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Home My WebLink About205-191• 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. ~(,~~- ~ ~ ~, Well History File Identifier Organizing (done) ^ Two-sided III II'III II III II III ^ Rescan Needed R CAN DI ITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ g !sl Project Proofing III IIIIII VIII II III BY: Maria Date: ~ S ~ ~ /s/ Scanning Preparation ~,_ x 30 = ~ + ~ =TOTAL PAGES ~ `~ (Count does not include cover sheet) BY: ~, Maria Dater ~ 5' O ~ /s! ~/ Production Scanning Stage 7 Page Count from Scanned File: ~ W (Count does include cove sheet) Page Count Matches Number in Scan ing Preparation: YES NO BY: Maria Date: ~ ~ O$ /s/ ~Y ~/f, Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO r BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: a~,~~,~~~~~ iuimiiuuuuii 10/6/2005 Well History File Cover Page.doc • i -~ -~ 4~, i :& ;. e ads' b ` ~ ~ ~ .~> j~'~.` x MICROFILMED 6/30/2010- DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Fites\OLK9\Microfilm_Marker.doc b r~1' DATA SUBMITTAL COMPLIANCE REPORT Zi2si2oos Permit to Drill 2051910 Well Name/No. PRUDHOE BAY UN UGN S-400 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23289-00-00 MD 4748 TVD 3948 Completion Date 1/28/2006 Completion Status WTRSP Current Status P&A IC Y REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, NEU, DEN, RES, CAL, GYRO, USIT Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D Asc Directional Survey r~t Directional Survey ~~ Cement Evaluation ~I"_Lo~g C~ment Evaluation ~,~ED C Lis 14053/Cement Evaluation C Lis 15292 Induction/Resistivity 15292 Induction/Resistivity og 15292 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORON Well Cored? Chips Received? ~~PI~ Analysis Received? Daily History Received? ~ N Formation Tops ~ N Log Log Run Scale Media No 5 Col 1 Col 1 1 25 Blu 25 Blu Directional Survey es (data taken from Logs Portion of Master Well Data Maint Interval OH / Start_ Stop CH Received Comments 0 4748 Open 2/14/2006 0 4748 Open 2/14/2006 0 4680 Case 3/3/2006 Cement Bod, Ultra Sonic Cement Bond 23-Jan-2006 0 4680 Case 3/3/2006 CEUCBL/UCL 26-Jan-2006 0 4680 Case 8/23/2006 CBL, USIT 27-Han-2006 "CORRECTED*" 103 4740 Open 7/25/2007 LIS Veri, GR, ROP, FET, DRHO, NPHI w/Graphics PDS and TIF 100 4748 Open 7/25/2007 MD Vision Service 100 4748 Open 7/25/2007 TVD Vision Service Sample Set Number Comme nts Interval Start Stop Sent Received Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051910 Well Name/No. PRUDHOE BAY UN UGN S-400 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23289-00-00 MD 4748 TVD 3948 Completion Date 1/28/2006 Completion Status WTRSP Current Status P&A UIC Y Compliance Reviewed By: - __ Date: STATE OF ALASKA ~~''~~~ ~~~~~~~=~ ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~r ~ ~ 2007 Alask>~ Oil ~ Gas Cons,. Cammiss+an 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 20AAC 25.105 2oMC 2s.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Clas nchOra~e ^ Development Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 9/11/2007 .p~' 12. Permit to Drill Number 205-191 Q - 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded 1/11/2006 13. API Number 50-029-23289-00-00 4a. Location of Well (Governmental Section): Surface: 4122' FSL 4504' FEL SEC T12N 35 R E M 7. Date T.D. Reached 1!19/2006 14. Well Name and Number: PBU S-400 , , , . , 12 , U Top of Productive Horizon: 2844' FSL, 966' FEL, SEC. 34, T12N, R12E, UM 8. KB (ft above MSL}: 64.60' Ground (ft MSL): 35.9' 15. Field /Pool(s): Prudhoe Bay Field / Ugnu Total Depth: 2722' FSL, 1113' FEL, SEC. 34, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) 4748 3948 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 618930 y- 5980325 Zone- ASP4 10. Total Depth (MD+TVD) 4748 3948 16. Property Designation: ADL 028258 TPI: x- 617210 y- 5979021 Zone- ASP4 Total Depth: x- 617065 y- 5978897 Zone- ASP4 11. SSSV Depth (MD+TVD} N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No bmi le r ni an rinted inf rm tin r 20 AAC 2 .0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD , GR , NEU ,DEN , RES ,CAL ,GYRO , USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT• PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED " 1 1. X- rf 1 rf 1 r' 13- / " x - / " x 47# L-8 rfa 22 ' rfa 771' 1 7 1 x Arc i e Li a 648 x'G' 7" 29# L-8 039' 470 ' 64 ' 91 -1/2" n m n d Ex ndabl r n 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each interval open (MD+TVD of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD N/A MD ND MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE,-ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 3099' Set Cement Retainer (08/30/07) -3066' P&A w/ 61 Bbls of Class 'G' Cement (08/31/07) 3005' Set CIBP (09/11/07) 2985' Set Whipstock 26• PRODUCTION TEST Date First Production: Not On Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: FIOW TUbing PreSS. Casing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF. WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? Yes ®No Sidewal l Cores Ac wired? Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results pe ,• ~. 25 A None ~ D ~~.. r r~ ,~ ~ 1 DQT ORIGINAL ~~~~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 2087' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. None Top of Ugnu (UG4) 4371' 3623' Ugnu 4A 4428' 3671' ~~.~v Q c ~ ~ ~ 2007 Alaska Gib & Gas Cobs. C~mmissor>t Ar-chotaga Formation at Total Depth (Name): Ugnu 4A 4428' 3671' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / s.t` ~ f ~ ~ Si d r gne / t Terrie Hubbl Title Drilling Technologist Date / 7 PBU S-400 205-191 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. / A r val No. ~N$TRUCTION$ GENeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22; Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Irer~ 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E ` Form 10-407 Revised 02/2007 ~ ~ ! G ~ (~! A L Submit Original Only ! • Well History - S-400 Date Summary 3/30/2007 *** (RWO Prep/ pre EL logging) *** MADE COUPLE ATTEMPTS TO PULL 7" BAKER WRP. SHUCKED 4 OF 8 COLLETS ON TOOL. REDRESSED & RERAN BAKER PULLING TOOL. TOOLS HUNG UP IN TT COMING OOH... TOOLS CAME FREE BUT RETAINER PIN CAME OUT OF GR... RETAINER PIN & GS LEFT IN HOLE. RAN 3.80 SUPER MAGNET TO LINER TOP @ 3015' SLM... RECOVERED -1/2 CUP METAL SHAVINGS & 2" X 3/8" PIECE OF SHEAR STOCK. RERAN SAME TO LINER TOP AGAIN ...RECOVERED -1/4 CUP METAL SHAVINGS. RIH W/ MAGNET '`** JOB IN PROGRESS/ CONT ON 03-31-07 WSR *** 3/31/2007 *** CONT FROM 03-30-07 WSR *'* (rwo prep/ pre EL logging) MADE SEVERAL ATTEMPTS TO FISH RETAINER PIN FROM TOP OF LINER @ 3015' SLM W/ 3.80 SUPER MAGNET. PICKED UP GS W/SUPER MAGNET BUT DROPPED IT COMING THRU TT. RAN BAITED TAPERED SLIP O-SHOT TO 3062' SLM & RECOVERED GS. MADE SEVERAL MORE ATTEMPTS W/ MAGNET TO 3064' SLM... STILL NO SIGN OF RETAINER PIN. TAGGED INSIDE OF BAITSUB W/ 3.25 LIB.. IMPRESSION OF BTM OF BAITSUB... NO SIGN OF RETAINER PIN. JARRING ON BAKER RBP PLUG, (3 HRS TOTAL BEATING TIME) *** JOB IN PROGRESS/ CONT ON 04-01-07 WSR *** 4/1/2007 *** CONT FROM 03-31-07 WSR *** (rwo prep/ pre EL logging) MADE SEVERAL MORE RUNS IN ATTEMPT TO SHUCK COLLETS ON BAKER PULLING TOOL. BAITED PULLING TOOL LEFT IN HOLE @ 3064' SLM (72" OAL W/ 5 1/2" G FN. MAX O.D 5.48"). JOB INCOMPLETE. RDMO ****** NOTE RETAINER PIN FROM 5 1/2" GR LEFT IN HOLE (.735" O.D X 3.75") ***** *** WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** 4/14/2007 '*** CTU 9 -Pull IBP **'* Complete rig up. Perform weekly BOP test on 7" BOP's. PJSM for making up Baker fishing string. Continued on 04/15/07 WSR. 4/15/2007 Continued from 04/16/07 WSR. MU/RIH w/ Baker fishing string #1 w/jars, accelerator, Hipp tripper, 5" GS. Tag plug @ 3081'. Run Hipp Tripper for 1 hr @ 0.5 bpm. Did not shift sleeve. PU 4 times, trying to strip bait. No jar action. Pump off. POOH. MU/RIH w/ Baker fishing string #2-1 w/jars, accelerator, wt bar, 5" GS. Latch and jar on WRP at 3081 -slipped off twice - POH no recovery -inspect tools- GS was in open position -redress GS and RIH with same BHA#2 -2 -Latch plug -jar 5 licks and slip off - re latch jar 29 licks lost weight whp dropped to 240 psi - IA inc to 250 - OA inc to 140. Recovered bait sub and XO. MU/RIH w/ BHA #5: accelerator, jars, Kipp tripper and 4" GS bait w/ Bowen overshot. Continued on 04/16/07 WSR. 4/16/2007 Continued from 04/15/07 WSR. RIH w/ BHA# 5. New 4"GS Bait sub w/ Bowen OS. Tag fish @ 3084', jar down, not latched. Hipp Tripp @ 1/2 BPM @ 3086' for 1 hour. No apparent latch. Final tag @ 3065'. POOH. Recovered remaining bait sub and entire model M wireline retrievable bridge plug. MU/RIH w/ 3.5" JSN for drift. Tag @ 3975'. Fluff to 3990' -Tag at 3994' -Fluff to 4010' -Tag at 4005' - Retag at 3985' solids continue to fall back. 853' of fill above TD at 4748' POH - RDMO *** Notify PCC/PO of well SI status **** Job Complete **** 5/11/2007 CTU #8, FCO/Set Bridge Plug; ... Cont' from WSR 05/10/07 ... Perfrom BOP test on 7-1/16" BOPs. Perform infectivity test to determine potential for FCO. 3.5 bpm at 65 psi. Decide to perform "fluff-n-stuff" clean out. RIH with 2.0"JSN. Tag fill at 3964' ctmd. "Fluff: n-Stuff' down to 4205 ctmd. POOH pumping to keep well over-ballanced to ensure no sand influx. MU and RIH with PDS gamma ray / ccl (SLB turned down job) and 5.95" OD drift. Tag 4185' ctmd. Log up at 45 fpm. Paint flags at 4050' ctmd and 3775' ctmd. POOH pumping to keep well over-ballanced to ensure no sand influx.Unable to work logging tools and drift through tail pipe.Lay in 10 bbls of Lube Tech @ end of tail pipe and let soak.Made several more attempt of work tools through 7" tail pipe with no success. RIH. to btm (top of fill) and disconnect tool string at 4136' ctmd. POOh ... Cont' on WSR 05/12/07 ... 5/12/2007 *** WELL SHUT IN ON ARRIVAL **** (Fish CTU Logging Tools) RAN 4.5" LIB TO 4092'SLM, POOH W/OUT PIC...SUSPECT FILL. RAN 3.50" x 10' PUMP BAILER, UNABLE TO PASS LINER TOP AT 3020' SLM. RAN 3.50" x 10' PUMP BAILER W/MULE SHOE, SAT DOWN AT 4043'SLM. TOP OF FILL HAD RISEN ~ 50' IN APPRX THREE HOURS BETWEEN RUNS. P. BAILER CONTAINS APPRX 3 GALLONS OF WHAT APPEARS TO BE FORMATION SAND. "**RDMO, UNABLE TO REACH FISH DUE TO FILL`** • • Well History - S-400 Date Summary CTU #8; Fishing Logging tools. Continue from WSR 05/11/07. MU and RIH With 3" 'GS' Spear. Made two unsuccessful attempt to latch to tool string left in hole @ 4138' ctmd. Rig down coil unit and let slickline try to retrieve logging tools with 7" drift on bottom of logging tools. 5/13/2007 CTU #8, Fish Toolstring /Set 7" BKR Plug; MIRU unit. MU and RIH with 2.0"JSN. Tag fish 4138' ctmd. Wash on top of fishing neck and up through top of perfs. POOH keeping well over-balanced. MU and RIH with jars and 3" GS spear with 5.85" OD bell guide. Tag and latch fish at 4143' ctmd. Observed slight overpull. POOH. Tag btm of 7" kill string. Hit a jar lick and work coil up and down attempting to get through. Had to run back to btm to reset jars. Repeat several times with no luck. RBIH and release fish at 4154' ctmd. POOH. Fishing attempt unsuccessful; follow plan discussed with pad engineer to set plug above fish. MU and R1H with SLB gamma ray/ccl. Log from 4130' to 3650' ctmd. POOH. MU and RIH with 7" WSRBP (5.97" OD) to flag. Correct depth to elmd (tied into CBL 01/27/06). ,RIH to set depth at 4095' elmd (middle of full joint) and set plug. POOH. ... Cont' on WSR 05/14/07 ... 5/14/2007 CTU #8, Set Plug; ... Cont' from WSR 05/13/07 ... POOH after plug set. RDMO. *** Job Complete *** 5/20/2007 CTU #5. Fish WSRBP . MIRU. BOP test of 7 1/16" BOP's. GC-2 shutdown. Standby while GC-2 in turmoil. RIH with 2.75" JSN for drift/tag. ***Job Continued on 5-21-07 WSR*** 5/21/2007 CTU #5. RIH with JSN for FCO. Tag @ 4084' ctmd. POOH while overdisplacing. MU Baker fishing string with 5.52" Retrieving Head. RIH. ***Job In Progress*** CTU #5. RIH with JSN for FCO. Tag @ 4084' ctmd. POOH while overdisplacing. MU Baker fishing string with 5.52" Retrieving Head. RIH. Tag up at top of 7" liner. Attempted to enter top of liner by pumping and running at diffrent speeds with no success. POOH and pickup hydraulic centralizer for tool string. RIH w/ BHA #3 adding Hydraulic Centralizer to BHA #2. Once fishing string exited 7" kill string, attempt to pull back through with fishing string with 4k over pull. Continnue RIH. At top of 7" liner, saw no weight change and did not require use of hydraulic centralizer. RIH and fish Baker 7" WSRBP recovering all elements. Perform infectivity test on wellbore at 5 bpm at 130 psi and 3 bpm @ 90 psi with 1 % KCI. Freeze protect wel(to 2200' with 84 bbls of 50/50 meth.. RDMO CTU. Notify pad operaror of well status. Final T/I/O = 96/200/204. *** Job Complete *** Note: InterACT not publishing. 6/12/2007 T/I/0= NA/200/150. PPPOT-T (PASS), PPPOT-IC (PASS). Pre rig. PPPOT-T: Stung into test port with high pressure bleeder tool (0 psi). Pressure void to 5000 psi for 30 min test, lost 120 psi in 15 min, lost 0 psi in second 15 min (PASS), bled to 0 psi. Functioned LDS, all moved freely, no sign of bent ro broken pins. 6/13/2007 T/I/O=NA/200/180. Temp SI. Bleed IA & OA for BPV (Pre Rig). Bled OAP from 180 psi to 120 psi to a bleed trailer in 1 hour. IA decreased 20 psi during OA bleed. "' bleed not completed due to reaching max volume for bleed trailer (50%) all liquid. *** No scaffolding in place. A ladder is not practical to reach the swab valve for TBGP reading. Monitored for 30 min. IAP & OAP unchanged. 6/15/2007 TIO= na/150/150. SI. Monitor WHP's (pre-BPV, RWO prep). In 2 days IAP decreased 30 psi, OAP increased 30 psi. 6/16/2007 T/I/O=na/150/150. Temp=Sl. Monitor (WHPs sample of IA FL). Took fluid sample from IA. 6/21/2007 T/I/0= 70/160/160. Temp= SI. Bleed WHP's to 0 psi (pre-BPV, RWO prep). No scaffolding on well. F/L and A/L line has been removed. IA FL @ surface. OA FL @ surface. Bled IAP to slop trailer from 160 psi to 155 psi in 45 minutes (slop trailer full). Bled IAP again from 160 psi to 155 psi in 45 minutes (slop full). Received a total of 26 bbls returns. Monitored for 30 minutes. IAP increased 5 psi. Final WHP's= 70/160/160. 8/26/2007 SET 6" CIW BPV FOR RIG TO MOVE ON 8/28/2007 PULL BPV 8/29/2007 T/I/O = 70/150/150. Temp = SI. T & IA FL Pre CTU (P&A). Flow line removed. TBG & IA FL @ surface. Spot equipment, MIRU, PJSM ***WSR Continued to OS-30-07*** • • Well History - S-400 Date Summary CTU #9 w/1.75" CT. Standby for E-line to set 7" cement retainer. *** Continued on 08/30/07 WSR *** 8/30/2007 *** WELL SHUT-IN ON ARRIVAL*** INITIAL T/I/O: 220/200/150 SET 7" HALLIBURTON CEMENT RETAINER. TOOL STRING LENGTH = 13.3' MAX OD = 5.5". SAT DOWN 10' BELOW SWAB ON RIH. BUMPED THROUGH BY HAND. SET 7" EZ DRILL SVB SQUEEZE PACKER WITH MID- ELEMENT AT 3099'. OVERALL LENGTH = 31.57". TOP TO MID-ELEMENT = 14". MID-ELMENT TO BOTTOM OF EZ DRILL = 16". PT T/I/O TO 2350 PSI WITH TRIPLEX -GOOD. FINAL T/I/0 = 100/100/100. *** JOB COMPLETE *** CTU #9 w/1.75" CT. *** Continued from 08/29/07 WSR *** Standby for E-Line to set cement retainer and VECO to rig up hardline and return tanks. *** Continued on 08/31/07 *** ***WSR Continued from OS-29-07*** T/I/0= 0/180/100 Temp= S/I (P&A) Load TBG & IA Pumped 250 bbls. 50* diesel down IA, RD IA & RU TBG, Pumped 195 bbls. 50* diesel down TBG, Final WHP's 24012801200. ***Annulus casing valves tagged & left open*** 8/31/2007 CTU #9 w/1.75" CT. Interact is not publishing. MIRU CTU. ***Notified AOGCC 24 hours in advance to witness stinging into the cement retainer and they declined to witness*** Perform BOP test on 7-1/16" Combis. MU BOT MHA with 5.76" OD HES stinger assembly and RIH to 2315' ctmd and back up through TT without any problem. RBIH and get up/dn weights at 3000'. RIH and sting into retainer. Set down 4k, pressure up on IA, and perform infectivity test down coi{. Pump 61 bbls of 15.8 ppg Class G cement through retainer w/- 1 bbl on top of retainer. Did not see a pressure bump during cementing. Est TOC 3066' ctmd. POOH while replacing voidage with diesel. Well is fluid packed with diesel to 2769' (TT at 2271'). Manifest all fluids and oversee fluid disposal/recycle.. Hang tag on tree to leave well shut-in. Blow down reel w/N2.. *** JOB COMPLETE *** 9/2/2007 T/1= 0/0 Temp= S/I CMIT Tx IA FAILED to 3000 psi. (Post P & A) Pumped 10.1 bbls. 60* diesel down IA to reach test pressure of 3000 psi., IA lost 140 psi in 1st 15 mins and 140 psi in 2nd 15 min for a total loss of 280 psi in 30 mins. ,Bleed WHP's, Final WHP's 0/0 9/3/2007 T/I/O = 190/220/200. Temp = SI. Monitor WHP's (post-cement sqz, pre-RWO). TBGP increased 190 psi overnight. IAP increased 220 psi overnight. 9/4/2007 T/I/O = 190/200/200. Temp SI. Bleed WHP's to 0 psi. (pre-rig Post P&A). TBG, IA, & OA FL @ surface. Bled TBGP from190 psi to 0 psi to bleed trailer in 25 mins. During TBG bleed IAP & OAP decreased 180 psi. Bled IAP from 20 psi to 0 psi in 10 mins. OAP decreased 20 psi. Bleed back a total of 2.5 BBLS. Monitor for 2 hrs. 1st HR monitor TBG, IA, OA increased 100 psi. 100/100/100.2nd HR monitor TBG, IA & OA increased 50 psi. FWHP'S = 150/150/150. 9/6/2007 RU to well, Stby for choke hand, (delayed flights) Insepect liner & open top tank --good condition Continued on 09- 07-07 9/7/2007 T/I/0=vac/100/100 Circ well to 9.2 brine (Pre SDTRK) Pumped 395 bbls 9.2 ppg brine down TBG (Kill string) taking returns up IA to choke/open top tank. 9.2 ppg brine returns @ surface (verified w/mud scale) @ shutdown. Monitor pressures for 90 mins T/IA/OA on vac. Tag well, notify operator & verify casing valves open to gauges. Final WHP's=vac/vac/vac 9/9/2007 Set 6" CIW for Rig Work. Pull 6" TWE for BOP Test. Pull 6" CIW for Rig work. • • BP EXPLORATIQN Page 1 of 16 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date ;From - T - - - ---~ - 9/9/2007 ! 00:00 - 03:( S-400 S-400 Spud Date: 1 /11 /2006 REENTER+COMPLETE Start: 9/9/2007 End: 9/29/2007 NABOBS ALASKA DRILLING I Rig Release: 9/29/2007 NABOBS 9ES Rig Number: Hours Task .Code NPT ', Phase Description of Operations 3.00 MOB ~ P PRE !Move in and rig up over S-400A. Hook up all lines at 03:00 - 04:30 1.50 WHSUR P 04:30 - 05:30 1.00 RIGU P 05:30 - 06:00 0.50 RIGU P 06:00 - 07:30 1.50 WHSUR P 07:30 - 09:30 2.00 W HSUR i P 09:30 - 12:00 2.50 BOPSU P 12:00 - 14:00 2.00 BOPSU P 14:00 - 18:00 4.00 BOPSUF~ i P 18:00 - 18:30 0.50 BOPSU~ P 18:30 - 19:30 1.00 BOPSU P 19:30 - 20:00 0.50 PULL P 20:00 - 20:30 0.50 PULL P 20:30 - 21:30 1.00 PULL P 21:30 - 00:00 19/10/2007 100:00 - 03:00 03:00 - 04:00 04:00 - 06:00 2.50 PULL P 3.00 PULL P 1.00 BOPSU P 2.00 BOPSU P 06:00 - 06:30 06:30 - 07:00 07:00 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 12:30 12:30 - 15:00 0.50 BOPSU P 0.50 CLEAN P 3.00 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 2.50 i CLEAN P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP interconnect. "'Accept rig for S-400A operations @ 03:00 hr, 9/9/2007 Verify annulus pressure is 0 psi - OK. Rig up working valve and secondary kill line on IA. Change out topdrive saver sub. Install bales on topdrive. PJSM with DSM. Rig up lubricator on tree. Pressure test to 1,000 psi - OK. Pull BPV. Tubing pressure = 0 psi. Set 2-way check valve. Test 2-way check valve to 1,000 psi from below - OK. Niipple down tree. Clean and check hanger threads - OK. Confirm X-over make up to hanger - OK. Remove X-over. Nipple up BOPE. Rig up to test BOPE. Make up 7" test joint with 7" TCII x 4.5" IF X-over. Make up safety valves and topdrive. Pressure test BOPE. Tested all equipment except bottom 7" rams due to spacing. 250 psi low / 3,000 psi high for 5 minutes witnessed by AOGCC rep Chuck Sheve, BP W SL T. Anglen, NAD TP K Cozby. Rig down BOPE test equipment. Test surface circulating equipment to 3,000 psi - OK. PJSM with DSM. Rig up SLB lubricator extension and DSM lubricator. Test to 1 000 si - OK. Pull 2-wav check valve_ Rig down lubricator and extension. Rig up to pull 7" kill string. PJSM. Back out tubing hanger lock-down screws. Pull hanger to rig floor. PU - 82k. Hanger and 7" tubing was covered in diesel. Rig up and circulate out remaining diesel. Pumped down tubing till clean, then down annulus till clean @ 200 gpm, 80 psi both ways. Only recovered 1/2 to 1 bbl total. Laydown hanger and landing joint. POH laying down 7" 26# L-80 BTC-M kill string. Layed down 25 joints to midnight. Continue POH with 7" kill string from 1,201' to surface. Recovered total of 54 joints. Make up and install BOP test plug. Change top rams from 7" to 3 1/2" x 6" VBR's. Rig up and test bottom 2 7/8" x 5" VBR's, top 3 1/2" x 6" VBR's, topdrive safety valves to 250 psi low / 3,000 psi high for 5 minutes each test. Rig down test equipment. Witnessing of test waived by AOGCC rep Chuck Sheve. Test witnessed by BP WSL R. French and NAD TP B. Tiedemann. Rig down test equipment. Install wear bushing. Change out elevators and prepare to pick up drill pipe. Pick up 69 joints of 4" drill pipe to 2,139'. POH standing back 8 stands of drill pipe to 1,387'. Inspect and adjust brakes. Continue POH to surface. PJSM. Make up BHA #1: Used 8.5" HTC MX1 bit, tea 9 5/8" casing scrapers, bit sub, bumper sub, oil jar, Sea 6 1!2" drill collars, x-over. Printed: 10/3/2007 2:25:04 PM • BP EXPLORATION Operations Summary Report Legal Well Name: S-400 Common Well Name: S-400 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours ' Task Code NPT - ~ __ 9/10/2007 15:00 - 16:00 ! 1.00 ~ CLEAN P 16:00 - 18:30 2.50 CLEAN P 18:30 - 20:30 2.00 CLEAN P 20:30 - 21:30 I 1.00 ~ CLEAN P 9/11 /2007 21:30 - 22:30 1.00 CLEAN P 22:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 00:00 - 01:30 I 1.50! CLEAN P 01:30 - 03:00 1.501 CLEAN I P 03:00 - 03:30 0.50 CLEAN P 03:30 - 05:00 I 1.50 DHB P 05:00 - 06:00 ' 1.00 DHB P 06:00 - 06:30 0.50 DHB P 06:30 - 07:00 0.50 DHB P 07:00 - 10:30 ~ 3.50, STWHIP P Start: 9/9/2007 Rig Release: 9/29/2007 Rig Number: Page 2 of 16 ~ Spud Date: 1/11/2006 End: 9/29/2007 Phase Description of Operations DECOMP Run in hole picking up 24 joints of 4" HWDP. DECOMP Run in hole with BHA #1, picking up 4" drill pipe out of pipeshed. Tagged up on 7" liner top 2 ft. high @ 3,037'. DECOMP Circulate, rotate and reciprocate. Change out well fluid from 9.2 ppg brine to 8.9 ppg brine. 223 gpm, 235 psi, 60 rpm, 3K TO. PU - 100k, SO - 80k, RWT - 92k. DECOMP Pressure test 13 3/8" X 9 5/8" casing and 7" liner top to 3,000 psi - 30 minutes -Good test DECOMP Cut and slip drilling line 45 ft. DECOMP Service topdrive and crown. Lubricate topdrive rail. DECOMP POH from 3,047' to 2,500'. 8.9 ppg MW . DECOMP Continue POH with cleanout assembly BHA #1 from 2,500' to 311'. DECOMP Stand back 3 stands of drill collars. Laydown oil jar, bumper sub, bit sub, casing scrapers and bit. DECOMP Clear rig floor. DECOMP PJSM. Rig up SLB E-line. Makeup Baker cast iron bridge plug DECOMP Run in hole with E-line GR/CCL, bridge plug. DEGOMP Position and set CIBP at 3005'. DECOMP Pull out with wireline and rig down. WEXIT PJSM. Make up Whipstock BHA to 488'. Shallow pulse test MWD too1,582 GPM @ 820 psi. ~ i ; 10:30 - 12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 15:00 1.50 2.00 0.50 0.50 STWHIP STWHIP STWHIP STWHIP N P P P RREP WEXIT WEXIT WEXIT WEXIT Change out brake linkage on drawworks. Run in hole with whipstock assembly to 2948'. Orient whipstock to 80 deg right of highside,450 GPM @ 1080 psi. Set whipstock at 3007',TOW 2985', BOW 3002'. Displace well to 9.0 ppg Flo Pro mud,480 GPM @ 859 psi. Record slow pum rates. 15:00 - 21:00 6.00 STWHIP P WEXIT Mill window, 450 GPM @ 815 psi. 83 RPM,20-30 k torque. S-~{(~~ WOB 4k, up wt. 105k,down wt. 93k, rotating wt. 85k. Drill new hole to 3025'. 21:00 - 22:30 1.50 STWHIP P WEXIT Dress window with string mill, mix and pump 25 bbl Hi-Vis sweep surface to surface. 22:30 - 23:30 1.00 STWHIP P WEXIT Perform FIT to 11.4 PPG. 23:30 - 00:00 0.50 STWHIP P WEXIT Monitor well,static, POOH from 2985' to 2060'. Up wt. i i 100k,down wt 86k. Mud wt. in and out 9.0 ppg. 9!12(2007 , 00:00 - 01:00 . 1.00 STWHIP WEXIT POOH from 2060' - 488'. 01:00 - 03:30 2.50 STWHIP WEXIT Rack back 3 stands of 6 1/2" drill collars and lay down milling assembly. 03:30 - 04:30 ~ 1.00 STWHIP WEXIT Lay down contractor tools from drill floor. 04:30 - 06:00 1.50 STWHIP WEXIT Make up test joint,back out lock down screws, and pull wear ring. Flush BOP with test joint and TIW. Install wear ring and run in lock down screws. 06:00 - 09:00 3.00 DRILL PROD1 Make up 8 1/2" directional assembly as per Schlumberger rep. Hycalog DSX 619M-D6 bit, Motor w/1.15deg bend and 8 3/8" ~ motor stab,8 1/2" motor top stab,MWD, NMDC, Jars,25 ~ j HWDP. 09:00 - 09:30 0.50 DRILL ( PROD1 Pick up 8 stds 4" HWDP and shallow test MWD tool, 480 GPM Printed: 10/3/2007 2:25:04 PM TREE = CNV 7" 5M WELLHEAD = ACTUATOR INLAY FMC = LEO KB. ELEV = _..64.6' BF. ELEV.- 39' KOP = 2985' Max Angle = Datum MD = Datum TV D = 47 @ 3422' 4260 3584 ~ ~ . ~20" CSG, 91.1#, H-40 13-318" CSG, 68#, L-80, ID =12.415" RA MARKER I 105' I 2264' --(7" 'R' Nipple; ID = 5.963" 2315' 5-1/2" X 7" XO 264$' I~ 5-115", 'X' Nipple; ID = 4.562" Minimum Gravel Pack Restriction = 3.550" Excluder Screens From 4024'-3495' 5-1/2" TBG, 17#, L-80, .0232 pbf, ID = 4.892" 2639' .~ a~- PERFORATION SUMMARY REF LOG: MWD Vision Resistivity ANGLE AT TOP PERF: 36° Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 4~/8" 21 3535' -3631 ' O 09119(07 ~r3f8~' 21 3938' - 4016' O 09/19(07 19-5/8" BKR Gen II Whipstock I '9-5/8" Cast Iron Bridge Plug I 3005' 9-518" CSG, 40#, L-80, ID = 8.835" 3221 IBKR, FA-1 PKR, w/S-22 SNAP LATCH I 17" LNR, 26#, L-80, ID = 6.276" I 1 4026' I I 4700' I 2669' I-~ HES SYMPHONY GAUGE WfTH I- WIRE, OD=0.25" 2692' CENTRiLiFT DiSCH HEAD, OD = 7.25" 2693' CENTRiUFT HPHV PUMPS, OD = 6.75" 2723' CENTRILIFTTANDEM SEALS, OD = 6.75" 2738' CENTRILFff HMI MOTORS (2), OD=7.25" 27$$' 6-FIN CENTRILIZER, OD = 8.0" 2843' BKR, ZXP LINER TOP PKR, PBR ID=7.5" 3385' BKRSGI GRAVEL PACK PKR 3394' BKR 80-40 SLIDING SLV 3414' BKR GPR-24 (63K} SHEAR OUT JOINT 3494-3417 4-1/2" BLANK PIPE, L-80, SLHT 4024-3495 BKR 4" IXCLUDER SCREEN MEDIUM, 9.5# , ID = 3.550" 4614' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 01/28!06 N7ES COMPLETION 12/26/06 N7ES RWO SUSPENDED 09/29/07 N9E5 SIDETRACK (S-400A) PRINCE CREEK WELL: S-400A PERMIT No: 2070740 API No: 50-029-23289-01-00 SEC 35, T12N, R12E, 4122' FSL, 4504' FEL BP F~cploration (Alaska) -400A Gravel ck PRINCE CREEK WATER SUPPLY WELL 1 1 I ~~~ ESP Maunder, Thomas E {DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 28, 2007 2:16 PM To: 'Smith, Phil G (ASRC)' Subject: RE: 5-400 (205-191) Rev 1 Operations summary.doc Phil, Your proposed change is acceptable. Nothing further is needed. The cement kill pill should work well. By the way, the correct well reference is 5-400. Be sure a copy of this message is at the rig. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From:. Smith, Phil G {ASRC) [mailto:Phii.G.Smith@bp.com] Sent: Tuesday, August 28, 2007 1:57 PM To: Maunder, Thomas E (DOA) Subject: 5-400A Rev 1 Operations summary.doc Tom, Current wellbore fluids have us in a bit of an underbalanced condition therefore we feel it would be safer to P&A the well pre-rig instead of after pulling tubing as the sundry is written. The change would simply replace the 9 5/8" retainer with a 7" retainer set about 40' deeper, and reduce the cement volume to 61 bbls from 67 bbls. May we have permission to make said change? Thanks, Phil «5-400A Rev i Operations summary.doc» ~. ~ ~~ S-400 O erations Summa Pre-Rig Work: 1. Recover RBP from 4095' MD. Perform infectivity test. 2. Set 7" cement retainer at ±3060' MD 3. RU Service CTU. Pump/squeeze 61-bbls 15.8 Class G cement to fill 100' below ESS 14 to the retainer. Unsting, Circulate out excess cement, POH. 4. Reverse circulate well to diesel at maximum rate from the casing annulus valve, taking returns up the 7" tubing. The annulus volume required = 232 bbls; tubing volume required = 87 bbls for a total of 319 bbls diesel. 5. Test casing to 3000 psi. Set BPV and test from below to 1000 psi 6. Level pad as required. Rig Operations: 1. MI / RU Nabors rig 9ES 2. Pull BPV with lubricator 3. Circulate out diesel freeze protection and displace the well to 8.9 ppg brine. Set TWC. 4. Nipple down tree. Nipple up and test BOPE to 3,000psi. Pull TWC. 5. Pull 7" tubing, install wear ring. 6. RIH with 8 '/" bit and 9 5/8" casing scraper to top of 7" cement retainer at ±3060' MD. Circulate well to clean brine. 7. P/U and RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly with space out joint as required to kick off at 3000' MD. Orient whipstock and set on bridge plug. Shear off of whip stock. 8. Displace the well to 9.0 ppg Flo-Pro milling fluid. Completely displace the well prior to beginning milling operations. 9. Mil{ window in 9 5/8" casing at ± 3,000' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 10. Pull up into 9 5/8" casing and conduct an FIT to 11.4 ppg EMW (10.4 EMW LOT is acceptable). POOH. 11. M/U 8 %" BHA. RIH, kick off and drill the production section to 200' below UG4A top. 12. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3000 psi. Gravel pack completion program to follow 07/23/07 Schlumh~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 'a9w' ? ; Il ~ t,.iS (C'b~i~. Oil"ili~ia51('aIi ~1~aos--~~~ # l5~ o~ NO. 4339 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~*e al r.~h. r•.n W-07A S-401 (REVISED) 4 4 40012483 40014121 OH EDIT MWD/LWD 11/06/05 10/21/06 2 1 1 1 S-401 PB7 (REVISED) 40014121 OH EDIT MWD/LWD 10/08/06 2 1 C-176 10715418 MCNL 08/10/04 1 L5-15 11626485 RST 05/12/07 1 1 N-15 11637129 RST 01/13/07 1 1 15-38A 10715446 MCNL 12/11/04 1 YLCA,C AGrINV WLCUIat KCla1Y 1 6T JW NINb ANU RC 1 UR1711YU V nc a.Vr 7 cna.n 1 v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • ~LASSA OII. A1~TD GAS CO1~T5ER~~~`I011T CO1rII-'IISSIOIQ Robert Tirpack Senior Drilling Engineer BP Exploration Alaska PO Box 196612 Anchorage, AK 99519-6612 SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Ugnu Undefined Water Supply Pool, PBU 5-400 Sundry Number: 307-179 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this `'~ day of June, 2007 Encl. ~~~~~1 ~7S /~/' STATE OF ALASI A~ f0~ -s~~ ~ E C E (VE D ALASKA OIL AND GAS CONSERVATION COMMISSION [NH`{ ~~ ~i ~~~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Dii ~ Gas ions. Commission 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time ExtensioAnchorage ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 205-191 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23289-00-00 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 S-400 _ Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028258 64.60' Prudhoe Bay Field / Ugnu 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4748 3948' 4748 - 3948 None None Casin en h Size MD TVD Burst Colla se Stru tural Con ctor 105' 2 1 10 ' Surface 3221 13-3/8" x 9-5/8" 3221' 2771' 4930 2270 Intermediate Pr uc ion Liner 1669' 7" 3039' - 4708' 2642' - 3913' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Expandable screens: 3300' - 4670' 2826' - 3879' 7", 26# L-80 2271' Packers and SSSV Type: None Packers and SSSV MD (ft): N!A 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ^ Development ®Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 26, 2007 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-x897 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number. Terrie Hubble, 564-4628 Signature ; Phone 564-4166 Date ~/ ~ „ ~ Commission Use Onl Sundry Number: _' Conditions of approval N otify Commission so that a representative may witness / ^ Plug Integrity LT BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Requir ~ .. APPROVED BY ~ r' ' ~ A roved B : __. .-- -- COMMISSIONER THE COMMISSION Date Form 10-403 Revised 0 2 ~ ~ Submit In Duplicate O Q, ~ BFL JUN 0 ~ 1007 • • ~ &_ ~e _v., Y ~ ~ - `. To: Tom Maunder - AOGCC Date: From: Phil Smith - BPXA GPB Rotary Drilling May 24, 2007 Subject: S-400 Application for Sundry Approval - Re-entry for sidetrack /gravel pack completion Reference: API # 50-029-23289-01 Approval is requested for the proposed re-entry of S-400 to sidetrack, perforate, gravel pack and complete the well with an ESP on tubing. The existing expandable screens failed to provide adequate sand control across the target SV and Ugnu sands. The 5-400 sidetrack is scheduled for Nabors rig 9ES. Current estimates have it beginning around July 4tn, 2007 following the completion of the S-401 gravel pack completion. The pre-rig work for this operation is planned to begin as soon as the attached Application for Sundry is approved. Current Condition: / Retrievable bridge plug set at 4095' / 7"26# freeze protection string surface to 2271' MD. Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Riq Work: 1. Recover RBP from 4095' MD. Perform infectivity test. 2. Set BPV. 3. Remove wellhouse and flowline. Riq Operations: 1. MI / RU Nabors rig 9ES 2. Pull BPV with lubricator 3. Circulate out diesel freeze protection and displace the well to 9.0 ppg brine. Set TWC. 4. Nipple down tree. Nipple up and test BOPE to 3,OOOpsi. Pull TWC. ~' 5. Pull 7" tubing, install wear ring. 6. RIH with 8 3/a" bit and 9 5/8" casing scraper to top of 7" liner at 3039' MD. Circulate well to clean brine. 7. RIH with 9 5/8" cement retainer on drillpipe. Set retainer at --3020' to allow for 3000' KOP without cutting a casing collar. Test casing to 3000 psi. 8. Pump/squeeze 67-bbls 15.8 Class G cement to fill 100' below ESS 14 to the retainer. Unsting, POH. 9. P/U and RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, as desired, and set on bridge plug. Shear off of whip stock. 10. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 11. Mill window in 9 5/8" casing at ± 3,000' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 12. Pull up into 9 5/8" casing and conduct an FIT to 10.4 ppg EMW. POOH. '~ 13. M/U 8 3/a" BHA. RIH, kick off and drill the production section to 200' below UG4A top. A~1 Isi'~~' ~~~' S-400 Application for Sundry • • 14. Circulate well clean, short trip to window. POOH. 15. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3000 psi. 16. RIH with 6 1/8" bit and 7" x 9 5/8" scrapers to landing collar. 17. Reverse circulate the well to 9.0 ppg brine. Employ Dirt Magnet sweeps and circulate until returns reach 50 ntu. 18. RU a-line. Run USIT log across 7" for cement evaluation. 19. Set Baker Model FA packer 10' below lowermost planned perforation. 20. RIH DPC perf guns and perforate ±310' net, 900' gross interval. 21. RIH with dummy ratchet latch and latch into the FA packer. POH. 22. RIH with ±1000' of Baker Excluder screen assembly and SC-1 packer. 23. Latch into FA packer and set the SC-1 packer 24. Pickle the 4" drillpipe with 500 gallons HCI acid. Perform matrix acid treatment. 25. Perform step rate test and gravel pack. 26. Complete well with 1000 HP ESP on 7" production tubing 27. Set TWC, ND BOP and NU tree. Test tree to 5000 psi. 28. Pull TWC and freeze protect well to 2200' with 310 bbls diesel. 29. Set BPV Secure the well. Rig down and move off. Post-Rict Work: 1. Install well house and instrumentation 2. POP well to test unit until cleaned up. Estimated Pre-rig Start Date: 06/01 /2007 Estimated Sidetrack Start Date: 07/04/2007 Phil Smith Operations Drilling Engineer 564-4897 office 240-8072 cell S-400 Application for Sundry Tree: CIW 7" 5M Wellhead: FMC Big Bore 20" 131.45 ppf, X-56 I 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. 13 3/8 68 ppf, L-80 BTC 2589` RA Tag 2812 7" Hanger/Packer 3039 9 5/8" 40 ppf, L-80 BTC 3221 7" csg. shoe 4707 8 1 /2" Driller's TD 4748 Orig. DF elev. = 64.4' Orig. Cellar elev. = 35.9' 7" Mule shoe pup end 2271 ` 95/8x7"Hngr top SV3 blank ESS 1-3 (150 -SV3) / SV3 blank ESS 4-5 (150 -SV2) / SV2 blank ESS 6-7 (150 -SV2) / Blank ~ ~ ESS 8 (150 -SV2) ~\ Blank ESS 9 (150 -SV2) i Blank i EZI ~ ~ top SV1 blank ~ \\\ ESS 10-12 (150 - SV1) i top SV1 blank ~ ESS 13 (150 - SV1) SV1 blank EZI(coal at top UG4) UG4A blank EZI Packer ~ ~ ESS 14 (230 -UG4) i Blank 7" Pipe Guideshoe DATE REV. BY COMMENTS 12/27/06 PGS Post RWO Operations shut-down 3039 3055 3300 3394 3515 3572 3582 3657 3672 3710 3748 3786 3843 3863 3959 4071 4201 4239 4268 4288 4593 4632 4670 4708 S-Pad Well S-400 WSW API NO: 50-029-23289 S-400 Actual Tree: CIW 7" 5M Wellhead: FMC Big Bore S-400A Pro 20" 131.45 ppf, X-56 105` , 7" 26# L-80 BTC-M TBG 2300` 13 318 68 ppf, L-80 BTCm 2589` 5.5" 17# L-80 BTC-M TBG 2,750` RA Tag 7" Hanger/Packer 9 5/8" Window 9 5/8" 40 ppf, L-80 BTCm (8.835" ID) 2812` 2850 Top Perf (310` of 900' Gross) `_ Bottom Perf 7" Landing Collar 4600 7" LNR Shoe 4683` 8 1 /2" Driller's TD 4683 7" BKR LNR HGR/PKR 2,850 I Baker SC-1 Packer Gravel Pack Extension Shear Out Safety Joint Blank Pipe, 4 1/2" 11.6# 28-each Excluder 2000 screens Orig. DF elev. = 64.4' os e d Orig. Cellar elev. = 35.9' 7" R Nipple 2,250` 5 1/2" X Nipple 2,600` HES Symphony gauge 2,650` w/ESP cable Centrilift 57 stage HC27000 2,750` 675 ESP, 6.75" OD,` Centrilift HST34B EHL PFS 2773' seal section Centrilift Series,HMIHE 2,800` 1000 hp series725motor S-22 Snap-Latch Assembly Baker FA Packer DATE REV. BY COMMENTS 05!14107 PGS Proposed Sidetrack /Gravel Pack 0 S-Pad Well S-400A WSW API NO: 50-029-23289-01 BP EXPLORATION STATE OF ALASKA r ~ O~ ~~~~ ALAS IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL ~~'b-31• Caf~lmissian ~I?OOi'8f~¢ Water Source Well 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ®Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 205-191 '~ 3. Address: ^ Stratigraphic ®Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-23289-00-00 7. KB Elevation (ft): o ~~ ~~~'~~ 9. Well Name and Number: ~ PBU S-400 8. Property Designation: 10. Field /Pool(s): ADL 028258 f Prudhoe Bay Field ! Ugnu 11. Present well condition summary Total depth: measured 4748 ~ feet true vertical 3948 ~ feet Plugs (measured) 3094 Effective depth: measured 4748 ~ feet Junk (measured) None true vertical 3948 ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 105' 20" 105' 105' Surface 3221 13-3/8" x 9-5/8" 3221' 2771' 4930 2270 Intermediate Production Liner 1669' 7" 3039' - 4708' 2642' - 3913' 8160 7020 Perforation Depth MD (ft): Expandable screens: 3300' - 4670' Perforation Depth ND (ft): 2826' - 3879' Tubing Size (size, grade, and measured depth): 7", 26# L-80 2271' Packers and SSSV (type and measured depth): None N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): p ~'q y rt/ t^, '~l LF Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbi Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after proposed work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after proposed work: d~J (,J'j- / ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Phil Smith, 564-4897 306-409 Printed Name Terrie nubble Title Technical Assistant l Prepared By Name/Number: Ot ~~ 1 Signature Phone 564-4628 Date D7 Terrie Hubble 564-4628 ~j7 Form 10-404 Revised 04/2006 ~`~~~ Submit Original Only BP EXPLORATION Page 1 of 7 .Operations Summary Report Legal Well Name: S-400 Common W ell Name: S-400 Spud Date: 1/11/2006 Event Nam e: REENTE R+COM PLET E Start : 12/9/2006 End: Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To , Hours Task ' Code NPT I Phase Description of Operations 12/14/2006 15:00 - 00:00 9.00 MOB P PRE Disconnect service lines at interconnect. Move pit module from sub base and set in the proximity of S-400. Move sub base off of S-31a to edge of pad. Move satellite camp and set in place. Remove top drive from blocks, bridal up, lower pipe chute. Lower derrick. 12/15/2006 00:00 - 04:00 4.00 MOB P PRE Move substructure to S-400. Set mats, spread herculite. Raise and pin derrick. 04:00 - 07:00 3.00 MOB P PRE Spot and level substructure over S-400. Spot and level pit module. 07:00 - 09:00 2.00 RIGU P PRE Hook up service Imes at inter connect. Spot and berm cuttings tank. Berm cellar area. 09:00 - 12:00 3.00 RIGU P PRE Safety stand down held with driller Will Tuner and crew members. Rig accepted on S-400 at 12:00 hrs. 12/15!2006. - 12:00 - 15:00 3.00 RIGU P PRE Safety stand down held with driller David Guess and crew members. 15:00 - 18:00 3.00 RIGU P PRE Bridal down. Hook blocks to top drive. Hang bridal Fines in derrick. Berm rig in place. 18:00 - 20:00 2.00 WHSUR P DECOMP Rig up lines to circulate freeze protect from well bore. 20:00 - 20:30 0.50 WHSUR P DECOMP Pre spud safety and environmental meeting. 20:30 - 23:00 2.50 WHSUR P DECOMP Bled off trapped pressure between master valve and tree cap from heat expansion. Pull VR plugs. Rig up lubricator and pull BPV with DSM lubricator. Rig down lubircator. 23:00 - 00:00 1.00 WHSUR P DECOMP Install secondary annulus vavle. IA 150 psi. OA 150 psi. 12116/2006 00:00 - 01:00 1.00 WHSUR P DECOMP Blow thru lines to cuttings tank. Test lines to 3000 psi. 01:00 - 03:30 2.50 WHSUR P DECOMP Circulate 90 degrees 8.6 ppg brine water down the 7" tubing. Taking returns out the OA thru the choke to the cuttings tank at 126 gpm, 170 psi. At calculated strokes freeze protect ceased and brine water became a milky color. Sample was taken and it was observed that there was +- 150 cc of sand in the bottom of vis cup. Recovered 377 bbls of diesel. 03:30 - 06:00 2.50 WHSUR P DECOMP Continue to circulate 243 bbls until returns clean up of formation sand at 126 gpm, 170 psi, by passing the super choke. taking returns out to the cuttings tank. Brine water wt. In 8.6 ppg. Out 8.6 ppg. Verify well dead. Blow down line to cuttings tank. No losses while circulating out freeze protect. 06:00 - 07:30 1.50 WHSUR P DECOMP Install TWC. Test from above to 1000 psi. Test from below only held 250 psi. 07:30 - 11:00 3.50 WHSUR P DECOMP Nipple down tree and adapter flange. Verify hanger threads. Terminate lines. 11:00 - 17:00 6.00 BOPSU P DECOMP Nipple up BOP. Change top pipe rams from 3.5" x 6" var. rams to 4.5" x 7" var rams. Change lower pipe rams from 2-7/8" x 5" var rams to 3 1/2" x 6" var rams. Change saver sub on top drive from 4" HT-40 to 4 1/2" IF. 17:00 - 18:00 1.00 BOPSU P DECOMP Rig up 7" test joint and test equipment. 18:00 -00:00 6.00 BOPSU P DECOMP Test BOPS and all associated valves to 250 psi low 3500 psi high. Utilizing 7" joint. BOP test wittnessed by AOGCC rep John Crisp, BP WSL Wade Frame, Nabors Toolpusher Lenward Toussant. Printed: 72/27/2006 1:39:33 PM BP EXPLORATION Operations Summary Report Page 2 of 7 Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1!11/2006 Event Name: REENTER+COMPLETE Start: 12/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To ,Hours Task Code NPT ~ Phase Description of Operations 12/16/2006 18:00 - 00:00 6.00 BOPSU P DECOMP Flange between mud cross and tower pipe rams leaked and had to be tightened. Tighten gland packing. 12/17/2006 00:00 - 04:00 4.00 BOPSU P DECOMP Continue to test BOPS and all associated valves to 250 psi low 3500 psi high. Utilizing 7" joint. Having difficulty obtaining a 3500 psi test on BOP. Change out faulty pressure sensor. Isolate and determine HCR kill valve leaking and Valve #14 leaking on choke. BOP test wittnessed by AOGGC rep John Crisp, BP WSL Wade Frame, Nabors Toolpusher Lenward Toussant. 04:00 - 12:00 8.00 BOPSU N RREP DECOMP 12:00 - 13:00 1.00 BOPSU P DECOMP 13:00 - 14:30 1.50 BOPSU P DECOMP 14:30 - 15:30 1.00 PULL P DECOMP 15:30 - 19:00 3.50 PULL P DECOMP 19:00 - 00:00 5.00 PULL P DECOMP 12/18/2006 100:00 - 04:30 I 4.501 PULL I P 04:30 - 07:30 I 3.001 PULL I P 07:30 - 10:00 I 2.501 PULL I P 10:00 - 12:00 f 2.001 BOPSUR P 13:00 - 15:00 2.00 F SH U I P 15:00 - 15:30 0.50 FISH P 15:30 - 20:30 5.00 FISH P 20:30 - 00:00 3.501 FISH P Change out HCR kill and valve #14 on choke manifold. Test choke valve #14 and HCR kill valve to 250 psi low 3500 psi high. Test wittnessed by BP WSL Cris Clemens, Nabors toolpusher Larry Wurdman. Blow down lines. Rig up DSM lubricator. Pull TWC valve. Rig down DSM lubricator. Engage tubing hanger. Back out lock down screws and pull 7" tubing hanger to rig floor at 95k Up wt. Circulate at 342 gpm 250 psi, while rigging up Centralift, Nabors casing, and Halliburton equipment. A very fine slity/sand was obsenrered at bottoms up. No gain or losses while circulating. Brine water wt. In 8.6 ppg. Out 8.6 ppg. Pull out of the hole laying down 7" 26# L-80 BTC-Mod tubing. Lost 6 bbls over calculated for 30 joints of 7" laid down. DECOMP Pull out of the hole laying down 7" 26# L-80 BTC-Mod tubing and accessories. Recovering ESP cable and I-wire on spooling units. Lost 10 bbls of 8.6 ppg brine water to well bore. Rercovered 59 joints of 7" and 6 joints of 5 1/2" tubing + accessories. DECOMP Terminate ESP cable at ESP motor. Remove Halliburton's spooling unit from rig floor. Rig down Centrilift equipment. Rig down Nabors casing equipment. DECOMP Disassemble ESP motor and lay down. Recovered (60) 7" LaSalle, (7) 5 1/2" LaSalle Clamps, (4) 1 1/4" SSB. Left (6) LaSalle hinge pins and (8) 1 1/4" SSB and (4) each 6 foot ESP cable guards that were attached to lower section of ESP motor in the hole. DECOMP Rig up and test lower pipe rams to 250 psi low, 3500 psi high. Utilizing 4" test joint. Test upper pipe rams to 250 psi low, 3500 psi high. Utilizing 5" test joint. BOP test wittnessed by BP WSL Christopher Clemens. Nabors toolpusher Larry Wurdeman. DECOMP Rig down test equipment. Instal{ wear bushing. DECOMP Change out bails on top drive. Pick up 5" drill pipe from pipe shed to 855', while mobilizing Schlumberger slick line. DECOMP Pull out of the hole with 5" drill pipe. DECOMP Spot Schlumberger slick line unit, Centrilift spooling unit in the way of slick line rig up. Move centrilift spooling unit. Rig up Schlumberger slick line. DECOMP Run in the hole with 6" guage ring and junk basket working Printed: 12/27/2006 7:39:33 PM BP EXPLORATION Operations Summary Report Page 3 of 7 Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: REENTER+COMPLETE Start: 12/9/2006 End: Contractor Name: NASORS ALASKA DRILLING I Rig Release: Rig Name: NASORS 7ES Rig Number: Date From - To Hours ~ Task Code' NPT ' Phase Description of Operations 12/18/2006 20:30 - 00:00 3.50 FISH P DECOMP past 1940' and tagging up at 2596' slick line measurment. Pull out of the hole with guage ring and junk basket. No recovery. Run in the hole with Bakers 5 1(2" magnet to tag up at 2596'. Observered a 50# over pull on pick up, pull out of the hole. Inspect magnet, only recovered 3 very small pieces of metal. run in the hole with 5 1/2" magnet, tagging up at 2598'. Observered the same over pull as the first magnet run. Pull out of the hole with no recovery. 12/19/2006 00:00 - 03:00 3.00 FISH P DECOMP Remove 5 1/2" magnet, dress slick fine with a 4 1/2" OD wire grab and run in the hole. Tagging up at 2596'. Pull out of the hole. Run in the hole with 6" impression block, setting down at 2596', pull out of the hole. Impression block had (2) 1 1/2" marks and (1) 1/2" mark on the shoulder of the impression block. 03:00 - 04:00 1.00 FISH P DECOMP Rig down Schlumberger slick line. 04:00 - 07:00 3.00 FISH P DECOMP Load pipe shed wIBHA components. PJSM and pick up BHA #1 consisting of 7 7/8" reverse circulating basket, one 7" boot basket, bit sub, 4-3/4" oil jar, xo, six 4-3/4" spiral drill collars. OAL BHA = 217.81'. 07:00 - 09:00 2.00 FISH P DECOMP PJSM and PU 66 jts of 5" drill pipe and RIH to 2305'. 09:00 - 12:30 3.50 FISH P DECOMP RIH w/drill pipe f/derrick washing down 278 gpm, 2700 psi, rpm 12, PU wt 80K, SO wt 70K. Wash down to 2884'. 12:30 - 14:00 1.50 FISH P DECOMP CBU. 279 gpm, 2747 psi, 22 rpm, 3K tq. Sand recovery negligible. Experienced 0 gains/losses while circulating. 14:00 - 16:30 2.50 FISH P DECOMP PJSM. Monitor well, OK. BD topdrive. POH. Ho{e fill = 4.2 bbls over calculated volume. 16:30 - 17:00 0.50 FISH P DECOMP Work BHA and find one 6' cable clamp and two bands inside reverse basket w/no recovery f/boot basket. 17:00 - 18:00 1.00 FISH P DECOMP Service/lubricate rig, top drive, drawworks. 18:00 - 19:00 i.00 FISH P DECOMP PJSM and pick up BHA #2 same as #1 consisting of 7 7/8" reverse circulating basket, one 7" boot basket, bit sub, 4-314" oil jar, xo, six 4-314" spiral drill collars. OAL BHA = 217.81'. 19:00 - 20:30 1.50 FISH P DECOMP RIH to 2871'. 20:30 - 21:00 0.50 FISH P DECOMP Wash down f/2871' to 2950'. 283 gpm, 2840 psi, 16 rpm, 3K tq, PU wt. 80K, SO wt. 70K, Rot. wt. 80K. 21:00 - 22:00 1.00 FISH P DECOMP CBU. 283 gpm., 2840 psi, 16 rpm, 3K tq. Experienced 0 gains/losses while circulating. No sand recovery. 22:00 - 00:00 2.00 FISH P DECOMP PJSM. Monitor well, OK. BD topdrive. POH. 12/20/2006 00:00 - 01:30 1.50 FISH P DECOMP POH. Work BHA. Find one band inside of reverse basket and nothing inside of boot basket. 01:30 - 02:00 0.50 FISH P DECOMP Work BHA. 02:00 - 03:30 1.50 FISH P DECOMP RIH U2950' w/BHA # 3 same as #1 & #2 consisting of 7 7/8" reverse circulating basket, one 7" boot basket, bit sub, 4-3/4" oil jar, xo, six 4-3/4" spiral drill collars. OAL BHA = 217.81'. 03:30 - 04:30 1.00 FISH P DECOMP Wash down slowly f/2871' to 2994'. 04:30 - 06:00 1.50 FISH P DECOMP CBU. 337 bbls. 276 gpm, 2700 psi, 16 rpm, PU wt 80K, SO wt. 77k. 06:00 - 08:30 2.50 FISH P DECOMP POH. POH f/2994'. Nothing in reversing junk basket. LD jars and make service breaks on jet basket. 08:30 - 09:30 1.00 FISH P DECOMP Service top drive and rig, clean rig floor while mobilizing Schlumberger slick line. 09:30 - 11:00 1.50 FISH P DECOMP PJSM. RU Schlumberger slick line unit. 11:00 - 12:30 1.50 FISH P DECOMP RIH w/5.5" OD magnet on slickline to 3041'. POH w/1/2" piece Printed: 12/27/2006 1:39:33 PM BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: REENTER+COMPLETE Start: 12/9/2006 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 7ES Rig Number: Date From - To ,Hours ' Task ,Code NPT Phase i Description of Operations 12/20/2006 11:00 - 12:30 1.50 FISH P DECOMP 12:30 -13:30 1.00 FISH P DECOMP 13:30 - 15:00 1.50 FISH P DECOMP 15:00 - 16:00 1.00 FISH P DECOMP 16:00 - 16:30 0.50 FISH P DECOMP 16:30 - 17:30 1.00 FISH P DECOMP 17:30 - 18:30 1.00 FISH P DECOMP 18:30 - 20:30 2.00 FISH P DECOMP 20:30 - 22:00 1.50 FISH P DECOMP 22:00 - 00:00 2.00 FISH N DECOMP 12/21/2006 00:00 - 02:00 2.00 FISH P DECOMP 02:00 - 03:00 1.00 FISH P DECOMP 03:00 - 03:30 0.50 FISH P DECOMP 03:30 - 06:00 2.50 FISH P DECOMP 06:00 - 06:30 0.50 FISH P DECOMP 06:30 - 07:30 1.00 FISH P DECOMP 07:30 - 09:00 1.50 FISH P DECOMP 09:00 - 10:00 1.00 FISH P DECOMP 10:00 - 10:30 0.50 FISH P DECOMP 10:30 - 12:30 2.00 FISH P DECOMP 12:30 - 14:00 1.50 FISH P DECOMP 14:00 - 18:00 4.00 CLEAN P DECOMP of hinge pin. RIH w/ junk basket w/6" OD gage ring on slickline to 3044'. POH. No junk recovered. RIH to 3044' w/5.5" OD 3 prong wireline grab. POH and recover one 6' cable guard and two SS bands. RIH to 3052' for run #2 w/3 prong grab. Latch on to junk and see 100# overpull. No junk recovered. RIH to 3044' for run #3 w/3 prong grab. Could not go deeper. Latch on to junk and see 100# overpull. No junk recovered. RIH w! junk basket w{6" OD gage ring on slickline to 3048' Could not go deeper. POH. No junk recovered. RIH to 3050' w/5.5" OD 4 prong wireline grab w/spear to 3050'. Could not go deeper. No overpulls. No junk recovered. RIH w/4.5" OD lead impression block to 3045'. Sit down twice. Come out w/two good images of top of cable guard in block. RD slick line. PU 5-3/4" OD reverse jet basket BHA #4 f/7" liner. Damage wash pipe during makeup of BHA. No replacement available. Break down and LD jet basket components. Consult w/town ODE and decision made to run rope spear. Send damaged jet basket component to Baker Machine shop for repair and turnaround to rig by 6:00 a.m. PU BHA #5 w/rope spear w/5.813" gage, XO, two 7" boot baskets, bit sub, 4-3/4" oil jars, 6 4-3/4" drill collars, XO, 4 jts 4" HT-40 drill pipe, XO to 4-3/4" IF, 5" drill pipe to surface. RIH to 3030'. PU wt. 85K. SO wt. 75K, Rot. wt. 80K. Tq. above liner top 2.6K. Set torque limiter to 5K. Rotate 15 rpms and slowly work pipe/rope spear past lead impression block run depth of 3045' down to 3054'. See 5K weight loss at 3046'. Torque increase f/2.7K to 3.5K. Stop rotation and slowly pull back up to liner top at 3039' w/PU wt 87K. POH wiWL spear BHA #5. No overpull coming off bottom. LD cleanout BHA #5. Clear floor. Make up BHA #6 w/mule shoe, 5-3/4" reverse jet basket, XO, two 3-1l2" boot baskets, bit sub, 4-3l4" oil jars, six 4-314" spiral drill collars, XO, 4" drill pipe XO, 5" drill pipe to surface. RIH t/2913' and wash down w/8.6 ppg brine to 3006'. 500 gpm, 2460 psi. PU 80K, SO 75K. Wash down f/3006' to 3070'. Saw 5K wt loss at 3060'. Kept washing down to 3070'. PU to 3050' w/5K overpull. Made 4 trips 3050' to 3070' and saw 5K weight loss each time at 3060'. CBU at 3070'. 357 bbls, 2460 psi, 508 gpm. POH w/cleanout reverse jet basket BHA #6 to BHA at 544'. Brine wt. = 8.6 ppg. Work BHA and recover final 2 cable guards of the total 4 cable guards lost in hole. Estimate recovery of 3 SS bands (some small pieces) of the total 4 SS bands lost in hole. Make up BHA #7 w/mule shoe, 5-3/4" reverse jet basket, XO, two 3-1/2" boot baskets, bit sub, 4-314" oil jars, six 4-314" spiral drill collars, XO, 4" drill pipe, 17 jts. 4" HWDP, XO, 4" DP XO, 5" drill pipe to surface. Printed: 12127!2006 1:39:33 PM BP EXPLORATION Operations Summary Report Page 5 of 7 Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: REENTER+COMPLETE Start: 12/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To ,Hours ' Task ,Code' NPT~ Phase Description of Operations _ - --. --- 12/21/2006 18:00 - 18:30 0.50 CLEAN I P ` DECOMP RIH to 2800'. 18:30 - 21:00 2.50 CLEAN I P I DECOMP ~ Wash down f/2800' to 3342'. 464 gpm, 2571 psi, PU wt. 90K, j I SO wt 75K. See 8K wt loss at 3080'. See 5K wt. loss at 3333'. 21:00 - 00:00 3.00 CLEAN P DECOMP 12/22/2006 00:00 - 01:00 1.00 FISH P DECOMP Oi :00 - 02:00 1.00 CLEAN P DECOMP 02:00 - 03:00 1.00 CLEAN P DECOMP 03:00 - 05:00 2.00 CLEAN P DECOMP 05:00 - 07:00 2.00 CLEAN P DECOMP 07:00 - 08:30 1.50 CLEAN P DECOMP 08:30 - 15:30 7.00 CLEAN P DECOMP 15:30 - 17:30 2.00 CLEAN P DECOMP 17:30 - 18:30 1.00 CLEAN P DECOMP 18:30 - 19:00 0.50 CLEAN P DECOMP 19:00 - 20:00 1.00 CLEAN P DECOMP 20:00 - 21:30 1.50 CLEAN P DEGOMP 21:30 - 23:00 1.50 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 12/23/2006 00:00 - 01:00 1.00 CLEAN P DECOMP 01:00 - 01:30 0.50 CLEAN P DECOMP 01:30 - 02:30 1.00 CLEAN P DECOMP 02:30 - 08:45 6.25 CLEAN P DEGOMP 08:45 - 10:00 1.25 CLEAN P DECOMP See 1200 psi pressure loss at 3342`. POH to check tools and checking flwashout. LD 5-3/4" jet reverse basket BHA #7. Find ball seat in reverse basket washed out and ball gone from seat area. No junk recovery f/RCJB or boot baskets. PU cleanout BHA #8 w/6" round nose junk mill (no cutrite on outer body), two 3-112" boot baskets, bit sub, 4-314" oil jars, 3-1/2" circ sub, six 4-3/4" drill collars, XO, 17 jts. 4" HWDP, XO, 33 jts. 4" drill pipe, XO to 5" drill pipe. BHA cumulative length to top of XO to 5" drill pipe = 1773.61. RIH to top of screen at 3299'. CO 8.6 ppg brine to 8.6 ppg Ffo-Pro mud at 3293' to complete cleanout. 510 gpm, 1230 psi. NOTE: Very fine sand in large quantities found under 325 mesh (34-53 micron) screens in shaker #4. Also find very fine sand under shaker # 1,2, and 3 screened f/200 to 230 mesh. Clean out sand from underneath shakers. Wash down w/8.6 ppg Flo Pro-Mud f13293' to 3733', 590 gpm, 1015 psi. Experience 100 bbl/hr mud losses. String in 20 sacks Mi 30/50 CaC03 for fluid loss control while working pipe back up hole f/3733' to 3670'. 593 gpm, 1006 psi. Shut down pumps. Monitor welt. Losses = 0 wlpumps off. Wash down f/3670' to 4707'. 597 gpm, 1195 psi. MW = 8.6 ppg. Monitor well. OK. BD topdrive. POH to 3069'. Circulate at 606 gpm, 942 psi, 14 rpm, 2.5K tq f/3069' to TOL i at 3039'. Park pipe just below liner top and CBU X 3 until mud clean across shakers. Losses dropped to 30-50 bbls/hr. when 'pumps on. Monitor well. OK. BD topdrive. MW = 8.6 ppg. POH to 2629'. !Circulate and work pipe up and down through 9-5/8" x 13-3/8" XO. 619 gpm, 769 psi, 14 rpm, 2K tq, PU wt = 75K, SO wt. _ 60K, Rot. wt. = 70K. Bring fine sand and CaC03 across shakers. ~ PJSM. Monitor well. RIH to 4707'. CBU X 3 until Flo-Pro clean across shakers. 504 gpm, 800 psi, PU wt. 120K, SO wt. 87K. MW = 8.6 ppg. Monitor well. OK. BD topdrive. POH f/4707' i to 3069'. CBU X 3 until Flo-Pro clean across shakers. CBU X 2 at 3069' below TOL until Ffo-Pro clean across shaker. 500 gpm, 590 psi. MW = 8.6 ppg. Monitor well. OK. POH to 2629' at 9-5/8" X 13-3/8" XO. CBU X 2 at 2629' below XO until Flo-Pro clean across shaker. 505 gpm, 538 psi, 15 rpm, 2.4 tq. i BD topdrive. Clean out sand (fall surface equipment, pumps, 'and lines. Prepare to take on clean brine prior to camera run. RIH and tag bottom at 4710'. PU and land bullnose at 4705' ~ f/circulation. PU wt. 120K, SO wt. 87K. Printed: 12/27/2006 1:39:33 PM BP EXPLORATION Page 6 of 7 Operations Summary .Report Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: REENTER+COMPLETE Start: 12/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: i Date ,From - To !Hours Task Code NPT Phase Description of Operations 12/23/2006 10:00 - 11:15 1.25 CLEAN P DECOMP Clean out pit system. 11:15 - 12:30 1.25 CLEAN P DECOMP CO Flo-Pro mud system to clean 8.6 ppg brine. 565 gpm, 1560 psi, reciprocate 30'. Monitor well. OK. BD top drive. 12:30 - 15:30 3.00 CLEAN P DECOMP RU Swaco DE filtration van. Berm around van completely wlherculite and 12" sills. Losing 5 bbls. brine/hr to well. 15:30 - 17:00 1.50 CLEAN N WAIT DECOMP Wait on Swaco to thaw out hoses for DE filtration van and utilize Nabors electrician to troubleshoot Swaco van electrical problem. 17:00 - 00:00 7.00 CLEAN P DECOMP Circulate and filter brine with Swaco DE filtration van. 162 gpm, 165 psi. Surface to surface X 2. Check fluid clarity wlHalliburton camera operator. More circulation required. 12/24/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Glean DE filter units. Circulate and filter brine with Swaco DE filtration van. 162 gpm, 165 psi. Surface to surface X 3 for a total of 5 round trips. Check fluid clarity w/Halliburton camera operator after each surface to surface cycle. Some improvement between circulation 2 and 3. No improvement to less clarity between 3 and 5. SD Swaco unk. 03:00 - 03:30 0.50 CLEAN P DECOMP PJSM and RU to POH. RD Swaco DE filtration van. 03:30 - 06:00 2.50 CLEAN P DECOMP POH. LD bullnose cleanout BHA #8 and 6 drill collars. 6" bullnose mill gone f/end of BHA. Length 16.67" 5.958" OD at bullnose milt. Fishing neck length = 11.00 in. Fishing neck OD = 4.75" . Baker serial # ZAF0026. 3-1/2" IF pin up. Clear rig floor. 06:00 - 10:45 4.75 EVAL P DECOMP PJSM w/WSL, toolpusher, Halliburton and rig crew. RU and RIH w/Halliburton camera. Some areas of clarity at upper end of screen section (ESS 1-3). Observed quite a few silt-like emmisions from this first set of screens. Also noted larger, hair like partic{es, sticking out of screens. Believe silt deteriorating brine clarity. 10:45 - 13:00 2.25 EVAL P DECOMP Rig up Halliburton grease injector for lubricator. Bullhead 211 bbls. of 8.6 ppg clear fresh brine to displace liner. Could not get good image below top screens with fluid and sand/silt movement. Camera lens was smudged withsome dark substance that further obscured video. 13:00 - 14:00 1.00 EVAL P DECOMP POH w/camera, change bulb ,clean lens. 14:00 - 17:00 3.00 EVAL P DECOMP RIH and video log to 4000'. Some areas of fluid clarity toward upper end of screen section of liner. A flour like material could be observed entering the wellbore through the screens -the majority in ESS i-3 with ESS 4-5, 6-7 & 8 showing less screen pass through but less clarity of picture. Turbidity increased below the top screen section where video acquisition became poorer moving toward the lowest point of any visability at 4000'. No attempt was made to go deeper. it would seem that the Glen brine bullheaded did not get this far down. No damage to screens was visible. Note: Video tog made on CD and copy downloaded to Anchorage server. 17:00 - 18:30 1.50 EVAL P DECOMP POH and RD Halliburton eline unit. 18:30 - 19:30 1.00 BOPSU P DECOMP Pull wear bushing and RU to test BOP. 19:30 - 21:00 1.50 BOPSU C DECOMP BOP test. Testing choke manifold. Well taking fluid at 50 bbls/hr. Mobilize Baker W ireline Retrievable Bridge Plug w/5.968" OD f/7" 29# casing. 21:00 - 00:00 3.00 TA C DECOMP RIH w/WLSRBP w/J hydraulic setting tool on drill pipe to 2561'. Printed: 12(27/2006 1:39:33 PM BP EXPLORATION Operations Summary Report Page 7 of 7 Legal Weft Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: REENTER+COMPLETE Start: 12/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date - `~From - To Hours Task Code I NPT ~ Phase ~ Description of Operations 12/25/2006 100:00 - 00:30 ~ 0.50 ~ TA ~C 00:30 - 01:30 I 1.00 I BOPSUF# C 01:30 - 02:30 1.00 BOPSU~ C 02:30 - 03:00 0.50 BOPSU C 03:00 - 04:00 1.00 BOPSU C 04:00 - 07:45 3.75 TA C 07:45 - 08:30 0.75 TA C 08:30 - 09:30 1.00 TA C 09:30 - 10:30 1.00 BOPSU C 10:30 - 15:30 5.00 BOPSUF~ N 15:30 - 21:30 6.00 BOPSU C 21:30 - 00:00 I 2.501 TA I C 12/26/2006 ~ 00:00 - 03:00 I 3.00 I TA I C 03:00 - 05:00 I 2.00 I TA I C 05:00 - 07:30 I 2.501 BOPSUFi C 07:30 - 09:00 1.50 BOPSU C 09:00 - 11:30 2.50 BOPSU C 11:30 - 14:30 3.00 BOPSU C 14:30 - 15:30 1.00 BOPSU C 15:30 - 16:00 0.50 BOPSU C 16:00 - 18:30 2.50 BOPSU C DECOMP Continue RIH to 7" liner w/WLSRBP/J hydraulic tool to set depth in middle of first full jt of 7" 29# blank pipe at 3094'. Drop brass ball and allow to gravitate to seat in J hydraulic setting tool. Pressure up to 2207 psi on tool and PU. Slowly pull 22K over string wt. to 102K and see J toot shear off WLSRBP as expected. DECOMP LD one jt drill pipe and close rams. Pressure test to 2500 psi. Bleeding off rapidly through rams at surface. DECOMP Troubleshoot and rebuild Koomey air pump. DECOMP Pressure test well bore f/surface to WLSRBP at 3094'. Hold 2500 psi w/chart f/30 mins. Good test. Bleed off pressure. Monitor well f/flow. Well static. DECOMP RD test equipment. BD topdrive. DECOMP POH laying down Drill Pipe. DECOMP RIH wl15 stds. 5" drill pipe. DECOMP POH laying down 15 stds. of drill pipe. DECOMP Pull wear ring. RU and continue to test BOPs. 250 low pressure. 3500 high pressure. RREP DECOMP Made repairs to Koomey electric pump and rebuilt test pump. DECOMP PJSM. Continue and complete BOP test. RD test equipment. BD top drive and choke. OTHCMP RU to RIH w/2271' of 7" 26# L-80 BTC-M kill string w/9.59' muleshoed pup on bottom of string. OTHCMP Continue to RIH w/2271' of 7" 26# L-80 BTC-M kill string wl9.59' muleshoed pup on bottom of string. IR #2098270 submitted for pipeskate incident. OTHCMP land 7" casing hanger w/TWC installed and makeup checked at surface. Install 2 control line plugs and one ESP penetrator plug. PU wt. 75K, SO wt. 68K. RILDS. Pull landing jt. Pressure test TWC to 1000 psi f/below. OK. OTHCMP PJSM. RU and replace variable 3-1/2" x 5" lower rams w12-7/8" x 4". Replace rental variable 4-112" x 7" rams on top OTHCMP PJSM. ND BOP stack and hang back and secure, OTHCMP NU adapter and test to 5000 psi f/10 mins. OTHCMP NU tree/adapter and test to 5000 psi f/10 mins. OTHCMP Pull TWC w/lubricator. OTHCMP RU Little Red Hot Oil Svc and test lines. OTHCMP Heat diesel w/hot oil unit and reverse circulate 360 bbls. 80 deg. diesel for freeze protection down 7" X 13-3/8" annulus to muleshoe at and up 7" tubing and see clean diesel at surface. 18:30 - 21:00 2.50 BOPSU C OTHCMP Set BPV w/lubricator and test f/below w/Hot Oii unit to 1000 psi f15 min. 21:00 - 00:00 3.00 BOPSU C OTHCMP Clean pits and cuttings tank, remove auxilliary annulus valve f/tree and install flange. Secure tree. Blow down pits, break lines at interconnect. Secure well. Secure location. Annular presssure = 0 at 23:59. Release rig at midnight. Contact pad operator and advise intent to move rig away f/well. Printed: 12/27/2006 1:39:33 PM v Tree: CIW 7" 5M Wellhead: FMC Big Bore -400 Actual Orig. DF elev. = 64.4' Orig. Cellar elev. = 35.9' 20" 131.45 ppf, X-56 , 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. 13 3/8 68 ppf, L-80 BTC 2589` RA Tag 2812 7" Hanger/Packer 3039 7" Retrievabie bridge plug 309 9 5/$" 40 ppf, L-80 BTC 3221 7" csg. shoe & fish 4707 8 1 /2" Driller's TD 4748 7" Mule shoe pup end 2271 ` 95/8x7"Hngr top SV3 blank ESS 1-3 (150 -SV3} SV3 blank ESS 4-5 (150 -SV2) / SV2 blank ESS 6-7 (150 -SV2) / Blank ~ HESS 8 (150 -SV2) '~~\ Blank ESS 9 (150 -SV2) ~ Blank i EZI ~ \~ top SV1 blank ~ ESS 10-12 (150 - SV1) i top SV1 blank ~ ESS 13 (150 - 5V1) SV1 blank EZI(coal at top UG4) UG4A blank EZI Packer ~ ____-~ ESS 14 (230 -UG4) i Blank 7" Pipe Guideshoe DATE REV. BY COMMENTS 12/27/06 PGS Post RWO Operations shut-down 3039 3055 3300 3394 3515 3572 3582 3657 3672 3710 3748 3786 3843 3863 3959 4071 4201 4239 4268 4288 4593 4632 4670 4708 S-Pad Well 5-400 WSW APf N4: 50-029-23289 BP EXPLORAT{ON S~4RAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Ugnu Undefined Oil Pool, PBU 5-400 Sundry Number: 306-409 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2007 Encl. ~oS- (`~ f Sincerely /~ ~" ~~ STATE OF ALASKA ~~ ~~~~~~~ ALAS IL AND GAS CONSERVATION COMMIS'~ldN ~~~ Zeds APPLICATION FOR SUNDRY APPROVAL ~~3 ~ $ 20 AAC 25.280 Alaska Oii & Gas Cons. Commission 1. Type of Request: ^ Abandon ^ Suspend ®Operation Shutdown ^ Pertorate ^ Time Exterr®>~tllOfa~@ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number / ' BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 205-191 / 306-333 aS,O~iYD.t?,~ 3. Address: ^ Stratigraphic ®Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23289-00-00 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 S-400 Spacing Exception Required? ^ Yes ®No i 9. Property Designation: 10. KB Elevation (ft): y~ / 11. Field /Pool(s): ADL 028258 64.60 / Prudhoe Bay Field / Ugnu t2_ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4748 3948 4748 3948 3094 None asin nth Size MD TVD Burst Colla se Structural on ct r 10 ' 20" 10 ' 1 ' Surface 3221 13-318" x 9-5/8" 3221' 2771' 4930 2270 Intermedi to Prod ion Liner 1669' 7" 3039' - 4708' 2642' - 3913' 816 7020 Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Expandable screens: 3300' - 4670' 2826' - 3879' 7", 26# L-80 2271' Packers and SSSV Type: None Packers and SSSV MD (ft): N/A 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 26, 2006 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. l hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name Robert T' ck ~rG ,=.Z , ,try Title Senior Drilling Engineer Prepared By Name/Number: _ Signature ~, ~~ i ~~~ Phone 564-4166 Date 12-2~.Oci Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~~ L\ ` APPROVED BY ~ '~ A roved B TONER THE COMMISSION Date ! Form 10-403 Revised 06/2006 v ~/ ~ ~ `r ~,~3 ~, ~ ~ Submit In Duplicate ORIGINAL Page 1 of 1 Hubble, Terrie L From: Smith, Phil G (ASRC) Sent: Wednesday, December 27, 2006 1:41 PM To: Hubble, Terrie L Cc: Young, Jim Subject: RE: S-400 Re-Complete Attachments: S-400 Post rig actual.CNV Hi Terrie, Yes we must submit a 10-403 for operations shutdown. We expect to be back on the well in, say, September. AOGCC will also want a short synopsis of what happened (below) and a diagram (attached). Thanks, Phil Following the S-400 decompletion and fill clean-out a video log revealed no damage to the 7" expandable screens as expected. Instead the screens were found to be permeable to the ultra-fine sand that filled the production liner during start-up attempts. The plan to straddle off any damaged portions of the production liner was aborted in favor of an operations shut down to evaluate options for recompletion of the well. S-400 was left with a 7" retrievable bridge plug at 3094' (pressure tested to 2500 psi} and a 7" freeze protection string to 2271' MD. From: Hubble, Terrie L Sent: Wednesday, December 27, 2006 1:21 PM To: Smith, Phil G (ASRC) Subject: S-400 Re-Complete Hi Phil, Doesn't look to me like things went as planned for this well. Since we ran a killstring (again) I am hoping that you have been in contact with the AOGCC to see what they want us to file, paperwork wise. It appears to be an Operations Shutdown. What is the plan forward and the timing. Thanks. Terrie 12/27/2006 Tree: CIW 7" 5M Wellhead: FMC Big Bore ~-~oo Orig. DF elev. = 64.4' Actual Orig. Cellar elev. = 35.9' 20" 131.45 ppf, X-56 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. 13 3/8 68 ppf, L-80 BTC 2589` RA Tag 2812 7" Hanger/Packer 3039 7" Retrievable bridge plug 309 9 5/8" 40 ppf, L-80 BTC 3221 7" csg. shoe 4707 8 1/2" Driller's TD 4748 7" Mule shoe pup end 2271 ` 9 5/8 x 7" Hngr top SV3 blank ESS 1-3 (150 -SV3) SV3 blank ESS 4-5 (150 -SV2) / SV2 blank ESS 6-7 (150 -SV2) / Blank ~ 1 ESS 8 (150 -SV2) `~\ Blank ESS 9 (150 -SV2) ~ Blank i EZI \~ top SV1 blank ~ ESS 10-12 (150 - SV1) i top SV1 blank ~ ESS 13 (150 - SV1) SV1 blank EZI(coal at top UG4) UG4A blank EZI Packer ~ `~ ESS 14 (230 -UG4) i Blank 7" Pipe Guideshoe DATE EV. BY COMMENTS 12/27/06 PGS Post RWO Operations shut-down 3039 3055 3300 3394 3515 3572 3582 3657 3672 3710 3748 3786 3843 3863 3959 4071 4201 4239 4268 4288 4593 4632 4670 4708 S-Pad Well S-400 WSW API NO: 50-029-23289 BP EXPLORATION FRANK H. MURKOWSKf, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska} Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Ugnu Undefined Water Source Pool, PBU 5-400 Sundry Number: 306-333 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2006 Encl. ~~5 -r~ ~ 1. Type Of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension Anchorage ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To D 'll Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 205-191 3. Address: ^ Stratigraphic ®Service ~ 6. API Number: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23289-00-00 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 S-400 / Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028258 64.60 Prudhoe Bay Field 1 Ugnu 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4748 3948 4748 3948 None None asin Len h Size MD TVD B rst Colla se Structural nd ct r 1 5' 2 1 5' 105' Surface 3221 13-3/8" x 9-5/8" 3221' 2771' 4930 2270 Intermediate Prod cti n Liner 1669' 7" 3039' - 4708' 2642' - 3913' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Expandable Screens: 3300' - 4670' 2826' - 3879' 7", 26# L-80 2884' Packers and SSSV Type: None Packers and SSSV MD (ft): N/A 13. Attachments: 14. Well Class after proposed work: /~ ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Seroice ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 15 2006 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date. ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By NamelNumber: Signature ~,~ ; ~ ~ ~ -- Phone 564-4166 Date ~~ ~ Terrie Hubble, 564-4628 Commission Use Ortl Sundry Number: ,,,,, Conditions of approval: Notify Commission so that a representative may witness ~/ ^ Plug Integrity LJ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ ,s 5 ~" ~~ ~ C ~ ~CDD ~ Sic, ~ ~~. i i c;? ~ 2006 Subsequent Form Required: 1(~ - O APPROVED BY /0~~ ,~Ob A roved B C MMISS ER THE COMMISSION Date Form 10-403 Revised 06/2006 Submit In Duplicate `~ 1~'Pe Io/~o,6 ~"' 3 Zooms ,, ~ ti STATE OF ALASKA ' y ~ ~ E ~ E I VE '~ i ~° s ~ ~ ALASKA OIL AND OAS CONSERVATfON COM~O~ APPLICATION FOR SUNDRY APPROVAL SEP 2 8 2oa6 20 AAC 25.280 Alaska ' sion ORIGINAL To: From Subject: Reference: Winton Aubert - AOGCC Phil Smith - BPXA GPB Rotary Drilling S-400 Application for Sundry Approval -Rig Workover API # 50-029-23289-00 Date: September 27, 2006 Approval is requested for the proposed workover of Prince Creek water source well S-400. The workover / is required to replace the ESP which sanded up immediately after start up. The sand production is suspected to be from a failed expandable screen. The workover will include setting a straddle screen across the failed section before re-completing with a new ESP. The workover is currently scheduled for Nabors rig 7ES, beginning around November 15, 2006. This well may move up on the schedule depending on production priorities. No further pre-rig work is required. Current Condition: / Sanded up production liner/screens, presumably from TD to the ESP. / Freeze protected tubing and IA with 490 bbls diesel pumped down IA, up tubing 5/2/06 / BPV Set in tubing hanger Rig Operations: 1. MI / RU Nabors rig 7ES 2. Pull BPV, circulate out diesel freeze rotection and displace the well to 8.8 ppg brine. 3. Set TWC and test. Nipple down e. 4. Nipple up and test BOPE to 3, 0~. Pull TWC. 5. R/U. Pull 7" tubing and ESP. a. If tubing does not pull free from produced sands RU wireline and freepoint /cut tubing; recover tubing and fish the ESP. b. If ESP cannot be recovered, s `pen the well with a 7" EZ-Drill set 50' above ESS #1 6. RIH with 6" mill on and boot baskets, nd non-ported float. Circulate/cleanout sand with high-vis sweeps to PBTD at 4707' MD. 7. Bullhead 1.5 well volumes of clean, filtered brine. 8. RU Halliburton video log with pump-in sub. Log production liner interval, bullheading clean brine as necessary. 9. Set FB-1 packer in blank pipe below ESS #13. 10. Run screens and upper packer. Stab into lower FB-1 to straddle ESS #13. Set upper packer. 11. Set 7" R e able bridge plug in liner top above uppermost screen and test to 3500 psi. ~ 12. Set 13 /8" torm packer below wellhead. ND BOP and replace casing spool with modified spool (to allow -to passage). 13. NU a est BOPs. 14. Recover storm packer and 7" bridge plug. LDDP. 15. Pull wear ring. R/U and run ESP and Y-tool, Phoenix gauge and 7", 26#, L-80 completion tubing. Land the tubing RILDS. 16. Set a TWC and test to 1000 psi ~ 17. Nipple down the ROPE. Nipple up the tree and test to 5,000psi. 18. Reverse circulate diesel to freeze protect the entire annulus and -2,100' of tubing. Secure the well. 19. Rig down and move off. • S-400 Application for Sundry • Post-Rig Work: 1. Install well house and instrumentation. 2. Pull BPV. 3. POP well to test unit until cleaned up. Phil Smith Operations Drilling Engineer 564-4897 S-400 Application for Sundry Tree: CIW 7" 5M Wellhead: FMC Big Bore 20" 131.45 ppf, X-56 ` 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. -IES Symphony gauge v/ESP cable 2480 ~entrilift 57 stage HC27000 i75 ESP, 8.75" OD,` 791 ~entrilift HST34B EHL PFS peal section 2822 HES "R" Nipple 5.625" ID 2509` 13 3/8 68 ppf, L-80 BTC 2589` RA Tag 2812 7" Hanger/Packer 3039 9 5/8" 40 ppf, L-80 BTC 3221 7" csg. shoe 8 1 /2" Driller's TD 4707 4748 ~entrilift Series,HMIHE 1000 hp series725motor 4160v./154amp, 2859 ~entrilift PumpMate 2884` 95/8x7"Hngr top SV3 blank ESS 1-3 (150 -SV3) / SV3 blank ESS 4-5 (150 -SV2) / SV2 blank ESS 6-7 (150 -SV2) / Blank ESS 8 (150 -SV2) Blank ---~--- ESS 9 (150 -SV2) Blank EZI top SV1 blank ~'-- ESS 10-12 (150 - SV1) top SV1 blank ESS 13 (150 - SV1) SV1 blank EZI(coal at top UG4) UG4A blank EZI Packer ~.----- ESS 14 (230 -UG4) Blank 7" Pipe Guideshoe DATE REV. BY COMMENTS 116/06 PGS Proposed ESS completion (WP-07)) 1/27/06 LV Actual 3039 3055 3300 3394 3515 3572 3582 3657 3672 3710 3748 3786 3843 3863 3959 4071 4201 4239 4268 428$ 4593 4632 4670 4708 S-Pad W@~~ $-400 WJ'W API NO: 50-029-23289 1 9/27/06 ~ PGS (Corrections ~ BP EXPLORATION (AK) ~ Orig. DF elev. = 64.4' S ~O 0 Orig. Cellar elev. = 35.9' Tree: CIW 7" 5M Wellhead: FMC Biq Bore ~ ~O 20" 131.45 ppf, X-56 I 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. HES "R" Nipple 5.625" ID 2509` 13 3/8 68 ppf, L-80 BTC 2589` RA Tag 2812 7" Hanger/Packer 3039 9 5/8" 40 ppf, L-80 BTC 3221 7" x 5" Baker Premier packer 4195` Baker Wirewrap screen straddle 4200` 7" x 5" Baker FB-1 packer 4245` 7" csg. shoe 4707 8 1/2" Driller's TD 4748 0 Proposed Orig. DF elev. = 64.4' Orig. Cellar elev. = 35.9' i i i i i DES Symphony gauge nr/ESP cable 2200 Fenix Auto Y-Tool " " OD, 2.992 ID ?5 ~trilift 48 stage HC27000 i ESP, 6.75" OD,` ~trilift HST34B EHL PFS tl sectior ~trilift Series,HMIHE )0 hp 7.25" OD motor 60v./154amp, ~ntrilift PumpMate 2575` 3-1/2" WLEG, 2.813" ID 2600` 9 5/8 x 7" Hngr top SV3 blank ESS 1-3 (150 -SV3) / SV3 blank ESS 4-5 (150 -SV2) / SV2 blank ESS 6-7 (150 -SV2) / Blank ESS 8 (150 -SV2) \ Blank ESS 9 (150 -SV2) i Blank i EZI \ top SV1 blank ~ ESS 10-12 (150 - SV1) top SV1 blank ESS 13 (150 - SV1) SV1 blank EZI(coal at top UG4) UG4A blank EZI Packer i ~- ESS 14 (230 -UG4) i Blank 7" Pipe Guideshoe DATE REV. BY COMMENTS 9/27/06 PGS Proposed RWO completion 3039 3055 3300 3394 3515 3572 3582 3657 3672 3710 3748 3786 3843 3863 3959 4071 4201 4239 4268 4288 4593 4632 4670 4708 S-Pad Well S-400 WSW API NO: 50-029-23289 BP EXPLORATION ~..~~ Y STATE OF ALASKA ALASK IL AND GAS CONSERVATION COM SION MAR A 9 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LO~~g$~~ ~~ ~ ~~~ L`alts Corrmissian Ant:har~ge 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned zoAACZS.~os ^ GINJ ^ WINJ ^ WDSPL No. of Completions ^ Suspended ^ WAG zoAACZS.iio One Other Water Source 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1/28/2006 12. Permit to Drill Number 205-191 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/11/2006 13. API Number 50-029-23289-00-00 4a. Location of Well (Governmental Section): Surface: " ' 7. Date T.D. Reached 1/19/2006 14. Well Name and Number: PBU S-400 4122 FSL, 4504 FEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 2844' FSL, 966' FEL, SEC. 34, T12N, R12E, UM g. KB Elevation (ff): 64.60 15. Field /Pool(s): Prudhoe Bay Field / Ugnu Total Depth: 2722' FSL, 1113' FEL, SEC. 34, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) 4748 + 3948 Ft 4b. Location of Well (State Base Plane Coordinates): 61 Surface: x- 8930 y- 5980325 Zone- ASP4 10. Total Depth (MD+TVD) 4748 + 3948 Ft 16. Property Designation: ADL 028258 _ _ TPI: x- 617210_ y- 5979021 Zone- ASP4 Total Depth: x- 617065 Y- 5978897 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: --~---- ----------- ----"----~------ - ----------~ - 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD , GR , NEU ,DEN , RES ,CAL ,GYRO , USIT 2. ASING, LINER AND EMENTING RECORD CASING ETTIN(3 EPTH MD ETTINC3 EPTH TVD HOLE ANT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 131.5# X-56 Surface 105' Surface 105' Driven 13-3/8" x 9-5/8" 68# x 47# L-80 Surface 3221' Surface 2771' 16" 731 sx Arcticset Lite, 648 sx 'G' 7" 29# L-80 3039' 4708' 2642' 3913' 8-1/2" Uncemented Ex andable Screens 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 7" Expandable Screens 7", 26#, L-80 2884' MD TVD MD TVD 3300' - 3394' 2826' - 2891' 3515' - 3572' 2973' -3011' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 3582' - 3657' 3017' - 3069' 3672' - 3710' 3079' - 3106' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 3748' - 3786' 3133' - 3160' 2000' Freeze Protected with 280 Bbls of Diesel 3959' - 4072' 3290' - 3378' 4201' - 4239' 3482' - 3513' 4632' - 4670' 3846' - 3879' 26. PRODUCTION TEST Date First Production: Not On Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PfeSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit-core: chips; if none, state "none". None ~ ~~2~'~~.""`"~ ~l ~',^~. ~ BFI: MA~t ~ - ?~ ~ ~ b/`G ~ Form 10-407 Revised 12/200 NTINUED ON REVERSE SIDE ~R1G11~ .. 2f3. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". None Top of Ugnu (UG4) 4371' 3623' UG4A 4428' 3671' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman itle Technical Assistant Date ~~' ~~ -(~ PBU S-400 205-191 Prepared By Name/Number Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. DriOinq Engineer: Phil Smith, 564-4897 INSTRUCTIONS GeNepaL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item i, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: S-400 Common Name: S-400 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW ~ Surface Pressure ~ Leak Off Pressure (BHP) EMW 1/18/2006 FIT I 3,246.0 (ft) 2,789.0 (ft) 8.90 (ppg) 250 (psi) I 1,539 (psi) 10.63 (ppg) Printed: 1/30/2006 11:21:07 AM BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Common W Event Nam Contractor Rig Name: Date ~ i Name: ell Name: e: Name: From - To ~ S-400 S-400 DRILL+C NABOB NABOB Hours ~~~~ OMPLE S ALASK S 7ES Task ~ TE A DRI Code LING NPT Start I Rig Rig Phase ~ Spud Date: 1/11/2006 : 1/9/2006 End: Release: Number: 7ES Description of Operations 1/10/2006 00:00 - 04:30 4.50 MOB P PRE Move Pits complex, Camp and shop to S-Pad. 04:30 - 05:00 0.50 MOB P PRE Move Sub off of Z-46A and stage on pad to lay down derrick. 05:00 - 05:30 0.50 MOB P PRE PJSM on laying down the derrick. 05:30 - 06:00 0.50 MOB P PRE Lay down the derrick and secure lines for move to S-Pad. 06:00 - 14:00 8.00 MOB P PRE Move Sub complex from Z-Pad to S-Pad. 14:00 - 15:00 1.00 MOB P PRE Lay rig mats & herculite liner around S-400 conductor. Stage well head equipment in cellar area. Suspend 20" Hydril and tree in cellar. 15:00 - 15:30 0.50 RIGU P PRE Spot Sub complex over S-400. 15:30 - 17:00 1.50 RIGU P PRE Set rig mats and spot pits complex. 17:00 - 22:00 5.00 RIGU P PRE Hook up service lines to pits complex. Inspect derrick ready to raise, PJSM, raise and pin derrick. Bridle down and pin blocks to top drive. Raise and pin cattle chute. Berm cellar area. Taking on spud mud to pits at 20:00 Hrs. Accept rig to S-400 @ 20:00 Hrs. 22:00 - 00:00 2.00 RIGU P PRE NU 20" diverter system and riser. 1/11/2006 00:00 - 05:00 5.00 RIGU P PRE NU Diverter system and 20" riser. Clean out snow and Ice from 16" diverter vent line. Change out top drive quill to 5" service. Spot cutting tank. Pre Spud Meeting Held With Crew and Service Co. Personnel at Tour Change. 05:00 - 08:30 3.50 RIGU P PRE Load pipe shed with 5" drill pipe, Steam and SLM same. 08:30 - 13:00 4.50 RIGU P PRE PU 84 Jts 5" drill pipe 1x1 building stands and rack back same. 13:00 - 14:00 1.00 RIGU P PRE Load pipe shed with 17 Jts. 5" HWDP, & BHA #1, Steam and SLM same. Pre Spud Meeting Held With Crew and Service Co. Personnel at Tour Change. 14:00 - 15:00 1.00 RIGU P PRE PU 5" HWDP 1x1 and rack back same. 15:00 - 15:30 0.50 BOPSU P PRE Function test diverter system. Witness of test waived by Chuck Scheve AOGCC. Test Witness by Duncan Ferguson (WSL) and Larry Wurdeman (Toolpusher). 15:30 - 16:30 1.00 DRILL P SURF MU BHA #1 16" bit, 2.12 deg 9-5/8" motor, XO. 16:30 - 17:00 0.50 DRILL P SURF Fill hole and check cirulating system for leaks. 17:00 - 18:30 1.50 DRILL P SURF Spud well and drill from 105' to 213'. 500 gpm 400 psi. 18:30 - 19:00 0.50 DRILL P SURF POH 19:00 - 21:30 2.50 DRILL P SURF MU Remainder BHA #1 Bit ! 9-5/8" motor / NM LDC / NM STB / MWD/UBHO/NMSTB/NMLDC/NMXO/NMDClNM STB / NM DC /FLT Sub /JAR. 21:30 - 22:15 0.75 DRILL P SURF Cut & Slip 129' Drilling line, while moblizing Super Sucker trucks stuck behind Doyon 16 rig move. 22:15 - 22:30 0.25 DRILL P SURF RIH to 213' 22:30 - 00:00 1.50 DRILL P SURF Drill from 213' to 264' w/ 500 gpm, 514 psi off bttm, 600 psi on bttm, 15k wob, 40 rpm, Up wt. 60k, Dn wt. 60k, Rt wt. 60k, TO 1 K. AST= .29 hrs, ART= .98 hrs, ADT= 1.27 hrs. 1!12/2006 00:00 - 01:00 1.00 DRILL N SFAL SURF Lower well control valve connection on top drive broke while making a connection. Remove clamp, Torque connection, re-dress clamp with new dies and re-install same. 01:00 - 02:00 1.00 DRILL P SURF PJSM & RU Halliburton E-Line unit and run gyro survey at 264' due to magnetic interference. 02:00 - 05:00 3.00 DRILL P SURF Drill from 264' to 443' w/ 500 gpm, 600 psi off bttm, 800 psi on bttm, 15k wob, 40 rpm, Up wt. 63k, Dn wt. 63k, Rt wt. 63k, TO Printed: 1!30/2006 11:21:13 AM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: DRILL+COMPLETE Start: 1/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To ~ Hours I Task Code !; NPT Phase Description of Operations 1/12/2006 02:00 - 05:00 3.00 DRILL P SURF 1 K. 05:00 - 05:30 0.50 DRILL P SURF Circulate & Run Gyro Survey. 05:30 - 08:45 3.25 DRILL P SURF Directionally Drill from 443' to 623' w/ 500 gpm, 600 psi off bttm, 800 psi on bttm, 15k wob, 40 rpm, Up wt. 63k, Dn wt. 63k, Rt wt. 63k, TO 1 K. 08:45 - 09:00 0.25 DRILL P SURF RD Halliburton E-Line unit, 09:00 - 12:00 3.00 DRILL P SURF Directionally Drill from 623' to 760' w/ 500 gpm, 600 psi off bttm, 800 psi on bttm, 15k wob, 40 rpm, Up wt. 75k, Dn wt. 70k, Rt wt. 75k, TO 2-4K on bttm, 2-3k off bttm. AST= 4.5 hrs, ART= 1.62 hrs, ADT= 6.12 hrs. 12:00 - 00:00 12.00 DRILL P SURF Directionally Drill from 760' to 1468' w/ 600 gpm, 1 t00 psi off bttm, 1400 psi on bttm, 15-35k wob, 40 rpm, Up wt. 85k, Dn wt. 75k, Rt wt. 83k, TO 7K on bttm, 3k off bttm. i AST= 4.25 hrs, ART= 4.73 hrs, ADT= 8.98 hrs. 1/13/2006 100:00 - 03:00 f 3.001 DRILL I P I I SURF 03:00 - 04:00 1.00 DRILL P SURF 04:00 - 05:30 i.50 DRILL P SURF 05:30 - 07:30 2.00 DRILL P SURF 07:30 - 08:00 0.50 DRILL P SURF 08:00 - 08:30 0.50 DRILL P SURF 08:30 - 09:30 I 1.001 DRILL I P I I SURF 10:00 - 10:30 0.50 DRILL P SURF 10:30 - 11:00 0.50 DRILL P SURF 11:00 - 12:00 1.00 DRILL P SURF 12:00 - 00:00 12.00 DRILL P SURF 1/14!2006 X00:00-01:30 ~ 1.50i DRILL ~P ~ SURF 01:30-02:001 0.501 DRILL IN ISFAL ISURF 02:00 - 08:30 6.50 DRILL P 08:30 - 10:00 1.50 DRILL P 10:00 - 12:00 2.00 DRILL P 12:00 - 13:00 1.00 DRILL P 13:00 - 15:00 2.00 DRILL P SURF SURF SURF SURF SURF Directionally Drill from 1468' to 1663' w/ 600 gpm, 1170 psi off bttm, 1540 psi on bttm, 45k wob, 40 rpm, Up wt. 95k, Dn wt. 80k, Rt wt. 85k, TO 8.5K on bttm, 3.5k off bttm. AST= 1.38 hrs, ART= 1.27 hrs, ADT= 2.65 hrs. Circulate 2 times bottoms up. Monitor well. Static. POH for bit. POH w/ BHA #1, Stand back HWDP & DC's, LD UBHO sub. & Bit #1 Clean and clear rig floor. MU BHA #2, Bit didn't appear to make up properly, Break out and inspect threads. Threads galled on two sides of bit connection Mobilize new bit and XO from baker. Adjust Motor bend to 1.83 deg. Service rig and Top Drive. MU Bit #2 & XO. & Orient BHA. RIH, MU Top Drive and wash last stand to bottom at 1663' Directionally Drill from 1663' to 2503' w/ 650 gpm, 1430 psi off bttm, 1750 psi on bttm, 45k wob, 50 rpm, Up wt. 110k, Dn wt. 80k, Rt wt. 90k, TO 8.5K on bttm, 5k off bttm. AST= 4.7 hrs, ART= 3.98 hrs, ADT= 8.68 hrs. Directionally Drill from 2503' to 2597' w/ 650 gpm, 1430 psi off bttm, 1750 psi on bttm, 45k wob, 50 rpm, Up wt. 110k, Dn wt. 80k, Rt wt. 90k, TO 8.5K on bttm, 5k off bttm. Upper well control valve connection on top drive broke while making a connection. Remove clamp, Torque connection, re-install clamp. Directionally Drill from 2597' to 3226' w/ 660 gpm, 1600 psi off bttm, 1860 psi on bttm, 20k wob, 80 rpm, Up wt. 125k, Dn wt. 90k, Rt wt. 100k, TO 10K on bttm, 6k off bttm. AST= 1.72 hrs, ART= 2.62 hrs, ADT= 4.34 hrs. Circulate 2 times bottoms until hole cleaned up Mud weight 9.4 ppg in and out. Short Trip / POH to 1624', No problems on trip out RIH with no problems and no fill on bottom at 3226' Circulate & condition mud ~ 660 gpm, 1475 psi. 80 rpm. 4k Printed: 1/30/2006 11:21:13 AM BP EXPLORATION Operations Summary Report Page 3 of 10 Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: DRILL+COMPLETE Start: 7/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES Date .From - To Hours ' Task ~ Code ~ NPT Phase 1/14/2006 13:00 - 15:00 2.00 DRILL P SURF 15:00 - 17:00 2.00 DRILL P SURF 17:00 - 19:30 2.50 DRILL P SURF 20:00 -210:30 10.50 CASE P (SURF 21:30 - 22:30 1.00 CASE P 22:30 - 23:30 I 1.001 CASE I P I (SURF 23:30 - 00:00 0.50 CASE P SURF 1/15/2006 00:00 - 00:30 0.50 CASE P SURF 00:30 - 03:30 3.00 CASE P SURF 03:30 - 06:30 , 3.00 CASE N WAIT SURF 06:30 - 07:30 1.00 ~ CASE ~ N ~ WAIT ~ SURF 07:30 - 10:30 ( 3.00 CASE P SURF 10:30 - 11:00 II 0.50 CASE P SURF 11:00 - 11:30 I 0.50 CEMT P SURF 11:30 - 14:30 I 3.001 CEMT I P I I SURF 14:30 - 17:30 ~ 3.00 ~ CEMT ~ P ~ ~ SURF 17:30 - 20:00 I 2.501 CEMT I P I I SURF 20:00 - 00:00 4.00 DIVRTR P SURF 1/16/2006 00:00 - 02:30 2.50 WHSUR N SFAL SURF 02:30 - 03:30 I 1.001 WHSUR I P I I SURF 03:30-07:00 ~ 3.50 BOPSUF~P ~ SURF 07:00 - 08:00 I 1.001 BOPSUR P I I SURF 08:00 - 12:30 I 4.501 BOPSUR P i !SURF Description of Operations Tq. Mud weight 9.4 ppg in and out. POH with no problems to BHA #2 LD BHA #2. LD 3x NM STB's / 2x NM LDC /Flt Sub / MWD Motor / XO /Bit. Clean and Clear rig floor of vendors tools. Make dummy landing run with 13-3/8" casing hanger RU 9-5/8" casing tools. PJSM - MU 9-5/8" Float equipment. BakerLok up to float collar. Fill pipe and check floats. OK. Run 9-5/8" casing, Install bowspring centrilizers frist 12 jts ran. Run a total 15 jts. RD 9-5/8" casing equipment. RU 13-3/8" casing equipment. MU 9-518 X 13-3/8" XO Jt. Run 13-3/8" Casing. to 1733' Work casing string while consulting with production engineer on 13-3/8" casing depth for ESP. Mobilize tools to pull casing. PU handling equipment to rig floor for laying down casing. PJSM and ready rig and equipment to LD Casing. Engineer confirmed no problem with 13-3/8" casing setting depth. Cont' to RIH with 13-3/8" casing with no problems. PU landing joint & hanger, MU same and land casing. RD Franks Fill Up Tooi, Blow down top drive, MU cement head and circulating lines. Break circulation and stage pump rate up to 10 bpm, 600 psi. Adjust mud properties to 81 Vis. 22 YP. Hold PJSM for cementing while conditioning mud. Pump 5 bbls water & test lines to 3000 psi. 80 bbls Mud Push II ~ 10.5 ppg. Drop bottom plug & pump 585 bbls 10.7 ppg Lead Arctic Set Lite II cement w/ red dye. Pump 138 bbls 15.8 ppg Class G Tail cement. Drop top plug & wash up with 3 bbls water followed by 427 bbls mud with rig pumps at 10 bpm. Bump plug W/ 500 psi over to 1500 psi. and hold for 5 min. Bleed off pressure & check floats -floats holding. During cement job maintained full returns throughout job. Cement back to surface after 322 bbls into displacement pumped. 108 bbls. 10.7 ppg cement returns back to surface. C!P C 17:30 hrs. Rig down casing equipment. Drain 20 riser. Flush riser, 20" Hydril, and flow line. Back out and lay down landing joint. ND diverter system. One of the four set screws holding the ACME threaded lock nut seized while removing them, locking the ring in place on the 13-5/8" mandrel hanger. Mobilize welder and cut ACME threaded lock ring away from 13-3/8" mandrel hanger and replace with new. Set screw was found to be bent. MU FMC Gen. 5 speed head. Test metal to metal seal to 1000 psi. for 10 min. Heid. Nipple up BOPE. Install pitcher nipple, turnbuckels and secondary working valve on annulus. MU Test joint and install test plug, RU test equipment and fill BOP with water. Test BOPE as per BP and AOGCC regulations. 250 psi Low, 3500 psi and record on chart. W ittness of test wavied by John Printed: 1/30/2006 11:21:13 AM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: DRILL+COMPLETE Start: 1/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES ~ Date I From - To -Hours Task Code NPT Phase Description of Operations 1/16/2006 08:00 - 12:30 4.50 BOPSU P SURF Crisp, AOGCC. Test wittnessed by Duncan Ferguson (WSL), and Larry Wurdeman (Toolpusher). 12:30 - 14:00 1.50 BOPSU P SURF Rig down test equipment, install wear bushing. 14:00 - 14:30 0.50 BOPSU P SURF Service rig and top drive. Blow down lines. Found kelly hose and standpipe to be obstructed with an ice plug. 14:30 - 00:00 9.50 BOPSU N SFAL SURF PJSM and start thawing ice out of standpipe and kelly hose. Remove kelly hose from derrick and lower to rig floor and snake steam hose into same to clear ice plug. Re-install keily hose and blow air through mud line to verify obstruction had been cleared. Attach kelly hose to top drive. Clear rig floor of tools and equipment. 1/17/2006 00:00 - 00:30 0.50 BOPSU N SFAL SURF Perform derrick inspection at tour change to confirm derrick was clear of any tools or objects after thawing operations. 00:30 - 01:30 1.00 DRILL P PROD1 PJSM - MU BHA #3. 01:30 - 04:00 2.50 DRILL P PROD1 RIH picking up 5" drill pipe 1x1 from pipe shed to 2316', and fill pipe 04:00 - 04:30 0.50 DRILL P PROD1 Cont' RIH with drill pipe from derrick to 3040' 04:30 - 05:45 1.25 DRILL P PRODi MU top drive, break circulation and wash last stand down and tag cement at 3114' & CBU 05:45 - 06:30 0.75 BOPSU P PROD1 RU and test casing to 3400 psi and record on chart for 30 min. 06:30 - 08:15 1.75 DRILL P PROD1 Drill float collar and shoe and drill cement + 5' of new hole to 3231. 08:15 - 09:45 1.50 DRILL P PROD1 Circulate and condition mud while rotating and reciprocating. 09:45 - 11:30 1.75 DRILL P PROD1 POH wlBHA #3. 11:30 - 12:00 0.50 DRILL P PROD1 LD BHA #3. 12:00 - 13:00 1.00 DRILL P PROD1 PU Cleanout bit/mill/scraper BHA #4. 13:00 - 15:30 2.50 DRILL P PROD1 RIH to 3114', make up top drive and establish circulation. 15:30 - 17:30 2.00 DRILL P PROD1 RIH cleaning out casing, rotate scraper f/scraper depth 2940' to 3057' (bit depth 3114' to 3231'), 80 rpm, 7K tq., 550 gpm, 1000 psi. There was no torque or WOB when reaming the milts and scraper. 17:30 - 18:00 0.50 DRILL P PROD1 Service rig and top drive. Find top drive blower motor bearing noise, send rig electrician to inspect. Bearings bad in motor. 18:00 - 18:30 0.50 DRILL P PROD1 POH and place bit at 2592', just below 13-3/8" x 9-5/8" transition area. 18:30 - 19:30 1.00 DRILL P PROD1 Circulate, 700 gpm, 1400 psi., rotate 80 rpm to cleanout transition area 13-3/8" x 9-5/8". 19:30 - 22:30 3.00 DRILL N RREP PROD1 Changeout topdrive blower motor. 22:30 - 23:30 1.00 DRILL P PROD1 POH to BHA. 23:30 - 00:00 0.50 DRILL P PRODi LD BHA # 4. No debris found in boot baskets. No debris on ditch magnets. 1/18/2006 00:00 - 00:30 0.50 DRILL P PRODi LD BHA and break bit. 00:30 - 01:00 0.50 DRILL P PRODi Service rig and top drive unit. 01:00 - 03:30 2.50 DRILL P PROD1 PJSM w/Schlumberger and all hands for handling nukes. PU BHA #5 w/MXL-C1 biU near bit stabilizer/ XO/ARC! MW D/ ~ ADN/ NM spiral DC/ NM string stabilizer/ NM spiral DC/ ~ saver-float sub/ Hyd. jars/ 17 jnts. HW DP RIH and load nukes. Shallow test MWD. 03:30 - 04:45 1.25 DRILL P PRODi RIH wash last stand down through 9-5/8" shoe to 3231'. 04:45 - 06:30 i.75 DRILL P PROD1 Circulate bottoms up w/50 bbl sweep. Displace well to 8.9 ppg Flo-Pro NT. 06:30 - 07:00 0.50 DRILL P PROD1 Drill to 3236'. Printed: 1/30/2006 11:21:13 AM BP EXPLORATfON Operations Summary Report Page 5 of 10 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To S-400 S-400 DRILL+C NABOB NABOB Hours , OMPLE S ALASK S 7ES Task TE A DRI Code T LING NPT _ Start I Rig Rig Phase Spud Date: 1/11/2006 : 1/9/2006 End: Release: Number: 7ES Description of Operations 1/18/2006 07:00 - 08:15 1.25 DRILL P - - PRODi - - - - -- -_ Blowdown topdrive and RU for FIT to 10.6 ppg EMW w/8.9 ppg mud, 3246' MD, 2789' TVD. 08:15 - 12:30 4.25 DRILL P PRODi Drill fl3236' to 3580' MD/3017' TVD, gpm 450, psi on 890, psi off 860, rpm 120, tq. on 5-9K, tq. off 5-6K, Up wt. 125K, SO wt. 95K, Rot wt. 100K. Building angle to rapidly w/current BHA configuration, consult w/ town engineering/geo team. 12:30 - 13:00 0.50 DRILL P PROD1 POH for BHA change to 3360', tight hole and swabbing.. Mud wt. 8.8 in and out. 13:00 - 15:30 2.50 DRILL P PROD1 RIH working pipe to 3430'. MU topdrive and backream up to 3360'. 80 rpm, 6K tq., 125 gpm, 275 psi. Packed off and torqued up. Unable to pump or rotate. Worked string and jarred down. 15:30 - 16:30 1.00 DRILL P PROD1 Free string and backream f/3360' to 9-5/8" shoe at 3221'. 100 rpm, 5-6K tq., 125 gpm, 250 psi. 16:30 - 17:00 0.50 DRILL P PROD1 POH to 13-3/8" x 9-5/8" transition point. 17:00 - 18:00 1.00 DRILL P PROD1 Circulate at 700 gpm, 1600 psi, 80 rpm, 4K tq. Pump dry job and blow down topdrive. 18:00 - 19:00 1.00 DRILL P PRODi POH to BHA. PJSM w/Schlumberger and all hands on nuke source removal. 19:00 - 20:00 1.00 DRILL P PROD1 Remove source, POH and LD BHA # 5. 20:00 - 20:30 0.50 DRILL P PROD1 MU BHA # 6. 20:30 - 21:30 1.00 DRILL P PROD1 Download MW D. 21:30 - 22:00 0.50 DRILL P PROD1 PJSM w/all hands and Schlumberger and load source. 22:00 - 23:30 1.50 DRILL P PROD1 RIH to 3310' and encounter tight hole. 23:30 - 00:00 0.50 DRILL P PROD1 MU topdrive and ream from 3300' to 3350'. 40 rpm, 6K tq., 300 gpm, 565 psi, Up wt. 120K, SO wt. 80 K, Rot wt. 100K. ADT = 3.12 for 24 hrs. Cum footage for 24 hrs = 354'. ROP for 24 hrs = 113'/hr. 1/19/2006 00:00 - 00:30 0.50 DRILL P PRODi RIH washing down to 3580'. 00:30 - 05:00 4.50 DRILL P PRODi Drill f/3580' to 3907' gpm 450, psi on 1132, psi off 950, rpm 120, tq. on 5-7K, tq. off 5K, Up wt. 130K, SO wt. 100K, Rot wt. 105K. Per DD 8HA #6 dropping 2.5 deg/100`. Consult w/town/asset engineer. Drill ahead w/current BHA. ECDs calcualated = 10.11 ppg, ECDs actual = 10.40 ppg. 05:00 - 06:00 1.00 DRILL P PROD1 Noted increases in ECDs and pump pressure. ECD actuals climbed to 11.2 ppg. Stopped drilling to circulate and pump 40 bbl. hi-vis sweep to lower ECDs. Continued drilling. 06:00 - 18:00 12.00 DRILL P PROD1 Drill (/3907' to 4748' MD, 3949' TVD. TD well. Gpm 450, psi on 1120, psi off 1040, rpm 120, tq. on 7-8K, tq. off 7K, Up wt. 160K, SO wt. 100K, Rot wt. 120K. ECDs calcualated = 10.44 ppg, ECDs actual = 10.71 ppg. Dropping angle at 1.5 deg./100'. 18:00 - 19:30 1.50 DRILL P PRODi Circulate two bottoms up. 450 gpm, 1000 psi, 120 rpm, 7K tq. 19:30 - 20:00 0.50 DRILL P PROD1 POH f/4748' to 4580'. Overpull to 35K. 20:00 - 00:00 4.00 DRILL P PRODi MU topdrive and backream f/4580' to 3727'. 100 gpm, 250 psi, 40 rpm, 6-SK tq. Packing off and swabbing when pulling. High torque occasionally. Could not RIH without rotation and pumps. Tight hole. Clay pancakes, sand and shale across shakers steadily. ADT for 24 hrs. = 12.64'. Footage = 1168. Time drilling. 1/20/2006 00:00 - 01:30 1.50 DRILL P PROD1 Backream (/3727' to 9-5/8" shoe at 3221'. Swabbing and Printed: 1/30/2006 11:21:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 6 of 10 S-400 S-400 Spud Date: 1 /11 /2006 DRILL+COMPLETE Start: 1/9/2006 End: NABOBS ALASKA DRILLING I Rig Release: NABOBS 7ES Rig Number: 7ES Date I From - To ~~ Hours I Task i Code'~~ NPT 1/20/2006 00:00 - 01:30 1.50 DRILL P 01:30 - 03:00 1.50 DRILL P 03:00 - 05:00 I 2.001 DRILL I P 05:00 - 05:30 ~ 0.50 ~ EVAL ~ P 05:30 - 13:30 ~ 8.00 ~ EVAL ~ P 13:30 - 14:30 I 1.001 EVAL I P 14:30 - 15:45 1.25 EVAL P 15:45 - 16:00 0.25 EVAL P 16:00 - 18:00 2.00 EVAL P 18:00 - 21:30 3.50 EVAL P 21:30 - 22:00 0.50 EVAL P 22:00 - 23:30 1.50 EVAL P 23:30 - 00:00 0.50 EVAL P 1/21/2006 00:00 - 01:30 1.50 EVAL P 01:30 - 03:00 1.50 EVAL P 03:00 - 06:00 I 3.001 EVAL I P 06:00 - 07:00 I 1.001 EVAL I P 07:00 - 11:30 I 4.501 EVAL I P 11:30 - 13:00 1.50 EVAL P 13:00 - 13:30 0.50 EVAL P 13:30 - 17:00 3.50 CASE P 17:00 - 00:00 f 7.001 CASE I P 1!22/2006 100:00 - 02:30 2.501 CASE P 02:30 - 03:30 1.00 CASE P 03:30 - 06:30 3.00 CASE P 06:30 - 10:00 3.50 CASE P Phase Description of Operations PROD1 packing off constantly. PRODi Circulate two bottoms up at 700 gpm, 1711 psi, tq. 5K, while rotating and reciprocating w/bit above shoe at 3159'. PROD1 RIH f/ 3159' to TD at 4748'. Trip in hole good. Worked through one tight spot at 4611'. Found three feet of fill on bottom. Circulated down. PROD1 Circulate and condition mud. RU for MADPass. MW = 9.2 ppg in and out. PROD1 MADPass f/4746' to 3231'. 150 gpm, 175 psi, 60 rpm, 6K tq. No excessive torque, drag, or pressure during MADPass. PROD1 CBU above 9-5/8" shoe at 3221', 700 gpm, 1700 psi, 80 rpm, 6K tq. Pump dry job. BD topdrive. PROD1 POH f/3259' to 200'. PROD1 PJSM to handle nukes w/all hands and Schlumberger. PRODi Handle nukes. LD BHA # 6. Download MWD. PROD1 Run Schlumberger caliper log from 4748' to 9-5/8" shoe at 3221'. RD Schlumberger. PROD1 PU cleanout BHA # 7. PRODi RIH w/drill pipe and cleanout BHA # 7 to shoe at 3221'. PROD1 Service rig and topdrive. PROD1 RIH f/3221' to 4746'. Found 2' of fill. PROD1 Circulate two bottoms up w/old Flo-Pro mud until wellbore clean. 450 gpm, 760 psi, 41 rpm, tq. 7K. Clean ditchmagnets, possum belly, troughs, and put new 325 mesh screens on one shaker and new Flo-Pro system started downhole. New 325 mesh screens were placed on other 3 shakers and they were put on line w/new Flo-Pro system. PROD1 Circulate new Flo-Pro SF mud to wellbore. 450 gpm, 760 psi, 41 rpm, tq. 7K. Performed Production Screen Test per Weatherford specifications, with wellbore effluent Flo-Pro SF samples taken upstream of shakers at entry point into possum belly. 3 x 300 ml samples passed through 1 ESS screen sample. Continue to condition well until PST test meets Weatherford specifications. PROD1 Monitor well for 10 mins. MW at 8.8 ppg. in and out. POH to shoe at 3221'. No excessive drag. PROD1 Condition mud per Weatherford. Run PST test as per Weatherford direction. 500 gpm, 565 psi, 80 rpm, 5K tq. PROD1 POH to BHA # 7. PROD1 LD BHA #7. Clear rig floor. RUNPRD RU to run 7" Weatherford expandable screen/liner. PJSM w/all hands, Weatherford and WSL. MU safety jt to TIW valve and store for quick access. MU practice joints to test tongs and torque turn equipment as required by Weatherford. RUNPRD RIH w/7' expandable screen/liner hanger/OH packer to 1,088'. Changed out tongs. The dies in 1st set would not bite Cr25 pipe. RUNPRD Continue to RIH w/7" expandable screens and liner on drillpipe. MU liner hanger. RUNPRD R/D liner casing handling equipment. RUNPRD PU nine 6.25" drill collars. LD jars. RIH w/HWDP. RUNPRD RIH w/drill pipe to shoe at 3221'. Break circulation. PU wt. 130K, SO wt. 105K. Continue to RIH to setting depth at 4708'. Printed: 1/30/2006 11:21:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: S-400 Common Well Name: S-400 Event Name: DRILL+COMPLETE Start: 1/9/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To Hours Task 1/22/2006 06:30 - 10:00 3.50 CASE 10:00 - 11:30 1.50 CASE 11:30 - 13:30 2.00 CASE 13:30 - 14:30 1.00 CASE 1 /23/2006 1/24/2006 14:30 - 16:00 16:00 - 18:30 18:30 - 19:00 19:00 - 20:00 20:00 - 23:30 23:30 - 00:00 00:00 - 01:30 01:30 - 03:00 1.50 CASE 2.50 CASE 0.50 CASE 1.00 CASE 3.50 CASE 0.50 CASE 1.50 CASE 1.50 CASE 03:00 - 04:00 1.00 CASE 04:00 - 10:00 6.00 CASE 10:00 - 11:00 1.00 CASE 11:00 - 00:00 13.00 CASE 00:00 - 06:00 06:00 - 06:30 06:30 - 07:30 07:30 - 10:00 10:00 - 10:30 10:30 - 11:00 11:00 - 12:30 12:30 - 13:00 6.00 CASE 0.50 CASE 1.00 CASE 2.50 CASE 0.50 CASE 0.50 CASE 1.50 CASE 0.50 CASE 13:00 - 13:30 13:30 - 13:45 13:45 - 14:00 14:00 - 14:30 14:30 - 15:15 15:15 - 15:30 0.50 CASE 0.25 CASE 0.25 CASE 0.50 CASE 0.75 CASE 0.25 CASE Page 7 of 10 Spud Date: 1 /11 /2006 End: Code NPT ' Phase Description of Operations P RUNPRD PU wt 75K, SO 70K. Work liner through tight spots at 3420' and again at 4020' max set down 25K. P RUNPRD Circulate, 168 gpm, 250 psi. P RUNPRD RU and run Schlumberger wireline to correlate liner into place. POH and RD wireline. P RUNPRD Drop and pump down 1.25" setting ball, pressure liner hanger to 1300 psi to set. Bleed off pressure. Top of liner at 3039', shoe at 4708'. SO 45K lbs., PU 65K lbs. Pressure test annulus to 500 psi. Release f/hanger/shear out ball seat w/2200 psi. P RUNPRD POH w/drill pipe and setting tool. MW = 8.8 ppg. P RUNPRD LD 5" HWDP and 6.25" drill collars. Function test BOP. P RUNPRD LD and clean liner hanger running tool. P RUNPRD RU to handle 4.75" drill collars. P RUNPRD PU and RIH w/4.75" collars and 4" HWDP. P RUNPRD Circulate to clean drill collars per Weatherford procedure. P RUNPRD POH w/4.75" drill collars and 4" HWDP and rack back. N WAIT RUNPRD Service, maintain, clean rig. WOW to bring Weatherford/BP personnel back to rig f/BOC/PBOC. N WAIT RUNPRD Hold safety meeting w/all hands and WSL. Cover current safety topics. Put up Weatherford slideshow covering makeup, running, setting and expanding screen liner for all hands. N WAIT RUNPRD Service, maintain, clean rig. Wait on weather to bring Weatherford/BP personnel back to rig f/BOC/PBOC/MCC. All Weatherford/BP personnel were sent back to BOC, MCC, PBOC per instructions of PBU IMT as precautionary measure in anticipation of phase III conditions. N WAIT RUNPRD RU to run swaging BHA for expandable liner. Surface test expansion tool. N WAIT RUNPRD Phase 3 weather security bulletin. Secure well and rig. Account for all personnel, safety brief on phase 3 weather policy, and secure quarters for all guest Weatherford/BP/Cenrilift personnel. N WAIT RUNPRD Wait on weather. Phase III conditions. P RUNPRD LD three drill collars. P RUNPRD MU swaging tool. Perform function test. P RUNPRD MU BHA. P RUNPRD RIH to 2796'. P RUNPRD Depth flow test swaging tool. P RUNPRD RIH to 3300'. P RUNPRD Circulate and move to zone 1. Expand ESS screens 1,2, and 3 from 3300' to 3394'. Low force roller hanging up between connections. 50 rpm, 4 fpm, 115 gpm. P RUNPRD Reduce circulation to 105 gpm, 4 fpm, 50 rpm. Complete expansion of screens 1 and 2. P RUNPRD Top drive stalled. P RUNPRD Complete expansion of screen 3. 105 gpm, 4 fpm, 50 rpm. P RUNPRD Moved down to zone 2. Expanded screens 4 and 5 f/3515' to 3572'. 105 gpm, 4 fpm, 50 rpm. P RUNPRD Moved down to zone 3. Expanded screens 6 and 7 f/3582' to 3657'. 105 gpm, 4 fpm, 50 rpm. P RUNPRD , Moved down to zone 4. Expanded screen 8 f/3672' to 3710'. Printed: 1/30/2006 11:21:13 AM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: S-400 Common Well Name: S-400 Spud Date: 1/11/2006 Event Name: DRILL+COMPLETE Start: 1/9/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: 7ES Date From - To 1 /24/2006 ~ 15:30 - 16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 17:30 17:30 - 21:30 21:30 - 23:00 Hours Task Code I 0.50 CASE P 0.50 CASE P 0.50 CASE P 0.50 CASE P 4.00 CASE P 1.50 CASE P 23:00 - 00:00 1.00 CASE P 1!25/2006 00:00 - 03:00 3.00 CASE P 03:00 - 04:30 1.50 CASE P 04:30 - 05:30 1.00 CASE P 05:30 - 08:30 3.00 CASE N 08:30 - 09:00 0.50 CASE N 09:00 - 11:00 I 2.001 CASE I N 11:00 - 13:00 2.00 CASE N 13:00 - 14:30 1.50 CASE N 14:30 - 15:30 1.00 CASE N 15:30 - t 7:00 1.50 CASE P 17:00 - 19:00 I 2.001 CASE I P 19:00 - 19:30 I 0.501 CASE I P 19:30 - 21:30 2.00 CASE P 21:30 - 22:30 1.00 CASE P 22:30 - 23:30 1.00 I CASE P 23:30 - 00:00 0.50 CASE P 1/26/2006 00:00 - 01:30 1.50 CASE P NPT Phase Description of Operations RUNPRD Moved down to zone 5. Expanded screen 9 (/3748' to 3786'. 105 gpm, 4 fpm, 50 rpm. RUNPRD Tagged EZI #1 OH packer at 3843'. 1' of elongation noted due to expansion process. 2 attempts to function diverfer failed at 2700 and 2900 psi. Successfully functioned diverter on third attempt and expanded EZI OH packer from 3843' to 3863'. 100 rpm, 2 fpm, 185 gpm. RUNPRD Tagged EZI #2 OH packer at 4269'. Expanded packer from 4269 to 4289. 100 rpm, 2 fpm, 185 gpm. RUNPRD Drop ball and open circulation sub, opened at 2300 psi. BD top drive. RUNPRD POH. MW = 8.8 ppg. RUNPRD LD swaging tool. Download expansion data from expansion tool. Function test BOP. RUNPRD PU expansion tools, shallow flow test, LD XOs, BD topdrive. RUNPRD RIH w/#2 swaging BHA. RUNPRD Expand ESS and EZI as per program. Expanded to 4214'. RUNPRD Stuck tool at 4214'. PU 20K over, SO 20K. Work tools free. Go down to blank joint to attempt to collapse rollers. Come back to 4214'. Pull over 10K. SO and rotate tools. Pull up and tools came free. Zones 1 through 6 expanded cleanly. 4214' to 4239' remain in zone 7 to be expanded. EZI remains to be expanded from 4593' to 4612'. Zone 8 from 4632' to 4670' remains to be expanded. DFAL RUNPRD POH to change out swaging tools. Mud wt. 8.9 ppg. DFAL RUNPRD LD swaging tool. Per Weatherford possible. problem w/EZI roller area w/roller cocking itself out of alignment to its carrier. Function test BOPs. DFAL RUNPRD Clean rig floor while downloading from data sub. MU expansion from redressed components and components f/swaging BHA #2. Test tool to 1200 psi for 10 mins. Surface test tools. DFAL RUNPRD PU swaging BHA # 3 and RIH to 3018'. DFAL RUNPRD Circulate 80 degree Hot Oil heated mud. Flow test expanding tools. DEAL RUNPRD Continue RIH to 4600'. RUNPRD Expand EZI from 4593' to 4612'. Expand zone 8 from from 4632' to 4670'. 100 rpm, 180 gpm on EZI packer. 50 rpm, 105 gpm on ESS screen secton. RUNPRD POH to 4215' Make expansion tools run through prior problem area (/4212' to 4238'. 50 rpm 50 gpm. Increase to 105 gpm as expansion proceed successfully. Finish expanding zone 7. RUNPRD RIH and tag bullnose at -4704'. Drop 1.75" ball to circ sub. Open circ sub. RUNPRD Displace hole to 8.9 ppg brine. 8 bpm 1450 psi. RUNPRD Spot trucks and RU to take enzyme pill directly to pumps from trucks to avoid pit contamination. PJSM w/all hands and WSL on handling and emergency handling of enzyme pill. RUNPRD Spot 90 bbls of enzyme filter cake breaker pill in liner. 126 gpm, 170 psi. RUNPRD POH through expanded zones at 15 ft/min. MW 8.9 ppg. RUNPRD POH standing back drill pipe to liner top at 3221' at 15'/min while pulling out of enzyme pill. MW 8.8 ppg. Printed: 1/30/2006 11:21:13 AM BP EXPLORATION Operations Summary Report Page 9 of 10 Legal Well Name: S-400 Common W ell Name: S-400 Spud Date: 1/11/2006 Event Nam e: DRILL+C OMPLE TE Start : 1/9/2006 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: Rig Name: NABOB S 7ES Rig Number: 7ES Date ; From - To Hours ~ Task Code NPT Phase Description of Operations 1/26/2006 01:30 - 02:30 1.00 CASE P RUNPRD Service rig and topdrive. Slip and cut drilling line. 02:30 - 06:00 3.50 CASE P RUNPRD POH laying down 44 stands of 5" drill pipe. 06:00 - 08:30 2.50 CASE P RUNPRD POH and LD HWDP and DC. 08:30 - 09:00 0.50 CASE P RUNPRD Make service breaks and LD Weatherford expansion tool. Function test BOPs when out of hole. 09:00 - 11:00 2.00 EVAL P RUNPRD RU Schlumberger W/L unit for USIT/CBUGR log. 11:00 - 12:00 1.00 EVAL P RUNPRD RIH w/ USIT/CBUGR log. USIT not working. Log CBL thru 9 5/8" csg. GR to surface. 12:00 - 14:00 2.00 EVAL P RUNPRD POH w/USIT/CBUGR tool problems. 14:00 - 15:00 1.00 EVAL N DFAL RUNPRD RU and changeout powerhead, surface test. 15:00 - 17:30 2.50 EVAL N DFAL RUNPRD RIH and Log w/USIT thru 7" liner. USIT tool failure. 17:30 - 18:30 1.00 EVAL N DFAL RUNPRD POH and LD tools. Retest powerhead. 18:30 - 20:30 2.00 EVAL N DFAL RUNPRD RIH and complete log w/ USIT of 9-5/8" section 2812' to 2589'. (Schl supervisor evaulated CBL and determined that log was ran with poor centrilization and recommended running USIT to determine cement bond) 20:30 - 00:00 3.50 EVAL N DFAL RUNPRD Log 13-3(8" section from 2589' to 2289'. Decision made to logged fr/2589' to 1250' as bond quality was poor. (30 mins) Poor bond to 1250'. POH w/wireline. Fluid lost to hole (/12:00 to 24:00 = 35 bbls. Note: Visual check shows cement at surface. 1/27/2006 00:00 - 01:30 1.50 CASE P PROD1 POH and rig down Schlumberger W/L. 01:30 - 02:30 1.00 BUNCO RUNCMP Pull wear bushing. Install test plug. C/O upper rams to fit 7" tubing and test doors to 3500 psi w/chart. 02:30 - 07:30 5.00 BUNCO RUNCMP PJSM w/Baker Centrilift, Halliburton, all hands. Make dummy run w/tubing hanger. Verify that X-overs to TIW valve are i made up and accessible on floor. Hang ESP cable & I wire sheaves. RU spooling units. 07:30 - 14:00 6.50 BUNCO RUNCMP PU ESP seal section, lower pump section, upper pump section. Bolt all together and attach ESP power cable to motor section. All components filled with oil. 14:00 - 15:00 1.00 BUNCO RUNCMP PU 6 jts. 5.5" BTC-M tubing. RD 5.5" handling equipment. 15:00 - 16:00 1.00 BUNCO RUNCMP RU to handle 7" casing. MU XOs and R nipple. Attach Halliburton Symphony gauge cable. Break circulation every 20 jts. while running in. Test cable for pump OK 16:00 - 21:30 5.50 BUNCO RUNCMP RIH w 7" tubing jts. 1 through 59. Up wt. 105K, SO wt. 85K. Break circulation w/146 gpm, 170 psi. Test cable for pump OK 21:30 - 22:00 0.50 BUNCO RUNCMP MU hanger to landing jt. 22:00 - 00:00 2.00 BUNCO RUNCMP MU I wire and ESP cable connections to penetrators in tubing hanger. RD 7" tubing handling equipment. 1/28/2006 00:00 - 01:30 1.50 BUNCO RUNCMP Land tubing hanger and LD landing jt. Dry rod in TWC. 01:30 - 03:00 1.50 BOPSU P WHDTRE Terminate cables. Nipple down BOP stack. 03:00 - 12:00 9.00 WHSUR P WHDTRE NU adapter and treelLEO valve. Test tubing head adapter, tree and packoff to 5000 psi. Test conductivity of ESP cable & I wire. 12:00 - 17:00 5.00 WHSUR P WHDTRE Pump 280 bbls diesel freeze protect down annulus. 126 gpm, 500 psi. Allow diesel to u-tube. 17:00 - 18:00 , 1.00 WHSUR P WHDTRE RU DSM and set BPV. Install VR plugs in annular valves. Check ESP conductivity. 18:00 - 00:00 6.00 RIGD P POST RD and prepare to move rig. Move trucks on location at 18:30 hrs. to keep them ahead of Nordic rig heading off Z pad to Printed: 1/30/2006 11:21:13 AM Printed: 1!30/2006 11:21:13 AM °~ S-400 Survev Report Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: S-PAD / S-400 Well: S-400 Borehole: S-400 UWUAPI#: 500292328900 Survey Name /Date: S-400 /January 19, 2006 Tort /AHD / DDI I ERD ratio: 84.639° / 2355.92 ft / 5.380 / 0.597 Grid Coordinate System: NA027 Alaska State Planes, Zone 04, US Feet location LaULOng: N 70 21 17.639, W 149 2 3.060 Location Grid WE Y/X: N 5980325.140 ftUS, E 618930.100 ftUS Grid Convergence Angle: +0.90960937° Grid Scale Factor: 0.99991607 Vertical Section Azimuth: 234.790° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 64.60 ft relative to MSL Sea Bed /Ground Level Elevation: 35,90 ft relative to MSL Magnetic Declination: 24.502° Total Field Strength: 57592.249 nT Magnetic Dip: 80.888° Declination Date: January 18, 2006 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.502° Local Coordinates Referenced To: Well Head f` u Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS H I C U.UU U.UU U.VU -b4.bU U.UV V.UU V.UV U.UV V.UU V.VV V.VV b`JtSVJLb. 14 b I25`J3V. I V IV /V L I I /.bSy VV 14`J Z 3.VOV GYD GC MS 100.00 0.71 9.66 35.40 100.00 -0.44 0.62 0.62 .0.61 0.10 0.71 5980325.75 618930.19 N 70 21 17.645 W 149 2 3.056 200.00 0.66 295.09 135.39 199.99 -0.59 1.66 1.50 1.47 -0.31 0.83 5980326.60 618929.76 N 70 21 17.653 W 149 2 3.069 300.00 1.18 276.62 235.38 299.98 0.46 3.25 2.61 1.83 -1.86 0.59 5980326.94 618928.21 N 70 21 17.657 W 149 2 3.114 Last GYD GC MS 346.81 1.81 273.17 282.17 346.77 1.40 4.47 3.63 1.93 -3.08 1.36 5980327.02 618927.00 N 70 21 17.658 W 149 2 3.149 First MWD+IFR+MS 373.95 2.23 270.97 309.30 373.90 2.16 5.43 4.48 1.96 -4.03 1.57 5980327.03 618926.04 N 70 21 17.658 W 149 2 3.177 463.46 3.22 258.44 398.70 463.30 5.87 9.67 8.37 1.48 -8.24 1.28 5980326.49 618921.84 N 70 21 17.654 W 149 2 3.300 553.89 4.93 241.40 488.91 553.51 12.06 16.05 14.16 -0.89 -14.14 2.30 5980324.03 618915.98 N 70 21 17.630 W 149 2 3.473 640.64 7.24 246.92 575.16 639.76 21.11 25.23 22.95 -4.81 -22.44 2.74 5980319.97 618907.74 N 70 21 17.592 W 149 2 3.715 737.83 10.86 247.56 671.13 735.73 36.03 40.52 38.08 -10.71 -36.54 3.73 5980313.85 618893.74 N 70 21 17.534 W 149 2 4.128 832.09 13.57 238.41 763.25 827.85 55.73 60.42 57.71 -19.90 -54.17 3.52 5980304.39 618876.26 N 70 21 17.443 W 1493 926.12 17.64 230.10 853.81 918.41 80.95 85.67 82.24 -34.82 -74.51 4.93 5980289.14 618856.16 N 70 21 17.297 W 149 8 1021.42 20.27 228.56 943.93 1008.53 111.76 116.62 112.36 -55.01 -97.97 2.81 5980268.58 618833.03 N 70 21 17.098 W 149 2 5.923 1115.37 22.13 228.40 1031.52 1096:12 145.53 150.59 145.74 -77.53 -123.40 1.98 5980245.66 618807.96 N 70 21 16.877 W 149 2 6.667 1210.01 23.60 229.81 1118.72 1183.32 182.12 187.36 182.17 -101.60 -151.21 1.66 5980221.16 618780.54 N 70 21 16.640 W 149 2 7.479 1305.23 24.35 231.72 1205.73 1270.33 220.71 226.05 220.72 -126.06 -181.18 1.13 5980196.23 618750.96 N 70 21 16.399 W 149 2 8.355 1396.93 23.85 231.74 1289.43 1354.03 258.10 263.50 258.10 -149.25 -210.57 0.55 5980172.58 618721.94 N 70 21 16.171 W 149 2 9.215 1488.73 27.89 230.72 1372.02 1436.62 298.07 303.54 298.08 -174.35 -241.78 4.43 5980146.99 618691.14 N 70 21 15.924 W 149 2 10.127 1581.84 28.23 231.56 1454.18 1518.78 341.78 347.34 341.83 -201.82 -275.88 0.56 5980118.98 618657.48 N 70 21 15.654 W 149 2 11.124 1677.39 30.12 236.25 1537.62 1602.22 388.32 393.90 388.37 -229.20 -313.53 3.10 5980091.01 618620.28 N 70 21 15.385 W 149 2 12.224 1770.36 34.21 235.44 1616.30 1680.90 437.79 443.38 437.83 -257.00 -354.46 4.42 5980062.57 618579.79 N 70 21 15.111 W 149 2 13.421 1864.20 38.32 233.89 1691.95 1756.55 493.28 498.87 493.32 -289.12 -399.71 4.49 5980029.74 618535.06 N 70 21 14.795 W 149 2 14.743 1958.30 39.73 234.24 1765.05 1829.65 552.53 558.12 552.57 -323.89 -447.69 1.52 5979994.21 618487.65 N 70 21 14.454 W 149 2 16.145 2052.59 40.68 233.29 1837.07 1901.67 613.38 618.99 613.43 -359.87 -496.78 1.20 5979957.46 618439.14 N 70 21 14.100 W 149 2 17.580 2146.44 42.10 234.39 1907.47 1972.07 675.42 681.04 675.48 -396.48 -546.88 1.70 5979920.07 618389.63 N 70 21 13.740 W 149 2 19.045 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-400\S-400\S-400\S-400 Generated 3/7/2006 3:56 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 2240.92 41.98 234.49 1977 .64 2042.24 738 .69 744.31 738.74 -433.27 -598.35 0.15 5979882.46 2337.48 42.77 235 .43 2048 .98 2113.58 803 .77 809.38 803.81 -470.63 -651.63 1.05 5979844.27 2433.03 43.01 235 .09 2118 .98 2183.58 868 .79 874.41 868.83 -507.69 -705.07 0.35 5979806.37 2528.38 42.05 234 .98 2189 .25 2253.85 933 .25 938.87 933.28 -544.62 -757.89 1.01 5979768.60 2623.04 41.16 234 .58 2260 .03 2324.63 996 .10 1001.72 996.13 -580.87 -809.24 0.98 5979731.55 2718.31 40.78 234.36 2331.96 2396.56 1058.56 1064.19 1058.60 -617.17 -860.07 0.43 5979694.45 2811.48 39.90 235.50 2402.98 2467.58 1118.87 1124.49 1118.90 -651.83 -909.43 1.23 5979659.01 2906.47 38.90 235.09 2476.38 2540.98 1179.16 1184.79 1179.19 -686.15 -959.00 1.09 5979623.91 3002.00 41.21 233.78 2549.50 2614.10 1240.63 1246.26 1240.65 -721.92 -1008.99 2.57 5979587.36 3094.84 44.52 233.43 2617.53 2682.13 1303.76 1309.40 1303.80 -759.39 -1059.82 3.57 5979549.09 3155.49 44,82 233.45 2660.67 2725.27 1346.39 1352.04 1346.43 -784.79 -1094.06 0.50 5979523.15 MWD Standard 3191.67 45.27 234.38 2686.23 2750.83 1371.99 1377.65 1372.03 -799.87 -1114.75 2.20 5979507.75 3286.08 46.04 234.68 2752.22 2816.82 1439.50 1445.16 1439.55 -839.05 -1169.74 0.85 5979467.70 3379.36 46.88 234.87 2816.48 2881.08 1507.12 1512.78 1507.16 -878.05 -1224.98 0.91 5979427.84 3473.03 47.68 234.82 2880.02 2944.62 1575.94 1581.60 1575.98 -917.67 -1281.24 0.85 5979387.33 Last MWD Standard 3537.29 48.22 234.58 2923.06 2987.66 1623.65 1629.31 1623.69 -945.24 -1320.19 0.88 5979359.14 MWD+IFR+MS 3566.28 48.36 233.75 2942.35 3006.95 1645.29 1650.95 1645.33 -957.91 -1337.73 2.19 5979346.19 3661.16 46.07 233.50 3006.79 3071.39 1714.91 1720.58 1714.96 -999.21 -1393.79 2.42 5979304.02 3756.30 43.77 232.67 3074.16 3138.76 1782.05 1787.76 1782.11 -1039.55 -1447.51 2.49 5979262.84 3851.39 41.85 231.94 3143.92 3208.52 1846.61 1852.37 1846.69 -1079.05 -1498.64 2.09 5979222.53 3944.87 40.27 231.62 3214.40 3279.00 1907.92 1913.78 1908.04 -1117.03 -1546.88 1.71 5979183.79 4039.85 37.95 230.72 3288.09 3352.69 1967.72 1973.68 1967.87 -1154.59 -1593.56 2.51 5979145.50 4133.69 36.47 230.04 3362.83 3427.43 2024.29 2030.43 2024.50 -1190.77 -1637.27 1.64 5979108.63 4229.99 34.72 230.11 3441.13 3505.73 2080.15 2086.48 2080.42 -1226.74 -1680.26 1.82 5979071.98 4325.02 33.34 229.82 3519.88 3584.48 2133.15 2139.66 2133.48 -1260.95 -1720.98 1,46 5979037.14 4418.24 32.07 229.66 3598.32 3662.92 2183.32 2190.03 2183.73 -1293.50 -1759.41 1.37 5979003.99 4515.40 31.08 230.72 3681.10 3745.70 2234.02 2240.90 2234.51 -1326.07 -1798.49 1.17 5978970.80 4611.17 29.88 230.82 3763.63 3828.23 2282.48 2289.48 2283.03 -1356.80 -i 836.11 1.25 5978939.48 Last MWD+IFR+MS 4684.31 28.75 230.77 3827.41 3892.01 2318.20 2325.29 2318.80 -1379.43 -1863.86 1.55 5978916.41 TD (Projected) 4748.00 28.75 230.77 3883.25 3947.85 2348.76 2355.92 2349.40 -1398.81 -1887.59 0.00 5978896.67 Survey Type: Definitive Survey NOTES: GYD-GC-MS - (Gyrodata - gyro compassing m/s -- Older G yrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multi shot into open hole" model. Not to be run above 70 degrees inclination.. } MWD +IFR + MS - (In-field referenced MWD with mult-stat ion analysis and correction applied in post-processing. Assumes a BHA sag correction is appli ed to enhance inclinati on accuracy. ) MWD -Standard - (Measu rement While Drilling with no (or no known) special corrections. The model allows for the fact that axial interference may marginally exceed the upper limit specified when the well is nea r horizontal easUwest. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4121 FSL 4504 FEL S35 T12N R12E UM 5980325.14 6 18930.10 BHL : 2722 FSL 1113 FEL S34 T12N R12E UM 5978896.67 6 17065.11 618338.76 N 70 21 13.378 W 149 2 20.549 618286.08 N 70 21 13.010 W 149 2 22.106 618233.24 N 70 21 12.646 W 149 2 23.668 618181.02 N 70 21 12.282 W 149 2 25.212 618130.25 N 70 21 11.926 W 149 2 26.713 618080.01 N 70 21 11.569 W 149 2 28.198 618031.21 N 70 21 11.228 W 149 2 29.641 617982.20 N 70 21 10.890 W 149 2 31.089 617932.78 N 70 21 10.538 W 149 2 32.551 617882.56 N 70 21 10.170 W 149 2 34.036 617848.73 N 70 21 9.920 W 149 7 617828.28 N 70 21 9.772 W 149 2 642 617773.92 N 70 21 9.386 W 149 2 37.249 617719.32 N 70 21 9.003 W 149 2 38.863 617663.70 N 70 21 8.613 W 149 2 40.507 617625.20 N 70 21 8.342 W 149 2 41.645 617607.86 N 70 21 8.217 W 149 2 42.158 617552.46 N 70 21 7.811 W 149 2 43.796 617499.40 N 70 21 7.414 W 149 2 45.366 617448.90 N 70 21 7.025 W 149 2 46.860 617401.28 N 70 21 6.652 W 149 2 48.270 617355.21 N 70 21 6.282 W 149 2 49.634 617312.08 N 70 21 5.926 W 149 2 50.911 617269.67 N 70 21 5.572 W 149 2 52.167 617229.51 N 70 21 5.236 W 149 2 53.357 617191.59 N 70 21 4.916 W 149 2 54.480 617153.04 N 70 21 4.595 W 149 2 55.622 617115.91 N 70 21 4.293 W 149 2 21 617088.53 N 70 21 4.070 W 149 ~~2 617065.11 N 70 21 3.880 W 149 26 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-400\S-400\S-400\S-400 Generated 3/7/2006 3:56 PM Page 2 of 2 Tree : CIW 7" 5M Wellhead: FMC Big Bore 20" 131.45 ppf, X-56 , 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. HES "R" Nipple 5.625" ID 2509` 13 3/8 68 ppf, L-80 BTC 2589` RA Tag 2812 7" Hanger/Packer 3039 9 5/8" 40 ppf, L-80 BTC 3221 -iES Symphony gauge N/ESP cable 2480 :,entrilift 57 stage HC27000 i75 ESP, 8.75" OD,` 791 :,entrilift HST34B EHL PFS >eal section .2822 :,entrilift Series,HMIHE 1000 hp series725motor 4160v./154amp, 2859 ,entrilift PumpMate 2884` top SV3 blank 3297 SV3 ESS 3299 SV3 blank 3394 top SV2 ESS 3514 SV2 blank 3572 SV2 ESS 3581 EZI 3842 top SV1 blank 3919 SV1 ESS 3959 SV1 blank 4071 EZI(coal at top UG4) 4268 UG4A blank 4288 UG4A ESS 0 UG4A blank 4553 UG4A EZI* 4592 blank/bullnose 4706 7" csg. shoe 4707 8 1/2" Driller's TD 4748 DATE REV. BY COMMENTS S-Pad 1/6/06 PGS Proposed ESS completion (WP-07)) Well S-400 WSW 1 /27/06 LV Actual API NO: 50-029-23289 QD CYDI ~'1DATI~lA1 /A1~C\ Orig. DF elev. = 64.4' S~OO Orig. Cellar elev. = 35.9' SCHLUMBERGER Survey report Client. ................. BP Exploration Alaska (Inc) Field ..................... Aurora Well ...................... 5-400 API number ...............: 50-029-23289-00 Engineer .................. F. Medina RIG :...................... Nabors-7ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS............ Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference... ...... GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 35.90 ft N/A Top Drive 64.60 ft ----- 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 Azimuth from Vsect Origin to target: 234.79 degrees Q V; r 21-Jan-2006 13:49:34 Page 1 of 3 Spud date ................. 11-Jan-06 Last survey date.......... 19-Jan-06 Total accepted surveys...: 55 MD of first survey.......: 0.00 ft MD of last survey........: 4748.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: il-Jan-2006 Magnetic field strength..: 1151.85 HCNT Magnetic dec (+E/W-).....: 24.51 degrees Magnetic dip .............. 80.89 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G...........: Tolerance of H............ Tolerance of Dip.......... Criteria --------- 1002.68 meal 1151.85 HCNT 80.89 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.51 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.51 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 21-Jan-2006 13:49:34 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) (f t) (ft) (ft) (ft) (f t) (f t) (deg} 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.71 9.66 100.00 100.00 -0.44 0.61 0.10 0.62 9.66 0.71 BP _GYD CT DMS 3 200.00 0.66 295.09 100.00 199.99 -0.59 1.47 -0.31 1.50 347.92 0.83 BP _GYD CT DMS 4 .300.00 1.18 276.62 100.00 299.98 0.46 1.83 -1.86 2.61 314.54 0.59 BP _GYD CT DMS 5 346.81 1.81 273.17 46.81 346.77 1.40 1.93 -3.08 3.63 302.05 1.36 BP GYD CT DMS 6 7 .373.95 463.46 2.23 3.22 270.97 258.44 27.14 89.51 373.90 463.30 2.16 5.87 1.96 1.48 -4.03 -8.24 4.48 8.37 295.91 280.21 1.57 1.28 BP BP _MWD+IFR+MS _MWD+IFR+MS • 8 553.89 4.93 241.40 90.43 553.51 12.06 -0.89 -14.14 14.16 266.41 2.30 BP _MWD+IFR+MS 9 .640.64 7.24 246.92 86.75 639.76 21.11 -4.81 -22.44 22.95 257.89 2.74 BP _MWD+IFR+MS 10 737.83 10.86 247.56 97.19 735.73 36.03 -10.71 -36.54 38.08 253.66 3.73 BP MWD+IFR+MS 11 832.09 13.57 238.41 94.26 827.85 55.73 -19.90 -54.17 57.71 249.83 3.52 BP _MWD+IFR+MS 12 926.12 17.64 230.10 94.03 918.41 80.95 -34.82 -74.51 82.24 244.95 4.93 BP _MWD+IFR+MS 13 1021.42 20.27 228.56 95.30 1008.53 111.76 -55.01 -97.97 112.36 240.68 2.81 BP _MWD+IFR+MS 14 1115.37 22.13 228.40 93.95 1096.12 145.53 -77.53 -123.40 145.74 237.86 1.98 BP _MWD+IFR+MS 15 1210.01 23.60 229.81 94.64 1183.32 182.12 -101.60 -151.21 182.17 236.10 1.66 BP MWD+IFR+MS 16 1305.23 24.35 231.72 95.22 1270.33 220.71 -126.06 -181.18 220.72 235.17 1.13 BP _MWD+IFR+MS 17 1396.93 23.85 231.74 91.70 1354.03 258.10 -149.25 -210.57 258.10 234.67 0.55 BP _MWD+IFR+MS 18 1488.73 27.89 230.72 91.80 1436.62 298.07 -174.35 -241.78 298.08 234.20 4.43 BP _MWD+IFR+MS 19 1581.84 28.23 231.56 93.11 1518.78 341.78 -201.82 -275.88 341.83 233.81 0.56 BP _MWD+IFR+MS 20 1677.39 30.12 236.25 95.55 1602.22 388.32 -229.20 -313.53 388.37 233.83 3.10 BP MWD+IFR+MS 21 1770.36 34.21 235.44 92.97 1680.90 437.79 -257.00 -354.46 437.83 234.06 4.42 BP _MWD+IFR+MS 22 1864.20 38.32 233.89 93.84 1756.55 493.28 -289.12 -399.71 493.32 234.12 4.49 BP _MWD+IFR+MS • 23 1958.30 39.73 234.24 94.10 1829.65 552.53 -323.89 -447.69 552.57 234.12 1.52 BP _MWD+IFR+MS 24 2052.59 40.68 233.29 94.29 1901.67 613.38 -359.87 -496.78 613.43 234.08 1.20 BP _MWD+IFR+MS 25 .2146.44 42.10 234.39 93.85 1972.07 675.42 -396.48 -546.88 675.48 234.06 1.70 BP MWD+IFR+MS 26 2240.92 41.98 234.49 94.48 2042.24 738.69 -433.27 -598.35 738.74 234.09 0.15 BP _MWD+TFR+MS 27 2337.48 42.77 235.43 96.56 2113.58 803.77 -470.63 -651.63 803.81 234.16 1.05 BP _MWD+IFR+MS 28 2433.03 43.01 235.09 95.55 2183.58 868.79 -507.69 -705.07 868.83 234.24 0.35 BP _MWD+IFR+MS 29 2528.38 42.05 234.98 95.35 2253.85 933.25 -544.62 -757.89 933.28 234.30 1.01 BP _MWD+IFR+MS 30 2623.04 41.16 234.58 94.66 2324.63 996.10 -580.87 -809.24 996.13 234.33 0.98 BP MWD+IFR+MS 1 1 SCHLUMBERGER Survey Report 21-Jan-2006 13:49:34 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 (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2718.31 40.78 234.36 95.27 2396.56 1058.56 -617.17 -860.07 1058.60 234.34 0.43 BP _MWD+IFR+MS 32 2811.48 39.90 235.50 93.17 2467.58 1118.87 -651.$3 -909.43 1118.90 234.37 1.23 BP _MWD+IFR+MS 33 2906.47 38.90 235.09 94.99 2540.98 1179.16 -686.15 -959.00 1179.19 234.42 1.09 BP _MWD+IFR+MS 34 3002.00 41.21 233.78 95.53 2614.10 1240.63 -721.92 -1008.99 1240.65 234.42 2.57 BP _MWD+IFR+MS 35 3094.84 44.52 233.43 92.84 2682.13 1303.76 -759.39 -1059.82 1303.80 234.38 3.57 BP MWD+IFR+MS 36 3155.49 44.82 233.45 60.65 2725.27 1346.39 -784.79 -1094.06 1346.43 234.35 0.50 BP _MWD+IFR+MS 37 3191.67 45.27 234.38 36.18 2750.83- 1371.99 -799.87 -1114.75 1372.03 234.34 2.20 BP _INC TREND 38 3286.08 46.04 234.68 94.41 2816.82 1439.50 -839.05 -1169.74 1439.55 234.35 0.85 BP _MWD 39 3379.36 46.88 234.87 93.28 2881.08 1507.12 -878.05 -1224.98 1507.16 234.37 0.91 BP _MWD 40 3473.03 47.68 234.82 93.67 2944.62 1575.94 -917.67 -1281.24 1575.98 234.39 0.85 BP MWD 41 3537.29 48.22 234.58 64.26 2987.66 1623.65 -945.24 -1320.19 1623.69 234.40 0.88 BP _MWD 42 3'566.28 48.36 233.75 28.99 3006.95 1645.29 -957.91 -1337.73 1645.33 234.39 2.19 BP _MWD+IFR+MS 43 3661.16 46.07 233.50 94.88 3071.39 1714.91 -999.21 -1393.79 1714.96 234.36 2.42 BP _MWD+IFR+MS 44 3756.30 43.77 232.67 95.14 3138.76 1782.05 -1039.55 -1447.51 1782.11 234.32 2.49 BP _MWD+IFR+MS 45 3851.39 41.85 231.94 95.09 3208.51 1846.61 -1079.05 -1498.64 1846.69 234.25 2.09 BP MWD+IFR+MS 46 3944.87 40.27 231.62 93.48 3279.00 1907.92 -1117.03 -1546.88 1908.04 234.17 1.71 BP _MWD+IFR+MS 47 4039.85 37.95 230.72 94.98 3352.69 1967.72 -1154.59 -1593.56 1967.87 234.08 2.51 BP _MWD+IFR+MS 48 4133.69 36.47 230.04 93.84 3427.43 2024.29 -1190.77 -1637.27 2024.50 233.97 1.64 BP _MWD+IFR+MS 49 4229.99 34.72 230.11 96.30 3505.73 2080.15 -1226.74 -1680.26 2080.42 233.87 1.82 BP _MWD+IFR+MS 50 4325.02 33.34 229.82 95.03 3584.48 2133.15 -1260.95 -1720.98 2133.48 233.77 1.46 BP MWD+IFR+MS 51 4418.24 32.07 229.66 93.22 3662.92 2183.32 -1293.50 -1759.41 2183.73 233.68 1.37 BP _MWD+IFR+MS • 52 4515.40 31.08 230.72 97.16 3745.70 2234.02 -1326.07 -1798.49 2234.51 233.60 1.17 BP _MWD+IFR+MS 53 4611.17 29.88 230.82 95.77 3828.23 2282.48 -1356.80 -1836.11 2283.03 233.54 1.25 BP _MWD+IFR+MS 54 4684.31 28.75 230.77 73.14 3892.01 2318.20 -1379.43 -1863.86 2318.80 233.50 1.55 BP _MWD+IFR+MS 55 4748.00 28.75 230.77 63.69 3947.85 2348.76 -1398.81 -1887.59 2349.40 233.46 0.00 Projection to TD [(c)2006 IDEAL ID10 2C O1] • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian 1" ~ Well No S-400 :~ ~ '~ 1 ~ Date Dispatched: 25-Jan-O6 Installation/Rig Nabors 7ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1,1, 10-02-03 Data No Of Prints No of Floppies Surveys 2 1 E~j~~ FEB ~ ~ 200 ~ & Gas Cons. ~~' Please sign and return to: ,lames H. Johnson ReCelved By: BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-11 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojhC~bp.com ri ~ 7.~ t y 1 '~ ~ ~ ~ ` ~ ~ a ~ ~ ~ Jl ~ I ~ ~ ~ ~ ~~~ ~ FRANK H. MURKOWSKI, GOVERNOR ~' ~~~~ ~~~~++ /-~ ~~r ~/~a7~ OIL ~ ~ ~ 333 W. T" AVENUE, SUITE 100 CO1~T5ERQA7'I011T COr'Il~'IISSIOI~T ~' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Robert Tirpack FAx t9a7) vs-7sa2 Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU S-400 BP Exploration (Alaska) Inc. Permit No: 205-191 Surface Location: 4122' FSL, 4504' FEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 2680' FSL, 1268' FEL, SEC. 34, T12N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). Sincerely, Cathy . Foerster Commissioner r~ DATED this day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~C STATE OF ALASKA ALASKA I_ AND GAS CONSERVATION COtSSION PERMIT TO DRILL 20 AAC 25.005 Nov ~ ~ zoos Aiaskg Oil !~ Ga4~ Vona. ComtrBSSiOtE Anchorage 1 a. Type of work ®Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Oil ^ Multiple Zone ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU S-400 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 4877 TVD 3964 12. Field /Pool(s): Prudhoe Bay Field /Ugnu 4a. Location of Well (Governmental Section}: Surface: 4122' FSL 4504' FEL SEC 35 T12N R12E UM 7. Property Designation: ADL 028258 , , . , , , Top of Productive Horizon: 3214' FSL, 512' FEL, SEC. 34, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 20, 2005 ~ Total Depth: 2680' FSL, 1268' FEL, SEC. 34, T12N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10260' 4b. Location of Well (State Base Plane Coordinates): Surface: x-618930 -5980325 Zone-ASP4 10. KB Elevation Plan (Height above GL): 35.9 feet 15. Distance to Nearest Well Within Pool W-400 > 2 Miles Away (Ugnu) 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: 43 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA .035) Downhole: 1620 Surtace: 25 1.. as ng rogram: Size Specffications Setting Depth To ' Bottom ua o ement c.. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 20" 131.5# X-56 Weld 80' Surface Surface 105' 105' Driven 16" 13-3/8" 68# L-80 BTC-M 2770' Surtace Surface 2800' 2440' 44 sx Arcticset Lite, 640 sx'G' ~ 16" 9-5/8" 47# L-80 BTC-M 516' 2800' 2440' 3316' 2825' Cemented w/ 13-3/8° Casin 8-1/2" 7" 29# L-80 VAM To .2-225" "2659' 2338' 4875' 3961' Uncemented Ex andable Screens i 1v S 3, ~~; ~i~ 19. PRESENT W ELL CONDITION SUMM ARY (To be completed: for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casin Len h Size Cement Volume MD TVD r r n r Pro Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-x897 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared ey Name/Number. Si nature ~°~ Phone 564-4166 Date 11 ~~~J Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ,,,. API Number: 50- ~ 2 - 2. 3 2 ~ Permit A proval -_.- Date: ~ See cover letter for other requirements Conditions of Approval: Sample a uired Hydr en S Ifide Measures Other: ~i ~'`~~~ } ~ ' (~~ .r~ t.: A roved B ^ Yes No Mud Log Required ^ Yes '~ No ^ Yes ~` No Directional Survey Required Yes ! ~ No APPROVED BY ` 9'P THE COMMISSION Date ~I~Y [/~ Form 10-401 Revised 0~ ~ ` ~-r' ° { 4 `,~ ~ Q '~~~~ ~~ ~~ i,0 Submit In Duplicate • Well Name: S-400 Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Service (Water Source Well) ~~ Surface Location: X = 618,930' Y = 5,980,325 AS-Built SIOt 43 1158' FNL, 776' FWL, Sec. 35, T12N, R12E Target Location: X = 617,658' Y = 5,979,397.00' 2066' FNL, 512' FEL, Sec. 34, T12N, R12E Bottom Hole Location: X = 616,912' Y = 5,978,852.00' 259,9' FNL, 1267' FEL, Sec. 34, T12N, R12E ~ AFE Number: PBD5M0089 Ri Nabors 7ES Estimated Start Date: 12/20/2005 O eratin da s to drill: 17.0 MD: 4877' TVD: 3964' KB: 28.5' KBE: 35.9' Well Desi n conventional, slimhole, etc.: 2 String Water Producer Ob'ective: Water source well in Ugnu reservoir CasinglTubing Program: Hole Size Csg/ Tb O.D. Wt/Ft Grade i Conn ~ Length Top MDlTVD Btm MD/TVD bkb NA 20" 131.5# X-56 WLD 80' GL 1051105 16" 13-3/8" 68# L-80 BTC-M 2770' GL 2800'/2440' 16" 9 5/8" 47# L-80 BTC-M 516' 2 440' 3316'/2825' 8'/2" 7" 29# L-80 Vam Top HT Expandable Screens 2715' 3 66'/'2338' .~=% 4875'/3961' Tubin 7" 26# L-80 BTC-M TBD GL TBD Logging Program: Surface Drilling: MWD / GR Open Hole: None Cased Hole: None Production Hole Drilling: MWD/GR/Neu/Den/Res/Cal Open Hole: 6-Arm caliper Cased Hole: Antech, USIT-contin ent S-400 Drilling Program Page 1 • • Mud Program: 16" Surface Hole Mud Properties: S ud -Freshwater Mud Interval Densit Funnel Vis PV YP FL Chlorides PH 0-1,865' Base Perm 8.8 250-300+ 20-45 50-70 NC-8.0 <1000 9.0-9.5 1,865-3,316 TD 9. -9. 200-250 20-40 40-50 8.0-7.0 <1000 9.0-9.5 8'/s" Production Hole Mud Properties: FloPro NT RDF Svstem Interval Densit Funnel Vis PV YP FL H LGS % MBT Surface shoe to TD 8.9 - 9.2 38-50 10-16 18-24 4.0-6.0 9.0-9.5 < 6.0 < 20 Directional: Ver. Anadrill (P6) KO P: 300' Maximum Hole An le: 43 deg at 1986' MD, Hold to TD Close Approach Wells: All wells pass 1/200 major risk criteria. S-41 - 31' @ 688' S-42 - 61' @ 648' IFR-MS corrected surve s will be used for surve validation. Formation Markers: Formation To s TVDss Estimated pore pressure, PPG(EMW) Base of Gubik Gravel 339 20 SV6 ].555 8.5 BPRF 1865 8.5 EOCU 2075 8.5 5V5 2170 8.5 SV4 2370 8.5 SV3 2770 8.5 SV2 2910 8.5 Fault 1 3200 n/a SVl 3220 8.5 UG4 3540 8.6 UG4A 3590 8.64 TD - 15 feet above UG-3~ 3900 8.6 TD Criteria TD in shale just above top UG3 coal bed, approx- imate) 275' below UG4A to . Do not enter UG3. Integrity Testing: q.z Test Point Depth Test Type EMW Surface Casin Shoe 20' min from surface shoe FIT 10.5 EMW Tar et S-400 Drilling Program Page 2 • • Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casing Size 113-3/8" Surface I Basis: ~ Lead: Based on conductor set at 100', 2000' of annulus in the permafrost C~ 250% excess and 475' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 500' of 9 5/8" x 16" Open hole +250' MD open hole volume (>500'TVD total} + 30°!° excess + 80' shoe track volume. Tail TOC: At -2250' Total Cement Volume: Lead 590 bbl / 33 3 #t / sks of Dowell ARTICSET Lite at 10.7 and cf/sk. Tail 133 b 0 ft / 4 ks of Dowell Premium `G' at 15.8 ppg and .1.~ cf/sk. Well Control: ,~ Surface hole will be drilled with a diverter. The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 3500 psi for casing integrity considerations, the ,- BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 1620 psi @ 3590' TVDss -Base Ugnu • Maximum surface pressure: 1255psi C surface ~ (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: 3500 psi (The casing and tubing will be tested to 3500) • Planned completion fluid: 9.1 ppg filtered brine / 6.8 ppg diesel l Disposal: • No annular disposal in this well • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. S-400 Drilling Program Page 3 • • DRILLING PROCEDURE SUMMARY Pre-Rig Work: 1. Weld an FMC landing ring for the FMC BB wellhead on the 20" conductor. Install two 4" outlets on the conductor pipe for surface cementing operations. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 7ES. 2. Nipple up diverter spool and riser. PU 5" DP as required and stand back in derrick. ~ 3. MU 16" drilling assembly with MWD/LWD and directionally drill surface hole to approximately 10' TVD above the base of the SV4 Sands. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the permafrost. • 500' of contingency 16" 65 #/ft casing is available to shut off surface flow if necessary. If required, the remainder of the surface hole should be drilled with a bi-center Hycalog on a 9 5/8" PDM. 4. Run and cement the 13-3/8", 68# x 9 5/8" 47# surface casing. • A Tam port collar may be run as a contingency if surface drilling is problematic. ~ 5. ND riser spool and NU casing /tubing head. NU BOPE and test to 3500 psi. ~ 6. MU 8 '/z" drilling assembly with MWD/GR/Res/Neu/Den/Caliper and RIH to float collar. Test the surface casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 8.9 ppg drilling fluid with 3% KCI. Drill new formation to 20' below 9-5/8" shoe and perform FIT to 10.5 ppg EMW. 8. Drill to +/- 4877' MD. Condition hole for e-line logging. ~ 9. POH, download LWD and caliper data. 10. RIH with bit, watermelon string mill and casing scraper clean out assembly to TD. Rotate to scrape c~ ing and dress shoe track with string mill. RIH to TD and swap over to Flo-Pro SF (~5% KCI). POOH. 11. Run 6-Arm caliper from TD to surface casing shoe. • Contingent plugback and re-drill with OBM if caliper indicates out of gauge hole. 12. PU and RIH with Weatherford expandable completion and liner hanger. Set liner hanger, test annulus to 500psi. POOH. 13. PU &RIH with expansion tools. Expand 7" expandable completion. 14. Open circulation sub and spot breaker across the screens. 15. Swap well over to 9.1 ppg brine from the top of 7" liner to surface. POOH with expansion tools. Download ~ Antech data. • Contingent E-line. Run USIT log across 7" expanded liner to determine formation compliance. Evaluate to determine if re-expansion is necessary. 16. Run the 7" 26# L-80 BTC-m completion with ESP and pressure gauge mandrel. 17. Install TWC and nipple down the BOPE. Nipple up tree adapter on top of wellhead with 7-1/16" valve on top. Remove TWC. 18. RU hot oil truck and freeze protect well by reversing in diesel to freeze .protect well from 2200' to surface. 19. Rig down and move off. S-400 Drilling Program Page 4 • • S-400 Drilling Program Job 1: MIRU Hazards and Contingencies - After fresh water broaching to nearby wells while drilling S-122, it is recommended to ensure cement to surface on all wells near new S-pad surface holes. Check the cement levels in the conductor x surface casing annuli in wells S-41, 42, 43, 44 and perform top jobs if necessary. j - S-Pad is designated as an H2S site. Seven wells on the east-west row of wells have measu d > ppm H2S. Well S-216, just north of S-400 produces the highest H2S on the pad atppm, measure 5/7/05. Standard Operating Procedures for H2S precautio s should be followed at all times. - The cellar area surrounding S-400 should be checked to ensure level prior to move in. - Check the landing ring height on the S-400 conductor prior to move-in. The BOP nipple up may need review for space out. Job 2: Drilling Surface Hole Hazards and Contingencies - There are two close approach issues in the surface hole. S-41 approaches with a center to center distance of 31' at 400' and S-42 approaches within 61' at 440'. Both wells pass major risk criteria - Hydrates/gas cut mud have been observed in wells drilled on S-Pad. These were encountered in the SV sands near planned casing point (2700'TVD +). - Review the pad data sheet for information on the S-122 surface water broaching. If this occurs while drilling S-400, a contingent 500' string of 16" 65#/ft is available to shut off the shallow zone. The hole will have to be opened to 17'h" while the casing is delivered and the 15.7 ppg Arctic Set cement ordered. The casing will not be suspended on surface, but held in place with~cement and rough cut just below the landing ring. The remainder of the surface hole will have to be drilled with a 12 ~/a" bit and under reamed to 16" to run the 13 3/8" x 9 5/8" surface casing. - The hole must be drilled at <2°/100' DLS across the section where the submersible pump will be set (-2400' TVD). Plan the directional work up hole and trip for BHA if necessary to achieve this objective. Job 3: Install Surface Casing Hazards and Contingencies - It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 13-3/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1000'MD to allow remedial cementing. Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies - Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Ugnu Sands. S-400 Drilling Program Page 5 • • - FIT: Perform a FIT (minimu 10.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max a ecte Ugnu reservoir pressure of 8.8 ppg and 9.0 ppg mud, a 10.5 ppg leak-off will an IN INIT kick tolerance. Contact Anchorage personnel if FIT is less than 10.5 ppg. Bas n off-set drilling data, a minimum leak-off of 13 ppg is expected at the 9 5/8" shoe. - Penetration Rate: A gauge hole is required for the success of the expandable liner. Keep ROP's below 200 fph through this section to avoid washouts or ledges. The 8-1/2" hole will be drilled in rotary mode only (no mud motor). A packed drilling assembly should provide minimum deviation from the planned trajectory. - Hole Quality: Open hole diameter must be at least 8.5" and must not exceed 9.25" in the sands and must be less than 9.1" for at least 6 feet within each shale section. DLS must be less than 7°/100' for the expandable screens. - Torque: This short, non-tortuous hole section drilled solely under rotary mode should not require lubricants. - Faults: One small fault, 40' throw, is mapped at 3200' TVDss just above the SV-1 sands. Lost circulation is not anticipated at this fault crossing. - Critical LWD Tools: It is critical to have the GR tool in order to identify all of the zones for accurate location of screens and zonal isolation devices. Therefore if the GR tool is lost, a trip will have to be made to change it out. The density based caliper will be used to give an immediate indication of hole quality but is not essential. - Well TD: The 7" expandable completion setting point will be determined by depth based on changes in GR/Res curves associated with the top UG4 markers. After seeing these tops, TD will be picked based on 15' MD above the UG3 coal bed. - BOP Test: Minimize the time between drilling 8'/z" hole and running expandable completion. Consider doing BOP test or cut and slip before drilling 8'/z" section Job 8: Wellbore Clean Up and Mud Conditioning, Caliper Log 8-1/2" Hole and 9-5/8" Casing: Hazards and Contingencies - - Wellbore Cleanliness: Damage to the screens while RIH could result in rupture during the expansion process or damage to the elastomers. A dedicated clean out trip will be run to TD including a string mill to dress any irregularities in the shoe track. - Casing Scraper: Residual cement left within the 9 5/8" casing will prevent setting of the upper completion packer and liner hanger. The Wellbore clean out trip will include a casing scraper to scrape the setting areas. - Mud Conditioning: Plugging of the screens while RIH could result in collapse of the screens or poor productivity during the life of the well. Mud will be conditioned over 250 US mesh shaker screens during the clean out trip. Mud condition will be verified by Weatherford using a mud flow through screens tester supplied by MI. - Dry Jobs/Slugging Pipe: slugging the pipe with barite laden mud can block screens. Keep pipe slugging to a minimum, use only calcium carbonate as weighting material in slugs (See MI mud program for slug recipe) and ensure that particle size is small enough to pass through screens by testing slug using Mud Flow-through Screen Tester. - Pipe 'Dope: Note that pipe dope is extremely detrimental to formation and expandable screens. Do not put dope on boxes white POOH after the clean out. Lightly dope pin threads with a paintbrush while running in hole. - Base Plan: Following the clean out trip a 6-arm caliper is required to determine accurate caliper log of the 8-1/2" open hole. The expansion team will use this data to determine 1} if the expandable will be run and 2) if run, the placement of ESS's (screen sections) and EZI's (external zonal isolation sections). S-400 Drilling Program Page 6 • • - USIT: A USIT will be run only if problems are encountered during the expansion process. - DPC: Running the logs on DP should not be required. Schlumberger will have their TLC tools lined up and ready to go at the shop, but not deployed to location. In the event that the log will not go to bottom on a-line, it will be run DP. Job 9: Run and Expand 7" Liner and Screens Hazards and Contingencies - Hole Quality: Open hole diameter must be at least 8.5" and must .not exceed 9.25" in the sands and must be less than 9.1" for at least 6 feet within each shale section - Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential sticking could be a problem if lost circulation is occurring or if the liner is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. - Mud Requirements: See attached MI Mud Program for WBM fluid properties and requirements. Soilds control and partical size distribution are of paramount importance. Everything that is put into the well bore must be able to pass through the screens. - Drill pipe: All drill pipe and drill collars must be drifted to 2.0" - Drill Collars: Thirty 4-3/4" DC's will be required to run the expandable liner. All DC's are to be cleaned and inspected prior to picking up. o Secure a short 4-3/4" DC from Anadrill. This short DC will be placed among the regular 4-/34" DC's the above the liner running tools. This short DC will be used with E-Line CCL for depth control to ensure the Expandabie liner is set at the correct depth. - Well control: Ensure that a TIW valve with a cross over from 7" 29ppf VAM TOP HT left hand thread to 7" BTC-M casing is made up to a joint of 7" BTC-M casing and ready in the pipe shed. - .Surface handling of Expandable Tubulars: o The expandable completion must be handled carefully to avoid damage. Surface scores can initiate failure during expansion. Damage to elastomers could prevent sealing. o Protective donuts will be applied to each ESS and EZI to prevent damage when moving up the skate. o Handling of the equipment will require working within 10 feet of the pipe handling machine to prevent damage when loaded onto the skate. A full risk assessment will be completed and reviewed by drill crews before picking up completion equipment. - Tubulars: All blank pipe and completion components will be shipped to location with storage compound on threads. All pipe will need to be drifted as per Weatherford procedures and threads cleaned. API modified compound will be put on connections. All connections are 7" VAM TOP HT 80ksi yield Special Clearance 90 left hand thread. All lower completion connections will be made using tongs dressed with non marking dyes and monitored using joint analyzed make up equipment. Tubular make up torques are specified in the detailed Weatherford procedures. Verify connection is made up correctly before moving to next joint. - Space Out and Depth Correlation: It is important to get the EZI devices into the optimum location in the open hole if they are to seal when expanded. Tallies must be discussed and double checked with BP Completion Engineer to eliminate errors. An electric line correlation S-400 Drilling Program Page 7 • • run will be carried out to double check the location of the expandable completion. - Running in hole: ensure string is self filling; if necessary fill from top every 5 stands and record volumes pumped to check if screens are plugging. Do not rotate at any time. Weatherford engineer and Baker liner hanger engineer to be on rig floor at all times. Minimize time during which string is stationary when completion is in open hole. Do not run into open hole if there is likely to be delays before hanger setting can be achieved. - Data Acquisition: It is vital to ensure that Epoch system is calibrated, functioning and set up to display key operating parameters on one screen on the rig floor and one remote screen in geo-shack. Expansion data will need to be saved, and downloaded from rig hard drive and processed in Anchorage into a usable ASCII format. Job 12: Run Completion Hazards and Contingencies - Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running the tubing. - Reference Running an ESP Completion RP Job 13: ND/NU/Release Rig Hazards and Contingencies - No hazards specific to this well have been identified for this phase of the well construction. S-400 Drilling Program Page 8 fi'ree : CIW 7" 5M Wellhead: FMC Big Bore 20" 131.45 ppf, X-56 I 105` NOTE: 7" Tubing 7", 26 # / ft., L-80 Mod Btrc. 13 3/8 68 ppf, L-80 BTCm 2800` '!(~~ 7" Hanger/Packer C 9 5!8" 40 ppf, L-80 BTCm 3316` 7" csg. shoe 4700` 8 1 /2" Driller's TD 4877` Orig. DF elev. = 64.4' Orig. Cellar elev. = 35.9' HES Symphony gauge w/ESP cable 2700` ~oenix Auto Y-Tool " " r--~ u 25 OD, 2.992 ID ~ntrilift 48 stage HC27000 5 ESP, 6.75" OD,` [~ ~ntrilift HST34B EHL PFS l al sectior ~ntrilift Series,HMIHE " a0 hp 7.25 OD motor 160v.l154amp, yntrilift PumpMate 2800` 3-1/2" WLEG, 2.813" ID 2840` ss 3V3 blank 2770 SV3 ESS 2800 SV3 blank 2880 top SV2 ESS 2938 SV2 blank 3025 SV2 ESS 3144 EZI 3225 SV1 blank 3240 SV1 ESS 3255 SV1 blank 3310 EZI(coal) 3567 UG4A blank 3582 UG4A ESS 3625 UG4A ESS 3663 UG4A blank 3720 UG4A ESS 3750 top MD 3,329 3,370 3,480 3,559 3,678 3,841 3,952 3,972 3,993 4,068 4,420 4,441 4,500 4,552 4,630 4,671 DATE REV. BY COMMENTS S-Pad 09101/05 PGS Proposed ESS completion (WP-06) Well S-400 WSW API NO: 50-xxx-xxxxx Q~ GY~1 r1~~TIr1A1 /ALCM ~~oo 27 20 ~ 25 n 5QAD I ~ I -N- s-1as ~ s-zc1 ^ 5-103 S--lC7 ^ S-1':3 ^ s-111 ^ 5-108 S-ti9 ^ S-1'Oi S-iC9 ^ s-1oz ^ s-loo ^ s-1o'I ^ s-'11 s ^ s-1zz ^ s-'v ^ s-1zo ^ S-2`3 ^ S-1'2i ^ s-z's ^ s-zco ^ J-44 -43 i 5_42 S-401 s-~', EXISTING PIT S-4.QQ S-BOOSTER TANK ~ ~~ ~~~ LEGEND AS-BUILT CONDUCTOR 34 " 35 36 ~a FROJEC he~~`` ARE A ~~ T.12N. 3 T.11 N, Z VICINITY MAP N.T.S. ' ^ EXISTING WELL ~ OF A ~ o" 49-" ~ °9~ °°°ao°°°ooeo°°°°eo<°oo°°ooo>°°o ~ °°o Richard F. Allison ° o ~,ff ~ °~' ~sr~ °° 10608 05 '~p p~ESS I pNA~ VpS~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT ' SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 10, 2005. NorES: 1. DA-~ 0.= SURVEYS: J'J~_Y 8-1Q 2005. 2. REEERENC- FI-LD ROOK: WO05-10 ;PGS 31-4-3). 3. COORDINATc_S AR A'!ASrCA S-ASE PLANE, ZONE-4 NAD 27. 4. ~rODE-1^ COORONA-ES AR. NAO-27. 5. MPJ S-?AD AVERAGE SCALE FACTOR IS: 0.9999165. 6. HORIZONTAL CONTROL !S BASED ON S-PAD MONUMENTS S-1 \ ., S -3 AND S-4. \ 7. VER KCAL CONTROL IS BASE) ON MON. 5-4. `LcVAT',ONS ARE BP EXPLORATION MEAN SEA LEVEL 'DATUM. I OCA-FD WITHIN PRnTRA(;TFD SFC_ 35_ -. 17 N_ R. 1i F.. UMIA- MERIDIAN- AI ASKA WELL. A.S.P. FLAN- GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS; POSI-ION(D.DD} . BOX ELEV. OFFSETS 40 Y-5,980,325.14 N 1010.07 7C° 21'17.639" 76.3548997° ~ 5 9 4,122' FSL S- 0 X= 618;930.10 E 529.84 149° 02'03.059" 149.0341831° ' 4;504' FEL Y-5,980,370.20 N 1010.25 70° 21'18.082" 70.3550228° 1' 36 4,167' FSI_ S-401 X= 618.,930.26 E 484.77 149° 02'03.034" 149.0341761° . 4,503' FEL Y-5,980,295.23 N 1010.05 70° 21'17.345" 70.3548181° 1' 36 4,092' FSL S-BOOSTER X- 618,930.09 E 559.75 149° 02'03.074" 149.0341872° . 4;505' FEL 6 ~ '~. •~~ U O1L ~~ dACOBS CHECKED: ALLISON X11 I {I I DATE: N f J 7/13/05 I IU n DRAWING. FRBQS WOS 07-0t PAD WOA S SHEET: ( ~~ (~ ] te (( qq ,GB ~~ - 1 ]/3'1/05 CHANGE GROUND EIEV. 1°CELLAR BOX ELEV. KWH LOH \\ \\ r _ ®~~LJO~ ~O AS-BUILT CONDUCTORS ~ p 7/'13/05 ISSUED FOR INFORMAT~N JJ RFA SCALE: r~-ioa WELLS 5-400 S-401 &8-BOOSTER ~ OF NO. SATE REVISION BV CHK , Schfumberger S-4~0 (P6l Proposal Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA ~ ~ C~ Structure I Slot: S-PAD / 5-400 well: Plan S-400 ~- ~-l MnC1,°'~ D ~1 u Borehole: Plan S-400 ~' G 41 ~/ UWIIAPI#: 50029 '-r` L~ Survey Name 1 Date: S-400 (P6) /November 14, 2005 Tort I AHD 1 DDI 1 ERD ratio: 43.118° / 2499.98 ft / 5.123 / 0.631 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LatlLong: N 70.35489974, W 149.03418320 location Grid NIE YIX: N 5980325.140 ftUS, E 618930.100 ftUS Grid Convergence Angle: +0.90960937° Grid Scale Factor: 0.99991607 Vertical Section Azimuth: 234.790° ) ~~ Vertical Section Origin: N 0.000 ft, E 0.000 ft ! c`_c% TVD Reference Datum: Rotary Table TVD Reference Elevation: 64.40 ft relative to MSL Sea Bed 1 Ground Level Elevation: 35.90 ft relative to MSL Magnetic Declination: 24.515° Total Field Strength: 57592.182 nT Magnetic Dip: 80.887° Dectination Date: January 05, 2006 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.515° • Measured Vertical Comments Inclination Azimuth Sub•Sea ND TVD NS EW DLS Taol Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft ft ft de 1100 ft de de 1100 ft de 1100 ft ftUS ftUS Klt U.UU U.W L34 Jy -64.40 U.UU U.UU U.UU U.UU U.UU -1Zb.Z1M U.UU U.UU bytSU3Zb.14 61tSy3U.1U N /U.3b425yy/4 W 14y .U341i531U KOP Bld 1/100 300.00 0.00 234. 79 235.60 300.00 0.00 0.00 0.00 0.00 -125.21M 0.00 0.00 5980325.14 618930.10 N 70.35489974 W 149 .03418320 400.00 1.00 234. 79 335.59 399.99 0.87 -0.50 -0.71 1.00 -125.21 M 1.00 0.00 5980324.63 618929.40 N 70.35489836 W 149 .03418899 Base Gubik 403.41 1.03 234. 79 339.00 403.40 0.93 -0.54 -0.76 1.00 -125.21M 1.00 0.00 5980324.59 618929.35 N 70.35489827 W 149. 03418939 500.00 2.00 234. 79 435.56 499.96 3.49 -2.01 -2.85 1.00 -125.21M 1.00 0.00 5980323.08 618927.28 N 70.35489424 W 149. 03420636 Bld 2/100 600.00 3.00 234. 79 535.46 599.86 7.85 -4.53 -6.42 1.00 -125.21 M 1.00 0.00 5980320.51 618923.76 N 70.35488737 W 149. 03423529 700.00 5.00 234. 79 635.21 699.61 14.83 -8.55 -12.11 2.00 -125.21 M 2.00 0.00 5980316.40 618918.12 N 70.35487638 W 149 .03428157 Bld 3/100 750.00 6.00 234. 79 684.98 749.38 19.62 -11.31 -16.03 2.00 O.OOG 2.00 0.00 5980313.58 618914.25 N 70.35486883 W 149. 03431336 800.00 7.50 234. 79 734.64 799.04 25.50 -14.70 -20.83 3.00 O.OOG 3.00 0.00 5980310.11 618909.51 N 70.35485958 W 149. 03435235 900.00 10.50 234. 79 833.39 897.79 41.14 -23.72 -33.61 3.00 O.OOG 3.00 0.00 5980300.89 618896.87 N 70.35483494 W 149 .03445612 1000.00 13.50 234. 79 931.20 995.60 61.93 -35.70 -50.60 3.00 O.OOG 3.00 0.00 5980288.64 618880.08 N 70.35480220 W 149 .03 1100.00 16.50 234. 79 1027.78 1092.18 87.81 -50.62 -71.74 3.00 O.OOG 3.00 0.00 5980273.39 618859.18 N 70.35476144 W 149. 4 03 1200.00 19.50 234. 79 1122.87 1187.27 118.70 -68.44 -96.99 3.00 O.OOG 3.00 0.00 5980255.18 618834.22 N 70.35471277 W 149. 034 2 1300.00 22.50 234. 79 1216.22 1280.62 154.54 -89.10 -126.27 3.00 O.OOG 3.00 0.00 5980234.06 618805.27 N 70.35465633 W 149. 03520845 1400.00 25.50 234. 79 1307.56 1371.96 195.21 -112.54 -159.50 3.00 O.OOG 3.00 0.00 5980210.09 618772.42 N 70.35459228 W 149. 03547826 1500.00 28.50 234. 79 1396.65 1461.05 240.60 -138.71 -196.59 3.00 O.OOG 3.00 0.00 5980183.34 618735.76 N 70.35452078 W 149. 03577942 1600.00 31.50 234. 79 1483.25 1547.65 290.59 -167.53 -237.44 3.00 O.OOG 3.00 0.00 5980153.87 618695.37 N 70.35444204 W 149. 03611110 SV6 1685.35 34.06 234. 79 1555.00 1619.40 336.80 -194.17 -275.19 3.00 O.OOG 3.00 0.00 5980126.64 618658.05 N 70.35436926 W 149. 03641764 1700.00 34.50 234. 79 1567.11 1631.51 345.05 -198.93 -281.93 3.00 O.OOG 3.00 0.00 5980121.78 618651.38 N 70.35435626 W 149. 03647238 1800.00 37.50 234. 79 1648.00 1712:40 403.82 -232.81 -329.96 3.00 O.OOG 3.00 0.00 5980087.14 618603.91 N 70.35426369 W 149. 03686228 1900.00 40.50 234. 79 1725.70 1790.10 466.75 -269.09 -381.37 3.00 O.OOG 3.00 0.00 5980050.05 618553.08 N 70.35416458 W 149. 03727974 End Bld 1987.27 43.12 234. 79 1790.74 1855.14 524.92 -302.63 -428.90 3.00 O.OOG 3.00 0.00 5980015.77 618506.09 N 70.35407296 W 149. 03766565 Base Perm 2089.00 43.12 234. 79 1865.00 1929.40 594.45 -342.71 -485.72 0.00 O.OOG 0.00 0.00 5979974.79 618449.93 N 70.35396344 W 149. 03812692 WeIlDesign Ver SP 1.0 Bld( doc40x_56) S-400\Plan S-400\Plan S-400\S-400 (P6) Generated 11/14/2005 3:50 PM Page 1 of 2 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft k ft ft ft de 1100 ft de de 1100 ft de 1100 ft ftUS ftUS tV(.U LJ/b.by 4J. 7L L:f4 ./'J LU/b .UV L7JJ.4V /'J7. U'J -4JO. UU -b40.JY U.UU U.UU(i U.UU U.UU bJ/yifbtl.JU b1tfL'J7.Uy N/U. :fb.fb5:f/7 W74y.UJ`J4J74U SV5 2506.83 43. 12 234 .79 2170 .00 2234.40 880 .05 -507. 36 -719.07 0.00 O.OOG 0.00 0.00 5979806.47 618219.23 N 70. 35351359 W 149.04002150 SV4 2780.83 43. 12 234 .79 2370 .00 2434.40 1067. 32 -615. 32 -872.09 0.00 O.OOG 0.00 0.00 5979696.10 618067.96 N 70. 35321859 W 149.04126381 13-3/8" x 9-5/8"Xover 2816.00 43. 12 234 .79 2395 .68 2460.08 1091 .36 -629. 18 -891.74 0.00 O.OOG 0.00 0.00 5979681.93 618048.54 N 70. 35318072 W 149.04142329 9-5/8" Csg Pt 3315.11 43. 12 234. 79 2760 .00 2824.40 1432 .51 -825. 86 -1170.48 0.00 O.OOG 0.00 0.00 5979480.88 617772.97 N 70. 35264332 W 149.04368620 SV3 3328.81 43. 12 234 .79 2770 .00 2834.40 1441. 87 -831. 25 -1178.14 0.00 O.OOG 0.00 0.00 5979475.36 617765.41 N 70. 35262857 W 149.04374831 SV2 3506.91 43. 12 234. 79 2900 .00 2964.40 1563. 60 -901. 43 -1277.60 0.00 O.ODG 0.00 0,00 5979403.62 617667.08 N 70. 35243681 W 149.04455574 S-400 Tgt 3523.35 43 .12 234 .79 2912 .00 2976.40 1574 .83 -907 .91 -1286.78 0.00 O.OOG 0.00 0.00 5979397.00 617658.00 N 70 .35241911 W 149.04463027 SV1 3945.29 43. 12 234. 79 3220. 00 3284.40 1863. 24 -1074. 18 -1522.43 0.00 O.OOG 0.00 0.00 5979227.02 617425.04 N 70. 35196476 W 149.04654320 UG4 4383.68 43. 12 234. 79 3540 .00 3604.40 2162. 88 -1246. 92 -1767.26 0.00 O.OOG 0.00 0.00 5979050.43 617183.00 N 70. 35149269 W 149.048 7 UG4A 4452.18 43. 12 234. 79 3590. 00 3654.40 2209. 70 -1273. 91 -9805.52 0.00 O.OOG 0.00 0.00 5979022.84 617145.18 N 70. 35141893 W 149.04 4876.87 43. 12 234. 79 3900 .00 3964.40 2499. 97 -1441. 26 -2042.70 0.00 O.OOG 0.00 0.00 5978851.76 616910.71 N 70. 35096159 W 149.050 5 TD / 7" Csg Pt 4876.88 43.12 234.79 3900.01 3964.41 2499.98 -1441.26 -2042.71 0.00 O.OOG 0.00 0.00 5978851.76 616910.70 N 70.35096158 W 149.05076631 WeIlDesign Ver SP 1.0 Bld( doc40x_56) S-400\Plan S-400iPlan S-400\S-400 (P6) Generated 11/14/2005 3:50 PM Page 2 of 2 F Schlumberger WELL S-400 (P6) FIFLD Prudhoe Bay Unit - WOA STRUCTURE S-PAD Ma9ndic Paremam,a Sutlace Localbn NAD2] Alaska 51a1e Planes, Zone 04. US Feel Mecepa neous Motlel: BGGM 2005 D'q'. 8088]° Dale: January 05. 2006 lal: M0211].639 NoMing: 5980325.14 flub G,itl DOnV: s0.9098093]° 6bL 5-000 TVD Ref: Rdary Tale ~64.40fl a5ova M6L) Map Dec: •26515° FS: 5]5922 nT Lon: Wt4923.080 Easling: 618930.10 M1S Scab Fad: 0.99991606]6 Plan: S<00 ~Pfi) Sny Dale: Nmam5er 14, 2005 0 500 1000 1500 2000 2500 0 500 1000 1500 0 0 c u 2000 m U 2500 3000 3500 4000 0 500 1000 1500 2000 2500 Vertical Section (ft) Azim = 234.79°, Scale = 1(in):500(ft) Origin = 0 N/-S, 0 E/-V 0 500 1000 1500 2000 2500 3000 3500 4000 Schlumberger WELL FIELD STRUCTURE S-400 (P6) Prudhoe Bay Unit - WOA S-PAD Ma9nelk Parameters Surlace Location NAD2]Alaska Slate Planes, ZOnB 04, US Feet Miscellaneous Motel: BGGM 20o5 Dip: 80.88]" January o5, 2006 N]0211].fi39 nbing: 5980325.14 NUS Grid COnv; X09096093]° SbL 3-000 TVD ReI: Rotary Table (64A0 Nabove MSL) Meg Dec'. x24.515° FS:e 5]5922 nT Lon: W14923.060 Easling: 19930.10 flUS Scala Fac1:099991606]6 Plan: S~4o0 (P6) Srvy Dale: November 14, 2005 -2100 -1800 -1500 -1200 -900 -600 -300 0 0 -300 n n n z -600 0 0 M c I I N N ~ -900 v v v -1200 -1500 0 -300 -600 -900 -1200 -1500 • 2100 -1800 -1500 -1200 -900 -600 -300 0 «< W Scale = 1(in):300(ft) E »> . Plan 5-400/Plan S-440 CSia(D 27 26 25 m - m S PAD _N_ ry N I S-104i ■ [10 S-105 ■ 34 35 36 5-1141 ■ PROJECT S-106 ■ _ Si PLANT 4`,/ ‘.0 AREA S-201 • ..0 / S-103 111 1 ' / T.12N. S-107 • t .1 T.11N, 2 S-113 ■ s-111 ■ LEGEND VICINITY MAP N.T.S. S-108 * -+-AS-BUILT CONDUCTOR 5-119 • +,1NVIVitiii S-110i * inEXISTING WELL S-109 ■ At...OFA4„s1I ^1 S-102 ■ 4\,'' •.T tiS-100 ■ z:-:7.- 5-101 5-101 ■ c---I #„ 49� s °. # 40, S-115 • _ .9.>°«.«............. S-122 ■ Cq _ ^'- - i s-120 ■ iro ".chore F. Allison / ,' S-213 • ` "», 0608 .. • S-112i ■ D gb S-216 IN iDNA 4 - S-200 ■ Ifq_fl - \ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED S-44 IL TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT J S-43 j MTHIS PLAT SENTS A SURVEY ADE BY MEEOREUNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE 5-42 CORRECT AS OF JULY 10, 2005. S-401 S-41 NOTES: 1. DATE OF SURVEYS: JULY 8-10, 2005. EXISTING PIT S-400- - 2. REFERENCE FIELD BOOK: W005-10 (PCS 31-43). S-BOOSTER 4- 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. S-PAD 6. HORIZONTAL CONTROL IS BASED ON S-PAD MONUMENTS S-1, TANK S-3 AND 5-4. '4 7. VERTICAL CONTROL IS BASED ON MON. S-4. ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. LOCATED WITHIN PROTRACTED SEC. 35, T. 12 N., R. 12 E., UMIAT MERIDIAN, ALASKA Y WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION i NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEV. OFFSETS 4 Y=5,980,325.14 N 1010.07 70'21'17.639" 70.3548997' 4,122' FSL ri 5-400 X= 618,930.10 E 529.84 149'02'03.059" 149.0341831' 35.9' 4,504' FEL f S-401 Y=5,980,370.20 N 1010.25 70'21'18.082" 70.3550228' 36.1' 4,167' FSL X= 618,930.26 E 484.77 149'02'03.034" 149.0341761' 4,503' FEL ° { S-BOOSTER Y=5,980,295.23 N 1010.05 70'21'17.345" 70.3548181' 361' 4,092' FSL X= 618,930.09 E 559.75 149'02'03.074" 149.0341872' 4,505' FEL F. Robert r*Aw,_ aAcoes __ ,-.. till ALLISON bp (Alt 7/13/05 ORASYSIvt`.- M _ rRaa5 wos 07-eg WOA S-PAD SHEET. _.___.__ -. .-..._.__ t JO6 NO. X50' AS-BUILT CONDUCTORS y `--- ::: , 'l slut'=l'= 100, WELLS S-400, S-401 & S-BOOSTER i OF 1 f 0_7f13Z65 1550E0 FOR 1NfpRMA7fON JJ R7'A .9 NO. OATS REVISION RY CHH may*.yw* m'+ C7 Oilfield Services, Alaska Schlumberger Drilling & Measurements • Schtamber~r 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Monday, November 14, 2005 Phil Smith Prudhoe Bay S-400 (P6) BP Exploration Alaska Nabors 7ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial .search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Prooram: Instrument Type Start Depth End Depth GYD GC SS 28.50'md 900.00'md MWD 900.00'md 2,200.00'md MWD + IFR + MS 900.00'md 4,876.88'md Close Approach Analysis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: _ Scott DeLapp 11/14/05 BP Alaska Anticollision Report Company: BP Amoco Date: 11/14/2005 Time: 15:51:21 Page: 1 Field: Prudhoe Bay Reference Site: PB S Pad Co-ordinate(NE) Refe rence: Well: Plan S-400, Tru e North Keference Well: Plan S-400 Vertical (CV D) Reference: S-400 Pl an 64.4 Reference Wellpath: Plan S-400 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Refe rence: Principal Plan & PLANNED PROGRA Interpolation Method: MD Interval: 20.00 ft Error Model: ISCWSA Ellipse ~ '. Depth Range: 28.50 to 4876.88 ft Scan Method: Trav Cylinder No rth i Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing ~ Survey Program for Definitive Wellpath Date; 9/13/2004 Validated: No Version: 3 Planned From To ~ Survey Toolcode Tool Name ft ft _ _ 28.50 900.00 Planned: Plan #6 V2 GYD-GC-SS Gyrodata gyro single shots i 900.00 2300.00 Planned: Plan #6 V2 MWD MWD - Standard 900.00 4876.88 Planned: Plan #6 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points ~ DID CVD Diameter Hole Size Name ' ft ft in in 2816.00 2460.08 13.375 16.000 13 3/8" I 3315.11 2824.40 9.625 12.250 9 5/8" 4876.88 3964.41 7.000 8.500 7" Summary <------------------- O ffset ~y'ellpath ----------------> Reference Offset Ctr-Ctr No-Go Allo~~mblc I~ Site 1Ve11 Wellpath MD Dell Distance Arcs Deviation N`arning ' ft ft ft ft ft ', PB S Pad Plan S-203 Plan S-203 (East) V3 P 1555.85 1420.00 865.62 33.44 832.18 Pass:. Major Risk '~ PB S Pad Plan S-203 Plan S-203 (West) V5 P 1754.35 1660.00 817.82 39.84 777.98 Pass: Major Risk ', PB S Pad Plan S-208 Plan S-208 VO Plan: S- 561.17 600.00 1453.10 11.95 1441.15 Pass: Major Risk PB S Pad Plan S-214 Plan S-214 V1 Plan: S- 2899.05 3140.00 216.16 101.96 114.19 Pass: Major Risk I ', PB S Pad Plan S-401 Plan S-401 V2 Plan: PI 637.21 640.00 45.11 12.43 32.69 Pass: Major Risk l PB S Pad S-01A S-01A V1 1627.10 1580.00 389.41 37.08 352.33 Pass: Ma~or Risk i J PB S Pad S-01 B S-01 B V1 1623.82 1580.00 389.33 36.97 352.36 Pass: Major Risk PB S Pad S-01 S-01 V1 1645.45 1600.00 372.82 45.36 327.47 Pass: Major Risk ', PB S Pad S-02AP61 S-02AP61 V1 1439.75 1420.00 448.38 27.95 420.43 Pass: Major Risk PB S Pad S-02A S-02A V1 1439.75 1420.00 448.38 27.95 420.43 Pass: Major Risk I PB S Pad S-02 S-02 V1 1438.65 1420.00 448.34 27.92 420.42 Pass: Major Risk PB S Pad S-03 S-03 V1 1242.78 1240.00 509.54 22.56 486.98 Pass: Major Risk PB S Pad S-04 S-04 V1 1060.33 1080.00 562.30 19.64 542.67 Pass: Major Risk ', PB S Pad S-05APB1 S-05AP61 V1 572.90 580.00 638.03 13.44 624.58 Pass: Major Risk I PB S Pad S-05A S-05A V1 572.90 580.00 638.03 13.44 624.58 Pass: Major Risk !, PB S Pad S-05 S-05 V1 566.63 580.00 637.99 13.31 624.67 Pass: Major Risk ~~ PB S Pad S-06 S-06 V1 588.56 600.00 717.91 11.77 706.14 Pass: Major Risk I PB S Pad S-07A S-07A V1 694.92 720.00 803.48 13.74 789.74 Pass: Major Risk PB S Pad S-07 S-07 V1 694.92 720.00 803.48 13.74 789.74 Pass: Major Risk PB S Pad S-08 S-08 V1 485.91 500.03 894.80 12.93 881.87 Pass: Major Risk PB S Pad S-08 S-08A V2 485.91 500.03 894.80 12.93 881.87 Pass: Major Risk PB S Pad S-08 S-08B V3 485.91 500.03 894.80 12.93 881.87 Pass: Major Risk PB S Pad S-09 S-09 V1 483.80 500.00 991.03 11.37 979.66 Pass: Major Risk PB S Pad S-100 S-100 V10 319.12 320.00 316.30 5.80 310.50 Pass: Major Risk PB S Pad S-101 S-101 V3 686.07 700.00 289.90 13.68 276.22 Pass: Major Risk PB S Pad S-101 S-101 PB1 V9 686.07 700.00 289.90 13.57 276.33 Pass: Major Risk PB S Pad S-102 S-102 V11 240.19 240.00 331.60 4.79 326.81 Pass: Major Risk ' PB S Pad S-102 S-102L1 V5 240.19 240.00 331.60 4.79 326:81 Pass: Major Risk PB S Pad S-102 S-102L1 PB1 V7 240.19 240.00 331.60 4.90 326.70 Pass: Major Risk PB S Pad S-102 S-102P61 V14 240.19 240.00 331.60 4.79 326.81 Pass: Major Risk PB S Pad S-103 S-103 V6 433.53 440.00 451.50 7.24 444.25 Pass: Major Risk ~, PB S Pad S-104 S-104 V1 337.85 340.00 525.55 6.82 518.73 Pass: Major Risk PB S Pad S-105 S-105 V5 337.33 340.00 512.71 5.98 506.73 Pass: Major Risk I PB S Pad S-106 S-106 V2 274.21 280.00 481.36 6.44 474.92 Pass: Major Risk ~, PB 5 Pad S-106 S-106P61 V12 274.21 280.00 481.36 6.28 475.08 Pass: Major Risk ~, PB S Pad S-107 S-107 V36 390.40 400.00 436.37 8.20 428.17 Pass: Major Risk I, PB S Pad S-108 S-108 V6 408.75 420.00 387.11 7.46 379.65 Pass: Major Risk i ', PB S Pad S-109 S-109 V8 549.54 560.00 345.30 10.05 335.25 ~ Pass: Major Risk PB S Pad S-109 S-109PB1 V2 549.54 560.00 345.30 10.05 335.25 Pass: Major Risk ', PB S Pad S-10APB1 S-10AP61 V1 480.62 499.96 1085.53 10.38 1075.15 Pass: Major Risk ', PB S Pad S-10A - - S-10A V1 -- 499.00 520.00 1085.84 10.60 1075.23 Pass: Major Risk I'' -- _ --- -_ _ _ BP Alaska • Anticollision Report Company-: BP Amoco Date: 1 111 4/20 0 5 Time: 15:51:21 Page: 2 Field: Prudhoe Bay Reference Site: PB S Pad Co-ordinate(NE) Refe rence: Well: Plan S-400, Tru e North Reference Wcll: Plan S-400 Vertical ('1VD) Reference: S-400 P lan 64.4 Reference Wcllpath: Plan S-400 Db: Oracle Summar~~ <---------- Offset ~~'ellpath -- ---------> Reference Offset Ctr-Ctr No-Co Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft j PB S Pad S-10 S-10 V1 480.62 499.96 1085.53 10.38 1075.15 Pass: Major Risk ~~, PB S Pad S-110 S-110 V18 448.70 460.00 356.77 9.65 347.12 Pass: Major Risk PB S Pad S-111 S-111 V10 279.98 280.00 407.78 5.38 402.40 Pass: Major Risk PB S Pad S-111 S-111 P61 V5 279.98 280.00 407.78 5.38 402.40 Pass: Major Risk PB S Pad S-111 S-111 P62 V2 279.98 280.00 407.78 5.38 402.40 Pass: Major Risk i, PB S Pad S-112 S-112 V20 431.78 440.00 207.78 8.70 199.08 Pass: Major Risk PB S Pad S-113 S-113 V14 294.05 300.00 421.64 6.36 415.28 Pass: Major Risk PB S Pad S-113 S-113A V3 294.05 300.00 421.64 6.20 415.44 Pass: Major Risk PB S Pad S-113 S-1136 V6 294.05 300.00 421.64 6.20 415.44 Pass: Major Risk PB S Pad S-114 S-114 V13 351.55 360.00 497.07 7.52 489.54 Pass: Major Risk PB S Pad S-114 S-114A V6 351.55 360.00 497.07 7.37 489.70 Pass: Major Risk PB S Pad S-115 S-115 ST V1 Plan: Plan 610.39 620.00 280.81 10.79 270.03 Pass: Major Risk PB S Pad S-115 S-115 V7 610.39 620.00 280.81 10.69 270.12 Pass: Major Risk PB S Pad S-116 S-116 V6 536.42 540.00 151.00 9.44 141.56 Pass: Major Risk PB S Pad S-117 S-117 V4 514.33 520.00 256.15 9.45 246.70 Pass: Major Risk PB S Pad S-118 S-118 V5 477.27 480.00 165.94 8.36 157.58 Pass: Major Risk ' PB S Pad S-119 S-119 V7 360.14 360.00 376.75 6.99 369.76 Pass: Major Risk I PB S Pad S-11 S-11 V4 496.10 520.00 1183.43 11.05 1172.39 Pass: Major Risk PB S Pad S-11 S-11A V1 496.91 520.00 1183.45 11.07 1172.39 Pass: Major Risk PB S Pad S-11 S-11 B V1 497.37 520.00 1183.46 11.08 1172.39 Pass: Major Risk ', PB S Pad S-120 S-120 V4 495.30 500.00 240.04 9.50 230.54 Pass: Major Risk ', I PB S Pad S-122 S-122 V9 684.88 700.00 266.93 11.85 255.08 Pass: Major Risk I PB S Pad S-122 S-122P61 V4 684.88 700.00 266.93 11.85 255.08 Pass: Major Risk ', ', PB S Pad S-122 S-122P62 V2 684.88 700.00 266.93 11.85 255.08 Pass: Major Risk ', PB S Pad S-122 S-122P63 V2 684.88 700.00 266.93 11.85 255.08 Pass: Major Risk i PB S Pad S-123 S-123 V10 203.94 200.00 742.41 6.68 735.73 Pass: Major Risk I PB S Pad S-12A S-12A V1 417.44 440.00 1279.06 9.62 1269.44 Pass: Major Risk PB S Pad l S-12 S-12 V1 77.28 80.00 1286.49 2.16 1284.34 Pass: Major Risk I i PB S Pad S-13 S-13 V1 420.41 440.00 1390.87 8.18 1382.68 Pass: Major Risk PB S Pad S-14 S-14 V5 592.08 640.00 1497.99 19.71 1478.28 Pass: Major Risk PB S Pad S-14 S-14A V3 592.08 640.00 1497.99 19.71 1478.28 Pass: Major Risk '~ PB S Pad S-15 S-15 V2 2014.78 1900.04 650.24 51.70 598.54 Pass: Major Risk I ~ PB S Pad S-16 S-16 V1 2121.48 1980.00 735.92 55.39 680.52 Pass: Major Risk ' PB S Pad S-17 S-17 V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk I PB S Pad S-17 S-17A V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk PB S Pad S-17 S-17AL1 V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk I PB S Pad S-17 S-17APB1 V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk ~I PB S Pad ~ S-17 S-176 V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk i PB S Pad S-17 S-17C V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk I I PB S Pad S-17 S-17CP61 V2 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk ii PB S Pad S-17 S-17CP62 V1 2221.68 2060.00 819.87 57.80 762.07 Pass: Major Risk ~, PB S Pad S-18 S-18 V1 1138.55 940.00 1153.66 23.31 1130.35 Pass: Major Risk '~ PB S Pad S-18 S-18A V16 1142.94 940.00 1153.77 23.15 1130.62 Pass: Major Risk PB S Pad S-19 S-19 V1 1520.18 1500.01 415.21 31.73 383.48 Pass: Major Risk PB S Pad S-200 Plan S-200A East V3 PI 476.47 480.00 180.86 8.37 172.49 Pass: Major Risk ', PB S Pad S-200 Plan S-200A West V1 PI 417.68 420.00 180.13 7.37 172.76 Pass: Major Risk PB S Pad S-200 S-200 V1 415.65 420.00 180.10 7.23 172.87 Pass: Major Risk i PB S Pad S-200 S-200PB1 V10 415.65 420.00 180.10 7.23 172.87 Pass: Major Risk PB S Pad S-201 S-201 V2 279.98 280.00 465.68 5.37 460.31 Pass: Major Risk '' PB S Pad S-201 S-201 PB1 V11 279.98 280.00 465.68 5.21 460.46 Pasx Major Risk i PB S Pad S-20 S-20 V4 1224.56 1199.99 463.51 22.28 441.23 Pass: Major Risk PB S Pad S-20 S-20A V2 1224.56 1199.99 463.51 22.28 441.23 Pass: Major Risk PB S Pad S-213 S-213 V9 474.45 480.00 225.00 7.84 217.16 Pass: Major Risk PB S Pad S-213 S-213A V22 478.43 480.00 225.06 7.90 217.16 Pass: Major Risk ', PB S Pad S-213 S-213AL1 V9 478.43 480.00 225.06 7.90 217.16 Pass: Major Risk PB S Pad S-213 S-213AL1-01 V7 478.43 480.00 225.06 7.90 217.16 Pass: Major Risk PB S Pad S-213 S-213AL2 V5 478.43 480.00 225.06 7.90 217.16 Pass: Major Risk PB S Pad S-213 S-213AL3 V7 478.43 480.00 225.06 7.90 217.16 Pass: Major Risk ', ' PB S Pad S-215 S-215 V9 1661.13 1520.00 777.09 33.75 743.34 Pass: Major Risk I PB S Pad S-216 S-216 V2 1092.75 1120.00 177.14 19.54 157.59 Pass: Major Risk PB S Pad S-21 S-21 V1 1143.39 1140.00 526.86 19.83 507.03 Pass: Major Risk PB S Pad S-22A S-22A V1 1576.53 1540.00 395.82 30.54 365:28 Pass: Major Risk PB S Pad S-226 S-226 V2 1576.53 1540.00 395.82 30.54 365.28 Pass: Major Risk BP Ala ka s Anticollision Report Company: BP Amoco Date: 11!14/2005 Timr. 15:51:21 Page: 3 Field: Prudhoe Bay Reference Site: PB S Pad Co-ordinate(NE) Refe rence: Well: Plan S-400, Tru e North Reference Wcll: Plan S-400 Vertical ('f'VD) Reference: S-400 P lan 64.4 Reference Wellpa th: Plan S-400 Db: Oracle Summart < ------------ - Offset ~'Vellpath ----____~_-> Reference Offset Ctr-Ctr No-Go - Allo~~able Site Well Wellpath MD MD Distance Area Deviation ~L'arning ' ft ft ft ft ft PB S Pad S-22 S-22 V1 1576.54 1540.00 395.82 30.54 365.28 Pass Major Risk PB S Pad S-23 S-23 V1 1311.39 1300.00 485.90 22.47 463.43 Pass: Major Risk PB S Pad S-24 S-24 V5 1075.73 1080.00 548.69 17.77 530.92 Pass: Major Risk j PB S Pad S-24 S-24A V1 1078.07 1080.00 548.74 17.81 530.92 Pass: Major Risk PB S Pad S-24 S-246 V2 1078.07 1080.00 548.74 17.81 530.92 Pass: Major Risk PB S Pad S-25AP61 S-25APB1 V2 1036.08 1060.00 581.04 26.67 554.37 Pass: Major Risk PB S Pad S-25A S-25A V1 891.89 900.00 591.37 15.69 575.67 Pass: Major Risk PB S Pad S-25 S-25 V1 891.89 900.00 591.37 15.69 575.67 Pass: Major Risk PB S Pad S-26 S-26 V1 849.34 860.00 616.07 14.11 601.96 Pass: Major Risk I i PB S Pad S-27 S-27 V1 729.31 740.00 664.08 13.34 650.74 Pass: Major Risk , PB S Pad S-27 S-27A V3 729.31 740.00 664.08 13.34 650.74 Pass: Major Risk PB S Pad S-27 S-276 V7 728.52 740.00 664.07 13.06 651.00 Pass: Major Risk PB S Pad S-28 S-28 V4 669.02 680.00 691.27 11.97 679.30 Pass: Major Risk PB S Pad S-28 S-28A V1 669.02 680.00 691.27 11.97 679.30 ~ Pass: Major Risk PB S Pad S-28 S-286 V2 670.16 680.00 691.30 12.00 679.30 Pass: Major Risk PB S Pad S-28 S-286PB1 V7 670.16 680.00 691.30 12.00 679.30 Pass: Major Risk j PB S Pad S-29AL1 S-29AL1 V1 522.06 540.00 924.34 10.17 914.17 Pass: Major Risk ~ PB S Pad S-29A Plan S-29AL2 VO Plan: 431.81 440.00 922.93 8.46 914.47 Pass: Major Risk PB S Pad S-29A S-29A V1 522.06 540.00 924.34 10.17 914.17 Pass: Major Risk PB S Pad S-29 Plan S-296 V1 Plan: S- 431.81 440.00 922.93 8.56 914.37 Pass: Major Risk ~ I PB S Pad S-29 S-29 V1 522.06 540.00 924.34 10.17 914.17 Pass: Major Risk PB S Pad S-30 S-30 V1 589.27 600.00 775.67 11.12 764.55 Pass: Major Risk '~ PB S Pad S-31A S-31A V3 545.99 560.00 830.62 9.82 820.80 Pass: Major Risk PB S Pad S-31 S-31 V1 545.99 560.00 830.62 9.82 820.80 Pass: Major Risk PB S Pad S-32 S-32 V1 428.96 440.00 1051.91 10.64 1041.27 Pass: Major Risk PB S Pad S-33 S-33 V1 466.51 480.00 861.33 8.47 852.85 Pass: Major Risk PB S Pad S-34 S-34 V1 385.85 400.00 1119.78 7.00 1112.78 Pass: Major Risk 1 PB S Pad S-35 S-35 V1 424.25 440.00 1152.40 7.28 1145.12 Pass: Major Risk PB S Pad S-36 S-36 V1 385.67 400.00 1217.49 6.83 1210.65 Pass: Major Risk PB S Pad S-37 S-37 V1 421.21 440.00 1247.81 7.21 1240.61 Pass: Major Risk ~ PB S Pad S-38 S-38 V1 444.20 460.00 1018.78 7.63 1011.15 Pass: Major Risk I PB S Pad S-40A S-40A V1 2160.43 1960.00 863.13 52.13 811.00 Pass: Major Risk 'I PB S Pad S-40 S-40 V1 2160.43 1960.00 863.13 52.13 811.00 Pass: Major Risk ~ PB S Pad S-41 L1 S-41 L1 V1 411.32 420.00 31.14 6.78 24.36 Pass: Major Risk ~ PB S Pad S-41 P61 S-41 PB1 V1 411.32 420.00 31.14 6.78 24.36 Pass: Major Risk PB S Pad S-41 S-41 V1 411.32 420.00 31.14 6.78 24.36 Pass: Major Risk PB S Pad S-42PB1 S-42PB1 V1 450.11 460.00 60.56 8.28 52.28 Pass: Major Risk PB S Pad S-42 S-42 V2 450.11 460.00 60.56 8.28 52.28 Pass: Major Risk PB S Pad S-43L1 S-43L1 V2 355.77 360.00 92.01 6.66 85.35 Pass: Major Risk PB 5 Pad S-43 S-43 V3 355.77 360.00 92.01 6.50 85.50 Pass: Major Risk PB S Pad S-44L1 P61 S-44L1 P61 V3 416.73 420.00 121.58 7.03 114.55 Pass: Major Risk PB S Pad S-44L1 S-44L1 V5 416.73 420.00 121.58 6.88 114.70 Pass: Major Risk L PB S Pad S-44 S-44 V10 416.73 420.00 121.58 6.88 114.70 Pass: Major Risk Field: Prudhoe Bay Site: PB S Pad Well: Plan 5-400 Wellpath: Plan 5-400 ~ ~I loo I o0 tau Travelling Cylinder Azimuth (TFO+AZ1) [deg] vs Centre to Centre Separation [100Nin] i 0 00 DD, D D ~~ n rf f~ Site: PB S Pad Drilling Target Conf.: 95% Description: Map Northing: 5979397.00 ft Map Easting :617658.00 ft Latitude: 70°2 I'08.709N Shape: Circle 0 0 Target: S-400 Target 1 • Well: Plan S-400 Based on: Planned Program Vertical Depth: 2912.00 ft below Mean Sea Level Local +N/-S: -907.90 ft Local +E/-W: -1286.78 ft Longitude: 149 °02'40.669 W Radius: 100 ft -h ~r ~l 0 0 0 0 -°C -IC 0 0 0 0 - o • • SONDRA D_ STEWMAN BP EXPLORATION AK RNC as-snz5z 1~ PO BOX 196612 MB 7-5 Mastercard Check" ANCHORAGE, AK 9951`9-661.2 DATE... ~ ~'"` PAY TO THE ORDER OF ~~" : $ { ~ i ~ ~'`.~ First National Bank Alaska a DOLLARS Anchorage, AtK ,995801 (c~'~ MEMO~~~ C...~` ~ W _<<`_ ~_ ~: i 25 200060~:4914~n6 2 2:7m L 564u 0 13 5 a • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER(pARAGRAPHS TO BE INCLUDED IN TIL4NSyIITTAL LETTER WELL NA11~IE `~~!~--~ `' 6 " " CHECK WHAT i ADD-ONS ~ CLUE APPLIES (OPTIONS) nt of ~ MULTI The permit is for a new welibore segme ~ LATERAL existing well , ~ (If API number ' Permit No, API No. Production should continue to be reported as ~ I ' last two (2) digits a function of .the original API number stated ! ~ are between 60-69) I above. i ~ PILOT HOLE ! In accordance with 20 AAC 25.005(f), all , (per ; records, data and logs acquired for the pilot ; hole must be clearly differentiated in both ~ I ~ % name (name on permit plus PH) ! i and API number (50 j ~ ! 70/80) from records, data and logs acquired {for well (name on permit). ~ ~ f t to full b ; SPACING jec !The permit is approved su EXCEPTION compliance with 20 AAC 25.055. Approval to I perforate and produce/infect is contingent ~ ~ upon issuance of a conservation order ;approving a spacing exception. f (Comnany Name) assumes ~ ~ I the liability of any protest to the spacing exception that may occur. bmitted to the DRY DITCH All dry ditch sample sets su SAMPLE ~ Commission must be in no greater than 30' sample intervals from below the permafrost j i or from where samples are first caught and 1 ` ~ ~ 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, UGNU UNDEF WTRSP -64017 _ ____Well Name: PRUDHOE BAY UN UGN S-400 Program SER Well bore seg ^ PTD#:2051910 Company BP EXPLORATION-.(ALASKA). INC Initial Class(fype SER 1 WTRSP GeoArea Unit On/Off Shore On Annular Disposal ^ Administration i i 1 Permit fee attached - - Yes - --------------------- - - - 1 2 Leas_enumberappropriat_e____________________________ _ _ Yes __ - -- - 3 Unique well-name and number-- -- -- --- -- - -- -- - - -- Yes -- -- -...- - -- -- ----- ------ - 4 Well located in a-de_finedpool- - - N0 - - i ~ i 5 Well located proper distance from drilling unitboundary_ NA_ This is a water supply well, we have-no spacing requirements for wells of this type: RPC- . - - . - - . - - i 6 Well located properdistance-from-othe-r wells--------------_-_.----- -.---. NA_- ----__---._.._______ -__ 7 Sufficient acreageayail_ablein_d_rillingunit_____ NA__ ______________________________________________ 8 If deviated,is_wellboreplat_inclu_ded_______ Yes_ ________________________________________________________ - -- 9 Operator only affected party Yes - - - 10 Operator has.appropriate_bondin force___________________________ ______Yes_ ___.-____________-__- ----------------------------------------------------- 11 Permit can be issued without conservation order Yes - - - - - Appr Date 12 Permitcan be issued without administtative_approval - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - . - RPC 11122/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by Injection Order # (put 10# in_camments) (For- NA- - - - - - - - - - - - - - - - - - 15 All wells within 114-mile area of review identified (For service well only)_ _ _ _ __ _ _ _ _ _ _ _ NA- . .. _ . _ . _ .. , . 16 Pre-produced injector: duration of pre production Less than_ 3 months_ (For service well only) NA- - - - - - - - - - - - - - - - - - - - - - - - ---------------------------------------------------- 17 ACMP_Finding of Consistency.has been issued_for_this project„ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ ---------------------------------------------------- Engineering 18 Condu_ctorstring_provided_-----------------_._.,._.-______ __.___Yes_ ____._20"X105'.___________,_-__-__.__-__. 19 Surface casing_protectsall_known_U$DWs_________________________ ______Yes_ __________________.__---.----_-__- 20 CMT_vol, adequate_to circulate.on conductor & surf_csg Yes - - . - - . -Adequate excess, - , - - - 21 CMT_vol_adeguate_totie-in long string to surfcsg_____________________ ______NA__ _____-_____-____.,.-__---_----------.---.-.--._____._________.________ _-- 22 CMT-will coyer all known-productiyehorizons------------------------ ------No-- -._-.Slotted,-__-_______ - - - 23 CasingdesynsadequateforC,TB&-permafrost--------------------- Yes- ----------------------- ------------,--..-------------------------- 24 Adequatetankage_orreservepit-..---_____- Yes_ ------Nabors-7E$,,-_,__________________________________-,.___ 25 If_a_re-drill,has_a_1.0-403 for abandonment been approved _____________ _____ NA_ __-__.Newwell,___-_--------.-._,._-..____ 26 Adequatewellbo-re separation-proposed--_._-__.-_._.._._.,.___ _..-__Yes_ __________________________ ----------------------------------------------- 27 Ifdiverterrequired,doesitmeetregu_lotions_________________________ ______Yes_ __-____________-__-__--_---__.--___--_-_.-_-,-.___-__._______________ -_- Appr Date 28 Drilling fluid_program schematic & equip listadequate_ Yes Max NiW 9,5 ppg- - - - - - - - - - - - - - - - - - WGA 1112212005 29 BOPEs,dotheymeetregulation------------------------------- ------Yes_ ._-________________________-_-______ _--______-___--_--_--__-_--___- ___ 30 BOPE_pressratingappropriate;testto_(putpsigincomments)______________ ______Yes_ _-,_.-Test to 3500psi._MSP1255psi.____,_.,_-_,_-____-________._____________,- '31 Choke.man'rfoldcomplieswlAPI_RP-53(May84)______________________ ______Yes_ _--__-_._ - - 32 Work willoccurwithoutoperationshutdown------------------------- ------Yes_ ----_-_-___________________ -- 33 Ispresence-of H2$gas-probable - - - - - - - Yes - 500-PPm onpad. - - - - 34 Mechanical_condition of wells within AOR verified (For_service well onlya NA- _ _ - - _ - .Water sourcewell. - - , - - - Geology 35 Permit_can be issued w/o hydrogen_sulfide measures - Yes _ .. - 36 _D_ata-presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ , Appr Date 37 Seismic analysis of shallow gas_zones_______ ______-_ ,- ---NA-- ----------------------------- RPC 11!2212005 38 Seabed condition suryey_(if off_-shore) NA- - 39 Contact nom-elphgne-for weekly progress-reports [exploratory only]_ .. - - - NA_ . Geologic Engineering Pub'c D t D t D t Commissioner: a a e Com ~ r e: Commissioner: a e