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Home My WebLink About207-067New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 • • ~~ ~ ~ ~~~~ ~~~ ~~~~~ ~~~~ : ~~~~~ ~' OI" c?/1/Z//?g (done) ^ Two-sided II ( II ~) II I) II I II III ^ Rescan Needed II ~ II ~I II II ( I I) I II g RE AN DIGITAL DATA OVERSIZED (Scannable) Co r items: ~kettes, No. ' ^ Maps: reyscale items: `~~ ^ Other, No/Type: ^ Other items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~S~ Project Proofing II I II'II) I((II I(~II BY: Maria Date: ~ ~S~ ~ ~ Scanning Preparation ~ x 30 = ~d + ~ ~= TOTAL PAGES ~ ~ (Count does not include cover sheet) ~ BY: Maria Q Date: ~S~ r duction Scannin Po g III IIIIII IIIII II III : ~~Q (Count does include cov r sneet) d Fil f S rom Stage 1 Page Count e canne Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: g 3~q / ! /sf ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ I( III ) I I Scanning is complete at this point unless rescanning is required. II I(I I I ( II I ReScanned III (I~II~~IIII ~~I~~ BY: Maria Date: ~S~ Comments about this file: Quality Checked I II ( III II (I I I~~ I II I 10/6/2005 Well History File Cover Page.doc ~, ,~ ~,~ .~ $~ , ~' , ~ w ~' 2 r~ ~ ~~ ~a r~ ~t MICROFILMED 6/30/2010 DO NOT PLACE ANY N EVii MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Company ConocoPhillips, Alaska, Inc. Well Name 1B-15AL3P61 ~~~~~~ Date 11/17/2009 /~ Gl~ ~!°li 1t'r l;! :, ;. . rise BA~ H1~IGHES IlrTTEQ ~- N 0 a Page 1 of 4 Company Well Name Date ConocoPhillips, Alaska, Inc. 1 B-15AL3 ~~~ 11 /17/2009 / ~ ^ Page 1 of 4 ~, I ~ __,,_ ~ ., ,,i ti J ;'l~i~! i ~r.~~ BAKER Ht~GHES INTEQ ~ ~ Jw~ DATA SU BMITTAL COMPLIANCE REPORT 6/2212009 Permit to Drill 2070670 Well Name/No. KUPARUK RIV UNIT 1 B-15AL3 Operator CONO COPHILLIPS ALASKA INC API No. 50-029-22465-62-00 MD 10952 lVD 6364 Completion Date 6/28/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other ~ogs Run: MWD DIR / GR (data taken from Logs Portion of Master Well Data Maint ~ Weil Log Information: Log/ Electr Data~' Digital Dataset Log Log Run Interval OH / Ty ~ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 9053 10952 Open 7/24/2007 Includes PB 1(8175' - 9223') pt Directional Survey 9053 10952 Open 7/24/2007 Includes PB 1(8175' - 9223') ~ Well Cores/Samples Infortnation: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL IrFORMATION Well Cored? Y~ Daily History Received? Y/ N ~ Chips Received? Y/ N Formation Tops ~ N Analysis ~G/-~d- Received? Comments: (~ ~`~r « `~ ~~ ~ l . ~ c~ ~ ~v~ J ~ ~ v.~, ~i ~ < rl ~a.~ ~j+~,u~t~l, ~ , ~ l~ J~ ~ °~ ;C ~~ / K ~ ~ V L`J Compliance Reviewed By: ~n~...~,_ . ~ Date: ~ STATE OF ALASKA !~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~x ;'``~~~~~~ ~~~~~~ ~ ~ zooT `:~ , .< ~ t:~:.~ f~°~ns. CQmmissian 1a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class: ""' "~~° 20AAC25.105 zoaa,czs.~,o ~ Development~^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number Conoco Phillips Alaska Inc. 6/28/2007 / 207-067 ~ 3. Address: 6. Date Spudded 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6/13/2007 ~ 50-029-22465-62-00 . 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' M f 6/25/2007 ~ Kuparuk 1B-15AL3 " FNL, 484 500 FEL, SEC. 09, T11 N, R10E, U Top of Productive Horizon: 8. KB (ft above MSL): 95 15. Field / Pool(s): 2850' FNL, 3305' FEL, SEC. 09, T11 N, R10E, UM Ground (ft MSL): Kuparuk River Unit / Kuparuk Total Depth: 9. Plug Back Depth (MD+~/D) River Pool ~ 2069' FNL, 1423' FEL, SEC. 09, T11 N, R10E, UM 10952 6364 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+~/D) 16. Property Designation: Surface: x- 549955 ~ y- 5969647 ~ Zone- ASP4 10952 ' 6364 ` AD,L 025648 ~ TPI: x- 547155 y- 5967279 Zone- ASP4 11. SSSV Depth (MD+T~/D) 17. Land Use Permit: Total Depth: x- 549030 ~ y- 5968071 - Zone- ASP4 1483 1482 18. Directional Survey ~ Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1558 (Approx.) 21. Logs Obtained (~ist all logs here and submit electronic and printed information per 20 AAC 25.071): To~ ~,e~ ~ mac~ : f3ZZ~' f MWD DIR / GR GZ$~ 22. CASING, LINER AND CEMENTING RECORD T' Z7•~ 7 CASING SETTING QEPTH MD SETTING DEPTH TVD HOIE AMOUHT '+ ` WT. PER FTJ GRADE TOP ` BOTfOM TOP BOTfOM S1Z~ CEMENTING RECORD PULIED ` 16" 62.5# H-40 Surface 121' Surface 121' 24" 200 sx Arcticset I 9-5/8" 40# L-80 Surface 4190' Surface 4138' 12-1/4" 900 sx AS III 400 sx Class'G' 7" 26# L-80 Surface 4405' Surface 4324' 8-1l2" 350 sx Class 'G' 5-1l2" 15.5# L-80 4234' 8350' 4176' 6361' 6-1/8" 38 sx Class'G' 3-1l2" 9.2# L-80 8121' 27' 6170' 6257' 6-1/8" 55 sx Class'G' 2-3/8" 4.44# L-80 8244' 10952' 6270' 6364' 3" Uncemented Slotted l.iner 23. Open to production or inject ion? ~ Yes ^ No 24. Tueiac Recazo If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): Size DePTH SeT MD PACKER SET MD 2-3/S" Slotted Section 3-1 /2", 9.3#, L-80 8121' 7890' MD TVD MD TVD 8245' - 8277' 6271' - 6293' :E~c. 25 ' Acio Fw-eruaE CEnn~Nr Sc~uEEZe 8902' - 9601' 6325' - 6355' , , . , 9637~ - ~O9'IH' 6356~ - 6384~ DEPTH INTERVAL MD AMOUNT Hc KIND OF MATERIAL USED 8227' Set Retrievable Baker KB Packer / Whipstock {w/ 1" flow-thru vent) 2200' Freeze Protect w/ Diesel ZB. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 8, 2007 Gas Lift Date of Test: Hours Tested: PROOUCr~or, FoR QIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 7/19/2007 15 TEST PERIOD 201 761 851 176 Bean 4,101 Flow Tubing Casing Press: C,a~cu~.aTeo OIL-BBL: GAS-MCF: WATER-BBL: Oll GRAVITY-API ~CORR~: Press. 150 828 24-HOUR RATE• 2gg 1,225 1,347 24 ° 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~~~~~~ None RBD'I~S ~F~ AUG ~ 4 20D7 ~ z.07 v~~r ~~~ ~~~ b ~ Form 10-407 Revised 02/200~ }(.~'t--~ ~'~H ~CONTINUED ON REVERSE SIDE ~c'~ j~ ~/~ 7 L7. 07 ~ l~ ~ ~ V ~~ "~'(fY~' ZS. GEOIOGIC MARKERS ~LIST ALL FORMATIONS AN KERS ENCOUNTERED~: Z9. NAME MD ND 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. Base Kuparuk C3 ! Top C2 8245' 6271' None Base Kuparuk C2 / Top C1 8254' 6278' Base Kuparuk C1 / Top B 8276' 6292' Base Kuparuk C3 / Top C2 9415' 6335' Base Kuparuk C2 / Top C1 9495' 6347' Base Kuparuk C4 / Top C3 10270' 6362' Base Kuparuk C4 / Top C3 10665' 6369' Formation at Total Depth (Name): Base Kuparuk C4 / Top C3 10665' 6369' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg9ing is true and correct to the best of my knowledge. O~~~ I~ ~ Signed Terrie Hubble / Title Technical Assistant Date Kuparuk 1 B-15AL3 207-067 Prepared By Name/Number.~ TerTie Hubble, 564-4628 Drilling Engineer: Mel Rixse, 564-5620 Well Number Permit N./ A roval No. INSTRUCTIONS GeNew-~: 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 to-407 wel! completion report and 10-404 well sundry report when the downhole well design is changed. ITea~ 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. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. 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). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraufic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Irem 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. FORMATION TESTS Form 10-407 Revised 02/2007 Submit Original Only . ~ Summary of Operations Kuparuk 1 B-15AL3, Multilateral Permit # 207-067, API # 50-029-22465-62-00 Date Job Type Summary of Pre-Rig Operations 3/16/07 SBHP/FBHP Survey (11) D&T TO 8259' RKB (DEPLOY SLV) W/ 2.65" CENT. RUN DUAL PANNEX GAUGES, SAT DOWN HIGH Q 8084' RKB. TOOK SBHP C~ 8074' RKB=2163 psi, 156 deg F. GRADIENT STOP MADE @ 7974' RKB. "'"JOB COMPLETE'~' 3/22/07 Ann-Comm PRE CTD, POT & PPPOT- T& IC ( PASSED), MITOA ( PASSED), TIFL ( PASSED), PT MV & SV (PASSED), DD MV & SV ( PASSED), DD SSSV (PASSED). 4/24/07 Drilling Support - Capital LOGGED PDS MTT FROM 8250' TO 800Q' SLM. 5/17/07 Drilling Support - Capital RUN PDS MTT FROM 8258' RKB- 8000' SLM. 1ST RUN, TOOL FAILED. 2ND RUN APPEAR TO HAVE GOOD DATA. JOB COMPLETE. 5/25/07 Drilling Support - Capital ATTEMPTED SET 2.75" X-PLUG @ 8032' RKB. IN PROGRESS. 5/26/07 Drilling Support - Capital BRUSHED AND FLUSHED TBG. SET 2.75" XX PLUG @ 8032' RKB; SET CATCHER SUB ON PLUG. PULLED OV @ 7822' & GLV @ 6978' RKB. IN PROGRESS. 5/27/07 Drilling Support - Capital PULLED GLVs FROM 5093', 3903', 2631' RKB. SET DVs @ 2631', 3903', 5093', 6974' RKB. READY TO PUMP FLUID. IN PROGRESS. 5/28/07 Drilling Support - Capital LOADED CSG W ITH SW & DSL CAP. SET DV @ 7822' RKB. MITIA 2500 PSI, GOOD. PULLED CATCHER SUB @ 8032' RKB, PULLED PLUG @ 8032' RKB. DRIFTED TBG WITH 2.74" x 15' DUMMY WHIPSTOCK, NO RESTRICTIONS. Summary of Post Rig Operations i 6/29/07 Drilling Support - Capital TAGGED TBG STUB C~ POOR BOY OVERSHOT @ 8081' RKB. TAGGED TOP OF LINER DEPLOYMENT SLEEVE WITH LIB @ 8253' RKB. GAUGED TBG TO 8235' RKB WITH 2.68" SWAGE, UNABLE TO WORK THRU WINDOW. IN PROGRESS. 6/30/07 Drilling Support - Capital INSTALLED NEW GAS LIFT DESIGN @ 2631', 3903' & 5093' RKB. PULLED SLIPSTOP CATCHER. IN PROGRESS. 7/1/07 Drilling Support - Capital ATTEMPTED PULL WHIPSTOCK WITH BAKER HOOK. PULLED BIND IN WINDOW AREA, NOT ENGAGING W/S. RAN BRUSH & MAGNETS, RECOVERING METAL SHAVINGS. IN 7/2/07 Drilling Support - Capital CLEANED METAL CUTTINGS FROM WHIPSTOCK WITH MAGNETS, BAILER & BRUSH. ATTEMPTED PULL WHIPSTOCK WITH BAKER HOOK, NO SUCCESS. R/D SLICKLINE. 7/3/07 Drilling Support - Capital MU and RIH with a 2.70" "GS" Hydraulic Release Spear (3") with a 3" GS Bait Sub and a 3" GS Skirted Slick Catch to try and latch Retrievable Whipstock tray.Unable to work passed poor boy overshot @ 8078' MD / 8089' ctmd.POOH to check tool string.While che 7/3/07 Drilling Support - Capital FISHED SLICK CATCH FROM POORBOY OVERSHOT C~ 8081' RKB. IN PROGRESS. 7/4/07 Drilling Support - Capital ATTEMPTED TO FISH WHIPSTOCK W/ DE-CENTRALIZED BAKER RETRIEVING TOOL. UNABLE TO LATCH. RDMO. ° , ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/9/2007 17:00 - 17:15 025 MOB P PRE 17:15 - 18:00 0.75 MOB P PRE 18:00 - 18:15 0.25 MOB P PRE 18:15 - 19:00 0.75 MOB P PRE 19:00 - 00:00 5.00 MOB P PRE 6/10/2007 00:00 - 03:30 3.50 MOB P PRE 03:30 - 06:15 2.75 MOB P PRE 06:15 - 06:30 0.25 MOB P PRE 06:30 - 07:30 1.00 MOB P PRE 07:30 - 09:00 1.50 BOPSU~ P PRE 09:00 - 16:00 7.00 BOPSU P PRE 16:00 - 21:00 I 5.001 BOPSUR P I I PRE Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: 21:00 - 22:00 1.00 BOPSU P PRE 22:00 - 23:30 1.50 RIGU P PRE 23:30 - 00:00 0.50 RIGU P PRE 6/11/2007 00:00 - 00:15 0.25 BOPSU P PRE 00:15 - 00:35 0.33 BOPSU P PRE 00:35 - 01:45 1.17 RIGU P WEXIT 01:45 - 02:25 0.67 BOPSU P PRE 0225-04:15 1.83 WHIP P WEXIT 04:15 - 04:20 0.08 WHIP P WEXIT 04:20 - 05:30 1.17 WHIP P WEXIT 05:30 - 05:45 0.25 WHIP P WEXIT 05:45 - 06:00 0.25 WHIP P WEXIT 06:00 - 06:15 0.25 WHIP P WEXIT 06:15 - 06:30 025 WHIP P WEXIT 06:30 - 07:00 0.50 WHIP P WEXIT 07:00 - 08:00 1.00 WHIP P WEXIT 08:00 - 11:00 3.00 WHIP P WEXIT 11:00 - 12:20 1.33 WHIP P WEXIT Safety meeting prior to moving rig. Move rig off 1 C-03 well. PJSM. Load rig mats from base of rig onto trailers. Begin rig move from 1 C pad to 1 B pad. Continue rig move to 1 B pad Rig is on 1 B pad. Start spotting rig mats around well head. Crew change/safety mtg Fin set mat, build ramp Move rig over tree and set down NU BOPE Spot cuttings box Remove and replace annular element Remove and replace choke line HCR Spot tiger tank. RU hardline Accept rig at 1400 hrs 6/10/07 Test BOPE. The AOGCC waived the right to witness the test Fill pits w/ 290 bbls SW. Install small crash guard around adjacent well - next to beaver slide. Post BOPE schematic. Install fuseable & bleed off SSV pressure to 0 psi. Install hyd line to SSSV on tree & function test SSSV - slight hesitation on closure. Attempt to fluid pack & pressure test tiger tank line. Try various ways to get fiuid to TT. Remove hammer valve & 90 & remove cement from line. Fluid pack & P.T. TT line to 1000 psi. Rig up lubricator & pull BPV - retrieved. LD BPV equipment. Pick up injector & meg line. Trouble shoot e-line cabie. Fill coil w/ SW. Continue filling coil w/ SW. PT inner reel valve per AOGCC regs. Bleed off coil. PU MWD BHA. Trouble shoot e-line. Replace flow sub. PU 5' lubricator. MU mwd to coil connector. Stab onto well. Set counters. Pressure test pack off per AOGCC reg. SD & Bleed off & replace block valve on manifold. Retest. Bleed off. Open master valve. RIH. WHP's = 10/20/0. VP's = 276. Take returns outside. WT ck, 21 k up & 13.1 k down. Tagged TOL ~ 8256ft - twice. Order more water, - 75% losses POH, 1.94in / 2842psi. 0.70 out / 7psi. Bring returns back inside. Close EDC & reciprocate across SSSV while jetting ~ max rate. Continue POH. SI swab. Crew change/safery mtg LD nozzle assy Open swab and fill hole w/ 7 bbls. Blow out debris in choke line MU WS assy to MWD assy Fill hole w/ charge pump at 17 bbls/hr static RIH w/ WS circ thru EDC 1.0/840 and taking returns to pits Log GR tie-in down from 8100' at 300'/hr circ thru EDC 1.0/0.6/820 w/ SW to 8220'. Corr -11' to CPAI 'Basic Log' of Printed: 7/10/2007 12:0626 PM ! ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA , Rig Name: NORDIC 2 6/11/2007 11:00 - 12:20 1.33 WHIP P 12:20 - 12:40 0.33 WHIP P Start: 6/9/2007 Rig Release: 6/12/2007 Rig Number: WEXIT WEXIT 12:40 - 14:30 1.83 WHIP N DFAL WEXIT 14:30 - 16:00 1.50 WHIP N DFAL WEXIT 16:00 - 17:40 1.67 WHIP N DFAL WEXIT 17:40 - 17:55 0.25 WHIP N DFAL WEXIT 17:55 - 20:15 2.33 WHIP N DFAL WEXIT 20:15 - 21:00 0.75 WHIP N DFAL WEXIT 21:00 - 22:35 1.58 WHIP N DFAL WEXIT 22:35 - 23:40 I 1.08I WHIP ~ N I DFAL I WEXIT 23:40 - 00:00 0.33 WHIP N DFAL WEXIT 6/12/2007 00:00 - 01:30 1.50 WHIP N DFAL WEXIT 01:30 - 02:30 1.00 WHIP N DFAL WEXIT 02:30-04:30 I 2.OOIWHIP IN IDFAL IWEXIT 04:30-07:30 3.00 WHIP N DFAL IWEXIT 07:30 - 08:00 0.50 W HIP N DFAL W EXIT 08:00-12:301 4.501WHIP IN IDFAL IWEXIT 12:30-17:30 I 5.OOIWHIP IN IDFAL IWEXIT 17:30-18:30 I 0.501WHIP IN IDFAL IWEXIT Spud Date: 6/9/2007 End: Apr 23, 200? PUH 2O.5k to 8000'. Log CCL to 8200', no corr RIH to 8248.2' and park w/ TF at 350 deg and TOWS at 8227'. SD pump, close EDC. Pressure up to 1165 psi to set WS and tool stroked at calc pressure. Stack 2k wt at surface and see 0.3k wob when WS started moving downhole. Chase down hole 10' to 8258.5' which is the TOL2 and stack 2.3k Open EDC. POOH circ 1.0/880 Inspect setting tools and confirm that WS and KB packer were left in the hole. Will probably be a two run fishing job. Bring fishing tools to floor MU BTT wall hook w/ guide and scribe to BHI MWD Fiil hole and taking <5 bph static-WS is good LCM RIH w/ BHA #3 circ 1.0/1560 thru ported tooi to recover the WS tray 8200' Corr -11'. PUH 2O.3k RIH circ 1.0/0.67/980 and tag at 8239.0'. Set 3k down. PUH 2O.3k. Repeat. Got an extra 1.Ok ~ POH OOH w/ no fish. PU GS overshot. Set counters & test tool. RIH. Sat down @ 8078ft (Poorboy overshot), pickup 20k up. Try to orientate past it, set down f~ 8084ft. Pick up & lightly set down & orientate with 500# WOB. Got through, continue RIH. WT ck 21.5k up. Set down at 8249ft, set 4k down. Stop pumping. Picked up with 3k over pull, slipped off or pulled whipstock out of collet. Set 4.5k down, start pumping & set more weight down. Pick up - no overpull. Set down & try to orintate on top of fish to get a bite. Set down & jar a couple of times. No more overpulls, no more indication of fish is on. Open EDC & POOH. Puiled heavy ~ 8138ft (packer) - 8k over & stop, jars went off. RIH - goes down fine. Continue POH. Slight overpull ~ 'X' nipple - 8033ft. PJSM while POH. Stop ~ 140ft & close EDC. Pop off & visualize coil while slowly POH. OOH with whipstock. MU hyd GS to MWD BHA. Replace o-rings on flow sub. Stab back onto well. Set counters. Well not takinf any fluid - good indication that packer is set. RIH w/ Hyd GS. WT ck ~ 8000ft, 20k up & 13k down. Stop pumping, set down ~ 8256ft & set down 3k. Pull 10k over & let jars go off, repeat 4 times - KB packer fish is free. POH & fill across the top. Slight bobble at the X nipple. LD fishing assy w/ KB packer, complete Load out WS and KB w/ BTT rep who will take to Deadhorse to remove OS and try to determine the failure mechanism. Then will MU and return to location Cut off CTC. Pumped slack back. Cut off 180' total of CT due to 80' of wet wire. Install CTC. PT ~ 35k. Rehead BHI. PT ~ 4000 and leaked Cut off CTC and install new one. PT 35k, Rehead BHI. PT ~ 4000. Pump slack forward and test both mud pumps for rate BTT call at 1445 hrs and said WS just left the shop PU KB WS Packer and Whipstock & set in hole. PU MWD BHA&MUtoWS Printed: 7/70/2007 12:0626 PM ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: 6/12/2007 18:30 - 2020 1.83 WHIP N DFAL WEXIT 20:20 - 21:10 0.83 WHIP N DFAL WEXIT 21:10 - 23:00 1.83 WHIP P 23:00 - 00:00 1.00 WHIP P 6/13/2007 00:00 - 01:45 1.75 WHIP P 01:45 - 02:00 025 WHIP P 02:00 • 02:15 025 WHIP P 02:15 - 04:00 1.75 STMILL P 04:00 - 04:30 0.50 STMILL P 04:30 - 05:40 1.17 STMILL P 05:40 - 10:50 I 5.171 STMILL I P 10:50 - 11:35 I 0.751 STMILL I P 11:35 - 12:15 12:15 - 14:00 14:00 - 16:30 16:30 - 18:30 18:30 - 18:45 18:45 - 19:00 0.67 STMILL P 1.75 STMILL P 2.50 DRILL P 2.00 DRILL P 0.25 DRILL P 0.25 DRILL P 19:00 - 2225 2225 - 00:00 6/14/2007 00:00 - 00:30 3.42 ~ DRILL I P 1.58 DRILL P 0.50 DRILL P W EXIT WEXIT WEXIT W EXIT WEXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Open EDC & RIH with WS Packer BHA Wt ck ~ 8160ft, 19.5k up & 12k down. Log for tie in (-10.5ft corr). Orintate to 10 degrees left of high side & zero the WOB sensor. RIH to 8248.7ft (Top of WS is at 8227ft). Stop pumping & close EDC. Start pumping ~ 0.5 bpm, sheared at 1240psi. Set 4k weight down. Whipstock has been set with the top of whipstock ~ 8227ft. r' POH & fill across the top. PJSM while POH Check for flow. LD MDW BHA & BOT setting tool. Reconfigure MWD tools. PU 2-1/8" 607 Extreme motor w/ 2.74" DSM & 2.74" string reamer. PU & MU MW D tools. Stab onto well, set counters & check tools. Close EDC & pump min rate while RIH. RIH w/ window & string mill. No losses. Log for tie-in (-10ft corr). Stop pumping, RIH & dry tag top of whipstock @ 8227ft. Pick up (20k up) 10ft & start pumping. VP's = 180bb1s 1.3bpm in /1.27bpm out, 1900psi fs. Slowly RIH & begin milling window ~ 8227.00 at .01 ff/hr with 200-300psi motor work & 1000-20001bs WOB. Pump 5bbl hi-vis biozan piil. Lost weight & pressure, went from 2200psi & 2500# W OB to 1900 psi & 1400# WOB. Drill another 0.1ft and pressures & weight came back to previous amounts. Pump 5bbl hi-vis biozan pill. Milling window as per BOT BP RP's Stali at 8,233.40 ft Swapped to mud at 8,230.90 ft Milling window Qp = 1.30 bpm at 2450 psi off bottom Drilling open hole section / rat hole ,~ Qp = 1.47 = 1.48 bpm CTP 3,300 / 3,560 psi ROP = 10-23 fph Reaming window and open hole section Dry tagged at 8,244 ft POOH with open EDC. Held PJSM and discussed hazards while POOH Changed out BHA, DSM at 2.74" go and 2.73" NoGo. PU 2.8 bend motor with BC bit. RIH w/ 2.8 bend motor with BC bit. Set down at overshot ~ 8068ft. PU & slightly sit 1000 # WOB and orientate 90 left - passed through. Log for tie-in (-8.5ft corr). Make correction & RIH. Run through window w/ out pumping, slight bobble at 8238ft. Begin adding MI products to mud to increase weight & lubricity. Drilling build section as per CTD Program. TF at HS to 5-10L Qp = 1.33 bpm at 3200 psi Density = 9.18 / 9.09 ppg BHP = 3662 psi = 11.47 ppg ROP = 20-40 fph Temp = 70/76 VP's = 314 bbls Discard biozan pill from pits & take on remainder of used Fio Pro drilling mud. VP's = 444 bb~s. Continue drilling build section as per CTD Program. TF at HS Printed: 7/10/2007 12:06:26 PM ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/14/2007 I00:00 - 00:30 I 0.50I DRILL l P 00:30 - 02:20 1.83 DRILL P 02:20 - 02:50 0.50 DRILL P 02:50 - 03:30 I 0.671 DRILL I P 03:30 - 06:25 I 2.921 DRILL I P 06:25 - 08:30 2.08 DRILL P 08:30 - 09:00 0.50 DRILL P 09:00 - 10:30 1.50 DRILL P 10:30 - 13:40 3.17 DRILL P 13:40 - 15:20 1.67 DRILL P 15:20 - 15:50 0.50 DRILL P 15:50 - 19:12 3.37 DRILL P 19:12 - 19:35 0.38 DRILL P 19:35 - 00:00 4.42 DRILL P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PROD1 to 45-60L Qp = 1.54 bpm at 3900 psi Density = 9.17 / 9.06 ppg BHP = 3809 psi = 11.81 ppg ROP = 10-15 fph Temp = 75/79 VP's = 446 bbis PROD1 Begin adding MI products to mud to increase weight & lubricity. PROD1 Wiper to window. Stop pumping & pull through window. Resume pumping & POH to 8110ft holding WHP to maintain constant BHP. PROD1 Log for tie-in from 8110ft (zero corr), RIH & log from 8220ft to 8255 ft. RA PIP tags in whipstock is @ 8131ft. Resume wiper to bottom. PROD1 Continue drilling build section as per CTD Program. TF at HS to 45-60L Qp = 1.50 bpm at 3900 psi Density = 927 / 9.19 pP9 BHP = 3813 psi = 11.79 ppg ROP = 10-15 fph Temp = 76/80 VP's = 450 bbls Last 3 survey's averaged > 55 deg/100 ft Projection at the 8380 ft= 84 dge a68 deg Azm and ND at 6232 ft. PROD1 POOH as per MPD schedule PROD1 Tagged up, held PJSM on plan forward on pressure undeploying BHA with 740 psi on wellhead. PRODi Pressure Undeploy BHA as per procedure SIWHP = 711 psi and after undeploying BHA SIWHP = 180 psi PROD1 Work on Swaco Choke and changing motor AKO setting. PU 1.3 deg BHA. Perform Table Top drills. PROD1 RIH and tagged the to poorboy stub at 8074 ft PU and oriented TF around PROD1 Tie-in at 8,130 ft Corrected - 8 ft Closed EDC and orient TF to HS PROD1 Tagged bottom at 8,380 ft. Drilling lateral section as per CTD Programme TF at 15L till achieve a hole angle of 90 deg then will roll over to 90 deg L Qp = 1.50 / 1.48 bpm CTP 3650 psi off bottom Vp = 442 bbl BHP 3823 psi ECD 11.81 ppg; WHP = 10 psi (full open) WOB 1.5k and ROP 30-50 fph PROD1 Wiper to window. Turn centrifuge on. VP's = 443 bbis. Perform Table Top drills. PROD1 Tagged bottom at 8,500 ft. Drilling lateral section as per CTD Programme TF at 15L till achieve a hole angle of 90 deg then will roll over to 90 deg L Qp = 1.53 / 1.51 bpm CTP 3623 psi off bottom Vp = 448 bbl Printed: 7/10/2007 12:06:26 PM ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Spud Date: 6/9/2007 Event Name: REENTER+COMPLETE Start: 6/9/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 6/12/2007 Rig Name: NORDIC 2 Rig Number: 6/t4/2007 19:35 - 00:00 4.42 DRILL P PROD1 BHP 3854 psi ECD 11.89 ppg; WHP = 10 psi (full open) WOB 1.9k and ROP 30-50 fph 6/15/2007 00:00 - 02:45 2.75 DRILL P PRODi Continue drilling from 8,593 ft. Drilling lateral section as per CTD Programme TF at 15L till achieve a hole angle of 90 deg then will roll over to 90 deg L Qp = 1.53 / 1.51 bpm CTP 3623 psi off bottom Vp = 448 bbl BHP 3854 psi ECD 11.80 ppg; WHP = 7 psi (fuli open) WOB 3k and ROP 10-25 fph 02:45 - 03:30 0.75 DRILL P PROD1 Wiper to window - clean. Wiper to bottom. One set down ~ 8496ft, ream clean. 03:30 - 07:15 3.75 DRILL P PROD1 Continue drilling from 8,651 ft. Drilling lateral section as per CTD Programme TF at 60L Qp = 1.52 / 1.49 bpm CTP 3663 psi off bottom Vp = 430 bbl BHP 3856 psi ECD 11.91 ppg; WHP = 4 psi (full open) WOB 3k and ROP 10-25 fph 07:15 - 08:30 125 DRILL P PRODi Drilling towards Fault #1 in the Kuparuk B Siltstone TF at 70-60 L Qp = 1.53 / 1.52 bpm CTP(ob) = 3760 psi Density = 9.27 / 9.20 ppg BHP = 3840 psi w/ EDC of 11.87 ppg at 6231 ft TVD WOB = 2.89k ROP = 18 fph Vp 425 bbl. Starting mud swap at 08:00 hrs 08:30 - 10:20 1.83 DRILL P PROD1 Drilling towards Fault #1 in the Kuparuk B Siltstone TF at 60 L Qp = 1.55 / 1.53 bpm CTP(ob) = 3760 psi Density = 9.27 / 9.20 ppg BHP = 3840 psi w/ EDC of 11.87 ppg at 6231 ft ND WOB = 2.89k ROP = 18 fph ' New Mud at bit at 08:30 hrs ', 10:20 - 11:35 1.25 DRILL P PROD1 Drilling towards Fault #1 in the Kuparuk B Siltstone TF at 60 L ' Qp = 1.55 / 1.53 bpm CTP(ob) = 3560 psi Density = 9.27 / 9.20 ppg BHP = 3840 psi w/ EDC of 11.87 ppg at 6231 ft TVD WOB = 2.89k ROP = 10-18 fph 11:35 - 13:00 1.42 DRILL P PROD1 Wiper trip to base of whipstock using pressure schedule Turn'A' centrifuge on Little Motor work and puil at 8,470 ft clean trip up RIH at driiled TF and tagged at 8,505 ft with motor work. PUH 100 ft RIH and seen small bobble at 8505 ft, RIH Seen some motor work at 8610 ft, 8650 ft Set down at 8656 ft. Worked through, RIH and set down again at 8710 ft, PUH and reduced the Qp to 1.00 bpm and adjusted the welihead to maintain the 11.7ppg BHP. RIH to 8,722 ft tagged again, PUH, RIH set down at 8,760 ft. RIH to 8,800 ft and tagged bottom. Zeroed W OB. ', 13:00 - 17:45 4.75 DRILL P PROD1 Drilling towards Fault #1 in the Kuparuk B Siltstone TF at 60 L Projected TD for the EOC at 8,950 ft MD Qp = 1.51 / 1.5 bpm CTP(ob) = 3,580 psi Density = 9.27 / 924 ppg Printed: 7/70/2007 12:0626 PM ~ ~~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/15/2007 I 13:00 - 17:45 I 4.751 DRILL I P 17:45 - 18:10 0.42 DRILL P 18:10 - 20:00 1.83 DRILL P 20:00 - 20:35 I 0.581 DRILL I P 20:35 - 20:45 0.17 DRILL P 20:45 - 21:44 0.98 DRILL P 21:44 - 23:00 I 1271 DRILL I P 23:00 - 00:00 I 1.001 DRILL I P I6/16/2007 ~ 00:00 - 01:30 I 1.50 ~ DRIU. I P 01:30 - 04:00 I 2.50 ~ DRILL ~ P 04:00 - 05:30 I 1.501 DRILL I P 05:30 - 07:10 1.67 DRILL P 07:10 - 08:00 0.83 DRILL P 08:00 - 09:30 1.50 DRILL P 09:30 - 13:00 I 3.501 DRILL I P 13:00 - 14:45 1.75 DRILL P 14:45 - 15:10 0.42 DRILL P 15:10 - 17:10 I 2.001 DRILL I P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PROD1 BHP = 3833 psi w/ EDC of 11.84 ppg at 6,231 ft ND WOB = 2.89k. ROP changed at 8,860 ft from 20 to 39 fph. GR showed the C4/C3 sand at 8,860 ft PROD1 Drilled to 8901 ft. PUH to flop TF around PROD1 Resume drilling towards Fault #1 in the Kuparuk B Siltstone TF at60L Qp = 1.50 / 1.49 bpm CTP(ob) = 3,580 psi Density = 9.27 / 9.27 ppg BHP = 3800 psi w/ EDC of 11.74 ppg at 6,231 ft ND WOB = 1.65k. PROD1 Wiper to window using pressure schedule - clean, no overpulls. PROD1 Log RA PIP tag located in whipstock for tie-in. (+1ft corr). PROD1 Wiper to bottom using pressure schedule. Reduce pump rate to 0.75bpm while RIH. Reduce running speed (15-20fUmin) to maintain proper tool face. Slight bobble at 8735ft. Set down at 8761ft - (orientation). PROD1 Tag bottom at 8950tf & resume drilling with TF at 60 L Qp = 1.55 / 1.54 bpm CTP(ob) = 3,580 psi, 3,700 psi FS Density = 9.27 / 9.24 ppg BHP = 3858 psi w/ EDC of 11.91 ppg at 6,231 ft ND WOB = 1.5-2.5k VP's = 400bb1s. ROP = 15-20Whr PROD1 EOC/EOB is complete. POOH for rib steer BHA using pressure schedule. Oped EDC at 8180ft. PROD1 PJSM prior to pressure undploying while POH with coil. Jet TRSSSV w/ EDC on way out of hole. PROD1 Close BOPE rams, bleed off & unstab injector from BHA - set injector on rig floor. Begin pressure undeploying BHA. Pressure test coil connector to 3500 psi. Replace back dies on little jerk tongs. PROD1 PU rib steer BHA - set upper section of BHA in mouse hole & attach it to the slickline. MU lower section of BHA. Pressure deploy BHA in hole. Set counters & power up & test tooi. PRODi RIH with lateral BHA, following pressure schedule. PROD1 Logged tie-in starting at 8130 ft to 8162 ft(-11 ft) Closed EDC and RIH with BHI Rib Steer BHA. Tagged the bottom of the window at 8,238 ft Tried several times without much success. PROD1 POOH , Held PJSM on trip out of hole. Trapped 690 psi on well PROD1 Pressure undeploy BHA with 700 psi as per procedure Repaired Swaco choke and tested OK Pressure deploy window dressing BHA with 200 psi PROD1 RIH as per MPD schedule PROD1 Tie-in at 8,100 ft. Corrected -10 ft. Closed EDC and increased Qp to 0.3 bpm. PROD1 RIH and feel my way through the window area RIH and tagged at 8232 ft. PUH and inc Qp to 1.4 bpm Dressing window starting at 8,229.6 ft to 8,240 ft and then backed ream back up to 8,230 ft Printed: 7/10/2007 12:0626 PM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I 6/16/2007 ~ 15:10 - 17:10 17:10 - 19:05 19:05 - 2020 1 B-15 1 B-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 2.00 DRILL P 1.92 DRILL P 1.25 DRILL P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PROD1 PROD1 PROD1 20:20 - 22:00 1.67 DRILL P PROD1 22:00 - 23:30 1.50 DRILL P PROD1 23:30 - 23:50 0.33 DRILL P PROD1 23:50 - 00:00 0.17 DRILL P PROD1 6/17/2007 100:00 - 01:45 I 1.751 DRILL I P I I PROD1 01:45 - 03:50 2.08 DRILL P PRODi 03:50 - 04:30 0.67 DRILL P PROD1 04:30 - 09:15 4.75 DRILL P PROD1 09:15 - 10:35 1.33 DRILL P PROD1 10:35 - 10:55 0.33 DRILL P PROD1 10:55 - 12:30 I 1.58I DRILL I P I I PROD1 12:30 - 13:20 I 0.831 DRILL I P I I PROD1 13:20 - 13:25 I 0.081 DRILL I P I I PROD1 13:25 - 14:15 0.83 DRILL P PROD1 14:15 - 19:06 4.85 DRILL P PROD1 19:06 - 20:11 I 1.08I DRILL ~ P I I PROD1 Q= 1.32 bpm at 2,889 psi ROP = 0.2 fpm SD pump and RIH past widow to 8241 ft, clean window area POOH with open EDC and maintaining BHP as per schedule. PJSM for pressure undeployment while POH. Begin pressure undeploying BHA with 700 psi as per procedure. Begin pressure deploying rib steer BHA as per procedure. RIH with lateral BHA, following pressure schedule. Log for tie-in (Oft corr) RIH. Set down ~ 8236ft. PU & RIH no probiems, log RA PIP tag (Oft corr). Set down ~ 8291 ft& 8298ft & 8335ft - twice, work past. Continue RIH with rib steer BHA. Set down ~ 8448ft, 8520ft, 8488ft, 8671 ft, 8703ft, 8712ft. Can't get past 8700ft. Try different running speeds & pump rates & w/ or w/out rib steer at 8700ft to 8712ft - no ga POH following pressure schedule w/ rib steer BHA. Begin pressure undeploying BHA per procedure. PU BHA & begin pressure deploying per procedure. RIH with EDC open Logged tie-in and corrected -11 ft. Closed EDC RIH with drilled TF and Qp = 0.50 bpm Stopped at 8250 ft and work CT and trouble shoot the CT roll to the left. Had to work through the 8712 ft using low pump rates. This area could be faulted . RIH Took some wt at 8,740 ft At 8,780 ft taking wt with motor work. Working through using Qp and running speed. Tagged at 8,987 ft MD PUH to 8,800 ft to check hole conditions prior to MAD pass. RIH and tagged TD at 8,987 ft PUH and setup to MAD pass from 8,987ft to 8,800ft. Unable to change data rates for MAD pass Drilling Lateral as per Geologist Qp = 1.48 / 1.48 bpm at 3,250 psi off bottom Density = 9.29 / 9.23 ppg BHP = 3,854 psi ECD at 11.91 ppg; WHP 20 psi Vp = 422 bbl Having some trouble with downhole communication with Coiltrac. MAD Pass up from 8,991 ft to 8,800 ft Drilling Lateral as per Geologist Qp = 1.48 / 1.48 bpm at 3,250 psi off bottom Density = 9.29 / 923 ppg BHP = 3,854 psi ECD at 11.91 ppg; WHP 20 psi Vp = 421 bbl ROP = 5-50 fph w/ 1-2 k DHWOB Sederite at 9050 ft MD 6224 ft ND Pulled at little tight at 9,062 ft sederite. Continue drilling lateral as per Geologist Begin MPD per procedure Qp = 1.49 / 1.48 bpm at 3,250 psi off bottom Density = 9.29 ! 9.24 Ppg Printed: 7/10/2007 12:06:26 PM ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/17/2007 I 19:06 - 20:11 I 1.08I DRILL ~ P 20:11 - 20:50 I 0.65I DRILL I P 20:50 - 21:35 ~ 0.75I DRILL I P 21:35 - 00:00 I 2.421 DRILL I P 6/18/2007 100:00 - 02:15 I 2251 DRILL I P 02:15 - 02:35 0.33 DRILL P 02:35 - 04:30 1.92 DRILL P 04:30 - 07:15 I 2.75I DRILL I P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 07:15 - 08:30 1.25 DRILL N DPRB PROD1 08:30 - 11:30 3.00 DRILL N DPRB PROD7 11:30 - 13:45 I 2.25I DRILL I N I DPRB I PROD1 13:45 - 14:00 0.25 DRILL N DPRB PROD1 14:00 - 15:20 1.33 DRILL N DPRB PROD1 1520 - 15:30 I 0.17I DRILL I N ~ DPRB I PROD1 15:30 - 16:10 I 0.67I STKOH I N I DPRB I PROD1 16:10 - 16:40 I 0.501 STKOH I N I DPRB I PROD1 BHP = 3,854 psi ECD at 11.88 ppg; WHP 100 psi Vp = 439 bbl ROP = 15-70 fph w/ 1-2 k DHWOB Centrifuge 'A' is on line. W iper to window - ciean 17k up wt. Minor overpulls (1 k) from 9150ft to 9100ft. Seeing 200psi motor work @ 8700ft. Wiper to bottom. Set down ~ 8700ft, PU & reduce pump rate to 0.75 bpm - passed through. Set down ~ 9100ft (tool face). Continue drilling lateral as per Geologist Begin MPD per procedure Qp = 1.57 / 1.56 bpm at 3,550 psi off bottom Density = 9.30 / 9.28 ppg BHP = 3,954 psi ECD at 12.23 ppg; WHP 100 psi Vp = 436 bbl ROP = 15-70 fph w/ 1-2 k DHWOB Continue drilling lateral from 9186ft as per Geologist Begin MPD per procedure Qp = 1.52 / 1.50 bpm at 3,250 psi off bottom Density = 9.30 / 9.23 ppg BHP = 3,820 psi ECD at 12.03 ppg; WHP 110 psi Vp = 437 bbl ROP = 5-12 fph w/ 2-3 k DHWOB BHA wiper. Continue drilling lateral from 9204ft as per Geologist Begin MPD per procedure Qp = 1.74 / 1.74 bpm at 3,890 psi off bottom Density = 9.31 / 923 ppg BHP = 3,935 psi ECD at 12.22 ppg; WHP 110 psi Vp = 436 bbl ROP = 15-20 fph w/ 2-3 k DHWOB Clear evidence that we are in the 'D' shale. POH for side track BHA. Pressure undeploy BHA Function test BOP as per AOGCC. Setup BHA for Sidetrack PJSM on Pressure Deploying BHA. PU HCC used R-60 bit with door knob. Set motor to 1.8 deg bend. RIH with ST BHA , open EDC at 200 ft and RIH. Head bolt broke of the retainer piate in the reel house, replaced Log tie in down at 8,120 ft. Corrected -11 ft RIH Tagged hard at 9,191 ft(shale). PUW 22k. Washed and reamed tobottom cleaning out shale. RIH and tagged bottom hard to shed the door knob PUH to conduct open hole sidetrack starting at 9,065 ft Qp = 3500 psi at 1.47 bpm off bottom Open hole sidetrack Qp = 1.47 / 1.48 bpm 3500 psi off bottom pressure Trough from 9065 ft to 9095 ft 1 st pass at 60 fph W OB 0.64k CTP = 3530 psi NBI at 92.78 deg Increased reaming speed due to WOB, CTP and DHWOB DHWOB increased to 3k, We are ST within 7-10 ft PUH to 9,045 ft to start sidetrack higher Open Hole sidetrack starting at 9045 ft Printed: 7/102007 72:0626 PM . ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/18/2007 ~ 16:10 - 16:40 I 0.50 I STKOH I N 16:40 - 18:27 I 1.78 I STKOH I N 18:27 - 23:59 I 5.53 I STKOH I N 23:59 - 00:00 I 0.021 STKOH I N 6/19/2007 100:00 - 02:15 I 2.251 STKOH I N 02:15 - 04:00 1.75 STKOH N 04:00 - 04:30 0.50 DRILL N 04:30 - 04:40 0.17 DRILL N 04:40 - 07:00 2.33 DRILL N 07:00 - 08:50 1.83 DRILL N 08:50 - 09:05 025 DRILL N 09:05 - 10:50 1.75 DRILL N 10:50 - 13:30 2.67 DRILL N 13:30 - 16:00 I 2.501 DRILL I N 16:00 - 17:50 1.83 DRILL N 17:50 - 20:45 2.92 DRILL P 20:45 - 00:00 I 3.251 DRILL I P 16/20/2007 100:00 - 02:45 I 2.751 DRILL I P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: DPRB ~ PRODi ~ Qp = 1.47 / 1.47 bpm at 3,300 psi 1 pass down at 60 fph WOB 0.7k to 9075 ft Started taking wt at 9073 ft 3.2 k DPRB PRODi Back ream from 9075 ft to 9045 ft at 50 ft/hr Qp = 1.47 / 1.47 bpm at 3,300 psi 2nd pass down at 60 fph WOB at 9075 = 1.8 k Backed reamed to 9,045 ft. DPRB PROD1 Begin time drilling ~d 9074ft. Begin MPD. Qp = 1.47 / 1.46 bpm at 3,200 psi Density = 9.28 / 9.21 ppg BHP = 3,820 psi ECD at 12.06 ppg; WHP 143 psi Vp = 430 bbl ROP = lfph w/ 200# DHWOB DPRB PROD1 Side track starts ~ 9074ft - need TF of 160R to enter the side track. POH for drilling BHA following pressure schedule. DPRB PROD1 POH for lateral driiling BHA, following pressure schedule. PJSM for pressure undepioyment while POH. DPRB PROD1 Begin pressure undeployment of side track BHA. DPRB PROD1 Reconfigure BHA & test toois. PU new motor & set in hole. DPRB PROD1 PJSM prior to pressure deploying BHA. DPRB PROD1 Begin pressure undeploy & deploying sidetrack to laterai BHA. DPRB PROD1 RIH with lateral / sidetrack BHA with res tool DPRB PROD1 Log tie-in at 8130 ft-10 ft corrrection DPRB PROD1 RIG and tagged TD at 9087 using 160 to 90 R toolface DPRB PROD1 Drilling sidetrack. TF at 90 to 60 R Qp = 1.51 / 1.55 bpm CTP 3350 psi off bottom BHP = 3814 psi w/ ECD at 11.7pppg DHWOB = 0.5 22 klb ROP = 5-40 fph Vp = 413 bbl's Parted CT and Well Control Issue Table Talk in Ops Cab with Crew DPRB PROD1 Drilling sidetrack. TF at 90 R Qp = 1.51 / 1.55 bpm CTP 3350 psi off bottom BHP = 3825 psi w/ ECD at 11.Spppg DHWOB = 0.5 2.2 klb ROP = 5-40 fph Vp = 422 bbl's Having trouble getting WOB at 9195 ft PUW 26k (8k up) DPRB PROD1 PUH for wiper to base of whipstock Had some motor work while PUH at 8,750 ft and 8,690 ft PROD1 Back on bottom working to get bit to drill. Took a while in the sederite Drilling sidetrack at a TF of 80 R Qp = 1.48 / 1.48 bpm CTP 3400 psi off bottom BHP = 3864 psi w/ ECD at 11.8pppg DHWOB = 0.5 2.2 klb ROP = 5-40 fph Vp = 421 bbl's PROD1 W iper trip back to window. Monitor TF through sidetrack area. Also reduce pump rate while RIH. Can not get past 8761'. Try all TF, pump, and running speed combinations. No progress. "Drill ahead" at the original tool face. Hoie cleaned up at +/-8785'. Continue wiper trip to bottom. PROD1 Drill ahead from 9350'. 3200 psi fs at 1.49 in/out. DPSI: 150-350. DHWOB: 2.0-3.Ok#. WHP/BHP/ECD: 29/3878/11.97 Printed: 7/10/2007 12:0626 PM ~ ~ Legal Weil Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 B-15 1 B-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: 6/20/2007 00:00 - 02:45 2.75 DRILL P PROD1 02:45 - 03:45 1.00 DRILL P PROD1 03:45 - 04:00 0.25 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PRODi 05:00 - 06:40 1.67 DRILL P PROD1 06:40 - 09:30 2.83 DRILL P PRODi 09:30 - 13:10 I 3.671 DRILL I P I I PROD1 13:10 - 15:00 I 1.831 DRILL I P I I PROD1 15:00 - 16:20 I 1.331 DRILL I P I I PROD1 16:20 - 20:00 I 3.671 DRILL I P I I PRODi 20:00 - 00:00 I 4.001 DRILL I P I I PROD1 6/21/2007 100:00 - 03:00 I 3.001 DRILL I P I I PROD1 ppg. IA/OA/PVT: 55/322/409 bbls. ROP: variable. Wiper trip to window. Hole mostly smooth. Log gr tie in. Add 2.5' correction. W iper trip back in hole. No problem at side track area of 9075'. Hole much smoother than previous trip at 8760-8790 interval. Drill ahead from 9500'. Drilling lateral Building up to 90 deh and a ND of 6258 ft. Qp = 1.50 / 1.51 bpm at 3543 psi on bottom (496 psi delta P) DHWOB = 1.5-0.5k Ib BHP = 3931psi ECD at 12.10 ppg WHP 20 psi Mud has 1,000 ft drilled onit and the solids at 0.8 % and MBT = 0.7#/bbl Time for a new batch of mud. 90 ft wiper trip at 9600 ft due to stacking. Leveled at 9,595 ft( 6,260 ft ND) Having trouble keeping TVD due to sederite bedding. Wiper trip after driliing 150 ft. Some motor work above 8,750 ft to 8610 ft Ciean trip up Reduced Qp to 0.56 and held 200 psi BHP = 3773psi At 8,718 ft small amout motor work and bump. Started mud swap while RIH at 9050 ft and orient TF to 160 R Tagged bottom at 9650 ft MD Driliing Lateral TF at 19 R to 90 R Trying to hole 90 deg Qp = 1.48 /148 bpm at 3400 psi free spin DHWOB 0.50 to 1.50 k Ib BHP = 3917 psi at 12.00 ppg ECD Density = 9.28 /924 ppg ROP = 40-120 fph Vp = finished at 14:00 hrs C2 Sand, dark gray, quartzose, very fine to medium grained, sub-angular to sub-rounded, clear to translucent, moderate sort, trace glauconite, 10% cemented with clays and silts, 90% unconsolidated, fair to poor porosity, no oil stain or fluorescence 40% Siltstone, light tan to light brown, blocky, firm to hard, with very fine grained sand, argillaceous. 10% Shale, dark brown, platy, firm, brittle. Drilling Lateral TF at 19 R to 90 R Turned TF to 60L at 9340 ft Trying to hole 91 deg Qp = 1.48 /148 bpm at 3400 psi free spin DHWOB 0.50 to 1.75 k Ib BHP = 3958 psi at 12.2 ppg ECD Density = 9.28 /9.24 ppg ROP = 20-120 fph Vp = 447 EDC rising from 12.1 to 12.6 ppg Seeing resisitivity separation and possible crossed fault at 9704 ft. W iper trip to base of whipstock Keeping TF at drilled orientation while POOH Clean trip out of hole. RIH at reduced circ rate (0.7 bpm) to maintain 3800 psi BHP. Had to work through a few set downs. Hole mostly very smooth. Drill ahead from 9800'. 3700 psi fs at 1.45 iN1.41 out. DPSI: 150-300. DHWOB:1.5-2.5k#. WHP/BHP/ECD:22/3980/12.24 ppg. IA/OA PVT: 46/99/438 bbls. INC/AZM/TF: 90.4/52.5/270L. Continue to drill lateral at 9917'. 3590 psi fs at 1.45 in/1.40 out. Weight transfer still good. Appears to be hard rock. ROP ranging from 10 to 50 fph. Printed: 7/10/2007 12:06:26 PM . ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/21 /2007 6/22/2007 03:00 - 04:30 1.50 DRILL P 04:30 - 04:45 0.25 DRILL P 04:45 - 06:35 1.83 DRILL P 06:35 - 08:00 I 1.421 DRILL I P 08:00 - 08:15 I 0.251 DRILL I P 08:15 - 09:10 I 0.921 DRILL I P 09:10 - 13:45 4.58 DRILL P 13:45 - 17:00 3.25 DRILL P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 17:00 - 20:00 3.00 DRILL P PROD1 20:00 - 23:00 3.00 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 00:00 - 00:45 0.75 BOPSU N PRODi 00:45 - 04:30 3.75 BOPSU P PRODi 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 06:45 0.75 DRILL P PROD1 06:45 - 11:00 4.25 DRILL P PROD1 W iper trip back to window. Some overpulls near bottom. Hole mostiy smooth. Log GR tie in. Manage BHP. Add 2 ft correction. Run back in hole at reduced pump rate. Maintain +/-3800 psi BHP. Had a little problem getting back to bottom from 9,800 ft to 9,950 ft. Drilling Laterai TF at 60R Qp = 1.51 /151 bpm at 3750 psi free spin DHWOB 0.50 to 1.50 k Ib BHP = 3994 psi at 12.28 ppg ECD Density = 9.28 /924 ppg ROP = 40-100 fph Vp = 391 Lost 63 bbl since mud swap and 5 bbl since crew change PU pulling tight increase the BHA to 4050 psi to see if that cures the PU weight W/ R back to bottom. Drilling Lateral TF at 135 R Hold between 88 and 89 deg hole angle Qp = 1.51 /1.48 bpm at 3750 psi free spin Reduced Qp to 1.45 / 1.43 bpm ECD DHWOB 0.50 to 1.50 k Ib BHP = 3994 psi at 12.28 ppg ECD Density = 9.28 /9.15 ppg ROP = 40-100 fph Vp = 385 W iper trip to base of whipstock RIH set down little at 9852 ft Drilling Lateral TF at 60 R. Hold between 88 and 89 deg hole angle Qp = 1.47 /1.47 bpm at 3650 psi free spin DHWOB 0.50 to 1.50 k Ib BHP = 4012 psi at 12.34 ppg ECD Density = 9.28 /9.15 ppg ROP = 40-100 fph Vp = 372 bbl Having trouble with weight transfer. Discuss with town. Decide to pick up an agitator. Wiper trip up to window. Circulate out of hole following BHP schedule. Hold PJSM in Ops cab. Pressure undeploy BHA. ISWHP: 590 psi. WHP quickly bled down to 180 psi. Hold PJSM. Pressure test BOPs. Continue to test BOP equipment. Replace whitey valve on test pump. Get good body test. Continue to test BOP equipment. Witness waived by B. Noble with AOGCC. Hold PJSM to discuss pumping coil slack. Rig up to reverse circulate. Held PJSM and determined way forward with crew Rig Seroice Electrican found the battery charger for the SCR controller had a bad fuse holder. The charger supplies all of the 24v to all of the controllers on the rig. Cut off 71 ft and 5 ft of wire. Installed CTC and pulled tested to 35k. Megged line +2000 mohms and Printed: 7/10/2007 72:06:26 PM i ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/22/2007 106:45 - 11:00 I 4.251 DRILL I P 11:00 - 12:00 1.00 DRILL P 12:00 - 13:45 1.75 DRILL P 13:45 - 14:03 0.30 DRILL P 14:03 - 17:15 3.20 DRILL P 17:15 - 21:30 I 4.251 DRILL I P 21:30 - 00:00 2.50 DRILL P 6/23/2007 00:00 - 01:15 1.25 DRILL P 01:15 - 03:30 I 2.251 DRILL I P 03:30 - 05:15 I 1.75I DRILL I N 05:15 - 07:45 I 2.501 DRILL I P PROD1 42 ohm resistivity. Reheading upper quick connect (UQC). Check WHP at 150 psi. Increased WHP to 550 psi at 09:22 hrs and shut in MV &SV Megged line following installation of UQC. Passed. PT Upper BHA to 3500 psi (OK) MU CoilTrac BHA with agitator and MPR tool Pressure deploy BHA, WHP 225 psi RIH to to 270 ft and tested the agitator and tested OK. Open EDC and RIH as per pressure schedule The density is 9.23 / 9.09 ppg and the Qp = 0.32 / 0.63 lossing some fluid to formation. . Its crew change at Kuparuk and now there is something going on with the wellbore parameters. Isolated pit 3& 4 and start to start to bring the density up from 9.0 to 9.2 ppg. Tied in at 8130 ft-11 correction Closed EDC and orient TF to HS. RIH. At 8,250 ft, Qp = 0.5 bpm CTP 1978 psi RIH with TF as driiled. Mixing salt. Set TF at 160R at 9,045 ft and preceded through open hole sidetrack area. Worked on MP 1 and MP2 RIH the micro motion is at 8.7 to 9.0 ppg The BHL of our well is in the same block as 1 B-02 and 1 B-05. We called CPF land checked the injection profile and decided to shut in 1 B-2 for the time being while 1 B-5 has been shut for a while. Lost valve cap on MP2, switch to MP1 and PUH to replace the valve cap gasket Drilling Lateral TF at 100 R. Hold between 88 and 89 deg hole angle Qp = 1.3 /1.3 bpm at 3750 psi free spin 18k PUwt DHWOB 0.50 to 1.50 k Ib BHP = 3980 psi at 12.24 ppg ECD Density = 9.30 /9.31 ppg ROP = 40-70 fph Agitator working well. Vp = 329 bbl LSRV at 41 K. Begin to add 55 bbls water to system to try and reduce pump pressure. W iper trip to window. Wlper trip back to bottom at reduced pump rate. Maintain as dri~led TF. Through side track area ok. One set down, hole mostly smooth. Coil down wt: 1 K-2K# at bottom. Drill ahead from 10,300'. 3900 psi fs at 1.49 in/1.45 out. DPSI:100-300 DHWOB: 1.5-1.9k#. CT WT: -1k to -6k#. WHP/BHP/ECD: 33/3940/12.11 ppg. IA/OA/PVT: 49/181/361 bbls. INC/AZM/TF: 87.7/60.6/65L. LSRV reduced from 40k to 31 k after adding water. Pump pressure and ECD still elevated. ROP varying from 15 to 70 fph. Stuck pipe at 10417. Suspect differential as ROP was 50-70 fpm. Stop circ and allow hole to relax. Work pipe to max at 60k#. Repeat several times. No go. Call for slick diesel from Wells group. Circulate 10 bbls diesel down coil. Spot 5 bbls in open hole. Pull to 60k. Popped free after a few minutes. Make wiper trip to window. Circulate out diesel. Maintain BHP. POOH as per pressure schedul. PUH to 7600 ft and circulate well clean before tieing in Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 STUC I PROD1 Printed: 7/10/2007 12:0626 PM ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 6/23/2007 105:15 - 07:45 I 2.501 DRILL I P 07:45 - 09:00 I 1.251 DRILL I P 09:00 - 12:05 I 3.081 DRILL I P 12:05 - 14:55 I 2.831 DRILL I P 14:55 - 18:15 I 3.331 DRILL I P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6h 2/2007 Rig Number: PROD1 PROD1 PROD1 PROD1 PRODi 18:15 - 22:00 I 3.75I DRILL I N I DFAL I PROD1 22:00 - 23:30 I 1.501 DRILL I N I I PROD1 23:30 - 00:00 0.50 DRILL N PROD1 6/24/2007 00:00 - 01:30 1.50 DRILL N DFAL PROD1 01:30 - 04:30 I 3.001 DRILL I N I DFAL I PROD1 04:30 - 04:45 0.25 DRILL N DFAL PRODi 04:45 - 07:30 2.75 DRILL N DFAL PRODi 07:30 - 10:25 I 2.921 DRILL I P I I PROD1 10:25 - 15:25 I 5.001 DRILL I P I I PROD1 Kuparuk Fire & Resuce held a man down in the pit area drill on Nordic 2 while at 1 B-15. Called Kuparuk Security 659-7300 and reported man down drill at 07:00 hrs Comments on the excerise on Remarks Page Tie-in at 8120 ft with EDC closed +12 ft. 8,176.4 ft. Set counters Qp=0.39/0.35 Density = 9.17 / 9.10 ppg HS TF. RIH conducting mud swap 9950 ft set down several times while working our way to bottom Tagged bottom at 10,417 ft Set TF at 90L Qp = 1.40 / 1.39 bpm at 3871 psi. free spin (old mud) Density = 9.23 / 9.25 ppg DHWOB = 1.5k, CTW = 1800k ROP = 50 fph; VP = 440 bbl Losing some fluid at 10,455 ft Stopped at 10,475 ft to turn TF around. PUW = 22k W iper trip at 10,550 ft Trip out was clean Reduced Qp to 0.5 bpm and RIH. Set down once at 8712 ft with right TF. Having troubie seeing mwd tools below DGS tool. Cannot resoive problem from surface. Circulate and wipe back to window. Open EDC. Circulate at 1.8 bpm while pulling out of hole. Maintain BHP as per pressure schedule. Jog back in well from surface. Saw no significant amount of cuttings. The hole appears to be clean. Hoid PJSM in Ops cab. Close EDC. Space out BHA. Pressure undeploy BHA. SIWHP dropped form 750 to 205 psi in 10 minutes. Bit had chipped gauge cutters 1-1-I. Lay down mwd tools. Trouble shoot and test tool string on catwaik. Continue to trouble shoot and test Inteq toois on cat walk. Replace DGS and HOT tool. Hold PJSM to discuss deployment. Pressure deploy from mouse hole due to tool length etc. Log GR tie in. Subtract 10' correction. RIH Closed EDC and RIH Little ratty during the last 250 ft to bottom. Tagged bottom at 10,549 ft Drilling lateral TF45L to HS to 90 R Qp = 1.41 / 1.40 bpm. CTP = 3675 psi off bottom BHP = 3,944 psi C~ 12.11 ppg ECD Density = 922 / 924 ppg DHWOB = 0.5-1.5 ROP = 50-70-10 fph. Vp = 428 bbis Stacking, wiper early Wiper trip to the base of the WS at 8250 ft Spill drill in the cellar, 2 crew members in the cellar area in < 2minutes Pulled a little tight at 8740 ft. RIH as per trippping procedure. Set down at 10,200 ft (orientation change) Printed: 7/10/2007 12:06:26 PM • ~ Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 6/24/2007 I 15:25 - 16:10 16:10 - 16:31 16:31 - 17:00 1 B-15 1 B-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 0.751 DRILL I P 0.35 DRIL~ P 0.48 DRILL P 17:00 - 17:30 0.50 DRILL P 17:30 - 20:00 2.50 DRILL P 20:00 - 00:00 4.00 DRILL N 6/25/2007 I 00:00 - 03:00 03:00 - 03:30 03:30 - 06:00 06:00 - 06:40 3.00 DRILL P 0.50 DRILL P 2.50 DRILL P 0.67 DRILL P PROD1 Wiper trip to window. Circulate out and discard diesel and contaminated mud. Pull 500' above window and run back in hole. PROD1 Log gr tie in. Add 16 ft correction. Check out pop off and add pressure to pulsation dampener. Maintain BHP as per schedule. PRODi Wiper trip back into hole at reduced circ rate. Hole mostly smooth. PROD1 Drilling lateral to flatten out at 90 deg TF 105R Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: PROD1 PROD1 PRODi PROD1 PROD1 Drilling lateral at 90 R W iper trip heiped for the 1 st 25 ft and then stacking started again. Qp = 1.43 / 1.42 bpm. CTP = 3675 psi off bottom BHP = 3,935 psi ~ 12.07 ppg ECD Density = 9.20 / 9.25 ppg DHWOB = 0.5-1.5 ROP = 10-100 fph. Vp = 402 bbls Geologist from town called and want to climb 15 ft ND at the end of this profile. 200 ft wiper trip. Drilling laterai at 90 to 75 R Hole angle in the last 90 ft rose from 88 deg to 94 deg 90 ft BHA wiper trips when needed. Its getting harder to push up hioll at the end of this profile. Qp = 1.43 / 1.42 bpm. CTP = 3675 psi off bottom BHP = 3,935 psi @ 12.07 ppg ECD Densiry = 9.20 / 9.25 ppg DHWOB = 0.5-1.5 ROP = 10-120 fph. Vp = 398 bbls Lost 28 in last 12 hr W iper trip to improve sliding uphill at the end of this profile. Talked with town and they agree to flatten the profile out to 90 deg. Crews building pill and pumping down coiled tubing while making wiper trip Drilling laterai to flatten out at 90 deg TF 105R Qp = 1.43 / 1.42 bpm. CTP = 3675 psi off bottom BHP = 3,935 psi ~ 12.03 ppg ECD Density = 9.20 / 925 ppg DHWOB = 0.5-1.5 ROP = 10-30 fph. Vp = 393 bbls Became differentially stuck at 10810' while running back in hole after a short wiper trip. Shut dn pump to relax hole. Work pipe. Call for slick diesel. Pump a 10 bbls hivis sweep while waiting on diesel. Work pipe. No movement. No surge of cuttings with sweep back to surface. Circulate 10 bbls slick diesel down hole. Spot 5 bbls in open hole. Allow well to relax. Work pipe. Relax pipe. Work pipe. Spot an additional 4 bbls diesel in open hole. Work pipe. Relax pipe. No movement. Finally after more rest, with diesel spotted for 1 hr total, pipe came free. STUC IPRODI Printed: 7/10/2007 12:0626 PM • ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Spud Date: 6/9/2007 Event Name: REENTER+COMPLETE Start: 6/9/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 6/12/2007 Rig Name: NORDIC 2 Rig Number: 6/25/2007 06:00 - 06:40 0.67 DRILL P PRODi 06:40 - 07:19 0.65 DRILL P PROD1 07:19 - 09:18 1.98 DRILL P PROD1 09:18 - 12:40 3.37 DRILL P PRODi 12:40 - 15:45 3.08 DRILL P PROD1 15:45 - 16:35 0.83 DRILL P PROD1 16:35 - 20:30 3.92 DRILL P PROD1 20:30 - 21:30 1.00 DRILL P PROD1 21:30 - 00:00 2.50 CASE P PROD1 6/26/2007 00:00 - 00:30 0.50 CASE P RUNPRD 00:30 - 02:00 1.50 CASE N RUNPRD Qp = 1.54 / 1.49 bpm. CTP = 3980 psi off bottom BHP = 4000 psi ~ 12.30 ppg ECD Density = 9.20 / 9.26 ppg DHWOB = 0.5-1.5 klb ROP = 10-60 fph. Controlling ROP <70 fph Vp = 314 bbls Lost approximately 50 bbl fluid to formation Wiper trip 10,870 ft 10,600 ft Driliing lateral to flatten out at 90 deg TF 105R Qp = 1.54 / 1.49 bpm. CTP = 3980 psi off bottom BHP = 4000 psi ~ 12.30 ppg ECD Density = 9.20 / 9.26 ppg DHWOB = 0.5-1.5 klb ROP = 70 fph. Controlling ROP <70 fph Vp = 308 bbl TD called from town at 10,950 ft ~ PUH to conduct wiper trip and tie-in for liner Pulled tight with motor work at 8475 ft. SD pump and pulied through window with HS toolface. PUH to 7,600 ft and RIH to 8,130 ft to tie-in. Plus 3 ft correction 8,142.60 + 3ft RIH with drilled toolface using pressure schedule Mixing up liner Alpine Bead pill as per: New 9.2 ppg Flo-Pro 2ppb Alpine beads, 1% Lube 776, 3% LowTorq, 14 #/bbl KlaGard. Having to work through hole section at 10,775 ft. Had to work through slow / drill. Got by at 10,804 ft. RIH having some trouble getting the last 200 ft Using Qp 1.4 bpm to wash through. Tagged bottom at 10952 ft Got survey on bottom PUH and conduct wiper trip to 10,700 ft to check hole conditions. Started Blead pill down CT Set down at 10,774 ft, worked through. Pushing BHA down to bottom at -3k to 2k Qp = 1.00 bpm Tagged bottom at 10,952 ft, circulate and work CT until beads are out of the coiled tubing. PUH laying in 70 bbls beads at Qp = 0.35 / 0.25 bpm Painted flag at 9500 ft EOP (yellow). Continue to puli out of hole laying in bead. Bead top estimate at 3500'. Close SSSV. Sleed off well. Check for flow. Ciose well in and check for pressure build up. SSSV appears to be holding. Hold PJSM while monitoring well. POOH to surface. Monitor well again. Pull and lay down BHA. Hold PJSM in dog hose. Rig up floor to pick up and run liner. 41 jts of 2-3/8" 4.7#, L-80 STL slotted w/ one solid shoe joint,o-ring sub, indexing guide shoe, and Baker deployment sleeve. Finish making up liner assembly. MU Inteq BHA toois including orienter. Stab coil. Get on well. Test tools. Unable to see EDC in mwd tool string. Get off well. Unsatb coil. LD tools. Change out EDC component. MU replacement. Stab coil. Test tools. Get on well. Open EDC. Printed: 7/10/2007 12:0626 PM ~ ~ Legal Well Name: 1 B-15 Common W ell Name: 1 B-15 Event Nam e: REENTE R+COM PLET E Contractor Name: NORDIC CALIST A Rig Name: NORDIC 2 , ~~ ' C~~~!~ ,F~'4m Tv H~c~rs T~sk ~~ -~1~ ' NPT ~ ch 21 ~ . r 6/26/2007 00:30 - 02:00 1.50 CASE N 02:00 - 05:15 3.25 CASE P 05:15 - 06:15 1.00 CASE P 06:15 - 06:36 0.35 CASE P 06:36 - 08:15 1.65 CASE P 08:15 - 13:00 4.75 CASE P 13:00 - 14:50 1.83 CASE P 14:50 - 16:45 1.92 CASE P 16:45 - 17:30 0.75 CASE P '', i 17:30 - 18:30 1.00 CASE N 18:30 - 19:35 1.08 CASE N 19:35 - 22:00 2.42 CASE N 22:00 - 22:15 025 CASE N 22:15 - 22:35 0.33 CASE P 22:35 - 00:00 1.42 CASE N 6/27/2007 00:00 - 00:30 0.50 CASE N 00:30 - 01:00 0.50 CASE P 01:00 - 01:40 0.67 STWHIP P 01:40 - 03:15 1.58 STWHIP P 03:15 - 03:35 0.33 STWHIP P 03:35 - 03:45 0.17 STWHIP P Spud Date: 6/9/2007 Start: 6/9/2007 End: Rig Release: 6/12/2007 Rig Number: y I Pk~as~ C~e~r~pf~c~~ ~f~~~~~r~on~ a il Y.~n uN:. „~ n~r 'a,~~~lu ~~l`i F,..riid 6lT~!i(~{ RUNPRD Pressure well to 700 psi. Open SSSV. RUNPRD Run in hole maintain BHP as per schedule. 18.5k# up, 11k# dn wt at 8,200'. Subtract 16' after tying into EOP flag(white at 8000'). Continue to run in hole at 35 fpm. 5.5k# dn, 27k# up wt at 10925'. Tag btm at 10,951'. Circulate down coil to release from liner. Top of lower liner section: 9634'. RUNPRD Pull out of hole. Maintain BHP as per schedule from the top. RUNPRD Log GR tie in to verify top of lower liner section. Plus 4 ft correction RUNPRD POOH using pressure schedule. Closed SSV with CT at 1300 ft and chcked flow. (OK) RUNPRD Held PJSM and PU liner as per Data Base Summary. Crayloa Guide shoe, 1 jt 2-3/8" O-Ring Sub 22 jts 2-3/8" slotted and 19 jts 2-3/8" solid. 3 pup jts, and 1 2-3/8" slotted liner at top with deployment sub. PU CoilTrac with DGS and EDC RUNPRD RIH maintaining BHP using surface pressure values. Wt check at 9400 ft. RIH and tagged at 9,635 ft Pumped and worked at releasing liner. Get off liner. The Baker GS is often in a bind when run to just outside the window. Top of upper liner section: 8244'. Btm of upper section: 9635'. Bottom of lower liner section: 10952'. RUNPRD POOH following sufrace pressure schedule. Close SSSV. Pull to surface. Hold PJSM while monitoring well for flow. RUNPRD Get off well. Unstab pipe. BHA is very heavy. Liner still attached. RUNPRD Wait on Baker to deliver a knuckle joint assembly. RUNPRD MU same MWD assy w/ knuckle above GS RUNPRD Pressure welibore to 800 psi, open TRSSSV. RIH w/ liner on CT holding 800 psi while circ down BS At 8000' 17.1 k. RIH thru openhole at 35'/min to tag at 9649.1' CTD (normai corr is -11'). PUH w/o pump at 20.3k, set liner back on top of deployment sub of bottom section RUNPRD Start pump 1.47/4500 while hold 800 psi whp. PUH 19.5k and were not released. RBIH and set liner on top of bottom section again. Pull a little faster and had released liner at 12.8k. PUH to log RUNPRD Log down from 9480' to 9520' CTD. Corr -12' which means the BOL is -9637' vs tally depth of 9635.03' which is close enough since the tally (and officiai) TOL is 8243.63' RUNPRD POOH circ thru GS 0.6/1850 holding 800 psi whp RUNPRD Close TRSSSV. Flow check. LD MWD assy. LD BTT liner running tools RUNPRD BHI reconfigure MWD tool string, add orientor and DPS Nordic change wt indicator WEXIT MU BTT wall hook w/ guide +jars + MWD assy WEXIT RIH w/ WS retrieving assy circ 0.37/1770 holding 725 psi. Open TRSSSV W EXIT Log tie-in down from 8115', corr -11' 8220' 16.5k WEXIT Orient hook to 170R. RIH to wt loss at 8232.0'. PUH 5'/min and had slow, inconsistent wt incr to 20.3k, then lost wt slowly Printed: 7/10/2007 12:0626 PM • ~ Legal Well Name: iCommon Well Name: I Event Name: !, Contractor Name: ', Rig Name: I 6/27/2007 I 03:35 - 03:45 03:45 - 05:15 1 B-15 1 B-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 0.171 STWHIPI P 1.501 STWHIPI P Start: 6/9/2007 Rig Release: 6/12/2007 Rig Number: W EXIT W EXIT 05:15-05:40 0.42 STWHIP P WEXIT 05:40 - 06:15 0.58 STWHIP N DPRB WEXIT 06:15 - 07:30 1.25 STWHIP N DPRB WEXIT 07:30-08:15 0.75 STWHIP N DPRB WEXIT 08:15-08:45 0.50 STWHIP N DPRB WEXIT 08:45-09:30 0.75 STWHIP N DPRB WEXIT 09:30 - 10:00 0.50 STWHIP N DPRB WEXIT 10:00-11:301 1.501STWHIPIN IDPRB IWEXIT 11:30 - 12:30 1.00 STWHIP N DPRB WEXIT 12:30-14:00 1.50 STWHIP N DPRB WEXIT 14:00 - 14:30 0.50 STWHIP N DPRB WEXIT 14:30-15:45 125 STWHIP N DPRB WEXIT 15:45 - 17:45 I 2.001 STW HIPi N I DPRB I W EXIT 17:45 - 19:30 I 1.751 STWHIPI N I I WEXIT 19:30 - 20:20 I 0.83I CONDHLI P I I RUNPRD 20:20 - 22:00 1.67 CONDH~P RUNPRD 22:00 - 22:25 0.42 CONDH P RUNPRD 22:25 - 00:00 I 1.581 CONDHU P I I RUNPRD 16/28/2007 100:00 - 00:45 I 0.751 CONDHU P I I RUNPRD Spud Date: 6/9/2007 End: back to 16.5k. Assumed it would be a tougher pull eventhough WS pins were set for 3k. Elected to POH to check for recovery rather than retry for better indication and possibly lose it POH circ 0.62/1900 w/ WS? foliowing pressure schedule. Close TRSSSV. Check weli for flow OOH w/ BHA and had no recovery, no marks MU same BHA Run in hole. Open SSSV. Maintain BHP as per schedule. Log GR tie in from 8130'. Subtract 11'. 18k# up, 10.3k# dn wt. Tag whipstock at 8232'. PU and jar up at 24k#, 26k#, 28k#, and 30k#. Then straight pull to 36.3k#. Something came free. Pull out of hole at 75 fpm maintaining BHP. At surface. LD BHA. No recovery. No obvious marks on the hook or skirt, or any where else on the BHA. Dlscuss options with Baker and town. Decide to run a non-skirted hook. MU BHA with replacement hook. Stab coil. Get on weli. Run in hole. Open SSSV. Maintain BHP as per schedule. Log GR tie in from 8110'. Subtract 11' correction. 16.5k# up, 10.Ok# dn wt. Tag fish at 8230'. TF 180. PU with a 3-5k# overpull, then back to 16.5k# up wt. Try changing TF 20 deg to left and right. Same resuit. Orient TF to HS. Attempt to RIH. Tag again at 8230'. Orient back to low side. Work pipe and TF a few more times. Begin trip out of hole. See severai 6-8k# overpulls in first 100 feet. Pull slowly until overpulls clear up and through X nipple at 8032'. Pull out of hole at 70 fpm. Close TRSSSV, chk for flow Hang BHA in derrick and check fishing assy. No recovery. Found the hook body was sli bent backwards near the middie of bar. Hook was sli rolled to the inside and paint was gone from the hook area. No other scars or marks showed anything other than RIH/POH wear Discuss w/ Asset. Will leave WS for Wells Group to recover LD fishing BHA. LD MWD assy WO suitable nozzle from KRU whse. MU 2.70" side/down jet nozzle on 5' stinger. BHA=8.48' RIH w/ nozzle assy circ 0.5/1800 holding 800 psi whp. Open TRSSSV Corr -11' at 8011' 12.5k, 6.8k while circ 0.52/1980 w/ 560 psi whp 8100' 13.6k, 7.6k RIH to tag at 8226.5' and stack 2k PUH clean at 13.4k. RIH 7.4k and retag at 8226.5' and stack 5k to 8228.7'. PUH w/ overpull to 18.3k and had sharp drop off in wt (acts like pinch point on WS). The the official recorded TOWS depth is at 8226.4'. There is no way to disconnect from this BHA, so did not attempt to push harder to go thru window Start SW down CT at 1.47/2700 w/ open choke. POOH from 8220' displacing wellbore to SW to 2200' and diesel to surface following pressure schedule. Close TRSSSV Finish POOH displacing 92# mud w/ SW. FP wellbore from 2200' to surface. Close TRSSSV. Bleed off 1200 psi surface Printed: 7/10/2007 12:0626 PM ~ ~ Legal Well Name: 1 B-15 Common Well Name: 1 B-15 Spud Date: 6/9/2007 Event Name: REENTER+COMPLETE Start: 6/9/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 6/12/2007 Rig Name: NORDIC 2 Rig Number: L3~#e W ~~ em~ . ~'~rc~m T~ Hc~ur~ T~~k~ - rry ~ Gci~3~ ,_ . 1~PT P,~ta~es `, i ~ N ~ , d .~.Y ~ ~~ ~~~ ~~~, ~~~i~ ~~ s~~ ~t~~i~~cr~~~~~r~ c~f ~°~ier~~~;~ n~ ~~ ; ~ ~ ,, , G 6/28/2007 00:00 - 00:45 0.75 CONDH P RUNPRD pressure and check for flow 00:45 - 01:15 0.50 WHSUR P POST FMC dryrod 3" BPV ~ 01:15 - 03:15 2.00 RIGD P POST MIRU SWS N2. Pump 10 bbls diesei into CT. Blow down CT w/ N2 and bleed off 03:15 - 06:00 2.75 RIGD P POST Cut off CTC. Set injector on legs. Install internal grapple and pull CT back to reel and secure. 06:00 - 12:00 6.00 DEMOB P POST ND BOPs. Lift stack off tree. Remove berm materials from cellar. Move misc equipment away from rig. Hold PJSM with crew to move off well. Release rig at 1200 on 6/28/07 Additional daily operations for this date wili be found under 1 B-08 Printed: 7/10/2007 12:06:26 PM • • ~ bp BP Alaska Baker Hughes INTEQ Survey Report ~~r aw~res INTEQ Company: BP Amoco Date: 6l26/2007 Time: 13:29:41 Page: i FieM: Kupa~'tik Co-ordinate(NE) Refereace: Well: 15, True North 5ite: KRU 1 B Pad VerticAl (7'VD) Reference: RKB Elev 3 85A WeIL• 15 Sectioo (VS) Referenca We8 (O.OON,O.OOE,210.79Azi) Welipath: 1 B-15AL3 Sarvey Calcalatioe Method: Minimum Curvature Dba Orade Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datam: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 1 B Pad Site Position: Northing: 5969646.72 ft Latitude: 70 19 40.290 N Erom: Map Easting: 549457.40 ft Longitude: 149 35 56.056 W Position Uncertainty: 0.00 ft Nort6 Reterence: True Groand Level: 0.00 ft Grid Convergence: 0.38 deg Well: 15 Slot Name: Well Position: +N/-S -2.95 ft Northing: 5969647.05 ft- Latitude: 70 19 40.261 N +E/-W 497.82 ft Eastiog : 549955.18 ft~ Longitude: 149 35 41.524 W Position Uncertainty: 0.00 ft Wellpath: 1 B-15AL3 Drilled From: 1 B-15A13PB1 Tie-on Depth: 9053.23 ft Current Datum: RKB Elev 3 Height 95.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/19/2007 Declination: 23.47 deg Field Strength: 57625 nT Mag Dip Angle: 80.86 deg Vertical Section: Dept6 From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.70 0.00 0.00 210.79 Survey Program for Definitive Wellpath Date: 6/19/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 463.34 4166.56 1 B-15 (463.34-7443.00) (0) MWD MWD - Standard 4405.00 8175.52 1B-15A mwd {4405.00-8585.57) ( MWD MWD - Standard 8226.40 9053.23 MWD (8226.40-9223.00) (6) MWD MWD - Standard 9065.00 10952.00 MWD (9065.00-10952.00) MWD MWD - Standard onotation NID TVD ft ft 9053.23 6319.46 Tie in Point 9065.00 6319.03 KOP 10952.00 6363.87 TD Survey: MWD Start Date: 6/19/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path i ~ bp BP Alaska ~s ~ Baker Hughes INTEQ Survey Report 1NTE 2 CompAny: BP Amoco Date: 6/26/2007 Time: 13:29;41 Page: 2 Field: Kuparuk Co-ordiuate(NE) Reference: Well: 15, True North Site: KRU 1 B Pad Verticai (1'VD) RePerence: RKB Elev 3 95.8 Well: 15 S ectioa (VS) Reterence: Well (O.OON,O .OOE,210. 79Azi) Wellpath; 1 B- 15AL3 Sarvey CalcolaHon Met6od: Minimum Curvature Db: OraGe Snrvey MD Iocl Azim TVD Sys TVD N/S E/W MapN MapE VS DI.$ Tool ft deg deg ft ft ft ft ft ft ft deg11008 9053.23 91. 84 56.23 6319.46 6224.46 -2669.46 -2323.44 5966962.44 547649.79 3482.50 0.00 MWD 9065.00 92. 30 54.44 6319.03 6224.03 -2662.77 -2313.76 5966969.20 547659.42 3471.80 15.69 MWD 9095.47 88. 52 61.93 6318.82 6223.82 -2646.72 -2287.90 5966985.42 547685.18 3444.77 27.53 MWD 9124.47 91. 38 67.03 6318.84 6223.84 -2634.23 -2261.74 5966998.08 547711.25 3420.65 20.16 MWD 9155.63 89. 88 70.91 6318.50 6223.50 -2623.05 -2232.66 5967009.45 547740.25 3396.17 13.35 MWD 9188.55 88. 77 74.57 6318.89 6223.89 -2613.28 -2201.23 5967019.42 547771.61 3371.69 11.62 MWD 9218.85 90. 28 79.65 6319.14 6224.14 -2606.53 -2171.71 5967026.37 547801.09 3350.78 17.49 MWD 9250.79 84. 86 81.97 6320.49 6225.49 -2601.43 -2140.22 5967031.68 547832.54 3330.28 18.45 MWD 9280.44 85. 42 86.33 6323.00 6228.00 -2598.42 -2110.84 5967034.88 547861.90 3312.66 14.77 MWD 9310.75 85. 88 91.05 6325.30 6230.30 -2597.73 -2080.63 5967035.78 547892.09 3296.60 15.60 MWD 9339.71 84. 19 96.39 6327.81 6232.81 -2599.60 -2051.85 5967034.10 547920.88 3283.48 19.27 MWD 9367.12 84. 71 92.53 6330.46 6235.46 -2601.72 -2024.66 5967032.16 547948.09 3271.38 14.14 MWD 9397.11 84. 01 88.62 6333.41 6238.41 -2602.02 -1994.82 5967032.06 547977.92 3256.37 13.18 MWD 9426.32 82. 86 85.29 6336.75 6241.75 -2600.48 -1965.85 5967033.79 548006.88 3240.22 11.99 MWD 9460.98 81. 01 80.73 6341.62 6246.62 -2596.31 -1931.79 5967038.19 548040.90 3219.21 14.08 MWD 9492.33 80. 35 77.04 6346.70 6251.70 -2590.35 -1901.44 5967044.35 548071.21 3198.55 11.80 MWD 9522.45 82. 19 73.90 6351.27 6256.27 -2582.88 -1872.63 5967052.01 548099.97 3177.39 11.98 MWD 9552.78 87. 51 72.89 6353.99 6258.99 -2574.25 -1843.69 5967060.83 548128.84 3155.16 17.85 MWD 9586.89 89. 69 70.43 6354.82 6259.82 -2563.52 -1811.33 5967071.78 548161.13 3129.38 9.63 MWD 9614.94 88. 83 66.28 6355.19 6260.19 -2553.18 -1785.27 5967082.29 548187.12 3107.15 15.11 MWD 9648.49 89. 48 62.95 6355.68 6260.68 -2538.80 -1754.96 5967096.87 548217.33 3079.29 10.11 MWD 9677.70 92. 33 60.67 635522 6260.22 -2525.00 -1729.23 5967110.84 548242.97 3054.27 12.49 MWD 9706.61 91. 41 57.08 6354.28 6259.28 -2510.07 -1704.50 5967125.93 548267.60 3028.78 12.81 MWD 9735.59 90. 89 52.29 6353.70 6258.70 -2493.33 -1680.86 5967142.83 548291.12 3002.30 16.62 MWD 9767.61 92. 03 48.02 6352.88 6257.88 -2472.82 -1656.29 5967163.50 548315.55 2972.11 13.80 MWD 9802.53 89. 66 42.02 6352.36 6257.36 -2448.15 -1631.61 5967188.33 548340.07 2938.28 18.47 MWD 9835.07 88. 49 37.52 6352.89 6257.89 -2423.15 -1610.80 5967213.46 548360.71 2906.15 14.29 MWD 9865.22 89. 26 33.98 6353.48 6258.48 -2398.69 -1593.19 5967238.04 548378.15 2876.13 12.01 MWD 9902.61 86. 31 27.11 6354.93 6259.93 -2366.54 -1574.21 5967270.31 548396.91 2838.79 19.98 MWD 9931.83 88. 65 28.77 6356.21 6261.21 -2340.75 -1560.54 5967296.19 548410.41 2809.64 9.82 MWD 9961.33 89. 85 32.43 6356.60 6261.60 -2315.37 -1545.52 5967321.67 548425.26 2780.15 13.06 MWD 9991.85 91. 35 36.57 6356.28 6261.28 -2290.22 -1528.24 5967346.93 548442.37 2749.70 14.43 MWD 10025.46 90. 06 40.76 6355.87 6260.87 -2263.99 -1507.25 5967373.30 548463.18 2716.42 13.04 MWD 10056.32 89. 54 45.54 6355.97 6260.97 -2241.48 -1486.15 5967395.94 548484.13 2686.28 15.58 MWD 10085.08 87. 45 48.72 6356.73 6261.73 -2221.92 -1465.08 5967415.64 548505.06 2658.70 13.23 MWD 10114.52 88 .13 52.93 6357.86 6262.86 -2203.35 -1442.28 5967434.36 548527.74 2631.07 14.48 MWD 10143.25 89 .35 56.47 6358.50 6263.50 -2186.75 -1418.85 5967451.11 548551.06 2604.82 13.03 MWD 10172.92 87 .51 60.58 6359.31 6264.31 -2171.27 -1393.56 5967466.76 548576.24 2578.57 15.17 MWD 10207.65 89 .94 63.35 6360.08 6265.08 -2154.95 -1362.92 5967483.28 548606.77 2548.87 10.61 MWD 10237.99 88 .03 59.86 6360.62 6265.62 -2140.53 -1336.23 5967497.88 548633.36 2522.83 13.11 MWO 10279.61 86 .80 52.61 6362.50 6267.50 -2117.44 -1301.69 5967521.20 548667.74 2485.31 17.65 MWD 10313.03 88 .59 49.05 6363.84 6268.84 -2096.35 -1275.81 5967542.46 548693.48 2453.95 11.91 MWD 10344.40 89 .51 46.09 6364.36 6269.36 -2075.19 -1252.66 5967563.77 548716.48 2423.92 9.88 MWD 10373.79 89 .26 42.75 6364.68 6269.68 -2054.20 -1232.10 5967584.89 548736.91 2395.36 11.40 MWD 10404.95 89 .94 39.49 6364.90 6269.90 -2030.73 -1211.61 5967608.49 548757.24 2364.71 10.69 MWD 10435.03 90 .34 36.73 6364.82 6269.82 -2007.07 -1193.04 5967632.28 548775.64 2334.88 9.27 MWD 10466.15 87 .08 31.38 6365.53 6270.53 -1981.31 -1175.63 5967658.15 548792.88 2303.84 20.13 MWD 10495.46 88 .50 28.60 6366.66 6271.66 -1955.94 -1160.99 5967683.61 548807.35 2274.55 10.64 MWD 10525.04 88 .31 24.38 6367.48 6272.48 -1929.48 -1147.81 5967710.15 548820.36 2245.08 14.28 MWD 10555.31 87 .91 20.61 6368.48 6273.48 -1901.54 -1136.23 5967738.17 548831.74 2215.14 12.52 MWD 10593.17 87 .15 16.73 6370.11 6275.11 -1865.71 -1124.13 5967774.08 548843.61 2178.17 10.43 MWD 10625.64 89 .66 16.18 6371.01 6276.01 -1834.58 -1114.93 5967805.26 548852.59 2146.72 7.91 MWD 10655.90 93 .84 18.51 6370.09 6275.09 -1805.72 -1105.92 5967834.18 548861.41 2117.32 15.81 MWD • . bp BP Alaska s~s ~ Baker Hughes INTEQ Survey Report 1NTE Q Company: $P Amoco Date: 6/26/2007 TLne: 13:29:41 Page: 3 Field: Kuparuk Co-ordinate(NE) Refereace: WeIL• 15, True North Site: KRU iB Pad Vertleal (1'VD) Refereece: RKB Elev 3 95.0 We1L• 15 ' Sectioo (VS) Reference. Well (O.OON ,O.OOE,21 Q. 79Azi) Wellpath: 1B- 15AL3 Survey Calcalation Method: Minimum Curvature Db: Orade Sarvey 1kID Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/1DOft 10686.62 94.24 21.99 6367.92 6272.92 -1776. 98 -1095.32 5967862.99 548871.83 2087.19 11.37 MWD 10722.70 92.79 26.34 6365.71 6270.71 -1744. 13 -1080.58 5967895.93 548886.34 2051.43 12.69 MWD 10754.33 90.89 31.95 6364.70 6269.70 -1716. 53 -1065.19 5967923.63 548901.55 2019.84 18.72 MWD 10788.99 88.43 32.77 6364.90 6269.90 -1687. 26 -1046.64 5967953.03 548919.90 1985.20 7.48 MWD 10820.38 89.20 36.74 6365.55 6270.55 -1661. 48 -1028.75 5967878.92 548937.61 1953.90 12.88 MWD 10850.44 90.71 40.99 6365.57 6270.57 -1638. 08 -1009.89 5968002.44 548956.31 1924.15 15.00 MWD 10882.82 92.37 44.56 6364.70 6269.70 -1614. 32 -987.92 5968026.34 548978.13 1892.49 12.15 MWD 10908.32 90.31 48.72 6364.11 6269.11 -1596. 83 -969.39 5968043.96 548996.54 1867.97 18.20 MWD 10952.00= 90.30 54.40 6363.87 6268.87 -1569. 68 -935.19 5968071.33 ~ 549030.56 .- 1827.15 13.00 MWD • ~ ~ ~ - ~ bp BP Alaska ~~ ~ Baker Hughes INTEQ Survey Report ~:r(TE Q Gompaay: BP Amoco Date. &/26f2007 Time: 10:04':18 `Pa~t: . 1 F~eld: Kuparuk Co-ordinate(NE) Reference: 1%1(ell: 15; True NorfFt Site: KRU 1 B Pad Ve~l (TVD) Refereuce: RKB Elev 3 95.0 Well: 15 Sectian (VS)Refereace: 'WeA (fl.QON,Q,00E,220.52Azi) Wellpath: 1&15AL3P61 Survey Cakulation Methad: Minimum Curvlture `: Db: Orade ~eld: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datam: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 1 B Pad 5ite Position: Northing: 5969646.72 ft Latitade: 70 19 40.290 N From: Map EasNng: 549457.40 ft Longitude: 149 35 56.056 W PosiHon Uncertainty: 0.00 ft North Reference: True Ground I.evel: 0.00 ft Grid Convergence: 0.38 deg Well: 15 Slot Name: Well Positioa: +N/-S -2.95 ft Northing: 5969647.05 ft Latitnde: 70 19 40.261 N +E/-W 497.82 ft Easting : 549955.18 ft Longitude: 149 35 41.524 W Position Uncertainty: 0.00 ft Wellpath: 1&15AL3P61 Drilled From: 1 B-15A Tie-on Depth: 8175.52 ft Current Datum: RKB Elev 3 Height 95.00 ft Above System Datnm: Mean Sea Level Magnetic Data: 5/7/2007 Declination: 23.52 deg Field Strength: 57623 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.70 0.00 0.00 220.52 Survey Program for Definitive Wellpath Date: 5/7/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 463.34 4166.56 1&15 (463.34-7443.00) (0) MWD MWD - Standard 4405.00 8175.52 1&15A mwd (4405.00-8585.57) ( MWD MWD - Standard 8226.40 9223.00 MWD (8226.40-9223.00) MWD MWD - Standard Aunotation 1l1U Ti~D fr : ft 8175.52 6214.10 Tie in Point 8226.40 6256.18 KOP 9223.00 6307.69 TD Survey: MWD Start Date: 6/18/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path ~(~? -~(~~ f ~ ~• ~ar i~s INTGQ ~ ~ ~ bp BP Alaska Baker Hughes INTEQ Survey Report Survey ,~ ..~ 8'! 75.52 35.11 8226.40 33.28 8260.09 46.55 8290.22 59.05 8321.06 71.51 8350.17 76.63 8380.10 84.59 8410.67 88.83 8441.68 87.54 8470.15 88.96 8501.68 90.21 8537.08 91.23 8561.24 91.29 8590.34 91.78 8620.21 91.32 8649.94 90.86 8681.32 90.00 8710.34 91.20 8745.33 90.74 8775.10 91.96 8808.41 91.07 8840.65 88.37 8870.28 89.39 8900.65 90.25 8930.07 90.25 8960.43 91.99 8993.77 93.72 9023.28 93.01 9053.23 91.84 9087.11 93.16 9120.39 94.95 9150.06 96.18 9180.58 94.76 9223.00 91.05 ~Ln ;1'~D Sys TVll N/5 E/W de~ ft ft ft ft 233.59 6214.10 6119.10 -2325.48 -2783.89 232.63 6256.18 6161.18 -2342.64 -2806.76 221.15 6282.00 6187.00 -2357.55 -2822.24 214.59 6300.19 6205.19 -2376.51 -2836.84 199.80 6313.13 6218.13 -2401.37 -2849.41 181.99 6321.17 6226.77 -2428.73 -2854.62 167.01 6326.08 6231.08 -2458.01 -2851.75 162.79 6327.83 6232.83 -2457.46 -2843.81 157.69 6328.82 6233.82 -2516.62 -2833.33 153.24 6329.69 6234.69 -2542.50 -2821.52 148.58 6329.91 6234.91 -2570.04 -2806.19 142.77 6329.54 6234.54 -2594.31 -2789.62 138.99 6328.88 6233.88 -2617.70 -2770.60 133.86 6328.10 6233.10 -2638.76 -2750.56 129.02 6327.29 6232.29 -2658.52 -2728.18 124.15 6326.73 6231.73 -2676.23 -2704.32 118.90 6326.49 6231.49 -2692.63 -2677.58 111.56 6326.19 6231.19 -2704.99 -2651.35 105.84 6325.59 6230.59 -2716.20 -2618.23 99.93 6324.89 6229.89 -2722.84 -2589.23 95.20 6324.01 6229.01 -2727.22 -2556.23 91.07 6324.17 6229.17 -2728.98 -2524.05 86.32 6324.75 6229.75 -2728.31 -2494.44 80.96 6324.84 6229.84 -2724.95 -2464.27 75.69 6324.72 6229.72 -2718.99 -2435.47 70.82 6324.12 6229.12 -2710.25 -2406.41 65.33 6322.46 6227.46 -2697.83 -2375.53 62.11 6320.73 6225.73 -2684.78 -2349.12 56.23 6319.46 6224.46 -2669.46 -2323.44 51.08 6317.98 6222.98 -2649.40 -2296.18 46.31 6315.63 6220.63 -2627.50 -2271.25 50.39 6312.75 6217.75 -2607.88 -2249.19 53.14 6309.84 6214.84 -2589.08 -2225.33 53.71 6307.69 6212.69 -2563.84 -2191.32 5967303.31 547187.11 5967286.00 547164.35 5967270.99 547148.97 5967251.94 547134.50 5967227.00 547122.10 5967199.61 547117.07 5967170.35 547120.13 5967140.96 547128.27 5967117.87 547138.94 5967086.07 547150.93 5967058.63 547166.43 5967034.48 547183.16 5967011.22 547202.34 5966990.29 547222.52 5966970.68 547245.02 5966953.13 547269.00 5966936.91 547295.84 5966924.73 547322.16 5966913.74 547355.35 5966907.30 547384.39 5966903.14 547417.41 5966901.59 547449.60 5966902.46 547479.20 5966906.02 547509.35 5966912.17 547538.11 5966921.10 547567.10 5966933.73 547597.89 5966946.95 547624.27 5966962.44 547649.79 5966982.68 547676.91 5967004.74 547701.69 5967024.51 547723.62 5967043.46 547747.35 5967068.93 547781.19 3576.52 0.00 MWD 3604.42 3.75 MWD 3625.81 44.91 MWD 3649.71 44.93 MWD 3676.77 59.29 MWD 3700.96 61.36 MWD 3721.35 56.04 MWD 3738.58 19.55 MWD 3753.94 16.96 MWD 3765.94 16.40 MWD 3776.92 15.30 MWD 3784,60 20.06 MWD 3790,02 12.53 MWD 3793,01 17.70 MWD 3793,49 16.27 MWD 3791,45 16.45 MWD 3786.55 16.95 MWD 3778.90 25.63 MWD 3765.90 16.40 MWD 3752.10 20.27 MWD 3733.99 14.44 MWD 3714.42 15.30 MWD 3694.68 16.39 MWD 3672.52 17.87 MWD 3649.28 17.97 MWD 3623,75 17.03 MWD 3594.25 17.24 MWD 3567.17 11.16 MWD 3538.83 20.00 MWD 3505.88 15.68 MWD 3473.03 15.27 MWD 3443.79 14.30 MWD 3413.99 10.10 MWD 3372.70 8.85 MWD KRU 1 B-15A L3 C-sand Lateral Final CTD Completion ConocoPhilli S p Alaska, Inc. 3-1/2" Camco TRM-5E SSSV, 2.812" min ID at 1483' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing 9-5/8~~ ao# 3-'/z' Camco KBUG-M GLMs @ 2633', 3905' MD ~-so @ a~so~ 5-'/" x 7" Baker CPH Packer w/SBE @ 4241' MD ~° 2s# ~-ao @ aao5~ M~ 3-'/2' Camco KBG-2-9 GLM @ 5094', 6979', & 7823' MD 3-'/" Baker SABL3 packer @ 7890' MD ! 3-YZ' HES "X" nipple, 2.75" min ID @ 8033' MD (May require milling out to 2.80" to accommodate 2.78" Baker KB packer/WS) Poor Boy Overshot @ 8078' MD 3-'/2' Baker ZXP liner top packer @ 8140' MD 2-3/8" slotted liner 2-3/8" deployment sleeve @ 8244' squeeze perfs with 1 joint 2-3/8" slotted liner below 8208' - 8218' 2-3/8" liner ~ 2.74" window 8227' - 8235' 1 B-15A L3 Lateral, 2-3/8" STL L-80 blank liner to junction @ 9635 i ~ 8902', slotted below TD @ 10952' md Retrievable Baker KB ~ ~-- Packer/Whipstock tray/ ~ I standing valve with 1" flow- I~~ i _ _ _ _ _ _ thru vent. Tray is 3000# release from packer. Faul @~ 8860~ nn~ 1 B-15A L2 Lateral, L2 liner top @ 8259' md TD @ 10896' md • L2 KOP 8289' MD -- .-- ~_ 8296~ . 2-3i8~~ liner 3" openhole ~ 1 junction @ 9655' ~ 3-~/2' LSX WS (flowthru) 2-3/8" slotted liner L1 KOP 8340' MD Squeeze perfs 1 B-15A L1, TD @ 9700' md 8305' - 8307' san pe ?/i' 15.5~ L80 Hydril aao8' - 8417~, 511 ~ 8350~ md 3" openhole 8432' - 8452' Squeeze pe 3-1/2" 9.3# L-80 8506' - 8510' ~ 8621' MD 06-28-07 DEV C~ ~ 11/09/04 STATE OF ALASKA O IL AND GAS CE?NSERYAT#C1N C~MMISStiDN BC}PE Test Report Submit to: Contractor; Nordic _. Rig No.: 2 aATE: 6/22/07 Rig Rep.: McKeiman/Sloan Rig Phone: 653~398 Rig Fa~c_ 659-4356 Operator: BPX Qp_ F~hone: 6F5~439~3 E~p. Fau: 659-4356 Rep.: Hikireth/Goodricf~ E-Mai{ , , : € ~ ~ Well Name: 1 B-15AL3 PTD # ZOT-067 Operation: Drk,~: X70C Wa~lcover: ExpEor.: Test: Initial: Weekty. Bi-Weekly XXX Test Pressure: Rams: 250-4(~0 Annular. 25Q-40U0 Vafves: 250-4000 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Resutt Te~st Resutt Quarriity Test Result Location Gen.: P Wett Sign P Upper Kelty NA Housekeeping: P Drl. Rig P Lower Keiiy NA PTD On Location P Hazarc! Sec. P Bali Type 1 P Standing Order Post~ P inside BOP NA BOP STACK: QuaM~ty Sizeffype Test Resuft MUD SYSTEM: Visual Alarm Stripper 1 2" P Tnp Tank P P Annular Preventer 1 7 1/16° P Pit Level lndicators P P #1 Rams 1 Blind / Shear P Fi~v Irxlicatar P P #2 Rams 1 2"combi's P lrliefh Gas ~tedor P F #3 Rams 1 2 3!8"camt~'~ P f~2S Gas Qetedor P P #4 Rams 1 2"combi's P #5 Rams NfA NA Quantity Test Result Choke Ln. Valves 1 3 9f8" P Ir~side Reet va{ves 1 P HCR Valves 2 3118" P Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve 2 21/16" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Ctasure 2300 P Quantity Test Result 2QQ psi Attained 22 sec. P No. Valves 14 P Ful1 Pre.ssure At#ained 1 miN29sec P Manual Chokes 1 P Bfind Switch Ccivers: AI! statrons Y Hydraulic Chokes 1 P Nitgn. Battles (avg): 4 2125 Test Resu~ts Number of Failures: 0 Test Time: 5 Hours Componerrts fested 30 Repair or replacement of equiprr-en# ~nrill be made ~nathin 0 days. Notify the N orth Slope Ins ector 659-3607, follaw with written cx~nfirmation ta Superviser at: ..._ _..w_. ; Remarks: Distribution: 24 HOUR NOTfCE GIVEN orig-Well File YES )OCX NO c- Oper./Rig Waived By Bob Noble c- Database Da#e S/Zi/07 Time 1730 hrs. c- Trip Rpt File Ulfitness Goodrich/Pederson c- Inspector Test start 23:Q0 Fin~h 04:~ Coil Tubing BFL 11/09/04 Noedic 2 BOP &22-07p.xls ~ ~ 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit ta: Contractor: Nordic _ __ _... Rig No.: 2 DATE: 6/10/07 Rig Rep.: Hoimes/Lancaster Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone= 659-4393 Op. Fax: 659-4356 Rep-: SevciklRoss E-Mail ~ _ _ ...._ r ~. . ~ . ~.: z ~ ;~ Wetl Name: 1 B-15AL3 PTD ~ F~ Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekty Test Pressure: Rams: 250-4~00 Annufar. 25Q-4U00 Valves: 250-4000 MISC. INSPECTIONS: 7EST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P We11 Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Batl Type 1 P Standing Order Posted P [nside BOP NA BOP STACK: Quanfity SizelType Test Resuft MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 i/16" P Pit Level Indicators P P #1 Rams 1 Blind / Shear P Flow Indicator P P #2 Rams 1 2"combi's P Me1h Gas Detector P P #3 Rams 1 2 3/8"cambi'c P H2S Gas Detector P P #4 Rams 1 2"combi's P #5 Rams N/A NA Qu~n#ii~ Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 31/8" P Kill Line Valves 1 31/8" P ACCUMULATOR SYSTEM: Check Valve 2 2 1/16" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 27 sec P No. Valves 14 P Full Pressure Attained 1 min/10sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nftgn. Botttes (avg): 4 2200 Test Resufts Number of Failures: 0 Tes# Tirr~e: S Hours Comt~onerrts tested 30 Repair or replacement of equipment will ~ made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with wrritten confirmation to Superviser a#: _. Remarks: The inside reel valve was tested after the coit cons-ector was installed 8 stripper were tested after the injector was picked up. The two "Check" 2 1/'f 6" valves are only used during & on pressure de lo ment wells. Distribution: 24 HOUR NOTICE GtVEN orig-Well File YES ~00C NO c- Oper./Rig Waived By Jeff Jones c- Database Date 6/9/07 Time ?????? c- Trip Rpt File Witness Bill D/James L c- Inspector Test start 16:00 Finish 21:00 Coil Tubing BFL 11/09/04 Plordic 2 BOP 6-10-Q7p.xls 1B-15 BOP Review Appreciated! ~ ~ Subject: 1B-15 BOP Review Appreciated! From: Mel Rixse <soccerctd@yahoo.com> Date: Sat, 09 Jun 2007 12:23:38 -0800 To: tom maunder@admin.state.ak.us CC: nsuadwdrlgnordic2supv@sel.bp.com ~1 -~Co``~ Tom, I, bp, and the Nordic 2 rig team sincerely appreciate your review at the hours you did. Thank you. I will have Chuck Sevcik post this email response when we are on 1 B-15A L3. Mel Rixse cc. Nordic 2 Supervisor From: Thomas E Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Fri 6/8/2007 9:32 PM To: Rixse, Mel G Cc: Rixse, Mel G; NSU, ADW Drlg Nordic 2 Supervisor Subject: Re: Request for BOP change for 16-15A L3 Mel, et al, Thanks for the explanation. It appears that there have been some subtle changes and that an older drawing was included. There is no objection to employing the "stack" without VBRs. A copy of this message should be at the rig. Call or message with any questions. Tom Maunder, PE AOGCC ----- Original Message ----- ~f 1 6/11/2007 837 AM ~ Request for BOP change for 1B-15A L3 • ~ Subject: Request for BOP change for 1B-15A L3 From: "Rixse, Mel G" <Me1.Rixse@bp.com> Date: Fri, 08 Jun 2407 19:59:57 -0800 To: "Rixse, Mel G" <Me1.Rixse@BP.com>, tom maunder@admin.sta.te.ak.us CC: "NSU, ADW Drlg Nordic 2 Supervisor" <nsuadwdrlgnordic2supv@sel.bp.com> Tom, Thanks so much for getting back to me. The BOP stack that I described in the "request for Permit to Drill" for 1 B-15A L3 was a stack that Nordic 2 was using on a prior Kuparuk campaign for Dynamically Overbalanced Drilling with CTD . That drawing showed (from top down) Bag, Blind Shears, 2" combi ram/slips, mud cross, 2-3/8" VBR, 2-3/8" pipe/slips. Nordic 2 is no longer configured to run that BOP. What I would request is approval to use the same BOP configuration we are currently running on 1C-03 which is a very similar "DOB with CTD" type well. The present configuration is shown in the attached file. The BOP configuration which we would like approval to run is (from top down) Bag, Blind Shears, 2" combi ram/slips, mud cross, 2-3/8" pipe/slip, 2" pipe/slips. We will be drilling with 2-3/8" OD BHA, 2" Coil, running 2-3/8" slotted liner, utilizing the SSSV for lubrication when possible. Nordic 2 will be moving to this well tomorrow 9-Jun-07. If you have any questions do not hesitate to call me. Thanks so much for your help in this time sensitive situation. Sincerely, Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell «BOP 1 B-15A L3.pdf» Content-Description: BOP 1B-15A L3.pdf BOP 1B-15A L3.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/11/2007 8:36 AM • • RE: BOP Diagram for 1B-15A L3 • ~ Subject: RE: BOF Diagram for 1B-15A L3 From: "Rixse, Mel G" <Me1.Rixse@bp.com> Date: Fri, 08 Jun 2007 20:12:00 -0800 To: T'homas E Maunder <tom maunder@admin.state.ak.us> Tom, I think I have answered your questions in the prior email I just sent. You are correct about using the combis instead of the VBRS and you are correct about using the rams if the SSSV does not hold. We should have the capability to use the rams if the SSSV does not hold with the proposed change to the BOP. Thanks again. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell -----Original Message----- From: Thomas E Maunder [mailto:tom maunder@admin.state.ak,us] Sent: Friday, June 08, 2007 4:59 PM To: Rixse, Mel G Subject: Re: BOP Diagram for 1B-15A L3 Mel, Could you elaborate with a bit more information. I understand that now there are combis instead of VBRs. Was the orginal drawing incorrectly attached? I seem to remember that it was metioned about using the rams for running some string if the SSSV did not hold. Is that the case? Tom Maunder, PE AOGCC ----- Original Message ----- From: °Rixse, Mel G" <Mel.uixse@bp.com> Date: Friday, June 8, 2007 4:43 pm J Subject: BOP Diagram for 1B-15A L3 To: tom maunder@admin.state.ak.us «BOP 1B-15A L3.pdf» Tom, This is slightly different from the permit. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell 1 of 1 6/11/2007 8:35 AM RE: RE: 1B-15AL3 again • • Tom, Service coil will go in at a later time and retrieve the plug. The C sand is at a higher initial pressure but is not expected to dominate as production proceeds. C sand permiability will be limited, so it is expected that production will come from all 3 laterals. I hope this helps. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell -----Original Message----- From: Thomas E Maunder [mailto:tor;1 m~un~er'~a~r:l~n.statc.ak.us] _.._..._...---------..._._.._........_ ............._......................_....._.........._...._.._..---__... _.._ Sent: Monday, June 04, 2007 6:37 PM To: Rixse, Mel G Cc: 4reve d.~vaesc~admir~.Nta~e.a.l....xs Subject: Re: RE: 1B-15AL3 again Mel, Thanks for the explanation. One further question, it is planned that the L1 and L2 penetrations will be retained by isolating with the plug. How will access to L1 and L2 be realized? It would appear that there could be a significant pressure imbalance in favor of the C sand which would prevent producing the existing laterals for some time. Thanks in advance for your comments. Tom Maunder, PE AOGCC ----- Original Message ----- From: "Rixse, Mel G" <~Iel.Rix.~c~=~b~.c~m> Date: Monday, June 4, 2007 4:42 pm Subject: RE: 1B-15AL3 again To: Thomas Maunder <ta~n maunderc~admir.sta~2.ak.:zs> Tom, Sorry for the confusion. I tried to use some average TVD's for the ', lateral, rather than TVD at the window. You are correct, there is no ; good justification for using 6I14' (from the original RKB of 95' above MSL) for a worst case condition which would be 3500 psi at the ' shallowest TVD at the window which is 6160' SSTVD. : The existing laterals into the A sand for this well will be completely pressure isolated with a plug. (We were originally going to obtain a one way standing valve but were ', unable to acquire it.} As things have now changed, we will run a plug ' and completely isolate the A sand while we are drilling. As th2 well stands today, before we run the plug, the well bore : pressure at 6450' TVD is 2163 psi. This equates to EMW of 6.45 ppg. ; When we set the plug and isolate the A sand and drill into the C sand, ' reservoir pressure could be 3500 p5i outside the window at a TVD of ', 6160' SSTVD. That is an EMW of 10.92 ppg. Maximum pressure at ' surfacewith gas (0.1 psiJft) to surface would be 3150 psi when under ' these 3saa - a i ~ ~, ~ c~~~ = a ~~~ ~~+~ 1 of 2 ~i~-~° '" l~( S' 6/5/2007 9:28 AM RE: RE: 1B-15AL3 again . • conditions. So to summarize I will use SSTVD at the window for these calculations, not original RKB or average SSTVD for the lateral. Let me know if this is satisfactory. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell -----Original Message----- From: Thomas Maunder [m~i.l.tc:~orr ma~ir:de.r.c~~at~:r:.in.vta.te.ak.us _..._._........._.._......._..._......_..... __..__ ................._.................... Sent: Monday, June 04, 2007 3:13 PM To: Rixse, Mel G Subject: Re: 1B-15AL3 again ', Me 1, ', On page 2 of your procedure under reservoir pressure an A sand BHP of ' 2163 psi at 6114' tvd and an EMW of 10.7 is given. I calculate an EMW ' of 6.8 given the pressure and depth listed. Also in the managed pressure section an estimated reservoir pressure of 3500 psi at 6114' tvd and an EMW of 10.8 are given. I calculate an EMW of nearly 11.0 with the values given. ', Would you please reconcile the different values? Also, a reply to the ' earlier message regarding the schedule would be appreciated. ' Thanks in advance. Tom Maunder, PE ' AOGCC Thomas Maunder wrote, On 6/4/2007 1:55 PM: Mel, I am reviewing this application. Approximate spud date is listed as June 15, however I understand the schedule may have moved up. Could you please give me an estimate of the possible spud for this well? Thanks in advance, Tom Maunder, PE AOGCC 2 of 2 6/5/2007 9:28 AM u ~~~ ~~ ~ ~ ~ ~~ ~ ~.~~ ~ ~~: ~,...,m.~ ~~ ..~ ~ ._~ o ~,.. ~S~i11 ~ui ~1TD r7r~-S CO1~T5ER~A~'I011T COMI~II5SIOlY Mel Rixse CT Drilling Engineer ConocoPhillips Alaska c/o PO Box 196612 Anchorage, AK 99519-6612 SARAH PALlN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 B-15AL3 ConocoPhillips Alaska Pernut No: 207-067 Surface Location: 500' FNL, 484' FEL, SEC. 09, T 11 N, R 10E, UM Bottomhole Location: 1831' FNL, 1381' FEL, SEC. 09, T11N , R10E, UM Dear Mel Ru~se: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1 B-15A, Permit No 204- 256, API 50-029-22465-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspe~a,r at (907) 659-3607 (pager). J DATED this ~day of June, 2007 ~ cc: Department of Fish 8v 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 R~~~I`~,/f~G ~f~ ~ MA'~( ~. 5 7007 ~~ Alaska Qil & G~s G~nx. Commission 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 propA~160~188 ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: 1 B-15AL3 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11250 TVD 6294ss 12. Field / Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: ,, 500' FNL T11N 484' FEL SEC 09 R10E UM ~ 7. Property Designation: ADL 025648 River Pool , , . , , , Top of Productive Horizon: 2905' FNL, 3377' FEL, SEC. 09, T11 N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 15, 2007 Total Depth: . 1831' FNL, 1381' FEL, SEC. 09, T11N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,370' 4b. Location of Well (State Base Plane Coordinates): Surtace: x-549955 y-5969647 Zone-ASP4 10. KB Elevation ~SDg•ziF • o~ (Height above~~ 95 feet 15. Distance to Nearest Well Within Pool: 1000' 16. Deviated Wells: Kickoff Depth: g224 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: ,2'F@3r ~~ ~ Surface: ,?~99~3~'s ~ 18: asin P ram: 5' ifi tio ns To - Settin ' De th - Bo tto uant' of Cemen c. r s" Hole Casin Wei ht Grade Cou lin Len th MD ND MD ND includin sta e data 3" 2-3/8" 4.6# L-80 STL 3021' 8229' 6163' 11250' 6294' Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for RedrilC and Re-entry Operations) ' Total Depth MD (ft): 8621 Total Depth ND (ft): 6607 Plugs (measured): None Effective Depth MD (ft): 8588 Effective Depth ND (ft): 6576 Junk (measured): None Gasing Length Size ement Volume MD ND Conductor / Structural 121' 16" 200 sx Arctic t I 121' 121' Surface 4190' 9-5/8" 900 sx AS III 400 sx Class 'G' 4190' 4138' Intermediate 4405' 7" 350 sx Class'G' 4405' 4324' Produc i n Liner 4116' S-1 /2" 383 sx Class 'G' 4234' - 8350' 4176' - 6361' Liner 500' 3-1/2" 55 sx Class 'G' 8121' - 8621' 6170' - 6607' L r I 1 B-15AL1 1366' 2- /8" nc men lotted Liner 8 34' - 97 0' 347' - 7' Lateral 1 B-15AL2 2637' 2-3/8" ncemented Slotted Liner 8259' - 10896' 6284' - 6537' Perforation Depth MD (ft): 1 B-15A: 8408' - 8452' L1: 8462' - 9667' & L2: 8449' - 10862' Perforation Depth ND (ft): 1 B-15A: 6412' - 6452' L1: 6439' - 6457' & L2: 6419' - 6538' 20. Attachments ^ Fiting 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 Me~ Rixse, 564-5620 Printed Name Mel Ri se Title CT Drilling Engineer ,, Prepared By Name/Number: Si nature Phone 564-5620 Date ~' -~ errie Hubble, 564-4628 Commission Use Onl ' Permit To Drill Number: Z~?'p 7 API Number: 50-029-22465-62-00 Permit Approval See cover letter for Date: ' d other re uirements Conditions ofApprovaL• If box is checked, well may not be used to explore for, test, or produce coalbed metha e, gas h ates, or gas contained shales: ~{OC7 ~~y, 3O~ ~~,~. Samples Req'd: ^ es No Mud Log Req'd: ^ Yes []'~No HZS Measures: s ' ectional Survey Req'd: ~Yes ^ No Other. '` /~ ~~ ~, ~ APPROVED BY THE COMMISSION Date CJ' , COMMISSIONER ~ ' ~'~" Form 10-401 Revised 12/2005 ~ R~ G~~ A~ ~ Submi~ DupliCate t~"'`L/' ^o ~U 1 B-15A L3 Sidetrack - Coiled Tub~ Drilling To: Thomas Maunder ~ ~ Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer 564-5620 Date: May 12, 2007 Re: 1B-15AL3 CTD Sidetrack - Application for Permit to Drill 1B-15 was drilled and completed in August 1994. The `A' sand was first completed and hydraulic fractured with 150M #'s. The `C234' sands were then perforated in October 1994. In June 1995, it was decided to perf the `C1' interval. Water cut immediately climbed from 30% to over 80%. The well sustained production of over 200 BOPD at 90% water cut until it was decided to cement squeeze the entire C interval in September 1997. The `C4' interval was then perforated and hydraulic fractured with 21.8M #'s. Post frac performance was good at over 400 BOPD, but quickly dropped off and was shut-in due to low rates in May 1999. The well briefly produced from April to August 2000 and was shut-in again. The well was returned to production June 2002 and production ranged from 30 -160 BOPD until the well was shut-in January 2005 in preparation for the sidetrack recompletion into the `A' sands. The 1B-15A well is a vertical sidetrack of the 1B-15 well producing from the `A' sand only. It was sidetracked in early 2005 in an attempt to improve the wells performance. Problems with the primary cement job on the 3- 1/2" liner delayed the initial production until a remedial cement job could be performed. The liner was successfully cemented in March 2005 and following an unsuccessful attempt in Apri12005 to produce the well unstimulated it was brought on production at a post frac rate of approximately 750BOPD and has since declined to about 425BOPD with a watercut of 4%. While the 1B-15A AFC did not include the follow-up CTD program in its scope, the team was aware that `C34' reserves were being bypassed, and planned the current well with the idea of returning to re-access the `C34' sand in the original 1B-15 location as well as the `A' sand target to the east. The 1B-15A L1 & L2 were drilled during the 2005 GKA CTD program to access bypassed and unswept `A' sand reserves to the east and west, and accelerate `A' sand oil production into field life. This project was Phase 1 of the original AFC. It should be noted that the lateral to the west was added at FEL2 as a direct result of the success at 1B-13, which is directly to the north and was at the time producing 1200 - 1500 BOPD. Summarv of Ouerations: A coiled tubing drilling unit will drill a lateral in KRU 1B-15A L3 using the managed pressure drilling technique ~ (MPD, see description below). The horizontal lateral will target Kuparuk C sand reserves for production. Positive pressure isolation, from this proposed lateral to the two existing A sand laterals, will be maintained by utilizing a retrievable standing valve while drilling. CTD Drill and Complete 1b-15A L3: Planned for June 15, 2007 Pre-Rig Work 1. O PT Master & Swab to 4000 psi. Drawdown test MV, SV, & SSSV to 0 psi. 2. O Load IA w SW/diesel freeze protect. 3. S Dummy GLVs. 4. O POT - T, PPPOT - Tubing, POT - IC, PPPOT-IC. 5. O MIT - OA 6. S Drawdown test and drift SSSV. 7. S Drift & tag with 2.745" drift to top of 2-3/8" liner @ 8258' md. 8. E Log EMTT tool from 8258' md to 8100' md to identify CCs. ~U 16-15A L3 Sidetrack - Coiled Tub~ Drilling 9. E Run 2.74" dummy whipstock drift to 8258'. 10. E Set Baker whipstock/KB packer (with standing valve) @ 8224' md. Orient tray 0° - 20° left of high side. Leave well SI. 11. O MIT IA to 2500 psi 12. S Obtain Gsand SBHP after 3 day shut in. 13. O Torque wellhead bolts. Set BPV 14. O Bleed GL and flowlines to zero, blind flange, remove wellhouse, level pad, drill mouse hole, Install SSSV panel (after rig MIRU). Rig Work 1. MIRU Nordic #2. NU 7-1/16" BOPE, test , 2. Mi112.74" window off a whipstock. The planned KOP is at 8224' in the C sand. 3. Dri113" bicenter hole horizontal lateral from window to 11,250' TD targeting Kuparuk C sands. 4. Complete with a 2 segmented 2 3/8" solid/slotted liner from TD to ~8229' md. Use SSSV for liner run. 5. Retrieve whipstock tray. 6. ND BOPE. RDMO Nordic 2. - Post Rig work 1. Post CTD rig -Run GLVs. Mud Program: • Will use chloride-based Biozan brine (9.4 ppg) for milling operations, and chloride-based Flo-Pro mud (9.2 " ppg) for drilling operations. Disposal: • No annular injection on this well. - • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1B-15A L3: 2-3/8", 4.6#, L-80, STL 0 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing) with blanks across B-shale and across faults in L3. Top of liner placed 5'-10' outside window. Casin~/Liner Information 9 5/8", L-80, 40#, Burst 5750; collapse 3090 psi. 7", L-80, 26#, Burst 6600, collapse 5410 5-1/2", L-80, 26#, Burst 7240; collapse 4990 psi 3-1/2", L-80, 9.3#, Burst 10,160; collapse 10,530 psi Well Control: • Two well bore volumes (~200 bbls) of KWF will be on location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1B-15A L3 s • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1B-15A L3 is 1B-O1 which is 1200 ft. away. It is 1000 ft to 1B-04 and 200 ft to well 1B-15 (abandoned old location, recently sidetracked)~ • Distance to the nearest property line is 21,370 ft. (measured at closest point). ~ ~U 1 B-15A L3 Sidetrack - Coiled Tubing Drilling Logging . • MWD directional and Gamma Ray will be run over all of the open hole section. Hazards • 1B-15A L3 lateral will cross 6 mapped faults. Plugbacks because of uncertain throw is a possibility. • KRU 1B pad is considered an H2S pad. The closest SHL to 1B-15 is 1B-OSi and has an H2S level of 110 ppm H2S. All H2S monitoring equipment will be operational. .-- ,~~,~n / ~Cc. ~.~c.i~, ~ ' ~' `! \., ~_~..~ ..w.,b ``~, Reservoir essure ~---~ ° • T most recent SBHP survey (03-16-06) was g at 2163 psi in the A sand. The EMW is 10.7 114' TVD. Max. surface pressure with gas (0.1 psi/ft) ace is 2799 psi. Variance request V~~~G~~c~ `~ ~eE~ C.~ f S~c~ o~'~.5t~~ ia ~a~s~~ ~~1-~4 (~ • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 1B-15 it will be routine to close the 2-3/8" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 9.2 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stabilitv. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses andlor fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. This well has a tubing retrievable sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. However, it is still possible that deployment of the BHA under trapped wellhead pressure would be necessary. Pressure deployxnent of the BHA will be accomplished utilizing the BOP pipe/slips (2- 3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 1B-15A L3 TD: • Estimated reservoir pressure: 3500 psi at 6114' TVD, 10.8 ppg EMW. / • Expected annular friction losses while circulating: 740 psi at KOP and 1012 psi at TD (assuming 90 psi/ft, for a 3026' lateraL • Planned mud density: 9.2 ppg equates to 2992 psi hydrostatic bottom hole pressure. • While circulating 9.2 ppg fluid, bottom hole circulating pressure is estimated to be 4483 psi or 13.8 ppg ECD • When circulation is stopped, a minimum of 750 psi surface pressure will be applied to maintain ~~~ nt BHP. Mel Rixse CTD Engineer 564-5620 CC: Well File Sondra Stewman/Terrie Hubble KRU 1 B-15A L3 C-sand Lateral Proposed CTD Completion, WP09 3-1/2" Camco TRM-5E SSSV, 2.812" min ID at 1483' MD 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing s-~a~~ ao# 3-%" Camco KBUG-M GLMs @ 2633', 3905' MD ~-so @ a~so~ 5-'/z" x 7" Baker CPH Packer w/SBE @ 4241' MD r~ 2s# ~-so ~ aaos~ Mo 3-'/2' Camco KBG-2-9 GLM @ 5094', 6979', & 7823' MD / 8208' - 8218' L3 KOP 8224' MD Retrievable Baker KB Packer/V1/hipstock/ standing valve (to be pulled after completing L3 leg) , ConocoPhilli s p Alaska, Inc. 3-'/z' Baker SABL3 packer @ 7890' MD 3-'/z' HES "X" nipple, 2.75" min ID @ 8033' MD (May require milling out to 2.80" to accommodate 2.78" Baker KB packer/WS) Poor Boy Overshot @ 8078' MD , ~._.3-%" Baker ZXP liner top packer @ 8140' MD 2-3/8" blank liner across B siltstone , to fault L2 liner top @ 8259' md L2 KOP 8289' MD Fault @ ~ 8950' MD i hz5 e~~:~-~- 2-318" slotted liner liner ~ 1 B-15A L3 Later~ TD @ 11250' md 1 B-15A L2 L-ateral,~ ~B-~"'fa896' md 3" openhole LSX WS (flowthru) L1 KOP 8340' MD queeze perfs 8305' - 8307' san pe ~ 8408' - 8417', ~ 8432' - 8452' ~ '/z' 15.5# L80 Hyi 511 @ 8350' md 3-112" 9.3# L-80 2-3/8" slotted liner 3" openhole 1 B-15A L1, TD @ 9700' md 05-14-07 DEV ~ • ~ bp ~ BP Alaska Baker Hughes INTEQ Planning Report ~.r s ~ ~$ 1NTEQ Company: BP Amoco Date: 5/8/2007 Time: 10:53:17 Page: 1 Field: Kuparuk Co-ordinate(NE) Reference: WeII: 15, True North Site: KRU 1 B Pad Verdcal (TVD) Referencec RKB Elev 3 95A ' Well: 15 Secuon (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Welipath: Plan 9, 16-15AL3 Survey Calculauon Method: Minimum Curvature Db: Oracle Fieid: Kuparuk 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: bggm2006 Site: KRU 1 B Pad Site Position: Northing: 5969646.72 ft Latitude: 70 19 40.290 N From: Map Easting: 549457 .40 ft Longitude: 149 35 56.056 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.38 deg We11: 15 Slot Name: Well Position: +N/-S -2.95 ft Northing: 5969647 .05 ft Latitude: 70 19 40261 N +E/-W 497.82 ft Easting : 549955 .18 ft Longitude: 149 35 41.524 W Position Uncertainty: 0.00 ft Wellpath: PIBn 9, 1 B-15AL3 Drilled From: 1 B-15A Tie-on Depth: 8175.52 ft Current Datum: RKB E~ev 3 Height 95 .00 ft ~ Above System Datum: Mean Sea Level - Magnetic Data: 5/7/2007 Declination: 23.52 deg Eield Strength: 57623 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.70 0.00 0.00 45.00 Plan: Plan #9 Date Composed: 5/7/2007 Version: 9 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +F/-W Northing EasHng Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 18-15AL3 Polygon 95.00 -2826.93 -2471.30 5966804.00 547503.00 70 19 12.454 N 149 36 53.640 W -Polygon 1 95.00 -2826.93 -2471.30 5966804.00 547503.00 70 19 12.454 N 149 36 53.640 W -Polygon 2 95.00 -2760.29 -2115.81 5966873.00 547858.00 70 19 13.110 N 149 36 43.267 W -Polygon 3 95.00 -2584.12 -1687.59 5967052.00 548285.00 70 19 14.844 N 149 36 30.772 W -Polygon 4 95.00 -2518.23 -1370.11 5967120.00 548602.00 70 19 15.493 N 149 36 21.507 W -Polygon 5 95.00 -1971.29 -1050.43 5967669.00 548918.00 70 19 20.872 N 149 36 12.180 W -Polygon 6 95.00 -1698.63 -844.59 5967943.00 549122.00 70 19 23.554 N 149 36 6.174 W -Polygon 7 95.00 -1386.61 -842.51 5968255.00 549122.00 70 19 26.623 N 149 36 6.114 W -Polygon 8 95.00 -1250.76 -966.62 5968390.00 548997.00 70 19 27.959 N 149 36 9.737 W -Polygon 9 95.00 -1497.45 -1018.27 5968143.00 548947.00 70 19 25.533 N 149 36 11.244 W -Polygon 10 95.00 -1769.28 -1349.12 5967869.00 548618.00 70 19 22.859 N 149 36 20.899 W -Polygon 11 95.00 -2266.21 -1668.47 5967370.00 548302.00 70 19 17.971 N 149 36 30216 W -Polygon 12 95.00 -2382.78 -1886.27 5967252.00 548085.00 70 19 16.824 N 149 36 36.571 W -Polygon 13 95.00 -2460.27 -2113.81 5967173.00 547858.00 70 19 16.061 N 149 36 43211 W -Polygon 14 95.00 -2526.91 -2469.30 5967104.00 547503.00 70 19 15.405 N 149 36 53.585 W 1B-15AL3 Fault 1 95.00 -2940.76 -2499.06 5966690.00 547476.00 70 19 11.334 N 149 36 54.449 W -Polygon 1 95.00 -2940.76 -2499.06 5966690.00 547476.00 70 19 11.334 N 149 36 54.449 W -Polygon 2 95.00 -2690.74 -2497.39 5966940.00 547476.00 70 19 13.793 N 149 36 54.403 W -Polygon 3 95.00 -2440.72 -2495.73 5967190.00 547476.00 70 19 16.252 N 149 36 54.357 W 1B-15AL3 Fault 2 95.00 -2865.85 -2184.52 5966767.00 547790.00 70 19 12.072 N 149 36 45.271 W -Polygon 1 95.00 -2865.85 -2184.52 5966767.00 547790.00 70 19 12.072 N 149 36 45.271 W -Polygon 2 95.00 -2615.83 -2182.86 5967017.00 547790.00 70 19 14.531 N 149 36 45.225 W -Polygon 3 95.00 -2365.81 -218i.19 5967267.00 547790.00 70 19 16.990 N 149 36 45.178 W 1 B-15AL3 Fault 4 95.00 -2208.29 -1655.08 5967428.00 548315.00 70 19 18.540 N 149 36 29.826 W -Polygon 1 95.00 -220829 -1655.08 5967428.00 548315.00 70 19 18.540 N 149 36 29.826 W ~ bp ~ ~ BP Alaska - Baker Hughes INTEQ Planning Report ~i~~ saiaR-Q _. - - --.~ Targets Name Description Dip. Dir -Polygon 2 -Polygon 3 1 B-15AL3 Fault 6 -Polygon 1 -Polygon 2 -Polygon 3 1 B-15AL3 Fault 5 -Polygon 1 -Polygon 2 -Polygon 3 1 B-15AL3 Fault 3 -Polygon 1 -Polygon 2 -Polygon 3 1 B-15AL3 Target 2 1 B-15AL3 Target 1 1 B-15AL3 Target 4 1 B-15AL3 Target 5 16-15AL3 Target 3 1 B-15AL3 Target 6 1 B-15AL3 Target 7 TVD ft 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 95.00 6320.00 6324.00 6336.00 6355.00 6356.00 6370.00 6382.00 +N/-S ft +FJ-W ft Map Northing ft Map Easting ft -2259.96 -1405.39 5967378.00 548565.00 -2311.63 -1155.71 5967328.00 548815.00 -1821.81 -1270.46 5967817.00 548697.00 -1821.81 -1270.46 5967817.00 548697.00 -1698.46 -1019.61 5967942.00 548947.00 -1575.12 -768.76 5968067.00 549197.00 -1630.48 -1467.21 5968007.00 548499.00 -1630.48 -1467.21 5968007.00 548499.00 -1882.16 -1218.86 5967757.00 548749.00 -2133.84 -970.50 5967507.00 548999.00 -2452.48 -2081.76 5967181.00 547890.00 -2452.48 -2081.76 5967181.00 547890.00 -2504.15 -1832.07 5967131.00 548140.00 -2555.82 -t582.39 5967081.00 548390.0~ -2610.28 -2114.81 5967023.00 547858.00 -2676.92 -2470.30 -2367.22 -1519.12 -187029 -1199.78 -2483.45 -1786.93 -1598.12 -918.93 -1351.10 -917.29 5966954.00 547503.00 5967270.00 548452.00 5967769.00 548768.00 5967152.00 548185.00 5968043.00 549047.00 5968290.00 549047.00 <---- Latitude -•--> Deg Min Sec <--- Longitude ---> Deg Min Sec 70 19 18.033 N 149 36 22.538 W 70 19 17.525 N 149 36 15251 W 70 19 22.342 N 149 36 18.603 W 70 19 22.342 N 149 36 18.603 W 70 19 23.556 N 149 36 11.282 W 70 19 24.769 N 149 36 3.961 W 70 19 24.224 N 149 36 24.346 W 70 19 24.224 N 149 36 24.346 W 70 19 21.749 N 149 36 17.096 W 70 19 19.274 N 149 36 9.847 W 70 19 16.138 N 149 36 42.276 W 70 19 16.138 N 149 36 42.276 W 70 19 15.630 N 149 36 34.989 W 70 9 9 15.123 N 149 36 27.702 W 70 19 14.586 N 149 36 43.239 W 70 19 13.929 N 149 36 53.612 W 70 19 16.978 N 149 36 25.857 W 70 19 21.866 N 149 36 16.539 W 70 19 15.834 N 149 36 33.671 W 70 19 24.543 N 149 36 8.344 W 70 19 26.972 N 149 36 8.297 W Annotation MD ft TVD ft 8175.52 6214.10 TIP (Tie to 1 B-15A) 8224.00 6254.18 KOP 8244.00 6270.71 End of 9 Deg/100' DLS 8368.42 6326.64 4 8568.42 6328.86 End of 45 Deg/100' DLS 8950.00 6330.58 Fault Intersection 8968.42 6330.58 6 9068.42 6329.89 7 9268.42 6327.38 8 9275.00 6327.30 Fauit IntersecNon 9343.42 6326.95 9 9468.42 6328.44 10 9588.42 6346.18 11 9650.00 6359.01 Fault Intersection 9688.42 6363.04 12 9763.42 6362.03 13 9828.42 6356.07 14 9928.42 6347.03 15 10003.42 6343.30 i 6 10150.00 6345.33 Fault Intersection 10153.42 6345.47 17 10353.42 6353.35 18 10575.00 6361.67 Fault Intersection 10598.42 6362.47 19 10728.42 6366.83 20 10850.00 637129 Fault Intersection ~ ~ ~ bp ~ BP Alaska Baker Hughes INTEQ Planning Report ~.r B ~i~s 1NTEQ Company: BP Amoco Date: 5/S/2007 Time: 10:53:17 Page: 3 Field: Kuparuk Co-ordinate(NE) Reference: W ell: 15, True North Site: KRU 1 B Pad Vertical (TVD) Reference: RKB Elev 3 95.0 Well: 1 5 Section (VS} Reference: WeN (O.OON,O. OOE,45.OOAzi) WellpatNo Plan 9, 1 B-15AL3 Survey CalcWation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 10968.42 6376.40 21 11250.00 6389.17 TD Plan Section Information MD Incl Azim TVD +N/S +FJ-W DLS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/100ft deg/100ft deg 8175.52 35.11 233.59 6214.10 -2325.48 -2783.89 0.00 0.00 0.00 0.00 8224.00 33.36 232.68 6254.18 -2341.84 -2805.71 3.76 -3,61 -1.88 195.93 8244.00 35.16 232.68 6270.71 -2348.67 -2814.66 9.00 9,00 0.00 0.00 8368.42 89.50 216.21 6326.64 -2426.91 -2885.64 45.00 43.67 -13.24 340.00 8568.42 89.50 126.21 6328.86 -2604.84 -2858.12 45.00 0.00 -45.00 269.50 8968.42 90.04 78.21 6330.58 -2686.96 -2478.50 12.00 0.13 -12.00 270.50 9068.42 90.74 66.23 6329.89 -2656.48 -2383.45 12.00 0.71 -11.98 273.40 9268.42 90:68 90.23 6327.38 -2615.98 -2189.10 12.00 -0.03 12.00 90.00 9343.42 89.97 81.26 6326.95 -2610.42 -2114.39 12.00 -0.95 -11.96 265.50 9468.42 88.68 66.31 6328.44 -2575.61 -1994.71 12.00 -1.03 -11.96 265.00 9588.42 74.28 66.31 6346.18 -2528.06 -1886.32 12.00 -12.00 0.00 180.00 9688.42 86.28 66.31 6363.04 -2488.53 -i79623 12.00 12.00 D.00 0.00 9763.42 9528 66.31 6362.03 -2458.44 -1727.62 12.00 12.00 0.00 0.00 9828.42 95.23 74.14 6356.07 -2436.56 -1666.76 12.00 -0.08 12.05 90.00 9928.42 95.11 62.10 6347.03 -2399.51 -1574.51 12.00 -0.11 -12.05 270.00 10003.42 90.58 54.31 6343.30 -2360.08 -1510.92 12.00 -6.04 -10.38 240.00 10153.42 87.78 36.52 6345.47 -2255.23 -1404.53 12.00 -1.87 -11.86 261.00 10353.42 87.77 12.51 6353.35 -2074.73 -1322.21 12.00 -0.01 -12.01 269.50 10598.42 88.06 41.92 6362.47 -1859.40 -1211.46 12.00 0.12 12.01 90.00 10728.42 88.13 57.53 6366.83 -1775.67 -1112.63 12.00 0.06 12.01 90.00 10968.42 87.40 28.72 6376.40 -1602.50 -950.41 12.00 -0.30 -12.01 268.00 11250.00 87.56 354.90 6389.17 -1331.14 -893.68 12.00 4.06 -12.01 269.50 Survey MD Incl Azim SS TVD N/S EJW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/t00ft ft deg 8175.52 35.11 233.59 6119.10 -2325.48 -2783.89 5967303.31 547187.11 0.00 -3612.87 0.00 MW D 8200.00 34.23 233.14 6139.24 -2333.79 -2795.06 5967294.93 547175.99 3.76 -3626.65 195.93 MW D 8224.00 33.36 232.68 6159.18 -2341.84 -2805.71 5967286.81 547165.40 3.76 -3639.87 196.30 MW D 8225.00 33.45 232.68 6160.02 -2342.18 -2806.15 5967286.47 547164.96 9.00 -3640.41 360.00 MW D 8244.00 35.16 232.68 6175.71 -2348.67 -2814.66 5967279.92 547156.49 9.00 -3651.03 0.00 MW D 8250.00 37.71 231.17 6180.54 -2350.87 -2817.47 5967277.71 547153.70 45.00 -3654.56 340.00 MW D 8275.00 48.47 226.36 6198.77 -2362.15 -2830.23 5967266.33 547141.01 45.00 -3671.57 34121 MW D 8300.00 59.38 222.94 6213.47 -2376.53 -2844.38 5967251.86 547126.96 45.00 -3691.74 344.75 MW D 8325.00 70.36 220.22 6224.08 -2393.45 -2859.36 5967234.85 5471 i 2. i 0 45.00 -3714.30 346.77 MW D 8350.00 81.37 217.86 6230.17 -241226 -2874.59 5967215.94 547096.99 45.00 -3738.37 347.93 MW D 8368.42 89.50 21621 6231.64 -2426.91 -2885.64 596720122 547086.04 45.00 -3756.54 348.51 MW D 8375.00 89.47 213.25 6231.69 -2432.31 -2889.39 5967195.79 547082.33 45.00 -3763.01 269.50 MW D 8400.00 89.39 202.00 6231.94 -2454.43 -2900.96 5967173.60 547070.91 45.00 -3786.83 269.53 MW D 8425.00 89.33 190.75 6232.22 -2478.37 -2908.00 5967149.61 547064.03 45.00 -3808.74 269.64 MW D 8450.00 89.30 179.50 6232.52 -250323 -2910.23 5967124.74 547061.97 45.00 -3827.89 269.76 MW D 8475.00 8929 168.25 6232.83 -2528,05 -2907.56 5967099.95 547064.80 45.00 -3843.56 269.90 MW D 8500.00 89.31 157.00 6233.13 -2551.87 -2900.11 5967076.18 547072.41 45.00 -3855.13 270.04 MWD 8525.00 89.36 145.75 6233.42 -2573.77 -2888.15 5967054.36 547084.51 45.00 -3862.16 270.17 MW D 8550.00 89.43 134.49 6233.69 -2592.93 -2872.14 5967035.31 547100.64 45.00 -3864.39 270.30 MW D 8568.42 89.50 126.21 6233.86 -2604.84 -2858.12 5967023.49 547114.74 45.00 -3862.90 270.42 MW D 8575.00 89.51 125.42 6233.91 -2608.69 -2852.78 5967019.68 547120.10 12.00 -3861.85 270.50 MWD 8600.00 89.53 122.42 6234.12 -2622.64 -2832.04 5967005,87 547140.94 12.00 -3857.04 270.51 MW D 8625.00 89.56 119.42 6234.32 -2635.48 -2810.60 5966993.17 547162.47 12.00 -3850.96 270.53 MW D 8650.00 89.59 116.42 6234.51 -2647.18 -2788.51 5966981.62 547184.63 12.00 -3843.61 270.56 MW D 8675.00 89.62 113.42 6234.68 -2657.71 -2765.84 5966971.24 547207.37 12.00 -3835.03 270.58 MWD ~ i ~ bp BP Alaska Baker Hughes INTEQ Planning Report ~.. ~s iNTEQ Company: BP Amoco Date: 5/8/2007 Time: 10:53:17 Page: 4 Field: Kuparuk Co-ordinate(NE) Reference: W ell: 15, True Nortfi Site: KRU 1 B Pad Vertical (TVD) Reference: RKB Elev 3 95A Well: 15 Section (VS) Reference: W ell (O.OON,O.OO E,45.OOAzi) Wellpath: Plan 9, 1 B-15AL3 Survey Ca1cWaNon Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S FJW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 8700.00 89.65 110.42 6234.83 -2667.04 -2742.65 5966962.06 547230.62 12.00 -382523 270.60 MW D 8725.00 89.69 107.42 6234.98 -2675.15 -2719.00 5966954.12 547254.31 12.00 -381424 270.62 MW D 8750.00 89.72 104.42 6235.11 -2682.00 -2694.96 5966947.43 547278.40 12.00 -3802.09 270.63 MWD 8775.00 89.76 101.42 6235.22 -2687.59 -2670.60 5966942.00 547302.79 12.00 3788.81 2~0.65 MW D 8800.00 89.79 98.42 6235.32 -2691.89 -2645.97 5966937.86 547327.44 12.00 -3774.44 270.66 MW D 8825.00 89.83 95.42 6235.40 -2694.90 -2621.16 5966935.02 547352.28 12.00 -3759.02 270.68 MW D 8850.00 89.86 92.42 6235.47 -2696.61 -2596.22 5966933.47 547377.22 12.00 -3742.60 270.69 MWD 8875.00 89.90 89.42 6235.52 -2697.01 -2571.23 5966933.24 547402.22 12.00 -3725.21 270.69 MW D 8900.00 89.94 86.42 6235.56 -2696.10 -254625 5966934.32 547427.19 12.00 -3706.90 270.70 MWD 8925.00 89.97 83.42 6235.58 -2693.89 -2521.35 5966936.70 547452.07 12.00 -3687.73 270.70 MW D 8950.00 90.01 80.42 6235.58 -2690.37 -2496.60 5966940.37 547476.79 12.00 -3667.74 270.71 MW D 8968.42 90.04 78.21 6235.58 -2686.96 -2478.50 5966943.91 547494.87 12.00 -3652.53 270.71 MW D 8975.00 90.08 77.42 6235.57 -2685.57 -2472.07 5966945.34 54750129 12.00 -3647.00 273.40 MW D 9000.00 90.26 74.42 6235.49 -2679.49 -2447.82 5966951.58 547525.49 12.00 -3625.56 273.40 MWD 9025.00 90.44 71.43 6235.34 -2672.15 -2423.93 5966959.08 547549.33 12.00 -3603.47 273.39 MWD 9050.00 90.61 68.43 6235.11 -2663.57 -2400.45 5966967.81 547572.75 12.00 -3580.80 273.37 MW D 9068.42 90.74 6623 6234.89 -2656.48 -2383.45 5966975.02 547589.70 12.00 -3563.77 273.34 MW D 9075.00 90.74 67.02 6234.81 -2653.87 -2377.41 5966977.67 547595.72 12.00 -3557.65 90.00 MW D 9100.00 90.74 70.02 6234.48 -2644.71 -2354.15 5966986.98 547618.91 12.00 -3534.73 90.01 MW D 9125.00 90.74 73.02 6234.16 -2636.79 -2330.45 5966995.06 547642.56 12.00 -3512.37 90.05 MWO 9150.00 90.73 76.02 6233.84 -2630.12 -2306.36 5967001.89 547666.61 12.00 -3490.62 90.09 MW D 9175.00 90.72 79.02 6233.52 -2624.71 -2281.96 5967007.46 547690.97 12.00 -3469.54 90.13 MW D 9200.00 90.71 82.02 6233.21 -2620.60 -2257.30 5967011.74 547715.59 12.00 -3449.20 90.16 MW D 9225.00 90.70 85.02 6232.90 -2617.78 -2232.47 5967014.72 547740.41 12.00 -3429.64 90.20 MWD 9250.00 90.69 88.02 6232.60 -261626 -2207.52 5967016.41 547765.34 12.00 -3410.92 90.24 MW D 9268.42 90.68 90.23 6232.38 -2615.98 -2189.10 5967016.81 547783.76 12.00 -3397.70 90.28 MW D 9275.00 90.62 89.44 6232.30 -2615.96 -2182.52 5967016.87 547790.33 12.00 -3393.04 265.50 MW D 9300.00 90.38 86.45 6232.08 -2615.06 -2157.54 5967017.94 547815.31 12.00 -3374.74 265.49 MWD 9325.00 90.14 83.46 6231.97 -2612.86 -2132.64 5967020.30 547840.19 12.00 -3355.58 265.47 MWD 9343.42 89.97 81.26 6231.95 -2610.42 -2114.39 5967022.87 547858.43 12.00 -3340.94 265.45 MW D 9350.00 89.90 80.47 6231.96 -2609.37 -2107.89 5967023.96 547864.91 12.00 -3335.61 265.00 MW D 9375.00 89.64 77.48 6232.06 -2604.59 -2083.35 5967028.90 547889.41 12.00 -3314.88 265.00 MW D 9400.00 89.38 74.49 6232.28 -2598.54 -2059.10 5967035.11 547913.62 12.00 -3293.45 265.01 MWD 9425.00 89.12 71.50 6232.60 -2591.23 -2035.20 5967042.58 547937.47 12.00 -3271.38 265.04 MW D 9450.00 88.86 68.52 6233.05 -2582.69 -2011.71 5967051.28 547960.90 12.00 -3248.73 265.08 MW 0 9468.42 88.68 66.31 6233.44 -2575.61 -1994.71 5967058.46 547977.86 12.00 -3231.71 265.13 MW D 9475.00 87.89 66.31 6233.64 -2572.97 -1988.69 5967061.15 547983.86 12.00 -3225.58 180.00 MWD 9500.00 84.89 66.31 6235.21 -2562.95 -1965.84 5967071.32 548006.64 12.00 -3202.34 180.00 MW D 9525.00 81.89 66.31 6238.09 -2552.97 -1943.10 5967081.45 548029.31 12.00 -3179.21 180.00 MW D 9543.17 79.71 66.31 6241.00 -2545.77 -1926.68 5967088.76 548045.68 12.00 -3162.49 180.00 1 B-15A 9550.00 78.89 66.31 624227 -2543.07 -1920.53 5967091.50 548051.81 12.00 -3156.24 180.00 MWD 9575.00 75.89 66.31 6247.73 -2533.2~ -1898.19 5967101.44 548074.08 12.00 -3133.52 180.00 MW D 9588.42 7428 66.31 6251.18 -2528.06 -1886.32 5967106.73 548085.92 12.00 -3121.44 180.00 MW D 9600.00 75.66 66.31 6254.18 -2523.57 -1876.08 5967111.29 548096.13 12.00 -3111.02 0.00 MWD 9625.00 78.66 66.31 6259.74 -2513.78 -1853.76 5967121.23 548118.38 12.00 -3088.31 0.00 MW D 9650.00 81.66 66.31 6264.01 -2503.88 -183121 5967131.28 548140.86 12.00 -3065.37 0.00 MW D 9675.00 84.66 66.31 6266.98 -2493.91 -1808.48 5967141.40 548163.52 12.00 -3042.25 0.00 MW D 9688.42 86.28 66.31 6268.04 -2488.53 -1796.23 5967146.85 548175.74 12.00 -3029.78 0.00 MW D 9700.00 87.66 66.31 6268.65 -2483.89 -1785.64 5967151.57 548186.29 12.00 -3019.01 0.00 MW D 9725.00 90.66 66.31 6269.02 -2473.85 -1762.75 5967161.76 548209.11 12.00 -2995.73 0.00 MW D 9750.00 93.66 66.31 6268.07 -2463.81 -1739.87 5967171.95 548231.92 12.00 -2972.45 0.00 MW D 9763.42 95.28 66.31 6267.03 -2458.44 -1727.62 5967177.41 548244.13 12.00 -2959.99 0.00 MWD 9775.00 95.27 67.71 6265.96 -2453.93 -1717.01 5967181.98 548254.71 12.00 -2949.30 90.00 MWD ~ ~ ~ bp ~ BP Alaska Baker Hughes INTEQ Planning Report ~t~ ~c~s 1NTEQ Company: BP Amoco Date: 5/8/2007 Timep 10:53:17 Page:' S Field: Kuparuk Co-ordinate(NE) Reference: Well: 15, True North Site: KRU 16 Pad Vertical (TVD) Reference: RKB Elev 3 95A Well: 15 Section (VS) Reference: W eil (O.OON,O.OOE,45.OOAzi} Welipath: Plan 9, 1 B-15AL3 Survey Calculauon Method: Minimum Curvature Dbi Oracle Survey MD Incl Azim SS TVD N/S FJW MapN MapE DLS VS TFO Tuol ft deg deg ft ft ft ft ft deg/100ft ft deg 9800.00 95.26 70.72 6263.67 -2445.10 -1693.74 5967190.97 548277.92 12.00 -2926.60 90.13 MW D 9825.00 95.23 73.73 6261.38 -2437.50 -1670.03 5967198.72 548301.58 12.00 -2904.46 90.40 MWD 9828.42 95.23 74.14 6261.07 -2436.56 -1666.76 5967199.69 548304.84 12.00 -2901.48 90.68 MWD 9850.00 9522 71.54 6259.11 -2430.22 -1646.23 5967206.16 548325.33 12.00 -2882.48 270.00 MWD 9875.00 95.20 68.53 6256.83 -2421.72 -1622.83 5967214.81 548348.67 12.00 -2859.93 269.76 MWD 9900.00 95.17 65.52 6254.57 -2412.01 -1599.91 5967224.68 548371.52 12.00 -2836.85 269.49 MW D 9925.00 95.12 62.51 6252.33 -2401.10 -1577.53 5967235.74 548393.83 12.00 -2813.31 269.22 MW D 9928.42 95.11 62.10 6252.03 -2399.51 -1574.51 5967237.34 548396.83 12.00 -2810.06 268.95 MWD 9950.00 93.81 59.85 6250.35 -2389.07 -1555.70 5967247.90 548415.57 12.00 -2789.38 240.00 MWD 9975.00 92.30 57.25 6249.01 -2376.05 -1534.41 5967261.07 548436.77 12.00 -2765.11 239.83 MW D 10000.00 90.79 54.66 6248.34 -2362.06 -1513.70 5967275.19 548457.38 12.00 -2740.58 239.69 MW D 10003.42 90.58 54.31 6248.30 -2360.08 -1510.92 5967277.20 548460.16 12.00 -2737.21 239.62 MW D 10025.00 90.17 51.75 6248.16 -2347.10 -1493.68 5967290.29 548477.31 12.00 -2715.84 261.00 MW D 10050.00 89.70 48.79 6248.19 -2331.12 -1474.45 5967306.39 548496.42 12.00 -2690.95 260,98 MW D 10075.00 89.23 45.83 6248.42 -2314.17 -1456.08 5967323.46 548514.68 12.00 -2665.97 260.99 MW D 10100.00 88.77 42.86 6248.85 4296.30 -1438.61 5967341.45 548532.03 12.00 -2640.98 261.01 MW D f 0125.00 88.30 39.90 6249.49 -2277.55 -1422.09 5967360.31 548548.42 12.00 -2616.04 261.07 MW D 10150.00 87.84 36.93 6250.33 -2257.97 -1406.57 5967379.98 548563.81 12.00 -2591.22 261.14 MW D 10153.42 87.78 36.52 6250.47 -2255.23 -1404.53 5967382.73 548565.84 12.00 -2587.84 261.24 MW D 10175.00 87.76 33.93 6251.30 -2237.62 -1392.09 5967400.43 548578.15 12.00 -2566.59 269.50 MW D 10200.00 87.74 30.93 625229 -2216.54 -1378.69 5967421.60 548591.41 12.00 -2542.21 269.60 MWD 10225.00 87.73 27.93 6253.27 -2194.79 -1366.42 5967443.43 548603.53 12.00 -2518.15 269.72 MWO 10250.00 87.73 24.93 6254.27 -2172.42 -1355.30 5967465.87 548614.50 12.00 -2494.48 269.84 MW D 10275.00 87.73 21.92 6255.26 -2149.50 -1345.37 5967488.85 548624.28 12.00 -2471.25 269.96 MW D 10300.00 87.73 18.92 625625 -2126.09 -1336.66 5967512.31 548632.84 12.00 -2448.53 270.08 MWD 10325.00 87.75 15.92 6257.23 -2102.26 -1329.18 5967536.19 548640.15 12.00 -2426.39 270.19 MW D 10350.00 87.77 12.92 6258.21 -2078.07 -1322.96 5967560.42 548646.21 12.00 -2404.89 270.31 MW D 10353.42 87.77 12.51 6258.35 -2074.73 -1322.21 5967563.76 548646.94 12.00 -2402.00 270.43 MW D 10375.00 87.77 15.10 6259.19 -2053.80 -1317.06 5967584.73 548651.95 12.00 -2383.56 90.00 MW D 10400.00 87.78 18.10 6260.16 -2029.86 -1309.93 5967608.71 548658.92 12.00 -2361.59 89.90 MW D 10425.00 87.79 21.10 6261.12 -2006.33 -1301.55 5967632.30 548667.14 12.00 -2339.02 89.78 MW D 10450.00 87.81 24.10 6262.08 -198327 -1291.95 5967655.42 548676.59 12.00 -2315.93 89.67 MWD 10475.00 87.84 27.11 6263.03 -1960.74 -1281.15 5967678.01 54868723 12.00 -2292.37 89.55 MW D 10500.00 87.87 30.11 6263.96 -1938.81 -1269.19 5967700.02 548699.05 12.00 -2268.40 89.44 MWD 10525.00 87.91 33.11 6264.88 -1917.54 -1256.10 5967721.38 548712.00 12.00 -2244.10 89.33 MW D 10550.00 87.96 36.11 6265.79 -1896.98 -1241.91 5967742.03 548726.05 12.00 -2219.53 89.22 MW D 10575.00 88.00 39.11 6266.67 -1877.19 -1226.66 5967761.92 548741.16 12.00 -2194.75 89.11 MWD 10598.42 88.06 41.92 6267.47 -1859.40 -1211.46 5967779.81 548756.25 12.00 -2171.42 89.00 MW D 10600.00 88.06 42.11 6267.53 -185822 -1210.40 5967780.99 548757.29 12.00 -2169.85 90.00 MWD 10625.Q0 88.06 45.12 626B.37 -1840.14 -1193.17 5967799.19 548774.40 12.00 -2144.87 89.99 MWD 10650.00 88.07 48.12 626922 -1822.98 -1175.01 5967816.47 548792.45 12.00 -2119.90 89.89 MW D 10675.00 88.08 51.12 6270.06 -1806.79 -1155.98 5967832.78 548811.37 12.00 -2095.00 89.79 MW D 10700.00 88.10 54.12 6270.89 -1791.62 -1136.13 5967848.08 548831.12 12.00 -2070.23 89.69 MW D 10725.00 88.12 57.12 6271.72 -1777.52 -1115.51 5967862.32 548851.64 12.00 -2045.68 89.59 MW D 10728.42 88.13 57.53 6271.83 -1775.67 -1112.63 5967864.18 548854.50 12.00 -2042.34 89.49 MW D 10750.00 88.04 54.94 6272.55 -1763.69 -1094.70 5967876.29 548872.35 12.00 -2021.19 268.00 MW D 10775.00 87.94 51.94 6273.43 -1748.81 -1074.63 5967891.30 548892.32 12.00 -1996.47 268.09 MW D 10800.00 87.85 48.94 6274.34 -1732.90 -1055.37 5967907.33 548911.47 12.00 -1971.61 268.19 MWD 10825.00 87.76 45.94 6275.30 -1716.00 -1036.98 5967924.35 548929.75 12.00 -1946.65 268.30 MW D 10850.00 87.68 42.94 6276.29 -1698.17 -1019.49 5967942.29 548947.12 12.00 -1921.67 268.42 MW D 10875.00 87.61 39.94 6277.32 -1679.45 -1002.96 5967961.12 548963.52 12.00 -1896.75 268.54 MWD 10900.00 87.54 36.94 6278.38 -1659.89 -987.43 5967980.79 548978.92 12.00 -1871.94 268.66 MWD ~ ~ ~ bp ~ BP Alaska Baker Hughes INTEQ Planning Report ~t~ s~~ iNTEQ Company: BP Amoco Date: 5/8/2007 Time: 10:53:17 Page: 6 Field: Kuparuk Co-ordinate(NE) Reference: ' W eIL' 15, True North Site: KR U 1 B Pad Vertical (TVD) Referencee RKB Elev 3 95A We1L• 15 Section (VS) Reference: We41(O.OON,O.OOE,45.OOAzi) Wellpath: Plan 9, 1 B-15AL3 Survey Caiculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S FJW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10925.00 87.48 33.94 6279.46 -1639.54 -972.95 5968001.23 548993.26 12.00 -1847.31 268.79 MW D 10950.00 87.43 30.93 6280.57 -1618.46 -959.56 5968022.39 549006.51 12.00 -1822.93 268.92 MWD 10968.42 87.40 28.72 6281.40 -1602.50 -950.41 5968038.42 549015.56 12.00 -1805.17 269.05 MW D 10975.00 87.39 27.93 6281.70 -1596.71 -947.29 5968044.22 549018.64 12.00 -1798.88 269.50 MWD 11000.00 87.37 24.93 6282.84 -1574.35 -936.17 5968066.65 549029.60 12.00 -1775.21 269.54 MW D 11025.00 87.36 21.92 6283.99 -1551.44 -926.25 5968089.63 549039.37 12.00 -1751.99 269.67 MW D 11050.00 87.35 18.92 6285.15 -1528.04 -917.53 5968113.09 549047.93 12.00 -172928 269.81 MW D 11075.00 87.35 15.92 6286.31 -1504.21 -910.06 5968136.96 549055.25 12.00 -1707.15 269.95 MW D 11100.00 87.36 12.91 6287.46 -1480.03 -903.84 5968161.18 549061.30 12.00 -1685.65 270.09 MWD 11125.00 87.37 9.91 6288.61 -1455.55 -898.90 5968185.69 549066.08 12.00 -1664.85 270.23 MWD 11150.00 87.40 6.91 6289.75 -1430.85 -895.25 5968210.41 549069.56 12.00 -1644.80 270.37 MW D 11175.00 87.43 3.91 6290.88 -1405.99 -892.90 5968235.29 549071.75 12.00 -1625.56 270.50 MWD 11200.00 87.46 0.90 6291.99 -1381.04 -891.85 5968260.24 549072.63 12.00 -1607.17 270.64 MW D 11225.00 87.51 357.90 6293.09 -1356.07 -892.11 596828521 54907221 12.00 -1589.70 270.77 MW D 11250.00 87.56 354.90 6294.17 -1331.14 -893.68 5968310.12 549070.47 12.00 -1573.18 270.90 2 3/8" ~ ~ ~ / ~ ~ ~ RE: 1 B-15AL3 ~ • Tom Thursday June 7, 2007 is the expected spud date. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 - Office (907)223-3605 - Cell --- ,~aye--- From: Thomas Maunder [~~~i.Itc;: ~o-ra rna.urd.er.~iwaclrr;.~.ra..>tate.r~;~.us] Sent: Monday, June 04, 2007 1:55 PM To: Rixse, Mel G Subject: 1B-15AL3 Mel, I am reviewing this application. Approximate spud date is listed as June 15, however I understand the schedule may have moved up. Could you please give me an estimate of the possible spud for this well? Thanks in advance, Tom Maunder, PE AOGCC 1 of 1 6/5/2007 9:28 AM Re: Permit to Drill for KRU IB-15A L3 I have it and am reviewing Jim Regg AOGCC Rixse, Mel G wrote, On 5/30/2007 10:01 AM: Jim, Do you know the status of the request for Permit to Drill for 1 B-15A L3? It may be needed in the next week. el ixse C~iled Tubing L~rilling ~ngirreer BP Expior~tion Al~ska; lr~c. {90')564-5620 - Office (907)223-3605 - Ce1I Jim Regg <jirn re~g(c%.adminsiate.ak.~xs> Petroleum Engineer ' AOGCC 1 of 1 5/30/2007 10:17 AM ~ ~ . PERMIT T4 DRILL 24 AAC 25.~05 U (e) E~ch well branch requires a separat~ P~ato~t to Drell. If a previously drilied weii is proposed to be redrilled below the struetural or cor~duct~r c~so~~ ~ a r~ew bo~om-hole location, the app(icati~n for a Permit to Drill must be accompani~d by a9~ ut~ros rsqvired under (c) of this section. If can~urrent multiple we~l b~anches are proposed from a sar~~le c~r~d~uctex, surface, or production casing, (2) for each ofher wel! branch, the appdo~ati~r~ fe.~- ~ Permit to Drill need only include information under (c) of this section that is unique to that well branch ~a~d need not be accompanied by tiie $100 fee. ~ ~ TRANSMIT'~'AL LE'T1'~R CHECKLIST i~VELL ~~1NIE _ ~~~ ~,~'- ~S~"[ L ~ PTn# 207 - C~(o ~7 / . Development Service Eaploratory Stratigraphic Test Yon-ConventioQa[ We1t Circle Appropriate Letter / Paragraphs to be Includ~d ia Transmittal Getter ~ CE~CK ~ ADD-O~fS ! TEXT FOR APPRO~'AL LETTER ; Vb'HAT ~ (OPTIONS) ~ APPLIES ~ ; ~ ; ' - ' ' r ~ ; I N[LiLTI LATERAL ~ The permit is for a new wetlbore se ent of exi~ting + ~ ~ we!! - / ~ 2/ I ~ (If tast two degits in I ~ N ~ ,~ P ~ i AP[ number o. S , AP[ No. ~0-C~~ _~ ~~~t are ; , ; berween 60-69) Prodaction ~hould continu~ to be repvrted as a function of the ~ , : original API number stated above. ~ , ~ i PILOT EIOLE i[n accordance with 20 AAC 2~.003(~, atl records, data and lo~s ; i j ~ acquiced for the pilot hoie must be ctearly diffec~ntiatcd in both ~ ~ i ~ we!! namc ( Pf~ and API number ~ I ; ' '(~~- -_) Prom records, data and logs ~ j ~ acquiced for wett ' . I i SPACING I EXCEPTION The permit is approved subject to fuU compliance with 20 AAC I 2~ 5 ~ .0 5. Approval to perforate and produce / inject is contingent ; ~ i I upon issuance of a conservation order approving a spacing ~ ~ exception ' . assum~s the L ~ liability of any protest to the spacing exception that may occur. i ~ ; DRY DCTCH J Al( dry ditch sample s~ts subrnitted to tt~e-Eommission must be n i SA.tiIPLE I no greater tltan 30' sampte intecvals from below• the pecmafro~t or ; ! ~ I from w6ere samptes are fnt caught and 10' sample intervals ; ; ~ thcough target zones. ~ ~ j Non-Conventionai ~ Please note the following_ special condition of this permit: ~ productioR or production testing of coat bed methane is not allowed i ~~z!! i foc (name of wetl) until after (Companv Name has designed and ! ' ~ implemented a water well testing program to provide baseline data j ; on water quality and quantity. (Company Narne? must contact the ( i - Commission to obtain advance approval of such water w~e!! testing ! ~ pcogtam. I Rev: 1'2~i06 C:!jody~transmictal chectclist ~ ~ ^^ ' ~ ~ , , , , ~ , , , , , ~ o a~ o- ~ ~ ~ ~ ~ ~ ~ ~, ~ ~ , ~ ~ ~ ~ , ~ ~ ~ ~, ~ ~ ~ ~, ~ ~ y y N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , , ~ ~ , ~ ~ , ~ ~ ~ ~ ~ ~ , ~ ~ ~ . ~ , ~ ~ , ~ , , ~ ~ ~ ~ ,~, , , ~ , , ~ ~ ~ ~ ~ ~~~ ~ ~ ~ ~ ~O ~ ~ ~ ~ ~ ~ , ~~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ , ~ ~ ~ ~ ~ , ~' , V1, , , , . ~ ~ ~ ~ ~' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~~~ , ~ ~ ~ Q , ~ , o ~ , ~ ~ , , O E, , , °` , , c ~°n , , , , , ~ , ~o, Q , ~ I ~ ~ ~ V~ ~~ ~ Y ~ ~ ~ , ~ ~ , ~ , ~ ~ , ~ ~ ~ p~ ~ N, ~ , ~ ~ ~ ~ cC4, ~~ ~ ~ ~ ~~ Q~ ~ ',. ~~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~~~ , ~ ~, , Z~ ~~, ~ , ~ ~ N~ , ~ I ~~ ~' ~ ~~ , C O ~ ~ ~ ~ .~ ~ C~ ~ O~ ~ Z~ ~ ~ 0~ ~ ~ ~ ~ ~ ~ ~ , , ~ . ~ ~ ~ ~ , ~ ~ ~ , ~ ~ N~ , ~ ~ ~ , ~ ~ N , ~ y , ~~ ~ C, ~ O~ , ~ ~ , ~ ~ ~ ~ ~~ ~ C, ~ tlA ~ ~ , ~ ~ N O ~ ~ ~ ~ c~ N= ~ ~ ~ , Q~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ , ~ , ~ ~ ~ ~ ~ ~ ~ N ~' , , ~ O' ~ N ~ , , ~ ~ ~ , ~ V , ~ tq' C' tl1' ~ ~ ~ ~' ~ ~ j' ~ ~ ~ ~ W ~ O o' 3 , ,n ~ ~ , f6, S ~ ~ y ~ ~~ ~ ~ c~ '~'~ ~ ~~, ~ , , ~ ~ ~ ~ ~ ~ ~ ~~~ m ~ °~~ , , . , ~n, ~, ~ ~ ~~ ~°- °' ~ O ~ ~ o, ~ , ~ , L o ~ ,~, a, c L ~ c o N~ ~ri ~ ~ N O , ~ ~ N~~ 4 , ~ ? ~ N~ , ~ ~ ~ ~ ~ ~ , , , ~ ~ , ~~ ~ ' , ~1 , ~~ U~ ' N N O L~ O ~ ~ Vl ~ O~ .L-~ ~ ~ C~ ~~ ~? , ~ ~ ~ ~ ~ ~ ,«~. ~ ~ ~ ~~ h ~ ~ p ~~ , , , N ! ~ , ~f ~, , , , ~' , pp Cj ~, ~, , , , , d ~ U 3 0- a m , , ~ ~ , o ~ , _~ , ~°, c , ~ ,c ~, ~ 'n ' ~ ~ y~ ~, , .C, ~~ ~, Q , , ~ , ~ ~ ~ ~ ~ , ~ , ~~ ~ V~ f6, 3 Q, ~ ~ ~, •~; ~; ~ , ~ ~ - ~ ~; 0 o 0, a , a ~, y, , , ~ ~ , ~ ~ ~ ~ >, ~ ~ ~ ~ , , -d, , o, ~ ~ _, ~, (O ~j, ~ , C~ U, N~ N, y, , , ~ ~ ~ , ~ ~ ~ ~~~ ~ L.~ Q~ ,~, . 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