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Home My WebLink About208-128Image Pro~ct Well History File Cov~age 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. ~~~~ ~p~,~ Well History File Identifier " ' aone Two-sided III IIIIIIIIIII II III ^ Rescan Needed Organ-z~ng ~ ) ^ RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q ~s~ Pro "ect Proofing J II I II I) II I I III I I III BY: Maria Date: /o /s/ I ~~ ~ Scannin Pre aration g p _~ x 30 = d =TOTAL PAGES-- + ~ (Count does not include cover sheet) ~~ BY: Maria Date: 3 4 - / D /s/ Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ~ ~ ' r ~ ~s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s/ Scannin is complete at this point unless rescanning is required. II I II II II I II II I I III 9 Rescanned III IIIIIIIIIII VIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III VIII III III I I 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 3/3/2010 Permit to Drill 2081280 Well Name/No. PRUDHOE BAY UNIT Y-09AL1-01 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20579-61-00 MD 16128 TVD 9044 Completion Date 10/21/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well tog Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / .y meairrnn ~.u~~~~~ name ....a.` .......... ~.., ~.~.~~ ..~..r .... ...,.,,.... ...,........ - ED D Asc Directional Survey 14471 16128 Open 11/14/2008 Diskette in PBU Y-09L1 {208-127) folder pt Di~ctional Survey 14471 16128 Open 11/14/2008 ~ D, C Las 1747 Induction/Resistivity 14002 16128 Open ROP, RPDRAD RAM ~pt LIS Verification 13999 16131 Open 3/19/2009 LIS Veri, GR, ROP, RAD, / ~ RAS, RPD, RPS }'ED C Lis 17695 ~sfnduction/Resistivity 13999 16131 Open 3/19/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 14283 16128 Open 3/19/2009 MD MPR, GR 17-Oct-2008 og Induction/Resistivity 5 Col 14283 16128 Open 3/19/2009 TVD MPR, GR 17-Oct-2008 ~og Gamma Ray 25 Col 14283 16128 Open 3/19/2009 MD GR 17-Oct-2008 Log See Notes 5 Col 13990 16140 Open 3/19/2009 Depth Shift Monitor Plot Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 313/2010 Permit to Drill 2081280 Well Name/No. PRUDHOE BAY UNIT Y-09AL1-01 Operator BP EXPLORATION (ALASI(Ey INC MD 16128 TVD 9044 Completion Date 10/21/2008 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y ~.J Daily History Received? N Chips Received? ~,~ Formation Tops ~/ N Analysis Received? API No. 50-029-20579-61-00 UIC N Comments: ~a Compliance Reviewed By: Date: i • ®/ ®® BAKER NY!'sNES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY I3Y EXYLUKA'I'lUN (ALASKA) 1NC CUUN'1'Y NUR'1'H SLUYE BUKUU(iH WELL NAME Y-09AL1-O1 STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 3/16/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2232624 Copies of Copies Digital Copies of Copies Digital Each Log oCFilm 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 I Company EXXON MOBIL PRODUCTION CO Company Person FILE RGGNI 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 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, February 23, 2009 12:34 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU Y-09AL1 & Y-09AL1-01 /PTD # 208-127 &PTD # 208-128 H i Art, Please reference the following well: Well Name: PBU Y-09AL1 & Y-09AL1-01 Permit #: 208-127 & 208-128 API #: 50-029-20579-60-00 & 50-029-20579-61-00 Y-09AL1 Top Slotted Section MD: 14508' Y-09AL1 Bottom Slotted Section MD: 15598' Y-09AL1-01 Top Slotted Section MD: 14322' Y-09AL1-01 Bottom Slotted Section MD: 15947' This well began Production on February 18, 2009 Method of Operations is: Gas Lifted Date of Test: 02121f09 Hours Tested: 12 24-Hour Rate /Oil-Bbl: 2,231 24-Hour Rate /Gas-Mcf: 2,806 24-Hour Rate 1 Water-Bbl: 3,652 Test Rate 1 Oil-Bbl: 1,116 Test Rate (Gas-Mcf: 1,403 Test Rate (Water-Bbl: 1,826 Choke Size: 95 Gas-Oil Ration: 1,258 Flow Tubing Pressure: 450 Casing Pressure: 1,300 Oil Gravity-API: 23 2/23/2009 ~t~~F'q, ,~. , Date 12-12-2008 Transmittal Number:93025 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 ~~ Delive Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: a01~-2~1,.Ary- -~ t 1=D~i4b t~)G~c~ fT ~ i -- ~-+L ~`~~i . i -_J :-~ %I L -- ~i 18-24B N-146 N-14BP61 Y-05BP61 Y-09AL1 Y-09AL 1-01 `-~ " ~ ~!' Please ~`ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~ ~ =~ ~ ~ t -~-~-i ~- r~ ~ ~- ~~~ I 7c~"J-r~~ ice'-ice 3 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • ~,D~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG _ ,~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: 20AAC 25.105 zoAAC zs.~~o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/21/2008 - 208-128 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/11/2008 ~ 50-029-20579-81-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 10/17/2008 PBU Y-09AL1-01 1387 FNL, 98 FEL, SEC. 33, T11N, R13E, UM Top of Productive Horizon: 8. KB (ft above MSC): 87.72' 15. Field /Pool(s): 4530' FNL, 18' FEL, SEC. 04, T10N, R13E, UM Ground (ft MSC): 50.15' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 701' FNL, 512' FWL, SEC. 10, T10N, R13E, UM 15982' 9037' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 644718 y- 5948866 Zone- ASP4 16128' / 9044' ADL 047471 TPI: x- 644977 y_ 5940448 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 64 - 5 Zone- ASP4 None y 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (l1/D): ' mi le roni an rin d inf rma i n er 2 25.0 0 N/A ft MSL (Approx.) 1900 21. Logs Obtained (List all logs here and submit electronic and printed 'nformati n r 20 AAC 25.071): MWD DIR, GR, RES f/%1/DD/r/~ /~~~~ ~/~7' 90 ~y?~D 22. r:,ASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD F'IOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED 20" x In I n r rfa 110' S rface 110' 36" 8 ncr e " 7 # rf 17- I - / " 47# L-8 urfa 9202' rf 7 4 ' 12-1/ " 1435 cu ft Class'G' 130 cu ft PF'C' 7" -8 1 2' 77 9' 89 1' -1/ " 22 I ' -7/ " .1 1 4 1' 1 2' 0' 9 7' 4-1/8" n n I e in r 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of To & Bottom; Pe nterval open rforation Size and Number): .SIZE DEPTH SET MD PACKER .SET MD p 2-718" Slotted Section 4-1/2", 12.6#, L-80 10469' 10413' MD TVD MD TVD 14322' - 15947' 9050' - 9037' 25. ACID, FRACTURE, CEMENT .SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED 2000' Freeze Protected w/ 29 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR IZnTE• 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. 3 .. ~~! None ~/ ~ -D ~~~~~ ~~ [~Ec~ ~ ~ ?QOB Form 10-407 Revised 02/2007 P CONTINUED UN REVERSE 51DE /~`~I~g ~ r 2$. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit 14570' 9026' None Sadlerochit 14666' 9025' Formation at Total Depth (Name): Sadlerochit 14666' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego' g is true and correct to the best of my knowledge. t ~ I ~~~ Signed Terrie Hubble Title Drilling Technologist Date 1 / PBU Y-09AL1-01 208-128 Prepared BylVame/Number. Terrie Hubble, 564-4628 Well Number P rm' A O. Drilling Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNeRA~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached. supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Operations Summary Report Page 1 of 18 Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/1/2008 00:00 - 01:20 1.33 RIGD P PRE 01:20 - 01:30 0.17 CONS P PRE 01:30 - 02:20 0.83 MOB P PRE 02:20 - 02:35 0.25 CONS P PRE 02:35 - 04:00 1.42 CONS P PRE 04:00 - 04:15 0.25 RIGD P PRE 04:15 - 13:00 8.75 RIGD X RREP PRE 13:00 - 15:00 2.00 RIGD X RREP PRE 15:00 - 17:00 2.00 RIGD X RREP PRE 17:00 - 18:30 1.50 RIGD X RREP PRE 18:30 - 19:30 1.00 MOB X RREP PRE 19:30 - 23:00 3.50 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 10/2/2008 00:00 - 07:00 7.00 MOB P PRE 07:00 - 10:40 3.67 MOB P PRE 10:40 - 11:10 0.50 MOB P PRE 11:10 - 11:40 0.50 MOB P PRE 11:40 - 13:30 1.83 MOB P PRE 13:30 - 20:20 ~ 6.83 ~ MOB ~ P ~ ~ PRE 20:20 - 22:00 1.67 MOB P PRE 22:00 - 00:00 2.00 MOB X RREP PRE 10/3/2008 00:00 - 05:00 5.00 MOB X RREP PRE 05:00 - 10:30 5.50 MOB X RREP PRE 10:30 - 10:45 0.25 MOB P PRE 10:45 - 11:30 0.75 MOB P PRE 11:30 - 14:00 2.50 RIGU P PRE 14:00 - 20:00 I 6.00 RIGU I P I PRE 20:00 - 21:40 1.67 RIGU X RREP PRE Clean up around well head. PJSM on moving rig. Move rig to other side of pad for rig maintenance. PJSM on lowering the BOP's and securing. Set BOP's on stand and secure. PJSM on prepairing rig for derrick down. Prepair rig to derrick down. Prep Mud manifold for replacement. Secure mud manifold, place injector in middle of rig floor. Remove gooseneck. Resecuer mud manifold. RU & scope upper derrick section down. RU & lay derrick down. Unstring blocks. Spot & RU crane. Lower down old blocks & mud manifold. Hoist up new blocks & mud manifold to RF. Secure new mud manifold. Restring new blocks w/ Hemp rope. Restring blocks wfth wire rope using the drawworks. Make ready to mobilize rig. Move satellite camp before rig. Rig waiting on security to move. Camp has to go first and security wont do both camp and rig at the same time. Safety meeting with CPS and security CPS measured rig ~ 57 ff. Move rig from DS 1 down the west dock road. Turn onto twin towers road. Heavy equipment is leveling the pad - 7" of dirt work in front of the well & 5" around the cellar. Move rig down twin towers road. Turn onto spine road & convoy with Doyon 16 to J pad. Wait for loaders to shuffle rig mats in front of the rig. Continue to convoy down the spine road with Doyon 16 to J pad. RU VR plug in DS of IA. RU double gate valve on ODS of IA Turn onto GC2 access road & travel to Y pad through H pad. Continue w/dirt work in front of the well. Spot rig at the entrance of the pad. Rasie the derrick up & scope it up. PU injector and reposition from rig floor. Install goose neck. PU new mud manifold and install. Continue to install new mud manifold. Spot rig mats and pit liner while waiting for welder. Weld new floor plate around new mud manifold. Tuboscope the back board of the monkey baord welds - no cracks. PJSM w/ pad op regarding pulling over the well. Spot the rig over the well. Level rig. Spot cuttings box. Spot tiger tank. Re spot office trailer. Spot welding shack. Spot reel trailer. Load reel into reel house. ND tree cap & NU BOP's. Load pits w/ 2% KCL + 2PP6 Biozan. Pressure test new mud manifold to 5000 psi. Chase down small leaks PT to 5000 psi - no more leaks. Draw down to 250 psi for 5 min. Pressure up to 5000 psi for 15 min of flat line -Charted Called and notified AOGCC for 2 hr notice for BOPE testing ~ 21:25. Jeff Jones waived witness ~ 21:40 BP EXPLORATION Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours I Task Code Start: 10/1 /2008 Rig Release: 10/21 /2008 Rig Number: Page 2 of 18 Spud Date: 6/14/1981 End: 10/21 /2008 NPT Phase Description of Operations 10/3/2008 20:00 - 21:40 1.67 RIGU X RREP PRE 21:40 - 22:30 0.83 BOPSU P PRE 22:30 - 00:00 1.50 BOPSU P PRE 10/4/2008 00:00 - 03:30 3.50 BOPSU P PRE 03:30 - 03:40 0.17 RIGU P PRE 03:40 - 04:45 1.08 RIGU P PRE 04:45 - 05:00 0.25 RIGU P PRE 05:00 - 06:00 1.00 RIGU P PRE 06:00 - 08:00 2.00 RIGU P PRE 08:00 - 09:15 1.25 BOPSU P PRE 09:15 - 11:30 ~ 2.25 ~ RIGU ~ P ~ ~ PRE 11:30 - 11:40 0.17 WHSUR P PRE 11:40 - 12:45 1.08 WHSUR P PRE 12:45 - 13:50 1.08 WHIP P PRE 13:50 - 15:35 1.75 KILL P PRE 15:35 - 15:45 0.17 WHIP P WEXIT 15:45 - 16:30 0.75 WHIP P WEXIT 16:30 - 16:45 0.25 WHIP P WEXIT 16:45 - 17:00 0.25 WHIP P WEXIT 17:00 - 21:55 4.92 WHIP P WEXIT 21:55-00:00 ~ 2.08~WHIP ~P ~ WEXIT 10/5/2008 ~ 00:00 - 00:45 ~ 0.75 W H I P ~ P ~ I W EXIT Still RU new coil hard line Finish RU for BOPE testing Continue to RU hard line in CT reel. Shell test BOP BOPE TESTING, as per permit to drill and AOGCC regs. Witness waived by Jeff Jones. 3500 psi high and 250 psi low. Continue BOPE TESTING, as per permit to drill and AOGCC regs. Witness waived by Jeff Jones. 3500 psi high and 250 psi low. Test -PASS PJSM on PU of injector. PU injector and install lubricator and legs. PJSM -Pulling coil across and stab into injector. Pull coil across and stab into injector. Secure wire and prep for slack management. Crew change and fill the coil with 2% KCL + 2ppb biozan. Pressure test inner reel valve & packoffs per AOGCC regs to 250psU3500psi -PASS. Pump slack into the coil. No movement. Pop off well. Cut 4 ft of coil & found wire. Meg wire -good test. Install SLB CTC. Pull test CTC to 40k -good. PJSM regarding pulling the BPV. RU DSM lubricator. P.T. 250/1000psi -good. Open MV - Opsi. Pull 4" CIW BPV. RD DSM lubricator. Head up BHI UOC. Pressure test coil to 4000psi -good. Hoist BOT whipstock & tools to the pipeshed. Open master valve & bull head 5 bbls of neat methanol followed by 325b1s of 2% KCI w/ 2ppb biozan at 6bpm. Starting pressure WHP = 44psi, IAP = Opsi. OAP = Opsi. Achieve a beginning injection rate of 6bpm ~ 760psi, final injection rate of 6bpm ~ 1525psi w/ IAP at 1700psi. Stop pumping & let pressure bleed off. Flow check well -vac, IAP = 285psi, OAP =0psi. PJSM regarding PU whipstock BHA. MU whipstock BHA to coil track tools. PU injector & stab onto tools. Stab injector onto well. Power up & test tools. Set counters. RIH with whipstock at 80fUmin while pumping across the top to keep the hole full. Stop at 300ft & work on BHI encoder. Continue to RIH 80fpm to 10,900 at 10,900 slow to 30 fpm ~ 11,038 small set down of 200 #'s Stop at 11,815 ft and line up to pump through the EDC and close in back side. 0=1.08 / .00 bpm ~ 12 fpm. CP=960 psi, IA=1000 psi Still 4 set downs of 200-600 #'s Clean after 11,826 ft to 14,000 ft. Log for GR tie in from 14,000 tt - 14,300 ft. tag ~ 14,155 ft 2,200 #'s PU to 14,150 ft and RIH and continue G R Log. GR Correction = -33 ft. PU to 14,140 ft and LOG from 14,150 ft to 14,410 ft. Evaluate log for WS setting. BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10!21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/5/2008 00:00 - 00:45 0.75 WHIP P WEXIT 00:45 - 00:50 0.08 WHIP P WEXIT 00:50 - 01:00 0.17 WHIP P WEXIT 01:00 - 02:10 1.17 WHIP P WEXIT 02:10 - 03:40 1.50 WHIP P WEXIT 03:40 - 03:55 0.25 WHIP N FLUD WEXIT 03:55 - 04:30 0.58 WHIP N FLUD WEXIT 04:30 - 04:45 0.25 WHIP N FLUD WEXIT 04:45 - 05:10 0.42 WHIP N FLUD WEXIT 05:10 - 06:30 1.33 WHIP N FLUD WEXIT 06:30 - 08:20 ~ 1.83 ~ WHIP ~ N ~ FLUD ~ WEXIT 08:20 - 10:20 ~ 2.00 ~ KILL ~ N ~ FLUD ~ WEXIT 10:20 - 10:30 0.17 KILL P 10:30 - 11:15 0.75 WHIP N 11:15-13:10 I 1.92IWHIP IP 13:10 - 13:20 I 0.171 WHIP I P WAIT !WEXIT WEXIT WEXIT PU to 14,290 ft bit depth. UP WT=43K#'s DNWT=16.5K#'s RIH to 14,308 ft bit depth. PU to 14,306 ft. Open choke for normal circ. Close EDC. Take crude retums to tiger tank. Slowly pressure up to 3200 psi then dropped off to 850 psi at .36 bpm. set down to 14 K DN WT with DH WOB = 4K #'s. Packer appears to have set. Top of whipstock set ~ 14,290 ft 20 deg LOHS. Circulate out well with 150 bbls surface to surface vol. taking contaminated retums out to tiger tank. POOH while circulating out well boar with remaining surface to surface vol. 0= 2.53 bpm ~ 2625 psi. IA= 676 psi OA= 150 psi. ~ 245 bbls total circulated out and about 12,500 ft still have gas in the retums. PU to 10,400 and bleed off IA to 90 psi. Gas and crude returns from IA. Shut in IA. PJSM on RU and circulating out the lA. RU squeeze manifold to IA. Wait on more fluid for IA displacment. consult with Sarber... not displacing the IA. RD squeeze manifold lines. Circulate out Well bore again from 10,000 ft with 8.48 ppg 2% KCUBIOZAN. Pump. after 121 bbls shut down pumps and and shut in choke. IA = 465 npsi W H = 304 psi Open IA to slop trailer -fluid packed w/crude. Wait on KCL water as we now have limited amounts of Biozan left on the slope. Also, pad 3 is down & have 2 full dirty trucks with no place to offload the fluid, which requires us to bullhead to kill the well. Hook up KCL truck, fill out transfer permit & flood the line. Starting pressure WHP = 157psi, IAP = 120psi, OAP = 157psi. Bullhead 2% KCI down the tubing ~ 1.75bpm & maintain IAP below 2000psi & maintain equal CTP versus WHP. Bullhead a total of 150bb1s. Final injection rate 1.84bpm ~ 1725psi w/ IAP ~ 1900psi. Stop pumping & bleed off the pressure. Flow check - no flow. IAP = 255psi, OAP = 160psi. Pump across the top to keep the hole full, PVT=149. SLB is inspecting the power pack traction motor. Fixed minor problem with traction motor, otherwise ok. POH filling across the top. Discrepancy in the trip sheet, stop at 3000ft & flow check - no flow. Continue to POH. Final PVT = 92. Lost 3bbls on the trip OOH. PJSM regarding handling whipstock setting BHA & handling milling BHA. ~~ BP EXPLORATION Page 4 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 10/5/2008 13:20 - 14:25 1.08 STMILL P WEXIT 14:25 - 17:07 2.70 STMILL P WEXIT 17:07 - 17:50 0.72 STMILL P WEXIT 17:50 - 20:40 2.83 STMILL N FLUD WEXIT 20:40 - 00:00 3.33 STMILL N FLUD WEXIT 10/6/2008 00:00 - 00:20 0.33 STMILL N FLUD WEXIT 00:20 - 00:45 0.42 STMILL N FLUD WEXIT 00:45 - 05:00 4.25 STMILL N FLUD WEXIT Description of Operations Flow check -no flow. Pop off well -slight vac. LD BHI coil trac tools & remove HOT. LD whipstock setting BHA. MU milling BHA w/ BOT straight motor w/ 2.80" go / 2.79"no-go mills + 2 jts PH6 + coil track tools. MU coil to BHA. Stab onto well. Power up & test tools. Set counters. Open EDC. RIH filling across the top. At 7500ft in the hole got crude back, check trip sheet, no loss or gain. Circulate down the coil for 15 bbls to the tiger tank -straight crude. Shut in choke & snub in the hole. Check IA -gas, bleed down until) fluid packed - 3min to fluid pack & shut it in. Consult town engineer. RIH & pump max rate down the coil while taking retums to the tiger tank. Log down for tie-in from 14,120ft. Circulate at.3.6bpm/3900psi, hold WHP constant to get 1 for 1 returns. Shut down & close the choke at 146bb1s away -Tiger tank is at 80%. (-39ft corr. ' Wait for dirty vac & clean KCL trucks. Dirty Vac cleaning out pit 2 and TT. still waiting for KCL and hard line crew. Off load and RT KCL truck. PJSM with Hard line crew boss, driller and tower pusher. Plan out to install 2" line off of IA to TT line as follows: From double block valves off IA,integral adapter to 1502, install T with pressure gauge, block valve, choke valve, T with valve and pressure gauge, hard line to block valve, one way check valve, Tiger Tank line. PT to 4000 psi Test good. Finish RU of IA PJSM Starting pressures: IA=553 psi W H = 330 psi OA= 157 psi Open IA to tiger tank while pumping .25 bpm down coil with WH shut in. IA pressure falling of fast and WH pressure following WH=95 while IA=50 psi and falling. IA fell to 17 psi shut down pumps IA fell to 0 with WH = 55 psi. Slowly equalizing while we shut in IA and open WH. Gas in WH retums. Pump .25 bpm through coil through tubing to tiger tank WH 0 and IA = 106 Shut in WH and Open IA. WH = 0 psi and IA =0. Pump at .29 bpm WH = 0 and IA = 1 psi. Shut in and wait WH = 0 and IA slowly climbing. at 5 min IA = 40 psi Open IA and pump 1 bpm CP=470 psi IA=32 psi and DS IA=25 psi. Bring pumps to 2 bpm ~ CP=1080 psi, IA open = 60 psi. Increase pump rate to 3 bpm CP=1970 psi IA=100 psi. Pump 104 bbls total. Pump of Shut in IA open WH and circulate out tubing. 0=2.3 bpm IA climbed to 330 psi WH = 80 psi Had gass in returns for first 5 bbls then density = 8.44/8.37 PP9 0= 2.31/2.25 with choke open WH=88 psi IA=348 psi. CBU ,~ BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT .Phase Description of Operations 10/6/2008 00:45 - 05:00 4.25 STMILL N FLUD WEXIT getting more gas ~ 19 bbls in. Ctose in choke for 1 for 1 returns 0=2.28/2.30 CP=1680 psi IA=540 psi WH=278 psi density = 8.45/8.2 ppg ~ BU (140 bbls) Shut in press = IA= 80 WH 04 psi Flow check - NO flow WH=O and IA=60 psi Blow Down Hard lines to TT. 05:00 - 17:00 12.00 STMILL P WEXIT Mill window from 14,291.3ft. 2.52bpm in / 2.46 out ~ 2040psi w/ 1-2k WOB using 2% KCL water. Mill 0.1ft/12min for the first foot followed by 0.1ft/6min there after, pumping 2ppb biozan sweeps as needed. Exit window at 14,298 ft. Continue to mill 0.1ft/6min for the next foot following by a faster ROP. Mill 10ft of OH. Milled to 14,301ft & stalled, PU wt = 50k, RIW = 19.6k. Resume milling OH & mill to 14,309ft. Ream & back ream the window until clean. Dry drift window -clean. 17:00 - 20:00 3.00 STMILL P WEXIT POH. Inspect bottom's up - small amount of formation cuttings in sample 20:00 - 20:20 0.33 STMILL P WEXIT PJSM on LD of BHA while POOH. 20:20 - 21:45 1.42 STMILL P WEXIT LD Milling BHA -window mill gauged 3.79 no go with good wear patterns. 21:45 - 21:50 0.08 DRILL P PROD1 PJSM - PU of BHA 21:50 - 22:10 0.33 DRILL P PROD1 PU build section BHA with 2.0 AKO rebuilt HYC 3.75 x 4.25 bi center bit. 22:10 - 00:00 1.83 DRILL P PRODi RIH with build section BHA 00:00 depth 10,672 ft. 10/7/2008 00:00 - 00:40 0.67 DRILL P PRODi Continue RIH to 14,000 ft 00:40 - 01:20 0.67 DRILL P PRODi Log for GR tie in from 14,060 to 14,200 ft -41.5 ft correction 01:20 - 01:40 0.33 DRILL P PROD1 RIH orientate tool. Op=2.51/2.41 bpm ~ 2020 psi 01:40 - 03:10 1.50 DRILL P PROD1 Tag bottom ~ 14309 ft Start to swap well to FloPro once bit was through the window. Drill build section. ® 14,318 ft Op=2.51/2.48 bpm ~ 2245 psi DH WOB=1390#'s ROP=1.7 fpm / 100 fph Vibration reading on BHA=6 (red) drop to Op=2.13/2.06 bpm ~ 2303 psi SEVXYX reading=5 Drop to Op=1.9611.90 bpm ~ 2700 psi. SEVXYX=5 still ~ 14,362 ft started to stack out and load up. PU wt=63K (11 K overpull) wiper to window and back to drilling ahead. Drilled to 14,419 ft 03:10 - 03:25 0.25 DRILL P PROD1 Wiper to window after PU for tool face change and had up wt = 62K. 03:25 - 05:30 2.08 DRILL P PROD1 Drill ahead from 14,419 ft. Drilling ~ 14,450 ft Op= 2.06/2.01 bpm ~ 3400 psi Printed: 11/3/2008 11:43:03 AM \~ BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of Operations 110/7/2008 ~ 03:25 - 05:30 ~ 2.08 ~ DRILL ~ P 05:30 - 06:00 0.501 DRILL P 06:00 - 10:05 4.08 DRILL P 10:05 - 13:05 I 3.00 I DRILL ~ P PRODi PROD1 PROD1 13:05 - 13:20 0.25 DRILL P PROD1 13:20 - 13:45 0.42 DRILL P PROD1 13:45 - 15:35 1.83 DRILL P PROD1 15:35 - 16:45 1.17 DRILL N STUC PROD1 16:45 - 17:25 0.67 DRILL P PROD1 17:25 - 19:45 2.33 DRILL P PROD1 19:45 - 20:30 0.75 DRILL P PROD1 20:30 - 21:10 0.67 DRILL P PROD1 21:10 - 21:30 0.33 DRILL P PROD1 21:30 - 22:00 0.50 DRILL P PROD1 22:00 - 22:45 22:45 - 23:15 0.75 DRILL P PROD1 0.50 DRILL P PROD1 23:15 - 00:00 0.75 DRILL N STUC PROD1 10/8/2008 00:00 - 00:40 0.67 DRILL N STUC PROD1 00:40 - 01:00 0.33 DRILL P PROD1 01:00 - 01:40 0.67 DRILL P PROD1 01:40 - 02:05 0.42 DRILL P PROD1 02:05 - 02:40 0.58 DRILL P PROD1 Stacking out again ~ 14,480 ft with 55K UP WT. Bring pump rate back up to 2.60 bpm FS=3280 psi OP=2.6/2.52 bpm ®3500 psi DH press dill= 688 psi ECD=10.03 ppg SEVXYX=6 Drill to 14,557 ft Wiper to window & to TD. Continue to drill the build section from 14,557ft. Op=2.50/2.44 bpm ~ 2900 psi Density=8.65/8.68 ppg DH Press=4640 psi ECD=10.0 ppg DH W06=1.5k-2.5k ROP= 20-90 fph PV=422 bbls Drilled to 14,650 ft. Sliding issues. Centrifuge the mud. Wiper trip to the window -clean. Stop pumping & pull through 'the window. Open EDC & jet tubing/belly of the well up to 10000'. RIH to 14055'. Log tie-in. Correction of +10'. Close EDC. Log tie-in at RA. Drill build to 14701'. FS 3060psi ~ 2.5bpm. Differentially stuck. Turned TF 180deg of drilled TF. Shut down pumps and relax pipe. Pull pipe free at 85k#. Wiper to window after freeing pipe. Drill to 14800' at 2.6bpm, 3330FS, 81psi WHP, 497psi IA. Short trip to window. Drill to 14849' at 2.60bpm in/ 2.58bpm out ~ 3400psi, 3500psi FS, 490psi IA, 237psi OA. Drilling is sticky. Short wiper trip to 14600'. Drill ahead to 14900' at 2.61 bpm in 2.57bpm out ~ 3790psi, 3500psi FS, 2.6K WOB, 123fph ROP, 10.10ppg ECD, 520psi IA, 238psi OA, 3 to 5 SEVXYX. Wiper trip to window. Drill ahead to 14944' at 2.60bpm in / 2.56 out ~ 3700-3780psi, 3500psi FS, 2.0-2.3K WOB, 130-170fph ROP, 10.15ppg ECD, 520psi IA, 243psi OA, 4 to 5 SEVXYX. Differentially stuck. Relax pipe for 15 minute. Work Pipe. Circulate bottoms up; receiving full returns. Called for crude. Pumps off and relax pipe. Work Pipe. Pull to 86k# and popped free. POOH to cased hole tie-in. Log tie-in. +10' correction. Log RA marker. Wiper to bottom. Drill ahead to 15001' at 2.53bpm in / 2.51 out ~ 3700psi, 3150psi FS, 1.9-2.iK WOB, 100fph ROP, 10.09ppg ECD, PROD1 den=8.69/8.63 ppg ECD=9.77 ppg DHPRESX=610 psi DH WOB=1500#'s ROP=.9 fpm / 49 fph TF=80 LOHS SEVXYX = 5 `~ BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/8/2008 02:05 - 02:40 0.58 DRILL P PROD1 510psi IA, 244psi OA, 4 SEVXYX. POH to PU lateral BHA. 02:40 - 06:30 3.83 DRILL P PROD1 POH to surface. 06:30 - 08:00 1.50 DRILL P PROD1 At surface. Get off well. Unstab coil. LD build BHA. Bit pilot cutters severely damaged. Nose mostly rung out. MU McRlbsteer BHA assy with 3.750" HCC HCM304Z bit. 08:00 - 10:45 2.75 DRILL P PROD1 Run in hole. 10:45 - 11:15 0.50 DRILL P PROD1 Log GR tie in from 14,100'. Subtract 43' correction. 11:15 - 12:30 1.25 DRILL P PROD1 Run in hole. Set down in window at 14,295' while RIH at 15 fpm. Try again with min circ rate. Set down again. Mtr stalled. PU and activate ribs to lift bit off low side (?). Through window ok. Continue to run to btm. Circ 1.04 bpm at 1787 psi. 3098 psi fs at 2.50 bpm in. Work through "tight" shale at 14965'. Back ream same. Tag TD at 14998'. 12:30 - 14:00 1.50 DRILL P PROD1 Drill ahead from 14,998'. 3098 psi fs at 2.50 bpm in/out. 150-350 psi mtr work. 2.2k# dhwob. ROP up to 120 fph. BHP: 4690 psi, ECD: 10.09 ppg, PVT: 345 bbls. Drill to 15,123'. 14:00 - 15:25 1.42 DRILL P PROD1 Run MAD pass back to window. 15:25 - 16:00 0.58 DRILL P PROD1 RIH to bottom. Swap to new mud. 16:00 - 18:15 2.25 DRILL P PRODi Drill ahead from 15,123'. 3230 psi FS at 2.5 bpm in/out; 3120 psi FS after new mud back to surface. ROP 100+ fph. WHP: 40 psi, IA: 460 psi Drill to 15,210'. 18:15 - 19:30 1.25 DRILL P PROD1 Wiper trip to window. 19:30 - 20:35 1.08 DRILL P PROD1 Drill ahead from 15,210'. 3200 psi FS at 2.49/2.46 bpm in/out. 100-400 psi mtr work. 1.7k - 2.3k# dhwob. ROP up to 150 fph. BHP: 4670 psi, ECD: 10.02 ppg, PVT: 388 bbls. Drill to 15,298'. 20:35 - 21:40 1.08 DRILL P PROD1 Wiper trip to window. 21:40 - 22:40 1.00 DRILL P PRODi Drill ahead from 15,298'. 3200 psi FS at 2.49/2.44 bpm iNout. 150-300 psi mtr work. 1.1 k-1.7k# dhwob. ROP up to 140 fph. BHP: 4671 psi, ECD: 10.02 ppg, PVT: 377 bbls. Drill to 15,401'. Losses at 5 bblJhr. 22:40 - 23:20 0.67 DRILL P PROD1 Wiper to window. 23:20 - 23:30 0.17 DRILL P PROD1 Log tie-in. Correction +6'. 23:30 - 00:00 0.50 DRILL P PROD1 Continue wiper to TD. 10/9/2008 00:00. - 01:40 1.67 DRILL P PROD1 Drill ahead from 15,404'. 3300 psi FS at 2.53/2.46 bpm iNout. 300 psi mtr work. 2.1 k# dhwob. ROP up to 110 fph. BHP: 4702 psi, ECD: 10.10 ppg, PVT: 370 bbl initial, 364 bbl final Sticky drilling. Made a few short wiper trips to 15300'. Drill to 15,510'. Losses at 3 bbl/hr. 01:40 - 03:10 1.50 DRILL P PROD1 Wiper to window. 03:10 - 04:15 1.08 DRILL P PROD1 Drill ahead from 15,404'. odrood• i ~ iannna 11 •d3~03 AM `~ BP EXPLORATION Page 8 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21!2008 Rig Name: NORDIC 2 Rig Number: Date From.. - To Hours Task Code NPT Phase I Description of Operations 10/9/2008 103:10 - 04:15 I 1.081 DRILL ~ P 04:15 - 07:15 3.001 DRILL ~ P 07:15 - 07:30 I 0.251 DRILL ~ P 07:30 - 08:15 0.75 DRILL P 08:15 - 10:00 1.75 DRILL P 10:00 - 12:15 2.251 DRILL P 12:15 - 12:45 0.50 DRILL P 12:45 - 13:30 0.75 DRILL P PROD1 3500 psi FS at 2.77/2.70 bpm iNout. 400 psi mtr work. 1.14k# dhwob. ROP up to 125 fph. BHP: 4750 psi, ECD: 10.21 ppg, PVT: 357 bbl initial, 351 bbl PROD1 PRODi PROD1 PRODi PROD1 PROD1 PROD1 13:30 - 15:45 2.25 DRILL P PROD1 15:45 - 16:15 0.50 DRILL P PROD1 16:15 - 16:45 0.50 DRILL P PROD1 16:45 - 21:45 5.00 DRILL N STUC PROD1 21:45 - 22:00 ~ 0.25 ~ DRILL ~ N ~ STUC ~ PROD1 22:00 - 00:00 ~ 2.00 ~ DRILL ~ N ~ STUC ~ PROD1 Drill to 15,582'. Losses at 5 bbUhr. Unable to achieve turn without exiting the polygon. Pull BHA for adjustable motor. POH. Open EDC above window and pump 3.2 bpm/3420 psi while POH. Rig lost power. Crew smelled something "burning" on second level. Genset #2 windings are fried. Bring another generator on line. Continue to pull out of hole. Hold PJSM near surface. At surface. Get off well. Unstab coil. LD BHA tools. Bit had a few chipped cutters. Possibly from window contact. Grade 1-1-I FUNCTION TEST BOPs. MU 1.4 AKO mtr with Hycalog 3.75" DSX413M-A4 bit, resistivity and agitator. Stab coil. Test tools. Get on well. Run in hole. Log gr tie in. Subtract 55.5' correction. Run in to open hole. Unable to get past 15,077'. Try all TF's, pump rates etc. No go. Noted overpulls up to 60-65k# (above CT up wt of 45k#). Make wiper trip back to window to clean up hole . Continue to run in hole. Drill ahead from 15,558'. 3900 psi fs at 2.40 bpm in/2.32 out. 200-300 psi mtr work. 2-3k#dhwob. Very fast drilling. BHP/ECD/PVT: 4740 psi/10.19 ppg/316 bbls. Stuck off btm at 15,573. Circ 50 bbls. Shut do pumps and hold coil in neutral. Order crude. Pull up to 85k# every ten minutes several times, then shutdown waiting on crude. Pumps off at 20:10. Pump 1.9 bpm, hold 85k# for 20 min. Relax pipe, continue pumping at 1.9 bpm waiting for crude. SAFETY MEETING discussing procedures and hazards of pumping crude. Volatility check on crude is 1.7 psi. Pump 15 bbls crude and circulate it to the bit. Spot 5 bbls, wait 15 min then work pipe. Pull to 87k#, wait 10 min, slack off, then repeat. Spot another 5 bbls, wait 15 min then work pipe. Hold 85k# & spot last 5 bbls. Work pipe. Hold 80k# & circulate crude out. 10/10/2008 00:00 - 03:40 3.67 DRILL N STUC PROD1 Hold 80k# and circulate out crude. Slack to 20k#. Shut down the pumps with the crude near surface and wait 30 min for the formation to relax and BHP to decrease. Pull to 85k#, slack to 0#, then pull to 80k# & hold while circulating out remaining crude. Pump remaining 35 bbl crude and circulate down to bit. BP EXPLORATION Page 9 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT .Phase Description. of Operations 10/10/2008 00:00 - 03:40 3.67 DRILL N STUC PROD1 Spot 17 bbls and let soak for 30 min (open hole section is 15.5 bbl). Work pipe. Spot 5 more bbls and let soak for 30 min. Work pipe and popped free. 03:40 - 06:45 3.08 DRILL P PROD1 Slow wiper to 9700' to clean up the hole. Crude has adversely affected mud. LSRV is 18K. Fluid looks thin. Plan to try and drill ahead with controlled ROP. 06:45 - 08:30 1.75 DRILL P PROD1 Run back in hole. 08:30 - 08:45 0.25 DRILL P PROD1 Log GR tie in from 14,085'. Add 13' correction. 08:45 - 09:30 0.75 DRILL P PROD1 Run in hole. 4120 psi fs at 3.43 bpm in. Close EDC. Continue in hole. 09:30 - 11:00 1.50 DRILL P PROD1 Drill ahead from 15,609'. 3700 psi fs at 2.24 bpm in/2.23 out. 150-300 psi mtr work. 2-3k# dhwob. BHP/ECD/PVT: 4630 psi/9.95 ppg/166 bbls. Drill to 15,620'. Stuck on btm. Shut do pumps to relax hole. Came free at 89k# up wt. Make BHA wiper. 11:00 - 13:00 2.00 DRILL P PROD1 Drill ahead from 15,620'. Plan is to drill at 70-100 fph, then PU and make BHA (100') wiper once differential drops off. Circ 10 bbl hi-vis sweeps. 3850 psi fs at 2.31 bpm in/2.30 out. Stuck again during BHA wiper. Relax hole. 13:00 - 16:15 3.25 DRILL N STUC PROD1 Spot 10 bbls crude outside coil in OH. Soak for 30 min. Pull to 89k#. Soak another 30 min. Pull and hold 90k# for 30 min. Pump 55 bbls to push crude into upper hole to reduce BHP. Came free pulling 60k# 16:15 - 21:00 4.75 DRILL P PROD1 Condition hole for liner. POH to surface. Open EDC above window. SAFETY MEETING discussing roles, procedures, and hazards to UD BHA. 21:00 - 21:45 0.75 DRILL P PROD1 UD Lateral BHA. Bit graded 1-1-WT. 21:45 - 22:25 0.67 CASE P RUNPRD PU bales and RU to run liner. 22:25 - 22:35 0.17 CASE P RUNPRD SAFETY MEETING discussing procedures and hazards to PU & run liner. 22:35 - 00:00 1.42 CASE P RUNPRD PU Liner assembly. 10/11/2008 00:00 - 00:30 0.50 CASE P RUNPRD Continue PU Liner Assembly. Stab injector. 00:30 - 01:50 1.33 CASE N WAIT RUNPRD Wait on delivery of knuckle joint for liner running tool. 01:50 - 02:30 0.67 CASE P RUNPRD PU Liner Running Tool & CoilTrak. Stab injector. 02:30 - 06:30 4.00 CASE P RUNPRD Open EDC, RIH w/ Liner pumping at 0.5 bpm. Liner: 3-1/2" Guide Shoe, 2-7/8" Pup Jnt, 2-7/8" Pup Jnt, 2-7/8" O-ring sub, 36 jnts of 2-7/8" STL 6.16ppf L-80 Slotted Liner, and Aluminum Billet. Up Wt above window w/ pumps off = 47.5k# & -2.6k DHWOB Log Tie-in, -60' correction. Tight Spot 15,423'. 57k# Up Wt Tag bottom at 15,622', hold 15k# and 3.2k DHWOB. Printed: 11/3/2008 11:43:03 AM BP EXPLORATION Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name:. NORDIC 2 Date From - To ~ Hours I Task I Gode NPT 10/11/2008 102:30 - 06:30 I 4.001 CASE 1 P 06:30 - 10:00 (~ \ 1000¢ - 111c:1-5 11:15 - 13:30 13:30 - 13:45 13:45 - 14:15 ~d•~~ _ i~•zn 15:30 - 17:00 ~',-D I~ \... -O ~... 3.50 CASE P 1.25 CASE P 2.25 STWHIP P 0.25 STWHIP P 0.50 STWHIP P 1.25 STWHIP P 1.501 STWHIPI P 17:00 - 18:15 I 1.251 STWHIPI P 18:15 - 20:20 1 2.081 STW HIP 1 P 20:20 - 00:00 3.671 STWHIPI P 10/12/2008 ~ 00:00 - 01:55 ~ 1.92 ~ STW H I P ~ P 01:55 - 04:15 I 2.33 STW HI P P 04:15 - 04:55 0.67 STWHIP P 04:55 - 08:00 3.08 STWHIP P Page 10 of 18 Spud Date: 6/14/1981 Start: 10/1 /2008 End: 10/21 /2008 Rig Release: 10/21/2008 Rig Number: Phase Description of Operations RUNPRD Pull uphole, 56k# Up Wt and -6.10k DHWOB, 15 fpm, no pumps RIH 20 fpm, 20k Dn Wt and 0.35k DHWOB Tag bottom at 15,622', hold 14k# and 3.Ok DHWOB Pump 2 bpm for 1 min. PU slowly, 42k# Up Wt and -1.43 DHWOB, pumping PU 15 fpm, pumps off, 44k# Up Wt and -1.7k DHWOB. Liner Released. RUNPRD Pull out of hole. Hold PJSM for handling the BHA. RUNPRD AT surface. Get off well. LD liner rng tools. MU kick off BHA. 2.0 AKO x-treme with STR335G25 bit. Stab coil. Test tools. PROD2 Run in hole. Circ at min rate. PROD2 Log gr tie in from 14,100'. Subtract 25' correction. PROD2 _ is at 14,621'. PROD2 Trough from 14479 to 14,499' with HS tool face. Time drill from 14,498'. 0.1 ft per 6 minutes. 2988 psi fs at 2.04 bpm in/out. PROD2 Time drill ahead from 14,500'. Six ft per hour. 3065 psi fs at 2.04 bpm. 1.5-2.5k# dhwob. BHP: 4587 psi, ECD: 9.87 ppg, PVT: 117 bbls. PROD2 Drill ahead from 14,505'. 2950 psi fs at 2.03 bpm in/out. 100 psi mtr work. 0.0-0.5k# dhwob. Drill build and turn as per DD to get lined up for second lateral. Drill to 14515'. Backream up past window at 45L and 45R. PROD2 Drill ahead from 14,515'. 3000 psi FS at 2.55/2.52 bpm in/out. 400 psi mtr work. 3.8-4.Ok# DHWOB, ROP up to 70 fph, 10.16 ppg ECD. PVT = 107 bbl, IA = 552 psi, BHP = 4723 psi, SEVXYX up to 6. Drill to 14603'. PROD2 Drill ahead from 14,603'. 3350 psi FS at 2.27/2.25 bpm in/out. 100-300 psi mtr work. 2.3k-4.3k# DHWOB, ROP up 10-50 fph, 10.08 ppg ECD. PVT = 107 bbl, IA = 503 psi, BHP = 4679 psi, SEVXYX up to 3 Drill to 14629'. PROD2 Drill ahead from 14,629'. 3500 psi FS at 2.51-2.51 bpm in/out. 200-300 psi mtr work. 4.2k# DHWOB, ROP up 10 fph, 10.09 ppg ECD. PVT = 101 bbl, IA = 510 psi, BHP = 4684 psi, SEVXYX 0 Mud Swap; New mud at bit ~ 14640'. Drill to 14,645'. PROD2 Drill ahead from 14,645'. 3450 psi FS at 2.50-2.48 bpm iNout. 400-600 psi mtr work. 3.9-4.1k# DHWOB, ROP up 1-10 fph, 10.04-9.94 ppg ECD. IA = 479 psi, BHP = 4608 psi Drill to 14,654'. Into Shublik. Very slow rop. PROD2 W iper to window. PROD2 Drill ahead from 14,650'. 3600 psi FS at 2.77-2.74 bpm in/out. 400-600 psi mtr work. Printed: 11/3/2008 11:43:03 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA ,Rig Name: NORDIC 2 Date From - To ~ Hours Task Code NPT 110/12/2008 104:55 - 08:00 I 3.081 STWHIPI P 08:00 - 11:00 ~ 3.00 STWHIP~ P 11:00 - 11:30 0.501 STWHIPI P Start: 10/1 /2008 Rig Release: 10/21 /2008 Rig Number: Page 11 of 18 Spud Date: 6/14/1981 End: 10/21 /2008 Phase Description of Operations PROD2 PROD2 PROD2 11:30 - 13:30 2.001 DRILL I P I 1 PROD2 13:30 - 16:30 3.00 DRILL P PROD2 16:30 - 17:00 0.50 DRILL P PROD2 17:00 - 17:40 0.67 DRILL P PROD2 17:40 - 19:50 2.17 DRILL P PROD2 19:50 - 20:15 0.42 DRILL P PROD2 20:15 - 21:25 1.17 DRILL P PROD2 21:25 - 00:00 2.58 DRILL P PROD2 10/13/2008 00:00 - 01:00 1.00 DRILL I P PROD2 01:00 - 01:40 0.67 DRILL P PROD2 01:40 - 02:10 0.50 DRILL P PROD2 02:10 - 03:00 0.83 DRILL P PROD2 03:00 - 06:15 I 3.251 DRILL I P 1 1 PROD2 06:15 - 06:30 0.50 DRILL P PROD2 06:30 - 07:00 0.50 DRILL P PROD2 07:00 - 08:00 1.00 DRILL P PROD2 08:00 - 09:00 1.00 DRILL P PROD2 09:00 - 10:00 1.00 DRILL I P 1 PROD2 3.3-3.67k# DHWOB, ROP 3-9 fph, 10.04 ppg ECD. IA = 504 psi, BHP = 4641 psi Drill to 14,654'. Finding some stator rubber on shakers. Directional line up is adequate for switching to rib steer system. Pull out of hole for BHA change. Unloaded a lot of aluminum as BHA neared surface. Get off well. Unstab coil and set injector on floor. Inspect SLB slings for injector (3rd party) LD kickoff BHA. Bit 1-1-I Make up lateral drilling BHA with resistivity and rib steer, with re-run HCM bit. Run in hole at reduced speed. Trouble shoot pump #2. Log GR tie in from 14,090'. Subtract 25'. Run in hole. Drill ahead from 14,654'. 3650 psi FS at 2.49/2.47 bpm in/out. 100-150 psi mtr work. 1.0-1.5k# DHWOB, ROP Up to 80 fph, 10.0 ppg ECD. IA = 490 psi, BHP = 4611 psi Drill to 14,759'. Wiper to window. MAD pass from Billet to TD. Logging 200 fph over the billet had 100 psi motor work. Drill ahead from 14,759'. 3650 psi FS at 2.58/2.57 bpm in/out. 150-300 psi mtr work. 1.4k# DHWOB, ROP Up to 60 fph, 10.0 ppg ECD. IA = 518 psi, BHP = 4647 psi, PVT = 406 Drill to 14,870'. Wiper to window. RIH w/ pumps off over AL billet sat down 2k DHWOB, PU -4.5k DHWOB, quickly RIH and slid through. Drill ahead from 14,870'. 3700 psi FS at 2.60/2.56 bpm in/out. 200 psi mtr work. 2.11 k# DHWOB, ROP Up to 160 fph, 10.18 ppg ECD. IA = 543 psi, BHP = 4731 psi, PVT = 396 Drill to 14,960'. Wiper to 14520'. Drill ahead from 14,960'. 3700 psi FS at 2.64/2.60 bpm in/out. 300 psi mtr work.. 1.6-1.8k# DHWOB, ROP Up to 200 fph, 10.20 ppg ECD. IA = 558 psi, BHP = 4748 psi, PVT = 395, Start centrifuge. Drill to 15,035'. Wiper to 10,000'. 10k# CT Wt overpull at 14,700'. -6k# DHWOB overpull at 14492'. Log tie-in from 14100'. Add 5' correction. Remain is csg. Tighten some loose bolts inside of reel. Run in hole back to btm. Note a few set down. Plan is for zero rate at billet and in Shublik during trips. Drill ahead from 15,035'. 3450 psi fs at 2.47 bpm in/out. 100 psi mtr work. 1-2k#dhwob BHP: 4717 psi, ECD: 10.14 ppg. PVT: 370 bbls. Very fast ROP in soft formation. Drill to 15130'. Wiper trip to 14300'. Reduce pump through Shublik, off past BP EXPLORATION Page 12 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2008 09:00 - 10:00 1.00 DRILL P PROD2 billet. Hole mostly smooth. No problems in Shublik. 10:00 - 12:30 2.50 DRILL P PROD2 Drill ahead from 15,130. Need to maintain 120-150 fph to keep coil sliding. Rib steer directional control is adequate. Currently building at 93-94 NBI. Drill to 15,260'. 11:45 - 12:45 1.00 DRILL P PROD2 Make wiper trip to window. Pump 10 bbls hi-vis sweep. Hole smooth. 12:45 - 13:45 1.00 DRILL P PROD2 Drill ahead from 15,260'. 4000 psi fs at 2.51 bpm in/out. 200-300 psi mtr work. 2-3k#dhwob. ROP variable but fast when pipe slides smoothly. Begining to stack out often. Pump another 10 bbl sweep. Continue to have trouble with stacking on/near btm. 13:45 - 16:30 2.75 DRILL P PROD2 Make wiper trip to 10,000'. Open EDC above window. POOH at 50-60 fpm. RIH at 90 fpm. Close EDC. Run through OH to btm. 16:30 - 20:00 3.50 DRILL P PROD2 Drill ahead from 15,305'. 3900 psi fs at 2.53 bpm in/out. 200-300 psi mtr work. 2.7k# DHWOB, 10.5 ppg ECD, Up to 230 fph ROP IA = 591 psi, BHP = 4906 psi, PVT = 302 bbls Drill to 15468'. 20:00 - 21:25 1.42 DRILL P PROD2 Wiper to window. Mud Swap. 21:25 - 23:10 1.75 DRILL P PROD2 Drill ahead from 15,468'. New mud out bit at 15485'. 3700 psi FS at 2.53 bpm in/out. 200-500 psi mtr work. 3.5k# DHWOB, 10.2 ppg ECD, Up to 160 fph ROP IA = 520 psi, BHP = 4734 psi Drill to 15,595'. 23:10 - 00:00 0.83 DRILL P PROD2 Wiper to window. After PU begin losing fluid at 0.3 bpm. Losses decreased gradually to 0.1 bpm at 14580'. 10/14/2008 00:00 - 00:50 0.83 DRILL P PROD2 Continue wiper to window. 0.1-0.2 bpm losses while RIH. 00:50 - 01:40 0.83 DRILL P PROD2 Drill from 15,595' - 15,643'. RSM unable to achieve needed DLS due to the high WOB needed to keep drilling. Perform wiper. 01:40 - 03:10 1.50 DRILL P PROD2 Wiper to 14,660' (bottom of the Shublick). Losses healed during the wiper. 03:10 - 04:20 1.17 DRILL P PROD2 Drill ahead from 15,643. 3650 psi FS at 2.64/2.56 bpm in/out. 150 psi mtr work. 1.1-1.5k# DHWOB, ROP Up to 55 fph, 10.26 ppg ECD. IA = 508 psi, BHP = 4770 psi, PVT = 372 Drill Yo 15,681'. 04:20 - 05:00 0.67 DRILL P PROD2 Wiper to 15,200'. 05:00 - 05:35 0.58 DRILL P PROD2 Drill ahead from 15,681'. 3700 psi FS at 2.67/2.63 bpm in/out. 400 psi mtr work. 1.8k# DHWOB, ROP Up to 150 fph, 10.35 ppg ECD. IA = 533 psi, BHP = 4810 psi, PVT = 361 Drill to 15,760'. 05:35 - 08:45 3.17 DRILL P PROD2 Wiper to 10,000'. POH at 25 fpm. Open eDC. Pull 50 fpm in csg. RIH. Close EDC. n-...-... ..innnnn ..•ea•n~ene • BP EXPLORATION Page 13 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2008 08:45 - 09:00 0.25 DRILL P PROD2 Log GR tie in from 14,070'. Add 11' correction. 09:00 - 10:00 1.00 DRILL P PROD2 Continue to run in to open hole. 10:00 - 11:00 1.00 DRILL P PROD2 Drill ahead from 15,760'. Drill to 15803'. Unable to get back to btm. Discuss with directional driller ans SLB driller. 11:00 - 14:30 3.50 DRILL P PROD2 Pull out of hole for AKO motor and agitator. 14:30 - 15:15 0.75 DRILL P PROD2 LD drilling BHA. Bit was 1-4- 15:15 - 16:00 0.75 DRILL P PROD2 Jet stack w/ swizzle stick Set injector to side 16:00 - 18:30 2.50 BOPSU P PROD2 Open doors on lower combi rams to check for aluminum, but found only formation debris. Change injector packoffs and check chains. 18:30 - 00:00 5.50 BOPSU P PROD2 BOPE TEST witnessed by Lou Grimaldi. Tested Annular, B/S, Upper 2-3/8" Combis, 2-3/8" X 3-1/2" Variables, Lower 2-3/8" Combis, and all manifold valves. 10/15/2008 00:00 - 00:30 0.50 BOPSU P PROD2 Finish BOPE TEST. 00:30 - 03:30 3.00 BOPSU N RREP PROD2 Reconfigure pipework on choke line from ROPE. 03:30 - 03:45 0.25 DRILL P PROD2 SAFETY MEETING covering plan to function test agitators, PT packoffs & inner reel valve, and cut coil. 03:45 - 04:45 1.00 DRILL P PROD2 Function test each agitator by MU to the CTC, stabbing onto the well, and pumping. 04:45 - 05:15 0.50 BOPSU P PROD2 PT packoffs and inner reel valve. 05:15 - 06:00 0.75 DRILL P PROD2 Cut coil. 06:00 - 06:15 0.25 DRILL P PROD2 Crew change/safety mtg 06:15 - 09:00 2.75 DRILL P PROD2 Pump slack back. Cut and dispose of 900' of CT and wire 09:00 - 11:00 2.00 DRILL P PROD2 Install CTC. PT 40k, 3500 psi Install BHI UOC 11:00 - 12:10 1.17 DRILL P PROD2 MU BHA while pump slack forward 1.65/1900 IA 60, OA 185 12:10 - 12:50 0.67 DRILL P PROD2 RIH w/ BHA #9 (bi bit, 0.8 deg motor, agitator) circ thru bit 0.62/1350 12:50 - 13:35 0.75 DRILL P PROD2 Park at 3400' to replace sheared reel drive plate bolt and for SWS crew change 13:35 - 15:20 1.75 DRILL P PROD2 Resume RIH IA 353, OA 195 15:20 - 15:40 0.33 DRILL P PROD2 Log tie-in down from 14100', corr -24.5' IA 267, OA 193 PVT 279 15:40 - 16:50 1.17 DRILL P PROD2 Set down twice at window. Wiper to EOB at reduced rates was clean. Finish wiper to TD 2.42/2850 at 15'/min w/ 10.15 ECD 16:50 - 17:20 0.50 DRILL P PROD2 Set down at 15265' and had overpull. Ream back thru and clean up shale area IA 487, OA 200, PVT 273 17:20 - 18:20 1.00 DRILL P PROD2 Resume wiper to TD at 5-15'/min. No problem thru 15320-60'. Agitator is affecting res tool 18:20 - 19:25 1.08 DRILL P PROD2 Drill from 15,803'. 3900 psi FS, 400 psi motor at 2.5 bpm 1.6kDHW06, ROP up 120 fph Downhole communication problems with Resistivity, HOT, & DGS at 2.5 bpm. Reduce to 1.5 bpm and communication w/ tools is good. Drill to 15860' at 2.0 bpm, still having problems w/ tools. Pull BHA. - s • BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ` Task Code NPT Phase Description of Operations ~ 10/15/2008 ~ 19:25 - 23:30 ~ 4.08 ~ DRILL ~ N ~ DFAL ~ PROD2 23:30 - 00:00 0.50 DRILL N DFAL PROD2 10/16/2008 00:00 - 02:00 2.00 DRILL N DFAL PROD2 02:00 - 04:25 2.42 DRILL N DFAL PROD2 04:25 - 04:55 0.50 DRILL N DFAL PROD2 04:55 - 05:30 0.58 DRILL N DFAL PROD2 05:30 - 06:30 1.00 DRILL N DFAL PROD2 06:30 - 08:00 I 1.50 DRILL I N I DFAL ~ PROD2 08:00 - 08:50 ~ 0.83 ~ DRILL ~ N ~ DFAL ~ PROD2 08:50 - 09:10 0.33 DRILL N DFAL PROD2 09:10 - 10:00 0.83 DRILL N DFAL PROD2 10:00 - 11:00 1.00 DRILL P PROD2 11:00 - 11:25 0.42 DRILL P PROD2 11:25 - 11:40 0.25 DRILL P PROD2 11:40 - 13:20 1.67 DRILL P PROD2 13:20 - 15:45 2.421 DRILL P I PROD2 15:45 - 16:00 0.25 DRILL P PROD2 16:00 - 17:15 1.25 DRILL P PROD2 17:15 - 20:50 ~ 3.58 ~ DRILL ~ P ~ ~ PROD2 POOH due to downhole tool failure. Work pipe from 14960' - 14700', appear to be dragging something uphole. Open EDC above window and POH 65 fph ~ 2.7 bpm. SAFETY MEETING covering procedures, hazards, and mitigations to UD & PU BHA. Stand back injector, BO mtr & agitator, blow down BHA. UD Lateral BHA #2. PU Lateral BHA #3 with new CoilTrak tools, same motor, & new HCC bicenter bit. Check CTC. Stab injector. Shallow test agitator. RIH Lateral BHA #3 w/ AKO mtr, agitator, and res tool. Log Tie-in. -25' Correction. RIH. Work pipe through 14670-14750 with mtr work, overpulls, and set downs. Shales appear to be falling in. RIH to 14831' Pull up above window. Open EDC and pump 2.6/3200 to 13000' while do crew change. Call town. PVT 222 RBIH and set down twice at window. Wiper back in hole 2.14/3530 to 14500'. Wiper from 14500' to 14600' at 1.1/2080. Wiper from 14600' 1.52/2530 and slow ream in hole. Took a couple tries to get by 14677'. Set downs at 14782' and 14917'. Continue wiper in hole 1.5/2650 24'/min Wiper from 12050' ~ 2.2/3650 to set down in shale at 15265'. Unable to get by w/o pump. Slow ream 2.4/4000/20L w/ 300 psi MW and 2.3k wob 15262-267' and stalled. PUH w/ 10k OP for 20'. BHA wiper 41.2k PVT 218 Ream at TF of 1758 and 908 w/o success to stalls at 15267'. Ream thru at 90L w/minor MW at 15267' Continue wiper in hole 2.4/4100/90L 20-30'/min to set down at 15431' and 15466'. Slow ream 2.44/4140/58 and was clean. Continue wiper to 15488' stall. Slow ream as before to TD tagged at 15856' PVT 212 Drill from 15856' 2.38/2.30/4130/90L w/ 100-350 psi dill, 0.5-1.5k wob, 10.27 ECD. Diff sticky at 15871', 15881', 15915' 200' wiper due to having trouble sliding back to bottom (fresh mud already ordered) Drill from 15915' to 15923' and can't get back to TD Wiper to window was clean at reduced pulling speeds over known OP areas Pull thru window, clean. Open EDC Wiper to 10000' 2.82/3340 jetting solids OOH (and saw some) Log tie-in down from 14100', corr +11'. Close EDC PVT 178 RBIH and set down 3 times at window. Wiper back in hole 2.12/3400 w/ 1.52/2710 thru Shublik and was clean. Swap to fresh mud. Set down one time at 15267', but ran thru w/o pump at 80L w/o problem. Continue wiper to TD 2.08/3840 ~ 30'/min while finish pumping fresh mud to bit and hole was clean. Tagged at 15926' Drill from 15926' 2.07/1.98/3800/100L w/ 100-300 psi dill, 0.40-1.3k wob w/ 10.12 ECD while displace wellbore to fresh mud w/ 12ppb KG and 3/3 lubs. PU's ~ 42.6k, SO's at 15.8k are clean w/fresh mud in OH. ! ! BP EXPLORATION Page 15 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task I Code NPT Phase Description of Operations 10/16/2008 117:15 - 20:50 3.581 DRILL I P 20:50 - 23:10 I 2.331 DRILL I C PROD2 Drill 2.09/2.01 bpm, 3600 psi FS, 300-500 psi dill, 10.27 ECD, 2k DHWOB, 80-120 fph ROP. Drill 2.08/1.99 bpm, 3850 psi FS, 500-850 psi dill, 10.31 ECD, 1.9-3.9k DHWOB, 50-80 fph ROP. Drill to 16100'. W iper to window. POH 1.5 bpm, 21 fpm. 10k OP at 14900' RIH 1.5 bpm, 40 fpm. 0.5 bpm over billet, 0.2 bpm through shale from 15262'-15267'. SD at 14575', 14644', 15266'-15275'. Drill from 16,097', 2.05 bpm, 3900psi FS, 450-500psi Diff, 1.8k DHWOB, 10.43 ECD. Differentially stuck at 16110', HOT can orient and DPS shows negative WOB. Pull to 85k several times. Relax pipe for 15 min pumps off. Pull to 86k, slack off to 0, pull to 83k and pump 2 bpm for 15 min. Relax pipe for 30 min. Work pipe w/ pumps on & off pulling up to 90k. PJSM. Crude vapor pressure is 0.6 psi. Pump 40 bbls crude. Spot 20 bbls (OH Vol = 16 bbls) then wait 30 min. Pull 70k and free pipe. Circulate remaining crude out of the coil. Wiper to 10,000'. POH 30 fpm, 2 bpm to the window. Decrease to 1.5 bpm above the window (Delta-P too high to open the EDC). 11350' Open EDC Finish wiper to 10000' and back to 14100' 2.88/3750 Log tie-in (missed it first time), Corr +20'. Close EDC RBIH and thru window, clean. Wiper to TD w/ red rates over Shublik w/minor MW Unable to pass 15265' w/o pump. Ream 1.5/3000/90L one time w/ minor MW. Continue wiper to TD 2.0/4000 PVT 234 Drill from tag at 16117' 1.97/1.89/3820/80L w/ 400 psi dill, 2.2k wob w/ 10.23 ECD. Drilled 120'/hr to 16128' and had signs of dill sticking. PU 72k and came free, but were losing 0.2 bpm. W iper up hole and losses slowly healed to 0.1 bpm. PVT 230 Continue wiper OOH at 25'/min and see slow loss of CTP and suspect washout. Wiper thru 15260' shale had 10k overpull, but no MW at 2.4/2600 (suspect big washout). Continue wiper thru OH at 38'/min. Minor OP's, but no MW at known spots. Just before billet, 2.4/2060, continue to window 1.57/1270 and see minor OP w/ CTC at window Park at 14250' Safety mtg re: pinhole hazards PVT 218 POOH looking for washout and filling from BS Find CT pinhole at 13740' bit depth. Actually, it was a hole about 1/2" diameter at a biased weld in a 35% wear area. Wrap w/duct tape and spool onto reel PVT 214 Reel has about 220k RF and is 19137' long POOH filling from BS while make preps to swap reels PVT 145, IA 107 LD drilling BHA. Bit was 1-1-I w/ one plugged nozzle MIRU SWS Safety mtg re: blow down reel w/ N2 PROD2 23:10 - 23:25 0.25 DRILL I C I PROD2 23:25 - 00:00 0.58 DRILL X STUC PROD2 110/17/2008 ~ 00:00 - 03:15 ~ 3.25 ~ DRILL ~ X ~ STUC ~ PROD2 03:15 - 06:30 I 3.25 DRILL I C I I PROD2 06:30 - 07:50 1.33 DRILL C PROD2 07:50 - 08:15 0.42 DRILL C PROD2 08:15 - 09:05 0.83 DRILL C PROD2 09:05 - 10:00 I 0.92 DRILL I C PROD2 10:00 - 10:20 0.331 DRILL IC IPROD2 10:20 - 11:15 I 0.921 DRILL X I DFAL I PROD2 11:15 - 11:30 ~ 0.251 DRILL I X I DFAL I PROD2 11:30 - 11:45 0.25 DRILL X DFAL PROD2 11:45 - 12:10 0.42 DRILL X DFAL PROD2 12:10 - 15:00 I 2.831 DRILL I X I DFAL I PROD2 15:00 - 16:00 1.001 DRILL I X I DFAL I PROD2 16:00 - 16:15 I 0.251 DRILL X ~ DFAL ~ PROD2 rnntea: ~ v~zuoa i i:vsw i+m BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/17/2008 16:15 - 18:45 2.50 DRILL X DFAL PROD2 PT N2 ~ 3000. Pump 15 bbls FW to reel followed by N2. Take all returns to tiger tank until bleed off was complete 18:45 - 19:00 0.25 DRILL X DFAL PROD2 Safety Meeting discussing procedures and hazards to pull the coil across and secure to the reel. 19:00 - 22:20 3.33 DRILL X DFAL PROD2 Unstab injector, cut CTC, install grapple, pull test grapple, pull coil across and secure to the reel. Suck out fluids in bomb bay door w/ vac truck. RD hardline inside reel. Wrap lower half of reel w/ herculite to contain drips. 22:20 - 22:30 0.17 DRILL X DFAL PROD2 Safety Meeting--lowering of the reel and PU of new reel. 22:30 - 00:00 1.50 DRILL X DFAL PROD2 Lower reel w/ pin hole and PU replacement reel. RU reel hardline. 10/18/2008 00:00 - 01:45 1.75 DRILL X DFAL PROD2 RU reel hardline, J box installation, RU reel plates, and install grapple. 01:45 - 02:00 0.25 DRILL X DFAL PROD2 Safety Meeting re: pulling coil across. 02:00 - 06:00 4.00 DRILL X DFAL PROD2 Pull coil across, fluid pack coil, PT hardline, PT inner reel 06:00 - 08:15 2.25 DRILL X 08:15 - 10:00 1.75 DRILL X 10:00 - 11:00 1.00 DRILL X 11:00 - 13:10 I 2.171 DRILL IX 13:10 - 13:40 0.50 DRILL X 13:40 - 15:15 1.58 DRILL X 15:15 - 15:40 0.42 DRILL C 15:40 - 16:35 0.92 DRILL C 16:35 - 19:30 2.92 DRILL C 19:30 - 19:40 0.17 DRILL C 19:40 - 21:00 1.33 DRILL C 21:00 - 21:15 0.25 CASE C 21:15 - 00:00 2.75 CASE C 10/19/2008 00:00 - 00:45 0.75 CASE C 00:45 - 06:20 5.58 CASE C valve, Slack management. PROD2 RU hyd cutter and cut off 368' CT w/o finding wire. Pump slack forward over bung hole to find wire PROD2 MU CTC. PT 40k, 3500 psi. Install BHI UOC PROD2 Open swab. Fill hole w/ 20 bbls mud MU drilling BHA while pump slack forward and displace FW in CT to mud PROD2 RIH w/ BHA # while circ thru bit 0.52/1340 PROD2 Log tie-in down from 14075', corr -24' PROD2 RIH thru window, clean. Wiper in hole following usual practice was clean until set down w/o pump at 12265'. Try to spud thru twice w/o success. Ream 1.56/2600/90L one time w/ stall at 12267' and get by. Continue wiper in hole and start 55 bbls of high vis mud sweep 2.3/3800. Hole was clean until preplanned stopping point at 15890' (end of reel, 1.5 wraps left) PROD2 Wiper OOH with hi vis at bit. Start 2 ppb beads in fresh mud 2.0/3620 PROD2 Wiper 2.0/3300 from 15890' leaving beads in OH 41.1k ~ 30'/min w/ no overpulls PROD2 POH for liner replacing voidage and leaving beads in tubing. PROD2 Tag up. Flowcheck. SAFETY MEETING re: UD BHA PROD2 Standback Injector. BO motor & agitator. Slowdown Coiltrak. UD BHA. RU to run liner RUNPRD SAFETY MEETING re: PU of Liner. RUNPRD PU liner. RUNPRD Finish PU Liner. PU CoilTrak tools. Stab injector. RUNPRD Run liner 100 fUmin pumping 0.3 bpm through the GS spear. Liner: Liner: Indexing guide shoe, 1 jnt 2-7/8" solid liner, O-Ring sub, 56 jnts 2-7/8" slotter line, and BTT steel deployment sub w/ 4" GS profile. RIH to 14255'. PU wt 44.2k# at 0 bpm, 16 fpm. Dn wt at 20.7k# at 0 bpm, 27 fpm. RIH through window at 0 bpm, 30 fpm. RIH through OH at 0 bpm, 55-60 fpm. 14588 10k# set down Ddnrnrl• 71/3/9f10A ~raa•ns • • BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1/2008 End: 10/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2008 00:45 - 06:20 5.58 CASE C RUNPRD 14860 SD, PU & work thoough Shales on depth with a -25' correction 14980 5k# SD 15294 15k# SD, work through 15559 SD, PU Wt 48.5k#, work through 15790 slow to 300 fph, log tie-in, -27' Correction (MD corrected) RIH 60 fpm, 14k# Down Wt. 16020 SD, PU Wt 51 k#. Work against shale for 20 min. Set down on shale & pump 1.4 bpm for 20 min to move cuttings up hole. Pumps off, work liner against shale for 30 min tripping out the injector several times. Set down on shale and pump 1.4 bpm for 20 min. Continue to work liner against shale through shift change w/o success. Discuss 06:20 - 06:50 0.50 CASE X DPRB RUNPRD POH filling from BS w/ no overpulls thru OH 06:50 - 07:30 0.67 CASE X RUNPRD POH w/liner filling from BS to shorten up liner 07:30 - 08:15 0.75 CASE P RUNPRD KWTdvill-discuss 08:15 - 10:30 2.25 CASE X RUNPRD Finish POOH w/ liner filliing from BS 10:30 - 11:45 1.25 CASE X RUNPRD Set injector on legs. LD 3 jts of slotted liner 11:45 - 14:05 2.33 CASE X RUNPRD RIH w/ BHA #13 (rerun of slotted liner) circ thru GS 14:05 - 14:30 0.42 CASE X RUNPRD RIH thru OH 60'/min to planned shoe depth of 16007' CTD w/ two wt loss spots 14:30 - 14:40 0.17 CASE C RUNPRD PUH 52k, RBIH w/ 14k and park at 16007' CTD Start pump and incr rate to 1.9/2600 and release from liner on first try 43k 14:40 - 15:05 0.42 CASE C RUNPRD PUH to tie-in spot. Log down from 15720', Corr -25' Corrected BOL ~ 15982' and TOL ®14321' ELMD PVT 228 15:05 - 18:20 3.25 CASE C RUNPRD POH circ thru GS 0.55/900 18:20 - 18:30 0.17 CASE C RUNPRD SAFETY MEETING re: UD BHA & PU whipstock retrieval tools. 18:30 - 19:45 1.25 CASE C RUNPRD Standback injector, UD Liner BHA, PU Whipstock retrieval tools, Stab injector. 19:45 - 22:05 2.33 FISH C LOWERI RIH w/ Whipstock Retrieval BHA 22:05 - 22:30 0.42 FISH C LOW ER1 Log Tie-In. -25.5' correction. 22:30 - 00:00 1.50 FISH C LOWERI Orient 160R and wash over hole in WS twice from 14299 to 14288. Orient 20L. PU 2 fpm from 14299', 40k# Up wt. Hook WS. Pull slowly to 90k#, 27k DHWOB. 2X decrease to 30k# and pull quickly to 90k#, 27k DHWOB. RIH to stack wt & cock jars, come unlatched. After a few tries hooked WS. Free WS after Jar 3 times. Overpull 15k#, 20k#, & 25k# surface weight; -12k, -15k, -20k DHWOB. 10/20/2008 00:00 - 03:40 3.67 FISH P LOWERi POH 23 fpm, 45k# Up Wt, 0.7 bpm. No returns for 10 min. POH 17 fpm, 1.32bpm in / 0.70bpm out. Returns coming back. POH 73 fpm, 0.83 bpm in / 0.30bpm out. 0.14 bpm losses. SAFETY MEETING re: UD whipstock & CoilTrak tools. 03:40 - 04:30 0.83 FISH P LOWERI UD whipstock & retrieval tools, UD CoilTrak 04:30 - 05:15 0.75 WHSUR P POST PU nozzle. RU Little Red Services to freeze protect IA. 05:15 - 08:35 3.33 WHSUR P POST RIH w/ nozzle to TOW circ 2% KCI ~ 0.35/800 Safety mtg re: LRS FP IA PT LRS f~ 3500 psi. IA 250, OA 178 • • BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Spud Date: 6/14/1981 Event Name: REENTER+COMPLETE Start: 10/1 /2008 End: 10/21 /2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 10/20/2008 05:15 - 08:35 3.33 WHSUR P POST LRS start diesel down the IA l~ 1.0/525. After 20 bbls, incr rate to 1.5/800 08:35 - 09:00 0.42 WHSUR P POST Fin RIH to 14292' CTD and have KCI at noz. Incr rate to 09:00 - 11:50 ~ 2.83 ~ WHSUR ~ P 11:50 - 12:15 0.42 WHSUR P 12:15 - 13:00 0.75 WHSUR P 13:00 - 13:10 0.17 WHSUR P 13:10 - 14:20 1.17 WHSUR P 14:20 - 14:30 0.17 WHSUR P 14:30 - 17:45 3.25 WHSUR P 17:45 - 18:40 0.92 WHSUR P 18:40 - 18:50 0.17 WHSUR P 18:50 - 20:30 1.67 WHSUR P 20:30 - 20:40 0.17 WHSUR P 20:40 - 22:00 1.33 WHSUR P 22:00 - 00:00 2.00 WHSUR P 10/21/2008 100:00 - 02:00 I 2.001 WHSUR ~ P 1.82/1250 and take retums to tiger tank LRS fin pump 134 bbls (2500') diesel 1.5/800 into IA taking returns up tubing. SI IA w/ 600 psi, OA 188. Move LRS to CT side POST POOH circ 2% KCI 2.0/1425, 2.43/1870 and fin displace wellbore of mud, crude, diesel and gas (from IA) PT LRS and load CT w/ 30 bbls diesel. Rig displace and FP wellbore from 2000' POST Close swab w/ whp=0, IA=75, OA=215 Jet stack. Set injector back and remove nozzle w/ stinger POST WO DSM valve crew MI SWS N2 POST Safety mtg re: set BPV POST Bring DSM lubricator to floor. Set 4" CIW BPV. Tubing is on sli vac while equalizing w/ IA=30 SI MV and SV. RDMO DSM POST Safety mtg re: pickle/blowdown reel POST Install nozzle, stab back on. Rig mix and pump 14 bbls corr inhibitor. LRS pump 10 bbls diesel. RDMO LRS. MIRU SWS N2. PT 3500. Blow down reel w/ N2 and bleed off POST Cut off CTC and install internal grapple. Crew change. Pull test then retighten setscrews. POST SAFETY MEETING re: pulling coil across. POST Pull coil across and secure to the reel. C/O annular preventer element on BOPE. POST SAFETY MEETING re: reel swap POST Swap reels. Continue working on annular preventer element. POST Finish C/O of annular preventer. ND BOPE. Clean & unwrap new reel, Install grapple in CT. POST GBR welders cut inner reel ramp on new reel to be able to RU hardline. Install tree cap. PT to 4000psi RDMO RELEASE RIG ~ 02:00 10/21/08 TOTAL TIME FROM ACCEPT TO RELEASE: 17 DAYS, 15.5 HOURS !' •'' • • BP Alaska gHU~~s .F ~;` Baker Hu hes INTE Surve Re ort g Q Y P I~vTrQ l uiupan~: 6P Amoco i)atc: 10!31!2006 -_ Tinic: 13:25:21 Pa~c: I field: Prudhoe Ea_V (~n-ordinatr(VE) Retcrc acc: Well: Y-09, True North tiitr: PC1 Y Pad \crLical ~'h~'D~ ILcfcrcuc c: Y-09AlAPB1 3?] ~~cll: Y-09 Seeuon 115) ILclcrence; VVcll i0.00fJ_O.OOE,'1?6.35A~i) V~cll~~;uh: Y-U9AL1-u1 Survc~ (alrulaLinu ~lel hnd: fdtinimuni Curvature I)b: Jrade 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 i Site: PB Y Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5948541.48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Longitude: 148 48 18.991 W I Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.12 deg Well: Y-09 Slot Name: Y-09 Well Position: +N/-S 384.41 ft Northing: 5948866.44 ft Latitude: 70 16 3.816 N +E/-W -3023.88 ft Easting : 644718.12 ft Longitude: 148 49 47.008 W Position Uncertainty: 0.00 ft Wellpath: Y-09AL1-01 Drilled From: Y-09AL1 500292057961 Tie-on Depth: 14471.98 ft Current Datum: Y-09A/APB1 Height 87.72 ft Above System Datum: Mean Sea Level Magnetic Data: 10/8/2008 Declination: 22.94 deg Field Strength: 57675 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 38.72 0.00 0.00 176.35 ~ ~urvey Program for Definitive Wellpath Date: 10/8/2008 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 100.72 9200.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 9202.00 11139.76 2 : MWD -Standard (9202.00-11 MWD MWD -Standard 11145.00 14283.21 3 : MWD -Standard (11145.00-1 MWD MWD -Standard 14292.00 14471.98 MWD (14292.00-15621.00) (3) MWD MWD -Standard 14498.00 16128.24 MWD (14498.00-16128.24) MWD MWD -Standard Annotation ~tll I ~ I) ft ff 14471.98 9036.73 TIP 14498.00 9035.02 KOP 16128.24 9044.51 TD Survey: MWD Start Date: 10/13/2008 Company: Baker Hughes INTEO Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Q ~ -~~~ ~. • • p~ BP Alaska gNU~~s '" Baker Hu hes INTE Surve Re ort g Q Y P 1N rN.Q f nui~rwt: GP Amoco _ .. ___ Date: 1U/31 ;2008 finis 13-25:21 __ Pa~c: '_ ~'ll'~1~: P~U d~IOP B8V CO-O 1'0111:1 L('(,~f.) ~~l'ICI"l'll l'l': ~/l~C~~~ ~'~-d~, TI LIC NOft~l 5itr~ P6 `f Pad ~crlical 1'I-~~D i Ilclcrcncc: Y-09A!APB1 8?., ~~~~u: ~-o ~ ~«~~~~~~~ ~~s~ iz,~i~~«~,~~~: weu ~o.aor~ o.ooE 1 /s.s <~zi) ~~cll~~alli: Y-U 9i;P1-01 Suns} falcul a~ion ~Trihud: P:linimurn Gui vature Ub: Uracle `unc~ JII) lurl Azim l~'Il tip."f~l) A;:~ fly \Ly~A \I:yil~ ~S I1L5 fool tt de•g deg ri ft ft ft tt f[ ft deg/100ft j 14471.98 94.00 155.01 9036.73 8949.01 -8333.90 56.88 - 5940535.81 644935.19 8320.59 -- 0.00 ---, MWD I 14498.00 93.56 148.73 9035.02 8947.30 -8356.79 69.11 5940513.16 644947.86 8344.20 24.14 MWD I 14545.43 98.69 159.03 9029.94 8942.22 -8399.05 89.86 5940471.31 644969.42 8387.70 24.14 MWD 14571.91 98.21 164.49 9026.05 8938.33 -8423.91 98.05 5940446.61 644978.09 8413.04 20.48 MWD 14597.41 94.05 168.79 9023.32 8935.60 -8448.57 103.90 5940422.07 644984.41 8438.02 23.39 MWD 14623.86 87.76 166.27 9022.91 8935.19 -8474.38 109.61 5940396.38 644990.61 8464.14 25.62 MWD i 14668.99 85.17 162.33 9025.69 8937.97 -8517.73 121.80 5940353.27 645003.63 8508.18 10.43 MWD 14701.47 83.73 162.66 9028.83 8941.11 -8548.56 131.52 5940322.64 645013.94 8539.57 4.55 MWD I 14732.64 83.79 165.11 9032.22 8944.50 -8578.33 140.12 5940293.05 645023.11 8569.82 7.82 MWD j 14764.36 83.52 168.16 9035.73 8948.01 -8609.00 147.41 5940262.53 645030.98 8600.89 9.59 MWD i 14793.18 83.58 168.31 9038.96 8951.24 -8637.03 153.24 5940234.61 645037.36 8629.24 0.56 MWD ~ 14835.17 84.56 169.53 9043.30 8955.58 -8678.02 161.27 5940193.79 645046.17 8670.65 3.71 MWD 14874.13 85.66 170.22 9046.62 8958.90 -8716.23 168.09 5940155.72 645053.73 8709.22 3.33 MWD 14920.46 86.62 167.78 9049.74 8962.02 -8761.60 176.91 5940110.53 645063.42 8755.07 5.65 MWD 14961.36 86.96 163.74 9052.03 8964.31 -8801.17 186.96 5940071.16 645074.22 8795.20 9.90 MWD 14994.75 87.55 161.36 9053.63 8965.91 -8832.99 196.96 5940039.54 645084.83 8827.59 7.34 MWD 15025.87 88.19 160.13 9054.79 8967.07 -8862.35 207.21 5940010.39 645095.65 8857.54 4.45 MWD 15063.41 90.40 160.02 9055.25 8967.53 -8897.63 220.00 5939975.36 645109.11 8893.57 5.89 MWD 15092.40 92.40 159.57 9054.54 8966.82 -8924.83 230.01 5939948.36 645119.64 8921.35 7.07 MWD 15123.06 92.46 160.61 9053.24 8965.52 -8953.63 240.45 5939919.77 645130.63 8950.75 3.39 MWD j 15162.82 92.58 160.12 9051.50 8963.78 -8991.04 253.79 5939882.62 645144.69 8988.94 1.27 MWD I 15194.21 92.80 161.32 9050.02 8962.30 -9020.64 264.15 5939853.23 645155.61 9019.14 3.88 MWD 15222.39 92.64 161.89 9048.69 8960.97 -9047.35 273.03 5939826.70 645165.00 9046.36 2.10 MWD 15252.55 92.79 163.74 9047.26 8959.54 -9076.13 281.93 5939798.10 645174.45 9075.65 6.15 MWD 15282.14 92.86 162.33 9045.80 8958.08 -9104.40 290.55 5939770.00 645183.62 9104.41 4.77 MWD 15309.14 92.64 161.14 9044.50 8956.78 -9130.01 299.00 5939744.56 645192.56 9130.50 4.48 MWD 15359.39 92.98 159.92 9042.04 8954.32 -9177.33 315.73 5939697.58 645210.19 9178.79 2.52 MWD 15390.95 92.92 159.55 9040.41 8952.69 -9206.89 326.65 5939668.23 645221.68 9208.99 1.19 MWD 15426.23 93.10 158.54 9038.56 8950.84 -9239.79 339.25 5939635.58 645234.90 9242.63 2.90 MWD 15460.88 93.07 158.80 9036.70 8948.98 -9272.02 351.83 5939603.60 645248.11 9275.60 0.75 MWD 15499.72 91.32 159.08 9035.21 8947.49 -9308.24 365.78 5939567.66 645262.74 9312.63 4.56 MWD 15531.95 91.32 159.86 9034.47 8946.75 -9338.42 377.08 5939537.71 645274.62 9343.46 2.42 MWD ~ 15558.47 91.87 160.28 9033.73 8946.01 -9363.34 386.12 5939512.97 645284.13 9368.91 2.61 MWD 15588.75 90.89 161.67 9033.00 8945.28 -9391.95 395.98 5939484.55 645294.55 9398.10 5.62 MWD 15624.05 90.12 160.54 9032.69 8944.97 -9425.35 407.41 5939451.38 645306.62 9432.15 3.87 MWD 15661.54 89.51 160.34 9032.81 8945.09 -9460.68 419.97 5939416.31 645319.85 9468.21 1.71 MWD 15701.60 89.26 161.04 9033.24 8945.52 -9498.48 433.21 5939378.77 645333.82 9506.78 1.86 MWD 15729.60 88.83 159.80 9033.71 8945.99 -9524.86 442.59 5939352.58 645343.70 9533.70 4.69 MWD 15757.13 88.16 160.72 9034.43 8946.71 -9550.76 451.89 5939326.86 645353.49 9560.14 4.13 MWD 15785.75 87.05 159.73 9035.63 8947.91 -9577.67 461.56 5939300.15 645363.68 9587.61 5.19 MWD 15819.26 87.94 157.25 9037.09 8949.37 -9608.81 473.84 5939269.25 645376.55 9619.48 7.86 MWD 15854.11 88.25 157.93 9038.25 8950.53 -9641.01 487.12 5939237.31 645390.45 9652.46 2.14 MWD 15883.94 89.54 154.85 9038.82 8951.10 -9668.33 499.06 5939210.22 645402.91 9680.49 11.19 MWD 15915.94 91.81 150.05 9038.45 8950.73 -9696.69 513.85 5939182.16 645418.25 9709.73 16.59 MWD 15947.21 92.27 149.57 9037.33 8949.61 -9723.71 529.57 5939155.45 645434.48 9737.69 2.13 MWD 15977.19 90.74 149.09 9036.55 8948.83 -9749.48 544.86 5939129.98 645450.26 9764.39 5.35 MWD 16013.41 87.27 150.60 9037.18 8949.46 -9780.79 563.04 5939099.03 645469.04 9796.79 10.45 MWD 16078.24 85.98 141.24 9041.00 8953.28 -9834.33 599.26 5939046.19 645506.28 9852.53 14.55 MWD 16128.24 85.98 141.24 9044.51 8956.79 -9873.23 630.49 5939007.91 645538.25 9893.34 0.00 MWD 'VEI.LHEAD= GRAY CTUA TOR=' :B. EI,EV = BAKER 87.77 3F. ELEV = 51.65 :OP = 3200' Aax Angle = 100 ~ 14472' )alum MD = )alum TV D = 10577 8800' SS aiarc i t rvv i w: `~09A L1 / L1-01 DRLG DRAFT r,1 LJ ~ 13-3/8" CSG, 72#, L-80, D = 12.347" Minimum ID = 2.37" a~ 14321' AL1-01 Lir- <~ _ ment Sub I 1-5/8" X 7" w /TIEBACK, ID = 6.375" X 7" BKR HMC LNR HGR, ID = Y-09 141/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 7" X 5-112" BKR ZXP PKR W/ T~BACK, ~ = 5.250" 5-1 /2" LNR, 17#, L-80, .0232 bpf, ~ = 4.892" 7" LNR, 29#, L-80, BTC, 0.371 bpf, ID = 6.184" ~ 10479' I I 10642' I PERFORATION SLMAMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 91 ~ 11030' Note: Refer to Production DB for historical data SIZE SPF INTERVAL OpNSgz DATE SEE PAGE 2 FOR PERF BREAKDOWN Top of Window ,Orientation 20 LHS ~ 14292' op of 2-7;'8" STL. 6 ^ 6 ppf, ~-8C Slotted LNR, ID = 2.441 - 14321' Bottom of Window 14302' Y-09A .0152 bpf, ID = 3.953" 141 /2" HES HXO SSSV NIP, ID = 3.813" I GAS L~TMANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DA 6 2996 2996 6 KBL-2LS DOME Nfr 16 04/0! 5 5329 4971 46 KBL-2LS DOME Nff 16 04/0: 4 7120 6222 43 KBL-2LS DOME INT 16 04/0! 3 8550 7361 29 KBL-2LS DOME Mff 16 04/0: 2 9239 7975 29 KBL-2LS SO NYT 22 04/0! 1 10254 8663 48 KBL-2LS "DM NVT 0 0310: 'S T#1 HAS T®G PATCH ACROSS DMY 9-5/8" MI.LOtIT WIJDOW (Y-09A~ 9207 - 9218' 10402' - 141 /2" HES X N~, ID = 3.813" I 10413' 7" X 41 /2" BKR S-3 PKR, ID = 3.875" 104$6' 41 /2" HES X N~, ID = 3.813" 10457' 41/2" HES XN NIP, NSlled tom = 3.80" /2" WLEG, ID = 3.958" u~ TT LOGGED 07/28/97 /2" X 41 /2" XO, ~ = 3.958" 14499' Top of Aluminum Billet I \ 2-718" STL, 6.16 ppf, L-80 Sbtted LNR, ID = 2.441" 15620' ~\ -- -- - ---- -09AL ~~ ~ ~~ ~ ~~ ~ 15982' 2-7/8" STL, 6.16 ppf, L-80 \~ ~ Sbtted LNR, ID = 2.441" \~~ ~~ ~ \~~ .~ ~ Y-09A L 1-01 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/04/81 ORIGINAL COMPLETKNI 07/15/97 CHH SIDETRACK COMPLETION 07/04/01 CWKAK CORRECTIONS 03/23/07 RRD/TLH 41/2" STRADDLE PATCH SET 10/20/08 NC~RDIC2 CTDMULTl-LATERAL (Y-09AL1-L1-01) 10/30/08 TLH CORRECTIONS PRUDHOE BAY UNfT WELL: Y-09AL1 ! Y-09AL1-0 PERMT No: 2081270 / 2081280 API No: 50-029-20579-60161 SEC 33, Ti 1 N, R13E, 1387' SNL i3< 98' WEL BP Exoloration IAlaskal ~ Y-09A ~ PERFS PERFORATION suMMnRY REF LOG: TCP PERF A NGLE AT TOP PERF: 75 ~ 10850' Note: Refer to Production DB for historical perf data S2E SPF MVTERVAL Opn/Sqz DATE 2-7/8" 4 10850 - 11000 O 05/14/02 2 3/4" 4 11030 - 11060 O 07/13/97 2-3/4" 4 11120 -11160 O 07/13/97 2-3/4" 4 11190 - 11250 O 07/13/97 2-3/4" 4 11540 -11580 O 07/13/97 2-3/4 4 11610 - 11740 O 07/13/97 2-7/8" 4 11750 - 11800 O 05/14J02 2-3/4" 4 11850 - 11980 O 07/13/97 2-7/8" 4 12000 - 12100 O 05/14/02 2-3/4" 4 12260 - 12390 O 07/13/97 2-3/4" 4 12500 - 12550 O 07/13/97 2-7l8" 4 12550 - 12550 O 05/14/02 2-7/8" 4 12670 - 12760 O 05/14/02 2-3/4° 4 14460 - 14540 O 07/13/97 2-314" 4 14830 - 15000 O 07!13/97 2-3/4" 4 15100 - 15150 O 07/13/97 2-3/4" 4 15170 -15280 O 07/13/97 2-3/4" 4 15330-15360 O 07/13!97 2-3l4" 4 15640 - 15690 O 07/13/97 2-3/4" 4 15770 - 15900 O 07/13/97 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/04!81 ORIGINAL COMPLETION 07/15/97 CHH SIDETRACKCOMPLETION 07/04/01 CH/KAK CORRECTIONS 03/23/07 RRD/TLH 4-1/2" STRADDLE PATCH SEf 10/20108 NORDIC2 CTDMULT1-LATERAL (Y-09AL1-L1-01) 1 fl/'~/1/(1R I TI H I rC1RRFrTI[1NR PRUDHOE BAY UNIT WELL: Y-09AL1 / Y-09AL1-( PERMIT No: 2081270 / 2081280 API No: 50-029-20579-60 / 61 SEC 33, T11 N, R13E, 1387' SNL & 98' WEL RP Firninrafinn /Olackal ri.r BAKER H1iGNES 7260 Homer Drive Anchorage, AK 99518 r~ To Whom It May Concern: November 14, 2008 °Please find enclosed directional survey data for the following wells: N-14BPB1 N-14B 01-21A Y-09AL1 Y-09AL1-O1 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: G~~ ,State of Alaska AOGCC DATE: ~ ~ Cc: State of Alaska, AOGCC ~~~ • I~.~ Nordic 2/Y-09 Sidetracks Upda: ~ Page 1 of 1 Maunder, Thomas E (DOAj From: Sarber, Greg J [SarberJG@BP.com] Sent: Monday, October 20, 2008 9:19 AM ~ - ~S A ~--~~ ~- ~ ~. To: Maunder, Thomas E (DOA) Subject: Nordic 2/Y-09 Sidetracks Update ~~~'- \~ Tom, Just a quick update. Nordic 2 managed to deal with the problematic shale long enough to get Y-09AL1-01 drilled to the planned TD. Liner was sucessfully run on this lateral, and the rig is preparing to move off the well. The appropriate post well reporting paperwork will be submitted to the AOGCC for the 2 laterals that were drilled and completed. We will not need to drill the contingency lateral on Y-09 that we discussed last Thursday. Thank you for your assistance. Cheers, Greg Ph: (907) 564-4330 Cell: (907) 242-8000 Email: sarberjg@bp.com 10/20/2008 Y-09AL 1-02 Approval ~ Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Y ~ ~ ~ ~ ~ ~ _ ~~ Sent: Thursday, October 1fi, 2008 2:59 PM To: 'Barber, Greg J' ~ ~ ~ ~~ Subject: RE: Y-09AL1-01-01 Approval Greg, This confirms our phone conversation of a few minutes ago. Commissioner Seamount has given his oral approval for BP to continue operations and drill the new well segment, if necessary. There is one change to the information in your message. After talking with Steve Davies, it is preferred that the name of this new segment be Y-09AL1-01-01. Employing this name honors the convention that Steve and I have tried to implement where there are redrills (A, B, etc), laterals (AL1, AL2, etc), spokes (AL1-01,AL1-02, AL2-01, etc) and in this case a "spoke of a spoke" (AL1-01-01). The API number for this segment will be incremented 1 digit to -fit- in digits 11 and 12. Call or message with any questions. Tom Maunder, PE AOGCC From: Sarber, Greg J [mailto:SarberJG@BP.com] Sent: Thursday, October 16, 2008 2:09 PM To: Maunder, Thomas E (DOA) Subject: Y-09AL1-02 Approval Dear Mr. Maunder, Verbal approval is requested for a permit to drill an additional lateral on Y-09A. Attached is a summary of the current state of operations on Nordic 2. The CTD rig is adding 2 horizontal sidetracks on well Y-09A. The second sidetrack is experiencing hole problems, and a portion of that lateral could potentially be lost later today. BP is seeking conditional approval to continue operations on Y-09A should the L1-01 lateral be lost. BP intends to sidetrack above the problem shale and continue drilling to the origional L1-01 TD. Because a portion of the L1- 01 lateral will reamain open, it will contribute production and will not be classified as a plugback lateral. Anew PTD will be needed for the new L1-02 lateral which targets the origional L1-01 bottom hole location. This PTD application will be completed and delivered to the AOGCC on Monday. Thank you for your consideration. Sincerely, Greg Sarber, PE BPXA Ph: (907) 564-4330 Cell: (907) 242-8000 Email: sarberjg@bp.com «Y-09AL1-02 Summary for Permit.ZlP» 10/16/2008 ~~ ~ 1 ~._ L~ ALASSA OIL A1QD GrAS C01~5ERQATIOI~T CO1rIIrIISSIOI~T Greg Sarber CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-09AL1-O1 BP Exploration Alaska, Inc. Permit No: 208-128 Surface Location: 1387' FNL, 98' FEL, SEC. 33, Tl 1N, R13E, UM Bottomhole Location: 529' FNL, 540' FWL, SEC. 10, T10N, R13E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Y-09A, Permit No 197- 083, API 50-029-20579-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . Sincerely Daniel T. Seamount, Jr. r~ -~'~ Chair DATED this ~ ¢day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~_ STATE OF ALASKA ~1p ~ ~, ~ ~. ~~ ;~I ALASI~IL AND GAS CONSERVATION COMMIN ~v PERMIT TO DRILL pp,,~/•~ ~~~' " ~["~~ f~- `1 20 AAC 25.005 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. peci~y i wed( i~ proposed for: ^ Coalbed Metfiane []~i8s Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Nu er: PBU Y-09 -01 ~'~ A~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 16,015' TVD 8934'ss 12. Field /Pool(s): 4,~LL,, Prudhoe Bay Field / Prudhbe~ay 4a. Location of Well (Governmental Section): Surface: 1 387' FNL 98' FEL SEC T11N R13E UM 33 7. Property Designation: ADL's 028287, 047471 Pool , , , , . , , Top of Productive Horizon: 843' FNL, 314' FEL, SEC. 04, T10N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 1, 2008 Total Depth: 529' FNL, 540' FWL, SEC. 10, T10N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7,320' 4b. Location of Well (State Base Plane Coordinates): Surface: x-644718 y-5948866 Zone-ASP4 10. KB Elevation (Height above GL): 87.72' feet 15. Distance to Nearest Well Within Pool: 1,180' 16. Deviated Wells: Kickoff Depth: 14,500 feet Maximum Hole An le: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3,142 Surface: 2,262 18. Casin Pro ram: S ecificatio ns To - Settin De th -Bo ttom uanf of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" 2-7/8" 6.16# L-80 STL 1 595' 14 420' 8952'ss 16 015' 8934'ss Uncemented Slotted Liner 19. PRESE NT WELLCONDITION SUMMARY (To be completed. for Redrill and Re-entry Operations) Total Depth MD (ft): 16,007' Total Depth TVD (ft): 9 034' Plugs (measured): None Effective Depth MD (ft): 15,920' Effective Depth TVD (ft): 9,033' Junk (measured): None Casing Length Size Cement Volume MD - TVD Conductor /Structural 110' 20" x 30" 8 cu ds Concrete 110' 110' Surface 2 686' 13-3/8" 3770 cu ft Permafrost II 2 686' 2 686' Intermediate 9 202' 9-5/8" 1435 cu ft Class'G' 130 cu ft PF'C' 9 202' 7 943' Production Liner 1 612' 7" 220 cu ft Class'G' 9 030' - 10642' 7 789' - 8 931' Liner 5 528' 4-1 /2" 653 cu ft Class 'G' 10 479' - 16 007' 8 820' - 9 034' Liner Y-09L1 1 175' 2-7/8" Uncemented Slotted Liner 14 500' - 15675' 8940' - 8946' ss Perforation Depth MD (ft): 10,850' - 15,900' Perforation Depth TVD (ft): 9,030' - 9,033' 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 Name Gre Sarber Title CT Drilling Engineer tt~~ Prepared By Name/Number: Si nature Phone 564-4330 Date O•-3 `48' Terrie Hubble, 564-4628 Commission-Use Onl Permit To Drill Number: ®~8 0~~ API Number: 50-029-20579-61-00 Permit A p o al ~ See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me_th/ane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes lM No Mud Log Req'd: ^ Yes (~dNo (~ HZS Measures: ~es ^ No Directional Survey Req'd: l~'es ^ No Other. ~~®~j~~l \~~` '~.. \ ~' „y- APPROVED BY THE COMMISSION Date ~°"~~ ,COMMISSIONER Form 10-401 Revised 12/1005 Submit In Duplicate ~, ~~i~AI by BPXA Prudhoe Bay Y-09AL1, Y-09AL1-01 CTD Sidetracks August 1, 2008 To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Greg Sarber CTD Engineer Date: August 1, 2008 Re: Y-09AL1, Y-09AL1-01 Permits to Drill Permit to Drill approval is requested for 2 sidetrack laterals added to well Y-09A. History - Y-09A is a Rig ST drilled in 1997 to the southern edge of the reservoir. The wellbore is a 5000' long horizontal 4 ~/2" monobore completion, cemented and perforated. The initial oil rate was -5000 bopd, with no water and a low GOR. It averaged 2000 bopd for the first year and declined to 700 bopd over the first two years of production. A HCL pert wash in October 1999 increased the rate to 900 bopd and decreased the rate of decline. Add perfs (490') were shot in the heel section of the well in May 2002 and the rate increased from 400 bopd to 600 bopd. A second HCL pert wash was done in September 2006 but did not improve production. A TIFL and subsequent MIT-IA failed after this pert wash. A tubing caliper survey was run and indicated the tubing was in fair-to-good condition, with the maximum penetration <34%. A LDL was run and found a leak at GLM #1 at 10,254'. The leak was patched in March 2007 and Y-09A returned to production. It currently produces at 200 bopd, 87% wc, 2800 gor, and has cumulative production of 2.4 mmbo. Reason for PTD Request -Your approval is requested to drill two coil sidetrack laterals from the Y-09A producer. When drilled in 1997, Y-09A tested the southern edge of the reservoir in the WPWZ. The wellbore is a cemented and perforated 4 ~/z" monobore completion. The Y-09A horizontal is ideally situated to drill two lateral legs to test large undeveloped areas east and south of the current drainage area. The scope of this CST includes pulling the tubing patch from 10,240'; drilling two lateral legs; completing with slotted liners landed outside the window; pulling the CST whipstock to regain access to the lower half of the parent wellbore, and then rerunning the tubing patch to restore tubing integrity. CTD Sidetrack Summary Pre-CT Rig Work: (Began on May 1, 2008) 1. MIT IA, OA Passed 5-08-2008 2. Dummy off all GLM's. Done 5-08-2008 3. Drift 4-1/2" liner to confirm it is possible to recover BTT 4-1/2" KB straddle patch. 4. Install 2nd 2" block valve on the IA (needed for T x IA communication after pulling patch during Rig MIRU operations.) 5. Fish BTT 4-1/2" KB straddle patch. 6. If step 3 unsuccessful, rig up coil and fish BTT 4-1/2" straddle patch. 7. Fish 2-7/8" nipple reducer from XN nipple at 10,475'. 8. After patch and nipple reducer OOH, mill XN nipple to 3.80" using Left handed motor. 9. Using LH motor and mill RIH to PBTD. 10. Run dummy whipstock to 14,500'. 11. Run memory caliper tool from 14,500' to surface. 12. AC-PPPOT-T 13. Install a BPV ~14. Bleed gas lift and production~rlines down to zero and blind flange. 15. Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on October 1, 2008 using Nordic rig 2) U Nordic Rig 2 2. NU 7-1 BOPE and test. 3. Pull BPV. 4. Mill 3.80" window at 14,400'. 5. Drill build/turNlateral section of L1 with 3.75" x 4.125" bicenter bi , teral to 15,675'. 6. Run a 2-7/8" L-80 slotted liner string with an aluminum deployment sleeve top at 1 . .. .., .. . ,cs , v 4vr,vr„ ~~., a v,cvvv, .., nrvwvr~ ua , ~,vvv ~~n„ a v. i v via. 8. Drill build/turn/lateral section of L1-01 with 3.75" x 4.125" bicenter bit, and drill L1-01 lateral to 16,015'. 9. Run a 2-7/8" L-80 slotted liner string with an L-80 deployment sleeve with top at 14,420'. 10. Recover Baker monobore whipstock at 14.400'. 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 ~`~S ~ Ec. v~~ T` 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. Re-run patch 10,240'-10,275', over GLM #1. 5. 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-center bits used) Casing Program: Uncemented Slotted liner • 2-7/8", L-80 6.16# STL 14,500' and -15,675' and for Y-09AL1 lateral • 2-7/8", L-80 6.16# STL 14,420' and -16,015' and for Y-09AL1-01 lateral Existing casina/tubina 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 29#, Burst 8160, collapse 7656 psi 4-1/2", L-8012.6#, 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 on both laterals is 97.15 deg at 14,420'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 7,320' (Y-09AL1-01) to unit boundary to south. • Distance to nearest well within pool -1,180 ft. (To Y-14B from heel of Y-09A) Logging • MW D directional, Gamma Ray and Resistivity will be run over all of the open hole section. Hazards • The maximum H2S concentration on the parent Y-09A well is 30 ppm recorded on 4/19/2008. • The maximum H2S concentration on the pad is on well Y-28 at 200 ppm on 8/29/1996. • Lost circulation is a common problem on Y pad, due to faulting and low reservoir pressure. However, the lost circulation risk on these wells is considered moderate due to the absence of faulting in the area accessed by these 2 laterals from seismic data. If complete losses are encountered, drilling will continue with 2% KCL as the drilling fluid. • The TD's are challenging from a weight on bit standpoint. The Andergauge Agitator tool will also be used to provide maximum weight on bit to allow TD to be reached. • There will be T x IA communications established after the patch is pulled. There will need to be a second redundant, 2" block valve installed on the IA prior to rig arrival. Reservoir Pressure • The reservoir pressure on Y-09A was last recorded at 3,142 psi at 8,800' TVDSS in September 2007. (6.87 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,262 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewmanlferrie Hubble 7Rff= d_1rl~raa,FRnnr WELLHEAD= GRAY ACTUATOR= BAKH2 KB. ELEV = 87.77 BF. ELEV = 51.65 KOP = 3200' Max Angle = 100 ~ 14472' Datum MD = 1057T Datum TV D = 8800' SS SAF OTE3: OLD P8A'D WELLBORE NOT Y-O9A SHOIAMONTHISDU4GRAMBELOWTHE9-5/S" CSG WINDOW. WELL EXCEEDS 70° ~ 10854' & GOES HORIZONTAL ~ 10950'. 2160' 41n" HES H10 SSSV NP. D = 3.813" 13-318" CSG, 72#, L-80, D = 12.34T ~--~ 2686' r- Minimum ID = 2.31" @ 10457' 2-7/8" NIPPLE REDUCER L-80, .0152 bpi, D = 3.958" KR W/ 71EBAd(_ ID = 5 75n" ~5-1n' LNR 17#, L-80, .0232 bpf, D = 4.892' ~ PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 91 ~ 11030' Note: Refer to Production DB for historical pertdeta A 2 FOR PERF BREAKDOWN I T LNR, 29#, L-80, .0371 bpf, D = 6.184" 41/2" 6 2996 2996 8 KBL-2LS DOME Ni 16 06102!08 5 5329 4971 46 KBL-2LS DOME N~tr 16 06/02/08 4 7120 8222 43 KBL-2LS DOME Ni 18 O6/OZ/Q8 3 8550 7361 28 KBL-2LS D~AE Mfr 18 06/02/08 2 9239 7975 29 KBL-2LS S/O Nff 22 08/02/08 1 10254 8683 48 KBL-2LS •~AIY NT 0 03/03/07 9030' H9{i8" X T BKR Z~ PKR W! TIEBApC, D = 6.375" 10240'"10275' 41n` KB STRADDLEFtiTCI{ D=245" 10473 ~ /' X47/L' tSKK S-3 PICK N.! = J.tl/D- I 10436' 41J? HES XNIP, D = 3.813" 10457' 41/2' HES J0J NIP, D = 3.725" 10457' 2.313° NIPPLE REDUCER (03104107) 10469' 41/2" WLEG, D = 3.956" 10473' ELMD TT LOGGED 07n8197 10500' 5.1/2" X 41/2" ~, D = 3.958" 9518" MLLOUT W NDOW 9207 -9218' \ 10642' 7" LNR 294. L-8o BTG .0371 bpf, D = 6.184" .0152 bpf, D = 3.953` D4TE REV BY COMMENTS ATE RP/ BY 07!04181 ORIGINALCOYPLETION 09n4/07 RCT/PJC MNDCORPECTION 07115197 CHH SIDEfRACKCaAAPLETION 05/24/08 SWGSV GLV GO {05/16108) 07/04/01 CF~IIKAK CORRECfIDNS 06!06!08 KSBITD GLV GO (06/02108) 05/142 JAF/TLH ADD PSiFS 03!23/07 RRDITLH 41n' STRADDLE FATCH SET 04/07-07 G1WPAIG GLV GO /PILL PLUG (04I05ro7 PRl1DFfOE BAY UNR WELL: Y-09A P8'tMT ND: a1970830 API No: 50-029.205/9-01 SEC 33, T11 N, R13E 138T SNL 8 98' WEL BP Expbratbn (Alaska) Y-09A PERFS PERFORATI~t SUNMARr R~ LOG: TCP P92F ANGLE AT TOP PBiF: 75 ®10850' Note: Refer to Production DB for historical pert data SQE SPF MER1/AL Opn/S~ DATE 2-7/8" 4 10850 -11(x10 O 05/14/02 23/4" 4 11030 -11060 O 07/13/97 2-3/4" 4 11120 -11160 O 07/13197 2-3/4" 4 11190-11250 O 07/13!97 23/4" 4 11540 - 11560 O 07/13197 2-314" 4 11610 -11740 O 07113!97 2-718" 4 11750 - 11800 O 05/14/02 23/4" 4 11850 -11960 O 07/13/97 2-7/8" 4 12000 - 12100 O 05/14102 2-3/4" 4 1228D- 12390 O 07/13/97 2-314" 4 12500 -12550 O 07/13/97 2-7/S" 4 12550 -12650 O 05/142 2-7/8" 4 72670 - 12760 O OS/14~2 2-3/4' 4 14460 -14540 O 07/137 2-314" 4 14830 - 15000 O 07/13/97 2-314" 4 15100 - 15150 O 07!13187 2-3/4' 4 15170 - 15280 O 07/13/97 2-3/4" 4 15330 -15360 O 07/13/97 2-3/4" 4 15640 -75690 O 07/13/97 2314" 4 15770 - 15800 O 07/13/97 DATE REV BY COMr6VTS DOTE REV BY COMu6~fTS 07/04/81 ORIGINAL C CNN PLETION 09124!07 RCfrP.~ NNI D CORRECTION 07/15J97 CHH SIDETRACKCOAAPLETKIN 05/24/08 SWGSV GLV ClO(05116I08) 07/04/01 CHIKAK 05114/02 JAF/TLH ADD PERFS 03/23/07 RRD/TLH 4-112" STRADDLE PATCH SEf 04/07/07 CJNIPAG GLV C:lO & PULL PLUG (OMOS/07) PRUDHOEBAY UNfT W9.L: Y-09A PERMT No: ti 970830 API No: 50029-20579-01 SEC 33, T11 N, R13E,1387' SNL 8 98' VNEL BP 6cploration (Alaska) TRf~ = 4-1/76" d1M320N WELLHEAC= ACTUATOR= GRAY BAKER KB.ELEV = _- -87 77 BF. ELEV = - - - 51.65' KOP = - 3200' Max Angle = 100 ~ 14472' Datum MD = 10577' Datum ND = 8800' SS ~ Y-09AL 1 & Y-09AL ~01 Proposed CTD Laterals 113-3/8° CSG, 72/, L-80, D = 12.347" l~ Minimum ID = 2.31" ~ 10457 2-7/8" NIPPLE REDUCER ~ 4-12" HES HXO SSSV NP, D = 3.813` I GAS LIFT MANDRELS ST MD ND OEV TYPE VLV LATCH PORT DOTE 6 2996 2996 6 KBL-2LS DOME IVT 16 04/05!07 5329 4971 46 KBL-2LS DOME tNT 16 04/05/07 4 7120 6222 43 KBL-ZLS DOME M 18 04/05/07 3 8550 7361 29 KBL-2LS OOME tVT 16 04/05/07 2 9239 7975 29 KBL-2LS SO YJT 22 04/05/07 1 10254 8863 48 KBL-2LS "OMY 9JT 0 03!03107 °J I iF7 111°15 I lJCi YA 17:11 A(:FiU03 UN T 9-310" MLLOIlT MVPOOVV (Y-09A) 9202' - 9218' 518" X 7" BKR ZXP R(R w / TIEBACK, D = 6.375" 9030' 9-5/B" X 7" BKR I-MC LNR HGR D = 6.250" 9043' 10240'-10275' a-712" KB sTRADOLE PATCH, D = 2 to be pulled and re-run 10402' 4-i2" HES X NP, D= 3.813" Y-09 10413' 7" X 4-72" BKR S-3 RCR D = 3.875" 10436' 4-12" HES X NP, D = 3.813" 10457' 4-12" HES XN NP, D = 3.725" 10457' 2-7/B" NP REDUCER D = 2.313" (03/04p 4-12" T13G, 12.6/, L-80, .0752 bpf, D= 3.958" 10469' to be pui~ed and rerun 10469' 4-1/2" WLEG, D = 3.958" X 5-112" BKR ZXP PKR W/ TRACK, D = 5.250" 10479' 10473' ELMD TT LOGGED 07/28!97 5-112" LNR, 1717, L-80, .0232 bpf, D = 4.892" 10500' 10500' ~---r-1/2" X 4-112" XO, D= 3.956" 7" LNR 297, L-80, BTC, 0.371 bpf, D = 6.184" 1064$' 14,420' Top of Slotted Liner PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 91 ~ 110317 Note: Rekr to Production DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE SEE PAGE 2 FOR PERF BREAKDOWN I monobore w hipstock, retrieved 12.6#, L-80, .0152 bpf, D = 3.953" 4,500' Top of OH Deployment sleeve/whipstock ~~\ -- -- -' -- --1 -09AL1 ~~ ~ - - ~~~ ~ ~~~ 2-718" sbtted finer 16015' ~~ ~ ~~ ~ \~ ~ ~~ ~ ~~ Y-09A L1-01 DATE REV BY COAINBJTS DOTE REV 8Y CONNB~fTS 07!04!81 ORIGINAL COMPLETION 03104!07 DRFITLH GLV GO (1/30/07) 07Hli197 CHH SIDETRACK COMPLETKN 03/06!07 JLJ/TLH GLV GO 07104/01 CWKAK CORRECTK)rt5 0323/07 RRD'RH 4-112" STRADDLE PATCH SET 05!14/02 JAFffLH ADD PEftFS 04/07/07 CJN/R4G GLV GO 8 PULL RUG (04/05/07) 07!04!06 DTR/FI4G GLV GO (06/29106) 09!24/07 RCTIPJC MIN D CTtON 10101106 WTS/FI4 GLV GO 04/30/08 MSE PROPOSED CTD LATf3L4LS PRlAF10E BAY UNT WELL: Y-09A L1 8 L1-01 PHtMIT No: AR No: 50-029-20579-01 SBC 33, T11 N, R/3E, 1387' SNL & 98' Wit ~ Exploration (Alaska) by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P INTEQ r --- Company: -- BP Amoco - - Date: 6/13/2008 Time: 16:55:41 page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well : Y-09, True North Site: PB Y Pad Vertical (TVD) Reference: 13: 09 5/30/1 997 00:00 88.2 Well: ~ell ath Y-09 1 Plan 3 Y~9A13 ~- - ~~ Section (VS) Reference: Welf (O.OON,O.OOE,150.OOAzi) p : , 1 Su rvey Calculation Meth od: Mini mum Curv ature Db: O racle Annotation _ MD TVD _ _ _- - ft ft 14377.26 9045.15 TIP 14400.00 9042.60 KOP 14420.00 9040.11 End of 9 deg / 100 ft DLS 14470.00 9034.01 4 14500.00 9032.08 End of 40 deg / 1.00 ft DLS 14600.00 9030.98 6 14690.00 9030.01 7 14870.00 9028.14 8 15120.00 9042.32 9 15283.23 9052.28 10 15433.23 9044.29 11 15583.23 9029.10 12 15703.23 9022.91 13 16015.00 0.00 TD Plan Section Information MD Incl Azim TVD +N/-S +F/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 14377.26 95.75 195.83 9045.15 -8241.51 17.41 0.00 0.00 0.00 0.00 14400.00 97.15 197.88 9042.60 -8263.13 10.86 10.87 6.16 9.01 55.39 14420.00 97.15 196.07 9040.11 -8282.11 5.07 9.00 -0.02 -9.07 270.00 14470.00 96.71 175.92 9034.01 -8331.21 -0.09 40.00 -0.87 -40.29 270.00 14500.00 90.64 165.55 9032.08 -8360.70 4.73 40.00 -20.26 -34.58 240.00 14600.00 90.62. 153.55 9030.98 -8454.22 39.61 12.00 -0.01 -12.00 270.00 14690.00 90.61 164.35 9030.01 -8538.09 71.89 12.00 -0.01 12.00 90.00 14870.00 90.57 142.75 9028.14 -8698.28 151.59 12.00 -0.02 -12.00 270.00 15120.00 83.06 171.86 9042.32 -8925.83 247.02 12.00 -3.00 11.65 105.00 15283.23 90.00 153.50 9052.28 -9080.57 295.38 12.00 4.25 -11.25 290.00 15433.23 96.07 136.52 9044.29 -9202.81 380.87 12.00 4.04 -11.32 290.00 15583.23 95.46 154.60 9029.10 -9325.38 464.91 12.00 -0.40 12.05 91.00 15703.23 90.43 168.12 9022.91 -9438.64 503.09 12.00 -4.19 11.26 110.00 16015.00 89.73 130.71 9022.45 -9702.29 658.93 12.00 -0.22 -12.00 269.00 Survey - - MD Incl Atim SSTVD N/S - E/W - MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 14377.26 95.75 195.83 8956.95 -8241.51 17.41 5940628.91 644893.59 0.00 7146.06 0.00 MW D 14400.00 97.15 197.88 8954.40 -8263.13 10.86 5940607.16 644887.46 10.87 7161.51 55.39 MW D 14420.00 97.15 196.07 8951.91 -8282.11 5.07 5940588.08 644882.03 9.00 7175.05 270.00 MW D 14430.00 97.13 192.03 8950.66 -8291.73 2.66 5940578.41 644879.81 40.00 7182.18 270.00 MW D 14440.00 97.08 188.00 8949.43 -8301.50 0.93 5940568.61 644878.27 40.00 7189.78 269.50 MW D 14450.00 96.99 183.97 8948.20 -8311.37 -0.10 5940558.72 644877.43 40.00 7197.81 269.00 MW D 14460.00 96.87 179.95 8947.00 -8321.29 -0.44 5940548.80 644877.28 40.00 7206.23 268.51 MW D 14470.00 96.71 175.92 8945.81 -8331.21 -0.09 5940538.89 644877.83 40.00 7215.00 268.02 MW D 14480.00 94.70 172.45 8944.82 -8341.11 0.92 5940529.01 644879.02 40.00 7224.07 240.00 MW D 14490.00 92.67 168.99 8944.17 -8350.95 2.53 5940519.20 644880.82 40.00 7233.40 239.65 MWD 14500.00 90.64 165.55 8943.88 -8360.70 4.73 5940509.50 644883.21 40.00 7242.95 239.43 MW D 14525.00 90.64 162.55 8943.61 -8384.74 11.60 5940485.60 644890.54 12.00 7267.20 270..00 MW D 14550.00 90.63 159.55 8943.33 -8408.38 19.72 5940462.12 644899.11 12.00 7291.73 269.97 MW D 14575.00 90.63 156.55 8943.06 -8431.56 29.07 5940439.13 644908.90 12.00 7316.48 269.93 MW D 14600.00 90.62 153.55 8942.78 -8454.22 39.61 5940416.67 644919.88 12.00 7341.38 269.90 MW D 14625.00 90.62 156.55 8942.51 -8476.88 50.16 5940394.22 644930.86 12.00 7366.28 90.00 MW D 14650.00 90.62 159.55 8942.24 -8500.07 59.50 5940371.22 644940.64 12.00 7391.02 90.03 MW D 14675.00 90.61 162.55 8941.97 -8523.71 67.62 5940347.74 644949.21 12.00 7415.56 90.07 MWD 14690.00 90.61 164.35 8941.81 -8538.09 71.89 5940333.45 644953.76 12.00 7430.14 90.10 MW D 14700.00 90.61 163.15 8941.70 -8547.69 74.69 5940323.91 644956.74 12.00 7439.86 270.00 MW D 14725.00 90.61 160.15 8941.44 -8571.41 82.56 5940300.34 644965.07 12.00 7464.34 269.99 MW D 14750.00 90.61 157.15 8941.17 -8594.69. 91.66 5940277.24 644974.61 12.00 7489.05 269.96 MW D by ~ BP Alaska Baker Hu es INTEQ Plannin Report l~ g INTEQ Company: BP AmoCO Date: 6/13/2008 Time: 16:55:41 Page: 3 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: Y-09, True North Site: PB Y Pad Vertical (TVD) Reference: 13:09 5/30/1997 00:00 88. 2 Well: Y-09 Wellpath: Plan 3, Y-09AL1k" O L Section Surrey (VS) Reference: Well (O.OON,O.OOE,150.OOAzi) Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Aim S5 TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 14775.00 90.60 154.15 8940.91 -8617.46 101.97 5940254.67 644985.36 12.00 7513.92 269.92 MWD 14800.00 90.60 151.15 8940.65 -8639.66 113.45 5940232.70 644997.26 12.00 7538.89 269.89 MW D 14825.00 90.59 148.15 8940.39 -8661.23 126.08 5940211.38 645010.31 12.00 7563.89 269.86 MW D 14850.00 90.58 145.15 8940.14 -8682.11 139.83 5940190.77 645024.45 12.00 7588.84 269.83 MW D 14870.00 90.57 142.75 8939.94 -8698.28 151.59 5940174.83 645036.52 12.00 7608.73 269.80 MW D 14875.00 90.41 143.33 8939.89 -8702.27 154.60 5940170.90 645039.61 12.00 7613.69 105.00 MW D 14900.00 89.64 146.22 8939.88 -8722.69 169.02 5940150.76 645054.41 12.00 7638.58 105.00 MW D 14925.00 88.86 149.12 8940.21 -8743.81 182.39 5940129.90 645068.18 12.00 7663.56 105.01 MW D 14950.00 88.09 152.02 8940.88 -8765.58 194.66 5940108.38 645080.87 12.00 7688.55 104.97 MW D 14975.00 87.32 154.92 8941.88 -8787.93 205.82 5940086.25 645092.46 12.00 7713.48 104.89 MW D 15000.00 86.56 157.83 8943.21 -8810.80 215.82 5940063.58 645102.90 12.00 7738.28 104.77 MW D 15025.00 85.81 160.74 8944.88 -8834.13 224.64 5940040.42 645112.16 12.00 7762.90 104.62 MW D 15050.00 85.06 163.66 8946.87 -8857.85 232.26 5940016.85 645120.24 12.00 7787.25 104.43 MW D 15075.00 84.33 166.58 8949.18 -8881.91 238.65 5939992.93 645127.09 12.00 7811.28 104.19 MW D 15100.00 83.62 169.51 8951.80 -8906.23 243.80 5939968.71 645132.71 12.00 7834.92 103.92 MW D 15120.00 83.06 171.86 8954.12 -8925.83 247.02 5939949.18 645136.30 12.00 7853.50 103.62 MW D 15125.00 83.27 171.29 8954.72 -8930.74 247.75 5939944.28 645137.12 12.00 7858.12 290.00 MW D 15150.00 84.30 168.46 8957.42 -8955.20 252.12 5939919.91 645141.96 12.00 7881.49 290.07 MW D 15175.00 85.35 165.64 8959.68 -8979.46 257.69 5939895.76 645148.00 12.00 7905.29 290.37 MW D 15200.00 86.42 162.83 8961.47 -9003.46 264.47 5939871.90 645155.24 12.00 7929.46 290.63 MW D 15225.00 87.49 160.02 8962.80 -9027.12 272.42 5939848.40 645163.64 12.00 7953.93 290.83 MW D 15250.00 88.56 157.22 8963.66 -9050.38 281.53 5939825.32 645173.20 12.00 7978.63 290.98 MW D 15275.00 89.64 154.42 8964.05 -9073.18 291.77 5939802.72 645183.87 12.00 8003.49 291.08 MW D 15283.23 90.00 153.50 8964.08 -9080.57 295.38 5939795.40 645187.62 12.00 8011.70 291.12 MW D 15300.00 90.69 151.61 8963.98 -9095.46 303.11 5939780.67 645195.64 12.00 8028.45 290.00 MW D 15325.00 91.71 148.79 8963.45 -9117.14 315.53 5939759.23 645208.47 12.00 8053.44 289.99 MW D 15350.00 92.73 145.96 8962.48 -9138.18 329.00 5939738.46 645222.34 12.00 8078.40 289.93 MW D 15375.00 93.75 143.13 8961.07 -9158.51 343.48 5939718.41 645237.20 12.00 8103.24 289.82 MW D 15400.00 94.75 140.30 8959.22 -9178.08 358.92 5939699.14 645253.02 12.00 8127.91 289.66 MW D 15425.00 95.74 137.46 8956.93 -9196.83 375.29 5939680.71 645269.75 12.00 8152.33 289.45 MW D 15433.23 96.07 136.52 8956.09 -9202.81 380.87 5939674.84 645275.44 12.00 8160.31 289.19 MW D 15450.00 96.03 138.54 8954.32 -9215.12 392.14 5939662.75 645286.94 12.00 8176.59 91.00 MW D 15475.00 95.96 141.56 8951.71 -9234.17 408.10 5939644.01 645303.26 12.00 8201.08 91.21 MW D 15500.00 95.87 144.57 8949.13 -9254.05 423.04 5939624.42 645318.58 12.00 8225.76 91.53 MW D 15525.00 95.76 147.59 8946.60 -9274.68 436.92 5939604.06 645332.85 12.00 8250.57 91.84 MW D 15550.00 95.64 150.60 8944.11 -9296.03 449.69 5939582.97 645346.04 12.00 8275.44 92.14 MWD 15575.00 95.51 153.61 8941.68 -9318.01 461.33 5939561.21 645358.10 12.00 8300.30 92.44 MW D 15583.23 95.46 154.60 8940.90 -9325.38 464.91 5939553.92 645361.81 12.00 8308.47 92.74 MW D 15600.00 94.77 156.50 8939.40 -9340.59 471.83 5939538.85 645369.02 12.00 8325.10 110.00 MWD 15625.00 93.73 159.32 8937.55 -9363.69 481.20 5939515.93 645378.83 12.00 8349.79 110.17 MW D 15650.00 92.68 162.14 8936.15 -9387.25 489.44 5939492.54 645387.52 12.00 8374.31 110.38 MW D 15675.00 91.63 164.95 8935.21 -9411.20 496.51 5939468.72 645395.06 12.00 8398.60 110.54 MW D 15700.00 90.57 167.75 8934.73 -9435.49 502.41 5939444.56 645401.42 12.00 8422.58 110.64 MW D 15703.23 90.43 168.12 8934.71 -9438.64 503.09 5939441.42 645402.16 12.00 8425.65 110.70 MW D 15725.00 90.38 165.50 8934.55 -9459.84 508.06 5939420.32 645407.53 12.00 8446.49 269.00 MW D 15750.00 90.33 162.50 8934.40 -9483.87 514.94 5939396.43 645414.88 12.00 8470.74 268.98 MW D 15775.00 90.27 159.50 8934.26 -9507.50 523.08 5939372.96 645423.47 12.00 8495.28 268.96 MW D 15800.00 90.22 156.50 8934.16 -9530.68 532.44 5939349.97 645433.27 12.00 8520.03 268.95 MW D 15825.00 90.16 153.50 8934.07 -9553.34 543.01 5939327.52 645444.27 12.00 8544.94 268.93 MW D 15850.00 90.11 150.51 8934.01 -9575.41 554.74 5939305.68 645456.42 12.00 8569.92 268.92 MW D 15875.00 90.05 147.51 8933.98 -9596.84 567.61 5939284.50 645469.71 12.00 8594.91 268.92 MW D 15900.00 89.99 144.51 8933.97 -9617.56 581.59 5939264.05 645484.08 12.00 8619.85 268.91 MW D 15925.00 89.94 141.51 8933.99 -9637.53 596.63 5939244.38 645499.50 12.00 8644.66 268.91 MW D by ~ BP Alaska Baker Hu hes INTEQ Ptannin Report g g INTEQ Company: BP Amoco Date: 6/13/2008 Time: 16:55:41 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-09, True North Site: PB Y Pad Vertical ('I'VD) Reference: 13:09 5!30/1997 00:00 88. 2 Weli: Y-09 Section (VS) Reference: Well (O.OON,O.OOE,150.OOAzi) Wellpath: Plan 3, Y-09AL~ • Off, Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 15950.00 89.88 138.51 8934.03 -9656.68 612.69 5939225.54 645515.93 12.00 8669.28 268.91 MWD 15975.00 89.82 135.51 8934.09 -9674.96 629.74 5939207.59 645533.32 12.00 8693.63 268.92 MW D 16000.00 89.77 132.51 8934.18 -9692.33 647.72 5939190.58 645551.63 12.00 8717.66 268.93 MW D 16015.00 89.73 130.71 8934.25 -9702.29 658.93 5939180.84 645563.03 12.00 8731.89 268.94 MW D LEGEND ••~n•~anmrnn ~.v x BP Alaska ~/.i _ Y-R9 (Plan 2,Y-09ALi) ro ~Nax aP - p~~~y~` ~~ EE//~~a - v-os (v-o9) BMEAiR Y-09 (Y-09A) ~r io t~„aNmn .....~ -. - - ,r~..TK _ ~,~~ by V-09 (Y-09AP0 1) asi e Plan 3, Y-99AL2 ~ ~ 5"x` Plan 3 og~ ~: m~ ,uv~ i, ~„ „ ~zo=~°~ ~-°~ 1NTEQ ~x ~~,~1~-Ta5>o atl. Mtu~n. ta: 0p ma0n00]00:00 N30n v. M`al: o.`iB~i °."r~-w s`~"rPio tN.ao• o.oe eoo ae zo .x , 1 .. -:. REFERENCE NFORMAi NN eool j hY ~ ~( ~~ 1 T CooN nale ``NIEI R9erence W YJ19, Trve NOnN .moo- ~ ~ - - ~ - VMra (iV0(Reference Sys M Sea Lerel -i r , 1 -~ 4 '- SstOn(VSIRalerara 5 09(000 OOOE) ~ it ~ ~ I I r } r I y i -T `~ Me~uree Depm Relerentct 095w 1931 WW ee 7o `t End of9tl I700R DL - ' i i ,7'"' cawai oa Me nm M wre ~, - ~~ TIP 0 .. ..... ~. F _'f_ ~ ~ Y t - ~ -_ KOP - '- ~ Y•09AL3 Pol on ~ } - ~ ~ - t }' Entl o/ 40 tl / 700 K DL - - - _. _,~' t ~ (• ~~~ a~ Tr.. rqr a' Y-09 Plan 2 r-09AL1 r J t r J ' r-0eALZ n .t a _ i t~ 1 ~ i ~` 1 ~w m- Ti 1T 1 1_ I r.09AL2 Tar at] ~...tl { T~ r _i ~ -- ~ f ~ ~j _ •nnorAr a.a s vo as .•••r•m• Nam a ma° 77 1-i 1 ~ ~ _ I f r [ J it uxu,aaoo.oo nor rasa, feutt AAA •t0w0~toon0u ry~0on ~ ~ i-y ~~ i i ~ ~ I T - t ~~ N0, 91,Y10.00 0na v~osut Feunn ~ ' 00av01,Y]a0a a ya9NL1 *arye ] - NuN,aem.oo wrmr.~,mnou va9usr.meii ~ ~~ 73 - ~ 1 y ~,LZ ~ amsoo 9o az, ~9ax Po•, !-~ ~ ~ ~ - - - ~ . ~ T '~,~ ~; , ~ ~ a , . l _ ~ ~ _ ' r-09ALR Ta at 3 { Plan ] r-09AL2 f = 7 t i~ T[ L ~ _ r fill I f i': + J 1 JI ...a...aNaaa ,. ...N.NtaN m { ~ ( {- T+ } ~ + i : ~ _ Ti Fi-- i ' ~- - ~+ tl _ ~ I r t j ' I t 1 i• g t~ r 1 j i ~ [} _,~ ~i~ r~ r r1{~ r~r},-.}~II~ ~~i ~F~ --~ (~~ f ~.~{~,I~r-i+a;.~l '. ema ; - `_ ti I r ' ~ I ._ i Its r ~ .. ~ ~ F. + } ~~ J 1 _ Na 7 I rr t ~ Y. I I t F ( 1 a } I~1 t {-; } ~ 1 I 1 ~ -~ I } '_, r rt 1 t ,aam ' r I~ ~} ± ~: ; ~ r r ~ +k ~ 1 I t ~ : ~ ~ t~ i ~t y~ j I 1 t I~ ~~ I ~ .. _ ' I - ~. } 1 ~' ~ ~ ~ i _ ~~ T I~ ~.~, itrt} J-r ~ l .i - LTIr ~ t ~ i' ~- t 1 ~ I ' ~ ~: „_ I ( I t ~ C:~ }iCi ~ ~ _ t ] i 1:r~i I I i ~~r a~: ~t i ~ ~ ~ 1 i ! ~ ~ -r ~ I { } . ~. t + I ... ( t~ I i ( i r`:~ ~ IT, .._I . ~ [ ~l I I-{ i1 (~ } ~ ~ }.r! ~1 }+I -'' l i Fa } }-~, ~~ ~ ~} , } - r 1 ~,~ a,m ,am ,am ,.m ,:m ,mo .m .m m a mo Fm mo ~ ,sm :ma nm ` - ~ i 1 - I } ~ ~ weaq-NEaay+~ ~zoowm;I "~^ ! 1. } ~ (~ }1 j~ 1 - ~r tl ~1( ~~1,.~ i (Ir' }}j jl~ i ' L'_r~ I / 1 -~}},i i as ~~~I I ~ I ~ } f- F a-:. i i~.{ } 4 r-{ ~~i I~T~I~ ":il ~.._~_. '.. r-aow..zravua ~{--f~~~~+}+~-E+{7~ t~• ~,~{f I ~.:I~ it---itr ~.._. 1+1 ~-+~F }}}i:- .~ _ I TII KOP I t { ~ { ~T eeo0 I,. - - Y-00 YO9APB 1 _ _.~. , .._ .. Y-09 Y-09A I nn ~I I ' ,~ I 'I ~ ~ \, I 11 QQ Q° I Q / to „ az u - - {._ i tF }- - i ~ r_ +F t"- - ~ -1---' /'(E- - - - - Plaa a roeALZ ~ i 1 L 1 t a - ~ -- -- ~ #'-- i ' G I I 1 • 1 ~ ~ i- ~ 1 It t `~ `~ : ~ r ~~ k i±- . entlwea nooa DL 1 ~ -~i +- h• r 1 - -_ I I ~1 ~ roeAU r. a z Y-0eALZ Ta. x a ~ -+ 1} -. ~r: ~ ~, ' I I I f Exw w.o tl.e / too n o`~ YosAtz T. .t ~ !_ } 1 1.1 J ~ 1 ~ t a ~ , T" . __ i ~ r +f j ~ ~ --~ C t I i ~ ~ - r ~ T +~ i I ~ f + I_. _ 14 ~ ' -~ I i lT?- I r -~'- :. roe roe ,- -{- _ I '.. ~ I - ~ _ .- __ . { ~ -I 1 ~ I:- - i - - t- { 1 --r r woo iwo rvo~ <•..~ ,.w .<~. ram +ao uw .,x~u spa eauu saa. cwo e.a s•'~ 6q' sw~,, Vertful5eetlon al a50.00'[300fLin] o nxuv won es,u enun wm v.oo r..n- wog rma .oovo ~a.a ~nmo i~Noo ca.. ~ooo ~~xa iwx • T Plan: PWn 3 (V-09/Plan 3, V-09AL2) - ~r~z~r~,l rig BP Alaska = %~~ ~= M AzmutM to Teue NOM Created By BP Dara &1112000 eft Ma0rwtic Nalh. 33.13° Checked' D'ale'. ,~~..TNO~r~ e~.n B~c~e by ~, I~F~e - Str ~:5~667nT t,1 - (~ 1 08 9~ eo ee• a ,u,. nrr m SOOtYMa>B68 :8/1012008 a B M av son ~ •~~ NTEQ Motley. Gggn3007 T~ ~.~: ~, ~.: ::::. +i: tii yw+an eo:oo u.aon M.~ ,as.oa• o.w a.m aa.:o REFERENCE INFORMATION Coordinate((NIE) Reference: Well Centre: Y-o9, True North Vertical T D Reference: 13:09 513017 997 00:0088.20 Section (VS) Reference: Slat - 09 (O.OON,O.OOE) Measured Depth Reference'. 13:0951301199700:00 88.20 Calculation Method: Minimum Curvature t ' I I_ ~ ~ I , . I.if 1 ~ ~~,~_ ~ I II , : r r I ~~ I'~~ ~ ~ I'-::. 1 a..-i.. { ,I I 1~:.1 _ ~ I..- ~f i:~ I~-f_ r ' Fi fZt ti i-{~ ~ rl- ~ {t4# ~ t' ; ,' T~~C }I j 7 I I ~ t _ + - I I I i ~- + -~- - 1 1 I I -, • r { ~- - ! 1_ I- t (( r ~f•: ' I ~• ; F ~ x r~ 1 { Gi T G i -- f '-1-.-} Y--- - I - ~ t-. f r.' i 1 _ h- ~7 : L t i_ I ~T ~-Y I f 1 ~ i, l~ r I i ~ Y i t. ~. ~r~ ~~...- ~ t~ ~ -} r ...., .. ,... :.". .. " r { ~..{:~I r C f 1-t~` I7 { -I-i I ~ + Tr T r-i r ~- rl tt t { r~{ h tt + + r- I I -82 ~ r I t -~ ~~ .-. ~. ,. ~.. I _. ...... :.-.. ~ f r-.t I-. ~ 1 r ~t t tT r~ ri FI-- F ~ ~ ~ ~ .I I t _~ t+` 1 L. I I J^ i_r I~{ i '. Tu -t-k 1~ i.~: + I i(i { {'._ ;1 ~ } _ : .. t 7 +Irl rt I Ili 17 ~~t ~~11 { , - ~ f ~ j r t ~ ~ {-- 1} 'i r4t9 r-osw . - : I ~ i _f.: t F *;11 ;-F1t ~a { -~' I { a { j-1 { . ^ I ! t ~ :~ !~ .. ~ t , ~., ~ ~ I r 1-_~ 1. + i ~ 'T 1 I ~ - l.Lj :!_1 ;1 { - y 1 , ,-T ~ -} C t Y 1..._ trt_..i ~r il'-~ r-~~. _:..I_, I fl .$ }. .. ~~ y--r, L1 r~i-+ ~~n t-I 1~1 t _;{ t~ 1 I ~ ~ Ii j. I,: 9000 -^ N ` r I' I ~ ! ~ 1 z t~-r r ., +'-i-r~ - T - t ~ ~I 1 ~'~ i~ t i r 1 r 1 T I. i 1 -r { r~ r -1 1 ~~ ?# { - ^ -920 ' Ir <- r fail ~ ~ r t 1 r ~ ~~1 i1 I ~~ t;1 ; + ~ '~ ~ F ~ t f1 ~-}:I 1 ' {~ +x~ G -940 ~~~ i T- ?- f t f._ f ~ '- r~ I_ 1 ~ t~ I I ~ ~ T _ ~;~ rrT ~~ r r-1 I~ ~r.t -I ~-t- ~ r ~_i ~~j - i ,} -~ r -~ai t I fi f ~ 'I ~ ~FI : r r. I~ { ,, tI r ~ ~ f { # 1 -9fi 1- t t+ t t ~ ~ ~ r ~ ' ~ r-. I I ,. t (. 4 I ~ I ~ G t - - vt.n s rAaw~2. C' ... { ~- r I I Tf i I ; , _ I ~ I ~ ~~ 11 r r rr+ 111 ~. I ~~ i ~ ~. _ ~ ~~..1 ~ II-~ i~ _ {:~i I ~:: ~~ If j I ( j..L ~~ -~{ ,~{f r_il~ ~xy ~ taooD - -_ - I ~ l r t { ~ ~ rt r F • j ; -.. ~ }T ~ 1 _ .. _ _ I i I 1 ,:. _ : _ ~ N- j I + ~ _ _ ~ - ' 1-1 ~~-r, ::., r i ~~ _~ { ~ ~ - - I r I t I I I -1 o2aD I ` + T I~ 1 - 4 t - 1. + ~~ I. I r l - t ;~ rl -r t r { I~ I I r - I- ~I~ ~ - _~ ti r --r ~l I~,-~r r I I:: 11- ~r~ _:- rl I t I .._I- 'li III ~' t .I! f.~. t /III ~'f rl Ii ~ r~l I_~ i i I~ i ~ - t 1 ~' ~,- ~ }~ '- 1 r ~ ~ } t ~ ,- 1 - r` ~r I -i 1 ~ 1-r -~ ~ 1 ----f + t ~ t -toaoo t - rt t t t t I fl r I i i ~ I r~-- r r i-_ {_ _ 7 i~ r •~_- ~,..i }I 7 + ~ ~ ~f I -I I ~~I - ~ r ~1 : ~ _t _ __ ~ :_ ~~ t I l 1 ~1 ~ ~ r ~ i-r ~._r tt .~ t I I ICI t (: I7 j ~ , j i ~ ' y r ~ 11 1}~~ t f_ 1 I ~ { ~. I ._- ' f ~ I - tri II I 11- li riy rFr 1 _ ~ + -10000 - - ~ ~; ~ _ Yi T i i ` ~} .. ff tt I ~ 'rt ~I -1~~ ~~ ~ - } t YI-r I. is {r 1 L L 1J ! I { }+ t t ~ ~i l I+, r, ' 1i .r (I r . i a tn6D --r-rTrr- -~ n-r-_ .,rte, . r'r-r-ny-r • 1TI~-i7~ -1-~ r. ' ~ r ~ ~ I r r r I i ~ r I r ; ~ i-~ - r ~, ~ - ~ I ~.. - - - - -r-r r. - I r.- ~-IT r_ r -r~r~-~ - - -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 E00 roo -zoo ri 200 400 fi00 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3D00 320D 3400 3600 3800 4000 4200 4400 West(-)/East(+) (200ft/in] i • WELL DETAILS Name ~NI-S -F%-W NoMing EuUvg Latituk Longitude Slol Y-W 385.90 -1024:!1 594tl86].93 644]1].]6 ]0'16'U3.83UN 14tl'49'41018W U9 ANTI-COLLISION SETTINGS rur.~A.~ ntuu.% Inlcrpolation MethodMD Interval: 25.U0 ` "'"` Depth Range From: 14377.2fi To: 16015.00 % Maxtmlm3 Range: 1797.58 Reference: Plan: Plan 3 w.m~n,.~.n.wL Xw„ x...a SURVEY PROGRAM Depth Fm 0.rylh To Survey/Plan 193]].]6 I W IS W Plmmed: Plm l V? WELLPATII DETAILS' TWI Plan 3, Y-WALL 5110292U5]Y61 MWD cvt WeIIpaN: Y419A m Tic an MD: 141]].26 Rig: NuNi< 1 Ref Datum: Il : W SI30/19Y] W:W 8R2Ufl V.Seetion Origin Origin Stvtivg Angle ~N/-S +FJ-W t'rom TVD IlS.W° OW U.W 19.20 LEGEND - Y-09 (Plan 2, Y-09ALI), Major Risk - Y-09 (Y-09A), Major Risk - Plan 3, Y-09AL2 - Plan 3 by r~ iNTE~ sECnoN Dr.Tnas See MU Ire: Aei TVU ~N1-S Ik%-W OLeg T4aec VSev TalXer I lil]126 9>]5 I95.b3 YIN5.15 ~tl?41.51 1].41 UW U.W 5%19.H3 144(M1.U11 Y).IS 19].%% HU42W IU.%fi III.%] 5519 5%SUSH 134?U 011 Y).15 IWr.U1 UMI.II %?.II SU] 4.W ?]U.W 5%SH.H2 144]U011 46.]1 1]5.9? W.i401 ~N331 ~I U.W NI.W 2]UW 5%911.99 5 145W (M) W 165.55 W32.UK W.)U 4.]J IO.Iq 2411.1X1 591<26 146W.IN1 Y11.62 IS1.55 WJO9% -%45422 1961 I2.W 2]0.1X1 lNMI6.05 196HU.IK1 H0.61 164.35 WJ11.01 -tl53%.W )I N9 I?W H11.W bU%X.I) 14%]01X1 911.5] 14?.]5 W2b.14 ~%lNb 2% 151 SH 1.W 2]aW 6?5161 9 151?O.W %l W 1]I.tl6 904? i? -%925.63 241 U2 12 W IUS W 6466.]6 U IS?%J2l 911.1X1 153.511 91152 ~b -9U%0.5] SHi,3b 1?_W 2HUW 6629.60 154)3.'!3 96 U] 36.5? H04429 ~9211_bl 3%U.%1 1.W 2HOW 6]]6.69 2 15563.23 9<46 154.60 H02H.10 91251% 464 H1 121X1 91 W 69?2.]% I3 IS)U3.23 Wl.9i Ibg l2 H43%.64 503.09 121X1 IU.W ]029 K] 14 IWI~W XY.)1 13a]I 9U??.45 -Y]U2.29 b5tl 93 I-W 26Y 00 ]12fi 49 • by ! BP Alaska Anticollision Re ort P °A. 1NTEQ Company: BP Amoco Date: 6!11/2008 Time: 15:26:56 Page: i Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-09, True North Reference WeII: Reference Wellpath: Y-09 Plan 3, Y-09A L2 Vertical (TVD) Reference: 13:09 5!30/1997 00:00 88.2 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'lT~eidi$e~ls in this fl2h71cipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSAEIIipse Depth Range: 14377.26 to 16015.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1797.58 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/1 0/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 101.20 9201.20 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 9202.00 11139.76 2 : MWD -Standard (9202.00-11 MWD MWD -Standard 11139.76 14377.26 3 : MWD -Standard (11139 .76-1 MWD MWD -Standard 14377.26 16015.00 Planned: Plan 3 V2 MWD MWD -Standard Casing Points MD I TVD Diameter Hole Size Name ft ft in in 16015.00 9022.45 2.875 4.125 2 7/8" Summary <-------------- -Offset Wellpath ------------------> Reference Offset Ctr-Ctr No-Go Allowable ~ Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB Y Pad Y-09 Plan 2, Y-09AL1 VO Pla 1 4631.54 14650.00 60.75 1088.99 -1028.25 FAIL: Major Risk PB Y Pad Y-09 Y-09A Vi 1 4469.27 14475.00 18.04 1157.15 -1139.11 FAIL: Major Risk Site: PB Y Pad Well: Y-09 Rule Assigned: Major Ris k Wellpath: Plan 2, Y-09AL1 VO Plan: Plan 2 V2 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable ', MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H SDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14400.00 9042.60 14400.00 9042.60 177.66 178.18 197.88 0.00 4.125 0.00 624.46 -624.46 FAIL 14425.00 9039.48 14425.00 9039.48 181.46 182.09 194.05 0.00 4.125 0.00 634.08 -634.08 FAIL 14450.00 9036.40 14450.00 9036.40 187.90 188.42 183.97 0.00 4.125 0.00 650.39 -650.39 FAIL 14475.00 9033.47 14475.00 9033.43 188.55 189.14 174.18 0.00 4.125 0.04 652.68 -652.64 FAIL 14499.93 9032.09 14500.00 9030.66 184.78 185.26 148.39 342.82 4.125 1.49 372.65 -371.16 FAIL 14524.78 9031.81 14525.00 9028.18 182.52 182.99 125.91 323.33 4.125 4.52 689.58 -685.06 FAIL 14549.39 9031.54 14550.00 9026.06 179.80 180.26 104.05 304.43 4.125 9.68 922.94 -913.26 FAIL 14573.53 9031.27 14575.00 9024.37 176.67 177.12 89.75 293.03 4.125 17.631008.27 -990.63 FAIL 14596.95 9031.02 14600.00 9023.16 173.20 173.65 79.95 286.04 4.125 28.441031.62 -1003.19 FAIL 14616.26 9030.81 14625.00 9022.46 175.29 175.77 76.79 281.29 4.125 42.631064.81 -1022.18 FAIL 14631.54 9030.64 14650.00 9022.30 177.54 178.04 75.23 277.89 4.125 60.751088.99 -1028.25 FAIL 14642.81 9030.52 14675.00 9022.67 179.09 179.59 74.19 275.50 4.125 81.901103.71 -1021.81 FAIL 14651.59 9030.42 14700.00 9023.21 180.26 180.73 73.70 273.96 4.125 104.451113.15 -1008.70 FAIL 14658.75 9030.35 14725.00 9023.74 181.10 181.62 73.56 272.96 4.125 127.721119.56 -991.84 FAIL 14664.44 9030.28 14750.00 9024.28 181.76 182.29 73.55 272.27 4.125 151.561124.24 -972.69 FAIL 14668.78 9030.24 14775.00 9024.81 182.27 182.79 73.57 271.77 4.125 175.821127.65 -951.82 FAIL 14671.90 9030.20 14800.00 9025.33 182.64 183.14 73.57 271.39 4.125 200.401130.02 -929.62 FAIL 14673.93 9030.18 14825.00 9025.85 182.88 183.36 73.52 271.10 4.125 225.21 1131.55 -906.34 FAIL 14674.96 9030.17 14850.00 9026.35 183.00 183.47 73.42 270.87 4.125 250.141132.34 -882.20 FAIL 14675.12 9030.17 14875.00 9026.85 183.02 183.48 73.24 270.69 4.125 275,121132.47 -857.35 FAIL 14675.57 9030.16 14900.00 9027.34 183.06 183.54 73.15 270.54 4.125 300.101132.83 -832.74 FAIL 14676.76 9030.15 14925.00 9027.84 183.18 183.66 73.17 270.41 4.125 325.001133.61. -808.61 FAIL 14678.64 9030.13 14950.00 9028.32 183.37 183.86 73.28 270.30 4.125 349.791134.80 -785.02 FAIL 14681.13 9030.11 14975.00 9028.81 183.63 184.12 73.48 270.20 4.125 374.391136.35 -761.97 FAIL 14684.18 9030.07 15000.00 9029.29 183.93 184.43 73.76 270.11 4.125 398.761138.23 -739.47 FAIL 14687.71 9030.03 15025.00 9029.77 184.29 184.78 74.11 270.04 4.125 422.871140.36 -717.49 FAIL by ~ BP Alaska Anticollision Re ort P °A INTEQ Company: BP Amoco Date: 6/11/2008 Time. 15:26:56 Page: 2 Field: Prudhoe Bay ' Reference Site: PB Y Pad Co-ordina te(NE) Refe rence: Well: Y-09, True Nort h Reference Well: Y-09 Vertical (TVD) Reference: 13:09 5!30/1997 00: 00 88.2 Reference Wellpath: Plan 3, Y-09AL2 Db: Oracle Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Plan 2, Y-09AL1 VO Plan: Plan 2 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Ands Ctr-Ctr No-Go Albwable 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 14715.54 9029.74 15050.00 9030.47 181.94 182.47 71.19 269.91 4..125 447.091126.39 -679.30 FAIL 14871.92 9028.12 15075.00 9031.51 156.55 156.92 52.56 269.59 4.125 469.75 973.56 -503.81 FAIL 14878.05 9028.07 15100.00 9032.89 157.88 158.27 53.12 269.44 4.125 491.60 981.58 -489.98 FAIL 14883.36 9028.05 15125.00 9034.60 159.00 159.42 53.57 269.27 4.125 514.14 988.37 -474.23 FAIL 14887.88 9028.04 15150.00 9036.63 159.95 160.38 53.90 269.08 4.125 537.28 994.08 -456.80 FAIL 14891.63 9028.05 15175.00 9038.98 160.75 161.18 54.14 268.88 4.125 560.92 998.77 -437.85 FAIL 14894.67 9028.06 15200.00 9041.64 161.39 161.81 54.28 268.67 4.125 584.951002.50 -417.55 FAIL 14897.58 9028.07 15225.00 9044.51 162.00 162.41 54.40 268.45 4.125 609.01 1006.03 -397.02 FAIL 14900.00 9028.08 15250.00 9047.49 162.52 162.91 54.47 268.24 4.125 632.751008.96 -376.20 FAIL 14904.66 9028.12 15275.00 9050.57 163.43 163.85 54.80 268.04 4.125 656.121014.33 -358.21 FAIL 14908.77 9028.16 15300.00 9053.73 164.23 164.67 55.08 267.84 4.125 679.091019.03 -339.93 FAIL 14912.98 9028.21 15325.00 9056.29 165.05 165.50 55.44 267.71 4.125 701.931023.84 -321.91 FAIL 14917.05 9028.27 15350.00 9057.54 165.85 166.29 55.89 267.69 4.125 724.901028.53 -303.63 FAIL 14921.04 9028.33 15375.00 9057.61 166.63 167.06 56.42 267.76 4.125 747.851033.16 -285.31 FAIL 14925.00 9028.41 15400.00 9057.14 167.40 167.81 56.99 267.86 4.125 770.41 1037.77 -267.36 FAIL 14929.77 9028.51 15425.00 9056.23 168.26 168.70 57.67 268.00 4.125 792.501043.03 -250.54 FAIL 14934.52 9028.62 15450.00 9054.87 169.10 169.57 58.38 268.15 4.125 814.071048.26 -234.19 FAIL 14939.38 9028.75 15475.00 9053.12 169.97 170.44 59.12 268.33 4.125 835.31 1053.57 -218.26 FAIL 14943.74 9028.88 15500.00 9051.19 170.75 171.21 59.80 268.51 4.125 857.171058.31 -201.14 FAIL 14950.00 9029.08 15525.00 9049.12 171.87 172.27 60.70 268.68 4.125 879.721064.90 -185.19 FAIL 14950.00 9029.08 15550.00 9046.92 171.87 172.31 60.89 268.87 4.125 902.821065.13 -162.31 FAIL 14950.00 9029.08 15575.00 9044.59 171.87 172.34 61.08 269.06 4.125 926.431065.32 -138.89 FAIL 14955.64 9029.27 15600.00 9042.13 172.79 173.25 61.90 269.22 4.125 950.421070.86 -120.45 FAIL 14957.31 9029.33 15625.00 9039.57 173.06 173.53 62.27 269.40 4.125 974.741072.58 -97.85 FAIL 14958.50 9029.38 15650.00 9036.89 173.25 173.73 62.58 269.57 4.125 999.291073.82 -74.53 FAIL 14959.23 9029.41 15675.00 9034.12 173.37 173.85 62.83 269.74 4.125 1024.001074.59 -50.58 FAIL Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Y-09A V1 Inter-Site Error: 0.00 ft Refe rence Offset Seroi-Major Axis Ctr-Ctr No-Go Allowable MD ~ TVD MD TVD Ref Offset TFO+A ZI TFO-HS Casing/HSDistance Area Deviation Warning ~ ft ft ft ft ft ft deg deg in ft ft ft 14400.00 9042.60 14400.00 9042.60 177.66 178.21 197.88 0.00 0.00 624.73 -624.73 FAIL 14424.92 9039.50 14425.00 9039.23 181.43 182.10 271.13 77.05 1.21 1086.32 - 1085.11 FAIL 14448.55 9036.58 14450.00 9035.54 187.63 188.26 266.10 81.54 7.131146.07 - 1138.94 FAIL 14469.27 9034.10 14475.00 9031.52 188.90 189.49 257.93 81.71 18.041157.15 - 1139,11 FAIL 14486.55 9032.56 14500.00 9027.54 187.30 187.93 251.38 81.20 32.871147.16 - 1114.28 FAIL 14500.48 9032.08 14525.00 9024.13 184.73 185.27 246.46 80.97 50.651130.30 - 1079.65 FAIL 14514.02 9031.93 14550.00 9021.28 183.50 184.09 245.17 81.30 70.461124.20 - 1053.73 FAIL 14525.10 9031.81 14575.00 9018.80 182.49 183.03 244.40 81.86 91.821119.69 - 1027.88 FAIL 14533.23 9031.72 14600.00 9017.05 181.59 182.16 244.21 82.65 114.721116.46 - 1001.73 FAIL 14538.57 9031.66 14625.00 9016.25 181.00 181.58 244.54 83.62 138.681115.05 -976.37 FAIL 14541.17 9031.63 14650.00 9016.02 180.71 181.28 245.12 84.52 163.321114.96 -951.64 FAIL 14541.85 9031.62 14675.00 9016.78 180.64 181.20 246.00 85.48 188.121115.95 -927.83 FAIL 14540.52 9031.64 14700.00 9018.48 180.78 181.36 247.14 86.46 212.801118.01 -905.21 FAIL 14538.53 9031.66 14725.00 9020.16 181.00 181.58 248.15 87.22 237.441120.03 -882.58 FAIL 14535.90 9031.69 14750.00 9021.13 181.29 181.88 248.93 87.69 262.031122.08 -860.05 FAIL 14532.32 9031.73 14775.00 9021.31 181.69 182.27 249.59 87.92 286.361124.53 -838.17 FAIL 14528.00 9031.77 14800.00 9021.57 182.17 182.73 250.30 88.12 310.331127.39 -817.06 FAIL 14523.36 9031.83 14825.00 9022.63 182.65 183.21 251.17 88.42 334.031130.36 -796.34 FAIL 14518.86 9031.88 14850.00 9024.68 183.06 183.65 252.13 88.85 357.661133.08 -775.42 FAIL -. "- by ~ BP Alaska ~ ~~'`~ Anticollision Re ort l~ iNTEQ Company: BP Amoco Date: 6/11!2008 1time: 15:26:56 Page: 3 Fietd: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-09, True Nort h Reference Well: Y-09 Vertical ('I'VD} Reference: 13:09 5/30!1997 00: 00 88.2 Reference Wellpath: -_ Plan 3, Y-09AL2 Db: Oracle Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Y-09A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD 'PVD MD TVD Ref Offset TFO+A ZI T'FO-AS Casing/HS!)istance Area Deviation Warning ft -- ft - ft ft ------ ft ft deg deg in ft ft - - ft 14514.62 9031.92 14875.00 9027.39 183.44 184.06 253.11 89.32 ~. , ~ 381.31 1135.56 _r ~ ._T -754.25 FAIL 14510.51 9031.97 14900.00 9030.20 183.82 184.44 254.04 89.75 404.981137.86 -732.88 FAIL 14506.58 9032.01 14925.00 9033.06 184.17 184.79 254.90 90.14 428.71 1139.96 -711.25 FAIL 14502.88 9032.05 14950.00 9035.59 184.51 185.11 255.65 90.45 452.561141.87 -689.31 FAIL 14500.00 9032.08 14975.00 9037.67 184.77 185.35 256.22 90.67 476.571143.31 -666.74 FAIL 14498.11 9032.11 15000.00 9039.18 185.16 185.79 257.01 90.81 500.741145.74 -645.00 FAIL 14496.63 9032.14 15025.00 9039.98 185.46 186.12 257.56 90.86 525.01 1147.61 -622.60 FAIL 14495.29 9032.18 15050.00 9040.09 185.74 186.41 257.99 90.83 549.361149.30 -599.94 FAIL 14494.03 9032.21 15075.00 9039.62 185.99 186.67 258.34 90.74 573.731150.88 -577.15 FAIL 14492.80 9032.26 15100.00 9038.88 186.25 186.91 258.66 90.64 598.081152.39 -554.30 FAIL 14490.00 9032.37 15125.00 9038.28 186.82 187.45 259.57 90.58 622.471155.71 -533.24 FAIL 14490.00 9032.37 15150.00 9037.81 186.82 187.44 259.49 90.49 647.001155.71 -508.71 FAIL 14490.00 9032.37 15175.00 9037.52 186.82 187.43 259.43 90.43 671.591155.69 -484.11 FAIL 14490.00 9032.37 15200.00. 9037.45 186.82 187.42 259.39 90.40 696.271155.67 -459.40 FAIL 14490.00 9032.37 15225.00 9037.48 186.82 187.41 259.36 90.37 721.01 1155.65 -434.65 FAIL 14487.60 9032.50 15250.00 9037.54 187.15 187.83 260.21 90.39 745.731157.91 -412.18 FAIL 14486.97 9032.53 15275.00 9037.72 187.24 187.93 260.42 90.39 770.491158.46 -387.97 FAIL 14486.42 9032.56 15300.00 9038.03 187.31 188.01 260.62 90.39 795.291158.94 -363.65 FAIL 14485.92 9032.59 15325.00 9038.48 187.38 188.09 260.81 90.41 820.121159.37 -339.25 FAIL 14485.47 9032.62 15350.00 9039.05 187.45 188.16 260.99 90.44 844.971159.74 -314.77 FAIL 14485.08 9032.65 15375.00 9039.74 187.50 188.21 261.16 90.47 869.851160.06 -290.20 FAIL 14484.73 9032.67 15400.00 9040.68 187.55 188.26 261.32 90.51 894.751160.33 -265.58 FAIL 14484.28 9032.70 15425.00 9041.68 187.61 188.32 261.53 90.56 919.581160.69 -241.11 FAIL 14483.83 9032.73 15450.00 9042.63 187.67 188.38 261.72 90.60 944.391161.04 -216.65 FAIL 14483.42 9032.76 15475.00 9043.36 187.73 188.44 261.89 90.63 969.241161.36 -192.13 FAIL 14483.06 9032.78 15500.00 9043.61 187.78 188.48 262.01 90.63 994.121161.65 -167.54 FAIL 14480.00 9033.02 15525.00 9043.61 188.20 188.89 263.14 90.69 1019.051164.12 -145.07 FAIL 14480.00 9033.02 15550.00 9043.08 188.20 188.89 263.09 90.64 1043.991164.14 -120.14 FAIL 14480.00 9033.02 15575.00 9042.14 188.20 188.89 263.02 90.57 1068.951164.16 -95.21 FAIL 14480.00 9033.02 15600.00 9041.16 188.20 188.89 262.96 90.51 1093.921164.19 -70.26 FAIL 14480.00 9033.02 15625.00 9040.23 188.20 188.89 262.90 90.46 1118.891164.21 -45.32 FAIL 14480.00 9033.02 15650.00 9039.35 188.20 188.90 262.85 90.41 1143.861164.24 -20.38 FAIL 14480.00 9033.02 15675.00 9038.48 188.20 188.90 262.81 90.36 1168.81 1164.26 4.55 Pass 14480.00 9033.02 15700.00 9037.61 188.20 188.91 262.77 90.32 1193.761164.29 29.47 Pass 14483.24 9032.77 15725.00 9036.74 187.75 188.46 261.51 90.19 1218.671161.64 57.03 Pass 14483.43 9032.76 15750.00 9035.89 187.73 188.43 261.40 90.14 1243.601161.50 82.11 Pass 1.4483.63 9032.74 15775.00 9035.11 187.70 188.41 261.30 90.11 1268.541161.35 107.19 Pass 14483.81 9032.73 15800.00 9034.44 187.67 188.38 261.20 90.08 1293.481161.20 132.28 Pass 14483.99 9032.72 15825.00 9033.89 187.65 188.36 261.12 90.05 1318.421161.06 157.36 Pass 14484.17 9032.71 15850.00 9033.47 187.63 188.34 261.04 90.03 1343.371160.92 182.45 Pass 14484.34 9032.69 15875.00 9033.19 187.60 188.31 260.97 90.02 1368.321160.79 207.54 Pass 14484.50 9032.68 15900.00 9033.08 187.58 188.29 260.91 90.02 1393.281160.65 232.62 Pass 14484.65 9032.67 15925.00 9033.13 187.56 188.27 260.86 90.02 1418.241160.53 257.71 Pass 14484.70 9032.67 15934.43 9033.19 187.55 188.26 260.84 90.02 1427.651160.48 267.17 Pass • Rig Floor to Top of W@II Y-09AL1 2.25 9.23 5.00 ~- 12.65 ~'~~ •- 7 1J16" X 3 1,'8" Flanged Adapter 20.04 --~ ~ Swab Valve Tree Size r Flew Te FI -~ 22.88 p SSV 24.86 ---~ ~~~ ~ tyiaster Valve 26.68 ~ Lock Down Screws 31.00 .~ Ground Level Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 13, 2008 3:59 PM To: 'Hubble, Terrie L' Subject: RE; Well Name? Y-09AL1 and Y-09AL1-01 Terrie, Thanks for the reply. I will make the changes and include a copy of this message in both files. Tom Maunder, PE AOGCC Page 1 of 1 From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, August 13, 2008 3:58 PM To: Maunder, Thomas E (DOA) Subject: RE: Well Name? Y-09AL1 and Y-09AL1-01 Hi Tom, Thanks for catching that... Yes, the well names of both lateral legs should have included the "A" indicator: Y-09AL 1 Y-09AL1-01 Additionally, it appears that I inadvertently attached the directional plans to the wrong permits. So, if you would be so kind, please swap the directional plans and add the "A" indicator to the Well Names. Your attention to detail is very much appreciated. Thank you, Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 13, 2008 3:15 PM To: Hubble, Terrie L Cc: Sarber, Greg J Subject: Well Name? Y-09AL1 and Y-09AL1-01 Terrie, I am reviewing the permit for the planned lateral and spoke in Y-09A. The name on the permits does not include the "A". From everything I can see, the "A" should be part of the names and the correct names are as listed in the message title. Would you please confirm? Thanks in advance, Tom Maunder, PE AOGCC 8/13/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~ C • ' _ ., ,_ - .. ~ ~_:~~ F~lat~, t , -.~r-ter's Search State Cabins ~i~tural i ~ ~If~s Alaska DNR Cass Summary File Type ADL„ File Number: 28287 ~ ~ Printable Case F.le_Summary See Township, Range, Section and Acreage? New Search Yes ~ No LAS MQn:.~ I Case Abstract I Case Detail I Land Abstract :.,, Pile: AUL 28287 ~ "~~'~' Search for Status Plat Updates ;~s oC 08;'1 ~;'?Ol)S Customer: OOU 107377 BY LXPLORA~IlO~~i (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 7~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG D[V OIL AND GAS Crrse Status: 35 ISSUED Status Date: 08/09/] 965 Total.AcNes: 2560.000 Dute Initiated: 05/28/1965 Office of Primary Res?~onsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: ~ NORTH SLOPE Lust Transaction: AA-NRB ASSIGNMENT APPROVED i-Ieridrurr: t ~ T~nr~rshii~: U I l ;~~ i~unae: 0l ~ I : ,S'ection: 2 ~ Section Acres: (~=1U Search °lats al~~f-r~lrun: l-! ~ulrrts~hrj~: O1 I\ Ruff<~e: 01 ~~ ,S'~~cti~~n: ~8 .ti'~~c~!«~it .Icrc~~~: 6~0 ;ll~~rh/iur~.~ U %uu~rr~~hii~: O1 I \ Ruf~gc.~ ll l ?I~; .ti`r~c~iuj~: >; ~~'c~c~tiun :1~~~•es: 6-~U rl~lc~ric/iun~ ll 7niriz~~hi~~: OI1N R~ut;~~~: 01 I_. ,1'ectror~: >~1 J'eetion~lc~r~~e: 6=10 Legal llescr•iption D~ -?8-196 * * *SALE NOTICE LEG,4L DESCRIPTION'` Cl d -9~ T11 N-R13E- UM 27, 28, 33.34 2560.00 uimim~° Last updated on 08/12/2008. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28287&... 8/12/2008 Alaska Department of Natural Resources Land Administration System Page 1 ofd ~ . - ~ - , ,-,; ~T;- ~ ~i~Es Re~orde~`s ~~~rciz State Cabins (11~3tE1~~ 3~u1YC~S _- Alaska DNR Case Summary File Type: ADL File Number: 47471 ~ Printable Case File_Summ....a..ry See Township, Range, Section and Acreage? New Search C Yes ~"' No -- ----- LAS Mena I Gase Abstract ~ Gase Detail I Land Abstract - ~., l rle: :aDL ~I7~71 ~''' "-' ~ Search for Status Plat Updates -~s of 08 ' 1 ~ ` 008 Custo~ner.~ 000107377 BP EXPLORATION (ALASKA) 1~C PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 9951 966 1 2 Cuse Type: 7fi~ OIL & GAS LEASE COMP DNR Ur~it.~ 780 O1L AND GAS file Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/30/1969 Total Acres: 2560.000 Date Initiated.' 08/1 1/1969 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype. S NORTH SLOPE Lust Transaction: AA-NRB ASSIGNMENT APPROVED Meri~iuj~: i 1 I rnrnshrp: 010\ IZartge: OI I .~'ection: 03 .5'eclinn ,ic~res: 640 Search Mats Illy°f-i~lian: U 7~n~~ ri.~lrr/~~ O l 0~] IZrr~rge: 013E ,S'eclru~r. U 1 .S'~~clrun _ le~r~e~~: (i~10 M~~rrclrun: lJ 7~~tirj~.chri~: 01U\~ lcra:~ge: 013E S'~-c~ion: 00 5'ce~nonAcres:64Q ~I~l~~f-ic~rc:n ~ U 7~rnr~rsh~~~: 010V'~ R~m~~.~ Ol ~ E S~>c~Jion. 10 S'ectinn _-]c~~es: 640 Lc;;al llestription Ob'-11-1969 * * *S~ILE NOTICE LEGAL DESCRIPTIONS C23-056 ION-RISE-UMGENERAL 03 6-10.00 ALL 04 6-?0.00 ALL 09 6-0.00 ~1LL 10 6=10.00 ~iGL TOTAL ACRES - 2560.00 l ~ base aimir ~'y http://www.dnr.state.ak.us/las/Gase_Summary.cfm?FileType=ADL&FileNumber=47471 &... 8/12/2008 r ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~1~l,/ J~ O9L~ O/ PTD# v~0~/~~jj ~Developmetrt~ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~i~~a.yo~- 3Ay POOL: _ f .e!/Gf~DE /~Ay 1 Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing /` well ~ - C~~~ V (If last two digits in AP1 number are Permit No. ~,S`1 -Ly~~ ,P[ No. 50- Gt~~1- ~US'1 - ~ ~ . 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 logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API cumber (50- - _) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of weln until after (Comoanv Namel has designed and implemental a water well testing program to provide baseline data on water quality and quantity. _(Comoanv Name) must contact the Commission to obtain advance approval of such water well testing ro Rev: 1/11/2008 WELL PERMIT CHECKLIST Fiekl 8 Pool PRUDHOE BAY, PRUDHOE OIL - 640150 WeN Name: PRUGHOE BAY UNIT Y-09AL1-01 Program DEV Well bore sag ^ PTD#:2089280 Company BP EXPLORATION (ALASKA) iNC Initial ClasslType DEV! P END GeoArea 890 Unit 11650 ONOff Shore On Annular Disposal ^ Administration 1 Permit fee attached------ - -- -- -- ------ - ------- ~`------- -- --- - ---- -- - -- - ----- - ---- 2 lease number appropriate--- - --- - --- - ----- - ---- YeS----- - -- - -- - - ------- --- - -- -- -- --- 3 Unique well-name and number--- - --- - --- - - --- - ---Yes - - ------------------ -- - --- -- ---- -- ----- -- -- 4 Wfllllocatedina-deflnedp9ol ----- --- --- - - ----- Yes--- ----- - ------- 5 Well located proper distance fromdnllingunit_boundary_______________ _______-Yes______- --_-_-____. i 6 Well_located proper distance from otherwells- - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficieniacreageayailableindrillingunii----------------------- ---- ----Yes------_ 256Dacres.-_-_._______--_---_--_-______----------- ------------------ 8 Ifdeviated~is-weliboreplat-included-- -- - ---- - -- - -----Y~- ----------------------- -- -- --- --------- ---- 9 Qperakoronlyaffe°tedparb ----- -- --- --- -- ----Yea - -- ----- -- ---- --- - - - ----------- - - ---- - 10 Opgratotbas_appropriatebondnfQrce------------------------ ---------Yes------- BlagketSond#61Q4193•--------------------------------.----------------.- 11 Petmitcanbeissuedw)thoutconsenlationordt<r_-_--------------- ---__---Yes------- ------------------------------------------------------------------ Appr Date 12 Pemlitr~nbeissuedwithoutadministrative_app[oval---------------- --------Yes------- -._---------.---.---.--------------------------------------------- ACS 8/1212008 13 Canpennitbeapprovt3dbefore15-daYwa~- -- - -- -- - --- - Y~ ------ -- --- -- - - ---- -------------- -- --- -- 14 WeII-locatedwiihinareaandstraiaauihorizedby_InjectionOrder~(putlA#in-comments{FOr_ NA________ ______________-___--___-__-_____.._-.__---._-----_____..-_---_-- 15 Aliwells_vritbin114_miie-atea_°freyiewidentified(F9rseNice_weU4niy)----- ----------NA-------- ------------------------------------------------------------------ 16 Pre-producedinjectoe duration ofprs-p%du°ti9n~ssthan3montha_(ForserviceweliQnly)---NA-------- -------------------------------------------------------------------- 17 .Kortcanven.gasconformstoAS31~05,03DQ.1.A)~(t•2.A-p) ----- - ------ .. NA--- --- - ------- - --- ---------- -- --- - - --------- - - -- - Engineering 18 Conductorstring-ptwided------------------------------- ---------NA____-__ ~onduutarsetinY-01(17$-0$5)•-------------------.---_------------------------- 19 SutfacecasingproiectsallknownUSRWs---------------------- --------NA------- All aquifersexempted~AEO1.-.--------------------------------------------- ZD CMT_vo(sdequate_tQCitculateon_cgnduct°[8,surfcsg_____--_.__--_ ________ NA_______ Surfa4BGasing§etinY-D1______________________-__--__--_________--_____._ 21 CMT_voladequate_t°fie-ir~longstringto_surfcsg------------------- ----------NA-_---_-_ Productioncasingsetin Y-Q1.---_--------------------------------------------- 22 CMTwiUcover-aliknown_productivehorizens----------------__._ -_-__-._--Ko-_---___ Slpttediinercompletionptanned~_____---_---_---___---..--..------------...-_-- 23 Casing designs adequate for G,_T, 9 8_permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - _ _ _ _ _ Anginal well met design specifications. _ NA for slotted linec_ _ _ _ _ _ - - - - - - - - - - - - _ - _ _ . - _ - - - _ _ - - 24 Adequate iankage_or reserve pit - - - - - - - - - - - - - - - -- - - - - - - - - - _ - - - _ _ Yes _ _ - - - _ _ Rig equipped with steel pits, No.reserve pit planned.- All waste t9 approved disposalwail(s). - - - - _ _ _ _ - _ _ 25 Ifa_re-drilGhas.a10.4031ora4andonmentbeenapproved------------ --------- NA------ ----------------------------------------------------------.-------- 26 Adequate welibore separationptoposed- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - _ - - _ Proximity analysis performed, Nearest segment is Y-01Ah1_ and paths diverge. - _ _ . - _ - - - _ _ - _ _ _ - - _ _ - _ 27 Ifdiverterre4uired,doesitmeetregulstions_____--------------- --------- NA-_-_____ BAPstaCkwillalready-be inplaee,_____-_-_______-_-------------------.--___--- Appr Date 28 Drilling fluid program schematic_$equip lisiadequate- - - - - - - - - - - - - - - - - - - - - - -Yes _ _ _ _ - - _ Maximum expected fo[mation pressure 6,9 EMW. MW planned $.$ ppg. _ _ _ - - _ - _ _ .. _ _ _ - - _ - - - _ - - _ TEM 8N3I2006 29 BOPEs,dotheymeetrsgulation-- - ----- --- - ---- ----Yes -- --- - --- ------ -- -------- -- - - -------- ~ ~~ 30 BOPE_press raiirtg appropriate; iesi to_(put psis in-comments)- - - - - - -- - - - - - - - - - - - Yes _ - - - _ - _ MASP calculated at 2262psi, 3500_psiBOP testpianned, ~ ~r/,,'~-. ~,°'./ 31 ChDke_manifold9omplieswlAPLRP•53{May$4_)------------------- ---------Yes------ - - - - - - - - - - - - - - - - - - - - --.---_ 32 Work willoccu[withoutoperationshutdown-_.___-------------- --__-_--Yes--__--- ------------------------------------------------------------------- 33 Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ Yes - - - - - _ _ H2S is niperted_al Y pad.. Mud-should pr~iude-H2S on rig._ Rig has sensors and_aiarms. _ - _ _ - _ _ _ _ _ _ _ _ . _ 34 _MeshanicaLcondidonofweilswithinAARverified(Forsen~icewellonlya----- --------- NA------- -------------------------------------.--------------------...---- Geology 35 Perm~.can be issued w1o hydrogensuifidemaasures - - - - - - - - - - - - - - - - - - - - - - - - - -hic- _ _ - . _ - _ Max y2$ level Qn Y-92A-3Dppm_ on 4119/08[ yreil Y-28=2DOppm on $1291. _ _ _ _ - - _ , , - - _ . _ - _ _ _ _ _ _ _ _ 36 Data-plesentedonpotentizl9verpressurezones------------------ ---------Yes---._- ----------.-----------------.-------------.----------------------- APW ~~ 37 Seismic_anaysisofsballowgaszone ---- --- --- - ---- ~' ----- - -- - --- --- - ------- ------- - ---------- -- - ACS 8!1212006 36 Seabed_condition suryey.(if o~•shore) . . . . . . . . . . . . . --- - - ----- N? •----- -- - - ---- ---------- - --------- - 39 Contactnamelphoneforweekly-progress repods[exploratoryonly]________ _________Yes..----- GtegSarber_•584.4330,----------------------------------------------------- Geologic pate: Engineering pate P ' Date Commissioner: er Com fission r: Co iss ~~~~ ~-~~ a~ '/~ 08 Well 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 efi(or1 has been made to chronologically organize this category of information. • A **** REEL HEADER **** MWD 09/03/03 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/10/18 2232624 01 3" CTK *** LIS COMMENT RECORD *** !!~!!!!!!!!!!~!~~!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 13999.5000: Starting Depth STOP.FT 16131.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: Y-09AL1-O1 FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 16' 3.830"N 148 deg 49' 47.018"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOT, NAME & TYPE: 3" CTK DATE. LOG DATE: 18 Oct 2008 API API NUMBER: 500292057961 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 33 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 87.72 DMF DF EKB .F 0 EDF .F 87.72 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. ~~~ -~a~ l~~-c~~ 5 s ~ (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. The MWD data from well Y-09AL1 is the PDCL for this well. All data above the Kick Off Point of 14479 feet MD was depth shifted carrying the final shift from 14479 feet MD to the bottom logged interval. (8) The sidetrack was drilled from Y-09AL1 through a milled window in a 4 1/2 inch liner. Top of window 14292 ft.MD (8964.1 ft.TVDSS) Bottom of window 14302 ft.MD (8963.4 ft.TVDSS) (9) Tied to Y-09A at 14283 feet MD (8964.7 feet TVDSS). (10) The interval from 14283 feet to 14498 feet MD (8964.8 ft to 8997.3 ft TVDSS)was logged 24 hours after drilling run 4. (11) Runs 4, 5 and 6 were used to drill Y-09AL1 ans set liner with the top of an aluminum billet at 14498 feet MD (8947.3 feet TVDSS). (12) Y-09AL1-O1 is sidetracked off of an aluminum billet from Y-09AL1 at 14498 feet MD (8947.3 feet TVDSS). (13) The interval from 14498 feet to 14629 feet MD (8947.3 feet to 8935.4 feet TVDSS) was logged 20 hours after drilling on run 8. (14) The resistivity interval from 15773 feet to 15816 feet MD (8947.2 to 8949.6 feet TVDSS) was relogged as a MAD Pass 16 hours after drilling run 10. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) (OHMM) (OHMM) (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 14011, 1 4008.7, ! -2.28027 14017.4, 14017.6, ! 0.207031 14047.1, 14047.3, ! 0.208008 14054.1, 14054.5, ! 0.414062 14064.9, 14065.5, ! 0.62207. 14068.7, 14071.6, ! 2.90137 14071.8, 14075.6, ! 3.73145 14076.8, 14080.5, ! 3.73145 14079.6, 14083.1, ! 3.52441 14286.5, 14288.8, ! 2.28027 14295.8, 14298.3, ! 2.4873 14299.7, 14301.6, ! 1.86523 14302.8, 14305.1, ! 2.28027 14317.1, 14319.6, ! 2.4873 14326.1, 14328.3, ! 2.28027 14332.1, 14334.4, ! 2.28027 14340.2, 14342.2, ! 2.07324 14346, 1 4348.2, ! 2.28027 • • 14350.3, 14352.8, ! 2.4873 14356.3, 14358.6, ! 2.28027 14358.8, 14361.1, ! 2.28027 14361.1, 14363.2, ! 2.07324 14386.2, 14388.7, ! 2.4873 14393.7, 14395.5, ! 1.86621 14409.6, 14411.9, ! 2.28027 14413.6, 14416.1, ! 2.4873 14419.8, 14422.1, ! 2.28027 14424.4, 14426.7, ! 2.28027 19426.9, 14429.4, ! 2.4873 14432.1, 14434.1, ! 2.07324 14434.4, 14436.6, ! 2.28027 14439.3, 14441.6, ! 2.28027 14445.3, 14448, ! 2.69434 14449.3, 14451.6, ! 2.28027 14454.3, 14456.5, ! 2.28027 14457.6, 14460.1, ! 2.48828 14464.8, 14467.1, ! 2.28027 14469.6, 14471.9, ! 2.28027 14476.6, 14478.7, ! 2.07324 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 125 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !~!!!~!~~!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL (Primary Depth Control) log. The MWD data deom well Y-09AL1 is the PDCL for this well. All data above the Kick Off Point of 14479 feet MD was shifted carrying the final shift from 14479 feet MD to the bottom logged interval. * 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: 119 Tape File Start Depth = 13999.500000 Tape File End Depth = 16131.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 132 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * 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 i 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: 237 Tape File Start Depth = 14002.000000 Tape File End Depth = 16129.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 250 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/10/18 2232624 01 **** REEL TRAILER **** MWD 09/03/03 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~ ~ Tape Subfile 1 is type: LIS ~ ~ Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 13999.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14100.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14300.0000 26.6951 1.0000 2000.0000 3.5211 2000.0000 8.4757 14400.0000 30.4498 90.2749 8.0520 8.4179 7.2936 6.3316 14500.0000 59.5006 113.5297 5.2757 6.1802 5.9028 5.3530 14600.0000 187.8539 39.3025 15.8226 2000.0000 1340.6086 58.6413 14700.0000 84.2994 76.4455 5.2932 23.8997 25.2456 2000.0000 14800.0000 32.6201 143.4328 6.8856 7.4186 7.2997 7.1883 14900.0000 30.7006 332.8414 4.7000 5.0184 4.9252 5.0462 15000.0000 40.0977 165.8597 4.9658 4.9238 4.4660 4.0560 15100.0000 30.6189 140.3670 5.3490 6.1170 5.4894 5.1783 15200.0000 40.2764 141.3244 7.9788 9.4990 9.4603 9.9214 15300.0000 25.5490 248.9646 9.4010 11.0623 10.7300 10.5590 15400.0000 79.4928 81.8340 9.1638 12.3664 11.8338 11.4390 15500.0000 208.4373 105.8438 4.4450 8.6186 8.2604 16.5230 15600.0000 136.3615 124.2299 8.3652 10.6598 10.2790 10..4759 15700.0000 36.5000 151.2035 10.0398 12.1836 12.1652 11.6060 15800.0000 37.4189 115.6184 9.9940 12.4488 11.6190 11.1237 15900.0000 47.0432 113.3012 11.0020 13.1104 12.0251 11.1465 16000.0000 128.2195 94.6959 7.6864 12.4063 13.2812 16100.0000 -999.2500 111.5793 -999.2500 -999.2500 -999.2500 16131.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13999.500000 Tape File End Depth = 16131.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 13.1411 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 14002.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14002.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14100.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 14300.0000 44.9000 5.4000 1756.2549 5.0390 0.9880 6.3540 14400.0000 33.1000 45.1000 8.1110 8.5440 7.4930 6.5650 14500.0000 54.1000 3.5000 4.8170 6.0790 5.9780 5.5750 14600.0000 187.4000 53.3000 12.3230 41.8490 47.4870 41.3010 14700.0000 79.9000 52.6000 19.7350 26.8960 32.9410 8.5320 14800.0000 38.6000 100.1000 6.7720 7.1550 7.0280 6.8840 14900.0000 33.5000 316.4000 4.5770 4.9620 4.8470 4.9930 15000.0000 39.3000 154.5000 4.9250 4.8650 4.4480 4.0850 15100.0000 27.1000 119.5000 5.3700 6.1510 5.4010 5.0320 15200.0000 58.0000 144.0000 8.0730 9.5990 9.5290 9.9550 15300.0000 31.7000 208.0000 9.4000 11.1570 10.8230 10.6640 15400.0000 79.4000 208.4000 9.0910 12.3090 11.7210 11.3690 15500.0000 190.6000 98.3000 4.8580 11.3380 9.5110 24.2210 15600.0000 60.6000 132.1000 8.8110 11.2550 10.8670 10.9760 15700.0000 43.3000 153.4000 9.8580 11.6710 11.5500 10.9380 15800.0000 42.0000 118.5000 10.0640 12.3560 11.9380 11.4860 15900.0000 63.1000 118.4000 11.0180 13.0960 12.0740 11.1290 16000.0000 133.7000 97.5000 7.7500 11.8300 12.3010 16100.0000 -999.2500 116.6000 -999.2500 -999.2500 -999.2500 16129.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14002.000000 Tape File End Depth = 16129.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 12.8810 -999.2500 -999.2500 Tape Subfile 4 is type: LIS