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208-078
• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - Q ~ S Well History File Identifier Two-sided III IIIIIIII III II III Rescan Needed III II'III II II III III Orgamzmg (done) ^ ^ RES AN DIGITAL DATA Color Items: ^ Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria Date: , Project Proofing BY: /s/ r Scannin Pre aration ~ x 30 = d + ~ =TOTAL PAGES v g p -""ter" (Count does not include covers et) BY: _ Maria Date: ~/ ~ ~s~ Production Scanning Stage 1 Page Count from Scanned File: _~, (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: ~I ` Q / Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. v u~ p "IIIIIIIIIIIINIIIII Rescanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III II'III III II'I III OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: O/ /D ~s~ Date: ~,//© 10/6/2005 WeII History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/10/2010 Permit to Drill 2080780 Well Name/No. PRUDHOE BAY UNIT 13-306 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20768-02-00 MD 11703 TVD 9000 Completion Date 7/18/2008 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATAINFORMATDN Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments j Rpt LIS Verification 9462 11703 Open 10/10/2008 LIS Veri, GR, ROP, RAD, ~ RAS, RPD, RPS I D C Lis 17008/Induction/Resistivity 9462 11703 Open 10/10/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS g Gamma Ray 5 Col 9490 11670 Open 10/10/2008 Depth Shift Monitor Plot g Gamma Ray 25 Col 9634 11703 Open 10/10/2008 MD GR g Induction/Resistivity 5 Col 9634 11703 Open 10/10/2008 ND MPR, GR 17-Jul-2008 ~g Induction/Resistivity 25 Col 9634 11703 Open 10/10/2008 MD MPR, GR 17-Jul-2008 'Cog Induction/Resistivity 25 Col 9634 11703 Open 10/10/2008 MD MPR, GR 17-Jul-2008 COPY D Asc Directional Survey v' 0 11703 Open 8/12/2008 PBU 13-30C also on Disk Rpt Directional Survey - - 0 11703 Open 8/12/2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/10/2010 Permit to Drill 2080780 Well Name/No. PRUDHOE BAY UNIT 13-306 MD 11703 TVD 9000 ADDITIONAL INFORMATION Well Cored? Y /~~~ Chips Received? X-F-N-'' Analysis Y'TFI - Received? Completion Date 7/18/2008 Operator BP EXPLORATION (ALASKIy INC Completion Status P&A Current Status P&A Daily History Received? ~ N Formation Tops ~/ N API No. 50-029-20768-02-00 UIC N Comments: _ -- -- - Compliance Reviewed By: ____ ~ Date: ~ y ~ , ~ l • ~ ~ ~ a ,s BAKER N~J6ME5 CUMYANY WELL NAME FIELD Baker Atlas PRINT DISTRIBUTION LIST BY EXYLURA'1'IUN (ALASKA) 1NC CUUNl'Y NUK'1'H SLUYE BUKUUUH 13-30B STATE ALASKA PRUDHOE BAY UNIT DATE 10/2/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2081739 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Completed Bv: ~'~%- Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7t" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 13-30B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Lag (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) 1 color print - MadPass MPR/Directional Measured Depth Log (to Follow) LAC Job#: 2081739 ~'~~ ~D Sent by: Catrina Guidry Date: 10/02/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: ~~vi) Zg 7-0023 ;xF BAKER ~ ., ~ FBIGI#S ~ . ,.r.,... ~. ..,.~,~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ ~~ STATE OF ALASKA AU G 2 9 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO~aska Oil ~ Gas Dons. Commission dnrhnTarlP 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os 2onAC2s.>>o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions Zero 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati ra hic 2. Operator Name: BP Ex /oration (Alaska) Inc. 5. Date Comp., Susp., or 7/18/2008 12. Permit to Drill Number 208-078 308-255 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded 7/13/2008 13. API Number 50-029-20788-02-00 4a. Loca6on of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/16/2008 14. Well Name and Number: PBU 13-30B FEL, SEC. 14, T10N, R14E, UM 1990 FSL, 1511 Top of Productive Horizon: N/A 8. KB (ft above MSL): 74.5' Ground (ft MSL): 46.94' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 925' FNL, 5156' FEL, SEC. 23, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 9686' 8935' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 685705 y- 5932020 Zone- ASP4 10. Total Depth (MD+TVD) 11703' 9000' 16. Property Designation: ADL 028315 TPI: x- N/A y_ N/A Zone- N/A th: x- 682134 - 5929017 Zone- ASP4 Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, GR, RES 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOB AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED u " 2854 sx Fondu 400 sx Permafrost 'C' / ~~ L~0 i Soo-ss - P F , ' 7 „ , „ 23. Open to production or inject ion? ^Yes ®No 24. TUBING RECORD If Yes, list each interval open rforation Size and Number): m MD+TVU f T & B tt P SIZE DEPTH SET MD PACKER SET MD ; ( o op o o e N/A MD TVD MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 9840' Set IBP 9686' P&A w/ 6 Bbls Class'G' 9620' SetUVhi stock 9620' Pum 10 Bbls Class'G' (2nd Plu for Kick Off) 26. PRODUCTION TEST Date First Production: Not Completed Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUTS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HouR RATE. OIL-BBL: GAS-MCF: WATER-BaL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Ac wired? ^Yes ®No SideW81 1 Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this forth, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resuks per 20 AAC 250071. CG„'i~ i_ETIi?IV None ~: _~;; Form 10-407 Revised 02/2007 ~~,~~~ CONTINUED ON REVERSE SIDE `C~ F~ SCt ~ 9 ZDDB 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ENCOUNTERED): 29. RMATION TESTS ` NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9593' None Shublik A 9619' Shublik B 9651' Shublik C 9674' Sadlerochit /Zone 46 / 46P 9740' Sadlerochit /Zone 4B / 46P 11640' Formation at Total Depth (Name): Sadlerochit /Zone 46 / 46P 9740' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ¢tip/ `~--CGS ~ ~ ! Title Drilling Technologist Date Signed Terrie Hubble PBU 13-308 208-078 308-255 Prepared ey NameAVumber. Terrie Hubble, 564~f628 Well Number Permit No. l A royal No. oriuing Engineer: Greg Barber, 564-4330 INSrnucnorts GeNewLL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, WaterSupply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top arxi base of permafrost in Box 28. ITEM 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 ors 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 tre separately produced, showing the data pertinent to such interval). ITEM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations,. and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Ony BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date ~ From - To Hours Task Code NPT Phase II Description of Operations 7/17/2008 08:30 - 10:15 1.75 PXA P ABAN Close out 13-30B and continue with 13-30C. Strip off connectror, PU Hydraulic coil cutter, Cut 100' of coil and cable, LD hyd cutter, MU coil connector PT to 35k, 3500 psi. 10:15 - 11:30 1.25 PXA P ABAN MU BHA#1 CoilTrack tools, Hydraulic running tool, and 3" IBP. 11:30 - 13:30 2.00 PXA. P ABAN RI with IBP and open EDC, and circulate at 0.2 bpm 13:30 - 14:30 1.00 PXA P ABAN Park coil, shut down pumps and wait for pressures to equalize. Close EDC to prepare to run in open hole. Log GR Tie-in (-11'), observe 200 psi differential at the DPS and then 3k set down at window. Pull heavy at 42k, and observe the differential go to zero. Assume the I P has_slLar released._ PU and RIH at normal weights so we will go through the set procedure in case the IBP hasn'tshear released. Run through window clean and get on depth at 9840'. Pressure up on tool and observe returns, confirms the IBP has sheared released. Wait 5 mins before coming out of hole. 14:30 - 16:35 2.08 PXA N DPRB ABAN POOH with no weight bobbles. 16:35 - 17:35 1.00 PXA N DPRB ABAN LD IBP and observe that it has shear released.. PU BHA#2 same as above with a fresh 3" IBP. Still not a good explanation for the 200 psi differential on the last run. Possible Flo-Pro holding pressure or aired up mud on the Backside. The EDC will be left open until the IBP is on depth for this run. 17:35 - 20:00 2.42 PXA N DPRB ABAN PU new IBP. RIH to 9630' and tie-in, +6 correction. Flag pipe at 9666'. EOP 9609'. 20:00 - 20:30 0.50 PXA N DPRB ABAN Park coil, Bottom of IBP at 9840', shut down pumps and wait for pressures to equalize. Close EDC. Differential pressure stabilized at 150 psi. Increase CT pressure to 1000psi, dill pressure stabilized at 840psi. Slack off weight. Increase pressure to 1315psi, differential pressure at 1290psi. Slack off weight. Inc to 1875psi, dill is 1790psi. Inc to 2800, dill is 2700psi. Good indication of shearing by dill pressure dump and WOB increase when slacking off. 20:30 - 23:00 2.50 PXA N DPRB ABAN POH. Open EDC due to high circulating pressures. 23:00 - 23:10 0.17 PXA N DPRB ABAN SAFETY MEETING covering procedures, hazards, and mitigations to RD IBP BHA and PU Cementing BHA. 23:10 - 23:30 0.33 PXA N DPRB ARAN RD IBP BHA, smaller screen installed, PT hardline in reel house 23:30 - 00:00 0.50 PXA N DPRB ARAN MU Cementin BHA #3 --- CTC, XO, UQC, LOC, Blind Sub, XO, 32K Shear Sub, XO, 2 jnts PH6, 3" Cement Dump Nozzle with 3/4"jet 7/18/2008 00:00 - 00:30 0.50 PXA N HMAN ABAN Continue MU Cementing BHA 00:30 - 03:15 2.75 PXA N HMAN ABAN Run in hole to IBP with Cementing BHA. Lightly tag IBP with 1.5K, slight movement. PU and taa with oumos off to pnci~ra was not movin h draulic-I moved down to 9 4'. 03:15 - 03:45 0.50 PXA N HMAN ABAN PJSM for procedure, risks and mitigations of cement job 03:45 - 05:00 1.25 PXA N HMAN ABAN PT Hardline to 4000 psi with fresh water Pump 10 bbl 2% KCI Pum 6 bbl 17 Cemen Pump 5 bbl 2% KCL, clean out lines to cementers Pump 2ppb biozan water, circulate at 9600' at 50 bbl away RIH to 9860' 4:45 56.2 bbl away (calculated) wait for .5 bbl then start o-...~...I• °MC/onn° an°•1R PEA BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/18/2008 03:45 - 05:00 1.25 PXA N HMAN ABAN pulling at 05:00 - 05:45 ~ 0.75 ~ PXA ~ N ~ HMAN ABAN 05:45 - 07:35 1.83 PXA N HMAN ABAN 07:35 - 08:00 0.42 PXA N HMAN ABAN 08:00 - 08:50 0.83 PXA N HMAN ABAN 08:50 - 09:45 0.92 PXA N HMAN ABAN 09:45 - 11:50 2.08 PXA N HMAN ABAN 11:50 - 12:10 0.33 PXA N HMAN ABAN 12:10 - 13:00 ~ 0.83 ~ PXA ~ N ~ H MAN ~ ABAN 13:00 - 15:15 2.25 PXA N HMAN ABAN 15:15 - 15:30 0.25 PXA N HMAN ABAN 15:30 - 15:50 0.33 PXA N HMAN ABAN 15:50 - 16:50 1.00 PXA N HMAN ABAN 16:50 - 18:45 I 1:921 PXA IN HMAN (ABAN 18:45 - 19:15 0.50 PXA N HMAN ABAN 19:15 - 20:00 0.75 PXA N HMAN ABAN 20:00 - 21:45 1.75 PXA N HMAN ABAN 21:45 - 22:00 0.25 PXA N HMAN ABAN 22:00 - 22:15 0.25 PXA N HMAN ARAN 22:15 - 23:00 0.75 DRILL N HMAN PROD1 23:00 - 00:00 1.00 DRILL N HMAN PROD1 7/19/2008 00:00 - 01:30 1.50 STKOH N HMAN PROD1 01:30 - 01:45 0.25 STKOH N HMAN PROD1 01:45 - 03:45 2.00 STKOH N HMAN PROD1 60 fUmin .51/.2 230psi At 9630' increase bpm 60 ft/min .93/.46 770psi Pull to safety at 9220', circulate at min rate for 15 minutes RIH at full rate with bio washing down to 9645' 2.5/2.48, 2000 psi Pumped 80 bbls of Bio, switch to Flo-Pro and POH 2.72/2.38 bpm 2377 psi POH displacing the well to Flo-Pro LD cementing assembly Wash BOP stack and function test rams. PU build assembly BHA#4. 3.8 deg bend and HCC bicenter bit. Had to screw it through the stack. RIH clean Log CCL for tie-in. 9300'-9600'. -21' correction. Used WS setting log that is tied into the Geo PDC log. D to at 9643' and 12fpm. Make pump rate 0.1 bpm and tag again at 9643'. Too close to window to bring on pumps. Decision a PO for diam nd mill to clean u the win and et a little rat hole. POH with BHA#4 Safety Meeting for laying down the BHA LD BHA#4 Bit is in great shape. We will run on the next build attempt. Adjust AKO from 3.8 to zero and lay down the HOT and DGS sub. PU a window mill and string mill, DPS, EDC, P&C's, OC, and CTC. RIH with BHA#5 clean Log CCL for tie-in 9300'-9600'. -21' Correction. Drv taa ~ 9643.9'. Start milling ~ 9643.7', ROP 30-40 fUhr, 2.48/2.43, FS 2800 psi, 3000 psi, 9.61 ECD, WOB 0.43K. Mill 10' of rat hole. PU 10' and RBIH to dry tag w/pumps off, clean to 9654', tag with 3K WOB. Ream up through 9630'. POOH for build assembly BHA #6. PJSM for LD Milling BHA LD Milling BHA #5. Mill and reamer were 3.79" go, 3.78" no-go MU build assem I -adjust bend from 0 to 3.8 degree bend and a HCC bicenter bit. Did not have much of a problem running the bend through the stack. Minimal screwing was used. RIH with BHA #6 RIH in clean to 9655' Tie-in -15' correction RIH ast window to cement lu .Start drillin at 9656. FS 2710psi, 2880psi, ROP 42 ft/hr, ECD 9.69, 2.36/2.36, WOB 1.48 ROP sudden) jum s to u wards of 100 ft/hr, ull u hole and slow) ease back down with less WOB Continue drilling ~ 9666' ~ 2.32/2.32, WOB 0.75K, Drill at 0.1 ft/min to make sure our kickoff is departing X9667' increase ROP to 0.4 ft/min, 2710psi, FS 2700 psi Printed: 8/25/2008 2:09:16 PM BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/19/2008 01:45 - 03:45 2.00 STKOH N HMAN PROD1 09670' increase WOB to 1.67K ROP jumps to 100-400 ft/hr "drilled" down to 9686' It seems as thou h the cement is either not set u et or it is contaminated. Take sample, geo confirms it is 95% cement, 5% cuttings Some of the cement was soft and some was hard. 03:45 - 04:30 0.75 STKOH N HMAN PRODi Open EDC bring up cuttings bottoms up. Cuttings are the same percents as before 04:30 - 06:30 2.00 STKOH N HMAN PROD1 Discuss options; Look at new directional plan with deeper KOP, think about another cmt job, muse setting aluminum billet, ponder an OHST. Convince ourselves (with town buy in) that the best Ian forward is to set a whi stock in the 4-1/2" tubin . 06:30 - 08:50 2.33 STKOH N HMAN PROD1 POH with build BHA #6. 08:50 - 09:00 0.17 STKOH N HMAN PROD1 PJSM for LD of BHA and cutting coil 09:00 - 11:45 2.75 STWHIP N HMAN WEXIT LD build assembly #6. Bit graded 1-4 with 6 chipped cutters on the wing, port plugged with cement and cement caked on wing. Trim 150' of coil and cable, redress and install CTC, rehead CoiITRAK tools, PT to 35k and 3500 psi. 11:45 - 12:30 0.75 STWHIP N HMAN WEXIT PU BHA #7 Whi stock settin BHA. 12:30 - 14:30 2.00 STWHIP N HMAN WEXIT RIH. 14:30 - 16:05 1.58 STWHIP N HMAN WEXIT Log GR Tie-at THRZ 8800' - 8884' at 80 fph. -18 correction. RIH and perform quick collar log from 9400' -9632' at 1200'/hr. 16:05 - 17:05 1.00 STWHIP N HMAN WEXIT PU to get string weight of 37k. RIH to 9633' (bottom of WS). Close EDC. PU to neutral weight. Walk pressure up and observe shear at 4200 psi. Top of whipstock set at 9620'. Set 1.5k on whipstock. PU to 9600', open EDC and start 2# bio down the coil. 17:05 - 19:00 1.92 STWHIP N HMAN WEXIT POH displacing the well to 2# Bio. 19:00 - 19:15 0.25 STWHIP N HMAN WEXIT PJSM for LD the whip set assembly. Discuss hazards and risks associated 19:15 - 20:30 1.25 STWHIP N HMAN WEXIT LD BHA #7 and pick uo millinn acsamhly BHA #8, CTC, XO, UOC LOC, Comms, EDC, DPS< DGS, Blind, XO x2, 2 jnt of PH6, XO, Xtreme motor, HCC Dia MITI, HCC window mill 20:30 - 22:40 2.17 STWHIP N HMAN WEXIT RIH with milling assembly and tie-in -13 correction 22:40 - 00: 1.3 M EXIT ry tag the whipstock at 96 .5. p weig t own weight ~n 19K FS-2740 psi 13, ~ C Begin time milling at 0.1 fU Mill ~ 2.49/2.45, 2800 psi, DWOB .63K to 9621.5 Mill ~ 2.45/2.45, 2850 psi, DWOB 1.3K to 9622.0 Mill ~ 2.45/2.45, 2800. psi, DWOB 2.14 to 9622.5 Mill ~ 2.45/2.43, 2750 psi, DWOB 2.24 to 9623.0 7/20/2008 00:00 - 04:15 4.25 STWHIP N HMAN WEXIT Continue milling 02.45/2.45, 2800 psi, DWOB 2.14K, mill to 9622.5' 02.45/2.43, 2750 psi, DWOB 2.24K, mill to 9623' 02.48/2.44, 2850 psi, DWOB 3.35K, mill to 9623.5' 02.48/2.47, 2850 psi, DWOB 3.99K, mill to 9624' 02.50/2.48, 2890 psi, DWOB 4.50K, mill to 9624.5' 02.45/2.46, 2681 psi, DWOB 3.13K, mill to 9625' 02.48/2.52, 2700 psi, DWOB 2.09K, mill to 9626 04:15 - 05:45 1.50 STWHIP N HMAN WEXIT Continue milling 02.48/2.51 2500 psi, DWOB 1.81 K, mill to 9628' 05:45 - 07:35 1.83 STWHIP N HMAN WEXIT Mill 0 2.49/2.54, 2563 psi, DWOB 2.03K, mill to 9628' BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/20/2008 05:45 - 07:35 1.83 STWHIP N HMAN WEXIT Mill ~ 2.49/2.54, 2670 psi, DWOB 2.27K, mill to 9628.5' Mill ~ 2.49/2.53, 2640 psi, DWOB 1.56K, mill to 9629' Mill ~ 2.48/2.53, 2618 psi, DHWOB 0.71 k, 9630.1' window mil exit window, trace formation cuttings in sample 07:35 - 11:00 3.42 STWHIP N HMAN WEXIT Drill Shublik formation to 9639'. Geo confirmed with cuttings sample. Stall at 9639'. PU above the window and RIH to bottom at 70fph observe 100 psi motonvork at the top and bottom of the window. Stall at 9639.6'. Drill to 9641'. Start reconditioned Flo-Pro down the hole. Ream window 2x. Drift dry with no problems. Open EDC. 11:00 - 12:45 1.75 STWHIP N HMAN WEXIT POH while finishing swap to FLO-Pro. 12:45 - 13:00 0.25 STWHIP N HMAN WEXIT PJSM for LD and PU of BHA 13:00 - 13:35 0.58 STWHIP N HMAN WEXIT LD BHA #8. Window and string mill gauge 3.79". 13:35 - 14:30 0.92 STWHIP N HMAN WEXIT PU build assembly (BHA #9}. 3.4 deg bend motor w /HCC bicenter bit; Open EDC 14:30 - 16:20 1.83 STWHIP N HMAN WEXIT RIH w BHA #9 pumping at minimum rate. 16:20 - 17:10 0.83 STWHIP N HMAN WEXIT Log GR Tie-in at THRZ, -16' correction. PU weight 38.5k. 17:10 - 18:20 1.17 STWHIP N HMAN WEXIT Drill from 9641' with 300 psi motor work for 1'. Motor work drops off and wash down unobstructed at 170 fph. We must be in the old hole. RIH to 9683' and get 200psi motor work at 160 fph. Stall at 9687.7'. Drill cmt at 100 fph. Cement still not hard enough for a kick off. Discuss options with town. 18:20 - 21:30 3.17 STWHIP N HMAN WEXIT Drill soft cement to 9843' at 50 fph. 21:30 - 23:30 2.00 STWHIP N HMAN WEXIT POH. Flag pipe at 9666', EOP at 9600', Continue pulling out of hole 23:30 - 23:45 0.25 STWHIP N HMAN WEXIT PJSM for LD BHA #9 and picking up cementing BHA. Discuss procedure, risks, and mitigations 23:45 - 00:00 0.25 STWHIP N HMAN WEXIT LD BHA #9 7/21/2008 00:00 - 00:35 0.58 REMCM N DPRB WEXIT PU BHA #10, w/ a 3" cementing nozzle(ID - 3/4"), 6' stinger 00:35 - 02:15 1.67 REMCM N DPRB WEXIT RIH with cementing BHA, tie-in using flag 02:15 - 06:30 4.25 REMCM N DPRB WEXIT PUH to park and pump at min rate. Wait on Cementers and crew change. 06:30 - 06:50 0.33 REMCM N DPRB WEXIT PJSM for pumping cement. 06:50 - 09:30 2.67 REMCM N DPRB WEXIT Verify coil volume is 55.2 bbl. Lead with 3 bbl of fresh H2O. Pt lines to 4000psi. Batch up 10 bbl of 17# cmt (0730 hrs) Zero in micromotion when cmt is at reel Load reel with 10 bbl of 16.8# cmt Pump 4 bbl of KCI spacer Follow with 2# BIO 20 bbl 2.14 bpm 2930psi 30 bbl 2.42 bpm 2210psi 40 bbl 2.43 bpm 2285psi 50 bbl 2.42/2.40 bpm 2260 psi ,nozzle at 9835' 55 bbl 2.43/2.40 bpm 2432 psi cmt at nozzle (observe slight pressure increase) 57 bbl slow rate to 0.5 bpm and PU at 30 fpm. cmt is 2 bbl above us 60 bbl .5 bpm 570psi 30fpm 61.4 bbl 0.5 bpm 773 psi 30fpm, nozzle at window, psi increase is due to cmt hydrostatic 65 bbl 0.5bpm 1018 psi, cmt out of coil rnncea: azaicvuo c.~a: io rm BP EXPLORATION Operations Summary Report Page 5 of 14 Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase j Description of Operations 17/21/2008 106:50-09:30 09:30 - 11:15 11:15 - 11:30 11:30 - 12:00 12:00 - 12:45 12:45 - 14:30 14:30 - 14:50 14:50 - 22:00 22:00 - 22:30 22:30 - 00:00 7/22/2008 00:00 - 01:30 01:30 - 01:45 01:45 - 02:45 02:45 - 04:30 04:30 - 04:45 04:45 - 08:00 2.67 REMCM N DPRB WEXIT pump at 0.1 bpm and pull to safety at 8600'. wait for 5 mins, displance KCI to put BIO at nozzle, shut in backside 69.2 bbl 0.36bpm 981 / 0 psi 70 bbl 0.36 bpm 1121 / 168 psi 70.2 bbl shut down for 1 min 1143 / 500 psi ;squeeze holding at 500 psi 71.2 bbl 1794 / 842 psi, 2 bbl squeezed, do not want to squeeze more and risk sending contaminated cmt down hole. wait 2 mins 1070/593, pressure heading back to -500psi. Wash down to 9600' with bio at 2.77bpm. Stop coil to verify we are not losing fluid. 2.60 in /2.61 out. 1.75 REMCM N DPRB WEXIT POH displacing the well to Flo-Pro 0.25 REMCM N DPRB WEXIT PJSM for LD BHA, washing the stack, and PU of Window milling assembly 0.50 REMCM N DPRB WEXIT LD cementing BHA#10. PU swizzle stick to wash stack. 0.75 STWHIP N DPRB WEXIT PU window dressing assembly (BHA#11). CoiITRAK tools, 2-7/8 straight motor, 3.8" string and window mill (used). Install check valves in UOC. 1.75 STWHIP N DPRB WEXIT RIH with BHA #11 0.33 STWHIP N DPRB WEXIT Tie-in log with CCL 9450'-9580' at 1200 fph. (much faster than the 100 fph GR logging). 14' correction 7.17 STWHIP N WAIT WEXIT WOC, 500 psi compressive strength at 15:45 RIH to 9605' at 0.5 bpm no indication of cmt (8.5 hrs on cement TT) PUH and WoC 2000 psi compressive strength at 16:40 RIH to 9610' at 0.25 bpm no indication of cmt PUH and WoC RIH to 9615' at 0.25 bpm slight indication of cmt PUH and WoC 0.50 STWHIP N DPRB WEXIT RBIH and see if cement is hard. Pumping at 0.25 bpm, 5ft/min, Start seeing motor work at 9616', see 3-4K WOB at 9619'. Decide to PUH and wait on cement a while longer 1.50 STWHIP N WAIT WEXIT WOC 1.50 STWHIP N DPRB WEXIT Run back down to bottom and begin milling FS - 2650 psi 9615' - 2.46/2.49, 2800 psi, WOB 1.OK, ROP 100 fUhr 9618' - 2.55/2.68, 3140 psi, WOB 2.7K, ROP - 25-39 fUhr 9620' - 2.50/2.60, 3000 psi, WOB 3.OK, ROP - 10-25 ft/hr 9625' - 2.50/2.49, 3030 psi, WOB 3.7K, ROP - 25 fUhr 9630' - 2.47/2.45, 3000 psi, WOB 3.5K, ROP - 20 ft/hr 9635' - 2.51/2.51, 3000 psi, WOB 3.9K, ROP - 20-25 ft/hr 0.25 STWHIP N DPRB WEXIT Start mud swap Continue milling 9640' - 2.49/2.48, 3000 psi, WOB 3K, ROP 20-30 ft/hr 1.00 STWHIP N DPRB WEXIT Make a slow pass up through the window Circulate bottoms up, RBIH and tag bottom at 9640' 1.75 STWHIP N DPRB WEXIT Open EDC and POOH 0.25 STWHIP N DPRB WEXIT PJSM for LD BHA #11. Discussed procedure, hazards and mitigations 3.25 STWHIP N DPRB WEXIT LD BHA #11, Trim 100' of CT as per chrome management procedure, install CTC and PT to 35k/4000psi rehead rnntea: azarzwo cva: io rm BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: 13-30 Spud Date: 7/6/1982 Common Well Name: 13-30 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Qperations 7/22/2008 0 8:00 - 09:10 1.17 DRILL P PROD1 PU BHA # 12, HCC bicenter bit, 3.4 bend motor, CoiITRAK t ools. 09:10 - 10:50 1.67 DRILL P PROD1 RIH w/ open EDC pumping at minimum rate. 10:50 - 11:05 0.25 DRILL ILL P P PROD1 PROD1 Log CCL Tie-in (-12' correction) Tag at 9637.4' PU 2' and start pumps. Slight MW, probably 11:05 - 12:15 1.17 DR t earing up the wing cutters on bottom of old window. Wash down to 9643'. Time drill to 9644' to get pilot engaged and don't want to stall and PU bit because of close proximity of old window. Observe a reduction in vibration assume pilot is engaged. 12:15 - 12:37 0.37 DRILL P PROD1 Drill at 2.57/2.65,bpm ~ 2900 psi,2750 psi FS, ROP 16fph, WOB 1.18K, ECD 9.49 ppg. TF OR, Inc at bit 43.6. Drill to 9650'. 12:37 - 15:00 2.38 DRILL P PROD1 Drill at 2.52/2.52,bpm C~3 3010 psi,2750 psi FS, ROP 30fph, WOB 1.92K, ECD 9.50 ppg. TF 30L, Inc at bit 43.7. Drill to 9710'. 15:00 - 16:45 1.75 DRILL P PROD1 Drill build section in Shublik, 2.6 bpm, 2800-3300 psi, 20 fph, ' . 4K wob, 9.5 ecd, 70 deg incl, Drilled to 9750 16:45 - 17:00 0.25 DRILL P PROD1 PROD1 Wiper trip to window, clean hole. 2800-3300 psi, 20-40 fph, 3-4K 2.5 bpm Drill build section 17:00 - 19:15 2.25 DRILL P , , wob, 9.6 ecd, 85 deg incl, Drilled to 9855' 19:15 - 19:30 0.25 DRILL P PROD1 PROD1 Wiper trip, clean hole. 2.61 bpm, 3000-3300 psi, 20-30 fph, 3-4K Drill build section 19:30 - 21:15 1.75 DRILL P , wob, 9.6 ecd, 107 deg near bit incl, Drilled to 9920' 21:15 - 23:00 1.75 DRILL P PROD1 Drill build section, 2.55 bpm, 3000-3300 psi, 15-45 fph, ' 3.5-4.5K, 9.6 ecd, 118 deg near bit, Drilled to 10,000 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip, Circulate bottoms up to catch a sample for geo, Geo ' TVD finds that a fault must have been crossed and we are 10 higher than thought. Point bit down at 180 to avoid the Kingak 7/23/2008 00:00 - 00:15 0.25 DRILL P PROD1 Drill build ~ 2.55bpm, 3190 psi, 60-90 fph, 3K WOB with a 180 deg near bit inclination 00:15 - 01:00 0.75 DRILL P PROD1 Drill build ~ 2.55 bpm, 3100 psi, 60-fph, 9.7 ecd, 2.5K WOB, at 88.5 deg inclination and 8813.5' TVD 01:00 - 03:15 2.25 DRILL P PROD1 PROD1 Open EDC and POOH for lateral BHA. PJSM for LD the build assembly. Discuss the procedure, risks 03:15 - 03:30 0.25 DRILL P and mitigations 03:30 - 05:00 1.50 DRILL P PROD1 LD build assembly and MU BHA #13 w/ a 1 deg motor and a HCC bicenter bit 05:00 - 05:45 0.75 DRILL P PROD1 D1 Test CoilTrak on catwalk RIH with lateral assembly BHA #13 with 1.0 deg motor, HCC 05:45 - 07:50 2.08 DRILL P PRO BC Bit, RES tool and Coiltrak. BHA OAL = 78.98'. 07:50 - 08:20 0.50 DRILL P PRODi Log GR tie-in at window. No RA Tag. -18' CTD correction. ' 08:20 - 09:45 1.42 DRILL P PROD1 . No RIH clean to bottom. Dropped pump at 9880' to 10,000 ledges. 09:45 - 11:10 1.42 DRILL P PROD1 Drill lateral in Sag River. 2.6 bpm, 2900-3600 psi, 90 deg incl, 9.9 ecd, 100 fph, 2K wob, Drilled to 10200'. 11:10 - 12:10 1.00 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. Dropped pump at 9880 - 10,000', No ledges. 12:10 - 13:30 1.33 DRILL P PROD1 Drill lateral in Sag River. 2.6 bpm, 2900-3600 psi, 90 deg incl, 9.9 ecd, 100 fph, 2K wob, Drilled to 10300'. Printed: 8/25/2008 2:09:16 PM BP EXPLORATION Page 7 of 14. ~ Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008. End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/23/2008 13:30 - 14:05 0.58 DRILL P PROD1 Drill lateral in Sag River. 2.6 bpm, 2900-3600 psi, 90 deg incl, 9.9 ecd, 90 fph, 2K wob, Drilled to 10,350'. 14:05 - 15:00 0.92 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. Dropped pump at 9880 - 10,000', No ledges. 15:00 - 16:15 1.25 DRILL P PROD1 Drill lateral in Sag River. 2.6 bpm, 2900-3800 psi, 87 deg incl, 9.9 ecd, 120 fph, 2-3K wob, Drilled to 10500'. 16:15 - 16:45 0.50 DRILL P PRODi Wiper trip to window. RIH clean to bottom. Dropped pump at 9880 - 10,000', No ledges. 16:45 - 17:10 0.42 DRILL P PROD1 Log GR tie-in at window. No RA Tag. On depth, Zero CTD correction. 1.7:10 - 17:25 0.25 DRILL P PROD1 RIH clean to bottom. Dropped pump at 9880 - 10,000', No ledges. 17:25 - 19:00 1.58 DRILL P PROD1 Drill lateral in Sag River. 2.6 bpm, 2900-3800 psi, 86 deg incl, 9.9 ecd, 120 fph, 2-3K wob, Drill to 10,650' 19:00 - 20:00 1.00 DRILL P PROD1 Wiper trip to window. Dripped pumps at 9,880'-10,000', 20:00 - 21:00 1.00 DRILL P PROD1 Drill lateral in Sag River. 2.58, 3000-3500 psi, 89 deg incl, 9.9 ecd, 70-100 fph, 2-3K WOB, Drill to 10,703' 21:00 - 22:30 1.50 DRILL P PROD1 Lost returns after crossing fault at 10,703', Start drilling with 2.5/0.3, 2400 psi, after 10' of drilling returns have improved ,slightly 2.4/0.9 bpm, 2700 psi At 10,720' drill at slightly slower rate 2.28/0.99, 2940 psi, ROP 80 fph, 89 deg near bit incl At 10,780' 2.4/1.5, 3300 psi, 126fph 22:30 - 23:30 1.00 DRILL P PROD1 Wiper trip to the window, 2.09/1.11 bpm 23:30 - 00:00 0.50 DRILL P PROD1 Drill Lateral in Sag River 2.34/1.42 bpm, 3430 psi, ROP 110 fph, 89 deg incl. 7/24/2008 00:00 - 02:00 2.00 DRILL P PROD1 Continue drilling lateral in the Sag River, 2.44/1.77 bpm, 3200 psi, ROP 98, 9.9 ecd, 92 deg incln., Start mud swap Continue drilling, 2.41/1.76, 3140 psi, ROP 105 fph, 9.8 ecd, 91 deg incl, 1.8 WOB 02:00 - 03:15 1.25 DRILL P PROD1 Wiper trip to window, tie-in -1.5' 03:15 - 04:00 0.75 DRILL P PROD1 Drill lateral in the Sag River, 2.48/1.92bpm, 3320 psi, 9.6 ecd, 92 deg incl, WOB 3.8K, ROP 135 04:00 - 05:15 1.25 DRILL P PROD1 Continue drilling, 2.35/1.88, 2920 psi, 9.5 ecd, 94 degree incl, WOB 3K, ROP 120 05:15 - 06:20 1.08 DRILL P PROD1 Wiper trip to window, Dropping pump rates at 9,880'-10,000' and 10710', no ledges, RIH clean to bottom. 06:20 - 07:50 1.50 DRILL P PROD1 Drill Sag River lateral, 2.5 bpm, 2.0 returns, 2700-3700 psi, 89 deg incl, 9.5 ecd, 120 fph, 3K wob, Drilled to 11300'. 07:50 - 09:00 1.17 DRILL P PROD1 Wiper trip to window, Drop pump rates at 9,880'-10,000' and 10710' to 1/2 bpm, no ledges, RIH clean to bottom. 09:00 - 10:15 1.25 DRILL P PROD1 Drill Sag River lateral, 2.5 bpm, 2.0 returns, 2700-3700 psi, 88 deg incl, 9.6 ecd, 110 fph, 3K wob, Drilled to 11400'. 10:15 - 10:45 0.50 DRILL P PROD1 Drill Sag River lateral, 2.5 bpm, 2.0 returns, 2700-3700 psi, 89 deg incl, 9.7 ecd, 100 fph, 3K wob, Drilled to 11,450'. 10:45 - 11:15 0.50 DRILL P PROD1 Wiper trip to window, clean hole. 11:15 - 11:45 0.50 DRILL P PROD1 Log GR tie-in, -1ft CTD. BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name:. NORDIC 1 Rig Number: Date From --To Hours .Task I Code NPT Phase ~ Description of Operations 7/24/2008 11:45 - 12:40 0.92 DRILL P PROD1 RIH clean to bottom, slow pump to 1/2 bpm from 9880-10000' and 10710', no ledges. 12:40 - 13:20 0.67 DRILL P PROD1 Drill Sag River lateral, 2.5 bpm, 2.0 returns, 2700-3700 psi, 89 deg incl, 9.7 ecd, 110 fph, 3-4K wob, Drilled to 11530'. 13:20 - 14:15 0.92 DRILL P PROD1 Drill Sag River lateral, 2.5 bpm, 2.0 returns, 2700-3700 psi, 89 deg incl, 9.7 ecd, 110 fph, 3-4K wob, ROP dropped to 80 fph at 11,580', no shift in RES or GR. RES =14.5, GR=95. Drilled to 11600'. 14:15 - 16:00 1.75 DRILL P PROD1 Wiper trip to window, Drop pump rates at 9,880'-10,000' and 10710' to 1/2 bpm, no ledges, RIH clean to bottom. 16:00 - 17:30 1.50 DRILL P PROD1 Drill Sag River lateral, 2.6 bpm, 2.1 returns, 2800-3700 psi, 90 deg incl, 9.7 ecd, 70 fph, 3K wob, Drilled to 11,680'. 17:30 - 18:15 0.75 DRILL P PROD1 Drill Sag River lateral, 2.6 bpm, 2.1 returns, 2800-3700 psi, 90 deg incl, 9.7 ecd, 70 fph, 3K wob, Drilled to 11,714'. 18:15 - 19:00 0.75 DRILL P PROD1 Drill Sag River lateral, 2.6 bpm, 2.1 returns, 2800-3700 psi, 90 deg incl, 9.7 ecd, 70 fph, 3K wob, Drilled to 11,750 19:00 - 20:45 1.75 DRILL P PROD1 Wiper trip to window, Drop pump rates at 9,880-10,000', clean no ledges 20:45 - 22:45 2.00 DRILL P PROD1 Drill Sag River lateral, 2.6/2.1, 3370-3400 psi, 90 deg incl, 9.8 ecd,40-90 fph, 3K WOB, Drilled to 11860' 22:45 - 23:20 0.58 DRILL P PROD1 Drill Sag River lateral, 2.79/2.31, 3300-3500 psi, 92 deg incl, 9.8 ecd, 60-80 fph, 1.8 WOB, 23:20 - 00:00 0.67 DRILL P PROD1 Wiper trip to window, slow pump to 0.5 bpm from 9880'-10,000' 7/25/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue wiper trip to the window 00:30 - 00:45 0.25 DRILL P PRODi Log GR tie in at window. No RA Tag, -2.5' correction ' 00:45 - 01:45 1.00 DRILL P PRODi RIH clean to bottom, dropped pumps from 9,880'-10,000 01:45 - 03:00 1.25 DRILL P PROD1 Drill lateral in the Sag River, 2.3/1.7, 3000-3300 psi, ROP 80-95 fph, WOB 3.3K, ECD 9.7 Drilled to 11960 03:00 - 04:30 1.50 DRILL P PRODi Drill lateral in the Sag River, 2.5/2.0, 3200-3500 psi., ROP 60-90 fph, WOB 3K, ECD 9.7 Drilled to 12,050' 04:30 - 05:45 1.25 DRILL P PROD1 Wiper trip to window, dropped pumps from 9,880'-10,000', clean to bottom, no ledges 05:45 - 07:30 1.75 DRILL P PROD1 Drill lateral in the Sag River, 2.6/2.1, 3000-3800 psi, ROP 80-100 fph, WOB 2-3K, ECD 9.9 Drilled to 12130'. 07:30 - 08:45 1.25 DRILL P PROD1 Drill lateral in the Sag River, 2.6/2.1, 3000-3800 psi, ROP 80-100 fph, WOB 2-3K, ECD 10.0 Drilled to TD of 12,200'. 08:45 - 10:00 1.25 DRILL P PROD1 Wiper trip to window. Slow pump to 1/2 bpm at 9880-10000'. Clean hole. 10:00 - 10:20 0.33 DRILL P PROD1 Log GR tie-in. On depth, no correction. 10:20 - 11:00 0.67 DRILL P PROD1 RIH clean to bottom. Slow pump to 1/2 bpm at 9880-10000'. Clean hole. Tag final TD at 12,201'. 11:00 - 11:30 0.50 DRILL P PROD1 POH. Lay in new FloPro liner pill while POH. 2.3 / 1.5 bpm. P~„fad• a/95/9nn8 2:09:16 PM BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: I Date Frorn - To ~ Hours Task ~ Code ~ NPT `Phase ~, Description of Operations 7/25/2008 11:30 - 13:15 1.75 DRILL P PROD1 Log up with Coiltrak RES/GR MAD pass from 11,000-10,500' at 300 fph. 13:15 - 15:15 2.00 DRILL P PROD1 POH with lateral drilling BHA. Flag coil at 8900' and 6200' EOP. 15:15 - 15:30 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out drilling BHA. 15:30 - 16:15 0.75 DRILL P PROD1 Lay out drilling BHA. HCC Bit #7 graded at (2,2,1, 1 plugged port). 16:15 - 17:45 1.50 CASE P RUNPRD Pump 35 bbl rig water and pump out E-Line slack from coil. Pumped 4.5 bpm at 4100 psi. Cut off 415' of extra E-Line from end of coil. 17:45 - 23:30 5.75 CASE P RUNPRD Pressure /Function test BOPE. Witness waived by AOGCC inspector, Bob Noble. Good test. 23:30 - 00:00 0.50 CASE N SFAL RUNPRD Swab valve is grease locked, work to get it unlocked. 7/26/2008 00:00 - 00:30 0.50 CASE N RUNPRD Continue to work swab valve 00:30 - 02:00 1.50 CASE P RUNPRD Open well, well is still taking fluid, fill hole with a total of 13 bbls, RU to run liner 02:00 - 02:30 0.50 CASE P RUNPRD PJSM for running liner, discussed the hazards and mitigations of the job 02:30 - 06:00 3.50 CASE P RUNPRD MU indexing guide shoe, BOT float collar, 2-7/8" STL pup jt, BOT Float Collar, 2-7/8" STL pup jt, BOT landing collar, 73 jts of 2-7/8" liner, pup jt and XO, 19 jts 3-3/16", XO, 3-1/2" pup, X nipple, two 3-1/2" pup jts, and BOT deployment sleeve Liner Total Length 2739.4'. Fill hole twice to keep it full, 24 bbls in all 06:00 - 06:30 0.50 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running liner with day crew. 06:30 - 09:00 2.50 CASE P RUNPRD Continue running liner. M/U Deployment sleeve and SELRT. 09:00 - 10:00 1.00 CASE P RUNPRD Run 8 jts of 2-3/8" PH6 tubing to swallow E-Line. (257.18'). 10:00 - 10:30 0.50 CASE P RUNPRD Pressure test inner reel valve on coil reel. 10:30 - 12:00 1.50 CASE P RUNPRD M/U BTT CTC and pull /press test. M/U to top of PH6. BHA total length = 3008.10'. Circ. 1 bpm at 9200 psi to fill liner and get returns. 12:00 - 13:30 1.50 CASE P RUNPRD RIH with liner. circ of 0.3 bpm, 0.5 bpm returns. Stop at coil flag, correct -8' CTD to flag at 9208'. Up wt = 37.5K, Dwn wt = 19K. 13:30 - 14:30 1.00 CASE P RUNPRD RIH clean thru window at 9620' with liner. RIH clean to bottom. RIH at 50 fpm, circ at 0.2 bpm with 0.7 bpm retums. Tag TD at 12,212' CTD, tagged three times at same depth. Liner is landed at TD.. 41 K up wt, 12K dvvn wt. 14:30 - 15:30 1.00 CASE P RUNPRD Insert 5/8" steel ball and displace with FloPro. Stack 10K down on liner. Circ ball at 1.9 bpm, 2300 psi, 1.4 bpm returns. Slow to 0.5 bpm at 30 bbls. Ball on seat at 41.1 bbls. Sheared at 4100 psi. Stop pump. Pick up 4 tt to 34K up wt. Liner is free from running tools. Stack 10K down on liner again. 15:30 - 18:00 2.50 CASE P RUNPRD Circ well to double slick 2% KCL water. 2.8 bpm, 2.4 returns. 15% losses. Clean rig pits. Haul used FloPro to MI plant. Rig up SWS cementing unit. • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: t Date'- From - To Hours Task Code NPT Phase Description of Operations 7/26/2008 18:00 - 18:30 0.50 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. 18:30 - 19:45 1.25 CEMT P RUNPRD Circ. KCL water while batch mix cement. Cement at wt at 19:40 hrs. 19:45 - 21:00 1.25 CEMT P RUNPRD Stage 2 bbl water. Press test cement line to 4000 psi. Stage 38.0 bbl, 15.8 PPG, G Cement, 2.0 bpm, 1500 psi 20 bbl, 2.0 bpm, 2050 psi, 15% Loss. 30 bbl, 2.0 bpm, 1650 psi, 15% loss 38.0 bbl, 2.0 bpm, 1350 psi. stop pump, iso-ate cementers, clean cementing line. Displace cement with 2# Bio, using rig pump with Micromotion, Zero on displacement. Stage 2# Biozan displ. 10 bbl displ, 3.5 bpm, 2000 psi, chasing cement. Catch up with cement at 15 bbl, 2.5 bpm, 1250 psi, 20 bbl displ, 2.4 bpm, 1100 psi, 13% loss 30 bbl displ, 2.4 bpm, 1440 psi, 17% loss 34.6 bbl, cement at shoe, zero out totalizer. 40 bbl displ, 2.4 bpm, 1950 psi, 17% loss, 50 bbl displ, 2.4 bpm, 2400 psi, 17% loss 53.7 bbl displ, 2.4 bpm, 2500 psi, stop pump. Pick up 14'. Circ. 7 bbl to side, 1.8 bpm, 1270 psi, (2 bbl cmt, 5 bbl Bio to backside) 61.1 bbl displ, stop pump, Open Baker choke. RIH with coil, stack wt at same depth, Close Baker choke. Zero in and out totalizers, LWP sheared at 0.4 bbl, at 2300 psi, looks good 10 bbl, 2.8 bpm, 2.0 retums, 2950 psi, 25% loss 14 bbl, 2.7 bpm, 2.0 returns, 3000 psi, slow pump to 1.5 bpm 15 bbl, 1.0 bpm, 0.70 returns, 1600 psi, 30% loss 16 bbl, 1.0 bpm, 0.6 returns, 40% loss, Fault at 10710' not sealed. Bump LWP at 17.4 bbls, calc was 16.9 bbl. hold 2620 psi. 5 min. no leak. Out totalizer had 29.6 bbls when bumped plug, lost 6.4 bbls to fault. Bled press to zero, check floats, floats holding. Press up to 500 psi and sting out clean from top of liner at 9461'. SELRT worked very well. 21:00 - 23:00 2.00 CEMT P RUNPRD POH replacing coil voidage. pump 0.8 bpm with 0.1 bpm returns. 23:00 - 23:15 0.25 CEMT P RUNPRD PJSM for LD liner running BHA. Discuss procedure, risks and mitigations. 23:15 - 00:00 0.75 CEMT P RUNPRD LD Liner running BHA 7/27/2008 00:00 - 00:30 0.50 CEMT P RUNPRD Continue laying down liner running BHA and SELRT 00:30 - 00:45 0.25 EVAL P LOWERI PJSM for picking up logging / cleanout assembly BHA #15 00:45 - 05:15 4.50 EVAL P LOWERI MU cleanouVlogging assembly, w/ 2.30" HCC diamond mill, motor, 2 jts of CSH, Memory GR/CCL carrier, Circ sub, Hyd Disc, 90 jts of CSH, disconnect, 2 jts of PH6, lockable swivel, and CTC 05:15 - 07:00 1.75 EVAL P LOWERI RIH to deployment sleeve at 9461, Tagged AL profile at 9469'. Printa~i• R/95/200R 2:09:16 PM BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: 13-30 Spud Date: 7/6/1982 Common Well Name: 13-30 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 7/27/2008 07:00 - 09:30 2.50 EVAL P LOWERI Mill out BTT AL profile in deployment sleeve with 2.30" d iamond mill. 1 .4 bpm, 1500 psi, Several stalls, tried to keep stalls light. Milled thru profile and reamed up /down 3 times at 1 fpm until clean. Full returns. 09:30 - 12:00 2.50 EVAL P LOWERI Log down from 9300' with SWS Memory GR/CCL at 30 FPM, Circ at 1.3 bpm at 1600 psi. Tag PBTD at 12192' CTD. 12:00 - 13:00 1.00 EVAL P LOW ER1 Log up to 9300' at 60 fpm while laying in 20 bbl new FloPro pert pill. 13:00 - 14:00 14:00 - 14:15 1.00 0.25 EVAL EVAL P P LOWERI LOWERI POH. SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring and laying out BHA. 14:15 - 16:45 2.50 EVAL P LOWERI Standback 45 stds of 1-1/4" CSH and tay out BHA. Download SWS Memory GR/CCL data. PBTD from Memory GR/CCL is 12,183'. Bottom pert in plan is at 12,180'. 16:45 - 18:00 1.25 CEMT P RUNPRD Jet stack and tree with swizzle stick to clear any cement from 18:00 - 18:30 0.50 EVAL P LOWERI rams. M/U SWS Memory Cement Bond logging tools on rig catwalk. ' Logging tools = 32.80'. XO to 3/4" SR = 2.0 18:30 - 18:45 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS Memory logging BHA. 18:45 - 22:00 3.25 EVAL P LOWERI M/U SWS Memory logging BHA, w/ 45 stands of CSH Total BHA length 2893.02' 22:00 - 23:45 1.75 EVAL P LOWERI RIH with the cement bond log BHA, RIH at 97 fpm 0.45/0.95. Run down to 12150' 23:45 - 00:00 0.25 EVAL P LOW ER1 Begin logging at 30 fpm 7/28/2008 00:00 - 01:30 1.50 EVAL P LOWERI Continue logging run up to 9300' at 30 fpm. 01:30 - 02:15 0.75 EVAL P P LOWERI LOW ER1 RBIH for second logging pass Begin second logging pass. Spot pert pill while logging up Log 02:15 - 04:00 1.75 EVAL up at 30 fpm 04:00 - 05:15 1.25 EVAL P LOW ERi POOH, with logging BHA 05:15 - 05:30 0.25 EVAL P LOW ER1 PJSM for laying down logging BHA, discuss procedure, hazards and mitigations 05:30 - 08:00 2.50 EVAL P LOW ER1 Stand back 45 sts of CSH. LD BHA #16. Download Memory CBL information. 08:00 - 10:00 2.00 CEMT P RUNPRD Press test liner lap to 2000 psi. Initial press = 2000 psi. Lost 700 psi in 20 min. Did infectivity test at 2000 psi, 0.7 bpm for 5 min. Repeated liner lap pressure test. Initial press = 2000 psi, Final press at 30 min = 400 psi. 10:00 - 12:15 2.25 PERFO P LOWERI Load SWS 2" pert guns into rig pipe shed. 104 guns, loaded and blanks. Prep to run pert guns as per the modified pert program. Sent fax copy of Memory CBL to Anc. Office. PBTD = 12,183'. Bottom shot at 12,180'. 12:15 - 12:45 0.50 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 2" pert guns. Printed: 8/25/2008 2:09:16 PM BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: ~ ~ Date From - To 'Hours Task Code NPT Phase Description of Operations 7/28/2008 12:45 - 17:30 4.75 PERFO P LOWERI Run SWS 2" PJ perf guns loaded at 6 SPF. 104 Guns total. 17:30 - 20:15 2.75 PERFO P LOW ERi M/U BTT Hyd Disc, 10 stds of CSH, BTT Hyd Disc, 2 jts PH6 Swivel and CTC. 20:15 - 22:15 2.00 PERFO P LOWERI RIH with SWS perf guns to PBTD 12183'. Tag bottom Correct depth 22:15 - 22:30 0.25 PERFO P LOWERI Pull up to 12,182'. Practice rolling pumps and getting correct flowrates 22:30 - 22:50 0.33 PERFO P LOW ER1 Start sequence No pumps for 2 min 0.3 bpm for 1 min 135 psi 1.5 bpm for 1 min 1350 psi Repeat this sequence two more times roll pumps at 0.3 bpm for one minute, bring pumps back up to 1.5 bpm for 2.5 minutes drop pumps down to 0.3 bpm for one minute and start to creep up hole at 2 fUmin All indications show that shots fired at 12,180' 90sec after last sequence No overpull after firing guns, clean pick up. 22:50 - 00:00 1.17 PERFO P LOW ER1 POH, pull up thru liner clean, perform flowcheck at TOL, no flow 7/29/2008 00:00 - 00:30 0.50 PERFO P LOW ER1 POOH 00:30 - 00:45 0.25 PERFO P LOWERI Flowcheck at surface, no flow Hold PJSM for LD the perf BHA and 20 jts of CSH, discuss procedure, risks and mitigations 00:45 - 02:00 1.25 PERFO P LOW ER1 LD perf BHA with 20 joints of CSH 02:00 - 02:15 0.25 PERFO P LOWERI PJSM for Laying down E-fire firing head and 104 guns. Discuss procedure risks and. mitigations 02:15 - 08:30 6.25 PERFO P LOWERI LD firing head and 104 SWS 2"perf guns. All shots fired. PERFORATED INTERVALS: 9,980 - 10,602 10,815 - 11,100 11,225 - 11,850 11,900 - 12,180', TOTAL PERFORATED INTERVAL = 1,812'. 08:30 - 09:30 1.00 PERFO P LOWERI Offload SWS perf guns from rig pipe shed. 09:30 - 09:45 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U BTT LT Packer BHA. 09:45 - 10:30 0.75 CASE P RUNPRD M/U LT Packer BHA #19 with BTT Seal Assembly, 4-1/2" KB Packer, running tool, Hyd Disc, 2 jts PH6, swivel and CTC. BHA OAL = 84.22'. 10:30 - 13:00 2.50 CASE P RUNPRD RIH with BHA #19. Circ at 0.3 bpm at 150 psi. 4-1/2" BTT 45 KB Retrievable Packer with 30K releasing ring and seal assembly. RIH clean to 9250'. Up wt = 36.5K, Dwn wt = 21 K. Top of BTT Deployment sleeve is at 9,454' corrected depth. Seals entered at 9479', Started Stacking wt at 9483.8'. Stacked 10K at 9486.3'. Pick up to 9463' to drop 5/8" steel ball. 13:00 - 13:40 0.67 CASE P RUNPRD Circ. 5/8" steel ball. slow down to 0.4 bpm at 35 bbl. Ball on o~~fo.~~ ai~v~nna Tn9~1sFM BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 7/29/2008 1 3:00 - 13:40 0.67 CASE P RUNPRD s eat at 40.3 bbl. RIH. Seals entered at 9478'. RIH and stop 2' above landing depth at 9481.5'. Press up 2700 psi. Stack 10K at 9484.4'. 13:40 - 14:30 0.83 CASE. P RUNPRD Pressure test KB Packer /liner lap with 2000 psi. Chart Press t est. 2000 psi at 1345 hrs. 2005 psi at 30 min. Good test. Press up to 3600 psi and release from Packer. Top of BTT 45 KB Packer is at 9447' corrected depth. 14:30 - 16:20 1.83 CASE P RUNPRD POH with BTT running tools. 16:20 - 16:45 0.42 CASE P RUNPRD L/O running tools. Recover 100%. 16:45 - 17:10 0.42 WHSUR P POST M/U nozzle BHA to freeze protect tubing. BHA OAL = 7.94'. 17:10 - 18:50 1.67 WHSUR P POST RIH with Nozzle BHA #19 to circ well to diesel. 0.5 bpm, 200 psi. 18:50 - 21:35 2.75 WHSUR P POST Park nozzle at 9,400 ft and use Little Red to pump 110 bbls diesel. Chase with fresh water until diesel seen at surface. Diesel at surface, shut down pump, shut in well and POOH. Initial WHP is 210 psi. 21:35 - 21:50 0.25 WHSUR P POST Tag stripper. Final WHP is zero. SAFETY MEETING. Discuss hazards and mitigations for UD nozzle. 21:50 - 22:10 0.33 WHSUR P POST Close master and swab valves. Break off CT riser, break off freeze protect nozzle, stand back injector. 22:10 - 23:30 1.33 WHSUR P POST Lift BPV lubricator and running equipment to rig floor. M/U BPv lubricator, pressure test to 1,000 psi good. Set BPV. 23:30 - 00:00 0.50 WHSUR P POST Load out BPV running tools and equipment. 7/30/2008 00:00 - 00:15 0.25 WHSUR P POST SAFETY MEETING. Discuss hazards and mitigations for pumping N2 to purge reel. 00:15 - 02:20 2.08 WHSUR P POST Pump remaining fresh water + inhibitor + McOH then purge with N2. Allow pressure to bleed off reel. 02:20 - 03:20 1.00 WHSUR P POST Break off well, break off BHA and cut off CTC. Cut off 10 ft of CT, install grapple connector. 03:20 - 04:00 0.67 WHSUR P POST Pull CT across pipe shed roof and onto reel. Secure it to reel. 04:00 - 05:10 1.17 RIGD P POST Prepare to place reel onto truck. Remove 1502 pump line. 05:10 - 05:25 0.25 RIGD P POST SAFETY MEETING. Discuss hazards and crew placements for lowering reel. 05:25 - 07:00 1.58 RIGD P POST Lower reel onto trailer and secure it. N/D BOPs, install tree cap. Pressure test tree cap. RELEASED RIG AT 0700 HRS. 07/30/2008. TOTAL TIME OF 12 DAYS, 22-1/2 HOURS ON THE DS 13-30C W ELL. RIG ON STANDBY WAITING ON DOYON 14 RIG MOVE AND RIG MATS TO GET OFF THE DS 13 LOCATION. ALL FUTURE RIG INFORMATION WILL BE IN DIMS UNDER WELL: P1-24L1 Printed 8/25/2008 2:09:16 PM ~ ~ BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/17/2008 End: 7/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/30/2008 .Rig Name: NORDIC 1 Rig Number: ~ Date From - To Hours Task Code NPT Phase ~ Description of Operations 7/30/2008 05:25 - 07:00 1.58 RIGD P POST ALL RIG MOVE AND STANDBY RIG COSTS WILL BE BILLED TO P1-24L1. BP Alaska ~ ~~ by Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco - - -~ Date: 7/28/2008 Time: 10:15:1$ Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 13-30, True North Site: PB DS 13 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5. Well: fi3-30 Section (VS) Reference: Well (O.OON,O.OOE,231.33Azi) ~ Wellpath: 13-30B --- - -- - Survey Calculation. Method: _ _ __ Minimum Curvature Db: Oracle ~i _ _ __ _ - -, Field: Prudhoe Bay I i North Slope i 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 Modcl: bggm2007 Site; PB DS 13 TR-10-14 UNITED STATES :North Slope i i , Site Position: Northing: 5932645.45 ft Latitude: 70 13 15.444 N From: Map Easting: 685828.44 ft Longitude: 148 30 2.303 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.41 deg _ ~ Well: 13-30 Slot Name: 30 13-30 Well Position: +N/-S -622.68 ft Northing: 5932019.57 ft Latitude: 70 13 9.320 N +E/-W -138.96 ft Easting : 685704.86 ft Longitude: 148 30 6.339 W Position Uncertainty: 0.00 ft ~ Wellpath: 13-30B Drilled From: 13-30A 500292076802 Tie-on Depth: 9622.99 ft Current Datum: 2ES @ 46+28.5 Height 74.50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/6/2008 Declination: 23.41 deg Field Strength: 57671 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft 50 0 00 28 ft 0 00 deg 231 33 . . - - - __ . . Survey Program for Definitive Wellpath Date: 7/22/2008 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 87.50 7987.50 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 7990.00 9622.99 13-30A IIFR (7990.00-10708.26) MWD+IFR+MS MWD +IFR + Multi Station 9634.60 11703.00 MWD (9634.60 11703.00) MWD MWD -Standard Annotation MD 1'VD ft ft 9622.99 8890.77 TIP 9634.60 8899.33 KOP 11703.00 8999.87 TD Survey: MWD Start Date: 7/22/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path BP Alaska by Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 7/28/2008 Time: 10:15:18 Pager 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well 13-30, True North .Site: PB DS 13 Vertical (T'VD) Reference: 2ES @ 46+28.5 74.5 We1L 13-30 Section (VS) Reference: Well (t).OON,O.p0E,231.33Azi) Wellpath: 13-30B Survey Calculation Method: Minimum Curvature Db: Oracle_ Survey MD ft 9622.99 9634.60 9664.38 9694.84 9724.64 9755.28 9787.58 9822.02 9855.25 9887.89 9918.61 9951.15 9983.69 10014.49 10048.50 10080.70 10109.34 10139.68 10171.63 10203.06 10235.86 10271.58 10302.09 10332.69 10363.17 10396.45 10428.47 10468.67 10499.03 10530.23 10560.15 10589.17 10623.29 10663.09 10693.83 10725.57 10755.85 10785.15 10815.21 10843.67 10880.78 10910.94 10949.80 10980.88 11003.44 11038.20 11079.24 11112.28 11142.48 11174.10 11198.88 11227.22 11260.56 [ncl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS "1'001 deg deg ft ft ft ft ft ft ft deg/100ft 41.52 212.68 8890.77 43.59 212.28 8899.33 46.57 211.38 8920.35 53.41 210.45 8939.92 59.71 209.55 8956.34 65.72 208.62 8970.38 71.41 207.64 8982.18 77.10 206.59 8991.52 84.93 203.12 8996.71 88.74 201.22 8998.51 90.49 201.70 8998.71 90.03 201.75 8998.57 89.45 201.43 8998.71 89.57 201.04 8998.98 89.36 200.26 8999.30 88.74 199.25 8999.83 89.42 198.54 9000.29 89.75 197.83 9000.51 90.18 197.22 9000.53 89.75 196.39 9000.55 90.49 195.86 9000.48 90.09 195.20 9000.30 90.65 194.71 9000.10 89.97 195.55 8999.94 89.72 196.22 9000.02 89.66 196.34 9000.20 88.65 197.05 9000.67 88.89 197.33 9001.53 88.92 197.61 9002.11 88.43 197.54 9002.83 88.06 197.75 9003.75 88.00 197.12 9004.75 88.09 197.17 9005.91 88.55 198.52 9007.08 88.89 200.04 9007.77 89.17 201.69 9008.30 89.20 202.96 9008.73 89.42 205.33 9009.09 89.36 205.89 9009.41 89.97 205.62 9009.57 89.60 205.81 9009.71 88.87 207.33 9010.12 89.63 212.37 9010.62 90.12 215.89 9010.69 89.82 218.54 9010.70 90.25 222.68 9010.68 88.07 226.62 9011.29 89.48 232.41 9011.99 88.59 236.66 9012.50 86.38 240.13 9013.89 85.22 243.32 9015.70 87.15 246.56 9017.59 92.91 247.20 9017.57 8816.27 -1446.47 8824.83 -1453.09 8845.85 -1471.00 8865.42 -1491.01 8881.84 -1512.54 8895.88 -1536.33 8907.68 -1562.83 8917.02 -1592.33 8922.21 -1622.09 8924.01 -1652.26 8924.21 -1680.85 8924.07 -1711.08 8924.21 -1741.33 8924.48 -1770.04 8924.80 -1801.87 8925.33 -1832.17 8925.79 -1859.26 8926.01 -1888.08 8926.03 -1918.55 8926.05 -1948.64 8925.98 -1980.15 8925.80 -2014.56 8925.60 -2044.04 8925.44 -2073.57 8925.52 -2102.89 8925.70 -2134.84 8926.17 -2165.50 8927.03 -2203.90 8927.61 -2232.85 8928.33 -2262.59 8929.25 -2291.09 8930.25 -2318.76 8931.41 -2351.34 8932.58 -2389.21 8933.27 -2418.22 8933.80 -2447.87 8934.23 -2475.88 8934.59 -2502.61 8934.91 -2529.71 8935.07 -2555.35 8935.21 -2588.78 8935.62 -2615.75 8936.12 -2649.44 8936.19 -2675.17 8936.20 -2693.13 8936.18 -2719.51 8936.79 -2748.70 8937.49 -2770.14 8938.00 -2787.65 8939.39 -2804.20 8941.20 -2815.91 8943.09 -2827.88 8943.07 -2840.97 -2506.29 -2510.51 -2521.62 -2533.59 -2546.02 -2559.24 -2573.41 -2588.50 -2602.28 -2614.57 -2625.81 -2637.85 -2649.83 -2660.98 -2672.98 -2683.86 -2693.13 -2702.60 -2712.22 -2721.31 -2730.42 -2739.98 -2747.85 -2755.84 -2764.18 -2773.51 -2782.71 -2794.59 -2803.70 -2813.12 -2822.18 -2830.87 -2840.93 -2853.12 -2863.26 -2874.57 -2886.07 -2898.05 -2911.04 -2923.41 -2939.51 -2953.00 -2972.33 -2989.77 -3003.41 -3026.03 -3054.86 -3079.98 -3104.56 -3131.46 -3153.22 -3178.83 -3209.48 5930511.97 683235.07 5930505.25 683231.02 5930487.06 683220.35 5930466.77 683208.87 5930444.94 683196.98 5930420.84 683184.35 5930393.99 683170.84 5930364.14 683156.47 5930334.05 683143.44 5930303.59 683131.89 5930274.73 683121.36 5930244.22 683110.06 5930213.68 683098.84 5930184.71 683088.39 5930152.60 683077.19 5930122.04 683067.06 5930094.73 683058.45 5930065.68 683049.70 5930034.99 683040.83 5930004.69 683032.49 5929972.97 683024.15 5929938.33 683015.44 5929908.67 683008.30 5929878.95 683001.04 5929849.44 682993.42 5929817.28 682984.88 5929786.39 682976.44 5929747.72 682965.51 5929718.55 682957.12 5929688.60 682948.43 5929659.89 682940.07 5929632.01 682932.07 5929599.19 682922.82 5929561.04 682911.56 5929531.79 682902.13 5929501.87 682891.57 5929473.59 682880.76 5929446.57 682869.44 5929419.16 682857.12 5929393.23 682845.38 5929359.41 682830.11 5929332.12 682817.29 5929297.96 682798.79 5929271.82 682782.00 5929253.53 682768.80 5929226.60 682746.84 5929196.71 682718.74 5929174.67 682694.16 5929156.55 682670.01 5929139.35 682643.53 5929127.11 682622.06 5929114.51 .682596.76 5929100.67 682566.44 2860.58 0.00 MWD 2868.01 17.95 MWD 2887.88 10.24 MWD 2909.73 22.58 MWD 2932.88 21.29 MWD 2958.07 19.80 MWD 2985.69 17.84 MWD 3015.91 16.78 MWD 3045.26 25.72 MWD 3073.71 13.04 MWD 3100.35 5.91 MWD 3128.64 1.42 MWD 3156.90 2.04 MWD 3183.55 1.32 MWD 3212.79 2.38 MWD 3240.22 3.68 MWD 3264.39 3.43 MWD 3289.80 2.58 MWD 3316.35 2.34 MWD 3342.24 2.97 MWD 3369.04 2.78 MWD 3398.02 2.16 MWD 3422.58 2.44 MWD 3447.28 3.53 MWD 3472.11 2.35 MWD 3499.35 0.40 MWD 3525.70 3.86 MWD 3558.96 0.92 MWD 3584.17 0.93 MWD 3610.11 1.59 MWD 3634.99 1.42 MWD 3659.07 2.18 MWD 3687.28 0.30 MWD 3720.46 3.58 MWD 3746.51 5.07 MWD 3773.86 5.27 MWD 3800.34 4.19 MWD 3826.40 8.12 MWD 3853.48 1.87 MWD 3879:15 2.34 MWD 3912.62 1.12 MWD 3940.00 5.59 MWD 3976.15 13.12 MWD 4005.83 11.43 MWD 4027.71 11.82 MWD 4061.86 11.97 MWD 4102.60 10.97 MWD 4135.61 18.03 MWD 4165.75 14.38 MWD 4197.09 13.00 MWD 4221.39 13.67 MWD 4248.87 13.29 MWD 4280.98 17.38 MWD BP Alaska ~ ; by Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Field:. Prudhoe Bay Date: 7/28/2008 Co-ordinate(NE) Reference: Time: 10 15:18 Page: Well 13-30, True North 3- Site: PB DS 13 Vertical (TVD) Reference: 2ES @ 46+28.5 74,5 Well: 13-30 Section (VS) Reference: Well (O.OON,O.OOE,231.33Aai) Wellpath: 13-306 Survey Calculation Method: . Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft degl100ft 11295.92 95.75 252.62 9014.90 8940.40 -2853.08 -3242.58 5929087.76 682533.65 4314.38 17.26 MWD 11328.96 92.73 254.52 9012.46 8937.96 -2862.39 -3274.18 5929077.66 682502.30 4344.87 10.79 MWD 11363.83 91.66 258.80 9011.12 8936.62 -2870.43 -3308.08 5929068.80 682468.61 4376.36 12.64 MWD 11399.37 90.49 263.77 9010.46 8935.96 -2875.81 -3343.19 5929062.55 682433.64 4407.14 14.36 MWD 11427.43 87.58 266.04 9010.93 8936.43 -2878.30 -3371.13 5929059.37 682405.77 4430.51 13.15 MWD 11458.29 85.37 268.38 9012.83 8938.33 -2879.80 -3401.89 5929057.12 682375.06 4455.46 10.42 MWD 11488.49 87.86 267.76 9014.61 8940.11 -2880.82 -3432.02 5929055.36 682344.97 4479.61 8.50 MWD 11520.15 90.86 266.67 9014.96 8940.46 -2882.36 -3463.63 5929053.05 682313.40 4505.26 10.08 MWD 11556.79 93.89 264.88 9013.44 8938.94 -2885.05 -3500.14 5929049.45 682276.98 4535.44 9.60 MWD 11586.31 95.28 261.78 9011.08 8936.58 -2888.47 -3529.36 5929045.32 682247.85 4560.39 11.48 MWD 11616.81 95.80 258.49 9008.14 8933.64 -2893.67 -3559.26 5929039.38 682218.09 4586.99 10.87 MWD 11656.79 95.41 254.47 9004.23 8929.73 -2902.97 -3597.94 5929029.14 682179.65 4623.00 10.05 MWD 11703.00 95.41 254.47 8999.87 8925.37 -2915.29 -3642.26 5929015.73 682135.65 4665.30 0.00 MWD FLLF~AD'- GRAY ~ 13 3 0 C ~TUATOR = AXELSON j~E EV = 8T ~. ELEV = 25.1' " DRLG DRAFT ~xAngle= 117.9 DEG itum MD = 9404' ~tum TV D = 8800' SS t 3-3/8" CSG, 72#, L-80, 0 = 12.34T' I~ 2608' Minimum ID = 2.30" a~ 9460' AL Profile in Deploy Slv SAFETY NOTES: 4-1f2" CHROME TBG 2226' I~ 41 /2" X NP, ID = 3.813" (,A S 1 lFT MA NI~RFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3003 3002 7 MMG-M DOME RK 16 08/01!08 4 3869 3828 26 MvICrM SO RK 20 08/01/08 3 5741 5516 27 NMG-M OMY RK 0 12/06/03 2 7070 6707 25 MMG-M DMY RK 0 12!06/03 1 7601 7191 23 MMG-M DMY RK 0 11 /24/03 7830' ~~ 9-5/8" X 7" BAKER HGR / PKR 9-518" CSG, 47#, L-80, ID = 8.681 " 41/2" TIEBACK SLV'--~ 9455' 41/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" -~ 4112" WLEG, O = 3.958" 9459' 7" X 5" LNR HGR 9466' 7" LNR, 26#, L-80 BTGM, .0383bof. ID = 6.276" 9590' 141/2" MECHANICAL WHIPSTOCK ~ 9620' 41 /2" MECHA NICA L WHIPSTOCK 9628' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9980 - 10602 O 07!28/08 2" 6 10815 - 11100 O 07/28/08 2" 6 11225 - 11850 O 07/28/08 2" 6 11900 - 12180 O 07/28/08 I 41/2" SLTD LNR, 12.6#, .0152 bpf, ID = 3.958" 3-1 /2" X 3-3/16" X 2-7/8" SOLID LNR 12183' 13-306, WET ZONE 4, P8A'd w /CEMENT DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNR 07!21182 ORIGINAL COMPLETION WELL: 13-30C 11127/U3 JLGlTLP PROPOSED 2E5 SIDETRACK PERMfT No: 82080870 12/06/03 RMWTLP GLV GO API No: 50-029-20768-03 07/30!08 RRW CTD HORQONTAL SIDETRACK SEC 14, T10N, R14E, 3882.14' FEL 8 4347.07' FN 08/03/08 KSB/PJC GLV GO (08/01 /08} RP Fxnlnrafinn (eUcka- TOP OF 9-5/8" WINDOW 7992' ~ 9382' H 41 /2" X NIP, ID = 3.813" ' 9402' 41 /2" X 7" BAKER S-3 PKR 9426' 4112" X NIP, ID=3.813" 9447' 41/2" XN NIP, ID=3.725" 9447' BTT KB LT PKR 3-112" X NIP, ID = 2.813" 3-112" X 3-3116" XO, ID I3-3/16" X 2-7/8" XO, ID = I • N.~~ BAKER IIIIti11ES C 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: August 08, 2008 Please find enclosed directional survey data for the following wells: 13-30B p't t1 ~ - ~ ~ 13-30C Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~~~ ~~ ,State of Alaska AOGCC DATE: ~ Z (~, aZ~ $ Cc: State of Alaska, AOGCC ~ ~ ~ ~ >~ Q SARAH PALIN, GOVERNOR ALA51~iA OIL A1~TD GA5 333 W. 7th AVENUE, SUITE 100 C01~5ERQATIOrIT COl-IIrII55IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-30B Sundry Number: 308-255 Dear McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager}. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / ~ Chair DATED this2o day of July, 2008 Encl. STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Cob ti 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 208-078- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20768-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-30B - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028314 74.5 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): 11704 8925 11704 8925 N/A N/A Casin Len th Size MD TVD Burst Colla se Structural C nductor 80' 20" 8 ' 80' 1490 470 Surface 2608' 13-3/8" 2608' 2608' 4930 2670 Intermediate 7990' 9-5/8" 7990' 7551' 6870 4750 Production Liner 732' 7" 7830" - 9590' 7402' - 8866' 7240 5410 Liner 1298' 4-1/2" 9455' - 9628' 8762' - 8895' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4-1/2", 12.6# 13Cr80 9459' Packers and SSSV Type: 7" x 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft): 9403' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: July 17, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: 7/17/2008 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: Cathy Foerster 18. I hereby certify that the going is true and correct to the best of my knowledge. Contact Greg Sarber, 564-4330 Printed Name Joh i 8 Title Engineering Team Leader / `~ /~} ~ Prepared By Name/Number. Signature Phone 564-4711 Date `-' Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: , Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other. Subsequent Form Required: ~D~ ~~~ A roved B COMMISSIONER THE OMMISSION Date `` Form 10-403 Revised'0~l2006 -~~dt ~~~~~ Submit In Duplicate Question about permitting 13-30C Page 1 of 2 . i ~- McMullen, John C From: Maunder, Thomas E (DOA) [tom.maunderC~lalaska.gov] Sent: Thursday, July 17, 2008 8:37 AM To: McMullen, John C Cc: Sarber, Greg J Subject: RE: Request verbal Sundry Approval--13-306 (208-078) John and Greg, Looks like the contingency came into play. I have spoken with Commissioner Foerster and apprised her of your request. She has given her oral approval for you to proceed with the planned plugging of 13-306. We will look forward to receiving the 403 later today. Call or message with any questions. Tom Maunder, PE AOGCC From: McMullen, John C [mailto:McMuIIJC@BP.com] Sent: Thursday, July 17, 2008 7:16 AM To: Maunder, Thomas E (DOA) Cc: Sarber, Greg J Subject: Request verbal Sundry Approval Tom - Nordic 1 is currently on well 13-30B (PTD #2080780). We have drilled from a window depth of 9635' MD to a TD of 11,703' MD. We have chosen not to complete this Ivishak target due to insufficient pay, and we will instead drill our contingent Sag target 13-30C (PTD #2080870). Plans are to drill the Sag target via the same window at 9635'. AOGCC approval is requested this morning to plug the Ivishak target by setting an IBP at 9840' MD and laying in cement from the IBP to the window. We will follow-up with the 10-403 paperwork later today and attach your reply to this a-mail. Thanks, John McMullen 529-9129 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 20, 2008 3:35 PM To: Sarber, Greg ] Subject: RE: Question about permitting 13-30C Greg, Needing to have a contingency well permitted has happened before. Oral approval on the abandonment can be handled fairly easily. You will need to send me some plan description via email so I can inform the Commissioners. With regard to the possible 13-30C, it makes sense to go ahead and permit the well so that timely part of the process can be completed prior to a potential spud. If you don't need 13-30C, it can be cancelled. Call or message with any other questions. Tom Maunder, PE AOGCC 7/17/2008 Question about permitting 13-30C Page 2 of 2 • From: Sarber, Greg J [mailto:SarberJG@BP.com] Sent: Tuesday, May 20, 2008 3:17 PM To: Maunder, Thomas E (DOA) Subject: Question about permitting 13-30C Tom, I have a question for you. I am currently planning a horizontal CTD sidetrack of well 13-30A. The AOGCC has issued a sundry to abandon the 13-30A perforations and a permit to drill 13-306. The "B" lateral is an Ivishak zone 4 sidetrack targeting an unswept area of the reservoir that is assumped to be isolated by a fault. There is a possibility that when the "B" lateral is drilled, the formation will be found to have been swept by water flood, with no recoverable reserves. BP has developed an alternate sidetrack candidate, well 13-30C targeting the Sag River formation. This candidate lateral would be more than 500' away from 13-30B and in a different horizon. A PTD would certainly be needed for sidetrack 13-30C. 13-30C has not had a PTD application submitted yet. Ideally, if the "B" lateral is wet, the rig would abandon it, and proceed immediately to setting a whipstock and drilling the "C" lateral. To make most efficient use of the rig, it would be best to have continuous operations without having to put the rig on standby or move off the well while a sundry and PTD are obtained. My question for you is how is this best handled? If the B lateral is found wet, would BP need a sundry to abandon the uneconomic 13-306 lateral? Could the sundry be obtained verbally, then the paperwork submitted. Should BP apply for a PTD well 13-30C, even though it may not be drilled? I can call and discuss on the phone if needed. Cheers, Greg Ph: (907) 564-4330 Cell: (907) 242-8000 Email: sarberjg C~ bp.com 7/17/2008 TREE = GRAY GEN 2 WELL•HEArs= GRAY ACTUATOR = AXELSON KB. ELEV = 87' BF. ELEV = 25.1' KOP = 7992' Max Angle = 94.6' Datum MD = 9404' Datum ND = 8800' SS 13-30B Plugging Proposal 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2608' Minimum ID = SAFETY NOTES: 4-112" CHROME TBG 2226' I~I4-1/2" X NIP, ID = 3.813" GA S LIFT MANDRELS ST NO TVD DEV TYPE VLV LATCH PORT DATE 5 3002 3001 9 MMG-M DMY RK - 12/06/03 4 3869 3827 23 MMGM DOME RK 16 12/06/03 3 5741 5515 27 MMG-M DOME RK 16 12/06/03 2 7070 6706 25 MMG-M S/O RK 24 12/06/03 1 7600 7190 23 MMG-M DMY RK - 11/24/03 19-5/8" X 7" BAKER HGR / PKR 1 14-1 /2" X NIP, ID=3.813" I 9426' 4112" XN N~, ID milled to =3.80" 9447' TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 9458' 7" LNR, 26#, L-80 AAOD-BTC TOP OF 9-5/8" VIANDOW 7992' 9382' H41l2" X NIP, O = 3.813" 940Z' I~41/2" X T' BAKER S-3 PKR Proposed cement from IBP to window r i /Proposed IBP 9840` MD 13-30B TD @ 11703` MD; ` ~ 9,635' Mechanical Whipstock X8925' SSTVD) 1 I I I li t I' 1' II 4-112" SLTD LNR, 12.6#, .0152 bpf, ID = 3.958" 10753' ~ _ - -_-~~ 3-30A DATE REV BY COMMENTS DATE REV BY COMMENTS 07/21/82 ORIGINAL COMPLETION 11/27103 JLGlTLP 2ES SIDETRACK 12/06/03 RMHJTLP GLV C/O 04/17/08 MSE PROPOSED CTD SIDETRACK PRUDHOE BAY UNfr WELL: 13-306 PERMfT No: API No: 50-029-20768-02 SEC 14, T10N, R14E, 3882.14' FEL &4347.07' FNL BP Exploration (Alaska) 9-5/8" CSG, 47#, L-80, ID = 8.681 " H 7992' PERFORATION SUMMARY REF LOG: BHCS ON 07/18/82 A NGLE A T TOP PERF: 20 ~ 9408' Note: Refer to Production DB for h~torical pert data SQE SPF INTERVAL OpnlSgz DATE SLID LNR 9602 - 9885 isolated proposed SLTD LNR 10174 - 10712 isolated proposed Question about permitting 13-~C • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 17, 2008 8:37 AM To: 'McMullen, John C' ~~ Cc; Sarber, Greg J Subject: RE: Request verbal Sundry Approval--13-306 (208-078) John and Greg, Looks like the contingency came into play. I have spoken with Commissioner Foerster and apprised her of your request. She has given her oral approval for you to proceed with the planned plugging of 13-30B. We will look forward to receiving the 403 later today. Call or message with any questions. Tom Maunder, PE AOGCC From: McMullen, John C [mailto:McMuIIJC@BP.com] Sent: Thursday, July 17, 2008 7:16 AM To: Maunder, Thomas E (DOA) Cc: Sarber, Greg J Subject: Request verbal Sundry Approval Tom - Nordic 1 is currently on well 13-30B (PTD #2080780). We have drilled from a window depth of 9635' MD to a TD of 11,703' MD. We have chosen not to complete this Ivishak target due to insufficient pay, and we will instead drill our contingent Sag target 13-30C (PTD #2080870). Plans are to drill the Sag target via the same window at 9635'. AOGCC approval is requested this morning to plug the Ivishak target by setting an IBP at 9840' MD and laying in cement from the IBP to the window. We will follow-up with the 10-403 paperwork later today and attach your reply to this a-mail. Thanks, John McMullen 529-9129 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 20, 2008 3:35 PM To: Sarber, Greg J Subject: RE: Question about permitting 13-30C Greg, Needing to have a contingency well permitted has happened before. Oral approval on the abandonment can be handled fairly easily. You will need to send me some plan description via email so I can inform the Commissioners. With regard to the possible 13-30C, it makes sense to go ahead and permit the well so that timely part of the process can be completed prior to a potential spud. If you don't need 13-30C, it can be cancelled. Call or message with any other questions. Tom Maunder, PE AOGCC 7/17/2008 Question about permitting 13-3 C Page 2 of 2 From: Sarber, Greg ] [mailto:SarberJG@BP.com] Sent: Tuesday, May 20, 2008 3:17 PM To: Maunder, Thomas E (DOA) Subject: Question about permitting 13-30C Tom, I have a question for you. I am currently planning a horizontal CTD sidetrack of well 13-30A. The AOGCC has issued a sundry to abandon the 13-30A perforations and a permit to drill 13-30B. The "B" lateral is an Ivishak zone 4 sidetrack targeting an unswept area of the reservoir that is assumped to be isolated by a fault. There is a possibility that when the "B" lateral is drilled, the formation will be found to have been swept by water flood, with no recoverable reserves. BP has developed an alternate sidetrack candidate, well 13-30C targeting the Sag River formation. This candidate lateral would be more than 500' away from 13-30B and in a different horizon. A PTD would certainly be needed for sidetrack 13-30C. 13-30C has not had a PTD application submitted yet. Ideally, if the "B" lateral is wet, the rig would abandon it, and proceed immediately to setting a whipstock and drilling the "C" lateral. To make most efficient use of the rig, it would be best to have continuous operations without having to put the rig on standby or move off the well while a sundry and PTD are obtained. My question for you is how is this best handled? If the B lateral is found wet, would BP need a sundry to abandon the uneconomic 13-30B lateral? Could the sundry be obtained verbally, then the paperwork submitted. Should BP apply for a PTD well 13-30C, even though it may not be drilled? I can call and discuss on the phone if needed. Cheers, Greg Ph: (907) 564-4330 Celt: (907) 242-8000 Email: sarberjg@bp.com 7/i 7/2008 •_ ~:~ ~ ~ ~~ ~ SARAH PALIN, GOVERNOR ~~ COlSSL1R~~ n ~ I ~ 333 W. 7th AVENUE, SUITE 100 ~7~! ~ii a.o•••~~•~auit~~'~~~i-7 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Sarber CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-30B BP Exploration Alaska Inc. Permit No: 208-078 Surface Location: 1990' FSL, 1511' FEL, SEC. 14, T10N, R14E, UM Bottomhole Location: 4265' FSL, 1076' FEL, SEC. 22, T10N, R14E, UM Dear Mr. Sarber: 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 iri 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). Sincerel Daniel T. Seamount, Jr. ~~ Chair DATED this ~ day of May, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA-~ ALASl~IL AND GAS CONSERVATION COMMI~N~! PERMIT TO DRILL 6~-S' ~ 20 AAC 25.005 MAY 0 5 200$ li~I ~.~ uas Cons. Commission ~nchoraoe 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 13-308 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13000 TVD 8992 ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1990' FS 1 11' FEL 1 T1 N R14E UM SEC 7. Property Designation: ADL 028314 Pool , , , L, 5 . 4, 0 Top of Productive Horizon: 469' FSL, 4061' FEL, SEC. 14, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 21, 2008 Total Depth: 4265' FSL, 1076' FEL, SEC. 22, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18530' 4b. Location of Well (State Base Plane Coordinates): Surface: x-685705 y-5932020 Zone-ASP4 10. KB Elevation (Height above GL): 74.5 feet 15. Distance to Nearest Well within Pool: 500' 16. Deviated Wells: Kickoff Depth: 9700 feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3345 Surface: 2465 18 Casin P -ram: bo ns ` To - Settin h - m tianti f n ` .f. r sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" s-~iz~~ X z-~ia~~ a.a~# X s.,sa 13Cr STL 3565' 9435' 8747' 13000' 8992' ss 198 x Class ' ' ~ g, PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10753 Total Depth TVD (ft): 8880 Plugs (measured): N/A Effective Depth MD (ft): 10753 Effective Depth TVD (ft): 8980 Junk (measured): N/A asing _ -Length Size emenYVo ume D D Conductor /Structural 20" 1 P I 0' 80' Surface 2608' 13-3/8" 2854 sx Fondu 400 sx PF 'C' 2608' 2608' Intermediate 7 90' 9-5/8" 500 sx Class'G' 300 sx PF'C' 7990' 7551' r in Liner 732' 7" 300 sx Class 'G' 7830" - 9590' 7402' - 8866' Liner 1298' 4-1/2" Uncem nted Slotted Liner 9455' - 10753' 8762' - 8980' Perforation Depth MD (ft): Slotted 9602' - 10712' Perforation Depth TVD (ft): Slotted 8875' - 8983' 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 Greg Sarber, 564-4330 Printed Nam Greg Sa er Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ ~ ~ Phone 564-4330 . Date Sondra Stewman, 564-4750 Commission Use Onl Permit To Drill Number:o?D~O~ API Number: 50-029-20768-02-00 Permit A rov I Date: ' D~ See cover letter for other re uirements 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 IJ No ,ry ` HZS Measures: Yes ^ No Directional Survey Req'd: pp Yes ^ No Other: ' J~'~ l.1 ,~,° ~ ~~+1 ~~'*` ~~ APPROVED BY THE COMMISSION ~' O ~ Date ,COMMISSIONER Form 16-401 Revised 12/2005 ~ ~ j i ~ 9 ".... ~ ~ ' ! u'1 Submit In Duplicate by BPXA Prudhoe Bay 13-306 CTD Sidetrack May 2, 2008 CTD Sidetrack Summary Pre-CT Rig Work: (Scheduled to begin on May 17, 2008) 1. MIT-IA, -OA Done 2-27-2008 2. Dummy GLV's Done 2-11-2008 3. Drift thru WS setting depth (9600') with 3.7" drift for cement retainer. 4. Set HES composite cement retainer at 9540'. 5. Pump cement thru cement retainer to P&A slotted liner. (Minimum of 15 bbls) 6. Mill XN nipple at 9447' to 3.80" with left handed motor. 7. Mill cement retainer at 9540', and cement in 4-1/2" liner to 9750'. With conventional motor assembly. 8. Drift and tag with dummy whipstock. 9. Set Baker 4-1/2" monobore whipstock using SLB WPPT tool. Set top at 9,700', with high side orientation. 10. PPPOT-IC, -T; LDS 11. PT MV, SV, WV 12. Blind and bleed lines, remove well house, level pad. Rig Sidetrack Operations: (Scheduled to begin on June 21, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull BPV. 4. Mill 3.80" window at 9,700'. 5. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. 6. Drill lateral section to 13,000. 7. Run and cement a 3-1/2" x 2-7/8" L-80 liner string. 8. Make a cleanout run with mill and motor to PBTD in combination with a MCNL-GR-CCL tool. 9. Perforate well. 10. Circulate well to KWF brine. FP well to 2000' with diesel. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. `Hole size: 3.75" x 4.125" (bi-cen~its used) Casing Program: fully cemented liner • 3-1/2", 13Cr80 8.81# STL 9,435' and - 9,670' rnd • 2-7/8", 13Cr80 6.16# STL 9,670' and -13,000' and • A minimum of 41 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD @ 13,000', and planning on 40% excess in the open hole interval) • TOC planned at the top of liner 9,435' Existing casing/tubing Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 psi 7", L-80 26#, Burst 7240, collapse 5410 psi 4-1/2", L-80 12.6#, Burst 8430, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 92.0 deg at 9,808'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -18,530' to unit boundry to south. • Distance to nearest well within pool - 500 ft. (Well 13-12) Logging • MW D directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole MCNL/GR/CCL logs will be run. Hazards • The parent well is a very prolific (+6000 bpd) water producer. Isolation from the parent is critical. This may require multiple cement squeezes. • The window will be milling in slotted liner. This is an unusual technique for CTD, and may require dressing runs with a tapered crayola mill. • There are 2 planned fault crossings. If losses are encountered at the faults, the drilling fluid will be switched to seawater. • This TD is challenging from a weight on bit standpoint. There are 2 techniques that will assist in maintaining weight on bit. First a new motor will be tried on the will a Baker Hughes "Rib Steer" motor. This has never been attempted in this BHA size. This motor will allow drilling of straighter holes, requiring less dog legs. Reducing dog leg will allow better weight to the BHA. The Andergauge Agitator tool will also be used. Reservoir Pressure • The reservoir pressure on 13-30A was last recorded at 3,345 psi at 8,800' TVDSS in June 2007. (7.31 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,465 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble Page 1 of 1 • Maunder, Thomas E (DOA) From: Sarber, Greg J [SarberJG@BP.com] Sent: Tuesday, May 13, 2008 1:38 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 13-306 H2S Tom, I apologise for not including the H2S information in the PTD summary for well 13-30B. That was an oversite on my part. The information is as follows; Well Name H2S Level Date of Reading Closest SHL Well H2S Level Closest SHL Well H2S Level Closest BHL Well H2S Level Closest BHL Well H2S Level ix. Recorded H2S on Pad/Facility her Relevant H2S Data LS alarms from rigs, etc.) 13-29L1 5 1/31/2005 13-12 0 /14/2007 13-30A 160 /2/2008 13-13A 0 /312005 13-OS 00 /29/2002 DS 13 is s H2S site The parent well is 13-30A with an H2S concentration of 160 ppm as measured on Z-z-ZUO~. Cheers, Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 13, 2008 12:37 PM To: Sarber, Greg J Subject: DS 13-30B Greg, I am reviewing the permit application for this well. I don't find any information regarding H2S for the well or pad. Could you provide that? That is a piece of information that should always be included. Please pass on to your colleagues as well. Thanks, Tom Maunder, PE AOGCC 5/13/2008 TREE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR= AXELSON Proposed CTD Sidetrack V'JP#12 SAFETY NOTES: 4-112" CHROMETBG KB. ELEV = 87' BF. ELEV = 25.1' KOP = 7992' Max Angle = -94.5 2226' 4112" X NIP, O = 3.813' Datum MD = 9404' Datum ND = 8800' SS GAS LIFT MANDRELS Minimum ID = 19.5/8" CSG. 47i, L•80. ID = 8.681" I 13 ST MD ND OEV TYPE VLV LATCH PORT DATE 3002 3001 9 MMG-M DMY RK 12/06/03 4 3869 3827 23 MMG-M DOME RK 16 12106/03 3 5741 5515 27 MMG-M DOME RK 16 12/06/03 2 7070 6706 25 MMG-M S/O RK 24 12106!03 1 i600 7190 23 MMG-M DMY RK - 1124/03 7830' ~--~ 9-5/8"X7" BAKER HGR / PKR J-3/18" L-80 X 2-7l8" 13G cmXod and period 13000' TOP OF 9-S18" WINDOW 7992' 5416' -i80T KB LTP 0 of ComonULmor ~ y TIEBACK SLV H 9466' X 9670' H3-12 x 2-7/8 X-ovor PERF'ORATiON SUMMARY REF LOG: BRCS ON 07/18/82 ANGLE AT TOP PtRF 20 ~ 9408' Note: Refer to Roduction DB for historical pert data SIZE SPF INTB~1/AL OpnfSgz DATE SLTD LNR 9602 -9866 solaced proposed SLTD LNR 101 74 - 10712 isolated proposed 13 30B 3-112" x 2-7/8" 13G LNR cntd and perfd DATE REV BY COMMENTS DATE REV BY OOMMENTS 07M1182 ORIGINAL COMPLETION 11/27A3 JLGITLP 2E3 SIDETRACK 12106/03 RMH/TLP GLV GO 04/17/08 MSE PROPOSED CTD S~RACK PRUJHOE BAY UNIT W3L 13-308 PERMR No: AP No: 50-029.2076&02 SEC 14, T10N, R14~ 3882.14' FEL 8 4347.OT FNL BP P~cpbration (Alaska) ~ M Well 2.25 9.23 5.00 ~ 12.65 ~f ~ ~ 13.56 ~_ 2 1:16" 5000 psi , R-24 ~~• ® ~ 16.10 ~ 16.66 ~- t Ciiti X 5 'rl '/ariable Ram -:: 8" Cumbi Lubricator ID = 6.375" with 6" Otis Unions 1 -~ 7 1l16" 5000 psi RX-46 ~ ~- 7 1!16" X 3 1,'8" Flanged Adapter L 20.04 ~ ~ Swab Valve ~TAree Size ~.LLJSJ Flcw Tea FI -~ 22.88 p SSV 24.86 -----= ~~~ Master Valve 26.68 i Lock Down Screws 31.00 ~ Ground Level by BP Alaska Baker Hughes INTEQ Planning Report ri~~ INTEQ ~ Company: BP Amoco T Date: 4/30/2008 Timc: 13:58:26 - Page: l- Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 13-30, True North Site: PB DS 13 Vertical (TVD) Reference: 2E S ~a 46+28.5 74.5 Well: 13-30 Section (VS) Reference: WeII (O.OON,O.OOE,230.OOAzi) ~~ Wellpathr Plan 12, 13-.306 Survey Calculation Method: Minimum Curvature Db: Sybase 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: bggm2007 ~, Site: PB DS 13 TR-10-14 UNITED STATES :North Slope ~ Site Position: Northing: 5932645 .45 ft Latitude: 70 13 15.444 N ~i From: Map Easting: 685828 .44 ft Longitude: 148 30 2.303 W ~ Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.41 deg - II Well: 13-30 Slot Name: 30 13-30 Well Position: +N/-S -622.68 ft Northing: 5932019 .57 ft Latitude: 70 13 9.320 N +E/-W -138.96 ft Easting : 685704 .86 ft Longitude: 148 30 6.339 W Position Uncertainty: 0.00 ft ~Wellpath: Plan 12, 13-30B Drilled From: 13-30A 500292076802 Tie-on Depth: 9685.04 ft Current Datum: 2ES @ 46+28.5 Height 74 .50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/6/2008 Declination: 23.41 deg ~, Field Strength: 57671 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 230.00 ~ Plan: Plan 12 Date Composed: 3/6/2008 ~ copy Mary's plan 12 Version: 8 Principal: Yes Tied-to: From : Definitive Path Targets .Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +Ni-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ~ Dip. Dir. ft ft ft ' ft ft 13-306 Faultl 74.50 -413.03 -5307.96 5931476.10 680408.99 70 13 5.239 N 148 32 40.467 W ~i -Polygon 1 74.50 -413.03 -5307.96 5931476.10 680408.99 70 13 5.239 N 148 32 40.467 W -Polygon 2 74.50 -473.52 -4801.27 5931428.10 680916.99 70 13 4.648 N 148 32 25.753 W -Polygon 3 74.50 -633.45 -4522.10 5931275.10 681199.99 70 13 3.077 N 148 32 17.644 W ', -Polygon 4 74.50 -643.05 -4335.27 5931270.10 681386.99 70 13 2.983 N 148 32 12.219 W -Polygon 5 74.50 -684.71 -4024.18 5931236.10 681698.99 70 13 2.575 N 148 32 3.185 W II -Polygon 6 74.50 -710.90 -3732.72 5931217.10 681990.99 70 13 2.319 N 148 31 54.722 W -Polygon 7 74.50 -684.71 -4024.18 5931236.10 681698.99 70 13 2.575 N 148 32 3.185 W -Polygon 8 74.50 -643.05 -4335.27 5931270.10 681386.99 70 13 2.983 N 148 32 12.219 W -Polygon 9 74.50 -633.45 -4522.10 5931275.10 681199.99 70 13 3.077 N 148 32 17.644 W I, -Polygon l0 74.50 -473.52 -4801.27 5931428.10 680916.99 70 13 4.648 N 148 32 25.753 W ~ 13-306 Polygon 74.50 -1399.09 -3086.43 5930545.06 682653.97 70 12 55.554 N I 148 31 35.948 W -Polygonl 74.50 -1399.09 -3086.43 5930545.06 682653.97 70 12 55.554 N 148 31 35.948 W -Polygon 2 74.50 -2464.60 -3162.68 5929478.06 682603.97 70 12 45.074 N 148 31 38.149 W -Polygon 3 74.50 -2711.10 -3186.75 5929231.06 682585.97 70 12 42.649 N 148 31 38.845 W I -Polygon 4 74.50 -2777.44 -3661.55 5929153.06 682112.97 70 12 41.995 N 148 31 52.627 W -Polygon 5 74.50 -2865.13 -3878.79 5929060.06 681897.97 70 12 41.131 N 148 31 58.931 W ~ -Polygon 6 74.50 -2848.49 -4107.46 5929071.06 681668.97 70 12 41.294 N 148 32 5.569 W -Polygon 7 74.50 -2823.08 -4815.10 5929079.06 680960.97 70 12 41.540 N 148 32 26.111 W -Polygon 8 74.50 -2980.08 -4939.00 5928919.06 680840.97 70 12 39.995 N 148 32 29.705 W ~, -Polygon 9 74.50 -3071.78 -4871.24 5928829.06 680910.97 70 12 39.093 N 148 32 27.736 W -Polygon l0 74.50 -3098.43 -4113.62 5928821.06 681668.97 70 12 38.836 N 148 32 5.744 W -Polygon 11 74.50 -3065.08 -3883.71 5928860.06 681897.97 70 12 39.165 N 148 31 59.071 W 'I -Polygon l2 74.50 -3029.84 -3567.73 5928903.06 682212.97 70 12 39.513 N 148 31 49.900 W -Polygon l3 74.50 -3012.50 -3134.14 5928931.06 682645.97 70 12 39.685 N 148 31 37.314 W -Polygon l4 74.50 -2867.46 -2930.50 5929081.06 682845.97 70 12 41.113 N 148 31 31.405 W ~ -Polygon 15 74.50 -2573.43 -2805.22 5929378.06 682963.97 70 12 44.005 N 148 31 27.771 W by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P uvTEQ Company: BP Amoco Date: 4/30/2008 Time: 13:58:26' Page: 2 ~ Field: ~ Prudhoe Bay. Co-ordinate(NE) Reference: Well: 13-30, True North Site: PB DS 13 Vertical (TVD) Reference: 2ES Qa 46+28.5 74.5 Well: 13-30 Section(VS) Reference: Well (O.OON,O.OOE,230.OOAzi) ~ L Wellpath: Plan 12, i3-306 Survey Calculation Method: Minimum Curvature Db: Sybase Targets ! Map Map Name Description TVD +N/-S +E/-W Northing Easting I Dip. .Dir. ft ft ft ft ft _ -Polygon 16 ___ 74.50 -1558.61 -2417.11 5930402.06 683326.97 -Polygon 17 74.50 -1360.79 -2610.32 5930595.06 683128.97 13-30B Fault 2 74.50 -257.92 -4416.82 5931653.08 681295.99 -Polygon 1 74.50 -257.92 -4416.82 5931653.08 681295.99 -Polygon 2 74.50 -233.05 -3638.92 5931697.08 682072.99 -Polygon 3 74.50 -269.31 -2978.58 5931677.08 682733.99 -Polygon 4 74.50 -155.78 -2510.61 5931802.08 683198.99 -Polygon 5 74.50 -269.31 -2978.58 5931677.08 682733.99 -Polygon 6 74.50 -233.05 -3638.92 5931697.08 682072.99 13-30B Target 1 8960.50 -1571.73 -2575.50 5930385.05 683168.97 13-30B Target 2 8965.50 -2042.47 -2674.12 5929912.05 683081.96 13-30B Target3 8969.50 -2391.31 -2807.76 5929560.05 682956.95 13-306 Target4 8986.50 -2518.43 -2885.92 5929431.05 682881.95 13-306 Targets 9005.50 -2932.36 -3585.37 5929000.07 682192.94 13-306 Target6 9058.50 -3063.24 -4485.92 5928847.08 681295.94 13-30B Target? 9065.50 -2970.34 -4845.76 5928931.09 680933.94 Annotation r MD TVD ft ft 9685.04 8932.97 TIP 9700.00 8941.81 KOP 9720.00 8953.06 End of 9 Deg/100' DLS 9808.35 8976.55 End of 40 Deg/100' DLS 10058.35 8968.22 5 10278.35 8966.14 6 10428.35 8967.86 7 10653.35 8970.26 8 10763.35 8980.71 9 10841.10 8988.38 10 10891.10 8989.25 11 11141.10 8993.39 12 11531.10 9001.26 13 11711.10 9006.47 14 11791.10 9009.20 15 11891.10 9012.55 16 12141 10 9020 43 17 ~, . 12441.10 . 9045.85 18 I, 12601.10 9058.08 19 12826.10 9062.52 20 13000.00 0.00 TD <---- Latitude ----> <--- Longitude ---> Deg Min Sec Deg Min Sec 70 12 53.987 N 148 31 16.514 W 70 12 55.932 N 148 31 22.125 W 70 13 6.770 N 148 32 14.593 W 70 13 6.770 N 148 32 14.593 W 70 13 7.019 N 148 31 52.005 W 70 13 6.665 N 148 31 32.830 W 70 13 7.784 N 148 31 19.242 W 70 13 6.665 N 148 31 32.830 W 70 13 7.019 N 148 31 52.005 W 70 12 53.857 N 148 31 21.112 W 70 12 49.227 N 148 31 23.971 W 70 12 45.796 N 148 31 27.847 W 70 12 44.545 N 148 31 30.114 W 70 12 40.472 N 148 31 50.413 W 70 12 39.180 N 148 32 16.551 W 70 12 40.091 N 148 32 26.998 W ~~ Plan Section Information MD - incl Azim TVD.... +NJ-S +FJ-W ' DLS Build --- Turn --_ TFO Target ft deg deg ft fT ft deg/100ft deg/t00ft degl100ft deg 9685.04 52.68 210.83 8932.97 -1485.07 -2530.11 0.00 0.00 0.00 0.00 9700.00 54.86 208.45 8941.81 -1495.56 -2536.07 19.42 14.57 -15.91 317.92 i 9720.00 56.66 208.45 8953.06 -1510.09 -2543.95 9.00 9.00 0.00 0.00 li 9808.35 92.00 208.45 8976.55 -1583.71 -2583.84 40.00 40.00 0.00 0.00 10058.35 91.73 178.43 8968.22 -1823.96 -2641.25 12.00 -0.11 -12.01 270.00 !10278.35 89.33 204.73 8966.14 -2037.56 -2685.04 12.00 -1.09 11.95 95.00 10428.35 89.36 186.73 8967.86 -2181.34 -2725.53 12.00 0.02 -12.00 270.00 BP Alaska by Baker Hughes INTEQ Planning Report uvTEQ ~ t:ompany: BP Amoco Date: 4/30/2008 Time: 13.58:26 Page: 3 ~, Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 13-30, True North ` Site: PB DS 13 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5 Welt: 13-30 Section(VS)Reference: Well (O.OON,O.OOE,230.OOAzi) Wellpath: Plan 12, 13-30B Survey Calculation Method: Minimum Curvature Db: Sybase Plan Section Information N1D Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/100ft deg/100ft deg 10653.35 89.43 213.73 8970.26 -2390.51 -2802.61 12.00 0.03 12.00 90.00 ~I, 10763.35 79.67 204.79 8980.71 -2485.79 -2856.07 12.00 -8.88 -8.12 222.00 10841.10 89.00 204.79 8988.38 -2555.95 -2888.48 12.00 12.00 0.00 0.00 110891.10 89.01 198.79 8989.25 -2602.35 -2907.03 12.00 0.01 -12.00 270.00 ~ ~ 11141.10 89.14 228.80 8993.39 -2807.71 -3044.49 12.00 0.05 12.00 90.00 111531.10 88.68 275.60 9001.25 -2923.63 -3405.50 12.00 -0.12 12.00 91.00 ~, j11711.10 88.04 254.00 9006.47 -2939.82 -3583.62 12.00 -0.36 -12.00 268.00 I, 11791.10 88.07 263.61 9009.20 -2955.33 -3661.96 12.00 0.03 12.01 90.00 ~, 11891.10 88.11 251.60 9012.55 -2976.74 -3759.40 12.00 0.04 -12.01 270.00 '~ 12141.10 88.36 281.62 9020.43 -2991.34 -4006.00 12.00 0.10 12.01 90.00 ~, ~ 12441.10 82.23 246.00 9045.85 -3022.63 -4298.32 12.00 -2.04 -11.87 259.00 12601.10 89.07 264.00 9058.08 -3063.61 -4451.72 12.00 4.28 11.25 70.00 i~ 12826.10 88.72 291.01 9062.52 -3034.49 -4672.69 12.00 -0.16 12.00 91.00 j 13000.00 88.80 270.14 9066.33 -3002.78 -4842.66 12.00 0.05 -12.00 270.00 Survey MD inct Azim SS TVD N/S FJW MapN Mapl; DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 9700.00 54.86 208.45 8867.31 -1495 56 -2536.07 5930462.16 683206.50 19.42 2904.07 310.92 MWD' 9720.00 56.66 208.45 8878.56 -1510.09 -2543.95 5930447.44 683198.99 9.00 2919.45 360.00 MWD'! ~, 9725.00 58.66 208.45 8881.24 -1513.81 -2545.96 5930443.68 683197.07 40.00 2923.38 0.00 MWD'; 9734.71 62.54 208.45 8886.00 -1521.24 -2549.99 5930436.14 683193.22 40.00 2931.24 360.00 13-308 '1 9746.50 67.26 208.45 8891.00 -1530.63 -2555.08 5930426.64 683188.37 40.00 2941.17 0.00 13-306 it 9750.00 68.66 208.45 8892.31 -1533.48 -2556.62 5930423.75 683186.90 40.00 2944.19 0.00 MWDj ~i 9757.95 71.84 208.45 8895.00 -1540.06 -2560.19 5930417.08 683183.50 40.00 2951.15 0.00 13-308 9775.00 78.66 208.45 8899.34 -1554.55 -2568.04 5930402.41 683176.00 40.00 2966.48 360.00 MWD. 9800.00 88.66 208.45 8902.10 -1576.37 -2579.86 5930380.31 683164.72 40.00 2989.56 360.00 MWD1i 1 9808.35 92.00 208.45 8902.05 -1583.71 -2583.84 5930372.87 683160.93 40.00 2997.32 0.00 MWD 9825.00 92.00 206.45 8901.47 -1598.47 -2591.51 5930357.92 683153.62 12.00 3012.69 270.00 MWDi '1 9850.00 91.99 203.45 8900.60 -1621.12 -2602.04 5930335.02 683143.65 12.00 3035.32 269.93 MWD ~ 9875.00 91.98 200.45 8899.73 -1644.30 -2611.38 5930311.63 683134.88 12.00 3057.37 269.83 MWD 9900.00 91.96 197.45 8898.87 -1667.92 -2619.49 5930287.81 683127.36 12.00 3078.77 269.72 MWD 9925.00 91.94 194.44 8898.02 -1691.95 -2626.36 5930263.63 683121.09 12.00 3099.47 269.62 MWD 9950.00 91.91 191.44 8897.18 -1716.29 -2631.95 5930239.15 683116.09 12.00 3119.40 269.52 MWD 9975.00 91.88 188.44 8896.35 -1740.90 -2636.26 5930214.44 683112.39 12.00 3138.53 269.42 MWD 10000.00 91.84 185.44 8895.54 -1765.70 -2639.28 5930189.58 683109.98 12.00 3156.78 269.32 MWD' 10025.00 91.80 182.44 8894.74 -1790.63 -2641.00 5930164.62 683108.88 12.00 3174.12 269.22 MWD 10050.00 91.75 179.44 8893.97 -1815.61 -2641.41 5930139.63 683109.08 12.00 3190.49 269.12 MWD 10058.35 91.73 178.43 8893.72 -1823.96 -2641.25 5930131.30 683109.44 12.00 3195.73 269.03 MWD 10075.00 91.56 180.43 8893.24 -1840.60 -2641.09 5930114.67 683110.02 12.00 3206.30 95.00 MWD 10100.00 91.29 183.42 8892.62 -1865.57 -2641.93 5930089.68 683109.79 12.00 3223.00 95.06 MWD 10125.00 91.02 186.40 8892.11 -1890.47 -2644.06 5930064.73 683108.27 12.00 3240.64 95.13 MWD 10150.00 90.75 189.39 8891.73 -1915.23 -2647.50 5930039.90 683105.45 12.00 3259.19 95.19 MWD 10175.00 90.47 192.38 8891.46 -1939.78 -2652.22 5930015.25 683101.33 12.00 3278.58 95.24 MWD 10200.00 90.20 195.37 8891.31 -1964.04 -2658.21 5929990.84 683095.94 12.00 3298.77 95.27 MWD 10225.00 89.92 198.35 8891.29 -1987.97 -2665.46 5929966.75 683089.28 12.00 3319.70 95.29 MWD 10250.00 89.64 201.34 8891.38 -2011.48 -2673.95 5929943.04 683081.37 12.00 3341.32 95.29 MWD 10275.00 89.37 204.33 8891.60 -2034.52 -2683.65 5929919.77 683072.24 12.00 3363.56 95.28 MWD 10278.35 89.33 204.73 8891.64 -2037.56 -2685.04 5929916.69 683070.93 12.00 3366.58 95.25 MWD 10300.00 89.33 202.13 8891.89 -2057.42 -2693.65 5929896.62 683062.81 12.00 3385.94 270.00 MWD 10325.00 89.33 199.13 8892.18 -2080.82 -2702.45 5929873.02 683054.58 12.00 3407.72 270.03 MWD 10350.00 89.34 196.13 8892.47 -2104.64 -2710.02 5929849.02 683047.60 12.00 3428.84 270.07 MWD 10375.00 89.35 193.13 8892.76 -2128.82 -2716.34 5929824.69 683041.89 12.00 3449.22 270.10 MWD 10400.00 89.35 190.13 8893.04 -2153.31 -2721.38 5929800.09 683037.45 12.00 3468.81 270.13 MWD by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ __ - Company: BP Amoeo -- _ - Date -- _ - - 4/30/2008 -- -- Time: 13:58:26 -- - --- Page: - 4 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: 13-30, True North I ~ Site: PB DS 13 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5 Well: 13-30 ~ Section (VS) Reference: Well (O. OON,O.OOE,230.OOAzi) Wellpath: Plan 12, 13-30B Survey CalculationiVIethod:° Minimu m Curvat ure Db: Syb ase Survey NID Incl Azim SS TVD ~ N/S E/W " i17apN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100 ft ft deg i 10425.00 89.36 187 .13 8893 .32 2178 .02 2725.13 5929775.30 683034.31 12.00 3487.57 270.17 MWD 10428.35 89.36 186 .73 8893 .36 _ 2181 .34 _ 2725.53 5929771.96 683033.99 12.00 3490.02 270.20 MWD, 10450.00 89.37 189 .33 8893 .60 -2202 .78 -2728.55 5929750.46 683031.49 12.00 3506.11 90.00 MWDI 10475.00 89.37 192 .33 8893 .87 -2227 .33 -2733.25 5929725.81 683027.41 12.00 3525.49 89.97 MWD! 10500.00 89.37 195 .33 8894 .15 -2251 .60 -2739.22 5929701.40 683022.03 12.00 3545.67 89.94 MWD ', 10525.00 89.38 198 .33 8894 .42 -2275 .53 -2746.46 5929677.30 683015.39 12.00 3566.59 89.90 MWD! 10550.00 89.38 201 .33 8894 .69 -2299 .04 -2754.94 5929653.59 683007.49 12.00 3588.20 89.87 MWD' j 10575.00 89.39 204 .33 8894 .96 -2322 .08 -2764.63 5929630.32 682998.36 12.00 3610.43 89.84 MWD 10600.00 89.41 207 .33 8895 .22 -2344 .58 -2775.52 5929607.56 682988.03 12.00 3633.24 89.81 MWD 10625.00 89.42 210 .33 8895 .48 -2366 .48 -2787.57 5929585.37 682976.52 12.00 3656.55 89.78 MWD 10650.00 89.43 213 .33 8895 .73 -2387 .71 -2800.75 5929563.82 682963.87 12.00 3680.30 89.75 MWD 10653.35 89.43 213 .73 8895 .76 -2390 .51 -2802.61 5929560.98 682962.09 12.00 3683.51 89.72 MWD 10675.00 I~ 87.50 211 .99 8896 .34 -2408 .68 -2814.35 5929542.52 682950.80 12.00 3704.19 222.00 MWD 10700.00 85.28 209 .97 8897 .91 -2430 .07 -2827.19 5929520.83 682938.49 12.00 3727.77 222.05 MWD 10725.00 83.06 207 .95 8900 .46 -2451 .83 -2839.23 5929498.78 682926.99 12.00 3750.98 222.17 MWD 10750.00 80.85 205 .90 8903 .96 -2473 .90 -2850.44 5929476.44 682916.32 12.00 3773.75 222.38 MWD 10763.35 79.67 204. 79 8906 .21 -2485 .79 -2856.07 5929464.42 682910.99 12.00 3785.71 222.67 MWD 10775.00 81.07 204 .79 8908 .16 -2496 .22 -2860.89 5929453.88 682906.43 12.00 3796.10 0.00 MWD 10800.00 84.07 204. 79 8911 .40 -2518 .72 -2871.28 5929431.13 682896.59 12.00 3818.53 360.00 MWDI 10825.00 87.07 204. 79 8913 .33 -2541 .34 -2881.73 592940825 682886.70 12.00 3841.08 0.00 MWD 10841.10 89.00 204. 79 8913 .88 -2555 .95 -2888.48 5929393.49 682880.32 12.00 3855.64 0.00 MWD 10850.00 89.00 203. 73 8914 .04 -2564 .06 -2892.14 5929385.29 682876.86 12.00 3863.65 270.00 MWDI 10875.00 89.00 200. 72 8914 .47 -2587 .20 -2901.59 5929361.93 682867.98 12.00 3885.77 270.02 MWD! '~, 10891.10 89.01 198. 79 8914 .75 -2602 .35 -2907.03 5929346.65 682862.91 12.00 3899.67 270.07 MWD' 10900.00 89.01 199. 86 8914 .91 -2610 .75 -2909.98 5929338.18 682860.17 12.00 3907.33 90.00 MW D';i 10925.00 89.01 202. 86 8915 .34 -2634 .02 -2919.08 5929314.69 682851.65 12.00 3929.26 89.98 MWD; 10950.00 89.01 205. 86 8915 .77 -2656 .79 -2929.39 5929291.68 682841.90 12.00 3951.80 89.93 MWD; 10975.00 89.02 208. 86 8916 .20 -2678 .99 -2940.88 5929269.20 682830.96 12.00 3974.86 89.88 MWDI 11000.00 89.03 211. 86 8916 .63 -2700 .55 -2953.51 5929247.34 682818.86 12.00 3998.40 89.83 MWD ~ 11025.00 89.04 214. 86 8917 .05 -2721 .43 -2967.26 5929226.13 682805.64 12.00 4022.35 89.78 MWD ~ 11050.00 89.06 217. 86 8917 .46 -2741 .55 -2982.08 5929205.65 682791.32 12.00 4046.64 89.72 MWD 11075.00 89.08 220. 86 8917 .86 -2760 .88 -2997.93 5929185.94 682775.95 12.00 4071.20 89.68 MWD 11100.00 89.10 223. 86 8918 .26 -2779 .34 -3014.77 5929167.07 682759.57 12.00 4095.98 89.63 MWD' 11125.00 89.12 226. 86 8918 .65 -2796 .91 -3032.56 5929149.07 682742.22 12.00 4120.89 89.58 MWD 11141.10 89.14 228. 80 8918 .89 -2807 .71 -3044.49 5929137.98 682730.56 12.00 4136.97 89.53 MWD 11150.00 89.12 229. 87 8919 .03 -2813 .51 -3051.24 5929132.01 682723.95 12.00 4145.87 91.00 MWD I 11175.00 89.07 232. 86 8919 .43 -2829 .12 -3070.76 5929115.93 682704.82 12.00 4170.86 90.98 MWD II 11200.00 89.02 235. 87 8919 .84 -2843 .68 -3091.07 5929100.88 682684.87 12.00 4195.78 90.94 MWD 11225.00 88.98 238. 87 8920. 28 -2857 .16 -3112.12 5929086.89 682664.17 12.00 4220.57 90.89 MWD 11250.00 88.93 241. 87 8920. 73 -2869 .51 -3133.85 5929074.00 682642.75 12.00 4245.15 90.83 MWD 11275.00 88.90 244. 87 8921 .21 -2880 .72 -3156.19 5929062.25 682620.70 12.00 4269.47 90.78 MWD, 11300.00 88.86 247. 87 8921. 70 -2890 .74 -3179.08 5929051.67 682598.06 12.00 4293.45 90.72 MWD 11325.00 88.83 250. 87 8922. 20 -2899 .55 -3202.47 5929042.29 682574.89 12.00 4317.03 90.66 MWD ~ 11350.00 88.80 253. 87 8922. 72 -2907 .12 -3226.29 5929034.14 682551.27 12.00 4340.14 90.60 MWDI; 11375.00 88.77 256. 87 8923. 25 -2913. 43 -3250.47 5929027.23 682527.25 12.00 4362.72 90.54 MWD! 11400.00 88.75 259. 87 8923. 79 -2918. 47 -3274.95 5929021.59 682502.91 12.00 4384.71 90.48 MWD 11425.00 88.73 262. 87 8924. 35 -2922. 22 -3299.66 5929017.23 682478.30 12.00 4406.05 90.41 MWD I 11450.00 88.71 265. 87 8924. 90 -2924. 67 -3324.53 5929014.17 682453.50 12.00 4426.68 90.35 MWD 11475.00 88.70 268. 87 8925. 47 -2925. 82 -3349.49 5929012.41 682428.57 12.00 4446.54 90.28 MWD'; 11500.00 88.69 271. 87 8926. 04 -2925. 66 -3374.48 5929011.96 682403.59 12.00 4465.58 90.21 MWD!. 11525.00 88.68 274. 87 8926. 61 -2924. 19 -3399.43 5929012.81 682378.61 12.00 4483.74 90.14 MWD 11531.10 88.68 275. 60 8926. 75 -2923. 63 -3405.50 5929013.22 682372.53 12.00 4488.04 90.07 MWD 11550.00 88.60 273. 34 8927. 20 -2922. 16 -3424.34 5929014.23. 682353.66 12.00 4501.52 268.00 MWD j BP Alaska by Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: .4/30/2008 Time: 13:58:26 Page: 5 ! Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 13-30, True North Site: PB DS i3 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5 Well: 13 30 Section (VS) Reference: Well (O.OON,O.OOE,230.OOAzi) L Wellpath: Plan 12, 13-306 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD Incl Azim SS TVD N/S - -- -- E!W MapN MapE DLS VS TFO Too ft dea deq ft ft` ft `ft ft desd100ft ft deq 11575. 00 88.50 - 270.34 - - 8927 --- .83 ---- -2921 - --- .36 - -3449 .31 __ 5929014. 41 682328.68 12. 00 - - 4520.14 268. 05 --~1 MWD 11600. 00 88.41 267 .34 8928 .51 -2921 .86 -3474 .30 5929013. 29 682303.72 12. 00 4539.60 268. 13 MWD 11625. 00 88.32 264 .34 8929 .22 -2923 .68 -3499 .22 5929010. 87 682278.85 12. 00 4559.86 268. 21 MWD 11650. 00 88.23 261 .34 8929 .98 -2926 .79 -3524 .01 5929007. 14 682254.14 12. 00 4580.85 268. 30 MWD 11675. 00 88.15 258 .34 8930 .77 -2931 .20 -3548 .60 5929002. 13 682229.67 12. 00 4602.53 268. 39 MWD 11700. 00 88.07 255 .34 8931 .59 -2936 .89 -3572 .93 5928995. 84 682205.49 12. 00 4624.82 268. 48 MWD 11711. 10 88.04 254 .00 8931 .97 -2939 .82 -3583 .62 5928992. 65 682194.87 12. 00 4634.90 268. 58 MWD 11725. 00 88.04 255 .67 8932 .45 -2943 .46 -3597 .03 5928988. 69 682181.55 12. 00 4647.51 90. 00 MWD 11750. 00 88.04 258 .68 8933 .30 -2949 .00 -3621 .39 5928982. 54 682157.34 12. 00 4669.73 89. 94 MWD 11775. 00 88.06 261 .68 8934 .15 -2953 .27 -3646 .01 5928977. 68 682132.84 12. 00 4691.33 89. 84 MWD 11791. 10 88.07 263 .61 8934 .70 -2955 .33 -3661 .96 5928975. 23 682116.94 12. 00 4704.87 89. 74 MWD i 11800. 00 88.07 262 .54 8935 .00 -2956 .40 -3670 .80 5928973. 94 682108.14 12. 00 4712.33 270. 00 MWD 11825. 00 88.07 259 .54 8935 .84 -2960 .29 -3695 .47 5928969. 44 682083.56 12. 00 4733.73 270. 04 MWD 11850. 00 88.08 256 .54 8936 .68 -2965 .47 -3719 .92 5928963. 66 682059.26 12. 00 4755.79 270. 14 MWD 11875. 00 88.10 253 .54 8937 .51 -2971 .92 -3744 .05 5928956. 62 682035.29 12. 00 4778.42 270. 24 MWD' 11891. 10 88.11 251 .60 8938 .05 -2976 .74 -3759 .40 5928951. 42 682020.06 12. 00 4793.28 270. 34 MWD 11900. 00 88.11 252 .67 8938 .34 -2979 .47 -3767 .87 5928948. 49 682011.67 12. 00 4801.52 90. 00 MWD 11925. 00 88.11 255 .67 8939 .17 -2986 .28 -3791 .91 5928941. 09 681987.81 12. 00 4824.31 89. 96 MWD ' 11950. 00 88.12 258 .68 8939 .99 -2991 .83 -3816 .27 5928934. 94 681963.59 12. 00 4846.54 89: 87 MWD ~ 11975. 00 88.14 261 .68 8940 .80 -2996 .09 -3840 .88 5928930. 08 681939.09 12. 00 4868.14 89. 77 MWD 12000. 00 88.16 264 .68 8941 .61 -2999 .06 -3865 .69 5928926. 50 681914.36 12. 00 4889.05 89. 67 MWD 12025. 00 88.18 267 .68 8942 .41 -3000 .72 -3890 .62 5928924. 22 681889.48 12. 00 4909.21 89. 57 MWD ~ 12050. 00 88.21 270 .68 8943 .20 -3001 .08 -3915 .60 5928923. 25 681864.52 12. 00 4928.58 89. 48 MWD 12075. 00 88.25 273 .68 8943 .97 -3000 .13 -3940 .57 5928923. 58 681839.54 12. 00 4947.10 89. 38 MWD 12100. 00 88.29 276 .68 8944 .73 -2997 .87 -3965 .45 5928925. 23 681814.61 12. 00 4964.71 89. 29 MWD 12125. 00 88.33 279 .68 8945 .47 -2994 .31 -3990 .18 5928928. 18 681789.80 12. 00 4981.37 89. 20 MWD 12141. 10 88.36 281 .62 8945 .93 -2991 .34 -4006 .00 5928930. 76 681773.92 12. 00 4991.57 89. 11 MWD 12150. 00 88.16 280 .57 8946 .20 -2989 .63 -4014 .73 5928932. 26 681765.15 12. 00 4997.16 259. 00 MWD 12175. 00 87.59 277 .62 8947 .13 -2985 .68 -4039 .39 5928935. 60 681740.39 12. 00 5013.51 259. 03 MWD 12200. 00 87.03 274 .67 8948 .30 -2983 .01 -4064 .22 5928937. 66 681715.51 12. 00 5030.81 259. 14 MWD 12225. 00 86.47 271 .72 8949 .72 -2981 .62 -4089 .14 5928938. 43 681690.57 12. 00 5049.01 259. 28 MWD 12250. 00 85.93 268 .76 8951 .38 -2981 .51 -4114 .08 5928937. 92 681665.63 12. 00 5068.05 259. 45 MWD 12275. 00 85.40 265 .80 8953 .27 -2982 .70 -4138 .98 5928936. 13 681640.77 12. 00 5087.88 259. 64 MWD 12300. 00 84.87 262 .83 8955 .39 -2985 .16 -4163 .76 5928933. 05 681616.06 12. 00 5108.45 259. 87 M W D ii 12325. 00 84.37 259 .86 8957 .73 -2988 .91 -4188 .37 5928928. 71 681591.55 12. 00 5129.71 260. 12 MWD 12350. 00 83.87 256 .89 8960 .29 -2993 .92 -4212 .72 5928923. 10 681567.33 12. 00 5151.58 260. 40 MWD i 12375. 00 83.40 253 .91 8963 .07 -3000 .18 -4236 .76 5928916. 25 681543.45 12. 00 5174.03 260. 70 MWD 12400. 00 82.94 250 .92 8966 .04 -3007 .68 -4260 .42 5928908. 17 681519.99 12. 00 5196.97 261. 03 MW D ~I 12425. 00 82.50 247 .93 8969 .21 -3016 .39 -4283 .64 5928898. 89 681496.99 12. 00 5220.35 261. 39 MWD 12441. 10 82.23 246 .00 8971 .35 -3022 .63 -4298 .32 5928892. 29 681482.47 12. 00 5235.61 261. 77 MWD 12450. 00 82.59 247 .01 8972 .52 -3026 .15 -4306 .41 5928888. 57 681474.47 12. 00 5244.07 70. 00 MWD 12475. 00 83.64 249 .85 8975 .52 -3035 .27 -4329 .49 5928878. 88 681451.62 12. 00 5267.62 69. 87 MWD 12500. 00 84.69 252 .67 8978 .06 -3043 .26 -4353 .04 5928870. 32 681428.28 12. 00 5290.79 69. 53 MWD 12525. 00 85.76 255 .48 8980 .15 -3050 .09 -4377 .00 5928862. 90 681404.50 12. 00 5313.54 69. 24 MWD 12550. 00 86.84 258 .29 8981 .76 -3055 .75 -4401 .29 5928856. 64 681380.35 12. 00 5335.78 69. 01 MWD 12575. 00 87.93 261 .09 8982 .90 -3060 .22 -4425 .86 5928851. 57 681355.90 12. 00 5357.48 68. 82 MWD 12600. 00 89.02 263 .88 8983 .57 -3063 .49 -4450 .63 5928847. 69 681331.22 12. 00 5378.56 68. 70 MWD 12601. 10 89.07 264 .00 8983 .58 -3063 .61 -4451 .72 5928847. 55 681330.13 12. 00 5379.47 68. 62 MWD 12625. 00 89.02 266 .87 8983 .98 -3065 .51 -4475 .54 5928845. 07 681306.37 12. 00 5398.94 91. 00 MWD 12650. 00 88.97 269 .87 8984 .42 -3066 .22 -4500 .53 5928843. 74 681281.41 12. 00 5418.53 90. 95 MWD 12675. 00 88.92 272 .87 8984 .88 -3065 .62 -4525 .51 5928843. 73 681256.42 12. 00 5437.29 90. 90 MWD 12700. 00 88.88 275 .87 8985 .36 -3063 .71 -4550 .43 5928845. 02 681231.46 12. 00 5455.15 90. 84 MWD BP Alaska by Baker Hughes INTEQ Planning Report iNTEQ Company: BP Amoco Date: 4/30/2008 Timer 13'58:26 Page: 6 Field: Prudhoe Bay Co-ordinate(NE)Reference: Well: 1 3-30, True North Site: PB DS 13 Vertical (TVI)) Reference: 2ES @ 46+28.5 74.5 i Well: 13-30 Section {VS) Reference: Well (O .OON,O.OOE,230.OOAzi) Wellpath: Plan 12, 13-306 Survey Calculation Method: Minimu m Curvatu re Db: Sybase Survey MD 'Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 12725.00 88.84 278.87 8985.86 -3060.51 -4575.22 5928847.62 681206.60 12.00 5472.07 90:79 MWD 12750.00 88.81 281.87 8986.37 -3056.00 -4599.80 5928851.51 681181.92 12.00 5488.01 90.73 MWD'. 12775.00 88.77 284.87 8986.90 -3050.22 -4624.11 5928856.69 681157.47 12.00 5502.92 90.67 MWD 12800.00 88.74 287.88 8987.44 -3043.18 -4648.09 5928863.14 681133.33 12.00 5516.76 90.60 MWD L 'i 12825.00 88.72 290.88 8988.00 -3034.89 -4671.67 5928870.85 681109.56 12.00 5529.49 90.54 MWD; 12826.10 88.72 291.01 8988.02 -3034.49 -4672.69 5928871.22 681108.53 12.00 5530.03 90.47 MWD! 12850.00 88.72 288.14 8988.56 -3026.49 -4695.21 5928878.67 681085.82 12.00 5542.13 270.00 MWD 12875.00 88.72 285.14 8989.12 -3019.33 -4719.15 5928885.23 681061.71 12.00 5555.87 270.06 MWD 12900.00 88.73 282.14 8989.67 -3013.44 -4743.44 5928890.52 681037.29 12.00 5570.69 270.13 MWD 12925.00 88.74 279.14 8990.22 -3008.83 -4768.00 5928894.53 681012.62 12.00 5586.54 270.20 MWD' 12950.00 88.76 276.14 8990.77 -3005.51 -4792.77 5928897.24 680987.78 12.00 5603.38 270.26 MWD! 12975.00 88.78 273.14 8991.31 -3003.49 -4817.68 5928898.65 680962.83 12.00 5621.16 270.33 MWD 13000.00 88.80 270.14 8991.83 -3002.78 -4842.66 5928898.74 680937.84 12.00 5639.84 270.39 3.5" BP Al k ,_ ~/ ~ LEGEND - 13-30(13-30) 'i 1zj}'~'" ' cnmuu ~ ~~~ as a w -a 13-30 (13-30A) Plan 12 13-308 K 1° r u z] _ - BNK~R f ~[ „ , Plan 12 rn 9 s+ wEwfiREEiu~f 1WGH! Vii ~ Il_J ~"~'-+' 'n eer women; °~v,d ini,..,,. c .,~.,n.~.~M~ ~.aF.~,°n 000303016103 e w.no.EN. 1NTEQ . , m.~~ao.~en~~~.,ee gem E m°. °~^' ~~„'~'~ R11. Dalu'i0w: 3Ef OI8~31.0 11300 V.M000n Or101j OcMlw FW1Ng0 3]O. 38.60 tWP :1 ~~ ~ ~ ~ ~ REFERENCE N O MP ON CPwa oats WEI Reference W C 330, T,ue NorM s a Lew, 101 Re,e,enc eeane 5 30 (OOON O VSed On (VS~R e OOE iiii 1 .tPo-+ I Y 7 1 ~ 1 t ~ ~. _ - ~ t r + I r , l _ ~~ r r{{+,~ ~ ~ - 1 I f I Y~ _ 1 i ~ ~ I rr ~ T L ~ O R l . a Mea a C e„o0 M m Curvature ~ ~ # - }I +# i t. _ f { 1 r ~ i ~ r ~ ~ -I - + f~ - '-+$ ~ { 1 ~_ -~ t . ~ + r l { I I J ~ ~ I .. wo { i i~ 6'x1 a"... : ;.»: a'°u. "° wu w __ _ _ I = L _ r _ _ Y -~_ r _t. - _ ~~ . .. ...~... ,....i,. ...R +'~ .~ e~N i 1 ir_ i _ 1. y ~ .~ 4_ i - e~ ...or.rwee n s o y j.. _ _ i 1.. T ; +.. i ~ . ~ t i :r; ~ .w,. a, . a.,.,~ ne, ,.~- l' ...,,..,.,..,, , ~~, ~ i.,1aa 7 r ...,,..es,,,, . „~a ww,..e,.]a, . ..,.,,.a.,.e .. - . 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F T l . li 1, I{ , r r t ~r r Y t-;_ ..I. ; r I,~ f ~ , ~ _ T - ' ;r I : :-r :-+; ~ - -~~ t ; ~; -+ ;; _ ., ; ; ; ~ ; j ; ; j ; j .;~„-.,,,~ ,T,,, , IT.r. , , iaoo :.oo xsm zeao vao a rr ,~,~ na 3aoo oo ; rT,. , T_~_, 1T~)T~„ ao ]toa ]zaa ]m aeao ~ aa T, n ] T~,T_ ,~~,,. 1, ,,.,.,,. , ,,..y ;..,..tr,,,j - -, „~,, - , „ zm oeoo aoao . m noa ,mo woo saoo ],m woo seen xw wao seoo sro ~voe~oa~ se<3(oo at zao.oo• ~~ooru~o~ <e , ,, , - ,.r.;,, ,,.,,,r, o lean 'woo sow etw ezao sam BP Alaska MRLV~TN DETMIt •e00N~ID118MD3 P M YYn11M1k: taaoA N TN en MD: BalE.04 Rn/. Wtaa: 1El D46~Sa.5 T4.MMlpt V.ECCDOn Orlyl; OrF/4Y FtarliTVD ~~In M/I rvm REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well CenUe' 13-30, Tlue NoM Vertir2l(ND Reference: 2E5 @ 46*28.5 74.50 Section (VS Reference: Slat - 30 (O.OON,O.OOE) Measured Depth Reference: 2ES @ 4628.5 74.50 Calculation Method. Minimum Curvature ue rD inc k~ E N T • olp ns~ T~.aw LEGEND T Plan: Plan 12 (1330/Plan 12, 13-308( M AvmuNS ~o True None Created 8y: BP Dale: 4/30/2008 Maprielia Ng0M: 23.41° Chocked: Data: by Bue~llg~h~5]6]niT Dip Aegk: 60.89' Comaci lnlormauon Date' 3/6/1008 Bin Mic~~aalsan Motley. 0gBm200] Cen Ia0]130!-35]0 E-nu~l nin micnaelsonLmie4.wm ii) -BOO y 13-31 t3atw I i -_ .. a ~ ... I I ( - ~ J900 I + ~ soo ' j , ~_~ t, I - ;~~~ -moo _ ' ._ _ _ ) ~ + - _ ~ . , . _ -aa°o -_..,1 --- 100 -_ ~ _ _ --psi°o~ { ~ 1-'.~l .. ,- - "-4100 1}30 7330 ~0/Q Ir f 11 r r ~ t 1 l L_ .~ +~ /4700 /8400 4700 ~ -12°0 I. 1 ... I ~~6000 4100 . ~,, I~ I ~ ~ : ~ ~~ ~ ~~ T ~ fi( I '~ ~__ ~s3oo I ~ ~ioo /~4ioo eTOO Deoo 740o T~0° .. _ e~oo - ~ ~~ ' Teoo eloo - 7 - a4oo 1oo_.~aoo ... . I _ ~ ~ _ ,~D°° :!4-Ir-i~~irtai~ I_: rlra,~r~G~rrt--r(;Iit)~1CTrr~~)nt r: + wliLL nLTA1LS ANTI-COLLISION SHTTINGS <omewnv uF_uus ~N/-S «V-W Northing lasting Lahwdc Longitude Slot In[Crpnlatlnn Me[hudMD Interval: 50.00 /, xi w„~~.o e,a~ -6?2.68 -138.96 593?019.57 6x5704.86 70°13'119.3?ON I4x°30'06.)39W 30 Depth Range From: 9685.04 To: 13000.00 _ i..t f„4n M1Onn Maximum Range: 149215 Reference: Plan: Plan 12 ti„M;~,i .1;,,;,,E k, i f .W..1. xW~, Ha,~.l w~.t.i.rwm or.T wns u,~ n. i3.tun >Ig29EU]M1tlU2 Pue l,e~w~M~ I96NSUW Nef nalw,ai: -Y. ~u -a5 ]S.SUn V.See„ou Iki¢w g Myle ~tNl-S -4%-W Y~rn,~fVn LEGEND - 13-12 (13-12), Major Risk - 13-12A (13-12A), Major Risk l3-IS (13-15), Major Risk - 13-29 (13-29), Major Risk - 13-29 (13-29L1), Major Risk 13-30 (13-30), Major Risk 13-30 (13-30A), Major Risk - Plan 12, 13306 - Plan 12 by ~~~' INTE(~ ,,~1,n~n~,w~~x _ _ _ 9,3 ~~;,~;, x -- - - - - ~~=;z, x - ~~zb - -- - - v~1= v= W;~, ~~, ,_~ ~,~W ;;9~a ~„a,~~~ ~ a ~,xd~ - ,,. 9,fi3 - - } n~a; - ~;a~ ~,~~ ~ -,~z ~~:; ~;,a ~;; ~ ovv,,; H685JNFm n~W,1.W IIau.W.lW1in l_~~ ii~,~.l> by ~ BP Alaska Anhcoll><s><on Report 1NTEQ Company:' BP Amoco Date: 4!30!2008 Time: 14:49:37 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE) Refe rence: Well: 13-30, True North Reference Well: 13-30 Vertical ('fVD) Reference: 2ES @ 46+28.5 74.5 i Reference Wellpath: Plan 12; 13-306 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Rfseells in thisll9ettBi pal Plan 8~ PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9685.04 to 13000.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1497.15 ft _ _ _ _ Error Surface: Ellipse + Casing - - Survey Program for ---- Definitive Wellpath --- ------- Date: 4/30/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ft ft 87.50 7987.50 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOS S gyro multi shot 7990.00 9685.04 13-30A IIFR (7990.00-1070 8.26) MWD+IFR+MS MWD +IFR + Multi Station 9685.04 13000.00 - _ Planned: Plan 12 V8 - MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in - - 113000.00 9066.33 __ 3.500 - 4.125 3.5" - _- Summary <-------------- O ffset Wellpath ---- --.a Reference Offset Gtr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 13 13-12 13-12 V1 1 1103.99 10325.00 666.48 801.53 -135.05 FAIL: Major Risk ~!~ PB DS 13 13-12A 13-12A V3 Plan: D efini 1 1171.65 10400.00 666.77 814.88 -148.11 FAIL: Major Risk PB DS 13 13-15 13-15 V1 1 0013.64 9875.00 902.77 302.32 600.45 Pass: Major Risk '', PB DS 13 13-29 13-29 V1 Out of range PB DS 13 13-29 13-29L1 V2 Out of range PB DS 13 13-30 13-30 V1 Out of range PB DS 13 13-30 13-30A V9 9724.99 9725.00 0.77 445.45 -444.68 FAIL: Major Risk PB DS 13 13-30 ___- Plan 3, 13-30C VO Plan 9699.54 9700.00 7.95 451.78 -443.84 FAIL: Major Risk - -- ~ Site: PB DS 1 3 Well: 13-12 Rule Assigned: Major Risk Wellpath: 13-12 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TY'D ttef Offset TFO+AZI TFO-HS Casing/IisDistance Area Deviation Warning ft 'ft ft ft ft ft deg deg. in ft ft ft _ 10600.00 8969.72 - 8875.00 7957.25 64.45 122.66 160.43 - - -. 313.11 1481.59 445.21 1036.37 - Pass 10600.00 8969.72 8900.00 7975.53 64.45 123.61 160.10 312.77 1464.16 449.52 1014.64 Pass 10600.00 8969.72 8925.00 7993.74 64.45 124.60 159.76 312.43 1446.95 453.94 993.01 Pass 10610.47 8969.83 8950.00 8011.97 65.54 126.99 160.65 312.06 1429.82 464.06 965.76 Pass 10615.45 8969.88 8975.00 8030.21 66.05 128.63 160.87 311.69 1412.88 471.37 941.51 Pass 10625.00 8969.98 9000.00 8048.47 67.04 130.85 161.63 311.30 1396.11 481.15 914.96 Pass 10625.00 8969.98 9025.00 8066.79 67.04 131.83 161.23 310.90 1379.43 486.05 893.38 Pass 10630.53 8970.03 9050.00 8085.21 67.57 133.50 161.48 310.49 1362.90 493.86 869.04 Pass 10635.56 8970.08 9075.00 8103.73 68.05 135.10 161.64 310.05 1346.51 501.57 844.93 Pass 10640.60 8970.14 9100.00 8122.34 68.54 136.69 161.79 309.59 1330.25 509.42 820.83 Pass 10650.00 8970.23 9125.00 8141.02 69.44 138.75 162.45 309.12 1314.16 519.48 794.68 Pass 10650.71 8970.24 9150.00 8159.75 69.51 139.80 162.05 308.64 1298.17 525.37 772.80 Pass 10662.58 8970.42 9175.00 8178.51 69.22 140.35 161.14 308.15 1282.32 531.98 750.35 Pass 10682.49 8971.21 9200.00 8197.31 68.06 139.71 159.12 307.73 1266.48 536.60 729.88 ~ Pass 10703.23 8972.69 9225.00 8216.20 66.84 138.87 157.10 307.39 1250.56 540.67 709.89 Pass i 10913.41 8989.64 9250.00 8235.20 60.04 128.90 149.20 307.73 1233.12 485.42 747.71 Pass i 10917.98 8989.72 9275.00 8254.32 60.58 130.54 149.28 307.27 1214.71 493.33 721.37 Pass 10925.00 8989.84 9300.00 8273.55 61.41 132.60 149.64 306.78 1196.39 503.12 693.27 Pass i i 10925.00 8989.84 9325.00 8292.89 61.41 133.39 149.14 306.28 1178.14 507.97 670.17 Pass 10931.66 8989.95 9350.00 8312.33 62.16 135.32 149.41 305.75 1159.96 517.58 642.38 Pass ' 10936.21 8990.03 9375.00 8331.87 62.67 136.89 149.41 305.20 1141.88 525.87 616.01 Pass ~, 10940.74 8990.11 9400.00 8351.50 63.18 138.45 149.38 304.63 1123.89 534.30 589.58 Pass 10950.00 8990.27 9425.00 8371.23 64.21 140.73 149.89 304.03 1106.04 546.02 560.02 Pass by ~ BP Alaska Anticollision Re ort P 11vTEQ i Company: BP Amoco Date: 4/30/2008 Time: 14.49:37 Page: 2 I Field: Prudhoe Bay Reference S ite: PB DS 13 Co-ordinate(NE) Reference: Well: 13-30, True North Reference Well: 13-30 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5 Reference Wellpath: Plan 12, 13-308' Dh! Oracle Site: PB DS 1 3 Well: 13-12 Rule Assigned: Major Risk Wellpath: 13-12 V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MI} TVD Ref Offset TFO+AZI TFO-HS Casing/Il~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10950.00 8990.27 9450.00 8391.04 64.21 141.49 149.28 303.41 1088.28 551.53 536.75 Pass 10950.00 8990.27 9475.00 8410.93 64.21 142.26 148.64 302.78 1070.73 557.14 513.59 Pass 10958.85 8990.42 9500.00 8430.91 65.15 144.46 149.02 302.09 1053.28 568.94 484.35 Pass 10963.38 8990.50 9525.00 8450.94 65.63 145.91 148.86 301.39 1036.03 577.84 458.19 Pass 10967.93 8990.58 9550.00 8471.02 66.11 147.37 148.68 300.66 1018.95 586.89 432.06 Pass 10975.00 8990.70 9575.00 8491.14 66.85 149.21 148.76 299.90 1002.06 597.77 404.28 Pass 10975.00 8990.70 9600.00 8511.30 66.85 149.95 147.99 299.12 985.34 603.99 381.36 Pass 10981.63 ~ 8990.81 9625.00 8531.52 67.50 151.68 147.96 298.30 968.83 614.61 354.22 i Pass , 10986.20 8990.89 9650.00 8551.81 67.95 153.08 147.66 297.45 952.53 623.99 328.53 Pass 10990.76 8990.97 9675.00 8572.17 68.40 154.48 147.32 296.57 936.44 633.48 302.96 Pass 10995.31 8991.05 9700.00 8592.61 68.85 155.87 146.95 295.65 920.59 643.05 277.54 Pass '~ 11000.00 8991.13 9725.00 8613.11 69.32 157.22 146.56 294.69 904.98 652.67 252.31 Pass 11004.38 8991.20 9750.00 8633.70 69.72 158.53 146.09 293.70 889.83 662.08 227.55 Pass 11008.89 8991.28 9775.00 8654.37 70.13 159.85 145.59 292.66 874.55 671.63 202.92 Pass 11013.38 8991.35 9800.00 8675.12 70.54 161.16 145.05 291.58 859.76 681.18 178.57 Pass 11017.85 8991.43 9825.00 8695.95 70.95 162.41 144.47 290.46 845.28 690.60 154.69 Pass '; 11025.00 8991.55 9850.00 8716.87 71.60 164.00 144.16 289.29 831.18 701.68 129.50 Pass 11025.00 8991.55 9875.00 8737.88 71.60 164.66 142.95 288.09 817.42 708.22 109.20 Pass i 11031.14 8991.65 9900.00 8758.97 72.11 166.11 142.42 286.82 804.07 718.41 85.66 Pass 11035.53 8991.72 9925.00 8780.13 72.48 167.27 141.64 285.51 791.14 727.27 63.87 Pass 11039.91 8991.79 9950.00 8801.36 72.85 168.44 140.81 284.16 778.66 735.95 42.70 Pass 11044.28 8991.86 9975.00 8822.65 73.21 169.59 139.93 282.75 766.64 744.41 22.24 Pass 11050.00 8991.96 10000.00 8844.00 73.69 170.89 139.16 281.30 755.12 753.38 1.75 Pass 11050.00 8991.96 10025.00 8865.42 73.69 171.48 137.67 279.80 744.11 758.52 -14.41 FAIL 11057.27 8992.08 10050.00 8886.89 74.25 172.91 136.98 278.24 733.58 767.41 -33.82 FAIL 11061.55 8992.15 10075.00 8908.43 74.57 173.98 135.90 276.64 723.60 774.14 -50.55 FAIL 11065.81 8992.22 10100.00 8930.03 74.90 175.04 134.76 275.00 714.17 780.35 -66.18 FAIL I 1 11070.04 8992.28 10125.00 8951.71 75.22 176.05 133.57 273.30 705.44 785.84 -80.40 I FAIL 11075.00 8992.36 10150.00 8973.48 75.59 177.13 132.41 271.55 697.54 791.08 -93.54 FAIL 11078.51 8992.42 10175.00 8995.35 75.83 178.05 131.04 269.76 690.50 794.74 -104.25 FAIL ~ 11082.73 8992.49 10200.00 9017.32 76.12 179.04 129.71 267.92 684.34 797.98 -113.65 FAIL 11086.95 8992.56 10225.00 9039.35 76.41 179.99 128.35 266.05 679.04 800.30 -121.27 FAIL i 11091.19 8992.62 10250.00 9061.42 76.70 180.94 126.95 264.15 674.58 801.78 -127.20 FAIL 11095.44 8992.69 10275.00 9083.52 76.99 181.88 125.54 262.22 670.98 802.70 -131.72 FAIL ~ 11100.00 8992.76 10300.00 9105.67 77.30 182.84 124.14 260.27 668.26 802.78 -134.53 i FAIL 11103.99 8992.83 10325.00 9127.87 77.53 183.72 122.65 258.31 666.48 801.53 -135.05 FAIL j 11108.28 8992.89 10350.00 9150.14 77.79 184.61 121.19 256.34 665.70 799.35 -133.65 FAIL 11112.58 8992.96 10375.00 9172.48 78.05 185.50 119.73 254.36 665.94 796.19 -130.24 FAIL 11116.88 8993.03 10400.00 9194.88 78.30 186.38 118.28 252.39 667.19 792.04 -124.86 FAIL 11121.17 8993.09 10425.00 9217.36 78.56 187.22 116.83 250.42 669.42 786.88 -117.46 FAIL 11125.46 8993.16 10450.00 9239.90 78.82 188.06 115.40 248.48 672.63 780.85 -108.21 FAIL 11129.73 8993.22 10475.00 9262.51 79.04 188.88 113.98 246.55 676.80 773.85 -97.05 FAIL 11133.99 8993.29 10500.00 9285.19 79.27 189.69 112.60 244.65 681.91 766.06 -84.15 FAIL , 11138.26 8993.35 10525.00 9307.91 79.49 190.47 111.24 242.79 687.94 757.54 -69.60 FAIL ', 11142.57 8993.42 10550.00 9330.66 79.72 191.25 109.94 240.96 694.88 748.42 -53.54 FAIL ~I 11146.93 8993.48 10575.00 9353.44 79.93 192.02 108.68 239.18 702.70 738.73 -36.03 FAIL ~I 1 11150.00 8993.53 10600.00 9376.25 80.08 192.70 107.32 237.45 711.37 728.35 -16.99 FAIL 11155.71 8993.62 10625.00 9399.10 80.32 193.50 106.32 235.77 720.85 718.07 2.78 Pass . 11160.08 8993.69 10650.00 9422.01 80.51 194.22 105.21 234.13 731.12 707.18 23.94 Pass 11164.44 8993.76 10675.00 9444.99 80.70 194.92 104.15 232.55 742.16 696.08 46.08 Pass 11168.77 --- 8993.82 10700.00 9468.02 80.88 195.61 103.14 231.02 753.92 684.82 69.10 Pass _ ~~~ by ~ BP Alaska Anticollision Re ort l~ 1NTEQ Company: BP Amoco Date: 4/30/2008 Time: 14:49:37 Page: 3 Field: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE) Reference: Well: 13-30, True North Reference Well: 13-30 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5 Reference Wellpath: Plan 12, 13-30B Db: Oracle Site: PB DS 13 Well: 13-12 Rule Assigned: Major Risk Wellpath: 13-12 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/HSflistance Area Deviation Warning ~ ft ft ft ft ft ft deg deg in ft ft ft ii 11175.00 8993.93 10725.00 9491.10 81.15 196.32 102.40 229.54 766.35 673.71 92.63 Pass 11177.38 8993.96 10750.00 9514.23 81.23 196.89 101.27 228.12 779.37 661.98 117.39 Pass 11181.67 8994.03 10775.00 9537.39 81.38 197.52 100.41 226.74 792.97 650.46 142.51 Pass 11185.94 8994.10 10800.00 9560.59 81.52 198.13 99.59 225.42 807.12 639.01 168.12 Pass 11190.21 8994.18 10825.00 9583.80 81.67 198.72 98.83 224.14 821.77 627.63 194.13 Pass 11194.51 8994.25 10850.00 9607.02 81.82 199.30 98.12 222.92 836.85 616.40 220.45 Pass 11200.00 8994.34 10875.00 9630.24 82.01 199.88 97.60 221.74 852.36 605.43 246.93 Pass 11203.17 8994.40 10900.00 9653.46 82.09 200.41 96.85 220.61 868.26 594.46 273.80 Pass 11207.54 8994.47 10925.00 9676.67 82.20 200.95 96.29 219.52 884.53 583.72 300.81 Pass 11211.92 8994.55 10950.00 9699.89 82.31 201.47 95.78 218.48 901.16 573.20 327.96 Pass 11216.32 8994.62 10975.00 9723.11 82.42 201.97 95.30 217.48 918.12 562.93 355.20 Pass II 11220.75 8994.70 11000.00 9746.32 82.54 202.47 94.87 216.52 935.40 552.90 382.50 Pass 11225.00 8994.78 11025.00 9769.54 82.64 202.94 94.46 215.60 952.98 543.17 409.81 Pass 11229.65 8994.86 11050.00 9792.76 82.72 203.40 94.14 214.71 970.84 533.58 437.25 Pass 11234.13 8994.94 11075.00 9815.98 82.80 203.85 93.83 213.87 988.96 524.26 464.70 Pass !I 11238.62 8995.02 11100.00 9839.19 82.87 204.27 93.55 213.05 1007.34 515.21 492.14 Pass 11239.61 8995.04 11105.50 9844.30 82.89 204.37 93.50 212.88 1011.42 513.25 498.17 Pass Site: PB DS 13 Well: 13-12A Rule Assigned: Major Risk Wellpath: 13-12A V3 Plan: Definitive V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Co Ariowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ', ft ft ft 'I 10600.00 8969.72 8875.00 7957.25 64.45 122.66 160.43 313.11 1481.59 445.21 1036.37 Pass 'i 10600.00 8969.72 8900.00 7975.53 64.45 123.61 160.10 312.77 1464.16 449.52 1014.64 Pass ~, 10600.00 8969.72 8925.00 7993.74 64.45 124.60 159.76 312.43 1446.95 453.94 993.01 Pass 10610.47 8969.83 8950.00 8011.97 65.54 126.99 160.65 312.06 1429.82 464.06 965.76 Pass 10615.45 8969.88 8975.00 8030.21 66.05 128.63 160.87 311.69 1412.88 471.37 941.51 Pass 10625.00 8969.98 9000.00 8048.47 67.04 130.85 161.63 311.30 1396.11 481.15 914.96 Pass 10625.00 8969.98 9025.00 8066.79 67.04 131.83 161.23 310.90 1379.43 486.05 893.38 Pass ', 10630.53 8970.03 9050.00 8085.21 67.57 133.50 161.48 310.49 1362.90 493.86 869.04 Pass j 10635.56 8970.08 9075.00 8103.73 68.05 135.10 161.64 310.05 1346.51 501.57 844.93 Pass 10640.60 8970.14 9100.00 8122.34 68.54 136.69 161.79 309.59 1330.25 509.42 820.83 Pass 10650.00 8970.23 9125.00 8141.02 69.44 138.75 162.45 309.12 1314.16 519.48 794.68 Pass 10650.71 8970.24 9150.00 8159.75 69.51 139.80 162.05 308.64 1298.17 525.37 772.80 Pass ~ 10662.58 8970.42 9175.00 8178.51 69.22 140.35 161.14 308.15 1282.32 531.98 750.35 Pass 10682.49 8971.21 9200.00 8197.31 68.06 139.71 159.12 307.73 1266.48 536.60 729.88 Pass 10703.23 8972.69 9225.00 8216.20 66.84 138.87 157.10 307.39 1250.56 540.67 709.89 Pass 10913.41 8989.64 9250.00 8235.20 60.04 128.90 149.20 307.73 1233.12 485.42 747.71 Pass 10917.98 8989.72 9275.00 8254.32 60.58 130.54 149.28 307.27 1214.71 493.33 721.37 Pass 10925.00 8989.84 9300.00 8273.55 61.41 132.60 149.64 306.78 1196.39 503.12 693.27 Pass 10925.00 8989.84 9325.00 8292.89 61.41 133.39 149.14 306.28 1178.14 507.97 670.17 Pass 10931.66 8989.95 9350.00 8312.33 62.16 135.32 149.41 305.75 1159.96 517.58 642.38 Pass 10936.21 8990.03 9375.00 8331.87 62.67 136.89 149.41 305.20 1141.88 525.87 61.6.01 Pass I ~~ 10940.74 8990.11 9400.00 8351.50 63.18 138.45 149.38 304.63 1123.89 534.30 589.58 ~ Pass 10950.00 8990.27 9425.00 8371.23 64.21 140.73 149.89 304.03 1106.04 546.02 560.02 Pass 10950.00 8990.27 9450.00 8391.04 64.21 141.49 149.28 303.41 1088.28 551.53 536.75 Pass 10950.00 8990.27 9475.00 8410.93 64.21 142.26 148.64 302.78 1070.73 557.14 513.59 Pass 10958.85 8990.42 9500.00 8430.91 65.15 144.46 149.02 302.09 1053.28 568.94 484.35 Pass 10963.38 8990.50 9525.00 8450.94 65.63 145.91 148.86 301.39 1036.03 577.84 458.19 Pass BP Alaska i s by Anticollision Report 1NTEQ Company: BP Amoco Date: 4!30!2008 Time: 14:49: 37 Page: 4 Field: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE}.Reference: Well : 13-30, True N orth Reference Well: 13-30 Vertical (TVD) Reference: 2ES @ 46+28. 5 74. 5 Reference Wellpath: Plan 12 , 13-3UB - -- --_- ------ --_-- Db: Oracle Site: PB DS 1 3 Well: 13-12A Rule Assigned: Major Risk Wellpath: 13-12A V3 Plan: Definitive V1 Inter-Site Error: 0.00 ft ~ Reference Offset" Semi-MajorAais ' Ctr-Ctr No-Go Allo wabl e MI) TVD MI) TVD Ref -0ffset TFO+AZI TFO-HS Casing/H~istance Are a Dev iation Warning ~ ft ft ft ft ft ft deg. deg in ft ft ft I 10975 .00 8990 .70 9575 .00 8491 .4 66 .85 149. 21 148. 76 299. 90 1002. 06 597. 77 404 .28 I Pass 10975 .00 8990 .70 9600 .00 8511 .30 66 .85 149. 95 147. 99 299. 12 985. 34 603. 99 381 .36 Pass 10981 .63 8990 .81. 9625 .00 8531 .52 67 .50 151. 68 147. 96 298. 30 968. 83 614. 61 354 .22 Pass 10986 .20 8990 .89 9650 .00 8551 .81 67 .95 153. 08 147. 66 297. 45 952. 53 623. 99 328 .53 Pass 10990 .76 8990 .97 9675 .00 8572 .17 68 .40 154. 48 147. 32 296. 57 936. 44 633. 48 302 .96 Pass 10995 .31 8991 .05 9700. 00 8592 .61 68 .85 155. 87 146. 95 295. 65 920. 59 643. 05 277 .54 Pass 11000 .00 8991 .13 9725 .00 8613 .11 69 .32 157. 22 146. 56 294. 69 904. 98 652. 67 252 .31 Pass ', 11004 .38 8991 .20 9750. 00 8633 .70 69 .72 158. 53 146. 09 293. 70 889. 63 662. 08 227 .55 Pass 11008 .89 8991 .28 9775 .00 8654 .37 70 .13 159. 85 145. 59 292. 66 874. 55 671. 63 202 .92 Pass 11013 .38 8991 .35 9800. 00 8675 .12 70 .54 161. 16 145. 05 291. 58 859. 76 681. 18 178 .57 Pass 11017 .85 8991 .43 9825 .00 8695 .95 70 .95 162. 41 144. 47 290. 46 845. 28 690. 60 154 .69 Pass ~ 11025 .00 8991 .55 9850 .00 8716 .87 71 .60 164. 00 144. 16 289. 29 831. 18 701. 68 129 .50 Pass 11025 .00 8991 .55 9875. 00 8737 .88 71 .60 164. 66 142. 95 288. 09 817. 42 708. 22 109 .20 Pass 11031 .14 8991 .65 9900. 00 8758 .97 72 .11 166. 11 142. 42 286. 82 804. 07 718. 41 85 .66 Pass 11035 .53 8991 .72 9925. 00 8780 .13 72 .48 167. 27 141. 64 285. 51 791. 14 727. 27 63 .87 Pass 11039 .91 8991 .79 9950. 00 8801 .36 72 .85 168. 44 140. 81 284. 16 778. 66 735. 95 42 .70 Pass 11044 .28 8991 .86 9975. 00 8822 .65 73 .21 169. 59 139. 93 282. 75 766. 64 744. 41 22 .24 Pass 11050 .00 8991 .96 10000. 00 8844 .00 73 .69 170. 87 139. 16 281. 30 755. 12 753. 33 1 .80 Pass 11050 .00 8991 .96 10025. 00 8865 .42 73 .69 171. 18 137. 67 279. 80 744. 11 757. 63 -13 .51 FAIL 11057 .27 8992 .08 10050. 00 8886 .89 74 .25 172. 32 136. 98 278. 24 733. 58 767. 32 -33 .73 FAIL 11061 .80 8992 .15 10075. 00 8908 .10 74 .59 172. 83 135. 95 276. 67 723. 58 772. 59 -49 .00 FAIL 11066 .69 8992 .23 10100. 00 8928 .85 74 .96 173. 35 134. 96 275. 09 714. 22 777. 26 -63 .04 FAIL 11075 .00 8992 .36 10125. 00 8948 .47 75 .59 174. 19 134. 42 273. 56 705. 60 783. 08 -77. 48 FAIL 11078 .75 8992 .43 10150. 00 8966 .78 75 .85 174. 56 133. 42 272. 11 697. 73 785. 84 -88. 11 FAIL 11085 .87 8992 .54 10175. 00 8983 .65 76 .33 175. 22 132. 91 270. 74 690. 70 789. 64 -98. 94 FAIL 11093 .66 8992 .66 10200. 00 8998 .95 76 .86 175. 89 132. 58 269. 47 684. 51 793. 22 -108. 71 FAIL 1 11100 .00 8992 .76 10225. 00 9012 .58 77 .30 176. 41 132. 20 268. 33 679. 19 795. 76 -116. 57 FAIL 11111 .02 8992 .93 10250. 00 9024 .42 77 .95 177. 24 132. 51 267. 33 674. 73 799. 64 -124. 91 FAIL 11120 .45 8993 .08 10275. 00 9034 .39 78 .52 177. 87 132. 79 266. 47 671. 17 802. 55 -131. 39 FAIL '~ 11130 .27 8993 .23 10300. 00 9042 .42 79 .07 178. 46 133. 28 265. 78 668. 48 805. 32 -136. 85 FAIL 1 11140 .39 8993 .38 10325. 00 9048 .45 79 .61 178. 99 133. 97 265. 26 666. 67 807. 91 -141. 25 FAIL 1 11150 .00 8993 .53 10350. 00 9052 .42 80 .08 179. 41 134. 79 264. 93 665. 73 810. 26 -144. 53 FAIL 11161 .19 8993 .70 10375. 00 9054 .32 80 .56 179. 82 135. 98 264. 77 665. 66 812. 68 -147. 03 FAIL II 11171 .65 8993 .87 10400. 00 9054 .49 81 .01 180. 11 137. 25 264. 78 666. 77 814. 88 -148. 11 FAIL 11181 .98 8994 .04 10425. 00 9054 .43 81 .39 180. 32 138. 53 264. 83 670. 42 816. 74 -146. 32 FAIL ~, 11192 .03 8994 .21 10450. 00 9054 .31 81 .73 180. 43 139. 81 264. 90 676. 71 818. 20 -141. 49 FAIL 11200 .00 8994 .34 10475. 00 9054 .13 82 .01 180. 47 140. 87 265. 00 685. 57 819. 33 -133. 76 FAIL 11210 .80 8994 .53 10500. 00 9053 .89 82 .28 180. 44 142. 27 265. 11 696. 83 820. 20 -123. 36 FAIL I 11219 .28 8994 .68 10525. 00 9053. 61 82 .50 180. 36 143. 42 265. 24 710. 38 820. 74 -110. 36 FAIL ~ 11225 .00 8994 .78 10550. 00 9053 .27 82 .64 180. 27 144. 25 265. 39 726. 04 821. 17 -95. 13 FAIL 11234 .02 8994 .94 10575. 00 9052 .88 82 .79 180. 08 145. 48 265. 53 743. 58 821. 22 -77. 63 FAIL 11240 .17 8995 .05 10600. 00 9052 .44 82 .90 179. 91 146. 37 265. 68 762. 83 821. 20 -58. 37 FAIL ~ 11245 .45 8995 .15 10625. 00 9051 .97 82 .98 179. 74 147. 16 265. 84 783. 54 821. 13 -37. 59 FAIL 11250 .00 8995 .23 10650. 00 9051 .45 83 .06 179. 58 147. 86 266. 00 805. 50 821. 03 -15. 54 FAIL 11250 .00 8995 .23 10675. 00 9050 .90 83 .06 179. 58 148. 02 266. 16 828. 49 821. 29 7. 20 Pass 11256 .54 8995 .36 10700. 00 9050 .34 83 .11 179. 31 148. 95 266. 30 851. 80 820. 78 31. 02 Pass 11259 .59 8995 .41 10725. 00 9049 .78 83 .14 179. 18 149. 45 266. 44 875. 20 820. 58 54. 62 Pass 11262 .53 8995 .47 10750. 00 9049 .21 83 .16 179. 05 149. 94 266. 57 898. 65 820. 35 78. 30 Pass 11265 .37 8995 .52 10775. 00 9048 .65 83 .18 178. 91 150. 41 266. 70 922. 16 820. 11 102. 05 Pass I, _ 11268 _1.1 8995 _57 10800. 00 9048 .09 83 .20 178. 77 150. 86 266. 82 _945. 72 819. 85 125. 88 Pass bP ~ BP Alaska Anticollision Re ort P 1NTEQ Company: BP Amoco Date: 4!30/2008 Time: 14:49:37 Page: 5 Field: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE) Reference: Well: 13-30, True North Reference Well: 13-30 Vertical (TVD) Reference: 2ES @ 46+28.5 74.5 Reference Wellpath: Plan 12, 13-306 Db: Oracle Site: PB DS 13 Well: 13-12A Rule Assigned: Wellpath: 13-12A V3 Plan: Definitive V1 Inter-Site Error: -- _ Reference Offset Semi-Major Axis Ctr-Ctr No-Go MD TVD MII TVD Ref Offset TFO+AZI TFO-HS Casing/IISDistance Area ft ft ft ft ft ft deg deg irr ft ft 11275.00 8995.71 10825.00 9047.53 83.26 178.39 151.79 266.92 969.36 818.95 11275.00 8995.71 10850.00 9046.96 83.26 178.40 151.90 267.03 992.99 819.04 Major Risk 0.00 ft Allowable Deviation Warning ft -- 150.41 Pass 173.96 Pass 11275.00 8995.71 10875.00 9046.40 83.26 178.40 152.01 267.14 1016.69 819.21 197.48 Pass 11275.00 8995.71 10900.00 9045.84 83.26 178.40 152.11 267.25 1040.45 819.28 221.18 Pass 11280.57 8995.81 10925.00 9045.28 83.25 178.07 152.87 267.34 1064.22 818.32 245.91 Pass 11282.84 8995.86 10950.00 9044.71 83.25 177.93 153.23 267.43 1088.05 817.94 270.11 Pass 11285.03 8995.90 10975.00 9044.15 83.24 177.79 153.58 267.51 1111.91 817.55 294.36 Pass 11287.16 8995.94 11000.00 9043.59 83.24 177.65 153.92 267.60 1135.81 817.16 318.64 Pass 11289.23 .8995.98 11025.00 9043.03 83.24 177.51 154.25 267.67 1159.74 816.78 342.96 Pass 11291.24 8996.02 11050.00 9042.46 83.24 177.37 154.57 267.75 1183.70 816.39 367.31 Pass 11293.19 8996.06 11075.00 9041.90 83.24 177.24 154.87 267.82 1207.69 816.00 391.70 Pass 11300.00 8996.20 11100.00 9041.34 83.23 176.73 155.75 267.88 1231.75 814.48 417.28 Pass 11300.00 8996.20 11125.00 9040.78 83.23 176.73 155.82 267.96 1255.78 814.50 441.28 Pass 11300.00 8996.20 11150.00 9040.21 83.23 176.74 155.89 268.02 .1279.85 814.53 465.32 Pass 11300.00 8996.20 11175.00 9039.65 83.23 176.74 155.96 268.09 1303.95 814.65 489.30 Pass 11300.00 8996.20 11200.00 9039.09 83.23 176.74 156.02 268.16 1328.09 814.67 513.41 Pass 11300.00 8996.20 11225.00 9038.53 83.23 176.75 156.08 268.22 1352.25 814.69 537.56 Pass 11300.00 8996.20 11250.00 9037.96 83.23 176.75 156.14 268.28 1376.45 814.71 561.74 Pass 11307.00 8996.34 11275.00 9037.40 83.16 176.19 157.03 268.32 1400.61 812.83 587.78 Pass 11308.52 8996.37 11300.00 9036.84 83.14 176.06 157.26 268.37 1424.82 812.41 612.41 Pass 11310.01 8996.40 11325.00 9036.28 83.13 175.94 157.49 268.42 1449.06 812.00 637.07 Pass 11311.47 8996.43 11350.00 9035.71 83.11 175.82 157.71 268.47 1473.32 811.59 661.74 Pass Site: PB DS 13 Well: 13-15 Rule Assigned: Major Risk Wellpath: 13-15 V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Avis Ctr-Ctr No-Go Allowable ~ MD TVD MD TVD Ref Offset TFO+AZI TFO-H3 Casing/HSflistance Area Deviation Warning ft ff ft ft ft ft deg deg in ft ft ft 9991.12 8970.32 8825.00 7708.21 41.47 60.15 195.98 9.48 1280.25 135.43 1144.82 Pass 9993.16 8970.26 8850.00 7728.60 41.18 59.75 196.51 10.25 1262.45 138.20 1124.25 Pass 9995.08 8970.20 8875.00 7749.03 40.91 59.37 197.07 11.04 1244.84 141.05 1103.79 Pass 9996.88 8970.14 8900.00 7769.50 40.66 59.02 197.67 11.86 1227.45 143.99 1083.45 Pass 9998.58 8970.08 8925.00 7789.95 40.42 58.69 198.31 12.70 1210.35 147.04 1063.31 Pass 10000.20 8970.03 8950.00 7810.36 40.19 58.44 199.01 13.57 1193.57 150.22 1043.35 Pass 10001.72 8969.98 8975.00 7830.74 39.98 58.10 199.70 14.46 1177.13 153.44 1023.69 Pass 10003.16 8969.94 9000.00 7851.11 39.77 57.82 200.45 15.39 1161.02 156.79 1004.23 Pass 10004.50 8969.89 9025.00 7871.53 39.58 57.57 201.23 16.34 1145.15 160.23 984.93 Pass 10005.75 8969.85 9050.00 7892.01 39.40 57.34 202.06 17.31 1129.53 163.75 965.79 Pass 10006.92 8969.82 9075.00 7912.56 39.24 57.14 202.91 18.31 1114.18 167.36 946.82 Pass 10008.00 8969.78 9100.00 7933.16 39.08 56.94 203.81 19.33 1099.11 171.05 928.06 Pass 10009.02 8969.75 9125.00 7953.74 38.94 56.76 204.74 20.38 1084.42 174.83 909.59 Pass 10009.98 8969.72 9150.00 7974.31 38.80 56.59 205.71 21.47 1070.14 178.71 891.43 Pass 10010.88 8969.69 9175.00 7994.87 38.67 56.44 206.71 22.58 1056.29 182.68 873.61 Pass 10011.71 8969.66 9200.00 8015.41 38.55 56.30 207.76 23.73 1042.89 186.75 856.14 Pass 10012.46 8969.64 9225.00 8035.91 38.44 56.18 208.85 24.90 1029.97 190.92 839.05 Pass 10013.13 8969.62 9250.00 8056.39 38.35 56.08 209.98 26.11 1017.56 195.20 822.36 Pass 10013.73 8969.60 9275.00 8076.84 38.26 56.01 211.15 27.36 1005.68 199.57 806.11 Pass 10014.25 8969.58 9300.00 8097.26 38.19 55.94 212.36 28.63 994.33 204.01 790.32 Pass 10014.72 8969.57 9325.00 8117.69 38.12 55.88 213.60 29.93 983.47 208.50 774.97 Pass 10015.15 8969.55 9350.00 8138.14 38.06 55.83 214.88 31.26 973.11 213.04 760.07 Pass 10015.54 8969.54 9375.00 8158.61 38.01 55.79 216.19 32.62 963.27 217.62 745.65 Pass BP Alaska ~ sus by Anticollision Report 11vTEQ Company: BP Amooo D ate: 4/30/ 2008 Time : 14:49 :37 Page: 6 ii Field: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE) Reference: Well: 13- 30, True North Reference Well: 13-30 .V ertical (TVD) Reference: 2ES @ 4 6+28.5 74.5 !~ Reference Weppath: Plan 12, 13-308 Db: Oracle Site: PB DS 1 3 Well: 13-15 Rule Assigned: Major Risk Wellpath: 13-15 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~Flsflistance Area De~~ation Warning ft ft ft ft ft ft , deg deg in R ft ft 10015.88 8969.53 9400.00 8179.08 37.96 55.75 217.54 34.00 953.97 222.22 731.75 Pass 10016.15 I 8969.52 9425.00 8199.54 37:92 55.73 218.92 35.42 945.28 226.86 718.41 Pass II 10016.37 8969.52 9450.00 8219.99 37.89 55.73 220.33 36.86 937.20 231.54 705.66 Pass ', 10016.52 8969.51 9475.00 8240.42 37.87 55.74 221.78 38.32 929.76 236.24 693.52 Pass 10016.62 8969.51 9500.00 8260.83 37.85 55.77 223.25 39.81 922.97 240.96 682.02 Pass ~, 10016.69 8969.51 9525.00 8281.22 37.84 55.80 224.75 41.32 916.88 245.65 671.23 Pass '~ 10016.73 8969.50 9550.00 8301.57 37.84 55.84 226.28 42.85 911.48 250.31 661.17 Pass 10016.74 8969.50 9575.00 8321.89 37.83 55.89 227.82 44.39 906.80 254.92 651.88 Pass 10016.73 8969.50 9600.00 8342.18 37.84 55.94 229.39 45.96 902.83 259.44 643.39 Pass 10016.66 8969.51 9625.00 8362.49 37.85 56.00 230.97 47.53 899.53 263.89 635.64 Pass 10016.54 8969.51 9650.00 8382.81 37.86 56.07 232.57 49.12 896.89 268.28 628.61 Pass 10016.38 8969.51 9675.00 8403.15 37.89 56.16 234.19 50.71 894.91 272.59 622.32 Pass 10016.16 8969.52 9700.00 8423.51 37.92 56.25 235.81 52.31 893.61 276.77 616.84 Pass 10015.90 8969.53 9725.00 8443.88 37.95 56.35 237.45 53.92 892.98 280.83 612.16 Pass 10015.60 8969.54 9750.00 8464.26 38.00 56.45 239.09 55.52 893.03 284.78 608.25 Pass 10015.26 8969.55 9775.00 8484.66 38.05 56.58 240.73 57.13 893.75 288.61 605.13 Pass 10014.88 8969.56 9800.00 8505.09 38.10 56.70 242.38 58.72 895.12 292.29 602.83 Pass ~i 10014.48 8969.58 9825.00 8525.57 38.16 56.83 244.02 60.32 897.09 295.80 601.30 Pass 'I 10014.07 8969.59 9850.00 8546.12 38.22 56.96 245.66 61.90 899.64 299.14 600.50 Pass 10013.64 8969.60 9875.00 8566.73 38.28 57.10 247.28 63.48 902.77 302.32 600.45 Pass i, 10013.20 8969.62 9900.00 8587.39 38.34 57.23 248.90 65.05 906.48 305.31 601.16 Pass 10012.75 8969.63 9925.00 8608.07 38.40 57.37 250.51 66.60 910.82 308.12 602.70 Pass 10012.29 8969.64 9950.00 8628.77 38.47 57.51 252.10 68.14 915.80 310.76 605.04 Pass 10011.81 I 8969.66 9975.00 8649.48 38.54 57.66 253.68 69.66 921.40 313.52 607.88 Pass ' 10011.32 8969.68 10000.00 8670.21 38.61 57.81 255.24 71.16 927.61 316.09 611.52 Pass i 10010.82 8969.69 10025.00 8690.97 38.68 57.95 256.78 72.64 934.39 318.47 615.92 Pass 10010.31 i 8969.71 10050.00 8711.76 38.75 58.11 258.30 74.09 941.73 320.69 621.04 Pass I~ 10009.79 8969.72 10075.00 8732.58 38.83 58.26 259.79 75.53 949.62 322.74 626.88 Pass i 10009.26 8969.74 10100.00 8753.43 38.90 58.41 261.27 76.94 958.04 324.60 633.44 Pass 10008.68 8969.76 10125.00 8774.29 38.98 58.57 262.73 78.33 967.00 326.33 640.67 Pass 10008.05 8969.78 10150.00 8795.17 39.07 58.76 264.17 79.69 976.47 327.97 648.50 Pass 10007.37 8969.80 10175.00 8816.07 39.17 58.96 265.58 81.03 986.44 329.52 656.92 Pass ~~ 10006.66 8969.82 10200.00 8836.97 39.27 59.17 266.98 82.34 996.91 330.98 665.93 Pass ~; 10005.95 8969.85 10225.00 8857.88 39.37 59.37 268.34 83.62 1007.88 332.26 675.62 Pass i 10000.00 8970.04 10250.00 8878.79 40.22 61.59 270.33 84.89 1019.39 341.74 677.66 Pass i 10000.00 8970.04 10275.00 8899.69 40.22 61.54 271.55 86.11 1031.33 341.68 689.65 Pass ', 10000.00 8970.04 10300.00 8920.61 40.22 61.49 272.75 87.31 1043.71 341.50 702.21 Pass ', 10000.00 8970.04 10325.00 8941.58 40.22 61.44 273.91 88.47 1056.45 341.19 715.26 Pass '~ 10000.00 8970.04 10350.00 8962.61 40.22 61.39 275.06 89.62 1069.54 340.78 728.76 Pass 10000.00 8970.04 10375.00 8983.70 40.22 61.33 276.17 90.73 1082.95 340.26 742.69 Pass 10000.00 8970.04 10400.00 9004.85 40.22 61.28 277.27 91.83 1096.69 339.63 757.05 Pass ', 10000.00 8970.04 10425.00 9026.02 40.22 61.22 278.33 92.89 1110.77 338.91 771.85 Pass I 10000.00 8970.04 10450.00 9047.22 40.22 61.17 279.38 93.94 1125.18 338.11 787.07 Pass ', 10000.00 8970.04 10475.00 9068.46 40.22 61.11 280.39 94.95 1139.92 337.19 802.73 Pass !i 10000.00 8970.04 10500.00 9089.73 40.22 61.05 281.39 95.95 1154.96 336.23 818.72 Pass I ~ 10000.00 8970.04 10525.00 9111.08 40.22 60.99 282.36 96.92 1170.20 335.21 834.99 Pass , ', 10000.00 ' 8970.04 10550.00 9132.50 40.22 60.92 283.31 97.87 1185.66 334.12 851.54 Pass I , ~ 10000.00 8970.04 10575.00 9153.93 40.22 60.86 284.23 98.79 1201.43 332.98 868.44 Pass 10000.00 8970.04 10600.00 9175.36 40.22 60.81 285.14 99.70 1217.51 331.83 885.68 Pass ~' 10000.00 8970.04 10625.00 9196.79 40.22 60.76 286.01 100.57 1233.88 330.63 903.25 Pass 10000.00 8970.04 10650.00 9218.22 40.22 60.71 286.87 101.43 1250.54 329.41 921.13 Pass ~ by ~ BP Alaska Anticollision Re ort p 11VTEQ ~ Company: - BP Amoco Date. 4/30/2008 Time: 14-49:37 Page: 7 i Field: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE)Reference: Well: 13-30, True North Reference Well: 13-30 Vertical. (TVD) Reference: 2ES @ 46+28.5 74.5 Reference Wellpath: Plan 12, 13-306. Db: OraGe Site: PB DS 13 Well: 13-15 Rule Assigned: Major Risk Wellpath: 13-15 V1 Inter-Site Error: 0.00 ft - - ---- - T Reference Offset Semt-Major Axis Ctr-Ctr No-Go Allowable ' MD TVD MD TVD Ref :Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning. I'~ ft ft ft ft ft ft .:..deg deg in ft, ft ft - - -- _ 10000.00 8970.04 10675.00 9239.65 40.22 60.66 287.70 102.26 1267.48 328.16 939.32 Pass 10000.00 8970.04 10700.00 9261.08 40.22 60.61 288.51 103.07 1284.67 326.88 957.80 Pass ', 10000.00 8970.04 10725.00 9282.50 40.22 60.56 289.30 103.86 1302.13 325.58 976.55 Pass 9993.23 8970.26 10750.00 9303.93 41.17 63.29 290.91 104.65 1319.75 335.06 984.70 Pass i 9992.69 8970.27 10775.00 9325.36 41.24 63.47 291.72 105.40 1337.67 334.56 1003.11 Pass ~ i 9992.16 8970.29 10800.00 9346.79 41.32 63.65 292.51 106.13 1355.81 334.04 1021.77 Pass 9991.64 8970.31 10825.00 9368.22 41.39 63.83 293.28 106.84 1374.17 333.49 1040.68 Pass 9991.13 8970.32 10850.00 9389.65 41.46 64.01 294.04 107.53 1392.73 332.92 1059.81 Pass 9990.62 8970.34 10875.00 9411.08 41.53 64.18 294.77 108.20 1411.49 332.34 1079.15 Pass 9990.51 8970.34 10880.50 9415.79 41.55 64.22 294.93 108.35 1415.64 332.20 1083.44 Pass ~ Site: PB DS 13 Well: 13-30 Rule Assigned: Major Risk Wellpath: 13-30A V9 Inter-Site Error: 0.00 ft i - _ ___ - -- --_.~ Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TV"D MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft _ ft ft deg , deg in ft ft ft 9700.00 8941.81 9700.00 8941.81 70.23 70.23 208.45 0.00 4.500 0.00 334.87 -334.87 FAIL 9724.99 8955.73 9725.00 8955.55 69.14 69.12 134.37 285.92 4.500 0.77 445.45 -444.68 FAIL 9749.67 8966.69 9750.00 8968.21 66.60 66.58 93.27 244.82 4.500 3.83 336.06 -332.23 FAIL 9773.05 8973.44 9775.00 8979.67 64.93 64.88 81.74 233.29 4.500 10.66 306.24 -295.59 FAIL ~ 9794.28 8976.35 9800.00 8989.97 64.20 64.14 78.13 229.68 4.500 21.09 316.33 -295.24 FAIL 9813.83 8976.36 9825.00 8999.33 63.59 63.55 76.36 228.57 4.500 34.73 327.94 -293.20 FAIL 9835.57 8975.60 9850.00 9007.63 61.23 61.19 74.63 229.45 4.500 49.30 321.35 -272.05 FAIL I, 9858.14 8974.81 9875.00 9014.23 58.68 58.62 74.02 231.55 4.500 63.44 317.90 -254.46 FAIL ', 9881.76 8974.00 9900.00 9019.30 55.88 55.80 73.51 233.88 4.500 76.90 312.81 -235.90 FAIL '~ 9906.45 8973.15 9925.00 9023.02 52.82 52.71 72.91 236.23 4.500 89.77 305.19 -215.41 FAIL 9932.03 8972.28 9950.00 9025.34 49.51 49.38 72.32 238.72 4.500 102.26 295.27 -193.01 FAIL 9958.58 8971.39 9975.00 9026.21 45.96 45.80 71.74 241.32 4.500 114.30 282.78 -168.47 FAIL ii '. 9986.61 8970.47 10000.00 9026.60 42.10 41.89 70.51 243.46 4.500 125.70 266.27 -140.57 FAIL 10016.34 8969.52 10025.00 9026.02 37.89 37.62 68.90 245.42 4.500 135.91 246.48 -110.56 FAIL 10047.16 8968.56 10050.00 9024.51 33.46 33.11 67.18 247.40 4.500 145.66 224.33 -78.67 FAIL ', 10069.36 8967.89 10075.00 9022.58 33.47 33.07 69.21 249.46 4.500 155.92 225.93 -70.01 FAIL ', 10085.84 8967.45 10100.00 9020.75 35.89 35.49 73.15 251.43 4.500 167.38 240.93 -73.55 FAIL 10101.16 8967.09 10125.00 9018.92 38.12 37.72 76.87 253.32 4.500 180.60 254.98 -74.38 FAIL 10114.74 8966.81 10149.97 9017.16 40.08 39.68 80.30 255.13 4.500 196.21 267.54 -71.33 FAIL ', 10126.87 8966.58 10175.00 9015.57 41.82 41.41 83.37 256.74 4.500 213.64 278.72 -65.08 FAIL ' 10137.78 8966.40 10200.00 9014.25 43.36 42.95 86.04 258.11 4.500 232.31 288.59 -56.28 FAIL Ii 10147.11 8966.27 10225.00 9013.10 44.68 44.26 88.36 259.31 4.500 252.50 297.01 -44.51 FAIL 10155.62 8966.16 10250.00 9011.82 45.86 45.44 90.44 260.38 4.500 273.28 304.57 -31.29 FAIL 10162.88 8966.07 10275.00 9010.22 46.86 46.43 92.32 261.39 4.500 294.94 311.01 -16.07 FAIL 10168.57 8966.02 10300.00 9008.19 47.64 47.21 93.98 262.37 4.500 317.57 316.11 1.47 Pass 10172.82 8965.98 10325.00 9005.90 48.22 47.79 95.40 263.28 4.500 340.97 319.97 21.00 Pass 10176.24 8965.95 10350.00 9003.79 48.68 48.25 96.57 264.05 4.500 364.80 323.03 41.77 Pass 10179.38 8965.93 10375.00 9001.75 49.10 48.67 97.61 264.71 4.500 388.78 325.76 63.02 Pass 10182.35 8965.90 10400.00 8999.75 49.50 49.06 98.55 265.30 4.500 412.84 328.30 84.54 Pass ~, 'I 10185.16 8965.89 10425.00 8997.85 49.87 49.44 99.40 265.81 4.500 436.99 330.67 106.32 Pass j 10187.81 8965.87 10450.00 8996.11 50.22 49.79 100.15 266.24 4.500 461.22 332.88 128.35 Pass ~ I 10190.32 8965.86 10475.00 8994.52 50.56 50.12 100.83 266.62 4.500 485.53 334.94 150.59 Pass 10192.68 8965.84 10500.00 8993.10 50.87 50.43 101.43 266.94 4.500 509.91 336.87 173.05 Pass 10194.63 8965.84 10525.00 8991.92 51.13 50.69 101.93 267.20 4.500 534.46 338.45 196.00 Pass 10196.13 8965.83 10550.00 8991.00 51.33 50.88 102.32 267.42 4.500 559.16 339.67 219.50 Pass r by ~ BP Alaska Anticollision Re ort l~ 1NTEQ Company: BP Amoco Date: 4!30/2008 Time: 14:49:37 Page: 8 I Fieid: Prudhoe Bay Reference Site: PB DS 13 Co-ordinate(NE) Referencez Well: 13-30, True North Reference Wep: 13-30 Vertical (TUD) Reference: 2ES @ 46+28.5 74.5 Referenee Wellpath: Plan 42, 13-308 Ub: Oracle. Site: PB DS 13 Well: 13-30 Rule Assigned: Major Risk Wellpath: 13-30A V9 Inter-Site Error: 0.00 ft Reference Offset ' Semi-Major Axis. Ctr-Ctr No-Go Allowable ~I MD TVD MD TVD Ref Offset TFO+AZI TFO-HS' Gasing/HSflistance Area Deviation Waruing ft ft ft ft ft' 'ft deg deg in ft ft ft -- ----- --- -- I ', 10197.20 8965.82 10575.00 8990.30 51.47 51.02 102.63 267.60 4.500 583.99 340.54 243.45 Pass ', 10200.00 8965.81 10600.00 8989.60 51.84 51.39 103.13 267.76 4.500 608.89 342.75 266.13 Pass 10200.00 8965.81 10625.00 8988.58 51.84 51.39 103.31 267.94 4.500 633.75 342.78 290.98 Pass ', 10200.00 8965.81 10650.00 8987.20 51.84 51.39 103.51 268.14 4.500 658.59 342.80 315.79 Pass ', 10200.00 8965.81, 10675.00 8985.47 51.84 51.39 103.72 268.35 4.500 683.40 342.82 340.58 Pass '~ 10200.00 8965.81 10700.00 8983.63 51.84 51.39 103.92 268.56 4.500 708.21 342.83 365.38 Pass 10200.00 8965.81 10725.00 8982.05 51.84 51.42 104.10 268.73 4.500 733.05 346.42 386.63 Pass 10200.00 8965.81 10750.00 8980.49 51.84 51.45 104.26 268.89 4.500 757.91 353.67 404.23 Pass j 10200.00 8965.81 10753.00 8980.30 51.84 51.46 104.27 268.91 4.500 760.89 354.54 406.35 Pass Site: PB DS 13 Well: 13-30 Rule Assigned: Major Risk Wellpath: Plan 3, 13-30C VO Plan: Plan #3 VS Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref :Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ' ft ft ft 9699.54 8941.55 9700.00 8939.61 70.29 70.32 135.85 287.33 4.125 7.95 451.78 -443.84 FAIL ~I 9723.53 8954.97 9725.00 8949.31 69.30 69.33 143.59 295.14 4.125 15.70 448.64 -432.94 FAIL 9747.92 8966.04 9750.00 8955.34 66.76 66.80 145.00 296.55 4.125 25.87 427.62 -401.75 FAIL 9772.27 8973.28 9775.00 8957.52 64.97 65.01 143.78 295.33 4.125 37.72 408.16 -370.45 FAIL 9796.44 8976.47 9800.00 8955.79 64.18 64.22 142.34 293.89 4.125 51.12 390.46 -339.34 FAIL 9819.71 8976.15 9825.00 8950.32 62.97 63.04 140.15 293.07 4.125 65.96 375.99 -310.02 FAIL 9841.02 8975.41 9850.00 8943.56 60.63 60.73 137.11 292.58 4.125 83.00 364.17 -281.17 FAIL 9860.33 8974.74 9875.00 8936.54 58.42 58.53 134.15 291.94 4.125 102.28 353.38 -251.10 FAIL 9877.07 8974.16 9900.00 8929.49 56.45 56.56 131.41 291.21 4.125 123.52 343.97 -220.45 FAIL 9890.53 8973.69 9925.00 8922.61 54.80 54.92 129.02 290.44 4.125 146.38 336.42 -190.04 FAIL I, 9899.80 8973.38 9950.00 8916.12 53.66 53.78 127.11 289.64 4.125 170.43 331.64 -161.21 FAIL 9903.88 8973.24 9975.00 8910.18 53.14 53.27 125.84 288.86 4.125 195.15 330.28 -135.13 FAIL 9905.29 8973.19 10000.00 8904.42 52.96 53.09 125.04 288.22 4.125 220.03 330.52 -110.50 FAIL 9904.85 8973.20 10025.00 8898.67 53.02 53.15 124.59 287.73 4.125 244.94 331.80 -86.86 FAIL 9903.63 8973.24 10050.00 8893.40 53.17 53.30 124.23 287.22 4.125 269.83 333.63 -63.81 FAIL 9903.27 8973.26 10075.00 8889.08 53.22 53.35 123.66 286.61 4.125 294.64 335.02 -40.38 FAIL 9904.12 8973.23 10100.00 8885.72 53.11 53.24 122.86 285.91 4.125 319.36 335.64 -16.28 FAIL 9906.78 8973.14 10125.00 8883.32 52.77 52.90 121.78 285.15 4.125 343.96 334.97 8.98 Pass 9912.40 8972.94 10150.00 8881.88 52.05 52.19 120.28 284.32 4.125 368.40 332.14 36.26 Pass it 9923.23 8972.58 10175.00 8881.42 50.67 50.80 118.09 283.43 4.125 392.64 325.37 67.27 Pass 9939.52 8972.03 10200.00 8881.45 48.52 48.67 115.26 282.56 4.125 416.81 314.00 102.82 Pass 9962.06 8971.28 10225.00 8881.49 45.49 45.65 111.75 281.75 4.125 441.08 297.15 143.92 Pass 10012.14 8969.65 10250.00 8881.56 38.49 38.69 104.90 280.92 4.125 465.33 256.77 208.56 Pass 10060.36 8968.16 10275.00 8881.65 32.14 32.38 98.87 280.19 4.125 489.21 219.87 269.33 Pass 10062.78 8968.08 10300.00 8881.75 32.50 32.74 98.65 279.69 4.125 513.30 222.53 290.77 Pass 9766.79 8971.99 10325.00 8881.87 65.29 65.35 128.44 279.99 4.125 536.89 425.01 111.88 Pass 9741.27 8963.39 10350.00 8882.00 67.39 67.43 127.68 279.23 4.125 558.97 432.85 126.12 Pass 9718.78 8952.39 10375.00 8882.13 69.74 69.76 126.79 278.34 4.125 580.40 437.50 142.90 Pass 9707.65 8946.17 10400.00 8882.26 70.03 70.05 125.86 277.41 4.125 601.30 436.23 165.07 Pass Alaska Department of Natural Resources Land Administration System Page 1 of • ~~k~ _, ~.- i '._... ~ t_:__~ E ...: fZerorder's Search State Cabins ~~#u!"~~ ~3~u~5 _.~.,_.._. AI+aS~C a C File Type: ADL ~ File Number: 28314 ~ Printable Case Fii.e_Surnmary See Township, Range, Section and Acreage? New search` ~' Yes No ~ _ ~~. _ ~ _ _ _~_ LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract _. I'rle: ~UL 2831-I '''''.~ Sea;cn_for Status Plat Updates ;~s cif O~IO(i'~0(lti Customer~.~ 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 C'crse Type: ;~~~~ O1L & GAS LEASE COMP DNR U~zit: 780 OIL AND GAS File Localiof~: DOG DIV OIL AND GAS Case Staters: 35 ISSUED Status Dute: 08/11/1965 Total Acr°es: 2560.000 Dute Inituated: OSl2SA 965 Office of Prirrut~~t~ Responsibility; DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype : ~iS NORTH SLOPE 1_ast Transaction: AA-NRB ASSIGNMENT APPROVED lYl~f~ir~rr-rrr.~ l! Township: OION R~o~~c•: Ol4E Section: IS S'ectioir:~crc>s~ 61U Search 'Fiats MF~ru%icm: C 7~n~~nship: OlON Ran~c~.~ 01-11: S'c~ctr~~ir: 16 Sec~iurt.lc~~~c~~~: 6~0 Mcrr~l'iutz:~ U 7~nnnship: OION Ran;~rc.~ U I ~l~ )'~~c~ir~rt: 21 SE~~~~inrr .lc~rc~: (x-10 Meric~icrn: LI Township: O1ON Rcrn,~rc~: 01 ~l: .S~°~~~iu~~.~ 22 Section ,1~~r~~~- E~~10 Lc;;al Description 0~-Z8-1965 *'~` * SALE NOTICE LEGAL DESCRIPTION C1=1-136 f10N, R1~{E, U~LI15, 16, 21, 2Z 2560.00 Last updated on 05/06/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28314&... 5/6/2008 TRA-1~TSMITTAL LETTER CHECKLIST WELL NAME ~~~ J3 -~~~ PTD# ~o~a ~~~ Developments Service Exploratory Stratigraphic Test Non---~~Conventional Well FIELD: ~,~1'/~DE ~~ly POOL: fe!/~/~OE/~,t~~ ~ 4 Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~ FOR APPROVAL LETTER APPLIES tvIULTi LATERAL The permit is for a new wellbore segment of existing well -~ (If last two digits in permit No. ,API No. 50- - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and togs acquired for the pilot hole must be clearly differentiated in both well name ( PI-I) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to ful[ compliance with ZO 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 pirotest 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 throu h tar et zones. Non-Conventions! please note the following special condition of this permit: Well production or production testing of coal bed mejfiane is not allowed for (name of weR) until after (Corapanv Narae) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SComganv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: vi Inooa WELL PERMIT CHfCKLI$T Field & Pool Well Name: PRUDHOE BAY UNIT 13-308 Program DEV Weil bore sag ^ PTD#:2080780 Company BP EXPLORATION (9LASKA} INC Initial Ctass(fype DEV 1 PEND GeoArea 890 Unit 11650 t)nlOff Shore 4n Annular Disposal ^ Administration 1 Petmitfeeattached--- - ------ ~----- -- - - -~A - - - --- -- - -- ---- -- - -- - - ------ 2 Lease number,aPProRnate - --------- - --- -- -- - Yes - - -- -- -- - --- -- - - - - ------------------------------- 3 Uniqueweli_rtameandoumber______--________________ ____---..Yes.-----_ _--- ---------------------------------------------------------------- 4 WQllfocatedina_defnedpool__-___________.____________ ________Yes--_-___ PrudhoeBayFieldlPrudhoe Bay POOL____-__-__- --------------------------------- 5 Weil located proper distance from drilling urtit.baundary_ - _ - - - - - - - - - - - - - _ -Yes - _ _ _ _ - - _ _ - --------------------------------------------------------- 6 Welilocatedproperdistanceftomotherwetls-----------------_- _________Yes_____-_ _--_.___--______--___-____- ---------------------------------------- 7 Sufficient acreege_ayailablein_drillit>gunit--------------------- ----------Yes------ 2569ACres•---------------------------------------------------------- 8 Ifdeviated,is-wellboreplai-induded_--_--___-------------- ---- --.-Yes------- ------------------___--- ----------------------------------------- 9 OPemtororllyaffectedParfY----------------------------- ----------Yes-._-- -- ---------------------------------------- - ------------------------ 10 Openatorhas_appropriatekondin}orCe---------------------- ---------Yes------- QlanketBond#6184183•-----------------------------------,---------------- 11 Petmhc~tlbeissuedwitbout4onservationorder----------------- ----------Yes------- ------------------------------------------__..----------------.-- Appr Date 12 Permitcan be issued without administrativ_e_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ Yes - _ - - . - - - - - . - _ _ - ACS 51612008 13 CanpertnitbeaPRrovedbeforSl5-daywait--------------------- ----------Yes------- ------------------------------------------- 14 WelilocatedwithinareaandstcaiaeuthorizedbY-Injectionprdet#(putl0#In- comments)-(For- NA------- ----------------------------------------------------------------- 15 Ali wells withinll4_roite_area_ofreyiewidentified(Fo[se[vicewellorlly)---- ----____--NA________ _________________________---_--_--------------------------_ ---- 16 P~-producedirljedor.durationofPre~roductionlessthan3months(Eorservicewellonly)---NA-------- ---------.------------------------------------------------------ 17 Nonconven,gasconformstoA631.05.039(}.t.A),Q.2.A-D)------------ -----------htA-------- -------------------------------------------- Engineering 18 Conductor string-prov_ided------------------------------- ---------- NA-------- Conductorset_inDS13-39(182-191).-------------------------------------------- 19 Surface casingprotects aII known USDWS - _ _ - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ No aquifers, A(Q 46,_Gonciusian-5. _ _ _ _ _ - _ _ _ _ _ _ _ _ - - - - - - - ------------------------- ~ 20 CMT_v_olat~quatetocirculate_onconductor&surf-csg-------------- ---------- NA__ -_--- Surface casing set in t3r30,-______,-____----_---_---_--__--_ ---------------- 21 CMTv_oladsquate-t9 tie-inlongstringfo_sudcsg_________________ ___-__--_-NA_.-__--_ Production-casiogget in-13,30.-____________--_-_----_---___-_- ------------------ 22 CMTwillcoveraHkocwrn-productivehorizons-------------------- ---------Yes------- -------.-------.------------------------------------ 23 Casing dasgns adequate fot C, T l3 &Permafrost- - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tartkage_or reserve pit - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - _ - _ Yes - - - . - - _ Rig equipped with steel pits, No_reserve pii planned._ Alt waste-to approved disposal well(s), _ - - - - - - - _ - - - _ 25 Ifa-re~dtilt,has-a 10.40$forebandonmentbesr~aPP-roved------------ --- _--Yes-. _--- 308-167---------------------------------------------------_---- 26 Adequa~wehboreseparation-P%Posed- ------ - - - ----------Yes---- -- - --- --- --- -- --- - -------- - -- -- --- 27 Ifdiverterrequired~doesit_rtieetrsgulations-------------------- -------- NA------- SQPStackwillalteadY-6e}nplace,---------------------------------------------- Appr Date 28 Drihing fluid- program schematic & equip list-adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ Yes - - _ - - - _ Maximum expec#ed formation pressure 7,3 EMW- Planned MUy 8.6ppg. _ _ _ _ _ _ - - _ _ - _ _ - _ - - - _ TEM 5/1312008 29 BQP)=s,.dotheymeetregulation------ - - -- -- --- - - - Yes - - -- - - ---------- - ------ -- - -------- - r,~~d ~ 30 BOP):_press rating approp[iate; Iasi to_(put prig in comments)- - - - - - - - - - - - - - - - - - - -Yes - - _ - - - _ MASP 4aiculated at 2465 psi, 3500-psi_BOP testplanned, _ - - _ - _ - - - - - - - _ - ~ 31 Choke-manifo~ complieswiAPI-RP-53 GMay 84)- - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work willoccutwithoutoperationshukd4w_n____-____________ ___________Yes------- -----------------------------------------------------------__---- 33 is presence of H2$ gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ . DS 13 is an H2S DS, Mud shouki_preclude H2S on rig. Rig has sensors and alarms, _ - - - - - _ _ _ _ _ _ _ _ _ _ 34 Mechanical condition of wellswhhinAQRverified(Fo(senncewellonly)--- ----------- NA-------- ----------------------------------------------------------------- Geology 35 Pe[mitcaot~eissuedwlohydrogQnsulfidemeasutes_------------ ----------- N°-------- --------------------------------------------------------------- 36 Data-presented onpolentiafovelgressurezones__------------- -_-- --.--Yes------ --------------------------------------------___-- ---------------- Appr Date 37 SeismicanatysisofshaHOwgaszones________________--__ __-______-_KA___--___ ___-___--__---___-----------------------_----- ------------------ ACS 516!2008 38 Seabed condition survey (i#off-shore)_________________--__- -__-___.___ NA-___ 39 Contactname/phongforweeky_progressrepods.(expioratoryonly]____-_ _-____Yes----- GregSarber-564-4330-----------------------------------------------_---- G~logic Engineering Public Date C Date: i Daie Commissioner: m oner: Commiss ~~i~~ ~i~~.~o8 • Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ ~ **** REEL HEADER **** MWD 08/09/30 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/06/24 2081739 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!ii!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!~~~~!! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9462.0000: Starting Depth STOP.FT 11703.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 13-30B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 13' 9.320"N 148 deg 30' 6.339"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 24 Jul 2008 API API NUMBER: 500292076802 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 24 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 74.5 DMF DF EKB .F 0 EDF .F 74.5 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~C~is-per t ~-Ob'~ ~ ~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Sperry Sun GR MWD dated 22 Nov 2003 per Daniel Schafer with BP Exploration (Alaska), Inc. Depth shifting was completed above the Kick Off Point (KOP) of 9640 feet carrying the final shift at KOP to bottom logged interval. (8) Tied to 13-30 at 9593 feet MD (8794.2 feet TVDSS). (9) The sidetrack was drilled from 13-30 through a milled window in a 4 1/2 inch liner. Top of window 9634 ft.MD (8824.1 ft.TVDSS) Bottom of window 9644 ft.MD (8831.3 ft.TVDSS) (10) The interval from 11662 feet to 11703 feet MD (8929.2 feet to 8925.3 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9537.73, 9536.49, ! -1.24316 9552.25, 9551.83, ! -0.414062 9555.35, 9555.35, ! 0 9562.2, 9561.78, ! -0.414062 9566.34, 9567.17, ! 0.829102 9585.82, 9586.86, ! 1.03613 9593.07, 9592.66, ! -0.414062 9596.6, 9595.35, ! -1.24414 9598.05, 9597.63, ! -0.415039 9600.74, 9599.5, ! -1.24316 9602.2, 9601.16, ! -1.03613 9614.63, 9612.56, ! -2.07227 9620.44, 9619.19, ! -1.24414 9623.75, 9621.89, ! -1.86523 9625.41, 9623.34, ! -2.07324 9629.56, 9627.49, ! -2.07324 9638.05, 9635.98, ! -2.07324 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 92 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 13-30B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 13-30B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!! " " !!!~! " !!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Sperry Sun GR MWD dated 22 Nov 2003 per Daniel Schafer with BP Exploration (Alaska), Inc. Depth shifting was completed above the Kick Off Point (KOP) of 9640 feet carrying the final shift at KOP to bottom logged interval. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM ----------- ODEP -------- - ------- GR GR GRAX - - 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 125 Tape File Start Depth = 9462.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 138 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 C~ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 13-30B MADPASS 5.xtf LCC 150 CN BP Exploration (Alaska) WN 13-30B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** ~~!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Sperry Sun GR MWD dated 22 Nov 2003 per Daniel Schafer with BP Exploration (Alaska), Inc. Depth shifting was completed above the Kick Off Point (KOP) of 9640 feet carrying the final shift at KOP to bottom logged interval. *** INFORMATION TABLE: LIFO MNEM ----- CHAN DIMT ------------------ CNAM - ODEP GR GR ----------- GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX RPD RPD RPCLX RPS RPS RPCHX * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 125 0.0 0.0 0.0 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9462.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 138 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .003 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 13-30B MADPASS.xtf ~ i LCC 150 CN BP Exploration (Alaska) WN 13-30B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MADPass data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 I OHMM 4 4 24 Total Data Records: 244 Tape File Start Depth = 9512.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 257 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .004 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 13-30B.xtf LCC 150 CN BP Exploration (Alaska) WN 13-30B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: LIFO MNEM ----- CHAN DIMT ------------------ CNAM ------- ODEP GR GR ---- GRAX ------------------ 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 244 Tape File Start Depth = 9512.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 257 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/06/24 2081739 O1 **** REEL TRAILER **** MWD 08/09/30 BHI 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes L~ Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9462.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9462.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 114.0080 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 90.8215 14.5803 2.8907 2000.0000 2000.0000 74.6747 9800.0000 28.9357 99.4142 5.3532 6.1223 6.1283 6.3494 9900.0000 46.6643 100.2168 7.6196 9.8517 9.3123 8.8343 10000.0000 55.7146 105.2537 4.4989 4.5277 4.2977 4.0760 10100.0000 44.0227 110.0475 4.4019 3.8766 3.7380 3.2529 10200.0000 36.6832 97.7832 5.1380 5.1522 4.6772 4.0599 10300.0000 39.5387 104.9767 5.3349 5.6012 4.7103 3.8527 10400.0000 40.1752 108.6693 5.3322 6.4561 6.4039 6.6760 10500.0000 38.9336 120.9869 5.3067 5.2525 4.7972 4.0735 10600.0000 38.2408 142.9461 5.6170 6.3359 6.6671 7.1862 10700.0000 44.2979 116.3277 5.0983 6.4624 6.5406 7.3119 10800.0000 45.3752 90.6168 5.0578 6.2949 6.3680 7.1010 10900.0000 70.9963 94.3070 6.6358 10.2561 10.9492 13.9690 11000.0000 23.8496 115.9000 4.0802 3.9800 3.8623 3.5492 11100.0000 31.7357 112.7307 3.1977 3.0076 3.1706 3.2809 11200.0000 35.2146 113.8467 4.2526 4.2881 4.4151 4.7611 11300.0000 26.1781 120.0734 9.2122 18.7810 i 20.5440 28.9572 11400.0000 206.1101 101.6475 15.7714 17.2963 11500.0000 151.3088 58.6664 14.5464 15.0275 11600.0000 60.6920 65.8322 4.7012 5.2123 11700.0000 -999.2500 66.3277 -999.2500 -999.2500 11703.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9462.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 10.0596 9.6942 3.8828 -999.2500 -999.2500 19.4126 16.2218 4.2869 -999.2500 -999.2500 • • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9462.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9462.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 114.0080 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 90.8215 14.5803 6.3876 44.4516 78.7060 72.9598 9800.0000 28.9357 99.4142 5.5500 6.1134 6.1731 6.1745 9900.0000 46.6643 100.2168 7.7428 9.0058 8.3306 7.3381 10000.0000 55.7146 105.2537 4.5755 4.7472 4.4086 4.2117 10100.0000 44.0227 110.0475 4.4672 3.9700 3.6345 3.0817 10200.0000 36.6832 97.7832 5.2742 5.7600 4.7255 4.0742 10300.0000 39.5387 104.9767 5.4486 5.7358 4.8028 3.9655 10400.0000 40.1752 108.6693 5.3714 6.1428 5.8589 5.6964 10500.0000 38.9336 120.9869 5.3358 5.0472 4.8058 4.1000 10600.0000 38.2408 142.9461 5.7300 6.1931 6.3686 6.4986 10700.0000 44.2979 116.3277 5.1572 6.2003 6.4758 7.1503 10800.0000 45.3752 90.6168 5.0814 6.3669 6.1786 6.6945 10900.0000 70.9963 94.3070 6.6300 9.9900 10.0525 12.3553 11000.0000 23.8496 115.9000 4.1228 4.4725 3.9569 3.6797 11100.0000 31.7357 112.7307 3.2086 3.0100 3.2000 3.3314 11200.0000 35.2146 113.8467 4.2614 4.3600 4.4014 4.7100 11300.0000 26.1.781 120.0734 9.0539 16.8610 i 19.9400 28.2064 11400.0000 206.1101 101.647 15.7055 16.0131 11500.0000 151.3088 58.6669 15.0239 15.6593 11600.0000 60.6920 65.8322 4.6445 5.1917 11700.0000 -999.2500 66.3277 -999.2500 -999.2500 11703.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9462.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 10.0900 10.0128 3.8486 -999.2500 -999.2500 17.8545 15.1364 3.9637 -999.2500 -999.2500 • • Tape Subfile 4 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9512.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9512.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 169.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 127.1000 19.1000 6.8300 81.4900 38.6100 46.6400 9800.0000 39.9000 104.2000 5.5800 6.3500 6.0900 5.9900 9900.0000 49.5000 129.8000 7.7700 9.5300 8.8700 8.1300 10000.0000 53.8000 101.3000 4.4600 4.7300 4.2700 4.1400 10100.0000 41.3000 108.0000 4.5100 3.9600 3.7300 3.1800 10200.0000 42.9000 96.5000 5.1100 5.5400 4.6000 4.0200 10300.0000 37.2000 111.4000 5.4000 5.8000 4.7400 3.9100 10400.0000 42.1000 109.1000 5.3800 6.1900 6.2500 6.4000 10500.0000 40.6000 114.8000 5.4700 5.1800 4.9000 4.1100 10600.0000 43.3000 129.7000 5.6800 6.3400 6.2900 6.3900 10700.0000 38.9000 118.8000 5.2600 6.3800 6.3800 6.8800 10800.0000 49.1000 96.7000 5.0300 6.2900 6.1900 6.8000 10900.0000 74.0000 88.7000 6.5500 9.8600 9.8300 11.6800 11000.0000 29.9000 117.8000 4.0100 4.1800 3.7600 3.4400 11100.0000 31.5000 116.6000 3.2200 3.0200 3.1800 3.2500 11200.0000 28.2000 93.6000 4.2400 4.2800 4.4200 4.8300 11300.0000 24.6000 141.2000 8.0700 19.0600 14.6300 19.9800 11400.0000 206.0000 101.4000 10.0100 18.5500 16.2200 16.6500 11500.0000 152.8000 59.5000 14.4600 15.0300 11600.0000 64.9000 56.8000 4.3700 4.5700 11700.0000 -999.2500 66.5000 -999.2500 -999.2500 11703.0000 -999.2500 68.2000 -999.2500 -999.2500 Tape File Start Depth = 9512.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 9.6300 3.9500 -999.2500 -999.2500 15.6300 4.2200 -999.2500 -999.2500 • Tape Subfile 5 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9512.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9512.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 169.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 127.1000 19.1000 3.9750 1894.6709 39270.0000 53.1720 9800.0000 39.9000 104.2000 5.4390 6.3450 6.2330 6.3520 9900.0000 49.5000 129.8000 7.6210 9.8230 9.3810 9.0020 10000.0000 53.8000 101.3000 4.3920 4.3000 4.2110 4.0470 10100.0000 41.3000 108.0000 4.4820 3.9460 3.7880 3.2430 10200.0000 42..9000 96.5000 4.9940 4.9610 4.4770 3.8610 10300.0000 37.2000 111.4000 5.2650 5.4620 4.7060 3.9040 10400.0000 42.1000 109.1000 5.3400 6.5290 6.5310 6.9530 10500.0000 40.6000 114.8000 5.4450 5.5050 4.9440 4.1790 10600.0000 43.3000 129.7000 5.5790 6.2800 6.5070 6.8070 10700.0000 38.9000 118.8000 5.2150 6.3960 6.4970 7.0750 10800.0000 49.1000 96.7000 4.9930 6.1920 6.3680 7.1620 10900.0000 74.0000 88.7000 6.6360 10.4600 11.2380 14.7490 11000.0000 29.9000 117.8000 3.9980 3.8590 3.6960 3.3790 11100.0000 31.5000 116.6000 3.2040 3.0190 3.1410 3.2040 11200.0000 28.2000 93.6000 4.2370 4.2630 4.3910 4.7660 11300.0000 24.6000 141.2000 8.3280 13.6100 16.9580 24.6870 11400.0000 206.0000 101.4000 9.7380 22.9020 • 18.4480 20.1950 11500.0000 152.8000 59.5000 10.6310 23.1090 20.6200 11600.0000 64.9000 56.8000 4.0520 4.2370 4.2580 11700.0000 -999.2500 66.5000 -999.2500 -999.2500 -999.2500 11703.0000 -999.2500 68.2000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9512.000000 Tape File End Depth = 11703.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 450.7940 4.0180 -999.2500 -999.2500 r: • Tape Subfile 6 is type: LIS
