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HomeMy WebLinkAbout201-196STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT P-07A JBR 06/14/2022 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:3 2 Test joint 2 7/8' and 4 1/2". 3 Failures CMV #4 Initial fail was serviced and functioned and retested good. Flow Indicator Failed Visual / Audible and CanRig Rep called out to make repairs. Closing times: Annular 19 Sec, VBR UPR 4 Sec, Blinds 4 Sec, HCR 2 Sec Test Results TEST DATA Rig Rep:FloresOperator:Hilcorp North Slope, LLC Operator Rep:Knowles/Bass Contractor/Rig No.:Hilcorp Thunderbird 1 PTD#:2011960 DATE:5/15/2022 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopMFH220516130519 Inspector Matt Herrera Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9.25 MASP: 2567 Sundry No: 321-271 Location Gen.:P Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec.P Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 11 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"P #1 Rams 1 2 7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1550 200 PSI Attained P18 Full Pressure Attained P122 Blind Switch Covers:PYES Nitgn. Bottles (avg):P3@2183 ACC Misc NA0 P PTrip Tank P PPit Level Indicators F FFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA 99 9 9 9 99 9 9 9 9 9 9 FP F F CMV #4 Initial fail Flow Indicator Failed Closing times: Annular 19 Sec, VBR UPR 4 Sec, Blinds 4 Sec, HCR 2 Sec Surface 3637 5210 Intermediate 12677 7-5/8"31 -12677 31 - 8810 8180 5120 Operator Name:2. Exploratory Development Service… …5 … Permit to Drill Number:201-196 6.API Number:50-029-22535-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028264 Property Designation (Lease Number):10. N/A 8. PBU P-07A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon …Plug Perforations …Fracture Stimulate …Repair Well 5 Operations shutdown Tubing Swap … Op Shutdown GAS … GSTOR…WAG … SPLUG … … Abandoned Oil 5 WINJ … Exploratory …Development 5Stratigraphic……Service WDSPL … 12. Attachments: PRESENT WELL CONDITION SUMMARY 14395 Effective Depth MD: L-80 11. 8/20/2021 Commission Representative: 15. Suspended … Contact Name: Noel Nocas Contact Email: Noel.Nocas@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity …BOP Test …Mechanical Integrity Test …Location Clearance … Other: Yes …No …Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing … Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8991 Effective Depth TVD:Plugs (MD):Junk (MD): …Other Stimulate Re-enter Susp Well Suspend … …Plug for Redrill …Perforate …Perforate New Pool 12570 8709 No SSSV Installed Date: Liner 1810 3-1/2" x 2-7/8" 12585-14395 8724 - 8992 10160 10530 Well Status after proposed work: 16. Verbal Approval: 5 … …Change Approved Program 34 - 3668 34 - 3268 14. Estimated Date for Commencing Operations: BOP Sketch 36 -110 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" BKR SABL-3 12818 - 14236 8934 - 8985 4-1/2" 12.6#29 - 12616 Production 14361 8988 36 - 110 470 10-3/4" Contact Phone:907-564-5278 Date: Conductor 74 20" 1490 2480 …GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 …… … Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. …No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic … 2567 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. NONE UNKNOWN By Samantha Carlisle at 9:17 am, Jun 02, 2021 321-271 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.01 15:38:22 -08'00' Stan Golis (880) DSR-6/2/21DLB 06/02/2021 X MGR18JUN21 BOPE test to 3000 psi. Annular test to 2500 psi. 10-404 2567  dts 06/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.18 15:45:49 -08'00' RBDMS HEW 6/21/2021 RWO Procedure WELL: P-07A PTD:2011960 Well Name:P-07A API Number:50-029-22535-01 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:8/20/2021 Permit to Drill Number:2011960 First Call Engineer:Noel Nocas 907-564-5278 (O)907-229-9532 M Second Call Engineer:Wyatt Rivard 907-777-8547 (O)509-670-8001 M Current Bottom Hole Pressure:3,447 psi @ 8,800’ TVD 7.6 PPGE | Average of 3 closest producers Max. Anticipated Surface Pressure:2,567psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1880 psi Min ID:2.375” ID BKR Straddle packer @ 12,475’ MD Max Relevant Angle:55 Deg @ 10,500’MD Brief Well Summary: P-07 parent bore was drilled in 1985. In 2001 CTD drilled the P-07A bore. The well was online until TxIA communication was remedied with a patch in 2009. In 2020 the well started to show signs of TxIA. While attempting to troubleshoot the communication, SL encountered an obstruction at 11,764’MD (GLM#2). A subsequent video log showed collapsed tubing/GLM. To repair TxIA communication a RWO will be performed. Notes Regarding Wellbore Condition: x The 7-5/8” production casing passed CMIT-TxIA to 3,000 psig on 12/11/2009. A current MIT-IA is not possible due to restriction in tubing. x As the tubing is collapsed below/at the #2 GLM, the Ivishak will not be isolated during the RWO. Fluid and BOP will be primary and secondary barriers. x Estimated Production Casing Cement top based on pumped volumes is 11,133’MD Objective: Pull the existing 4 ½” L80 tubing out of the well and replace with 13 chrome tubing. Achieve a passing MIT-IA & MIT-T. Primary completion objective is to remove obstruction to regain reservoir access for future perforations. If fishing tubing below collapse is unsuccessful, future tool access will not be available, but reservoir communication will be maintained and the well will be completed with the contingent completion plan (Contingent schematic attached) Pre Sundry Work: DHD 1. Cycle LDS’s 2. PPPOT-T 3. PPPOT-IC Sundry Procedure (Approval required to proceed): Eline 4. Cut tubing @ ~ 11,760’MD 5. Circulate well to 8.4 ppg 1% KCL or equivalent (Freeze protect with diesel on T & IA if needed before next step) Valve Shop/Ops 6. Kill well if needed with additional 8.4 ppg 1% KCL or equivalent. Keep fill on IA 7. Check WHP and Confirm well is dead -00 DLB RWO Procedure WELL: P-07A PTD:2011960 8. Set and test TWC. Test from above to 3000psi then perform rolling test from below attempting to catch 500psi (anticipating 5bpm loss at this pressure) – confirm no pressure through TWC into tree 9. Nipple Down Tree and tubing head adapter. Inspect lift threads. 10. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and flow cross. RWO 11. MIRU Thunderbird #1 Rig. Throughout operations, maintain hole fill in IA with KWF to maintain a barrier throughout operations. If the hole cannot hold a column, maintain fill at 30bbl/hr. 12. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-½” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Rig up lubricator and test to 3000psi. Pull TWC with lubricator and circulate well STS to KWF. Monitor well to confirm dead. LD Lubricator and TWC. Can bullhead tubing/liner volume to perfs if needed prior to STS. 14. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~130K 15. With 4 1/2” tubing at floor, circulate bottoms up if needed. 16. LD Tubing to cut. Confirm and Strap cut joint length, and eccentricity of pipe to latch with overshot. 17. PU workstring and overshot. RIH to tubing cut, engage tubing stub and attempt to release from K-22 anchor per fishing hand on location. If unable to release, contact OE for plan forward. a. If unable to fish remaining tubing the contingency completion (schematic attached) will be utilized. Use Lessons learned from P-11 RWO, if retrieving tubing stub unlikely, proceed with contingency. b. Additional milling runs may be used to clear obstruction. If any milling was done to fish, a cleanout/magnet/junk basket BHA may be ran. 18. POOH with remaining 4-1/2” Tubing and 4-1/2” Tubing patch. LD same. 19. Pick up 7-5/8” retrievable test packer, RIH and set packer below primary or contingency packer setting depth (whichever applies) MIT-IA to 3,000-psi for 30 charted minutes. Leak hunt if necessary. 20. LD workstring and 7-5/8” test packer. 21. Run 4 ½” 13Cr tubing with stacker packer completion as detailed on applicable schematic. 22. Land Hanger and load IA with corrosion inhibited 8.4 ppg 1% KCL or equivalent. 23. Drop ball and rod and set packer with 3,500psi pump pressure. 24. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 25. Shear valve in upper GLM. No Freeze protect needed if valve shop is lined up for tree work. 26. Set TWC. Test from below to 3000psi 27. Rig down Thunderbird #1. RWO Procedure WELL: P-07A PTD:2011960 Valve Shop/Ops 28. ND BOPE 29. NU tree and tubing head adapter. 30. Test both tree and tubing hanger void to 500psi low/5,000psi high. 31. Pull TWC and freeze protect to ~2,000ft with diesel. Slickline 32. Pull Ball and rod and RHC profile 33. Set GLV’s per GL Engineer 34.RDMO & pop well. Obtain AOGCC witnessed SVS test within 5 days of putting well online Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing RWO Procedure WELL: P-07A PTD:2011960 Wellbore Schematic RWO Procedure WELL: P-07A PTD:2011960 Proposed PRIMARY Wellbore Schematic RWO Procedure WELL: P-07A PTD:2011960 Proposed CONTINGENT Wellbore Schematic RWO Procedure WELL: P-07A PTD:2011960 RWO BOPs RWO Procedure WELL: P-07A PTD:2011960 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 , v r ! 1 Mr. Tom Maunder RECEIVED Alaska Oil and Gas Conservation Commission AUG 31 2t 333 West 7 Avenue Anchorage, Alaska 99501 G» Cam, grlissi0o Anci�r� Subject: Corrosion Inhibitor Treatments of GPB P -Pad aoi Dear Mr. Maunder, o / F Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) P -Pad Date: 07/21 /11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal P - 1920920 500292228700 0.30 NA 0.30 NA 0.85 4/24/2010 P -02A 2000840 500292237601 0.30 NA 0.30 NA 4.25 4/25/2010 P -03A 1972280 500292217601 12.70 5.0 0.30 7/12/2010 2.55 8/5/2010 P -04 1910760 500292218000 1.80 NA 1.80 NA 15.30 4/25/2010 P -05A 2000510 500292254501 0.80 NA 0.80 NA 5.95 4/25/2010 P -06B 2051380 500292216602 11.30 3.0 1.00 7/12/2010 9.35 8/5/2010 ro , P -07A 2011960 500292253501 0.50 NA 0.50 NA 1.70 4/24/2010 P -08A 2000850 500292237701 0.10 NA 0.10 NA 0.85 4/24/2010 P -09 1930580 500292236200 0.10 NA 0.10 NA 0.85 4/24/2010 P -10 1910520 500292215800 3.00 NA 3.00 NA 28.05 4/24/2010 P -11 1910290 500292214300 3.00 NA 3.00 NA 23.80 4/23/2010 P -12B 2001330 500292213602 0.30 NA 0.30 NA 0.85 4/23/2010 P -13 1901110 500292208000 0.30 NA 0.30 NA 1.70 4/23/2010 P -14 1910070 500292212900 7.50 NA 7.50 NA 56.10 7/21/2011 P -16 1901630 500292211300 4.30 NA 4.30 NA 37.40 4/22/2010 P -17 1901550 500292210500 8.00 NA 8.00 NA 89.30 4/28/2010 P -19 1901360 500292209400 0.80 NA 0.80 NA 5.10 4/21/2010 P -20B 2001590 500292208902 0.20 NA 0.20 NA 0.85 4/21/2010 P -21B 1970640 500292214802 0.40 NA 0.40 NA 4.30 4/21/2010 P -22 1931210 500292239600 0.30 NA 0.30 NA 1.70 4/23/2010 P -23 1931120 500292239300 0.30 NA 0.30 NA 0.85 4/24/2010 P -24 1970540 500292275500 1.80 NA 1.80 NA 8.50 4/24/2010 P -25 1970260 500292274200 64.00 24.0 2.60 7/17/2011 23.80 7/20/2011 P -26 1962000 500292272700 2.60 NA 2.60 NA 22.10 4/25/2010 P -27 2040500 500292320300 1.00 NA 1.00 NA 6.80 4/25/2010 P -28 2100480 500292342500 1.20 NA 1.20 NA 10.20 8/7/2010 STATE OF ALASKA ALASKA LAND GAS CONSERVATION COMMISS~ `°~ REPORT OF SUNDRY WELL OPERATIONS~o,~~~. _. ,r . ~~ 1.Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ ter ~ 6 ` " "pr_ Pertormed: Alter Casing ^ Pull Tubing^ Pertorate New Pool ^ Waiver^ Time Extension^ Change Approved Program ^ Operat. Shutdown ^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development 0 Exploratory 201-1960 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-22535-01-00 8. Property Designation (Lease number) : 9. Well Name and Num r: ADLO-028264 PBU P-07A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14395 feet Plugs (measured) None feet true vertica~ 8991.43 feet Junk (measured) None feet Effective Depth measured 14395 feet Packer (measured) 12570 true vertical 8991.43 feet (true vertical) 8709 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20"91.5# H-40 30 - 110 30 - 110 1490 470 Surtace 3638 10-3/4" 45.5# NT-80 30 - 3668 30 - 3249 5210 2480 Intermediate Production 12677 7-5/8" 29.7# NT95HS 31 - 12677 31 - 8810 8180 5120 Liner 1810 3-1/2"X3-3/16"X2-7/8" 12585 - 14395 8723 - 8991 Liner 8.81 #/6.2#/6.16# Pertoration depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 12618 SURFACE - 8754 Packers and SSSV (type, measured and true vertical depth) 7-5/8"X4-1/2" BKR SABL-3 12570 8709 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~,yg_~rr~~ e°~ir!"~Di~':/ ,j,L'~j~I ~ ~ ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 75 1340 2321 307 Subsequent to operation: 68 1103 1798 472 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X Wel- Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exe mpt: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 12/31/2009 Form 10-404 Kevised 7/2009 ©~ ~ s ~~ RRDMS JAN ~ 5 ZO~ j submit Original Only P-07A 201-196 e~rrfr w'rr A/+LI wI CwIT • Sw Name P-07A Operation Date 10122/01 Perf Operation Code SL r ~~~~ ~~ ~ Meas Depth Top 12,818. Meas Depth Base 12,850. Tvd Depth Top 8,933.58 Tvd Depth Base 8,959.44 P-07A 10/22/01 SL 13,445. 14,236. 9,005.83 8,985.06 P-07A 9/23/08 BPS 12,580. 14,236. 8,718.41 8,985.06 P-07A 5/18109 BPP 12,580. 13,000. 8,718.41 9,049.97 P-07A 5/22/09 BPS 12,324. 12,818. 8,481.66 8,933.58 P-07A 5/24/09 BPP 12,324. 12,818. 8,481.66 8,933.58 P-07A 10/9109 MLK 12,890. 13,090. 8,990.74 9,052.16 P-07A 10/9/09 MLK 13,090. 13,120. 9,052.16 9,051.4 P-07A 10/9109 MLK 13,160. 13,180. 9,046.86 9,043.82 P-07A 10/9/09 MLK 13,210. 13,240. 9,039.3 9,035.07 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n U • P-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/5/2009!*"" WELL SHUT IN ON ARRIVAL "** (ELINE: SET LOWER PKR) =INITIAL T/IA/OA: 275/0/0 sSET 4-1/2" BAKER 9CR 45 FLO-GUARD LOWER STRADDLE PACKER AT j 12506' MD (MID ELEMENT). TOP OF PACKER = 12504.9', TOP OF 13CR - 4" CGS PROFILE DEPLOYMENT SLEEVE LOCATED AT 12504.16', GS `DEPLOYMENT SLEEVE O.D. = 3.7", GS DEPLOYMENT SLEEVE LD. = 3.0", ;MINIMUM PACKER ID = 2.45", BOTTOM OF PACKER LOCATED 12510.4', ?OVERALL LENGTH OF PACKER = 5.5'. OVERALL LENGTH OF PACKER SAND 4" GS DEPLOYMENT SLEEVE = 6.24'. =THIS IS PART ONE OF A THREE RUN PATCH TO COVER LEAKING GLM #1 AT 12492' ~ ;DSO NOTIFIED OF VALVE POSTIONS: W=C, M=O, SSV=O, CASING=OTG. FINAL T/I/0=275/0/0 *** JOB COMPLETE. WELL LEFT SHUT-IN*'""* °~ n. ..........~....,~,®®~~.~~._.~~~ ~ ~..~ ~....~ 12/10/2009T/I/O 300/0/20 Temp SI Assist Slickline, MIT-IA to 3000 psi (Post patch). Load .fluids and road to location. *** Job continued on 12-11-09 WSR**" 12/10/2009'"**WELL S/I ON ARRIVAL""* [SET 14.68' x 3.50" (MAX OD: 3.70", MIN ID:2.375) BAKER SEAL BORE RECEPTICLE AT 12,475' SLM SET BKR UPPER STRADDLE PACKER (7.70' OAL, 3.70" OD, 2.375" ID), AT =12,467' SLM ***CONT WSR ON 12-11-09""* 1 2/1 0/2009 1T/I/O = 320/0+/0. Temp=S1. TBG & IA FL (SLB call-in). TBG FL @ 1050' (10 bbls), IA FL @ 250' (10 bbls). SLB has control of well valves. 12/11 /2009 "**CONT WSR FROM 12-10-09*"* (patch tubing) LRS MIT-IA TO 3000 PSI **PASS*" (see Irs log) SET WHIDDON C-SUB AT 12,447' SLM PULL ST# 2,3,4,5 & 6 BK-DGLV'S SET ST# 6,5,4,3 BK-LGLV'S AND ST# 2 BK-OGLV CURRENTLY IN HOLE PULLING WHIDDON C-SUB *""CONT WSR ON 12-12-09""" ...~ ~ ~ ......................~. .. ~ ~. a .n._.~w,_~ _.w 12/11/2009,*** Job continued from 12-10-09 WSR*** Assist Slickline, MIT-IA PASSED to 3000 psi (Post patch). Pressured up IA with 12.6 bbls crude. IA lost 60 psi in 1st 15 mins and 20 psi in 2nd 15 mins for a total loss of 80 psi in 30 min test. Bled back pressure, bled aprox 8 bbls crude. Final WHPs 300/0/20 Slickline still on well at time of departure _ _ _ ~m ...__ __ __ ~. FLUIDS PUMPED BBLS 2 diesel 1 METH 3 Total KB. ELEV = , 8a.oa' BF. ELEV = ,.:,.,,,.,,..,,,,.. 59.88' ,,,,..,..... KOP = 700' Max Angle = 102° @ 13434' Datum MD = 12764' Datum TV D = 8800' SS ~ 10-3/4" CSG, 45.5#, NT-80 BTRS, ID = 9.953" ~ Minimum ID = 2.377" @ 12744' 3-1 /2" X 2-7/8" XO FISH -PATCH ELEMENTS (11/22!09) i ~4-112" HES X NIP,ID = 3.813" ~ 12570' ~ 7-5/8" x 4-1/2" BKR SABL-3 PKR, w / K-22 A NCHOR LATCH, ID = 3.95" TOP OF 2-718" LNR SA,FETY~'ES: WELL ANC~E> 70° @ 12990'. P-o7A 2194' ~--~ 4-112" HES SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3252 3003 45 KBMG-M DMY BK 0 10!19(09 5 6387 4836 55 KBMG-M DMY BK 0 10/19/09 4 8733 6201 54 KBMG-M DMY BK 0 10!19!09 3 10623 7289 55 KBMG-M DMY BK 0 10/19!09 2 11764 8017 38 KBMG-M DMY BK 0 10/19/09 1 12492 8635 21 KBMG-M DMY BK 0 03/14(02 12585' 1-i 3.70" BKR LNR DEPLOY SLV, ID= 3.00" 12856' 3-112" XO PIN, ID = 2.992" 12595' 4-1/2" HES X NIP, ID = 3.813" 12606' ~-I4-1/2" HES XN NIP, ID = 3.725" 4-112" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" 7-518" WHIPSTOCK ~-~ 12672' RA TAG 12682' PERFORATION SUMMARY REF LOG: SPERRY MWD GR/RES 10(22!01 ANGLE AT TOP PERF: 35° @ 12$18' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" SLTD 12818 - 12850 O 10/22/01 2-7/8" SLTD 13445 - 14236 O 10/22/01 7-518" CSG, 29.7#, NT-95 HS NSCC, .0459 bpf, ID = 6.875" \ 12618' -~4-1/2" WLEG, ID = 3.958" 12614' ELMD TT LOGGED 03/29/95 ? FISH: 2 WRP ELEMENTS (05124109) MILLOUT WINDOW (P-OlA) 12677' - 12683` ^ 12744' 3-1/2" X 2-7/8" XO, ID = 2.377" \ ~~ ~ ~ ~` ~ ~ PBTD - ~~ .` .` ~~ ~~ 3-112" LNR, 8.18#, L-80 STL, 12744' ~ ~ ~ .0087 bpf, ID = 2.992" ~ 2-718" LNR, 6.5#, L-80 STL, .0058 bpf, ID = 2.377" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 02!18195 MDO ORIGINAL COMPLETION 06/01!09 GJF/TLH GLV C/O (05/23/09) & IBPPULL 10/22/01 CWKAK CTDSIDETRACK{P-O7A} 10/23/09 DMS/PJC GLV C/O(10/19/09)~ 12/17/01 AFiKAK SLTD PERF CORRECTIONS 11/23/09 GJF/SV FISH-PATCH ELEMENTS 03114/02 RLJTLH GLV UPDATE 10/17/08 RRD/PJC SEf IBP (09/22/08) 10!17/08 PJC DRAWING CORRECTIONS PRUDHOE BAY UNff WELL: P-07A PERMrf Na: X2011960 API No: 50-029-22535-01 SEC 31, T11N, R13E, 2476' FSL & 1944' FWL, BP F~cploration {Alaska) 10/16/09 SCpIU� er � 1 1 1 l` Z0 NO. 5418 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD P1 -25 AP3O -00063 INJECTION PROFILE 10/0209 1 1 W-01A 82NJ -00026 MEMORY GLS 10102/09 1 1 12-06A AZCM -00043 LDL 10103/09 1 1 W -36 AViWOM28 PRODPROMEW /GL 09/29/09 1 1 E -35A B2NJ -00027 MEM CEMENT BOND LOG 10/03/09 1 1 12 -34 AYS4 -00104 INJECTION PROFILE 10111/09 1 1 Z -07A AYS4 -00101 PRODUCTION PROFILE 10108109 1 1 15 -1 HA 82WY -00015 MEMPRODPROFILE — 07101/09 1 1 05 -18A B04C -00069 SCMT — 07130109 1 1 "SA 8146 -00068 US17 08117/09 1 1 P -07A AWJI -00051 MEM PRO ROFILE 10/09109 1 1 09-03 AZCM -00044 PRODUCTION LOG — 10/10/09 1 1 1- 45/0 -26 B2NJ -00032 MEM LDL 10/10/09 1 1 S-134 AWLH -00039 USIT _ 09/28/09 1 1 V -105 8350 -00026 (PROF 10/03/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, SUR. 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISS N REPORT OF SUNDRY WELL OPERATIONS /0~.~ 1. Operations Abandon ~ Repair Well ~ Piug Pertorations ~ Stimulate0 Other Q MILL Pertormed: Alter Casing ~ Pull Tubing~ Pertorate New Pool ~ Waiver~ Time Extension~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ^ ~ 201-1960 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage,AK 99519-6612 \ 50-029-22535-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: V ADLO-028264 ~~ PBU P-07A 10. Field/Pool(s): `~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Gas Con C A'$~k ~~ ~ s. OtIltiT~ Total Depth measured '` 14395 feet Plugs (measured) None ` ~ee~ true vertical v 8991.43 feet Junk (measured) None feet ~~ChCC~~` Effective Depth measured 14395 feet Packer (measured) 12570 true vertical 8991.43 feet (true vertical) 8709 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surtace 3638 10-3/4" 45.5# NT-80 30 - 3668 30 - 3249 5210 2480 intermediate Production 12677 7-5/8" 29.7# NT95HS 31 - 12677 31 - 8810 8180 5120 Liner 1810 3-1/2"X3-3/16"X2-7/8" 12585 - 14395 8723 - 8991 Liner 8.81#/6.2#/6.16# Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ ~ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L=80 SURFACE - 12618 SURFACE - 8754 Packers and SSSV (type, measured and true vertical depth) 7-5/8"X4-1/2" BKR SABL-3 -. --_ .-- -- 12570 8709 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~.~~~~~~ ~j~ y~ ~ ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 49 286 382 344 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WlNJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/30/2009 ~~~t~ Form 10-404 Revised 7/2009 P~ ~~,~ ~ ~' ( ~ , ~e~ ~-`Y1 ~ ~p f ~ Submit Originai Only P-07A 201-196 ococ ATTA/'~LJIIACAIT • Sw Name Operation Date Perf Operation Code ~Meas De th Top Meas De th Base Tvd Depth Top Tvd De th Base P-07A 10/22/01 SL 12,818. 12,850. 8,933.58 8,959.44 P-07A 10/22/01 SL 13,445. 14,236. 9,005.83 8,985.06 P-07A 9/23/08 BPS 12,580. 14,236. 8,718.41 8,985.06 P-OlA 5/22/09 BPS 12,324. 12,818. 8,481.66 8,933.58 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ • P-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU #5 w/1.75" OD CT. Job scope - Drift tbg, Mill scale. «< InterACT publishing »> Continued from WSR 09/20/2009. Continue RIH w/2" OD JSN assy. Taqqed up 12,798'. Washed down to 12,816'. Leak developed on flange in flow cross under the BOP's. Shut down pump and bleed well to 0 psi. Tightened flange. Pump engine died. Attempted to restart engine, but had no success. Called mechanic to location. POOH w/coil and freeze protected with Meth triplex.Bring out another pump RIH w/ 2.30" Turbo Mill. Taqqed at 12744' PU get freespin milled to 12817.9' had 7 stalls without any progress. POOH MU 2.125" BHA w/ 2.25" Speed Mill. RIH and mill down to 12.819'. Continued on WSR 09-22-2009. 9/22/2009~CTU #5 w/1.75" OD CT. Job scope - Mill scale. «< InterACt publishing »> IContinued on WSR 09/21/2009. Backreamed from 12,818'to top of 3-1/2" at ' 12,585'. RIH and milled from 12.818' to 12,881'. Continued to mill ahead to i 13089'. POOH. LD Baker HD, Extreme motor, 2.27" od HSPM. PU & MU ; new HD, Extreme motor, 2.27"od HSPM. Old HSPM gauged out on gauge. i RIH. Started milling at 13,094'. Milled down to 13,094', could not get any ~ deeper. Can not get any weight on bit. Continued on WSR 09/23/2009. 9/24/2009 CTU #5 w/1.75" OD CT. Job scope - Mill scale. «< InterACT publishing »> Continued from WSR 09/22/2009. Mill down to 13,097'. Loosing wt and motor not stalling. Bad dog leg in this section of liner. Posibility of exiting casing w/Diamond mill. POOH to drop jar and swap to 2.30" ODTurbo Scale Mill. RIH.Milled to 13455' top of lower slotted liner. Unable to get past with current mill POOH PU Diamond Parabolic speed mill. LD Turbo Scale mill and PU High Speed Diamond Parabolic mill. Changed out Hyd Disco. RIH. Tagged high at 12,956'. Continued on WSR 09/24/2009 CTU #5 w/1.75" OD CT. Job scope - Mill scale. «< InterACT publishing »> Continued from WSR 09/23/2009. Tagged up 12,958'. PUH and started milling down w/2.27" OD Diamond Parabolic mill. Milled down to 13,452'. Could not get any deeper. Motor would not stall and max down weight was achieved. Attempted to work mill down with pump shut down and different speeds but could not get past obstruction. Used 2% KCL w/SafeLub and GeoVisc to help lube pipe.Unable to get past 13442' pump 10 bbls DAD acid squeeze into lower slotted liner. Broke over at 750 psi squeezed acid away . POOH Freeze protect well with 35 bbls 60/40 Meth. RDMO ASRC test unit on location to flow acid back and get a well test. "*""" Job Complete """`** ~ ~ FLUIDS PUMPED BBLS 187 2% XS KCI W/SL 3224 2% XS KCL 53 GEO VISC W/SL 66 50/50 METH 3530 TOTAL • ~L.L LAG '~ ~- TR~4/il~~/CAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 ~ r ~ ., 4jj ~~' J•° /~~j l ''~ L// t / 1) Injection Profile 25•Dec~08 L-04 1 Color Log / EDE 50-029-23319-00 Leak Detection - WLD 05,1an-09 P-07A Signed 1 Color Log / EDE 50-029-22535-01 -~ - -~ ', ; ~ ,, Date ~~'-... x Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanchorageCte?t~errtesr~iop.a:~rrt WEBSRE : ww~N.irtern®rvlcc~.ct3rn C:\Documads and Settn~gslOwnerlDesktop\Transmit_BP.docx 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD STATE OF ALASKA. F~ECE/\lEO ALASKA Oil AND GAS CONSERVATION COMMISSION OCT 1 7 REPORT OF SUNDRY WELL OPERA TIQtI§Díl £, f'.. Aff~~~'~1'trl9lti~ n Time Extensionl] Re-enter Suspended WellD . 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Repair WellD Plug PerforationsD Pull TubingD Perforate New PoolO Operation ShutdownD Perforate 0 4, Current Well Class: Development 00 Stimulate 0 waiverD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicD 9. Well Name and Number: P-07 A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool ServiceD 5. Permit to Drill Number: 201·1960 6. API Number 50-029-22535-01-00 ExploratoryD 88.04 8. Property Designation: ADL-028264 11. Present Well Condition Summary: Total Depth measured 14395 feet true vertical 8991.0 feet Plugs (measured) None Effective Depth measured 14361 feet Junk (measured) None true vertical 8989.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 20" 91.5# H-40 34 - 110 34.0 - 110.0 1490 470 SURFACE 3605 10·3/4" 45.5# NT·80 33 - 3638 33.0 · 3249.0 5210 2480 PRODUCTION 12645 7-5/8" 29.7# NT95HS 32 - 12677 32.0 - 8810.0 8180 5120 LINER 159 3-1/2" 9.3# L-80 12585 . 12744 8723.0 · 8871.0 10160 10530 LINER 1651 2-7/8" 6.5# L-80 12744 . 14395 8871.0 · 8991.0 10570 11160 Perforation depth: . . A'I.""\~lr·; 'j~"":J"" ~ ',!C:!.,' ;}: l> Measured depth: 2-7/8" Slotted Liner 12818-12850,13445-14236 True vertical depth: 2-7/8" Slotted Liner 8934-8959,9006·8985 Tubing (size, ç¡rade, and measured depth): 4-112" 12.6# L80 @ 29 - 12618 Packers & SSSV (type & measured depth): 7·5/8" SABL-3 Packer @ 12570 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl SI SI Representative Daily Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 00- o 0 --. Tubing Pressure o o 14. Attachments: ~ 15. Well Class after proposed work: Exploratory(] 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 SUndry Number or NIA if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr R80MS BFI", OCT 11 Z006 Printed Name DeWayn(l R. Schnorr ^ ~ ~_.~ " $ ~/j Form 10-404 Revised 4/2004 I :) I r I 1\1 lj I. Signature ~ Phone Petroleum Engineer 564-5174 Date 10/16/06 Title If . . P-07A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/14/2006 ***WELL SHUT IN ON ARRIVAL ***( drift&tag,sbhps,set Up,cmit) ATTEMPT TO OBTAIN SAMPLE OF SCALE WI 2.25" D.D. BAILER, DID NOT SIT DOWN. RAN SBHPS AS PER PROGRAM (GOOD DATA), FINAL STOP @ 12737' MD DUE TO DOG LEG IN LINER. (SEE SBHPS DATA) RIH WI 3.805" GAUGE RING 3' STEM, 2.50" MODIFIED GAUGE RING WI SAMPLE CATCHER. 04/15/2006 MADE 2 ATTEMPTS TO OBTAIN SAMPLE OF SCALE, RECOVERED VERY SMALL SAMPLE OF SAND, *** LEFT WELL SHUT IN *** 06/14/2006 T1I10=2210/2110/90 Temp=SI Bleed lAP to CLP (FO call-in). AIL pressure is 1250 psi & is shut in @ casing valve. IA FL @ 9325' between st# 4 & 3 (244 bbls). Bled lAP to production from 2110 psi to 620 psi in 90 minutes (FTS). Shut in IA bleed for 30 minutes to allow gas to break out. While bleeding the lAP the TBGP decreased 950 psi to 1260 psi. lAP increased 180 psi in 30 minutes to 800 psi. Bled lAP from 800 psi to 750 psi (FTS) in 5 minutes. Could not get lAP to bleed down to CLP. While rigging down lAP increased 70 psi. Final WHPs=1260/820/90. 06/15/2006 T/I/O = 1620/1060170. On Inj. Monitor WHPs (FO call-in). TBGP increased 360 psi, lAP increased 240 psi, OAP decreased 20 psi since yesterday. 06/16/2006 T/I/0=1770/1160/70. Temp=SI. Monitor WHP's (FO call-in). TBGP increased 150 psi, lAP increased 100 psi since yesterday. No flow-line on well. AIL line SI @ IA casing valve (1240 psi). 06/17/2006 T/I/O = 1850/1220/70. No flowline. Monitor WHPs (FO call-in). TBGP increased 80 psi, lAP increased 60 psi since yesterday. AL gas shut-in. 06/18/2006 T/I/O= 1880/1200/60. Temp= SI. Monitor WHP's (FO call-in). No FIL on this well. AIL line SI @ IA casing valve. Tubing pressure increased 30 psi. lAP decreased 20 psi. OAP decreased 10 psi overnight. 09/09/2006 MIRU CTU# 9. MU Weatherford 2 7/8" motor/3.75" carbide crayola mill. Bleed WHP to tiger. 09/10/2006 Bleed WHP to tiger. RIH wi 3.75" carbide crayola mill. Load IA wi 302 bbl crude. Begin milling from 11000' wi 5 bbl Flopro sweeps. First stall was at 11767' and we had 27 stalls milling to 11816' on average 0.3 fpm. (50 feet) POOH to change BHA. Changed 2 7/8" PDM for a rebuilt one and changed mill to a 3.75" 00 3-blade junk mill. RIH wi BHA #2. Dry tag @ 11816'. Begin milling from 11800' wi 5 bbl Flopro sweeps. Milling in progress @ 11937'. 09/10/2006 T/I/O= 0/125010 Assist Coil - Loaded IA wi 302 bbls crude. 09/1112006 Milling in progress wi 3/75" three blade junk mill, from 11937' w/5 bbl Flopro sweeps. One motor stall @ 12304'. Milling in progress @ 12400'. 09/12/2006 Milling w/2 7/8" motor & 3.75" three blade junk mill. Mill from 12400' wi 5-10 bbl Flopro sweeps. CTD depth to liner top corrected to 12,585' & flagged at 12,555', Set WRP @ 12580'. POOH. Perform combo CMIT T X IA to 3k psi. CMIT T X IA passed OK on 1 st test. Page 1 . . P-07 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/12/2006 T/IAlOA = SI/260/300 (Lockdown Screw Leak) Repaired Leak on Lockdown Screws I Gland Nuts Bled inner casing hanger void to 0 psi. Torqued all Glands Nuts to 500 ftllbs. Energized assembly packing on Casing Head, no leaks. Bled tubing hanger void to 0 psi. Torqued all Gland Nuts to 500 ftllbs. Energized assembly packing on Tubing Head, no leaks. Monitor 30 mins. 09/13/2006 MUlRIH wi Weatherford jars & WRP retrieval tool. Tag WRP @ 12583' CTM. Stack 2-3k twice to equalize. PU to 28k# to shear release. Relax element, POOH. WRP at surface, repair CT speed read out. RIH to drift I CIO as required. Tagged hard fill 12,692', POOH and MIU weld- on CC I milling assembly: jars, 2 1/8" motor, 2.67" three blade junk mill. 09/14/2006 RIH w/2 1/8" motor/2.67" three blade junk mill. Mill from 12438' wi 5 bbl bio sweeps, to 12,735'. POOH. MUlRIH wi 1- 11/16" string wi 2.2" drag bit for 2 7/8" linerlslotted liner section. 09/15/2006 RIH w/1 11/16" string wi 2.2" drag bit. Tag @ 12731'. Mill from 12738' w/5 bbl Flopro sweeps to 12754' w/19 stalls. POOH. Change out diso and mill to 2.2" metal muncher. Mill form 12755' w/5 bbl Flopro sweeps to 12789' w/12 additional stalls. In progress @ 12789'. 09/16/2006 T1II0=0/20010 MIT OA @ 3000 psi. PASSED (Shut In)(Waiver) OA pressured up 3.2 bbls of 60* Crude pumped. 1 st test 1 st 15min lost 150 psi 2nd 15min lost 20 psi for a total of 170 psi in 30 min bleed back3 bbls Final Whp's=0/20010 09/16/2006 Milling from 12789' wi 2.2" metal muncher mill. Progress stopped @ 12816', close to top of slotted liner section. Circ out, drop ball and finish circ out. Injection test to 2000 psi down Tbg, dropped to 1926 psi in 10 minutes. Freeze protect Tbg to 2500' w/50/50 MEOH. RID MOL **** Job Complete**** 09/23/2006 T/I/O= 901240/12. Temp= SI. ALP= 480 psi (SI at the casing valve). NFT (waiver testing, post- FCO). IA FL @ 426' (11.2 bbls). Bled lAP from 240 psi to 60 psi in 20 minutes. Fluid to surface, shut down bleed (returned approximately 1 bbl to tank). Monitored WHP's for 30 minutes while rigging down equipment. FinallA FL @ 234' (6.1 bbls). Final WHP's= 40170/12. FLUIDS PUMPED BBLS 1 PT Surface Equipment 119 50/50 Methanol Water 305.2 Crude 7196 1 % Extra Slick KCL Water 190 Flopro (150,000 LSRV) 7811.2 TOTAL Page 2 . . I TREE = 4-1/16" 5M CrN SAFETY NOTES:W8..L ANGLE > 70 DEG@ 12990' W8...LHEAD = 5M FMC P-07 A & > 90 DEG @ 13044'. A CflV'. TOR = BAKEf1 KB. ELEV = 88.04' BF. ELEV = 59.86' KOP= 700' H4-1/2"HEB SSSV NP,ID=3.813" I Max Ang Ie = 102 @ 13434' . 2192' DatumMD= 12868' Datum 1VD = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID= 9.953" 3638' I----A . GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH FURT DATE 6 3250 3001 45 CA M:;O KBMG-M BK 16 03/14/02 U 5 6385 4835 55 CA M:;O KBMG-M BK 16 03/14/02 - 4 8731 6199 54 CA M:;O KBMG-M BK 16 03/14/02 Minimum ID = 2.377" @ 12744' 3 10621 7287 55 CA M:;O KBMG-M BK 20 03/14/02 3-112" X 2-7/8" LNR XO 2 11762 8015 38 CA M:;O SO BK 03/14/02 1 12490 8634 22 CA M:;O [;MY BK 03/14/02 12559' H4-1/2" HEB X NIp, ID= 3.813" I 8: ....,.. 12570' 1- 7-5/8" x 4-1/2" BKRSABL-3 PKR, I ......... I - W/ K-22 ANOiOR LA TOi, ID = 3.93" 13-1/2" LNR, 9.3#, L-80, S11., D =2.972" 1 12586' I r--r 12585' ¡- 3.70" BKR LNR DER.OY!\.£NT SLV, D= 3.00" 12595' 1- 4-1/2"HEBXNIP,ID=3.813" I 12606' H4-1/2"HEBXNNP, D=3.725'" 4-1/2"TTP, 12.6#, L-80, .0152 bpt,ID= 3.958" I 12617' I 12618' 1-i4-1/2"WLEG, ID= 3.958" I I 12614' H 8.MD TT LOGGED 03/29/95 7 -518" MLLOvr WIN row 12677' - 12683' wHlPsma< @ 12672' RA TAG@ 12682' PERFORA TION SUMMA. RY ~ REF LOG: SPERRY MWDGR'RES 10/22/01 ~ 12744' 1-13-112" LNRX 2-7/8" LNRXO,/D = 2.377" I ANGLEA TTOP PERF: 35@ 12818' ~, N:Jte: Refer to A-oduction DB for historical pert data SIZE SPF INTER\! AL OpnlSqz DATE .... 2-7/8" SLTD 12818 - 12850 0 10122/01 ........""....'~ 2-7/8- SLTD 13445 - 14236 0 10122/01 ~, ....", ~ 14361' , , .... ... " , .... '... , , .... .... 17-5/8" CSG, 29.7#, L-80, ID= 6.875" 13093' J I - 12-718" LNR, 6.5#. L-80, STL, .0058 bpf,lD = 2.377" I 14395' I DATE REV BY COM!\.£NlS DATE REV BY COfl.t..1ENTS FRUŒiOE SA Y UNT 02/18/95 MOO ORIGINAL COM"LEfION W8...L: P.{J7A 03/04/01 SIS-SL T CONv' ERrED TO CANVAS ÆRMfTNo: 201-1960 10/22/01 CHiKA K cm SIŒTRA a< API N:J: 50-029-22535-01 12/17/01 AFiKAK SL TO PERF CORRECTONS 2476' NSL & 1944' EWL, Sec. 31, T11 N. R13E 03/14/02 RUtlh GLV UPOA. TE BP EKploration (Alaska) P-07 A (P11J #1U llYóU) ClaSSItled as problem well '-' "-" Subject: P-07A (PTD #2011960) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWeIHntegrityEngineer@BP.com> Date: Sun, 18 Jun 2006 08:53:36 -0800 To: "Subekti, Herry" <Herry.Subekti@BP.com>, ftLuedke;..Chan,Beverly (PRA)" <Beverly.Luedke-Chan@BP.com>, "GPB, GC 1 Area Mgr" <GPBGCI TL@BP.com>, "Rossberg, R Steven"'<Steven.Rossberg@BP.com>, "NSU, ADW Well ,Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@admin~state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>."NSU. ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@BP..com>;"GPB, GCl Wellpad Lead" <GPBGC 1 Wellpad~ad@BP .com> CC:·"NSU,ADW Well Integrity Engineer" <NSUADWWelllnte~tyEngineer@BP.com>, "Lau, J.obn,Jack" <laujjO@B:P;.com>,"Winslow, Jack L."<Lyonsw@B,P~coin>;"MCCOLLUM,CODY 0 - . - . . (VECO)" <Cody.McCollum@BP.com> All, Well P-07 A (PTD #2011960) has been found to have sustained casing pressure on the IA. The TIO pressures were 2210/2110/90 on 06/14/06 when wellhead pressures were bled to 1260/820/90. Plans are in place to set a downhole plug, obtain a passing CMIT-TxIA, and evaluate the well for a TxlA waiver. Given the potential for wellhead pressures to build up prior to the work being completed, the well is being reclassified as a problem well ~..p M..J4 p 1(> þlJ:Ái P The plan forward for this well is as follows: .JA- ZI IDf5. 6tt/1D~:3ù 6~ 1. SL: Set PGSL, CMIT-TxIA 2. SL: Pull PGSL pending passing CMIT 3. WAV: Waiver for TxlA comm ð t: f<'~ (6 't-1 z.. , lc"".}j~Cc0t'L¿~; f1J.f.s 0~!1 f, };2 ¡ Ilt:~ «P-07 A.pdf» A wellbore schematic has been included for reference. The well has been classified as a Problem well. Please call if you have any questions. Thank you, }lnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED JUN 2 7 2006 Content-Description: P-07 A.pdf P-07 A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/21/2006 3: 14 PM TREE = 4-1/16"5MCIW WELLHEAD = 5M FMC A CTUA. TOR = BAKER KB. ELEV = 88.04' BF. ELEV = 59.86' KOP = . .- - - - 700' Max Ange = 102 @ 13434' Datum MD = - 12868' DatumTVD = 8800' SS 110-3/4" CSG, 45.5#, NT-80, 10 = 9.953" H 3638' µ Minimum ID = 2.377" @ 12744' 3-112" X 2-7/8" LNR XO 13-1/2" LNR, 9.3#, L-80, Sl1, () =2.972" 1-1 12586' 1 14-1/2"TTP, 12.6#, L-80, .0152 bpf, 10= 3.958" H 12617' 1 PERFORATION SUMfv\A.. RY REF LOG: SPffiRY MWD GF~/RES 10/22/01 A NGLEA T TOP PffiF: 35 @ 12818' NJte: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" SL TO 12818 - 12850 0 10/22/01 2-7/8" SL TO 13445 - 14236 0 10/22/01 17-5/8" CSG, 29.7#, L-80, 10= 6.875" 1---1 13093' 1 DATE 02/18/95 03/04/01 10/22/01 12/17/01 03/14/02 REV BY COfvUvENTS MOO ORIGINAL COrvPLEfION SIS-SLT COt-NERTEDTOCANVAS CHIKA K CTD S IŒTAA CK A FIKA K SL TO PffiF CORRECTONS RUtlh GL V UP[)/\ TE DATE ',- P-07 A SAÆTY NOTES:W 8...L ANGLE > 70 DEG @ 12990' & > 90 DEG @ 13044'. 8 2192' H4-112"HES SSSV NP, 10=3,813" I . GAS LIFT MANDRELS ST MD TVD DEV TYFE VLV LATCH FORT DATE 6 3250 3001 45 CAM:;O KBMG-M BK 16 03/14/02 L-- 5 6385 4835 55 CAM:;O KBMG-M BK 16 03/14/02 4 8731 6199 54 CAM:;O KBMG-M BK 16 03/14/02 3 10621 7287 55 CAM:;O KBMG-M BK 20 03/14/02 2 11762 8015 38 CA M:;O SO BK 03/14/02 1 12490 8634 22 CA M:;O ctv'IY BK 03/14/02 . 12559' H4-1/2" HES X NIP, 10= 3.813" 1 Z z,. 12570' r 7-5/8" x 4-1/2" BKR SABL-3 PKR, W/ K-22 ANCHOR LA TCH,ID = 3.93" 12585' r 3.70" BKR LNR DEA...OYrvENT SLV, ()= 3.00" 12595' H4-1/2" HES X NIP, 10= 3.813" 1 12606' H4-112" HES XN NIP, () = 3.725" 1 12618' H4-1/2"WLEG, 10= 3.958" 1 12614' H ELMO TT LOGGED 03/29/95 1 7 -5/8" MLLOllT VIIINOOW 12677' - 12683' WHIPSTOCK @ 12672' ~,~;, ~ ~ RA :::4:' ':2~'/2" LNRX 2-7/~' LNRXO, ID = 2.377' ..~,.~~ ........ , "-...-..., .......~ ~-... '........................ I FBTD H 14361' 1 -... ....... , , -... ........ '......., ............... -... -... , I ~ ~ ~ ~ JC.A. ~ 12-7/8" LNR, 6.5#, L-80, STL, .0058 bpf,lD =2.377" H 14395' REV BY CO Mv1 ENTS FRUDI-IOE SAY UNIT WELL: P-07A Æ~ITNo: 201-1960 API NJ: 50-029-22535-01 2476' NSL & 1944' EWL, Sec. 31, T11 N, R13E BP Exploration (Alaska) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm _ Marker.doc Ä 5 N~\i ~~1 DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 ~. / ~- 0 tJ;-~ ( Permit to Drill 2011960 Well Name/No. PRUDHOE BAY UNIT P-07 A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22535-01-00 MD 14395 - ND 8991 - Completion Date 1 0/23/2001 ~ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey -NDYM- ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~ Log/ Data Type ;ED I ~ Well Cores/Samples Information: Electr Digital Dataset Med/Frmt Number D 11339 Name Log Log Run Scale Media No 1 1 Interval OH / Start Stop CH Received 12485 14351 Case 12/6/2002 Comments - ---- 12485 14351 Case 12/6/2002 Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? y~ Daily History Received? @N (J/ N Chips Received? Y/N- Formation Tops Analysis Received? y! r~ -~- --~ Comments: C it ?L{~.. ~~f :t-~~... ~ Compliance Reviewed By: ~ Date: {(f tU' tv ~ J------- - ( ( 8-D 1- V=lk¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage, Alaska 99501 May 09, 2003 RE: MWD Formation Evaluation Logs: P-07 A, AK-MW-11170 P-O7A: Digital Log Images 50-029-22535-01 1 CD Rom I \-lLtq PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ &4----- Date: lor I D ,[)3 f~ECEIVED MAY 13 2003 ÞJaska O¡'¡ 8, Gas Cons. Gommission Anchoæge ¡ ( ( \ ¿;<O(-/gtp / 133 i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7ili Avenue, Suite 100 Anchorage, Alaska December 04, 2002 RE: MWD Fonnation Evaluation Logs P-07A, AK-MW-l1170 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22535-01 PLEASE ACKNOWLEDGE _RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~~ Date: I~' 'CE\VED DEC 06 2002 AJast'Ji O¡.¡ & Gas CQn~. C(Jmmi$sion Anchorage ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ISI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface '..0___". - . . 2476' NSL, 1944' EWL, SEC. 31, T11N, R13E, UM ::M . At top of productive interval " L6...:-~_2.__(¿.L , 31?~~t~~~e~t~4' WEL, SEC. 35, T11 N, R12E, UM J ~-;i1>-:~~~~_...: 2123' NSL, 606' WEL, SEC. 35, T11N, R12E, UM ~,.",,"'_"_d' 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 88.04' ADL 028264 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 10/15/2001 10/21/2001 10/23/2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 14395 8991 FT 14395 8991 FT ISI Yes 0 No 22. Type Electric or Other Logs Run G R, RES, MWD 23. CASING SIZE 20" 10-3/4" 7-5/8" 3.1/2 x 3-3/16" Classification of Service Well - .. - . 7. Permit Number 201-196 8. API Number -.~ 50- 029-22535-01 9. Unit or Lease Name .. ~ IK'WI' s~¿;Jr') Prudhoe Bay Unit '" '":st\ ~:::.;"';-~ ~:.3;. 10. Well Number !K.-- P-07 A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2192' MD 1900' (Approx.) WT. PER FT. 91.5# 45.5# 29.7# 8.81# / 6.2# 6.16# GRADE H-40 NT-80 NT95HS L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 30' 110' 30" 260 sx Arctic Set lApprox.) 30' 3638' 13-1/2" 1046 sx CS III 375 sx Class 'G' 31' 12677' 9-7/8" 265 sx Class 'G' 12585' 14395' 3-3/4" Uncemented Slotted Liner AMOUNT PULLED x 2.7/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Slotted Liner SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 12618' PACKER SET (MD) 12570' 25. MD 12818' - 12850' 13445' - 14236' TVD 8933' - 8959' 9006' - 8985' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 30 Bbls MeOH 27. Date First Production November 11, 2001 Date of Test Hours Tested 12/2/2001 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 749 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF 516 GAs-McF WATER-BBL 1428 WATER-BBL CHOKE SIZE GAS-OIL RATIO 91 688 OIL GRAVITY-API (CORR) 24.1 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED . DEC 1 7' 2001 Form 10-407 Rev. 07-01-80 r-.. 1"""\ , - I .. . .. Alaska all & Gas Cons. Commission t j ¡!./ {r f f\>:J /\ L_R B OMS B F L DEC 28 200/súbmit In Duplicate &;~ ( 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Sag River 12677' 8801' Shublik A 12690' 8822' Shublik B 12735' 8863' Shublik C 12762' 8886' Shublik D /' 12792' 8912' Eileen 12789' 8909' Sadlerochit I 46P 12817; 8933' 45P 12860' 8967' 44P 12921' 9013' 43P / 12973' 9041' 43P 13187' 9043' 44P 13386' 9016' 45P 13585' 8986' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys f 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RECE\VED DEC 1 7 2001 O. , ) Gas Cons CommisSion A\as\(a lea' Anchorage 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant P-07 A Well Number 201-196 Permit No. / A roval No. INSTRUCTIONS Date Prepared By Name/Number: Terrie Hubble, 564-4628 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGI~fl\l BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07 A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 38 Rig Number: 3S Date From - To Hours Activity Code NPT Phase Description of Operations 10/12/2001 00:00 - 02:30 2.50 CONS P PRE Prepare grade and remove flowlines on P-07 pad. 02:30 - 08:30 6.00 RIGU P PRE Begin moving rig to P-07. RIU Nabors 3S and DS unit #4. 08:30 - 12:00 3.50 BOPSUF P DECOMP Accept Rig at 08:30 hrs. N/U BOP stack. Called AOGCC and gave notice of BOP testing. 12:00 - 16:30 4.50 WHSUR P DECOMP Move over and r/u upright tanks and other skid mounted units. Install 2-way check in wellhead for bop testing purposes, grease choke manifold valves. 16:30 - 21 :25 4.92 BOPSUF P DECOMP Pressure test BOP's and test H2S monitors 21 :25 - 22:30 1.08 WHSUR P DECOMP Pull 2-way check. 22:30 - 23:00 0.50 STWHIP P WEXIT Make up BHA and stab on well. 23:00 - 00:00 1.00 STWHIP N SFAL WEXIT Shut-down to repair wellhead pressure read out in coil cab. 10/13/2001 00:00 - 01:10 1.17 STWHIP N SFAL WEXIT Wait on repair of wellhead pressure transducer on coil unit. 01:10-01:45 0.58 STWHIP P WEXIT Pressure test hard lines. 01:45 - 02:15 0.50 STWHIP P WEXIT PJSM prior to killing well. 02:15 - 02:40 0.42 STWHIP N SFAL WEXIT Continue to wait on repair of wellhead pressure transducer. Finally found problem to be in the computer board in the coil cab. By-passed bad board and got good wellhead pressure readings on a different display. 02:40 - 03: 15 0.58 STWHIP P WEXIT Displace methanol from the coil to the open top tank. 03:15 - 04:15 1.00 STWHIP P WEXIT Pump 290 barrels of 140 degree seawater at 4.5 BPM to kill the well. Maximum pressure on the coil/tubing annulus was 1,075 psi. Pressure on the wellhead dropped to 0 psi in about 1 minute after shutting down the pumps. 04:15 - 07:00 2.75 STWHIP P WEXIT RIH with coil to tag the top of the whipstock at 12,672'. PU 10' and flag coil at 12,662'. Same time r/u cementers. 07:00 - 07:15 0.25 STWHIP P WEXIT PJSM covering safety and procedures for cement job. 07:15 -10:00 2.75 STWHIP P WEXIT PT lines to 4000 spi. Pump 5 bbls water ahead then 5 bbls neat cmt followed by 12 bbls w/15ppb aggregrate then 3 bbl neat. Displ w/ rig pump hold positve annulus pressure. Squeezed away first 10 bbls having good gradual increase in pressure to 950 psi. Layed in remainder 1: 1to 12000'. Pulled to safety, closed choke and walk squeezed 4 bbls holding 950 psi. Cracked open choke and circulate 1: 1 hold 100 psi on annulus for 30 min. 10:00 - 13:25 3.42 STWHIP P WEXIT Dropped 13/16" ball and followed with 35 bbls 2% KCL w/ 1.5ppb bio. Make several passes jetting down WS and up through jewelry in tbg. 13:25 - 13:30 0.08 STWHIP P WEXIT LID nozzle assembly and p/u swizzle stick to clean bop's. 13:30 - 13:45 0.25 STWHIP P WEXIT Wash BOP's 13:45 - 14:45 1.00 STWHIP P WEXIT PT MHA 3500 psi 14:45 - 16:45 2.00 STWHIP P WEXIT P/U Anadrill TORQ tool and RIH to 130' to test. Performed okay for awhile then failed. 16:45 -17:00 0.25 STWHIP P WEXIT LID TORQ tool. 17:00 -19:00 2.00 STWHIP P WEXIT Wait on Cement. 19:00 - 19:20 0.33 STWHIP P WEXIT PJSM prior to PU milling BHA. 19:20 - 20:00 0.67 STWHIP P WEXIT Pick up window milling BHA. (Cement lab called at 19:30 hrs and said that after 8 hours our cement had a compressive strength of 2384 psi. Maximum expected compressive strength for this blend is 2500 psi.) 20:00 - 22:45 2.75 STWHIP P WEXIT RIH with BHA. 22:45 - 23:55 1.17 STWHIP P WEXIT Tag XN nipple at 12,614' CTM (12,602' ELM). Mill through (" ( Printed: 11/1/2001 9:39:53 AM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 1 0/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date From - To Hours Activity Code NPT Phase Description of Operations 10/13/2001 22:45 - 23:55 1.17 STWHIP P WEXIT 3.725" XN nipple. (-12' correction to coil depth). 23:55 - 00:00 0.08 STWHIP P WEXIT RIH and tag the whipstock pinch point at 12,699' (the pinch point on this whipstock is 4' below the top). (-11' coil correction with reference to the wireline corrected XN nipple depth). 10/14/2001 00:00 - 00:20 0.33 STWHIP P WEXIT Pick up and tag the whipstock again and found the pinch point at 12,699' CTM. Made a -11' correction to coil depth (the -12' correction plus the -11' correction at the whipstock add up to a total correction of -23'). 00:20 - 14:00 13.67 STWHIP P WEXIT Begin milling window at 12,676'. Freespin was 2,750 psi at 2.7 BPM. Added .5# Bio to system reduced PP and bettered weight transfer. Bleed down IA 1,000>900 psi. Milled down to 12,682' and appears to be drilling on formation but unable to make any hole (mill could be polished off). 14:00 - 18:00 4.00 STWHIP P WEXIT Swapping over to Flo-Pro prior to TOH to look at mill. TOH laying Flo-Pro. 18:00 - 20:00 2.00 STWHIP P WEXIT Speed mill appears to have crossed casing while cuttting window but is undergauge 3.77" P/U another used speed mill from BP stock which is good shape and in gauge. reamer that is above mill in gauge and shows some wear. We believe window is cut just unable to make a few feet of formation. 20:00 - 21 :30 1.50 STWHIP P WEXIT RIH with replacement mill to finish dressing off window. Tie in to coil flag at 12,676'. Made a -27' correction to coil depth. 21 :30 - 22:05 0.58 STWHIP P WEXIT . Free spin 2800 psi at 2.7 BPM. Work the mill through the window twice with pumps on and once with pumps off. Saw some minor motor work while passing through the window. Drilled to a TD of 12,688'. 22:05 - 00:00 1.92 STWHIP P WEXIT POOH with milling assembly. 10/15/2001 00:00 - 01:15 1.25 STWHIP P WEXIT Continue to POOH with window milling assembly. 01:15 - 01:30 0.25 STWHIP P WEXIT PJSM prior to laying down milling BHA and picking up drilling BHA. 01 :30 - 02:00 0.50 STWHIP P WEXIT Lay down Window milling BHA. 02:00 - 03:30 1.50 DRILL P PROD1 Make up drilling BHA with 2.77 degree Anadril motor. 03:30 - 04:00 0.50 DRILL P PROD1 RIH with BHA stop at 1500', attempt to activate MWD. No luck. RIH to 5,000' and attempt again with greater hydrostatic head on the MWD. 04:00 - 05:00 1.00 DRILL P PROD1 Stop BHA at 5,000' MD and again test MWD. Got good signal. Tested TORC. Also good test. 05:00 - 06:30 1.50 DRILL P PROD1 Continue to RIH. Tie in with BHC Acoustilog Gamma Ray log (run 02/15/1995) at 12,510' - 12,518'. 06:30 - 07:45 1.25 DRILL P PROD1 Log tie-in -4' correction. WINDOW: top 12677' bottom 12683' Bit>survey = 20.23' Bit>gr = 29.09' 07:45 - 09:00 1.25 DRILL P PROD1 Orienting TORC tool. First commands not responding. Changed modulation from 90 to 93 and tool started to respond. Orient to 77L. Bleed off IA f/1400 psi to 1190 psi. Will not go any lower with pumps on. Loss of .4 bpm returns while bleeding off. 09:00 - 16:30 7.50 DRILL P PROD1 Drilling build section 77-90L 2850 free-spin 3000 on bottom .- light wob frequent stalling in shales 15-20'/hr. Drilled f/12689' to 12788'. 16:30 -17:00 0.50 DRILL P PROD1 Wiper trip to window. 17:00 - 23:35 6.58 DRILL P PROD1 Drill build section 2850 free-spin 3100 on bottom 2.6 in /2.60ut 40-60'/hr f/12788' to 12980'. 23:35 - 00:00 0.42 DRILL P PROD1 Wiper trip to window. No problems. ( ( Printed: 11/1/2001 9:39:53 AM - BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07 A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date From - To Hours Activity Code NPT Phase Description of Operations 10/16/2001 00:00 - 00:20 0.33 DRILL P PROD1 FINISH WIPER TRIP 00:20 - 02:40 2.33 DRILL P PROD1 CONTINUE DRILLING BUILD SECTION. HOLDING HIGH SIDE DRILLINGf/12980' LANDING AT 13056'md, 8965.68' tvdss WITH PROJECTED ANGLE OF 96 deg. 02:40 - 05:30 2.83 DRILL P PROD1 TOH 05:30 - 06:00 0.50 DRILL P PROD1 UD BHA #4 06:00 - 07:00 1.00 DRILL P PROD1 M/U BHA #5 WITH R RES TOOL AND 1.15DEG MOTOR. UNABLE TO REPROGRAM TORC TOOL'S TF OFFSET. WILL NEED TO REPLACE PROGRAMER WITH NEW ONE FROM DEADHORSE. 07:00 -10:15 3.25 DRILL N SFAL PROD1 WAIT ON TOOLS FROM DEADHORSE. 10:15 -10:45 0.50 DRILL N PROD1 PROGRAM TOCC AND M/U IINJECTOR 10:45 -13:40 2.92 DRILL N PROD1 TIH SHALLOW HOLE TEST MWD & TORC WORKS FINE BOTH LEFT AND RIGHT ORIENTATION. TAGGED BOTTOM 13:40 -16:30 2.83 DRILL N PROD1 MAD PASS f/13010' to 12660'.TIE-IN AT PIP TAG (GOOD DEFINITION 12677') +3' CORRECTION. 16:30 - 16:45 0.25 DRILL N PROD1 TIH 16:45 - 17:30 0.75 DRILL N PROD1 DIRECTIONALL Y DRILLING AHEAD WITH LATERAL. DRILLEDf/13060 TO 13107'. UNABLE TO BUILD OR HOLD ANGLE WITH 1.15 MOTOR. 17:30 - 19:55 2.42 DRILL N PROD1 TOH TO CHANGE MOTOR SETTING 19:55 - 20:20 0.42 DRILL N PROD1 BENT HOUSING ON MOTOR BACKED OFF. OVER 1" GAP. 20:20 - 21 :30 1.17 DRILL N PROD1 DOWN LOAD MWD DATA 21 :30 - 23:00 1.50 DRILL N PROD1 PU BHA #6 1.5 DEGREE MOTOR AND CHANGEOUT MWD PROBE. GAMMA RAY DATA HAD A GAP SO PROBE WAS CHANGED. 23:00 - 00:00 1.00 DRILL N PROD1 RUNNING IN HOLE AT 4000' 10/17/2001 00:00 - 02:00 2.00 DRILL N PROD1 RIH. NO PROBLEM THRU WINDOW PU 44,000 SO 11,000 CORRECTED -26' TO FLAG 02:00 - 02:18 0.30 DRILL P PROD1 DRILLING AT 2.6 BPM 84 FT/HR NO LOSSES 02:18 - 02:30 0.20 DRILL P PROD1 SURVEY AT 13127' 02:30 - 02:51 0.35 DRILL P PROD1 DIRECTIONALLY DRILL TO 13,150' 02:51 - 03:04 0.22 DRILL P PROD1 SURVEY @ 13147' 03:04 - 05:20 2.27 DRILL P PROD1 DIRECTIONALL Y DRILL TO 13,250' 05:20 - 05:45 0.42 DRILL P PROD1 WIPER TRIP TO WINDOW. NO PROBLEMS 05:45 - 08:20 2.58 DRILL P PROD1 DIRECTIONALL Y DRILL F/13,250' TO 13384'. 3280 FS 3600 BTM, 08:20 - 09:10 0.83 DRILL P PROD1 WIPER TRIP TO WINDOW. NO PROBLEMS 09:10 - 12:30 3.33 DRILL P PROD1 DIRECTIONALL Y DRILL F/13,384'. ORIENT TF 45L BUILD TO GET BACK ON WELLPLAN. DRILL TO 13525'. 12:30 - 13:45 1.25 DRILL P PROD1 WIPER TRIP TO WINDOW. 13:45 - 15:40 1.92 DRILL P PROD1 DIRECTIONALL Y DRILL F/13525' TO 13611'. 3650 PSI ON BTM. PLAN TO MAKE MUD SWAP THE AFTERNOON. MWD APPARENTLY HAS FAILED INTERMINTANT SIGNALS. FINISH CIRC NEW MUD TO SURFACE. 15:40 - 17:30 1.83 DRILL N DFAL PROD1 EVALUATE MWD 17:30 -19:50 2.33 DRILL N DFAL PROD1 POH MWD FAILED 19:50 - 20:30 0.67 DRILL N DFAL PROD1 DOWN LOAD MWD DATA 20:30 - 21 :00 0.50 DRILL N DFAL PROD1 PU NEW MOTOR AND MWD 21 :00 - 23:30 2.50 DRILL N DFAL PROD1 TEST MWD 23:30 - 00:00 0.50 DRILL N DFAL PROD1 START PICKING UP PH6 STINGER(18 JOINTS) 10/18/2001 00:00 - 01 :46 1.77 DRILL N DFAL PROD1 STAB INJECTOR AND STRIP DOWN. 01:46 - 02:10 0.40 DRILL N DFAL PROD1 RIH to 1500'. ( ( Printed: 11/1/2001 9:39:53 AM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07 A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date From - To Hours Activity Code NPT Phase Description of Operations 10/18/2001 02:10 - 02:20 0.17 DRILL N DFAL PROD1 SHALLOW TEST OK 02:20 - 04:24 2.07 DRILL N DFAL PROD1 RIH TO 12600'. SAME TIME REPLACE VALVES & SEATS ON NABORS PUMP. 04:24 - 04:45 0.35 DRILL N DFAL PROD1 BLOW DOWN LINES ON DOWELL PUMP. 04:45 - 05:00 0.25 DRILL N DFAL PROD1 SEAT VALVES IN NABORS PUMP SUBSEQUENT TO ROUTINE MAINTENANCE. 05:00 - 06:10 1.17 DRILL N DFAL PROD1 TIE-IN TO RA TAG AT 12681' CORRECT +19'. 06:10 - 10:30 4.33 DRILL N DFAL PROD1 TIH TO 12740'. 10:30-12:00 1.50 DRILL N DPRB PROD1 PROBLEMS GETTING TO BOTTOM WITH PH-6. WORK PIPE F/12740' TO 13611'. SEEING SMALL CHUNKS OF STATOR RUBBER FROM MUD MOTOR COMING ACROSS SHAKERS WHILE DOING SO. 12:00 - 12:15 0.25 DRILL N DFAL PROD1 ON BOTTOM BUT UNABLE TO SEE ANY MOTOR WORK. GETTIING GOOD WEIGHT TRANSFER AND WEIGHT TO BIT. IT APPEARS THAT THE MOTOR HAS CHUNKED OUT. 12:15 -15:15 3.00 DRILL N DFAL PROD1 TOH. SET BACK INJECTOR. 15:15 -15:30 0.25 DRILL N DFAL PROD1 PJSM ABOUT RACKING BACK PH-6 TBG. 15:30 -15:35 0.08 DRILL N RREP PROD1 PREP TO SETBACK PH-6 TBG AND LOST ALL AIR TO DRAW WORKS. 15:35 -18:10 2.58 DRILL N RREP PROD1 REPLACE SHUTTLE AIR VALVE TO DRAW WORKS. 18:10 - 20:00 1.83 DRILL N DFAL PROD1 TOH STANDBACK PH-6. DOWNLOAD INFO FROM TORC. DRAINED MOTOR, APPEARS TO BE OKAY BUT SO DID THE OTHER MOTOR FROM P-25L 1 THAT CHUNKED RUBBER AND WOULDN'T DRILL ON BOTTOM. BIT IN GAUGE. 20:00 - 22:50 2.83 DRILL N DFAL PROD1 P/U 1.37 BAKER MOTOR. (ANADRILL DOES NOT WANT TO RUN THEIR MOTORS BEFORE CHECKING SPECS ON STATOR RUBBER). M/U SPERRY MWD AND WOULD SURFACE TEST. CHANGE OUT PROBS AND TESTS OKAY. 22:50 - 23:50 1.00 DRILL N DFAL PROD1 RIH WITH BHA#8 23:50 - 00:00 0.17 DRILL N DFAL PROD1 PU INJECTOR 10/19/2001 00:00 - 00:35 0.58 DRILL N DFAL PROD1 PT MHA AND STRIP DOWN. 00:35 - 00:50 0.25 DRILL N DFAL PROD1 RIH TO 1000' AND SHALLOW TEST OK 00:50 - 03:41 2.85 DRILL N DFAL PROD1 RIH TO 12699' 03:41 - 03:45 0.07 DRILL N DFAL PROD1 CORRECT TI RA TAG +14'. 03:45 - 04:12 0.45 DRILL N DFAL PROD1 TAG TD AT 13627'. 04:12 - 05:30 1.30 DRILL P PROD1 DIRECTIONALLY DRILLING F/13627' TO 13659'. HAVING TROUBLE WITH WEIGHT TRANSFER, STACKING WT. MAY ALSO BE THE THIRD FAULT REVISED PREDICTIONS PUT IT AT 13660'. NO MUD LOSSES SO FAR. 05:30 - 07:30 2.00 DRILL P PROD1 WIPER TRIP AND ADDING 2 DRUMS "LUBE TEX" TO SYSTEM 07:30 - 08:05 0.58 DRILL P PROD1 ORIENTING TO 90+R. SLOW ORIENTATION FOR SOME REASON THIS MORNING. 08:05 - 10:40 2.58 DRILL P PROD1 DIRECTIONALL Y DRILLING F/13659'. ON BOTTOM 3600 PSI FREESPIN 3200 PSI. 2.6/2.6 BPM GOOD WEIGHT TRANSFER 1 OO'/HR NO MUD LOSSES (13688'). DRILLED TO 13792'. 10:40 - 12:05 1.42 DRILL P PROD1 WIPER TRIP TO WINDOW.1110' 12:05 - 16:00 3.92 DRILL P PROD1 DIRECTIONALLY DRILL F/13792' TO 13924'. NO MUD LOSSES TO HOLE. HAVING TROUBLE WITH MWD NOT SENDING GOOD CONSISTANT SURVEY DATA. 16:00-17:05 1.08 DRILL P PROD1 WIPER TRIP TO WINDOW NO PROBLEMS 1244'. WILL (" ( Printed: 11/1/2001 9:39:53 AM BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07 A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date From - To Hours Activity Code NPT Phase Description of Operations 10/19/2001 16:00 -17:05 1.08 DRILL P PROD1 WORK WITH MWD FOR A LITTLE WHILE MAY NEED TO TRIP. 17:05 - 17:15 0.17 DRILL N DFAL PROD1 NO RESPONCE FROM MWD SURVEY PACKAGE. 17:15 - 20:00 2.75 DRILL N DFAL PROD1 POH TO SURFACE 20:00 - 20:40 0.67 DRILL N DFAL PROD1 BREAK OFF LUBRICATOR, SET INJECTOR BACK, FREEZE PROTECT COIL. 20:40 - 21 :30 0.83 DRILL N DFAL PROD1 STAND BACK PH6 TUBING 21 :30 - 23:00 1.50 DRILL N DFAL PROD1 LD TORC & MWD TOOLS 23:00 - 00:00 1.00 DRILL P PROD1 SET TWC. GREASE VALVES, PREP FOR BOP TEST. 10/20/2001 00:00 - 05:30 5.50 DRILL P PROD1 TEST BOP'S. AOGCC NOTIFIED. JEFF JONES WAIVED WITNESSING TEST. 05:30 - 08:45 3.25 DRILL N WAIT PROD1 WAIT ON VALVE CREW. CREW CHANGE HOLD PJSM ABOUT P/U BHA. HOLD SPILL DRILL. 08:45 - 09:00 0.25 DRILL P PROD1 PULL 2-WA Y CHECK. 09:00 - 12:25 3.42 DRILL P PROD1 MU BHA #9. SURFACE TEST "NEW" MWD AND TORC TOOLS - OKAY. RIH W/9 STDS PH-6 TBG. 12:25 - 14:00 1.58 DRILL P PROD1 P/U INJECTOR. CIRCULATE METHANOL OUT OF COIL. STAB ON INJECTOR. 14:00 - 16:50 2.83 DRILL P PROD1 RIH TO 1500' SHALLOW TEST TOOLS - OKAY. CaNT. RIH 16:50 - 17:45 0.92 DRILL P PROD1 LOG TIE IN AT "RA"-22' CORRECTION. 17:45 - 19:26 1.68 DRILL P PROD1 DIRECTIONALL Y DRILL TO 13,970. AFTER SHORT TRIP TORC WOULDN'T RETURN TO 170RT. 19:26 - 20:30 1.07 DRILL P PROD1 SEND ROTATE COMMAND AND AFTER A COUPLE ATTEMPTS WHILE PICKING UP THE TOOL RESPONDED.AFTERWARDS IT ACCEPTED THE 150 DEGREE COMMAND 20:30 - 22:10 1.67 DRILL P PROD1 SHORT TRIP 666' 22:10 - 00:00 1.83 DRILL P PROD1 DRILL TO 14057. SEND 50 DEGREE COMMAND. DRILL TO 13120 SEND 300 DEGREE COMMAND. DRILL TO 14140. CIRCULATING AT 2.5 BPM 3600 PSI CIRCULATING PRESSURE 10/21/2001 00:00 - 03:58 3.97 DRILL P PROD1 DRILL TO 14,187'. DRILLING WITH DS PUMP AND SWITCHING TO NABORS PUMP FOR SURVEYS. NABORS PUMP UNABLE TO PUMP ABOVE 2.4 BPM. DS PUMP HAS NO PULSE DAMPNER THERFORE SURVEY CANNOT BE DONE WITH THE DS PUMP. 03:58 - 04:30 0.53 DRILL N STUC PROD1 PUMP 30 BBL NEW MUD 04:30 - 05:40 1.17 DRILL N STUC PROD1 RU AND PUMP 20 BBL CRUDE OIL. PIPE FREE AFTER SETTING 10 MIN. 05:40 - 06:15 0.58 DRILL N PROD1 WIPER TRIP 200'. WORKING ON NABORS PUMP TO IDENTIFY LOSS OF PUMP EFFICIENCY 06:15 - 06:45 0.50 DRILL P PROD1 DIRECTIONALL Y DRILL F/14187' TO 14237'. THE FLUID END ON THE NABORS PUMP IS WASHED OUT. SPARE IN DEADHORSE. PUMP WILL BE DOWN MOST OF THE DAY. RUNNING DS PUMP AT 2.5 BPM, ANY FASTER CAUSES INTERFERENCE WITH SPERRY TOOLS. 06:45 - 08:40 1.92 DRILL P PROD1 WIPER TRIP TO WINDOW. HOLE IN GOOD SHAPE 08:40 - 08:55 0.25 DRILL P PROD1 ORIENT. TORC WORKING GOOD. 08:55 - 11 :50 2.92 DRILL P PROD1 DIRECTIONALL Y DRILL F/14237' TO 14328' 2.5 2.5 PP 4100 PSI 11 :50 - 15:30 3.67 DRILL P PROD1 TORC TOOL NOT RESPONDING TO COMMANDS. MAKING A WIPER TRIP TRYING TO CLEAR ANY HOLE CONDITIONS UP. PUT TORC IN CONTINUES ROTATION MODE WITH (' ( Printed: 11/1/2001 9:39:53AM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: P-07 Common Well Name: P-07 A Spud Date: 1/8/1995 Event Name: REENTER+COMPLETE Start: 10/11/2001 End: 10/23/2001 Contractor Name: NABORS Rig Release: 10/23/2001 Rig Name: NABORS 3S Rig Number: 3S Date From - To Hours Activity Code NPT Phase Description of Operations 10/21/2001 11 :50 - 15:30 3.67 DRILL P PROD1 GOOD RES PONCE. BUT STILL FIGHTING IT WITH INDIVIDUAL TF SETTINGS. BRING NABORS PUMP BACK ONLINE AND WILL TRY WITH IT. TORC IS BASICIAL Y DEAD. 15:30 - 18:00 2.50 DRILL P PROD1 DIRECTIONALL Y DRILL F/14328' TO 14380' HOLDING 50-70R TF. STACKING WEIGHT. RESISTIVITY DROPPING TO 5 OHMS AND HOLDING LAST 10'. UNABLE TO ACCURATELY DRILL EITHER UP OR DOWN TO GET OUT OF THIS ZONE. TOWN WANTS TO DRILL AHEAD IN HOPES OF FINDING HIGHER RES. 18:00 -19:00 1.00 DRILL P PROD1 SHORT WIPER TRIP 19:00 -19:30 0.50 DRILL P PROD1 MOTOR RUBBER COMING OVER SHAKER. WEIGHT STACKING OUT NO REACTIVE TORQUE SHOWING. MOTOR WORN OUT.WAIT ON ORDERS. ANCHORAGE DECIDED TO CALL THIS TD. 19:30 - 22:15 2.75 DRILL P PROD1 MAD PASS TO WINDOW. 22:15 - 23:30 1.25 DRILL P PROD1 TIE IN TO RA TAG CORRECTION +21'. 23:30 - 00:00 0.50 DRILL P PROD1 RIH TO CONFIRM TD. 10/22/2001 00:00 - 01 :00 1.00 DRILL P PROD1 LAY IN NEW MUD IN OPENHOLE. 01:00 - 01:34 0.57 DRILL P PROD1 DROP 5/8 BALL CIRCULATE BALL DOWN. OPEN CIRC SUB. 01 :34 - 03:00 1.43 DRILL P PROD1 POH TO 1800' 03:00 - 03:20 0.33 DRILL P PROD1 FREEZE PROTECT COIL. 03:20 - 04:20 1.00 DRILL P PROD1 STRIP OFF WELL.SET INJECTOR BACK ON THE DECK. 04:20 - 05:15 0.92 DRILL P PROD1 LD PH-6 TUBING. 05: 15 - 06:45 1.50 DRILL P PROD1 LID BAKER AND SPERRY SUN TOOLS. 06:45 - 07:45 1.00 CASE P COMP CLEAR FLOOR AND PREP TO RUN 2 7/8" LINER 07:45 - 08:00 0.25 CASE P COMP PJSM CONCERNING P/U LINER 08:00 - 12:30 4.50 CASE P COMP P/U 2 7/8" AND 31/2" LINER 12:30 -13:45 1.25 CASE P COMP P/U INJECTOR. CIRCULATE COIL TO MUD AT SURFACE. DISPLACE TO OPENTOP TANK. 13:45 - 14:45 1.00 CASE P COMP MAKE UP MHA TO LINER. HANGING WEIGHT 6K 14:45 -17:40 2.92 CASE P COMP TIH W/ LINER to 14395. NO PROBLEMS - NEVER TOOK WEIGHT. 17:40 -18:20 0.67 CASE P COMP DROP 5/8" DISCONNECT BALL. LINER RELEASED WITH 3200 PSI. 18:20 -18:45 0.42 CASE P COMP SWAP 41/2" PRODUCTION TUBING TO 8.5 PPG 3% KCL 18:45 - 21 :55 3.17 CASE P COMP POH FREEZE PROTECT WELL FROM 2000' TO SURFACE. 21 :55 - 22:20 0.42 CASE P COMP SET BPV 22:20 - 00:00 1.67 CASE P COMP RU N2 AND TEST LINES. 10/23/2001 00:00 - 03:00 3.00 CASE P COMP BLOW DOWN COIL WIH N2. R/D N2 PUMPER 03:00 - 09:00 6.00 CASE P COMP SETBACK INJECTOR UNSTAB COIL. RID DS #4. (OFF LOCATION AT 0700 WILL DO GENERAL MANIT AND CHG OUT COIL) NIPPLE DOWN BOPE INSTALL CAP AND TEST TO 4K. KNOCK DOWN HARD LINES TO OUTSIDE TANKS. 09:00 - 09:01 0.02 CASE P COMP NABOR 3S RELEASED AT 0900 HRS 10-23-2001 09:00 - 0.00 CASE P COMP R/D NABORS 3S. PLAN TO START MOVE +/-1200 HRS END OF REPORT 10/24/2001 00:00 - 0.00 CASE COMP (" ( Printed: 11/1/2001 9:39:53 AM ( ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well P-07 A aD J- 19~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,510.00' MD Window / Kickoff Survey 12,676.00' MD Projected Survey: 14,395.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 07-Nov-01 ECEIVED Nav 1 J 2001 A~aska Oil & Gas Co~'" . A... i1i), CûmmeSSian nr.¡~rage DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA P Pad, Slot P-O7 P-O7 A Job No. AKMW11170, Surveyed: 21 October, 2001 -~l SURVEY REPORT 7 November, 2001 Your Ref: API 500292253501 Surface Coordinates: 5947203.00 N, 631228.00 E (70015' 49.8891" N, 148056' 20.4835" W) Kelly Bushing: 88.04ft above Mean Sea Level -- spear""'" 'J - BUll DRILLING seRVices A Halliburton Company Survey Ref: svy11005 Sperry-Sun Drilling Services . Survey Report for P-07 A DEF\N'1\VE Your Ref: API 500292253501 Job No. AKMW11170, Surveyed: 21 October, 2001 Alaska Drilling & Wells North Slope Alaska PBU WOA P Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ~c 12510.00 20.220 291.800 8564.55 8652.59 1046.41 N 8118.16 W 5948107.76 N 623092.84 E -2615.49 Tie On Point MWD Magnetic 12610.00 19.340 295.090 8658.66 8746.70 1059.85 N 8149.20 W 5948120.66 N 623061.56 E 1.419 -2634.75 12676.00 19.050 296.390 8720.99 8809.03 1069.27 N 8168.75 W 5948129.74 N 623041.86 E 0.783 -2647.82 Window Point 12702.57 23.050 264.530 8745.86 8833.90 1070.71 N 8177.84 W 5948131.01 N 623032.74 E 44.994 -2651.01 12729.57 29.160 243.490 8770.14 8858.18 1067.26 N 8189.03 W 5948127.37 N 623021.62 E 40.771 -2649.81 12754.37 30.400 229.500 8791.70 8879.74 1060.48 N 8199.22 W 5948120.41 N 623011.55 E 28.403 -2645.16 12778.97 31.360 218.770 8812.82 8900.86 1051.44 N 8207.96 W 5948111.22 N 623002.96 E 22.698 -2638.01 12799.97 33.150 209.300 8830.59 8918.63 1042.16 N 8214.20 W 5948101.84 N 622996.88 E 25.505 -2630.13 12820.17 35.120 195.470 8847.34 8935.38 1031.73 N 8218.46 W 5948091.33 N 622992.81 E 39.562 -2620.73 12840.17 36.680 183.060 8863.56 8951.60 1020.21 N 8220.32 W 5948079.78 N 622991.15 E 37.158 -2609.80 12859.97 38.070 173.780 8879.31 8967.35 1008.22 N 8219.97 W 5948067.80 N 622991.71 E 29.281 -2597.98 12880.17 39.150 159.660 8895.12 8983.16 996.03 N 8217.07 W 5948055.66 N 622994.82 E 43.875 -2585.45 12899.97 40.560 147.650 8910.35 8998.39 984.71 N 8211.45 W 5948044.44 N 623000.64 E 39.472 -2573.25 12919.97 48.160 153.560 8924.64 9012.68 972.52 N 8204.64 W 5948032.38 N 623007.66 E 43.221 -2559.97 12939.97 54.870 150.160 8937.08 9025.12 958.74 N 8197.24 W 5948018.72 N 623015.29 E 36.084 -2545.00 --- 12959.97 62.040 149.540 8947.54 9035.58 944.01 N 8188.68 W 5948004.15 N 623024.11 E 35.947 -2528.88 ~>. 12979.97 68.740 153.570 8955.87 9043.91 928.03 N 8180.04 W 5947988.32 N 623033.02 E 38.173 -2511.52 12999.97 75.900 150.380 8961.94 9049.98 911.23 N 8171.09W 5947971.67 N 623042.27 E 38.887 -2493.29 13019.97 83.550 149.250 8965.50 9053.54 894.23 N 8161.20 W 5947954.85 N 623052.45 E 38.651 -2474.68 13033.17 88.030 152.080 8966.4 7 9054.51 882.76 N 8154.75 W 5947943.49 N 623059.10 E 40.110 -2462.17 13044.38 90.660 154.670 8966.60 9054.64 872.74 N 8149.73 W 5947933.56 N 623064.30 E 32.925 -2451.36 13060.98 94.630 153.080 8965.83 9053.87 857.85 N 8142.43 W 5947918.81 N 623071.85 E 25.758 -2435.34 13081.38 92.860 150.610 8964.50 9052.54 839.91 N 8132.83 W 5947901.03 N 623081.77 E 14.874 -2415.86 13107.58 90.340 148.880 8963.77 9051.81 817.29 N 8119.63 W 5947878.65 N 623095.36 E 11.665 -2391.09 13127.38 95.080 147.380 8962.83 9050.87 BOO. 50 N 8109.19W 5947862.04 N 623106.09 E 25.106 -2372.58 13158.18 98.770 146.560 8959.12 9047.16 774.B7 N 8092.53 W 5947836.70 N 623123.19 E 12.268 -2344.19 13198.78 98.680 140.220 8952.95 9040.99 742.67 N 8068.61 W 5947804.93 N 623147.67 E 15.436 -2307.93 13226.98 98.130 131.510 8948.83 9036.B7 722.67 N 8049.20 W 5947785.27 N 623167.42 E 30.616 -2284.52 13249.78 97.090 128.410 8945.81 9033.85 708.16 N 8031.88 W 5947771.06 N 623184.99 E 14.228 -2266.90 13267.58 96.830 124.890 8943.65 9031.69 697.61 N 8017.71 W 5947760.77 N 623199.35 E 19.684 -2253.78 -~----- -..--.-- 7 November, 2001 - 14:05 Page 2 of 5 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for P-07 A Your Ref: API 500292253501 Job No. AKMW11170, Surveyed: 21 October, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA P Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 13300.18 97.620 126.120 8939.55 9027.59 678.83 N 7991.38 W 5947742.45 N 623226.00 E 4.459 -2230.21 -~,. 13341.38 97.530 135.810 8934.10 9022.14 652.09 N 7960.58 W 5947716.25 N 623257.26 E 23.315 -2197.95 13375.78 97.270 143.390 8929.67 9017.71 626.13 N 7938.49 W 5947690.67 N 623279.80 E 21.864 -2168.17 13403.38 98.940 147.440 8925.77 9013.81 603.64 N 7922.98 W 5947668.46 N 623295.70 E 15.736 -2143.08 13433.98 102.380 154.490 8920.11 9008.15 577.38 N 7908.39 W 5947642.45 N 623310.75 E 25.275 -2114.47 13462.18 100.700 159.780 8914.46 9002.50 551.93 N 7897.66 W 5947617.19 N 623321.92 E 19.320 -2087.41 13495.78 98.770 165.770 8908.78 8996.82 520.31 N 7887.86 W 5947585.75 N 623332.26 E 18.485 -2054.49 13522.98 97.180 169.640 8905.00 8993.04 494.00 N 7882.13 W 5947559.54 N 623338.46 E 15.254 -2027.56 13547.38 97.000 163.300 8901.99 8990.03 470.47 N 7876.47 W 5947536.12 N 623344.53 E 25.795 -2003.38 13569.98 96.210 158.370 8899.39 8987.43 449.27 N 7869.10 W 5947515.05 N 623352.26 E 21.949 -1981.15 13609.74 95.510 153.990 8895.32 8983.36 413.10 N 7853.13 W 5947479.16 N 623368.86 E 11.099 -1942.55 13631.54 95.680 151.500 8893.20 8981.24 393.81 N 7843.20 W 5947460.05 N 623379.13 E 11.394 -1921.69 13665.74 98.240 152.550 8889.05 8977.09 363.83 N 7827.27 W 5947430.35 N 623395.58 E 8.082 -1889.18 13692.54 96.920 158.010 8885.52 8973.56 339.71 N 7816.17 W 5947406.43 N 623407.10 E 20.786 -1863.35 13720.14 96.040 162.070 8882.40 8970.44 313.94 N 7806.81 W 5947380.83 N 623416.90 E 14.960 -1836.24 13747.54 95.560 164.660 8879.63 8967.67 287.82 N 7799.01 W 5947354.85 N 623425.16 E 9.566 -1809.10 13781.14 95.240 168.760 8876.47 8964.51 255.27 N 7791.32 W 5947322.44 N 623433.41 E 12.185 -1775.68 13811.94 95.510 176.160 8873.58 8961.62 224.90 N 7787.30 W 5947292.14 N 623437.96 E 23.936 -1745.10 ~-'. 13865.94 92.470 181.040 8869.82 8957.86 171.07 N 7785.99 W 5947238.34 N 623440.21 E 10.628 -1692.06 13880.94 91.810 182.330 8869.26 8957.30 156.08 N 7786.43 W 5947223.35 N 623440.03 E 9.655 -1677.45 13910.52 91.930 184.350 8868.29 8956.33 126.57 N 7788.15 W 5947193.81 N 623438.83 E 6.837 -1648.85 13946.52 90.860 187.620 8867.42 8955.46 90.78 N 7791.90 W 5947157.96 N 623435.70 E 9.555 -1614.49 13978.92 87.670 188.680 8867.83 8955.87 58.72 N 7796.49 W 5947125.82 N 623431.67 E 10.375 -1583.94 14004.12 84.050 189.560 8869.65 8957.69 33.91 N 7800.48 W 5947100.94 N 623428.12 E 14.781 -1560.39 14044.32 77.970 187.620 8875.93 8963.97 5.335 7806.41 W 5947061.61 N 623422.87 E 15.857 -1523.07 14087.92 77.620 189.030 8885.15 8973.19 47.50 S 7812.58 W 5947019.34 N 623417.43 E 3.261 -1482.93 14139.52 82.910 194.840 8893.88 8981.92 97.21 S 7823.11 W 5946969.45 N 623407.77 E 15.105 -1436.24 14168.12 86.730 191.350 8896.46 8984.50 124.95 S 7829.56 W 5946941.61 N 623401.81 E 18.057 -1410.30 14211.92 90.750 193.790 8897.42 8985.46 167.67 S 7839.09 W 5946898.72 N 623393.03 E 10.735 -1370.27 14251.72 91.280 184.620 8896.72 8984.76 206.91 S 7845.44 W 5946859.38 N 623387.35 E 23.075 -1333.03 _..- - - ----- 7 November, 2001 - 14:05 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for P-07 A Your Ref: API 500292253501 Job No. AKMW11170, Surveyed: 21 October, 2001 . Alaska Drilling & Wells North Slope Alaska PBU WOA P Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) -- 14287.32 88.990 176.520 8896.63 8984.67 242.48 S 7845.80 W 5946823.81 N 623387.62 E 23.643 -1298.23 14319.12 86.520 170.170 8897.88 8985.92 274.02 S 7842.12 W 5946792.34 N 623391.85 E 21.410 -1266.57 14353.32 85,900 170.700 8900.14 8988.18 307.67 S 7836.45 W 5946758.79 N 623398.10 E 2.383 -1232.46 14395.00 85.110 171.410 8903.41 8991.45 348.72 S 7829.99 W 5946717.87 N 623405.28 E 2.545 -1190.95 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.377° (13-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 168.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14395.00ft., The Bottom Hole Displacement is 7837.75ft., in the Direction of 267.450° (True). Comments ~- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12510.00 12676.00 14395.00 8652.59 8809.03 8991,45 1046.41 N 1069.27 N 348.72 S 8118.16 W 8168.75 W 7829.99 W Tie On Point Window Point Projected Survey 7 November, 2001 - 14:05 Page 4 of 5 DrillQuest 2.00.08.005 North Slope Alaska Survey tool program for P-07 A From Measured Vertical Depth Depth (ft) (ft) 0.00 12510.00 0.00 8652.59 r- 7 November, 2001 - 14:05 To Measured Vertical Depth Depth (ft) (ft) 12510.00 14395.00 Sperry-Sun Drilling Services Survey Report for P-07 A Your Ref: API 500292253501 Job No. AKMW11170, Surveyed: 21 October, 2001 Survey Tool Description 8652.59 AK-1 BP _HG - BP High Accuracy Gyro (P-O7) 8991.45 MWD Magnetic (P-O7 A) ------._----- Page 5 of 5 . Alaska Drilling & Wells PBU WOA Þ Pad .~-. --"0 --------------- DrillQuest 2.00.08.005 ti ( ~1f !A\1fŒ (ill ~ !A\~!A\~[\!A\ / TONY KNOWLES, GOVERNOR ALAS KA 0 IL AND GAS CONSERVAnONCO~SSION 333 W. ]TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit P-07 A BP Exploration Alaska, Inc. Permit No: 201-196 Sur Loc: 2476' NSL, 1944' EWL, Sec. 31, TIIN, R13E, UM Btmhole Loc. 1985' NSL, 613' WEL, Sec. 35, TIIN, R12E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit P-07 A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~-~ Cammy Otàhsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 5th day of October, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA { ... AND GAS CONSERVATION COMf\Í PERMIT TO DRILL 20 MC 25.005 .. ALASK/( 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 24761 NSL, 1944' EWL, SEC. 31, T11N, R13E, UM At top of productive interval 3559' NSL, 981' WEL, SEC. 35, T11N, R12E, UM At total depth 1985' NSL, 613' WEL, SEC. 35, T11N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028265, 1985' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 126821 MD Maximum Hole Angle 18. Casin~ Program Specifications IZ Hole Casin Gra e Cou lin 3-3/4" 3-1/2" x 3-3116" L-80 ST-L x 2-7/8" 1 b. Type of well .>ION ,j.'U\ '(\ \' ,) \ -",,_0-. it\lY~ ¡ ~~¡,~ '.- --~ ~l \U,l. ~ ~ - 0 Exploratory Q8tratigraphic Test II Development Oil 0 Service 0 Development Gas mI Si Ie Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) O. Field and Pool KBE = 88.041 Prudhoe Bay Field / Prudhoe 6. Property Designation oz ., .. Bay Pool ADL 028264 ..J]) 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Prudhoe Bay Unit 8. Well Number Number 2S 100302630-277 9. Approximate spud date ,;,:~_~i:' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14450' MD /89551 TVDss 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} 96 0 Maximum surfac~!:g, At total depth (TVD) 8800' / 3300 psig Setting Depth TVD 8630' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fore oin is true and correct to the best of my knowledge Signed Thomas McCarty /' ':/{. '.., ¡1.{y~ Title CT Drilling Engineer 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 13102 feet 9214 feet 12979 feet 9097 feet Length Size 80' 3608' 20" 10-3/4" 13063' 7-5/8" Perforation depth: measured 12803' - 128431 true vertical 8929' - 8967' 20. Attachments Plugs (measured) Junk (measured) Cemented MD TVD 260 sx Arcticset (Approx.) 110' 110' 1046 sx Coldset III, 375 sx Class IGI 36381 3249' 265 sx Class IG' 13094' 92061 (' 1:") C}) ¡' 2 () 0 ',I ,) t If (..,1 ,J .. c' ~ f\i3.si'..31 Oil (~ Gas Cons. Colnniis;;icn ....'..,; ',. :..i:i,'::\,:;,:::.::':::::!:::::,:;::,'::!;::::.:),':;..::"!::'¡'::':':;:,';:/:::::"::.:;:,:):).',\;:"¡i:':':'.:i:!:::'.;:'.:'::'::.":,.::¡i,t,::.,,;.:i::'¡::.,::;:::::~;:":::¡'~:i,::¡Çøroijjj~~.iñ;¡':~:,.:!:~n:~y::::!::,:::!.,:':,:jij:¡,¡:;::'::;¡:i:..:::.i,;,:,r ;::.::::;!',:::.::",:,;; ¡:;:::::. ¡ ,'::.::,. ...'.",:,... API Number 50- 029-22535-01 Samples Required DYes rg;J No Hydrogen Sulfide Measures 1!.1 Yes D No Required Working Pressure for BOPE D 2K D 3K Other: Ap 0 al at See cover letter () for other re uirements Mud Log Req ire DYes BI No Directional Survey Required 1&1 Yes D No D 4K D 5K D 10K D 15K R.3.5K psi for CTU Permit Number ~bl" I Conditions of Approval: Rev. 12-01-85 Origins' Signed By . Commissioner ORIGIN by order of the commission Date ( BPX P-07 A CTD Sidetrack ('" Summary of Operations: A CTD horizontal sidetrack of well P-07 A is proposed. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus (IA). Drift liner. P&A. Planned for September 28, 2001 . Drift well with dummy whipstock to pbtd. ~ . Integrity test IA after fluid packing & installing dummy gas lift valves. ~d<"\. . P&A existing perforations with approx. bbls of 17ppg cement. î? . Mill window with service coil if available. Phase 2: Drill and Complete CTD horizontal Sidetrack: Planned for October 18, 2001 2%" coil will be used to drill a 33A" open hole sidetrack, approx. 1768' feet. (as per attached plan) A solid/uncemented and slotted 3-1/2"x 3-3/16" x 2-7/8" liner completion will be run. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular disposal on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 3-1 /2" siJ.¿i~~8g¡~,~:['I from the top of the liner at approx. 12580' md (TOl, 8630' TVDss) to approx 12,652'md. 3-3/16", l-80, P~iJaQ¡,~IU~ii1!Hm.i!\¡wJttbe run from 12,652'md to approx. 12740'md, (TSAD, Zone 4) and then crossed over to 2%", l-80, ~!~@~t~,(¡hH:FJ>e:E~:~hich will be run to TD at approx 14,450'md. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray + Resistivity log will be run over the open hole section. . Memory CNl will be run in the cased hole after reaching TD. Hazards . H2S was measured at 20 ppm on Dec 3, 2000. . 5 fault crossings are prognosed, all five faults are believed to be non-conductive. Reservoir Pressure . Reservoir pressure is estimated to be 3,300 psi (7.2ppg) at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is ~~ W 8.. LI-EA D = 5M FMC ACTUATOR= BAKER KB. ELEV = 88.04' BE ELEV = 59.86' KOP= 700' Max AnQle = 57 @ 6110' Datum MD = 12759' Datum TVDss= 8800' P-O7 (' I SA FEfY NOTES ( TREE = 4-1/16" 5M ON (f) 2192' ~4-1/2" HES SSSV NP, ID = 3.813"j 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 3638' ST M) TVD 6 3250 3001 5 6385 4835 4 8731 6199 3 10621 7287 2 11762 8015 1 12490 8634 GAS LIFT MANDRELS DEV TYPE VLV LATCH SIZE 45 CArvcO KBMG-M BK 1 55 CArvcO KBMG-M BK 1 54 CArvcO KBMG-M BK 1 55 CA rvco KBMG- M BK 1 38 CArvcO KBMG-M BK 1 22 CArvcO KBMG-M BK 1 Minimum ID = 3.725" @ 12606' 4-1/2" HES 'XN' NIPPLE 12559' ~4-1/2" HES ')(' NP,ID= 3.813"1 12570' 7-5/8" x 4-1/2" BKRSABL-3 PKR,ID =3.93" w iK-22 ANCI-K)R LATCH 12595' ~4-1/2" HES ')(' NP, ID = 3.813" I 12606' ~4-1/2" HES 'XN' NIP, ID = 3.725" 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 12618' 12618' ~4-1/2"WLEG, ID= 3.958"1 I 12614' I-iELMD03129195 PERFORATION SUrvYv1ARY REF LOG: BHCS 2/15/95 ANGLEATTOPÆRF: 18@ 12803' Note: Refer to Production DB for historical perf data SIZE SFF IN1ERVAL nl z DATE 3-3/8' 6 12803-12843 0 3/29/1995 12979' 7 -5/8" CSG, 29.7#, L-80, ID = 6.875" 13093' DATE REV BY COMrvENTS 02/18/95 MOO ORIGINAL COfvPLEfION 03/04101 SIS-SL T CONVERTED TO CANVAS 03/08/01 SIS-LG ANAL 05/13/01 RN'tlh CORRECTIONS PRLDI-K)EBA Y LNIT WELL: P-07 PERMrr No: 94-1640 AA No: 50-029-22535-00 Sec. 31, T11 N, R12E BP Exploration (Alaska) TREE = 4-1/16" 5M CIW WELLHEAD= 5M FMC '.................. ...............".......... .... ...... ............. ACTUA TOR= BAKER ....w_,.,.~.....w^,..w......""....,.,.,... ..,.,......w.".....w..,..w..'...-,. KB. ELEV = 88,04' BF ELEV = 59.86' ,.....'.. .', . KOP = 700' ... ...... ..... Max Angle = 57 @ 6110' ".......,.......W.'.."'."~"'.'...'_."."~"'......w,..,w..,_.......w..- Datum MD = 12759' '._W'.."....'",..,.""...'.,..".""w..w...w.. ...-..........-.'w_........'. Datum lVDss= 8800' ( P-O7 A I SAF( \JOTES PROPOSED CTD SIDETRACK 110-3/4" CSG, 45.5#, NT-80, ID = 9.953" I 3638' Minimum ID = 3.725" @ 12606' 4-1/2" HES 'XN' NIPPLE I Top of Cement 1 12575' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 12618' (Perf's to be P&A'd prior to Sidetrack) ÆRFORA TION SUMMARY REF LOG: BHCS 2/15/95 ANGLE AT TOP PERF: 118 @ 12803' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 3-3/8" 6 12803-12843 0 3/29/1995 P&A'd wi Cement 17-5/8" CSG, 29.7#, L-80, ID = 6.875" I 13093' (8 2192' --14-1/2" HES SSSV NIP, ID = 3.813" I ST MD lVD 6 3250 3001 5 6385 4835 4 8731 6199 3 10621 7287 2 11762 8015 1 12490 8634 GAS LIFT MANDRELS DEV ìYPE VLV LATCH SIZE 45 CAMCO KBMG-M BK 1 55 CAMCO KBMG-M BK 1 54 CAMCO KBMG-M BK 1 55 CAMCO KBMG-M BK 1 38 CAMCO KBMG-M BK 1 22 CAMCO KBMG-M BK 1 12559' -l4-1/2" HES 'X' NIP, ID = 3.813" I 12570' 7-5/8" x 4-1/2" BKR SABL-3 PKR. ID = 3.93" w IK-22 ANCHOR LATCH -l Top of Proposed 3-3/16" Liner 12580' 12595' -l4-1/2" HES 'X' NIP, ID = 3.813" I -l4-1/2" HES 'XN' NIP, ID = 3.725" I 12606' -l4-1/2" WLEG, ID = 3.958" I 12618' l-l ELMD 03/29/951 12614' 12652' ---l 3-1/2" x 3-3/16" XO 12682' l---l Cement Ramp KOP (TOW) I I 12740' l---l 3-3/16" x 2-7/8" XO n. --_U_-"-----..---.-w.-..'-..-----..-...---------...--...---..--...-.---.. .--- .'- ."".""'---""-' ~~"I~~~~,~o~~~~~~:t~-"--; 12-7/8" L-80 Pre-Drilled Liner 1-l14450' I 12848' ---l Hard BTM Tagged 1/9/2001 1 DATE REV BY COMMENTS 02118/95 MDO ORIGINAL COMPLETION 03/04/01 SIS-SL T CONVERTED TO CANVAS 03/08/01 SIS-LG FINAL 05/13/01 RN/tlh CORRECTIONS 06/13/01 pcr P-07 A Proposed Sidetrack PRUDHOE BA Y UNIT WELL: P-07 A Proposed ST PERMIT No: 94-1640 APt No: 50-029-22535-01 Sec. 31, T11N,R12E BP Exploration (Alaska) p....,t wo.patlo: Ti... MD: lUg: Ref. Do"m: V.$octio. Aqlo "".00' BP Amoco WELLPATH DETAILS Ptooll7 P-<l7A 500212253501 P.o7 12'12.00 11 : 071/'/1"5 00:00 lI.04ft Oris;. oNJ..$ Oris;" oEf..W 0... :~ 0..0 0.00 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Cenlre: P-07. True North Vertical (TVD) Reference: System: Mean Sea level Section (VS) Reference: Slol- 07 (O.OON,O.OOE) Measured Depth Reference: 11: 07 1/8/1995 00:00 88.04 Calculation Method: Minimum Curvature SECT1OH OET""" s.. 110 In. .... "TVD oIU-S oE>-W Ous TFo.o vSe. T"S" , ""..00 ,.... _.0' ,...."" '05"'4 """'O 0.00 0.00 .2505.3' 2 ""'2.00 ,.... ...~, 072'."" '070." "UO~O 0.7. ..5... .2609.41 . '_00 ..." ""'7 ..... '4 "7.43 "UU' .4.00 230.00 -244"" 4 ,3044.2' ...00 "3.3' "2'." ...... "'60.47 '0.00 345.00 -2311.2' . ",04.2, ..... ",.22 ""'72 704.00 -8099.44 '0.00 272.00 -2238~' . ,3504.2, 02.27 "'.'4 ..T4.'2 32'.'2 ...,..., '0.00 04.00 .,145.1, 7 "",.'O ...00 '03.76 ....... 7...1 -1002.03 '0.00 265.00 .'604.71 , ""4.'° ,.... '10.60 "75.'° .03." .TO7..3. '0.00 '°2.00 -'430.77 . '4314.'0 77.0' 152.07 ,....., -37"" -7""" '0.00 250.00 ."'7.72 'O '4450.00 72.73 '31.70 ,.....,. -411... .7"7~0 '0.00 250.00 .'OU.'O II"'" 12110.00 TIP '721'" 12112.00 KOP "25.1. 121...00 1 ..21..' 13""-2. 2 .105.72 131..... 3 ..7...2 135..... . II"'" 13131.10 5 "75.10 ,...14.,0 , .....21 ,..,4.,0 7 ......2 ""0.00 TO ANNOTATiONS TVD MD "'.0..60. TIoRGETDETAJLS 1VO ...o.s <£I-W S- P<>7AT7., ""_00 ""02 -015'.75 P- P<>7A 77.2 ""_00 SOlI." -7697." P",", P-<J7A T7.3 '.,,00 39.23 .7979" P",", P<>7AT7.' '95500 -53H1 -779H9 P""" 8350 8400 8450. 8500 - C ;S 8550 .... 0 II) 8600. - .c .. 8650 . a. GJ a 8700 - ca U 8750 i 8800 > GJ 8850 :s .. ... 8900 8950 9000 9050 9100 ¡ ITœJ I j i /-1 KOP: I " 'i h í \ ! -. ! \, ¡ '. ¡ ¡ ! ! ¡ í í , ! í s , ¡ j , ! i P-07 (P-O7): v,:.;..:.:, I P-O7A T7.11 op ---. .- .-- T l Plan: Plan 117 (P.07/PlanIl7 P-07A) Crealed By: Brij Potnis Dale: 8/23/2001 lEGEND P-O7 (P-O7) - PIan#7 P-O7A Plan 117 Azimuths to True North Magnetic North: 26.40. Magnetic Field Strength: 57477nT Dip Angle: 80.74. Date: 8/23/2001 Model: BGGM2001 i I I OH':(,L(907;2tì7.GG13 I E .m,,;!: lY.i!:pot,,¡>1~j~\cQ[cm Ba~"" H"\Jhes INTEG: (,~~ì 2r,7-t6!)~~ -. i C()nl~çl ¡nf;.)lm~4tion: 1100 -~ 1000.. 900n, 800 , I P-07A T7.1 r---of\. 700 -,~'3' - C ~ 600 = 0 0 500- "I"" - - 400. + - .c 300 .. .. 0 Z 200 - - I ~ 100 c .. :s 0 en 0 -100 - -200.. -300 -400. \~ " I Plan#7 P-O7Ai .,.., 'TD1 -500" -9300-9200-9100-9000-8900-8800-8700-8600-8500-8400-8300-8200-8100-8000-7900-7800-7700-7600-7500-7400-7300-7200-7100-7000-6900-6800-6700-6600 West( - )/East( +) [100ft/in] -.,~ i]J ..~_..._j--------;---- ¡ ; P-O7A T7.3: )'6l ..--<-..-....--.---.---..-.....-....---. ..............-.;:::.-...-........ ).l[)l + i Plan#7 P-Õ7¿'\.f>..~t~:rJ.4 . . .. .. ... -2700-2650-2600-2550-2500-2450-2400-2350-2300-2250-2200-2150-2100-2Ò50-2000-1950-1900-1850-1800-1750-1700-1650-1600-1550-1500-1450-1400-1350-1300-1250-1200-1150-1100-1050-1000 -950 -gOO -850 -800 Vertical Section at 169.00° [50ft/in] -8/23/2001 3;.17 PM ObP BP Amoco ( Baker Hughes INTEQ Planning Report Rií8 IIAKUt HUGHES ,--.-..-......--...-....-.-,.--......--- INTEQ ( - - .. ..- .--., -- - -- - .. -,- -- -.---.-- -------- -- -- ---- - - .----..---.- -- ------ ---.- --- ----- ----.---"" ---- --_._----- --_..-- - --- - ----- ,-, ----" - -" - - - - - -- - -- ,,-,,' - -_.. --- -_. - -- -. - --- -------- ; ¡ : Company: BP Amoco Date: 8/23/2001 Time: 15:17:37 Page: 1 ; i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: P-07, True North ! Site: PB P Pad Vertical (TV D) Reference: System: Mean Sea Level i Well: P-07 Section (VS) Reference: Well (0_00N,0.00E,169.00Azi) L_~el!p_~!..."..:____~la~#7 P~7 A ----------------------------------------- Survey Calculation ~_et~~~_~-----_..._~~_~i_~.~~_~~-~~!~~~----_..__...__....--~~~-_._9..~~~~--_._....._-,._-j Field: -.-'--.------.--,,-----------.-.--------- ,,-,-- ---,---,,--------,----------,---------_u,,---,----_._-----. ----,-,.--..------------------------. --------,,--,-,---- Prudhoe Bay North Slope UNITED STATES 1 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 L~;~a~~~~_~~~;~~~I~~k:e~ 866~___.._---- -----------...--------------- -- -~:~~~;;~i~~~~~~_~__I~~ ~~~~~-------------- ----..---.---- ---..--_..- -- ,! Site: ,---.------'--..-.-.----- -- .-------..---------- -.---..-.---,,---,,------- ---------u_--------------,---, -'---"-"----- -------- __'_n_- ,- --.._-- ---..----- ---- -...---- -...-. -- ---- ------------.. PB P Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5949377.17 ft 623154.06 ft Latitude: 70 16 Longitude: 149 0 North Reference: Grid Convergence: 12.612 N 14.402 W True 0.94 deg ------,,_...._,------_.. -,-,- ----------,--- ,,----,,--""-----------------.-,,-...-,-..---..---.--. '-'----"-----'---'--------'----"----------""-"----"--- ------- -,,--..---- ------------------_u_-.-- -----""'--.--.----.---------- ------. "..,,-- ----------.- - ,,------,----- ---.----.----- .-------------..----..."'--------,---.-. ..--.,.... "',' ------'.--,-- - - ---- --- -- -----"-"'-' ,- ...----- - -..-_.., "..--,---.. Well: P-07 P-07 Well Position: +N/-S -2306.37 ft Northing: +E/-W 8037.98 ft Easting: Position Uncertainty: 0.00 ft Slot Name: 07 70 15 49.887 N 148 56 20.483 W 5947202.81 ft 631228.03 ft Latitude: Longitude: "--",-.---..-. ..----,-,-----.------..--,-,---.---.-.---..-----, -'-----""'-----"-'-'---'-'--------------- n____....,- -"----,.._------,-----,,,-,,-,---------_.----,,---- ,,--_.. "-,,,,-,- "-,,...__.__...,,---,,--.....------------_..,,--,- " ,_.,,-----,----,- -..-,--..-...----------,,-------.--- -"-,-,,.-_._._,- ---"._-------, ----------.- - -,--------,--,--,_._---,-,.---_.--.._"--,,,,-- ---,_.._- ___m._",,__...._,-_..._- -. ,,----_._,,---, -,-_. ,,_n.._'___.-- _._-",,-,,_. Wellpath: Plan#7 P-07 A 500292253501 Current Datum: 11 : 07 1/8/1995 00:00 Magnetic Data: 8/23/2001 Field Strength: 57477 nT Vertical Section: Depth From (TVD) ft "----------'-"---- 0.00 Drilled From: P-07 Tie-on Depth: 12682.00 ft Height 88.04 ft Above System Datum: Mean Sea Level Declination: 26.40 deg Mag Dip Angle: 80.74 deg +N/-S +E/-W Direction ft ft deg ----------------------.------- '-'---'- ---.---".----..------- -- ----" ----- --- -- --.., ._-" 0.00 0.00 169.00 ..-- __n______,--.------ - "..-, ---'-----'---'-"---,-_"___.n'_.___,---"..-" ,,-.._-.,---.,,- --.-----.-- n_____._--,,- ",-,- ,-- ---"--"-""--'-""m-"-"'-' - - ""---'----"------'-----'-'-'-----"---- ...---.----------.....- "'-'-'-"'--"'.,,-_" "--"-_.",_.n_, ----..--"--..,...",,, [~~~~[ ];~Ito~~a:~[::~ =.. -~:~,,-=~-~:_- ~::[ =H~:(P~;:~-[:-:[ h:~~~~v~_~a ~~~~ =~~-[:-- [:=[=] Targets ,.........--"" "-.._,-...._--_..._....._"-,,..,, "" ._" ",,--._... "" "," ......,......." .."...-.. .....-..." "-....."..",, - """-,,...-, -,-..-"...--...." .."_..",, ,..,." ".... ".."-.....,,...., -..-".......... ,......- ....- c.."..--...-.."" -... ,." ..._"" -" ",," "...."" ...".. ".. -".--" ..-..." - """""""",, ,,-,,"'-" "...."".." .........-..... "..".... - ..-..." "......".."" ".."".- "." "-c""" ,,' ,," "_.,, "... ......"" --" ""...., Map Map <--- Latitude ---> <-- Longitude ---> . Name Description TVD +N/-S +E/-WNorthing Easting Deg Min Sec Deg Min See" , ...' ftftft , ft ft ---_._-~ ---. --- -.. -- .---- ------_... -- - ----- - ,,- ,,- ---- ---..--. ..-- ._----" _-m" .-..--...---..-.. .-- ----- ,--.-- -..-_.- -- -------..- .-----.. .------.---- -- -..--..-......-" ,- --- --..-.. - -- -----"----"" ----..- ---- ..--.. -. - ..-... - ---_.._. , ..- ----- ..-- --.. P-07A T7.1 8926.00 780.02 -8151.75 5947840.58 623064.59 70 15 57.515 N 149 0 17.738 W P-07A T7.2 8890.00 508.61 -7997.87 39.23 -7979.05 -534.71 -7794.79 5947571.92 623223.15 70 15 54.848 N 149 0 13.251 W P-07A T7.3 8870.00 5947102.98 623250.15 5946532.38 623444.37 70 15 50.231 N 70 15 44.589 N 149 0 12.688 W 149 0 7.309 W P-07A T7.4 8955.00 Annotation ----,...--.----......-------,-.-.-.---.-----,.-----,..----....---,-_.._-,_._._-,,---_._---_.~-------,-,,------_.._,.- "...-"."....-.---,.----,-.---...----.-" .-- -"-,----...__..,,, ---._---- ."-------..--.-"",-.,,..--.,,----,------.--..,-..--------,,-,,-------,..,--_._,------- '. MD ft 12610.00 12682.00 12984.00 13044.26 13194.26 13594.26 13839.10 14014.10 14314.10 14450.00 TVD ft 8658.66 8726.66 8925.14 8921.89 8905.72 8874.52 8869.59 8875.10 8919.21 8954.83 ,.."..--.. -"""'-"-"""""""""" ",,".."""""..-..-""""""-..""- ""'-'--"-""-""-""""",._,,,,,-"'-""""'-"'" TIP KOP 1 2 3 4 5 6 7 TD ------- ------------,---------,------.-.------.-- ,-,----------, -- .-,- -~----.._---- ------.--,---------------..-..--"...-.---.------- ,--,,- - -------,----, ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report Bii8 BAKU. HUGHlS '--"""""""""'--"'--'-""'-"--"- INTEQ ,'-' - --.. -. i I Company: BP Amoco ¡ Field: Prudhoe Bay ! Site: PB P Pad I Well: P-07 l__~~.~P~ th: ._~I~~~!._~~~!.~------_....__.."._..._........_._.._._.._..._._...._.. -.....--.-,,- - -.- -'------ --"'----""'--'----"'-' -- .-- _.- "----'--'---""-.---..-..-.....- ""---""---"-'-------'-------"'-"'-"....-.. .-......-.-. ..... -..-.-..---...-..----..-.. ..- .. . -- _. "-"-'-"-........--.....-..- Date: 8/23/2001 Time: 15:17:37 Page: 2 Co-ordinate(NE) Reference: Well: P-07. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,169.00Azi) .......-..-.- .... ...-..." -..... -- ---~~~~!._~~~~~..I.~!! ~~- .~-~~~.~..~:.._.... ........ ..~.i_~! ~.~~--~~-~-~~~~~.. ..-... ......... -. .-.. -~~:..- - ~.~~~~ !"........ J Plan Section Information i----"-MD-"----i~'~I"-"'--"--"A;¡~-----TVD--'-----+N/-S --- +EI-W----i>is-BuiI-d- Torn TFO Target ì l.....- - .. .- -_.~ ..,,- -..." ". -..-...... .~: ~- - ._-" ".. - ,,_.... ~ :~- -" -..." - -....- ..- --. _..~. -... - .. -...--. ..... ."" -. !!_...-.......... - -" ..._~.. ..... -."" - .. " .. ~-~,,~ ~~-~ 3!t__~ .:~~" ~ ~~~ _..~.:.~.~. ~.~,.. , . ..,- ~:~ .- - ,-,.. - -..-- ...... -.. .. -...-..- -... --- - ....-- .._".. _0'" .-.J .. 12610.00 19.34 295.09 8658.66 1059.84 -8149.20 0.00 0.00 0.00 0.00 I 12682.00 19.02 296.51 8726.66 1070.13 -8170.50 0.79 -0.44 1.97 125.12 12984.00 90.18 164.87 8925.14 897.43 -8176.96 34.00 23.56 -43.59 230.00 13044.26 96.00 163.31 8921.89 839.59 -8160.47 10.00 9.66 -2.60 345.00 13194.26 96.31 148.22 8905.72 704.00 -8099.44 10.00 0.21 -10.06 272.00 13594.26 92.27 188.14 8874.52 321.52 -8019.81 10.00 -1.01 9.98 94.00 13839.10 90.00 163.76 8869.59 79.19 -8002.63 10.00 -0.93 -9.96 265.00 14014.10 86.42 180.90 8875.10 -93.48 -7979.35 10.00 -2.05 9.79 102.00 14314.10 77.01 152.07 8919.21 -378.86 -7911.68 10.00 -3.14 -9.61 250.00 14450.00 72.73 138.70 8954.83 -486.61 -7837.50 10.00 -3.15 -9.84 250.00 L- ----.-..-----..----.......--.....--.-..------------.--..-..---.....---"'-'---_"'_...-m_-_---_"--'--"'--'-"-""-____-m.__.__-...'..---.....-. "----'-'------""'-'-""----------'--"----"----"------,-",, -- ....----- __...__m___.._.......,-- Survey ,...,-"----"'- -..--..-"..,.... .,....,. "_._."_......~.....-.__.._.._...... ,"-' ".....". ,... ".- - '...... ,.,...,,".,. ""- ,.. - ..-.....- ...- -.. ....-...- -.-... --..-... --.. ""-----"------- -... -"--"--""-'-"-"'-'-'--""""-"'-'-" . .......--..---.----.---.----.-- .-.-....... ..- ........ - MD Incl AzÎln SSTVD N1S E/W 1\Iap~ :\lapE OtS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg ... ......., """""""'-. ...". ........ ,.., "'-....." -,.........-...,......-....-.........-,-........, ..... .."" . 12610.00 19.34 295.09 8658.66 1059.84 -8149.20 5948120.38 623062.26 0.00 -2595.31 0.00 TIP 12625.00 19.27 295.38 8672.82 1 061.95 -8153.69 5948122.42 623057.73 0.79 -2598.24 125.12 MWD 12650.00 19.16 295.87 8696.42 1065.51 -8161.10 5948125.85 623050.25 0.79 -2603.15 124.84 MWD 12675.00 19.05 296.37 8720.05 1069.12 -8168.45 5948129.32 623042.85 0.79 -2608.09 124.38 MWD 12682.00 19.02 296.51 8726.66 1070.13 -8170.50 5948130.30 623040.78 0.79 -2609.47 123.91 KOP 12700.00 15.77 279.02 8743.85 1071.82 -8175.55 5948131.91 623035.71 34.00 -2612.10 230.00 MWD 12725.00 14.61 246.46 8768.02 1071.10 -8181.80 5948131.07 623029.46 34.00 -2612.58 246.70 MWD 12750.00 17.87 217.99 8792.05 1066.81 -8187.06 5948126.69 623024.28 34.00 -2609.37 278.19 MWD 12775.00 23.81 200.67 8815.43 1059.05 -8191.22 5948118.86 623020.26 34.00 -2602.55 305.57 MWD 12800.00 30.91 190.42 8837.63 1047.99 -8194.16 5948107.75 623017.51 34.00 -2592.25 321.80 MWD 12825.00 38.54 183.80 8858.17 1033.88 -8195.84 5948093.61 623016.07 34.00 -2578.72 330.93 MWD 12840.68 43.47 180.70 8870.00 1023.60 -8196.23 5948083.33 623015.86 34.00 -2568.71 336.38 P-O7 A 12850.00 46.44 179.11 8876.59 1017.02 -8196.22 5948076.75 623015.99 34.00 -2562.24 338.72 MWD 12870.77 53.11 176.08 8890.00 1001.19 -8195.54 5948060.94 623016.95 34.00 -2546.57 339.85 P-07A 12875.00 54.48 175.53 8892.50 997.78 -8195.29 5948057.54 623017.26 34.00 -2543.18 341.81 MWD 12900.00 62:60 172.60 8905.54 976.60 -8193.06 5948036.39 623019.86 34.00 -2521.96 342.14 MWD 12925.00 70.78 170.08 8915.42 953.92 -8189.59 5948013.79 623023.72 34.00 -2499.04 343.67 MWD 12950.00 78.99 167.79 8921.94 930.26 -8184.95 5947990.21 623028.77 34.00 -2474.93 344.67 MWD 12975.00 87.22 165.64 8924.94 906.13 -8179.25 5947966.18 623034.89 34.00 -2450.15 345.27 MWD 12984.00 90.18 164.87 8925.14 897.43 -8176.96 5947957.53 623037.33 34.00 -2441.18 345.48 1 13000.00 91.73 164.46 8924.87 882.00 -8172.73 5947942.18 623041.83 10.00 -2425.23 345.00 MWD 13025.00 94.14 163.81 8923.59 857.99 -8165.90 5947918.29 623049.07 10.00 -2400.35 345.06 MWD 13044.26 96.00 163.31 8921.89 839.59 -8160.47 5947899.99 623054.83 10.00 -2381.26 345.03 2 13050.00 96.02 162.73 8921.29 834.13 -8158.80 5947894.56 623056.59 10.00 -2375.58 272.00 MWD 13075.00 96.10 160.22 8918.65 810.56 -8150.91 5947871.13 623064.89 10.00 -2350.93 271.94 MWD 13100.00 96.17 157.71 8915.98 787.36 -8141.98 5947848.09 623074.22 10.00 -2326.46 271.67 MWD 13125.00 96.22 155.19 8913.28 764.58 -8132.05 5947825.49 623084.54 10.00 -2302.20 271.41 MWD 13150.00 96.26 152.68 8910.56 742.26 -8121.14 5947803.36 623095.85 10.00 -2278.21 271.13 MWD 13175.00 96.29 150.16 8907.83 720.44 -8109.25 5947781.75 623108.11 10.01 -2254.52 270.83 MWD 13194.26 96.31 148.22 8905.72 704.00 -8099.44 5947765.49 623118.21 10.01 -2236.51 270.55 3 13200.00 96.27 148.80 8905.09 699.13 -8096.46 5947760.68 623121.27 10.00 -2231.17 94.00 MWD 13225.00 96.09 151.30 8902.40 677.60 -8084.05 5947739.37 623134.05 10.00 -2207.66 94.06 MWD 13250.00 95.89 153.81 8899.79 655.54 -8072.59 5947717.51 623145.89 10.00 -2183.82 94.33 MWD 13275.00 95.69 156.31 8897.27 632.99 -8062.11 5947695.15 623156.77 10.00 -2159.68 94.59 MWD 13300.00 95.47 158.82 8894.84 609.99 -8052.61 5947672.32 623166.66 10.00 -2135.29 94.85 MWD 13325.00 95.24 161.32 8892.50 586.59 -8044.13 5947649.07 623175.55 10.00 -2110.71 95.09 MWD 13350.00 95.01 163.82 8890.27 562.84 -8036.67 5947625.46 623183.42 10.00 -2085.96 95.32 MWD 13375.00 94.76 166.31 8888.14 538.77 -8030.25 5947601.51 623190.26 10.00 -2061.12 95.55 MWD 13400.00 94.50 168.81 8886.12 514.44 -8024.88 5947577.28 623196.05 10.00 -2036.21 95.76 MWD 13425.00 94.24 171.30 8884.22 489.89 -8020.58 5947552.81 623200.78 10.00 -2011.29 95.96 MWD ..- """'-"""-"-------'--'----"----"""----"""'-"--""'-"".'-- ---.-...-......-----..-.. ----....------------...---,- ......-- ----,-..--,-. -----".----......-.........---...-..-..-...-..--,---,,---......--..-..----."... ...._, ..,..--,...-..... --"---",,-"--"........-.... ...._n... "-"--"-"-"-" -,' ObP ( BP Amoco <. .fi. BA.K88. HUGHIS Baker Hughes INTEQ Planning Report "-'-'-""""-""--""-"""-"""""'-"'- INTEQ r""--'-""'-- -...--...-......-.-----...- - ---'-'..---....' ---..-..-.-....---"'-.----- -- '--'----------"--"-"'-'-'--'--""-----'---"""-'--"--..--...-.-.---..... -"""---"'-'--'-"'-' .-...-.-- '..-.-..-.---...--...-....-...."'--,...--.. .---..,..,-, I Company: BP Amoco Date: 8/23/2001 Time: 15:17:37 Page: 3 1 , i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: P-07. True North 1 Site: PB P Pad Vertical (TVD) Reference: System: Mean Sea Level ! 1 Well: P-07 Section (VS) Reference: Well (0.00N,0.00E.169.00Azi) ! I Wellpath: Plan#7 P-07A Survey Calculation Method: Minimum Curvature Db: Oracle I l__.......m_____..---..-..--...-.-.----.-----........---.. -----.---- -.--------------. .--..------._._._m- .---..- ...-. -.----............-. ...---....--.........-..-.--.. ..-....-....-...-...... ..-.-......-..-- ""'- .----.- "'-"""..'" --.... -.-.-.-....-----.. ... -.... ......- "---""""""'-- - . - --.--.....; Survey ...-"" .----_... ..---.---...----. --- - - . - --- --....-------...-- ...._-- -..- - --.--.---.-..-.-, - -. --- -'-"-- --'- .....---.---....- ----.--------..... .---...- -"'-" ..-..------ --.------.-......- .---. ..--.-...-..- .----_.. ... -- ---.. --, \ MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool: Lm_.-...- ~.- - .... - -. - - . -... _...~ :..~... ._-.... .-- .- ~_:~ ...- -... - - -. .. -.. ...~........_... .... .. ... - - ... - .~.- -.. -" -.... _m_- - - ~..... .. -- .. -... - ......-.......- ~ .-.... ... - -......... ..- --. - ~- ....... - -..... -. ~:- ~!..~.? ~~- - -_....~.. -..... .-_.. .. ...- ...- - - - ~=~ - m.....""'" -. --.....- - -.. ...J I 13450.00 93.97 173.79 8882.43 465.17 .8017.34 5947528.14 623204.44 10.00 -1986.40 96.15 MWD i 13475.00 93.69 176.28 8880.76 440.32 -8015.19 5947503.34 623207.03 10.00 -1961.60 96.33 MWD i , 13500.00 93.40 178.77 8879.21 415.39 -8014.11 5947478.44 623208.54 10.00 -1936.92 96.50 MWD 13525.00 93.11 181 .26 8877.79 390.43 -8014.12 5947453.48 623208.97 10.00 -1912.42 96.65 MWD 13550.00 92.81 183.74 8876.50 365.49 -8015.21 5947428.53 623208.32 10.00 -1888.15 96.79 MWD 13575.00 92.51 186.23 8875.34 340.61 -8017.38 5947403.62 623206.58 10.00 -1864.14 96.93 MWD 13594.26 92.27 188.14 8874.52 321.52 -8019.81 5947384.49 623204.48 10.00 -1845.86 97.05 4 13600.00 92.22 187.57 8874.30 315.84 -8020.59 5947378.80 623203.80 10.00 -1840.44 265.00 MWD 13625.00 92.00 185.08 8873.37 291.01 -8023.34 5947353.92 623201.48 10.00 -1816.59 264.98 MWD 13650.00 91.77 182.58 8872.55 266.08 -8025.01 5947328.97 623200.25 10.00 -1792.44 264.89 MWD 13675.00 91.55 180.09 8871.83 241.10 -8025.60 5947303.99 623200.10 10.00 -1768.03 264.80 MWD 13700.00 91.32 177.60 8871.20 216.11 -8025.10 5947279.02 623201.04 10.00 -1743.40 264.73 MWD 13725.00 91.08 175.11 8870.68 191.17 -8023.51 5947254.11 623203.06 10.00 -1718.62 264.67 MWD 13750.00 90.85 172.63 8870.26 166.32 -8020.84 5947229.31 623206.16 10.00 -1693.71 264.62 MWD 13775.00 90.61 170.14 8869.94 141.61 -8017.09 5947204.67 623210.33 10.00 -1668.74 264.58 MWD 13800.00 90.37 167.65 8869.73 117.08 -8012.28 5947180.23 623215.58 10.00 -1643.74 264.54 MWD 13825.00 90.13 165.16 8869.62 92.78 -8006.40 5947156.04 623221.88 9.99 -1618.77 264.55 MWD 13839.10 90.00 163.76 8869.59 79.19 -8002.63 5947142.52 623225.88 9.99 -1604.71 264.54 5 13850.00 89.77 164.83 8869.61 68.70 - 7999.68 5947132.08 623229.01 10.00 -1593.85 102.00 MWD 13875.00 89.25 167.27 8869.82 44.44 - 7993.65 5947107.93 623235.46 10.00 -1568.88 102.00 MWD 13900.00 88.74 169.72 8870.26 19.95 -7988.67 5947083.53 623240.87 10.00 -1543.89 101.98 MWD 13925.00 88.22 172.17 8870.93 -4.73 -7984.73 5947058.92 623245.24 10.00 -1518.91 101.93 MWD 13950.00 87.71 174.61 8871.81 -29.55 -7981.86 5947034.16 623248.55 10.00 -1494.01 101.87 MWD 13975.00 87.20 177.06 8872.93 -54.46 -7980.04 5947009.29 623250.79 10.00 -1469.21 101.78 MWD 14000.00 86.70 179.52 8874.26 - 79.41 -7979.30 5946984.36 623251.97 10.00 -1444.57 101.67 MWD 14014.10 86.42 180.90 8875.10 -93.48 - 7979.35 5946970.29 623252.17 9.99 -1430.77 101.37 6 14025.00 86.05 179.87 8875.82 -104.36 -7979.42 5946959.42 623252.28 10.00 -1420.11 250.00 MWD 14050.00 85.20 177.51 8877.72 -129.27 -7978.86 5946934.51 623253.28 10.00 -1395.54 250.07 MWD 14075.00 84.36 175.15 8880.00 -154.12 -7977.26 5946909.70 623255.31 10.00 -1370.85 250.25 MWD 14100.00 83.53 172.78 8882.64 -178.84 -7974.65 5946885.03 623258.35 10.00 -1346.08 250.46 MWD 14125.00 82.71 170.40 8885.63 -203.39 -7971.02 5946860.55 623262.41 10.00 -1321.29 250.71 MWD 14150.00 81.90 168.01 8888.98 -227.72 -7966.38 5946836.30 623267.47 10.00 -1296.52 251.00 MWD 14175.00 81.11 165.62 8892.68 -251.80 -7960.74 5946812.34 623273.53 10.00 -1271.81 251.32 MWD 14200.00 80.33 163.21 8896.71 -275.56 -7954.12 5946788.69 623280.57 10.00 -1247.22 251.67 MWD 14225.00 79.57 160.79 8901.07 -298.97 -7946.51 5946765.42 623288.58 10.00 -1222.79 252.06 MWD 14250.00 78.82 158.36 8905.76 -321.98 -7937.94 5946742.57 623297.55 10.00 -1198.57 252.48 MWD 14275.00 78.10 155.92 8910.76 -344.55 -7928.43 5946720.17 623307.45 10.00 -1174.60 252.94 MWD 14300.00 77.40 153.46 8916.07 -366.63 -7917.98 5946698.27 623318.28 10.00 -1150.93 253.43 MWD 14314.10 77.01 152.07 8919.21 -378.86 -7911.68 5946686.16 623324.79 10.02 -1137.72 253.90 7 14325.00 76.64 151.02 8921.69 -388.19 -7906.62 5946676.92 623330.01 10.00 -1127.60 250.00 MWD 14343.22 76.03 149.25 8926.00 -403.55 -7897.81 5946661.72 623339.09 10.00 -1110.84 250.24 P-07A 14350.00 75.81 148.59 8927.65 -409.18 -7894.41 5946656.15 623342.59 10.00 -1104.67 250.66 MWD 14375.00 75.00 146.15 8933.95 -429.55 -7881.37 5946636.01 623355.98 10.00 -1082.18 250.82 MWD 14400.00 74.21 143.68 8940.59 -449.27 -7867.52 5946616.53 623370.17 10.00 -1060.18 251.43 MWD 14425.00 73.46 141.20 8947.55 -468.30 -7852.88 5946597.76 623385.14 10.00 -1038.70 252.04 MWD 14450.00 72.73 138.70 8954.83 -486.61 -7837.50 5946579.72 623400.83 10.00 -1017.80 252.73 TD .. .-.---.--. ---.--- ---- ._-----~--_..- -..-----..---.----.-.---..------.-. - -'---'--'---'--- ----...---- ----.- .. -.....-...-..---- -"'--'--"'-'-"-- --- .----.. ..' ( 38 CTD BOP Detail (" --CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on OS Hardline to Standpipe manifold ~ - 1" Riser Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Methanol Injection gtis 1" WLA Quick onnect - Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE ~ Manual over Hydraulic ~ 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOP~ ~ Manual over Hydraulic 2" Side outlets @ I 2 7/811 Combi Pipe/Slip I 2 3/811 Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve (optional depending on RU) 2 flanged gate valves ~ 7" Annulus MOJ 5/21/01 9 5/8" Annulus o~ I I ~. f ( ./ \ DATE 07/31/01 ~ H 194718 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 072701 CK072701J PVMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it To Drill ee S/H - Terrie Hub Ie X4628 ?Ò7 A- ~ TOTAL ~ iE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 194719 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00194719 PAY ONE HUNDRED 8< OO/100********************~**************** US DOLLAR DATE. 07/31/01 J I AMOUNT $100.00 I To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOTVALID AFTER 120 DAYS AK 99501 Ç(... .... .... fl/~/¡A,'lJ ... --.rtP' ~" ''It L - ........'N.',...,"'.'... . -- III ¡. g ~ ? ¡. g III I: 0 ~ ¡. 2 0 ~ B g 5 I: 0 0 B ~ ~ ¡. Ii III (' ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER P¿¿f r-- 6 7 /l CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILY EXPLORATION INJECTION WELL INJECTION WELL RED RILL WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) li ANNULAR DI~OSAL ( ¡ ANO -v-- ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS L-) YES + SPACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 2S.00S(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disþosal of drilling wastes will not be approved. . . Please note that an disposal of fluids generated. . . Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION COMP ANY WELL NAME INITCLASS~V 70/c , 1.Permitfeeattached....................... 2. Lease number appropriate.~. . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . - 4. Well located in a defined pool.. . . . . . . . . . - . . - - - . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat induded.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . 11. Permit can be issued without conserJation order. . . . . . . . 12. Permit can,be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . , . . . . 14. Conductor string provided. . . . . . . . .. . . . . . . . . . Y N 15. Surface casing protects all known USDWs. . .. . . . . . . . AlA -¥-N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N 18. CMT will cover all known productive horizons. . . . .'. . . . . Y 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . ~ N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N 21. If a re-drill, has a 10-403 for abandonment been approved. . . N 22. Adequate wellbore separation proposed.. . . . . . ; . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . J.¥ N 24. Drilling ,fluid program schematic & equip list adequate. . ~ . - N 25. BOPEs, do they meet regulation. . . . . . . . . . "0 . . . . N . ("\ , 26. BOPE press rating appropriate; test to ~~psig. N \-t..(b..~V ~~~ ;;9-Y.l.\ ~~\. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdöwn. . . . . . . . . . . ~ ~ ~ ~" . ~,' \\: c.: ð... . , 29, Is presence of HoS gas probable.. , . , , , , , . , , , , , , , Y ~~..:> ":> ~ ~ \"¿ .> ""' ,> ~ ")'. Q~~",,> <;. ~~ >¡.. <:'> ~ ~"> 30. Permit can be issued wlo hydrogen sulfide measures. . . . ,. Y @ 2...D f(J/h.. 1'1'U2A!(;v i.A<-- ~C? 7 t4<.- ~ 2L:::c:b.. ..~;) 31. Data presented on potential overpressure zones. . . . . . . ~ ' 32. Seismic analysis of shallow gas zones. . . . . . . . . . Z'. If Y N APPR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . '.' Y N . . ¿(D 9. ZÇJ~ D ( 34. Contact name/phone for weekly progress reports [explo tory only] Y N ' ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; " (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC! nular COMMISSION: WM8~s , ..,"A\ol JM A~ DATE I '1. Zff.O ENGINEERING u Pðl{ GEOLOGY APPR DATE ~Þ8# tolt:Yc~ c:\msoffice\wordian\diana\checklist (rev. 11/01/100) PROGRAM: exp dev V redrll serv well bore seg _ann. disposal para req- GEOL AREA 't> UNIT# 0/ /6ÇT) ON/OFF SHORE tf?P'1 ~~ 51..lA~ 4~h;""" vJv ADt- 6ZS'ZGG' --;jÞ~~:IN',¿ V1-~Þ'I./4..( ~ N -,. 7::>, ~ /1- P,- 0 Zi:. ~ 7'-. L>P / c 0 Z 0 -t ~ ::0 f ~~~ ~~l ~ ~~ ~ ~ ' ~ ~ c~ ~~ Ct~~~~ .~ ~~~ . \...:)~ - -t m - Z -t J: - en > ::0 m » ( .'\ Y N Y N I -"", (,... C omments/l nstructions: ( ( Well History File APPENDIX ~ Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information. information of this . . nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . - organize this category of information. " .1 ( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 03 13:12:43 2002 Reel Header Service name.............LISTPE Date.....................02/12/03 Origin...................STS Reel Name..........-_....UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date.....................02/12/03 Origin...................STS Tape Name................ UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MADLOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-11170 S. LATZ FEKETI/CUBBO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-1117 0 S.LATZ FEKETI/LAULE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MS.L 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Writing Library. P-07A 500292253501 BP Exploration Sperry Sun 02-DEC-02 MWD RUN 2 AK-MW-1117 0 S. LATZ FEKETI/CUBBO .MWD RUN 6 AK-MW-1117 0 S.LATZ FEKETI/LAULE 31 I1N 13E 2476 1944 88.04 .00 .00 ( Scientific Technical Services Scientific Technical Services (Alaska) Inc MWD RUN 3 AK-MW-1117 0 S. LATZ FEKETI/LAULE MAD RUN 6 AK-MW-1117 0 S. LATZ FEKETI/LAULE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING ORILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.625 ¡2675.0 3.750 4.500 12618.0 # REMARKS: éXOJ-/gtp 1(331 ,. ;' ('" (' 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS) . 3. MWD RUN 1 WAS DIRECTIONAL WITH GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 4. RESISTIVITY DATA FROM 12672' MD TO 13024' MD WERE OBTAINED DURING A WIPE PRIOR TO MWD RUN 2. 5. MWD RUNS 2-6 WERE DIRECTIONAL WITH GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWRP4). ALL GAMMA RAY DATA FROM MWD RUNS 2-6 WERE REAL-TIME DATA. MEMORY DATA WAS UNAVAILABLE DUE TO REPEATED MEMORY FAILURE. 6. DATA IN THE INTERVAL 12762' MD, 8798' TVDSS TO 14353' MD, 8900' TVDSS WERE ACQUIRED ON ,A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE PULLING OUT OF HOLE FOLLOWING MWD RUN 6. MAD PASS DATA WAS CORRECTED TO THE MWD GAMMA RAY DATA. 7. DEPTH SHIFTING 1 CORRECTION OF MWD DATA IS WAIVED PER 11/16/2001 E-MAIL FROM Ð. SCHNORR (BP EXPLORATION) . 8. MWD RUNS 1-6 REPRESENT WELL P-07A WITH API # 50,..029-22535-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14395'MP 1 8903'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) SGRD= SMOOTHED GAMMA RAY COMBINED (SCINTILLATION DETECTORS) SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME CURVES WITH "M" SUFFIX DENOTE MAD PASS DATA $ File Header Service name......... '. . . . STSLIB. 001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: 1 clipped curves; all bit runs merged. .5000 ./ 1" (' (" # FILE SUMMARY PBU TOOL CODE GR FET RPS RPX RPD RPM ROP $ START DE PTH 12485.0 12672.5 12672.5 12672.5 12672.5 12672.5 12688.0 STOP DEPTH 14351.5 14365.5 14365.5 14365.5 14365.5 14365.5 14395.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 3 5 6 MERGE TOP 12485.0 13056.5 13107.0 13611.0 13932.5 MERGE BASE 13056.0 13106.5 13610.5 13932.0 14395.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Dìrection.................Down Optical, log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Or(jer Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12485 14395.5 13440.3 3822 12485 14395.5 ROP MWD FT/H 0 2422.43 82.2415 3416 12688 14395.5 GR MWD API 3.8 917 . 9 54.2174 3476 12485 14351.5 RPX MWD OHMM 0.2 2000 23.1496 3387 12672.5 14365.5 RPS MWD OHMM 0.26 2000 19.605 3387 12672.5 14365.5 RPM MWD OHMM 0.55 2000 17.5428 3387 12672.5 14365.5 RPD MWD OHMM 0.17 2000 17.3646 3387 12672.5 14365.5 FET MWD HR 0.2535 37.9458 6.81113 3387 12672.5 14365.5 First Reading For Entire Fi1e..........12485 Last Reading For Entire File...........14395.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/03 . ' .' (' ( Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPM RPD RPS RPX FET RAT GR $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 12713.5 12713.5 12713.5 12713.5 12734.0 12744.5 12762.5 STOP DEPTH 14373.5 14373.5 14373.5 14373.5 14373.5 14373.0 14353.5 # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. 6 1 MERGE TOP 12713.5 MERGE BASE 14395.5 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Da ta Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type.,..O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12713.5 14373.5 13543.5 3321 12713.5 14373.5 RAT MAD FT/H 100 704.67 536.595 3237 12744.5 14373 GR MAD API 7.01 141. 39 40.228 2782 12762.5 14353.5 RPX MAD OHMM 0.89 1248.5 6.82025 3282 12713.5 14373.5 RPS MAD OHMM 0.75 135.25 7.26221 3282 12713.5 14373.5 RPM MAD OHMM 0.58 115.31 7.96257 3282 12713.5 14373.5 ( RPD MAD FET MAD 0.48 2.17 OHMM HR 88.88 153.01 3282 3257 8.83209 81. 0732 First Reading For Entire File..........12713.5 Last Reading For Entire File...........14373.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation__._...02/12/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPM RPD ROP $ 3 (^ 12713.5 12734 14373.5 14373.5 header data for, each bit run in separate files. 1 .5000 START DEPTH 12485.0 12672.5 12672.5 12672.5 12672.5 12672.5 12688.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 13026.0 13024.5 13024.5 13024.5 13024. 5 13024.5 13056.0 16-0CT-Ol Insite 4.3 Memory 13056.0 12689.0 13056.0 23.0 88.0 TOOL NUMBER TLGO33 3.750 12618.0 Flo Pro 8.60 (" (. MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 65.0 9.2 17500 9.6 .000 .000 .000 .000 .0 165.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOI0 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWDOI0 OHMM 4 1 68 16 5 RPM MWDOI0 OHMM 4 1 68 20 6 RPD MWDOI0 om.1M 4 1 68 24 7 FET MWDOI0 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12485 13056 12770.5 1143 12485 13056 ROP MWDOI0 FT/H 0 158.16 48.9557 737 12688 13056 GR MWDOI0 API 21. 94 917.94 88.7539 825 12485 13026 RPX MWDOlO OHMM 0.2 2000 75.1699 705 12672.5 13024.5 RPS MWDOI0 OHMM 0.26 2000 54.5663 705 12672.5 13024.5 RPM MWDOlO OHMM 0.55 2000 42.9451 705 12672.5 13024.5 RPD MWD010 OHMM 0.17 2000 42.4694 705 12672.5 13024.5 FET MWDOI0 HR 12.3707 33.8845 20.7086 705 12672.5 13024.5 First Reading For Entire File..........12485 Last Reading For Entire File...........13056 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header .. ( Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 ( header data for each bit run in separate files. 2 .5000 START DEPTH 13025.0 13025.0 13025.0 13025.0 13025.0 13026.5 13056.5 STOP DEPTH 13074.0 13074.0 13074.0 13074.0 13074.0 13063.0 13106.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER I S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPE.RATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 16-0CT-0l Insite 4.3 Memory 13106.8 13056.0 13106.8 93.6 93.6 TOOL NUMBER 69706 126583 3.750 12618.0 Flo Pro 8.60 65.0 9.2 17500 10.0 .000 .000 .000 .000 .0 161. 0 .0 .0 co ( Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13025 13106.5 13065.8 164 13025 13106.5 ROP MWD020 FT/H 12.9 135.01 92.5377 101 13056.5 13106.5 GR MWD020 API 20.11 41.72 30.2718 74 13026.5 13063 RPX MWD020 OHMM 1.8 3.23 2.16141 99 13025 13074 RPS MWD020 OHMM 1.9 3.18 2.23515 99 13025 13074 RPM MWD020 OHMM 1. 94 3.21 2.29606 99 13025 13074 RPD MWD020 OHMM 2.01 2.86 2.31606 99 13025 13074 FET MWD020 HR 0.368167 15.5635 10.6779 99 13025 13074 First Reading For Entire File....._....13025 Last Reading For Entire File...........13106.5 HIe Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......02j12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.O04 Comment Record FILE HEADER FILE NUMBER: RAW .MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM 5 header data for each bit run in separate files. 3 .5000 START DEPTH 13063.5 13074.5 13074.5 STOP DEPTH 13559.0 13578.0 13578.0 ( RPS RPX FET ROP $ 13074.5 13074.5 13074.5 13107.0 13578.0 13578.0 13578.0 13610.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZ.E (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) "MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type......O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max ftames per record.............Undefined Absent value...................... - 9 9 9 Depth Units....................... Datum Specification Block sub-type...O (' 17-0CT-01 Insite 4.3 Memory 13611.0 13106.8 13611.0 90.3 102.4 TOOL NUMBER 72829 126583 3.750 12618.0 Flo Pro 8.60 65.0 9.2 23000 9.2 .320 .175 .150 .190 85.0 161. 0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO30 FT/H 4 1 68 4 2 GR MWDO30 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 (' (' First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13063.5 13610.5 13337 1095 13063.5 13610.5 ROP MWD030 FT/H 3.79 1561.82 88.113 1008 13107 13610.5 GR MWD030 API 5.09 168.37 46.7295 992 13063.5 13559 RPX MWD030 OHMM 1. 99 30.47 6.47248 1008 13074.5 13578 RPS MWD030 OHMM 2.12 31. 08 6.6884 1008 13074.5 13578 RPM MWD030 OHMM 2.3 31. 89 6.91296 1008 13074.5 13578 RPD MWD030 OHMM 2.74 22.85 6.89875 1008 13074.5 13578 FET MWD030 HR 0.344333 9.15567 1.6191 1008 13074.5 13578 First Reading For Entire Fi1e._-_______13063_5 Last Reading For Entire File...........13610.5 File Trailer Service name...--........STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number....:.... ..1. O. 0 Date of Generation.......02/12/03 Maximum Physical Record..65535 File Type................ LO Previous File Nàme.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 13559.5 13578.5 13578.5 13578.5 13578.5 13578.5 13611. 0 STOP DEPTH 13888.0 13899.0 13899.0 13899.0 13899.0 13899.0 13932.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 19-0CT-0l Insite 4.3 Memory 13924.0 13611.0 13924.0 92.5 98.2 # TOOL STRING (TOP TO BOTTOM) (! VENDOR TOOL CODE GM EWR4 $ TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQYENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O (' TOOL NUMBER 72829 126583 3.750 12618.0 FLOPRo 8.60 62.0 9.0 16000 10.8 .190 .081 .140 .210 70.0 174.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO50 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13559.5 13932 13745.8 746 13559.5 13932 ROP MWD050 FT/H 0.31 610 104.036 643 13611 13932 GR MWD050 API 24.09 173.15 45.0868 658 13559.5 13888 RPX MWD050 OHMM 2.39 47.89 14.469 642 13578.5 13899 RPS MWD050 OHMM 2.64 136.7 16.3633 642 13578.5 13899 RPM MWD050 OHMM 3.03 142.11 17.0197 642 13578.5 13899 RPD MWD050 OHMM 5.1 58.07 17.727 642 13578.5 13899 FET MWD050 HR 0.318667 37.9458 5.165 642 13578.5 13899 First Reading For Entire Fi1e..........13559.5 Last Reading For Entire File...........13932 File Trailer Service name.............STSLIB.006 ( Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO7 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 7 (' header data for each bit run in separate files. 6 .5000 START DEPTH 13888.5 13899.5 13899.5 13899.5 13899.5 13899.5 13932.5 STOP DEPTH 14351.5 14365.5 14365.5 14365.5 14365.5 14365.5 14395.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 21-0CT-01 Insite 4.3 Memory 14395.0 13924.0 14395.0 77.6 91. 9 TOOL NUMBER 69706 126583 3.750 12618.0 FloPro 8.70 60.0 8.9 14400 10.0 .190 .077 .140 .210 70.0 182.0 70.0 70.0 (" (' # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWDO60 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13888.5 14395.5 14142 1015 13888.5 14395.5 ROP MWD060 FT/H 20.71 2422.43 86.0812 927 13932.5 14395.5 GR MWD060 API 3.82 137.78 39.881 927 13888.5 14351. 5 RPX MWD060 OHMM 2.5 28.5 10.0598 933 13899.5 14365.5 RPS MWD060 OHMM 4.31 41. 4 11. 2161 933 13899.5 14365.5 RPM MWD060 OHMM 4.33 302. 96 11.8103 933 13899.5 14365.5 RPD MWD060 OHMM 4.64 93.49 11. 0491 933 13899.5 14365.5 FET MWD060 HR 0.2535 28.13 2.64162 933 13899.5 14365.5 First Reading For Entire File..........13888.5 Last Reading For Entire File...........14395.5 File Trailer Service name.............STSLIB.OO7 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......O2/12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.008 Physical EOF File Header Service name.............STSLIB.O08 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OO7 Comment Record , ... ( FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET RAT GR $ 8 (' header data for each pass of each run in separate files. .5000 6 1 START DEPTH 12713.5 12713.5 12713.5 12713.5 12734.0 12744.5 12762.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROT.ATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ STOP DEPTH 14373.5 14373.5 14373.5 14373.5 14373.5 14373.0 14353.5 BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASÍNG DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined 21-0CT-01 Insite 4.3 Memory 14373.0 12744.0 14373.0 77.6 91. 9 TOOL NUMBER 126583 126583 3.750 12618.0 FloPro 8.70 60.0 8.9 14400 10.0 .190 .077 .140 .210 70.0 182.0 70.0 70.0 , ,. (' ( Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code O:f:fset Channel DEPT FT 4 1 68 0 1 RAT MAD061 FT/H 4 1 68 4 2 GR MAD061 API 4 1 68 8 3 RPX MADO61 OHMM 4 1 68 12 4 RPS MAD061 OHMM 4 1 68 16 5 RPM MAD061 OHMM 4 1 68 20 6 RPD MAD 0 61 OHMM 4 1 68 24 7 FET MAD061 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12713.5 14373.5 13543.5 3321 12713.5 14373.5 RAT MAD061 FT/H 100 704.67 536.595 3237 12744.5 14373 GR MAD061 API 7.01 141. 39 40.228 2782 12762.5 14353.5 RPX MAD061 OHMM 0.89 1248.5 6.82025 3282 12713.5 14373.5 RPS MAD061 OHMM 0.75 135.25 7.26221 3282 12713.5 14373.5 RPM MAD061 OHMM 0.58 115.31 7.96257 3282 12713.5 14373.5 RPD MAD061 OHMM 0.48 88.88 8.83209 3282 12713.5 14373.5 FET MAD061 HR 2.17 153.01 81. 0732 3257 12734 14373.5 First Reading For Entire File..........12713.5 Last Reading For Entire File...........14373.5 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/03 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name.............LISTPE Date.....................02/12/03 Origin...................STS Tape Name................UNKNOWN Continuation Number......O1 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................02/12/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File