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Home My WebLink About208-127Ima a Pro~ct Well History File Cov~age 9 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. ~~g _ ~ ~ ~ Well History File Identifier Organizing (done) RESC olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o..o.,a~, iiummuiiuii DIG TAL DATA Diskettes, No. ~~„ ^ Other, No/Type: o ae,~..x~~d iiiuiiiuiuum OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: gY; Maria Date: ~ / ~ ^ Other:: /s/ Project Proofing IIIII~IIIIIIII VIII gY; Maria Date: D /s/ n ti P - ~ x 30 - ~ + ~ =TOTAL PAGES o repara Scanning _, (C~unt ~~es nit include cover sheet) gY. Maria Date: /s/ Production Scanning " "' - ~ -~ ~ - ~ ~~ Stage 1 Page Count from Scanned File: ---L=' - (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO gY: Maria Date: 3 ~ ! ~ /s/ V~/f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO gY: Maria Date: /s/ IIIIIII nless rescannin is required. II I II VIII I II Scanning is complete at this point u 9 d IIIIIIIIIIIIII VIII ReScanne BY: Maria Date: /s! Qualit Checked II I II II II III (III II Comments about this file: y 10/6/2005 Well History File Cover Page doc DATA SUBMITTAL COMPLIANCE REPORT 313/2010 Permit to Driil 2081270 Well Name/No. PRUDHOE BAY UNIT Y-09AL1 Operator BP EXPLORATION (ALASI(A) INC MD 15621 ND 9047 Completion Date 10/21/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20579-60-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / type mearrrmt D Asc ' nu~nurr name Directional Survey ....a.` .......... ~.~ ~~..~ 14283 ....,,, 15621 .... Open .............. 11/14/2008 __......_.._ PBU Y-09-AL1-01(208-128- ~ ~ 0) also on Diskette ~ ~ ` Directional Survey 14283 15621 Open 11/14/2008 r~ l0 C Las 17472 "induction/Resistivity 14002 15620 Open RPM, GR, RAD, RAM, ROP, RPD ~ pt LIS Verification 13999 15623 Open 3/19/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS C Lis 17694 "Induction/Resistivity 13999 15623 Open 3/19/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 14283 15621 Open 3/19/2009 MD MPR, GR 10-Oct-2008 og Induction/Resistivity 5 Col 14283 15621 Open 3/19/2009 TVD MPR, GR 10-Oct-2008 og Induction/Resistivity 25 Col 14283 15621 Open 3/19/2009 MD GR 10-Oct-2008 ~ og - See Notes _ 5 Col 13999 15580 Open 3/19/2009 Depth Shift Monitor Plot Weli CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/3/2010 Permit to Drill 2081270 Well Name/No. PRUDHOE BAY UNITY-09AL1 Operator BP EXPLORATION (ALASICa INC API No. 50-029-20579-60-00 MD 15621 TVD 9047 Completion Date 10/21/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y N~ Daily History Received? N Chips Received? Yf#~ Formation Tops ~ N Analysis YXN- Received? Comments: Compliance Reviewed By: Date: i • ~ INTEQ Log ~ Data Transmittal Form To: State of Alaska -A®GCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: Y-09AL1 & Y-09AL1-Ol Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary '~ 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2232624 ~0~-12 ~ t~t ~ ~ H Sent by: Catrina Guidry Date: 03/16/ ~~ ~,~ ~ ~~~~- Received by:w , Date• ~~ ~ ~ n ~~~'~~_~ 1 .? 1 3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN4`~ETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~ ~f IiES INTEQ -,. -~- Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 • • ,/- BAKER Mt~GNES Baker Atlas PRINT DISTRIBUTION LIST CUMPAN Y BP EXYLUKA'1'lUN (ALASKA) 1NC WELL NAME Y-09AL1 CUUNl'Y NUK'IH SLUPE BUKUUGH 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 of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE. AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOYI 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. TTH 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 1701 Aldine Westfield Houston, Texas 77073 This Distribution List Completed Bti ~~ 1= Page 1 of 1 • Yage 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 Hi 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: 02/21/09 Hours Tested: 12 24-Hour Rate /Oil-Bbl: 2,231 24-Hour Rate /Gas-Mcf: 2,806 24-Hour Rate (Water-Bbl: 3,652 Test Rate /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 ~;,., >~'~Y., 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 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-21 A ~ ~ ~ -y ~. 18-246 N-146 N-14BP61 Y-05BPB1 Y-09AL1 Y-09AL1-01 u - ~ i~; 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 ~; ~L~_i3r i~~-~,; ~~~a~ I ~b'S -- 1 ~ ~J i ~ ~-! ~ z-f Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . w 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 zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. ~ 10/21/2008 12. Permit to Drill Number 208-127 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/7/2008 ' 13. API Number S0-029-20579-60-00 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached 10/10/2008 ~ 14. Well Name and Number: PBU Y-09AL1 FEL, SEC. 33, T11 N, R13E, UM 1387' FNL, 98 Top of Productive Horizon: 4569' FNL, 58' FWL, SEC. 03, T10N, R13E, UM 8. KB (ft above MSL): 87.72' Ground (ft MSL): 50.15' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4317' FNL, 958' FWL, SEC. 03, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 15620' 9047' Pool 4b. Location of Well (State Base Ptane Coordinates, NAD 27): Surface: x- 644718 y- 5948866 Zone- ASP4 10. Total Depth (MD+TVD) 15621' ~ 9047' 16. Property Designation: ADL 047471 TPI: x- 645055 y- 5940410 Zone- ASP4 - 5940680 Zone- ASP4 th: x- 645949 T tal De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p y o 18. Directional Survey ®Yes ^ No S i 1 r ni and tinted inform i n er 20 AA 2. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and print informafon per AAC 25.071): MWD DIR, GR, RES !/~NDO`/(~/~o? i~9 ~~~5'/.~TY~ Z2. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" x I lated Co or rfa 11 Su 110' 36" c d C n r t -1/ " 7 9-5/8" 47# L- rf ce 2 2' Surf 7 1 -1/4" 1435 cu tt Class'G' 130 cu tt PF'C' 7" L-8 030' 1 2' 77 1' -1/ " ft Cla ' 4-1 1 " -7/ " .1 14499' 1 9 " 7' a-va~~ X s-3/a^ nc met to ed finer 23. Open to production or inject ion? ®Yes ^ No 24. TuawG RECORD If Yes, list each i MD+TVD f T 8 B tt P nterval open nd Number): r ti n Siz rf SIZE DEPTH SET MD PACKER SET MD ~ o om; e o a o e a ( o op 2-7/8" Slotted Section 4-1/2", 12.6#, L-80 10469' 10413' MD TVD MD TVD 14508' - 15598' 9034' - 9048' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l 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. ~., ~, .. ui M1.i,3 n1+ i None g nn „pal y' Form 10-407 Revised 02/2007 CONTINUED UN KEVERSE SIDE . a. ~.. ~~aj~ t ~~(~ I r 2??s. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit 14648' 9025' None Sadlerochit 14667' 9024' Formation at Total Depth (Name): Sadlerochit 14667' 30. List of Attachments: Summary of Pre-Rig work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. D 't ate Signed Terrie Hubble Title Drilling Technologist PBU Y-09AL7 208-127 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Greg Sarber, 564-4330 P mi N . / A I No. INSTRUCTIONS GeNeRaL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 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. ITEM 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 Y-09AL1, Well History (Pre Rig Sidetrack/Multilateral) Date Summary 8/9/2008 WELL FLOWING ON ARRIVAL. DRIFT TBG WITH 3.80 G-RING TO BK PATCH AT 10204' SLM. 8/10/2008 ATTEMPT TO PULL BKR PATCH WITH 4-1/2" GS. AFTER 6 HRS OF JARRING, PATCH MOVED UP HOLE T 9240 . 8/11/2008 RECOVER BKR STRADDLE PATCH. (1 ELEMENT STILL IN WELL) DRIFT TO 10,427' SLM WITH 4- 1/2" BLB AND 3 PRONG WIRE GRAB. NO PORTION OF ELEMENT RECOVERED. PULL 4-1/2 x 2-7/8 NIPPLE REDUCER FROM 10,427' SLM. DRIFT TO DEVIATION AT 10,871' SLM WITH 4-1/2" BLB AND 3 RONG WIRE GRAB. NO PORTION OF ELEMENT RECOVERED. WELL LEFT S/I. TURNED WELL OVER TO DSO. 8/20/2008 WELL S/I ON ARRIVAL. CURRENTLY DRIFTING W/ 3.80" GAUGE RING. 8/21/2008 WELL S/I ON ARRIVAL. TAGGED XN NIPPLE C~ 10457' MD W/ 2' 1 7/8" STEM, 3.80" GAUGE RING. RAN PETRADAT GAUGES AS PER PROGRAM (G 8/30/2008 T/I/0=1510/1500/150. SI. Bleed IAP < 500 psi (secure). AL SI C«3 casing valve, ALP=1720 psi. Initial IA FL C~ 6380' (342 bbls), between sta# 4 & 5. Bled IAP to production to 230 psi in 2 hrs 45 minutes. IA FL inflowed 4148' or 222 bbls, TP decreased 60 psi during bleed. Monitor for 1 hr, TP &IAP increased 20 psi. Final WHPs=1470/350/150 SV,WV,SSV,ALV=Closed MV=Open IA & OA=OTG NOVP 8/30/2008 T/I/O=SSV/340/140. Temp=Sl. Monitor, post bleed (secure). AL SI ~ casing valve, ALP=1720 psi. IAP decreased 10 psi & OAP decreased 10 psi since last night. IA valve has small stem packing leak, notified greased crew. SV,WV,SSV, ALV=C. MV=O. IA & OA=OTG. NOVP. 8/31/2008 T/I/O=SSV/340/140. Temp=S1. Monitor, post bleed (secure). AL SI C~3 casing valve. ALP=1720 psi. IAP & OAP unchanged overnight. SV, WV, SSV, ALV=Closed. MV=Open. IA&OA=OTG. NOVP. 9/1/2008 T/I/O=SSV/350/140. Temp=S1. Monitor, post bleed (secure). AL SI Q casing valve, ALP=1700 psi. IAP increased 10 psi & OAP unchanged overnight. SV, WV, SSV, ALV=C. MV=O. IA & OA=OTG. 9/1/2008 T/I/0=1550/400/100 Load Tbg & IA (Pre CTD). Pumped 5 bbls meth and 296 bbls 110°F crude down IA. Pumped 300 bbls 110°F crude down Tbg. Annulus casing valves tagged and left open, operator notified. FWHP's=350/80/200 9/2/2008 T/I/0= SSV/VAC/150. Temp= SI. Monitor (eval WHPs post L&K). AL SI C~ the casing valve w/1750 psi. IAP decreased 350 psi. OAP unchanged overnight. SV,WV,SSV,ALV= Closed. MV= Open. IA,OA= OTG. NOVP. 9/7/2008 Mill XN nipple & whipstock drift., RIH with 3.80" parabolic mill & left handed motor, Mill thru XN, Run into bridge at 12270', appeared to be rubber, milled it up, 9 stalls w the motor. RIH to 14519' (not enough pipe to reach PTD). PUH to 10421, RBIH dry. 9/8/2008 Whipstock drift and Caliper Log. POOH from milling job, Lay down BHA and MU &RIH Dummy whipstock drift. Unable to aet oast 12274' with drift. POOH to p/u motor and venturi basket with burn shoe. Found a rock brass pin cement & metal shaving in venturi basket. RIH with Dummy whipstock, Unable to~~oa t 1 78'. Discuss with town engineer, POOH to p/u motor, mill and string reamer. 9/9/2008 MU &RIH diamond speed mill and string mill. T~gy;,o 1 77'. Mill throegh and trip to 14450', POOH, UD milling BHA, MU &RIH dummy whipstock, could not pass 12276'. POOH, UD dummy whipstock, MU & RIH PDS caliper. 9/10/2008 RIH with PDS Caliper tools to 14500'. Log up at 50 fUmin to 10,000'. Left one arm of the caliper tool in the hole. Downloaded data was good. Page 1 of 2 ~ r Y-09AL1, Well History (Pre Rig SidetracWMultilateral) Date Summary 9/12/2008 MU & RIH, BHA with 2 diamond string mills and diamond parabolic mill. Tag funk at 10953' rotate mill and push sunk down hole. 9/13/2008 Dressed up area C~ 12274' w /mill and two stream reamers. Appears we are chasing the arm off the caliper tool lots of stalls and slow ROP all the way to 14450', MU & RI dummy whipstock drift, Passed through problem area at - 12276' at 80 ft/min with -2k wt bobble. Had another weight bobble at 13520', continued in hole to 14500' with no problems. POOH, saw a weight bobbles at - 12270' up to 12250', nothing at 13520'. 9/14/2008 Continue POOH with Dummy whipstock drift. RDMO. Job Complete. 9/15/2008 T/I/0=100/0/0, Temp=Sl. PPPOT-T (PASS). Pre CTD. PPPOT-T: Stung into test port (50 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test; lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 9/27/2008 T/I/0=vac/0/100. Set 4" CIW H BPV. Pre Nordic 2. 10/2/2008 T/I/0=0/0/0; Set 3" Gray VR Plug in I/A removed Annulus valve and Piggy-backed on opposite side of well for Nordic 2. Complete. Page 2 of 2 ~ r BP EXPLORATION Page 1 of 18 Operations Summary Report Legal Well Common W Event Name Contractor Rig Name: Date , Name: Y ell Name: Y : R Name: N N From - To -09 -09 EENTE ORDIC ORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig R Rig N Phase Spud Date: 6/14/1981 : 10/1/2008 End: 10/21/2008 elease: 10/21/2008 umber: Description of Operations 10/1/2008 00:00 - 01:20 1.33 RIGD P PRE Clean up around well head. 01:20 - 01:30 0.17 CONS P PRE PJSM on moving rig. 01:30 - 02:20 0.83 MOB P PRE Move rig to other side of pad for rig maintenance. 02:20 - 02:35 0.25 CONS P PRE PJSM on lowering the BOP's and securing. 02:35 - 04:00 1.42 CONS P PRE Set BOP's on stand and secure. 04:00 - 04:15 0.25 RIGD P PRE PJSM on prepairing rig for derrick down. 04:15 - 13:00 8.75 RIGD X RREP PRE 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. 13:00 - 15:00 2.00 RIGD X RREP PRE Unstring blocks. 15:00 - 17:00 2.00 RIGD X RREP PRE Spot & RU crane. Lower down old blocks & mud manifold. Hoist up new blocks & mud manifold to RF. Secure new mud manifold. 17:00 - 18:30 1.50 RIGD X RREP PRE Restring new blocks w/ Hemp rope. Restring blocks with wire rope using the drawworks. 18:30 - 19:30 1.00 MOB X RREP PRE Make ready to mobilize rig. 19:30 - 23:00 3.50 MOB P PRE 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. 23:00 - 00:00 1.00 MOB P PRE Safety meeting with CPS and security CPS measured rig (~ 57 ft. 10/2/2008 00:00 - 07:00 7.00 MOB P PRE 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. 07:00 - 10:40 3.67 MOB P PRE Move rig down twin towers road. 10:40 - 11:10 0.50 MOB P PRE Turn onto spine road & convoy with Doyon 16 to J pad. 11:10 - 11:40 0.50 MOB P PRE Wait for loaders to shuffle rig mats in front of the rig. 11:40 - 13:30 1.83 MOB P PRE 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 13:30 - 20:20 6.83 MOB P PRE 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. 20:20 - 22:00 1.67 MOB P PRE PU injector and reposition from rig floor. Install goose neck. 22:00 - 00:00 2.00 MOB X RREP PRE PU new mud manifold and install. 10/3/2008 00:00 - 05:00 5.00 MOB X RREP PRE Continue to install new mud manifold. Spot rig mats and pit liner while waiting for welder. 05:00 - 10:30 5.50 MOB X RREP PRE Weld new floor plate around new mud manifold. Tuboscope the back board of the monkey baord welds - no cracks. 10:30 - 10:45 0.25 MOB P PRE PJSM w/ pad op regarding pulling over the well. 10:45 - 11:30 0.75 MOB P PRE Spot the rig over the well. 11:30 - 14:00 2.50 RIGU P PRE Level rig. Spot cuttings box. Spot tiger tank. Re spot office trailer. Spot welding shack. Spot reel trailer. 14:00 - 20:00 6.00 RIGU P PRE Load reel into reel house. ND tree cap & NU BOP's. Load pits w/ 2% KCL + 2PPB Biozan. 20:00 - 21:40 1.67 RIGU X RREP PRE 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 Nnntea: i vsi~uuo 11:43:UJ HM ~ r BP EXPLORATION Page 2 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 10/3/2008 20:00 - 21:40 1.67 RIGU X RREP PRE 21:40 - 22:30 0.83 BOPSU P PRE 22:30 - 00:00 1.501 BOPSUFj P PRE 10/4/2008 100:00 - 03:30 3.501 BOPSUF~ 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 08:00 - 09:05 1.25 BOPSUF~ P PRE 09:15 - 11:30 2.251 RIGU P i PRE 11:30 - 11:40 0.17 WHSUR P PRE 11:40 - 12:45 1.08 WHSUR P PRE 12:45 - 13:50 1.081 WHIP P PRE 13:50 - 15:35 1.751 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 0.25WHIP P (WEXIT 16:45 - 17:00 0.25 WHIP P WEXIT 17:00 - 21:55 4.92 WHIP P WEXIT 21:55 - 00:00 2.081 WHIP P WEXIT 110/5/2008 00:00 - 00:45 0.75 WHIP P W EXIT Description of Operations 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 waive~c ~y 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 250psi/3500psi -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. Pull 4" GIW BPV RD DSM I~bricatnr_ 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 C~ 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 80ft/min 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 ft - 14,300 ft. tag ~ 14,155 ft 2,200 #'s PU to 14,150 ft and RIH and continue GR 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. rrirneo: i usrzuu° i i:asva rm 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 PU to 14,290 ft bit depth. 00:50 - 01:00 0.17 WHIP P WEXIT UP WT = 43 K #'s 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 1.831 WHIP N FLUD WEXIT 08:20 - 10:20 2.00 KILL N FLUD WEXIT 10:20 - 10:30 0.17 KILL P WEXIT 10:30 - 11:15 0.75 WHIP N WAIT WEXIT 11:15 - 13:10 1.921 WHIP P 13:10 - 13:20 I 0.171 WHIP ( P WEXIT WEXIT 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 returns 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 C~ 14 290 ft 20 dea LOHS. Circulate out well with 150 bbls surface to surface vol. taking contaminated returns 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 returns. 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 IA. 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% KCL/BIOZAN. Pump. after 121 bbls shut down pumps and and shut in choke. IA = 465 npsi WH = 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 C«~ 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. rnmea: i uarzuu° 11:43:V3 HNI • • 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 Description ofi Operations 10/5/2008 13:20 - 14:25 1.08 STMILL P WEXIT 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 strai ht 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. 14:25 - 17:07 2.70 STMILL P WEXIT 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 returns to the tiger tank. 17:07 - 17:50 0.72 STMILL P WEXIT 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. 17:50 - 20:40 2.83 STMILL N FLUD WEXIT 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. 20:40 - 00:00 3.33 STMILL N FLUD WEXIT 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. 10/6/2008 00:00 - 00:20 0.33 STMILL N FLUD WEXIT Finish RU of IA 00:20 - 00:45 0.42 STMILL N FLUD WEXIT PJSM 00:45 - 05:00 4.25 STMILL N FLUD WEXIT Starting pressures: IA=553 psi WH = 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 returns. 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 C~ 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 Pf111t8tl: 11/:t/'LUUt3 11:4J:U:3 HM ~ r BP EXPLORATION Operations Summary Report Legal Well Name: Y-09 Common Well Name: Y-09 Event Name: REENTER+COMPLETE Start: 10/1/2008 Contractor Name: NORDIC CALISTA Rig Release: 10/21/2008 Rig Name: NORDIC 2 Rig Number: Page 5 of 18 ~ Spud Date: 6/14/1981 End: 10/21 /2008 Date :From - To Hours Task Code NPT Phase Description of Operations -_ _ - - 10/6/2008 100:45 - 05:00 I 4.25 STMILL N FLUD WEXIT getting more gas ~ 19 bbls in. 05:00 - 17:00 12.001 STMILL ~ P ~ ~ WEXIT 17:00 - 20:00 3.00 STMILL P WEXIT 20:00 - 20:20 0.33 STMILL P WEXIT 20:20 - 21:45 1.42 STMILL P WEXIT ', 21:45 - 21:50 0.08 DRILL P PROD1 21:50 - 22:10 0.33 DRILL P PROD1 22:10 - 00:00 1.83 DRILL P PRODi 10/7/2008 00:00 - 00:40 0.67 DRILL P PROD1 00:40 - 01:20 0.67 DRILL P PROD1 01:20 - 01:40 0.33 DRILL P PROD1 01:40 - 03:10 ~ 1.501 DRILL ~ P ~ ~ PROD1 03:10 - 03:25 0.25 DRILL P PROD1 03:25 - 05:30 2.08 DRILL P PROD1 Close 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. ' Mill window from 14,291_.3ft. 2.52bpm in / 2.46 out ~ 2040psi w/ 1-2k WOB using 2% KCL water. Mill 0.1fU12min for the first foot followed by 0.1fU6min there after, pumping 2ppb biozan sweeps as needed. Exit window at 14,298 ft. Continue to mill O.ift/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. POH. Inspect bottom's up - small amount of formation cuttings in sample PJSM on LD of BHA while POOH. LD Milling BHA -window mill gauged 3.79 no go with good wear patterns. PJSM - PU of BHA PU build section BHA with 2.0 AKO rebuilt HYC 3.75 x 4.25 bi center bit. RIH with build section BHA 00:00 depth 10,672 ft. Continue RIH to 14,000 ft Log for GR tie in from 14,060 to 14,200 ft -41.5 ft correction RIH orientate tool. Op=2.51/2.41 bpm C~ 2020 psi Taa 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=1.96/1.90 bpm ~ 2700 psi. SEVXYX=5 still C~ 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 Wiper to window after PU for tool face change and had up wt = 62K. Drill ahead from 14,419 ft. Drilling ~ 14,450 ft Op= 2.06/2.01 bpm ~ 3400 psi rnmea: i vsizuu° i rvsua r+m ~ • 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: i Date 'From - To 'Hours ' Task Code NPT Phase Description of Operations 10/7/2008 03:25 - 05:30 2.08 DRILL P PROD1 den=8.69/8.63 ppg ECD=9.77 ppg DHPRESX=610 psi DH W06=1500#'s ROP=.9 fpm / 49 fph TF=80 LOHS SEVXYX = 5 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 10:05 4.08 DRILL P PROD1 10:05 - 13:05 3.001 DRILL ~ P I 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 21:30 - 22:00 0.50 DRILL P 22:00 - 22:45 22:45 - 23:15 0.75 DRILL P 0.50 DRILL P PROD1 PROD1 PROD1 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 diff= 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 WOB=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, 81 psi 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. W iper to bottom. Drill ahead to 15001' at 2.53bpm in / 2.51 out ~ 3700psi, 3150psi FS, 1.9-2.1 K WOB, 100fph ROP, 10.09ppg ECD, rrinteo: ivaizwa 11:43:VJAIV~ BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: 'From - To Y-09 Y-09 REENTE NORDIC NORDIC Hours R+COM CALIS 2 Task PLET TA Code E NPT Start Rig Rig Phase Spud Date: 6/14/1981 : 10/1/2008 End: 10/21/2008 Release: 10/21/2008 Number: 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 PROD1 Drill ahead from 15,298'. 3200 psi FS at 2.49/2.44 bpm in/out. 150-300 psi mtr work. 1.1k-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 bbl/hr. 22:40 - 23:20 0.67 DRILL P PROD1 W iper 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 in/out. 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'. Printed: 11/3/2008 11:43:03 AM BP EXPLORATION Page 8 of 18 ~ 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 10/9/2008 103:10 - 04:15 1.081 DRILL P 04:15 - 07:15 I 3.001 DRILL I P 07:15 - 07:30 I 0.251 DRILL I P 07:30 - 08:15 0.75 DRILL P 08:15 - 10:00 1.75 DRILL P Spud Date: 6/14/1981 Start: 10/1 /2008 End: 10/21 /2008 Rig Release: 10/21/2008 Rig Number: Phase Description of Operations PROD1 3500 psi FS at 2.77/2.70 bpm in/out. 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 final Drill to 15,582'. Losses at 5 bbl/hr. Unable to achieve turn without exiting the polygon. Pull BHA for adjustable motor. PROD1 POH. Open EDC above window and pump 3.2 bpm/3420 psi while POH. PROD1 Rig lost power. Crew smelled something "burning" on second level. Genset #2 windings are fried. Bring another generator on line. PROD1 Continue to pull out of hole. Hold PJSM near surface. PROD1 At surface. Get off well. Unstab coil. LD BHA tools. Bit had a few chipped cutters. Possibly from window contact. Grade 1-1-I 10:00 - 12:15 2.25 DRILL P 12:15 - 12:45 0.50 DRILL P 12:45 - 13:30 0.75 DRILL P PROD1 PRODi PRODi 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 0.251 DRILL N STUC PROD1 22:00 - 00:00 I 2.001 DRILL I N I STUC I PROD1 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. Soot another 5 bbls, wait 15 min then work oioe. 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. Printed: 11/3/2008 11:43:03 AM 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 it 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 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. 11:00 - 13:00 2.00 DRILL P PROD1 Dri -5 6?0,. , 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 a ain 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 ullin 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 ints of 2-7/8" STL 6.16nnf I -AO Slnttarl Up Wt above window w/ pumps off = 47.5k# & -2.6k DHWOB Log Tie-in, -60' correction. Tight Spot 15,423'. 57k# Up Wt Taa bottom at 15,622', hold 15k# and 3.2k DHWOB. Panted: 11/3/200tl 11:4;i:U:7 AM s ~ BP EXPLORATION Page 10 of 18 .Operations Summary Report Y-' 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 I, Hours Task Code ~ NPT 1 10/11/2008 02:30 - 06:30 I 4.00 CASE P 06:30 - 10:00 10:00 - 11:15 3.50 CASE P 1.25 CASE P 11:15 - 13:30 13:30 - 13:45 13:45 - 14:15 15:30 - 17:00 ~ ~,~ -~~, 17:00 - 18:15 >'.`~ 18:15 - 20:20 20:20 - 00:00 10/12/2008 ~ 00:00 - 01:55 01:55 - 04:15 04:15 - 04:55 04:55 - 08:00 2.25 STWHIP P 0.25 STWHIP P 0.50 STWHIP P 1.25 STWHIP P 1.50 STWHIP P 1.25 STWHIP P 2.08 STWHIP P 3.67 STWHIP P 1.92 STWHIP P 2.33 STWHIP P 0.67 STWHIP P 3.08 STWHIP P 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 RIM 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. 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 Run in hole. Ta liner to at 14,499'~Liner btm 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 in/out. 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'. PROD2 Wiper 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 Page 11 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: i Date From - To Hours Task Code NPT ~ Phase- i Description of Operations 10/12/2008 04:55 - 08:00 3.08 STWHIP P PROD2 3.3-3.67k# DHWOB, ROP 3-9 fph, 10.04 ppg ECD. IA = 504 psi, BHP = 4641 psi Drill to 14,654'. 08:00 - 11:00 3.00 STWHIP P 11:00 - 11:30 0.50 STWHIP P 11:30 - 13:30 I 2.001 DRILL I P 13:30 - 16:30 3.00 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 17:40 0.67 DRILL P 17:40 - 19:50 2.17 DRILL P 19:50 - 20:15 0.42 DRILL P 20:15 - 21:25 1.17 DRILL P 21:25 - 00:00 2.58 DRILL P 10/13/2008 00:00 - 01:00 1.00 DRILL P 01:00 - 01:40 0.67 DRILL P 01:40 - 02:10 0.50 DRILL P 02:10 - 03:00 0.83 DRILL P 03:00 - 06:15 I 3.251 DRILL I P 06:15 - 06:30 0.50 DRILL P 06:30 - 07:00 0.50 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 09:00 1.00 DRILL P 09:00 - 10:00 1.001 DRILL ~ P Findin some stator rubber on shakers. Directional line up is adequate for switching to rib steer system. PROD2 Pull out of hole for BHA change. nl I f I min m as BHA neared surface. PROD2 Get off well. Unstab coil and set injector on floor. Inspect SLB slings for injector (3rd party) LD kickoff BHA. Bit 1-1-I PROD2 Mak - ro lateral drillino BHA with resistivity and rib der with re-run HCM bit. PROD2 Run in hole at reduced speed. Trouble shoot pump #2. PROD2 Log GR tie in from 14,090'. Subtract 25'. PROD2 Run in hole. PROD2 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'. PROD2 Wiper to window. PROD2 MAD pass from Billet to TD. Logging 200 fph over the billet had 100 psi motor work. PROD2 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'. PROD2 Wiper to window. RIH w/ pumps off over AL billet sat down 2k DHWOB, PU -4.5k DHWOB, quickly RIH and slid through. PROD2 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'. PROD2 Wiper to 14520'. PROD2 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'. PROD2 Wiper to 10,000'. 10k# CT Wt overpull at 14,700'. -6k# DHWOB overpull at 14492'. PROD2 Log tie-in from 14100'. Add 5' correction. PROD2 Remain is csg. Tighten some loose bolts inside of reel. PROD2 Run in hole back to btm. Note a few set down. Plan is for zero rate at billet and in Shublik during trips. PROD2 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'. PROD2 Wiper trip to 14300'. Reduce pump through Shublik, off past Punted: i v3izuus 11:43:U3 HM • 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 to 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. Printed: 11/3/2008 11:43:03 AM • 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'. 11:00 - 14:30 3.50 DRILL P 14:30 - 15:15 0.75 DRILL P 15:15 - 16:00 0.75 DRILL P 16:00 - 18:30 2.50 BOPSU P 18:30 - 00:00 ~ 5.50 ~ BOPSUF{ P 10/15/2008 00:00 - 00:30 0.50 BOPSU P 00:30 - 03:30 3.00 BOPSU N 03:30 - 03:45 0.25 DRILL P 03:45 - 04:45 1.00 DRILL P 04:45 - 05:15 0.50 BOPSU P 05:15 - 06:00 0.75 DRILL P 06:00 - 06:15 0.25 DRILL P 06:15 - 09:00 2.75 DRILL P 09:00 - 11:00 2.00 DRILL P 11:00 - 12:10 1.17 DRILL P 12:10 - 12:50 0.67 DRILL P 12:50 - 13:35 0.75 DRILL P 13:35 - 15:20 1.75 DRILL P 15:20 - 15:40 0.33 DRILL P 15:40 - 16:50 1.17 DRILL P 16:50 - 17:20 0.50 DRILL P 17:20 - 18:20 1.00 DRILL P 18:20 - 19:25 1.08 DRILL P Drill to 15803'. Unable to get back to btm. Discuss with directional driller ans SLB driller. PROD2 Pull out of hole for AKO motor and agitator. PROD2 LD drilling BHA. Bit was 1-4- PROD2 Jet stack w/ swizzle stick Set injector to side PROD2 Open doors on lower combi rams to check for aluminum, but found only formation debris. Change injector packoffs and check chains. 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. PROD2 Finish BOPE TEST. RREP PROD2 Reconfigure pipework on choke line from BOPE. PROD2 SAFETY MEETING covering plan to function test agitators, PT packoffs & inner reel valve, and cut coil. PROD2 Function test each agitator by MU to the CTC, stabbing onto the well, and pumping. PROD2 PT packoffs and inner reel valve. PROD2 Cut coil. PROD2 Crew change/safety mtg PROD2 Pump slack back. Cut and dispose of 900' of CT and wire PROD2 Install CTC. PT 40k, 3500 psi Install BHI UOC PROD2 MU BHA while pump slack forward 1.65/1900 IA 60, OA 185 PROD2 RIH w/ BHA #9 (bi bit, 0.8 deg motor, agitator) circ thru bit 0.62/1350 PROD2 Park at 3400' to replace sheared reel drive plate bolt and for SWS crew change PROD2 Resume RIH IA 353, OA 195 PROD2 Log tie-in down from 14100', corr -24.5' IA 267, OA 193 PVT 279 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 PROD2 Set down at 15265' and had overpull. Ream back thru and clean up shale area IA 487, OA 200, PVT 273 PROD2 Resume wiper to TD at 5-15'/min. No problem thru 15320-60'.- Agitator is affecting res tool 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. Printed: 11/3/2008 11:43:03 AM 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 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 L/D & PU BHA. 23:30 - 00:00 0.50 DRILL N DFAL PROD2 Stand back injector, BO mtr & agitator, blow down BHA. 10/16/2008 00:00 - 02:00 2.00 DRILL N DFAL PROD2 UD Lateral BHA #2. PU Lateral BHA #3 with new CoilTrak tools same motor, & 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 1.501 DRILL N DFAL PROD2 08:00 - 08:50 0.831 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 2.42 DRILL P PROD2 15:45 - 16:00 0.25 DRILL P PROD2 16:00 - 17:15 1.25 DRILL P PROD2 17:15 - 20:50 3.581 DRILL ~ P ~ ~ PROD2 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 tubs. PU's ~ 42.6k, SO's at 15.8k are clean w/fresh mud in OH. Nrmted: i v3izuus 11:4J:U3 HM • 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 10/16/2008 17:15 - 20:50 3.58 DRILL P 20:50 - 23:10 I 2.331 DRILL I C Start: 10/1 /2008 Rig Release: 10/21/2008 Rig Number: Page 15 of 18 ~ Spud Date: 6/14/1981 End: 10/21/2008 Phase Description of Operations PROD2 PROD2 23:10 - 23:25 0.25 DRILL C PROD2 23:25 - 00:00 0.58 DRILL X STUC PROD2 10/17/2008 100:00 - 03:15 3.251 DRILL X STUC PROD2 03:15 - 06:30 3.251 DRILL C PROD2 06:30 - 07:50 I 1.331 DRILL I C I I PROD2 07:50 - 08:15 0.42 DRILL C PROD2 08:15 - 09:05 0.83 DRILL C PROD2 09:05 - 10:00 I 0.921 DRILL I C I I PROD2 10:00 - 10:20 I 0.331 DRILL I C I I PROD2 10:20 - 11:15 0.921 DRILL X DFAL PROD2 11:15 - 11:30 I 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 2.831 DRILL X DFAL PROD2 15:00 - 16:00 1.00 DRILL X DFAL PROD2 16:00 - 16:15 I 0.251 DRILL I X I DFAL I 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'. Wiper 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. J 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 ofd diff sticking. PU 72k and came free, but were losing 0.2 bpm. Wiper 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 Printed: 11/3/2008 11:43:03 AM 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 116:15 - 18:45 2.501 DRILL X DFAL PROD2 ~ PT N2 ~ 3000. Pump 15 bbls FW to reel followed by N2 18:45 - 19:00. 0.251 DRILL X DFAL PROD2 19:00 - 22:20 3.331 DRILL X DFAL PROD2 22:20 - 22:30 0.17 DRILL X DFAL PROD2 22:30 - 00:00 1.50 DRILL X DFAL PROD2 10/18/2008 100:00 - 01:45 1.751 DRILL X DFAL PROD2 01:45 - 02:00 0.25 DRILL X DFAL PROD2 02:00 - 06:00 4.00 DRILL X DFAL PROD2 06:00 - 08:15 I 2.251 DRILL I X 08:15 - 10:00 1.75 DRILL X 10:00 - 11:00 1.00 DRILL X 11:00 - 13:10 2.17 DRILL X 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 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Take all returns to tiger tank until bleed off was complete Safety Meeting discussing procedures and hazards to pull the coil across and secure to the reel. 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. Safety Meeting--lowering of the reel and PU of new reel. Lower reel w/ pin hole and PU replacement reel. RU reel hardline. RU reel hardline, J box installation, RU reel plates, and install grapple. Safety Meeting re: pulling coil across. Pull coil across, fluid pack coil, PT hardline, PT inner reel valve, Slack management. RU hyd cutter and cut off 368' CT w/o finding wire. Pump slack forward over bung hole to find wire MU CTC. PT 40k, 3500 psi. Install BHI UOC Open swab. Fill hole w/ 20 bbls mud MU drilling BHA while pump slack forward and displace FW in CT to mud RIH w/ BHA # while circ thru bit 0.52/1340 Log tie-in down from 14075', corr -24' 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) 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 ~ PROD2 POH for liner replacing voidage and leaving beads in tubing. PROD2 Tag up. Flowcheck. SAFETY MEETING re: L/D BHA PROD2 Standback Injector. BO motor & agitator. Slowdown Coiltrak. L/D 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 ft/min 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 rnmea: ~ u~izuuu i rvsv~ Hm • M 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 KWT drill-discuss 08:15 - 10:30 2.25 CASE X RUNPRD Finish POOH w/liner filliin from BS 10:30 - 11:45 1.25 CASE X RUNPRD Set injector on legs. LD 3 its 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/ 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 tir t t 43k 14:40 - 15:05 0.42 CASE C RUNPRD PUH to tie-in spot. Log down from 15720', Corr -25' Corrected BOL C~ 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, VD 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 LOWERI 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 hooke 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. 03:40 - 04:30 0.83 FISH P LOWERI L/D whipstock & retrieval tools, L/D 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 ~ 3500 psi. IA 250, OA 178 Printed: 11/3/2008 11:43:03 AM • 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 ~ 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 1.82/1250 and take returns 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 09:00 - 11:50 2.83 WHSUR P 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' 11:50 - 12:15 0.42 WHSUR P POST Close swab w/ whp=0, IA=75, OA=215 Jet stack. Set injector back and remove nozzle w/ stinger 12:15 - 13:00 0.75 WHSUR P POST WO DSM valve crew MI SWS N2 13:00 - 13:10 0.17 WHSUR P POST Safety mtg re: set BPV 13:10 - 14:20 17 1 WHSUR P POST Bring nSM lubricator to floor. Set 4" CIW 13PV. Tubingjs on . sli vac while equalizing w/ IA=30 SI MV and SV. RDMO DSM 14:20 - 14:30 0.17 WHSUR P POST Safety mtg re: pickle/blowdown reel 14:30 - 17:45 3.25 WHSUR P 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 17:45 - 18:40 0.92 WHSUR P POST Cut off CTC and install internal grapple. Crew change. Pull test then retighten set screws. 18:40 - 18:50 0.17 WHSUR P POST SAFETY MEETING re: pulling coil across. 18:50 - 20:30 1.67 WHSUR P POST Pull coil across and secure to the reel. C/O annular preventer element on BOPE. 20:30 - 20:40 0.17 WHSUR P POST SAFETY MEETING re: reel swap 20:40 - 22:00 1.33 WHSUR P POST Swap reels. Continue working on annular preventer element. 22:00 - 00:00 2.00 WHSUR P POST Finish C/O of annular preventer. ND BOPE. Clean & unwrap new reel, Install grapple in CT. 10/21/2008 00:00 - 02:00 2.00 WHSUR P POST GBR welders cut inner reel ramp on new reel to be able to RU hardline. Install tree cap. PT to 4000psi RDMO RELEA 02:0010/21/08 TOTAL TIME FROM ACCEPT TO RELEASE: 17 DAYS, 15.5 HOURS rnntea: nisizuuu 11:4J:W HM • }. ~'~ ;. ~ BP Alaska gHU~~s ~'~ ~~` Baker Hughes INTEQ Survey Report t~~ LQ Comp:uiy: BP Amoco Hield: Prudhoe Fav U>~tc: 10/31'~Q08 (~~-urdinate([SI~) kcti~rcncc: Cinu•~ 13224) P:~~;c: l Nell. Y-09 True North Site: PrJ '~~ Pad ~~~ell: ~l-0'~ ~~r~nical (TVD}Retcrcucc: ticciion(VS)Refercucc: Y-05.4IAPE,1 37.7 `Nell i0.00N.0.00E 1-~ 56P,zi1 ~~rll~iaih: 'r-09AL1 tiurveyCalcula~imi ~lcihuil: h4inimum Curvature Uh: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB 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 Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg We1~09 Slot Name: Y-09 ~ I Well Position: +N/-S 384.41 ft Northing: 5948866.44 ft Latitude: 70 16 3.816 N I +E/-W -3023.88 ft Easting : 644718.12 Position Uncertainty: 0.00 ft ft Longitude: 148 49 47.008 W Wellpath: Y-09AL1 Drilled From: Y-09A 500292057960 Tie-on Depth: 14283.21 ft Current Datum: Y-09A/APB1 Height 87.72 ft Above System Datum: Mean Sea Level Magnetic Data: 10/2/2008 Declination: 22.95 deg Field Strength: 57674 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 0.00 172.56 Survey Program for Definitive Wellpath Date: 10/2/2008 Validated: Yes Version: 9 Actual From To Survey Toolcode Tool Name ft ft 100.72 9200.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sp erry-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 15621.00 MWD (14292.00-15621.00) MWD MWD -Standard Annotation ___ _ __ SID TVD ft ft __ __ __ __ 14283.21 9052.47 TIP 14292.00 9051.85 KOP 15621.00 9047.36 TD Survey: MWD Start Date: 10/8/2008 Company: Baker Hughes INTEQ Engineer: ~ Tool: MWD;MWD -Standard Tied-to: From: MWD I auk-/2~ '/ryt `:., BP Alaska BN~G~S "`_ r, Baker Hughes INTEQ Survey Report m~r~a~ ('umpany: BP Amoco Uate . 10~31 12Q08 Tina. 13:22-49 I'a_c : 2 i'ieltl: Prudhoe Eey Co-< n~~lina~clAI'1 Reference: PJell: Y-09 T rue North ti'lic: PB Y Pad ~'enc ~al ill'll) Reference: Y-09A/APG 1 57.7 ~~cll: Y-09 Secti on (~~) Reference: Well (O.OOfV Q00E1 72.5 6F+zi1 \~cll~~aUi: Y-0 6iiC1 Sun~ ey Calcul atinu ~lcthod: Miniininr~ Cu rvature DV: Orac(e `un cc ~~1D Incl Azim 11~U tip. I~lr A ti ~~ 1:/1'~ D1apA ~1;i01: ~S DLS Tuol ft deg deg It tt it ft ft it It deg/100ft 14283.21 94.03 184.66 9052.47 8964.75 -8149.56 33.72 __ 5940719.66 644908.50 __ 8085.34 0.00 MWD 14292.00 94.03 185.58 9051.85 8964.13 -8158.29 32.94 5940710.91 644907.88 8093.90 10.44 MWD 14368.47 95.04 175.44 9045.79 8958.07 -8234.42 32.26 5940634.79 644908.67 8169.29 13.28 MWD 14401.59 95.53 171.24 9042.74 8955.02 -8267.16 36.08 5940602.13 644913.12 8202.26 12.71 MWD 14427.89 95.20 164.32 9040.28 8952.56 -8292.74 41.62 5940576.66 644919.15 8228.34 26.23 MWD 14471.98 94.00 155.01 9036.73 8949.01 -8333.90 56.88 5940535.81 644935.19 8271.13 21.22 MWD 14506.02 93.41 146.79 9034.53 8946.81 -8363.56 73.38 5940506.48 644952.26 8302.67 24.16 MWD 14545.61 94.15 140.75 9031.92 8944.20 -8395.41 96.72 5940475.08 644976.21 8337.28 15.34 MWD 14576.67 94.70 134.62 9029.52 8941.80 -8418.30 117.56 5940452.60 644997.48 8362.67 19.76 MWD 14609.33 94.09 127.80 9027.01 8939.29 -8439.74 142.04 5940431.64 645022.37 8387.10 20.90 MWD 14636.52 93.28 123.73 9025.26 8937.54 -8455.59 164.05 5940416.21 645044.68 8405.67 15.23 MWD 14671.06 89.63 118.55 9024.39 8936.67 -8473.44 193.59 5940398.94 645074.55 8427.19 18.34 MWD 14700.01 89.69 112.01 9024.56 8936.84 -8485.79 219.76 5940387.09 645100.95 8442.83 22.59 MWD 14737.77 87.82 105.26 9025.38 8937.66 -8497.85 255.50 5940375.72 645136.92 8459.41 18.54 MWD 14768.75 87.88 99.61 9026.54 8938.82 -8504.51 285.72 5940369.64 645167.26 8469.93 18.23 MWD I 14817.04 87.48 91.16 9028.50 8940.78 -8509.04 333.72 5940366.04 645215.33 8480.63 17.50 MWD 14849.10 86.75 85.23 9030.12 8942.40 -8508.03 365.71 5940367.66 645247.29 8483.77 18.61 MWD 14876.12 85.85 81.37 9031.86 8944.14 -8504.88 392.48 5940371.32 645273.99 8484.12 14.64 MWD 14908.61 85.05 75.96 9034.44 8946.72 -8498.52 424.22 5940378.29 645305.61 8481.92 16.78 MWD 14951.33 84.12 70.45 9038.47 8950.75 -8486.24 464.92 5940391.35 645346.06 8475.01 13.02 MWD 14984.14 83.02 65.82 9042.15 8954.43 -8474.10 495.17 5940404.07 645376.07 8466.89 14.42 MWD 15015.71 83.17 63.23 9045.95 8958.23 -8460.62 523.47 5940418.09 645404.09 8457.19 8.16 MWD 15051.39 82.41 63.26 9050.42 8962.70 -8444.69 555.07 5940434.63 645435.39 8445.48 2.13 MWD 15082.82 82.03 63.28 9054.68 8966.96 -8430.68 582.89 5940449.16 645462.92 8435.19 1.21 MWD 15112.28 81.46 63.41 9058.91 8971.19 -8417.60 608.94 5940462.74 645488.72 8425.60 1.98 MWD 15143.96 83.70 63.19 9063.00 8975.28 -8403.49 637.01 5940477.39 645516.51 8415.24 7.10 MWD 15174.10 87.21 63.40 9065.39 8977.67 -8389.99 663.84 5940491.40 645543.08 8405.32 11.67 MWD 15208.81 89.26 64.21 9066.46 8978.74 -8374.67 694.97 5940507.31 645573.90 8394.17 6.35 MWD 15265.14 92.36 64.95 9065.66 8977.94 -8350.50 745.83 5940532.46 645624.29 8376.78 5.66 MWD 15297.66 93.88 64.44 9063.89 8976.17 -8336.62 775.19 5940546.90 645653.37 8366.82 4.93 MWD 15333.24 94.15 64.26 9061.40 8973.68 -8321.26 807.18 5940562.87 645685.06 8355.73 0.91 MWD 15357.59 93.90 65.80 9059.69 8971.97 -8311.00 829.20 5940573.55 645706.88 8348.41 6.39 MWD 15390.85 93.69 65.62 9057.49 8969.77 -8297.35 859.45 5940587.78 645736.86 8338.79 0.83 MWD 15429.91 93.14 68.58 9055.16 8967.44 -8282.18 895.37 5940603.63 645772.47 8328.40 7.69 MWD 15458.82 92.89 66.97 9053.64 8965.92 -8271.26 922.09 5940615.06 645798.98 8321.03 5.63 MWD 15486.86 92.52 67.38 9052.32 8964.60 -8260.40 947.91 5940626.42 645824.57 8313.60 1.97 MWD 15529.07 91.69 68.03 9050.77 8963.05 -8244.39 986.93 5940643.17 645863.28 8302.78 2.50 MWD 15570.02 92.25 67.36 9049.36 8961.64 -8228.86 1024.80 5940659.43 645900.84 8292.28 2.13 MWD 15621.00 92.25 67.36 9047.36 8959.64 -8209.25 1071.81 5940679.93 645947.47 8278.93 0.00 MWD ~ CTUA TOR= :B. ELEV = BAKER 87.77 3F. ELEV = 51.65' :OP = 3200' Aax Angle = 100 @ 14472' Yatum MD = )alum TV D = 1057T 8800' SS JHrCI T IVV 1 GJ: ~09A L 1 / L 1-01 DRLG DRAFT 113-318" CSG, 72#, L-80, ~ = 12.347" I Minimum ID = 2.37" ~ 14321' AL1-01 Liner Deployment Sub x-5/8" X 7" BKR ZXP PKR w /TIEBACK, ID = 6.375" X 7" BKR HMC LNR HGR, ID = 6.250" Y-09 141/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10469' 7"X5-112" BKR ZXP PKR W/ TIEBACK, ~ = 5.250" 10479' 5-1 /2" LNR, 17#, L-80, .0232 bpf, b = 4.892" 10500' 7" LNR, 29#, L-80, BTC, 0.371 bpf, ID = 6.184" 10642' PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 91 @ 11030' Note: Refer to Production DB for historical data SQE SPF INTERVAL OpNSgz DATE SEE PAGE 2 FOR PERF BREAKDOWN I Top of Window ,Orientation 20 LHS - 14292' op of 2-7; 8" STL, 5.16 ppf, L-80 Slotted LNR, ID = 2.441 14321 Bottom of Watdow Y-09A I 4112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" ~ 41/2" HES HXO SSSV N~, ID = 3.813" ~ GAS L~TMANDRELS 5T MD TVD DEV TYPE VLV LATCH PORT DATE 6 2996 2996 6 KBL-2LS DOME YJT 16 04/05/07 5 5329 4971 46 KBL-2LS DOME WT 16 04!05/07 4 7120 6222 43 KBL-2LS oOAAE INT 16 04/05/07 3 8550 7361 29 KBL-2LS DOME WT 16 04/05/07 2 9239 7975 29 KBL-2LS SO NVT 22 04/05/07 1 10254 8663 48 KBL-2LS °DM BJT 0 03/03/07 'S T#1 HAS TBG PATCH ACROSS DMY 9-518" M~LOUT WINDOW (Y-09Ay 9207 - 9218' 10402' - ~ 4112" HES X N~, ~ = 3.813" I 10413' 7" X 41 /2" BKR S-3 PKR, ID = 3.875" 104$6' 41 /2" HES X N~, ~ = 3.813" 10457' 4112" HES XN NIP, Nflled to ID = 3.80" 4-112" WLEG, ID = 3.958" ELMD TT LOGGED 07/28/97 5-112" X 41/2" XO, ~ = 3.958" 14499' ' ~ Top of Aluminum Billet ~ y \ 2-7/8" STL, 6.16 ppf, L-80 Sbtted LNR, ID = 2.441 ~\ = - _ _ _ _ _ _ __ -09A L ~~ ~ \~~ ~ ~~ ~ 15982 2-7/8" STL, 6.16 ppf, L-80 \~ ~ Sbtted LNR, ID = 2.441" \~~ ~~ ~ \~~ ~~ ~ Y-09A L1-01 DATE REV BY COMMENTS DATE REV BY COMuENTS 07/04/81 ORIGINAL COMPLETION 07/15/97 CHH SIDETRACK COMPLETION 07/04/01 CWKAK CORRECTIONS 03/23/07 RRD/TLH 4112" STRADDLE PATCH SET 10!20108 NOROIC2 CTD MULTI-LAT6tAL (Y-09AL1-L1-01) 10/30/08 TLH CORRECTIONS PRUDHOE BAY UNIT WELL: Y-09AL1 ! Y-09AL1-0 PERMIT No: 208127012081280 API No: 50-029-20579-60 / 61 SEC 33, T11 N, R13~ 138T SNL & 98' WEL BP Exoloration IAlaskat Y-09A PERFS PERFORATION suMMARY REF LOG: TCP PERF A NGLE AT TOP PERF: 75 @ 10850' Note: Refer to Production tag for historical pert data SQE SPF OVAL Opn/Sqz QATE 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 -1 t 250 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 05/14/02 2-314" 4 11850 - 11980 O 07/13/97 2-7/8" 4 12000 - 12100 O OSH 4/02 2-3/4" 4 12260 - 12390 O 07113/97 2-3/4" 4 12500 - 12550 O 07!13/97 2-7/8" 4 12550 - 12650 O 05/14/02 2a/6" a 12670 - t 27so 0 os/14ro2 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 2-3/4" 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 07104/01 CH/KAK CORRECTIONS 03/23/07 RRD/TLH 4-112" STRADDLE PATCH SET 10/20!08 NORDIC2 CTDMULTI-IATERAL(Y-09AL1-L1-01) 1 1 f1/3(1/f1R I TI H I (;(1RRFCTICINS PRUDHOE BAY UNff WELL: Y-09AL1 / Y-09AL1-C PERMIT No: 2081270 / 2081280 API No: 50-029-20579-60 / 61 SEC 33, T11 N, R13E, 1387' SNL & 98' WEL RP Firnlnrafinn /Olackal ~!~ BAKER MUG1~S ~FJ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: November 14, 2008 `Please find enclosed directional survey data for the following wells: N-14BPB 1 N-14B 01-21A Y-09AL1 'r Y-09AL1-Ol Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ~ ~ ,State of Alaska AOGCC DATE: ~ ~` ~ Cc: State of Alaska, AOGCC ~ ~ - 1 ~1,~ • ~ I ~ ~ ¢ ~. ~`~ c COI~TSERY~ ATIO COl-~IISSIQl` Greg Sarber CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE {907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Y-09AL1 BP Exploration Alaska, Inc. Permit No: 208-127 Surface Location: 1387' FNL, 98' FEL, SEC. 33, T11N, R13E, UM Bottomhole Location: 4416' FNL, 996' FWL, SEC. 03, 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). Sincerel Danie . Seamount, Jr. Chair DATED this ,L day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. h ~ ~, ~, f' . ~ .~ ~~j STATE OF ALASKA 1 ,~ ~ ° °°• - ~ $ °'' '~° ` ~~ ~~~~ ALASN~IL AND GAS CONSERVATION COMMI N g--~ ~ I.p, ~, ,. ~, PERMIT TO DRILL C~ `~`~"`~ `~ ~ 2GJ8 20 AAC 25.005 ~ _ ~ :r,.., 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed fa{: ^Coalbed Methart2' ^ GasiWydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU Y- 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15,675' TVD 8,946'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1 387' FNL 98' FEL SEC 33 T11N R13E UM 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: 4,416' FNL, 996' FWL, SEC. 03, T10N, R13E, UM 9. Acres in Property: 2,560 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: 14,400 feet Maximum Hole An le: 97 de reel 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3,142 Surface: 2,262 18. Casin Pro ram: S cifioations To - Settin De th -Bo ttom uanti 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 1 175' 14 500' 8940'ss 15 675' 8946'ss Uncemented Slotted Liner 19. PRESE NT WELL CONDITION 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' 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 reg Sarb Title CT Drilling Engineer o Prepared By NamelNumber: Si nature ~` ~ ~ ~ 8 Phone 564-4330 Date b ~ 3 `v 4 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: O / ~ API Number: 50-029-20579-60-00 Permit Approval 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 methane, gas hydrates, or gas contained shales: ,~ Samples Req'd: ^ Yes ~lo Mud Log Req'd: ^ Yes t~ No ~p~, HZS Measures: t~Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~S~V'~-~~5~ ~Q ` .,~ ~.~ APPROVED BY THE COMMISSION Date ,COMMISSIONER 1~ 1~ L Form 10-401 Revised'12/2005 W Submit In Duplicate ~ ~ 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 ~/z" 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 2"d 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 lines 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) 1. MIRU Nordic Rig 2 ~~ 2. NU 7-1/16" CT Drilling BOPE and test. 1 1 ~ 1S ~ilN1 3. Pull BPV. 4. Mill 3.80" window at 14,400'. 5. Drill build/turn/lateral section of Li with 3.75" x 4.125" bicenter bit, and drill L1 lateral to 15,675'. 6. Run a 2-7/8" L-80 slotted liner strin with an aluminum de to ment sleeve to at 14,500'. 7. i the L1 lateral off of the deployment sleeve whipstoc at 14,500 wit a it. 8. Drill build/turn/latera 1-01 with 3.75" x 4.125" bicenter bit, and drill Li -01 lateral to 16,015'. 9. Run a 2-7/8" L-80 slotted liner string w e loyment 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. 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 casing/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-80 12.6#, Burst 8430, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle 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-146 from heel of Y-09A) . ~o99~^g • 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 wilt 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 Stewman/Terrie Hubble .- TREE= 4-1/16" CAMEPoON itv = i.EV = Datum MD = 1057T Datum TV D = 8800' SS SAFET OTES: OLD PSA'0 WELLBORE NOT Y-O9A SHOWN ON THIS DIAGRAM BELOW THE9-518" CSG WINDOW. WELL EXCEEDS 70° C~ 10854' 8 GOES HORIZONTAL (i~ 10950'. 2160' 4112" HES HX3 SSSV NP, A) = 3.813" 13-318" CSG, 72#, L-80, O = 12.34T H 2686' ~ Minimum ID = 2.31" @ 10457' 2-718" NIPPLE REDUCER 14112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.858' 7" X S 112' BKR ZXP FKR Wl TEBACK, ID = 5.250" S 112" LNR 17#, L-80, .0232 bpi, ID = 4.892" PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 9t Q 11030' Note: Refer to Production DB for historical perfdata A 2 FOR PERF BREAKDOW N 7" LNR 29#, L-80, .0371 bpf, D = 6.184" H 1 CAS L ET MANt]RELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 2998 2996 6 KBL-2LS DOME O+fi 16 06/02/08 5 5329 4971 46 KBL-2LS DOME MlT 16 06/02/08 4 7120 6222 43 KBL-2LS DOME If•R i6 06/02/08 3 8550 7361 29 KBL-2LS DOME INT 16 06/02/08 2 9239 7975 29 KBL-2LS S/0 AYT 22 06/02/08 1 10254 8663 48 KBL-2LS '"OMY INT 0 03/03!07 "5 T#'1 HA 3 TBG PATC H ACR03 3 DRAY W1EXT P KG 9030' p--195/8'X7' BKR Z~' PKR W/ TIEBACK, D = 6.3 10240'-10275' I--)4112" KB STRADDLEPATCH, D = 2.45' I 10402' 41/2" HES X NIP, ~ = 3.813" 10413' 7" X4112" BKR S-3 PKR ID = 3.875' 10436' 4112' HES XNIP, D = 3.813" 10457' -4717' HES MJ NIP, ID = 3.725" 10457' 2.313" NPPLE REDUCER (03104/07) 10469' 41/7' WLEG, ID = 3.958" 10473' ELMD TT LOGGED 07!28197 10500' 51/2' X 4112' XD, O = 3.958" 95/S MA-LOUT W AVDOW 9207 -9218' .0371 twf. ID = 6.184' I PBTD 1 41/2" LNR 12.6#, L-80, .0152 bpf, ~=3.953" I d1TE REV BY COMMENTS DATE REV BY C,OMM6JTS 07/04181 ORIGINAL COMPLEfKNd 09124/07 kCT/PJC MN D CORf~CTION 07115197 CHH SIDETRACK COMPLETION 0.5124108 SWGSV GLV GO (05/16108) 07/04101 CHIKAK CORRECfgNS 06!06!08 KSBRD GLV GO (06/02/08} 05/14102 JAFlTLH ADD P62FS 03/23/07 RRD/iLH 41/2° STRADDLE FATCH SET 04/07!07 CJNIPAG GLV GO /PILL PLUG (04/05/07) Ff2UCHOE BAY UNIT WELL: Y-09A F$2MfT No: x1970830 API No: 50-029-2(1579-01 SEC 33, Ti t N, R13E 138T SNL 8 98' WEL BP Exploration (Alaska) Y-09A PERFS PERFORATION SUMu9ARY REF LOG: TCP P@2F ANGLE AT TOP PERF: 75 (c~ 10850' Note: Refer to Prod~tion DB for historical perf data SQE SPF NTERVAL OpnlSgz DATE 2-7/8" 4 10650 - 11000 O 05/14102 2-3I4" 4 11030 - 17060 O 07/13197 2-3/4" 4 11120 - 11160 O 07/13197 2-314" 4 11190 -11250 O 07/13!97 2-3/4" 4 11540 - 11560 O 07/13197 2-3/4" 4 11fi10 - 71740 O 07/13197 2-718" 4 17750 - 11800 O 05/14/02 2-314" 4 11850 -11960 O 07/13/97 2-7/8" 4 12000 - 12100 O 05N4/02 2-3/4" 4 12280 - 12390 O 07/137 2-314" 4 12500 - 12550 O 07/13/97 2-718" 4 12550 - 12650 O 05/14102 2-718" 4 12670 - 12760 O 05/14/02 2-3l4" 4 14460 -14540 O 07/13/97 2-314" 4 14830 -15000 O 07/13197 2-314" 4 15100- 15150 O 07113!97 2-3/4" 4 15170 -15280 O 07/13197 2-314" 4 15330 - 15360 O 07/13/97 2-314" 4 15840 - 15690 O 07/13/97 2-314" 4 15770 - 15900 O 07/13/97 DATE REV BY ODMuHdTS DOTE REV BY COMuB~fTS 07/04/87 atiGINAL COMPLETION 09/24107 RCf/P.K; MN D CORRECTION 07/15/97 CFli SIDETRACK COMPLETION 05/24/08 SWGSV GLV C/O (05116/08) 07/04/01 CI-VICAK CORRECTIONS 05/14!02 JAFfIIH ADD FERFS 03/23/07 RRD/TLH 4-1/2" STRADDLE PATCH SEf 04!07/07 CJNIPAG GLV C/O8 PILL PLUG (04105107) PRUDHDEBAY UNR WELL: Y-09A PERMf No: 1970830 API No: 50-029-20579-01 T11 N. R13E 1387' SNL 898' WEL BP 6cploratlon (Alaska) 4-1/18" CAMERON Y- - ~0 09AL 1 & Y 09AL 1 Proposed CTD Laterals 14-1/2" HES HXO SSSV NP. D = 3.813' I 113-318' CSG, 721, L-B0, D = 12.347" H Minimum ID = 2.31" Q 10457 2-7/8" NIPPLE REDUCER X 7" BKR ZXP PKR w! TIEBACK, D = 6.375" 9-518" X 7" BKR HMC LNR HGR D = 6.250" Y-09 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DOTE 6 2996 2996 6 KBL-2LS DOME NIT 16 04ro5ro7 5329 4971 46 KBL-2LS DOME NIT 16 04ro5ro7 4 7120 6222 43 KBL-2LS DOME NR 18 04ro5ro7 3 8550 7381 29 KBL-2LS DOME NR 16 04ro5ro7 2 9239 7975 29 KBL-2LS SO N1T 22 04/05/07 1 10254 8683 48 KBL-2LS '-DMY NR 0 03ro3ro7 ~ST/'1 I1AS TBLi PA I GM A(:NCRi3 UN T 9-3/8" MLLOIJT WNOOVIf (Y-09A) 9202' -9218' 10240'-10175' 4-112" KB STRADDLEPATCH, D = 2 to be pulled and re-run 10402' 4-112" FIES X NP, D= 3.813" 10413' 7" X 4-112" BKR S-3 PKR D = 3.875" XNP,D=3.81; XNNP,D=3.7: a a?crv rFa n = 4-112" TBG, 12.611, L-80, .0152 bpf, D = 3.958" H 10469' 5-112' BKR ZXP PKR W/ TEBACK. D = 5.250" 10479' 5-112" LNR, 17s, L-80, .0232 bpf, D = 4.892" 10500' " LNR 29M, L-80, BTC, 0.371 bpf, D = 6.184" 10642' 14,420' Top of Slotted Liner PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 91 ~ 11030' Note: Refer to Production DB far historical pert data SIZE SPF INTERVAL OpNSgz DATE SEE PAGE 2 FOR PERF BREAKDOWN w I 10457' I 10500' N 5-1/2" X 4-1/2" XO, D = 3.958" 4,500' Top of OH Deployment sleeve/whipstock ~ ~\ - -- - -- --I -09AL1 ~~ ~ - - ~~~ ~~ ~ ~~~ 2-718" sbtted liner 16015' ~\ \~ \~ ~ \~ ~ ~~ Y-09A L1-01 41/2" LNR 12.611, L-80, .0152 bpf, D = 3.953" DATE REV BY CONNB~(TS DATE REV BY CONVENTS 07!04/81 ORIGINAL COMPLETION 03/04!07 DRF/TLH GLV C!O (1!30/07) 07N5197 CHH SIDEfRACKCOMPLETION 03/06!07 JLJ/TLH GLV C10 07!04!01 CWKAK CORRECTIONS 03/23/07 RRD'TLH 4-1/2" STRADDLE PATCH SET 05J14/02 JAF/TLH ADD PERFS 04107!07 CJWPAG GLV C!O 8 PULL PLUG (04!05107) 07/04/06 DTWPAG GLV GO (06129/06) 09124/07 RCTIPJC MIN DCORRECTION 10/01106 WTS/PA GLV C!O 04/30/08 MSE PROPDSED CTD LATERALS PRUDFIOE BAY UNT IMELL: Y-09A L1 & L1-01 PERMR No: AR No: 50-029-20579-01 711 rl R13E, 1387' SNL 898' WEL ~ 6rpbrstion (Alaska) b ~ BP Alaska P Baker Hughes INTEQ Planning Report °,'~ Company: BP Amoco Date: 6!13(2008 Time: 16:55:41 Page: 1 Field: Prudhoe Bay Comrdinate(NE) Reference: Well: Y-09, True North Site: PB Y Pad Vertical (TVD) Reference: 13:09 5/30!1997 00:00 88.2 it Well: Wellpath: Y-09 Plan 3, -Y~;l=• ~-- 0 !/~ ~, 1 "` Q , Section (VS) Reference: Snrvey Calculation Method: Well (O.OON,O.OOE,150.OOAzi) Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB 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 Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-09 Slot Name: 09 Y-09 Well Position: +N/-S 385.90 ft Northing: 5948867.93 ft Latitude: 70 16 3.830 N +FJ-W -3024.21 ft Easting : 644717.76 ft Longitude: 148 49 47.018 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, Y-09AL2 Drilled From: Y-09A 500292057961 Tie-on Depth: 14377.26 ft Current Datum: 13:09 5/30/1 997 00:00 Height 88.20 ft Above System Datum: Mean Sea Level Magnetic Data: 6/10/2008 Declination: 23.13 deg Field Strength: 57667 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 39.20 0.00 0.00 150.00 Plan: Plan 3 Date Composed: 6/10/2008 copy Mary's Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft Y-09AL2 Polygon 88.20 -8344.34 220.91 5940530.01 645099.02 70 14 41.764 N 148 49 40.595 W -Polygon 1 88.20 -8344.34 220.91 5940530.01 645099.02 70 14 41.764 N 148 49 40.595 W -Polygon 2 88.20 -8507.13 -104.30 5940361.01 644777.02 70 14 40.163 N 148 49 50.050 W -Polygon 3 88.20 -8998.44 113.31 5939874.01 645004.02 70 14 35.331 N 148 49 43.723 W -Polygon 4 88.20 -9509.75 330.53 5939367.01 645231.02 70 14 30.302 N 148 49 37.409 W -Polygon 5 88.20 -10017.45 567.84 5938864.01 645478.02 70 14 25.309 N 148 49 30.511 W -Polygon 6 88.20 -10721.29 966.41 5938168.01 645890.02 70 14 18.386 N 148 49 18.928 W -Polygon 7 88.20 -10734.54 1395.27 5938163.01 646319.02 70 14 18.255 N 148 49 6.463 W -Polygon 8 88.20 -9946.51 936.30 5938942.01 645845.02 70 14 26.006 N 148 49 19.800 W -Polygon 9 88.20 -9317.39 626.31 5939565.01 645523.02 70 14 32.194 N 148 49 28.810 W -Polygon 10 88.20 -8909.88 449.10 5939969.01 645338.02 70 14 36.202 N 148 49 33.961 W Y-09AL1 Fault 1 88.20 -13211.07 15696.39 5935962.05 660664.01 70 13 53.740 N 148 42 10.941 W -Polygon 1 88.20 -13211.07 15696.39 5935962.05 660664.01 70 13 53.740 N 148 42 10.941 W -Polygon 2 88.20 , -13723.67 15876.58 5935453.05 660854.01 70 13 48.695 N 148 42 5.736 W Y-09AL1 Fault A 88.20 -13077.86 15790.97 5936097.05 660756.01 70 13 55.048 N 148 42 8.184 W -Polygon 1 88.20 -13077.86 15790.97 5936097.05 660756.01 70 13 55.048 N 148 42 8.184 W -Polygon 2 88.20 -12929.70 16513.01 5936259.05 661475.01 70 13 56.490 N 148 41 47.195 W -Polygon 3 88.20 -12541.85 17306.67 5936662.05 662261.01 70 14 0.287 N 148 41 24.108 W Y-09AL2 Target 3 9022.20 -9430.20 511.11 5939450.01 645410.02 70 14 31.084 N 148 49 32.159 W Y-09AL2 Target 1 9028.20 -8693.36 165.19 5940180.01 645050.02 70 14 38.331 N 148 49 42.215 W Y-09AL2 Target 2 9053.20 -9016.21 309.02 5939860.01 645200.02 70 14 35.156 N 148 49 38.034 W - b ~ BP Alaska P Baker Hughes INTEQ Planning Report llYTEQ Company: BP Amoco Date: 6/13/2008 Time: 16:53:35 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-09, True North Site: PB Y Pad Vertical (TVD) Reference: 13:09 5/30/1997 00:00 88.2 WeII: Y-09 Section (VS) Reference: Well (O.OON,O.OOE,SO.OOAzi) Wellpath: Plan 2, Y-09AL1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB 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 Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-09 Slot Name: 09 Y-09 Well Position: +N/-S 385.90 ft Northing: 5948867.93 ft Latitude: 70 16 3.830 N +E/-W -3024.21 ft Easting : 644717.76 ft Longitude: 148 49 47.018 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, Y-09AL1 Drilled From: Y-09A 500292057960 Tie-on Depth: 14377.26 ft Current Datum: 13:09 5/30/1997 00:00 Height 88.20 ft Above System Datum: Mean Sea Level Magnetic Data: 6/10/2008 Declination: 23.13 deg Field Strength: 57667 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 39.20 0.00 0.00 80.00 Plan: Plan 2 Date Composed: 6/10/2008 Copy Mary's Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Name Description Dip. Dir. TVD ft +N/-S ft +E!-W ft Map Northing ft Map Easting ft <---- Latitude ----> Deg Min Sec <--- Longitude ---> Deg Min Sec Y-09AL1 Fault 1 88.20 -13211.07 15696.39 5935962.05 660664.01 70 13 53.740 N 148 42 10.941 W -Polygon 1 88.20 -13211.07 15696.39 5935962.05 660664.01 70 13 53.740 N 148 42 10.941 W -Polygon 2 88.20 -13723.67 15876.58 5935453.05 660854.01 70 13 48.695 N 148 42 5.736 W Y-09AL1 Polygon 88.20 -8377.32 63.23 5940494.01 644942.02 70 14 41.440 N 148 49 45.179 W -Polygon 1 88.20 -8377.32 63.23 5940494.01 644942.02 70 14 41.440 N 148 49 45.179 W -Polygon 2 88.20 -8257.41 797.73 5940628.01 645674.02 70 14 42.619 N 148 49 23.823 W -Polygon 3 88.20 -8182.47 1478.35 5940716.01 646353.02 70 14 43.355 N 148 49 4.034 W -Polygon 4 88.20 -8125.55 1847.54 5940780.01 646721.02 70 14 43.914 N 148 48 53.299 W -Polygon 5 88.20 -7977.19 2246.50 5940936.01 647117.02 70 14 45.372 N 148 48 41.697 W -Polygon 6 88.20 -8262.60 2368.04 5940653.01 647244.02 70 14 42.564 N 148 48 38.166 W -Polygon 7 88.20 -8439.25 1931.53 5940468.01 646811.02 70 14 40.828 N 148 48 50.859 W -Polygon 8 88.20 -8520.51 851.69 5940366.01 645733.02 70 14 40.031 N 148 49 22.255 W -Polygon 9 88.20 -8615.08 151.69 5940258.01 645035.02 70 14 39.101 N 148 49 42.607 W Y-09AL1 Fault A 88.20 -13077.86 15790.97 5936097.05 660756.01 70 13 55.048 N 148 42 8.184 W -Polygon 1 88.20 -13077.86 15790.97 5936097.05 660756.01 70 13 55.048 N 148 42 8.184 W -Polygon 2 88.20 -12929.70 16513.01 5936259.05 661475.01 70 13 56.490 N 148 41 47.195 W -Polygon 3 88.20 -12541.85 17306.67 5936662.05 662261.01 70 14 0.287 N 148 41 24.108 W Y-09AL1 Target 4 9020.20 -8294.17 1253.14 5940600.01 646130.02 70 14 42.256 N 148 49 10.582 W Y-09AL1 Target 1 9021.20 -8427.04 360.36 5940450.01 645240.02 70 14 40.950 N 148 49 36.540 W Y-09AL1 Target 3 9034.20 -8310.46 1111.79 5940581.01 645989.02 70 14 42.096 N 148 49 14.692 W Y-09AL1 Target 2 9058.20 -8360.32 791.75 5940525.01 645670.02 70 14 41.606 N 148 49 23.997 W b , BP Alaska ~ P Baker Hu hes INTEQ Plannin Report g g INTEQ - -- - -- - Company: BP Amoco Date: 6/13/2008 Time: 16:53:35 Page: 2 i Field: Prudhoe Bay Co-ordinate(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 Section (VS) Reference: Weli (O.OON,O. OOE,80.OOAzi) Wellpath: Plan 2, Y-09A L1 Survey Cakula8on Method: Minimum Curvature Dh: Oracle 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 14670.00 9022.56 End of 40 deg / 100 ft DLS 14870.00 9026.75 5 15020.00 9029.66 6 15200.00 9041.64 7 15300.00 9053.73 8 15361.41 9057.68 9 15461.41 9054.11 10 15675.00 0.00 TD Plan Section Information MD Incl Azim TVD +N/-S +E!-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 14670.00 88.76 96.14 9022.56 -8463.13 127.88 40.00 -3.35 -39.97 270.00 14870.00 88.87 72.14 9026.75 -8442.86 325.34 12.00 0.05 -12.00 270.00 15020.00 88.92 90.14 9029.66 -8419.86 472.91 12.00 0.04 12.00 90.00 15200.00 83.53 69.17 9041.64 -8387.90 648.56 12.00 -3.00 -11.65 255.00 15300.00 82.63 81.23 9053.73 -8362.58 744.35 12.00 -0.90 12.05 95.00 15361.41 90.00 81.23 9057.68 -8353.24 804.87 12.00 12.00 0.00 0.00 15461.41 94.08 92.52 9054.11 -8347.79 904.48 12.00 4.08 11.30 70.00 15675.00 96.49 66.89 9034.12 -8310.20 1111.97 12.00 1.13 -12.00 276.50 Survey ~ MD Incl 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 14377.26 95.75 195.83 8956.95 -8241.51 17.41 5940628.91 644893.59 0.00 -1413.98 0.00 MW D 14400.00 97.15 197.88 8954.40 -8263.13 10.86 5940607.16 644887.46 10.87 -1424.18 55.39 MW D 14420.00 97.15 196.07 8951.91 -8282.11 5.07 5940588.08 644882.03 9.00 -1433.18 270.00 MWD 14430.00 97.13 192.03 8950.66 -8291.73 2.66 5940578.41 644879.81 40.00 -1437.23 270.00 MW D 14440.00 97.08 188.00 8949.43 -8301.50 0.93 5940568.61 644878.27 40.00 -1440.62 269.50 MW D 14450.00 96.99 183.97 8948.20 -8311.37 -0.10 5940558.72 644877.43 40.00 -1443.36 269.00 MWD 14460.00 96.87 179.95 8947.00 -8321.29 -0.44 5940548.80 644877.28 40.00 -1445.41 268.51 MW D 14470.00 96.71 175.92 8945.81 -8331.21 -0.09 5940538.89 644877.83 40.00 -1446.78 268.02 MW D 14480.00 96.53 171.90 8944.66 -8341.09 0.97 5940529.04 644879.07 40.00 -1447.46 267.54 MW D 14490.00 96.31 167.88 8943.54 -8350.87 2.71 5940519.29 644881.00 40.00 -1447.44 267.08 MW D 14500.00 96.06 163.86 8942.46 -8360.51 5.14 5940509.70 644883.61 40.00 -1446.73 266.63 MWD 14510.00 95.78 159.85 8941.43 -8369.96 8.23 5940500.31 644886.89 40.00 -1445.32 266.20 MW D 14520.00 95.47 155.85 8940.45 -8379.17 11.99 5940491.17 644890.82 40.00 -1443.22 265.79 MWD 14530.00 95.13 151.84 8939.53 -8388.11 16.37 5940482.32 644895.38 40.00 -1440.45 265.39 MW D 14540.00 94.78 147.84 8938.66 -8396.72 21.38 5940473.81 644900.54 40.00 -1437.02 265.02 MW D 14550.00 94.39 143.85 8937.86 -8404.97 26.97 5940465.67 644906.30 40.00 -1432.94 264.68 MWD 14560.00 93.99 139.86 8937.13 -8412.81 33.13 5940457.95 644912.60 40.00 -1428.24 264.36 MWD 14570.00 93.57 135.87 8936.47 -8420.21 39.83 5940450.68 644919.44 40.00 -1422.93 264.07 MW D 14580.00 93.13 131.89 8935.89 -8427.13 47.02 5940443.90 644926.76 40,00 -1417.05 263.80 MWD 14590.00 92.67 127.91 8935.38 -8433.53 54.68 5940437.65 644934.54 40.00 -1410.62 263.57 MW D 14600.00 92.20 123.93 8934.96 -8439.39 62.77 5940431.94 644942.74 40.00 -1403.67 263.37 MW D 14610.00 91.72 119.96 8934.62 -8444.68 71.25 5940426.82 644951.32 40.00 -1396.24 263.20 MW D 14620.00 91.24 115.99 8934.36 -8449.37 80.07 5940422.30 644960.24 40.00 -1388.36 263.06 MWD 14630.00 90.75 112.02 8934.18 -8453.43 89.21 5940418.41 644969.44 40.00 -1380.07 262.96 MW D 14640.00 90.25 108.05 8934.10 -8456.86 98.60 5940415.17 644978.90 40.00 -1371.42 262.89 MWD 14650.00 89.75 104.08 8934.10 -8459.62 108.21 5940412.59 644988.56 40.00 -1362.44 262.86 MWD 14660.00 89.25 100.11 8934.18 -8461.72 117.98 5940410.68 644998.37 40.00 -1353.17 262.86 MWD b ~ BP Alaska i P Baker H hes INTEQ Plannin Re ort ~ g P INTEQ ' Company: BP Amoco --- - Date: 6/13/2008 Time: 16: 53:35 - Page: 3 Field: Pru dhoe 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: Y-09 Section (VS) Reference: Well (O.OON,O.OOE,SO.OOAz i) Wellpath: Plan 2, Y-09AL1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~ MD - Incl - Azim SS TVD N/S -- E/W MapN MapE DLS -- VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg 14670.00 88.76 96.14 8934.36 -8463.13 127.88 5940409.46 645008.29 40.00 -1343.67 262.89 MWD 14675.00 88.76 95.54 8934.47 -8463.64 132.85 5940409.05 645013.27 12.00 -1338.86 270.00 MWD 14700.00 88.76 92.54 8935.01 -8465.40 157.78 5940407.76 645038.23 12.00 -1314.62 270.01 MWD 14725.00 88.77 89.54 8935.54 -8465.86 182.77 5940407.79 645063.22 12.00 -1290.09 270.08 MWD 14750.00 88.78 86.54 8936.08 -8465.00 207.74 5940409.13 645088.17 12.00 -1265.34 270.14 MWD 14775.00 88.79 83.54 8936.61 -8462.84 232.64 5940411.77 645113.02 12.00 -1240.45 270.21 MWD 14800.00 88.81 80.54 8937.13 -8459.38 257.39 5940415.70 645137.70 12.00 -1215.47 270.27 MWD 14825.00 88.83 77.54 8937.65 -8454.63 281.93 5940420.92 645162.14 12.00 -1190.49 270.33 MWD 14850.00 88.85 74.54 8938.15 -8448.60 306.18 5940427.42 645186.27 12.00 -1165.55 270.39 MW D 14870.00 88.87 72.14 8938.55 -8442.86 325.34 5940433.52 645205.31 12.00 -1145.69 270.46 MW D 14875.00 88.87 72.74 8938.65 -8441.36 330.10 5940435.12 645210.05 12.00 -1140.74 90.00 MW D 14900.00 88.87 75.74 8939.14 -8434.57 354.16 5940442.37 645233.96 12.00 -1115.87 89.99 MWD 14925.00 88.88 78.74 8939.64 -8429.05 378.53 5940448.36 645258.22 12.00 -1090.91 89.93 MW D 14950.00 88.89 81.74 8940.12 -8424.81 403.16 5940453.07 645282.77 12.00 -1065.92 89.87 MW D 14975.00 88.90 84.74 8940.61 -8421.87 427.98 5940456.48 645307.52 12.00 -1040.96 89.81 MWD 15000.00 88.91 87.74 8941.09 -8420.23 452.92 5940458.60 645332.42 12.00 -1016.12 89.75 MW D 15020.00 88.92 90.14 8941.46 -8419.86 472.91 5940459.36 645352.40 12.00 -996.37 89.70 MW D 15025.00 88.77 89.56 8941.57 -8419.84 477.91 5940459.47 645357.40 12.00 -991.44 255.00 MW D 15050.00 88.00 86.66 8942.27 -8419.02 502.88 5940460.77 645382.35 12.00 -966.71 255.01 MW D 15075.00 87.23 83.76 8943.31 -8416.94 527.77 5940463.33 645407.19 12.00 -941.83 255.09 MW D 15100.00 86.46 80.85 8944.69 -8413.59 552.50 5940467.15 645431.86 12.00 -916.89 255.21 MW D 15125.00 85.71 77.94 8946.40 -8409.01 577.02 5940472.21 645456.28 12.00 -891.96 255.37 MW D 15150.00 84.97 75.03 8948.43 -8403.18 601.24 5940478.49 645480.38 12.00 -867.09 255.57 MW D 15175.00 84.24 72.10 8950.78 -8396.14 625.11 5940485.99 645504.11 12.00 -842.36 255.81 MW D 15200.00 83.53 69.17 8953.44 -8387.90 648.56 5940494.68 645527.39 12.00 -817.84 256.08 MW D 15225.00 83.28 72.18 8956.31 -8379.68 671.99 5940503.35 645550.66 12.00 -793.33 95.00 MW D 15250.00 83.04 75.19 8959.29 -8372.71 695.81 5940510.77 645574.34 12.00 -768.66 94.65 MW D 15275.00 82.83 78.21 8962.37 -8367.01 719.96 5940516.94 645598.37 12.00 -743.90 94.30 MWD 15300.00 82.63 81.23 8965.53 -8362.58 744.35 5940521.84 645622.67 12.00 -719.10 93.92 MW D 15325.00 85.63 81.23 8968.09 -8358.79 768.93 5940526.10 645647.17 12.00 -694.24 0.00 MW D 15350.00 88.63 81.23 8969.34 -8354.98 793.60 5940530.38 645671.76 12.00 -669.28 0.00 MW D 15361.41 90.00 81.23 8969.48 -8353.24 804.87 5940532.34 645683.00 12.00 -657.88 0.00 MW D 15375.00 90.56 82.76 8969.41 -8351.35 818.33 5940534.49 645696.42 12.00 -644.29 70.00 MW D 15400.00 91.58 85.58 8968.94 -8348.81 843.20 5940537.51 645721.23 12.00 -619.37 70.01 MW D 15425.00 92.60 88.40 8968.03 -8347.49 868.14 5940539.30 645746.14 12.00 -594.57 70.06 MW D 15450.00 93.62 91.23 8966.67 -8347.41 893.10 5940539.86 645771.09 12.00 -569.98 70.16 MW D 15461.41 94.08 92.52 8965.91 -8347.79 904.48 5940539.71 645782.47 12.00 -558.84 70.32 MW D 15475.00 94.26 90.90 8964.92 -8348.19 918.03 5940539.56 645796.03 12.00 -545.57 276.50 MW D 15500.00 94.59 87.91 8962.99 -8347.93 942.95 5940540.30 645820.94 12.00 -520.98 276.38 MW D 15525.00 94.90 84.91 8960.92 -8346.37 967.81 5940542.34 645845.76 12.00 -496.22 276.15 MW D 15550.00 95.21 81.92 8958.72 -8343.51 992.55 5940545.67 645870.44 12.00 -471.37 275.90 MW D 15575.00 95.49 78.92 8956.39 -8339.37 1017.09 5940550.28 645894.89 12.00 -446.48 275.64 MW D 15600.00 95.77 75.91 8953.93 -8333.95 1041.37 5940556.17 645919.06 12.00 -421.63 275.36 MW D 15625.00 96.02 72.91 8951.37 -8327.27 1065.32 5940563.31 645942.88 12.00 -396.88 275.07 MW D 15650.00 96.26 69.90 8948.69 -8319.34 1088.87 5940571.69 645966.27 12.00 -372.31 274.76 MW D 15675.00 96.49 66.89 8945.92 -8310.20 1111.97 5940581.27 645989.19 12.00 -347.98 274.43 MW D [eVHOSI .00'08 le uopaeg RapaaA IYLAwULI (a)Lee3/(-)3eeM uxO Mug®'nMeN~~t~q'ew.3 [roLwLW nwrv ~,ew,w ~~~ ~~"~ Z veld Re ' o- L~tls A i id (l Bdtl60-A) 60-A - - ** _-.- _.. a.w+n v~io~.~vway (tl60-A)60-A - (60-A)60-A - ae ~~ (ziv6o-A'e Reid) 6o-A ---~ ON3'J3l dq uou;~ voegea u ~ey~ Lc sax<< i~za~coo ... en 2 "u n° x~ :^ R a 3 Qu S a wea .u ....L e.. es w , . ~. unp~~aw5nwmry p00~ery uape~m~e~ OZ BB ~ 'NOOO1 b0 IqS aaw~ 1 tllsnlOM~S~ yyaN arvl'80'AgeWUe~IIOM ~ ~ePn 13~N~la~Pw~'J NO11tlWllOiNl 3JNitlii3tl ~LLLLLOL'OL 00~0 0000'L10 .00'00 000140L0 ~IeMO u10M0 uw10M'~ LOL h 0000100NOL~9 60 ~ CL PII a McIM 9L'LL[tL iiwn~'i e' w e~seld d8 BP Alaska - ~~m~n~Ya3fi~z1 asnl B,1 _ ~~~ /~Y~/~~~ ~ R T M Azmurhs tO True NoM Mapnalc NMfi: 23.13' Plan: PWn 2 (Y-09/Plan 2. V-09AL1) Created By: BP Date: 611112008 Checked: Dele - . NELL00TN OFTYY P4~2 ~ ~~ ~Ilif~i ~p Ma9nelr lSeN Sven991h'S]6fi-/nT 80 Oi 99° ^ l .. ~_ ; :~ , . 0 rN a. Oate: 611012008 C n : wc~ln~wm alwBill MiMaelsw, , .. 6.. Men taJTl M NT EQ Momr6y9m2097 , 41. ~~.m: 0~,1]:of/N „framlTYe N.20F rg y 110.00 0.00 0.00 19.30 REFERENCE INFORMATION ~'I Coordinate (NIE) Reference: Well Gentle: V-09, True NoM VeNwl ( D) Reference: 13:09 5/30/1997 00:00 88.20 S ti VS R f Sl t 09 O OON O OOE '~ M re ec on ( ) e erence: o - ( . , . ) easuretl Depth Reference: 13:09 5/30/1997 00:00 88.20 Calculation Method. Minimum Curvature a~ ~.~ rw ~ecrNµocTU Mar .~. w.a r.rpr -7500 f ll ~ ~~ t~~l~!~ I ~ r~ I ~ , 1 a }j~t I i i i ~ ~ I _- ~ ~ ~ '~ ~~ I ~ ~} l~[ } ~ ; 750U , + ~ 1 ! , { ~ ~ ~ ~ r ; : l _ 11II I !.!'_ -_ H~ ~T .-.. ~ 1.. ~1 - ]-.{."I -- .[ I _- 1 F !:; _ f--r ~ I i -._ -_fi- r I f_~--~ `-- . 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I I .: i ~. ~~ ~ ~ ` w -8300_ . - -.. - ~ } C -e4oo r-oa r-0aw _ ~/ + I ~ ? f -8500 i ~. 7 ~ _ -r i ' ~ 1 - I ~ F + r t 1 . ~ -fifiw. .. -. , ..-1 - ~ r ~~ ~ ~ - ~ ~ 1 I- E 1 f ~ ~ ~ I ~ - 1 r + ~r r ' ' f'' ~ } { 1 I- I T -. -' -+1~ ti ~ I . ~~~~ ~ 1 ~ ~ t t ~ ~ ~~~, ' .- -~ ; I ~ 1 ~ ~ ~i ' { { , 11 .... I I ~. - ~ ~ ~ .;:_: TITt :._ _ ~ I ~ ~ ~ . I r I ~ ~ /41 1 ~ ~ ~t I r I ~ _t~~ ~ T 1 I F I ~ ) r r i I a ~+ a- I ,- - ~-T ~ , 1 ' .... r f_r 1 'r r _ ~T . r .r ~ E j t 7-j r r ~ ~~ ' ~ r _ { I y -8800 _ T~ - ~ ' + .. I ; .. - ~ ~' ; ..- '-1. 1 ' T .;_.. ~ . i- _ k; . ' I ..-.~ _ •_' ) ' l - 1, I - i . I~-.~ 111 ' -fi 4 i ~1 , i..• r ) -~.. 1 ~ t f. .~ ~ ~ . --7 ~. ~ i . - ~~~ # t 1 1 - ~ . I - - i .- ? -.~ C r: ; . , , ; Y ~ 1 L . . ~ ~ _ - 1 , i l _.. r r - _. - -~ 1 ~ _ II t t I rr 1._ __ :- _.. 1 - - I 1 I -8900 _ 1 -t t __ ~I 1 ~ ' I ~ ...1 I _... ' I 1 ~ ~ I - - ,T t ,; ,~ + _i f~-~ ~ •..4 f I r f 1 ~~ + ~ { :-I L 1 it ~ ~ l ~ t t~ 1 . -1 L , I 1 ~ j }i { _ _ t II t -soon T - , - ~ I} -~ { I I I I 1 ~{ I ~ r 1', I I I ~ ~ ~' 1 ~ rt - -_. ~ _ - J , -rr 1 ~ L ~#1 ~ rt I I{ }~ 1 , i 1 1~ i i +, a 1 I _ - ,III 1 j~ I'I ji r t t I -i 11 - _ 7 9100 ~ I I, • I , T_ -- __. . ; 1 I _! . t; t .. I ~ ,-..,+ -_ .._ , „ _~': ~ " ' f i l-T ... _.,.._ •L 1 1 ! i Y-08 Plan? Y-08AL3 I r , t :TI dd'l'+ 1,.. 'I , ,F r ~ ( - -, . _ .. T'T I "' _ ' 4 -'.~ r +, f t k+ . -. _ ~ -t - Y 9200 -. -.- .-.. _. _..... .... . ... - .... ~ i . ... ... ~, . . ~ - / ~ ', . -9300- ..-, _~ T'-r.T,, •t--T~+-1-rr ~T-r~ :~rrr ~ -r- rr~ ~Trt '~ _T -. _ .. _ _- rr-- T;~r,-Trtr 1~ r ; r rl - .. .... , I 1 r; r :. i . ' i ... ,.: , :. , ~ - _ ~ _ ~ _ _ _ - -1000 -900 800 -700 -fi00 -500 -000 -300 200 -1 00 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 17 00 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 _ West(-}lEasR(+) [~pOftlin] _ I • W F:I.L DETAR.S Narrar IN/-S •EI-W NUMing Eastiog LatilWe Longitude Slot Y-W 385.90 -30?421 594tltl6].Y.1 644]1 ].]G ]0'I fi U).tl30N 14tl°4Y'4].OIBW U9 ANTI-COLLISION SETTINGS tv.uwm ~e-rats Interpolation MeihodMD Interval: 25.00 ` ~A~J """ Depth Range From: 14377.26 To: 15675A0 Maximum Range: 1763.58 Reference: Pla¢ Plan 2 w x - n,a, e..,a SURVEY PROGRAM DeptM1 Fm DeptM1 To Survey/Plan 143]].26 I56]S.W Plawed: Plan 2 V2 WELLPATII DETAILS Tool Plop ~. Y-09AL1 SW19_U$)960 MWD arent WeI1pnN: Y-09A Tie an MD: 143]7.16 Rig: Nordic I Rcf Datum: Il : W 5/lUll99] W:W tl8.10a i V.Settion Origin Origin Starting Angle +NI-S +E/-W From TVD IIU.W° OW U.W l9.lU LEGEND Y-09 (Plan 3, Y-09AL2), M jor Risk - Y-09 (Y-U9A), Major Risk Plan 2, Y-09AL1 Plan 2 by ~~~' TE(~ SECTION DETAILS Sec MD Lw An TVU +N/-S +P-W ULeg TPaee V9u Twgn 141tt 3fi 9s )5 IYS tl3 YW5.15 -6241.51 1]41 UW UW 2635.12 149W.W 4].IS 19).tltl YW26U -8?61.11 SS 3y 2636.36 1 1 I 144~OW 9].IS Iy6.0] 146)U.W tlg]6 Y6.14 9U4UI1 -8282.11 YO?156 -8443.13 50] 9W 2)O.W 18)].41 12)tlb 3U10 )3 5 148)O.W 88.8) P_.14 150?II.W tl W.14 9016.]5 X442.86 9U2Y 66 -841Y Nfi J25 ]4 11.W 2tU.W 319]35 4)241 1100 9U.IM] )321.15 i IS?W W 83.53 69.It 91N104 -tl36-/.Ya 64b.5fi I2.W ~SS.W 34]g28 IS1W.W tl?.61 tl12J 9 15)61.41 W.W 81 i3 YOSi )3 -blfi?.Sb WS).6tl -bJ53 ~4 ]41.35 12W 95W 3SSY.6l W.tl) 12.W II.W )61131 IU 15961.41 y4.Utl 92.5? I I 156)5 lxl 96.49 66.by W5a 11 -8J4>.]•) Y034.12 ~b310.211 yoi.4a 12W )O.W 3)USW I II I Y] 12 W 2]6.50 3btl).16 ~~ b ~ BP Alaska P Anticollision Report iNTEQ ~ _- - -- -- Company: Field: BP Amoco Prudhoe Bay Date: 6!1 1/2008 Time: 15:40:48 Page: 1 Reference Si te: PB Y Pad Co-ordinate(NE) Reference: Well: Y-09, True North Reference Well: Y-09 Vertical (TVD) Reference: 13:09 5/30/1 997 00:00 88.2 Reference Wellpath: Plan 2, Y-09AL1 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are ~nmlis in this fiztdJcipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCW SA Ellipse Depth Range: 14377.26 to 15675.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1763.58 ft Erro r 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 : MW D -Standard (9202.00-11 MW D MW D -Standard 11139.76 14377.26 3 : MW D -Standard (11139 .76-1 MW D MW D -Standard 14377.26 15675.00 Planned: Plan 2 V2 MW D MW D -Standard Casing Points --- MD TVD Diameter Hole Sine Name -- - ', ft ft in in 15675.00 9034.12 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 3, Y-09AL2 VO Pla 1 4548.16 14550.00 9.51 793.83 -784.31 FAIL: Major Risk PB Y Part Y-09 Y-09A V1 1 4469.27 14475.00 18.04 1157.15 - 1139.11 FAIL: Major Risk Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Plan 3, Y-09AL2 VO Plan: Plan 3 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis -_ _-_ Ctr-Ctr No-Go Allowable I MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/IISDistance Area Deviation Warning I, 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 9033.43 14475.00 9033.47 188.46 189.08 173.91 0.00 4.125 0.04 651.99 -651.95 FAIL 14499.93 9030.67 14500.00 9032.08 183.60 184.07 326.61 162.72 4.125 1.49 346.66 -345.17 FAIL 14524.52 9028.23 14525.00 9031.81 173.20 173.74 297.05 143.01 4.125 4.50 628.56 -624.06 FAIL 14548.16 9026.21 14550.00 9031.53 158.61 159.05 268.73 124.14 4.125 9.51 793.83 -784.31 FAIL 14570.22 9024.66 14575.00 9031.26 141.15 141.68 248.80 112.92 4.125 16.97 794.17 -777.20 FAIL 14590.41 9023.57 14600.00 9030.98 122.28 122.55 233.93 106.18 4.125 26.64 724.91 -698.27 FAIL 14608.08 9022.88 14625.00 9030.71 103.82 104.07 222.25 101.52 4.125 39.24 635.91 -596.67 FAIL 14622.59 9022.50 14650.00 9030.44 87.59 87.78 213.23 98.27 4.125 55.20 549.02 -493.82 FAIL 14634.15 9022.34 14675.00 9030.17 74.11 74.26 206.47 96.10 4.125 73.75 473.04 -399.28 FAIL 14643.27 9022.29 14700.00 9029.90 63.26 63.35 201.39 94.64 4.125 94.14 410.16 -316.02 FAIL 14651.32 9022.30 14725.00 9029.64 53.59 53.63 197.22 93.66 4.125 114.91 353.24 -238.33 FAIL 14658.72 9022.37 14750.00 9029.37 44.69 44.70 193.58 92.96 4.125 135.72 300.32 -164.60 FAIL 14665.62 9022.47 14775.00 9029.11 36.59 36.52 190.31 92.43 4.125 156.50 251.67 -95.17 FAIL 14673.41 9022.63 14800.00 9028.85 30.34 30.40 187.74 92.01 4.125 177.18 214.27 -37.08 FAIL 14683.82 9022.86 14825.00 9028.59 27.29 27.21 186.15 91.66 4.125 197.52 194.07 3.44 Pass 14694.35 9023.08 14850.00 9028.34 24.28 24.56 184.60 91.38 4.125 217.40 174.19 43.22 Pass 14704.97 9023.31 14875.00 9028.09 22.14 22.90 183.10 91.16 4.125 236.86 157.04 79.82 Pass 14714.78 9023.52 14900.00 9028.08 21.11 22.25 181.78 91.02 4.125 256.93 143.46 113.47 Pass 14723.41 9023.71 14925.00 9028.41 20.21 22.08 180.70 90.97 4.125 277.99 132.16 145.83 Pass 14730.90 9023.87 14950.00 9029.08 20.21 22.12 179.83 90.99 4.125 299.91 127.50 1.72.41 Pass 14737.30 9024.01 14975.00 9030.08 20.40 22.25 179.14 91.08 4.125 322.56 125.62 196.94 Pass 14742.66 9024.12 15000.00 9031.41 20.55 22.43 178.63 91.21 4.125 345.83 124.94 220.88 Pass 14747.06 9024.22 15025.00 9033.08 20.68 22.62 178.27 91.37 4.125 369.59 124.98 244.62 Pass y ~ BP Alaska ~ ~'~~ by Anticollision Re ort ~ l~ iNTEQ Company: BP Amoco Date: 6/11/2008 Time: 15:40:48 Page: 2 Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Refe rence: Well: Y-09, True North Reference Well: Y-09 Vertical (TVD) Reference: 13:09 5/30/1997 00:00 88.2 Reference WeUpath: Plan 2, Y-09AL1 Db: Oracle Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Plan 3, Y-09AL2 VO Plan: Plan 3 V2 Inter-Site Error: 0.00 ft Refe rence Otlset Semi-Major Aa6s Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglllSDistance Area Deviation Warniug ft ft ft ft ft ft deg deg in ft ft ft 14750.54 9024.29 15050.00 9035.07 20.83 22.81 178.04 91.57 4.125 393.76 125.68 268.08 Pass 14753.18 9024.35 15075.00 9037.38 21.14 22.97 177.94 91.79 4.125 418.23 127.79 290.44 Pass 14755.03 9024.38 15100.00 9040.00 21.37 23.10 177.96 92.02 4.125 442.92 129.28 313.64 Pass 14756.17 9024.41 15125.00 9042.92 21.50 23.19 178.07 92.27 4.125 467.74 130.12 337.62 Pass 14757.46 9024.44 15150.00 9045.62 21.66 23.29 178.11 92.47 4.125 492.55 131.22 361.33 Pass 14759.27 9024.48 15175.00 9047.88 21.87 23.44 178.02 92.59 4.125 517.24 133.00 384.24 Pass 14761.56 9024.52 15200.00 9049.67 22.15 23.64 177.81 92.66 4.125 541.77 135.49 406.28 Pass 14764.28 9024.58 15225.00 9051.00 22.47 23.90 177.50 92.68 4.125 566.06 138.68 427.39 Pass 14767.41 9024.65 15250.00 9051.86 22.85 24.24 177.09 92.64 4.125 590.08 142.58 447.50 Pass 14770.91 9024.72 15275.00 9052.25 23.26 24.66 176.60 92.57 4.125 613.78 147.19 466.59 Pass 14775.00 9024.81 15300.00 9052.18 23.75 25.21 176.00 92.46 4.125 637.12 152.83 484.28 Pass 14778.91 9024.89 15325.00 9051.65 24.66 25.82 175.39 92.32 4.125 660.05 159.63 500.42 Pass 14783.36 9024.98 15350.00 9050.68 25.70 26.60 174.69 92.16 4.125 682.54 167.63 514.91 Pass 14788.08 9025.08 15375.00 9049.27 26.80 27.53 173.94 91.97 4.125 704.57 176.38 528.19 Pass 14793.04 9025.19 15400.00 9047.42 27.95 28.62 173.13 91.76 4.125 726.09 185.80 540.28 Pass 14800.00 9025.33 15425.00 9045.13 29.57 30.34 172.06 91.53 4.125 747.08 199.20 547.88 Pass 14800.00 9025.33 15450.00 9042.52 29.57 30.31 171.81 91.27 4.125 767.85 199.36 568.49 Pass 14808.14 9025.50 15475.00 9039.91 32.09 32.56 170.61 91.05 4.125 789.34 216.06 573.28 Pass 14812.23 9025.59 15500.00 9037.33 33.35 33.76 169.90 90.83 4.125 811.59 224.65 586.94 Pass 14815.74 9025.66 15525.00 9034.80 34.44 34.82 169.28 90.63 4.125 834.48 232.09 602.39 Pass 14818.70 9025.72 15550.00 9032.31 35.35 35.74 168.73 90.44 4.125 857.92 238.39 619.53 Pass 14825.00 9025.85 15575.00 9029.88 37.30 37.77 167.82 90.28 4.125 881.84 251.75 630.09 Pass 14825.00 9025.85 15600.00 9027.60 37.30 37.76 167.66 90.12 4.125 906.08 251.84 654.24 Pass 14825.00 9025.85 15625.00 9025.75 37.30 37.75 167.53 90.00 4.125 930.64 251.91 678.73 Pass 14825.00 9025.85 15650.00 9024.35 37.30 37.74 167.45 89.91 4.125 955.43 251.96 703.46 Pass 14825.00 9025.85 15675.00 9023.41 37.30 37.74 167.39 89.85 4.125 980.35 251.99 728.36 Pass 14825.00 9025.85 15700.00 9022.93 37.30 37.74 167.37 89.83 4.125 1005.34 252.01 753.33 Pass 14825.00 9025.85 15725.00 9022.75 37.30 37.74 167.36 89.82 4.125 1030.34 252.02 778.32 Pass 14825.00 9025.85 15750.00 9022.60 37.30 37.74 167.36 89.82 4.125 1055.29 252.01 803.28 Pass 14825.00 9025.85 15775.00 9022.46 37.30 37.73 167.35 89.81 4.125 1080,15 251.99 828.16 Pass 14825.00 9025.85 15800.00 9022.36 37.30 37.72 167.34 89.81 4.125 1104.84 251.96 852.87 Pass 14825.00 9025.85 15825.00 9022.27 37.30 37.71 167.34 89.80 4.125 1129.31 251.92 877.38 Pass 14832.16 9025.99 15850.00 9022.21 39.75 40.10 166.49 89.81 4.125 1153.44 267:28 886.16 Pass 14834.35 9026.04 15875.00 9022.18 40.50 40.83 166.23 89.81 4.125 1177.27 271.95 905.32 Pass 14836.83 9026.09 15900.00 9022.17 41.35 41.67 165.93 89.81 4.125 1200.72 277.26 923.46 Pass 15056.42 9030.71 15925.00 9022.19 22.32 24.21 175.52 89.60 4.125 1222.08 134.49 1087.59 Pass 15060.58 9030.87 15950.00 9022.23 22.97 24.71 175.03 89.60 4.125 1242.39 138.03 1104.36 Pass 15064.94 9031.05 15975.00 9022.29 23.64 25.30 174.53 89.60 4.125 1262.04 142.21 1119.84 Pass 15075.00 9031.51 16000.00 9022.38 25.19 26.93 173.39 89.63 4.125 1281.06 153.27 1127.78 Pass 15075.00 9031.51 16015.00 9022.45 25.19 26.94 173.38 89.62 4.125 1292.06 153.35 1138.71 Pass Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Y-09A V i Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 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 14486.34 9032.15 14500.00 9027.54 186.90 187.56 251.26 81.91 32.941148.09 -1115.15 FAIL b ~ BP Alaska ~ ~'`~ P Anticollision Report 1NTEQ Company: BP Amoco Date: 6/11!2008 Time: 15:40:48 Page: 3 ~ Field: Prudhoe Bay Reference S ite: PB Y Pad Co-ordinate(NE) Reference: Well: Y-09, True North Reference Welt: Y-09 Vertical (TVD) Reference: 13:09 5!30/1997 00:00 88.2 Reference Wellpath: Plan 2, Y-09AL1 Db: Oracle Site: PB Y Pad Well: Y-09 Rule Assigned: Major Risk Wellpath: Y-09A V1 Inter-Site Error: 0.00 ft ~~ Refe rence Otlset Semi-Major Aaos Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area I~viation Warning ~, ft ft ft ft ft ft deg deg in ft ft ft 14499.81 9030.68 14525.00 9024.13 183.63 184.17 246.50 82.56 50.881130.92 -1080.04 FAIL 14509.95 9029.64 14550.00 9021.28 180.03 180.55 243.10 83.23 71.261111.28 -1040.03 FAIL 14517.13 9028.93 14575.00 9018.80 176.86 177.45 240.75 83.75 93.51 1093.65 -1000.14 FAIL 14521.49 9028.51 14600.00 9017.05 174.80 175.34 239.62 84.37 117.291082.11 -964.83 FAIL 14523.62 9028.31 14625.00 9016.25 173.68 174.26 239.50 85.10 141.871076.19 -934.32 FAIL 14523.93 9028.28 14650.00 9016.02 173.51 174.10 240.04 85.77 166.781075.64 -908.86 FAIL 14523.13 9028.36 14675.00 9016.78 173.94 174.51 241.11 86.52 191.601078.43 -886.83 FAIL 14521.30 9028.53 14700.00 9018.48 174.90 175.44 242.65 87.32 216.051084.24 -868.19 FAIL 14519.28 9028.72 14725.00 9020.16 175.91 176.44 244.08 87.95 240.401090.13 -849.73 FAIL 14517.11 9028.93 14750.00 9021.13 176.87 177.46 245.30 88.30 264.641096.03 -831.39 FAIL 14514.63 9029.17 14775.00 9021.31 177.97 178.59 246.43 88.43 288.541102.72 -814.17 FAIL 14511.91 9029.44 14800.00 9021.57 179.17 179.76 247.64 88.55 312.091109.84 -797.75 FAIL 14509.15 9029.72 14825.00 9022.63 180.32 180.89 248.98 88.78 335.41 1116.63 -781.22 FAIL 14506.57 9029.98 14850.00 9024.68 181.24 181.89 250.38 89.15 358.741122.30 -763.56 FAIL 14504.20 9030.22 14875.00 9027.39 182.08 182.75 251.75 89.57 382.161127.29 -745.13 FAIL 14501.98 9030.46 14900.00 9030.20 182.87 183.51 253.03 89.96 405.651131.79 -726.14 FAIL 14500.00 9030.66 14925.00 9033.06 183.58 184.15 254.18 90.32 429.251135.67 -706.42 FAIL 14498.06 9030.87 14950.00 9035.59 184.10 184.75 255.24 90.60 453.021138.87 -685.86 FAIL 14496.39 9031.05 14975.00 9037.67 184.54 185.23 256.11 90.80 476.971141.57 -664.60 FAIL 14494.91 9031.21 15000.00 9039.18 184.94 185.65 256.83 90.92 501.101143.95 -642.85 FAIL 14493.56 9031.35 15025.00 9039.98 185.30 186.00 257.39 90.95 525.331146.11 -620.78 FAIL 14492.36 9031.48 15050.00 9040.09 185.62 186.30 257.84 90.90 549.651148.06 -598.41 FAIL 14490.00 9031.74 15075.00 9039.62 186.25 186.88 258.74 90.86 574.001151.77 -577.78 FAIL 14490.00 9031.74 15100.00 9038.88 18625 186.86 258.58 90.70 598.31 1151.84 -553.52 FAIL 14490.00 9031.74 15125.00 9038.28 186.25 186.85 258.44 90.56 622.671151.88 -529.21 FAIL 14490.00 9031.74 15150.00 9037.81 186.25 186.84 258.33 90.45 647.201151.91 -504.71 FAIL 14487.43 9032.02 15175.00 9037.52 186.71 187.41 259.38 90.47 671.761155.05 -483.29 FAIL 14486.74 9032.10 15200.00 9037.45 186.83 187.55 259.63 90.44 696.421155.87 -459.44 FAIL 14486.11 9032.17 15225.00 9037.48 186.94 187.67 259.87 90.42 721.141156.58 -435.44 FAIL 14485.51 9032.24 15250.00 9037.54 187.05 187.79 260.09 90.41 745.861157.26 -411.40 FAIL 14484.96 9032.30 15275.00 9037.72 187.15 187.89 260.31 90.41 770.61 1157.88 -387.26 FAIL 14484.46 9032.36 15300.00 9038.03 187.24 187.98 260.52 90.41 795.41 1158.42 -363.01 FAIL 14484.01 9032.41 15325.00 9038.48 187.32 188.06 260.72 90.43 820.231158.90 -338.67 FAIL 14483.60 9032.45 15350.00 9039.05 187.39 188.13 260.90 90.45 845.071159.32 -314.24 FAIL 14483.25 9032.49 15375.00 9039.74 187.45 188.18 261.07 90.48 869.951159.67 -289.72 FAIL 14482.93 9032.53 15400.00 9040.68 187.51 188.24 261.25 90.53 894.841159.98 -265.14 FAIL 14480.00 9032.86 15425.00 9041.68 188.03 188.72 262.59 90.69 919.691162.98 -243.29 FAIL 14480.00 9032.86 15450.00 9042.63 188.03 188.71 262.61 90.71 944.491162.95 -218.46 FAIL 14480.00 9032.86 15475.00 9043.36 188.03 188.71 262.62 90.72 969.331162.93 -193.60 FAIL 14480.00 9032.86 15500.00 9043.61 188.03 188.70 262.60 90.70 994.201162.92 -168.72 FAIL 14480.00 9032.86 15525.00 9043.61 188.03 188.70 262.57 90.67 1019.101162.92 -143.82 FAIL 14480.00 9032.86 15550.00 9043.08 188.03 188.69 262.52 90.62 1044.041162.93 -118.89 FAIL 14480.00 9032.86 15575.00 9042.14 188.03 188.69 262.45 90.55 1069.001162.96 -93.96 FAIL 14480.00 9032.86 15600.00 9041.16 188.03 188.69 262.39 90.49 1093.971162.99 -69.02 FAIL 14480.00 9032.86 15625.00 9040.23 188.03 188.70 262.33 90.43 1118.941163.02 -44.07 FAIL 14480.00 9032.86 15650.00 9039.35 188.03 188.70 262.29 90.39 1143.901163.04 -19.14 FAIL 14480.00 9032.86 15675.00 9038.48 188.03 188.70 262.24 90.34 1168.861163.07 5.79 Pass 14480.00 9032.86 15700.00 9037.61 188.03 188.71 262.20 90.30 1193.81 1163.10 30.71 Pass 14480.00 9032.86 15725.00 9036.74 188.03 188.71 262.17 90.27 1218.751163.13 55.63 Pass 14480.00 9032.86 15750.00 9035.89 188.03 188.72 262.13 90.23 1243.691163.15 80.54 Pass BP Alaska by Anticollision Report INTEQ Company: BP Amoco Date: 6/11/2008 Time: 15:40:48 Page: 4 l Field: Prudhoe Bay Reference Site: PB Y Pad Co-ordinate(NE) Reference: Well: Y-09, True North i Reference Well: Y-09 Vertical (TVD) Reference: 13:09 5/30/1 997 00:00 88.2 Reference Weupath: Plan 2, Y-09A L1 Db: Oracle Site: ~_ PB Y Pad Well: Y-09 Rule Assigned: Major Risk Weupath: Y-09AV1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD ~ TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/FISDistance Area Deviation Waiving I ft ft ft ft ft ft deg deg in ft ft ft 14480.00 9032.86 15775.00 9035..11 188.03 188.72 262.10 90.20 1268.631163.18 105.46 Pass 14480.00 9032.86 15800.00 9034.44 188.03 188.73 262.08 90.18 1293.581163.20 130.38 Pass 14480.00 9032.86 15825.00 9033.89 188.03 188.73 262.06 90.16 1318.531163.22 155.31 Pass 14480.00 9032.86 15850.00 9033.47 188.03 188.74 262.05 90.15 1343.481163.24 180.24 Pass 14480.00 9032.86 15875.00 9033.19 188.03 188.74 262.04 90.14 1368.441163.25 205.18 Pass 14480.00 9032.86 15900.00 9033.08 188.03 188.75 262.04 90.14 1393.401163.27 230.13 Pass 14480.00 9032.86 15925.00 9033.13 188.03 188.75 262.05 90.15 1418.361163.28 255.08 Pass 14480.00 9032.86 15934.43 9033.19 188.03 188.75 262.06 90.16 1427.781163.29 264.49 Pass • Rig Floor to Top of Well Y-09AL1 2.25 9.23 ~_ 5.00 ~ 12.65 ~~~~ 13.56 .~ 2 1'16" 5000 psi , R-24 Mud gross 14.89 HCR M Choke Line 16.10 f-~ 16.66 f- ~ 7 1:16" ArxxAar x 5000 psi 7 1,•'16" 5000 psi, RX-46 -~ 1.•'16" 5000 psi (RX-46i ~- 7 1 i 16" X 3 1 8" Flanged Adapter I Swab Valve SSV Master Valve Lock Down Screws Ground Level ti1Zl.JiiYL LJGj.1~1.iLlliGllL Ul iVd.LUIt1.i~SUUT'CeS Lana L-1Qm1n1Siratlon JyStem Yage 1 ofx i S.~ ., ~ , .. =~'---~ ' ~rnr~~St~teisP~~ts ~d~corder's Search State Gabins ~~#181'~ ~~S~tir~#!S .~, _ Alaska D~11Fi. Case Summary File Type: ADL File Number: 2$287 ~ ~ Printable Case Fle_Summary See Township, Range, Section and Acreage? ~ Yes ~` No New Search i_AS Menu ~ Case Abstract i Case Detail i Land Abstract _ _~~, File: ADL 28287 `'''E'_ Searcn__f_or Status Plat Updates As oi'08!12~%2008 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: T64._ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/09/1.965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DN OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: ~dS NORTH SLOPE Last Transaction` AA-NRB ASSIGNMENT APPROVED Meridian: U Township: OI1N Range: .013E .Sectiof:: 2? Sectiofi,~cr~ts:6=10 Search Plats .~lIC'Y1dLQ)7: ~ ~ Ioli'nS/I1 j): U 1 ~ ~ Range: ~~~ _3 ~', S~eeliUn: 2~ ,Sect(un _~creC: 640 ;Meridian: U Tu~a~nship: 01 1 N Range: 01 i E S'ectiun: 33 Secliun ~cr~~s: 640 ~Llerld7ai2: tJ IO~ti'7lShZI7: o i ~ ~ Range. U 1_~ F ~Se~'tlOll: ~-~ ~Sec'11071 ~-~C7'es: 6=10 Legal i)escrption _. 0~-28-196 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14-98 TII N-R13E-L1LI27, 28, 33, 34 2560.00. ~l ~~t~ !, Last updated on 08/12/2008. http://www.dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28287&... 8/ 12/2008 t-~iasxa liepartment or i~aturai esources t,ana Aammistration System Yage 1 of'~~ r, :~=-k =',a~: ~~r (m~~z~I ?~ eordslS~at~~s Flats r~~c~rder`s search State Cabins [~~tE~1~~ ~~~ll~C~eS A~ask~ DNR Case Summery File Type: A~~ File Number: 47471 Prn..tabie Case File Summary See Township, Range, Section and Acreage? Yes ~ No fVew Search i..AS i+lienc~ I Case Abstract I Case Detail I t_and Abstract ~~ File: AllL 17471 '`~~'!' Search for Status Plat Updates ~1s of 08 `1 x!2008 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/9.00 E. BENSON BL ATTN: LAND_MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type: 784. OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/30/1969 Total Acres: 2560.000 Date Initiated: 08/11/1969 Dice of Primary Responsibility: DOG DN OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED .Meridian: U Township: OlON Range: 013E Section: 03 ~ Seetiof~ ,2cj~es: 640 Search Plats llleridiurr: U T~ni~nship: OION Ran~e.~ 013E Sectrnn: 04 S'~~ction _=i~~re.e: ~~0 Meridlart: li Tuu~r~s{~irp: 0 L 0~' Runge: O l 3 E Sec~irm: 04 ~c'~ lion . toes: 641) Merld![{n: t~ lOlL71S{nt7. (}~ nTV l~a]hC': ~)~ 3I. ~~c'c (IOn: 1 O S2Ctlf)77 ,~C]'r'S: 64U Legal Description 08-i 1-1969 * * SALE NOTICE LEGAL DESCRIPTION~* C23-056101V-R13E-UMGENERAL 03 640.DOALL 04 640.00.ALL 09 640.00 ALL 10 640.00 ALL TnTAL <4CF~'S _ 2s~0.00 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=47471 &... 8/12/2008 ~ ~ 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 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, Page 1 of 1 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 6050000 6000000 5950000 5900000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 5850000 ~ ---_ .._ ._~ .~ _.__~._... 400000 500000 600000 700000 800000 ~i ~ ~ TRANSMITTAL LETTER CHECKLIST . C~~~~ WELL NAME f ~Pl./ J~ d~/ PTD# d0~/dam / Devetopmen~t~ Service Exploratory Stratigraphic Test Non-Conventioaal Well FIELD: _ /~.C!/d.~/DE ~~.4y POOL: ~,e~G1~~0~' ~A~ 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 ~ '~a~1 , ~ / (If last two digits in Permit No. ~~ ~ - API No. 50- ~~`1 - ~ '1 -~. / P A I number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - _, from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is 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 h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me~liane is not allowed for (name of well) until after (Comoanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Comaanv Name) must contact the Commission to obtain advance approval of such water well testing ro Rev: 1/I I/2008 WELL PERMIT CHECKLIST Field 8 Pool PRUDHOE BAY, PRUDHOEOIL -640150 WeA Name: PRUDHOE BAY UNIT Y-09AL1 Program DEV Well bore seg ^ PTD#: 2081270 Company BP EXPLORATfON (ALASKA) INC Initial Glassll'ype DEV / PEND GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 PermitfEeattached - -- - ---------- -- ----- -- - ----- NA- - ----- -- -- - ---- - - - --- - ------- 2 lsasenombBrapproRnate - ----- ------ ----- - --- YeS----- ---------------------- ---------------------------------------------- 3 Unique well-name andnurober------ - - - - - - ----Yes------ - -- ------ - ------- --- -- -- - - -- ------ -- 4 Well locatedlna-defined_pool -------------- -- -- - -- ---- -- -Yes - ---------- - - ------ - ------- - - -- -- - - 5 VVaIIIQCatedP[operd[stanoef[omdr[Ilingpnitboundary-----.------- -_-------Yes------ -------------------------------------------------.-------------- 6 Well locatedPtoperd[stanoefromottlflrwells--------------------- --------Yes----.- -------------------------------------- ------------------- - ----- - -- 7 SutTcientacrsageayailablain_dti[lingunit_____-_______________ _________ Yes--_-_. _2569 acres,____--_.__________-____---_---_----_--_--__-- ----------- 8 If deviated~is+MellborePlatiocluded - - -- - -- Yes------ --~---- ------ -- ----------- --- ----- -- - --- -------- 9 Qperatoronlyaffectedparly------ - - - - - ----- YeS---- - - --- - -- ----- - ------ - -- -- - ----------- 10 Opetatorbas.apP[opr[atef2ondinforCe------------------------ ---------Yes----. _BlanketBond;~61g419&..--.-------------------------,-------------. __._._ 11 Permltcanbe[ssuedwlthoutconsen(ationorder...-------------- ---------Yes------ -----.------------------------------------------,-------------____-- Appr Date 12 Permit Fan be[ssuetlwithauladministrative_approval---------------- ---------Yes.----- ----------------------------..-------------------------------,-. ---- ACS SI1212008 13 Can permit beaRRrovedbaforel5•day-wait______________________ _______-Yes______ ______---_--_,--__--_____-_._--_-----__.--------------------_--_-- 14 Welllocatedw[thinareaartdstrataapthor[zedbylnjectionOrder#(ps~tlQ~in-comments)(For--NA------ -----------------------------------------,----------------------- 15 Ahwells_with[n114.roileatea_ofreyiewidentitied(Por&etvicewellonly).----- --,------Nq------ ------------------------------------..---------------------------- 16 Pre-producedinjectoeduratfonofpreproductionlesgthan$months(Forserv[cewellonlyl---NA---_-- -_--.____--_---_---___--_--_--_-------------------------------- 17 .Konoonven,gas-conformstQ AS31,05,030Q.1.A)~Q.2.A-D).- -- - ------ -- NA------ ------ --- ---- - -- -------- ----------- - -- -- --- --- - Englneering 16 Conductorst~ing-prov[ded-------------------------------- ----------NA------. -GorlduotorsetlnY,01(17;~-0$5)•--------.---.----------------------------------- 19 Surface-cagingproiectg allknovmUSDWg___--------_---_--. ___.-__ NA_______ _Allaqu[fergexempted,-AEO1.--_--_--_---_--_------------------------____-- 20 CMT-vo[adequate_t9circu[at~onconductor8 surf-csg--------------- ---------NA------- -Surfas~oasingset inY-01.------------------------------------------------ 21 CMT_voladequatetolie-[nlongstringto_surfcgg___________________ __________ryA______ _Product[on_casingget[nY-01,_-____-______-__-.____--------------.__---_ 22 CMT will coverall known-Productiveboruorts_____________________ _________No-_--___ .Slottedlinercomplet[onplanned.-__--__...______-__-___-__-__--__--_-___-__-__ 23 Casing designs adequate for G, T f3 & permafrost- - . - - _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ . _ Qrigina[ well met design specificat[ons• _ NA for glotied liner._ _ _ _ _ - _ _ _ _ _ - --------------------- 24 Adequate tankage_or reserve Pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ . - _ - -Rig equipped w[th steel pits. No-reserve p[t planned.- AIl_waste-to approved d~Rosal well(s), - . _ _ _ _ _ _ _ _ _ _ _ 25 Ifa_re~dril[,bas-a10.40$fQrabandonmentheen appoved___________ _________NA------- --------------------------.----------------.--..----------_--_- - 26 Adequate_we[Ikote geparation_propoged_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - - - . - _ Proxim[ty analy[s performed. _Nearestsegment is_retained-portion gf Y-OtA and paths diverge. - - - _ _ . _ _ _ _ _ 27 If dtverterraqui-red, does itmeet regulati9ns_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _KA_ _ _ - _ _ _ . gQP staokwiU al[eady_be in place, . _ _ _ _ _ _ _ _ . Appr Date 28 Drilling fluid Rrog~m sehemat[c_& equip list_adequate- - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ _ Ma>amuro expected formation pressure 6,9 EMW, MW planned $.$ ppg. - - _ - - - _ - - - - - - - - - - _ - - _ - - - TEM SI13I2008 29 SOPEs,_dotheymeetre9ulation - - -- - - _ - Y~----- --- -- -------- - -------- --- -- - -- /~ ' 30 13OPE_press eating appropriate;-test to-(put psis [n comments)- - - - - - - - - - - - - - - - - - - - Yes _ - - - -------- _ MASP calculated a} 2262 psi. $500_psi-BOP test planned, _ - _ _ - - _ _ _ - _ _ - - - _ - - _ - . - - - ~~ ~~ 31 Choke-manifoldcon7PlieswlAPI-RP-53(May84) --- - --- - - - Yom- --- --- - -- --- -- -- ---- ---- - -- --- --- --- -------- bbd 32 VYorlcv+i[I9ceurwithoutoperationshutdovm_____--__-___-_-_- _________Yes------ -----------.-------------------------------------------------_-_--- 33 Ig presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - H2S is reperted_at Y pad• .Mud- shegld prec{ude [i2$ on rig._ Rig hag senserg $nd alarms. _ - - - - _ - . _ _ _ _ _ _ _ 34 _Mechanicalcondit[onofyiel!$vr[thinAQRyer[fied(F4[servic;awe[lonly)-.-- -------NA------- ------------------------------------------ Geology 35 Permit can be [slued wlo hydrogen suN'Memeasures - - - - - - - - - - - - - - - - - - - - - - No- _ _ _ _ _ _ _ Max H2$ level on Y-98A=3Qppm_ on 4119108; well Y~28=200ppm 8129196._ _ _ - - _ _ - - _ - - . _ . - - _ _ _ _ _ _ _ _ 36 Dataptesentedonpotentialovetpregsurezones---------------- ---_-__--Yes------ ----------------------------------------------------------.____,-- Appr Date 37 Se[smic_analysisofshallowgaezones_____________________-_ -_ NA------- ----------------------------------------------- -------- ACS 8I12I2008 38 Seaked_conditionsurvey_(ifoff-gho[e)------------------------- --------- NA------- ------------- ---- - - - 39 ContaCtnamelphoneforweekly_progressreporis[a~splolatoryonlyl-------- --------Yes-.---- -GregSarber-•564.4$30--------------------------------------.------------- Geologic Date: Engineering Date Pub6 Date Commissioner: Co issioner. Co r ~~- ~ ~~-~ ~-~y~-o8 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 effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 09/03/02 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/10/10 2232624 01 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!ii!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 13999.5000: Starting Depth STOP.FT 15623.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: Y-09AL1 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. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 10 Oct 2008 API API NUMBER: 500292057960 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. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Sperry GR MWD dated 28 Jun 1997 per Cole Abel with BP Exploration (Alaska), Inc. The MWD data is the PDCL for this well and was shifted to the MWD above the Kick Off Point of 14291 feet MD. (8) The sidetrack was drilled from Y-09A 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 14975 feet MD (8964.8 ft to 8953.4 ft TVDSS)was logged 24 hours after drilling run 4. (11) The interval from 15584 feet to 15621 feet MD (8961.1 feet to 8959.7 feet TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 14011, 14008.7, ! -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 14286.5, 14288.8, ! 2.28027 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 88 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 from Sperry GR MWD per Cole Abel with BP Exploration (Alaska), Inc. The MWD data is the PDCL for this well and was shifted to the MWD above the Kick Off Point of 14291 feet MD. * 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: 91 Tape File Start Depth = 13999.500000 Tape File End Depth = 15623.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 104 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 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: 180 Tape File Start Depth = 14002.000000 Tape File End Depth = 15621.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 193 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/10/10 2232624 O1 **** REEL TRAILER **** MWD 09/03/02 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 RPD RPS 13999.5000 -999.2500 -999.2500 -999.2500 -999.2500 14000.0000 -999.2500 -999.2500 -999.2500 -999.2500 14100.0000 -999.2500 -999.2500 -999.2500 -999.2500 14200.0000 -999.2500 -999.2500 -999.2500 -999.2500 14300.0000 26.5203 1.0000 2000.0000 8.2548 14400.0000 30.5000 90.4199 7.2782 6.3100 14500.0000 60.2404 110.0234 6.3730 5.9836 14600.0000 75.4424 143.4434 10.3653 5.1539 14700.0000 84.6945 65.9215 4.5279 4.0521 14800.0000 48.4219 110.1621 11.2852 12.2326 14900.0000 50.7992 123.9809 11.0360 10.6580 15000.0000 34.7004 97.9000 9.4944 9.4210 15100.0000 45.6395 201.3701 7.0512 6.7674 15200.0000 51.8019 73.8203 11.4686 12.2570 15300.0000 35.5791 100.2652 5.8716 5.8508 15400.0000 32.3596 130.1199 5.6084 5.7462 15500.0000 27.2984 174.5691 4.6584 3.8122 15600.0000 -999.2500 94.3201 -999.2500 -999.2500 15623.5000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13999.500000 Tape File End Depth = 15623.500000 Tape File Level Spacing = 0.500000 RAD -999.2500 -999.2500 -999.2500 -999.2500 2000.0000 8.0294 5.4570 2000.0000 5.6617 6.7070 9.3398 9.1620 7.4012 9.0530 5.7400 5.1460 6.1074 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 -999.2500 3.4346 8.3968 6.7188 9.3823 4.1009 11.0870 12.0392 9.8600 7.2322 10.6316 5.8842 5.7344 5.4636 -999.2500 -999.2500 • ~ Tape File Depth Units = feet r~ Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 14002.0000 -999.2500 -999.2500 -999.2500 -999.2500 14002.2500 -999.2500 -999.2500 -999.2500 -999.2500 14100.0000 -999.2500 -999.2500 -999.2500 -999.2500 14200.0000 -999.2500 -999.2500 -999.2500 -999.2500 14300.0000 44.9000 5.4000 0.9880 6.3540 14400.0000 33.1000 45.1000 7.4930 6.5650 14500.0000 58.2000 98.8000 6.4530 6.0850 14600.0000 70.1000 123.3000 4.7000 4.2270 14700.0000 52.1000 78.0000 3.8790 4.0170 14800.0000 48.3000 45.7000 11.3560 11.8860 14900.0000 41.8000 134.9000 11.1570 10.5830 15000.0000 36.9000 96.8000 9.3890 9.2060 15100.0000 41.0000 170.8000 6.5840 6.0570 15200.0000 50.4000 77.8000 11.3890 12.3860 15300.0000 30.4000 68.2000 6.3410 6.6270 15400.0000 28.7000 130.5000 5.5080 5.6020 15500.0000 27.7000 143.2000 4.4590 3.6300 15600.0000 -999.2500 97.0000 -999.2500 -999.2500 15621.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 14002.000000 Tape File End Depth = 15621.000000 Tape File Level Spacing = 0.250000 • RAD -999.2500 -999.2500 -999.2500 -999.2500 1756.2549 8.1110 5.3850 4.1450 4.4940 6.8910 9.4360 9.1700 7.4190 8.9230 5.8620 5.1460 5.9600 -999.2500 -999.2500 RAS -999.2500 -999.2500 -999.2500 -999.2500 5.0390 8.5440 6.7840 4.2290 3.7380 11.3570 12.1580 9.8100 6.9650 10.5510 6.1230 5.6540 5.2190 -999.2500 -999.2500 • • Tape File Depth Units = feet s Tape Subfile 4 is type: LIS