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206-073
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG R E C V E D MAY 7 1, ^n50 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 • Suspended ❑ Well Class: 20AAC 25.105 20AAC 25.110 ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 11b. Development �. Exploratory ElGINJ Service ❑ Stratigraphic Test ❑ 2. Operator Name. 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry SP Exploration (Alaska), Inc 4/28/2019 206-073 � 318434 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 7/72006 50.029-22480-02-00 4a. Location of Well (Governmental Section): 8, Date TO Reached: 16. Well Name and Number. 8/4/2006 PBU 15-361 Surface: 1440' FNL, 887; FWL, Sec. 22, T11N, R14E, UM 9 Ref Elevations KB 64.60 • 17. Field/Pool(s): v Top of Productive Interval: 4646FSL, 401h FWL, Sec. 15, T17 N. R14E, UM GL 31.00 * BF 32.45 • PRUDHOE BAY, PRUDHOE OIL 10. Plug Back Depth(MD/TVD): 18. Property Designation: Total Depth: 4592' FSL, 282' FWL, Sec. 14, T11N, R14E, UM 10998"/ 8282' ADL 028306 8 028307 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 676825 y- 5950062 Zone - ASP 4 13285'18777' 78-084 TPI: x- 679867 y- 5966222 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/WD: Total Depth: x- 681344 y- 5966203 Zone - ASP 4 None 1900' (Approx.) r 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drimLateni Top Wndov Submit electronic and printed information per 20 AAC 25.050 N/A (fl MSL) MDrrVD: 10097'17507' r 22. Logs Obtained List all logs run and, pursuant to AS 31 .05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD /GR/EWR, MWD /GR/EWR, MWD/GR/EWR, MGR / CCL /CNL, MGR / CCL /CNL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER I GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEFT CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 34' 114' 34' 114' 30" 260 sx Arctic Set (APpri 10-3/4" 45.5# L-80 34' 3906' 34' 3562' 13-1/2" 1105 sx PF'E', 375 sx Class'G' 7-5/8" 29.7# W-95 31' 10097' 31' 7507' 9-7/8" 617 sx Class *G' 4-1/2" 12.6# 130010 0 9951' 10988' 7405' 8273' 6-3/4" 200 sx Class'G' -1/n3-3/16"8.81#/6.2# 1450 10697' 13285' 8008' 11 8777' 4-1/4" 158 sx Class'G' x2-7/8" /6.16# 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perftl): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.6# 13Cr80 9957' 9921'17384' oo Aiom oii ^^ ` 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE y)ZOII Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed VERIFIED information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED _ 10998' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lie, etc.): WA Dale of Test: Hours Tasted:: Production for Oil -Bbl Gas -MCF: Water -Bbl: Choke Abe. Gas -Oil Ratio Test Penod -y Flow Tubing Press Casing Press: I Calalated 24 Hour Rale __► OIkBbl: Gas -MCF: Water -Bbl: Oil Gravity- API(cum: Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only � 7 kr� -Sori RMS -1i MAY 2 3 2019 0- psl�%!4 28. CORE DATA Conventional Corals) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top • Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed lest information per 20 Top of Productive Interval 11739' 8776' AAC 25.071. Sag River 10971' 8257' Shublik A 11014' 8297' Shublik B 11044' 8324' Shublik C 11060' 8339' Shublik D 11087' 8363' Sadlerochit-Zone 4 11093' 8368' CGL 11230' 8494' Base of CGL 11302' 8557' 22SB - Zone 2B 11361' 8605' 22TS 11416' 8646' 21 TS - Zone 2A 11515' 8709' Zone 113 11603' 8748' TDF - Zone 1A 11739' 8776' Formation at total depth: .- Zone 1A 11739' B776' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Browning, Zachary H Authorized Title: SIM list Contact Email: Zachary.Srowning@bp.com Authorized Signature: e:5/�'� Contact Phone: +1 907 564 5220 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Raring. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true verfical thickness of permafrost in Box 20. Provide MO and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in Rem 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10407 Revised 5/2017 Submit ORIGINAL Only **`WELL S/I ON ARRIVAL***(ctd) DRIFT W/ 20'x 2.70 DUMMY WHIPSTOCK TO 2-7/8" XO @ 11,367' MD RAN 3.50" GAUGE RING & 4-1/2" BRUSH TO 2000' SLM 2/21/2019 ***JOB IN PROGRESS, CONTINUED ON 02/22/2019*** ***CONTINUED FROM 02-21-2019 WSR***(ctd) SET 4-1/2" X -CATCHER IN X -NIPPLE @ 9,900' MD PULLED BK-DGLV ST#2 (6,828' MD) & BK-LGLV ST#3 (3,447' MD) SET BK-DGLV IN ST#3 (3,447' MD) LRS LOADED IA W/ 215 bbls CRUDE. SET BK-DGLV IN ST#2 (6,828' MD) 2/22/2019 ***WSR CONTINUED ON 2/23/19*** T/1/0=2100/1954/354 Temp=Sl LRS unit 46 Assist SL with load & test (CTD) Pumped 5 bbls 60/40 MW followed by 215 bbls of 180* crude down IA to load. 2/22/2019 `*` WSR continued on 02/23/19**` *** WSR continued from 02/22/19*** MIT -IA PASSED to 2645 psi. Max Applied Pressure= 2750 psi Target Pressure= 2500 psi. Pressured IA to 2741 psi with 3.1 bbls of crude. MIT -IA lost 75 psi in 1st 15 min and 21 psi in 2nd 15 min for a total loss of 96 psi during 30 min test. Bled IA to 500 psi recovering - 3.3 bbls. Freeze protected FL w/6 bbls 60/40 MW. SSL in control of well upon LRS departure. IA/OA= OTG Tags hung AFE sign hung on MV. FWHP's 2/23/2019 2200/500/0. ***WSR CONTINUED FROM 2/22/19*** (CTD) LRS OBTAINED PASSING 2,500 psi MIT -IA. PULLED EMPTY CATCHER FROM 9,900' MD.. 2/23/2019 ***JOB COMPLETED, WELL LEFT S/I`*` ***WELL S/I ON ARRIVAL*** (SLB ELINE WHIPSTOCK SETTING) INITIAL T/I/O = 2100/475/150. MIRU SLB & LRS. LRS PUMP DOWN TUBING W/ 290 BBL 1% KCL & 38 BBL FP W/ DIESEL AT 5 BPM ryBAK&P PAQKEW2_WHlRRTOCKAT 10 998' TOWS, 23.5 DEGREES LOHS. ALL LOGS CORRELATED TO SCHLUMBERGER MCNL DATED 05 -AUG -2006.. RDMO. TURN WELL OVER TO LRS FOR MIT -T. FINAL T/1/0 = 150/475/0. 3/2/2019 ***JOB COMPLETE ON 02 -MAR -2019*** T/1/0= 2058/449/136. (LRS Unit 72 - Assist E -line: Load & Test) (Whipstock packer set). Load Tubing w/ 2 bbls Net Meat Meth followed by 280 bbls 1 % KCL, Freeze Protect Tubing w/ 5 bbls Neat followed by 38 bbls Diesel. MIT -T to 2717 psi PASS Target pressure = 2500 psi Max Applied pressure = 2750 psi Pumped 6.2 bbls DSL down Tbg for MIT -T. Started test w/ 2760 psi on Tbg. Tbg lost 27 psi in 1st 15 mins and 16 psi in 2nd 15 mins for a total loss of 43 psi in 30 minute test. Ble Tbg to 150 psi and got back -5 bbls. SV,WV,SSV=SI MV=O IA,OA=OTG 3/2/2019 FWHP's=150/0/0 3/3/2019 LRS Unit 72 - Assist Eline: Load & Test) Finish RD/ Job Complete T/I/O = 100/100/0. Pre CDR2 Tree Work. RU CIW lubricator #68-840 and PT to 350/3500psi (PASS) Run down and set CIW 'H' TWC #294 at 125". Remove 4" CIW upper tree and install CDR Tree #4. Torque to API specs. Install Kill Line #1 and torque to API specs. RU CIW lubricator #68-840 and PTagainst TWC to 350/3500psi (PASS) PT against MV top side x SV bottom side to 350/3500psi (PASS). Run down and pull 4" CIW 'H' TWC #294 at 125". RD lubricator and remove tree cap assembly. Instal tapped blind flange and PT (PASS). 4/2/2019 IRDMO *"Job Complete*** SEE LOG FOR DETAILS Final T/I/O = 100/100/0. Daily Report of Well Operations 15-36B TWO = 110/160/160. Temp = SI. Bleed WHPs (Pre -Rig). No wellhouse, flowline, Al or scaffold. Kill line installed. TBG FL and IA FL @ Near Surface. OA FL @ Surface. Bled OAP to BT from 160 psi to 0 psi in 20 min (fluid, 8 gal). Bled IAP from 160 psi to 0 psi in 35 min (gas). Bled TP from 110 psi to 0 psi in 30 min (gas/fluid mix 45 gals). Monitored for 30 min. IAP increased 5 psi and OAP increased 7 psi. Final WHPs = 0/5/7. 4/22/2019 SV, WV, MV = C. IA, OA = OTG. 12:30 TWO = 10/40/160. Temp = SI. Bleed IAP/OAP to 0 psi (Pre -Rig). IA FL @ near surface, OA FL @ surface. Bled OAP to BT to 0+ psi in 10 min, maintained open bleed for an additional 3.25 hrs (19 gal). Bled IAP to 0 psi in -10 min (gas). Monitored for 30 min. OAP increased 15 psi, IAP increased 5 psi. Final WHPs = 10/5/15. 4/24/2019 SV, WV(x2), MV = C. IA, OA = OTG. 04:40. TWO = 10/30/150. Temp = SI. WHPs (Pre Rig). IAP increased 25 psi, OAP increased 135 psi overnight. 4/24/2019 SV, WV x2 , MV = C. IA, OA = OTG. 00:30. TWO = 08/60/160. Temp + SI. Bleed WHPs. No wellhouse, flowline, or scaffolding. Kill line installed. Bled IAP to BT from 60 psi to 0 psi in 3 minutes. All gas. Monitor for 30 minutes. IAP increased 8 psi during monitor. Final WHPs = 08/08/160. 4/26/2019 ISV, WV (x2), MV = C. IA, OA = OTG. 21:30 Printed 5/9/2019 8:57:16AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 1 able Operation Summary Report Common Well Name: 15-36 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Dale'. 4/27/2019 End Date5/3/2019 X3-0199D-C: (1,976,175.00) Project: PBU Site: 15 Rig Name/No.: CDR-2 Spud Dale/Time: 9/14/2001 12:00:00AM Rig Release: 5/5/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USAD0000959 Active datum: RT @64.60usft (above Mean Sea Level) Date From -To Him Task Code NPT I Total Depth Phase Description or Operations (hr) _ I (usft) 4/27/2019 01:30 - 03:00 1.50 MOB P PRE MOVE RIG FROM S-105ATO 15-36C - PJSM FOR MOVING RIG WITH PEAKAND NABORS CREWS. -MOVE RIG OFF WELLS-105A _ -INSTALL JEEPS TO PREP FOR MOVE 03:00 - 13:00 10.00 MOB P PRE MOVE RIG TO 15-36C -10:00 RIG ON DS 15 REMOVE JEEPS - PJSM FOR MOVING RIG OVER WELL WITH PEAK AND NABORS CREWS. - SPOT STOP BLOCK - VERIFY TREE & CSG VALVESARE CLOSED - SPOT SUB OVER WELL AND SET DOWN - SPOT PIT MODULEAND SET DOWN - RIG ACCEPTED AT 13:00 13:00 - 19:30 6.50 RIGU P PRE MIRU OPS -CYCLE TREE VALVES ,- START MIRU CHECK LIST - LTT MASTER & SWAB VALVES - RU MPL —... - NU BOPE 19:30 - 23:30 4.00 RIGU Imo. P PRE - FLUID PACK SURFACE EQUIPMENT - SHELL TEST 23:30 - Woo 0.50 RIGU P PRE " NOTIFYLOU LAUBEMSTEIN@23:30HRS" "HOLD PRESPUD MEETING WITH BOTH CREWS" _ 4/28/2019 00:00 - 00:30 0.50 RIGU P PRE PERFORM TABLE TOP EVAC DRILL -CREW HANDOVER " LOU LAUBENSTIEN ON LOCATION Cat 00:15 Printed 5/9/2019 8:57:16AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 2.-A" Operation Summary Report Common Well Name: 15-36 AFE No Event Type'. RE -ENTER -ONSHORE (RON) Stan Date. 4/27/2019 End Date: 5/3/2019 X3 -01990-C'. (1,976,17500) Project: PBU Site: 15 Rig Name/No.: CDR -2 Spud Date/rime: 9/14/2001 12:OO:OOAM Rio Release. 5/5/2019 Rig Contractor: NABORSALASKA DRILLING INC. Active datum: RT Q64.60usft (above Mean Sea Level) BPUOI: USA00000959 Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hl) _ lust) _ 00:30 - 08:30 8.00 BOPSUR P PRE TEST BOPS " WITENSSED BY LOU LAUBENSTIEN" ALL TESTS TO 25013500 PSI. TEST 1: IRV, STRIPPER, C9, C10 BACKWARDS - PASS TEST 2: BLIND / SHEARS, R1,BOA, BI, B4 - PASS INSTALL TEST JOINT WITH SAVER SUB REMOVED. TEST 3: ANNULAR (2"), TIW#2, B3, B2, BL1 - FAIL - FUNCTION ANNULAR 3 TIMES & INCREASE PRESSURE TO RETEST 3: ANNULAR (2"), TIW#2, B3, B2, BL1 - FAIL RETEST 3: UPPER PIPE / SLIPS, TIW#2, B3, B2, BLt - PASS TEST 4: UPPER 2" PIPE / SLIPS, TIW #2, BL2, R2, T2, C75-FAIL(T2) RETEST 4: UPPER 2" PIPE / SLIPS, TIW #2, BL2, R2, Ti, C15 - PASS TEST 5: C16, Ti, Cll - PASS TEST 6: LOWER 2" PIPE / SLIPS, C7, C9, CIO, •TV2-PASS TEST 7: C5, C6, C8, TVI - PASS TEST B: CHOKE A, CHOKE C - PASS CONDUCT DRAWDOWN TEST AND RECORD PRESSURES AND TIME - WITNESSED BY STATE REP, TOOLPUSHER AND WSL REPLACE ANNULAR AND SERVICE T2 VALVE RETEST: ANNULAR AND T2 -PASS TAKE OUT TEST JOINT AND INSTALL SUB TO MOVE 2-3/8" ACROSS ANNULAR AND VBR TEST 9: ANNULAR (2-3/8"), Cl, C4 - PASS TEST 10: VARIABLES (2-3/8"), C2, C3 - PASS 08'.30 - 13:00 4.50 BOPSUR P PRE BOP TEST COMPLETED - RD TEST JOINT - SWAP OUT LUBRICATOR AND GREASE CHOKE MANIFOLD - INSTALL BHI CVS AND TEST -GOODTEST -STAB INJECTOR ON AND FLUID PACK TO PT THE LUBRICATOR - GOOD TEST, FLUID PACK TREE WITH METHANOL - CLOSE CHOKE, OPEN UP TO THE WELL TO CHECK FOR PRESSURE - NO PRESSURE, FILL WELL, WELLS FULL, FLOW CHECK -GOOD NO FLOW Printed 5/9/2019 8:57:16AM **All depths reported in Drillers Depths" Printed 5/9/2019 8:57:16AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 ofd Operation Summary Report Common Well Name: 15-36 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 4/27/2019 End Date 5/3/2019 X3 -0199D -C (1,976,175.00 ) Project PBU Site: 15 Rig Name/No.: CDR -2 Spud Daterrime: 9/14/2001 12:00:00AM Rig Release: 5/52019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000959 Active datum: RT @64.60usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Desorption of Operations _ (hr) (usft) _ _ _ 13:00 - 18:30 5.50 STWHIP P 10,998.00 WEXIT MU WINDOW MILLING BHA - HOLDA PJSM TO MU THE MILLING BHA - PU THE INJECTOR, FLUID LEVEL IN THE STACK, MU THE MILLING BHA - RIH HOLDING 100 PSI TAKING ALL RETURNS THROUGH THE CHOKE OUT TO THE TT - GETTING A LITTLE GAS CUT FLUID BACKAT 4100', NOTIFY WSUPT NEWLON, AGREE TO KEEP RIH TO BOTTOM TO CIRC A BOTTOMS UP TO CLEAN UP WELLBORE. - BLEED OA DOWN TO 300 PSI FROM 625 PSI -10850'WT CK=46K RIH Wr=22K - TAG PINCH POINT PU AND CIRC A BOTTOMS UP WHILE TYING IN -TAG AT 11007 UNCORRECTED, CIRCULATEA BOTTOMS UP TAKING ALL RETURNS TO THE TT THROUGH THE CHOKE '- 80 BBLS AWAY GETTING A LITTLE GAS CUT FLUID, STILL GOING TO TT - LOG DOWN FROM TIE IN @ 10850' WITH -7.5 'CORRECTION 1830 - 0000 5.50 STWHIP P 11,000.10 WEXIT MILLING WINDOW FROM 10998.3 TO 11000.1 JJ 1 -CLOSE EDC 15 -3 ,+ I - LIGHTLY DRYTAG PINCH PONT@ 10999.0' JJ '�li '.- PU, BRING PUMPS ON @ 1.61 GPM - EASE DOWN AND TAG @ 10998.3' FREE SPIN - 1630 PSI ON BOTTOM 2170 PSI GPM 1.611N/ 1.61 OUT PU 46 SO 23 WOB_1.8-2.4 _ 4/292019 0000 - 1030 10.50 STWHIP P 11,000.10 WEXIT MILLING WINDOWAND RATHOLE WINDOW 10998.3 TO 11002.4 -FREE SPIN - 1630 PSI -ON BOTTOM 2170 PSI -GPM 1.74 IN / 1.74 OUT -PU 46 SO 23 -WOB 1.6-2.4 -PUMP 5/5SWEEP EVERY FOOT -MILL RATHOLE TO 11013' -DISPLACE WELL TO DRILLING FLUID -START REAM PASSES - REAM PASSES ARE CLEAN, DRY DRIFT, DRY DRIFT IS CLEAN - PU HOLE 100', PAINTA FLAG AND OPEN THE EDC - FLOW CH WCK WELL THEN POOH - GOOD NO FLOW, POOH - FLOW CHECK AT SURFACE -GOOD NO FLOW, PU TRHE INJECTOR AND LD THE BHA - INJECTOR OFF AT 10:00 - MILLS GAUGED 2.74 GO 2.73 NO GO 1030 - 14:30 4.00 DRILL P 11,013.00 PROD? LATERAL SECTION - MU LATERAL BHA, INJECTOR ON AT 11:15 - PT OTS AND RIH Printed 5/9/2019 8:57:16AM **All depths reported in Drillers Depths" TREE= 4-1116' CNV WELLHEAD= FMC ACRATOR= BAKERC OM —E -EV = 65.76 Fill BEI/ = 64.6' BE ELEV = 32-45' KOP= 1721' Max Angle = 96' Q 11793' Datum MD= NA Datum T 8800' SS 10-3/4' CSG, 45.5#, L-80, D = 9.950" 3907' Minimum ID = 2.37" @ 11367' TOP OF 2-7/8" LNR 4-1/2' TBG, 12.6#, 13CR-80 VAM TOP, -0152 bpf, D = 3.958- 15-36B 1 9957' 1 1 10700' 1 5-12" LNR H 10965' 7-5/8' CSG, 29.7#, NT-95HS NSOC, D = 6.875" S-LM(O.Jif, L -BU, U=L.J//- 1� 73U1U 5-12' LNR MLLOUT WINDOW (15-36A) 11428' - 11435' (OFF WHIPSTOCK) PERFORATION SUMdARY REF LOG: MCNJOCL/GR ON 06/07/06 TEN LOG: GBOLOGY FOC LOG ANGLEATTOPPE2F: 91' @ 12025' Note: refer to Production DB for historical pert data SIZE SPF NEERVAL Opn/Sw SHOT SOZ 2' 6 12025-120W O 07/26/10 BP Exploration (Alaska) 2" 6 12110-12135 O 07/26/10 2" 6 12135-12160 O 0726110 2' 6 12440-13150 O 08108/06 1 2213' 1 SAFETY NOTES: WELL ANGLE> 70' @ 11605" ORIG WELLBORE NOT SHOWN —4-1/2- CHROME TBG& LNR- 14-1/2- HES X NP, D = 3.813" 1 GAS LFT MANDRELS ST'S MD ITVD I DE/I TYPE I VLV ILATCH I PORTI DATE 3 3447 3245 42 KBCr2 DMY BK 0 0222119 2 6828 5414 51 KBG-2 DMY BK 0 0222119 1 9831 7323 47 KBG-2 OMY SK 0 0928/11 9900' 4-12" HES X NP, D = 3.813' 9921' 7-5/8" X 4-12" BKR S-3 WP, D = 3.870" 9944' 4-12' HES X NP, K)=3-813' 9951' 7-5/8' X 5-12' G2 ZXP LTP w /FLDDLOCK LNR HGR, ID 995T 4-112" VALEG, 0=4-00' 9979'---]-]5-1/2' X 4-12' XO, D = 3.970" 7-5/8' MLLOUT WINMW (15-36B) 10097' - 10110- 4-1/2- LNR, 12.6#,1094 13CR-80 VAM TOP, ID = 3.958" 4-12" LNR, 12.6#, L-80 i6 .0152 bpf, D = 3.958" 1069T H3.70- DEPLOY SLV, D = 3.000' 10715' 3-1/2'HESXNP,D=2.813" 10745' 3 V7 X 33/16' XO, D= 2.867' —10998' 1 3-3116" BKR PKR WS w IRA TAGS (3/2/19) 1136T 3-3/16' x 2-718" ,y. XO, D=2.441" 13-3116' LN; 6.2#, L-80 TCI, .0076 bpf, D = 2.80' I LNR, 6.16#, L-80 STL, .0058 bpf, D = 2.441" 1-i 13285' PRUDHOE BAY LW WELL 15-36B PEFMT No: 2060730 API No: 50-029-22480-02 SEL 22 ,T11 N, RUE, 1440' SNL & 88T EWL DATE REV BY COMV6JTS DATE REV BY COMMENTS 06/08/94 OOYON9 ORIGINgLCOMPLETION 10/01114 JIM SCHBMTIC CLEANP PER TALLIES 1221/01 CHMK CTO SIDETRACK 09/01/15 TBDYJMD GLV CJO (0826115) 07/16/06 N2Es RVVO & PARTIAL SIDETRACK 0927118 JNJJM) AIX7ED REF & BF ELEV 08104/06 NORQCI CTD SIDETRACK 0225119 MJM) GLV GO (0222119) 0728/10 D3BWPJC FSS (07126/10) 03/07/19 Mi/JWD SET 33116' WHIPSTOCK (03102/19) BP Exploration (Alaska) 10/12/11 WIM RJC GLV CIO (09r2811 1) 1 THE STATE of1-1 — — — GOVERNOR BILL WALKER John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-36B Permit to Drill Number: 206-073 Sundry Number: 318-434 Dear Mr. Egbejimba: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.aiaskc.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this day of October, 2018. Sincerely, I (� Cathy P. Foerster Commissioner RBD��pGt % 31919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 E B V.. k-. L. 9 V F. �-' ,, 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll [Z- Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to DO Number: 206-073 ' 3. Address: P.O. Box 196612 Anchorage, AK 6. AN Number50-029-22480-02-00 : 9951 9-66 7 2 Stratigraphic ❑ Service ❑ 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? WII planned perforations require a spacing exception? Yes O No 0 PBU 15-36B - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028306'& 028307 PRUDHOE BAY, PRUDHOE OIL 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (h): Total Depth TVD(b: Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13285 8777 73249 8778 2332 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 34-114 35-115 1490 470 Surface 3872 10-3/4" 34-3906 34-3562 5210 2480 Intermediate 10088 7-5/8" 31-10097 31- 7507 8180 5120 Liner 1037 4-1/2" 9951-10988 7405 - 8273 8430 7500 Liner 2588 3 -1/2"x3 -3/16"x2-718" 10697-13285 8008-8777 Perforation Depth MD (ft): Perforation Depth TVD (ft) : Tubing Size, Tubing Grace: Tubing MD (0): 1 12025- 13150 1 - 8777 4-1/2" 12.6# 13CB0 29-9957 Packers and SSSV Type: 4-1/2" Baker S-3 Penn Packer Packers and SSSV MD (h) and TVD (ft): 9921, 7383.60 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: November 1, 2018 15. Well Status after proposed work: Oil ❑ WNJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date. GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning, Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browning(S2bp.com Authorized Name: Egbejimba, John Contact Phone: +1 907 564 5220 Authorized Title: Engine ng Team Leader - CTD 5 RWO Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so thata representative may witness Sundry Number: /✓` L✓.1,•� UN Plug Integrity BOP Test frY Mechanical Integrity Test ❑ Location Clearance ❑ 1 y�❑ Other: pBYL.-T-e�-G-v \O 3'© 4r Q'ZOI}GL-1L j{L.Z'SIkW" E PLUG RAPRo�1 M Post Initial Injection MIT Req'd? Yes ❑ No ❑J/ Spacing Exception Required? Yes ❑ No Id Subsequent Form Required: e � APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: \�( O R I G I N A L RgpM CCS Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. � 31�16t„�R�•Ia ,il' 9zs is S`ubm0 Form and Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission-�N100 From: Zach Browning r V, CTD Engineer Date: September 26, 2018 Re: 15-36B Sundry Approval Request Sundry approval is requested to plug off the 15-36B production as part of the pre -rig work, drilling and completing the proposed 15-36C coiled tubing sidetrack. History of 15-36B: 15-36B was drilled and completed in 2006 as a CTD sidetrack. The well came on strong, but over time became less economic with higher GOR. The parent was recently evaluated and determined to have no remaining value and no 0 remaining wellwork opportunities. The best use of the wellbore is for a Coil sidetrack. . O � T ��, r ;iy Proposed plan for 15-36C: 1 cot,«' Gog for r0 vl(j h4S cNInbeo( tv 0v6/ 8 ��fjj 4pr The sidetrack 15-36C will be the first drilled dedicated Sag rich gas well. It is being drilled in an area north of thea,/bw4e,y mid -field graben where the condensate within the Sag constitutes a significant prize. The sidetrack will be drilled on or ref4G'�/ 's around May 1't, 2019. During pre -rig work it is proposed to drift and set a 3-3/16" packer WS in the production liner. The rig will move in, test BOPE and kill the well. A 2.74" window+ 10' of rathole will be milled. The well will kickoff in the Sag, p. 0 dip into the Shublik and possibly Zone 4 while turning up to land back in the Sag. The proposed sidetrack will be completed �� 100.,with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated (post rig). This Sundry covers plugging the TM 1 / existing 15-36B production via the packer WS set pre -rig the liner cement iob or liner top packer, if the liner lap pressure f (0 /4 test fails (alternate plug placement per 20 AAC 25.1120)). � The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin November 1", 2018) 1. SL Dummy GLMs. Drift for Whipstock. 2. E Set Whipstock. 3. V Pre -CTD Tree work. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2332 psi). 2. Mill 2.74" Window +l0' of rathole 3. Drill Production build section: 3.25" OH, `232' (35 deg US planned). 4. Drill Production lateral section: 3.25" OH, 1659' (12 deg DLS planned). S. Run 2-3/8" liner to TD (planned at 12,891' MD, 8126' TVD). 6. Pump primary cement job: 16.5 bbls, 15.3 ppg Class G, TOC at TOL (10,650 M 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. ' Approved alternate plug placement per 20 AAC 25.112(1) SurjtR-K 31-e—'ytg y Nem AT1, Post -Rig Work: 1. V: pull TWC if set 2. FB: Perform liner lap test 3. SL: Set LGLVs/Set LTP if liner lap fails 4. FB: PT LTP if set 5. C: Perforate (50-100'), PBGL kick off required. Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 TREE= 4-1116"CNV WELLFEAD= FMC ACT7IATOR- OKB. ELEV =-- --__HRC BAK - 65.75' RR3= R -ey =__— 64.6' BF. BEV = 32.45' KOP= Max Angle = _.-1721' 9T@11793' Datum MD= WA _-_---- Datum ND= 8BW SS 10-3/4" CSG, 45.5#, L-80, D = 9.950' 1-1 390T Minimum ID = 2.37" @ 113671 TOP OF 2-7/8" LNR 4-1/2' TBG, 12.6#, 13CR-80 I 9957 VAM TOP, .0152 bpf, D = 3.956' WHIPSTOCK (07/08/06) H 1 YID x"Awsymil1_:3 D=6.875" 2-7/8' LNR 6.5#, L-80, D= 2.377' 1301W 5-1/2- LNR MLLOUT WINDOW (15-36A) 11428'-11435- (OFF WHIPSTOCK) /S� /Nf R SAFETY NOTES: WELL ANGLE> 70'@ 116W' ORIG L 15-3 V V �BORENOT SHOWN ""4-112"CHROME TBG& PERFORATION SL&fMRY REF LOG: MCNJCCL(GR ON 08/07/06 TIE-IN LOG: GEOLOGY PDC LOG ANGLEATTOP91" @ 12025' Note: Refer to Production LIB for historical pert data SIZE SPF NIERVAL Opn/Sgz SHOT SOZ 2" 6 12025 - 12050 O 07/26110 20 2' 6 12110-12135 O 07/26/10 0 2" 6 12135-12160 O 07/26/10 2" 6 12440-13150 O 08/08/06 CNcF94ai��.\21.i. �4`9 ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3447 3245 42 KBC-2 DOME BK 16 08/26/15 2 6828 5414 51 KBG2 SO BK 20 08126/15 1 9831 7323 47 KBG2 DMY BK 0 09128/11 HES X NP, D = 3.813" FES X NP, D = 3.813" 17-5/8' X 5-1/2" G2 ZXP LTP w /FLEXLOCK LNR HGP V=4-90" 1 99�—i 5-1/2" X 4-1/2" XO, D = 3.970' 7-5/8" MLLOUT WNDOW (15-36B) 10097--10110' DEPLOY SLV, D=3.000' 3-1/2" HES X NP, D=2.813' 11 1 10745' 1 VJ 4-11P LNR, 12.6#, —L 10943' �\ 13CR-80 VAM TOP, D = 3.958" 4-111 LNR, 12.6#, L-80 BT -M, 10988' .0152 bpf, D = 3.958' LNR 8.81#, L-80 STL, .0087 bpf, D = 2.992' { 3-3/16" LNR 6.2#, L-80 Tq, .0076 bpf, D = 2.80' 12-718' LNR 6.16#, L -B0 STL, .0058 bpf, D=2.441" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/09/94 OOYON9 ORIGINAL COMPLETION 10/01/14 JMD SCHEMATIC CLEANUPPERTALLU 12121/01 CWKAK CTD SIDETRACK 09/01/15 TBOJMD GLV CIO (08/26/15) 07/16/06 N2ES RANO & PARTIAL SIDETRACK 09/27/18 JNJJMD ADDED REF & BF E LEV INIM 06 NORDIC? CTD SIDETRACK 07128110 DBWVPJC PERFS (07/26/10) 10/12/11 VW%RPJC GLV 00(09/28/11) 3-112' XO, D - 2.867' r3-3/16" x 2-718' XO. 0=2 .441' PRIDHOE BAY UNIT WELL' 15-368 PERMIT No: 2060730 API No: 50-029-22480-02 SED 22,T1 I N, RUES 1440' SNL & 887' EWL BP Exploration (Alaska) . TREE = WH.LIEAD= ACRIATOR = OKB. HEV = FMC --- --_ 65.75 BF. 8" = NA KOP= 1721' Max Angle DATE Dalian ND = 3245 Datum TVD = 8800'99 PROPOSED 15-36C 10-3/4- CSG, 45.51x, L-80, D = 9.950' H 3907' Minimum ID = 2.37" @ 11367' TOP OF 2-7/8" LNR I 995T I VAM TOP. .0152 bol'. D = 3.958' D = 6.875' 3-12- LW 8.810, L-80 STL, .0087 bpf, D = 2.992" 1.0152 bpf, D = 3.958' bpf, D = 2.80' PEW -ORATION S1 MPOARY REF LOG: MCN /OCUGR ON 08/07/06 TEN LOG: GEOLOGY FDC LOG ANGLE AT TOP PERF: _'@_' Nate: %far to production DB for historical oerf data 2-318' LNI7, 4.7#, L-80 S .003866 bpf, D = 1.995' SAFETY NOTES: WELL ANGLE> 70° @ '. MAX DLS: °@_'.—4-18'CNROMETBGR— 'e�GI6 a/!riC�:•51F� ST MD ITVDIDEVI 06109194 DOYON9 ORIGINAL COMPLETION TYPE I VLVj LATCH I PORT DATE 3 3447 3245 42 KBG2 DOLE BK 16 08/26/15 2 6828 5414 51 KBG2 SO BK 20 0826/15 1 9831 7323 47 KBG2 OM1' BK 0 0928/11 �-15-12- X 4-12- XO. D = 3.970' 7-5/8' MLLOIJT WINDOW (15-368) 10097'-10110' 3.70- X 2.70' DEPLOY SLV. D - H3 X 1•P, D = 2.813- X 3-3/18' XO. D = 2.786' MLLOUT WINDOW (15-36C) 11000' - 11010' DATE REV BY COKUNT5 DATE REV BY OOwMBdTB 06109194 DOYON9 ORIGINAL COMPLETION 12121101 CIYKAK CTD SIDETRACK 07MG106 N2PS RWO d PARTIAL SIDETRACK 06/04106 NO1701C1 CTDSIDETRACK(15-368) _I_I_ CTDSIDETRACK(15-36C) 08123118 JM) BLR T RiOPOSED D=4.90' i PRUME BAY LUT WELL iS36C PEFUT Na: AR No: 50-029-22480-03 S13C 22 T11 r4 R14E, 1440 SNL & 88T EWL BP Exploration (Alaska) Well Slimhole 4 Ram BOP Schematic (example) Date `Note: Updated schematic will be submitted once rig contracts are final. Quick Test Sub to Otis Top of 7" Otis 0.0 ft ——.— .... ........... ---.-----.- CDR2 Riga Drip Pan Distances from top of riser Excluding quick -test sub 7r 7-1116" 6k Flange x 7" Otis Box Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0ft Cc Blind/Shears CL 2" Pipe/Slips 10.1 k e1 a2 Kill Line CL 2-3/8" x 3-1/2" VERB CL 2" Pipe/Slips CL of Top Swab CL of Flow Cross CL of Master LDS LDS Ground Level 0 16.0 ft 63 t� Swab T1 T2 Master IA OA Test Pomo Hose SPREADSH EET_Prod-1 nject_Cu Nes-Wel I_V 116_2060730_P B U_15-36B_20180928.xlsx 9/28/2018 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 15-36B (206-073) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 10,000,000 Cum. Prod Oil (bbls): 1,214,538 Cum. Prod Water (bbls): 5,683 Cum. Prod Gas (md): 33,588,208 d 1,000,000 1,000,000 Y rD 0 M 0 4) 100,000 _ e ______— ______—_-.__ _.... -.. _e _._._ e v��g. 100,000 _.. -.__• v - O O no 10,000 ��_� - I;_°_"_ q, _ 10,000 S ., �__.—� o — rpm aco —Y - O O N O O ° 03 N al C7 0 O O iy 1,000 O._—..__. __9..._____... __. 1,000 V o o — O U • e N N m 100 _ __ ___ _. - o n 100 7 o !D o o t F O 10 --� 10 3 T i I "- a Produced Gas (MCFM)- GOR a Produced Water (BOPM) o Produced Oil (BOPM) 1 1 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSH EET_Prod-1 nject_Cu Nes-Wel I_V 116_2060730_P B U_15-36B_20180928.xlsx 9/28/2018 Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a "Suspended." current status of Ste Task="Abandon" 1 The initial reviewer will check to ensure that trill" box Res onsible Geologist in the upper left comer of Form 10-403 is chedon" or"Suspend" boxes are also checked, cross out try andinitial it on both copies of the Form 10-403 (Arator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist / work) the initial reviewer will cross out that erroneous entry and initial then. it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling The drilling engineers will serve as quality control for steps 1 and 2. Engineer (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of sus ended wells for accurac . 2.0G,-o'T3 G2:17 Wed Mil PRINT DISTRIBUTION LIST BAKER 15-3(03 05-02 A Please sign and return one copy of this transmittal fc HUGHES o 2 zgA, 0\-1-(‘ ,andatoryl Ql•-1(0 Petrotechnical Data Center, LR2-1 DATA WELL NAME 5 DIFFERENT WELLS 900 E. Benson Blvd. 9 t2-1/2oi5 (mandatory) Anchorage, Alaska 99508 M.K.BENDER FIELD Prudhoe Bay Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE RPM-Wireline (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: September 3,2015 TODAYS DATE: 24-Sep-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: CANIZARES EMAIL: (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS #OF COPIES#OF COPIES#OF COPIES#OF COPIES#OF COPIES U v V V U 1 ConocoPhillips Alaska Inc. 1 1 1 1 Attn:Ricky Elgaricio 05-02ARPM PNC3D_RAW_03SEP2015_BH I.m eta ATO 3-344 700 G Street Anchorage,AK 99510 B= (Folder 1 on cd/dvd) 05-02A_RPM_PNC3D_RAW_O3SE1 2 ExxonMobil,Alaska RECEIVED\/ I I I I Attn:Lynda M.Yaskell and/or Leonardo Elias n 3700 Centerpointe Dr.Suite 600 SEP 2 8 201 SCANNED A U G 1 7 201.. Anchorage,AK 99503 AOGCC SCANNED 3 State of Alaska-AOGCC 1 I 1 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 4 DNR-Division of Oil&Gas 0 0 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5 I I TOTALS FOR THIS PAGE: 2 1 0 0 TOTALS FOR ALL PAGES: 2 1 1 1 0 0 OPERABLE: 15 -36B (PTD #2060730 Tubing Integrity Confirmed Page 1 0 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, September 06, 2011 10:37 AM P � rJ 91614 To: 'AK, D &C Well Integrity Coordinator' Subject: RE: OPERABLE: 15 -36B (PTD #2060730) Tubing Integrity Confirmed 15 -36B Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 4 `r 7 nit From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, September 04, 2011 8:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan; G GPB FS3 Drillsites Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: OPERABLE: 15 -36B (PTD #2060730) Tubing Integrity Confirmed All, Producer 1 5 (PTD #2060730) passed a TIFL on 09/03/2011 after bringing the well online proving tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, September 01, 2011 11:08 AM To: AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; : , RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cis •.ski, Doug A; Daniel, Ryan; G GPB FS3 Drillsites Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: UNDER EVALUATION: 15 -36B (PTD #2060730) Evaluate f• igh IA Pressure During TAR All, Producer 15 -36A (PTD #2060730) had s = ained IA pressure above the MOASP during the TAR. The well is now ready to be brought online • perform a TIFL. In the event the TIFL fails, a follow -up e-mail will be sent with a plan forward. Th- ell is reclassified as Under Evaluation and may be returned to production. 9/6/2011 Producers with Sustained Casing Pressure on IA During TAR • Page 1 of 1 • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com Sent: Monday, August 15, 2011 5:14 PM t1 ZS ( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug A; Daniel, Ryan Cc: Walker, Greg (D &C); Stechauner, Bernhard; Lee, Timothy; Reynolds, Charles (ALASKA) Subject: Producers with Sustained Casing Pressure on IA During TAR All, The following producers were found to have sustained casing_pressure on the IA during shut down for . turnaround activity. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repress to iazir on. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 06 -04A (PTD #2001020) 06- 'TD #2090120 15 -36B (PTD #2061730) All the wells listed above will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, SEP L 2. 0! Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com II I 8/25/2011 STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ^ ~ 206-0730 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-22480-02-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~ ADLO-028306 PBU 15-36B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13285 feet Plugs (measured) None feet true vertical 8776.98 feet Junk (measured) None feet Effective Depth measured 13249 feet Packer (measured) 9921 true vertical 8778 feet (true vertical) 7384 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3907 10-3/4" 45.5# L-80 35 - 3907 35 - 3565 5210 2480 Intermediate 10097 7-5/8" 29.7# NT95HS 33 - 10097 33 - 7509 8180 5120 Production 1037 4-1/2" 12.6# 13CR80/L-80 9951 - 10988 7407 - 8275 Liner 2588 3-1/2"X3-3/16"X2-7/8" 10697 - 13285 8010 - 8779 Liner 8-81#/6.2#/6.16# L-80 Perforation depth: Measured depth: O 12440 - 13150 O 12025 - 12050 O 12110 - 12160 _ _ True Vertical depth: 8766.52 - 8776.91 8772 - 8771 8770 - 8770 _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR-80 SURFACE - 9957 SURFACE - 7409 Packers and SSSV (type, measured and true vertical depth) 7-5/8"X4-1/2" BKR S-3 PKR 7384 9921 ``~` { ~5 M ~V 12. Stimulation or cement squeeze summary: rrtt q Intervals treated (measured): ""~ ~~~ ~ ~ ;~, ~U !~ `~~~ ~~tpission Cbfi3 G ~ ~11~ . 8S S sk~ , Treatment descriptions including volumes used and final pressure: ~;;1CI3t1!'l~E 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 42 6725 0 372 Subsequent to operation: 422 6419 15 274 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well 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. Exempt: NA Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer .- Signature Phone 564-4944 Date 7/29/2010 Form 10-404 Revised 7/2009 F~DMS RIL ~ 8 ~ %y~ 7-3v ~o Submit Original Only C~ • 15-36B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/17/2010T/I/0=2300/600/0 Hot Oil Treatment (Scheduled) Pumped into Tbg w/ 150 bbls 180* Diesel. Continued on 7-18-10 , 7/18/2010Continued from 07-17-10 Hot Oil treatment. (Scheduled) Pumped39 bbls 180* Diesel down FL. FWHP=1200/600/150 SV,WV,SSV shut. MV,IA,OA Open, 7/19/2010 CTU #9 w/ 1.75" CT (Log/perf) 'MIRU. RIH w/ 2" SWS MGR/CCL carrier BHA 7/20/2010CTU #9 w/ 1.75" CT (perforate) Continued from WSR 7/19/2010 RIH w/ SWS 2" !MGR/CCL carrier to setdown at 11566'. Sticky and could not jet thru. POOH. CRIH w/ 1.7" motor and 2.25" mill. Sat down @ 3570. Came online down coil and RIH to 5184. could not RIH due to well locking up due to parafin. Pooh. Found ;pinhole in coil while pooh. Bled down coil, checks held. cont. pooh. FP well w/ 38 bbls of 50/50 meth. Blow down pipe w/ N2. RD **job incomplete"* 7/22/2010T/I/O 250/ 600/5 Assist CTU with paraffin clean out. Pumped 96.5 bbls of 160* F diesel down the coil to assist with clean out. Final WHP 250/620/180. CTU on ;well at departure. 7/22/2010;: MIRU CTU #9. Job scope hot diesel/coil flag/pert. Pump 1.25" ball through new ;reel. Perform weekly BOP test. MU 1.75" nozzle. Perform dropped objects ;audit. Jet to 6000' with hot diesel .Chase out with KCL. Start back in hole 'w/nozzle assembly to clean out w/diesel. (JOB INCOMPLETE CONTI NUED ON 7-23-10) 7/22/2010; Load and road to loc., Assist CTU ***Contined on 07-23-10 WSR'`** 7/23/2010; ***Continued from 07-22-10 WSR***Assist CTU, Pumped 215 bbls of 150" diesel into CTU. CTU had control of well head during and on departure from job. 7/23/2010; (Continued From 7-22-20) CT-9 Hot diesel parrafin clean out. 2.2" drift on CCUGR carrier, & Ad 75' perfs. Jet w/ hot diesel from 3700'-13220'. Had ;tag/break through @ 11595'. Did not tag TD, but getting high weights near ;13220'. POOH. MU WOT MHA and SWS GR/CCL in carrier w/ 2.25" drift 'nozzle. RIH to tag @ 11542, jet to 11548'. Tag again @ 11572', Work down to j 11604'. PU & run back to 11,540' 3 times, tag solid & P/U clean each time, ;POOH. JOB NOT COMPLETE CONTINUED 7-24-10 7/24/2010(Continued from 7-23-10) POOH with 2.25 JS nozzle assembly, MU/RIH with ;2.30" mill. Perform weekly emergency drill -Man Down. Dry tag w/ mill @ 11551'. Mill to 13200' w/ minimal work and PowerVis Sweep. Back ream same 'interval. Dry drift with no problems to 13200'. Pump final 20 bbl sweep from 13200'. Chase out to surface. N/D milling assembly, & M/U SLB logging tools. JOB CONTINUED ON 7-25-10 _...__......._.______~____w _____.._._.._....___..__. ____.___------_--- _--_-_ 7/25/2010FCONTINUED FROM 7-24-10 RIH with memory GR/CCL. Make logging pass #from12,300 to 11,300 @ 45 fpm, pump Diesel Xylene 50/50 mix into perfs. ;Pump 59 bbl KCL down backside to test injectivty/displace. Inj =0.5 bpm @ 1600 !psi. MU/RIH w/gun #1, 25' of 2" gun. Tie in to flag. Shoot interval 12135'- ! 12160'. POOH guns fired, RIH w/#2 pert run, 25' of 2" guns, 2006 power jet, 6 sspf. shoot 12110-12135'. POOH for next run. 'JOB INCOMPLETE CONTINUED ON 7-26-10 7/26/2010~(CONTINUED FROM 7-25-10) POOH w/Gun #2, guns fired, recovered ball, R/D, M/U Gun #3, RIH and pert last (3rd) interval from 12,025-12,050' 2" 2006 power jet, 6 spf. FP wellbore w/ water/meth. RDMO. Job is complete. Well is ready to ;POP FLUIDS PUMPED BBLS 80 50/50 METH 404 DIESEL 30 POWER VIS 144K 183 1 % KCL W/SL 418 1%KCL 1115 Total TREE = 4-1116" CM/ WELLHEAD = ' FMC ACTUATdt2 = BAKER C KB. ELEV = 65.8' BF. ELEV = NA KOP = 1721' Max Angle = 96 @ 11793' Datum MD = WA Datum TV D = 8800' SS ~ 1 U-3/4" C;SG, 45.5#, L-80, ID = 9.950" ~-i $g0T Minimum ID = 2.37" @ 11367' TOP OF 2-7/8" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM, .0152 bpf, ID = 3.958" 7-5/8" WHIPSTOCK (07/08/06} ~-) 10097' ~s-sse SAFETY: PARENT WELL {15-36) IS NOT SHOWN - ORIGINAL WELL FILE FOR MORE DETAILS. 70° @ 11605' ***4-1 /2" C HROM E TBG &LNR*** 2213' I-14-1/2" HES X NIP, ID = 3.813" GAS LIFT MANI~F2FI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3447 3245 42 KBG-2 DOME BK 16 12/06106 2 6828 5414 51 KBG-2 DOME BK 16 12/06/06 1 9831 7325 47 KBG-2 SO BK 20 07/22!08 9900' - 14-1/2" HES X NIP, ID = 3.813" 9921' 7-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 9944' 4-1/2" HES X NIP, ID = 3.813" 9951' 7-518" X 5-1 /2" ZXP LNR TOP PKR w RB SLV, ID = 4.90" 9957' 4-1/2" WLEG, ID 4.00" 9969' 7-5/8" X 5-112" FLIX LOCK LNR HNGR ID = 4.920" 9979' 7-5/8" X 5-112" XO, ID = 3.970" 7-5/8" MILLOUT WINDOW (15-36B) 10097' - 10110' 7-518" EZSV (07105(06} ~ 10117' ESTIMATED TOP OF CEMENT 10700' TOP OF 3-1 /2" LNR, 9.3#, ID = 2.972" ~-~ 10934' TOP OF5-1/2" LNR ( 10965' 7-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" 11119' 2-718" LNR, 6.5#, L-80, ID = 2.377" 13010' 5-1/2" LNR MILLOUT WINDOW (15-36A) 11428' - 11435' (OFF WHIPSTOCK) PERFORATION SUMMARY REF LOG: MCNL/CCL/GR ON 08!07106 TIE-IN LOG: GEOLOGY PDC LOG A NGLE AT TOP PERF: 87 @ 12440' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 12440 - 13150 O 08/08/06 10697' --3.70" DEPLOY SLV, ID = 3.000" I 10715' 3-1/2" HE5 X NIP, ID = 2.813" 1 ' ' 4-1 /2" LNR, 12.6#, -i 10943' 13CR-80 VAM, C ID = 3.958" \ 4-1/2" LNR, 12.6#, L-80 IBT-M, 10988' .0152 bpf, ID = 3.958" 3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID = 2.99" 10745' 3-3116" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" 11367' PBTD - 2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/09/94 ORIGINAL COMPLETION 08/26/06 SMMfTLH DRLG DRAFT CORRECTIONS 12121!01 CH/KAK CTD SIDETRACK 09/28/06 MSSlPA GLV C/O 09124!01 ATTEM PT CTD SIDETRACK 12/06/06 JLJ/TLH GLV CJO 07/16/06 N2ES RWO & PARTIAL SIDETRACK 08/05/08 DR/PJC GLV C/O (07/22/08) 08/04/06 NORDICI CTD SIDETRACK 07/19!06 /TLH DRLG DRAFT CORRECTIONS 3-1/2" X 3-3/16" XO, ID - 2.867" 3-3/16" x 2-7/8" XO, ID = 2.441 " PRUDHOE BAY UNIT WELL: 15-366 PERMfT No: 2060730 API No: 50-029-22480-02 SEC 22 ,T11 N, R14E, 1440' SNL & 887' EWL BP Exploration {Alaska) .- ~"' . i~ .~ ~w i Ss$~.... ..._ x~. ~ ~. _ y ~~ ~' i ?~ tt r } C e ~1 ' E ~~ y ti _ ~ a .~. ~ .y~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9~1VIicrofilm_Marker.doc U BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, • ~~ .; . ~n~~~ Jr~ ~~ ~ ~ ~ ~ t e as 6- a~3 i ~"- a6 8 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 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, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 r1a4c• rt1/n5/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-018 2042570 50029206960200- NA Sealed NA 15-028 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000- NA Sealed NA 15-04B 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-126 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9!2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11 /10!2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-338 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9!2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-45B 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-498 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 • • WELL LOG TRANSMITTAL To: State of Alaska August 20, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-36B PB 1 PB2 AK-MW-4521685 w~.a C~ v~ l~ 15-36B+PB1+PB2: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 5 0-029-22480-02, 71, 72 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 5 0-029-2248 0-02, 71, 72 Digital Log Images: r~ ~~~,~~~.' .,f,,. ~, ~, ~~~ 50-029-22480-02,71,72 ` ~ ~ ~°~, -~~ ''"'~ 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: Signed: ~c~Co - c~~3 ~ ~~-t3v d~ )3 j -~-- 3a OPERABLE: 15-36B (PTD #2060730) Tubing Integrity Restored Page 1 e~"Z • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] r~ 1~~~ Sent: Sunday, August 17, 2008 10:20 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L.; Wellman, Taylor T; Sinyangwe, Nathan; GPB, Gas Lift Engr; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 15-36B (PTD #2060730) Tubing Integrity Restored Follow Up Flag: Follow up Flag Status: Green All, Well 15-366 {PTD #2060730) passed a TIFL on 08/17/08. The passing test confirms that tubing integrity has been restored. The well has been reclassified as Operable. Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADV~`10L11 Integrity Engineer Sent: Saturday, August 2008 7:46 PM To: 'Regg, James B (DOA)'; 'M der, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, even; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; Townsend, liot; Wellman, Taylor T; Sinyangwe, Nathan; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 15-36B (PTD #2060730 Sustained Casing Pressure due to TxIA Comm All, Well 15-36B (PTD #2060730) has been found to have sustained casi ressure on the IA. The TIOs were 2210/2220/0 psi on 08/07/08 when the well failed a TIFL. The well has be eclassified as Under Evaluation and may be produced under a 28-day clock. Alternatively, Operations may allow th pressure to continue to build. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. S: Change out the S/O 3, DHD: Re-TIFL A TIO Plot and wellbore schematic have been included for reference. 10/1712008 UNDER EVALUATION: 15-36B (PTD #2060730) for Sustained Casin~ressure due to ... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, August 09, 2008 7:46 PM ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Wellman, Taylor T; Sinyangwe, Nathan; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 15-36B (PTD #2060730) for Sustained Casing Pressure due to TxIA Comm Follow Up Flag: Follow up Flag Status: Green Attachments: 15-36B.pdf; OPERABLE: 15-36B (PTD #2060730) Tubing integrity has been restored; 15- 366 90-day TIO Plot.doc AI I, Well 15-36B (PTD #2060730) has been found to have sustained casing pressure on the IA. The TIOs were 2210/2220/0 psi on 08/07/08 when the well failed a TIFL. The well has been reclassified as Under Evaluation and may be produced under a 28-day clock. Alternatively, Operations may allow the IA pressure to continue to build. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. S: Change out the S/O 3, DHD: Re-TIFL A TIO Plot and wellbore schematic have been included for reference. «15-36B.pdf» «OPERABLE: 15-36B (PTD #2060730) Tubing integrity has been restored» «15-36B 90-day TIO Plot.doc» Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/17/2008 PBU 15-36B PTD 206-073 8/9/2008 • TREE= 4-1116" CM! WELLHEAD= ACTUATOR = FMC BAKER C KB. ELEV..- 65.8'. BF. ELEV = NA KOP = 1721' Max Angle = 96 @ 11793' Datum MD = NIA Datum TV D - _ -- ~~~ 8800' SS 10-314" CSG, 45.5#, L-80, ID = 9.950" SA NOTES: PARENT WELL {15-36) 3S NOT 1 ~ _~ /'!I- S SEE ORIGINAL WELL FILE FOR M ORE (+~ DETAILS. 70 @ 11605° *"4-112" GIiROMETBG &LNR*** 2213' I-{4-1%2" HES X NIP, ID = 3.813" Minimum ID = 2.37" @ 11367' T4P 4F 2-7/8" LNR 4-1/2" TBG, 12.6#, 13CR-80 VAM; .0152 bpf, ID = 3.958" ~7-5,-8" WHIPSTOCK (07108(06} 7-5f8" EZSV (07105/06} ~ 10117' ESTIMATED TOP OF CE1ti1ENT 10700' TOP OF 3-112" LNR, 9.3#, ID = 2.972" ~-~ 109.34' 10$97' ~-{ 3.70" DEPLOY SLV, ID = 3.000„ 3-1(2" HES X NIP, ID = 2.813" ~ TOP OF5-1?2"LNR ~-{ 1 7-518" CSG, 29.7#, NT-95HS, ID = 6.875" I 11119' ~ ! ~- 2-7!8" LNR, 6.5#, L-80, ID = 2.377" 13010` 4-112° LNR, 12.6#, 10943' 13CR-80 VAM. -~ ID = 3.958" 5-1/2" LNR MILLOUT WINDOW (15-36A) _ 11428' - 11435' (OFF WHIPSTOCK) 4-112" LNR, 12.6#, L-80 IBT-M, - - 1(}Q$$' .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: MCNL/CCL/GR ON 08I07f06 TIE-IN LOG: GEOLOGY PDC LOG ANGLEAT TOP PERF: 87 @ 12440' Note: Refer to Production D8 for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 12440 - 13150 O 08/08!06 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3447 3245 42 KBG-2 DOME BK 16 12/06106 2 6828 5414 51 KBG-2 DOME BK 16 12!06106 1 9831 7325 47 KBG-2 SO BK 20 07/22/08 99110' 4-1(2" HES X NIP, ID = 3.813" 9921' 7-518" X 4-1l2" BKR S-3 PKR, ID = 3.870" 9944' 4-1/2" HE5 X NIP, ID = 3,813" 8951' 7-5/8" X 5-112" ZXP LNR TOP PKR w /TB SLV, ID = 4.90" 9957 4-112" WLEG, ID = 4.00" gg6$` 7-518" X 5-112" FLEX LOCK LNR HNGR, tD = 4.920" 9979" 7-518"' X 5-1/2" XO, ID = 3.970" 7-5/8" MILLOUT WINDOW {15-368) 10097' - 10110' 1 10745' i 3-112" LNR, 8.81 #, L-80 STL, .0087 bpf, ID = 2.99" !-j 10745' 3-3116" LNR; 6.2#; L-80 TCII..0076 bpf, ID = 2.80" 11367' PBT© I-I 13249' 3-1/2°' X 3-3(16" XO, ID - 2.867" 3-3116" x 2-7l8" XO, ID = 2.441" 2-7(8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 132$5' DATE REV BY COMMENTS DATE REV BY COMMENTS 06(09194 ORIGINAL COMPLETION 08(26/06 SMMITLH DRLG DRAFTCORRECTiONS 12/21!01 CWKAK CTD SIDETRACK 09128(06 MSSIPAG GLV C1O 09124401 ATTEM PT CTD SIDETRACK 12!06106 JLJITLH GLV C!O 07118/06 N2ES RWO & PARTIAL SIDETRACK 08!05108 DR/PJC GLV C!O (07!22!08) i/ 08104(06 NORDIC! CTD SIDETRACK 07,-19r'06 iTLH DRLG DRAFTCORRECTIONS PRUDHOE BAY UNIT WELL: 15-36B PERMff No: 20fi0730 API Na: 50-029-22480-02 SEC 22 ,T11 N, R14E, 1440' SNL & 88T EWL BP Exploration {Alaska) q r- ~" DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2060730 Well Name/No. PRUDHOE BAY UNIT 15-36B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22480-02-00 MD 13285 TVD 8779 Completion Date 8/9/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD GR /EWR, MWD GR /EWR, MWD GR /EWR, MGR /CCL / C Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Directional (data taken from Logs Portion of Master Well Data Maint Interval OH / ~~ iy meairrmt rvumper Name D Asc Directio E D Asc Directio ED D Asc Directio nai Survey nal Survey nal Survey ~ ~D C Las 15621 Induction/Resistivity 4 ~D C Las 15622 Gamma Ray 'ED C L I i / i i i as 15623 nduct on Res st v ty r~9 Neutron scale meaia No 25 Blu Rpt LIS Verification I ; Efl C Lis 16094 Induction/Resistivity '~ Rpt LIS Verification C Lis 16095 Gamma Ray Rpt LIS Verification C Lis 16096 Induction/Resistivity Start Stop CH Received Comments 0 13285 Open 8/30/2006 0 11998 Open 8/30/2006 PB 1 0 12232 Open 8/30/2006 PB 2 10960 13285 Open 10/26/2007 LAS, RPM, GR, RPS w/PFD graphics 9809 1198 Open 10/26/2007 PB1 LAS, GR, ROP w/ PDF graphics 9809 12232 Open 10/26/2007 PB2 RPM, FET, GR, ROP RPS w/PDF graphics ~ 9730 12650 Case 2/13!2008 MCNL, GR, CCL, TNN, TNF 5-Aug-2006 9b~4 ~&"~ -~3Fse- -~1~29E1~- L-~•a ~~,••: ro ~niT,..io~ 9813 13254 Open 4/10/2008 LIS Veri, GR, ROP, RPS, RPD, FET, RPM 9813 13254 Open 4/10/2008 LIS Veri, GR, ROP, RPS, RPD, FET, RPM 9813 12000 Open 4/10/2008 PB1 .LIS Veri, GR, ROP 9813 12000 Open 4/10/2008 P61 LIS Veri, GR, ROP ~ 9813 12203 Open 4/10/2008 P62 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD 9813 12203 Open 4/10/2008 P62 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD ' DATA SUBMITTAL COMPLIANCE REPORT 8/4/2008 Permit to Drill 2060730 Well Name/No. PRUDHOE BAY UNIT 15-36B Operator BP EXPLORATION (ALASKA) INC MD 13285 TVD 8779 Completion Date 8/9/2006 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? T'/~ Chips Received? ~VL Analysis Y~ / N Received? Comments: Compliance Reviewed By: Daily History Received? ~/ N Formation Tops ~/ N API No. 50-029-22480-02-00 UIC N Date: • OPERABLE: 15-36B (PTD #2060730) Tubing integrity has been restored Page 1 r~fy2' • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, July 24, 2008 9:45 AM ~~ To: Regg, James B (DOA}; Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Roschinger, Torin T.; Sinyangwe, Nathan; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 15-36B (PTD #2060730) Tubing integrity has been restored Follow Up Flag: Follow up Flag Status: Green Hi ali, Well 15-368 (PTD #2060730} passed a TIFL an 07/23/08 after changing out the orifice gas lift valve proving integrity has been restored. The well has been reclassified as Operable and may be brought on line when convenient for operations. ~:~'~~ i~01/ ~ ~.~ 2008 From: NSU, ADW II Integrity Engineer Sent: Sunday, July 13, 8 8:36 PM To: 'Regg, James B (DOA)'; ' nder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossber , Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L.; NSU, ADW Well Integri ngineer; Sinyangwe, Nathan Subject: UNDER EVALUATION: 15-366 (PTD #2 730) for Sustained casing pressure due to TxIA Comm Hi all, Well A-40 (PTD #1930140) has been found to have sustain casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2300/20 psi on 07/09/08. A TI failed on 07/11/08 due to IA repressurization overnight confirming TxIA communication. The well has been recta 'fled as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to incr e or may return the well to production while Under Evaluation. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Slickline: Change out orifice gas lift valve 3. DHD: re-TIFL A TIO plot and wellbore schematic have been included for reference. 10/17/2008 UNDER EVALUATION: 15-36B (PTD #2060730) for Sustained casing pressure due to ... Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, July 13, 2008 8:36 PM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer; Sinyangwe, Nathan Subject: UNDER EVALUATION: 15-36B (PTD #2060730) for Sustained casing pressure due to TxIA Comm Follow Up Flag : Follow up Flag Status: Green Attachments: 15-36B TIO plot.BMP; 15-36B.pdf Hi all, i~-~~ L~ ~~3~> Well has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2300/20 psi on 07/09/08. A TIFL failed on 07/11/08 due to IA repressurization overnight confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to increase or may return the well to production while Under Evaluation. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Slickline: Change out orifice gas lift valve 3. DHD: re-TIFL A TIO plot and wellbore schematic have been included for reference. «15-36B TIO plot.BMP» «15-36B.pdf» Please call with any questions. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 10/17/2008 p~c.~L I ~ -3~ 2L6-°c~7~ -i- 3,oaa a,aoa -i~ 1,0x0 ~'''~'' MAASP a 4l13~aa8 ar~sr~aos sr~ 3r~oa~ sr~srzooa sr~ 2~2oos sr2~rzoos rr, ;~rzoas ~r~snaos ~~ ~ ~~ '~ -> oo~ ~ ,~,~ s ~ WELL LOG TRANSMITTAL To: State of Alaska April 8, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-36B AK-MW-4521685 1 LDWG formatted CD rom with verification listing. API#: 50-029-22480-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Dater Signed: ~ ~b~-v~-~ ~~~09~E ~ • WELL LOG TRANSMITTAL To: State of Alaska Apri18, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-36BPB2 AK-MW-4521685 1 LDWG formatted CD rom with verification listing. API#: 50-029-22480-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 lI Date: Signed:l~. ~~~-C~~- , ~ ~~~9~ WELL LOG TRANSMITTAL To: State of Alaska April 8, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 15-36BPB1 AK-MW-4521685 1 LDWG formatted CD rom with verification listing. API#: 50-029-22480-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 94518 Anchorage, Alaska 99508_ ~e , Date: Signed: ~~66-~~3~ 16a9s~ 02/04/08 i ~~il~~~~i~~~~~ NO. 4572 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 Field: P.Bay, Milne Pt, Polaris,Lisburne Wpll .Inh it Lnn Desr_rintinn Date 8L Colnr CD LGI-04 11970706 SBHP SURVEY - j 6° " '~ 01101/08 1 MPH-12 11978435 MEM DDL 01/31/08 1 W-216 12031441 USIT ~f}- 01111/08 1 W-214 11855826 CH EDIT PDC GR (USIT) l 11/19/07 1 GNI-04 11846828 CH EDIT PDC GR (USIT) .. 11/11/07 1 15-36B 11216209 MCNL (0 ^ 08/05/06 1 1 H-24A 11767145 MCNL -'~_ 15 ~j~t 11/29/07 1 1 C-046 11216198 MCNL ~ ~ ~j'~ ~ I 3 06/02/06 1 1 L3-11 11962776 MCNL ~ ~ q 12/12/07 1 1 PLEASE AGKNUWLEUGE KEGEIPT BY SIGNING ANU RETURNING UNE GUPY EAGFi TU: BP Exploration (Alaska) Inc. Petrotechnical Dafa Center LR2-1 z_a i'i "" )~ ~ /' '~ t~- ~~ 900 E. Benson Blvd. ~ t; _ ~ _ r L~ Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 Received by: i ~~ by Date 10-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv Questions, please contact Douglas Dortch at the PDC at 564-4973 ra Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-126 c~d~-- c~s5r_~'~L~ .___. 02-16CPB1 a0 '~!---0$3_ ~ lSfal`9 _ 02-18~-~ J~ln ~-F~2~ 04-01 A ~0~ -0.35-- _ ~ t5~aC3-._--_.__.. 15-16B c~ - v33____t~~21 15-16BP61 _ ~ -p~-3 ~~~c~_,___ 15-16BP62 .~nG--n~3 ~G,23 .~,_ 18-27Ds~4~-133-_ r~'~oc2`L_----_.___ 18-27DP61_- 20~_1~~.__l5lac0~- --.___ --_-__- G-24A _ c~6_4_ -.O_~a___ ~J~-~~ -_-__ G-24AP61 ~-v~_-a~a_ ~ ~.5~-~_..______...____ - P2-11 A _~t2~ -vat _L;S_~~`.'t___________._.___ P2-11 APB1 _~(ULo-~.i~ ~ .._1S~r3.~...._..__.---_..._._ P2-37APB 1.:~:Q.S.~.Q~ ~._._ j.~(0-33...~.-._... -102 _._.._~_~~.._____ . _ ~ j?=. it -102P6 Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 AnchoraDe, AK 995 1 9-66 1 2 l~ STATE OF ALASKA ~ ALASKA IL AND GAS CONSERVATION COM SIGN `'~ ~.' T ~ ,~ t'~U WELL COMPLETION OR RECOMPLETION REPORT AND L0~3aska Oil & ~~~ Loris C~rrltnls~ors 10/11/06 Revised~~roduct~on 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 2oAAC zs.~~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/9/2006 12. Permit to Drill Number 206-073 306-239 3. Address: P.O. Box 1966'12, Anchorage, Alaska 99519-6612 6. Date Spudded 7/7/2006 13. API Number 50-029-22480-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/4/2006 14. Well Name and Number: PBU 15-36B 1440 FNL, 887 FWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 4635' FSL, 4109' FWL, SEC. 15, 711 N, R14E, UM 8. KB Elevation (ft): 65.75 15. Field / Poof(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4581' FSL, 305' FWL, SEC. 14, 711 N, R14E, UM 9. Plug Back Depth (MD+TVD) 13249 + 8778 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676825 y- 5960062 Zone- ASP4 10. Total Depth (MD+TVD) 13285 + 8779 Ft 16. Property Designation: ADL 028306 TPI: x- 679891 y_ 5966211 Zone- ASP4 Total Depth: x- 681367 y- 5966193 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD GR /EWR, MWD GR /EWR, MWD GR /EWR, MGR /CCL /CNL, MGR /CCL /CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTHTVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 30' 110' 30' 110' 30" 260 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 3907 35' 3565' 13-1/2" 1105 sx PF'E' 375 sx Class'G' 7-518" 29.7# NT95HS 33' 1 7' 33' 7509' 9-7/8" 617 sx Class'G' 4-1/2" 12.6# 13Cr80 J L-80 9951' 10988' 7407' 8275' 6-3l4" 200 sx Class'G' s-vr x 3-3/16° X z-~~s° a.a,a i s.z# r s.isn L-80 10697 13285' 8010' 8779' 4-1l4" 158 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9957' 9921' MD TVD MD TVD 12440' - 13150' 8765' - 5779' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 2250' Freeze Protect with 60/40 McOH 26. PRODUCTION TEST Date First Production: October 2, 2006 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 10/10/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 92 GAS-MCF 7 WATER-BBL 2 CHOKE SIZE gg GAS-OIL RATIO 7g Flow Tubing Press. 267 Casing Pressure 1,800 CALCULATED Z4-HOUR RATE• OIL-BBL 549 GAS-MCF 43 WATER-BBL 11 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None 0 CT l 9 2006 Form 10-407 Revised 12/2003 ~ ~ (~ ~ ~ /~C~NTINUED ON REVERSE SIDE ,~ r L 2i~. GEOLOGIC MARKE 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10971' 8259' None Shublik A 11014' 8299' Shublik B 11044' 8326' Shublik C 11060' 8341' Shublik D 11087 8365' Sadlerochit 11093' 8370' Top CGL 11230' 8496' Base. CGL 11302' 8559' 23S6 /Zone 26 11361' 8607' 22TS 11416' 8648' 21TS /Zone 2A 11515' 8711' Zone 1 B 11603' 8750' TDF /Zone 1A 11739' 8778' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date ~f<~ V 1~ PBU 15-36B 206-073 306-239 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Sean McLaughlin, 564-4387 L INSTRUCTIONS GeNew-L: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irma 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements. given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED S E P 1 3 2006 Alaska Oil & Gas Cons. Commission 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoaAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well ClassAnChOr~@ ®Development Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/9/2006 12. Permit to Drill Number 206-073 306-239 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/7/2006 13. API Number 50-029-22480-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/4!2006 14. Well Name and Number: PBU 15-36B 1440 FNL, 887 FWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 4635' FSL, 4109' FWL, SEC. 15, T11 N, R14E, UM 8. KB Elevation (ft): 65.75 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4581' FSL, 305' FWL, SEC. 14, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 13249 + 8778 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676825 y- 5960062 Zone- ASP4 10. Total Depth (MD+TVD) 13285 + 8779 Ft 16. Property Designation: ADL 028306 TPI: x- 679891 y- 5966211 Zone- ASP4 Total Depth: x- 681367 y- 5966193 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD GR /EWR, MWD GR /EWR, MWD GR /EWR, MGR /CCL /CNL, MGR /CCL /CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING' DEPTH MO( SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP. BOTiO1N - TOP- .' BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 30' 110' 30' 110' 30" 260 sx Arctic Set A rox. 10-3/4" 45.5# L-80 35' 3907' 35' 3565' 13-1/2" 1105 sx PF'E' 375 sx Class 'G' 7-5/8" 29.7# NT95HS 33' 1 7' 33' 7509' 9-7/8" 617 sx Class'G' 4-1 /2" 12.6# 13Cr80 / L-80 9951' 10988' 7407' 8275' 6-3/4" 200 sx Class 'G' s-,~z~~ x 3-3116" x z-~ra~~ e.s,~ ~ s.z~ i s.,s# L-80 10697' 13285' 8010' 8779' 4-1 /4" 158 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. Tuswc RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9957' 9921' MD TVD MD TVD 12440' - 13150' 8768' - $779' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 2250' Freeze Protect with 60/40 McOH 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HouR RATE• OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ' ~~I'~ ~~:;~`~ f S ~Fl~ SEP 15 2006 Form 10-4 d 1 /2003 CONTINUED ON REVERSE SIDE ~R~~~~VA~. ~ 28. GEOLOGIC MARK 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, Nanne MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10971' 8259' None Shublik A 11014' 8299' Shublik B 11044' 8326' Shublik C 11060' 8341' Shublik D 11087' 8365' Sadlerochit 11093' 8370' Top CGL 11230' 8496' Base CGL 11302' 8559' 23S6 /Zone 26 11361' 8607' 22TS 11416' 8648' 21TS /Zone 2A 11515' 8711' Zone 1 B 11603' 8750' TDF /Zone 1A 11739' 8778' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~13 ~ Signed Terrie Hubble Title Technical Assistant Date b~ PBU 15-36B 206-073 306-239 Prepared By NameMumber.~ Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeru+L: This form is designed for submitting a complete and corcect well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITenn 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Irene 20: True vertical thickness. Irene 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Irene 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Irene 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Irene 27: If no cores taken, indicate "None". Irene 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 8/14/2006 11:21:47 AM BP EXPLORATION Page 1 of 6 Operations Summary: Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/2/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/1/2006 00:00 - 03:00 3.00 MOB P PRE R/D Floor, Blow Down All lines, Separate All Complexes 03:00 - 04:00 1.00 MOB P PRE Remove Berms from Around Rig 04:00 - 12:00 8.00 MOB P PRE Move All Support Complexes off 15-02B 12:00 - 20:00 8.00 MOB P PRE Move Substructure from 15-02B to 15-366 and Spot over Wellhead. 20:00 - 00:00 4.00 MOB P PRE Set Pipesheds 7/2/2006 00:00 - 06:00 6.00 MOB P PRE Set Pit, Motor and Pump Complexes. 06:00 - 18:00 12.00 MOB N HMAN PRE Start Investigation of Geronimo Line Incident. Identified Possible Hazards Associated with Damaged Derrick Platform. Developed Safe Work Plan to Remove Platform from Derrick. Preliminary Investigation Completed. 18:00 - 20:00 2.00 MOB N HMAN PRE Removed Derrick Platform According to Safe Work Plan. 20:00 - 21:00 1.00 MOB P PRE Held PJSM, Plan Forward to Get Rig Operational, Pre-Spud Meeting with Rig Crew, MWD and Mudman. 21:00 - 00:00 3.00 MOB P PRE Finalize Rig Acceptance Check List, Addressed All Outstanding Issues on Check List. 7/3/2006 00:00 - 01:00 1.00 WHSUR P DECOMP ACCEPTED RIG FOR OPERATIONS AT 0001, 7/3/2006. Installed Double Annulus Valves on IA and OA. 50 psi on OA. 0 psi on IA. 01:00 - 02:30 1.50 WHSUR P DECOMP PJSM, P/U and R/U DSM Lubricator. Pull BPV. R/D and UD Lubricator 02:30 - 04:30 2.00 WHSUR P DECOMP PJSM, R/U Circulating Lines to Top of Tree and IA from Circulating Manifold. 04:30 - 05:00 0.50 WHSUR P DECOMP Fill All Circulating Lines with Water. Tested Circulating System to 3,500 psi. 05:00 - 08:30 3.50 WHSUR P DECOMP PJSM, Pump 35 bbls Down 7-5/8" 4-1/2" Annulus at 3 bpm, 150 psi. Taking Returns from Tubing Through Choke Manifold to Slop Tank. Shut Down Pumps and Line Up to Pump Down Tubing. Pump 25 bbl Safe-Surf Pill Followed by 430 bbls 120 deg Water Down Tubing Taking Returns from IA Through Choke Manifold To Slop Tank. Final Circulating Pressure 210 psi. 08:30 - 09:30 1.00 WHSUR P DECOMP Set TWC and Pressure Test from Below to 1,000 psi. Bled Down All Pressure to 0 psi and Close Well In. 09:30 - 10:30 1.00 WHSUR P DECOMP Blow Down Circulating Lines and R/D Same. 10:30 - 13:30 3.00 W HSUR P DECOMP PJSM, N/D Tree and Adapter Flange. 13:30 - 14:30 1.00 WHSUR P DECOMP Installed 4-1/2" NSCT XO in Tubing Hanger to Check M/U Integrety of the Threads for Pulling Tubing. Made Up 7-1/2 Turns. 14:30 - 22:00 7.50 BOPSU P DECOMP PJSM, N/U BOPE's, M/U Choke and Kill Lines, Installed Drilling Riser and R/U Flowline. Secure BOPE's with Turnbuckles and Pressure Up All Air Boots. 22:00 - 22:30 0.50 BOPSU P DECOMP Energized Accumulator and Function Teted and BOPE Components. 22:30 - 23:30 1.00 BOPSU P DECOMP P/U 4-1/2" Test Joint. M/U Testing Sub and Floor Safety Valve. Installed Test Joint. 23:30 - 00:00 0.50 BOPSU P DECOMP R/U BOPE Testing Equipment. 7/4/2006 00:00 - 09:00 9.00 BOPSU P DECOMP Tested BOPE's Utilizing 4-1/2" Test Joint. Test All Rams, Annular, Choke and Kill Line Valves, Choke Manifold and Floor Safety Valves to 250 psi/ 3,500 psi. All Tests held 5 min each. Witness of Test Waived by AGOCC Rep. John Crisp. Test Witnessed by BP WSL Rodney Klegzig & Chris Clemens / Nabors Toolpushers Alan Lunda & Rick Brumley Printed: 8/14/2006 11:21:54 AM BP EXPLORATION Page 2 of 6 Operations Summary Report- Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/2/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 27E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/4/2006 00:00 - 09:00 9.00 BOPSU P DECOMP Testing Sequence; (1.) Bottom Pipe Rams, Floor Safety Valve, (2.) Top Pipe Rams, Kill HCR, Choke Valves 1 & 2 (3.) Choke Valves 3,4,5 & 6, (4.) Choke Valves 7,8 & 9, (5.) Choke Valves 10, 11 & 12, (6.) Manual Kill, Choke Valves 13, 14 & 15, (7.) Choke Line HCR, (8.) Choke Line Manual, (9.) Annular, (10.) Accumulator Test, Starting Pressure 2,825 psi, After Closure 1,525 psi, Initial 200 psi Recovery 50 sec, Final Pressure 2,825 psi, Full Recovery Time 1 min 50 sec., (11.) Blind Rams, (12.) IBOP Top Drive, (13.) Lower Safety Valve - Top Drive. 09:00 - 11:30 2.50 DHB P DECOMP Rig down test equipment, blow down choke line, PJSM with rig site maintenance, pull two way check with lubricator. 11:30 - 12:00 0.50 PULL P DECOMP Pick up 1 jt 4" dp and XO to 4.5" nsct, screw into tubing hanger 7.5 turns, make up topp drive to drill pipe to pull tbg hanger. 12:00 - 12:30 0.50 PULL P DECOMP Check alignment of choke manifold, pull tubing hanger to rig floor. No problem pulling hanger out of spool. Up wt=150k. Monitor well for flow, well static. 12:30 - 13:30 1.00 PULL P DECOMP Circulate a bottoms up at 315 gpm at 300 psi. Pick up 4.5" handling equipment and rig up same. 13:30 - 14:00 0.50 PULL P DECOMP Monitor well and pump dry job. MW in/out=8.4 ppg. 14:00 - 15:30 1.50 PULL P DECOMP Terminate control line, lay down landing jt and tubing hanger. rig up Schlumberger to spool SSSV control line when 4.5" tubing is being laid down. 15:30 - 21:00 5.50 PULL P DECOMP POH laying down 52 jts of 4.5" tubing. 21:00 - 21:30 0.50 PULL P DECOMP Lay down SSSV, rig down SSSV control line spooler. Retrieved 28 out of 31 stainless steel bands. 21:30 - 00:00 2.50 PULL P DECOMP Lay down 38 jts of 4.5" tubing for a total of 90 jts. 7/5/2006 00:00 - 06:30 6.50 PULL P DECOMP Continue laying down 4.5" tubing for a total of 247 jts, one 20.61' stub, 3 gas lift mandrels, and 3 pup jts. 06:30 - 07:00 0.50 PULL P DECOMP Make up running tool and set wear ring. 07:00 - 08:00 1.00 PULL P DECOMP Clear floor, rig down tubing tongs and handling equipment. 08:00 - 13:00 5.00 DHEOP P DECOMP Rig up Schlumberger, Run #1-Gamma Ray, Junk Basket, and 6.75" Gauge Ring. Tagged stump up at 10,357'. Recovered 2 stainless steel bands. 13:00 - 15:00 2.00 DHEOP P DECOMP Run #2 -Rerun Junk Basket and recovered 1 stainless steel band for a total of 31 bands 15:00 - 18:30 3.50 DHEOP P DECOMP Rig up EZSV plug, GR, and CCL, run in hole and set at 10,117', pull out of hole and rig down Schlumberger. 18:30 - 20:30 2.00 DHB P DECOMP Pull wear bushing, rig up and test 7-5/8" casing to the EZSV to 3,500 psi for 30 minutes and record on chart. 20:30 - 21:00 0.50 DHB P DECOMP Rig up to pull 10-3/4" x 7-5/8" pack off, open bottom annulus, no flow. Pull pack off. 21:00 - 23:30 2.50 EVAL P DECOMP As pack off was being pulled the well started flowing. Monitored well until stack was full. Blind rams were closed and we monitored well from 21:15 to 22:45 hrs. Notifications were made to Anchorage Rig Team and AOGCC State Inspector Jeff Jones. Casing pressure built from 80 psi to 120 psi. From 22:45 to 22:50 we bled 11 bbls through the choke line through the gas buster, taking returns into the cuttings tank. The well was shut in and monitored the well for 10 minutes to 23:00, building from 40 psi to 80 psi. From 23:00 to 23:05 another 11 bbls were bled off. The well was shut in and from 23:05 to Printed: 8/14/2006 11:21:54 AM r~ BP EXPLORATION Page 3 ofi 6 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/2/2006 End: 7/15/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name: NABOBS 27E Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~ NPT 7/5/2006 121:00 - 23:30 I 2.501 EVAL I P 23:30 - 00:00 I 0.501 DHB P 7/6/2006 00:30 - 02:30 2.00 BOPSUF~ P 02:30 - 03:00 0.501 BOPSUF{ P 03:00 - 03:30 0.50 BOPSU P 03:30 - 04:00 0.50 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 07:00 2.00 CLEAN P 07:00 - 14:30 7.50 CLEAN N RREP 14:30 - 15:30 1.00 CLEAN P 15:30 - 16:00 0.50 BOPSU P 16:00 - 19:00 I 3.001 CLEAN I P 19:00 - 21:30 2.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 7/7/2006 00:00 - 02:00 2.00 CLEAN P 02:00 - 11:30 9.50 CLEAN P 11:30 - 12:00 0.50 CLEAN P 12:00 - 16:30 4.50 CLEAN P 16:30 - 18:30 2.00 CLEAN P 18:30 - 19:00 0.50 STWHIP P 19:00 - 21:30 2.50 STWHIP N SFAL 21:30 - 22:00 0.50 STWHIP P 22:00 - 00:00 2.00 STWHIP P 7/8/2006 00:00 - 07:30 7.50 STWHIP P 07:30 - 08:30 I 1.001 STWHIPI P 08:30 - 10:30 I 2.001 STWHIPI P 10:30 - 17:00 I 6.501 STWHIPI P Phase ( Description of Operations DECOMP 23:15 the well the pressure went from 20 psi to 50 psi. From 23:15 to 23:25 we bled another 9 bbls, shut the well in and monitored the well from 23:25 to 23:30. In this 5 minutes the well stayed at 20 psi. Gained a total of 65 bbls of dead crude at 7.3 PPg• DECOMP The choke was opened and flow was monitored into the cuttings tank. The flow slowed to a 1.5" stream. At this point the blind rams were opened and the cellar pump was turned on to suck the stack out through the lower annulus. After the stack was sucked out we installed and energized the 10-3/4" x 7-5/8" pack off and tested it at 5,000 psi for 10 minutes. DECOMP Lay down pack off running tool. DECOMP Test top pipe rams, bottom pipe rams, and hydril to 250 psi low and 3,500 psi high for 5 minutes each. Record on chart. Witnessed by WSL Charlie Noakes and Nabors TP Rick Brumley. DECOMP Circulate water through choke line and gas buster to clear dead crude. DECOMP Blow down choke line and mud lines to rig pumps. DECOMP Install wear bushing, RILDS. DECOMP Clear and clean rig floor. DECOMP PJSM, Pick up mule shoe and 27 jts of 4" dp 1 x 1. DECOMP Replace landing outside derrick board, rig up and secure geronimo line. DECOMP POH and stand back 9 stands 4" dp. DECOMP Test blind rams to 250 psi low and 3,500 psi high for 5 minutes each. Witnessed by WSL Chris Clemens and TP Dave Hanson. DECOMP Pick up window mill, bit sub, string mill, 1 jt 3.5" hwdp, bumper sub, 12 4.75" spiral dc's, and a xo. DECOMP Trip in picking up 4" dp 1 x 1 to 2,054'. DECOMP Cut and slip drilling line. DECOMP Inspect and adjust draw works brakes. DECOMP Trip in picking up 4" dp 1 x 1, tag EZSV at 10115'. DECOMP Circulate bottoms up at 420 gpm, 2,750 psi, MW=8.4 ppg in/out, UW=170k, DW=150k, RW=160k. DECOMP POH to bha. DECOMP Stand back 4 stands of dc's in derrick WEXIT Pick up MWD, UBHO sub and orient to whipstock slide. WEXIT Trouble shoot MWD, could not communicate with the tool at surface. WEXIT Surface test MWD tool. OK WEXIT TIH with whipstock assy. WEXIT TIH with 7-5/8" whipstock to mill 6-3/4" window. Fill dp every 30 jts. 'WEXIT Set 7-5/8" whipstock at 71 degrees right of highside. TOW=10,097', BOW=10,110'. WEXIT Displace water out of well with 9.9 ppg LSND mud. Pumped 50 bbl high visc spacer, YP of 75, visc of 300, pump 440 bbls 9.9 ppg LSND mud, visc 45, at 350 gpm at 2,150 psi. WEXIT Mill window from 10,097' to 10,110', pumped 150 visc sweep, drill new formation from 10,110' to 10,124'. UW=154k, DW=140k, RW=145k, 100 rpm's, 350 gpm at 2,400 psi, 5k Printed: 8/14/2006 11:21:54 AM BP EXPLORATION Page 4 of s Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/2/2006 End: 7/15/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/15/2006 Rig Name:. NABORS 27E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/8/2006 10:30 - 17:00 6.50 STWHIP P WEXIT WOB, 50% increase in cuttings when sweep returned. 17:00 - 18:30 1.50 STWHIP P WEXIT Pump weighted sweep. 11 ppg, 85 yp. UW=154k, DW= 140k, MW in/out=9.9 ppg. 350 gpm ~ 2,400 psi. No increase in cuttings returns. 18:30 - 20:00 1.50 STWHIP P WEXIT Perform FIT to 11.5 ppg, 625 psi. Held 10 minutes, bled down to 560 psi in 10 minutes. Passed test. Pumped 1 bbl, gained 1 bbl back after bleeding off pressure. 20:00 - 21:30 1.50 STWHIP P WEXIT MAD Pass up from 10,000' to 9,870'. 21:30 - 23:00 1.50 STWHIP P WEXIT Pump 24 bbl super sweep, MW 9.9 ppg, visc 70, YP 35, 300 gpm ~ 1,900 psi, 20 rpm's. No significant increase in cuttings returns. 23:00 - 00:00 1.00 STWHIP P WEXIT Circulate while taking blower hose off of TD. Build dry job. 7/9/2006 00:00 - 04:00 4.00 STWHIP P WEXIT Pump dry job. POH to 4-3/4" dc's. 04:00 - 07:30 3.50 STWHIP P WEXIT Lay down 12 4.75" dc's, bumper sub, UBHO sub, MWD, float sub, 1 Jt HWDP, upper string mill, bit sub, and starting mill. 07:30 - 08:00 0.50 STWHIP P WEXIT Back out LDS, pull wear ring. 08:00 - 09:30 1.50 STWHIP P WEXIT P/U stack flushing tool, flush the stack of metal cuttings, function rams, flush choke and kill lines. 09:30 - 10:00 0.50 STWHIP P WEXIT Install wear ring, RILDS. 10:00 - 10:30 0.50 STWHIP P WEXIT Rig Service. 10:30 - 13:30 3.00 STWHIP P WEXIT P/U bit, motor, float sub, stab, MWD, initialize MWD, P/U 3 nmfdc's, jar, and xo sub. Shallow pulse test MWD 13:30 - 17:00 3.50 STWHIP P WEXIT TIH to shoe filling dp every 30 stands. 17:00 - 18:00 1.00 STW HIP P WEXIT Install TD blower hose, set block height, orient motor to 70R, get slow pump rate, exit window to 10,124'. 18:00 - 00:00 6.00 DRILL P INT1 Directional drill from 10,124' to 10,195'. UW 152k, DW 138k, RW 150k, 350 gpm ~ 2,800 psi, WOB 5k, TO on 4k, TO off 3.5k, RPM's 50, MW 9.9 ppg in/out. AST=2.55, ART=.25, TDT=2.8. 7/10/2006 00:00 - 17:30 17.50 DRILL P INT1 Directional drill from 10,195' to 10,988'. UW 170k, DW 138k, RW 150k, 320 gpm @ 2,850 psi, WOB 5-8k, TO on 4k, TO off 3.5k, RPM's 100, MW 9.9 ppg in/out. 17:30 - 20:00 2.50 DRILL P INT1 Pump high visc sweep, 200 visc, 40 yp, 9.9 ppg mw. 25% increase in cuttings when sweep came back. Noticed 1/2" long splintered shale coming over the shaker. Backed off the pump to 275 gpm and slowed the rotary to 80 rpm's. MW 9.9 ppg in/out. 20:00 - 21:00 1.00 DRILL P INT1 Monitored well 10 minutes, pumped dry job, and short tripped 11 stands into the shoe. No tight spots, no overpull coming through the window. 21:00 - 22:00 1.00 DRILL P INT1 Service rig. 22:00 - 22:30 0.50 DRILL P INT1 Exit window with no problems, TIH to 10,988'. No problems. 22:30 - 00:00 1.50 DRILL P INT1 Stage pumps up slowly to 275 gpm ~ 2,000 psi and 80 rpm's. Pumped high visc sweep, YP 45, MW 9.9 ppg, 7/11/2006 00:00 - 02:00 2.00 DRILL P INT1 Circulate 3 bottoms up at 275 gpm ~ 2,000 psi and 80 rpm's. Once the sweep came back we saw a 30% increase in cuttings with large splintered shale. Once the sweep was gone the splintered shale diminished quickly. MW 9.9 ppg in/out. 02:00 - 02:30 0.50 DRILL P INT1 Monitor well 10 minutes, pump dry job. 02:30 - 08:00 5.50 DRILL P INT1 POH to shoe, no problems. Drop 2.5" od rabbit with 100' of tail, continue to pull out of the hole to the bha. SLM out. No correction. 08:00 - 10:00 2.00 DRILL P INT1 UD 2 jts dp, xo, jar, three 4.75" NMDC's, MWD, stab, float Printed: 8/14/2006 11:21:54 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E i Date From - To j Hours Task Code NPT 7/11/2006 08:00 - 10:00 2.00 DRILL P 10:00 - 10:30 0.50 DRILL P 10:30 - 13:30 3.00 CASE P 13:30 - 18:30 5.00 CASE N WAIT 18:30 - 19:30 1.001 CASE P 19:30 - 20:30 ~ 1.00 ~ CASE ~ P 22:30 - 00:00 1.50 CASE P 7/12/2006 00:00 - 01:00 1.00 CASE P 01:00 - 09:30 8.50 CASE P 09:30 - 11:00 1.50 CASE P 11:00 - 12:30 I 1.50 I CASE I P 12:30 - 14:00 1.50 CASE P 14:00 - 17:00 3.00 CEMT P 17:00 - 19:00 I 2.001 CASE I P Start: 7/2/2006 Rig Release: 7/15/2006 Rig Number: Phase INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INTi INT1 INTi INT1 INTi INT1 19:00 - 21:30 2.50 CASE P INT1 21:30 - 23:00 1.50 CASE P INT1 23:00 - 00:00 1.00 CASE P INT1 7/13/2006 00:00 - 07:30 7.50 CASE P INT1 07:30 - 08:30 1.00 CASE N WAIT INT1 08:30 - 15:00 ~ 6.501 CASE P INTi 15:00 - 16:00 ~ 1.00 ~ CASE P ~ ~ INT1 16:00 - 17:00 1.00 CASE P INT1 17:00 - 18:00 1.00 CASE P INT1 Page 5 of 6 Spud Date: 9!14/2001 End: 7/15/2006 Description of Operations sub, motor, and bit. Grease draw works, clean rig floor. Rig up to run 4.5" intermediate liner. Discovered 4-1/2" elevators wouldn't fit on 500 ton bales. All available bales in use, wait on 1st available bales. Hold PJSM on making critical lifts up the beaver slide, install bales and elevators on TD. Pick up shoe track as follows. Float shoe with float collar stacked on top of float shoe, 1 jt 4.5" liner, landing collar on bottom of jt #2 Bakerloc'd between jt 1 and jt 2. Checked floats, ok. Ran 22 jts of 4.5" liner for a total of 24 jts, picked up Flex-Lock liner hanger and "C-2" ZXP liner top packer and inspected same. Rig down liner handling equipment, change bales on TD. Pick up a single, a 15' and a 10' 4"dp pup jt on top of the packer. Circulate 1 liner volume. 4 bpm, 120 psi, UW 60k, DW 60k. TIH with 4.5" liner on dp filling every 10 stands, breaking circulation at 4 bpm for 350 stks. Circulate bottoms up ~ 10.053'. Stage pumps up slowly to 230 gpm at 900 psi. Full returns. TIH to 10,988', pass through window with no problem, no tight spots in open hole. P/U cement head and install pump manifold. UW 175k, DW 135k. Circulate bottoms up, hold PJSM on cement job. Pressure test surface lines to 4,000 psi. Pump 35 bbls 12 ppg mud push, 43.4 bbls 15.8 ppg Class "G" cement, drop plug, displace with Schlumberger 20 bbls 10 ppg pert pill, followed by 103 bbls mud. Bump plug, pressure up to 4,000 psi, slack off to confirm hanger is set, bleed off pressure and check floats, OK. Cement in place at 15:00 hrs. 100% returns during cement job. Rotate 15 rounds to the right to release running tool out of packer. Switch over to rig pumps and pressure up to 1,000 psi, pull up out of packer with running tool, circulate 30 bbls at 10 bbls/min, slow pump to 1.5 bbls/min, set wt down to set ZXP liner top packer. Circulate bottoms up at 10 bpm, 15 bbls contaminated cement returns. Rig down cement head, stand back in derrick, rig down cement equipment. Rig up to displace well with sea water. Displace mud out of well with sea water. POH laying down 4" dp. POH laying down 4" dp. Joint of 4" dp fell off the skate. Held a Safety Shut Down, investigated incident, developed and initiated procedure to positively secure jt to skate while laying down dp. Continue Laying down 4" dp securing each jt to skate prior to unlatching elevators. Make service break on liner top packer running tool, lay down 2-7/8" pup jts. Clear floor of liner running tools. Test liner top to 3,500 psi for 30 minutes, record on chart. Hold PJSM on running completion string while waiting on test. Printed: 8/14/2006 11:21:54 AM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: 1 5-36 Common W ell Name: 1 5-36 Spud Date: 9/14/2001 Event Nam e: REENTE R+COM PLET E Start : 7/2/2006 End: 7/15/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 7/15/2006 Rig Name: NABOB S 27E Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/13/2006 18:00 - 19:00 1.00 BUNCO RUNCMP Rig up to run 4.5" chrome tubing. 19:00 - 20:30 1.50 BUNCO RUNCMP Pull wear ring, make a dummy run with the 4.5" tubing hanger. Marked at 29.3', which is what the RKB is. 20:30 - 21:30 1.00 BUNCO RUNCMP Finish rigging up 4.5" tubing handling equipment. 21:30 - 00:00 2.50 BUNCO RUNCMP Hold short refresher PJSM, run wire line entry guide and #1 "X" nipple assy in hole, pick up Baker S-3 production packer and Bakerloc pin end, make up packer to the "X" nipple assy, run 4.5" completion string as per program. Use collar clamp on first 10 joints before using air slips. Use compensator and torq turn all connections. 7/14/2006 00:00 - 16:00 16.00 BUNCO RUNCMP Run 4.5" completion string as per program. Use compensator and torq turn all connections. Measure space out for landing tubing hanger, bottom out on No Go with W LEG in liner top packer at 9,961', set 15k do to prove it was the No Go. No change in 4.5" tubing tally needed. UW 140k, DW 120k. 16:00 - 17:30 1.50 BUNCO RUNCMP Make up hanger on landing jt, land hanger and RILDS. 4.5" tubing set at 9,956' with the WLEG 6' into the top of the liner top packer. 17:30 - 19:30 2.00 BUNCO RUNCMP Reverse circulate corrosion inhabiter down the 4-1/2" x 7-5/8" annulus, spotting it below the DCK valve to the RCH plug. 19:30 - 22:00 2.50 BUNCO RUNCMP Drop ball/bar landing in the RCH plug, hold PJSM, pressure up to 3,500 psi on 4-1/2" tubing setting prod. packer, hold and record on chart 30 minutes, OK. Bleed tubing off to 1,500 psi, pressure up on the 4-1/2" x 7-5/8" annulus to 3,500 psi, hold and record on chart for 30 minutes. OK, Bleed off annulus, bleed off tubing, pressure up to 3,000 psi to open DCK valve. To verify DCK valve was open we pumped 2 bbls at 1 bpm, 260 psi. Switch to tubing side, pumped 3 bbls at 1 bpm, 240 psi. DCK valve open. 22:00 - 22:30 0.50 BUNCO RUNCMP FMC set Cameron two way check in 4-1/2" tubing hanger. Test from below to 1000 psi. 22:30 - 00:00 1.50 BUNCO RUNCMP L/D casing bales, blow down kill line, choke line, 4" mud line, and hole fill line. Clear floor. 7/15/2006 00:00 - 00:30 0.50 BUNCO RUNCMP Blow down all mud lines from rig floor and BOP. 00:30 - 02:00 1.50 BUNCO RUNCMP L/D long bales, pick up and install short bales, rig down casing stabbing board. 02:00 - 08:00 6.00 BOPSU P RUNCMP Nipple down ckoke line, riser, remove turnbuckles, drain stack, move tree into cellar, nipple down BOP, stand back on BOP stand and secure BOP. 08:00 - 11:30 3.50 WHSUR P RUNCMP Install adapter flange, nipple up tree, test tree and adapter flange to 5,000 psi for 10 minutes. 11:30 - 12:00 0.50 WHSUR P RUNCMP Rig up to U-Tube diesel. 12:00 - 13:00 1.00 WHSUR P RUNCMP Rig up lubricator, pull 2 way check, rig up to freeze protect, R/D lubricator. 13:00 - 15:30 2.50 WHSUR P RUNCMP Test manifold to 2,500 psi, pump 98 bbls diesel down 4-1/2" x 7-5/8" annulus taking returns to cuttings tank. Allow to U-Tube. 15:30 - 17:00 1.50 WHSUR P RUNCMP R/U lubricator, install BPV, test backside to 1,000 psi. OK. 17:00 - 20:00 3.00 WHSUR P RUNCMP Secure well, remove plug valves from tree, install flanges with gauges. Clean cuttings tank, suck rain water out of rig conainments, clean cellar area. 20:00 - 20:00 24.00 RIGD P RUNCMP Rig released at 20:00 hrs. Printed: 8/14/2006 11:21:54 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To ~ Hours Task Code NPT 7/22/2006 02:00 - 03:00 1.00 MOB P 03:00 - 03:15 0.25 MOB P 03:15 - 14:00 10.75 MOB P 14:00 - 14:15 0.25 MOB P 14:15 - 14:40 0.42 MOB P 14:40 - 15:40 1.00 BOPSU P 15:40 - 23:00 7.33 BOPSU P 23:00 - 23:30 I 0.50 I BOPSUR P 23:30 - 00:00 I 0.50 I BOPSUR P 7/23/2006 100:00 - 08:00 I 8.00 I BOPSUR P 08:00 - 08:30 0.50 BOPSUF~ P 08:30 - 10:00 1.50 DRILL P 10:00 - 13:30 3.50 DRILL P 13:30 - 19:30 6.00 DRILL P 19:30 - 21:30 I 2.001 DRILL I P Start: 7/11 /2006 Rig Release: 8/9/2006 Rig Number: N1 Phase PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE WEXIT WEXIT WEXIT WEXIT 21:30 - 00:00 2.50 DRILL P WEXIT 7/24/2006 00:00 - 00:15 0.25 DRILL P WEXIT 00:15 - 00:40 0.42 DRILL P WEXIT 00:40 - 01:30 0.83 DRILL N DPRB WEXIT 01:30 - 02:10 I 0.671 DRILL I P I I PROD1 02:10 - 03:00 0.83 DRILL P PROD1 03:00 - 03:10 0.17 DRILL P PROD1 03:10 - 04:00 0.83 DRILL P PROD1 04:00 - 06:00 2.00 DRILL P PROD1 06:00 - 07:00 1.00 DRILL P PROD1 Page 1 of 16 Spud Date: 9/14/2001 End: 8/9/2006 Description of Operations Prepare rig for move to DS15-36B. PJSM w/ crew, security and tool service. Nordic 1 turnkey rig move f/ K-02D to DS15-366. PJSM, review procedure, hazards, and mitigation for backing rig over well. Back rig over well, sit down. NU BOP while replacing choke manifold valves. Replacing choke manifold valves. Fill pits with Biozan fluid. Position trailers and tanks on location. Rig up and p-test tiger tank. Complete NU BOP. ACCEPT RIG @ 23:00, 22-Jul-2006. Perform initial BOPE pressure/function test. Witness waived by AOGCC John Crisp. Test witnessed by Robert Caughlin, BP WSL. Continue initial BOPE pressure/function test. Witness waived by AOGCC John Crisp. Test witnessed by Robert Caughlin, BP WSL. Pump volume dart thru reel. P/U BHA #1 -milling assembly. Pull and pressure test CTC to 35kIbs,3500psi. RIH to mill out 4.5" shoe. Tag cement stringers ~d 10860' and 10892'. Washed down to 10940', milled dart and liner wiper plug, 10942' -landing collar. Mill landing collar(.88'), washed down to 10960', drill hard cement to top of float collar ~ 10985'. Float collar(1.45') and float shoe(1.75') to 10988' Enter formation shown by drop in motor work and increased ROP. Drill 14' of formation to 11002'. Geologist confirmed sand in returns. Worked through shoe track 3 times, no issues. Swap to Flo-pro prior to starting out of the hole. POH to p/u build assembly. Pumped through the bit 3.Obpm to 500'. Continue to POOH. L/D BHA #1. BHA hung up w 20.72' above the rig floor. No up motion w 10001bs force. Pull back down to free -assumed hung up on bit due to ability to turn. P/u high enough to close master valve. Break out 2 jts of PH6. Bring bit to surface -the bit encased by a metal sheath -assume from float shoe. Chunks of rubber and metal had been coming over shakers. L/d the tools. P/U nozzle to jet the stack w master still closed. More chunks of rubber, composite and metal over shakers. Jet until cleaned up. Open master. Rack back injector and UD nozzle. C/o ctc. Pull test and pressure test - 35klbs/4000psi. PJSM to review procedure, hazards and mitigation of hazards of P/U build assembly. P/U BHA #2 build assembly. RIH w BHA #2 to 10780'. SHT C~? 2000' OK. Run Tie-in strip f/ 10780' to 10846', +5.5' depth correction Printed: 8/14/2006 11:03:40 AM BP EXPLORATION Page 2 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To i Hours Task Code NPT Phase Description of Operations 7/24/2006 07:00 - 07:15 0.25 DRILL P PRODi RIH, tagged btm at 11000', washed litely off btm in case junk below. 07:15 - 07:30 0.25 DRILL P PROD1 Orient around to 4L 07:30 - 18:45 11.25 DRILL P PROD1 Dir Drill in shublik formation w/ TF at 16L - 13R, 2.8 / 2.9 bpm, 3100 / 3450 psi, Avg ROP 7, Dn wt 15.6K, WOB 2-4K, motor stalling out occasionally 18:45 - 21:00 2.25 DRILL P PROD1 Drill into the top of saddlerochit zone 4. Increase in ROP to 30-40fph. 2.8/2.8bpm, 2600-2800psi, WOB 1-4k. FS -2500psi. Motor stalling out occasionally on stringers. 21:00 - 22:30 1.50 DRILL P PROD1 POH due to stalling problems. Little to no motor work causing stalls for the last 1.5hrs. 22:30 - 23:15 0.75 DRILL P PROD1 Check BHA for damage. Bit in good shape, no balling or plugged jets. Motor good. C/O bit to Hughes bi-center. 23:15 - 00:00 0.75 DRILL P PROD1 RIH to continue build section with BHA #3 7/25/2006 00:00 - 01:00 1.00 DRILL P PROD1 RIH w BHA #3 to tie-in depth of 10780' 01:00 - 01:30 0.50 DRILL P PROD1 Tie-in to GR. +4'. 01:30 - 01:45 0.25 DRILL P PROD1 RIH to bottom of 11101. 01:45 - 03:15 1.50 DRILL P PROD1 Dir drill to 11171'. TF 180ROHS, average 65fph, 2.7/2.7bpm, 2900-3000psi, 2000-3000#WOB. 03:15 - 04:00 0.75 DRILL P PROD1 Dir drill to 11197'. TF 0 HS, average 85fph, 2.7/2.7bpm, 3000psi, 2-3k# WOB. FS 2400psi. 04:00 - 04:30 0.50 DRILL P PROD1 Orient full circle to deal with roll to the right. 45-50 degs of reactive torque. 04:30 - 05:30 1.00 DRILL P PROD1 Dir drill to 11228'. TF 0 HS, average 80fph, 2.5/2.5bpm, 2700psi, 2-3k# WOB. FS 2400psi. 05:30 - 06:00 0.50 DRILL P PROD1 Wiper trip to 11000', mad pass f/ 11000' to 10970' to fill log void, RIH to btm, no problems 06:00 - 06:25 0.42 DRILL P PROD1 Orient TF around to 4L 06:25 - 13:15 6.83 DRILL P PROD1 Dir drill thru Z3 to 11269', TF 27L - 13R, 2.68 / 2.75 bpm, FS 2675 psi, 2850 / 3175 psi, WOB 1-2K, ROP 10 - 15fph, ROP dropped to 5-6fph 13:15 - 15:00 1.75 DRILL P PROD1 POH to BHA #3, std bk injector 15:00 - 15:45 0.75 DRILL P PROD1 POH w/ BHA #3, brk out MHA, LD mwd probe, check mtr, LD bit, secure well, LD NRJ, Cut off CTC 15:45 - 16:30 0.75 DRILL P PRODi PJSM on cutting and laying out CT, cut 100' of CT 16:30 - 17:30 1.00 DRILL P PROD1 Install SLB CTC, pull and P/T to 35K and 3500 psi 17:30 - 18:20 0.83 DRILL P PROD1 MU Hycalog used DS3611 bit, 1.5 deg mtr, install MWD probe, MHA, CTC, stab Injector 18:20 - 20:15 1.92 DRILL P PROD1 RIH w/ BHA #4, shallow hole test MWD at 1800'. Continue RIH to 10810'. 20:15 - 20:45 0.50 DRILL P PROD1 Log down GR & tie-into RA marker -add 3' to CTD. 20:45 - 21:10 0.42 DRILL P PROD1 RIH & tag btm C~? 11269'. 21:10 - 00:00 2.83 DRILL P PROD1 Drill ahead to 11280' with 15R-30L TF, 2.55/2.55bpm, 2700/2850psi, 3k WOB & 4fph ave ROP. Getting frequent stalls. Eased in several times but not able to make any progress. Still getting 60-80% chert in BU samples. Decide to POOH & P/U different bit. 7/26/2006 00:00 - 01:45 1.75 DRILL P PROD1 POOH drilling BHA #4. 01:45 - 02:15 0.50 DRILL P PROD1 OOH. PJSM. S/B injector. UD drilling BHA #4. Bit remains in same condition as went-in. Check motor - OK. C/O MWD probe. 02:15 - 02:30 0.25 DRILL P PROD1 M/U drilling BHA #5 with 1.5 deg X-treme motor, MWD/GR, orienter & rebuilt Bit #5 [Hughes 3-3/4" x 4-1/8" RWD2ST Printed: 8/14/2006 11:03:40 AM ~: BP EXPLORATION Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To !Hours Task Code NPT 7/26/2006 __ 02:15 - 02:30 I 0.25 DRILL _ P _ ___ 02:30 - 04:15 1.75 DRILL P 04:15 - 04:30 0.25 DRILL P 04:30 - 05:45 1.25 DRILL P 05:45 - 06:00 0.25 DRILL P 06:00 - 12:25 6.42 DRILL P 12:25 - 12:45 0.33 DRILL P 12:45 - 16:30 3.75 DRILL P 16:30 - 16:50 0.33 DRILL P 16:50 - 16:55 0.08 DRILL P Start: 7/11 /2006 Rig Release: 8/9/2006 Rig Number: N1 Phase PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 16:55 - 21:55 I 5.001 DRILL I N I RREP I PROD1 21:55 - 22:30 I 0.581 DRILL I N I RREP I PROD1 22:30 - 22:45 I 0.251 DRILL I N I RREP I PROD1 22:45 - 23:30 0.751 DRILL I N RREP PROD1 23:30 - 23:45 0.25 DRILL N RREP PROD1 23:45 - 00:00 0.25 DRILL P PROD1 7/27/2006 00:00 - 00:50 0.83 DRILL P PROD1 00:50 - 01:15 0.42 DRILL P PROD1 01:15 - 02:30 1.25 DRILL P PROD1 02:30 - 03:15 I 0.751 DRILL I P I I PROD1 03:15 - 03:45 0.50 DRILL P PROD1 03:45 - 04:05 0.33 DRILL P PROD1 04:05 - 04:35 0.50 DRILL P PROD1 Page 3 of 16 Spud Date: 9/14/2001 End: 8/9/2006 Description of Operations bicenter]. Scribe tools & M/U injector. RIH drilling BHA #5. SHT orienter & MWD - OK. Continue RIH & tag btm ~ 11280'. Orient TF to HS. Drill to 11302' with 20L TF, 2.55/2.55bpm, 2650/2950psi, 3k WOB & 25fph ave ROP. Having difficulty maintaining HS TF with up to 140degs reactive. Orient TF to HS. Dir. Drill to 11450' with TF at 15L - 50R, 2.71/2.75bpm, 3300/3650psi, 1 - 3k WOB & 25 - 40fph ROP. Wiper trip to 4 1/2" shoe, RBIH to Btm Orient TF 60R, Dir. Drill to 11565' with TF at 55 - 74R, 2.62/2.70bpm, FS at 2833 psi, 3100/3400psi, 1 - 3k WOB & 19 - 66fph ROP, Dn Wt 16.6K. Orient TF around to 32R Dir. Drill to 11565' with TF at 49R, 2.62/2.70bpm, 2875/3050psi, Dn Wt 16.6K. Lost power to rig while drlg on bottom at 11565' at 16:55 hrs Troubleshoot generator problem. Rig electrician arrived on location at 17:30 hrs. Put rig on Gen-3. Meanwhile mobilize crude tanker & SLB cement pump truck for possible contingencies. Trace short problem to be coming from the rig's 24 Volts ESD system which is made up of 3 remote switch lines. Isolate the ESD system & put rig gens back online without problem. Establish circ & P/U CT string with no O/pulls. Wiper trip clean into shoe (10760'). Meanwhile review situation with CTD Manager & decide to conduct a risk assessment for the continuation of operations while further tracing and/or repairing the faulty switch line(s) in the rig's ESD system. Conduct risk assessment for repairing the faulty switch line(s) in the rig's ESD system. Decide to go ahead & rectify problem with the bit at the shoe before going back to work. Shut down gens & put back rig back on Gen-3. Trace fault in ESD to a damaged cable on the 1st level. Somebody must have inadvertently bumped into the cable conduit to the ESD switch on the 1st level leading to a cut in the cable & subsequent grounding/tripping of the rig gens. This may have been done while bringing in materials into the engine room. Isolate the ESD switch on 1st level pending repairs. Reconnect the other 2 switches in the Ops cab & rig floor. RBIH clean to btm. Orient TF to 60R. Drill to 11633' with 50L TF, 2.6/2.6bpm, 2950/3250psi, 5k WOB & 95fph ave ROP. Orient TF around to 20R. Drill to 11716' with 15-30R TF, 2.6/2.6bpm, 2950/3350psi, 5k WOB & 95fph ave ROP. Orient & drill to 11750' with 50R TF, 2.6/2.6bpm, 2950/3350psi, 2k WOB & 95fph ave ROP. Wiper trip clean to window. Log down GR & tie-into RA marker -add 5' to CTD. RBIH to btm tagged @ 11754'. Printed: 8/14/2006 11:03:40 AM C BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase 7/27/2006 04:35 - 06:00 1.42 DRILL P PROD1 06:00 - 06:10 I 0.171 DRILL I N I STUC I PROD1 06:10 - 06:25 0.25 DRILL N STUC PROD1 06:25 - 07:45 1.33 DRILL N STUC PROD1 07:45 - 09:00 I 1.251 DRILL I N I STUC I PRODi 09:00 - 10:15 I 1.251 DRILL I N I STUC I PROD1 10:15 - 10:40 I 0.421 DRILL (P I I PROD1 10:40 - 11:10 0.50 DRILL P PROD1 11:10 - 13:25 2.25 DRILL P PROD1 13:25 - 13:55 0.50 DRILL P PROD1 13:55 - 16:00 2.08 DRILL P PROD1 16:00 - 17:05 1.08 DRILL P PROD1 17:05 - 17:15 0.17 DRILL P PROD1 17:15 - 18:00 0.75 DRILL P PROD1 18:00 - 18:30 0.50 DRILL P PROD1 18:30 - 20:10 1.67 DRILL P PROD1 20:10 - 21:15 1.08 DRILL P PROD1 21:15 - 21:30 0.25 DRILL P PROD1 21:30 - 22:15 0.75 DRILL P PROD1 22:15 - 22:35 0.33 DRILL P PROD1 22:35 - 23:30 0.92 DRILL P PRODi 23:30 - 00:00 0.50 DRILL P PRODi Description of Operations Orient & drill to 11833' with 70R TF, 2.6/2.6bpm, 2950/3350psi, 5k WOB &75fph ave ROP. Lose motorwork. P/U & get differentially stuck @ ca. 5' off btm. Work pipe to 80k without sucess. Orient 4 clicks &circ for 10mins. S/D & relax pipe for 15mins, called out crude tanker Attempting to work pipe free, pulling 90k, slack off -16k, work back and forth while waiting on crude, able to orient TF to 53L f/ 150R, crude tanker arrived at 07:45 hrs RU crude tanker, PJSM on operational procedure, Pump 10 bbls of crude, spot 5 bbls of crude on backside, work pipe pulled free at 90k, first attempt Wiper trip to above 4 1/2" shoe to 10800', circ crude around, tie-in w/ +12' correction, RBIH to btm, pumping new Flo-Pro mud Dir. Drill to 11858' with TF at 111- 105R , 2.8/2.8bpm, FS 3250psi, Up wt 41.5k, Dn wt 14k, 3600 / 3950psi, WOB 3 - 6k, ROP 75 - 90fph, displacing well to new Flo-Pro mud Orient TF to 71 R Dir. Drill to 11932' with TF at 54 - 82R , 2.8/2.8bpm, 3675 / 4000psi, WOB 3 - 6k, ROP 25 - 100fph, displaced well to new Flo-Pro mud Orient TF to 8L Dir. Drill to 11991' with TF at 13L - 26R, 2.7/2.7bpm, 3325 / 3650psi, WOB 3 - 6k, ROP 25fph, PVT 315 bbls Wiper Trip to 4 1/2" shoe, RBIH, no hole problems Dir. Drill to 11998' with TF at 15R, 2.7/2.7bpm, 3425 / 3750psi, WOB 4 - 6k, ROP 39fph, PVT 314 bbls POOH drilling BHA #5 to 10810'. Log down GR & tie-into RA marker -add 3' to CTD. POOH drilling BHA #5. Paint EOP flag ~ 10700'. OOH. PJSM. S/B injector. UD drilling BHA #5. Bit grades 5/2/1 with a ring & 2 plugged jets on the nose. Held PJSM for SHT the SLB X-bow BHA. M/U X-bow testing BHA #6 with used DS49 bit & without the mud-motor. M/U injector. RIH to 1700'. Circ ~ 2.05bpm/1770psi for 15mins. Circ ~ 2.35bpm/1970psi for 15mins. Circ ~ 2.6bpm/2250psi for 5mins. Circ C~ 2.9bpm/2550psi for 5mins. Circ @ 3.1 bpm/2770psi for 5mins. Circ ~ 3.21 bpm/2940psi for 5mins. Circ ~ 2.86bpm/2460psi for 5mins. Send downlink to X-bow tool by circ as follows: 2.86bpm for 45secs. 2.38bpm for 60secs. 2.86bpm for 60secs. 2.38bpm for 60secs. 2.86bpm for 30secs. 2.38bpm for 30secs. 2.86bpm for 60secs. 2.38bpm for 60secs. 2.86bpm for 60secs. 2.38bpm for 30secs. 2.86bpm for 30secs. 2.38bpm for 30secs. 2.86bpm for 30secs. 2.38bpm for 30secs. 2.86bpm for 30secs. 2.38bpm for 60secs. 2.86bpm for 60secs. 2.38bpm for 30secs. 2.86bpm for 15secs. Above sequence is suppose to set the TF to Odegs ~ 0% SR. Tool received command but did not achieve the desired settings. Printed: 8/14/2006 11:03:40 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-36 15-36 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/11 /2006 Rig Release: 8/9/2006 Rig Number: N1 Date i From - To Hours Task i Code NPT Phase 7/28/2006 00:00 - 00:20 0.33 DRILL P PROD1 00:20 - 00:40 0.33 DRILL P PROD1 00:40 - 01:00 0.33 DRILL P PROD1 01:00 - 01:15 0.25 DRILL P PROD1 01:15 - 02:10 0.92 DRILL P PROD1 02:10 - 02:35 I 0.421 DRILL I P I I PROD1 02:35 - 03:00 0.42 DRILL P PROD1 03:00 - 03:30 0.50 DRILL P PROD1 03:30 - 04:45 1.25 STKOH N WAIT PROD1 04:45 - 06:10 I 1.421 STKOH I C I I PROD1 06:10 - 08:45 I 2.581 STKOH I C I I PROD1 08:45 - 12:30 3.75 STKOH C PROD1 12:30 - 13:00 0.50 STKOH C PROD1 13:00 - 13:40 0.67 STKOH C PROD1 13:40 - 15:00 1.33 STKOH C PROD1 15:00 - 16:50 I 1.831 STKOH I C I I PROD1 16:50 - 17:25 I 0.581 STKOH I C I I PROD1 17:25 - 19:30 I 2.081 STKOH I C I I PROD1 Page 5 of 16 Spud Date: 9/14/2001 End: 8/9/2006 Description of Operations Repeat command & achieve desired results. Acquire additional data C 1.98bpm/1600psi. POOH to P/U mud motor. OOH. S/B injector. P/U mud motor. M/U injector. RIH to 1600'. Creep in hole ~ 2fpm circ ~ 2.68bpml2500psi for 5mins. Circ 2.86bpm/2650psi for 5mins. Circ C 3.13bpm/3000psi for 5mins. Circ @ 3.21bpm/3160psi for 5mins. Circ ~ 2.62bpm/2520psi for 5mins. Circ C«~ 2.38bpm/2130psi for 5mins. Circ C~ 2.14bpm/1910psi for 5mins. Circ @ 2.02bpm/1750psi for 5mins. Circ C~ 1.88bpm/1640psi for 5mins. Circ @ 1.78bpm/1560psi for 5mins. Circ C~ 2.62bpm/2380psi for 5mins. Send downlink to X-bow tool by circ a pumping sequence. Achieve desired results with ca. 10% fluid lubrication by-pass thru the motor lower thrust bearing. POOH SLB X-bow BHA #7. OOH. PJSM. S/B injector. L/D X-bow BHA #7. Review possibility of eliminating the anchor & running the WFD AL billet on 2-7/8" STL liner with ANC. Agree to run billet on +/-450' of 2-7/8" liner to place TOWS ~ +/-11540'. Mobilize another billet & Unique indexing Shoe. Meanwhile prep & tally 14jts of 2-7/8" STL liner. M/U 2-7/8" STL rotating guide shoe, 14jts of 2-7/8" STL 6.16# L-80, 2-7/8" pup OH AL billet, 3.5 "G" Spear, XO &MHA. M/U Injector. OAL - 468.72'. RIH w/ OH AL billet assy, correct to EOP flag +3', up wt 38.5k, do wt 18k at 10885', RIH to 11913', unable to work past tight hole POH to OH AL Billet Assy, std back inj POH, LD 3 jts of 2 7/8" liner Replaced SLB CTC w/ WFD CTC, Pull and pressure test OK MU OH AL WS w/ G spear, 2 jts of PH-6, 3 25" Agitator, WFD MHA and injector, LocTite all connections f/ G spear up. AOL = 446.30' RIH w/ OH AL billet assy #9, correct to EOP flag +5', up wt 40k, do wt 18k at 11145', RIH set do at 11913', PU Wt 45K at 11904' Set down w/ 16k - -6k, pumping at 1.80 bpm, 4480 psi, cycle pump and worked pipe f/ -6k dnwt to 30 K upwt for 30 minutes, no progress Released OH AL Billet, POH w/ G spear, Pu Wt 36K with pumps, Pu Wt without pumps 37K, Paint EOP at 10700' Top of OH AL billet at -11540' Bottom of Index Guide Shoe at -11904' 19:30 - 19:50 0.33 STKOH C PRODi OOH. PJSM. S/B injector. L/D R/tools & G-Spear. 19:50 - 20:00 0.17 DRILL C PROD1 PJSM for cutting CT. 20:00 - 20:30 0.50 DRILL C PROD1 R/U hydraulic cutter & cut 100' of CT for chrome tbg management. Have 14175' of CT left on reel. 20:30 - 21:00 0.50 DRILL C PROD1 Rehead & install SLB CTC. Pull test to 35k & P/test to 3500psi OK. Printed: 8/14/2006 11:03:40 AM BP EXPLORATION Page 6 of 16 Operations Summary Report. Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 i Date From - To Hours Task Code NPT Phase ' Description of Operations ._ . - __ -- 7/28/2006 21:00 - 22:00 1.00 DRILL C ~ PROD1 ~ M/U OH ST BHA #10 with 1.8degs X-treme motor, MWD/GR, 22:00 - 00:00 2.00 DRILL C PROD1 7/29/2006 00:00 - 00:40 0.67 DRILL C PROD1 00:40 - 01:00 0.33 DRILL C PRODi 01:00 - 01:25 0.42 DRILL C PROD1 01:25 - 02:15 0.83 DRILL C PROD1 02:15 - 03:00 0.75 DRILL C PROD1 03:00 - 03:10 0.17 DRILL C PROD1 03:10 - 03:35 0.42 DRILL C PROD1 03:35 - 03:45 0.17 DRILL C PROD1 03:45 - 04:30 0.75 DRILL C PROD1 04:30 - 06:45 2.25 DRILL C PROD1 06:45 - 08:00 1.25 DRILL C PROD1 08:00 - 12:30 4.50 DRILL C PROD1 12:30 - 15:00 2.50 DRILL C PROD1 15:00 - 15:30 0.50 DRILL C PROD1 15:30 - 15:45 0.25 BOPSU C PROD1 15:45 - 17:05 1.33 DRILL C PROD1 17:05 - 19:40 2.58 DRILL C PRODi 19:40 - 22:30 2.831 DRILL C ~ PROD1 22:30 - 23:10 0.67 DRILL C PROD1 23:10 - 23:35 0.42 DRILL C PROD1 23:35 - 00:00 0.42 DRILL C PROD1 7/30/2006 00:00 - 00:15 0.25 DRILL C PROD1 00:15 - 02:40 2.42 DRILL C PROD1 02:40 - 04:40 2.00 DRILL X DFAL PROD1 04:40 - 05:15 0.58 DRILL X DFAL PROD1 orienter & rerun Smith 3-3/4" M09 PDC bit #8. Scribe tools & M/U injector. RIH OH ST BHA#10. SHT MWD & orienter ~ 2000' - OK. Correct +2' ~ the flag. RIH to 10800'. Log down GR & tie-into RA marker -subtract 4' from CTD. RIH & lightly dry tag top of AL billet ~ 11540'. PUH & orient TF around to 20L. Ease in from 11538' & tag ~ 11539.6'. Resume time drilling with 20L TF, 2.55/2.55bpm, 2800/3030psi, Ok WOB & 1.2fph ave ROP. Drill to 11540'.6. Time drill to 11542' with 20L TF, 2.55/2.55bpm, 2800/3030psi, 0.5k WOB & 2fph ave ROP. Time drill to 11542.6' with 20L TF, 2.55/2.55bpm, 2800/3030psi, 0.5k WOB & 3fph ave ROP. Getting AL shavings over the shaker. Control drill to 11547' with 20L TF, 2.55/2.55bpm, 2800/3120psi, 3k WOB & 10fph ave ROP. Control drill to 11550' with 25L TF, 2.55/2.55bpm, 2800/3250psi, 4k WOB & 20fph ave ROP. Orient & drill to 11565' with HS TF, 2.65/2.65bpm, 2850/3150psi, 4k WOB & 30fph ave ROP. Survey shows an inclination of 58.89degs ~ 11545'. Orient & drill to 11691' with 60 - 104R TF, 2.65/2.65bpm, 2850/3050psi, 3 - 5k WOB & 70fph ave ROP. Wiper Trip thru OHWS above 4 1/2" shoe, RBIH, orient 20L, slide thru window Dir. drill to 11805' with 30 - 64R TF, 2.65/2.65bpm, 3200/3500psi, 3 - 6k WOB & 20 - 45fph ROP. POH to BHA, Std Bk Injector POH w/ BHA, LD MWD tools and bit, bit grade 1-1 PU test joint, weekly function test of BOP's Adj motor to 1 deg bend, MU bit, PU MWD-GR-RES, orient, test, upload MWD, MU MHA and injector RIH w/ drlg lateral BHA #11, SHT MWD tools, RIH to 11400'. Orient TF to 20L & run thru OH S/T pt with slight 1 k wt bobble. Continue RIH to btm. MAD pass resistivity real time ~ 150fph from 11805' to 11540'. Observe slight wt bobble & motor work across S/T pt. MAD pass in memory mode ~ 750fph from 11540' to shoe. PUH to 10825' for tie-in log. Log down GR & tie-into RA marker -subtract 5' from CTD. RIH to 11500'. Orient TF to 20L & run thru OH S/T pt with slight 1 k wt bobble. Continue RIH to btm. Orient TF around to HS. Continue orienting TF to HS. Drill to 11843' with 4L-1 R TF, 2.5/2.5bpm, 3060/3500psi, 1 k WOB & 20fph ave ROP. Observe pressure fluctuations without any drill-off like the bit jets are plugged. Observe 300psi pressure drop in freespin. POOH to inspect BHA. OOH. PJSM. S/B injector. UD drilling BHA #10. Observed a blown seal on orienter. Also, bit has 5 rubber pieces in it Printed: 8/14/2006 11:03:40 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code ~ NPT Start: 7/11 /2006 Rig Release: 8/9/2006 Rig Number: N1 Page 7 of 16 Spud Date: 9/14/2001 End: 8/9/2006 Phase Description of Operations 7/30/2006 04:40 - 05:15 0.581 DRILL X DFAL I PROD1 05:15 - 06:00 0.75 DRILL X DFAL PROD1 06:00 - 06:30 0.50 DRILL X DFAL PROD1 06:30 - 07:45 1.25 DRILL X DFAL PROD1 07:45 - 10:10 2.42 DRILL X DFAL PROD1 10:10 - 10:30 0.33 DRILL C 10:30 - 14:00 3.50 DRILL C 14:00 - 14:40 ~ 0.671 DRILL C 14:40 - 14:55 0.25 DRILL C 14:55 - 16:35 1.67 DRILL C 16:35 - 18:50 I 2.251 DRILL I C 18:50 - 19:30 19:30 - 20:25 20:25 - 20:50 20:50 - 21:45 21:45 - 21:55 21:55 - 22:05 22:05 - 22:35 22:35 - 22:55 22:55 - 00:00 7/31 /2006 00:00 •00:20 00:20 - 00:30 00:30 - 02:50 0.671 DRILL C 0.92 DRILL C 0.42 DRILL C 0.92 DRILL C 0.17 DRILL C 0.17 DRILL C 0.50 DRILL C 0.33 DRILL C 1.08 DRILL C 0.33 DRILL C 0.17 DRILL C 2.33 DRILL C 02:50 - 05:00 2.171 DRILL IC 05:00 - 07:20 2.33 DRILL C 07:20 - 08:30 1.17 DRILL C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 plugging the internal jets & 2 jets (on the nose & gauge) were plugged with shale. Found additional rubber pieces over the shakers. Download RES data & initialize EWR. P/test orienter &MHA on catwalk - OK, no Teaks C/O mtr and orientor, inspect MWD tools, orient, C/O circ sub, hyd disconnect and check valves, PR CTC, OK, stab injector RIH w/ drlg lateral BHA #12, SHT MWD tools, RIH to 11400'. Orient TF to 0 - 45R & run thru OH S/T pt. Continue RIH to btm. Orienting TF to 10L Dir. Drill to 11904' w/ TF at 28L - 1 R, 2.64 / 2.68 bpm, FS 3100 psi, 3300 / 3600 psi, WOB 2.5 - 4k, ROP 33fph, PVT 272 bbls, IA at Opsi, OA 149psi Short trip to 11700', overpulls at 11790' and 11770' w/ 5k, worked thru area several times, RBIH, OK Orient TF to 113R Dir. Drill to 11904' w/ TF at 107 - 142R, 2.6 / 2.65 bpm, FS 3150 psi, 3400 / 3700 psi, WOB 4 - 6k, ROP 25 -55fph, PVT 271 bbls, IA at 150psi, OA 375psi, difficult sliding, stacking out w/ no motor work, new Flo-Pro mud called out Wiper trip above shoe to 10800', tie-in f! 10825' to 10846', +3' correction, RBIH, set down at 11785', work thru tight hole several times. RBIH to btm. Orient & drill to 11965' with 125R TF, 2.6/2.6bpm, 3170/3500psi, 1 k WOB & 60tph ave ROP. Observe drilling break. Orient & drill to 12010' with 145R TF, 2.6/2.6bpm, 3250/3600psi, 1k WOB & 70fph ave ROP. Orient TF around to 100R. Up wt = 33k, Run-in wt = 10k, TAP = 290psi, OAP = 450psi, PVT = 261 bbls. Drill to 12046' with 125R TF, 2.6/2.6bpm, 3250/3600psi, 2k WOB & 40fph ave ROP. Stacking wt. Short 100' wiper. Drill to 12057' with 130R TF, 2.6/2.6bpm, 3250/3600psi, 2k WOB & 60fph ave ROP. Orient TF to 50R Drill to 12090' with 65R TF, 2.6/2.6bpm, 3250/3600psi, 2k WOB & 90fph ave ROP. Wiper trip to shoe. RBIH to btm with minor wt bobbles across 11700' - 11800' shales. Orient TF to 90L. Drill to 12176' with 75L TF, 2.6/2.6bpm, 3250/3550psi, 3k WOB & 60fph ave ROP. Got back into shale from 12110'. Geo wants to drill up to get us out of the shale. Orient & drill to 12232' with 15R TF, 2.6/2.6bpm, 3250/3450psi, 4k WOB & 45fph ave ROP. Meanwhile swap well to new 8.6ppg flopro mud with 3% L-T & 14ppb K-G. Not getting enough build rate from the 1 deg motor. Decide to POOH to increase motor bend in order to stay inside the polygon. POOH to drilling BHA#12. POH w/ BHA #12, brk out MHA, download MWD, LD mwd Printed: 8/14/2006 11:03:40 AM BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To i Hours Task Code NPT Phase Description of Operations 7/31/2006 107:20 - 08:30 1.17 DRILL C PROD1 08:30 - 09:00 ~ 0.50 ~ DRILL ~ C ~ ~ PROD1 09:00 - 09:45 0.75 DRILL C PROD1 09:45 - 11:00 1.25 DRILL C PROD1 11:00 - 12:15 I 1.251 DRILL I C I I PROD1 12:15 - 13:15 1.00 DRILL X MISC PROD1 13:15 - 14:15 1.00 DRILL X MISC PROD1 14:15 - 15:00 0.75 STKOH X WAIT PROD1 15:00 - 15:45 0.75 STKOH X WAIT PROD1 15:45 - 17:10 I 1.42 I STKOH I C I I PROD1 17:10 - 19:05 1.92 STKOH C PROD1 19:05 - 19:10 0.08 STKOH C PROD1 19:10 - 21;15 2.08 STKOH C PROD1 21:15 - 21:30 0.25 STKOH C PROD1 21:30 - 22:10 0.67 STKOH C PROD1 22:10 - 00:00 i 1.831 STKOH I C I I PROD1 8/1/2006 00:00 - 00:10 0.17 STKOH C PROD1 00:10 - 00:40 0.50 STKOH C PROD1 00:40 - 01:00 0.33 STKOH C PROD1 01:00 - 01:30 0.50 STKOH C PROD1 01:30 - 02:15 0.751 STKOH C PROD1 02:15 - 02:45 0.50) STKOH C PROD1 02:45 - 03:10 0.421 STKOH ~ C PROD1 03:10 - 03:30 0.331 STKOH C PROD1 03:30 - 03:45 0.25 ~ STKOH I C PROD1 03:45 - 04:05 I 0.331 STKOH I C I I PROD1 probe, c/o pulser, mtr adjusted to 1.6 deg bend, LD bit, bit grade 2-2 PJSM on cutting and laying out CT, RU CT hydraulic cutter,cut, LD 100' of CT, RD cutter Install SLB CTC, pull and PR to 35K and 3500 psi MU Hughes rebuilt 4 1/8" RWD2ST304 BC bit, 1.6 deg mtr, install MWD probe,orient, test and upload MWD tools, MHA, CTC, stab Injector RIH w/ BHA #13, shallow hole test MW D and orientor at 1600'. Continue RIH to 6000'. Notified by town engineer to POH, plugback w/liner and openhole aluminum billet, perform OHST POH to BHA #13 POH w/ BHA #13, brk out MHA, download MWD, LD mwd probe, collar, motor and bit Weatherford equipment and personnel and 2 7/8" 6.2# L-80 STL tubing and pup jts w/o cementrailzers arrived on location PU aluminum billet and releated tools to rig floor, Load pipeshed and strap 25 jts of 2 7/8" STL Tbg MU OH AL Billet Assy as follows, 3 1/2" bias index shoe, 23 jts of 2 7/8" 6.12# L-80 STL tbg without cementralizers, 3 1/2" Aluminum Liner Top Billet w/ 2 7/8" 2.16# L-80 STL pup jt = 717', 3.5 "G" Spear, XO &MHA. M/U Injector. OAL -723.86'. RIH w/ OH AL billet assy & tag btm 2x @ 12245'. Wt check: Up = 40k & Run-in = 15k. Set down 16k & release G-Spear with 1.5bpm & 3700psi. P/U with 34k & confirm release. Top of AL billet ~ 11515'. POOH with G-Spear & R/tools. OOH. PJSM. S/B injector. UD R/tools & G-Spear. M/U OH ST BHA #15 with 1.7degs X-treme motor, MWD/GR, orienter & rerun Smith 3-3/4" M09 PDC bit #12. Scribe tools & M/U injector. RIH OH ST BHA#15. SHT MWD & orienter ~ 2000' - OK. RIH. Continue RIH to 10800'. Log down GR & tie-into RA marker -subtract 1' from CTD. RIH & lightly dry tag top of AL billet ~ 11515'. PUH & orient TF around to 25L. Ease in from 11514' & tag ~ 11514.3'. Resume time drilling with 20L TF, 2.65/2.65bpm, 2900/2950psi, Ok WOB & 1.2fph ave ROP. Drill to 11515'.2. Time drill to 11516.2' with 20L TF, 2.65/2.65bpm, 2900/2950psi, Ok WOB & 2fph ave ROP. Time drill to 11517.3' with 20L TF, 2.65/2.65bpm, 2900/2950psi, Ok WOB & 3fph ave ROP. Control drill to 11525' with 20L TF, 2.65/2.65bpm, 2900/3000psi, 2k WOB & 10-15fph ave ROP. Backream from 11525' to 11519' with 20L TF, 2.65/2.65bpm, 2900/2900psi, Ok WOB & 30fph ave ROP. RBIH to btm & orient 1 click. Drill to 11535' with HS TF, 2.65/2.65bpm, 2900/3000psi, 2k WOB & 50fph ave ROP. Printed: 6/14/2006 11:03:40 AM ~ ~ BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours Task Code ~ NPT Phase Description of Operations 8/1/2006 04:05 - 06:35 2.50 DRILL C PROD1 Orient & drill to 11673' with 20-70R TF, 2.65/2.65bpm, 2900/3300psi, 4k WOB & 90fph ave ROP. Survey shows an inclination of 61.26degs ~ 11539'. 06:35 - 07:05 0.50 DRILL C PROD1 Orient TF around to 40R 07:05 - 07:30 0.42 DRILL C PROD1 Dir. drill to 11710' with 37 - 42R TF, 2.7/2.79bpm, 3325/3700psi, WOB 5k & ROP 80fph, PVT 282bb1s, IA Opsi, OA 290psi 07:30 - 07:55 0.42 DRILL C PRODi Wiper trip to 11535', RBIH, no hole problems 07:55 - 08:45 0.83 DRILL C PRODi Dir. drill to 11755' with 42R TF, 2.7/2.79bpm, 3375/3750psi, WOB 5k & ROP 90fph, PVT 281bb1s, IA 26psi, OA 303psi 08:45 - 11:00 2.25 DRILL C PRODi POH to BHA #15, std bk injector 11:00 - 11:30 0.50 DRILL C PROD1 POH w/ BHA #15, brk out MHA, LD orientor, MWD and bit 11:30 - 13:00 1.50 DRILL C PROD1 MU Lateral Drlg BHA #16, Hughes rebuilt 4 1/8" RWD2ST304 BC bit, 1.3 deg mtr, install MWD probe w/ GR-RES, orient, test and upload MWD tools, PU new orienter, MHA, CTC, stab Injector 13:00 - 15:00 2.00 DRILL C PROD? RIH w/ BHA #i6, shallow hole test MWD and orientor at 1600'. Continue RIH to 10825' 15:00 - 15:30 0.50 DRILL C PROD1 Log down w/ GR, tie-in correction -4'. 15:30 - 16:00 0.50 DRILL C PROD? RIH w/ BHA #16 to 11480', TF at 45L, shut down pumps, RIH to Btm, no problem, Dn Wt 15k 16:00 - 16:50 0.83 DRILL C PRODi Madd Pass f/ Btm to 11545' 16:50 - 17:00 0.17 DRILL C PROD1 RIH to Btm 17:00 - 18:45 1.75 DRILL C PROD1 Dir Drill to 11877' w/ TF at 72 - 102R, 2.75/2.82bpm, FS 2850 psi at 2.65bpm, 3450/3825psi, WOB 4-8k, ROP 60 - 120fph, PVT 268bb1, IA 45psi, OA 310psi 18:45 - 19:00 0.25 DRILL C PROD1 Orient TF around to 90R. 19:00 - 19:15 0.25 DRILL C PROD1 Drill to 11901' with 70R TF, 2.75/2.75bpm, 3350/3600psi, 2k WOB & 150fph ave ROP. 19:15 - 19:25 0.17 DRILL C PROD1 Float off-btm survey. 19:25 - 20:20 0.92 DRILL C PRODi Wiper trip to shoe. RBIH to btm. 20:20 - 20:35 0.25 DRILL C PROD1 Orient TF around to 30R. 20:35 - 20:45 0.17 DRILL C PROD1 Drill to 11920' with 15R TF, 2.75/2.75bpm, 3250/3600psi, 2k WOB & 150fph ave ROP. 20:45 - 21:10 0.42 DRILL C PROD1 Orient & drill to 11945' with 60-90R TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 90fph ave ROP. 21:10 - 21:30 0.33 DRILL C PROD1 Orient & drill to 11980' with 115R TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 90fph ave ROP. 21:30 - 21:40 0.17 DRILL C PROD1 Orient Tf to 150L. 21:40 - 22:00 0.33 DRILL C PROD1 Orient & drill to 12010' with 140E TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 90fph ave ROP. 22:00 - 22:25 0.42 DRILL C PROD1 Orient & drill to 12050' with 90L TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 100fph ave ROP. 22:25 - 23:45 1.33 DRILL C PROD1 W iper trip to shoe. RBIH to btm. 23:45 - 00:00 0.25 DRILL C PROD1 Orient & drill to 12065' with 90L TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 100fph ave ROP. 8/2/2006 00:00 - 00:30 0.50 DRILL C PROD1 Orient & drill to 12108' with 90L TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 150fph ave ROP. 00:30 - 01:15 0.75 DRILL N STUC PROD1 Orient TF around & get differentially stuck. CBU. S/D & relax CT. Work string with 16k set down wt & 90k pull & pop free. Conduct short 100' wiper. RBIH to btm. 01:15 - 01:30 0.25 DRILL C PROD1 Orient TF to 120L. 01:30 - 02:10 0.67 DRILL C PROD1 Drill to 12150' with 120E TF, 2.65/2.65bpm, 3150/3400psi, 2k Printed: 8/14/2006 11:03:40 AM ~ ~ BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Nours Task ~ Code NPT I Phase ~ Description of Operations 8/2/2006 01:30 - 02:10 0.67 DRILL C PROD1 02:10 - 02:30 0.33 DRILL C PROD1 02:30 - 05:15 2.75 DRILL C PROD1 05:15 - 06:00 0.75 DRILL C PRODi 06:00 - 06:30 0.50 DRILL C PROD1 06:30 - 07:10 0.67 DRILL C PROD1 07:10 - 07:25 0.25 DRILL C PROD1 07:25 - 07:35 0.17 DRILL C PROD1 07:35 - 09:55 I 2.331 DRILL I C I I PROD1 09:55 - 10:10 0.25 DRILL C PROD1 10:10 - 12:00 1.83 DRILL C PROD1 12:00 - 14:30 2.50 DRILL C PROD1 14:30 - 15:45 1.25 DRILL C PROD1 15:45 - 16:00 0.25 DRILL C PROD1 16:00 - 17:00 I 1.001 DRILL I C I I PROD1 17:00 - 17:20 I 0.331 DRILL I C I I PROD1 17:20 - 19:15 I 1.921 DRILL I C I I PROD1 19:15 - 20:00 0.75 DRILL C PROD1 20:00 - 20:45 0.75 DRILL C PROD1 20:45 - 20:50 0.08 DRILL C PROD1 20:50 - 21:30 0.67 DRILL C PROD1 21:30 - 22:00 0.50 DRILL C PROD1 22:00 - 23:45 1.75 DRILL C PROD1 23:45 - 00:00 0.25 DRILL C PROD1 8/3/2006 00:00 - 00:50 0.83 DRILL C PROD1 00:50 - 00:55 0.08 DRILL C PROD1 00:55 - 01:10 0.25 DRILL C PROD1 01:10 - 02:45 I 1.581 DRILL I C I I PROD1 WOB & 95fph ave ROP. Short BHA wiper. Orient & drill to 12210' with 60-90L TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 35fph ave ROP. Drilling ratty. Wiper trip to shoe. Log down w/ GR f/ 10810' to 10850', tie-in correction +7' RIH to 11450' above OHST, orient TF to 48L, RIH to btm, Dn Wt 14.5k Orient TF around to 100E Dir. drill to 12219' with 94 - 112E TF, 2.65/2.65bpm, FS at 3075 psi, 3250/3650psi, 2k WOB & 28fph ave ROP. Drilling ratty, PVT 243bb1s, IA 283psi, OA 500psi Orient and drill to 12250' with 74-94TF, 2.65/2.65bpm, FS at 3075 psi, 3250/3650psi, 2k WOB & 55fph ROP. Drilling ratty, mfr stalled out several times w/ life weight f/ 12232' to 12248', PVT 242bb1s, IA 283psi, OA 500psi, bled down IA to 35psi, OA to 100 psi Orient TF around to 130E Dir. drill to 12276' with 127E - 120R TF, 2.73/2.8bpm, 3475/3838psi, 2 -3k WOB & 10-70fph ROP. Drilling ratty formation- pyrite in samples, difficult to slide, stacking weight, mfr stalling out several times, TF flipped around a few times after stalling out mfr, PVT 234bb1s, IA 103psi, OA 173psi POH to BHA #16, Std Bk Injector POH w/ BHA #16, brk out MHA, LD Bit, download, test and upload MWD, LD Mtr, bit grade 1-4-1/8 under gauged, MU Mtr, adj to 1.2 deg, MU new RW D2ST304 BC bit, orient to MWD, stand back in derrick PJSM on cutting and laying out CT, removed CTC, RU CT hydraulic cutter, cut, LD 100' of CT, RD cutter, Install SLB CTC, pull and P!T to 35K and 3500 psi RIH w/ RWD2ST304 BC bit, 1.2 deg mfr, MWD-GR-RES, orientor, MU MHA, CTC, stab Injector RIH w/ BHA #17, shallow hole test MWD and orientor at 1700'. Continue RIH to 10815'. Log down GR & tie-into RA marker -subtract 7' from CTD. RIH to btm. Orient TF to 140L. Drill to 12288' with 120E TF, 2.65/2.65bpm, 3150/3400psi, 2k WOB & 15fph ave ROP. Difficult to slide & drilling ratty. Meanwhile swap well to new 8.6ppg flopro mud with 3% L-T & 14ppb K-G. Short BHA wiper. Drill to 12320' with 120E TF, 2.75/2.75bpm, 2950/3400psi, 2k WOB & 25fph ave ROP. Difficult to slide & drilling ratty. Orient TF to LS to drill off ratty zone. Drill to 12331' with 170E TF, 2.75/2.75bpm, 2950/3400psi, 2k WOB & 25fph ave ROP. Achieve drilling break. Orient TF to 130L. Drill to 12339' with 120E TF, 2.75/2.75bpm, 2950/3400psi, 2k WOB & 55fph ave ROP. Orient & drill to 12425' with 90-120L TF, 2.75/2.75bpm, 2950/3400psi, 4k WOB & 75fph ave ROP. Printed: 8/14/2006 11:03:40 AM BP EXPLORATION Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date ~ From - To Hours Task 'Code (NPT ___ - +- ~ - 8/3/2006 02:45 - 04:25 1.67 DRILL C 04:25 - 05:35 1.17 DRILL C Start: 7/11 /2006 Rig Release: 8/9/2006 Rig Number: N1 Page 11 of 16 Spud Date: 9/14/2001 End: 8/9/2006 Phase ' Description of Operations PROD1 Wiper clean to shoe. RBIH to btm. PROD1 Orient & drill to 12518' with 90-120L TF, 2.75/2.75bpm, 05:35 - 05:45 0.17 DRILL C PROD1 05:45 - 06:15 0.50 DRILL C PROD1 06:15 - 06:35 0.33 DRILL C PROD1 06:35 - 07:05 0.50 DRILL C PROD1 07:05 - 07:20 0.25 DRILL C PROD1 07:20 - 09:05 1.75 DRILL C PROD1 09:05 - 09:15 0.17 DRILL C PROD1 09:15 - 09:30 0.25 DRILL C PROD1 09:30 - 10:20 0.83 DRILL C PROD1 10:20 - 11:05 0.75 DRILL C PROD1 11:05 - 11:25 0.33 DRILL C PROD1 11:25 - 11:40 0.25 DRILL C PROD1 11:40 - 12:15 0.58 DRILL C PROD1 12:15 - 12:40 0.42 DRILL C PROD1 12:40 - 13:55 1.25 DRILL C PROD1 13:55 - 14:15 0.33 DRILL C PROD1 14:15 - 14:20 0.08 DRILL C PROD1 14:20 - 14:40 0.33 DRILL C PRODi 14:40 - 14:50 0.17 DRILL C PROD1 14:50 - 15:30 0.67 DRILL C PROD1 15:30 - 16:30 1.00 DRILL C PROD1 16:30 - 17:05 0.58 DRILL C PROD1 17:05 - 18:05 1.00 DRILL C PROD1 18:05 - 18:15 0.17 DRILL C PROD1 18:15 - 18:45 0.50 DRILL C PROD1 18:45 - 18:55 0.17 DRILL C PROD1 18:55 - 19:55 1.00 DRILL C PROD1 19:55 - 20:00 0.08 DRILL C PRODi 20:00 - 20:15 0.25 DRILL C PROD1 20:15 - 20:55 0.67 DRILL C PROD1 2950/3200psi, 3k WOB & 95fph ave ROP. Orient TF to 160L. Drill to 12539' with 135E TF, 2.75/2.75bpm, 2950/3200psi, 3k WOB & 95fph ave ROP. Orient TF to 90R. PVT 293bb1s, IA 0 psi, OA 200psi Drill to 12569' with 80 - 87R TF, 2.75/2.75bpm, FS at 2800psi, 3150/3500psi, 3k WOB & 102fph ROP. Orient and Drill to 12585' with 110 - 1138 TF, 2.7512.75bpm, FS at 2800psi, 3300/3700psi, 3 - 5k WOB & 105 - 150fph ROP. Wiper Trip to shoe, RBIH to btm, DnWt 14k Orient TF to 43R. PVT 289bb1s, IA 0 psi, OA 242psi Drill to 12605' with 22R TF, 2.75/2.75bpm, FS at 2800psi, 3325l3700psi, 3k WOB & 100fph ROP. Orient and Drill to 12665' with 66 - 101 R TF, 2.75/2.75bpm, FS at 2800psi, 3160/3549psi, 1.6k WOB & 69fph ROP. Orient and Drill to 12695' with 130 - 160R TF, 2.75/2.75bpm, FS at 2800psi, 3300/3650psi, 3k WOB & 112fph ROP. Orient TF around to 78R Dri1{ to 12700' with 95 - 84R TF, 2.80/2.91 bpm, FS at 2800psi, 3280/3625psi, 2k WOB & 125fph ROP. 12700' had several mtr stalls w/ one overpull to 52k. Wiper trip to 11540' below OHST RIH to btm, PVT 278bb1s, DnWt 14k, UpWt 37k Drill to 12739' with 95 - 84R TF, 2.85/2.93bpm, FS at 2900psi, 3250/3600psi, 2-3k WOB & 50 - 140fph ROP. 12700' had several mtr stalls before able to drill after wiper trip. Drlg ratty formation w/ IROP of 25 to 179fph. Overpulls of 50-60k each time PU off btm Orient TF around to 45R, rolled to 151 R Drill to 12744', TF rolled f! 45R to 151 R, 2.85/2.93bpm, FS at 2900psi, 3250/3600psi, 2-3k WOB & 122fph ROP. Orient TF around to 15R Drill to 12750', TF at 46R, 2.85/2.93bpm, FS at 2970psi, 3300/3670psi, 2-3k WOB & 120fph ROP. Orient TF at 75R, Drill to 12795' w/ TF at 92R, 2.85/2.93bpm, FS at 2970psi, 3370/3720psi, 2 -3k WOB & 107fph ROP, drlg ratty formation, mtr stalling out, overpulls of 45 to 55k Wiper Trip to above shoe at 10825' Log down w/ GR f/ 10825' to 10850', tie-in correction +9' RBIH to btm, DnWt 14k Orient TF around to 10R Drill to 12841' with 35R TF, 2.55/2.55bpm, 2850/3050psi, 3k WOB & 100fph ave ROP. Orient & drill to 12855' with 70R TF, 2.55/2.55bpm, 2850/3050psi, 3k WOB & 100fph ave ROP. Orient & drill to 12919' with 105-135R TF, 2.55/2.55bpm, 2850/3050psi, 3k WOB & 100fph ave ROP. Shoot off btm survey. Orient TF to 130L. Drill to 12949' with 90-120L TF, 2.55/2.55bpm, 2850l3050psi, 3k WOB & 90fph ave ROP. Printed: 6/14/2006 11:03:40 AM BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 5-36 5-36 REENTE NORDIC NORDIC Hours R+COM CALIST 1 Task PLET A Code E NPT 8/5/2006 00:00 - 00:15 0.25 CASE P 00:15 - 02:15 2.00 CASE P 02:15 - 03:00 0.75 CASE P 03:00 - 03:15 0.25 CEMT P 03:15 - 05:15 2.00 CEMT P 05:15 - 07:00 1.75 CEMT P 07:00 - 07:15 0.25 CEMT P 07:15 - 10:25 3.17 EVAL P 10:25 - 11:50 1.42 EVAL P 11:50 - 13:50 2.00 EVAL P 13:50 - 15:20 1.50 EVAL P 15:20 - 16:15 0.92 EVAL P 16:15 - 17:10 0.92 EVAL P 17:10 - 18:30 1.33 EVAL P 18:30 - 19:00 0.50 EVAL P 19:00 - 19:15 0.25 EVAL P 19:15 - 20:30 1.25 EVAL P 20:30 - 20:45 0.25 EVAL P 20:45 - 21:00 0.25 EVAL P 21:00 - 21:30 0.50 EVAL P Spud Date: 9/14/2001 Start: 7/11/2006 End: 8/9/2006 Rig Release: 8/9/2006 Rig Number: N1 Phase Description of Operations RUNPRD Slow down pumps to 0.80bpm/1540psi @ 40bbls away. Ball on seat ~ 47bbls. Pressure up to 4250psi & release CTLRT. P/U ~ 29k & confirm release. RUNPRD Circ well to 2% KCL water with double friction reducer ~ 2.8/2.8bpm & 2850psi. Send used FloPro to MI for reconditioning. Meanwhile R!U SLB cementers. RUNPRD Load balance KCL into pits & mix KCL-bio displacement pill. Meanwhile continue circulating KCL ~ 1.4/1.3bpm & 400psi. RUNPRD PJSM with all personnel concerning cementing operations. Continue circulating 2% KCL ~ 1.37/1.27bpm & 300psi. RUNPRD Batch mix 34bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt ~ 04:05hrs. Flush/PT lines to 4k. Pump 32.6bbls cmt slurry C~ 2.02/1.92bpm & 1400psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 30bbls bio-KCL ~ 2.86/2.79bpm & 2070psi. Slow down pumps to 1.40bpm/520psi ~ 50bbls. CTW P engage LW P ~ 55.5bbls away. Shear plug with 3100psi. Continue displacing LWP ~ 2.58/2.45bpm, 2580psi & bump ~ 71.4bbls away with 1000psi over. Bleed off & check floats -held. Pressure up to 500psi & sting out of liner. 31.2bbls cmt pumped around shoe. CIP 05:15hrs. RUNPRD Circ 1 bbl of bio-KCL at 0.5bpm on TOL. POOH to BHA at 100fpm pumping at 0.55bpm to replace CT voidage only. RUNPRD POH w! BHA #18, LD and offload Baker running tool, Recovered 100%, No cement on tools. LOWERI PJSM on P/U &RIH MCNL tools & 1-1/4" CHS tbg., RU Handling tools for 1 1/4" tbg, Initialize & test logging tools, PU MCNL tools to rig floor, MU 2.3" mill, mtr, 2 jts of 1 1/4" CSH, MCNUCCUGR logging tool carrier, XO, lower MHA, RIH w/ 42 stds of 1 1/4" CSH, MU upper MHA and CTC, Stab injector. LOWERI RIH with logging/cleanout BHA #19 to 9700 LOW ER1 Cleanout wellbore at 1.3bpm, tagged cement stringers at 10039', 10051', 10091', 10127' and 10141', wash down to 10250', POH to 10000', log down MCNUCCUGR C~ 30fpm from 9700' to 10329', tag cmt stringer at 10329, 10356', 10419', 10690 -10697', washed down to 10726'. POH to 10300' LOW ER1 Log down MCNUCCUGR at 30fpm from 10300' to 12740', Reciprocate 2x across LSL sub ~ 11366' w/ 1.5bpm, Pumped 20 bbls of pert pill LOWERI Tagged cement at 12740', Drill hard cmt f/ 12740' to 12746', WOB 4-6K, 75# of mtr work, pumped 20 bbl pert pill around LOWERI Log up to 12300', flagged EOP at 9577', Log up ~ 60fpm to 9600' LOWERI POOH to logging/cleanout BHA #19 from 9600', S/B injector LOW ER1 OOH. S/B injector. UD upper MHA. Drop 5!8" ball & open up circ sub. B/D CSH with air. RU for R/B 1-1/4" CSH. LOW ER1 PJSM for R/B CSH. LOWERI R/B 42 stands of 1-1/4" CSH. LOWERI PJSM for UD SWS MCNUCCUGR logging tool. LOW ER1 UD lower MHA, SWS MCNUCCUGR logging tool, X/Os, 2 jts of 1-1/4" CSH, motor & mill. Observe some cmt chips, brass & metal shavings on mill & motor. LOWERI Check log data quality - OK. Download MCNUCCUGR data & Printed: 8/14/2006 11:03:40 AM • BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/11/2006 End: 8/9/2006 Contractor Name: NORDIC CALISTA Rig Release: 8/9/2006 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours Task Code NPT Phase Description of Operations 8/5/2006 21:00 - 21:30 0.50 EVAL P LOWERI fax CNL tog to ANC Geo. ANC Geo agrees not to re-run the CNL log & also OKs preliminary pert picks. From log data, TOL = 10688' & TOC = 12738'. 21:30 - 21:45 0.25 EVAL N DPRB LOWERI PJSM on re-running the cleanout BHA & 1-1/4" CHS tbg. 21:45 - 23:15 1.50 CLEAN N DPRB LOW ER1 M/U cleanout, BHA #20 with 2.30" D331 mill, new 2-1/8" straight motor, Tower MHA, XO, 86jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. 23:15 - 00:00 0.75 CLEAN N DPRB LOW ER1 RIH with cleanout BHA #20. 8/6/2006 00:00 - 01:10 1.17 CLEAN N DPRB LOW ER1 Continue RIH cleanout BHA #20. Correct CTD by - 23.3' ~ EOP flag. Wash in hole & tag ~ 12740'. 01:10 - 03:00 1.83 CLEAN N DPRB LOW ER1 Attempt to mill with 1.5bpm/2760psi. Stacking wt & not getting any motor work. Swap well to new double-slick 2% KCL. Work string & push down to 12762'. Getting 10k O/pails on P/Us. 03:00 - 03:10 0.17 CLEAN N DPRB LOW ER1 Conduct 100' wiper trip. UP wt = 44k Run-in wt = 14.5k. Getting cement-bio balls over the shaker. 03:10 - 04:20 1.17 CLEAN N DPRB LOWERI Working CT string with 16k WOB & -2.5K CT wt. Getting Intermittent motor-works on set downs. Work string down to 12780'. Lose SLB CTDS. 04:20 - 07:00 2.67 CLEAN N SFAL LOW ER1 Troubleshoot SLB data sensors -CTDS not showing correct CT wt, WOB, Depth, Pump rates & pressures. W.O. SLB Electric Tech. Meanwhile circ well @ min rate. SLB electician arrived at 06:30, replaced a bad power supply which converts 12 volts to 5 volts. Computer back online 07:00 - 08:00 1.00 CLEAN N DPRB LOWERI Working CT string with 1.38 bpm, FS at 1857psi, WOB 6-10k, Getting little to no motor-work, milted down to 12781', UP wt 41 k, Dn wt 14.3k 08:00 - 10:10 2.17 CLEAN N DPRB LOWERI POH to BHA # 20, S/B injector 10:10 - 12:00 1.83 CLEAN N DPRB LOWERI POH w/ BHA #20, Drop 5/8" ball & open up circ sub. B/D CSH with air. RU for R/B 1-1/4" CSH, PJSM for R/B CSH, R/B 43 stands of 1-1/4" CSH, LD mtr and mill, mill looked good. pressure test both MHA's and CTC, OK 12:00 - 18:00 6.00 BOPSU P LOW ER1 RU Test equipment, Perform BOPE pressure /function test. AOGCC witness waived by Chuck Shevie, RD test equipment 18:00 - 20:00 2.00 CLEAN N DPRB LOW ER1 PJSM handling cleanout asst' and running 1 1/4" CSH, M/U cleanout BHA #21 with 2.31"junk mill, 2-1/8" straight motor, lower MHA, jar, XO, 86jts of 1-1/4" CSH tbg, XO & upper MHA. M/U Injector. 20:00 - 22:15 2.25 CLEAN N DPRB LOW ER1 RIH cleanout BHA #20. Wash in hole with min rate & tag 12810'. Push down to 12814'. 22:15 - 22:45 0.50 CLEAN N DPRB LOW ER1 Attempt to mill with 1.56bpm/2760psi. Still stacking wt & not getting much motor work. Also over-pulling by 10k on P/Us. Suspect 3-1/8" X/Over is hanging up on cement stringer above the TOL. Review situation with ANC & decide to cleanout above the TOL with 3.80 mill. 22:45 - 00:00 1.25 CLEAN N DPRB LOWERI POOH cleanout BHA#21. 8/7/2006 00:00 - 00:30 0.50 CLEAN N DPRB LOW ER1 Continue POOH cleanout BHA#21. 00:30 - 01:00 0.50 CLEAN N DPRB LOWERI OOH. S/B injector. UD upper MHA. Drop 1/2" ball & open up circ sub. B/D CSH with air. RU for R/B 1-1/4" CSH. 01:00 - 01:15 0.25 CLEAN N DPRB LOWERI PJSM for R/B CSH. 01:15 - 02:30 1.25 CLEAN N DPRB LOW ER1 R/B 43 stands of 1-1/4" CSH & UD cleanout BHA#21. 02:30 - 03:00 0.50 CLEAN P LOW ER1 M/U cleanout BHA #22 with 3.79" D331 mill, 2-7/8" Xtreme motor, XO, 2jts of 2-3/8" PH6 tbg, XO &MHA. M/U Injector. 03:00 - 05:00 2.00 CLEAN P LOWERI RIH cleanout BHA #22. Wash in hole with min rate & tag TOC Printed: 8/14/2006 11:03:40 AM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 7/11 /2006 Rig Release: 8/9/2006 Rig Number: N1 Spud Date: 9/14/2001 End: 8/9/2006 Date From - To ;Hours Task ~ Code --- 8/7/2006 03:00 - 05:00 2.00 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:15 2.25 CLEAN P 08:15 - 08:30 0.25 CLEAN P 08:30 - 11:00 I 2.501 CLEAN I N 11:00 - 11:45 I 0.75 I EVAL I P 11:45 - 13:15 ~ 1.50 ~ EVAL ~ P 13:15 - 15:00 1.75 EVAL P 15:00 - 15:50 0.83 EVAL P 15:50 - 16:35 I 0.751 EVAL I P 16:35 - 18:00 I 1.421 EVAL I P 18:00 - 18:15 I 0.25 I EVAL I P 18:15 - 18:30 0.25 EVAL P 18:30 - 20:45 2.25 EVAL P 20:45 - 21:00 0.25 EVAL P 21:00 - 21:15 0.25 EVAL P 21:15 - 21:40 ~ 0.42 ~ CLEAN ~ P 21:40 - 22:30 I 0.831 EVAL I P 22:30 - 00:00 1.50 EVAL N 8/8/2006 00:00 - 13:00 13.00 EVAL N 13:00 - 14:00 1.00 EVAL P 14:00 - 14:15 0.25 PERFO~ P 14:15 - 15:45 1.50 PERFO P 15:45 - 17:00 1.25 PERFO P 17:00 - 19:00 I 2.001 PERFOBI P NPT ~ Phase Description of Operations LOWERI as expected ~ 10125'. LOW ER1 Mill cement &cleanout tbg with 2.5bpm, 1150/1250psi & 60-90fph ave ROP. Fall thru @ 10145'. Wash in hole ~ 12fpm to TOL tagged ~ 10694'. LOW ER1 POOH to cleanout BHA #22. LOW ER1 POH w/ cleanout BHA #22, std bk 2 3/8" PH-6 tbg, LD motor and mill WAIT LOWERI Consult with Anch office, decided to p/u logging tools on cleanout run, Waiting on SLB, Called out SLB at 08:00 hrs for GR-CCL logging tools LOW ER1 SLB arrived on location, programmed tool, PU to rig floor, Held PJSM, reviewed handling and running procedures LOWERI MU logging/cleanout BHA #22 w/ 2.3" mill, 2 1/8" mtr, 2 jts of 1 1/4" CSH, logging tool carrier w/ CCUGR , XO, lower MHA, RIH w/ 42 stds of 1 1/4" CSH, MU upper MHA and CTC, Stab injector LOWERI RIH with logging/cleanout BHA #22 to 10750' LOWERI cleanout wellbore at 1.3bpm, log down CCUGR @ 60fpm from 10700' to 13248', Pumped 30 bbls of pert pill. LOWERI Log up ~ 60fpm to 10650', flagged EOP at 10500', laid in 30 bbls of pert pill LOWERI POOH to logging/cleanout BHA #22, second EOP flag at 8200', S/B injector LOWERI OOH. S/B injector. UD upper MHA. Drop 5/8" ball & open up circ sub. B/D CSH with air. RU for R/B 1-1/4" CSH. LOWERI PJSM for R/B CSH. LOWERI R/B 42 stands of 1-1/4" CSH. LOWERI PJSM for UD SWS CCUGR logging tool. LOWERI UD lower MHA, SWS CCUGR logging tool, X/Os, 2 jts of 1-1/4" CSH, motor & mill. Check log data quality - OK. From log data, PBTD = 13243.9' & TOL = 10688'. LOWERI SI swab valve. M/U swizzle stick to CT & stab injector on well. Jet BOP stack & surface lines ~ 2.6bpm. S/B injector & UD swizzle stick. LOW ER1 Cement > 2000psi compressive strength. Line up & P/test wellbore via the CT as follows: Time WHP CTP IAP OAP Onset -11 0 0 95 0 2391 2102 0 103 15 2249 1956 0 100 30 2186 1897 0 98 _> Passed: Leaked 8.5% of test pressure in 10 mins. Will not set LTP. WAIT LOWERI S/D operations & W. O. Orders. WAIT LOWERI Continue W. O. Orders. LOW ER1 Receive authority to proceed & pert the well. Call out SLB TCP crew. Prep rig floor to run guns. R/U safety jt. Drift MHAs with 5/8" ball - OK. LOW ER1 PJSM on perforation job. LOWERI M/U 34jts of 2" HSD 6spf 2006PJ guns with CBF firing system. LOWERI M/U lower disconnect, 32 doubles of 1-1/4" CSH tbg & upper MHA. M/U injector. LOWERI RIH with perforating BHA#23 circ 15 bbl FloPro pert pill ahead Printed: 8/14/2006 11:03:40 AM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: 15-36 Common Well Name: 15-36 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date j From - To Hours Task I Code NPT --L- - 1 8/8/2006 17:00 - 19:00 2.00 ~ PERFOB P 19:00 - 22:00 I 3.001 PERFOBI P Spud Date: 9/14/2001 Start: 7/11/2006 End: 8/9/2006 Rig Release: 8/9/2006 Rig Number: N1 Phase ~ Description of Operations LOWERI @ min rate.correct to flag, +5'. RIH. Tag PBTD and correct +5' CTD to 13,244' PBTD. LOWERI Pull up to 13,160'. Insert 5/8" steel ball and displace with New FloPro pert pill, 15 bbls. Circ. ball on seat at 54 bbl. Pull up hole and fire pert guns on depth with bottom shot at 13,150'. Up wt 44K, no overpull. Continue to POH with fired pert guns. PERFORATED INTERVAL: 12,440 - 13,150' BKB. Flow check at top of liner. No flow. POH. Flow check at surface, No flow. 22:00 - 23:00 1.00 PERFO P LOWERI Stand back CSH workstring. 23:00 - 23:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired SWS pert guns. 23:15 - 00:00 0.75 PERFO P LOWERI Lay out fired SWS 2" pert guns. All shots fired. 8/9/2006 00:00 - 01:30 1.50 PERFO LOWERI Lay out 2" SWS fired pert guns. All shots fired. Offload guns from pipe shed. 01:30 - 03:00 1.50 WHSUR POST RIH with nozzle to 2000' and freeze protect 4-1/2" tubing with MEOH. POH. 03:00 - 04:15 1.25 RIGD POST Blow down reel with N2, sent coil volume to tiger tank, no vac trucks available, bleed off pressure. 04:15 - 05:00 0.75 BOPSU POST Nipple down BOPE. 05:00 - 09:30 4.50 BOPSU N WAIT POST Wait on vac truck to empty rig pits. None available at present. Meanwhile inspect & greased injector chains & perform general rig housekeeping. Inspect the "K-spec twin-path" sling for hoisting the injector -failed fiber optics lighting test & will be replaced. 09:30 - 12:00 2.50 RIGD N POST Cleanout pits. Release rig ~ 12:00 Hrs on 8/9/06. Will N/U & PT tree cap after moving rig off well. Printed: 8/14/2006 11:03:40 AM r ~ Halliburton Com an P Y Survey Report Company: BP Amoco L)atc: 8/16/2006 "time: 18:15.52 Pater. Hield: Prudhoe $ay Co-ordinah•i~E) Ketercncc Well: 15-36, True North Site: PB DS 15 ~ crticrl illD) Reference: 15-36B- 64.6 ~~ ell: 15-36 ticctiou (~~,ti~ Reference: Well (0-OON.O OOE90.OONzi) ~~ellpath: 15-36B Sur~ep (:'ulculation Method: Minimum Curvature Db: Oracle Survey MD Incl ~iim TVll S~sl~"0 N/S E/W MapN MapE Tool ft deg deg fi ft ft ft ft ft 33.60 0.00 0.00 33.60 -31.00 0.00 0.00 5960062.30 676824.72 TIE LINE 249.85 0.20 339.87 249.85 185.25 0.35 -0.13 5960062.65 676824.58 MWD 426.85 0.21 288.76 426.85 362.25 0.75 -0.54 5960063.04 676824.16 MWD 517.85 1.02 15.58 517.84 453.24 1.58 -0.48 5960063.87 676824.20 MWD 608.85 2.12 28.14 608.81 544.21 3.85 0.53 5960066.16 676825.16 MWD 696.85 3.33 32.95 696.71 632.11 7.43 2.69 5960069.79 676827.23 MWD 785.85 3.32 30.89 785.56 720.96 11.81 5.41 5960074.23 676829.85 MWD 875.85 3.83 34.28 875.38 810.78 16.53 8.45 5960079.02 676832.77 MWD 965.85 4.89 35.42 965.12 900.52 22.14 12.36 5960084.72 676836.56 MWD 1054.85 5.41 34.74 1053.76 989.16 28.68 16.95 5960091.37 676840.99 MWD 1150.85 5.71 29.14 1149.31 1084.71 36.57 21.86 5960099.37 676845.71 MWD 1246.85 6.49 23.73 1244.77 1180.17 45.71 26.36 5960108.61 676850.00 MWD 1341.85 6.75 21.97 1339.13 1274.53 55.80 30.61 5960118.80 676854.01 MWD 1436.85 7.49 24.77 1433.40 1368.80 66.60 35.30 5960129.71 676858.44 MWD 1530.85 8.13 24.14 1526.53 1461.93 78.23 40.58 5960141.46 676863.45 MWD 1626.85 9.59 21.95 1621.38 1556.78 91.84 46.35 5960155.20 676868.89 MWD 1719.85 10.86 21.30 1712.90 1648.30 107.19 52.43 5960170.69 676874.61 MWD 1816.85 12.93 22.74 1807.81 1743.21 125.71 59.94 5960189.38 676881.68 MWD 1911.85 14.86 23.35 1900.03 1835.43 146.70 68.88 5960210.57 676890.12 MWD 2006.85 17.29 24.74 1991.31 1926.71 170.71 79.62 5960234.83 676900.29 MWD 2102.85 19.92 25.45 2082.28 2017.68 198.44 92.62 5960262.85 676912.64 MWD 2197.85 22.40 27.85 2170.87 2106.27 229.06 108.03 5960293.83 676927.32 MWD 2293.85 24.34 26.06 2258.99 2194.39 263.01 125.27 5960328.17 676943.76 MWD 2389.85 24.89 25.55 2346.27 2281.67 299.01 142.67 5960364.57 676960.31 MWD 2484.85 25.30 26.26 2432.30 2367.70 335.25 160.28 5960401.21 676977.05 MWD 2579.85 24.34 26.06 2518.53 2453.93 371.04 177.86 5960437.40 676993.79 MWD 2674.85 25.85 29.97 2604.56 2539.96 406.57 196.81 5960473.37 677011.90 MWD Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2005 Well: 15-36 Slot Name: WeII Position: +N/-S 1212.31 ft Northing: 5960062.30 ft Latitude: 70 17 47.159 N +E/-W 556.36 ft Easting : 676824.72 ft Longitude: 148 34 4.997 W Position Uncertainty: 0.00 ft Wellpath: 15-366 Drilled From: 15-366PB1 500292248002 Tie-on Depth: 11514.28 ft Current Datum: 15-36B: Height 64.60 ft Above System Datum: Mean Sea Level Magnetic Data: 8/2/2006 Declination: 24.51 deg Field Strength: 57611 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.60 0.00 0.00 90.00 Survey Program for Definitive Wellpath Date: 8/16/2006 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 249.85 10064.81 1 : MWD -Standard (249.85-118 MWD MWD -Standard 10097.00 10949.48 15-36BPB1 MWD+IIFR+MS (10097.0 MWD+IFR+MS MWD +IFR + Multi Station 10949.48 11514.28 15-36BP61 MWD (10949.48-11976. MWD MWD -Standard 11515.00 13258.73 15-366 MWD (11515.00-13258.73) MWD MWD -Standard Halliburton Com an P Y Survey Report Compan}~; Field: Sitr. ~~ dl: ~Fcllpath: BP Amoco Prudhoe Bay PB DS 15 15-36 15-36B Datr. 8/16/2006 Co-ordinate(~E)}Zcfcrence: Fcrtical (TVD) Reference: Section (~'S) Reference: Sure. Calculation Method: 7imc: 18:15-52 Yage: Well: 15-36, True North 15-36B~ 64-6 Well (0-OON.O OOE,9000Azi) Minimum Curvature llb: racle Survey MU Int l Azim 'I~~~U Sys'Iv D N/S ~ H:/~~ MapN ~~~ 11apE Tool ft L deg deg fl ft ft H ft ft 2770. 85 29 .09 31 .25 - 2689 .73 -_ -- 2625. 13 444. 67 219. 38 --- 5960511 .98 677033 .56 _. __ MWD - 2864. 85 31 .19 30 .90 2771 .01 2706. 41 485. 09 243 .73 5960552 .96 677056 .96 MWD 2960. 85 32 .07 27 .71 2852 .76 2788. 16 528. 99 268 .35 5960597 .42 677080 .53 MWD 3056. 85 33 .97 27 .83 2933 .25 2868. 65 575. 27 292 .72 5960644 .27 677103 .81 MWD 3151. 85 35 .16 25 .13 3011 .48 2946. 88 623. 51 316 .73 5960693 .06 677126 .68 MWD 3246. 85 35 .58 23 .64 3088 .95 3024. 35 673. 60 339 .43 5960743 .66 677148 .19 MWD 3341. 85 38 .69 25 .53 3164 .68 3100. 08 725. 72 363 .32 5960796 .33 677170 .84 MWD 3437. 85 41 .43 24 .36 3238 .15 3173. 55 781. 74 389 .36 5960852 .94 677195 .55 MWD 3531. 85 43 .95 26 .50 3307 .24 3242. 64 839. 28 416. 75 5960911 .10 677221 .58 MWD 3628. 85 45 .99 26 .36 3375 .86 3311. 26 900. 67 447 .26 5960973 .18 677250 .63 MWD 3723. 85 46 .30 26 .71 3441 .68 3377. 08 961. 95 477 .86 5961035 .17 677279 .79 MWD 3819. 85 48 .69 25 .81 3506 .54 3441. 94 1025. 42 509 .16 5961099 .35 677309 .58 MWD 3850. 85 48 .70 26 .29 3527 .00 3462. 40 1046. 34 519 .39 5961120 .51 677319 .31 MWD 3974. 28 47 .40 26 .35 3609 .51 3544. 91 1128. 62 560 .09 5961203 .72 677358 .06 MWD 4068. 96 48 .66 23 .87 3672 .83 3608. 23 1192. 36 589 .94 5961268 .13 677386 .41 MWD 4164. 35 50 .67 25 .69 3734 .57 3669. 97 1258. 36 620 .43 5961334 .83 677415 .33 MWD 4259. 67 51 .56 25 .68 3794 .41 3729. 81 1325. 23 652 .59 5961402 .43 677445 .91 MWD 4355. 37 50 .07 24 .39 3854 .88 3790. 28 1392. 43 683 .98 5961470 .35 677475 .71 MWD 4450. 91 49 .95 23 .78 3916 .28 3851. 68 1459. 25 713 .86 5961537 .85 677504 .00 MWD 4546. 44 51 .41 24 .32 3976 .81 3912. 21 1526. 74 743 .98 5961606 .02 677532 .52 MWD 4641. 30 51 .06 25 .06 4036 .20 3971. 60 1593. 94 774 .87 5961673 .93 677561 .83 MWD 4736. 93 50 .82 25 .21 4096 .46 4031. 86 1661. 16 806 .41 5961741 .87 677591 .78 MWD 4831. 94 50 .28 24 .53 4156 .83 4092. 23 1727. 72 837 .27 5961809 .14 677621 .05 MWD 4927. 24 50 .40 24 .51 4217 .66 4153. 06 1794. 47 867 .71 5961876 .58 677649 .92 MWD 5022. 51 50 .35 24 .66 4278 .41 4213. 81 1861. 20 898 .24 5961944 .00 677678 .87 MWD 5117. 91 52 .15 25 .04 4338 .13 4273. 53 1928. 71 929 .51 5962012 .22 677708 .54 MWD 5211. 89 51 .70 25 .95 4396 .08 4331. 48 1995. 49 961 .35 5962079 .73 677738 .80 MWD 5306. 81 51 .98 25 .81 4454 .73 4390. 13 2062. 64 993 .93 5962147 .62 677769 .79 MWD 5402. 24 51 .80 26 .61 4513 .63 4449. 03 2130. 00 1027 .09 5962215 .74 677801 .35 MWD 5497. 73 51 .64 25 .86 4572 .78 4508. 18 2197. 24 1060 .23 5962283 .73 677832 .89 MWD 5594. 11 51 .00 26 .11 4633 .02 4568. 42 2264. 87 1093 .19 5962352 .12 677864 .26 MWD 5689. 31 50 .12 25 .96 4693 .50 4628. 90 2330. 93 1125 .46 5962418 .92 677894 .96 MWD 5785. 31 51 .60 26 .17 4754 .09 4689. 49 2397. 81 1158 .18 5962486 .55 677926 .09 MWD 5878. 23 50 .54 28 .51 4812 .48 4747. 88 2462. 02 1191. 36 5962551 .51 677957 .75 MWD 5975. 68 50 .92 29 .20 4874 .17 4809. 57 2528. 10 1227 .77 5962618 .42 677992 .60 MWD 6071. 26 50 .12 28 .86 4934 .94 4870. 34 2592. 60 1263 .57 5962683 .74 678026 .87 MWD 6166. 54 50 .68 30 .46 4995 .67 4931. 07 2656. 39 1299 .90 5962748 .37 678061 .68 MWD 6261. 42 52 .67 29 .47 5054 .51 4989. 91 2720. 87 1337 .07 5962813 .70 678097 .32 MWD 6356. 93 51 .68 28 .50 5113 .08 5048. 48 2786. 86 1373 .63 5962880 .53 678132 .32 MWD 6452. 36 51 .04 28 .15 5172 .67 5108. 07 2852. 47 1409 .00 5962946 .95 678166 .13 MWD 6547. 42 50 .30 28 .47 5232 .92 5168. 32 2917. 21 1443 .87 5963012 .48 678199 .46 MWD 6641. 78 49 .43 29 .39 5293 .74 5229. 14 2980. 35 1478 .76 5963076 .42 678232 .86 MWD 6735. 65 49 .21 29 .65 5354 .93 5290. 33 3042. 29 1513. 84 5963139 .17 678266 .47 MWD 6831. 20 51 .04 29 .33 5416 .18 5351. 58 3106. 12 1549 .93 5963203 .83 678301 .05 MWD 6926. 18 50 .91 29 .94 5475 .99 5411. 39 3170. 26 1586 .42 5963268 .80 678336 .01 MWD 7020. 69 52 .11 27 .76 5534 .81 5470. 21 3235. 05 1622 .09 5963334 .41 678370 .15 MWD 7116. 13 51 .86 28 .38 5593 .59 5528. 99 3301. 39 1657 .48 5963401 .56 678403 .96 MWD 7211. 75 52 .31 28 .92 5652 .35 5587. 75 3367. 59 1693 .64 5963468 .59 678438 .56 MWD 7305. 81 51 .58 27 .25 5710 .33 5645. 73 3432. 93 1728 .52 5963534 .73 678471 .88 MWD 7401. 15 51 .38 28 .55 5769 .71 5705. 11 3498. 85 1763 .42 5963601 .45 678505 .22 MWD 7495. 97 49 .75 24 .52 5829 .95 5765. 35 3564. 33 1796. 15 5963667 .67 678536 .40 MWD 7592. 14 49 .72 25 .12 5892 .11 5827. 51 3630. 94 1826 .95 5963734 .98 678565 .63 MWD 7685. 90 51 .22 24 .84 5951 .79 5887. 19 3696. 49 1857 .49 5963801 .23 678594 .61 MWD Halliburton Com an • P Y Survey Report Companc : BP Amoco Date: 8/16/2006 ' time: 18:15:52 Page: Field: Prudho e Bay Co-or dinals (.AH:) Kcferrncc: Well: 15-36, Tr ue North ~ Site PB DS 15 1srtieul ('ll 'D) Refersnec 15-36B_ 6=1 .6 ~~ ~~cll: 15- 36 Sectio n (~~S ) Ref erence: Well (O.OON.O. OOE90-OOAzi} ~ Wsllpath: 15- 36B Surve y Calc ulati on Method: Minimum C urv ature Db: Oracle Survcv - - -- MD loc i Azim TVD Sys T~' D \;S E/W -- Maps MapE "fool ft d eg de g ft ft ft ft ft ft 7779. 85 51 .23 24 .16 6010 .62 5946. 02 3763. 13 1887 .86 5963868. 57 678623 .41 MWD 7877. 39 51 .44 23 .68 6071 .56 6006. 96 3832. 75 1918. 74 5963938. 89 678652 .64 MWD 7972. 90 51 .10 24 .17 6131 .32 6066. 72 3900. 86 1948. 96 5964007. 68 678681 .24 MWD 8068. 01 51 .16 24 .77 6191 .01 6126. 41 3968. 26 1979. 63 5964075. 78 678710 .32 MWD 8162. 94 51 .37 25 .54 6250 .41 6185. 81 4035. 28 2011 .11 5964143. 52 678740 .20 MWD 8258. 31 51 .05 23 .60 6310 .16 6245. 56 4102. 88 2042 .01 5964211. 82 678769 .51 MWD 8353. 63 50 .96 24 .06 6370 .14 6305. 54 4170. 65 2071 .95 5964280. 27 678797 .84 MWD 8447. 76 51 .15 24 .39 6429 .30 6364. 70 4237. 41 2101 .99 5964347. 72 678826 .30 MWD 8542. 70 51 .04 23 .60 6488 .93 6424. 33 4304. 91 2132 .03 5964415. 90 678854 .74 MWD 8637. 24 50 .72 24 .26 6548 .58 6483. 98 4371. 95 2161 .78 5964483. 62 678882 .91 MWD 8732. 79 50 .46 23 .14 6609 .24 6544. 64 4439. 54 2191 .45 5964551. 89 678910 .98 MWD 8827. 64 51 .28 26 .75 6669 .11 6604. 51 4506. 23 2222 .49 5964619. 28 678940 .43 MWD 8922. 53 50 .95 26 .57 6728 .68 6664. 08 4572. 24 2255 .63 5964686. 05 678972 .01 MWD 9019. 69 50 .74 26 .31 6790 .03 6725. 43 4639. 70 2289 .18 5964754. 28 679003 .96 MWD 9114. 02 49 .95 25 .70 6850 .23 6785. 63 4704. 97 2321 .02 5964820. 27 679034 .26 MWD 9209. 26 49 .62 26 .04 6911 .72 6847. 12 4770. 41 2352 .75 5964886. 44 679064 .44 MWD 9305. 30 49 .44 24 .56 6974 .06 6909. 46 4836. 46 2383 .98 5964953. 20 679094 .10 MWD 9386. 58 48 .94 26 .53 7027 .18 6962. 58 4891. 96 2410 .50 5965009. 31 679119 .31 MWD 9495. 25 48 .38 24 .94 7098 .96 7034. 36 4965. 45 2445 .93 5965083. 60 679152 .99 MWD 9588. 06 48 .01 27 .00 7160 .83 7096. 23 5027. 64 2476 .22 5965146. 49 679181 .81 MWD 9683. 11 47 .35 26 .20 7224 .83 7160. 23 5090. 48 2507 .68 5965210. 04 679211 .79 MWD 9778. 97 47 .17 28 .04 7289 .89 7225. 29 5153. 14 2539 .77 5965273. 44 679242 .39 MWD 9875. 02 47 .31 28 .34 7355 .10 7290. 50 5215. 30 2573 .09 5965336. 35 679274 .23 MWD 9968. 97 46 .64 27 .84 7419 .20 7354. 60 5275. 89 2605 .43 5965397. 69 679305 .14 MWD 10064. 81 45 .15 29 .36 7485 .90 7421. 30 5336. 31 2638 .36 5965458. 86 679336 .64 MWD 10097. 00 44 .45 29 .06 7508 .75 7444. 15 5356. 11 2649 .43 5965478. 91 679347 .24 MWD+IFR+MS 10134. 05 43 .95 29 .37 7535 .31 7470. 71 5378. 65 2662 .04 5965501. 75 679359 .31 MWD+IFR+MS 10227. 93 40 .42 30 .26 7604 .86 7540. 26 5433. 35 2693 .36 5965557. 16 679389 .34 MWD+IFR+MS 10320. 08 35 .69 31 .31 7677 .40 7612. 80 5482. 15 2722 .40 5965606. 63 679417 .22 . MWD+IFR+MS 10414. 07 29 .37 32 .73 7756 .61 7692. 01 5525. 00 2749 .14 5965650. 10 679442 .94 MWD+IFR+MS 10460. 08 27 .44 35 .25 7797 .08 7732. 48 5543. 15 2761 .36 5965668. 53 679454 .73 MWD+IFR+MS 10508. 49 26 .00 35 .94 7840 .32 7775. 72 5560. 86 2774. 02 5965686. 52 679466 .97 MWD+IFR+MS 10553. 90 25 .79 32 .34 7881 .17 7816. 57 5577. 26 2785 .15 5965703. 18 679477 .71 MWD+IFR+MS 10602. 34 25 .90 31 .97 7924 .76 7860. 16 5595. 14 2796 .39 5965721. 32 679488 .52 MWD+IFR+MS 10648. 11 26 .61 29 .43 7965 .81 7901. 21 5612. 55 2806 .72 5965738. 97 679498 .44 MWD+IFR+MS 10696. 06 26 .39 31 .29 8008 .73 7944. 13 5631. 01 2817 .53 5965757. 67 679508 .81 MWD+IFR+MS 10727. 80 26 .08 31 .38 8037 .20 7972. 60 5642. 99 2824 .83 5965769. 83 679515 .83 MWD+IFR+MS 10758. 96 25 .82 29 .55 8065 .21 8000. 61 5654. 74 2831 .74 5965781. 73 679522 .46 MWD+IFR+MS 10790. 37 25 .21 29 .00 8093 .56 8028. 96 5666. 54 2838 .36 5965793. 69 679528 .80 MWD+IFR+MS 10821. 55 24 .75 32 .42 8121 .83 8057. 23 5677. 86 2845 .08 5965805. 16 679535 .25 MWD+IFR+MS 10852. 70 24 .07 32 .33 8150 .19 8085. 59 5688. 73 2851 .97 5965816. 19 679541 .88 MWD+IFR+MS 10885. 34 23 .62 32 .66 8180 .04 8115. 44 5699. 86 2859 .06 5965827. 48 679548 .71 MWD+-FR+MS 10916. 05 22 .83 33 .57 8208 .27 8143. 67 5710. 01 2865 .67 5965837. 78 679555 .08 MWD+IFR+MS 10949. 48 21 .71 33 .40 8239 .20 8174. 60 5720. 57 2872 .66 5965848. 51 679561 .82 MWD+IFR+MS 11000. 13 21 .88 32 .59 8286 .23 8221. 63 5736. 35 2882 .90 5965864. 51 679571 .68 MWD 11031. 33 24 .61 32 .09 8314 .90 8250. 30 5746. 75 2889 .49 5965875. 07 679578 .02 MWD 11061. 07 26 .81 31 .61 8341 .69 8277. 09 5757. 71 2896 .29 5965886. 19 679584 .57 MWD 11094. 92 27 .25 31 .05 8371 .84 8307. 24 5770. 85 2904 .29 5965899. 51 679592 .25 MWD 11121. 56 24 .70 30 .61 8395 .79 8331. 19 5780. 87 2910 .27 5965909. 66 679598 .00 MWD 11155. 50 21 .03 30 .04 8427 .06 8362. 46 5792. 24 2916 .93 5965921. 20 679604 .39 MWD 11182. 86 21 .88 30 .33 8452 .52 8387. 92 5800. 90 2921 .97 5965929. 96 679609 .22 MWD 11212. 92 24 .52 30 .86 8480 .15 8415. 55 5811. 09 2927 .99 5965940. 29 679615 .00 MWD Halliburton Com an • P Y Survey Report Cumpam field: Sitr. ~bdl: Wdlparh: : BP Amoco Prudhoe Bay PB DS 15 15-36 15-36B ~ ~ Date 8/16/2006 Cu-urdinatc(_Af:) Rcfcreoce: ~~erticul ("I ~~L)) Reference: ficctiun (~~ ti) Reference Surrc~ Calculufion ~lcthud: "fink: 18-15:52 Page: Well: 15-36. True Noith 15-36B~ 64.6 Well (O.OON.O.OOE.90 DOP,zi) Minimum Curvature Db: 4 rade ~ Sur~c~ ~MD Ind Azim TVD Sys 'f VD V'/S Ef~~ ~tapN ~tapE "fool I -- d eg de g ft ft ft ft ft ft 11241 .50 27. 07 29. 28 8505. 88 8441 .28 5821 .85 2934. 22 5965951. 20 679620. 97 MWD 11271 .95 29. 27 34. 03 8532. 72 8468. 12 5834. 07 2941. 77 5965963. 59 679628. 24 MWD 11301 .79 32. 08 33. 32 8558. 39 8493. 79 5846. 74 2950. 21 5965976. 45 679636. 37 MWD 11332 .32 35. 24 34. 38 8583. 79 8519 .19 5860. 78 2959. 64 5965990. 72 679645. 47 MWD 11362 .34 38. 14 31. 04 8607. 87 8543. 27 5875. 88 2969. 31 5966006. 03 679654. 78 MWD 11392 .83 42. 28 30. 33 8631. 15 8566 .55 5892. 81 2979. 35 5966023. 19 679664. 42 MWD 11423 .74 46. 67 32. 27 8653. 20 8588 .60 5911. 30 2990. 61 5966041. 94 679675. 24 MWD 11450 .99 49. 31 33. 85 8671. 43 8606 .83 5928. 26 3001. 66 5966059. 16 679685. 89 MWD 11481 .98 52. 29 38. 07 8691. 02 8626 .42 5947 .68 3015. 77 5966078. 90 679699. 54 MWD 11514 .28 54. 58 43. 87 8710. 28 8645 .68 5967 .24 3032. 78 5966098. 85 679716. 08 MWD 11515 .00 54. 62 43. 97 8710. 69 8646 .09 5967 .66 3033. 19 5966099. 28 679716. 48 MWD 11545 .32 62. 49 48. 46 8726. 50 8661 .90 5985 .51 3051. 87 5966117. 57 679734. 73 MWD 11574 .71 66. 36 52. 46 8739. 19 8674 .59 6002 .36 3072. 31 5966134. 90 679754. 77 MWD 11604 .62 70. 58 56. 23 8750. 17 8685 .57 6018 .56 3094. 92 5966151. 62 679776. 99 MWD 11637 .00 74. 00 60. 06 8760. 02 8695 .42 6034. 83 3121. 11 5966168. 50 679802. 79 MWD 11665 .84 75. 78 63. 29 8767. 54 8702 .94 6048. 03 3145. 62 5966182. 28 679826. 98 MWD 11696 .95 80. 51 67. 25 8773. 93 8709 .33 6060. 76 3173. 27 5966195. 65 679854. 32 MWD 11727 .26 85. 60 70. 06 8777. 60 8713 .00 6071 .70 3201. 28 5966207. 24 679882. 06 MWD 11772 .11 88. 99 83. 92 8779. 72 8715 .12 6081 .75 3244. 82 5966218. 32 679925. 35 MWD 11801 .95 90. 84 89. 56 8779. 77 8715 .17 6083 .45 3274. 60 5966220. 71 679955. 08 MWD 11836 .54 90. 40 96. 43 8779. 39 8714 .79 6081 .64 3309. 12 5966219. 72 679989. 63 MWD 11865 .11 89. 52 103. 30 8779. 41 8714 .81 6076 .75 3337. 25 5966215. 49 680017. 86 MWD 11893 .97 90. 48 108. 59 8779. 41 8714 .81 6068 .82 3364. 99 5966208. 22 680045. 78 MWD 11921 .67 93. 72 114. 41 8778. 40 8713 .80 6058 .69 3390. 73 5966198. 69 680071. 75 MWD 11966 .52 94. 45 121. 10 8775. 20 8710 .60 6037 .87 3430. 29 5966178. 81 680111. 79 MWD 12002 .68 90. 22 121. 98 8773. 73 8709 .13 6018 .97 3461. 08 5966160. 65 680143. 01 MWD 12033 .45 90. 66 119. 34 8773. 49 8708 .89 6003 .28 3487. 54 5966145. 58 680169. 84 MWD 12066 .45 90. 40 114. 93 8773. 18 8708 .58 5988. 24 3516. 90 5966131. 23 680199. 54 MWD 12097 .38 91. 54 112. 11 8772. 66 8708 .06 5975. 90 3545. 26 5966119. 56 680228. 18 MWD 12126 .79 90. 48 107. 35 8772. 14 8707 .54 5965. 97 3572. 93 5966110. 30 680256. 07 MWD 12156 .88 89. 34 104. 89 8772. 19 8707 .59 5957. 62 3601. 83 5966102. 62 680285. 16 MWD 12185 .93 90. 22 100. 66 8772. 30 8707 .70 5951 .20 3630. 15 5966096. 87 680313. 63 MWD 12223 .49 92. 51 95. 55 8771. 41 8706 .81 5945 .90 3667. 31 5966092. 45 680350. 90 MWD 12257 .26 94. 89 94. 84 8769. 23 8704 .63 5942 .85 3700. 87 5966090. 19 680384. 52 MWD 12287 .07 93. 30 93. 61 8767. 10 8702 .50 5940 .66 3730. 52 5966088. 70 680414. 21 MWD 12318 .03 91. 45 89. 91 8765. 81 8701 .21 5939 .71 3761. 44 5966088. 48 680445. 13 MWD 12354 .97 88. 64 86. 21 8765. 79 8701 .19 5940 .96 3798. 35 5966090. 60 680482. 00 MWD 12386 .06 88. 63 81. 10 8766. 53 8701 .93 5944 .40 3829. 23 5966094. 76 680512. 79 MWD 12415 .19 88. 02 74. 40 8767. 38 8702 .78 5950 .57 3857. 66 5966101. 60 680541. 07 MWD 12444 .11 86. 70 72. 82 8768. 71 8704 .11 5958 .72 3885. 38 5966110. 40 680568. 59 MWD 12479 .28 86. 43 68. 06 8770. 82 8706 .22 5970. 47 3918. 45 5966122. 92 680601. 37 MWD 12512 .09 86. 43 59. 25 8772. 87 8708 .27 5984. 99 3947. 77 5966138. 13 680630. 33 MWD 12542 .02 85. 02 57. 13 8775. 10 8710 .50 6000. 72 3973. 13 5966154. 45 680655. 32 MWD 12580 .90 85. 73 64. 89 8778. 24 8713 .64 6019 .49 4007. 00 5966174. 00 680688. 74 MWD 12612 .47 89. 34 68. 41 8779. 60 8715 .00 6031 .98 4035. 95 5966187. 18 680717. 38 MWD 12642 .87 90. 84 75. 64 8779. 55 8714 .95 6041 .36 4064. 84 5966197. 23 680746. 05 MWD 12673 .24 90. 57 80. 39 8779. 17 8714 .57 6047 .66 4094. 54 5966204. 23 680775. 59 MWD 12702 .15 88. 55 83. 39 8779. 40 8714 .80 6051 .74 4123. 16 5966208. 98 680804. 10 MWD 12731 .64 86. 96 87. 97 8780. 55 8715 .95 6053 .96 4152. 53 5966211. 89 680833. 41 MWD 12759 .46 86. 78 92. 02 8782. 07 8717 .47 6053 .96 4180. 30 5966212. 54 680861. 17 MWD 12795 .57 87. 05 99. 07 8784. 02 8719 .42 6050 .48 4216. 17 5966209. 91 680897. 11 MWD 12828 .48 91. 63 103. 65 8784. 40 8719 .80 6044 .00 4248. 42 5966204. 19 680929. 49 MWD 12862 .72 95. 59 106. 30 8782. 24 8717 .64 6035 .17 4281. 42 5966196. 14 680962. 69 MWD Halliburton Com an P Y Survey Report Comp:mc: BP Amoco Nield: Prudhoe Bay Site: PB DS 15 Well: 15-36 W'ellpath: 15-36B Survey ~ - Mll Incl Azim TVD ft deg deg ft 12900.07 91.81 111.05 8779.83 12939.26 88.19 111.05 8779.83 12968.54 87.93 107.35 8780.82 12995.81 90.13 104.89 8781.28 13026.08 90.93 99.07 8781.00 13060.06 90.21 93.93 8780.66 13094.88 90.75 91.85 8780.37 13123.25 92.01 86.45 8779.69 13153.75 91.45 81.98 8778.77 13191.09 90.84 77.93 8778.02 13220.31 90.40 72.11 8777.70 13258.73 88.28 67.71 8778.15 13285.00 88.28 67.71 8778.94 Svs "h~ I~ N/S n Date: 8116/200ri Time: 18:15:52 Pakc: 5 Cu-ordinatc~NL) fiefereoce: Well: 15-36, True North ~crtic~l 1~1 ~ D) Reference: 15-36B~ 64.6 tiectiun (~'S) Reference: Well (O.OON.O OOE.90-OOAzi) Survcs C~Iculation Method: Minimum Curvature I)b: Oracle 8715.23 6023.24 8715.23 6009.17 8716.22 5999.55 8716.68 5991.98 8716.40 5985.70 8716.06 5981.85 8715.77 5980.10 8715.09 5980.52 8714.17 5983.59 8713.42 5990.10 8713.10 5997.65 8713.55 6010.84 8714.34 6020.80 E/~F 11.~p~ ft ft 4316.71 5966185.04 4353.28 5966171.84 4380.91 5966162.87 4407.10 5966155.92 4436.70 5966150.33 4470.45 5966147.28 4505.22 5966146.35 4533.57 5966147.44 4563.89 5966151.22 4600.64 5966158.59 4628.85 5966166.80 4664.92 5966180.84 4689.22 5966191.37 ~tapE Tool ft 680998.25 MWD 681035.14 MWD 681062.99 MWD 681089.35 MWD 681119.08 MWD 681152.91 MWD 681187.71 MWD 681216.04 MWD 681246.28 MWD 681282.87 MWD 681310.89 MWD 681346.64 MWD 681370.69 PROJECTED ' • Halliburton Company Survey Report Company: BP Amoco Date: 811 6120 0 6 Time: 17:57.19 Pa~;c: 1 Field: Prudhoe Bay C'o-ordinate(!VE) Reference: Well: 15-36, Tru e North Sire: PB DS 15 ~~crtical (TVD) Re ference: 15-36B: 64.6 ~~ell: 15-36 ,Section (VS) Refer ence: Well (O.OON.O.O OE,90-OOAzi) ~~ellpath: 15-36BP61 Sur~e~ Calculatio n Method: Minimum Curva ture Ub: Oracle Survey - - MD Inc! Azim - ---- TVD ----- Sys TVD --------- N!S ElW --- MapN MapE Tool -l _ft _ __ deg deg ft ft ft ft ft ft J 33.60 0.00 0.00 33.60 -31.00 0.00 0.00 5960062,30 676824.72 TIE LINE 249.85 0.20 339.87 249.85 185.25 0.35 -0.13 5960062.65 676824.58 MWD 426.85 0.21 288.76 426.85 362.25 0.75 -0.54 5960063.04 676824.16 MWD 517.85 1.02 15.58 517.84 453.24 1.58 -0.48 5960063.87 676824.20 MWD 608.85 2.12 28.14 608.81 544.21 3.85 0.53 5960066.16 676825.16 MWD 696.85 3.33 32.95 696.71 632.11 7.43 2.69 5960069.79 676827.23 MWD 785.85 3.32 30.89 785.56 720.96 11.81 5.41 5960074.23 676829.85 MWD 875.85 3.83 34.28 875.38 810.78 16.53 8.45 5960079.02 676832.77 MWD 965.85 4.89 35.42 965.12 900.52 22.14 12.36 5960084.72 676836.56 MWD 1054.85 5.41 34.74 1053.76 989.16 28.68 16.95 5960091.37 676840.99 MWD 1150.85 5.71 29.14 1149.31 1084.71 36.57 21.86 5960099.37 676845.71 MWD 1246.85 6.49 23.73 1244.77 1180.17 45.71 26.36 5960108.61 676850.00 MWD 1341.85 6.75 21.97 1339.13 1274.53 55.80 30.61 5960118.80 676854.01 MWD 1436.85 7.49 24.77 1433.40 1368.80 66.60 35.30 5960129.71 676858.44 MWD 1530.85 8.13 24.14 1526.53 1461.93 78.23 40.58 5960141.46 676863.45 MWD 1626.85 9.59 21.95 1621.38 1556.78 91.84 46.35 5960155.20 676868.89 MWD 1719.85 10.86 21.30 1712.90 1648.30 107.19 52.43 5960170.69 676874.61 MWD 1816.85 12.93 22.74 1807.81 1743.21 125.71 59.94 5960189.38 676881.68 MWD 1911.85 14.86 23.35 1900.03 1835.43 146.70 68.88 5960210.57 676890.12 MWD 2006.85 17.29 24.74 1991.31 1926.71 170.71 79.62 5960234.83 676900.29 MWD 2102.85 19.92 25.45 2082.28 2017.68 198.44 92.62 5960262.85 676912.64 MWD 2197.85 22.40 27.85 2170.87 2106.27 229.06 108.03 5960293.83 676927.32 MWD 2293.85 24.34 26.06 2258.99 2194.39 263.01 125.27 5960328.17 676943.76 MWD 2389.85 24.89 25.55 2346.27 2281.67 299.01 142.67 5960364.57 676960.31 MWD 2484.85 25.30 26.26 2432.30 2367.70 335.25 160.28 5960401.21 676977.05 MWD 2579.85 24.34 26.06 2518.53 2453.93 371.04 177.86 5960437.40 676993.79 MWD 2674.85 25.85 29.97 2604.56 2539.96 406.57 196.81 5960473.37 677011.90 MWD 2770.85 29.09 31.25 2689.73 2625.13 444.67 219.38 5960511.98 677033.56 MWD Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 15-36 Slot Name: Well Position: +N/-S 1212.31 ft Northing: 5960062.30 ft Latitude: 70 17 47.159 N +E/-W 556.36 ft Easting : 676824.72 ft Longitude: 148 34 4.997 W Position Uncertainty: 0.00 ft Wellpath: 15-366PB1 Drilled From: 15-36 500292248071 Tie-on Depth: 10064.81 ft Current Datum: 15-36B: Height 64.60 ft Above System Datum: Mean Sea Level Magnetic Data: 7!12/2006 Declination: 24.53 deg Field Strength: 57611 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.60 0.00 0.00 90.00 Survey Program for DeTinitive Wellpath Date: 8/16/2006 Validated: Yes Version: 8 Actual From To Survey Toolcode Tool Name ft ft 249.85 10064.81 1 : MWD -Standard (249.85-118 MWD MWD -Standard 10097.00 10949.48 15-366P61 MWD+IIFR+MS (10097.0 MWD+IFR+MS MWD +IFR + Multi Station 10949.48 11976.12 15-366P61 MWD (10949.48-11976. MWD MWD -Standard Halliburton Com an P Y Survey Report Cumpan~: Hield: Site: 1Vcll: Wcllpath: BP Amoco Prudhoe Bay PB DS 15 15-36 15-368PB1 Date: 8/16/2006 Co-ordinate(IVE) Rci`ercnce Vertical (TVD) Reference Section (VS) Reference: Survey Calculation ~lekhutl; Time: 17~5Z99 Pagr. 2 Well: 15-36, True North 15-36B 64.6 Well (O.OON,O.OOE,90.OOAzi) Minimum Curvature Db: Oracle Surccc ~1U Int l ~iim TVD Scs'I~'D N/S E/W ____- MapN -- ~tapE 7on1 fl deg deg ft ft ft ft ft ft 2864. 85 31. 19 30. 90 2771. 01 2706. 41 485 .09 243. 73 5960552 .96 677056. 96 MWD 2960. 85 32. 07 27. 71 2852. 76 2788. 16 528 .99 268. 35 5960597 .42 677080. 53 MWD 3056. 85 33. 97 27. 83 2933. 25 2868. 65 575 .27 292. 72 5960644 .27 677103. 81 MWD 3151. 85 35. 16 25. 13 3011. 48 2946. 88 623 .51 316. 73 5960693 .06 677126. 68 MWD 3246. 85 35. 58 23. 64 3088. 95 3024. 35 673 .60 339. 43 5960743 .66 677148. 19 MWD 3341. 85 38. 69 25. 53 3164. 68 3100. 08 725 .72 363. 32 5960796 .33 677170. 84 MWD 3437. 85 41. 43 24. 36 3238. 15 3173. 55 781 :74 389. 36 5960852 .94 677195. 55 MWD 3531. 85 43 .95 26. 50 3307. 24 3242. 64 839 .28 416. 75 5960911 .10 677221. 58 MWD 3628. 85 45 .99 26. 36 3375. 86 3311. 26 900 .67 447. 26 5960973 .18 677250. 63 MWD 3723, 85 46 .30 26. 71 3441. 68 3377. 08 961 .95 477. 86 5961035 .17 677279. 79 MWD 3819. 85 48 .69 25. 81 3506. 54 3441. 94 1025 .42 509. 16 5961099 .35 677309. 58 MWD 3850. 85 48 .70 26. 29 3527. 00 3462. 40 1046 .34 519. 39 5961120 .51 677319. 31 MWD 3974. 28 47 .40 26. 35 3609. 51 3544. 91 1128 .62 560. 09 5961203 .72 677358. 06 MWD 4068. 96 48. 66 23. 87 3672. 83 3608. 23 1192 .36 589. 94 5961268 .13 677386. 41 MWD 4164. 35 50. 67 25. 69 3734. 57 3669. 97 1258 .36 620. 43 5961334 .83 677415. 33 MWD 4259. 67 51. 56 25. 68 3794. 41 3729. 81 1325 .23 652. 59 5961402 .43 677445. 91 MWD 4355. 37 50 .07 24. 39 3854. 88 3790. 28 1392 .43 683. 98 5961470 .35 677475. 71 MWD 4450. 91 49 .95 23. 78 3916. 28 3851. 68 1459 .25 713. 86 5961537 .85 677504. 00 MWD 4546. 44 51 .41 24. 32 3976. 81 3912. 21 1526 .74 743. 98 5961606 .02 677532. 52 MWD 4641. 30 51 .06 25. 06 4036. 20 3971. 60 1593 .94 774. 87 5961673 .93 677561. 83 MWD 4736. 93 50 .82 25. 21 4096. 46 4031. 86 1661 .16 806. 41 5961741 .87 677591. 78 MWD 4831. 94 50 .28 24. 53 4156. 83 4092. 23 1727 .72 837. 27 5961809 .14 677621. 05 MWD 4927. 24 50 .40 24. 51 4217. 66 4153. 06 1794 .47 867. 71 5961876 .58 677649. 92 MWD 5022. 51 50 .35 24. 66 4278. 41 4213. 81 1861 .20 898. 24 5961944 .00 677678. 87 MWD 5117. 91 52 .15 25. 04 4338. 13 4273. 53 1928 .71 929. 51 5962012 .22 677708. 54 MWD 5211. 89 51 .70 25. 95 4396. 08 4331. 48 1995 .49 961. 35 5962079 .73 677738. 80 MWD 5306. 81 51 .98 25. 81 4454. 73 4390. 13 2062 .64 993. 93 5962147 .62 677769. 79 MWD 5402. 24 51. 80 26. 61 4513. 63 4449. 03 2130 .00 1027. 09 5962215 .74 677801. 35 MWD 5497. 73 51. 64 25. 86 4572. 78 4508. 18 2197 .24 1060. 23 5962283 .73 677832. 89 MWD 5594. 11 51. 00 26. 11 4633. 02 4568. 42 2264 .87 1093. 19 5962352 .12 677864. 26 MWD 5689. 31 50. 12 25. 96 4693. 50 4628. 90 2330 .93 1125. 46 5962418 .92 677894. 96 MWD 5785. 31 51. 60 26. 17 4754. 09 4689. 49 2397 .81 1158. 18 5962486 .55 677926. 09 MWD 5878. 23 50 .54 28. 51 4812. 48 4747. 88 2462 .02 1191. 36 5962551 .51 677957. 75 MWD 5975. 68 50 .92 29. 20 4874. 17 4809. 57 2528 .10 1227. 77 5962618 .42 677992. 60 MWD 6071. 26 50 .12 28. 86 4934. 94 4870. 34 2592 .60 1263. 57 5962683 .74 678026. 87 MWD 6166. 54 50 .68 30. 46 4995. 67 4931. 07 2656 .39 1299. 90 5962748 .37 678061. 68 MWD 6261. 42 52 .67 29. 47 5054. 51 4989. 91 2720 .87 1337. 07 5962813 .70 678097. 32 MWD 6356. 93 51 .68 25. 50 5113. 08 5048. 48 2786 .86 1373. 63 5962880 .53 678132. 32 MWD 6452. 36 51 .04 28. 15 5172. 67 5108. 07 2852 .47 1409. 00 5962946 .95 678166. 13 MWD 6547. 42 50 .30 28. 47 5232. 92 5168. 32 2917 .21 1443. 87 5963012 .48 678199. 46 MWD 6641. 78 49 .43 29. 39 5293. 74 5229. 14 2980 .35 1478. 76 5963076 .42 678232. 86 MWD 6735. 65 49 .21 29. 65 5354. 93 5290. 33 3042 .29 1513. 84 5963139 .17 678266. 47 MWD 6831. 20 51. 04 29. 33 5416. 18 5351. 58 3106 .12 1549. 93 5963203 .83 678301. 05 MWD 6926. 18 50. 91 29. 94 5475. 99 5411. 39 3170 .26 1586. 42 5963268 .80 678336. 01 MWD 7020. 69 52 .11 27. 76 5534. 81 5470. 21 3235 .05 1622. 09 5963334 .41 678370. 15 MWD 7116. 13 51 .86 28. 38 5593. 59 5528. 99 3301 .39 1657. 48 5963401 .56 678403. 96 MWD 7211. 75 52 .31 28. 92 5652. 35 5587. 75 3367 .59 1693. 64 5963468 .59 678438. 56 MWD 7305. 81 51 .58 27. 25 5710. 33 5645. 73 3432 .93 1728. 52 5963534 .73 678471. 88 MWD 7401. 15 51 .38 28. 55 5769. 71 5705. 11 3498 .85 1763. 42 5963601 .45 678505. 22 MWD 7495. 97 49 .75 24. 52 5829. 95 5765. 35 3564 .33 1796. 15 5963667 .67 678536. 40 MWD 7592. 14 49 .72 25. 12 5892. 11 5827. 51 3630 .94 1826. 95 5963734 .98 678565. 63 MWD 7685. 90 51 .22 24. 84 5951. 79 5887. 19 3696 .49 1857. 49 5963801 .23 678594. 61 MWD w Halliburton Com an p Y Survey Report Companc Ficki: Site: Nell: Wellpath: : BP AmoCO Prudhoe Bay. PB DS 15 15-36 15-36BP61 Uate: S116/200n Cu-nrdinah•(~P~) Reference: Vertical Il~~ll) Reference: .Section (VS) Reference: Sunet Calculation Mekl,od: Time: 175219 Page: 3 Well: 15-36, True North 15-36B- 64-6 Well (O.OON,O.OOE,90-OOAzi) Minimum Curvature Un: oracle ~ Sure ev - - --- Ml) Inc 1 Azim TVD Sys T~'n N/S ElW MapN MapE; Tool tt dey deg ft ft ft ft ft ft 7779. 85 51 .23 24 .16 6010 .62 5946. 02 3763. 13 1887. 86 5963868 .57 678623 .41 MWD 7877. 39 51 .44 23 .68 6071 .56 6006. 96 3832. 75 1918. 74 5963938 .89 678652 .64 MWD 7972. 90 51 .10 24 .17 6131 .32 6066. 72 3900. 86 1948. 96 5964007 .68 678681 .24 MWD 8068. 01 51 .16 24 .77 6191 .01 6126. 41 3968. 26 1979. 63 5964075 .78 678710 .32 MWD 8162. 94 51 .37 25 .54 6250 .41 6185. 81 4035. 28 2011. 11 5964143 .52 678740 .20 MWD 8258. 31 51 .05 23 .60 6310 .16 6245. 56 4102. 88 2042. 01 5964211 .82 678769 .51 MWD 8353. 63 50 .96 24 .06 6370 .14 6305. 54 4170. 65 2071. 95 5964280 .27 678797 .84 MWD 8447. 76 51 .15 24 .39 6429 .30 6364. 70 4237. 41 2101. 99 5964347 .72 678826 .30 MWD 8542. 70 51 .04 23 .60 6488 .93 6424. 33 4304. 91 2132. 03 5964415 .90 678854 .74 MWD 8637. 24 50 .72 24 .26 6548 .58 6483. 98 4371. 95 2161. 78 5964483 .62 678882 .91 MWD 8732. 79 50 .46 23 .14 6609 .24 6544. 64 4439. 54 2191. 45 5964551 .89 678910 .98 MWD 8827. 64 51 .28 26 .75 6669 .11 6604. 51 4506. 23 2222. 49 5964619 .28 678940 .43 MWD 8922. 53 50 .95 26 .57 6728 .68 6664. 08 4572. 24 2255. 63 5964686 .05 678972 .01 MWD 9019. 69 50 .74 26 .31 6790 .03 6725. 43 4639. 70 2289. 18 5964754 .28 679003 .96 MWD 9114. 02 49 .95 25 .70 6850 .23 6785. 63 4704. 97 2321. 02 5964820 .27 679034 .26 MWD 9209. 26 49 .62 26 .04 6911 .72 6847. 12 4770. 41 2352. 75 5964886 .44 679064 .44 MWD 9305. 30 49 .44 24 .56 6974 .06 6909. 46 4836. 46 2383. 98 5964953 .20 679094 .10 MWD 9386. 58 48 .94 26 .53 7027 .18 6962. 58 4891. 96 2410. 50 5965009 .31 679119 .31 MWD 9495. 25 48 .38 24 .94 7098 .96 7034. 36 4965. 45 2445. 93 5965083 .60 679152 .99 MWD 9588. 06 48 .01 27 .00 7160 .83 7096. 23 5027. 64 2476. 22 5965146 .49 679181 .81 MWD 9683. 11 47 .35 26 .20 7224 .83 7160. 23 5090. 48 2507. 68 5965210 .04 679211 .79 MWD 9778. 97 47 .17 28 .04 7289 .89 7225. 29 5153. 14 2539. 77 5965273 .44 679242 .39 MWD 9875. 02 47 .31 28 .34 7355 .10 7290. 50 5215. 30 2573. 09 5965336 .35 679274 .23 MWD 9968. 97 46 .64 27 .84 7419 .20 7354. 60 5275. 89 2605. 43 5965397 .69 679305 .14 MWD 10064. 81 45 .15 29 .36 7485 .90 7421. 30 5336. 31 2638. 36 5965458 .86 679336 .64 MWD 10097. 00 44 .45 29 .06 7508 .75 7444. 15 5356. 11 2649. 43 5965478 .91 679347 .24 MWD+IFR+MS 10134. 05 43 .95 29 .37 7535 .31 7470. 71 5378. 65 2662. 04 5965501 .75 679359 .31 MWD+IFR+MS 10227. 93 40 .42 30 .26 7604 .86 7540. 26 5433. 35 2693. 36 5965557 .16 679389 .34 MWD+IFR+MS 10320. 08 35 .69 31 .31 7677 .40 7612. 80 5482. 15 2722. 40 5965606 .63 679417 .22 MWD+IFR+MS 10414. 07 29 .37 32 .73 7756 .61 7692. 01 5525. 00 2749. 14 5965650 .10 679442 .94 MWD+IFR+MS 10460. 08 27 .44 35 .25 7797 .08 7732. 48 5543. 15 2761. 36 5965668 .53 679454 .73 MWD+IFR+MS 10508. 49 26 .00 35 .94 7840 .32 7775. 72 5560. 86 2774. 02 5965686 .52 679466 .97 MWD+IFR+MS 10553. 90 25 .79 32 .34 7881 .17 7816. 57 5577. 26 2785. 15 5965703 .18 679477 .71 MWD+IFR+MS 10602. 34 25 .90 31 .97 7924 .76 7860. 16 5595. 14 2796. 39 5965721 .32 679488 .52 MWD+IFR+MS 10648. 11 26 .61 29 .43 7965 .81 7901. 21 5612. 55 2806. 72 5965738 .97 679498 .44 MWD+IFR+MS 10696. 06 26 .39 31 .29 8008 .73 7944. 13 5631. 01 2817. 53 5965757 .67 679508 .81 MWD+IFR+MS 10727. 80 26 .08 31 .38 8037 .20 7972. 60 5642. 99 2824. 83 5965769 .83 679515 .83 MWD+IFR+MS 10758. 96 25 .82 29 .55 8065 .21 8000. 61 5654. 74 2831. 74 5965781 .73 679522 .46 MWD+IFR+MS 10790. 37 25 .21 29 .00 8093 .56 8028. 96 5666. 54 2838. 36 5965793 .69 679528 .80 MWD+IFR+MS 10821. 55 24 .75 32 .42 8121 .83 8057. 23 5677. 86 2845. 08 5965805 .16 679535 .25 MWD+IFR+MS 10852. 70 24 .07 32 .33 8150. 19 8085. 59 5688. 73 2851. 97 5965816 .19 679541 .88 MWD+IFR+MS 10885. 34 23 .62 32 .66 8180 .04 8115. 44 5699. 86 2859. 06 5965827 .48 679548 .71 MWD+IFR+MS 10916. 05 22 .83 33 .57 8208 .27 8143. 67 5710. 01 2865. 67 5965837 .78 679555 .08 MWD+IFR+MS 10949. 48 21 .71 33 .40 8239 .20 8174. 60 5720. 57 2872. 66 5965848 .51 679561 .82 MWD+IFR+MS 11000. 13 21 .88 32 .59 8286 .23 8221. 63 5736. 35 2882. 90 5965864 .51 679571 .68 MWD 11031. 33 24 .61 32 .09 8314 .90 8250. 30 5746. 75 2889. 49 5965875 .07 679578 .02 MWD 11061. 07 26 .81 31 .61 8341 .69 8277. 09 5757. 71 2896. 29 5965886 .19 679584 .57 MWD 11094. 92 27 .25 31 .05 8371 .84 8307. 24 5770. 85 2904. 29 5965899 .51 679592 .25 MWD 11121. 56 24 .70 30 .61 8395 .79 8331. 19 5780. 87 2910. 27 5965909 .66 679598 .00 MWD 11155. 50 21 .03 30 .04 8427 .06 8362. 46 5792. 24 2916. 93 5965921 .20 679604 .39 MWD 11182. 86 21 .88 30 .33 8452 .52 8387. 92 5800. 90 2921. 97 5965929 .96 679609 .22 MWD 11212. 92 24 .52 30 .86 8480 .15 8415. 55 5811. 09 2927. 99 5965940 .29 679615 .00 MWD 11241. 50 27 .07 29 .28 8505 .88 8441. 28 5821. 85 2934. 22 5965951 .20 679620 .97 MWD Halliburton Company Survey Report Company: Fidd: Site ~~cll: Wellpath: BP Amoco Prudhoe Bay PB DS 15 15-36 15-3FRFB1 Date: 8/16/2D06 Co-ordinate(\E) Rc(crcnce: ~crtical ~'f~lll }tePcrcnce: Section (~'S) Reference Sur~e~ Calculation Method: Time 17-5219 Pa~,e: Well: 15-36, True North 15-366- 64-6 Well {O.OON.O.OOE,90 OOAzij Minimum Curvature U6r. -i racle Su n ec ~1D L~c l .~zint "('VD Sys TVD YIS F.%N' 11apN MapLr fool ft deg deg ft ft ft ft ft ft 11271. 95 29 .27 34. 03 8532. 72 8468 .12 5834 .07 2941. 77 5965963 .59 679628. 24 MWD 11301. 79 32 .08 33. 32 8558. 39 8493 .79 5846 .74 2950. 21 5965976 .45 679636. 37 MWD 11332. 32 35 .24 34. 38 8583. 79 8519 .19 5860 .78 2959. 64 5965990 .72 679645. 47 MWD 11362. 34 38 .14 31. 04 8607. 87 8543 .27 5875 .88 2969. 31 5966006 .03 679654. 78 MWD 11392. 83 42 .28 30. 33 8631. 15 8566 .55 5892 .81 2979. 35 5966023 .19 679664. 42 MWD 11423. 74 46 .67 32. 27 8653. 20 8588 .60 5911 .30 2990. 61 5966041 .94 679675. 24 MWD 11450. 99 49 .31 33. 85 8671. 43 8606 .83 5928 .26 3001. 66 5966059 .16 679685. 89 MWD 11481. 98 52 .29 38. 07 8691. 02 8626 .42 5947 .68 3015. 77 5966078 .90 679699. 54 MWD 11514. 28 54. 58 43. 87 8710. 28 8645 .68 5967 .24 3032. 78 5966098 .85 679716. 08 MWD 11548. 09 56. 34 48. 44 8729. 45 8664 .85 5986 .51 3052. 87 5966118. 59 679735. 70 MWD 11575. 78 58. 36 50. 90 8744. 39 8679 .79 6001 .59 3070. 64 5966134. 09 679753. 12 MWD 11609. 73 63. 11 53. 01 8760. 98 8696 .38 6019 .83 3093. 96 5966152. 87 679776. 00 MWD 11652. 53 68. 99 55. 30 8778. 35 8713 .75 6042 .71 3125. 66 5966176. 48 679807. 16 MWD 11686. 26 74. 09 57. 58 8789. 03 8724 .43 6060 .38 3152. 32 5966194. 78 679833. 39 MWD 11721. 13 79 .19 61. 27 8797. 09 8732 .49 6077 .62 3181. 52 5966212 .70 679862. 17 MWD 11751. 51 81. 65 64. 79 8802. 15 8737 .55 6091 .20 3208. 21 5966226 .90 679888. 54 MWD 11781. 27 82. 97 70. 59 8806. 13 8741 .53 6102 .39 3235. 49 5966238 .72 679915. 54 MWD 11816. 25 84 .81 76. 39 8809. 86 8745 .26 6112 .26 3268. 82 5966249 .38 679948. 62 MWD 11847. 66 84 .11 80. 43 8812. 89 8748 .29 6118 .54 3299. 44 5966256 .38 679979. 08 MWD 11876. 89 85 .43 84. 30 8815. 56 8750 .96 6122 .41 3328. 28 5966260 .92 680007. 83 MWD 11907. 53 87 .89 88. 17 8817. 34 8752 .74 6124 .41 3358. 79 5966263 .65 680038. 28 MWD 11946. 88 90 .35 95. 02 8817. 95 8753 .35 6123 .32 3398. 10 5966263 .48 680077. 60 MWD 11976. 12 93 .60 96. 08 8816. 94 8752 .34 6120 .49 3427. 18 5966261 .34 680106. 74 MWD 11998. 00 93 .60 96. 08 8815. 57 8750 .97 6118 .18 3448. 89 5966259 .54 680128. 50 PROJECTED Halliburton Com an i P Y Survey Report Cumpam: BP Amoco Date: 8116!2003 Timc: 18:10:08 Pale: 1 Field: Prudhoe Bay Co-ordinatc(~l:) K cicrencc: Well. 15-36. Tru e Noi1h Site: PB DS 15 Vertical fly U) Ncfercnce: 15-36B: 64.3 ~ Wcll: 15-36 Section ('1'ti~ Ncfcr encc Well (O OON.O.O OE90-OOP~zi) Weltpath: 15-36BPB2 - Survey CHleulatlult - - f~tctliod: Minimum Curva - - ture Db: Oracle --- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 15-36 Slot Name: Well Position: +N/-S 1212.31 ft Northing: 5960062.30 ft Latitude: 70 17 47.159 N +E/-W 556.36 ft Easti ng : 676824.72 ft Longitude: 148 34 4.997 W Position Uncertainty: 0.00 ft Weltpath: 15-36BPB2 Drilled From: 15-36BPB1 500292248072 Tie-on Depth: 11514.28 ft Current Datum: 15-366: Height 64.60 ft Above System Datum: Mean Sea Level Magnetic Data: 7/31/2006 Declination: 24.51 deg Field Strength: 57611 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.60 0.00 0.00 90.00 Survey Program for Definitive Weltpath Date: 8/16/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 249.85 10064.81 1 : MWD - Standard (249.85-118 MWD MWD -Standard 10097.00 10949.48 15-366PB 1 MWD+II FR+MS (10097. 0 MWD+IFR+MS MWD +IFR + Multi Station 10949.48 11514.28 15-366PB 1 MWD (1 0949.48-11976. MWD MWD -Standard 11540.00 12203.22 15-36BPB 2 MWD (1 1540.00-12203. MWD MWD -Standard Survey ~11D Inc! Azim TVD Sys TVD N/S E/W MapN MapE Tool ~ ft deg deg ft ft ft ft ft ft 33.60 0.00 0.00 33.60 -31.00 0.00 0.00 5960062.30 676824.72 TIE LINE 249.85 0.20 339.87 249.85 185.25 0.35 -0.13 5960062.65 676824.58 MWD 426.85 0.21 288.76 426.85 362.25 0.75 -0.54 5960063.04 676824.16 MWD 517.85 1.02 15.58 517.84 453.24 1.58 -0.48 5960063.87 676824.20 MWD 608.85 2.12 28.14 608.81 544.21 3.85 0.53 5960066.16 676825.16 MWD 696.85 3.33 32.95 696.71 632.11 7.43 2.69 5960069.79 676827.23 MWD 785.85 3.32 30.89 785.56 720.96 11.81 5.41 5960074.23 676829.85 MWD 875.85 3.83 34.28 875.38 810.78 16.53 8.45 5960079.02 676832.77 MWD 965.85 4.89 35.42 965.12 900.52 22.14 12.36 5960084.72 676836.56 MWD 1054.85 5.41 34.74 1053.76 989.16 28.68 16.95 5960091.37 676840.99 MWD 1150.85 5.71 29.14 1149.31 1084.71 36.57 21.86 5960099.37 676845.71 MWD 1246.85 6.49 23.73 1244.77 1180.17 45.71 26.36 5960108.61 676850.00 MWD 1341.85 6.75 21.97 1339.13 1274.53 55.80 30.61 5960118.80 676854.01 MWD 1436.85 7.49 24.77 1433.40 1368.80 66.60 35.30 5960129.71 676858.44 MWD 1530.85 8.13 24.14 1526.53 1461.93 78.23 40.58 5960141.46 676863.45 MWD 1626.85 9.59 21.95 1621.38 1556.78 91.84 46.35 5960155.20 676868.89 MWD 1719.85 10.86 21.30 1712.90 1648.30 107.19 52.43 5960170.69 676874.61 MWD 1816.85 12.93 22.74 1807.81 1743.21 125.71 59.94 5960189.38 676881.68 MWD 1911.85 14.86 23.35 1900.03 1835.43 146.70 68.88 5960210.57 676890.12 MWD 2006.85 17.29 24.74 1991.31 1926.71 170.71 79.62 5960234.83. 676900.29 MWD 2102.85 19.92 25.45 2082.28 2017.68 198.44 92.62 5960262.85 676912.64 MWD 2197.85 22.40 27.85 2170.87 2106.27 229.06 108.03 5960293.83 676927.32 MWD 2293.85 24.34 26.06 2258.99 2194.39 263.01 125.27 5960328.17 676943.76 MWD 2389.85 24.89 25.55 2346.27 2281.67 299.01 142.67 5960364.57 676960.31 MWD 2484.85 25.30 26.26 2432.30 2367.70 335.25 160.28 5960401.21 676977.05 MWD 2579.85 24.34 26.06 2518.53 2453.93 371.04 177.86 5960437.40 676993.79 MWD 2674.85 25.85 29.97 2604.56 2539.96 406.57 196.81 5960473.37 677011.90 MWD r Halliburton Company Survey Report Company: Field: Site: ~~ ell: Wellpath: BP Amoco Prudhoe Bay PB DS 15 15-36 15-36BPB2 Date: 8/16!2006 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section ('tit Reference: tiur.c} Calculation Method: Time: 18:10:08 Pnt;e: Well. 15-36, True North 15-36B~ 64.6 Well (O OON,O.OOE,90 OOAzi) Minimum Curvature Db: racle I Survev MD Inc ! Aziro I ~'U Sys'i~' I) N/S E/W Map\ ~1apE Tool ft deg de g ft ft ft ft ft ft 2770. 85 29. 09 31 .25 2689. 73 2625 .13 444 .67 219. 38 5960511 .98 677033 .56 MWD 2864. 85 31. 19 30. 90 2771. 01 2706 .41 485 .09 243. 73 5960552. 96 677056. 96 MWD 2960. 85 32. 07 27. 71 2852. 76 2788 .16 528 .99 268. 35 5960597 .42 677080. 53 MWD 3056. 85 33. 97 27. 83 2933. 25 2868 .65 575 .27 292. 72 5960644 .27 677103. 81 MWD 3151. 85 35 .16 25. 13 3011. 48 2946 .88 623 .51 316. 73 5960693 .06 677126. 68 MWD 3246. 85 35. 58 23. 64 3088. 95 3024 .35 673 .60 339. 43 5960743 .66 677148. 19 MWD 3341. 85 38 .69 25. 53 3164. 68 3100 .08 725 .72 363. 32 5960796 .33 677170. 84 MWD 3437. 85 41 .43 24 .36 3238. 15 3173 .55 781 .74 389. 36 5960852 .94 677195. 55 MWD 3531. 85 43 .95 26 .50 3307. 24 3242 .64 839 .28 416. 75 5960911 .10 677221. 58 MWD 3628. 85 45 .99 26 .36 3375. 86 3311 .26 900 .67 447. 26 5960973 .18 677250. 63 MWD 3723. 85 46 .30 26 .71 3441. 68 3377 .08 961 .95 477. 86 5961035 .17 677279 .79 MWD 3819. 85 48 .69 25 .81 3506. 54 3441 .94 1025 .42 509. 16 5961099 .35 677309 .58 MWD 3850. 85 48 .70 26 .29 3527. 00 3462 .40 1046 .34 519. 39 5961120 .51 677319 .31 MWD 3974. 28 47. 40 26. 35 3609. 51 3544 .91 1128 .62 560. 09 5961203 .72 677358 .06 MWD 4068. 96 48. 66 23. 87 3672. 83 3608 .23 1192 .36 589. 94 5961268. 13 677386. 41 MWD 4164. 35 50. 67 25. 69 3734. 57 3669 .97 1258 .36 620. 43 5961334 .83 677415. 33 MWD 4259. 67 51. 56 25. 68 3794. 41 3729 .81 1325 .23 652. 59 5961402 .43 677445. 91 MWD 4355. 37 50. 07 24. 39 3854. 88 3790 .28 1392 .43 683. 98 5961470 .35 677475. 71 MWD 4450. 91 49. 95 23. 78 3916. 28 3851 .68 1459 .25 713. 86 5961537 .85 677504. 00 MWD 4546. 44 51 .41 24 .32 3976. 81 3912 .21 1526 .74 743. 98 5961606 .02 677532. 52 MWD 4641. 30 51 .06 25 .06 4036. 20 3971 .60 1593 .94 774. 87 5961673 .93 677561. 83 MWD 4736. 93 50 .82 25. 21 4096. 46 4031 .86 1661 .16 806. 41 5961741 .87 677591. 78 MWD 4831. 94 50 .28 24 .53 4156. 83 4092 .23 1727 .72 837. 27 5961809 .14 677621 .05 MWD 4927. 24 50 .40 24 .51 4217. 66 4153 .06 1794 .47 867. 71 5961876 .58 677649 .92 MWD 5022. 51 50 .35 24 .66 4278. 41 4213 .81 1861 .20 898. 24 5961944 .00 677678 .87 MWD 5117. 91 52 .15 25 .04 4338. 13 4273 .53 1928 .71 929. 51 5962012 .22 677708 .54 MWD 5211. 89 51 .70 25 .95 4396. 08 4331 .48 1995 .49 961. 35 5962079 .73 677738 .80 MWD 5306. 81 51. 98 25. 81 4454. 73 4390 .13 2062 .64 993. 93 5962147 .62 677769 .79 MWD 5402. 24 51. 80 26. 61 4513. 63 4449 .03 2130 .00 1027. 09 5962215. 74 677801. 35 MWD 5497. 73 51. 64 25. 86 4572. 78 4508 .18 2197 .24 1060. 23 5962283. 73 677832. 89 MWD 5594. 11 51. 00 26. 11 4633. 02 4568 .42 2264 .87 1093. 19 5962352. 12 677864. 26 MWD 5689. 31 50. 12 25. 96 4693. 50 4628 .90 2330 .93 1125. 46 5962418. 92 677894. 96 MWD 5785. 31 51. 60 26. 17 4754. 09 4689 .49 2397 .81 1158. 18 5962486. 55 677926. 09 MWD 5878. 23 50. 54 28. 51 4812. 48 4747 .88 2462 .02 1191. 36 5962551 .51 677957. 75 MWD 5975. 68 50. 92 29. 20 4874. 17 4809 .57 2528 .10 1227. 77 5962618. 42 677992. 60 MWD 6071. 26 50. 12 28. 86 4934. 94 4870 .34 2592 .60 1263. 57 5962683 .74 678026. 87 MWD 6166. 54 50. 68 30. 46 4995. 67 4931 .07 2656 .39 1299. 90 5962748 .37 678061. 68 MWD 6261. 42 52. 67 29. 47 5054. 51 4989 .91 2720 .87 1337. 07 5962813 .70 678097. 32 MWD 6356. 93 51. 68 28. 50 5113. 08 5048 .48 2786 .86 1373. 63 5962880 .53 678132. 32 MWD 6452. 36 51 .04 28. 15 5172. 67 5108 .07 2852 .47 1409. 00 5962946 .95 678166. 13 MWD 6547. 42 50. 30 28. 47 5232. 92 5168 .32 2917 .21 1443. 87 5963012 .48 678199. 46 MWD 6641. 78 49. 43 29. 39 5293. 74 5229 .14 2980 .35 1478. 76 5963076. 42 678232. 86 MWD 6735. 65 49. 21 29. 65 5354. 93 5290 .33 3042 .29 1513. 84 5963139. 17 678266. 47 MWD 6831. 20 51. 04 29. 33 5416. 18 5351 .58 3106 .12 1549. 93 5963203. 83 678301. 05 MWD 6926. 18 50. 91 29. 94 5475. 99 5411 .39 3170 .26 1586. 42 5963268. 80 678336. 01 MWD 7020. 69 52. 11 27. 76 5534. 81 5470 .21 3235 .05 1622. 09 5963334. 41 678370. 15 MWD 7116. 13 51. 86 28. 38 5593. 59 5528 .99 3301 .39 1657. 48 5963401. 56 678403. 96 MWD 7211. 75 52. 31 28. 92 5652. 35 5587 .75 3367 .59 1693. 64 5963468. 59 678438. 56 MWD 7305. 81 51. 58 27. 25 5710. 33 5645 .73 3432 .93 1728. 52 5963534 .73 678471. 88 MWD 7401. 15 51. 38 28. 55 5769. 71 5705 .11 3498 .85 1763. 42 5963601 .45 678505. 22 MWD 7495. 97 49. 75 24. 52 5829. 95 5765 .35 3564 .33 1796. 15 5963667 .67 678536. 40 MWD 7592. 14 49. 72 25. 12 5892. 11 5827 .51 3630 .94 1826. 95 5963734 .98 678565. 63 MWD 7685. 90 51 .22 24 .84 5951. 79 5887 .19 3696 .49 1857. 49 5963801 .23 678594. 61 MWD r S Halliburton Company Survey Report Compam: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Nell: 15-36 N'ellpath: 15-36BPB2 Survr~ M1tU Incl ft deg zim deg VD ft cs"I~~U ft late: 8/16/2006 Time: 18:10-08 Page: 3 Co-ordinah~t.~E) Itcfcrcncc: Well; 15-36, True North Vertical (1 ~7)) Kefcrencc 15-36B: 6~.6 Section (~~ti- Retcrencc: Well (O.OON.O.OOE,90-OOAzi) Surve} Calculation }lcthod: Minimum Curvahire Db: Orade N,'S N:iW h1apN ~1a~E "1'001 ft ft ft ft 7779.85 51.23 24.16 6010.62 5946.02 3763.13 1887.86 5963868.57 678623.41 MWD 7877.39 51.44 23.68 6071.56 6006.96 3832.75 1918.74 5963938.89 678652.64 MWD 7972.90 51.10 24.17 6131.32 6066.72 3900.86 1948.96 5964007.68 678681.24 MWD 8068.01 51.16 24.77 6191.01 6126.41 3968.26 1979.63 5964075.78 678710.32 MWD 8162.94 51.37 25.54 6250.41 6185.81 4035.28 2011.11 5964143.52 678740.20 MWD 8258.31 51.05 23.60 6310.16 6245.56 4102.88 2042.01 5964211.82 678769.51 MWD 8353.63 50.96 24.06 6370.14 6305.54 4170.65 2071.95 5964280.27 678797.84 MWD 8447.76 51.15 24.39 6429.30 6364.70 4237.41 2101.99 5964347.72 678826.30 MWD 8542.70 51.04 23.60 6488.93 6424.33 4304.91 2132.03 5964415.90 678854.74 MWD 8637.24 50.72 24.26 6548.58 6483.98 4371.95 2161.78 5964483.62 678882.91 MWD 8732.79 50.46 23.14 6609.24 6544.64 4439.54 2191.45 5964551.89 678910.98 MWD 8827.64 51.28 26.75 6669.11 6604.51 4506.23 2222.49 5964619.28 678940.43 MWD 8922.53 50.95 26.57 6728.68 6664.08 4572.24 2255.63 5964686.05 678972.01 MWD 9019.69 50.74 26.31 6790.03 6725.43 4639.70 2289.18 5964754.28 679003.96 MWD 9114.02 49.95 25.70 6850.23 6785.83 4704.97 2321.02 5964820.27 679034.26 MWD 9209.26 49.62 26.04 6911.72 6847.12 4770.41 2352.75 5964886.44 679064.44 MWD 9305.30 49.44 24.56 6974.06 6909.46 4836.46 2383.98 5964953.20 679094.10 MWD 9386.58 48.94 26.53 7027.18 6962.58 4891.96 2410.50 5965009.31 679119.31 MWD 9495.25 48.38 24.94 7098.96 7034.36 4965.45 2445.93 5965083.60 679152.99 MWD 9588.06 48.01 27.00 7160.83 7096.23 5027.64 2476.22 5965146.49 679181.81 MWD 9683.11 47.35 26.20 7224.83 7160.23 5090.48 2507.68 5965210.04 679211.79 MWD 9778.97 47.17 28.04 7289.89 7225.29 5153.14 2539.77 5965273.44 679242.39 MWD 9875.02 47.31 28.34 7355.10 7290.50 5215.30 2573.09 5965336.35 679274.23 MWD 9968.97 46.64 27.84 7419.20 7354.60 5275.89 2605.43 5965397.69 679305.14 MWD 10064.81 45.15 29.36 7485.90 7421.30 5336.31 2638.36 5965458.86 679336.64 MWD 10097.00 44.45 29.06 7508.75 7444.15 5356.11 2649.43 5965478.91 679347.24 MWD+IFR+MS 10134.05 43.95 29.37 7535.31 7470.71 5378.65 2662.04 5965501.75 679359.31 MWD+IFR+MS 10227.93 40.42 30.26 7604.86 7540.26 5433.35 2693.36 5965557.16 679389.34 MWD+IFR+MS 10320.08 35.69 31.31 7677.40 7612.80 5482.15 2722.40 5965606.63 679417.22 MWD+IFR+MS 10414.07 29.37 32.73 7756.61 7692.01 5525.00 2749.14 5965650.10 679442.94 MWD+IFR+MS 10460.08 27.44 35.25 7797.08 7732.48 5543.15 2761.36 5965668.53 679454.73 MWD+IFR+MS 10508.49 26.00 35.94 7840.32 7775.72 5560.86 2774.02 5965686.52 679466.97 MWD+IFR+MS 10553.90 25.79 32.34 7881.17 7816.57 5577.26 2785.15 5965703.18 679477.71 MWD+IFR+MS 10602.34 25.90 31.97 7924.76 7860.16 5595.14 2796.39 5965721.32 679488.52 MWD+IFR+MS 10648.11 26.61 29.43 7965.81 7901.21 5612.55 2806.72 5965738.97 679498.44 MWD+IFR+MS 10696.06 26.39 31.29 8008.73 7944.13 5631.01 2817.53 5965757.67 679508.81 MWD+IFR+MS 10727.80 26.08 31.38 8037.20 7972.60 5642.99 2824.83 5965769.83 679515.83 MWD+IFR+MS 10758.96 25.82 29.55 8065.21 8000.61 5654.74 2831.74 5965781.73 679522.46 MWD+IFR+MS 10790.37 25.21 29.00 8093.56 8028.96 5666.54 2838.36 5965793.69 679528.80 MWD+IFR+MS 10821.55 24.75 32.42 8121.83 8057.23 5677.86 2845.08 5965805.16 679535.25 MWD+IFR+MS 10852.70 24.07 32.33 8150.19 8085.59 5688.73 2851.97 5965816.19 679541.88 MWD+IFR+MS 10885.34 23.62 32.66 8180.04 8115.44 5699.86 2859.06 5965827.48 679548.71 MWD+IFR+MS 10916.05 22.83 33.57 8208.27 8143.67 5710.01 2865.67 5965837.78 679555.08 MWD+IFR+MS 10949.48 21.71 33.40 8239.20 8174.60 5720.57 2872.66 5965848.51 679561.82 MWD+IFR+MS 11000.13 21.88 32.59 8286.23 8221.63 5736.35 2882.90 5965864.51 679571.68 MWD 11031.33 24.61 32.09 8314.90 8250.30 5746.75 2889.49 5965875.07 679578.02 MWD 11061.07 26.81 31.61 8341.69 8277.09 5757.71 2896.29 5965886.19 679584.57 MWD 11094.92 27.25 31.05 8371.84 8307.24 5770.85 2904.29 5965899.51 679592.25 MWD 11121.56 24.70 30.61 8395.79 8331.19 5780.87 2910.27 5965909.66 679598.00 MWD 11155.50 21.03 30.04 8427.06 8362.46 5792.24 2916.93 5965921.20 679604.39 MWD 11182.86 21.88 30.33 8452.52 8387.92 5800.90 2921.97 5965929.96 679609.22 MWD 11212.92 24.52 30.86 8480.15 8415.55 5811.09 2927.99 5965940.29 679615.00 MWD Halliburton Company Survey Report Compao~: BP Amoco Date: $/16/2006 Timc: 18.10-08 Page: 4 Field: Prudhoe Bay Co-ordinate (NE) Reference: Well: 15-36 . Tru e North Site: PB DS 15 Vertical (TV D) Reference: 15-36B: 64 .6 1~d1: 15- 36 Scetio u (VS) Re ference: Well (O.OON.O.O OE90-OONzi) Wcllpath: 15- 36B P62 Sunr~ Calc ulation Method: h9u~imum C urva ture Db: Orade Sung M1tU Ind ~iim Il'L) ti~ti'1~~' p N/S - -__ E/~~~ Map'V --_- Map E; -fool ft deg deg ft ft ft ft ft ft 11241. 50 27. 07 29. 28 8505. 88 8441. 28 5821. 85 2934. 22 5965951 .20 679620 .97 MWD 11271. 95 29. 27 34. 03 8532. 72 8468. 12 5834. 07 2941. 77 5965963 .59 679628. 24 MWD 11301. 79 32 .08 33. 32 8558. 39 8493. 79 5846. 74 2950. 21 5965976 .45 679636. 37 MWD 11332. 32 35 .24 34. 38 8583. 79 8519. 19 5860. 78 2959. 64 5965990 .72 679645. 47 MWD 11362. 34 38 .14 31. 04 8607. 87 8543. 27 5875. 88 2969. 31 5966006 .03 679654. 78 MWD 11392. 83 42 .28 30. 33 8631. 15 8566. 55 5892. 81 2979. 35 5966023 .19 679664. 42 MWD 11423. 74 46 .67 32. 27 8653. 20 8588. 60 5911. 30 2990. 61 5966041 .94 679675. 24 MWD 11450. 99 49 .31 33 .85 8671. 43 8606. 83 5928. 26 3001. 66 5966059 .16 679685. 89 MWD 11481. 98 52 .29 38 .07 8691. 02 8626. 42 5947. 68 3015. 77 5966078 .90 679699 .54 MWD 11514. 28 54 .58 43 .87 8710. 28 8645. 68 5967. 24 3032. 78 5966098 .85 679716 .08 MWD 11540. 00 55 .90 47 .36 8724. 94 8660. 34 5982. 01 3047. 88 5966113 .98 679730 .83 MWD 11570. 51 63 .98 54 .38 8740. 23 8675. 63 5998. 59 3068. 37 5966131 .04 679750 .92 MWD 11600. 09 67 .15 60 .79 8752. 47 8687. 87 6013. 00 3091. 10 5966145 .97 679773 .30 MWD 11635. 53 70 .58 68. 01 8765. 26 8700. 66 6027. 25 3120. 89 5966160 .92 679802 .75 MWD 11668. 57 71 .81 74. 33 8775. 92 8711. 32 6037. 33 3150. 47 5966171 .69 679832. 08 MWD 11706. 06 73 .79 81. 11 8787. 02 8722. 42 6044. 93 3185. 45 5966180 .11 679866. 86 MWD 11739. 86 78 .66 85. 18 8795. 07 8730. 47 6048. 84 3218. 02 5966184 .78 679899. 34 MWD 11770. 47 82 .70 91. 16 8800. 03 8735. 43 6049. 79 3248. 19 5966186 .45 679929. 48 MWD 11800. 30 85 .46 99. 95 8803. 11 8738. 51 6046. 92 3277. 69 5966184 .27 679959. 03 MWD 11831. 80 88 .55 97 .66 8804. 76 8740. 16 6042. 10 3308. 77 5966180 .19 679990. 22 MWD 11867. 75 91 .45 96 .96 8804. 76 8740. 16 6037. 53 3344. 43 5966176 .45 680025. 96 MWD 11897. 50 94 .98 98 .72 8803. 09 8738. 49 6033. 48 3373. 85 5966173 .10 680055. 47 MWD 11925. 99 94 .10 99 .60 8800. 83 8736. 23 6028. 96 3401. 88 5966169 .24 680083 .60 MWD 11956. 18 93 .13 103 .65 8798. 93 8734. 33 6022. 89 3431. 39 5966163 .86 680113 .24 MWD 11988. 67 92 .42 107 .53 8797 .36 8732. 76 6014. 17 3462. 64 5966155 .88 680144 .69 MWD 12021. 14 90 .22 113 .17 8796. 61 8732. 01 6002. 88 3493. 06 5966145 .31 680175 .36 MWD 12050. 79 89 .34 115 .64 8796 .72 8732. 12 5990. 63 3520. 06 5966133 .70 680202 .64 MWD 12080. 40 91 .45 119 .69 8796 .52 8731. 92 5976. 89 3546. 28 5966120 .58 680229 .17 MWD 12112. 26 91 .72 116 .69 8795. 64 8731. 04 5961. 85 3574. 34 5966106 .20 680257. 58 MWD 12140. 93 91 .45 114 .40 8794. 84 8730. 24 5949. 49 3600. 20 5966094 .46 680283. 72 MWD 12172. 62 90 .31 110 .17 8794. 36 8729. 76 5937. 48 3629. 51 5966083 .14 680313. 31 MWD 12203. 22 89 .69 110 .53 8794. 36 8729. 76 5926. 83 3658. 20 5966073 .18 680342. 24 MWD 12232. 00 89 .69 110 .53 8794. 51 8729. 91 5916. 74 3685. 15 5966063 .72 680369. 42 PROJECTED TREE = 4-1116" CMJ WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 65.8' BF. ELEV = NA KOP = 1721' Max Angle = 96 @ 11793' Datum MD = N/A Datum TVD = 8800' SS S~ NOTES: PARENT WELL (15-36) IS NOT -3 6 B S -SEE ORIGINAL WELL FILE FOR MORE DETAILS. 70 @ 11605' ***4-112" CHROMETBG &LNR*"" 2213' ~ 4-1/2" HES X NIP, ID = 3.813" 110-3/4" CSG, 45.5#, L-80, ID = 9.950" I-I 3907' Minimum ID = 2.37" @ 11367' TOP OF 2-7/8" LNR 4-112" TBG, 12.6#, 13CR-80 VAM, .0152 bpf. ID = 3.958" ~7-518"WHIPSTOCK (07/08/06) GAS I_ IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 2 1 3447 6828 9831 3245 5414 7325 42 51 47 K8G-2 KBG-2 KBG-2 DMY DMY DMY BK BK BK 0 0 0 07/12/06 07/19/06 07/12/06 9900' I- j 4-112" HES X NIP, ID = 3.813" 9921 ~ 7-5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.870" gg44' 4-1/2" HES X NIP, ID = 3.813" 9951' 7-5/8" X 5-1/Z" ZXP LNR TOP PKR w /TB SLV, ID = 4.90" 9957' 4-112" WLEG, ID = 4.00" 9969' 7-5/8" X 5-1/2" FLIX LOCK LNR HNGR, ID = 4.920" 997 7-518" X 5-1/2" XO, ID = 3.970" 7-5/8" MILLOUT WINDOW (15-368) 10097' - 10110' I7-5/8" EZSV (07/05/06) ~ 10117' ESTIMATED TOP OF CEMENT 10700' ITOPOF 3-1/2" LNR, 9.3#, ID=2.972" I--I 10934' TOP OF 5-1/2" LNR ~ 10965' 7-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" 11119' 2-718" LNR, 6.5#, L-80, ID = 2.377" 13010' 5-112" LNR MILLOUT WINDOW (15-36A) 11428' - 11435' (OFF WHIPSTOCK) PERFORATION SUMMARY REF LOG: MCNL/CCUGR ON 08/07/06 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 87 @ 12440' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12440 - 13150 O 08/08/06 10697' 3.70" DEPLOY SLV, ID = 3.000" 10715' 3-112" HES X NIP, ID = 2.813" I 10745' I ' ~ 4-1/2" LNR, 12.6#, -~ 10943' ~ \ 13CR-80 VAM, 1 ID = 3.958" 4-1/2" LNR, 12.6#, L-80 IBT-M, 10988' .0152 bpf, ID = 3.958" 3-1/2" LNR, 8.81#, L-80 STL, .0087 bpf, ID= 2.99" 10745' 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" 11 I PBTD I I 11367' I 3-112" X 3-3/16" XO, ID - 2.867" 3-3/16" x 2-718" XO, ID = 2.441" 131 249' 1- 13285' 12-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" I DATE REV BY COMMENTS DATE REV BY COMMENTS 06!09194 ORIGINAL COMPLETION 07119/06 JRP/PJC GLV C10 12/21!01 CH/KAK CTD SIDETRACK 08/26/06 SMM~TLH DRLG DRAFT CORRECTIONS 09/24/01 ATTEMPTCTDSIDETRACK 07116/O6 N2ES RWO 8~ PARTIAL SIDETRACK 08/04/06 NORDIC1 CTD SIDETRACK 07/19/06 ITCH DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 15-36B PERMfI• No: 2060730 API No: 50-029-22480-02 SEC 22 ,T11 N, R14E, 1440' SNL & 887' EWL BP Exploration (Alaska) 17-Aug-06 AOGCC Helen. Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-36B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,514.28' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 13,285.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 17-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-36B PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.60' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 11,998.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHCHALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 /~ ~ / ~ / - , Date Signed /~M~-s~< <!~~~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.6~ - o? 3 • • 17-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-36B PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,514.28' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 12,232.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~?HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 3 d ~ ~ (~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich ~E~ErvED Survey Manager AUG 3 0 2006 Attachment(s) ITtISS10r- q~(g (~{ & GSS ~S• COm Anchorage ~~ 3 ~~ I~ ?~ ~~~ ~ 1 ~ia ~ ,~~.,'' ~ x a ALA-SSA OIL A1QD GAS COI~TSERQATI01~ CO1~'IISSIOIQ Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 j, 1' f1 J` Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 15-36B Sundry Number: 306-239 Dear Mr. McLaughlin: FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~~y of July, 2006 Encl. l~ gv(o - a~-3 V 1 10111 1110.1 1 f. ` ~ ~ ~ STATE OF ALASKA ~~ ~ • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 W G ~4- -I (ll 120 c (P REGEIVEd J U L 1 1 2006 Alaska (lil R Gas Cons. CQCTII'111851f1i~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time ExtensiorAllChOf8Q8 ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Restart O s w/ Nordic #1 2. Operator Name: 4. Current Well Class: E 5. Permit To Drill Number ~ BP Exploration (Alaska) Inc. ®Development ^ xploratory 206-073 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22480-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 26,000' PBU 15-36B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028306 65.75 Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT. WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10378 7580 10378 7580 None None Casin Len th Size MD TVD Burst Colla se Structural Conductor 80' 20" 110' 110' 1490 470 Surface 3872' 10-3/4" 3907' 3565' 5210 2480 Intermediate 11086' 7-5/8" 10097' 7509' 8180 5120 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ~ None - P&A'd None N/A -Below Kick Off N/A N/A Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 18, 006 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: a ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Prepared By Name/Number: Signature C~ Phone 564-4387 Date (~ (~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ S'f " [3 O ~ C {D 3 S D O ~ LL RBDMS BFL JUL 13 2006 Subsequent Form Required: ~ ' APPROVED BY A roved B COMMISSIONER THE COMMISSION Date Q~ Form 10-403 Revised 06/2006 ~bmit~S Duplicate r: To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: July 10, 2006 Re: 15-36B Sundry to resume drilling operations with Nordic 1 by Sundry approval is requested to resume drilling operations on 15-36B. Rig 27E is currently drilling the intermediate hole and will land and cement the liner in the Sag River formation prior to shutting down operations. Nordic 1 will rig up and drill the production hole as planned on Permit to Drill 206-073. ~ The estimated start date is July 18, 2006. Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble T'F~= 41/18' CNV VH~LFCAD = ACTUATOR = BAKBt KB. 9.Eb = 85.8' BF. t3.EV = NA KOP = 1721' tit A = 96 11793' Dattxn hD = WA Ded~m TV D = 8800' SS • 15-36 B ~°~~ WI~.^Na.EI~>70°~ 1600' b > 90° (~ 11740"'LOST 4-1R" X K~1f Proposed Complstlon 2"x 1-1/Z" X 1/4" (12/11/05)" 2200 - 4-1/2" X Nipple (3.813" ID) (,AS LET MAPDRaS 103/4' CSG, 45.5#, L-80, ID = 9.950" - 3907' Minimum ID = 2.75" @ 10730' 3-112" XN Nipple ST WD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 a 9,930' - 4-1/2" X Nipple (3.813" ID) 9,950' 7-5/8" X 4-1/2" BKR S3 PKR/HGR 9,980' - 4-1/2" X Nipple (3.813" ID) 4-1 /2", 12.6#, L-80 tbg cut @ 10,400' TOC @ 10,700' 7-5l8" X 5-1/2" BKR H PKR, ID = 6.56" - 10,972 PERFORATION SUMINARY REF LOG: SWS CNUGR ON 12/18/01 ANGLE AT TOP PERF: 81 @ 12000' Note: Refer to Production DB for historical pert data S¢E SPF NTERVAL Opn/Sgz DATE 2" 4 12000 - 12390 C 12/21/01 2" 4 12440 - 12690 C 12/21(01 2" 4 12780 - 12990 C 12/21 /01 7-5/8" CSG, 29.7#, NT-95 HS, ID = 6.875" - 11,119' ~~~~.~ ~. '''=, ig a• ~ ~ is _ ,012' - 4-112". 12.6#, L-80 liner r`: ~ ~ ~ , .~ t'~+ • i. µ51Y.. 3-1 /2" x 3-3/16" x 2-7/8" cmted - 12808` / 10730` - 3-1/2" XN nipple, ID =2.75" 10700' -Top of 3-1/2" liner' 2-7/8" 6.5#, L-80 Liner -13010' 5-1/2" LNR, 17#, NT-80, ID = 4.892" -11,813' DATE 08/0!/94 12!21101 REV BY CWKAK OOMuB~ITS ORIGINAL COMPLETION CTD SIDETRACK QATE 09/24/05 12/11/05 REV BY RAOR/TLH DAV/PJC OOM~ITS XX TTP SET (OB/Ofi/M) SFIY NOTE d~ PULL TTP 1084 0!/24101 ATT6N PT CTD SIDETRACK 08/13/03 KB H.EVATiON OORRBCTION 08/'12/03 CMOfiLP OATUM bD 8 PERF ANGLE 08/02!04 JL.JITLP GLV Ci!O PRUDtiOE BAY UNtT Wl3L: 15-36A PERMT No: 82011820 AR No: 50-029-22480-01 SEC 22 .T11N, 814E 1440' SNL 8 88T EYVL BP Brploration (Alsska) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 7/1/2006 00:00 - 03:00 03:00 - 04:00 04:00 - 12:00 12:00 - 20:00 15-36A 15-36A REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 27E Hours ~ Task I Code ~ NPT ---~- . .r _ _._ 3.00 MOB P 1.00 MOB P 8.00 MOB P 8.00 MOB P Page 1 of 4 Spud Date: 9/14/2001 Start: 7/2/2006 End: Rig Release: Rig Number: 27E Phase j Description of Operations PRE R/D Floor, Blow Down All lines, Separate All Complexes PRE Remove Berms from Around Rig PRE Move All Support Complexes off 15-026 PRE Move Substructure from 15-026 to 15-366 and Spot over Wellhead. 20:00 - 00:00 4.00 MOB P PRE Set Pipesheds 7/2/2006 00:00 - 06:00 6.00 MOB P PRE Set Pit, Motor and Pump Complexes. 06:00 - 18:00 12.00 MOB N HMAN PRE Start Investigation of Geronimo Line Incident. Identified Possible Hazards Associated with Damaged Derrick Platform. Developed Safe Work Plan to Remove Platform from Derrick. Preliminary Investigation Completed. 18:00 - 20:00 2.00 MOB N HMAN PRE Removed Derrick Platform According to Safe Work Plan. 20:00 - 21:00 1.00 MOB P PRE Held PJSM, Plan Forward to Get Rig Operational, Pre-Spud Meeting with Rig Crew, MWD and Mudman. 21:00 - 00:00 3.00 MOB P PRE Finalize Rig Acceptance Check List, Addressed All Outstanding Issues on Check List. 7/3/2006 00:00 - 01:00 1.00 WHSUR P DECOMP ACCEPTED RIG FOR OPERATIONS AT 0001, 7/3/2006. Installed Double Annulus Valves on IA and OA. 50 psi on OA. 0 psi on IA. 01:00 - 02:30 1.50 WHSUR P DECOMP PJSM, P/U and R/U DSM Lubricator. Pull BPV. R/D and UD Lubricator 02:30 - 04:30 2.00 WHSUR P DECOMP PJSM, R/U Circulating Lines to Top of Tree and IA from Circulating Manifold. 04:30 - 05:00 0.50 WHSUR P DECOMP Fill All Circulating Lines with Water. Tested Circulating System to 3,500 psi. 05:00 - 08:30 3.50 WHSUR P DECOMP PJSM, Pump 35 bbls Down 7-5/8" 4-1/2" Annulus at 3 bpm, 150 psi. Taking Returns from Tubing Through Choke Manifold to Slop Tank. Shut Down Pumps and Line Up to Pump Down Tubing. Pump 25 bbl Safe-Surf Pill Followed by 430 bbls 120 deg Water Down Tubing Taking Returns from IA Through Choke Manifold To Slop Tank. Final Circulating Pressure 210 psi. 08:30 - 09:30 1.00 WHSUR P DECOMP Set TWC and Pressure Test from Below to 1,000 psi. Bled Down All Pressure to 0 psi and Close Well In. 09:30 - 10:30 1.00 WHSUR P DECOMP Blow Down Circulating Lines and R/D Same. 10:30 - 13:30 3.00 WHSUR P DECOMP PJSM, N/D Tree and Adapter Flange. 13:30 - 14:30 1.00 WHSUR P DECOMP Installed 4-1/2" NSCT XO in Tubing Hanger to Check M/U Integrety of the Threads for Pulling Tubing. Made Up 7-1/2 Turns. 14:30 - 22:00 7.50 BOPSU P DECOMP PJSM, N/U BOPE's, M/U Choke and Kill Lines, Installed Drilling Riser and R/U Flowline. Secure BOPE's with Turnbuckles and Pressure Up All Air Boots. 22:00 - 22:30 0.50 BOPSU P DECOMP Energized Accumulator and Function Teted and BOPE Components. 22:30 - 23:30 1.00 BOPSU P DECOMP P/U 4-1/2" Test Joint. M/U Testing Sub and Floor Safety Valve. Installed Test Joint. 23:30 - 00:00 0.50 BOPSU P DECOMP R/U BOPE Testing Equipment. 7/4/2006 00:00 - 09:00 9.00 BOPSU P DECOMP Tested BOPE's Utilizing 4-1/2" Test Joint. Test All Rams, Annular, Choke and Kill Line Valves, Choke Manifold and Floor Safety Valves to 250 psi/ 3,500 psi. All Tests held 5 min each. Witness of Test Waived by AGOCC Rep. John Crisp. Test Witnessed by BP WSL Rodney Kleqzig & Chris Clemens / Nabors Toolpushers Alan Lunda & Rick Brumley Printed: 7/10/2006 226:10 PM BP EXPLORATION Operations Summary Report Page 2 of 4 Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To 5-36A 5-36A REENTE NABOB NABOB Hours R+COM S ALASK S 27E Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 9/14/2001 : 7/2/2006 End: Release: Number: 27E Description of Operations 7/4/2006 00:00 - 09:00 9.00 BOPSU P DECOMP Testing Sequence; (1.) Bottom Pipe Rams, Floor Safety Valve, (2.) Top Pipe Rams, Kill HCR, Choke Valves 1 & 2 (3.) Choke Valves 3,4,5 & 6, (4.) Choke Valves 7,8 & 9, (5.) Choke Valves 10, 11 & 12, (6.) Manual Kill, Choke Valves 13, 14 & 15, (7.) Choke Line HCR, (8.) Choke Line Manual, (9.) Annular, (10.) Accumulator Test, Starting Pressure 2,825 psi, After Closure 1,525 psi, Initial 200 psi Recovery 50 sec, Final Pressure 2,825 psi, Full Recovery Time 1 min 50 sec., (11.) Blind Rams, (12,) IBOP Top Drive, (13.) Lower Safety Valve - Top Drive. 09:00 - 11:30 2.50 DHB P DECOMP Rig down test equipment, blow down choke line, PJSM with rig site maintenance, pull two way check with lubricator. 11:30 - 12:00 0.50 PULL P DECOMP Pick up 1 jt 4" dp and XO to 4.5" nsct, screw into tubing hanger 7.5 turns, make up topp drive to drill pipe to pull tbg hanger. 12:00 - 12:30 0.50 PULL P DECOMP Check alignment of choke manifold, pull tubing hanger to rig floor. No problem pulling hanger out of spool. Up wt=150k. Monitor well for flow, well static. 12:30 - 13:30 1.00 PULL P DECOMP Circulate a bottoms up at 315 gpm at 300 psi. Pick up 4.5" handling equipment and rig up same. 13:30 - 14:00 0.50 PULL P DECOMP Monitor well and pump dry job. MW in/out=8.4 ppg. 14:00 - 15:30 1.50 PULL P DECOMP Terminate control line, lay down landing jt and tubing hanger. rig up Schlumberger to spool SSSV control line when 4.5" tubing is being laid down. 15:30 - 21:00 5.50 PULL P DECOMP POH laying down 52 jts of 4.5" tubing. 21:00 - 21:30 0.50 PULL P DECOMP Lay down SSSV, rig down SSSV control line spooler. Retrieved 28 out of 31 stainless steel bands. 21:30 - 00:00 2.50 PULL P DECOMP Lay down 38 jts of 4.5" tubing for a total of 90 jts. 7/5/2006 00:00 - 06:30 6.50 PULL P DECOMP Continue laying down 4.5" tubing for a total of 247 jts, one 20.61' stub, 3 gas lift mandrels, and 3 pup jts. 06:30 - 07:00 0.50 PULL P DECOMP Make up running tool and set wear ring. 07:00 - 08:00 1.00 PULL P DECOMP Clear floor, rig down tubing tongs and handling equipment. 08:00 - 13:00 5.00 DHEOP P DECOMP Rig up Schlumberger, Run #1-Gamma Ray, Junk Basket, and 6.75" Gauge Ring. Tagged stump up at 10,357'. Recovered 2 stainless steel bands. 13:00 - 15:00 2.00 DHEOP P DECOMP Run #2 -Rerun Junk Basket and recovered 1 stainless steel band for a total of 31 bands 15:00 - 18:30 3.50 DHEOP P DECOMP Rig up EZSV plug, GR, and CCL, run in hole and set at 10,117', pull out of hole and rig down Schlumberger. 18:30 - 20:30 2.00 DHB P DECOMP Pull wear bushing, rig up and test 7-5/8" casing to the EZSV to 3,500 psi for 30 minutes and record on chart. 20:30 - 21:00 0.50 DHB P DECOMP Rig up to pull 10-3/4" x 7-5/8" pack off, open bottom annulus, no flow. Pull pack off. 21:00 - 23:30 2.50 EVAL P DECOMP As pack off was being pulled the well started flowing. Monitored well until stack was full. Blind rams were closed and we monitored well from 21:15 to 22:45 hrs. Notifications were made to Anchorage Rig Team and AOGCC State Inspector Jeff Jones. Casing pressure built from 80 psi to 120 psi. From 22:45 to 22:50 we bled 11 bbls through the choke line through the gas buster, taking returns into the cuttings tank. The well was shut in and monitored the well for 10 minutes to 23:00, building from 40 psi to 80 psi. From 23:00 to 23:05 another 11 bbls were bled off. The well was shut in and from 23:05 to Printed: 7/10/2006 2:26:10 PM BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: 15-36A Common Well Name: 15-36A Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 27E Date From - To Hours Task ~ Code NPT ~ - 2.50 ~ EVAL _; _ . - - 7/5/2006 21:00 - 23:30 ~ P 23:30 - 00:00 I 0.501 DHB I P 7/6/2006 00:00 - 00:30 0.50 DHB P DECOMP 00:30 - 02:30 2.00 BOPSU P DECOMP 02:30 - 03:00 I 0.501 BOPSUFi P I I DECOMP 03:00 - 03:30 0.50 BOPSU P DECOMP 03:30 - 04:00 0.50 CLEAN P DECOMP 04:00 - 05:00 1.00 CLEAN P DECOMP 05:00 - 07:00 2.00 CLEAN P DECOMP 07:00 - 14:30 7.50 CLEAN N RREP DECOMP 14:30 - 15:30 1.00 CLEAN P DECOMP 15:30 - 16:00 0.50 BOPSU P DECOMP 16:00 - 19:00 I 3.001 CLEAN I P I I DECOMP 19:00 - 21:30 2.50 CLEAN P DECOMP 21:30 - 00:00 2.50 CLEAN P DECOMP 00:00 - 02:00 2.00 CLEAN P DECOMP 02:00 - 11:30 9.50 CLEAN P DECOMP 11:30 - 12:00 0.50 CLEAN P DECOMP 12:00 - 16:30 4.50 CLEAN P DECOMP 16:30 - 18:30 2.00 CLEAN P DECOMP 18:30 - 19:00 0.50 STWHIP P WEXIT 19:00-21:30 2.50 STWHIP N SFAL WEXIT 21:30 - 22:00 0.50 STWHIP P WEXIT 22:00 - 00:00 2.00 STWHIP P WEXIT 7/8/2006 00:00 - 07:30 7.50 STWHIP P WEXIT 07:30 - 08:30 I 1.001 STWHIPI P I I WEXIT 08:30 - 10:30 J 2.001 STWHIPI P I I WEXIT 10:30-17:00 I 6.501STWHIPIP I (WEXIT Spud Date: 9/14/2001 Start: 7/2/2006 End: Rig Release: Rig Number: 27E Phase Description of Operations 23:15 the well the pressure went from 20 psi to 50 psi. From 23:15 to 23:25 we bled another 9 bbls, shut the well in and monitored the well from 23:25 to 23:30. In this 5 minutes the well stayed at 20 psi. Gained a total of 65 bbls of dead crude at 7.3 PPg• The choke was opened and flow was monitored into the cuttings tank. The flow slowed to a 1.5" stream. At this point the blind rams were opened and the cellar pump was turned on to suck the stack out through the lower annulus. After the stack was sucked out we installed and energized the 10-3/4" x 7-5/8" pack off and tested it at 5,000 psi for 10 minutes. Lay down pack off running tool. Test top pipe rams, bottom pipe rams, and hydril to 250 psi low and 3,500 psi high for 5 minutes each. Record on chart. Witnessed by WSL Charlie Noakes and Nabors TP Rick Brumley. Circulate water through choke line and gas buster to clear dead crude. Blow down choke line and mud lines to rig pumps. Install wear bushing, RILDS. Clear and clean rig floor. PJSM, Pick up mule shoe and 27 jts of 4" dp 1 x 1. Replace landing outside derrick board, rig up and secure geronimo line. POH and stand back 9 stands 4" dp. Test blind rams to 250 psi low and 3,500 psi high for 5 minutes each. Witnessed by WSL Chris Clemens and TP Dave Hanson. Pick up window mill, bit sub, string mill, 1 jt 3.5" hwdp, bumper sub, 12 4.75" spiral dc's, and a xo. Trip in picking up 4" dp 1 x 1 to 2,054'. Cut and slip drilling line. Inspect and adjust draw works brakes. Trip in picking up 4" dp 1 x 1, tag EZSV at 10115'. Circulate bottoms up at 420 gpm, 2,750 psi, MW=8.4 ppg in/out, UW=170k, DW=150k, RW=160k. POH to bha. Stand back 4 stands of dc's in derrick Pick up MWD, UBHO sub and orient to whipstock slide. Trouble shoot MWD, could not communicate with the tool at surface. Surface test MWD tool. OK TIH with whipstock assy. TIH with 7-5/8" whipstock to mill 6-3/4" window. Fill dp every 30 jts. Set 7-5/8" whipstock at 71 degrees right of highside. TOW=10,097', BOW=10,110'. Displace water out of well with 9.9 ppg LSND mud. Pumped 50 bbl high visc spacer, YP of 75, visc of 300, pump 440 bbls 9.9 ppg LSND mud, visc 45, at 350 gpm at 2,150 psi. Mill window from 10,097' to 10,110', pumped 150 visc sweep, drill new formation from 10,110' to 10,124'. UW=154k, DW=140k, RW=145k, 100 rpm's, 350 gpm at 2,400 psi, 5k DECOMP DECOMP Printed: 7/10/2006 2:26:10 PM BP EXPLORATION Operations Summary Report Page 4 of 4 Legal Well Name: 15-36A Common Well Name: 15-36A Spud Date: 9/14/2001 Event Name: REENTER+COMPLETE Start: 7/2/2006 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 27E Rig Number: 27E Date From - To Hours Task Code i NPT Phase ~ Description of Operations 7/8/2006 10:30 - 17:00 6.50 STWHIP P WEXIT WOB, 50% increase in cuttings when sweep returned. 17:00 - 18:30 1.50 STWHIP P WEXIT Pump weighted sweep. 11 ppg, 85 yp. UW=154k, DW= 140k, MW in/out=9.9 ppg. 350 gpm C~ 2,400 psi. No increase in cuttings returns. 18:30 - 20:00 1.50 STWHIP P WEXIT Perform FIT to 11.5 ppg, 625 psi. Held 10 minutes, bled down to 560 psi in 10 minutes. Passed test. Pumped 1 bbl, gained 1 bbl back after bleeding off pressure. 20:00 - 21:30 1.50 STWHIP P WEXIT MAD Pass up from 10,000' to 9,870'. 21:30 - 23:00 1.50 STWHIP P WEXIT Pump 24 bbl super sweep, MW 9.9 ppg, visc 70, YP 35, 300 gpm C~3 1,900 psi, 20 rpm's. No significant increase in cuttings returns. 23:00 - 00:00 1.00 STW HIP P WEXIT Circulate while taking blower hose off of TD. Build dry job. 7/9/2006 00:00 - 04:00 4.00 STW HIP P WEXIT Pump dry job. POH to 4-3/4" dc's. 04:00 - 07:30 3.50 STWHIP P WEXIT Lay down 12 4.75" dc's, bumper sub, UBHO sub, MWD, float sub, 1 Jt HWDP, upper string mill, bit sub, and starting mill. 07:30 - 08:00 0.50 STWHIP P WEXIT Back out LDS, pull wear ring. 08:00 - 09:30 1.50 STWHIP P WEXIT P/U stack flushing tool, flush the stack of metal cuttings, function rams, flush choke and kill lines. 09:30 - 10:00 0.50 STWHIP P WEXIT Install wear ring, RILDS. 10:00 - 10:30 0.50 STWHIP P WEXIT Rig Service. 10:30 - 13:30 3.00 STWHIP P WEXIT P/U bit, motor, float sub, stab, MWD, initialize MWD, P/U 3 nmfdc's, jar, and xo sub. Shallow pulse test MW D 13:30 - 17:00 3.50 STWHIP P WEXIT TIH to shoe filling dp every 30 stands. 17:00 - 18:00 1.00 STWHIP P WEXIT Install TD blower hose, set block height, orient motor to 70R, get slow pump rate, exit window to 10,124'. 18:00 - 00:00 6.00 DRILL P INT1 Directional drill from 10,124' to 10,195'. UW 152k, DW 138k, RW 150k, 350 gpm ~ 2,800 psi, WOB 5k, TO on 4k, TO off 3.5k, RPM's 50, MW 9.9 ppg in/out. AST=2.55, ART=.25, TDT=2.8. 7/10/2006 00:00 - 06:00 6.00 DRILL P INT1 Directional drill from 10,195' to 10,378'. UW 152k, DW 138k, RW 150k, 350 gpm C~ 2,800 psi, WOB 5k, TO on 4k, TO off 3.5k, RPM's 50, MW 9.9 ppg in/out. Printed: 7/10/2006 2:26:10 PM 27E OA Well Control Event. • • Subject: 27E OA WeII Control Event. ~~~~, ~~~~~~ F'ro~n: "NSU, ADW Drlg Rid ?7E" <NSUADWDr1~Rig27E@BP.cam> ~ ~ D~~te: Thu. O(~ Jul 2UOb 09:3~:2~1-0800 To: ao~rcc_ prudhoc hav(u',admin.state..ak.us CC: "Easley, 13arhara N1" -cI3arbara.L.asley(ciBP.eori~=~ "ti~'esley. Dare E" <Davc;.Wesleyrcl;BP.eoiT1==~ P~ ~ ~ ~~ ~~ Jeff, ~ ~ ?.~C~ ,° ~' 73 Below is the chain of events off of the DIMS report as per your request. 18:30 - 20:30 Hrs. Pull wear bushing, rig up and test 7-5/8" casing to the EZSV to 3,500 psi for 30 minutes and record on chart. 20:30 - 21:00 Hrs. Rig up to pull 10-3/4" x 7-5/8" pack off, open bottom annulus, no flow. Pull pack off. 21:00 - 23:30 Hrs. As pack off was being pulled the well started flowing. Monitored well until stack was full. Blind rams were closed and we monitored well from 21:15 to 22:45 hrs. Notifications were made to Anchorage Rig Team and AOGCC State Inspector Jeff Jones. Casing pressure built from 80 psi to 120 psi. From 22:45 to 22:50 we bled 11 bbls through the choke line through the gas buster, taking returns into the cuttings tank. The well was shut in and monitored the well for 10 minutes to 23:00, building from 40 psi to 80 psi. From 23:00 to 23:05 another 11 bbls were bled off. The well was shut in and from 23:05 to 23:15 the well the pressure went from 20 psi to 50 psi. From 23:15 to 23:25 we bled another 9 bbls, shut the well in and monitored the well from 23:25 to 23:30. In this 5 minutes the well stayed at 20 psi. Gained a total of 65 bbls of dead crude at 7.3 ppg. 23:30 - 00:00 Hrs. The choke was opened and flow was monitored into the cuttings tank. The flow slowed to a 1.5" stream. At this point the blind rams were opened and the cellar pump was turned on to suck the stack out through the lower annulus. After the stack was sucked out we installed and energized the 10-3/4" x 7-5/8" pack off and tested it at 5,000 psi for 10 minutes. Regards, Chris Clemens BP Well Site Leader -Nabors 27E BPXA / GPB Drlg. Office:(907) 659-4345 Cell: (907) 943-1228 1 of 2 0~~ - 0~3 7/7/2006 9:42 AM 27E OA Well Control Event. Fax: (907) 659-4788 2 of 2 7/7/2006 9:42 AM • 1 t '1 ' ' ~ l ~ a~~~ ~ , ,~ i ~ ~, J~ ~~ ~~ ~ i'~ ~ a~ = ~3 -°-a ~ j ~ ~ ~~ ;~ dilL17aL1 ®IId ~lsL COI~TSERQATIOI~T COMN'IISSIOI~T Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSK/, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-36B BP Exploration (Alaska), Inc. Permit No: 206-073 Surface Location: 1440' FNL, 887' FWL, SEC. 22, T11N, R14E, UM Bottomhole Location: 4547' FSL, 5216' FWL, SEC. 16, T11N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission. reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy., P. Foerster Commissioner ~`~ DATED this day of May, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. w STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMMON PERMIT TO DRILL 20 AAC 25.005 4 5 ~ 2Z.- toDfo 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1c. Specify if weH is proposed for. ^ Coalbed Methane Q Ga~'Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 15-36B 41a~zoo~, 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12808 TVD 8769 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: UM / 887' FWL T11 N R14E 1440' FNL SEC 22 7. Property Designation: ADL 028306 Pool , , , , . , Top of Productive Horizon: 4640' FSL, 4268' FWL, SEC. 15, T11N, R14E, UM 8. Land Use Permit: 13. Approximate S ud Date: Jun 15, 2'006 Total Depth: 4547' FSL, 5216' FWL, SEC. 15, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 26,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-676825 y-5960062 Zone-ASP4 10. KB Elevation (Height above GL): 65.75 feet 15. Distance to Nearest Well Within Pool: 600' 16. Deviated Wells: Kickoff Depth: 10100 feet Maximum Hole Angle: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3612 Surface: 2785 Y 18. Casin Pro ram: S eclfications To - Settin De tli -Bottom Quanti of Cement, c.f. or sacks Hole Casin Wei ht Grade ou lin Len th MD TVD MD TVD includin sta a data 6-3/4" 4-1/2" 12.6# 13Cr Vam To 1062' 9950' 7406' 11012' 8274' 204 sx Class 'G' i' 4-1/4" s-~~s^ x z-~is• 6.3# / 4.6# L-80 STL 1946' 10862' 8143' 12808' 8769' 134 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redril l and Re-entry Operations) Total Depth MD (ft): 13010 Total Depth TVD (ft): 8776 Plugs (measured): None Effective Depth MD (ft): 12996 Effective Depth TVD (ft) 8775 Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor /Structural 80' 20" 260 sx Arctic Set A rox. 110' 110' Surface 3872' 10-3/4" 1105 sx PF 'E', 375 sx Class 'G' 3907' 3565' Intermediate 11086' 7-5/8" 617 sx Class 'G' 11119' 8333' Pr c ion 460' 5-1/2" 126 sx Class'G' 10965' - 11425' 8197' - 8612' Liner 2087' a-,n• x 3-3/16• x z-~ia• 66 sx Class 'G' 10923' -13010" 8160' - 8776' Perforation Depth MD (ft): 12000' - 12990' Perforation Depth TVD (ft): 8747' - 8775' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Barbara Lasley, 564-5126 Printed Name ave Wesley Title Senior Drilling Engineer can c aug in, Prepared By NamelNumber: Si nature ~~'~ ~ ~~~ - K~ ~~ Phone 564-5153 Date ~~ ~~L~~l~ Terrie Hubble, 564-4628 Commission Use OM y Permit To Drill Number: `^' API Number: 50- 029-22480-02-00 Permit Approval Date: S - ZZ' d See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales Samples Req'd: ^ Yes ~, No Mud Log Req'd: ^ Yes ~No i ,~ S ~- ~?j(~ ~ C ~-p 'Z~ rj p p ,p u . H2S Measures: Yes ^ No Directional Survey Req'd: ,Yes ^ No OtF~r~ 20 A~-C ZS , 0 3 >; (~,.~ (I ~ c~.l ~-e,~ru~., e !S~ l'E {'-t f - I° ~~ ~~// r01c'c.d f-Urr,,,~ ~ o _ {~,~ >r K.~:~~ t-o res~~- r~~~-r'~,.s , ~'S t~u ~e d. ~~ ~ APPROVED BY THE COMMISSIO Date ~ ~Z.L' ©~ ,COMMISSIONER orm 1 -401 Revised 12/2005 f^°~ Submit In Duplicate • ~ To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Lasley, 27E Drilling Engineer Sean McLaughlin, Nordic 1 Drilling Engineer Date: May 16, 2006 Re: 15-36B Sidetrack Permit to Drill y . - 4 f' ~ ~. Approval is requested for the permit to drill for well 15-36B. The 15-36B sidetrack is currently scheduled for Nabors 27E beginning the third week of June, 2006, followed by Nordic Rig #1 by year end. Well 15-36A is an Ivishak producer that is currently shut-in for tubing by IA communication. The well has been shut in and secured with an XX plug set at 10,841' MD. The plan is to exit the 15-36A wellbore at 10,100' md. A whipstock will be run and a 6-3/4" window will be milled in the 7-5/8" casing. A 6-3/4" hole will be drilled to the Top of the Sag River formation. A 4-1/2" liner will then be run and cemented. A 4-1/2" tubing string will be run to the top of 4-1/2" liner at 9950' MD. At this point, the operations will be temporarily shut down awaiting coil tubing drilling operations. Following Nabors 27E, Nordic Rig #1 will resume operations for a coil tubing sidetrack. CTD Sidetrack operations commence with the cleanout of cement left in the intermediate liner run during the rotary operation. The well will be extended into the Sag River formation, building angle through the Sadlerochit section to land horizontal in the Zone 1 target interval. The wellbore will then be extended horizontally for 1800 ft in the target interval. The production interval will be completed with a cemented and perforated 3-3/16" x 2-7/8" liner with roughly 700 feet of perforations. Planned Well Summary Well 15-36B Well Horizontal Sidetrack Target Zone 1 A/1 B T e Rotary/CTD combo Ob'ective AFE Number: PBD 4P 2485 API Number: 50-029-22480-02 Surface Northin Eastin Offsets TRS Location 5,960,062 676,825 1440' FNL / 887' FWL 11 N, 14E, 22 Northin Eastin Offsets TRS Target 5,966,220 680,050 640' FNL / 1011' FEL 11 N, 14E, 15 Locations 5,966,180 680,500 690' FNL / 562' FEL 11 N, 14E, 15 5,966,150 680,900 730' FNL / 163' FEL 11 N, 14E, 15 Bottom Northin Eastin Offsets TRS Location 5,966,150 681,000 732' FNL / 63' FEL 11 N, 14E, 15 Planned KOP: 10,100' and / 7,511' tvd Planned TD: 12,808' and / 8,769' tvd Ri Nabors 27E CBE: 31.0' RTE: 63.5' Nordic Rig #1 15-36B Sidetrack Page 1 Directional Program A roved Well Ian: Wp06 Exit oint: 10,100' and / 7,511' tvd Maximum Hole Inclination: ~90° in the tanned roduction section. Proximit Issues: All wells pass ma'or risk criteria. Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: Well 15-30A at 600 ft. from open erforations Nearest Pro ert Line 26,000' Logging Program Hole Section: Required Sensors /Service 6-3/4" intermediate: Real time MWD Dir/GR 4-1/4" production: Real time MWn Dir/GR/Res in the build Real time MWU Dir/GR/Res in the lateral. Sam les at 50' intervals throu hout. Cased Hole: MCNUCCL O en Hole: None tanned Mud Proaram Hole Section / o eration: Mill window in the 7 5/8" casin at 10,100' and T e Densit MBT PV YP API FL H LSND 9.9 <12 15-22 30-40 <6.0 9.0 -10.0 Hole Section / o eration: Drillin 6 3/4" interval from 10,100' and to section TD T e Dens' MBT PV YP API FL H LSND 9. <15 15-22 20-24 4.0 - 6.0 9.0 -10.0 Hole Section / o eration: Drillin 4 1/4" production interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >58,000 8 -12 22 - 28 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd Tubin 4-1/2" 12.6# 13Cr Vam To 9950' Surface 9950' / 7406' 6-3/4" 4-1/2" 12.6# 13Cr Vam To 1062' 9950' / 7406' 11012' / 8274' 4-1/4" 3-3/16" x 2-7/8" 6.3# x 4.6# L-80 STL 1946' 10,862' / 81.43' 12808' / 8769' Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 7 5/8" casin Bride lu to surface 30 min recorded .3,500 si surface 7 5/8" casin window 20' new formation be and FIT 11.5 EMW 4-1/2" casin Float a ui ment to surface 30 min recorded 3,500 si surface 4-1/2" casin shoe 20' new formation be and FIT 10.0 EMW 3-3/16" x 2-7/8" roduction liner Float a ui ment to surface 30 min recorded 3,500 si surface 15-36B Sidetrack Page 2 • Cementing Program Casin Strin 4-1/2", 12.6#, 13-Cr, VAM To intermediate liner Lead slurry: None planned. Slurry Design Basis: Tail slurry: 912' of 4-1/2" X 6-3/4" annulus with 40% excess, plus 40' of 4- " " ' ' " 1/2 , 12.6# shoe track, plus 150 of 4-1/2 x 7-5/8 Ilner lap, plus 200 of 7-5/8 x 4" drill i e annulus. Pre-Flush None tanned Fluids S n /V l S acer 35bbls MudPUSH at 12.0 eque ce ume: o Lead Slur None tanned Tail Slur 42 bbl / 236 cf 20 sxs Class `G', 15.8 ; 1.16 cf/sk. ( :-~~ Casin Strin 3-3/16" x 2-7/8", 6.3# x 4.6#, L-80, STL solid production liner Lead slurry: none planned Tail slurry: 1,308' of 2-7/8" X 4-1/4" annulus with 40% excess, plus 500' of 3- Slurry Design Basis: 3/16" X 4-1/4" annulus with 40% excess, plus 150' of 5-1/2" x 3-3/16" lap, plus 50' of 4-1/2" x 3-1/2" lap, plus 40' shoe track and 2 bbls above the top of liner. Pre-Flush 2% KCI Fl id S /V l S acer None tanned u s equence ume: o Lead Slur None tanned ~ Tail Slur 28 bbl / 157 cf 1341sx Class `G', 15.8 ; 1.17jcf/sk. Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 6-3/4" intermediate interval Maximum anticipated BHP: 3,612 psi at 8,270' TVD. Maximum surtace pressure: 2,785 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Infinite with 11.5 ppg EMW FIT Planned BOPE test pressure: 250 psi low / 3,500 psi high 7 day test cycle (Pre drilling phase) 14 da test c cle Drillin o erations Well Interval: 4 1/4" production interval Maximum antici ated BHP: 3,300 psi at 8,800' TVDss. Maximum surface ressure: 2,420 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 pp EMW FIT. Planned BOPE test ressure: 250 si low / 3,500 si hi h - 14 da test c cte Drillin o erations) / Planned com letion fluid: 8.4 seawater / 7.1 Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ! equipment for other than well control or equivalent ~/~- purposes, except when the routine use of BOP _ equipment may have compromised their //~ effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. 15-36B Sidetrack Page 3 Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Estimated Estimated Hydrocarbon Est. Formation To s Formation To s Uncertainty Bearin Pore Press. Formation (TVD) (MD) (feet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells CM3 6293 0 CM2 6818 0 CM 1 7449 0 KOP 10100'MD THRZ 7825 10501 10 B H RZ 8020 10725 10 LC U 8120 10840 10 TSGR 8270 11012 10 TSHA 8310 11058 10 TSHB 8340 11092 1 Q TSHC 8345 11100 10 TSAD 8364 11120 10 es 44SB 8390 11150 10 es 43S6 8410 11173 10 es 42SB 8435 11201 10 es 41 SB 8475 11247 10 es TCGL 8500 11276 10 es 31 SB 8525 11305 10 es BCGL 8550 11333 10 es 23S6 8598 11389 10 es 22TS 8637 11437 10 es 21 TS 8700 11524 10 es TZ1 B 8755 11618 10 es TZ1 AITDF 8790 11702 10 es 3300 BSAD/Kavik ss2o 10 Reach planned TD unless drilling conditions deteriorate. Final TD TBD by both rig TD Criteria: and town geologist. Wellbore maybe extended to meet minimum 500' perforation requirement. 15-366 Sidetrack Page 4 Fault Prognosis The 15-366 well is located in a smaller E-W trending graben that extends to the east of the main NW-SE trending graben. No seismically mapped faults are anticipated to be crossed by the well. 15-36B is bounded to the north by Regional Fault #1 with throws of 30-90 ft down to the south. The amount of throw on Regional Fault #1 increases from west to east. 15-366 is bounded to the south by Regional Faults #2 and #3. Regional Fault #2 has throws of 25-50 ft down to the north. Regional Fault #3 appears to be the eastern continuation of Regional Fault #2 and has throws of 30-50 ft down to the north. In addition to the graben- bounding faults, several small seismically mapped faults (N-S trending) are located to the west of the well location. These include Faults #4 and #5 which both trend NE-SW with throws of 10-20 ft down to the south. The greatest potential sources of lost circulation in the vicinity of 15-36B are the north and south graben- bounding faults. The proposed 15-36B well does not cross either of these faults. Furthermore, the only losses experienced by the parent well, 15-36, were a result of running casing, and none of the other nearby wells experienced losses due to faulting. Although no faults are anticipated to be crossed by the proposed well, I categorize the structure risk to be medium. The reason for this is due to the location of the well in the small E-W graben. Seismic imaging in this small graben is challenging, and therefore, there is a chance of the presence of faults which are not visible in the seismic. 15-36B Sidetrack Page 5 Operations Summary Current Condition: / SI since August 2004. / 4-1/2", 12.6#, L-80 x 3-1/2', 9.2#, L-80 tubing, WLEG (behind pipe) Q 10,966' MD. / 7-5/8"X4-1/2"BABE-3 packer at 10,904'MD. / 4-1/2" `XX' tubing tail plug set at 10,841' MD (10,809' SLM) in X nipple. Scope * Notify the field AOGCC representative with intent to plug and abandon Pre-Rig Operations (27E): 1. CMIT/MIT-OA complete Jan 2006. Tests passed 3500 psi CMIT TxIA and 2000 psi MIT-OA 2. Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 3. R/U SL and drift the 4-1/2" tbg down to the 3-1/2" liner top @ 10923" MD 4. RIH with CT and P&A the 15-36A well bore. Pump --17.1 bbls of 15.8 ppg cement, leaving TOC in the 4-1/2" tbg at 10,700' MD. Cement volume based on the following calculations: 0 1506' of 2-7/8" liner (cap. = 0.0058 bbl/ft) = 8.7 bbls 0 126' of 3-3/16" liner (cap. = 0.0076 bbl/ft) = 1.0 bbls 0 455' of 3-1/2" liner (cap. = 0.0087 bbl/ft) = 4.0 bbls 0 223' of 4-1/2" liner (cap. = 0.0152 bbl/ft) = 3.4 bbls 5. RIH with the appropriate jet cutter and cut the 4'/z" tubing at -10,400' MD 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all lock down screws, repair or replace as needed. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. Rig Operations (27E): 1. MIRU Nabors rig 27E. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Run TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi high, 250 psi low. '~- 4. RU. Pull 4-1/2" tubing from the cut at 10,400' MD. y 5. RU E-line. 6. MU 6.75" gauge ring / jun suet / CCL. RIH and tag tubing stump. POH. 7. RIH with EZSV. Set bri ge pl at 10,118', as required to avoid cutting a casing collar while milling the window. POH. -~-~ 8. R/D E-line. ~~.. 9. Pressure-test the 7-5/8" casing and EZSV to 3,500psi for 30 minutes. Record test. ~ `10. PU and RIH with 7-5/8" Baker bottom-trip anchor whip stock assembly on 4" DP. Orient whip stock to O 85 deg right of high side and set on bridge plug. Shear off of whip stock. 1 ~ 11. Displace the well to 9.9 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 12. Mill window in 7-5/8" casing at ± 10,100' MD, plus approximately 20' beyond middle of window. ~ t~ Circulate well bore clean. 15-36B Sidetrack Page 6 • • 13. Pull up into 7-5/8" casing and conduct an FIT to 11.5 ppg EMW. POH. 14. MU 6-3/4" Dir/GR assembiy. RIH, kick off and drill the 6-3/4" intermediate section to the 4 1/2" liner point at top of the Sag River, as per the directional plan. 15. Run and cement a 4-1/2", 12.6#, Cr13 VAM Top intermediate drilling liner. 16. Test casing and liner lap to 3,500 psi for 30 minutes, chart same. 17. MU and run a 4'/z", 12.6#, 13Cr, VamTop tubing completion with 4-1/2" tubing tail, stinging into the 4'/z" liner tie back sleeve. 18. Set packer and individually test the tubing and annulus to 3,500psi for 30 minutes. Record each test. 19. Prepare for "Temporary Operational Shut down" 20. Set a TWC and test. 21. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 22. Freeze protect the well to 2,200' TVD with diesel. Secure the well. /~ 23. Rig down and move off. Post-Riq Operations (27E): 1. MIRU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Riq Operations (Nordic 1): 1. MIRU and test BOPE to 250 psi low and 3500 psi high. ~ 2. Mill 3.8" out of shoe track at 11,012' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Lateral: 4.125" OH, 1796' horizontal w/resistivity 4. Run 3'/i" x 3 3/16" x 2 7/8" solid lin aving TOL at 10700' 5. Pump primary cement job to TOL, 28 bl of 15.8 ppg liner cmt planned 6. Cleanout liner and MGR/CCL log 7. Test liner lap to 2000 psi. 8. Perforate liner per asset instructions (700') 9. Freeze protect well, RDMO Post-Riq Operations (Nordic 1): 1. Move wellhouse, Install production flowline 2. Run GLVs 3. Flowback well to separator 15-36B Sidetrack Page 7 27E Rig Operations Phase 1: Move In / Rig Up /Test BOPE Planned Phase Time Planned Phase Cost 48 hours $515,317 includes re-ri costs Reference RP • "Drilling/VNork-over Close Proximity Surface and Subsurface Wells Procedure" SOP • "Hydrogen Sulfide" SOP. • "ADW Rig Move" SOP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto 15-36A. Well 15-37 is 30' to the West and well 15-35 is 30' to the East. As always, care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 15-36A well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the 15-36A well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - DS 15 is n~designated as an HAS si#e. Standard Operating Procedures for HZS precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 15-37B none 15-376 none 15-35 11 ~~ 15-30A None The maximum level recorded of H2S on the pad was 50 ppm in well 15-21A on 0212412001. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 38 hours $193,386 Reference RP • "De-completions" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. 15-36B Sidetrack Page 8 • • - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a 5000 psi FMC with 4-1/16 Cameron tree. Verify with the wellhead representative that all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a 4-1/2" Camco SSSV at 2228' MD. - Caliper shows tubing to be in poor condition with wall loss of greater than 50% from joint #94 to the tubing tail - Run GR/CCL Log from the bridge plug setting depth to surface after setting the EZSV. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 32 hours $233,686 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 5: Drill 6 3/4" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 54 hours $355,003 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - For this well, the Kingak will require a mud weight of 9.9 ppg. Maintain mud weight at 9.9 ppg, minimally, to the 4-1/2" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.9 ppg pore pressure, a fracture gradient of 11.5 ppg at the 7 5/8" casing window, and 9.9 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 11.5 ppg EMW; if this is not reached contact the ODE. - No faults are anticipated in this hole section. 15-36B Sidetrack Page 9 • Phase 6: Run and Cement 4 1/2" Intermediate Casing Planned Phase Time Planned Phase Cost 26 hours $206,754 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - The completion design is to run a 4-1/2", 12.6#, CR13, VAM Top solid liner. - Sufficient 4-1/2" liner will be run to extend -150' back up into the 7-5/8" casing. - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 12: Run 4'/z", 12.6#, 13Cr, VamTop Completion Planned Phase Time Planned Phase Cost 28 hours $600,379 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP • "Handling and Running 13 Chrome" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion design will be a 4Yz", 12.6#, 13Cr, VamTop production tubing string with 7 5/8" x 4-1/2" Baker S-3 packer with 4 GLM's. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 16 hours $49,538 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off of 15-36B. Well 15-37 is 30' to the West and well 15-35 is 30' to the East. As always, care should be taken while moving onto the well. Spotters should be employed at all times. 15-36B Sidetrack Page 10 TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 65.8' BF. ELEV = NA KOP= 1721' Max Angle = 96 @ 11793' Datum MD = WA Datum TVD = 8800' SS • 15 3 6 A NOTES: WELL ANGLE IS > 70° @ 11600' & > 90° @ 11740' **LOST 4-1 /2" X F~1f 2"x 1-1 /2" X 1 /4" (12/11 /05)** 222$' 4-1/2" CAMCO SSSV NIP, ID = 3.812" GAS LIFT MANDRELS 10-3/4" CSG, 45.5#, L-80, ID = 9.950" Minimum ID = 2.377" @ 11504' 3-3/16" X 2-7/8" LINER XO TOP OF 3-1/2" LNR, 9.3#, ID = 2.972" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10965' 7-5/8" X 5-1/2" BKR H PKR, ID = 6.56" 10972' 7-5/8" X 5-1/2" BKR LNR HGR, ID = 6.56" 10978' ~ 7-5/8" CSG, 29.7#, NT-95 HS, ID = 6.875" ~ TOP OF WHIPSTOCK ~ 11430' RA TAG 11439' PERFORATION SUMMARY REF LOG: SWS CNL/GR ON 12/18/01 A NGLE AT TOP PERF: 81 @ 12000' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2" 4 12000 - 12390 C 12/21 /01 2" 4 12440 - 12690 C 12/21 /01 2" 4 12780 - 12990 C 12/21/01 5-1/2" LNR, 17#, NT-80, ID = 4.892" ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE J ~ 1 2 3542 6961 3248 5432 45 52 CAMCO CAMCO DMY DMY BK BK 0 0 08/02/04 08/02/04 3 9502 7037 48 CAMCO DMY BK 0 08/10/01 4 10814 7999 33 CAMCO DMY BK 0 08/10/01 10841' ~~ 4-1 /2" HES X NIP, ID = 3.813" 10904' 17" X 4-1/2" BAKER SABL-3 PKR, ID = 3.875" 10923' 4-1/2" BKR KB LT PKR, ID = 2.560" 10928' 3.70" BKR DEPLOYMENT SLV, ID = 3.00" 10937' 4-1/2" HES X NIP, ID = 3.813" (BEHIND PIPE) 10954' 4-1/2" HES XN NIP, MILLED ID = 3.80" (BEHIND 10965' TOP OF BAKER TIEBACK SLV, ID = 6.38" • 10966' 4-1/2" TBG TAIL WLEG, ID = 3.960" (BEHIND F 10957' ELMD TT LOGGED 07/24/95 5-1/2" LNR MILLOUT WINDOW 11428' - 11435' (OFF WHIPSTOCK) 11378' ~ 3-1/2" X 3-3/16" LNR XO, ID = 2.786" 1~ 0~ 3-3/16" X 2-718" LNR XO, ID = 2.377" 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.377" ~~ 13010' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 06/09/94 ORIGINAL COMPLETION 09/24/05 MOR/TLH XX TTP SET (08/06/04) WELL: 15-36A 12/21/01 C WKAK CTD SIDETRACK 12/11/05 DAV/PJC SFTY NOTE & PULL TTP @ 1084 1 PERMfT No: 2011620 09/24/01 ATTEMPT CTD SIDETRACK API No: 50-029-22480-01 06/13!03 CMOlfLP KB ELEVATION CORRECTION SEC 22 ,T11 N, R14E, 1440' SNL & 887' EWL 09/12/03 CMO/TLP DATUM MD & PERF ANGLE 08/02/04 JLJ/TLP GLV GO BP Exploration (Alaska) TREE= 4-1/16" CM/ WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV - 65.8' BF. ELEV = NA KOP = 1721' Max Angle = 96 @ 11793' Datum MD = N/A Datum TV D = 8800' SS ~~ ~ ~ NOTES: WELL ANGLE IS > 70° @ 11600' 8~ > 90° @ 11740""`LOST 4-1 /2" X KEY Proposed Completion 2"x 1-1 /2" X 1/4" (12/11/05)** 10-3/4" CSG, 45.5#, L-80, ID = 9.950" - 3907` 1Ct111"Il.[Ctl ID =2.75" `~{~~~~~ 3-1 /2" XN Nipple 4-1 /2", 12.6#, L-80 tbg cut @ 10,400` TOC @ 10,700` 7-5/8" X 5-112" BKR H PKR, ID = 6.56" - 10,972 PERFORATION SUMMARY REF LOG: SWS CNUGR ON 12/18/01 ANGLE AT TOP PERF: 81 @ 12000' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12000 - 12390 C 12/21/01 2" 4 12440 - 12690 C 12/21 /01 2" 4 12780 - 12990 C 12/21/01 7-5/8" CSG, 29.7#, NT-95 HS, ID = 6.875" - 11,119' 5-1/2" LNR, 17#, NT-80, ID = 4.892" - 11,813` 2200 - 4-1/2" X Nipple (3.813" ID) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 9,930' - 4-1/2" X Nipple (3.813" ID) 9,950' 7-5/8" X 4-1/2" BKR S3 PKR/HGR 9,980' - 4-1/2" X Nipple (3.813" ID) 2-7/8" 6.5#, L-80 Liner - 13010` ~,©12` - 4-1I2", 12.6#, L-SD liner .: .. r S ~F _ I ~_` - ~ - -~~ - ----- J 3-1/2" x 3-31.16" x 2-718" anted - 12808 j 10/730` - 3-112" XN Hippie, ID =2.75" 10700` -Top of 3-112" liner` DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNrf 06/09/94 ORIGINAL COMPLETION 09/24/05 MOR/TLH XX TTP SET (08/06/04) WELL: 15-36A 12/21/01 CH/KAK CTD SIDETRACK 12/11/05 DAV/PJC SFTY NOTE & PULL TTP @ 1084 1 PERMff No: 2011620 09/24/01 ATTEMPT CTD SIDETRACK API No: 50-029-22480-01 06/13/03 CMO/TLP KB ELEVATION CORRECTION SEC 22 ,T11 N, R14E, 1440' SNL & 887' EWL 09/12/03 CMO/TLP DATUM MD & PERF ANGLE 08/02/04 JLJ/TLP GLV GO BP Exploration (Alaska) ('IIMPANY UEIAB.ti IU:I~I:IU:NI'P WH)Rh1A 11(1N tlP Am~MO c'~r-r~Nuun~IN I:I Mclin~uc: WJI C.mtre: IS-JG, lme Nunh Vortical (IV111141in~n'a•'. 3^_.S+JI fi}_511 by Cakvhlira hLYh.J: hlmimVm l'la~etum ti..u.'o IV~I Relinvce tike- (U.l%IN.U UUNI Imrctiyxum: Ltil'W1A lcao hktWvl: Im~l'ylinlu Noah hlc:uunxl U7rth Rc4nu'c' 1'_.S+JI G3.SU (':JcuWtara hklh~J: Mitimum ('m+alme lima \mlau•'. I:Ilipliul + l'axuy! Wetaw@ M~•Ihxl: Ruk. tlaxxl ~. ~ 7200 _ __,. ~ ~ fir: _~C . ~ ~ Tr ~ 4 1 `! ~ ~~~ Du 12/100': I0100'MD, 751 57TVD ~ - ~!~ •` r ~ 7s ~ i `•~ ~. Slafl Dir 4/100': 10120'M 7524.84TVD ,__.__ _. _ -- - i I - ' - - ~^ i c X 0 c s S v I ^ m U Li e, a, 2 F ll1RVLY PRII(iRAM Plan: IS-3GB wPI1L (15.1L/Plaa I S-IGB) Ucpth Fm IkPl6 to \unxy. Ylm foul Crialal BY: imy laLaMukY 0aka18(I,lq.u10%IC: 4/12/28116 IUI W.I%1 12%U%.IS Plamld: IS3(41 wpU6 VlY MWD+IPR+bLti Checkal: Dalc: ~ Rwiewnl: Date: I~ Naar +N.-5 +8i-W WBLL Uk'IAa.5 Nurlhiog Ivaliog Latitub LoalPluk tiMl ~ IS3G 1211.31 SSfi.3fi 5'NAIUGI_711 G7fi%24.71 7U"IT47.15'1N 14%°34'U4.9Y7W WA TARGET DETAILS Name TVD +N/-S +E/_µ' Northing Easting Shape 15-36B T4 8768.50 5988.17 4317.63 5966150.00 681000.00 Point ~ 15-36B T3 8773.50 5990.52 4217.65 5966150.00 G80900.OU Point IS-36B T2 8803.50 6029.92 3818.44 5966180.00 680500.00 Point I S-36B geo poly 8813.50 6080.50 3369.48 5966220.00 IS-36B T1 8818.50 6060.50 3369.48 5966220.00 680050.00 680050.00 Polygon Point i SECTION DETAILS Sec MD I>LC Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 10100.00 44.36 29.02 7510.57 5358.62 2650.82 0.00 0.00 5896.92 2 10120.00 44.62 32.42 7524.84 5370.66 2657.98 12.00 85.00 5910.88 3 10501.68 29.36 33.01 7828.80 5563.42 2781.55 4.00 178.91 6139.51 4 11348.19 29.36 33.01 8566.59 5911.48 3007.64 0.00 0.00 6554.06 5 11851.50 90.00 80.00 8816.50 6080.50 3369.48 14.00 50.89 6902.79 IS-368 TI 6 11995.54 92.25 100.05 8815.65 6080.46 3512.75 14.00 83.47 6986.54 7 12204.63 92.25 100.05 8807.46 6044.01 3718.48 0.00 0.00 7077.30 8 12305.68 92.24 96.00 8803.50 6029.92 3818.44 4.00 -90.00 7124.34 IS-36BT2 9 12364.40 94.59 95.99 8800.00 6023.80 3876.73 4.00 -0.20 7153.46 10 12636.56 94.59 95.99 8778.23 5995.48 4146.54 0.00 0.00 7288.29 II 12708.02 93.00 92.00 8773.50 5990.52 4217.65 6.00 -111.60 7325.85 IS-36B T3 12 12719.81 92.85 91.31 8772.90 5990.18 4229.42 6.00 -101.93 7332.46 13 12808.15 92.85 91.31 8768.50 5988.17 4317.63 0.00 0.00 7382.42 IS-36B T4 [ ~ ~ ~ ~ Isna utr '-~7r'?~- Tota FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 7828.50 10501.33 THRZ 2 8023.50 10725.07 BHRZ 3 8123.50 10839.81 LCU 4 8273.50 11011.91 TSGR 5 8313.50 11057.81 TSHA 6 8343.50 11092.23 TSHB 7 8348.50 11097.96 TSHC 8 8367.50 11119.76 TSAD 9 8393.50 11149.60 44SB 10 8413.50 11172.54 43SB ll 8438.50 11201.23 42SB 12 8478.50 11247.12 41 SB 13 8503.50 11275.81 TCGL 14 8528.50 11304.49 31 SB 15 8553.50 11333.17 BCGL 16 8601.50 11389.04 23SB 17 8640.50 11437.11 22TS 18 8703.50 11523.78 21TS 19 8758.50 11617.90 TZ16 20 I it 8793.50 11701.92 TZ1A/fDF 6600 6900 Vertical Sec[ion at 35.79° [300fUin] 7500 7800 CASING DETAILS No. TVD MD Name 8273.50 11011.91 5 I/2" 2 8768.51 12808.00 31/2 Siu 5.500 3.500 bJl l'UMPANY DElAlL5 dP Amlw~~ KI I FKI'N( I' W13INNIAII(1N l N -le IN 1:1K t W II l'wVC. IS-lb. Trw.•NoM ti11KV1:Y I'KIKiRAM IkpW I'm 1hpW li. Surv Y~1'W li~iil Plan: IS-36B Wp11((IS 3G/Plm IS 166) ClealUJ By T[oy Jakalkla'kYG~II~.;bp.G~81111•'4/12/2(X16 ('a4WalnuMMd: Mmimuml unalun VW'111V III K~I ib 11 63.511 \'1 'I11~~I KClirutu• 14t (tl WN,11 UlIN) IIIIINIIMI 1'_IiUN.15 Plmnrl: 153(4 up(Ifi V39 MWU +IPR+MS CWskod: Da1C I~mrtly~m: L1('WtiA M wnunil lkpih K.linnc 3_.5+i1 L3.511 ~ ti.au fi4lhd-. Ira. (ylioJ¢ Nnnh 1':JiuLnum McUnJ: htiomim l'mvaturc WF].L lld1ALLl ~ I:mrz \urfaa': I~I~irai~+l *l'avY1~ I Wamm4 AkMrl. Ru4 da; v1 Name +N,-S +}~-W NoMiog F tiog Lalilule Llwguuk SAn SECTION DETAILS IS3b L'1?31 55fi.M 5'XaN162-.311 fi76N?i7. 7U"1T47.15UN 17N"1iV3717W !L'A TARGET DETAILS Sec MD luc Azi TVD +N/-S +E/-W DLeg TFa(:e VSec Target Na3ne TVD +N/-S +E/-W Northing Easting Shape 1 10100.00 44.36 29.02 7510.57 5358.62 2650.82 0.00 0.00 5896.92 2 10120.00 44.62 32.42 7524.84 5370.66 2657.98 12.00 85.00 5910.88 IS-36B T4 8768.50 5988.17 4317.63 5966150.00 681000.00 Point ~ 3 10501.68 29.36 33.01 7828.80 5563.42 2781.55 4.00 178.91 6139.51 IS-36B T3 8773.50 5990.52 4217.65 5966150.00 680900.00 POinI 4 l 1348.19 29.36 33.01 8566.59 5911.48 3007.64 0.00 0.00 6554.06 IS-36B T2 8803.50 6029.92 3818.44 5966180.00 680500.00 Point 5 11851.50 90.00 80.00 8818.50 6080.50 3369.48 14.00 50.89 6902.79 IS-36B TI IS-368 geo poly 8813.50 6080.50 3369.48 5966220.00 680050.00 Polygon 6 11995.54 92.25 100.05 6815.65 6080.46 3512.75 14.00 83.47 6986.54 IS-36B TI 8818.50 6080.50 3369.48 5966220.00 680050.00 Point I 7 12204.63 92.25 100.05 8807.46 6044.01 3718.48 0.00 0.00 7077.30 I 8 12305.68 92.24 96.00 8803.50 6029.92 3818.44 4.00 -90.00 7124.34 IS-366 T2 9 12364.40 94.59 95.99 8800.00 6023.80 3876.73 4.00 -0.20 7153.46 CASING DETAILS 10 12636.56 94.59 95.99 6778.23 5995.48 4146.54 0.00 0.00 7288.29 I ll 12708.02 93.00 92.00 8773.50 5990.52 4217.65 6.00 -111.60 7325.85 IS-366 T3 No. TVD MD Name Size 12 12719.61 92.85 91.31 8772.90 5990.18 4229.42 6.00 -101.93 7332.46 13 12806.15 92.85 91.31 8768.50 5988.17 4317.63 0.00 0.00 7382.42 IS-366 T4 1 8273.50 11011.91 5 1/2" 5.500 2 8768.51 12808.00 31/2 3.500 _- _ -_ . __ _ - ---i--r-r---. _ ' T-. ---- - __ _. ___~ ._ --- . .. - ~~ - _ ._ .. --r _ __ I _ ~- _ ._~r- _ _-. _~_.-_ _ - ~-- . _- T~- End Dir : 11995.54' M D. 8815.65' TVD - _. - - --- 6300 - ---- - - --_ _ -- - -- Start Dir 4/ ' : t 2204.63' MD. 8807. TVD --- --- ° -- I5-3 6(15-36) - ----~ End Dv:12364.4'M 8800'TVD 3G T -. _ __ - __ __ ---- - - ~ ~ - -. . r - - •- -- - - - °-----~ -_ _. ~-~- - ~ - _._ _. 1/2 + ~_y- - - - - - ~ 1 •~ 6000 T - -~_ o -- r 0 O1 5 1. ~f / -~--- ~ ` 8000 ~ 1' _-T - - -- FORMATION TOP DETAILS --- i ~~ End D : 10501.68' MD, 7828.8' VD `^ ~' -'------ No. TVDPath MDPath Formation ~. - - _ -__- _ - ~ I I 7828.50 10501.33 THRZ -' Start Dir 4/1 ' : IO120' MD, 7524.84' D ---- -- - - 2 8023.50 10725.07 BHRZ 3 8123.50 10839.81 LCU _~ _ _ ' 4 8273.50 11011.91 TSGR 5 8313.50 11057.81 TSHA - - -- - 6 8343.50 11092.23 TSHB t - - --- - - - - 7 8348.50 11097.96 TSHC _ ~ - - - - 8 8367.50 11119.76 TSAR -_ -T 9 8393.50 11149.60 4456 Start Dir 12/1 ' :10100' MD, 7510.5TT D -~' ter--- ~*-' ' 10 8413.50 1 1172.54 4356 __ _ _ __ / II 8438.50 11201.23 42SB ___ ______ ,__ _-____ / 12 8478.50 11247.12 41SB 13 8503.50 11275.81 TCGL / 14 8528.50 11304.49 3ISB / IS 8553.50 1 .1 Ib 8601.50 11389.04 23SB ~ 17 8640.50 11437.11 22TS / O I8 8703.50 11523.78 21TS / ~ 19 8758.50 11617.90 TZIB / o v ~ 20 8793.50 11701.92 TZIA/1'DF 2700 3000 3300 3600 3900 4 ~ ~ +- ® "~ West(-)/East(+) [300fl/inJ ~.~ f-,0 Sperry-Sun i BP Planning Report Company: BP Amoco Date: 4/12/2006 Time: 10:05:05 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-36, True North Site: PB DS 15 Vertical (TVD) Reference: 32.5 +31 63.5 Well: 15-36 Section (VS) Reference: Well (O.OON,O.OOE,35.79Azi) ~Vellpath: Plan 15-36B Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 15-36B wp06 Date Composed: 11/29/2005 Version: 29 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plan e Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 15 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.34 deg Well: 15-36 Slot Name: Well Position: +N/-S 1212.31 ft Northing: 5960062.30 ft Latitude: 70 17 47.159 N +E/-W 556.36 ft Easting : 676824.72 ft Longitude: 148 34 4.997 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 11011.91 8273.50 5.500 6.750 51/2" 12808.00 8768.51 3.500 4.750 3 1 /2 Formations MD TVD Formations Lithology Dip Angle Dip Arection ft ft deg deg 10501.33 7828.50 THRZ 0.00 0.00 10725.07 8023.50 BHRZ 0.00 0.00 10839.81 8123.50 LCU 0.00 0.00 11011.91 8273.50 TSGR 0.00 0.00 11057.81 8313.50 TSHA 0.00 0.00 11092.23 8343.50 TSHB 0.00 0.00 11097.96 8348.50 TSHC 0.00 0.00 11119.76 8367.50 TSAD 0.00 0.00 11149.60 8393.50 44S6 0.00 0.00 11172.54 8413.50 43S6 0.00 0.00 11201.23 8438.50 42S6 0.00 0.00 11247.12 8478.50 41 SB 0.00 0.00 11275.81 8503.50 TCGL 0.00 0.00 11304.49 8528.50 31SB 0.00 0.00 11333.17 8553.50 BCGL 0.00 0.00 11389.04 8601.50 23S6 0.00 0.00 11437.11 8640.50 22TS 0.00 0.00 11523.78 8703.50 21TS 0.00 0.00 11617.90 8758.50 TZ16 0.00 0.00 11701.92 8793.50 TZ1A/TDF 0.00 0.00 0.00 BSAD/Kavik 0.00 0.00 Targets Map; Map <-- Latitude -> <- Longitude ---> Name Description TVD +N/-S +E/-W Northing Eastin g Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ' ft ft 15-36B T4 8768.50 5988.17 4317.63 5966150.00 681000. 00 70 18 46.040 N 148 31 59.046 W 15-366 T3 8773.50 5990.52 4217.65 5966150.00 680900. 00 70 18 46.064 N 148 32 1.963 W 15-366 T2 8803.50 6029.92 3818.44 5966180.00 680500.00 70 18 46.454 N 148 32 13.608 W Sperry-Sun '~ BP Planning Report Company: BP Amoco Date: 4/12/2006 Time: 10:05:05 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: W ell: 15-36, True North Site: PB DS 15 Vertical (TVD) Reference: 32.5 +31 63.5 We1L• 15-36 Section (VS) Reference: W ell (O.OON,O.OOE,35. 79Azi) ~Vellpath: Plan 15-36B Survey Calculation Method: Mi nimum Curvature Db: Oracle Targets Map Map <- Latitude --> <- Longitude --> Name De scription TVD +N/-S +E/-W Northing Eas6ng Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft; ` ft ft 15-36B geo poly 8813.50 6080.50 3369.48 5966220.00 680050.00 70 18 46.953 N 148 32 26.704 W -Polygon 1 8813.50 6096.57 4047.09 5966252.00 680727.00 70 18 47.108 N 148 32 6.937 W -Polygon 2 8813.50 6103.77 3826.18 5966254.00 680506.00 70 18 47.180 N 148 32 13.381 W -Polygon 3 8813.50 6198.92 3438.29 5966340.00 680116.00 70 18 48.117 N 148 32 24.695 W -Polygon 4 8813.50 6148.05 3091.98 5966281.00 679771.00 70 18 47.619 N 148 32 34.798 W -Polygon 5 8813.50 6005.01 3091.61 5966138.00 679774.00 70 18 46.212 N 148 32 34.811 W -Polygon 6 8813.50 5861.44 3666.43 5966008.00 680352.00 70 18 44.797 N 148 32 18.044 W -Polygon 7 8813.50 5871.34 4265.87 5966032.00 680951.00 70 18 44.892 N 148 32 0.558 W -Polygon 8 8813.50 5985.08 4703.69 5966156.00 681386.00 70 18 46.008 N 148 31 47.785 W -Polygon 9 8813.50 6264.14 4620.23 5966433.00 681296.00 70 18 48.753 N 148 31 50.214 W 15-366 T1 8818.50 6080.50 3369.48 5966220.00 680050.00 70 18 46.953 N 148 32 26.704 W Plan Section Information _ MD Incl Azim ...TVD +N/-S +E/-W DLS Build Turn ' TFO Targe t ft deg deg ft ft ft deg/100ft degl100ft deg/100ft deg 10100.00 44.36 29.02 7510.57 5358.62 2650.82 0.00 0.00 0.00 0.00 10120.00 44.62 32.42 7524.84 5370.66 2657.98 12.00 1.30 17.02 85.00 10501.68 29.36 33.01 7828.80 5563.42 2781.55 4.00 -4.00 0.15 178.91 11348.19 29.36 33.01 8566.59 5911.48 3007.64 0.00 0.00 0.00 0.00 11851.50 90.00 80.00 8818.50 6080.50 3369.48 14.00 12.05 9.34 50.89 15-36B T1 11995.54 92.25 100.05 8815.65 6080.46 3512.75 14.00 1.56 13.92 83.47 12204.63 92.25 100.05 8807.46 6044.01 3718.48 0.00 0.00 0.00 0.00 12305.68 92.24 96.00 8803.50 6029.92 3818.44 4.00 -0.01 -4.00 -90.00 15-36 6 T2 12364.40 94.59 95.99 8800.00 6023.80 3876.73 4.00 4.00 -0.01 -0.20 12636.56 94.59 95.99 8778.23 5995.48 4146.54 0.00 0.00 0.00 0.00 12708.02 93.00 92.00 8773.50 5990.52 4217.65 6.00 -2.22 -5.59 -111.60 15-36 B T3 12719.81 92.85 91.31 8772.90 5990.18 4229.42 6.00 -1.24 -5.88 -101.93 12808.15 92.85 91.31 8768.50 5988.17 4317.63 0.00 0.00 0.00 0.00 15-36 6 T4 Survey MD Intl _ Azim TVD Sys TVD - VS N/S E/W DLS MapN MapE TooUCo' ft deg deg ft ft ft ft ft deg/100ft ft ft 10100.00 44.36 29.02 7510.57 7447.07 5896.92 5358.62 2650.82 0.00 5965481.45 679348.57 Start Dir 1 10120.00 44.62 32.42 7524.84 7461.34 5910.88 5370.66 2657.98 12.00 5965493.66 679355.44 Start Dir 4/ 10200.00 41.42 32.51 7583.32 7519.82 5965.37 5416.71 2687.28 4.00 5965540.38 679383.64 MWD+IFR 10300.00 37.42 32.65 7660.55 7597.05 6028.76 5470.21 2721.46 4.00 5965594.67 679416.56 MWD+IFR 10400.00 33.43 32.81 7742.02 7678.52 6086.63 5518.97 2752.79 4.00 5965644.15 679446.73 MWD+IFR 10500.00 29.43 33.00 7827.34 7763.84 6138.69 5562.73 2781.10 4.00 5965688.57 679474.00 MWD+IFR 10501.33 29.37 33.01 7828.50 7765.00 6139.34 5563.28 2781.46 4.00 5965689.12 679474.35 THRZ 10501.68 29.36 33.01 7828.80 7765.30 6139.51 5563.42 2781.55 4.00 5965689.27 679474.44 End Dir : 1 10600.00 29.36 33.01 7914.49 7850.99 6187.66 5603.85 2807.81 0.00 5965730.30 679499.74 MWD+IFR 10700.00 29.36 33.01 8001.65 7938.15 6236.63 5644.97 2834.52 0.00 5965772.03 679525.47 MWD+IFR 10725.07 29.36 33.01 8023.50 7960.00 6248.91 5655.27 2841.22 0.00 5965782.49 679531.92 BHRZ 10800.00 29.36 33.01 8088.81 8025.31 6285.60 5686.08 2861.23 0.00 5965813.76 679551.20 MWD+IFR 10839.81 29.36 33.01 8123.50 8060.00 6305.10 5702.45 2871.86 0.00 5965830.37 679561.44 LCU 10900.00 29.36 33.01 8175.96 8112.46 6334.57 5727.20 2887.94 0.00 5965855.49 679576.93 MWD+IFR 11000.00 29.36 33.01 8263.12 8199.62 6383.54 5768.31 2914.65 0.00 5965897.22 679602.66 MWD+IFR 11011.91 29.36 33.01 8273.50 8210.00 6389.38 5773.21 2917.83 0.00 5965902.19 679605.73 5 1 /2" 11057.81 29.36 33.01 8313.50 8250.00 6411.85 5792.08 2930.08 0.00 5965921.34 679617.54 TSHA 11092.23 29.36 33.01 8343.50 8280.00 6428.71 5806.23 2939.28 0.00 5965935.70 679626.40 TSHB 11097.96 29.36 33.01 8348.50 8285.00 6431.52 5808.59 2940.81 0.00 5965938.10 679627.87 TSHC 11100.00 29.36 33.01 8350.27 8286.77 6432.52 5809.43 2941.35 0.00 5965938.95 679628.40 MWD+IFR 11119.76 29.36 33.01 8367.50 8304.00 6442.19 5817.56 2946.63 0.00 5965947.20 679633.48 TSAD 11149.60 29.36 33.01 8393.50 8330.00 6456.80 5829.82 2954.60 0.00 5965959.64 679641.16 44SB gent Sperry-Sun BP Planning Report Company: BP Amoco Date: 4/12/2006 Time: 10:05:05 Page: 3 Field: Pru dhoe Bay C o-ordinate(N E) Reference: Well: 15-36, True North Site: PB DS 15 V ertical (TVD ) Reference: 32. 5 +31 63.5 ~i'ell: 15- 36 Section (VS) Reference: Well (O.OON,O.OOE,35.79Azi) Wellpath: Pla n 15-366 Survey Calculation Method: Minimum Curvature Db: Oracle Sur~eV MD Incl rtim TVD Sys TVD VS N/S E/W DLS NIapN MapE Tool/Co ft deg ..deg ft ft ft ft ft deg/100ft ft ft 11172.54 29.36 33.01 8413.50 8350.00 6468.04 5839.26 2960.73 0.00 5965969.22 679647.06 43SB 11200.00 29.36 33.01 8437.43 8373.93 6481.49 5850.54 2968.06 0.00 5965980.68 679654.13 MWD+IFR 11201.23 29.36 33.01 8438.50 8375.00 6482.09 5851.05. 2968.39 0.00 5965981.19 679654.44 42S6 11247.12 29.36 33.01 8478.50 8415.00 6504.56 5869.92 2980.65 0.00 5966000.34 679666.25 41 SB 11275.81 29.36 33.01 8503.50 8440.00 6518.61 5881.71 2988.31 0.00 5966012.31 679673.64 TCGL 11300.00 29.36 33.01 8524.59 8461.09 6530.46 5891.66 2994.77 0.00 5966022.41 679679.86 MWD+IFR 11304.49 29.36 33.01 8528.50 8465.00 6532.66 5893.51 2995.97 0.00 5966024.28 679681.02 31 SB 11333.17 29.36 33.01 8553.50 8490.00 6546.70 5905.30 3003.63 0.00 5966036.25 679688.40 BCGL 11348.19 29.36 33.01 8566.59 8503.09 6554.06 5911.48 3007.64 0.00 5966042.52 679692.26 Start Dir 1 I 11389.04 33.24 41.12 8601.50 8538.00 6575.22 5928.32 3020.47 14.00 5966059.66 679704.69 23S6 11400.00 34.36 43.00 8610.61 8547.11 6581.28 5932.84 3024.55 14.00 5966064.28 679708.66 MWD+IFR 11437.11 38.33 48.65 8640.50 8577.00 6602.90 5948.11 3040.35 14.00 5966079.92 679724.09 22TS 11500.00 45.56 56.21 8687.28 8623.78 6643.04 5973.54 3073.71 14.00 5966106.11 679756.85 MWD+IFR 11523.78 48.40 58.58 8703.50 8640.00 6659.20 5982.90 3088.36 14.00 5966115.81 679771.27 21 TS 11600.00 57.78 64.97 8749.26 8685.76 6713.78 6011.48 3142.05 14.00 5966145.65 679824.27 MWD+IFR 11617.90 60.02 66.27 8758.50 8695.00 6727.07 6017.80 3156,00 14.00 5966152.30 679838.07 TZ1 B 11700.00 70.45 71.60 8792.86 8729.36 6789.30 6044.41 3225.50 14.00 5966180.53 679906.92 MWD+IFR 11701.92 70.70 71.72 8793.50 8730.00 6790.76 6044.98 3227.22 14.00 5966181.14 679908.62 TZ1A/TDF 11800.00 83.33 77.24 8815.51 8752.01 6865.11 6070.37 3319.11 14.00 5966208.69 679999.89 MWD+IFR 11851.50 90.00 80.00 8818.50 8755.00 6902.79 6080.50 3369.48 14.00 5966220.00 680050.00 15-366 T1 11900.00 90.77 86.75 8818.17 8754.67 6935.48 6086.10 3417.63 14.00 5966226.73 680098.00 MWD+IFR 11995.54 92.25 100.05 8815.65 8752.15 6986.54 6080.46 3512.75 14.00 5966223.33 680193.22 End Dir : 1 1 12000.00 92.25 100.05 8815.47 8751.97 6988.48 6079.68 3517.14 0.00 5966222.65 680197.63 MWD+IFR 12100.00 92.25 100.05 8811.56 8748.06 7031.88 6062.25 3615.53 0.00 5966207.54 680296.40 MWD+IFR 12200.00 92.25 100.05 8807.64 8744.14 7075.29 6044.82 3713.92 0.00 5966192.43 680395.16 MWD+IFR 12204.63 92.25 100.05 8807.46 8743.96 7077.30 6044.01 3718.48 0.00 5966191.74 680399.73 Start Dir 4/ 12300.00 92.24 96.23 8803.72 8740.22 7121.52 6030.53 3812.80 4.00 5966180.47 680494.34 MWD+IFR 12305.68 92.24 96.00 8803.50 8740.00 7124.34 6029.92 3818.44 4.00 5966180.00 680500.00 15-366 T2 12364.40 94.59 95.99 8800.00 8736.50 7153.46 6023.80 3876.73 4.00 5966175.25 680558.41 End Dir : 1 12400.00 94.59 95.99 8797.16 8733.66 7171.10 6020.10 3912.02 0.00 5966172.38 680593.78 MWD+IFR 12500.00 94.59 95.99 8789.16 8725.66 7220.64 6009.69 4011.16 0.00 5966164.31 680693.13 MWD+IFR 12600.00 94.59 95.99 8781.16 8717.66 7270.18 5999.29 4110.29 0.00 5966156.24 680792.47 MWD+IFR 12636.56 94.59 95.99 8778.23 8714.73 7288.29 5995.48 4146.54 0.00 5966153.29 680828.79 Start Dir 6/ 12700.00 93.18 92.45 8773.93 8710.43 7321.42 5990.83 4209.65 6.00 5966150.12 680891.99 MWD+IFR 12708.02 93.00 92.00 8773.50 8710.00 7325.85 5990.52 4217.65 6.00 5966150.00 680900.00 15-36B T3 12719.81 92.85 91.31 8772.90 8709.40 7332.46 5990.18 4229.42 6.00 5966149.94 680911.77 End Dir : 1 12800.00 92.85 91.31 8768.91 8705.41 7377.81 5988.35 4309.49 0.00 5966150.00 680991.86 MWD+IFR 12808.00 92.85 91.31 8768.51 8705.01 7382.33 5988.17 4317.48 0.00 5966150.00 680999.85 31/2 12808.15 92.85 91.31 8768.50 8705.00 7382.42 5988.17 4317.63 0.00 5966150.00 681000.00 15-366 T4 ent S 9 S S S 0 S 6 S S S 0 S 1 S W}1.L IRilAa.S ANTI-COLLISION SETTINGS l'GMrnNV u}3nas SIIRVF.Y PROGRAM Naux +N--C +L'-W NI'nhing Ivaivr. Lalllutlc InmEnuJc Nl~u tlY Auun~' lkplh I'm UcYm To 8wcy.PLw Innl Interyolation MethodMD Interval: 25.00 1576 I^_19.31 ss6. iG 5`)/ANffi'UI G~GN24T 711"1T4ZISYN 14N 34114.9'17W NA Depth Range From: 10100.00 To: 12808.15 fakuWGuu MelhrU. Mmmuml unalum IUIWIp 1'_NlIx.IS rlam°d_IS-J6tl wpl16 V2Y Mw'IHNx+MS Maximum Range: 1477.57 Reference: Plan: IS-36B wp06 }m'~xy~l.m. Ixcwsn kau hktkrJ: Irav ('Ylialu Nonh }nru 1urW«•. I:Ililxiul +l'asutg Wamiu6 M ti~rU: Rules tlaavl 160 150 0 2 bloat To MD - 0 500 1000 - 1500 2000 2500 3500 4500 5500 6500 - 7500 - 8500 9500 - 10500 11500 - 12500 - 13500 17aa 1576tl 1`almv WellpuW: 1536 1'ie rm MI1: IUI W.W ~B: ReC Ualum: L.5+31 fi35Ufl V.5 7Wa Oigy lhi8m SWIio6 AgJe +W-8 +}~-W Fmm'IVU 35.7Y° O.W O.W 72311 00 25 - Is36tl x~p16 Lu Aa 7VU +N'-x +P.'-W U1.:8 '1'Facc VSec 7'arBa 150 44 Sfi 44.fi2 2Y 112 3'_.42 75111.57 7524.84 535N L_' 577U.6fi 2GSII.R2 2657.Y8 U.IN) U.W 12.1X) BS INI 58'16.'1? 591U.RR 2'Y.36 .33.UI 782%811 iS6142 '_781.55 4.UI1 17N.YI 6139.51 '_'/.3fi 17.U1 8566.5y SYI I iN iUU764 I1.W U.(NI 6554.116 160 'NI.W BU.IN1 B8I %.511 MINI1.511 336Y.4A 14.W SU.BY 6W2.7Y IS-36B Ti Y2.s IIN).US 881565 FAINII ifi 3512.75 14.W 81.47 6Y86.54 92,2s IIN1.U5 8RU7.46 G)44U1 3718,48 O.W O.W 7077.SU R 121115.fi% Y2 .4 'M lN) 88111.AI GI12Y.12 3X18.44 4.W -YU.W 7124.34 15368 T2 '/ 127fi4.4U Y4.SY 5/, Y4 SY III I2fi3fi Y>!/') YS Y') BBW.INI 8778 ' 3 6103.x11 48 5715 3R7fi.73 414fi 54 4.W 41.2U O W O UII 7153.46 7'_88 '_Y Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOf~1in] . . II 127118.02 '11 W 12 1271Y.e1 Y2B5 13 I?8lN{.IS Y2.%5 T.W YI ,1 '11.31 . _ 8773.511 8772/x1 X76%.5(1 . 5'1'/11.5'_ 59)11.1% 5'I%R.17 . 4'_I7.fi5 4'_'_Y 42 4717.63 . . 6.W 111.611 61X1 ~IIlLY3 UUU U.(N) . 7125.85 15-3fiB T3 7332.46 71R'_A'_ 15-1611 T4 Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: l Field: Prudhoe Bay Reference Site: PB DS 15 Co-ordinate(NE) Refer ence: Well: 15-36, True North Reference Well: 15-36 Vertical (TVD) Reference: 32.5 +31 63.5 Reference Wellpath: Plan 15-36B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are T1reld~aaalls in this ft2tittCipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10100.00 to 12808.15 ft Scan Method: Trav Cylinder North Maximum Radius: 1477.57 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/29/2005 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 248.75 10100.00 1 : MWD -Standard (248.75-11810.75) (0) MWD MWD - Standard 10100.00 12808.15 Planned: 15-36B wp06 V29 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD ~Diameter Bole Size Nante- ff ft in in 11011.91 8273.50 5.500 6.750 51/2" 12808.00 8768.51 3.500 4.750 31/2 Summary <------- Offset Wellpath -- -----> Reference Offset Ctr-Ctr No-Go Allowable Site `Wep Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 15 15-16 15-16 V5 11666.61 11883.50 405.75 289.43 116.32 Pass: Major Risk PB DS 15 15-16 15-16A V3 11504.09 11750.00 517.22 310.73 206.49 Pass: Major Risk PB DS 15 15-20 15-20 V5 Out of range PB DS 15 15-20 15-20A V6 Out of range PB DS 15 15-20 15-20AP61 V6 Out of range PB DS 15 15-20 15-208 V5 Out of range PB DS 15 15-20 15-20C V2 Out of range PB DS 15 15-30 15-30 V3 12807.29 11300.00 936.08 291.87 644.21 Pass: Major Risk PB DS 15 15-30 15-30A V2 12807.29 11300.00 936.08 292.93 643.15 Pass: Major Risk PB DS 15 15-30 15-30APB1 V10 12807.29 11300.00 936.08 292.80 643.28 Pass: Major Risk PB DS 15 15-34 15-34 V1 Out of range PB DS 15 15-34 15-34A V1 Out of range PB DS 15 15-35 15-35 V1 Out of range PB DS 15 15-36 15-36 V1 10100.00 10100.00 0.00 0.60 -0.60 FAIL: NOERRORS PB DS 15 15-36 15-36A V2 10100.00 10100.00 0.00 0.60 -0.60 FAIL: NOERRORS PB DS 15 15-36 15-36APB1 V3 10100.00 10100.00 0.00 0.60 -0.60 FAIL: NOERRORS PB DS 15 15-37 15-37 V1 10106.67 10150.00 1041.62 331.74 709.89 Pass: Major Risk PB DS 15 15-37 15-37A V2 11245.58 12547.76 1090.69 395.97 694.72 Pass: Major Risk PB DS 15 15-37 15-37APB1 V1 11108.29 11225.00 955.62 248.17 707.45 Pass: Major Risk PB DS 15 15-37 15-37B V4 10105.68 10200.00 1174.20 186.05 988.15 Pass: Major Risk PB DS 15 15-38 15-38 V3 Out of range PB DS 15 15-38 15-38A V3 Out of range PB DS 15 15-38 15-38APB1 V3 Out of range PB DS 15 15-39 15-39 V1 Out of range PB DS 15 15-39 Plan 15-39A VO Plan: 1 Out of range PB DS 15 15-40 15-40 V1 Out of range PB DS 15 15-40A 15-40A V1 Out of range PB DS 15 15-40AP61 15-40AP61 V1 Out of range PB DS 15 15-40PB1 15-40PB1 V1 Out of range PB DS 15 15-40P62 15-40P62 V1 Out of range PB DS 15 15-41 15-41 V1 Out of range PB DS 15 15-41 15-41A V2 Out of range PB DS 15 15-41 15-41 B V3 Out of range PB DS 15 15-41 15-41 BP61 V1 Out of range PB DS 15 15-41 Plan#3 15-41A VO Plan: Out of range PB DS 15 15-44 15-44 V1 Out of range PB DS 15 15-49 15-49 V2 Out of range PB DS 15 15-49 15-49A V5 Out of range PB DS 15 15-49 15-49AP61 V2 Out of range PB DS 15 15-49 15-49PB1 V1 Out of range PB DS 15 15-49 Plan 15-498 VO Plan: 1 Out of range Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 2 Field: Prudhoe Bay Reference S ite: PB DS 15 Co-ordinate(NE) Refe rence: Well: 15-36, True Nor th Reference Well: 15-36 V ertical (TVD) Refere nce: 32.5 +31 63.5 Reference Weltpath: Plan 15-368 Db: Oracle Site: PB DS 1 5 Well: 15-16 Rule Assigned: Major Ris k Weltpath: 15-16 V5 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZF TFO-H S Casing/HSflistance Area Deviafion Warning ft ft ft ft ft ft deg deg in ft ft ft 10140.96 7539.87 10500.00 8094.75 73.40 37.08 191.71 159.27 10.750 857.43 177.49 679.93 Pass 10197.73 7581.62 10525.00 8111.59 73.54 37.10 191.53 159.02 10.750 856.36 178.06 678.30 Pass 10254.02 7624.50 10550.00 8128.38 73.66 37.11 191.33 158.74 10.750 854.30 178.59 675.71 Pass 10309.67 7668.25 10575.00 8145.13 73.78 37.13 191.10 158.44 10.750 851.29 179.17 672.11 Pass 10364.49 7712.64 10600.00 8161.82 73.90 37.14 190.84 158.10 10.750 847.33 179.75 667.58 Pass 10418.28 7757.34 10625.00 8178.40 74.00 37.16 190.56 157.72 10.750 842.38 180.41 661.97 Pass 10470.84 7802.09 10650.00 8194.84 74.10 37.17 190.25 157.31 10.750 836.47 181.13 655.34 Pass 10511.07 7836.99 10675.00 8211.13 74.18 37.18 189.90 156.89 10.750 829.69 182.24 647.45 Pass 10534.45 7857.36 10700.00 8227.29 74.21 37.19 189.52 156.52 10.750 822.66 183.78 638.88 Pass 10557.78 7877.70 10725.00 8243.36 74.25 37.20 189.14 156.14 10.750 815.53 185.36 630.17 Pass 10581.08 7898.00 10750.00 8259.34 74.28 37.21 188.75 155.75 10.750 808.34 186.98 621.36 Pass 10604.34 7918.28 10775.00 8275.25 74.32 37.22 188.36 155.35 10.750 801.07 188.63 612.44 Pass 10627.58 7938.53 10800.00 8291.07 74.35 37.22 187.95 154.95 7.000 793.73 190.17 603.56 Pass 10650.78 7958.75 10825.00 8306.83 74.39 37.24 187.55 154.54 7.000 786.32 191.91 594.42 Pass 10673.95 7978.95 10850.00 8322.52 74.42 37.25 187.13 154.13 7.000 778.83 193.66 585.17 Pass 10697.10 7999.12 10875.00 8338.14 74.46 37.26 186.72 153.71 7.000 771.26 195.45 575.81 Pass 10720.21 8019.27 10900.00 8353.69 74.49 37.27 186.29 153.28 7.000 763.61 197.26 566.35 Pass 10743.26 8039.35 10925.00 8369.10 74.53 37.28 185.86 152.85 7.000 755.84 199.14 .556.70 Pass 10766.23 8059.37 10950.00 8384.34 74.56 37.30 185.40 152.39 7.000 747.96 201.10 546.86 Pass 10789.11 8079.32 10975.00 8399.42 74.60 37.31 184.93 151.92 7.000 739.96 203.13 536.83 Pass 10811.91 8099.19 11000.00 8414.33 74.63 37.33 184.44 151.44 7.000 731.85 205.24 526.60 Pass 10834.62 8118.98 11025.00 8429.06 74.67 37.34 183.94 150.93 7.000 723.60 207.44 516.16 Pass 10857.23 8138.69 11050.00 8443.61 74.70 37.36 183.41 150.41 7.000 715.21 209.72 505.49 Pass 10879.75 8158.32 11075.00 8457.97 74.74 37.38 182.87 149.86 7.000 706.69 212.08 494.62 Pass 10902.18 8177.86 11100.00 8472.14 74.77 37.40 182.31 149.30 7.000 698.05 214.52 483.53 Pass 10924.53 8197.34 11125.00 8486.19 74.81 37.42 181.73 148.72 7.000 689.33 217.05 472.28 Pass 10946.84 8216.78 11150.00 8500.14 74.84 37.44 181.14 148.13 7.000 680.55 219.64 460.92 Pass 10969.09 8236.17 11175.00 8513.99 74.87 37.46 180.52 147.52 7.000 671.72 222.29 449.43 Pass 10991.28 8255.52 11200.00 8527.73 74.91 37.48 179.90 146.89 7.000 662.84 225.03 437.82 Pass 11013.42 8274.82 11225.00 8541.37 74.94 37.50 179.25 146.24 7.000 653.94 227.84 426.10 Pass 11035.52 8294.08 11250.00 8554.93 74.98 37.53 178.58 145.58 7.000 645.00 230.73 414.28 Pass 11057.57 8313.29 11275.00 8568.40 75.01 37.55 177.90 144.89 7.000 636.05 233.69 402.36 Pass 11079.56 8332.46 11300.00 8581.77 75.05 37.58 177.19 144.18 7.000 627.08 236.73 390.35 Pass 11101.45 8351.54 11325.00 8594.95 75.08 37.60 176.45 143.44 7.000 618.05 239.82 378.23 Pass 11123.20 8370.50 11350.00 8607.90 75.11 37.63 175.68 142.67 7.000 608.93 243.12 365.82 Pass 11144.83 8389.34 11375.00 8620.62 75.15 37.66 174.87 141.86 7.000 599.76 246.56 353.20 Pass 11166.32 8408.07 11400.00 8633.11 75.18 37.68 174.02 141.01 7.000 590.54 250.14 340.40 Pass 11187.71 8426.72 11425.00 8645.44 75.21 37.71 173.12 140.12 7.000 581.35 253.86 327.49 Pass 11209.01 8445.29 11450.00 8657.62 75.25 37:74 172.19 139.19 7.000 572.22 257.72 314.51 Pass 11230.23 8463.78 11475.00 8669.65 75.28 37.77 171.22 138.21 7.000 563.18 261.71 301.47 Pass 11251.35 8482.19 11500.00 8681.54 75.31 37.80 170.20 137.19 7.000 554.22 265.84 288.38 Pass 11272.37 8500.50 11525.00 8693.25 75.35 37.84 169.14 136.13 7.000 545.35 270.12 275.23 Pass 11293.26 8518.71 11550.00 8704.77 75.38 37.87 168.02 135.01 7.000 536.56 274.53 262.03 Pass 11314.04 8536.82 11575.00 8716.10 75.41 37.90 166.85 133.84 7.000 527.88 279.09 248.79 Pass 11334.69 8554.82 11600.00 8727.23 75.44 37.94 165.63 132.62 7.000 519.32 283.78 235.54 Pass 11357.03 8574.26 11625.00 8738.12 75.37 38.00 164.61 129.69 7.000 510.82 288.69 222.12 Pass 11383.72 8597.04 11650.00 8748.76 75.00 38.07 164.16 124.00 7.000 502.20 292.88 209.32 Pass 11411.67 8620.17 11675.00 8759.15 74.39 38.05 163.86 118.96 7.000 493.34 296.34 196.99 Pass 11440.74 8643.34 11700.00 8769.29 73.50 37.93 163.72 114.57 7.000 484.17 298.97 185.19 Pass 11470.85 8666.26 11725.00 8779.36 72.34 37.71 163.76 110.79 7.000 474.72 300.63 174.09 Pass 11501.79 8688.52 11750.00 8789.40 70.89 37.38 164.02 107.62 7.000 464.97 301.28 163.69 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 3 Field: Prudhoe Bay Reference S ite: PB DS 15 Co -ordinate( NE) Reference: Well: 15-36, True North Reference Well: 1 5-36 Yertital (TV D) Reference: 32.5 +31 63.5 Reference Wellpath: Plan 15-36B Db: Oracle Site: PB DS 15 We1L• 15-16 Rule Assigned: Major Ris k Wellpath: 15-16 V5 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Asis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZ i TF0-HS Casing/H SDistance Area Deviation Wnrning ft ft ft ft ft ft deg - deg in ft ft ft 11533.21 8709.69 11775.00 8799.41 69.16 36.94 164.49 105.03 7.000 454.83 300.95 153.88 Pass 11564.77 8729.35 11800.00 8809.41 67.21 36.40 165.18 102.97 7.000 444.26 299.59 144.67 Pass 11596.10 8747.16 11825.00 8819.40 65.09 35.78 166.11 101.43 7.000 433.25 297.31 135.94 Pass 11626.86 8762.90 11850.00 8829.38 62.87 35.11 167.27 100.37 7.000 421.78 294.29 127.49 Pass 11656.71 8776.43 11875.00 8839.37 60.62 34.41 168.66 99.76 7.000 409.89 290.74 119.15 Pass 11666.61 8780.53 11883.50 8842.77 59.86 34.17 169.19 99.65 7.000 405.75 289.43 116.32 Pass Site: PB DS 15 Well: 15-16 Rule Assigned: Major Risk Wellpath: 15-16A V3 Inter-Site Error: 0.00 ft Reference Offset. Semi-Major Axis' Ctr-Ctr No-Go Allowable MD TVp MD TVD Ref Offset , TFO+AZI TFO-HS Casing( HSflistance Area Deviation Waning ft ft ft ft ft ft ° deg deg in ft ft ft 10140.96 7539.87 10500.00 8094.75 73.40 37.08 191.71 159.27 9.625 857.43 177.45 679.98 Pass 10197.73 7581.62 10525.00 8111.59 73.54 37.10 191.53 159.02 9.625 856.36 178.01 678.34 Pass 10254.02 7624.50 10550.00 8128.38 73.66 37.11 191.33 158.74 9.625 854.30 178.54 675.76 Pass 10309.67 7668.25 10575.00 8145.13 73.78 37.13 191.10 158.44 9.625 851.29 179.13 672.16 Pass 10364.49 7712.64 10600.00 8161.82 73.90 37.14 190.84 158.10 9.625 847.33 179.70 667.62 Pass 10418.28 7757.34 10625.00 8178.40 74.00 37.16 190.56 157.72 9.625 842.38 180.37 662.02 Pass 10470.84 7802.09 10650.00 8194.84 74.10 37.17 190.25 157.31 9.625 836.47 181.09 655.38 Pass 10511.07 7836.99 10675.00 8211.13 74.18 37.18 189.90 156.89 9.625 829.69 182.20 647.50 Pass 10534.45 7857.36 10700.00 8227.29 74.21 37.19 189.52 156.52 9.625 822.66 183.73 638.93 Pass 10557.78 7877.70 10725.00 8243.36 74.25 37.20 189.14 156.14 9.625 815.53 185.31 630.22 Pass 10581.08 7898.00 10750.00 8259.34 74.28 37.21 188.75 155.75 9.625 808.34 186.93 621.40 Pass 10604.34 7918.28 10775.00 8275.25 74.32 37.22 188.36 155.35 9.625 801.07 188.59 612.48 Pass 10627.58 7938.53 10800.00 8291.07 74.35 37.22 187.95 154.95 7.000 793.73 190.17 603.56 Pass 10650.78 7958.75 10825.00 8306.83 74.39 37.24 187.55 154.54 7.000 786.32 191.91 594.42 Pass 10673.95 7978.95 10850.00 8322.52 74.42 37.25 187.13 154.13 7.000 778.83 193.66 585.17 Pass 10697.10 7999.12 10875.00 8338.14 74.46 37.26 186.72 153.71 7.000 771.26 195.45 575.81 Pass 10720.21 8019.27 10900.00 8353.69 74.49 37.27 186.29 153.28 7.000 763.61 197.26 566.35 Pass 10743.26 8039.35 10925.00 8369.10 74.53 37.28 185.86 152.85 7.000 755.84 199.14 556.70 Pass 10766.23 8059.37 10950.00 8384.34 74.56 37.30 185.40 152.39 7.000 747.96 201.10 546.86 Pass 10789.11 8079.32 10975.00 8399.42 74.60 37.31 184.93 151.92 7.000 739.96 203.13 536.83 Pass 10811.91 8099.19 11000.00 8414.33 74.63 37.33 184.44 151.44 7.000 731.85 205.24 526.60 Pass 10834.62 8118.98 11025.00 8429.06 74.67 37.34 183.94 150.93 7.000 723.60 207.44 516.16 Pass 10857.23 8138.69 11050.00 8443.61 74.70 37.36 183.41 150.41 7.000 715.21 209.72 505.49 Pass 10879.75 8158.32 11075.00 8457.97 74.74 37.38 182.87 149.86 7.000 706.69 212.08 494.62 Pass 10902.18 8177.86 11100.00 8472.14 74.77 37.40 182.31 149.30 7.000 698.05 214.52 483.53 Pass 10924.53 8197.34 11125.00 8486.19 74.81 37.42 181.73 148.72 7.000 689.33 217.05 472.28 Pass 10946.84 8216.78 11150.00 8500.14 74.84 37.44 181.14 148.13 7.000 680.55 219.64 460.92 Pass 10969.09 8236.17 11175.00 8513.99 74.87 37.46 180.52 147.52 7.000 671.72 222.29 449.43 Pass 10991.28 8255.52 11200.00 8527.73 74.91 37.48 179.90 146.89 7.000 662.84 225.03 437.82 Pass 11013.42 8274.82 11225.00 8541.37 74.94 37.50 179.25 146.24 7.000 653.94 227.84 426.10 Pass 11035.52 8294.08 11250.00 8554.93 74.98 37.53 178.58 145.58 7.000 645.00 230.73 414.28 Pass 11057.57 8313.29 11275.00 8568.40 75.01 37.55 177.90 144.89 7.000 636.05 233.69 402.36 Pass 11079.56 8332.46 11300.00 8581.77 75.05 37.58 177.19 144.18 7.000 627.08 236.73 390.35 Pass 11101.45 8351.54 11325.00 8594.95 75.08 37.60 176.45 143.44 7.000 618.05 239.82 378.23 Pass 11123.20 8370.50 11350.00 8607.90 75.11 37.63 175.68 142.67 7.000 608.93 243.12 365.82 Pass 11144.83 8389.34 11375.00 8620.62 75.15 37.66 174.87 141.86 7.000 599.76 246.56 353.20 Pass 11166.32 8408.07 11400.00 8633.11 75.18 37.68 174.02 141.01 7.000 590.54 250.14 340.40 Pass 11187.71 8426.72 11425.00 8645.44 75.21 37.71 173.12 140.12 7.000 581.35 253.86 327.49 Pass 11209.01 8445.29 11450.00 8657.62 75.25 37.74 172.19 139.19 7.000 572.22 257.72 314.51 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 4 Field: P rudhoe Bay Reference S ite: P B DS 15 Co-ordinate(NE) Reference: Well: 15-36, True North Reference Welt: 1 5-36 Vertical (TV D) Reference: 32.5 +31 63.5 Reference Wellpath: P lan 15-366 Db: Oracle Site: PB DS 15 Well: 15-16 Rule Assigned: Major Risk Wellpath: 15-16A V3 Inter-Site Error: 0.00 ft Refe rence Offset Semi-M ajor Aacis Ctr-Ctr No-Go Allowable MD TVD MD T'VD Ref Offset TFO+AZf-TFO HS Casing/ HSflistance Area De~~ation Wanting ft ft ft ft ft ft deg deg in ft ft ft 11230.23 8463.78 11475.00 8669.65 75.28 37.77 171.22 138.21 7.000 563.18 261.71 301.47 Pass 11251.35 8482.19 11500.00 8681.54 75.31 37.80 170.20 137.19 2.375 554.22 265.65 288.58 Pass 11272.37 8500.50 11525.00 8693.25 75.35 37.84 169.14 136.13 2.375 545.35 269.92 275.43 Pass 11293.57 8518.98 11550.00 8705.32 75.38 37.85 168.01 135.00 2.375 537.48 274.34 263.14 Pass 11315.25 8537.88 11575.00 8718.46 75.41 37.87 166.81 133.80 2.375 532.13 280.29 251.85 Pass 11336.17 8556.11 11600.00 8730.71 75.45 37.87 165.39 132.38 2.375 528.33 285.47 242.86 Pass 11358.21 8575.28 11625.00 8741.58 75.36 37.91 164.05 128.88 2.375 525.72 291.39 234.33 Pass 11385.34 8598.40 11650.00 8752.31 74.97 37.94 163.31 122.85 2.375 522.81 296.31 226.50 Pass 11414.49 8622.46 11675.00 8762.69 74.31 37.89 162.73 117.39 2.375 520.10 300.41 219.69 Pass 11444.57 8646.32 11700.00 8771.36 73.37 37.73 162.14 112.47 2.375 517.98 304.06 213.92 Pass 11474.42 8668.90 11725.00 8776.78 72.20 37.48 161.37 107.98 2.375 516.70 307.56 209.14 Pass 11504.09 8690.13 11750.00 8779.01 70.77 37.14 160.44 103.81 2.375 517.22 310.73 206.49 Pass 11534.13 8710.28 11775.00 8778.74 69.10 36.71 159.48 99.93 2.375 520.66 313.06 207.60 Pass 11565.71 8729.91 11800.00 8777.59 67.15 36.17 158.73 96.44 2.375 528.58 313.82 214.76 Pass 11598.66 8748.54 11825.00 8775.65 64.91 35.52 158.28 93.41 2.375 540.37 312.67 227.69 Pass 11633.41 8766.02 11850.00 8773.55 62.38 34.75 158.23 90.88 2.375 555.37 309.50 245.87 Pass 11670.50 8782.09 11875.00 8772.30 59.56 33.87 158.72 88.93 2.375 572.99 304.12 268.88 Pass 11709.67 8796.00 11900.00 8772.16 56.57 32.91 159.75 87.57 2.375 592.37 296.89 295.47 Pass 11750.20 8806.96 11925.00 8772.29 53.60 31.93 161.17 86.67 2.375 612.75 288.26 324.50 Pass 12055.83 8813.29 11950.00 8771.74 29.40 21.31 186.24 86.20 2.375 626.73 174.05 452.68 Pass 12076.18 8812.49 11975.00 8771.12 29.45 21.38 186.34 86.30 2.375 641.19 174.46 466.73 Pass 12095.47 8811.73 12000.00 8770.20 29.51 21.46 186.42 86.37 2.375 657.07 174.96 482.10 Pass 12113.61 8811.02 12025.00 8768.94 29.56 21.53 186.46 86.42 2.375 674.25 175.42 498.83 Pass 12130.63 8810.36 12050.00 8767.54 29.61 21.59 186.50 86.45 2.375 692.55 175.86 516.69 Pass 12147.36 8809.70 12075.00 8766.40 29.66 21.66 186.55 86.51 2.375 711.12 176.32 534.80 Pass 12164.48 8809.03 12100.00 8765.78 29.71 21.74 186.64 86.60 2.375 729.30 176.83 552.46 Pass 12182.40 8808.33 12125.00 8765.77 29.76 21.82 186.78 86.73 2.375 746.65 177.40 569.25 Pass 12201.07 8807.60 12150.00 8766.34 29.81 21.91 186.94 86.90 2.375 763.12 178.04 585.08 Pass 12204.63 8807.46 12175.00 8767.35 29.82 22.01 187.14 87.09 2.375 778.83 178.56 600.27 Pass 12227.63 8806.56 12200.00 8768.80 30.73 22.50 186.40 87.27 2.375 793.80 183.55 610.25 Pass 12240.53 8806.05 12225.00 8770.52 31.24 22.82 186.09 87.48 2.375 808.32 186.60 621.71 Pass 12253.77 8805.53 12250.00 8772.04 31.77 23.16 185.74 87.66 2.375 821.92 189.70 632.22 Pass 12267.23 8805.00 12275.00 8772.97 32.30 23.51 185.34 87.80 2.375 834.90 192.83 642.07 Pass 12280.80 8804.47 12300.00 8773.04 32.84 23.85 184.87 87.87 2.375 847.51 195.92 651.59 Pass 12305.68 8803.50 12325.00 8772.91 33.82 24.39 183.91 87.91 2.375 859.72 201.17 658.54 Pass 12310.02 8803.32 12350.00 8773.28 33.89 24.55 184.02 88.02 2.375 871.01 201.75 669.26 Pass 12333.09 8802.17 12375.00 8773.92 34.27 24.77 184.16 88.16 2.375 881.35 202.53 678.82 Pass 12356.60 8800.61 12400.00 8774.77 34.66 25.00 184.33 88.33 2.375 890.48 203.27 687.21 Pass 12380.23 8798.74 12425.00 8775.81 34.84 25.18 184.52 88.53 2.375 898.38 204.14 694.24 Pass 12404.15 8796.82 12450.00 8776.66 34.92 25.35 184.71 88.72 2.375 905.05 205.12 699.93 Pass 12428.44 8794.88 12475.00 8776.83 35.00 25.52 184.85 88.86 2.375 910.50 206.08 704.42 Pass 12453.02 8792.91 12500.00 8776.04 35.09 25.71 184.93 88.94 2.375 914.87 207.02 707.85 Pass 12477.62 8790.95 12525.00 8774.86 35.17 25.90 184.99 88.99 2.375 919.18 207.97 711.21 Pass 12502.08 8788.99 12550.00 8773.82 35.25 26.09 185.05 89.06 2.375 924.26 208.92 715.34 Pass 12526.36 8787.05 12575.00 8772.94 35.33 26.29 185.12 89.13 2.375 930.10 209.88 720.22 Pass 12550.39 8785.12 12600.00 8772.16 35.42 26.48 185.20 89.20 2.375 936.89 210.86 726.03 Pass 12573.96 8783.24 12625.00 8771.37 35.50 26.68 185.27 89.28 2.375 945.12 211.84 733.28 Pass 12596.98 8781.40 12650.00 8770.57 35.58 26.89 185.34 89.35 2.375 954.80 212.81 741.99 Pass 12619.52 8779.59 12675.00 8769.66 35.66 27.09 185.40 89.41 2.375 965.55 213.76 751.78 Pass 12639.21 8778.02 12700.00 8768.49 35.85 27.33 185.28 89.44 2.375 976.98 215.30 761.68 Pass 12650.00 8777.19 12725.00 8766.74 36.37 27.71 184.63 89.39 2.375 989.88 218.60 771.29 Pass Sperry-Sun Anticollision Report Company: B P Amoco Da te: 4/12 /2006 Tim e: 09:51: 06 Page: 5 Field: P rudhoe Bay Reference S ite: P B DS 15 Co -ordinate(NE) Refe rence: Well: 15- 36, True North Reference Well: 1 5-36 Ve rtical (TV D) Refere nce: 32.5 +31 63.5 Reference Wellpath: P lan 15-366 ~ Db: Oracle Site: PB DS 15 WeIL• 15-16 Rule Assigned: Major Risk Wellpath: 15-16A V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZL TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg.. deg in ft ft ft 12660.38 8776.43 12750.00 8764.33 36.90 28.07 183.97 89.31 2.375 1004.53 221.72 782.81 Pass 12669.89 8775.78 12775.00 8761.38 37.39 28.40 183.32 89.19 2.375 1020.77 224.56 796.22 Pass 12678.73 8775.20 12800.00 8758.38 37.84 28.70 182.70 89.07 2.375 1038.31 227.17 811.14 Pass 12687.08 8774.68 12825.00 8756.25 38.27 28.99 182.17 89.00 2.375 1056.70 229.67 827.04 Pass 12700.00 8773.93 12850.00 8755.39 38.93 29.35 181.43 88.98 2.375 1075.78 233.27 842.51 Pass 12702.38 8773.80 12875.00 8755.05 39.06 29.52 181.33 89.02 2.375 1095.57 234.31 861.26 Pass 12709.03 8773.45 12900.00 8755.07 39.42 29.75 181.00 89.06 2.375 1116.31 236.35 879.95 Pass 12714.68 8773.16 12925.00 8755.15 39.76 29.94 180.70 89.09 2.375 1138.09 238.14 899.95 Pass 12719.38 8772.92 12950.00 8754.64 40.03 30.11 180.43 89.10 2.375 1160.88 239.60 921.28 Pass 12727.47 8772.52 12975.00 8753.58 40.09 30.19 180.39 89.08 2.375 1184.35 240.02 944.33 Pass 12735.20 8772.13 13000.00 8753.11 40.12 30.25 180.40 89.10 2.375 1208.12 240.32 967.80 Pass 12743.29 8771.73 13025.00 8753.30 40.15 30.32 180.45 89.14 2.375 1231.75 240.67 991.08 Pass 12752.64 8771.26 13050.00 8753.87 40.18 30.40 180.51 89.20 2.375 1254.90 241.06 1013.84 Pass 12762.44 8770.78 13075.00 8755.26 40.22 30.49 180.61 89.30 2.375 1277.79 241.51 1036.28 Pass 12773.29 8770.24 13100.00 8757.13 40.26 30.58 180.73 89.42 2.375 1300.15 242.00 1058.15 Pass 12785.38 8769.63 13125.00 8759.07 40.30 30.70 180.85 89.54 2.375 1321.86 242.57 1079.29 Pass 12798.53 8768.98 13150.00 8760.59 40.35 30.82 180.95 89.64 2.375 1342.99 243.15 1099.83 Pass Site: PB DS 15 Well: 15-30 Rule Assigned: Major Risk WeHpath: 15-30 V3 Inter-Site Error: 0.00 ft Reference Offset ` Semi-Major Axis Ctr-Ctr No-Go Atloavable MD TVI) MD TW Ref Offset `TFO+AZI TFO-HS Casingl HSflistance Area Deviation ~'~'arning ft ft ft ft ft ft deg deg in ft ft< ft 12607.17 8780.58 10625.00 8332.96 35.61 40.42 168.28 72.28 7.000 1475.79 223.47 1252.32 Pass 12617.72 8779.74 10650.00 8347.67 35.65 40.58 168.66 72.67 7.000 1455.42 224.82 1230.60 Pass 12628.38 8778.89 10675.00 8362.31 35.69 40.74 169.06 73.07 7.000 1435.14 226.18 1208.96 Pass 12637.60 8778.15 10700.00 8376.88 35.77 40.96 169.40 73.47 7.000 1414.96 227.95 1187.01 Pass 12642.02 8777.80 10725.00 8391.36 35.98 41.33 169.55 73.87 7.000 1394.88 230.99 1163.89 Pass 12646,49 8777.46 10750.00 8405.69 36.20 41.71 169.70 74.26 7.000 1374.78 234.06 1140.72 Pass 12650.00 8777.19 10775.00 8419.86 36.37 42.04 169.91 74.67 7.000 1354.66 236.74 1117.92 Pass 12650.00 8777.19 10800.00 8433.87 36.37 42.21 170.33 75.09 7.000 1334.54 238.00 1096.53 Pass 12660.21 8776.45 10825.00 8447.73 36.90 42.87 170.15 75.48 7.000 1314.36 243.35 1071.01 Pass 12664.92 8776.12 10850.00 8461.45 37.14 43.26 170.30 75.89 7.000 1294.23 246.49 1047.74 Pass 12669.70 8775.79 10875.00 8475.02 37.38 43.67 170.45 76.31 7.000 1274.13 249.67 1024.46 Pass 12674.55 8775.47 10900.00 8488.46 37.63 44.08 170.61 76.74 7.000 1254.06 252.88 1001.18 Pass 12679.48 8775.15 10925.00 8501.76 37.88 44.49 170.77 77.17 7.000 1234.00 256.10 977.89 Pass 12684.47 8774.84 10950.00 8514.93 38.14 44.91 170.93 77.61 7.000 1213.95 259.35 954.60 Pass 12689.53 8774.53 10975.00 8527.96 38.40 45.33 171.09 78.06 7.000 1193.92 262.63 931.29 Pass 12700.00 8773.93 11000.00 8540.85 38.93 46.04 170.94 78.50 7.000 1173.94 268.05 905.89 Pass 12700.00 8773.93 11025.00 8553.62 38.93 46.21 171.42 78.98 7.000 1153.97 269.30 884.66 Pass 12705.25 8773.65 11050.00 8566.27 39.21 46.65 171.60 79.45 7.000 1134.09 272.64 861.46 Pass 12710.67 8773.36 11075.00 8578.78 39.52 47.12 171.77 79.93 7.000 1114.30 276.05 838.24 Pass 12716.16 8773.08 11100.00 8591.14 39.84 47.61 171.94 80.42 7.000 1094.56 279.53 815.04 Pass 12723.97 8772.69 11125.00 8603.32 40.07 47.99 172.23 80.92 7.000 1074.88 282.30 792.58 Pass 12735.96 8772.09 11150.00 8615.32 40.12 48.17 172.75 81.45 7.000 1055.21 283.70 771.51 Pass 12747.94 8771.50 11175.00 8627.13 40.16 48.34 173.28 81.98 7.000 1035.52 285.10 750.42 Pass 12759.89 8770.90 11200.00 8638.69 40.21 48.52 173.82 82.51 7.000 1015.77 286.48 729.29 Pass 12771.81 8770.31 11225.00 8650.00 40.25 48.69 174.36 83.05 7.000 995.95 287.85 708.10 Pass 12783.68 8769.72 11250.00 8661.06 40.30 48.87 174.91 83.60 7.000 976.07 289.21 686.86 Pass 12795.52 8769.13 11275.00 8671.85 40.34 49.04 175.46 84.15 7.000 956.12 290.55 665.57 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 6 Field: P rudhoe Bay Reference S ite: P B DS 15 Co -ordinate(NE) Refe rence: Well: 15- 36, True Nor th Reference Well: 1 5-36 Vertical (TV D) Refere nce: 32.5 +31 63.5 Reference Wellpath: P lan 15-36B Db: Oracle Site: PB DS 15 Well: 15-30 Rule Assigned: Major Risk Wellpath: 15-30 V3 Inter-Site Error: 0.00 ft Refe rence ~ Offset Senu-M ajor Axis Ctr-Ctr No-Go Allowable MD TVD IVTD TVD Ref Offset TFO+AZI TFd-HS Casing/HS>Distance Area Deviation Warning ft ft ft ft ft ft deg' deg in ft ft ft 12807.29 8768.54 11300.00 8682.36 40.39 49.21 176.02 84.71 7.000 936.08 291.87 644.21 Pass Site: PB DS 15 Well: 15-30 Rule Ass igned: Major Risk Wellpath: 15-30A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-bT ajor Aeis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFQ+A~I T[+O-HSCasing/H~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 12607.17 8780.58 10625.00 8332.96 35.61 40.69 168.28 72.28 7.000 1475.79 224.23 1251.56 Pass 12617.72 8779.74 10650.00 8347.67 35.65 40.85 168.66 72.67 7.000 1455.42 225.58 1229.84 Pass 12628.38 8778.89 10675.00 8362.31 35.69 41.01 169.06 73.07 7.000 1435.14 226.95 1208.19 Pass 12637.60 8778.15 10700.00 8376.88 35.77 41.23 169.40 73.47 7.000 1414.96 228.73 1186.24 Pass 12642.02 8777.80 10725.00 8391.36 35.98 41.60 169.55 73.87 7.000 1394.88 231.78 1163.10 Pass 12646.49 8777.46 10750.00 8405.69 36.20 41.99 169.70 74.26 7.000 1374.78 234.86 1139.92 Pass 12650.00 8777.19 10775.00 8419.86 36.37 42.32 169.91 74.67 7.000 1354.66 237.55 1117.10 Pass 12650.00 8777.19 10800.00 8433.87 36.37 42.49 170.33 75.09 7.000 1334.54 238.83 1095.71 Pass 12660.21 8776.45 10825.00 8447.73 36.90 43.16 170.15 75.48 7.000 1314.36 244.20 1070.16 Pass 12664.92 8776.12 10850.00 8461.45 37.14 43.56 170.30 75.89 7.000 1294.23 247.36 1046.87 Pass 12669.70 8775.79 10875.00 8475.02 37.38 43.97 170.45 76.31 7.000 1274.13 250.55 1023.58 Pass 12674.55 8775.47 10900.00 8488.46 37.63 44.38 170.61 76.74 7.000 1254.06 253.77 1000.29 Pass 12679.48 8775.15 10925.00 8501.76 37.88 44.80 170.77 77.17 7.000 1234.00 257.01 976.99 Pass 12684.47 8774.84 10950.00 8514.93 38.14 45.22 170.93 77.61 7.000 1213.95 260.27 953.68 Pass 12689.53 8774.53 10975.00 8527.96 38.40 45.65 171.09 78.06 7.000 1193.92 263.56 930.35 Pass 12700.00 8773.93 11000.00 8540.85 38.93 46.36 170.94 78.50 7.000 1173.94 269.00 904.93 Pass 12700.00 8773.93 11025.00 8553.62 38.93 46.53 171.42 78.98 7.000 1153.97 270.27 883.70 Pass 12705.25 8773.65 11050.00 8566.27 39.21 46.98 171.60 79.45 7.000 1134.09 273.61 860.48 Pass 12710.67 8773.36 11075.00 8578.78 39.52 47.45 171.77 79.93 7.000 1114.30 277.05 837.25 Pass 12716.16 8773.08 11100.00 8591.14 39.84 47.94 171.94 80.42 7.000 1094.56 280.53 814.03 Pass 12723.97 8772.69 11125.00 8603.32 40.07 48.33 172.23 80.92 7.000 1074.88 283.32 791.56 Pass 12735.96 8772.09 11150.00 8615.32 40.12 48.51 172.75 81.45 7.000 1055.21 284.73 770.48 Pass 12747.94 8771.50 11175.00 8627.13 40.16 48.69 173.28 81.98 7.000 1035.52 286.13 749.39 Pass 12759.89 8770.90 11200.00 8638.69 40.21 48.86 173.82 82.51 7.000 1015.77 287.51 728.25 Pass 12771.81 8770.31 11225.00 8650.00 40.25 49.04 174.36 83.05 7.000 995.95 288.89 707.06 Pass 12783.68 8769.72 11250.00 8661.06 40.30 49.22 174.91 83.60 7.000 976.07 290.26 685.81 Pass 12795.52 8769.13 11275.00 8671.85 40.34 49.39 175.46 84.15 7.000 956.12 291.60 664.52 Pass 12807.29 8768.54 11300.00 8682.36 40.39 49.56 176.02 84.71 7.000 936.08 292.93 643.15 Pass Site: PB DS 15 Well: 15-30 Rule Assigned: Major Risk Wellpath: 15-30APB1 V10 Inter-Site Error: 0.00 ft Befcrence `Offset Semi-Major Axis - Gtr-Ctr No-Co Allowable MD TVD..: MD TVD :.'Ref Offset TFO+AZL TFO-HS CasinglHSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 12607.17 8780.58 10625.00 8332.96 35.61 40.66 168.28 72.28 7.000 1475.79 224.14 1251.65 Pass 12617.72 8779.74 10650.00 8347.67 35.65 40.82 168.66 72.67 7.000 1455.42 225.49 1229.93 Pass 12628.38 8778.89 10675.00 8362.31 35.69 40.98 169.06 73.07 7.000 1435.14 226.86 1208.28 Pass 12637.60 8778.15 10700.00 8376.88 35.77 41.19 169.40 73.47 7.000 1414.96 228.63 1186.33 Pass 12642.02 8777.80 10725.00 8391.36 35.98 41.57 169.55 73.87 7.000 1394.88 231.69 1163.19 Pass 12646.49 8777.46 10750.00 8405.69 36.20 41.95 169.70 74.26 7.000 1374.78 234.77 1140.02 Pass 12650.00 8777.19 10775.00 8419.86 36.37 42.29 169.91 74.67 7.000 1354.66 237.46 1117.20 Pass 12650.00 8777.19 10800.00 8433.87 36.37 42.46 170.33 75.09 7.000 1334.54 238.73 1095.81 Pass 12660.21 8776.45 10825.00 8447.73 36.90 43.12 170.15 75.48 7.000 1314.36 244.10 1070.26 Pass 12664.92 8776.12 10850.00 8461.45 37.14 43.52 170.30 75.89 7.000 1294.23 247.25 1046.98 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 7 Field: P rudhoe Bay Reference S ite: P B DS 15 Co-ordinate(NE) Refe rence: Well: 15-36, True Nor th Reference We1L• 1 5-36 V ertical (TV D) Refere nce: 32.5 +31 63.5 Reference Wetlpath: P lan 15-36B Db: Oracle Site: PB DS 15 Well: 15-30 Rule Assigned: Major Risk Wetlpath: 15-30APB 1 V10 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF~-HS Casing/RSflistance Area Deviation Warning ft ft ft ft ft ft deg. deg in ft ft ft 12669.70 8775.79 10875.00 8475.02 37.38 43.93 170.45 76.31 7.000 1274.13 250.44 1023.69 Pass 12674.55 8775.47 10900.00 8488.46 37.63 44.34 170.61 76.74 7.000 1254.06 253.66 1000.40 Pass 12679.48 8775.15 10925.00 8501.76 37.88 44.76 170.77 77.17 7.000 1234.00 256.90 977.10 Pass 12684.47 8774.84 10950.00 8514.93 38.14 45.18 170.93 77.61 7.000 1213.95 260.16 953.79 Pass 12689.53 8774.53 10975.00 8527.96 38.40 45.61 171.09 78.06 7.000 1193.92 263.45 930.47 Pass 12700.00 8773.93 11000.00 8540.85 38.93 46.32 170.94 78.50 7.000 1173.94 268.89 905.05 Pass 12700.00 8773.93 11025.00 8553.62 38.93 46.49 171.42 78.98 7.000 1153.97 270.15 883.82 Pass 12705.25 8773.65 11050.00 8566.27 39.21 46.94 171.60 79.45 7.000 1134.09 273.50 860.60 Pass 12710.67 8773.36 11075.00 8578.78 39.52 47.41 171.77 79.93 7.000 1114.30 276.93 837.37 Pass 12716.16 8773.08 11100.00 8591.14 39.84 47.90 171.94 80.42 7.000 1094.56 280.41 814.15 Pass 12723.97 8772.69 11125.00 8603.32 40.07 48.29 172.23 80.92 7.000 1074.88 283.20 791.68 Pass 12735.96 8772.09 11150.00 8615.32 40.12 48.47 172.75 81.45 7.000 1055.21 284.60 770.61 Pass 12747.94 8771.50 11175.00 8627.13 40.16 48.65 173.28 81.98 7.000 1035.52 286.00 749.52 Pass 12759.89 8770.90 11200.00 8638.69 40.21 48.82 173.82 82.51 7.000 1015.77 287.39 728.38 Pass 12771.81 8770.31 11225.00 8650.00 40.25 49.00 174.36 83.05 7.000 995.95 288.77 707.18 Pass 12783.68 8769.72 11250.00 8661.06 40.30 49.18 174.91 83.60 7.000 976.07 290.13 685.94 Pass 12795.52 8769.13 11275.00 8671.85 40.34 49.35 175.46 84.15 7.000 956.12 291.47 664.64 Pass 12807.29 8768.54 11300.00 8682.36 40.39 49.52 176.02 84.71 7.000 936.08 292.80 643.28 Pass Site: PB DS 15 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36 V1 Inter-Site Error: 0.00 ft .Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD "Ref Offset TFO+AZI TFO-HS Casing/HSflstance Area Deviation Warning #t ft ft ft ft ft deg deg in ft #t ' ft 10100.00 7510.57 10100.00 7510.57 73.41 72.73 29.02 0.00 7.625 0.00 0.60 -0.60 FAIL 10124.98 7528.39 10125.00 7528.53 73.37 72.78 286.05 253.63 7.625 0.68 0.60 0.08 Pass 10149.96 7546.39 10150.00 7546.65 73.43 72.99 290.40 257.95 7.625 1.83 0.60 1.23 Pass 10174.94 7564.67 10175.00 7564.91 73.48 73.20 295.72 263.24 7.625 3.03 0.60 2.43 Pass 10199.90 7583.25 10200.00 7583.27 73.54 73.40 302.16 269.65 7.625 4.30 0.60 3.70 Pass 10224.85 7602.10 10225.00 7601.70 73.60 73.61 308.73 276.18 7.625 5.71 0.60 5.11 Pass 10249.77 7621.20 10250.00 7620.21 73.65 73.81 314.96 282.38 7.625 7.31 0.60 6.71 Pass 10274.65 7640.56 10275.00 7638.80 73.71 74.02 320.82 288.21 7.625 9.05 0.60 8.45 Pass 10299.50 7660.16 10300.00 7657.48 73.76 74.22 326.65 294.00 7.625 10.82 0.60 10.22 Pass 10324.31 7679.98 10325.00 7676.25 73.81 74.43 332.42 299.74 7.625 12.67 0.60 12.07 Pass 10349.07 7700.02 10350.00 7695.10 73.87 74.63 338.09 305.37 7.625 14.64 0.60 14.05 Pass 10373.75 7720.25 10375.00 7714.04 73.92 74.84 343.29 310.53 7.625 16.90 0.60 16.30 Pass 10398.35 7740.65 10400.00 7733.04 73.97 75.04 347.71 314.91 7.625 19.54 0.60 18.94 Pass 10422.86 7761.21 10425.00 7752.11 74.01 75.24 351.42 318.57 7.625 22.57 0.60 21.97 Pass 10447.27 7781.90 10450.00 7771.25 74.06 75.44 354.51 321.62 7.625 25.97 0.60 25.37 Pass 10471.60 7802.74 10475.00 7790.55 74.10 75.63 357.09 324.15 7.625 29.57 0.60 28.97 Pass 10495.84 7823.72 10500.00 7810.04 74.15 75.82 359.30 326.30 7.625 33.30 0.60 32.70 Pass 10520.42 7845.13 10525.00 7829.71 74.19 76.01 1.12 328.11 7.625 37.05 0.60 36.45 Pass 10545.15 7866.69 10550.00 7849.56 74.23 76.20 2.47 329.47 7.625 40.56 0.60 39.97 Pass 10569.91 7888.27 10575.00 7869.51 74.27 76.38 3.56 330.56 7.625 43.94 0.60 43.34 Pass 10594.68 7909.86 10600.00 7889.52 74.30 76.56 4.48 331.47 7.625 47.21 0.60 46.62 Pass 10619.48 7931.47 10625.00 7909.61 74.34 76.74 5.25 332.24 7.625 50.37 0.60 49.77 Pass 10644.29 7953.09 10650.00 7929.79 74.38 76.92 5.90 332.89 7.625 53.40 0.60 52.80 Pass 10669.13 7974.74 10675.00 7950.13 74.42 77.09 6.36 333.35 7.625 56.16 0.60 55.56 Pass 10694.00 7996.42 10700.00 7970.65 74.45 77.27 6.65 333.65 7.625 58.65 0.60 58.05 Pass 10718.90 8018.12 10725.00 7991.35 74.49 77.44 6.81 333.80 7.625 60.87 0.60 60.27 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 8 Field: Prudhoe Bay Reference S ite: PB DS 15 Co-ordinate(NE) Reference: Well: 15-36, True North Reference Well: 15-36 Vertical ("I'V D) Refere nce: 32.5 +31 63.5 Reference Wellpath: Plan 15-366 Db: Oracle Site: PB DS 1 5 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36 V1 Inter-Site Error: 0.00 ft Refe rence Off set Semi-Nl aj'or Axis ~ Ctr-Ctr No-Go Allowable N1D TVD MD TVD Ref Offset TFO+AZI TEO-HS Casing/ HSDistance Area De~~ation Warning ft ft ft ft ft ft deg deg in ft ft ft 10743.82 8039.85 10750.00 8012.20 74.53 77.61 6.81 333.81 7.625 62.84 0.60 62.24 Pass 10768.76 8061.57 10775.00 8033.16 74.57 77.77 6.64 333.63 7.625 64.68 0.60 64.08 Pass 10793.69 8083.31 10800.00 8054.24 74.61 77.93 6.29 333.28 7.625 66.38 0.60 65.78 Pass 10818.64 8105.05 10825.00 8075.43 74.64 78.10 5.79 332.78 7.625 67.94 0.60 67.34 Pass 10843.59 8126.80 10850.00 8096.74 74.68 78.25 5.19 332.18 7.625 69.33 0.60 68.73 Pass 10868.55 8148.55 10875.00 8118.17 74.72 78.41 4.56 331.55 7.625 70.48 0.60 69.88 Pass 10893.52 8170.32 10900.00 8139.73 74.76 78.56 3.90 330.89 7.625 71.39 0.60 70.79 Pass 10918.50 8192.08 10925.00 8161.42 74.80 78.72 3.20 330.19 7.625 72.08 0.60 71.48 Pass 10943.47 8213.85 10950.00 8183.22 74.84 78.86 2.43 329.42 7.625 72.56 0.60 71.96 Pass 10968.45 8235.62 10975.00 8205.13 74.87 79.01 1.58 328.57 7.625 72.87 0.60 72.27 Pass 10993.42 8257.38 11000.00 8227.15 74.91 79.16 0.64 327.63 7.625 73.00 0.60 72.40 Pass 11018.38 8279.14 11025.00 8249.27 74.95 79.30 -0.40 326.60 5.500 72.98 0.51 72.47 Pass 11043.34 8300.89 11050.00 8271.47 74.99 79.44 358.46 325.45 5.500 72,85 0.51 72.34 Pass 11068.29 8322.63 11075.00 8293.75 75.03 79.58 357.19 324.18 5.500 72.66 0.51 72.15 Pass 11093.22 8344.37 11100.00 8316.09 75.07 79.71 355.80 322.79 5.500 72.41 0.51 71.90 Pass 11118.15 8366.09 11125.00 8338.51 75.11 79.85 354.27 321.26 5.500 72.12 0.43 71.69 Pass 11143.06 8387.80 11150.00 8361.00 75.14 79.98 352.61 319.60 5.500 71.79 0.43 71.36 Pass 11167.96 8409.50 11175.00 8383.55 75.18 80.12 350.82 317.81 5.500 71.45 0.43 71.02 Pass 11192.85 8431.20 11200.00 8406.11 75.22 80.25 348.96 315.95 5.500 71.17 0.43 70.75 Pass 11217.73 8452.88 11225.00 8428.72 75.26 80.37 346.98 313.97 5.500 70.96 0.43 70.53 Pass 11242.58 8474.54 11250.00 8451.40 75.30 80.50 344.79 311.78 5.500 70.82 0.43 70.39 Pass 11267.40 8496.18 11275.00 8474.16 75.34 80.62 342.40 309.39 5.500 70.76 0.43 70.34 Pass 11292.20 8517.79 11300.00 8496.98 75.38 80.74 339.81 306.81 5.500 70.83 0.43 70.41 Pass 11316.97 8539.38 11325.00 8519.82 75.42 80.87 337.13 304.12 5.500 71.10 0.43 70.67 Pass 11341.74 8560.96 11350.00 8542.68 75.46 80.99 334.41 301.40 5.500 71.58 0.43 71.15 Pass 11365.33 8581.41 11375.00 8565.63 75.28 80.90 331.79 295.16 5.500 72.20 0.43 71.78 Pass 11388.05 8600.67 11400.00 8588.71 74.92 80.59 328.29 287.35 5.500 73.38 0.43 72.95 Pass 11410.14 8618.93 11425.00 8611.86 74.43 80.13 323.95 279.29 5.500 75.54 0.43 75.11 Pass 11431.49 8636.08 11450.00 8635.04 73.82 79.53 319.09 271.22 5.500 78.97 0.43 78.55 Pass 11452.01 8652.05 11475.00 8658.30 73.11 78.81 313.99 263.34 5.500 83.82 0.43 83.40 Pass 11471.63 8666.84 11500.00 8681.65 72.31 78.01 308.91 255.85 5.500 90.14 0.43 89.71 Pass 11490.36 8680.46 11525.00 8705.02 71.44 77.14 304.21 249.03 5.500 98.02 0.43 97.59 Pass 11508.21 8692.97 11550.00 8728.39 70.55 76.22 300.02 242.97 5.500 107.39 0.43 106.96 Pass 11525.17 8704.42 11575.00 8751.77 69.64 75.27 296.39 237.70 5.500 118.14 0.43 117.71 Pass 11541.26 8714.86 11600.00 8775.13 68.68 74.29 293.32 233.13 5.500 130.14 0.43 129.71 Pass 11556.56 8724.39 11625.00 8798.43 67,74 73.32 290.80 229.28 5.500 143.26 0.43 142.83 Pass 11571.08 8733.08 11650.00 8821.67 66.80 72.34 288.75 226.03 5.500 157.35 0.43 156.92 Pass 11584.87 8740.98 11675.00 8844.83 65.86 71.38 287.10 223.28 5.500 172.29 0.43 171.86 Pass 11597.93 8748.15 11700.00 8867.99 64.96 70.44 285.72 220.90 5.500 187.96 0.43 187.53 Pass 11610.25 8754.62 11725.00 8891.29 64.08 69.53 284.45 218.73 5.500 204.25 0.43 203.82 Pass 11621.85 8760.46 11750.00 8914.71 63.24 68.65 283.29 216.74 5.500 221.12 0.43 220.69 Pass 11632.80 8765.73 11775.00 8938.15 62.42 67.82 282.30 214.99 5.500 238.58 0.43 238.15 Pass 11643.15 8770.50 11800.00 8961.60 61.64 67.01 281.47 213.46 5.500 256.59 0.43 256.17 Pass 11647.42 8772.41 11810.75 8971.68 61.32 66.68 281.15 212.85 5.500 264.50 0.43 264.07 Pass Site: PB DS 1 5 Wetl: 15-36 Rule Assi gned: NOERRORS Wellpath: 15-36A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-MajUr Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A7I-TFO-HS Casing/HSDistance Area Deviation Warning Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 9 Field: Prudhoe Bay Reference Site: PB DS 15 Co-ordinate(NE) Refer ence: Well: 15-36, True Nor th Reference Well: 1 5-36 Vertical (TV D) Refere nce: 32.5 +31 63.5 Reference Wellpath: Plan 15-366 Db: Oracle Site: PB DS 15 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36A V2 Inter-Site Error: 0.00 ft Reference Offset Senu-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TYD Ref Offset TFO+AZY TFO-HS Casing/H SDistance Area Deviation ~i'arning ft ft ft ft ft ft deg deg in ft ft ft 10100.00 7510.57 10100.00 7510.57 73.41 73.04 29.02 0.00 7.625 0.00 0.60 -0.60 FAIL 10124.98 7528.39 10125.00 7528.53 73.37 73.08 286.05 253.63 7.625 0.68 0.60 0.08 Pass 10149.96 7546.39 10150.00 7546.65 73.43 73.30 290.40 257.95 7.625 1.83 0.60 1.23 Pass 10174.94 7564.67 10175.00 7564.91 73.48 73.51 295.72 263.24 7.625 3.03 0.60 2.43 Pass 10199.90 7583.25 10200.00 7583.27 73.54 73.71 302.16 269.65 7.625 4.30 0.60 3.70 Pass 10224.85 7602.10 10225.00 7601.70 73.60 73.92 308.73 276.18 7.625 5.71 0.60 5.11 Pass 10249.77 7621.20 10250.00 7620.21 73.65 74.12 314.96 282.38 7.625 7.31 0.60 6.71 Pass 10274.65 7640.56 10275.00 7638.80 73.71 74.33 320.82 288.21 7.625 9.05 0.60 8.45 Pass 10299.50 7660.16 10300.00 7657.48 73.76 74.54 326.65 294.00 7.625 10.82 0.60 10.22 Pass 10324.31 7679.98 10325.00 7676.25 73.81 74.74 332.42 299.74 7.625 12.67 0.60 12.07 Pass 10349.07 7700.02 10350.00 7695.10 73.87 74.95 338.09 305.37 7.625 14.64 0.60 14.05 Pass 10373.75 7720.25 10375.00 7714.04 73.92 75.15 343.29 310.53 7.625 16.90 0.60 16.30 Pass 10398.35 7740.65 10400.00 7733.04 73.97 75.35 347.71 314.91 7.625 19.54 0.60 18.94 Pass 10422.86 7761.21 10425.00 7752.11 74.01 75.56 351.42 318.57 7.625 22.57 0.60 21.97 Pass 10447.27 7781.90 10450.00 7771.25 74.06 75.76 354.51 321.62 7.625 25.97 0.60 25.37 Pass 10471.60 7802.74 10475.00 7790.55 74.10 75.95 357.09 324.15 7.625 29.57 0.60 28.97 Pass 10495.84 7823.72 10500.00 7810.04 74.15 76.14 359.30 .326.30 7.625 33.30 0.60 32.70 Pass 10520.42 7845.13 10525.00 7829.71 74.19 76.33 1.12 328.11 7.625 37.05 0.60 36.45 Pass 10545.15 7866.69 10550.00 7849.56 74.23 76.52 2.47 329.47 7.625 40.56 0.60 39.97 Pass 10569.91 7888.27 10575.00 7869.51 74.27 76.70 3.56 330.56 7.625 43.94 0.60 43.34 Pass 10594.68 7909.86 10600.00 7889.52 74.30 76.88 4.48 331.47 7.625 47.21 0.60 46.62 Pass 10619.48 7931.47 10625.00 7909.61 74.34 77.07 5.25 332.24 7.625 50.37 0.60 49.77 Pass 10644.29 7953.09 10650.00 7929.79 74.38 77.24 5.90 332.89 7.625 53.40 0.60 52.80 Pass 10669.13 7974.74 10675.00 7950.13 74.42 77.42 6.36 333.35 7.625 56.16 0.60 55.56 Pass 10694.00 7996.42 10700.00 7970.65 74.45 77.59 6.65 333.65 7.625 58.65 0.60 58.05 Pass 10718.90 8018.12 10725.00 7991.35 74.49 77.77 6.81 333.80 7.625 60.87 0.60 60.27 Pass 10743.82 8039.85 10750.00 8012.20 74.53 77.94 6.81 333.81 7.625 62.84 0.60 62.24 Pass 10768.76 8061.57 10775.00 8033.16 74.57 78.10 6.64 333.63 7.625 64.68 0.60 64.08 Pass 10793.69 8083.31 10800.00 8054.24 74.61 78.26 6.29 333.28 7.625 66.3$ 0.60 65.78 Pass 10818.64 8105.05 10825.00 8075.43 74.64 78.43 5.79 332.78 7.625 67.94 0.60 67.34 Pass 10843.59 8126.80 10850.00 8096.74 74.68 78.58 5.19 332.18 7.625 69.33 0.60 68.73 Pass 10868.55 8148.55 10875.00 8118.17 74.72 78.74 4.56 331.55 7.625 70.48 0.60 69.88 Pass 10893.52 8170.32 10900.00 8139.73 74.76 78.90 3.90 330.89 7.625 71.39 0.60 70.79 Pass 10918.50 8192.08 10925.00 8161.42 74.80 79.05 3.20 330.19 7.625 72.08 0.60 71.48 Pass 10943.47 8213.85 10950.00 8183.22 74.84 79.20 2.43 329.42 7.625 72.56 0.60 71.96 Pass 10968.45 8235.62 10975.00 8205.13 74.87 79.35 1.58 328.57 7.625 72.87 0.60 72.27 Pass 10993.42 8257.38 11000.00 8227.15 74.91 79.49 0.64 327.63 7.625 73.00 0.60 72.40 Pass 11018.38 8279.14 11025.00 8249.27 74.95 79.64 -0.40 326.60 5.500 72.98 0.51 72.47 Pass 11043.34 8300.89 11050.00 8271.47 74.99 79.77 358.46 325.45 5.500 72.85 0.51 72.34 Pass 11068.29 8322.63 11075.00 8293.75 75.03 79.91 357.19 324.18 5.500 72.66 0.51 72.15 Pass 11093.22 8344.37 11100.00 8316.09 75.07 80.05 355.80 322.79 5.500 72.41 0.51 71.90 Pass 11118.15 8366.09 11125.00 8338.51 75.11 80.19 354.27 321.26 5.500 72.12 0.43 71.69 Pass 11143.06 8387.80 11150.00 8361.00 75.14 80.32 352.61 319.60 5.500 71.79 0.43 71.36 Pass 11167.96 8409.50 11175.00 8383.55 75.18 80.46 350.82 317.81 5.500 71.45 0.43 71.02 Pass 11192.85 8431.20 11200.00 8406.11 75.22 80.59 348.96 315.95 5.500 71.17 0.43 70.75 Pass 11217.73 8452.88 11225.00 8428.72 75.26 80.71 346.98 313.97 5.500 70.96 0.43 70.53 Pass 11242.58 8474.54 11250.00 8451.40 75.30 80.84 344.79 311.78 5.500 70.82 0.43 70.39 Pass 11267.40 8496.18 11275.00 8474.16 75.34 80.96 342.40 309.39 5.500 70.76 0.43 70.34 Pass 11292.20 8517.79 11300.00 8496.98 75.38 81.09 339.81 306.81 5.500 70.83 0.43 70.41 Pass 11316.97 8539.38 11325.00 8519.82 75.42 81.21 337.13 304.12 5.500 71.10 0.43 70.67 Pass 11341.74 8560.96 11350.00 8542.68 75.46 81.33 334.41 301.40 5.500 71.58 0.43 71.15 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: L0 Field: Prudhoe Bay Reference Site: PB DS 15 Co-ordinate(NE) Reference: Well: 15-36, True North Refereuce Well: 15-36 Vertical (TV D) Reference: 3 2.5 +31 63.5 Reference W ellpath: Plan 15-36B Db: Oracle Site: PB DS 15 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-M ajor Asis Ctr-Ctr No-Go Allowable MD TVD i~fD TVD Ref Offset TFO+AZI TFO-HS CasiaglHSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11365.33 8581.41 11375.00 8565.63 75.28 81.24 331.79 295.16 5.500 72.20 0.43 71.78 Pass 11388.05 8600.67 11400.00 8588.71 74.92 80.93 328.29 287.35 2.875 73.38 0.32 73.06 Pass 11410.14 8618,93 11425.00 8611.85 74.43 80.45 323.96 279.30 2.875 75.54 0.32 75.22 Pass 11431.63 8636.19 11450.00 8634.44 73.81 79.86 319.93 272.05 2.875 79.90 0.32 79.58 Pass 11452.43 8652.38 11475.00 8655.29 73.09 79.15 317.73 267.04 2.875 87.57 0.32 87.25 Pass 11472.10 8667.18 11500.00 8673.97 72.29 78.38 317.22 264.11 2.875 98.21 0.32 97.90 Pass 11489.92 8680.15 11525.00 8690.02 71.47 77.62 317.89 262.76 2.875 112.07 0.32 111.75 Pass 11505.95 8691.42 11550.00 8703.23 70.67 76.88 319.49 262.67 2.875 128.10 0.32 127.78 Pass 11520.71 8701.45 11575.00 8714.13 69.88 76.15 321.54 263.26 2.875 145.23 0.32 144.91 Pass 11534.50 8710.53 11600.00 8723.44 69.08 75.43 323.62 264.04 2.875 163.12 0.32 162.80 Pass 11547.33 8718.69 11625.00 8731.15 68.32 74.73 325.69 264.96 2.875 181.73 0.32 181.41 Pass 11559.25 8726.03 11650.00 8737.07 67.56 74.05 327.79 266.04 2.875 200.91 0.32 200.59 Pass 11570.04 8732.47 11675.00 8741.25 66.87 73.42 329.83 267.18 2.875 220.88 0.32 220.56 Pass 11579.60 8738.00 11700.00 8743.98 66.23 72.85 331.68 268.27 2.875 241.77 0.32 241.45 Pass 11587.93 8742.69 11725.00 8745.46 65.65 72.35 333.33 269.27 2.875 263.49 0.32 263.18 Pass 11595.14 8746.64 11750.00 8745.60 65.16 71.92 334.86 270.25 2.875 285.82 0.32 285.51 Pass 11601.62 8750.12 11775.00 8744.39 64.70 71.54 336.35 271.26 2.875 308.37 0.32 308.06 Pass 11607.47 8753.19 11800.00 8741.92 64.28 71.19 337.81 272.28 2.875 331.09 0.32 330.77 Pass 11612.60 8755.83 11825.00 8739.30 63.91 70.89 339.00 273.11 2.875 354.35 0.32 354.03 Pass 11616.99 8758.04 11850.00 8736.86 63.59 70.64 339.92 273.71 2.875 378.14 0.32 377.83 Pass 11620.65 8759.87 11875.00 8734.80 63.32 70.43 340.58 274.11 2.875 402.37 0.32 402.06 Pass 11624.08 8761.55 11900.00 8733.95 63.07 70.23 340.96 274.25 2.875 426.85 0.32 426.53 Pass 11627.35 8763.14 11925.00 8734.56 62.83 70.03 341.08 274.14 2.875 451.43 0.32 451.11 Pass 11629.91 8764.36 11950.00 8737.24 62.64 69.87 340.83 273.72 2.875 475.98 0.32 475.67 Pass 11631.11 8764.93 11975.00 8741.29 62.55 69.80 340.27 273.08 2.875 500.38 0.32 500.06 Pass 11630.51 8764.65 12000.00 8745.39 62.59 69.88 339.55 272.39 2.875 524.54 0.32 524.22 Pass 11627.62 8763.27 12025.00 8748.43 62.81 70.13 338.72 271.77 2.875 548.18 0.32 547.87 Pass 11622.68 8760.87 12050.00 8749.88 63.18 70.55 337.88 271.27 2.875 571.02 0.32 570.71 Pass 11616.05 8757.57 12075.00 8750.35 63.66 71.09 336.95 270.81 2.875 592.52 0.32 592.20 Pass 11608.16 8753.54 12100.00 8751.06 64.23 71.73 335.84 270.27 2.875 612.04 0.32 611.72 Pass 11599.39 8748.93 12125.00 8751.24 64.86 72.41 334.68 269.75 2.875 629.95 0.32 629.63 Pass 11590.36 8744.03 12150.00 8751.02 65.49 73.10 333.50 269.26 2.875 647.04 0.32 646.72 Pass 11581.73 8739.21 12175.00 8750.96 66.08 73.75 332.35 268.77 2.875 664.28 0.32 663.96 Pass 11573.35 8734.40 12200.00 8751.09 66.65 74.36 331.19 268.28 2.875 681.34 0.32 681.02 Pass 11565.14 8729.57 12225.00 8751.41 67.18 74.94 330.01 267.77 2.875 698.01 0.32 697.70 Pass 11556.98 8724.65 12250.00 8751.82 67.71 75.49 328.81 267.25 2.875 714.01 0.32 713.69 Pass 11548.84 8719.63 12275.00 8752.27 68.23 76.03 327.58 266.72 2.875 729.23 0.32 728.92 Pass 11540.71 8714.51 12300.00 8752.80 68.71 76.54 326.31 266.17 2.875 743.38 0.32 743.06 Pass 11532.45 8709.20 12325.00 8753.58 69.20 77.03 324.96 265.56 2.875 755.33 0.32 755.01 Pass 11525.00 8704.31 12350.00 8754.35 69.65 77.43 323.61 264.92 2.875 766.71 0.32 766.39 Pass 11516.49 8698.62 12375.00 8755.01 70.10 77.90 322.24 264.36 2.875 778.00 0.32 777.68 Pass 11508.80 8693.38 12400.00 8755.48 70.51 78.29 320.89 263.78 2.875 789.14 0.32 788.82 Pass 11500.00 8687.28 12425.00 8755.75 70.99 78.74 319.53 263.32 2.875 800.17 0.32 799.86 Pass 11494.10 8683.12 12450.00 8755.95 71.27 78.97 318.28 262.69 2.875 811.95 0.32 811.64 Pass 11487.25 8678.23 12475.00 8756.13 71.59 79.26 317.03 262.19 2.875 824.61 0.32 824.29 Pass 11480.67 8673.47 12500.00 8756.30 71.90 79.52 315.81 261.71 2.875 837.65 0.32 837.33 Pass 11475.00 8669.32 12525.00 8756.46 72.17 79.71 314.64 261.19 2.875 851.00 0.32 850.68 Pass 11468.22 8664.30 12550.00 8756.59 72.45 79.96 313.45 260.79 2.875 864.61 0.32 864.29 Pass 11462.32 8659.88 12575.00 8756.73 72.69 80.15 312.30 260.36 2.875 878.43 0.32 878.11 Pass 11456.67 8655.61 12600.00 8757.26 72.92 80.31 311.14 259.90 2.875 891.98 0.32 891.66 Pass 11450.00 8650.51 12625.00 8758.33 73.19 80.50 309.91 259.53 2.875 905.10 0.32 904.78 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: ( I Field: P rudhoe Bay Reference S ite: P B DS 15 Co-ordinate( NE) Refe rence: Well: 15-36, True Nor th Reference Well: 1 5-36 V ertical (TV D) Refere nce: 32.5 +31 63.5 Reference Wellpath: P lan 15-368 Db: Oracle Site: PB DS 15 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36A V2 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable NID TVD MD TVD i~ef Offset TFO+AZI 'CFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11450.00 8650.51 12650.00 8760.11 73.19 80.31 308.84 258.46 2.875 917.43 0.32 917.11 Pass 11441.33 8643.80 12675.00 8762.40 73.48 80.59 307.48 258.25 2.875 929.33 0.32 929.02 Pass 11436.66 8640.15 12700.00 8764.57 73.64 80.64 306.28 257.69 2.875 942.07 0.32 941.76 Pass 11431.96 8636.45 12725.00 8765.91 73.80 80.69 305.15 257.22 2.875 955.56 0.32 955.24 Pass 11425.00 8630.92 12750.00 8765.60 74.03 80.85 304.03 257.11 2.875 969.35 0.32 969.04 Pass 11425.00 8630.92 12775.00 8765.38 74.03 80.65 303.10 256.18 2.875 982.43 0.32 982.11 Pass 11417.32 8624.75 12800.00 8765.49 74.24 80.82 301.91 256.13 2.875 994.77 0.32 994.45 Pass 11412.88 8621.15 12825.00 8765.91 74.36 80.83 300.85 255.76 2.875 1008.31 0.32 1007.99 Pass 11408.79 8617.82 12850.00 8766.64 74.46 80.81 299.86 255.42 2.875 1023.57 0.32 1023.25 Pass 11400.00 8610.61 12875.00 8767.56 74.70 81.00 298.77 255.77 2.875 1039.77 0.32 1039.45 Pass 11400.00 8610.61 12900.00 8768.59 74.70 80.82 297.97 254.97 2.875 1056.37 0.32 1056.05 Pass 11400.00 8610.61 12925.00 8769.72 74.70 80.65 297.19 254.19 2.875 1073.45 0.32 1073.13 Pass 11400.00 8610.61 12950.00 8770.95 74.70 80.47 296.45 253.44 2.875 1090.96 0.32 1090.64 Pass 11391.26 8603.36 12975.00 8772.14 74.86 80.65 295.49 253.98 2.875 1109.16 0.32 1108.84 Pass 11388.24 8600.83 13000.00 8773.17 74.92 80.61 294.76 253.78 2.875 1128.24 0.32 1127.92 Pass 11387.31 8600.05 13007.75 8773.50 74.94 80.59 294.53 253.72 2.875 1134.08 0.32 1133.76 Pass Site: PB DS 15 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36AP61 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Gtr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A2t TFO-HS Casingl llSDistance Area. Deviation . Warning ft ft ft ft ft ft deg deg in ft' ft ft 10100.00 7510.57 10100.00 7510.57 73.41 73.02 29.02 0.00 7.625 0.00 0.60 -0.60 FAIL 10124.98 7528.39 10125.00 7528.53 73.37 73.07 286.05 253.63 7.625 0.68 0.60 0.08 Pass 10149.96 7546.39 10150.00 7546.65 73.43 73.28 290.40 257.95 7.625 1.83 0.60 1.23 Pass 10174.94 7564.67 10175.00 7564.91 73.48 73.49 295.72 263.24 7.625 3.03 0.60 2.43 Pass 10199.90 7583.25 10200.00 7583.27 73.54 73.70 302.16 269.65 7.625 4.30 0.60 3.70 Pass 10224.85 7602.10 10225.00 7601.70 73.60 73.90 308.73 276.18 7.625 5.71 0.60 5.11 Pass 10249.77 7621.20 10250.00 7620.21 73.65 74.11 314.96 282.38 7.625 7.31 0.60 6.71 Pass 10274.65 7640.56 10275.00 7638.80 73.71 74.32 320.82 288.21 7.625 9.05 0.60 8.45 Pass 10299.50 7660.16 10300.00 7657.48 73.76 74.52 326.65 294.00 7.625 10.82 0.60 10.22 Pass 10324.31 7679.98 10325.00 7676.25 73.81 74.73 332.42 299.74 7.625 12.67 0.60 12.07 Pass 10349.07 7700.02 10350.00 7695.10 73.87 74.93 338.09 305.37 7.625 14.64 0.60 14.05 Pass 10373.75 7720.25 10375.00 7714.04 73.92 75.14 343.29 310.53 7.625 16.90 0.60 16.30 Pass 10398.35 7740.65 10400.00 7733.04 73.97 75.34 347.71 314.91 7.625 19.54 0.60 18.94 Pass 10422.86 7761.21 10425.00 7752.11 74.01 75.54 351.42 318.57 7.625 22.57 0.60 21.97 Pass 10447.27 7781.90 10450.00 7771.25 74.06 75.74 354.51 321.62 7.625 25.97 0.60 25.37 Pass 10471.60 7802.74 10475.00 7790.55 74.10 75.93 357.09 324.15 7.625 29.57 0.60 28.97 Pass 10495.84 7823.72 10500.00 7810.04 74.15 76.13 359.30 326.30 7.625 33.30 0.60 32.70 Pass 10520.42 7845.13 10525.00 7829.71 74.19 76.32 1.12 328.11 7.625 37.05 0.60 36.45 Pass 10545.15 7866.69 10550.00 7849.56 74.23 76.50 2.47 329.47 7.625 40.56 0.60 39.97 Pass 10569.91 7888.27 10575.00 7869.51 74.27 76.68 3.56 330.56 7.625 43.94 0.60 43.34 Pass 10594.68 7909.86 10600.00 7889.52 74.30 76.87 4.48 331.47 7.625 47.21 0.60 46.62 Pass 10619.48 7931.47 10625.00 7909.61 74.34 77.05 5.25 332.24 7.625 50.37 0.60 49.77 Pass 10644.29 7953.09 10650.00 7929.79 74.38 77.23 5.90 332.89 7.625 53.40 0.60 52.80 Pass 10669.13 7974.74 10675.00 7950.13 74.42 77.40 6.36 333.35 7.625 56.16 0.60 55.56 Pass 10694.00 7996.42 10700.00 7970.65 74.45 77.58 6.65 333.65 7.625 58.65 0.60 58.05 Pass 10718.90 8018.12 10725.00 7991.35 74.49 77.75 6.81 333.80 7.625 60.87 0.60 60.27 Pass 10743.82 8039.85 10750.00 8012.20 74.53 77.92 6.81 333.81 7.625 62.84 0.60 62.24 Pass 10768.76 8061.57 10775.00 8033.16 74.57 78.08 6.64 333.63 7.625 64.68 0.60 64.08 Pass 10793.69 8083.31 10800.00 8054.24 74.61 78.25 6.29 333.28 7.625 66.38 0.60 65.78 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 12 Field: P rudhoe Bay Reference S ite: P B DS 15 Co-ordinate(NE) Reference: Well: 15-36, True North Reference Well: 1 5-36 Vertical (TV D) Reference: 32.5 +31 63.5 Reference Wellpath: Plan 15-366 Db: Oracle Site: PB DS 15 Well: 15-36 Rule Assigned: NOERRORS Wellpath: 15-36APB 1 V3 Inter-Site Error: 0.00 ft Refe rence Offset Semi--tl~iajor Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offsek TFO+AZ} TFO-HS Casing_/H Spistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10818.64 8105.05 10825.00 8075.43 74.64 78.41 5.79 332.78 7.625 67.94 0.60 67.34 Pass 10843.59 8126.80 10850.00 8096.74 74.68 78.57 5.19 332.18 7.625 69.33 0.60 68.73 Pass 10868.55 8148.55 10875.00 8118.17 74.72 78.72 4.56 331.55 7.625 70.48 0.60 69.88 Pass 10893.52 8170.32 10900.00 8139.73 74.76 78.88 3.90 330.89 7.625 71.39 0.60 70.79 Pass 10918.50 8192.08 10925.00 8161.42 74.80 79.03 3.20 330.19 7.625 72.08 0.60 71.48 Pass 10943.47 8213.85 10950.00 8183.22 74.84 79.18 2.43 329.42 7.625 72.56 0.60 71.96 Pass 10968.45 8235.62 10975.00 8205.13 74.87 79.33 1.58 328.57 7.625 72.87 0.60 72.27 Pass 10993.42 8257.38 11000.00 8227.15 74.91 79.48 0.64 327.63 7.625 73.00 0.60 72.40 Pass 11018.38 8279.14 11025.00 8249.27 74.95 79.62 -0.40 326.60 5.500 72.98 0.51 72.47 Pass 11043.34 8300.89 11050.00 8271.47 74.99 79.76 358.46 325.45 5.500 72.85 0.51 72.34 Pass 11068.29 8322.63 11075.00 8293.75 75.03 79.90 357.19 324.18 5.500 72.66 0.51 72.15 Pass 11093.22 8344.37 11100.00 8316.09 75.07 80.03 355.80 322.79 5.500 72.41 0.51 71.90 Pass 11118.15 8366.09 11125.00 8338.51 75.11 80.17 354.27 321.26 5.500 72.12 0.43 71.69 Pass 11143.06 8387.80 11150.00 8361.00 75.14 80.31 352.61 319.60 5.500 71.79 0.43 71.36 Pass 11167.96 8409.50 11175.00 8383.55 75.18 80.44 350.82 317.81 5.500 71.45 0.43 71.02 Pass 11192.85 8431.20 11200.00 8406.11 75.22 80.57 348.96 315.95 5.500 71.17 0.43 70.75 Pass 11217.73 8452.88 11225.00 8428.72 75.26 80.70 346.98 313.97 5.500 70.96 0.43 70.53 Pass 11242.58 8474.54 11250.00 8451.40 75.30 80.82 344.79 311.78 5.500 70.82 0.43 70.39 Pass 11267.40 8496.18 11275.00 8474.16 75.34 80.95 342.40 309.39 5.500 70.76 0.43 70.34 Pass 11292.20 8517.79 11300.00 8496.98 75.38 81.07 339.81 306.81 5.500 70.83 0.43 70.41 Pass 11316.97 8539.38 11325.00 8519.82 75.42 81.19 337.13 304.12 5.500 71.10 0.43 70.67 Pass 11341.74 8560.96 11350.00 8542.68 75.46 81.31 334.41 301.40 5.500 71.58 0.43 71.15 Pass 11365.33 8581.41 11375.00 8565.63 75.28 81.22 331.79 295.16 5.500 72.20 0.43 71.78 Pass 11388.05 8600.67 11400.00 8588.71 74.92 80.91 328.30 287.35 5.500 73.38 0.43 72.96 Pass 11410.17 8618.95 11425.00 8611.77 74.43 80.44 324.09 279.43 3.750 75.66 0.35 75.31 Pass 11431.58 8636.15 11450.00 8634.62 73.81 79.83 319.66 271.79 3.750 79.77 0.35 79.42 Pass 11452.33 8652.30 11475.00 8656.03 73.10 79.12 316.86 266.18 3.750 87.03 0.35 86.68 Pass 11472.04 8667.14 11500.00 8675.31 72.29 78.35 315.94 262.83 3.750 97.36 0.35 97.00 Pass 11490.25 8680.38 11525.00 8692.03 71.45 77.56 316.50 261.33 3.750 110.42 0.35 110.07 Pass 11506.74 8691.96 11550.00 8706.11 70.63 76.79 317.96 261.06 3.750 125.78 0.35 125.43 Pass 11522.63 8702.74 11575.00 8719.02 69.77 75.99 319.60 261.13 3.750 141.53 0.35 141.18 Pass 11537.74 8712.61 11600.00 8730.51 68.89 75.18 321.38 261.50 3.750 157.92 0.35 157.57 Pass 11551.81 8721.48 11624.98 8740.24 68.04 74.37 323.29 262.17 3.750 175.17 0.35 174.81 Pass 11564.86 8729.40 11650.00 8748.10 67.20 73.60 325.30 263.08 3.750 193.28 0.35 192.93 Pass 11576.79 8736.39 11675.00 8753.96 66.42 72.87 327.38 264.19 3.750 212.16 0.35 211.80 Pass 11587.68 8742.55 11700.00 8757.77 65.67 72.20 329.51 265.47 3.750 231.67 0.35 231.31 Pass 11597.69 8748.02 11725.00 8759.42 64.98 71.56 331.72 266.92 3.750 251.48 0.35 251.13 Pass 11606.85 8752.86 11750.00 8759.60 64.32 70.98 333.81 268.34 3.750 271.87 0.35 271.51 Pass 11615.09 8757.09 11775.00 8758.83 63.73 70.45 335.68 269.61 3.750 293.00 0.35 292.65 Pass 11622.34 8760.70 11800.00 8758.33 63.20 69.97 337.08 270.49 3.750 315.26 0.35 314.90 Pass 11628.50 8763.69 11825.00 8758.84 62.74 69.56 337.95 270.93 3.750 338.56 0.35 338,21 Pass 11633.83 8766.22 11850.00 8759.76 62.34 69.20 338.54 271.16 3.750 362.37 0.35 362.02 Pass 11638.38 8768.33 11875.00 8761.01 62.00 68.90 338.91 271.22 3.750 386.53 0.35 386.18 Pass 11642.13 8770.04 11900.00 8762.58 61.72 68.66 339.11 271.17 3.750 410.97 0.35 410.62 Pass 11644.65 8771.18 11925.00 8764.38 61.53 68.48 339.11 271.00 3.750 435.69 0.35 435.33 Pass 11645.43 8771.53 11950.00 8766.27 61.47 68.46 338.89 270.73 3.750 460.58 0.35 460.22 Pass 11644.55 8771.13 11975.00 8768.24 61.54 68.58 338.49 270.38 3.750 485.34 0.35 484.98 Pass 11642.48 8770.20 12000.00 8769.94 61.69 68.76 338.00 270.03 3.750 509.88 0.35 509.52 Pass 11639.48 8768.84 12025.00 8771.19 61.92 69.03 337.48 269.72 3.750 534.16 0.35 533.80 Pass 11635.65 8767.07 12050.00 8771.98 62.21 69.38 336.94 269.43 3.750 558.09 0.35 557.74 Pass 11631.04 8764.90 12075.00 8772.30 62.55 69.79 336.36 269.17 3.750 581.61 0.35 581.26 Pass Sperry-Sun r Anticollision Report Company: ' BP Amoco Date: 4/12/2006 Timr. 09:51:06 Page: 13 Field: Prudhoe Bay Reference Si te: PB DS 15 Co-ordinate(NE) Reference: Well: 15-36, True North Reference Well: 1 5-36 V ertical (TV D) Refere nce: 32.5 +31 63.5 Reference Wellpath: Plart 15-36B Db: Oracle Site: PB DS 15 Well: 15-36 Rule Ass igned: NOERRORS Wellpath: 15-36AP81 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis - Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZL TFO-HS Casing/ HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11625.75 8762.36 12100.00 8772.01 62.95 70.25 335.78 268.96 3.750 604.68 0.35 604.33 Pass 11620.00 8759.55 12124.93 8771.30 63.37 70.74 335.19 268.76 3.750 627.27 0.35 626.91 Pass 11613.86 8756.47 12150.00 8770.91 63.81 71.25 334.51 268.52 3.750 649.41 0.35 649.06 Pass 11607.29 8753.09 12175.00 8771.14 64.29 71.77 333.70 268.20 3.750 670.58 0.35 670.22 Pass 11600.11 8749.31 12200.00 8771.49 64.81 72.36 332.80 267.83 3.750 690.56 0.35 690.20 Pass 11592.44 8745.17 12225.00 8771.95 65.34 72.96 331.82 267.41 3.750 709.23 0.35 708.87 Pass 11584.16 8740.58 12250.00 8772.25 65.91 73.57 330.74 266.98 3.750 726.09 0.35 725.73 Pass 11575.00 8735.36 12275.00 8772.23 66.54 74.25 329.58 266.53 3.750 740.72 0.35 740.37 Pass 11566.07 8730.12 12300.00 8771.72 67.12 74.87 328.38 266.06 3.750 753.48 0.35 753.13 Pass 11556.70 8724.48 12325.00 8770.88 67.73 75.50 327.14 265.61 3.750 764.53 0.35 764.18 Pass 11547.42 8718.74 12350.00 8770.45 68.31 76.09 325.82 265.08 3.750 773.44 0.35 773.09 Pass 11538.22 8712.92 12375.00 8770.10 68.86 76.64 324.44 264.52 3.750 780.03 0.35 779.67 Pass 11529.05 8706.98 12400.00 8769.36 69.40 77.15 323.03 263.95 3.750 784.09 0.35 783.74 Pass 11519.78 8700.83 12425.00 8767.44 69.93 77.65 321.64 263.44 3.750 785.84 0.35 785.49 Pass 11510.50 8694.54 12450.00 8764.49 70.42 78.11 320.28 263.00 3.750 786.90 0.35 786.54 Pass 11500.00 8687.28 12475.00 8760.89 70.99 78.65 318.90 262.69 3.750 788.61 0.35 788.26 Pass 11492.51 8681.99 12500.00 8757.57 71.34 78.96 317.64 262.22 3.750 794.33 0.35 793.98 Pass 11484.41 8676.19 12525.00 8754.72 71.73 79.30 316.40 261.88 3.750 804.07 0.35 803.72 Pass 11475.00 8669.32 12550.00 8752.53 72.17 79.74 315.19 261.73 3.750 816.98 0.35 816.63 Pass 11470.60 8666.07 12575.00 8750.79 72.35 79.86 314.21 261.27 3.750 832.41 0.35 832.05 Pass 11464.72 8661.69 12600.00 8749.59 72.59 80.08 313.24 261.00 3.750 849.35 0.35 849.00 Pass 11459.13 8657.47 12625.00 8749.13 72.82 80.26 312.22 260.68 3.750 865.90 0.35 865.54 Pass 11453.66 8653.32 12650.00 8749.35 73.04 80.42 311.13 260.28 3.750 881.28 0.35 880.92 Pass 11450.00 8650.51 12675.00 8750.02 73.19 80.45 310.02 259.64 3.750 895.00 0.35 894.65 Pass 11443.10 8645.18 12700.00 8750.70 73.42 80.65 308.85 259.38 3.750 909.55 0.35 909.20 Pass 11438.22 8641.37 12725.00 8751.64 73.59 80.73 307.75 258.94 3.750 924.40 0.35 924.04 Pass 11433.40 8637.58 12750.00 8753.49 73.75 80.79 306.51 258.38 3.750 936.10 0.35 935.75 Pass 11425.00 8630.92 12775.00 8756.31 74.03 80.98 305.08 258.15 3.750 945.36 0.35 945.01 Pass 11425.00 8630.92 12800.00 8759.49 74.03 80.76 303.84 256.92 3.750 952.85 0.35 952.50 Pass 11420.05 8626.95 12825.00 8762.24 74.17 80.76 302.46 256.27 3.750 958.86 0.35 958.51 Pass 11415.52 8623.29 12850.00 8764.18 74.29 80.72 301.08 255.59 3.750 963.38 0.35 963.02 Pass 11410.84 8619.50 12875.00 8765.17 74.41 80.69 299.73 254.96 3.750 967.15 0.35 966.79 Pass 11406.10 8615.63 12900.00 8765.56 74.53 80.64 298.40 254.39 3.750 971.55 0.35 971.20 Pass 11400.00 8610.61 12925.00 8765.84 74.70 80.64 297.07 254.06 3.750 978.23 0.35 977.88 Pass 11400.00 8610.61 12950.00 8765.87 74.70 80.41 295.98 252.97 3.750 987.15 0.35 986.80 Pass 11392.35 8604.26 12975.00 8765.25 74.84 80.47 294.74 253.04 3.750 997.89 0.35 997.54 Pass 11387.83 8600.49 13000.00 8764.01 74.93 80.41 293.67 252.77 3.750 1010.39 0.35 1010.03 Pass 11383.59 8596.93 13025.00 8762.93 75.01 80.34 292.68 252.55 3.750 1024.72 0.35 1024.37 Pass 11382.19 8595.75 13033.75 8762.67 75.03 80.32 292.36 252.48 3.750 1030.17 0.35 1029.82 Pass Site: PB DS 15 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go :Allowable IViD TVD MD TVD Ref Offset TFO+AZI TFO-I•IS CasingJHSDistance Area Deviation ~i'arning ft ft ft ft ft ft deg deg in ft ft ft 10106.67 7515.34 10150.00 8092.28 73.39 66.66 247.87 217.71 1.000 1041.62 331.74 709.89 Pass 10115.93 7521.94 10175.00 8115.34 73.37 66.59 248.06 216.33 1.000 1049.68 330.32 719.36 Pass 10151.62 7547.59 10200.00 8138.46 73.43 66.65 248.01 215.55 1.000 1057.84 330.08 727.76 Pass 10209.58 7590.53 10225.00 8161.63 73.56 66.83 247.79 215.27 1.000 1065.30 330.78 734.52 Pass 10269.13 7636.24 10250.00 8184.84 73.70 67.00 247.60 214.99 1.000 1072.02 331.51 740.51 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 14 Field: Prudhoe Bay Reference S ite: PB DS 15 C o-ordinate(NE) Refe rence: Well: 15-36, True Nor th Reference Well: 15-36 V ertical (TV D) Reference: 32.5 +31 63.5 Reference Weltpath: Plan 15-366 Db: Oracle Site: PB DS 1 5 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37 V1 Inter-Site Error: 0.00 ft Reference Offset Sethi-M ajor Axis Ctr-Ctr No-Go Allowable NTD TVI) MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10330.16 7684.69 10275.00 8208.10 73.83 67.17 247.43 214.74 1.000 1077.98 332.30 745.68 Pass 10392.52 7735.79 10300.00 8231.39 73.95 67.34 247.29 214.50 1.000 1083.16 333.13 750.03 Pass 10456.05 7789.40 10325.00 8254.73 74.08 67.51 247.19 214.27 1.000 1087.54 333.96 753.57 Pass 10508.85 7835.05 10350.00 8278.16 74.17 67.66 247.10 214.10 1.000 1091.37 334.54 756.83 Pass 10533.48 7856.52 10375.00 8301.69 74.21 67.75 247.02 214.01 1.000 1095.35 334.39 760.96 Pass 10558.04 7877.92 10400.00 8325.31 74.25 67.85 246.93 213.93 1.000 1099.71 334.24 765.47 Pass 10582.53 7899.27 10425.00 8349.03 74.29 67.95 246.85 213.84 1.000 1104.46 334.10 770.36 Pass 10606.94 7920.54 10450.00 8372.84 74.32 68.04 246.77 213.76 1.000 1109.65 333.97 775.69 Pass 10631.21 7941.70 10475.00 8396.75 74.36 68.13 246.69 213.69 1.000 1115.44 333.86 781.58 Pass 10655.35 7962.74 10500.00 8420.75 74.40 68.21 246.63 213.62 1.000 1121.81 333.79 788.03 Pass 10679.41 7983.71 10525.00 8444.79 74.43 68.29 246.56 213.55 1.000 1128.47 333.73 794.75 Pass 10703.45 8004.66 10550.00 8468.84 74.47 68.37 246.50 213.49 1.000 1135.21 333.67 801.55 Pass 10727.47 8025.60 10575.00 8492.91 74.51 68.45 246.43 213.43 1.000 1142.03 333.61 808.41 Pass 10751.48 8046.52 10600.00 8516.98 74.54 68.53 246.37 213.36 1.000 1148.88 333.56 815.32 Pass 10775.48 8067.44 10625.00 8541.06 74.58 68.61 246.31 213.30 1.000 1155.77 333.50 822.27 Pass 10799.47 8088.35 10650.00 8565.15 74.61 68.68 246.24 213.24 1.000 1162.69 333.45 829.24 Pass 10823.45 8109.25 10675.00 8589.24 74.65 68.76 246.18 213.17 1.000 1169.64 333.39 836.25 Pass 10847.43 8130.14 10700.00 8613.35 74.69 68.84 246.12 213.11 1.000 1176.60 333.33 843.27 Pass 10871.40 8151.04 10725.00 8637.45 74.72 68.92 246.05 213.05 1.000 1183.55 333.26 850.29 Pass 10895.38 8171.94 10750.00 8661.57 74.76 69.00 245.99 212.98 1.000 1190.49 333.19 857.30 Pass 10919.36 8192.84 10775.00 8685.69 74.80 69.07 245.92 212.91 1.000 1197.43 333.11 864.32 Pass 10943.34 8213.73 10800.00 8709.82 74.84 69.15 245.85 212.85 1.000 1204.38 333.03 871.35 Pass 10967.30 8234.62 10825.00 8733.97 74.87 69.23 245.78 212.78 1.000 1211.35 332.93 878.41 Pass 10991.25 8255.49 10850.00 8758.12 74.91 69.30 245.72 212.71 1.000 1218.36 332.83 885.53 Pass 11015.19 8276.35 10875.00 8782.29 74.95 69.38 245.65 212.64 1.000 1225.43 332.74 892.70 Pass 11039.10 8297.20 10900.00 8806.47 74.98 69.45 245.58 212.57 1.000 1232.56 332.63 899.93 Pass 11063.00 8318.03 10925.00 8830.66 75.02 69.53 245.51 212.50 1.000 1239.73 332.52 907.21 Pass 11086,89 8338.85 10950.00 8854.87 75.06 69.60 245.44 212.43 1246.95 332.40 914.55 Pass 11110.73 8359.63 10975.00 8879.13 75.09 69.67 245.36 212.35 1254.27 332.16 922.11 Pass 11134.53 8380.37 11000.00 8903.45 75.13 69.74 245.27 212.26 1261.68 331.95 929.73 Pass 11158.28 8401.07 11025.00 8927.82 75.17 69.80 245.17 212.17 1269.18 331.68 937.50 Pass 11182.02 8421.76 11050.00 8952.22 75.21 69.87 245.07 212.06 1276.69 331.37 945.32 Pass 11185.59 8424.87 11053.76 8955.89 75.21 69.88 245.06 212.05 1277.82 331.33 946.49 Pass Site: PB DS 1 5 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casng/HSDiskance Area Deviation Warning ft ft ft ft ft ft deg deg in ft `' ftr ft 10106.67 7515.34 10150.00 8092.28 73.39 66.83 247.87 217.71 7.000 1041.62 332.34 709.28 Pass 10115.93 7521.94 10175.00 8115.34 73.37 66.77 248.06 216.33 7.000 1049.68 330.92 718.76 Pass 10151.62 7547.59 10200.00 8138.46 73.43 66.83 248.01 215.55 7.000 1057.84 330.68 727.16 Pass 10209.58 7590.53 10225.00 8161.63 73.56 67.00 247.79 215.27 7.000 1065.30 331.38 733.92 Pass 10269.13 7636.24 10250.00 8184.84 73.70 67.17 247.60 214.99 7.000 1072.02 332.12 739.90 Pass 10330.16 7684.69 10275.00 8208.10 73.83 67.35 247.43 214.74 7.000 1077.98 332.90 745.08 Pass 10392.52 7735.79 10300.00 8231.39 73.95 67.52 247.29 214.50 7.000 1083.16 333.73 749.43 Pass 10456.05 7789.40 10325.00 8254.73 74.08 67.69 247.19 214.27 2.375 1087.54 334.38 753.16 Pass 10508.85 7835.05 10350.00 8278.16 74.17 67.83 247.10 214.10 2.375 1091.37 334.96 756.41 Pass 10533.48 7856.52 10375.00 8301.69 74.21 67.93 247.02 214.01 2.375 1095.35 334.81 760.54 Pass 10558.04 7877.92 10400.00 8325.31 74.25 68.03 246.93 213.93 2.375 1099.71 334.66 765.05 Pass 10582.53 7899.27 10425.00 8349.03 74.29 68.13 246.85 213.84 2.375 1104.46 334.52 769.94 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: I$ Field: P rudhoe Bay Reference S ite: P B DS 15 Co-ordinate( NE) Refe rence: Well: 15-36, True North Reference Well: 1 5-36 Vertical (TV D) Refere nce: 32.5 +31 63.5 Reference Wellpath: Plan 15-368 Db: Oracle Site: PB DS 15 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37A V2 Inter-Site Error: 0.00 ft Reference Offset Semi-M ajor Axis Ctr-Ctr iVo-Co Allowable MD TVD MD TVD Ref Offset TFO~-AZI TFO-HS Casing/HSUistance Arca Deviation Warning ft ft ft ft ft ft deg; deg in ft ft ft 10606.94 7920.54 10450.00 8372.84 74.32 68.22 246.77 213.76 2.375 1109.65 334.38 775.27 Pass 10631.21 7941.70 10475.00 8396.75 74.36 68.31 246.69 213.69 2.375 1115.44 334.28 781.16 Pass 10655.35 7962.74 10500.00 8420.75 74.40 68.39 246.63 213.62 2.375 1121.81 334.21 787.61 Pass 10679.41 7983.71 10525.00 8444.79 74.43 68.47 246.56 213.55 2.375 1128.47 334.14 794.33 Pass 10703.45 8004.66 10550.00 8468.84 74.47 68.55 246.50 213.49 2.375 1135.21 334.09 801.13 Pass 10727.47 8025.60 10575.00 8492.91 74.51 68.63 246.43 213.43 2.375 1142.03 334.03 807.99 Pass 10751.48 8046.52 10600.00 8516.98 74.54 &8.71 246.37 213.36 2.375 1148.88 333.98 814.90 Pass 10775.48 8067.44 10625.00 8541.06 74.58 68.79 246.31 213.30 2.375 1155.77 333.92 821.85 Pass 10799.47 8088.35 10650.00 8565.15 74.61 68.87 246.24 213.24 2.375 1162.69 333.87 828.82 Pass 10823.45 8109.25 10675.00 8589.24 74.65 68.94 246.18 213.17 2.375 1169.64 333.81 835.83 Pass 10847.45 8130.16 10700.00 8613.33 74.69 69.03 246.12 213.11 2.375 1176.54 333.76 842.78 Pass 10872.04 8151.59 10725.00 8636.39 74.73 69.13 246.14 213.13 2.375 1180.78 334.15 846.63 Pass 10896.94 8173.30 10750.00 8657.69 74.76 69.27 246.23 213.22 2.375 1181.05 334.91 846.13 Pass 10921.70 8194.87 10775.00 8677.69 74.80 69.41 246.28 213.28 2.375 1177.91 335.45 842.46 Pass 10946.02 8216.07 10800.00 8697.38 74.84 69.56 246.17 213.16 2.375 1172.72 335.11 837.62 Pass 10969.52 8236.56 10825.00 8715.77 74.88 69.71 245.99 212.98 2.375 1165.15 334.33 830.82 Pass 10991.85 8256.02 10850.00 8732.21 74.91 69.86 245.76 212.76 2.375 1154.90 333.33 821.58 Pass 11012.50 8274.01 10875.00 8746.72 74.94 70.00 245.44 212.44 2.375 1142.38 331.76 810.61 Pass 11031.35 8290.44 10900.00 8759.95 74.97 70.13 244.98 211.97 2.375 1128.84 329.36 799.48 Pass 11047.90 8304.86 10925.00 8771.84 75.00 70.24 244.33 211.33 2.375 1115.02 325.92 789.10 Pass 11062.01 8317.16 10950.00 8782.01 75.02 70.31 243.56 210.55 2.375 1100.93 321.65 779.28 Pass 11073.74 8327.39 10975.00 8789.82 75.04 70.38 242.71 209.70 2.375 1085.87 316.93 768.94 Pass 11082.19 8334.75 11000.00 8794.42 75.05 70.44 241.80 208.79 2.375 1069.80 311.78 758.01 Pass 11088.65 8340.38 11025.00 8797.60 75.06 70.47 240.81 207.80 2.375 1054.21 306.07 748.14 Pass 11093.89 8344.95 11050.00 8800.41 75.07 70.50 239.72 206.71 2.375 1039.94 299.80 740.14 Pass 11098.25 8348.75 11075.00 8802.90 75.07 70.50 238.57 205.56 2.375 1026.77 293.08 733.69 Pass 11101.85 8351.88 11100.00 8804.93 75.08 70.51 237.37 204.36 2.375 1014.33 285.96 728.37 Pass 11104.57 8354.26 11125.00 8805.81 75.08 70.51 236.15 203.15 2.375 1001.60 278.81 722.79 Pass 11106.69 8356.11 11150.00 8805.74 75.09 70.52 234.93 201.92 2.375 988.57 271.59 716.97 Pass 11107.92 8357.18 11175.00 8804.99 75.09 70.52 233.67 200.66 2.375 976.14 264.13 712.01 Pass 11108.12 8357.35 11200.00 8803.77 75.09 70.51 232.35 199.34 2.375 964.98 256.34 708.64 Pass 11108.29 8357.50 11225.00 8803.21 75.09 70.49 230.96 197.96 2.375 955.62 248.22 707.40 Pass 11108.71 8357.86 11250.00 8803.48 75.09 70.46 229.53 196.52 2.375 948.03 239.88 708.15 Pass 11109.39 8358.46 11275.00 8803.72 75.09 70.44 228.08 195.08 2.375 940.54 231.56 708.98 Pass 11110.20 8359.16 11300.00 8803.75 75.09 70.42 226.63 193.62 2.375 933.01 223.34 709.68 Pass 11110.99 8359.85 11325.00 8803.57 75.09 70.41 225.15 192.15 2.375 925.73 215.21 710.52 Pass 11112.42 8361.10 11350.00 8803.70 75.10 70.41 223.67 190.66 2.375 918.59 207.26 711.33 Pass 11114.69 8363.07 11375.00 8804.30 75.10 70.41 222.17 189.16 2.375 911.57 199.55 712.01 Pass 11117.70 8365.70 11400.00 8805.14 75.10 70.43 220.67 187.67 2.375 904.38 192.21 712.17 Pass 11121.19 8368.74 11425.00 8806.02 75.11 70.46 219.17 186.16 2.375 897.06 185.30 711.76 Pass 11124.64 8371.75 11450.00 8806.75 75.12 70.49 217.64 184.64 2.375 890.15 178.84 711.31 Pass 11127.22 8373.99 11475.00 8806.89 75.12 70.52 216.08 183.08 2.375 884.21 172.91 711.31 Pass 11128.70 8375.29 11500.00 8806.45 75.12 70.53 214.49 181.48 2.375 879.70 167.67 712.03 Pass 11129.17 8375.70 11525.00 8805.60 75.12 70.53 212.87 179.86 2.375 876.84 163.30 713.53 Pass 11128.89 8375.46 11550.00 8804.44 75.12 70.53 211.24 178.23 2.375 875.38 160.01 715.38 Pass 11127.88 8374.57 11575.00 8803.02 75.12 70.50 209.60 176.60 2.375 875.41 157.92 717.49 Pass 11126.15 8373.07 11600.00 8801.36 75.12 70.48 207.98 174.97 2.375 876.93 157.10 719.83 Pass 11124.28 8371.43 11625.00 8799.53 75.12 70.45 206.35 173.35 2.375 879.07 157.57 721.51 Pass 11122.00 8369.45 11650.00 8797.54 75.11 70.41 204.75 171.74 2.375 882.29 159.28 723.01 Pass 11118.98 8366.81 11675.00 8795.59 75.11 70.36 203.18 170.17 2.375 887.56 162.09 725.47 Pass 11116.72 8364.85 11700.00 8794.70 75.10 70.31 201.64 168.63 2.375 894.28 165.88 728.40 Pass Sperry-Sun i Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 16 Field: Prudhoe Bay Reference S ite: PB DS 15 Co-ordinate(NE) Refe rence: Well: 15-36, True North Reference Well: 15-36 Vertical (TVD) Reference: 32.5 +31 63.5 Reference Wellpath: Plan 15-366 Db: Oracle Site: PB DS 15 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37A V2 Inter-Site Error: 0.00 ft Refe rence Offset Semi-M ajor Asis ~ Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFb-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg: in ft ft ft 11114.56 8362.96 11725.00 8794.55 75.10 70.24 200.15 167.14 2.375 902.92 170.30 732.62 Pass 11110.89 8359.77 11750.00 8794.24 75.09 70.16 198.76 165.76 2.375 914.26 175.03 739.23 Pass 11106.46 8355.90 11775.00 8793.24 75.09 70.06 197.42 164.41 2.375 926.07 180.11 745.96 Pass 11100.97 8351.12 11800.00 8790.83 75.08 69.98 196.09 163.08 2.375 937.40 185.61 751.80 Pass 11094.72 8345.67 11825.00 8787.05 75.07 69.90 194.77 161.76 2.375 947.88 191.61 756.27 Pass 11089.35 8341.00 11850.00 8783.32 75.06 69.84 193.42 160.41 2.375 957.60 197.97 759.63 Pass 11085.12 8337.31 11875.00 8779.73 75.05 69.80 192.05 159.04 2.375 966.31 204.80 761.51 Pass 11081.69 8334.31 11900.00 8775.94 75.05 69.78 190.66 157.65 2.375 973.94 212.02 761.92 Pass 11078.96 8331.94 11925.00 8772.42 75.04 69.78 189.27 156.26 2.375 981.45 219.47 761.98 Pass 11078.05 8331.15 11950.00 8770.63 75.04 69.78 187.90 154.89 2.375 989.91 226.99 762.92 Pass 11078.82 8331.82 11975.00 8770.40 75.04 69.79 186.56 153.56 2.375 999.09 234.53 764.57 Pass 11080.15 8332.98 12000.00 8770.16 75.05 69.81 185.23 152.22 2.375 1007.84 242.16 765.68 Pass 11081.79 8334.40 12025.00 8769.63 75.05 69.85 183.89 150.89 2.375 1016.06 249.88 766.18 Pass 11083.69 8336.06 12050.00 8768.76 75.05 69.90 182.56 149.55 2.375 1023.71 257.67 766.04 Pass 11086.20 8338.25 12075.00 8767.89 75.06 69.96 181.23 148.22 2.375 1030.81 265.48 765.33 Pass 11089.61 8341.22 12100.00 8767.33 75.06 70.04 179.91 146.90 2.375 1037.43 273.28 764.16 Pass 11094.02 8345.06 12125.00 8767.39 75.07 70.13 178.60 145.60 2.375 1044.00 280.99 763.00 Pass 11099.58 8349.91 12150.00 8768.03 75.08 70.23 177.31 144.31 2.375 1050.08 288.64 761.44 Pass 11106.25 8355.72 12175.00 8769.29 75.09 70.35 176.04 143.03 2.375 1055.75 296.09 759.66 Pass 11114.01 8362.48 12200.00 8771.16 75.10 70.47 174.78 141.78 2.375 1061.02 303.48 757.54 Pass 11122.36 8369.76 12225.00 8773.55 75.11 70.61 173.55 140:54 2.375 1066.65 310.71 755.94 Pass 11130.83 8377.15 12250.00 8775.96 75.13 70.75 172.33 139.33 2.375 1072.54 317.83 754.71 Pass 11139.42 8384.63 12275.00 8777.72 75.14 70.90 171.11 138.10 2.375 1077.19 324.92 752.26 Pass 11148.00 8392.11 12300.00 8778.77 75.15 71.07 169.87 136.87 2.375 1080.70 331.99 748.72 Pass 11156.34 8399.38 12325.00 8779.12 75.17 71.25 168.63 135.63 2.375 1083.54 339.01 744.53 Pass 11165.13 8407.04 12350.00 8779.43 75.18 71.44 167.40 134.40 2.375 1085.65 345.91 739.73 Pass 11174.48 8415.19 12375.00 8779.84 75.19 71.63 166.18 133.18 2.375 1086.98 352.68 734.30 Pass 11184.33 8423.77 12400.00 8780.22 75.21 71.84 164.97 131.96 2.375 1087.27 359.31 727.96 Pass 11194.23 8432.40 12425.00 8780.16 75.22 72.06 163.76 130.76 2.375 1086.47 365.83 720.64 Pass 11203.25 8440.26 12450.00 8779.23 75.24 72.29 162.53 129.53 2.375 1086.32 372.35 713.97 Pass 11212.91 8448.68 12475.00 8778.91 75.25 72.51 161.32 128.31 2.375 1086.52 378.69 707.83 Pass 11223.62 8458.02 12500.00 8779.67 75.27 72.74 160.13 127.12 2.375 1087.12 384.81 702.31 Pass 11235.05 8467.98 12525.00 8781.37 75.29 72.96 158.96 125.95 1088.73 390.72 698.01 Pass 11245.58 8477.15 12547.76 8783.08 75.30 73.17 157.90 124.90 1090.69 395.97 694.72 Pass Site: PB DS 1 5 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37AP B1 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go .411owable NiD TVD MD TVD Ref :Offset TFO+AZI TFO-HS Casing/ HSilistance Area Deviation Warning ft ft ft `' ft ft ft deg deg in ft ft ft 10106.67 7515.34 10150.00 8092.28 73.39 66.83 247.87 217.71 1.000 1041.62 332.09 709.53 Pass 10115.93 7521.94 10175.00 8115.34 73.37 66.77 248.06 216.33 1.000 1049.68 330.67 719.01 Pass 10151.62 7547.59 10200.00 8138.46 73.43 66.83 248.01 215.55 1.000 1057.84 330.43 727.41 Pass 10209.58 7590.53 10225.00 8161.63 73.56 67.00 247.79 215.27 1.000 1065.30 331.13 734.17 Pass 10269.13 7636.24 10250.00 8184.84 73.70 67.17 247.60 214.99 1.000 1072.02 331.87 740.15 Pass 10330.16 7684.69 10275.00 8208.10 73.83 67.35 247.43 214.74 1.000 1077.98 332.65 745.33 Pass 10392.52 7735.79 10300.00 8231.39 73.95 67.52 247.29 214.50 1.000 1083.16 333.48 749.68 Pass 10456.05 7789.40 10325.00 8254.73 74.08 67.69 247.19 214.27 1.000 1087.54 334.32 753.21 Pass 10508.85 7835.05 10350.00 8278.16 74.17 67.83 247.10 214.10 1.000 1091.37 334.90 756.47 Pass 10533.48 7856.52 10375.00 8301.69 74.21 67.93 247.02 214.01 1.000 1095.35 334.75 760.60 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 17 Field: Prudhoe Bay Reference S ite: PB DS 15 C o-ordinate(NE) Reference: Well: 15-36, True North Reference V1'elL• 1 5-36 v ertical (TVD) Refere nce: 32.5 +31 63.5 Reference Wdlpath: Plan 15-36B Db: Oracle Site: PB DS 15 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37AP61 V1 Inter-Site Error: 0.00 ft Refe rence Offsek Semi-Majpr Axis Gtr-Gtr No-Go Allowable N1D TVD N1D TVD Ref Offset TFO+AZI TFO-HS Gasing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10558.04 7877.92 10400.00 8325.31 74.25 68.03 246.93 213.93 1.000 1099.71 334.60 765.11 Pass 10582.53 7899.27 10425.00 8349.03 74.29 68.13 246.85 213.84 1.000 1104.46 334.46 770.00 Pass 10606.94 7920.54 10450.00 8372.84 74.32 68.22 246.77 213.76 1.000 1109.65 334.33 775.33 Pass 10631.21 7941.70 10475.00 8396.75 74.36 68.31 246.69 213.69 1.000 1115.44 334.22 781.22 Pass 10655.35 7962.74 10500.00 8420.75 74.40 68.39 246.63 213.62 1.000 1121.81 334.15 787.67 Pass 10679.41 7983.71 10525.00 8444.79 74.43 68.47 246.56 213.55 1.000 1128.47 334.09 794.39. Pass 10703.45 8004.66 10550.00 8468.84 74.47 68.55 246.50 213.49 1.000 1135.21 334.03 801.18 Pass 10727.47 8025.60 10575.00 8492.91 74.51 68.63 246.43 213.43 1.000 1142.03 333.97 808.05 Pass 10751.48 8046.52 10600.00 8516.98 74.54 68.71 246.37 213.36 1.000 1148.88 333.92 814.96 Pass 10775.48 8067.44 10625.00 8541.06 74.58 68.79 246.31 213.30 1.000 1155.77 333.87 821.90 Pass 10799.47 8088.35 10650.00 8565.15 74.61 68.87 246.24 213.24 1.000 1162.69 333.81 828.88 Pass 10823.45 8109.25 10675.00 8589.24 74.65 68.94 246.18 213.17 1.000 1169.64 333.75 835.88 Pass 10847.45 8130.16 10700.00 8613.33 74.69 69.03 246.12 213.11 1.000 1176.54 333.71 842.84 Pass 10872.04 8151.59 10725.00 8636.39 74.73 69.13 246.14 213.13 1.000 1180.78 334.09 846.69 Pass 10896.94 8173.30 10750.00 8657.69 74.76 69.27 246.23 213.23 1.000 1181.05 334.86 846.19 Pass 10921.70 8194.87 10775.00 8677.69 74.80 69.41 246.28 213.28 1.000 1177.91 335.40 842.51 Pass 10946.01 8216.07 10800.00 8697.38 74.84 69.56 246.17 213.16 1.000 1172.73 335.05 837.68 Pass 10969.52 8236.55 10825.00 8715.77 74.88 69.71 245.99 212.98 1.000 1165.16 334.28 830.88 Pass 10991.85 8256.02 10850.00 8732.21 74.91 69.86 245.76 212.76 1.000 1154.91 333.27 821.63 Pass 11012.50 8274.01 10875.00 8746.72 74.94 70.00 245.44 212.44 1.000 1142.38 331.71 810.67 Pass 11031.35 8290.44 10900.00 8759.95 74.97 70.13 244.98 211.97 1.000 1128.85 329.31 799.54 Pass 11047.89 8304.86 10925.00 8771.84 75.00 70.24 244.34 211.33 1.000 1115.02 325.86 789.16 Pass 11062.01 8317.16 10950.00 8782.01 75.02 70.31 243.56 210.55 1.000 1100.93 321.60 779.33 Pass 11073.74 8327.39 10975.00 8789.82 75.04 70.38 242.71 209.70 1.000 1085.88 316.88 769.00 Pass 11082.19 8334.75 11000.00 8794.41 75.05 70.44 241.80 208.79 1.000 1069.80 311.73 758.07 Pass 11088.65 8340.38 11025.00 8797.60 75.06 70.47 240.81 207.80 1.000 1054.21 306.02 748.19. Pass 11093.89 8344.95 11050.00 8800.40 75.07 70.50 239.72 206.71 1.000 1039.94 299.75 740.19 Pass 11098.25 8348.75 11075.00 8802.90 75.07 70.50 238.57 205.56 1.000 1026.78 293.02 733.75 Pass 11101.85 8351.88 11100.00 8804.93 75.08 70.51 237.37 204.36 1.000 1014.33 285.91 728.43 Pass 11104.57 8354.26 11125.00 8805.81 75.08 70.51 236.15 203.15 1.000 1001.61 278.76 722.85 Pass 11106.69 8356.11 11150.00 8805.74 75.09 70.52 234.93 201.92 1.000 988.57 271.54 717.03 Pass 11107.92 8357.18 11175.00 8804.99 75.09 70.52 233.67 200.66 1.000 976.14 264.08 712.06 Pass 11108.12 8357.35 11200.00 8803.77 75.09 70.51 232.35 199.34 1.000 964.98 256.29 708.69 Pass 11108.29 8357.50 11225.00 8803.21 75.09 70.49 230.96 197.96 1.000 955.62 248.17 707.45 Pass 11108.71 8357.86 11250.00 8803.48 75.09 70.46 229.53 196.52 1.000 948.03 239.83 708.21 Pass 11109.39 8358.46 11275.00 8803.72 75.09 70.44 228.08 195.08 1.000 940.54 231.51 709.03 Pass 11110.20 8359.16 11300.00 8803.75 75.09 70.42 226.63 193.62 1.000 933.01 223.29 709.73 Pass 11110.99 8359.85 11325.00 8803.56 75.09 70.41 225.15 192.15 1.000 925.73 215.16 710.58 Pass 11112.42 8361.10 11350.00 8803.70 75.10 70.41 223.67 190.66 1.000 918.59 207.21 711.38 Pass 11114.68 8363.07 11375.00 8804.30 75.10 70.41 222.17 189.16 1.000 911.57 199.50 712.07 Pass 11117.70 8365.70 11400.00 8805.14 75.10 70.43 220.67 187.67 1.000 904.38 192.16 712.22 Pass 11121.19 8368.74 11425.00 8806.02 75.11 70.46 219.17 186.16 1.000 897.06 185.25 711.81 Pass 11124.64 8371.75 11450.00 8806.75 75.12 70.49 217.64 184.64 1.000 890.15 178.79 711.36 Pass 11127.21 8373.99 11475.00 8806.89 75.12 70.52 216.08 183.08 1.000 884.21 172.86 711.36 Pass 11128.70 8375.29 11500.00 8806.45 75.12 70.53 214.49 181.48 1.000 879.70 167.62 712.08 Pass 11129.17 8375.70 11525.00 8805.60 75.12 70.53 212.87 179.86 1.000 876.84 163.25. 713.58 Pass 11128.89 8375.46 11550.00 8804.44 75.12 70.53 211.24 178.23 1.000 875.38 159.95 715.43 Pass 11127.88 8374.57 11575.00 8803.02 75.12 70.50 209.60 176.60 1.000 875.40 157.86 717.54 Pass 11126.15 8373.07 11600.00 8801.36 75.12 70.48 207.98 174.97 1.000 876.93 157.05 719.88 Pass 11124.28 8371.43 11625.00 8799.53 75.12 70.45 206.36 173.35 1.000 879.07 157.51 721.56 Pass 11122.00 8369.45 11650.00 8797.54 75.11 70.41 204.75 171.74 1.000 882.29 159.22 723.06 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4/12/2006 Time: 09:51:06 Page: 18 Field: Prudhoe Bay Reference S ite: PB DS 15 C o-ordinate(NE) Refe rence: Well: 15-36, True North Reference Well: 15-36 V ertical (TV D) Reference: 32.5 +31 63.5 Reference Wellpath: Plan 15-366 Db: Oracle Site: PB DS 15 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-37AP 61 V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Aus Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingJ HSDistauce Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11118.98 8366.81 11675.00 8795.59 75.11 70.36 203.18 170.17 1.000 887.56 162.04 725.52 Pass 11116.72 8364.85 11700.00 8794.70 75.10 70.31 201.64 168.63 1.000 894.28 165.83 728.45 Pass 11115.32 8363.63 11725.00 8794.72 75.10 70.27 200.12 167.12 1.000 901.98 170.47 731.52 Pass 11114.60 8363.00 11750.00 8795.17 75.10 70.23 198.63 165.62 1.000 909.98 175.82 734.16 Pass 11114.57 8362.97 11775.00 8796.03 75.10 70.19 197.15 164.14 1.000 918.23 181.77 736.47 Pass 11115.02 8363.37 11800.00 8797.03 75.10 70.16 195.68 162.68 1.000 926.54 188.22 738.32 Pass 11115.18 8363.50 11825.00 8797.11 75.10 70.14 194.22 161.21 1.000 934.19 195.16 739.03 Pass 11115.01 8363.35 11850.00 8796.46 75.10 70.14 192.76 159.75 1.000 941.56 202.47 739.09 Pass 11114.91 8363.27 11875.00 8795.56 75.10 70.14 191.31 158.30 1.000 948.94 210.06 738.88 Pass 11115.99 8364.21 11900.00 8795.45 75.10 70.16 189.88 156.87 1.000 956.45 217.83 738.62 Pass 11118.30 8366.23 11925.00 8796.20 75.11 70.17 188.46 155.46 1.000 964.09 225.71 738.38 Pass 11120.80 8368.40 11950.00 8797.14 75.11 70.20 187.08 154.07 1.000 972.35 233.62 738.73 Pass 11123.03 8370.34 11975.00 8797.99 75.11 70.22 185.72 152.71 1.000 981.48 241.49 739.99 Pass 11125.39 8372.40 12000.00 8799.09 75.12 70.24 184.39 151.38 991.38 249.26 742.12 Pass 11127.39 8374.15 12020.76 8800.07 75.12 70.26 183.31 150.30 1000.05 255.63 744.42 Pass Site: PB DS 15 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-376 V4 Inter-Site Error: 0.00 ft Reference Offset `Semi-Major Avis Ctr-Cfr No-Go Allowable MD TVIT NtD TVD Ref Offset TFO+AZI TFO-I3S Casing/HSflistance Area Deviation Warning ft ft ft ft - ft ft deg deg , in ' ft ft ft 10105.68 7514.63 10200.00 8281.03 73.40 29.81 231.17 201.18 4.500 1174.20 186.05 988.15 Pass 10115.36 7521.54 10225.00 8305.69 73.37 29.75 231.40 199.77 4.500 1187.71 185.05 1002.66 Pass 10169.92 7560.98 10250.00 8330.36 73.47 29.75 231.43 198.95 4.500 1201.19 185.04 1016.15 Pass 10273.03 7639.29 10275.00 8355.01 73.70 29.80 231.26 198.65 4.500 1213.38 185.86 1027.52 Pass 10385.23 7729.74 10300.00 8379.65 73.94 29.86 231.12 198.34 4.500 1223.91 186.55 1037.36 Pass 10502.55 7829.56 10325.00 8404.23 74.16 29.91 231.00 197.99 4.500 1232.37 186.95 1045.42 Pass 10526.40 7850.34 10350.00 8428.60 74.20 29.93 230.82 197.82 4.500 1238.83 186.29 1052.55 Pass 10550.34 7871.21 10374.98 8452.75 74.24 29.95 230.62 197.61 4.500 1244.45 185.53 1058.93 Pass 10574.37 7892.15 10400.00 8476.78 74.27 29.97 230.40 197.40 4.500 1249.58 184.70 1064.88 Pass 10598.27 7912.99 10425.00 8500.66 74.31 29.99 230.15 197.14 4.500 1254.35 183.73 1070.63 Pass 10621.87 7933.55 10450.00 8524.28 74.34 30.00 229.83 196.83 4.500 1258.74 182.49 1076.25 Pass 10645.02 7953.73 10475.00 8547.56 74.38 30.02 229.45 196.44 4.500 1262.79 180.98 1081.81 Pass 10667.59 7973.40 10500.00 8570.34 74.41 30.04 228.99 195.98 4.500 1266.48 179.18 1087.30 Pass 10689.39 7992.40 10525.00 8592.46 74.45 30.05 228.46 195.45 4.500 1269.78 177.08 1092.70 Pass 10710.39 8010.70 10550.00 8613.83 74.48 30.06 227.86 194.85 4.500 1272.66 174.72 1097.94 Pass 10730.72 8028.42 10575.00 8634.52 74.51 30.07 227.22 194.21 4.500 1275.23 172.19 1103.03 Pass 10750.29 8045.48 10600.00 8654.59 74.54 30.08 226.53 193.52 4.500 1277.74 169.51 1108.24 Pass 10769.02 8061.80 10625.00 8673.65 74.57 30.09 225.79 192.78 4.500 1279.64 166.65 1112.99 Pass 10786.61 8077.13 10650.00 8691.58 74.60 30.10 225.00 191.99 4.500 1281.20 163.62 1117.58 Pass 10802.97 8091.40 10675.00 8708.27 74.62 30.10 224.16 191.15 4.500 1282.39 160.44 1121.95 Pass 10818.29 8104.75 10700.00 8723.56 74.64 30.11 223.27 190.27 4.500 1282.67 157.17 1125.50 Pass 10832.54 8117.17 10725.00 8737.32 74.67 30.12 222.36 189.35 4.500 1281.91 153.84 1128.06 Pass 10846.00 8128.90 10750.00 8750.02 74.69 30.12 221.42 188.41 4.500 1280.62 150.52 1130.10 Pass 10859.16 8140.37 10775.00 8762.21 74.71 30.13 220.47 187.46 4.500 1279.15 147.28 1131.87 Pass 10872.11 8151.65 10800.00 8773.89 74.73 30.14 219.51 186.51 4.500 1277.34 144.13 1133.21 Pass 10884.46 8162.42 10825.00 8784.58 74.74 30.15 218.54 185.54 4.500 1274.92 141.08 1133.85 Pass 10895.99 8172.47 10850.00 8794.30 74.76 30.16 217.55 184.54 4.500 1272.28 138.12 1134.16 Pass 10906.82 8181.91 10875.00 8803.20 74.78 30.17 216.54 183.54 4.500 1269.62 135.30 1134.32 Pass 10916.48 8190.33 10900.00 8810.55 74.79 30.18 215.51 182.51 4.500 1266.23 132.63 1133.59 Pass 10924.60 8197.40 10925.00 8815.87 74.81 30.20 214.46 181.45 4.500 1261.83 130.15 1131.68 Pass Sperry-Sun Anticollision Report Company: BP Amoco Date: 4(12/2006 Time: 09:51:06 Page: 19 Field: Prudhoe Bay Reference S ite: PB DS 15 CO-r-rdlnate(NE) Refe rence: Well: 15-36, True No rth Reference Wcll: 15-36 Vertical (TV D) Refere nce: 32.5 +31 63.5 Reference ~Yel-path: Plan 15-36B Db: Oracle Site: PB DS 1 5 Well: 15-37 Rule Assigned: Major Risk Wellpath: 15-376 V4 Inter-Site Error: 0.00 ft Refereuce Offset Semi-Major Aus Ctr-CG• No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZL TFO=HS Casing/H~Distance Area Deviation Warning ft ft ft ft ft ft deg , deg_ in ft ft ft 10931.15 8203.11 10950.00 8819.21 74.82 30.21 213.39 180.38 4.500 1256.62 127.90 1128.72 Pass 10936.73 8207.97 10975.00 8820.98 74.83 30.23 212.31 179.30 4.500 1250.40 125.95 1124.45 Pass 10941.81 8212.40 11000.00 8821.80 74.83 30.25 211.23 178.23 4.500 1243.53 124.32 1119.21 Pass 10946.78 8216.73 11025.00 8822.10 74.84 30.27 210.15 177.14 4.500 1236.26 123.04 1113.22 Pass 10951.57 8220.91 11050.00 8822.08 74.85 30.29 209.06 176.05 4.500 1229.07 122.14 1106.93 Pass 10955.95 8224.73 11075.00 8821.77 74.85 30.31 207.95 174.94 4.500 1222.50 121.64 1100.87 Pass 10960.17 8228.40 11100.00 8821.47 74.86 30.33 206.83 173.82 4.500 1216.70 121.56 1095.14 Pass 10963.71 8231.49 11125.00 8820.93 74.87 30.35 205.68 172.67 4.500 1212.12 121.94 1090.19 Pass 10967.08 8234.43 11150.00 8820.38 74.87 30.37 204.52 171.51 4.500 1208.34 122.76 1085.58 Pass 10970.33 8237.26 11175.00 8819.97 74.88 30.39 203.35 170.34 4.500 1205.58 124.05 1081.53 Pass 10973.33 8239.87 11200.00 8819.69 74.88 30.40 202.17 169.17 4.500 1204.06 125.78 1078.28 Pass 10976.12 8242.30 11225.00 8819.41 74.89 30.41 200.99 167.98 4.500 1203.44 127.94 1075.51 Pass 10978.79 8244.63 11250.00 8819.08 74.89 30.43 199.81 166.80 4.500 1203.45 130.47 1072.98 Pass 10981.32 8246.83 11275.00 8818.75 74.89 30.44 198.62 165.62 4.500 1204.24 133.36 1070.87 Pass 10983.72 8248.93 11300.00 8818.46 74.90 30.45 197.44 164.44 4.500 1205.83 136.55 1069.28 Pass 10986.32 8251.20 11325.00 8818.25 74.90 30.46 196.27 163.26 4.500 1207.76 140.01 1067.75 Pass 10989.06 8253.58 11350.00 8818.06 74.91 30.47 195.09 162.09 4.500 1209.98 143.70 1066.27 Pass 10991.30 8255.53 11375.00 8817.49 74.91 30.48 193.92 160.92 4.500 1212.84 147.60 1065.24 Pass 10992.98 8257.00 11400.00 8816.52 74.91 30.49 192.76 159.75 4.500 1216.37 151.66 1064.71 Pass 10994.11 8257.98 11425.00 8815.14 74.91 30.50 191.60 158.59 4.500 1220.58 155.86 1064.72 Pass 10994.93 8258.70 11450.00 8813.57 74.91 30.51 190.45 157.45 4.500 1225.45 160.16 1065.28 Pass 10995.89 8259.54 11475.00 8812.20 74.92 30.52 189.32 156.31 4.500 1230.96 164.54 1066.42 Pass 10997.00 8260.50 11500.00 8811.04 74.92 30.53 188.19 155.19 4.500 1237.11 168.96 1068.15 Pass 10998.24 8261.58 11525.00 8810.07 74.92 30.54 187.08 154.08 4.500 1243.88 173.40 1070.48 Pass 10999.60 8262.77 11550.00 8809.28 74.92 30.54 185.99 152.98 4.500 1251.24 177.85 1073.39 Pass 11001.09 8264.06 11575.00 8808.65 74.92 30.55 184.91 151.90 4.500 1259.17 182.29 1076.88 Pass 11002.68 8265.46 11600.00 8808.17 74.93 30.56 183.84 150.84 4.500 1267.64 186.69 1080.94 Pass 11004.44 8266.99 11625.00 8807.87 74.93 30.57 182.79 149.79 4.500 1276.61 191.06 1085.54 Pass 11006.88 8269.11 11650.00 8807.97 74.93 30.58 181.76 148.75 4.500 1285.59 195.41 1090.18 Pass 11009.78 8271.64 11675.00 8808.32 74.94 30.59 180.73 147.72 4.500 1294.68 199.72 1094.96 Pass 11012.79 8274.26 11700.00 8808.75 74.94 30.61 179.72 146.71 4.500 1304.13 203.98 1100.15 Pass 11015.90 8276.97 11725.00 8809.26 74.95 30.62 178.72 145.71 4.500 1313.97 208.18 1105.79 Pass 11019.07 8279.74 11750.00 8809.91 74.95 30.64 177.74 144.74 4.500 1324.35 212.30 1112.05 Pass 11022.15 8282.42 11775.00 8810.52 74.96 30.65 176.78 143.78 4.500 1335.20 216.34 1118.86 Pass 11024.46 8284.43 11800.00 8810.33 74.96 30.67 175.83 142.82 4.500 1346.24 220.34 1125.90 Pass 11026.26 8286.00 11825.00 8809.58 74.96 30.68 174.89 141.88 4.500 1357.44 224.27 1133.17 Pass 11027.99 8287.51 11850.00 8808.67 74.97 30.69 173.95 140.95 4.500 1368.84 228.12 1140.71 Pass 11029.38 8288.73 11875.00 8807.31 74.97 30.71 173.03 140.02 4.500 1380.32 231.92 1148.39 Pass 11030.11 8289.36 11900.00 8805.14 74.97 30.73 172.11 139.10 4.500 1391.74 235.67 1156.07 Pass 11030.98 8290.12 11925.00 8802.94 74.97 30.74 171.20 138.19 4.500 1403.22 239.37 1163.85 Pass 11032.41 8291.36 11950.00 8801.08 74.97 30.76 170.30 137.29 4.500 1414.78 242.99 1171.79 Pass 11034.36 8293.06 11975.00 8799.70 74.98 30.78 169.42 136.41 4.500 1426.70 246.54 1180.16 Pass 11036.76 8295.15 12000.00 8798.81 74.98 30.81 168.56 135.55 4.500 1439.09 249.98 1189.11 Pass 11039.02 8297.13 12025.00 8797.96 74.98 30.83 167.71 134.71 4.500 1452.09 253.30 1198.79 Pass 11041.16 8298.99 12050.00 8797.17 74.99 30.85 166.89 133.89 4.500 1465.71 256.51 1209.20 Pass are • • i N ~_ ~ 15-36B of bag BAG 7 1/16" 5000 psi. of bag of slips of pipes of flow cross of pipe/slips Blind/Shears _ TOTs 2 3/8" combi ram/slips ~ ~ ~/is" 5ooopsi Mud Cross I I Mud Cross 7 1/16" 5000psi variable bore pipe 3 1/2"-2 3/8" TOTs 2 3/8" combi ram/slips ~ 1/16" 5000psi Flow Tee • TERRIE L NUBBLE 89-6/1252 271 BP EXPLORATION AK INC "Mastercard Check" PO BOX 1.96612 MB 7-5 , I ,~ ANCHORAGE, AK 99519-6612 DATE ~ PAY TO THE w ORDER OF ~ ~ ~ ~ ~ First National Bank Alaska Anchorage, AK 99501 MEMO'~~_~ 6 ~:L25200060~:99L4~~~622?~~~L5S6li' 0271 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ ~~ ,~~~~ PTD# ~ -r ~ ~ ~ _~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with ZO AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Com~any Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\jody\transmittal checklist WELL PERMIT CHECKLIST Feld & Pool PRUDHOE BAY, PRUDHOE OIL.- 640150 _ _ _ _ Well Name: PRUDHOE BAY UNIT 15-366 _ _ __ _Program DEV _ Well bore seg PTD#:2060730 C ompany BP EXPLORATION (ALASKA) INC_____ __ __- Initial ClasslType DEV /_PEND__GeoArea 890 Unit 11650 _. On1Off Shore On Annular Disposal Administration '~ 1 Permit fee attached _ _ _ Yes ~2 Lease number appropriate _ - - Yes 3 Unique well-name and number Yes !~4 Well located n_a defned-pool Yes - 5 Well located properdistancefro_m.drillingunit_boundary_ Yes ',6 Well located proper distance from other wells , - _ _ _ - Yes ~'i7 Sufficient acreage available in drillingunit_ Yes '8 If.deviated, s_wellbore platincluded - . _ Yes ,,9 Operator only affected party-- _ _ Yes '~10 Operator has appropriate bond intorce - . Yes 1111 Permitcan be issued without conservation order- Yes 12 Pe[mit-can be issued without administrative approval Yes A r Date pp 13 -Can permit be approved before 15-day wait- - - - - - - - - - - - - - - - - - - - - - - - - Yes RPC 5H8l2006 x,14 Well cczted within area and strata authorized by Injection O[de[# (put1O# in-comments)_(For_ NA- ~115 All wells within 114,mile area of review identified (For service-well only) NA_ 16 Pre-produced mjector; duration of pre production less than_ 3 months (For service welt only) NA- ACMP-Finding of Consistency_has been issued forthis p[oject_ - - - - - ---- - - - - - - tJA- 18 - -- _ -- - - ---- -- Conductor strmgprovided - _ _ _ A -- - Engineering I19 Surface casing_protects all.known_ USDWS - NA 20 CMT_voladequate-to circulate on conducto[& surf.csg _N_A 121 CMT-votadequate.to tie-in.long string to surf csg_ _ - _ _ _ _ _ _ _ . _ _ _ _ _ - NA_ - - _ 122 CMT_will cover all known_productiye horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ Adequate excess ~,i23 Casing designs adequate f_or C, T, B & permafrost_ _ - - _ _ - . Yes 24 Adequaie tankage or reserve pit Yes . Nabors 27E / CTDU. ~i25 If.a-re-drill, has a.10-403 for abandonment been approved - - Yes - - 411112006..... '26 Adequate wetlbore separation_p(oposed- - . - _ _ _ - - - Yes _ _ _ _ '!27 If diverter required, does it meet_ regulations NA_ _ _ _ Sidetrack. __ ~~28 Dril_lingFlnid-program schematic & equip list adequate- Yes . . Max MW 9,9 ppg, Appr Date ':29 x BOPEs,_do they meetregulation - - Yes WGA 512212006 ,30 BOPE_press rating appropriate; test t_o_(pu_t prig in comments)- Yes Test to 3500. psi. MSP 2785 psi.- 131 Choke_manifold complieswlAPl_RP-53 (May84)- - - - - - - - -- - - - - - -- - - - - - - - - - Yes _ _ '32 Work will occur without operation shutdown- - _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes !~33 Is Rresence_of H2$ gas_probable - - No Not an H2S pad, - 134 Mechanical condition of wells within AOR verified (FOrservice well only NA- - - . - 35 --- - - -,. Permitcan be issued wlo hydrogen_sulfidemeosures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ o_ - ------ -- _ _ _ - - -- Geology 136 Data-presented on potential overpressure zones.. - - NA_ '37 Seismic.analysis ofshallow gas zones- - NA_ Appr Date 38 Seabed condition sunrey_(if off shore) _ _ _ _ _ NA_ - _ -- - RPC 5!1812006 '139 Contact namelphonefor weekly_p_rogressreports-[exploratory only) NA - . • ~i Geologic Engineering Public Date: Date Date Commissioner: Commissioner: Commiss ner ~ ~ ~. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Penmmitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify Minding information, infommation of this nature is accumulated at the end of ttie Mile under APPENDIX. IJo special effort has been made to chronologically organize this category of information. ~~ 15-36b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 04 15:11:44 2008 Reel Header Service name .............LISTPE Date . ...................08/04/04 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/04/04 Origin ...................STs Tape Name. ... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Library. scientific Technical services Library. scientific Technical services 15-366 500292248002 BP Exploration (Alaska) Inc. Sperry Drilling Services 04-APR-08 MWD RUN 2 MWD RUN 3 MWD RUN 4 Mw0004521685 Mw0004521685 Mw0004521685 N. WHITE N. WHITE B. JAHN C. CLEMENS C. CLEMENS R. BORDES / MWD RUN 5 MWD RUN 6 MWD RUN 7 Mw0004521685 Mw0004521685 Mw0004521685 B. JAHN B. JAHN S. LATZ R. BORDES / R. BORDES / R. BORDES / MWD RUN 9 MWD RUN 11 MWD RUN 12 Mw0004521685 Mw0004521685 MW0004521685 S. LATZ S. LATZ S. LATZ R. BORDES/J. R. BORDES/J. R. BORDES/J. MWD RUN 13 MAD RUN 13 Page 1 ~~C`SCo- 0~3 ~ 1~~ JOS NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Mw0004521685 S. LATZ R. BORDES/J. 15-36b.tapx Mw0004521685 S. LATZ R. BORDES/J. 22 11N 14E 1440 SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 887 64.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1sT STRING 6.500 7.625 10097.0 2ND STRING 4.125 4.500 10988.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. 15-366 WAS DRILLED FROM AN ALUMINUM BILLET (WHIPSTOCK) POSITIONED IN THE 15-366 PB1 WELLBORE. THE TOP OF THE BILLET WAS AT 11515'MD/8647'TVDSS. THIS OPEN-HOLE SIDETRACK WAS EFFECTED ON MWD RUN 11. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THESE RUNS WERE DRILLED BY NABORS 27E. NO PROGRESS WAS MADE ON MWD RUN 1 DUE TO A TOOL MALFUNCTION. THE WHIPSTOCK WAS SET, THE WINDOW MILLED, AND A BIT OF RAT HOLE DRILLED ON MWD RUN 2. S. MWD RUNS 4-7,11 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. RUNS 9 (ONLY RUN 9 MAD DATA ARE INCLUDED - FOR CONTINUITY),12,13 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). EWR4 MAD DATA OVER THE RUN 11 INTERVAL WERE ACQUIRED WHILE RIH FOR MWD RUN 12. THESE MAD DATA WERE MERGED WITH RUN 12 MWD DATA. UPHOLE MAD DATA ACQUIRED WHILE POOH AFTER REACHING FINAL TD ARE PRESENTED SEPARATELY. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA Page 2 15-36b.tapx RAY RUN IN 15-366 oN 8/5/2006. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 1/31/2008. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1-7,11-13 REPRESENT WELL 15-36B WITH API#: 50-029-22480-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13285'MD/8715'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPS RPD FET RPM RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 9813.0 10090.5 10971.0 10971.0 10971.0 10971.0 10971.0 STOP DEPTH 13242.5 13285.0 13254.5 13254.5 13254.5 13254.5 13254.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 9847.5 9844.0 9860.0 9856.5 9874.5 9871.5 9900.5 9898.5 Page 3 15-36b.tapx 9924.5 9923.5 9936.0 9934.0 9945.5 9944.5 9969.5 9969.0 9988.5 9986.5 10031.5 10029.0 10083.5 10090.0 10087.5 10094.0 10095.0 10102.5 10109.0 10115.0 10121.0 10126.5 10128.5 10134.5 10135.5 10140.5 10139.5 10146.0 10172.5 10176.5 10279.0 10284.5 10287.5 10292.0 10292.5 10298.0 10339.5 10343.5 10342.5 10345.5 10344.0 10347.0 10360.0 10362.5 10362.5 10365.0 10373.5 10376.0 10375.5 10378.0 10404.0 10406.5 10406.0 10409.0 10408.0 10411.0 10417.5 10421.0 10425.5 10427.5 10432.5 10434.5 10447.5 10449.5 10455.5 10457.0 10457.5 10459.5 10478.5 10481.5 10500.5 10503.0 10513.0 10514.5 10522.5 10524.5 10524.5 10527.0 10537.0 10539.5 10544.0 10545.5 10549.0 10550.5 10552.0 10553.5 10562.0 10564.5 10565.5 10567.5 10571.0 10572.5 10583.0 10585.0 10588.5 10591.0 10593.5 10595.5 10595.5 10597.5 10598.0 10600.0 10611.5 10611.5 10618.0 10619.5 10624.5 10625.0 10631.5 10632.0 10645.5 10646.5 10660.5 10661.0 10664.0 10665.0 10668.0 10669.0 10670.5 10671.5 10674.0 10675.0 10675.5 10676.5 10682.5 10684.0 Page 4 15-36b.tapx 10684.5 10685.5 10686.5 10688.5 10700.0 10700.0 10705.0 10705.5 10715.5 10717.0 10719.5 10720.0 10729.0 10729.5 10761.0 10761.0 10771.5 10771.5 10785.5 10785.5 10787.0 10787.0 10790.5 10791.5 10796.5 10797.0 10808.5 10810.0 10819.5 10820.0 10836.5 10836.5 10852.0 10851.0 10858.5 10858.0 10905.0 10905.0 10944.5 10946.5 10971.0 10970.0 10974.5 10973.5 10980.5 10979.5 11001.5 11000.5 11015.0 11013.5 11017.0 11015.5 11023.0 11022.5 11038.5 11037.5 11041.0 11040.0 11042.5 11041.5 11047.0 11047.5 11054.5 11053.5 11059.0 11057.5 11065.5 11063.0 11067.5 11065.5 11075.5 11075.0 11079.0 11078.5 11085.5 11085.5 11089.5 11089.0 11101.5 11101.0 11106.5 11106.5 11118.0 11116.5 11127.0 11126.5 11129.0 11128.0 11132.0 11130.0 11147.0 11146.0 11150.5 11149.5 11156.5 11156.5 11161.0 11159.5 11165.0 11164.0 11170.0 11169.5 11172.0 11171.0 11176.5 11176.0 11178.0 11177.0 11184.0 11182.5 11189.5 11189.0 11199.5 11198.5 11202.5 11202.5 11214.0 11213.5 11220.5 11220.0 11224.5 11224.0 11229.0 11228.5 11233.0 11232.5 Page 5 • 15-36b.tapx 11238.0 11237.5 11265.0 11263.0 11365.0 11362.5 11371.0 11369.0 11414.0 11412.0 11428.5 11427.0 11431.5 11429.5 11433.5 11431.5 11443.0 11441.5 11452.5 11450.0 11454.0 11453.0 11459.5 11458.5 11463.0 11463.0 11484.5 11484.0 11487.5 11486.0 11494.0 11492.0 11501.0 11500.0 11508.0 11507.0 11511.0 11509.5 11513.5 11512.5 11515.5 11514.5 11550.5 11549.5 11554.0 11554.0 11565.0 11565.0 11575.5 11576.0 11580.0 11580.0 11582.5 11582.0 11603.5 11603.0 11608.0 11607.0 11632.5 11632.0 11643.5 11643.5 11653.5 11653.0 11659.5 11659.5 11684.0 11684.0 11692.5 11692.0 11709.0 11708.5 11737.0 11738.0 11744.5 11745.5 11766.0 11767.0 11769.0 11771.5 11782.0 11783.5 11789.5 11791.0 11818.0 11821.0 11823.0 11826.0 11836.5 11839.5 11842.5 11845.5 11855.5 11856.0 11866.0 11866.0 11875.5 11874.5 11884.0 11882.5 11894.0 11891.5 11915.0 11916.5 11928.0 11930.0 11952.0 11953.5 11972.5 11975.0 11982.5 11984.0 11987.0 11990.5 12021.0 12024.5 12062.0 12062.5 12063.5 12064.0 12068.0 12068.5 12070.5 12071.0 12082.0 12082.5 Page 6 r ~~ 12090.5 12130.0 12142.5 12163.0 12199.0 12214.0 12231.0 12267.0 12372.5 12450.5 12454.5 12460.5 12470.0 12483.0 12486.5 12508.5 12510.5 12533.0 12553.0 12555.5 12564.5 12591.0 12601.5 12617.5 12631.0 $3285.0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD REMARKS: 12091.0 12130.0 12142.5 12163.5 12198.0 12213.5 12231.0 12266.5 12371.0 12451.5 12455.0 12461.0 12472.0 12482.5 12486.5 12509.5 12512.0 12532.5 12551.0 12554.0 12565.5 12590.5 12601.5 12618.0 12631.0 13285.0 15-36b.tapx BIT RUN NO MERGE TOP MERGE BASE 2 9809.5 10124.0 3 10124.0 10988.5 4 10988.5 11101.0 5 11101.0 11269.0 6 11269.0 11280.0 7 11280.0 11515.0 9 10970.0 11515.0 11 11515.5 11754.0 12 11754.0 12276.0 13 12276.0 13285.0 MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 s Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 Page 7 ~ ~ 15-36b.tapx FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 9813 13285 11549 6945 9813 13285 RPD MWD OHMM 0.16 2000 121.618 4568 10971 13254.5 RPM MWD OHMM 2.31 2000 166.199 4568 10971 13254.5 RPS MWD OHMM 0.25 2000 105.786 4568 10971 13254.5 RPX MWD OHMM 0.14 2000 75.3302 4568 10971 13254.5 FET MWD HOUR 0.22 460.71 28.9616 4545 10971 13254.5 GR MWD API 19.15 755.57 90.9967 6860 9813 13242.5 ROP MWD FT/H 0.08 747.67 81.5567 6390 10090.5 13285 First Reading For Entire File..........9813 Last Reading For Entire File...........13285 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......5T5LI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10972.0 13231.0 RPS 10990.0 13245.0 RAT 10990.0 13282.0 RPM 10990.0 13245.0 RPD 10990.0 13245.0 RPx 10990.0 13245.0 FET 11002.0 13245.0 MERGED DATA SOURCE Page 8 15-36b.tapx PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MwD 13 1 10971.0 13285.0 S REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MAD OHMM 4 1 68 4 2 RPM MAD OHMM 4 1 68 8 3 RPS MAD OHMM 4 1 68 12 4 RPX MAD OHMM 4 1 68 16 5 FET MAD HOUR 4 1 68 20 6 GR MAD API 4 1 68 24 7 RAT MAD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 10972 13282 12127 4621 10972 13282 RPD MAD OHMM 3.56 2000 103.108 4511 10990 13245 RPM MAD OHMM 1.87 2000 104.306 4511 10990 13245 RPS MAD OHMM 1.39 2000 77.8768 4511 10990 13245 RPX MAD OHMM 1.36 2000 52.1809 4511 10990 13245 FET MAD HOUR 0.6 277.22 82.5279 4487 11002 13245 GR MAD API 15.49 324.7 54.8036 4519 10972 13231 RAT MAD FT/H 470 3528 978.46 4585 10990 13282 First Reading For Entire File..........10972 Last Reading For Entire File...........13282 File Trailer service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service sub Level Name... Page 9 15-36b.tapx version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9809.5 10072.5 ROP 10097.5 10124.0 LOG HEADER DATA DATE LOGGED: 08-]UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME); Memory TD DRILLER (FT): 10124.0 TOP LOG INTERVAL (FT): 9809.0 BOTTOM LOG INTERVAL (FT): 10124.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE; ,Q MAXIMUM ANGLE; ,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 93091 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.500 DRILLER'S CASING DEPTH (FT): 10097.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 52.0 MUD PH: $.9 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 3.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 109.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 10 i • REMARKS: 15-36b.tapx Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9809.5 10124 9966.75 630 9809.5 10124 GR MwD020 API 38.38 158.5 87.568 527 9809.5 10072.5 ROP MWD020 FT/H 0.68 10.24 5.55778 54 10097.5 10124 First Reading For Entire File..........9809.5 Last Reading For Entire File...........10124 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type .. .............LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 Page 11 15-36b.tapx FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10073.0 10946.0 ROP 10124.5 10988.5 LOG HEADER DATA DATE LOGGED: 10-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10988.0 TOP LOG INTERVAL (FT): 10124.0 BOTTOM LOG INTERVAL (FT): 10988.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.7 MAXIMUM ANGLE: 44.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78012 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.500 DRILLER'S CASING DEPTH (FT): 10097.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 47.0 MUD PH: $,9 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 109.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 12 15-36b.tapx Depth units .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 RoP MwD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10073 10988.5 10530.8 1832 10073 10988.5 GR MWD030 API 49.59 448.21 173.678 1747 10073 10946 ROP MWD030 FT/H 0.23 377.06 91.8584 1729 10124.5 10988.5 First Reading For Entire File..........10073 Last Reading For Entire File...........10988.5 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EoF File Header service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10946.5 11071.0 ROP 10989.0 11101.0 LOG HEADER DATA DATE LOGGED: 24-7UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 13 15-36b.tapx TD DRILLER (FT): 11101.0 TOP LOG INTERVAL (FT): 10988.0 BOTTOM LOG INTERVAL (FT): 11101.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21,7 MAXIMUM ANGLE: 27,3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 35.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 120.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ...,. Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10946.5 11101 11023.8 310 10946.5 11101 Page 14 15-36b.tapx GR MWD040 API 47.5 538.99 141.302 250 10946.5 11071 ROP MWD040 FT/H 0.08 747.67 48.6664 225 10989 11101 First Reading For Entire File..........10946.5 Last Reading For Entire File...........11101 File Trailer service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........sTSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sT5LI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11071.5 11239.5 ROP 11101.5 11269.0 LOG HEADER DATA DATE LOGGED: 25-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11269.0 TOP LOG INTERVAL (FT): 11101.0 BOTTOM LOG INTERVAL (FT): 11269.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.0 MAXIMUM ANGLE: 27.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $CG Natural gamma ray TLG015 Page 15 15-36b.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (s): 39.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 6.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 124.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD050 API 4 1 68 4 2 ROP MWD050 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11071.5 11269 11170.3 396 11071.5 11269 GR MWD050 API 20.83 755.57 59.556 337 11071.5 11239.5 ROP MWD050 FT/H 0.51 172.14 49.6838 336 11101.5 11269 First Reading For Entire File..........11071.5 Last Reading For Entire File...........11269 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Page 16 15-36b.tapx Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EoF File Header Service name... .......STSLIB.007 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 ... File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11240.0 11250.5 ROP 11269.5 11280.0 LOG HEADER DATA DATE LOGGED: 26-~uL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11280.0 TOP LOG INTERVAL (FT): 11269.0 BOTTOM LOG INTERVAL (FT): 11280.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.1 MAXIMUM ANGLE: 27.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (5): 62.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 7.6 RESISTIVITY (OHMM) AT TEMPERATU RE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 Page 17 .0 ~ ~ 15-36b.tapx MUD AT MAX CIRCULATING TERMPERATURE: .000 124.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ........,.0 Data Specification Block Type.....0 Logging DireCtion .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11240 11280 11260 81 11240 11280 GR MWD060 API 22.26 26.77 24.2736 22 11240 11250.5 ROP MWD060 FT/H 0.24 230.14 33.4734 22 11269.5 11280 First Reading For Entire File..........11240 Last Reading For Entire File...........11280 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........sT5L26.008 Physical EOF File Header Service name... ......STSLI6.008 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Page 18 • • 15-36b.tapx Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: $ RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11251.0 11515.0 ROP 11280.5 11515.0 LOG HEADER DATA DATE LOGGED: 27-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11515.0 TOP LOG INTERVAL (FT): 11280.0 BOTTOM LOG INTERVAL (FT): 11515.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 29.3 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 62.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 19500 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 137.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 19 ~ ~ 15-36b.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11251 11515 11383 529 11251 11515 GR MWD070 API 21.36 283.89 57.6976 529 11251 11515 ROP MWD070 FT/H 1.01 171.4 33.4637 470 11280.5 11515 First Reading For Entire File..........11251 Last Reading For Entire File...........11515 File Trailer service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........5T5LIB.009 Physical EOF File Header Service name... .......STSLIB.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY Page 20 15-36b.tapx VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 10970.0 11515.0 FET 10970.0 11515.0 RPS 10970.0 11515.0 RPM 10970.0 11515.0 RPX 10970.0 11515.0 LOG HEADER DATA DATE LOGGED: 30-7uL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11515.0 TOP LOG INTERVAL (FT): 10971.0 BOTTOM LOG INTERVAL (FT): 11515.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 8,6 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .090 70.0 MUD AT MAX CIRCULATING TERM PERATURE: .050 132.3 MUD FILTRATE AT MT: .140 70.0 MUD CAKE AT MT: .080 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing .....................60 .lIN Page 21 15-36b.tapx Max frames per record .............undefined Absent value ... ...................-999 Depth Units. .. .. ..... Datum specifica tion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10970 11515 11242.5 1091 10970 11515 RPD MWD090 OHMM 0.16 2000 121.161 1091 10970 11515 RPM MWD090 OHMM 2.31 2000 204.363 1091 10970 11515 RPS MWD090 OHMM 0.25 2000 74.3879 1091 10970 11515 RPX MWD090 OHMM 0.14 2000 30.8952 1091 10970 11515 FET MWD090 HOUR 78.09 460.71 114.613 1068 10970 11515 First Reading For Entire File..........10970 Last Reading For Entire File...........11515 File Trailer Service name... .......STSLIB.009 Service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.010 Physical EOF File Header Service name... .......STSLIB.O10 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 11515.5 11754.0 GR 11515.5 11725.0 Page 22 • i 15-36b.tapx LOG HEADER DATA DATE LOGGED: O1-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11754.0 TOP LOG INTERVAL (FT): 11515.0 BOTTOM LOG INTERVAL (FT): 11754.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 54.6 MAXIMUM ANGLE: 85.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): $,$ RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 129.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 23 • 15-36b.tapx GR MWD110 API 4 1 68 4 2 ROP MWD110 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11515.5 11754 11634.8 478 11515.5 11754 GR MWD110 API 19.15 99.65 35.0405 420 11515.5 11725 ROP MWD110 FT/H 0.18 176.44 77.2906 478 11515.5 11754 First Reading For Entire File..........11515.5 Last Reading For Entire File.... ........11754 File Trailer service name... .......sTSLI6.010 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.011 Physical EOF File Header service name... .......sTSLI6.011 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 11515.5 12245.5 RPx 11515.5 12245.5 RPS 11515.5 12245.5 RPM 11515.5 12245.5 FET 11515.5 12245.5 GR 11725.5 12231.0 ROP 11754.5 12276.0 LOG HEADER DATA DATE LOGGED: 02-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 24 • • 15-36b.tapx TD DRILLER (FT): 12276.0 TOP LOG INTERVAL (FT): 11754.0 BOTTOM LOG INTERVAL (FT): 12276.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .100 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 133.0 MUD FILTRATE AT MT: .150 65.0 MUD CAKE AT MT: .120 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 GR MWD120 API 4 1 68 20 6 ROP MwD120 FT/H 4 1 68 24 7 FET MWD120 HOUR 4 1 68 28 8 Page 25 LJ 15-36b.tapx • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11515.5 12276 11895.8 1522 11515.5 12276 RPD MWD120 OHMM 21 2000 162.658 1461 11515.5 12245.5 RPM MWD120 OHMM 12.97 2000 226.864 1461 11515.5 12245.5 RPS MWD120 OHMM 9.79 2000 148.535 1461 11515.5 12245.5 RPX MWD120 OHMM 7.37 2000 99.5 1461 11515.5 12245.5 GR MWD120 API 25.85 159.18 52.2173 1012 11725.5 12231 ROP MWD120 FT/H 0.83 374.21 90.8075 1044 11754.5 12276 FET MWD120 HOUR 0.23 145.34 4.41405 1461 11515.5 12245.5 First Reading For Entire File..........11515.5 Last Reading For Entire File...........12276 File Trailer Service name... .......sTSLI6.011 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.012 Physical EOF File Header Service name... .......STSLIB.012 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12231.5 13242.5 RPS 12246.0 13254.5 RPD 12246.0 13254.5 FET 12246.0 13254.5 RPM 12246.0 13254.5 RPx 12246.0 13254.5 ROP 12276.5 13285.0 LOG HEADER DATA DATE LOGGED: SOFTWARE Page 26 header data for each bit run in separate files. 13 .5000 04-AUG-06 • 15-36b.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13285.0 TOP LOG INTERVAL (FT): 12276.0 BOTTOM LOG INTERVAL (FT): 13285.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3): 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .070 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .030 147.0 MUD FILTRATE AT MT: .150 68.0 MUD CAKE AT MT: .090 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth units .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 Page 27 • 15-36b.tapx GR MWD130 API 4 1 68 20 6 ROP MWD130 FT/H 4 1 68 24 7 FET MWD130 HOUR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 12231.5 13285 12758.3 2108 12231.5 13285 RPD MWD130 OHMM 70.27 120.95 91.335 2018 12246 13254.5 RPM MWD130 OHMM 61.98 146.66 100.596 2018 12246 13254.5 RPS MWD130 OHMM 55.02 147.16 92.0564 2018 12246 13254.5 RPX MWD130 OHMM 45.35 163.99 81.9792 2018 12246 13254.5 GR MWD130 API 40.27 85.73 59.6081 2023 12231.5 13242.5 ROP MWD130 FT/H 0.1 343.26 92.1424 2018 12276.5 13285 FET MWD130 HOUR 0.22 12.16 1.36412 2018 12246 13254.5 First Reading For Entire File..........12231.5 Last Reading For Entire File...........13285 File Trailer Service name... .......STSLIB.012 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.013 Physical EOF File Header Service name... .......STSLI6.013 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MAD curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 13 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10971.0 13231.0 RPD 10990.0 13245.0 RPM 10990.0 13245.0 RPS 10990.0 13245.0 RPx 10990.0 13245.0 RAT 10990.0 13282.0 FET 11001.0 13245.0 Page 28 • 15-36b.tapx LOG HEADER DATA DATE LOGGED: 04-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13285.0 TOP LOG INTERVAL (FT): 10971.0 BOTTOM LOG INTERVAL (FT): 13285.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3): 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .070 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .030 147.0 MUD FILTRATE AT MT: .150 68.0 MUD CAKE AT MT: .090 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. undefined Frame spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 29 • 15-36b.tapx RPD MAD131 OHMM 4 1 68 4 2 RPM MAD131 OHMM 4 1 68 8 3 RPS MAD131 OHMM 4 1 68 12 4 RPX MAD131 OHMM 4 1 68 16 5 FET MAD131 HOUR 4 1 68 20 6 GR MAD131 API 4 1 68 24 7 RAT MAD131 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10971 13282 12126.5 4623 10971 13282 RPD MAD131 OHMM 3.56 2000 101.856 4511 10990 13245 RPM MAD131 OHMM 1.87 2000 104.477 4511 10990 13245 RPS MAD131 OHMM 1.39 2000 77.1512 4511 10990 13245 RPX MAD131 OHMM 1.36 2000 52.1501 4511 10990 13245 FET MAD131 HOUR 0.6 277.22 82.5176 4489 11001 13245 GR MAD131 API 15.49 324.7 54.7656 4521 10971 13231 RAT MAD131 FT/H 470 3528 978.149 4585 10990 13282 First Reading For Entire File..........10971 Last Reading For Entire File...........13282 File Trailer Service name... .......STSLI6.013 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.014 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/04 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/04/04 Ori yin ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF writing Library writing Library. Page 30 scientific Technical Services Scientific Technical services i • 15-36b.tapx Physical EOF End Of LIS File Page 31 i 15-36bpbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 04 11:28:31 2008 Reel Header Service name .............LISTPE Date . ...................08/04/04 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comment5 .................STS LIS Writing Library. scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/04/04 0rigin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical Services Physical EOF comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: 15-366pb1 API NUMBER: 500292248071 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 04-APR-08 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: Mw0004521685 Mw0004521685 Mw0004521685 LOGGING ENGINEER: N. WHITE N. WHITE B. JAHN OPERATOR WITNESS: C. CLEMENS C. CLEMENS R. BORDES / MWD RUN 5 MWD RUN 6 MWD RUN 7 JOB NUMBER: Mw0004521685 Mw0004521685 Mw0004521685 LOGGING ENGINEER: B. JAHN B. JAHN S. LATZ OPERATOR WITNESS: R. BORDES / R. BORDES R. BORDES / SURFACE LOCATION SECTION: 22 TOWNSHIP: 11N RANGE: 14E FNL: 1440 FSL: FEL: FwL: 887 Page 1 c~~`~~J ~I~j~ `~ • 15-36bpbl.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: 64.60 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.500 7.625 10097.0 2ND STRING 4.125 4.500 10988.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. 15-366 PBl WAS DRILLED FROM A WHIPSTOCK POSITIONED IN THE 15-36 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 10097'MD/7445'TVD55. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THESE RUNS WERE DRILLED BY NABORS 27E. NO PROGRESS WAS MADE ON MWD RUN 1 DUE TO A TOOL MALFUNCTION. THE WHIPSTOCK WAS SET, THE WINDOW MILLED, AND A BIT OF RAT HOLE DRILLED ON MWD RUN 2. 5. MWD RUNS 4-7 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. THESE RUNS (AND ALL SUBSEQUENT RUNS) WERE DRILLED BY NORDIC 1. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN IN 15-366 ON 8/5/2006. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 1/31/2008. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-7 REPRESENT WELL 15-366 PB1 WITH API#: 50-029-22480-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11998'MD/8752'TVD55. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY COMBINED. File Header Service name... .......STSLIB.001 Service SUb Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Page 2 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP 1 15-36bpbl.tapx 000 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH 9813.0 11970.0 10090.5 12000.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9847.5 9844.0 9860.0 9856.5 9874.5 9871.5 9900.5 9898.5 9924.5 9923.5 9936.0 9934.0 9945.5 9944.5 9969.5 9969.0 9988.5 9986.5 10031.5 10029.0 10083.5 10090.0 10087.5 10094.0 10095.0 10102.5 10109.0 10115.0 10121.0 10126.5 10128.5 10134.5 10135.5 10140.5 10139.5 10146.0 10172.5 10176.5 10279.0 10284.5 10287.5 10292.0 10292.5 10298.0 10339.5 10343.5 10342.5 10345.5 10344.0 10347.0 10360.0 10362.5 10362.5 10365.0 10373.5 10376.0 10375.5 10378.0 10404.0 10406.5 10406.0 10409.0 10408.0 10411.0 10417.5 10421.0 10425.5 10427.5 10432.5 10434.5 10447.5 10449.5 10455.5 10457.0 10457.5 10459.5 10478.5 10481.5 10500.5 10503.0 10513.0 10514.5 10522.5 10524.5 Page 3 15-36bpbl.tapx 10524.5 10527.0 10537.0 10539.5 10544.0 10545.5 10549.0 10550.5 10552.0 10553.5 10562.0 10564.5 10565.5 10567.5 10571.0 10572.5 10583.0 10585.0 10588.5 10591.0 10593.5 10595.5 10595.5 10597.5 10598.0 10600.0 10611.5 10611.5 10618.0 10619.5 10624.5 10625.0 10631.5 10632.0 10645.5 10646.5 10660.5 10661.0 10664.0 10665.0 10668.0 10669.0 10670.5 10671.5 10674.0 10675.0 10675.5 10676.5 10682.5 10684.0 10684.5 10685.5 10686.5 10688.5 10700.0 10700.0 10705.0 10705.5 10715.5 10717.0 10719.5 10720.0 10729.0 10729.5 10761.0 10761.0 10771.5 10771.5 10785.5 10785.5 10787.0 10787.0 10790.5 10791.5 10796.5 10797.0 10808.5 10810.0 10819.5 10820.0 10836.5 10836.5 10852.0 10851.0 10858.5 10858.0 10905.0 10905.0 10944.5 10946.5 10971.0 10970.0 10974.5 10973.5 10980.5 10979.5 11001.5 11000.5 11015.0 11013.5 11017.0 11015.5 11023.0 11022.5 11038.5 11037.5 11041.0 11040.0 11042.5 11041.5 11047.0 11047.5 11054.5 11053.5 11059.0 11057.5 11065.5 11063.0 11067.5 11065.5 11075.5 11075.0 11079.0 11078.5 11085.5 11085.5 Page 4 w 11089.5 11101.5 11106.5 11118.0 11127.0 11129.0 11132.0 11147.0 11150.5 11156.5 11161.0 11165.0 11170.0 11172.0 11176.5 11178.0 11184.0 11189.5 11199.5 11202.5 11214.0 11220.5 11224.5 11229.0 11233.0 11238.0 11265.0 11365.0 11371.0 11414.0 11428.5 11431.5 11433.5 11443.0 11452.5 11454.0 11459.5 11463.0 11484.5 11487.5 11494.0 11501.0 11508.0 11511.0 11513.5 11516.0 12000.0 11089.0 11101.0 11106.5 11116.5 11126.5 11128.0 11130.0 11146.0 11149.5 11156.5 11159.5 11164.0 11169.5 11171.0 11176.0 11177.0 11182.5 11189.0 11198.5 11202.5 11213.5 11220.0 11224.0 11228.5 11232.5 11237.5 11263.0 11362.5 11369.0 11412.0 11427.0 11429.5 11431.5 11441.5 11450.0 11453.0 11458.5 11463.0 11484.0 11486.0 11492.0 11500.0 11507.0 11509.5 11512.5 11514.5 11998.5 15-36bpbl.tapx MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 9809.5 10124.0 MwD 3 10124.0 10988.5 MwD 4 10988.5 11101.0 MwD 5 11101.0 11269.0 MwD 6 11269.0 11280.0 MWD 7 11280.0 11998.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Page 5 15-36bpbl.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9813 12000 10906.5 4375 9813 12000 GR MWD API 20.83 755.57 117.279 4315 9813 11970 ROP MWD FT/H 0.03 788.43 72.6372 3820 10090.5 12000 First Reading For Entire File..........9813 Last Reading For Entire File...........12000 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9809.5 10072.5 ROP 10097.5 10124.0 Page 6 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 GM Duai GR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 15-36bpbl.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 O8-~uL-06 Insite 4.3 Memory 10124.0 9809.0 10124.0 .0 .0 TOOL NUMBER 93091 6.500 10097.0 Fresh water Gel 9.90 52.0 8.9 800 3.9 .000 .0 .000 109.6 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 7 ~ ~ 15-36bpbl.tapx GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9809.5 10124 9966.75 630 9809.5 10124 GR MWD020 API 38.38 158.5 87.568 527 9809.5 10072.5 ROP MWD020 FT/H 0.68 10.24 5.55778 54 10097.5 10124 First Reading For Entire File... .......9809.5 Last Reading For Entire File.... .......10124 File Trailer Service name... .......STSLIB.002 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10073.0 10946.0 $OP 10124.5 10988.5 LOG HEADER DATA DATE LOGGED: 10-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10988.0 TOP LOG INTERVAL (FT): 10124.0 BOTTOM LOG INTERVAL (FT): 10988.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 8 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 15-36bpbl.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MuD vlscoslTY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 21.7 44.5 TOOL NUMBER 78012 .6.500 10097.0 Fresh water Gel 9.90 47.0 8.9 900 4.0 .000 .0 .000 109.0 .000 .0 .000 .0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 GR MwD030 API 4 1 68 4 2 RoP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10073 10988.5 10530.8 1832 10073 10988.5 GR MWD030 API 49.59 448.21 173.678 1747 10073 10946 ROP MWD030 FT/H 0.23 377.06 91.8584 1729 10124.5 10988.5 First Reading For Entire File..........10073 Page 9 15-36bpbl.tapx Last Reading For Entire File...........10988.5 File Trailer service name... .......sTSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH GR 10946.5 ROP 10989.0 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 VENDOR TOOL CODE PCG STOP DEPTH 11071.0 11101.0 BOTTOM) TOOL TYPE Natural gamma ray BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 24-JUL-06 Insite 7.75 Memory 11101.0 10988.0 11101.0 21.7 27.3 TOOL NUMBER TLG015 4.125 10988.0 Page 10 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 15-36bpbl.tapx MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 35.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 6.2 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 .000 .0 .000 120.6 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD040 API 4 1 68 4 2 ROP MwD040 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10946.5 11101 11023.8 310 10946.5 11101 GR MWD040 API 47.5 538.99 141.302 250 10946.5 11071 ROP MWD040 FT/H 0.08 747.67 48.6664 225 10989 11101 First Reading For Entire File..........10946.5 Last Reading For Entire File...........11101 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Page 11 • 15-36bpbl.tapx Physical EOF File Header Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11071.5 11239.5 ROP 11101.5 11269.0 LOG HEADER DATA DATE LOGGED: 25-7UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11269.0 TOP LOG INTERVAL (FT): 11101.0 BOTTOM LOG INTERVAL (FT): 11269.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.0 MAXIMUM ANGLE: 27.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL Polymer 8.60 39.0 9.1 21000 6.1 .000 .0 .000 124.8 .000 .0 .000 .0 Page 12 • MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): • 15-36bpbl.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 ~ogginy Direction .................DOwn optical log depth units.........,.Feet Data Reference Point ..............undefined Frame Spacing....... ..........,.60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ...,. Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD050 API 4 1 68 4 2 ROP MWD050 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11071.5 11269 11170.3 396 11071.5 11269 GR MWD050 API 20.83 755.57 59.556 337 11071.5 11239.5 ROP MWD050 FT/H 0.51 172.14 49.6838 336 11101.5 11269 First Reading For Entire File..........11071.5 Last Reading For Entire File...........11269 File Trailer Service name... ......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record Page 13 15-36bpbl.tapx FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11240.0 11250.5 RoP 11269.5 11280.0 LOG HEADER DATA DATE LOGGED: 26-]UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11280.0 TOP LOG INTERVAL (FT): 11269.0 BOTTOM LOG INTERVAL (FT): 11280.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.1 MAXIMUM ANGLE: 27.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 62800.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 124.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Page 14 • 15-36bpbl.tapx Loggin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading. DEPT FT 11240 11280 11260 81 11240 11280 GR MWD060 API 22.26 26.77 24.2736 22 11240 11250.5 ROP MWD060 FT/H 0.24 230.14 33.4734 22 11269.5 11280 First Reading For Entire File..........11240 Last Reading For Entire File...........11280 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File TyC~e ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11251.0 11968.5 ROP 11280.5 11998.5 Page 15 • • 15-36bpbl.tapx LOG HEADER DATA DATE LOGGED: 27-]UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11998.0 TOP LOG INTERVAL (FT): 11280.0 BOTTOM LOG INTERVAL (FT): 11998.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 29.3 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 62400.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 19500 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: 137.000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ......... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 Page 16 LJ 15-36bpbl.tapx ~~ LJ First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11251 11998.5 11624.8 1496 11251 11998.5 GR MWD070 API 20.85 283.89 69.6629 1436 11251 11968.5 ROP MWD070 FT/H 0.03 788.43 62.0339 1437 11280.5 11998.5 First Reading For Entire File..........11251 Last Reading For Entire File...........11998.5 File Trailer Service name... .......STSLI6.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/04 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/04/04 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical services Page 17 15-36bpb2.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Apr 04 13:33:52 2008 Reel Header Service name .............LISTPE Date . ...................08/04/04 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/04/04 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: 15-36Bpb2 API NUMBER: 500292248072 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 04-APR-08 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: Mw0004521685 Mw0004521685 Mw0004521685 LOGGING ENGINEER: N. WHITE N. WHITE B. JAHN OPERATOR WITNESS: C. CLEMENS C. CLEMENS R. BORDES / MWD RUN 5 MWD RUN 6 MWD RUN 7 Job NUMBER: Mw0004521685 Mw0004521685 Mw0004521685 LOGGING ENGINEER: B. JAHN B. JAHN S. LATZ OPERATOR WITNESS: R. BORDES / R. BORDES / R. BORDES / MWD RUN 8 MWD RUN 9 MWD RUN 10 JOB NUMBER: MW0004521685 Mw0004521685 Mw0004521685 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: R. BORDES / R. BORDES/J. R. BORDES/J. SURFACE LOCATION SECTION: 22 Page 1 ~ -0~-3 #16696 15-36bpb2.tapx TOWNSHIP: 11N RANGE: 14E FNL: 1440 FSL: FEL: FWL: 887 ELEVATION (FT FROM MSL O) KELLY BUSHING: 64.60 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.500 7.625 10097.0 2ND STRING 4.125 4.500 10988.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. 15-366 PB2 WAS DRILLED FROM AN ALUMINUM BILLET (WHIPSTOCK) POSITIONED IN THE 15-366 PBl WELLBORE. THE TOP OF THE BILLET WAS AT 11540'MD/8661'TVDSS. THIS OPEN-HOLE SIDETRACK WAS EFFECTED ON MWD RUN 8. 4. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THESE RUNS WERE DRILLED BY NABORS 27E. NO PROGRESS WAS MADE ON MWD RUN 1 DUE TO A TOOL MALFUNCTION. THE WHIPSTOCK WAS SET, THE WINDOW MILLED, AND A BIT OF RAT HOLE DRILLED ON MWD RUN 2. 5. MWD RUNS 4-8 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. RUNS 9,10 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). UPHOLE EWR4 MAD DATA ACQUIRED WHILE RIH FOR MWD RUN 9 WERE MERGED WITH MWD RUN 9 DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN IN 15-366 ON 8/5/2006. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 1/31/2008. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1-10 REPRESENT WELL 15-366 PB2 WITH API#: 50-029-22480-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF Page 2 15-36bpb2.tapx 12232'MD/8730'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED, SGRD = SMOOTHED NATURAL GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......ST5LI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9813.0 12188.5 ROP 10090.5 12234.0 FET 10971.0 12203.0 RPx 10971.0 12203.0 RPS 10971.0 12203.0 RPM 10971.0 12203.0 RPD 10971.0 12203.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9847.5 9844.0 9860.0 9856.5 9874.5 9871.5 9900.5 9898.5 9924.5 9923.5 9936.0 9934.0 9945.5 9944.5 9969.5 9969.0 9988.5 9986.5 10031.5 10029.0 10083.5 10090.0 10087.5 10094.0 10095.0 10102.5 10109.0 10115.0 10121.0 10126.5 10128.5 10134.5 Page 3 15-36bpb2.tapx 10135.5 10140.5 10139.5 10146.0 10172.5 10176.5 10279.0 10284.5 10287.5 10292.0 10292.5 10298.0 10339.5 10343.5 10342.5 10345.5 10344.0 10347.0 10360.0 10362.5 10362.5 10365.0 10373.5 10376.0 10375.5 10378.0 10404.0 10406.5 10406.0 10409.0 10408.0 10411.0 10417.5 10421.0 10425.5 10427.5 10432.5 10434.5 10447.5 10449.5 10455.5 10457.0 10457.5 10459.5 10478.5 10481.5 10500.5 10503.0 10513.0 10514.5 10522.5 10524.5 10524.5 10527.0 10537.0 10539.5 10544.0 10545.5 10549.0 10550.5 10552.0 10553.5 10562.0 10564.5 10565.5 10567.5 10571.0 10572.5 10583.0 10585.0 10588.5 10591.0 10593.5 10595.5 10595.5 10597.5 10598.0 10600.0 10611.5 10611.5 10618.0 10619.5 10624.5 10625.0 10631.5 10632.0 10645.5 10646.5 10660.5 10661.0 10664.0 10665.0 10668.0 10669.0 10670.5 10671.5 10674.0 10675.0 10675.5 10676.5 10682.5 10684.0 10684.5 10685.5 10686.5 10688.5 10700.0 10700.0 10705.0 10705.5 10715.5 10717.0 10719.5 10720.0 10729.0 10729.5 10761.0 10761.0 10771.5 10771.5 10785.5 10785.5 10787.0 10787.0 10790.5 10791.5 Page 4 15-36bpb2.tapx 10796.5 10797.0 10808.5 10810.0 10819.5 10820.0 10836.5 10836.5 10852.0 10851.0 10858.5 10858.0 10905.0 10905.0 10944.5 10946.5 10971.0 10970.0 10974.5 10973.5 10980.5 10979.5 11001.5 11000.5 11015.0 11013.5 11017.0 11015.5 11023.0 11022.5 11038.5 11037.5 11041.0 11040.0 11042.5 11041.5 11047.0 11047.5 11054.5 11053.5 11059.0 11057.5 11065.5 11063.0 11067.5 11065.5 11075.5 11075.0 11079.0 11078.5 11085.5 11085.5 11089.5 11089.0 11101.5 11101.0 11106.5 11106.5 11118.0 11116.5 11127.0 11126.5 11129.0 11128.0 11132.0 11130.0 11147.0 11146.0 11150.5 11149.5 11156.5 11156.5 11161.0 11159.5 11165.0 11164.0 11170.0 11169.5 11172.0 11171.0 11176.5 11176.0 11178.0 11177.0 11184.0 11182.5 11189.5 11189.0 11199.5 11198.5 11202.5 11202.5 11214.0 11213.5 11220.5 11220.0 11224.5 11224.0 11229.0 11228.5 11233.0 11232.5 11238.0 11237.5 11265.0 11263.0 11365.0 11362.5 11371.0 11369.0 11414.0 11412.0 11428.5 11427.0 11431.5 11429.5 11433.5 11431.5 11443.0 11441.5 11452.5 11450.0 11454.0 11453.0 11459.5 11458.5 Page 5 • 11463.0 11484.5 11487.5 11494.0 11501.0 11508.0 11511.0 11513.5 11516.0 12234.0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD REMARKS: 15-36bpb2.tapx 11463.0 11484.0 11486.0 11492.0 11500.0 11507.0 11509.5 11512.5 11514.5 12232.5 BIT RUN NO MERGE TOP MERGE BASE 2 9809.5 10124.0 3 10124.0 10988.5 4 10988.5 11101.0 5 11101.0 11269.0 6 11269.0 11280.0 7 11280.0 11540.0 8 11540.5 11804.5 9 11804.5 11842.0 10 11842.0 12232.5 MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9813 12234 11023.5 4843 9813 12234 RPD MWD OHMM 0.16 2000 92.9247 2465 10971 12203 RPM MWD OHMM 2.31 2000 133.626 2465 10971 12203 RPS MWD OHMM 0.25 2000 68.646 2465 10971 12203 RPX MWD OHMM 0.14 2000 39.976 2465 10971 12203 FET MWD HOUR 0.35 460.71 57.8362 2465 10971 12203 GR MWD API 20.44 755.57 113.53 4752 9813 12188.5 ROP MWD FT/H 0.04 747.67 64.8223 4288 10090.5 12234 Page 6 ~ ~ 15-36bpb2.tapx First Reading For Entire File..........9813 Last Reading For Entire File...........12234 File Trailer service name... .......sTSL26.001 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Ty e ................LO N2xt Fl~e Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9809.5 10072.5 OP 10097.5 10124.0 $ LOG HEADER DATA DATE LOGGED: O8-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10124.0 TOP LOG INTERVAL (FT): 9809.0 BOTTOM LOG INTERVAL (FT): 10124.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 93091 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.500 DRILLER'S CASING DEPTH (FT): 10097.0 Page 7 i ~ 15-36bpb2.tapx BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (S): 52.0 MUD PH: $.g MUD CHLORIDES (PPM): 800 FLUID LOSS (C3): 3.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 109.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 LOg~ing Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9809.5 10124 9966.75 630 9809.5 10124 GR MWD020 API 38.38 158.5 $7.568 527 9809.5 10072.5 ROP MWD020 FT/H 0.68 10.24 5.55778 54 10097.5 10124 First Reading For Entire File..........9809.5 Last Reading For Entire File...........10124 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Page 8 ~ ~ 15-36bpb2.tapx Physical EOF File Header Service name... .......sTSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10073.0 10946.0 ROP 10124.5 10988.5 LOG HEADER DATA DATE LOGGED: 10-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10988.0 TOP LOG INTERVAL (FT): 10124.0 BOTTOM LOG INTERVAL (FT): 10988.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.7 MAXIMUM ANGLE: 44.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78012 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.500 DRILLER'S CASING DEPTH (FT): 10097.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.90 MUD VISCOSITY (5): 47.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 109.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O Page 9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 15-36bpb2.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loginy Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10073 10988.5 10530.8 1832 10073 10988.5 GR MWD030 API 49.59 448.21 173.678 1747 10073 10946 ROP MWD030 FT/H 0.23 377.06 91.8584 1729 10124.5 10988.5 First Reading For Entire File..........10073 Last Reading For Entire File...........10988.5 File Trailer Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... ... ...STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Page 10 ~ ~ 15-36bpb2.tapx Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10946.5 11071.0 ROP 10989.0 11101.0 LOG HEADER DATA DATE LOGGED: 24-1UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11101.0 TOP LOG INTERVAL (FT): 10988.0 BOTTOM LOG INTERVAL (FT): 11101.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.7 MAXIMUM ANGLE: 27.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 35.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 120.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Page it ~ ~ 15-36bpb2.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10946.5 11101 11023.8 310 10946.5 11101 GR MWD040 API 47.5 538.99 141.302 250 10946.5 11071 ROP MWD040 FT/H 0.08 747.67 48.6664 225 10989 11101 First Reading For Entire File..........10946.5 Last Reading For Entire File...........11101 File Trailer Service name... .......STSL2B.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 5 .5000 VENDOR TOOL CODE START DEPTH GR 11071.5 ROP 11101.5 STOP DEPTH 11239.5 11269.0 Page 12 • ~ 15-36bpb2.tapx LOG HEADER DATA DATE LOGGED: 25-7UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11269.0 TOP LOG INTERVAL (FT): 11101.0 BOTTOM LOG INTERVAL (FT): 11269.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.0 MAXIMUM ANGLE: 27.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 39.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 6.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 124.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 13 • • 15-36bpb2.tapx GR MWD050 API 4 1 68 4 2 ROP MWD050 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11071.5 11269 11170.3 396 11071.5 11269 GR MWD050 API 20.83 755.57 59.556 337 11071.5 11239.5 ROP MWD050 FT/H 0.51 172.14 49.6838 336 11101.5 11269 First Reading For Entire File..........11071.5 Last Reading For Entire File...........11269 File Trailer Service name... .......ST5LI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSL26.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO PreviOUS File Name.......STSLIB.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11240.0 11250.5 ROP 11269.5 11280.0 LOG HEADER DATA DATE LOGGED: 26-7UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11280.0 TOP LOG INTERVAL (FT): 11269.0 BOTTOM LOG INTERVAL (FT): 11280.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 14 • • 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): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 15-36bpb2.tapx 27.1 27.1 TOOL NUMBER TLG015 4.125 10988.0 Polymer 8.60 63.0 9.0 21000 7.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 .000 .0 .000 124.8 .000 .0 .000 .0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11240 11280 11260 81 11240 11280 GR MWD060 API 22.26 26.77 24.2736 22 11240 11250.5 ROP MWD060 FT/H 0.24 230.14 33.4734 22 11269.5 11280 First Reading For Entire File..........11240 Page 15 • • 15-36bpb2.tapx Last Reading For Entire File...........11280 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......sTSLI6,007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11251.0 11540.0 ROP 11280.5 11540.0 LOG HEADER DATA DATE LOGGED: 27-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11540.0 TOP LOG INTERVAL (FT): 11280.0 BOTTOM LOG INTERVAL (FT): 11540.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 29.3 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS Page 16 • • 15-36bpb2.tapx MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 62.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 19500 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: 137.000 .O MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data Specification Block Type .....0 Logyin Direction ............ .....Down optical log depth units...... .....Feet Data Reference Point ......... .....undefine d Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefine d Absent value ................. .....-999 Depth units. .. .. ..... Datum specification Block sub -type...0 Name service order units size N sam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MwD070 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11251 11540 11395.5 579 11251 11540 GR MWD070 API 20.85 283.89 54.9795 579 11251 11540 ROP MWD070 FT/H 1.01 171.4 34.9903 520 11280.5 11540 First Reading For Entire File..........11251 Last Reading For Entire File...........11540 File Trailer Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Page 17 15-36bpb2.tapx Physical EOF File Header Service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 11540.5 11804.5 GR 11540.5 11774.5 LOG HEADER DATA DATE LOGGED: 29-]UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11805.0 TOP LOG INTERVAL (FT): 11540.0 BOTTOM LOG INTERVAL (FT): 11805.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 55.9 MAXIMUM ANGLE: 82.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.2 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATUR E (DEGF) MUD AT MEASURED TEMPERATURE ( MT): .000 .O MUD AT MAX CIRCULATING TERMPE RATURE: .000 133.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL Page 18 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 15-36bpb2.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD080 API 4 1 68 4 2 ROP MWD080 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11540.5 11804.5 11672.5 529 11540.5 11804.5 GR MWD080 API 20.44 169.92 53.5118 469 11540.5 11774.5 ROP MWD080 FT/H 0.04 95.18 53.9535 529 11540.5 11804.5 First Reading For Entire File..........11540.5 Last Reading For Entire File...........11804.5 File Trailer Service name... .......STSLI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type. ...........,LO Previous File Name.......ST5LI6.008 Comment Record Page 19 15-36bpb2.tapx FILE HEADER FILE NUMBER: 9 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10970.0 11812.0 RPx 10970.0 11812.0 RPS 10970.0 11812.0 RPM 10970.0 11812.0 RPD 10970.0 11812.0 GR 11775.0 11797.5 ROP 11805.0 11842.0 LOG HEADER DATA DATE LOGGED: 30-7UL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11842.0 TOP LOG INTERVAL (FT): 11805.0 BOTTOM LOG INTERVAL (FT): 11842.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 218615 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .090 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 132.3 MUD FILTRATE AT MT: .140 70.0 MUD CAKE AT MT: .080 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 20 15-36bpb2.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logyin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order .units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MwD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10970 11842 11406 1745 10970 11842 RPD MWD090 OHMM 0.16 2000 115.548 1685 10970 11812 RPM MWD090 OHMM 2.31 2000 171.943 1685 10970 11812 RPS MWD090 OHMM 0.25 2000 79.3478 1685 10970 11812 RPX MWD090 OHMM 0.14 2000 39.3958 1685 10970 11812 FET MWD090 HOUR 1.74 460.71 83.5424 1685 10970 11812 GR MWD090 API 92.6 128.26 109.491 46 11775 11797.5 ROP MWD090 FT/H 3.35 140.12 28.4872 75 11805 11842 First Reading For Entire File..........10970 Last Reading For Entire File...........11842 File Trailer Service name... .......STSLIB.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.010 Physical EOF File Header service name... .......STSLIB.O10 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Page 21 • • 15-36bpb2.tapx Previous File Name.......STSLI6.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11798.0 FET 11812.5 RPD 11812.5 RPM 11812.5 RPS 11812.5 RPX 11812.5 ROP 11842.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12187.0 12201.5 12201.5 12201.5 12201.5 12201.5 12232.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR EWR4 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 (DEG F) 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): header data for each bit run in separate files. 10 .5000 10 31-JUL-06 Insite 4.3 Memory 12232.0 11842.0 12232.0 88.6 95.0 TOOL NUMBER 82758 218615 4.125 10988.0 Polymer 8.60 65.0 8.2 28000 5.8 .090 70.0 .050 135.0 .140 70.0 .080 70.0 Page 22 • • 15-36bpb2.tapx TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11798 12232.5 12015.3 870 11798 12232.5 RPD MWD100 OHMM 9.17 1176.79 43.7782 779 11812.5 12201.5 RPM MWD100 OHMM 7.19 957.99 50.1899 779 11812.5 12201.5 RPS MWD100 OHMM 7.05 148.94 45.2073 779 11812.5 12201.5 RPX MWD100 OHMM 7.04 139.13 41.1248 779 11812.5 12201.5 FET MWD100 HOUR 0.35 10.2 2.15012 779 11812.5 12201.5 GR MWD100 API 49.29 132.23 91.792 779 11798 12187 ROP MWD100 FT/H 0.51 134.06 52.1815 781 11842.5 12232.5 First Reading For Entire File..........11798 Last Reading For Entire File...........12232.5 File Trailer Service name... .......STSLIB.O10 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/04 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.011 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/04 Origin ...................STS Page 23 15-36bpb2.tapx Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer service name .............LISTPE Date . ...................08/04/04 Ori9in ...................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 Page 24
