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206-003
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED MAL) 0 0 nA'n Is, Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 • Suspended ❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero Developmen wMplaefenL ig j�>+Tb� 1hA•st1�0- Service ❑ S 2. Operator Name: 6. Date Comp., Susp.,trid.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 3/2/2019 206-003 • 318-366 3. Address: 7. Date Spudded: 15_ API Number: P.O. Box 196612 Anchorage, AK 99519-6612 2/18/2006 50-029-20570-02-00 - 4a. Location of Well (Go temmental Section): 8, Date TO Reached: 16. Well Name and Number: Surface: 1534' FNL, 527' FWL, Sec. 24, T10N, R15E, UM • 2/24/2006 PBU 16.148 ' 9 Ref Elevations KB 87 0 17. Field/Pool(s): Top Of Productive Interval: 1858' FSL, 1894' Flki, Sec. 13, TION, R15E, UM GL 37.06 BF 37.73 PRUDHOE BAY, PRUDHOE OIL ' Total Depth: 3503' FSL, 710' FWL, Sec. 18, T10N, RmE, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 7499'18904' ADL 028332 & 028346 - 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 719306 • y- 5929396 Zone - ASP 4 15307'18990' 79-081 TPI: x- 720573 y- 5932826 Zone - ASP 4 Total Depth: x- 724618 y- 5934591 Zone - ASP 4 12. SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MDfrVD: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Wndm Submit electronic and printed information per 20 AAC 25.050MDr N/A (ft MSL) VD: • 9916'/8835* 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD/GR/RES/ABI, CBT/GR/CCL 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 94# 1440 31' 111' 31' 111' 32" 300 sx Permafrost 13-3/8" 72# L -ac 30' 2672' 30' 2672' 17-1/2" 3000 sx Fonou, 1250 sx Permafrost 9-5/8" 47# L-00500.95 27' 8963' 27' 8073' 12-114" 500 sx Class'G' 7" 26# L-80 8773' 9916' 7915' 8835' 8-1/2" 288 sz Class'G' 4-1/2" 12.6# L-80 9795' 15307' 8741' 8990' 6-1/8" 643 sx Class'G' 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.8# L-80 7610'- 9805' 9665'/ 8637' —i �`2Ja1yal 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE 2 y Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed Yes ❑ No 0 information t�IFIE� DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Dale First Production: Not on Production Method of Operation (Fb ing, gas lift, etc.): NIA Data of Test: Hours Tested: Production for Test Period —..► Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: Flow Tubing Press Casino Press: I Calculated 24 Hour Rate �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil GnwiN- API(oom: Form 10.407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only 4eYl;-Of '" &Ka* I4t RBDMS MAR 2 9 2019 -"e> - ' �G 28. CORE DATA Conventional Corals) Yes ❑ No IM Sidewall Cores Yes ❑ No IZ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No ® - Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10387' 9036' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. CGL - Zone 3 10184' 8987' Base of CGL - Zone 2 10387' 9036' Formation at total depth: Zone 2 10387' 9036' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Mingle, David Authorized Title: S cialist0.0. Contact Email. Davitl.Minge@bp.com Authorized Signature: ate: /yvl) Contact Phone: +19075845279 INSTRUCTIONS General: This form is designa for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 41b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071, Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Forth 10407 Revised 512017 Submit ORIGINAL Only WELL NAME: 16-14B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9433' 35 Bbls Class'G' 9398'- 9403' Tubing Punch 8164' 51.5 Bbls Class'G' 7610' Cut & Pull Tubing 7499' Set Whipstock Daily Report of Well Operations 16-14B ACTIVITYDATF ci inenenov T/I/O=SSV/250/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre rig. PPPOT-T: Stung into test void (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Function LDS, all moved freely. Torqued to 500 Ib/ft. Single port, unable to pump through void. Pressured void to 5,000 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void (100 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Function LDS, 5 gland nuts were stuck to the LDS. Broke free and functioned. Pumped through void, good returns. Pressured void to 3,500 psi for 30 min test, lost 0 psi in 10/19/2018 15 min, lost 0 psi in second 15 min PASS). bled void to 0 psi. T/I/0= SSV/255/17 Temp= S/I (Injectivity Test) Pumped 10 bbls 60/40 followed by 596 bbls -112*F 1 % kcl down TBG during injectivity test (See log for details and emailed graph to fullbore) followed up with 38 bbls crude down TBG to freeze protect. Wing shut swab 11/8/2018 shut ssv shut master open casing valves open to gauges Final Whp's=1300/360/56 Initial T/1/0= Vac/265/15 Temp=S/1. (SLB - Reservoir P&A) Schlumber pumps the following down the tubing: 10 bbls 60/40 meth spear 360 bbls 9.8 ppg brine 35 bbls 15.8 ppg Class G Cement ***Estimated TOC = 9900' MD/8822' TVD*** s freshwater LRS pumps the following down the tubing: 144 bbls 70* diesel displacement Valves positions upon departure: SV, WV, SSV=Closed. MV=Open. CV=OTG 12/24/2018 Final T/I/0= 500/280/12 psi T/I/00/270/10 (LRS Unit 76 -Assist SLB Cementers: Displace Reservoir Cement Plug) Displaced cement w/ 133 bbls Diesel. Slowed rate to 1 BPM. Pumped an additional 10.6 bbls down tbg before Tbg. locked up. held squeeze for 30 min @ 3000 SV,WV,SSV Shut. MV,IA,OA Open 12/24/2018 FWHP=500/280/12 12/24/2018 (LRS Unit 46 - Assist SLB Cementers: Heat Diesel) Heat CH2 tanker of diesel to 70* ****WELL S/I UPON ARRIVAL**** (Pre -Sidetrack) RAN 3.0" CENT, 4-1/2" BRUSH TO BPV PROFILE (Brushed for 30 minutes) DRIFTED W/ 4-1/2" XN LOCATOR, 20'x 1-3/4" DD BAILER, S/D @ 9,386' SLM (Sample of cement & foam ball) DRIFTED W/ 2-1/2" SAMPLE BAILER, TAGGED TOC @ 9,433' SLIM (AOGCC witnessed by Austin McLeod) LRS PERFORMED PASSING MIT -T TO 2,500 psi AOGCC witnessed by Austin McLeod BEGIN PDS MTT LOG FROM TOC TO SSSVLN PER PROGRAM 12/29/2018 ****CONT JOB ON 12/30/18**** T/1/0=0/2785/10 (LRS Unit 76 - Assist Slickline: AOGCC MIT -T) MIT -T PASSED to 2713 psi (2750 Max, 2500 Target) (AOGCC witness by Austin McLeod) Pumped 4.2 bbls down Tbg. to reach test pressure. Loss of 19 psi 1 st 15 min, Loss of 8 PSI 2nd 15 min. Casing valves OTG. S -Line on location upon departure 12/29/2018 FRHP=0/275/0 ****CONT. JOB FROM 12/29/18**** (Pre -Sidetrack) COMPLETE MTT LOG R/D SLICKLINE UNIT SWCP #4522 12/30/2018 ****WELL LEFT S/1 & DSO NOTIFIED OF STATUS UPON DEPARTURE**** Daily Report of Well Operations 16-14B ***WELL SHUT IN ON ARRIVAL''* (ELINE TUBING PUNCH) INITIAL T/1/0=0/250/0 MIRU E -LINE 1/1/2019 ***JOB CONTINUED ON 1/2/2019*** ***JOB CONTINUED FROM 1/1/19*** RIH W/ 4 SPF TUBING PUNCHER/SPD. OAL = 36',MAXOD = 1.69" CCL TO TOP SHOT=5.7' CCL TO BOTTOM SHOT= 10.7' CCL TO BOTTOM OF TOOLSTRING=13.8' SHOT TUBING PUNCHER ACROSS COLLAR AT 9400'. TUBING PUNCHED FROM 9397.5 - 9402.5'. CCL STOP DEPTH--939T-8— TIED INTO TUBING TALLY DATED 03-05-2006 ESTABLISH COMMUNICATION WITH IA BY PUMPING DOWN TUBING WITH TRIPLEX 1/2/2019 FINIAL TWO = 980/360/0 PSI. SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment w/balanced cement plug TBG x IA Pumped 5 bbls 60/40 meth, 290 bbls FW @ 140 deg. 446 bbls of 9.8 brine, 2 bbls freshwater spacer, 51.5 bbls of 15.8 ppg class G cement 2 bbls freash water and shut down pumping. Llned up to launch two seven inch foam balls behind cement. Back on line w/1120 bbls 9.8 ppg NaCl, LRS pumped 18 bbls of diesel. Line up TBG & IA to Utube diesel into IA. Left LRS to handlle Utube of diesel after placement. Secured area and had grease crew service all valves on tree & wellhead. 15.8 ppg Class G cement in TBG & IA from 8332' MD/ 7594' TVD to 9400' MD/8423' TVD 1/3/2019 T/1/0=937/387/22. Assist Cement crew. Pumped 5 bbls 60/40 meth down tbg taking returns up IA to open tops, followed by 289 bbls of 135*F fresh water, then 446 bbls 9.8 brine. Flush surface lines to open tops with 3 bbls 60/40, followed by 2 bbls diesel (to displace McOH from hardline for cement) Pumoped 4 bbls DSL to FP surface lines. 1/3/2019 Pumped 18 bbls DLS down TBG for U-tube and FP. FWHP=310/294/0 ***WELL S/I ON ARRIVAL***(side track) (post fb cement circ) RAN 4-1/2" BRUSH AND 3.00" CENT TO BPV PROFILE BELOW TREE. RAN 2.80" CENT, 2.50" S.BAILER TO 7874' SLM, WORK TO 7945' SLM (Sample of foam ball) RAN 2.80" CENT, 2.50" S.BAILER TO 8091' SLM (Bailer full of foam ball, trace of cement) RAN 2.80" CENT, 2.50" S.BAILER TO 8092' SLM, WORK PAST & RIH TO 8164' SLM 1/4/2019 (Sample of cement T/1/0=vac/O/26 Temp=S1 CMIT-TxIA, OA integrity test. Pumped 8 bbls -5* diesel down TBG & IA to reach CMIT-TxIA 4000 psi test pressures. First two test failed, continued 1/5/2019 testing on next da . continued on 01-06-19*** ***CONTINUE WSR FROM 1/04/19 SWCP 4518***(side track) RAN 4-1/2" BRUSH & 3.75" G -RING PUSH FOAM BALL FROM 7887' SLM TO 8088' SLM. 1/5/2019 IDRIFT W/ NO ISSUES W/ 3.70" CENT TO 8088' SLM. Daily Report of Well Operations 16-14B ***WSR continued from 01-05-19*** LRS Unit 70 perform CMIT-TxIA 4000 psi and Pressure Test OA to 1200 psi CMIT-TxIA PASSED on 3rd attempt to 4088/4165 psi. Target Pressure = 4000 psi, Max Applied Pressure = 4250 psi. Reached 4125/4205 psi with 8.1 bbls -5*F diesel. TBG/IA lost 19/21 psi in 1st 15 min and 18/19 psi in 2nd 15 min for a total loss of 37/40 psi during 30 minute test. Pressured OA to 1200 psi. while TBG/IA were at 530/530 psi. OA lost 8 psi during 5 minute 1/6/2019 pressure test. "Good test" Bled back TGB/IA/OA to 0/12/14, returned -3 bbls TWO = 20/100/20. Temp = SI. Inflow test *** PASSED *** (Pre-Rig). WAG. T FL @ near surface. IA FL @ surface. Bled IAP to slop tank from 100 psi to 0+ psi (<2 gals fluid) in 2 mins. TP decreased 13 psi to 7 psi. Bled TP to slop tank from 7 psi to 0 psi (<1 gal fluid) in 1 min. Held open bleed for 15 mins. Held open bleed & monitored flow for 30 mins. Zero flow observed. Final WHPs = 0/0+/20. 1/7/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 1245 hrs. ***WELL 5/1 ON ARRIVAL*** (sidetrack) HES RELAY UNIT #46 INTIAL T/I/O = 0/0/0. MIRU & PT. STAND-BY FOR ENGINEER. 1/10/2019 ***JOB CONTINUED ON 11-JAN-2019*** ***JOB CONTINUED FROM 10-JAN-2018*** (sidetrack) HES RELAY UNIT #46 RUN 1: CUT TBG W/ 3.625" JRC JET CUTTER AT 7610' MD. ALL LOGS CORRELATED TO PDS MTT LOG DATED 29-DEC-2018. RDMO. FINAL T/I/O = 0/0/0. WELL LEFT S/I ON DEPARTURE. 1/11/2019 ***JOB COMPLETE 11-JAN-2018*** T/1/0=31/0/14 Temp=Sl (LRS Unit 46 - CMIT-TxIA Post Jet Cut) Pumped 6.6 bbls DSL down TxIA to achieve test pressure of 4250 psi. Target pressure=4000 psi Max applied 4250 psi. 15 min loss of 24/20 psi, 30 min loss of 20/22 psi, continue to monitor pressure through 23:59 (still above test target). 1/11/2019 "*Test continued to 01/12/19*** **Continued from Previous WSR** (LRS Unit 46 - CMIT-TxIA Post Jet Cut) Perform CMIT-TxIA (SIDETRACK) CMIT TxIA to 4127/4067 psi ***PASSED*** Target pressure=4000 psi Max applied 4250 psi. Monitored pressures from previous WSR (above target). 15 min loss of 20/20 psi, 30 min loss of 17/17 psi, for total loss of 37/37 psi in 30 mins. Bleed TxIA to 0 psi Bled back - 6.6 bbls DSL. Tags hung on WV/IA AFE sign hung on MV ***FLUID PACKED WELL*** Valve positions=SV WV SSV closed MV open CVs OTG 1/12/2019 FWHP=2/0/0 T/1/0=0/0/0. Pre Parker 272, RU CIW lubricator #839 with 4" CIW TWC #439. Set @ 135 ". Set good. RD 4 1/8 CIW upper tree and RU temp valve #70 as dry hole SV. PT'd 300 psi low and 5000 psi high, for 5 min. ea. charted and retained.(PASSED)***JOB IN 1/22/2019 PROGRESS***. See to for details Final WHP's=TWC/0/0. T/I/O=TWC/0/0 Job in Progress. Installed 2" Piggyback IA Temp. #14 & 3" piggyback OA temp. #19. Torqued flanges to specs. PT'd piggybacks against inner valves. R/U lubricator 1/23/2019 on Drvhole tree,ulled 4" CIW H TWC #439 FWP's 0/0/0 see to for details. TWO = 0/Vac/10. Temp = SI. WHPs (Pre Rig). No wellhouse, SSV or flowline. SV = C. MV = O. IA, OA = OTG. 16:30 2/14/2019 T/I/O = O/Vac/0+. Temp = SI. WHPs (Pre Rig). No wellhouse, SSV or flowline. 2/18/2019 SV = C. MV = O. IA, OA = OTG. 12:45 Daily Report of Well Operations 16-14B T/I/O = 0/Vac/10. Temp = SI. WHPs (pre Rig). No SSV, flowline, or wellhouse. OA FL @ near surface. Bled OAP from 10 psi to 0 psi in 10 min and held open for 20 min. Monitored for 30 min, OAP unchanged. Final WHPs = 0/Vac/0. 2/26/2019 SV, SV = C. IA, OA = OTG. 09:50 North America - ALASKA - BP Operation Summary Report Common Well Name: 16-14 Event Type: RE-ENTER- ONSHORE (RON) Stan Date2/28/2019 _—_- Project: PBU Site: 18 End Date, 3/14/2019 AFE No X3 -0197F -C'. (5,676,591.00 ) Page 1 Rig Name/No.: PARKER 272 - 08:30 Spud Daterrime: 2/18/2006 12:00 OOAM RIGU Rig Release: 3/22/2019 Rig Contractor. PARKER DRILLING CO. - 09:30 - MATE UP UTILITY MODAND MUD MOD TO RIGU P BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) 2.50 RIGU P Date From - To Hm Task Code NPT Total Depth Phase Description of Operations -1.07 (hr) GENERAL RIG UP: (usft) - PUMP 20 BBL DOWN THE IAAT 3 BPM, 350 _ 2/27/2019 10:00 - 18:00 8.00 MOB P -1.07 PRE GENERAL RIG DOWN: -MONITOR WELL WITH CHARGE PUMP ON AN ISOLATED PIT FOR 10 MIN (STATIC) - OPEN UP WELLAND MONITOR WELL FOR 10 - SKID RIG FLOOR - INSTALL ROOF TOP WALKWAYS -1.07 PRE PERFORM RIG EVAC / H2S DRILL WITH LYLE BUCKLER'S CREW _ - LOWER DERRICK NIPPLE DOWN THE TREE AND ADAPTER FLANGE - INSTALL PIPE SHED/ROOF TRANSITIONS -CLEAN AND INSPECT HANGER THREADS - PREP MODULES FOR SEPARATION -INSTALL CROSSOVER AND BLANKING PLUG _ - CAMERON REP ON LOCATION TO FUNCTION LOCK DOWN SCREWS '-SEPARATE MODULESANDSTAGE ON PAD 18:00 - 22:00 4.00 MOB P -1.07 PRE MOVE ALL 3 MODULES FROM DS09 TO DS16 22:00 - 00:00 2.00 MOB P -1 07 PRE SPOT THE DRILL MOD OVER WELL 16-14 0530 - 08:30 3.00 RIGU P 08:30 - 09:30 - MATE UP UTILITY MODAND MUD MOD TO RIGU P 09:30 - 12:00 2.50 RIGU P THE DRILL MOD 2/28/2019 00:00 - 0300 3.00 MOB P -1.07 PRE GENERAL RIG UP: - PUMP 20 BBL DOWN THE IAAT 3 BPM, 350 PSI - PUMP 40 BBL DOWN THE TUBING AT 4 BPM, - HOOK UP INTERCONNECTS -MONITOR WELL WITH CHARGE PUMP ON AN ISOLATED PIT FOR 10 MIN (STATIC) - OPEN UP WELLAND MONITOR WELL FOR 10 - INSTALL ROOF TOP WALKWAYS -1.07 PRE PERFORM RIG EVAC / H2S DRILL WITH LYLE BUCKLER'S CREW _ -1.07 PRE NIPPLE DOWN THE TREE AND ADAPTER FLANGE - INSTALL PIPE SHED/ROOF TRANSITIONS -CLEAN AND INSPECT HANGER THREADS -INSTALL CROSSOVER AND BLANKING PLUG _ - CAMERON REP ON LOCATION TO FUNCTION LOCK DOWN SCREWS -HOOKUP WELLHOUSE 03:00 - 03:30 0.50 MOB P -1.07 PRE RAISE DERRICK SII _ALBS OFF RACK 103:30 - 04:00 0.50 MOB P -1.07 PRE SKID FLOOR -SKID HAUNCH - RAISE PIPE CAT 104:00 - 05:30 1.50 RIGU P -1.07 PRE GENERAL RIG UP: - HOOK UP MUD LINES AND STEAM LINES TO RIG FLOOR - CALIBRATE TOTCO SYSTEM -COMPLETE PRESPUD CHECKLIST 0530 - 08:30 3.00 RIGU P 08:30 - 09:30 1.00 RIGU P 09:30 - 12:00 2.50 RIGU P 12:00 - 13:00 1.00 RIGU P Printed 3/282019 8:32:58AM **All depths reported in Drillers Depths" "'ACCEPT RIG AT 05:30 PER APPROVED CHECKLIST"' 13:00 - 13:30 0.50 ' RIGU P 13:30 - 17:30 4.00 RIGU P Printed 3/282019 8:32:58AM **All depths reported in Drillers Depths" "'ACCEPT RIG AT 05:30 PER APPROVED CHECKLIST"' WBS:RU -1.07 PRE GENERAL RIG UP: I - BRIDAL DOWN -PERFORM DERRICK INSPECTION -1.07 PRE HOLD RIG EVAC/112S DRILL WITH JAMES HUNDLEY'S CREW - HOLD PRESPUD MEETING -1.07 PRE RIG UP TO CIRCULATE OUT DIESEL FREEZE PROTECT -1.07 PRE ROCK OUT DIESEL FREEZE PROTECT - PUMP 20 BBL DOWN THE IAAT 3 BPM, 350 PSI - PUMP 40 BBL DOWN THE TUBING AT 4 BPM, 250 PSI -MONITOR WELL WITH CHARGE PUMP ON AN ISOLATED PIT FOR 10 MIN (STATIC) - OPEN UP WELLAND MONITOR WELL FOR 10 MIN (STATIC) -1.07 PRE PERFORM RIG EVAC / H2S DRILL WITH LYLE BUCKLER'S CREW _ -1.07 PRE NIPPLE DOWN THE TREE AND ADAPTER FLANGE -CLEAN AND INSPECT HANGER THREADS -INSTALL CROSSOVER AND BLANKING PLUG - CAMERON REP ON LOCATION TO FUNCTION LOCK DOWN SCREWS -MONITOR WELLTHROUGH OPEN T Printed 3/282019 8:32:58AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Page 2 Common Well Name: 16-14 - 05:30 2.00 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date 3/14/2019 X3 -0197F -C'. (5,676,591 00 ) Project: PBU Site: i6 Rig Name/No.: PARKER 272 Sputl Date/Time: 7/16/2006 12:00:OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93us8 (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) 17:30 - 20:00 2.50 RIGU P _. -1.07 PRE NIPPLE UP THE BOP STACK 20:00 - 22:00 2.00 22:00 - 0000 2.00 3/1/2019 00:00 - 03:30 3.50 RIGU P RIGU P RIGU P 03:30 - 05:30 2.00 STCTPL P 0530 - 06.30 1.00 STCTPL P 06'.30 - 0900 2.50 STCTPL P 09.00 - 16:00 7.00 STCTPL P - NIPPLE UP HIGH PRESSURE RISERS AND THE BOP STACK - INSTALL CHOKE LINE, FLOW LINE, FILL UP LINES, AND TURNBUCKLES -INSTALL FLOW NIPPLE - INSTALL MOUSEHOLE MONITOR_ WELL THROUGH OPEN -1.07 PRE RIG UP TO TEST BOPE - MAKE UP TEST JOINT - BLEED AIR FROM BOPE -PERFORM SHELL TEST - CHECK TORQUE OF BOLTS ON THE BOP STACK -1.07 PRE PRESSURE TEST BOPETO 250 PSI LOWAND 5000 PSI HIGH FOR 5 MIN EACH - PRESSURE TEST THE ANNULAR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH - TEST WITH 4", 5" AND 7" TEST JOINTS -TEST WITNESSED BYAOGCC REP BOB _ NOBLE -1.07 PRE PRESSURE TEST BOPE TO 250 PSI LOW AND 5000 PSI HIGH FOR 5 MIN EACH - PRESSURE TEST THE ANNULAR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH - TEST WITH 4", 5" AND 7" TEST JOINTS TEST GAS ALARMS - TEST PVT AND FLOW ALARMS - NO FAILURES - TEST CHARTS ATTACHED - TEST WITNESSED BY AOGCC REP BOB NOBLE _ -1.07 DECOMP BLOW DOWN AND RIG DOWN TESTING EQUIPMENT -PULL BLANKING PLUG - BREAK DOWN TEST JOINT - MAKE UP LANDING JOIINT WBS:DECOMP _ -1.07 DECOMP PULL TUBING HANGER TO THE RIG FLOOR - CAMERON REP ON LOCATION TO BACK OUT LOCK DOWN SCREWS - PULL 135 KLBS TO OFFSEAT TUBING HANGER AND 120 KLBS TO PULL HANGER TO THE RIG FLOOR -1.07 DECOMP CIRCULATE SOAP SWEEP SURFACE TO SURFACE - 500 GPM, 570 PSI - LAY DOWN HANGER AND LANDING JOINT - MONITOR WELL, WELL U -TUBING FROM IA UP THE TUBING - CIRCULATE 2X TUBING VOLUME _ - MONITOR THE WELL FOR 10 MIN (STATIC) -1.07 DECOMP PULL OUT OF THE HOLE LAYING DOWN 4-1/2" TCII TUBING FROM CUTAT 7629' MD (FROM 272 RKB) - LAY DOWN TOTAL OF 181 FULL JOINTS, 1 CUT JOINT 39.47', 1 X -NIPPLE ASSY Printed 3/28/2019 832:58AM "All depths reported in Drillers Depths" Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 OIL Operation Summary Report Common Well Name: 16-14 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 2/28/2019 End Date: 3/14/2019 X3-0197F-C: (5,676,591.00) Protect: Pau Site: 16 - - Rig Name/No.: PARKER 272 Spud Date/Time: 2/16/2006 12:00 OOAM Rig Release: 3/22/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001922 Active datum: ACTUAL KB P272 @82.93usft (above Mean Sea Level) Date From- To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr) (usft) 16:00 - 17:30 1.50 STCTPL P -1.07 DECOMP RIG DOWN TUBING HANDLING EQUIPMENT - CLEAN AND CLEAR RIG FLOOR - CHANGE OUT MOUSEHOLE TO 30' _ - SET WEAR BUSHING (8-7/8" ID) 17:30 - 21:00 3.50 STWHIP P -1,07 WEXIT _ MAKE UP 9-5/8"X8-1/2" WHIPSTOCK/WINDOW MILLING BHA TO TOTAL LENGTH OF 953' MD -SURFACE TEST THE MWD PRIOR TO PICKING UP THE WHIPSTOCK WITH 600 GPM, 1000 PSI (GOOD TEST) WBS:WEXIT 21:00 - 00:00 3.00 STWHIP P -1.07 WEXIT RUN IN THE HOLE WITH THE 9-5/8" X 8-1/2" WHIPSTOCK/WINDOW MILLING BHA ON 5" DP FROM 953' MD TO 3000' MD AT MIDNIGHT SINGLE IN THE HOLE WITH 5" DP 3/2/2019 00:00 - 05:30 5.50 STWHIP P -1.07 WEXIT RUN IN THE HOLE WITH THE 9-5/8" X 8-1/2" WHIPSTOCK(WINDOW MILLING BHA ON 5" DP FROM 3000'MD TO THE TOP OF THE TUBING STUB AT 7621' MD - SINGLE IN THE HOLE WITH 5" DP _ - PU 227 KLBS, SO 193 KLBS 05:30 - 07:00 1.50 STWHIP P 7,497.93 WEXIT SETWHIPSTOCK — ORIENT WHIPSTOCK 41°LEFT OF HIGH SIDE - SET DOWN ON TUBING STUB 10K TO TRIP ANCHOR - PULL UP THE HOLE PIPE STRETCH +99' MID TO SETTING DEPTH AT 7522' MD -SET WHIPSTOCK AND SHEAR OFF WITH 50 KLBS DOWN - TOP OF WHIPSTOCK(TOP OF WINDOW SET AT 7499' MD, BOTTOM OF WINDOWN SET AT 7513'MD 0700 - 08.00 1.00 STWHIP P 7,497.93 WEXIT DISLACE WELL TO 10 PPG -SND MILLING FLUID - 550 GP1440 P STS 0800 - 1800 10.00 STWHIP P 7,53193 WEXIT KICK OFF "C" SIDETRACKAND MILL 9-5/8"X 8-1/2" WINDOW FROM 7499' MD TOP OF WINDOW TO 7513'MD+201OF NEW 4r I� 1`(T) FORMATION TO 7533' MD - 450 GPM, 1200 PSI, 120 RPM, 10-19/12 KFT-LBS TRO ON/OFF BTM - MW W/OUT = 10 PPG LSND, NO LOSSES - NO CEMENT OBSERVED BEHIND 9-5/8" CASING, NO PRESSURE OBSERVED ON OA - CLOSE MANUAL VALVES ON MUD CROSS - OBSERVE HIGHER THAN EXPECTED TORQUE WHILE MILLING THE WINDOW AND RATHOLE - TEMPORARILY HELD UP AT 7131' MD, WORK PIPE FREE WITH PUMPS AND OVER PULL UP TO 50K Printed 3/28/2019 8:32:58AM **All depths reported in Drillers Depths" WELLHEAD= VETCOGRAY ACTUATOR= BAKER OKB. E -EV = 70' REFELBE = fir BF. E -EV = 37.73 KCP= 4200' Max Angle = 97 @ 13355' Datum MD= 9960' Datum TVD= 8800'SS C. 1)= Minimum ID = 3.725" @ 9793' 4-1/2" HES XN NIPPLE 14-12' TBG 12.61!, L-80 TCI, .0152 bpf, D= 3.958' I 1 9805' 1 19941' ELM 14-12' TBG, 12.610, 13 -CR D = 3.958. 1 4-12' LNR 12.610, L-80, D = 3.958- I— PEiFORATIONSL#J WRY FEF LOG AMID GR ON 0225/06 ANGLEATTOP PERF: 91° 0 11548' Note: Refer to Production DB for historical perf d SIZE SPF INTERVAL OpWSgz SHOT 2-7/8' 6 11548 - 11580 S 10/18/16 20//8' 6 11750-11782 S 10/17/16 2-7/8' 6 11968 - 12000 S 10/17116 2-7/8• 6 12440 - 12530 c 0427114 2-4/5' 6 13400 - 13425 c 05/11/12 2-4/5' 6 13425 - 13450 C 05/10/12 2-4/5' 6 13450 - 13475 c 05/10/12 2-415' 6 13475- 13500 c 05/10/12 2-7/8' 6 14150 -14250 c 0824/08 2-718' 6 15000 - 15100 c 05/19/06 16-146 SAFEfYNOTES: WELL REQUIRES A SSSV WHEN ON ML WELL ANGLE> 70° § 10189'. AS OF 3/21106, POSSIBLE SOLIDS IN TOP OF LNR DUE TO MILLING ON OG 7499' -j9-5/8'VN-PSTOCI((03/01/19) -7610' JEr CUTTBG(01/11/19) 8773' 9-5/8- X 7- BKR PKR & HNGR D = 6.25' 4-12'HESXNP,D=3.813' 9886' H r X 4-12• BKR S-3 PKR D = 3-875- iiiiF HES X NP, D = 3.813' REV BY COMyBJIS 07/09/81 ORIGINAL COMPLETON 8793'4-12- HES XN NP. D = 3.725• 9795' H T X 5' W/ ITERACK SLV, D= 5.25- -14-1/2- WLEG, D=3.955' abD Ti NOT LOGGED 9815' T x 5- BKR FLEX -LOC, LNR HNGR w/5' RS PACKOFF NP, D=4250' 982TH 5 -X4 -12 -XO, D=3.950' Y ILLOUT WINDOW (16.146) 981V - 9921' 14-12- LNR 12.61!, L -BO BT -IA .0152 bDf. D = 3.958' I DATE RV BY COMMBYfS DATE REV BY COMyBJIS 07/09/81 ORIGINAL COMPLETON OVOB/19 MRDdJMD RES P&A- RAN CMT(12/24/18) 04!13/98 SIDETRACK(16.14A) 01/08/19 MTWAD RES P&A - TOC TAGGED BY SL 03/10/06 N28S SUDEI'RACK(IS-148) —FIM—8/19 BTNJMD RUNCHEDTBG(Ot/02119) 0627117 LLG/JMD SETPXNFiUG(0623/17) 01/08/19 JUJMD TAGGED —TOC (01/04119) 1024117 FJMD PULLED PXN PLUG (10/23/17) 01/14/19 iidJMD JETCUTTBG(01/11/19) 07/30/18 JNJJMD ADDED REF & BF 0/B/ FBH: 2 4-12' CEPS MLLED & RUSHED DH (10/16/16) CBP 1 15307' 1 PRJDHOE BAY LM WELL: 16-148 PETN1f No: 0/1060030 AR No: 50429-20570-2 TION, R15E 1534' FNL & 526' FWL SP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: gg DATE: Tuesday,February 06,2018 P.I. Rp Supervisor C SUBJECT: Mechanical Integrity Tests P.I. BP EXPLORATION(ALASKA)INC. 16-14B FROM: Chuck Scheve PRUDHOE BAY UNIT 16-14B Petroleum Inspector Src: Inspector Reviewed By:t P.I.Supryv VR NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-14B API Well Number 50-029-20570-02-00 Inspector Name: Chuck Scheve Permit Number: 206-003-0 Inspection Date: 1/22/2018 Insp Num: mitCS180123103753 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Mien 45 Min 60 Min Well 16-14B Type Inj G "TVD 8637 Tubing 3108 3085 3072 3071 3073 PTD 2060030 Type Test SPT Test psi 3500 IA 645 3848_ 3794 - 3759 ' 3732-.t BBL Pumped: 13 -!BBL Returned: 8 - OA 163 189 191 189 - 185 - Interval REQVAR P/F P Notes: Tested per AIO 4G.007 SCANNED ,, Tuesday,February 06,2018 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,January 24,2018 Jim Rp P.I.Supervisor ''.-.(7e(1''.-.(7e(1I/ )16 SUBJECT: Mechanical Integrity Tests / BP EXPLORATION(ALASKA)INC. 16-14B FROM: Chuck Scheve PRUDHOE BAY UNIT 16-14B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-14B API Well Number 50-029-20570-02-00 Inspector Name: Chuck Scheve Permit Number: 206-003-0 Inspection Date: 1/23/2018 Insp Num: mitCS180123103753 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 16-14B Type Inj G ITVD 8637 - Tubing' 3108 3085 3072 "1 3071 ' 3073- --- - -- — – -- --- -- --- PTD 2060030 - Type Test SPT Test psi 3500 IA 645 3848 . 3794 _ 3759 - 3732 - BBL Pumped: 13 BBL Returned: 8 OA 163 189 - 191 - 189 185 - Interval REQVAR P/F . P Notes: Tested per AIO 4G.007 - e C�(.44erck2at eAkti: , Vewv f3f)6:4- reictrott vo u. t 44.zte A paktneel sCANNED A Wednesday,January 24,2018 Page 1 of 1 • As-144440.41-40 . cc . 1.11. • til t c CS 1601 Z3 i o37.5-• Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 24, 2018 10:57 AM ( 7 To: Regg, James B (DOA) 12-41 t e Cc: AK, GWO Projects Well Integrity Subject: RE: PBU 16-14B (PTD 2060030) Mr. Regg, In short the IA was not fluid packed prior to the test because the fluid level was suspected to be at surface. An IA fluid level shot was performed on 1/20/17 pre MIT-IA and showed to be at surface. We try to avoid topping off annuli on injectors due to annular fluid expansion caused by thermal swings so the IA was not pumped into at that time. Looking back over the well history I see where the fluid level was shot on 10/24/17 and it was found to be at 90' (which equates to about 5bbls of fluid). No IA pumping operations took place between 10/24/17—1/20/18 so I would conclude that the fluid level shot performed on the 1/20 was erroneous. This was an oversight on our part and I will speak with our team to ensure we are more diligent with verifying annuli are fluid packed before state witnessed testing. Thanks, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, January 23, 2018 3:45 PM To: AK, GWO Well Integrity Engineer Subject: PBU 16-14B (PTD 2060030) AOGCC witnessed MIT on PBU 16-14b today; pumped 13 bbls of fluid and returned 8bbls. Was the IA fluid packed prior to the test? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 1 . • • 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.reggPalaska.gov. 2 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, October 24, 2017 8:26 AM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OIL;AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA);Ohms, Danielle H; Nottingham, Derek Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, GWO Projects Well Integrity Subject: OPERBALE: Injector 16-14B (PTD#2060030)AOGCC administrative approval 4G.007 granted for continued WAG injection with slow TxIA communication Attachments: 16-14 Approved AA -A104G.007.pdf All, Injector 16-14B (PTD#2060030)was made not operable on 6/2/17 for having slow TxIA communication. On 7/27/17 DHD performed a passing MIT-IA to 3,850psi proving two competent well barriers. Administrative approval AIO 4G.007 was granted by the AOGCC on 9/18/17 for continued WAG injection with slow inner annulus repressurization. At this time the well is reclassified as Operable. As a condition of the AA all bleeds must be flagged, and any change in the wells mechanical condition must be immediately reported. An AOGCC witnessed MIT-IA will be conducted once the well returns to stable injection. Please mind fluid packed annuli when bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 SCANNED E-t,a=' 2 ;p Cell: 907-341-9068 wo .war.......s....«.. From: AK, GWO We : ' Engineer Sent: Friday, June 02, 2017 2:32 • To: AK, GWO Well Integrity Engineer; AK, GWO • . - '.ns Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; A , .• 2 Field OTL; AKOpsProdEOCTL; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan; , • GPB East Wells Opt Engr; AK, OPS 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,June 2,2017 2:32 PM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OIL;AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Ohms, Danielle H; Nottingham, Derek Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J;AK, GWO Projects Well Integrity Subject: NOT OPERBALE: Injector 16-14B (PTD#2060030)TxIA communication confirmed All, Injector 16-14B(PTD#2060030)was made under evaluation on 05/05/17 for exhibiting an anomalous pressure trend on the inner annulus. Further diagnostics and attempts to bleed the IA have confirmed TxIA communication. The well is now classified as Not Operable and will be secured with a downhole plug. Please arrange to shut in the well as soon as operationally possible. Plan Forward: 1. Fullbore: Load and Kill TBG 2. Slickline: Secure well with TTP 3. Fullbore: CMIT-TxIA, MIT-T 4. ANC Engineer:Additional Diagnostics as Needed Please Respond with any questions, SCANNED JUN 0 62017 Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 wo 1 ! ! From: AK, GWO Well Integrity Engineer Sent: Friday, May 05, 2017 10:02 AM To: AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AKOpsProdEOCTL; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; 'Regg, James B (DOA) (jim.regg©alaska.gov)'; 'chris.wallace©alaska.gov'; Ohms, Danielle H; Nottingham, Derek Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J; AK, GWO Projects Well Integrity Subject: UNDER EVALUATION: Injector 16-14B (PTD# 2060030) Anomalous IA Pressure Trend All, Injector 16-14B (PTD#2060030) has begun to exhibit an anomalous IA pressure trend. Attempts to bleed the inner annulus on 05/04/17 show a repressurization rate of"600psi/day indicating possible TxIA communication. The well is now classified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. DHD: MIT-IA 2. Well Integrity Engineer: Additional Diagnostics as Needed 3. Fullbore(Contingent): Load and Kill Well 4. Slickline (Contingent): Secure well with downhole plug Please respond if in conflict with plan, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9038 4,000 •- 3.500- 3.000- 2.500- 2.000 1,500 - 1,000 - 500 - 01105/17 011217 01;19117 011126=17 0210217 0210917 02'1617 022117 2 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, May 5, 2017 10:02 AM To: AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AKOpsProdEOCTL; AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg, James B (DOA);Wallace, Chris D (DOA); Ohms, Danielle H; Nottingham, Derek Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J;AK, GWO Projects Well Integrity Subject: UNDER EVALUATION: Injector 16-14B (PTD#2060030) Anomalous IA Pressure Trend All, Injector 16-14B (PTD#2060030) has begun to exhibit an anomalous IA pressure trend. Attempts to bleed the inner annulus on 05/04/17 show a repressurization rate of^'600psi/day indicating possible TxIA communication. The well is now classified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan Forward: 1. DHD: MIT-IA 2. Well Integrity Engineer: Additional Diagnostics as Needed 3. Fullbore(Contingent): Load and Kill Well 4. Slickline (Contingent): Secure well with downhole plug Please respond if in conflict with plan, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9038 SCANNED MAY 1 02017 Vti 1 µ' • • 4,000 - 3.500 3,000 2,500 - 2,000 - 1,500 - 1,000 500 01/05/17 01/12'17 01/19/17 01126'17 02102/17 02,D9,117 02/16117 02123/17 3,000 - 2,500 2,000 - = 1,500 - 1,000 - 500 01/05117 01/1217 01/19117 01;26>17 02.'0217 02109/17 02116/17 2 STATE OF ALASKA OASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ` 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Mill CIBP 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-003 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-20570-02-00 7. Property Designation(Lease Number): ADL 0028332 8. Well Name and Number: PBU 16-14B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 15307 feet Plugs measured 13900/14625 feet true vertical 8990 feet Junk measured feet N Q V 21 2016 Effective Depth: measured 2193 feet Packer measured 9667 feet h true vertical 2193 feet Packer true vertical 8638.92 feet (fid- Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 32-112 32-112 1530 520 Surface 2646 13-3/8"72#L-80 30-2677 30-2677 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet ri True vertical depth: See Attachment feet SCONE° MAR 0 8 Ll t Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 27-9807 27-8751 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2193 2193 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 14616 920 1283 Subsequent to operation: Shut-In 100 1298 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ICt„ _ CL..............,------;:=7-...N....-- Phone +1 907 564 4424 Date 11/21/16 Form 10-404 Revised 5/2015 / ! / RBDMS L tz NOV 2 8 2016 Submit Original Only I 71107 • • m QoOOOOOO • N N- (000 — O0 -- co N- O v Ln Lr) 15 11) N Nr L() Ln N- N- V 4. e CD 01 01 0- I ) d' M CC) 3 Ln O) OD '— N T- 1- (D 00 03 OD I's d) Ln (p O (0N- OODO) N- `- N N- O CO O OD O) O (r) N O O) ON- M M N N- a) N- N 0- CO QDN I� N CO 00 M O O Ln O O 1.0 co . N 00 CO O O C.) 1-1 1L.%- N O O N 0- O 0- 01 M N Ln 0- 0- N co13) OOO :3 rei W LC) a OO O O O C) 0 000CD 11 O00OD •N00 N r r V O M DO CO CD '7 v7 O — (O co NCD C)0 .4' O N 00 C 00 a) z Ln N- JJ N CO - r- Ln O W W F- r-1W - - N 00WW W LCC• CCLZ Z W W W W m 0 D ~ F- Z Z D 0 fn Z Z J J • a) H m I• ,- M N- O) CO e- CO N N. 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N- N- N- N. 0❑ W ❑ w ❑ N U 4 0 0 0 0 0 0 0 0 0 0 0 0 0 Z U W W LL W d Q ❑ J H J J J ❑ IX a 0 Q Q a Cn LL LL u_ In a [Y d ea Z CO CO 00m03m03COCO00m03CO 3 �rvvvvvvvvvvv "' COCOCOCOCOCOCOCOCDCOCOCDCO m a 0. 0. 00 J 0 0 N W 0 ¢ < mmu_ cncnam • Packers and SSV's Attachment PBU 16-14B SW Name Type MD TVD Depscription 16-14B SSSV 2193 2192.91 4-1/2" MCX I-SSV 16-14B PACKER 8773.25 7915.25 7" Baker HMC Packer 16-14B TBG PACKER 9666.84 8638.92 4-1/2" Baker S-3 Perm Packer 16-14B PACKER 9808.76 8752.22 5-1/2" Baker ZXP Hydro Set Packer • • 0) H o c •c m m coi o @)-v c 0 a3 LS u_ v a m 11H 0 Q >, m s' Q o u� a � _0 Q C N — to • C a) 7 Q) w c 3 _0 HO2 m C a) J o co O E u_ D J - N N c •- r� II a) Q N Q m O co o - > (7) .S N co -= �_ > > O 2 a s 15 @ °� co "O b 12 > o c'o Cl) Z o LL � NQLL S Q' - II in C Q Q v— II . "p a Q O . 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O • 't U + • U ++ a) >+ c �_ m N a o a) CD- N _7 c Lo N cn 7) c N 15 Co O E CO U .- -O O 7 +. 0 M > a• o � > ao• -.E. a) oo c U o Cu O c Co C co N O N N co 1 3 3 -t OrSw � 2 � S.. to N c U to co c w U CCO "0 X c0 *r0 a C EO 0 CoSa) 0No N t Q i 7 a) 2 e N N Z to O CO O o O 0-2 O U w- U CO , a) o c E mr' .- a � = E , a � = 7 ' a0_'` 0E ° N- '• 00,200 ?� co c.i Q o Q II. � M Q O Q- a .0 a) � 2 + � a t° __ a � CO Q c c - c CO Q c c c CO Q E o c CO N 3 'Ot ..- 0 O = a co m m a m co 9 co a m_c 3 Q t 2 a) t CO Em 8 cn Em oo cnbo Em = = cam'- Ea 3 � a �. a) .rrn 3 ' • ct a oV EN 3r0i m oV EN 3a) C0 � U2 Em -ow cc°i � o � Uo c ; -8 CO 12,. a) _ ± a) � _ . a) O E 7 - N ' c }+ .c N 0 0u) ©� � O C,O 0 � 7.� ©� NO (6 OHO O 5a) •:--•°° N � O (n -0m E 2a-. th �+ *, aNmaCOa a *, aN11 m � mo_ OVa- a cif i- 0) >.N z ° •' o: O UI– O . * m Q ch - * m a c•,) _ * co oo 9 � c co * m c2in -0 RI CI •o0 � U '- Ua o0 mU ' Ua ( 5U5 D N -la u) a A ° c° oco- c" U = ,c cLna m � U _ Y �, o2m � U = � 3 a � a to : co := 0o (j cin .em 0oU cCn � c`hccco u) UO � . .e- Q-mE � I� Qj 2 Q co -.. a) O N aj 0 M 2 N O N - CO O a) O 6 _ C a) O 8 O S • U N a) a) 4cDO2EQ ° cva1) ~ 2EQ ° 3va4) ooEa C .-.-Cv°), � I– a0 U o rn c U O rn c am c c �* 0 003 CO CD'*- b .- 0 - - =CO cn CD C O D O o D co o -a S)a o 0 ? O 3 1 U 0 0 - co ' UF - rn 'oUFc - DUFO OC 3OUF- ON a) coQ 0N a) r) _ O c O N U -) a .- 0-N- cn 0 C .- a- cn : 0 2 > I- E 2 : U -) - U 0 rna . CO CO CO CO s- 1- e- 0 0 O 0 N N N N c) ) 0 N- O O O O • • o § k b � Q • O@ = $ 7 \ � = R o E o 2 \ sal E7 , — m kz�u) wfk - \ . ƒ � atE CD � : TREE= 41!16"CMI 0 -S-it(NOTES: WELL REQUIRES A SSSV WHEN WELLHEAD= VETCO GRAY 1 6-14 B ON ML WELL ANGLE>70°@ 10189'. AS OF 3/21/06, ACTUATOR= BAKER OKB.ELEV= 70' POSSIBLE SOLIDS IN TOP OF LNR DUE TO MILLING ON BE ELEV= 40.43 RIG KOP= 4200' Max Angle= 93°@ 13355' Datum MD= 9960' Datum TVD= 8800'SS I J 2193' -14-1/2-HES X NP,D=3.813" 13-3/8"CSG,72#,L-80,D=12.347" — 2675' �f 1: 8773' H9-5/8"X 7'BKR PKR&MGR,D=6.25" Minimum ID =3.725" @ 9793' ° ° 4-1/2" HES XN NIPPLE I 9644' H4-1/2"HES X NIP,D=3.813" 041 e 9665' —{7"X 4-1/2"BKR S-3 PKR D=3.875" 9689' 4-1/2"HES X NP,D=3.813" 9793' —14-1/2"FES XN NP,D=3.725" 9795' —7"X 5"BKR ZXP LNR TOP PKR w/ 9-5/8"CSG,47#,N-80,(3=8.681' -I 9772' ,�%�.� TEBACK SLV,0=5.25" '.'�:���„ WD 9805' H4-1/2” LEG, =3.958" -I H.IuD TT NOT LOGGED 4-1/2"TBG 12.6#,L-80 TCI,.0152 bpf,D=3.958" H 9805' 9815' —7"x 5'BKR FLEX-LOC,LNR HNGR w/5"RS PACKOFF NP,D=4.250" WNPSTOCK(02/14/06) — 9921' 9827' J--15"X 4-1/2"XO,D=3.950' MILLOUT WINDOW(16-146) 9916'-9921' ESZV(02/14/06) 9941'ELM 12200'j--I4-1/2"BOT CUP(10/18/16) 4-1/2"TBG,12.6#,13-CRD=3.958" 9978' 111 -1 `7"LNR26#,L-80,D=6.276" —I 10444' ` 4-1/2"LNR 12.6#,L-80,D=3.958" H 15175' P4•11V4v•••4•4414 , ` 14625' —FISFt241/2"CIBPS FERFORATION SUMMARY ��4.4.4��� ` K LLED&PUSHED REF LOG:MWD GR ON 02/25/06 ')44444444441° 444441 DN(10/16/16) ANGLE AT TOP PEW:91°@ 11548' (44444444441 Note:Refer to Production DB for historical pert data �4�4.4.4..4�1 ` 14625' —41/2"CEP • (08/21/08) SIZE SPF MERVAL Opn/Sqz SHOT SQZ .111.111. 2-7/8" 6 11548-11580 0 10/18/16 :••4•4•4V1 2-7/8" 6 11750-11782 0 10/17/16 / 2-7/8" 6 11968-12000 0 10/17/16 / 2-7/8" 6 12440-12530 C 04/27/14 2-4/5" 6 13400-13425 C 05/11/12 4`� 2-4/5" 6 13425-13450 C 05/10/12 MID H 15221' V�Stik. 2-4/5" 6 13450- 13475 C 05/10/12 111:141144," 2-415" 6 13475-13500 C 05/10/12 4-1/2"LNR,12.6#,L-80 BT-M,.0152 bpf,ID=3.958" H 15307' 2-7/8" 6 14150-14250 C 08/24/08 2-7/8" 6 15000-15100 C 05/19/06 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT • 07/09/81 ORIGINAL COMPLETION 05/15/12 TTW/JMD CEP/FERE(05/09-11/12) WELL: 16-14B 04/13/98 SIDETRACK(16-14A) 05/05/14 ALMJMD CBF'/ADF (04/26-27/14) FERNITNo:' 060030 03/10/06 NES SIDETRACK(16-14B) 05/30/14 JKDVJMD ADDED PERF SYMBOL AR No: 50-029-20570-02 09/05/08 GIMPJC CEP!PERF(08/21-24/08) 10/20/16 ATO/JMD MLL CEPS/SET CBF/ADFERFS SEC 24,T1ON,R15E,1534'FPI.&526'FWL 02/14/11 MB/JMD ADDED SSSV SAFETY NOTE ' 01/17/12 TMWJMD ADDED H2S SAFETY NOTE BP Exploration(Alaska) OF 1 1 /�� THE S ATA:. Q ckC3, ; (1 c tS k - / - 333 Wes Seventh Avenue "' ,�!� GOVERNOR SEAN FARNELI Anchorage, Alaska 99501 3572 yq� Main 907 279 1433 P.� Liv � Lv Fc,x: 9(;7.276.7:942 5`PNN*O �`V Berhard Stechauner Lead Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 a0(7 -063 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 16-14B Sundry Number: 314-167 Dear Mr. Stechauner: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i Daniel T. Seamount, Jr. Commissioner DATED this Z 0 day of March, 2014. Encl. STATE OF ALASKA Vi,;‘; 1 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ • Perforate Q • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate Q Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: ,if_iv,e,&&jc5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ / evetopm`enc� Yv206-003-0 ' 3.Address: '04\ 6.API Number. Stratigraphic ❑ Service Li P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20570-02-00 - 7.If perforating: /, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C ,LS, 54/16 , \- PBU 16-14B - Will planned perforations require a spacing exception? Yes ❑ No E / . (b', r 4 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028332 ' PRUDHOE BAY, PRUDHOE OIL • 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): 15307 • 8990 • 13900 9013 See Attachment None Casing Length Size MD TVD Bust Collapse Structural Conductor 80 20"94#H-40 27-107 27-107 Surface 2646 13-3/8"72#L-80 27-2673 27-2672.79 4930 2670 Intermediate None None None None None None Production 8938 9-5/8"47#L-80 26-8964 26-8074.2 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 25-9805 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 4-1/2"MCX I-SSV 2193',2192.91' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service 2 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG Q Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Berhard Stechauner Email Berhard.Stechauner@BP.Com Printed Name Berhard Stechauner Title Lead Petroleum Engineer Signature C �� Phone 564-4594 Date Prepared by Garry Catron 564-4424 '. _., _ 3/ 14 /20(4 4./". COMMISSION USE ONLY '231*- Conditions of approval: Notify Commission so that a representative may witness Sundry Number. J 1*- \LRst Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 1 0 2014 Spacing Exception Required? Yes ❑ No M Subsequent Form Required: /D _ 4 D �1_ / 'T „,,e 4----z-...o APPROVED BY J Approved by: COMMISSIONER THE COMMISSION Date: 31 2 d) 1 4_ " Form 10-403 Revised 10/2012 OARotellitiktAvE for 12 months from the date of approval. Submit Form and Attachrffents in Duplicate 4 Plugs Attachment ADL0028332 Well Date MD Plug Type TVD 16-14B 5/11/2012 13900 4-1/2 CIBP 13967 16-14B 8/22/2008 14625 4-1/2" CIBP 14692 Perforation Attachment ADL0028332 Well Date Perf Code MD Top MD Base TVD Top TVD Base 16-14B 5/11/12 APF 13400 13425 9025 9024 16-14B 5/10/12 APF 13425 13500 9024 9021 16-14B 5/9/12 BPS 14150 14170 9008 9008 16-14B 5/9/12 BPS 14170 14190 9008 9008 16-14B 5/9/12 BPS 14190 14210 9008 9007 16-14B 5/9/12 BPS 14210 14230 9007 9007 16-14B 5/9/12 BPS 14230 14250 9007 9007 16-14B 5/9/12 BPS 15000 15100 8993 8992 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028332 Well Facility Type MD Top Description , TVD Top 16-14B SSSV 2193 4-1/2" MCX I-SSV 2193 16-14B PACKER 8774 7" Baker HMC Packer 7916 16-14B PACKER 9665 4-1/2" Baker S-3 Perm Packer 8637 16-14B PACKER 9807 4-1/2" Baker ZXP Packer 8751 • • 000000 � cococococo = J J J J J N Q O 00000 N SOC) N- CO CO to r N U N o 0 0 0 0 0 MNrM N- co co = IC) N oo a) • CO CO CO V CO N Cn o M O) CO CO CA I,- N O co co O CO C- v- CO co CO N CO C1 0 I- Cs- N CO I- U) Q N CO N N N aS M M vii Nm0rn � rnm000 0 Q • 0) Co CN a) m o 2 C J H N- N- N CD N- L[) U Q NN- N- N N CV 2 O C9 ✓ OOOO 0? *k N CO N CO N N (nN r - - e-- O N N ) C'7 N C Cr) ' 4 ▪ N N Co CO 0 O O r- C'r) CO ) O C[) co CD N O0) z O 0 O H W U kzi V 0 c Q o LL Z z LU LU O Z Z eCD , Uniav) I— Note: This program was de;. _ ed with the intention that it would reqs.,,u 6 coil runs: 1. Drift/Log/Flag 2. Set CIBP 3. Add 30'perforations 4. Add 30'perforations 5. Add 30'perforations 6. Acidize perforations to increase injectivity (pending infectivity test) 16-14B DHD Procedure 1. Perform TIFL to verify tubing integrity. • Well has passed MIT-IA passed @ 3,750 psi on 12/08/2010 16-14B SL Procedure 2. MIRU Slickline. PJSM. 3. Pull MCX from 4-1/2" HES X Nipple @ 2,193' MD. 4. Drift to max deviation with drift large enough for 4-1/2" CIBP and 30' 2-7/8" dummy gun. OD CIBP: 3.562". Drifted to 14,250' on May 9, 2012 with 3.7" tool. 5. RDMO. 16-14B Fullbore - Schmoo-B-Gone Treatment 1. MIRU. PJSM. 2. Pressure test. 3. Pump 5 bbl of methanol spear 4. Pump 215 bbl of SBG mix. 5. Wait six to twelve hours if possible. 6. Hand well back to operations to put well back on injection. 16-14B Coil Procedure 1. MIRU CTU. PJSM 2. Displace wellbore with -1.2 tubing volumes of diesel at ambient temperature. Bullhead -215 bbl diesel down tubing. 3. MU drift assembly with nozzle and GR/CCL. Drift to -13,100 MD, log to 10,300', paint flag and POOH. Tie in log: Haliburton (Sperry Sun): DGR Dual Gamma Ray Log: Date: 14-Feb-06 to 25- Feb-06 OD of Weatherford CIBP to be run: 3.562" 4. Pick up CIBP, RIH, tie into flag and set CIBP @ 12,990' MD. POOH. Ensure good depth control so we can use the CIBP to tag for future tie in if needed. When pumping balls to seat use diesel to maintain diesel fluid column. 5. Pick up 30' of 2-7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 6. RIH, tag CIBP for deh control and perforate 12,500' — 12,53k IAD. POOH. Note any tubing pressure changes in AWGRS summary. 7. Pick up 30' of 2-7/8" 2906 PowerJet Omega HMX, 6 SPF, 60 deg phasing guns. 8. RIH, tag CIBP for depth control and perforate 12,470' — 12,500' MD. POOH. 9. Pick up 30' of 2-7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 10.RIH, tag CIBP for depth control and perforate 12,440' — 12,470' MD. POOH. 11.Pick up 200' and perform injectivity test with diesel down backside of coil. If injectivity is less than 2 bpm @ 2,000 psi, perform the following acid stimulation. Otherwise, RDMO. Please record injectivity results in AWGRS report. PENDING Acid Stimulation Comments: • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • In general, pump job at maximum allowable or achievable rate/pressure. • Attempt to not exceed 2000 psi while acid is entering the perforations if possible. It is ok to go up to 3000 psi surface pressure in the following cases: a. If the diversion is very effective at plugging slots. Increase pressure as needed to allow job to be completed. • Send an electronic copy of the treatment report including digital, ASCII, or an excel copy of pumping rates and pressures to Spencer Morrison @ Spencer.Morrison@BP.com Perforation Details Zone MDT MDB H Status 26P 12,440' 12,530' 90 Open Design Details: Wellbore Volume 190 bbls to top of perf at 12,440 MD, 198 bbls to CIBP at 12,990' MD Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Acid Volume 12% HCI — 65 bbls, 9:1 Mud Acid — 65 bbls Oilseeker Design 5 bbl Oilseeker diversion Pres No SBHPS but expect 3,450 psi Treatment Procedure 12.Ensure the following before starting the job: a. Ensure current MSDS for this job is onsite and acid safe handling procedures are followed b. Ensure that the acid shower trailer is on site and functional c. Keep out all personnel not associated with this job 2 _ d. Ensure Sund, Jr performing acid stimulation is on lot—ion. e. Well has L-80 liner. Ensure correct additives are used. SBHT 177 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/-1% for HCI. Fluids should be 90-110 F 13.MU coil tool string with jet swirl nozzle and RIH to top of perforations (diesel should be in the coil at this stage) and displace coil with Ammonium Chloride while taking returns through backside. Displace diesel -500ft away from top of perforations to prevent diesel and acid getting into contact with each other (500 ft - 6.5 bbl). Close in backside and keep on injecting ammonium chloride until steady injection is achieved. If needed to establish injection, go to 3,000 psi WHP, but drop immediately back to 2,000 psi WHP as to not fracture the well during the acid wash. 14.Pump fluids per attached pump schedule while reciprocating nozzle across newly perforated ✓ interval (12,440 - 12,530'). When acid is on the perforations, maximum WHP should be 2,000 psi. Before POOH, complete the over flush to ensure that the acid has been pushed away. The acid stimulation should take -9.5 hours to pump. Please record rates and total volumes pumped in AWGRS report. 15.POOH with coil and perform another injectivity test with diesel down the backside and make note of stabilized rate and pressure in daily report. 16.RDMO Coil. HCL/Mud Acid Recommended Additive Concentrations L80 at temps Completion metallurgy from 175 F to 225 F Loading for 12% 911 ProductHCI Mud Code Function Units acid A264 Acid Corrosion GaI/Mgal 6 6 Inhib. A201 Inhibitor Aid Gal/Mgal 15 15 A153 Intensifier Ib/Mgal 0 0 F103 Flowback Aid GaI/Mgal 2 2 L058 Iron Control lb/Mgal 20 20 W054 Anti emulsifier Gal/Mgal 5 5 U067 Mutual Solvent Gal/Mgal 0 50 3 Diverter Recipe Concentra_ .is (OILSEEKER) OILSEEKER Product Function 80-150 F BHST 151 -280 F BHST 80-150 F BHST 151 -280 F BHST Code HCL HCI : Mud Acid J570 Gelling agent 5% 6°%o M117 KCI 2% 0 J285 NH4CI 0 3°%0 NOTE: For Oilseeker diversion recommend shutting down for 5-10 min after diversion stage invaded formation to restore diverter viscosity. For Oilseeker continue to reciprocate throughout the job. Pumping Schedule: Cum. Step Description Fluid Stage Vol Fluid Fluid Vol Vol bbl bbl 1 Load 3% NH4CI + F103 50 50 2 Acid 12% HCI 33 83 3 Mud Acid 9:1 Mud Acid 33 116 4 Overflush 3% NH4CI + F103 99 215 5 Diverter OILSEEKER 5 220 6 Pre-Flush 3% NH4CI + F103 32 252 7 Acid 12% HCI 33 285 8 Mud Acid 9:1 Mud Acid 33 318 9 Overflush 3% NH4CI + F103 99 417 10 Coil tubing displacement 3% NH4CI + F103 40 457 16-14B SL Procedure 1. MIRU Slickline. PJSM. 2. SBHPS as per attached form. 3. Run MCX and set in 4-1/2" HES X Nipple @ 2,193' MD. 4. Run check set to ensure MCX is set. 5. RDMO SL. 6. Hand well back to operation to POI. 4 . . Tie In Log Header Page . . perry- Sun DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity Horizontal Presentation i 'Nary INE3ITE [ 1 : 600 / 1 : 240 ] HALLIBURTCIN i i 1 ' Company : BP Exploration Alaska, Inc. ! , . ! Rig : Nabors 2ES !' Weil : 16-14Si Z' Field : Prudhoe Bay 4 Ii I a Country • USA s - , , ia Ce • , k :_, i ' 6 -a•- iiiI, 2e API Number • SG-029-20570-02 0 Li. L'alitudu 70°12'34,68—North Other Ser.i(t...s Lcrigitude 14r 13 53.14"West a i ABI At Bit Inclination Ui AK . iate Pli-,t.. TN 4 X = 719 307 ft AK r)Lit( Plain:.1N 4 Y= 6,929,396 ft Perrnanent Datum Mean Sea Level Eleqatior, 0.00 R Elev KB 0 00 It Log Was+,eil c--:r a n Drilf Floor 67.00 It Above Penymen1 011unt DF 57.00 ft GL 38.50 ft Drilling Measured From Drill Floor I MD LOG 1 WD 0.00 It Dwiti Logged 9,916.00 ft To 15,307 00 ft Unit No 119 Joh No AK-141A1-00042,;242 Date Logged 14-Feb-06 To 25-Feb-06 Total Depli) MD 13O700 ft TVD: 8,999.99 R ! Pict Type . Field Spud Date 14-Feb-013 Pict Dale 25-Feb-06 Pun No • Flofehizge Record IMF)! Run No 1.Scwholi:R 1.9.olil,,rvICJI 1 . <,i.i..i.' . f—Orri . 10 -.-...i.::,..' . I-ruin Tcj 6 1 2t-.1 In 9,. !,,',`CCI ft 943.tX1 tt , 6 1.2f in , 9,941',,,X1 rt . 10.84100 11 : ?.• . 4125 in : 10,5?„,1 CIO ft', 153(274X)ft Casiug qi.--coril I p&I; i: Wei,Jht I(L111! To 1! !.7-5 n , 7:-. 01; t)r,t . suRP-A.:,,- :i-Jr,00 tt ,L.7.f.e,_?_-, in 47.0C' tr.t SI..,.R.7A(:L. ':-.. .' .' C0 ft 7 OCO ir 71-: Or. if ,c: 773 .'.,7, 'I !--:-.,';-,CIO ft 1 , , • 5 Tie In Strip for CIBP Naglea . i�. 1 I . ._ + 111111■ , ; , ! 111 11 111 r11111111„311:, l .■ ■s __ -----� - ` ;_t_ :- :c . ._ i I 1 _ ■ 111 ■ „„,P......1:- .'' 12000 a t 1111111 11 ■ 11111■ 1 .� , 1 _-_ N11I■ 1 1111 111■ �_._ _ t - , 111 ! 111■ . 111 111■ i� a 11 -fi ti. '}'± ■ ,1. Set CIBP @ 12,990' 1111 Red Haliburton (Sperry Sun) DGRDualGammaRayLog_ - IIIPrhhJMINII. Date: 14-Feb-06 to 25-Feb-06- --- ,,its SORG M ( . SEX SP Mp SE ____ : 3FXE -� ' 7-..*- , _ �_ 1 t, - i it _ l . : .11I `, II 11111 '_t_ i -r . .... . 1 1111 ■11 - r _1 , ..: 1111 ■1111 . _ ... 13100I . lIll__lillIfi - 1!-i- NNW. 1 . .1 - - 1111 111111111 NEW' . ,' . - IMO' 111110 4a •■■ i immill ''l ' j-._. . !,+ v- 1111111mm■NIIIie MI I I e ■11 11 __-..__ . ■ 1111 _ ` 11111 _ VII wIi _ ii` _ r 1 _ _11111 !JIRMI NM 13200 11r� �.tl1 I ' , ■ 1� , , :. iiir1 l�1 __ _ '111111 11 _ �:_i _ i .._ 1 ii: : . ,.r_�_ 111 1�1 1 .-__-_-::;'41_.1I.ii 11,ranillalc __-__- . .mii I .—_.iI1.rI.iI. ■ l■ II 1 - ' . 11ii1•0■ X11111■ ■■ 1 . 1 .1111 illy u i ` 7 `._ 1� ■1111 I' . 11 I I-_ •. _. _ ... _ ■ Ili1■ 133°C1111111 dB ■■1111■ 11181 ■I _.. - ' ' , : ._ . ■!11 ■ i 1!1 11 ■ ■ ' ' 1III1 a a■'■■ ■■ ` '` y - i- . ■ ■11111 1 1t. g•�•_ _ NI _ ■illIl ■ 6 Tie In Strip for Perfs t "ll�� F 1 -.:1 f r k t { .. 12300 .i , T; - _ }-i-- ; . _ . . :r •---- L. i ■■ ll ,. I I ■11■''' , ! _ C 1.� 12400 + _ -"-'''''.%-tti • IIII — — _. IIII lir_ Adperf 12,440' to 12 ' •"• ■��/ p ,530 Y _ __. Red Haliburton (Sperry Sun) _ ,.;;j � '.� DGR Dual Gamma Ray Log --- • '* Date: 14-Feb-06 to 25-Feb-061. 5..4 25 i • 1 i T I1 `L I---t-t ,1 1-- • % 12600 s - i r. r. ,q I 1 ...„...,,........ . . , ... ______ , , .. , . , ___ • ,..... . <1 . , .i ..z.-.... „ ...5 L*--- 'N._ 1 T 1200 7 —� 1 __ �� - F t 7 Well Integrity History Dewatering '01 Rig ST 03/06 fixed slow TxIA comm > 03/06/06: Rig ST complete MIT-T Passed to 4000 psi, MITIA Passed to 4000 psi > 06/09/06: AOGCC MITIA Passed to 2500 psi > 06/25/07: OART complete no BUR > 07/09/07: Set new MCX SSSV @ 2193' > 12/15/09: MITIA Passed to 4000 psi > 06/01/10: AOGCC MIT-IA Passed to 2500 psi > 12/03/10: PPPOT-T Passed to 5000 psi > 12/06/10: Oper call in IAP @ 2300 psi > 12/08/10: MIT-IA Passed to 3750 psi > 05/07/12: Pulled SSSV > 05/30/12: Set SSSV 8 TREE=r 4-1/16"CW WELLHEAD= VETCO GRAY 16 14 B SA. t NOTES: WELL REQUIRES A SSSV WHEN ACTUATOR= BAKER ON MI. WELL ANGLE>70°@ 10189'. AS OF 3/21/06, KB ELEV= 66 15' POSSIBLE SOLIDS IN TOP OF LNR DUE TO MILLING ON BF ELEV= 40.43 RIG KOP= 4200' Max Angle= 93°@ 13355' Datum MD= 9960' ] [ Datum TVD= 8800'SS 2193' —14-1/2"HES X NIP,ID=3.813" 13-3/8"CSG,72#, L-80, ID=12.347" —i 2675' C 8773' -19-5/8"X 7"BKR PKR&HNGR, ID=6.25" Minimum ID = 3,725" @ 9793' 4-1/2" HES XN NIPPLE 9644' —14-1/2"HES X NIP,ID=3.813" Z 0 9665' HT X 4-1/2"BKR S-3 PKR, ID=3 875" I 9689' H4-1/2"HES X NIP,ID=3.813" 1 9793' H4-1/7'HES XN NIP,ID=3 725" �� 9795' 7""X 5"BKR ZXP LNR TOP PKR w/ 9-5/8"CSG,47#,N-80,ID=8.681" H 9772' ,.ii::. TIEBACK SLV, ID=5 25" ....... 11000. 9805' H4-1/2"WLEG, ID=3 958" i� ,ii —I ELN)TT NOT LOGGED 4-1/2"TBG 12.6#,L-80 TCII, 0152 bpf,ID=3.958" H 9805' 9815' I--T'x 5"BKR FLEX-LOC,LNR HNGR w/5"RS PACKOFF NIP,ID=4 250" WHIPSTOCK(02/14/06) H 9921' 9827' He"X 4-1/2"X0,ID=3.950" MILLOUT WINDOW(16-14B) 9916'-9921' ESZV(02/14/06) —{ 9941' ELM 13900' H4-1/2“CIBP(05/09/12) 4-1/2"TBG, 12.6#, 13-CR,ID=3 958" —{ 9978' g1[ , 7"LNR,26#, L-80, ID=6.276" —{ 10444' �� it I 14625' --I4-1/7'CIBP(08/21/08) 4-1/2"LNR, 12 6#, L-80, ID=3.958" —1 15175' ♦X4444444444' 440444444441 PERFORATION SUMMVIARY44444 Ad 444+4 �, REF LOG MWD GR ON 02125/06 141�4A ANGLE AT TOP PERF 92°@ 13400' 4�4�4�1�1. Note Refer to Production D8 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE Wilk, 2-4/5" 6 13400- 13425• 0 05/11/12 ������ 2-4/5" 6 13425- 13450• 0 05/10/12 2-4/5" 6 13450- 13475' 0 05/10/12 2-415" 6 13475- 13500 ' 0 05/10/12 4 2-7/8" 6 14150-14250 ' C 08/24/08 PBTD — 15221' \��\��\ 2-7/8" 6 15000-15100 ' C 05/19/06 —1 \```ii-► 4-1/2"LNR, 12 6#,L-80 IBT-M, 0152 bpf,ID=3.958" —1 15307' DATE REV BY COI MENTS DATE REV BY COMIMENTS PRUDHCE BAY UNIT 07/09181 ORIGINAL COMPLETION 09/05/08 GLM/PJC CIBR'PERF(08/21 -24/08) WELL 16-148 04/13/98 SIDETRACK(16-14A) 02/14/11 MB/JA/C) ADDED SSSV SAFETY NOTE PERMIT No `2060030 03110/06 LAZES SIDETRACK(16-14B) 01/17/12 TMNWJM) ADDED H2S SAFETY NOTE AR No. 50-029-20570-02 03/21/06' R• WUTLH DRLG DRAFT CORRECTION 05/15/12 TTW/JIV) CIBFY PERF(05/09. 11/12) SEC 24 T10N, R15E, 1534'SNL&527'EWL 05/19/06 D• MS/PJC PERFORATION 06/25/08 P• JP/PJC PERF REF LOG(05/16/08) BP Exploration(Alaska) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 8 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations U Perforate H Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ig Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Numbes: Name: BP Exploration (Alaska), Inc Development ❑ Exploratory ❑ 206 -003 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20570 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028332 PBU 16 -14B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): s To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 15307 feet Plugs measured 14625 feet true vertical 8990 feet Junk measured None feet Effective Depth measured 13900 feet Packer measured See Attachment feet true vertical 9013.4 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 31 - 111 31 - 111 1530 520 Surface 2641 13 -3/8" 72# L -80 30 - 2671 30 - 2670.79 4930 2670 Intermediate None None None None None None Production 9746 9 -5/8" 47# N -80 26 - 9772 26 - 8723.14 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet '! A i C 2 4 'a U12 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 9805 26 - 8749.27 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" MCX I -SSV 2193 2192.91 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13400' 13500' Treatment descriptions including volumes used and final pressure: 75 bbls 12% HCL, 75 bbls 9:1 Mud Acid, Final Pressure = 3226 psig 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 -9355 . 0 884 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: • Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: s, Oil ❑ Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSPE SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -315 Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature M ~ ti Phone 564 -4424 Date 8/7/2012 Form 10-404 Revised 10 /fie S A�U 9 2012 �� V 1 " t L 0,000- � " " Z Submit Orig inal Onl \�' �sil e l f � � Packers and SSV's Attachment ADL0028332 SW Name Type MD TVD Depscription 16 -14B SSSV 2193 2125.91 4 -1/2" MCX I -SSV 16 -14B PACKER 8773 7848.04 7" Baker Packer 16 -14B PACKER 9665 8570.45 4 -1/2" Baker S -3 Perm Packer 16 -14B PACKER 9795 8674.38 4 -1/2" Baker ZXP Packer Casing / Tubing Attachment ADLOO28332 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 31 - 111 31 - 111 1530 520 LINER 1143 7" 26# L -80 8773 - 9916 7915.04 - 8834.52 7240 5410 LINER 5512 4 -1/2" 12.6# L -80 9795 - 15307 8741.38 - 8990 8430 7500 PRODUCTION 9746 9 -5/8" 47# N -80 26 - 9772 -41 8723.14 6870 4760 SURFACE 2641 13 -3/8" 72# L -80 30 - 2671 30 - 2670.79 4930 2670 TUBING 9780 4 -1/2" 12.6# L -80 25 - 9805 -42 8749.27 8430 7500 Perforation Attachment ADL0028332 Meas Meas SW Operation Pelf Operation Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 16 -14B 5/11/12 APF 13400 13425 9025.05 9024.03 . 16 -14B 5/10/12 APF 13425 13500 8957.03 8954.21 . 16 -14B 5/9/12 BPS 13900 15000 8946.4 8926.13 16 -148 8/24/08 APF 14150 14170 8941.44 8941.08 16 -14B 8/23/08 APF 14170 14190 8941.08 8940.72 16 -14B 8/23/08 APF 14190 14210 8940.72 8940.37 16 -14B 8/23/08 APF 14210 14230 8940.37 8940.01 16 -14B 8/22/08 APF 14230 14250 8940.01 8939.65 16 -14B 8/21/08 BPS 14625 15000 8932.28 8926.13 16 -148 5/19/06 PER 15000 15100 8926.13 8925.02 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Daily Report of Well Operations ADL0028332 * * ** WELL SHUT IN ON ARRIVAL*** RAN 3.85" G.RING,SAT DOWN @ 2172 SLM.ALL CLEAR RAN 4 1/2 GS,W/ MCX PRONG, SAT DOWN © 2170 SLM. LATCHED AND PULLED 4 1/2 MCX SER.(M- 24),RECOVERED ALL PACKING. RAN 3.70 CENT,S.BAILER,SAT DOWN @ 10,460' SLM,DUE TO DEVIATION,RDMO. 5/7/2012 * * * ** LEFT WELL SHUT IN,TURNED WELL OVER TO DSO. * * ** T /I /0= 2000/400/200 Temp =Hot Assist Slickline (freeze protect) Safety Drill (Man Down) Pump 40 bbls 60* 60/40 meth down FL, shut pit valve pressure up FL to 2500 with .2 bbls. 5/7/2012 Pump 40 bbls 60* 60/40 meth down TBG. Slickline on well upon LRS departure. CTU #9 w 1.75" ct :Job objective, Log w / GR CCL set CIBP perforate , Acid stimulation 5/8/2012 «< Continue WSR on 5/9/12 »> CTU #9 w/ 1.75" ct. Job objective: Log w / GR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/8/12 »> RIH w / PDS GR CCL logging tools & WRP drift 3.70 "x 3.93'. Unable to get past top pelf @ 14250', log up from 14233' to 13000'ctmd. POOH to surface. MU & RIH w/ Weatherford 3.2" XO, 3.075" XO, 3.625" Hyd setting tool, 3.625" setting adapter, 3.565" CIBP. Corrected flag depth to middle of element on CIBP. Correction +6ft. Set 4.5" CIBP w /2150psi CTP at 13900ctmd . Set down 2klbs to confirm plug is set. Good indication of 5/9/2012 plug set. POOH. CTU #9 w/ 1.75" ct. Job objective: Log w / GR CCL, set CIBP, Perforate. Acid stimulation «< Continue WSR from 5/8/12 »> RIH w / PDS GR CCL logging tools & WRP drift 3.70 "x 3.93'. Unable to get past top perf's @ 14250', log up from 14233' to 13000'ctmd. POOH to surface. MU & RIH w/ Weatherford 3.2" XO, 3.075" XO, 3.625" Hyd setting tool, 3.625" setting adapter, 3.565" CIBP. Corrected flag depth to middle of element on CIBP. Correction +6ft. Set 4.5" CIBP a , w /2150psi CTP at 13900ctmd . Set down 2klbs to confirm plug is set. Good indication of plug set. POOH. At surface ball has been recovered.RIH w / 2.80 X 25' PJOmega pert guns 5/9/2012 «< Continue WSR on 05/10/12 »> CTU #9 w/ 1.75' ct. Job objective: Log w TGR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/9/12 »> Perforate w / 2.80" x 25' HSD -PJ Omega 2906 -HMX guns / Top shI 1341_5' Bottom Shot 5/10/2012 13500' RIH w / gun run #2 CTU #9 w/ 1.75" ct. Tob objective: Log w T GR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/9/12 »> Perforate w / 2.80"_x 25' HSD -PJ Omega 2906 -HMX guns. RIH w/ gun run #1. Top shot 13475', Bottom Shot 13500'. RIH w / gun run #2. Tagged 4.5" CIBP. Corrected bottom shot off the plug depth. Total correction +15ft. PUH to bottom shot depth and fire the guns. Tom 5/10/2012 shot 13450' Bottom shot 13475'. POOH. RIH w/ gun run #3. CTU #9 w/ 1.75" ct. Job objective: Log w / GR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/9/12 »> Perforate w / 2.80" x 25' HSD -PJ Omega 2906 -HMX guns. RIH w/ gun run #1 Top shot 13475', Bottom Shot 13500'. RIH w / gun run #2. Tagged 4.5" CIBP. Corrected bottom shot off the plug depth. Total correction +15ft. PUH to bottom shot depth and fire the guns. Top shot 13450', Bottom shot 13475'. POOH. RIH w/ gun run #3.Fired guns Top shot 13425' 5/10/2012 Bottom shot 13450' POOH At surface ball has been recovered «« Job in progress »» • Daily Report of Well Operations ADL0028332 CTU #9 w/ 1.75" ct. Job objective: Log w / GR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/10/12 »> RIH w / 2.80" x 25' HSD -PJ Omega 2906 HMX guns run #4 Tagged 4.5" CIBP. Corrected bottom shot off the plug depth. Total correction +10ft. PUH to bottom shot depth and fire the guns. Top shot 13400', Bottom shot 13425'. POOH. RIH w/ gun run #4. At surface ball has been recovered. Weekly BOP test completed and passed. Establish injection rate =0.7 bpm @ 1930 psi (see log for details). MIRU cement 5/11/2012 pump van. «< Job in Progress »> CTU #9 w/ 1.75" ct. Job objective: Log w / GR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/11/12 »> Begin Acid stimulation wash acrass pelfs 13400' to 13500' pump total of 75 bbls of Inc, 5/12/2012 HCL acid & 75 bbls of 9:1 Mud acid. riguInTrIr ct. Job objective: Log w / GR CCL, set CIBP, Perforate, Acid stimulation «< Continue WSR from 5/11/12 »> Performed Acid stimulation washed across perf s 13400' to 13500' pump a total of 75 bbls of 12% HCL acid & 75 bbls of 9:1 Mud acid. Overflushed CT with NH4CI and FP. Flushed down BS with NH4CI and performed injectivity test (see log for details). Max injection rate 4bpm @ 1800psi WHP. FP the well. RDMO. 5/12/2012 «< JOB COMPLETED »> ***WELL S/I ON ARRIVAL** *(Profile Mod) TAGGED SVLN @ 2178' MD/ 2193' MD SET 4 -1/2" MCX(serial# M -05, 1.375 BEAN) @ 2178' SLM/ 2193' MD 5/30/2012 ** *WSR CONT. ON 5/31/12 * ** ** *CONT. FROM 5/30/12 WSR ** *(Profile Mod) RAN 4 -1/2" CHECK SET TO 2176' SLM/ 2193' MD(sheared) 5/31/2012 ** *WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED * ** • Tt2EE= ' 4 -1/16" CW WELLHEAD - VETCO GRAY 16-14B SAFETY NOTES: WELL REQUIRES A SSSV WHEN ACTUATOR = BAKER ON MI. WELL ANGLE> 70 @ 1 0189'. AS OF 3121/06, POSSIBLE SOLIDS IN TOP OF LNR DUE TO MILLING ON KB ELEV = 66.15' BE ELEV = 40.43 RIG KOP= 4200' Max Angle = 93° 13355' Datum MD= 9960' DatumTVD= 8800'SS I 2193' H4-1" HESXNIP,ID= 3.813" 113 -3/8" CSG, 72 #, L -80, ID = 12.347" IH 2675' I C 8773' — I9 -5/8" X 7" BKR PKR & HNGR, ID = 6.25" ' Minimum ID = 3.725" @ 9793' 4 -1/2" HES XN NIPPLE ,. ,,,,,!,!4,,:;, i 9644' —j4-1/2" HES X NIP, ID = 3.813" /.1 9665' 1-17" X 4-1/2" BKR S -3 PKR, ID = 3.875" 1 I 9689' —14-1/2" HES X NIP, ID = 3.813" I 9793' H4-1/2" HES XN NIP, ID = 3.725" I 9795' - 1 7" X 5" BKR ZXP LNR TOP PKR w / 1 9-5/8" CSG, 47 #, N -80, ID = 8.681" H 9772' TIEBACK SLV, ID = 5.25" ' : ;; ;; 9805' H4-1/2" \LEG, ID = 3.958" I '' `A 1 H ELNO TT NOT LOGGED 1 I L -80 TCII, 0152 bpf, ID = 3.958" H 9806' 9815' I— 7" x 5" BKR FLEX -LOC, LNR HNGR w/5" RS PACKOFF NIP, ID = 4.250" I WHIPSTOCK (02/14/06) H 9921' 1 L 9827' 1-15" X 41/2" XO, ID = 3.950" I MIL LOUT WINDOW (18-14B) 9916' - 9921' I ESZV (02/14/06) H 9941' ELM I- - 13900' H 4-1/2" CIBP (05/09/12) I 14-1/2" TBG, 12.6 #, 13-CR, ID= 3.958" H 9978' $ , , 17" LNR, 26 #, L -80, ID = 6.276" H 10444' (-77 ' , 1 4-1/2' LNR, 12.6#, L -80, ID = 3.958" I 15175' :MAW.? ` 14625' —14 1/2" CIBP (08!21108) 1 PERFORATION SUMNIAARY �••••/� C / • •••••1 REF LOG: GR ON 0225!06 � � I � � � � � � � � � � j ■ , A MW ANGLE AT TOP PERF: 92 @ 1 �����1�����1 tiv Note: Refer to oducti for h' rical perf data = 0l" ' SIZE ST''' INTER pn /Sqz DATE 'gel/A, 2 -4/5" 6 13400 - 13425 1 0 05/11/12 2 -4/5" 13425 - 13450 ' 0 05/10/12 2 -4/5" 6 13450 - 13475 0 05/10/12 2 -4/5" 6 475 - 13500 0 05/10/12 A ;\ 2-7/8" 6 14 4 C 08/24/08 I PBTD -I 15221 n`% 2 -7/8" 6 1500 - 15100 C 05/19/06 � ;;`� \ ► 14 -1/2" LNR, 12.6 #, L -80 IBT -M, 0152 bpf, ID = 3,958" H 15307 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/09/81 ORIGINAL COMPLETION 09/05/08 GLMVPJC CIBP/ PELF (08/21 - 24/08) WELL: 16-148 04/13198 SIDETRACK (16 -14A) 02/14 /11 MEI/JMD ADDED SSSV SAFETY NOTE PERMIT No: `2060030 03/10106 N2ES SIDETRACK (16 -14B) 01/17/12 TMNWJMD ADDED H2S SAFETY NOTE AR No: 50- 029 - 20570 -02 03/21/06 RWL/TLH DRLG DRAFT CORRECTION 05/15 /12 TTW /JND CIBP/ PERF (05/09 - 11/12) SEC 24, T10N, R15E, 1534' SNL & 527' EWL 05/19/06 DMS /PJC PERFORATION 06/25/08 PJP/PJC PERF REF LOG (05/16/08) BP Exploration (Alaska) • SINE [IF A[LASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Matt Brown Petroleum Engineer % 0 (23 BP Exploration (Alaska), Inc. 10 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 16 -14B Sundry Number: 311 -315 Dear Mr. Brown: l 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, P Daniel T. Seamount, Jr. Chair DATED this 13 day of October, 2011. Encl. tr • RECEIVED STATE OF ALASKA ID ' l; OCT 201 ALASKA /AND GAS CONSERVATION COMMISSIOW /p -A,y-// APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Oil &Gas Oons. Commission 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Alaska Chan :0 rogram ❑ Suspend ❑ Plug Perforations 0 - Perforate 0 ' Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El- Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206 -0030- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 . 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20570 -02 -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: Spacing Exception Required? Yes ❑ No ❑ PBU 16-14B . 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028332- PRUDHOE BAY Field / PRUDHOE 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): 15307 • 8990 • 15221- 8990.86 - 14625 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 94# H -40 31 111 31 111 1530 520 Surface 2641' 13 -3/8" 72# L -80 30 2671 30 2671 4930 2670 Production 9746' 9- 5/8 "47# N -80 26 9772 26 8723 6870 4760 Liner 1143' 7" 26# L -80 8773 9916 7915 8835 7240 5410 Liner 5512' 4 -1/2" 12.6# L -80 9795 15307 8741 8990 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 25 9805 Packers and SSSV Tvoe: 7" Baker Packer Packers and SSSV MD and TVD (ft): 8773 7915 4 -1/2" Baker S -3 Perm Packer 9665 8637 4 -1/2" Baker ZXP Packer 9795 8741 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/25/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Y Printed Name - r Title PE Signature i� Phone Date / /`' 564 -5874 10/11/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ! ' — 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /t ` 0 I APPROVED BY Approved bye, A � COMMISSIONER THE COMMISSION Date: 6//3/ S OCT , % /a. /3A ORIGINAL //3/// Form 10-403 Revise. 2010 ub �u Duplicate 16 -146 206 -003 ' PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 16 -14B 5/19/06 PER 15,000. 15,100. 8,993.13 8,992.02 16 -14B 8/21/08 BPS 14,625. 15,000. 8,999.28 8,993.13 16 -14B 8/22/08 APF 14,230. 14,250. 9,007.01 9,006.65 16 -14B 8/23/08 APF 14,170. 14,190. 9,008.08 9,007.72 16 -146 8/23/08 APF 14,190. 14,210. 9,007.72 9,007.37 16 -14B 8/23/08 APF 14,210. 14,230. 9,007.37 9,007.01 16 -14B 8/24/08 APF 14,150. 14,170. 9,008.44 9,008.08 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III • • b • y 144••••• To: C. Olsen/T. Norene Date: September 30, 2011 J. Bixby /R. Liddelow From: Anthony McConkey, DS 16 Production Engineer Est. Cost. Matt Brown, Wells Group Engineer IOR: 250 AFE: APBD16WL14 Subject: DS 16 -14b CIBP, Add Perf, and Acid Stimulation 3 v .,t MI 5/4 j Cyr — 7 Attached is a CT procedure that includes the following steps: °• •�� 1. S Pull MCX/Drift to deviation 2. C Set CIBP, Adperf, Mud Acid Stim • 3. S Set MCX Well Status: Current Status SI Injector Last Inj: 7000 BWPD, 1900 psi WHIP Max Deviation 93° at 13356 ft Min ID 3.725" @9793' MD Last Tag: 14625' MD set CIBP 22- Aug -08 Last Downhole Op: Set MCX 29- Aug -08 Latest H2S value: No data available for well SBHP/T: 3390 psi / 188° ave for DS16 for 2010 & 2011 SBHP/T: No Data available for 16 -14B Sundry Required Well History: Well 16 -14Bi is a horizontal MIST injector sidetracked into upper Zone 2 in March 2006. The well path comes into the 16-01i pattern and will eventually support multiple Z2 /Z3 patterns as future perforations are placed. It has 4 -1/2" L -80 tubing with perforations from 15,000' – 15,100'. The plan for this well is to have six sets of perfed injection intervals, each set separated by a CIBP. Due to 16- 14B's close proximity to perforations in 16 -14A, the plan may be reduced to five sets of perfed injection intervals instead of six. MI will be injected into each set w ith each "plug - pert -MI injection" cycle lasting 1 - years. In the first set, 100' of perforations were shot from 15,000' – 15,100' on V 05/19/06 and 9 bcf of MI was injected into those perforations from May, 2006 to July, 2007. The well was put on PWI on 01/30/2008, but only injected a maximum of 5200 bwpd, dropping off to 615 bwpd. Although the well has injectivity problems on water, stimulation of the perfs has shown to have good effects on injectivity on MI. Response in the offset producers to the first bulb of MI was strong, although slightly choked due to commonline constraints on the drillsite. On 8/24/2008 the second set of perforations were shot from 14150'- 14250' and injected approximately 4.3 bcf of MI prior to swapping back to PWI. Production metering problems at DS16 began in September 2010 but were not discovered until December 2010- causing significant Toss of MI response due to unforeseeable metering issues. The effects of MI on the crude produced from the wells caused the 'new' Red Eye WC meter to see oil as water- making some of the wells uncompetitive on the drillsite. These wells, then unfortunately were SI until this effect was discovered in December 2010 and they were • • immediately brought back online. Then, due to issues with meter calibration it became troublesome to track the benefits of the MI bulb and eventually some of the wells were shut in again. 16 -14B was put back on PWI on 08/01/2011 due to high RMI in the offset producers as well as inability to track the benefits. The second bulb of injection did show some response (although convoluted) from offset producing wells, including 09 -13, 16 -13, 16 -20, 16 -19, and 16 -21. Following this metering incident, the Phase Dynamics meter is now being used as default WC measurement on the drillsite, and will better allow us to optimize and track MI benefits during the third bulb of MI. Obiective: u .I, ML � 3r� b The objectives of this job are to isolate the current perforations, add 100' of new perfs from 13,400' — 13,500' and stimulate the perfs with a mud acid job. The mud acid job will use OilSeeker for diversion, with acid pumped in three stages. If you have any questions or comments regarding this procedure, please call: Matt Brown Anthony McConkey 564 -5874 (w) 564 -4146 (W) 223 -7072 (c) 529 -6199 (C) 344 -1130 (h) Cc : Well Files Attachments Perf Form Tie in Log Header Page CIBP Tie in Strip Perf Tie in Strip Well Integrity History Wellbore schematic II • • Previous CIBP /Adperf /Stim Job This job is similar to the previous CIBP /Adperf/Acid stim job of 8/2008. It is recommended to review the WSRs from 8/20/08 to 8/24/08. The various CT runs are summarized below. Initially, there were difficulties getting down to set the CIBP. Once the well had been circulated to KCI with Safelube, the various BHAs could make it to bottom without incident. Run #1: Dummy CIBP. Well had low injectivity. Circ'd McOH from 5000' to surf for FP. Couldn't get down to CIBP set depth. Run #2: FCO with 2" JSN. Low injectivity. Got to 14800' no problems Run #3: Dummy CIBP. Got to setting depth but had to work thru some spots Run #4: Attempt to set CIBP. Set down shallow (14000' vs target 14625'). POH. Run #5: Couldn't get past 13358' w /3" JSN. Circ 1% KCI + Safelube from 13358'. Circ McOH from 5000' to surf. Run #6: Set CIBP. RIH to 14650' and set CIBP at 14625'. No problems RIH. PT CIBP to 3000 psi- ok. Run #7: Perf gun #1- ok Run #8: Perf gun #2- ok Run #9: Perf gun #3- ok Run #10: Perf gun #4- ok Run #11: Perf gun #5- ok Run #12: Mud acid stim w /2" JSN Well Integrity There are no documented issues with well integrity. The well integrity history is attached. Job Notes Well 16 -14 has exhibited low injectivity in the past. Bullheading fluids could potentially be difficult. The rig up should include a return line to an offset producer; any returns should be taken to the offset producer's flowline. A contingency flowback tank should be rigged up also. The procedure calls for displacing the well with KCI + Safelube to help get coil to bottom. The tie in log for setting the CIBP and for the adperf is the Halliburton (Sperry Sun) DGR /EWR, which was logged 14- Feb -06 to 25- Feb -06 (copy of log header, CIBP and adperf tie in strips attached). Volumes vol, Tubing top MD bot MD Size ID bbl /ft ft bbls 4 -1/2" tub 0 9805 4 -1/2" 12.6# 3.958 0.0152 9805 149.2 vol, Casing top MD bot MD Size ID bbl /ft ft bbls 4 -1/2" liner 9805 14150 4 -1/2" 12.6# 3.958 0.0152 4345 66.1 4 -1/2" liner across perfs 14150 14250 4 -1/2" 12.6# 3.958 0.0152 100 1.5 4 -1/2" liner to CIBP 14250 14625 4 -1/2" 12.6# 3.958 0.0152 375 5.7 . • 1. Pull MCX. • 2. Drift to deviation w /dummy CIBP - Note: if there is evidence of Schmoo from the drift, perform contingency SBG as follows: Contingency SBG - Bullhead fluids -pump at max rate with max WHP of 3000 psi - monitor IA pres and be prepared to bleed IA a. 5 bbls 60/40 McOH water b. 232 bbls SBG c. 5 bbls 60/40 McOH water d. SD. Let SBG soak for 3 hours e. 175 bbls 1% KCI f. 40 bbls 60/40 McOH water yf r CIBP 1. Rig up to take returns down adjacent well's flowline. Rig up a contingency flowback tank. Check that the well is shut in at lateral and wing valves. Have hose rigged up to IA to bleed or pump small volumes. Note that IA and OA FL's were found near surface on 22- Jul -11. 2. MIRU CT. 3. MU BOT 1.90" OD CTC. Pull test. 4. RIH with BHA #1 — 1.90" OD CTC, 1.688" OD DCV, 1.688" OD Hyd Disco, 1.688" OD Burst, XO, 2.20" OD PDS MEM GR/CCL in carrier, XO, dummy CIBP. 5. While RIH, pump 1% KCI + Safelube down backside. FP top of well once wellbore is displaced to KCI + Safelube. Note: when the well was on PWI, injectivity was about 4.5 bpm at 1900 psi WHIP. 6. Perform weight checks as necessary. Drift to top of existing CIBP @ 14625' MD. Flag pipe as needed. Log tie in pass from 14100' up to 13000'. POOH. 7. Download memory tool data. Determine depth correction reference to Halliburton (Sperry Sun) DGR/EWR, which was logged 14- Feb -06 to 25- Feb -06. 8. MU BHA for CIBP: CTC, DCV, Hyd Disco, Burst disc, Setting tool, CIBP 9. RIH with CIBP. Correct flag depth and set CIBP at 13900' per PE Manual guidelines. PT CIBP to 2500 psi DP. POOH. 10. RU for perforating. RIH and perforate with 2 -7/8" PowerJet Omega charges, 6 SPF from 1. 400' — �3,�nn° nnn rPf Hallib on (Sperry Sun) DGR/EWR Do not use 3 -3/8" guns due to concerns about residual fill. 11. Pull above the perforations and perform an injectivity test by pumping about 25 bbls of 60/40 McOH water down 4 -1/2" tubing @ max pressure of 2000 psi. Note injectivity on WSR. POOH. . • Acid Stimulation 12. RIH with MHA + 2 -1/2" jet swirl nozzle (Note: Min ID = 3.725" @ 9793'). Pump fluids per attached Pump Schedule Reciprocate nozzle across newly perforated interval while pumping fluids. Note: If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. 13. Do an injectivity test post acid stim by pumping -20 bbls 60/40 McOH down the backside at 2000 psi WHP. Establish a stabilized rate and pressure to make certain of positive injection. POOH. FP top 2500' of well as necessary. %V ,�;2'',0% ;;; 1. Run MCX. RDMO Stimulation Target Total Footage 13400'- 13500' (100 ft) Acid Design 12% HCI Pre -Flush - 30 gal /ft 9:1 Mud Acid - 30 gal /ft Acid Volume 12% HCI - 75 bbls V 9:1 Mud Acid - 75 bbls Diversion 7.5 gal /ft of 7.5% OIISEEKER Over Flush Design 34 gal /ft - 80 bbls Reservoir Pressure 3390 psi /188° @ 8800' SS Fluid Requirements Fluid Type Vol Vol, gal 3% NH4CI + F103 210 bbls 8,820 gal 12% HCI 75 bbls 3,150 gal 9:1 Mud Acid 75 bbls 3,150 gal 7.5% OIISEEKER 100 bbls 4,200 gal HCI & Mud Acid Loading for: 12% HCI 9/1 mud acid tot chemical tot chemical Product Code: Function: Units: per Mgal per Mgal in HCI in Mud acid A264 ACI gal /Mgal 6 6 19 gal 19 gal A201 Inhibitor Aid gal /Mgal 15 15 47 gal 47 gal F103 Flowback aid gal /Mgal 2 2 6 gal 6 gal L058 Iron Control Ib /Mgal 20 20 63 Ib 63 Ib W054 Antiemulsifier gal /Mgal 5 5 16 gal 16 gal U067 Mutual Solvent gal /Mgal 0 50 0 gal 158 gal • • Acid Pump Schedule Stage Step Description Fluid Stage Cum CT Depth Pump down Vol Vol 1 Preflush 3% NH4CI + F103 50 50 13100 -13600 CT 2 Acid 12% HCI 25 75 13500 -13400 CT 3 Mud Acid 9:1 Mud Acid 25 100 13400 -13500 CT 1 4 Overflush 3% NH4CI + F103 20 120 13500 -13400 CT 5 Diverter 7.5% OIISEEKER 50 170 13400 -13500 CT 6 Spacer 3% NH4CI + F103 20 190 13500 -13400 CT 7 Acid 12% HCI 25 215 13400 -13500 CT 8 Mud Acid 9:1 Mud Acid 25 240 13500 -13400 CT 2 9 Overflush 3% NH4CI + F103 20 260 13400 -13500 CT 10 Diverter 7.5% OIISEEKER 50 310 13500 -13400 CT 11 Spacer 3% NH4CI + F103 20 330 13400 -13500 CT 12 Acid 12% HCI 25 355 13500 -13400 CT 3 13 Mud Acid 9:1 Mud Acid 25 380 13400 -13500 CT 14 Overflush 3% NH4CI + F103 80 460 13500 -13400 CT • • PERFORATING PROCEDURE HOW rwumruue& —u Well: 16-14B API #: 50 -029- 20570 -02 Date: 30- Sep -11 Prod Engr: Anthony McConke! Office Ph: 564 -4146 I H2S Level: Home Ph: 529 -6199 Cont Fax: unknown CC orAFE: APBD16WL14 WBL Entries IOR Type Work Desciption 250 C Set CIBP 250 C ADPERFS (100') 250 C Acid Stim Well Objectives and Perforatina Notes: Add 100 of perfs for MIST injector Attachment: Reference log with proposed perfs annotated, 5 '/100' scale. Reference Log Tie in Log Add 0 feet Log: DGR/EWR DGR/EWR tie-in log to be on Date: 14 -Feb-06 to 25- Feb-06 14- Feb -06 to 25 -Feb -06 depth with the reference log. Company: Halliburton/Sperry Halliburton/Sperry Depths (from -to) Depths (from -to) Feet SPF Orient Phasing Zone AdIRe /Iperf 13,400' - 13,500' 13,400' - 13,500' 100' 6 random 60° 4 ADPERFS Requested Gun Size: 2 -7/8" Charge: 2 -7/8" Power Jet Omega Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary Preferred Amount of Drawdown/Suggestions to Achieve Drawdown N/A Last Tag: 14,625 ft MD on 8/22/2008 Est Res. Pres. @ 8800' MD is 3,390 psi Perforation Summary Summary Dist Well: 16 -14B Town: Date: API #: 50 -029- 20570 -02 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf O I B/ U - 2 -7/8" random 6° 60° 4 ADPERFS O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - O /B /U _- O/B/U - . . • • Tie In Log Header Page 7 . riP erry•Bun DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity i Horizontal Presentation "s INBITE 4 IN . r' 1:-600 11:240 1 HALLIBURTON Company : BP Exploration Alaska, Inc. Rig ; Nabors 2ES Well : 16-14B1 Z . Field : Prudhoe Bay 1 ' 4 c t k tli 7 , !I . Country : USA ' ! • * 0 11 Ct" .: • : E , - : API Nurnber : 50-029-20570-02 0 z; Latitude , 70 1r 34.68• North ; Other Services —I ° I lcrigilude : iar 13' 53.14" Wee! —J '., A131 At Bit Inclination 11J i I ; 11 E As 51 I AK ....Late Plaike ZN 4 X 719 ft ; l Q r4 1 ‘._ I AK State Piai.e ZN a Y = 5,929 ,396 ft Permanent Datum : Meen Sea Levet Elevahon • 0.00 R Elev. Ka 0 00 ft ' I Log Measured F rorn . OM Floor 87.00 ft Above Permanent Datum DF 87.00 ft GL 38.50 It Dsiling Measured From , WU Floor rtiutlob1 IND 0.00 ft Depth Legjell 9,916,00 I To 15,307.00 ft ; Unit No. 118 Job No. AK4AW Date Ls' d 14-Feb46 To 25-Feb I i Teta! Depth MD : 15,307.00 11 TVD : 11,989.99 it I Plot Type : Field Spud Date 14-Feb-06 ; Piot Dale : 254eb-08 Ruo No . „„ , „.„17 RecurOJMOt„ , Run No „ „ . „ ,Bcpiiisiie,'R,tio:rej irk40) ' Sce 1 6,14 in „9.91,6.00 ft, 1„9.$43,00,tt„ „„ „„ „ . „ 2 „ 6,125,,In„„. „ 9,94,;3.0011 1 10,64t,txin; „„ . „„ „„ „ „ a , 6 125 In 10, el7,,00 4,15307,0051.. Casing Record tmpi Weight i From To SURFACE „ 1 .. , ,„9,625 in 47.00 big , SURFACE 9.772,00 tt 1 „ „„ ",, 7 000 0 „ 26.00 Lpf ;', .8,774 OQ rt 9,91O0Q ft ' „ „ _ „ „ , 1 • • Tie In Strip for CIBP 1 — I -. : r-----......,. ! , „,..,„ t - - - ____...„ - --- ,-;--, ,-,----- . + j .. �. . 5 13850 4 { 3 { Set CIBP 13900' i t ._. Ref Halliburton (Sperry Sun) DGR Dual Gamm Ray log Date: 14- Feb -06 to 25- Feb -06 , _-1-.t f/ J . J r � n . I J t 13950 ..-_ . } _. . t t . H „ z *Nil .-”: 3 . . MN _ f l x t _ t 1 - 4 . _ • • Tie In Strip for Perfs oi t { ~ Adperf 13400' to 13500' , } Ref Halliburton (Sperry Sun) own „. 1 'I DGR Dual Gamm Ray log - ' ...:. e K Date: 14- Feb -06 to 25- Feb -06 smog . �.. 1l f . r __ , _ . , ) • • _s5.0 1 i y . •,... , i f 1/1:: , . . , 1 I • • Well Integrity History Dewatering '01 Rig ST 03/06 fixed slow TxIA comm > 03/06/06: Rig ST complete MIT -T Passed to 4000 psi, MITIA Passed to 4000 psi > 06/09/06: AOGCC MITIA Passed to 2500 psi > 06/25/07: OART complete no BUR > 07/09/07: Set new MCX SSSV @ 2193' > 12/15/09: MITIA Passed to 4000 psi > 06/01/10: AOGCC MIT -IA Passed to 2500 psi > 12/03/10: PPPOT -T Passed to 5000 psi > 12/06/10: Oper call in IAP @ 2300 psi > 12/08/10: MIT -IA Passed to 3750 psi • 0 TREE= 4- 1/16" OW 16 1 4 B SAFETY NOTES: 70° @ 10189' WELLHEAD = VETCO GRAY ACTUATOR; BAKER AS OF 3/21/06, POSSIBLE SOLIDS IN TOP OF LNR k ' ' = " ' ' ' 66.1 DUE TO MILLING ON RIG BF. ELEV = 40.43 ' KOP= 4200' Max Angle = 93 @ 13355' Datum MD = 9960' Datum TV D = 8800' SS I I 2193' H4 -1/2" HES X NIP, ID = 3.813" I 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2675' I--i _1 ■ 8773' H9-5/8" X 7" BKR PKR & HNGR ID = 6.25" I Minimum ID = 3.725" @ 9793' ' 4 -1/2" HES XN NIPPLE ' 94' - 14 -1/2" HES X NIP, ID= 3.813" I ►�� 9665' H7" X 4 -112" BKR S -3 PKR ID = 3.875" I I I 9689' I— I4 -1/2" HES X NIP, ID = 3.813" I 9793' — I4 -1/2" HES XN NIP, ID = 3.725" 1 9795' 7" X 5" BKR ZXP LNR TOP PKR w / 1 9 -5/8" CSG, 47 #, N -80, ID =8.681" H 977Z .. % TIEBACK SLV, ID =5.25" , , • ..r .' ∎ :'. 9805' 4-1/2" WLEG, ID = 3.958" If .. 'f I I H1 E LMD TT NOT LOGGED 14-1/2" TBG 12.6#, L -80 TAI, .0152 bpf, ID = 3.958" H 9805 9815 n 7 " x 5 BKR FLEX -LAC, LNR HNGR w /5" RS PACKOFF NIP, ID = 4.250" (WHIPSTOCK {02/14106) H 9921' I 9827 H5" X 4-1/2" XO, ID = 3.950" I ■ S I ESZV (02/14/06) H 9941' ELM ° --....-- MILLOUT WINDOW (16 -14B) 9916' - 9921' '' I 14625' 1-14 -112" CIBP (08 /21/08) 1 14-1/2" TBG, 12.6 #, 13 -CR, ID =3.958" H 997W I fir q,3 6�J ;K�c L� 1 7" LNR 26 #, L -80, ID= 6.276" H 10444' ` Or ,.4444... IVO 44444�p, 4 -1/2" LNR, 12.6 #, L -80, ID= 3.958" H 15175 i• 14 4 N 44r� • P ■ • # 4 • • • * 4 . 1 1 t • • • • a s t i AI 1 . 4 4 4 . 4 1 Per r \ct 6 � e 4K PERFORATION SUMMARY I••••• 1,1,E 4 ,4 REF LOG: MWD GR ON 02/25/06 ANGLE AT TOP PERF: 91 ° @ 14150' 4 Note: Refer to Production DB for historical pert data x.4.4.1.1.1 SIZE SPF INTERVAL Opn/Sqz DATE 2 -7/8" 6 14150 - 14250 O 08/24/08 2 -7 /8" 6 15000 - 15100 0 05/19/06 4� J ** * ` IPBTD H 15221' * * *.. .% t*. 14-1/2" LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" H 1530T I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/09/81 ORIGINAL COMPLETION 09/05/08 GLM/PJC OBR PERF(08 /21 - 24/08) WELL: 16 -14B 04/13/98 SIDETRACK (16 -14A) PERMIT No: r 2060030 03/10/06 N2ES SIDETRACK(16 -14B) API No: 50 -02.9- 20570 -02 03/21/06 RWUTLH DRLG DRAFT CORRECTIONS SEC 24, T1 ON, R15E 1534' SNL & 527' EWL 05/19/06 DMS/PJC PERFORATION 06/25/08 PJP /PJC PERF REF LOG (05/16/08) BP Exploration (Alaska) OPERABLE: Injector 16 -14B (PT�2060030) Passing MITIA - Verified competant... Page I of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, December 20, 2010 4:59 AM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; Cismoski, Doug A; Engel, Harry R Cc: King, Whitney; Longden, Kaity; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Injector 16 -14B (PTD #2060030) Passing MITIA - Verified two competant barriers Attachments: MIT PBU 16 -14 12- 08- 10.xis; 16 -14B TIO Plot 12- 19- 10.doc All, Injector 16 -14B (PTD #2060030) passed an MITIA to 3750 psi on 12/08/10. In addition, the IA pressure has remained stable around psi since it was bled for the MITIA as seen on the attached TIO plot. The passing test verifies two competent barriers. The well has been reclassified as Operable and may continue on injection. A TIO plot and MIT form have been attached for reference. <<MIT PBU 16 -14 12- 08- 10.xls>> «16 -14B TIO Plot 12- 19- 10.doc>> Thank you, Torin Rosch tiger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376`[ Cell (406) 570 -9630 Pager (90 7) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, December 07, 2010 6:00 AM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; "Schwartz, Guy (DOA'; 'Regg, James B (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; Cismoski, Doug A; Engel, Harry R; Longden, Kaity Cc: Murphy, Gerald L; Janowski, Carrie; Quy, Tiffany; King, Whitney Subject: UNDER EVALUATION: Injector 16 -14 (PTD #2060030) Sustained IA Casing Pressure All, WAG injector 16 -14 (PTD #2060030) was found to have sustained IA casing pressure. The wellhead pressures were 3200/2310/170 psi 12/6/10. The well has been reclassified as Under Evaluation and placed on a 28 clock. The plan forward is as follows: 1. DHD: MIT -IA to 4000 psi. 2. DHD: Bleed IA pressure and monitor build up rate. 12/20/2010 OPERABLE: Injector 16 -14B (PT* 2060030) Passing MITIA - Verified t competant... Page 2 of 2 A TIO plot and wellbore schematic are attached for reference. << File: 16 -14 TIO plot.doc >> << File: 16 -14B WBS.pdf >> Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer phone: (907) 659 -5102 AKDCWelllntegrityCoordinator @bp.com 12/20/2010 W.t UM4 j i I —W -Tbg —DA 2,4'11) BOA OOOA On i i i i.Doo I 07 /2Er0 1042110 70Wd110 10'16710 1022 10. 1110 1b7C110 11113/10 ivE9.ho 1L27110 72,64 /10 IL 1110 12718110 I I njector 16 -14 TIO Plot W.I. 1414 1 � – I 4om 3M —4— Tbn + IA oa z000 ooa +000A — on 1A00 ! MMA0 m . sma o34b/10 10107/70 lalmo ICA V1O 1023710 1ord0/IO 1IAMO 1171AIO lir"D 11127110 Mwo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.regga(,alaska.gov; doa. aogcc.prudhoe.bay(a_)alaska.gov; phoebe.brooks(d)alaska.gov; tom.maundercDalaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay/ PBU / DS 16 DATE: 12/08/10 OPERATOR REP: Jerry Murphy AOGCC REP: N /A �`� Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16 -14B I Type In'. I G TVD 1 8,637' Tubinq 2950 2950 1 2950 2950 Interval O P.T.D. 2060030 1 Type test I P Test psi 2159.25 Casing 900 3750 3740 3740 P/F P Notes: Unwitnessed MITIA to evaluate IA repressurization. 0A1 80 90 90 90 Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well T pe In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. I Type test I Test psi Casin P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test I Test psi Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU 16 - 14 12 08.10.xls MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 03, 2010 To: Jim Regg ~ C I?I ~ (1 ° P.I. Supervisor ! ~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-] 4B ~oM~ Chuck Scheve PRUDHOE BAY UNIT 16-14B Petroleum Inspector Src: Inspector Reviewed By: P.1. Suprv 5~~ NON-CONFIDENTIAL Comm Well Name: pRUDHOE BAY UNIT 16-14B API Well Number: 50-029-20570-02-00 Inspector Name: Chuck Scheve Insp Num: mitCS100602071913 Permit Number: 206-003-0 Inspection Date: 6/1/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-iaB 'Type Inj. G TVD 8637 Iq 6o zsoo za6o za6o ~~- ~ P.T.Di zo6ooso " TypeTest SPT ,Test psi J 1 ~ ~ zls9 pA 60 ~0 70 o II Interval aYRTST ~ p~ P ~ Tubing ! zsoo zsoo zsoo zsoo NOtes: pretest pressures observed and found stable Thursday, June 03, 2010 Page 1 of 1 fr ~ ~. ~` ;~, - ~-~;, k „t ,..M- f -~... ;~~ ~ ~. i, ~ ,~. ,~., ~'~+ ~~,~ ,,~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Maunder, Thomas E From: Maunder, Thomas E (DOA) Sent: Wednesday, September 17, 20081:52 PM Ta: 'Preble, Gary B (SAIG)' Subject: P6U 16-148 (206-003) Gary, 1 am reviewing the perforate and stimulate 404 recently submitted. tt appears that you did not capture the CiBP set at 14625 an 8/22!08. Could you revise the pert sheet and email it in? I will make a hand entry on the 404 regarding the C1BP. Thanks in advance, Tom Maunder, PE AOGCC Maunder, Thomas E DOA From• Preble, Gary 8 (SA1C) [Gary-Preble@bp.com] Sent•• Wednesday, September 17, 2008 4:24 PM Ta• Maunder, Thomas E (DOA) Subject: Emaiting: 16-14B-PERF-ATTACH.pd# Attachments: 16-14&PERF-ATfACH.pdf ~~~y~ ~~~ ~; ~Q~~ <<... 16-14B-PERF-ATTA CH.pdf (34 KB)... Tom, It appears that the GIBP's are not getting entered into our database from the slope. I'1 look into it and get it repaired. Thanks for reading again. The message is ready to be sent with the following file or link attachments: 16-14B-PERF-ATTACH.pdf Note: To protect against computer viruses, a-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. « 16-14B-PERF-ATTACH.pdf» STATE OF ALASKA ~~~ AUG ~ ~ ~: ~G~ ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERA~~~ ~ Gas Cods. s.;ommissiorl 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate 0 ~e Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory j~ 206-0030 3. Address: P.O. Box 196612 Stratigraphic ~' $erVlCe $~ 6. API Number: Anchorage, AK 99519-6612 50-029-20570-02-00 7. KB Elevation (ft): 9. Well Name and Number: 67 KB - PBU 16-146 8. Property Designation: 10. Field/Pool(s): ADLO-028332 - PRUDHOE BAY Field/ PRUDHOE BAY Pool 11. Present Well Condition Summary: ~ Total De th measured 15307 feet Plu s measured e `~~ ~ ~ p 9 ( ) ~ C. ~ ~(p a-~ ~ ~~ true vertical 8990 feet Junk (measured) None ~ f ( '~~ `/ L 1 Effective Depth measured 15221 feet true vertical 8991 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94# H-40 SURFACE - 110 SURFACE - 110 1530 520 SURFACE 2675 13-3/8" 72# L-80 SURFACE - 2675 SURFACE - 2675 4930 2670 PRODUCTION 9772 9-5/8" 47# 12.6# L-80 SURFACE - 9772 SURFACE - 8723 6870 4760 LINER 5480 4-1/2" 12.6# L-80 9827 - 15037 8766 - 8993 8430 7500 LINER 1143 7" 26# L-80 8773 - 9916 7899 - 8835 7240 5410 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9805' 0 0 - Packers and SSSV (type and measured depth) 7" BKR PKR 8773' 4-1/2" BKR S-3 PKR 9665' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 358 1898 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-187 Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 8/28/2008 Form 10-40 ev`s~~0+~/6~ ~`-""~ -- - ~~~ ~ ~ ~~~~ Submit Original Only c~ i~~ 16-i 4B 206-0030 PFRf ATTO[`FIMFNT Sw Narrte ~-- i Operation Date ~ Perl Opera#iorl Code i Meas Depth Top : Meas D,. _e~th Base ~ Tvd Depth Top j Tvd Depth Base 18.148 16-14B ~ 5/19/06 ~ PER ___ ~ 8/22t08{BPS ______ ~ i _ 15,000. __~___-_,_.14,625 t i 5,100. - --J .__-~ 14,625. __.__._. ___ ' 8,993.13 8,992.02 8999.28; 8,999.28 16-14B __._._.____..._.._._ 16-148 __ _ i ~22Jt 8~APF __, _ ~__ _-___ ....__..__._.._________.~_, _ 8/23108(APF _ 14,230. 14,170. ~ 14,250. ; 14,190. / . ~ _ 9,007.01 ' 9,006.88 _ 9,00$.08 ~ 9,007.72 t6-14B_i_~ ___.__.._.._ 8/23/08 APF _ ~-~ Y-- ~+~ _ 14,19_8. -~ ~ _ ~_ 14,210. _~ _ ( 9,007.72 9,007.37 - 16-148 i 8/23/08 APF~__~ ~ _ ' ,____ 14,210. _. ' f~~_~ f4,230. . 9,007.01 ~.._ 9,007.371 ___. 16-148 8/24/08 APF t 14150 ' 14,170 . 9,008.0= ~ 9,008.44 ~ i _ __-___! 3 W__ _ - ----- - - I AB _ ABANDONED ~{ _ _._.__.____ - ~_ . _. PER ~ - PERF _ ~~ j_ -- APF..___.,._._.. BPP _ ADD PERF._._._..__...I.._____~._-____-- - BRIDGE PLUG PULLED _ _ _, ___- ___~_~_- ~_.__~ RP_F__ _ SL^- _~_____ REPERF SLOTTED LINER E BPS A BRIDGE PLUG SET ; SPR SAND PLUG REMOV D FCO .~.~-.._. rFILL CLEAN OUT ~-.~--~~~---~ ~; ~ SF S ~ ,_~, SAND PLUG SET ~~.~ ~.~_~ FEL ~~ _._._.. ... j JFILL T' --------_- ; SQf St~UEEZE FAILED ~- T MIR ' MIS ~ ~~~- MECHANICAL ISOLATED REMOVED M~CHANICAL ISOLATED~~ I f _~_~ _ ~ _ _ SL1Z_ _~ STC ~ y~ W~ SCtUEEZE __ ; _ STRADDLE PACK, CLOSED MLK _____ _~ __,__ MECHANICAL LEAK .`__..--.~__ ._._..._.._ -- ___ ~Y`_ _ _ STO ----.--- .- -.----.- STRADDLE PACK, OPEN ._~.~ OH j OPEN HOLE ' • 16-14B 206-0030 PERF ATTACHMENT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 16-14B 5/19/06 PER ____ 15,000. 15,100. 8,993.13 8,992.02 16-14B 8/22/08 APF 14,230. , 14,250. 9,007.01 9,006.65 B _ 8/23/08 APF 14,170. 14,190. 9,008.08 9,007.72 i6-14 8/23/08 APF 14,190. 14,210. 9,007.72 9,007.37 16-14B 8/23/08 APF _ 14,210. 14,230. 9,007.37 9,007.01 16-14B 8/24/08 APF 14,150. 14,170. 9,008.44 9,008.08 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STRADDLE PACK, OPEN OH OPEN HOLE ~~~ ~`~I" • c~~t • • • 16-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE SUMMARY 8/19/2008+.:CTU # 6 (CIBP/ Perf /Acid Stimulation) MIRU CTU..: **Job continued on WSR 08/20/2008 "*" 8/20/2008CTU # 6 Drift Tubing, Set CIBP. <interact publishing> Rig up. perform ;weekly BOP test. Makeup BHA #1, 3.70" dummy CIBP drift with 0.75" hole. €RIH to 5000' and circulate in 50/50 meth cap on top of well. RIH and taa at :10120' ctmd Jet down to 10151' ctmd slowly Decision made toJ'OOH and :pickup a iet nozzle. At surface, no obvious markings on toolstring. Makeup iBHA #2 with 3" JSN. RIH to 14.800' ctmd and iet out fill to surface. '*** Job continued on WSR 8/21/08 *** 8/21/2008 CTU # 6 FCO, Drift Tubing, Set CIBP. ***Job continued from WSR ?'?8/20/08*** <interact publishing> Continue FCO from 14,800' chasing fill to ''surface. MU Drift BHA and RIH. Tagged in same spots as first run. Slowed ':down through high DLS areas and passed through clean, cuo ~ IH to ''' 14800' ctmd. POOH loading well with 30 bbls of 50/50 meth to keep well loaded. MU BHA #3, Weatherford 4-1/2" CIBP. RIH and encounter helical 'lockup at 13900'. Pickup 400' and attempt to run in hole deeper ;unsuccessfully. Max depth reached with CIBP was 14000'. POOH leaving well shut-in. MU BHA #4 with 3" JSN and RIH to turn wellover to 1 % KCI :with 0.6% SafeLube. SafeLube did not help, without SafeLube in the well we ;got to 13,514'. After several attempts to get deeper swapped well over to 1 KCL W/Safelube and still couldn't get any deeper. POOH to 5000' and swap :well to 50/50 and POOH for CIBP. """` Job continued on WSR 8/22/08 *"'` 8/22/2008 CTU # 6 Set CIBP & Perforate ***Job continued from WSR 8/21/08*** <interact publishing> MU CIBP BHA and RIH. Made it past deepest depth (13,577') on last run with 10.5k RIH WT. Set CIBP at 14625' ctmd. PT'd CIBP to 3000 psi losing 140 psi total over 15 minutes. i ling down backside with 50/50. Makeup 1st 2-7/8" Perf gun using 2 x 10' guns loaded with PJ2906 charge), 6 SPF and RIH to . Fire guns using 34 bbls of 1%KCL. POOH and verified guns fired. LD spent guns and MU gun run #2 perforating 14250' to 14210' and RIH *"`* Job continued on WSR 08/23/2008'`'`'` ~_ ., _ _. 8/23/2008. CTU # 6 Perforate "**Job continued from WSR 8/22/08*** <interact publishing> MU gun run #2 (2-10' guns loaded with PJ2906 Omega charges) and RIH perforating from 14,230' to 14,210' ctmd. Good indication ', guns fired, POOH from 14230'. All shots fired. MU 20' gun run #3 (2-10' guns loaded with PJ2906 Omega charges) and RIH. Perforate from 14,210' to 14190' ctmd using 34 bbls of 1 %KCI. At surface, all shots ire gun #4 2-10 guns loaded with PJ2906 Omega charges) and RIH. Perforate from 14,190'to 14170' ctmd using 34 bbls of 1%KCI. Guns fired POO 'OOH we have holes LD spent guns. PT CTC failed, call out for another one. Replaced CTC, MU Guns and RIH ', *** Job continued on WSR 8/24/08 *** 8/24/2008 CTU # 6 Perforate ***Job continued from WSR 8/23/08*** <interact publishing> Continue RIH W/Gun Run #5 (2-10' guns loaded with PJ2906 Omega charges) to perforate from 14,150' to 14,170'. Pump 34 bbls of 1 KCL and fire guns. At surface, all shots fired. MU 2.5" JSN and RIH. Pump'; ''50 bbls of 3% ammonimum chloride, 30 bbls of 12% HCI, 30 bbls of 9:1 mud: ''acid and overdisplace into formation with 120 bbls of amonium chloride. ';Initial injection with 3% ammonium chloride was 0.4 bpm at 2000 psi. After '! 10 bbls of HCI exited nozzle, reciprocating from 14140' ctmd to 14260' ctmd 'with 2 passes, infectivity increased to <1 bpm at 400 psi WHP. After mud acid reached nozzle, injectivity increased to 1.9 bpm at 360 psi. Perform ;injectivity test, at 215 bbls away we were at 3 bpm @ 2068psi`for an ',:injection rate of 4320 bbls/day. Swap to 50/50 Meth to freeze protect tubing `and CT. Pumped 40 bbls of 50/50 down tubing (FP to 2628'), FP CT and RD Gunit. Unit released at 23:59 and on the road to END1-21 ', Injectivity test 3.0 bbls/min 1220psi 53 bbls away 4.0 bbls/min 1590psi 94 bbls away 3.2 bbls/min 2015psi 165 bbls away ''3.0 bbls/min 2068psi 215 bbls away 1%KCL at perfs from surface """'` Job Complete*** FLUIDS PUMPED BBLS 46 1 %KCI W/0.6% SAFELUBE 215 1 %KCI 174 3% AMMONIUM CHLORIDE WITH 0.2% F103 10 3% AMMONIUM CHLORIDE WITH 0.2% F103 AND 5% MUTUAL SOLVENT 30 12% HCI 30 9:1 MUD ACID 78 50/50 METH 583 Totai ~ ~ J,~ DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060030 Well Name/No. PRUDHOE BAY UNIT 16-146 Operator BP EXPLORATION (ALASKA) INC MD 15307 TVD 8990 Completion Date 5/17/2006 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION API No. 50-029-20570-02-00 Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / RES / ABI, CGT / GR / CCL (data taken from Logs Portion of Master Well Data Maint 1 G C Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / I e meairrmt rvumoer Name Scale Media No Start Stop CH Received Comments D~ D Asc Dj~ectional Survey '~ 9892 15307 Open 4/17/2006 IED C Las 15434 See Notes 9811 15307 Open 9/17/2007 Field Data LAS, GR, ROP w/EMF Graphics pt LIS Verification 9822 15317 Open 3/7/2008 LIS Veri, GR, RPS, FET, RPM, RPD, RPX, ROP / iED C Lis 16002vlnduction/Resistivity 9822 15317 Open 3/7/2008 LIS Veri, GR, RPS, FET, RPM, RPD, RPX, ROP ,Log Induction/Resistivity 25 Col 9916 15307 Open 3/24/2008 MD ROP, DGR, EWR 11- ~ Feb-2006 g Induction/Resistivity 25 Col 8934 8989 Open 3/24/2008 TVD DGR, EWR 11-Feb- 2006 ~ C 16053~duction/Resistivity 0 0 Open 3/24/2008 TVD and MD logs in EMF, ~ CGm, and PDF graphics Well Cores/Samples Information: Name ADDITIONAL INFORM~ON Well Cored? Y / Chips Received? .~Ff'I~ Analysis `f`7'I~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? V N Formation Tops ~/ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060030 Well Name/No. PRUDHOE BAY UNIT 16-14B Operator BP EXPLORATION (ALASKA) INC MD 15307 ND 8990 Completion Date 5/17/2006 Completion Status WAGIN Current Status WAGIN Compliance Reviewed By: Date: API No. 50-029-20570-02-00 UIC Y 1~_J __ i ~) ~ E r.. ) ~ ~ e 4 t ~_ i,,\ ~ q ~ r ~ s \ ALASSA OIL AHD GAS COH5ERQATIOI~T C01-IIrII55IO1K Patti Phillips P.E. BP Exploration Alaska. lnc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 16-14B Sundry Number: 308-187 Dear Ms. Phillips: 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, Daniel T. Seamount, Jr. o~~ Chair DATED this ~ 6day of May, 2008 Encl. ~ STATE OF ALASKA MAY 2 2 ~ ,~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION , APPLICATION FOR SUNDRY APPROVA~~aska Oil ~ Gas Cons. Camrn~sion 20 AAC 25.280 A 1. Type of Request: Abandon Suspend Operational shuldown Perforate ~ ~ Waiver ^ Othe Alter casing^ Repair well ^ Plug Perforations^ Stimulate Q- Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 206-0030' 3. Address: P.O. Box 196612 Stratigraphic^ Service 0~ 6. API Number: Anchorage, AK 99519-6612 50-029-20570-02-00 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 16-14B Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028332 ~ 67 KB - PRUDHOE BAY Field / PRUDHOE BAY 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): 15307 - 8990 - 15221 - 8991 _ NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 94# H-40 URFACE 110' SURFACE 110' 1530 520 Surface 2675' 13-3/8" 72# L-80 URFACE 2675' SURFACE 2675' 4930 2670 Production 9772' 9-5/8" 47# N-80 URFACE 9772' SURFACE 8723' 6870 4760 Liner 5480' 4-1/2" 12.6# L-80 9827' 15037' 8766' 8993' 8430 7500 Liner 1143' 7" 26# L-80 8773 9916' 7899' 8835' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD {ft): 15000 - 15100 8993.13 - 8992.02 4-1/2" 12.6# L-80 SURFACE - 9805' Packers and SSSV Type: 9-5/8"x7"bkr pkr Packers and SSSV MD (ft): 8773' 7"x4-1 /2" bkr S-3 PKR 9665' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development [] Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/5/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Patti Phillips Printed Name Patti Phillips Title P.E. Signature ~- Phone 564-4578 Date 5/22/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Q Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance [] Other: ~SQV ~St ~~t~1 Y'~V ~~©` ~S~ Subsequent Form Required: ~~ ! APPROVED BY ~ ~ Approved by: COMMISSIONER THE COMMIS ON ,Da `/ Form 10-403 Revised 06/2006 ~ ~ ~ ~ ~ n ~ ^ ~ ~ ~~~ ~~ _~ ~ t ~ `~~ it i ate To: Jerry Bixby /Clark Olsen Well Operations Supervisors From: Patti Phillips DS 16 Production Engineer Subject: DS 16-146i CIBP, Perf and Acid Stimulation PBD16WL14-C Capacity Sustainment Please perform the following steps: Date: May 20, 2008 Est. Cost: $240M IOR: 800 1. S Pull MCX SSSV. Drift and tag with dummy gun. 2. C Set CIBP at 14,625 'MD. AdPerf 100'. Mud. acid. Test separator not required. Injectivity post acid stim. Well Status: MIST WAG injector, on PWI Last PWI Injection: 846 bwpd C~ 1778 psi on 05/12/2008 Last MI Injection: 2876 mscfd C«~3165 psi on 7/9/2007 Max Deviation: 93° @ 13,355'MD Proposed Plug Deviation: 91 ° at 14625' Proposed Adperf Deviation: 95° Min. ID: 3.725" @ 9793' MD, 4-1/2" HES XN Nipple Last TD tag: 05/17/2006, 15,250' during CT FCO and mill Last Downhole Ops: 05/17/2006 - 05/19/2006, 15,000' -15100' Initial Perfs Latest H2S value: No Data - DS 16 is an H2S Site Tie-in/ PDC Log: 02/25/2006 MWD/GR WELL HISTORY Well 16-14Bi is a horizontal MI injector drilled and completed in Zone 2 in March 2006. It has 4-1/2" L-80 tubing with perforations from 15,000' -15,100'. The plan for this well is to have six sets of perfed injection intervals, each set separated by a CIBP. MI will be injected into each set with each "plug-perf-MI injection" cycle lasting 1-2 years. Initially, 100' of perforations were shot from 15,000' - 15,100' on 05/19/06 and four MI slugs have been injected into those perforations from May, 2006 to July, 2007, since the sidetrack was completed. The well was put on PWI on 01/30/2008, but has only injected a maximum of 5200 bwpd, dropping oft to 615 bwpd. Injectivity in other ,MIST horizontal wells has been improved with acid stimulation. OBJECTIVE The purpose of this procedure is to set a CIBP and add a second set of injection perforations to start the next MI bulb for well 16-14Bi. An acid stimulation procedure is included to improve Injectivity. Please contact Patti Phillips at 564-4578 (office), 346-1755 (home), 240-3742 (cell) or Jennifer Julian at 564- 5663 (office), 274-0929 (home) or 240-8037 (cell) with any questions or comments. Note: Jennifer Julian's cell phone may not work from the coil tubing unit so you may have to use an alternate line to call her. cc: 16-14B WeII File 16-14Bi Recompletion Program Note: Please call Jennifer Julian at 564-5663 (office), 274-0929 (home) or 240-8037 (cell) to use this well as a test for Safelube prior to rigging up. JOB PLANNING DETAILS: CIBP: Set at 14625' MD Perfs : 14150' - 14250' MD (to be added) 15,000' - 15,100' (to be isolated by plug) Proposed Plug Deviation: 90° at 14,625' Proposed Perf Deviation: 92° at top of perf interval 14,150' TD Tag History: 05/17/2006, 15,250' during CT FCO and mill Displacement bbls: 215 bbls (4-1/2" monobore to new perfs - 14150') Static Pressure: 3348 psi @ -8800' SS from 16-14Ai wellbore 02/14/2002 Recent Infectivity: 23,500 mcfgd in July, 2007 NOTE: A milling job (post side track) was required prior to shooting first set of perfs. See attached WSR. It is not expected that a FCO will be required on this job. Slickline Prep Work: 1. Pull MCX SSSV at 2193'. 2. Drift and tag as deep as possible with dummy gun CT Operations: Note: *Memory log is not required for CIBP setting or perf job due to large window '`*25' 2.875" guns were used for the previous perforations (see attached WSR). Caution: CTU #5 reached TD on 5/17/2006 (see WSR for details), however CoiICADE is predicting lock-up to take place prior to reaching TD. Set CIBP and Perforate 1. RU CT. RU to be able to pump down tubing for injectivity test post acid stim. 2. Make CTU drift run with nozzle to 14800' CTMD prior to running the CIBP. 3. RIH with 4-112" CIBP and set at 14,625' CTMD while POOH. Pressure test the CIBP to 3000 psi. 4. RIH and perforate with 2-7/8" PowerJet Omegas, 6 SPF, from 14,150' - 14,250' CTMD. Memory depth control log not required due to large window. Acid Stimulation -REVISION #1 1. RIH CT with a 2" - 2 1/4" jet swirl nozzle (Note: Min ID = 3.725" @ 9793'). Pump the following fluid schedule while reciprocating slowly across all perfs: 50 bbls 3% NH4CI + F103 10 bbls 3% NH4CI + F103 + U067 30 bbls 12% HCI 30 bbls 9:1 Mud Acid 120 bbls 3% NH4CI + F103 If needed to establish injection, go to 3000 psi WHP, but drop immediately to 2000 psi WHP as to not frac the well during the acid wash. When acid is on the perfs, max WHP should be 2000 psi. Before POOH, complete the overflush to ensure acid has been pushed away. 2. Do an injectivity test post acid stim down the backside. Establish. a stabilized rate and. pressure to make certain of positive injection. 3. Turn well over to the DSO to put on produced water injection. S,3ilurniDerper~ifFi~fd ;er..f~c i?+'i~r~ ~ irm~a. ArLlrnaga. ~R, pient: LAP bc~Ir;rr~tior~ Al~ka.'h~. 1:f~irneer : i+~ ~iti Phillip: ~~r~i~ ~"tstii~; Pru~hn~ Pav Reid Systems: ~l~~~~~ 1. t'Aar-~B Well f+lArne; 7b 1 ~Bi Field: PrrrJhne Bar' Fomtration: 'r:. Y 30 bhts ~1 Regnlar Mnd Acid ~' 34 bbls 1?°~ HCl 0.5 °~. ~;~PI Inhibitor .~itl ~?.S "b "~B 'Inhibitor :~itl 0..5 ~ ~~ti1 lnhibitm 0 5 Qo b,'>~t 'Inhibitor 0 ~ po F l03 5uri~nt E`EFLCr 0 ~ ~ F~o3 5uriactarn E`EFLCr Z~).0 ~+t loss 'iron `:tabil¢er X0.0 ~t lafSEf 'hnn 5tabiliter 0.5 "ro S1+315-A tlorrEmulaifivinp~~n o.5 °o w'~a0 ldcm-EmulsiivinoAgern 0.5 56 1~",rte 5lucic~e and Emulsion FY~aen~r 9.5 ?b w'i 51ud~ and Emulsion Fr~uenter ,~ 170 bb)s 3°'~ NNiCI t 1`103 71 14 bbls 3% NNaCI !r 1`103 + U067 02 '~, Flo3 5urfia~nt E~FLC~ 9? ~ FtIO+s Suriactarn E~FLl7 :50.0 ~ ,IAS Ammonium ~Mnri~ ~5?_v~ ppt Jf'R~ Ammonium chlnriiie 5.0 ae R.r~ArT lvlurual5nfvem Nnt~:EIIiST=1BD~F,°.v~llboreeontein:'i-i~~vibulacs. hitifiitm~anilnr~rr~mul„*itiersYOt~d~:"r~nedtrccordm~ly Chernicai Regnirements: To><al Liquid load. 2ri0 bbls '13 gtil A'~Ot 'Inhibitrn,Ail 13 yratil A~51 'Inhbitnr ~1 Viral F103 5mfacKarn.1"EfLL~ fl8g1 lb J_"1LS Ammoniumshloii~e 31 lb LoStt 'hon `tYahIIIIP.I ~1 r,~l Lb67 1Jluttral Solvent 1~ ~I 4"rb5~i rJon-Emulsifuinn Agent 73 ~I w'.'+A~ 5ludcte anill Emul~inrFrr ' '16-14B Wellbore Schiiatic ~- Mi~in~an ®= 3.725 ~ 9793 ~I-1 ~'2- HES XN N9'P'LE 16-14B ~"'~~~ ^iu~~©ur ~wnmow :;~su~ ss~s-- ss2-~ F~E7R47i]nr 9UIrINRK ~~MWDGR AfiQEATiETA~:91 g *~® AIRL~~.l~' Yl~f ~~: +6= 6 ~YT'!b:~~1'~ AW6+~: ~9ii~~"• 7T.SIy, Rt 5E '~ ~C ~L i TJT'r' ~_ WSR from first perf iot~ne with Coil WELL SERVICE REPORT WELL 16-14B JOB SCOPE SIDETRACK UNIT CTU #5 DATE 5/19/2006 DAILY WORK FILL CLEAN OUT; PERFORATING DAY SUPV SCHULTZ COST CODE PLUS PBD4P2454-D KEY PERSON DS-YORK NIGHT SUPV SCARPELLA MIN ID 3.725 " DEPTH 9793 FT TTL SIZE 4.5 " DAILY SUMMARY ""Continue WSR from 5/18/06'*' Fire Guns C~ 15,025' top shot. POOH. MU guns for run #4. RIH. Shoot 15,000' to 15,025'. POOH. Freeze protect well with 60/40 meth. RDMO. Turn well over to DSO to pop. '*`Job Com lete""" LOG ENTRIES Init Tb , IA, OA 0 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 15025 4 Continue WSR from 5/18/06 00:04 15025 4 1000 .8 26 Reduce um rate 00:16 15025 0 2980 .8 32.7 Ball on seat ood indication uns fired C«3 2980 si, POOH 00:17 14950 0 312 37 Cap well with 2 bbls 60/40 Meth down backside of CT 00:18 14400 0 228 39 Freeze rotect surface lines 02:15 0 CT ~ surface, PJSM on handlin of s ent uns 02:30 0 Brake down uns 02:53 0 Ball recovered 02:55 0 0 Fill CT w. 60/40 Meth to PT MHA 03:08 0 30 PT to 3500 si 03:15 0 MU firin head and 25' 2.875" un 03:37 0 32 PT surface a ui ment 200/2000 si 03:50 0 0 34 RIH w. uns 04:39 5000 0 28 Wt ck 9k riw 6.5 k 05:31 10000 0 21 Wt ck 18.8k riw 11.5k 06:23 14983 0 21 Sto ~ fla and correct de th to to shot = 14913.6' 06:30 15030 0 13 Sto CT and ull u to firin de th 06:32 15000 0 9 CT @firin de th to shot 06:39 15000 1 2500 1.6 0 Launch 0.5" aluminum ball into CT 06:55 15000 5 844 .8 26 Reduce um rate 07:05 15000 1 2800 .8 31.2 Ball on seat ood indication uns fired, POOH 07:06 14900 0 264 33 Freeze rotect surface lines w. 60/40 Meth 07:08 14700 0 0 0 33 Swa to backside of CT freeze rotectin wellbore 08:34 4126 0 0 1 70 Done freeze rotectin the well. Con#inue to POOH. 09:14 0 Ta u .Close swab. Bleed off. Po off. 09:23 0 Confirmed shots fired. Break down uns. 09:45 0 Chan a ackoffs 10:00 0 Start RD 12:00 0 Finish RDMO. Final T b , IA, OA 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL DOW ELL $7,433 $46,228 SCHLUMBERGER $32,654 $77,602 V ECO $690 $17,100 PDS $0 $9,140 PAD THREE $0 $2,371 COBURN MACHINE $0 $289 MI FLUIDS $0 $3,395 WEATHERFORD $0 $16,911 WAREHOUSE $0 $10,673 HOT WATER PLANT $0 $2,275 ORBIS $0 $1,900 GBR $0 $3,360 • i I TOTAL FIELD ESTIMATE: I $40,7771 $191,244 FLUID SUMMARY 141 bbls 60/40 Meth PERFORATIONS TOP DEPTH BOTTOM DEPTH GUN DIAMETER ORIENTATION SHOT DENSITY SHOT PHASE 15,000 15,100 2.875 N 6.00 60 WELL SERVICE REPORT WELL 16-14B JOB SCOPE SIDETRACK UNIT CTU #5 DATE 5/18/2006 DAILY WORK FILL CLEAN OUT; PERFORATING DAY SUPV SCHULTZ COST CODE PLUS PBD4P2454-D KEY PERSON DS-YORK NIGHT SUPV SCARPELLA MIN ID 3.725 " DEPTH 9793 FT TTL SIZE 4.5 " DAILY SUMMARY ""Continue from 5/17/06 WSR"" Continue in hole w/gun run #2 of 4. Stop at CT flag. Correct to top shot. Continue to firing depth 15,050'-15,074'. Drop 1/2" ball to perforate. POOH. MU memory logging tools. RIH. Log from 15,200' to 13,800'. Paint flag at 14,950'. POOH. No data recorded. Re-run memory logs across same interval. Paint flag at 14,958.1'. POOH. Good data recovered -42' correction. RIH w. un #3 of 4 Perf 15025'-15049'. POOH. LOG ENTRIES Init T b , IA, OA 0 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 8000 0 12 Continue WSR from 5/17/06 00:33 11600 WHP building do to CT displacement crack choke taking returns to surface 00:37 12000 0 8 Wt ck 21.5k, 12k riw 01:20 14980 Sto C~ CT fla and correct de th to to shot of un = 14903.46' 01:23 14903 Continue to firin de th, riw 12.6k 01:29 15570 Sto and PUH 23k, to firin de th of 15050' "to shot" 01:32 15050 2000 1.6 0 Dro 0.5" ball and chase w. 60/40 meth down coil 01:56 15050 880 .8 Reduce um rate 02:05 15050 10 2612 .8 32.7 Ball on seat, ood indication uns fired C~ 2612 si, POOH 02:10 14500 37 Freeze rotect surface lines, dro a few down backside of CT 03:52 200 PJSM, handlin of TCP 04:02 0 CT C~ surface 04:10 0 All shots fired, brake down 25' uns 04:25 0 Ball recovered, cut MHA off and 50' of coil 04:37 0 MU MHA 04:47 0 Pull test MHA to 20k 04:58 0 33 Fill coil & PT MHA to 3500 si 05:25 0 MU PDS memo to in tools 05:45 0 PT surface a ui ment 300 si/4000 si 06:03 0 O en swa , RIH w/ to in tools 08:59 15200 7 22 184 Sto at 15,200.3' for 5 min. 09:06 15200 7 22 184 PUH at 40 f m. 09:12 14950 0 0 184 Paint fla at 14950.1'. PUH at 40 f m. 09:55 13800 0 0 184 Sto for 5 min. POOH. 11:50 0 Tools at surface. Close swab. Bleed off. Po off. 12:01 0 PJSM. Break down to in tools. 12:20 0 0/33 PT connector to 2500 si. 12:34 0 Bad to data. Pre to rerun to s. 13:03 0 MU to in tools. 13:33 0 35 PT wellhead stack to 350 si / 4000 si. 13:44 0 0 23 0 0/ RIH w/ to in tools 16:06 15200 0 20 0 0 Sto at 15,200.1' for 5 min. 16:12 15200 0 19 0 0 PUH at 40 f m. 16:18 14958 0 0 0 0 Paint fla at 14958.1'. Sto for 5 min. PUH at 40 f m. 16:53 13800 0 0 0 0 Stop for 5 min. POOH. 18:32 0 Tools at surface. Close swab. Bleed off. Po off. 19:10 0 Data ood from memo tools -42' correction 19:28 0 Fill CT w. 60/40 Meth 19:45 0 33 PT MHA to 3500 si 19:58 0 MU firin head and 25' 2.875" uns 20:35 0 35 PT surface a ui ment 200/2000 si 20:43 0 0 38 RIH w. uns 21:30 4000 0 27 Wt ck 7k, riw 5.5k 22:10 8000 0 21 Wt ck 13k, riw 8.5k 23:00 12000 0 18 Wt ck 19k, riw 11.5k 23:28 14913 0 Sto CT at fla and correct de th to to shot = 14913.6' 23:39 15050 0 8 Sto CT and PU to firin de th 23:45 15025 0 2230 1.6 0 Sto CTand launch 0.5" aluminum ball w. 60/40 meth 23:59 15025 4 2230 1.6 Continue WSR on 5/19/06 Final Tb , IA, OA JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL DOW ELL $14,866 $38,795 PAD THREE $785 $2,371 PDS $4,570 $9,140 SCH LU MB E RG E R $32,654 $44,948 VECO $2,033 $16,410 WAREHOUSE $7,350 $10,673 COBURN MACHINE $0 $289 MI FLUIDS $0 $3,395 W EATHERFORD $0 $i 6,911 HOT WATER PLANT $0 $2,275 ORRIS $0 $1,900 GBR $0 $3,360 TOTAL FIELD ESTIMATE: $62,258 $150,467 FLUID SUMMARY 35 bbls XS1 %KCL 37 bbls of 60/40 Meth 184 bbls of Safe Lube. PERFORATIONS TOP DEPTH BOTTOM DEPTH .GUN DIAMETER ORIENTATION SHOT DENSITY SHOT PHASE 15, 000 15,100 2.875 N 6.00 60 WELL SERVICE REPORT WELL 16-14B JOB SCOPE SIDETRACK UNIT CTU #5 DATE 5/17/2006 DAILY WORK FILL CLEAN OUT DAY SUPV SCHULTZ COST CODE PLUS PBD4P2454-D KEY PERSON DS-YORK NIGHT SUPV SCARPELLA MIN ID 3.725 " DEPTH 9793 FT TTL SIZE 4.5 " DAILY SUMMARY CTU #5, FCO; Cont' from WSR 5/16/06 ... RIH with WFD 2 7/8" motor and 3.70" concave 5-blade junk mill. Sat down at 9930' ctmd. Milled a couple of hard feet at 9930' ctmd then milled easier. RIH milling to 14900' ctmd, seeing lock up. PUH, vary rate and work mill down to TD C~ 15250' ctmd. Continue circulating while POOH with mill (backreaming). RIH with PDS memory GR/CCL. RIH w. CBF firing head and 25' of 2.875" HSD TCP gun. Perf from 15075'- 15100' RIH w. 2nd of 4 perf runs with same confi uration. ""* Job still in ro ress, continue WSR on 5/18/06"'** LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:00 Cont' from WSR 5/16/06 ... RIH with motor and 3.70" concave 5-blade 'unk mill 00:33 Wei ht check 21.6 k# 00:40 Down on um .Continue RIH ford to . 00:42 Sat down at 9931' ctmd. PUH. PU (~ 9927 ctmd. Wei ht 20.2 k# .00:46 Online down coil w/ XS KCL. Frees in at 2.6 b m is 1900 si CTP. RIH millin . D0:55 Millin on 'unk. Easier oin after a cou le of feet. 01:02 PUH. Weight 20 k# • 01:10 ROP=5f m 01:23 PUH. Wei ht 20.2 k# 01:35 ROP = 12 f m. Wei ht check 20 k# 01:43 ROP = 15 f m. Wei ht check 20 k# 01:49 ROP = 25 f m. Wei ht check 20 k# 01:53 ROP = 30 f m. Wei ht check 20 k# 01:55 Increase ROP to 50 f m. 02:05 Wei ht check 21 k# 02:14 Increase ROP to 70 f m. 02:18 Swa to FloPro 02:22 10 bbls FloPro um ed. Swa back to XS KCL. 02:23 Wei ht check 21.5 k# 02:26 Increase ROP to 90 f m. 02:31 FloPro at bit. 02:36 FloPro out bit. Wei ht check 21.5 k# 02:41 Swa to FloPro 02:45 10 bbls FloPro um ed. Swa back to XS KCL. 02:46 Wei ht check 22.4 k# 02:49 Reduce rate. 02:57 Settin wei ht down. FloPro at bit. PUH. Wei ht 22 k#. 02:58 Cannot et dee er. No motor work. PUH. Wei ht 22.5 k# 03:01 FloPro out bit. Increase rate. RBIH millin . 03:03 Cannot et back down hole. PUH. 03:05 Cannot et down. Pi a in locku . 03:09 PUH to 14500' ctmd. RBIH. 03:24 Makin headwa . 03:32 FloPro showin in returns. 03:35 Reduce rate. 03:36 Ta ed TD at 15257 ctmd. PUH. PU ~ 15250' ctmd. Wei ht 23.5 k#. 03:38 Increase rate. RBIH to circ. bottom. 03:40 Pause near TD. 3 wra s of i e left on reel. POOH. 03:43 Reduce rate. Conservin fluids because of half loads across Sa brid e. 04:36 Out of water, Swa to meth down coil. 04:44 15 bbls Meth um ed. Swa back to XS KCL 05:48 Down on um . 05:49 Pum meth down the backside to ca well. 05:55 Flush surface lines. 05:57 Down on um . 06:07 At surface. Close swab. Crew chan a PJSM. 06:16 Off well. Break down millin BHA. 07:00 PJSM, MU PDS to in tools in 2.2" OD carrier 07:34 In'ector on well, PT low 300 si 5 min, hi h 4000 si 5 min 07:53 O en swab and RIH 08:55 Wt ck 13.2k, riw 8.6k 09:31 Start um in Safe Lube 10:01 Wt ck 23.2k, riw 13.2k 10:02 Safe Lube C~ nozzle 10:28 Wt ck 23.8k, riw 13k 10:47 Sto CT and wait 5 min 10:53 Sto um sand start to in u ass C~ 40 f m 11:01 Sto to in ,wait 5 min, aint ellow and white fla on CT 11:06 Continue to in u @ 40 f m 14:07 Tools at surface. Pum ed 16 bbls of 60/40 meth down backside while POOH. Close swab. Bleed off. 14:08 Safet meetin . 14:15 Break down tools. 14:25 PT connector to 3500 si. with 60/40 meth. 14:40 MU erf uns 15:05 PT wellhead stack to 300 si / 2000 si. 15:16 RIH takin returns to ti er tank. 16:08 Wt ck = 8.6 klbs 17:34 Wt ck = 22 klbs. 18:15 Correct to to shot at fla = 14903.5'. 18:22 Sto .PUH to 15,075'. 18:24 Drop 1/2" aluminum ball to shoot. Displace with 60/40 meth. • • 18:53 Guns fired. POOH 20:51 PJSM on s ent TCP uns 21:13 CT C~ surface 21:37 All shots fired on un, break down 25' uns, recovered ball 21:50 PT MHA to 3500 si 22:05 Start MU of CBF firin head, 25' 2.875" HSD uns 22:33 PTsurface a ui ment to 300 si / 2000 si 22:43 O en swab and RIH 23:41 Wt ck 12.8k, riw 9.2k 23:59 Continue WSR on 5/18/06 Fi nal Tb , IA, OA -> JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL DOW ELL $14,944 $23,929 HOT WATER PLANT $1,022 $2,275 MI FLUIDS $1,590 $3,395 ORBIS $950 $1,900 PAD THREE $1,586 $1,586 PDS $4,570 $4,570 VECO $7,406 $14,377 WAREHOUSE $2,184 $3,323 COBURN MACHINE $0 $289 SCHLUMBERGER $0 $12,294 W EATHERFORD $0 $16,911 GBR $0 $3,360 TOTAL FIELD ESTIMATE: $34,252 $88,209 FLUID SUMMARY 627 bbls -XSL 1 %KCL 20 bbls -Flo Pro 86 bbls - 60/40 Methanol 100 bbls -XSL 1 %KCL 0.6 % SafeLube WELL SERVICE REPORT WELL 16-14B JOB SCOPE SIDETRACK UNIT CTU #5 DATE 5/17/2006 DAILY WORK FILL CLEAN OUT DAY SUPV SCHULTZ COST CODE PLUS PBD4P2454-D KEY PERSON DS-YORK NIGHT SUPV SCARPELLA MIN ID 3.725 " DEPTH 9793 FT TTL SIZE 4.5 " DAILY SUMMARY CTU #5, FCO; Cont' from WSR 5/16/06 ... RIH with WFD 2 7/8" motor and 3.70" concave 5-blade junk mill. Sat down at 9930' ctmd. Milled a couple of hard feet at 9930' ctmd then milled easier. RIH mil8ng to 14900' ctmd, seeing lock tap. PUN, .vary rate and work milt down to TD ~ 15250' ctmd. Continue circulating while POOH with mill (backreaming). RIH with PDS memory GR/CCL. RIH w. CBF firing head and 25' of 2.875" HSD TCP gun. Perf from 15075'- 15100' RIH w. 2nd of 4 pert runs with same confi uration. "" Job still in ro ress, continue WSR on 5/18/06"' LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:00 Cont' from WSR 5/16/06 ... RIH with motor and 3.70" concave 5-blade 'unk mill. 00:33 Wei ht check 21.6 k# 00:40 Down on um .Continue RIH ford to . 00:42 Sat down at 9931' ctmd. PUH. PU (~ 9927' ctmd. Wei ht 20.2 k# 00:46 Online down coil w/ XS KCL. Frees in at 2.6 b m is 1900 si CTP. RIH millin . 00:55 Millin on 'unk. Easier oin after a cou le of feet. 01:02 PUH. Wei ht 20 k# 01:10 ROP=Sf m 01:23 PUH. Wei ht 20.2 k# 01:35 ROP = 12 f m. Wei ht check 20 k# 01:43 ROP = 15 f m. Wei ht check 20 k# 01:49 ROP = 25 f m. Wei ht check 20 k# 01:53 ROP = 30 fpm. Weight check 20 k# ', • 01:55 Increase ROP to 50 f m. 02:05 Wei ht check 21 k# 02:14 Increase ROP to 70 f m. 02:18 Swa to FloPro 02:22 10 bbls FloPro um ed. Swa back to XS KCL. 02:23 Wei ht check 21.5 k# 02:26 Increase ROP to 90 f m. 02:31 FloPro at bit. 02:36 FloPro out bit. Wei ht check 21.5 k# 02:41 Swa to FloPro 02:45 10 bbls FloPro um ed. Swa back to XS KCL. 02:46 Wei ht check 22.4 k# 02:49 Reduce rate. 02:57 Settin wei ht down. FloPro at bit. PUH. Wei ht22 k#. 02:58 Cannot et dee er. No motor work. PUH. Wei ht 22.5 k# 03:01 FloPro out bit. Increase rate. RBIH millin . 03:03 Cannot et back down hole. PUH. 03:05 Cannot et down. Pi a in locku . 03:09 PUH to 14500' ctmd. RBIH. 03:24 Makin headwa . 03:32 FloPro showin in returns. 03:35 Reduce rate. 03:36 Ta ed TD at 15257 ctmd. PUH. PU ~ 15250' ctmd. Wei ht 23.5 k#. 03:38 Increase rate. RBIH to circ. bottom. 03:40 Pause near TD. 3 wra s of i e left on reel. POOH. 03:43 Reduce rate. Conservin fluids because of half loads across Sa brid e. 04:36 Out of water, Swa to meth down coil. 04:44 15 bbls Meth um ed. Swa back to XS KCL. 05:48 Down on um . 05:49 Pum meth down the backside to ca well. 05:55 Flush surface lines. 05:57 Down on um . 06:07 At surface. Close swab. Crew Chan a PJSM. 06:16 Off well. Break down millin BHA. 07:00 PJSM, MU PDS to in tools in 2.2" OD carrier 07:34 In'ector on well, PT low 300 si 5 min, hi h 4000 si 5 min 07:53 O en swab and RIH 08:55 Wt ck 13.2k, riw 8.6k 09:31 Start um in Safe Lube 10:01 Wt ck 23.2k, riw 13.2k 10:02 Safe Lube C~ nozzle 10:28 Wt ck 23.8k, riw 13k 10:47 Sto CT and wait 5 min 10:53 Sto um sand start to in u ass @ 40 f m 11:01 Sto to in ,wait 5 min, aint ellow and white fla on CT 11:06 Continue to in u C~ 40 f m 14:07 Tools at surface. Pum ed 16 bbls of 60/40 meth down backside while POOH. Close swab. Bleed off. 14:08 Safet meetin . 14:15 Break down tools. 14:25 PT connector to 3500 si. with 60/40 meth. 14:40 MU erf uns 15:05 PT wellhead stack to 300 si / 2000 si. 15:16 RIH takin returns to ti er tank. 16:08 Wt ck = 8.6 klbs 17:34 Wt ck = 22 klbs. 18:15 Correct to to shot at fla = 14903.5'. 18:22 Sto .PUH to 15,075'. 18:24 Dro 1/2" aluminum ball to shoot. Dis lace with 60/40 meth. 18:53 Guns fired. POOH 20:51 PJSM on s ent TCP uns 21:13 CT (~ surface 21:37 All shots fired on un, break down 25' uns, recovered ball 2.1:50 PT MHA to 3500 si 22:05 Start MU of CBF firing head, 25' 2.875" HSD guns ~~ 22:33 PT surface a ui ment to 300 si / 2000 si 22:43 O en swab and RIH 23:41 Wt ck 12.8k, riw 9.2k 23:59 Continue WSR on 5/18/06 ~. '.-. !- i by PERFORATING PROCEDURE Well: 16-146 API #:50-029-20570-02 .......... Date: ..................................................... .D5/14/2008 g ..........................P................. Prod En r Patti Philli s Office Ph: 564-4578 H2S Level Home Ph: .......... 346-1755 ............................................................. No Data ...... Cost: $l OQ000 Cell/Pager: 240-3742 D5 t 6 is an H2S site CC or AFE: .......... PBD16WL14-C ..................................................... IOR: .......... 600 ..................................................... WBL Entries IOR Type Work Desciption Priority/Comments 1 ............................:................._S....:..........._PuII.MCX.SSSV;.Drift.and tag with.dummY...g!~.~.:..;:..............................................................................:. 2 C :Set CIBP ~ 14625' :.............................i.....................................~......................................................................................_.........................~.........................................................................:...............r 3 800.____........_.._....C ...............~_Adperf from.14150' - 14250' 4 C :.Mud acid. Infectivity post acid slim. Well Ob~ectives and Pertoratin Notes: Min ID = 3.725" ~ 9793' MD, 4-1/2" HES XN Nipple; Angle at Min ID = 38 deg Max Angle = 93 deg @ 13355' MD; Angle at top of current perforations = 91 deg Angle at prosedCIBP = 91 deg. Angle at top of proposed perfs = 92 deg Memory log is not required for CIBP or pert job due to large window. Depths (from-to) Feet SPF 100 6 Aorirsubtract ................................................. tees to the tie-in log to be on depth with the reference log. Orient. Phasing Zone Ad/ReAperf Random 60° 2 Adperf Requested Gun Size: 2-7/8" Charge: 2906 PowerJet Omega HMX .............. Is Drawdown Necessary/DesiredNnnecessary During Perforating Unnecessary ........................................ Preferred Amount of Drawdown/Suggestions to Achieve Drawdown NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Last Prod: BOPD BWPD Last Tag: ......_1.5,250',...,, ft MD on ..._5/17/2006 Est Res. Pres. ~ .......................8,800......,.,............. MD is ,..........,..,.,.,...,............, 3348 psi (Estimate from wsf sia Perforation Summary summary Dist Well: ____1_&___1.4__B____ Town: Date: API #: 50-029-20570-02 Prod Engr: Anch Prod Engr .................................................................... P.D. Center PBTD General Comments: Adperf/Reperf WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 16-14B 16-14B: March 10, 2008 AK-MW-4208242 2" x S" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-20570-02 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-20570-02 Digital Log Images: 1 CD Rom 50-029-20570-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date~"jY ;~, ;~ ~~i,+>~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: i.IY c ~c~(v r~2 ~ `~ 6v ~ WELL LOG TRANSMITTAL To: State of Alaska March 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 16-14B AK-MW-4208242 1 LDWG formatted CD rom with verification listing. API#: 50-029-20570-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date:'` ` n -' -' ~ Signed: CnC c~OCo - ~D3 1~ ~(~ a Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) f you have any questions, please contact Douglas Dortch at the Yll(_; at 564-4y /3 u~~- Deliver Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 06-06B ~ +5 yab 06-06BPB1 ~ aos-cY~~ ~ c~ ~~a~ 13-31 A -~TCaoS -~~OD '~ ~`~a~ 14-11 A `~ ao~ ~a6 +! ~a 14-11 APB1 14-21A uzcao5 -rod ~ r5 x/31 15-39A c~o(o-o~~r ~ ryy3a 16-066 aoc.-o ~ ~ '` ~ sy33 16-14Bc3o(o'~3 "t5S~3y C-036 ao5- i5~ '~ 66'Y35 C-10A aos--«~ +-+sua~ J-17C o~a`S O~f2 ~ +5`~3~' NGI-07A uaeacx.-,ate '~ IS~I~~l r f~ ~ ~. ,~'~ ~ Please sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 '~ `' . ~, ~ - HI mac;, !~ a+ _ ~ ts~u, ~~~r~~ 6re-~: Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 MEMORANDUM To: .Tim Regg P.I. Supervisor ? ~~~ ~~Zl,:r%~,,; .t FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 12, 2006 StiBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-14B PRUDHOE BAY UNIT 16-14B Src: Inspector NON-CONFIDENTIAL Reviewed By: _ P.I. Suprv~~ ~~" Comm Well Name: PRUDHOE BAY UNIT 16-14B Insp Num: mitLG060609132745 Rel Insp Num API Well Number 50-029-20570-02-00 Permit Number: 206-003-0 Inspector Name• Lou Grimaldi Inspection Date: 6/9/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 16-14B Type Inj. G '~ TVD 8637 ~ IA 1400 ! 2500 2490 ~ 2490 ~ ~ P.T. 2060030 TypeTCSt ~ SPT TCSt pSl 2159.25 ~ ~A ~ 340 430 ~ 430 '' 440 ~ Interval ~T~' P/F P Tubing 2410 2370 j 2370 2370 ~ ~ Notes Pretest conditions observed for two hours with no change. Post workover initial MIT. Monday, June 12, 2006 Page 1 of 1 STATE OF ALAS KA ~..._ '`~~ t '. ..;~ ~ ~`~ ALAS~IL AND GAS CONSERVATION COSIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG o- . _ 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 5/17/2006 12. Permit to Drill Number 206-003 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/16/2006 13. API Number 50-029-20570-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/24/2006 14. Well Name and Number: PBU 16-14B FNL, 527 FWL, SEC. 24, T10N, R15E, UM 1534 Top of Productive Horizon: 3673' FSL, 3826' FWL, SEC. 13, T10N, R15E, UM g, KB Elevation (ft): 67' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 3503' FSL, 710' FWL, SEC. 18, T10N, R16E, UM 9. Plug Back Depth (MD+TVD) 15221 + 8991 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 719306 y- 5929396 Zone- ASP4 10. Total Depth (MD+TVD) 15307 + 8gg0 Ft 16. Property Designation: ADL 028332 TPI: x- 722450 y- 5934698 Zone- ASP4 Total Depth: x- 724618 Y- 5934591 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: th if ff 1 W d h f 20 Thi k s f P t 18. Directional Survey ®Yes ^ No , ater ep o s ore 9. N/A MSL ne ros c s o erma . 1900' (Approx.) 21. Logs Run: MWD DIR / GR / RES / ABI, CBT / GR / CCL ASING, LINER AND EMENTING ECORD CASING ETTING EPTH MD ETTfNG EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 110' Surface 110' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2675' Surface 2671' 17-1/2" 3000 sx Fondu, 1250 sx Permafrost 9-5/8" 47# L-80 / S00-9 Surface 8963' Surface 7693' 12-1/4" 500 sx Class 'G' 7" 26# L-80 8773' 9916' 7899' 8835' 8-1/2" 288 sx Class 'G' 4-1/2" 12.6# L-80 9795' 15307' 8741' 8990' 6-1/8" 643 sx Class 'G' 23. Perforations open.to Production (MD +TVD of Top and " ' 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9805' 9665' MD TVD MD TVD 15000' - 15100' 8993' - 8992' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protected w/ 155 Bbls of Diesel 26• PRODUCTION TEST Date First Production: May 26, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas ,Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL' GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED Z4-HOUR RATE AIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures;' apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ a± :-~ ~~ i ~ D7 ~/~elwJ ~,(~E~ ~ !~ ~ ~J ~li,~ L ~~~~~~~II ~~~ ~~ ~~ ~ l~ 1 Y ~ ~ 6 V a~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 26P 10830' 9061' None 26N 10930' 9059' 23SB /Zone 2B 13133' 9035' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~Qt!~~ Signed ~ p Title Technical Assistant Date Terrie Hubble PBU 16-14B 206-003 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Jeff Cutler, 564-4134 Permit No. /Approval No. INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 3/13/2006 10:59:17 AM i i BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 16-146 Common Well Name: 16-14B Spud Date: 2/i 6/2006 Event Name: REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: Date From - To 2n/2oo6 13:00 - oo:oo 2/8/2006 00:00 - 13:00 13:00 - 13:30 2/9/2006 13:30 - 14:00 14:00 - 17:30 17:30 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 01:00 01:00 - 01:30 01:30 - 04:30 04:30 - 06:30 06:30 - 08:00 08:00 - 10:00 10:00 - 12:00 Hours ~ Task Code NPT , Phase ~ Description of Operations - - - - ~- 11.00 MOB P PRE Move rig to 16-14 13.00 MOB P PRE Move rig /Rig up /Spot buildings /Rig up lines and berms 0.50 WHSUR ~ P DECOMP Pre-Spud safety and enviromental awareness meeting. Rig accepted for operations @ 13:00 hrs 02!08!2006. 0.50 WHSUR P DECOMP PJSM Install secondary Annulus valve 3.50 WHSUR P DECOMP PJSM Rig up slick line 4.50 WHSUR P DECOMP Run in hole with 3.55" bell guide and retreive prong Run in hole with 3 1/2" slimline pulling toot Run #1 attempt to retrieve DVP plug pinned with brass Run #2 Attempt to retrieve DVP plug pinned with steel i Run #3 Install oil jars RIH and jar DVP plug free POH 0.50 WHSUR P 1.50 WHSUR P 1.00 WHSUR P 0.50 WHSUR P 3.00 WHSUR P 2.00 WHSUR P 1.50 WHSUR P 2.00 WHSUR P 2.001 WHSURIP 12:00 - 12:30 0.50 WHSUR P 12:30 - 14:30 2.00 WHSUR P 14:30 - 15:00 0.50 WHSUR P 15:00 - 20:30 5.50 WHSUR P 20:30 - 21:00 0.50 WHSUR P 21:00 - 21:30 0.50 WHSUR P 21:30 - 22:30 1.00 WHSUR P 22:30 - 00:00 1.50 WHSUR P 2/10/2006 00:00 - 04:00 4.00 WHSUR P 04:00 - 15:00 J 11.001 WHSUR I P 15:00 - 17:30 17:30 - 19:00 2.501 WHSURIP 1.501 WHSUR ~ P DECOMP Reverse circulate lines and test lines to 3500psi DECOMP Reverse circulate 48bb1 seawater /Flip lines and pump 35bb1 Soap Pill /Chase with clean seawater the long way to surface / 9BPM @1100psi DECOMP Circulate well to seawater 9BPM C~ 1100psi DECOMP Test casing to 1500psi for 10 mintutes -Blow down surface equipment DECOMP Run DVP plug in hole with slickline -Test to 1000psi from below. Blow down surface equipment. DECOMP Nipple down tree & adaptor and remove from cellar DECOMP Nipple up BOP's DECOMP RIH with slickline and pull prong 02194' -POOH change out tools and RIH and pull DVP Plug -Rig down wireline DECOMP Make up landing joint and Pull hanger to rig floor - 135K up wt free -Cut control lines -Lay down Hanger -Lay down 2 pup joints and one joint 4 1/2" tubing DECOMP Secure control lines and clear floor DECOMP PJSM Rlg up and run RTTS storm packer Set 5' below wellhead test to 1000psi DECOMP PJSM make up test joint and set test plug. DECOMP Test BOP 250 psi low 4000 psi high Waived witness by Jeff Jones of AOGCC. Witnessed by Dick Maskell and Blair Neufeld. DECOMP Rig down test joint and pull test plug -Clear floor DECOMP Make up and attempt to set wear ring /Too short /POOH DECOMP PJSM Engage RTTS storm packer -Pull RTTS and tubing to rig floor DECOMP Remove saver sub and rig up 4 1/2" handling equpment with compensator DECOMP Lay down 4 1/2" 12.6# L-80 13 cr tubing - 9534'- 7330' Spool up control lines. 55 SS bands recovered out of 58. Rig down control line spooler and lay down SSSVLN. DECOMP Lay down 4 1/2" 12.6# L-80 13 cr tubing 7330'-surface Recovered 227jts + 19.91'cut joint , 6 gas lift mandrels and an SSSV landing nipple. Tubing was cut in middle of first full joint of tubing leaving 21.21' of tubing jt #1 plus a pup joint 9.75' long screwed into the top of the packer. Will have to mill up -30' of 4.5" tubing. Chemical cut was clean - no flaring. DECOMP Rig down tubing handling equipment. Clean and clear floor. Install wear ring. DECOMP PJSM Make up milling assembly to 766'. Printed: 3/t 3/2006 10:59:24 AM BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: 16-14B Common Well Name: 16-14B Spud Date: 2/16/2006 Event Name: REENTER+COMPLETE Start: 2/6!2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: Date From - To , Hours Task. Code NPT ' Phase Description of Operations I - - -- 2/10/2006 19:00 - 23:30 4.50 WHSUR P ~ DECOMP RIH picking up singles from pipe shed 766'-7275'. Fill pipe every 3000' 23:30 - 00:00 0.50 WHSUR I P ~ DECOMP Service Top drive. 2/11/2006 00:00 - 03:00 3.00 CLEAN ; P j DECOMP RIH picking up singles from pipe shed 7275'- 9502' .Fill pipe every 3000' 03:00 - 10:00 7.00 CLEAN P ~ DECOMP Break circulation and wash down to top of cut off @ 9502' - 2' high from calculated. 175K up 158K down 170K rotating 4000 ft/Ibs off bottom torque. Start milling on 4.5" tubing stub. 60 ~ RPM. 5k WOB. 5000 ft/Ibs torque. 490 gpm @ 2640psi. Mill 9502'-9510' by 05:45 hrs. Swap system to 8.5ppg Flo-Pro mud/milling fluid while milling. Mill to 9517' where progress halted. Suspect that a coupling may be turning. 10:00 - 12:00 2.00 CLEAN P DECOMP Pump Hi vis sweep Mix and pump dry job. Blow down top drive and remove blower hose ~ 12:00 - 15:00 3.00 CLEAN P ~ DECOMP POOH 9517' - 766' 15:00 - 17;00 2.00 CLEAN P ~ DECOMP Pull out BHA .Clean out boot baskets ,Clear floor 17:00 - 18:30 1.50 CLEAN P DECOMP Wait on Baker overshot 18:30 - 19:30 1.00 CLEAN P DECOMP Make up BHA #2 to 759' 19:30 - 22:00 2.50 CLEAN P i DECOMP Run in hole 759'-9448' fill pipe every 3000' 22:00 - 23:00 1.00 CLEAN P DECOMP Engage overshot @9517' Pull 350K and jar with 100k overpull. No success disengage overshot 23:00 - 00:00 1.00 CLEAN P DECOMP Pump dry job POOH Mud weight in and out 8.5ppg 2/12/2006 00:00 - 03:00 3.00 CLEAN P DECOMP POOH !o BHA X760' 03:00 - 04:00 1.00 CLEAN P DECOMP Rack back HW DP, lay out jars and overshot. Service float and ~ clear floor. 04:00 - 05:00 1.00 CLEAN P DECOMP Make up BHA #3 with burn shoe and washpipe. 05:00 - 08:00 3.00 CLEAN P DECOMP Run in hole with BHA #3. Fill pipe every 300' 08:00 - 19:30 11.50 CLEAN P DECOMP Mill over Tubing stub with collar ~ 9524'. Start milling on packer X9532' Up 175K Down 155K Rotating 170K Off bottom torque 3000 fUlbs On bottom 3K-7K ft/Ibs, 60m RPM, 10K weight on bit, 250 GPM @ 780psi Progress stopped at -9533.5' and no further progress for several hours. Tried all known techniques to make headway. Pump a 30bb1 safecarb/nutplug sweep was run to make the slip rings more abrasive hoping to grind them up. No progress so pumps were shut off and milled without circulation in an attempt to heat things up. Again no success. 18:00 - 19:30 1.50 CLEAN P DECOMP Circulate bottoms up 200 strokes / min ~ 1600psi -Pump dry job Blow down surface equipment. Remove Blower hose 19:30 - 22:30 3.00 CLEAN P DECOMP POOH 9534' to 799' MW in and out 8.4 ppg. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH with BHA from 799' to jars at 62'. Change out burn shoe and empty boot baskets. All 3 boot baskets were full - approx 40 Ibs of debris. Mill about 50% worn but still had cutting structure. 2/13/2006 00:00 - 04:00 4.00 CLEAN P DECOMP RIH 798' to 9534' wash to bottom 04:00 - 11:30 7.50 CLEAN P DECOMP Mill with burn shoe on Packer. Initially shoe made 3-4 inches then did not drill off until 11:15 when it broke through. Monitor wel I 11:30 - 12:00 0.50 CLEAN P DECOMP Run in hole with dril pipe, chase packer down hole to cement. Tag ~ 10,150' Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: 16-14B Common Well Name: 16-14B Spud Date: 2/16/2006 Event Name: REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: Date ;~ From - To ~'~, Hours ' Task ~ __ - 13/2006 ~ 12:00 - 14:30 2.50 ~ CLEAN Code NPT ', '.Phase - -~----- P 14:30 - 15:30 I 1.001 CLEAN I P 15:30 - 16:00 0.50 CLEAN P 16:00 - 19:00 3.00 CLEAN P 19:00 - 21:00 2.00 CLEAN P 21:00 - 00:00 3.00 CLEAN P 4/2006 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 04:00 I 2.501 CLEAN I P 04:00 - 06:30 I 2.501 CLEAN I N 06:30 - 11:30 5.00 CLEAN P 11:30 - 12:30 1.00 CLEAN P 12:30 - 15:30 3.00 STWHIP P 15:30 - 20:30 I 5.001 STWHIPI P 20:30-21:00 ~ 0.50~STWHIP~P 21:00 - 00:00 I 3.001 STWHIPI P 5/2006 100:00 - 08:00 8.001 STWHIPI P 08:00 - 11:30 I 3.501 STWHIPI P 11:30 - 12:00 I 0.501 STWHIPI P 12:00 - 12:30 I 0.501 STWHIPI P 12:30 - 16:00 3.50 STWHIP P 16:00 - 18:00 2.00 STWHIP P 18:00 - 19:00 I 1.001 STWHIPI P 19:00 - 22:00 I 3.001 STWHIPI P Description of Operations ~ DECOMP i Circulate supersweep around 2 x bottoms up, 200SPM ~ @ 1750psi Monitor well -Pump dry job Blow down surface equipment DECOMP Cut 81' of drilling line. Inspect and lubricate draw works. Inspect Traction motor brushes. Lube Elmago splines. Service Crown DECOMP Service Top drive DECOMP POOH 10,150' to 799' DECOMP POOH 799' to 62' Lay down Baker fishing tools. Clear floor DECOMP PJSM rig up E-line, run gauge ring and junk basket to 9960'. POOH to 9039' where tool became stuck. Worked tool free down then pulled obstruction up hole to liner lap at 8773'. POOH to change out line weak point due to max overpull on line when stuck. DECOMP POOH with E-line guage ring / junk basket and rehead rope socket. DECOMP RIH with gauge ring / junk basket on E-line. At 9250' lost 300 Ibs on line weight. Pulled back up with no overpull. Lowered back down with no loss of weight on line. RIH to 9960'. POOH with no overpull, only slight fluctuation at liner lap. POH UD guage ring ! junk basket. DFAL DECOMP Trouble shoot wireline tools firing ability. Arm firing head, M/U tools and EZSV. DECOMP RIH with EZSV and set @ 9941' ELM. POH & R/D SWS. DECOMP Close blind rams and test casing to 4000 psi, OK. WEXIT M/U whipstock BHA to 847'. Up-load MWD, orient. Test MWD @ 325 gpm @ 700 psi. WEXIT RIH from 847' to 9850'. Fill pipe @ 3000' intervals. Install top drive blower hose. WEXIT Orient whipstock 29 degrees RHS. Tag EZSV @ 9933', set anchor with 11 K down, shear lug with 35K down. WEXIT Record milling parameters & SPR. Mill window in 7" 26# casing from 9916' to 9921'. UWT = 180K, DWT = 140K, RWT = 170K. WOB = 5K. Torque = 5K @ 100 rpm. Pump @ 325 gpm @ 1480 psi. No metal cuttings in returns, pump high vis weighted sweeps. No metal or cement in returns. WEXIT Mill window in 7" 26# casing and 20' of new formation from 9921' to 9943'. WOB = 5/10K. Torque = 4/5K @ 100 rpm. Pump @ 330 gpm @ 1600 psi. WEXIT Pump 2 high vis sweeps and 2 super sweeps, circ until clean. Recovered 40# of metal cuttings. WEXIT Pull into casing. Perform FIT to 10.17 ppg EMW. (770 psi with 8.5 ppg mud @ 8825' TVD) WEXIT Pump dry job. Blow down surface equipment. Mud weight in and out = 8.5 ppg. WEXIT POH for BHA to 829', change handling equip. WEXIT POH with BHA. Stand back 2 stands HWDP, L/D whipstock milling assy from 649'. Down load MWD. Upper mill full gauge. Clear rig floor. WEXIT Pull wear ring, flush BOP stack and function rams. Install wear ring. Blow down lines. WEXIT M/U BHA to 746'. P/U insert bit, 1.5 degree mud motor drilling assy. Orient, up load & surface test MWD. Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: 16-14B Common Well Name: 16-14B Spud Date: 2/16/2006 Event Name: REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 2ES Rig Number: Date From - To I Hours ' NPT Phase Description of Operations (.Task :Code --- - ~, --- - - 2/15/2006 r 22:00 - 00:00 i 2.001 ~- STWHIP ~ P ~ --- WEXIT - _ __ _ -- i RIH P/U 4" HT40 drill pipe from 746' to 3553', fill pipe. 2/16/2006 00:00 - 02:00 ' 2.00 i STWHIP P W EXIT ~ RIH P/U 4" HT40 drill pipe from 3553' to 6067. 02:00 - 03:30 1.50 i STWHIP P W EXIT RIH with stands from derrick from 6067' to 9802'. Fill pipe ~ 13000' intervals. Orient & install top drive blower hose. Pass ~ through window, wash to bottom @ 9943'. 03:30 - 00:00 20.50 DRILL P PROD1 Drill ahead from 9943' to 10238'. Pump C~ 247 gpm @ 1500 ~ psi. UWT= 180K, DWT= 150K, RWT= 165K, Torque = 5/6K C~3 50 rpm's AST=11.89 -ART=1.63. ROP slow in Zone 4 to -10140' (10 fph) but improved with formation change. 2/17/2006 00:00 - 16:30 16.50 DRILL P PRODi Drill 6 1/8" hole from 10238' to 10847'. UWT = 180K, DWT = ~ 145K, RWT = 165K. Torque = 5/6K @ 50 rpm. Pump C~3 250 ~ gpm @ 1540 psi. WOB = 10K. 16:30 - 18:30. 2.00 DRILL P PRODi Pump sweep, observe well. 18:30 - 19:30 1.00 DRILL P PROD1 ROP slowed to 10/15 ft per hour. POOH from 10,847' to 9950' for PDC bit & high speed mud motor. UWT=195K, DWT=145K. 19:30 - 20:30 1.00 DRILL P PROD1 MAD Pass from 9989' to 9880'. 20:30 - 21:00 0.50 DRILL P PROD1 Drop dart to open circ sub (sub did not open, dart landed on corrosion rig @ top of jars. Ring was cocked) pump dry job. 21:00 - 00:00 3.00 DRILL P PROD1 POOH from 9880' to 2338' for PDC bit & BHA. 2/18/2006 00:00 - 01:30 1.50 DRILL P PROD1 POH from 2338' to BHA @ 746'. Monitor well. 01:30 - 03:30 2.00 DRILL P PROD1 POH with BHA, down load MWD. L/D mud motor and bit. Clear rig floor, monitor well. 03:30 -04:30 1.00 DRILL P PROD1 M/U BHA #3, P/U high speed mud motor with 1.5 degree bend, check float. P/U PDC bit & orient. 04:30 - 06:00 1.50 DRILL P PROD1 Shallow pulse test MWD Q 280 gpm @ 830 psi. RIH from 737' to 3544', fill pipe. 06:00 - 08:00 2.00 PROD1 RIH from 3544' to 6339'. Fill pipe. Test MWD @ 260 gpm @ 1100 psi. RIH from 6339' to 10729'. 08:00 - 09:30 1.50 DRILL P PROD1 PJSM. Cut & slip 85' drilling line. Change out low clutch quick release valve. 09:30 - 10:30 1.00 DRILL P PROD1 Service rig & top drive. Install blower hose. Fill pipe & orient 10:30 - 11:00 0.50 DRILL P PROD1 Wash & ream from 10729' to 10847'. Hole in good shape, no fill. 11:00 - 00:00 13.00 DRILL P PROD1 Drill from 10847' to 11757'. UWT = 185K, DWT = 140K, RWT= 165K. TO = 6K ~ 55 rpm. Pump Ca3 316 gpm C~3 2250 psi. ART = 7.03 hrs. AST = 1.14 hrs. 2/19/2006 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" hole from 11757' to 12829'. AST = 6.95 hrs. ART = 5.92 hrs. UWT = 185K, DWT = 135K, RWT = 165K. Torque on and off bottom = 6/7K @ 60 rpm. WOB = 5K. Pump Q 316 gpm Q 2280 psi. Mud weight in 8.6 ppg, out 8.7 ppg. 2/20/2006 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" hole from 12829' to 13493'. Pump ~ 316 gpm C~3 2370 psi. Torque = 6/7K on & off bottom C~ 60 rpm. WOB = 5K. UWT = 185K, DWT = 130K, RWT = 160K. AST = 2.13 hrs, ART = 4.67 hrs. 2/21/2006 00:00 - 11:00 11.00 DRILL P PROD1 Drill 6 1/8" hole. Pump Q 316 gpm @ 2280 psi. WOB = 5K. Torque = 6/7K @ 80 rpm. Drill to 13912' MD rotating at 30 to 100 fph. Minimal sliding required from this point. Weather at phase 2. Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Operations Summary Report Page 5 of 9 Legal Well Common W Event Nam Contractor Rig Name: Date I _ _ Name: 1 ell Name: 1 e: Name: From - To i 6-14B 6-146 REENTE NABOB NABOB Hours I R+COM S ALASK S 2ES Task - - PLET A DRI Code ~ E LLING NPT Start I Rig Rig Phase --_ _ -- Spud Date: 2/16/2006 : 2/6/2006 End: 3/6/2006 Release: Number: Description of Operations - --- _ - 2/21/2006 11:00 - 14:00 3.00 DRILL N WAIT PROD1 Phase 3 weather announced -closed to atl travel. Circulate the hole clean. 14:00 - 19:00 I 5.00 DRILL N WAIT PROD1 Monitor well. POH to window laying down singles. Wind is blowing the top drive hoses outside the windwalls when trying to pull stands. 19:00 - 00:00 5.00 DRILL N WAIT PROD1 Circulate across top of hole waiting for Phase 3 weather to subside. Possible crew change this morning -also fuel & water delivery. Well taking 2 bph static loss. 2/22/2006 00:00 - 12:00 12.00 DRILL N WAIT PROD1 Continue waiting on weather. At 05:45 hrs, weather downgraded to phase 2 level 3 -access road is blown in. Circ across top of well. (2 bph loss) Light housekeeping. Plowing pad as visibility allows. 12:00 - 14:00 2.00 DRILL P PROD1 PJSM. P/U joint of drill pipe, M!U storm packer (RTTS) assy & set C~ 37'. UD joint of pipe & running tool. Test packer from above to to 1000 psi. 14:00 - 20:00 6.00 BOPSU P PROD1 PJSM. Pull wear ring, install test plug. M/U test joint & test BOPE to 250 psi low & 4000 psi high test. Annular preventor tested to 250 low & 2500 high. Witness of test waived by Lou Grimalde w/AOGCC. Test witnessed by Rig Rep. Dick Maskell & Tool pusher Cleve Coyne. Blow down lines, pull test plug & install wear ring. 20:00 - 21:00 1.00 DRILL P PRODi P/U joint of drill pipe, storm packer running tool & Safety valve. Retrieve packer & UD. 21:00 - 21:30 0.50 DRILL P PRODi Service top drive & splines on dwks dynamatic brake. 21:30 - 00:00 2.50 DRILL N WAIT PRODi RIH P/U drill pipe, pass window @ 9916 to 9929'. P/U pipe to 12223'. 2/23/2006 00:00 - 02:30 2.50 DRILL N WAIT PRODi Fill pipe and break circ, stage pumps up to 7 bpm @ 2175 psi. Blow down circ lines and check for flow. RIH P/U drill pipe from 12223' to 13812'. Hole in good shape. 02:30 - 03:00 0.50 DRILL N WAIT PROD1 Fill pipe and break circ, stage pumps up to 7 bpm @ 2200 psi. Wash & ream from 13812' to 13905'. 03:00 - 00:00 21.00 DRILL P PROD1 Drill 6 1!8" hole from 14747' AST = .47 hrs, ART = 9.01 hrs. Pump @ 316 gpm C~3 2550 psi. WOB = 5K. Torque = 9K on and off bottom C~ 85 rpm. HWT = 190K, SWT = 120K, RWT = 160K. MWT in & out = 8.8 ppg. 2/24/2006 00:00 - 10:30 10.50 DRILL P PROD1 Drill 6 1/8" hole from 14747' to 15307'. Pump Cam? 330 gpm @ 2750 psi. WOB = 7K. Torque = 9K on bottom & 8K off C 85 rpm. HWT = 195K, DWT = 115K, RWT = 160K. MWT in & out = 8.8 pPg• 10:30 - 14:30 4.00 DRILL P PRODi Pump high vis sweep, rotate & reciprocate. Circ until clean Q 330 gpm @ 2600 psi. Drop dart & open pump out sub. Pump dry job. Monitor well 14:30 - 17:30 3.00 DRILL P PRODi POH from 15307' to 9886' racking drill pipe back in derrick. 17:30 - 19:00 1.50 DRILL P PRODi Monitor well @ shoe. CBU @ max rate, 540 gpm @ 1730 psi. Circ until clean, rotate & reciprocate. Pump dry job. Monitor well. 19:00 - 21:00 2.00 DRILL P PRODi POH from 9886' to 5497' racking pipe back in derrick. 21:00 - 22:30 1.50 DRILL P PROD1 PJSM. Slip & cut 95' drill line. Visual inspection of dwks brakes. 22:30 - 23:00 0.50 DRILL P PRODi Service rig & top drive. 23:00 - 00:00 1.00 DRILL P PROD1 POH LDDP from 5497' to 4289'. 2/25/2006 00:00 - 03:00 3.00 DRILL P PROD1 POH for 4.5" 12.6# L-80 IBT-M liner. LDDP from 4289' to 360'. Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Operations Summary Report Page 6 of 9 Legal Well Name: 16-14B Common Well Name: 16-14B Spud Date: 2/16/2006 Event Name: REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ~~, Hours Task ~~ Code ~ NPT 2/25/2006 03:00 - 07:00 ~ 4.00 DRILL ~ P ~I 07:00 - 08:00 1.00 CASE P 08:00 - 08:30 0.50 CASE P 08:30 - 15:00 6.50 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 19:00 3.00 CASE P 19:00 - 20:00 20:00 - 22:00 22:00 - 22:30 22:30 - 00:00 2/26/2006 100:00 - 02:30 02:30 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 08:00 08:00 - 15:30 15:30 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21:00 21:00 - 00:00 2/27/2006 00:00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 08:30 Phase ~ Description of Operations PROD1 PJSM. L/D BHA from 360'. Flush tools with water and blow down top drive. L/D HWDP, flex collars, and jars. Down load MWD. Clear rig floor. RUNPRD PJSM. R/U 4 1/2" liner handling equip. RUNPRD PJSM with all personell. P/U float equip and check floats are holding. RUNPRD RIH with 4 1/2" 12.6# L-80 IBT-M liner to 5474'. Fill every joint. M/U torque = 3800 ft. lbs. UWT = 85K, DWT = 85K. RUNPRD M/U hanger, gel pack top of hanger. P/U XO and 15' pup. RUNPRD Circ liner volume, pump C~3 6 bpm C~3 285 psi. RUNPRD RIH with liner on 4" drill pipe from 5474' to 7" window @ 9916'. Fill pipe @ 10 stand intervals. 1.00 CASE P RUNPRD Fill pipe, break circ & stage pump up to 6 bpm C~ 560 psi. UWT = 155K, DWT = 135K. Blow down top drive. 2.00 CASE P RUNPRD RIH with 4" drill pipe from 9916' to 15283'. 0.50 CASE P RUNPRD P/U joint of drill pipe & cement head, R/U circ lines. 1.50 CASE P RUNPRD Fill pipe and break circ, stage pumps up to 5 bpm C«? 1300 psi. Tag bottom @ 15307. UWT = 180K, DWT = 130K. 2.50 CASE P RUNPRD Circ & cond. mud @ 15307'. Pump ~ 6 bpm ~ 1350 psi. PJSM with drill crew, Schlumberger cement crew & Veco. Batch mix cement. 2.00 CEMT P RUNPRD Cement 4 1/2" liner. Pump 5 bbl water & test lines to 4500 psi. Pump 15 bbl of CW 100 followed by 30 bbl 9.5 ppg Mud Push II spacer. Pump 134 bbls of class "G" 15.8 ppg cement. Wash lines to tee on rig floor with pert pill. Drop wiper plug and displace with 82 bbl of pert pill. Finish displacing with 101 bbl 8.8 ppg mud. Bump plug with 3785 psi. CIP ~ 04:15 hrs. 1.00 CEMT P RUNPRD Set liner on bottom. Pressure up to 3000 psi to set hanger. Set down 75K weight to confirm set. Pressure up to 4000 psi to release running tool. Check floats are holding. P/U to release dogs. Rotate C~? 20 rpm, slack off and weight set packer with 70K down. Pressure up to 1000 psi and P/U to unsting. Circ at max rate, 498 gpm @ 2300 psi. Approx 3 bbl cement returns. 0.50 CEMT P RUNPRD R/U cement head &circ lines. 2.00 CEMT P RUNPRD Pump 30 bbl soap pill. Displace well to 8.5 ppg seawater @ 12 bpm C~3 2100 psi. Pump dry job, blow down top drive. 7.50 CEMT P RUNPRD POH LDDP from 9795'. 0.50 CEMT P RUNPRD L/D Baker liner running tool, clear rig floor. 2.00 BUNCO RUNCMP Clean out rotary table with super sucker. 1.00 BUNCO RUNCMP Pull wear bushing, M/U XO to landing joint. 1.00 BUNCO RUNCMP Test casing/liner to 4000 psi for 30 min, OK. 1.00 BUNCO RUNCMP PJSM with all personell, R/U to run 4 1/2" 12.6# L-80 TCII tubing. 3.00 BUNCO RUNCMP RIH with 4 1/2" completion. Torque turn pipe. Make up torque = 3850 ft lbs. 6.00 BUNCO RUNCMP RIH with 4 1/2" 12.6# L-80 TCII tubing from 3320' to 9746'. 0.50 BUNCO DPRB RUNCMP Tag obstruction @ 9746'. UWT = 140K, DWT = 110K. Work pipe. 1.50 BUNCO DPRB RUNCMP PJSM. R/U circ lines, attempt to pump, pressure up to 500 psi. No circ. 0.50 BUNCO DPRB RUNCMP PJSM. R/D circ lines. Attempt to work pipe free. Pull 240K, no movement. Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: 16-14B Common Well Name: 16-14B Spud Date: 2/16/2006 Event Name: REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: Date 2/27/2006 From - To ~ Haurs ! Task Code NPT ~ Phase 08:30 - 10:00 1.50 RUNC I 10:00 - 13:00 3.00 RUNC 13:00 - 15:00 15:00 - 16:30 116:30 - 18:30 X18:30-20:30 20:30 - 23:00 23:00 - 00:00 2/28/2006 00:00 - 01:30 101:30 - 05:00 05:00 - 07:30 07:30 - 10:30 10:30 - 12:00 12:00 - 13:00 2.00 BUNCO 1.50 BUNCO 2.00 BUNCO 2.00 BUNCO 2.50 BUNCO 1.00 BUNCO 1.50 BUNCO 3.50 BUNCO 2.50 BUNCO 3.00 BUNCO 1.50 BUNCO 1.00 BUNCO 13:00 - 00:00 11.00 RU 3/1/2006 00:00 - 01:30 1.50 RU 01:30 - 03:00 1.50 RU 03:00 - 03:30 0.50 RU 03:30 - 04:00 0.50 RU 04:00 - 04:30 0.50 RU 04:30 - 14:30 10.00 RU 14:30 - 15:30 1.00 RU 15:30 - 17:30 2.00 RU 17:30 - 20:30 I 3.001 RU 20:30 - 00:00 I 3.501 RU 3/2/2006 100:00 - 10:30 I 10.501 RUN 10:30 - 1 i :00 I 0.50 I RU N Description of Operations DPRB ' RUNCMP _--- - - - -- Drop ball & rod. Pressure up to 4000 psi & set packer. Hold for ~ 20 min, bleed pressure & pull 190K on tubing string. WLEG C«~ 9746', packer @ 9689'. Blow down surface equip, R/D circ ~, lines. DPRB i RUNCMP PJSM. R/U SWS. Change of plans. R/D SWS. Load pipe shed with 4" HT40 drill pipe. DPRB ~ RUNCMP Wait for slick line crew to arrive. DPRB I RUNCMP Wait on 7" OTIS x 4 1/2" IF XO & wire line pack-off assy. DPRB ~ RUNCMP Install OTIS XO & pack-off assy. DPRB ~ RUNCMP PJSM. R/U SWS slick line unit. I Run # 1, RIH with slick line to 9738' & retrieve ball & rod, POH. DPRB ~ RUNCMP Run # 2, RIH to 9742' & retrieve RHC plug, POH. DPRB i RUNCMP Run # 3, RIH with 3.625 centralizer & sample bailer. DPRB ~ RUNCMP Run # 3 with slick line. RIH with 3.625 centralizer & sample bailer. Tag obstruction @ 9753' WLM. POH, hard cement chips in sample bailer. DPRB RUNCMP Run # 4, RIH with 3.625 centralizer and sample bailer with knuckle joint. Tag obstruction @ 9753'. POH. Hard cement chips in sample bailer. R/D slick line. DPRB 'RUNCMP R/U SWS E-line & prepare to Jet cut tubing. DPRB RUNCMP Run in hole with CCL and jet collar. Cut tubing 2' above packer C 9687'. Good surface indication POOH DPRB RUNCMP Pick up on tubing with no overpull 135K up 110K down. Lay down landing joint. Rig up handling equipment with compensator. DPRB RUNCMP POOH lay down 4 1/2" 12.6# TC11 tubing using compensator DPRB RUNCMP 9687'-9355' Pump dry job monitor well/POOH lay down tubing 9355'-830' DPRB ~ RUNCMP POOH lay down 4 1/2" 12.6# TC11 tubing using compensator DPRB RUNCMP Rig down 4 1/2" handling equipment /Install saver sub DPRB RUNCMP Install wear ring DPRB RUNCMP Pick up Baker milling tools to floor DPRB RUNCMP Pre job safety meeting /Make up Mill and Junk baskets DPRB RUNCMP Run in hole picking up Drill collars and Drill pipe from pipe shed. Tag and wash cement stringers 08760' 190GPM 335psi, 20RPM 4-5K fUlbs torque. RUNCMP Service Topdrive and. rig /Install blower hose RREP RUNCMP Rig Repair /Change out air quick release on drum clutch / Change out master cylinder on rotary brake. DPRB RUNCMP Run in hole picking Drill pipe from pipe shed. Tag cement stringers wash and rotate from 9100' to 9687'. Top of fish tagged ~ 9687' DPRB RUNCMP Mill tubing stub and packer 9687'-9691'. 410GPMC~31920psi,90 RPMC«~8-9kfUlbs torque,185Kup/145K down/rotating 165K,W06 5-7K,8.5ppg Seawater in and out DPRB RUNCMP Mill packer 9691'.410GPM@1920psi,100RPMC8-9kfUlbs torque,175Kup/155K down/rotating 165K,W06 5-15K,8.5ppg Seawater in and out. Mill for 1 hour with no pump some intermittent torque spikes then torque leveled off at 8-9K. Milled a total of 6' from tag up. DPRB RUNCMP Monitor WeII,Static,Slug pipe,Blow down topdrive,Remove blower hose Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 16-14B 16-14B Spud Date: 2/16/2006 REENTER+COMPLETE Start: 2/6/2006 End: 3/6/2006 NABOBS ALASKA DRILLING 1 Rig Release: NABOBS 2ES Rig Number: Date From - To I Hours ': Task I Code ~ NPT 3/2/2006 ~ 11:00 - 14:00 3.00 BUNCO li DPRB 14:00 - 15:30 1.50 RUNCO~ I DPRB 15:30 - 17:00 1.50 BUNCO I DPRB 17:00 - 18:30 1.50 BUNCO DPRB 18:30 - 20:00 1.50 BUNCO i 20:00 - 21:00 1.00 BUNCO ~ 21:00 - 22:00 1.00 BUNCO DPRB 22:00 - 00:00 2.00 BUNCO DPRB 00:00 - 00:30 0.50 BUNCO DPRB 00:30 - 05:00 4.50 BUNCO DPRB 05:00 - 05:30 0.50 BUNCO DPRB 05:30 - 07:00 1.50 BUNCO DPRB 07:00 - 10:30 3.50 BUNCO DPRB 10:30 - 11:30 1.00 BUNCO DPRB 11:30 - 16:30 5.00 BUNCO DPRB 16:30 - 18:00 1.50 BUNCO DPRB 18:00 - 19:30 1.50 BUNCO DPRB 19:30 - 20:00 0.50 BUNCO 20:00 - 21:30 1.50 BUNCO DPRB 21:30 - 00:00 2.50 BUNCO DPRB 3/4/2006 00:00 - 01:30 1.50 BUNCO DPRB 01:30 - 04:30 3.00 RUNCO~ DPRB 04:30 - 07:00 2.50 BUNCO DPRB 07:00 - 09:30 2.50 RUNCO~ DPRB 09:30 - 10:30 1.00 BUNCO DPRB 10:30 - 12:00 I 1.501 RUNC01~4T1 I DPRB 12:00 - 12:30 I 0.501 RUNCOAVN I DPRB 12:30 - 14:00 1.50 BUNCO DPRB 14:00 - 15:30 1.50 BUNCO DPRB 15:30 - 20:30 5.00 BUNCO DPRB 20:30 - 22:00 1.50 BUNCO DPRB 22:00 - 22:30 0.50 BUNCO DPRB 22:30 - 23:30 1.00 BUNCO DPRB 23:30 - 00:00 0.50 BUNCO DPRB 3/5/2006 00:00 - 08:30 8.50 BUNCO DPRB 08:30 - 09:00 0.50 09:00 - 10:00 1.00 Phase Description of Operations RUNCMP PJSM, POOH 9696'-305',Monitor well C~36HA RUNCMP POOH to surface, stand back dill collars and lay down mills & boot baskets. Mill had some wear, but still good. Some large chunks of packer slips in boot baskets. RUNCMP PJSM, Make up fishing BHA with Spear, RIH to 300' RUNCMP Run in hole with BHA#8 300'-5995' RUNCMP PJSM Cut and slip drilling line RUNCMP Service topdrive and draworks RUNCMP Safety Meeting RUNCMP Run in hole 5995'-9693' 185K up 145Kdown, 8.5ppg seawater in and out RUNCMP Attempt to Engage fish RUNCMP POOH 9693'-300' RUNCMP Rack back collars. Spear came out of hole in the release position without shearing set screw. RUNCMP Change out head on spear. Run in hole to 300' RUNCMP RIH 300'-9640' RUNCMP Wash down to fish 9640'-9693' up wt185K, down wt 150K, rotating wt 155K. 196GPM @615psi. Engage fish with 20K slackoff. Pull 40k overpull pump through fish 147GPM C~ 575psi. Slack off 20K to verify fish engagement pull 5-10K overpull. Monitor well. RUNCMP POOH with fish 9693'-300' RUNCMP PJSM Lay down fish and spear. Clear and clean floor RUNCMP Bring tools to the drill floor. Make up BHA to 34' RUNCMP Lubricate rig, Service topdrive RUNCMP Make up BHA 34' to 54' Run in drill collars to 331' RUNCMP Run in hole 331'-9671' RUNCMP Reverse circulate 4 BPM ~500psi. Strip in the hole through bag 9671'-9728'. Screen plugged and pressured up to 1200psi Bleed off and open bag. Drop dart to open circulating sub. Pump dry job and blow down surface equipment. RUNCMP POOH 9728' - 54' RUNCMP Lay down BHA no debris found in catcher. Clean out junk baskets.Make up polish mill RUNCMP Run in hole 54' - 9676' RUNCMP Wash and ream 9676'-9804'. 380GPMC~31350psi. 90RPM @4k ft/Ibs RUNCMP Pump high vis sweep and chase with clean seawater. 495GPM 2350psi. Rotate and reciprocate. RUNCMP Monitor well 039804' Static. Pump Dry job. Blow down topdrive Remove blower hose RUNCMP PJSM POOH laying down pipe 9804'-7466' RUNCMP Cut drilling line. Inspect and adjust brakes RUNCMP POOH laying down drill pipe 7466'-335' RUNCMP Lay down BHA & clean floor RUNCMP PJSM Pull wear ring RUNCMP PJSM Rig up 4 1/2" tubing handling equipment RUNCMP Pick up tailpipe and Packer RUNCMP Run 4 1/2" 12.6# L-80 Completion to 9776' OPT TO=3850 ft/Ibs 135K up 110K down. RUNCMP Space out TagC~9806 No pup needed RUNCMP Make up landing joint and hanger. Land string Printed: 3/13/2006 10:59:24 AM BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: 16-14B Common Well Name: 16-14B Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Start: 2/6/2006 Rig Release: Rig Number: Spud Date: 2/16/2006 End: 3/6/2006 Date ~ From - To Hours ! Task Ik Gode NPT 3/5/2006 10:00 - 10:30 0.50 RUNCOA hP ~ 10:30 - 11:00 0.50 RUNCO 11:00 - 13:00 2.00 BOPSU ~ P 1 13:00 - 16:00 3.00 WHSUR' P ~ 16:00 - 17:00 1.00 WHSUR P 1, 17:00 - 18:00 1.00 WHSUR P 18:00-00:00 6.00 WHSUR, P 3/6/2006 i 00:00 - 03:00 3.00 W HS U R P 03:00 - 08:30 5.50 WHSUR P 08:30 - 09:00 0.50 WHSUR P ~ 09:00 - 10:30 1.50 WHSUR P 10:30 - 11:00 0.50 WHSUR P 11:00 - 12:30 1.50 WHSUR P Phase Description of Operations RUNCMP Dry rod TWC -Test from below to 1000psi RUNCMP Blow down surface equipment rig down tubing equipment RUNCMP PJSM Nipple down BOP RUNCMP PJSM Nipple up tree and adapter flange.Test to 5000psi RUNCMP PJSM Pull TWC with lubricator -Rig down lubricator RUNCMP Rig up circulating line. Test lines to 4000psi RUNCMP Attempted to reverse circulate.Kept Plugging. Pump freeze protect down the tubing. Pump 150bb1 Seawater / 350bb1 Corrosion inhibited Seawater / 155bb1 Diesel. RUNCMP Displace with 148bb1 Seawater 3 BPM ~ 800psi RUNCMP Allow freeze protect to U-tube RUNCMP Drop 1 7/8" ball and rod RUNCMP Test tubing to 4000psi for 30 min. Test annulus to 4000psi for 30 min. RUNCMP Dry rod BPV RUNCMP Rig down circulating lines and remove 2nd annular valve. Rig release 12:30 3-6-2006 Printed: 3/13/2006 10:59:24 AM • • Well: 16-14B Accept: 02/08/06 Field: Prudhoe Bay Unit Spud: 02/16/06 API: 50-029-20570-02 Release: 03/06/06 Permit: 206-003 Riq: Nabors 2ES POST RIG WORK 04/08/06 PULLED B&R AT 9778' SLM. PULLED RHC PLUG BODY AT 9784' SLM. DRIFT W/ 12' X 3 3/8 DMY GUN TO 9890' SLM, (-40'` DEV) UNABLE TO WORK PAST -POOH. 04/09/06 BAILED AT 9891' SLM W/ 3.625" CENT AND 10' X 3" P. BAILER. RECOVERED FORMATION SAND, METAL SHAVINGS AND PIECES OF PACKING. WELL LEFT S/I. 05/16/06 RIH WITH WFD 3 1/8" VENTURI JUNK BASKET. SAT DOWN AT 9930' CTMD. COULD NOT MAKE ANY HOLE. POOH. RECOVERED SEVERAL LARGE METAL SCRAPS AND A PARTIAL LARGE PACKING ELEMENT. RIH WITH WFD 2 7/8" PDM WITH 3.70" CONCAVE 5-BLADE JUNK MILL. 05/17/06 RIH WITH WFD 2 7/8" MOTOR AND 3.70" CONCAVE 5-BLADE JUNK MILL. SAT DOWN AT 9930' CTMD. MILLED A COUPLE OF HARD FEET AT 9930' CTMD THEN MILLED EASIER. RIH MILLING TO 14900' CTMD, SEEING LOCK UP. PUH, VARY RATE AND WORK MILL DOWN TO TD AT 15250' CTMD. CONTINUE CIRCULATING WHILE POOH WITH MILL (BACKREAMING). RIH WITH PDS MEMORY GR/CCL. RIH WITH CBF FIRING HEAD AND 25' OF 2.875" HSD TCP GUN. PERF FROM 15075' - 15100' RIH WITH 2ND OF 4 PERF RUNS WITH SAME CONFIGURATION. 05/18/06 CONTINUE IN HOLE W/GUN RUN #2 OF 4. STOP AT CT FLAG. CORRECT TO TOP SHOT. CONTINUE TO FIRING DEPTH 15050' - 15074'. DROP 1/2" BALL TO PERFORATE. POOH. MU MEMORY LOGGING TOOLS. RIH. LOG FROM 15200' TO 13800'. PAINT FLAG AT 14,950'. POOH. NO DATA RECORDED. RE-RUN MEMORY LOGS ACROSS SAME INTERVAL. PAINT FLAG AT 14958.1'. POOH. GOOD DATA RECOVERED - 42' CORRECTION. RIH W. GUN #3 OF 4 PERF 15025' - 15049'. POOH. 05/19/06 FIRE GUNS AT 15025' TOP SHOT. POOH. MU GUNS FOR RUN #4. RIH. SHOOT 15000' TO 15025'. POOH. FREEZE PROTECT WELL WITH 60/40 METH. RDMO. TURN WELL OVER TO DSO TO POP. JOB COMPLETE. Halliburton Company , Survey Report Company: BP Amoco Date: 3/14/2006 Time: 10.39:20 Page: ] Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 1fi-14, T rue North i Site: PB DS 16 Vertical (TVD) Reference: 38.5 + 28.5 67.0 ~~ ell: 16-14 Section (VS) Reference: Well (O.OON,O .OOE,47.33Azi} ~~ ellpath: 16-146 Survev Calculation Method: Minimum Cur vature Db: Oracle - - Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea L evel Geomagnetic Model: bggm2005 Well: 16-14 Slot Name: 14 16-14 Well Position: +N/-S 1943.96 ft Northing: 5929396.43 ft Latitude: 70 12 34.664 N +E/-W 392.96 ft Fas ting : 719306.30 ft Longitude: 148 13 53.161 W Position Uncertainty: 0.00 ft Wellpath: 16-14B Drilled From: 16-14A 500292057002 Tie-on Depth: 9892.17 ft Current Datum: 38.5 + 28.5 Height 67.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/12/2006 Declination: 24.82 deg Field Strength: 57621 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29.00 0.00 0.00 47.33 Survey Program for DeSnitive Wellpath Date: 3/14/2006 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 100.85 9000.85 16-14 GyroData (1 00.85-9000.85 GYD-CT-CMS Gyrodata cont.casing m/s 9025.85 9480.85 16-14A GyroData (9025.85-9480. GYD-CT-CMS Gyrodata cont.casing m/s 9481.45 15110.43 2 : MWD -Standard (9069.95-15 MWD MWD -Standard 15111.03 15270.30 16-14B IIFR+MS+SAG (9916.00-15 MWD+IFR+MS MWD +IFR + Multi Station Survey ~ MD Incl Azim TVD Sys TVD N/S E/W Mapi~' MapE Tool ~~I ft deg deg ft ft ft ft ft ft 29.00 0.00 0.00 29.00 -38.00 0.00 0.00 5929396.43 719306.30 TIE LINE 100.85 0.06 193.94 100.85 33.85 -0.04 -0.01 5929396.40 719306.30 GYD-CT-CMS 200.85 0.12 228.37 200.85 133.85 -0.16 -0.10 5929396.27 719306.21 GYD-CT-CMS 300.85 0.12 202.99 300.85 233.85 -0.32 -0.22 5929396.10 719306.09 GYD-CT-CMS 400.85 0.24 195.77 400.85 333.85 -0.62 -0.32 5929395.80 719306.00 GYD-CT-CMS 500.85 0.31 203.40 500.85 433.85 -1.07 -0.48 5929395.35 719305.85 GYD-CT-CMS 600.85 0.30 272.76 600.85 533.85 -1.31 -0.85 5929395.10 719305.49 GYD-CT-CMS 700.85 0.49 258.43 700.84 633.84 -1.38 -1.53 5929395.01 719304.81 GYD-CT-CMS 800.85 0.54 241.67 800.84 733.84 -1.69 -2.36 5929394.68 719303.99 GYD-CT-CMS 900.85 0.49 244.70 900.84 833.84 -2.10 -3.17 5929394.25 719303.20 GYD-CT-CMS 1000.85 0.40 255.44 1000.83 933.83 -2.37 -3.89 5929393.96 719302.48 GYD-CT-CMS 1100.85 0.32 262.19 1100.83 1033.83 -2.49 -4.50 5929393.81 719301.87 GYD-CT-CMS 1200.85 0.32 243.41 1200.83 1133.83 -2.65 -5.03 5929393.63 719301.35 GYD-CT-CMS 1300.85 0.48 189.88 1300.83 1233.83 -3.19 -5.35 5929393.09 719301.05 GYD-CT-CMS 1400.85 0.49 182.98 1400.82 1333.82 -4.03 -5.45 5929392.25 719300.98 GYD-CT-CMS 1500.85 0.59 200.28 1500.82 1433.82 -4.94 -5.65 5929391.33 719300.80 GYD-CT-CMS 1600.85 0.59 202.36 1600.81 1533.81 -5.90 -6.02 5929390.36 719300.46 GYD-CT-CMS 1700.85 0.62 191.56 1700.81 1633.81 -6.91 -6.33 5929389.35 719300.18 GYD-CT-CMS 1800.85 0.63 168.53 1800.80 1733.80 -7.98 -6.33 5929388.28 719300.21 GYD-CT-CMS 1900.85 0.79 161.04 1900.80 1833.80 -9.17 -5.99 5929387.10 719300.58 GYD-CT-CMS 2000.85 0.96 128.86 2000.78 1933.78 -10.34 -5.12 5929385.95 719301.49 GYD-CT-CMS 2100.85 0.74 132.00 2100.77 2033.77 -11.30 -3.98 5929385.02 719302.65 GYD-CT-CMS 2200.85 1.15 148.52 2200.76 2133.76 -12.59 -2.98 5929383.76 719303.69 GYD-CT-CMS 2300.85 1.24 145.62 2300.74 2233.74 -14.34 -1.84 5929382.05 719304.88 GYD-CT-CMS 2400.85 1.22 147.07 2400.71 2333.71 -16.13 -0.65 5929380.30 719306.12 GYD-CT-CMS 2500.85 1.29 138.01 2500.69 2433.69 -17.86 0.68 5929378.61 719307.50 GYD-CT-CMS 2600.85 1.46 134.52 2600.66 2533.66 -19.59 2.34 5929376.93 719309.21 GYD-CT-CMS Halliburton Company Survey Report ' Company: BP Amoco llate: 3!14/2006 Cime: '10:3920 Nagc: 2 I I Field: Pru dhoe Bay Co-ordinate(;~E) Reference: Weli: 16-14, True North '~ Site: PB DS 16 Vertical (TVD) Reference: 38.5 + 28.5 67.0 Nell: 16- 14 Section (VS) Reference: Well (O.OON,O.OOE,47.33Azi) Wellpath: 16- 14B Survey Calcu lation Method: Minimum Cu rvature Db: Oracle Sur~e~ MD - lncl - Azim -- _ T~'D _ - Sys TVD Iv/S E1W MapN -- MapE 't'oot ft deg deg ft ft ft ft ft ft 2700.85 1.42 135.84 2700.63 2633.63 -21.37 4.11 5929375.20 719311.03 GYD-CT-CMS 2800.85 1.48 139.17 2800.60 2733.60 -23.23 5.82 5929373.38 719312.79 GYD-CT-CMS 2900.85 1.62 141.51 2900.56 2833.56 -25.32 7.54 5929371.35 719314.58 GYD-CT-CMS 3000.85 1.74 143.38 3000.52 2933.52 -27.64 9.33 5929369.08 719316.43 GYD-CT-CMS 3100.85 2.03 147.53 3100.46 3033.46 -30.35 11.18 5929366.42 719318.36 GYD-CT-CMS 3200.85 2.09 149.06 3200.40 3133.40 -33.41 13.07 5929363.42 719320.34 GYD-CT-CMS 3300.85 2.03 152.06 3300.34 3233.34 -36.54 14.84 5929360.34 719322.20 GYD-CT-CMS 3400.85 1.39 150.93 3400.29 3333.29 -39.17 16.26 5929357.76 719323.69 GYD-CT-CMS 3500.85 1.35 148.17 3500.26 3433.26 -41.23 17.47 5929355.73 719324.96 GYD-CT-CMS 3600.85 0.82 158.89 3600.24 3533.24 -42.90 18.35 5929354.09 719325.89 GYD-CT-CMS 3700.85 0.81 159.64 3700.23 3633.23 -44.23 18.85 5929352.78 719326.43 GYD-CT-CMS 3800.85 0.74 164.10 3800.22 3733.22 -45.51 19.27 5929351.51 719326.89 GYD-CT-CMS 3900.85 0.70 151.23 3900.22 3833.22 -46.67 19.75 5929350.36 719327.39 GYD-CT-CMS 4000.85 2.10 20.02 4000.20 3933.20 -45.48 20.67 5929351.58 719328.28 GYD-CT-CMS 4100.85 5.44 7.68 4099.97 4032.97 -39.06 21.93 5929358.03 719329.36 GYD-CT-CMS 4200.85 9.11 1.37 4199.15 4132.15 -26.44 22.75 5929370.66 719329.81 GYD-CT-CMS 4300.85 12.29 7.87 4297.40 4230.40 -7.98 24.40 5929389.17 719330.92 GYD-CT-CMS 4325.85 13.12 11.56 4321.79 4254.79 -2.56 25.33 5929394.61 719331.70 GYD-CT-CMS 4350.85 13.95 13.70 4346.09 4279.09 3.14 26.61 5929400.35 719332.81 GYD-CT-CMS 4375.85 14.73 15.08 4370.31 4303.31 9.14 28.15 5929406.39 719334.18 GYD-CT-CMS 4400.85 15.59 13.36 4394.44 4327.44 15.48 29.76 5929412.77 719335.60 GYD-CT-CMS 4425.85 16.00 11.23 4418.50 4351.50 22.13 31.20 5929419.46 719336.85 GYD-CT-CMS 4450.85 16.78 11.14 4442.48 4375.48 29.05 32.57 5929426.41 719338.02: GYD-CT-CMS 4475.85 17.31 10.84 4466.39 4399.39 36.24 33.97 5929433.64 719339.20 GYD-CT-CMS 4500.85 17.70 11.45 4490.23 4423.23 43.62 35.42 5929441.06 719340.44 GYD-CT-CMS 4525.85 18.35 11.96 4514.00 4447.00 51.19 36.99 5929448.68 719341.79 GYD-CT-CMS 4550.85 18.71 12.32 4537.70 4470.70 58.96 38.66 5929456.49 719343.24 GYD-CT-CMS 4575.85 19.34 12.12 4561.34 4494.34 66.92 40.39 5929464.50 719344.73 GYD-CT-CMS 4600.85 19.80 12.95 4584.89 4517.89 75.10 42.21 5929472.72 719346.31 GYD-CT-CMS 4625.85 20.50 13.90 4608.36 4541.36 83.47 44.21 5929481.15 719348.07 GYD-CT-CMS 4650.85 20.84 13.35 4631.76 4564.76 92.05 46.29 5929489.79 719349.89 GYD-CT-CMS 4675.85 21.67 14.65 4655.05 4588.05 100.84 48.48 5929498.64 719351.83 GYD-CT-CMS 4700.85 22.28 15.19 4678.24 4611.24 109.88 50.89 5929507.74 719353.98 GYD-CT-CMS 4725.85 23.02 16.11 4701.31 4634.31 119.15 53.49 5929517.08 719356.31 GYD-CT-CMS 4750.85 23.96 16.96 4724.24 4657.24 128.70 56.32 5929526.71 719358.86 GYD-CT-CMS 4775.85 24.75 17.54 4747.01 4680.01 138.55 59.38 5929536.64 719361.63 GYD-CT-CMS 4800.85 25.67 18.19 4769.63 4702.63 148.68 62.65 5929546.87 719364.61 GYD-CT-CMS 4825.85 26.38 18.35 4792.10 4725.10 159.10 66.09 5929557.38 719367.74 GYD-CT-CMS 4850.85 27.08 18.96 4814.43 4747.43 169.75 69.69 5929568.13 719371.03 GYD-CT-CMS 4875.85 27.81 19.96 4836.61 4769.61 180.62 73.53 5929579.10 719374.55 GYD-CT-CMS 4900.85 28.84 21.15 4858.62 4791.62 191.72 77.69 5929590.32 719378.39 GYD-CT-CMS 4925.85 29.78 21.20 4880.42 4813.42 203.13 82.11 5929601.86 719382.48 GYD-CT-CMS 4950.85 30.74 22.48 4902.01 4835.01 214.83 86.80 5929613.68 719386.83 GYD-CT-CMS 4975.85 31.49 22.75 4923.41 4856.41 226.75 91.77 5929625.75 719391.45 GYD-CT-CMS 5000.85 31.96 23.51 4944.68 4877.68 238.84 96.93 5929637.98 719396.26 GYD-CT-CMS 5025.85 32.82 23.91 4965.79 4898.79 251.10 102.32 5929650.39 719401.28 GYD-CT-CMS 5050.85 33.10 23.95 4986.77 4919.77 263.53 107.84 5929662.98 719406.44 GYD-CT-CMS 5075.85 33.61 24.63 5007.65 4940.65 276.06 113.49 5929675.66 719411.72 GYD-CT-CMS 5100.85 34.03 25.01 5028.42 4961.42 288.69 119.33 5929688.46 719417.20 GYD-CT-CMS 5125.85 34.28 24.94 5049.11 4982.11 301.42 125.26 5929701.35 719422.75 GYD-CT-CMS 5150.85 34.41 25.23 5069.75 5002.75 314.19 131.24 5929714.29 719428.36 GYD-CT-CMS 5175.85 34.55 25.38 5090.35 5023.35 326.98 137.29 5929727.25 719434.03 GYD-CT-CMS 5200.85 34.86 25.15 5110.91 5043.91 339.86 143.36 5929740.29 719439.73 GYD-CT-CMS Halliburton Company Survey Report Company: BP Amoco Date: 3/14/2006 Time: 10:39 20 Pagr. 3 Field: Pru dhoe Bay Co-ordinate(\'E) Reference: Weil: 1fi-14, True North Site: PB DS 16 Vertical (TVD) Reference: 38.5 + 28.5 67.0 Wcll: 16- 14 Section (VS) Reference: Weil (O.OON,O.OOE,47.33Azi) Wellpath: 16- 14B Survev Calcu lation Method: Minimum Cu rvature Db: Oracle Su rve~~ MD [ncl Azim TVD Sps"I~VD ti/S E/W Map\ MapE "fool ft deg deg ft ft ft ft ft ft 5225.85 34.50 25.00 5131.47 5064.47 352.74 149.39 5929753.35 719445.38 GYD-CT-CMS 5250.85 34.79 25.03 5152.03 5085.03 365.62 155.40 5929766.40 719451.01 GYD-CT-CMS 5275.85 34.48 25.03 5172.60 5105.60 378.49 161.41 5929779.44 719456.65 GYD-CT-CMS 5300.85 34.60 25.29 5193.20 5126.20 391.32 167.44 5929792.44 719462.30 GYD-CT-CMS 5325.85 34.65 25.25 5213.77 5146.77 404.17 173.50 5929805.45 719467.99 GYD-CT-CMS 5350.85 34.63 25.26 5234.34 5167.34 417.02 179.57 5929818.48 719473.67 GYD-CT-CMS 5375.85 34.61 25.28 5254.91 5187.91 429.87 185.63 5929831.49 719479.36 GYD-CT-CMS 5400.85 34.46 25.27 5275.50 5208.50 442.68 191.68 5929844.48 719485.04 GYD-CT-CMS 5425.85 34.09 25.22 5296.16 5229,16 455.42 197.69 5929857.38 719490.67 GYD-CT-CMS 5450.85 34.16 25.60 5316.86 5249,86 468.08 203.70 5929870.21 719496.32 GYD-CT-CMS 5475.85 34.52 25.37 5337.50 5270.50 480.81 209.77 5929883.12 719502.01 GYD-CT-CMS 5500.85 34.25 25.51 5358.13 5291.13 493.56 215.84 5929896.04 719507.70 GYD-CT-CMS 5525.85 33.89 25.55 5378.84 5311.84 506.20 221.87 5929908.84 719513.37 GYD-CT-CMS 5550.85 33.89 25.92 5399.59 5332.59 518.76 227.92 5929921.57 719519.06 GYD-CT-CMS 5575.85 34.06 26.10 5420.33 5353.33 531.31 234.05 5929934.30 719524.82 GYD-CT-CMS 5600.85 34.02 25.79 5441.04 5374.04 543.90 240.17 5929947.05 719530.57 GYD-CT-CMS 5625.85 33.90 25.80 5461.78 5394.78 556.47 246.25 5929959.80 719536.28 . GYD-CT-CMS 5650.85 33.80 25.79 5482.54 5415.54 569.01 252.31 5929972.51 719541.97 GYD-CT-CMS 5675.85 34.02 26.11 5503.29 5436.29 581.55 258.41 5929985.22 719547.71 GYD-CT-CMS 5700.85 34.19 26.03 5523.99 5456.99 594.14 264.57 5929997.98 719553.50 GYD-CT-CMS 5725.85 34.35 26.05 5544.65 5477.65 606.79 270.75 5930010.80 719559.31 GYD-CT-CMS 5750.85 34.64 26.13 5565.25 5498.25 619.51 276.98 5930023.70 719565.16 GYD-CT-CMS 5775.85 34.81 26.13 5585.80 5518.80 632.29 283.25 5930036.66 719571.06 GYD-CT-CMS 5800.85 34.93 26.19 5606.31 5539.31 645.12 289.55 5930049.66 719576.99 GYD-CT-CMS 5825.85 34.95 26.34 5626.81 5559.81 657.96 295.89 5930062.68 719582.95 GYD-CT-CMS 5850.85 34.93 26.25 5647.30 5580.30 670.80 302.23 5930075.69 719588.91 GYD-CT-CMS 5875.85 35.18 26.40 5667.76 5600.76 683.67 308.60 5930088.74 719594.91 GYD-CT-CMS 5900.85 35.31 26.27 5688.18 5621.18 696.60 315.00 5930101.85 719600.93 GYD-CT-CMS 5925.85 35.73 26.53 5708.53 5641.53 709.61 321.46 5930115.04 719607.00 GYD-CT-CMS 5950.85 36.05 26.56 5728.78 5661.78 722.72 328.01 5930128.34 719613.17 GYD-CT-CMS 5975.85 36.32 26.74 5748.96 5681.96 735.91 334.63 5930141.72 719619.40 GYD-CT-CMS 6000.85 36.68 26.83 5769.06 5702.06 749.18 341.33 5930155.18 719625.72 GYD-CT-CMS 6025.85 36.99 27.03 5789.07 5722.07 762.55 348.12 5930168.73 719632.11 GYD-CT-CMS 6050.85 37.19 27.04 5809.01 5742.01 775.98 354.97 5930182.36 719638.57 GYD-CT-CMS 6075.85 37.53 27.50 5828.88 5761.88 789.46 361.92 5930196.04 719645.13 GYD-CT-CMS 6100.85 38.03 27.56 5848.64 5781.64 803.04 369.00 5930209.82 719651.81 GYD-CT-CMS 6125.85 38.37 27.61 5868.28 5801.28 816.74 376.16 5930223.72 719658.57 GYD-CT-CMS 6150.85 38.66 27.71 5887.85 5820.85 830.53 383.39 5930237.71 719665.39 GYD-CT-CMS 6175.85 38.58 27.86 5907.38 5840.38 844.34 390.66 5930251.72 719672.26 GYD-CT-CMS 6200.85 38.79 27.98 5926.89 5859.89 858.14 397.98 5930265.74 719679.17 GYD-CT-CMS 6225.85 38.95 28.04 5946.36 5879.36 872.00 405.35 5930279.79 719686.14 GYD-CT-CMS 6250.85 39.25 28.06 5965.76 5898.76 885.91 412.76 5930293.92 719693.14 GYD-CT-CMS 6275.85 39.48 28.12 5985.09 5918.09 899.90 420.23 5930308.12 719700.20 GYD-CT-CMS 6300.85 39.52 28.33 6004.38 5937.38 913.91 427.75 5930322.34 719707.31 GYD-CT-CMS 6325.85 39.74 28.37 6023.63 5956.63 927.94 435.32 5930336.59 719714.47 GYD-CT-CMS 6350.85 39.99 28.31 6042.82 5975.82 942.05 442.93 5930350.90 719721.66 GYD-CT-CMS 6375.85 40.45 28.64 6061.91 5994.91 956.24 450.62 5930365.31 719728.95 GYD-CT-CMS 6400.85 40.62 28.89 6080.91 6013.91 970.48 458.44 5930379.77 719736.35 GYD-CT-CMS 6425.85 40.99 28.95 6099.83 6032.83 984.78 466.34 5930394.30 719743.83 GYD-CT-CMS 6450.85 41.33 29.04 6118.66. 6051.66 999.17 474.32 5930408.91 719751.38 GYD-CT-CMS 6475.85 41.41 29.31 6137.42 6070.42 1013.60 482.37 5930423.57 719759.01 GYD-CT-CMS 6500.85 41.50 29.55 6156.15 6089.15 1028.01 490.50 5930438.21 719766.72 GYD-CT-CMS Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 16 Well: 16-14 Wellpath: 16-14B Surccv llate: 3/14/2006 Co-ordinate(NE) Refere~cc: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Time: 10:39:20 Page: 4 ~ Well: 16-14, True North 38.5 + 28.5 67.0 Well (O.OON,O.OOE,47.33Azi) Minimum Curvature Db: Oracle MU Incl - Azim - TVD Sys "IVD N/S -- E/W Mapi~ MapE - ~ Tool ft deg deg ft ft ft ft ft ft 6525.85 41.71 29.89 6174.85 6107.85 1042.43 498.73 5930452.86 719774.53 GYD-CT-CMS 6550.85 41.94 29.89 6193.48 6126.48 1056.88 507.04 5930467.55 719782.42 GYD-CT-CMS 6575.85 42.33 29.94 6212.02 6145.02 1071.42 515.41 5930482.32 719790.35 GYD-CT-CMS 6600.85 42.55 29.99 6230.47 6163.47 1086.04 523.83 5930497.18 719798.35 GYD-CT-CMS 6625.85 42.49 30.14 6248.89 6181.89 1100.66 532.30 5930512.04 719806.39 GYD-CT-CMS 6650.85 42.72 30.01 6267.29 6200.29 1115.30 540.78 5930526.92 719814.44 GYD-CT-CMS 6675.85 42.77 30.02 6285.65 6218.65 1130.00 549.27 5930541.85 719822.50 GYD-CT-CMS 6700.85 42.78 29.33 6304.00 6237.00 1144.75 557.67 5930556.84 719830.47 GYD-CT-CMS 6725.85 42.27 27.57 6322.43 6255.43 1159.60 565.72 5930571.92 719838.09 GYD-CT-CMS 6750.85 41.99 25.45 6340.97 6273.97 1174.61 573.21 5930587.14 719845.13 GYD-CT-CMS 6775.85 41.86 23.93 6359.57 6292.57 1189.78 580.19 5930602.51 719851.67 GYD-CT-CMS 6800.85 41.69 22.79 6378.22 6311.22 1205.07 586.79 5930617.99 719857.82 GYD-CT-CMS 6825.85 41.69 22.45 6396.88 6329.88 1220.42 593.18 5930633.51 719863.77 GYD-CT-CMS 6850.85 41.66 22.46 6415.56 6348.56 1235.78 599.53 5930649.05 719869.67 GYD-CT-CMS 6875.85 41.72 22.49 6434.23 6367.23 1251.15 605.89 5930664.59 719875.58 GYD-CT-CMS 6900.85 41.64 22.47 6452.90 6385.90 1266.51 612.25 5930680.13 719881.48 GYD-CT-CMS 6925.85 41.58 22.43 6471.59 6404.59 1281.85 618.59 5930695.65 719887.37 GYD-CT-CMS 6950.85 41.58 22.34 6490.29 6423.29 1297.19 624.90 5930711.17 719893.24 GYD-CT-CMS 6975.85 41.51 22.22 6509.00 6442.00 1312.54 631.19 5930726.69 719899.08 GYD-CT-CMS 7000.85 41.51 22.18 6527.72 6460.72 1327.88 637.45 5930742.20 719904.89 GYD-CT-CMS 7025.85 41.20 22.08 6546.49 6479.49 1343.18 643.67 5930757.68 719910.67 GYD-CT-CMS 7050.85 41.26 22.08 6565.29 6498.29 1358.45 649.87 5930773.12 719916.42 GYD-CT-CMS 7075.85 41.51 22.06 6584.05 6517.05 1373.76 656.08 5930788.61 719922.18 GYD-CT-CMS 7100.85 41.52 22.02 6602.77 6535.77 1389.12 662.30 5930804.14 719927.95 GYD-CT-CMS 7125.85 41.33 21.97 6621.51 6554.51 1404.46 668.49 5930819.65 719933.70 GYD-CT-CMS 7150.85 40.97 21.81 6640.34 6573.34 1419.73 674.62 5930835.09 719939.38 GYD-CT-CMS 7175.85 40.76 21.76 6659.24 6592.24 1434.91 680.69 5930850.45 719945.01 GYD-CT-CMS 7200.85 40.77 21.88 6678.18 6611.18 1450.07 686.76 5930865.77 719950.63 GYD-CT-CMS 7225.85 40.80 21.80 6697.11 6630.11 1465.23 692.84 5930881.10 719956.27 GYD-CT-CMS 7250.85 40.91 21.74 6716.02 6649.02 1480.41 698.90 5930896.45 719961.89 GYD-CT-CMS 7275.85 40.99 21.71 6734.90 6667.90 1495.64 704.97 5930911.84 719967.51 GYD-CT-CMS 7300.85 40.78 21.60 6753.80 6686.80 1510.84 711.01 5930927.22 719973.10 GYD-CT-CMS 7325.85 40.65 21.50 6772.75 6705.75 1526.01 717.00 5930942.55 719978.65 GYD-CT-CMS 7350.85 40.79 21.49 6791.70 6724.70 1541.19 722.97 5930957.90 719984.18 GYD-CT-CMS 7375.85 40.50 21.41 6810.66 6743.66 1556.34 728.93 5930973.22 719989.69 GYD-CT-CMS 7400.85 40.57 21.40 6829.67 6762.67 1571.47 734.86 5930988.51 719995.18 GYD-CT-CMS 7425.85 40.34 21.40 6848.69 6781.69 1586.57 740.78 5931003.78 720000.66 GYD-CT-CMS 7450.85 40.27 21.36 6867.75 6800.75 1601.63 746.67 5931019.00 720006.11 GYD-CT-CMS 7475.85 40.33 21.22 6886.82 6819.82 1616.70 752.54 5931034.23 720011.54 GYD-CT-CMS 7500.85 40.10 21.20 6905.91 6838.91 1631.75 758.38 5931049.44 720016.94 GYD-CT-CMS 7525.85 40.15 21.19 6925.03 6858.03 1646.77 764.21 5931064.62 720022.33 GYD-CT-CMS 7550.85 40.08 21.07 6944.15 6877.15 1661.79 770.01 5931079.81 720027.70 GYD-CT-CMS 7575.85 39.90 20.88 6963.30 6896.30 1676.79 775.76 5931094.97 720033.01 GYD-CT-CMS 7600.85 40.05 20.88 6982.46 6915.46 1691.80 781.49 5931110.14 720038.30 GYD-CT-CMS 7625.85 40.01 20.86 7001.60 6934.60 1706.83 787.22 5931125.32 720043.59 GYD-CT-CMS 7650.85 39.69 20.75 7020.79 6953.79 1721.80 792.91 5931140.46 720048.84 GYD-CT-CMS 7675.85 39.77 20.70 7040.02 6973.02 1736.75 798.56 5931155.56 720054.06 GYD-CT-CMS 7700.85 39.67 20.63 7059.25 6992.25 1751.69 804.20 5931170.66 720059.26 GYD-CT-CMS 7725.85 39.66 20.62 7078.49 7011.49 1766.63 809.82 5931185.75 720064.44 GYD-CT-CMS 7750.85 39.32 20.62 7097.79 7030.79 1781.51 815.42 5931200.79 720069.61 GYD-CT-CMS 7775.85 39.20 20.49 7117.14 7050.14 1796.32 820.97 5931215.76 720074.73 GYD-CT-CMS 7800.85 39.19 20.46 7136.52 7069.52 1811.12 826.50 5931230.71 720079.82 GYD-CT-CMS 7825.85 39.00 20.36 7155.92 7088.92 1825.90 832.00 5931245.64 720084.89 GYD-CT-CMS Halliburton Company Survey Report C Company: BP Amoco Field: Prudhoe Bay I Site: PB DS 16 ~ Well: 16-14 t Wellpath: 16-14B Sunev _ MD Inc! ft deg _- Azim deg D ft sTVU ft S ft Date: 3!14/2006 Time: 10:39:20 Page: 5 ~ Co-ordinate(NE) Reference: WeII: 16-14, True North Vertical (TVD) Reference: 38.5 + 28.5 67.0 Section (VS) Reference: Well (O.OON,O.OOE,47.33Azi) Survey Calculation Method: Minimum Curvature Db: Oracle -_ _ E/W Maps MapE Tool ft ft ft 7850.85 39.02 20.30 7175.35 7108.35 1840.65 837.47 5931260.55 720089.92 GYD-CT-CMS 7875.85 38.91 20.24 7194.79 7127.79 1855.40 842.91 5931275.45 720094.94 GYD-CT-CMS 7900.85 38.54 20.22 7214.29 7147.29 1870.08 848.32 5931290.27 720099.92 GYD-CT-CMS 7925.85 38.50 20.27 7233.85 7166.85 1884.68 853.71 5931305.03 720104.88. GYD-CT-CMS 7950.85 38.43 20.24 7253.42 7186.42 1899.27 859.09 5931319.77 720109.84 GYD-CT-CMS 7975.85 38.51 20.25 7273.00 7206.00 1913.87 864.47 5931334.51 720114.79 GYD-CT-CMS 8000.85 38.20 20.22 7292.60 7225.60 1928.42 869.84 5931349.22 720119.73 GYD-CT-CMS 8025.85 38.06 20.30 7312.27 7245.27 1942.90 875.18 5931363.84 720124.66 GYD-CT-CMS 8050.85 37.99 20.28 7331.96 7264.96 1957.35 880.53 5931378.44 720129.57 GYD-CT-CMS 8075.85 37.78 20.24 7351.69 7284.69 1971.75 885.84 5931392.99 720134.47 GYD-CT-CMS 8100.85 37.78 20.31 7371.45 7304.45 1986.12 891.15 5931407.50 720139.36 GYD-CT-CMS 8125.85 37.68 20.29 7391.22 7324.22 2000.46 896.46 5931422.00 720144.25 GYD-CT-CMS 8150.85 37.54 20.28 7411.03 7344.03 2014.78 901.75 5931436.46 720149.12 GYD-CT-CMS 8175.85 37.41 20.25 7430.87 7363.87 2029.04 907.01 5931450.87 720153.97 GYD-CT-CMS 8200.85 37.29 20.21 7450.74 7383.74 2043.28 912.26 5931465.25 720158.80 GYD-CT-CMS 8225.85 37.26 20.20 7470.64 7403.64 2057.48 917.49 5931479.60 720163.61 GYD-CT-CMS 8250.85 37.15 20.29 7490.55 7423.55 2071.67 922.72 5931493.93 720168.43 GYD-CT-CMS 8275.85 36.86 20.29 7510.51 7443.51 2085.78 927.94 5931508.19 720173.23 GYD-CT-CMS 8300.85 36.78 20.27 7530.53 7463.53 2099.83 933.13 5931522.39 720178.02 GYD-CT-CMS 8325.85 36.72 20.35 7550.56 7483.56 2113.86 938.32 5931536.56 720182.80 GYD-CT-CMS 8350.85 36.60 20.42 7570.61 7503.61 2127.85 943.52 5931550.70 720187.59 GYD-CT-CMS 8375.85 36.58 20.42 7590.68 7523.68 2141.82 948.72 5931564.81 720192.38 GYD-CT-CMS 8400.85 36.36 20.47 7610.79 7543.79 2155.74 953.91 5931578.87 720197.16 GYD-CT-CMS 8425.85 36.24 20.42 7630.94 7563.94 2169.61 959.08 5931592.89 720201.93 GYD-CT-CMS 8450.85 35.97 20.30 7651.14 7584.14 2183.42 964.21 5931606.84 720206.65. GYD-CT-CMS 8475.85 35.86 20.30 7671.38 7604.38 2197.18 969.29 5931620.73 720211.34 GYD-CT-CMS 8500.85 35.69 20.32 7691.67 7624.67 2210.88 974.37 5931634.58 720216.01 GYD-CT-CMS 8525.85 35.49 20.25 7712.00 7645.00 2224.53 979.41 5931648.37 720220.66 GYD-CT-CMS 8550.85 35.43 20.29 7732.36 7665.36 2238.14 984.44 5931662.11 720225.28 GYD-CT-CMS 8575.85 35.19 20.18 7752.76 7685.76 2251.69 989.43 5931675.81 720229.88 GYD-CT-CMS 8600.85 35.07 20.12 7773.21 7706.21 2265.20 994.39 5931689.45 720234.45 GYD-CT-CMS 8625.85 34.89 20.08 7793.69 7726.69 2278.66 999.31 5931703.05 720238.98 GYD-CT-CMS 8650.85 34.65 20.06 7814.23 7747.23 2292.05 1004.21 5931716.58 720243.48 GYD-CT-CMS 8675.85 34.60 20.13 7834.80 7767.80 2305.39 1009.09 5931730.05 720247.97 GYD-CT-CMS 8700.85 34.38 20.20 7855.40 7788.40 2318.68 1013.97 5931743.48 720252.46 GYD-CT-CMS 8725.85 34.28 20.08 7876.05 7809.05 2331.92 1018.82 5931756.85 720256.93 GYD-CT-CMS 8750.85 34.26 20.22 7896.71 7829.71 2345.13 1023.67 5931770.20 720261.39 GYD-CT-CMS 8775.85 33.96 20.34 7917.41 7850.41 2358.28 1028.53 5931783.48 720265.87 GYD-CT-CMS 8800.85 33.64 20.37 7938.18 7871.18 2371.32 1033.37 5931796.66 720270.32 GYD-CT-CMS 8825.85 33.73 20.33 7958.98 7891.98 2384.32 1038.19 5931809.79 720274.77 GYD-CT-CMS 8850.85 33.47 20.44 7979.81 7912.81 2397.29 1043.01 5931822.89 720279.21 GYD-CT-CMS 8875.85 33.38 20.51 8000.67 7933.67 2410.19 1047.83 5931835.93 720283.65 GYD-CT-CMS 8900.85 33.23 20.59 8021.57 7954.57 2423.05 1052.65 5931848.92 720288.09 GYD-CT-CMS 8925.85 33.05 20.87 8042.50 7975.50 2435.83 1057.48 5931861.83 720292.55 GYD-CT-CMS 8950.85 34.01 21.17 8063.34 7996.34 2448.72 1062.44 5931874.86 720297.13 GYD-CT-CMS 8975.85 35.10 21.46 8083.93 8016.93 2461.93 1067.59 5931888.21 720301.90 GYD-CT-CMS 9000.85 36.62 21.14 8104.19 8037.19 2475.57 1072.91 5931902.01 720306.82 GYD-CT-CMS 9025.85 38.45 20.71 8124.01 8057.01 2489.80 1078.35 5931916.38 720311.84 GYD-CT-CMS 9050.85 39.67 20.39 8143.43 8076.43 2504.55 1083.88 5931931.29 720316.94 GYD-CT-CMS 9075.85 39.78 20.13 8162.65 8095.65 2519.54 1089.41 5931946.43 720322.04 GYD-CT-CMS 9100.85 39.69 19.92 8181.88 8114.88 2534.55 1094.88 5931961.60 720327.07 GYD-CT-CMS 9125.85 39.06 19.95 8201.20 8134.20 2549.46 1100.29 5931976.66 720332.04 GYD-CT-CMS Halliburton Company i Survey Report Company: BP Amoco Date: 3/14/2006 Time: 1039:20 Page: 6 Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: 6-14, True North Site: PB I DS 16 Vertical ('fVD) Reference: 38.5 + 28.5 67.0 Well: 16- 14 Section (VS) Reference: Well (O.OON,O.OOE,47.33Azi) j Wellpath: 16- 14B Survey Calcu lation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim "fVD SysTVD N/S E/W MapN MapE 'Ibol ft deg deg ft ft ft ft ft ft ~ 9150.85 38.05 20.00 8220.75 8153.75 2564.11 1105.61 5931991.45 720336.94 GYD-CT-CMS 9175.85 37.40 19.89 8240.53 8173.53 2578.49 1110.83 5932005.97 720341.73 GYD-CT-CMS 9200.85 36.93 19.06 8260.45 8193.45 2592.72 1115.87 5932020.35 720346.35 GYD-CT-CMS 9225.85 36.49 18.31 8280.49 8213.49 2606.88 1120.65 5932034.64 720350.73 GYD-CT-CMS 9250.85 35.86 18.16 8300.67 8233.67 2620.89 1125.27 5932048.78 720354.94 GYD-CT-CMS 9275.85 35.53 17.90 8320.98 8253.98 2634.77 1129.79 5932062.78 720359.05 GYD-CT-CMS 9300.85 34.96 17.46 8341.39 8274.39 2648.51 1134.17 5932076.64 720363.03 GYD-CT-CMS 9325.85 34.71 16.62 8361.91 8294.91 2662.16 1138.35 5932090.41 720366.81 GYD-CT-CMS 9350.85 34.64 15.73 8382.47 8315.47 2675.82 1142.32 5932104.18 720370.38 GYD-CT-CMS 9375.85 34.27 14.95 8403.09 8336.09 2689.46 1146.06 5932117.92 720373.72 GYD-CT-CMS 9400.85 35.06 13.72 8423.65 8356.65 2703.24 1149.58 5932131.79 720376.84 GYD-CT-CMS 9425.85 36.01 12.82 8443.99 8376.99 2717.38 1152.91 5932146.03 720379.76 GYD-CT-CMS 9450.85 35.60 12.55 8464.27 8397.27 2731.65 1156.12 5932160.38 720382.56 GYD-CT-CMS 9475.85 34.42 12.61 8484.75 8417.75 2745.65 1159.25 5932174.46 720385.27 GYD-CT-CMS 9480.85 34.41 12.47 8488.87 8421.87 2748.41 1159.86 5932177.24 720385.81 GYD-CT-CMS 9542.17 35.84 12.60 8539.02 8472.02 2782.85 1167.52 5932211.89 720392.46 MWD 9574.34 36.73 13.30 8564.95 8497.95 2801.40 1171.79 5932230.55 720396.19 MWD 9606.10 36.74 13.70 8590.41 8523.41 2819.87 1176.22 5932249.14 720400.08 MWD 9637.73 37.30 14.50 8615.66 8548.66 2838.34 1180.86 5932267.74 720404.18 MWD 9669.69 36.52 14.90 8641.22 8574.22 2856.91 1185.73 5932286.44 720408.51 MWD 9733.76 36.77 16.20 8692.62 8625.62 2893.74 1195.98 5932323.56 720417.69 MWD 9791.69 37.63 15.50 8738.77 8671.77 2927.44 1205.55 5932357.51 720426.27 MWD 9859.21 40.41 13.60 8791.22 8724.22 2968.58 1216.20 5932398.95 720435.73 MWD 9892.17 40.08 14.70 8816.38 8749.38 2989.23 1221.41 5932419.74 720440.33 MWD 9916.00 40.74 13.81 8834.52 8767.52 3004.20 1225.21 5932434.81 720443.70 MWD+IFR+MS 9940.29 42.11 14.73 8852.74 8785.74 3019.77 1229.17 5932450.49 720447.21 MWD+IFR+MS 9973.01 46.62 15.84 8876.12 8809.12 3041.83 1235.21 5932472.72 720452.60 MWD+IFR+MS 10004.05 49.66 16.79 8896.83 8829.83 3064.02 1241.71 5932495.08 720458.45 MWD+IFR+MS 10033.55 52.71 17.60 8915.32 8848.32 3085.97 1248.51 5932517.22 720464.61 MWD+IFR+MS 10064.47 55.57 18.39 8933.43 8866.43 3109.80 1256.25 5932541.26 720471.66 MWD+IFR+MS 10095.60 60.39 19.12 8949.93 8882.93 3134.78 1264.74 5932566.48 720479.42 MWD+IFR+MS 10127.32 63.59 19.82 8964.83 8897.83 3161.18 1274.07 5932593.14 720487.98 MWD+IFR+MS 10159.91 66.84 20.49 8978.49 8911.49 3188.96 1284.27 5932621.19 720497.36 MWD+IFR+MS 10188.64 69.76 19.20 8989.11 8922.11 3214.06 1293.33 5932646.55 720505.69 MWD+IFR+MS 10220.74 75.37 22.15 8998.73 8931.73 3242.69 1304.15 5932675.49 720515.67 MWD+IFR+MS 10251.81 77.63 23.62 9005.98 8938.98 3270.52 1315.89 5932703.65 720526.61 MWD+IFR+MS 10284.33 77.36 23.06 9013.02 8946.02 3299.68 1328.47 5932733.15 720538.33 MWD+IFR+MS 10314.46 77.23 22.71 9019.65 8952.65 3326.75 1339.90 5932760.55 720548.97 MWD+IFR+MS 10347.08 77.06 22.52 9026.91 8959.91 3356.11 1352.13 5932790.24 720560.34 MWD+IFR+MS 10377.00 76.73 21.90 9033.69 8966.69 3383.09 1363.15 5932817.53 720570.57 MWD+IFR+MS 10408.23 77.42 23.66 9040.68 8973.68 3411.15 1374.93 5932845.92 720581.53 MWD+IFR+MS 10440.05 79.88 27.42 9046.94 8979.94 3439.29 1388.38 5932874.44 720594.16 MWD+IFR+MS 10470.55 82.18 29.48 9051.70 8984.70 3465.78 1402.74 5932901.33 720607.74 MWD+IFR+MS 10501.89 84.73 32.29 9055.27 8988.27 3492.49 1418.72 5932928.49 720622.93 MWD+IFR+MS 10533.35 86.52 34.99 9057.67 8990.67 3518.60 1436.09 5932955.10 720639.54 MWD+IFR+MS 10564.76 87.38 36.14 9059.34 8992.34 3544.12 1454.34 5932981.13 720657.04 MWD+IFR+MS 10596.05 87.32 35.88 9060.79 8993.79 3569.40 1472.71 5933006.93 720674.67 MWD+IFR+MS 10640.95 88.33 37.17 9062.49 8995.49 3605.45 1499.42 5933043.75 720700.31 MWD+IFR+MS 10690.49 90.74 38.61 9062.89 8995.89 3644.55 1529.84 5933083.70 720729.59 MWD+IFR+MS 10735.52 90.79 37.64 9062.29 8995.29 3679.97 1557.63 5933119.91 720756.34 MWD+IFR+MS 10783.60 90.37 38.73 9061.80 8994.80 3717.75 1587.36 5933158.55 720784.95 MWD+IFR+MS 10874.94 91.36 39.10 9060.43 8993.43 3788.82 1644.72 5933231.24 720840.23 MWD+IFR+MS 10970.10 91.20 40.77 9058.30 8991.30 3861.76 1705.79 5933305.93 720899.15 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 16 ~I Well: 16-14 I Wellpath: 16-14B Sun'cv llate: 3/14/2006 Co-ordinate(NE) Refcrencr. Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: Time: 10:39:20 Page: 7 Well: 16-14, True North 38.5 + 28.5 67.0 Well (O.OON,O.OOE,47.33Azi) Minimum Curvature Db: Oracle - MU incl Azim TVD Sys "fVU IY/S E/H' Map\ MapE "1'001 i ft deg deg ft ft fit ft ft ft 11064.25 91.77 41.67 9055.86 8988.86 3932.55 1767.81 5933378.49 720959.09 MWD+IFR+MS 11156.19 91.65 41.26 9053.12 8986.12 4001.42 1828.66 5933449.09 721017.91 MWD+IFR+MS 11203.28 90.53 41.10 9052.22 8985.22 4036.85 1859.66 5933485.41 721047.86 MWD+IFR+MS 11248.67 90.09 40.51 9051.98 8984.98 4071.21 1889.32 5933520.61 721076.51 MWD+IFR+MS 11298.06 90.33 41.15 9051.79 8984.79 4108.58 1921.61 5933558.90 721107.71 MWD+IFR+MS 11342.03 90.48 41.09 9051.48 8984.48 4141.71 1950.53 5933592.85 721135.65 MWD+IFR+MS 11436.98 90.95 39.19 9050.30 8983.30 4214.28 2011.73 5933667.17 721194.71 MWD+IFR+MS 11530.02 90.96 39.44 9048.75 8981.75 4286.26 2070.67 5933740.82 721251.53 MWD+IFR+MS 11623.63 89.12 40.03 9048.68 8981.68 4358.24 2130.51 5933814.51 721309.25 MWD+IFR+MS 11717.41 88.24 39.29 9050.84 8983.84 4430.41 2190.35 5933888.39 721366.96 MWD+IFR+MS 11810.42 89.91 39.13 9052.34 8985.34 4502.47 2249.13 5933962.12 721423.63 MWD+IFR+MS 11904.28 89.68 40.98 9052.68 8985.68 4574.31 2309.53 5934035.68 721481.92 MWD+IFR+MS 11997.75 90.83 40.41 9052.26 8985.26 4645.17 2370.48 5934108.28 721540.77 MWD+IFR+MS 12090.71 91.59 41.13 9050.30 8983.30 4715.56 2431.17 5934180.39 721599.39 MWD+IFR+MS 12183.17 92.18 40.76 9047.26 8980.26 4785.36 2491.73 5934251.92 721657.90 MWD+IFR+MS 12277.84 91.57 41.46 9044.16 8977.16 4856.65 2553.94 5934324.98 721718.01 MWD+IFR+MS 12326.72 92.13 42.21 9042.58 8975.58 4893.05 2586.52 5934362.31 721749.52. MWD+IFR+MS 12371.61 91.75 45.14 9041.06 8974.06 4925.50 2617.50 5934395.64 721779.54 MWD+IFR+MS 12421.13 90.64 46.88 9040.03 8973.03 4959.88 2653.12 5934431.04 721814.15 MWD+IFR+MS 12464.78 90.53 49.85 9039.59 8972.59 4988.87 2685.74 5934460.97 721845.91 MWD+IFR+MS 12512.36 90.03 52.22 9039.35 8972.35 5018.79 2722.73 5934491.95 721882.01 MWD+IFR+MS 12559.66 89.22 53.74 9039.66 8972.66 5047.27 2760.49 5934521.51 721918.93 MWD+IFR+MS 12610.25 89.41 56.16 9040.27 8973.27 5076.32 2801.90 5934551.75 721959.48 MWD+IFR+MS 12652.25 89.67 58.88 9040.60 8973.60 5098.87 2837.33 5934575.32 721994.23 MWD+IFR+MS 12683.33 90.21 61.64 9040.64 8973.64 5114.29 2864.31 5934591.51 722020.76. MWD+IFR+MS 12716.41 90.03 63.57 9040.57 8973.57 5129.51 2893.68 5934607.58 722049.67 MWD+IFR+MS 12744.28 89.05 66.17 9040.79 8973.79 5141.34 2918.91 5934620.14 722074.54 MWD+IFR+MS 12775.91 88.43 68.85 9041.49 8974.49 5153.44 2948.12 5934633.08 722103.39 MWD+IFR+MS 12806.48 88.55 71.26 9042.29 8975.29 5163.86 2976.85 5934644.33 722131.80 MWD+IFR+MS 12836.05 89.22 73.64 9042.87 8975.87 5172.77 3005.03 5934654.06 722159.71 MWD+IFR+MS 12868.90 90.34 76.18 9042.99 8975.99 5181.32 3036.75 5934663.53 722191.16 MWD+IFR+MS 12899.90 90.76 77.96 9042.70 8975.70 5188.26 3066.96 5934671.34 722221.16 MWD+IFR+MS 12929.40 90.76 80.21 9042.31 8975.31 5193.85 3095.92 5934677.76 722249.95 MWD+IFR+MS 12962.05 91.63 81.98 9041.62 8974.62 5198.90 3128.17 5934683.75 722282.03 MWD+IFR+MS 12994.91 91.88 84.60 9040.62 8973.62 5202.74 3160.79 5934688.53 722314.52 MWD+IFR+MS 13025.50 92.25 86.51 9039.52 8972.52 5205.11 3191.26 5934691.78 722344.92 MWD+IFR+MS 13057.61 92.12 87.75 9038.29 8971.29 5206.71 3223.31 5934694.32 722376.90 MWD+IFR+MS 13089.28 92.32 89.36 9037.06 8970.06 5207.51 3254.94 5934696.04 722408.50 MWD+IFR+MS 13118.30 92.37 89.24 9035.88 8968.88 5207.86 3283.94 5934697.23 722437.47 MWD+IFR+MS 13152.60 92.25 90.58 9034.49 8967.49 5207.92 3318.21 5934698.28 722471.72 MWD+IFR+MS 13212.94 91.82 93.87 9032.35 8965.35 5205.58 3378.46 5934697.69 722532.01 MWD+IFR+MS 13258.86 91.95 93.86 9030.84 8963.84 5202.48 3424.25 5934695.93 722577.87 MWD+IFR+MS 13306.81 92.39 92.76 9029.03 8962.03 5199.72 3472.08 5934694.55 722625.76 MWD+IFR+MS 13355.75 92.50 92.44 9026.94 8959.94 5197.50 3520.93 5934693.75 722674.65 MWD+IFR+MS 13400.65 92.38 92.25 9025.03 8958.03 5195.66 3565.75 5934693.22 722719.50 MWD+IFR+MS 13446.58 92.25 92.12 9023.17 8956.17 5193.91 3611.61 5934692.80 722765.39 MWD+IFR+MS 13492.48 92.01 92.91 9021.46 8954.46 5191.90 3657.43 5934692.12 722811.25 MWD+IFR+MS 13540.57 91.32 92.47 9020.07 8953.07 5189.64 3705.45 5934691.26 722859.31 MWD+IFR+MS 13584.51 90.89 92.57 9019.22 8952.22 5187.71 3749.34 5934690.61 722903.23 MWD+IFR+MS 13634.28 90.70 93.19 9018.53 8951.53 5185.21 3799.04 5934689.55 722952.99 MWD+IFR+MS 13678.40 91.01 93.01 9017.87 8950.87 5182.83 3843.09 5934688.44 722997.09 MWD+IFR+MS 13772.40 91.09 92.64 9016.15 8949.15 5178.20 3936.96 5934686.54 723091.05 MWD+IFR+MS Halliburton Company Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 16 ~Vcll: 16-14 W'ellpath: 16-14B Survev 1~ID lncl Azim TVD Sys TVD ft deg deg ft ft 13865.02 91.27 92.06 9014.24 8947.24 13958.66 91.82 94.15 9011.72 8944.72 14052.92 90.54 93.48 9009.78 8942.78 14146.47 91.02 95.15 9008.50 8941.50 14240.39 91.02 95.66 9006.83 8939.83 14333.77 91.15 95.09 9005.06 8938.06 14427.96 91.07 96.09 9003.24 8936.24 14522.00 91.08 94.52 9001.47 8934.47 14614.48 91.33 94.94 8999.53 8932.53 14707.50 91.57 96.88 8997.17 8930.17 14801.07 90.71 95.41 8995.31 8928.31 14$94.95 90.54 96.33 8994.29 8927.29 14988.42 90.70 96.81 8993.28 8926.28 15082.94 90.60 95.87 8992.20 8925.20 15176.31 90.53 96.39 8991.28 8924.28 15270.30 90.58 96.97 8990.37 8923.37 15307.00 90.58 96.97 8990.00 8923.00 \/S ft 5174.40 5169.33 5163.06 5156.02 5147.18 5138.43 5129.26 5120.56 5112.94 5103.37 5093.35 5083.75 5073.06 5062.62 5052.65 5041.72 5037.26 Date: 3/14/2006 Time: 10:39.20 Pagc: R Co-ordinate(NE) Reference: Well: 1fi-14, True North Vertical (TVD) Reference: 38.5 + 28.5 67.0 Section (VS) Reference: Well (O.OON,O.OOE,47.33Azi) Survev Calculation Method: Minimum Curvature Dh: Oracle E/N' ft 4029.48 4122.94 4216.97 4310.25 4403.73 4496.68 4590.41 4684.03 4776.17 4868.66 4961.67 5055.05 5147.90 5241.84 5334.67 5428.02 5464.44 M1IapV ft 5934685.43 5934683.08 5934679.54 5934675.22 5934669.09 5934663.05 5934656.60 5934650.63 5934645.69 5934638.80 5934631.49 5934624.61 5934616.62 5934608.91 5934601.64 5934593.43 5934590.03 MapE Toot ft 723183.64 MWD+IFR+MS 723277.20 MWD+IFR+MS 723371.37 MWD+IFR+MS 723464.80 MWD+IFR+MS 723558.50 MWD+IFR+MS 723651.67 MWD+IFR+MS 723745.61 MWD+IFR+MS 723839.44 MWD+IFR+MS 723931.76 MWD+IFR+MS 724024.49 MWD+IFR+MS 724117.74 MWD+IFR+MS 724211.36 MWD+IFR+MS 724304.48 MWD+IFR+MS 724398.67 MWD+IFR+MS 724491.75 MWD+IFR+MS 724585.37 MWD+IFR+MS 724621.91 PROJECTED TREE = 4-1116" CMJ WELLHE~AD= VETCOGRAY ACTUATOR= BAKER KB. ELEV = __ BF. ELEV..- _ 66.15' 40.43 KOP = 4200' Max Angle = 93 @ 13355' Datum MD = Datum TV D = 9960' -_--- 8800' SS -14 B A 210106 POSS BLE SOLIDS IN TOP OF LNR DUETO MILLINGON RIG 93' ~-I4-1/2" HES X NIP, ID = 3.813" 13-318" CSG, 72#, L-80, ID = 12.347" 2675' 8773' ~-~ 9-518" X 7" BKR PKR &HNGR, ID = 6.25" Minimum ID = 3.725" @ 9793' 4-1/2" HES XN NIPPLE 9644' 4-112" HES X NIP, ID = 3.813" 9665' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9689' 4-1/2" HES X NIP, ID = 3.813" 9793' 4-1/2" HES XN NIP, ID = 3.725" 9795' 7" X 5" BKR ZXP LNR TOP PKR w! 9-5/8" CSG, 47#, N-80, ID = 8.681" 9772' TIEBACK SLV, ID = 5.25" 9805' 4-112" WLEG, ID = 3.958" ELMD TT NOT LOGGED 4-112" TBG 12.6#, L-80 TCII, .0152 bpf, ID = 3.958 9805' 9815' 7" x 5" BKR FLEX-LOC, LNR HNGR w /5" RS PACKOFF NIP, ID = 4.250" WHIPSTOCK (02/14/06) 9921' J827' 5" X 4-112" XO, ID = 3.950" ~ ESZV (02114/06) ~ 4-1/2" TBG, 12.6#, 13-CR ID = 3.958" ~ 9978' 7" LNR, 26#, L-80, ID = 6.276" 10444' 4-112" LNR, 12.6#, L-80, ID = 3.958" 15175' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 91 @ 15000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 15000 - 15100 O 05!19!06 MILLOUT WINDOW {16-14B) 9916' - 9921' PBTD -~ 15221' 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 15307' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/09!81 ORIGINAL COMPLETION 04113/98 SIDETRACK (16-14A) 03/10/06 N2ES SIDETRACK(16-14B) 03/21/06 RWL/TLH DRLG DRAFT CORRECTIONS 05/19106 DMSIPJC PERFORATION PRUDHOE BAY UNfT' WELL: 16-146 PERMf-f No: x2060030 API No: 50-029-20570-02 SEC 24, T10N, R15E, 1534' SNL & 527' EWL BP Exploration {Alaska) • • 13-Apr-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 16-14B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,892.17' MD Window /Kickoff Survey: 15,270.30' MD (if applicable) Projected Survey: 15,307.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a ~ ~ - a b~ ~~~, 16-14Bi Proposed Stacker Packer Completion ~ 2O ~ "' ~ 0 3 Subject: 16-14Bi Proposed: Stacker Packer Completion.. From: "Cutler, Jeff N" <Jeff.Cutler@bp:com> Date: Mon, 27 Feb 2006 17:40:48 -0900 To: winton_aubert@admin.state.ak.us Winton, While running in the hole with the 4-1/2" completion the production packer set at 9693', this put the WLEG 49' above the ,~ tie-back sleeve of the 4-1/2 production liner. We propose cutting the 4-1/2" tubing currently in the hole and running a stacker packer with a Unique overshot to allow us to space out and land the completion tubing. The attached completion schematic shows the depths of the current packerMILEG and approximate depths of the proposed stacker packer completion. «1243 001.tif» Jeff Cutler BPXA -Alaska Drilling and Wells Operations Drilling Engineer Office: (907) 564-4134 Cell: (907) 529-8092 Fax: (907) 564-4040 ~- Content-Description: 1243_001.tif 1243_001.ti Content-Type: image/tiff ~ ~ Content-Encoding: base64 i 1 of 1 2/28/2006 7:13 AM ... s~ /~ ._.. (~~ ... - • 16-14Bi Proposed Completion 2200' - 4-112" X nipple ID = 3.813" ~- 2875` -13-3i8" 72#, L-80 CSG, ID = 12.347" -4-112", 12.6#, L-80, TC-ll TBG, ID = 3.958" $773` - 9-5/8" X 7" Baker Packer -9567` - 4-112" X Nipple, ID = 3.813 --95$7' - 7" X4-112" Baker S3 Packer, 1D = 3.875" -9607' - 4-112" X Nipple, ID = 3.813 -9671' - Tubing cut --9677' - 4112" X 7"Unique Overshot 9693' - 7" X4-1 /2" Baker S3 Packer, !D = 3.875" 9714' - 4-1 /2" X Hippie, ID = 3.813" 9735' - 4-112" XN Nipple, ID = 3.725" 974fi` - 4-112" WLEG 9795' - 4-1/2" Hanger /Liner Top Packer -~ ~ 7"Window milled off of whipstock @ 9910' e { r~ r~~a f +Y3'~ } • TREE = 4-1/16" CMI WELLHEAD= VETCO ACTUATOR = BAKER KB. ELEI/ = 66.15' BF. ELEV = _ 40.43 KOP = 4200' Max Angle = 93 @ 10979" Datum Mq = 9979' Datum TV D = 8800' SS Minimum 1D = 3.725" @ 9790' 4-1I2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: ANADRILL MWD ON 03/30!98 ANGLE AT TOP pERF: 92 @ 11525' Note: Refer to Production DB for historical pert data SIZE SPF pVTERVAL Opn/Sqz DATE NOTE: .., ... ~ .. ~~ ~, r . :- .v.. , vs,. ... .. . PBTD = 15,222 Ip ,3> „ 4-1l2", 12.6#, L-80, IBT-M, LNR ID = 3.958 - 15307' -.., „. DATE 07109/81 REV BY COMMENTS ORIGINAL COMPLETION DATE 10/23103 REV BY JMcANTL COMMENTS CORRECT PERF/CISP SET 04/13198 RIG SlD1:T'RACK 11118-23104 DBMITLP CIBP, ADD PERFS 03/08/01 CHlKAK CORRECTIONS 11/17/05 JNC Proposed Completion 08!16/01 CN1tlh PERF CORRECT~NS ~nrnama r.uKaK ~~r.~RraF~TU~n~¢ PRUDHOE BAY tJNfT WELL: 16-14A PERMrf No: 1980360 API No: 50-029-20570-01 SEC 24, 710N, R15E, 1534' SNL & 527' EW Q E X ~~lOTS~lt~t1l~'I~ ®~SI1C)~I Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay, 16-14B BP Exploration (Alaska), Inc. Permit No: 206-003 Surface Location: 1534' FNL, 527' FWL, SEC. 24, TlON, R15E, UM Bottomhole Location: 3606' FSL, 725' FWL, SEC. 18, TlON, R16E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager) . ~~, Jorfn ~. N DATED this~l day of January, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COSSION PERMIT TO DRILL 20 AAC 25.005 / .1~1 ~ Y 1 2006 Aiasxa Cit ~ Gas Cans. Colm~~q Anchorage 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Oil ^ Multiple Zone ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 16-14B tz/tz~®s 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15278 TVD 9056 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surtace: 1534' FNL 527' FWL SEC 24 T10N R15E UM 7. Property Designation: ADL 028332 Pool , , . , , , Top of Productive Horizon: 3586' FSL, 3425' FWL, SEC. 13, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spu Janua 23,006 Total Depth: 3606' FSL, 725' FWL, SEC. 18, T10N, R16E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13,830' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 719306 y- 5929396 Zone- ASP4 10. KB Elevation Plan (Height above GL): 66.5' feet 15. Distance to Nearest Well Within Pool 370' 16. Deviated Wells: Kickoff Depth: 9910 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3804 Surtace: 2923 ''~ 18. asing rogram: Size Specifications Setting Depth To Bottom uantity o ement e.f, or-sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 6-1/8" 4-1/2" 12.6# L-80 IBT-M 5468' 9810' 8740' 15278' 9056' 2 sx Class 'G' 19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill AND Re-entry,Operations) Total Depth MD (ft): 15175 Total Depth TVD (ft): 9026 Plugs (measured): +++~•+_+~,+~•+~•+~ Effective Depth MD (ft): 11150 Effective Depth TVD (ft): 9037 Junk (measured): None Casing Length Size Cement Volume MD TVD r 110' 20" 00 sx Permafrost 110' 110' 2675' 13-3/8" 000 sx Fondu, 1250 sx Permafrost 2675' 2671' 8963' 9-5/8" 00 sx Class 'G' 8963' 7693' r n 1671' 7" 88 sx Class 'G' 8773' - 10444' 7899' - 9055' 4883' 4-1/2" 77 sx Class 'G' 10292' - 15175' 9031' - 9026' Perforation Depth MD (ft): 10700 - 10800 Perforation Depth TVD (ft): 9051 - 9049 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jeff Cutler, 564-x134 Printed Name Dave Wesley Title Senior Drilling Engineer Prepared By Name/NUmber. Si nature vC Phone 564-5153 Date / /®~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: 2 API Number: 50- 029-20570-02-00 Permit Approval Date: - See cover letter for other requirements Conditions of Approval: Samples Required ~i Yes~No Mud Log Required ^ Yes~`No L `, Hydrogen Sulfide Measures ~lfes ; ~ No Directional Survey Required Yes ^ No Other: I'eS~' ~~r E t0 4D~O ~lS.•c' l~~- /~rt,(.~`VC.c~. ~ 7,,~ 1~~4- C ZS - s C E~) C ~ ~ a.t` ~2rr K.cc T,. 'c (3 o PctI~',~ s f ~ lro ce du n.-e r S c~f'~'~ ~ler~ ~~.,~ ~ ki4~~ L cU), ~-,l~~l.~.fe ~arrc+r-~ ~f!'~` ~l~wc.~..c.-~- d s ~yopt~-~~d . A roved ~ THE COMMISSION Date ~0~ Form 10-401 ev' d 6/2004 ~~` ~ ~ ~ ~ ! ~ C Submit In Duplicate • • Well Name: 16-14Bi Planned Well Summary Well Horizontal Target Zones 2 and Well 16-14Bi Type Sidetrack Objective 3 In'ector AFE Number: PBD4P2454 Surface Northin Eastin Offsets TRS Location 5,929,396 719,307 1534' FNL / 527' FWL 10N, 15E, 24 API Number: 50-029-20570-02 T t Northin Eastin Offsets TRS arge ' ' Locatio 5934599 722051.9 2 FSL / 847 FWL 11 N, 15E, 13 ns 5934695 724629.6 1674' FNL / 725' FWL 10N, 16E, 18 Bottom Northin Eastin Offsets TRS Location 5934695 724629.6 1674' FNL / 725' FWL 10N, 16E, 18 Planned KOP: 9,910' and / 8,815' tvd Planned TD: 15,278' and / 9,056' tvd Ri Nabors 2ES j CBE: 38.0' RTE: 66.5' Directional Program i A roved Weil Ian: Wp04 Exit oint: 9,910' and / 8,815' tvd Maximum Hole Inclination: -90° in the tanned 6 1/8" roduction section. Proximity Issues: Gyro surveys will be run in 16-14A pre-rig. With the gyro surveys 16-13 and 16-20 pass with 1/200 minor risk, all other wells pass major risk. A Tolerable Collision Risk Worksheet will be com leted. Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: Well 16-14Bi, wp04 asses 1600' from 16-20. Closest a roach is 370' Nearest Pro ert Line 13,830' East to unit bounda 16-14Bi Sidetrack Page 1 • • Logging Program Hole Section: Required Sensors /Service 6 1/8" roduction: Real time MWD Dir/GR/Res/ABI throu hout the interval. Sam les at 50' intervals. Cased Hole: Schlumberger CBT/GR/CCL log run 9-APR-1998 in 7" liner shows adequate cement to satisf AOGCC zonal isolation re uirements Open Hole: None tanned Mud Program Hole Section / o eration: 6-%e" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 8.5 >20,000 8 - 15 24 - 30 7 - 9 9.0 - 9.5 ~./ Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 6-%g" 4 ~/s" 12.6# L-80 IBT-M 5,468' 9,810/ 8,740' 15,278' / 9,056 Tubin 4 Yz" 12.6# L-80 TC-II 9,810' Surface 9,810/ 8,740' NOTE: This well is planned with the minimum allowed, 100' liner lap, the window in the 7" liner will be located at the top of the Ivishak Zone 4, but with the planned completion, the packer to injection zone distance may exceed the 200' limit as per 20 AAC 25.412 (b) depending on the perforated intervals. A variance to 20 AAC 25.412 (b) is requested allowing a packer to injection zone distance of greater than 200' is requested Cementing Program Casin Strin 4 1/2", 12.6#, L-80, IBT-M solid production liner Lead slurry: none planned Slurry Design Basis: Tail slurry: 5,368' of 4 1/2" X 6 1/8" annulus with 40% excess, plus 85' of 4 " ' " ' ' 1/2 , 12.6# shoe track, plus 100 X 4 /z liner lap, plus 200 of 7 of 7 X 4 drill i e annulus. ?l~=' Pre-Flush 15 bbls CW 100 Fl id S /V l S acer 30 bbls MudPUSH II at 9.5 u s equence ume: o Lead Slur None tanned Tail Slur 133.7 bbl / 750.7 cf 64 ~'sx Class `G', 15.8 .1 cf/sk. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 7" Casin Bride lu to surface 30 min recorded 4,000 si surface 7" liner window 20' new formation be and FIT 10.0 EMW 4 Yz" roduction liner Float e ui ment to surface 30 min recorded 4,000 si surface 16-14Bi Sidetrack Page 2 • • Well Control ~, Z 3 Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 6 1/8" production interval Maximum antici ated BHP: 3„804-psi at 8,815' TVDss. Maximum surface ressure: 2,923 psi (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: finite with 10.0 pp EMW FIT. Planned BOPE test ressure: 250 si low / 4,000 si hi h - 14 da test c cle Drillin o erations Planned completion fluid: 8.4 pp seawater / 7.1 p Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo e Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Area of Review Dist. to nearest property line, ft.: Dist. to nearest well within pool, ft: Wells within 1/4 mi. of this injection well within the reservoir Well Status @ Com 13,830'East to unit boundary 1600' from 16-20. Closest a roach is 370' i Well Name Min. Dist, Ft. Annulus Inte rit Comments 16-20 370 Currently on production, 03/21/04: RWO completed with new tubing, MIT-T & MIT-IA Passed to 3500# 16-13 634 Failed IA X OA comm. Well shut-in pending RWO 16-21 902 Failed IA X OA comm. Well shut-in pending R W O Water In~ection, then 2 weeks later MI swa ~, ',~~, , 16-14Bi Sidetrack Page 3 • • Geologic Prognosis Est. Formation To s Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (TVDss) (eet) (Yes/No) (Psi) ( EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks CM3 6925 +/- 30 CM2 7560 +/- 30 CM1 8225 +/- 30 THRZ 8515 +/- 30 BHRZ-TSAD (Truncated b LCU) 8735 +/- 30 45N 8748 +/- 30 es 3300 45P 8755 +/- 30 es 3300 44N 8785 +/- 30 es 3300 44P 8788 +/- 30 es 3300 43N 8810 +/- 30 es 3300 43P 8812 +/- 30 es 3300 42N 8843 +/- 30 es 3300 42P 8888 +/- 30 es 3300 41N 8890 +/- 30 es 3300 41P 8891 +/- 30 es 3300 31N 8897 +/- 30 es 3300 31P 8907 +/- 30 es 3300 27N 8958 +/- 30 es 3300 27P 8959 +/- 30 es 3300 26N 8988 +/- 30 yes 3300 26P 8990 +/- 30 es 3300 MHO/HOT 8990 +/- 30 TD Criteria: TD as per Sperry Sun Directional Plan #04, with input from town and rig drilling team Oaerations Summar Current Condition: / Currently on MI injection. / Between April 1998 and November 2004 perforations have been added for 6 MI injection bulbs. / 7'; 26#, L-801iner landed at 10,444'. / 4-1/2'; 12.6#, L-80 liner landed at 15,175' / 7" X 4-1/2" Baker ZXP packer at 10,292 / 4-1/2'; 12.6#, 13Cr Tubing with WLEG at 9,579'. / 4-1/8 CIW tree Gray gen 111 retro to Gray New Standard. / 03/26/05: M/TIA Passed to 3000 psi. / 04/01/05: PPPOT-T Passed to 5000 psi. / 9-APR-1998: Schlumberger CBT/GR/CCL log in 7"liner shows adequate cement to satisfy AOGCC ~ zonal isolation requirements 16-14Bi Sidetrack Page 4 • • Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Riq Work: 1. Replace all live Gas Lift valves with Dummy valves and fluid pack as necessary for CT P&A. 2. RU CT unit. RIH with CT and P&A the 16-14A well bore. Pump sufficient cement to leave top of cement in the 7" liner at 10,200' MD. Calculated cement volume; 16.5 bbls, based on 858' of 4-1/2" , 12.6# liner (cap. = 0.0152 bbl/ft) and 92' of 7", 26# liner (cap. = 0.0383 bbl/ft). 3. Drift the 4~h" tubing to confirm clear to the required cut depth of 9,534' MD. Tag up on cement at 10,200' to confirm TOC. 4. RU E-line with a GyroData continuous casing multi-shot gyro survey tool. RIH taking gyroi surveys from surface down to 9,500' MD. This will verify the position of the 16-14A wellbore, allowing the 16- 14B to pass minor risk anti-collision criteria with 16-13 and 16-20. 5. RIH with the appropriate chemical cutter and cut the 4~h" tubing at -9,534' MD. A chemical cutter will be used on this well due to the fact that an overshot packer milling assembly will be run and the chemical cutters have shown less of a tendency to flare the tbg stub than the jet cutters. 6. Displace the well to clean seawater by circulating down the tubing and through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' MD with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. 10. Remove well houses required to rig up Nabors 2ES. Level the pad as necessary. 11. Provide total pre-rig costs on the handover form. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to 4,OOOpsi. 4. R/U. Pull 4~h" tubing from the cut at 9,534' MD and above. 5. MU BOT packer milling assembly and RIH. Mill 7" X 4-1/2" Baker S3 packer at 9,535'. 6. The packer milling assembly will not have a PRT, the packer will be pushed down to the top of cement at 10,200' MD, POH 7. R/U E-line. M/U 6.125" gauge ring /junk basket / CCL. RIH and tag up on the packer to ensure it is below the depth required to set the EZSV. POH. 8. RIH with HES EZSV on E-line. Set bridge plug at 9,934', as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 9. Pressure-test the 7" liner to 4,000 psi for 30 minutes. Record test. and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orient whip stock 30 degrees right of high side and set on bridge plug. Shear off of whip stock. 11. Displace the well to 8.4 ppg Flo-Pro drilling fluid. Completely displace the well prior to beginning milling T~',S In - 4n ( operations. 12. Mill window in 7" liner at ± 9,910' MD, plus approximately 20' beyond middle of window. Circulate well ~ ~PY"'`~''~a-~ . bore clean. 13. Pull up into 7" liner and conduct an FIT to 10.0 ppg EMW. POH. ~ 14. M/U 6-1/8" Dir/GR/Res assembly and RIH. 15. Drill the 6-1/8" production interval building at ~12°/100' to horizontal, targeting Ivishak zones 2 and 3. Drill ahead to an estimated TD of 15,267 MD. ~ 16. Run and cement a 4-1/2" liner with 100' liner lap in the 7" drilling liner. Displace cement with Safe Break L bleach treatment and mud. 17. Release from liner, displace well to clean seawater. 18. Pressure test 4-1/2" liner to 4,000 psi for 30 mins. 19. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. Estimated pert interval of 90' included in the AFE costs 20. POH. LD DP and pert guns. 21. R/U and run a 4~h", 12.6#, L-80 tubing completion, stinging into the 4~h" liner tie back sleeve. 16-14Bi Sidetrack Page 5 • A 22. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 23. Freeze protect the well to -2,200' TVD. /~ 24. Set packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 25. Set a BPV. 26. Secure the well. 27. Rig down and move off. Post-Riq Work: 1. Install wellhouse and flowlines. Phase 1: Move In /Riq Up /Test ROPE Planned Phase Time Planned Phase Cost 55.9 hours $409,000 includes re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - No wells will require shut-in for the rig move onto 16-14A. The closest neighboring wells are 16- 28, 59' to the South and 16-15, 120' to the North. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 16-14A well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the 16-14A well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - Dr-/I Site 16 IS designated a5 an H2S Slte. H2S Operating Procedures should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 16-15 67 ppm 03-05 NA 16-28 267 ppm 03-35 220 ppm i The maximum level recorded of H2S on the pad was 450 ppm in well 16-21 on 05/28/2005. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 16-146i Sidetrack Page 6 • • Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 151.2 hours $451,000 Reference RP • "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a Gray Gen III updated to new standard. Check with Cameron to ensure all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a CAMCO 4'/i" SVN at 2197' MD, the valve was removed with slick line pre-rig. The original completion shows the SVN being run with dual ~/a" control lines secured with 58 SS bands. - Run the GR/CCL Log high enough above the bridge plug setting depth to tie into the primary depth control log supplied by the wellsite geologist. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 42.0 hours $235,000 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - The SLB CBT/GR/CCL log run in the 7" liner on 9-APR-1998 shows very little cement behind the liner at the window. - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 189.6 hours $1,154,000 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP 16-14Bi Sidetrack Page 7 ~ ~ Issues and Potential Hazards - The geologic polygon has the following hardlines; • On the North and Northwest by the parent well 16-14A and proximity to offset producers • On the Southeast by a close approach with 16-20 • On the East by a fault beyond planned TD and proximity to well 16-02 - 16-146i crosses three small faults, #1 @ 10,225" MD, #2 @ 11,900' MD, and #3 @ 13,100' MD, these depths are estimated from WP04, with the uncertainty of the faults these crossing depths could be +/- 100' MD. The first and most significant fault, estimated throw ~25', was crossed while drilling 16-14A without losses. The last two faults, estimated throw ~10', are poorly imaged on 3D seismic and show little continuity. The risk of lost circulation is considered low for all three faults. Phase 9: Run 4~h" Production Liner Planned Phase Time Planned Phase Cost 43.2 hours $407,000 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4'/z", 12.6#, L-80 solid liner throughout the production interval. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 500 psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4 ~/z" liner will be run to extend 100' back up into the 7" liner. - The recommended completion includes a Baker ZXP packer with Flexlock hanger run on a C2 running tool. If the wellbore exhibits excess tortuosity while drilling the production section an HR, rotatable, running tool may be substituted. - Ensure the 4 ~h" liner top packer is set prior to POH. Job 10: DPC Perforate Well Planned Job Time Planned Job Cost 40.8 hours $154,000 Hazards and Contingencies - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach tag the landing collar due to cemenbfill. Reference RPs • DPC Perforating RP 16-14Bi Sidetrack Page 8 • Schlumberger DPC Perforating Guidelines • Phase 12: Run 4'/2", 12.6#, L-80, TC-II Completion Planned Phase Time Planned Phase Cost 24.0 hours $479,000 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 4~h", 12.6#, L-80, TC-II production tubing string, stinging into the 4'/z" liner tieback sleeve. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 7.2 hours $21,000 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig to move off of 16-14B. The closest neighboring wells are 16-28, 59' to the South and 16-15, 120' to the North. Care should be taken while moving off of the well. Spotters should be employed at all times. 16-14Bi Sidetrack Page 9 ('UM1II'ANY DID L11LS nl1 1 -I~) l'~ I vlulio ht I uJ. M' - I INn ('unana. hrrur Syat~in: IS(\V 5,1 Sian M1Ir1h+~d: 7'ra1' l)~IvN.m N~mli hrrur SUrti.~.: Lllipornl ~ ('ain~ \\nming AIaMd: Ruk~ DsxJ kI:FI~:kI:N('t: INi1Ikh1A 1 II )N ('..~d IN(IRr N'll( hlf lJ.1-1ni.~N~m \rm 1111n1kt iN %.S (1.1 S 1\til k I M t - IJ III ININ 1. I. hl.-e. u.d D.plh R.fvr~liv. l%_+%.5 M1I.Su ('uhulanun M.O~,J: Alinnnum (lu~vuuc li CASING DETAILS ', No. TVD MD Name Sipe ~ / ~/ ; ~~ ~ -I-_. I 9056.46 15267.00 4 I/2" 4.5110 I - ,_ I / I ~ ~ FORMATION TOP DETAILS ~ ~~ V~ ' ~ N TVDP h MDP h F i ~ !~_ , r~ 1. o. at at ormat on I~`~ ` ' 1 8965.50 10170.66 TCGL ~- 2 9016.50 10300.87 BCGL 3 9056.50 15278.40 HOT • u I ~~ ~~ ~ ~ P ~~ , ~ c .~ _. c Z 0 r G F St1RV LY I'xtx;knM Plan: Ifi-14B wplld ll6-IlA; Plan 16-IdBI n plb fl D.PIh l S rymlao l ool (rr.u.'<I Hv: Tr oy Jnkehuxky IJ+JcuRku bp. 8pe: I I ?~.?1105 Y4111N1 IS"x.JU Ilm~m~J: l6-IJa xPIN V'~ MN'D~IFk-hIS l'hrikr~. D~IC: Itel lewrJ'. Dafr: N:ui%~ -N -S t: - N I:LL DELI.\IL 11' N.~nliinz I::..linE S LatilnAc L.~ngnuk Sl~i l In-IJ,\ I`1J1')h lY_' 4M1 -4414[.1,1 'IY111f•ifl i11-I"1i.I.t.1N IJ%'I1'Cllfil\1 IJ TARGET DETAILS Name "fVD +Ni-S +Ei-W Northin4 Eastiog Shape 16-14B TI 9O46.5O 5120.87 2895.66 5934599.00 7221151.90 Poim IG-14B T3 90$650 5141.97 5475.18 5934695.00 724629.60 Poin( 16-146 TO 9056.50 3597-09 1493.32 5933035.21 720694.47 Poinl SECTION DETAILS Scc MD Inc Azi TVD +N/-S +Ei-W DLcg TFacc VScc Targcl I 9910.00 40.59 14.01 8815.112 3065.73 1169.40 O.UO 0.00 2133.62 2 9930-OU 42.68 15.78 8829.96 3078.57 1172.82 12.00 30.00 2143.26 3 1(1156.20 GG.94 30.99 8959.84 3244.68 1248.67 12.00 31.94 2252.90 4 10300.03 66.94 30.99 9016.17 3358.14 1316.81 ~.00 0.00 2319-97 5 10503.86 90.00 39.00 91156.50 3519.38 1430.39 12A0 19.77 2407.29 6 10603.86 90.00 39.011 9056.50 3597.09 1493.32 0.00 0.00 2445.46 IG-148 TO 7 10623.44 90.33 40.19 905GA4 3612.95 1506.44 6.00 74.42 2453.12 8 12271.07 90.33 40.19 )046.90 4871.58 2%9.66 0.00 0.00 3050.29 9 12684b8 89.78 65.00 9046.50 5120.87 2895.66 6.00 9L25 3113.39 IG-14BT1 10 13131.55 89.78 9L81 9(148?6 5209.86 3329.43 6.OU 90.05 2984.18 II 15278.40 8).78 91.81 9056.50 514197 5475.18 Q.OU 0.00 18')8.72 16-14B'f2 Vertical Section al 90.00° [6001Vin] o .. ~ -~ ~ -- ~I --. _. -- vl ~ ~ '. ~ ~ F J I ~ t t I __ . _~ _ - _ O n F ~ Fm2 . I _ r_ _. I _ _ _ _. _. - _ m ~ I ~ - ~ ~ ~ ~ ~ ~ ~ _ = ~ F n c ~ - - -- - ~ I- ~-- - ~ - ~ ~ ~ ~ ~ n t === o 0 o ` ~ rl ~ ~ 00~ - _ _ i _ _ 4 I _ I I i ~ '~ __ d, .,, In a a c F. P ~ ~ ~ ` . _. ; . ~ i ~ f ^ C > .p . vi m in N T o~c~ n < n F .. l _ i _.._ __. m s -. NYO u Q ~ __ _ -r~r-, C - L -0 Vl ~ ~ u - _ J 7 T T v ~ ~ T ~ J J . a . . _. .- . NN 0 - - ~ =- ~I _ = = ~ 3 ~ _ '~ ri ~ s ~ _ . J - F ~ I. t l T r T ~ ~ ~ N s ~ + ~I ~ ~ _ ._ ~ ~ °~ _ 3 _ I ~ ~ rrT x ~ ~ i I _ z Z T.. n _ ~ I eN , _ _ 5 5 _ ; vi Vi nl '~ ', '. i . I a. ~ _ _ a ... ~~ F ~~h I I a a a _ f - x ~~ - a I~ FFF 3 - a Z mmm - u c YYY _ ^ _ ~ I I _ _ - z _~= t _ ' I r _ ' i I ~ i I _ ~ ~ i .. I _ _ i i i : F, I I _. . n ~. ...._ > co i _ _.,. - ?~L - ~ = ~ ~ F p ce. :* 0 > ~= ~ i2 f ~ _ W n ~ . _ _ z - - ' ^ .'~2 ~ ~~ oNr-ariYU~ .ONx ~ Yx~p xr+im Yip ,D Y-- T lx~O~r~~OT~n I i ~. . rl .. rl ~ ~ .ri _ _Oa ~ _ _ . _ _ _ 5 .i i C ^ > _ N~KITO~OT nYY'~ R ' '~ O Q ~ ~ N Q 2, ~ ___ ri rir v i .. _ . I i __ s ~ »aor b ~ - ., NCO oY _ ,~ , r .. i I ~ ~ - ^ ., _ ~ > _ ~ v -, y+ o ooooo000 ~ooooo00000 - _ ! - I w . F _ .-. ~. ~ .x. --___ ~ oriNOric ^:o.~.oc _ F i - _ _ ~ i ~ ~ ~ ^. .9. .. _ C .. j a o T - N _- ~ _ ~ -'- -. - a.. 0__ .. ~ arix~cor, .:avia vi `~ era-MTC.~TNr + < i :. _ ttl .'3 o _ _ ~~. _ _ ~_ _. ., z ~ n Y Y v~ v~ x ro R F f tJ ~ _ _ 1 h . ^ _ _ - ,_- v + ~+ _ _ i ~. dz n ~ ~ -,'~ ~ ,J F. naa~~~.. ,6 - Ian ~n vi ~n Y Y Y ~n xxT OOO.-..0000 x» x T T T T T T T T _. ~ -- _ + j ~-._ .. _. __- . N i ..._~ Y ~nOOTTOO~n-•- ' _ _. .. .. Y ~ I _ _ --nnr ~n YY ~aa - - - ~N.O .G~~O~TTT Y?~O .OTTTTxxx ~ ~ Y ?~ Cj _ .j I OWN=xxY O ~C VtY _ y. O O C N r x n n 'TT~nl v1 J' J' NJ' -N TTOOOOONNr1 vt Vf ~Nn?~n .p r`xT-- ~ O .. . ~ ~ i 3 ~~!NOOLI (+)4uoN!(-)4lnoS S er -Sun P rY SP Planning Report Company: BP Amoco Date: 11/22/2005 Time: 12:49:53 Page: I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-14A, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-14A Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpath: Plan 16-146 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 16-14B wp04 Date Composed: 8/31/2005 Version: 22 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 16 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 5927441.99 ft Latitude: 70 12 15.545 N From: Map Easting: 718969.88 ft Longitude: 148 14 4.567 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.66 deg Well: 16-14A Slot Name: 14 16-14A Well Position: +N/-S 1943.96 ft Northing: 5929396.43 ft Latitude: 70 12 34.664 N +E/-W 392.96 ft Easting : 719306.30 ft Longitude: 148 13 53.161 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 15278.00 9056.50 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 LCU/TSAD 0.00 0.00 10170.66 8965.50 TCGL 0.00 0.00 10300.87 9016.50 BCGL 0.00 0.00 15278.40 9056.50 HOT 0.00 0.00 Targets Map Map <---- Latitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 16-146 T1 9046.50 5120.87 2895.66 5934599.00 722051.90 70 13 25.023 N 148 12 29.057 W 16-146 T2 9056.50 5141.97 5475.18 5934695.00 724629.60 70 13 25.216 N 148 11 14.135 W 16-14B TO 9056.50 3597.09 1493.32 5933035.21 720694.47 70 13 10.040 N 148 13 9.797 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9910.00 40.59 14.01 8815.02 3065.73 1169.40 0.00 0.00 0.00 0.00 9930.00 42.68 15.78 8829.96 3078.57 1172.82 12.00 10.46 8.85 30.00 10156.20 66.94 30.99 8959.84 3244.68 1248.67 12.00 10.72 6.72 31.94 10300.03 66.94 30.99 9016.17 3358.14 1316.81 0.00 0.00 0.00 0.00 10502.86 90.00 39.00 9056.50 3519.38 1430.39 12.00 11.37 3.95 19.77 10602.86 90.00 39.00 9056.50 3597.09 1493.32 0.00 0.00 0.00 0.00 16-146 TO 10623.44 90.33 40.19 9056.44 3612.95 1506.44 6.00 1.61 5.78 74.42 12271.07 90.33 40.19 9046.90 4871.58 2569.66 0.00 0.00 0.00 0.00 12684.68 89.78 65.00 9046.50 5120.87 2895.66 6.00 -0.13 6.00 91.25 16-146 T1 13131.55 89.78 91.81 9048.26 5209.86 3329.42 6.00 0.00 6.00 90.05 15278.40 89.78 91.81 9056.50 5141.97 5475.18 0.00 0.00 0.00 0.00 16-14B T2 S err -Sun P Y BP Planning Report Company: BP Amoco Date: 11/22/2005 Time: 12:49:53 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-14A, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-14A Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpath: Plan 16-146 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft ft deg/100ft ft ft 9910.00 40.59 14.01 8815.02 8748.52 1169.40 3065.73 1169.40 0.00 5932494.69 720386.13 Start Dir 12/10 9930.00 42.68 15.78 8829.96 8763.46 1172.82 3078.57 1172.82 12.00 5932507.62 720389.17 MWD+IFR+MS 10000.00 49.97 21.57 8878.29 8811.79 1189.16 3126.41 1189.16 12.00 5932555.92 720404.11 MWD+IFR+MS 10100.00 60.76 27.98 8935.08 8868.58 1223.83 3200.82 1223.83 12.00 5932631.30 720436.61 MWD+IFR+MS 10156.20 66.94 30.99 8959.84 8893.34 1248.67 3244.68 1248.67 12.00 5932675.86 720460.17 End Dir :1015 10170.66 66.94 30.99 8965.50 8899.00 1255.52 3256.09 1255.52 0.00 5932687.46 720466.68 TCGL 10200.00 66.94 30.99 8976.99 8910.49 1269.42 3279.23 1269.42 0.00 5932711.00 720479.90 MWD+IFR+MS 10300.00 66.94 30.99 9016.16 8949.66 1316.80 3358.11 1316.80 0.00 5932791.22 720524.97 MWD+IFR+MS 10300.03 66.94 30.99 9016.17 8949.67 1316.81 3358.14 1316.81 0.00 5932791.24 720524.98 Start Dir 12/10 10300.87 67.04 31.03 9016.50 8950.00 1317.21 3358.80 1317.21 11.97 5932791.92 720525.36 BCGL 10400.00 78.28 35.11 9046.01 8979.51 1368.83 3437.90 1368.83 12.00 5932872.47 720574.65 MWD+IFR+MS 10500.00 89.67 38.89 9056.49 8989.99 1428.59 3517.15 1428.59 12.00 5932953.43 720632.09 MWD+IFR+MS 10502.86 90.00 39.00 9056.50 8990.00 1430.39 3519.38 1430.39 11.97 5932955.71 720633.82 End Dir :1050 10600.00 90.00 39.00 9056.50 8990.00 1491.52 3594.87 1491.52 0.00 5933032.94 720692.73 MWD+IFR+MS 10602.86 90.00 39.00 9056.50 8990.00 1493.32 3597.09 1493.32 0.00 5933035.21 720694.47 16-146 TO 10623.44 90.33 40.19 9056.44 8989.94 1506.44 3612.95 1506.44 6.00 5933051.44 720707.12 End Dir :1062 10700.00 90.33 40.19 9056.00 8989.50 1555.84 3671.43 1555.84 0.00 5933111.34 720754.80 MWD+IFR+MS 10800.00 90.33 40.19 9055.42 8988.92 1620.37 3747.82 1620.37 0.00 5933189.56 720817.08 MWD+IFR+MS 10900.00 90.33 40.19 9054.84 8988.34 1684.91 3824.21 1684.91 0.00 5933267.79 720879.36 MWD+IFR+MS 11000.00 90.33 40.19 9054.26 8987.76 1749.44 3900.61 1749.44 0.00 5933346.02 720941.65 MWD+IFR+MS 11100.00 90.33 40.19 9053.68 8987.18 1813.97 3977.00 1813.97 0.00 5933424.25 721003.93 MWD+IFR+MS 11200.00 90.33 40.19 9053.10 8986.60 1878.50 4053.39 1878.50 0.00 5933502.48 721066.21 MWD+IFR+MS 11300.00 90.33 40.19 9052.52 8986.02 1943.03 4129.78 1943.03 0.00 5933580.71 721128.49 MWD+IFR+MS 11400.00 90.33 40.19 9051.94 8985.44 2007.56 4206.17 2007.56 0.00 5933658.94 721190.77 MWD+IFR+MS 11500.00 90.33 40.19 9051.37 8984.87 2072.09 4282.56 2072.09 0.00 5933737.16 721253.06 MWD+IFR+MS 11600.00 90.33 40.19 9050.79 8984.29 2136.62 4358.95 2136.62 0.00 5933815.39 721315.34 MWD+IFR+MS 11700.00 90.33 40.19 9050.21 8983.71 2201.15 4435.34 2201.15 0.00 5933893.62 721377.62 MWD+IFR+MS 11800.00 90.33 40.19 9049.63 8983.13 2265.68 4511.73 2265.68 0.00 5933971.85 721439.90 MWD+IFR+MS 11900.00 90.33 40.19 9049.05 8982.55 2330.21 4588.12 2330.21 0.00 5934050.08 721502.18 MWD+IFR+MS 12000.00 90.33 40.19 9048.47 8981.97 2394.74 4664.51 2394.74 0.00 5934128.31 721564.47 MWD+IFR+MS 12100.00 90.33 40.19 9047.89 8981.39 2459.27 4740.90 2459.27 0.00 5934206.54 721626.75 MWD+IFR+MS 12200.00 90.33 40.19 9047.31 8980.81 2523.80 4817.29 2523.80 0.00 5934284.76 721689.03 MWD+IFR+MS 12271.07 90.33 40.19 9046.90 8980.40 2569.66 4871.58 2569.66 0.00 5934340.36 721733.29 Start Dir 6/100 12300.00 90.29 41.92 9046.74 8980.24 2588.66 4893.39 2588.66 6.00 5934362.72 721751.65 MWD+IFR+MS 12400.00 90.16 47.92 9046.35 8979.85 2659.25 4964.17 2659.25 6.00 5934435.51 721820.15 MWD+IFR+MS 12500.00 90.03 53.92 9046.18 8979.68 2736.84 5027.17 2736.84 6.00 5934500.74 721895.87 MWD+IFR+MS 12600.00 89.89 59.92 9046.26 8979.76 2820.59 5081.73 2820.59 6.00 5934557.70 721978.00 MWD+IFR+MS ', 12684.68 89.78 65.00 9046.50 8980.00 2895.66 5120.87 2895.66 6.00 5934599.00 722051.90 16-146 T1 12700.00 89.78 65.92 9046.56 8980.06 2909.59 5127.23 2909.59 6.00 5934605.77 722065.64 MWD+IFR+MS 12800.00 89.77 71.92 9046.95 8980.45 3002.85 5163.18 3002.85 6.00 5934644.41 722157.81 MWD+IFR+MS 12900.00 89.77 77.92 9047.35 8980.85 3099.37 5189.19 3099.37 6.00 5934673.21 722253.52 MWD+IFR+MS 13000.00 89.77 83.92 9047.74 8981.24 3198.07 5204.97 3198.07 6.00 5934691.84 722351.72 MWD+IFR+MS 13100.00 89.78 89.92 9048.13 8981.63 3297.88 5210.34 3297.88 6.00 5934700.11 722451.33 MWD+IFR+MS 13131.55 89.78 91.81 9048.26 8981.76 3329.42 5209.86 3329.42 6.00 5934700.55 722482.87 End Dir :1313 13200.00 89.78 91.81 9048.52 8982.02 3397.84 5207.70 3397.84 0.00 5934700.37 722551.32 MWD+IFR+MS 13300.00 89.78 91.81 9048.90 8982.40 3497.78 5204.53 3497.78 0.00 5934700.11 722651.31 MWD+IFR+MS 13400.00 89.78 91.81 9049.29 8982.79 3597.73 5201.37 3597.73 0.00 5934699.86 722751.31 MWD+IFR+MS 13500.00 89.78 91.81 9049.67 8983.17 3697.68 5198.21 3697.68 0.00 5934699.60 722851.30 MWD+IFR+MS 13600.00 89.78 91.81 9050.06 8983.56 3797.63 5195.05 3797.63 0.00 5934699.34 722951.30 MWD+IFR+MS 13700.00 89.78 91.81 9050.44 8983.94 3897.58 5191.88 3897.58 0.00 5934699.08 723051.29 MWD+IFR+MS 13800.00 89.78 91.81 9050.82 8984.32 3997.53 5188.72 3997.53 0.00 5934698.82 723151.28 MWD+IFR+MS 13900.00 89.78 91.81 9051.21 8984.71 4097.48 5185.56 4097.48 0.00 5934698.56 723251.28 MWD+IFR+MS 14000.00 89.78 91.81 9051.59 8985.09 4197.43 5182.40 4197.43 0.00 5934698.31 723351.27 MWD+IFR+MS S err -Sun • P Y BP Planning Report Company: BP Amow Date: 11/22/2005 Time: 12:49:53 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 16-14A, True North Site: PB DS 16 Vertical (TVD) Reference: 38+28.5 66.5 Well: 16-14A Section (VS) Reference: Well (O.OON,O.OOE,90.OOAzi) Wellpath: Plan 16-146 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 14100.00 14200.00 14300.00 14400.00 14500.00 14600.00 14700.00 14800.00 14900.00 15000.00 15100.00 15200.00 15278.00 15278.40 Incl deg 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 89.78 Azim deg 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 91.81 TVD Sys TVD VS N/S ft ft ft ft 9051.98 8985.48 4297.38 5179.24 9052.36 8985.86 4397.33 5176.07 9052.74 8986.24 4497.28 5172.91 9053.13 8986.63 4597.23 5169.75 9053.51 8987.01 4697.18 5166.59 9053.90 8987.40 4797.12 5163.42 9054.28 8987.78 4897.07 5160.26 9054.66 8988.16 4997.02 5157.10 9055.05 8988.55 5096.97 5153.94 9055.43 8988.93 5196.92 5150.78 9055.81 8989.31 5296.87 5147.61 9056.20 8989.70 5396.82 5144.45 9056.50 8990.00 5474.78 5141.98 9056.50 8990.00 5475.18 5141.97 E/W ft 4297.38 4397.33 4497.28 4597.23 4697.18 4797.12 4897.07 4997.02 5096.97 5196.92 5296.87 5396.82 DLS MapN deg/100ft ft 0.00 5934698.05 0.00 5934697.79 0.00 5934697.53 0.00 5934697.27 0.00 5934697.01 0.00 5934696.76 0.00 5934696.50 0.00 5934696.24 0.00 5934695.98 0.00 5934695.72 0.00 5934695.47 0.00 5934695.21 MapE Tool/Comme 1 ft 723451.27 MWD+IFR+MS 723551.26 MWD+IFR+MS 723651.26 MWD+IFR+MS 723751.25 MWD+IFR+MS 723851.24 MWD+IFR+MS 723951.24 MWD+IFR+MS 724051.23 MWD+IFR+MS 724151.23 MWD+IFR+MS 724251.22 MWD+IFR+MS 724351.22 MWD+IFR+MS 724451.21 MWD+IFR+MS 724551.21 MWD+IFR+MS 5474.78 0.00 5934695.01 724629.20 4 1 /2" 5475.18 0.00 5934695.00 724629.60 16-14B T2 S err -Sun A Y Anticollision Report Company: BP Amoco Date: 12/21/2005 Time: 09:54:00 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 16 Co-ordinate(NE) Reference: Well: 16-14A, True North Reference Well: 16-14A Vertical (TVD) Reference: 38+28.5 66.5 Reference Wellpath: Plan 16-146 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Tlsr~ls in this fl2Fdtcipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9910.00 to 15278.40 ft Scan Method: Trav Cylinder North Maximum Radius: 1724.99 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/31/2005 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft 28.50 8996.50 1 : Sperry-Sun BOSS gyro multi (32. 30-8996.~'f~¢T-CMS Gyrodata cont.casing m/s 9000.30 9910.00 2 : MWD -Standard (9069.40-15109.88) (0) MWD MWD -Standard 9910.00 15278.40 Planned: 16-14B wp04 V23 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 15278.00 9056.50 4.500 6.125 41/2" Summary <---------- Offset Wellpath ---------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 03 03-04 03-04 V1 11095.33 12981.50 1261.06 275.80 985.26 Pass: Major Risk PB DS 16 16-01 16-01 V2 Out of range PB DS 16 16-02 16-02 V1 Out of range PB DS 16 16-03 16-03 V1 Out of range PB DS 16 16-04 16-04 V1 Out of range PB DS 16 16-04A 16-04A V1 Out of range PB DS 16 16-10 16-10 V1 Out of range PB DS 16 16-10A 16-10A V3 Out of range PB DS 16 16-11 16-11 V1 Out of range PB DS 16 16-12 16-12 V1 Out of range PB DS 16 16-12A 16-12A V3 Out of range PB DS 16 16-13 16-13 V1 12700.00 11750.00 658.61 0.00 658.61 Pass: Minor 1/200 PB DS 16 16-14 16-14 V3 12909.54 9925.00 117.03 No Reference Casings PB DS 16 16-14A 16-14A V3 9925.00 9925.00 0.22 No Reference Casings PB DS 16 16-15 16-15 V1 Out of range PB DS 16 16-16 16-16 V1 Out of range PB DS 16 16-17 16-17 V1 Out of range PB DS 16 16-18 16-18 V1 Out of range PB DS 16 16-19 16-19 V1 Out of range PB DS 16 16-20 16-20 V1 11770.55 10650.00 403.75 0.00 403.75 Pass: Minor 1/200 PB DS 16 16-21 16-21 V1 14591.45 12025.00 868.24 805.52 62.73 Pass: Major Risk PB DS 16 16-24 16-24 V1 Out of range PB DS 16 16-28 16-28 V1 Out of range PB DS 16 16-29 16-29 V1 Out of range PB DS 16 16-29A 16-29A V1 Out of range Site: PB DS 03 Well: 03-04 Rule Assigned: Major Risk Wellpath: 03-04 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11124.52 9053.54 12300.00 9122.02 21.35 60.66 307.90 267.71 1711.74 282.04 1429.70 Pass 11123.42 9053.55 12325.00 9137.07 21.34 60.61 307.36 267.17 1692.50 282.05 1410.45 Pass 11122.38 9053.55 12350.00 9152.12 21.34 60.58 306.81 266.62 1673.40 282.09 1391.31 Pass 11121.40 9053.56 12375.00 9167.16 21.34 60.54 306.25 266.06 1654.45 282.12 1372.34 Pass 11120.47 9053.56 12400.00 9182.21 21.34 60.50 305.68 265.49 1635.67 282.13 1353.54 Pass 11119.43 9053.57 12425.00 9197.25 21.33 60.46 305.09 264.90 1617.05 282.12 1334.93 Pass 11118.35 9053.58 12450.00 9212.30 21.33 60.43 304.49 264.30 1598.61 282.10 1316.52 Pass 11117.27 9053.58 12475.00 9227.34 21.33 60.39 303.88 263.69 1580.36 282.05 1298.30 Pass 11116.19 9053.59 12500.00 9242.39 21.32 60.35 303.25 263.06 1562.28 281.99 1280.29 Pass TREE= 4-1/16" CNV WELLHEAD= VETCO ACTUATOR= BAKER KB. ELEV = 66.15' BF. ELEV - _ 40.43 KOP = 4200' Max Angle = __ 93 @ 10979" Datum MD = 9979' Datum TVD = 8800' SS ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 9-5/8" X 7" BKR PKR/HGR, ID = 6.25" ~-~ 8773' Minimum ID = 3.813" @ 9558' 4-1 /2" HES X NIPPLE 114-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" I~ 9578' 1 2197' ~--~ 4-1 /2" CA MCO SVN, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3518 3518 1 MMGM DMY RK - 04/15/98 2 5084 5014 34 MMGM DMY RK - 04/13/98 3 6568 6201 43 MMGM DMY RK - 04/13/98 4 7901 7202 39 MMGM DMY RK 04/13/98 5 8747 7878 35 MMGM DMY RK - 04/13/98 6 9467 8463 36 KBG2LS DMY BTM - 04/13/98 9-5/8" MILLOUT WINDOW 8963' - 8979' (OFF WHIPSTOCK ) 9535' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9558' 4-1 /2" HES X NIP, ID = 3.813" 9579' 4-1/2" WLEG ELMD TT NOT LOGGED 10292' ~ 7" X 4-1 /2" BKR ZXP PKR/ HGR, (I ID = 4.430" 9-5/8" CSG, 47#, N-80, ID = 8.681" '~ 9772' I IXXXXXXXX. 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: ANA DRILL MWD ON 03/30/98 ANGLE AT TOP PERF: 92 @ 11525' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10700 - 10775 O 11 /23/04 2-7/8" 6 10775 - 10800 O 11/18/04 2-78" 6 11525 - 11625 O 10/24/03 2-7/8" 6 12300 - 12400 C 02/20/02 2-7/8" 6 13130 - 13230 C 09/29/00 2-7/8" 6 14081 - 14181 C 10/31 /99 2-3/4" 4 14976 - 15076 C 10/29/99 NOTE: LOWER 3 ZONES ISOLATED BY CIBPS I 10444' I CIBP SET 11/18/04 ~ 11150' CIBP SET 10/23/03 12100' CIBP SET 02/19/02 12500' 4-1/2" CIBP SET o9/28/00 13380' 4-1/2" CIBP SET 10/29/99/ 14258' PBTD 15089' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 15175' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/09/81 ORIGINAL COMPLETION 10/23/03 BJMcM/TL CORRECT PERF/CIBP SET 04/13/98 RIG SIDETRACK 1 111 8-2 3/04 DBMITLP CIBP, ADD PERFS 03/08/01 CH/KAK CORRECTIONS 08/16/01 CH/tlh PERF CORRECTIONS 10/09/01 CJ/KAK PERF CORRECTIONS 02/24/02 DCRlKAK ADPERF &CIBP PRUDHOE BAY UNfT WELL: 16-14A PERMff No: 1980360 API No: 50-029-20570-01 SEC 24, T10N, R15E, 1534' SNL & 527' EWL BP Exploration (Alaska) ~ 16 -14A S,~ NOTES: 4-1 /2" CHROME TBG. W ELL > 70° @ 10269' AND > 90° @ 10468'. * A-1 INJ VLV SET IN SVN @ 2197' ON 10/1/00 (1.55" BEAN ). •16-14Bi Propos~ Completion ~ 2200` - 4-1/2" X nipple ID = 3.813" 2675` - 13-3/8" 72#, L-80 CSG, ID = 12.347" 4-1/2", 12.6#, L-80, TC-II TBG, ID = 3.958" I 8773`.- 9-5/8" X 7" Baker Packer 9730` - 4-1/2" X Nipple, ID = 3.813 9750` - 7" X4-1/2" Baker S3 Packer, ID = 3.875" 9770` - 4-1/2" X Nipple, ID = 3.813" 9790` - 4-1/2" XN Nipple, ID = 3.725" 9800` - 4-1/2" WLEG 9810' - 4-1/2" Hanger /Liner Top Packer 7"Window milled off of whipstock @ 9910' ,.. TREE= 4-1/16" CM/ WELLHEAD= VETCO ACTUATOR= BAKER KB. ELEV = 66.15' BF. ELEV = _ __ 40.43 KOP = 4200' Max Angle = 93 @ 10979" Datum MD = 9979' Datum TV D = 8800' SS Minimum ID = 3.725" @ 9790' 4-1 /2" HES XN NIPPLE a •. , - - PBTD = 15187' ~ 4-1/2", 12.6#, L-80, IBT-M, LNR ID = 3.958 - 15267` 9772` - 9-5/8" 47#, N-80 CSG, ID = 8.681 7" X4-1 /2" BKR ZXP PKR - 10292` 7", 26#, L-80, LNR ID = 6.276 - 10444' 4-1/2", 12.6#, L-80, LNR ID = 3.958" - 15175` 7" X 4-1/2" BKR ZXP PKR milled and pushed to the top of the 4-1/2" liner PERFORATION SUMMARY REF LOG: ANADRiLL MWD ON 03/30/98 ANGLE AT TOP PERF: 92 @ 11525' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE NOTE: DATE REV BY COMMENTS DATE REV BY COMMENTS 07/09/81 ORIGINAL COMPLETION 10/23/03 BJMcMITL CORRECT PERF/CIBP SET 04/13/98 RIG SIDETRACK 11!18-23/04 DBM/TLP CIBP, ADD PERFS 03/08/01 CWKAK CORRECTIONS 11/17/05 JNC Proposed Completion 08/16/01 CH/tlh PERF CORRECTIONS 10/09/01 CJ/KAK PERF CORRECTIONS 02!24102 DCR/KAK ADPERF &CIBP PRUDHOE BAY UNIT WELL: 16-14A PERMIT No: 1980360 API No: 50-029-20570-01 SEC 24, T10N, R15E, 1534' SNL & 527' EWL BP Exploration (Alaska) ~4 i~ - Z3 74 ~ TIO~tI, ~P/5E, U ~a ~/b . .; 483' l4/7' 504' ~/5 1534' 52 7' "/¢ 1653' ~ 5~8 /3 570' -~ 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND:SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE 8Y ME, AND THAT ALl DIMENSIONS AND OTHEP~ DETAILS RE ORRECT, AS OF: DATE ~}~Z2~8O D.S. 16 - CONDUCTORS 12 THRU 16 AS-BUILT LOCATIONS -STATE PLANE LAT ~ LONG i,~12, Y = i X = LAT = LONG = 3. X LAT = LONG = 5,929.160.99 X14, Y = X = LAT = LONG = ~15. Y = X = LAT = LONG = X16. Y = x= LAT - N /77/' '*/Z 5,929,396.43 719,306,30 •7o°12134,664" 148°13`53.162" 5,929,512087 719,280.83 70°12=35.816" 148°13153.803" 5,929,630.65 719,255,58 70°12'36.982" 148°13:54.437" 719,356.93 .~~tOF ~\Z~ ~_oNG = 70012132.335" ~.~~ , ...'4~,qs~~~ 148 13151.892" ~,`Q•,.••' • 5,929,278.37 j*; 49TH ~ ~~ 719,331.30 ~ .. ........... ......... .. 70°12'33.496" t 48°13 `52.537" = C~A. CRENSiIAw ~ i ~o ~ ~~,•..No. 4277-S . ~ ~ rF •. •• oQ~~ ®`~~ p'~~ffSSIONAt~~~~~-~ \\a ~ _ ~~~ C /~ S'. # /6 / /2-/b ~D,(/DUCT0~4 X9.5 fU/LT AtlanticRichfietdCompany O DATE: DRAWING No: NORTH AMERICAN PRODUCING DIVISION /SE~F.~ .ALASKA DISTRICT - PRUDHOE BAY n 16-14Bi Area of Review Dist. to nearest property line, ft.: Dist. to nearest well within pool, ft: Wells within 1/4 mi. of this injection well within the reservoir Well Status 13,830'East to unit boundary 1600' from 16-20. Closest a roach is 370' Well Name Min. Dist. Ft. Annulus Inte rit Comments 16-20~ 370 Currently on production, 03/21/04: RWO ~ `~ ~ Z$~ completed with new tubing, MIT-T & MIT-IA Passed to 3500# 16-13 ~ 634 Failed IA X OA comm. Well shut-in pending r ~~ m ~-7 RW O 16-21' 902 Failed IA X OA comm. Well shut-in pending t3S 3i z RWO a14~ 435 Plu ed and Sidetracked 16-04A ~ 1139 Producing, IA x OA managed by bleeds. 9 z ~ st 01 /21 /05: M ITOA Passed to 2500 psi 16-01~~ 1272 Online -injecting. 07/13/04: MITIA Passed ~ ~ `~ ~ ~' ~ to 2400 psi, state witnessed by Chuck Scheve Water In~ection, then 2 weeks later MI swa • TERRIE L RUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF r~ L 89-6/1252 24$ DATE ~ ~ $ ~~, e~ First National Bank Alaska Anchorage, AK 99501 MEMO~`~-'^ ~~~ ~: 1 2 5 200060:99 L4~~~6 2 27~~~ L 556~~' 0 248 £- • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~~ ~ ~ ~~ PTD# 2n~~ ~ {F Development ~ Service Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist i i I~~ : I I ~ O ~~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ o ~ ~ o: ~ ~ ~ ~ co c , a' co , II `~ `O j 0i - ~ : ~I ~ ~ ~: ~ ~~ ~', ~ ~': : ~': w ri ~; ~ ~ ~ ~' ~ ~:. ~ ~: ~ I (~ , O : ~ n. ~; i : j ~ ~ ~: ~: ~ ~ : : ~, : ~ ~ ~: : ~ j ~: : I , O u•, a, i , '~ o 'I ~I, y ¢ zi I o: c: i - O 2 y '~ ~ N` ,: ~, ~, N ~ " ~: i i U, i ~ v, y~ vi ~, ~: ~: ~: N O. d': Z ~ ~ ~ U, ~ ~ ~ j, ~ ~: ~ O: a N. I M N~ N~ dM N' Hh UY UA UT N' N' M UY N, p)' N~ N~ N OD N' N• N dl N~ UY~. f/A N~ ~ a~: d: d: a~: a~. m, m: a~: a~: a~: m: a~: m: a~: a~. Q. ¢ ¢: ¢ ¢ ¢, a~: a~. m a~: a~: ¢: m: a~: d: m: a~: a~: m: o: ¢ ¢: ¢ ¢. n >-: ~ ~, ~: ~. >-: ~, ~: ~: ~, }: ~: ~, ~, >-:. Z, Z; Z, Z, Z, Z, >-, ~, ~, >-, }, Z, ~, }, ~, >-, ~: Y, ~, Z, Z, Z, Z, Z, : c, ~ : as : ~' ~: : O: o I ~ : " : ~ . 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N! ~: w w C U. :- '6 V: N N' y O Q: ~>~ p O: ~ 7: V a .C Q, ~ " V O ~ n.~ O ~ 3 O > ~: T Q i O C O O ~ CY C. .y.: G• g y m ~ m '~ m a. m~ N >; O DI O' y E N O a Q a~ ~, n ~ ~ .c is ~: ~" ~_ ~_' ~ ~, ~ ~ m ~; ~ ° c. 4 m ~ ° ~m, ~~ a~ rn o N, a a ~ I o' `~ o ~ 3, m c: v. ~ ~: m n a °~ v o: m a ~ m N ~ ~ c ~: ~ M, ~: ui ~ d y: ° ,~ ,~ ~ a'iri `o o Z n a' c' v v, > ~' •°, m 3 3 ,: m: ~ .. ~ '~. ~ '~ :. o: °: ~.: ~ a N: ~ a n o rn c, i ~: o ~: P~ ~ o p v, o ~: ~: ~ a m: o ~ ~ a ~: ~ o 0 0: a: a o Y ~ o o ar ~ ~: o m ~ ~ U :o: ° °' ,~ N' c, 0. f= o a v' N `m' .Q Ti, ° ° a c' d. ~' C} n Q :: ~ - •° ~ ~ y' v m' ~ rn o .. ~ c o 0 otS ~I t' a m: ~ a a ~ y ~ a N ur a r: ~ m. V-' o: m' a> co' a~ `of c ca 3 N: ~ ' N a ar c s' U: f6 ~: O: O: a N, N f0, C O O f6, l6, f6 ~ O T 2. N~ 'O N O a v OI m m ~: a a a``ai 3' m' `° °, y an 3: c rn l ~ ~' a 'ar ~' c' Y ~; ~: '~ ° ~ ~ o, ~: ~ o o: u~ >, "' y: ~ ~, ~ ~ ~: -o: -o: v: U ~'. ~ ~: .n: n ~: -a 's a-°r :a i w' 'A' v a o •N :°- ~ 3 d v o ~ c c~ ° °: I ~: c ~ ~ ~: lL a~ m E' ar +:' :: :?~ f0 ti a ~ c c ~. ~3 ~ c I.- ca m' m. U ar _ ~ -p ~ m' ° ~' ~' i ° ~ m;. ~', c. w w c ° c~ U 0 0 ° ° v ~ o ii i ti o o. v' m v` m: ~ ~ vi q E' '-~~ a~ c ~, ~' ° -p f"i cn ar o' o a ~ ~ ~; m - n -°, a~, a ~ ~ c~' > > 3 ~? ° ° o o ~ w w: ° yr m a ' ~, m ~ m,, '€ N ~ -' - +~°- a>i a~, a~ ~: ~ c -. 3. a ~ ! c~ ~ H H I-, 'y: ~ ~ >_ - n. ~., o', Yo n ~ I ~; m ~ ~: c: m: ~ c, a~ a~ d' ° v a a m. m m ° ~ U ~ o. ° ~, ~' ~ co, a ~. v, v - O O: ~: m a~: ~ m a~: o: v ~ a, ~ ~, ~; ~, ~: cn ~, o; o a, a U; ~': a; a, ¢ ~ U, cn, U, v; U; v, ¢ ~-: ¢. w o, m, m, U, ~: ": ~ ~ a, o ~, ~, U, W a G r -- - 0----N M 'a ~ O O O O N M a~ O n O O) O N M I I. O O n O O) N M.~ ~!") t0f~ t0_O ~- ~ N_ N N N N N N N.N N M M M M M'M M M M M U U __ I, }----- - -7- ~------ ---------- p ~ O O N p d O G7 O O O ~ N ~ N ~ N Q!. M O 0 N ~ 0 r Q N a'~~ ~ ~i ` O y ~ d I ~` ,.N C a. U C QQ i O aV w~ ~E a s , a~ a c7 ~ a s ~ as Iw I~~_ ~.J Q :? \ 0 d a m O ~ rn~ C C O .~ .y c ~ c o W U ui O 'ate N U = O O N c~ ~ O U • Well History File APPENDIX • Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and io simplify rending information, information of this nature is accumulated at the. end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. r 16-14b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 03 11:12:40 2008 Reel Header Service name .............LISTPE Date . ...................08/03/03 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/03/03 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0004208242 A. SHANAHAN D. MASKELL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services 16-14B 500292057002 BP Exploration Alaska, Inc. Sperry Drilling Services 03-MAR-08 MWD RUN 2 MWD RUN 3 Mw0004208242 Mw0004208242 A. SHANAHAN A. SHANAHAN D. MASKELL D. MASKELL 24 lON 15E 1534 527 67.00 38.50 Page 1 • • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: File Header 16-14b.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 9916.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 16-14A WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 9916'MD/8835'TVD. 4. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. RUNS 2 & 3 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). MWD RUN 2 ALSO INLCUDED AT-BIT INCLINATION (ABI). UPHOLE TIE-IN SGRC DATA ACQUIRED WHILE POOH AFTER REACHING TD ON RUN 2 WERE MERGED WITH RUN 1 MWD DATA. 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE ANADRIL GAMMA RAY LOG RUN IN 16-14A ON 30 MARCH 1998. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 10 DECEMBER 2007, AS AUTHORIZED BY COLE ABEL (BP). THIS SHIFTED DATASET IS THE PDCL FOR 16-14B. 7. MWD RUNS 1-3 REPRESENT WELL 16-14B WITH API#: 50-029-20570-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15307'MD/8990'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. Page 2 • i 16-14b.tapx Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9822.0 15259.0 RPS 9909.5 15266.0 FET 9909.5 15266.0 RPM 9909.5 15266.0 RPD 9909.5 15266.0 RPx 9909.5 15266.0 ROP 9930.5 15317.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9822.0 9811.5 9822.5 9812.0 9827.0 9817.0 9847.5 9838.0 9849.5 9842.0 9883.5 9876.0 9885.5 9877.5 9895.0 9887.5 9904.0 9895.0 9913.0 9903.0 9916.0 9906.5 9918.0 9908.0 $5317.5 15307.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 9811.5 9943.0 MwD 2 9943.0 10847.0 MwD 3 10847.0 15307.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Page 3 • 16-14b.tapx Absent value .... ..................-999 Depth units. .. . . ..... Datum specificat ion Block sub-type...0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9822 15317.5 12569.8 10992 9822 15317.5 RPD MWD OHMM 1 1626.55 9.064 10714 9909.5 15266 RPM MWD OHMM 0.09 2000 9.92558 10714 9909.5 15266 RPS MWD OHMM 1.21 2000 7.55848 10714 9909.5 15266 RPX MWD OHMM 0.42 1352.47 6.49764 10714 9909.5 15266 FET MWD HOUR 0.35 41.24 2.23804 10714 9909.5 15266 GR MWD API 9.49 187.69 33.7986 10875 9822 15259 ROP MWD FT/H 0.09 704.22 84.0518 10775 9930.5 15317.5 First Reading For Entire File..........9822 Last Reading For Entire File...........15317.5 File Trailer service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/03 Maximum Physical Record..65535 File Type ................L0 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.......08/03/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY Page 4 16-14b.tapx VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9811.5 9876.0 ROP 9920.5 9943.0 LOG HEADER DATA DATE LOGGED: 15-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9943.0 TOP LOG INTERVAL (FT): 9916.0 BOTTOM LOG INTERVAL (FT): 9943.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9916.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 56.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 9500 FLUID LOSS (C3): 6.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 145.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Page 5 16-14b.tapx Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9811.5 9943 9877.25 264 9811.5 9943 GR MWDO10 API 91.96 187.69 148.874 130 9811.5 9876 ROP MWDO10 FT/H 0.23 12.63 4.12696 46 9920.5 9943 First Reading For Entire File..........9811.5 Last Reading For Entire File...........9943 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/03 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.......08/03/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 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 GR 9876.5 10780.0 FET 9900.0 10787.0 RPD 9900.0 10787.0 RPX 9900.0 10787.0 RPS 9900.0 10787.0 RPM 9900.0 10787.0 ROP 9943.5 10847.0 LOG HEADER DATA DATE LOGGED: SOFTWARE 17-FEB-06 Page 6 • i 16-14b.tapx SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10847.0 TOP LOG INTERVAL (FT): 9943.0 BOTTOM LOG INTERVAL (FT): 10847.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.1 MAXIMUM ANGLE: 90.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9916.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 52.0 MUD PH: 9,2 MUD CHLORIDES (PPM): 10000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .320 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .190 122.0 MUD FILTRATE AT MT: .780 70.0 MUD CAKE AT MT: .530 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 Page 7 ' • • 16-14b .tapx FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9876.5 10847 10361.8 1942 9876.5 10847 RPD MWD020 OHMM 1 1626.55 22.556 1775 9900 10787 RPM MWD020 OHMM 0.09 2000 29.8015 1775 9900 10787 RPS MWD020 OHMM 1.21 2000 16.6943 1775 9900 10787 RPX MWD020 OHMM 0.42 1352.47 11.4058 1775 9900 10787 FET MWD020 HOUR 0.9 33.81 3.78943 1775 9900 10787 GR MWD020 API 14.33 130.53 37.5747 1808 9876.5 10780 ROP MWD020 FT/H 0.09 192.46 48.1401 1808 9943.5 10847 First Reading For Entire File..........9876.5 Last Reading For Entire File...........10847 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/03 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.......08/03/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLi6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10780.5 15249.0 RPx 10787.5 15256.0 RPD 10787.5 15256.0 RPM 10787.5 15256.0 RPS 10787.5 15256.0 FET 10787.5 15256.0 ROP 10847.5 15307.5 Page 8 • 16-14b.tapx LOG HEADER DATA DATE LOGGED: 24-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15307.0 TOP LOG INTERVAL (FT): 10847.0 BOTTOM LOG INTERVAL (FT): 15307.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $$,2 MAXIMUM ANGLE: 92,5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9916.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 49.0 MUD PH: 9,3 MUD CHLORIDES (PPM): 3500 FLUID LOSS (C3): 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .420 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .170 184.0 MUD FILTRATE AT MT: 1.870 70.0 MUD CAKE AT MT: .660 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 Page 9 • • 16-14b.tapx RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 RoP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10780.5 15307.5 13044 9055 10780.5 15307.5 RPD MWD030 OHMM 2.19 30.01 6.32926 8938 10787.5 15256 RPM MwD030 OHMM 2.09 33.71 5.96935 8938 10787.5 15256 RPS MWD030 OHMM 2.01 33.15 5.67055 8938 10787.5 15256 RPX MWD030 OHMM 1.95 28.27 5.52357 8938 10787.5 15256 FET MWD030 HOUR 0.35 41.24 1.92662 8938 10787.5 15256 GR MWD030 API 9.49 140.96 31.418 8938 10780.5 15249 ROP MWD030 FT/H 9.16 704.22 91.7421 8921 10847.5 15307.5 First Reading For Entire File..........10780.5 Last Reading For Entire File...........15307.5 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/03 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/03 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/03/03 Ori in ...................5T5 Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF writing Library. writing Library. Page 10 Scientific Technical services scientific Technical services Physical EoF End Of LIS File 16-14b.tapx Page 11
