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202-156
'" ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .:Q 0:1- 1-5 b Well History File Identifier Page Count from Scanned File: l} L- (Count does include cover sheet) Page Count Matches Number in scann;ng Preparation: V yt=S NO Helen ..~ Date: I àS O.s- Isl If NO in stage 1, page(s) discrepancies were found: Organizing (done) ~Wo-Sided 1111111111111111111 REJCAN },ØColor Items: 0 Greyscale Items: DIGITAL DATA ,z¡;;S, kettes No. I 0 Other, NolType: 0 Poor Quality Originals: 0 Other: NOTES: BY: Helen ~ Project Proofing BY: Helen~a ) Scanning Preparation 1 x 30 = --3 0 BY: Helen ~ Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~scan Needed I OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds: D Other:: ,: P Date: I ;t:5 OS Is/ n1i' , I Date: I 9- ~ Ó s;- /s/ rill P , + 13 = TOTAL PAGES ~"j (Count do's nO,t in~ude cover sheet),/) A,' P Date: J ;}.:S Ó¿;- /s/ r V I I mp YES NO Date: Is/ I I Date: /s/ Quality Checked 1111111111111111111 BOPE usage report: Nabors 7ES well R -14B • • Page 1 of 1 Regg, James B (DOA) From: Rall, John R RalIJR2 BP.com] r/ Sent: Thursday, October 27, 2011 6:27 AM To: DOA AOGCC Prudhoe Bay Cc: Daniel, Ryan; Kilfoyle, Jeffery A; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft); Schultz, Mikel; Willingham, James M; AK, D &C Rig 7ES Well Site Leader; Allen, Kenneth W; Egbejimba, Uchenna J Subject: BOPE usage report: Nabors 7ES well R -14B Attachments: R -14B 10- 26- 2011.doc «R -14B 10- 26- 2011.doc» John Rall Wells Operations Superintendent �r -- Office: 659 -4618 Cell: 907 - 980 -2589 • 11/4/2011 • ! Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Mak rs 7Fs Field Superintendent Name: John Rall Welisite Leader Name: Dan Shearer Contact Number: 659 4618 Contact Number: 659 4835 Traction Number: 2011 -IR- 3976671 Well Location & Name: R pad well 14B Permit To Drill (PTD) Number: 202 -156 Date and Time of Incident: 26 October 2011. 17:00 hrs Original Scope of Work: Pulling out of the hole to replace failed MWD equipment. Operational Description Leading up to Well Control Event: Finished circulating a bottoms up at the 7" casing window. BOPE Used and Reason: Driller observed more flow than expected after circulating. Driller flow checked the well and the flow was not decreasing so the driller performed a hard shut -in of the well using the annular preventer. Is a BOPE Test Required after use (Yes / No): If no, why? Yes. Will need to test the Annular Preventer, Choke HCR, IBOP, and choke valves 2, 4, 7, 10, 12, and 14. °O 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: The well was shut in, an exhale test was completed and the well flowed back 2 bbls of mud. Shut -in and monitored pressures - 10 psi. Circulated 4bbls through the choke to keep from freezing top drive. Monitored pressures and found well to be stable. Opened well and circulated a bottoms up prior to returning to normal operations. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aogcc.prudhoe.bavAalaska.gov Email CC List Well Integrity Team Leader Ryan Daniel HSE Advisor Jeff Kilfoyle Engineering Team Leader Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager Steve Rossberg Wells Intervention Manager Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC August 2, 2010 HRE 1 STATE OF ALASKA • ALASAPOIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ■:• Abandoned • ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 El Development • ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 9/22/2011 ' 202 - 156 - 311 - 138 3. Address: 6. Date Spudded: 13. API Number. P.O. Box 196612, Anchorage, Alaska 99519 11/09/2002 50 029 - 20909 - 01 - 00 • 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/11/2002 PBU R -14A 1444' FSL, 1756' FWL, SEC. 32, T12N, R13E, UM 8. KB (ft above MSL): 53.5 1 5. Field / Pool( s ) Top of Productive Horizon: 817' FSL, 2541' FEL, SEC. 31, T12N, R13E, UM GL (ft above MSL): 20' Prudhoe Bay Field / Prudhoe Bay • Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 465' FSL, 3516' FEL, SEC. 31, T12N, R13E, UM 3046' 3015' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 635391 • y- 5977927 • Zone- ASP4 11378' • 8819' . ADL 028279 . TPI: x - 631107 y- 5977224 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 630140 Y 5976855 Zone- ASP4 N/A 18. Directional Survey: 0 Yes 181 No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MWD, GR, RES 9888' 8644' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING Wr. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 2697' Surface 2685' 17 -1/2" 3535 cu ft Permafrost I1 9-5/8" 47# L -80 Surface 9823' Surface 8590' 12 -1/4" t• cu ' ass . • cu " 7" 26# L -80 9566' 9888' 8379' 8644' 8 -1/2" 10 cu ft Class 'G' 5" 18# C -95 9504' 9888' 8330' 8644' N/A 1 • cu . ass trier le a 3-1/2" 9.2r 6.2# L -80 9366' 11378' 8220' 8819' 3-3/4" Uncemented Slotted Liner 24. Open to production or injection? ❑ Yes El No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 5 -1/2 ", 17 #, 13Cr 3259' - 9505' 9395' / 8243' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8490' Pumped 25 BBIs of Class 'G' . 10iN -•) `? ; t r :. (I 4 /Irk/ 7095' Pumped 81 Bbls of Class 'G' 3068' Set EZSV 3068' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 4 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes Ei No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, phot• ,,•sand laboratory analytical results per 20 AAC 250.071. 0,0 • ( None icr `1 7 nil RBDMS OCT 17 2011 Alaska Oil & Gay r 4n s . C Or r�►r Form 10-407 Revised 12/2009 j / CONTINUED ON REVERSE Submit Original Only 5ia1/20 ,. `s1Iz 29. GEOLOGIC MARKERS (List all formations aillarkers encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ■:■ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit 10152' 8725' None Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' QJ Signed: Terrie Hubble ° s u Q .!� l 1 Title: Drilling Technologist Date: ` O /1 f PBU R - 14A 202 - 156 311 - 138 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: John Rose, 564-5271 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123-00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • R -14A, eII History (Pre Rig Sidetrack) Date Summary 07/21/11 RAN IN HOLE TO DEVIATION AT 9937'. LOGGED UP AT 30 FPM WHILE PUMPING 80 °F CRUDE DOWN IA AT .5 BPM LOOKING FOR IA LEAK. LEAK FOUND AT 9360' AT BOTTOM OF TUBING PATCH. PUMPED TOTAL OF 230 BBLS CRUDE DOWN IA TO FORMATION. FINAL T /I /O = 0/600/60 PSI. JOB COMPLETE. WELL LEFT SHUT IN UPON DEPARTURE) . 07/21/11 T /I /0= 180/500/0. (Injectivity test). Spear into tbg w/ 5 bbls 60/40 meth followed by 291 bbls 1% KCL @ max rate of 5 bpm. Pumped all fluid @ 5 bpm. Pressure never exceeded 430 psi. Freeze protect tbg w/ 63 bbls diesel. FWHP = 0/760/0. 07/24/11 T /I /O= VAC /380/70. Temp =Sl. WHPs. Monitored pressures @ 19:00 PM and @ 3:30 AM 7/25/11, w /no changes on WHPs. 07/24/11 MIRU. Pump 360 1% KCL sweep down TBG. 10 bbls chemical wash, 25 bbls of class G cement, 2 bbls FW, launched 8" foam pig, 5 bbls FW, chasing with 195 bbls of 70 °F diesel placing TOC @ —8668' MD. No indications of cement entering perforations so shut down early with consideration of shallowest TOC of 8500'. Bleed T /IA/OA. Called Pad Op and requested well to be left shut in. Grease crew called out to service tree. DHD notified that visual on tbg pressure needed and bled down if needed. Stage 1 of Cement Job Complete. Will be back after S/L confirms TOC for Stage II of P &A. 07/26/11 WELL S/I ON ARRIVAL. RAN 2 -1/2" SAMPLE BAILER TO TOC @ 8,490' SLM (8,507' CMD). RECOVERED CEMENT IN SAMPLE BAILER. BRUSHED TBG. HANGER W /7" BRAIDED LINE BRUSH. PERFORM PASSING MIT -T TO 3,500 PSI (140/40). PULLED STA.# 3 RM -DGLV @ 8,393' SLM ( +17' CORR. TO 8,410' MD). WELL S/I ON DEPARTURE, PAD -OP NOTIFIED OF STATUS. 07/26/11 T /I /O =SI (SIDETRACK) CMIT TxIA 3000 psi. 07/27/11 MIRU. Pump 555 BBLs 1% KCL sweep down tubing, 130 BBLs diesel, 196 BBLs 1% KCI, 10 BBLs chemical wash, 81 BBLs of class G cement, 2 bbls FW. Launched 7" wiper ball. Pumped 5 bbls FW, chasing with 102 BBLs of 70 °F diesel placing TOC @ —7205' MD. Called Pad Op and requested well to be left shut in. Grease crew called out to service tree. Stage 2 of Cement Job Complete. 07/29/11 WELL S/I ON ARRIVAL. DRIFT TO 6,908' SLM W/ 4.50" CENT, S -BLR (Recovered small chunk of cement). TAGGED TOC @ 7,095' SLM W/ 3.00" S -BLR (Bailer full of cement). BRUSHED BPV PROFILE W/ 7" BRUSH (No issues). PERFORMED PASSING MIT -T TO 1000 PSI W/ TRI -PLEX. WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS. 07/31/11 WELL SHUT IN ON ARRIVAL. INITIAL T /I /0= 50/50/0 TUBING CUT AT 3259' WITH 4.15" POWER CUTTER CCL TO CUT= 11.6' CCL STOP DEPTH = 3247.4'. PRESSURE UP ON TUBING AND MONITOR IA FOR TXIA COMMUNICATION TO VERIFY CUT, IA INCREASE 100 PSI WHILE PUMPING. FINAL T /I /O= 100/100/0 NOTIFY DSO OF VALVE POSITIONS. JOB COMPLETE LEAVE LOCATION. 08/03/11 T /I /O = 100/100/0 Inspected all valves on tree. (Pre -rig) 6 x 7 McEvoy Big Bore with Axelson double clamp actuator. Each valve should have 26 turns. MV =24 1/2 turns. SV= 20 1/2 turns. WV =26 turns. SSV would not close all the way. (1/2" from being fully shut) Shut swab valve and tested to 3500 psi. Good test. Job Complete. 08/04/11 T /I /O =SI /400/0 (Pre Post Rig /Replace Swab Valve) Verified barriers, bled off above SSV and removed tree cap, pulled old 6 3/8 swab valve and replaced w/ 6 3/8 CIW FLS and torqued to 1281 ft lbs, pressure tested low 500 psi 5 min (PASS) high 4800 psi 5 min (PASS). 08/04/11 T /I /0= 100/0/0 Pressure tested against Master, Wing 1000 psi. /5 min. Pass... Pressure tested against SSV, Wing. SSV would not fully close, could not get to test pressure of 1000 psi. Page 1 of 2 • • • R -14A, Well History (Pre Rig Sidetrack) Date Summary 08/05/11 T /I /0= 160/0/0 Upon arrival, verified barriers (Master Valve, with WSL approval) to remove swab cap. Pass. Attached Lubricator, pressure tested low /300 psi. high /3500 psi. Pass. Tried to set 6 3/8" CIW "J" TWC #423 thru tree using Cameron lubricator. Tagged @ 127" TWC locked into anti - rotation slot but dogs would only come out 2 turns. Reversed 2 turns and tried to remove plug but pins sheared. Retracted lubricator, removed, attached pulling tool, pressure tested, and retrieved plug. Attached new TWC #422, pressure tested, set TWC. Tagged @ 127" Achieved full 7 turns. Tubing would not bleed off (160 psi.) Pressure Tested from above to 3500 psi. TWC held, but would not bleed off from below. Removed lubricator, attached pulling tool, pressure tested, pulled TWC. 08/05/11 T /I /O = SSV /140/0 +. Temp = SI. Bleed IA and OA to 0 psi (RST prep). ALP = 160 psi, SI @ casing valve. IA FL @ 100'. Bled IAP to 0 psi in 20 min (gas). Monitor 30 min. IA FL, IAP & OAP unchanged. Final WHPs = SSV /0/0 +. Job complete. 08/06/11 T /I /O= BPV /0 +/0 +, Temp =Sl. PPPOT-T (PASS), PPPOT -IC (PASS) pre RST. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (2.5 "), all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (2.5 "), (one LDS broken, 7:00 position, flagged) all the rest moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 08/06/11 T /I /0= 10/0/0 ( Pre Rig) Verified barriers. Rigged up lubicator and tested to 350 psi low 5 min (PASS) high 3500 psi 5 min (pass). Set 6 3/8 CIW (J) #401 BPV @ 127 no problems. 08/16/11 T /I /O = NA/0 +/0 +. Temp = SI. Assist Cameron (drillout LDS). Wellhouse, flowline, AL spool, and scaffold removed. Assisted Cameron with open bleed on both the IA and OA for LDS replacement. 09/09/11 T /I /O = 0 +/0 +/0 +. Temp = SI. Test BPV from below to 1000 psi (FAILED), MIT -OA to 2000 psi (PASSED) (RWO prep). Well house, flowlline, AL spool and scaffoling removed. T, IA & OA FL near surface. Pumped 3.7 bbls diesel to reach 2000 psi test pressure on OA. Lost 61/28 psi in 15/30 min test. Pumped 6.3 bbls deisel to reach 1000 psi test pressure on IA. Tubing tracked. 1034/1000/131. Monitor for 30 min. 1002/965/131. Bled TP & IAP back. Final WHPs = 150/120/0 +. Page 2 of 2 . • 0 North America - ALASKA - BP Page 1.1 Operation Summary Report Common Well Name: R -14 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/15/2011 1 End Date: `X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 11/6/2002 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292090900 Active Datum: R -14 ©53.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/15/2011 06:00 - 07:00 1.00 RIGD P PRE ' BEGIN DRILLING EVENT AT 06:00 ON 9- 15 -11. GENERAL RIG DOWN OPERATIONS IN l . PREPARATION FOR RIG MOVE. 07:00 - 08:00 1.00 MOB P PRE I MOVE RIG OFF R -12 WELL. 08:00 - 00:00 16.00 MOB N WAIT PRE STAGE RIG ON R PAD. WAIT ON PAD PREP WORK AROUND R -14 WELLHEAD. TEST EMERGENCY SHUT DOWN DEVICES ON RIG. 9/16/2011 00:00 - 21:00 21.00 MOB N WAIT PRE ' WAIT ON PAD PREP AROUND R -14 WELLHEAD. CONDUCT RIG EVACUATION / 1 H2S DRILL AND AAR. HOLD PRE -SPUD MEETING WITH RIG CREW. PERFORM VISUAL INTERNAL INSPECTION OF BOP ELEMENTS. NOTIFIED AOGCC AT 10:00 AM OF INTENTION TO TEST BOP AT 10 AM ON 9/17/2011. 121:00 - 00:00 3.00 MOB N WAIT PRE PULL DRILLING SCAFFOLDING FROM AROUND WELL. LAY RIG MATS ON PAD l BUILD UP. DISCONNECT CAMP AND SHOP 1 FROM RIG ELECTRICITY. PREPARE FOR RIG I MOVE TO R -14. 9/17/2011 00:00 - 02:00 2.00 MOB P I PRE MOVE NABORS 7ES RIG OVER WELL R -14 FROM STAGING AREA ON R PAD. 02:00 - 04:00 2.00 RIGU P PRE 1 SPOT PIT MODULE AND RIG UP. SPOT _ 1 CUTTINGS BOX. 1 04:00 06:00 2.00 WHSUR P 1 t DECOMP INSTALL DOUBLE VALVES ON WORKING SIDE OF OA AND IA. PRESSURE TEST VALVES TO 1 250 PSI LOW AND 3500 PSI HIGH. 06:00 - 09:00 3.00 RIGU P 1 DECOMP ACCEPT RIG AT 06:00 ON 9- 17 -11. TAKE ON 580 BBLS 8.5 PPG SEAWATER. LOAD 5" DRILLPIPE IN PIPE SHED AND STRAP. RIG UP RETURNS TANK AND HARDLINE. 09.00 - 12:00 3.00 CASING t P DECOMP 7 PERFORM MIT -OA TO 250 PSI LOW FOR FIVE 1 ' MIN AND 2000 PSI HIGH FOR 30 MIN. PERFORM CMIT -TXIA TO 250 PSI LOW FOR ( FIVE MIN AND 2000 PSI HIGH FOR 30 MIN. SEE ATTACHED CHART. 12:00 P DECOMP 12:30 0.50 WHSUR MIRU VALVE SHOP LUBRICATOR CREW. 12:30 - 17:00 4.50 WHSUR N SFAL DECOMP PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. 17:00 - 18:00 1.00 WHSUB 1 P DECOMP I PULL BPV AND RDMO VALVE SHOP } i LUBRICATOR CREW. 18:00 - 19:00 1.00 PULL P DECOMP RIG UP TO CIRCULATE OUT FREEZE - -- PROTECT IN TUBING AND IA. 19:00 20:00 1.00 PULL P DECOMP tCIRCULATE 250 BBLS 8.5 PG 2% KCL AT 8 BPM, 700 PSI DOWN TUBING. DIESEL RETURNS DIVERTED TO RETURNS TANK OUTSIDE RIG. MONITOR TUBING AND IA FOR FLOW AFTER SHUT DOWN. WELL STATIC. NOTE: BEGIN OA MONITOR PERIOD FOR - 1_9 -5/8" CASING PACKOFF CHANGEOUT. Printed 9/26/2011 11:35:52AM ' North America - ALASKA - BP . Page 2 Operation Summary Report Common Well Name: R -14 'AFE No Event Type: RE- ENTER- ONSHORE (RON) l Start Date: 9/15/2011 End Date: X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay Site: PB R Pad I Rig Name /No.: NABORS 7ES I Spud Date/Time: 11/6/2002 12:00:OOAM ! Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. IUWI: 500292090900 Active Datum: R -14 @53.48ft (above Mean Sea Level) Date I From - To I Hrs I Task I Code 1 NPT NPT Depth Phase 1 Description of Operations I (hr) (ft) 20:00 - 23:00 3.00 WHSUR P DECOMP MIRU VALVE SHOP CREW. PRESSURE TEST 1 LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. INSTALL TWC. PRESSURE TEST FROM BELOW TO 250 LOW AND 2000 PSI HIGH FOR FIVE MIN EACH. PRESSURE TEST FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. RDMO VALVE ' SHOP LUBRICATOR CREW. 23:00 - 00:00 1.00 WHSUR I P J_ DECOMP NIPPLE DOWN TREE. 9/18/2011 00:00 - 02:30 2.50 WHSUR t P DECOMP !NIPPLE DOWN MCEVOY /CAMERON 6 -3/8" X 7- 1/16" 5K TREE AND 13 -5/8" X 7- 1/16" 5K MCEVOY TUBING SPOOL. MAKEUP IJ4S XO 'TO TUBING HANGER (6 -1/2" TURNS). BACK OUT AND RUN IN LOCKDOWN SCREWS. 02:30 - 06:00 I 3.50 BOPSUR P DECOMP , NIPPLE UP HYDRIL 13 -5/8" 5K BOP STACK - GK ANNULAR PREVENTER - 3 -1/2" X 6" UPPER PIPE VARIABLE BORE I I :RAMS - BLIND -SHEAR RAMS I - CHOKE AND KILL LINE FLOW CROSS - 2 -7/8" X 5" LOWER PIPE VARIABLE BORE ' { RAMS ' - 2' SPACER SPOOL WITH TWO SIDE -- - I OUTLETS. Printed 9/26/2011 11:35:52AM North America - ALASKA - BP Page 3 a Operation Summary Report Common Well Name: R -14 ' AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/15/2011 End Date: X3- 00YRC -C: (5,042,419.00 ) 4 Project: Prudhoe Bay ; Site: PB R Pad Rig Name /No.: NABORS 7ES 1 Spud Date/Time: 11/6/2002 12:00:OOAM I Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292090900 Active Datum: R -14 @53.48ft (above Mean Sea Level) Date From - To Hrs Task ' Code NPT NPT Depth I Phase ' Description of Operations (hr) 1 (ft) 06:00 - 16:30 10.50 1 BOPSUR P DECOMP PRESSURE TEST BOPE PER AOGCC REGULATIONS AND BP ADWOP. JOHN CRISP, AOGCC REPRESENTATIVE, ON 1 OCATION TO WITNESS TESTING. ALL TESTS WITNESSED BY BP WSL AND NABORS ' I 1 TOOLPUSHER (SEE ATTACHED SIGNED PRESSURE CHARTS AND TEST REPORT). - 24 HOUR NOTICE WAS PROVIDED TO AOGCC AT 10:00 ON 9/16/11. - PRESSURE TEST FOLLOWING 'COMPONENTS TO 250 PSI LOW AND 3500 PSI I HIGH FOR 5 MINUTES EACH. - ALL CHOKE MANIFOLD VALVES (16 1 TOTAL) + CHOKE/KILL LINES ■ - MANUAL CHOKE AND MANUAL KILL LINE ;VALVES - HCR CHOKE AND HCR KILL VALVES (CLOSING AND 5" ULL OPENING SAFETY " L VALVE. 5" FOSV FAILED FIRST TEST. CHANGE OUT AND RE -TEST. 1 - 4" AND 5" DART VALVE 1 - BLIND /SHEAR RAMS (CLOSING TIME = 13 i SEC) 1 - LOWER PIPE RAMS WITH 4" TEST JOINT (CLOSING TIME = 7 SEC) - ANNULAR PREVENTER WITH 4" TEST JOINT (CLOSING TIME ON 4" TEST JOINT = 26 ISEC) - UPPER PIPE RAMS WITH 4" TEST JOINT I (PASS), 5-1/2" TEST JOINT (FAIL) - TOP DRIVE AIR ACTUATED IBOP AND MANUAL IBOP (BOTH FAIL) - TEST THE HYDRAULIC SUPER CHOKE AND ' MANUAL BEAN CHOKE TO 1500 PSI HIGH FOR 5 MIN. 1- PERFORMED AN ACCUMULATOR DRAWDOWN TEST. - STARTING ACCUMULATOR PRESSURE = 3050 PSI I - FINAL PRESSURE AFTER FUNCTIONING ALL PREVENTERS AND TWO HCRS = 1700 PSI I ' 1 - 16 SEC TO BUILD 200 PSI TO 1900, 87 1 SEC TO FULL 3025 PSI PRESSURE. - 5 NITROGEN BACKUP BOTTLES WITH 11 1 12200 PSI. i - CALIBRATED AND TESTED THE SIERRA GAS MONITORING SYSTEM DURING INITIAL MIRU. - PRESSURE TESTING CONCLUDED ON 9- 19 -11. 16:30 19:00 2.50 BOPSUR N RREP I DECOMP CHANGEOUT MANUAL AND AIR ACTUATED � + ! IBOPS ON TOP DRIVE. 19:00 - 21:30 2.50 BOPSUR N RREP I DECOMP TROUBLESHOOT AIR ACTUATED IBOP. 1 21:30 - 00:00 2.50 BOPSUR N RREP DECOMP RE-TEST UPPER PIPE RAMS WITH 5 -1/1/ 2" TEST JOINT (FAIL). CHANGEOUT UPPER 1 PIPE RAMS. -- --- — CHANGEOUT UPPER PIPE RAMS. RREP .', C 9/19/2011 00:00 - 01:00 1.00 I BOPSUR N 1 DECOMP � 1- Printed 9/26/2011 11:35:52AM North, America - ALASKA - BP 4 Page 4'B. Operation Summary Report Common Well Name: R -14 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/15/2011 End Date: 1X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 11/6/2002 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. [UWI: 500292090900 Active Datum: R -14 @53.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase ' Description of Operations (hr) O 01:00 - 03:00 2.00 BOPSUR P DECOMP PRESSURE TEST FOLLOWING EQUIPMENT TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH (SEE ATTACHED CHARTS). 1- UPPER PIPE RAMS WITH 4" AND 5 -1/2" TEST , JOINT - MANUAL AND AIR ACTUATED IBOPS ON TOP ' DRIVE - LOWER PIPE RAMS WITH 5" TEST JOINT 03:00 - 03:30 0.50 BOPSUR P DECOMP [RIG DOWN BOP TESTING EQUIPMENT. 03:30 - 05:30 2.00 WHSUR P DECOMP I MIRU VALVE SHOP LUBRICATOR WITH DUTCH RISER AND PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. PULL TWC. RDMO VALVE SHOP LUBRICATOR CREW. 05:30 07 :00 1.50 PULL P DECOMP RIG UP TO PULL 5 -1/2" TUBING. BACK OUT TUBING HANGER LOCK DOWN SCREWS. 07:00 - 08:00 1.00 PULL P DECOMP ENGAGE 12" X 7" IJ4S TUBING HANGER AND PULL TO RIG FLOOR. STRING WEIGHT = 80 KLES. NO OVERPULL REQUIRED TO UNSEAT HANGER. MONITOR WELL FOR 30 MINUTES. LAYDOWN HANGER AND LANDING JOINT. 08:00 - 09:30 1.50 PULL P DECOMP CIRCULATE 40 BBL SAFE - SURF -O PILL SURFACE TO SURFACE. CHASE WITH 8.5 PPG 2% KCL AT 13 BPM, 175 PSI. CHECK FOR FLOW. WELL STATIC. RIG UP SLB SPOOLING UNIT. SLOW PUMP RATES AT 08:45, 3229' MD, 3187' ND: MP #1 2 BPM / 20 PSI, 3 BPM / 25 PSI — ' I I MP #2 2 BPM / 20 PSI, 25 PSI / 3 BPM 1- 09:30 14:30 5.00 PULL P DECOMP LAYDOWN 5 -1/2 ", 17 #,13CR, NSCC TUBING FROM JET CUT AT 3259' MD. RECOVER [TUBING HGR, 7 "X5-1 /2" XO PUP, 80 FULL ! JOINTS 5 -1/2" TUBING, 4 PUP JOINTS, 1 GLM WITH PUPS, 1 CUT JOINT (4.07' WITH 6 -1/4" FLARE, GOOD QUALITY), 2 SS BANDS, 27 I CONTROL LINE PROTECTORS AND PINS. 14:30 15:30 1.00 PULL P DECOMP j RIG DOWN TUBING EQUIPMENT AND INSTALL WEAR BUSHING. 15:30 - 19:00 I l i 3.50 CLEAN P DECOMP MAKEUP 8 -1/2" CLEANOUT BHA WITH WATERMELON MILL, BUMPER JARS, (9) 6 -1/4" DRILL COLLARS, (15) JTS 5" HWDP. TOTAL BHA WEIGHT = 33 KLBS. _ 19:00 - 23:00 4.00 CLEAN P DECOMP PICKUP 5" DRILLPIPE AND TIH WITH 8 -1/2" OT A ' MD. BREAK CIRCULATION CLEAN CLEANOUT AA WORK 3138 MILL ACROSS EZSV SETTING DEPTH, 3043' - 3138' MD; 50 RPM, 1.2 KFT -LBS TORQUE, 250 GPM, 225 PSI. CONTINUE IN HOLE AND TAG TBG STUB AT 3250' DPM (9' ABOVE JET CUT AT 3259' ELM). SLACK OFF 10 KLBS ON STUB TO CONFIRM. 23:00 - 00:00 1.00 PULL P DECOMP CIRCULATE 40 BBL HI-VIS SWEEP SURFACE j TO SURFACE; 581 GPM, 835 PSI. SLOW PUMP RATES AT 23:30, 3250' MD, 3197' ND: MP #1 AND MP #2 2 BPM / 30 PSI, 3 BPM _ I / 60 PSI. Printed 9/26/2011 11:35:52AM ' North America - ALASKA - BP Page 5 af46 • 0 Operation Summary Report Common Well Name: R -14 l AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/15/2011 1 End Date: X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay Site: PB R Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 11/6/2002 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292090900 Active Datum: R -14 @53.48ft (above Mean Sea Level) Date From - To 1 Hrs I Task Code NPT I NPT Depth Phase I Description of Operations ft 9/20/2011 00:00 - 01:30 1.50 CLEAN P ' r DECOMP I TOH FROM TUBING STUB AT 3250' TO BHA AT 100 CHECK FOR FLOW PRIOR TO BHA ENTERING STACK. WELL STATIC. 01:30 - 03:00 1.50 ' CLEAN P 1 DECOMP LAYDOWN 8 -1/2" CLEANOUT BHA. 03:00 - 05:00 2.00 I DHB P r DECOMP MIRU SLB E -LINE UNIT WITH AIR LINE WIPER. 05:00 - 06:30 1.50 DHB P DECOMP j RIH WITH HES EZSV ON E -LINE WITH GRAND CCL. LOCATE COLLARS AND SAND FORMATION FOR WHIPSTOCK WINDOW. SET EZSV AT 3065' ELMD. 06:30 - 07:30 1.00 DHB P DECOMP PRESSURE TEST 9 -5/8" CASING AND EZSV TO 250 PSI LOW FOR FIVE MIN AND 3500 PSI I HIGH FOR 30 MINUTES. SEE ATTACHED CHART. AUTHORIZATION TO PROCEED 'RECEIVED FROM WELLS TEAM LEADER. 07:30 - 08:00 0.50 DHB P DECOMP 1 RIG DOWN MOVE OUT SLB E -LINE UNIT. 08:00 - 11:00 3.00 CLEAN P DECOMP 1 PU 5" DRILLPIPE WITH (15) JTS 5" HWDP AND (9) 6-1/4" DRILL COLLARS. RIH TO TAG EZSV AT3068' DPMD. PU WEIGHT = 112 KLBS, DOWN= 107 KLBS. TOTAL STANDS DRILLPIPE RACKED BACK IN DERRICK = 51 STANDS. 11:00 12:30 ' 1.50 DHB t P DECOMP PICK UP TO 2916' MD. MAKEUP 9 -5/8" STORM i PACKER. RIH AND SET STORM PACKER AT 37'. PRESSURE TEST STORM PACKER FROM ABOVE TO 250 PSI LOW AND 2000 PSI HIGH , FOR 5 MIN EACH. 12:30 - 17:00 4.50 WHSUR �� P DECOMP � PULL WEAR BUSHING. BACKOUT LOCK DOWN SCREWS ON CASING PACK -OFF. I PULL 9 -5/8" PACK -OFF WITH 13 KLBS. INSTALL NEW 9 -5/8" MCEVOY MANDREL PACK -OFF TYPE YBT. 17:00 - 19:30 I 2.50 WHSUR P DECOMP 'i INSTALL NEW CAMERON 3 -1/8" GATE VALVES ON TUBING SPOOL. INSTALL VR PLUGS FOR I WHSUR TESTING. 119:30 23:00 3.50 P I DECOMP PRESSURE TEST CONNECTIONS AND VALVE SHELL AGAINST VR PLUGS ON BOTH SIDE . 1 I OF TUBING SPOOL TO 250 PSI LOW. TESTS ON BOTH OUTLETS FAIL DISCUSS WITH ANCHORAGE. DECISION TO CHANGEOUT TUBING SPOOL. 23:00 - 00:00 1.00 BOPSUR P DECOMP I NIPPLE DOWN BOP. UNINSTALL CAMERON 3 -1/8" GATE VALVES FROM OLD TUBING _ -- SPOOL. 9/21/2011 00:00 01:30 1.50 BOPSUR P 1 DECOMP NIPPLE DOWN BOP AND SETBACK ON STUMP. PULL MCEVOY SPLIT SPEED HEAD 13 -5/8" 5K TUBING SPOOL WITH 3" SIDE 04:00 2.50 OUTLETS. 01:30 - WHSUR P DECOMP I INSTALL NEW MCEVOY SPLIT SPEED HEAD 113 -5/8" 5K TUBING SPOOL WITH 2- 1/16" CAMERON GATE VALVES ON EACH SIDE. 04:00 05:00 1.00 WHSUR P I DECOMP TEST N -.__-- 9 - SG PACK -OFF - ' PRESSURE TEST NEW 9 -518" CSG IN NEW TUBING SPOOL TO 250 PSI LOW FOR 15 MIN AND 3500 PSI HIGH FOR 30 MIN. 05:00 - 05:30 0.50 BOPSUR P DECOMP I HOLD RIG EVACUATION / H2S / MAN DOWN DRILL AND AAR. 05:30 - 06:30 1.00 BOPSUR P 1 DECOMP NIPPLE UP BOP AND PRESSURE TEST BREAK AT TUBING SPOOL TO 250 PSI LOW 1 I AND 3500 PSI HIGH FOR FIVE MIN EACH. Printed 9/26/2011 11:35:52AM " North America - ALASKA - BP Page 6 1111 0 Operation Summary Report Pe rY p Common Well Name: R -14 I AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/15/2011 1 End Date: X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay ' Site: PB R Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 11/6/2002 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I UWI: 500292090900 Active Datum: R -14 @53.48ft (above Mean Sea Level) Date ! From - To Hrs 1 Task 1 Code NPT 1 NPT Depth I Phase Description of Operations (hr) I (ft)- 06:30 - 07:30 I 1.00 I WHSUR � P DECOMP I INSTALL SECOND GATE VALVE ON WORKING r SIDE OF TUBING SPOOL. 07:30 08:30 1.00 WHSUR P DECOMP PRESSURE TEST FLANGE BETWEEN 'ANNULUS VALVES AND OUTER ANNULUS VALVE. 1 - RIG UP TEST EQUIPMENT TO IA. - TEST FLANGE BETWEEN VALVES TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED j ; MIN EACH. j 1 - GOOD TESTS. I - TEST OUTER ANNULUS VALVE TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN EACH. 1 - GOOD TESTS. 08:30 - 09:30 1.00 WHSUR P DECOMP 1PRESSURE TEST BOP FLANGE. - INSTALL TEST PLUG. h CLOSE BLIND /SHEAR RAMS 1 , I - TEST BOP FLANGE TO 250 PSI LOW AND ! ' 3500 PSI HIGH FOR 5 CHARTED MIN EACH. GOOD TESTS. 09:30 - 10:00 0.50 i WHSUR P DECOMP PULL TEST PLUG AND INSTALL WEAR BUSHING. 10:00 - 11:00 1.00 STWHIP P DECOMP [RELEASE AND LAY DOWN HES RTTS. j- MAKE UP RUNNING TOOL AND ENGAGE RTTS. - CLOSE ANNULAR AND RELEASE RTTS. ■ - ENSURE NO TRAPPED PRESSURE AND I PULL RTTS. 11:00 - 13:00 2.00 ; STWHIP ! P DECOMP PULL OUT OF THE HOLE, STANDING BACK !THE 5" DRILL PIPE. CONTINUE TO RIG UP THIRD PARTY PERSONNEL (SPERRY SUN DD AND MWD) 13:00 - 15:30 2.50 STWHIP P DECOMP ' RUN IN THE HOLE, PICKING UP 5" DRILL PIPE TO 2910' MD. 1 15:30 - 16:00 0.50 STWHIP P DECOMP CIRCULATE 43 BBLS OF 8.5 PPG 2% KCL. - 253 GPM AND 217 PSI. SLOW PUMP RATES TAKEN AT 2910' MD, I 2879' TVD. - PUMP 1: 3 BPM AND 50 PSI. - MONITOR THE WELL FOR 5 MIN. - WELL IS STATIC. - BLOW DOWN TOP DRIVE. 16:00 17:00 1.00 STWHIP P DECOMP I PULL OUT OF THE HOLE, STANDING BACK , I I THE 5" DRILL PIPE. CONTINUE TO RIG UP THIRD PARTY PERSONNEL (SPERRY SUN DD AND MWD). MONITOR WELL FOR 5 MIN. - WELL IS STATIC. 17:00 - 19:30 2.50 I STWHIP P DECOMP RUN IN THE HOLE, PICKING UP 5" DRILL PIPE 1 TO 2912' MD. Printed 9/26/2011 11:35:52AM ' - North America - ALASKA - BP Page Operation Summary Report Common Well Name: R -14 1AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 9/15/2011 I End Date: X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay Site: PB R Pad ' Rig Name /No.: NABORS 7ES Spud Date/Time: 11/6/2002 12:00:00AM I Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292090900 Active Datum: R -14 ©53.48ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr (ft) 1 1 19:30 - 20:00 1 0.50 STWHIP P � 1 DECOMP 1 CIRCULATE 43 BBLS OF 8.5 PPG 2% KCL. - 255 GPM AND 212 PSI. SLOW PUMP RATES TAKEN AT 2910' MD, 2879' TVD. 1 - PUMP 1: 2 BPM - 30 PSI; 3 BPM - 50 PSI. I- MONITOR THE WELL FOR 5 MIN. I - WELL IS STATIC. _ :- BLOW DOWN TOP DRIVE. 20:00 - 21:30 1.50 STWHIP P DECOMP ' PULL OUT OF THE HOLE, STANDING BACK THE 5" DRILL PIPE. CONTINUE TO RIG UP THIRD PARTY PERSONNEL (SPERRY SUN DD AND MWD). MONITOR WELL FOR 5 MIN. _ 1 1 - WELL IS STATIC. 21:30 - 23:00 1.50 STWHIP P I DECOMP I RUN IN THE HOLE, PICKING UP 5" DRILL PIPE I TO 1776' MD. 123:00 - 23:30 0.50 STWHIP P DECOMP CIRCULATE 43 BBLS OF 8.5 PPG 2% KCL. - 256 GPM AND 190 PSI. - MONITOR THE WELL FOR 5 MIN. - WELL IS STATIC. T I- BLOW DOWN TOP DRIVE. 23:30 00:00 j 0.50 STWHIP P DECOMP 1 PULL OUT OF THE HOLE, STANDING BACK THE 5" DRILL PIPE. - FROM 1776' TO 1589' MD. 1 - MONITOR WELL FOR 5 MIN. 1 -WELL IS STATIC. CONTINUE TO RIG UP THIRD PARTY PERSONNEL (SPERRY SUN DD AND MWD). 9/22/2011 00:00 - 01:00 1.00 STWHIP P DECOMP PULL OUT OF THE HOLE, STANDING BACK THE 5" DRILL PIPE. ! - FROM 1589' �- MONITOR WELL FOR 5 MIN. - WELL IS STATIC. CONTINUE TO RIG UP THIRD PARTY PERSONNEL (SPERRY SUN DD AND MWD). 01:00 03:00 2.00 STWHIP P DECOMP RUN IN THE HOLE, PICKING UP 75 JOINTS OF 4" DRILL PIPE. 03:00 - 03:30 0.50 STWHIP P DECOMP CIRCULATE 40 BBLS OF 8.5 PPG 2% KCL. - MONITOR THE WELL FOR 5 MIN. - WELL IS STATIC. - BLOW DOWN TOP DRIVE. 03:30 - 04:00 0.50 STWHIP P DECOMP 1 PULL OUT OF THE HOLE, STANDING BACK 1 THE 4" DRILL PIPE. - MONITOR WELL FOR 5 MIN. 1 1 - WELL IS STATIC 04:00 - 07:00 3.00 STWHIP P DECOMP 1 PICK UP AND RUN IN THE HOLE WITH BHA 1 I #1, 95/8" WHIPSTOCK ASSY. - PJSM WITH THE RIG CREW AND BAKER REPRESENTATIVES. 1, - PICK UP MILL ASSY. - PICK UP MWD TOOLS AND ORIENT. 1 ' I - PICK UP WHIPSTOCK SLIDE AND MAKE UP 1 MILL ASSY. - SHALLOW HOLE TEST MWD. I - 550 GPM; 950 PSI. Printed 9/26/2011 11:35:52AM North America - ALASKA - BP Page 8 ONO. Operation Summary Report Common Well Name: R -14 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 9/15/2011 End Date: X3- 00YRC -C: (5,042,419.00 ) Project: Prudhoe Bay I Site: PB R Pad Rig Name /No.: NABORS 7ES Spud Date/Time: 11/6/2002 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292090900 Active Datum: R -14 @53.48ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 09:30 2.50 STWHIP P DECOMP RUN IN THE HOLE WITH BHA #1 ON 5" DRILL PIPE 1- FROM 367' TO 3000' MD. - UP WEIGHT = 115K LBS; DOWN WEIGHT = 1112K LBS 09:30 - 10:30 1.00 STWHIP P DECOMP ORIENT AND SET WHIPSTOCK. - STAGE PUMPS TO 470 GPM; 975 PSI. ORIENT TO 64 DEG LEFT. - SET DOWN AND TAG EZSV AT 3068' MD. - 'SLACK OFF AND SET ANCHOR WITH 18K LBS. ! - PICK UP 10K LBS OVER AND CONFIRM ANCHOR SET. - SET DOWN 25K LBS AND THEN PICK UP 15K LBS OVER. - SHEAR MILL BOLT WITH 45K LBS DOWN WEIGHT AND PICK UP OFF SLIDE. 1 10:30 - 12:00 1 1.50 STWHIP P DECOMP I DISPLACE WELL TO 9.3 PPG LSND MILLING FLUID. - PUMP A 30 BBL HIGH -VIS SPACER. - 450 GPM; 790 PSI. SLOW PUMP RATES: • -TMD = 3046', TVD = 2967'. - PUMP 1 -- 2 BPM AND 140 PSI; 3 BPM AND 180 PSI. - PUMP 2 -- 2 BPM AND 140 PSI; 3 BPM AND 190 PSI. i 12:00 - 17:30 5.50 STWHIP P DECOMP MILL WINDOW IN 95/8" CASING. - OBTAIN MILLING PARAMETERS - MILL WINDOW FROM 3046' TO 3063'. - CONTINUE TO 30' OF NEW HOLE TO 3085' MD. - UP WEIGHT = 112K LBS; DOWN WEIGHT = 106K LBS. - 404 GPM; 765 PSI. 100 RPM; ROTATING WEIGHT = 108K LBS. - TORQUE ON = 5K FT -LBS; OFF = 1.2K I FT -LBS. - PUMPED SEVERAL 30 - 50 BBL SUPER SWEEPS WHILE MILLING. 17:30 - 18:30 li 1.00 STWHIP P DECOMP WORK MILLS THROUGH WINDOW. - PUMPED A 50 BBL HIGH VIS / SUPER SWEEP. - WORKED THE MILLS THROUGH THE WINDOW WITH AND WITH OUT ROTATION AND CIRCULATION. - NO DRAG OR OVERPULLS NOTED. 18:30 - 20:00 1.50 STWHIP P DECOMP PERFORMED A LOT. - PULLED ABOVE THE WINDOW AND RIGGED UP THE CEMENT LINE TO THE CIRCULATING HEAD. - CLOSED THE UPPER RAMS. - PUMPED 5 BBLS OF 9.3 PPG LSND. - BROKE OVER AT 389 PSI, EMW = 11.78 PPG. I - TMD = 3054; TVD = 3018' - NO RETURNS WHEN BLEEDING OFF. - TOOK 13 BBL TO FILL THE HOLE AFTER OPENING THE RAMS. Printed 9/26/2011 11:35:52AM TREE =' 7" CM/ - ACTUATOR = AXELSON • 14A SA. 5 - 1 /2 " CHROME TBG ANGLE > 70 @ 10730' KB. ELEV = 53.50' ' BF. ELEV = 22.16' 1 31' .. 1-17" TBG HGR / PUP JT I KOP = 2200' Max Angle = 97 @ 10499' MD \_ ' 33' 1-17" X 5 -1/2" X0, ID = 4.892" 1 Datum = 11420' eZS' V 0 wn _ 2111' H5-1/2" OTIS SSSV LAND NIP, ID = 4.562" I Datum MD = 8785' SS a* V J p B I ' GAS LIFT MANDRELS � -------bib 1,11NWITTiTirAt ST MD TVD DEV TYPE VLV LATCH PORT DATE c,_ 6 3079 3045 25 OTIS DMY RM 0 03/16/11 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 1-I 2697' 1--- - 5 5338 4927 34 OTIS DMY RM 0 03/16/11 ��� 4 7053 6318 36 OTIS DMY RA 0 10/14/91 3 8410 7451 31 OTIS EMPTY RM - 07/26/11 1 JET CUT (07/31/11) H 3259' 2 9221 8106 39 OTIS DMY RM 0 03/16/11 *1 9329 8191 38 OTIS DMY RA 0 10/14/91 1 TOP OF CEMENT - TUBING (TAGGED 7/31/11) 1 7095' `CAN'T USE; PATCHED � . ✓ ■ 9322' - 9362' -I WFD ECLIPSE PATCH, ID = 2.860" I ESTIMATED TOP OF CMENT (IA) I 7150' ► •_ WW"� 4 . •, ►•∎ • ►-x-14.14. •., i• 4 1 •�• •�•�•�•�•∎ ••� 9366' • • � � 11,. 9366 3 -3/4" BAKER DEPLOYMENT SLV, ID = 3.00" 1 •�• • � �• � j' j 9371' 1-i -1/2" HES XN NIP, ID = 2.75" 1 ►�� � dOOi • i i �i� �i�i�i i!i 9394' -I TIW ANCHOR LATCH I r * ∎ • • • • • • 1 • . • 7 I 9395' 1-1 9 -5/8" X 5 -1 /2" TIW HBBP PKR, ID = 4.815" I • Minimum ID = 2.387" @ 9945' ' i• • •iii •• ' Vii( .■�OOi/1 Oi • 3- 3/16" X 2 -7/8" XO ..4.0•ODi/'4 ••• .. ∎ ∎OO .. i 5 -112" TBG, 17 #, 13 -C R, .0232 bpf, ID = 4.892" 9505' et :�� �• • 1 � • � •• W • • -• 9505' 5 -1 /2" TT PUP JT /MULE SHOE, ID = 4.892" ► ► .� 4 ►4 N t► •• ♦ • N 4 • 1 9499' H ELMD TT LOGGED ON 10/26/91 1 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9823' ► • • • 10 • 4, ► ►1 4 ► 4 ►� 3-1/2" LNR, 9.20 #, L -80, .0086 bpf, ID = 2.98" 1 9849' '.0•••41 ►4 9849' —13-1/2" X 3- 3/16" XO, ID = 2.80" 1 'TOP OF WHIPSTOCK H 9885' - ►�� X .:4 5" LNR, 18 #, C-95, .0177 bpf, ID = 4.276" 1 ' -988 ► 1 �` �.•••• 0 •�4,v, MILLOUT WINDOW (R -14A) 9888' - 9898' 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" 1-i -9898 � �� � � � � � ���� �� \ • 9945' H 3- 3/16" X 2 -7/8" XO, ID = 2.387" 1 13-3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.80" H 9945 -'' -4• PERFORATION SUMMARY •• • � •• REF LOG: • � i it�`. ANGLE AT TOP PERF: % `� s � Note: Refer to Production DB for historical perf data �•' •.* SIZE SPF INTERVAL Opn /Sqz DATE ♦• j�• • 2 -7/8" SLTD 10490 - 11345 SLOT 11/13/02 1 PBTD H 11377' 1-- -•' 12 -7/8" SLTD LNR, 6.16 #, L -80, .0058 bpf, ID = 2.44" 1--1 11378' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/13/83 ORIGINAL COM PLETION JJ 04/30/11 DAV/ PJC PULL LTTP (04 /07/11) WELL: R-14A 10/15/91 RWO (R -14) 08/15/11 TTW/ PJC JET CUT/ P&A (7/31/11) PERMIT No: 2021560 11/13/02 JDM/TP CTD SIDETRACK (R -14A) , 08/15/11 BES/ PJC GLV GO (07/26/11) API No: 50- 029- 20909 -01 08/24/06 JCM/PAG GLV C/O SEC 32, T12N, R13E, 1444' FSL & 1756' FWL 03/28/11 JM/ PJC GLV C/O (3/16/11) 04/29/11 CDJ/ PJC SET CAT STD VALVE (4/6/11> BP Exploration (Alaska) • III WELL LING TFANSMITTAL PR0ActivE DiAgNoslic SERVICES, INC. To: AOGCC Christine Mahnken 333 W. Suit 00th Ave S , t- ,' '- G ti 4 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: [907) 245 -8952 ( 7 Yr 1) Leak Detection - WLD 21- Jun -11 R -14A —BL / CD ----- 50 -029- 20929 -01 2) 1 Li Signed : P Date : Var) 3■A k 1 Print Name: vsi 0,0 £ k Ian PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGE(MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Atchives\ Distribution\ TransmittalSheets \BP_Transmit.docx 2‘. O z ` • • SINE Cl[F u SEAN PARNELL, GOVERNOR 333 ALA CO A1�TD GAS W. A, CONSERVATION CO 11SSIOIQ ANCHORAGE7th VENUE , ALASKA SUITE 99501 100 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. ao P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU R -14A Sundry Number: 311 -138 Dear Mr. Egbejimba: ��� 2011 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, /0 0: 1-6 0 4A-7 Cathy '' . Foerster Commissioner DATED this'U day of April, 2011. Encl. - STATE OF ALASKA A A I �� ALASKI AND GAS CONSERVATION COMMIS T iR 2 2011 /� APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Cam 1. Type of Request: ;I,r'cr r&ge Canwiission ❑ Abandon • ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. - ® Development ❑ Exploratory 202 -156 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20909 -01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number property line where ownership or landownership changes: PBU R-14A - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): _ ADL 028279 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11378' - 8819' - 11378' 8819' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2697' 13 -3/8" 2697' 2685' 4930 2670 Intermediate 9823' 9-5/8" 9823' 8590' 6870 4760 Production Liner 322' 7" 9566' - 9888' 8379' - 8644' 7240 5410 Liner 384' 5" 9504' - 9888' 8330' - 8644' Liner 2012' 3 -1/2" x 3- 3/16" x 2-7/6" 9366' - 11378' 8220' - 8819' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Section: 10490' - 11345' 8756' - 8803' 5 -1/2 ", 17# 13Cr 9505' Packers and SSSV Type: 9-5/8" x 5-1/2" TIW 'HBBP' packer Packers and SSSV 9395' / 8243' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: :∎ Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - 0 Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 20, 2011 ❑ Oil ❑ WINJ ❑ WDSPL i" Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned ot t ❑ WAG ❑ SPLUG - [B Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564 -5271 Printed Name John Egbejimba Title Engineering Team Leader Prepared By Name/Number. Signature j - - Phone 5645859 Date T Hubble, 564 -4628 _ C Use Only Conditions of approval: Notify Co ission so that a representative may witness 311--(/3` Sundry Number: ❑ Plug Integrity ]BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance > 3 Soo 105 c. SoP cs f Other: --�.. Subsequent Form Required: /0 4 107 ��// �� APPROVED BY (24-4 Approved By: (24-4 ` t �� `' ` Y COMMISSIONER THE COMMISSION Date ¢-2-7—/ F svi g0Lii'!• Submit In 0 plicate B GINAL ���OR1 • • P GP6p -„, . Well Name: R -14A Well Type: Producer Current Status: Shut -In Request: P &A - Well Prep f /Rotary Sidetrack MIT - T x IA (Failed) MIT - OA Passed to 2500 psi (04/24/04) Request: The R -14A coil tubing sidetrack was drilled in November 2002. It was completed with 2 -7/8" slotted liner in Zone 4B. Once flow -line repairs were complete the well was placed on production in October 2003. R -14A came on with lot of gas initially that was interpreted as an MI slug. In December 2003, the well was shut -in due increasing severity of already known TxIA communication through a leak at 9345'ft which was confirmed by an October 2002 leak detect log. A tubing patch was run in April 2004 and the well returned to production. However, the water -cut increased significantly over two months from 32% to 92% which was interpreted as water break - through from the toe because the well trajectory toed down to the water -oil- contact and due to the slotted liner completion there was no way to shut -off water. The well then kept cycling through GC -2 depending on GC -2 water handling capacity until it was completely shutdown in 2006. Reason for Sidetrack: High WC 99% was no way to shut -off water (last well test: 226 bopd, 7142 bwpd, 1634 mscfd (flush production, normally at 99% WC)). Other Requests: None. Scope Planned Sundry Work: As currently planned, the P&A of the R -14A well and the well work in preparation for the R -14B rotary sidetrack will be as follows: 1. Pre -rig, perform a full -bore P &A cement job of the existing 3 -1/2" x 3- 3/16" x 2 -7/8" coil production liner. 2. Add a second P &A cement plug from TOC in step #1 to -8200' MD. 3. Make tubing cut at 3250' MD. 4. With the drilling rig on the well, pull the 5 -1/2" tubing from 3250' MD. 5. Set and test an EZSV in the 9 -5/8" casing at -3070' MD' for a whipstock departure /sidetrack of the well from that depth. MASP: 2322 psi (7.18 ppg pore pressure at TSAG) Estimated Pre -Rig Start Date: 5/20/11 Proposed Pre -riq prep work: 1. P &A current coil liner with 20 bbls 15.8 class G cement (TOC at 9300' MD). 2. D &T Cement and CMIT -TxIA to 3000 psi (assume P &A cement plug w /allow ). 3. Make tubing punch at -9300' MD. • 4. Circulate cement plug in TBG and IA (69 bbls of 15.8 class G cement w/TOC at -8200' MD). 5. D &T cement. Drift for jet cut. • 6. Jet cut TBG at 3250' MD. • 7. CMIT -TxIA to 3500 psi. • 8. Set BPV. fair T.'m a rife" trod a*,v fos /4 , Al t,'o.• off I '.s ifree.4 �esf rte► 66O 11J gme hisitte Glen , ?7% '. w cf( 141 trite a Q /(A(, M> valve a*o/ P 444 irrketk mcovfrfr fie gOL 44#4 Planned Rig Work: • • 1. MI /RU Doyon 25. 2. Nipple down tree. Nipple up BOPE (IF there is not room to test the lower set of RAMS, a spacer spool will be needed to accommodate that test PRIOR to pulling the tubing). Test BOPE to 250 psi low /3500 psi high. 3. RU and pull the 5 -1/2" 17 #, chrome tubing from the pre -rig jet cut at -3250' MD. 4. RU E -line, RIH with GR /CCL and 9 -5/8" EZSV for 47# casing. Tag tubing stub at -3250'. Set the EZSV at -3000' MD (competent sand / confirm with GR) as required to avoid cutting a casing collar while milling the window. POOH. Rig down E -line. P.Ak 5. Pressure test the EZSV to 3500 psi for 30 minutes and chart. 6. PU and RIH with 9 -5/8" Baker bottom -trip anchor whipstock assembly and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Shear off the whipstock. 7. Mill a window in the 9 -5/8" casing at -3000' MD' plus 20' of formation trom mid- window. 8. PU into 9 -5/8" casing. Perform a LOT. POOH for drilling BHA. 9. MU an 8 -1/2" drilling BHA with DIR /GR /RES /PWD and 2 ghost reamers per this plan. RIH. 10. Drill 8 -1/2" intermediate interval to 7" casing point at the top of the Sag River. 11. Circulate and condition the hole prior to TOH to run a 7" drilling liner. , / 12. Change upper VBR's to 7" casing rams and test to 250 psi low / 3500 psi high. �( 13. Run a 7 ", 26 #, L -80, Vam -Top, HC drilling liner back into the 9 -5/8" casing with minimum of 150' liner pj-D lap. Cement 7" liner with -1500' tail of 15.8 ppg class G cement. 14. Pressure test the casing /7" liner to 3500 psi for 30 minutes. 15. Change out 7" rams to VBR's and test to 250 psi / 3,500 psi. 16. MU a 6 -1/8" BHA with DIR /GR /RES /DEN /NEU with an insert bit and RIH to the 7" landing collar and displace well to the planned 8.5 ppg DIF. 17. Drill out the 7" shoe plus 20' of formation. Pull into the shoe and perform an FIT. 18. Drill the 6 -%a' production interval as per directional plan to TD. 19. Circulate hole clean, short trip as needed /MAD Pass where required. POOH. 20. MU and RIH to bottom with a 4 -1/2 ", 12.6 #, 13CR -85, VamTop liner from TD to 150' liner lap inside the 7" shoe. 21. Fully cement the liner to the TOL with 15.8 ppg Class G Latex cement. 22. Set liner top packer and displace well to clean seawater above the liner top. 23. Pressure test casing and liner to 3,500 psi for 30 minutes. 24. RU DPC pert guns, RIH and perforate. 25. RU and run 4 -1/2 ", 12.6#, 13CR -85 Vam -Top completion, stinging into the 4 -W liner tie back sleeve. 26. Space out and make up tubing hanger per FMC Rep. 27. Land the tubing hanger, and run in lock down screws. 28. Reverse circulate to seawater with Corrosion Inhibitor (surface to surface). 29. Drop ball and rod. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. 30. Set a TWC. 31. ND the BOPE. NU the tree and test to 5,000 psi. 32. Pull TWC. Reverse in sufficient volume of diesel to freeze protect the well to -2,100' MD. Allow the diesel to U -tube to equilibrium. 33. Set a BPV. Secure the well. 34. RDMO. Post -Rig Work: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Replace the DCK shear valve with a dummy GLV. 3. Install well house and instrumentation. 4. Modify S- Riser as needed. Drilling Engineer: John Rose (907) 564 -5271 Production Engineer: Megan Kimmit (907) 564 -5851 Geologist: Cole Abel (907) 564 -5576 • 0 T Caw ACTUATOR AXELSC R-11 444 r "PIETY Nara: ... S-112-4:11""EnG... , I K8.O.EV = 53 5C ' $F ELEV= 2218I Er MI i. 31 1r1r ?SG HIGR / PUP 3T K0P 1 �:all r x 5.12• xo Abe At e= 97# 10499 OnL111 113T8i 2111 M5 U2 OfSSSSVLAI MP. D =4_ 2' Oatun7V0= 878 5- OAS UFO' I 13-3/8' eta n#.. -80. K7 = 17 —f 2694 5 5338 4874 34 OTS COVE RAll 16 08/38/06 4 7053 8263 36 0715 t*4Y RA 0 I., ,..o 3 8410 1308 31 0115 CONE RM 16 04130/04 2 9221 8052 39 OM S0 RM 24 • +'. •1 9329 8137 38 O115 � CMY RA 0 1111TIum �� _ " 9945' • CAWT UDE PATCHED 33116 "X 27/8" XO 1um . y ''MTh Wit t) ECUPSE mum D =2ascr i1 lr _ . 9 , ' w 3 . 1/ _ 2'WESXN 3'71 3-12' xN NP. D =2.75 9304' ,• 1W A ORLATO1 :' 0.:. � _ _ 9 5/8" x 5-12 TON HAP FKR, D= 4.815' 1 5- r 7 .171!.13-01 -0232 bp1, ' =4.: ' •'.`- F t� 5-1124 . 'r- =' .. . , rliF '•`" 0.4..1 . � ELMDTT LOGGED 10/2191 23* j 1 9-58' CSG. 478. L-80. D =8.681' it 9$ ' ' 132' 1 LNR. 9.20*, L-80..00!16 bpf. D = 2.98' 9 8 1 :� 3-1/2' 16' x0. + , . .96^ "-."'i"°.. 1 NlWtfr 9888' -989& I �•1 011111 r -1 - .� ....■ yam• 3/16- x2-n8' IOD. D = 2.44" 1 5'u 188.c ..0177 111111 t bpt.D =4zT8' 10S$ 1 1 i.rrrrr y rrr.r i .rrr.r.i r .err. 111 111, 1 1 1 1111111• • 11111111 • r LNR 268. L-80. .0383 . • . p = 627e , ;: - 1111111 . 1111111 , 3-3/16' LAIR 6.28. L x0. 994s I-- PERFORATION SMART RY ` 007680.V.2.80" ��\� + FLOG �:\:� ANGLE AT Tc P P87F: � � Nrie: Refer b Production poo for lYS ?art data � .. 5M SPF' INTERVAL ,..., OpniStg DATE �� 51.70 '0490- 11345 0 ,1/13102 12 -7/8' SLID LAM. 6.190. L.80..0058bp1. D =214' 11319' .Y ' r " : t t . _ •; ut , -... 148.0111E BAY WIT ' 't � � ( . + . - ∎Ir ' .': 1111 08/24/06 �` «'! :'T l . WELL R-14A NNW 11111111111•111•marl mx X1560 "Mil' a rw" IJ.4 L.111 ".. iL...:..1(.+ .".r1� 1 API Mt 50.029.20909-01 t=i1111■=1111111 MIME 11111111111111111111111111111101111111. SEC 32. T17N. R13E 1444' FSL & 1758` FNL . r. ' r 06/00106 1=1 r MINN 11111111= 1111111111111111111111111111111=11 eP E lorat1on (Alaska) • 0 1 HIL= rcNV WELLHEAD= M E Y A CT R -1 4A l POST AXELSONI KB. ELEV = 53.50' BF. ELEV = 22.16'I t I 31' Hr TBG HGH i FLIP 31 I KOP= 22001 - - _ _ 33' 7' X 5.1/7 XO Max Angie = 97 ( 104991 Datum M) = 113781 2111' H 5 -1/2' OTIS SSSV LAND NIP. ID 4.562" I Datum TVD = 8785' SS1 O GAS LIFT MANDRELS _ ` MD P✓O LEV TYPE VLV LATCH PORT DAZE ' 307x3 2931 25 OM' DOME RM 16 08i24106 MP 31 13-8' CSG, 724, L-B0, ID= 12.34r H 2697' 5338 4874 34 OTIS DOME F21vI 16 08/24/06 7353 6263 36 OTIS LMI' RA 0 09/28/03 Est TOG behind 9'518' Csg -5500' MD— 3 8410 7396 31 0115 DOME HM 16 04/30/04 _ _ 2 9221 8052 39 0115 SO HM 24 04/30/04 P&A Cement f/9394' back to 8200' MD - •1 9329 8137 38 0115 CAN RA 0 5-112' Tubing Punch at 9310' MD --- - .... _ _ • CAN'T USE PATCt® 5 -112' Cmt Retainer at -9315' MD 1 9322 - 93Gt' W 1HHFD ECLIPSE PA TCH, 13= 2860" P&A Cement 0`9945' back t0 9315' MD 1 —� 9366` H3- 3i4' BAKERDEPLOYMENTSLV,D =3.00' I '— 9:373939451:* ' H 3 -17'2" HES XN NF, ID =2.75' I _ - - -I • H IIWANCIOR LA TCHI - -- H 1- 5.'8'X5- 1 /2 "TNV14BBPPKR. ID= 4.815" I Minimum ID =2.44" @9945' 3-3/16" X 2-7/8" XO N -VZ' TBG. 1 7,:. 13 - CR. _0232 bpi, ID = 4.892' I--I 9503' • 195505' H5-1%2' 1T FLP 31: MLLE SI+OE ID= 4.892" I - I 9499' H aMD 1'1 L000ED 13.•26191 I I J -58' CSG, 474, L -83, ID = 9.SB1' --I 9823' [ IL I ::1 2'LNR 9.204. L- 90..0086bpf.8) =2.19' ^ 9849' _ - _I 9849' H3- 1/2 - X3 -3116' X0, ID= 2.80'( TOP OF WHIPSTOO< - 9885' N11LLGL 1 4': lM)CV. :36138' 9898' 1,1 k1,11N1 IS BAKER Ck1P- 1031132 H 99Wb' ` '.� I 9945' H3 -3/16' X 2 -7.B' XO. (3= 2. "* 1' I ' 6 • 11 1j 4 1 + 4 1 1 N.. N NN:N. S' LNR 18 4, C-95, .0177 bpl. ID = 4.276 H 10546' ` x # 4 , 1 , 4 1 1 1 . + 1 1 .. LLNR 264, L -80, .3383 twt, ID= 5.276 H 10593' I- I 4.FY11N1• 3- 3/16'LNR 6.24.1.-80, H 9945' I �1D PERFORA DON SUMMARY .3076 IV, ID= 283' REF LOG: ANGLE AT TOP P61F: Note: Refer to Productu n DB Ior tustoncal Dort data SIZE SPF INTERVAL Opn:Sgz DATE �.` SLID 13490- 11345 0 11/13/32 12-7/8' SL TD LNR, 6.16#. L- 80..0058 bpt. ID = 2.44' 11378' OA 1 E KU.; BY COMMENT; D, IE REV BY CO1tlE'. - . PRUCHOE BAY UNIT 021183 0RIGINAL COMPLETIONJJ i 39.24.36 a. - M.PM(3 GL'✓ 00 WELL: R -14A 10/15;91 RIND 02 -14) ':215:11' fgt. R -14A P&A PERMIT No: / 2021560 11/1102 JCIIVI/TP CTD SIDETRACK 1R -14A, APINo: 50- 029 - 2090901 04/24/04 MJAIKAK SET EC11PSE PAl 13]' I SEC 32, T12N. R13E, 1444' FSl & 176' FWL 04/30/04 RNIEKAK C1V 0'0 08/09/06 TELJPJC GXV 00 • BP Exploration (Alaska) u' July 10, 2009 ~`p~~~~~~~ `~~'~`` :~ i¢ ~~~~ Mr. Tom Maunder ~~ / Alaska Oil and Gas Conservation Commission <1 b~,.,--~ ~~ 333 West 7th Avenue ~~'~" Anchorage, Alaska 99501 (~," ~ ~" Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator . • BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date R-pad Revised 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-186 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 225 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11 /2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 325 NA 22.1 5/12/2009 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, ~~ ~ ~~. Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, w . , ~} ~ /~~~} ~,~7~~ ~~1rt~ £ ~LJ~'J 1~r ~r~i7Y/ ~ l.~ ~ . 1.` .L . iJ E~~ ~J ~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) / natp R-pad ~ 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 125 NA 1.25 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11l2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 025 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 025 NA 1.7 6/i 1/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11 /2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 325 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5h 1/2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 . . ~.~ ·.....r.............·.'.'.··..<·,",··.. '"i" ~':,' ~~ ..: . ..";, 'a .. \. ..... MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc J J ~~'i DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 ~' MD 11378 Well Name/No. PRUDHOE BAY UNIT R-14A Operator BP EXPLORATION (ALASKA) INC /// TVD 8819 /' Completion Date 11/13/2002 Completion Status 1-01L Permit to Drill 2021560 ~- - --.- ---------~------~----~ - ______n_--------~-----~--'--- ----. REQUIRED INFORMATION - --- -_.---,--------~----------~~ ----~ -- - -_._-,---~------------------ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ~----~-------- ~D C LA4730 ~ ~ / - ---~-._-~--_._--.--"~-~~--- Well Cores/Samples Information: Name Name Induction/Resistivity Induction/Resistivity Log Log Run Scale Media No 25 Blu 1 Induction/Resistivity 25 Blu Directional Survey Directional Survey I nd uction/Resistivity 25 Blu Interval Start Stop Sent Received Current Status 1-01L API No. 50-029-20909-01-00 UIC N Directional Survey (!!y ~ (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 9904 11378 9904 11378 OHI CH Received Open 3/25/2003 Open 3/25/2003 9904 11378 Open 3/25/2003 9800 11378 Open 11/21/2002 9800 11378 Open 11/21/2002 9904 11378 Open 3/25/2003 Sample Set Number Comments c-/ Comments BHP A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/29/2002. An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 7/29/2002. '-~ Permit to Drill 2021560 MD 11378 TVD 8819 Well Cored? ADDITIONAL INFORMATION If;) -- Chips Received? --'Y/N '/" T1'Ñ Analysis Received? Comments: --- ~ --- ~-~-_._---_._----~~-----~--- .---.----~_._~---_._-------~-- - - -_.~-- ---.--- -- -- -------_u_--~ ---~---- ._.--~~-------- --------- ~-- - -- ------, Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Well Name/No. PRUDHOE BAY UNIT R-14A Operator BP EXPLORATION (ALASKA) INC Completion Date 11/13/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? l0/N 0N Formation Tops I ' ~ , Date: API No. 50-029-20909-01-00 UIC N --/ ) 'Je--, Jv~~- ~ " '~ ') STATE OF ALASKA) I\/ED ALASKA OIL AND GAS CONSERVATION COMMISSION ,., REPORT OF SUNDRY WELL OPERATlð~992004 perforateAfjka &~:1~~7{H¡ ;)~ AnC!lOhr.g'l."i Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1560 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 Repair WellŒJ Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: OtherD BP Exploration (Alaska), Inc. Development ŒJ Stratigraphic D 9. Well Name and Number: R-14A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 6. API Number 50-029-20909-01-00 53.50 8. Property Designation: ADL-0028279 11. Present Well Condition Summary: Total Depth measured 11378 feet true vertical 8818.8 feet None None Plugs (measured) Junk (measured) measured 11378 feet Effective Depth true vertical 8818.8 feet Length 80 491 322 96 1433 9793 2666 Size 20" 91.5# H-40 3-1/2" 9.3# L-80 7" 26# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD 32 112 32.0 - 112.0 9358 - 9849 8213.5 - 8611.9 9566 - 9888 8379.5 - 8644.3 9849 - 9945 8611.9 - 8686.1 9945 - 11378 8686.1 - 8818.8 30 - 9823 30.0 - 8590.2 31 - 2697 31.0 - 2684.6 Burst Casing Conductor Liner Liner Liner Liner Production Surface Collapse 470 10530 5410 1490 10160 7240 13450 6870 4930 13890 4760 2670 Perforation deDth: Measured depth: 10490 -11345 True vertical depth: 8756.27 - 8803.34 Tubing ( size, grade, and measured depth): 7" 26# 13CR80 5-1/2" 17# 13Cr80 3-1/2" 9.3# L-80 3-1/2" Eclipse Patch Packer 3-1/2" Eclipse Patch Packer 5-1/2" Baker HB Packer 9-5/8" DV Packer @ 30 @ 33 @ 9322 @ @ @ @ 33 9505 9362 Packers & SSSV (type & measured depth): 9322 9360 9395 2592 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 21.6 400 860 13 Tubing Pressure 1154 964 Oil-Bbl 537 Prior to well operation: Subsequent to operation: 0.9 111 16 0 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ) ServiceD 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Copies of Logs and Surveys run - Daily Report of Well Operations. ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron jj~ Cd-&., Form 1 0-404 Revised 12/2003 Production Technical Assistant Title Signature Phone 564-4657 Date 617/04 (1Q!(,I~,'^' ') ) R-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/25/04 *** WELL SHUT-IN ON ARRIVAL*** RIH WI 4 1/2 GR 14-1/2" ECLIPSE PULLING TOOL. SET @ 9267' SLM. RIH WI 4 1/211 GS. LATCHED PATCH @ 92671 SLM. JARRED UP FOR 50 MIN. ATTEMPTING TO SHEAR OFF. JOB IN PROGRESS. *** JOB CONTINUED ON 2-26-04 *** 02/26/04 T/I/O=0/88010. TEMP=SI. TBG & IA FL. (SLICK LINE). TBG FL @ 1741 (5 BBLS). IA FL @ 25301 (110 BBLS). 02/26/04 AWGRS CONTINUED FROM 2-26-04 ASSIST SLlCKLlNE WITH CMIT TO 2500 PSI. PUMPED 83 BBLS CRUDE TO TEST. INITIAL, TIO=2350/250010. 30 MIN. TIO=2250/241 010. PASSED. WHP=0/150010 02/26/04 *** JOB CONTINUED FROM 2-25-04 *** PULLED TOP ECLIPSE PACKER AND EXTENSION ATTEMPTING TO RECOVER LOST ELEMENT FROM PACKER JOB IN PROGRESSI CONTINUE ON 12-27-04 02/27/04 *** JOB CONTINUED FROM 2-26-04 *** RIH WI 3.511 CENT & CENTER SPEAR. SPEARED ELEMENT @ 93091 SLM. (RETREIVED NYLON RING FROM EXTENSION SEAL) RIH W / BRUSHES TO 9305' SLM RIH W SNAP LATCH/CAT SET @ 9306' SLM. CMIT T X I A TO 2500 PSI PASSED. PULL SNAP LATCH CAT. RDMO ***LEAVE WELL SHUT-IN *** 03/03/04 T/I/O=180/82010. (FOR E-LlNE). TBG FL @ 5401, IA FL @ 24421. 03/07/04 ***FOUND WELL SHUT IN ON ARRIVAL *** RUN DUAL PETREDAT GAUGES TO FOLLOWING STOPS - 95341 MD (8300ISS) - 30 MIN = 3025 PSI - 197 DEG. F & 9409' MD (8200'SS) - 10 MIN = 2991 PSI - 194 DEG. F. RDMO. ***LEFT WELL SHUT IN ON DEPARTURE*** 03/17/04 RIGGED UP TO SET TOP SECTION OF WFD ECLIPSE 5.5" TUBING PATCH. JOB CANCELLED DUE TO WIND CONDITIONS (18-31 MPH). 03/18/04 ATTEMPT TO LATCH 38.21 WFD 5.5" TUBING PATCH TOP SECTION AND SET PACKER ELEMENT. AFTER LATCHING INTO LOWER PACKER, ATTEMPTED TO SET UPPER PACKER. 13.11 FROM CCL TO CENTER ELEMENT OF UPPER PACKER. CCL STOP DEPTH @ 9309.2. CENTER ELEMENT LOCATED AT 9322.31. PACKER DID NOT SET, NO GOOD INDICATION SETTING TOOL (CPST) FIRED. PULLED OFF AND LEFT SWS HEAD, CCL, SETTING TOOL AND TOP OF WFD PATCH. OAL TOOL = 49.21, TOP OF FISH AT 9306.11. LEFT FISH IN WELL LATCHED TO BOTTOM PACKER, FROM BOTTOM UP: ECLIPSE PATCH UPPER ELEMENT WITH PACKER, WFD ADAPTER, SWS CPST SETTING TOOL, CAL-B (CCL), PEK-B HEAD. NOTIFY PAD OPERATOR TO LEAVE WELL SI. 03/18/04 ATTEMPT TO LATCH 38.2' WFD 5.511 TUBING PATCH TOP SECTION AND SET PACKER ELEMENT. AFTER LATCHING INTO LOWER PACKER, ATTEMPTED TO SET UPPER PACKER. 13.11 FROM CCL TO CENTER ELEMENT OF UPPER PACKER. CC Page 1 " ') ') R-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/05/04 *** WELL SHUT IN ON ARRRIVAL*** FISH E-LlNE TOOLS @ 9174 SLM FISH 51/2 ECLIPSE PATCH @ 9184 SLM, RECOVERED ALL SLIPS AND RUBBERS. IN PROSES OF LAYING DOWN EXT LUBRICATOR AND REALEASE CRANE. CONTINUE ON 04-06-04 WSR 04/05/04 *** WELL SHUT IN ON ARRRIVAL*** FISH E-LlNE TOOLS @ 9174 SLM FISH 5 1/2 ECLIPSE PATCH @ 9184 SLM, RECOVERED ALL SLIPS AND RUBBERS. IN PROSES OF LAYING DOWN EXT LUBRICATOR AND REALEASE CRANE. CONTINUE ON 04-06-04 WSR 04/06/04 ***CONTINUED FROM 04-05-03 WSR*** RIG DOWN EXTRA LUB AND REALEASE CRANE. ATTEMPT TO PULL LOWER PACKER @9284 SLM. ***CONTINUE ON 04-07-04 WSR.*** 04/06/04 ***CONTINUED FROM 04-05-03 WSR*** RIG DOWN EXTRA LUB AND REALEASE CRANE. ATTEMPT TO PULL LOWER PACKER @9284 SLM. ***CONTINUE ON 04-07-04 WSR.*** 04/07/04 *** CONTINUED FROM 04-06-04 WSR**** PULLED ECLIPSE PACKER WI BAKER STINGER SEAL ASSY @ 9317 SLM. ***LEFT WELL SHUT IN*** 04/07/04 *** CONTINUED FROM 04-06-04 WSR**** PULLED ECLIPSE PACKER WI BAKER STINGER SEAL ASSY @ 9317 SLM. ***LEFT WELL SHUT IN*** 04/21/04 T/I/O = 40/1100/0. TBG AND IA FL1S. (E-LlNE). TBG FL NEAR SURFACE. IA FL @ 32751 (143 BBLS). 04/22/04 SET WEATHERFORD TWO RUN PATCH FROM 93221-93621 MID ELEMENTS. WELL SHUT IN FLUIDS PUMPED BBLS 118 118 Crude TOTAL Page 2 ... \. TREE = 7" CIW WELLHEAD = WCEVOY ACfUÄf6Ff;~ . ÁXElSÖÑ KËlËlêr;;---^^5~Ü5Õ' ^BTILEV;;-~^ 22.16' KOP = 2200' MãX-Ãngle ;"--^§i@ffõ499i .bãtum MD;_"M~mM^^'^H37âì """"""".~"'-.,",..,........".''''HN'o''~''''"'~''''''''''''''''''''''''''''''''''''''''' Datum TVD = 8785' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I., 2697' ) M in imum ID = 2.44" @ 9945' 3-3/16" X 2-7/8" XO 1 5-1/2" TBG, 17#, 13-CR .0232 bpf, ID = 4.892" H 9S05' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9823' 13-112" LNR, 9.20#, L-80, .0086 bpf, ID = 2.98" H 9849' ITOPOFWHPSTOex H 988S' 15" BAKER CBP - 10/31102 H 15"LNR, 18#, C-95, .0177bpf, ID=4.276" H I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9970' 1 10546' 1 10593' J PffiFORA TION SUtvfv1ARY REF LOG: ANGlEA TTOP PffiF: ~te: Refer to A"oduction DB for historical perf data SIZE SA= INTERV AL Opn/Sqz DATE SLTD 10490-11345 0 11/13/02 DATE REV BY COtvfv1ENfS 02/13/83 ORIGINAL COM PlETION 10/15/91 RWO(R-14) 11/13/02 JDMITP CTD SIŒTRACK (R-14A) 01/23/03 BrvvTP ECLlPSEPATa-I 03/27/03 JMA<A K FULL PA Ta-I/RUNNNG TOOLS 09/28/03 JL.vTLH Gl V C/O 11/29/03 KDC'TLP ECLIPSE PA Ta-I SET 01/16/04 3JMcMIlU IGl V C/O & PATCH CORRECT. DA. TE 03l18¡{)4 04l07¡{)4 04l24¡{)4 04130104 R-14A ~ )- 8 r-J L K & ~ g H I 1 ~ 8- .. . I .. 1 ,. 1 ~ 1 ) I SAFETY NOTES: -* 5-112" CHROMETBG*- ~ 31' H 7" lEG HGR / FUP JT 1 33' H7" X5-1/2"XOI 2111' H5-112" OTIS SSSV LAND NIP, ID = 4.562" I GAS LIFT MA NDRELS ST IVD TVD DEV TYÆ VLV LATCH PORT DATE 6 3079 2991 25 OTIS DOI'Æ RM 16 04/30/04 5 5338 4874 34 OTIS DOI'Æ RM 16 04130/04 4 7053 6263 36 OTIS DMY RA 0 09/28/03 3 8410 7396 31 OTIS DOI'Æ RM 16 04/30/04 2 9221 8052 39 OTIS SO RM 24 04/30/04 1 9329 8137 38 OTIS *NEEDS PATCH 1 -t I 19322' - 9362' HWfl-RFD ECLIPSE PATCH, ID= 2.860" 9366' 9371' 9394' 939S' H3-3/4" BAKERDER..OYMENTSLV, ID=3.00" 1 H3-112" t-ESXNNIP, ID= 2.75" I H llW A NeHOR LA TCH 1 H 9-518" X 5-1/2" TIW HBBP PKR, ID = 4.815" 1 950S' H5-112" IT FUP Jf/MJLE SI-K)E, ID= 4.892" I 9499' H ELIVD IT LOGGED 10/26191 I 9849' 1-13-112" X 3-3116" XO, ID=2.80" I I MlLOUTWINDOW 9888' - 9898' 994S' l--þ-3I16"X 2-718" XO, ID =2.44" I 3-3/16" LNR, 6.2#, L-80, ~ 9945' .0076 bpf, ID = 2.80" , , "', 1 11377 , , , , , , , , , , , , , , , , " ~ ) 12-7/8" SLID LNR, 6.16#, L-80, .0058 bpf, D =2.44" H 11378' I REV BY rvDCA<A K JLJ MJAA<AK RMHA<A K COtvfv1ENfS FISH PULL PA Ta-I & FISH SETEQIPSE PATCH GLV C/O H PBTD I PRUDI-K)E BAY lJ'JrT WELL: R-14A PffiMT f\b: 2021560 API f\b: 50-029-20909-01 SEC 32, T12N, R13E, 1444' FSL & 1756' FWL BP Exploration (Alas ka) ) STATE OF ALASKA') ALASKM ÓIL AND GAS CONSERVATION COr\,...i,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 Repair WellŒJ Pull Tubing 0 Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1560 OtherD BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 53.50 8. Property Designation: ADL-0028279 11. Present Well Condition Summary: Total Depth Development Œ] StratiQraphic D 9. Well Name and Number: R-14A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 Service 0 6. API Number 50-029-20909-01-00 measured 11378 feet Effective Depth true vertical 8818.8 feet Size 20" 91.5# H-40 3-1/2" 9.3# L-80 7" 26# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 32 112 32.0 112.0 1490 470 9358 - 9849 8213.5 - 8611.9 10160 10530 9566 - 9888 8379.5 - 8644.3 7240 5410 9849 - 9945 8611.9 - 8686.1 9945 - 11378 8686.1 - 8818.8 13450 13890 30 - 9823 30.0 - 8590.2 6870 4760 31 - 2697 31.0 - 2684.6 4930 2670 measured 11378 feet true vertical 8818.8 feet Casing Conductor Liner Liner Liner Liner Production Surface Perforation depth: Measured depth: 10490 -11345 True vertical depth: 8756.27 - 8803.34 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 20 338 950 Daily Report of Well Operations - ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature _ß~ Ca~ Form 1 0-404 Revised 12/2003 Length 80 491 322 96 1433 9793 2666 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - 7" 26# 13CR80 5-1/2" 17# 13Cr80 3-1/2" Eclipse Patch Packer 5-1/2" Baker HB Packer 9-5/8" DV Packer ECEI MAR 1 0 2004- @ @ 30 33 @ @ @ 33 9505 9322 9395 2592 Ala:;',ka I~~ Cons Anchor-lfi> ",.". Oil-Bbl 452 Tubing Pressure 367 1154 537 21.6 400 860 15. Well Class after proposed work: ExploratoryD DevelopmentŒ) ServiceD 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 Date 3/10/04 lijij~ URlö NA-. BFL MARl ') ') R-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/29/03 PUMP TBG KILL PRE E-LlNE TBG PATCH SET 11/29/03 TOP SECTION OF WFD TUBING PATCH SET AT 9307.1. STABBED LOWER SECTION AT 93611 WHILE LOGGING DOWN AT 200 FPM. 5.511 WFD TUBING PATCH SET IN PLACE FROM 9322 TO 9365.51. 11/30/03 TIO= VAC/860/30. IA FL @ 20201 (90 BBLS). (FOR FB). FLUIDS PUMPED BBLS 5 320 70 395 Methonal Water Crude TOTAL Page 1 TREE = 7" CrN WELLHEAD = MCEVOY ACi"ÜATöFf ~ "'''-AXElSON' kB"~"ËLBi"';'''''''' "'''''''''''''''5'3:5"0; 13F:"E[ËV"'''; .. ""...mom'" "'22~1"6; "KOP";" ....... .. "22()eV ^MaxÄngle = ^g7@'Tó49""g. Dãtuïîï"M5'-; 00-11378' YjatumTvD = --ãis5'SS' ') 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2697' Minimum ID = 2.44" @ 9945' 3-3/16" X 2-7/8" XO 15-1/2" TBG, 17#, 13-CR, .0232 bpf, ID = 4.892" l-i 9S0S' 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9823' 13-1/2" LNR, 9.20#, L-80, .0086 bpf, ID = 2.98" l-i 9849' 1 TOP OF WHIPSTOCK l-i 988S' 15" BAKERCIBP-10/31/02 l-i 9970' 1 15" LNR, 18#, C-95, .0177 bpf, ID = 4.276" l-i 10546' 1 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 10S93' ~ ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SL TD 10490 - 11345 0 11/13/02 DATE 02/13/83 10/15/91 11/13/02 01/23/03 03/27/03 09/28/03 REV BY COMMENTS ORIGINAL COM PLETION RWO (R-14) CTD SIDETRACK (R-14A) ECLIPSE PATCH PULL PA TCHlRUNNING TOOLS GL V C/O R-14A l J 8) ~ L ) SAFETY NOTES: *** 5-1/2" CHROMETBG*** 31' I-iT' TBG HGR/ PUPJT 1 33' I-iT' X 5-1/2" XO 1 2111' 1-i5-1/2" OTIS SSSV LAND NIP, ID = 4.562" 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3079 2991 25 OTIS DMY RA 0 01/15/04 5 5338 4874 34 OTIS DMY RA 0 01/15/04 4 7053 6263 36 OTIS DMY RA 0 09/28/03 3 8410 7396 31 OTIS DMY RA 0 09/28/03 2 9221 8052 39 OTIS DMY RA 0 09/28/03 1 9329 8137 38 OTIS DMY RA 0 09/28/03 19322'-9366'1- 5-1/2" ECLIPSE PATCH (11/29/03), ID = 2.970" NOTE: PATCH STUNG INTO BKR DEPLOY SL V ~ 9366' 9371' 9394' 939S' 1-i3-3/4" BAKER DEPLOYMENT SLY, ID = 3.00" 1 1-i3-1/2" HES XN NIP, ID = 2.75" 1 l-i TrN ANCHOR LATCH 1 1-i9-5/8" X 5-1/2" TrN HBBP PKR, ID = 4.815" 1 go g I ~ 9S0S' 1-i5-1/2" TT PUP JT/MULE SHOE, ID = 4.892" 1 9499' l-i ELMD TT LOGGED 10/26/91 1 H~ : g~ J l I ~ 9849' 1-i3-1/2"x3-3/16"xo,ID=2.80" 1 I MILLOUT WINDOW 9888' - 9898' 994S' I., 3-3/16" X 2-7/8" XO, ID = 2.44" 1 , , , " 1 11377' , ' , ' , ' , ' , ' , ' , ' , ' , ' ,~ 7 2-7/8"SLTDLNR,6.16#,L-80,.0058bPf,ID=2.44" l-i 11378' 1 3-3/16" LNR, 6.2#, L-80, -i 994S' .0076 bpf, ID = 2.80" l-i PBTD 1 DA TE REV BY COMMENTS 11/29/03 KDCffLP ECLIPSE PA TCH SET 01/16/04 BJMc MlTLH GL V C/O & PATCH CORRECT. JDMITP BM'TP JMlKAK JLJffLH PRUDHOE BAY UNIT WELL: R-14A ÆRMIT No: 2021560 API No: 50-029-20909-01 SEC 32, T12N, R13E, 1444' FSL & 1756' FWL BP Exploration (Alaska) " ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 11/19/03, Put on Production 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-156 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20909-01 4. Location of well at surface 9. Unit or Lease Name 1444' NSL, 1756' EWL, SEC. 32, T12N, R13E, UM X = 635391, Y = 5977927 Prudhoe Bay Unit At top of productive interval 817' NSL, 2541' WEL, SEC. 31, T12N, R13E, UM X = 631107, Y = 5977223 10. Well Number At total depth 4651 NSL, 3526' WEL, SEC. 31, T12N, R13E, UM X = 630130, Y = 5976855 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 53.5' ADL 028279 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 11/9/2002 11/11/2002 11/13/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11378 8819 FT 11378 8819 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES Classification of Service Well R-14A 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2111' MD 1900' (Approx.) 23. , CASING SIZE ,- 20" X 30" 13-3/8" 9-5/8" CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE WT. PER FT. GRADE Top BOTTOM SIZE Insulated Conductor Surface 110' 36" 72# L-80 Surface 2697' 17-1/2" 47# L-80 Surface 98231 12-1/4" 26# L-80 9566' 9888' 8-1/2" 18# C-95 9504' 98881 N/A 9.2#/6.2/6.16# L-80 9366' 113781 3-3/4" 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 2-7/8" Slotted Section MD TVD 10490' - 11345' 8756' - 8803' 7" 5" CEMENTING RECORD 8 cu yds Concrete 3535 cu ft Permafrost II 1362 cu ft Class 'G', 130 cu ft PF 'C' 310 cu ft Class 'GI 129 cu ft Class 'G' (Liner Tieback) Uncemented Slotted Liner TUSING RECORD DEPTH SET (MD) 95051 AMOUNT PULLED .3-1/2" x 3-3/16" x 2-7/8" SIZE 5-1/2", 17#, 13Cr PACKER SET (MD) 93951 MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production October 22, 2003 Date of Test Hours Tested 10/24/2003 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BSl TEST PERIOD 414 Flow Tubing Casing Pressure CALCULATED Press. 262 24-HoUR RATE Oll-Bsl 2,484 GAs-McF 22,223 GAs-McF 133,338 WATER-Bsl 36 WATER-Bsl 216 CHOKE SIZE 58° Oil GRAVITY-API (CORR) 27.8 GAS-Oil RATIO 53,615 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gaspr water. Submit core chips. No core samples were taken. RBDMS BFL NOV 2$ 20W tYDV2.ül003 Form 10-407 Rev. 07-01-80 ORIGfNAI \sç Submit In Duplicate ') ) 29. Marker Name Geologic Markers Measured Depth 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. . Sadlerochit 10152' 8725' NbV;~02ð03 '31. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrìeHubble~~ ~ ~ Title Technical Assistant Date ll-19'Q3 R-14A 202-156 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number . I Drilling Engineer: Ted Stang, 564-4694 Permit No. Approval No. /::1, INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), 50 state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 nq1G1NAI .) ') Well: Field: API: Permit: Date R-14A Prudhoe Bay Unit 50-029-20909-01 202-156 Accept: Spud: Release: Rig: 11/07/02 11/09/02 11/13/02 Nordic #2 POST RIG WORK 11/22/02 SET ECLIPSE PACKER WITH BAKER STINGER SEAL ASSEMBLY AT TOP OF 31/2" LINER (9358'), RAN A GRICCL JEWELRY LOG FROM 9500' TO 9174'. RDMO. WELL LEFT SHUT IN. 01/20/03 T/I/O = 560/1950180. IA FL @ 5736' (276 BBLS). (FL FOR EL TBG PATCH). 01/21/03 ATTEMPTED TO LOAD IA. STARTING PRESSURES 700/200010. IA STARTED BUILDING NOTICEABLE PRESSURE AFTER THE FIRST 20 BBLS. PUMPED A TOTAL OF 77 BBLS, IA UP TO 3000 PSI, TUBING @ 2300 PSI. BLEED DOWN IA TO 2500 PSI. FINAL PRESSURES 2500/2100/0. RIH WIUPPER ELEMENT OF 5-1/2" ECLIPSE PATCH (37' 5" LONG). LATCHED INTO BOTTOM ELEMENT (SET 11/22/02). SET TOOL WOULD NOT FIRE, PULLED OFF WEAK POINT, LEFT 40.5' PATCH AND 13' RUNNING TOOL IN HOLE. TOP OF FISH @ 9306'. 03/26/03 PULLED E-LINE RUNNING TOOL STRING FROM ECLIPSE PATCH PULLING OUT OF HOLE W/ 5 1/2" ECLIPSE PATCH. 03/27/03 PULLED 40' ECLIPSE PATCH (MISSING 1 ELEMENT) DRIFTED DOWN TO 9338' AMS NO PROBLEMS W/ WIRE GRAB (NO RUBBER ELEMENT RETURNED). 04/04/03 T/I/O=500/1960/0 FL FOR EL. TBG FL AT 1440' (33.5 BBLS). IA FL AT 7730' (339 B BBLS). DRIFT FOR PACKER ELEMENTS TO TOP OF 3 1/2 LINER, NONE RETRIEVED DRIFT TO 9600' WLM, 225' INTO CTD LINER. 04/08/03 T/I/O = 500/1950/20 BLEED lA, TIFL FAILED (PREP FOR TBG PATCH) TBG FL @ 1536' (36 BBLS). IA FL @ 7972' (349 BBLS). BLED IA FROM 1950 PSI TO 460 PSI IN 4 HRS WITH FLUID COMING TO SURFACE. NO CHANGE IN TBG PRESSURE WHILE BLEEDING IA. SI IA BLEED AND MONITOR FOR 30 MIN. TBG FL @ 1430', IA FL @ 320'. IA PRESSURE INCREASED FROM 460 PSI TO 620 PSI IN 30 MIN. AT LEAST SOME OF lAP INCREASE WAS DUE TO AL CASING VALVE LEAKING (FROST BUILDING). CALLED VALVE CREW TO SERVICE. FINAL WHP'S = 500/620/20. 04/09/03 T/I/O=SI/1200/0 (POST IA BLEED) IA FL @ 660'. lAP INCREASED 580 PSI IN 24 HRS. T/I/O=SI/1180/0 (POST IA BLEED) NO CHANGE IN lAP. 04/10/03 T/I/O=SI/1180/0 (POST IA BLEED) NO CHANGE IN lAP. , '\ R-14A, Coil Tubing Drilling, Post, )work Page 2 ) 04/15/03 IA PRESSURED UP TO 3000 PSI AFTER PUMPING 10 BBLS METH & 67 BBLS INHIBITED 1% KCL WATER, FREEZE PROTECT IA W/ 100 BBLS CRUDE & 10 BBLS METH. BRING TUBING PUMP ONLINE & PUMP 500 BBLS 10/0 KCL,88 BBLS FLO-PRO,200 BBLS 1% KCL DOWN TUBING SPOTTING FLO-PRO ACROSS PERFS. CAP TUBING W/ 40 BBLS CRUDE & 10 BBLS METH TO FREEZE PROTECT. 04/16/03 T/I/0=SI/920/0 (POST LOAD) MONITOR WHP'S. 09/26/03 RIH TO SET 5-1/2 SS C-SUB POOH W/ CATCHER. 09/27/03 , T/I/0=100/500/0. IA FL@ 955', TBG FL @ 1030' FOR (WL). SET 5 1/2" XN C-SUB @ 9321' SLM PULLED DGLV'S FROM STA #5 & #6. SET 1.5" LGLV (1/4", TRO 1500#) W/ RA LATCH IN STA #6 @ 3053' SLM. SET 1.5" ORIFICE (5/16) W/ RA LATCH IN STA #5 @ 5311' SLM. 09/28/03 PULLED CATCHER @ 9321' SLM. 10/25/03 TIO= 1300/1540/680. NFT-IA. FAILED FTS. (EVAL POST CTD TX IA). WELL IS FLOWING WITH OUT G/L. INITIAL IA FL @ 5600' (250 BBLS), SO SET @ 5338' STA # 5. SI WELL START BLEEDING lAP DOWN FLOW LINE TO 720 PSI IN 2.5 HOURS, FTS S/I BLEED. OAP DECREASED TO 200 PSI DURING THE BLEED. MONITOR WHPS FOR 30 MINS, IN 30 MINS lAP INCREASED 100 PSI & OAP DECREASED 40 PSI. R/D EQUIP. FINAL WHPS= 1480/820/160 P.O.P. NOTE: R-14A IS NO LONGER TWINED WITH R-16. 11/10/03 T/I/O= 1280/1000/0. PUMP 180 BBLS HOT CRUDE DOWN TBG FOR BRUSH AND FLUSH. FINAL WHP; T /1/0=200/1100/0. BRUSH & FLUSH 7" CASING @ 9316' WLM TO 9175' WLM, BRUSH THRU PACKER @ 9316' WLM W/ 3 1/2" BL BRUSH. RE: New Waivers ) :ht ~ 202- t5'Ç<> Subject: RE: New Waivers Date: Thu, 23 Oct 2003 17:54:30 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> To: Jim Regg <jim _regg@admin.state.ak.us> CC: Winton GAubert <winton_aubert@admin.state.ak.us>, Admin AOGCC Prudhoe Bay <aogcc -prudhoe - bay@admin.state.ak.us> Jim, The operator tells me that the well was POP on 10/21/03. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 -----Original Message----- From: Jim Regg [mailto:jim regg@admin.state.ak.us] Sent: Thursday, October 23, 2003 2:42 PM To: NSU, ADW Well Integrity Engineer Cc: Winton G Aubert; Admin AOGCC Prudhoe Bay Subject: Re: New Waivers BP internal waiver for Well R-14A allows a 2 wk flow period to assist with decisions about waiver or repair; what is the status? Jim Regg "NSU, ADW Well Integrity Engineer" wrote: > Hi Jim and Win ton. > Attached are several waivers: > > M-26: TxIAxOA > NGI-07: Slow IAxFormation > R-14: 14-day flow waiver, post CTD. > > «M-26 TxIAxOA 09-15-03.ZIP» «NGI-07 Slow IA x Formation 09-15-03.ZIP» > «R-14A T x IA Flow Waiver 09-1B-03.ZIP» > > Please call if you have any questions > Joe Anders, P.E. > Well Integrity Coordinator, BP Exploration, (Alaska) Inc. > Work: (907) 659-5102 > Mobile: (907) 943 -1154 > Pager: (907) 659-5100, xl154 > Email: NSUADWWellIntegrityEngineer@bp.com > > ------------------------------------------------------------------------ > > M-26 TxIAxOA 09-15-03.ZIP (application/x-zip-compressed) > Encoding: base64 Name: M-26 TxIAxOA 09-15-03.ZIP Type: Zip Compressed Data > > Name: NGI-07 Slow IA x lof2 10/2312003 3: 11 PM RE: New Waivers 20[2 Formation 09-15-03.ZIP > NGI-07 Slow IA x Formation 09-15-03.ZIP (application/x-zip-compressed) > > > 09-18-03.ZIP > R-14A T x IA Flow Waiver 09-18-03.ZIP (application/x-zip-compressed) > Type: Zip Compressed Data Encoding: base64 Name: R-14A T x IA Flow Waiver Type: Zip Compressed Data Encoding: base64 10/23/2003 3: 11 PM 2- Scblumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well A-20 I ?d. --0/3 PWDW2-1 J í ~ -°lr ~ V-03 ~œ-a I ~ 1-51N-20 I qd -II q R-14A ~- ,~((, R-14A R-14A R-14A ---/ Job# Log Description GLS LDL STATIC SURVEYITEMP/PRESS INJECTION PROFILE 23086 LDWG EDIT ARC RESISTIVITY DATA 23086 MD VISION RESISTIVITY 23086 TVD VISION RESISTIVITY 23086 MD VISION RESISTIVITY (BHP) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~R.. . r("r-~Vt:rD' å "¡¡::vCU' ~' .... r (',1"\"7 MAK ¿ 0 LuvJ 1\.1"'$1.0'" ("'\l.~ & Gas Cons. CQmrni~n ~H:.!..."~ ,..;11 And1ctage NO. 2702 Company: 03/18/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott Color Date Blueline Prints CD 03/05/03 1 02107/03 1 03/03/03 1 03/07/03 1 11/11/02 11/11/02 1 11/11/02 1 11/11/02 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~ 'f- RecejV~ ~ '-' ~ '. ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1444' NSL, 1756' EWL, SEC. 32, T12N, R13E, UM At top of productive interval 817' NSL, 2541' WEL, SEC. 31, T12N, R13E, UM X = 631107, Y = 5977223 10. Well Number At total depth 465' NSL, 3526' WEL, SEC. 31, T12N, R13E, UM X = 630130, Y = 5976855 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 53.5' ADL 028279 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 11/9/2002 ø 11/11/2002 I 11/13/2002 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11378 8819 FT 11378 It 8819 FT 181 Yes DNa 22. Type Electric or Other Logs Run MWD, GR, RES Classification of Service Well D Suspended D Abandoned¡::~:~~,ÿ~": I ,';~ ""T, ~ ~;ðf,- \/;;:)\ P¡~¡) 7. Permit Number 202-156 8. API Number 50- 029-20909-01 9. Unit or Lease Name X = 635391, Y = 5977927 Prudhoe Bay Unit R-14A 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2111' MD 1900' (Approx.) '17tV:-¡".J~,d I/g9S' h?,Þ ~Çf$ 'rrb 23. CASING SIZE 20" X 30" 13-3/8" 9-518" CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE WT. PER FT. GRADE Top BOTTOM SIZE Insulated Conductor Surface 110' 36" 72# L-80 Surface 2697' 17-1/2" 47# L-80 Surface 9823' 12-1/4" 26# L-80 9566' 9888' 8-1/2" 18# C-95 9504' 9888' NIA 9.2#/6.2/6.16# L-80 9366' 11378' 3-3/4" 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 2-7/8" Slotted Section 7" 5" CEMENTING RECORD 8 cu yds Concrete 3535 cu ft Permafrost II 1362 cu ft Class 'G', 130 cu ft PF 'C' 310 cu ft Class 'G' 129 cu ft Class 'G' (Liner Tieback) Uncemented Slotted Liner TUBING RECORD DEPTH SET (MD) 9505' AMOUNT PULLED . 3-1/2" x 3-3/16" x 2-7/8" SIZE 5-1/2", 17#, 13Cr PACKER SET (MD) 9395' MD TVD 10490' - 11345' 8756' - 8803' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chi" j ;~, No core samples were taken. RBDMS BF l Form 10-407 Rev. 07-01-80 FEB I 9 200$ubmit In Duplicate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sadlerochit 1 0152' 8725' 31. List of Attachments: \ Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I ~erebY certify that the fO~Oin? is tru, e and correct to the best of my knowledge Signed Terrie Hubble ~OMJJl ~ Title Technical Assistant Date tJa. ( 1"'03 R-14A 202-156 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Ted Stagg, 564-4694 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: Ifthis well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. hEM 28: If no cores taken, indicate 'none'. l... Form 10-407 Rev. 07-01-80 ) ) BP..EXPLORATION "'.'."Qp.r..'iøþ-~.'~t)mm'~ty:.:R~pØff' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-14 R-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2002 Rig Release: 11/13/2002 Rig Number: Spud Date: 1/29/1983 End: Date From7To Hours. Tas: ( COdeNPT 11/6/2002 1.50 MOB 9.00 MOB 13:30 - 15:00 15:00 - 00:00 P N PRE WAIT PRE 11/7/2002 1.00 MOB N 2.00 MOB P 3.00 BOPSUR P WAIT PRE PRE PRE 00:00 - 01 :00 01 :00 - 03:00 03:00 - 06:00 06:00 - 06:30 06:30 -10:15 0.50 BOPSURP 3.75 BOPSUR P PRE DECOMP 10:15 - 10:30 10:30 - 14:30 0.25 BOPSUR P 4.00 BOPSUR N DECOMP SFAL DECOMP 14:30 - 14:45 0.25 BOPSUR P DECOMP 14:45 - 18:00 3.25 BOPSUR P DECOMP 18:00 - 19:00 1.00 BOPSURP DECOMP 19:00 - 21 :30 2.50 BOPSUR P DECOMP 21 :30 - 21 :45 0.25 STWHIP P WEXIT 21 :45 - 00:00 2.25 STWHIP P WEXIT 11/8/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 02:50 1.33 STWHIP P WEXIT 02:50 - 03:30 0.67 STWHIP P WEXIT 03:30 - 05:30 2.00 STWHIP P WEXIT 05:30 - 08:00 2.50 STWHIP P WEXIT 08:00 - 12:00 4.00 STWHIP P WEXIT 12:00 - 14:00 2.00 STWHIP P WEXIT 14:00 - 15:00 1.00 STWHIP P WEXIT Continue prep for rig move. Back rig off R-14. Standby on pad while location prep is completed. Pad found to be not level once well house was removed. Haul in gravel. Delay is due to winds which delayed well house removal. Continue leveling pad. MIRU Nordic #2 over well. Remove tree cap and install BOP stack. Accept rig at 0300 hrs on 11/7/02. Crew change. PJSM and TL meeting Secure BOP stack. Spot other rig equipment. RIU BOP test equipment. PJSM on testing BOP's. Fill stack w/ H2O. Full body test 250/3500 psi. Test lower 2-3/8" combi's. Slips failed to hold test joint during high pressure build-up at 3100 psi (accumulator's manifold closing pressure not set to highside). 2-3/8" test joint pushed out of BOP stack, landing on rotary table. No personnel on rig floor while testing. No-Go failed to stop test joint under the rams (tj pin-end cracked). Stop operation to investigate failure. Remove & replace 2-3/8" combi rams. Recover No-Go from top of swab valve. Locate a second test joint. Hold PJSM before resuming BOP test. Continue testing BOPE. 250/3500psi Crew change. PJSM and Tech Limit meeting. Continue testing BOPE. 250/3500psi. Perform accumulator function test and check bottle pressures. PJSM handling injector and cut coil. P/U injector and cut 50' of 2 3/8" coil. Make up Baker coil connecter Continue to install Baker connector. Pull test to 40k. PT to 3500 psi. Test inner reel valve 3500 psi Displace meth from coil. Same time p/u BHA #1. Disconnect placed under the PH-6 P/U and stab on injector. RIH to 3500'. Displace meth to cuttings tank. Continue RIH. Tagged at 9885' coil depth. (expected +/-9850' cmt top). Top of whipstock is 9885'. 41k# up, 20k# dn wt. Up & dn wt varies with pipe running speed (We are told this is due to chrome tbg) Motor stalling so would have to assume we are on the whipstock. Start window milling. 2.5 bpm in/out 1410 psi off btm pressure. Mill to 9890.1'. Maintain 400 psi or less diff press. Milling to 9891.4'. 1650 psi free spin. Motor work increasing above 400 dpsi. PU and time ream slowly back down through window. 2.5 bpm in & out. Continue trying to mill and keep motor work near 400 psi. Pressure keeps jumping to 600-900 psi above free spin near btm. Time mill 0.1' every 5 minutes using weight instead of motor work. Mill to 9892.1'. Gradually motor work dropped back to 300-500 psi. Able to mill ahead within this pressure range once again. Printed: 11/18/2002 4:00:25 PM ') ') Bp:EXPLC)'AATlQN . ., . . - , . Q:p~;r'Jiørt_:S."'rnr11.tY;ß'P9n ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-14 R-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date " From -1 () HoUrs TasK:,>Code. NPJ ' Phase WEXIT 11/8/2002 15:00 - 21 :20 6.33 STWHIP P 21 :20 - 22:25 1.08 STWHIP P 22:25 - 23:40 1.25 STWHIP P 23:40 - 00:00 0.33 STWHIP P 00:00 - 03:00 3.00 STWHIP P 03:00 - 04:00 1.00 STWHIP P 04:00 - 05:15 1.25 DRILL P 05:15 - 05:40 0.42 DRILL P 05:40 - 06:30 0.83 DRILL P 06:30 - 07:30 1.00 DRILL P 07:30 - 08:45 1.25 DRILL P 08:45 - 09:25 0.67 DRILL P 09:25 - 12:30 3.08 DRILL P 12:30 - 14:30 2.00 DRILL P 14:30 - 15:00 0.50 DRILL P 15:00 - 18:50 3.83 DRILL P 11/9/2002 18:50 - 21 :00 2.17 DRILL P 21 :00 - 23:45 2.75 DRILL P 23:45 - 00:00 0.25 DRILL P 11/1 0/2002 00:00 - 00:20 0.33 DRILL P 00:20 - 00:40 0.33 DRILL P 00:40 - 02:00 1.33 DRILL P 02:00 - 02:40 0.67 DRILL P 02:40 - 02:55 0.25 DRILL P 02:55 - 03:40 0.75 DRILL P 03:40 - 06:00 2.33 DRILL P 06:00 - 06:45 0.75 DRILL P 06:45 - 08:45 2.00 DRILL P 08:45 - 10:00 1.25 DRILL P 10:00 -10:30 0.50 DRILL P 10:30 - 11 :30 1.00 DRILL P 11 :30 - 14:00 2.50 DRILL P 14:00 - 14:45 0.75 DRILL P 14:45 - 15:30 0.75 DRILL P 15:30 -17:30 2.00 DRILL P 17:30 -18:30 1.00 DRILL P 18:30 - 20:00 1.50 DRILL P 20:00 - 21 :00 1.00 DRILL P 21 :00 - 22:00 1.00 DRILL N WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 Start: 11/6/2002 Rig Release: 11/13/2002 Rig Number: Spud Date: 1/29/1983 End: Milling window. Through window 9897.5' and drilling formation at 2120 hrs. 2400-2800 psi on btm @ 2.5 bpm Drilling formation f/9897.5' to 9908'. Wash and ream window area. RIH dry without tagging. Circulate Pump 20 bbl high vis Bio-Zan sweep from bottom. TOH flagged pipe at 9700'. Set back injector. Kick drill. UD BHA #1 P/U BHA #2. Align and program toolfaces. Stab on injector RIH Shallow test mwd system at 2300'. Some minor problems getting TORC signals on pump #2. Continue to run in hole. Log GR tie in from 9850' to 9880'. Subtract l' correction. Begin displacement to mud. Drill ahead. 39k# up, 20 k# dn wt. 2.7 in/out 2700 psi fs. Drill to 9970'. Drill ahead to 10020'. Short trip to window. Drill ahead. 2.7 in/out. 2700 psi fs. ROP: 30-50 fph. Begining to get good surveys now that we are away from casing. Drill to 10135'. Total on bottom drilling hrs 7.58 TOH f/laterial BHA Setback injector, I/d BHA #2. p/u BHA #3 align toolfaces. P/U and stab injector. RIH wI BHA #3 RIH to 2400'. Shallow hole test MWD and TORQ. ok Continue RIH to 9865'. Log tie-in. -5' correction RIH to TD Orient TF Directionally drill f/10135'. 2.80 in/out 2845 FS 3310 on btm 100'/hr. Start loosing .3 bpm at 10145' healing back up by 10155'. Drilling ahead 10250' @ 0600 hrs Short trip to window. Hole smooth. Drilling ahead at 10400'. 2.6 in/out. 100-120 fph. 2750 free spin. 100-150 fph rop. Drill to 10426' Short trip to window Repair small leak on hydraulic power pack. RIH. Re-survey several stations. Drilling ahead. 2800 fs/2.7 in/out/100-150 fph. Drill to 10580'. Short trip to window. Hole smooth. Drilling ahead. 2850 fs/2.7/50-75 fph. Unable to get enough turn from motor, probably due to soft formation. POOH for motor angle change. Setback injector. UD MWD & download, re-adjust motor to 1.69 deg. Cut 100' coil. Rehead w/ Baker CC. Pull test 40k PT 3500psi P/U MWD. Align toolfaces. Maintenance on Schlumberger's Power Pack. Fixing several small hydraulic projects. Printed: 11/18/2002 4:00:25 PM ') ) Legal Well Name: R-14 Common Well Name: R-14 Spud Date: 1/29/1983 Event Name: REENTER+COMPLETE Start: 11/6/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 11/13/2002 Rig Name: NORDIC 2 Rig Number: Qaté From-To H()ÜrsTask. DeseriptiqmofOperations 11/10/2002 22:00 - 22:40 0.67 DRILL P PROD1 Stab on injector 22:40 - 00:00 1.33 DRILL P PROD1 RIH to 2400'. Shallow hole test MWD and TORQ - ok. Continue to RIH 11/11/2002 00:00 - 01 :30 1.50 DRILL P PROD1 RIH to 9865'. 01 :30 - 03:15 1.75 DRILL P PROD1 Log tie-in. Unable to see marker. Tie-in again higher up. -6' correction 03: 15 - 04:00 0.75 DRILL P PROD1 RIH to TD 04:00 - 06:00 2.00 DRILL P PROD1 Directionally drill from 10635'.2850 fs 3150 on btm @ 2.7 bpm. Depth at 0600 hrs 10720'. 06:00 - 08:00 2.00 DRILL P PROD1 Drilling ahead. 2800/3200/2.7 bpm. Drill to 10830'.. Begin displacement to new mud system. Ship old mud to MI plant. 08:00 - 08:45 0.75 DRILL P PROD1 Short trip to window. Hole smooth. 08:45 - 11 :00 2.25 DRILL P PROD1 Drilling ahead. 2950/3350/2.7 bpm. Drill to 10925. New mud helping ROP. 11:00-12:15 1.25 DRILL P PROD1 Wiper trip to window. Hole smooth. 12:15 -13:30 1.25 DRILL P PROD1 Drilling ahead 13:30 - 14:45 1.25 DRILL P PROD1 Wiper trip to window. Hole smooth. 14:45 - 15:30 0.75 DRILL P PROD1 Drilling ahead. 2950/3250/2.6 bpm.. ROP:100-150 fph. Drill to 11075'. 15:30 -16:30 1.00 DRILL P PROD1 Wiper trip to window. 16:30 - 18:00 1.50 DRILL P PROD1 Drilling ahead. Looking for water. 2850/3450/2.7 in/out. Drill to 11315'. 18:00 - 21 :25 3.42 DRILL P PROD1 Wiper trip to window. Hole smooth. Resurveyed at 5 locations. 21 :25 - 21 :45 0.33 DRILL P PROD1 Drill to 11375' TD. Never seen water. Close to drilling into 3rd fault. 21:45 - 23:10 1.42 DRILL P PROD1 Short trip to 9860' coil depth. 23: 1 0 - 00:00 0.83 DRILL P PROD1 Log tie-in. 11/12/2002 00:00 - 00:30 0.50 DRILL P PROD1 Continue log tie-in. +4' correction. 00:30 - 01 :30 1.00 DRILL P PROD1 RIH to TD. Correct TD to 11378'. 2.8 bpm in/out 01 :30 - 02:30 1.00 DRILL P PROD1 TOH to window. Hole smooth no problems 02:30 - 03:40 1.17 DRILL P PROD1 RIH to TD. 03:40 - 04:30 0.83 DRILL P PROD1 POH lay in hi-vis LubeTex pill from TD to window. Install 175's on shaker 04:30 - 06:00 1.50 DRILL P PROD1 Launch 13/16" ball open circ sub w/3100 psi. POH pump at 5 bpm 3500 psi. Flagged EOP at 7000'. 06:00 - 07:30 1.50 DRILL P PROD1 POOH to surface. RIH and displace well for fresh water from 2000' (to help reduce flow back while running liner) 07:30 - 09:30 2.00 DRILL P PROD1 Set back injector. LD drilling BHA. 09:30 - 09:45 0.25 DRILL P PROD1 Hold PJSM to discuss running liner. 09:45 - 16:00 6.25 CASE P COMP Stand 2-3/8" PH6 safety joint in derrick. Run 2-7/8 x 3-3/16 x 3-1/2 liner assembly. (64 joints & 1 pup) 16:00 - 18:00 2.00 CASE P COMP MU liner setting & tie back sleeve assy with Baker CTLRT. MU & test acme type Baker coil connector. 18:00 - 18:45 0.75 CASE P COMP Stab onto well. 18:45 - 21 :00 2.25 CASE P COMP RIH to flag. 9033.9 correct -8' to 9025. RIH to 9790' 43K UP wt, 24K DN. 21 :00 - 21 :35 0.58 CASE P COMP Continue to RIH. No problen thru window. To 11373.6' TD. PU wt 47K. Hole in good condition. 21 :35 - 21 :50 0.25 CASE P COMP Position to drop ball. Drop ball. Kick out with 200 psi. Set down 10K. 21 :50 - 23:20 1.50 CASE P COMP Circulate ball to liner running tool 2.3 bpm at 1900 psi. for 25 bbls 16 bbl volume still on reel. Reduce rate to .46 bpm 952 psi. Pump total 79 bbl coil volume 52.6 bbl. Seen no indication Printed: 11/1812002 4:00:25 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) .BP:E:><e:t.ORf\JtON ' -.. -, .. ... Q;Þ~;r'1i:()n;~.,;~\J¡rn:ìp;.!ÎJ';':~..ÞÞ;" R-14 R-14 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/6/2002 Rig Release: 11/13/2002 Rig Number: Spud Date: 1/29/1983 End: Date From - To Hours, Task. COde. NPT 11/12/2002 21 :50 - 23:20 23:20 - 00:00 11/13/2002 00:00 - 02:00 02:00 - 02:45 02:45 - 05:00 05:00 - 06:00 06:00 - 06:45 06:45 - 08:45 08:45 - 09:30 09:30 - 11 :30 11 :30 -13:00 13:00 - 15:00 15:00 - 21 :00 1.50 CASE P 0.67 DRILL P COMP PROD1 2.00 CASE N DFAL COMP 0.75 CASE N DFAL COMP 2.25 CASE N DFAL COMP 1.00 CASE N DFAL COMP 0.75 CASE N DFAL COMP 2.00 CASE N 0.75 CASE N DFAL COMP DFAL COMP 2.00 CASE P COMP 1.50 CASE N 2.00 CASE P 6.00 RIGD P WAIT COMP COMP COMP of seat shearing. Check ball drop. No Ball. Circulate 20 bbl 3 bpm 2790 psi. Slow rate to .9 bpm @1348 psi displace balance of second volume. Drop second 5/8 steel Ball and kick out with high vis pill at 800 psi. Definitely heard ball leave. Displaced at 3 bpm , 2790 psi. After 35 bbl slow to .7 bpm at 1417 psi. No Go. Review option with Baker dart versis foam pig. Consult with Nordic 1 on same. Obtained foam pig from Witlow. Drop foam pig and displace at 2.4 bpm 2161 psi. Seen pressure increase on one coil displacement. Circulate as high as 4.5 bpm at 4600 psi. Un able to generate 2000 psi differential required to release hanger. Circulate at 4000 psi while working pipe. PU 47K Still there. Work pipe SO to 17K in compression. Work pipe without pressure. Worked pipe total of 6 cycles. No go. Up weight 47K still there. POH. 50 ftImin thru window. Hole on good shape. Set back injector. Break out ball catcher sub. Ball seat sheared two balls in catcher. PU dual catcher with dart or ball capability. Stab injector. Tour and Tech Limits meetings.Subject rerun liner. RIH while holding mtg. RIH No problems at window or in open hole. RIH to 11,381'. Up weight 48K. Drop 5/8" Phenolic 1.9 SG ball. Lauch ball with 500 psi.pump 25 bbls @ 2.5 bpm and 1865 psi. Reduce rate to .75 bpm @1234 psi. Ball on seat 49.4 bbl. Coil volume 52.6 bbl. Pressure to 4200 psi to shear seat and release liner running tool. PU 38400#. 10000# loss. Top of liner at 9365'. TD at 11378'. Change over to KCL. POOH to 2000'. Wait on additional 60/40 to complete freeze protection. Tag up. LD BHA. Clean pits & cuttings tank. ND BOPS. NU tree cap. Test same. Release rig at 2100 hrs 11-13-02. Printed: 11/1812002 4:00:25 PM Well: Field: API: Permit: Date ') ) 11/07/02 11/09/02 11/13/02 Nordic #2 11/22/02 SET ECLIPSE PACKER WITH BAKER STINGER SEAL ASSEMBLY AT TOP OF 3 1/2" LINER (9358'), RAN A GR/CCL JEWELRY LOG FROM 9500' TO 9174'. RDMO. WELL LEFT SHUT IN. R-14A Prudhoe Bay Unit 50-029-20909-01 202-156 Accept: Spud: Release: Rig: POST RIG WORK 01/20/03 T/I/O = 560/1950/80. IA FL @ 5736' (276 BBLS). (FL FOR EL TBG PATCH). 01/21/03 ATTEMPTED TO LOAD IA. STARTING PRESSURES 700/2000/0. IA STARTED BUILDING NOTICEABLE PRESSURE AFTER THE FIRST 20 BBLS. PUMPED A TOTAL OF 77 BBLS, IA UP TO 3000 PSI, TUBING @ 2300 PSI. BLEED DOWN IA TO 2500 PSI. FINAL PRESSURES 2500/210010. RIH WIUPPER ELEMENT OF 5-1/2" ECLIPSE PATCH (37' 5" LONG). LATCHED INTO BOTTOM ELEMENT (SET 11/22/02). SET TOOL WOULD NOT FIRE, PULLED OFF WEAK POINT, LEFT 40.5' PATCH AND 13' RUNNING TOOL IN HOLE. TOP OF FISH @ 9306'. SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field....................: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: R-14a API number........ .......: 50-029-20909-01 Engineer............ .....: Flores Rig Label................: Nordic 2 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Correlation Marker GL above permanent... ....: N/A KB above permanent... ....: N/A DF above permanent.......: N/A ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft @9836'MD Azimuth from rotary table to target: 275.45 degrees 12-Nov-2002 06:54:21 Spud date. . . . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey.......: MD of last survey..... ...: Page 1 of 3 08-Nov-02 12-Nov-02 38 9800.00 ft 11378.00 ft ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2002 Magnetic date............: 08-Nov-2002 Magnetic field strength..: 1150.56 RCNT Magnetic dec (+E/W-). ....: 25.97 degrees Magnetic dip......... ....: 80.83 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: R..............: Dip. . . . . . . . . . . . : of G...........: of R.. . . . . . . . . . : of Dip......... : Criteria --------- 1002.68 mGal 1150.56 RCNT 80.83 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.97 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.97 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~ SCHLUMBERGER Survey Report 12-Nov-2002 06:54:21 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type ( deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9800.00 33.87 270.20 0.00 8517.63 3963.68 -540.46 -4033.24 4069.29 262.37 0.00 TIP None 2 ~9885.00 33.55 270.15 85.00 8588.34.. 4010.65 -540.32 -4080.41 4116.03 262.46 0.38 MWD M None 3 9904.54 38.06 269.00 19.54 8604.18 4022.02 -540.41 -4091.84 4127.37 262.48 23.34 MWD M None - 4 9929.00 46.63 264.00 24.46 8622.25 4038.26 -541.47 -4108.26 4143.79 262.49 37.62 MWD M None 5 9963.00 59.26 259.00 34.00 8642.70 4064.50 -545.57 -4135.01 4170.84 262.48 38.94 MWD M None 6 9994.74 73.53 257.25 31.74 8655.38 4092.18 -551.56 -4163.39 4199.77 262.45 45.24 SP None ~. 7 10026.26 83.15 257.00 31.52 8661.74 4121.45 -558.44 -4193.45 4230.47 262.41 30.53 SP None 8 10056.26 85.13 245.50 30.00 8664.82 4148.62 -568.02 -4221.65 4259.70 262.34 38.66 SP None 9 10087.11 89.50 234.85 30.85 8666.26 4173.73 -583.33 -4248.34 4288.20 262.18 37.30 SP None 10 10131.76 83.88 223.25 44.65 8668.85 4204.41 -612.48 -4281.94 4325.52 261.86 28.82 SP None 11 10160.75 78.75 222.02 28.99 8673.23 4221.72 -633.56 -4301.34 4347.75 261.62 18.18 SP None 12 10211.68 71.88 219.67 50.93 8686.14 4250.25 -670.79 -4333.55 4385.16 261.20 14.23 SP None 13 10256.63 76.85 216.12 44.94 8698.25 4273.44 -704.93 -4360.11 4416.73 260.82 13.44 SP None 14 10303.52 81.68 213.20 46.90 8706.99 4295.91 -742.82 -4386.29 4448.75 260.39 11.98 SP None 15 10344.67 86.48 210.75 41.15 8711.23 4314.18 -777.54 -4407.95 4476.00 260.00 13.07 SP None 16 10371.34 90.05 209.87 26.67 8712.04 4325.38 -800.55 -4421.40 4493.29 259.74 13.81 SP None 17 10409.50 93.19 215.34 38.16 8710.96 4342.78 -832.66 -4441.95 4519.32 259.38 16.52 MWD M None 18 10447.50 96.46 217.59 38.00 8707.77 4362.29 -863.11 -4464.44 4547.11 259.06 10.43 MWD M None - 19 10498.50 97.12 217.29 51.00 8701.74 4389.12 -903.32 -4495.23 4585.09 258.64 1.42 MWD M None - 20 10556.61 95.05 222.92 58.11 8695.57 4421.96 -947.49 -4532.44 4630.42 258.19 10.27 SP None 21 10605.43 93.68 226.45 48.82 8691.86 4452.75 -982.09 -4566.67 4671.08 257.86 7.74 SP None ~~ 22 10656.80 90.40 234.70 51.37 8690.03 4489.09 -1014.66 -4606.28 4716.71 257.58 17.25 SP None 23 10706.14 88.60 246.45 49.34 8690.46 4529.49 -1038.86 -4649.18 4763.83 257.40 24.11 SP None 24 10741.12 87.20 254.27 34.98 8691.74 4561.12 -1050.61 -4682.07 4798.50 257.35 22.70 SP None 25 10798.84 93.20 264.50 57.72 8691.54 4616.49 -1061.23 -4738.70 4856.08 257.38 20.53 SP None 26 10837.74 95.95 272.15 38.90 8688.43 4654.93 -1062.37 -4777.43 4894.12 257.46 20.84 SP None 27 10890.94 95.10 286.92 53.20 8683.28 4707.60 -1053.62 -4829.50 4943.10 257.69 27.70 SP None 28 10940.21 89.20 295.92 49.27 8681.43 4754.86 -1035.66 -4875.27 4984.06 258.01 21.82 SP None 29 10984.85 88.38 306.22 44.64 8682.38 4795.05 -1012.66 -4913.44 5016.71 258.35 23.14 SP None 30 11024.42 89.75 303.15 39.57 8683.02 4829.57 -990.15 -4945.97 5044.11 258.68 8.52 SP None SCHLUMBERGER Survey Report 12-Nov-2002 06:54:21 Page 3 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 31 11065.37 90.70 294.60 40.95 8682.86 4867.11 -970.40 -4981.80 5075.43 258.98 20.98 SP None 32 11100.69 89.10 287.70 35.32 8682.92 4901.09 -957.66 -5014.72 5105.34 259.19 20.05 SP None 33 11148.94 83.13 277.92 48.25 8686.20 4948.75 -946.99 -5061.58 5149.40 259.40 23.70 SP None 34 11201.49 75.43 271.00 52.55 8695.98 5000.31 -942.95 -5112.98 5199.20 259.55 19.55 SP None 35 11259.75 69.18 261.27 58.26 8713.71 5054.99 -946.60 -5168.26 5254.23 259.62 19.17 SP None 36 11296.94 65.13 254.25 37.19 8728.17 5087.61 -953.84 -5201.72 5288.45 259.61 20.55 SP None 37 11331.14 62.10 247.92 34.20 8743.38 5115.51 -963.74 -5230.68 5318.73 259.56 18.76 SP None Survey Projected to TD 38 11378.00 62.10 247.92 46.86 8765.31 5152.23 -979.31 -5269.06 5359.29 259.47 0.00 MWD M None [(c)2002 IDEAL ID8_0C_06J -' õ R-14A Schlumberger Survey Report - Geodetic Report Date: 12.Nov.02 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: Shared Services Drilling Vertical Section Azimuth: 275.450° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure I Slot: R-PAD / R-14 TVD Reference Datum: MSL Well: R-14 TVD Reference Elevation: 0.000 ft relative to MSL Borehole: R-14A UWVAPI#: 500292090900 Magnetic Declination: +25.955° Survey Name I Date: R-14A / November 12, 2002 Total Field Strength: 57528.114 nT Tort I AHD / DDI/ ERD ratio: 368.933° /5580.59 ft /6.427 / 0.637 Magnetic Dip: 80.828° ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: November 18, 2002 Location LatlLong: N 70 20 51.311, W 148 54 3.20E Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 5977927.300 ftUS, E 635390.600 ftUS North Reference: True North Grid Convergence Angle: +1.03510115° Total Corr Mag North -> True North: +25.955° Grid Scale Factor: 0.99992082 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S Ei-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 9800.00 33.87 270.20 8517.65 3963.52 -540.52 -4033.08 5977314.06 631368.27 N 7020 45.984 W 148 56 1.046 9885.00 33.55 270.15 8588.36 4010.49 -540.37 -4080.26 0.38 5977313.36 631321.10 N 70 20 45.985 W 148 56 2.424 9904.54 38.06 269.00 8604.20 4021.86 -540.46 -4091.69 23.34 5977313.06 631309.68 N 70 20 45.984 W 148 562.758 9929.00 46.63 264.00 8622.27 4038.10 -541.53 -41 08.1 0 37.62 5977311.70 631293.28 N 702045.974 W 148 56 3.238 9963.00 59.26 259.00 8642.72 4064.34 -545.62 -4134.85 38.94 5977307.12 631266.61 N 70 20 45.933 W 148564.020 9994.74 73.53 257.25 8655.40 4092.02 -551.62 -4163.24 45.24 5977300.62 631238.35 N 70 20 45.874 W 148564.849 10026.26 83.15 257.00 8661.76 4121.29 -558.49 -4193.29 30.53 5977293.20 631208.42 N 702045.806 W 148 56 5.727 10056.26 85.13 245.50 8664.83 4148.46 -568.07 -4221.50 38.70 5977283.11 631180.39 N 702045.712 W 148566.551 10087.11 89.50 234.85 8666.28 4173.58 -583.37 -4248.19 37.27 5977267.33 631153.99 N 702045.561 W 148 56 7.330 '-..-ø 10131.76 83.88 223.25 8668.87 4204.26 -612.52 -4281.79 28.82 5977237.59 631120.92 N 70 20 45.275 W 148 568.312 10160.75 78.75 222.02 8673.24 4221.58 -633.59 -4301.20 18.19 5977216.17 631101.90 N 70 20 45.067 W 148568.878 10211.68 71.88 219.67 8686.15 4250.11 -670.83 -4333.41 14.21 5977178.36 631070.37 N 702044.701 W 148569.819 10256.63 76.85 216.12 8698.26 4273.30 -704.98 -4359.97 13.42 5977143.74 631044.43 N 70 20 44.365 W 148 56 10.594 10303.52 81.68 213.20 8707.00 4295.77 -742.86 -4386.15 11.98 5977105.39 631018.94 N 70 20 43.992 W 148 56 11.359 10344.67 86.48 210.75 8711 .24 4314.04 -777.57 -4407.81 13.08 5977070.30 630997.91 N702043.651 W1485611.991 10371.34 90.05 209.87 8712.05 4325.24 -800.58 -4421.27 13.79 5977047.05 630984.88 N 70 20 43.424 W 148 56 12.384 10409.50 93.19 215.34 8710.97 4342.64 -832.70 -4441.81 16.52 5977014.57 630964.92 N 70 20 43.108 W 1485612.983 10447.50 96.46 217.59 8707.77 4362.15 -863.15 -4464.31 10.43 5976983.72 630942.98 N 702042.809 W 148 56 13.640 R-14A ASP Final Surveys.xls Page 1 of 2 11/19/2002-10:28 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S EI-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 10498.50 97.12 217.29 8701.74 4388.97 -903.36 -4495.09 1.42 5976942.97 630912.92 N 702042.413 W 148 56 14.539 10556.61 95.05 222.92 8695.58 4421.82 -947.53 -4532.30 10.27 5976898.14 630876.52 N 70 20 41.978 W 1485615.625 10605.43 93.68 226.45 8691.86 4452.61 -982.13 -4566.53 7.74 5976862.92 630842.93 N 70 2041.638 W 1485616.625 10656.80 90.40 234.70 8690.03 4488.95 -1014.70 -4606.15 17.27 5976829.65 630803.91 N 70 20 41.317 W 148 5617.782 10706.14 88.60 246.45 8690.46 4529.36 -1038.89 -4649.04 24.09 5976804.68 630761.46 N 702041.079 W 148 56 19.035 1 0741 .12 87.20 254.27 8691.75 4560.99 -1050.63 -4681.94 22.70 5976792.35 630728.78 N 70 20 40.963 W 148 56 19.995 10798.84 93.20 264.50 8691.54 4616.35 -1061.25 -4738.57 20.54 5976780.72 630672.36 N 702040.859 W 148 5621.650 10837.74 95.95 272.15 8688.44 4654.80 -1062.38 -4777.30 20.84 5976778.88 630633.66 N 70 20 40.847 W 148 56 22.781 10890.94 95.10 286.92 8683.29 4707.47 -1053.63 -4829.37 27.68 5976786.69 630581.44 N 70 20 40.933 W 148 56 24.303 10940.21 89.20 295.92 8681 .43 4754.73 -1035.67 -4875.13 21.82 5976803.82 630535.37 N 702041.109 W 148 5625.640 "-,,I 10984.85 88.38 306.22 8682.38 4794.92 -1012.67 -4913.31 23.14 5976826.12 630496.78 N 70 20 41.335 W 148 5626.756 11024.42 89.75 303.15 8683.03 4829.44 -990.16 -4945.84 8.49 5976848.04 630463.86 N 70 20 41.556 W 148 5627.707 11065.37 90.70 294.60 8682.86 4866.98 -970.40 -4981.66 21.01 5976867.15 630427.68 N 70 20 41.750 W 1485628.754 111 00.69 89.10 287.70 8682.93 4900.96 -957.67 -5014.58 20.05 5976879.29 630394.54 N 70 20 41.876 W 148 56 29.716 11148.94 83.13 277.92 8686.20 4948.62 -947.00 -5061.44 23.70 5976889.11 630347.50 N 70 20 41.980 W 148 56 31 .085 11201.49 75.43 271.00 8695.98 5000.17 -942.95 -5112.84 19.54 5976892.23 630296.04 N 70 20 42.020 W 1485632.587 11259.75 69.18 261 .27 8713.72 5054.85 -946.60 -5168.12 19.18 5976887.58 630240.84 N 70 20 41.983 W 148 56 34.202 11296.94 65.13 254.25 8728.17 5087.48 -953.83 -5201.59 20.52 5976879.75 630207.51 N 70 2041.912 W 148 5635.180 11 331 . 14 62.10 247.92 8743.38 5115.38 -963.73 -5230.55 18.80 5976869.32 630178.73 N 70 20 41.814 W 1485636.026 11378.00 62.10 247.92 8765.31 5152.10 -979.30 -5268.93 0.00 5976853.07 630140.65 N 70 20 41.661 W 148 5637.147 ~ R-14A ASP Final Surveys.xls Page 2 of 2 11/19/2002-10:28 AM ~) ) ó1oJ-) 5~ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No R-14A Date Dispatched: 13-Nov-02 Installation/Rig Nordic 2 Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys Field Copy ASP (Alaska State Plane) 2 2 1 on floppy on floppy RECEI' 'ED NOV 21 2)02 Alaska Q~ & Gas Cons. ~mmiIIion Anchorage Received~~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1 Dec '97 ~} " ) ~~fÆ~! ffi)~ !Æ[fÆ~æ!Æ AI/ASIiA. OIL AlVD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ¡TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT. Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AI( 99519 Re: Prudhoe Bay Unit R-14A BP Exploration Alaska, Inc. Pennit No: 202-156 Surface Location: 1444' NSL, 1756' WEL, Sec. 32, TI2N, RI3E, UM Bottomhole Location: 423' NSL, 3143' WEL, Sec. 31, TI2N, RI3E, UM Dear Mr. Stagg: Enclosed is the approved application for pennit to redrill the above development well. The pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CiA ~- jrJd cam:<ðechsli TaylorO Chair BY ORDER OF THE COMMISSION DATED thisM day of July, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKAul AND ~:~~g:~':~~ON COMMI~l,oN PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work 0 Drill iii Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test iI Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) to. Field and Pool BP Exploration (Alaska) Inc. KBE = 53.5' Prudhoe Bay Field I Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279 4. Location of well at surface 7. Unit or Property Name 1444' NSL, 1756' EWL, SEC. 32"T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number /' 903' NSL, 2377' WEL, SEC. 31, T12N, R13E, UM R-14A At total depth 9. Approximate spud d~ 42'3' NSL, 3143' WEL, SEC. 31, T12N, R13E, UM 10/05/02 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well // 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028282, 423' MD No Close Approach / 2560 10900' MD I 8720' TVDss 16. To be completed for deviated wells I 0 17. Anticipated pressure {S~20 MC 25.035 (e) (2)} Kick Off Depth 9850' MD Maximum Hole Angle 97 "Maximum surface 2144 psig, At total depth (TV D) 8800' / 3200 psig 18. Casin~ Program Specifications Setting Depth Size Top Bottom Quantitv of Cement Hole Casina Weiaht Grade Couplinq Lenath MD TVD MD TVD (include staae data) 3-3/4" 3-3I16"x2-7/S" 6.2/6.16# L-80 TCIII ST-L 1425' 9475' 8253' 10900' 8720' 79 cu ft Class 'G' \ti4^ 1/t,/O'L. ~7(~~ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 /' 19. To be completed for Red rill , Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 10595 feet 9246 feet 10505 feet 9169 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 110' 20" x 30" 2697' 13-3/8" 9823' 9-5/8" 1 027' 7" 1042' 5" 8 cu yds Concrete 3535 cu ft Permafrost II 1362 cu ft 'G', 130 cu ft PF 'C' 110' 2697' 9823' 110' 2685' 8590' 310 cu ft Class 'G' 129 cu ft Class 'G' 9566' - 10593' 9504' - 10546' 8380' - 9244' 8330' - 9204' RECEI\/ED Perforation depth: measured 9984' - 10035', 10050' - 10086', 10098' - 10126', 10144' - 10154' true vertical 8725' - 8768', 8781' - 8811', 8821' - 8845', 8860' - 8869' JUL. 25 2002 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Divert~i.~~nm55IOfi II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 ~'~_50 Requirements Contact Engineer NamelNumber: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21.ls~;~:Y~~;m::a~~~:,an~co~:tO:~~i~:r . Dat~1:1~ Permit Number API NumberApproval.R~ l See cover letter 2. (j 2 - /. 5" G 50- 029-20909-01 '. {, 1) ,.)~ for other reauirements Conditions of Approval: Samples Required 0 Yes at No Mud Log ,Required 0 Yes 181 No Hydrogen Sulfide Measures 1:81 Yes 0 No Directional Survey Required BYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other:T.eS t- ßO lE fo 35 00 ~ / ' .,\ Ooglnal Stgned By by òrder of Approved By C1cnmy ()erJ\sii Taylor OCf"!'lis$fon,rr" ~ tre commission Form 10-401 Rev. 12-01-85 f\ i lJ ¡ '\~ L... Date' /1 \3/6~ Sub 11 it Ir Triplicate ) ) BP R-14a CTD Sidetrack Summarvof Operations: A CTD through tubing sidetrack is planned for R-14. The coil sidetrack, R-14a, will exit the 5"x 7" liner in the Sag River formation and will target Zone 4. / R-14 is a high water cut, low oil rate fracced Zone 4 producer, currently shut in due to high water production. Remedial options for R-14 are unattractive. The sidetrack will target bypassed oil in the 46P and 45P sands. The planned sidetrack completion is a 27/8" pre-drilled and solid x 3 3/16" solid liner. The solid liner will be cemented from a cementing collar at approx. 10,300'. /The production interval will be covered by pre-drilled liner. The cemented portion of the liner will isolate the sidetrack from water and corrosion holes in the parent well and from any conductive faults that may be crossed. There is some risk that the hydraulic frac in the parent well will be intersected and cause lost circulation. Two small faults (10'-15' throw) will be crossed in the polygon with some risk of losses. Phase 1: Prep work. Planned for between Sept. 15 to Sept. 30, 2002. 1. Dummy all GLM's and perform an MIT-IA. 2. Set a 5" cast iron bridge plug at approx. 9975' (8663'ss) to isolate existing Zone 4 perfs. 3. Set a flow through whipstock in the 5" liner a¡approx. 9890' (8591'ss). 4. Service coil will pump a minimum of 40 bbls cement to squeeze corrosion holes and to stabilize the 5" x 7" annulus for window milling. Phase 2: Mill window, Drill and Complete sidetrack: Planned for Oct. 5, 2002. Drilling coil will be used to mill the window in the 5" x 7" liner then drill9nd complete the directional hole as per attached plan. Maximum hole angle will be 97 degrees. ('" Mud Program: / . Phase 1 &2: Seawater and 8.6 ppg Flo-Pro . Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3 3/16" TC II x 2 7/8" ST-L solid and pre-drilled liner from TD to approx. 9475' MD (8253'ss). The Xi> between 33/16" x 2 7/8" will be at 9985' MD (8642'ss). The cementing collar will ~e at approx. 10,300' (8707'ss). Top of liner cement is planned to be at 9515' MD (8285'ss). A minimum of 14 bbls of 15.8 ppg latex cement will be used for liner cementing. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 97 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ) ) Logging . An MWD Gamma Ray/Resistivity will be run over all of the open hole section. Hazards . R-14 measured 120 ppm H2S on 7/5/00. The highest nearby well is R-12 at 100 ppm H2s ot 8/14/01. . Lost circulation risk to the parent well's frac and to two small faults is considered moderate. Reservoir Pressure Res. press. is estimated to beJ200 psi at 8800'ss (ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2144 psi. ) ) I SAFETY NOTES TREE = 7" OW WB..U-EAD = MCEVOY "R~""...,;....»....,,,,..,,,..,..........,, ,., .........", . . "" ,...,.,.",.,..", . ACfUATOR = AXELSON KB. ËLEV'= " '53.48' 'g'F."E[§];;ww.,"'"'"W'2'2:räi "KOP =W' .' 2200" 'MãXAngÎè-;""^"" 39@ 910()' ÖatÚmMÖ;",ww'1Ö13éï . ÒatUm TV b' ;"""8806'-8'8 R-14 2111' H5-1/2" 011S SSSV LAND NP, ID = 4.562" 1 8 GAS LIFT MANDRELS DEV TYPE VLV LATCH 25 OTIS RA 34 . OTIS RA 36 OTIS RA 31 OTIS RA 39 OTIS RA 38 OTIS RA ST ~ TVD 6 3079 2991 5 5338 4874 4 7053 6263 3 8410 7396 2 9221 8052 1 9329 8137 FORT DATE r-J ~ 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2697' l Minimum ID = 4.276" @ 9504' 5" LINER (TOP) ~ 9394' 1-1 TIW ANCI-OR LATCH 1 9395' H 9-5/8" x 5-1/2" HN I-f:3BP PKR, ID = 4.815" 1 ~ 9467 1-15-1/2" 011S X NIp, ID = 4.562" 1 9492' H 5-1/2" 011S XN NIP, ID = 4.455" . 9505' H5-1/2"TTPUPJT/Mll.ESHOE, ID =4.892" 1 9499' 1-1 ELMD TT LOGGED 10/26/91 1 :8: TOP OF 5" LNR H 9504' 1 5-1/2" TBG, 17#, 13CR, .0232 bpf, ID = 4.892" H 9505' I TOP OF T' LNR 1-1 9566' I'Ú",,'. ',ß: 'J ~ .. 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 9823' ÆRFORA 110N SU\t1MARY REF LOG: SWS-BI-CS ON 02/09/83 ANGLE A TTOPPffiF: 32 @ 9984' Note: Refer to Production œ for historical perf data SIZE SPF INTER\! AL OpnlSqz DA TE 2-7/8" 4 10098-10136 S 07/15/88 2-7/8" 4 10050-10086 S 07/15/88 3-1/8" 4 9984-10035 S 07/15/88 3-3/8" 1 10116-10126 0 01/09/89 3-3/8" 4 10024-10035 0 01/09/89 3-3/8" 4 10098-10116 0 01/09/89 3-3/8" 4 10050-10086 0 01/09/89 3-3/8" 10 9984-10024 0 01/09/89 3-3/8" 6 10144-10154 0 07/22198 J 1 FBTD H 15" LNR, 18#, Cr95, .0177 bpf, ID = 4.276" H 1 T' LNR, 26#, L-80, .0383 bpf, ID = 6.27ft H 10505' 1 10546' 1 a 10593' 1 DA TE RBI BY COMv1ENTS 05101102 /tlh MINIDCORRECTION FRUCHOE SA Y UNIT WB..L: R-14 PERrv11T No: 83-0220 API No: 50-029-20909-00 Sec.32,T12N,R13E BP Exploration (Alaska) DATE 02/13/83 10/15/91 03/14/01 03/14/01 09/23/01 COMv1ENTS ORIGINAL COrvPLEfION RNO CONVERTED TO CANVAS RNAL CORRECfIONS REV BY SIS-SL T SIS-MD RN'TP TREE = 7" CrN WELLHEAD = MCEVOY 'ÃcfUÁ TOR';" '" ÃXÊLšóÑ Ì<S:^ELEV ";;,,,,w"'"""""5'3:48; BfmELÎ3T;"n'''m,~wwwMwm22:'16~' , ,............w.w.''''''''''''''W''.w....,.'.,.....,...',~....."""...~'...''''''''.W,',','",'''''~w.w.w.'~'.''''''.w,,,,.w.''.'.',,,, KOP = 2200' ~~:~n9~~M~,:n^,:39.,~:,~f~~; Datum MD = 10136' ,wU,W""......-.w.w.....'''''''.W.WN,''''''''".w.-.-.''-'''W'''_W'''''''''''''',"oW.'W.W."'.','.w,",',',",'.",'.".''''''''''W Datum TVD = 8800' SS ') R-14A Proposed CTD Sidetrack . 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2697' ~ ~ L Minimum ID = 4.455" @ 9492' 5-1/2" OTIS XN NIPPLE ~ ~8~ 1 w II 8: ITOPOF 3-3/16 LNR I.., 9475' 15-1/2" TBG, 17#, 13CR, .0232 bpf, ID = 4.892" l-t 9499' 1 TOP OF 5" LNR l-i 9504' I TOP OF 7" LNR l-i 9566' 'I 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9823' 41 ~ ÆRFORA TION SUMMARY REF LOG: SWS-BHCS ON 02/09/83 ANGLE AT TOP PERF: 32 @ 9984' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10098-10136 isolated proposed 2-7/8" 4 10050-10086 isolated proposed 3-1/8" 4 9984-10035 isolated proposed 3-3/8" 1 10116-10126 isolated proposed 3-3/8" 4 10024-10035 isolated proposed 3-3/8" 4 10098-10116 isolated proposed 3-3/8" 4 10050-10086 isolated proposed 3-3/8" 10 9984-10024 isolated proposed 3-3/8" 6 10144-10154 isolated proposed SAFEl')TES 2111' 1-i5-1/2" OTIS SSSV LAND NIP, ID = 4.562" 1 ST MD TVD 6 3079 2991 5 5338 4874 4 7053 6263 3 8410 7396 2 9221 8052 1 9329 8137 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 25 OTIS RA 34 OTIS RA 36 OTIS RA 31 . OTIS RA 39 OTIS RA 38 OTIS RA PORT DATE 9394' 1-1 TrN ANCHOR LA TCH I 9395' 1-i9-5/8" x 5-1/2" TrN HBBP PKR, ID = 4.815" I 9467' 1-i5-1/2" OTIS X NIP, ID = 4.562" 1 9492' - 5-1/2" OTIS XN NIP, ID = 4.455" I 9505' - 5-1/2" TT PUP JT/MULE SHOE, ID = 4.892" I 9499' - ELMD TT LOGGED 10/26/91 I 9515' l-i Top of cement I 9985' l-i 3-3/16" x 2-7/8" X-over 1 10300' l-i Bottom of cemented liner 1 \ ù I 0 o~ 3-3/16" x 2-7/8" Cemented/pre-drilled 1-1 10900' I ~ 9890' H 5" Mechanical Whipstock j I 9975' H 5" Bridge Rug I 1 PBTD I.., 10505' I 15" LNR, 18#, C-95, .0177 bpf, ID = 4.276" l-i 10546' I Jl 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 10593' I DATE 02/13/83 10/15/91 03/14/01 03/14/01 09/23/01 DA TE REV BY COMMENTS REV BY COMMENTS ORIGINAL COMPLETION RWO SIS-SL T CONVERTED TO CANVAS SIS-MD FINAL RN/TP CORRECTIONS PRUDHOE BA Y UNrr WELL: R-14 PERMrr No: 83-0220 API No: 50-029-20909-00 Sec. 32,T12N, R13E BP Exploration (Alaska) BP Amoco Pa_tW~1 Tte ... MDt l1li1 Ref. 0.1- W8LLPATH DllTAlLS p,..n .101... '001'_"1 11-1. ....... No_1 18 11.11H118es - 8~- v.aoo.,:.: 0.-= = -.... 0... 0.00 :::..~ 0.00 REFERENCE INFORMATION Co-ordinate (NIE¡ Reference: We" Centre: R-14, True North Vr~~~j ~:=~~~: ~~~~~ ~~38J.~~)el Measured Depth Reference: 18: 141~9I1983 00:00 53.50 Calculation Method: Minimum Curvature 811CT1ON D81'A'" tV. +N,.. ..,.. ....... -au... "".M "'1.03 "'..7 ooIOn.:so .en.n "''''''1t .eoaAO ""'.84 ..71tM .31." "'.'1. -4Q0&.7a ..u.t.01 ......... ......., ...-.a.u .tOt..'. ....:11 DL.. Tf'ace 0.00 0.00 0.. .....» "00 118.00 40.00 311.00 12.00 ...00 1.... 171.00 '12.00 0.00 11.00 ...00 12.00 tu.oø 11.00 121.00 VS8c Tar- a....oJ ,....... :=:1 =~i U7L81 -.01 --... 8M MD tno All t ""00 11..87 1YG.20 I .....00 13.87 870."1 : == === mfl . ......... 78.1' "'''.U . 1011.... 77."""" ...~ , 1017&18 87.00 818." .,...1. . ..oaa... ..... U7.71 .....n . tOlM.7. 80.00 "".7" ..,..,... 1010100.00 'ioU 81.... 87tan ANNOTATIONS TYD MD -..- 1117"~ .-... np "".1' '_.80 KOP ..7..71 "78'" 1 -... .-... 1 H"'" 1_'" ~ H...a1 1.11'''' . .7...11 1017'''' . ''''.n 111..... . "78.1' 1_.78 7 '71'.71 1'_.80 TO TARGETDETAlL$ TW ~/..s +£l.W Sh8pe 86Ji !U i~iI §F 8710-00 -618.56 -4302.26 Point 8720.00 .100429 ..4884.82 Point ~:~~~~_1 ~¡~ifi62 _8200 C ~ 8250-:: i8300 .c i 8350 -..: a 8400 .. ß 8450 - ¡ 8500 > . 8550 i! ... 8600 - 8650 8750 - Obi> .,~ 'fIII,8 :,' i INTEQ I i I Direct: (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 T AM é Plan: Plan #7 (R-14/Plan#7 R-14A) Created By: Bnj Potnis Date: 5/17/2002 LEGEND - ~:H ~11lÁ) - R-14 (R-14) - R-29A. (R-29A.) ---- Plan#7 R-14A. - Plan #7 Azimuths to True North Magnetic North: 26.26' Magnetic Field Strength: 57498nT Dip Angle: 80.81' Date: 5/17/2002 Model: BGGM2oo1 Contact Information: - C ~ 0 ... - - + - .c 1:: 0 Z :::=.. . - .c .. :I 0 . 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 Vertical Section at 249.00° [50ft/in] 5/17/2002 3:29 PM '-" '~ ) ) BP Baker Hughes INTEQ Planning Report IN'TEQ -------- Company: BP Amoco' Field: Prudhoe Bay Site: PB R Pad Well: 'R-14 , WeUpath: . =)JaIi#7R.14A l_"____c....~_..' ,', ',' ~--,~~~--- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level I -- J>ate:5/17/2002 ' Time: '15:30:19 ' C~rdinate(NE)R~fetenee: . Well:R-14~TruØNorth Vertical (TV))) R~fø'e~ee~ Systêm: Mea...' Sea Level, S~tjon,(VS)Referenc~' Well(0~OON.O.00E 249.00Azi) _._--~_~~urvèyCalClÍlat,iC)~MetbØ4:, ' Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre BGGM2001 PB R Pad TR-12-13 UNITED STATES: North Slope Site Position: Northing: 5975706.22 ft Latitude: From: Map Easting: 637446.42 ft Longitude: Position Uncertainty: 0.00 ft North Reference: Ground Level: 0.00 ft Grid Convergence: -------'---"---"'---"'--"----"-------""'-'-'-'-------.-..- Site: Well: R-14 R-14 Well Position: Slot Name: 70 20 29.100 N 148 53 4.328 W True 1.05 deg 14 70 20 51.310 N 148 54 3.205 W ---.----. +N/-S 2258.56 ft Northing: 5977927.29 ft Latitude: +E/-W -2014.92 ft Easting: 635390.59 ft Longitude: Position Uncertainty: 0.00 ft --.---..----.--.---.-.-..--.-....-------.."..-......----'-""'--"--"'"'-----.'--.--'---,----"--------------"------- -.---.,-.-..--.--- ----- Wellpath: Plan#7 R-14A 500292090901 Current Datum: 18: 141/29/198300:00 Magnetic Data: 5/17/2002 Field Strength: 57498 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft ------- 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 R-14 9800.00 ft Mean Sea Level 26.26 deg 80.81 deg Direction deg 249.00 Height 53.50 ft --------- Targets Map, .M~p <~ Latitude --> ~'Longitude ',-,.> Name Description TVD +N/;;.S +EI-W Northing Easting DegMinSec Deg,Min,.,Sec --_.----,----_._-,--_____--Dip~____J?ir. ft ft ft ft ft "----..-------- R-14A Polygon5.1 0.00 -617.78 -4072.92 5977236.09 631329.82 70 20 45.224 N 148 56 2.209 W -Polygon 1 0.00 -617.78 -4072.92 5977236.09 631329.82 70 2045.224 N 148 56 2.209 W -Polygon 2 0.00 -722.84 -4234.89 5977128.13 631169.78 70 20 44.190 N 148 56 6.940 W -Polygon 3 0.00 -988.86 -4400.80 5976859.18 631008.72 70 20 41.572 N 148 56 11.783 W -Polygon 4 0.00 -1090.27 -4652.72 5976753.24 630758.69 70 20 40.574 N 148 56 19.142 W .Polygon 5 0.00 -1069.55 -4964.42 5976768.32 630446.69 70 20 40.775 N 148 56 28.249 W -Polygon 6 0.00 -1012.28 -5196.43 5976821.39 630213.71 70 2041.337 N 148 56 35.028 W -Polygon 7 0.00 -850.08 -5150.44 5976984.38 630256.75 70 20 42.933 N 148 56 33.688 W -Polygon 8 0.00 -928.64 -4793.80 5976912.28 630614.73 70 20 42.162 N 148 5623.266 W .Polygon 9 0.00 -883.85 -4617.93 5976960.24 630789.75 70 2042.604 N 148 56 18.129 W -Polygon 10 0.00 -531.39 -4311.40 5977318.15 631089.83 70 20 46.072 N 148 56 9.179 W -Polygon 11 0.00 -463.02 -4112.09 5977390.10 631287.86 70 2046.746 N 148 56 3.356 W R-14A Fault 5.1 0.00 -646.72 -4403.53 5977201.18 630999.81 70 20 44.937 N 148 56 11.869 W -Polygon 1 0.00 -646.72 -4403.53 5977201.18 630999.81 70 20 44.937 N 148 56 11.869 W I -Polygon 2 0.00 -720.01 -4224.83 5977131.13 631179.79 70 20 44.217 N 148 56 6.646 W R-14A Fault 5.2 0.00 -892.12 -4658.09 5976951.24 630749.74 70 20 42.522 N 148 56 19.302 W -Polygon 1 0.00 -892.12 -4658.09 5976951.24 630749.74 70 2042.522 N 148 56 19.302 W -Polygon 2 0.00 -996.51 -4419.94 5976851.18 630989.72 70 2041.497 N 148 56 12.342 W R-14A T5.1 8670.00 -550.95 -4171.72 5977301.12 631229.83 70 20 45.880 N 148 56 5.097 W R-14A T5.2 8710.00 -578.56 -4302.26 5977271.15 631099.83 70 2045.608 N 148 56 8.911 W R.14A T5.3 8720.00 -1004.29 -4884.92 5976835.00 630525.00 70 2041.418 N 148 5625.927 W _._-~_._------ bp Company:BP AmOco Fi~Id; 'PrudhoeBé:1Y Sj~: PBRPad W~lí: R-14 w~npatb: PIan#7R.14A Annotation MD TV» ft ft _._-~---------'-- 9800.00 8517.63 9850.00 8559.19 9870.00 8575.71 9990.86 8643.95 10040.86 8655.98 10215.86 8696.31 10378.58 8704.12 10528.58 8685.73 110636.76 8679.15 10900.00 8719.72 ") BP Baker Hughes INTEQ Planning Report ---'---'-----~-- ..8 .--.. INTEQ Date: ,: 5/17/2002 Time: "'15:30:19 . Page: Co.oordtnät~)Rëference: ' Wèli:R.;t4;Xrue Nòrth Ve~I(T~)Referenee: $Y~Etrn:MeaoSEta. LEtvel SeCtion(VS)Referenè~: '., " "VVf}IIW~OON.0;(~0§.249;OOAzi) SUrvey CalÇùlaÍioùi\leðlod: ' Minimum Curvature Db:Oraclè 2 TIP KOP 1 2 3 4 5 6 7 TD Plan: -'-'-------------'--------'-------- Plan #7 Well was shortened Principal: Yes Plan Section Information .-..----.-....--."---.--..,-.----...--...-..-.-- --~-~ Incl Azim TVD +N/.;S deg deg ft . ft -'---''''_._-----'._-----------'---'-_._------'--_._;--~--...;..._--~ 9800.00 33.87 270.20 8517.63 -540.46 9850.00 33.67 270.16 8559.19 -540.38 9870.00 34.96 267.94 8575.71 -540.57 9990.86 76.00 234.95 8643.95 -577.72 10040.86 76.18 241.13 8655.98 -603.40 10215.86 77.47 219.59 8696.31 -711.46 10378.58 97.00 219.59 8704.12 -836.10 10528.58 96.96 237.73 8685.73 -934.02 10636.76 90.00 248.71 8679.15 -982.53 10900.00 72.52 275.45 8719.72 -1019.35 Survey """""-""'-''''''-''''-'---'- MD ft 9800.00 9825.00 9850.00 9870.00 9875.00 Incl deg 33.87 33.77 33.67 34.96 36.40 Azim deg 270.20 270.18 270.16 267.94 265.56 SSTVD N/S ft ft ~------~-- 8517.63 -540.46 8538.40 -540.42 8559.19 -540.38 8575.71 -540.57 8579.77 -540.73 9900.00 44.16 255.76 8598.85 9925.00 52.55 248.45 8615.46 9950.00 61.30 242.65 8629.10 9975.00 70.25 237.76 8639.35 9990.86 76.00 234.95 8643.95 10000.00 76.02 236.08 8646.16 10025.00 76.11 239.17 8652.18 10040.86 76.18 241.13 8655.98 10050.00 76.20 240.00 8658.16 10075.00 76.29 236.91 8664.11 10099.96 76.41 233.83 8670.00 10100.00 76.41 233.83 8670.01 10125.00 76.58 230.75 8675.85 10150.00 76.78 227.67 8681.61 10175.00 77.01 224.60 8687.28 10200.00 77.28 221.53 8692.84 10215.86 77.47 219.59 8696.31 10225.00 78.57 219.59 8698.21 10250.00 81.57 219.59 8702.52 10275.00 84.57 219.59 8705.53 --_._----- +E/-W ft -4033.24 -4061.03 -4072.30 -4160.19 -4201.34 -4331.65 -4434.73 -4546.04 -4642.25 -4896.32 E/W ft -4033.24 -4047.15 -4061.03 -4072.30 -4075.21 Date Composed: Version: Tied-to: DLS' Bund Turn deg/10Oft deg/10Oftdeg!100ft. 0.00 0.00 0.00 0.40 -0.40 -0.08 9.00 6.47 -11.11 40.00 33.95 -27.30 12.00 0.37 12.36 12.00 0.74 -12.31 12.00 12.00 0.00 12.00 -0.02 12.09 12.00 -6.44 10.15 12.00 -6.64 10.16 MapN Mäp~ ft ft -----.-- 5977314.10 631368.09 5977313.90 631354.18 5977313.69 631340.31 5977313.29 631329.04 5977313.07 631326.13 5/17/2002 1 From: Definitive Path TFO deg 0.00 186.33 315.00 315.00 89.00 271.00 0.00 89.00 122.00 125.00 VS ft 3959.03 3972.01 3984.95 3995.54 3998.32 -543.46 -4091.09 5977310.06 631310.31 4014.12 -549.26 -4108.80 5977303.94 631292.70 4032.74 -557.97 -4127.82 5977294.90 631273.85 4053.61 -569.31 -4147.56 5977283.20 631254.32 4076.10 -577.72 -4160.19 5977274.56 631241.85 4090.91 Target ------.- DLS deg/100ft 0.00 0.40 0.40 9.00 )0.00 40.00 40.00 40.00 40.00 40.00 TFO deg ------- 0.00 TIP 186.33 MWD 186.34 KOP 315.00 1 315.00 MWD Tool 316.94 MWD 324.44 MWD 329.31 MWD 332.49 MWD 334.50 2 -582.74 -4167.50 5977269.41 631234.63 4099.53 12.00 89.00 MWD -595.73 -4187.98 5977256.05 631214.38 4123.31 12.00 88.73 MWD -603.40 -4201.34 5977248.15 631201.17 4138.53 12.00 87.98 3 -607.76 -4209.07 5977243.65 631193.52 4147.31 12.00 271.00 MWD -620.46 -4229.76 5977230.57 631173.06 4171.17 12.00 271.27 MWD -634.24 -4249.72 5977216.43 631153.36 4194.75 12.00 272.00 R-14A -634.27 -4249.75 5977216.41 631153.33 4194.78 12.00 272.73 MWD -649.13 -4268.97 5977201.20 631134.38 4218.06 12.00 272.73 MWD -665.03 -4287.39 5977184.98 631116.25 4240.95 12.00 273.45 MWD -681.90 -4304.94 5977167.80 631099.01 4263.38 12.00 274.16 MWD -699.70 -4321.58 5977149.69 631082.69 4285.29 12.00 274.86 MWD -711.46 -4331.65 5977137.76 631072.84 4298.91 12.00 275.54 4 -718.35 -4337.34 5977130.77 631067.27 4306.69 12.00 360.00 MWD -737.32 -4353.04 5977111.52 631051.93 4328.14 12.00 0.00 MWD -756.44 -4368.85 5977092.11 631036.46 4349.76 12.00 0.00 MWD ) ) ... .~ IN'TEQ BP Baker Hughes INTEQ Planning Report çQmpany: BP AmoCo Field:' , PfudhOêBay Site: PB,R Pad, Well: R~1,4 _~~!l~at~~lan#7,R~14A Survey MD ft 10300.00 10325.00 10350.00 10375.00 10378.58 loCi A:iinl deg deg -----_.:.....-.~--- 87.57 219.59 90.57 219.59 93.57 219.59 96.57 219.59 97.00 219.59 SSTVD ft 8707.25 8707.65 8706.75 8704.54 8704.12 10400.00 97.04 222.18 8701.50 10425.00 97.06 225.20 8698.43 10450.00 97.07 228.23 8695.35 10475.00 97.06 231.25 8692.28 10500.00 97.03 234.27 8689.21 10525.00 96.97 237.30 8686.17 10528.58 96.96 237.73 8685.73 10550.00 95.60 239.92 8683.39 10575.00 93.99 242.46 8681.30 10600.00 92.38 244.99 8679.91 --"------'-'-- Date: 5/17/2002 Tuoe:>'15:30:19 Çó..ordil1ât~)~ëferen~: ' ",: wen: R~14,True~orth 'Vert~aI(TV;Q1Refere~: Sys~em: MeanS~aLevel Sêetion(vSl,Refer~Dœ:.' ", WelJ,{O.QOtc.J,0.OO~,249.00Azj)" ~~rvey CalcDlationMeth~: 'Minimum Curvature Db:, Oracle Page: 3 N/S ft -775.66 -794.92 -814.17 -833.36 -836.10 EiW ff -4384.75 4400.67 4416.60 -4432.46 4434.73 MapN ft 5977072.61 5977053.07 5977033.54 5977014.07 5977011.28 ,MapE' ft, 631020.92 631005.34 630989.77 630974.25 630972.03 VS ft 4371.48 4393.26 4415.02 4436.71 4439.81 DLS ' TFO ctegl100ft ' dég 12.00 360.00 MWD 12.00 0.00 MWD 12.00 360.00 MWD 12.00 0.00 MWD 12.00 0.00 5 -852.17 -4448.65 5976994.97 630958.42 4458.56 12.00 -870.11 4465.78 5976976.73 630941.61 4480.99 12.00 -887.11 4483.84 5976959.40 630923.86 4503.94 12.00 -903.15 -4502.77 5976943.03 630905.22 4527.36 12.00 -918.16 -4522.52 5976927.66 630885.75 4551.18 12.00 89.00 MWD 89.32 MWD 89.69 MWD 90.06 MWD 90.43 MWD -932.11 -4543.04 5976913.34 630865.49 4575.33 12.00 90.80 MWD -934.02 -4546.04 5976911.38 630862.52 4578.82 12.00 91.17 6 -945.04 -4564.25 5976900.03 630844.52 4599.77 12.00 122.00 MWD -957.04 -4586.08 5976887.64 630822.91 4624.45 12.00 122.24 MWD -968.09 -4608.46 5976876.19 630800.74 4649.30 12.00 122.45 MWD 10625.00 90.76 247.52 8679.22 -978.15 -4631.33 5976865.72 630778.05 4674.26 12.00 122.59 MWD 10636.76 90.00 248.71 8679.15 -982.53 -4642.25 5976861.14 630767.22 4686.02 12.00 122.66 7 10650.00 89.09 250.01 8679.25 -987.20 -4654.63 5976856.25 630754.92 4699.26 12.00 125.00 MWD 10675.00 87.37 252.47 8680.02 -995.24 -4678.29 5976847.79 630731.41 4724.22 12.00 124.99 MWD 10700.00 85.66 254.94 8681.54 -1002.24 -4702.24 5976840.36 630707.59 4749.09 12.00 124.91 MWD 10725.00 83.95 257.42 8683.81 -1008.19 -4726.41 5976833.97 630683.53 4773.79 12.00 124.76 MWD 10750.00 82.26 259.91 8686.81 -1013.06 -4750.74 5976828.66 630659.30 4798.25 12.00 124.54 MWD 10775.00 80.58 262.42 8690.54 -1016.86 -4775.17 5976824.42 630634.95 4822.41 12.00 124.24 MWD 10800.00 78.91 264.96 8695.00 -1019.56 -4799.62 5976821.27 630610.55 4846.21 12.00 123.86 MWD 10825.00 77.27 267.53 8700.15 -1021.17 -4824.02 5976819.23 630586.18 4869.57 12.00 123.41 MWD 10850.00 75.66 270.13 8706.01 -1021.67 -4848.32 5976818.29 630561.90 4892.43 12.00 122.88 MWD 10865.59 74.66 271.77 8710.00 -1021.42 -4863.39 5976818.27 630546.83 4906.41 12.00 122.27 R-14A T5 10875.00 74.07 272.77 8712.53 -1021.06 -4872.44 5976818.46 630537.77 4914.73 12.00 121.85 MWD 10900.00 72.52 275.45 8719.72 -1019.35 -4896.32 5976819.74 630513.87 4936.41 12.00 121.58 TD ) . " " ) All Measurements are from top of Riser s- a> en æ top of bag bttm of bag middle of slips Blind/Shears middle of pipes 2 3/8" combi ram/slips ~ middle of flow cross Mud Cross .....-- middle of blind/shears variable bore pipe 31/2".2 7/S" middle of pipe/slips I 2 3/8" combi ram/slips Flow Tee "'............... ../......../ '--' '---' -""""'............... / ) 7/23/2002 BAG ~' TOTs Mud Cross /' TOTs H 206982 DATE 7/01/02 DESCRIPTION GROSS CK062602 INVOICE I CREDIT MEMO PERMIT TO DRIL~ FEE ALASKA ST1\TE ALASKA OIL 333W 7TH ANCHORAG:¡:!:, R~ IY/f THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP.EXRLORATION,.(ALASKA)INC.. P.O. BOX 196612 ANCHORAGE,ALASKA99519-6612 PAY TO THE ORDER OF DATE JULY 1, 2002 III 20 b qa 2111 ':0... ~ 20 j8 q 5': 008... ~ ~ qlll DATE 7/01/02 CHECK NO. H206982 VENDOR DISCOUNT NET H RE(: JUl 25 2002 !.\taska au & G3s Gon& A1choraaÐ *****$100.00***** r..::........~O,!: VAlin AFP= ::~::'<"[Jl:~o.;¡~~~...,....., .'. i~~m~~~:¡;~~~¡t¿. 'f F '~ .~/ ') ) TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME j?ß/~ 1{-/7'/1 PTD# 202-- /---S ¿::; CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be' reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be 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. . WELL PERMIT CHECKLIST COMPANY (1 f )t WELL NAME ¡:>ß( -1 1(-j'lA PROGRAM: Exp - Dev.k Redrll ~ Re-Enter - Serv _Wellbore seg- ,FIELD & POOL ¡.:::; 71 ð I_)~ INIT CLASS /J'P.././ J-rJ/ J GEOL AREA'? i ò UNIT# / I ~ ç /) ON/OFF SHORE ...Q!t) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 'Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . ,Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N '7£ - ./ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~~::z... 9. Operator only affected party.. . . . . . . . . . . . . . . . . . !Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N , (Service Well Only) 13. Well located wlin area & strata authorized by injection order#- Y~ /£./,A. . (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y t~ 16. Surface casing protects all known USDWs. . . . . . . . . . . Y N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥-'M-lJ/1r- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~" . 19. CMTWill, coverall known productive horizons. . . . . . . . . . NAde?c-.7u.tVb Uc.açç: 20. Casing designs adequate for C, T. B & permafrost. . . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N C1 Du ' 22. If a re-drill, has a 10-403 for abandonment been approved. .. .J/.:g¿, N 7/2.,(,1, ¡tJL. 23. Adequate wellbore separation proposed.. . . . . . . . . . .. (f N 24. If diverter required, do, es it meet regulations. . . . . . . . . . ~Y, N N" fA- 25. Drilling fluid program schematic & equip list adequate. . . . . N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . , N ¡f,.J' 27. BOPE press rating appropriate; testto "3~ 00 psig. N M Ç{J -¿ {r.r'f- t!. ¿. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ' N 29. Work will occur without operation shutdown. . . . . . . . . . . fi2.. N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ~N 120 ppJ1.Á. 31. Mechanical condition of wells within AOR verified. . . . . . . . ~^'-/A!- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Y <1Þ 33. Data presented on potential overpressure zones. . . . . . .. )fN 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y N Ñ. A . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . Y N APPR DATE APPR DATE ífJ~1t- 712f1!pL. (Service Well Only) .GEOLOGY APPR DATE /?fJt"1 ~ ¿:z.. .. (É~ploratory Only) Rev: 07/12/02 GEOLOGY: RPC~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING .~ JDH Q ~ UIC ENGINEER JBR SFD WGA \tJ4Â- MJW G: \geology\perm its\checklistdoc COMMISSIONER: COT DTS D7/j¡laZ Commentsllnstructions:
