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207-102
lma~e Project Well History File Gover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available ire tfle original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~C ~ ~ - ~~ ~. Well History File Identifier 4rganixing (done ~,wa.ded iuumiiuiiuiu Re,~a~~e~~ iuiuumiiuuii R CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIG TAL DATA Diskettes, No. ` ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable} ^ Logs of various kinds: NOTES: BY: Maria Date: ^ Other:: I ~ Qg /s/ Project Proofing III ll~lllVIII III~I BY: Maria Date: ~,., ~ /s/ Scanning Preparation ___~___ x 30 = 1~~ + ~ =TOTAL PAGES__ c BY: Maria Date: (Count does not include cover sheet) ~~,! ~ °a,., J ~ ~ /s! Production Scanning Stage 7 Page Count firom Scanned File: ~ (Count does include c er sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ a,~ / ~) ~ g /s/ ~/~/~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO 1 ~ BY: Maria Date: /s1 Scanning is complete at this point unless rescanning is required. II I II f) I) I ~I II ~~ III ReScanned III II'II) VIII II I~) BY: Maria Date: /s/ Comments about this file: Quality Checked III ~IIIII III II'I II 10/6/2005 Well History File Cover Page.doc • • v~,.' _ _W ,~ . ~.;: ~~. ~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: K-14A 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) I LAC Job#: 1662127 Sent by: Catrina Guidry Date: 12/11/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (90~) 26~-6623 ~~ BAKER ~a~Raac~ _.. s~oGc ~~. Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 COMPANY WELL NAME FIELD • ~ ®. BAKER Nuc~NEs Baker Atlas PRINT DISTRIBUTION LIST BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH K-14A STATE ALASKA PRUDHOE BAY UNIT DATE 12/11/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1662127 Copies of Copies Digital Copies of Copies igital Each Log ofFihn Data Each Log ofFi Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE. AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston Texas 77073 Y"his Distribution List Comnleted Bv: `~~~ ~0~-10~ ~~~ ~~ ;~~ ~ . 4 ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2071020 Well Name/No. PRUDHOE BAY UNIT K-14A Operator BP EXPLORATION (ALASKA) INC A PI No. 50-029-21752-01-00 MD 12634 TVD 8913 Completion Date 11/17/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional S ey Yes DATA INFORMATION Types Electric or Other Log s Run: MWD, DIR, RES, GR, MCNL / GR !CCL, ROP. RACLX / RACHX, RP (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr i~ Data Digital Dataset Log Log Run Interval OH / T e Med/Frmt Number -- -- --_..-- - Name - -- - ---- ------- Scale Media No Start Stop CH Received Comments D D Asc Directional Survey --- 11192 12634 Open ----- 1/10/2008 ---- ----- 1 pt Directional Survey 11192 12634 Open 1/10/2008 ~D C Las 15912 Gamma Ray 10834 12634 Open 1/24/2008 LAS, GR and ROP in PDF '~ form Graphics D C Las 15920 Gamma Ray 1163 12554 Open 1/24/2008 LAS, CCL, FNCL, GR, NCNL,GR PDF form / Graphics E C Lis 16693 Neutron 10226 12543 Open 7/28/2008 LIS Veri, MCNL, CNT og Neutron 5 Blu 10234 10538 Open 7/28/2008 MCNL, Mem Lee, CCL, GR, CNL 15-Nov-2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y r N Daily History Received? Chips Received? -~f-Pl- Formation Tops / N Analysis .~J-PIS Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2071020 Well Name/No. PRUDHOE BAY UNIT K-14A MD 12634 TVD 8913 ompletion Date 11/17/2007 Compliance Reviewed By: ____ _ __ - _____. Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21752-01-00 Completion Status 1-OIL Current Status 1-~OI`L\ ~(~ UIC N Date: ® _! `!_y ~ _~ o7i2sioa ~chlumberger NO.4799 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WPII .Inh $ 1 nn rlo¢rrinfinn fleafn RI !`nlnr r`r1 G-29A 12096905 MEM PROD PROFILE ~ 07/18/08 1 Pi-04 12017505 PROD PROFILE 07/17/08 1 1 L-219 11999028 FLUID DENSITY LOG 07/16/08 1 1 L-205 11999021 USIT 06/17/08 1 1 X-16A 11978465 RST 06/03/08 1 1 K-14A 11628804 MCNL 11/15/07 1 1 rLGMJG MV n1YV •YLGNVG nGVGir'1 Di .71~.71YIIY67 NIVU flCl Vr11V11Vt1 VIVC I.VYT CHGr1 1 V: BP Exploration (Alaska) Inc; PetrotechnicaL Data Center" LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,~ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9 503-28 .8 ATTN: Beth j / Received by: Y ~"~ by BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Contents 18-13BPB1 I $'~'-loQ t5 q ~ S- 18-13BP62 l $'~-r6o l S~il~ 18-13BP63 l$~-l(~ lS9i~ H-14B ~U'~ - I l (o t~ g / ~ 14A ~~-_ 102 ! 59ao -214 u=~ao~- tea 15~c~1 Date 02-08-2008 Transmittal Number:92927 Dortch at the PDC at 564-4973 ~a~,~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 by • Date 01-24-2008 Transmittal Number:92926 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv questions, please contact Douglas Dortch at the PDC at 564-4973 Contents ~O'~- lad ~ ~ Sql~ JO'a-- l~`~ A t541~ 14A c')C~'~ tiDa ~'159/a I-13A J~C.aD~-- ~ l~l '~ t 5~1~ -2oA u= ~ ao'~- - < < 3 '~ ~ Sri ! Y Y Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~ ~il~- '> >~ ~3 ~'~~ ~7a~ ~ lias ~or~s, ~~r~ani~~~a ~~~W~~~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 • BAKER HUGHES INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 To Whom It May Concern: January 18, 2008 Please find enclosed directional survey data for the following wells: 18-13BPB1 18-13BPB2 18-13BPB3 18-13B K-14A H-24A~ 15-04BPB 1 15-04B 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:_ ~ U~~~ ,State of Alaska AOGCC DATE: .~ t~ a .,,,r.-. ~~.~ Cc: State of Alaska, AOGCC ~~~~ ~~~ ~~~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION T~~~EiVE ~IEC 1 4 2Q07 WELL COMPLETION OR RECOMPLETtON REPORT AND LOG Alaska Oil ~ Gay ~~~~ w.,~~.i:;.^r 1 a. Well Status: ®Oil ^ Gas ^ Plugged ~ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Cla `~ ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 11/17/2007 ~ 12. Permit to Drill Number 207-102 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/12/2007 13. API Number 50-029-21752-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/14/2007 14. Well Name and Number: PBU K-14A 1909 FNL, 4106 FEL, SEC. 04, T11 N, R14E, UM Top of Productive Horizon: 3617' FNL, 2956' FEL, SEC. 09, T11N, R14E, UM 8. KB (ft above MSL): 53.20' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3674' FNL, 2789' FEL, SEC. 09, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 12626' 8911' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 671441 y- 5975311 Zone- ASP4 10. Total Depth (MD+TVD) 12634' 8913' 16. Property Designation: ADL 028303 TPI: x- 672769 y- 5968352 Zone- ASP4 Total Depth: x- 672937 y- 5968299 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No ubmit electronic and rinted information er 20 AA 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): , MWD, DIR, RES, GR, MCNL / GR / CCL, ROP, RACLX / RACHX, RPCLX, RPCHX ~./60iJ~~1o?a?~jyQ ~6/p~ 7Y6 22. 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 20" Conductor Surface 110' Surface 110' 8 cu ds Concrete 13-3/8" 72# L-80 / S-95 Surface 2720' Surface 2678' 17-1/2" 4185 cu ft Arctic Set II -5/8" 47# L-80 Surface 10830' urfa 338' 12-1/4" 2375 cu I ss'G' 7" 26# L-80 3968' 10467' 3611' 8081' 8-1l2" 1095 cu ft Class 'G' 7" 26# L-80 10567' 1' 8151' 8610' 8-1/2" 414 cu ft Class'G' -1 /2" x 3-3116" 8.81 # / 6.2# L-80 1 554' 12634' 142' 891 4-1 /8" 104 cu ft 23. Open to production or inject ion? ^Yes ®No 24. TURING RECORD If Yes, fist each interval open (MD+TVD of Top & Bottom; Perforation Slze and Number): SIZE DEPTH SET MD PACKER .SET MD 2" Gun Diameter, 6 SPF 4-1/2", 12.6#, 13Cr80 10435' 10348' MD TVD MD TVD 4-1/2", 12.6#, L-80 10463' - 10662' 10501' 12475' - 12625' 8857' - 8910' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 2200' Freeze Protected with Diesel 26. PRODUCTION TEST Date First Production: December 16, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 12/9/2007 ROUTS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 680 GAS-MCF: 677 WATER-BBL: 14 CHOKE SIZE: 93 GAS-OIL RATIO: 994 Flow Tubing Press. 220 Casing Press: 1100 CALCULATED 24-HOUR RATE• OIL-BBL: 2041 GAS-MCF: 2030 WATER-BBL: 43 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^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. pp ``~~ ~11~~.~...., ~ ~ VI +I~Lf .I41Y ~. None pp //~~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE C7 2t'~. GEOLOtiIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Sadlerochit 10984' 8447' None TCGL / TZ3 11079' 8513' BCGL / TZ2C 11179' 8582' 23SB / TZ26 11283' 8647' 21 TS / TZ2A 12180' 8744' Top of Zone 1 B 12443' 8845' Top of Zone 1A 12566' 8890' Formation at Total Depth (Name): Zone 1A 12566' 8890' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. Signed So ra Stewman Title Drilling Technologist Date I ~ " +~'« PBU K-14A 207-102 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Dulling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRO,~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND 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. Irene 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 .TREE= 4-1/8" CAMERON WELLHEAD= MCEVOY A~TUATOR,= AXELSON KB. ELEV = BF. ELEV = 53.20' 25.62. __ KOP = 2055' Max Angk: = 88 (c~ 11389' Datum MD - 11587 Datum TV D = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" 2719' TOPof 7" Lnr 3968' 4-112° HES X NY3', 1L7- 3.8#3" F'acke:r E3aker .`>-3 9<:a• 7'° x ~1 'I f:"'" .1...1 `~" 't 2. l~-B<~, 'I 3Cr3~, .i3'? ~u`~%bpf, a = 3 ~~;3'> r~~ i~'Jrtc:C1 ~~? <~" X s1-1f<" y ~-."y7 ~'i° X sj...1 f2" l~V u"?'aii ckt Minimum ID = 2.00" ~ 'i° 3-12~' 3af°I.. TOP OF 7" LNR ~~ 10567' ~~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" ~~ 10622' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 10827' PERFORATION SUMMARY REF LOG: BHCS ON 09/26/87 ANGLE AT TOP PERF: 49 ~ 11508 Note: Refer to Roduction DB for historical pert data SQE SPF INTERVAL OpnlSgz DATE 2" 6 12475-12625 Opn 11 I(3:07 PBTD 11756' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 11800' .-~, h i`i" y © „i} q" i " 9 ,1 E , 2023' X Nipple ID = 3.813 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3104 38 OTIS RA 3 7517 45 OTIS RA 2 10237 46 OTIS RA 1 10345 46 OTIS RA ~ 10381 ° ~~`I- t i°~' ~F~"': i`. I`1~'. 'l~ ; 3 t... '>> ` 10484' -{7BG SEAL ASSY SBR E.{r3PP .~.r€ri~r~er~t,:rkr) 10500' 9-5/8" X 4-112" TNV PKR 10547' 4-1/2" OTIS X NIP, ID = 3.813" '40555" 7t36'«F3-1f2" I..IdP 1£3596' :3.5° X Nilr 28'13" _~ 10586' 4-1 /2" OTIS XN NIP, ID = 3.725" 10622' 4-112" TBG TAIL ID= 3.958" 1 Q626' ELMD TT LOGGED 10/30!87 10975' 7" MARKER JOINT ~°°~ .°.° ~ 11100` Tcxp of C;evx-~lrt ~~ t ,,,r° 11202' 3--1t2'" x 3-3f1~" XC - ~ PBTD 12826' _, - ~rr '-1f2" x 3 311`6" c;rv~'ed ancf perfe I 11220' Mechanical Wliilasiack 11730' HFISH - KINLEY CUTTER DATE REV BY COMMENTS DATE REV BY COMMENTS 09/30/87 ORIGINAL COMPLETION 07!16/01 RN/KAK CORRECTIONS 11/16/02 AS/KAK PERFCORRECTIONS 08/16/03 CMO/TLP KB ELEV AND MAX ANGLE 08/16/03 JLA/KK WANER SAFETY NOTE 11116107 GJS CTD S'sdetrack (K-14A) PRUDHOE BAY UNff WELL: K-14A PERMff No: 2071330 API No: 50-023-21752-01 SEC 4, 711 N, R14E, 1909' FNL 8 4106' WEL BP Exploration (Alaska) BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 .Date From - To Hours Task Code NPT Phase Description of Operations ~~ 11/8/2007 11:00 - 14:00 3.00 MOB P PRE Prep rig to move to K-14A 14:00 - 14:30 0.50 MOB P PRE PJSM for rig move 14:30 - 15:30 1.00 MOB P PRE Move rig from K-08 to K-14 15:30 - 16:00 0.50 MOB P PRE Align rig and spot over K-14 RIG ACCEPTED ON K-14A @ 16:00 16:00 - 20:00 4.00 MOB P PRE Dress cellar, install hardline into reel, continue to spot equipment, remove tree cap, NU BPOE 20:00 - 20:30 0.50 MOB P PRE Fill stack, PJSM for BOPE testing 20:30 - 00:00 3.50 BOPSU P PRE BOPE test, 250 psi Low - 3500 psi High - AOGCC notified - witness test waived by Chuck Sheve 11/912007 00:00 - 01:30 1.50 BOPSU P PRE BOPE Test 250 psi low / 3500 psi high 01:30 - 01:45 0.25 RIGU P PRE PJSM for pulling coil from reel throught horses head and injector 01:45 - 02:50 1.08 RIGU P PRE Pull coil to injector/ roller slightly out of adjustment, fix roller, cont. pulling coil through injector 02:50 - 04:30 1.67 RIGU P PRE Stab into injector, stuffing box, connect hydraulic lines, recut 04:30 - 04:40 0.17 RIGU P PRE 04:40 - 05:03 0.38 RIGU P PRE 05:03 - 05:30 0.45 RIGU P PRE 05:30 - 07:30 2.00 RIGU N PRE 07:30 - 08:30 1.00 RIGU P PRE 08:30 - 12:00 3.50 RIGU P PRE 12:00 - 12:25 0.42 STWHIP P WEXIT 12:25 - 12:45 0.33 ZONISO N WEXIT 12:45 - 12:55 0.17 ZONISO N WEXIT 12:55 - 13:10 0.25 ZONISO N WEXIT 13:10 - 15:00 1.83 ZONISO P WEXIT 15:00 - 16:40 1.67 ZONISO P WEXIT 16:40 - 17:00 0.33 ZONISO P. WEXIT 17:00 - 18:22 1.37 ZONISO P WEXIT 18:22 - 19:55 1.55 ZONISO P WEXIT 19:55 - 20:10 0.25 ZONISO P WEXIT 20:10 - 00:00 3.83 ZONISO N WEXIT 11/10/2007 00:00 - 03:00 3.00 WHIP P WEXIT coil, protect eline, pump 5 bbl McOH Filling coil Test inner reel valve Slack management, pumped 40 bbts, got it to move a couple times on first pump up at 4.2 bpm. Cut 55' of coil, 10' Eline Repair SLB injector packoff. Probably damaged by being pressurized, thinking coil was lower in the stuffing box then it actually was. RU and test lubricator to 1000 psi. Pull BPV. LD lubricator. Cut coil and E line. Megar E line. Install coil connector and pull test CTC. MU Baker MHA.MU nozzel. RIH wo pump to 2100' O-ring on injector leaking POH. Install new O ring. RIH to 2100'. Continue to RIH. No returns. until 10900' then only speratic returns. Up Wt at 11000'. 56K Continue RIH to 11700 Pump 5 bbl Hi Vis Bio pill . POH laying in 30 additional bbl of pill. Lost 60 bbl before we had fluid to surface.POH to 6600. Flo Check . A few burbs but no flo. POH to surface PU Baker Thru tubing Whipstock, CoilTrak Circulate 6bbl at surface before returns (Fluid level 260' down in 5-1/2" tubing). Repair SLB injector, 3 -SLB mechanics working to adjust gripper position and tension RIH with whipstock OA=O, IA= 0, WHP=44, PVT=218 bbl, 0.53 bpm in, 0.93 bpm out, tubing speed 85 fpm Printed: 12/4/2007 8:53:40 AM l~ BP EXPLORATION <Page 2 of 8 Operations Summary: Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/10/2007 03:00 - 03:22 0.37 WHIP P WEXIT Begin tie-in at 10,970 and end at 11,031. Add 5.5'to SLB coil depth measurement. RIH to 11237.5 (bottom of WS -length of WS 17.5- TOWS at 11220'MD') Circulating .5 bpm/900 psi. Orient WS to high side. Close EDC. Check up weight 03:22 - 03:43 0.35 WHIP P WEXIT Bring up pump to 3400 psi, pressure dropped to 2000 psi. Kill pump. Set down, tag WS. POOH seems to be pulling heavy. Pull up 150'. Decide to go back and tag TOWS. WS tagged spot on at 11220 with DWOB showing good set. 03:43 - 06:45 3.03 WHIP P WEXIT POOH pumping at 1bpm, might be losing a 0.1 bpm, but hole looks pretty tight. PVT = 248 b, OA=O, IA=10, WHP=22, Cir Press 1176, pulling a bit heavy at 51 fpm (chrome tubing). POH to serface 06:45 - 07:30 0.75 WHIP P WEXIT LD WS setting tools. 07:30 - 09:00 1.50 WHIP P WEXIT LD Baker MHA.Cut coil due to flat spotting. Intatll new coil dimple connector. MU SLB wire Anchor. Pull test to 38K, PT to 4500 psi. 09:00 - 09:15 0.25 ZONISO P WEXIT MU cementing stinger. 09:15 - 11:30 2.25 ZONISO P WEXIT RIH.Tag WS @ 11221 and Paint flag. Up Wt 51 K. 11:30 - 11:45 0.25 ZONISO P WEXIT PJSM for cement job. 11:45 - 13:50 2.08 ZONISO P WEXIT Circulate .6 BPM @ 960 psi. Pump 5 bbl H2O. PT cementers to 3700 psi. Pump 30 bbl 1/1 returns. Pump 5 H2O. Swap to Bio. Displace with rig pump 2..37 bpm /2.34 bpm @ 2220 psi. Circulate to nozzel. Shut in backside Bullhead @ 2.25 bpm @ 2820 psi 13 bbl away WH Presssure increase to 2400-2600. After 28 bbl Open backside and circ 1.5 bpm @ 1400 psi, Lay in 2bbls PU to 10600'. Break circulation to assure well is fluid packed. Pressure well to 500 psi with 1.1 bbls Pressure well to 677 psi with 1.2 bbls Pressure well to 1177 psi with 1.9 bbls Pressure well to 1600 psi with 2.9 bbls Pressure well to bleed off to 1223 psi in 10 min. = 2.6 ppg EMW got back 1.9 bbls .One bbl squeezed away 13:50 - 15:10 1.33 ZONISO P WEXIT Wash to top of WS. Circualte bottoms up.2.52 bpm @ 2200 psi. TAg WS at 11221. 15:10 - 18:00 2.83 ZONISO P WEXIT POH 18:00 - 18:15 0.25 ZONISO P WEXIT Flo Check 18:15 - 19:25 1.17 ZONISO P WEXIT Lay out SLB wireline anchor, anchor screw stripped, tap out, cut 5' coil, MU SLB coil connector 19:25 - 20:42 1.28 ZONISO P WEXIT Headup eline coif, pump to assure coil not frozen, pressure test CT connector 20:42 - 21:40 0.97 STWHIP P WEXIT PU Milling BHA, Stab over well, Surface Test MWD 21:40 - 23:30 1.83 STWHIP P WEXIT RIH, PVT=273 bbl @ start of TIH, Tubing Speed = 107 fpm, flow in 0.26 bpm, flow out = .85 bpm, Cir Pressure = 635 psi, OA = 0, IA=4, wellhead pressure = 18. 23:30 - 23:48 0.30 STWHIP P WEXIT Tie-in with gamma-ray. PVT=331 bbl, Tubing Speed 2 fpm, flow in 0.22 bpm, flow out = .22 bpm, Cir press = 795, OA = 0, IA=O, wellhead pressure = 18 psi. Add 2.3' to SLB depth for tie-in. 23:48 - 00:00 0.20 STWHIP P WEXIT RIH to top of WS 11/11/2007 00:00 - 02:20 2.33 STWHIP P WEXIT Tag pinch point with low flow rate, PU 10', bring up pump to 2.7 bpm, Cir Press 2480 psi free spin, RIH 3 fpm, tag pinch point Printed: 12/4/2007 8:53:40 AM ,- 1- BP EXPLORATION Page 3 ofi 8 Opell•atiolns Summalry Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11 /17/2007 Rig Name: NORDIC 1 Rig Number: N1 .Date From - To Hours Task Code NPT Phase Description of Operations 11/11/2007 00:00 - 02:20 2.33 STWHIP P WEXIT @ 11,224.1' ,multiple tries w/ hard stalls (2500 up to 3800 psi) like hanging up uphole then release with a quick slide the last couple of feet down the whipstock. PVT = 328 bbl, IA=250 psi, OA=O psi, WHP=50 psi, Flow in 2.5 bpm, flow out 2.52 bpm 02:20 - 03:00 0.67 STWHIP P WEXIT Park at 11224.0 until DWOB starting to take a little weight so start of milling at 11224.1, free spin = 2660 psi, milling = 2780 psi. DWOB 0.64K Ib, PVT = 315 bbl, IA=262 psi, OA=O psi, WHP= 51 psi. 03:00 - 04:24 1.40 STWHIP P WEXIT Milling 11225.0 - 11226.0 MD, PVT=315 bbl., Cir press = 2812 psi, 2.72 bpm in, 2.77 bpm out, OA=O, IA=366, WHP= 51, DWOB increase from .64K to 2.5K over the 1' of milling. 04:24 - 05:32 1.13 STWHIP P WEXIT Milling 11226.0 - 11227.0, PVT=315 bbl., Cir press = 2809 psi, 2.72 bpm in, 2.77 bpm out, OA=O, IA=420, WHP= 48, DWOB 2.7K 05:32 - 06:25 0.88 STWHIP P WEXIT Milting 11227.0 - 11228.0, PVT=315 bbl., Cir press = 2809 psi, 2.72 bpm in, 2.77 bpm out, OA=O, IA=420, WHP= 48, DWOB 2.7K 06:25 - 07:00 0.58 STWHIP P WEXIT Milling 11228.0 - 11229.0, PVT=316 bbl., Cir press = 2870 psi, 2.72 bpm in, 2.77 bpm out, OA=O, IA=470, WHP= 48, DWOB 2.8K ' 07:00 - 11:00 4.00 STWHIP P WEXIT Milling 11230.0 - 11232, PVT=315 bbl., Cir press = 2830 psi, 2.75 bpm in, 2.77 bpm out, OA=O, IA=528, WHP= 48, DWOB 2.11K Broke out in open hole at 11232. 11:00 - 13:00 2.00 STWHIP P WEXIT Drill 10 open hole .2.79/2.78 bpm at 3060 psi. Drill to 11244.7 13:00 - 14:15 1.25 STWHIP P WEXIT Backream to 11219. Three passed OK. 2.5/2.5 bpn at 2424psi. Shut down pump .Dry tag OK. 14:15 - 14:40 0.42 STWHIP P WEXIT Swap well to Flo Pro .Circulate Flo Pro to Bit. 14:40 - 17:00 2.33 STWHIP P WEXIT POH swapping to Flo Pro.POH to 1459' 17:00 - 17:20 0.33 STWHIP N RREP WEXIT Replace peanut on injector chain. 17:20 - 18:00 0.67 STWHIP P WEXIT Continue to POH to surface. 18:00 - 18:50 0.83 STWHIP P WEXIT LD window milling assy .Window mill 3.74 No Go, String mill 3.78 No Go. 18:50 - 22:00 3.17 STWHIP N SFAL WEXIT Tee off hydraulic pump line at SLB power pack to reel for greater volume, adjusting injector skates, pipe straightener and gooseneck, rotate stuffing box 180 degrees 22:00 - 22:45 0.75 DRILL P PROD1 MU Build BHA #5 with 4.125 BC bit, 3.1 degree mtr, coil trak tools, SLB dipple CTC 22:45 - 00:00 1.25 STWHIP N SFAL WEXIT Replacing sheared cotter pins on injector 11/12/2007 00:00 - 02:00 2.00 DRILL P PROD1 RIH with build BHA #5 to 10868' 02:00 - 03:50 1.83 DRILL P PROD1 Madd Pass and tie-in from 10868' to 11030' at 110fph, .53bpm, y-~, ,,~-- 1 ,..~ -.~~ ~'' a (~{ ~ 1200psi, Correction SLB .2', Baker .6' 2.50 DRILL P PROD1 Dir Drill from 11247' - 11440', TF at 50-100L, 2.60/2.59bpm, 3660psi, FS 3310psi, 2.60psi, rop 100-140fph, ECD 10.07ppg, pvt 273-285bb1s, IA 150-300psi. Drill to 11440 EOB. UP Wt 45K. 06:20 - 09:15 2.92 DRILL P PROD1 POH for lateral BHA. 09:15 - 10:45 1.50 DRILL P PROD1 Dial downmotor from 3.1 to 1.2. Bit 1:1. 10:45 - 13:15 2.50 DRILL P PROD1 RIH to 11250'. 13:15 - 13:20 0.08 DRILL P PROD1 log tie-in to RA tag in WS. Correction +1' MWD. 13:20 - 13:25 0.08 DRILL P PROD1 RIH to TD 13:25 - 15:30 2.08 DRILL P PROD1 Drill 2.4 / 2.42 bpm @ 3130 psi.FS, Having vibration issues. Adjust pump rate.To 1.98 /1.98 bpm @ 2700 psi, 2460 psi FS, W06.8K,Rop 75, Printed: 12/4/2007 8:53:40 AM C_ BP EXPLORATION Page 4 of 8 Operations Summalry Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2007 15:30 - 16:00 0.50 DRILL P PROD1 Drill from 11560' - 11600', TF 74L, 1.92/1.91 bpm, 2670psi, FS 16:00 - 16:30 0.501 DRILL i P 16:30 - 19:00 2.50 DRILL I P 19:00 - 19:30 I 0.501 DRILL I P 19:30 - 23:10 I 3.671 DRILL I P 23:10 - 23:25 I 0.251 DRILL ~ P 23:25 - 23:35 0.17 DRILL P ',11/13/2007 0:00 - 010:05 10.081 DRILL I P 01:05 - 03:22 I 2.281 DRILL I P 03:22 - 04:50 I 1.471 DRILL I P 04:50 - 05:40 0.83 DRILL P 05:40 - 06:30 0.83 DRILL P 06:30 - 10:50 4.33 DRILL P 10:50 - 11:00 0.171 DRILL I P 11:00 - 11:50 0.83 DRILL P 11:50 - 13:45 I 1.921 DRILL I P 13:45 - 16:00 I 2.251 DRILL I P 16:00 - 16:15 0.251 DRILL I P 16:15 - 16:45 0.50 DRILL P 16:45 - 18:00 I 1.251 DRILL I P 2531 psi, 2..02bpm, rop 108fph, ECD 9.92ppg, pvt 285bb1s, IA 431 psi PROD1 Wiper to window PROD1 Drill from 11600' - 11750', TF 77 -87L, 1.92/1.91 bpm, 2970psi, FS 2500psi, 1.94bpm, rop 85 - 95fph, ECO 10.03ppg, pvt 285bb1s, IA 500psi PROD1 Wiper to 11240' MD PROD1 Drill from 11750' - 11,925', TF 60L, 2.1bpm in/ 2.47bpm out, 3400psi, FS 3050psi, rop 85 - 95fph, ECD 10.03ppg, pvt 278 bbls, IA 137psi (bled down from 530 psi) PROD1 100' Wiper PROD1 Drill 11,925'-11,950, HS TF, 2.7 bpm in/ 2.7bpm out, 3650 psi, FS 3350psi, rop 90 fph, ECD 10.03ppg, PVT=268, IA=315 PROD1 Wiper trip to tubing tail PROD1 Wiper to tubing tail 10,595'MD, RIH through window, tag w/ pumps off TF 20 L, reorient to HS, run cleanly through window, tie-in log (+3.5'), RIH, 2.3 bpm in/ 2.7bpm out, 3050 psi, 90 fpm, ECD 10.03ppg, PVT=264 bbl, IA=297 psi PROD1 Drill 11,950'-12,039, TF =55R-90L, 2.4 bpm in/ 2.4bpm out, 3500 psi, FS 2900psi, ROP 90 fph, ECD 10.2 ppg, PVT=268 bbl, IA=405 psi PROD1 Drill 12,039 - 12,069 while swapping to new Flo-Pro , TF =90L, 2.3 bpm in/ 2.3bpm out, 3500 psi, FS 3100psi, ROP 20 fph, ECD 10.2ppg, PVT=Mud Swap 500 bbl old/500 bbl new, IA=405 psi PROD1 Drill 12,069' MD - 12,100' MD, TF 180, 2.6 bpm in, 2.6 bpm out, 3330 psi, FS 3050 psi, ROP = 70 fph, ECD 9.8, PVT = 200 bbl and increasing because of mud swap, IA=132 psi PROD1 Wiper trip to window PROD1 Drill 12,100' - 12206', TF 150R, 2.04/1.95 bpm, 3075psi, FS at 2.04bpm, 2415psi, ROP 73fph, ECD 9.79, PVT 324bb1s, IA=107psi PROD1 100' wiper trip PROD1 Drill 12,206' - 12250', TF 130-80L, 2.50/2.44 bpm, 3575psi, FS 3080psi, ROP 73-106fph, ECD 9.79 - 10.Oppg, WOB 2k, PVT 324-318bb1s, IA 107-315psi, PROD1 Wiper thru tubing tail 10,600', opened EDC above window at 11200', Up Wt off btm 48K, no hole problems, opened EDC above window, RIH to 11207', closed EDC, run through window with slight bobble of 1-2k, Dn wt below window 20.2k, 12k do drag at 11295', no other hole problems PROD1 Drill 12250' - 12367', TF 95R, 2.62/2.60 bpm, 3250psi, FS at 2.62bpm, 3050psi, ROP 100 - 144fph, ECD 10.Oppg, WOB .5 - 1 k, PVT 326bb1s, IA 315psi, hole ratty do to formation changes - shale stringers PROD1 200' wiper trip PROD1 Drill 12367' - 12400', TF 102L, 2.30/2.30 bpm, 3900psi, FS at 2.30bpm, 3100psi, ROP 100 - 60fph, ECD 10.09 - 10.16ppg, WOB 4k, PVT 320bb1s, IA 450psi PROD1 Wiper trip to window, tie-in pass, correction of +2' SLB, +6' Baker, RBIH, 12k do drag at 11300', no other hole problems Printed: 12/4/2007 8:53:40 AM BP EXPLORATION Page 5 of 8 Operations Summary Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 .Date From - To Hours Task Code NPT Phase Description of Operations 11/13/2007 18:00 - 20:30 2.50 DRILL P PROD1 Drill ahead, 2.25/2.25 bpm, 3000-3500 psi, 90L TF, 2-3K DHWOB, 30 fph, 10.0 ECD, drilled to 12430'. Stacking weight, hard to make any hole. 20:30 - 23:30 3.00 DRILL P PROD1 POOH to check BHA. 23:30 - 23:45 0.25 DRILL P PROD1 SAFETY MEETING. Reviewed procedure, hazards and mitigation for UD Drilling BHA 23:45 - 00:00 0.25 DRILL P PROD1 S/B injector. L/D Drilling BHA #6. Bit rung out. Bit graded 7,6,1/16th out. C/O motor and bit. 11/14/2007 00:00 - 01:00 1.00 DRILL P PROD1 M/U Drilling BHA #7. Overall BHA length 66.06' 01:00 - 03:00 2.00 DRILL P PROD1 RIH w/ drilling BHA. 03:00 - 03:15 0.25 DRILL P PROD1 Run in clean through window. Tie in from 11250' - 11258'. +2' correction. 03:15 - 04:10 0.92 DRILL P PROD1 RIH clean to bottom. 04:10 - 05:30 1.33 DRILL P PROD1 Drill Zone 1 lateral, 2.40/2.40 bpm, 3500 psi, 100E TF, 1.5-2.5K DHWOB, 130-150 fph, 10.1 ECD, drilled to 12505'. Still seeing fairly high vibration. 05:30 - 06:00 0.50 DRILL P PROD1 Drill Zone 1 lateral, 2.60/2.60 bpm, 3600 psi, 30L TF, 2K DHWOB, 85-100 fph, 10.2 ECD, drilled to 12545' 06:00 - 07:00 1.00 DRILL P PROD1 Drill Zone 1 lateral, 2.59/2.57 bpm, 3500 psi, 76L TF, 1.8K DHWOB, 125 fph, 10.24 ECD, drilled to 12634' 07:00 - 09:30 2.50 DRILL P PROD1 Wiper trip thru tbg tail to 10600', No hole problems, open EDC above window at 11200', RIH, close EDC at 11200', slide thru window, Tie-in pass with correction of +2' SLB, +2.5' Baker, RIH to btm at 12634', No hole problems, spot liner pill to bit 09:30 - 13:00 3.50 DRILL P PROD1 POH to Drig BHA #7, spot liner pill across open hole, Std Bk Injector 13:00 - 13:25 0.42 DRILL P PROD1 PJSM on handling BHA, POH flush and LD BHA #7 13:25 - 14:50 1.42 CASE P RUNPRD PJSM on pickle job, RU circ nozzle, stab injector, flush surface lines with 6bbls 110 deg FW safe surf W soap pill, RU on CT, pump 20 bbls 110 deg FW safe surf W soap pill, 50 bbls of 110 deg FW, 30 bbls A266 corrosion inhibitor and 6 bbls of McOH 14:50 - 15:45 0.92 CASE P RUNPRD PJSM on blow down procedure with N2, RU N2 unit, Test lines to 4000psi, blow down CT with N2, take returns to tiger tank, bleed do CT, RD N2 unit while N2 bled down 15:45 - 18:00 2.25 CASE P RUNPRD PJSM on pulling CT across pipeshed securing to reel, Back out, PU injector, LD nozzle, pulled and cut 87' of a-line, Cut off CTC, head up internal CTC, pull test, pull across pipeshed, secure to reel, cut off internal grapple, RD hard line 18:00 - 20:00 2.00 CASE P RUNPRD PJSM on reel swap, swap out 2 3/8" a-coil to 2 3/8" a-free coil 20:00 - 22:15 2.25 CASE P RUNPRD PJSM. Install internal grapple, rig up hardline, pull test, pull across pipeshed, install Baker CTC, pull test CTC. 22:15 - 00:00 I 1.751 CASE I P 11/15/2007 ' 00:105 - 09:00 I 8.751 CASE I P P/U BOT liner running tools through beaver slide. RUNPRD Pump 5 bbls McOH followed by mud. Fill coil with mud, pressure test CTC and inner reel valve, RU dart catcher, pump dart, dart landed at 60.0 bbls, calculated volume was 61.1 bbls, RD dart catcher, recovered dart, stand back injector RUNPRD PJSM on RU and running 3 3/16" liner assy RUNPRD RU handling tools, PU 3 3/16" liner assy BHA #8, RIH with shoe track, 48 jts of 3 3/16" 6.2 # L-80 TC11 and 20 jts of 3 1/2" 9.3 # L-80 STL liner, X nipple, 1 jt 3 1/2" 9.3# L-80 STL liner and BOT deployment sleeve, OAL 2076.00', BOT MHA, Printed: 12/4/2007 8:53:40 AM BP EXPLORATION Page 6 of 8 Opelrations Summary Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/15/2007 00:15 - 09:00 8.75 CASE P RUNPRD BOT CTC, stab injector, doped pin end only, Avg MU torque for 3 3/16" to 1400ft1bs and 3 1/2" to 1600ft1bs, MU MHA, CTC, Stab injector KICK WHILE TRIP DRILL 0400 HRS 09:00 - 09:20 0.33 CASE P RUNPRD Brk circ, pumped two liner volumes, ok 09:20 - 12:15 2.92 CASE P RUNPRD RIH with liner to 11200', Up Wt 46K at 32fpm, Dn Wt 22.8K at 31fpm, continue RIH to TD, no problems. Tag at 12634', Up Wt 60K, Dn Wt 17.5K, set down and reconfim TD 2x, OK. Paint EOP flag at 10446', note PU off btm 12:15 - 12:55 0.67 CASE P RUNPRD Stack 10K on liner. Launch ball 5/8 steel. Circulate to seat with 50.4bbls, calculated 61.7bbls. Release liner with 4200 psi. PU 27K. Confirm release Suck down pits in preparation to swapping well to 2% KCL double slick with .6 percent safe tube 12:55 - 15:15 2.33 CASE P RUNPRD Displace well to 2% KCL double slick with .6 percent safe tube, 2.65 bpm, 1300psi 15:15 - 15:30 0.25 CEMT P RUNPRD SAFETY MEETING covering HSE hazards with mitigations and procedure of cement job. 15:30 - 16:15 0.75 CEMT P RUNPRD Batch mix 22 bbl of 15.8 ppg class "G" with additives. Ciculating KCL, in rate 1.52bpm out rate 1.48bpm 16:15 - 17:30 1.25 CEMT P RUNPRD Isolate CT pump, line up cementers to pump, line up biozane on CT pump, cementers pump 2 bbl fresh water, isolate micro motion, test cmt line to inner reel valve to 6500psi, line up and pump cement as follows: 16:18 - 16:30 hrs -Pump 18.5 bbl class G cement with latex additives at 2.0 - 1.75bpm, 865 - 1375 psi. 16:30 - 16:45 hrs -Flush cement line with Biozan, Install and launch wiper dart with 600 psi, 16:45 - 17:52 Displace with Biozan and 2% KCL double slick with .6 percent safe tube 15 bbl displ, 2.77/2.75 bpm, 1510 psi 25 bbl displ, 2.67/2.60 bpm, 1350 psi (21 bbl Biozan pumped, switch to 2% KCL double slick with .6 percent safe tube) 30 bbl displ, 2.72/2.68 bpm, 1450 psi 35 bbl displ, 2.75/2.71 bpm, 1485 psi 45 bbl displ, 2.74/2.70 bpm, 1375 psi 55 bbl displ, 2.72/2.68 bpm, 1165 psi 60 bbl displ, 1.5/1.5 bpm, 250 psi Dart landed on LWP at 60.3 bbl, Sheared at 3200 psi 65 bbl displ, 1.96/1.90 bpm, 1245 psi 70 bbl displ, 1.98/1.90 bpm, 1275 psi Slow to 1.5 bpm at 71 bbl displ, 945 psi 75 bbl displ, 1.45/1.40 bpm, 1000 psi 76.6 bbl displ, 1.45/1.40 bpm, 1000 psi Bumped plug at 76.6 bbl [78.1 bbl calc]. Holding pressure at 2100 psi for 5 minutes. CIP at 17:52 am 11/15/07; Pumped total 76.7 bbl with 74.6 bbl returns Bleed pressure to 0 psi, check floats. Floats holding. Printed: 12/4/2007 8:53:40 AM __ _ __ _ _- BP EXPLORATION Page 7 of 8 Operatiolns Slummary Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours I Task I Code I NPT ( Phase I Description of Operations 11/15/2007 116:15 - 17:30 I 1.251 CEMT I P I I RUNPRD Index Shoe at 12634', Land Collar at 12626', Top Of Liner at 10554' 17:30 - 20:15 2.75 CEMT P RUNPRD Pressure up to 500 psi, unsting running tool, circ .5 bbl at 0.5 bpm, POOH to 12434'CTD, 200' from TD, paint EOP flag at 10346', POH replacing voidage, Std back injector 20:15 - 20:30 0.25 CEMT P RUNPRD L/D liner running BHA #8 20:30 - 21:15 0.75 BOPSU P RUNPRD Funtion Test BOPE 21:15 - 21:30 0.25 EVAL P LOWER1 P/U MCNUGR/CCL logging tools up beaver slide. Layout on catwalk. 21:30 - 21:45 0.25 EVAL P LOWER1 SAFETY MEETING. Reviewed procedure, hazards and mitigation for P/U logging /cleanout BHA. 21:45 - 00:00 2.25 EVAL P LOWER1 M/U logging cleanout BHA #9. M/U 2.71" mill, 2-1/8" motor, 2 jts 1-1/4" CSH, MCNL/GR/CCL carrier, 66jts 1-1/4" CSH. Overall BHA length 2142.71.39'. 11/16/2007 00:00 - 01:00 1.00 EVAL P LOWER1 Continue M/U liner cleanout /logging BHA #9. Stab injector. 01:00 - 03:00 2.00 EVAL P LOWER1 RIH to 10300' 03:00 - 04:45 1.75 EVAL P LOWER1 Log down with SWS Memory CNL/GR/CCL logging tools at 30 fph, circ 1.5 bpm at 1650 psi, full returns. RIH into top of liner with no wt loss. Did not see any . contaminated cement circ to surface. Tagged PBTD at 12,624' CTD. 04:45 - 05:30 0.75 EVAL P LOWER1 Log up to 10300' at 60 fpm. Lay in new High Vis FloPro pert pill from PBTD to top of liner. 05:30 - 09:00 3.50 EVAL P LOWER1 Circ. 5/8" steel ball and open circ sub. POOH to cleanout logging BHA, Std Bk Inj 09:00 - 11:00 2.00 EVAL P LOWER1 PJSM on handling 1 1/4" CSH and CNL tools, POH with BHA, std bk 33stds, LD 2 jts of 1 1/4" CSH, LD MCNL tools 11:00 - 12:00 1.00 EVAL P LOWER1 PJSM on pressure testing Liner and lap, Press test LTP with 2010 psi, held for 30 min with 76 psi pressure lost, IA Opsi, OA Opsi, lost 54psi in first 15mins, lost 22psi in the last 15mins, Good Liner Lap test, Held PJSM on handling and running pert guns ISIP 2010psi 5min 1981 psi 10min 1967psi 15min 1956psi 20min 1948psi 25min 1941 psi 30min 1934psi 12:00 - 12:45 0.75 PERFO P LOWER1 PU tools and equipment to rig floor, RU handling tools, Set up floor for pert job, PJSM on handling and running pert guns, MU Perf Gun Assy, BHA #17, PU 8 2" 6SPF, 2006JP guns and blank, Gun length 174.36' 12:45 - 14:00 1.25 PERFO P LOWER1 RIH with total of 32 stds of 1 1/4" CSH, M/U SWS XO, Hyd Disc, Checks, NRJ, RD handling tools, MU CTC, OAL 2158', Stab injector 14:00 - 16:00 2.00 PERFO P LOWER1 RIH with pert gun BHA # 10, Circ. at .2 bpm, 75 psi, Tag and correct PBTD to 12626' per memory log, PU to 12604' ball drop position, Pump 6 bbl pert pill, Install 1/2" steel ball (firing head at 68 degrees), Launch ball with 500 psi, 10 bbl pert pill behind ball, RIH tagged PBTD at 12626', DN WT 23k, UP WT 44k, Printed: 12/4/2007 8:53:40 AM BP EXPLORATION Page 8 of 8 Operatiolns Summary: Report Legal Well Name: K-14 Common Well Name: K-14 Spud Date: 9/10/1987 Event Name: REENTER+COMPLETE Start: 11/7/2007 End: 11/17/2007 Contractor Name: NORDIC CALISTA Rig Release: 11/17/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/16/2007 14:00 - 16:00 2.00 PERFO P LOWER1 PU, position pert guns with btm shot at 12625', Circulate ball to seat 1.52 bpm at 1450 psi, On seat at 55.8 bbl, Fire guns on the fly with 3600 psi, SLB shot detection 16:00 - 17:00 1.00 PERFO P LOWER1 PU to 12604' ball drop position, Pump 6 bbl pert pill, Install 1/2" steel ball (firing head at 68 degrees), Launch ball with 500 psi, 5 bbl pert pill behind ball, RIH tagged PBTD at 12626', Dn Wt 23k, Up Wt 44k, PU, position perf guns with btm shot at 12625', Circulate ball on seat with 61.2 bbls at 1.05 bpm, 825 psi, Fire guns on the fly with 2850 psi, SLB shot detection with slight bobble, OK 17:00 - 19:30 2.50 PERFO P LOWER1 POH to BHA # 10 19:30 - 20:00 0.50 PERFO P LOWER1 Flow check at surface. Okay. 20:00 - 23:30 3.50 PERFO P LOWER1 PJSM. S/B injector. UD perf gun BHA #10. S/B 32 stds 1-1/4" CSH in derrick. Layout 8 perf guns in pipeshed. ASF. 23:30 - 00:00 0.50 WHSUR P POST Stab injector. RIH, freeze protect well to 2200' with diesel. 11/17/2007 00:00 - 01:10 1.17 WHSUR P POST Freeze protect to 2200' with diesel. S/B injector. 01:10 - 01:20 0.17 WHSUR P POST SAFETY MEETING. Reviewed procedure, hazards and mitigation for setting BPV. 01:20 - 01:45 0.42 WHSUR P POST Set BPV using T-bar. Stab injector. 01:45 - 03:30 1.75 RIGD P POST PJSM on pickle job, RU circ nozzle, stab injector, flush surface lines with 6bbls 110 deg FW safe surf W soap pill, RU on CT, pump 25 bbls 110 deg FW safe surf W soap pill, 50 bbls of 110 deg FW, 15 bbls A266 corrosion inhibitor and 10 bbls of McOH 03:30 - 04:45 1.25 RIGD P POST PJSM on blow down procedure with N2, RU N2 unit, Test lines to 3500psi, blow down CT with N2, take returns to tiger tank, bleed do CT, RD N2 unit while N2 bled down 04:45 - 06:45 2.00 RIGD P POST PJSM on pulling CT across pipeshed securing to reel, Back out, PU injector, LD nozzle, cut off CTC, head up intemal grapple, pull test, pull across pipeshed, secure to reel, cut off internal grapple, RD hard line 06:45 - 07:00 0.25 RIGD P POST PJSM, review procedure, hazards and mitigation for CT reel swap 07:00 - 08:15 1.25 RIGD P POST Swap reels from 2 3/8" a-free CT to 2 3/8" a-line CT, std back Injector 08:15 - 09:00 0.75 RIGD P POST ND BOP's, Secure tree, test tree cap to 4000psi, Release Rig at 09:00 Hrs on 11/17/2007 Printed: 12/4/2007 8:53:40 AM BP EXPLORATION Page 1 of 3- Wellbore Equipment .Report. Legal Well Name: K-14 Spud Date: 9/10/1987 Common Well Name: K-14 Report #: 2 Report Date: 8/14/2007 Event Name: WORKOVER Start: 8/2/2007 End: 8/14/2007 Assemb ly Name: TUB ING Install D ate: 8/13/2007 Suspen ded From: @ ( ft) Pull Da te: TMD C orrection: (ft) Final St ring We ight: (Ib) Landed TMD: 10,4 34.89 (ft) Landed Weight: (Ib) om. Siz Component .Description # Jts LD. O.D. Weight Grade Length Top Set Manufacturer Model # Connection Comments (in) (in) (in) (Ib/ft) (ft) (ft) 22.6 13.62 TUBING HANGER 1 3.95 13.51 0.7 22.6 CAMERON CONTRO TCII 4.50 TUBING PUPJOINT 1 3.95 4.54 12.6 13CR80 2.4 23.4 VAM TOP 4.50 TUBING JOINTS 1 3.95 4.96 12.6 13CR80 41.9 25.8 VAM TOP 4.50 TUBING PUPJOINT 1 3.95 4.96 12.6 13CR80 9.7 67.8 VAM TOP 4.50 TUBING JOINTS 4 3.95 4.96 12.6 13CR80 1,926.4 77.5 VAM TOP 4.50 TUBING PUPJOINT 1 3.95 4.96 12.6 13CR80 9.7 2,004.0 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 2,013.7 VAM TOP 4.50 X NIPPLE 1 3.81 5.01 9CR 1.2 2,023.6 HALLIBURTON TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.6 2,024.8 TCII 4.50 TUBING JOINTS 3 3.95 4.96 12.6 13CR80 1,380.91 2,034.5 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 3,415.4 VAM TOP 4.50 GAS LIFT MANDRE 1 3.85 7.031 9CR 9.1 3,425.3 CAMCO INTERNATI TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.7 3,434.51 TCII 4.50 TUBING JOINTS 7 3.95 4.96 12.6 13CR80 2,924.9 3,444.2 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 6,369.1 VAM TOP 4.50 GAS LIFT MANDRE 1 3.93 6.00 9CR 6.9 6,378.9 CAMCO INTERNATI TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 6,385.9 TCII 4.50 TUBING JOINTS 5 3.95 4.96 12.6 13CR80 2,170.6 6,395.7 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 8,566.41 VAM TOP 4.50 GAS LIFT MANDRE 1 3.93 6.00 9CR 6.9 8,576.2 CAMCO INTERNATI TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.7 8,583.2 TCII 4.50 TUBING JOINTS 4 3.95 4.96 12.6 13CR80 1,678.0 8,593.0 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 10,271.0 VAM TOP 4.50 GAS LIFT MANDRE 1 3.93 6.00 9CR 6.9 10,280.9 CAMCO INTERNATI TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.6 10,287.9 TCII 4.50 TUBING PUPJOINT 1 3.95 4.96 12.6 13CR80 9.7 10,297.5 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.9 10,307.3 VAM TOP 4.50 X NIPPLE 1 3.81 5.01 9CR 1.2 10,317.2 HALLIBURTON TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.7 10,318.4 TCII 4.50 TUBING PUPJOINT 1 3.95 4.96 12.6 13CR80 9.7 10,328.1 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 10,337.8 VAM TOP 7.00 PACKER (PERMAN 1 3.87 5.95 9CR 4.0 10,347.7 BAKER OIL TOOLS TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 10,351.7 TCII Printed: 12/4/2007 8:54:02 AA BP EXPLORATION Page 2 of 3~ Wellbore Equipment Report Legal Well Name: K-14 Spud Date: 9/10/1987 Common Well Name: K-14 Report #: 2 Report Date: 8/14/2007 Event Name: WORKOVER Start: 8/2/2007 End: 8/14/2007 om. Siz Component Description # Jts LD. O.D. Weight Grade Length Top Set Manufacturer Model # Connection Comments (in) (in) {in) (Ib/ft) (ft) (ft) 4.50 TUBING PUPJOINT 1 3.95 4.96 12.6 13CR80 9.71 10,361.5 VAM TOP 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.8 10,371.2 VAM TOP 4.50 X NIPPLE 1 3.81 5.01 9CR 1.2 10,381.1 HALLIBURTON TCII 4.50 X-O 1 3.95 4.96 12.6 13CR80 9.7 10,382.3 TCII 4.50 TUBING JOINTS 1 3.95 4.96 12.6 13CR80 41.3 10,392.11 VAM TOP 5.75 WIRELINE GUIDE 1 3.95 5.87 13CR80 1.3 10,433.5 VAM TOP • Printed: 12/4/2007 8:54:02 AM BP EXPLORATION Page 3 of 3~ Wellbore Equipment Report` Legal Well Name: K-14 Spud Date: 9/10/1987 Common Well Name: K-14 Report #: 2 Report Date: 8/14/2007 Event Name: WORKOVER Start: 8/2/2007 End: 8/14/2007 Remarks P/U Wt = 165,000 Ibs S/O Wt = 105,000 Ibs Printed: 12/4/2007 8:54:02 AM 1 ~ BP Alaska r Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 11/19/2007 Time: 09:49:04 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeB: K-14, True North Site_ PB K Pad Vertical (TVD) Reference: 26:14 9!10/1987 00:00 53.2 Well: K-14 Section (VS) Reference: User (O.OON,O.OOE,169 .26Azi) Wellpath: K-14A Survey Calculation Method: Minimum Curvature Db: Orade 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 K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973 161.33 ft Latitude: 70 19 57.435 N From: Map Easting: 670342.10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg Well: K-14 Slot Name: 14 K-14 Well Position: +N/-S 2124.30 ft Northing: 5975311.00 ft Latitude: 70 20 18.327 N +E/-W 1147.51 ft Easting : 671441.00 ft Longitude: 148 36 31.729 W Position Uncertainty: 0.00 ft Wellpath: K-14A Drilled From: K-14 500292175201 Tie-on Depth: 11192.39 ft Current Datum: 26:14 9!10/1987 00:00 Height 53.20 ft Above System Datum: Mean Sea t.evel Magnetic Data: 11/1/2007 Declination: 23.58 deg Field Strength: 57665 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.92 0.00 0.00 169.26 Survey Program for Definitive Wellpath Date: 7/5/2007 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 38.50 11192.39 1 : Schlumberger GCT multishot GCT-MS Sohlumberger GCT muRishot 11219.50 12634.00 MWD (11219.50-12634.00) MWD MWD -Standard Annotation IViD TVD ft ft 11192.39 8590.80 TIP 11219.50 8609.11 KOP 12634.00 8913.35 TD Survey: MWD Start Date: 11/13!2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11192.39 47.40 184.02 8590.80 8537.60 -6271.20 282.35 5969048.31 671866.63 6214.04 0.00 MWD 11219.50 47.60 183.94 8609.11 8555.91 -6291.14 280.97 5969028.35 671865.70 6233.37 0.77 MWD 11248.55 50.55 179.17 8628.15 8574.95 -6313.07 280.39 5969006.41 671865.63 6254.81 16.03 MWD 11270.77 57.96 176.14 8641.12 8587.92 -6331.07 281.15 5968988.43 671866.80 6272.64 35.13 MWD 11298.27 67.14 172.85 8653.79 8600.59 -6355.33 283.52 5968964.24 671869.72 6296.91 35.02 MWD 11324.67 79.53 169.99 8661.35 8608.15 -6380.28 287.30 5968939.38 671874.08 6322.13 48.06 MV1ID 11362.39 87.08 160.98 8665.75 8612.55 -6416.48 296.70 5968903.41 671884.30 6359.45 31.03 MWD 11388.87 87.88 150.07 8666.92 8613.72 -6440.52 307.64 5968879.63 671895.79 6385.11 41.27 MWD 11422.08 86.46 138.04 8668.56 8615.36 -6467.32 327.07 5968853.28 671915.83 6415.06 36.43 MWD 11450.16 85.57 130.95 8670.52 8617.32 -6486.94 347.04 5968834.12 671936.24 6438.06 25.39 MWD 11480.68 84.63 127.85 8673.12 8619.92 -6506.24 370.54 5968815.36 671960.16 6461.39 10.58 MWD ~v~-1v~ ~~ ,~ by BP Alaska s Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 11/19/2007 Time: 09:49:04 Page: 2 Field: Prudhoe Bay Co-ordina[e(NE) Reference: Well: K-14, True North Site: PB K Pad Vertical (TVD) Reference: 26:14 9/10/1987 00:00 53.2 Well: K-14 Section (VS) Reference: User (O.OON,O.OOE,169.2fiAzi~ Wellpath: K-14A Survey Calculation Method: Minimum Curvature Db: Orade Survey MD Ind Azim 1'VD ft deg deg ft 11516.52 85.51 129.71 8676.20 11543.34 84.72 129.97 8678.49 11576.54 85.88 127.59 8681.21 11606.58 87.45 125.65 8682.96 11635.74 87.60 122.70 8684.22 11670.66 86.18 119.27 8686.11 11697.64 85.07 116.80 8688.17 11727.40 83.96 113.66 8691.01 11752.32 84.33 111.36 8693.56 11782.38 85.45 109.32 8696.23 11809.40 86.16 105.60 8698.21 11840.72 87.30 110.01 8700.00 11871.06 87.11 116.17 8701.48 11894.06 85.90 120.27 8702.88 11926.10 84.83 125.70 8705.47 11956.54 84.34 129.31 8708.35 11986.62 84.33 134.99 8711.32 12011.22 84.18 127.03 8713.79 12041.08 84.95 123.88 8716.61 12075.06 82.27 121.57 8720.40 12106.86 80.22 121.25 8725.24 12137.95 75.59 120.52 8731.75 12168.68 71.03 119.45 8740.57 12200.48 66.53 117.26 8752.08 12231.52 65.45 115.34 8764.71 12261.16 64.64 116.56 8777.22 12295.78 65.28 123.20 8791.88 12329.46 67.82 127.91 8805.29 12366.20 69.85 126.04 8818.56 12397.27 70.30 121.98 8829.15 12426.62 68.64 118.13 8839.45 12468.54 67.99 114.15 8854.94 12503.58 68.23 112.09 8868.00 12530.88 69.55 109.49 8877.84 12567.60 69.08 106.26 8890.81 12602.46 70.55 102.40 8902.84 12634.00 70.55 102.40 8913.35 Sys TVD N/S E/W ft ft ft 8623.00 -6528.61 398.37 8625.29 -6545.73 418.89 8628.01 -6566.45 444.68 8629.76 -6584.34 468.75 8631.02 -6600.70 492.85 8632.91 (618.65 522.74 8634.97 -6631.29 546.48 8637.81 -6643.92 573.27 8640.36 -6653.41 596.17 8643.03 -6663.81 624.24 8645.01 -6671.90 649.94 8646.80 -6681.45 679.71 8648.28 -6693.33 707.57 8649.68 -6704.19 727.79 8652.27 -6721.56 754.57 8655.15 -6740.01 778.61 8658.12 -6760.09 800.79 8660.59 -6776.14 819.25 8663.41 -6793.38 843.46 8667.20 -6811.63 871.86 8672.04 -6828.01 898.68 8678.55 -6843.61 924.76 8687.37 -6858.32 950.25 8698.88 -6872.40 976.32 8711.51 -6884.97 1001.74 8724.02 -6896.73 1025.90 8738.68 -6912.34 1053.08 8752.09 -6930.31 1078.20 8765.36 -6950.92 1105.57 8775.95 -6967.25 1129.78 8786.25 -6981.01 1153.56 8801.74 -6998.17 1188.52 8814.80 -7010.94 1218.42 8824.64 -7019.98 1242.22 8837.61 -7030.52 1274.91 8849.64 -7038.61 1306.61 8860.15 -7045.00 1335.65 MapN MapE ft ft 5968793.64 671988.50 5968777.00 672009.40 5968756.87 672035.66 5968739.54 672060.13 5968723.74 672084.59 5968706.48 672114.88 5968694.38 672138.91 5968682.37 672165.98 5968673.41 672189.09 5968663.65 672217.39 5968656.15 672243.27 5968647.28 672273.24 5968636.04 672301.36 5968625.65 672321.83 5968608.89 672349.00 5968591.00 672373.45 5968571.44 672396.08 5968555.82 672414.90 5968539.13 672439.49 5968521.54 672468.30 5968505.78 672495.49 5968490.77 672521.92 5968476.65 672547.74 5968463.17 672574.12 5968451.19 672599.82 5968439.99 672624.24 5968425.00 672651.77 5968407.61 672677.29 5968387.64 672705.12 5968371.87 672729.69 5968358.65 672753.78 5968342.29 672789.12 5968330.22 672819.30 5968321.73 672843.31 5968311.93 672876.23 5968304.57 672908.10 5968298.85 672937.28 VS DLS Tool ft deg/100ft 6488.55 5.72 MWD 6509.19 3.10 MWD 6534.36 7.95 MWD 6556.41 8.30 MWD 6576.98 10.12 MWD 6600.18 10.62 MWD 6617.02 10.01 MWD 6634.42 11.15 MWD 6648.01 9.30 MWD 6663.46 7.72 MWD 6676.19 13.98 MWD 6691.13 14.52 MWD 6707.99 20.29 MWD 6722.42 18.55 MWD 6744.48 17.22 MWD 6767.08 11.92 MWD 6790.94 18.79 MWD 6810.15 32.20 MWD 6831.59 10.81 MWD 6854.82 10.38 MWD 6875.91 6.52 MWD 6896.10 15.07 MWD 6915.30 15.21 MWD 6933.99 15.54 MWD 6951.07 6.64 MWD 6967.12 4.63 MWD 6987.53 17.47 MWD 7009.86 14.88 MWD 7035.20 7.28 MWD 7055.75 12.37 MWD 7073.71 13.52 MWD 7097.08 8.96 MWD 7115.19 5.50 MWD 7128.51 10.11 MWD 7144.95 8.33 MWD 7158.81 11.22 MWD 7170.49 0.00 MWD • d a a ~ SARAH PALIN, GOVERNOR gLASSA OIL ~r ~D ~ 333 W. 7th AVENUE SUIT C011TSE-RQA'1`IOrT C01~'II5SIOIQ E 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Abby Higbie FAx (907) 27sa5a2 CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-14A BP Exploration Alaska Inc. Permit No: 207-102 Surface Location: 1909' FNL, 4106' FEL, SEC. 14, T11N, R14E, UM Bottomhole Location: 3654' FNL, 2848' FEL, SEC. 09, T 11 N, R 14E, UM Dear Ms. Higbie: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witnes ny required test, contact the Commission's petroleum field inspector~t ( 7) 59-3607 (pager). J DATED this ~ day of July, 2007 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N PERMIT TO DRILL 20 AAC 25.005 ~iqo~ ,J U ~_ ~ 9 2007 . ~ ~... ~:~: C~:ns. Cemrti~i~si~n .aT , 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU K-14A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12590 TVD 8855ss 12. Field !Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1909' FNL 4106' FEL SEC 04 T11 N R14E UM ' 7. Property Designation: ADL 028303 Pool , , , , . , Top of Productive Horizon: 2749' FNL, 3827 FEL, SEC. 09, T11 N, R14E, UM ~ 8. Land Use Permit: 13. Approximate Spud Date: October 15, 2007 - Total Depth: 3654' FNL, 2848' FEL, SEC. 09, T11 N, R14E, UM - 9. Acres in Property: 2560 14. Distance to Nearest Property: 19,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x-671441 y-5975311 Zone-ASP4 10. KB Elevation (Height above GL): 53.2 feet 15. Distance to Nearest Well within Pool: 1,330' 16. Deviated Wells: Kickoff Depth: 11220 feet Maximum Hole An le: 86 de reel 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3260 Surface: 2380 18._ Casin P ram:. S eifications To - Settln . De th -Bo ttom uantit 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" 3-3/16" 6.2# L-80 TC-II 2035' 10555' 8089' 12590' 8855' 95 cu ft Class'G' 19. PRESE NT WELCCONDITION SUMMARY (To be completed for Redril6and Re-ehtry Operations) Total Depth MD (ft): 11800 Total Depth TVD (ft): Plugs (measured): ggg2 None Effective Depth MD (ft): 11756 Effective Depth TVD (ft): 8964 Junk (measured): 11730 Casing Length Size Cement Volume MD TVD Conductor /Structural 110' 20" 8 cu ds Concrete 110' 110' Surface 2720' 13-3/8" 4185 cu ft Arcticset II 2720' 2678' Intermediate 10830' 9-5/8" 2375 cu ft Class'G' 10830' 8338' Production Liner 1226' 7" 414 cu ft Class'G' 10574' - 11800' 8156' - 8992' Perforation Depth MD (ft): 11575' - 11697' Perforation Depth TVD (ft): 8846' - 8925' 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 Abby Higbie, 564-5480 Printed Name Abby Higbie Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-5480 Date ~ ~ 7 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: oTO~/G~,?D AP! Number: 50-029-21752-01-00 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 as contained shales: Samples Req'd: ^ Yes ^ No Log Req'd: ^ Yes ^ No HZS Measures: ^ Yes irecti a urvey Req'd: ^ Yes ^ No ~~~5~~~~ ~fiS Other: ROVED BY THE COMMISSION Date ~~ '~ e MISSIONER Form 10-401 Revised 12!2005 ~ ~ ~ y !~ 1 ~ ` / 7/~?ubmit In Duplicate 1\YI L • BP Prudhoe Bay K-14A CTD Sidetr~ CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin August 20th, 2007) 1) S Passed tubing caliper inspection 2) O Dummy GLVs 3) O Passed MIT-IA and MIT-OA. 4) O AC-LDS; AC-PPPOT-IC, T ~~~~ 5) S Run dummy whipstock drift 6) E Set 4'/z" x 7" W S at 11220' 7) O Perform infectivity test 8) C Pump 15.8 ppg cement down squeeze past WS to isolate existing perfs-25bb1 9) O PT cement plug to 2000 psi 10) O PT MV, SV, WV 11) O Blind and bleed lines 1 Z) O Remove wellhouse, level pad Rig Work: (Scheduled to begin October 15th, 2007) 1) MIRU Nordic 1 and test BOPE to 250psi low and 3500psi high. 2) Mi113.80" window in 7" liner at 11220' 3) Drill Build: 4.125" OH, 525' (45 deg/100 planned) 4) Drill Lateral: 4.125" OH, 845' (12 deg/100 planned) 5) Run 3-3/16" solid liner leaving TOL at 10555' ~~ n 6) Pump cement leaving TOC at 11100' ~~ ~ P Y ~~ ~ 7) Cleanout liner and MCNL/GR/CCL log 8) Test liner lap to 2000 psi 9) Perforate liner per asset instructions 0200') 10) Freeze protect well, set BPV and RDMO Post-Rig Work: 1) Install well house, GLM and attach production lines 2) Pull BPV Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 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: • 4.125" Casing Program: Fully cemented liner • 3-3/16", 6.2#, L-80, TCII 10555'MD - 12590'MD • A minimum of 17 bbls 15.8 ppg cement will be used for liner cementing. 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. Max. planned hole angle is 86 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property -19300 ft • Distance to nearest well within pool -1330 ft. (15-22) Anti-collision • All wells passed anti-collision scan Logging • MWD directional, gamma ray, and resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run Hazards • The maximum recorded H2S level on K Pad is 25 ppm (K-16AL2 on 1/13/2006). • High risk of lost circulation due to two fault crossings expected in Zone 2 • Structural uncertainty due to known graben fault (KO below graben) Reservoir Pressure • Res. press. is estimated to be 3260 psi at 8800'TVDss (7.1 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2380 psi. LHEAD = MCEVOY CTUATOR = AXELSON B. ELEV = 53.20' F. ELEV = 25.62' OP = 2055' Angle = 50 ~ 3962' tum MD = 11587' tum ND = 8800' SS 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~--~ 2500' TOP OF 4-12" TBG 2500' 13-3/8" CSG, 72#, L-80, ID =12.34T' 2719' Minimum ID = 3.725" ~ 10586' 4-1/2" OTIS XN NIPPLE K-14 SAFEP'PNOTES: CI~TACEOUS LEAK.«"" PRODUCTION CASING LEAK. OPERATING UMITS: MAX IAP = 500 PSI; MAX OAP =1000 PSI (08116103 WANFJ~ *"" • 1978' 5-12" OT1S HRQ SSSV LAND NIP, ID = 4.582" 2600' 5-12" X 41/7' XO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3104 2942 38 OTIS RA 3 7517 5967 45 OTIS RA 10237 7870 46 OTIS RA 1 10345 7943 46 OTIS RA 10425' H 4117' BKR L SLIDMIG SLV, ID = 3.812" 10484' TBG SEAL ASSY SBR 10500' 518" X 4-12" TNV PKR 10547' 4-1/7' OTIS X NIP, ID = 3.813" TOP OF T' LNR H 10667' 10586' 4-1/2" OTC XN NIP, ID = 3.725 4-1 /2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" 10622' 10622' 4-1 /2" TBG TAIL O = 3.958" 10626' ELMD TT LOGGED 10/30/87 9-5/8" CSG, 47#, L-B0, ID = 8.681" H 10827' PERFORATION SUMMARY REF LOG: BHC,S ON 0926/87 ANGLE AT TOP PERF: 49 ~ 11508 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz OIATE 3-3/6" 4 11508 - 11515 S 06/18/99 3-318" 4 11560 - 11575 S 06/18/99 3-3/8" 6 11575 - 11585 O 11/25/99 3-3/S" 10 11599 - 116'10 O 0823/99 3-3/8" 10 11630 - 11659 O 0823/99 3-1/8" 4 11864-11675 O 07/03/99 3-1/8" 4 11682-11697 O 07/03/99 10975' H 7" MA RKER JOINT 11730' ~ PBTD ~ 11756' T' LNR, 26#, L-80, .0383 bpf, ID = 6.276" 11800' OWTE REV BY COMMENTS DATE REV BY COMMBVTS 09130187 ORIGINAL COMPLETION 07/16/01 RWKAK CORRECTIONS 11/16/02 AS/KAK PERF OORRECTIONS 08M6/03 CMOlTLP KB ELEV AND MAXANGLE 08/16/03 JLA/KK WAVER SAFETY NOTE I FISH - KINLEY CUTTER I PRUDHOE BAY UNIT WELL: K 14 PERMT No: 1870950 API No: 50-029-21752-00 SEC 4, T71 N, R14E, 1909' FNL & 4106' WEL BP Exploration (Alaska) LHEAD= MCEVOY CTUATOR = AXl3SON . ELEV = 53.20' F. ELEV = 25.62' OP = 2055' x Angle = 50 C~13962' tum MD = 11587' tum ND = 8800' SS K-14A Proposed CTD Sidetra (Combo RWO &CTD SiT SAFET~NOTES: CRETACEOUS LEAK "' PRODUCTION CASING LEAK. OPERATING LIMITS: MAX IAP = 500 PSI; MAX OAP =1000 PSI (08116/03 WAIVER) "' GAS LFT MANDRELS 113-3/8" CSG, 72~, L-80, ID = 12.347" I 14-1l2" Chrome TBG, .0152 bpf, ID = 3.958" I 17" L-80 tie-back I ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3104 2942 38 OTIS RA 3 7517 5967 45 OTIS RA 10237 7870 46 OTIS RA 1 10345 7943 48 OTIS RA 10450? Chem cut tbg 10484' TBG SEAL ASSY SBR Minimum ID = 3.725" @ 10586' ermanent kr 10500' 9-5l8" X 4-1/2" TNV PKR 4-1 /2" OTIS XN NIPPLE ' " " 10547 a-1n oTIS x Nom, ID= 3.813 (milled to 3.8 TC~OF 3 3/?6" LNR TOP OF 7" LNR 10567' 3 5" XN Nip 2.75" ID 10586' 4-1 /2" OTIS XN NIP, ID = 3.725 ,r~iaed tc ; ~~ i 4-1 /2" TBG, 12.6, L-80, .0152 bpf, ID = 3.958" 10622' 10622' 4-1 /2" TBG TAIL ID = 3.958" 10626' ELMD TT LOGGED 10!30/87 PERFORATION SUMMARY REF LOG: BRCS ON 09/26/87 ANGLE AT TOP PERF: 49 ~ 11508 Note: Refer to Production DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 3-318" 4 11508- 11515 oosea 3-3/8" 4 11560- 11575 soiated proposec 3-3/8" 6 11575 - 11595 isolated proposec 3-3/8" 10 11599 - 11620 isolated proposec 3-3/8" 10 11630 - 11659 isolated proposed 3-1/8" 4 11664 - 11675 isolated proposed 3-1/8" 4 11682 - 11697 isolated proposed 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10975' H 7" MARKER J01VT 1100' Top cf Corer! 3-3/16" cmt'ed and perfed ~--~ 1 11220' Mechanical Wh~pstocK DATE REV BY COMMENTS DATE REV BY COMMBVTS 09/30/87 OPoGINAL COMPLETION 07/16/01 RWKAK CORRECTIONS 11/16/02 AS/KAK PERF CORRECTIONS 08/16/03 CMO/TLP KB ELEV AND MAX ANGLE 08!16/03 JLA/KK WANff2 SAFETY NOTE PRUDHOE BAY UNfr WELL: K-14 P~2Mrr No: 1870950 API No: 50-029-21752-00 SC-C 4, T11 N, R14E, 1909' FNL 8 4106' WEL BP 6rploration (Alaska) 110400? I • • by BP Alaska s Baker Hughes INTEQ Planning Report 11YTE Q Company: BP Amoco Date: 7/10/2001 Time: 16:01:22 Page: 1 Fier Id: Prudhoe $ay Co-ordipate(NE) Reference: We1L' K-14, True North Site: PB K Pad Vertical (TVD}Reference: 26 :14 9/10/1987 00:00 53:2 Wells K-14 Sectroe(VS)Retereoce: User (O.OON,O.OOE,130. OOAzi) Wellpath: Plan 12, K-14A SarveyCakolsrtien Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Positioe: Northing: 5973161 .33 ft Latitude: 70 19 57.435 N From: Map Easting: 670342 .10 ft Longitude: 148 37 5.245 W Positron Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg Weil: K-14 Slot Name: 14 K-14 Well Position: +N/-S 2124.30 ft Northing: 5975311 .00 ft Latitude: 70 20 18.327 N +E/-W 1147.51 ft Easting : 671441 .00 ft Longitude: 148 36 31.729 W Position Uncertainty: 0.00 ft Wellpath: Plan 12, K-14A Drilled From: K-14 500292175201 Tie-on Depth: 11 192.39 ft Current Datum: 26:14 9/10/1987 00 :00 Height 53 .20 ft Above System Datum: Mean Sea Level Magnetic Data: 11/1/2007 Declination: 23.58 deg Field Strength: 57665 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.92 0.00 0.00 130.00 Plan: Plan #12 Date Composed: 7/5/2007 Copy Lamafs plan 12 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude --> <- Longitade --> Name Description TVD +N/-S +E/-W North(og Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft K-14A Fault 1 53.20 -6624.02 80.59 5968691.00 671673.00 70 19 13.180 N 148 36 29.377 W -Polygon 1 53.20 -6624.02 80.59 5968691.00 671673.00 70 19 13.180 N 148 36 29.377 W -Polygon 2 53.20 -6343.82 513.13 5968981.00 672099.00 70 19 15.936 N 148 36 16.754 W K-14A Fault 2 53.20 -6717.95 557.60 5968608.00 672152.00 70 19 12.256 N 148 36 15.457 W -Polygon 1 53.20 -6717.95 557.60 5968608.00 672152.00 70 19 12.256 N 148 36 15.457 W -Polygon 2 53.20 -6669.58 1372.97 5968675.00 672966.00 70 19 12.731 N 148 35 51.663 W K-14A Fault 3 53.20 -6740.32 -39.11 5968572.00 671556.00 70 19 12.036 N 148 36 32.870 W -Polygon 1 53.20 -6740.32 -39.11 5968572.00 671556.00 70 19 12.036 N 148 36 32.870 W -Polygon 2 53.20 -6641.76 506.32 5968683.00 672099.00 70 19 13.005 N 148 36 16.953 W K-14A Fault 4 53.20 -6678.34 1318.75 5968665.00 672912.00 70 19 12.645 N 148 35 53.245 W -Polygon 1 53.20 -6678.34 1318.75 5968665.00 672912.00 70 19 12.645 N 148 35 53.245 W -Polygon 2 53.20 -7099.92 1775.26 5968254.00 673378.00 70 19 8.498 N 148 35 39.926 W K-14A Fault 6 53.20 -6321.38 450.63 5969002.00 672036.00 70 19 16.156 N 148 36 18.578 W -Polygon 1 53.20 -6321.38 450.63 5969002.00 672036.00 70 19 16.156 N 148 36 18.578 W -Polygon 2 53.20 -6375.28 1232.65 5968966.00 672819.00 70 19 15.625 N 148 35 55.756 W K-14A Regional Fault 1 53.20 -6353.77 -1194.65 5968932.00 670392.00 70 19 15.837 N 148 37 6.592 W -Polygon 1 53.20 -6353.77 -1194.65 5968932.00 670392.00 70 19 15.837 N 148 37 6.592 W -Polygon 2 53.20 -6802.21 -219.59 5968506.00 671377.00 70 19 11.428 N 148 36 38.136 W -Polygon 3 53.20 -7304.48 222.08 5968014.00 671830.00 70 19 6.488 N 148 36 25.248 W -Polygon 4 53.20 -7189.93 724.86 5968140.00 672330.00 70 19 7.614 N 148 36 10.577 W -Polygon 5 53.20 -7968.84 2196.53 5967395.00 673819.00 70 18 59.951 N 148 35 27.641 W -Polygon 6 53.20 -7189.93 724.86 5968140.00 672330.00 70 19 7.614 N 148 36 10.577 W -Polygon 7 53.20 -7304.48 222.08 5968014.00 671830.00 70 19 6.488 N 148 36 25.248 W by BP Alaska Baker Hughes INTEQ Planning Report ~i~r s"~w ins INTEQ Targets Map Map_ <.._ Latitude -> ~... Loegitnde --> Name Description: TVD +N/-S +E/-W Northing.. Fasting Deg Mie Ser Deg Min ..,Sec I)ip. Dir. ft ft ft ft ft -Polygon 8 53.20 -6802.21 -219.59 5968506.00 671377.00 70 19 11.428 N 148 36 38.136 W -Polygon 9 53.20 -6353.77 -1194.65 5968932.00 670392.00 70 19 15.837 N 148 37 6.592 W K-14A Fault 7 53.20 -5924.21 142.61 5969392.00 671719.00 70 19 20.063 N 148 36 27.567 W -Polygon 1 53.20 -5924.21 142.61 5969392.00 671719.00 70 19 20.063 N 148 36 27.567 W -Polygon 2 53.20 -6360.41 582.78 5968966.00 672169.00 70 19 15.772 N 148 36 14.721 W K-14A Fault 5 53.20 -7145.34 1574.16 5968204.00 673178.00 70 19 8.051 N 148 35 45.795 W -Polygon 1 53.20 -7145.34 1574.16 5968204.00 673178.00 70 19 8.051 N 148 35 45.795 W -Polygon 2 53.20 -7024.25 2403.20 5968344.00 674004.00 70 19 9.240 N 148 35 21.602 W K-14A_Target#1 8753.20 -6834.46 928.05 5968500.00 672525.00 70 19 11.110 N 148 36 4.647 W -Circe (Radius: 50) -Plan out by 1.16 at 8753.20 -6833.51 928.72 5968500.97 672525.64 70 19 11.119 N 148 36 4.628 W K-14A_Target#2 8933.20 -7022.43 1273.87 5968320.00 672875.00 70 19 9.261 N 148 35 54.556 W -Circle (Radius: 75) Annotation MD TVD ft ff 11192.39 8590.80 TIP 11220.00 8609.45 KOP 11240.00 8622.71 End of 9 Deg/100' DLS 11320.04 8653.27 4 11395.03 8659.43 End of 45 Deg/100' DLS 11745.03 8686.85 6 11945.03 8701.83 7 12070.03 8726.77 8 12195.03 8767.89 9 12590.00 8908.45 TD Plan Section information MD ft Incl deg Azim deg TVD ft +N/-S ft +E/-W ft DLS deg/100ft Build Turn deg/100ft degt100ft TFO .Target deg 11192.39 47.40 184.02 8590.80 -6271.20 282.35 0.00 0.00 0.00 0.00 11220.00 47.60 183.94 8609.45 -6291.51 280.94 0.76 0.72 -0.29 343.54 11240.00 49.37 183.53 8622.71 -6306.45 279.97 9.00 8.87 -2.06 350.00 11320.04 85.00 177.65 8653.27 -6379.01 279.73 45.00 44.51 -7.35 350.00 11395.03 85.84 143.80 8659.43 -6448.53 304.06 45.00 1.13 -45.13 270.00 11745.03 85.58 101.67 8686.85 -6633.01 590.98 12.00 -0.08 -12.04 268.00 11945.03 85.96 125.74 8701.83 -6712.62 772.25 12.00 0.19 12.03 90.00 12070.03 70.96 125.74 8726.77 -6783.94 871.38 12.00 -12.00 0.00 180.00 12195.03 70.86 141.62 8767.89 -6865.20 956.48 12.00 -0.08 12.70 93.00 12590.00 69.96 91.12 8908.45 -7024.23 1276.26 12.00 -0.23 -12.79 260.00 • • by BP Alaska sus Baker Hughes INTEQ Planning Report 1NTE Q .Company: BP Amoco Date: 7/10/2007 Time: 16:01.:22 Page: 3 Field: Prudhoe Bay . Co-ordinate(NE) Reference: Well: K-14, True North Site: PB K Pad Vertical (TVD) Reference: ' 26:1 4 9!1011987 00:00 53.2 Well: K-1 4 Section (VS) Reference: User (O.OON,O.OOE,130.OOAzi) Wellpath: Plan 12, K-14A Survey Calculation Method: Minimum Curvature Db: Orade Survey MD ' !feel Azim SS TVD N/S E/W MapN MapE 1)L5 VS r TFO' TooC ft deg deg ft ft ft ft ft deg/100ft ft deg 11192. 39 47.40 184.02 8537.60 -6271.20 282. 35 5969048.31 671866.63 0.00 4247.35 0.00 MWD 11200. 00 47.46 184.00 8542.75 -6276.79 281. 96 5969042.71 671866.37 0.76 4250.64 343.54 MWD 11220. 00 47.60 183.94 8556.25 -6291.51 280. 94 5969027.98 671865.69 0.76 4259.32 343.56 MWD 11225. 00 48.04 183.83 8559.61 -6295.21 280. 69 5969024.28 671865.52 9.00 4261.50 350.00 MWD 11240. 00 49.37 183.53 8569.51 -6306.45 279. 97 5969013.02 671865.05 9.00 4268.18 350.07 MWD 11250. 00 53.81 182.56 8575.72 -6314.28 279. 55 5969005.19 671864.82 45.00 4272.89 350.00 MWD 11275. 00 64.93 180.55 8588.44 -6335.75 278. 99 5968983.71 671864.75 45.00 4286.26 350.60 MWD 11300. 00 76.06 178.87 8596.77 -6359.27 279. 12 5968960.20 671865.42 45.00 4301.48 351.63 MWD 11320. 04 85.00 177.65 8600.07 -6379.01 279. 73 5968940.48 671866.47 45.00 4314.63 352.20 MWD 11325. 00 85.00 175.40 8600.50 -6383.94 280. 03 5968935.56 671866.89 45.00 4318.03 270.00 MWD 11350. 00 85.14 164.11 8602.65 -6408.41 284. 45 5968911.19 671871.87 45.00 4337.15 270.20 MWD 11375. 00 85.46 152.83 8604.71 -6431.55 293. 58 5968888.27 671881.52 45.00 4359.01 271.17 MWD 11395. 03 85.84 143.80 8606.23 -6448.53 304. 06 5968871.54 671892.39 45.00 4377.96 272.10 MWD 11400. 00 85.82 143.20 8606.59 -6452.51 307. 01 5968867.62 671895.43 12.00 4382.78 268.00 MWD 11425. 00 85.73 140.19 8608.43 -6472.08 322. 46 5968848.42 671911.32 12.00 4407.19 268.04 MWD 11450. 00 85.64 137.19 8610.31 -6490.80 338. 91 5968830.08 671928.20 12.00 4431.83 268.26 MWD 11475. 00 85.57 134.18 8612.23 -6508.63 356. 33 5968812.65 671946.01 12.00 4456.63 268.49 MWD 11500. 00 85.51 131.17 8614.18 -6525.52 374. 65 5968796.18 671964.71 12.00 4481.52 268.72 MWD 11525. 00 85.46 128.16 8616.14 -6541.43 393. 83 5968780.72 671984.25 12.00 4506.44 268.96 MWD 11550. 00 85.42 125.15 8618.13 -6556.30 413. 82 5968766.31 672004.58 12.00 4531.32 269.19 MWD 11575. 00 85.40 122.14 8620.13 -6570.11 434. 56 5968752.98 672025.63 12.00 4556.08 269.43 MWD 11600. 00 85.39 119.13 8622.14 -6582.81 456. 00 5968740.78 672047.35 12.00 4580.67 269.67 MWD 11625. 00 85.39 116.12 8624.15 -6594.36 478. 08 5968729.73 672069.68 12.00 4605.00 269.91 MWD 11650. 00 85.41 113.11 8626.16 -6604.74 500. 73 5968719.87 672092.57 12.00 4629.03 270.16 MWD 11675. 00 85.43 110.10 8628.15 -6613.92 523. 90 5968711.23 672115.93 12.00 4652.67 270.40 MWD 11700. 00 85.47 107.09 8630.14 -6621.86 547 .51 5968703.83 672139.73 12.00 4675.87 270.64 MWD 11725. 00 85.52 104.08 8632.10 -6628.56 571. 52 5968697.68 672163.87 12.00 4698.56 270.88 MV1fD 11745. 03 85.58 101.67 8633.65 -6633.01 590. 98 5968693.68 672183.44 12.00 4716.34 271.11 MWO 11750. 00 85.58 102.27 8634.04 -6634.04 595. 83 5968692.76 672188.30 12.00 4720.71 90.00 MV1fD 11775. 00 85.58 105.28 8635.96 -6639.97 620. 04 5968687.38 672212.64 12.00 4743.07 89.95 MWD 11800. 00 85.60 108.29 8637.88 -6647.17 643. 90 5968680.73 672236.66 12.00 4765.97 89.72 MWD 11825. 00 85.64 111.30 8639.79 -6655.61 667. 35 5968672.83 672260.29 12.00 4789.36 89.49 MWD 11850. 00 85.68 114.31 8641.68 -6665.27 690. 33 5968663.70 672283.48 12.00 4813.17 89.26 MWD 11875. 00 85.74 117.32 8643.56 -6676.13 712. 77 5968653.36 672306.16 12.00 4837.34 89.03 MWD 11900. 00 85.81 120.32 8645.40 -6688.14 734. 61 5968641.85 672328.27 12.00 4861.80 88.81 MWD 11925. 00 85.89 123.33 8647.21 -6701.29 755 .79 5968629.19 672349.75 12.00 4886.48 88.59 MWD 11945. 03 85.96 125.74 8648.63 -6712.62 772 .25 5968618.24 672366.46 12.00 4906.36 88.37 MWD 11950. 00 85.36 125.74 8649.01 -6715.51 776 .27 5968615.44 672370.55 12.00 4911.30 180.00 MWD 11975. 00 82.36 125.74 8651.68 -6730.03 796 .44 5968601.39 672391.05 12.00 4936.09 180.00 MWD 12000. 00 79.36 125.74 8655.65 -6744.44 816. 48 5968587.44 672411.40 12.00 4960.70 180.00 MWD 12025. 00 76.36 125.74 8660.91 -6758.72 836. 31 5968573.62 672431.56 12.00 4985.07 180.00 MWD 12050. 00 73.36 125.74 8667.44 -6772.81 855. 90 5968559.98 672451.46 12.00 5009.13 180.00 MWD 12070. 03 70.96 125.74 8673.57 -6783.94 871. 38 5968549.20 672467.19 12.00 5028.15 180.00 MWD 12075. 00 70.93 126.37 8675.19 -6786.71 875 .17 5968546.53 672471.05 12.00 5032.83 93.00 MWD 12100. 00 70.81 129.54 8683.39 -6801.23 893 .79 5968532.43 672489.99 12.00 5056.43 92.79 MV1fD 12125. 00 70.74 132.72 8691.62 -6816.76 911 .57 5968517.32 672508.12 12.00 5080.03 91.75 MWD 12150. 00 70.74 135.90 8699.87 -6833.24 928 .46 5968501.23 672525.38 12.00 5103.56 90.71 MWD 12150. 39 70.74 135.95 8700.00 -6833.51 928 .72 5968500.97 672525.64 12.00 5103.93 89.66 K-14A 12175. 00 70.78 139.07 8708.11 -6850.64 944 .41 5968484.20 672541.72 12.00 5126.96 89.64 MWD 12195. 03 70.86 141.62 8714.69 -6865.20 956 .48 5968469.92 672554.12 12.00 5145.57 88.61 MWD 12200. 00 70.75 140.99 8716.33 -6868.86 959 .41 5968466.33 672557.14 12.00 5150.17 260.00 MWD 12225. 00 70.27 137.85 8724.67 -6886.76 974 .74 5968448.78 672572.87 12.00 5173.42 260.20 MWD 12250. 00 69.84 134.69 8733.20 -6903.74 990 .98 5968432.18 672589.49 12.00 5196.77 261.25 MWD • • by BP Alaska B ~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 7M 012007 Time: 16:01.:22 Page: 4 Field; Pnidhoe Bay Co-ordinate(NE) Reference: Well: K-14, True North Site: PB K Pad Vertical ('f'VD) Reference: 26 : 1 4'9!1011987.00:00 53.2 We1L• K-7 4 Section (YS) References User (Q.OON,O.OOE,130.OOAzi) Wellpatb: Plan 12, K-14A Survey CaknlationMethod: Minimum Curvature Db: OraGe Survey MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft - ft deg " 12275.00 69.47 131.52 8741.89 -6919.76 1008. 09 5968416.56 672606.96 12.00 5220.18 262.33 MWD 12300.00 69.16 128.33 8750.73 -6934.77 1026. 02 5968401.97 672625.23 12.00 5243.56 263.43 MWD 12325.00 68.90 125.13 8759.68 -6948.73 1044. 73 5968388.44 672644.25 12.00 5266.86 264.56 MWD 12350.00 68.71 121.92 8768.72 -6961.60 1064. 16 5968376.02 672663.97 12.00 5290.02 265.71 MWD 12375.00 68.57 118.70 8777.82 -6973.35 1084. 25 5968364.73 672684.33 12.00 5312.97 266.87 MWD 12400.00 68.50 115.48 8786.97 -6983.94 1104. 97 5968354.62 672705.27 12.00 5335.64 268.04 MWD 12425.00 68.49 112.25 8796.14 -6993.35 1126. 23 5968345.70 672726.75 12.00 5357.98 269.22 MWD 12450.00 68.54 109.03 8805.30 -7001.55 1148. 00 5968338.00 672748.70 12.00 5379.93 270.40 MWD 12475.00 68.66 105.81 8814.42 -7008.51 1170. 20 5968331.54 672771.05 12.00 5401.41 271.58 MWO 12500.00 68.83 102.60 8823.48 -7014.23 1192. 79 5968326.34 672793.76 12.00 5422.39 272.76 MWD 12525.00 69.07 99.39 8832.47 -7018.68 1215. 69 5968322.42 672816.75 12.00 5442.79 273.92 MWD 12550.00 69.36 96.20 8841.34 -7021.85 1238. 84 5968319.78 672839.97 12.00 5462.56 275.07 MWD 12575.00 69.72 93.02 8850.08 -7023.73 1262. 19 5968318.43 672863.35 12.00 5481.65 276.21 MWD 12590.00 69.96 91.12 8855.25 -7024.23 1276. 26 5968318.25 672877.43 12.00 5492.76 277.32 3 3/16" • • ~~ ~ ~ I,. # it k-~ l "i~ 11 ? +itirljl 41~iifirtt~t $ -t ~ ~t,f ' 1i 4k~~ 1 ~ :. 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I I. pp+qi+liCQiL s ~aa i f { {~1} _T 1 r~ _ I s ° ~ 7L~i~ii~7 ~ asy. .saa -I. , i ~} ~ -i-7.1 ~ I I _~_~rt ~ :. ~- i~ .;.II ~{'. _ 1 '~. n ~ ~~iE~~~~~ ~ 3888888888 ~I~ I k,S - ( 4' Y 8 ~ ~ s; - ~ ~i~~lil=~3S~ 1 .$ ~~;~1 ~-~I~1 I I .I~; '~ }~+_.{~+~ }}`# r+rl-±lr+.. tt ~ N ~ _ °m q si -: ~' ~:I ~l ~ +! i. ,ti.~.~ l ~ C..ril ~t {1~; 1'~tf I II ~I i i~ R a ~ o ~;o: e ~ ~ 1~~~~~C~~ ili5i~35e: ,. ~ ~ 1 ~ ~ 1-^ r ~ ~ -..} t - t ~ I ~. ~}}--~~-- x ~' a a_ ° sssssssssi, i, I lil` , t ill. ~ ~~ - 7 ~) } i~I iii ~ ~ ~ ~ ~ s ,...._.: l ~ t ~ : L I ' i I ' I {~ I + r 1 r ~ 1 ~ ~ {- { l ~- a pia=~ ~ ' se ~ ;3 =oa-- ~ tiiii $ ~ ~itl ~~I ' ', t'ii_:'tl ~,t ~ai~ 1'~ ~ ~ k~ f. ~ m ~t E ~~ R ~ ~ 9~$€~$>s~i '! ~ ~ ~ I 1 1 t { ` j~-H y L r ; i t ~~ ' ~ ' t + } ~ ~ ~ ~,j, I L.. ~~ ~ , .~,~. f~ i~i~~~ 9 ; ~ssaas°ves (F ~; f~ ~~ ' I I ~ YR 9vRrS I I' ~II 1WAIOi1 gM01~~MM gel ...yn~ by BP Alaska Anticollision Report Nits sus INTEQ ..Company: BP Amoco Date: 7/10/2007 Time: 16:19:01 Page: 1 Fretd•' Prudhoe Bay Reference Site: PB K Pad Co-ordieate(NE) Reference: Well: K-14, True North Reference We1L• K-14 Vertieal (1'VD) Reference: 26 :14 9/10/1987 00:00 53.2 Reference Wellpath: 'Plan 12, K-14A Db: Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Raeells in this9ii911L'ipal Plan 8 PLANNED PROGRAM Interpolation Method: MD Inte rval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 11192.39 to 12590.00 ft Scan Method: Trav Cylinder North Maximam Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7!5/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 38.50 11192.39 1 : Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 11192.39 12590.00 Planned: Plan #1 2 V3 MWD MWD -Standard Casing Points MD TVD Diameter Hok Size Name ft ft in in 12590.00 8908.45 3.188 4.125 3 3/16" Summary ~- -- :Offset Wellpath --------> Reter+eoce Offset Ctr-Ctr No-Go Allowable. Site Well. Wellpath MD MD Distance Area Deviation Wareing ft ft ft ft ft PB DS 15 15-21 15-21 V6 12483.25 12036.20 1267.94 254.03 1013.90 Pass: Major Risk PB DS 15 15-21A 15-21A V7 11425.00 13400.00 972.63 320.51 652.12 Pass: Major Risk PB DS 15 15-22 15-22 V1 Out of range PB DS 15 15-46 15-46 V1 12483.01 12425.00 755.07 343.01 412.06 Pass: Major Risk PB DS 15 15-46 15-46L1 V2 Out of range PB DS 15 15-46 15-46L1 P61 V1 Out of range PB K Pad K-14 K-14 V1 11200.00 11200.00 0.00 270.29 -270.28 FAIL: Major Risk PB K Pad K-16 K-16 V3 12093.09 12123.80 1365.21 368.09 997.12 Pass: Major Risk PB K Pad K-20 K-20 V1 Out of range PB K Pad K-20 K-20A V1 Out of range Site: PB DS 15 Well: 15-21 Rule Assigned: Major Risk Wellpath: 15-21 V6 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/I3SUistance Area Deviation .Warning ft ft ft ft ft ft deg. deg in ft ft ft 12425.00 8849.34 10300.00 7591.07 34.40 37.42 169.43 57.17 2483.68 218.19 2265.48 Pass 12425.00 8849.34 10400.00 7679.13 34.40 37.69 170.76 58.50 2401.60 220.93 2180.67 Pass 12425.00 8849.34 10500.00 7766.95 34.40 37.95 172.15 59.90 2320.21 223.82 2096.39 Pass 12425.00 8849.34 10600.00 7854.79 34.40 38.21 173.64 61.39 2240.12 226.76 2013.36 Pass 12425.00 8849.34 10700.00 7942.28 34.40 38.48 175.20 62.95 2160.82 229.77 1931.05 Pass 12425.00 8849.34 10800.00 8029.46 34.40 38.75 176.85 64.60 2082.46 232.86 1849.60 Pass 12434.08 8852.67 10900.00 8116.53 34.18 38.70 177.84 66.76 2005.03 234.34 1770.69 Pass 12437.42 8853.89 11000.00 8202.63 34.10 38.84 179.36 68.71 1927.92 236.74 1691.17 Pass 12441.06 8855.22 11100.00 8288.59 34.02 38.93 180.99 70.81 1852.58 239.04 1613.53 Pass 12450.00 8858.50 11200.00 8374.48 33.80 38.84 182.34 73.31 1779.55 240.22 1539.33 Pass 12450.00 8858.50 11300.00 8458.49 33.80 39.08 184.53 75.50 1706.69 243.37 1463.32 Pass 12450.00 8858.50 11400.00 8541.21 33.80 39.32 186.86 77.83 1635.03 246.64 1388.39 Pass 12450.00 8858.50 11500.00 8624.05 33.80 39.55 189.39 80.36 1566.52 249.79 1316.74 Pass 12460.48 8862.32 11600.00 8706.57 33.65 39.39 191.28 83.60 1500.93 250.44 1250.49 Pass 12465.02 8863.98 11700.00 8789.02 33.59 39.32 193.89 86.79 1439.11 252.03 1187.08 Pass 12475.00 8867.62 11800.00 8871.77 33.44 39.02 196.30 90.50 1381.99 251.71 1130.27 Pass 12475.00 8867.62 11900.00 8954.54 33.44 39.12 199.81 94.00 1329.82 253.96 1075.86 Pass 12475.00 8867.62 12000.00 9037.31 33.44 39.23 203.58 97.77 1283.34 255.74 1027.60 Pass 12483.25 8870.62 12036.20 9067.28 33.38 38.96 204.33 99.58 1267.94 254.03 1013.90 Pass • • are L ~~_/ I..L of bag BAG Dowell of bag Blind/Shears TOTs 2 3/8" combi ram/slips Mud Cross I I Mud Cross cross variable bore pipe 3 1/2"-2 7/8" TOTs 2 3/8" combi ram/slips Swab Valv Flow Tee Alaska Department of Natural Resources Land Administration System Page 1 of 2 ~~ r"~.!:~sk ~a ~~;~. ~ ~ ~~~. ,., =~~ort~er's Search; State Cabins ~atua~l ~ ~ X41 s Alaska DNR Case Summary File Type: ADS ~ File Number: _?8303 ~ Printable Case File Summary See Township, Range, Section and Acreage? ~` Yes C> No New Search _1 I.AS nli~ntl ~ Case Abstract ~ Case Detail ~ Land Abstract _ ~, 1~'ile: AUL 28303 `'~~'~'' Search for Status Plat Updates :~~ cif 07% 19r~'007 C,'~r~!~n2ez~: 000107377 BP EXPLOR.-~11ON (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99519661.2 C'ccse Tvpe: ~~ OIL & GAS LEASE COMP File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Total Acres: 2560:000 Office of Primary Responsibility: DOG I Last Transaction Date: 12/04/2006 DNR Unit: 780 OIL AND GAS Status Date: 09/14/1965 Date Initiated: 05/28/1965 >IV OIL AND GAS Case Subtvbe: NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED ~ ~~t['17C~Ipi1: ~~ ]r)lt'/L~/~t~J: 011N ~~[1I1,~E': n~ ~i', ,`•'['CllOn: ~_~ ~~cChllil.~C/'~'S: ~~=~U SG'~t'Ci"1 Plats ;Llc~i~li~ur: ll foil>n~{zip: O1 IN Rurr,~rc: 014C~. Sc~fiu~1: U4/ Sc~cttuft ~lcrcrs: 640 i~INYI[/1011: ~_~ jUl6il~~'/n~I: OI ~ N /~Qil~'C: 0~ 4E ,ti~c'C/1(41: O~)~ ~SE'Cl!Oj1 ~ICF(LC: 64O I~k~riclic~r~: U 7r~i~~~~.~~1zip: O11N Range: 014E S~~e~tion: l0' S'ei ion~lcres: 6411 Le;;al Description 0~-28-196 * * * SASE NOTICE LEGAL DESCRIPTION* C1=~-12~ IIN 14E UM 3, ~, 9,10 260.00 U- 3- 7 End ~-f Case Sum»ary Last updated on 07119/2007. http://www.dnr.state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28303 &... 7/19/2007 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~.8~ ~/~~ PTD# os'~~~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 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 contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until. after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 ~ • ^^ , . „ , , o ~ a ~ , N N , a~ o ` , o ~ ~ , , ~ , c Q ~ , , , 3 O i ~ ; N m. o o a c, a, c. ~, a. 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O O ~ o ~ a „_ „_ c ~ o m o _ y o, o, Q c , ~ a ~ _ fl. c ~ . a o, ~ ui' Q ~ 3 o ~ ~e '~ . ~' a~' m' ' ~ ' ' ' m o' ' ' o o' a~ Z' , o' ' ~ m' 3 m v- i -a , ~ o' o i ~ ,u a , Q m E a a m ' . m o ~ .a °~' o t o r c m - a ~' ' 3 ,., t a ° a~ a ~ o °: 3' r ' ~' ' 3 3' ° ~ ~c ° Z . .a a, c a' ~ ~ ~ . .~ o, a ~~ ~ 3, a ca' f° a; E. a~, a i; y ~ ~, ~ ~ ~~ c n; ~~ w. ~ ~ ° ~ ~, ~ °= ' o 3, ~ ° ; ~ o W U O o a o~ c 4=~ ~ m o >~ o' m ~~ o a. a~ a. m o o~ c I `m~ ~' ' a ~ o. o, ~ a a~ o' Y d v o N' E' a~ E' o . rn c o ~i' ~ ~, m. .~ ~' c a ~ . t a o, ~° a fl ~, o . v. o fl o ~ a o, ~ v ~; v I a o' m' ~i Y - , a ~ m ~ m' ~ ` ~ O, , ~ ~ ~ ~, c' o, N o' ~ U. p, , ~~ ~ O O ' O1 N~ o, 3' , , '~ o' ~ f tq M m .L.. ~-' N, ~ c ~ 0- f6 f6 , , f6 N~ N 0) m. ~ f0' p' N. , , a ~ C. U, 'm -a ~~ N. :~, 2. c N. "' O. N, p L• , o. a • v N O ~ ~~ m c_ C' ~ O. O. N. y ~ y 4J, N~ N ~ , ~ 3~ ~, a' Of ~ ~ c ~ i. p, ~ Di N' C, C' N ~ ._ p, O a ~~ . ~~ V, ~~ V, p, a d~ N T ii d m. ' ~ E - a. a a ' °~ ~ ~, : v. ~ - c' m' ~ 0 ~, s, c a ~, ~ c' ~ ' N' N' a -o ~o o' .N? ~ ~ ~ s, 3 °O ~ •~ o o ~' ~ c m m w m . . ' 8 , , ~ , ~ 3. ~ o' i' o, m o c cr a~' m; ' =' ai ~ a m' ~ ` . ~ m oi' o, . m v c ~ ~' ' °~ °~ ~, m ~ ~ ~ `~ a `~ o !~~ o, o ~ a~ ~ ~, •3 ~, ~ v, ~, ~C ~ ui, o ~ 3; N; ~~ o' a '?; ~; ~; a J m E' m ~ ° - ~, - , , a ~ a~i m. ~ ~ c 3 ~ c ~ ~' c '`° ~ ~ ° `~ ° ? ~ 0 a; o ~ a ~ ~ ° c N, m 's .. Y ~, ~ a a~ ~ ~ ~ . ~ c, ~; ~; ~; O ~, v' cn a> a o_ O; O; m a; a~ a; m U . m - o. ; z ~; ¢; n t o, ~, g' ~; tq U U; U ~; U m U; i a a Q; a i, - ~ a. v' O, o; m Q O, ~ m U c i ~ ~; y; ~' m, a : ~ o; . . m, a~ o, <n cn; U ~ U c , , , , -, . , , , , -, , , -, , , , , W a _ ~ O ~ N M ~~ t0 h _ 00 O O N M ~ ~ (O h 00 O _ O N M d' ~ O ~ O O O ~ N M I tp (D __. I~ O O _ ~ ~ ~ N N N N N N N N N N M M M M M M M M M M U U __ _ _. ~ ~ h ~ . . p C G C N _N O N O N_ U w o k o _m ~, o ~ o~ aN " /~ Li. O JL.1 ~ ~ •L ~ i ~ C C ~ C N J !~ c m ~ ~ U E a cn ~ a g ~ '~ ~ ~ o a to U ~ a a a ¢ w a~ ~ a s • Well History File U APPENDIX Information of detailed nature that is not particularly germane to the Welt Permitting Process but is part of the history file. To improve the readability of il~e Well History file and to simplify rending infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronatogicatly organize this category of information. ~o~- ~a~ C~ **** REEL HEADER **** MWD 08/12/02 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/11/14 1662127 O1 • W 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10835.0000: Starting Depth STOP.FT 12607.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K-14A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 20' 18.327"N 148 deg 36' 31.729"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 14 Nov 2007 API API NUMBER: 500292175201 Parameter Information Block #MNEM.UNIT Value SECT. 04 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 53.2 DMF DF EKB .F 0 EDF .F 53.2 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. ao~-!®a ~ 1~~9 y (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 Schlumberger GR CNL per the request of Doug Stoner with BP Exploration (Alaska), Inc. (8) Tied to K-14 at 11192.39 feet MD (8537.6 feet TVDSS). (9) The sidetrack was drilled from 05-13A through a milled window in a 7 inch liner. Top of window 11223.7 ft.MD (8559 ft.TVDSS) Bottom of window 11231.5 ft.MD (8564 ft.TVDSS) (10) The interval from 12607 feet to 12634 feet MD (8851 feet to 8860 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour TVD -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10836.3, 10837.6, ! 1.24414 10849.8, 10851.3, ! 1.45117 10865.8, 10866, ! 0.207031 10868, 10867.6, ! -0.415039 10871, 10871.6, ! 0.621094 10872.8, 10873.6, ! 0.829102 10876.5, 10877, ! 0.414062 10883.6, 10883.8, ! 0.207031 10885.7, 10885.7, ! 0 10886.7, 10887.1, ! 0.415039 10889.4, 10889.6, ! 0.207031 10949.6, 10950, ! 0.414062 10952.3, 10952.3, ! 0 10956, 10955.8, ! -0.207031 10958.1, 10958.1, ! 0 10962.5, 10961.4, ! -1.03613 10966.4, 10965.8, ! -0.62207 10971.6, 10972.2, ! 0.62207 10981.1, 10981.9, ! 0.829102 10984, 10984.8, ! 0.829102 10986.3, 10986.9, ! 0.621094 10995.4, 10996.7, ! 1.24316 10999.4, 11000, ! 0.62207 11226.4, 11228.9, ! 2.4873 11228.7, 11230.6, ! 1.86523 11230.2, 11231.8, ! 1.65918 11232, 11234.1, ! 2.07324 11247.2, 11249.5, ! 2.28027 11271.4, 11273.2, ! 1.86621 11281.5, 11283.2, ! 1.65918 11288, 11289.8, ! 1.86523 11290.6, 11293.5, ! 2.90234 11295.4, 11297.3, ! 1.86523 11307.6, 11308, ! 0.414062 11391.5, 11393.4, ! 1.86621 11488, 11487.6, ! -0.414062 11499.2, 11498.4, ! -0.829102 11638.9, 11642, ! 3.10938 C~ 11763, 11766.1, ! 3.10938 11891.5, 11894.2, ! 2.69531 11893, 11896.1, ! 3.10938 11895.5, 11898.1, ! 2.69531 11897.9, 11899, ! 1.03711 11902.5, 11903.7, ! 1.24414 11905.2, 11908.1, ! 2.90234 12057.1, 12056.4, ! -0.621094 12081.5, 12080.1, ! -1.4502 12118.3, 12119.5, ! 1.24414 12124.1, 12126.1, ! 2.07227 12127.8, 12129, ! 1.24316 12131.5, 12133, ! 1.45117 12160.8, 12162.7, ! 1.86621 12167.1, 12170.2, ! 3.10938 12176, 12175.1, ! -0.829102 12178, 12177, ! -1.03711 12181.6, 12179.5, ! -2.07227 12195.9, 12198.4, ! 2.4873 12202.3, 12204.4, ! 2.07227 12206.2, 12208.5, ! 2.28027 12209.6, 12211.6, ! 2.07324 12212.5, 12214.3, ! 1.86523 12226.2, 12230.8, ! 4.56055 12232, 12235.6, ! 3.52441 12253, 12255.9, ! 2.90234 12269.1, 12273.1, ! 3.93945 12273.6, 12277.9, ! 4.35254 12277.1, 12281.5, ! 4.35352 12285.8, 12289.3, ! 3.52344 12321.3, 12324.4, ! 3.10938 12349.3, 12349.5, ! 0.208008 12352.8, 12352.6, ! -0.207031 12354.7, 12355.7, ! 1.03711 12369, 12369, ! 0 12385.8, 12382.3, ! -3.52441 12400.3, 12398.5, ! -1.86621 12421.7, 12421.7, ! 0 12446.2, 12446, ! -0.207031 12448.7, 12450.2, ! 1.4502 12452.5, 12453.1, ! 0.62207 12470.5, 12471.1, ! 0.62207 12472.8, 12473.8, ! 1.03613 12474.8, 12476.5, ! 1.6582 12490.1, 12491.3, ! 1.24414 12493, 12494.4, ! 1.45117 12499.4, 12501.9, ! 2.48828 12504, 12506, ! 2.07324 12512.5, 12513.5, ! 1.03711 12514.7, 12515.4, ! 0.62207 12517.2, 12518, ! 0.829102 12521.4, 12521.6, ! 0.207031 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 160 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 r~ 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN K-14A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN K-14A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** L~ ~~!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Comtrol) log provided by Schlumberger GR CNL per the request ofDoug Stoner with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 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 8 Total Data Records: 43 Tape File Start Depth = 10835.000000 Tape File End Depth = 12607.000000 Tape File Level Spacing = 0.500000 i Tape File Depth Units **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 = feet 52 records... 54 bytes 4124 bytes *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN K-14A.xtf LCC 150 CN BP Exploration (Alaska) WN K-14A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1,000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 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: 84 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 2 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 8 Total Data Records: 85 Tape File Start Depth = 10835.000000 Tape File End Depth = 12607.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 94 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/11/14 1662127 O1 **** REEL TRAILER **** MWD 08/12/02 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 10835.0000 -999.2500 -999.2500 10835.5000 65.7865 -999.2500 10900.0000 54,8806 -999.2500 11000.0000 30,2188 -999.2500 11100.0000 -999.2500 -999.2500 11200.0000 -999,2500 -999.2500 11300.0000 28,5000 95.3000 11400.0000 24,8040 107.3951 11500.0000 33.8207 75.5204 11600.0000 23.8409 106.7264 11700.0000 25.1398 80.9801 11800.0000 27.1903 65.5450 11900.0000 35.4202 59.3218 12000.0000 38.0081 102.3411 12100.0000 22.5348 79.6138 12200.0000 85.4352 34.6510 12300.0000 26.7565 108.3843 12400.0000 32.8373 102.2608 12500.0000 25.9885 88.9389 12600.0000 65.7531 99.3336 12607.0000 50.5195 89.7969 Tape File Start Depth = 10835.000000 Tape File End Depth = 12607.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet i ~ Tape Subfile 3 is type: LIS DEPTH GR ROP 10835.0000 86.9000 -999.2500 10835.2500 -999.2500 -999.2500 10900.0000 54.6000 -999.2500 11000.0000 31.5000 -999.2500 11100.0000 -999.2500 -999.2500 11200.0000 -999.2500 -999.2500 11300.0000 30.1000 94.9000 11400.0000 23.5000 109.0000 11500.0000 32.1000 75.4000 11600.0000 25.4000 104.0000 11700.0000 23.5000 80.0000 11800.0000 25.6000 90.7000 11900.0000 30.6000 65.0000 12000.0000 35.7000 131.8000 12100.0000 22.5000 80.5000 12200.0000 112.8000 70.8000 12300.0000 21.6000 132.7000 12400.0000 36.2000 143.5000 12500.0000 39.1000 78.5000 12600.0000 64.0000 97.7000 12607.0000 50.4000 89.0000 Tape File Start Depth = 10835.000000 Tape File End Depth = 12607.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • Tape Subfile 4 is type: LIS
