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Home My WebLink About207-075~ • ~~~ ~ ' ~~~~~~ ~~~ ~~~~~~ ~~1~ ~,~~~~~ ~ FtE CAN DIGiTAL DA°fA Color Items: ~skettes, No. I ^ Greyscale items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: IVOTES: BY: ~Maria Date: C. Project Proofing BY Oi/ERSIZED (Scannable) ^ Maps: ^ Other items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: slo~ ,S, ~ ~ Date: ~ I V f`-' L__ lsl Scanning Preparation o~ ._ x 30 = I BY: Maria Date: Production Scanning Stage 1 Page Count from Scanned File: (count does ;nciude cover sneet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ g~~ ~S~ ~ r 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ Scanning is complete at this point unless rescanning is required. II ~ II II II I II ~~ I~ II~ fteScanrred II ( II'l l) l l(ll l l(ll BY: Maria Date: ~S~ Comments about this fife: Quality Checked ~ + = TOTAL PAGES ~/ ~ (Count does not include cover sheet) _ /s/ 10/6/2005 Well History File Cover Page.doc t, . p, " ~~~> '~ k~o~ '~ ~ . ~~~ ~ a ~. ~~~~ ~~ ~; ~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~--- 1 `~IC~C~ Company ConocoPhillips, Alaska, Inc. Well Name ~B-osAt.~ ~~'~' ""~ Date 1213/2009 A ~I •11• A 1 I /1 _ _ I _ _ I/. _._ _ ___ _1_ A __ _~b~4 ~1 11.1. n__L___1_.l____ ~i BAKER ~~~~E~ INTEQ i • Page 1 of 4 ..-,.. ~ `~'f d ~l Company ConocoPhillips, Alaska, Inc. Well Name 1B-08AL1PB1 f-~~~~-~ ~,~ ~~!~,~ `r ~ ~.~~~+ ,, ~ ~. Date 12/312009 ~`t ~ ~~ BAKER N~1~II~IE ll~i 1 ~~ Page 1 of 4 ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070750 We~~ Name/No. KUPARUK RIV UNIT 1B-08AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20635-60-00 MD 11500 ND 6417 Completion Oate 7/26/2007 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI~N Types Electric or Other Logs Run: MWD DIR, RES, GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digitai Dataset Log Log Run Interval OH / Ty~e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 11500 Open 9/25/2007 D D Asc Directional Survey 0 11028 Open 9/25/2007 PB 1 Well Cores/Samples Information: Sample interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ~ Well Cored? Y~ Daily History Received? Chips Received? ~`'11~ Formation Tops ~N Analysis ~C1,Pd~ Received? ~ ~ Comments: (~ ~..~ ~ ~ ~ ~t ~ ~~ y'~. ~,~ - Date: u Compliance Reviewed By: Z~~ \ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COM~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~EIVE~ aUG 2 7 2007 ~~~~;~ka Oii & Gas Cons. Commissiot! 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Aba~doned ^ Suspended 1 b. Well Class: nC Of , 2onnc2s.~os 2oa~.c2s.~,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. 7/26/2007 . 207-075 - 3. Address: 6. Date Spudded 13. API Number c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 7/2/2007 ' 50-029-20635-60-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached ~, 14. Well Name and Number: Surface: 01' FNL i41' FEL ~ 7/13/2007 1 B-08AL1 J , 5 , SEC. 09, T11N, R10E, UM Top of Productive Horizon: 8• KB (ft above MSL): 93' - 15. Fieid / Pool(s): 1027' FNL, 4709' FWL, SEC. 10, T11 N, R10E, UM Ground (ft MSL): Kuparuk River Unit / Kuparuk Total Depth: 9. Plug Back Depth (MD+7yD) River Pool ~ 673' FNL, 4016' FWL, SEC. 10, T11N, R10E, UM 11500 6417 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 550298 ' y- 5969648' Zone- ASP4 - 11500 6417 f ADL 025648 G2SG~ TPI: x- 555153 y- 5969156 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: g~ Total Depth: x- 554457 - y- 5969505 -Zone- ASP4 None 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 1465' (Approx.) ~ 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, RES, GR Z2. CASING, LINER AND CEMENTING RECORD GASWG SETTING DEPTH MD' SETTING DEPTH ND HOLE AMOUNT r WT. PER FT. ` GRADE TOP + BOTfOM TOP BOTfOM SIZE CEMENTING RECQRD AULLEQ'' > 16" 65# H-40 Surf ce 112' Surfa e 112' 4" 200 sx Permafro t 10-3/4" 45.5# K-55 Surface 2343' Surface 2246' 13-3/4" 1000 sx Fondu 250 sx AS II 7" 26# K-55 Surface 6339' Surface 5025' 8-3/4" 923 sx Class'G' 4-1/2" 1.6# L- 0 612 ' ' 4846' 45 ' 6-1/8" 496 sx lass' ' Za~a° X a-v2° x 3-3/16" 6.4# / 8.81 #/ 62# L-80 9019' 10480' 6344' 6490' 4-1 /8" 34 sx Class 'G' 2-3/8" 4,44# L-80 10468' 11497' 6492' 6417' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ~ Yes ^ No 24. TusiNC RecaRo If Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): Size ~EPTH SET MD PACKER SET MD 2-3/8" Slotted Section - Note: 4-1/2", 12.6#, L-80 6135' 6110' ~ ` ~ '` MD TVD MD TVD 1 '~ 'k~l ~ 10706' - 11463' 6446' - 6417' Only Well Branch FRacruRe C~nneror SQUE~ ~c 25: Acio 1 B-08AL1 , . , , °' Is Directly DEPTH INTERVAI MD AMOUNT Sc KIND OF MATERIAL USED Accessible g256' Set Flow-Thru Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test: Hours Tested: PROOUCT~on, FoR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: Cn~cu~.a,Te~ OIL-BBL: GAS-MCF: WATER-BBI: OIL GRAVITY-API ~CORR~: Press. 24-HouR RAre.~ 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, as or water (submii separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical r~s~1~$v~~~ 250.071. ~ ' ~, ~ ~~tF £ ~tr~ .. ~ p None ' d~"~ ~~p ~ ~ ~~~~ ~ '? ~2G •d~~ ~ VEniFlED . X~~ ~~~ _ ~ L.., .wr~nr ~ ,~b _v7 ~ Form 10-407 Revised 02/2007 ~ ~ ~ ~ ~ ni n ~orvTINUED ON REVERSE SIDE ~` ~'~ ~d~~~/~/~~ ~ ~_~7 ~ ~ V/"ti L,~. Id~ i~ Jv ZH. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AN KERS ENCOUNTERED~: 29. FORMATION TESTS . NAME 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. ~ Kuparuk - Base of C4 / Top C3 9315' 6478' None ~ . Top C3 / Base C4 (Inverted) 9870' 6496' Top C1 / Base C2 (Inverted) 10438' 6498' Top C2 / Base C3 (Inverted) 10673' 6451' ,~ Top C3 / Base C4 (Inverted) 10800' ` 6433' Formation at Total Depth (Name): Top C3 / Base C4 ~ 10800' ' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~/ ~ /, Signed Terrie Hubble Title Technical Assistant Date ~ V 1 B-08AL1 207-075 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Gary Eller, 529-1979 Permit No. / A roval Na 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 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ireM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternafing-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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 onfy 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, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detaited description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ~ ~ Wellname DATE Summary of Pre-Rig Operations 1 B-08 3/21/07 PRE CTD - POT & PPPOT-T & IC PASSED, POT & PPPOT-OC PASSED, TORQUED OC LDS, INITIAL ENERGIZE ON OC PO 'Y' SEAL, INSTALLED GAUGE AND JEWELRY ON CONDUCTOR, MITIA PASSED, MITOA PASSED 1 B-08 3/22/07 PT, MV & SV ( PASSED), DD, MV ( INCONCLUSIVE ), DD, SV ( PASSED). 1 B-08 4/15/07 PULLED 3.81" INJ VALVE @ 517' RKB. BRUSH & GAUGED TBG TO 3.75" TO 9173' RKB. UNABLE TO REACH TARGET DEPTH OF 9350' RKB WITH CALIPER. LOGGED TBG FROM 9329' RKB TO SURFACE. SET 3.81" A-1 INJECTION VALVE (SN HRS-51/ .625 BEAN). PERFORMED CLOSURE TEST. P 1 B-08 6/14/07 PULLED A-1 INJECTION VALVE @ 517' RKB ( S.N. HRS-51 }. TAGGED TD C~« 9323' RKB W/ 10.5' X 3.70 OD DUMMY DRIFT. 1 B-08 6/16/07 DRIFT TO 3.75" DB NIPPLE @ 9173' RKB W ITH 3.76" GAUGERING.TAGGED W ITH 2.5" BAILER @ 9468' RKB EST 66' RATHOLE 1 B-08 6/19l07 BAKER WHIPSTOCK SET WITH TOP AT 9265', RA TAG AT 9273.6' WS FACE SET AT 16 DEG LEFT OF HIGH SIDE (CCW) SETTING TOOL DID NOT RELEASE FROM WS AFTER FIRING PULLED OUT OF WIRELINE WEAK POINT, ALL CABLE OOH TOP OF TOOLSTRING AT 9235' 1 B-08 6/20/07 ATTEMPT TO FISH 42' EL TOOLS LEFT FISH BAITED FOR AM, JOB IN 1 B-08 6/21/07 ATTEMTP TO FISH EL TOOLS , LEFT FISH BAITED W/ 3.70" G-BATE SUB, 2.70" BELL GUIDE WITH 2" JDC INSIDE @ 9191' WLM, 3' 4" OAL FOR COIL 1 B-08 6/22/07 LATCHED FISH AT 9242' CTMD, HIT 20 JAR LICKS AND PULLED FREE, LEFT FISH AT SURFACE, TURN OVER TO SLICKLINE TO FINISH RETRIVAL. (( IN PROGRESS 1 B-08 6/22/07 FISHED E-LINE TOOLSTRING FROM TREE ( ALL PARTS ACCOUNTABLE ). , ~ ~ BP ANiERICA P~ge 1 af 26 ,C~p~~r~~ions Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date _~ From - To Hours Ta~k Code I~PT Phase Descriptic~n of C3peratic~ns 6/28/2007 ~ 12:00 - 15:00 3.00 MOB P PRE Spot herculite and rig mats around 1 B-O8. 15:00 - 16:30 1.50 MOB P PRE Move rig onto mats in front of well. Lower BOPs to rig mat. Install proper rams for 2-3/8" coil. ; 16:30 - 17:00 0.50 MOB P PRE Spot rig over well. Accept rig at 1700 hrs on 6/28. i 17:00 - 18:30 1.50 RIGU P PRE RU berm around cellar. Spot cuttings box. Move office trailer. Change injector gripper blocks to 2-3/8" Crew change 18:30 - 20:45 2.25 BOPSU P PRE ND tree cap. Take on rig water and diesel. Load out 2" E-CT on VECO lowboy. Load in 2-3/8" E-CT. Cut herculite and berm around rig for rig washing. Kuparuk Wells Services RU I hardline to tiger tank I 20:45 - 23:30 2.75 BOPSU P PRE NU BOPE. Set mousehole. Spot cuttings box. RU hardline in reelhouse. Install packoff in injector 2330 - 00:00 0.50 BOPSU P PRE Test BOPE. AOGCC waived witness PreSpud mtg 6/29/2007 00:00 - 03:30 3.50 BOPSU P PRE Continue BOPE test. No failures Continue to RU berm around rig '~ 03:30 - 05:00 1.50 RIGU P PRE RU injector and gooseneck 05:00 - 08:30 3.50 RIGU P PRE Install internal grapple and PT. Remove shipping bar. Pull CT to floor. Stab coil. Fill coii with fresh water. 08:30 - 13:15 4.75 RIGU P PRE Seal e-line end. Get on well. Reverse circulate slack. MU e-coil head. Test same for continuity and pressure integrity. 13:15 - 15:00 1.75 BOPSU P PRE PU lubricator. Hold PJSM. NU and pull type H BPV. Found j 720 psi on weil. RD lubricator. remove same from rig floor. Circulate coil 2.5 volumes while pulling BPV. 15:00 - 15:15 0.25 KILL P WEXIT Hold PJSM. MU 3.5" nozzie assembly with stinger. Pressure test packoff to 1000 psi. Ok. 15:15 - 16:45 1.50 KILL P WEXIT Open well. 760 psi ISITP. Bleed well to tiger tank. Bleed 10 bbls diesel. Shut in weil and monitor pressure build up. 16:45 - 18:45 2.00 KILL P WEXIT Run in hole with nozzle. Hold 700 psi WHP. Circ at min rate, ( j 0.1 bbm) down coil. Take rtns to tiger tank. Rtns density ~ indicates diesel and no gas. Start getting back all gas. Notify DSO and Halliburton Unit down pad. Post tank watcher to "guard" tank and monitor wind direction. Tag whipstock at 9243'. Pick up to 9240'. Finally wise up and decide to bulihead down the CT annulus. 3.0 bpm at 1835 psi. Pump up packoff. Displace wellbore w/ 180 bbis (ann vol is 90 bbls) of 8.75 ppg used FloPro mud. FIP 1835, ISIP 1800, 10 min 1600 TT PVT 59 bbls 18:45 - 19:20 0.58 KILL P WEXIT After 20 min, SIP=1500 psi. Begin circ 0.2/1700 w/ 1535 psi and whp still falling slowly. PVT 222 Bleed off whp slowly to 700 psi while incr rate to 1.5 bpm IA 350, OA 34 i 19:20 - 21:00 1.67 KILL P W EXIT POH circ 1.5/1520 w/ 700 psi induced whp. After 10 bbls of returns, mud became cut w/ oil and 'ouY density was '0.00' so sent mud to trash pit. After dumping 60 bbls resume taking returns to the pits w/ density at 8.2 ppg and density slowly increased to normal after 30 additional bbis 21:00 - 21:10 0.17 CLEAN P W EXIT Tag up w/ 1.53/1.53/1580 w/ 700 psi whp. SI SV (24) and chk MV (24) PVT 144 Safety mtg: LD BHA/MU milling assy 21:10 - 21:45 0.58 STWHIP P WEXIT LD nozzle assy. Set injector on legs. Chg packoff 2t:45 - 22:05 0.33 STWHIP P WEXIT Safety mtg: pressure deployment ~ 22:05 - 00:00 1.92 STW HIP P W EXIT ~ Bring BTT motor and miil to floor and set in lub. Pressure Printed: S/6/2007 2:44:30 PM , ~ ~ BP AM~RICA Pa~e 2 af 26 Operatior~s ~ummary Repo'rt Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTEFi+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: ' ~ate From - To Hours Task Cade NPT Phase ' Description of Operations 6/29/2007 22:05 - 00:00 ~ 1.92 STWHIP P WEXIT deploy MWD assy w/ 500 psi 6/30/2007 00:00 - 01:35 1.58 STW HIP~ P W EXIT Open VBR's to 450 psi. Tag up w/ 2.0'. RIH circ thru mifl 0.57/1200 holding 700 psi whp 01:35 - 02:00 0.42 STWHIP P WEXIT 9100' 19.3k, 6.8k RIH to tag at 9260.3' CTD. PVT 180 PUH ~ w/ 2k overpull. Start motor 2.52/2290. Drop whp to zero, but gained 3 bbls at 0.5 bpm. Apply 300 psi whp and RIH 2.52/2290 and first MW was at 9258.4'. Corr to 9265.0' and flag 02:00 - 02:30 0.50 STWHIP P WEXIT Mill window by time schedule according to BTT. Red rate to 2.34/2135 due to BHI getting bad vibrations. DHP is 3470 psi w/ 300 psi whp. No decrease in mud wt at btms up so assume i formation is charged up. Red whp to 250 psi. First serious ~ MW at 9265.6' 02:30 - 03:00 0.50 STWHIP P WEXIT Mill from 9265.6' 2.31/2135 w/ 250 psi whp=3360 psi dhp=10.18 ECD PVT 185 03:00 - 04:00 1.00 STWHIP P WEXIT Mill from 92662' 2.23/2060 w/ 200 psi whp=3300 psi dhp=10.0 ' ECD PVT 186 1.3k wob 04:00 - 04:30 0.50 STWHIP P WEXIT Mill from 9267.0' 2.09/1910 w/ 175 psi whp=3268 psi dhp=9.91 ECD PVT 185 1.87k wob 04:30 - 05:00 0.50 STWHIP P WEXIT Mill from 9267.4' 2.09/1910 w/ 150 psi whp=3240 psi dhp=9.80 ECD PVT 187 2.4k wob 05:00 - 06:15 1.25 STWHIP P WEXIT Mill from 9268.0' 2.07/1900 w/ 150 psi whp=3240 psi dhp=9.80 ECD 3.Ok wob 06:15 - 11:15 5.00 STWHIP P WEXIT Mill from 9268.5'. 2000 psi fs at 2.36 in/2.35 out. 200-300 dpsi. 3k# dhwob. WHP/BHP/ECD: 170/3258/9.87 ppg. IA/OA/PVT: 431/44/193 bbls. 11:15 - 13:00 1.75 STWHIP P WEXIT Continue to mill from 9272.6'. 1900 psi fs at 2.16 in/2.19 out. 200-350 dpsi. 2.Ok# dhwob. WHP/BHP/ECD: 157/3286/9.95 ppg. PVT: 194 bbls. Using reduced pump rate to reduce down hole vibration. Drilling formation at 9272'. Drili rat hole to 9283'. CorrectedTop of window: 9256'. Bottom of window: 9263'. 13:00 - 14:00 1.00 STWHIP P WEXIT Back ream window three times. Sut in well and dry drift. Window smooth. Geologist reports galuconite in btms up sample. 14:00 - 16:00 2.00 STWHIP P WEXIT Circulate out of hole maintaining constant BHP using choke. Hold PJSM in Ops Cab near surface. 16:00 - 18:15 2.25 STWHIP P WEXIT Pressure undeploy BHA with 400 psi SIWHP. Mill and string reamer both gauge 3.74" go, 2.73" no go. 18:15 - 19:15 1.00 BOPSU P W EXIT Stab back on and PT replaced CT stripper packoff as part of BOPE test 19:15 - 19:30 0.25 DRILL P PROD1 Safety mtg re: pressure deploy 19:30 - 22:40 3.17 DRILL P PROD1 Remove res tool from BHA. MU 3.72" bi bit on 3.0 deg motor. MU to MWD assy in lub and tag SV, okay. Finish pressure deployment w/ 385 psi whp. Use 3' + 5' lubs and 0.18' tag up 22:40 - 00:00 1.33 DRILL P PROD1 Open EDC. RIH w/ BHA #3 circ thru EDC 0.5/830 following pressure schedule 7/1/2007 00:00 - 00:45 0.75 DRILL P PROD1 Continue RIH w/ BHA #3 00:45 - 01:00 0.25 DRILL P PROD1 Log tie-in down from 9213' 0.5/760 w/ 300 psi whp PVT 189 Corr +9.0'. Close EDC 01:00 - 02:50 1.83 DRILL N DPRB PROD1 RIH thru window at 0.35/900 and set down at BOW at 9273.8'. Try multiple times w/o success and always stop at the same . Printed: 8/6/2007 2:44:30 PM , ~ ~ BP AMERICA Page 3 of 26'' , Operations Summ~ry Repc~rt Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date ' FrQm - Tc~ H~urs Task Code NPT Phase ' Description of Operations 7/1/2007 01:00 - 02:50 1.83 DRILL N DPRB PROD1 spot. Get crude contaminated mud back while circ at 0.5 bpm i w/ 350 psi whp and incr to 450 psi whp. Go around the clock w/ TF's. Start having 5-10k OP's at 9250' w/ TF at 180 deg and determine this is probably the CTC catching the DB nipple at 9178' 02:50 - 03:30 0.67 DRILL I N DPRB PROD1 Relog tie-in down from 9213' to 9270' w/ HS TF and had no ' I correction. Try getting by 9273.8' a few more times w/o success 03:30 - 03:45 0.25 DRILL N DPRB PROD1 Open EDC and circ out crude contaminated mud while discuss. i Returns cleaned up to 8.56 ppg after 20 bbls 03:45 - 06:00 225 DRILL N ~ DPRB PROD1 POOH circ thru EDC 2.4/1950 following pressure schedule 06:00 - 08:30 2.50 DRILL I N DPRB PROD1 Hold PJSM. Pressure undeploy BHA. Review undeploy procedure during operation. 07:45 - 08:45 1.00 DRILL N DPRB PROD1 Test MW D tools on rig floor. 08:45 - 10:30 1.75 DRILL N DPRB PROD1 PJSM. Make up milling assembly (3.73 window miil and string ~ reamer on 0.9 deg mtr) with HOT and DGS toois. Pressure ! deploy BHA. FOund 450 psi on well once open. 10:30 - 12:30 2.00 DRILL N DPRB PROD1 Run in hole. Maintain constant BHP. 12:30 - 12:45 0.25 DRILL N DPRB PROD1 Log gr tie in from 9200'. Add 16' correction. RIH. 12:45 - 18:45 6.00 DRILL N DPRB PROD1 Tag btm at 9283'. 2220 psi fs at 2.56 in/2.61 out. WHP/BHP/ECD: 155/3305/10.0 ppg. IA/OA/PVT: 490/54/170 bbls. Ream and back ream window at 1 fpm at HS, 315, 290. Circulate a high vis sweep. Continue to dress window at 215, 120, 75, 45, and 15 deg. 18:45 - 20:30 1.75 DRILL N PROD1 POH circ thru mill 2.65/2330 following pressure schedule 20:30 - 22:20 1.83 DRILL N PROD1 Pressure undeploy w/ 435 psi 22:20 - 23:20 1.00 DRILL N + PROD1 Test MWD assy 23:20 - 00:00 0.67 DRILL N PROD1 Pressure deploy w/ 385 psi. Have trouble getting the bit by the i tubing hanger 7/2/2007 00:00 - 02:00 2.00 DRILL ~ N DPRB PROD1 Continue trying to get bit past the tbg hanger (0.5). Fin pressure deploy w/ 366 psi 02:00 - 03:55 1.92 DRILL N DPRB PROD1 RIH circ 0.5/850 thru EDC following pressure schedule 03:55 - 04:20 0.42 DRILL N DPRB PROD1 Log tie-in down from 9213', corr -11'. Close EDC 04:20 - 05:15 0.92 DRILL P PROD1 RIH thru window and tag at 9275.3'. Repeat tag numerous , times w/ HS TF's. PU off btm at 9273' and start pump at 1.25 bpm and acts like formation. Incr pump to 2.4/2285 and ease in hole holding 200 psi whp. Start getting the normai crude in the mud back so send it to tiger tank in prep for mud swap. j Finish ream OH w/ 1-3k wob and find TD at 9283' 05:15 - O8: f5 3.Q0 DRILL ~ P PRODf Drill from 9283' 2.41/2.41/2500/5L w/ 100-250 psi diff, 0.5-2.Ok wob w/ 150 psi induced whp to give 3320 psi dhp or 10.0 ECD. Start mud swap. Drill build and turn to 9450'. 08:15 - 10:30 2.25 DRILL P PROD1 Log MAD pass up to and across RA tag at 9274'. -9 ft correction for RA tag once tied into PDC log. Log again running in hole to confirm RA tag depth. Corrected TOW: 9256' Corrected BOW: 9263' RA tag: 9265' The orignal WS setting depth recorded by Wells Group was +/- 9 ft deep. 10:30 - 12:30 2.00 DRILL P PROD1 Drill ahead from 9450'. 3000 psi fs at 2.42 in/2.45 out. 200-300 dpsi. 2.5-3.5k# dhwob; WHP/BHP/ECD: Printed: 8/6/2007 2:44:30 PM . ~ ~ BP ANIERICA Page 4 of 26 ' 4pera#ions Summary Repvrt Legal Well Name: 1B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: ' Date ' Fram - Tc~ Hours Task Code NPT Phase Descriptifln c~f Operations 7/2/2007 10:30 - 12:30 2.00 DRILL ; P i PROD1 150/3550/10.63 ppg. lA/OA/PVT: 431/45/356 bbls. I I INC/AZM/TF: 90.8/8.97/277 deg. Build complete, continue turn to the left. ROP: 50-80 fph. 12:30 - 13:15 0.75 DRILL P ' + PROD1 Wiper trip to window. Hole smooth. 13:15 - 15:15 2.00 DRILL P I PROD1 Drill ahead from 9600'. 3100 psi fs at 2.58 in/2.57 out. ROP: 50-100 fph. Continue turn to the left. Dog legs averaging about 35/100. TD and turn section of hole. 15:15 - 15:45 0.50 DRILL P PROD1 Wiper trip to window. 15:45 - 17:30 1.75 DRILL P PROD1 Reduce circ rate through window. Open EDC. Circulate out of ~ ~ hole. Hold PJSM. 17:30 - 18:00 0.50 DRILL P ; PROD1 SIWHP: 392 psi. Tag up and space out coil. Close rams. Push/pull test. Close variables. Bleed off pressure. 18:00 - 19:30 1.50 DRILL P PROD1 Finish pressure undeploy w/ 382 psi 19:30 - 21:45 2.25 DRILL P PRODi Cut off 25' slickline and rehead while 8H1 reconfigue tools string and program res tool 21:45 - 22:00 0.25 DRILL P PROD1 Safety mtg re: pressure deploy 22:00 - 00:00 2.00 DRILL P PROD1 MU BHA #5 and pressure deploy w/ 370 psi. PT CTC @ 3800 7/3/2007 00:00 - 01:00 1.00 DRILL P PROD1 Finish pressure deploy BHA #6 01:00 - 02:50 1.83 DRILL P PROD1 RIH circ thru EDC 0.5/1250 following pressure schedule 02:50 - 03:10 0.33 DRILL P PROD1 Log tie-in down from 9225', corr +3'. Close EDC 03:10 - 03:30 0.33 DRILL P ~ PROD1 RIH thru window, clean. Precautionary ream 20'/min 2.45/2900 w/ 150 psi whp clean to TD tagged at 9730' 03:30 - 05:00 1.50 DRILL P PROD1 Log MAD pass up for resistivity data at 300'/hr to 9296' 05:00 - 0520 Q.33 DRILL P PROD1 Wiper back to TD was clean PVT 353 05:20 - 07:15 1.92 DRILL P PROD1 Drill from 9730' 2.44/2.44/2850/90L w/ 100-200 psi diff, 1-2k wob w/ 100 psi induced whp for 3470 psi dhp or 10.4 ECD at 100'/hr @ 90 deg @ 6401' TVD. ~ Found micro motion was partially plugged off. Once cleared. ~ WHP dropped to 55 psi. BHP/ECD: 3442/10.35 ppg. 07:15 - 08:30 1.25 DRILL P PROD1 Wiper trip to window. Hole smooth. 08:30 - 09:30 1.00 DRILL P PROD1 Drill ahead from 9900'. Became differentially stuck at 9994'. 09:30 - 11:30 2.00 DRILL N STUC PROD1 Drill ahead from 9900'. Became differentially stuck at 9994'. Call for slick diesel. Relax hole to reduce BHP. BHP dropped to 3220 psi. No movement. Pump and spot 10 bbls slick diesel. Spot 5 in open hole. DHWOB changed from -3k# to zero. Picked up. Coil came tree at 40k# up wt. (normai up ~ weight is 20k#). 11:30 - 13:00 1.50 DRILL P PROD1 Wiper trip to window. Circulate out diesel. 13:00 - 14:15 1.25 DRILL P PROD1 Drill ahead from 9,990'. 3000 psi fs at 2.58 in/2.51 out. 50-100 dpsi. ik#dhwob. WHP/BHP/ECD:55/3458/301 bbis. INC/AZM/TF: 89.7/278.5/275 deg. Limiting ROP to 60-80 tph to try and avoid differential sticking problem. Hit a hard spot. Having problems with orienter and controliing tool face. Trouble shoot MWD. Unable to resolve the problem. 14:15 - 17:00 2.75 DRILL N DFAL PROD1 W Iper trip to window. Circulate out of hole. 17:00 - 17:15 0.25 DRILL N DFAL ~ PROD1 PJSM prior to pressure undeploying. 17:15 - 18:00 0.75 DRILL N DFAL PROD1 Swab's shut. LD MWD tools. 18:00 - 20:50 2.83 DRILL N DFAL PROD1 MU new MWD BHA & test same. 20:50 - 21:00 0.17 DRILL N DFAL PROD1 PJSM prior to pressure deploying. 21:00 - 23:00 2.00 DRILL N DFAL PROD1 Set back lubricator & pick up injector & test lines - ok. Pressure deploy BHA. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 Test MWD tools. Problems with BHI computers & possible tooi problems. Printed: 8/6/2007 2:44:30 PM . ~ ~ BP AMERIGA Page 5 of 26' Ctperations Summary Repor# Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Qate From - To Hc~urs Task Code NPT Phase ' DeSCriptic~n vf Upera~ion~ 7/4/2007 00:00 - 01:00 1.00 DRILL N DFAL PRODi Work on computer system. BHA tool tested ok. MU injector & stab onto well. BHI is fixing computer problems. 01:00 - 02:35 1.58 DRILL N DFAL PRODi ~ Close EDC. Circulate at min rate & RIH using MPD techique. 02:35 - 03:35 1.00 DRILL N I DFAL PROD1 Park coil @ 9200ft, circ at min rate holding 300 psi W HP. BHI is re-imaging the computers - apparent communication with ~ tooi problem. Bleed IAP from 450psi to 125psi to Tiger Tank i (gas and fluid) 03:35 - 05:30 1.92 DRILL N DFAL PROD1 Re-imaging of computers was no help. POH to re-program BHA tools per BHI 'experts'. Test previous tool string on cat walk that had downhole failure. PJSM while POH for pressure undeploying. 05:30 - 07:00 1.50 DRILL N DFAL PROD1 Pressure undeploy BHA w/ 420 psi 07:00 - 10:00 3.00 DRILL N DFAL PROD1 LD BHA. Reprogram and test tools 10:00 - 10:15 Q.25 DRILL N DFAL PROD1 Safety mtg re: pressure deploy 10:15 - 12:10 1.92 DRILL N DFAL PROD1 Pressure deploy w/ 420 psi 12:10 - 13:50 1.67 DRILL N DFAL PROD1 RIH circ thru bit 0.5/1800 following pressure schedule ; 13:50 - 14:10 0.33 DRI~L N DFAL PROD1 Log tie-in down from 9300', corr -13' ~ 14:10 - 14:35 0.42 DRILL N DFAL PROD1 Wiper to TD was clean PVT 284 14:35 - 15:50 1.25 DRILL P PROD1 brill from 10041' 2.44/2.42/2960/90L w/ 100-200 psi diff, 1.5-2.5k wob on open choke w/ 3500 psi dhp or 10.5 ECD at 92 deg. Drill to 10090' ( 15:50 - 16:10 0.33 DRILL P PRODt Start fosing 0.5 bpm at 10090'. Drilled to 10093' and became ~ stuck. Pulled free after a few cycles at 20k over. 100' wiper PVT 280 16:10 - 18:00 1.83 DRILL P PROD1 Resume drilling and losses had healed to 0.15 bpm. Drill ahead 2.44/2.30/3000 to 10110' and started losing additional 0.15 bpm. Losses slowly healed to 0.1 bpm from cuttings. Drill ahead and lost angle down to 86 deg. Swap to right at 10180'. Drill to 10200' 18:00 - 19:10 1.17 DRILL P PROD1 Wiper to 9300ft - ciean. Wiper to TD - clean. 19:10 - 22:20 3.17 DRILL P PROD1 Drilling lateral. TF at 30 R Qp = 2.43 / 2.42 bpm CTP 2941 psi off bottom BHP = 3881 psi w/ ECD at 10.62 pppg DHWOB = 0.2 - 0.6 klb ROP = 40-70 fph Vp = 252 bbl's 22:20 - 23:35 125 DRILL P PROD1 Wiper to 9300ft - clean. Wiper to TD - clean. 23:35 - 00:00 0.42 DRILL P PROD1 Drilling laterai. TF at HS Qp = 2.3 / 224 bpm CTP 2930 psi off bottom 2840 psi fs BHP = 3511 psi w/ ECD at 10.54 pppg DHWOB = 0.8 - 2.2 kib ROP = 40-70 fph Vp = 222 bbl's 7/5/2007 00:00 - 01:00 1.00 DRILL P PROD1 Continue drilling lateral. TF at HS Qp = 2.3 / 224 bpm CTP 2930 psi off bottom 2840 psi fs BHP = 3511 psi w/ ECD at 10.54 pppg DHWOB = 0.8 - 2.2 klb ROP = 10-40 fph Vp = 222 bbl's 01:00 - 04:00 3.00 DRILL P PROD1 Decision was made to drill to 10,550ft due to the inability to locate the fault zone. POH to change bend on motor to higher degree. PJSM while POH for pressure undeployment. 04:00 - 06:00 2.00 DRIL~ P PROD1 Begin pressure undeploying BHA. 06:00 - 08:00 2.00 DRILL P PROD1 LD drilling BHA. Adjust motor bend to 1.8 deg, bit is okay. MU BHA 08:00 - 10:20 2.33 DRILL P PROD1 ( Pressure depioy w/ 366 psi Printed: 8/6/2007 2:44:30 PM R ~ ~ __ 8P AI4~ERICA Page 6~f 26'' Operat~c~n~ Sur~nmary Repc3r# Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date Frorn - To Hours Task Code NPT Phase DeSeription of C?p~:r~ticrns 7/5/2007 10:20 - 12:15 1.92 DRILL P PROD1 RIH circ thru EDC 0.5/1600 following pressure schedule ~ 12:15 - 12:50 0.58 DRILL P PROD1 Log tie-in down from 9200', corr -14'. Close EDC I 12:50 - 13:30 0.67 DRILL P PROD1 Wiper to TD was clean PVT 224 13:30 - 14:30 1.00 DRILL P PROD1 Dritl from 10401' 2.47/2.25/3160/10R w/ 100-200 psi diff, I 1.5-4.Ok wob, w! open choke and 3510 psi dhp or 10.59 ECD. Drill from 10418' in what acts like siderite-stacking near full surface wt w/ 3.2k wob and avg 10-15'/hr to 10424' and got ~ temporarily detained ' 14:30 - 14:45 0.25 DRILL P PROD1 BHA wiper 14:45 - 16:3Q 1.75 DRILL P PROD1 Drill from 10424' 2.43/2.28/3100/10R w/ 100-200 psi diff, 2.0-3.5k wob w/ open choke and 3495 psi dhp or 10.5 ECD and showing siow build. NBI at 10407' is 93 deg. Drill to 10446' and NBI at 10428' is 102 deg ~ 16:30 - 19:40 ~ 3.17 DRILL P PROD1 Drili from 10446' at very slow penetration rate while stacking ~ fuil wt to get 2.5k wob due to DLS in this hard spot. Perform numerous short wipers and move the TF to open up the hole to let the BHA pass easier. Finally started making hole again. 19:40 - 19:50 0.17 DRILL P PROD1 BHA wiper - clean. 19:50 - 21:30 1.67 DRILL P PROD1 Drilling lateral. TF at 90 R ~ ~ Qp = 2.43 / 2.24 bpm CTP 2914 psi off bottom BHP = 3489 psi w/ ECD at 10.48 pppg DHWOB = 2- 3.5 klb ROP = 5-60 fph Vp = 157 bbl's 21:30 - 23:30 2.00 DRILL P PROD1 TD spot has been picked. Wiper to window - clean. Log for i tie-in (+4ft corr). W iper to TD - clean. Begin pumping 10.46 Ib/bbl KW F @ 9800ft. ' 23:30 - 00:00 0.50 DRILL P PROD1 Tagged bottom @ 10,532ft. Lay in KWF while POH. 7/6/2007 00:00 - 02:20 2.33 DRILL P PROD1 Continue POH while laying in KW F. Paint EOP flag @ 9050ft. 02:20 - 02:30 0.17 DRILL P PROD1 PJSM prior to LD BHA. Flow check well - ok. 02:30 - 03:30 1.00 DRILL P PROD1 Pop off well. Break off coil from BHA. Set coil over bung hole via legs. Blow down BHA with water & air. L/D BHA in 3 sections. 03:30 - 03:45 0.25 CASE P RUNPRD PJSM prior to MU liner. 03:45 - 04:25 0.67 CASE P RUNPRD Hole is in static condition - mud @ swab valve. Hook up Farr Tongs & PU Baker T7 knack box via beaver slide. MU TIW vaive & cross over. Perform weekly function test of BOPE per AOGCC regs. 04:25 - 05:45 1.33 CASE P RUNPRD Begin running 3-3/16" liner. Baker-loc first 14 jts. j 05:45 - 09:40 3.92 CASE P RUNPRD Fill liner after first 14 jts have been run. Finish run 46 jts 3-3l16" 6.2# L-80 TC11 liner w/ 3-1/2 X nipple and BTT deployment sub MU BTf GS running tooi MU BHI MWD assy ~ 09:40 - i 1:10 1.50 CASE P RUNPRD RIH w/ liner circ Q.4/1100 and had 1/2 relurns to 5000'. After 5000' had no returns so RIFf w/o pump PVT 111 11:10 - 12:10 1.00 CASE P RUNPRD 9200' 23.7k, 8.7k RIH thru window w/o pump, ciean. See ik wt loss at window from each cementralizer. See wt loss w/ shoe at 10086' (tault). Then had several set downs when first cementralizer got to fault. Broach out fault area with first three I cementralizers. Work liner in hole w/ several set downs. Lost liner once. Had to go in high gear to get liner to 10465' and set down solid. Not making any progress due to high DLS and hard formation. PUH 100' clean at 38k. After > 10 tries, work Printed: 8/6/2007 2:44:30 PM . ~ ~ ~P AMERlCA Page 7 c~fi ~6 Opera~~~n~ ~ummary Report Legal Well Name: 1 B-08A Common Weil Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: '~ate ' From - To Hours Task Cade NPT Pha~e ' Description af C7perations 7/6/2007 11:10 - 12:10 1.00 CASE P RUNPRD past 10465', then set down solid at 10495' 12:10 - 13:10 i 1.00 CASE P RUNPRD Work to get by 10495' CTD w/o success-setting down solid. Can puil up hole 100' clean at 35k. See cementralizer catch at 10465' each time going down and getting cleaner each pass. Circ to freshen up beads occasionally w!o returns. After 20-25 ~ tries, no progress was made. Est BOL at 10480', TOL at 9060' 13:10 - 15:00 1.83 CASE P RUNPRD Release GS from liner at 1.5 bpm. Swap to filling hole from the BS. POOH w/ liner setting tool PVT 56 15:00 - 15:40 0.67 CASE P RUNPRD Flowcheck. LD liner running tools. LD MWD assy. SI swab. Install nozzle assy 15:40 - 16:30 0.83 CASE N RUNPRD Displace CT w/ 10 bbls FW. WO bleach, N2 16:30 - 17:10 0.67 CEMT P RUNPRD MIRU SWS N2. Safety mtg. MIRU bleach pup truck 17:10 - 19:20 2.17 CEMT P RUNPRD Pickle CT w/ 15 bbls bleach, 60 bbls water, 15 bbls corrosion inhibited water, 10 bbls diesel. Displace diesel w/ N2 and blowdown to tiger tank. Let coil bleed off. 19:20 - 20:45 1.42 CEMT P RUNPRD Pop off from well. Break down BHA. Remove grud screws & pull connector off of end of coil. Cut off coil. Prep end of e-line ( ~ cable for storage. Swab cable in winch tor stabbing cable. Prep ~ end off coil for internal grappie connector & pull test same with stabing winch. 20:45 - 21:00 0.25 CEMT P RUNPRD PJSM prior to unstabbing coil & lowering coil from Nordic rig. 21:00 - 22:15 1.25 CEMT P RUNPRD Unstab coil from injector & pull coil across to reel house. Secure coii on reel via shipping bar. Remove grapple & stabbing cabie from coil. Remove inner hardline from reel. Begin off loading 3" coil track tools from pipe shed. Give 24 hr notice to AOGCC for BOPE testing. 22:15 - 00:00 1.75 CEMT P RUNPRD Hook up bridge crane to reel. Retract drive plates. Lower reel down to low boy trailer. PU 2-3/8" e-less coil tubing from low boy trailer. 7/7/2007 00:00 - 00:30 0.50 CEMT P RUNPRD Finsh picking up 2-3/8" e-less coil into reel house. 00:30 - 02:25 1.92 CEMT P RUNPRD Remove & string back lifting cables. Dress end of coil & install grapple connector. Pull test grapple connector. Remove shipping bar from reel. Stab coil into horses head. 02:25 - 02:50 0.42 CEMT P RUNPRD Pull coil across & stab into injector. 02:50 - 03:50 1.00 CEMT P RUNPRD Remove grapple connector. Dress end of coil & install BTT CTC. Hook up hardline inside coiled tubing reel. Torque up drive plates to drive motors. 03:50 - 04:20 0.50 CEMT P RUNPRD Pull test BTT CTC to 30k - retorque same. Make up dart catcher. Place injector over bung hole. 04:20 - 05:05 0.75 CEMT P RUNPRD Put water in coil. Load dart & circulate around to check volumes. Coil volume is 59.8 bbls. 05:05 - 06:00 0.92 CEMT P RUNPRD Break off dart catcher & recover dart. MU test plate. PT coii & hardline. Test to 4000 psi - ok. Bleed off & install BHA. Stab onto well & open swab valve. RU cementers. 06:00 - 07:45 1.75 CEMT P RUNPRD RIH with GS / cementing BHA. Circ 1.12/530 w/ ~W while diluting 10.5# mud and taking returns to tiger tank. 8950' 21.5k, 10.Ok RIH to ball drop spot at 9035' CTD 07:45 - 08:40 0.92 ~ CEMT P RUNPRD Load 5/8" steel ball and displace w/ SW 1.52/1.3/1120 w/ open choke w/ initial returns at steady 9.7#. Return density started decreasing so incr whp to match in/out rate and aRer 20 bbls were at 100 psi. Ball over gooseneck at 53 bbls and were at 250 psi whp. SD pump trapping 400 psi. RIH to TOL and first wt loss at 9072.0' CTD. Ease stinger into liner and stack 3k @ . Printed: 8/6/2007 2:44:30 PM ` ~ ~ BP AMERICA Page 8 of 26 Operat~ons Summary Repc~rt Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: [~ate FrQm - Ta Mours Task Code NPT Phase ' Description of Operations 7/7/2007 07:45 - 08:40 0.92 CEMT P RUNPRD 9073.2'. PUH to 26k to prove were latched. Set back down, SD pump and wait for bali to tall 08:40 - 08:55 025 CEMT P RUNPRD Safety mtg re: cementing 08:55 - 09:30 0.58 CEMT P i RUNPRD Resume circ at 0.5/750 holding 400 psi whp and bail went on ~ seat. Pressure up to 3490 psi and ball seat sheared. SD i ; pump. PUH 2O.8k to verify released. Finish displace liner and I annulus of 10.5# mud 1.5/1,5/1230 holding 250 psi whp while fin wait on cementers to prep. Incr rate to 2.5/2.45/2060 w/ 150 psi whp and returns cleaned up to 8.7 ppg after 3S bbis pumped. SD pump and trap 500 psi 09:30 - 11:00 1.50 CEMT P RUNPRD Cementers pump 2 bbls FW. PT 4000. Mix on the fly and load , CT w/ 7.1 bbls 15.8 ppg 'G' cement w/ latex. Load wiper dart i and launch (not so easy when there is well pressure). Check that dart is gone. Rig displace w/ SW 1.52/1.45/1430 w/ 340 psi whp. Got some crude back from bottoms up. See dart latch up at 61.3 bbls. Displace to seat 1.5/1430 at 71.9 bbls holding choke at +/-350 psi to maintain 1/1 returns. Chk floats, okay. Unsting w/ 21.4k and 500 psi. Saw last returns of KW F ~ from liner at surface 11:00 - 12:30 1.50 CEMT P RUNPRD POOH circ at pipe displacement of 0.55/550 while SI @ choke to let well dictate SI pressure. Flnal SIP 430 psi. Close MV and SV. Bleed off whp 12:30 - 12:45 0.25 CEMT P RUNPRD Safety mtg re: LD BHA, welding in reelhouse, N2 blowdown 12:45 - 13:15 0.50 CEMT P RUNPRD LD BHA Weld heater core in reelhouse j Stab back on w/ jet nozzle 13:15 - 14:30 1.25 RIGD P ~ RUNPRD Displace CT w/ 10 bbls diesel followed by N2 and jet stack while taking returns to tiger tank. Bleed down 14:30 - 16:30 2.00 RIGD P RUNPRD Cut off CTC. Install internal grapple and pull CT back to reel 16:30 - 17:30 1.00 RIGD P RUNPRD SWS secure reel and RD hardline. Load out 2-3/8" E-free CT onto VECO lowboy Nordic convert BOPE for 2" CT and tools 17:30 - 19:30 2.00 MOB P PROD2 Remove gooseneck from injector and set injector off to side for ~ conversion. RU hardline & bulk head & junction box inside of ' reel. Clean out high pressure filter on hardline. 19:30 - 00:00 4.50 BOPSU P PROD2 Start BOPE test. 7/8/2007 00:00 - 01:35 1.58 BOPSU P PROD2 Complete BOPE test. The AOGCC waived their right to witness the BOPE test 01:35 - 03:00 1.42 MOB P PROD2 Pick up injector & stab onto stuffing box. Prep end of coil for internal grapp(e. Hook up grapple cable to winch & install ~ internal grapple inside coil. 03:00 - 03:10 0.17 MOB P PROD2 PJSM prior to stabbing pipe. 03:10 - 03:57 0.78 MOB P PROD2 Pull coil across & stab pipe into injector. Put coil in levelwind. Adjust gooseneck. 03:57 - 05:00 1.05 MOB P PROD2 Swap out cable for winching. Move injector over bung hole & fill coil with SW. 05:00 - 05:30 0.50 MOB ~ P PROD2 Prep end of e-line cable. Pick up lubricator & stab onto well. 05:30 - 05:45 025 MOB P PROD2 Conduct slack management. 05:45 - 07:00 1.25 MOB P PROD2 Pop off & check for wire at end of coil. Cut off 66' of CT and dispose. Install CTC. PT @ 35k 07:00 - 09:00 2.00 DRILL P PROD2 Install and test BHI UQC. PT 3500 psi 09:00 - 10:00 1.00 BOPSU P PROD2 Pump CT vol of slack forward stabbed onto well 2.58/4000. PT packoff and inner reel valve as part of BOPE test @ 300/3500 Printed: 8/6/2007 2:44:30 PM . ~ ~ BP AMERIC~ .,N~. ~.~. Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 6/27/2007 Rig Release: 7/26/2007 Rig Number: ~ ~ Spud Date: 6/27/2007 End: 7/26/2007 ~~~~ons 1 7/8/2007 09:00 - 10:00 1.00 BOPSU P PROD2 psi. Check well pressure at 320 psi 10:00 - 10:30 0.50 DRILL ~ P PROD2 Bring BTT tools to floor. MU mill and SR to motor 10:30 - 10:45 0.25 DRlLL P ~ PROD2 Safety mtg re: deploy w/ 320 psi 10:45 - 11:50 1.08 DRILL P PROD2 Pressure deploy milling assy 11:50 - 12:15 0.42 DRILL P PROD2 Nordic crew change Safety mtg re: deploy w/ 320 psi w/ fresh crew 12:15 - 13:20 1.08 DRILL P PROD2 Finish pressure deploy BHA 13:20 - 15:05 1.75 DRILL ~ P I PROD2 RIH w/ BHA #12 circ thru mill 0.4/650 taking SW/crude returns to tiger tank while holding 400 psi whp 15:05 - 15:50 0.75 DRILL P PROD2 RIH thru TOL w/ no wt loss. Log tie-in down from 9200' 0.42/660 while holding 400 psi whp. Still taking crude returns to tiger tank. Corr -18' 15:50 - 16:15 0.42 DRILL P PROD2 RIH to landing collar circ 0.5/800 w/ 400 psi whp and taking I ~ crude returns to tiger tank. Set down at 10373' I 16:15 - 16:35 0.33 DRILL P PROD2 Start pump 1.7/3330 and ease in hole w/ a little MW and drill minor cement at 150-350'/hr w/ 250 psi whp or 9.8 ECD. Reduce rate to 1.50/2700 due to vibration 16:35 - 19:45 3.17 DRILL P PROD2 Tag PBD at 10444.9'. Drill LWP 1.5/2680 w/ 250 psi whp. , Have one 8k overpull, then start having stalls and MW at 10443.6'. Note: Tagged depth is within a foot of estimated drillers depth for liner placement. Confirms TOL Q 9060' and BOL @ 10480' ', Still taking crude returns to tiger tank. After getting somewhat ', clean returns (0.1 bpm extra), iYs obvious that 250 psi whp or 'i 9.8 ECD is too low with a low viscosity fluid. Increase whp to 400 psi to give 3350 dhp or 10.0 ECD until crude and gas is out of system. Obviously the perfs behind the liner did not get covered by cement . . . I 19:45 - 20:15 0.50 DRILL P PROD2 Wiper trip to 10,200ft - dean. RIH & surge liner - clean. 20:15 - 21:00 0.75 DRILL P PROD2 Drill LWP 1.74/3171 w/400 psi whp. Take returns outside & clean pits while pumping from vac truck. Aluminum & cement in returns. 21:00 - 00:00 3.00 DRILL P PROD2 Pump bio sweeps. Bring returns back inside, fill pits with new sea water. 7/9/2007 00:00 - 00:45 0.75 DRILL P PROD2 Drilled out cement inside liner to shoe. Slow progress @ 10,480ft. 00:45 - 03:25 2.67 DRILL P PROD2 Broke through shoe & cement. RIH to TD @ 20ft/min. 03:25 - 06:15 2.83 DRILL P PROD2 Tagged bottom @ 10,532ft. PU back to shoe & dress up float collar & latch collar area. Start pumping Flo Pro Q lay in from TD. 06:15 - 06:30 0.25 DRlLL P PROD2 Crew change/safety mtg 06:30 - 08:15 1.75 DRILL P PROD2 Pressure undeploy milling assy w/ 530 psi 08:15 - 09:45 1.50 DRILL P PROD2 Prep and test res tool for addition to BHA Cut off 25' of slickline and rehead and test 09:45 - 10:00 0.25 DRILL P PROD2 Safety mtg re: pressure deploy drilling assy 10:00 - 11:40 1.67 DRILL P PROD2 MU 1.1 deg motor on MWD assy w/ resistivity and pressure deploy w/ 500 psi 11:40 - 13:30 1.83 DRILL P PROD2 RIH w/ BHA #13 circ thru bit 0.34/1200 following pressure schedule 13:30 - 13:50 0.33 DRILL P PROD2 Log tie-in down from 9285', corr -16' 13:50 - 14:15 0.42 DRILL P PROD2 RIH thru 3-3/16" liner circ 0.44/1550 following pressure schedule 14:15 - 14;25 0.17 DRILL P PROD2 Log down from 10470' to tie to GR in 3-3/16" at 10445' and Printed: 8/6/2007 2:44:30 PM • ~ ~ BP AMERICA Page 10 of 26 Qpreration$ Summary Rep~ort Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27l2007 Event Name; REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date : From -'Fo Hours Ta~k Cocte NPT Phase D~~cr~~tiQn af Qpe~atf6~s -- -- 7/9/2007 ~ 14:15 - 1425 0.17 DRILL P - ---j PROD2 I - were on depth 14:25 - 14:30 0.08 DRILL P PROD2 Start pump 1.67/3280 and wiper to TD tagged at 10530.8' PVT 14:30 - 16:45 225 DRILL P PROD2 298 Drill from 10531' 1.66/3260/85R w/ 100-200 psi diff, 1-2.5k wob ~ w/ 175 psi whp induced to give 3500 psi or 10.5 ECD. Drili at ~ 102 deg to 10690' PVT 305 16:45 - 17:45 1.00 DRILL P PROD2 Wiper to 9000' was clean 17:45 - 18:30 0.75 DRILL P PROD2 RBIH at 0.5/1475 following pressure schedule @ 50'/min - clean. 18:30 - 21:10 2.67 DRILL P PROD2 Drill from 10690' 1.61/3210/90R w/ 100-200 psi diff, 0.75-1.2k wob w/ 175 psi whp induced to give 3500 psi or 10.5 ECD. 10-60 ft per hr ROP. PVT 306 21:10 - 21:30 0.33 DRILL P PROD2 Wiper to 10480' was clean. 21:30 - 21:50 0.33 DRILL P PROD2 Wiper to bottom - clean. 21:50 - 00:00 2.17 DRILL P PROD2 Drill from 10830' 1.61/3210/90L (Begin steering to left) w/ 100-200 psi diff, 0.75-12k wob w/ 175 psi whp induced to give 3500 psi or 10.5 ECD. 10-60 ft per hr ROP. PVT 304 7/10/2007 00:00 - 01:30 1.50 DRILL P PROD2 Drill from 10,926' 1.64/3210/90L w/ 100-200 psi diff, 0.75-1.1 k ~ wob w/ 175 psi whp induced to give 3500 psi or 10.5 ECD. 10-60 ft per hr ROP. PVT 296 01:30 - 03:05 1.58 DRILL P PROD2 Wiper to 8000' - clean. 03:05 - 03:30 0.42 DRILL P PROD2 RBIH at 0.5/1475 following pressure schedule @ 50'/min. Cannot maintain pressure schedule - annular pressure keeps climbing, suspecf cuttings in annulus however returns are clean.... ~ Stop @ 9000ft & open EDC & increase pump rate to 1.9 bbl/min. 03:30 - 03:35 0.08 DRILL P PROD2 Log for tie-in C~ 9280ft. (+1ft corr). Lots of cuttings & rubber coming across the shaker - suspect rubber from liner wiper plug. 03:35 - 04:15 0.67 DRILL P PROD2 Wiper to bottom - clean. 04:15 - 06:00 1.75 DRILL P PROD2 Drili from 10,955' 1.62/3160/120L w/ 100-200 psi diff, 0.75-1.75k wob w/ 175 psi whp induced to give 3500 psi or 10.54 ECD. 40-60 ft per hr ROP. PVT 281 06:00 - 09:40 3.67 DRILL P PROD2 Driil from 11000' in what acts like siderite 1.7/3280/150-170L w/ 100 psi diff w/ 1.0-2.Ok wob (w/ -6k surface wt) at 90 deg w/ 175 psi induced whp to give 3500 psi dhp or 10.66 ECD at steady, but <10'/hr penetration rate. Drill to 11028' and hole momentarily took a one bbl drink twice, and then had a stall ~ and overpull. Have now crested and are at 90 deg and plan to start the drop. Assume probably a formation change and possibly a projected fault. Also, res tool and GR are trending toward 'D' looking numbers . . . 09:40 - 10:45 1.08 DRILL P PROD2 Wiper from 11028' to clean up wellbore of cuttings. Had a few minor OP's in OH due to TF 180 out. Had MW and OP the last 20' before the 3-3/16" shoe 10:45 - 11:40 0.92 DRILL P PROD2 Open EDC at 9000'. PUH to 7000' circ at 1.9/3000 to remove solids from 4-1/2" tubing Meanwhile discuss and decide to sidetrack 11:40 - 13:00 1.33 DRILL P PROD2 Finish POOH circ thru EDC 1.94/2990 from 7200' DPS is working intermittently 13:00 - 14:45 1.75 DRILL P PROD2 Pressure undeploy w/ 350 psi 14:45 - 16:20 1.58 DRILL P PROD2 MU & test BHI tools on catwalk - ok. Printed: 8/6/2007 2:44:30 PM ~ ~ ~ BP AMERiCA Page 11 af ~6 ((~p~rations ~~mmary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: ~; Date From - To Hours Task Code NPT Phase Description af C}peration~ _--~--- --- 7/10/2007 I 16:20 - 16:35 I 0.25 DRILL P PROD2 PSJM prior to pressure deploying. 16:35 - 17:55 ~ 1.33 DRILL P PROD2 Begin pressure deploying BHA. I 17:55 - 18:50 0.92 DRILL P PROD2 Stab injector onto well head. Set depths. ~ 18:50 - 20:30 1.67 DRILL P PROD2 RIH with OHST BHA. Town has extended TD of the well to ~ r 11,500 ft Recieved new targeys from Geologist 20:30 - 20:45 0.25 DRILL P PROD2 Log tie in at 9,280 ft Corrected -18 ft 20:45 - 21:56 1.18 DRILL P PROD2 RIH to break off the lamp shade. Tagged at 11,020 ft and broke oft lamp shade. PUH to 10856 ft 21:56 - 00:00 2.07 DRILL P PROD2 Trough Sidetrack from 10,856 ft to 10,886 ft at 60 fph with 150R TF 1st Pass DHWOB = 0.52k to 0.90k with motor work. At 10,879 ft, inc in WOB to 1.0 k and at 10,883 ft the WOB inc to 1.9k wo/ ~ ; motor work PU wt = 21.8 k. ~ ~ Backed reamed 10,886 ft to 10,856 ft at 60 fph w/ TF at 150R 2nd Pass: 10856 ft to 10,886 ft at 60 fph. Seeing motor work and WOB at 10,884 ft to 10.886 ft. Backed reamed 10,886 ft to 10,856 ft at 60 fph w/ TF at 150R. 3rd Pass 10,856 ft to 10,886 ft. Started WOB at 10,884 ft Qp 1.61 / 1.64 bpm, CTP = 2952 psi PVT 240 bbPs BHP = 3447 psi = 10.47 ppg ECD 7/11/2007 i 00:00 - 00:45 0.75 DRILL P PROD2 OHST Trough 10,856 ft to 10,886 ft 00:45 - 03:10 2.42 DRILL P PROD2 Time milling at 0.1 ft / 6min starting at 10,885.51 ft to 10,887.50 ft. Seeing WOB Qp = 1.62 / 1.61 bpm CTP = 2926 psi. At 10,887.50 ft started pushing at 2 ft / 6 min 03:10 - 04:22 1.20 DRILL P PROD2 Coiled tubing stacking in welibore. Bit jumped the sidetrack lip. I RIH to 10,889 ft and just stack CT weight. Back ream from ~ 10,888 ft to 10,856 ft and try to re-establish the lips. RIH at 60 fph with TF at 150 R to establish lip. 04:22 - 06:00 1.63 DRILL P PROD2 Stopped at 10,885.90 ft with 0.45k WOB to time drill. Qp = 1.60 / 1.60 bpm at 2926 psi PVT = 238 bbl CT is just stacking. PUH to 10870 ft and RIH at 60 fph (150 deg TF) i Started taking WOB at 10,884.8 ft. Stopped at 10,886.ft and i use just WOB to sidetrack. Lost motor work at 10,886.75 ft. PUH and restart 06:0~ - 12:25 6.42 DRILL P PROD2 Starting @ 10886.9ft, PU & get coil WT to break over. Time drill 0.1ft deeper than previous depth in an attempt to prevent coil WT from stacking out 1fUhr for the 1st foot. At 10,888.1ft appears to be taking W OB (200#), allow to drill off & time driil ~ @ 2fUhr starting at 10,888.1ft, however continue to PU & get j WT back it that time frame. At 10,889ft start time drilling @ ~ 3fUhr. 12:25 - 13:20 0.92 DRILL P PROD2 Near-bit inclination shows 0.5 degree less versus previous well bore path. Due to coil life constraints, complete rest of time drilling without picking up each time. Increase ROP to 10fVhr i from 10,893ft to 10,894ft. Increase ROP to 15fUhr from 10, 894ft. 13:20 - 14:40 i.33 DRILL P PROD2 Seems to be stacking out, PBU & R1H. Getting 750# WOB @ ~ 10fUhr with near bit INC dropping, continue to drill ahead. Printed: B/6/2007 2:44:30 PM ~ ~ ~ $P AMERICA Page i2 of 26'' Opera#`ro'n~ Summary Repar# Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date ' Frorn - To Hours Task Code NPT Phase ' Qescription of Operations 7/11/2007 14:40 - 15:00 0.33 DRILL P PROD2 Can't make any more hole, stacking weight @ surface & have ~ 2500 # WOB, suspect hanging up on bend of motor. PU & ~ back ream section to clean up side track entrance from ~ 10,901ft to 10,875ft @ 240TF (have motor work & over pull). RBIH & ream with 150TL to bottom. 15:00 - 15:20 0.33 DRILL P PROD2 Back ream from 10,901 ft to 10,875ft with 330TF. RBIH & ream with 150TL to bottom. 15:20 - t5:30 0.17, DRILL P PROD2 RIH to 10,901.5ft & seeing motor work now. Attempt to drill ahead. Drili to 10,902.6ft, stack weight & not driiling. 15:30 - 15:50 0.33 DRILL P PROD2 Back ream from 10,902.6ft to 10,875ft with 90TF. 15:50 - 17:30 1.67 DRILL P PROD2 Set down @ 10,900ft now. POH for lateral BHA following pressure schedule. Open EDC & POH. 17:30 - 17:48 0.30 DRILL P PROD2 BHI tools failed while POH. Continue to POH, adjust WHP to keep returns slightly less than 1 for 1. Stop at 4700ft, secure reel, PJSM & trouble shhot junction box inside reel. 17:48 - 18:45 0.95 DRILL P PROD2 Problem is down hole. Continue to POH. Closed tool at 1350 ft. BHI MU new tool string 18:45 - 23:10 4.42 DRILL P PROD2 OOH, Held PJASM and Pressure undeploy BHA with 400 psi SIW HP Instailed and tested new tools string with agitator. tested CT eline "ok" MU Set injector on the floor. Cut off 160 ft slickline after finding a bad kink at the reel. Reheaded slickline ~ tool. PU and pressure deploy BHA 23:10 - 00:00 0.83 DRILL I P PROD2 RIH as per Pressure Schedule 7/12/2007 00:00 - 01:12 1.20 DRILL P PROD2 RIH to 9280 ft 01:12 - 01:30 0.30 DRILL P PROD2 Tie-in at 9300 ft Corrected -18 ft. 01:30 - 03:07 1.62 DRILL P PROD2 RIH to 10,350 ft. Closed EDC and Orient TF to HS Set down at 10,848 ft and then fell through. RIH at Qp = 1.51 bpm Tagged at 10,901 ft 03:07 - 03:30 0.38 DRfLL P PROD2 Drill lateral from 10,901 ft to 10,930 ft Hole angle fell off to 87 deg Qp = 1.51 / 1.54 bpm CTP at 3340 psi free spin PVT = 290 bbl Density = 8.7 / 8.72 ppg BHP = 3418 psi = 10.4 ppg ECD DHWOB = 0.5-1.0 klb ROP = 80 fph 03:30 - 04:00 0.50 DRILL P PROD2 Back reamed OHST area at 150R TF to 10,845 ft 04:00 - 05:45 1.75 DRILL P PROD2 Drili lateral from 10,930 ft to Turned TF to 90L from 90R at 10,930 ft Turned TF up to 45L to try and buiid Qp = 1.51 / 1.54 bpm CTP at 3,340 psi free spin i PVT = 298 bbl, Density = 8.7 / 8.72 ppg BHP = 3418 psi = 10.4 ppg ECD WHP = 170 psi DHWOB = 0.5-1.0 kib ROP = 30-60 fph PU ai 10,998 ft to check survey. hole angle @ 85.89 deg. Turned TF to 10L 05:45 - 07:00 125 DRILL P PROD2 Wiper to BOL @ 10,480ft - ciean. RBIH to bottom. 07:00 - 08:10 1.17 DRILL P PROD2 Drill lateral from 11,056 ft with TF at 45L to try and build ~ Qp = 1.51 / 1.54 bpm CTP at 3,340 psi free spin PVT = 260 bbl, Density = 8.7 / 8.72 ppg BHP = 3499 psi = 10.62 ppg ECD WHP = 176 psi DHWOB = 0.5-1.0 klb ROP = 40-75 fph 08:10 - 10:45 2.58 DRiLL P PROD2 ECD's are 10.7, losses are 20bbls for 3 hrs. W iper to 8,OOOft I I following pressure schedule. Printed: 8/6/2007 2:44:30 PM . ~ ~ $P AME-R1CA Page 13 of 26 Opera#ians Surnmar~ Re~c~rt Legal Wel! Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: ' Date From - To Hours Task Code NPT Phase Deseription of Operatians 7/12/2007 10:45 - 10:50 0.08 DRILL i P PROD2 Log for tie in (Oft). 10:50 - 11:40 0.83 DRILL i P I PROD2 W iper to bottom. 11:40 - 12:25 0.75 DRILL ~ P PROD2 Conduct Mud Swap. Drill lateral from 11,119 with TF of 60L to 90L Qp = 1.63 / 1.66 bpm CTP at 3,565 psi free spin PVT = 231 bbl, Density = 8.72 / 8.65 ppg BHP = 3499 psi = 10.67 ppg ECD WHP = 176 psi DHWOB = 0.5-2.0 klb ROP = 40-75 fph 12:25 - 12:35 0.17 DRILL ~ N DFAL PROD2 Trouble shoot resistivity tool while POH @ 85fUhr. Tools I working now. 12:35 - 12:50 0.25 DRILL % P ~ PROD2 Log from 11,125ft to TD for GEO. 12:50 - 13:40 0.83 DRILL P PROD2 Drill lateral from 11,155 with TF of 60L to 90L Qp = 1.63 / 1.66 bpm CTP at 3,565 psi free spin PVT = 231 bbl, Density = 8.67 / 8.67 ppg BHP = 3477 psi = 10.57 ppg ECD WHP = 176 psi DHWOB = 0.5-2.0 kib ROP = 40-75 fph 13:40 - 13:50 0.17 DRILL P PROD2 Slow drilling & stacking WT & no motor work. PU - 15 k# over pull. Assume we have crossed a geological phenomenon, aka: a fault. Pull up 100ft. 13:50 - 14:40 0.83 DRILL ; P ~ PROD2 Set down @ 11,179ft & motor work. ~ Drill lateral from 11,179 with TF of 120L Qp = 1.64 / 1.67 bpm CTP at 3,565 psi free spin PVT = 0 bbl, Density = 8.68 / 8.69 ppg BNP = 3455 psi = 10.51 ppg ECD W HP = 200 psi DHWOB = 0.5-2.0 klb ROP = 40-75 fph New mud @ surface. Continually increase WHP to maintain 1:1 returns. WHP @ 220psi & ECD 10.55. 14:40 - 14:55 025 DRILL I N DFAL PROD2 Trouble shoot resistivity tool while POH @ 85fUhr. 14:55 - 16:05 1.17 DRILL ~ P PROD2 Drill lateral from 11,211 with TF of 85L Qp = 1.61 / 1.61 bpm CTP at 3,565 psi free spin PVT = 78 bbi, Density = 8.69 ! 8.70 ppg BHP = 3473 psi = 10.57 ppg ECD WHP = 215 psi DHWOB = 1.5-2.0 klb ROP = 40-60 fph Can no longer keep drilling at 75ft/hr. Loosing motor work & WOB. Acts like drilling break every time. 16:05 - 18:00 1.92 ~RILL P PROD2 Wiper to window - clean. Wiper to bottom. 18:00 - 2025 2.42 [)RILL ~ N DFAL PROD2 BHI tool problems. POH held PJSM and discussed the hazards 20:25 - 23:05 2.67 URILL j N DFAL PROD2 Pressure Undeploy BHA, Bit good, changed out BHI's MW D tool string. trouble shoot old string and it shorted. PU new tool string and pressure deploy into wellbore at 400 psi Recieved 290 bbl of 10.2 ppg KWF for running liner 23:05 - 00:00 0.92 URILL N DFAL PROD2 RIH following pressure schedule 7/13/2007 00:00 - 00:45 0.75 [)RILL N DFAL PROD2 RIH 00:45 - 01:02 028 DRILL N DFAL PROD2 Tie-in at 9300 ft. to RA marker in whipstock. Corrected -18 ft ~ TF at HS 01:02 - 02:00 0.97 DRILL N DFAL PROD2 RIH to 10,350 ft and close EDC. or'ient TF to HS and RIH to 10,850 ft.Tagged bottom at 11,270 ft. Clean trip in the open hole 02:00 - 02:55 0.92 DRILL P PROD2 Drill lateral in putty from 11,270 ft to 11,307 ft Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin PVT = 214 bbl, Density = 8.7 / 8.72 ppg BHP = 3450 psi = 10.5 ppg ECD WHP = 200 psi DHWOB = 0- 0.5 klb Controlling ROP to a max of 100 fph. Printed: S/6/2007 2:44:30 PM . ~ ~ BP AMER(CA Page 14 of 26- Operations Summary Repart Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: ~ate Frc~m - To Hours Task Code NPT Phase Description af C?perations 7/13/2007 02:00 - 02:55 0.92 DRILL P PROD2 ~ Drilling with no WOB. But every once in a while the bit finds ; j something to push on. At 11296 ft, have 0.5 k WOB , motor I work and CT weight (02:55 - 03:05 0.17 DRILL P PROD2 Pulied tight. PU to 55k and worked free going down with low Qp. PUH and conducted 100 ft wiper trip Qp = 1.56 bpm. RIH and the hole is ratty from 11,280 ft to ~ 11,307 ft 03:05 - 03:40 0.58 DRILL P ~ PROD2 Drill lateral in putty from 11307 ft to 11,335 ft Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin PVT = 214 bbl, Density = 8.7 / 8.72 ppg BHP = 3450 psi = 10.5 ppg ECD WHP = 200 psi DHWOB = 0- 1.0 klb Controlling ROP to a max of 100 tph in this soft formation PU at 11, 325 ft, clean. PU 11332 ft, some what clean, Small 100 ft wiper The hole is acting like its getting unstable. 03:40 - 03:50 0.17 DRILL P PROD2 Drill lateral from 11,335 ft to 11,355 ft Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin PVT = 214 bbl, Density = 8.7 / 8.72 ppg BHP = 3475 psi = 10.6 ppg ECD WHP = 200 psi DHWOB = 0- 1.0 kib Controlling ROP to a max of 100 fph in this soft formation I Formation getting more compenent at 11,335 ft 03:50 - 05:10 1.33 DRILL P ~ PROD2 W iper trip to 10,500 ft and try to clean up around BHA. 05:10 - 05:45 0.58 DRILL P i PROD2 Drill lateral from 11,355 ft to 11,388 ft Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin PVT = 228 bbl, Density = 8.7 / 8.72 ppg BHP = 3480psi = 10.6 ppg ECD WHP = 212 psi DHWOB = 0- 1.0 klb Controlling ROP to a max of 100 fph in this soft formation. 05:45 - 06:15 0.50 DRILL P i PROD2 Wiper trip to 10,500 ft and try to clean up around BHA. 06:15 - 06:35 0.33 DRILL P PROD2 Drill lateral from 11,388 ft to 11,415 ft Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin PVT = 228 bbl, Density = 8.68 / 8.50 ppg BHP = 3492psi = 10.63 ppg ECD WHP = 212 psi DHWOB = 0- 0.5 klb Controlling ROP to a max of 100 fph in this soft formation. 06:35 - 06:55 0.33 DRILL P PROD2 Wiper trip. 20k over pull off bottom. Wiper 100ft. 06:55 - 07:00 0.08 DRILL P I PROD2 Drill lateral from 11,415 ft to 11,420 ft I Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin PVT = 198 bbl, Densiry = 8.68 / 8.50 ppg i BHP = 3492psi = 10.63 ppg ECD WHP = 212 psi ~ DHWOB = 0- 0.5 klb Controiling ROP to a max of 100 fph in this soft formation. 07:00 - 08:25 1.42 DRILL P PROD2 Wiper to 10,400ft. 10k over pull off bottom. Coil PU WT is - 24k. Seeing motor work @ 11,344ft & 11,255ft W iper to bottom. Access through window with no problem. RIH @ i 30fUmin, minor set down @ 11,170ft (300#). 11,212ft (300#). 11,246ft (2000#). 11,363ft (2000#) All pop free with out having to PU. 08:25 - 08:40 0.25 DRILL P PROD2 Drill lateral from 11,420 ft to 11,440 ft Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin I PVT = 198 bbl, Density = 8.70 / 8.44 ppg BHP = 3493psi = 10.63 ppg ECD WHP = 212 psi Printed: 8/6/2007 2:44:30 PM . ~ ~ _ _ _ _ BP AMERICA Pa~e 1~ af 26 (?p~erations Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date Frorn - To Hours Task Cade NPT Phase Description af Qperations 7/13/2007 I08:25 - 08:40 0.25 DRILL P PROD2 DHWOB = 0- 1.0 klb Controlling ROP to a max of 100 fph in this soft formation. ' 08:40 - 08:50 0.17 DRILL P PROD2 PU 40ft - clean off bottom. ; 08:50 - 08:55 0.08 DRILL P PROD2 Drill laterai from 11,440 ft to 11,455 ft ~ Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin ~ PVT = 197 bbl, Density = 8.70 / 8.44 ppg I BHP = 3499psi = 10.65 ppg ECD WHP = 212 psi DHW OB = 0-.65 klb Controlling ROP to a max of 100 fph in ~~ this soft formation. 08:55 - 09:10 0.25 DRILL P PROD2 PU 100ft wiper. 5k overpull off bottom, otherwise clean. RBIH ~ to bottom - clean. I 09:10 - 0920 0.17 DRILL P PROD2 Drill lateral from 11,455 ft to 11,470 ft i Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin i PVT = 195 bbl, Density = 8J0 / 8.44 ppg ; BHP = 3499psi = 10.66 ppg ECD WHP = 220 psi ~ f DHWOB = 0- 1.15 kib Controlling ROP to a max of 100 fph in i this soft formation. i 09:20 - 09:30 0.17 DRILL P PROD2 PU for 70ft wiper - 2k over pull off bottom, otherwise clean. i 09:30 - 09:55 0.42 DRILL P PROD2 Drill lateral from 11,470 ft to 11,498 ft j Qp = 1.51 / 1.52 bpm CTP at 3,253 psi free spin ~ PVT = 195 bbl, Density = 8.70 / 8.44 ppg ~ BHP = 3505psi = 10.68 ppg ECD WHP = 220 psi DHWOB = 0-.65 klb Controlling ROP to a max of 100 fph in I this soft formation. 09:55 - 10:00 0.08 DRILL P PROD2 i PU for 30ft wiper - 10k over pull otf bottom. 10:00 - 10:05 0.08 DRILL P PROD2 Drill lateral from 11,498 ft to 11,500 ft Qp = 1.51 / 1.52 bpm CTP at 3,253 psi free spin PVT = 193 bbl, Density = 8.70 / 8.39 ppg BHP = 3505psi = 10.68 ppg ECD WHP = 220 psi ~ DHWOB = 0-.65 klb Controlling ROP to a max of 100 fph in this soft formation. 10:05 - 10:45 0.67 DRILL P PROD2 TD has been achieved. PU was 10k over, 24k up wt. Wiper to 11,OOOft @ 10fUmin to clean up open hole section. Begin mixing KW F& beads & store into pits 3,4,5. Slight motor work (200psi) while POH @ 11,333ft to 11,322ft. Slight motor work (200psi) while POH @ 11,272ft to 11,260ft. 10:45 - 11:15 0.50 DRILL P PROD2 Wiper to bottom from 11,OOOft. Minor set down @ 11,245ft (work area). Continue to bottom. 11:15 - 13:50 2.58 DRILL P PROD2 Wiper to 8000ft @ 10ft/min in OH section. 20k = coil wt off bottom. 11,350ft seeing (motor work for -5ft) & 3000 Ibs overpull (23k = coii wt)- the entire length upto 11,265ft. Now seeing motor work again @ 11,260ft. RIH to work section. Slight bobble @ 11,360ft. PU from 11,365ft (22k up wt) & loosing weight down to 20k. Coil WT is upto 23k @ 11,330ft & motor work now too, falls off @ 11,325ft & WT is 23k. 13:50 - 14:55 1.08 DRILL P PROD2 Wiper to bottom. Log for final correction @ 9290ft (+2ft corr) 14:55 - 15:20 0.42 DRILL P PROD2 Log from 10,350ft to 10,550ft for CCL. Bottom of 3-3/16" liner is @ 10,479' 15:20 - 16:00 ~.67 DRI~L P PROD2 Wiper to bottom, start pumping KWF w/ beads down coil. No set downs while RIH. 16:00 - 20:00 4.00 DRILL P PROD2 Tagged bottom @ 11,500ft. Begin POOH laying in KW F. Adjust WHP to obtain returns for 1:1. Held PJSM on handiing BHA conventionally Printed: 8/6/2007 2:44:30 PM ' ~ ~ Eii~ ANIERICA Page 16 c~fi 2s Upera#ions Summary Report Legal Well Name: 1 B-O8A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27l2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code 1~PT Phase Deseription af C7peratians 7/13/2007 I 20:00 - 21:00 1.00 DRILL P PROD2 LD BHA 21:00 - 21:30 0.50 CASE P RUNPRD RU to run liner 21:30 - 00:00 ; 2.50 CASE P RUNPRD Run 2-3/8" Slotted Liner as per programme ' PU BHI CoilTrac BHA Floor Vaive drill while running liner (good) 7/14/2007 ~ 00:00 - 01:30 1.50 CASE P RUNPRD RIH with liner and coiltrac Corrected to 8100 EOP flag. -17 correction 01:30 - 02:15 0.75 CASE P RUNPRD RIH from 9167 ft . Wt check at 10,400 ft= 23.6 k, RIH and tagged 11,497 ft PU wt = 28 k i 02:15 - 02:30 0.25 CASE P RUNPRD Inc Qp and release from liner at 10,467 ft. RU to line out to log up with CCL Density = 10.2 / 10.3 ppg at 1.00 bpm 02:30 - 02:40 0.17 CASE P RUNPRD PUH logging w/ CCL to confirm top of 2-3/8" liner 02:40 - 04:35 1.92 CASE P RUNPRD POOH with CTLRT's. Held PJSM on BHA handling. 0435 - 05:15 i 0.67 CASE P RUNPRD Checked flow, LD CTLRT and Coiltrac BHA ; PU 2.70 / 2.63 W S drift tool 1423 ft long ~ 05:15 - 07:00 1.75 WHIP P WEXIT RIH with drift run while pumping max rate to clean up well bore. 07:00 - 07:35 0.58 W H~P P W EXIT Log for tie-in. (-12ft corr). Continue RIH to bottom. 07:35 - 09:30 1.92 WHIP P WEXIT POH. PJSM while POH regarding BHA handling. 09:30 - 11:30 2.00 WHIP P WEXIT Tag up. Flow check well. Pop off well. Break off BHA & blow down. Set BHA on cat walk & add HOT & reprogram tools. + Perform weekly BOP function test per AOGCC regs. Fill across the top to keep hole full. PU whipstock & BHI tools. Stab injector onto tools. Set depths. 11:30 - 13:30 2.00 WHIP P WEXIT RIH with whipstock. -50% losses while RIH. 13:30 - 13:50 0.33 WHIP P WEXIT Log for tie-in. (-13ft corr). 13:50 - 14:15 0.42 WHIP P WEXIT Resume RIH. 14:15 - 14:35 0.33 WHIP P WEXIT Log CCL to confirm placement of collars. 14:35 - 14:40 0.08 WHIP P WEXIT Pressure up to 3400psi. Set top of whipstock Q 10,337ft with 30 degree rrghY of high side. Set 2,000 Ibs down on whipstock. 14:40 - 16:40 2.00 WHIP P WEXIT POH with whipstock setting tool. Fill across the top. PJSM while POH regarding handling BHA's. 16:40 - 17:45 1.08 WHIP P WEXIT Tag up. Flow check well. Pop off well. Break off BHA & blow down. Set BHA on cat walk & remove HOT & recheck tools. Fill across the top to keep hole full. 17:45 - 18:25 0.67 WHIP P WEXIT PU BHI tools with 2-1/8" BOT straight motor & 2.74" string reamer & 2.74" mill. MU to injector & stab onto well. Set depths ~ & power up tools. ~~ A~ 18:25 - 20:10 1.75 WHIP P WEXIT RIH with window exit BHA 20:10 - 20:24 023 WHIP P WEXIT RU to tie -in Switch pumping to down the coiled tubing Corrected -17 ft 20:24 - 21:09 0.75 WHIP P WEXIT RIH. Mud pumps pressure cycling causing erriatic pressure ~ cycles . Unab~e to milil window. Called for rig electrician to ~ check SCR RIH and tagged TOWS at 10,339.3 ft without ~~` pump. PUH started MP2 and RIH and tagged TOWS at ~ 10338.9 ft 21:09 - 00:00 2.85 STWHIP P WEXIT Milling window as per BOT SOP's Qp = 1.44 / 1.30 bpm Density = 9.37 / 10.32 ppg, blending muds 10.2 down to 9.4 to use up all muds PVT = 418 bbl at 21:10 hrs ~_ ~ g~~ _~/( ~ ~ Fluid blended 9.4 ppg at at 23:30 hrs BHP = 3536 psi EDC= 10 7 . PP9 ~ Printed: 8/6/2007 2:44:30 PM ~ ~ ---_ _ __ _ EiF' AMERICA Page 17 af 26 Qperatic~r~s Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Start: 6/27/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: i i i i ~ i ~ Spud Date: 6/27/2007 End: 7/26/2007 7/15/2007 00:00 - 02:10 ~ 2.17 STWHIP, P WEXIT Milling window as per BOT SOP's ' ~!I Qp = 1.44 / 1.40 bpm i Density = 9.5 / 9.4 ppg i PVT = 411 bbls, Lossing 2.6 bph 02:10 - 03:15 1.08 STWHIP P WEXIT Milling window as per BOT SOP's Qp = 1.44 / 1.40 bpm Density = 9.5 / 9.4 ppg ~ PVT = 401 bbls, Lossing 2.6 bph 03:15 - 04:13 0.97 i STWHIP P W EXIT Driliing ratehofe from 10,344.90 ft to 10,355 ft ~ Qp = 1.45 / 1.41 bpm Density = 9.56 / 9.65 ppg PVT 402 bbp at 03:15 hrs. WOB = 0.50 to 1.5 klbf ! Geologist seen sample with the help of Sandy Lott I 04:13 - 05:30 1.28i STWHIP P WEXIT Back reaming window area from 10,355 ft 10,335 ft Motor work at 10,337 ft and 10,347 ft on back reams Set brake at 10,337.15 ft to ream out tight section (top of , ~ window). Every trip down and up we are see some motor wokr somewhere along the window exit path. 3-3/16" liner could be moving around 05:30 - 06:00 0.50 ~ STWHIP P WEXIT Ream up from 10,355ft to 10,330ft @ 1.6fVmin. Slight motor work @ 10,336ft. 06:00 - 06:30 0.50 STWHIP P WEXIT Ream down from 10,330ft to 10,355ft @ 1.6ft/min. 06:30 - 06:50 0.33 STWHIP P WEXIT Ream up from 10,355ft to 10,330ft @ 1.6fUmin. ', 06:50 - 07:00 0.17 STWHIP P WEXIT Shut down pumping & dry tag. No set downs & no overpulls. Geologist reports seeing cement in returns - firm to hard. 07:00 - 08:50 1.83I STWHIP P WEXIT POH with window miil BHA foliowing pressure schedute. PJSM prior to POH regarding pressure undeployment, BHA handling, slack management & changing out pump control reostat. Tag , up & trap 200 psi on choke. j 08:50 - 10:25 1.58 STWHIP P WEXIT Begin pressure undeploying BHA. Mill gauges out 2J4" go, 2.73" no-go. 10:25 - 14:00 3.58 DRILL P PROD3 Begin coil slack management. BHI is blowing down tools on catwalk, add HOT & resistivity to tool string. BHI testing tool string. Cut off 1000ft of coil. 14:00 - 16:10 2.17 DRILL P PROD3 Install dimple connector & puli test to 30k - good. BHI installing UQC. PT coii connector to 3500 psi - good test. 16:10 - 16:20 0.17 DRILL P PROD3 PJSM regarding pressure deploying BHA 16:20 - 18:00 1.67 DRILL P PROD3 Begin pressure deploying BHA. 18:00 - 19:50 1.83 ~ DRILL P PROD3 RIH with open EDC ST BHA 19:50 - 20:00 0.17 DRILL P PROD3 Tie-in Corrected -15.5 ft 20:00 - 20:35 0.58 DRILL P PROD3 RIH to 10,300 ft and closed EDC and orient TF to 30 R RIH and tagged first at 10,344 ft then stacked out at 10,347 ft (uncorrected) Unable to get past 10,344 ft This is the same ~ area that was repeatly reamed and backed reamed more than I usual this morning. 20:35 - 22:30 1.92 DRILL P PROD3 POOH, Held PJSM and discussed the pressure undeploy BHA with new crew 22:30 - 00:00 1.50 DRILL P PROD3 Pressure undeploying BHA 7/16/2007 00:00 - 01:40 1.67 DRILL P PROD3 Finished RD BHA 01:40 - 01:55 0.25 DRILL P PROD3 PJSM 01:55 - 02:15 0.33 DRILL P PROD3 Pressure Deploy BHA in well WHP = 250 psi ~ 02:15 - 03:55 1.67 DRILL i P PROD3 RIH with window dressing BHA Printed: 8/6/2007 2:44:30 PM ~ ~ BP AMER~i~CA Page 18 ot 26 Operations Summa~y Repvrt Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Date ' Fram - To Hours Task Code NPT Phase Description of Qperations 7/16/2007 03:55 - 04:30 0.58 DRILL P PROD3 Tie-in at 9280 ft. Closed EDC at 10,300 ft 04:30 - 06:00 1.50 DRILL I~ P PROD3 RIH and worked way through whipstock area. j Ream through at Qp = 1.52 bpm. 50 psi motor work at 10,342 ~ ' j ft, then fell off in 2 ft. '~ Took an little CT weight and some motor work at 10,347 ft. , Tagged bottom at 10,355 ft i Backed reamed from 10,349 ft to 10,242 ft. Clean. Reamed once more from 10,342 ft to 10,347 ft. Clean. Reamed back ~ down to 10,350 ft and clean. Backed reamed and motor work ~ i at 10,347 ft. This thing isn't consistant. 06:00 - 08:00 2.00 i DRILL ~ P i PROD3 Ream through whipstock area from 10,342ft to 10,350ft at Qp = ~ 1.52 bpm. Seeing motor work at 10,347ft. Park @ 10,347ft & 'i let drill off (75 psi motor work, 5 min to drill off). Ream up & down @ varing speeds from 1fVmin up to 15fUmin from 10,350ft to 10,340ft. 08:00 - 09:50 1.83 DRILL ~~ P PROD3 Back ream. Park @ 10,336.46ft & let drill off (150 psi motor ~ work, 5 min to drill off, not showing any WOB via BHI's screen). j ~ Continue to backream upto 10,330ft. RIH & ream down @ ~ 20ft/hr. Park @ 10,338.73ft (50 psi motor work, 5 min to drill i off, not seeing any WOB via BHI's screen). Inch our way down, park @ 10,338.86ft (100 psi motor work, 5 min to drili off, not seeing any WOB). Park Q 10,339.09ft (150psi motor work, no WOB). Continue to RIH @ 20ft/hr, no other set downs or motor work. Tag bottom @ 10354.75ft, 10,349ft is off bottom upward direction. 09:50 - 10:50 1.00 DRILL i P PROD3 Ream down @ 2.5ft/min from 10,325ft. Slight pressure bobble @ 10,339ft. Ream up @ 2.5ft/min from 10,351ft. Slight ~, pressure bobble @ 10,336ft. Reduce pump rate to 0.25bpm & RIH, slight pressure bobble Q 10,339ft. PUH while pumping @ 0.25 bpm slight pressure bobble Q 10,336ft. Trap 200 psi on well. RIH & dry tag - smooth both ways. 10:50 - 12:45 1.92 DRILL P PROD3 POH following pressure schedule. PJSM regarding pressure undeployment of BHA. 12:45 - 13:45 1.00 DRILL P PROD3 Pressure undeploy BHA. 13:45 - 15:30 1.75 DRILL j P PROD3 LD BHI tools on catwalk, Milk motor. Mill gauges 2.74" go, 2.73" no-go, string reamer has more wear. Blow down & purge BHI tools. Connect orientator & resistivity to tool string. Test tool on catwalk. 15:30 - 15:40 0.17 DRILL P PROD3 PJSM regarding pressure deployment of BHA. 15:40 - 17:00 1.33 DRILL P PROD3 Pressure deploy BHA - 2.3 degree motor & HCC BC bit & BHI ; tools. 17:00 - 18:40 1.67 DRILL I P PROD3 RIH with BHA. 18:40 - 18:55 0.25 DRILL ~ P PROD3 Log tie in and correct -16 ft 18:55 - 19:20 0.42 DRILL P PROD3 RIH to 10,300 ft and close EDC and orient TF to 30deg R Tagged at 10355 ft ' ~~ 19:20 - 21:30 2.i7 DRILL P PROD3 Drilling Build Section 1B-08 L101 TF at 80-90R n `,,0` Qp = 1.52 / 1.48 bpm ~~' p~l i CTP = 3000 / 3200 psi BHP = 3604 psi = 10.85 ppg ECD PVT = 359 bbl Found RA Marker at 10342 ft 21:30 - 21:50 0.33 DRILL P PROD3 Smelled smoke by ops cab, PUH while investiagation is taking i place. Vent sump above boiler is the culprit Smell coming from i Printed: S/6/2007 2:44:30 PM ~ ~ BP AMERICA ' Page 19 of 26 :Operations Summary t~ep~rt Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ' From - Tc~ Hours Task Code 7/16/2007 21:30 - 21:50 0.33 DRILL I P 21:50 - 23:10 I 1.331 DRILL I P 23:10 - 00:00 I 0.831 DRILL I P 7/17/2007 I 00:00 - 01:30 I 1.501 DRILL I P 01:30 - 02:15 I 0.751 DRILL I P 02:15 - 05:50 I 3.581 DRILL I P 05:50 - 06:55 1.08 DRILL P 06:55 - 07:20 0.42 DRILL P 07:20 - 09:15 1.92 DRILL P 09:15 - 10:30 1.25 DRILL P 10:30 - 11:45 1.25 DRILL P 11:45 - 13:30 1.75 DRILL P 13:30 - 15:00 1.50 DRILL P 15:00 - 17:00 I 2.001 DRILL I P Spud Date: 6/27/2007 Start: 6/27/2007 End: 7/26/2007 Rig Release: 7/26/2007 Rig Number: NPT Phase ' Descript~on of ~perations PROD3 motor # 2 generator side, smells like rubber burning. SD Motor #2 and stated Motor #1 Found copper motor winding around the traction motor. PUH to 9300 ft to tie in and locate the RA Marker in the whipstock. j PROD3 , Tie in at 9300 ft. (Corrected 0.5 ft). RIH Electrican found the exiciter (rotator / stator) on Motor 2 winding came apart. Running on engine 1 and 3 RIH and tied in to RA marker Found RA Marker at 10343 ft TOWS at 10,337.65 ft TOW at 10,337.65 ft RA Marker at 10,343.00 ft BOW at 10,342.85 ft PROD3 Drilling Build Section 1 B-08 L101 TF at 80-90R Qp = 1.52 / 1.48 bpm Density = 9.52 / 9.58 ppg ~ CTP = 3000 / 3200 psi BHP = 3604 psi = 10.85 ppg ECD PVT = 359 bbf Lost Generator #1 Shut down drilling, lower pump pressure. PUH. Restarted generator The cards in the SCR panel of Gen ~ 1 caused the problem when LOTO MP2 This has been a ongoing problem with wore out cards or card holders in SCR panel. Presently down to two motor. PROD3 Drilling Build Section 1 B-08 L101 TF at 80-110R Qp = 1.52 / 1.48 bpm Density = 9.52 / 9.58 ppg CTP = 3000 / 3200 psi BHP = 3604 psi = 10.85 ppg ECD ROP at 100 fph PROD3 Wiper trip. Had to pull above the WS and lock in TF at 30R for us to pass the high DLS area below the window. After 10,360 ft the hole in good shape. PROD3 Drilling Build Section 1 B-08 L101 TF at 80-130 R Qp = 1.52 / 1.48 bpm Density = 9.52 / 9.58 ppg CTP = 2900 / 3200 psi BHP = 3630 psi = 10.89 ppg ECD ROP at 80-100 fph PROD3 POH following pressure schedule. PROD3 Log for tie-in @ 9280ft (+1ft corr). PUH to 8900ft & log down to determine top ot 3-3/16" liner. PROD3 POH following pressure schedule. PJSM while POH regarding pressure undeployment. PROD3 Begin pressure undeployment of BHA. PROD3 Begin pressure deployment of BHA. PROD3 RIH with 1.1 degree motor & BHI tools. PROD3 Log for tie-in (-15ft). PUH. Trap 200 psi on well head, stop pumping. Log 4-1/2" tubing & top of 3-1/16" liner. PROD3 Drilling Lateral Section 1 B-08 L101 TF at 80-130 R. Started 8.6 ppg mud Swap. Qp = 1.52 / 1.48 bpm Density = 9.52 / 9.58 ppg CTP = 2900 / 3200 psi Printed: 8/6/2007 2:44:30 PM ~ ! ~ BP AMERICA P~~e 2{7 of 26 ~per~ti~ns Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date Fram - To Hottrs Ta~k Code NPT 7/17/2007 15:00 - 17:00 2.00 DRILL P 17:00 - 17:20 0.33 DRILL P i I ~ ~~ ~ 17:20 - 18:15 0.92 DRILL P I ~ i 18:15 - 00:00 5.75 DRILL P i 7/18/2007 00:00 - 04:00 4.00 DRILL P 04:00 - 05:00 1.00 DRILL P 05:00 - 06:40 i 1.67 DRILL P Q6:40 - 09:15 2.58 DRILL P 09:15 - 12:45 3.50 DRILL P 12:45 - 17:30 4.75 DRILL P 17:30 - 15:30 22.00 DRILL P I 15:30 - 00:00 i 8.50 DRILL P 7/19/2007 I 00:00 - 03:00 3.00 DRILL P 03:00 - 06:15 I 3.25 DRILL P Spud Date: 6/27/2007 Start: 6/27/2007 End: 7/26/2007 Rig Release: 7/26/2007 Rig Number: Phase Description afi C~peratic~ns r-- - -- PROD3 ~ BHP = 3630 psi = 10.89 ppg ECD ROP 0-100 fph PROD3 Drilling Lateral Section 1 B-08 L101 TF at 80-150 R. Density = 8.64 / 8.87 ppg CTP = 2600 / 3200 psi BHP = 3327 psi = 10.00 ppg ECD ROP 0-100 fph PROD3 PUH, pull 3,000 Ib heavy. Qp = 1.52 / 1.68 bpm Increased the WHP to 150 psi, BHP = 3460 psi at 10.4 ppg ECD RBIH at 10,650 ft to 10750 ft Clean . PVT = 386 bbl. PUH to base of WS at Cutting build up in the annulus with new mud in well. PUH and normal CT until 1065 ft andf started to pull 3k heavy Increased WHP to 200 psi. PUH SD and pull through window area. Open EDC at 10,330 ft Qp = 1.86 / 2.00 bpm Densiry = 8.75 8.6 ppg SW I to determine SIWHP 200 psi at 6400 TVD EMW = 9.3 ppg PROD3 Circulate bottom up while holding a WHP = 223 psi PUH Density = 8.7 ppg pressure scales and perform wiper trip while conditioning hole and new mud. 2860 psi fs at 1.87 in/1.92 out. Wait on vac trucks to complete mud swap. PROD3 Drill lateral from 10890. 2700 psi fs at 1.51 in/1.52 out 200-300 dpsi. 1-2k# dhwob. WHP/BHP/ECD: 285/3555/10.67 ppg. IA/OA/PVT: 180/49/424 bbls. i Up to 40 % chert in samples. Very slow drilling. PROD3 ~ W iper trip to window. Hole smooth. PROD3 Drilling laterai ROP at 7-9 fph, Last Sample 40% chert. Sample at 10,800 % 10% Chert and 10850 ft 40 % Chert Sample description : C1 Sand, Sand and Silty Sand, medium brown, quartzose, very fine to fine grained, disaggrated, sub-round to angular, transparent, 1 to 4% glauconite, very well sorted, PROD3 POOH due to low ROP anchorite / Cherity material PROD3 Pressure undeploy BHA WHP = 490 psi. 3 frontal insets chipped up on DOSTRDW3242.7 BC bit PU HYC DSX 3408 BC with agitator. Pressure deploy BHA in the well with 500 psi wellhead pressure. PROD3 RIH with EDC open and following pressure schedul PROD3 Log tie-in Corrected -11 ft, RIH and tagged bottom at 10897 ft PROD3 Drill Iateral from10,897 ft CTP = 3182 psi off bottom Qp=1.45/1.40bpm Density = 8.76 / 8.60 ppg BHP = 3547 psi at 10.6 ppg ECD PVT = 341 bbl ROP 5-70 fph Switch to MP 2 changed swabs in MP1 Possible drilling in concretion. Unable to make any progress for last hour. 3-4k# dhwob. 200-300 psi mtr work. PROD3 W iper trip to window. Pull out of hole to check BHA and bit. Follow pressure schedule. PROD3 Hold PJSM. Pressure undeploy BHA. Found leaking check valve. Get back on well to circulate through cfiecks to try and Printed: 8/6/2007 2:44:30 PM • . ~ ~P AMERICA Page 21 c~f 26' Opera~C~ons Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: , , Date From - To Hours Task Code NPT Phase Description of Operations 7/19/2007 03:00 - 06:15 3.25 DRILL P PROD3 clear same. Checks holding this time. Pressure undeploy. i Lay down BHA to change ball valves and floats. Change ~ motor. Change bend to 1.4 deg. MU new Hycalog bi center. 06:15 - 07:15 1.00 DRILL N WAIT PROD3 SD while Schlumnberger Installing CT Inspect on CT 07:15 - 07:30 0.25 DRILL N DFAL PROD3 PJSM on pressure deploying BHA 07:30 - 08:30 ' 1.00 DRILL N DFAL PROD3 Pressure Depioy BHA in the weil 08:30 - 10:15 i 1.75 DRILL N DFAL PROD3 RIH to 9300 ft 10:15 - 10:30 ~ 0.25 DRILL N DFAL PROD3 Log tie-in at 9300 ft Corrected -13 ft 10:30 - 11:20 ~ 0.83 DRILL N DFAL PROD3 RIH, tagged at 11024 BHI back on the clock at 11:20 hrs due to motor rubber on the shaker and resulting from poor drilling perforance. 11:20 - 13:05 1.75 DRILL P PROD3 Drill lateral from11,024 ft with TF at HS. Build hole angle up to 6,425 ft TVDss CTP = 3,300 psi off bottom Qp=1.54/1.54bpm Density = 8.76 / 8.60 ppg BHP = 3,567 psi at 10.67 ppg ECD WHP = 200 psi PVT = 309 bbl W OB 1-2 klb ROP 3- 20 fph 13:05 - 14:30 1.42 DRILL P PROD3 Stacking. PU and pulled heavy to 32k (8k over) PUH and unabie to go back in the hole. Time for a wiper. PUH to 10,360 ~ i ft. Little rough below 11,000 ft. Worked through 14:30 - 16:45 I 225 DRILL P 16:45 - 18:00 1.25 DRILL P 18:00 - 21:45 3.75 DRILL P 21:45 - 23:45 I 2.001 DRILL I P 23:45 - 00:00 0.25 DRILL P 7/20/2007 00:00 - 02:45 2.75 DRILL P 02:45 - 03:00 0.25 DRILL P 03:00 - 04:00 ( 1.00 DRILL P 04:00 - 07:29 I 3.481 DRILL I P PROD3 Drill lateral fromi t,024 ft with TF at HS. Build hole angle up to 6,425 ft TVDss CTP = 3,525 psi off bottom Qp=1.54/1.54bpm Density = 8.76 / 8.60 ppg BHP = 3,564 psi at 10.67 ppg ECD WHP = 209 psi PVT = 328 bbl WOB 1-2 kIb ROP 0- 95 fph Don't let the pump pressure drop off suddenly followed by CT weight stacking , could get stuck. Turned TF down at 11,100 ft to 120L TF PROD3 Wiper trip to window. Hole smooth. PROD3 Drill lateral from 11,183'. 3420 psi fs at 1.56 in/1.51 out. 100-200 dpsi. 1-2k# dhwob. WHP/BHP/ECD: 205/3595/10.77 ppg. IA/OA/PVT: 182/50/339 bbls. INC/AZM/TF: 86.2/13.9/155R. Having trouble with stacking. Make frequent pick ups and short wiper trips. Slow ROP to 11,238'. 5-10 fph. PROD3 Drill ahead trom 11,238'. Nice drilling break with ROP 50-70 fph. INC: 84 deg at NB. Continue to drop with TF: i65R. Driil ahead at 120 R to hoid 80 deg inc. Seeing some 300-400 psi pressure fluctuations on circ pressure. May have piugged off a jet. Continue to drill to TD of 11,300'. PROD3 Wiper trip back to 9000' PROD3 Wiper trip to 9000'. Run back in hole to 3-3/16" window. PROD3 Log gr tie in from 10370'. Add 4' correction. PROD3 Run in open hole. Displace coil to KWF flo pro (9.9 ppg) w/ 2ppb beads. Tag TD at 11,304'. 25k# up, 5k# dn wt at TD. PROD3 Circulate out of hole laying bead mud 1:1. Paint EOP flag at 9300'. Continue to circulate out of hole. Increase rate to 1.5 bpm from 9000' to surface. Slowly reduce WHP pressure as KWF fills the CT annulus. Printed: 8/6/2007 2:44:30 PM . ~ ~ ~ w Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: 7/20/2007 07:29 - 08:25 0.93 DRIL~ P 08:25 - 09:15 0.83 DRlLL P 09:15 - 10:00 I 0J51 DRILL I N 10:00 - 11:45 I 1 J51 DRILL i N 11:45 - 12:45 I 1.001 DRILL I N 12:45 - 14:25 1.67 DRILL N 14:25 - 15:00 0.58 DRILL N 15:00 - 1525 0.42 DRILL P 15:25 - 17:30 2.08 CASE P 17:30 - 19:15 1.75 CASE P 19:15 - 20:00 0.75 CASE P 20:00 - 22:15 2.25 CASE P 22:15 - 00:00 1.75 CASE P 7/21 /2007 00:00 - 00:15 0.25 W H I P P 00:15-01:45 1.50~ WHIP P 01:45 - 02:00 0.25 ~ WHIP P 02:00 - 02:15 0.25 WHIP P ~ 02:15 - 02:30 0.25 W H I P P 02:30 - 05:00 I 2.50 I W H I P I P 05:00 - 07:30 I 2.50 ~ W H I P ~ P NPT Phase De~cription of Operations PROD3 PJSM on BHA handling. LD BHA using conventional methods. Well started to fiow. PROD3 WSI at 08:25 Open vaive 17 & 18. WHP 10 psi BHI rigging up tool string for RIH to kili well 10 min 30 psi 25 min 35 psi 60 min 42 psi Steady at 43 psi for 9 minutes FLUD PROD3 PU P&C's & EDC and Nozzle BHA. Stab on well and pressured up to 100 psi and open master valve.SIWHP = 70 psi FLUD PROD3 RIH holding 100 psi on WH to circulate well clean Density = 9.65 / 9.70 ppg to start Mixed 75 sxs salt to increase the density up to 9.9 ppg FLUD PROD3 Circulat bottom up at 10,300 ft Qp=1.9/1.9bpm Density in = 10.Oppg Density dropped to 9.46 ppg and then with 50 bbl up the annulus, density out started to rise. Mixing another 75 sxs to even out the density in & out. With 99 bbl pumped density out was 10.00 ppg SD and checked flow, Well stable FLUD PROD3 POOH to run liner. OOH, Checked flow, (OK) FLUD PROD3 LD drilling BHA PROD3 PJSM RUNPRD PU MU 2-3/8" Liner and BOT CTLRT and BHI CoilTrac BHA RUNPRD RIH fillling across the top RUNPRD Subtract 11' correction at 10,300'. 24k# up, 6.5k# dn wt. Run into open hole. Tag at 11,301'. With standard -11' correction, liner is on btm. Bring on pump to disconnect. 4500 psi at 1.85 bpm. PU. New up weight is nowl9k#. TOL: 10,364'. BOL: 11,304'. RUNPRD Pull out of hole. RUNPRD LD BHA tools. MU skirted hook assembly with Baker mwd, including HOT. Orient hook to HOT. RUNPRD Continue to make up WS retrieval BHA. Stab coil. Get on well. RUNPRD Run in hole. RUNPRD Log gr tie in. No correction. RUNPRD Run in hole to top of 2-3/8" liner. 22k# up, 8k# dn wt. RUNPRD Engage whipstock. Pick up to 29k#. Jars fired. Fish or hook came free. RUNPRD Pull out of hole. Get hung up at 6130' which is in or near a seal assembly. The smallest ID here is 3.937' but there may be a lip or edge to catch top of tray. Suspect tray edge is hitting something. Using DHWOB, slack off to reduce coil weight. Orient TF to re-orient tray edge. Able to continue out of hole. Cannot determine if WS tray is still on hook. RUNPRD Get off well. No recovery. Marks on hook indicate tray may have been engaged, however brass shear screw was stiil intact. Looked at options, with shear pin still intact, decided to rerun hook Printed: 8/6/2007 2:44:30 PM . ~ BP AMERi~A ' Page 23 €~f 26' ` Operations Sumnnary R~p4rt Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: Q~te ' From - To Hours Task Code NPT Phase ' D~seription af Operations 7/21/2007 07:30 - 09:00 1.50 WHIP N DFAL RUNPRD RIH. Set down at 6,123 ft PU and tied on something. PUH and jarred on 6 times. Set string in neutral and orient TF was able ~ to rotate off. PUH free. Latch up again at 180 TF and PU and j jarred twice. Unable to move. Set string in neutral, rotated off. 09:00 - 10:00 1.00 WHIP ~ N ~ DFAL RUNPRD POOH to look at hook. Checked flow 10:00 - 11:45 1.75 ~ W HIP i N i DFAL RUNPRD ~D BHA and inspect hook. The hook looks to be inside the ~ j whipstock slot. The blue paint used as a indentify show the l hook was latched into the whipstock. The shear pin is still I attached but worn at the top. Ordered out wireline from CPAI Spot Wireline truch. Held THA on RU wireline on rig with Halliburton 11:45 - 14:45 3.00 WHIP N DFAL RUNPRD RU Halco to run LIB RIH with 3.79 LIB and tagged the 3.813" DB "Nipple @ 517 ft. POOH and change out LIB to 3.71" RIH and tagged up at 6133 ft. Jarred down, and had to jar once to get out. POOH and seen the arc of the WS at 0.9" 14:45 - 15:00 0.25 WHIP I N DFAL RUNPRD RD Halliburton Wireline 15:00 - 16:00 1.00 ~ WHIP ; N DFAL RUNPRD PU WS Fishing BHA #31 16:00 - 17:30 1.50 WHIP I N DFAL RUNPRD RIH, Wt check at 5914 ft = 12.6k1b ( i Tagged at 6,143 ft (10 ft deeper than wireline). Set setting j sleeve in WS siot and pumping down CT at 1.47 psi 3100 psi. SD and picked up, clean RIH and set 6k down and no movement downhole. 17:30 - 18:30 1.00 WHIP N DFAL RUNPRD POOH with setting sleeve 18:30 - 19:15 0.75 WHIP N DFAL RUNPRD LD BHA tools. Inspect setting tool. Removed blue paint and scarred edge of engagement shoulder indicate sleeve was engaged in WS slot. 19:15 - 22:00 2.75 WHIP P RUNPRD Hold PJSM to discuss slack management. Rig up to reverse circulate. 2.11 bpm at 3650 psi. Cut coil and e-line.(124' coil, 78' wire) TEst e-line. Re-head e-coil w/ Kendal connector. Test line again. Pressure and pull test coil connector. 22:00 - 22:45 0.75 WHIP P RUNPRD Mu overshot assembly on coil track tools. Stab coii. Get on well. 22:45 - 00:00 125 WHIP P ~ RUNPRD Run in hole. 7/22/2007 00:00 - 01:30 1.50 W HIP N ~ DFAL RUNPRD 13.5k# up, 6k# dn wt. Circulate at 1.2 bpm @ 3200 psi to lift collet sleeve during each set dn, then bleed pressure. TF 180 deg. Tag at 6144.7' Set dn 3k#. PU. Came free at 14k# up. Repeat. Same result. Orient to 270 TF. Set down again at 6144'. Wait for dn jars -fired. PU to 17k#, then free at 13k#. Orient to TF145R. Set dn again. PU. Same result at 17k# up, ', then 13k# up. Looks like we are probably wedging in along ! WS tray face. Orient to HS TF. Set dn 3k#. PU to 16-17k#. Pop free each time. 01:30 - 02:00 0.50 WHIP ~ N DFAL RUNPRD Log CCL from 5,900' down to fish. CCL log (coil depth) is 8' I deep compared to tbg detail. This confirms that fish is wedged i at btm of seal assembly at 6141' (CTD depth) or 6133' drillers depth on tbg detail. 02:00 - 02:45 0.75 WHIP N DFAL RUNPRD POOH. Discuss options with town. Decide to make setting , sleeve run with bigger mwd tools. ' Hold PJSM with crew to discuss plan forward. 02:45 - 03:15 0.50 WHIP N DFAL RUNPRD At surface. Get otf well. LD slim Inteq BHA tools. Baker overshot sleeve was pinched indicating that overshot was along side the tray. 03:15 - 05:00 1.75 W HIP j N ~ DFAL RUNPRD Bring 3" Coiltrack tools into pipe shed. Printed: 8/6/2007 2:44:30 PM • ~ BP AMERICA Page 24 of 26 Qperations Summ,ary Rep~r~t Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 ~_~_ I~---- T I„ _ I T_, I,._ , I Start: 6/27/2007 Rig Release: 7/26/2007 Rig Number: Spud Date: 6/27/2007 End: 7/26/2007 7/22/2007 03:15 - 05:00 1.75 W H I P N 05:00 - 08:30 I 3.501 WHSUR I P 08:30 - 14:30 6.00 WHSUR P 14:30 - 18:00 3.50 WHSUR N 18:00 - 19:00 1.00 WHSUR I P 19:00 - 21:00 2.00 WHIP ~ N 21:00 - 22:00 1.00 W H I P N 22:00 - 00:00 2.00 W H I P N 7/23/2007 I 00:00 - 02:45 I 2.75 ~ W H I P I N 02:45 - 03:30 I 0.751 WHIP I N 03:30 - 06:00 I 2.50 I W H I P I N 06:00 - 09:00 3.00 FISH N 09:00 - 12:15 3.25 FISH N 12:15 - 14:30 I 2.25 I FISH ~ N 14:30 - 18:30 4.00 FISH N 18:30 - 20:45 2.25 FISH N 20:45 - 21:45 1.00 FISH I N 21:45 - 23:30 1.75 FISH i N NPT Phase D~scription c~f Qperations DFAL RUNPRD Re-head e-coil for big tools. Installing 2-3/8" X 3-1l2" variable in station 3 Notify AOGCC on up coming BOP test. RUNPRD Installed 2-3/8 X 3-1/2" Variable (VBR's) Conducted test. Inspect and service injector chains RUNPRD BOP test with John Crisp AOGCC. RREP RUNPRD Blind/shears not testing. Rebuild same and instal~. No test. Rebuild again and install. Get good test. 250 psi low, 3500 psi high. RUNPRD Test inner reel valve to 250 and 4500 psi. Good test. DFAL RUNPRD Hold PJSM with crew to discuss BHA makeup. Pick up tools on to floor. MU Baker setting sleeve fishing BHA on 3" Inteq tools. Stab coil. Get on well. DFAL RUNPRD Run in hole. 15k# up wt at 6050'. DFAL RUNPRD Orient to HS to try and locate pineh point. Set dn at 6150'. Orient to LS. Set dn at 6147'. Orient to 200 deg. Set dn at 6148'. PU and orient to 160 deg. Set dn at 6149'. LS orientation was shallowest tag, assume this is with tang latached in W S slot. Attempt to orient to left and right. High torque and pipe is turning, not TF. PU to release any stored torque. RIH agin with LS TF. Set dn at 6147' w/ 8k dn wt. Jar dn. PU w/ 7k# overpull. Orient to TF: 200 deg. Set dn 8.4 k#. Jar dn. PU w/ 8k# overpull. TF keeps orienting to 200 when RIH. Assume this is the groove. Continue to jar. On average setting max coil wt dn (-6.5k#) with -8.5k# dhwob. dhwob increases to -10.8k# after jar hit. Jar 20 times. No apparent movement of WS tray. DFAL RUNPRD Puil out of hole to inspect setting sleeve. Call for 3-1/8" drill coliars from Baker Fishing. DFAL RUNPRD LD and inspect BHA. Paint on tang indicates no engagement in WS tray. Stand off due to weigh bars (3.625" od) held setting sleeve tang away from tray slot. DFAL RUNPRD Call for additional small weight bars from Baker. Load 3-1/8" drill collars into pipe shed. DFAL ( RUNPRD PU Fishing BHA Scribed hook to BHI's MWD DFAL RUNPRD RIH Set TF at 180 and Tagged at 6140 ft Worked several TF between 170 deg and 210 dge. At 170 deg tagged at 6147 ft All I I other TF the tag was 6150 ft to 6152 ft, RIH to 6,147 and i orient TF around ti look at the torque RIH and took wt at 6147 ft with 3k down Jarring. Weight fell off, tang fell out of slot. Working to get re-attached to WS at 180 R Unable to set tang in WS. 22 cycles on CT DFAL RUNPRD POOH to look at tool. PJSM and stood 3" DC back. Recovered setting sleeve. Tang broken off Sent setting sleeve to BOT in Deadhorse for modification. DFAL RUNPRD Wait on BOT to modify WS setting sleeve DFAL RUNPRD Hold PJSM with crew. MU modified setting sleeve on fishing and Inteq tools. Scribe BHA from sleeve to HOT. Stab coil. Get on well. DFAL RUNPRD Run in hole. 17.5k# up, 7.5k# dn wt at 6000'. DFAL RUNPRD Tag at 6150' CT depth. Attempt to engage fish at 180 deg TF. Set dn 5k#. Overpull to 23k# with pick up. Not engaged. ~ Orient to 200 deg TF. RIH. Tag at 6147'. Set 5k# dn. Pick up Printed: S/6/2007 2:44:30 PM R , ~ BP AMERICA Page 25 afi 2s: (3perations Sumrnary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: 6/27/2007 End: 7/26/2007 Contractor Name: NORDIC CALISTA Rig Release: 7/26/2007 Rig Name: NORDIC 2 Rig Number: ~ Date From - To Hours Task Code NPT Phase ~ De~cription c~f Operatians 7/23/2007 I 21:45 - 23:30 1.75 FISH N DFAL RUNPRD is clean. RIH. Slipped out of slot. PU and re-orient to 200 deg 1 TF. Missed again. PU and make several tries. Finally get back in at TF 210 deg. at 6147'. Begin jaring. Set 4500 # dn wt. Jar with 10k# DFiW06 several I times. Jar 28 times. Pipe now has 50 cycles over gooseneck & at reel. Need to cut pipe. Will also add more drill coilars. 23:30 - 00:00 0.50 FISH N DFAL RUNPRD Pull out of hole. 7/24l2007 00:00 - 01:00 1.00 FISH N DFAL RUNPRD Continue to pull out of hole. Hold PJSM. Tag up. Get off weil. Unstab coil. Set back injector. 01:00 - 02:30 1.50 FISH N DFAL RUNPRD Pull and stand back BHA including Inteq tools and drill collars. Setting sleeve was bent on backward near its bottom. 02:30 - 03:45 1.25 FISH N DFAL RUNPRD Rig up and cut coil. 03:45 - 05:30 1.75 FISH N DFAL RUNPRD ~ Re head e-coil. Test line. Test Kendal connector. 05:30 - 08:15 2.75 FISH N DFAL RUNPRD ' Wait on BOT to fix setting sleeve 08:15 - 08:30 0.25 FISH N DFAL RUNPRD PJSM on PU BHA and discussed the Nordic 1 incident i i 08:30 - 10:30 2.00 FISH N DFAL RUNPRD PU BHA scribe HS added 6 drill collars to BHA i 10:30 - 12:05 1.58 FISH N DFAL RUNPRD RIH, Wt Check at 6,104 ft= 20.4k up and 8.9k down. RIH and i ~ tagged the Seal nipple at 6,109 ft. Using the orienter, RIH and set down at 6,147 ft at 210R. PU and try to confirm we can pass the slot. At 150R, RIH to 6151 ft. PUH and set tang in WS and jarring down jarred 3 times and held the high fives till we went a little deeper. The whipstock is gone. RIH to 6489 ft, clean 12:05 - 13:45 1.67 FISH N DFAL RUNPRD POOH to PU the 2-3/8" Coiltrac and BOT overshot Held PJSM and discussed the hazards and talked about and confirm the flow path once tagged up 13:45 - 15:00 1.25 FISH N DFAL RUNPRD Tagged up, checked flow after confirming flow path. OK. LD Coiltrac and DC BHA. 15:00 - 16:00 1.00 FISH N DFAL RUNPRD Re configure e-line in connector for slim hole tools. Test same. 16:00 - 17:00 1.00 FISH N DFAL RUNPRD MU Baker overshot, disconnect, and jars on slim hole Inteq tools. 17:00 - 19:10 2.17 FISH N DFAL RUNPRD Run in hole with fishing assembly circ over the top. Set down at 6130' one time. Continue RIH at 40'/min looking for WS ~ 19:10 - 19:30 0.33 FISH N DFAL RUNPRD Set down at TOL at 9064' w/ 2k wob and LS TF. PUH w/ 3k ~ OP twice. Orient to HS TF. RIH and set down at 9060' w/ 2k. ~ PUH w/o OP at 21 k. Orient to LS. R~H thru TOL clean. May have W S on now 19:30 - 20:10 0.67 FISH N DFAL RUNPRD RIH thru 3-3/16" liner looking for WS. Go by window area at 10345' clean. A few minor bobbles starting at 10381'. RIH to setdown at 10476' w/ LS TF. PUH clean at 21.5k at 10'/min for 30' 20:10 - 2025 0.25 FISH N DFAL RUNPRD RBIH w/ LS TF and set 3.8k wob at 10477.8' and wo jars to fire w/o success twice. Orient to HS and repeat w/o firing jars. Assume fish is on. Any more down weight could be counter productive PVT 152 2025 - 21:25 1.00 FISH N DFAL RUNPRD POOH filiing from BS PVT 136 21:25 - 23:10 1.75 FISH N DFAL RUNPRD Pull slowly 12.Sk at 6144' and start to have OP w/ 90L TF. RBIH clean at 6.1 k. Orient to HS and pull thru w/ no overpull. Continue POH 23:10 - 23:30 0.33 FISH N DFAL RUNPRD Chk for flow. Pull fishing assy to floor and find that WS has been recovered. LD fishing assy tools. LD MW D assy 23:30 - 00:00 0.50 FISH N DFAL RUNPRD Remove orientor from MWD assy. MU drift assy 7/25/2007 00:00 - 00:25 0.42 FISH N DFAL RUNPRD MU 3.70" x 6' drift on MWD assy Printed: 8/6/2007 2:44:30 PM . • • ~ BP Afu Oper~tic~ns S~ Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From - T~ ~ Ha rr~ I Ta~k ~ C;nr~a , -~ 7/25/2007 ~ - 00:25 - 02:10 1.75 FISH N I 102:10 - 04:00 1.83 FISH N 04:00 - 04:30 0.50 FISH N 04:30 - 04:40 0.17 CASE P 04:40 - 06:15 1.58 CASE P 06:15 - 09:30 3.25 CASE P 09:30 - 10:30 ~ 1.00 CASE P 10:30 - 12:00 1.50 CASE P 12:00 - 13:00 1.00 CASE P 13:00 - 13:30 0.50 CASE P 13:30 - 15:30 2.00 CASE P 15:30 - 17:45 225 CASE P 17:45 - 18:15 0.50 CASE P 18:15 - 18:35 0.33 WHSUR P 18:35 - 19:35 1.00 WHSUR P 19:35 - 21:00 I 1.421 RIGD I P 21:00 - 00:00 ( 3.001 RIGD I P 7/26/2007 100:00 - 00:30 I 0.501 RIGD I P 00:30 - 02:00 I 1.501 RIGD I P 02:00 - 03:15 1.25 RIGD I P -II 03:15 - 05:00 1.75 BOPSUR P Start: 6/27/2007 Rig Release: 7/26/2007 Rig Number: Spud Date: 6/27/2007 End: 7/26/2007 ' NPT Phase Description of Qperations DFAL RUNPRD RIH w/ BHA #36 circ thru drift 0.29/300. RIH clean to tag at TOL at 9066' CTD. Tag twice while pump at 0.5/400 DFAL RUNPRD POOH for KB packer assy DFAL RUNPRD i Chk for flow. LD drift assy RUNPRD Safety mtg re: MU BHA RUNPRD MU KB packer assy w/ ball on seat w/ closed sliding sleeve assy and seal assy RUNPRD Run in hole with KB packer assy. 20k# up, 5.5k# dn wt. RUNPRD See seals start in at 9072'. Stack 3k# dn at 9077'. PU to neutral wt +1' more to 9072'. Pressure up coil to 3450 psi, sheared. Stack 7k# dn wt on packer to set slips. Pressure up ct anulus. Coii and annular pressure are tracking. Check all valves etc. Re-pressure. Same result. PU out of packer. Sting back in to packer. Pressure CT annulus to 2000 psi. Held solid. Top of KB packer is at 9019' RUNPRD Pull out of hole. Tag up. RUNPRD Get off well. Unstab coii. LD BHA tools RUNPRD MU nozzle assembly with stinger. RUNPRD Run in hole. RUNPRD Pull out of hole. Displace well to seawater from 9000' with 2000' diesel on top. Final SIP 650 psi RUNPRD Set injector to side while MIRU SWS N2 and CIW BPV crew POST Crew change/safety mtg re: MIRU N2 and BPV crew POST Bring CIW lubricator to floor and RU. PT @ 800 psi. Open well to 275 psi. Set 4" CIW Type H BPV. Test from below w/ weli pressure. RDMO CIW Close MV and SV (24 ea) POST Stab back on w/ injector SWS crew change/safety mtg re: N2 blow down N2 pumper begin cool down Blow down CT w! N2 and bleed off POST Install internal grapple in CT. Pull CT back to reel and secure. Begin RD hardline in reelhouse. Set injector off to side and remove packoff POST Fin RD hardline in reel house Finish clean pits and vac outside tanks DTS start laying rig mats on Spine Rd POST SWS load out used 2" reel w/ 818k RF onto VECO lowboy Nordic LD lubricator sections from derrick RDMO cuttings box POST RD floor tools, standpipe lines, etc and prep pipeshed for LD derrick. Remove Swaco choke panel and set off to side POST ND BOPE. NU tree cap and PT @ 4000 DTS RD hardline to TT Load trailers w/ misc equipment Rig Released at 0500 hrs Additional daily entries will be found under 5-28 / ~ Printed: 8/6/2007 2:44:30 PM • • a ~~ BP Alaska Baker Hughes INTEQ Survey Report .~' BA~1CElt !~lGNES INTEQ Company~ : BP AmoCO Dates 7123l2Q47 Time: t 1:AQ:21 ~~: Pa~e: !~, ~.1 Field: `Kupar~ak' Co-ardinate(NEj Refe~ence: ' VI+eIL' (38, Tru~ NE~rth Site: KRU 1 B'Pad Ver~ical (TVD) Referel~ee: ' f~KB EIE;v 1 93.Q' Well: 08 Section (VS) Referenee: Well (O.Of1N,~.6#?E,93.8&Azi) Wellpath: '~~ 7 B-~8AG1 PB1 Suriey Catcula#ion Method: ~~~ Minimum Curvature 1~?b: Qra~le 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 Datum: Mean Sea Level Geomagnetic Model: bggm2007 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 Well: 08 Slot Name: Well Position: +N/-S -5.26 ft Northing: 5969647.00 ft'~ Latitude: 70 19 40.238 N +E/-W 840.67 ft Easting : 550298.00 ft~ Longitude: 149 35 31.515 W Position Uncertainty: 0.00 ft Wellpath: 1 B-08AL1 PB1 Drilled From: 1 B-08A Tie-on Depth: 9244.48 ft Current Datum: RKB Elev 1 Height 93.00 ft Above System Datum: Mean Sea Level / Magnetic Data: 5/25/2007 Declination: 23.33 deg Field Strength: 57613 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +1~1/-S +E/-W Direction ft ft ft deg ~ 93.00 0.00 0.00 93.88 Survey Program for DeTinitive Wellpath Date: 5/25/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft -1.00 6344.00 Gyro (-1.00-8507.00) (0) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6479.66 9244.48 MWD (6479.66-9710.00) (1) MWD MWD - Standard 9256.00 11028.00 MWD (9256.00-11028.00) MWD MWD - Standard Annotation Mll TViJ! ft ft 9244.48 6447.25 TIP 9256.00 6452.55 KOP 10480.00 6489.53 3.1875" Liner 10532.00 6479.02 End 4 1/8" hole 11028.00 6410.49 TD Survey: MWD Start Date: 7/6/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD - Standard T;ed-to: From: Definitive Path ~ ~ ~~ BP Alaska Baker Hughes INTEQ Survey Report ~"~ Bm~E~ HUC'sHIE~'e ~~T~c~ CQ,mpany: BP Amoea Dater 71~312f?(37 , Time: 11:4~k:2"1 ~' Page: ~ 2 Flel~. Kuparuk Caardinate(L*fE) Reference: Well: 0$, True North S€t~_ 'KRU 1 B Pad Verficai {T~D} 12eference: RKB Elev 1 93.0 ~eY: '08 Sectinn {V~) Referenee: Weli (0':QON,Q.QQE,93.88A~i) Wellpath: . 1 B-Q8AL1 PB1 Snrvey Calcula}iou M~thod. " Minimum Curvature Db: Qracle Survey lY1D Incl Azim TVD ', Sys'FUD AI/S ~tW MapN MapE ~S DLS ' Tuol ft deg deg ft ft' ft ft ft ' ft ft deg/100#k ' 9244.48 62.55 87.66 6447.25 6354.25 -870.64 5645.78 5968814.31 555948.94 5691.77 0.00 MWD 9256.00 62.60 87.66 6452.55 6359.55 -870.22 5656.00 5968814.80 555959.16 5701.93 0.43 MWD 9297.13 64.88 78.31 6470.78 6377.78 -865.70 5692.55 5968819.57 555995.67 5738.09 21.12 MWD 9327.86 71.04 71.81 6482.32 6389.32 -858.33 5720.03 5968827.12 556023.09 5765.01 28.03 MWD 9360.74 77.31 65.20 649129 6398.29 -846.72 5749.42 5968838.92 556052.40 5793.54 27.15 MWD 9394.03 85.18 54.52 6496.37 6403.37 -830.21 5777.79 5968855.62 556080.66 5820.73 39.53 MWD 9425.07 89.88 45.41 6497.71 6404.71 -810.29 5801.50 5968875.70 556104.23 5843.04 32.99 MWD 9461.11 91.07 31.91 6497.41 6404.41 -782.21 5823.96 5968903.92 556126.50 5863.55 37.60 MWD 9491.37 90.86 20.84 6496.90 6403.90 -755.15 5837.38 5968931.07 556139.74 5875.11 36.58 MWD 9523.47 90.80 8.97 6496.43 6403.43 -724.19 5545.62 5968962.09 556147.77 5881.23 36.97 MWD 9552.86 90.71 359.52 6496.04 6403.04 -694.91 5847.79 5968991.37 556149.75 5881.42 32.15 MWD 9582.58 90.15 348.17 6495.82 6402.82 -665.41 5844.61 5969020.84 556146.37 5876.25 38.23 MWD 9611.02 91.17 338.79 6495.49 6402.49 -638.18 5836.53 5969048.02 556138.11 5866.34 33.17 MWD 9640.63 91.04 327.93 6494.92 6401.92 -611.76 5823.28 5969074.35 556124.68 5851.33 36.67 MWD 9672.60 90.18 317.54 6494.58 6401.58 -586.35 5803.95 5969099.62 556105.18 5830.33 32.61 MWD 9698.07 89.94 308.93 6494.55 6401.55 -568.92 5785.41 5969116.93 556086.53 5810.65 33.82 MWD 9730.57 90.18 298.41 6494.51 6401.51 -550.93 5758.40 5969134.74 556059.40 5782.48 32.38 MWD 9761.51 90.06 295.42 6494.45 6401.45 -536.92 5730.81 5969148.56 556031.73 5754.01 9.67 MWD 9796.29 88.90 291.99 6494.77 6401.77 -522.94 5698.98 5969162.32 555999.80 5721.30 10.41 MWD 9826.60 89.85 290.09 6495.10 6402.10 -512.06 5670.69 5969173.01 555971.44 5692.35 7.01 MWD 9885.83 89.36 284.62 6495.51 6402.51 -494.40 5614.18 5969190.29 555914.82 5634.77 9.27 MWD 9918.84 89.14 281.44 6495.94 6402.94 -486.96 5582.03 5969197.51 555882.62 5602.19 9.66 MWD 9960.44 89.36 278.34 6496.48 6403.48 -479.82 5541.05 5969204.38 555841.61 5560.82 7.47 MWD 10001.25 89.42 274.09 6496.92 6403.92 -475.40 5500.49 5969208.53 555801.02 5520.66 10.41 MWD 10030.82 90.55 272.02 6496.92 6403.92 -473.83 5470.97 5969209.90 555771.49 5490.49 7.98 MWD 10062.85 90.34 269.07 6496.68 6403.68 -473.52 5438.94 5969209.99 555739.47 5458.52 9.23 MWD 10096.15 90.31 263.65 6496.49 6403.49 -475.63 5405.72 5969207.66 55570627 5425.52 16.28 MWD 10130.63 89.32 260.08 6496.60 6403.60 -480.51 5371.60 5969202.55 555672.18 5391.80 10.74 MWD 10160.51 86.96 254.36 6497.57 6404.57 -487.11 5342.49 5969195.76 555643.11 536321 20.70 MWD 10190.57 88.50 255.15 6498.76 6405.76 -495.01 5313.51 5969187.66 555614.19 5334.83 5.76 MWD 10220.65 87.79 256.33 6499.73 6406.73 -502.42 5284.37 5969180.07 555585.11 5306.26 4.58 MWD 10250.29 89.36 256.50 6500.47 6407.47 -509.38 5255.57 5969172.91 555556.36 5278.00 5.33 MWD 10282.34 88.56 256.30 6501.05 6408.05 -516.91 5224.42 5969165.17 555525.26 5247.43 2.57 MWD 10310.29 89.45 255.81 6501.54 6408.54 -523.65 5197.30 5969158.25 555498.19 5220.83 3.63 MWD 10341.80 88.98 255.29 6501.97 6408.97 -531.51 5166.79 5969150.19 555467.74 5190.92 2.22 MWD 10371.17 89.57 254.21 6502.34 6409.34 -539.23 5138.46 5969142.28 555439.46 5163.17 4.19 MWD 10400.52 92.09 253.76 6501.92 6408.92 -547.33 5110.25 5969133.99 555411.31 5135.58 8.72 MWD 10430.08 98.59 254.01 6499.17 6406.17 -555.49 5081.99 5969125.64 555383.11 5107.94 22.01 MWD 10462.07 102.30 259.63 6493.36 6400.36 -562.67 5051.38 5969118.26 555352.55 5077.88 20.81 MWD 10485.88 102.41 264.49 6488.27 6395.27 -565.88 5028.36 5969114.89 555329.55 5055.13 19.94 MWD 10518.20 101.05 272.51 6481.68 6388.68 -566.71 4996.75 5969113.86 555297.95 5023.65 24.66 MWD 10548.50 101.34 277.31 6475.80 6382.80 -564.16 4967.14 5969116.20 555268.33 4993.94 15.57 MWD 10582.93 102.23 283.14 6468.76 6375.76 -558.19 4933.99 5969121.95 555235.14 4960.46 16.78 MWD 10614.22 101.91 288.87 6462.21 6369.21 -549.75 4904.59 5969130.19 555205.69 4930.56 17.94 MWD 10652.29 100.52 295.24 6454.80 6361.80 -535.73 4870.00 5969143.98 555171.01 4895.10 16.81 MWD 10680.31 99.00 299.44 6450.05 6357.05 -523.05 4845.48 5969156.49 555146.41 4869.77 15.74 MWD 10711.98 97.82 304.35 6445.41 6352.41 -506.50 4818.89 5969172.86 555119.71 4842.13 15.78 MWD 10741.63 97.97 309.42 6441.34 6348.34 -488.88 4795.41 5969190.32 555096.11 4817.50 16.94 MWD 10770.24 98.66 314.13 6437.20 6344.20 -470.03 4774.30 5969209.03 555074.88 4795.17 16.47 MWD 10800.63 97.91 318.17 6432.82 6339.82 -448.35 4753.48 5969230.57 555053.91 4772.92 13.38 MWD 10828.69 96.80 322.71 6429.22 6336.22 -426.90 4735.76 5969251.90 555036.05 4753.79 16.53 MWD 10860.49 96.06 316.68 6425.66 6332.66 -402.81 4715.33 5969275.85 555015.46 4731.78 18.99 MWD 10890.39 95.29 311.89 6422.70 6329.70 -382.04 4694.03 5969296.47 554994.03 4709.13 16.15 MWD Company: BP Rmc~ct~ Date: 71~~/2Qt~7 Tirne: 11:~{a:2'I Page: 3 Field: 1{uparuk' Co-ordinate(1VE)Referenee: Well: d8', True Na~th Sit"e: iCRU 'IB P~d Ver€ieal (TV~7) I2efere~see: RI~6 Elev 1 93.Q: Wells Q$ ~eetian (VS) R~Ssrence: ' klUeit (€~.OOM1l,O.OOE,93.88Azi} kVellpath: '1B-CT8/~LL1P6'4 Survey Calcniati4ri lwlethod: ' Minimum Curvature ' Db: Uracle 5urvey ' 11~I} tncl Azim TuD Sys'CVD NJS E!W M~pN l~apE ' YS DLS Taol ' ft deg deg ' ft ft ft i ft ft' ft ft': deg/100ft 10921. 99 97.01 307.55 6419.31 6326 .31 -361. 97 4669. 87 5969316.38 554969. 74 4683. 66 1470 MWD 10950. 22 96.24 301.11 6416.05 6323 .05 -346. 16 4646. 73 5969332.03 554946. 49 4659. 50 22.82 MWD 10980. 34 93.59 296.40 6413.47 6320 .47 -331. 74 4620. 43 5969346.28 554920. 10 4632. 29 17.89 MWD 11028. 00 93.59 296.40 6410.49 6317 .49 -310. 59 4577. 82 5969367.14 554877. 36 4588. 35 0.00 MWD LJ • s, ~~ BP Alaska Baker Hughes INTEQ Survey Report ~~ BA~ER ~~~H~~ ~ v~rEt~ - Company: ;BF? Amoco Dafe: 7(23120Q7 x'ime: 11:~t4:16 ` Page: ` 1 Field: '~Kup~ruk'~~ ~ ~~~ Co-ardinate(l~E} Referencet W~(I. 4$, TCUe NoCth Sife: `I~RU 1B P~d Verticai (TVDj Reference: RK8 E[4v 1 93.Q' We[I: fl8 Section (~'S) ~Referenee: '~, W~II (ti~~3QP#.,4:€~QE,92,37/~zi} Weltpath: 1B-O8AL'1 Survey Calculatian Method: ' Mini~ttum ~urv~tU1'e ' Db: Oracle _ : , --- - - --- --- ---- Field: Kuparuk ~ I ~ i Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 --_ Site: KRU 1 B Pad Site Position: Northing: 596964672 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 ' ______ J Wellr 08 Slot Name: ~I Well Position: +N/-S -5.26 ft Northing: 5969647.00 ft Latitude: 70 19 40.238 N +E/-W 840.67 ft Easting : 550298.00 ft Longitude: 149 35 31.515 W Position Uncertainty: 0.00 ft Wellpath: 1 B-08AL1 Drilled From: 1 B-08AL1 P61 Tie-on Depth: 10860.49 ft Current Datum: RKB Elev 1 Height 93.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/12/2007 Declination: 23.26 deg ( Field Strength: 57616 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 93.00 0.00 0.00 92.37 Survey Program for Definitive Wellpath Date: 7/12/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft -1.00 6344.00 Gyro {-1.00-8507.00) (0) BOSS-GYRO Sperry-Sun BOSS gyro multishot 6479.66 9244.48 MWD (6479.66-9710.00) (1) MWD MWD - Standard 9256.00 10860.49 MWD (9256.00-11028.00) (2) MWD MWD - Standard 10886.00 11500.00 MWD (10886.00-11500.00) MWD MWD - Standard Annotafion ~~ 1VID ~< 'I'~ ft €t ' 10860.49 6425.66 TIP 10886.00 6423.11 KOP 11500.00 6416.40 TD Survey: MWD Start Date: 7/12/2007 Company: Baker Hughes (NTEQ Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path ~ • ~~ BP Alaska Baker Hughes INTEQ Survey Report e~:~~~ ~~,~N~s I_NTE(;~ Campany: ';BP Amoca Date: 7123/2Qt}7 1'ime: 11: 44:16 Page: ? 2 Field: 'Kuparuk: Co-ordinate(NE) Reference: Well: O8, True N~rth Site: 'KRU 1 B Pad Vertical (TVD} Reference: RKB Eleu 1 93.0 W~~llt 08 Seetinn ~VS) lteterence: Well (O.OON,OAOE,92.3~Azij W~~llpatfis 16- 08A L1 Survey CaIculation Me#hod: + Minimum Curvatwre ` Db: br~cle Survey MD ' Incl Azim TYD ', Sys TYD Nl~ EfW MapN MapE VS ~}L.S ~'ooi ' ft deg deg ft fit ' ft ' f~ ft ft ft' deg/1:04fik ': 10860. 49 96. 06 316.68 6425 .66 6332. 66 -402 .81 4715 .33 5969275 .85 555015 .46 4727 .96 0.00 MWD 10886. 00 95. 41 312.59 6423 .11 6330. 11 -384 .98 4697 .27 5969293 .55 554997 29 4709 .18 16.15 MWD 10916. 11 88. 07 320.63 6422 .19 6329. 19 -363 .14 4676 .63 5969315 .25 554976 .50 4687 .65 36.13 MWD 10948 .83 85. 89 319.20 6423 .92 6330. 92 -338 .14 4655 .59 5969340 .11 554955 .30 4665 .60 7.96 MWD 10982. 44 82. 68 314.64 6427 .27 6334. 27 -313 .72 4632 .76 5969364. 37 554932 .31 4641 .77 16.54 MWD 11012. 19 84. 96 311.00 6430 .47 6337. 47 -293 .63 4611 .07 5969384. 32 554910 .48 4619 .27 14.38 MWD 11040. 43 88. 01 308.32 6432 20 6339. 20 -275 .64 4589 .37 5969402. 16 554888 .67 4596 .85 14.36 MWD 11071. 11 91. 32 305.74 6432 .38 6339. 38 -257 .17 4564 .89 5969420. 46 554864 .06 4571 .62 13.68 MWD 11100. 78 95. 10 303.99 6430 .72 6337. 72 -240 .24 4540 .58 5969437 23 554839 .65 4546 .64 14.03 MWD 11130. 03 99. 01 301.71 6427 .13 6334. 13 -224 .49 4516 .21 5969452 .81 554815 .17 4521 .63 15.44 MWD 11160 27 95. 54 298.49 6423 .30 6330. 30 -209 .46 4490 .26 5969467 .67 554789 .13 4495 .08 15.59 MWD 11189. 58 89. 51 293.31 6422 .01 6329. 01 -196 .68 4463 .94 5969480 .27 554762 .72 4468 .25 27.11 MWD 11218. 05 87. 82 288.16 6422 .67 6329. 67 -186 .61 4437 .33 5969490 .16 554736 .05 4441 .25 19.03 MWD 11253. 62 93. 20 287.70 6422 .35 6329. 35 -175 .66 4403 .50 5969500 .88 554702 .15 4407 .00 15.18 MWD 11290 .74 89. 97 279.11 6421 .33 6328. 33 -167 .07 4367 .45 5969509 .23 554666 .04 4370 .62 24.71 MWD 11322. 12 93. 32 275.27 6420 .42 6327. 42 -163 .14 4336 .34 5969512. 94 554634 .91 4339 .37 16.23 MWD 11355. 16 90. 89 267.36 6419 .21 6326. 21 -162 .39 4303 .36 5969513. 48 554601 .93 4306 .39 25.03 MWD 11380. 61 90. 95 265.49 6418 .80 6325. 80 -163 .98 4277 .96 5969511. 72 554576 .55 4281 .08 7.35 MWD 11410. 70 90. 86 264.11 6418 .32 6325. 32 -166 .70 4248 .00 5969508. 79 554546 .61 4251 .26 4.60 MWD 11441. 80 91. 23 266.33 6417 .76 6324. 76 -169 .29 4217 .01 5969505. 99 554515 .64 4220 .41 7.24 MWD 11456. 43 91. 35 267.10 6417 .43 6324. 43 -170 .13 4202 .41 5969505. 06 554501 .05 4205 .85 5.33 MWD / 11500. 00 91. 35 267.10 6416 .40 , 6323. 40 -172 .34 4158 .91 5969502. 56 ~ 554457 .57 ~- 4162 .48 0.00 MWD Well Name: 16-08A Wellbo~iagram (7-26-07) • nPi a so-ozs-zosss-sors~-oo 1 B-08A `~ PTD: 207-075,076 ConocoPh i I I i ps ~ 16" 65#/ft H-40 Alaska • 80.0 k 4-t/2" Camco'DB' nipple 517.00 ft 10.75" 45.5 #/ft K-55 2343.0 ft 4112" 12.62 #Ift L-80 EUE 8rd Mod Tbg ID 3.953" 7" 26 #Ift K-55 ID 6.375" -~ ~~_ ~~ -Calista O~\~ Perforations 9270 9306 36 9306 9306 0 9306 9310 4 9340 9350 10 9360 9380 20 9392 9402 10 80 7" 26#/ft L-80 -'~ '•` 8465.0 ft 9173.00 ft 41/2" Camco'DB' nipple ~ 4-1l2" LSX WS (Bow thruJ TOW 9256 k BOW 9263 ft 4-1/2" 12.6#Ift L-80 Prepared by Dave Hildreth Orbis Engineering Inc Houston, Texas 4-112" Baker'CMU' SSD 6049.00 ft Baker EL-1 SBR PBR 6095.00 ft 4-1/2" Baker FAB-1 LTP 6110.00 ft Seal Assy 6123.00 ft ~KB packer @ 9079' ,~ CMU sliding sle~ eeve @ 9045 OH Side Track H~ 3-112" x 33/16" Liner @ 9060' 10886' 11028 ft 3-3116" Casi g Shoe 10,480 ft ` Lt Lateral 11 3.7" "X" Nipple @ 9078' 2-3/8" TOL @ 10,467' ~ ""' 11304' window10337ft - - ---------------- ---- ----- ------- 2-3/8" TOL @10,363.6' Lt-Ot Lateral 9708.0 ft ~ S/20/2007 ft / • • ri.~ BAKER HI~GNES INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Te1907-267-6600 Fax 907-267-6623 To Whom It May Concern: September 20, 2007 Please find enclosed directional survey data for wells: 1B-08AL1PB1, 1B- 08AL1 and 1B-08AL1-Ol. Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey files Cc: State of Alaska, AOGCC Christine Mahnken ~,c~?-U?~^ ~ ~ Page 1 of 1 ~, , -. , Mahnken, Christine R (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, September 12, 2007 8:02 AM To: Mahnken, Christine R (DOA) Subject: FW; Kuparuk 1 B-08AL1 & 1 B-08AL1-01 / PTD # 207-Q75 & 207-076 Christine, _ Please print two copies of this email and place them in the appropriate well history files. Thanks, Steve Davies From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] ' Sent: Tuestlay;~Septemb~r 11, 2U07 11:44 AM ; ` _ To: Davies, Stephen f (DOA) Subject: Kuparuk 16-08AL1 & 16-08AL1-01 / PTD # 207-075 & 207-076 H i Steve Please reference the following well: Well Namfi~~uR,paru .~ B-Q$~,.L,1 &~upaXUk 1 B-08AL1-01 _ ~ Permit #: ~~=~7~ & 207-076 - API #: 50-029-20635-60-00 & 50-029-20635-61-00 1B-Q8AL1 Top Slotted Section MD: 10706' 1 B-08AL1 Bottom Slotted Section MD: 1`1463' & . .. ~~,~ ~,,,; _ . _ ~ ~. ~ . ~=~8AL1~op ~~lo'~etl' Section 1111D:'~ 1`0545' . ' 1 B-08AL1-01` Bottom Slotted Section MD: 11270' These two well bores began Injection on September $, 2007 Method of Operations is Water Injection Thanks, Terrie . ~. _~,.~, -.,a,_,- , ,. •=~~~~;~.;~.~.~,~,~¢,, ,~. .o~.. ~~ l ~ ~ 11/09/04 STATE QF ALASKA OIL AND GAS CO[~ISER~/ATION Ct)~~i11SS10N BOPE Test Repart s~~nrt to: Contractor. Nordic Rig No.: 2 Qt~TE: 7/22147 Rig Rep.: McKeimaNSlaar~ Rig Phone: 659-4398 Rig Fa~c: 659-4356 Operator. BPX Op. Piwree: &59-4393 Op. Fax: 65~4356 Rep.: Hildreth/G~drich E-Maii < . .., Well Name: 1B-08AL1-0t PTD# ZElT-~4T6 Operation: Drig: XXX Warkaver Explaf.: Test: InitiaL- VVeekly: Bi-Weekty XXX Test Pressure: Rams: 250-3:500 Annutar. 25tt-3500 Valves: 250-350Q MISC. INSPECTIONS: TEST DATA FLQOR SAFETY VALVES: Test Resutt Test Resutt Quantity Test Result Location Gen_: P Weil Sign P Upp~ Kelly NA Housekeeping: P D~i. R~ P L~ Kelty NA PTD On Location P Hazaisd Sec. p Bal! Type 1 P Standing Order Posted P lnside B~P NA BOP STACK: Quarrtity SizefType Test Resu~t MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preverrter 1 71116" P Pit ~evei lr~dicators P P #1 Rams 1 81ind / Shear P Ftow Indieator P P #2 Rams 1 2"eombi's P N~th Gas Detector P P #3 Rams 1 2_3x3.5VBR P H2S Gas Uetector P P #4 Rams 1 2"cambi's P #5 Rams NfA NA (~uarrtity Test Result Choke Ln. Valves 1 3118" P I~side Ree! vatves 1 P HCR Valves 2 31/8" P Kill Line Valves 1 31l8" P ACCUMULATOR SYSTEM: Check Valve 2 21/16" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Cfasure 2300 P Quanfity Test Resutt 200 psi Attair~ed 2Q sec. P No. Valves 14 P Full Pressure Attaineti 1 minl34sec P Manual Chokes 1 P B{ind Switd~ fi.overs: Ati stations Y Hydraulic Chokes 1 P Nitgre. Bottles (avg}: 4~ 2125 Test Results Number of Failures: 0 Tesi Time: 10 Hours Comoonerrts tested 3Q Repair or replacement of equi~ment witi be m~ within 0 days. Notify the N orth~ Slope Inspector 659-3607, follaw+ with writter~ ~nflrmatron tfl Su ~ser at~ ..~ . .., . ._._ ...... . Remarks: F~ctended testing time due ta faii~ce ar~ replacement of btirxilst~ear cams. Retested OK Distribution: 24 HCiUR NOTICE G11lEN orig-Well File YES JOf3C NO c - OperJRig 1iVaived By c- Database Date 7~7 Time 2U(X3 Hrs. c- Trip Rpt File Witness John Cris c- Ins ectar Test start 0830 Finish 1900 Coil Tubing BFL 11/09/Q4 Norciic 2 BOP 7-22-07.x1s 1 B-08A L 1-O l Change to Permit to Drill ~ ~ Page 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, July 'f 3, 2007 2:50 PM To: 'Gantt, Lamar L' Subject: RE: 1B-08A L1-01 Change to Permit to Drill ---~- a0~ ~ C~`Z S ~ ~~ "' ~ ~ ~0 Lamar, I have discussed your forward plan with Cathy and you may proceed as planned. We will look for the new paperwork on Monday. So far as I understand, the name, permit and API # will remain the same. Call or message with any questions. Tom Maunder, PE AOGCC From: Gantt, Lamar L [mailto:lamar.gantt@bp.com] Sent: Friday, July 13, 2007 2:22 PM To: Maunder, Thomas E (DOA) Cc: Elfer, J Gary; NSU, ADW Drlg Nordic 2 Supervisor; Venhaus, €?an E; Hubble, Terrie L; McMullen, John C; GRNTRL@bp.cam; laird.d.little@canocophitlips.com Subject: 1B-08A L1-01 Change to Permit to Drill Tom As per our phone discussion today, this e-mait is to document a proposed change ta the Permit to Drill for the Kuparuk 1B-08A L1-01 fateral> Current operations on the 1 B-088L1 fateral with the Nordic 2 CTD rig are we have reached TD and have encountered an interval at roughly 1125Q' MD that appears very "soft". This is likely due to a fault zone that is mapped at this location. The formation drills with minimat weight on bit and we have been holding back to prevent excessive RpPS through this zone. We have decided to TD this lateral at 11500' MD and run a liner as proposed in the permit far this lateral. The lower lateral, 1 B-08 AL1-01, was originally proposed to dritl generaHy in the same direction at a tower subsea elevatian. Based on the results of the upper 9 B-08AL1 lateral described above, we now propose to alter the trajectory of the second laterai to tum north and avoid this fault zone. We have not yet finalized new coordinates, but the new proposed TD will remain in the same "C1" Kuparuk sand unit, but very likely vary from the original permitted TD by more than 500 ft taterally. Given that it is tate on a Friday aftemoon, we wil{ not complete plar-ning a new trajectory until after close of business hours today, but wif~ likely be ready to begin dnlling the L1-01 taterat before Manday moming. As you requested, this correspondence is to document the plan we verbally discussed this aftemoon, Friday, July 13, 2Q07 so we can proceed an through tt~e weekend. We witl faltow up with a written revision to the permit to drill for tt~e 1 B-08 AL't-01 on Monday, Ju1y 16, 2007. Lamar L. Gantt CTD Engineer - ConocoPhillips Alaska, inc. Offi~e: 907-564-5593 Cell: 907-240-8045 7/i 3/2007 • • 11/09/04 ST~j~ (}F ~~~-~ OIL AND GAS ~Q~ISEF~~t~T~4M Gt~MN~ISS{ON BQPE Test Repart Su~it to: ~ _ _. _ . __ _ _. _ .~~ ~ ~' ~` ~ .._ _. . _. Contracfor: Nordic . __, _.,. _ . _ Rig E~.: 2 QATE: 7/8/07 Rig Rep.: Holmes/Lancasfer Rig Phone: 659-4398 Rg Fax: 65~4356 O~rator. BPX Op. Phone= ~59-4393 fJp. Fax: 659-485G Rep.: SecviklRo~s ~.,;. r . , . ; .i j f , t ..,..rv~-, I -Mai „ _. __ _ ._.. ..__ .__, ~ _ ~ _._ Well Name: 1B-08A~1 PTD # 20T-0T5 Operation: Drfig: ~ V4Fc>rlcover: E~c.: Test: In~tial: 7QOC Wesicty: Bi-Weekly XX3C Test Pressure_ Rams= 25f~3500 Annular: 250-3500 Vatves: 25Q-3500 MISC. INSPECTtONS: TEST DATa FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Weli Sign P Upper Keity NA Housekeeping: P Dri. Rig P Lu~r Ketly NA PTD On Location P Hazaa! Sec. P 6afl Type i P Standing Order Posteci P Ins~e BOP NA BOP STACK: Quarrtity SizelType Test Re.sutt MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 71/16" P Pit Level lndicatc~s P P #1 Rams 1 Biind / Shear P F~ t~icator P P #2 Rams 1 2"c;ambi's P Meth Gas Defector P P #3 Rams 1 2 3!8"cwnbi'~ P H2S Gas Ddedor P P #4 Rams 1 2"c~mbi`s P #5 Rams NiA NA Quantity Test Result Choke Ln. Valves 1 3118" P 1-~side Ree~ valves 1 P HCR Vaives 2 31l8" P Kill Line Valves 1 3118" P ACCUMULATOR SYSTEM: Check Valve 2 21116" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure Afler Closure 2300 P Quantity Test Resutt 20t! psi Attainec# 21 sec P No. Valves 14 P Fui~ Pressure A#ained 1 rr-inl19sec P Manual Chokes 9 P Bfir~d Sv~tch Covers: Afl statians Y Hydraulic Chokes 1 P Nitgn. Bottles (avg}: 4 2100 Test Result~s Number of Failures_ 0 Test 7ime: 6 Mours ComponeMs tested 30 Repair or replacement of equi~ v~riil be made wiEhin 0 days. Rlotify the North Slope Ins ector 659-3607, foNow with w~itten ~firmatiErn #o Sup~~rviser at_ M `~ _ _. . _ ~~~ ~ ; `.. -, Remarks: This was a CT size cha-~ge "driven" BOP test, as we v~ere ~ due fgr a Bi-weekly until 7/13/07 Distribution: 24 HOUR NOTICE GlVEN orig-Well File YES ~OCX NO c- OperJRig Waiveci By Chuck Scheve c- Database Date 7/6J07 Time 22:~ c- Tnp Rpt File WiEness RossJDaniell c- Inspector Test start 19:30 Finish 01:3t? Coil Tubing BFL 11/09/04 Piorciic 2 BOP 07-08-07p.xls ~ • 11/09104 ~TATE O~ ~4-L~4SK~A OIL AND G/~-S COWSERV~T(ON CC~NI~IItSS10N BOPE Test Report submit to: .. , .. ..t ~ , _. .. . ~ . , ~ .. ._ ~: . ~ ~:n . _ . __ _, . _ Contractor: Nordis Rig No_: 2 T DATE: 6/28f07 Rig Rep.: Sloan/Hoimes Rig Phone. 659-4398 Rig Fax: 659-4356 Operator. BPX OR. Pbone: 659-4393 Op. Fax: 659-4356 Rep.: Secvik/Goodrictt , E-MaT, _, ~.~~ ~ ~ r : ~ ~ ~~ _.~__ Wefl Name: 1 B-08AL1 PTD ~x~~~i, Operation: Drig: XXX V{lrnicaver. Explor_: Test: Initi~i: )OKX Weekty. Bi-Vlleekly Test Pressure: Ramx 250-35Q0 Arrnular. 250-25(fU Valves: 250-3500 MISC. INSPECTtONS: TEST DATA FLOOR SAFETY VALVES: Test Resuft Test Resuit Quantity Test Result Location Gen.: P Well Sign P Upper Kelfy NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazarti Sec. P Ball Type 2 P Standing Order Posted P tnsicle BOP NA BOP STACK: Quarrtity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8 " P Trip Tank P P Annular Preventer 1 71/16" P Pit L~ve! Endicators P P #1 Rams 1 Bdind 1 Shear P F~ar Icxlicator P P #2 Rams 1 3" Sli~ NT M~th Gas ~tedar P P #3 Rams 1 2 3/8'tic 3'{!2' P HZS Gas [)etedor P P #4 Rams 1 2 3/8"c~mbi'~ P #5 Rams N/A NA Quarrtity Test Result Choke Ln. Vatves 1 31l8" P Inside Ree! valves 1 P HCR Valves 2 3 9I8" P Kill Line Valves 1 3118" P ACCUMUtATOR SYSTEM: Check Valve 2 2 t/16" P Time/Pressure Test Result Sysfem Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2100 P Quarrtity Test Result 2~ psi Attained 20 sec. P No. Valves 14 P Fuil Fressur+e Aftained 1 min/40sec P Manual Chokes 1 P Btirtd Switch Covers: A11 stations Y Hydraulic Chokes 1 P Nitgn. Batttes (avg}: 4 2025 Test Results Number of Failures: 0 Test Time: 4 l-laurs Corrfpanerrts tested 30 Repair or replacement of equipme~ vrrtll be made within 0 days. Notify the North Slope Inspeckor 659-3607, follow with written c~nfirmatic~n #€r Superviser at: ;; : ~ Remarks: Distributian: 24 HOUR NOTICE GIVEN orig-Well File YES ~OCX NO c- Oper./Rig Waived By John Crisp c- Database Da#e f~27iU7 Time 1404 hrs_ c- Trip Rpt File V\frtness SecviklHobart c- Inspector Test start 23.OQ Fin"~sFe 03:Q0 Coil Tubing BFL 11/09/04 Nordic 2 BOP 6-28-07p.xls Lamar Gantt CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Ku~aruk River Oil Pool, 1 B-08AL 1 ConocoPhillips Alaska, Inc. Perniit No: 207-075 Surface Location: 501' FNL, 141' FEL, SEC. 09, T 11 N, R 10E, UM Bottomhole Location: 770' FNL, 4014' FWL, SEC. 10, T11N, R10E, UM Dear Mr. Gantt: 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 KBU 1 B-08A, Permit No 197- 112, API 50-029-20635-01. 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 i~ accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Fa.ilure 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 Comm:ysion to witness any required test, contact the Commission's petroleum field inspe~r at (90?) 659-3607 (pager). DATED this l~ day of June, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ~ ALA~OIL AND GAS CONSERVATION COMMI lON PERMIT TO DRILL 20 AAC 25.005 RECEIVED ~~,i~~, MAY 3 1 2007 Alaska Oil & Gas Cons. Commission 1a. 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 propose o. ^ 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-08AL1 ~ 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 11300 ~ TVD 6337ss 12. Field / Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: 501' FNL 141' FE~ SEC T11 N R10E UM ~ 09 7. Property Designation: ADL 025648~ dLS~6~ River Pool - , , , , . , Top of Productive Horizon: 1373' FNL, 237' FWL, SEC. 11, T11 N, R10E, UM 8. Land Use Permit: ~•'I•o7 13. Approximate Spud Date: June 5, 2007 ~ Total Depth: 770' FNL, 4014' FWL, SEC. 10, T11N, R10E, UM 9. Acres in Property: 2560 , 14. Distance to Nearest Property: r 15,550' 4b. Location of Well (State Base Plane Coordinates): SurFace: x-550298 - y-5969648 - Zone-ASP4 10. KB Elevation ~~,. (Height above ~ 93 feet 15. Distance to Nearest Well Within Pool: 1,000' 16. Deviated Wells: Kickoff Depth: 9265 ~ feet Maximum Hole An le: 105 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3471 " SurFace: 2825 ' 18i Casi Pr ram: S cifications To - Setti~ ° De th - Bo ttom uanti of Cement c:f, or cks Hote Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 4-1/8" 3-3/16" 6.2# L-80 TC-II 1200' 9100'• 6288' 10300'• 6402' 15 sx Class'G' 3" 2-3/8" 4.6# L-80 STL 1010' 10290' 6402' 11300' 6337' Uncemented Slotted Liner 19. 'PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9710 Total Depth ND (ft): 6660 Plugs (measured): None Effective Depth MD (ft): 9611 Effective Depth ND (ft): 6614 Junk (measured): None asing Length Size Gement Volume MD TVD Conductor / Structural 112' 16" 200 sx Permafrost 112' 112' Surface 2343' 10-3/4" 1000 sx Fondu 250 sx Arcticset II 2343' 2246' Intermediate 6339' 7" 923 sx Class'G' 6339' S025' Pr u ion Liner 3588' 4-1/2" 496 sx Class 'G' 6120' - 9708' 4846' - 6659' Perforation Depth MD (ft): 9270' - 9402' Perforation Depth ND (ft): 6459' - 6519' 20. Attachments ^ Filing Fee, $100 ~ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Dan Venhaus, 263-4372 Printed Nam ~amar Gan for Gary Eller Title CT Drilling Engineer Gary El~er, 263-4172 Prepared By NamelNumber: Si nature . ~-t i= Phone 263-4172 Date S 3/ p 7 Terrie Hubble, 564-4628 Commission Use Onl - Permit To Drill Number: ~7'b~s API Number: 50-029-20635-60-00 Permit Approval See cover letter for Date: • other re uirements Conditions of Approval: ~ If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~~ ~~~Q p s~ rLS ~` ~~-C-~ Samples Req'd: ^ ~Ges [~'No Mud Log Req'd: ^ Yes LrJ No HZS Measures: [~Yes ^ No Dire ional Survey Req'd: []~Yes ^ No Op~z-~:~.o ~S ~~ c~. ~~-`c~ `~.' l t~~D c,~'~ _ Other: Dat~/' / D PROVED BY THE COMMISSION , COMMISSIONER Form 10-401 Revised 12/2005 r /~ ~ Submit In DupliCate ORIGINAL `~ ~`.~`~°~ ~ KRU 1 B~ L1 & L1-01 Sidetrack Laterals - Coiled Tubing Drilling Summarv of Ouerations: A coiled tubing drilling rig will drill a dual lateral in injection well KRU 1B-08A using the managed pressure drilling technique. These horizontal laterals will target Kuparuk C3/4 and Cl sand reserves for increased injection support. The perforations in the motherbore will also remain open for injection.+ The L1 lateral will ' target C3/4 Sands and will include a 1035' cemented 3-3/16" liner followed by a 1000' 23/a" slotted liner to a TD of 11,300' MD. The L1-Ol lateral will target the C1 Sand and will kick off from the L1 lateral from the 3-3/16" liner. That lateral will be 1675' in length and will be completed with 23/8" slotted liner to a TD of 11,900' MD. Only the L1 lateral will remain accessible through-tubing. ~ CTD Drill and Comulete 1B-08A nrogram: Planned for June 2007 Pre-Ri~ Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs - T& IC. 3. MIT-IA, MIT-OA. 4. Slickline tag fill. Drift 4'h" tubing with whipstock dummy. 5. Obtain static BHP on C sand. - 6. Caliper 4'h" liner. 7. Set 4'h" monobore flow-through whipstock on e-line at 9265' MD at an orientation of 20° left of highside Rig Work l. 2. 3. 4. ~~~ s. ~~' 6. 7. 8. w 9. 10. 11 ~~~ ~~~,1.~ 12. 13. MIRU Nordic Rig #2 using 23/8" coil tubing. NU 7-1/16" BOPE, test. Mi113.74" window and 10' of open hole at 9265' MD. ' Drill the 1B-08AL1 trunk lateral to the west with a 3.72" x 4'/8" bi-center bit from the window to 10,300' TD, which is ~200 feet beyond a major N-S fault. Run a 3-3/16" solid liner from TD up into the 4'/z" liner at 9100' MD. Swap reel to 2" e-free coil tubing and 23/8" BHA. Change pipe rams, retest BOPE. Pump a 3 to 4 bbl "puddle" cement job around the 3-3/16" liner. Swap reel to 2" e-coil tubing. Drill out the 3-3/16" float and shoe and 20' of new formation. Drill the remaining portion of the L1 lateral to the west with a 2.70" x 3" bi-center bit to 11,300' MD targeting C3 and C4 sands. Complete the Ll lateral with 23/8" slotted liner from TD u~ into the 3-3/16" liner to 10.290' MT~. Set a Baker thru-tubing whipstock at 10,225' MD. Whipstock should be set at least 50+ feet away from the top of the L1 slotted liner with an orientation of 30° left of highside. Mill a 2.74" window in the 3-3/16" liner plus 10' of open hole at 10,225' MD. Drill the L1-O1 lateral to the west with a 2.70" x 3" bi-center bit to 11,900' MD targeting the C1 sand. 14. Complete the Ll-O1 lateral with 23/g" slotted liner with the top of tbe liner spotted 5'-10' outside the window to allow retrieval of the thru-tubing whipstock. 15. Pull the whipstock in the 3-3/16" liner at 10,225' MD. I6. Install KB liner top packer and 2.313" CMD sliding sleeve onto 3-3/16" liner-top at 9100' MD. 17. Freeze protect. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Obtain static BHP 2. MIlZU CTU. Lift well with nitrogen for temporary flowback to tanks. ! 3. Install injection valve in DB nipple at 517' MD. 4. Do not put the well on injection without an approved 10-403 or 10-407. Page 1 of 3 May 29, 2007, FINAL i KRU 1 B~ L1 & L1-01 Sidetrack Laterals - Coiled Tubing Drilling Mud Program: ~ • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud (8.6 ppg) for drilling operations. Will have to kill the well to deploy 23/8" slotted liner since there is no SCSSV. 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-08AL1 trunk: 3-3/16", 6.2#, L-80, TGII solid liner from 91Q0' MD to 10,300' MD. "Puddle" cemented in place for isolation of laterals from motherbore perfs. • 1B-08AL1: 23/8", 4.6# L-80 STL slotted liner from 10,300' MD to 11,300' MD • 1B-08AL1-Ol: 23/8", 4.6#, L-80, STL slotted liner from 10,225' MD to 11,900' MD Existing Casing/Liner Information Surface: 103/a", K-55, 45.5 ppf Burst 3580 psi; Collapse 2090 psi. Production: 7", K-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Liner: 41/z", L-80, 12.6 ppf Burst 8430 psi; Collapse 7500 psi Well Control: • Two well bore volumes (~220 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • Separate BOP diagrams are attached for operations with 2" and 23/s" coil tubing. ~ • Pipe rams, biind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. MaYimum potential surface pressure is 2825 psi assuming a gas gradient to surface and maximum expected formation pressure (i.e. based on highest pressure measurement in the vicinity, which is 3471 psi in 1B- 17 in July 1994). • The annular preventer will be tested to 250 psi and 2500 psi. Logging , • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. / / Hazards f ~ • Lost circulation is a risk due to anticipated lower BHP in the target fault block directly west (i.e. 8.3 ppg EMW) and potentially high ECD. Expect to encounter decreasing pressure as the laterals are drilled away from the mother well. • Well 1B-08A has no HzS since it is an injection well. Well 1B-17 is adjacent to 1B-08A and has 100 ppm HZS as measured on 6/18/06, which is the maximum HZS level on the 1B pad. All H2S monitoring equipment wi11 be operational. ~ Reservoir Pressure ~ The most recent static BHP survey in well 1B-08A was taken in October 2006 after the well had been shut-in for several days. The measured reservoir pressure was 3232 psi at 6496' TVD which .~ corresponds to 9.6 ppg EMW. Expect to encounter decreasing pressure as both laterals are drilled away from mother well. The expected static BHP in the target fault block to the west is 2600 - 2800 psi % based on recent measurements in several wells. Maximum expected pressure is 3471 psi (i.e. well 1B- Page 2 of 3 May 29, 2007, FINAL ~ KRU 1 B-~ L1 & L1-01 Sidetrack Laterals - Coiled Tubing Drilling 17 from July 1994) which corresponds to an EMW of 10.3 ppg at 6457' TVD (i.e. KOP for L1 lateral). Maximum surface pressure with gas (0.1 psi/ft) to surface is 2825 psi. - Quarter-Mile Well Evaluation for Injection Both of these 1B-08A laterals will be completed as injection wells, and the 1B-08A motherbore will also remain in service as an injector. The only well within a quarter-mile of either lateral is the former injection well 1B-08 which will be approximately 1000' away. The perfs in 1B-08 were plugged in ~ mid-1997 prior to the well being abandoned and sidetracked. In plugging well 1B-08, an A-2 slickline plug was set in the D nipple at 8054' MD to isolate the A sand perfs from the C sand perfs. Next, a 31/z" cement retainer was set above the C sand at 7730' MD and 15.5 bbl of 15.8 ppg cement were bullheaded through the retainer to plug the C sand. The A-2 plug was not pressure tested prior to setting the retainer, so there is ,potential for A sand and C sand - communication through the abandoned 1B-08 wellbore. However, even if communication does exist between the A and the C sand, the consequences would be negligible. The static pressure in this fault block is approximately 3200 psi in the A sand versus 2800 psi in the C sand (as per 1B-07, June 2006), so opportunity for crossflow is small. Any unintended injection into the A sand via 1B-08 would support A sand producers to the south. An attempt was made to pressure test the tubing after cementing through the retainer at 7730' MD, but they were still able to pump in at 0.25 bpm with 3000 psi. A 31/z" bridge plug was set at 7724' MD and pressure tested to 2500 psi. Prior to sidetracking 1B-08, an abandonment cement plug was placed from 7700' - 7385' MD and a 7" bridge plug was set in the production casing at 6540' MD. The 7" bridge plug was tested to 3500 psi prior to sidetracking 1B-08. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 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 hoie stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (i.e. either 23/8" or variable rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. There is no SCSSV in well 1B-08A, so the well will have to be killed prior to running 23/8" slotted liner. 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 TD: ~ • Estimated reservoir pressure: 3232 psi at 9350' MD (6496' TVD), or 9.6 ppg EMW. • Expected annular friction losses while circulating: 468 psi (assuming friction of 50 psi/1000 ft). • Planned mud density: 8.6 ppg equates to 2905 psi hydrostatic bottom hole pressure at 6496' TVD • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3373 psi or 10.0 ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that 330 psi of additional surface pressure shall have to be applied to balance reservoir pressure. 470 psi of additional surface pressure must be held to maintain the same bottom hole pressure as during drilling operations. Page 3 of 3 May 29, 2007, FINAL ~ ~ i ConocoPhillips Alaska, Inc. 1 B-08A API: 500292063501 WeIIT pe: INJ__ _ . _ - - - - SSSV TyLe_ NIPPLE Orig Completiorr 8/3/1997 --- . --- - - ~ VALVE Annular Fluid: __. _ Last W/O: 8/3/1997 ', (517-518, Reference Lo : Ref Lo Date: , Last Ta : 9479' RKB TD: 9710 ftK i OD:3.810) - - - - - _ ------ Last_Ta Date: 6/28l2006 Max Hole An le: 64 de c '~ NIP (517-518, Casin Strin - ALL STRINGS I OD:4.500) ---- - - - - Description _ Size Top _ _ Bott --- , SURFACE 10.750 0 23~ _ - PRODUCTION 7.000 0 84E CONDUCTOR 16.000 0 8( ~ SLEEVE-C - -- LINER 4.500 6120 97( ,~soas-soso, ~ ~ Tubin Strin - TUBING OD:4.500) Size Top Bottom TVD --4.500 _ _ 0 - --- - ___-- _ - ~ 6135 4858 Perforations Summa Interval TVD Zone Status Ft SPI 9270 - 9306 6459 - 6475 C-4 Open 36 4 PBR 9306 - 9306 6475 - 6475 C-4 Open 0 5 (6095-6096, OD:4.500) 9306 - 9310 6475 - 6477 C-4 Open 4 4 9310 - 9310 6477 - 6477 C-4 O en 0 1 I 9314 - 9314 6479 - 6479 C-3 O en 0 1 9318 - 9318 6481 - 6481 C3 O en 0 1 ANCHOR 9322 - 9322 6483 - 6483 C-3 O en 0 1 (6109-6110, m° 0 9326 - 9326 6485 - 6485 C-3 O en 0 1 OD:4.500) ' 9340 - 9350 6491 - 6495 C-3 O en 10 12 I 9360 - 9380 6500 - 6509 G2 O en 20 12 i~~~~ qso~ _ onro R51 d_ RF1 Q c_~ n„o~ ~ n ~~ SEAL (6123-6124, OD:4.500) TUBING (0-6135, OD:4.500, ID:3.953) NIP (9173-9174, OD:3.828) I Perf i (9270-9310) Perf I (9306-9306) ' Perf (9318-9318) Perf (9340-9350) Perf (9360-9380) KRU 1 B-08A SO deg. Perf (9392-9402) ~ ~ BP Alaska ~` ~'R r ~ bp ~s Baker Hughes INTEQ Planning Report INTEQ Company: " BP Amoco Date: 5/25/2007 Time: 14:25:59 Page: 1 Field: Kuparuk Co-ordinAte(NE) Refereace: Well: 08, True North ' Site: KRU 1 B Pad Vertical (7'VD) Reference: RKB Elev 1 93.0 We1L• 08 Section (VS) Reference: Well (O.OON,O.OOE,280.OOAzi) Wellpath: Plan 3, 1B-08AL1 Survey Calculation Method: Minimum Curvature ~ Db: 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 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 Posifion Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.38 deg W ell: 08 Slot Name: Well Position: +N/-S -5.26 ft ~iorthing: 5969647.00 ft- Latitude: 70 19 40.238 N +E/-W 840.67 ft Easting : 550298.00 ft- Longitude: 149 35 31.515 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, 16-08AL1 Drilled From: 1&08A Tie-on Depth: 9244.48 ft Current Daturo: RKB Elev 1 Height 93.00 ft Above System Datu m: Mean Sea Level ' Magnetic Data: 5/25/2007 DeclinaHon: 23.50 deg Field Strength: 57624 nT Mag Dip Angle: 80.86 deg VerHcal SecNon: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 93.00 0.00 0.00 280.00 Plan: Plan #3 Date Composed: 5/25/2007 Copy Lamar's Plan 3 Version: 5 Principal: Yes Tied-to: From: Definitive Path Targets Name DescripNon Dip. Dir. TW ft +N/-S ft +E/-W ft Map Nortning ft Map Easting ft <- LaHtuQe -- Deg Min Sec --> <_- Lougitude ---> Deg Min Sec 16-08AL1/AL1-01 Polygon 93.00 -857.69 5606.92 5968827.00 555910.00 70 19 31.782 N 149 32 47.853 W -Polygon 1 93.00 -857.69 5606.92 5968827.00 555910.00 70 19 31.782 N 149 32 47.853 W -Polygon 2 93.00 -749.20 5684.66 5968936.00 555987.00 70 19 32.848 N 149 32 45.582 W -Polygon 3 93.00 -672.82 5630.16 5969012.00 555932.00 70 19 33.600 N 149 32 47.171 W -Polygon 4 93.00 -648.33 5258.28 5969034.00 555560.00 70 19 33.843 N 149 32 58.026 W -Polygon 5 93.00 -613.21 4942.48 5969067.00 555244.00 70 19 34.191 N 149 33 7.243 W -Polygon 6 93.00 -533.71 4570.97 5969144.00 554872.00 70 19 34.975 N 149 33 18.086 W -Polygon 7 93.00 -276.10 3589.58 5969395.00 553889.00 70 19 37.514 N 149 33 46.730 W -Polygon 8 93.00 -220.36 3480.94 5969450.00 553780.00 70 19 38.062 N 149 33 49.901 W -Polygon 9 93.00 84.78 3614.00 5969756.00 553911.00 70 19 41.063 N 149 33 46.012 W -Polygon 10 93.00 126.69 3777.30 5969799.00 554074.00 70 19 41.474 N 149 33 41.244 W -Polygon 11 93.00 672.19 4010.99 5970346.00 554304.00 70 19 46.838 N 149 33 34.414 W -Polygon 12 93.00 481.34 4730.79 5970160.00 555025.00 7Q 19 44.957 N 149 33 13.402 W -Polygon 13 93.00 359.36 5025.01 5970040.00 555320.00 70 19 43.755 N 149 33 4.815 W -Polygon 14 93.00 -241.88 4900.96 5969438.00 555200.00 70 19 37.843 N 149 33 8.448 W -Polygon 15 93.00 -343.12 5381.34 5969340.00 555681.00 70 19 36.844 N 149 32 54.427 W -Polygon 16 93.00 -443.61 5751.71 5969242.00 556052.00 70 19 35.853 N 149 32 43.618 W -Polygon 17 93.00 -662.65 5903.26 5969024.00 556205.00 70 19 33.698 N 149 32 39.199 W -Polygon 18 93.00 -804.59 5891.31 5968882.00 556194.00 70 19 32.302 N 149 32 39.551 W -Polygon 19 93.00 -924.72 5759.49 5968761.00 556063.00 70 19 31.121 N 149 32 43.402 W -Polygon 20 93.00 -857.69 5606.92 5968827.00 555910.00 70 19 31.782 N 149 32 47.853 W 1 B-OSAL1 Fault 7 93.00 -194.82 5488.35 5969489.00 555787.00 70 19 38.302 N 149 32 51.300 W -Polygon 1 93.00 -194.82 5488.35 5969489.00 555787.00 70 19 38.302 N 149 32 51.300 W -Polygon 2 93.00 -479.69 5315.42 5969203.00 555616.00 70 19 35.501 N 149 32 56.354 W -Polygon 3 93.00 -776.93 5196.41 5968905.00 555499.00 70 19 32.579 N 149 32 59.834 W -Polygon 4 93.00 -479.69 5315.42 5969203.00 555616.00 70 19 35.501 N 149 32 56.354 W ~ r bp BP Alaska s ~$ ~ Baker ~Iu hes INTE Plannin Re ort g Q g P INTEQ Company: BP Amoco Date: 5/2b/2007 Time: 14:25:59 Page: 2 Field: Kaparuk Co-ordinxte(NE) Referencer WeIC 08, True NoRh Sitec KRU 1 B Pad Vertical (TVD) Reference: RKB Elev t 93:0 We1L• 08 Section (VS) Reference: Well (O.OON,O.OOE,280.OOAzi) Wellpath: Plan 3, 1 B-08AL1 Survey CatculaHon Method: Minimum Curvature Db: Oracle Targets Name Description TVD Dip. Dir. ft 16-08AL1/AL1-01 Fault 2 93.00 -Polygon 1 93.00 -Polygon 2 93.00 -Polygon 3 93.00 -Polygon 4 93.00 18-08AL1 Target 4 6414.00 1 B-08AL1 Target 5 6430.00 1 B-08AL1 Target 3 6449.00 1B-08AL1 Target 1 6495.00 1 B-08AL1 Target 2 6495.00 +N/-S ft -101.82 -101.82 -242.11 -510.28 -242.11 -339.11 -266.89 -381.65 -479.69 -471.36 Map Map +E/-W NoMhing Easting ft ft ft 4296.83 5969574.00 554595.00 4296.83 5969574.00 554595.00 4337.90 5969434.00 554637.00 4209.08 5969165.00 554510.00 4337.90 5969434.00 554637.00 4485.26 5969338.00 554785.00 4155.71 5969408.00 554455.00 4863.02 5969298.00 555163.00 5315.42 5969203.00 555616.00 5117.45 5969210.00 555418.00 <-> Latitude' -> <-- Longitude --> Deg Min Sec Deg Mim Sec 70 19 39.224 N 149 33 26.081 W 70 19 39.224 N 149 33 26.081 W 70 19 37.844 N 149 33 24.885 W 70 19 35.207 N 149 33 28.650 W 70 19 37.844 IV 149 33 24.885 W 70 19 36.889 N 149 33 20.585 W 70 19 37.601 N 149 33 30.204 W 70 19 36.469 N 149 33 9.558 W 70 19 35.501 N 149 32 56.354 W 70 19 35.585 N 149 33 2.133 W Annotation MD ft TVD ft 9244.48 6447.25 TIP 9265.00 6456.69 KOP 9285.00 6465.62 End of 9 Deg/100' DLS 9325.00 6479.05 4 9451.33 6495.10 5 9571.33 6495.10 End of 45 Deg/100' DLS 10096.33 6495.10 7 10296.33 6495.10 8 10456.33 6473.35 9 10606.33 6444.85 10 10746.33 6430.03 11 10896.33 6417.69 12 10996.33 6414.57 13 11146.33 6419.64 14 11300.00 0.00 TD Plan Section Information MD ft Incl deg Azim deg 1'VD ft +N/-S ft +E/-W ft DLS deg/100ft Build Turn deg/100ft deg/100ft TFO Target deg 9244.48 62.55 87.66 6447.25 -870.64 5645.78 0.00 0.00 0.00 0.00 9265.00 62.64 87.64 6456.69 -869.89 5663.98 0.45 0.44 -0.10 348.84 9285.00 64.33 86.96 6465.62 -869.05 5681.86 9.00 8.47 -3.41 340.00 9325.00 76.53 72.87 6479.05 -862.31 5718.75 45.00 30.50 -35.22 310.00 9451.33 90.00 17.09 6495.10 -776.70 5803.04 45.00 10.66 -44.16 279.00 9571.33 90.00 323.09 6495.10 -662.81 5783.14 45.00 0.00 -45.00 270.00 10096.33 90.00 260.09 6495.10 -479.25 5319.18 12.00 0.00 -12.00 270.00 10296.33 90.00 284.09 6495.10 -472.03 5120.77 12.00 0.00 12.00 90.00 10456.33 105.63 295.38 6473.35 -419.04 4972.18 12.00 9.77 7.06 35.00 10606.33 96.17 279.77 6444.85 -375.06 4832.29 12.00 -6.31 -10.41 240.00 10746.33 95.90 262.87 6430.03 -371.87 4693.61 12.00 -0.19 -12.07 270.00 10896.33 93.46 280.77 6417.69 -367.10 4544.82 12.00 -1.63 11.93 97.00 10996.33 90.10 292.30 6414.57 -338.70 4449.18 12.00 -3.36 11.53 106.00 11146.33 86.05 274.75 6419.64 -303.76 4304.02 12.00 -2.70 -11.70 256.80 11300.00 86.26 293.23 6430.04 -266.86 4155.89 12.00 0.13 12.03 90.00 ~ , - b ~ BP Alaska ~ ~ p Baker Hughes INTEQ Planning Report ~.r s N~~ INTEQ Compaoy: BP Amoco Date: 5/25/2007 Time: 14:25:59 Page: 3 Field: Kupar'uk Co-ord inate(NE) Reference: WeIL 08; True North Site: KRU 1B Pad Vertical (TVD}Reference: RKB Elev 1 93A We1L• 08 Section (VS) Reference: Well (O.OON,O. OOE,280.OOAzi) WeOpath: Pla rt 3; 1 B-08AL1 Survey Calculation Met6od: Minimum Gurvature Db: Orade , Survey MD Incl Azim SS TVD ' N/S E/W MapN MapE DLS VS 1'FO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9244.48 62.55 87.66 6354.25 -870.64 5645.78 5968814.31 555948.94 0.00 -5711.19 0.00 MWD 9248.28 62.57 87.66 6356.00 -870.50 5649.15 5968814.47 555952.31 0.45 -5714.49 348.84 1B-OS 9250.00 62.57 87.65 6356.79 -870.44 5650.68 5968814.54 555953.84 0.45 -5715.98 348.84 MWD - 9265.00 62.64 87.64 6363.69 -869.89 5663.98 5968815.18 555967.14 0.45 -5728.99 348.84 MWD 9275.00 63.49 87.30 6368.22 -869.50 5672.89 5968815.63 555976.04 9.00 -5737.69 340.00 MWD 9285.00 64.33 86.96 6372.62 -869.05 5681.86 5968816.14 555985.01 9.00 -5746.45 340.16 MWD 9300.00 68.77 81.41 6378.59 -867.64 5695.54 5968817.64 555998.67 45.00 -5759.68 310.00 MWD 9325.00 76.53 72.87 6386.05 -862.31 5718.75 5968823.13 556021.85 45.00 -5781.61 312.21 MWD 9350.00 78.54 61.53 6391.47 -852.86 5741.21 5968832.73 556044.24 45.00 -5802.09 279.00 MWD 9375.00 80.97 50.37 6395.93 -839.10 5761.55 5968846.62 556064.49 45.00 -5819.73 281.46 MWD 9400.00 83.73 39.36 6399.26 -821.56 5779.00 5968864.28 556081.81 45.00 -5833.86 283.45 MWD 9425.00 86.73 28.48 6401.35 -800.92 5792.87 5968885.01 556095.55 45.00 -5843.94 284.92 MWD 9450.00 89.83 17.66 6402.10 -777.96 5802.65 5968908.03 556105.17 45.00 -5849.58 285.83 MWD 9451.33 90.00 17.09 6402.10 -776.70 5803.04 5968909.30 556105.55 45.00 -5849.75 286.15 MWD 9475.00 90.00 6.43 6402.10 -753.55 5807.86 5968932.47 556110.22 45.00 -5850.48 27Q.00 MWD 9500.00 90.00 355.18 6402.10 -728.60 5808.21 5968957.42 556110.40 45.00 -5846.49 270.00 MWD 9525.00 90.00 343.93 6402.10 -704.05 5803.69 5968981.94 556105.71 45.00 -5837.78 270.00 MWD 9550.00 90.00 332.68 6402.10 -680.86 5794.46 5969005.07 556096.33 45.00 -5824.66 270.00 MWD 9571.33 90.00 323.09 6402.10 -662.81 5783.14 5969023.03 556084.89 45.00 -5810.38 270.00 MWD 9575.00 90.00 322.65 6402.10 -659.89 5780.92 5969025.94 556082.65 12.00 -5807.68 270.00 MWD 9600.00 90.00 319.65 6402.10 -640.42 5765.24 5969045.30 556066.84 12.00 -5788.86 270.00 MWD 9625,00 90.00 316.65 6402.10 -621.80 5748.56 5969063.81 556050.04 12.00 -5769.20 270.00 MWD 9650.00 90.00 313.65 6402.10 -604.08 5730.93 5969081.41 556032.29 12.00 -5748.76 270.00 MWD 9675.00 90.00 310.65 6402.10 -587.31 5712.40 5969098.05 556013.65 12.00 -5727.60 270.00 MWD 9700.00 90.00 307.65 6402.10 -571.53 5693.01 5969113.70 555994.16 12.00 -5705.76 270.00 MWD 9725.00 90.00 304.65 6402.10 -556.78 5672.82 5969128.31 555973.88 12.00 -5683.33 270.00 MWD 9750.00 90.00 301.65 6402.10 -543.12 5651.89 5969141.84 555952.86 12.00 -5660.34 270.00 MWD 9775.00 90.00 298.65 6402.10 -53Q.56 5630.28 5969154.24 555931.16 12.00 -5636.87 270.00 MWD 9800.00 90.00 295.65 6402.10 -519.16 5608.03 5969165.50 555908.84 12.00 -5612.99 270.00 MWD 9825.00 90.00 292.65 6402.10 -508.93 5585.22 5969175.57 555885.97 12.00 -5588.75 270.00 MWD 9850.00 90.00 289.65 6402.10 -499.92 5561.91 5969184.43 555862.60 12.00 -5564.22 270.00 MWD 9875.00 90.00 286.65 6402.10 -492.13 5538.16 5969192.05 555838.79 12.00 -5539.48 270.00 MWD 9900.00 90.00 283.65 6402.10 -485.60 5514.03 5969198.42 555814.62 12.00 -5514.58 270.00 MWD 9925.00 90.00 280.65 6402.10 -480.34 5489.59 5969203.52 555790.15 12.00 -5489.60 270.00 MWD 9950.00 90.00 277.65 6402.10 -476.37 5464.91 5969207.32 555765.45 12.00 -5464.67 270.00 MWD 9975.00 90.00 274.65 6402.10 -473.69 5440.06 5969209.83 555740.58 12.00 -5439.67 270.00 MWD 10000.00 90.00 271.65 6402.10 -472.32 5415.10 5969211.04 555715.62 12.00 -5414.85 270.00 MWD 10025.00 90.00 268.65 6402.10 -472.26 5390.10 5969210.93 555690.62 12.00 -5390.22 270.00 MWD 10050.00 90.00 265.65 6402.10 -473.50 5365.13 5969209.52 555665.67 12.00 -5365.85 270.00 MWD 10075.00 90.00 262.65 6402.10 -476.05 5340.27 5969206.80 555640.82 12.00 -5341.80 270.00 MWD 'l0096.33 90.00 260.09 6402.10 -479.25 5319.18 5969203.46 555619.76 12.00 -5321.59 270.00 MWD 10100.00 90.00 260.53 6402.10 -479.87 5315.56 5969202.82 555696.14 12.OQ -5318.14 90.00 MWD 10125.00 90.00 263.53 6402.10 -483.34 5290.81 5969199.19 555591.41 12.00 -5294.36 90.00 MWD 10150.00 90.00 266.53 6402.10 -485.51 5265.90 5969196.85 555566.53 12.00 -5270.21 90.00 MWD 10175.00 90.00 269.53 6402.10 -486.37 5240.92 5969195.82 555541.56 12.00 -5245.76 90.00 MWD 10200.00 90.00 272.53 6402.10 -485.92 5215.93 5969196.10 555516.56 12.00 -5221.07 90.00 MWD 10225.00 90.00 275.53 6402.10 -484.16 5190.99 5969197.69 555491.62 12.00 -5196.20 90.00 MWD 10250.00 90.00 278.53 6402.10 -481.11 5166.18 5969200.58 555466.79 12.00 -5171.24 90.00 MWD 10275.00 90.00 281.53 6402.10 -476.75 5141.57 5969204.77 555442.15 12.00 -5146.24 90.00 MWD 10296.33 90.00 284.09 6402.10 -472.03 5120.77 5969209.36 555421.32 12.00 -5124.94 90.00 MWD 10300.00 90.36 284.34 6402.09 -471.12 5117.21 5969210.23 555417.76 12.00 -5121.28 35.00 MWD 10325.00 92.82 286.06 6401.40 -464.57 5093.10 5969216.62 555393.60 12.00 -5096.40 35.00 MWD 10350.00 95.27 287.79 6399.63 -457.31 5069.24 5969223.72 555369.70 12.00 -5071.64 35.05 MWD b ~ BP Alaska ~ ~ p Baker Hughes INTEQ Planning Report ~.r BAK~~ INTEQ Compaoy: BP Amoco Date: 5/25l2007 Time: 14;25:59 Page: 4 Fieid: Kuparuk Co-ord inate{1~1E)Beference: Welk 08, True North Site: KRU 16 Pad Vertical (1'VD) Reference; RKB Efev 1 93 A Well: 08 Section (VS) Reference: Well (O.OON,O.OOE,28Q.OOAzi) Wellpath: Plan 3, 1 B-08AL1 Survey Calculatioo Methoda Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S FJW MapN MapE DLS VS TFO Tool R deg deg R ft ft ft ft deg/100ft ft deg 10375.00 97.72 289.53 6396.80 -449.37 5045.71 5969231.51 555346.12 12.00 -5047.09 35.17 MWD 10400.00 100.16 291.30 6392.92 -440.76 5022.57 5969239.96 555322.93 12.00 -5022.80 35.37 MWD 10425.00 102.60 293.09 6387.99 -431.50 4999.88 5969249.07 555300.18 12.00 -4998.85 35.64 MWD 10450.00 105.02 294.91 6382.02 -421.63 4977.70 5969258.79 555277.93 12.00 -4975.30 36.00 MWD 10456.33 105.63 295.38 6380.35 -419.04 4972.18 5969261.34 555272.39 12.00 -4969.41 36.43 MWD 10475.00 104.50 293.38 6375.49 -411.59 4955.76 5969268.67 555255.92 12.00 -4951.94 240.00 MWD 10500.00 102.96 290.73 6369.56 -402.48 4933.25 5969277.64 555233.36 12.00 -4928.19 239.48 MWD 10525.00 101.40 288.11 6364.28 -394.36 4910.21 5969285.60 555210.26 12.00 -4904.09 238.85 MWD 10550.00 99.81 285.52 6359.68 -387.25 4886.69 5969292.55 555186.70 12.00 -4879.69 238.30 MWD 10575.00 98.20 282.95 6355.77 -381.18 4862.75 5969298.46 555162.73 12.00 -4855.07 237.82 MWD 10600.00 96.58 280.41 6352.55 -376.17 4838.48 5969303.31 555138.42 12.00 -4830.29 237.42 MWD 10606.33 96.17 279.77 6351.85 -375.06 4832.29 5969304.37 555132.22 12.00 -4824.00 237.09 MWD 10625.00 96.16 277.51 6349.85 -372.28 4813.93 5969307.04 555113.85 12.00 -4805.44 270.00 MWD 10650.00 96.14 274.50 6347.17 -369.68 4789.22 5969309.47 555089.12 12.00 -4780.65 269.76 MWD 10675.00 96.10 277.48 6344.50 -36$.38 4764.40 5969310.60 555064.30 12.00 -4755.98 269.43 MWD 10700.00 96.05 268.46 6341.86 -368.39 4739.54 5969310.42 555039.44 12.00 -4731.51 269.11 MWD 10725.00 95.98 265.45 6339.24 -369.72 4714.72 5969308.93 555014.63 12.00 -4707.29 268.79 MWD 10746.33 95.90 262.87 6337.03 -371.87 4693.61 5969306.63 554993.54 12.00 -4686.88 268.48 MWD 10750.00 95.85 263.31 6336.65 -372.31 4689.99 5969306.17 554989.92 12.00 -4683.39 97.00 MWD 10775.00 95.47 266.30 6334.19 374.56 4665.21 5969303.75 554965.17 12.00 -4659.38 97.04 MWD 10800.00 95.08 269.29 6331.89 -375.52 4640.34 5969302.63 554940.30 12.00 -4635.05 97.34 MWD 10825.00 94.68 272.28 6329.76 -375.18 4615.44 5969302.81 554915.40 12.00 -4610.47 97.61 MWD 10850.00 94.26 275.26 6327.81 -373.54 4590.57 5969304.28 554890.52 12.00 -4585.69 97.87 MWD 10875.00 93.83 278.23 6326.05 -370.61 4565.81 5969307.04 554865.75 12.00 -4560.80 98.10 MWD 10896.33 93.46 280.77 6324.69 -367.10 4544.82 5969310.41 554844.73 12.00 -4539.52 98.31 MWD 10900.00 93.34 281. i 9 6324.47 -366.40 4541.22 5969311.08 554841.13 12.00 -4535.85 106.00 MWD 10925.00 92.51 284.08 6323.20 -360.94 4516.86 5969316.38 554816.74 12.00 -4510.91 106.03 MWD 10950.00 91.67 286.96 6322.29 -354.26 4492.79 5969322.90 554792.63 12.00 -4486.05 106.17 MWD 10975.00 90.82 289.84 6321.74 -346.37 4469.08 5969330.63 554768.86 12.00 -4461.33 106.28 MWD 10996.33 90.10 292.30 6321.57 -338.70 4449.18 5969338.17 554748.91 12.00 -4440.40 106.34 MWD 11000.00 90.00 291.87 6321.57 -337.32 4445.77 5969339.52 554745.50 12.00 -4436.81 256.80 MWD 11025.00 89.32 288.95 6321.72 -328.60 4422.35 5969348.08 554722.02 12.00 -4412.22 256.80 MWD 11050.00 88.64 286.03 6322.16 -321.09 4398.51 5969355.43 554698.13 12.00 -4387.44 256.82 MWD 11075.00 87.96 283.10 6322.91 -314.81 4374.32 5969361.55 554673.91 12.00 -4362.53 256.87 MWD 11100.00 87.28 280.18 6323.95 -309.77 4349.86 5969366.43 554649.42 12.00 -4337.57 256.96 MWD 11125.00 86.61 277.25 6325.28 -305.99 4325.19 5969370.04 554624.72 12.00 -4312.61 257.08 MWD 11146.33 86.05 274.75 6326.64 -303.76 4304.02 5969372.12 554603.54 12.00 -4291.38 257.23 MWD 11150.00 86.05 275.19 6326.89 -303.45 4300.37 5969372.42 554599.89 12.00 -4287.73 90.00 MWD 11175.00 86.06 278.19 6328.61 -300.54 4275.61 5969375.16 554575.11 12.00 -4262.84 89.97 MWD 11200.00 86.08 281.20 6330.33 -296.34 4251.02 5969379.19 554550.50 12.00 -4237.90 89.76 MWD 11225.00 86.11 284.21 6332.03 -290.85 4226.69 5969384.51 554526.14 12.00 -4212.99 89.56 MWD 11250.00 86.15 287.22 6333.72 -284.10 4202.69 5969391.10 554502.09 12.00 -4188.17 89.35 MWD 11275.00 86.20 290.22 6335.39 -276.10 4179.06 5969398.95 554478.42 12.00 -4163.52 89.15 MWD . 11300.00 86.26 293.23 6337.04 ~ -266.86 4155.89 5969408.03 554455.19 12.00 -4139.10 88.95 3.50" ~ • ~ ~ Kuparuk`CTD BOP Configuration for Managed Pressure Drilling 2'/a" CT Well ~ 1 B-08A Floor I Lubricator ID = 6.375" with 6" Otis Unions 1 ~ ~ C ~ C 3" 5000 psi ~ ~.1 HCR M Choke Line ~ C ~ ~ ~ -~ Tree Size 4-1/16", 5M 7 1/16" 5000 psi, RX-46 ~ 7 1/16" 5000 psi RX-46 Kill Line t L I 2 1/16" 5000 psi , RX-24 ~- 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve ee SSV Master Valve Base Flan e Page 1 .. , ~ Kuparuk~TD BOP Configuration for Managed Pressure Drilling 2" CT Well 1 B-08A Rig Floor ~ ~ ~ C ~ ~ 3" 5000 psi I ~ • HCR M Choke Line ~ C ~ C ~ Tree Size 4-1/16", 5M Flow T n a- Lubricator ID = 6.375" with 6" Otis Unions ^ 7 1/16" 5000 psi BOP's. ID = 7.06" 7 1/16" 5000 psi, RX-46 ~- 1/4 Turn LT Valve SSV Master Valve Base Flan e Page 1 KRU 1 B-08AL 1 AREA OF REVIEW zo?-o~S- ~l B-03 6-12 -08 _ _ ,' SW-03 . . ~ C-'1-~ ~ ~ ~S ~ p_~ ~ ~ ~ r o~,~.~ ;~ ~ -0 ~ -~ , ` - _ - -- '~-~1~~'~'~3iL1 ~ ' ,----- ~~ ~ B-~~/~L~ ~ . ~ _:_ ~ ~ S ~~~ ~ ~ ~~ ~~~~ <<~~-~119 ~ ~ _ -~ - _ _ ,. ; ~ ~ __~ . ~ ' - ;'I B-}{~~A ; ~, ; S - ~ - ~ , _. ~-~ , ~ ; ~ ;f ~.i ~ ~ ~ S -05 .--~;~-B ~8 I ~',, 15 ; g-17 ~ a ~ ~ ~I .'~ _~ g B- _ - = " ~ _ , ~ ~ ~~V L~'~ _'~ -- ~ P F-01 A ~ ~,~. ~ B-15 ' 2 ~~ ~; ~ ,' ^` ti,~~`h ~-~~-- j ' ~~ , O S~a~f-+.~ ~~ _~' --~ ' 4 ., ~~„ v~~~~ ~ ,~-~~,. ~6 7 ~ ~~~~~~ ~ ~ ~ ~ ~ ~ ~~~_ ; ~ E- ~ ~ ~~~~ :.~ ~~~ ~ ~~;~, ~- , ,, , _.__ ~ __ __ _ ~=~~ ~ _.. _. - --_ _ _ ~ , . _ ~ ~ ~~~ _~g ~ ~~ ' ' ~ T 11 , RlOE, UM ~ ~ ~ \\DOA-ANC-AOGCC\VOLI\HOME~AOGCC\SFDAVIES\Daily_Doc;ument_Record\2007\070604_2070750_KRU_1B-08AL1_Location_Map.ppt SFD 6/4/2007 s • PERMIT TO DRILL 20 AAC 25.005 (e) Each well branch requires a separate Permit to Drill. If a previously drilled well is proposed to be redrilled below the structural or conductor casing to a new bottom-hole location, the application for a Permit to Drill must be accompanied by all items required under (c) of this section. If concurrent multiple well branches are proposed from a single conductor, surface, or production casing, (2) for each other well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that well branch and need not be accompanied by the $100 fee. ~ ~ ~'RAi~TS~IITT'AL [.~E~'TER ~'I~.ECK.L.IST ~VEL.L NA~'~IE ~ ~~ -L~~i~t- ~. ,~ PTD# Zb ~ D'7~ Deve[opmenr Service Ex loraro _ iYon-CoaveQtionat Well P ~'~ Stratigraphic Z'est Circie Appropriate Letter / Pa~graphs to be Includ~d ia Transmitta! Letter ' CE~CK I ADD-OiVS 1"EXT' FOR APPROVAL LETTER ~ 4L'HAT ! I (OPTIONS) ; ; APPGtES ~ i , i I MliLTi LATERAL ; T'he f perrnit i; or a new weii6ore se nt of exi~ting i / + j ~~ /~ -D~~ , i j~ (IF last two digits in ~`~e[1 ; ; API number are : Permit Yo. -// , AP( No. ~0-0~.~_ _~ . ,`' between 60-69) ~'rvdaction should continue to be reported as a function of the f ~ originat AP[ number stated above. ~ P(LOl" HOLE ' ' I ~[n accocdance with 20 A..4C 25.005(~, ait records, data and [o~s ; ~ j ~ acquired far the pitot hole must be cleac(y diffecentia.ted in both ~ i ~ i '(,ptl name ( PE~ and API nurctber ~ i -_) from records, data and lo~s ~ ~ ~ acquired for we[t ~ SPACING The permit is approved subject to fu!! compliattce with 2p ~ ' EXCEPTION ~ 2~.055. Approvat to pecforate and produce / in~,ect is conting t? ' , ( upoa issuance of a conservatior~ o r d e r approving a spacing ~ ~ ~ exception. ; I liabi[ity ofany protest ro the spacing exception that may oc urs ~e j ; DRY DITCH ' i SA!bIPLE i ,' ~ 1~on-Conventionat , j Wel1 f i ~ ~ ~ I ~ ~ AI! dry ditch sampie sets subrnitted to the-Eommission must be in ; ~ no greater than 30' sampte intecvals fi-om betow~ the permafrost or ; ~ from where sampies are fint caught and 10' sample intere~•als j , through target Zones. i ~ ~ Please note the following specia! condition of thi; i permit: ~ ~ production or production testiag of coa! bed methane is not atlowed ~ ~ for (name of wetl) until after (Cornoanv IYarrie) has designed arid i ~ imp[emented a water welt testing program to provide base(ine data ; oa water quality artd quantity. 1Comnanv 1Yamel must contact the ~ ! Commission to obtain advance approva! of such water well testing ! ra , , \ Rev: [ 2~i06 C '1~Y~«nsmitta!_checklist Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 B-08AL1 Program SER Well bore seg 0 PTD#:2070750 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type _ SER I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ ` Administration 1 Pe[mit fee at#ached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ Multilateral well bo[e; fee waiyed_per 20 AAC 25.005(e) _ . _ _ _ 2 Lease number appropriale_ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ . Cor[ected 10-407: TD in.ADL_025648,to_ in'ection interval in ADL 025649., . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , P 1 3 Uniquewell_nameandnumber___________________________ Yes_ ___________________ --- - -- -- - ----- -- - 4 Well located in_a defined_pool. , _ _ . _ _ _ _ _ - Yes _ _ _ _ . _ . KUPARUK RIVER,.KUPA_RUK_RV OIL - 490_10Q governed by Conservation Order No. 432C._ _ _ _ _ _ _ _ 5 Weli located proper distance from drilling unit_boundary_ _ _ _ _ _ _ . _ Yes _ _ _ _ _ _ _ Cpnseryation Orde[ No. 432C contains no spacing restrictions with [espectto d[illing unit boundaries. _ _ _ _ _ _ _ _ 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . _ _ _ Conseryation Ord_er No. 432C has_no intenvelLsp~cing_ restrictions. _ _ _ _ _ _ _ _ _ _ _ . . . _ _ 7 Su_fficient acreage_ayail_able in_drilling un_it_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Con_servation Orde[ No. 432C has.no interwell_spacing_restrictions, Wellbote_will be.more than 50Q from _ _ _ _ _ _ 8 If_deviated, is_wellbore plat_included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ an extemal property line_wh_ere ownership or_landownership_changes._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 9 Operatoronlyaff_ectedparty_--------------- ------------ ----------Yes- ------ ----------.- 10 Ope[atorhas_appropria~ebondinforce_______________________ __________ Yes_ ._____.__ ----- --- -- -- -- --- -- --- ------ -- -- 11 Permitcanbeissuedwithoutconseryationorder_________________ __________ Yes_ ____________.______ -- Appr Date ~ Z Pe[mit rzn be issued without administrative_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _ _ _ - -- SFD 6/4/2007 ~ 3 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authqrizQd by Inje~tion Order # (put 10# in_comments). (Fpr_ Yes _ . _ _ _ _ _ Area Injeckion_Order No, 2B _ _ _ _ _ _ _ _ _ _ _ _ _ - 15 All wells.wit_hin 114_mile area_of reyiew identifed (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes , _ _ , . _ KRU 1 B-O8, KRU_1 B-08A_ _ _ _ _ _ _ _ _ _ _ _ _ _ , , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- 16 Pre-produced injector; dur_ation_of pr_e production less than 3 months (For_seryice well only} _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 17 Nonconven, gas conforms to AS31,05,030(j.1_.A),(~.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ -- -- Engineering 18 Condu_cto[string_p_rovided____________________,__________ _________ NA__ ______Conductorinstalledin1B-08(181-113)._._____________,______ 19 Surfacecasingprotectsall_knownUSDWs__________ __________ _________ NA__ _____ Allaquifersexempke~,_40CFR_147.102(b~(3),_____________,.___._________________ __ 20 CMT_vol adeguate_to circul_ate_on conducto[ & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ . Surface casin mstal_led in 1 B-08. _ g -- 21 CMT_v_oladequate_totie-inlongstringtosurfcsg___________________ ________ NA__ _____ Productioncasinginstalledln.1B-08,____.._._____ __________, _____.__.____ ___ __ 22 CMT_will coyer.ali known_productive horizqn_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Slotted_liner completion pl_anned, _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . , _ _ . _ _ _ _ _ _ 23 Casing des~n~ adequate fo[ G,_T, B & permaf[ost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ Original tubulars metdesi r~ s ecifcations, NA for slotted IinQr. _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 p 24 Adequate tankage_or reserue pi# _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig is, equipped_with steel_p~s. No reserve_p_itplanned, All waste to_appr~yed dispos_al well(s). _ _ _ _ . _ _ _ 25 If_a_re-drill, has_a 10-403 for ab~ndonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA, _ _ _ _ _ _ _ - - - 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ _ _ _ Proximity analysis performed, Nearest segment is 16-08A and_paihs diverge._ _ _ _ _ _ _ . , . _ . , _ . _ _ . _ _ , _ 27 If_diverter required, does it mee~ regulatigns_ _ _ . _ _ _ _ _ _ _ _ - NA. _ -- - _ _ _ _ _ _ BOP stackwill already be_ip place_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 Drillinq fluid_ program schematic.& equip list adequake_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Maximum expected fotmatiqn prQSSU[e 9,6_EMW, Plan to dynamic overbalance_ with 8:6_ ppg fluid and circulating _ TEM 6/1012007 2g BOPEs,_do they meetregulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ _ _ _ _ _ . . Density.. 2 volumes of kill weight_fluid will_be_avail_able in.Kuparuk Field._ _ _ _ _ . _ ~+~y„` 30 BOPE_press raiing approp[iate; test to,(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes , _ _ _ _ _ _ MASP calculated_at 2$25 psi, 3500_psi_ BOP test_planned, _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ . _ _ _ _ . _ _ _ _ ~ 31 Chgke_manifold complies w/AP( RP-53 (May 84)_ _ _ . _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ ~ 32 Workwilloccurwithoutoperationshutdown___._._.____________ ________ Yes_ _______.____________ ,____________.___._______,_ 33 Is presence.of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ . _ H2S is repo[ted_on.1B_pad._ Mud should p[eclude.H2_S.on rig._ Rig h~s ~ensors and_alarms._ _ _ _ _ _ _ _ _ _ _ _ 34 Mechanic~l_condition of wells within AOR yerified (For_service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ No i_ssues with AOR._ _ _ -- - Geology 35 Permil can be issued wlo hyd[ogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ All welis on KR~11 B-Pad measure_?20 ppm H2S._ H2$ measuCes aCe_mandatory.. _ _ _ _ _ _ _ _ _ . _ . _ _ _ . . . _ 36 Data_p_resented on potential overpressur_e zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Expected [eservoir.pressure is 9:6_ppg EMW decreasing to 8,4_ppg aS the target fault block is entered_. Max, _ _ Appr Date 37 Seismic analysis qf shallQw gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ . _ _ _ _ expected_ pressure is_ 10,4_ppg EMW. _Will be drilled w~h 8.6 ppg mud_ using coiled tubing and. ~mploying _ _ _ . _ . SFD 6l4I2007 38 Seabed condition suryey (if off-shore) _ _ _ _ _ _ _ NA_ _ _ _ managed pressure drilling techniques, _ _ _ _ _ _ _ _ _ _ _ _ _ 39 Contact name/phone for weekly_progress reports [exploratory only] _ . , _ _ _ _ _ NA _ _ _ Geologic Commissioner: Engineering Public Date: Commissioner: Date ' ner Date Multilateral wellbore tar etin Ku aruk C4IC3 sands to rovide increased in ection su ort. 9 9 P P 1 pP `~ ~ ~ 6~~~ (~ ~~~-o ~~ ~