with 1 bbls meth, 3 bbls diesel. U -tube TxIA for 1 hr. Bleed TP &IAP to 0 psi. FWHP= 0/0/0. 6/9/2011 T /I /O =0/0/0 CMIT T x IA to 2500 psi. PASSED ( Pre - sidetrack) Pumped 7.1 bbls diesel down IA to bring pressure on IA up to 2500 psi and Tubing to 2420 psi. Lost 0 psi in 30 minutes on 2nd attempt. Bleed pressures down to 0 psi. FWHP =0/0/0 6/10/2011 T /I /O =0/0/0 Test I/A valve to 500 psi for 5 min. (passed). Install VR lubricator and test to 2500 psi for 5 min. (passed). Set VR plug and test to 2500 psi for 5 min. (passed). Pull annulus valve off front side of tubing spool and intall flange, Test to 4500 psi for 5 min. (passed) 6/10/2011 WELL SHUT IN ON ARRIVAL. STAND BY AFTER SPOTTING 3RD PARTY EQUIPMENT SINCE ADW IS IN WELLHOUSE PERFORMING SERVICES. 6/11/2011 INITIAL TWO = 0/0/0 PSI RIH WITH TOOLSTRING AND 3.65" JET CUTTER. TIE IN TO TUBING TALLY DATED 15- JAN -2010. PULL TO CUTTING POSITION AT 3622' AFTER CONFIRMING WITH THE CLIENT CCL TO MIDDLE OF CUTTER = 11.6' AND CCL STOP DEPTH = 3610.4'. PRESSURES STILL THE SAME AFTER CUT T /I /A = 0/0/0 PSI. POOH AFTER SEEING GOOD CONFIRMATION OF CUT. FINAL T /I /O = 0/0/0 PSI. JOB COMPLETED. LEFT WELL SHUT IN. 6/18/2011 0/0/0= SI (CMIT T x IA PASSED) Pumped 4.6 bbls down TBG to achieve test pressure of 2500 psi, 1st 15 min pressure loss of 35 psi and 34 psi, 2nd pressure loss of 15 psi and 16 psi, for a total pressure loss of 50 psi and 50 psi. Bleed down pressures. Pad op notified. FWHP =0/0/0 Page 1 of 2 • • 13 -27A, Well History (Pre Rig Sidetrack) Date Summary 6/19/2011 T /I /O= 0/0/0 Conduct PJSM. Test SV to 300 and 3500 psi for 5 min. (passed) Install Lubricator with setting tool and test to 300 & 3500 psi for 5 min. (passed) Set 4- 1/16" CIW "H" BPV #254 thru tree for 7ES pre -rig, 1 -1' ext. used, tagged @ 110 ". RDMO. Test tree cap & plug to 500 psi for 5 min. (passed) No Problems. 6/20/2011 T /I/O= 0/100/0 Test BPV, PASSED. Pump 2.2 bbls Diesel down IA to pressure to 1000 psi. IA lost 20 psi 1st 15 min, 3 psi 2nd 15 min. No change on treecap pressure. FWHP = 0/100/09 6/21/2011 T /I /O = SSV /50/0. TEMP = SI. Bleed IA/OA to 0 psi (Pre RIG). IA FL @ surface. Bled IAP to slop trailer from 50 psi to 0 psi in 10 minutes. Monitored for 30 min, IAP remained at 0 psi. Job complete. Final WHPs = SSV /0/0. Page2of2 • • North America ALA IQ , BPS Page Operation :Summa ry Report Common Well Name: 13 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) , Start Date: 6/24/2011 1 End Date: iX3- OOXTY -C (4,681,752.11 ) Project: Prudhoe Bay I Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: 5/26/1983 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date ' From - To Hrs Task Code NPT : NPT Depth Phase ! Description of Operations (h (ft) 6/26/2011 00:00 - 03:00 3.00 MOB P PRE I ACCEPT NABORS 7ES RIG CHARGES @ 00:00 ON 6/26/2011. CONTINUE GENERAL RIG I DOWN OPERATIONS ON X -22 IN ! PREPARATION FOR RIG MOVE TO DS 13 -27B. - WSL OPEN WELLWORK TRANSFER PERMIT 'WITH DS 13 OPERATOR. I- COMPLETE RIG FLOOR RIG DOWN `CHECKLIST. LAYDOWN CATTLE CHUTE. ! - DISCONNECT AND SECURE TOP DRIVE AT RIG FLOOR. RU BRIDLE LINES TO BLOCKS. I- FIRE UP COLDSTART GENERATOR AND DISCONNECT PIT MODULE. PULL MODULE AWAY FROM SUB AND STAGE ON X PAD - PULL CUTTINGS BOX AWAY FROM RIG. WELL PROGRAM PURPOSE: I ! - DECOMPLETION & ABANDONMENT OF ' 13 -27A (UNABLE TO PRODUCE DUE TO CMT IN LNR). - DRILLING & COMPLETION OF 13 -27B ! SIDETRACK, MAINTAINING OPTIONS FOR ! FUTURE SIDETRACK. 03:00 - 04:00 ! 1.00 MOB P PRE PJSM _ LAYDOWN DERRICK AND SECURE FOR RIG MOVE. 04:00 - 10:00 6.00 MOB P PRE MOVE RIG FROM X PAD TO DS 13. STAGE ! RIG ON PAD, WAITING ON GRAVEL AND RIG MAT WORK AROUND WELL 13 -27B. ' - SECURITY ESCORT PROVIDE FOR ROAD , TRAVEL. - RIG MATS LAID FOR MAJORITY OF X PAD ' � ACCESS ROAD. NO ROAD STABILITY ISSUES ENCOUNTERED DURING RIG MOVE. 10:00 12:00 2.00 MOB P , PRE RIG DOWN AUXILLARY MODULES ON X PAD / — _ - _ AND PREPARE TO MOVE TO DS 13. ✓ 12:00 - 16:00 I 4.00 MOB P 1 PRE MOVE CAMP, SHOP AND PIT MODULE TO DS 13. SPOT SATELLITE CAMP & RIG UP. ! 16:00 - 19:00 3.00 MOB N WAIT PRE WAIT ON GRAVEL WORK AROUND WELL. - N7ES RIG STAGED ON DRILLSITE 13 - CANRIG MODEL 6027E -939, 600 HP, 275 TON TOP DRIVE DUE FOR 3 YEAR INSPECTION. - CHANEGOUT OF TOP DRIVE REQUIRES MOBILE CRANE OPERATION TO PICK OLD AND SET REPLACEMENT TOP DRIVE ON RIG. - WINDS GUSTING TO OVER 20 MPH. LEVEL 2 RISK ASSESSMENT REQUIRED. - CALLS MADE TO OPERATION SUPERINTENDENTS, BP DRLG HSE, BP LIFTING AUTHORITY. - BEN CUARESMA, BP LIFT AUTHORITY, TO GIVE VERBAL APPROVAL AFTER PRE -JOB AND RISK ASSESSMENT / LIFT PLAN , COMPLETED. Printed 7/5/2011 10:34:12AM vrth Amenea - A@ASKA BP Page 2 cam . d eratioin Summary Report ■ Common Well Name: 13 -27 I AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 6/24/2011 I End Date: l X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay Site: PB DS 13 , Rig Name /No.: NABORS 7ES Spud Date/Time: 5/26/1983 12:00:OOAM ! Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292094900 Active Datum: 13 -27 ©83.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth ! Phase Description of Operations (hr) I (ft) i19:00 - 20:00 1.00 MOB N I WAIT PRE PEAK LATTICE CRANE ON LOCATION. - MEETING WITH WSL, PEAK PUSHER, I , i NABORS SAFETY AND NABORS I I i TOOLPUSHERS. F- WIND SPEED OVER 20 MPH. AIRPORT ' WIND SPEED 28 MPH. - DECISION MADE TO NOT PERFORM LIFT f UNTIL WINDS SUBSIDE, CRANE TO WAIT ON I LOCATION. PEAK TO GENERATE LIFTING PLAN PRIOR ! TOLIFT. ' 20:00 - 00:00 4.00 MOB N WAIT PRE !CONTINUE TO WAIT ON GRAVEL BUILDUP !AROUND WELL 13 -27B I ! ' - TOOL SERVICES AND ROADS/PADS WORKING ON 40" BUILDUP AROUND WELL , MADE OF GRAVEL AND RIG MATS. ! ;- RIG CREWS PREPPING TOP DRIVE FOR 1 REMOVAL FROM RIG. I- NEW ROLLER INSTALLED ON OFF DRILLER I SIDE TUGGER. !- BORESCOPE INSPECTION OF BOP STACK _ INTERNAL ELEMENTS. 6/27/2011 00:00 - 08:00 8.00 MOB N WAIT 1 PRE CONTINUE TO WAIT ON GRAVEL BUILDUP ;AROUND WELL 13 -27B - 7ES RIG STAGED ON PAD - TOOL SERVICES & ROADS/PADS CONTINUE TO BUILDUP PAD 40" AROUND WELL 13 -27B. '- WELLHEAD & TREE LINED ON THREE SIDES . WITH RIG MATS. FOURTH SIDE (TOWARDS • FLOWLINE) IS OPEN TO ALLOW ACCESS TO WELLHEAD WITHOUT CONFINED SPACE / 1 I ' HAZARD. - AUXILIARY BUILDINGS AND SUPPORT EQUIPMENT SPOTTED ON DRILLSITE 13. I- PEAK CRANE ON LOCATION, WAITING ON WINDS TO SUBSIDE FOR CHANGEOUT TOP DRIVE - RIG CREW CONTINUING TO CLEAN & PREPARE TOP DRIVES FOR CHANGEOUT. DISCONNECT KELLY HOSE AND SERVICE BUNDLE. - REBUILD 2" DEMCO BLEED VALVE ON RIG FLOOR MUD MANIFOLD. - REPLUMB AIR LINE TO CELLAR. 08:00 10:00 2.00 MOB N WAIT I PRE CONTINUE TO WAIT ON GRAVEL BUILDUP AROUND WELL 13 -27B - PEAK TRUCK PUSHER AND CRANE OPERATOR ARRIVE ON LOCATION AND DEVELOP LIFT PLAN FOR TOP DRIVE. - PRE -JOB MEETING HELD WITH WSL, TOOLPUSHER, RIG CREW, CRANE OPERATOR, RIGGER, PEAK HSE REP & BP DRILLING HSE REP TO DISCUSS LIFT PLAN. - SPOT CRANE AND PICKUP SLIGHT TENSION ON TOP DRIVE TO CONFIRM WEIGHT FOR LIFT PLAN. TOP DRIVE WEIGHT = 23 KLBS. - POSITION OF EACH CREWMEMBER DURING ' I JOB REVIEWED. Printed 7/5/2011 10:34:12AM pith America ALASKA - BP L Page,3 Rte °Aeration Summary Report ' Common Well Name: 13 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/24/2011 i End Date: X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay I Site: PB DS 13 —I I, Rig Name /No.: NABORS 7ES Spud Date/Time: 5/26/1983 12:00:OOAM I Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ' UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date ' From - To ' Hrs Task Code i NPT NPT Depth Phase Description of Operations (hr) i- __ (ft) 10:00 - 13:00 3.00 MOB N WAIT I PRE j PEAK LATTICE CRANE CHANGEOUT TOP !DRIVE ON RIG N7ES ; - CANRIG TOP DRIVE (SER # 220) PICKED FROM TORQUE TRACKS ON RIG FLOOR AND ',LOWERED TO GROUND. - SERVICED CANRIG TOP DRIVE FROM 2ES (SER # 211) RAISED TO RIG FLOOR AND GUIDED ONTO TORQUE TRACKS. - HYDRAULIC IBOP ON NEW TOP DRIVE SWAPPED OUT FOR PNEUMATIC IBOP FROM ' 7ES TOP DRIVE. ' - RDMO PEAK CRANE. 7ES CANRIG TOP DRIVE SENT IN FOR THREE YEAR INSPECTION. 13:00 - 00:00 11.00 MOB I N WAIT PRE CONTINUE TO WAIT ON GRAVEL BUILDUP I AROUND WELL 13 -27B - RAISE DERRICK, RIG DOWN BRIDLE LINES, ' RU BLOCKS TO TOP DRIVE, RU KELLY HOSE & SERVICE BUNDLE. RAISE CATTLE CHUTE. - RE- CONNET TOP DRIVE. FUNCTION TEST !AND TROUBLESHOOT AS NECESSARY. - QUILL THREADS ON NEW TDS INSPECTED BY TUBOSCOPE. - VARIOUS MAINTENANCE ACTIVITIES ACCOMPLISHED ON THE RIG AND IN PIT j MODULE. I - NOTIFICATION - AOGCC REP JEFF JONES NOTIFIED OF IMPENDING BOPE TEST @ ' 19:22 HRS (MESSAGE). MR. JONES ' RETURNED CALL AND WAIVED STATE'S ' !RIGHT TO WITNESS TEST. 6/28/2011 00:00 - 03:00 3.00 MOB N WAIT : PRE WAIT ON PAD PREP WORK AROUND WELL ! 13 -27. - DOUBLE STACK RIG MATS ON GRAVEL PAD AROUND WELL 13 -27. RIG MATS LAID ON ACCESS ROAD TO BACK OF DS 13 FROM ' FRONT OF DRILLSITE. 03:00 - 05:00 2.00 1 MOB P PRE MOVE RIG FROM STAGING AREA ON FRONT OF DRILLSITE TO WELL 13 -27. - GRAVEL BUILDUP AND RIG MAT WORK AROUND WELL COMPLETE @ 03:00. 05:00 - 06 :00 1.00 MOB P ; PRE , SPOT RIG OVER WELL. , - WH & TREE PRESSURES: OA = IA = TBG = 0 PSI. OA CEMENTED TO SURFACE DURING ; RWO IN FEB 2010. 500 PSI MIT -OA IN MAR 2010 CONFIRMED CEMENT IN OA. - ALL PRE -RIG WORK CONFIRMED COMPLETE. 4 -1/2" CAMERON TYPE H BPV SET AND TESTED FROM BELOW ON 6/20/2011. - WSL WITNESS RIG SPOTTING. - DROP PLUM BOB FROM ROTARY TABLE TO CENTER OVER WELL. COVER RIG MATS W/ HERCULITE LINER. LAY DOWN LINER j AROUND BASE OF WELLHEAD IN CELLAR. Printed 7/5/2011 10:34:12AM orth America - ALASKA BP Page 4 oe .. ' Operation Summary Report ______ Common Well Name: 13 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/24/2011 End Date: X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay ! Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: 5/26/1983 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date From - To Hrs 1 Task I Code NPT NPT Depth Phase Description of Operations (hr) 1 06:00 - 14:00 8.00 RIGU P , PRE , SPOT PIT MODULE NEXT AND RIG SUB AND RIG UP CONNECTIONS. - INSTALL DOUBLE VALVES ON IA AND OA. !- ELECTRICIANS AND CANRIG REP 'TROUBLESHOOTING TDS PROGRAMMABLE LOGIC CONTROL (PLC). - LOAD 4" DRILLPIPE INTO PIPE SHED. I I- HELD PRESPUD MEETING WITH BOTH CEWS AT NOON CHANGE OUT. - WELDER INSTALLED GUARD ON PIPE SKATE TO ELIMINATE POTENTIAL TRIPPING HAZARD ON RIG FLOOR. - LAY MATS AND SET CUTTINGS BOX - LAY MATS IN FRONT OF PITS TO 'ACCOMMODATE VAC TRUCKS. � - SPOT 500 BBL BLEED DOWN TANK 14:00 19:30 5.50 1 RIGU 1 P PRE RECEIVE TWO TRUCK LOADS (580 BBL) OF 120 DEG F 1% KCL WATER 8.5 PPG. ***ACCEPT RIG AT 14:00 HRS 6 -28 -2011 * ** - CONDUCT A RIG EVACUATION DRILL WITH I 1 TALL HANDS ON THE RIG AND CAMP 1 I 1 - WELL SUPPORT CREW RIG UP AND TEST HARD LINE FROM 500 BBL TANK TO WELL. - RIG UP LINES TO WELL HEAD AND TREE TO `PERFORM MIT - MIT TUBING AND IA TO 250 PSI FOR 5 I MINUTES AND 2000 PSI FOR 30 MINUTES - PASSED MIT: FIRST 15 MIN - LOST 25 PSI. 1 SECOND 15 MIN - LOST 20 PSI. THIRD 15 MIN - LOST 5 PSI. - CONTACTED WTL AND DISCUSSED RESULTS OF MIT. 19:30 - 21:30 2.00 WHSUR P DECOMP PICK UP DSM LUBRICATOR AND PRESSURE TEST. 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN j EACH. PULL BPV AND LAY DOWN. 21:30 - 00:00 2.50 WHSUR P DECOMP '' CIRCULATE OUT DIESEL FREEZE PROTECT, I TO OPEN TOP TANK. - REVERSE OUT 34 BBLS OF DIESEL FROM THE TUBING. - 4 BPM AND 340 PSI. - SWAP LINES AND CIRCULATE OUT 134 BBLS OF DIESEL FROM THE IA. - 4 BPM AND 130 PSI. 6/29/2011 00:00 01:00 1.00 WHSUR P DECOMP CONTINUE TO CIRCULATE OUT DIESEL FREEZE PROTECT. - CIRCULATE UNTIL RETURNS ARE CLEAN. - SHUT DOWN AND MONITOR WELL. - NO FLOW. 01:00 03:00 2.00 WHSUR P DECOMP RIG UP DSM LUBRICATOR AND INSTALL TWC. - RIG UP DSM LUBRICATOR AND PRESSURE TEST 250/3500 FOR 5 CHARTED MIN. - INSTALL TWC. - PRESSURE TEST TWC: - 250/3500 PSI FROM ABOVE FOR 5 CHARTED MIN EACH. - 250/2000 PSI FROM BELOW FOR 5 CHARTED MIN EACH. I - RIG DOWN DSM LUBRICATOR AND LAY I DOWN. Printed 7/5/2011 10:34:12AM orth America ALASKA Bt' age 5 0200tr Operation Summary Report Common Weli Name: 13 -27 I AFE No Event Type: RE- ENTER- ONSHORE (RON) ' Start Date: 6/24/2011 1 End Date: X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay I Site: PB DS 13 I Rig Name /No.: NABORS 7ES I Spud Date/Time: 5/26/1983 12:00:OOAM ' Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ! UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date I From - To ! Hrs I Task 1 Code I NPT i NPT Depth Phase Description of Operations ' (hr) I I I (ft) ' 03:00 - 05:00 2.00 ' WHSUR I P , DECOMP NIPPLE DOWN TREE AND ADAPTFR Fl ANC,F I I AND REMOVE FROM CELLAR. 1 I i- PJSM WITH RIG CREW AND FMC REPRESENTATIVE. '- FMC REPRESENTATIVE INSPECTED THE HANGER THREADS. ' - GOOD CONDITION; 7 TURNS HANDY I 'WITH THE 'XO'. ! - CLEAR CELLAR OF WELLHEAD EQUIPMENT. 05:00 - 08:00 3.00 BOPSUR P DECOMP ! NIPPLE UP BOPE. I '- PJSM WITH RIG CREW. 08:00 - 08:30 0.50 BOPSUR T P NIPPLE UP ROPE STACK AND RISER. DECOMP - - - - -- - - - -- - - - -- 1 !RIG UP TO TEST BOPE. 08:30 - 09:00 0.50 BOPSUR I P I I DECOMP I PERFORM H2S /RIG EVACUATION DRILL. I- __— AAR FOLLOWING DRILL. 09:00 09:30 0.50 BOPSUR P — - DECOMP CONTINUE TO RIG UP BOPS TEST EQUIPMENT. r FILL THE STACK AND CHOKE MANIFOLD. I Printed 7/5/2011 10:34:12AM pC T AAmeriCB 7 ALASKA - BP Page 6 peratiorn� Summary Report Common Well Name: 13 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/24/2011 End Date: 1X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay Site: PB DS 13 1 Rig Name /No.: NABORS 7ES ' Spud Date/Time: 5/26/1983 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date From - To 1 Hrs Task Code i NPT ' NPT Depth Phase ' Description of Operations (hr) (ft) 109:30 17:00 Ir 7.50 I BOPSUR I P DECOMP TEST BOPE PER AOGCC REGULATIONS AND I I BP ADWOP POLICY. PRESSURE TESTED TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. - TESTED ALL CHOKE MANIFOLD VALVES (16 ; TOTAL). MANUAL CHOKE AND MANUAL KILL VALVES. - HCR CHOKE AND NCR KILL VALVES. n FULL OPENING SAFETY VALVES (3 1/2 ", 4" ANDS "). I i - 4" DART VALVE. - AIR ACTUATED IBOP ON TOP DRIVE. 1: MANUAL IBOP ON TOP DRIVE. - BLIND /SHEAR RAMS. - UPPER 3 1/2" x 6" VBRS WITH 4" AND 4 1/2" TEST JOINT. - LOWER 2 7/8" x 5" VBRS WITH 4" AND 4 1/2" TEST JOINT. - - ANNULAR PREVENTER WITH 4" TEST JOINT. - SUPER CHOKE AND MANUAL BEAN CHOKE. ' l - 250 PSI LOW AND 1600 PSI HIGH FOR 5 CHARTED MINUTES. 1 FAIUPASS: - BLIND SHEAR RAMS LEAKED ON INITIAL 1 LOW PRESSURE TEST. - FUNCTIONED RAMS AGAIN AND RETESTED GOOD. CLOSING TIMES: - ANNULAR CLOSED IN 25 SEC. ' - UPPER VBRS CLOSED IN 7 SEC. 1 - BLIND /SHEAR RAMS CLOSED IN 14 SEC. 1 - LOWER VBRS CLOSED IN 7 SEC. PERFORMED AN ACCUMULATOR DRAWDOWN TEST. - 19 SEC TO 200 PSI. - 96 SEC TO FULL PRESSURE. - 5 BOTTLES WITH 2050 PSI. TESTED THE SIERRA GAS MONITORING SYSTEM. TESTS WITNESSED BY BP WSL AND NABORS TOOLPUSHER. AOGCC, JEFF JONES, WAIVED THE STATE'S 1 RIGHT TO WITNESS THE TEST. 17:00 - 18:00 1.00 WHSUR ! P DECOMP RIG DOWN BOPE TEST EQUIPMENT. 1 - BLOW DOWN TOP DRIVE, CHOKE MANIFOLD, AND CHOKE AND KILL LINES. ' 18:00 - 19:00 1.00 WHSUR P DECOMP RIG UP DUTCH RISER. 19:00 - 20:30 1 1.50 BOPSUR N RREP - - --- - - -- - -- - -- DECOMP ' 0-RINGS ON LOCK DOWN SCREWS FOR 1 DUTCH RISER LEAKED. - RIG DOWN DUTCH RISER ' - DRAIN STACK TO BELOW LOCK DOWN ' SCREWS FOR DUTCH RISER. - PULL LOCK DOWN SCREWS AND REPLACE 0-RINGS. - RIG UP DUTCH RISER. Printed 7/5/2011 10:34:12AM arth America - ALASKA - BP Page 7 Ozer Operation Summary Report Common Well Name: 13 -27 �u AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 6/24/2011 I End Date: X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: 5/26/1983 12:00:OOAM : Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date ' From - To Hrs Task Code ' NPT !, NPT Depth I Phase Description of Operations (hr) I (ft) L 20:30 - 23:00 2.50 1 WHSUR N SFAL DECOMP TRIG UP DSM LUBRICATOR. I - PRESSURE TEST LUBRICATOR TO 250/3500 I I PSI FOR 5 CHARTED MIN. I - ATTEMPTED TO PULL TWC. - UNABLE TO ENGAGE THE TWC DUE TO DEBRIS ON TOP OF THE TWC. T CHANGED OUT THE RUNNING TOOL. `- PRESSURE TEST THE QUICK TEST SUB ' 250/3500 PSI FOR 5 MIN EACH. - ATTEMPTED TO PULL THE TWC. - STILL UNABLE TO ENGAGE THE TWC DUE TO DEBRIS. 23:00 00:00 ' 1.00 WHSUR N WSEQ1 DECOMP .WASH DEBRIS FROM THE TOP OF THE TWC. I- MAKE UP A MULE SHOE ON 1 JOINT OF4" DRILL PIPE. 1 ,- MAKE UP, TOP DRIVE AND PUMP AT 13.5 1 BPM AND 83 PSI. RECOVERED SEVERAL GALLONS OF SAND. 6/30/2011 00:00 - 00:30 0.50 WHSUR N ? WSEQ I i DECOMP „CONTINUED TO CLEAN OFF DEBRIS FROM 1 THE TOP OF THE TWC. - RECOVERED SEVERAL GALLONS OF SAND. ' . � - LAY DOWN MULE SHOE AND JOINT OF 4" DRILL PIPE. 00:30 02:30 2.00. WHSUR NI WSEQ I , DECOMP ATTEMPT TO PULL TWC. ' - PICK UP AND INSTALL DUTCH RISER. - MAKE UP DSM LUBRICATOR AND TEST 1250/3500 PSI. - ATTEMPT TO PULL TWC. i - UNABLE TO ENGAGE THE TWC. 02:30 - 04:00 1.50 1 WHSUR N 1 WSEQ' ! DECOMP RIG UP SUPERSUCKER AND ATTEMPT TO I 1 I CLEAN DEBRIS OFF OF TWC. 04:00 - 07:00 3.00 WHSUR ! N i WSEQ DECOMP I PULL TWC. - MAKE UP DSM LUBRICATOR AND PRESSURE TEST QUICK TEST SUB 250/3500 1 PSI. '1 I - UNABLE TO GET RUNNING TOOL TO ENGAGE TWC. I - RIG DOWN LUBRICATOR. ' - RIG UP SECONDARY KILL LINE TO IA. - APPLY 2000 PSI TO BOTTOM OF TWC THROUGH IA. - ATTEMPTING TO MOVE POPPET IN TWC 'AND DISLODGE DEBRIS. - BLEED OFF PRESSURE ON IA. - RUN A WATER HOSE DOWN STACK AND FLUSH TOP OF TWC. ' - USE SUPERSUCKER AND CLEAN OUT „ DEBRIS FROM TWC. - RIG UP DSM LUBRICATOR AND PRESSURE TEST QUICK TEST SUB TO 250/3500 PSI. - PULL TWC AND RIG DOWN DSM LUBRICATOR. 07:00 - 08:00 1.00 PULL P DECOMP RIG UP TUBING HANDLING EQUIPMENT. - RIG UP DOUBLE STACK TONGS AND ELEVATORS. Printed 7/5/2011 10:34:12AM gr th America,- ALASKA - BP Page 8 oft rat io , n Summary Report Common Well Name: -27 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/24/2011 End Date: 1X3- OOXTY -C (4,681,752.11 ) Project: Prudhoe Bay I Site: PB DS 13 Rig Name /No.: NABORS 7ES 1 Spud Date/Time: 5/26/1983 12:00:OOAM ,Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ! UWI: 500292094900 Active Datum: 13 -27 ©83.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT . NPT Depth Phase I Description of Operations 09:00 1 00 PULL P (ft) 08:00 DECOMP - I UNSEAT AND PULL TUBING HANGER TO THE I RIG FLOOR. - MAKE UP LANDING JOINT TO TUBING HANGER AND TOP DRIVE. 1 1- FMC REPRESENTATIVE BACKED OUT THE 1 I LOCK DOWN SCREWS. I 1 - PULLED TUBING HANGER TO RIG FLOOR. I , - NO OVERPULL WAS REQUIRED TO UNSEAT THE HANGER. ' - UP WEIGHT = 63K LBS. ' 09:00 - 10:00 1.00 PULL P DECOMP {PUMPED A 50 BBL SAFE - SURF -O II PILL 1 ! SURFACE TO SURFACE. 1 - 8 BPM AND 135 PSI. 1 - MONITORED WELL FOR 10 MIN. NO FLOW. 10:00 - 10:30 0.50 1 PULL 1 P ' DECOMP RIG UP COMPENSATOR AND 41/2" YC ' ELEVATORS TO PULL THE 4 1/2" VAMTOP COMPLETION. 10:30 15:00 4.50 ! PULL 1 P DECOMP PULLED THE 4 V2 ", 12. 6 LB/FT, VAMTOP - - COMPLETION. FROM 3622' SLM TO CUT JOINT. '- RECOVERED: 85 JTS OF 4 1/2" TUBING, 2 PUP JOINTS WITH AND 'X' ' NIPPLE, I CUT JOINT (38.45'). ' 15:00 - 17:00 ! 2.00 PULL ' P DECOMP ' RIG DOWN TUBING HANDLING EQUIPMENT. RIG DOWN DOUBLE STACK TONGS AND . I COMPENSATOR. , I 1- CHANGE THE BAILS AND ELEVATORS. - - - -- -- -, -- - -- -- - -- - - - - - - -- 1 17:00 17:30 0.50 WHSUR '� P DECOMP INSTALL 9 " ID WEAR RING. I 1 17:30 - 19:00 j 1.50 ' CLEAN 1 P DECOMP PICK UP SOME OF THE CLEAN OUT BHA , 1 PRIOR TO PICKING UP DRILL PIPE. ,- RUN IN THE HOLE WITH A MULE SHOE AND (9) 6 1/4" DRILL COLLARS. - TO 277' DPM. UP WEIGHT = 45K LBS, DOWN WEIGHT = 145K LBS. 19:00 - 23:00 4.00 I CLEAN P , DECOMP RUN IN THE HOLE WITH THE MULE SHOE , AND DRILL COLLARS, PICKING UP 4" DRILL PIPE FROM THE PIPE SHED. - FROM 277' TO 3569' DPM. - UP WEIGHT = 60K LBS, DOWN WEIGHT = 60K LBS. 23:00 00:00 1.00 CLEAN P DECOMP TRIP OUT OF THE HOLE STANDING BACK 4" ' DRILL PIPE STANDS IN THE DERRICK. - FROM 3569' TO 277' DPM. 7/1/2011 00:00 01:00 1.00 CLEAN P DECOMP RUN IN THE HOLE PICKING UP 4" DRILL PIPE FROM THE PIPE SHED. - FROM 277' TO 1500' DPM. 01:00 02:00 1.00 CLEAN ' P DECOMP TRIP OUT OF THE HOLE STANDING BACK 4" DRILL PIPE STANDS IN THE DERRICK. ' - FROM 1500'. - STAND BACK 6 1/4" DRILL COLLARS IN THE DERRICK. - MONITOR WELL FOR 10 MIN. - NO FLOW. Printed 7/5/2011 10:34:12AM •orth America .7 ALASKA BP Page 9 a Oper'atio'n Summary Report. , Common Well Name: 13 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/24/2011 End Date: IX3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES Spud Date/Time: 5/26/1983 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date From - To Hrs ! Task r Code NPT NPT Depth Phase Description of Operations (hr) 1 (ft) I 02:00 - 03:00 1.00 CLEAN P WEXIT [PICK UP CLEAN OUT BHA. - PJSM WITH RIG CREW AND BAKER FISHING REPRESENTATIVE. - DISCUSS NON - SHEARABLES ACROSS THE BOP STACK. CLEAN OUT BHA AS FOLLOWS: - 8 1/2" USED MILL TOOTH BIT. 1 f - BIT SUB WITH FLOAT. - 8 1/2" UPPER WATERMELON MILL. ' - (9) 6 1/4" DRILL COLLARS. - (15) 5" HEAVY WEIGHT DRILL PIPE. - 'XO' BACK TO 4" HT -40. OVERALL LENGTH = 747.06' MAX OD = 8.5" 1 03:00 - 06:00 3.00 CLEAN P '� WEXIT RUN IN THE HOLE WITH THE CLEAN OUT BHA. 1- FROM 747' TO 3473' DPM. PICKING UP 4" DRILL PIPE FROM THE PIPE . SHED. 06:00 - 06:30 0.50 CLEAN P WEXIT I CONTINUE TO RUN IN THE HOLE WITH THE CLEAN OUT BHA. - FROM 3473' TO 3632' DPM. I- RUN IN THE HOLE ON STANDS OF 4" DRILL L PIPE FROM THE DERRICK. TAG TOP OF TUBING STUB AT 3632' WITH 5K LBS. 06:30 - 07:30 1.00 CLEAN P WEXIT CIRCULATE A 25 BBL HIGH -VS SWEEP TO CLEAN UP THE WELLBORE. 12 BPM AND 1152 PSI. 1 SLOW PUMP RATES TAKEN AT 3632' MD , 3593' TVD. - PUMPS 1 AND 2: ' I - 2 BPM AND 40 PSI; 3 BPM AND 60 PSI. 07:30 - 10:00 2.50 I CLEAN P WEXIT ' TRIP OUT OF THE HOLE WITH THE CLEAN OUT BHA, STANDING BACK 4" DRILL PIPE IN THE DERRICK. - FROM 3632' TO 747' DPM. - ROTATED PAST THE ES CEMENTER AT ; 1867'. - MONITORED THE WELL. NO FLOW. 10:00 - 11:30 1.50 CLEAN P WEXIT LAY DOWN THE CLEAN OUT BHA. - STOOD BACK THE 5 STANDS OF HEAVY WEIGHT DRILL PIPE. - STOOD BACK THE 3 STANDS OF 6 1/4" DRILL COLLARS. LAID DOWN THE REST OF THE CLEAN OUT BHA. 11:30 - 13:00 1.50 STWHIP P WEXIT RIC; t IP SCHI 11MRFRGFR F -I INF - PJSM WITH RIG CREW AND SCHLUMBERGER E -LINE CREW. - RIG UP E -LINE WITH AN AIR LINE WIPER. 13:00 - 14:00 1.00 STWHIP P WEXIT RUN AND SET 95/8" HES 'EZSV' BRIDGE , PLUG ON E -LINE. - 9 5/8" COLLAR AT 3428'. .SET 'EZSV' AT 3423'., 14:00 15:00 1.00 STWHIP P WEXIT PULL OUT OF THE HOLE WITH 1 SCHLUMBERGER E -LINE AND RIG DOWN. Printed 7/5/2011 10:34:12AM orth Amriertca.; ALASKA - BP Page 10 Operation Summaiy Report ■ Common Well Name: 13 -27 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 6/24/2011 End Date: X3- 00XTY -C (4,681,752.11 ) L -J, Project: Prudhoe Bay Site: PB DS 13 Rig Name /No.: NABORS 7ES I Spud Date/Time: 5/26/1983 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (ft) 15:00 - 16:30 1.50 STWHIP P WEXIT +, PRESSURE TEST 'EZSV' BRIDGE PLUG AND 9 I I ' 5/8" CASING. - 250 PSI LOW FOR 5 CHARTED MIN. - PRESSURED UP TO TEST AT HIGH PRESSURE AND SENSATOR FAILED. - REPLACED SENSATOR AND PRESSURED 1 UP. - SECOND SENSATOR FAILED. , - CHANGED SENSATOR AND LINE. ; I `- PRESSURED UP TO 3500 PSI FOR 30 1 1 CHARTED MIN. - USED DIGITAL GUAGE FOR PRESSURE LOSSES: - LOST 5 PSI IN FIRST 15 MIN. - LOST 2 PSI IN SECOND 15 MIN. - GOOD TEST. - DISCUSSED PRESSURE TEST RESULTS — WITH WTL. ' 16:30 - 00:00 7.50 I STWHIP N RREP I WEXIT ADJUST TOP DRIVE ALIGNMENT. - WHEN SAVER SUB IS AT THE FLOOR IT IS j ALMOST 4" OFF CENTER TO THE DRAW I ! I WORKS SIDE. - SHIM LOWER TORQUE TUBE. ' t - NEEDS ALMOST 2" OF SHIMS. - MOVE SERVICE LOOP TO LOWER BRACKET TO AVOID CONTACT WITH PAD EYES IN DERRICK. 7/2/2011 00:00 - 05:00 5.00 STWHIP ; N RREP WEXIT I CONTINUE TO ADJUST TOP DRIVE. CONTINUE TO SHIM AND ADJUST TOP I I DRIVE. ' I I - TAKE PHOTOS OF SHIMS AND I 1 ADJUSTMENTS AND SEND TO CANRIG. STWHIP P 05:00 - 06:00 1 1.00 I WEXIT BRING BHA COMPONENTS FOR WHIPSTOCK TO RIG FLOOR. - PREP THE PIPE SHED FOR PICKING UP BHA. 06:00 - 07:00 I 1.00 STWHIP P WEXIT PICK UP BHA #2, WHIPSTOCK ASSY. - PJSM WITH RIG CREW AND BAKER I REPRESENTATIVE. - DISCUSS NON - SHEARABLES ACROSS THE BOP STACK. - THE TRIP ANCHOR ON THE WHIPSTOCK WAS SHEARED. - THE SHEAR PINS AND SHIPPING BOLT WERE SHEARED. 07:00 - 08:00 1.00 STWHIP N WAIT WEXIT MOBILIS A NEW TRIP ANCHOR FOR THE WHIPSTOCK ASSY. - BROKE THE TRIP ANCHOR OFF OF THE ' WHIPSTOCK ASSY. - BAKER BROUGHT OUT A NEW TRIP ANCHOR. I I - INSTALLED AND TORQUED UP THE NEW TRIP ANCHOR PER THE BAKER , I I REPRESENTATIVE. Printed 7/5/2011 10:34:12AM al•th America ALASKA - BP Page 11 ! , . • Operation Summary Report ___ Common Well Name: 13 -27 �J �� I` AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 6/24/2011 I End Date: X3- 00XTY -C (4,681,752.11 ) Project: Prudhoe Bay I Site: PB DS 13 Rig Name /No.: NABORS 7ES I Spud Date/Time: 5/26/1983 12:00:OOAM 1Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292094900 Active Datum: 13 -27 @83.00ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT III NPT Depth Phase Description of Operations (hr) (ft) I — — 08:00 - 10:00 III 2.00 STWHIP P 1 1 WEXIT I CONTINUE TO PICK UP BHA #2, WHIPSTOCK ASSY. - PICK UP AND MAKE UP BHA #2 AS FOLLOWS: - TRIP ANCHOR. - GEN 2 WHIPSTOCK SLIDE. - 8 1/2" STARTER MILL. ' - 8 3/8" LOWER WATERMELON MILL. 8 UZ" UPPER WATERMELON MILL. - 8 1/2" UPPER WATERMELON MILL. I - (1) 5" HEAVY WEIGHT DRILL PIPE. - MWD. - (9) 6 1/4" SPIRAL DRILL COLLARS. - (15) 5" HEAVY WEIGHT DRILL PIPE. -'XO'. 1 OVERALL LENGHT = 842.9" . I MAX OD = 8.50". 10:00 11:30 1.50 STWHIP P WEXIT I RUN IN THE HOLE WITH THE WHIPSTOCK BHA. - TO 3381' DPM. FILLING THE PIPE EVERY 20 STANDS. I - UP WEIGHT = 106K LBS, DOWN WEIGHT - I , I 100K LBS. I - SHALLOW TEST THE MWD. I - PUMP AT 450 GPM AND 570 PSI. 11:30 12:00 0.50 STWHIP P WEXIT CONTINUE TO RUN IN THE HOLE WITH THE WHIPSTOCK BHA. I - FROM 3381' TO 3425' DPM. - ORIENT THE WHIPSTOCK TO 60 DEG RIGHT. SET DOWN 22K LBS AND SHEAR THE TRIP I I ANCHOR. SET DOWN 50K LBS AND SHEAR THE MILLS , j I FROM THE SLIDE. , 1 ' - TOP OF WINDOW = 3404'; BOTTOM OF _ _ WINDOW = 3421'. t 12:00 - 13:00 1.00 STWHIP P WEXIT I DISPLACE WELL TO 10.0 PPG LSND. 1- 450 GPM AND 840 PSI. - SLOW PUMP RATES PUMPS 1 AND 2. - TMD = 3404', TVD = 3385'. 2 BPM AND 110 PSI; 3 BPM AND 150 PSI. 13:00 - 18:30 5.50 STWHIP P ' WEXIT !MILL WINDOW IN 9 5/8" CASING. ' - FROM 3404' TO 3421' DPM. G-9:76 - MILL 40' OF NEW HOLE TO 3452' DPM. I - UP WEIGHT = 105K LBS; DOWN WEIGHT = 98K LBS. - ROTATING WEIGHT = 102K LBS. 1 - 100 RPM AND 2K FT -LBS OF TORQUE OFF BOTTOM. I - 8K LBS WEIGHT ON BIT AND 6K FT -LBS I TORQUE ON BOTTOM. - 450 GPM AND 840 PSI. 18:30 - 19:30 1.00 1 STWHIP P WEXIT CIRCULATE A 0.25 PPB SUPER SWEEP TO I CLEAN THE HOLE. - WORKED THE MILLS ACROSS THE WINDOW WITH AND WITHOUT CIRCULATION. - CIRCULATED THE SUPER SWEEP WITH ROTATION AND RECIPROCATION. - 450 GPM AND 895 PSI. - UP WEIGHT = 105K LBS; DOWN WEIGHT = 98K LBS. - 100 RPM AND 2K FT -LBS TORQUE. , 1- RECOVERED 305 LBS OF METAL. Printed 7/5/2011 10:34:12AM TREE = ' CM/ WELLHEAD = FMC • SAFETY : WELL ANGLE> 70° @ 10535'. ACTUATOR = BAKER 0 13 -2 7 ** *CHROME TBG & NIPPLES * ** KB. ELEV = 83' BF. ELEV = ? A w KOP = 2800' '1' 1 ♦1 - 14 14 Max Angle = 97° @ 11087' ' +, X 4 4 GAS LIFT MANUKLL 14 Datum MD = 10297' Wile S L 1_ i it / 1I ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800' SS �S V y0 , , ∎ I 5 3686 3651 23 MMG DMY RK 0 04/27/11 9 -5/8" CSG, 47 #, L -80 HYD 563, ID = 8.681" 1 1 : 67' �� 4 6421 5755 43 KBG2 OPEN BK 06/05/11 3 8199 7098 38 KBG2* DMY BK 0 01/15/10 1 13 -3/8" CSG, 72#, L -80 BUTT, ID = 12.347" 1-I 2634' 2 9189 7902 32 KBG2 DMY BK 0 01/15/10 1 9641 8292 28 KBG2 DMY BK 0 01/15/10 13.65" JET CUT (6/11/11) 1 3622' *SPECIAL CLEARANCE 3949' 1- 9 -5/8" X 7" ZXP LTP w /FLEXLOC LNR HGR, ID= 8.310" Minimum ID = 3.813" @ 2036' �� ,� 4-1/2" HES X NIPPLE i � 1•:•:•: 9719' 1 -14 -1/2" HES X NIP. ID = 3.813" 1 TOP OF CEMENT (05/31/11) 7990' CTM : ** * :1 : . : /� ► .4�, X766' j� 7" X 4 - BKR S -3 PAR, ID = 3.870" ♦ 111 • 9784' —14-1/2" HES X NIP, ID = 3.813" 1 • •• ■ 4 ►11111111• 4� 9857' H4-1/2" HES XN NIP, ID = 3.725" 1 4-1/2" TBG, 12.6 #, 13CR -85 VAM TOP, -$ 9869' ∎ 1 ► 4 • • • 4 • % • ' 1 1 1 9869' -14-1/2" WLEG 1 10 = 3.958" .0152 bP f,ID=3.958" /1 11111 .11111.1 . -' , 1. E -4, . �11A& V, 17" SCAB LNR, 264, L -80 BTC-M, ID = 6.276" 1 9912' X1. • 1 • 1.1 • • 1 •• 9910' --17' 1 /2 "XO,ID= 3.958"1 • ♦1 ∎•••••ff �1��11111 1• ► . t a i •• +4 9968 H4-1/2" X 5-1/2" X0, ID = 3.958" 1 • 0 P • 10, 9970' - 15 -1/2" BKR PBR ASSY, ID = ? 1 ■ ►•111111 •D�i / i 1 i 1 • 9984' H 5 -1/2" K ANCHOR, ID = 4.875" 1 ► .ti ► /2 ►11111111111 ►.1 ► � � � � � . 9985'1-19-5/8" X 5-1/2" BKR SA$ PAR. ID = 4.75" •'1 111111 •",, • ►••••• N TOP OF 7" LNR 1- 10038' •1 ••1••••. 9990' 1-17" BKR MILLOUT EXTENSION, ID = 5.50" 1 • ••••••4 1 : TOP OF 2 - 718" LNR 1 10044' 1 i -6 i+i 9997' H 7" X 4 X0, ID = 3.958" 1 ► „ ► 1 1 1 1 1 1 1 1 1 ► 1 1 1 • ► 1 ; 1 ; 1 -6 1 ; 1 ► - 10044' CEMENT SHEATH, ID = 2.20” (05/03/10) - �• 1 4-1/2" TBG -PC, 12.64, L -80, .0152 bpf, ID = 3.958" H 10101' ,► 1 ► 1 1 1 1 1 1 1 1 11 1 ► 1 , ►► 10044' - TOP OF LNR (46" SECTION PULLED OUT • 1 9 -5/8" CSG, 474, L -80 BTC, ID = 8.681" 1 10322' � ' - � �' AND TAGGED 0 9/04103) 4 ■ ►� i ►4 ♦4 ► • •,1 ; . . 10114F X 2 X0, ID = 2.441" 1 7" WHIPSTOCK 1 10440' ■i►i1 •i ► ► « % 1.4,4 4 10088' -14-1/2" OTIS XN NIP, ID = 3.725" 1 PERFORATION SUMMARY 1. ► i. 1` ► 1 • 1 ■• 14 4 REF LOG: BRCS ON 06/07/83 144 •■ • ►11• • 10099' — 14-112" BROWN SHEAROUT SUB 1 BEHIND • - * • CT LNR ANGLE AT TOP PERF: 97° @ 11035' j •j j • j • ►j 10101' — 14 - 1/2" TUBING TAIL, ID = 3.958 1 •• +1 111 Note: Refer to Production DB for historical pert data 04.4 •• 1,•41 INTERVAL Opn /Sqz DATE �•�•� 0� 1.4 • 1� ELMD TT NOT LOGGED 1 .7 11 ∎1 1414 2" 11035 - 11135 0 0 01 1414 . 1 �� ► ► 1 11 11 •• ■• 1114 2" 4 11', 50 - 11250 0 03/22/01 ►1 • • ♦ ♦ MILLOUT WINDOW (13 -27A) 10457' - 7 •• ■• ►11 11/ 41 1i 2-1/8" 4 • 0 - 11498 0 09/29197 ► 1 • 1 1 ∎• • ► 1 1 1 !1 2 -7 /8" 4 11450 - : t 0 10/05/97 1 • • • ,4 i! ►11•,4 ► • ∎•• X1 2 4 1 : • - 1151 0 09/29/97 ► 1 1 1 1 '•11.11. 10723' - TOP OF CEMENT (05/03/10) 1 1♦ 1•♦. 2-1/8" 4 11850 - 12150 ! 06/02/97 • "i !i�1�'•� �• 2 -1/:" 4 12400 - 12630 0 .6/02/97 rvmvegra . - � ♦ ♦ ♦N +��► "` 12626' FISH - CIBPPUSHEDTO 4'0'0'0'4 -.....1.4m.,, 0040. 1••••••44 80TTOPi(03 /02/99) aM *I ► 11 4 1 4 1 441 144 � 7" LNR, 294, L -80 BTC, .0371 bpf, ID = 6.184" H 10687' ` "IA ' L & PBTD -1 12638' `=:• 2 -7/8" LNR, 6.5 #, L -80 FL4S, .0058 bpf, ID = 2.441" H 12672' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/29/83 ORIGINAL COMPLETION 06/13/11 SET /PJC GLV C/0 (6 /5/11) WELL: 13 -27A 06/02/97 N3S CTD SIDETRACK (13 -27A) 06/15/11 SRD /PJC JET CUT (6/11/11) PERMIT No: n961210 01/21/10 016 RWO API No: 50- 029 - 20949 -01 02/09/11 MB /JMD REMVVD SSSV SAFETY NOTE SEC 14, T1ON, R14E, 526' FSL & 1185' FEL 05/01/11 SET/ PJC GLV C/O (04/27/11) 05/31/11 PBS / PJC P &A (05/31/11) BP Exploration (Alaska) • • [IF AILASIK(A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Egbejimba p,vR 2. n(0, 13-A Engineering Team Leader - BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13 -27A Sundry Number: 311 -108 Dear Mr. Egbejimba: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, aniel T. Seamount, Jr. e . 7-1%1 Chair DATED this +! day of April, 2011. Encl. STATE OF ALASKA (� '� ALAS. GAS CONSERVATION COMMIS ,, RECEI Kf APPLICATION FOR SUNDRY APPRO ` 20 AAC 25.280 MAR 3 0 L 11 1. Type of Request: gg� ❑ Abandon ® Plug for Redrill - ❑ Perforate New Pool ❑ Repair Well ❑ Change AO* 1 :. . 4,f as C8n8. Commission ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ lime Extension Moorage ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. • _. Development ❑ Exploratory 196-121 3. Address: ❑ Service ❑ Stratigraphic 6. API Number P.O. Box 196612, Anchorage, Alaska 99519- 6612 50- 029 - 20949 -01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: PBU 13 -27A - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field I Pool(s): ADL 028315 - Prudhoe Bay Field / Prudhoe Bay Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12672' - 9057' , 12640' 9058' 10723' (top of cement) 12626' Casing Length Size MD TVD Burst Collapse 1 Structural Conductor 80' 16" 80' 80' Surface 2633' 13 -3/8" 2633' 2633' 4930 2670 Intermediate 10322' 9-5/8" 10322' 8905' 6870 4760 Production Liner 415' 7" 10038' - 10453' 8648' - 9023' 8160 7020 Liner 2628' 2 -7/8" 10044' - 12672' 8654' - 9057' 10570 11160 Scab Liner 5986' 7" 3949' - 9935' 3888' - 8555' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11035' - 12630' (cemented in) 9058' - 9058' (cemented in) 4 - 1/2 ", 12.6# 13Cr80 9869' Packers and SSSV Type: 7" x 4 Baker 'S - packer, Packers and SSSV 9750' / 8389' 9-5/8" x 5-1/2" Baker 'SAB' packer MD (ft) and TVD (ft): 9985' I 8600' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch_ ❑ Detailed Operations Program 13 Exploratory ® �� Development 13 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2011 ❑ Oil ❑ W1NJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG - ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jacob Thompson, 564-5579 Printed Name John E. beimba Title Engineering Team Leader Prepared By Signature • .„ Phone 564 Date 3/30/1 El izabeth Barker, 564-5674 �� 111 / / Commission Use Only Conditions of approval: N tify Commission so that a representative may witness I I /r1 (�/ Sundry Number i c D ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ( 35&) P$` 5C)P 7 i - Other * 2 5oo pr.:- ! t f (kn.,...) :, n.1w4.r �S A ! - far„ pl.) plice....... �2traae /art Zo 4A zs. (ra u) Subsequent Form Required: / 6 l , 7 i 1 APPROVED BY Approved By: 41 , COMMISSIONER THE COMMISSION Date 4 s ) (1 i Form 10 -403 Revi - • 01 /MOMS E' R 0 8 t l ,V Su " n Duplicate ORGNAL - Y ' /, • • b P r 13 -27A Well Type: Producer Current Status: The well is currently shut -in. 3/5/10: MIT -OA to 500 psi passed. Cemented to surface 1/6/10 1/20/10: MIT -IA to 3500 psi passed. 1/20/10: MIT -T to 3500 psi passed. Request: Approval is requested for the P&A of PBU well 13 -27A. On 2/10 a RWO was completed to address the TxIA, PC leak, and SC leak. The RWO installed a scab liner to repair the PC leak and cemented the OA to repair the SC leak. When the RWO was completed the well passed both a MIT -T to 3500 psi and a MIT -IA to 3500psi. The well is operable, however, it was never returned to production due to significant cement found in the liner from the RWO. It is believed that the packer or tailpipe failed during the RWQ_ PC scab cement iob and went sou h filling the 2 -7/8" liner w/ 15.8 ppg cement. On 5/10/2010 coil tried to drill out the cement, but was only successful to a depth of 10,723'. Since all perforations are cemented off the only option is a rotary side track to return this well to production. . Scope of Work: The sidetrack plan for 13 -276 (an Ivishak Z4 producer) includes the following during pre -rig operations: laying cement above the perforations, the 4 -1/2" `' LNR will be cut -200' below planned whipstock exit point. The whipstock exit from the 9 -5/8" casing is estimated at 3400' MD and will be milled using an 8 -1/2" milling assembly. The 8 -1/2" hole will be drilled to the Top of the Sag River where a 7" drilling liner will be run to -150' inside the 9 -5/8" casing. The 7" drilling liner will have 1,000' of cement above the shoe. The production hole will be drilled with a 6 -1/8" BHA building to horizontal. The well will then run horizontally through the Ivishak formation. The production liner will be 4 -1/2" 13CR and fully cemented. Tubing will be 4 -1/2" 13Cr, tied into the top of the production liner. MASP: 2494 Estimated Start Date: May 2011 (.pnGvl. Pre -rig prep work: 1. PPOT -T and IC (A' Gr 2. Lay in cement plug 3. MIT -T to 2500 psi. MIT -OA to 2000 psi • 4. Circ out well 5. Jet cut tubing -3600' MD 6. Set BPV Proposed Procedure: 1. MIRU. 2. MIT - OA 2000 psi for 30 minutes (begin monitoring OA). 3. Pull BPV. Circulate out freeze protection and circulate well to seawater. Set a' TWC and test from above to 3500 psi for 30 minutes and from below to 2000psi - for 30 minutes. 4. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. 5. RU and pull the 4 -1/2" tubing from the pre -rig jet cut at -3,600' MD. 6. Pick up 9 -5/8" full gauge String Mills. RIH to tubing stub at -3,600' MD, ensure casing is clean. POOH. LD scraper assembly. 7. RU E -line and RIH w/ CCL and EZSV for 47# casing, and set at -3,400'. • 8. Pressure test the EZSV to 3500 psi for 30 minutes and chart. • Q 4 9. PU 9 -5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Swap the well over to 10 ppq fresh water LSND milling fluid. 10. Mill a window in the 9 -5/8" casing at -3400' MD' plus 20' of formation. 11. Perform a FIT /LOT. POOH for drilling BHA. 12. MU an 8-1/2" drilling BHA with 2 ghost reamers DIR /GR /RES /ACAL /ALD and RIH. Kick off and drill 8 -1/2" intermediate interval to 7" casing point at the top of the Sag River CBU a minimum of 2 times, short trip until upper ghost reamer Fir) pulls inside the window, RIH to bottom, circulate well clean and POOH. a. NOTE: The mud will need to be weighted up with spike fluid. Plan for 0 711-04 one weight -up with the spike fluid to 10.2 ppg over several circulations prior to drilling the HRZ and Kingak. 13. Change out upper 3.5" x 6" VBR to 7" CSG rams. 14. Run and partially cement a 7 ", 26 #, L -80 drilling liner in the 8 -1/2" wellbore with a minimum of 150' overlap into the 9 -5/8" casing. Set hanger / liner top packer and displace cement with mud. POOH. 15. Change out upper 7" CSG rams to 3.5" x 6" VBR. 16. MU a 6 -%s" DIR /GR /RES drilling assembly. P/U additional 4" drill pipe as required to TD the well and RIH to top of the float collar and test the casing to 3,500 psi for 30 minutes. 17. Displace the well to 8.5 ppg Flo -Pro. 18. Drill out shoe and 20' of new formation and perform an FIT. 19. Drill build section, per directional plan. POOH for PDC assembly 20. MU a 6 -1/8" BHA with PDC bit and DIR /GR /RES /GABI. RIH and drill ahead, per directional proposal and rig site geologist, to TD. 21. CBU 2 times minimum at TD. POOH to the shoe, MAD passing as required by geologist. Open circ sub and circulate the well clean at the shoe and POOH. 22. Run and a cement a 4 -1/2 ", 12.6 #, 13CR -85 liner, VAM TOP liner from TD to 150' inside the 7" shoe. Set the liner top packer and displace the well to seawater. s • 23. After cement reaches -1000 psi compressive strength, pressure test well to 3500 psi for 30 minutes and chart. Spot perf pill in LNR and POOH. 24. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 25. Run the 4 -1/2 ", 12.6 #, 13Cr completion tying into the 4 -1/2" liner top. 26. Drop ball & rod and set the production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 27. Shear valve and confirm circulation. 28. Set and test a TWC to 2000psi. 29. ND BOPE. NU and test the tree to 5,000 psi 30. Pull TWC. Freeze protect the well to 2,200' TVD. 31. Seta BPV. 32. RDMO. Post -Rig Work: 1. Pull BPV. 2. Pull ball and rod / RHC plug. Set generic GLV design. 3. Install wellhouse, instrumentation, and flowlines. (S -Riser modification WILL be required.) 4. Set SSSV post well Drilling Engineer: Jacob Thompson (907) 564 -5579 Production Engineer: Megan Kimmet (907) 564 -5851 Geologist: Cole Able (907) 564 -5576 WEL = CM/ WELLHEAD= FMC • SAFETYN: WELLANGLE> 70° @ 10535'. ACTUATOR = BAKER C 1 3 -2 7 A * * *CHRO G& NIPPLES * ** KB. ELEV = 83' BF. ELEV = ? KOP = 2800' I , . ' , � ' I 2036' H4 -1/2" HES X NIP, ID = 3.813" I Max Angle = 97° @ 11087' 14 ., X 10 GAS LIFT MANDRELS Datum MD = 10297' �.j il ST MD ND DEV TYPE VLV LATCH PORT DATE Datum TVD = 8800' SS ' ' 5 36861 3651 Fr 23 MMG DOME RK 16 01/28/10 4 6421 5755 r 43 KBG2* SO BK 20 01/28/10 19-5/8" CSG, 47 #, L -80 HYD 563, ID = 8.681" I 1867' 3 8199 7098 r 38 KBG2* DMY BK 0 01/15/10 2 9189 7902 ' 32 KBG2* DMY BK 0 01/15/10 1 9641 8292 r 28 KBG2* DMY BK 0 01/15/10 113 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" H 2634' I 'SPECIAL CLEARANCE 3949' 1 9 -5/8" X 7" ZXP LTP w /FLEXLOC LNR HGR, Minimum ID = 2.20" @ 10044' Ei 1 ID= 8.310" 2 -7/8" LNR (CMT SHEATH) j 4 I 1 1 • �• 9719' I- -I4 -1/2" HES X NIP, ID = 3.813" I t o 1 j0 9750' 1-17" X 4-1/2" BKR S -3 PKR, ID = 3.870" I 0 II 9784' H 4 -1/2" HES X NIP, ID = 3.813" I • ''1 9857' H 4 -1 /2" HES XN NIP, ID = 3.725" 4 -1/2" TBG, 12.6 #, 13CR -85 VAM TOP, 9869' • • �4 1 9869' - I4 -1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" i ' ! - K` 44 9910' I--I 7" X 4-1/2" X0, ID = 3.958" I 17" SCAB LNR, 26 #, L -80 BTC-M, ID = 6.276" I 9912' ► %i • ,.• • • 9968' -14 -1/2" X 5 -1/2" XO, ID = 3.958" I ♦ k, • of t,. 9970' H5 -1/2" BKR PBRASSY, ID =? I • 4 • I 9984' H5-1/2" K ANCHOR, ID = 4.875" I F∎ 0 9985' H9 -5/8" X 5 -1/2" BKR SAB PKR, ID = 4.75" I ••� i ♦i TOP OF 7" LNR ( 10038' V. �.i 9990' H 7" BKR MILLOUT EXTENSION, ID = 5.50" I • TOP OF 2 -7/8" LNR I 10044' • •t ♦ • • � ♦ I 9997' H7" X 4 -1/2" XO, ID = 3.958" I •-• � 4:1 10044' H CEMENT SHEATH, ID = 2.20" (05/03/10) I 4 -1/2" TBG -PC, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 10101' ►� ►� ► ►� 0I 10044 _1- TOP OF LNR (46" SECTION PULLED OUT • 9 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" 1 10322' ■ ► j *� j f AND TAGGED 09/04/03) • 1 k . 10044' 1-13-1/2" X 2 -7/8" XO, ID = 2.441" I 17" WHIPSTOCK I 10440' 1 + 4 i • ►• ► • 10088' -14-1/2" OTIS XN NIP, ID = 3.725" I PERFORATION SUMMARY i ♦ i ► i'► ►!► ♦ 4 :•1 •1 10099' -14 -1/2" BROWN SHEAROUT SUB I BEHIND REF LOG: BHCS ON 06/07/83 1.114 ♦ ►� CT LNR ANGLE AT TOP PERF: 97° @ 11035' j • ♦j • ' I 10101 -14-1/2" TUBING TAIL, ID = 3.958" I Note: Refer to Production DB for historical perf data 14 ♦j ♦j I SIZE SPF INTERVAL Opn /Sqz DATE ∎•••4 ��I I H ELMD TT NOT LOGGED 2" 4 11035 11135 0 03/22/01 �♦� ♦� 1•4 2" 4 11150 - 11250 0 03/22/01 1114 •• MILLOUT WINDOW (13 -27A) 10457' - ?' •• ► •4 j 2 -1/8" 4 11450 - 11498 0 09/29/97 ♦� ♦� 1♦4 2 -7/8" 4 11450 - 11650 0 10/05/97 1414 • ♦j ♦j 2 -1/8" 4 11509 11513 0 09/29/97 1414 10723' H TOP OF CEMENT (05/03/10) I 2-1/8" 4 11850 - 12150 0 06/02/97 ♦��♦ _ 2 -1/8" 4 12400 - 12630 0 06/02/97 •� �� _ 12626' -I FISH - CIBPPUSHED TO 1111144 �� BOTTOM (03/02/99) 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" I 10687' 1 � +� a • I PBTD I 12638' " ....� • 2 -7/8" LNR, 6.5 #, L -80 FL4S, .0058 bpf, ID = 2.441" I-I 12672' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/29/83 ORIGINAL COMPLETION 06/03/10 OOP /PJC CMT / SHEATH (05/03/10) WELL: 13 -27A 06/02/97 N3S CTD SIDETRACK (13 -27A) 12/20/10 MB /JMD ADDED SSSV SAFETY NOTE PERMIT No: 1961210 01/21/10 D16 RWO 02/09/11 MB /JMD REMVD SSSV SAFETY NOTE API No: 50- 029 - 20949 -01 01/25/10 TLH DRLG HO CORRECTIONS SEC 14, T1ON, R14E, 526' FSL & 1185' FEL 02/04/10 DAV /PJC GLV C/O (01/28/10) 03/15/10 HB /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) i ■ TREE- 41/16' i'd WELLHEAD= FMC 3 -27B Pro os ACTUATOR = I KB. ELEV = - SAFETY NOTES: BF. ELEV = KOP = 3400' Max Angle = - -- .j H412' HXNe X3813' Datum MD = Datum TVD= ST MD TVD DEV TYPE VLV LATCH 5 3800 3766 38 4.5 "X1" DMY RK 9 - 5/8" CSG, 47 #, L - 80 HYD 563, ID = 8.681" I 1867' 4 6500 5847 38 4.5 "X1" DMY RK 3 8000 6964 38 4.5 "X1" DMY RK 13 - 3/8" CSG, 72 #, L - 80 BUTT, ID = 12.347" I I 2634' 2 9100 7844 28 4.5 "X1" DMY RK 4 1 9800 8469 28 4.5 "X1" DMY BK i I 3250' H9 -5/8" X 7" BKR ZXP LNR TOP PKR HGR - I I9 -5/8" BOT Whipstock H 3400' 1--- I9 -5/8" I SV Plug , 3400' 13-1/2" Tubing Stub I- I 3600' I 1 1 9970' H4-1/2" HES X NIP, ID = 3.813" I P'/ Z 10000' H HAL TNT 4-1/2" X 7" PKR I 9 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" H 10322' ( _ — • I 10045' 4 -1 /2" HES X NIP, ID = 3.813" 1 2 -7/8" LNR 6.5#, L -80 FL4S, .0058 bpf, ID= 2.441" I 12672' t'" ..••■••* I I 10115' H4 -1/2" HES XN NIP, ID = 3.725" I ••••••4 • ∎ ∎ ∎ ∎ � ( 10119'- -7 "X5" BKR ZXP LNR TOP PKR, ` 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" H 10687' I f HGR w /TIEBACK 11.15' X 5.25" I4 -1/2" TBG, 12.6 #, 13Cr, .0152 bpf, ID = 3.958 "H 10119' 1 10125' H41 /2" WLEG, ID = 3.958" I7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H 10269' I FI PERFORATION SUMMARY ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 412' L1• 12Et# 13a' -a .01141, 1:`,=3.;:' 'Its DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/29/83 ORIGINAL COMPLETION 06/03/10 OOP /PJC CMT/ SHEATH (05/03/10) WELL: 13 -27A 06/02/97 N3S CTD SIDETRACK (13 -27A) PERMIT No: '1961210 01/21/10 D16 RWO API No: 50- 029 - 20949 -01 01/25/10 TLH DRLG HO CORRECTIONS SEC 14, T1 ON, R14E, 526' FSL & 1185' FEL 02/04/10 DAV /PJC GLV C/O (01/28/10) 03/15/10 HB /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO OF SUNDRY WELL OPERA ONS 1R~V~I Y ~® F~t~ 0 5 2010 1. Operations Performed: 1m88~(a ~l~ 8$ Afl~. >~SIO ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspendej~r8~ ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 196-121 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20949-01-00 7. Property Designation: \ 8. Well Name and Number: ADL 028315 PBU 13-27A 9. Field / Pool(s~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary ~ Total depth: measured 12672' feet true vertical ~ 905T feet Ptugs (measured) None Effective depth: measured 12640' feet Junk (measured) 12626' true vertical g05g' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 2633' 13-3/8" 2633' 2633' 4930 2670 Intermediate 10322' 9-5/8" 10322' 8905' 6870 4760 Production Liner 415' 7" 10038' - 10453' 8648' - 9023' 8160 7020 Liner 2628' 2-7/8" 10044' - 12672' 8654' - 9057' 10570 11160 Scab Liner 5986' 7" 3949' - 9935' 3888' - 8555' 7240 5410 Perforation Depth: Measured Depth: 11035' - 12630' True Vertical Depth: 9058' - 9058' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr80 / L-80 10100' 8705' Packers and SSSV (type, measured and true vertical depth): 7" x 4-1/2 Baker'S-3' packer; 9750' 8389' 9-5/8" x 5-1/2" Baker'SAB' packer 9985' 8600' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9931'. Cut and pull 9-5/8" from 1867'. Run 9-5/8" Tieback (47#, L-80) to 1874', cement w/ 136 Bbls of Class 'G' (Yield 1.16, 658 sx). Run 7" Scab Liner (26#, L-80), cement w! 175 Bbls Class 'G' (Yield 1.16, 847 sx). Pull WRP (f/ 10008'). Run tubing (4-1/2", 12.6#, 13Cr80). 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run • Well Class after work: ^ Exploratory ®Development ^ Service f W ll O rations ® D il R rt a y epo o e pe ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 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: Contact Hank Baca, 564-5444 309-415 Printed Name T rrie Hubble Title Drillin Technolo ist Prepared By Name/Number. Ph 4628 Date ~ ~ 64 one 5 Signature - Terris Hubble, 564-4628 Form 10-404 Revised 07/2009 Submit Original Only RBDMS FEB ~ 8 20~ ~ ~. z •y / o -- ,. ~ " C``~O ~ Pf, tr) 4 13-27A, Well History (Pre Rig Workover) Date Summary 12/2/2009 T/I/0=250/150/1 temp= si Attempt LLR T/IA- CMIT Tx IA 1000 FAIL, CMIT Tx IA 400 FAIL Rigged up to IA and pumped 31.5 bbls DSL in attempt to establish a LLR. TBG & IA tracked together and presured up to 1050/1070 psi. CMIT TxIA - TxIA lost 20/0 in 15 min's, 10/10 in 2nd 15 min's, total loss of 30/10 in 30 min's. Rigged up to Tubing and pumped 10.7 bbls to bring T/IA pressures up to 400/440. T/IA lost 30/20 in 15 min's, 10/0 in 2nd 15 min's, for a total loss of 40/20 in 30 min's. Bled back approx. 3 bbls. Swab, SSV, Wing, Companion valves closed. Master, IA, OA valves open on departure. FWHP's = 250/250/0 12/2/2009 T/I/0=250/150/1 LLR on IA &TBG Pumped 31.5 bbls DSL down TBG in attempt to establish a LLR. TBG & IA tracked together and presured up to 1050/1070 psi. Monitored TxIAP for 30 min. TxIA lost 30/10 psi in 30 min. RD IA, RU TBG. 12/2/2009 T/I/O = 240/200/0. Temp = SI. TxIAxOA FL (fullbore). No AL. TBG FL C~? 750' (18bbls). IA FL C~3 300' (18bbls). OA FL C~ 330' (20bbls). SV, WV, SSV, = C. MV = O. IA, OA = OTG. NOVP. 12/3/2009 T/I/0=250/190/0. Temp=S1. Assist Fullbore w/MIT's, w/SC leak. LRS rigged to well from day shift. 9" of void from fluid to top of SC, soft bottom in SC. Monitor SC during MIT's. PASSING CMIT (T x IA)~ complete, rig down for end of job. Final W HP's=200/290/0. 12/5/2009 T/I/O=SSV/300/0+, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (FAIL). Pre RWO. PPPOT-T: Stung into test port (0 psi). Functioned LDS, 3 LDS moved only 1/2" (flagged), the rest moved normal (1").Eddie with FMC said 1/2" movement should clear hanger. Pumped through void, good returns. Pressured void to 5000 psi, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. ~L^C~S PPPOT-IC: Stung into test port (200 psi), bled to 0 psi (fluid). Functioned LDS, all moved freely (1 "). Pumped through void, good returns. Pressured void to 3500 psi, lost 400 psi in 15 min, torqued LDS to 450 Ib/ft. Re-pressured void to 3500 psi, lost 900 psi in 15 min. Re-pressured to 3500 psi, at 3000 psi the void pressure dropped to 300 psi and would not re-pressure above that. Suspect secondary seals, void would not bleed off (gas). (FAIL) 12/6/2009 WELL S/I ON ARRIVAL. TAG 4 1/2"WRP C~ 9981' SLM W/ 3.5" LIB (IMPRESSION OF SHEAR STUD). MADE MULTIPLE DUMP BAIL RUNS WITH SLUGGITS TO 4 1/2" WRP ~ 9981' SLM, 10008' MD. 12/7/2009 DUMPED TOTAL OF 3 BAGS OF SLUGGITS ON 4 1/2" WRP C~ 9981' SLM, 10008' MD. SAT DOWN ON SOMETHING C~3 9165' SLM W/ 3.68" CENTRALIZER. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 12/11/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0=100/200/0. DRIFT 4.5" TUBING WITH 3.72" GAUGE RING PRIOR TO RUNNING JETCUTTER. DRIFT GOOD TO 9965', NOTHING RETURNED IN JUNK BASKET. RUNNING IN HOLE WITH 3.65" CUTTER. 12/12/2009 CUT TUBING AT 9931' W ITH SLB 3.65 IN POW ERCUTTER. FINAL T/I/O = 200/200/0. JOB COMPLETE. 12/13/2009 T/I/0= 220/210/10. Temp= SI. Assist FB w/ cellar watch (secure). AL spool dropped. OA FL near surface. 27" containment installed in cellar. Fluid in conductor with 9" of void to top of conductor. Bled OAP from 10 psi to 0 psi in 5 min. Maintained open bleed on OA during pumping. Vac truck on location to assist. FB started pumping 9.8 brine to circ well. Conductor started to inflow & OAP increased to 5 psi, with no LEL detected. Vac'ed fluid from conductor and continued to vac conductor during pumping (21 gallons total). Also had an additional 19 gallons of returns to bleed tank. Assist FB w/CMIT-TxIA to 500 psi. ""PASSED" Final WHPs= 0/0/0. Job complete. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. Page 1 of 2 13-27A, Well History (Pre Rig Workover) Date Summary 12/13/2009 T/I/0=225/210/10 Temp= S/I Circ-Out, CMIT Tx IA PASSED to 500 psi (RWO prep). Pumped 1 bbl 60/40 meth followed by 1034 bbls 9.8# brine down TBG up IA taking returns to the flowline on well # 29. Pumped 21 bbls DSL down TBG (U-tubed into IA for a freeze protect). Freeze protected hardline w/ 5 bbls 60/40 meth and 1.5 bbls DSL. Pumped .6 bbls DSL down TBG to pressure up TBG & IA to 500 psi. In 15 minutes TBG/IA lost 0/20 psi. TBG/IA lost 0/10 psi in the second 15 minutes for a total 30 minute loss of 0/30 psi. Bled TBG/IAP (.8 bbls fluid). Tags hung and wellhead valves left in the following positions: SV, WV &SSV=S/I. MV, IA & OA left open. FWP's=0/0/0 12/14/2009 T/I/O = SSVNac/Vac. Temp = SI. Remove liner from cellar (pre rig). AL is disconnected. Circ out rigged up to IA & flow cross companion. Heater on loc, but not rigged up. Cellar still frozen. Rigged heater up blowing in cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 12/15/2009 T/I/0= SSVNacNac. Temp= SI. Check heater in cellar. AL spool disconnected. Heater still working w/heater trunk in wellhouse. Unable to remove spill containment around conductor, still frozen to the ground. Hardline rigged up to IA will need to be removed before cellar grading can be lifted to get containment. SV, WV, SSV =closed. MV =open. IA, OA =open to gauge. NOVP. 12/16/2009 T/I/O = SSVNac/Vac. Temp = SI. Check heater (pre-rig). Heater trunk was removed from cellar. Cellar is still full of ice and snow. Re-installed trunk blowing into cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 12/17/2009 T/I/O = SSVNacNac. Temp = SI. Check heater (pre-rig). Removed 27" sombrero from cellar. Heat left blowing into cellar. SV, W V, SSV = C. MV = O. IA, OA = OTG. NOVP. Page 2 of 2 BP EXPLORATION Page 1 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 12/28/2009 17:00 - 00:00 7.00 MOB P PRE REMOVE UPPER IBOP. -CHANGE OUT GRABBER DIES. -CHANGE OUT UPPER IBOP (4" HT-38). -SWAP LOCK RINGS. -MOVE RIG OFF OF DS13-22i. 12/29/2009 00:00 - 04:30 4.50 MOB P PRE MOVE RIG. -MOVE OVER AND CENTER UP ON DS13-27a. -R/U SET CUTTINGS TANK. -RU DOUBLE ANNULUS VALVE -RU CIRC LINES -ACCEPT RIG AT 0400 HRS. 04:30 - 06:00 1.50 RIGU P DECOMP -FILL PITS WITH 9.8 PPG BRINE. -RU DSM LUBRICATOR AND TEST TO 500-PSI -PULL BPV 06:00 - 10:30 4.50 BOPSU P DECOMP PJSM -REVERSE CIR 32-BBL AT 7-BPM WITH 770-PSI -PUMP THROUGH TUBING, CBU AT 7-BPM WITH 660-PSI -MONITOR WELL. WELL STATIC. -BLOW DOWN LINES 10:30 - 12:00 1.50 BOPSU P DECOMP INSTALL BPV AND TEST FROM BELOW TO 500-PSI -BLOW DOWN LINES 12:00 - 13:00 1.00 BOPSU P DECOMP BLEED DOWN CONTROL LINE AND TUBING HANGER VOID 13:00 - 15:00 2.00 BOPSU P DECOMP PJSM -ND TREE AND ADAPTOR FLANGE 15:00 - 17:00 2.00 BOPSU P DECOMP CLEAN TUBING SPOOL -TEST FIT 5-3/4" LH ACME XO TO HANGER NECK (12 TURNS) -INSTALL BLANKING PLUG 17:00 - 18:00 1.00 BOPSU P DECOMP PJSM NU BOP -INSTALL RISER -RU BOP TEST EQUIPMENT -FLUID LEVEL IN CONDUCTOR RISING, USE CELLAR PUMP TO PERIODICALLY REMOVE FLUID FROM FLUTES. 18:00 - 23:00 5.00 BOPSU P DECOMP PJSM -TEST ROPE TO 250-PSI LOW, 3500-PSI HIGH PER BP AND AOGCC BEGS. -TEST 3 1/2" X 6" VBR'S WITH 4" AND 4-1/2" TEST JOINTS. TEST ANNULAR WITH 4" TEST JOINT. -AOGCC REP JEFF JONES WAIVED WITNESS OF BOP TEST, 24 HR NOTICE GIVEN. TEST WITNESSED BY WSL AND DOYON TOOLPUSHER. -HOLD AND CHART ALL TESTS FOR 5-MINUTES. -FLUID LEVEL IN CONDUCTOR STATIC. HAVE NOT NEEDED TO PUMP OUT FLUID SINCE 2230-HRS 23:00 - 00:00 1.00 BOPSU P DECOMP RD BOP TEST EQUIPMENT -BLOW DOWN LINES -RU DUTCH RISER 12/30/2009 00:00 - 01:30 1.50 BOPSU P DECOMP WAITING ON DSM 01:30 - 04:30 3.00 BOPSU P DECOMP RU DSM LUBRICATOR AND TEST TO 500-PSI. -RD DUTCH RISER, DUE TO BLANKING PLUG NOT BEING ABLE TO PULL THROUGH RISER. ~uPl rnntea: zinizu~u a:uu:~u rm Y Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code 'NPT 12/30/2009 101:30 - 04:30 I 3.00 I BOPSUR P 04:30 - 07:00 2.501 PULL P 07:00 - 08:30 1.501 PULL P 08:30 - 11:00 I 2.501 PULL P 11:00 - 12:00 I 1.001 PULL I P 12:00 - 20:00 I 8.001 PULL I P 20:00 - 22:00 I 2.00 I PULL P 22:00 - 00:00 2.00 PULL P 12/31/2009 100:00 - 04:00 I 4.001 CLEAN P BP EXPLORATION Operations Summary Report Start: 12/15/2009 Rig Release: 1 /21 /2010 Rig Number: Page 2 of 35 Spud Date: 5/26/1983 End: 1/21/2010 Phase Description of Uperatlons DECOMP -PULL BLANKING PLUG. -RU DUTCH RISER -RU DSM LUBRICATOR. -PULL BPV -RD DSM -RD DUTCH RISER DECOMP MU LANDING JOINT WITH XO. -FMC TECH BOLDS. 3 OF THE LDS BACKED OUT TO 3-3/8". -PULL HANGER TO RIG FLOOR. PULLED 150K-LBS ON HANGER. PIPE MOVED 4". PULLED TO 230K-LBS. WORKED PIPE SEVERAL TIMES WITH NO GAIN IN PIPE MOVEMENT. -ABLE TO BACK OUT LDS A LITTLE MORE, BUT WITH NO FURTHER GAIN IN PIPE MOVEMENT. -PULLED TO 250K-LBS HANGER CAME FREE. -HANGER HAD 3 EACH - 4" GASH IN THE SIDE. APPEARS AT LEAST TWO LDS TIPS BROKE,,. -LD HANGER DECOMP RU TO CIRCULATE BOTTOMS UP. -CBU AT 10-BPM WITH 1730-PSI -RU SCHLUMBERGER SPOOLING EQUIPMENT. -MONITOR WELL. WELL STATIC DECOMP PJSM -POH LD 4-1/2" BTC TUBING FROM 9931'-7735' -LD SSSV - 33-SS BANDS RECOVERED OF 34-REPORTED SS BANDS. DECOMP RD SCHLUMBERGER SPOOLER. -CHANGE OUT POWER TONGS DUE TO LEAKING VALVE. DECOMP PJSM -INSPECT TOP DRIVE AND SKATE. -CONTINUE POH LD 4-1/2" BTC TUBING FROM 7735' TO SURFACE. -TUBING APPEARS TO BE IN GOOD CONDITION. LIGHT CORROSION SEEN ON SOME PIN ENDS. COAT OF PARAFFIN/CRUDE ON EXTERIOR OF PIPE. -AT 1530-HRS -- NOTICED SEEPAGE OF BLUE GOO FROM CONDUCTOR AND HAD FLOWED INTO CELLAR. BLUE GOO WAS FOLLOWED BY A SLOW CONTINUOUS FLOW OF WATER. USE A SUPERSUCKER TO VAC OUT CELLAR. MANNED THE CELLAR WITH A PERSON TO MONITOR THE FLOW FROM THE CONDUCTOR. CONTINUOUS FLOW OF WATER = 5-7-BPH OF FRESH WATER. -POH LD TOTAL 239-JOINTS, 11- GLM, 1-SSSV -CUTOFF JOINT 8.96' LENGTH, 5-1/8" OD OF FLARE. DECOMP RD POWER TONGS -CLEAN AND CLEAR RIG FLOOR. DECOMP PJSM PU HALLIBURTON 9-5/8" RTTS. -RIH WITH 4" DP FROM THE PIPESHED FROM SURFACE TO 967' DECOMP CONTINUE TO RIH WITH 9-5/8" RTTS ON 4" DP FROM 967' TO 6000'. Printed: 2/4/2010 4:00:30 PM ~ ! BP EXPLORATION Page 3 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/31/2009 ~ 00:00 - 04:00 ~ 4.00 ~ CLEAN ~ P ~ ~ DECOMP -CONTINUED TO MONITOR THE WATER FLOW FROM THE 04:00 - 05:00 ~ 1.00 ~ CLEAN ~ P 05:00 - 06:30 I 1.50 I CLEAN I P 06:30 - 07:00 0.50 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 09:00 I 1.00 ~ CLEAN ~ P 09:00 - 11:00 2.001 CLEAN ~ P 11:00 - 12:00 1.00 CLEAN P 12:00 - 13:00 1.00 EVAL P 13:00 - 13:30 0.50 EVAL ~ P CONDUCTOR AT 5-7-BPH OF FRESH WATER. - ESTABLISH PARAMETERS -- PU = 115K-LBS, SO = 110K-LBS -PUMP AT 5-BPM WITH 370-PSI DECOMP SET RTTS AT 6000'. -PRESSURE UP TO 2000-PSI FROM BELOW FOR 10-MIN CHARTED. TEST GOOD. -RELEASE RTTS. DECOMP CBU AT 5-BPM WITH 370-PSI -SMALL AMOUNT OF SANDY PARAFIN NOTED WHILE CIRCULATING. DECOMP POH, STANDING BACK 4" DP IN DERRICK, TO 4532'. -SET RTTS AT 4532'. DECOMP RU AND TEST 9-5/8" CASING ABOVE 4532' TO 3500-PSJ FOR 30-CHARTED MINUTES. -GOOD TEST. -RD TEST EQUIPMENT AND RELEASE RTTS. DECOMP CBU AT 5-BPM WITH 270-PSI. -SMALL AMOUNT OF SANDY PARAFIN SEEN WHILE CIRCULATING. -MONITOR WELL -STATIC. DECOMP BLOW DOWN LINES. -POH, STANDING BACK 4" DP IN DERRICK. -LD RTTS AND RUNNING TOOL. -RTTS IN GOOD CONDITION WITH SMALL AMOUNT OF PARAFIN ON DRAG BLOCKS AND AROUND HOLD DOWN BUTTONS. -SPOT E-LINE UNIT. DECOMP CLEAN AND CLEAR RIG FLOOR. -INSPECT AND GREASE TOP DRIVE. TIE61 HOLD PJSM ON RU E-LINE UNIT. -DISCUSS DROPPED OBJECTS POTENTIAL, IMPORTANCE OF GOOD COMMUNICATION AND PROPER TOOL HANDLING. -RU E-LINE EQUIPMENT AND MU USIT TOOL STRING. TIE61 RIH WITH USIT LOGGING TOOLS. -WHEN ON BOTTOM AND ATTEMPTING TO BEGIN LOGGING, DISCOVER SHORT IN TOOLSTRING. 13:30 - 15:00 1.50 EVAL N DFAL TIEB1 POH TO TROUBLESHOOT E-LINE TOOL FAILURE. -PROBLEM WITH WIRELINE HEAD. -REPLACE HEAD AND REINSTALL ON TOOLSTRING. 15:00 - 16:00 1.00 EVAL P TIEB1 RIH TO 2700' AND USIT LOG BACK TO SURFACE TO DETERMINE TOC IN 13-3/8" X 9-5/8" ANNULUS. -WHILE LOGGING, CONTINUE STRAPPING AND DRIFTING 9-5/8" CASING IN THE PIPE SHED. -ALSO, TEST HARDLINE TO FLOWBACK TANK TO 3000-PSI. GOOD TEST. 16:00 - 17:00 1.00 EVAL P TIE61 RD USIT LOGGING TOOLS AND E-LINE UNIT. -DETERMINE ESTIMATED CUT DEPTH OF 1862' WITH RWO ENGINEER. -FIELD PICK FOR TOC AT 1900'. 17:00 - 19:30 2.50 DHB P TIE61 PJSM Printed: Z4/2010 4:00:30 PM ' BP EXPLORATION Page 4 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From -To Hours Task Code NPT Phase Description of Operations 12/31/2009 17:00 - 19:30 2.50 DHB P TIEB1 -PU 9-5/8" HES RBP. 19:30 - 20:30 I 1.00 DHB P TIEBI 20:30 - 00:00 3.50 DHB P TIEB1 1/1/2010 00:00 - 01:00 1.00 CASE P TIEB1 01:00 - 02:30 1.50 CASE P TIE61 02:30 - 04:00 1.501 CASE P TIEB1 04:00 - 06:00 2.001 CASE P TIEBi 06:00 - 07:00 1.00 CASE P TIEB1 07:00 - 00:00 17.00 CASE N WAIT TIEB1 -RIH WITH RBP ON 4" DP FROM DERRICK. -SET RBP AT 1995'. CIRCULATE SURFACE TO SURFACE TO VERIFY ALL AIR OUT OF DP. -PUMP AT 8-BPM WITH 290-PSI -PRESSURE TEST RBP TO 1000-PSI TO 10-MIN CHARTED. TEST GOOD. -BLOW DOWN TOP DRIVE DROP 44-SKS OF 20/40 MESH RIVER SAND DOWN HOLE ON TOP OF RBP USING SAND HOPPER FOR 50' OF COVERAGE ON RBP -DUMP SAND AT 1-SK PER 2-MIN -PULL UP HOLE 60' PUMP DP VOLUME AT 2-BPM. -BLOW DOWN TOP DRIVE. POH WITH 4" DP RACKING BACK STANDS -LD RBP RUNNING TOOL MU CSG CUTTER BHA. , - 8-1/4" STRING CUTTER, XO, 8-1/2" STABLIZER, XO SUB -RIH ON 4" DP TO TOP OF SAND. -TAG TOP OF SAND AT 1940' -LOCATE FIRST COLLAR AT 1895' -LOCATE TOP COLLAR AT 1857'. -SPOT CUTTER AT 1867' TO MAKE CUT. PJSM WITH CH2MHILL, LITTLE RED, RIG CREW, MUD ENGINEER, BAKER, TOOL PUSHER, WSL. -RU LITTLE RED AND PRESSURE TEST LINES TO 2500-PSI -RU CIRCULATING LINES IN CELLAR TO OA WITH GUAGE. -MAKE CASING CUT AT 1867' WITH 5.5-BPM WITH 620-PSI, ROTATING AT 100-RPM, 5K-TO -MADE CUT IN 15-MIN - 220-PSI ON OA AFTER CUT CIRC WELL -LRS PUMP 15-BBL OF 90 DEGREE DIESEL DOWN DP AT 1-BPM. TAKING RETURNS TO PITS. -CLOSE ANNULAR, LRS PUMP 35-BBL DOWN DP AT 1-BPM. TAKING RETURNS THROUGH OA TO FLOW BACK TANK. -PUMP 20-BL OF 100 DEGREE 9.8-PPG BRINE AT 5-BPM. TAKING RETURNS THROUGH OA. -SEE SOME CRUDE/HYDROCARBON IN RETURNS FROM OA. "WEATHER CONDITIONS ARE AT PHASE II" ALLOW DIESEL TO SOAK IN OA FOR 60-MIN. PHASE THREE WEATHER CONDITIONS -CEASE ALL OPERATIONS. -TAKE HEAD COUNT OF ALL EXTRA PERSONNEL ON LOCATION - 5-CH2MHILL DRIVERS, 1-BAKER FISHING REP AND 1-MI MUD ENGINEER. -MONITOR OA PRESSURE ON GAUGE -HOLDING STEADY AT 110-PSI. -MONITOR RETURNS FROM CONDUCTOR. CONTINUES Printed: 2/4/2010 4:00:30 PM ~ i BP EXPLORATION Page.5 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase. Description of,Operations 1/1/2010 07:00 - 00:00 17.00 CASE N WAIT TIE61 TO FLOW FRESHWATER AT 7-BPH -PERFORM CREW CHANGE AT 1300-HRS WITH HEAVY EQUIPMENT ESCORT AND LMT COORDINATION. CONVOY TO RETURN MI ENGINEER AND BAKER FISHING REP TO THEIR RESPECTIVE CAMPS. -CH2MHILL SEND CONVOY WITH HEAVY EQUIPMENT ESCORT, RIG WATER TRUCK AND IMT COORDINATION. ALL CH2MHILL TRUCKS EXCEPT ONE DIRTY VAC TRUCK RETURN SAFELY TO CH2MHILL BASE. DIRTY VAC TRUCK REMAINS ON LOCATION AT RIG. 1/2/2010 00:00 - 12:00 12.00 CASE N WAIT TIEB1 PHASE THREE WEATHER CONDITIONS -CEASE ALL OPERATIONS. -PERFORM RIG CREW CHANGE AT REGULAR TIME WITH HEAVY EQUIPMENT ESCORT AND IMT COORDINATION. -TAKE HEAD COUNT OF ALL EXTRA PERSONNEL ON LOCATION - 1-CH2MHILL DRIVER. -MONITOR OA PRESSURE ON GAUGE -HOLDING STEADY AT 91-PSI. -MONITOR RETURNS FROM CONDUCTOR. CONTINUES TO FLOW FRESHWATER AT 7-BPH. -WEATHER CONDITIONS IMPROVE TO PHASE 2, LEVEL 3. -REMAIN ON STANDBY PER DIRECTION FROM IMT. -PERFORM CREW CHANGE WITH CONVOY. 12:00 - 19:00 7.00 CASE N WAIT TIE61 _ PHASE TWO, LEVEL THREE WEATHER CONDITIONS. -CLEAR~SNOW FROM RIG AND ENTRANCES. -LOADER CLEAR ROADWAY TO RIG AND PREP LOCATION FOR RETURNING TO OPERATIONS. -OA PRESSURE = 30-PSI -CONDUCTOR FLOW STOPPED. 19:00 - 21:30 2.50 CASE N WAIT TIEB1 WAITING FOR CH2MHILL VAC TRUCKS. -TROUBLE GETTING TRUCKS STARTED AFTER PHASE 3. 21:30 - 23:30 2.00 CASE P TIEBi PJSM FOR CIRC OUT OA -SPOT VAC TRUCKS -PUMP 15-BBL HEATED BRINE TO ESTABLISH CIRCULATION AND THAT LINES NOT FROZEN. -PUMP 40-BBL SAFE-SURF-O -AFTER 65-BBL PUMPED AWAY CONDUCTOR FLOW STARTED FLOWING FRESHWATER AGAIN. -PUMP 150-BBL 9.8-PPG BRINE FROM PITS TILL RETURNS WERE CLEAN. TAKING RETURNS FROM THE OA TO THE FLOWBACK TANK -PUMP AT 5-BPM WITH 600-PSI PUMP PRESSURE. WHILE CIRCULATING OA = 225-PSI. -INITIAL RETURNS FROM OA DIESEL FOLLOWED BY DIESEL MIXED FLUID 7.8-PPG -TOTAL FLUID PUMPED TO FLOWBACK = 236-BBLS 23:30 - 00:00 0.50 CASE P TIEB1 OPEN ANNULAR -CBU -PUMP AT 7.5-BPM WITH 900-PSI -INITIAL RETURNS WERE ABOUT 10-BBL DIESEL. FLOW CLEANED UP FOR REMAINING PUMPING. 1/3/2010 00:00 - 01:00 1.00 CASE P TIEB1 BLOW DOWN TOP DRIVE -POH RACKING BACK 4" DP FROM 1867' TO SURFACE PfintBtl: 2/4/2010 4:00:30 PM i BP EXPLORATION Page 6 of°35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours ..Task Code NPT Phase Description of Operations 1/3/2010 00:00 - 01:00 1.00 CASE P TIE61 -LD MECHANICA_L CASING CUTTER. -CONTINUE TO MONITOR WELL WITH 7-BPH FRESHWATER FLOW FROM CONDUCTOR. 01:00 - 02:00 1.00 CASE P TIE61 MU CSG PACKOFF RETRIEVAL TOOL -ENGAGE PACKOFF -FMC BOLDS -PULL PACKOFF WITH 5K-LBS -LD RUNNING TOOL WITH PACKOFF. 02:00 - 06:00 4.00 CASE P TIE61 MU CASING SPEAR e$1H.AI~1[?_.ENSzAGE CASING. , -PULL AND WORK CASING UP TO 230K-LBS. -0320-HRS STOP PULLING TO STEAM WELLHEAD. -ATTEMPT TO ESTABLISH RETURNS THROUGH 9-5/8" X 4" DP ANNULUS WITHOUT SUCCESS. -ATTEMPT TO AND ESTABLISH RETURNS FROM 13-3/8" X 9-5/8" ANNULUS IMMEDIATELY. -VAC OUT STACK AND INSPECT HANGER FROM ABOVE. SOLID BODY MANDREL HANGER. -FMC REP INSPECT WELLHEAD AND ENSURE NOTHING TO HANG UP HANGER. -CONTINUE TO WORK PIPE PULLING UP TO 300K-LBS. 06:00 - 08:00 2.00 CASE P TIEBi DISCUSS SITUATION WITH RWO ENGINEER AND SUPERINTENDENT, BAKER FISHING, FMC, DOYON TOOLPUSHERS AND BP WSLS. -DECIDE TO CONTINUE TO STEAM AND WORK PIPE TO ATTEMPT TO FREE 9-5/8" CASING -RESUME STEAMING WELLHEAD AT 0700-HRS. 08:00 - 09:00 1.00 CASE P TIEB1 RIH AND ENGAGE SPEAR. -STAGE UP TO PULLING 300K-LBS. CHAIN BRAKE HANDLE AND WAIT 10-MINUTES. -CONTINUE TO STAGE UP TO 325K-LBS. HOLD FOR 10-MINUTES. -STAGE UP TO 350K-LBS, CLOSE ANNULAR AND REDUCE ANNULAR PRESSURE TO 0-PSI, PRESSURE UP UNDER HANGER TO 500-PSI. -WORK PIPE UP TO 400K-LBS MAINTAINING 500-PSI PRESSURE UNDER HANGER. HOLD 400K-LBS FOR 5-MINUTES. -NO MOVEMENT SEEN IN PIPE OR WELLHEAD. -CONDUCTOR FLOW BECOMES STEADY AND FLUID WEIGHT FROM CONDUCTOR INCREASES TO 9.1-PPG WHILE WORKING PIPE. 09:00 - 10:00 1.00 CASE P TIEB1 BLEED OFF PRESSURE AND OPEN ANNULAR. -RELEASE SPEAR AND POH. -BLOW DOWN TOP DRIVE. 10:00 - 12:00 I 2.001 CASE I P 12:00 - 15:00 3.00 CASE ~ P TIEBi .U.~.-SLR"_SrA51NG CUTTER . -RIH TO 100', PUMP AT 5.5-BPM WITH 240-PSI -LOCATE COLLARS AT 106.5' AND 67' -CUT CASING AT 72' W ITH 90-RPM, 4K FREE TORQUE -POH LD CUTTER -BLOW DOWN TOP DRIVE. TIEB1 PU SPEAR AND ENGAGE 9-5/8" CASING -WORK STRING FROM 100K-LBS TO 150K-LBS Printed: Z4/2010 4:00:30 PM ` ~ • BP EXPLORATION Page 7 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From -,To Hours Task Code NPT Phase Description of Operations 1/3/2010 12:00 - 15:00 3.00 CASE P TIEB1 -STEAM WELLHEAD. -PULLED PLUG ON CSG SPOOL TO VISUALLY SEE IF HANGER MOVING. NO MOVEMENT. 15:00 - 15:30 0.50 CASE P TIE61 PUMP 5-BBL FRESHWATER DYE PILL TO VERIFY CASING CUT AT 72' -DYE RETURNED AT CALCULATED STROKES 15:30 - 16:00 0.50 CASE P TIE61 PJSM n RnPF ;N -2 BARRIERS FOR ND ARE 1) TESTED WRP AT 10008' AND 16:00 - 18:30 2.501 CASE P 18:30 - 19:00 0.50 CASE P 19:00 - 23:00 4.00 CASE P 23:00 - 00:00 I 1.001 CASE I P 1/4/2010 100:00 - 01:30 1.501 CASE ~ P 2 TESTED RBP AT 1995' TIEB1 CLEAN OUT WELLHEAD -METAL CUTTINGS AND SMALL CHUNKS OF SOLID WHITE MATERIAL ON TOP OF HANGER -NO CLEAR SIGN OF WHAT MAY BE HANGING UP HANGER -FILL VOID ABOVE HANGER WITH DYED WD-40 -REMOVE OA VALVE AND LOOK UNDER HANGER. SEE 9-5/8" CASING WITHOUT ANY DEBRIS TIEB1 NU BOPE TIEB1 PU SPEAR AND RIH AND ENGAGE CASING , -CLOSE ANNULAR AND BLEED OFF PRESSURE -WORK PIPE TO 150K-LBS, PUMP AND HOLD 500-PSI BELOW -PIPE APPEARS TO MOVE 1" -FLUID RETURNS FROM CONDUCTOR 9.1-PPG WITH TRACE OF BLUE GOO RETURNS -2015-HRS PUT STEAM BACK ON WELLHEAD. CONTINUE TO WORK PIPE. -2045-HRS BLOW DOWN LINES. CONTINUE TO STEAM 1ELLHEAD. -2050-HRS PULL AND HOLD 150K-LBS ON PIPE. -2110-HRS CONTINUE TO WORK PIPE UP AND DOWN. APPEARS TO BE NO GAIN IN MOVEMENT. -2120-HRS PULL AND HOLD 150K-LBS -2140-HRS WORK PIPE SEVERAL TIMES TO 150K-LBS -2200-HRS PULL AND HOLD 150K-LBS -2205-HRS PUMP TO 500-PSI, PULL 150K-LBS -2210-HRS FILL STACK WITH COLD WATER ABOVE ANNULAR. OPEN ANNULAR AND LET COLD WATER TO HANGER AFTER HAVING STEAM ON IT OF 2-HRS. CLOSE ANNULAR, CONTINUE TO WORK PIPE TO 150K-LBS. NO GAIN -2225-HRS BLOW DOWN LINES. RELEASE, POH, AND LD SPEAR TIEB1 PJSM COMPLETE FULL DERRICK AND TOP DRIVE INSPECTION FOR PRE SURFACE JARRING INSPECTION CHECKLIST. TIE61 PU CASING CUTTER -RIH TO VERIFY PIPE IS COMPLETELY CUT AT 72' -START PUMPING WITH 6-BPM WITH 580-PSI, 30-RPM, LOWER PIPE IN HOLE TO 72' PRESSURE DROPPED TO 200-PSI. SLOWLY SET 5K-WOB ON CUT JOINT TO SCAR KNIVES Printed: 2/4/2010 4:00:30 PM ` • • BP EXPLORATION Page 8 of 35' Operations Summalry Report Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From.- To Hours Task Code NPT 1/4/2010 100:00 - 01:30 1.501 CASE P 01:30 - 05:30 1 4.00 CASE P 05:30 - 07:00 1.50 ~ CASE ~ P 07:00 - 07:30 I 0.501 CASE I P 07:30 - 08:00 I 0.501 CASE I P Spud Date: 5/26/1983 Start: 12/15/2009 End: 1 /21 /2010 Rig Release: 1 /21 /2010 Rig Number: Phase Description of Operations TIE61 -PULL UP HOLE AND VERIFY LOCATION OF COLLAR BELOW HANGER AT 28'. -POH LD CUTTER. -BLOW DOWN TOP DRIVE TIEB1 PJSM FOR MU JAR ASSEMBLY. -PU SPEAR, 6-1/4" JAR, 2-EA 6-1/4" DRILL COLLAR, 6-1/4" ACCELERATOR, 10' PUP 4" DP -0315-HRS PERFORM DERRICK INSPECTION -0400-HRS BEGIN JARRING. PU 125K-LBS -JAR UP 28 TIMES. PIPE MOVING 2-4" EACH TIME. TOTAL OF 13' OUT OF HOLE. AFTER EACH JAR PULL TO 150K-LBS TO SEE IF PIPE PULLS FREE. -AFTER JARRED UP 3' BEGAN CIRCULATING. CIRCULATED AT 6-BPM WITH 70-PSI. SAND, GRAVEL SEEN ACROSS SHAKERS. STAGED PUMPS UP TO 11-BPM WITH 500-PSI TIEB1 SHUT DOWN TO LD ONE COLLAR DUE TO CLEARANCE IN THE DERRICK. -BLOW DOWN TOP DRIVE. -BREAK OUT SPEAR AND JAR TO LD DRILL COLLAR. -MU SPEAR AND JAR TO REMAINING COLLAR AND ACCELERATOR IN DERRICK. -PERFORM TOP DRIVE AND DERRICK INSPECTION. TIEB1 CONTINUE JARRING -PU TO 150K-LBS AFTER EACH PULL. JAR FOR ANOTHER -PIPE BEGAN TO PULL WITH 60K-LBS. PIPE NOT COMPLETLY FREE WAS SLIPPING ITS WAY OUT OF HOLE. UNABLE TO GO DOWN WITH PIPE AT ALL. -PULL HANGER TO RIG FLOOR AND SET SLIPS ON JOINT BELOW THE HANGER. TIE61 LD SPEAR, JARS, COLLAR, ACCELERATOR. -BREAK HANGER WITH RIG TONGS AND LD. -LIP OF HANGER WHERE THE PACKOFF SITS SHOWED SIGNS OF BEING PULLED AGAINST WITH MUSHROOMING, LIKE IT WAS HANGING UP ON ONE SIDE. 08:00 - 08:30 I 0.501 CASE I P 08:30 - 10:30 2.001 CASE ~ P 10:30 - 11:30 ( 1.001 BOPSUF{ P TIEB1 -5/8" CASING ELEVATORS. _ -PULL 1-FULL JOINT AND 5.42' OF A CUT JOINT TO FLOOR AND LD. CUT JOINT FLARED TO 10" OD. -PIPE SHOWING NO SIGN OF WHAT COULD HAVE BEEN HANGING UP. CEMENT CHUNKS ON COLLAR. TIE61 CLEAR AND CLEAN RIG FLOOR. -FUNCTION VBRS, BLINDS AND ANNULAR SEVERAL TIMES TO CLEAR. -PU SINGLE JT OF DP AND MU STACK WASHER. -FLUSH STACK AND JET FLOW LINE. SAND AND QUARTER SIZED BROKEN PIECES OF CEMENT SEEN ACROSS SHAKERS -FUNCTION ALL BOPE AGAIN AND THEN FLUSH STACK A SECOND TIME. RETURNS INDICATE STACK IS CLEAN. -LD STACK WASHER. TIEB1 RU TO PERFORM WEEKLY ROPE TEST. PriMetl: 2/4/2010 4:00:30 PM ` ~ • BP EXPLORATION'' Page 9 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 1/4/2010 10:30 - 11:30 1.00 BOPSU P 11:30 - 15:30 I 4.001 BOPSUR P 15:30 - 16:00 I 0.501 BOPSUR P 16:00 - 18:30 2.501 CASE P 18:30 - 19:00 0.501 CASE P 19:00 - 20:00 I 1.001 CASE I P 20:00 - 20:30 I 0.501 CASE i P 20:30 - 21:30 I 1.001 CASE I P Spud Date: 5/26/1983 Start: 12/15/2009 End: 1 /21 /2010 Rig Release: 1/21/2010 Rig Number: Phase pescription of Operations TIE61 -8.4-PPG FLUID FLOWING AROUND OUTSIDE OF CONDUCTOR AND FLOATING CELLAR RHINO LINER. -RU VAC TRUCK TO CAPTURE RETURNS AROUND CONDUCTOR. -SET LOWER TEST PLUG. TIEB1 PERFORM WEEKLY BOPE TEST (IN THE COURSE OF THIS TEST, THE TBG SPOOUCSG SPOOL BREAK IS ALSO TESTED). -TEST TO 250-PSI LOW AND 3500-PSI HIGH FOR 5-CHARTED MINUTES PER TEST. -TEST 3-1/2" X 6" VBRS USING 4-1/2" AND 4" TEST JTS -TEST ANNULAR USING 4" TEST JT -ALL TESTS WITNESSED BY BP WSL AND DOYON TOOLPUSHER. -VERY SLOW FRESHWATER RETURNS THROUGH CONDUCTOR. TIEB1 RD TEST EQUIPMENT. -BLOW DOWN ALL LINES. -PULL TEST PLUG. -INSTALL LONG WEAR RING. 12.375" ID. TIE61 PJSM ON MU 9-5/8" RETRIEVAL BHA. -BHA CONSISTS OF SPEAR WITH PACKOFF, JAR, DC, JOINT OF 4" DP -1745-HRS--RIH AND TAG 11' ABOVE CUT AT 61' -1800-HRS--ESTABLISH CIRCULATION AT 11-BPM WITH 100-PSI -WORK PIPE TO WASH DOWN. A LOT OF SAND SEEN AT SHAKERS. -WASHED DOWN TO 63'. -1810-HRS--MADE DECISION TO POH AND PICK UP BIT. -1815-HRS--AS WE BEGAN TO POH WE PACKED OFF AND PUMP PRESSURE ROSE TO 500-PSI AND STARTED PUMPING OURSELVES OUT OF HOLE. TURNED OFF PUMPS. PIPE PUSHED UP MAKING THE BLOCKS SWAY BACK AND FORTH JOLTING THE TOP DRIVE. -1820-HRS--NOTICED A LEAK ON THE TOP DRIVE. UPON INVESTIGATION NOTICES A LEAK IN THE HYDRAULIC HOSE FOR THE COMPENSATOR. PLUGGED LEAK. TIEB1 POH WITH BHA AND LD. -PULLED 15K-LBS OVER AT 56' -BLOW DOWN TOP DRIVE. TIE61 PERFORM TOP DRIVE INSPECTION. -CHANGE OUT HOSE ON COMPENSATOR. TIE61 PU 8-1/2" BIT BHA -BHA CONSISTS OF BIT, BIT SUB, JAR, XO, DRILL COLLAR, STAND OF 4" DP. TIEB1 RIH TO 48' ESTABLISH CIRC WITH 14-BPM 220-PSI, 5-RPM, 2K- FREE TORQUE -A L_O_T OF CEMENT AND SAND ACROSS SHAKERS. -WASH DOWN TO AND TAG TOP OF 9-5/8" CASING AT 71.5' -PUMP 5-BBL SWEEP, INCREASED IN CEMENT CUTTING Printetl: 2/4/2010 4:00:30 PM • BP EXPLORATION Page 10 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/4/2010 20:30 - 21:30 1.00 CASE P TIEB1 RETURNS. 21:30 - 22:00 0.50 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 00:00 1.00 CASE P '.1/5/2010 00:00 - 01:00 1.001 CASE P 01:00 - 03:00 I 2.001 CASE I P -RIH TO 125' (53' INSIDE OF 9-5/8" CASING), PUMP 5-BBL SWEEP -POH TO 70', PUMP 5-BBL SWEEP -AFTER THIRD SWEEP, RETURNS LOOKED CLEAN. TIEB1 POH LD 8.5" BIT AND BHA. -BLOW DOWN TOP DRIVE. TIEB1 PU SPEAR ASSEMBLY -SPEAR, JARS, 2-EA DRILL COLLARS, ACCELERATOR. TIEB1 RIH TO GRAPPLE AT 72' -PULL TO 300K-LBS -ESTABLISH CIRCULATION AT 6-BPM WITH 150-PSI -INCREASE RATE TO 8-BPM WITH 480-PSI -BEGIN JARRING AT 150K-LBS FOLLOWED WITH PULLING TO 300K-LBS. -GAINING 2-4" EACH JAR. -BEGIN GETTING SHAKERS FULL OF ARTIC PACK RETURNS, OVERLOADING SHAKERS. -SLOWED PUMPS TO 4-BPM WITH 700-PSI -JARRED 52" OUT OF HOLE. TIE61 PERFORM DERRICK AND TOP DRIVE INSPECTION -CONTINUE CIRCULATING AT 6-BPM WITH 1000-PSI -PUMP 10-BBL SWEEP. RETURNS HAD SOME ARTIC PACK BUT MOSTLY CLEAN. TIEB1 RESUME JARRING -JAR AT 175K-LBS FOLLOWED BY PULLING 325K-LBS -CIRCULATE AT 3-BPM WITH 1200-PSI -PUMP PRESSURE BEGAN FALLING TO 600-PSI WHEN PULLING PIPE UP AND RISING BACK TO 1200-PSI WHEN SLACK OFF. -0115-HRS--PIPE BEGAN JUMPING FREE. PULLING 150K-175K-LBS. -CONTINUE PULLING TILL SPEAR STOP WAS JUST BELOW RIG FLOOR. -PUMP 10-BBL SWEEP AT 3-BPM WITH 1200-PSI. BEFORE SWEEP CAME TO SURFACE GOT BACK A LARGE AMOUNT OF GRAVEL, PUMP PRESSURE DROPPED TO 80-PSI, INCREASED RATE TO 15-BPM WITH 1000-PSI. SHAKERS WERE LOADED WITH LARGE PIECES OF GRAVEL, PIPE SCALE, SAND. OVERLOADED SHAKERS AND DRAG CHAIN. SLOWED PUMPS TO 5-BPM WITH 80-PSI, TO ALLOW TO CLEAN OUT DRAG CHAIN AND SHAKERS. -PUMP ANOTHER 10-BBL SWEEP AND CONTINUE WORKING PIPE. SHAKERS OVEROADED WITH GRAVEL. -RAISE PUMP RATE TO 11-BPM WITH 200-PSI. SEND 20-BBL SWEEP. SHAKERS LOADED TILL SWEEP WAS HALF WAY OUT OF HOLE THEN CLEANED UP. FINISHED CIRCULATING SWEEP OUT. CLEAN RETURNS. -ABLE TO WORK PIPE UP AND DOWN FREELY WITH PU = 125K-LBS SO = 125K-LBS -WHILE CIRCULATING BEGAN BRINGING UP 9-5/8" CASING HANDLING EQUIPMENT TO RIG FLOOR. rnncea: uaizu io wv~sv rm BP EXPLORATION Page 11 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/5/2010 03:00 - 04:30 1.501 CASE I P 04:30 - 06:00 1.50 CASE P 06:00 - 08:30 2.50 CASE P 08:30 - 09:30 1.00 CASE P 09:30 - 12:00 2.50 CASE P 12:00 - 13:00 1.001 CASE ~ P 13:00 - 15:00 I 2.001 CASE I P 15:00 - 15:30 I 0.501 CASE P 15:30 - 16:00 I 0.501 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 17:30 1.00 CASE P TIE61 POH LD SPEAR BHA ASSEMBLY. -BLOW DOWN TOP DRIVE -LD FIRST JOINT OF CASING WITH CUT. TIEB1 RU 9-5/8" CASING HANDLING EQUIPMENT. TIEB1 PULL & LD 9-5/8" 47# BTC CASING TO CUT USING POWER TONGS. -AVERAGE BREAK OUT TORQUE = 30-45k-LBS. -RECOVER 43 FULL JTS, 35.61' UPPER CUT JT AND 10.47' LOWER CUT JT. -RECOVER 10-CENTRALIZERS RECOVERED WITH -12-BLADES MISSING -LOWER CUT JT FLARED TO 9-3/4". -TOTAL 9-5/8" CASING RECOVERED = 46-JTS AND 10.47' CUT JT. TIEB1 RD 9-5l8" HANDLING EQUIPMENT AND POWER TONGS. -CLEAN AND CLEAR RIG FLOOR. TIEBi TOP DRIVE AND DERRICK INSPECTION. -REPLACE LINK TILT BOLTS AS PREVENTATIVE MAINTENANCE. -REMOVE TWO PIECES OF CENTRALIZER BLADES FROM LOWER RAM CAVITIES WITH A MAGNET ON A-SASH CORD. TIEB1 BRING CLEANOUT BHA COMPONENTS TO THE RIG FLOOR. -SERVICE TOP DRIVE. TIEBi M/U CLEANOUT BHA: 8-1/2" BIT, 2-EA BOOT BASKETS, 13-3/8" ULTRA CLEAN CASING BRUSH ON 12-1/8" MANDREL, AND OIL JARS AND RIH ON DCS AND DP FROM DERRICK TO 1,836'. TIEB1 GET PARAMETERS: P/U WT 70K-Ibs; S/O WT 75K-Ibs; ROT WT 75K-Ibs AT 20-RPM AND 1.5K-Ib-ft FREE TORQUE; 10-BPM AT 490-psi. -S/D PUMP, STOP ROTATING, AND RIH TO DRY TAG AT 1859'. P/U AND START ROTATING AT 10-RPM AND SLOWLY BRING PUMP UP TO 10-BPM AND RIH AND EASILY GET INSIDE THE STUB. -POH AND STOP ROTATING THEN SLOWLY RIH AND SEE STUB AT 1859'. LET THE STUB START TO TAKE WEIGHT, 1,000-Ibs, AND THE BIT DROPS INSIDE THE STUB. -CIRCULATE DOWN TO THE SHOULDER OF THE CASING BRUSH, PLACING THE BIT AT 1878', OR 19' INSIDE THE 9-5/8" STUB. -SEE SOME ARCTIC PACK OVER THE SHAKERS DURING THE INITIAL CIRCULATION WHILE RUNNING INSIDE THE STUB, BUT THE FLUID QUICKLY RESUMES ITS LIGHT TAN COLOR. TIEB1 PUMP 20-Bbl HI-VIS SWEEP AT 9-BPM, 390-psi, AND SEE ONLY THE LIGHT TAN COLORED FLUID ACROSS THE SHAKERS. TIEB1 MONITOR WELL AND BLOW DOWN THE TOP DRIVE; PREPARE TO POH WITH CLEANOUT BHA. TIEB1 PJSM. POH AND S/B DP AND DCS IN DERRICK. SEE OVERPULL OF 30K-Ibs WHEN PULLING OFF BOTTOM, BUT rnmea: u4iluiu a:uu::tu rrh ~ i BP EXPLORATION Page 12 of 35 Operations Summary".Report Legal Well Name: 13-27 '.Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 'Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/5/2010 16:30 - 17:30 1.00 CASE P TIE61 DO NOT SEE ANY OVERPULL OR RESTRICTIONS WHILE CONTINUING TO POH. 17:30 - 18:00 0.50 CASE P TIEBi CLEAN BOOT BASKETS AND GET 3.5-GALLNS OF GRAVEL AND SAND OUT OF THE BASKETS. ALSO FIND THE INSIDE MANDREL OF THE BOTTOM BOOT BASKET PLUGGED WITH GRAVEL AND A SAND PLUG INSIDE THE TOP BOOT BASKET MANDREL. THIS PLUGGING OCCURRED WHEN FLUID U-TUBED FROM THE ANNULUS BACK UP THROUGH THE BIT AND INTO THE DP. 18:00 - 18:30 0.50 CASE P TIE61 CLEAR AND CLEAN THE RIG FLOOR AND BRING THE 9-5/8" DRESS-OFF BHA TO THE RIG FLOOR. 18:30 - 20:00 1.50 CASE P TIEB1 - FF BHA:RESS OFF SHOE, WASHPIPE EXTENSION, MILL INSIE SHOE, WASHOVER BOOT BAASKET, DOUBLE PIN SUB, 13-3/8" CASING SCRAPER, OUBLE BOX PIN, CASING CLEANING BRUSH, XO, BUMPER SUB, OIL JAR, FLOAT SUB, XO, 6-EA DRILL COLLARS, XO. 20:00 - 21:00 1.00 CASE P TIE61 RIH TO 1867' -WASH DOWN LAST STAND TO ENSURE WE DO NOT PACKOFF THE SHOE. NOTHING SEEN WHILE RUNNING IN HOLE. -ESTABLISH PARAMETERS AT 10-BPM WITH 470-PSI, 50-RPM, 3K-FREE TORQUE. 21:00 - 22:00 1.00 CASE P TIEB1 DRESS OFF 9-5/8" CASING STUB AT 6-BPM WITH 150-PSI, 3-5K TORQUE, 50-RPM, 1-3K-WOB. SOME GRAVEL SEEN IN RETURNS ACROSS SHAKERS. 22:00 - 23:30 1.50 CASE P TIEB1 CIRCULATE WELL. -CIRCULATE 20-BBL HIVIS SWEEP. SMALL AMOUNT OF GRAVEL AND SAND SEEN AT SHAKERS. -CIRCULATE 40-BBL SAFE-SURF-O UNABLE TO DISTINGUISH WHEN IT RETURNED TO SURFACE. -BLOW DOWN TOP DRIVE. 23:30 - 00:00 0.50 CASE P TIE61 POH RACKING BACK 4" DP. 1/6/2010 00:00 - 01:30 1.50 CASE P TIE61 POH RACKING BACK 4" DP. -RACK BACK 6-EA DRILL COLLARS -LD DRESS OFF BHA -VERIFY SCRATCHES ON NOGO INNER MILL 01:30 - 02:30 1.00 CASE P TIEB1 -CLEAR AND CLEAN RIG FLOOR -MU XO FOR TIW. -PULL WEAR RING 02:30 - 04:00 1.50 CASE P TIEBi PJSM. RU 9-5/8" CASING HANDLING EQUIPMENT. -TEST TORQUE TURN SYSTEM. 04:00 - 09:00 5.00 CASE P TIEB1 PJSM ON RUNNING CASING WITH RIG CREW, DOYON CASING, HALLIBURTON, BAKER FISHING, BAKER COMPLETIONS, WSL -RUN 9-5/8" 47# L80 HYDRIL 563 CASING. -MU CONNECTIONS TO OPTIMUM 15,800FT-LBS. -BAKERLOK ALL CONNECTIONS BELOW ES CEMENTER -USE JET LUBE SEAL GUARD ON ALL HYDRIL 563 THREADS. -INSTALLED 1-EA FREE FLOATING CENTRALIZER PER JOINT ABOVE ES CEMENTER. TOTAL = 47 09:00 - 10:00 1.00 CASE P TIEB1 P/U 5' PUP JOINT AND M/U TO FULL JOINT #48. RIH SLOWLY WITH 1-RPM ROTATION AND SLIDE-OVER STUB, P~fltetl: L4/'LULU 4:UU:3U YM BP EXPLORATION Page 13 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To 'Hours. Task Code NPT 1/6/2010 09:00 - 10:00 1.00 CASE P 10:00 - 10:45 0.75 CASE P 10:45 - 11:30 0.75 CASE P 11:30 - 13:00 1.50 CASE P 13:00 - 15:00 2.00 CASE P Spud Date: 5/26/1983 Start: 12/15/2009 End: 1/21/2010 Rig Release: 1/21/2010 Rig Number: Phase Description of Operations TIE61 STOP ROTATING AND CONTINUE ON DOWN FORA 3' SWALLOW OVER THE STUB WITH THE 9-5/8" BOWEN CASING PATCH. -P/U TO TO 150K-Ibs AND S/O TO 85K-Ibs. P/U TO 300K-Ibs TO SET SLIPS. -M/U XO: 9-5/8" BTC box x HYDRIL 563 pin. -VERIFY PUMP DOWN PLUG PLACEMENT IN CEMENTING HEAD THEN M/U HALLIBURTON XO AND CEMENTING HEAD. -P/U TO 320K-Ibs TO PULL SLIPS. S/O TO 220K-Ibs FOR 100K-Ibs OVERPULL. TIEB1 R/U TO PT CASING AND TO SET ECP AND HOLD PJSM FOR PRESSURE TESTING THE CASING, SETTING THE ECP, AND OPENING THE HALLIBURTON CEMENTER. TIEB1 BRING PRESSURE UP TO 800-psi TO STABILIZE. INCREASE PRESSURE TO 1100-psi AND HOLD FOR 10-minutes RECORDED ON CHART FOR SOLID TEST. INCREASE PRESSURE TO 1700-psi AND SEE PACKER INFLATE WITH ABLEED-OFF TO 1500-psi. LET THE PRESSURE STABILIZE A FEW MINUTES, THEN INCREASE TO 2000-psi TO CLOSE THE INFLATION VALVE AND IT TAKES SLIGHTLY LESS THAN 1/4-Bbl TO REFILL. -HOLD PRESSURE AT 2000-psi FOR 10 CHARTED MINUTES. -BLEED OFF CASING PRESSURE TO 0-psi. -PRESSURE UP THE CASING TO OPEN THE CEMENTER AND THE CEMENTER OPENS AT 3000-psi. TIE61 CIRCULATE 9.6-ppg BRINE FROM PITS STARTING AT 90F AT 5-BPM. -1200-Hrs--HOLD PJSM WITH 6-CH2MHILL PERSONNEL, 5-SCHLUMBERGER, 2-BAKER COMPLETIONS, 1-BAKER FISHING, 1-HALLIBURTON HAND, RIG CREW, TOOLPUSHER, SPOC, AND WSL TO COVER THE SAFETY AND OPERATIONAL ASPECTS OF THE 9-5/8" CEMENTING PROCEDURE. EACH PERSON WAS ASKED TO DESCRIBE THEIR SAFETY CONCERNS WHICH RANGED FROM SLIPPERY SURFACES OUTSIDE TO TRAPPED PRESSURE TO COMMUNICATION REQUIREMENTS TO CORRECT VALVE ALIGNMENT AND LEAK CHAMPION SELECTIONS FOR ALL SOULS. -1230-Hrs--RETURNING FLUID TEMPERATURE AT 350-Bbls CIRCULATED IS 72F, FLUID LEAVING PITS IS 82F. -1300-Hrs--390-Bbls AWAY; TEMP GOING IN IS 82F, RETURNING IS 72F. -CALL ADW ENGINEERING AND AGREE TO START PUMPING THE CEMENT.- TIEB1 PT SCHLUMBERGER LINES TO 1000-psi TO WALK THE LINES CHECKING FOR LEAKS. THE PUMP TRUCK POP-OFF WAS CHECKED AND IS SET AT 4900-psi. -INCREASE PRESSURE TO 4500-psi. -1303-Hrs--SCHLUMBERGER GET READY TO PUMP 136-Bbls OF 15.8-ppg, GASBLOCK, CLASS G CEMENT. -1310-Hrs--GET SLOW RETURNS R rnntea: uaizutu a:vu:~u rnn • • BP EXPLORATION Page 14 of 35 "Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT Spud Date: 5/26/1983 Start: 12/15/2009 End: 1/21/2010 Rig Release: 1 /21 /2010 Rig Number: Phase ~ Description of Operations 1/6/2010 13:00 - 15:00 I 2.00 CASE P 15:00 - 15:30 I 0.501 CASE I P TIE61 THE TOP OF THE CONDUCTOR. -1320-Hrs--BLUE GOO OOZES OUT THE TOP. USING SUPER SUCKER TO SUCK OFF THE BLUE GOO AND USE VAC TRUCK TO SUCK CLEAR FLUID FROM CELLAR. THE TOTAL FLOW FROM THE CONDUCTOR IS LIKELY LESS THAN 1-GPM. -PRESSURE AT THE INLET TO THE CHOKE MANIFOLD IS 150-psi DURING THE CEMENT PUMPING PHASE. -1335-Hrs--RELEASE PUMP-DOWN PLUG. SCHLUMBERGER SWITCH OVER TO TAKE 9.8-ppg BRINE FROM CH2MHILLTO DISPLACE THE CEMENT. -CHASE PLUG AT 7.6-BPM AND 800-PSI AT SHCLUMBERGER PUMP; 75-psi AT THE CHOKE SKID. -1347-Hrs--CATCH CEMENT AT 52-Bbls DISPLACEMENT -1335-Hrs--ALL CEMENT PUMPED. -1350-Hrs--175-psi AT THE INLET TO THE CHOKE MANIFOLD. -1400-Hrs--AT 102-Bbls DISPLACEMENT SEE CEMENT TO RED FLOWBACK TANK. PINCH CHOKE TO 250-psi TO START SQUEEZING CEMENT INTO THE 13-3/8". _. -1405-Hrs--AT 112-Bbls DISPLACEMENT PUMPED, THE 2" LINE TO THE RED FLOWBACKTANK APPEARED TO PACKOFF. STOP SCHLUMBERGER PUMP. OPEN HYDRIL TO VERIFY FLOW. CHECKED CHOKE AT MANIFOLD AND OPERATOR HAD FULLY CLOSED CHOKE, BECAUSE OPERATOR WAS LOOKING AT DOWNSTREAM GUAGE AND WAS CLOSING CHOKE TO TRY TO INCREASE PRESSURE. OPEN CHOKE. CLOSE HYDRIL AND BEGIN PUMPING AND SEE RETURNS AT RED TANK IMMEDIATELY. THIS ACTION CONSUMED 3-MINUTES. CONTINUE SCHLUMBERGER PUMP AT 2.4-BPM, 1300-PSI, INLET TO CHOKE MANIFOLD AT 200-psi. -1413-Hrs--REDUCE PUMP RATE TO 1-BPM, 1000-psi. FLOW INCREASES RAPIDLY IN CONDUCTOR WITH LOTS OF BLUE GOO COMING OUT OF THE CONDUCTOR. -1420-Hrs--CEMENT IN CELLAR AT 134-Bbls DISPLACEMENT. -1421-Hrs--BUMPED PLUG AT 135.9-Bbls; PINS SHEARED AT 1800-psi--CEMENT IN PLACE AT 1421-Hrs. -PRESSURE TEST ON CLOSING PLUG TO 1700-psi FOR 15-MINUTES SOLID TEST RECORDED ON CHART. -OPEN ALL VALVES ON CEMENTING HEAD AND SEE NO FLOW UP THE CASING. -CEMENT IN CONDUCTOR IS CONSISTENT AROUND THE PERIPHERY OF THE TOP AND CONTINUED TO OOZE FOR 30-MINUTES TO THE SURFACE. -CEMENT IN PLACE AT 1420-HRS. 32-BBL CEMENT TO_ _. TIE61 BLEED DOWN AND CLEAN UP LINES. R/D SCHLUMBERGER. START CLEANING PITS TO PREPARE FOR FLUID SWAP TO CLEAN 9.8-ppg BRINE. R/D HALLIBURTON CEMENTING HEAD. -CHECK CEMENT LEVEL IN CONDUCTOR AND IT IS rooted: ziarzuiu a:uusu rrvi • • BP EXPLORATION Page 15 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From- To Hours. Task Code NPT Phase Description of Operations 1/6/2010 15:00 - 15:30 0.50 CASE P TIEB1 THICKENING JUST BELOW THE FLUTES IN THE TOP OF THE CONDUCTOR. -PUMP 40-BBL CITRIC PILL THROUGH KILL LINE AND OUT THE OA. 15:30 - 16:30 1.00 BOPSU P TIEB1 HOLD PJSM FOR N/D BOP STACK. N/D BOP STACK TO PREPARE FOR INSTALLING EMERGENCY SLIPS AND CUT CASING. 16:30 - 19:00 2.50 WHSUR P TIE61 FMC AND CREW HOLD PJSM TO INSTALL EMERGENCY SLIPS AND CUT CASING. -FMC ASSEMBLE AND INSTALL EMERGENCY SLIPS. DRILLER SLACKED OFF ON THE CASING AND SAW ONLY 1/4" MOVEMENT OF PIPE BEFORE ELEVATORS WERE FREE. -SET SLIPS WITH 100K-LBS . -FMC RU WACHS CUTER AND MAKE CUT ON 9-5/8" CASING. -CASING JOINT CUT OFF WITH 13.5' LEFT IN WELL. 19:00 - 20:30 1.50 WHSUR P TIEB1 PJSM ON ND UBING SPOOL. -CLEAN OFF SLIPS, SET PACKOFF -FMC RILDS 20:30 - 23:00 2.50 WHSUR P TIEB1 NU NEW TUBING SPOOL -NU BOP -CHANGEOUT BAILS ON OP DRIVE 23:00 - 23:30 0.50 WHSUR P TIEB1 PRESSURE TEST NEW PACKOFF TO 3500-PSI FOR 30-MIN. TEST GOOD. 23:30 - 00:00 0.50 BOPSU P TIEB1 FUNCTION TEST BOP COMPONENTS. -MU TEST PLUG 1/7/2010 00:00 - 00:30 0.50 BOPSU P TIE61 PRESSURE TEST BREAKS ON BOP STACK TO 250-PSI LOW AND 3500-PSI HIGH FOR 5-MIN CHARTED. GOOD TEST -LD TEST JOINT. -INSTALL WEAR RING. 00:30 - 01:30 1.00 DRILL P TIE61 CLEAR AND CLEAN RIG FLOOR BREAK OUT AND LD PRIOR BHA ASSEMBLIES. 01:30 - 02:30 1.00 DRILL P TIEB1 MU CEMENT DRILL OUT BHA: 8-1/2" BIT, 4-EA BOOT BASKET, BIT SUB, OIL JAR, XO, 6-EA DRILL COLLAR, XO. 02:30 - 03:00 0.50 DRILL P TIEB1 RIH ON STANDS WITH 4" DP. O JUST ABOVE OP OF CEMENT. 03:00 - 06:00 3.00 DRILL P TIEBi ESTABLISH PARAMETERS -CIRCULATE AT 7-BPM WITH 300-PSI. PU = 75K-LBS, SO = 75K-LBS, RO = 75K-LBS. 100-RPM, 5K-FREE TORQUE. -TAG TOP OF' CEMENT AT 1820'. -TAG TOP OF PLUG AT 1821'. -DRILL CEMENT WITH 2-3K-WOB. BREAK THROUGH PLUG AT 1824', CONTINUE WASHING DOWN TO A HARD TAG AT 1933'. DRILL ON TOP OF JUNK WITH VARYING PARAMETERS: 40-60-RPM, 1-5-BPM, 30-100-psi, 2-10-K-Ibs WOB. MAKE NO PROGRESS AFTER 45-MINUTES. -CALL ADW ENGINEER AND DECIDE TO POH TO M/U A SHOE ON RCJB WITH 4-BOOT BASKETS. 06:00 - 07:30 1.50 DRILL P TIEB1 PJSM. SLOWDOWN TOPDRIVE AND POH, S/B DP AND DCS IN DERRICK. -GET A HANDFULL OF ALUMINUM PIECES WITH A (~f<~ Printetl: 2/4/2010 4:00:30 PM $P EXPLORATION Page 16 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/7/2010 06:00 - 07:30 1.50 DRILL P 07:30 - 09:00 1.501 DRILL I P 09:00 - 10:30 1.501 DRILL ~ P 10:30 - 12:00 1.501 DRILL P 12:00 - 14:00 I 2.001 DRILL I P 14:00 - 15:00 I 1.001 DRILL I P 15:00 - 16:30 I 1.501 DRILL I P 16:30 - 18:00 I 1.501 DRILL I P 18:00 - 18:30 0.501 DRILL P TIEB1 COUPLE 1/2" CHUNKS OF BRASS ALONG WITH FINE CUTTINGS FROM THE BOOT BASKETS. TIE61 M/U SHOE ON RCJB AND RIH ON DP AND DCS FROM DERRICK TO 1926'. GET PARAMETERS: 80K UP WT, 75K DN WT. SEE THE CASING PATCH AT 1867' TAKE WEIGHT WHILE RIH, BUT THE SHOE SLIDES OFF IMMEDIATELY. TIEB1 PJSM. SLOWDOWN TOPDRIVE AND DROP RCJB BALL. M/U TO TOPDRIVE AND PUMP DOWN WITH 4-BPM, 660-psi AFTER BALL IS ON SEAT. START ROTATING AND BRING UP TO 80-RPM WITH 75K ROTATING WEIGHT, 4K-ft-Ibs FREE TORQUE. STOP ROTATING. -WASH DOWN TO TAG JUNK AT 1933 ; P/U AND START ROTATING AT 80-RPM AND WASH DOWN WITH 5K-WOB. INCREASE PUMP RATE TO 8-BPM, 1750-psi. CONTINUE TO ROTATE AND WASH DOWN TO 1943' WITH 5-10K-WOB. P/U, BREAK OFF TOPDRIVE FROM DP, AND BLOW DOWN TOPDRIVE. TIE61 POH S/B DP AND DCS IN DERRICK. FIND 45-50 PIECES OF BOW-SPRING CENTRALIZERS AND ALUMINUM WADDED UP INSIDE THE MOUTH OF THE SHOE. THESE RANGE IN LENGTH FROM 1" TO 14". ALSO GET 2-1/2-GALLONS OF PEA-SIZED AND LARGER GRAVEL OUT OF THE BOOT BASKETS. -THE SHOE WAS SEVERELY WORN IN THE INSIDE OF THE MOUTH. -CALL ADW ENGINEER AND AGREE TO CONTINUE RUNNING THE SAME, RE-DRESSED BHA. TIEB1 M/U A NEW 8-1/2" SHOE ON THE 7-7/8" RCJB AND RIH TO 1931', GET PARAMETERS: ROTATE AT 80-RPM WITH FR ORQUE OF 4K-ft-Ibs, 10-BPM AT 1440-psi, 3K WOB. REDUCE RIH SPEED WHEN NEAR THE CASING PATCH AT 1867' AND DO NOT SEE IT WHILE RUNNING THROUGH IT. TIEB1 P/U. BREAKOFF TOPDRIVE AND PREPARE TO DROP RCJB REVERSE CIRCULATING BALL. -DROP BALL AND START PUMP AND WORK UP TO 10-BPM, 1440-psi. START ROTATING AND BRING UP TO 80-RPM, 4K-ft-Ibs, GET 3-5K WOB AND WASH DOWN TO 1961'. -P/U, STOP ROTATING AND PUMPING TO RIH TO DRY TAG AT 1965'. -MIX DRY JOB AND PREPARE TO POH. TIEB1 POH AND S/B DP AND DCS IN DERRICK. -BREAK OUT BHA COMPONENTS; CLEANOUT SHOE AND BOOT BASKETS AND GET 15-PIECES OF CENTRALIZER BOW-SPRINGS, MOST AVERAGING 4" TO 6" LONG WITH 3 THAT ARE 8" TO 10" LONG. -SAND WAS CIRCULATED OUT OVER THE SHAKERS WHILE WORKING THE RCJB, BUT ONLY A GALLON OF SAND AND TWO CHUNKS OF CEMENT WERE RECOVERED FROM THE BOOT BASKETS. TIEB1 B WITH N ARBIDE ON RCJB HEAD -RIH TO 1929' TIE61 CLEAN OUT SAND FROM 1965' TO 1984'. LEAVE 10' OF Printed: 2/4/2010 4:00:30 PM BP EXPLORATION Page 17 of 35 Operations. Summary Report. Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code. NPT 1/7/2010 18:00 - 18:30 0.50 DRILL P 18:30 - 19:30 1.00 DRILL P 19:30 - 21:00 1.50 DRILL P 21:00 - 22:00 1.00 DHB P 22:00 - 23:00 1.00 DHB P 23:00 - 00:00 1.00 DRILL P 1/8/2010 00:00 - 00:30 0.50 DRILL P 00:30 - 01:30 1.00 DHB P 01:30 - 02:00 0.50 DHB P 02:00 - 03:30 1.50 DHB P 03:30 - 04:30 1.00 CASE P 04:30 - 12:00 7.50 CASE P Spud Date: 5/26/1983 Start: 12/15/2009 End: 1 /21 /2010 Rig Release: 1 /21 /2010 Rig Number: Phase.. Description of Operations TIEB1 SAND ABOVE RBP. -PARAMETERS PU = 75K-LBS, SO = 80K-LBS, RO = 75K-LBS. ROTATING AT 60-RPM, 3K- FT-LBS FREE TORQUE. PUMP AT 8-BPM WITH 2000-PSI. SEE THE CASING PATCH AT 1867' TAKE WEIGHT WHILE RIH, PICK UP MU TOP DRIVE AND ROTATE AT 5-RPM. RIH SLOWLY AFTER ONE TURN THE SHOE SLIDES OFF. TIE61 CIRCULATE WELL. -PUMP AT 8-BPM WITH 2040-PSI - SAND SEEN AT SHAKER. CIRCULATED TILL RETURNS WERE CLEAN. TIE61 BLOW DOWN TOP DRIVE. -POH RACKING BACK DP AND DRILL COLLARS. -LD BHA. -RCJB EMPTY AND ONLY 1- 1" PIECE OF METAL IN ONE ri BOOT BASKET THE REST WERE EMPTY. TIE61 CLOSE BLIND RAMS AND PRESSURE TEST CASING TO ~~' 3500-PSI FOR 30-MIN. LOST 190-PSI OVER 30-MIN WITH DECREASING LOSS RATE ACROSS THE 30-MIN. TEST GOOD. TIEB1 PJSM -PU R_ B_P RETRIEVING TOOL. _ -RIH TO 1908' -DID NOT SEE ANY OBSTRUCTIONS WHILE RUNNING IN HOLE. TIE61 PJSM -CUT 67' (10-WRAPS) OF DRILL LINE -INSPECT TOP DRIVE. TIEB1 SLIP AND CUT 6T OF DRILL LINE TIEB1 ESTABLISH PARAMETERS -PU = 62K-LBS SO = 64K-LBS, 8-BPM WITH 300-PSI -LATCH TO RBP AT 1995' AND CBU. -0100-HRS--PUMP 10-BBL HIVIS SWEEP. WHEN RETURNED SAW A LOT OF SAND AT THE SHAKERS. TIE61 RELEASE RBP -CBU AT 8-BPM WITH 300-PSI. SAW SAND AT THE SHAKERS. -NOTICED A 5-BBL LOSS AND THEN LOSSES STOPPED. -DID NOT SEE ANY OBSTRUCTIONS WHEN POH WITH THE RBP. TIEBi BLOW DOWN TOP DRIVE -POH WITH RBP. RACKING BACK 4" DP. -LD RBP AND RETRIEVING TOOL. -SMALL PIECE OF ALUMINUM WEDGED UNDER SEAL ON RBP. RBP SEAL HAS A GASH AROUND ENTIRE SEAL . TIEB2 PJSM. MU 4.5" DRESS OFF BHA: SHOE, 3-EA EXTENSION, WASHOVER BOOT BASKET, 4-1/2" DRESS OFF MILL, DOUBLE PIN SUB, 9-5/8" CASING SCRAPER, BIT SUB, BUMPER SUB, PUMP OUT SUB, XO, 6-EA DRILL COLLARS, XO. TIEB2 RIH WITH STANDS OF 4" DP FROM DERRICK TO 6202'. CONTINUE TO RIH WITH JOINTS OF 4" DP FROM THE PIPE SHED TO 9931'. .~~t~~ rnncev: ua¢u iu v:uusv rm BP EXPLORATION Page 18'of 35 Operations Summary-Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/8/2010 104:30 - 12:00 ~ 7.501 CASE P 12:00 - 13:30 1.50 ~ CASE P 13:30 - 14:30 1.00 CASE P 14:30 - 15:00 I 0.501 CASE I P 15:00 - 18:00 3.00 CASE P TIEB2 -MAKE 4-PASSES WITH THE 9-5/8" SCRAPER THROUGH , THE CASING PATCH AREA UNTIL NO WEIGHT OR RESTRICTION IS SEEN THROUGH THE PATCH AREA at 1866' to 1867'. -CONTINUE RIH AND MAKE 3-PASSES WITH THE 9-5/8" SCRAPER FROM 3900' TO 4083'. -1145-Hrs--P/U AND M/U JT #307. SLOWLY RIH AND TAG STUB AT 9921'. TIEB2 GET PARAMETERS: P/U WT 180K-Ibs, S/O WT 148K-Ibs, 10-BPM, 1980-psi, 40-RPM, 5K-ft-Ibs FREE TORQUE. STOP ROTATING AND RIH TO TAG AGAIN AT 9921'. -1200-Hrs--START LOADING 7" CASING INTO THE PIPE SHED TO STRAP AND RABBIT FOR RUNNING SCAB LINER. -P/U AND ROTATE AT 40-RPM, WITHIN A FEW ROTATIONS THE 4-9/16" ID SHOE EASILY SLIPS OVER THE STUB. -CONTINUE RIH AND SEE THAT THE SHOE MAY BE PUSHING SOMETHING A FEW FEET IN; P/U AND RIH SLOWLY, BUT THE DEBRIS DISAPPEARS. -CONTINUE WASHING DOWN TO 9937' IN WITH THE SHOE. STOP PUMPING AND ROTATING AND BREAK-OFF TOPDRIVE. -P/U #308 AND M/U TO STRING. START PUMPING A 20-Bbl HI-VIS SWEEP. -RESUME WASHING DOWN AND FIND THE STUB WITH THE INNER MILL. INCREASE RPMs TO 80-RPM AND MILL WITH 4-5K-Ibs WOB. MILL OFF ABOUT 2', WHICH PLACES THE STUB AT 9923' AND THE BOTTOM OF THE SH E A 9939'. -INCREASE RPM AND P/U TO PLACE THE SHOE ABOVE THE STUB. STOP ROTATING, RIH, AND THE SHOE SLIDES OVER THE STUB WITHOUT ANY PROBLEMS, LETTING STUB TAKE 5000-Ibs. -P/U SLIGHTLY AND ROTATE AT 100-RPM TO POLISH THE STUB WHILE POH TO A FEW FEET ABOVE THE TOP OF THE STUB. RETURNS ACROSS THE SHAKERS ARE CARRYING VARYING AMOUNTS OF BLACK GOOEY BALLS CONTAINING SAND, CUTTINGS AND OTHER FINES FROM 1/4" TO 1" IN DIAMETER. -REPEAT ONE TIME BY STOPPING ROTATION, SLOWLY RIH TO TAG OUT AT 9923', LETTING THE STUB TAKE 5K-Ibs, THEN ROTATING AT 100-RPM WHILE POH OVER THE STUB. -THERE WERE NO LOSSES TO THE WELLBORE DURING THE DRESS-OFF OPERATIONS. TIEB2 CIRCULATE ANOTHER 20-Bbl HI-VIS SWEEP AT 11-BPM, 2540-psi. THE RETURNS SPORADICALLY CARRY SMALL BALLS OF FINE DEBRIS OVER THE SHAKERS, BUT THE RETURNS CLEAN UP BEFORE THE SWEEP GETS TO THE SURFACE. TIEB2 MONITOR WELL AND PUMP DRY JOB TO PREPARE TO POH. TIE62 POH AND S/B DP AND DCS. Printed: 2/4/2010 4:00:30 PM • BP EXPLORATION Page 19 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: ~ ~ i r i Date From - To Hours Task Code NPT Phase 1/8/2010 15:00 - 18:00 3.00 CASE P TIEB2 18:00 - 00:00 6.00 CASE N HMAN TIE62 1/9/2010 100:00 - 02:00 2.00 ~ CASE ~ N ~ HMAN TIEB2 02:00 - 03:30 1.501 CASE ~ P 03:30 - 11:00 7.501 CASE ~ P TIEB2 TIE62 11:00 - 00:00 I 13.001 CASE I N I WAIT I TIEB2 Description of Operations -POH FROM 9921' TO 230' WHILE PULLING OUT OF THE HOLE, FLOORHAND INSTALLED DOG COLLAR ON DRILL COLLAR BUT THE ADJUSTMENT NUT WAS LOOSE AND SLIPPED OFF AND FELL THROUGH A HOLE AROUND THE GAP IN THE SLIPS. CALLED SUPERINTENDENT AND DISCUSSED OPTIONS FOR RECOVERING THE NUT. -1.PJSM AND THA FILLED OUT. PULL MASTER BUSHING UP AND SECURE IT WITH TUGGERS. LOCK OUT BRAKE HANDLE. A THOROUGH INSPECTION OF THE DRIP PAN DID NOT LOCATE THE NUT. -2. PICK UP BAKER 1-1/4" PIPE AND 3-1/2" MAGNET. ATTEMPT TO FIT THROUGH WEAR RING; WAS UNSUCCESSFUL. -3. WAIT FOR BAKER TO BRING 2-1/4" MAGNET. PICK UP 2-1/4" MAGNET ON 1-1/4" PIPE. RIH TO TRY TO FISH NUT. UNABLE TO CATCH NUT. -4. RACK BACK STAND OF DP, AND STAND OF COLLARS. SLOWLY PULL UP USING SCRAPER TO BRING NUT FURTHER UP HOLE TO WHERE WE CAN SEE THE NUT. PICK UP 35' AND START PICKING UP WEIGHT. SLACK OFF, ABLE TO GO DOWN. -5. LD JOINT OF DRILL COLLAR, PICK UP PUP JOINT OF DP. RU TO TOP DRIVE AND ROTATE AT 5-RPM WHILE PICKING UP. ABLE TO PICK UP WITH NO OVER PULL. LD 2-DRILL COLLARS, WHILE PULLING AND ROTATING AT 5-RPM. -CONTINUE LOADING, DRIFTING, AND STRAPPING CASING IN PIPE SHED. CONTINUE PULLING THE DRILL COLLARS OUT OF HOLE LAYING THEM DOWN TILL THE SCRAPER BRINGS THE NUT TO THE WEAR RING. ABLE TO PULL 2-DRILL COLLARS WITHOUT ROTATING AND NO OVERPULL. -0200-HRS ABLE TO PULL NUT OUT OF HOLE WITH MAGNET. --~ -CONTINUE LOADING, DRIFTING, AND STRAPPING CASING IN PIPE SHED. -CONTINUE TO LD 4-1/2" BHA. -INNER MILL SHOWED SIGNS OF WEAR. WASHOVER BOOT BASKET HAD 2-GAL OF SAND, METAL SHAVINGS, CRUDE, DRILLING MUD. CLEAR AND CLEAN RIG FLOOR. -BEGIN TO RU FLOOR FOR RUNNING 7" CASING. -CONTINUE DRIFTING AND STRAPPING 7" CASING IN PIPE SHED. 80-JOINTS OF 152-JOINTS LOADED IN PIPE SHED AS OF 0600-Hrs. -1100-Hrs--STOP FORKLIFT OPERATIONS DUE TO -45F TEMPERATURE. 20-JOINTS OF 7" REMAINING OUTSIDE. - FLUID LEVEL IN WELLBORE STATIC. NO LOSSES TO WELLBORE DURING FISHING OPERATION. S/D FORK LIFTING OPERATIONS AND OUTSIDE WORK OTHER THAN PERIODIC SPCC PATROLS, DUE TO TEMPERATURE BELOW -45-DEGREES F. rnnceo: uaiw ro v:uu:ou rm • s BP' EXPLORATION Page 20 of 35` Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To, Hours Task ,Code NPT Phase Description of Operations 1/9/2010 11:00 - 00:00 13.00 CASE N WAIT TIEB2 -RIG CREW PERFORMING WORK ORDERS, 1/10/2010 100:00 - 00:30 I 0.501 CASE I P 00:30 - 01:00 0.50 CASE P 01:00 - 09:00 8.00 CASE P 09:00 - 13:30 4.501 CASE P 13:30 - 16:00 I 2.501 CASE I P HOUSEKEEPING, AND ROUTINE MAINTENANCE INSIDE RIG AND MODULES. TIEB2 MONITOR CONDUCTOR X 13-3/8" ANNULUS FOR FLOW. -FRESH WATER FLOW IDENTIFIED; LESS THAN 1 GAUHR. - NOTIFIED TOWN ENGINEER AND DAY WSL. -OA=OPSI. - USED A BROOM HANDLE TO PROBE FOR AND TAG HARD CEMENT 1' BELOW FLUTED MANDREL HANGER IN EVERY OPENING. TIE62 PJSM FOR RIH W/7" SCAB LINER. TIE62 RIH W/ 7", 26#, L-80, BTC-M AND VAM TOP HC SCAB LINER TO 2,555'. - MU TQ 7,600 FT-LBS ON BTC-M TO STAMP ON AVERAGE. -OPTIMUM MU TQ 11,950 FT-LBS ON VAM TOP HC. - OPTIMUM MU TQ 10,500 FT-LBS ON VAM TOP HT X VAM TOP HC CONNECTION AT PIN END OF LINER TOP PACKER. -UNIQUE OVERSHOT AND SHOE TRACT ALL BAKER-LOC'ED. -WSL CHECKED THE CELLAR AND THE FRESHWATER FLOW UP THE CONDUCTORS REMAINS CONSTANT AT -1-GAUHR. A CREW MEMBER IS ASSIGNED TO THE CELLAR AT ALL TIMES TO MONITOR FLOW AND TO SUCK OUT THE TOP OF THE CONDUCTOR WITH TRASH PUMP. - 0900-HRS--FINISH RIH WITH THE FIRST 128-JOINTS OF 7" 26# BTC-M THAT HAD BEEN LOADED INTO THE PIPE SHED. FILLED EACH JOINT WITH 9.8-PPG BRINE WHILE RIH. - PERFORM RISK ASSESSMENT USING 5.1 "EQUIPMENT OPERATIONS IN EXTREME WEATHER ASSESSMENT SIGNATURE FORM" FOUND IN THE BP HSEMS "INCLEMENT WEATHER EQUIPMENTOPERATING PROCEDURE". TIEB2 LOAD PIPE SHED WITH 20-JOINTS OF 7", 26#, L-80, BTC-M CASING AND RABBIT, STRAP, AND CHECK THREADS. - WSL UPDATE RUNNING SUMMARY. - 1240-HRS--CALLED AOGCC TO ADVISE IMPENDING WEEKLY BOPE TEST FOR EARLY TOMORROW. BOB NOBLE, AOGCC NS INSPECTOR, IMMEDIATELY RETURNED CALL AND WAIVED STATE'S RIGHT TO WITNESS THE TESTS. TIEB2 RESUME RIH WITH 7", 26#, L-80, BTC-M CASING. FILLED EACH JOINT WITH 9.8-PPG BRINE WHILE RIH. - 1530-HRS--P/U AND M/U THE XO FULL JOINT: 7", 26#, L80, VAM-TOP HC box X 7", 26#, L80 BTC-M pin. M/U TORQUE TO THE BTC-M IS 8000-ft-Ibs. RAN 144 FULL JOINTS OF 7", 26#, L80, BTC-M. - 1545-HRS--P/U AND M/U THE BAKER LINER HANGER AND PACKER ASSEMBLY WITH 7", VAM-TOP HT pin ON BOTTOM. M/U TORQUE IS 10,500-ft-Ibs. P/U WT 162-K-Ibs, Printed: 2/4/2010 4:00:30 PM BP EXPLORATION. Page 21 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 1/10/2010 13:30 - 16:00 2.50 CASE P 16:00 - 19:00 3.001 CASE ~ P 19:00 - 19:30 0.50 ~ CASE ~ P 19:30 - 22:00 I 2.501 CASE N ~ HMAN ~ TIEB2 Spud Date: 5/26/1983 Start: 12/15/2009 End: 1/21/2010 Rig Release: 1/21/2010 Rig Number: Phase Description of :Operations TIEB2 S/O WT 152-K-Ibs. - 1615-HRS--M/U TO TOPDRIVE AND PUMP 50-BBLS TO ENSURE STRING AND FLOAT ARE CLEAR. PUMP RATE 4-BPM AT 50-PSI. BREAK OFF AND BLOW DOWN TOP-DRIVE. - 1645-HRS--RESUME RIH WITH THE 7" SCAB LINER ON DP STANDS FROM THE DERRICK. TIEB2 RIH WITH THE 7" SCAB LINER FROM 5,995' TO WHAT WAS THOUGHT TO BE 9,878', FILLING PIPE EVERY 5 STANDS. TIE62 EASED IN HOLE AND CONTINUED IN HOLE UNTIL 45' PAST CALCULATED 4-1/2" STUMP TAGGING DEPTH. - NIGHT WSL, DRILLER, AND BAKER HANDS STOPPED THE JOB AND DISCUSSED WHAT COULD BE HAPPENING; AFTER REVIEW OF THE ORIGINAL TALLY, IT WAS DISCOVERED THAT WE WERE 12 JOINTS SHORT DUE TO 12 JOINTS OF 7" VAM-TOP HC BEING KICKED OUT OF THE PIPE SHED, BUT REMAINING IN THE TALLY. - PU WT 230K. SO WT 162K. 22:00 - 00:00 2.00 CASE N ~ HMAN ~ TIE62 1/11/2010 ~ 00:00 - 02:30 ~ 2.50 ~ CASE ~ N ~ HMAN ~ TIEB2 02:30 - 05:00 2.50 CASE N HMAN TIE62 05:00 - 06:00 1.00 CASE P TIE62 06:00 - 19:30 13.501 CASE N ~ HMAN ~ TIEB2 - LD LINER HANGER AND CROSSOVER. - LOAD/STRAP APPROPRIATE 7" BTC-M AND VAM-TOP HC IN PIPESHED. - RU POWER TONGS AND CASING HANDLING EQUIPMENT. CONTINUE WORK ON 7" JOINTS IN PIPESHED WHILE PREPPING RIG FLOOR FOR RUNNING CASING. -GET NEW STRAP TO NIGHT WSL FOR NEW RUN TALLY. - RU FILL-UP LINE. - MU FLOOR SAFETY VALVE AND CROSSOVER. RESUME RIH WITH 7", 26#, L-80, BTC-M AND VAM-TOP HC CASING FROM 5,454' TO 5,977'. FILLED EVERY 5 JOINTS WITH 9.8-PPG BRINE WHILE RIH. - PU AND MU THE XO FULL JOINT: 7", 26#, L-80, VAM-TOP HC BOX X 7", 26#, L-80, BTC-M PIN. MU TORQUE TO THE BTC-M IS 8,000 FT LBS. RAN 140 FULL JOINTS OF 7", 26#, L-80, BTC-M. MU TORQUE IS 11,950 FT LBS FOR THE VAM TOP HC. RAN 4 FULL JOINTS OF 7", 26#, L-80, VAMTOP HC. - PU AND MU THE BAKER FLEX-LOCK LINER HANGER AND PACKER ASSEMBLY WITH 7", VAM-TOP HT PIN ON BOTTOM. MU TORQUE IS 10,500 FT LBS. PU WT 230K, SO WT 162K. RIH WITH 7" SCAB LINER ON 4" DP FROM 5,977' TO 9,878'. WASHED DOWN FROM 9,878' TO 9,900'. - 7.7 BPM, 950 PSI. - CONTINUED RIH TO 9,909' USING 5-FT STICK TO VERIFY DEPTH; TOOK 7K AT 9,909'. - CONTINUED RIH TO 9,913'; TOOK 5K AT 9,913'. - STACKED OUT AT 9,923'; TOOK 18K AT 9,923'. - REPEATED THIS SEQUENCE 12 TIMES. - MADE ONE LEFT-HAND ROTATION AND REPEATED SEQUENCE TWICE WITH THE SAME RESULTS. CONSULTED WITH ADW ENGINEERING AND RWO Printed: 2/4/2010 4:00:30 PM BP EXPLORATION Page 22 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2010 06:00 - 19:30 13.50 CASE N HMAN TIEB2 SUPERINTENDENT AND DECIDE TO POH AND RETALLY ALL CASING, VERIFY CONDITION OF OVERSHOT SHEAR PINS, AND RE-RUN 7" SCAB LINER BASED ON NEW TALLY. - 1030-HRS---FINISH S/B 4" DP STANDS IN DERRICK. - BREAK OUT, PROTECT SEALS, AND UD THE LINER HANGER AND LINER TOP PACKER ASSEMBLY. INSPECT FOR SIGNS OF DAMAGE AND FIND NOTHING BUT SMALL SCRATCHES ON THE BODY OF THE LINER TOP. - 1230-HRS---BEGIN BREAKING OUT AND UD THE 7" SCAB LINER. - 1530-HRS---UD CASING JOINT #60. NOT EXPERIENCING ANY PROBLEMS BREAKING OUT THE 7", 26#, L-80, BTC-M CASING. - 1630-HRS---UD #75. - 1715-HRS---UD #101. - 1830-HRS---UD #121. - 1930-HRS---FINISH UD 7" SCAB LINER TO JEWELRY/CEMENT TRACT. DID NOT EXPERIENCE ANY PROBLEMS BREAKING OUT THE 7", 26#, L-80, VAM TOP HC CASING. 19:30 - 20:30 1.00 CASE N HMAN TIEB2 LD JEWELRY/CEMENT TRACK AND HOT SHOT TO BAKER MACHINE FOR REBUCKING/RETHREADING AND INSTALLATION OF 6-EA, 3,565# SHEAR PINS AT 4' AND 12' INTO 9-5/8" X 4-1/2" OVERSHOT GUIDE. - STRING OUT TORCH LEADS TO RIG FLOOR, PJSM/THA, MONITOR FOR GAS ON RIG FLOOR, AND SECURE HOT WORK PERMIT. - USE ROSE BUD TORCH TO BREAK-OUT BAKERLOK'ED CONNECTIONS; SUCCESSFUL WITH ALL CONNECTIONS; FLOAT AND LANDING COLLARS REPLACED DUE TO POSSIBLE HEAT DAMAGE. -CLOSED HYDRIUANNULAR PREVENTER WHILE USING ROSE BUD. -ALL PINS AT 4' AND 12' INTO 9-5/8" X 4-1/2" OVERSHOT GUIDE SHEARED AND INSIDE BORE OF OVERSHOT WAS POLISHED BY 4-1/2" TUBING STUMP. - AFTER 7" CASING RE-STRAP, NIGHT WSL FOUND CRITICAL ERROR.IN ORIGINAL PIPE TALLY FROM P_IPESHED THAT ACCOUNTED FOR PERCEIVED LACK OF OVERSHOT S_W_ALLOW IN THE PREVIOUS 7" SCAB LINER RUN AND TAG OPERATION. 20:30 - 21:30 1.00 CASE N HMAN TIEB2 RD 7" SCAB LINER RUNNING EQUIPMENT, PULL WEAR RING, AND INSTALL TEST PLUG TO FACILITATE TESTING BOPE. 21:30 - 00:00 2.50 CASE P TIEB2 PERFORM WEEKLY BOPE TEST. - TEST TO 250-PSI LOW AND 3,500-PSI HIGH FOR 5-CHARTED MINUTES PER TEST. -TEST 3-1/2" X 6" VBRS USING 4-1/2" AND 4" TEST JTS. "/~ -TEST HYDRIUANNULAR PREVENTER USING 4" TEST JT. - ALL TESTS WITNESSED BY BP WSL AND DOYON TOURPUSHER. - VERY SLOW FRESHWATER RETURNS THROUGH Printed: 2/4/2010 4:00:30 PM ~ ~ BP EXPLORATION Page 23 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2010 121:30 - 00:00 I 2.501 CASE I P 1/12/2010 100:00 - 03:00 3.001 CASE ~ P 03:00 - 03:30 0.501 CASE I P TIEB2 CONDUCTOR; 1 GAUHR. - AOGCC TEST WITNESS WAIVED BY BOB NOBLE ON 10 JAN 10 AT 1240 HRS. TIEB2 TIE62 03:30 - 04:00 0.50 CASE N HMAN TIEB2 04:00 - 13:30 9.50 CASE N HMAN TIEB2 13:30 - 14:00 0.50 CASE N 14:00 - 16:30 2.50 CASE N 16:30 - 17:00 I 0.501 CASE I N TIEB2 TIE62 TIEB2 -TEST TO 250-PSI LOW AND 3,500-PSI HIGH FOR 5-CHARTED MINUTES PER TEST. - TEST 3-1/2" X 6" VBRS USING 4-1/2" AND 4" TEST JTS. - TEST HYDRIUANNULAR PREVENTER USING 4" TEST JT. - ALL TESTS WITNESSED BY BP WSL AND DOYON TOURPUSHER. -VERY SLOW FRESHWATER RETURNS THROUGH CONDUCTOR; 1 GAUHR. - AOGCC TEST WITNESS WAIVED BY BOB NOBLE ON 10 JAN 10 AT 1240 HRS. RD TEST EQUIPMENT. - BLOW DOWN ALL LINES. - PULL TEST PLUG. - INSTALL WEAR RING. PJSM AND RU TO RIH WITH 7" SCAB LINER. RIH W/ 7", 26#, L-80, BTC-M AND VAM TOP HC SCAB LINEF TO 1,000'. - MU TQ 8,200 FT-LBS ON BTC-M TO STAMP ON AVERAGE. - OPTIMUM MU TQ 11,950 FT-LBS ON VAM TOP HC; WILL BE TORQUE TURNED. - OPTIMUM MU TQ 10,500 FT-LBS ON VAM TOP HT X VAM TOP HC CONNECTION AT PIN END OF LINER TOP PACKER; WILL BE TORQUE TURNED. - UNIQUE OVERSHOT AND SHOE TRACT ALL BAKER-LOK'ED. - SHOE TRACT FILLED WITH 9.8 PPG BRINE AND FLOATS CHECKED; CHECKED GOOD. -WSL CHECKED THE CELLAR AND THE FRESHWATER FLOW UP THE CONDUCTOR REMAINS CONSTANT AT -1-GAUHR. A CREW MEMBER IS ASSIGNED TO THE CELLAR AT ALL TIMES TO MONITOR FLOW AND TO SUCK OUT THE TOP OF THE CONDUCTOR WITH TRASH PUMP. - RIH WITH CASING JOINT #32 AT 0640-Hrs; #66 AT 0800-Hrs; #85 at 0900-Hrs; 7" LINER HANGER AND PACKER ASSEMBLY AT 1300-Hrs. - 1320-Hrs---P/U FIRST STAND OF DP, M/U TO DP HANDLING PUP ON TOP OF HANGER/PACKER ASSEMBLY, M/U TOPDRIVE TO STAND AND CIRCULATE 50-Bbls OF 9.8-ppg BRINE. CIRCULATE 50-Bbls, 4-BPM, 110-psi. CONTINUE RIH. STOP JUST ABOVE THE STUB AT 9923' AND GET PARAMETERS: 250K-Ibs UP WEIGHT, 168K-Ibs DOWN WEIGHT. CONTINUE RIH SLOWLY AND FIND TOP OF STUB AT 9323', TAKING 6K-Ibs TO SLIDE OVER. CONTINUE RIH ANOTHER 4' AND SEE THE FIRST SET OF SHEAR PINS; SET DOWN 9K-Ibs AND THE PINS SHEAR. CONTINUE RIH FOR ANOTHER 8' AND SEE THE SECOND SET OF SHEAR PfI0t8tl: 1/4/ZUIU 4:UU:3V NM ~ ~ BP EXPLORATION' Page 24 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2010 16:30 - 17:00 0.50 ~ CASE ~ N 17:00 - 17:30 I 0.501 CASE I N 17:30 - 19:00 I 1.501 CASE I P 19:00 - 19:30 0.501 CASE ~ P 19:30 - 00:00 4.501 CASE P TIEB2 PINS. SET DOWN 10K-Ibs AND THE PINS SHEAR. CONTINUE RIH ANOTHER 6-1/2' AND SEE NO-GO, WHICH PUTS THE BOTTOM OF THE OVERSHOT AT -9937'. SET DOWN 21K-Ibs TO VERIFY NO-GO. P/U -2' TO MARK THE DP TO CALCULATE THE SPACE-OUT OF THE CEMENTING HEAD ABOVE THE RIG FLOOR. TIE62 S/B STAND #42; P/U AND M/U A SINGLE JOINT OF DP AND A 15' DP PUP JOINT, M/U TO THE STRING. - P/U 5' DP PUP JOINT, M/U TO STRING AND RIH TO REPEAT TAG AND SWALLOW DOWN TO NO-GO, SEEING BOTH THE TOP OF THE STUB AT 9923' AND THE NO-GO AT 9937. - P/U 2' AND BREAK OFF THE 5' DP PUP JOINT. THIS SPOTS THE BOTTOM OF THE OVERSHOT AT 9935', WHICH GIVES A -12' SWALLOW WITH THE NO-GOOF THE OVERSHOT 2' ABOVE THE STUB AT 9923'. - THE BOTTOM OF THE CEMENTING HEAD ASSEMBLY IS 4' ABOVE THE RIG FLOOR. TIE62 .BRING CEMENTING HEAD TO THE RIG FLOOR TO PREPARE FOR R/U. - PJSM FOR R/U - R/U CEMENT EQUIPMENT. - R/U CHART RECORDER. TIE62 PJSM FOR CEMENT JOB WITH CREWS, WSLs, TOUR PUSHER, CEMENTERS, TRUCK DRIVERS, AND MUD ENGINEER. DISCUSSED WHAT EACH PERSON RECOGNIZED AS A HAZARD IN THE UPCOMING JOB. TIE62 PRESSURE TEST CEMENT LINES. -BATCH UP CEMENT. - CEMENTERS PUMP 175 BBLS OF 15.8 PPG CEMENT AT 6 0 BPM WITH 600 PSI.. - DROPPED DART WITH GOOD INDICATION OF DART LEAVING HEAD. - CEMENTERS CHASED DART OUT W ITH 5 BBL OF WATER. - RIG TOOK OVER DISPLACING CEMENT WITH 9.8 PPG BRINE. PUMPED AT 6 BPM WITH 300 PSI TO CATCH UP SLOWING RATE TO 5 BPM WITHIN 10 BBLS OF LATCH UP SEEING NO INDICATION OF LATCH UP. -CONTINUE PUMPING AT 5 BPM WITH 200 PSI TILL PRESSURE INCREASED AT 127 BBLS AWAY TO 460 PSI. CONTINUE PUMPING AT 5 BPM LETTING PRESSURE INCREASE TO 2000 PSI AND SLOWING RATE. - SLOWED TO 0.8 BPM AT 238 BBLS AWAY AND PRESSURE AT 2900 PSI. - AT 254 BBLS AWAY (3 BBLS EARLY FROM BUMPING PLUG) PRESSURE INCREASED AND PIPE JUMPED. THE PRESSURE THEN DROPPED TO 0 PSI. SHUT DOWN PUMPS AND P/U TO STRING WEIGHT AT 250K. PRESSURE UP TO 2700 PSI AND PIPE JUMPED AGAIN, DROPPING PRESSURE TO 2400 PSI AND HOLDING. - CONTINUE PRESSURING UP TO 3300 PSI WITH MUD PUMPS AND HOLDING. R/U AND PRESSURE UP TO 3400 rnmea: riaizuiu a:uu:su rnn ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Event Name: WORKOVER Start: 12/15/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Page 25 of 35 Spud Date: 5/26/1983 End: 1 /21 /2010 Date From - To Hours Task Code NPT Phase Description of Operations 1/12/2010 19:30 - 00:00 4.50 CASE P TIEB2 PSI WITH TEST PUMP SEEING INDICATION OF PUSHER TOOL SETTING. CONTINUE TO PRESSURE UP TO 4500 PSI AND HOLD FOR 5 MIN. - RELEASE PRESSURE AND CHECK FLOATS. -FLOATS HOLDING. - RELEASE FROM LINER RUNNING TOOL. - PICK UP AND CIRCULATED CEMENT OUT OF HOLE ~ 13 BPM WITH 1600 PSI, CLOSE ANNULAR AT 185 BBLS AWAY AND TAKE RETURNS TO SLOP TANK THROUGH IA AT 5 BPM WITH 350 PSI. - 15 BBLS CEMENT SEEN AT SURFACE. - CEMENT IN PLACE AT 2230 HRS. 1/13/2010 00:00 - 01:00 1.00 CASE P TIE62 UD CEMENT HEAD. - CBU AT 12.5 BPM AND 1400 PSI. - MONITOR WELL -STATIC. - BLOW DOWN TOP DRIVE. - PJSM AND POOH. 01:00 - 03:30 2.50 CASE P TIEB2 POH FROM 3900' TO SURFACE. - ALL SHEAR PINS WHERE SHEARED ON LINER RUNNING TOOL. - L/D LINER RUNNING TOOL. 03:30 - 04:30 1.00 CASE P TIE62 PJSM - RUN IN WITH STACK WASHER AND FLUSH STACK. - CLEAN UP LINES AND VALVES FROM CEMENT JOB. 04:30 - 06:00 1.50 CASE P TIE62 PJSM - M/U CLEAN OUT BHA. - BHA CONSISTING OF: 6-1/8" NEW BIT, BOOT BASKETS, CASING SCRAPER, BIT SUB, BUMPER SUB, PUMP OUT SUB, 4-3/4" DRILL COLLARS. 06:00 - 10:00 4.00 CASE P TIE62 PJSM -RIH WITH DP FROM DERRICK. - 0730-Hrs--STAND # 39 RIH. - EASED THROUGH THE LINER TOP AT 3949', BUT DID NOT SEE ANY BOBBLE ON THE WEIGHT INDICATOR. - 0845-Hrs--STAND #75 RIH. - PARK WITH #97 IN THE HOLE, PLACING THE BIT AT 9502'. 10:00 - 11:30 1.50 CASE P TIEB2 PJSM WITH RIG CREW, SITE CONTROL SPOC, AND WSL. SLIP AND CUT DRILLING LINE. -INSPECT TOPDRIVE SAVER SUB. 11:30 - 12:30 1.00 CASE P TIEB2 PJSM. INSTALL CHART RECORDER AND LINE UP TO TEST CASING TO 3500-psi. - SOLID 30-MINUTES, CHART-RECORDED PRESSURE TEST. TESTED 7". 26# CASING FROM -9827' TO 3946' AID THE 9-5/8" CASING FROM 3946' TO SURFACE. - R/D TEST EQUIPMENT AND PREPARE TO CONTINUE RIH TO TAG WIPER PLUG. 12:30 - 23:30 11.00 CASE P TIEB2 P/U STANDS #98, #99, AND #100, SLOWLY RIH WITH EACH TO LOOK FOR HARD TAG. - P/U #101, GET PARAMETERS: P/U WEIGHT, 195K-Ibs; S/O WEIGHT, 134K-Ibs; ROTATING WEIGHT, 162K-Ibs AT 100-RPM AND FREE TORQUE OF 9K-ft-Ibs; PUMPING RATE 9-BPM AT 2470-psi. - STOP PUMPS AND ROTATING AND SLOWLY RIH TO DRY TAG AT 9816' WHICH IS 11' ABOVE THE LANDING COLLAR Printed: Z4/2010 4:00:30 PM ~ ~ BP EXPLORATION Page 26 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task. Code NPT Phase Description of Operations ',1/13/2010 12:30 - 23:30 11.00 CASE P TIEB2 AT 9827. - 1300-Hrs--START PUMPS AND BRING UP TO 9-BPM, 2250-psi. BRING ON TOPDRIVE, ROTATING AT 100-RPM, 7-8K-ft-Ibs, WITH 5K-8K-Ibs-WOB. SLOWLY RIH AND TAG. - 1315-Hrs--DRILL OFF QUICKLY TO HARD DRILLING AT 9827' WHERE THE LANDING COLLAR IS SET. -GET FINE FLAKES OF ALUMINUM WITH CEMENT ACROSS SHAKERS AFTER 540-BBLS PUMPED. - 1347-Hrs--PUMP 20-Bbl HI-VIS SWEEP. - 1835-Hrs--DRILLED DOWN TO 9829' ON THE LANDING COLLAR. - 2000-Hrs--DRILLED DOWN TO 9831' ON CEMENT SEEING CEMENT IN RETURNS. - 2100-Hrs--CONTINUE TO DRILL DOWN 9875' SEEING NO SIGNS OF THE FLOAT COLLAR AT 9868' AND CONTINUED THROUGH AT 9 BPM AND 2100 PSI. - 2200-Hrs--DRILLED DOWN TO 9910' AND TAG UP ON XO. VERIFY TAG. PUMP 20 BBL HI-VIS SWEEP ~ 10 BPM AND 2730 PSI. SMALL AMOUNT OF FINE METAL SHAVINGS SEEN AT SURFACE. - RUN SCAPER 4 TIMES FROM 9684' TO 9784'. 23:30 - 00:00 0.50 CASE P TIEB2 MONITOR WELL -STATIC. - PUMP DRY JOB. - POH. 1/14/2010 00:00 - 02:30 2.50 CASE P TIEB2 POH FROM 9881' TO 309'. - STANDING BACK PIPE IN THE DERRICK. 02:30 - 04:30 2.00 CASE P TIEB2 L/D 4-3/4" DRILL COLLARS AND CLEAN OUT BHA. -CLEAN AND CLEAR RIG FLOOR. 04:30 - 06:00 1.50 CASE P TIE62 PJSM - M/U 3.8" JUNK MILL BHA. 06:00 - 08:30 2.50 CASE N HMAN TIE62 RIH WITH MILL BHA. STOP WITH 30-STANDS AND PUMP THROUGH BIT, BUT BIT IS PLUGGED. R/U TO REVERSE THROUGH MILL, BUT FLOW THROUGH MILL IS INSUFFICIENT TO EFFECTIVELY CLEAN DOWNHOLE DUE TO IT HAVING ONLY 3-EA 3/8" HOLES. - CALL ADW ENGINEER TO DISCUSS REPLACEMENT OF THE MILL TO AS CLOSE TO THE MILL THAT WAS SPECIFIED IN THE ORIGINAL PROGRAM; A 3.80" OD MILL WITH 1-HOLE, 1" OD. 08:30 - 10:30 2.00 CASE N HMAN TIEB2 POH AND S/B DP AND DCs. UPON INSPECTION OF THE 3.80" MILL, IT WAS FOUND THAT THE THREE 3/8" DIAMETER HOLES ACTUALLY FED INTO ONE 3/8" HOLE. 10:30 - 11:30 1.00 CASE N HMAN TIE62 M/U NEW 3.8" MILL WITH FULL 1" HOLE. 11:30 - 18:30 7.00 CASE P TIEB2 RIH WITH 3.80" MILL BHA, PUMPING THROUGH DP EVERY 30-STANDS. - 1300-Hrs--PUMP 30-Bbls AT 3-BPM AND 175-psi. - 1406-Hrs--PUMP 30-Bbls AT 3-BPM AND 300-psi. - 1507-Hrs--PUMP 30-Bbls AT 3-BPM AND 350-psi. - 1615-Hrs--ATTEMPT TO PUMP AND DP IS PLUGGED. TRY MOVING DP RAPIDLY AND STOPPING TO DISLODGE PLUG, WITH NO SUCCESS. - 1630-Hrs--R/U TO REVERSE CIRCULATE. START PUMPING AND IT TAKES 650-psi TO DISLODGE PLUG 18:30 - 00:00 5.50 CASE P TIE62 - 1830-Hrs--DRILLING AHEAD AT 9931' WITH 7 BPM AND Printed: 2/4/2010 4:00:30 PM BP EXPLORATION. Page 27 of 35 Operatiolns Summary Report... Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/14/2010 18:30 - 00:00 5.50 CASE P TIEB2 1750 PSI. 3K WOB. - 1925-Hrs--DRILLING AHEAD AT 9937' SAME PARAMETERS. SEEING PARTS OF WIPER PLUG AND CEMENT AT SHAKERS. - 2030-Hrs--DRILLED DOWN TO 9974' STOPPED. AND CBU AT 8.25 BPH AND 2376 PSI. SEEING CEMENT CUTTINGS AND SMALL AMOUNT OF METAL AND RUBBER. - 2100-Hrs--DRILLED DOWN TO 9977' SEEING A DRILLING BREAK. STOPPED DRILLING AND CBU LOOKING FOR SAND AT 7.6 BPM AND 2050 PSI. SEEING CEMENT CUTTINGS. NO SAND WAS SEEN. - 2230-Hrs--POH TO 7" X 4-1/2" XO. RIH AND DRY TAG TOP AT 9980'. - 2245-Hrs--ATTEMPT TO WASH DOWN WITH NO ROTATION.NOT ABLE TO WASH DOWN. ESTABLISH ROTATION AND DRILL DOWN TO 9988' DRILLING ON CEMENT WHEN BECAME HARD. P/U AND CIRCULATE BOTTOMS UP SEEING ONLY SMALL AMOUNTS OF CEMENT CUTTINGS. 1/15/2010 00:00 - 03:00 3.00 CASE P TIEB2 SHUT DOWN ROTATION AND RIH WASHING TO BOTTOM TAGGING AT 9989' WASHING TO 9990' WITH 10K WOB. P/U WITH 18K OVERPULL AND WORK DOWN TO 9990' STACKING 10K WOB. -P/U AND BEGIN ROTATION AND WORK WAY DOWN 9990' WHEN ROTARY STALLED. P/U TO 230K P/U 42K OVER AND 10K DOWN. CONTINUE TO WORK PIPE SEVERAL TIMES. INCREASING P/U TO 245K. - 0130-Hrs--PUT 10K DOWN AND P/U FREE. - 0200-Hrs--DRILLED DOWN TO 9994' WITH NO WOB NO TORQUE INCREASE. NO BLOCKAGES. - SEEING SMALL AMOUNTS OF CEMENT AT SHAKERS. - 0230-Hrs-- WASHED DOWN TO 9996' WITH NO ROTATION AND NO WOB. SLUGGITS SEEN AT SHAKERS. 12' ABOVE WRP PLUG. 03:00 - 06:30 3.50 CASE P TIEB2 CLEAN PITS AND PREPARE TO DISPLACE TO 8.5 PPG SEAWATER. -PJSM FOR DISPLACEMENT. -DISPLACE WELL TO 8.5 PPG SEAWATER. 06:30 - 11:00 4.50 CASE P TIEB2 PJSM. POH AND S/B DP IN DERRICK. - 9920', SEE TIGHT SPOT AND PULL 10K-Ibs OVER TO GET FREE. - CONTINUE POH AND S/B DP IN DERRICK. - 0930-Hrs--STAND #85 S/B IN DERRICK. - 1015-Hrs--ALL DP S/B IN DERRICK. BREAK OUT AND L/D THE 4-JOINTS OF 2-7/8" HT-PAC DP AND BOOT BASKETS. - THE MILL HAD SEVERAL GOUGES IN THE BODY JUST ABOVE THE CARBIDE BLADES, AND THE CARBIDE WAS WORN IN THE FACES OF THE BLADES. THE BIT SUB JUST ABOVE THE MILL ALSO HAD BODY DAMAGE AT THE CONNECTION FACE AND WILL HAVE TO BE REPLACED. 11:00 - 13:00 2.00 CASE P TIEB2 CLEAR AND CLEAN RIG FLOOR. DUMP OUT AND CLEAN BOOT BASKETS AND PREPARE FOR NEXT RUN WITH AN RCJB. --_ Printed: 2/M2010 4:00:30 PM BP EXPLORATION Page 28 of 35' Operations Surnmary'Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ,Description of Operations 1/15/2010 11:00 - 13:00 2.00 CASE P TIE82 -GET 2-1/2-GALLONS OF DEBRIS FROM THE BOOT 13:00 - 15:00 I 2.001 CASE I P 15:00 - 19:30 4.50 CASE P 19:30 - 00:00 4.50 CASE P ~ 1/16/2010 100:00 - 01:30 1.50 ~ CASE ~ P 01:30 - 03:30 I 2.001 CASE I P 03:30 - 07:30 4.00 CASE P BASKETS; MADE UP OF SCALE, SANDY FINES, CEMENT FINES, SOME SLUGGITS, AND ALUMINUM FLAKES. NO BIG OR UNUSUAL DEBRIS. - WAIT ON API TO SEND OUT ANOTHER BIT SUB VIA TOOLS SERVICES. TIE62 PJSM. - M/U RCJB BHA: 3-3/4" RCJB, 4-JTS 2-7/8" HT-PAC DP, 3-EA BOOT BASKETS, LUBRICATED BUMPER SUB, OIL JARS, AND PUMP-OUT SUB. TIE62 RIH OUT OF DERRICK. TIE62 -ATTEMPT TO BREAK CIRCULATION (REVERSE) AND SAW AN INCREASE IN PRESSURE ~ 3.8 BPM PSI WAS 2200. WHILE CIRCULATING PRESSURE DECREASED. CIRCULATE A B/U LOBBING 300 PSI. SEEING DOPE AND SCALE OVER SHAKERS. CIRCULATE THE LONG WAY TO ENSURE NO PROBLEMS. -2015-Hrs-- RIH OUT OF DERRICK BREAKING CIRCULATION EVERY 20 STANDS. -2200-Hrs--RIH TO 9843' AND BREAK CIRCULATION SEEING AN INCREASE IN PRESSURE. R/U AND REVERSE CIRCULATE A DP VOLUME. PRESSURE DROPPED BY 300 PSI. SEEING PIPE DOPE. -TEMP OF SEAWATER IS 57 DEGREE F. APPLY STEAM TO PITS TO HEAT UP SEAWATER. -PUMP THE LONG WAY TO ENSURE PIPE IS CLEAR. PRESSURE IS 2200 PSI AT 5.5 BBLS. -2250-Hrs--RIH WITH LAST 2 STANDS. TAG ON 9987". -P/U AND DROP BALL PUMP AT 2 BBU MIN 240 PSI. TO GET BALL ON SEAT. TIE62 -CONTINUE TO ATTEMPT TO PUMP BALL ON SEAT. P/U AND DROP PIPE TO ASSIST. -DROP A SECOND BALL AS NO SIGN OF FIRST BALL GOING ON SEAT. -WASH DOWN WITH RCJB FROM 9987' AT 5.8 BPM AND 2120 PSI. STACK 3K WOB. P/U AND SLOWLY ROTATE AT 1 RPM. RIH AND WALK DOWN WHILE SLOWLY ROTATING. P/U AND PULL 10K OVER AT 9984'. PULLED FREE AND P/U TO 9972'. -DISCUSS WITH TOWN ENGINEER AND DECIDED TO POH AND RIH WITH A 3.8" STRING MILL ASSY WITH A BULL NOSE. TIEB2 -BRING ON 100 BBLS OF 130 DEGREE SEAWATER AND BLEND WITH 60 DEGREE SEAWATER IN PITS. -CIRCULATE WARM SEAWATER SURFACE TO SURFACE AT 6 BPM AND 2400 PSI, 70 DEGREE SEAWATER AT SURFACE. SHUT DOWN AND MONITOR WELL -STATIC -PUMP 10 BBL DRY JOB. -PJSM AND POH. TIE62 POOH FROM 9972' TO SURFACE. - 0615-Hrs--ALL DP S/B. BREAK-OFF AND CLEANOUT BOOT BASKETS. FIND -1 QUART OF CEMENT CHUNKS AND A SMALL AMOUNT OF FINE SCALE AND SAND, ALSO Printed: 2/4/2010 4:00:30 PM I BP EXPLORATION Page 29 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task. Code NPT Phase Description of Operations 1/16/2010 03:30 - 07:30 4.00 CASE P TIEB2 ONE CHUNK OF ALUMINUM 2" SQUARE AND 3/8" THICK. - 0630-Hrs--BREAK OFF AND UD THE 4-JTS OF 2-7/8" HT-PAC DP. - 0730-Hrs--BREAK OFF AND CLEAN OUT THE RCJB AND FIND NOTHING INSIDE. - THE SHOE ON THE END OF THE RCJB HAD TWO SEGMENTS THAT WERE ROUNDED AND PUSHED TOWARD THE INSIDE OF THE TUBE. ONE OF THE SEGMENTS WAS FRACTURED AT THE ROOT OF THE CARBIDE CHUNKS WHERE THEY ARE WELDED TO THE BODY OF THE TUBE. 07:30 - 09:00 1.50 CASE P TIEB2 PJSM ON RIG FLOOR TO MAKE UP THE NEXT BHA: - P/U AND M/U A 3-1/8" SMOOTH BULLNOSE TO THE BOTTOM OF A 3.80" SIX-BLADED STRING MILL. - M/U STRING MILL BHA AND RIH ON 4-JOINTS OF 2-7/8" HT-PAC DP. - M/U 3-EA, 4-3/4" BOOT BASKETS AND RIH. - M/U LUBRICATED BUMPER SUB AND OIL JARS AND RIH. 09:00 - 15:30 6.50 CASE P TIEB2 RIH STRING MILL BHA ON DP FROM DERRICK. - 1230-Hrs--STAND #45 RIH. - 1500-Hrs--STAND #95 RIH. 15:30 - 17:30 2.00 CASE P TIEB2 STOP RIH ABOVE THE 7" X 4-1/2" CROSSOVER AND GET PARAMETERS: START PUMP AND BRING UP TO 8-BPM AT 1130-psi. P/U WT 198K-Ibs, S/O WT 131K-Ibs, ROT WT 160K-Ibs, 60-RPM AT 9K-ft-Ibs FREE TORQUE. -SLOWLY RIH AND DO NOT SEE THE CROSSOVER. DRILL DOWN TO 9936' AND REAM BACK OUT WITHOUT SEEING ANY DRAG. DRILL BACK DOWN TO PICK UP STAND #104. - 1600-Hrs--STOP, PICK UP STAND #104 AND START DRILLING AGAIN WITH PUMP RATE AT 7.5-BPM, 1045-psi, 60-RPM. - TAG TIGHT SPOT AT 9987' AND P/U THEN RESUME RIH SLOWLY, DRILLING THROUGH TO 9999'. DO NOT SEE ANYTHING OVER THE SHAKERS OTHER THAN TINY, MUSHY BALLS OF BLACK SUBSTANCE DURING ANY OF THE MILLING OPERATION. - REAM OUT ALL THE WAY TO 9960'. - 1630-Hrs--CALL SLICKLINE LEADER AT PBOC TO VERIFY THE DEPT DEFINITIVE ANSWER OTHER THAN THE ORIGINAL DEPTH MAY HAVE BEEN TAKEN BACK TO THE ULDSs, WHICH PLACES THE WRP 22' LOWER OR AT 10030' - 1700-Hrs--CONTINUE SLOWLY RIH AND MAKE IT TO 10005'. STILL NOT SEEING ANYTHING OTHER THAN FLUID OVER THE SHAKERS. - 1710-Hrs--PRESSURE SPIKES QUICKLY TO OPEN PUMP POP-OFF AND SEE -8-10K-Ibs FALL OFF. IMMEDIATELY P/U OFF OBSTRUCTION AT 10008' WHICH IS THE SLICKLINE MD OF THE WRP. - CALLED ADW ENGINEER TO REPORT THAT WE FOUND THE TOP OF THE WRP WITH THE SMOOTH BULLNOSE OF THE BHA. -PUMP SWEEP AND WAIT FOR RETURNS ACROSS Printed: 2/4/2010 4:00:30 PM BP EXPLORATION Page 30 of,35 Operations Summall•y Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/16/2010 15:30 - 17:30 2.00 CASE P TIEB2 SHAKERS. 17:30 - 19:00 1.50 CASE P TIEB2 PUMP 20-Bbl HI-VIS SWEEP, 7.5-BPM AT 1100-psi. THE FLUID STAYED CLEAR COMING ACROSS THE SHAKERS WHEN THE SWEEP RETURNED. ONLY A FEW SMALL PIECES OF RUBBER WERE SEEN. -RIH AT 80 RPM WITH 8K TO. TO POLISH FROM 9998' TO 9938'. WITH NO PROBLEMS OR OBSTRUCTIONS. -PUMP DRY JOB. 19:00 - 23:00 4.00 CASE P TIEB2 POOH FROM 9938' TO 175' -CLEAN OUT BOOT BASKETS. BOOT BASKETS FULL OF SLUGGITS, SMALL CHUNKS OF CEMENT ABOUT 1/4" ROUND, SMALL BITS OF RUBBER. 3 GALLONS OF A 5 GALLON BUCKET. 23:00 - 00:00 1.00 CASE P TIEB2 L/D BHA. -CUTTING BLADES ON MILL - 1/4" DEEP GROOVES AND A CHUNK WAS MISSING. BOX WAS MUSHROOMED ON MILL, TAKING 12K TORQUE TO BREAK. -BULL NOSE WAS IN GOOD CONDITION. NO DAMAGE SEEN. 1/17/2010 100:00 - 01:30 I 1.501 CASE I P 01:30 - 07:00 I 5.501 CASE I P 07:00 - 10:30 I 3.501 CASE I P TIEB2 L/D STRING MILL. -CLEAN AND CLEAR RIG FLOOR. PJSM FOR M/U BHA. -M/U RCJB BHA SAME COMPONENTS AS PRIOR RUN. TIEB2 RIH FROM 179' TO 9980' -CIRCULATE DP VOLUME EVERY 30 STANDS. -0300-Hrs--KELLEY UP AND ROTATE BY 7" LINER TOP AT 3949'. -0530-Hrs--90-STANDS RIH. ATTEMPT TO CIRCULATE, BUT NO SUCCESS. R/U TO REVERSE CIRCULATE WITH SUCCESS. TIE62 -0700-Hrs--DROP BALL TO USE RCJB WHILE RIH. ATTEMPT TO CIRCULATE ON STAND #103, BUT CAN'T. S/B STAND #103 AND R/U TO REVERSE CIRCULATE. -0730-Hrs--REVERSE CIRCULATE 25-Bbls AT 4-BPM AND 430-psi, WITH BOTTOM OF RCJB AT 9845'. -0830-Hrs--CIRCULATE LONG WAY AND PIPE IS CLEAR. B/O TOP-DRIVE, P/U STAND #103, M/U TO STRING, M/U TOP-DRIVE. GET PARAMETERS: P/U WT 136K-Ibs, S/O WT 192K-Ibs, 20-RPM, 7K-ft-Ibs, 4-BPM, 1180-psi. -0900-Hrs--STOP ROTATING AND RIH, WASHING DOWN, BUT PRESSURE INDICATES ANOTHER BLOCKAGE. STOP PUMP, RE-ALIGN VALVES, AND REVERSE CIRCULATE 25-Bbls. -0920-Hrs--RE-ALIGN VALVES AND BEGIN TO WASHDOWN SLOWLY WITH STAND #103 FROM 9845'. SEE THE 7" X 4-1/2" XO AT 9908', DPM. STOP, P/U AND RESUME RIH AND SLIDE THROUGH WITHOUT SEEING A BOBBLE. -0945-Hrs--GET TO 9940'. STOP PUMP, B/O TOP-DRIVE, P/U STAND #104, M/U TOP-DRIVE, BRING PUMP UP TO 5-BPM AT 1500-psi. CONTINUE RIH SLOWLY WASHING DOWN AND SEE TIGHT SPOT FROM 9985' TO 9987', DPM. APPROACH THE WRP TO WITHIN 3' OR 10,005' DPM, WRP AT 10,008' DPM. -0955-Hrs--STOP AND CIRCULATE THROUGH RCJB FROM Printed: 2/4/2010 4:00:30 PM • • BP EXPLORATION Page 31 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/17/2010 07:00 - 10:30 3.50 CASE P TIEB2 10,005', 5-BPM AT 1670-psi FOR 25-Bbls. -1000-Hrs--STOP PUMP AND START POH. SEE DRAG AT 9999' AND GET TO OVERPULL OF 24K-Ibs. STOP POH, SLACK OFF, BRING PUMP UP TO 5-BPM AND RESUME POH WITH 5-10-K-Ibs DRAG FROM 9999' TO 9985'. CONTINUE POH TO BREAK OFF STAND #104. -1020-Hrs--POH AND BREAK OFF STAND #104 AND #103. DROP PUMP-OUT SUB DART AND SEE SHEAR AT 2200-psi. CBU, 10-BPM AT 2190-psi. 10:30 - 11:30 1.00 CASE P TIE62 CBU 10-BPM AT 2200-psi FOR 380-Bbls. SAW SOME PARAFFIN-LIKE MATERIAL OVER THE SHAKERS, BUT NOTHING ELSE, OTHER THAN THE FLUID IS GETTING VERY DIRTY. WILL PLAN TO SWAP FLUID BEFORE LATCHING ONTO THE WRP. -1115-Hrs--R/U TO BLOWDOWNTQP-DRIVE; GET READY TO POH AND S/B DP IN DERRICK. -MIX AND PUMP DRY JOB. 11:30 - 12:00 0.50 CASE P TIEB2 CREW CHANGE. PJSM FOR POH AND S/B DP IN DERRICK. 12:00 - 17:00 5.00 CASE P TIEB2 POH AND S/B DP IN DERRICK. -1250-Hrs--STAND #25 POH. DID NOT SEE ANY DRAG WITH THE FIRST 25-STANDS POH. -1350-Hrs--STAND #55 POH. SAW NO DRAG WHILE POH. -1430-Hrs--STAND #82 POH. SAW NO DRAG WHILE POH. -1530-Hrs--AT BOOT BASKETS. GET -1-GALLON OF SMALL CEMENT CHUNKS AND OTHER FINE DEBRIS. ONE PIECE OF ALUMINUM, 1"SQUARE AND 3/8" THICK. -1600-Hrs--BREAK OFF AND UD 2-7/8" HT-PAC DP. -1630-Hrs--BREAK OFF AND EMPTY THE RCJB, BUT GET ONLY A HANDFULL OF FINE DEBRIS. FIND A 1/8" THICK PIECE OF ALUMINUM 1-1/2" BY 3/4". THE CIRCULATING PORTS IN THE PUMP-OUT SUB APPEARED TO HAVE BEEN DRAGGING SOMETHING UPHOLE. HAD SMALL INDENTATIONS BELOW THE BOTTOM OF TWO OF THE PORTS. 17:00 - 17:30 0.50 CASE P TIE62 CLEAR AND CLEAN RIG FLOOR. 17:30 - 18:30 1.00 CASE P TIEB2 R/U EQUIPMENT FOR TESTING BOPE. -PULL WEAR RING. -INSTALL TEST PLUG. -R/U CHART RECORDER AND HOSES. 18:30 - 23:30 5.00 CASE P TIE62 PJSM TEST BOPE. -TEST BOPE TO 250-PSI LOW, 3500-PSI HIGH PER BP AND AOGCC BEGS. -TEST 3 1/2" X 6" VBR'S WITH 4" AND 4-1/2" TEST JOINTS. TEST ANNULAR WITH 4" TEST JOINT. -AOGCC REP JOHN CRISP WAIVED WITNESS OF BOP TEST, 24 HR NOTICE GIVEN. TEST WITNESSED BY WSL AND DOYON TOOLPUSHER. -HOLD AND CHART ALL TESTS FOR 5-MINUTES. -EMPTY AND CLEAN PITS FOR DISPLACEMENT. 23:30 - 00:00 0.50 CASE P TIE62. R/D BOPE TEST EQUIPMENT. -R/D CHART RECORDER. -UD TEST JOINTS. 1/18/2010 00:00 - 01:00 1.00 CASE P TIEB2 R/D FROM BOPE TEST. Printed: 2/4/2010 4:00:30 PM BP EXPLORATION Page 32 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: I Date From - To Hours Task. Code NPT Phase Description of Operations 1/18/2010 00:00 - 01:00 1.00 CASE P TIEB2 -B/D CHOKE AND KILL LINES. -PULL TEST PLUG. -INSTALL WEAR RING - 8-3/4" ID. -FILL PITS WITH CLEAN 8.5 PPG SEAWATER. 01:00 - 02:00 1.00 CASE P TIE62 PJSM - M/U BHA. -BHA CONSISTS OF: WRP RETRIEVAL TOOL, XO, HTPAC 1 JAR, M OUT SUB. 02:00 - 02:30 0.50 CASE P TIEB2 RIH ON DP FROM 155' TO 1245' -RIH WITH DP OUT OF DERRICK. 02:30 - 03:00 0.50 CASE P TIE62 HOLD H2S DRILL WITH CREW, TOOL PUSHER, WSL, BAKER FISHING AND CH2MHILL TRUCK DRIVER. -THE TOOL PUSHER ACTIVATED THE H2S ALARM. DRILLER AND HANDS RESPONDED, DONNING THE SUPPLIED AIR PACKS AND SECURING THE WELL. ALL PERSONNEL WHERE ACCOUNTED FOR. -ONCE HEAD COUNT WAS DONE AND DRILL COMPLETED, AN AFTER ACTION REVIEW WAS HELD. DISCUSSING WHAT WENT RIGHT AND WHAT COULD BE IMPROVED. LESSONS LEARNED FROM THE DRILL WILL BE DISCUSSED AT THE WEEKLY SAFETY MEETING. 03:00 - 07:00 4.00 CASE P TIE62 RIH ON DP FROM 1245' -0430-Hrs--STAND #51 BREAK CIRCULATION AND CIRCULATE A DP VOLUME. -0600-Hrs--STAND #85 POH. -PARK WRP COLIETT RETRIEVAL TOOL AT 9832' TO PREPARE TO SLIP AND CUT DRILLING LINE. 07:00 - 09:30 2.50 CASE P TIE62 PJSM. SLIP AND CUT DRILLING LINE. INSPECT TOPDRIVE AND FIND A SAFETY WIRE IN A BOLT ON THE IBOP ACTUATOR THAT WASN'T PROPERLY TIED. REMOVE, REINSERT AND CORRECTLY TIE-OFF THE WIRE. 09:30 - 10:00 0.50 CASE P TIE62 GET PARAMETERS: P/U WT 196K-Ibs, S/O WT 135K-Ibs. EASE INTO THE CROSSOVER AT 9911', AND SEE ABOUT 2K-Ibs AS THE COLLETT LATCH TOOL WENT THROUGH IT, THEN THE WEIGHT CAME BACK TO 135K-Ibs. CIRCULATE THROUGH TOPDRIVE, 4-BPM AT 360-psi AND SLOWLY RIH TO 10,005' AND PARK THERE TO BEGIN DISPLACEMENT TO CLEAN SEAWATER. 10:00 - 10:30 0.50 CASE P TIE62 PJSM WITH 4 CH2MHill DRIVERS AND PUSHER, RIG CREW, TOOLPUSHER, BAKER FISHERMAN, AND WSL TO DISCUSS THE FLUID SWAP. PRIMARY SAFETY CONCERNS ARE: EXTREME COLD (-38F), COMMUNICATIONS, SPILL PREVENTION, SLIPPERY SURFACES. NO ONE WAS EXEMPTED FROM CONTRIBUTING TO THE PJSM. 10:30 - 12:15 1.75 CASE P TIEB2 CIRCULATE THE DISPLACEMENT THE LONG WAY TO REMOVE A PLUG ENCOUNTERED WHEN WE TRIED TO REVERSE CIRCULATE. PUMP AT 5-BPM, 650-psi FOR 528-Bbls UNTIL FLUIDS ACROSS SHAKERS WERE CLEAR. -NOTE: TOTAL PIPE IN PIPE SHED FOR COMPLETION---243-Jts OF "BARE" 4-1/2", 12.6#, 13Cr85; 1 WLEG WITH XN-NIPPLE ASSY; 3-EA X-NIPPLE ASSYs; 5-EA GLM ASSYs; BAKER S3 PACKER ASSY. -228-JOINTS OF "BARE" 4-1/2" TUBING NEEDED FOR THE Printed: 2/4/2010 4:00:30 PM BP EXPLORATION Page;.33 of 35 Operations Summary-Reporf (Legal Well Name: 13-27 (Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 1/18/2010 10:30 - 12:15 1.75 CASE P TIE62 COMPLETION. 12:15 - 14:30 2.25 CASE P TIE62 REALIGN VALVES TO REVERSE CIRCULATE. CLOSE 14:30 - 15:00 0.50 CASE P 15:00 - 16:30 1.50 CASE P 16:30 - 23:30 7.00 CASE P 23:30 - 00:00 0.501 CASE P 1/19/2010 00:00 - 01:30 1.50 CASE P 01:30 - 02:30 1.00 CASE P 02:30 - 06:00 3.50 06:00 - 06:30 I 0.501 RU HYDRIL AND BRING ON PUMP TO 3-BPM, 220-psi. SLOWLY RIH TO GET -2' ABOVE WRP TO REVERSE CIRCULATE DEBRIS OFF THE WRP. -STOP AT 10.007' AND REVERSE CIRCULATE 4-BPM AT 650- si FOR 172-Bbls, A LITTLE OVER 1-1/2 DP VOLUME. -SLOW PUMP TO 3-BPM, 340-psi; SLACK OFF AND SEE PRESSURE START TO INCREASE WHEN RETRIEVING TOOL IS AT 10,008'. CONTINUE RIH AND STACK OUT 5K-Ibs. -P/U TO CONFIRM LATCH, BUT DO NOT SEE INCREASE ABOVE 200K-Ibs. -1335-Hrs--PUMP LONG WAY 6-BPM AT 850-psi AND SLOWLY LOWER. SEE STACK OUT IN SAME SPOT AS PRESSURE INCREASES TO 1000-psi. -SET DOWN 10K, BUT DON'T SEE FLUID LEVEL DROP INDICATING ELEMENT HAS RELAXED. -1350-Hrs--P/U AND SEE 15K-Ibs OVERPULL. SET DOWN AND GET 2' DEEPER TO 10,010' WITHOUT SEEING STACK OUT OF W EIGHT. -P/U 8' TO LET ELEMENT RELAX, BUT FLUID LEVEL DOES NOT DROP. WAIT 10-MINUTES. -1410-Hrs--P/U AND FLUID LEVEL DROPS 3". CONTINUE POH FOR 10'. STOP AND RIH TO 10,018'. DO NOT SEE ANY SETDOWN WEIGHT. TIEB2 POH TO UD A SINGLE AND S/B 2-STANDS OF DP TO PLACE THE WRP AT 9830'. TIE62 CBU TO CLEAR ANY TRAPPED PRESSURE FROM UNDER THE WRP; PUMP 7-BPM AT 940-psi_, -1600-Hrs--MONITOR WELL FOR 30-MINUTES. TIE62 PJSM AND POH FROM 9830' TO 2521' (238 JTS) -HOLE TAKING CALCULATED FILL. -UD 4" DRILL PIPE WHILE POH. -SPR, #1 = 190 PSI f~ 30 SPM, 460 PSI ~ 40 SPM. #2 = 300 PSI ~ 30 SPM, 600 PSI (~ 40 SPM TIE62 CLEAN RIG FLOOR. -P/U THREAD PROTECTORS. -HOLD TABLE TOP RIG EVACUATION DRILL. TIE62 PJSM POH FROM 2521' TO 155'.. -UD DRILL PIPE. TIE62 POH UD BHA. -UD 4 JOINTS OF 2-7/8" PAC DP. -UD WRP. RUNCMP CLEAN AND CLEAR RIG FLOOR. -PULL WEAR RING. -P/U 4-1/2" COMPLETION EQUIPMENT. -R/U POWER TONGS. -R/U SINGLE JOINT COMPENSATOR. -ALLOW EQUIPMENT TO WARM UP AND INPSECT PRIOR TO USE. RUNCMP PJSM WITH RIG CREW, DOYON CASING TECHNICIAN, BAKER COMPLETIONS TECHNICIAN, AND WSL TO COVER Printetl: 2/4/2070 4:00:30 PM • ~ • BP EXPLORATION Page 34 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: .Date From - To Hours Task Code NPT Phase Description of Operations 1/19/2010 106:00 - 06:30 I 0.50 06:30 - 00:00 I 17.501 RUN 1 /20/2010 100:00 - 01:30 I 1.50 01:30 - 03:00 I 1.50 03:00 - 06:30 3.50 06:30 - 08:30 I 2.00 08:30 - 09:00 ~ 0.50 ~ RU 09:00 - 10:30 I 1.501 WHSUR I P RUNCMP THE COMPLETION OPERATION WITH SPECIAL EMPHASIS ON DROPPED OBJECTS. RUNCMP P/U WLEG / XN-NIPPLE ASSY AND DOUBLE-CHECK CALIPER OD OF WLEG AT 4.950". P/U BAKERLOK'D SINGLE JOINT AND BAKERLOK TO THE WLEG/XN-NIPPLE ASSY AND RIH. P/U X-NIPPLE ASSY #1, BAKERLOK IT TO STRING AND RIH. -0700-Hrs--P/U BAKER PACKER ASSY, UNWRAP THE PACKER AND INSPECT FOR DAMAGE. BAKERLOK THE ASSY TO THE X-NIPPLE ASSY AND RIH. -0715-Hrs--P/U MX-NIPPLE ASSY #2 AND RIH ON TOP OF PACKER ASSY. CONTINUE RIH WITH 4-1/2", 12.6#, 13Cr80, VAM TOP, USING JET LUBE SEALGUARD PIPE DOPE ON ALL JOINTS AND TORQUE TURNING TO 4440-Ib-ft. -2330-Hrs--CHANGE OUT JOINT 210 FOR JOINT 230. BOTH JOINTS ARE THE EXACT SAME LENGTH. CROSS THREADED. RUNCMP CONTINUE RIH WITH 4-1/2", 12.6#, 13Cr80, VAM TOP, USING JET LURE SEALGUARD PIPE DOPE ON ALL JOINTS AND TORQUE TURNING TO 4440-Ib-ft. -0010-Hrs--REPLACE JOINT #211 WITH JOINT #231. BOTH JOINTS THE SAME LENGTH. CROSS THREADED. -BEGIN CLEANING BOTH BOX AND PIN. -0130-Hrs--JOINT 228 RIH. -123K DOWN WEIGHT, 155K UP WEIGHT. RUNCMP -PJSM FOR P/U HANGER AND DISPLACEMENT. -R/D COMPENSATOR. -M/U HANGER. -0251-Hrs--LAND HANGER AT 22' IN. -RUN IN LOCK DOWN SCREWS. RUNCMP R/U LINES AND REVERSE CIRCULATE TUBING VOLUME OF CLEAN 8.5 PPG SEAWATER AT 120 DEGREE. -CHASE WITH 290 BBLS OF 8.5 PPG SEAWATER AND CORROSION INHIBITOR AT 120 DEGREE. -CHASE WITH 30 BBLS OF 8.5 PPG CLEAN SEAWATER AT 120 DEGREE. -3 BPM ~ 160 PSI. RUNCMP R P B & R D AND ALLOW TO FALL FOR 10-MINUTES. -PRESSURE UP AND SET PACKER. -TEST TUBING TO 3500-PSI FOR 30-CHARTED MINUTES. GOOD TEST. -BLEED TUBING PRESSURE TO 1500-PSI AND SHUT IN. -TEST IA TO 3500-PSI FOR 30-CHARTED MINUTES. GOOD TEST. -BLEED TUBING DOWN TO OPSI AND SHEAR THE DCR VALVE. -PUMP DOWN TBG f~ 36PM AND 160 PSI, AND DOWN IA AT 3 BPM AND AT 350 PSI. CONFIRMING SHEAR. RUNCMP BLOW DOWN AND RD LINES. -LD LANDING JT. RUNCMP PJSM ON SETTING & TESTING TWC WITH RIG CREW, Printed: 2/4/2010 4:00:30 PM a ~ • BP EXPLORATION'. Page 35 of 35 Operations Summary Report Legal Well Name: 13-27 Common Well Name: 13-27 Spud Date: 5/26/1983 Event Name: WORKOVER Start: 12/15/2009 End: 1/21/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 1/21/2010 Rig Name: DOYON 16 Rig Number: Date From - To Hours .Task Code NPT Phase Description of Operations 11/20/2010 109:00 - 10:30 I 1.501 WHSUR I P 10:30 - 11:00 0.50 WHSUR P 11:00 - 13:30 2.50 BOPSU P 13:30 - 15:30 2.00 WHSUR P 15:30 - 17:30 2.00 WHSUR P 17:30 - 19:00 1.501 WHSUR P 19:00 - 22:30 3.501 WHSUR P 22:30 - 00:00 1.501 WHSUR P 1/21/2010 100:00 - 03:00 I 3.001 WHSUR I P RUNCMP DOYON TOOLPUSHER, BP WSL AND FMC TECH. -DISCUSS DROPPED OBJECT POTENTIALS, HAZARDS ASSOCIATED WITH HIGH PRESSURE TESTING AND PROCEDURE FOR SETTING & TESTING TWC. -PU T BAR. MU RUNNING TOOL AND TWC. -SET TWC. LD T BAR. -TEST TWC ABOVE TO 3500-PSI FOR 10-CHARTED MINUTES. GOOD TEST. -TEST TWC BELOW TO 1000-PSI FOR 10-CHARTED MINUTES. GOOD TEST. RUNCMP RD AND BLOW DOWN LINES USED FOR PRESSURE TESTS. ,(Jo+ RUNCMP HOLD PJSM ON ND BOP STACK. -BARRIERS ARE: TESTED TWC BALL ON SEAT r -DRAIN BOP STACK. -REMOVE RISER AND TURNBUCKLES. -STAND BOP STACK BACK ON PEDESTAL. RUNCMP NU ADAPTER FLANGE AND TREE. RUNCMP FMC TECH TEST ADAPTER FLANGE / TBG HANGER TO 5000-PSI FOR 30-MINUTES. GOOD TEST. -RU AND TEST NEW TREE USING DIESEL TO 5000-PSI FOR 10-CHARTED MINUTES. -RD TESTING EQUIPMENT. RUNCMP HOLD PJSM ON PULLING TWC WITH LUBRICATOR. -PU DSM LUBRICATOR AND PRESSURE TEST TO 500-PSI. GOOD TEST. -DSM PULL TWC. RUNCMP R/U TO REVERSE IN 90 DEGREE DIESEL. -PJSM FOR PUMPING DIESEL WITH LRS. -PUMP 145 BBLS OF DIESEL AT 3 BPM. -ALLOW TO U-TUBE FOR 1 HOUR. RUNCMP -PJSM FOR INSTALLING BPV. -R/U LUBRICATER AND TEST TO 500 PSI. GOOD TEST -INSTALL BPV. -TEST BPV FROM ABOVE AND BELOW TO 1000 PSI FOR 10 MIN. GOOD TEST. RUNCMP L/D DSM LUBRICATOR. -R/U VALVES ON TREE. -SUCK OUT AND CLEAN CELLAR BOX. -SECURE WELL. -RELEASE RIG AT 0300 Hrs. Printed: 2/4/2010 4:00:30 PM TREE = cIW WELLHEA~ = FMC ACTUATOR = AXELSON KE.° ELEV = 83' BF. ELEV KOP = 2800' Max Angle = 97 @ 11087 Datum MD = 10297' Datum TV D = 8800' SS • DRLG DRAFT 9-518" 47#, L-80 from 1867' to Surface- 13-3/8" CSG, 72#, L-80 BUTT, ID = 12.347" 26~ 4-1 f2" HES X-NIP, 3,813" ID--9719` - 4-112" HES X-NIP, 3.813" ID--9784` 7" 26# L-80 scab liner cmt'd 9912' to 3949` XQ 7", 26# x 4-1/2", 12.6# --9910` Minimum ID = 2.441" @ 10044' TOP OF 2-7/8" LINER 13-27A f 2036` 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3686 3651 23 MMG DCR RKP 0 01/15/10 4 6421 5755 43 KBG2* DMY BK 0 01/15/10 3 8199 7098 38 KBG2* DMY BK 0 01/15/10 2 9189 7902 32 KBG2* DMY BK 0 01/15/10 1 9641 8292 28 KBG2* DMY BK 0 01/15/10 SPECIAL CLEARANCE 949`--Top of 7", 26#, L-80 Liner \\ 3961 `--Baker ZXP Liner Tap Packer 968`--Baker 7" Flexlack Liner Hanger =-4-112" x 7" Baker S3 Packer ~___.-9857`--4-1 /2" HES XN-NIP, 3.725" iD, _---- 9867`--4-1 /2" 12.6#, 13Cr-85 VamTop tbg 9868`--4-1/2" Unique Machine WLEG 9970' 5-1/2" BKR PBR ASSY, ID = ?~ 9984' 5-1/2" K ANCHOR, ID = 4.875" 9985' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.75" 9997' I~ 7" X 4-1 /2" XO, ID = 3.958" TOP OF 7" LNR ~-~ 10038' TOP OF 2-7/8" LNR ~-~ 10044' ~~ 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" I~ 7" WHIPSTOCK 10440 PERFORATION SUMMARY REF LOG: BHCS ON 06/07/83 ANGLE AT TOP PERF: 97 @ 11035' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 11035 - 11135 O 03/22/01 2" 4 11150 - 11250 O 03/22/01 2-1/8" 4 11450- 11498 O 09/29/97 2-7/8" 4 11450 - 11650 O 10/05/97 2-1/8" 4 11509 - 11513 O 09/29/97 2-1/8" 4 11850 - 12150 O 06/02/97 2-1/8" 4 12400 - 12630 O 06/02/97 10044' ~ TOP OF LNR (46" SECTIOIN PULLED OUT AND TAGGED 09/04/03) 10044' 3-1/2" X 2-7/8" XO, ID = 2.441" 10088 4-1/2" OTIS XN NIP, ID = 3.72" 10099 4-1/2" BROWN SHEAROUT SUB BEHIND CT LNR 10100' 4-1/2" TUBING TAII, ID = 3.958" -~ ELMD TT NOT LOGGED MILLOUT WINDOW (13-27A) 10457' - ?' 12626' ~-( FISH - CIBP PUSHED TO BTM 03/02/99 PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10687` d- 2-7/8" LNR 6.5#, L-80 FL4S, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/29/83 ORIGINAL COMPLETION 01/21/10 D16 RWO 07/28/87 SIDETRACKED (13-27A) 01/25/10 TLH DRLG HO CORRECTIONS 02/09/02 RNITP CORRECTIONS 11/22/07 PJC DRAWING CORRECTIONS 06/13/09 006/TLH PKR DESC/ 1997 ADPERFS 09/10/09 JCMITLH PLUG PULL / SET WRP (08/17/09) PRUDHOE BAY UNfr WELL: 13-27A PERMfI' No: 1961210 API. No: 50-029-20949-01 SEC 14, T10N, R14E, 596.47' FEL & 4889.41' FNL BP Exploration (Alaska) sehl~u~nb~rger ~ska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage,AK 99503-2838 TN: Beth Well Job # NO. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 02-31 A 17-09 12-30 17-09 13-27A 8146-00087 B3S0-00042 B9RH-00003 AWJB-00047 BALL-00009 SCMT - ~ - TBG. CUT/FLOW DETECTION _ LDL ~ C MEM LDL USIT 12/24/09 01/05!10 12/26/09 01/03/10 1 1 1 1 1 1 1 1 JX-02A MPJ-19A L-103 W-217 12-05AL7 V-224 D-14A 11-27 AWJI-00065 AP3Q-00075 BALL-00010 AYKP-00056 B2NJ-00025 AYKP-00059 AWJI-00060 AP3Q-00068 MEM LDL - USIT RST/WFL - C CH EDIT PDC USIT _ MCNL CH EDIT PDC USIT MCNL - C ~ RST 'jj - 12/31/09 12/29/09 12/29/09 01/06/10 11/27/09 09/29/09 12/14/09 11/15/09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 3-27/M-33 88K5-00012 ~ RST 11/06/09 11/18/09 1 1 1 1 ASE ACKNOWLEDGE REC EIPT sY str;Nttu r, eNn aaT~ ionuur_ nue rnov e.r.., T... :xploration (Alaska) Inc. technical Data Center LR2-1 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~~~~ ~~13 s ~ ~~~~i /~ ~~ • � , � `^ji i ; G � ` ¢ ,. � kl SEAN PARNELL, GOVERNOR P P I LL L [All i� ALASIrLAL OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. David C. Reern Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-27A Sundry Number: 309-415 DE Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, O 0 7 ' 4issio om DATED this, day of December, 2009 Encl. • STATE OF ALASKA A �'Ib' _Ids � r � r ALASKAIL AND GAS CONSERVATION CdMMIAN CE1 Y E Is,4? APPLICATION FOR SUNDRY APPROVAL DEC 1 C M9 20 AAC 25.280 1. Type of Request: Alaska Oil & 683 Cons. COMMissi . ❑ Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Re -Enter Suspend I OrB,$ ® Alter Casing - ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Specify: ❑ Change Approved Program .® Pull Tubing ❑ Perforate New Pool ❑ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 196 - 121 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20949 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13 -27A 1 Spacing Exception Required? []Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028315 - I Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12672' - 9057' - 1 12640' 9058' 10008' 12626' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' ' Surface 2633' 13 -3/8" 2633' 2633' 4930 2670 Intermediate 10322' 9 -5/8" 10322' 8905' 6870 4760 Production Liner 415' 7" 10038'- 10453' 8648'-9023' 8160 7020 Liner 2628' 2 -7/8" 10044'- 12672' 8 9057' 1 10570 1 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 11036-1 9058'- 9058' 4 -1/2 ", 12.6# L -80 10100' Packers and SSSV Type: 9 -5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV 9985'/8600' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: December 15, 2009 ® Oil - ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date: ❑ WINJ ❑ GINJ ❑ WAG ❑ Plugged ❑ SPLUG Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca 5645444 Printed Name David Reem Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564 -5743 Date f Dg 2o0 Terrie Hubble, 564 -4628 Commission Use Onl Conditions of approval: Ijl Commission so that a representative may witness Sundry Number: J L ❑ Plug Integrity V3 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: � ,t 2 1 0 .5 L 14 h 1 G,S Subsequent Form Required: APPROVED BY �� ,► Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revised (k7/2CAO Submit Duplicate /� 4 2� �- RIB R I G f A L Obp GP 4 13 -27A Rig Workover (Repair IA x OA communication and PC leak) Scope of Work: Pull 4.5" L -80 completion. Run & cement 7" 26# L -80 scab liner from 9900- 4000'. Run USIT log to find TOC, cut and pull 9 -5/8" casing as deep as possible. Tie back 9 -5/8" casing, and cement to surface. Replace 9 -5/8" packoff and hanger. Run 4.5" 13Cr -80 completion. Engineer: Hank Baca MASP: 2420 psi Well Type: Producer Estimated Start Date: December 15th, 2009 F 1 Fluid -pack wellbore and obtain LLR data on IA @ 500 & 1000 psi to update 2007 LLR data. No need to test OA S 2 Dump 20' of sluggits on top of WRP plug at 10,008'. Run memory LDL to confirm packer/WRP are barriers to the formation cA ,00) sT GM iT E 3 Power Jet cut tubing @ - 9,931'. Reference tubing tally dated 7/26/87. Cut desired to be 10' down first full joint above packer F 4 Circulate well with 9.8 ppg brine and freeze protect to 2000'. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage check one at a time). PPPOT -T & IC. V 6 Set a BPV in the tubing hanger. O 7 Remove the well house & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. NU and test BOPE to 250 psi low/ 3500si high. Three preventer stack consists of annular, blinds, and 3 -1/2" x 6" variable rams. Circulate out freeze protection and circulate 9.8 ppg brine. 2. Pull and LD tubing to the cut. 3. Pull /jar seals out of PBR 4. PU 9.625" RTTS & RIH to - 3500'. Test above RTTS to 3500 psi for 30 minutes to determine top of leak and scab liner top. Continue to RIH w/ RTTS to 9900' and test WRP /packer to 3500 psi for 10 minutes to verify they're holding 5. Run 7 ", 26 #, L -80 scab from -9900'- 4000'. 6. Cement 7" liner, set liner hanger and packer 7. Drill out 7" float equipment. 8. Test 7" scab liner to 3500 psi for 30 charted minutes. 9. RU wireline and run USIT from cut to surface. 10. Run 9 - / RBP and set -100' below TOC determined from USIT. Test RBP to 1000 psi to prove plug is set. Dump -50 ft of sand on RBP. 11. Mechanically cut 9- 5 /8' casing in 1 St full joint above top of cement. Pull casing thru stack. Dress -off 9- 5 / stub in preparation of casing overshot. Note: VBR's will not be changed to 9 - / pipe rams as the well has 2 tested barriers (RBP & packer/WRP) to the reservoir. 12. Run 9 5 / ", 47 #, L -80 casing and land on emergency slips with new primary pack -off. Test 9- 5 / a " pack - off to 3500 psi. 13. Cement 9 - / casing to surface • 14. Drill out 9 -5/8" 15. Run RCJB to clean out above 9-%" RBP. Test 9 -5/8" tieback to 3500 psi for 30 minutes. 16. Pull 9-%" RBP. 17. Pull WRP @ 10,008' 18. Run 4 -'/2" 13Cr -80 completion 19. Displace the IA to packer fluid and set the packer. 20. Test tubing and IA to 3500 psi. Freeze protect to 2,000' MD. 21. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE _ , FMC GEN 3 STES: IA x OA COMMUNICATION TO AlL. 4CTUATO = FMC 13-27A 7°° @ 5'. ACTUATOR = AXELSON KB. ELEV = 83' BF. ELEV = ? KOP = 2800 2196 4 -1/2" CAM BA L-0 SSSV NIP, ID = 3.81" Max Angle = 97 @ 11087' Datum MD = 10297' GAS LIFT MANDRELS Datum M D = 88 97' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2859 2857 r 12 TGPD DMY RK 0 11/19/07 * *2 5095 4776 42 TGPD DMY RK 0 09/03/03 3 6905 6111 42 TGPD DMY TG 0 08/19/02 13 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" 2634' 4 8136 7049 39 TGPD DMY RK 0 09/03/03 5 8808 7585 35 TGPD DMY TG 0 08/19/02 6 9034 7771 34 TGPD DMY TG 0 08/19/02 * *7 9380 8063 31 TGPD DMY RK 0 09/03/03 8 9609 8263 28 TGPD DMY TG 0 08/19/02 Minimum ID = 2.441" @ 10044' 9 9718 8360 27 TGPD DMY TG 0 08/19/02 TOP OF 2 -7/8" LINER 10 9829 8456 26 TGPD DMY TG 0 08/19/02 * *11 9901 8524 26 TGPD DMY RK 0 08/19/02 ** STATION # 2, # 7 & # 11 = DMY HAS EXTENDED PACKING 9968' 4 -1/2" X 5 -112" XO, ID = 3.958" j 7" BKR MILLOUT IXTENSION, ID = 5.50" 7" X 4 -1/2" XO, ID = 3.958" TOP OF 7" LNR 10038 4 -1/2" WRP(08/17/09) TOP OF LNR (46" SECTIOIN PULLED OUT AND TAGGED 09/04/03) TOP OF 2 -7/8" LNR 10044' 10044' 3 -1/2" X 2 -7 /8" X K) = 2. 441" 10088' 4 -1/2" OTIS XN NIP, � = 3.72" 10099' 4 -1/2" BROWN BREAKOUT SUB BEHIND 4 -1/2" TBG -PC, 12.6 #, L-80_0152 bpf, ID = 3.958" 10101 CT LNR 10100' 4 - 1/2" TUBING TAiI, � = 3.958" 9 -5/8" CSG, 47 #, L -80 BTC, ID = 87681" 10322 E — LM D T OT LOGG D 7" WHIPSTOCK 10440' PERFORATION SUMMARY REF LOG: BRCS ON 06107/83 ANGLE AT TOP PERF: 97 @ 11035' MILLOUT WINDOW (13 -27A) 10457'-?' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2" 4 11035 -11135 C 03/22/01 2" 4 11150 -11250 C 03/22/01 2 -1/8" 4 11450 - 11498 C 09/29/97 12626' FISH - CIBP PUSH® TO BTM 03/02/99 2 -7/8" 4 11450 - 11650 C 10/05/97 2 -1/8" 4 11509 -11513 C 09/29/97 2 -1/8" 4 11850 - 12150 C 06/02/97 PBTD 12638' 2 -1/8" 4 12400 - 12630 C 06/02/97 7" LNR, 29 #, L-80,.0371 bpf, ID = 6.184" 10687' 2 -7/8" LNR 6.5 #, L -80 FL4S, .0058 bpf, ID = 2.441" 12672' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/29183 ORIGINAL COMPLETION 06/13/09 OOBfTLH PKR DESC / 1997 ADPERFS WELL: 13 -27A 07/28/87 SIDETRACKED (13 -27A) 09/10/09 JCM/TLH PLUG PULL / SET WRP (08/17/09) PERMIT No: 1961210 02/09 /02 RNITP CORRECTIONS API No: 50- 029 - 20949 -01 11/19/07 JLJ /PJC GLV C/O SEC 14, T10N, R14E, 596.47' FEL & 4889.41' FNL 1 11/221071 PJC DRAWING CORRECTIONS 01/15/08 SEWlSV SET WRP(11116/07) BP Exploration (Alaska) TREE FMC G EN 3 • 13-27A WELLHEAD = FMC ACTUAT = XELSON PROPOSED -.. _ - A - - -- ,ON KB. E1EV = 83' BF. REV= ? KOP= 2800' 2000'4-1/2" HES X NIP, ID = 3.813" Max Angl 97 @11087' GAS LIFT MANDRELS Datum MD = 10297' S T MD T V D 1 3685 1 3650 Datum TV D= 8800' SS z 64 14 1 5750 9 -5/8" 47 #, L -80 from old TOC to surface 4 9188 7900 5 9718 8360 13 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" 2634' -1/2" 12.6 # /ft, 13Cr -80 VamTop tbg Minimum ID = 2.441" @ 10044' TOP OF 2 -7/8" LINER 7" 26# L -80 scab liner cmt'd 4000' -9900' 9970' S -1/2" BKR PBR ASSY, ID = ? 9984' S -1 /2" K A NCHOR, ID = 4.875" 9985' 9 -5/8" X 5 -1/2" BKR SAB PKR, ID = 4.75" 9990' 7" BKR MILLOUT EXTENSION, ID = 5.50" 9997' TOP OF 7" LNR 10038' 10008' 4 -1/2" WRP(08/17/09) 10044' TOP OF LNR (46" SECTIOIN PULLED OUT AND TAGGED 09/04/03) TOP OF 2 -7/8" LNR 10044' 10044' 10088' 4 -1/2" OTIS XN NIP, ID = 3.72" 10099' 4 -1/2" BROWN SHEA ROUT SUB BEHIND 4 -1/2" TBG -PC, 12.6 #, L -80, .0152 bpf, ID = 3.958" 10101' CT LNR 10100' 4 -1/2" TUBING TA 11, ID = 3.958" 9 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681 " 10322' ELMD TT NOT LOGGED 7" WHIPSTOCK 10440' PERFORATION SUMMARY REF LOG: BRCS ON 06/07/83 ANGLE AT TOP PERF: 97 @ 11035' MILLOUT WINDOW (13 -27A) 10457'-?' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 4 11035 - 11135 03/22/01 2" 4 11150 - 11250 C 03/22/01 2 -1/8" 4 11450 - 11498 C 09/29/97 12626' FISH - CIBP PUSHED TO BTM 03/02/99 2 -7/8" 4 11450- 11650 C 10/05/97 2 -1/8" 4 11509 - 11513 C 09/29/97 2 -1/8" 4 11850 - 12150 C 06/02/97 PBTD 12638' 2 -1/8" 4 12400- 12630 C 06/02/97 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" 10687' 2 -7/8" LNR, 6.5 #, L -80 FL4S, .0058 bpf, ID = 2.441" 12672' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/29/83 ORIGINAL COMPLETION 06/13/09 OOB /TLH PKR DESC / 1997 ADPERFS WELL: 13 -27A 07/28/87 SIDETRACKED (13 -27A) 09/10/09 JCM/TLH PLUG PULL / SET WRP (08/17/09) PERMIT No: 1961210 02/09/02 RN/TP CORRECTIONS API No: 50- 029 - 20949 -01 11/19/07 JLJ /PJC GLV C/O I I I SEC 14, T10N, R14E, 596.47' FEL & 4889.41' FNL 11/22/07 PJC DRAWING CORRECTIONS 01/15/08 SEW /SV SET WRP(11/16/07) BP Exploration (Alaska) • Page I of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, December 17, 2009 3:28 PM To: 'Hubble, Terrie L' Subject: RE: 13 -27A Sundry Request, PTD 196 -121 Terrie, It is on the commissioner desk.. only one commissioner is here now. We need two to sign off on it. I talked to Cathy Foerster about the urgency of getting it approved. You have verbal permission to proceed with the RWO as outlined in the sundry. Will send a signed copy to you as soon as we get two signatures... Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Hubble, Terrie L [mailto:Terrie.Hubble @bp.com] Sent: Thursday, December 17, 2009 2:59 PM To: Schwartz, Guy L (DOA) Cc: Baca, Hank Subject: RE: 13 -27A Sundry Request, PTD 196 -121 Hi Guy, I still haven't seen this Sundry... I sent an envelope over today, so thought I would be getting one back. I have tried to call Darlene, but got her voice mail so am wondering if she is out. Would you mind terribly checking on this one? Thanks! Terrie From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, December 15, 2009 11 :27 AM To: Hubble, Terrie L Subject: RE: 13 -27A Sundry Request, PTD 196 -121 Terrie, Hasn't crossed my desk yet.... It is circulating. Is tomorrow soon enough? I can probably push it thru today if I can find it. Guy Schwartz Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Hubble, Terrie L [mailto:Terrie.Hubble @bp.com] Sent: Tuesday, December 15, 2009 11:06 AM 12/17/2009 Page 2 of 2 To: Schwartz, Guy L (DOA) Cc: Baca, Hank Subject: 13 -27A Sundry Request, PTD 196 -121 Hi Guy, We submitted a 10 -403 for this well late last week which has a planned start date of today. Is there any chance we can get it back soon? As usual, the holidays are sneaking up on us and folks are trying to wrap up their work to get out of here... you know how it is. Anyway, this is one of the loose ends we were hoping to get wrapped up before certain folks head out. Thanks for any help you are able to provide. Merry Christmas! Terrie 12/17/2009 1 0/01/09 Scbtumherger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2528 Gambell Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD K -11 AY1M -00033 SBHP SURVEY 09/12/09 1 1 14-30 AWLS -00031 PRODUCTION PROFILE a( t5(1 08/06/09 1 1 P2 -31 AP3Q -00045 LDL /a 4/ g) 3 4,, -9(( 07/11/09 1 1 01-29 BSJE -00009 PRODUCTION PROFILE jf `it 08/11/09 1 1 J -22A 1369K -00013 PRODUCTION PROFILE no- 1 1 08/30/09 1 1 ST W-44 B14B -00071 INJECTION PROFILE t 1 L ?n, 09/06/09 1 1 12-25 B581-00010 INJECTION 00 PROFILE 1 4 4 6/� 0 9/01/09 1 1 L5-33 AYK VKP- 00 SURVEY 1 Z b J r V 09/01/09 1 1 P2-48 B69K -00015 SBHP SURVEY j 09/01/09 1 1 Z -28 B69K -00016 INJECTION PROFIL 0a /e03 09/19/09 1 1 Q -02A AP30 -00054 IBP /LDL q a e 07/24/09 1 1 I N -10A AXED -00040 MEM PROD PR FILE n L( 08/25/09 1 1 W -24 AWJI -00044 MEM INJECTION PROFILE j AR Q 'Q118/15/09 1 1 V -03 B2NJ -00021 MEM PROD PROFILE a[� j 09/03/09 1 1 H -14B B2WY -00026 MEM PROD PROFILEaQ�. J 1 08/27/09 1 1 P1 -01 AY1M -00031 INJECTION PROFILE t'[,(t /S 6 9 08/20/09 1 1 P1-05 B58I -00009 PRODUCTION PROFIL j 08/20/09 1 1 NK -10 B2WY -00023 MEM INJECTION PROFILE i t tt J f' 08/22/09 1 1 13 -27A B2NJ -00019 MEMORY SCMT �9� ...1 7Q 08/13/09 1 1 18-02B 82WV -00021 MEMOR SCMT ry .�C.[(� gl 08/19/09 1 1 NK -38A AYKP -00049 USIT i� !4 L 1 7 1 08/17109 1 1 06 -09 SWL8 -00028 USIT i q a 07/30/09 1 1 13 -03A 09AKA0150 OH MWD/LWD EDIT /t l 'i vs 07/06/09 2 1 C -188 B2NJ -00017 MCNL Lj 1 it 08/09/09 1 1 1- 35/0 -25 B69K -00011 RST if r r 08/26/09 1 1 04 -35A AXBD -00025 MCNL A 9 _Ag 05/13109 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 N O'! 200S J„ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 10/07/03 NO. 2984 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99504 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD P2-41 I C.~ ~;~ "lq ,,"-'~, ,, SBH TEMP & PRESSURE SURVEY 10103107 GNI-04 lC/-c~ -g~ TEMP & PRESS SURVEY 10104103 D.S. 13-27AT~ ~; I~ LDL ~0/01107 D.S. 6-2~A ~-~F~ LDL ~010~/03 D.S. ~4-32 }~'~~ LDL J0/03/03 C-23B ~-~ ~O~ MEM PPROF & IPROF LOG 09101103 F-13A ~ ~l ~ ~ MEM PPROF & IPROF LOG '" 09~08~03 MPS-02 ~--t~ ~ INJECTION PROFILE ~0/04103 ..s-=o,. - - '- ~oss~=~4 c. ~m~ sc=~(.oc} 0=~0~0~ =.s-=o ~~q ~ ~oss~==4 sc=~ 0=~0=~0= PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4749' FNL, 1183' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 3317' FNL, 4607' FEL, Sec. 24, T10N, R14E, UM At effective depth At total depth 4889' FNL, 596' FEL, Sec. 23, T1 ON, R14E, UM 5. Type of Well: Development __X Explorato~ Stratigraphic_ Service__ (asp's 686068, 5930565) (asp's 688022, 5926768) (asp's 686792, 5925163) 6. Datum elevation (DF or KB feet) RKB 83 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-27A 9. Permit number / approval number 196-121 10. APl number 50-029-20949-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2550' Production 10239' Liner 415' Liner 2632' 12672 feet Plugs (measured) 9057 feet 12485 feet Junk (measured) 9064 feet Tagged PBTD @ 12485' MD on 3/21/2001. Size Cemented Measured Depth True Vertical Depth 20" 2115# Poleset 80' 80' 13-3/8" 2700 Sx CS III & 400 Sx CS II 2633' 2633' 9-5/8" 5oo sx Class G & 3OO Sx CS J 1 0322' 8905' 7" 265 Sx Class G 1 0453' 9024' 2-7/8" 21 bbis Class G 12672' 9057' Perforation depth: measured 11035'-11135'; 11150'-11250'; 11450'-11498'; 11500'-11650'; 11850'-12150'; 12405'-12630'. true vertical 9058' - 9046'; 9044' - 9038'; 9041' - 9044'; 9044' - 9056'; 9059' - 9068'; 9069' - 9058'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 PCT @ 10100' MD. 9-5/8" X 4-1/2" BAKER SAB PACKER @ 9985' MD. 4-1/2" CAMCO BAL-O SSSV @ 2196' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 266 268 Bepresentative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 1491 1936 621 3613 Casing Pressure Tubing Pressure 291 314 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,. , ,-, Title: DS 13 Surveillance Engineer .. Andy Parker Date April 18, 2001 Prepared by Paul Rauf 564-5799 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 13-27A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 3/08/2001. 3/20/2001. 3/21/2001. 3/22/2001. 4/09/2001' 4/10/2001. RIH w/dummy gun & drifted to 10515' SLM (HAW). MIRU Work Platform & CTU. PT'd equip to 3500 psi. Loaded & killed well w/1% KCL Water. RIH w/Mem GR/CCL & logged well f/10450' to 12485' MD. Placed FIo Pro across perforations. POOH w/logging tools. MU 2" PJ perf guns. RIH w/guns. Shot overbalanced the following add perforations f/: 11035' - 11135' MD (Zone 4) Reference Log: BHCS 6/07/1983. 11150' - 11250' MD (Zone 4) All shots @ 4 SPF, random orientation, & 60° phasing. POOH w/guns - ASF. RD CTU & Work Platform. Placed well 13-27A BOb Performed welltest. Page 1 bp March 21,2001 BP EXPLORATI ON BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~ 001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: RECEIVED MAR 2 3 2001 Alaska Oil & Gas Oons. C0mm~n An~0ra~ Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as req~uired under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list 6f well work tentativel~ scheduled for March 19 - 26, 2001' 05-01C Work Planned CTE PERFORATION 05-18A CTE ADD PERFORATION 06-24A CT ACD STIMULATION W/DIVERTER 16-23Ai SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W/WORK PLATFORM CHEMICAL CUT TUBING (PRE RIG ST) NK-65i CTE ADD PERFORATION S-101 S'103 ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Sincerely, ~ ~ ¢ Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells FAX 907 ~§4 4Z§4 BP EXPLOILATION ~ UU] bp BP Exploration (Alaska) Inc. 900 E~t Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-$111 March 14, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite !00 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 34 lC (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 12 - 19, 2001: Well 03-27 03 -28 05-18A 12-15 ~-!: 13_27A~. 16-21 NK-65i S-101 S-103 Work Planned REPERFORATION I HYDRAULIC FRACTURE TREATMENT REPERFORATION CTE ADD PERFORATION SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W/WORK PLATFORM REPERFORATION CTE ADD PERFORATION ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc@bp.com. Sincerely, Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells t Ae 1.; 2001 03/08/2001 15:43 FAX 907 564 4264 BP EXPLORATION bp BP Exploration (Alaska) Inc. 900 East Benson Bmtlevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 7, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Prudhoe-EOA, Pt, Mac, & Lisburne Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001: wen 03-08 03-25A 03-27 03-28 06-18 16-05Ai 16-2I NK-22 S-101 S-103 S-I05 Work Planned REPERFORATION REPERFORATION REPERFORATION / HYDRAULIC FRACTURE TREATMENT REPERFORATION CT ACID WASH - GEL CEMENT SQUEEZE GSO CT ADD PERFORATION W/WORK PLATFORM CTD SIDETRACK (NABORS 3S) REPERFORATION ADD PERFORATION ADD PERFORATION INITIAL PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please cai1 me at 564-5799 or E-mail me at raufpc@bp.com~ Sincerely, ~;;~n~;aRlaAu~ssistant, BPX~ Alaska Drilling & Wells RECEIVED t AR 0 8 ?OOl Alaska Oil & Gas Cons. Commission Anchorage BP Exploration Endioott Well Operations ~./'24/01 Sunday_.. $1i~kline: E-line: Other: 2/25 4-10 1-47 Dummy off GLV;s a'r{~l drift tui~i~g.,to 3.625" Leak detection water flow log Monda~ [E-li~e.: IOther: 2/26 3-25 2-14 Pull SSSV~ drift ~N~h dumm~y whipstock Water flow Io~ . Tueeda~v IllSlickline; IEqiqe; Other: 2/27 3-25 Run static pressure survey 3-39 gas-lift survey & FSPL 1-0,5~.2-12~ 3-45~ 4-10~ 5-01 & 5-02 MIT's w/AOGCC witness Wednesday 2/28 Slickline: 1-25 Other: ~=~. _ Brush, Flush &-~ull SSSV~'~l-~'~t'tubing .ThursdaY 3/01 tSlicl<line: 1-25 Other: 2_~_56 Caliper s~rvey tuSi~{t & liner PFO _Frid_a.y IloSlickline: 3/02 1-25 Static pressure ~u~y. Saturday 3/04 o Iol~kline; 1-21 her: ....... 1-25 Caliper survey of tubing. I njectivity test bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 28, 2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Pax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for February 26 - March 4, 2001: Well Work Planned ~ ~., 03-28 REPERFORATION ~ 02-34A CT SET CIBP FOR GSO ~ ~ O~ ~.. I5-41A CTD SIDETRACK (NABORS CDR1) _ ~.~ ~ ~ 16,05Ai CTD SIDETRACK (NABORS 3S) 7:13:27A :: .!.! CT ADD PERFORATION W/WORK PLATFORM 11-32 ADD PERFORATION 15-35 ADD PERFORATION 16-21 REPERFORATION S-101 ADD PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Technical Assistant, BPXA Alaska Drilling & Wells bp February 28,2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for Febmmy 26 - March 4, 2001' Well Work Planned 03 -28 REPERFORATION 02-34A CT SET CIBP FOR GSO 15-41A 16-05Ai · ?i!3~27A ?! .. 11-32 CTD SIDETRACK (NABORS CDR1) CTD SIDETRACK (NABORS 3S) CT ADD PERFORATION W/WORK PLATFORM ADD PERFORATION 15-35 16-21 ADD PERFORATION REPERFORATION S-101 ADD PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. ;ianulerCilYR' u f~ ~ Technical Assistant, BPXA Alaska Drilling & Wells R C IVED ~IllR 0 ~ 2001 Alaska Oil ~ Gas Cons AnChorage' C°n~rnission PERMIT 96-121 96-121 96-121 96-121 96-121 96-121 AOGCC Individual Well Geological Materials Inventory . DATA T DATA PLUS MWD SRVY ~10400.-12672. MWD SRVY ~SPERRY 10400-12672. NGP-MD ~/~0457-12672 8089 d~PERR¥ ~R/ROP PROD/D /2630-11750 10-407 /~R~OMPLETION DATE @ ~/~! Are dry ditch samples required? yes ~ And received? Was the well cored? yes n~Analysis & description received? Are well tests required? yes ~?~Received? .~es..~~' : Well is in compliance Initial COMMENTS Page: 1 Date: 05/24/99 RUN RECVD 06/11/97 06/20/97 FINAL 09/03/97 FINAL 09/03/97 2-7 08/27/97 FINAL 09/05/97 T D BOX -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI~dON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 83' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service _ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 526' FSL, 1185' FEL, Sec 14, T11N, R14E, UM. 13-27A At top of productive interval: 9. Permit number/approval number: 3319' FNL, 674' FWL, Sec 24, T10N, R14E, UM. 96-121 At effective depth: 10. APl number: 50-029-20949-01 At total depth: 11. Field/Pool: 4889' FNL, 596' FEL, Sec 23, T10N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12672 feet Plugs (measured) Milled CIBP @ 12626' MD (since 3/3/99). true vertical 9057 feet Effective Depth: measured 12640 feet Junk (measured) true vertical 9058 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2115# Poleset 80' 80' Surface 2550' 13-3/8" 2700 Sx CS III & 2633' 2633' 400 Sx CS II Production 10239' 9-5/8" 500 Sx Class G & 10322' 8905' 300 Sx CS I Liner 415' 7" 265 Sx Class G 10453' 9024' Liner 2632' 2-7/8" 21 Bbls Class G 12672' 9057' Perforation Depth measured 11450 - 11498'; 11500- 11650'; 11850- 12150'; 12405 - 12630' true vertical 9041 - 9044'; 9044- 9056'; 9059- 9068'; 9069- 9058' 'ubing(size, grade, and measured depth) 4-1,2", 12.6#,L-80, Tbg @ 10100'MD.MDt~ N4 / Packers and SSSV (type and measured depth) Baker SAB Packer @ 9985' MD; 4-1/2" Camco BaI-O SSSV @ 2196' 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) · 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 291 251 1941 248 Subsequent to operation 391 592 1885 - 243 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.,,~ ~)'[,") · (~,~.. Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE..... 13-27A DESCRIPTION OF WORK COMPLETED SELECTIVE HIGH PRESSURE BREAKDOWN TREATMENT 2/8/98: RIH w/CIBP & set CIBP in the 2-7/8" liner at 10750' MD, to isolate the lower open perforation intervals located at: 11850 - 12150' MD 12400 - 12630' MD Performed an injectivity test pumping Crude through the open perforation intervals located above the CIBP at: 11450 - 11498' MD 11500 - 11650' MD Well took 2 bpm @ 1500 psi. RD. 2/17/98: Performed a fullbore selective High Pressure Breakdown Treatment to stimulate the open perforation intervals located above the ClBP (listed above). Pumped 200 bbls Crude @ 11 bpm / 5950 psi, followed by 159 bbls 60% Diesel / 30% Xylene / 10% Musol, followed by 161 bbls Crude Flush, followed by Shutdown. RD. 8/6/98 - 8/7/98: RIH w/CT milling BHA to tag ClBP (listed above). No movement of CIBP. POOH w/milling BHA. Milled on CIBP and attempted to push plug down hole. RD. 3/3/99: RIH w/CT milling BHA to tag CIBP and resumed milling operations. CIBP fell free. Pushed CIBP down hole to open the lower perforation intervals (above) to production. Pushed CIBP to stop on float shoe at 12626' MD. POOH w/milling BHA. RD. Placed well on production w/lift gas and obtained a valid well test. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIL,~,~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate~ Plugging _ Perforate _X Pull tubing_ After casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 83' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 526' FSL, 1185' FEL, Sec 14, T11N, R14E, UM. 13-27A At top of productive interval: 9. Permit number/approval number: 3319' FNL, 674' FWL, Sec 24, T10N, R14E, UM. 96-121 At effective depth: 10. APl number: 50-029-20949-01 At total depth: 11. Field/Pool: 4889' FNL, 596' FEL, Sec 23, T10N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12672 feet Plugs (measured) true vertical 9057 feet Effective Depth: measured 12640 feet Junk (measured) true vertical 9058 feet Casing Lenglh Size Cemented Measured depth True vedlcal depth Conductor 80' 20" 2115# Poleset 80' 80' Surface 2550' 13-3/8" 2700 Sx CS III & 2633' 2633' 400 Sx CS II Production 10239' 9-5/8" 500 Sx Class G & 10322' 8905' 300 Sx CS I Liner 415' 7" 265 Sx Class G 10453' 9024' Liner 2632' 2-7/8" 21 Bbls Class G 12672' 9057' !Perforation Depth measured 11450 - 11498'; 11500 - 11650'; 11850 - 12150'; 12405 - 12630' true vertical 9041 - 9044'; 9044 - 9056'; 9059 - 9068'; 9069 - 9058' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Tbg @ 10100' MD. Packers and SSSV (type and measured depth) Baker SAD Packer @ 9985' MD; 4-1/2" Camco BaI-O SSSV @ 2196' MD. 13. Stimulation or cement squeeze summary .., · -~r' Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 300 333 1535 244 Subsequent to operation 318 184 2021 260 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ ~1,') , ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~ 13-27A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/29197: MIRU CTU & PT equipment. RtH w/CT conveyed perforating guns & shot perforations as follows: Added perforations: 11450 - 1 t498' MD (Z.4) 11509- 11513' MD (74) Used 2-1/8" carriers & shot the perfs at 4 spf. POOH w/perf guns. Rigged down. 10/4/97 - 10/5/97: MIRU CTU & PT equipment. RIH w/CT conveyed perforating guns & shot perforations as follows: Added perforations: 11500 - 11509' MD (74) 11513- 11650' MD (Z.4) Reperforated: 1 t 509 - 11513' MD (74) Used 2-t/8" carriers & shot the perfs at 4 spf. POOH w/perf guns. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11316 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 9/3/97 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL RF Sepia Disk Tape D.S. 7-32 PRODUCTION PROFILE 9 70 50 8 1 1 -- 'D.S. 5-22 PRODUCTION PROFILE 97061 7 1 1 D.S. 17-14 PRODUCTION PROFILE W/DEFT 970625 I 1 D.S. 15-48 PRODUCTION LOG 970607 I 1 ..... D.S. 9-6 PRODUCTION PROFILE W/DEFT 97061 8 I 1 ..... D.S. 13-27A PRODUCTION PROFILE W/DEFT 97061 6 I 1 ,. ,. ., SEP 0 5 199/ Alaska Oil & Gas Cons. Commission Anch0r'~je Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank you. WELL LOG TRANSM1TT~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs D.S. 13-27A, September 3, 1997 AK-MW-70153 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 D.S. 13-27A: 2" x 5" MD Gamma Ray Logs: 50-029-20949-01 2" x 5" TVD Gamma Ray Logs: 50-029-20949-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 13-27A, August 27, 1997 AK-MW-70153 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20949-01. RECEIVED AUG £ 7 1997 Alaska Oil & Gas ~ns. Oommissk~ Anchorage · Alaska99/518 · (9¢7)563-3256 · Fax (907)563-7252 5631 Silverado Way, Suite G Anchorage, A Dresser Industries, linc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG f Status of Well Classification of Service Well Oil._~X Gas__ Suspended__ Abandoned_ Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 96-121 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 -' ; 50-029-20949-01 4 Loc~f wel~at surfac~ ~' ...... ~ .......... ~ , ~ 9 Unit or Lease Name 526' FSL 1185' FEL Sec 14 ~"'J ! '! ~'-(~1~t ' ' PRUDHOE BAY UNIT · ' . ' ' ' ' ' I i'~-'f'~ ~ '' ~----~ At Top Producing ,nterval., ~..../.. /~ '-~ ~i ,,,¢. ~'/~); i '~f~'_~.-..,"~_._.~,..,.,m~J 10 Well Number 3319' FNL 674' FWL S9024 T10N R14E UM ~,~-/-~-~¢-~-- i , '-'-'~ 13-27A 4889' FNL, 596' FEL, Sec 23, T10N, R14E, UM. .... ~- .... '. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 83' RKB ADL 28315 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 5/21/97 5/30/97 6/2/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 12672' MD / 9057' TVD 12640' MD / 9058' TVD YES_X NO__ 2196' feet MD 1500' feet (approx) 22 Type Electric or Other Logs Run GR, MWD. 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMT PULLED 16" 91.5# H-40 Surf 80' 30" 2115# Poleset 13-3/8" 72# L-80 Surf 2633' 17.5" 2700 Sx CS III & 400 Sx CS II 9-5/8" 47# L-80 Surf 10322' 12.25" 500 Sx Class G & 300 Sx CS I 7" 29# L-80 10038' 10453' 8.5" 265 Sx Class G 2-7/8" 6.5# L-80 10040' 12672' 3.75" 21 bbls Class G 24 Perforations open to Production (MD+-I-VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET MD PACKER MD 4-1/2" Tbg 10100' 9985' 11850 - 12150' MD; 9060- 9068' TVD; at 4 spf. 12405 - 12630' MD; 9069 - 9058' TVD; at 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 6/6/97 Flowing w/Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR 6/13/97 10 TEST PERIOD --I 799 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 252 - 24 HOUR RATE _X 548 438 2126 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 7/15/96 (Approval # 9~,~21_).. ~ 0RI6I~I~AL j(IP4. 20 1997 Form 10-407 Submit in duplicate Rev. ?-1-80 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit cwo GEOLOGIC MARKERS MEAS DEPTH 10421' 10532' TRUE VERT DEPTH 8994' 9094' FORMATION TESTS Include interval tested, pressure data, and fluids recovered and gravity, GOR, and time of each phase, N/A 31 LIST OF ATTACHMENTS Summary of 13-27A Coil Tubing Sidetrack Drilling Operations. 321 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/./(,t~ '~1. ~'~ Engineering Supervisor Date ~ - 20-- ¢ '~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Li~, Rod Pump, Hydraulic Pump, Submersible, Water InjectTo-~" Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". 4&~ /alii ,& FO~ 10'407 13-27A DESCRIPTION OF WORK COMPLETED CTU SIDETRACK DRILLING OPERATIONS 5/21/97: MU & RIH w/3.8" milling BHA. PT cement plug; well took 1 bpm at 1100 psi. Milled through the XN nipple at 10086' MD, then RIH to top of cement plug at 10444' MD. RIH along whipstock & started milling a window through the 7" liner at 10453' MD. Milled window to 10459' & drilled formation to 10460' MD. POOH w/BHA. 5/22/97: RIH w/milling BHA. w/50 bbls biozan. Reamed window & drilled 3.8" sidetrack hole to 10466' MD. POOH w/BHA. RDMO CTU. Circulated wellbore clean 5124197: MIRU CTU & PT BOP's. 5/25/97: RIH w/drilling BHA & circulated well to FIo-Pro. Drilled to 10610' MD losing mud at 4 - 12 bph. 20 bbl LCM pill & squeezed to 750 psi. POOH w/BHA. Pumped a 5/26/97: RIH w/drilling BHA. Drilled to 10860' MD w/periodic short trips to window. POOH w/BHA. 5/27/97: RIH w/drilling BHA. Drilled to 11656' MD w/periodic short trips. 5/28/97: POOH w/BHA. RD CTU to swap CT reel. Spooled pipe. 5~29/97: RU CTU w/new pipe. MU & RIH w/drilling BHA. horizontally to 12225' MD. Circulated system over to new FIo-Pro, then drilled 5130197: Drilled to TD at 12672' MD. Circulated hole clean. POOH w/BHA. MU & RIH w/2-7/8" liner assembly. 5/31/97: Landed liner on bottom at 12672' MD. Pumped 21 bbls of Class G cement to set liner at 10040 - 12672' MD. Bumped plug, unstung from PBR, & POOH displacing FIo-Pro from well to 1% KCl Water. RIH w/milling BHA. 6/1/97: Ran through liner to tag up at 12640' MD. Pumped 30 bbl FIo-Pro pill in liner. to 1500 psi; held. RIH w/2-1/8" perforation guns & shot a perforation interval at: POOH w/BHA. PT liner lap 11850- 12150' MD (Z4) POOH w/perf guns. 6/2./97: RIH w/225' of 1-11/16" perf guns & shot a perforation interval at: 12405- 12630' MD (Z4) POOH w/perf guns; noted all shots fired. ND & NU tree. RDMO CTU. Placed the well on initial production with gas lift & obtained a valid welltest. S--~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / 13-27A 5oo292o949o1 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052997 MWD SURVEY JOB NUMBER: AK-MW-70153 KELLY BUSHING ELEV. = 83.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10400.00 8975.62 8892.62 10444.00 9015.02 8932.02 10456.60 9026.07 8943.07 10470.10 9037.44 8954.44 10489.50 9052.33 8969.33 25 40 27 17 30 0 35 17 44 17 S 10.22 E .00 3834.77S 1858.81E S .70 E 10.32 3854.25S 1860.63E S 1.10 E 21.48 3860.29S 1860.72E S 2.00 E 39.42 3867.57S 1860.92E S 3.00 E 46.51 3879.96S 1861.47E 2166.69 2181.92 2186.90 2192.85 2202.87 10503.60 9061.85 8978.85 10519.14 9070.96 8987.96 10534.99 9078.76 8995.76 10565.20 9089.31 9006.31 10596.69 9094.21 9011.21 5O 57 63 75 86 42 28 32 3O 34 S 4.60 E 46.15 3890.33S 1862.17E S 6.28 E 44.43 3902.85S 1863.37E S 6.26 E 38.30 3916.55S 1864.88E S 3.20 E 40.74 3944.71S 1867.18E S .42 W 36.91 3975.75S 1867.91E 2211.12 2220.89 2231.47 2253.65 2279.11 10612.74 9094.43 9011.43 91 50 10630.04 9093.83 9010.83 92 6 10652.34 9093.06 9010.06 91 50 10680.19 9092.21 9009.21 91 40 10715.09 9090.61 9007.61 93 35 S 3.93 W 39.45 3991.78S 1867.30E S 3.58 W 2.55 4009.03S 1866.17E S 4.46 W 4.13 4031.26S 1864.61E S 5.51 W 3.82 4058.99S 1862.19E S 5.69 W 5.55 4093.68S 1858.79E 2292.80 2307.80 2327.18 2351.62 2382.41 10757.04 9087.52 9004.52 94 49 10780.12 9085.51 9002.51 95 10 10847.12 9079.43 8996.43 95 14 10869.14 9077.35 8994.35 95 35 10890.00 9075.08 8992.08 96 54 S 6.22 W 3.19 4135.29S 1854.45E S 7.80 W 6.99 4158.11S 1851.64E S 7.16 W .96 4224.26S 1842.96E S 8.75 W 7.37 4245.97S 1839.92E S 8.60 W 6.27 4266.47S 1836.80E 2419.47 2440.03 2499.95 2519.72 2538.52 10933.20 9069.81 8986.81 10955.79 9067.11 8984.11 10991.70 9063.07 8980.07 11029.60 9058.78 8975.78 11047.09 9056.71 8973.71 97 5 96 37 96 18 96 41 96 55 S 10.60 W 4.62 4308.74S 1829.65E S 11.77 W 5.56 4330.74S 1825.30E S 15.00 W 8.98 4365.45S 1817.04E S 18.20 W 8.46 4401.53S 1806.28E S 19.05 W 4.99 4417.99S 1800.74E 2577.69 2598.43 2631.91 2667.92 2684.70 11086.60 9051.78 8968.78 11135.20 9045.82 8962.82 11179.99 9041.32 8958.32 11203.00 9039.62 8956.62 11238.70 9037.93 8954.93 97 24 96 41 94 48 93 41 91 41 S 23.60 W 11.49 4454.50S 1786.48E S 25.40 W 3.95 4498.38S 1766.48E S 27.80 W 6.80 4538.22S 1746.53E S 29.50 W 8.81 4558.35S 1735.53E S 31.50 W 7.92 4589.08S 1717.43E 2723.00 2770.62 2814.85 2837.71 2873.31 11276.12 9037.35 8954.35 11303.90 9037.56 8954.56 11335.60 9038.33 8955.33 11375.99 9039.42 8956.42 11401.20 9039.83 8956.83 9O 89 88 88 89 5 1 11 43 22 S 33.84 W 7.59 4620.57S 1697.24E S 35.70 W 7.71 4643.39S 1681.40E S 37.30 W 5.68 4668.86S 1662.55E S 39.49 W 5.57 4700.50S 1637.48E S 41.40 W 8.01 4719.67S 1621.13E 2910.72 2938.49 2970.13 3010.36 3035.38 F--PRRY-SUN DRILLING SERVICES ANCHOR_AGE ALASK~ PAGE SHARED SERVICES DRILLING PBU / 13-27A 500292094901 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052997 MWD SURVEY JOB NUMBER: AK-MW-70153 KELLY BUSHING ELEV. = 83.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11432.80 9040.22 8957.22 11452.20 9040.75 8957.75 11493.24 9043.17 8960.17 11523.30 9045.45 8962.45 11547.50 9047.41 8964.41 89 12 87 41 85 31 85 48 84 54 S 42.30 W 2.90 4743.21S 1600.05E S 43.30 W 9.33 4757.44S 1586.88E S 44.71 W 6.32 4786.90S 1558.42E S 46.60 W 6.34 4807.85S 1536.98E S 48.40 W 8.29 4824.14S 1519.20E 3066.65 3085.79 3126.08 3155.38 3178.79 11577.50 9050.26 8967.26 11603.62 9052.77 8969.77 11651.37 9056.66 8973.66 11674.44 9058.09 8975.09 11705.72 9059.15 8976.15 84 11 84 46 85 52 87 0 89 7 S 49.30 W 3.79 4843.80S 1496.72E S 50.01 W 3.50 4860.63S 1476.90E S 54.20 W 9.04 4889.85S 1439.35E S 55.79 W 8.47 4903.06S 1420.50E S 56.14 W 6.84 4920.55S 1394.60E 3207.60 3232.58 3277.70 3299.13 3328.03 11736.04 9059.54 8976.54 89 22 11764.49 9059.81 8976.81 89 33 11789.57 9059.81 8976.81 90 26 11838.67 9059.58 8976.58 90 5 11855.07 9059.63 8976.63 89 33 S 57.02 W 3.03 4937.25S 1369.29E S 58.42 W 4.96 4952.44S 1345.24E S 60.71 W 9.78 4965.14S 1323.62E S 64.22 W 7.18 4987.84S 1280.09E S 65.63 W 9.18 4994.79S 1265.24E 3355.94 3381.90 3404.44 3447.42 3461.42 11891.97 9060.22 8977.22 88 35 11925.27 9061.25 8978.25 87 53 11960.79 9062.39 8979.39 88 25 11972.67 9062.75 8979.75 88 4 12001.84 9063.78 8980.78 87 53 S 68.09 W 7.17 5009.28S 1231.31E S 70.73 W 8.20 5020.99S 1200.16E S 73.01 W 6.59 5032.03S 1166.43E S 74.42 W 12.22 5035.36S 1155.03E S 76.18 W 6.06 5042.76S 1126.84E 3492.27 3519.25 3547.11 3556.19 3577.94 12034.67 9064.84 8981.84 88 25 12067.42 9065.41 8982.41 89 35 12100.74 9065.98 8982.98 88 25 12118.99 9066.56 8983.56 87 54 12154.59 9068.09 8985.09 87 11 S 74.07 W 6.62 5051.18S 1095.13E S 72.01 W 7.25 5060.73S 1063.81E S 70.38 W 6.04 5071.47S 1032.28E S 69.40 W 6.05 5077.74S 1015.15E S 65.80 W 10.30 5091.29S 982.28E 3602.49 3627.77 3654.16 3668.86 3698.33 12181.27 9069.56 8986.56 86 28 12205.04 9070.98 8987.98 86 39 12241.19 9072.70 8989.70 87 53 12268.62 9073.44 8990.44 89 1 12293.09 9073.63 8990.63 90 5 S 62.99 W 10.85 5102.80S 958.26E S 61.41 W 6.68 5113.87S 937.27E S 59.48 W 6.33 5131.67S 905.86E S 58.42 W 5.67 5145.82S 882.38E S 57.90 W 4.83 5158.72S 861.59E 3721.21 3742.03 3774.24 3799.01 3821.26 12316.94 9073.30 8990.30 12352.07 9071.82 8988.82 12370.34 9070.75 8987.75 12407.02 9068.56 8985.56 12429.44 9067.20 8984.20 91 29 93 20 93 20 93 31 93 25 S 55.96 W 10.03 5171.73S 841.61E S 55.61 W 5.36 5191.47S 812.59E S 54.56 W 5.74 5201.91S 797.63E S 52.09 W 6.74 5223.77S 768.27E S 51.22 W 3.89 5237.65S 750.72E 3843.15 3875.64 3892.61 3927.06 3948.34 S~'-~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / 13-27A 5OO292O949O1 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052997 MWD SURVEY JOB NUMBER: AK-MW-70153 KELLY BUSHING ELEV. = 83.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12455.92 9065.74 8982.74 92 54 S 48.58 W 10.15 5254.68S 730.50E 12489.49 9064.11 8981.11 92 38 S 45.94 W 7.89 5277.44S 705.88E 12521.44 9062.59 8979.59 92 48 S 42.95 W 9.36 5300.22S 683.53E 12557.99 9060.83 8977.83 92 43 S 40.67 W 6.24 5327.42S 659.20E 12591.89 9059.33 8976.33 92 22 S 38.38 W 6.83 5353.54S 637.65E 3973.71 4006.29 4037.63 4073.75 4107.43 12620.92 9058.24 8975.24 91 55 S 36.62 W 6.25 5376.55S 619.99E 12643.02 9057.56 8974.56 91 34 S 33.99 W 12.00 5394.58S 607.23E 12672.00 9056.88 8973.88 91 7 S 33.40 W 2.58 5418.68S 591.15E 4136.37 4158.44 4187.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5450.83 FEET AT SOUTH 6 DEG. 13 MIN. EAST AT MD = 12672 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 213.58 DEG. TIE-IN SURVEY AT 10,400.00' MD WINDOW POINT AT 10,444.00' MD PROJECTED SURVEY AT 12,672.00' MD F--~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING PBU / 13-27A 500292094901 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052997 JOB NUMBER: AK-MW-70153 KELLY BUSHING ELEV. = 83.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10400.00 8975.62 8892.62 3834.77 S 1858.81 E 1424.38 11400.00 9039.82 8956.82 4718.77 S 1621.92 E 2360.18 935.80 12400.00 9068.99 8985.99 5219.46 S 773.80 E 3331.01 970.83 12672.00 9056.88 8973.88 5418.68 S 591.15 E 3615.12 284.11 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING PBU / 13-27A 500292094901 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/10/97 DATE OF SURVEY: 052997 JOB NUMBER: AK-MW-70153 KELLY BUSHING ELEV. = 83.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10400.00 10408.14 10545.96 1058O.OO 8975.62 8892.62 8983.00 8900.00 9083.00 9000.00 9092.36 9009.36 3834.77 S 1858.81 E 1424.38 3838.13 S 1859.69 E 1425.14 .76 3926.61 S 1865.80 E 1462.96 37.83 3959.17 S 1867.76 E 1487.64 24.68 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS pemm - ur, 0 I::! I I_1-- I I~1G S ~:: I~! ~ I r" ~:: S AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data 13-27A June 10, 1997 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 13-27A MWD survey Tie-In point at 10,400.00', Window point at 10,444.00' and a Projected survey at 12,672.00'. Please call me at 563-3256 if yOu have any questions or concerns. Regards, William T. Allen Survey Manager Attachments 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 15, 1996 ._ Erin Oba, Engineering SUPervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit 13-27A ARCO Alaska, Inc. 96-121 526'FSL, 1185'FEL, Sec 14, T10N, R14E, UM 4643'FNL, 283'FEL, Sec 23, T10N, R14E, UM Dear Ms. Oba: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659- 3607. David Chairman BY ORDER OF THE COMMISSION dlf/encl c: Dept ofFish & Game, Habitat'Section - w/o encl Dept of Environmental Conservation - W/o encl ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 J. W. Groth Supervisor Greater Pt. Mclntyre Area June 28, 1996 Mr. D. W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: -COMM ~'~.~ __ 'COMM ., COMM ~ __ RES ENG -- __ ~SR ENG _ NRO SR GEOi' - __ _GEOL ASST ~ STAT I'ECH ~ STAT I'ECH _ _ _ _ _ FIL~ ~ ARCO Alaska, Inc., as Operator of the West Beach Oil Pool, is requesting a one year extension of the gas-oil ratio waiver set under 20 AAC 25.240 for the West Beach #4 well. Extension of the waiver will allow continued production of the West Beach #4 and North Prudhoe Bay #3 wells. Consistent with your July 17, 1995 approval letter (Administrative Approval No. 311.4), an annual update was provided for the West Beach Pool on Wednesday, June 26, 1996. As discussed at this meeting, our plans are to continue to restrict offtake from the West Beach #4 well to control the producing gas-oil ratio while also utilizing the West Beach #4 production to lift fluids from the North Prudhoe Bay #3 well. Furthermore, we will be reviewing the potential for additional development opportunities in the West Beach Pool. Sincerely, J. W. Groth CC: D. Coleman (Exxon) M. Griffith (Exxon) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill __ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test Development Oil X Re-Entryw Deepen _ Service Development Gas __ Single Zone x_~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 83' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28315 Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 526' FSL, 1185' FEL, Sec 14, T10N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 3319' FNL, 674' FWL, Sec 24, T10N, R14E, UM. 13-27A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4643' FNL, 283' FEL, Sec 23, T10N, R14E, UM. July 25, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 3roperty line No Close Approach 12188' MD / 9063' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10330' MD Maximum hole angle 89° Maximum surface 2800 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 L80 FL4S 2138' 10050' 8658' 12188' 9063 25 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10690 feet Plugs(measured) PBTD Tagged at 10473' MD (11/7/95). true vertical 9237 feet 0 ' L Effective depth: measured 10473 feet Junk (measured) true vertical 9042 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 2700 Sx CS III & 400 Sx CS 112115¢ Polese, 2633'80' VED RFCEI Production 10239' 9-5/8" 500 Sx Cl G & 300 Sx CS I 1 0322' 8904' Liner 648' 7" 265 Sx Cl G 1 0686' 9234' Perforation depth: measured 10323- 10346'; 10429- 10439'; 10444- 10470'; 10477- 10495' JUl~ ?_ 6, 1996 true vertical 8906 - 8927'; 9001 - 9011" 9015 - 9039'; 9045 - 9061' Alaska 011 & GasCons. Commission 20. Attachments Filing fee ~x Property plat __ BOP Sketch ~ Diverter Sketch _ Drilling program Drilling fluid program__ Time vs depth plot_ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~¢eSJ[.;c)nS ? Co-Il po.~ Signed ~'~,W~/ ~, ;'~'/',&,,,.~ Titlle Engineering Supervisor Date ¢/2--5-/% .¢ ~ Commission Use Only Permit Number ?~'~ .,.- /r~--~./r I o z¢_.zo ? 4,.~_~ ~ Approval date ? ]/~ "C~(o Isee c°ver letter f°rother requirements Cohditions of al~proval Samples required ~Y e s ~ N o' Mud Icg required__ Y e s .~ N o Hydrogen sulfide measures ~ Y e s __ N o Directional survey required /~ Yes N o Required working pressure for BOPE ~2M; __ 3M' __ 5M' __ 10M' __ 1 5M '~ 3500 psi for CTU Other: Original Signed David W. J0hnst0n by order of Approved by Commissioner the commission Date ~ " Form 10-401 Rev. 7-24-89 Submit in triplicate DS 13-27A CT Sidetrack and Completion Intended Procedure Objective; Directionally drill N1675' horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: P&A existing interval. Mill window in 7" casing at -10,330' md. Build angle to horizontal (87°) at-~32°/100'. Directionally drill-~1675' horizontal to access upper Zone 4 reserves. Run and cement 2-7/8" liner to TD. Perforate selected intervals. Return well to production. June 25, 1996 DS 13-27A Potential Drilling Hazards POST ON RIG The last test for H2S production was 12 ppm on 3/23/96. B HP: 3420 psi @ 8800' ss (7.5 ppg EMW), B HT 220 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/ full column of gas: 2800 psi. No gas saturated intervals are expected. Faulting and fractures in the Shublik interval can lead to lost circulation. Have plans in place in the event LC occurs. o/i ~ c-,,: ,-., .... ~. 5,','.~ · June 25, 1996 DS 13-27A Items in Bold to be installed by Coiled Tubing Proposed Sidetrack 4-1/2" Tubing 2196' 4-1/2" Camco BAL-O SSSVN (3.813' ID) 9-5/8' SAB Pkr. 4-1/2" XN Nipple 4-1/2" Tubing Tail 9985' 10,083' 10,100' 10,038' 7" Liner Top Top of Uner -10,050' -- 2-7/8" FL4S liner 9-5/8" Casing Shoe @ Original perforations cement sqz'd. 7' Liner Shoe 10,322' 10,686' Window Cut in 7" casing with CTU @ 10,330' f 3-3/4" Open hole RECEIVED JUN 2 c i99~ Ceme. nted~-,7/8" F. L4S Niner, TO @ + 12,188' 6118/95 DTK ARCO ALASKA INC. 13-27 SIDETRACK PRUDHOE BAY ALASKA i i ~ ST-00T : Directional Sidetrack in True Relative Coordinates 13-27TRU : OriginaIWell Bore ARCO ALASKA iNC. 8700 9100 1 KOP Br 0°/100 Tr 0°/100 HOLD MD 10300 25.7° __~ 2 DI 35.82°/100 Tf0° '-~MD 10330 ~5-7° ~3 DJ14.59°/10~-~ Tf 9~"--~.5~ -~ ------'"''" 4 TD 8980.2 SS MD 12177 89.0° Vertical Section Scale I inch · 400 ft Plane of Vertical Section 214.62° Ref. From True North of Tie In Point. · North Ref. to True True (+0) /~ Mag (+29.63) E/W Scale 1 Inch ' 800 ft File Name · C:LARCOALK\13-27\13-27A1 Drawn By · Bimo Hadiputro Date · June 16. 1996 1 St-OOsum 6/14/96 6:39 PM ONE MINUTE SUMMARY OF THE WELL PLAN. ARCO 13127 SIDETRACK AT 10300' MD PREPARED FOR DAN KARA (PE - ARCO) ff deg deg ~ ~ ' ' ' ~ ~ degll00 degil'00 degll00 ft .... ft ...... ' i'0300"6 ...... ~i~ ........ i~'~)-]~ 88021~ ......... 01~ ]37911~ ~'8541~ ...... ~j~'~i ............ b~ ............. ~'~ 59268i9'.5~ ..... 688015.~0 1~ TIE IN POINT 10330.0 25.7 179.3 8829.5 10.6 -3804.8 1854.9 0.0 0.0 0.0 5926806.50 688016.00 2. KOP ~ 35.8°/t00. HS 10502.8 87,6 ...... 179'.3 ...... 8920~0 ............. i22.7 ..... ~3942.1 ..... 1856~5 .......... 35.8 .............. 0~0 ........ 35'~8 5926669'~00 688020~90 3. EOB, 8920 SS REACHED TURN RIGHT 4.5901100. DLs 12177.8 ......... 89~0 ............ 2~'~'~'~': ............... 8-9~'~' ................ -~"~'?¥~'~ ........ ~-~'~-?'~; ....... i ................................... L .................................................................................................................................... VERTICAL SECTION USED , : 174.54° Relative to true Nodh NOTE ~ ' · Relative Coordinates are off of true Nodh/ASP are relative to grid Nodh , . / . ' ' .... COUVE. EUC :. : 1 St-O0 6/14/96 6:37 PM I I ARCO 13-27 S!DE..TRACK AT 10300' MD PREPARED FOR D,~N KARA !PE ,ARCO) .... MD Inc. Dir SS DEPTH VS NI-S EI-W Build Turn Dogleg ASP Y ASP X Comments 10300.0 25.7 179.3 8802.5 0.0 -3791.8 1854.7 0.0 0.0 0.0 5926819.50 688015.50 1. TIE IN POINT ..... ~)-:~i'~)' .............. '~:'~ ............. ~"~-~:'~ ............. §8201~' .................. ~'i'{ ........ ~§§~':~ ......... ~'~'~,'i'§ ........... ~'~ .............. -~i~ ............... ~'i~" 5926810.50 688015.80i ............. 10350.0 32,8 17g.3 8846.g 18.6 -3814.5 1855,0 35,8 0,0 35.8 5g267g6.50 688016.30 10380.0 43.6 179.3 8870.5 33.7 -3833.1 1855.2 35.8 0.0 35.8 5926778.00 688017.00 ' ,i 10410.0 54.3 179.3 8890.1 52.1 -3855.7 1855.5 35.8 0.0 35.8 5926755.50 688017.80 10440.0 65.1' i79.3 890513 73.3 ~388'~'.5 185~.8 35.8 0.0 35.8 5926729.50 '688018.80 ~04~.0 ~.8~' ~7(~i':~ 89~'51:~' .... 9(~13 ~:~909.~ ~i~i~' ~5.8 0.0 35.8 5926701.50 688019.80 10500.0 86.6 179.3 8919.9 120.5 -3939.3 1856.4 35.8 0.0 35.8 5926672.00 688020.90 ;J ~J~:'8 §:~ i~ ...... 'J ;~(~:':~ ........ ~§;~":~)' ~ ~'~:;~ ....... :,~i;J ....... ~"§'~':~) .............. -:~:'§ ................. '~J:~ ........ ~,~:§ ~'~:'~ ..... ~'~':~'~" 3:-'E'~B'~-89'20' SS REA'CHED TURN 'RIGHT 4.5g°/100' DLS 10530:0 87.6 180,6 892'1':2 ...... 14'5.1 :3969.3 i856:5 ............. 0','0 ............. '4:6 4:6' 5926642.00 688021'.60 90:5~-boL-FA~-E ................ 10560.0 87.5 182.o 8922,.5 17o.1 -3999.3 1855.8 o,o 4.6 4.6 5926612.00 688021.80 7.5 ',. ::. "~'06~0:0 ~7.~ i~:?' 8925.0 221.4 -4059.1 1852.3 ....0,0' '4:6 4:~ 5926552.00' 6880~'9.70 10650.0 87,5 186.1 8926.3 247.5 -4089.0 1849.5 0.0 4.6 4.6 5926522.00 688017.60 10680.0 87.51 187.5 8927.6 274.0 -4118.7 1846.0 0.0 4.6 4.6 5926492.00~ 688014.80 10710.0 87.5 188.9 8928.9 300.8 -4148.4 1841.7 0.0 4.6 ......... ~:~ '~~:~ ~'~:~ ~-- -~-~:~ ..... 87.5 190.2' 8930.2 328.0 -4177.9 1836.8 0.0 4.6 .......... ~':~ ~2~'~:~ ...... ~007:'1~- ..................................... ~77~.0 ~?.~ ...... ~-:6 ~:5 ~.4 '-~207.~ i~.i- .... 0:~ ~.~ ~.6 5~26~03.50 "~b02.i~ 10800.0 ~87.5 193.0 8932.8 383.2 -4236.7 1824.7 0.0 4.6 4.6 5926374.00 687996.40 10830.0 ~:~7.~- 1~ 8934.2 411.1 -4265.8 1817.6 0.0 4.6 4.6 5926344.50 687990.10 ~6~.~ ~'~.~:~:.~'-~ '~5.~ - ~39.4 -~9~.~' i~09.~ - ~.~ ~.~ 4.6 ~9~3~.~0 ~87~83.00 .... ~-~9~:~ ~:~- ..... ~-~-- 8936.8 .......... 4~:~ .... :~:~ ...... ~8~:~ ...... 0~0 ......... ~:~ .......... ~:~ 5926286.50 687975.30 ........................... 10920.0 -~,..~:'87.5~ i~- 8938.0 496.6 -4352.0 1792.2 0.0 4.6 4.6 5926257.50 687966.80 ~ ............................................... 10950.0 ~ <_,87.~ 1~ 8939.3 525.~ -4380.3 1782.3 0.0 4.6 4.6 5926229.00 687957.60 2 St-O0 6/14/96 6:37 PM 10980.0' 87.6 201.3 8940.6 554.5 -4408.4 1771.8 0.0 4.6 4.6 5926201.00 687947.80 ..... 1-~"~J~'~6 ............... §'?i~ .......... ~i:J21~ ~4'1-'i{) ............... ~,'§~i'~ .... :44~3~i~ ~ 7661~ ............. 616 ~,'16 ......... ~,'i~' '~9~'~73.0(J ~i~7'~7 11040.0 87.6 204.0 8943.2 613.2 -4463.7 1748.7 0.0 4.6 4.6 5926145.00 687926.10 11070.0 87.6 205.4 8944.4 642.7 -4490.9 1736.2 0.0 4.6 4.6' 5926117.50 687914.30 11100.0 87.6 206.8 894517' 672.3 ',451'7.8 1723.0 0.'i 4.6 4.6 5926090.00 687901.80 11130.0 87.6 208.2 8946.9 702.1 -4544.4 1709.2 0.1 4.6 4.6 5920063.50 687888.00 11160.0 87.6 209.5 8948.2 731.9 -4570.7 1694.8 0.1 4.6 4.6 5926036.50 687874.80 '~1i~j~)i0 '87.'~ 2i'0.9 §94914 ' 7(~i.8, -459~.6 ~79.? o.i 41~ 416 59f)60~0150' '11250.0 87.7 21:~.7 §95118 8~i.7 ':464~.3' i647.7 ..... 0.i ~ . ~ 4.6 ,~(Jf),~959.60 ~§7829i66 11280.0 87.7 215.0 8953.0 851.6 -4672.0 1630.8 0.1 4.6 4.6 5925934.00 687813.30 ...... ~-~'~1--0'~'~)- ........ 8-~-i~- ......... 216.4 8954.2 881.6 .... -~-~(~'~, ..... ~-~-~ ............. D-['I- ............... ~'~ ......... ~,(~" 5925909.00"--~7'?~i'4-~ ...... ~1-'~4~16 ............. §71'8 ............ f~'~'?]-§ ............... ~{~F~iZ~ .................. ~'~'"Ji~ ...... ]47~'i,~ ....... ~9,~ ............ 6]-~ ...................... ~) ................... 4']~ ~2-~8-§~]'~)~J ....... ~§??-~'§i~'6 .............................................................. 'i137010 '87.8 219.2 895616 94i.5 -4743.7 1576.5' 0.1 4.6 4.~ 5925861.00 687760.80 11400.0 87.8 220.6 ;895717 971.3 :4766.8 i55;~.3 0.i 4.6 4'J~ 59~)5837.50 .... i"':I430'iO' ............ 8719 .......... 22'i'~i'9 ................ 89'~§1'8 ........... .~"i"0-0:1'11 ...... ~4789,'3 ....... i"53':F'15 .......... O.'1 ................. ~'~- ............. 416 ..... 5925814'.'50 ..... 68~7'2219'0 11460.0 87.g 223.3 8959.9 1030.8 -4811.4 ..... 1-~'~i§ ....... b'i'{ .................. 4-i~ ............ ~,'ii~- 5925791.50 ....... 11520.0 88.0 226.1 8962]:1' ' i089.8 -4854.0 i47~.1 0.1 4,6 4i6 5925748.00 687662.i0 ...... ~-~'~5-~i~J .......... ~§i~J ......... 2-~i~ ......... §'~'~§i~'~ ........ -~"1--~i~- ..... "~§~Z~i~ ......... ~,~§i'~ ........ 61'1-- 4.6 ........... ~,~i~- 5925727.00'-~;{'618~ .... i1'580'.0 ......... 88.0 ........ 22~'.'8 ........ 89~41'2 ......... i'-i'48.3' .... ]4894.5 ...... 143019 ......... 0'.1 ............ ~i~ .......... 4]'6 59257061-50 ....... 687619.00 ..... ~:~'~.~ ....... ~§.:i .......... ~,~]'~ ...... ~'{~i~ ........ i'~.~ -~,c~:1"~,.6 'J40§.~ ..... (Ji'~ ..... 4'.~' 4.~ 59~56~6.~0 "~87~96.76 11640.0 ~88.1 231.6 8966.2 1206.0 -493ffi~ ...... ~§§4.9 01¥........... 4.6 4.6 5925667.00 --~8-~5-~§1'9-6 --~'1670.0_i~_~'~i~~ 232.9 8967:2 1234.6 -4951.3 1361.2 0.1 4.6 4.6 5925648.00 687550.60 11700.0 f;'.~88.~ 2~ 8968.1 1263.0 -49691~ 1337.0 ..... -6-~-~- .... 4~ ......... ~,i~ 5925629.50 .... ~§~'~)~19-~ ...................................... ---i-1'~0'i0'~81~'"-~'- ............ -8~)9-] .... ~1-2-9:i-11- .... :4986[-:~ ....... ~§i-~i~ ........ 5[-'1-" 4.6 ............ 416 F-~-9~i~-~0'--~50'2]'8-~- ~6-~i~ ~ ~-8~'-~.~ ~ "-~- '- ¥:f~'ic5 .... :~j~6~ic5 ..... ~-~[~ ....... 61-~ ............. ~:~ ....... ~,'i~' ~,~9~'i-~0----~§~§,§~ ..................................... 11790.0.~ ~8.3 ~ ~ 897019 1346.5 -501'8.9 i262.1 0.i 4.6 4.6 5925578.00 687453.30 11820.0' .~8.4,,~; ;~ ~g7-i.~ i~'~.~' -~i33~,.'~ ' ~.:~]4 "' 01i J,J~ .... ~,'i~' ~§~-,~6'~]~ "~-'~'~]{)'6 ' i18~5o.0 ~8.4 8972.6 i4o0.7 i564~.0 i21-013 0.2 4.~ ....... _4_-.16 5925546.'5~ ~87462.2o ......................... 3 St-00 6/14/96 6:37 PM 11880.0 88,5 " 242.6 8973.4;" 1427.4 -5063.1 1183.8 0.2 4,6 4.6 5925532.00 687376.10 11910.0 88,5 244.0 8974.2 1453.7 -5076.6 1157.0 0.2 4.6 4.6 5925517.50 687349.60 11940.0 88,6 245.3 8975,0 1479.7 -5089.5 1129.9 0.2 4,6 4.6 5925504.00 687322.90 11970.0 88.6 246.7 8975.71 1505.3 -5101.6 1102.5 0.2 4.6 4.6 5925491.50 687295.80 12000.0 ~8.7 2~,8.i 8976.5~ 'i530.5' -5i1'3.2 'i07;4.9 "'O'.'~l ~,.6 4.6 59254;~9.00 ~87~8.40 12030.0 88.7 249.5 897712 1555.3 "L5124.0 "104619 " 0.2 416 ' 416 5925467.50 687240.70 12060.0 88.8 250.8 8977.8 1579.7 -5134.2 1018.7 ....... 0-:~ ......... 4.6 4.6 5925456.50 687212.80 12090.0 88.8 252.2 8978.5 1603.7 -5143.7 990.2 0.2 4.6 4.6 5925446.50 687184.60 12120.0 88.9 253.6 8979.1 1627.2 -5152.5 961.6 0.2 4.6 4.6 5925437.00 687156.10 12177.8 ..... 89.0 25'612 898012 .... 167'i'.3= _5167.6 90518 0.2 416 .... 4'16 5925420.50 687100.70 41 TDREACHED 8980 SS VERTICAL SECTION USED · 174.54° Relative to true North 1- ............................................................................................................................................................................................................................ ...................NOTE ~_. .................... .~[. ................................................ '. Relative Coordinates are off of true Nodh/ASP are relative to grid Nodh................................... IL L iGRID CONVERGENCE' , ' 11.410 ~ i I ~ I [ ~ C T Drilling Wellhead Detail ~ CT Injectm' Head Me b'-~-,ol Injection Alignment Guiele ~., 7-1/16"', 5M Ram Type Dual Gate BOPE Flanged Fire Resistant ~ VaJve Ketly Hose To Dual \ ~ifoid X ~ Stuffing Box (Pack-Off), 10,0(X) psi Working Presaxe Annular BOP (Hyddl),7-1/16" ID 5,000 psi worldng pressure Combination Cutter/Blinds Slip/Pipe rams Manual Valves Drtng spool 7-1/'16', 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16' ID with Pipe/Slip Rams 0.458' (5.5') Mammi Master Valve 2' Pump-in Fire Resisla~l Kelly Hose to Flange b~ ~Up 1/4 Turn Valve on DS I-.lardllne 10' from Tree Tubing Hanger 9-5/8' Annulus 13-3/1~' Annulus 60/40 I Trplx I Shop Fu~l Boi~r~ Water Mud Pump Room Ext. Pipe rack Preferred Major Equipment Layout for CT Drilling Dowell Drilling Equipment Trailer Ext. ,~-. STATE OF ALASKA ALASKA _AND GAS CONSERVATION COb 3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation shutdown Alter casing Repair well Plugging X 2. Name of Operator ARCO Alaska, Inc. Change approved program 3. Address P.O. Box 100360, Anchorage, AK 99510-0360. Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service 4. Location of well at surface 526' FSL, 1185' FEL, Sec. 14, T10N, R14E, UM. At top of productive interval 3319' FNL, 674' FWL, Sec. 24, T10N, R14E, UM. At effective depth 3416' F_NL, 680' FWL, Sec. 24, T10N, R14E, UM. At total depth 3435' FNL, 681' FWL, Sec. 24, T10N, R14E, UM. 12. Present well Condition summary · Total depth: measured 10690 feet true vertical 9237 feet Re-enter suspended well Time extension Stimulate Perforate Othe'r 6. Datum of elevation(DF or KB) 83' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-27 9. Permit number 83-67 10. APl number 50 - 029-20949 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10473 feet true vertical 9042 feet Plugs(measured) PBTD Tagge0~0¢~'~(1/~7~.~5). Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80' 16" 2115# Poleset 80' 80' Surface 2550' 13-3/8" 2700 Sx CS III & 400 Sx CS II 2633' 2633' Production 10239' 9-5/8" 500 Sx CIG & 300 Sx CS I 10322' 8904' Liner 648' 7" 265 Sx CIG 10686' 9234' Perforation depth: Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, PCT @ 10100' MD. RECEIVED measured 10323 - 10346'; 10429 - 10439'; 10444 - 10470'; 10477 - 10495' JUN ~ ~ 1996 true ver[ical 8906 -8927'; 9001 - 9011'; 9015 - 9039'; 9045 - 9061' Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Baker SAB Packer @ 9985' MD; 4-1/2", Camco BaI-O SSSV @ 2196 MD. 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x Approved b~/order of the Commissioner Form 10-403 Rev 06/15/88 Original Signea By David W. Johnston JApproval No.q ~.. Approv6dr6h3ip¥ioner Returned FOR COMMISSION USI= ONLy Conditions of approval: Notify Commission so re_/pr?sentative may witness Plug integrity 4,,;" BOP Test v Location clearance Mechanical Integrity Test Subsequent form required 10- F~ ~' 14. Estimated date for commencing operation 15. Status of well classification as: July 25, 1996 16. If proposal was verbally approved Oil X Gas Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ues't'~o~qs ? ~',,.J J J~,,,~ ~..co.. Signed ~¢,~ '~,t. ~ Title Engineering Supervisor Date WELL PERM IT "' "-'"'"'""-' C O M P A N Y,~. ~..(~_ .,'~"~) ADMINISTRATION 1. Permit fee attached ....................... I.Y~ 2. Lease number appropriate .................. 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from drtg unit boundary ..... 6. Weii locsted proper distance from other wells ......... 7. Sufficient acrea? available in drilling unit ........... .I.Y IN 8. If deviated, is weilbore plat included ............. 9. Operator only affected party .................. 10. Operator has appropriate bond in force ........... 11 Permit can be issued without conservation order 12. Permit can be issued without administrative approval .... 13. Can permit be approved before 15-day wait ......... ENGINEERING REMARKS APPR DATE 14. Conductor string provided ................... ~ N 15. Surface casing protects ail known USDWs ......... ¢_Y_t N 16. CMT vol adequate to circulate on conductor & surf csg . . . I..Y. I N 17. CMT vol adequate to de-in tong sluing to surf csg ...... (..Y. ~ N 18. CMT will cover ail known productive hodzons ......... .'kY./N 19. Casing designs adequate for C, T, B & permafrost. ...... ,,,-.(~¢5 N 20. Adequate tankage or reserve pit ............... ~N' (,,Y_.~N Y 21. If a re-drill, has a 10.403 for abndnmnt been approved... ¢_~,~ 22. Adequate wellbore separation proposed ............ 23. If diverter required, is it adequate ................ "~ 24. Drilling fluid program schematic & equip list adequate .... '.~ N 25. BOPEs adecluate ........................ (_Y2 N 26. BOPE press rating adequate; test to ~ 5'-~c.3 psig. ~ N 27. Choke m~ifold complies w/APl RP-53 (May 84) ....... "'~ N 28. 7ork will occur without operation shutdown .......... ,.¢~k ,N 29. l., presence cf H2S gas probaz:le ' v ~i GEOLOGY ,~ ,, ,// 30. Permit can b~ issued w/o hvdroaen sulfide measures ..... Y N,,/ ,~ ) ,,,,¢ 31. Data presented on potenti~ ove~ressure zones ....... Y 32. Seismic .~2_.J~.,sls of sn..~lcw g~ zones ............. .~o. ~=¢.~ed con~,,,on survey (ff o,,-o, ,o, e) ........... 2/f.Y ~ '~ /~ rl ' r - I [ 34..,.,on=~', nme, ~, ,o, .e fo, wee.kJv progress reports .... /4'... Y N GEOLOGY: ENGINEERING: COMMISSION: JDH %.'¢;~ ,~//~ JDN TAB Comments/ins~uctions; HOW4~- A:FC'RN S~c..he~l~ rev 4/r.~ Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history' file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Reel Header Service name ............. LISTPE Date ..................... 97/08/25 Origin ................... STS Date //~/~ Reel Name ................ UNKNOWN Continuation Nu~er ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Mon Aug 25 15:20:00 1997 Tape Header Service name ............. LISTPE Date ..................... 97/08/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-70153 C. JACKSON ARVILLE BASS DS 13-27A 500292094901 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 25-AUG-97 MWD RUN 4 AK-MW-70153 C. JACKSON ARVILLE BASS MWD RUN 5 AK-MW-70153 C. JACKSON ARVILLE BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 6 AK-MW-70153 C. JACKSON ARVELL BASS MWD RUN 7 AK-MW-70t53 A. WORTHINGT GARY GOODRIC 14 I0N 14E 526 1185 RECEIVED AUG 2 7 199'¢ Ai~a Oil & Gas Cons. Oommi~ior, An~omge FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 83.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 10322.0 2ND STRING 7.000 10686.0 3RD STRING 4.500 10100.0 PRODUCTION STRING 3.750 12674.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL TRUE VERTICAL DEPTHS (TV]D) ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD). 3. MWD RUNS 1 AND 3 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUNS 2 AND 4 THROUGH 7 ARE DIRECTIONAL WITH NATURAL GAM~4A RAY PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 5. GAMMA RAY DATA FROM 10664'MD, 9010'SSTVD TO 10841'MD, 8997'SSTVD ARE -OBTAINED FROM A MEASUREMENT AFTER DRILLING (MAD) PASS MADE WHILE LOGGING OUT OF THE HOLE PRIOR TO MWD RUN 5. 6. DEPTH SHIFTING/CORRECTION IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN DOUG KNOCK OF ARCO ALASKA, INC. AND ALI TURKER OF SPERRY-SUN DRILLING SERVICES ON 8/19/97. 7. MWD RUNS 2 AND 4 THROUGH 7 REPRESENT WELL 13-27A WITH API#: 50-029-20949-01 THIS WELL REACHED A TOTAL DEPTH (TD) OF 12674'MD, 8974'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRD-M= SMOOTHED GAMMA RAY FROM MAD PASS. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUI~ARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10431.5 12646.5 ROP 10457 . 0 12672 . 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 10457.0 10610.0 4 10610.0 10860.0 6 10865.0 11654.0 7 11654.0 12672.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10431.5 12672 11551.8 4482 10431.5 GR 21.04 173.97 36.012 4431 10431.5 ROP 17.47 1456.1 106.925 4431 10457 Last Reading 12672 12646.5 12672 First Reading For Entire File .......... 10431.5 Last Reading For Entire File ........... 12672 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH STOP DEPTH 10663.5 10841.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 5 1 10860.0 10865.0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD AAPI 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 10663.5 10841 10752.2 356 10663.5 GR 24.6 145.49 52.4101 356 10663.5 Last Reading 10841 10841 First Reading For Entire File .......... 10663.5 Last Reading For Entire File ........... 10841 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10431.0 10609.5 GR 10431.5 10573.5 $ LOG HEADER DATA DATE LOGGED: 25-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.0 MAXIMUM ANGLE: 63.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10610.0 10457.0 10610.0 TOOL NUMBER NGP SPC 321 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: I~JD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 FLO-PRO 8.80 .0 8.0 5.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MwD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 84.4 First Name Min Max Mean Nsam Reading DEPT 10431 10609.5 10520.2 358 10431 GR 25.14 173.97 46.471 285 10431.5 ROP 17.47 1608.1 291.988 358 10431 Last Reading 10609.5 10573.5 10609.5 First Reading For Entire File .......... 10431 Last Reading For Entire File ........... 10609.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Corament Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10574.0 10662.5 ROP 10610.0 10860.0 $ LOG HEADER DATA DATE LOGGED: 26-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 91.8 MAXIMUM ANGLE: 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10860.0 10610.0 10860.0 TOOL NUMBER NGP SPC 321 3.750 3.8 FLO-PRO 8.80 .0 8.7 FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.9 .000 · 000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 75.3 First Name Min Max Mean Nsam Reading DEPT 10574 10860 10717 573 10574 GR 24.81 160.62 45.4563 178 10574 ROP 29.67 1456.1 106.535 501 10610 Last Reading 10860 10662.5 10860 First Reading For Entire File .......... 10574 Last Reading For Entire File ........... 10860 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10842.0 11623.0 ROP 10866.5 11654.0 $ LOG HEADER DATA DATE LOGGED: 27-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.2 MAXIMUM ANGLE: 97.4 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 11654.0 10865.0 11654.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 288 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 8.8 7.4 · 000 .000 .000 .000 84.4 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10842 11654 11248 1625 10842 GR 21.15 75.03 33.0429 1563 10842 ROP 37.79 222.9 104.562 1576 10866.5 Last Reading 11654 11623 11654 First Reading For Entire File .......... 10842 Last Reading For Entire File ........... 11654 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Fhysical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUM/WARY VENDOR TOOL CODE START DEPTH GR 11625.0 ROP 11654.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12646.5 12672.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 29-MAY- 97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 12672.0 11654.0 12672.0 83.4 93.5 TOOL NUMBER NGP SPC 288 3.750 3.8 FLO-PRO 8.80 .0 8.8 7.4 .000 · 000 .000 .000 .0 .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11625 12672 12148.5 2095 11625 GR 21.04 137.77 33. 116 2044 11625 ROP 27.39 659.2 113.946 2036 11654.5 Last Reading 12672 12646.5 12672 First Reading For Entire File .......... 11625 Last Reading For Entire File ........... 12672 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and lo9 header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 1 FILE SUM~gARY VENDOR TOOL CODE START DEPTH GR 10663.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10841.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE 2 6-MAY- 97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10865.0 10860.0 10865.0 95.2 95.2 TOOL NUMBER NGP SPC 164 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record 3.750 3.8 FLO-PRO 8.80 .0 9.0 5.8 .000 .000 .000 .000 .3 82.0 Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR Service Order Units Size Nsam Rep FT 4 1 68 MAD 5 AAPI 4 1 68 Code Offset 0 4 Channel 1 2 Name Min Max Mean Nsam DEPT 10663.5 10841 10752.2 356 GR 24.6 145.49 52.4101 356 First Reading 10663.5 10663.5 Last Reading 10841 10841 First Reading For Entire File .......... 10663.5 Last Reading For Entire File ........... 10841 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/25 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/08/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File