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Home My WebLink About207-076~ • ~~ ~ ~'~~~~~ ~~~ ~3~~~~ ~~~~ ~~~~~° ; ~ 19J~~~~L ~~is pag~ ider~iifies ~r~ose ite~s tha~ ~ere ~o~ ~ca~c~ed d~~ir~g ~t~e ~nitoa~ ~r~d~~tio~ ~~a~~i~g p~as~. T~ey are available in the ~riginal ~ile, r~ay ~e scan~ed dur~ng ~ special resca~a ~ct9vgty ~~ ~~-e vievva~le ~y direct ~r~spectior~ ~f ~he file. a V -/ ~ ~ ~~p ~e10 ~I°s~~~ry ~s9e ~d~rat~fier ~/'~a-1/Z917~ (done) RESCp-N ~olor Items: ^ Greyscale Items: ,,~wo-sided I~~ ~~I~II ~I II~ ~I ~N DIGITd~L DATA ^ Diskettes, No. ^ Other, No/Type: ^ Rescan Needed ~I~II~~~I~~~IIIII~I OVEftSIZED (Scannable) ^ iVlaps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Poor Quality Originals: ^ Other: NOTES; BY: Maria Date: ^ Other:: ~S~ Project Proofing IIIII'IIIIIIII ~I~II 6Y: Mana Date: ~S~ ' ~ ti x 30 ~ =~Q~ +~= TOTAL PAGES~ on Scanning Prepara _ . ,,,///~~~ (Count does not include cover sheet) ,/~/) ~{,.~ BY: Maria ~' Date: /~ ~ D~ n /s/ ~ ~ K ~ Production Scanning """"""" Stage 1 Page Count from Scanned File: ~ v (Count does include cov r sheet) ches Number in Scannin Preparation: ~YES NO Page Count Mat 9 BY: Maria Date: ~ ~~ ~ ~ ~S~ ~ ~ ~ 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. I) I I) II (I I II I) I I II) PZeScanned III II~II) ~III) II ~I) BY: Maria Date: ~S~ Comments about this file: Quality Checked III II'I~) (I~ I~~I'll 10/6/2005 Well History File Cover Page.doc ~ ~ ~.. A ~ `"" is ,~.Kr ~ ~, merit,- ., , ~~ ~ ~ =,.; ~ ... m~ ~. ,t ~ }~ ~'~ < , ~ ~~ ~ _. ~~~', ~;~.: ~~ ' ~~ ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ConocoPhillips Alaska • RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, M633 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia"* Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia'"' Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS uzc ~o~ -~ ~ t9a3a <~~3 ao~s-o~G~ ~9a3 vsc 2~~-~~-~ ~o~4s- /o~-f ~ `~ b 35 1 "` ~_" E ~ 5 _ DEC ~ ~ X009 Masks Dil ~ ~a~ C®ns C~t~r~'niasion A~nc~ra~ ~p~, ~ vc~ I ~io3 ~ ~.-~a- ~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070760 Well Name/No. KUPARUK RIV UNIT 1B-08AL1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20635-61-00 MD 11304 ND 6535 Completion Date 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: DIR, RES, GR Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Weil Data Maint Log Log Run Interval OH / Type ed/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 0 11304 Open 9/25/2007 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ~ Well Cored? YJ N Daily History Received? Chips Received? "-~= Formation Tops ~N Analysis ~hIQ' Received? Comments: ~ ~ ~~~~ ~~c~~,~~~C ~ V ~ ~ Compliance Reviewed By: _ Date: v ~ ~{ \ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COM~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~~~rvEa ~.~~ a ~ 7 2007 ~;,,, ~~„~ ,~, ~a~ Cons. Cammission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zo,v~c zs.~os zo,v~c zs.~~o ^ GINJ ^ WINJ ^ WDSPL ~ WAG ^ Other No. of Completions One 1b. Well Class: ~~~~y~t8g~ ^ Development ^ Exploratory ~ Service ~ ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 7/26/2007 ~ 12. Permit to Drill Number 207-076 ~ 3. Address: Go P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/16/2007 ' 13. API Number 50-029-20635-61-00 ' 4a. Location of Well (Governmental Section): Surface: 501' FNL 141' FEL SEC T11N R1 09 U ' 7. Date T.D. Reached 7/19/2007 14. Well Name and Number: 1B-08AL1-01 ~ , , , . , 0E, M Top of Productive Horizon: 999' FNL, 207' FWL, SEC. 11, T11N, R10E, UM 8• KB (ft above MSL): 93' . Ground (ft MS~): 15. Field / Pool(s): Kuparuk River Unit / Kuparuk Total Depth: 287' FNL, 5085' FWL, SEC. 10, T11N, R10E, UM 9. Plug Back Depth (MD+'n/D) 11304 6535 River Pool - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 550298 - y- 5969648 " Zone- ASP4 10. Total Depth (MD+ND) , 11304 6535 ' 16. Property Designation: ADL 025648 o2S~! TPI: x- 555930 y- 5969190 Zone- ASP4 Total Depth: x- 555523° y- 5969899 ~ Zone- ASP4 ~ 1. SSSV Depth (MD+T'VD) None 17. Land Use Permit: ~ `J-`~•O 18. Directional Survey ~ Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1465' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, RES, GR 22• CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT- ` WT: PER FT. GRADE TOP `B07TOM TOP BQTfOM SIZE CEMENTtNG REGORD PULLEDI ` 2-3/8" 4.44# L-8 10364' 11304' 6502' 6535' 3" Uncemented SI ed Liner 23. Open to production or inject ion? ~ Yes ^ No 24. TuaiN~ RecoRo If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): Size ~EPTH SET MD PACKER SET MD 2-3/8" Slotted Section ' Note: 1 4-1/2", 12.6#, L-80 6135' 6110' MD TVD MD TVD ~~~ `1 `•~~a ~ ~ 10545' - 11270' 6506' - 6528' Well Branch6l Well Branch 16-08AL1- y0"~ ~1 B-08AL1-01 25. Acio, FRACTURE, CEn~terrr SQUe~, ~rc. , o Departs From,~.4' is not Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Well Branch Accessible 1 B-08AL1 10338' Set Whipstock (Recovered 07/24/07) PTD # 207-075, at 10338' MD 6502' TVD 2000' Freeze Protect w/ Diesel ( ) 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: PRO~ucrioN FoR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIp: Flow Tubing Press. Casing Press: Ca,LCU~a,Te~ 24-HouR FtaTe• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: 27. CoRe Da,Ta Conventional Core(s) Acquired? ^ Yes ~ No " Sidewal l Core s A uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+7VD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. S ~~ SEP ~ Q ?D0~ ~~~Eriori`~ None ' .p~~ U'ER - ED ~ ~! Form 10-407 Revised 02/2007 0 R I G 1 N A~TINUED ~N REVERSE SIDE ~~~~ ~~~~ L3_r/ 07 ! T~ ~ ~ ~H. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AN ERS ENCOUNTERED~: Z9. FORMATION TESTS NAME ND Well Teste ~^ 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. From 1 B-08AL1 None ' Kuparuk - Base of C4 / Top C3 9315' 6478' Top C3 / Base C4 (Inverted) 9870' 6496' From 16-08AL1-01 Kuparuk - Base C1 / Top B 11272' 6529' Formation at Total Depth (Name): Kuparuk - Base C1 / Top B - 11272' 6529' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ~ng is true and correct to the best of my knowledge. ~ Signed Terrie Hubble Title Technical Assistant Date ( Z~ ~ 4 B-08AL1-09 207-076 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A ~OV81 NO. Drilling Engineer: Gary Ellei 529-1979 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. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Muttiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Irem 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data peRinent to such interval). ITeM 26: Method of Operation: Flowing, Gas ~ift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). tTeM 27: Provide a listing of intervafs cored and the corresponding formations, and a brief description in this box. Submit detailed description and analyticaf laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ~ ~ ' BP AMERICA Page 1 of 26 Operations 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 Mours Task Code NPT Phase Description of Operations 6/28/2007 ~ 12:00 - 15:00 3.00 MOB P PRE Spot herculite and rig mais around 1 B-08. i 15:00 - 16:30 1.50 MOB P PRE Move rig onto mats in front of well. Lower BOPs to rig mat. ~ lnsta!! 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. 17:00 - 18:30 i 1.50 RIGU P PRE RU berm around cellar. Spot cuttings box. Move office trailer. ~ Change injector gripper blocks to 2-3/8" : I ~ ' 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 !~ i I on VECO lowboy. Load in 2-3/8" E-CT. Cut herculite and ' , ' ~~ ~ , berm around rig for rig washing. Kuparuk WeAs Services RU ' hardline to tiger tank ! 20:45 - 23:30 I 2.75 ~ BOPSU P PRE NU BOPE. Set mousehole. Spot cuttings box. RU hardline in ~ I reelhouse. Install packoff in injector 23:30 - 00:00 0.50 ~ BOPSU P PRE Test BOPE. AOGCC waived witness I PreSpud mtg 6/29/2007 j 00:00 - 03:30 I 3.50 BOPSU P PRE Continue BOPE test. No failures ' ' I i l Continue to RU berm around rig 03:30 - 05:00 i 1.50! RIGU P PRE RU injector and gooseneck I05:00 - 08:30 , 3.50 j RIGU P ~ PRE Install internal grapple and PT. Remove shipping bar. Pull CT ' ~ ' to floor. Stab coil. Fill coil 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 , I 720 psi on well. RD lubricator. remove same from rig floor. ' Circulate coil 2.5 volumes while puliing BPV. ', 15:00 - 15:15 , 0.25 ~ KILL P ~ W EXIT Hold PJSM. MU 3.5" nozzle assembly with stinger. Pressure I j ' test packoff to 1000 psi. Ok. ', 15:15 - 16:45 i 1.50 KII.L P W EXIT Open well. 760 psi ISITP. Bleed well to tiger tank. Bleed 10 ; bbls diesei. Shut in well antl monitor pressure build up. ,16:45 - 18:45 2.00 KILL P WEXIT Run in hole with nozzle. ,~Jold 700 psi WHP. Circ at min rate, ( ' 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 Haliiburton Unit down pad. Post tank watcher to ; "guard" tank and monitor wind direction. Tag whipstock at i 9243'. Pick up to 9240'. Finally wise up and decide fo bullhead i down the CT annulus. 3.0 bpm at 1835 psi. Pump up packoff. ~ Displace wellbore w/ 180 bbls (ann vol is 90 bbls) of 8.75 ppg used FloPro mud. FIP 1835, ISIP 1800, 10 min 1600 j TT PVT 59 bbls 18:45 - 19:20 0.58 KILI P WEXIT After 20 min, SIP=1500 psi. Begin circ 02/1700 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 19:20 - 21:00 1.67 KILL P WEXIT 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 pii. 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 bbls 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 STW HIP P W EXIT LD nozzle assy. Set injector on legs. Chg packoff 21:45 - 22:05 0.33 STWHIP P WEXIT Safety mtg: pressure deployment 22:05 - 00:00 1.92 STWHIP P WEXIT ~ Bring BTT motor and mill to floor and set in lub. Pressure Printed: 8/6/2007 2:44:30 PM • ~ BP AMERICA Page 2 of 26' Operations Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+COMPLETE Start: ~ 6127I2007 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 -- - --~- 6/29/2007 22:05 - 00:00 ; 1.92 i STWHIP P ~ WEXIT deploy MWD assy w/ 500 psi 6/30/2007 00:00 - 01:35 ; 1.58~ STWHIP P i WEXIT Open VBR's to 450 psi. Tag up w/ 2.0'. RIH circ thru mill i ; 0.57/1200 holding 700 psi whp 01:35 - 02:00 i 0.42; STWHIP P WEXIT 91Q0' 19.3k, 6.8k RIH to tag at 9260.3' CTD. PVT 180 PUH I. w/ 2k overpull. Start motor 2.52/2290. Drop whp to zero, but ! ' j gained 3 bbis at 0.5 bpm. Appiy 300 psi whp and RIH I ! i I ' 2.52/2290 and first MW was at 9258.4'. Corr to 9265.0' and ~ ; ~ I flag ~ 02:00 - 02:30 ~ 0.50 ~ STWHIP P ~ WEXIT Mill window by time schedule according to BTT. Red rate to j ' , I 2.34/2135 due to BHI getting bad vibrations. DHP is 3470 psi ~ i I w/ 300 psi whp. No decrease in mud wt at btms up so assume j ', , formation is charged up. Red whp to 250 psi. First serious i I i 02:30 - 03:00 ~ 0.50', STWHIP; P I WEXIT MW at 9265.6' MiA from 9265.6' 2.31l2i35 w/ 250 psi whp=3360 psi ', ~ , ~ ~I dhp=10.18 ECD PVT 185 03:00 - 04:00 ,; 1.001 STWHIPj P I 'I WEXIT Mill from 9266.2' 2.23/2060 w/ 200 psi whp=3300 psi dhp=10.0 ' ' I ECD PVT 186 1.3k wob 04:00 - 04:30 ,' 0.50'~ STWHIP~ P ! WEXIT Mili from 9267.0' 2.09/1910 w/ 175 psi whp=3268 psi dhp=9.91 ' I ~, ECD PVT 185 1.87k wob 04:30 - 05:00 ', 0.50; STWHIP! P , i 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'I STWHIPi P ~~ I WEXIT Mill from 9268.0' 2.07/1900 w/ 150 psi whp=3240 psi dhp=9.80 ~, ' ~ '; ECD 3Ak wob 06:15 - 11:15 !, 5.00 ~, STW H I P P , ~ W EXIT Miil from 9268.5'. 2000 psi fs at 2.36 inl2.35 out. 200-300 ~ j I 'i I dpsi. 3k# dhwob. WHP/BHP/ECD: 170/3258/9.87 ppg. ', ~I ~! ' i IA/OA/PVT: 431/44/193 bbls. ' 11:15 - 13:00 'i 1.75 j STWHIP~I P WEXIT Continue to mill from 9272.6'. 1900 psi fs at 2.16 in/2.19 out. ! ', I I 200-350 dpsi. 2.Ok# dhwob. WHP/BHP/ECD: 157/3286/9.95 I~ I j ppg. PVT: 194 bbls. Using reduced pump rate to reduce down ' ~ hole vibration. Drilling for~,mation at 9272'. Drill rat hole to I ~ 9283'. ; 'i CorrectedTop of window: 9256'. i Bottom of window: 9263'. 13:00 - 14:00 1.00 j STWHIP P WEXIT Back ream window three times. Sut in welV and dry drift. i Window smooth. Geologist reports galuconite in btms up ' ~ sample. ' 14:00 - 16:00 2.00 i STWHIP P WEXIT Circulate out of hole maintaining constant BHP using choke. ! I 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 depioy 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 OJ5 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 I ; 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'. I ~ Try muitiple times w/o success and always stop at the same i Printed: 8/6/2007 2:4430 PM ~ ~ BP AMERICA ' Page 3 ofi 26 Operations Summary, Report Legal Well Name: i 8-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 i Spud Date: 6/27/2007 Start: ~ 6/27/2007 End: 7/26/2007 Rig Release: 7/26/2007 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations -~--- ~ 7/1/2007 01:00 - 02:50 1.83I DRI~L ', N ! DPRB ~ PROD1 spot. Get crude contaminated mud back while circ at 0.5 bpm 02:50 - 03:30 0.67'i DRILL ~I N 03:30 - 03:45 0.25 DRILL ' N 03:45 - 06:00 2.25' DRILL i I, N 06:00 - 08:30 2.50 i DRI~L I N 07:45 - 08:45 08:45 - 10:30 10:30 - 12:30 12:30 - 12:45 12:45 - 18:45 1.00: DRILL 1 J5', DRILL 2.00' DRILL 0.25' DRILL 6.00 DRILL ~ 18:45 - 20:30 ' 1.75'' DRILL i I N 20:30 - 22:20 1.83, DRILL ', N 22:20 - 23:20 1.00; DRILL I N 23:20 - 00:00 0.67' DRILL I N 17/2/2007 I 00:00 - 02:00 I 2.00 02:00 - 03:55 1.92 03:55 - 04:20 0.42 04:20 - 05:15 0.92 DRILL I N DRILL N DRILL N DRILL , P I w/ 350 psi whp and incr to 450 psi whp. Go around the ciock 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' ~i 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 I DPRB ~ PROD1 Open EDC and circ out crude contaminated mud while discuss. Returns cleaned up to 8.56 ppg after 20 bbls DPRB PROD1 POOH circ thru EDC 2.4/1950 following pressure schedule i DPRB I PROD1 Hold PJSM. Pressure undeploy BHA. Review undeploy procedure during operation. ', DPRB PROD1 Test MWD tools on rig floor. ', DPRB PROD1 PJSM. Make up miliing assembly (3.73 window mill and string ' reamer on 0.9 deg mtr) with HOT and DGS tools. Pressure ' deploy BHA. FOund 450 psi on well once open. DPRB , PROD1 Run in hole. Maintain constant BHP. DPRB ! PROD1 Log gr tie in from 9200'. Add 16' correction. RIH. DPRB ~ PRODt 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. PROD1 POH circ thru miil 2.65/2330 foliowing pressure schedule PROD1 Pressure undeploy w/ 435 psi PROD1 Test MWD assy PROD1 Pressure deploy w/ 385 psi. Have trouble getting the bit by the tubing hanger DPRB PROD1 Continue trying to get bit past the tbg hanger (0.5). Fin pressure deploy w/ 366 psi DPRB PROD1 RIH circ 0.5/850 thru EDC following pressure schedule DPRB PROD1 Log tie-in down from 9213', corr -11'. Close EDC 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 125 bpm and acts like formation. Incr pump to 2.4/2285 and ease in hole holding 200 psi whp. Start getting the normal crude in the mud back so send it to tiger tank in prep for mud swap. Finish ream OH w/ 1-3k wob and find TD at 9283' PROD1 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. Drili build and turn to 9450'. PRODi 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. 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: 05:15 - 08:15 I 3.001 DRILL I P ~ 08:15 - 10:30 I 2.251 DRILL I P 10:30 - 12:30 I 2.001 DRILL I P Printed: 8/6/2007 2:44:30 PM ~ ~ BP AMER'ICA ' Page 4 of 26 Operations Surnmary 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 I Task Code ~ NPT Phase Description of Operations ~ 7/2/2007 ~ 10:30 - 12:30 ~ 2.00 ~ DRILL ~ P 12:30 - 13:15 0.75 DRILL P 13:15 - 15:15 2.00 DRILL P 15:15 - 15:45 0.50 DRILL I P 15:45 - 17:30 1.75 DRILL ~ P 17:30 - 18:00 I 0.501 DRILL I P 18:00 - 19:30 ~ 1.50 DRILL j P ', 19:30 - 21:45 i 2.25 DRIL~ i P 21:45 - 22:00 ~ 025 DRILL I P 22:00 - 00:00 2.00 DRILL P 7/3/2007 00:00 - 01:00 1.00 DRILL P ~ 01:00 - 02:50 i 1.83 DRILL I P ' 1 02:50 - 03:10 ~ 0.33 DRILL I P , ~ 03:10 - 03:30 ~ 0.33 DRILL ' P i ' ~ 03:30 - 05:00 1.50 DRILL i , P 05:00 - 05:20 0.33 DRILL j P 05:20 - 07:15 1.92 DRILL ! P 07:15 - 08:30 08:30 - 09:30 09:30 - 11:30 11:30 - 13:00 13:00 - 14:15 1.25 DRILL P 1.00 DRILL P 2.00 DRILL N 1.50 DRILL P 1.25 DRILL P ~ PROD1 i I PROD1 I PROD1 ~ ; PROD1 ~ PROD1 i ~PROD1 IPRODI IPRODI i ;PROD1 '~PROD1 ~PROD1 PROD1 ; PROD1 PROD1 i PROD1 ~ !PROD1 ';PROD1 i PROD1 PROD1 STUC PROD1 PROD1 PROD1 14:15 - 17:00 2.75 DRILL N DFAL PROD1 17:00 - 17:15 0.25 DRILL N DFAL PROD1 17:15 - 18:00 0.75 DRILL N DFAL PROD1 18:00 - 20:50 2.83 DRILL N DFAL PROD1 20:50 - 21:00 0.17 DRILL N DFAL PROD1 21:00 - 23:00 2.00 DRILL N DFAL PROD1 23:00 - 00:00 I 1.00 I DRILL I N I DFAL I PROD1 150/3550/10.63 ppg. IA/OA/PVT: 431/45/356 bbls. INC/AZMlfF: 90.8/8.97/277 deg. Build complete, continue turn to the left. ROP: 50-80 fph. W iper trip to window. Hole smooth. 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. Wiper trip to window. Reduce circ rate through window. Open EDC. Circulate out of hole. Hold PJSM. SIWHP: 392 psi. Tag up and space out coil. Close rams. Push/pull test. Close variables. Bleed off pressure. Finish pressure undeploy w/ 382 psi Cut off 25' slickline and rehead while BHI reconfigue tools string and program res tool Safety mtg re: pressure deploy MU BHA #5 and pressure deploy w/ 370 psi. PT CTC @ 3800 Finish pressure deploy BHA #6 RIH circ thru EDC 0.5/1250 following pressure schedule Log tie-in down from 9225', corr +3'. Close EDC RIH thru window, clean. Precautionary ream 20'/min 2.45/2900 w/ 150 psi whp clean to TD tagged at 9730' Log MAD pass up for resistivity data at 300'/hr to 9296' Wiper back to TD was clean PVT 353 Driil 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.A 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. W iper trip to window. Hq,~ smooth. Drill ahead from 9900'. Became differentially stuck at 9994'. 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 bbis slick diesei. Spot 5 in open hole. DHWOB changed from -3k# to zero. Picked up. Coil came free at 40k# up wt. (normal up weight is 20k#). Wiper trip to window. Circulate out diesel. Drill ahead from 9,990'. 3000 psi fs at 2.58 in/2.51 out. 50-100 dpsi. 1k# dhwob. WHP/BHP/ECD: 55/3458/301 bbls. INC/AZM/TF: 89.7/278.5/275 deg. Limiting ROP to 60-80 fph to try and avoid differential sticking problem. Hit a hard spot. Having problems with orienter and controlling tooi face. Trouble shoot MWD. Unable to resolve the problem. W Iper trip to window. Circulate out of hole. PJSM prior to pressure undeploying. Swab's shut. LD MWD tools. MU new MWD BHA & test same. PJSM prior to pressure deploying. Set back lubricator & pick up injector & test lines - ok. Pressure deploy BHA. Test MWD tools. Problems with BHi computers & possible tool problems. Pri~ted: 8/6/2007 2:44:30 PM ~ ~ ' BP AMERICA ' Page 5 of 26 Opera#ions Summary Report Legal Welt 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 ~perations 7/4/2007 I00:00 - 01:00 1.00 DRILL N DFAL PROD1 Work on computer system. BHA tool tested ok. MU injector & 01:00 - 02:35 1.58 DRILL N DFAL PROD1 02:35 - 03:35 I 1.00 DRILL N DFAL PROD1 03:35 - 05:30 I 1.921 DRILL I N I DFAL I PROD1 05:30 - 07:00 ' 1.50 DRILL N DFAL PROD1 I 07:00 - 10:00 3.00 DRILL N DFAL PROD1 10:00 - 10:15 ~I 0.25 DRILL I N DFAL PROD1 10:15 - 12:10 ~I 1.92 DRILL N I DFAL , PROD1 12:10 - 13:50 1.67 DRILL N DFAL I PROD1 13:50 - 14:10 0.33 DRILL N DFAL ~ PROD1 14:10 - 14:35 I 0.42 DRILL N DFAL PROD1 14:35 - 15:50 ~'i 1.25 DRILL ~, P I PROD1 15:50 - 16:10 '~, 0.33 ( DRILL ~ P I ~ PROD1 16:10 - 18:00 i I 1.83 DRILL ~ I P II I ~~ PROD1 ~ I~ 18:00 - 19:10 1.17 DRILL P PROD1 19:10 - 22:20 3.17 DRILL P PROD1 22:20 - 23:35 I 1.25 DRILL P PROD1 23:35 - 00:00 ~ 0.42 DRILL P PROD1 j 7/5/2007 ~ 00:00 - 01:00 I 1.00 ~ DRILL I P I I PR001 01:00 - 04:00 3.00 DRILL P PROD1 04:00 - 06:00 2.00 DRILL P PROD1 06:00 - 08:00 2.00 DRILL P PROD1 08:00 - 10:20 I 2.331 DRILL I P I I PROD1 stab onto well. BHI is fixing computer problems. Close EDC. Circulate at min rate & RIH using MPD techique. Park coil @ 9200ft, circ at min rate holding 300 psi WHP. BHf is re-imaging the computers - apparent communication with tool problem. Bleed IAP from 450psi to 125psi to Tiger Tank (gas and fluid) Re-imaging of computers was no help. POH to re-program BHA tools per BHI 'experts'. Test previous too! string on cat walk that had downhole failure. PJSM while POH for pressure undeploying. Pressure undeploy BHA w/ 420 psi LD BHA. Reprogram and test tools Safety mtg re: pressure deploy Pressure deploy w/ 420 psi RIH circ thru bit 0.5/1800 following pressure schedule Log tie-in down from 9300', corr -13' W iper to TD was clean PVT 284 Drill 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' Start losing 0.5 bpm at 10090'. Drilled to 10093' and became stuck. Pulled free after a few cycles at 20k over. 100' wiper PVT 280 Resurne 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' W iper to 9300ft - clean. ~iper to TD - clean. 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 W iper to 9300ft - clean. W iper to TD - clean. Drilling lateral. TF at HS Qp = 2.3 / 2.24 bpm CTP 2930 psi off bottom 2840 psi fs BHP = 3511 psi w/ ECD at 10.54 pppg DHWOB = 0.8 - 22 klb ROP = 40-70 fph Vp = 222 bbl's Continue drilling lateral. TF at HS Qp = 2.3 / 2.24 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 bb!'s 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. Begin pressure undeploying BHA. LD drilling BHA. Adjust motor bend to 1.8 deg, bit is okay. MU BHA Pressure deploy w/ 366 psi Printed: 8/6/2007 2:4430 PM ~ ~ ' BP AMERICA Page 6 of 26 Operations Summary Report 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 Description of Operations 7/5/2007 i 10:20 - 12:15 ~ 1.92 DRILL P PROD1 RIH circ thru EDC 0.5/1600 following pressure schedule ! 12:15 - 12:50 I 0.58 ~RILL P PROD1 Log tie-in down from 9200', corr -14'. Close EDC ~' 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 Drili from 10401' 2.47/2.25/3160/10R w/ 100-200 psi diff, I I 1.5-4.Ok wob, w/ open choke and 3510 psi dhp or 10.59 ECD. I ', Drill from 10418' in what acts like siderite-stacking near full '~ ' surface wt w/ 32k wob and avg 10-15'/hr to 10424' and got i temporarily detained ~ 14:30 - 14:45 025 i DRILL P PROD1 BHA wiper ! 14:45 - 16:30 1 J5 ~ DRILL P PROD1 Drill from 10424' 2.43/2.28/3100/10R w/ 100-200 psi diff, I 2.0-3.5k wob w/ open choke and 3495 psi dhp or 10.5 ECD and showing slow build. NBI at 10407' is 93 deg. Drill to 10446' ; and NBI at 10428' is 102 deg ' 16:30 - 19:40 i 3.17', DRILL P PROD1 Drill from 10446' at very slow penetration rate while stacking ' ! i ' fuil wt to get 2.Sk wob due to DLS in this hard spot. Perform I i ~ 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 l 1.67', DRILL P PROD1 Drilling lateral. TF at 90 R i I ', ~ Qp = 2.43 / 224 bpm CTP 2914 psi off bottom I ! 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'~ DRI~L P PROD1 TD spot has been picked. Wiper to window - clean. Log for , ~ ', tie-in (+4ft corr). W iper to TD - ciean. Begin pumping 10.46 ~ I Ib/bbl KWF @ 9800ft. 23:30 - 00:00 0.50 ~ DRILL P PROD1 Ta ed bottom @ 10,532ft. La in KW F while POH. 7/6/2007 ; 00:00 - 02:20 2.33 DRILL P PROD1 Continue POH while laying in KWF. Paint EOP flag @ 9050ft. ~ 02:20 - 02:30 0.17; DRILL P PROD1 PJSM prior to LD BHA. Fiow check well - ok. i 02:30 - 03:30 1.00 j DRILL P PROD1 Pop oft well. Break off ccy~,from BHA. Set coil over bung hole ~~ via legs. Blow down BHA with water & air. UD BHA in 3 I03 30 - 03 45 25 CASE 0 P RUNPRD sections. PJSM i t MU li : : . ner. pr or o I, 03:45 - 04:25 0.67 CASE P RUNPRD Hole is in static condition - mud @ swab valve. Hook up Farr Tongs & PU Baker TT knack box via beaver slide. MU TIW valve & 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. ~ 05:45 - 09:40 3.92 CASE P RUNPRD Fill liner after first 14 jts have been run. ~ I Finish run 46 jts 3-3/16" 6.2# ~-80 TC11 liner w/ 3-1/2 X nipple , and BTT deployment sub '~ MU BTT GS running tool ' MU BHI MWD assy ; 09:40 - 11:10 1.50 CASE P RUNPRD RIH w/ liner circ 0.4/1100 and had 1/2 returns to 5000'. After ~ 5000' had no returns so RIH 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, clean. See 1 k j wt loss at window from each cementralizer. See wt loss w/ i shoe at 10086' (fault). Then had several set downs when first i cementralizer got to fault. Broach out fault area with first three 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 ~ ~ ' BP AMERICA ' 'Page 7 of 26 Operations Summary Report Legaf 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 7/6/2007 11:10 - 12:10 j 1.00 ~ CASE P RUNPRD past 10465', then set down solid at 10495' 12:10 - 13:10 j 1.00 I CASE P RUNPRD Work to get by 10495' CTD w/o success-setting down solid. ~ Can pull up hole 100' clean at 35k. See cementralizer catch at ' ,,,~_ ^ '~ 10465' each time going down and getting cleaner each pass. ~ 1 t'~Cc ~ h~~! v`~~~ ~ ! ~O ~ ~~ ~ Circ to freshen up beads occasionaliy w/o returns. After 20-25 tries, no progress was made. Est BOL at 10480', TOL at 9060' 13:10 - 15:00 1.83 ~ C SE P RUNPRD Release GS from liner at 1.5 bpm. Swap to filling hole from the ~ I BS. POOH w/ liner setting tool PVT 56 15:00 - 15:40 ! 0.67j CASE P RUNPRD Flowcheck. LD liner running tools. LD MWD assy. SI swab. ~ I ~ I Install nozzle assy 15:40 - 16:30 I~ CASE 0.83 N RUNPRD Displace CT w/ 10 bbls FW. WO bleach, N2 i 16:30 - 17:10 I 0.671, CEMT P RUNPRD MIRU SWS N2. Safety mtg. MIRU bleach pup truck 17:10 - 19:20 2.17'i CEMT P RUNPRD Pickle CT w/ 15 bbls bleach, 60 bbls water, 15 bbls corrosion I ' inhibited water, 10 bbls diesel. Displace diesel w/ N2 and I~ ' ~ blowdown to tiger tank. Let coil bleed off. 19:20 - 20:45 I 1.42 j CEMT P RUNPRD Pop off from well. Break down BHA. Remove grud screws & i pull connector off of end of coil. Cut off coil. Prep end of e-line ~ ', I cable for storage. Swab cable in winch for stabbing cable. Prep , '~ end off coil for internal grapple 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 j CEMT ~ P ~ RUNPRD Unstab coil from injector & pull coil across to reel house. ' ~ ~ Secure coil on reel via shipping bar. Remove grapple & ' stabbing cable 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 j 1 JSI~ CEMT I 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~ess coil into reel house. 00:30 - 02:25 1.92 CEMT P RUNPRD Remove & string back lifting cables. Dress end of coil & instali grapple connector. Puil test grapple connector. Remove shipping bar from reel. Stab coii 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 FtUNPRD 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 coil & 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/ SW 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 wl SW 1.52/1.3/1120 wl open choke w/ initial returns at steady 9.7#. Return densiry started decreasing so incr whp to match in/out rate and after 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 @ Pnnted: 8/6/2007 2:44:30 PM ~ ~ BP AMERICA `` Page 8 of 26 Operations'Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORD{C CALISTA ,Rig Name: NORDIC 2 I Date Frorn - To Hours Task Code NPT 7/7/2007 07:45 - 08:40 0.92 CEMT , P 08:40 - 08:55 0.25I CEMT I P 08:55 - 09:30 0.58, CEMT ~' P ~ ~ 09:30 - 11:00 1.50; CEMT i P ! i ~I ' I ~ ~ ~ 11:00 - 12:30 i 1.50I CEMT : P ' 12:30 - 12:45 I 0.25 i CEMT ': P 12:45 - 13:15 ~ 0.501 CEMT ' P 13:15 - 14:30 i 1.25 ~ RIGD I' P 14:30 - 16:30 i 2.00 I RIGD ~ P 16:30 - 17:30 ~ 1.00 ~ RIGD ~ P 17:30 - 19:30 I 2.001 MOB ! P 19:30 - 00:00 4.50 BOPSUp P 7/8/2007 00:00 - 01:35 1.58, BOPSUF~ P 01:35 - 03:00 I 1.421 MOB I P 03:00 - 03:10 0.17 MOB I P 03:10 - 03:57 0.78 MOB ~ P 03:57 - 05:00 1.05 MOB P , 05:00 - 05:30 0.50 MOB I P 05:30 - 05:45 0.25 MOB ~, P 05:45 - 07:00 1.25 MOB I P 07:00 - 09:00 2.00 DRILL ~ P 09:00 - 10:00 1.00 BOPSU P Spud Date: 6/27/2007 Start: ~ 6/27/2007 End: 7/26/2007 Rig Release: 7/26/2007 Rig Number: Phase Description of Operations RUNPRD 9073.2'. PUH to 26k to prove were latched. Set back down, Sq pump and wait for ball to fall RUNPRD Safety mtg re: cementing RUNPRD Resume circ at 0.5/750 holding 400 psi whp and ball went on seat. Pressure up to 3490 psi and ball seat sheared. SD pump. PUH 2O.8k to verify released. Finish displace liner and 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 38 bbls pumped. SD pump and trap 500 psi 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 and launch (not so easy when there is well pressure). Check that dart is gone. Rig displace w/ SW 1.52f1.45(1430 w( 340 psi whp. Got some crude back from bottoms up. See dart latch up at 61.3 bbis. 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 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. Bieed off whp RUNPRD Safety mtg re: LD BHA, welding in reelhouse, N2 blowdown RUNPRD LD BHA Weld heater core in reelhouse Stab back on w/ jet nozzle RUNPRD Displace CT w/ 10 bbls diesel followed by N2 and jet stack while taking returns to tiger tank. Bleed down RUNPRD Cut off CTC. Install internal grapple and pull CT back to reel RUNPRD SWS secure reel and R~,hardline. Load out 2-3/8" E-free CT onto VECO lowboy Nordic convert BOPE for 2" CT and tools PROD2 Remove gooseneck from injector and set injector off to side tor conversion. RU hardline & bulk head & junction box inside of reel. Clean out high pressure filter on hardline. PROD2 Start BOPE test. PROD2 Complete BOPE test. The AOGCC waived their right to witness the BOPE test PROD2 Pick up injector & stab onto stuffing box. Prep end of coil for internal grapple. Hook up grapple cable to winch & install internal grapple inside coil. PROD2 PJSM prior to stabbing pipe. PROD2 Pull coil across & stab pipe into injector. Put coil in levelwind. Adjust gooseneck. PROD2 Swap out cable for winching. Move injector over bung hole & fill coil with SW. PROD2 Prep end of e-line cable. Pick up lubricator & stab onto well. PROD2 Conduct slack management. PROD2 Pop off & check for wire at end of coil. Cut off 66' of CT and dispose. Install CTC. PT @ 35k PROD2 Install and test BHI UQC. PT 3500 psi PROD2 Pump CT vol of slack forvvard stabbed onto well 2.58l4000. PT packoff and inner reel valve as part of BOPE test @ 300/3500 Printed: 8/6/2007 2:44:30 PM ~ ~ BP AMER'lCA Page 9 of 26 Operations :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 Description of Qperations 7/8/2007 09:00 - 10:00 1.00 BOPSUR P ~ PROD2 ~ psi. Check well pressure at 320 psi 10:00 - 10:30 0.50 DRILL I P I , PROD2 Bring BTT tools to floor. MU mill and SR to motor 10:30 - 10:45 0.25 DRILL I P ~ ~ PROD2 Safety mtg re: deploy w/ 320 psi 10:45 - 11:50 1.08 DR~LL ~ P ~ PROD2 Pressure deploy milling assy 11:50 - i2:15 0.42 DRILL i P ~ PROD2 Nordic crew change I ~ ~ i Safety mtg re: deploy w/ 320 psi w/ fresh crew 12:15 - 13:20 1.08 i DRILL ~ P ; PROD2 Finish pressure deploy BHA 13;20 - 15:05 1.75 DRILL ~ P ~ 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 j DRILL i P ! PROD2 RIH thru TOL w/ no wt loss. Log tie-in down from 9200' i ; I ~ , 0.42/660 while holding 400 psi whp. Still taking crude returns ' ! I 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 ~ ~ crude returns to tiger tank. Set down at 10373' 16:15 - 16:35 0.33; DRILL ; P I PROD2 Start pump 1.7/3330 and ease in hole w/ a little MW and drill i i i ; minor cement at 150-350'/hr w/ 250 psi whp or 9.8 ECD. j j ~ Reduce rate to 1.50/2700 due to vibration i 16:35 - 19:45 3.17! DRILL j P ~ I PROD2 Tag PBD at 10444.9'. Drili LWP 1.5/2680 w/ 250 psi whp. I ' i Have one 8k overpull, then start having stalis and MW at I ! ' ~ 10443.6'. ~ , ' Note: Tagged depth is within a foot of estimated drilters depth ~ ~I ; i for liner placement. Confirms TOL @ 9060' and BOL @ 10480' ( ', ~ i Stili taking crude returns to tiger tank. After getting somewhat i ', 'i i i clean returns (0.1 bpm extra), iYs obvious that 250 psi whp or 9.8 ECD is too low with a low viscosity fiuid. Increase whp to ~ , i % i 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 b cement . . . 19:45 - 20:15 0.50 j DRILL P PROD2 Wiper trip to 10,200ft - clean. RIH & surge liner - ciean. 20:15 - 21:00 0.75 ~ DRILL P PROD2 Drill LWP 1.74/3171 w/4Q,p 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 DR1LL 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 @ lay in from TD. 06:15 - 06:30 0.25 DRILL 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 Operations 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: i Date From - To Hours Task Code NPT Phase ~ Description of Operations -- !- --- - ~ 7/9/2007 14:15 - 14:25 0.17 DRILL P PROD2 ! 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 I 2251 DRILL I P 16:45 - 17:45 I 1.00' DRILL P 17:45 - 18:30 i 0.75I DRILL P 18:30 - 21:10 I 2.671 DRILL I P 21:10 - 21:30 0.33 DRILL I P 21:30 - 21:50 0.33 DRILL ~ P 21:50 - 00:00 2.17 ~', DRILL i P ~7/10/2007 I00:00 - 01:30 i 1.50I DRILL ' P 01:30 - 03:05 I 1.58I DRILL I P 03:05 - 03:30 I i ' 0.42 j DRILL I I P 03:30 - 03:35 i 0.08 i DRILL P 03:35 - 04:15 0.67 DRILL P 04:15 - 06:00 1.75 DRILL P 06:00 - 09:40 I 3.671 DRILL I P 09:40 - 10:45 I 1.081 DRILL I P 10:45 - 11:40 I 0.921 DRILL I P 11:40 - 13:00 I 1.331 DRI~L I P 13:00 - 14:45 1.75I DRILL P 14:45 - 16:20 1.58, DRILL P 298 PROD2 ~: 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. Drill at ~ 102 deg to 10690' PVT 305 PROD2 I Wiper to 9000' was clean PROD2 ' RBIH at 0.5/1475 following pressure schedule @ 50'/min - i clean. PROD2 I Drill from 10690' 1.61/3210/90R w/ 100-200 psi diff, 0.75-1.2k I wob w/ 175 psi whp induced to give 3500 psi or 10.5 ECD. ~~ 10-60 ft per hr ROP. PVT 306 PROD2 ~ W iper to 10480' was clean. PROD2 ', W iper to bottom - clean. PROD2 I Drill from 10830' 1.61/3210/90L (Begin steering to left) w/ I 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 304 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 PROD2 I Wiper to 8000' - clean. PROD2 ~ RBIH at 0.5/1475 following pressure schedule @ 50'/min. I Cannot maintain pressure schedule - annular pressure keeps I climbing, suspect cuttings in annulus however returns are ' clean.... ', Stop @ 9000ft & open EDC & increase pump rate to 1.9 i, bbl/min. PROD2 I Log for tie-in @ 9280ft. (+1ft corr). Lots of cuttings & rubber ~ coming across the shaker - suspect rubber from liner wiper plug. ,,, PROD2 Wiper to bottom - clean. PROD2 Drill 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 PROD2 Drill 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 . . . PROD2 W i r from 11028' to clean up welibore 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 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 PROD2 Finish POOH circ thru EDC 1.94/2990 from 7200' DPS is working intermittently PROD2 Pressure undeploy w/ 350 psi PROD2 MU & test BHI tools on catwalk - ok. printed: 8/6/2007 2:44:30 PM ~ ~ BP AMERICA Page i1 of 26'' Operations 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 7/10/2007 I 7/11 /2007 From - To ~ Hours ~ Task ~ Code ~ NPT ~ Phase 16:20 - 16:35 0.25 DRILL P PROD2 16:35 - 17:55 1.33 DRILL P PROD2 17:55 - 18:50 0.92 DRILL P PROD2 18:50 - 20:30 1.67 DRILL P PROD2 20:30 - 20:45 0.25I DRILL P 20:45 - 21:56 1.181 DRILL P 21:56 - 00:00 I 2.071 DRILL I P I i00:00 - 00:45 0.75I DRILL P %00:45 - 03:10 ~ 2.42 ~I DRILL P 03:10 - 04:22 I 1.201 DRILL I P 04:22 - 06:00 I 1.631 DRILL I P 06:00 - 12:25 I 6.421 DRILL I P 12:25 - 13:20 I 0.921 DRIIL I P 13:20 - 14:40 I 1.331 DRILL I P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 Description of Operations PSJM prior to pressure deploying. Begin pressure deploying BHA. Stab injector onto well head. Set depths. RIH with OHST BHA. Town has extended TD of the well to 11,500 ft Recieved new targeys from Geologist Log tie in at 9,280 ft Corrected -18 ft RIH to break off the lamp shade. Tagged at 11,020 ft and broke off lamp shade. PUh! fo 10856 ft 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 bbl's BHP = 3447 psi = 10.47 ppg ECD OHST Trough 10,856 ft to 10,886 ft Time milling at O.ift / 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 Coiled tubing stacking in welibore. Bit jumped the sidetrack lip. RIH To 10,889 ft and just stack CT weight. Back ream from 10,888 ft to 10,856 ft an~ry to re-establish the lips. RIH at 60 fph with TF at 150 R to establish lip. 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) Started taking WOB at 10,884.8 ft. Stopped at 10,886.ft and use just WOB to sidetrack. Lost motor work at 10,886.75 ft. PUH and restart Starting @ 10886.9ft, PU & get coil WT to break over. Time drill 0.1 ft deeper than previous depth in an attempt to prevent coil WT from stacking out 1 ft/hr for the 1 st foot. At 10,888.1 ft appears to be taking WOB (200#), allow to drill off & time drill Q 2ft/hr starting at 10,888.1 ft, however continue to PU & get WT back it that time frame. At 10,889ft start time drilling @ 3fUhr. Near-bit inciination 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 10fUhr from 10,893ft to 10,894ft. Increase ROP to 15ft/hr from 10,894ft. Seems to be stacking out, PBU & RIH. Getting 750# WOB @ 10fUhr with near bit INC dropping, continue to drill ahead. Printed: 8/6/2007 2:44:30 PM ~ ~ ~ BP AMERICA Page 12 of 26 I, Operafions 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 7/11/2007 14:40 - 15:00 j 0.331 DRILL I P PROD2 Can't make any more hole, stacking weight @ surface & have 15:00 - 15:20 i 0.331 DRILL I P 15:20 - 15:30 ! 0.17 i, DRILL j P 15:30 - 15:50 i 0.33 DRILL P 15:50 - 17:30 1.67, DRILL ~ P 17:30 - 17:48 , 0.301I DRILL i P 17:48 - 18:45 ' 0.951 DRILL P 18:45-23:10 '', 4.42i DRILL j P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 23:10 - 00:00 ' 0.83I DRILL I P I ~ PROD2 7/12/2007 00:00 - 01:12 ' 1.201 ~ DRILL P I PROD2 1 01:12 - 01:30 j 0.30; DRILL P ; PROD2 j 01:30 - 03:07 ~ 1.62' DRILL ~ P ~ PROD2 03:07 - 03:30 i I ', 0.38 1 DRILL ~ P 'I PROD2 i ' 03:30 - 04:00 I i 0.50 DRILL P PROD2 04:00 - 05:45 1.75 DRI~L P PROD2 05:45 - 07:00 1.25 DRILL P PROD2 07:00 - 08:10 1.17 DRILL P PROD2 08:10 - 10:45 ~ 2.58 ~ DRILL ~ P ~ ~ PROD2 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. Back ream from 10,901ft to 10,875ft with 330TF. RBIH & ream with 150TL to bottom. RIH to 10,901.5ft & seeing motor work now. Attempt to driil ahead. Drill to 10,902.6ft, stack weight & not drilling. Back ream from 10,902.6ft to 10,875ft with 90TF. Set down @ 10,900ft now. POH for lateral BHA following pressure schedule. Open EDC & POH. 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. Problem is down hole. Continue to POH. Closed tool at 1350 ft. BHI MU new tool string OOH, Held PJASM and Pressure undeploy BHA with 400 psi SIWHP Installed 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 RIH as per Pressure Schedule RIH to 9280 ft Tie-in at 9300 ft Corrected -18 ft. RIH to 10,350 ft. Closed EDC and Orient TF to HS Set down at 10,848 ft and then fell through. RIF4 at Qp = 1.51 bpm Tagged at 10,901 ft Drill laterai from 10,901 ft to 10,930 ft Hole angie 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 Back reamed OHST area at 150R TF to 10,845 ft Drill lateral from 10,930 ft to Turned TF to 90L from 90R at 10,930 ft Turned TF up to 45L to try and build Qp = 1.51 / 1.54 bpm CTP at 3,340 psi free spin PVT = 298 bbl, Density = 8.7 / 8.72 ppg BHP = 3418 psi = 10.4 ppg ECD WHP = 170 psi DHWOB = 0.5-1.0 klb ROP = 30-60 fph PU at 10,998 ft to check survey. hole angle @ 85.89 deg. Turned TF to 10L Wiper to BOL @ 10,480ft - clean. RBIH to bottom. 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 ECD's are 10.7, ~osses are 20bbis for 3 hrs. Wiper to 8,OOOft following pressure schedule. Printed: S/6/2007 2:4430 PM ~ • BP AMERiCA Page 13 of 26' Operations Summary Report Legal Well Name: 1 B-08A Common Well Name: 1 B-08A Spud Date: 6/27/2007 Event Name: REENTER+CO MPLETE 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 7/12/2007 10:45 - 10:50 -- 0.08; DRILL --; i P i I PROD2 - Log for tie in (Oft). 10:50 - 11:40 0.83 i DRILL ; P i PROD2 W iper to bottom. 11:40 - 12:25 OJS; DRILL !I P i 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 I ~i PVT = 231 bbl, Density = 8.72 / 8.65 ppg I BHP = 3499 psi = 10.67 ppg ECD WHP = 176 psi I I I DHWOB = 0.5-2.0 klb ROP = 40-75 fph 1225 - 12:35 0.17I DRI~L N i 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 0.831 DRILL ~, P ~~ PROD2 Drill lateral from 11,155 with TF of 60L to 90L ' !i Qp = 1.63/ 1.66 bpm CTP at 3,565 psi free spin i ', I PVT = 231 bbl, Density = 8.67 / 8.67 ppg ~ ' '~ BHP = 3477 psi = 10.57 ppg ECD W HP = 176 psi , I DHWOB = 0.5-2.0 klb 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: I a fault. Puli up 100ft. 13:50 - 14:40 0.83: DRILL ', P I PROD2 Set down @ 11,179ft & motor work. i Drill lateral from 11,179 with TF of 120L ' i Qp = 1.64 / 1.67 bpm CTP at 3,565 psi free spin , , ~ PVT = 0 bbl, Density = 8.68 / 8.69 pp9 ' ', BHP = 3455 psi = 10.51 ppg ECD WHP = 200 psi ~ I i DHWOB = 0.5-2.0 klb ROP = 40-75 fph ' i ; New mud @ surface. Continually increase WHP to maintain ', ! 1:1 retums. WHP @ 220psi & ECD 10.55. 14:40 - 14:55 0.25'', DRILL i N I DFAL PROD2 Trouble shoot resistivity tool while POH @ 85fVhr. 14:55 - 16:05 1.17'~ DRILL P I PROD2 Drill lateral from 11,211 with TF of 85L ', I ~ Qp = 1.61 / 1.61 bpm CT,e at 3,565 psi free spin ~~I I I PVT = 78 bbl, Density = 8.69 / 8.70 ppg ~ BHP = 3473 psi = 10.57 ppg ECD WHP = 215 psi I DHWOB = 1.5-2.0 klb ROP = 40-60 fph i I~ Can no longer keep drilling at 75ft/hr. Loosing motor work & ~ i I WOB. Acts like drilling break every time. 16:05 - 18:00 1.92 ~ DRILL 'I P PROD2 Wiper to window - clean. Wiper to bottom. 18:00 - 20:25 2.42' DRILL i, N DFAL PROD2 BHI tool problems. POH held PJSM and discussed the hazards 20:25 - 23:05 2.67 DRILL i N I DFAL PROD2 Pressure Undeploy BHA, Bit good, changed out BHI's MWD 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 DRILL ~ N DFAL PROD2 RIH following pressure schedule 7/13/2007 00:00 - 00:45 0.75 DRILL ~ N DFAI PROD2 RIH 00:45 - 01:02 0.28 DRILL ~I N DFAL PROD2 Tie-in at 9300 ft. to RA marker in whipstock. Corrected -18 ft I TF at HS 01:02 - 02:00 0.97 DRILL ~ N DFAL PROD2 RIH to 10,350 ft and close EDC. orient TF to HS and RIH to I ~ 10,850 ft.Tagged bottom at 11,270 ft. Clean trip in the open ! ' hole 02:00 - 02:55 0.92 DRILL i 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 kib Controiling ROP to a max of 100 fph. Printed: 8/6/2007 2:44:30 PM n LJ BP AMERICA Page 14 of 26 Operations 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 i NPT Phase Description of Operations ------ --- ------- - ---- -- 7/13/2007 02:00 - 02:55 0.92I DRILL P ' i PROD2 Drilling with no WOB. But every once in a while the bit finds ' ', ' 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 Pulled tight. PU to 55k and worked free going down with low ~ I !, ~ Qp. PUH and conducted 100 ft wiper trip ~ ' ; Qp = 1.56 bpm. RIH and the hole is ratty from 11,280 ft to i I ' 11,307 ft 1,03:05 - 03:40 0.58 DRILL j P ' I PROD2 li Driil lateral in putty from 11307 ft to 11,335 ft ~ I I I Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin i I j PVT = 214 bbl, Density = 8.7 / 8.72 ppg , j BHP = 3450 psi = 10.5 ppg ECD WHP = 200 psi I I ' ~ DHWOB = 0- 1.0 klb Controlling ROP to a max of 100 fph in ~'i I ~ i this soft formation I il , , ~ PU at 11, 325 ft, clean. PU 11332 ft, some what clean, Small j 100 ft wiper The hole is acting like its getting unstable. ~~ 03:40 - 03:50 0.17 j DRILL P I PROD2 i Drill lateral from 11,335 ft to 11,355 ft , I i ~ , ; Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin ' ~i i PVT = 214 bbl, Density = 8.7 / 8.72 ppg ; ~~i j BHP = 3475 psi = 10.6 ppg ECD WHP = 200 psi ! i I i DHWOB = 0- 1 A klb Controlling ROP to a max of 100 fph in i , ; this soft formation ) I ~ Formation getting more compenent at 11,335 ft 03:50 - 05:10 1.33 DRILL ' P I '; PROD2 ~ W iper trip to 10,500 ft and try to ciean up around BHA. 05:10 - 05:45 0.58 DRILL P ', PROD2 ~ Drill lateral from 11,355 ft to 11,388 ft ', ' ~ Qp = 1.47 / 1.47 bpm CTP at 3,153 psi free spin I ', i PVT = 228 bbl, Density = 8.7 / 8.72 ppg i I , , ; BHP = 3480psi = 10.6 ppg ECD WHP = 212 psi ~ 'I DHWOB = 0- 1.0 klb Controlling ROP to a max of 100 fph in I ' this soft formation. 05:45 - 06:15 0.50 DRILL P 'I PROD2 Wiper trip to 10,500 ft an~,i try to clean up around BHA. 06:15 - 06:35 0.33 DRILL P j I 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 I BHP = 3492psi = 10.63 ppg ECD WHP = 212 psi DHWOB = 0- 0.5 kib 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 PROD2 Drill lateral from 11,415 ft to 11,420 ft , Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin I PVT = 198 bbl, Density = 8.68 / 8.50 ppg ~, j BHP = 3492psi = 10.63 ppg ECD WHP = 212 psi I ~ ~ ~ DHWOB = 0- 0.5 kib Controlling 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 @ 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 PVT = 198 bbl, Density = 8.70 / 8.44 ppg I BHP = 3493psi = 10.63 ppg ECD WHP = 212 psi Printed: 8/6/2007 2:44:30 PM ~ • BP AMERiCA Page 15 of 26 Operations 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 - ----- ,-- 7/13/2007 ', 08:25 - 08:40 0.25 DRILL ~ P I PROD2 --- DHWOB = 0- 1.0 klb Controlling ROP to a max of 100 fph in I ~ this soft formation. ', 08:40 - 08:50 0.17 DRILL P ~ PROD2 PU 40ft - clean off bottom. I08:50 - 08:55 0.08 DRILL P ~ i PROD2 Drill lateral from 11,440 ft to 11,455 ft I ~ Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin , I ~ ~ PVT = 197 bbl, Density = 8.70 / 8.44 ppg ~ I I BHP = 3499psi = 10.65 ppg ECD WHP = 212 psi ; ~ DHWOB = 0-.65 klb Controlling ROP to a max of 100 fph in ! i I this soft formation. i 08:55 - 09:10 0.25 DRILL P ~ PROD2 PU 100ft wiper. 5k overpull off bottom, otherwise clean. RBIH ~~ to bottom - clean. ~ 09:10 - 09:20 0.17 DRILL P ~ PROD2 ~ Drill lateral from 11,455 ft to 11,470 ft j i li ~ Qp = 1.51 / 1.52 bpm CTP at 3,153 psi free spin i i~ I PVT = 195 bbl, Density = 8.7018.44 ppg i i BHP = 3499psi = 10.66 ppg ECD WHP = 220 psi ', i I I ~ DHWOB = 0- 1.15 kib Controlling ROP to a max of 100 fph in , I ~ this soft formation. ' 09:20 - 09:30 ~ 0.17 DRILL ~I P PROD2 ~I! PU for 70ft wiper - 2k over puli off bottom, otherwise ciean. 09:30 - 09:55 ! 0.42 ~ DRILL j P ', PROD2 I Driii lateral from 11,470 ft to 11,498 ft ~ ~ ~ I ; Qp = 1.51 / 1.52 bpm CTP at 3,253 psi free spin ~ i PVT = 195 bbl, Density = 8.70 / 8.44 ppg ~ ', i BHP = 3505psi = 10.68 ppg ECD WHP = 220 psi ~i j DHWOB = 0-.65 klb Controlling ROP to a max of 100 fph in i this soft formation. 109:55 - 10:00 0.08 DRILL i P ~ PROD2 ~ PU for 30ft wiper - 10k over pull off bottom. I 10:00 - 10:05 0.08 DRILL ~ ~ ~ P i, ~ PROD2 i Drill lateral from 11,498 ft to 11,500 ft ' i Qp = 1.51 / 1.52 bpm CTP at 3,253 psi free spin j ~ ! i PVT = 193 bbl, Density = 8.70 / 8.39 ppg ! i ~, ~ BHP = 3505psi = 10.68 ppg ECD WHP = 220 psi ' DHWOB = 0-.65 klb Gpntroiling ROP to a max of 100 fph in ~! this soft formation. I 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 KWF & beads & store into pits 3,4,5. Slight motor work I (200psi) while POH Q 11,333ft to 11,322ft. Slight motor work ' (200psi) while POH Q 11,272ft to 11,260ft. j 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 Q 10fUmin in OH section. 20k = coil wt off ~, ~ bottom. 11,350ft seeing (motor work for -5ft) & 3000 Ibs ; overpuli (23k = coil wt)- the entire length upto 11,265ft. Now I 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 W iper 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 i @ 10,479' ~ 15:20 - 16:00 0.67 DRILL 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 KWF. Adjust WHP to obtain returns for 1:1. I Held PJSM on handling BHA conventionally Prinled: 8/6/2007 2:4430 PM • • BP AMERICA Page 16 of 26' Operations 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 I Phase Description of Operations 7/13/2007 , 20:00 - 21:00 1.00 DRILL ~ P i 21:00 - 21:30 0.50 CASE P i 21:30 - 00:00 ~ 2.50 CASE ~ P ~ I 7/14/2007 I 00:00 - 0130 ~ 1.50 CASE P 01:30 - 02:15 i OJ51 CASE I P '~ 02:15 - 0230 I i 0.25I I CASE P ~ 02:30 - 02:40 ~I 0.17 ~ CASE ~II P ; 02:40 - 04:35 I 1.92 N CASE I P i 04:35 - 05:15 I 0.67 i CASE I P 05:15 - 07:00 ; 1.75I WHIP I~ P 07:00 - 07:35 ! , 0.58 WHIP '~ P 07:35-09:30; 1.92~ WHIP '; P 09:30-11:30 i ~ j 2.OO~ , WHIP ~ ! P i 11:30 - 13:30 I 2.00 ~ WHIP ~ P 13:30 - 13:50 I ~ 0.33 WHIP ; P 13:50-14:15 0.42 WHIP i P 14:15- 14:35 0.33 WHIP ~ P 14:35 - 14:40 0.08 WHIP I P 14:40-16:401 2.OOIWHIP IP 16:40 - 17:45 I 1.081 WHIP I P 13-d~ ~ ~ ~ G i _ `\~ \ '~- 17:45-18:251 0.671WHIP IP 18:25 - 20:10 1.75 WHIP P 20:10 - 20:24 023 WHIP P 20:24 - 21:09 0.75 WHIP P 21:09 - 00:00 2.85 STWHIP P ~ ~, ~.~.- p~~ PROD2 LD BHA RUNPRD RU to run liner RUNPRD Run 2-3/8" Slotted Liner as per programme PU BHI CoilTrac BHA Floor Valve drill while running liner (good) RUNPRD RIH with liner and coiltrac Corrected to 8100 EOP flag. -17 correction RUNPRD RIH from 9167 ft. Wt check at 10,400 ft= 23.6 k, RIH and tagged 11,497 ft PU wt = 28 k 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 RUNPRD PUH logging w/ CCL to confirm top of 2-3/8" liner RUNPRD POOH with CTLRT's. Held PJSM on BHA handling. RUNPRD Checked flow, LD CTLRT and Coiltrac BHA PU 2.70 / 2.63 WS drift tool 14.23 ft long WEXIT RIH with drift run while pumping max rate to clean up weil bore. WEXIT Log for tie-in. (-12ft corr). Continue RIH to bottom. WEXIT POH. PJSM while POH regarding BHA handling. ~ W EXIT Tag up. Flow check well. Pop off well. Break off BHA & blow down. Set BHA on cat walk & add HOT & reprogram toois. Perform week~y BOP function test per AOGCC regs. Fili across the top to keep hoie fuil. PU whipstock & BHI toois. Stab injector onto tools. Set depths. WEXIT RIH with whipstock. -50% losses while RIH. WEXIT Log for tie-in. (-13ft corr). WEXIT Resume RIH. W EXIT Log CCL to confirm placement of collars. W EXIT Pressure up to 3400psi. Set top of whipstock @ 10,337ft with 30 degree right of high s~de. Set 2,000 Ibs down on whipstock. WEXIT POH with whipstock setting tool. Fill across the top. PJSM while POH regarding handling BHA's. W EXIT Tag up. Flow check well. Pop off well. Break off BHA & biow down. Set BHA on cat walk & remove HOT & recheck tools. Fill across the top to keep hole full. 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. WEXIT RIH with window exit BHA WEXIT RU to tie -in Switch pumping to down the coiled tubing Corrected -17 ft WEXIT RIH. Mud pumps pressure cycling causing erriatic pressure cycles . Unable to milll 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 nnnnng winaow as per tsv t svr~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 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 ~ • BP AMER'ICA ' Page 17 of 26 Operations 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 Description of Operations 7/15/2007 00:00 - 02:10 i, 2.17'~ STWHIP P WEXIT Milling window as per BOT SOP's '~, ! Qp = 1.44 / 1.40 bpm I '~, i Density = 9.5 / 9.4 ppg I ~ PVT = 411 bbls, ~ossing 2.6 bph 02:10 - 03:15 I 1.08I 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 = 401 bbls, Lossing 2.6 bph i 03:15 - 04:13 I 0.97 ~ STWHIP~ ~ P WEXIT Drillin g ratehole from 10,344.90 ft to 10,355 ft ; , , , I Qp = 1.45 / 1.41 bpm i , i Density = 9.56 / 9.65 PP9 i ; PVT 402 bbp at 03:15 hrs. ~ ~ WOB = 0.50 to 1.5 klbf i ~ ; 04:13 - 05:30 1.28' STW HIP'~ P ~, W EXIT Geologist seen sample with the help of Sandy Lott Back reaming window area from 10,355 ft 10,335 ft ~ ~ ' ~ ~ Motor work at 10,337 ft and 10,347 ft on back reams I~ ' ', i Set brake at 10,337.15 ft to ream out tight section (top of ~ I ~ window). Every trip down and up we are see some motor wokr i ; ~ i 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 @ 1.6fUmin. Slight motor ' ' I ~ 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 j 0.33'~, STWHIPI~ ~ P i WEXIT Ream up from 10,355ft to 10,330ft @ 1.6fUmin. 06:50 - 07:00 0.17 ~, STW HIPi~ P i WEXIT Shut down pumping & dry tag. No set downs & no overpulls. ', I Geologist reports seeing cement in returns - firm to hard. 07:00 - 08:50 ' 1.83'I STWHIP ~ P ~ WEXIT POH with window mill BHA following pressure schedule. PJSM j !i I I prior to POH regarding pressure undeployment, BHA handling, ~ !~ j ~ stack management & changing out pump control reostat. Tag i ~i I 08:50 - 10:25 ~ 1.581 STWHIP ~ P WEXIT up & trap 200 psi on cho1~. Begin pressure undeploying BHA. Mill gauges out 274" go 10:25 - 14:00 ~ 3.58 ~ DRILL 14:00 - 16:10 I 2.17; DRILL 16:10 - 16:20 I, 0.17 i DRILL 16:20 - 18:00 1.67 ~ DRILL 18:00 - 19:50 1.83 i DRILL 19:50 - 20:00 0.17 i DRILL 20:00 - 20:35 0.58 i DRILL 20:35 - 22:30 I 1.921 DRILL 22:30 - 00:00 1.50 DRILI 7/16/2007 00:00 - 01:40 1.67 DRILL 01:40 - 01:55 0.25 DRILL 01:55 - 02:15 0.33 DRILL 02:15 - 03:55 1.67 i DRILL 2.73" no-go. 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. P PROD3 Install dimple connector & pull test to 30k - good. BHI installing UQC. PT coil connector to 3500 psi - good test. P PROD3 PJSM regarding pressure deploying BHA P PROD3 Begin pressure deploying BHA. P PROD3 RIH with open EDC ST BHA P PROD3 Tie-in Corrected -15.5 ft 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 usual this morning. P PROD3 POOH, Held PJSM and discussed the pressure undeploy BHA with new crew ~ P PROD3 Pressure undeploying BHA P PROD3 Finished RD BHA P PROD3 PJSM P PROD3 Pressure Deploy BHA in well WHP = 250 psi P PROD3 RIH with window dressing BHA Printed: 8/6/2007 2:44:30 PM ~ ~ ~ \ ~- BP AMERICA Page 18 of 26 Operations Summary Report L.egal Weil 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: bate From - To 'Hour~Task ~ Code j NPT Phase Qescription of Operations 7/16/2007 03:55 - 04:30 - 0.58I, DRILL I~ P PROD3 - Tie-in at 9280 ft. Ciosed EDC at 10,300 ft 04:30 - 06:00 1.50 ~ DRILL ' p ; PROD3 RIH and worked way through whipstock area. ' ~ Ream through at Qp = 1.52 bpm. 50 psi motor work at t0,342 , I ft, then feli offi in 2 ft. Took an little CT weight and some motor work at 10,347 ft. I Tagged bottom at 10,355 ft ~, 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', DRILL P ', ~, PROD3 Ream through whipstock area from 10,342ft to 10,350ft at Qp = ' I I 1.52 bpm. Seeing motor work at 10,347ft. Park @ 10,347ft & ' ~I let drili off (75 psi motor work, 5 min to drill off). Ream up & ' ' I, down @ varing speeds from 1fUmin 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). i , I 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, I park @ 10,338.86ft (100 psi motor work, 5 min to drili off, not I , ~ seeing any WOB). Park @ 10,339.09ft (150psi motor work, no I ~ WOB). Continue to RIH @ 20ft/hr, no other set downs or motor I ; work. Tag bottom @ 10354.75ft, 10,349ft is off bottom upward ~ ! ~ direction. 09:50 - 10:50 1.00 I DRILL ' P ' PROD3 Ream down @ 2.5fUmin from 10,325ft. Slight pressure bobble i ' , @ 10,339ft. Ream up @ 2.5fUmin from 10,351ft. Slight '~ ' pressure bobble @ 10,336ft. Reduce pump rate to 0.25bpm & ' ~ RIH, slight pressure bobble @ 10,339ft. PUH while pumping @ ' ~ 0.25 bpm slight pressure~obble @ 10,336ft. Trap 200 psi on j I 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 I P PROD3 Pressure undeploy SHA. 13:45 - 15:30 1.75 DRILL i 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 I P I PROD3 Pressure deploy BHA - 2.3 degree motor & HCC BC bit & BHI tools. 17:00 - 18:40 1.67 DRILL j 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 ! ~ Ta ged at 10355 ft ~~ 19:20 - 21:30 2.17 DRILL i P j PROD3 Drilling Build Section 1 B-08 L101 TF at 80-90R n ~`,.O ` ' ' I I QP = 1.52 / 1.48 bpm CJ r ~ ~ CTP = 3000 / 3200 psi i ~ BHP = 3604 psi = 10.85 ppg ECD ~ PVT = 359 bbl i Found RA Marker at 10342 ft 21:30 - 21:50 0.33 DRILL P i PROD3 Smelled smoke by ops cab, PUH while investiagation is taking I place. Vent sump above boiler is the culprit Smell coming from Printed: 8/6/2007 2:44:30 PM • i BP AMERlCA Page 19 of 26 ' Operations 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: NORD~C 2 Rig Number: Date From - To Hours Task Code NPT ~ Phase Description of ~perations 7/16/2007 21:30 - 21:50 0.33 DRILL II p ~~ ! PROD3 motor # 2 generator side smelis like rubber burning. SD Motor 21:50 - 23:10 I 1.331 DRILL I P 7/17/2007 ~ 00:00 - 01:30 j 1.50 i DRILL ! P 01:30 - 02:15 ~ OJ5 ~ 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 DRI~L P 07:20 - 09:15 I 1.921 DRILL I P PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 09:15 - 10:30 1.25 DRILL I P ~ PROD3 10:30 - 11:45 1.25 DRILI P I PROD3 11:45 - 13:30 1.75 DRILL P I PROD3 13:30 - 15:00 1.50 DRILL P ~ PROD3 15:00 - 17:00 ~ 2.00 I DRILL I P I I PROD3 #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. 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 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 bbl Lost Generator #1 Shut down drilling, lower pump pressure. PUH. Restarted generator The cards in the SCR panel of Gen 1 caused the probiem when LOTO MP2 This has been a ongoing problem with wore out cards or card holders in SCR panel. Presently down to two motor. 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 Wiper trip. Had to pull abqye 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. 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 POH following pressure schedule. Log for tie-in @ 9280ft (+1ft corr). PUH to 8900ft & log down to determine top of 3-3/16" liner. POH following pressure schedule. PJSM while POH regarding pressure undeployment. Begin pressure undeployment of BHA. Begin pressure deployment of BHA. RIH with 1.1 degree motor & BHI tools. l.og for tie-in (-15ft). PUH. Trap 200 psi on well head, stop pumping. Log 4-1/2" tubing & top of 3-1/16" liner. 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: 8/62007 2:44:30 PM i • BP AMERICA Page 20 of 26 Operations 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 Code NPT Phase Description of Operations ]/17/2007 I 15:00 - 17:00 2.00 DRILL P PROD3 BHP = 3630 psi = 10.89 ppg ECD ', ROP 0-100 fph ' 17:00 - 17:20 0.33 DRILL P PROD3 ; Drilling Lateral Section 1 B-08 L101 TF at 80-150 R. , i Density = 8.64 / 8.87 ppg ', CTP = 2600 / 3200 psi ', i BHP = 3327 psi = 10.00 ppg ECD i ROP 0-100 fph ,17:20 - 18:15 , 0.92 DRILL P PROD3 i PUH, pull 3,000 Ib heavy. Qp = 1.52 / 1.68 bpm Increased the ~ I 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 ', ~ I base of WS at Cutting build up in the annulus with new mud in ', II ~ ~ ~ well. PUH and normal CT until 1065 ft andf started to puq 3k ~ i ! ~I heavy Increased W HP to 200 psi. PUH SD and pull through I I ~ II ~ ~ window area. Open EDC at 10,330 ft I ~ Qp = 1.86 / 2.00 bpm Density = 8.75 8.6 ppg SWI to I~ ~ ~ I determine SIWHP 200 psi at 6400 ND EMW = 9.3 ppg , 18:15 - 00:00 i 5.75 DRILL P PROD3 I Circulate bottom up while holding a WHP = 223 psi PUH i , j , Density = 8.7 ppg pressure scales and perform wiper trip while ! ~ j I conditioning hole and new mud. 2860 psi fs at 1.87 in/1.92 out. ' , ~ ~li ~ ~! ~ ~I Wait on vac trucks to compiete mud swap. 7/18/2007 ! 00:00 - 04:00 ~il 4.00 DRI~L II P I~ PROD3 ~I~ Drill lateral from 10890. 2700 psi fs at 1.51 in/1.52 out 200-300 ' I 'idpsi. 1-2k# dhwob. WHP/BHP/ECD: 285/3555/10.67 ppg. ; I ~ i IA/OA/PVT: 180/49/424 bbls. ' ~i Up to 40 % chert in samples. Very slow drilling. ', 04:00 - 05:00 1.00 DRILL P PROD3 I W iper trip to window. Hole smooth. ' 05:00 - 06:40 1.67 DRILL P PROD3 i Drifling lateral ROP at 7-9 fph, Last Sample 40% chert. ~ , ~ ISample at 10,800 % 10% Chert and 10850 ft 40 % Chert ' i ! Sample description : j j I C1 Sand, Sand and Silty,$and, medium brown, quartzose, very ' fine to fine grained, disaggrated, sub-round to angular, transparent, 1 to 4% glauconite, very well sorted, 06:40 - 09:15 2.58 DRILL P PROD3 POOH due to low ROP anchorite / Cherity material 09:15 - 12:45 3.50 DRILL P 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 welihead pressure. ' 12:45 - 17:30 4.75 DRILL P PROD3 RIH with EDC open and following pressure schedul 17:30 - 15:30 22.00 DRILL P PROD3 Log tie-in Corrected -11 ft, RIH and tagged bottom at 10897 ft 15:30 - 00:00 8.50 DRILL P PROD3 Drill lateral from10,897 ft I CTP = 3182 psi off bottom Qp=1.45/1.40bpm ~ Density = 8J6 / 8.60 ppg ~ BHP = 3547 psi at 10.6 ppg ECD ! PVT = 341 bbl ROP 5-70 fph j 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. 7/19f2007 00:00 - 03:00 3.00 DRILL P PROD3 Wiper trip to window. Pull out of hole to check BHA and bit. Follow pressure schedule. 03:00 - 06:15 325 DRILL P PROD3 Hold PJSM. Pressure undeploy BHA. Found leaking check ~ valve. Get back on well to circulate through checks to try and Printed: 8/6/2007 2:44:30 PM • ~ BP AMERfCA ; Page 21 of 26 Operations 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 I i06:15 - 07:15 1.00 DRILL N WAIT PROD3 , I07:15 - 07:30 '', 0.25 I DRILL N DFAL PROD3 ~ 07:30 - 08:30 , 1.00 DRILL N DFAL PROD3 ~i 08:30 - 10:15 ' 1 J5 ~ DRILL N DFAL PROD3 I 10:15 - 10:30 ', 0.25 I DRILL N DFAL PROD3 I 10:30 - 11:20 ', 0.83 1 DRILL N DFAL PROD3 , 11:20 - 13:05 1.75 ' ~ , + DRILL ( , ; P ~ I ; I PROD3 ! ' 13:05 - 14:30 , 1.42 ~~ ~~ , DRILL i ~ ~ II P I i I PROD3 I I 14:30 - 16:45 I 2.25 ~ I DRILL I P PROD3 i I I ~ ( ~ ~ ~I 16:45 - 18:00 i 125 RILL P ROD3 18:00 - 21:45 I 3.75 DRILL P PROD3 21:45 - 23:45 I 2.001 DRILL I P I I PROD3 23:45 - 00:00 0.25 DRILL P PROD3 7/20/2007 00:00 - 02:45 2.75 DRILL P PROD3 02:45 - 03:00 0.25 DRILL P PROD3 03:00 - 04:00 1.00 DRILL P PROD3 04:00 - 07:29 I 3.481 DRILL I P I I PROD3 clear same. Checks holding this time. Pressure undeploy. Lay down BHA to change ball vaives and floats. Change motor. Change bend to 1.4 deg. MU new Hycalog bi center. SD while Schiumnberger Installing CT Inspect on CT PJSM on pressure deploying BHA Pressure Deploy BHA in the well RIH to 9300 ft Log tie-in at 9300 ft Corrected -13 ft 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. Drill laterai 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 WOB 1-2 kib ROP 3- 20 fph Stacking. PU and pulled heavy to 32k (8k over) PUH and unable to go back in the hole. Time for a wiper. PUH to 10,360 ft. Little rough below 11,000 ft. Worked through Drill lateral from 11,024 ft with TF at HS. Buiid 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 klb ROP 0- 95 fph Don't let the pump pressure drop off suddenly followed by CT weight stacking , could gQt stuck. Turned TF down at 11,100 ft to 120L TF Wiper trip to window. Hole smooth. Drill lateral trom 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/AZMlTF: 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. Drill ahead from 11,238'. Nice drilling break with ROP 50-70 fph. INC: 84 deg at NB. Continue to drop with TF: 165R. Drill ahead at 120 R to hold 80 deg inc. Seeing some 300-400 psi pressure fiuctuations on circ pressure. May have plugged off a jet. Continue to drill to TD of 11.300'_ _ W iper trip back to 9000' W iper trip to 9000'. Run back in hole to 3-3/16" window. Log gr tie in from 10370'. Add 4' correction. 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. Circulate out of hole laying bead mud 1:1. Paint EOP flag at 9300'. Continue fo circulate out of hole. Increase rate to 1.5 bpm from 9000' to surface. Slowly reduce WHP pressure as KWF filis the CT annulus. ~ Printed: 8/6/2007 2:44:30 PM • • BP AMERICA Page 22 of 26 Operations 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 HoursI Task Code NPT Phase- Description of Operations L 7/20/2007 i 07:29 - 08:25 -. _ 0.93 ~ DRILL P PROD3 - - - --- PJSM on BHA handling. LD BHA using conventional methods. ; Wel1 started to flow. 0825 - 09:15 0.83; DRILL P PROD3 WSI at 08:25 Open valve 17 & 18. WHP 10 psi BHI rigging up tool string for RIH to kili weli 10 min 30 psi I 25 min 35 psi 60 min 42 psi Steady at 43 psi for 9 minutes 09:15 - 10:00 0.75 ~ DRILL N FLUD PROD3 PU P&Cs & EDC and Nozzle BHA. Stab on well and l pressured up to 100 psi and open master valve.SIWHP = 70 ~ i psi 10:00 - 11:45 ~ i 1.75; DRILL li N 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 11:45 - 12:45 i 1.00 DRILL N I FLUD PROD3 Circulat bottom up at 10,300 ft i ' QP=1.9/1.9bpm Density in = 10.Oppg Density dropped to 9.46 ppg and then I with 50 bbl up the annulus, density out started to rise. Mixing I , another 75 sxs to even out the density in & out. With 99 bbl ~, , I pumped density out was 10.00 ppg ' j SD and checked flow, Well stable 12:45 - 14:25 ; 1.67, DRILL N FLUD ~ PROD3 POOH to run liner. OOH, Checked flow, (OK) 14:25 - 15:00 '~, 0.58' DRIIL i N FLUD PROD3 LD dri~ling BHA 15:00 - 15:25 I 0.42' DRILL I P PROD3 PJSM 15:25 - 17:30 j 2.08', CASE ~ P ~ RUNPRD PU MU 2-3/8" Liner and BOT CTLRT and BHI CoilTrac BHA 17:30 - 19:15 '; 1.75 ~ CASE P ~ RUNPRD RIH fillling across the top 19:15 - 20:00 I 0.75' CASE ', P RUNPRD Subtract 11' correction at 10,300'. 24k# up, 6.5k# dn wt. ~ ', , Run into open hole. Tag at 11,301'. With standard -11' I correction, liner is on btm. I Bring on pump to disconnect. 4500 psi at 1.85 bpm. PU. New I up weight is nowl9k#. .,, T0~:10,364'. BOL:11,304'. 20:00 - 22:15 2.25 CASE P RUNPRD Pull out of hole. 22:15 - 00:00 1.75 CASE P RUNPRD LD BHA tools. MU skirted hook assembly with Baker mwd, including HOT. Orient hook to HOT. 7/21/2007 00:00 - 00:15 0.25 ~ WHIP P RUNPRD Continue to make up WS retrieval BHA. Stab coil. Get on ~ well. 00:15 - 01:45 1.50 j WHIP P RUNPRD Run in hole. 01:45 - 02:00 0.25 j WHIP , P RUNPRD Log gr tie in. No correction. 02:00 - 02:15 0.25 WHIP P RUNPRD Run in hole to top of 2-3/8" liner. 22k# up, 8k# dn wt. 02:15 - 02:30 0.25 WHIP P RUNPRD Engage whipstock. Pick up to 29k#. Jars fired. Fish or hook I came free. 02:30 - 05:00 2.50 WHIP P 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. 05:00 - 07:30 2.50 WHIP P RUNPRD Get off well. No recovery. Marks on hook indicate tray may have been engaged, however brass shear screw was still intact. Looked at options, with shear pin still intact, decided to rerun hook Printed: 8/62007 2:44:30 PM • i BP AMERICA Page 23 of 26 Operations Summary: Report Legal Well Name: 1 B-08A Common Weil Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 , Date From - To Hours Task Code NPT . _ _ --- - ~__~ 7/21/2007 07:30 - 09:00 1.50 I WHIP I N i ~ ~ DFAL I ~ ~ 09:00 - 10:00 1.00 ~ , II WHIP I N DFA~ 10:00 - 11:45 1.75 WHIP I N I I DFAL I 11:45-14:45 3.OO I ~IWHIP ,N 'I ' ~IDFAL 14:45- 15:00 0.25 I '' , ~, WHIP ~,N 'I IIDFAL 15:00 - 16:00 1.00 WHIP ; N I DFAL I ~ 16:00-17:30 1.50 I,WHIP ',N I ~DFAL I ~ I 17 30 18 30 1 0 I ' ' , W IP ' ~~ ' I : - : 18:30 - 19:15 . 0 0.75 H N WHIP ; N IDFAL I DFAL i I I 19:15-22:00 2.75 ~ WHIP !P ~ 22:00 - 22:45 0.75 i W H I P j P 22:45 - 00:00 1.25 I WHIP ~ P 7/22/2007 00:00 - 01:30 1.50 W H I P i N I ~ I i D FAL 01:30 - 02:00 0.50 ~ WHIP N DFAL 02:00 - 02:45 0.75 WHIP N DFAL 02:45 - 03:15 0.50 WHIP N DFAL 03:15 - 05:00 1.75 WHIP N DFAL Spud Date: 6/27/2007 Start: ~ 6/27/2007 End: 7/26/2007 Rig Release: 7/26/2007 Rig Number: Phase Description of Operations -- 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 jarred twice. Unable to move. Set string in neutral, rotated off. RUNPRD POOH to look at hook. Checked flow RUNPRD LD BHA and inspect hook. The hook looks to be inside the whipstock slot. The blue paint used as a indentify show the hook was latched into the whipstock. The shear pin is stili attached but worn at the top. Ordered out wireline from CPAI Spot Wireline truch. Held THA on RU wireline on rig with Halliburton RUNPRD RU Halco to run LIB RIH with 3.79 LIB and tagged the 3.813" DB "Nipple Q 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" RUNPRD RD Halliburton Wireline RUNPRD PU WS Fishing BHA #31 RUNPRD RIH, Wt check at 5914 ft = 12.6k1b Tagged at 6,143 ft (10 ft deeper than wireline). Set setting sleeve in WS slot and pumping down CT at 1.47 psi 3100 psi. SD and picked up, clean RIH and set 6k down and no movement downhole. RUNPRD POOH with setting sleeve RUNPRD LD BHA tools. Inspect setting tool. Removed blue paint and scarred edge of engagement shouider indicate sleeve was engaged in WS slot. 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. Pressur~nd pulf test coil connecior. RUNPRD Mu overshot assembiy on coil track tools. Stab coil. Get on well. RUNPRD Run in hole. 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. RUNPRD Log CCL from 5,900' down to fish. CCL log (coil depth) is 8' deep compared to tbg detail. This confirms that fish is wedged at btm of seal assembly at 6141' (CTD depth) or 6133' drillers depth on tbg detaii. RUNPRD POOH. Discuss options with town. Decide to make setting sleeve run with bigger mwd tools. Hold PJSM with crew to discuss plan forward. RUNPRD At surface. Get off well. LD slim Inteq BHA toois. Baker overshot sleeve was pinched indicating that overshot was along side the tray. RUNPRD Bring 3" Coiltrack tools into pipe shed. Printed: 8/6/2007 2:4430 PM • • BP AMERICA Page 24 of 26 Operations 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 7/22/2007 I 03:15 - 05:00 05:00 - 08:30 1.751 WHIP I N DFAL i RUNPRD i Re-head e-coil for big tools. installing 2-3/8" X 3-1/2" variable in j station 3 Notify AOGCC on up coming BOP test. I RUNPRD ; Installed 2-3/8 X 3-1/2" Variable (VBR's) Conducted test. , I Inspect and service injector chains i RUNPRD ~ BOP test with John Crisp AOGCC. RREP ~ RUNPRD ~ Blind/shears not testing. Rebuild same and install. No test. ! Rebuild again and install. Get good test. 250 psi low, 3500 psi j high. { RUNPRD `Test inner reel valve to 250 and 4500 psi. Good test. DFAL '~ RUNPRD I Hold PJSM with crew to discuss BHA makeup. Pick up tools on ' i 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 I Orient to HS to try and locate pinch point. Set dn at 6150'. ~I 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 , I orientation was shallowest tag, assume this is with tang ~', latached in WS 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. I Set dn at 6147' w/ 8k dn wt. Jar dn. PU w/ 7k# overpull. ~I 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 I 20 times. No apparent movement of WS tray. DFAL ,; RUNPRD i Pull out of hole to inspect setting sleeve. Call for 3-1/8" drill ;collars from Baker Fishing. DFAL ; RUNPRD LD and inspect BHA. Pa,{~t on tang indicates no engagement j 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 other TF the tag was 6150 ft to 6152 ft, RIH to 6,147 and 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. I 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 wetl. 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 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 I I 1.00, WHSUR P 19:00-21:00', 2.OO~ i i WHIP ~N 21:00 - 22:00 ', 1.00 i W H i P N 22:00 - 00:00 ' 2.00 I W H I P N 7/23/2007 I 00:00 - 02:45 , 2.75 ~ W H I P ; N , ; 02:45 - 03:30 '~ OJ5 WHIP ; 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 I 3.25 FISH I N 12:15 - 14:30 I 2.251 FISH I N 14:30 - 18:30 i 4.00 FISH N 18:30 - 20:45 I 2.25 FISH N 20:45 - 21:45 ' 1.00 FISH ~ N 21:45 - 23:30 ~ 1.75 FISH ~ N Printed: 8/6/2007 2:4430 PM s • BP AMERICA Page 25 of 26 ; Operations 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: 7/26I2007 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 - ~-- -- -- 7/23/2007 , 21:45 - 23:30 1.75 FISH N DFAL RUNPRD is clean. RIH. Slipped out of slot. PU and re-orient to 200 deg ~i TF. Missed again. PU and make several tries. Finally get ~i back in at TF 210 deg. at 6147'. ; ~ Begin jaring. Set 4500 # dn wt. Jar with 10k# DHWOB several ~ ~ times. Jar 28 times. Pipe now has 50 cycles over gooseneck j & at reel. Need to cut pipe. Will also add more drill collars. ; 23:30 - 00:00 0.50 FISH N DFAL RUNPRD Pull out of hole. 7/24/2007 '~ 00:00 - 01:00 1.00 FISH N DFAL RUNPRD Continue to pull out of hole. Hold PJSM. Tag up. Get off well. i ~~ Unstab coii. Set back injector. I 01:00 - 02:30 1.50 FISH N DFAL RUNPRD I Pull and stand back BHA including Inteq tools and drill collars. Setting sleeve was bent on backward near its bottom. 1 02:30 - 03:45 1.25 FISH N DFAL RUNPRD Rig up and cut coii. ~ 03:45 - 05:30 1.75 FISH N DFAL RUNPRD Re head e-coii. Test line. Test Kendal connector. j 05:30 - 08:15 2.75 FISH N OFAL 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 ' 08:30 - 10:30 2.00 FISH N DFAL RUNPRD PU BHA scribe HS added 6 drill coliars 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 I tagged the Seal nipple at 6,109 ft. Using the orienter, RIH and I ~ ~i set down at 6,147 ft at 210R. PU and try to confirm we can i ~ pass the slot. At 150R, RIH to 6151 ft. PUH and set tang in I ! i W S and jarring down jarred 3 times and held the high fives till I ~ ! we went a little deeper. The whipstock is gone. RIH to 6489 ft, ~ ~ clean 12:05 - 13:45 ( 1.67 FISH N DFAL RUNPRD i POOH to PU the 2-3/8" Coiltrac and BOT overshot Held PJSM ~ and discussed the hazards and talked about and confirm the i I fiow path once tagged up , i 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. 'i 16:00 - 17:00 1.00 FISH N OFAL RUNPRD MU Baker overshot, discqpnect, 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 iop. 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. RIH 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' I 20:10 - 20:25 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 20:25 - 21:25 1.00 FISH N DFAL RUNPRD POOH filling from BS PVT 136 21:25 - 23:10 1.75 FISH N DFAL RUNPRD Pull slowly 12.8k 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 • i ' BP AMERICA Page'26 of 26 Operations Summary Report Legal Well Name: 1B-08A Common Well Name: 1 B-08A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date from - To Hours Task Code 7/25/2007 ! 00:25 - 02:10 i 1.751 FISH ~ N 02:10 - 04:00 i 1.83 ~ FISH N 04:00 - 04:30 ~ 0.50 j FISH N 04:30 - 04:40 ~ 0.17I CASE P 04:40 - 06:15 ~ 1.58 ~ CASE P 06:15 - 09:30 I 325; CASE ~ P 09:30 - 10:30 ~ 1.00 i CASE I P ':10:30 - 12:00 I'~ 1.50I CASE P ! 12:00 - 13:00 I 1.001, CASE P ~ 13:00 - 13:30 ! 0.50'~ CASE P i 13:30 - 15:30 I 2.00'' CASE I P ', 15:30 - 17:45 ; 225'; ~ , CASE ~II P 17:45 - 18:15 r 0.50 ~ CASE ~ P 18:15 - 18:35 i 0.33I WHSUR I P 18:35 - 19:35 I 1.00 I WHSUR I P 19:35 - 21:00 i 1.42 j RIGD ', P 21:00 - 00:00 I 3.001 RIGD I P 17/26/2007 100:00 - 00:30 I 0.501 RIGD I P 00:30 - 02:00 I 1.50 ~ RIGD ~ P 02:00 - 03:15 I 1.251 RIGD ; P 03:15 - 05:00 I 1.751 BOPSUFI 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 Operations 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 Chk for flow. ~D 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. Coil and annular pressure are tracking. Check ail ~ valves etc. Re-pressure. Same result. PU out of packer. ' Sting back in to packer. Pressure CT annulus to 2000 psi. I Held solid. Top of KB packer is at 9019' I RUNPRD Pull out of ho~e. Tag up. ~ RUNPRD Get off well. Unstab coil. LD BHA tools i RUNPRD MU nozzie 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 wl well 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 da,~yn 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 ~ • . ~~ BP Alaska Baker Hughes INTEQ Survey Report r' gAKE~ ~u~~~~ IN'I`~Q Campany: 'BPAm€rca Uate: 8/22/2{?07 T9me. 10:0~_98 .~age: ' 1 Field. Kuparuk: Co-a~rdirtate(NE} l~eference: Well: 08, True Ntldh Site: KRU 1 B Pad Uerfieat (TVI3} 12eference: E'~KB Elev 1 93.Q' ~ Well: ~ 08 Secdon ('VS) l~efer~nce: ~'~ Wel{ (Q t}ON,O.OD~,87.66Azi) 1'Veltpa#h: ;1 B-08AL1-01 ~urvey Caleuaatian Niethod: ' Minimurn Curvature r Db: Oracle 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: 596964672 ft Latitude: 70 19 40290 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: ti~'elt 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-08AL1-01 Drilled From: 1 B-08AL1 PB 1 Tie-on Depth: 1031029 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 Angte: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 93.00 0.00 0.00 87.66 Survey Program for Detinitive Wellpath Date: 7/14/2007 Validated: No Version: 3 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 10310.29 MWD (9256.00-11028.00) (2) MWD MWD - Standard 10338.00 11304.00 MWD (10338.00-11304.00) MWD MWD - Standard Annotation 1Y1D ' TVD ft ft: 10310,29 6501.54 TIP 10338.00 6501.90 KOP 11304.00 6534.74 TD Survey: MWD Start Date: 7/19/2007 Company: Baker Hughes INTEQ Engineer; Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Company: 'BP Am~c4 ~ Date: 8/22/2QQ~ Time: 10:00:06 Page: 2 k'i~ld: ~~~~Kuparu[c'~~~ ~ ~ Co-ur$inate(k~iE}32eference~ '~ W611: 08, True Narth ~ Sitie: '~KR~1 1B Pad Ver[ical(TU~)Refer~hce: " RKB Elev 1 93.fl '~~~ Wells ~08 ~ ~ Section (~S} ~tef~rene~: ~~: ~IeO (0 OON,O.ORE,87.66AZi) Wellpafh: '1B-iJ8AL1-41 SuryeyCalculattonMethod: MinimumCurvature ' Db: Oracle Survey f~ deg deg ; ft ft ft ft ft: ft ft deg/100ft 10310.29 89.45 255.81 6501.54 6408.54 -523.65 5197.30 5969158.25 555498.19 5171.53 0.00 MWD 10338.00 89.04 255.35 6501.90 6408.90 -530.55 5170.47 5969151.18 555471.41 5144.43 2.22 MWD 10365.01 90.18 265.83 6502.09 6409.09 -534.96 5143.86 5969146.59 555444.83 5117.67 39.03 MWD 10394.50 88.00 277.28 6502.56 6409.56 -534.16 5114.44 5969147.19 555415.40 5088.30 39.52 MWD 10425.56 89.32 284.77 65~3.28 6410.28 -528.22 5083.98 5969152.92 555384.91 5058.11 24.48 MWD 10456.46 89.05 294.15 6503.72 6410.72 -517.94 5054.88 5969163.00 555355.75 5029.46 30.37 MWD 10487.20 87.63 304.73 6504.62 6411.62 -502.86 5028.16 5969177.90 555328.93 5003.37 34.71 MWD 10515.24 89.51 313.85 6505.32 6412.32 -485.13 5006.49 5969195.49 555307.14 4982.45 3320 MWD 10546.76 87.27 323.80 650621 6413.21 -461.45 4985.77 5969219.03 555286.27 4962.72 32.34 MWD 10576.59 57.97 333.69 6507.45 6414.45 -436.00 4970.33 5969244.37 555270.66 4948.33 33.21 MWD 10613.86 87.94 344.94 6508.78 6415.78 -401.21 4957.19 5969279.07 555257.29 4936.63 30.17 MWD 10643.25 &6.28 353.74 651027 6417.27 -372.39 4951.77 5969307.84 555251.67 4932.38 30.43 MWD 10675.56 86.19 4.40 6512.39 6419.39 -340.21 4951.24 5969340.02 555250.93 4933.18 32.92 MWD 10702.07 85.14 9.04 6514.40 6421.40 -313.96 4954.34 5969366.29 555253.85 4937.34 17.90 MWD 10730.41 85.02 16.59 6516.83 6423.83 -286.45 4960.59 5969393.84 555259.92 4944.72 26.55 MWD 10760.57 86.34 20.82 6519.11 6426.11 -257.97 4970.24 5969422.38 555269.37 4955.52 14.65 MWD 10793.91 90.92 27.57 6519.90 6426.90 -227.59 4983.89 5969452.84 555282.82 4970.40 24.46 MWD 10824.54 88.40 30.40 6520.09 6427.09 -200.81 4998.73 5969479.73 555297.47 4986.33 12.37 MWD 10855.10 89.85 34.78 6520.55 6427.55 -175.07 5015.18 5969505.57 555313.75 5003.82 15.10 MWD 10886.50 88.96 38.22 6520.88 6427.88 -149.83 5033.85 5969530.93 555332.26 5023.51 11.32 MWD 10915.33 87.76 39.86 6521.70 6428.70 -127.45 5052.00 5969553.43 555350.25 5042.56 7.05 MWD 10944.62 90.34 41.22 6522.19 6429.19 -105.20 5071.04 5969575.81 555369.14 5062.49 9.96 MWD 10976.31 91.10 36.96 6521.79 6428.79 -80.61 5091.01 5969600.53 555388.94 5083.45 13.65 MWD 11005.70 90.55 31.71 6521.37 6428.37 -56.35 5107.58 5969624.89 555405.35 5101.00 17.96 MWD 11035.21 93.07 26.26 6520.44 6427.44 -30.56 5121.87 5969650.78 555419.46 5116.33 20.34 MWD 11062.38 94.92 24.78 6518.54 6425.54 -6.10 5133.55 5969675.31 555430.97 5129.00 8.71 MWD 11091.60 91.38 20.32 6516.94 6423.94 20.83 5144.73 5969702.32 555441.97 5141.27 19.47 MWD 11122.68 87.05 17.43 6517.36 6424.36 50.23 5154.78 5969731.77 555451.83 5152.52 16.75 MWD 11148.85 86.13 13.98 6518.92 6425.92 75.37 5161.85 5969756.96 555458.73 5160.61 13.62 MWD 11175.88 88.93 19.80 6520.08 6427.08 101.20 5169.69 5969782.84 555466.40 5169.50 23.87 MWD 11209.50 88.95 25.50 6520.71 6427.71 132.21 5182.63 5969813.93 555479.13 5183.70 16.95 MWD 11242.93 81.82 32.27 6523.40 6430.40 161.35 5198.70 5969843.18 555495.00 5200.95 29.36 MWD 11254.56 79.03 28.15 6525.33 6432.33 171.26 5204.47 5969853.12 555500.70 5207.12 42.37 MWD , 11304.00 79.03 28.15 653474 ~ 644174 214.05 5227.37 5969896.07 - 555523.31 5231J5 0.00 MWD Well Name: 16-08A Welibo~liagram (7-26-07) i API # 50-029-20635-60/61-00 ~ B~~BA ~~ PTD: 207-075,076 ConocoPh i I I i ps ~ 16" 65#/ft H-40 Alaska p 8ooh 4-1/2" Camco'DB' nipple 517.00 ft 1075" 45 5 #/ft K-55 2343.0 ft 4112" 12.62 !~/ft L-80 EUE 8rd Mod Tbg ID 3.953" 7" 26 #/ft K-55 ID 6.375" t"~~ O~~ -Calista ~ Pwrforati~ns 4-1/2" 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 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 ~ •5 9173.00 ft 4-1/2" Camco'DB' nipple ~ ~KB packer @ 9019' ~~~ CMU sliding sle~ eeve @ 9045 OH Side Track 1~ 3-1/2" x 33/16" Liner @ 9060' 10886' 33116" Casi g Shoe 10,480 f[ 3.7" "X" Nipple @ 9078' 2-3/8" TOL @ 10,467' ~ .~ ~nzz~ k " / \ ~~.~.Qr ---'-"' 23/6" TOL @10,363.6' ~„o28ft a~1-O'1~ I L1 Lateral 11 497 ft 4-1l2"LSX WS (Flow thiu) TOW 9256 ft BOW 9263 ft 11304' ~ ~~_Ot> f Lt-01 Lateral lb 4-712" 12.6#/ft L-80 Prepared by Dave Hildreth Orbis Engineering Inc Houston, Texas 9708.0 ft 1 8/20/2007 ~ ~ INTEQ To Whom It May Concern: ~ ~; BAKER H~JGHES 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 September 20, 2007 Please ~nd 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 ~ ~ ~ ~ ~'~ ~ ~ -~ , C~j " C~ ~ I'~ ~. ~ ~,2,dZ - U'2 ) ) ~ ~ ~ ~ ~~. ~ 1 ~ e " 7 Cc: State of Alaska, AOGCC Christine Mahnken ao~-~~~ . Page 1 of 1 ~ ~,. . _ , . Mahnken,:Christine R (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, September 12, 2007 8:02 AM To: Mahnken, Qhristine R (DOA) Subject: FW: Kuparuk 1 B-08AL1 & 1 B-08AL1-01 / PTD # 207-075 & 207-OZ6 . Christine, Please print finro copies of fhis email and place them in the appropriate well history files. Thanks, : Steve Dadies From: Hubble, Terrie L [mailto:Terrie.Hubble@bp:com] Sent: Tuesday, September 11, 2007 11;44 AM : _ To: .Davies, St~P~~'I F~E~OA) . . - . :.~ _ ::_ : Subject: Kuparuk 16-08AL1 & 1B-08AL1=01 / PTD # 207-075 & 207-076 H i Steve Please reference the following well: ~ Well Name: Kuparuk 1 B-08AL1, &°~=Kuparuk 1 B-08AL1-01 Permit #: 207=075 & ~l~'~ `= ,, ~.. . AP I #: ~"~"~"~5~=029=20635=~0=00 ~& 50-029-20635-61-00 , ~ 1 B-08AL1 Top Slotted Section MD: 10706' 1 B-08AL1 Bottom Slotted Section MD: 11463' & , 1 B-08AL1-01 Top Slotted Section MD: 10545` `° ,.-=-1B=08AL'~1=~"~~'Stt~m'~Sfott~~~ti~~"1171D°*~1127D' . .~ .. .,_ ,~:. :, These two well bores began Injection on September 8, 2007 Method of Operations is: Water Injection Thanks, : TPrrie _ _ _ . . ;; . ;-., ,. ~ ... ,~t~,..~~~~ ~ ~~.,~ ti ,~ . ~~<.. , 9/12/2007 ~ ~ 6 d ~ ~ ~ SARAH PAUN, GOVERNOR ~S~A ~~j ~i`D ~S 333 W. 7thAVENUE, SUITE 100 COI~TSERQA~`I011T CODII~II5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Gary Eller Fnx (so~> z~sasa2 CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 B-08AL 1-O 1 ConocoPhillips Alaska, Inc. Permit No: 207-076 Surface Location: 501' FNL, 141' FEL, SEC. 09, T 11 N, R 10E, UM Bottomhole Location: 38' FNL, 5194' FWL, SEC. 10, T11N, RlOE, UM Dear Mr. Eller: Enclosed is the approved revised application for permit to redrill the above referenced service well. The bottom hole location was changed by more than 500' laterally before starting drilling operations on this segment, due to information developed drilling 1B- 08AL 1. The permit is for a new wellbore segment of existing well KBU 1 B-08A, Permit No 19?- 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 in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chairman DATED this 1~day of July, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~~t~~ivc~ ~ STATE OF ALASKA ~ 1 7 2pQ ~/@_ _ ALAS IL AND GAS CONSERVATION COMMI ~~'r ~~1~ PERMIT TO DRILL q(~5ka Oi9 & Gas Cons. ~~mmission 20 AAC 25.005 p~~,~rr~~~, Flevfsed.Q7/16/07 : 1 a. Type of work ^ Drill ~ Redrili ^ Re-Entry 1 b. Current Well Class ^ Expioratory ^ Development Gas ~ Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco PhillipsAlaska Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: 1B-08AL1-01 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 11570 ' TVD 6453ss 12. Field / Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): 501' FNL 141' FEL SEC 09 T11 N UM ~ R10E 7. Property Designation: ADL 025648 ~ o2S~ River Pool ~~ ,~ , , . , , , Top of Productive Horizon: 1373' FNL, 237' FWL, SEC. 11, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: July, 2007 Total Depth: 38' FNL, 5194' FWL, SEC. 10, T11N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 17,900' 4b. Location of Welt (State Base Plane Coordinates): Surface: x-550298 ' y-5969648' Zone-ASP4 10. KB Elevation (HeightaboveGL): 93 feet 15. Distance to Nearest Well Within Poot: 1,730' (1B-12) 16. Deviated Wells: Kickoff Depth: 10337 ~ feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3471 ~ SurFace: 2825 `` 18: Casin 'Pro ram: S cifications To - Settin De t- Bo ttom uanf of ` ent cif, ar sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 3" 2-3/8" 4.6# L-80 STL 1228' 10342' 6409' 11570' 6453' Uncemented Slotted Liner 19. PRESE NT WEIL CONDiTION SUMMARY (To be campleted for Redritl and Re-entry Operations} Total Depth MD (ft): 11500 Total Depth TVD (ft): 6 23 Plugs (measured): None Effective Depth MD (ft): 11500 Effective Depth TVD (ft): 6323 Junk (measured): None Casing : Length Size Cement Volume MD ` ND 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' 5025' Production Liner 3588' 4-1/2" 496 sx Class'G' 6120' - 9708' 4846' - 6659' Liner 1 B-08AL1 1200' 3-3l16" 15 sx Class 'G' 9050' - 10480' 6265' - 6395' Liner 1 B-08AL1 1010' 2-3/8" Uncemented Slotted Liner 10467' - 11497' 6400' - 6323' Perforation Depth MD (ft): 9270' - 9402' (1 B-08A) Perforation Depth TVD (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 ce ~ that the fore ing is true and correct. Contact Gary Eller, 529-1979 Printed Na Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 529-1979 Date ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: 207-076 API Number: 50-029-20635-61-00 Permit Approval See cover letter for Date: • '~ other re uirements Conditions of Approval: ~ If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes L7No Mud Log Req'd: ^,_, /Yes [yNo HZS Measures: [~Yes ^ No Directional Survey Req'd: Uv Yes ^ No Other: APPROVED BY THE COMMISSION Date , COMMISSIONER Form 10-401 f~evised 1~212605 ~ ~~ / Submit In Duplicate `~i~~~~~~'l ,~ ~' /g ~~ ~R1~INAL KRU 1 B-O~L1 & L1-01 Sidetrack Laterals - Coiled Tubin Drillin J 9 Summary 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 C1 sand reserves for increased injection support. The perforations in the motlierbore 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' 23/8" slotted liner to a TD of 11,300' MD. The L1-O1 lateral will target the C1 Sand and will kick off from the Ll lateral from the 3-3/16" liner. That lateral will be 1233' in length and will be completed with 23/8" slotted liner to a TD of 11,570' MD. Only the L1 lateral will remain accessible through-tubing. CTD Drill and Comulete 1B-08A proEram: Julv 2007 Pre-Rig 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%2" tubing with whipstock dummy. 5. Obtain static BHP on C sand. 6. Caliper 4%a" liner. 7. Set 4%2" monobore flow-through whipstock on e-line at 9265' MD at an orientation of 20° left of highside RiE Work 1. MIRU Nordic Rig #2 using 2'/8" coil tubing. NU 7-1/16" BOPE, test. 2. Mi113.74" window and 10' of open hole at 9265' MD. 3. 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. 4. Run a 3-3/16" solid liner from TD up into the 4'/z" liner at 9100' MD. 5. Swap reel to 2" e-free coil tubing and 23/8" BHA. Change pipe rams, retest BOPE. 6. Pump a 3 to 4 bbl "puddle" cement job around the 3-3/16" liner. 7. Swap reel to 2" e-coil tubing. 8. Drill out the 3-3/16" float and shoe and 20' of new formation. 9. 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. 10. Complete the L1 lateral with 23/8" slotted liner from TD up into the 3-3/16" liner to 10,467' MD. 11. Set a Baker thru-tubing whipstock at 10,337' I~VID. Whipstock should be set at least 50+ feet away from the top of the L1 slotted liner with an orientation of 30° right of highside. 12. Mill a 2.74" window in the 3-3/16" liner plus 10' of open hole at 10,337' MD. 13. Drill the L1-O1 lateral to the north with a 2.70" x 3" bi-center bit to 11,570' MD targeting the C 1 sand. - 14. Complete the Ll-Ol lateral with 23/8" slotted liner with the top of the 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 10,337' MD. 16. 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. MIRU 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 4 July 16, 2007, FINAL KRU 1B-08~- L1 & L1-01 Sidetrack Laterals - Coiled Tubin Drillin g g 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 inj ection 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, TC-II solid liner from 9100' 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-O1: 23/8", 4.6#, L-80, STL slotted liner from 10,342' MD to 11,570' 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: 4'/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 2'/8" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum 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 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 taterals 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 HZS monitoring equipment will 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 4 July 16, 2007, FINAL KRU 1 B-08A L1 & L1-01 Sid tr k L r I -~il T in Dri ' e ac ate a s Co ed ub g Iling ~ 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-OSA 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 the L1 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 3%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 1 B-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 3'h" 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. The revised directional plan for the L1-O1 lateral, verbally approved by the AOGCC on July 13, 2007, ~~ mav place that lateral within one-quarter mile of wells 1 C-08 and/or 1 B-12. That has not been ~.,. ~ confirmed at this time. If the L1-O 1 lateral does turn out to be within one-quarter mile of either well, a Jr~ separate report of the mechanical condition of the affected wells will be issued separately at a later date. ~ '"~~~~ 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 hole 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 Page 3 of 4 July 16, 2007, FINAL KRU 1B-O~L 1- 1 i r k ral ~ 1& L 0 S det ac Late s Coiled Tubing Drilling • 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 4 of 4 July 16, 2007, FINAL ~ • bp BP Alaska s~~ ~ Baker Hughes INTEQ Planning Report 1NTE Q Gompnny: BP Amoco Date: 7/14/2007 Time: 12:46;Q9 Pase: 1 Field; Kuparuk Co-ordinate(NE) Reference: We11: 0&, True North Ske: KRU 1 B Pad Vertical (TVD) Reference: RKB Elev 1 93A We1L• 08 Sectioo (VS) Reference: Well (O.OON,O.OOE,t0.00A2i) Wellpath: Plan 6, 1B-08AL1-01 Survey CakulatiouMethod: Mi nimum 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: bggm2007 Site: KRU 1 B Pad Site Position: Northing: 5969646 .72 ft L.atitude: 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 Nort6ing: 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 Wellpat6: Plan 6, 1 B-08AL1-01 Drilled From: 1 B-08AL1 PB1 Tie-on Depth: 10310.29 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 Streogth: 57613 nT Mag Dip Angle: 80.83 deg Vertical Sectioa: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 93.00 0.00 0.00 10.00 Plan: Plan #6 Date Composed: 5/25/2007 strike new tgts from Laird L. 07-13-2007 Version: 9 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitude --> <--- Longitude ---> Name Description TYD +N/-S +E/-W Northing Eastiog Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 16-08AL1/AL1-01 New Polygon 93.00 -596.07 5217.69 5969085.98 555519.07 70 19 34.357 N 149 32 59.209 W -Polygon 1 93.00 -596.07 5217.69 5969085.98 555519.07 70 19 34.357 N 149 32 59.209 W -Polygon 2 93.00 -617.61 4999.52 5969062.98 555301.07 70 19 34.147 N 149 33 5.578 W -Polygon 3 93.00 -458.84 4887.57 5969220.98 555188.07 70 19 35.709 N 149 33 8.843 W -Polygon 4 93.00 -293.88 4896.68 5969385.98 555196.07 70 19 37.332 N 149 33 8.574 W -Polygon 5 93.00 -76.57 5003.15 5969603.98 555301.07 70 19 39.468 N 149 33 5.462 W -Polygon 6 93.00 201.64 5126.03 5969882.98 555422.07 70 19 42.203 N 149 33 1.869 W -Polygon 7 93.00 404.25 5187.40 5970085.98 555482.07 70 19 44.196 N 149 33 0.074 W -Polygon 8 93.00 584.42 5165.60 5970265.98 555459.07 70 19 45.968 N 149 33 0.706 W -Polygon 9 93.00 582.86 5398.62 5970265.98 555692.07 70 19 45.951 N 149 32 53.903 W -Palygon 10 93.00 470.70 5420.87 5970153.98 555715.07 70 19 44.848 N 149 32 53.256 W -Polygon 11 93.00 237.18 5344.30 5969919.98 555640.07 70 19 42.552 N 149 32 55.497 W -Polygon 12 93.00 -62.13 5236.28 5969619.98 555534.07 70 19 39.609 N 149 32 58.656 W -Polygon 13 93.00 -370.25 5099.19 5969310.98 555399.07 70 19 36.579 N 149 33 2.664 W -Polygon 14 93.00 -506.06 5218.30 5969175.98 555519.07 70 19 35.243 N 149 32 59.190 W 1B-08AL1/AL1-01 Fault2 93.00 -101.84 4296.90 5969573.98 554595.07 70 19 39.224 N 149 33 26.079 W -Polygon 1 93.00 -101.84 4296.90 5969573.98 554595.07 70 19 39.224 N 149 33 26.079 W -Polygan 2 93.00 -242.13 4337.96 5969433.98 554637.07 70 19 37.844 N 149 33 24.883 W -Polygon 3 93.00 -510.30 4209.15 5969164.98 554510.07 70 19 35.207 N 149 33 28.648 W -Polygon 4 93.00 -242.13 4337.96 5969433.98 554637.07 70 19 37.844 N 149 33 24.883 W 1B-08AL1-01 Plan 6 Target 1 6505.00 -510.83 5034.24 5969169.98 555335.07 70 19 35.197 N 149 33 4.563 W 1 B-O8AL1-01 Plan 6 Target 2 6509.00 -367.43 4977.20 5969312.98 555277.07 70 19 36.608 N 149 33 6.225 W 1 B-08AL1-01 Plan 6 Target 4 6519.00 30.43 5154.89 5969711.98 555452.07 70 19 40.519 N 149 33 1.030 W ~ ~ ~ bp BP Alaska Baker Hughes INTEQ Planning Report ~.r sAM1leGi~S iNTEQ Company: BP Amoco Date: 7/14/2007 Tiroe: 12:46;U9 Pagep 2 Fieid: kuparuk Ca-ordinate(NE) Reference: We1t: 08, True North Site: KRU 16 Pad Vertica} (1'VD) Referc~ce: RKB Elev Y93A WeIL• 08 Section (VS) Referencr. Well (O.OON,O. OOE,10.OOAzi) ' Weilpat6: Plan 6, 1 B-O8AL1-01 Sarvey CalculaHon Method: Minimum Curvature Db: OraGe Targets Map Map <-- Latitude ---> <- Loogitude ---> Name Description TVD +N/-S +E/-W Northiog Eastin~ Deg Min Sec De~ Min Sec Dip. Dir. ft ft ft ft ft 16-08AL1-01 Plan 6 Target 3 6527.00 -172.98 5063.51 5969507.98 555362.07 70 19 38 .519 N 149 33 3. 702 W 16-08AL1-01 Plan 6 Target 5 6534.00 283.68 5270.60 5969965.98 555566.07 70 19 43 .009 N 149 32 57. 647 W 18-08AL1-01 Plan 6 TD 6546.00 462.19 5346.80 5970144.98 555641.07 70 19 44 .764 N 149 32 55. 419 W Annotation NID 'I'~'D ft R 10310.29 6501.54 TIP 10337.00 6501.89 KOP 10357.00 6501.95 End of 9 Deg/100' DLS 10682.00 6510.00 End of 38 Deg/100' DLS 10780.00 6519.71 5 10872.23 6527.03 6 11000.23 6522.33 7 11100.23 6518.76 8 11240.23 6522.91 9 1138023 6534.30 10 11460.23 6541.14 11 11570.00 0.00 TD Plan Section Information MD Incl Azim TVD +N1-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100Pt deg/100ft degl100ft deg 10310.29 89.45 255.81 6501.54 -523.65 5197.30 0.00 0.00 0.00 0.00 10337.00 89.05 255.37 6501.89 -530.29 5171.44 2.23 -1.50 -1.65 227.72 10357.00 90.61 256.27 6501.95 -535.19 5152.05 9.00 7.79 4.50 30.00 10682.00 87.75 19.77 6510.00 -337.93 4974.32 38.00 -0.88 38.00 92.30 10780.00 80.90 29.39 6519.71 -249.38 5014.77 12.00 -6.99 9.81 126.00 10872.23 90.00 23.06 6527.03 -167.02 5055.30 12.00 9.87 -6.85 325.00 11000.23 94.19 37.86 6522.33 -57.08 5119.93 12.00 3.27 11.56 74.00 11100.23 89.89 26.64 6518.76 27.29 5173.15 12.00 -4.29 -11.21 249.30 11240.23 86.74 10.13 6522.91 159.60 5217.15 12.00 -2.26 -11.79 259.00 11380.23 83.99 26.76 6534.30 291.50 5261.10 12.00 -1.96 11.88 100.00 11460.23 86.22 17.39 6541.14 365.29 5291.01 12.00 2.79 -11.72 283.00 11570.00 88.59 30.36 6546.12 465.33 5335.31 12.00 2.15 11.82 80.00 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10310.29 89.45 255.81 6408.54 -523.65 5197.30 5969158.25 555498.19 0.00 386.81 0.00 MWD 10325.00 8923 255.57 6408.71 -527.28 5183.05 5969154.52 555483.96 2.23 380.75 227.72 MWD 10337.00 ~' 89.05 255.37 6408.89 -530.29 5171.44 5969151.44 555472.37 2.23 375.77 227.72 MWD 10350.00 90.06 255.95 6408.99 -533.51 5158.84 5969148.13 555459.80 9.00 370.42 30.00 MWD 10357.00 90.61 256.27 6408.95 -535.19 5152.05 5969146.41 555453.02 9.00 367.58 30.00 MWD 10375.00 90.33 263.10 6408.80 -538.41 5134.35 5969143.07 555435.34 38.00 361.34 92.30 MWD 10400.00 89.94 272.60 6408.74 -539.35 5109.39 5969141.96 555410.40 38.00 356.08 92.36 MWD 10425.00 89.55 282.09 6408.85 -536.16 5084.63 5969144.99 555385.61 38.00 354.92 92.38 MWD 10450.00 89.17 291.58 6409.13 -528.93 5060.73 5969152.06 555361.67 38.00 357.90 92.34 MWD 10475.00 88.81 301.08 6409.58 -517.85 5038.35 5969162.98 555339.22 38.00 364.91 92.23 MWD 10500.00 88.49 310.57 6410.17 -503.24 5018.11 5969177.46 555318.88 38.00 375.79 92.06 MWD 10525.00 88.20 320.07 6410.89 -485.49 5000.56 5969195.09 555301.22 38.00 390.22 91.84 MWD 10550.00 87.97 329.58 6411.73 -465.09 4986.18 5969215.39 555286.70 38.00 407.81 91.56 MWD 10575.00 87.79 339.08 6412.65 -442.60 4975.37 5969237.80 555275.74 38.00 428.09 91.24 MWD 10600.00 87.68 348.59 6413.64 -418.64 4968.42 5969261.72 555268.64 38.00 450.48 90.89 MWD i • ~ bp BP Alaska ~ ~ Baker Hughes INTEQ Planning Report 1NTEQ Company: BP AmoCO Date: 7/14/2007 Tims: 12:46:09 Page: 3 Field: Kupatuk Co-ordioAtc(NE) Refereace: Well: 08, True North Site: KRU 1 B Pad Vertical (TVD) Reference: RKB E-ev 1 93A We1L• 08 Section (VS) Rekreoce: Well (O.OON,O.OOE,t0;00Azi) Weilpat6: Pla n 6, 16-08AL1-01 Sarvey CakalaNon Method: Minimum Curvature Db: OraGe Survey MD Ieci Azim SS TVD N!S F./W MapN MapE DLS VS TFO Tool R deg deg ft ft ft ft ft deg/700ft ft deg 10625.00 87.62 358.10 6414. 67 -393.85 4965.53 5969286.48 555265.58 38.00 474.38 90.51 MWD 10650.00 87.64 7.60 6415. 71 -368.94 4966.77 5969311.40 555266.65 38.00 499.14 90.12 MWD 10675.00 87.71 17.11 6416. 72 -344.56 4972.11 5969335.81 555271.82 38.00 524.07 89.73 MWD 10682.00 87.75 19.77 6417. 00 337.93 4974.32 5969342.46 555273.99 38.00 530.99 89.34 MWD 10700.00 86.48 21.52 6417. 91 -321.11 4980.66 5969359.32 555280.22 12.00 548.65 126.00 MWD 10725.00 84.72 23.96 6419. 83 -298.12 4990.30 5969382.37 555289.70 12.00 572.96 125.91 MWD 10750.00 82.98 26.42 6422. 50 -275.63 5000.87 5969404.92 555300.12 12.00 596.95 125.72 MWD 10775.00 81.24 28.89 6425. 94 -253.70 5012.36 5969426.93 555311.46 12.00 620.54 125.46 MWD 10775.41 81.21 28.93 6426. 00 -253.34 5012.56 5969427.29 555311.66 12.00 620.93 125.12 1 B-OS 10780.00 80.90 29.39 6426. 71 -249.38 5014.77 5969431.26 555313.84 12.00 625.21 125.12 MWD 10800.00 82.87 28.00 6429. 54 -232.02 5024.27 5969448.69 555323.23 12.00 643.96 325.00 MWD 10825.00 85.33 26.28 6432. 11 -209.89 5035.61 5969470.89 555334.42 12.00 667.72 325.20 MWD 10850.00 87.80 24.58 6433. 61 -187.35 5046.33 5969493.50 555344.98 12.00 691.78 325.37 MWD 10872.23 90.00 23.06 6434. 03 -167.02 5055.30 5969513.88 555353.82 12.00 713.36 325.47 MWD 10875.00 90.09 23.38 6434. 03 -164.48 5056.40 5969516.44 555354.89 12.00 716.06 74.00 MWD 10900.00 90.92 26.27 6433. 81 -141.79 5066.89 5969539.19 555365.24 12.00 740.22 74.00 MWD 10925.00 91.74 29.15 6433. 23 -119.67 5078.51 5969561.39 555376.71 12.00 764.03 74.03 MWD 10950.00 92.56 32.04 6432. 29 -98.17 5091.23 5969582.97 555389.28 12.00 787.41 74.09 MWD 10975.00 93.38 34.93 6431. 00 -77.35 5105.00 5969603.88 555402.91 12.00 810.30 74.20 MWD 11000.00 94.18 37.83 6429. 35 -57.26 5119.79 5969624.06 555417.57 12.00 832.65 74.35 MWD 11025.00 93.13 35.07 6427. 75 -37.20 5134.62 5969644.22 555432.26 11.78 854.98 24925 MWD 11050.00 92.06 32.27 6426. 62 -16.42 5148.47 5969665.09 555445.96 12.00 877.85 249.12 MWD 11075.00 90.98 29.47 6425. 95 5.03 5161.29 5969686.62 555458.64 12.00 901.20 249.00 MWD 11100.00 89.90 26.67 6425. 76 27.08 5173.05 5969708.76 555470.25 12.00 924.96 248.92 MWD 11125.00 89.33 23.72 6425. 93 49.70 5183.69 5969731.45 555480.74 12.00 949.09 258.91 MWD 11150.00 88,76 20.78 6426. 35 72.84 5193.15 5969754.64 555490.04 12.00 973.51 259.02 MWD 11175.00 88,19 17.83 6427. 02 96.42 5201.41 5969778.27 555498.14 12.00 998.17 259.07 M1ND 11200.00 87,63 14.88 6427. 93 120.39 5208.45 5969802.29 555505.02 12.00 1023.00 259.15 MWD 11225.00 87.07 11.93 6429. 09 144.68 5214.24 5969826.61 555510.64 12.00 1047.92 259.26 MWD 11240.23 86.74 10.13 6429. 91 159.60 5217.15 5969841.56 555513.45 12.00 1063.13 259.39 MWD 11250.00 86.53 11.29 6430. 48 169.19 5218.96 5969851.15 555515.20 12.00 1072.88 100.00 MWD 17275.00 86.02 14.25 6432. 11 193.52 5224.47 5969875.51 555520.55 12.00 1097.80 99.93 MWD 11300.00 85.52 17.22 6433. 95 217.51 5231.23 5969899.55 555527.15 12.00 1122.60 99.74 MWD 11325.00 85.03 20.19 6436. 01 241.11 523922 5969923.20 555534.98 12.00 1147.23 99.52 MWD 11350.00 84.55 23.16 6438. 28 264.24 5248.41 5969946.39 555544.01 12.00 1171.60 99.28 MWD 11375.00 84.09 26.14 6440. 76 286.85 5258.79 5969969.07 555554.23 12.00 1195.67 99.01 MWD 11380.23 83.99 26.76 6441. 30 291.50 5261.10 5969973.74 555556.52 12.00 1200.66 98.71 MWD 11400.00 84.53 24.44 6443. 28 309.25 5269.60 5969991.53 555564.90 12.00 1219.60 283.00 MWD 11425.00 85.23 21.51 6445. 51 332.17 5279.32 5970014.52 555574.46 12.00 1243.87 283.23 MWD 11450.00 85.93 18.58 6447. 44 355.58 5287.86 5970037.98 555582.85 12.00 1268.41 283.49 MWD 11460.23 86.22 17.39 6448. 14 365.29 5291.01 5970047.71 555585.93 12.00 1278.51 283.72 MWD 11475.00 86.53 19.14 6449. 07 379.28 5295.63 5970061.74 555590.46 12.00 1293.10 80.00 MWD 11500.00 87.06 22.10 6450. 47 402.64 5304.42 5970085.15 555599.09 12.00 1317.63 79.89 MWD 11525.00 87.60 25.05 6451. 63 425.53 5314.41 5970108.10 555608.92 12.00 1341.90 79.72 MWD 11550.00 88.15 28.00 6452. 56 447.88 5325.56 5970130.53 555619.93 12.00 1365.85 79.59 MWD , 11570.00 88.59 30.36 6453. 12 ~ 465.33 5335.31 5970148.04 555629.55 12.00 1384.73 79.48 2.375" ~ • ~ a &I i~t S ' O{~ / ~3 = =1 i 8 °R~ + ~ j"g3 ~~! :i c? °z ~ ~~~~~s J saaaa~ a .o ~ ~ i ~~~a~~~~ a avas_ j ~ _ - saseassa I ~.,- aa~~3~ r.... ~ ~ 2~1 ~ n~ ~; o ! ~p~:z~~~ iaE - Y ~ R d R$ ~"a e ' m~gw- ~ s a83 S ?a:~aa=a=aaa a xi ; a ?; ~ g ° ~ Ya ~g ~ ~ ~~ ~ ~ ~ ~ F: ^ 4 ':x =A~; Q ~ ~ ~ $ ~ e ~ ~ a s Q ~~ ~ i ~A .x.;ASt~~ :RA ~ ._3 a ~ ~ ~r ~~ ~~ ~ d e `o~£~ ¢ 3~~Sy ~ ~ x~~~= RSi ~S •,.i~~p~:p~,i. i S~~i7~i~7~7~ ~ i F~ ~ j ~9~=, ~'R3 :.^.CC.ili:t.t j aeiedA:dede! ~ ~ ! i~ ~t{e;~tqq xe:ci:i:ids~ :cttaxt^^^^^{^t ~t~3'~~ s ~ ~ Si6i ~ _ .........Fi. ~ ~~{ i~ 1'•'a ,1~, '41 iif' ~~ I~,.: f+ I ~ ~ __{-ii ~i~: t~ ~ ~ t ~ ..~1 *i' {if~ ~~i~ ~ f 1 F ~ ti } I I I { ~ ; t ~f+l . { ~~~; i~ a i t, !~a ~, Yi *T '+i;_ ~ ~ ~t ~~4'~~~ ~f ;~ft ~_}~± (ii',.,F}t_ti~i ~uV40f~ qdM I :~M~A ~~+1 ~9~f r~ ~ li~ ~ I I~ ~ i__ ~g f i ~ :~ .... ~.. ~ ~ ~ ~ i !I ~ ~~ , r - ~~ i. : #~ , ~ ° ^ i ~i~~~ {!~a~~~li i I ~ ~~ :; . ~ , ~ 8 :~ i ~" ' ~ ~' ~~~~ ~rr1 ~I1 fYt~ ~ ~. ~ ~ { ~ -} ~ ' _ ,.~ { ~ ~ ~ ~~~ t~~ ~ ,,,,1 ~~ :... ,~ . ,~ . ,; ;, ~ , ~ ... .. . ,. . ~ . .. :~ ~ ~ - j ~ a I ~i`( -E ~ ~. ~ ~. ~~~~ -' ~i ~I . ..a . ~ r ~~~ l ~ ~ ~~ :. . ~ ~ ! - . , a ] .~ ;~.~ .'.~.. . . .. . ~ . ~ ~ Kuparuk CTD BOP Configuration for Managed Pressure ~rilling 2" CT Well 1 B-08A Rig Ftoor ~ _. ~ ~~ ~ ~ 3" 5000 psi i~ ~ ~ ~ HCR Choke Line ~ C ~ ~ ~ --~ Tree Size 4-1/16", 5M KB Elevation -~ ( Lubricator €D = 5.375" with 6" Otis Unions 7 1(16" 5000 psi BOP's. iD = 7,06" 7 1/16" 5000 psi, RX-46 ~-- t/4 Tum LT Valve 7 1/16" 5000 psi RX-46 ~ HCR Kill Line t I ~ 2 ~€/16" 5000 psi , RX-24 ~ 7 1/16" 5000 psi (RX-46) or f- 4 1l16" 5000 psi (RX-39) Swab Valve SSV Master Valve Base F1an e Page 1 1 B-08A L 1-O l Change to Perm~o Drill Maunder, Thomas E (DOA) From: Maunder, Thnmas E (DOA) Sent: Friday, July 13, 2007 2:50 PM To: 'Gantt, Lamar L' Subject: RE: 1 B-08A L1-01 Change to Permit to Drill . Page 1 ~~ [` ~~. ~ ---~ a o~ - o~ c~ 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 [maiito:lamar.ganttCa~bp.com] Sent: Friday, July 13, 2007 2:22 PM To: Maunder, Thomas E (DOA) Cc: Eller, ) Gary; NSU, ADW ~rlg Nordic 2 Supervisor; Venhaus, Dan E; Hubble, Terrie L; McMulien, ]ohn C; GANTTLL@bp.com; laird.d.little@conocophillips.com Subject: 1B-08A L1-01 Change to Perrnit to Driil Tom As per our phone discussion today, this e-mail is to document a proposed change to the Permit to Drill for the Kuparuk 16-08A L1-01 lateral> Current operations on the 1 B-086L1 tateral with the Nordic 2 CTD rig are we have reached TD and have encountered an interval at roughly 11250' MD that appears very "soft". This is likely due to a fault zone that is mapped at this locatian. The formation drilts with minimat weight on bit and we have been holding back to prevent excessive ROPS through this zone. We have decided to TD this lateeal at 11500' MD and rur~ a[iner as proposed in the permit for this lateral. The lower lateral, 1 B-Q8 AL1-01, was originalty proposed to drill generally in the same direction at a tower subs+~a efevation. Based on the resu{fs ot the upper 1 B-08A11 lateral described above, we now propose to alter the trajectory of the seeond lateral 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 fiom the original permitted TD by more than 500 ft tatera(ly. Given that it is late on a Friday aftemoon, we will not complete pfanning a new trajectory un#il after close of business hours today, but witf likely be ready to t~gin drilling the L~f-01 lateral before Monday moming. As you requested, this correspondence is to document the ptan we verbaliy discussed this afternoon, Friday, July 13, 2007 so we can proceed on through the weekend. We wifl follow up with a written revision to the permit to dri41 for the 1B-~8 AL1-01 on Monday, Juty 16, 2007. Lamar L. Gantt CTD Engineer - ConocoPhillips Alaska, Inc. Office: 907-564-5593 Cell: 907-240-8045 '7/13/2007 1 B-08AL 1 Gary and Lamar, I am in today reviewing the application for 1B-08AL1 and a statement at the end of the procedure that advises not operation with out an approved 10-403 or 10-407. The wel and after adding the lateral and spoke, the "unit" will r the sidetrack is in zone, the cement job on the 4-1/2" li integrity. Do you feel another approval is needed? Thanks. Tom Maunder, PE AOGCC L1-O1. I am to place the 1 currently i emain an inje ner will stil curious about well in s an injector ctor. Since 1 provide 1 of 1 6/10/2007 2:08 PM ~ ~ ~ i TRANSMITTAL LETTER CHECKLIST WELL NAME ~ T~-~ SS I~+ ~...~5 - C71 CT~J'~~_c= c~~ PTD# a~~ - v~ ~ Development ~f Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ~ 1~- O~ A ~ ~ (If last two digits in API number are permit No. , API No. 50- - - Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(fl, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after ~,Com.pany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCom~anv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. 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O ~~ ~. f6 O. ~ ~ os a~' ~' ~ O~ N~ 7 U1~ p. fl. c t~ ~~ N~ U i ' p O' d d~ - ~ ~ i Q m ~~ ~ ~ ~ ~ U~ ~6 ~ ~ N, 3 -°~ V1, O~ ~ p '~ ~~ v d u, m c a 0, E, m ~ a o, a m 3 f0 ~. u~ c° !~ m . ~. c c v ' c°' o co m m c' ~~' ~' ~~e , >, ° y~' '~ ~ a~ m a' 2 ~' ~~ ° o y, ~ a •N, ' a ~ o~ O ii U . ~, ~; Q ~, -a ~ a~ c~ •~' " '~ a n, .n , -a', ~, ~° °' ' ~ , N, •~ m ~ > .ot ~ ' N' °' t, ~ a` °: ~ y, ° ' c ' ' c i ° c ~, v' ~; w ~, ~ ~' ~°' ~' ~' 0 ~, ~ ~ m ~, .o ~, ~ o .c~ c c, ~ a~ ~, 3' , c c ~~' v a o m~ ~, `~; c° f6 ~ o 'o o~n _ 3 ~ _, , , ~ ~ ~, ~ o ~ m, c a> c o u~ co m z ~, ~ c ~ m m ~; o, o, m, m o, a~i m~ ~, ~ ~° ~ °, E ~ m o~' o~ ' , ~? ~, m, o o-~ m 3' •-, ~?, v m, r~ ui °s ~' = c ~ •; ~•~ c~ m, ~~' g; v ~ c ~ o 0 U ' ai ~' N ~, a- - , 8'~ m, - a> ` m, . ` ~ . ~, Q a~, - 3 I p: o c ~ a>> c 3 c, 't ~~~' °~ ~~ a~, °f W, W~ ?'~ o a o °~ ~' ~6 L ~~ • °- ~ ~ ~, m ° m, c ~? o c~ >, ~, a~ a c, a~ a~ ~' ~' ~ a > a~ 7 v' Q cn ~-; O ~' a ~, a~ a O ~ a' c m U , ~' ~ ~' ¢ ~' o; j va a i o~~' ~' ~' m v ' ' i ' ' ' ' - , i~ a ~ v~~~ O O~ - = ' ' ' ' c i °°- a~ ~' N' ~' . , : m, m, ~, ~ o i O, p N ~ c , -r, , , , , , , ; ; , , ; o. z , v c~ U U c~ U ¢ , c] ¢; m m U , a cn v , U, ~ ~ n ~ ~ ~ N M'cl' ~ CO i~ 00 m O __ N _ ~ M V tf') ~ ~ CO I~ 00 ~ O (V M~ N N N N N ef) CO f~ t0 ~ O N N N N N M M N M V M M M ~fl f~ I~ OD M M M M Q7 M V o _ _ __ _ - __ - O O p C d ~ o N d o ~ N m o ~ N ~ ~ U ~ C~O y Q OO ~ 0 W 0 OO O'y N fn ~ ~ ~ ~ ~ ` ~ ~ ~ ~~ ~ N y ~ N ,.~ ~ ~ ~ a 0 ~ a~ vK ~ c,~ U a Q a c~n W Q~~~L ( j Q uLLi Lamar Gantt CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool; ConocoPhillips Alaska, Inc. Permit No: 207-076 Surface Location: 501' FNL, 141' FEL, SEC. Bottomhole Location: 584' FNL, 3444' FWL, Dear Mr. Gantt: 1 B-08AL 1-O 1 09, T 11 N, R 10E, UM SEC. 10, T11N, R10E, UM 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 in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable prcvision of AS 31.05, Title 20, Chapter 25 of the Alaska Admir~istrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspec~ at (907) 659-3607 (pager). DATED this ~ day of June, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. r STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM~ON PERMIT TO DRILL ~~~ 20 AAC 25.005 1 a. Type of work , ^ Drill ~ Redrili ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ~ Service ~ ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify ~19~'i ~~b}~ . ^ Coaibed Methane ~~81'18~ates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 59-52-180 r 11. Well Name and Number: 1 B-08AL1-01 ~ 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 11900 ' ND 6413ss 92. Field / Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: 501' FNL 141' FEL SEC T11 N R10E 09 UM ~ 7. Property Designation: ADL 025648; OTS(o~ River Pool , , , . , , Top of Productive Horizon: 1373' FNL, 237' FW~, SEC. 11, T11N, R10E, UM 8. Land Use Permit: b,~.o~ 13. Approximate Spud Date: June 5, 2007 Total Depth: 584' FNL, 3444' FWL, SEC. 10, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 15,875' 4b. Location of Well (State Base Plane Coordinates): Surface: x-550298 a y-5969648 6 Zone-ASP4 10. KB Elevation (Height above GL): 93 feet ~ 5. Distance to Nearest Well Within Pooe 1,000' 16. Deviated Wells: Kickoff Depth: 10225 ' feet Maximum Ho~e An le: 94 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3471 SurFace: 2825 18' Gasin Pr ram: S ificatio ns To = Settin ` th - Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 3" 2-3/8" 4.6# L-80 STL 1675' 10225' 6402' 11900' 6413' Uncemented Slotted Liner 1'9. PRESE NT WELL CONDITION SUMAAARY (To be completed for Redrill and Re-entry Qperations) Total Depth MD (ft): 9710 Total Depth TVD (ft): Plugs (measured): 6660 None Effective Depth MD (ft): 9611 Effective Depth TVD (ft): 6614 Junk (measured): None Casing, Length Size Cement Volume MD ND 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' 5025' Produ tion Liner 3588' 4-1/2" 496 sx Class 'G' 6120' - 9708' 4846' - 6659' Liner 1 B-08AL1 1200' 3-3116" 15 sx Class 'G' 9100' - 10300' 6288' - 6402' Liner 1 B-08A11 1 10' 2-3/8" Uncemented Slotted Liner 9Q290' - 11 00' 6402' - 6337' Perforation Depth MD (ft): 9270' - 9402' (1 B-08A) 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 Name Lamar Gantt for Gary Eller Title CT Drilling Engineer Gary Eller, 263-4172 Prepared By Name/Number: Si nature (,~/~Yit~i"~ ~ i~R C~~ ~ Phone 263-4172 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill / Number: ~-v ~~75~ API Number: 50-029-20635-61-00 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: ~ -~S-M ~, ~~ ~, Samples Req'd: ^ es L-SNo Mud Log Req'd: ^ Yes L~'No ``~'~ ~ ~~ ~ M ~ ~ HZS Measures: ~es ' ctional Survey Req'd: [i~'Yes ^ No Other: ~Qce.cT~~'tp'~S't,~CaC~SJ~ ~ 1 ~\l~, ~ APPROVED BY THE COMMISSION Date ~~~/` , COMMISSIONER ~~~EIVED ~~aY 3 1 2007 'n Form 10-401 Revised 12l2005 ~~~~~~ A L Submit In Dupticate ,,~_ G . ~! . c ~ KRU 1 B~A L1 ~ L1-01 Sidetrack Laterals• iled Tubin Drillin 9 J Summary of Operations: 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 C1 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' 23/8" slotted liner to a TD of 11,300' MD. The L1-O1 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/g" slotted liner to a TD of 11,900' MD. Only the L1 lateral will remain accessible through-tubing. CTD Drill and Complete 1B-08A pro~ram: 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'/z" liner. 7. Set 4%2" monobore flow-through whipstock on e-line at 9265' MD at an orientation of 20° left of highside Rig Work 1. MIRU Nordic Rig #2 using 23/8" coil tubing. NiJ 7-1/16" BOPE, test. 2. Mi113.74" window and 10' of open hole at 9265' MD. 3. 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. 4. Run a 3-3/16" solid liner from TD up into the 4%z" liner at 9100' MD. 5. Swap reel to 2" e-free coil tubing and 23/g" BHA. Change pipe rams, retest BOPE. 6. Pump a 3 to 4 bbl "puddle" cement job around the 3-3/16" liner. 7. Swap reel to 2" e-coil tubing. 8. Drill out the 3-3/16" float and shoe and 20' of new formation. 9. 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. I0. Com lete the Ll lateral with 23/g" slotted liner fr - "' ' 11. 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. 12. Mill a 2.74" window in the 3-3/16" liner plus 10' of open hole at 10,225' MD. ~ 13. 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 L1-O1 lateral with 23/s" slotted liner with the top of the 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. 16. 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-RiE Work 1. Obtain static BHP " 2. MIIZU CTU. Lift well with nitrogen for temporary flowback to tanks. 3. Install inj ection valve in DB nipple at S 1 T 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 KRU 1B-~A L1 & L1-01 Sidetrack Laterals - Coiled Tubin Drillin g g 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/g" 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, TC-II solid liner from 9100' 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-O1: 23/8", 4.6#, L-80, STL slotted liner from 10,225' MD to 11,900' MD ~ Existing Casing/Liner Information Surface: 103/", K-55, 45.5 ppf Burst 3580 psi; Collapse 2090 psi. Production: 7", K-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Liner: 4%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 23/8" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum 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 • 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 HZS monitoring equipment will 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-08A L1 & L1-01 Sidetrack Laterals - Coiled Tubin Drillin 9 g 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 3'h" 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 1 B-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 3%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 T' 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 hole 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 2'/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 ` J ~ ConocoPhillips Alaska, Inc. 1 B-08A API: 50029206: SSSV T e: NIPPLE Annular Fluid: VALVE Reference Lo : (517-518, Last Ta : 9479' RKB OD:3.810) Last Ta Date: 6/28/2006 NiP~S»-5~a, Casing String - ALL OD:4.500) ~- _ SLEEVE-C (6049-6050, OD:4.500) P R ac i v- a~vo oyoa - B (6095-6096, OD 4 500 9306 - 9306 6475 - : . ) g306 - 9310 6475 - 9310 - 9310 6477 - 9314 - 9314 6479 - 9318 - 9318 6481 - 9322-9322 6483- ANCHOR _ _ = 9326 - 9326 6485 - (6109-6110, - _ ' 9340 - 9350 6491 - OD:4.500) 9360 - 9380 6500 - A399 - 94(19 fi514 - SEAL (6123-6124, OD:4.500) TUBING (0-6135, OD:4.50Q ID:3.953) NIP (9173-9174, OD:3.828) Perf (9270-9310) Perf (9306-9306) Perf (9318-9318) Perf (9340-9350) Perf (9360-9380) 1 ~ KRU 1 B-08A 4 12/7/1997 5 12/7/1997 4 12/7/1997 Jet Perf (9392-9402) - bP ~ BP Alaska ~ ~ Baker Hu hes INTE Plannin Re ort g Q g P s~ tr ~~s INTEQ Company: BP Amoco Datr. 5/25/2007 Time: i4:27:11 Page: 1 Field: Kuparuk Co-ordinate(NE)Reference: Well: 08, True North ' Site: KRU 1 B Pad Vertieal (TVD) Refereace: RKB Elev 1 93A Well: 08 Section (VS) Refereoce: Well (O.OON,O.OOE,280. OOAzi) Weltpath: Plan 4, 1 B-08A11-01 Survey Calculation Method: Minimum Gurvature , Db: Orade Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866j 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 ~Torthing: 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 4, 16-08AL1-01 Drilled From: Plan 3, 16-08AL1 Tie-on Depth: 10225.00 ft Current Datum: RKB Elev 1 Height 93. 00 ft Above System Datum: Mean Sea Level blagneNc Data: 5/25/2007 Declination: 23.50 deg Field Strength: 57624 nT Mag Dip Angle: 80.86 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 93.00 0.00 0.00 280.00 Plan: Plan #4 Date Composed: 5/25/2007 Copy lamar's Plan 4 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ---> <--- Longitude ---> Name DescripNon 1'VD +N/-S +E/-W Nort6ing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1B-08A~1/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 32.845 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 t2 93.00 481.34 4730.79 5970160.00 555025.00 70 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 -Polygon18 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 16-08AL1/AL1-01 Fault 2 93.00 -101.82 4296.83 5969574.00 554595.00 70 19 39.224 N 149 33 26.081 W -Polygon 1 93.00 -101.82 4296.83 5969574.00 554595.00 70 19 39.224 N 149 33 26.081 W -Polygon 2 93.00 -242.11 4337.90 5969434.00 554637.00 70 19 37.844 N 149 33 24,885 W -Polygon 3 93.00 -510.28 4209.08 5969165.00 554510.00 70 19 35.207 N 149 33 28.650 W -Polygon 4 93.00 -242.11 4337.90 5969434.00 554637.00 70 19 37.844 N 149 33 24.885 W bp ~ BP Alaska ~ ~ Baker Hu hes INTE Plannin Re ort g Q g P ~~~ sN~u~s iNTEQ Company: BP Amoco Date: 5/25/2007 Timr. 14:27:1 ? Psge: 2 Field: Kuparuk Co-ordinate(NE) Reference: ` We1t: 08; True North Site: KRU 1 B Pad Vertical (TVD} Reference: RKB Elev 1 93A We1L• 08 Sectioo (VS) Reference: Well (O.OON,O. OOE,280.OOAzi) Wellpath: Plan 4, 1B-08AL1-01 Survey Cateulation Met6od: Minimum Gurvature Db: Oracle Annotation MI) 'I'VD ft ft 10225.00 6495.10 Tie to 1 B-08A Plan 3 10245.00 6494.79 End of 9 Deg/100' DLS 10275.00 6493.03 3 10339.00 6491.83 4 10559.00 6502.67 5 10729.00 6510.76 6 10829.00 6513.05 7 11079.00 6505.25 8 11314.00 6491.49 9 11464.00 6483.57 10 11564.00 6481.01 11 11664.00 6485.45 12 11764.00 6494.20 13 11900.00 6505.76 TD Plan SecNon Information MD Incl Azim 1'VD +N/-g +E/-W DLS Bui1d Turn TFO Target ft deg deg ft ft ft deg/100ft deglt00ft deg/100ft deg 10225.00 90.00 275.53 6495.10 -484.16 5190.99 0.00 0.00 0.00 0.00 10245.00 91.80 275.53 6494.79 -482.24 5171.09 9.00 9.00 0.00 0.00 10275.00 94.92 273.72 6493.03 -479.82 5141.24 12.00 10.39 -6.02 330.00 10339.00 87.24 273.72 6491.83 -475.67 5077.44 12.00 -12.00 0.00 180.00 10559.00 87.21 300.15 6502.67 -412.23 4869.09 12.00 -0.01 12.01 90.70 10729.00 87.39 279.73 6510.76 -354.62 4710.31 12.00 0.10 -12.01 270.00 10829.00 90.00 268.01 6513.05 -347.89 4610.75 12.00 2.61 -11.72 282.40 11079.00 93.49 297.83 6505.25 -292.71 4369.96 12.00 1.40 11.93 83.00 11314.00 93.08 269.58 6491.49 -237.69 4144.34 12.00 -0.18 -12.02 270.00 11464.00 92.93 287.61 6483.57 -215.40 3996.84 12.00 -0.10 12.02 90.00 11564.00 89.99 299.25 6481.01 -175.72 3905.29 12.00 -2.94 11.64 104.00 11664.00 84.94 288.34 6485.45 -135.46 3814.05 12.00 -5.04 -10.90 245.00 11764.00 85.06 276.30 6494.20 -114.25 3716.91 12.00 0.11 -12.05 270.00 11900.00 85.26 292.68 6505.76 -80.46 3586.16 12.00 0.15 12.04 90.00 Survey MD Incl Azim SS T'VD N/S E/W MapN MapE DI.S VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg - 10225.00 90.00 275.53 6402.10 -484.16 5190.99 5969197.69 555491.62 0.00 -5196.20 0.00 MWD 10245.00 91.80 275.53 6401.79 -482.24 5171.09 5969199.48 555471.70 9.00 -5176.27 0.00 MWD 10250.00 92.32 275.23 6401.61 -481.77 5166.11 5969199.92 555466.73 12.00 -5171.29 330.00 MWD 10275.00 94.92 273.72 6400.03 -479.82 5141.24 5969201.70 555441.85 12.00 -5146.46 329.99 MWD 10300.00 91.92 273.72 6398.54 -478.20 5116.34 5969203.15 555416.94 12.00 -5121.65 180.00 MWD 10325.00 88.92 273.72 6398.36 -476.58 5091.40 5969204.60 555391.99 12.00 -5096.81 180.00 MWD 10339.00 87.24 273.72 6398.83 -475.67 5077.44 5969205.42 555378.02 12.00 -5082.90 180.00 MWD 10350.00 87.22 275.04 6399.36 -474.83 5066.48 5969206.18 555367.06 12.00 -5071.97 90.70 MWD 10375.00 87.19 278.05 6400.58 -471.99 5041.68 5969208.86 555342.24 12.00 -5047.04 90.64 MV11D 10400.00 87.17 281.05 6401.81 -467.85 5017.06 5969212.84 555317.59 12.00 -5022.08 90.49 MWD 10425.00 87.16 284.05 6403.05 -462.42 4992.69 5969218.10 555293.19 12.00 -4997.14 90.34 MWD 10450.00 87.15 287.06 6404.29 -455.73 4968.64 5969224.63 555269.10 12.00 -4972.29 90.19 MWD 10475.00 87.15 290.06 6405.53 -447.78 4944.97 5969232.42 555245.38 12.00 -4947.60 90.04 MWD 10500.00 87.16 293.06 6406.77 -438.61 4921.75 5969241.44 555222.10 12.00 -4923.14 89.89 MWD 10525.00 87.18 296.07 6408.01 -428.23 4899.04 5969251.66 555199.33 12.00 -4898.97 89.75 MVVD 10550.00 87.20 299.07 6409.24 -416.67 4876.91 5969263.07 555177.12 12.00 -4875.17 89.60 MWD 10559.00 87.21 300.15 6409.67 -412.23 4869.09 5969267.46 555169.28 12.00 -4866.70 89.45 MWD 10575.00 87.22 298.23 6410.45 -404.44 4855.14 5969275.16 555155.27 12.00 -4851.61 270.00 MWD 10600.00 87.22 295.23 6411.66 -393.21 4832.84 5969286.24 555132.90 12.00 -4827.70 270.09 MWD 10625.00 87.24 292.22 6412.87 -383.16 4809.99 5969296.13 555109.98 12.00 -4803.45 270.24 MWD 10650.00 87.26 289.22 6414.07 -374.33 4786.63 5969304.81 555086.57 12.00 -4778.91 270.38 MWD 10675.00 87.30 286.22 6415.26 -366.73 4762.85 5969312.24 555062.74 12.00 -4754.17 270.53 N-WD - bp ~ BP Alaska ~ s~~ ~ Baker Hu hes INTE Plannin Re ort g Q g P INTEQ Comp~ny: BP Amoco D~te: 5f25/2007 Time: 14:27:11 Page: 3 Field: Kuparuk Co-ord inate(NE) Reference: WeIG 08, True North Site: KR U YB Pad Verticai (TVD) Reference: RKB Elev 1 93.0 Well: 08 SecNon (VS) Reference: Well (O.OON,O. OOE,280.OOAzi) Weilpath: Pla n 4, 1 B-08AL1-01 Survey Caiculation Method: Minimum Curvature Db: Orade Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10700.00 87.33 283.21 6416.43 -360.38 4738.70 5969318.42 555038.55 12.00 -4729.29 270.67 MWD 10725.00 87.38 280.21 6417.58 -355.32 4714.25 5969323.33 555014.06 12.00 -4704.33 270.81 MWD 10729.00 87.39 279.73 6417.76 -354.62 4710.31 5969323.99 555010.12 12.00 -4700.33 270.95 MWD 10750.00 87.93 277.27 6418.62 -351.52 4689.56 5969326.95 554989.36 12.00 -4679.36 282.40 MWD 10775.00 88.58 274.34 6419.38 -349.00 4664.70 5969329.31 554964.48 12.00 -4654.44 282.50 MWD 10800.00 89.24 271.41 6419.86 -347.74 4639.74 5969330.40 554939.52 12.00 -4629.64 282.59 MWD 10825.00 89.90 268.48 6420.05 -347.77 4614.75 5969330.21 554914.52 12.00 -4605.03 282.65 MWD 10829.00 90.00 268.01 6420.05 -347.89 4610.75 5969330.06 554910.53 12.00 -4601.11 282.67 MWD 10850.00 90.31 270.52 6419.99 -348.16 4589.75 5969329.65 554889.54 12.00 -4580.48 83.00 MUVD 10875.00 90.67 273.49 6419.78 -347.29 4564.77 5969330.36 554864.55 12.00 -4555.73 83.01 MWD 10900.00 91.04 276.47 6419.41 345.11 4539.87 5969332.36 554839.64 12.00 -4530.83 83.03 MWD 10925.00 91.40 279.45 6418.87 -341.65 4515.12 5969335.65 554814.87 12.00 -4505.85 83.08 MWD 10950.00 91.75 282.43 6418.19 -336.91 4490.59 5969340.23 554790.31 12.00 -4480.87 83.14 MWD 10975.00 92.10 285.41 6417.35 -330.90 4466.34 5969346.08 554766.02 12.00 -4455.94 83.22 MWD 11000.00 92.45 288.39 6416.35 -323.64 4442.44 5969353.18 554742.08 12.00 -4431.15 83.32 MWD 11025.00 92.79 291.38 6415.21 -315.15 4418.96 5969361.51 554718.54 12.00 -4406.55 83.44 MWD 11050.00 93.12 294.36 6413.92 305.44 4395.95 5969371.06 554695.48 12.00 -4382.21 83.58 MWD 11075.00 93.44 297.35 6412.49 -294.56 4373.50 5969381.79 554672.95 12.00 -4358.20 83.73 MWD 11079.00 93.49 297.83 6412.25 -292.71 4369.96 5969383.62 554669.40 12.00 -4354.40 83.90 MWD 11100.00 93.49 295.30 6410.97 -283.34 4351.21 5969392.87 554650.59 12.00 -4334.31 270.00 MWD 11125.00 93.48 292.30 6409.45 -273.27 4328.38 5969402.78 554627.70 12.00 -4310.08 269.85 MWD 11150.00 93.46 289.29 6407.93 -264.41 4305.06 5969411.48 554604.31 12.00 -4285.57 269.66 MWD 11175.00 93.42 286.29 6406.43 -256.78 4281.30 5969418.95 554580.51 12.00 -4260.85 269.48 MWD 11200.00 93.38 283.28 6404.95 -250.42 4257.17 5969425.15 554556.34 12.00 -4235.98 269.30 MWD 11225.00 93.33 280.28 6403.48 -245.32 4232.74 5969430.08 554531.88 12.00 -4211.04 269.12 MWD 11250.OQ 93.27 277.27 6402.04 -241.51 4208.08 5969433.72 554507.20 12.00 -4186.09 268.95 MWD 11275.00 93.20 274.27 6400.63 -239.00 4183.25 5969436.07 554482.35 12.00 -4161.20 268.77 MWD 11300.00 93.13 271.27 6399.25 -237.80 4158.32 5969437.10 554457.42 12.00 -4136.44 268.60 MWD 11314.00 93.08 269.58 6398.49 -237.69 4144.34 5969437.11 554443.44 12.00 -4122.65 268.44 MWD 11325.00 93.08 270.91 6397.90 -237.65 4133.36 5969437.09 554432.46 12.00 -4111.83 90.00 MWD 11350.00 93.07 273.91 6396.56 -236.60 4108.42 5969437.97 554407.51 12.00 -4087.09 90.07 MWD 11375.00 93.05 276.91 6395.22 -234.24 4083.57 5969440.16 554382.65 12.00 -4062.21 90.23 MWD 11400.00 93.03 279.92 6393.90 -230.59 4058.87 5969443.65 554357.93 12.00 -4037.25 90.39 MWD 11425.00 93.00 282.92 6392.58 -225.65 4034.41 5969448.42 554333.44 12.00 -4012.30 90.55 MWD 11450.00 92.96 285.93 6391.28 -219.43 4010.23 5969454.48 554309.22 12.00 3987.41 90.71 MWD 1! 464.00 92.93 287.61 6390.57 -215.40 3996.84 5969458.42 554295.81 12.00 -3973.53 90.87 MWD 11475.00 92.61 288.89 6390.03 -211.95 3986.41 5969461.79 554285.35 12.00 -3962.65 104.Q0 MVVD 11500.00 91.88 291.80 6389.06 -203.27 3962.99 5969470.32 554261.88 12.00 -3938.08 104.06 MWD 11525.00 91.14 294.71 6388.40 -193.40 3940.03 5969480.03 554238.86 12.00 -3913.76 104.18 MWD 11550.00 90.40 297.62 6388.06 -182.38 3917.60 5969490.90 554216.35 12.00 -3889.75 104.25 MWD 11564.00 89.99 299.25 6388.01 -175.72 3905.29 5969497.48 554204.00 12.00 -3876.47 104.29 MWD 11575.00 89.43 298.05 6388.07 -170.44 3895.63 5969502.69 554194.31 12.00 -3866.05 245.00 MWD 11600.00 88.16 295.33 6388.60 -159.22 3873.31 5969513.77 554171.91 12.00 -3842.11 245.01 MWD 11625.00 86.90 292.61 6389.67 -149.07 3850.49 5969523.76 554149.02 12.00 -3817.87 245.06 MWD 11650.00 85.64 289.88 6391.30 -140.03 3827.24 5969532.64 554125.72 12.00 3793.41 245.18 MWD 11664.00 84.94 288.34 6392.45 -135.46 3814.05 5969537.12 554112.50 12.00 -3779.63 245.36 MWD 11675.00 84.95 287.02 6393.42 -132.14 3803.61 5969540.38 554102.04 12.00 -3768.77 270.00 MWD 11700.00 84.96 284.01 6395.62 -125.48 3779.62 5969546.87 554078.01 12.00 -3743.99 270.12 MWD 11725.00 84.99 280.99 6397.81 -120.09 3755.31 5969552.10 554053.67 12.00 -3719.11 270.38 MWD 11750.00 85.03 277.98 6399.99 -115.98 3730.75 5969556.04 554029.08 12.00 -3694.21 270.65 MWD 11764.00 85.06 276.30 6401.20 -114.25 3716.91 5969557.68 554015.23 12.00 -3680.28 270.91 MWD 11775.00 85.06 277.62 6402.14 -112.92 3706.03 5969558.94 554004.34 12.00 -3669.34 90.00 MWD 11800.00 85.07 280.63 6404.30 -108.97 3681.44 5969562.72 553979.73 12.00 -3644.44 89.89 MWD , bp ~ BP Alaska ~ ~ Baker Hu hes INTE Plannin Re ort g Q g P ~a~ sn~cN~s~~ INTEQ Company: BP Amoco : Date: 5/25/2007 Time: 14:27:11 Page: 4 Field: Kuparuk Co-ordinate(NE) Reference: Well: O8, True North' Sitec KRU 16 Pad Vertical (1'VD) Reference: RKB Elev 1 93A We1L• 08 Section (VS) Reference: Well (O.OON,O.OOE,280.OOAzi) Wellpath: Plan 4, 1B-08AL1-01 Survey C~Iculation Method: Minimum Curvature Db: Oracle Survey MD Inci Azim SS 1'VD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11825.00 85.10 283.64 6406.44 -103.73 3657.09 5969567.79 553955.35 12.00 -3619.55 89.63 MWD 11850.00 85.14 286.66 6408.57 -97.22 3633.05 5969574.14 553931.27 12.00 -3594.74 89.37 MWD 11875.00 85.19 289.67 6410.68 -89.46 3609.39 5969581.75 553907.55 12.00 -3570.09 89.11 MWD . 11900.00 85.26 292.68 6412.76 , -80.46 3586.16 5969590.58 553884.27 12.00 -3545.65 88.86 2.375" ~ ~ Kuparu~TD BOP Configuration for Managed Pressure Drilling 23/8' CT Well I 1 B-08A Floor ~ ~ ~ ~ C 3" 5000 psi 1 ~ • HCR M Choke Line ~ C ~ ~ ~ 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 ~ 1/16" 5000 psi RX-46 Kill Line t L I 2 1/16" 5000 psi , RX-24 ~--- ~4 1/16" 5000 psi (RX-39) ~ ~ Tree Size 4-1 /16", 5M Flow T Swab Valve SSV Master Valve Base Flan e Page 1 Kuparu~TD BOP Configuration for Managed Press• Drilling 2" CT Well I 1 B-08A I Rip Floor ~ ~ C ~ C 3" 5000 psi ~~ ~ ~ ~\ Choke Line ~ C ~ C ~ ~ Tree Size 4-1116", 5M ~ 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 ~ 7 1/16" 5000 psi RX-46 Kill Line t L I Combi 2 1/16" 5000 psi , RX-24 nr ~- 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 1 207-076 KRU 1 B-08AL 1-O 1 AREA OF REVIEW IS 1 - ~~ B-o3 SW-03 KRU 1 B~08AL 1-01 15 6-1 19 S~f -05 ~`~ ~ ~~-. t' ,~I B-17 18 ~ ~ P F-01 A 0 '~' ~~ l~ R 1(~~ T T l~ ~ B-12 D-1 =-~f22~3iL1 1 B-O~AL1 C- " ~~-12 '~' < .~~,: _' ~~~ ~ , _ _ ^\ _.~ `,,~„_ `~ ~o 0 ti ..~ ,~ ,~~1~°~r _ ,.~„ _ ~ 't; --i..; ~ '~~.~~ ~~~~ ~ ~~~;~1~,ti } ~ ~~~~.~,: , v ~ ~ ~~ ~ ~,~~~, ~~~~ ;~ ~~~~~; ~~~~. ~~~ ~ ~„ ~ ,~ ~~ ` -~ ~ _ ~ s ~ \\DOA-ANGAOGCC\VOLI~IIOME~,AOGCC\SFDAVIES~Daily_Document_Record~2007\070604_2070750_KRU_IB-O8AL1_Location_Map.ppt SFD 6/4/2007 C~ C~ ~"RAiYS1dIIT~'AL L,ET'~'ER C'Fi~CKLIST wEL.L N:~~tiIE ~2l.~ ~.~ "b~~~~- ~ ~ P'i'D# Z.U '"7 -- p "7~ Deve[opmeat ~ Service Ex forato iYon-Coaveatio~tat P ~"~ _._._, Stratigraphic Z'est Circ[e 4ppropriate Letter / Paragraphs to be Inciuded in Transmittal Letter ' CHECK ~ ; w'IIAT ~ APPL[ES ~ ~ i ; ADD-OiYS (OPT[ONS) NtULTI LATERA ~ ([f ta,t two digits ~ ~P[ nurnber ; between 60-69) PILOT f[OLE TEXT FOR APPROVAL LETT6R ~ ~ L ~ The perinit i; for a new we(]bore segme t of exisring ~ we(1 ,~ ~ ~.G~ ~v~ ~ in ~ Pecmit ~to. /97- //Z, ~ are ; , ~4Pi No. ~0-~'~. (,3,5" _~ ~ ; Production shoutd continue to be reported as a function of the ~ ~ originai 4P[ number stated above. i tn accocdance with 20 A.~C 2i.0U~ ~~ ; acquired far the pilot hole must be c~tear(y differentia d~n both ~ ; wet! name ( Pf•n ar~d API number ~ ~~~~- -~, from records, data and logs ~ ~ acquired for well ! ~ SPACING ; EXC6PTION The permit is approved subject to full compliance with Zp AqC 2~ 455 ~ ! ~ . . Approva! to perforate and ocoduce / in~,~~ is contingent f I upon issuan f ; ~ ce o a conservatioa onier approving a spacing j ; exception. ' ~ ~ ~ liabi[i ofan assumes the ~ ty y protest to the spacing exception that may occur. ~ ; DRY DITCH ' ' I Alt dry ditch samp(e sets subrnitted to tt~ -E i SA!~IPLE ~ ~ e ommission must be in ; i no greater than 30' sampte intervals &om betow• the f ~ ~ ~ ' ~ + I rom where sampt~s ~ fnt caught and IO' samp e irtten;als ; ~ through target iones. r ~ , i ~ wz~i Conventio~at r i Ptease note the fo[lowing special con@ition oP thi; i producrion or productioa testin f ~ ~~~ ~ ~ g o coa! bed methane is not at w ~ lo ed ~ for (name of well) until after LCorneanv lv'aime) has designed and i ~ ( ~ ~ irriplemeated a water welf testing program to provide basetine data ; on water quality and ti ~ ~ ~ ~ quan ty. (Compa~ty IYame) must contact the ~ Commission to obtain advance approval of such water welf t i ! est ng ~ pCOqt~t I Rev: [ '2~i06 Ca jody~transmittal_checklist ~ • i~l ^ ~ y ~ ~ ~ , ~ ~ ~ ~ ~ ~ , , , ~ , . , ~ ~ ~ ~ , ~ . ~ ~ ~ ~~ ~ ~ ~ ~ ~ „ ~ ~ ~ ~ ~ pI O ~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ , , ~ ~ , ~ , ~ . ~ ~ ~ ~ C~ , ~ , , , I , ~ , ~ N fl- ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ . ~ , ~ , ~ , ~ , ~ ~ ~ ~ ~p~ ~ ~ , ~ N 0 ~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ . , ~ ~ . ~ ~ ~ , ~ ~ ~ ~~~ , ~ , , ~ ~ I ~~~ . ~ ~ ~ ~~ ~ ~ ~ , ~ , ~ ~ , ~' ' U' ~~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ , O' F ~ ~ ~ ~ , , ~ , , ~ , , , ~ , , , ~ 'C ~ ~ Q ~ ~~ ~ .a~ ~ , ~ o ~ ~ ~ ~ , ~ , , , ~ , ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ a ~ ~ , , ~ ~ ~ ~ Q a ~ ' , c ~ ~ ~ ~ ~ V~ ~ ~ ~ (O~ L ~ ~ ~ , ~~ ~~ ~ ~ ~ ~ ~ ~ ~~ ~ y ~ ~ ~ 6~ ~~ ~ ~ ~ ~ , ~ C, , ~ ~ ~ ~ N~ ~~ ~ ...~ ~. ~ ~~ ~ , ~ , , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ , ~ ~, 3: ~ ~ ~ ~ ~ a ~ , , ~ ~ ~ , , , y~ . ~~ ~ V~ f0~ ~ , p~ pp ~ V c ~ c ~ , ~ , ~ ~~ c~ , p~ ~~ ~ ~~ ~ ~ , , ~ . ~ , ~ ~ ~ , ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~~ ~ ~ cD , ~ ~ , ~ ~ ~ ~~ , 9, ~, , , ~ Z~ CI ~ ~ ~ , , , , ~ ~ ~ ~ , ~ ~ ~ ~ ~, ~ t ~ , ~ ..~., ~ ~ a~ ~ ~._, ~ _ ~ ~~ ~ , , ~ ~ , ~ ~ ~ ~ , ~ a y 3, a ;~, -o, m o W ~ , ~ •-, o , O _, •3, , , , , , , ~, , ~ , , c co y m o ~ U m c ~ ~ , , ~ c ~ ~, , ~ ~ , ~ ~ ~, v~i ~, :a, rn ~ O oi, , o, ~, ° ' o, n ~ ~ ~ , ~ , ~ , ~ ~ ~ ~ ~ o , a m a ~ ~ ~ c ~~ ~~~ ~~, ~ ~~ ~, ~~~ ~ v ' E O 6 ~ ~ - , Z, , ~ N ~ a~~ ~ , ~ ~ ~ , ~ , ~ ~ ~ ~ , ~, °~ , ~ o ( ~ ~ NO~ ~ y~ ~ ~~~ uj~ ~ N ~ ~ , ~ ~ ~ ~ ~, , , ~ ~ ~ ~p~ ~ O~ y~ ~ ~ ~ (6~ L ~~ f6~ ~~ ~ ~- a ~ ~ c, ~~ U ~ 0 o ~ ~ a , ~ , , , , ~ ~ fl. ~c , V, ~~ ~ ~ , ~ N~ pl ~ ~ °~ O ~ Q ~ 3 , ~ , f4 ~ o~ r a ~ c ui c, . ~,Q c, ~ ii i~ ` ` ~ , ~ ~ m 3 , ~, T Y , g> ~ fl. ao ~ N ~ o ~ v ° ~ `~ N, N~ 4 ~~ , , _ ~ Q - O a ~ ~ ~ ~ ~ L N ~ C ~~ ~ ~ ~ , ~ , ' ~ ~ ~ , ~ ~ i , , , ~, ~, , , p, , ~ , , ~ V, C~ ~ ~~ ~~ ~~ ~~ ~ ~ , ~ ~ ~ ~ , , ~ ~ ~ ~ ~~ ~ m, ~ ~~ N, C~ ~ - ~~~ ry~ y~ 3~ ~ ~ Q ~~ m m o , ~ ~ N c a , , _ = m ° o~, ~ Q, c o' ~ ~ oo ' o' ~ ~ ua'i ufl'i c , ~ , ~ , ~ ,° , ~ m, ' > Q- , ~~ N , ~ ~ ~ m Vj v=~ , ' Y ~ ~ N: ~ ~ o~ ~~ _~ _, ~, , , ~ ~ , ~ .~ ~ ~ , Q~ °~ ~ ~~ ~, a~, p~. ~ cv, a, -a , ~ Q O ~ •~ . ~ o a ~ ~/1~ a~ ~, ~ , , . , ~ ~ ~ , ~ ~ ~ ~ M ~ ~ , , Z ~ ~ W~ a U , ~ ~ C ~ a v, o, ~ ~ Q , , ~ ~ m ~ , , ~ , , , <o ~3 ~~ , o. , fl, ~, _ , rn C~ ~~ o, ~ ~ c ~~ ~~ t, , ~ ~ ~ ~ ~ ~ . 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