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Home My WebLink About207-175• . Image Project Weil History File hover Page XtiVZE This page identifies Those items that were not scanned during the initial production scanning phase. They are available in the original fide, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~ ~ Well History File Identifier Qrganizing (done) ^ Two-sided III II'IIIII III II III ^ Rescan Needed I)(II'I(I II II III III RE CAN DIGITAL DATA Color Items: :~iskettes, No. ^ Greyscate Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ' ir,~--' ~~ lsl Project Proofing BY: ~ M~ ~ Date: / /,/~., ~ ~1 [~ /s/ ' ~' ~I Scanning Preparation ~_ x 30 = C C~ + ~ =TOTAL PAGES I (Count does not include cover sheet) BY: Maria ~ Date: ~ ~ /s/ .Production Scanning Stage 7 Page Count from Scanned File: ~ (Count does include cove sheet) Page Count Matches Number in Scanfning Preparation: YES ~/~ NO BY: Maria Date: 11 f r~ ls/ 1' ~~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: a , , ~.~„a IIIIIIIIIIIIIIIIIII 10/6/2005 Well History File Cover Page.doc • _,. iY µr ' W4 h y L ;~ ~y ~~ ~'.:.~ ~~ ~~„' ,~ ,, ~,,r ". ,.~~,~` ~t~:'4 ...i _'~w~ '~ MICROFILMED 6/30/2010 DO NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • STATE OF ALASKA • '`Y' ' ~ ; ~' ' f ~ ~l ~-i ALASKA OIL AND GAS CONSERVATION COMMISSION WELL~ COMP~LETlON OR R~ECOMPLETlON REPOR'~" ~-~N~C~j-~-~~ 4~`'~~~°~~'~'~~~ 1a. Wel1 Status: Oil ~ Gas Plugged ~ Abandoned Suspended ~ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development ~/ Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 1 5. Date Comp., Susp. J~ ~ orAband.: ,~24, 2009 12. Permit to Drill Number: /207-175 / 309-190 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 26, 2008 13. API Number: 50-029-21425-01 ~'' 4a. Location of Well (Govemmental Section): Surface: 1257' FNL, 1229' FEL, Sec. 14, T12N, R9E, UM 7. Date TD Reached: February 22, 2008 14. Well Name and Number: 3C-14A ,/ Top of Productive Horizon: 2542' FNL, 42' FWL, Sec. 13, T12N, R9E, UM 8. KB (ft above MSL): 88' RKB Ground (ft MSL): 47.6' AMSL 15. Field/Pool(s): Kuparuk River Field , Total Depth: 2611' FSL, 41' FWL, Sec. 13, T12N, R9E, UM 9. Plug Back Depth (MD + ND): 6789' MD / 6273' TVD Kupuruk River Oil Pooi , 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528346 y- 5995180 f Zone- 4 10. Total Depth (MD + ND): 6953' MD / 6403' ND 16. Property Designation: ADL 25634 - TPI: x- 529622 y- 5993894 Zone- 4 Total Depth: x- 529621 - 5993767 Zone- 4 ~ ~. SSSV Depth (MO + ND): SSSV @ 2026' MD / 2026' ND 17. Land Use Permit: 2567 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): approx. 1700' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE Wf. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 38' 116' 38' 116' 24" 1ss sx CS II 9.625" 36# J-55 38' 4061' 38' 3720' 12.25" 94o sx PF'E', 380 sx PF'C', 125 sx PF'C' 7" 26# J-55 38' 4150' 38' 3787' 8.5" 55o sx Class G, 20o sx PF'C' 5.5" 15.5# L-80 3924' 6616' 3617' 6116' 7" 153 sx Class G, 57 sx CI G w/GasBLOK 3.5" 9.2# L-80 6316' 6951' 5828' 6401' 4.75" 51 sx Class G 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 6341' 3924', 6335' perfs squeezed off 6789'-6803' MD 6273'-6285' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~~~Q~~ e DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED :' t°~'f ~,~a~~~~~ l~~v l ~`~w 44 6789'-6803' 8 bbls behind pipe 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) perforations plugged Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-oIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE • ~~-Y~~°' "~"~ , y .. ~~ n;~ ~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~c ~~ ~~~!~ ~~~; 7t:!'~ ?~ ai ,~%~,~~l7 l l1 ~ r~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to thisform, if Pe~maffost - Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk D 6654' 6153' Top Kuparuk C4 6731' 6222' Top Kuparuk C3 6764' 6251' Top Kuparuk C2 6778' 6263' Top Kuparuk C1 6788' 6272' Top Kuparuk B 6812' 6292' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: James Ohlinger @ 1102 ~~r Printed Name Ja er Title: CT Drillina Enqineer Si nature Phone Date ~/~~~~9 g ~`~ ~~~a INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a wetl producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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 Item 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 prodwcing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical ~aboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • 3C-14A Well Events Summary • DATE SUMMARY 6/18/09 DRIFT TBG W/ 20' X 2.73" SOLID DRIFT, NO RESRICTIONS. TAG 6800' SLM. EST 24' OF RATHOLE. APPROX. 15' HIGHER THAN TARGET DEPTH FOR WHIPSTOCK. IN PROGRESS. 6/19/09 BAILED SAND FROM 6803' SLM TO 6822' SLM (~6849' RKB). DRIFT TBG W/ 21' OF 2.73" SOLID DRIFT (DUMMY WHIPSTOCK) TO 6823' SLM (~6850' RKB}, NO RESTRICTIONS. JOB COMPLETE. 6/22/09 MEASURED P 58 6 95' RKB AND GRADIENT OF 2216# @ 6682' RKB. JOB COMPLETE 7/3/09 SET 3.5" BAKER MONOBORE RETRIEVABLE WHIPSTOCK AT 6828i CORRELATED TO PDC AND PERFORATION RECORD. 2 PIP TAGS INSTALLED IN WHIPSTOCK AT 6833.35'. WHIPSTOCK IS ORIENTED 6 DEG RIGHT OF HIGH SIDE. WEIGHT WAS SLACKED OFF ON WHIPSTOCK TO CONFIRM SET. 7/21/09 PT/DDT- MV/SV- PASSED, DDT-SSV/SSSV - PASSED (PRE-CTD) 7/21/09 TAGGED WHIPSTOCK @ EST. 6828' RKB. SET 2.75" CA-2 PLUG @ 6252' RKB WITH CATCHER @ SAME. PULLED GLV @ 5872' RKB. IN PROGRESS. 7/22/09 PULLED GLVs @ 6172', 5058', 4065' & 2543' RKB. SET DVs @ 5872', 5082', 4065' & 2543' RKB. CIRCULATED 140 BBL DSL, TAKING RETURNS TO PROD. IN PROGRESS. 7/23/09 CIRCULATE 50 BBL DSL TO PROD. SET DV @ 6172' RKB. MIT IA 2500 PSI, PASSED. PULLED CATCHER & CA-2 PLUG @ 6252' RKB. READY FOR CTU. 7/24/09 PERFORMED CEMENT SQUEEZE ON C-SAND PERFS. ESTIMATE APPROXIMATELY 8-BBL BEHIND PIPE BASED ON LOSSES OBSERVED DURING HESITATION SQUEEZE. LEFT WELL SHUT-~N AND FREEZE PROTECTED WITH 1200-PSI AT SURFACE. 7/29/09 TAG TOP OF WHIPSTOCK @ 6800' SLM. MIT TBG TO #1000. MIT PASS. JOB COMPLETE • `~~ . ~ K U P ~, ConocoPhilii s We~~ Attribute \ s p a~y~ ; ~,_ ~ WeIIGOreAPI/UWI ~Fiela Name % 500292142501 KUF'ARUN Comment H 1 ]/16I2 Y ' " 93]~N 0Ui2" SSSV.Th'DP ~ 4A ~¢.p~ QryQg ?~' _, ...'__'__ $chemetlt A s al ~ Annotation DepM(kKB) En _ I Last Tag~ SLM I 6 823.0 E Casing String Cas:ng Descrip~ion s _ I, Shing 0... CONDUCIOR ~ 16 Gasing Description String 0... SURFACE 9 5I8 Casing Dascription ~i,5tring 0... HANGER, 38 ~ _. WINDOW , 8 sssv.2.oze ~ ~- GAS LIFT. _ 2$4s SURFACE. 35-4,061 GAS LIFT, 4,066 sing Desc~iption NER 3 5" iner Details Top De~ (TVD~ >o(kK61 (kK6', 6,316.1 I 5,82f inc WINDOW. 6.150~1.163 'RODUCTION. 33<.1)8 GAS LIFT, 5 061 GAS IIFT, 5 8l3 GAS LIFf, 8,172 NIPPLE,6,254 - • ~......i 36.0 .........r...~.... 116.0 _"_'~...~.._~... 116 0 (ftKB) Set Depih (f... Sat Depth (TVOj ... 352 4 060.5 3,720 0 (ttK6) I Set Dep~h (t... Set Depth (TVD) ... ,150.0 4,163.0 3,7972 (tiKB) ISet Depth (i... Set Dapth (TVD) ... 33.0 4,178.0 I 3,808.3 (kK8) Set Depth (i... ~ Se~ Depth (TVD) ... ,924.1 6616.0 ~ 6,1159 Comment 5' X 7' LTP "CHP" G2 profile w/ 6.1' ext NCliner hanger-5.5'VampXp (4 5' Wea[heAord 403 Float Collar (RKB) ~Se~ Depth (f... ~Sel Depth (TVD)... SBE ZXP Seal Bore Extension PACKER HR ZXP Liner Top Packer HANGER HMC ~iner Hanger COLLAR Baker 3-i/2 Type I Lantling Coll COLLAR 3-U2" Weatherford Float Collar I ID 4 I 4. 4. TM 511 IBl M 37. Inc CIW Gen 4, Type N-FBB, "H" BPV profoe, P!N 156156-Ot 3.5' TRMAXX-5E SCSSV w/2.812' X Profile Ser.# HZS-0. 3-t/2' x 2J50' Camco "D' Nipple (EUE 8rtl) 2.750' No-Go Baker Locamr Coupling (4.40' O.D.) Baker Bullet Seal Assembly (O.D. 4.125") ?.625' OD BAKER MONOBORE WHIPSTOCK 8_74' OAL, 875' FLUID PASS ID: 7.3.2009 WSR FOR OETAILS I Sho~ I Dens OFF 7/24/2009 LOCATOR, _ _ 6.323 SEALASSY, _ _ 8.336 8;22/2008 INOTE: VIEW SCIItMA I IC w/Alaska . . ._ . __. LWER5.5". Mandrel D ' etails TopDep~~. Top I .. .. . _ _ __ _ ~ _ ~ .Port . _....__. . ._.____ 3.929-6616 I~ (ND~ i Incl OD Valve Latch I Siza TRORun Sin Top (ftKB) (NKB~ ' (~) Make I T T Mod I (~~) Serv YPB YPa (~^) (psi) Run D t Com... s,~aePeeoi , i i~ 2.543.9 2,527.0 23.11'~ Camco KBG-2-9 I 1~GAS LIFT DMY INT 0.000 0.0 7/22/2009 cemem Spuaeze,6.]89 p'~ 4,0659 3,724.1 40.77 Camco KBG-2-9 ' 7 GASLIFT IDMY INT 0.000 OA~7/22/2009 3 5,082.3 4,605.7 8.66 Camco KBG-2-9 1 GAS LIFT ~DMY INT 0.000 0.0 7(22/2009 WHIPSTOCK, s,s2e 4 5,872.5 5,389.0 6.58 Camco ~~ ~ KBG-2-9 1 GAS LIFT 'DMY INT 0.000 - 0.0 7/22/2009 ' 5 6,172.1I 5,6867 ZSfi Camco KBG-2-9 1 GAS LIFT IDMY IINT IO_000 0.0 7/2312009 I _ 3C-14A 8MD ~TD KB) Act Bhn (kKB~ P4.67 . 6.953.0 ~d (k) Rig Release Da4 37.40 I 70/18l1985 lotl By I End Date [riolwi 7/26/2009 LINER 3.5'. ~ ~ 6,3~6-6.951 TD(3C~11A~. ~ 6953 ~ i : ~ . • ~ ~ . ' . ~ • ~~l,.s~~ V ~~ COr1 ~ . . ocoPhilt~ps AlaSka P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 20Q9 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ;° 3~ ' ~li~ .. ; ~~t~~ ~~ .. Dear Mr. Maunder: JUL 0 ~ 20p9 ~laska Qil & Gas Cons, ~~mmixsian Anshnr~~~ ~- ~ ~~~ Q`~.~ 7 ~' ~~~ ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 16~' & 26~', 2009 and the corrosion inhibitor/sealant was pumped June 23rd & 30~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~`f~ MJ Loveland ConocoPbillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/3/09 3 C PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Conosion inhibitort sealant date ft bbls ft al 3C-01 500292141300 1851870 22' 2.3 28" 6/26/2009 5.9 6/30/2009 3C-02 500292141400 1851880 76' 10.0 22" 6/26/2009 5.1 6/30/2009 3C-03 500292141500 1851890 5' 1.0 21 " 6/26/2009 5.1 6/30/2009 3C-04A 500292141601 2020570 4' 1.0 23" 6/26/2009 5.1 6/30/2009 3C-05 500292138900 1851540 24" Na 24" Na 4.25 6/23/2009 3C-06 500292109600 1840420 6" Na 6" Na 7.65 6/23/2009 3C-07 500292139100 1851560 37' 5.00 25" 6/16/2009 5.52 6/23/2009 3C-08 500292139000 1851550 12' 2.00 22" 6/16/2009 3.4 6/23/2009 3C-09 500292135500 1851000 20" n/a 20" n/a 2.55 6/23/2009 3C-10 500292135600 1851010 30' 4.10 24" 6(16/2009 4.25 6l23l2009 3C-12 500292135400 1850990 45' 9.30 26" 6/26/2009 4.3 6/30/2009 3C-13 500292142400 1851980 20" n/a 20" Na 2.12 6/23/2009 3C-14A 500292142501 2071750 3' Na 3' Na 8.07 6/23/2009 3C-15A 500292142601 2080810 31' 4.40 26" 6/16/2009 2.75 6/23/2009 3C-16 500292142700 1852010 20" n/a 20" n/a 2.12 6/23/2009 3C-17 500292338900 2080590 2'6" n/a 2'6" n/a 8.92 6/23/2009 • • " ` ' _- SARAH PAL/N, GOVERNOR ~5~ OI~ Ai`D ~ ~~" 333 W. 7th AVENUE, SUITE 100 C01~5ER'PA'1'IO1~T CO1rIIrII55IO1Q 9 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Ohlinger Drilling Engineer , :'.~,;,~~'~~;';~; f ~..I ~ ~ °tx 2QQ ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~ ~ ~ r ~ ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-14A Well Sundry Number: 309-190 Dear Mr. Ohlinger: Enclosed is the approved Application for Sundry• Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~) ~~ John K. Norman Q~,~y_ Commissioner DATED this ~? day of June, 2009 Encl. ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~UN a ~. ~(~~~ G~S'" APPLICATION FOR SUNDRY APPR~~ ~~~ Cons Cumm~s~iQr~ 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver = ' ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ . Exploratory ^ 207-175 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21425-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 3C-14A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25634 • RKB 88' Kuparuk River Field /Kuparuk River Oil Pool , 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6953' 6403' . 6854' 6327' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 116' 116' SURFACE 4025' 9-5/8" 4061' 3720' PRODUCTION 4062' 7" 4150' 3787' 5 1/2" LINER 2692' 5-1/2" 6616' 6116' 3 1/2" LINER 635' 3-1/2" 6951' 6401' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6789'-6803' 6273'-6285' 3.5" L-80 6341' Packers and SSSV Type: Packers and SSSV MD (ft) CHP' pkr, HR ZXP liner top pkr @ 3924', 6335' TRMAXX-5E SSSV @ 2027' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: plugged Q Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat July 1, 2009 Oil ^ Gas ^ Plugged ^~ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Printed Name Ja Ohlin er Title: CT Drilling Engineer Signature ^~, - Phone 265-1102 Date lp 03 O Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3D9-/c~D Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~~ ` ` j., ~ ~~~ ~ ~ < ~Q I APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~ (~~ I t Submit in Duplicate ~~.~ .. e ~~KUP ~- " Con~r~Philiips ~ ~~ Well Attributes __ _ ___ __ API I UWI Fieltl Name Well Stab 6002921425 IKUPARUK RIVER UNIT IINJ comment - $S$V. TRD H2S (ppm) Date Annofatiol Wen coneg 3c-t 4A.622!2UU62:9e.eb -~^ Last Tao. P 130 7/1/2008 (Last WO: '~-~~- S hemeTp~ACWaI Annotation (Depth (ftKB) End Date Annotation 6.816.0 8/21!2008 (Rev Reason. GLV G HANGER, 36 Casing Description OD (inl ID (inl Top (ftKB) Sat Depih (ft .. Sat Depth (ND) (ft VYt (It ProtlucLon 7 6.151 0.0 41500 3,787.5 ~ 26~ .Casing Descn ption OD (in) ID (in) Top (ftKB) (Set Depth (ft .. Set Depth (ND) (k .. '', WI (It ~ 51/2'Lner 151/2 4.850 3924.1 '~ 6,616.0 6,115.9 15. xo ruBING.42 - - - Liner Details `" Top (ftKB) i kem Description Comment conductor, _- - 3,924.1 PACKER 5.5" X 7" LTP "CHP" C-2 profile w/ 6.1' ext. Est 5.5" ID (Pkr 4.91" ID) o-11s ~ I. 3,934.91 HANGER HMC liner hanger - 5.5" Vam p X p (4.96" ID ) SSSV, 2,026- _ ~ ~~Casing Description OD (in) ID (in) Top (kK8) '3-1 /2"Liner 312 2.992 6,316.1 Liner Details _ GAS LIFE, L•. Top (ftK6)~ Hem Description 25^4 G,316.1 SBE ~LXP Seal Bore Extension 6,335.31 PACKER HR ZXP Liner Top Packer ?~ 6,343.7'IHANGER ~HMC Liner Hanger -~ 5 6,854.0,COLLAR (Baker 3-1/2 Type l Landing Sutlece. Oi.061 GAS LIFT. 4,(166 F4odud'an. 03,150 GAS LIFT. 5,082 GAS LIFT. 5.8]3 GAS LIFT. _ _ 6.1]2 NIPPLE. 6.252 LOCATOR, 6,323 SEAL ASSY. _. 6.336 51/2'Liner, ___ 3,924-6,616 IPERF, 6,769-6.803 Description iOD (inl ~ 'ID (in) Top (k... Set Depih(ftK...Se[Depih (TVD)(ftKBl Wt(Ibsi G 31/2 ( ( 2992 37.7 6,341.0 5,852.8 9.31 pletion Details KBI Item Description _ _ ___ Comment 7J HANGER CIW Gen 4, Type N-FBB, "H" BPV profice, P/N 156156-01-01-01 6.5 SSSV X13.6" TRMAXX-SE SCSSV w/ 2.812" X Profile Ser.# HZS-028 2.3 NIPPLE 3-1/2" x 2750" Camco "D" Nipple (EUE 8rd) 2.750" No-Go Profile 2.7 LOCATOR Baker Locator Coupling (4.40" O.D.) S.SSEAL ASSY iBaker Bullet Seal Assembly (O.D. 4.125") gyrations -- _ Btm (TVD1 R D) Dens 3C-14A Depth (kK6) 8,450.0 g Release Data 2/26!2008 ErM Date 8!22/2008 511 511 3-112' Liner, 6,316-6,951 \ TD (3C~14A), 6,953 KRU 3C-14A -Plug Perfor~s 3C-14A Sundry Engineer: James Ohlinger CT Drilling Engineer (907) 265-1102 The anticipated spud date for Nabors CDR-2AC to drill a CTD A-sand horizontal lateral injector from we113C-14A is August 2009. Summary of Operations: We113C-14A is currently a producer completed in the C-sand with a 3-1/2" liner and tubing. The existing C-sand perforated interval (6789' - 6803' MD) is to be cement squeezed/plugged to allow a sidetrack that will utilize athrough-tubing whipstock for exiting the 3-1/2" liner. The sidetrack will be completed with a 23/s" slotted liner to the top of the A-sand and solid liner covering the B-interval up to the liner top located inside the existing 3'h" liner 6822' MD. The 2-3/8" liner top will be tied into astraddle-packer completion that will cover the cemented C-sand perforated interval. - Pre-Rig Work 1. SCMT Cement Bond Log 2. Test packoffs - T & IC, MIT-OA 3. TIFL, Positive pressure and drawdown tests on MV and SV. Drawdown test on SCSSV 4. Slickline tag filUbottom, drift w/ dummy whipstock, obtain SBHP 5. E-Line to set a BOT 3'/z" Mono-bore whipstock at 6828' MD 6. Cement squeeze on existing C-sand perfs, clean out cement to TTWS 7. Load tbg & IA, DGLV's. MIT-lA 8. Prep site for Nabors CDR2-AC Page 1 of 1 6/3/2009 • ~ Review of Sundry Application 309-190 ConocoPhillips Alaska, Inc. We113C-14A AOGCC Permit 207-175 Requested Action: ConocoPhillips Alaska, Inc. (CPAI) proposes to plug the perforations on this oil producer to prepare the well for a coiled tubing sidetrack. Recommendation: I recommend approval of Sundry Application 309-190 to allow CPAI to perform this operation. Discussion: CPAI proposes to plug the perforations in the subject well to prepare the well for a coiled tubing sidetrack to change the well from a C Sand producer to an A Sand injector in the Kuparuk River Oil Pool. The well was originally drilled and completed in early 2008 and first production occurred in April of that year. The well has remained on essentially continuous production (the gap in production corresponds to a major facility shutdown that occurred last year for maintenance and upgrade purposes) since that time but has never been a strong producer. Initial production from the well was less than 100 BOPD with a water cut near 95%. Oil production rate did increase somewhat, up to a peak of 174 BOPD and water cut did drop as low as 68.5% but recent trends show oil rate dropping and water cut increasing again. Cumulative production from this well has been slightly less than 37.5 MBO through Apri12009. This data suggests that this portion of the reservoir was swept prior drilling and completion of the well and that remaining reserves would be negligible. (See production chart on following page.) Due to the production data showing a modest increase in oil production and decrease in water cut I called Mr. James Ohlinger with CPAI to see if they thought this was indicative of the well having potential to become a better producer. He informed me that more recent production data shows that oil rates have dropped below 100 BOPD in recent weeks and the water cut has increased again. Also, he informed me that the proposed side track would be an injector providing pressure support to two wells, the 3C-16 and the yet to be drilled 1 Q-15 L 1 and 1 Q-15 L 1-O l laterals. The 1 Q-1 S laterals are currently isolated from any injection support due to a major fault. The planned 3C-14A redrill would cross this fault and provide injection support to the 1Q-15 Laterals. • laooo • T ozszlaz5o1oo:l00 Oil Rate (R7l (bbUd ) Voter Fite (R7/ (bbVd ) Ces Fite (f~j (Ntf/d ) ~ Voter Qrt (% ) . ~ Oes /Oil F+aGo (NEf/bbl ) 1 +-- - -- - -mac--- ----~-- 1----------- _-_-~ - - - -_ ~ - 1--~` - _-- _ _ __ ..-- -, T- ____ ,.._--.. 0.1A M4Y JlN ~ Jll ~ AUG Sly OCT NUV ~ ~, JAN F® M4R AFit -- --- -- - -2008 - __~ ._ _. - - 2009 i DOTE Conclusion: The 3C-14A well has very limited value currently as there are limited remaining reserves. Abandoning the existing completion so that the well can be sidetracked to provide pressure support in what is believed to be an unswept area of the reservoir should yield greater ultimate recovery from the field. Therefore, I recommend that CPAI's proposed activities for the subject well be approved. D.S. Roby `~`T ~% Sr. Reservoir Engineer June 5, 2009 DATA SUBMITTAL COMPLIANCE REPORT 1 /12/2009 Permit to Drill 2071750 Well Name/No. KUPARUK RIV UNIT 3C-14A MD 6953 TVD 6403 Completion Date 3/14/2008 REQUIRED INFORMATION Mud Log No (data taken from Logs Portion of Master Well Data Maint DATA INFORMATION Types Electric or Other Logs Run: GR/RES Well Log Information: Log/ Electr Data Digital Dataset ~pe Med/Frmt Number Name ED D Asc Directional Survey ~Rpt Directional Survey ,. Rpt LIS Verification ~~ ',~D C Lis 16262 ~duction/Resistivity ~wXog Induction/Resistivity jLog Induction/Resistivity ~D C 16263~ee Notes wog Cerement Evaluation 1~D C Pds 17052 Cement Evaluation _ _ _. _. Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / I~ Chips Received? Y R'" Analysis `T/fN- Received? Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21425-01-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey Yes Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments _ 40 6953 Open 5/7/2008 - ---- --------- 40 6953 Open 5/7/2008 4137 6904 Open 5/19/2008 LIS Veri, GR, RPD, RPS, RPM, FET, ROP 4137 6904 Open 5/19/2008 LIS Veri, GR, RPD, RPS, RPM, FET, ROP 25 Col 6628 6953 Open 5/19/2008 MD ROP, DGR, GM, EWR 25 Col 6127 6402 Open 5/19/2008 TVD ROP, DGR, GM, EWR 0 0 Open 5/19/2008 MD and TVD in PDS, EMF, and CGM graphics 5 Col 6020 6817 Case 11/7/2008 SCMT, CBL 22-Sep-2008 6020 6817 Case 11/7/2008 SCMT, CBL 22-Sep-2008 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ..~~~ ~N~~ Formation Tops Xi'~ ~~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 1 /12/2009 Permit to Drill 2071750 Well Name/No. KUPARUK RIV UNIT 3C-14A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21425-01-00 MD 6953 TVD 6403 Completion Date 3/14/2008 Completion Status 1-OIL Current Status 1-OIL UIC N -- -- --- - -- - - - Compliance Reviewed By: __ _____ _ Date: ~~~~,~..-- f~Jl}~.~ 4 \J _ 10/14/08 NO.4914 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1 L-23 12097405 SBHP SURVEY / 07/17/08 1 1 2A-17 i i 975793 PRODUCTION PROFILE 9 - /L {~ L 09/10/08 1 1 3G-25X 12080437 LDL ~ - ~j L[(o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE C C / 09/14/08 1 1 3M-13 12096541 LDL - (~L( j 09/10/08 1 1 2Z-13A 12100446 LDL b(o- ('~ O ~U 3 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 C-14A 12080436 SCMT - ~' S~ 09/22/08 1 1 10-111 12100451 INJECTION PROFILE ~ p ~ 09/20/08 1 1 30-15 12100452 LDL - ~ 5O 09/21/08 1 1 iC-117 12100453 INJECTION PROFILE o ~ r 09/23/08 1 1 1 R-11 11966277 SBHP SURVEY ~ - (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY p - 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE 09/30/08 1 1 iR-34 12080444 _ GLS L ,.. 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .: L ~~C/ 10/02/08 1 1 iD-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~ '~- ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L 10/03/08 1 1 18-16 12097426 GLS Cj - =' 10/07/08 1 1 36-09 12100442 PRODUCTION PROFILE - 09/12/08 1 1 3K-103 12096550 USIT _ 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE ~~ 10/07/08 1 1 iB-04 12096552 INJECTION PROFILE ~ 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 1 B-16 12096554 PRODUCTION PROFILE G~ C~ .. G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE )"~C . 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~1 ~ -: ~ ~ WELL LOG TRANSMITTAL To: State of Alaska May 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3C-14A AK-MW-5681882 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3C-14A Z" x 5" MD RESISTIVITY AND GAMMA RAY Logs: 1 Color Log 50-029-21425-01 2" x 5" TVD RESISTIVITY AND GAMMA RAY Logs: 1 Color Log 50-029-21425-0 l Digital Log Images 1 CD Rom 50-029-21425-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish ~U arctic Blvd.: . ~ •~ Anchorage, Alask~Y99518 Date: - ~'~' Y ~ Signed: ~ ~~- 07 /7S ~i~~~~ ., MAY-21-2008 15 47 D~ i WELLS ~ACSYIVI~I,~ T~t.A~l'S~X~"~'.A.~ S~E~'~' DATE: ~~ ~ ~~~ '~'U: ~crJ n~ /!~ ~ U ~ ~ E~ ~A~~: a ~~ ^ ~~-~~ 907 265 1336 P.01 FROM: ~~ y i t~ ~ n/ J 6~N'r Notes: ~IAY ~ ~?Q0 Alaska ~tid ~ Gas LQns. ~omrraiss~~~ ~4nchorage ~1'O.O~ PAGES FOLLQ'PVYN'Cx COVER: j l~axc: (90'n 265 -1,336 MAY-21-2008 15 48 i WELLS 907 265 1336 P.02 ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATtdN COMMISSION WELL COiVIPLETION OR RECOMPLETION REPORT AND LOG . Well Sia#us: OII Q Gas Pkuggsd Abandoned suspended tb. Wail Class: ~-~1 20AAC 25,105 20AAC 25.110 Development l.:J Exploratory ^ S i Q Stratigraph~Test^ GtNJ ^ WiNJ ^ WDSPL ^ WAG ^ Other © No, Of Completions. erv ce 1a. Permit ~ Drhl Number. OperaUDr Name: 5. Late Comp., Susp., ConocoPhiltips Alaska, Inc. orAband,: March 14, 2008 207-175 / 308-042 Address: 6. Date Spudded: 13. AP) Number 50-029-21425-01 Anchorage, AK 99510.0360 Box 100360 P O January 26, 2008 , . . Locatiorf of Watl (Governmental SeClion): ~ 7, Date TD Reached; 14. Well Name and Number. , 1229' FEL, Sec. 14, T12N, R9E, UM Surface: 1251' FNL February 22, 2008 3C-14A , 8. KB (ft above MSL): 38' RKB t5. FieldlPoof(s): Top of Productive Horizon: 2542' FNL, 42' F11VL, S®C. 13, T12N, R9E, UM Ground {ft MSL): 76' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 2611' FSL, 41' 1-tNL, Set;. 13, T12N, R9E, UM 6854' MD / 6327' TVD Kuparuk Oil Pool Location of Wall (State Base Plana Coordinates}: ~ 10. Total Pepin (MD + TVD): 16. Properly Designation: . Surface: x- 528346 y- 5995180 Zone- 4 6953' MD / 641)3' TVD ALK 25634 TPI: x- 529622 y- 5993894 Zone- 4 11. SSSV Depth (MD + TVD): 97. Land Use Permit: Total Depth: x- 529621 - 5993787 Zone- 4 55SV ~ 2026' MD / 2026' TVO 2567 ;, Otfegtignal Survey: Yes l~J No^ ta. Water Depth, If Offshore: 20. Thickness of Permafrost (ND): ' (Submit electronic and pCinted information per 20 AAC 25.050) NIA (ft MSt) ND 1700 ' I. Logs Obtained (List all logs here and sutxnlt electronic and pdnted information per 20 AAC 2s,o79): top ar window (~ 41 SO GR/F~ES SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 16" 62.5# M-40 38' 716' 9-5l8" 36# J-55 38' 4061' 7" 267E J_55 3$' 4150' 5.5" 15.5# L-80 3924' 6616' 3.5" 9,2~ L-80 6316' 6851' '3.Open to prod uction or inject'son? Yes No ~ If Yes, list each interval open (MD+TVD of Top 8 Bottom; Perfgration Size and Number): 6789' - 6803' MD 6273' -62 85' TVD 6 spf ._P O Cl (Flowing, gas SETTING OEPTEi ND 70P BOTTOM 38' 116' 38' 3720' 38' 3787' 361T 6116' 5828' 6401' SIZE 3,5" DEwPTH St=T (MP) 6341 SET ACID, FRACTURE, CEMENT SQUEEZE, ETC. qtr (+ d DEPTH INTERVAL {MD) AMOUNT AND KINp OF MATERIAL LIBEL na on facility Hook-up ate of Test Hours Tested Protluctlon for OtL-BBL GAS-MCF WATER-BBL CHOKE SIZE uN Tesi Period -y ow Tubing Casing Pressure Calculated OIL-BBL GAS-MCf WATER-BBL OIL GRAVITY -API (oorr) •eSg, pg; 24-Hour Rate -~ r, CORE DATA Conventional Core(s) Aoquired7 Yes No r Sidewall Cores Acquired? Yes No Yes to either question, list formations and intervals rAreq (MD*TVD of top anq bottom of each), and summaru:e lilnology and presAnCe of oil, gas or water Submit separate sneers witn this form, if needeo). Submit detailed descriptions, core chips, photograpns and laboratory analytical results per 20 AttArC'25.079 R 9/ ~~ NONE ~~~ ~ 2 ZOOS ~Ilrrks iii & ~~ Cons. CatiM111SSIQtiI Form 10.407 Revised 2!2007 CONTINUED ON REVERSE SIDE HOLE AMOUNT CEMENTING RECORD PULLED SIZE 24" ~ Ss sx GS II 12.25" 940 sx PF'E', 360 sx PF'C', 125 sx PF'C' 8.5" 550 sx Cla$S G, 200 5x PF'C' 7" 153 sx Class G, 57 sx GI G wlGasBLOK 4.75" 51 sx Class G r TOTAL P.02 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 21, 2008 9:56 AM To: 'Chip Alvord'; 'Randy Thomas'; 'Jerome Eggemeyer ; 'Sharon Allsup-Drake ; 'Dan Kara ; 'Pat Archey'; 'Lowell Crane ; 'Greg Hobbs ; 'Robert Tirpack ; 'Robert Younger'; 'Paul Figel'; 'Larry Buster'; 'Steve Tyler ; 'Tim Brandenburg ; 'Chantal Walsh -Petrotechnical'; 'Dave Reem'; 'Bob Gardner'; 'Bill Penrose ; 'Jesse Mohrbacher'; 'Sondra Stewman'; 'Terrie Hubbie'; 'Gary Preble (SAIC) ; 'Gary Eller'; 'Guy Schwartz ; 'Chuck Rowe'; 'Jim White ; 'John Lewis'; 'Paul Mazzolini'; 'Mike Quick'; 'Tim Flynn'; 'Bart Armfield'; 'Harry Engel ; 'Ken Walsh'; 'Kevin Skiba ; 'Wayne Cissell'; 'Will Tank'; 'Jeff Gasch ; 'Vance Hazzard'; 'Joe Polya ; 'Erik Opstad ; 'Ed Jones ; 'Mike Cook ; 'arlenehm@gci.net'; Winton Aubert; 'Coyner, Vern ; 'Venhaus, Dan E'; 'lamar.gantt@bp.com' Cc: AOGCC North Slope Office; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA); Howard Okland; Regg, James B (DOA); McMains, Stephen E (DOA); Bob Fleckenstein Subject: RE: Listing Packers and Depths on forms 401 and 407 All, It is not unusual to run a liner top packer in wells. This device effectively seals the liner top and in conjunction with seal receptacle and appropriate seals can provide the "bottom" of the inner annulus when a traditional packer is not run on the tubing. On some completion (407) and workover (404) reports "none" is entered in the packer data block [block 24 on 407 and lower right corner of block 11]. When a tubing packer is not included in the completion assembly and the tubing is stung into the seal receptacle, the liner top packer depth should be included in the appropriate location on the respective forms. Please share this with others in your organization I may have missed. Thanks in advance for your attention to this matter. Call or message with any questions. Tom Maunder, PE AOGCC ~ ~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : Gubik 3 WELL LOG TRANSMITTAL May 13, 2008 AK-MW-5551160 Gubik 3: 2" MD GOM Logs: 1 Color Log 50-287-20017-00 5" MD GOM Logs: 1 Color Log 50-287-20017-00 2" MD QC Logs: 1 Color Log 50-287-20017-00-00 5" MD QC Logs: 1 Color Log 50-287-20017-00-00 2" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-287-20017-01-00 5" MD Resistivity & G a Ray Logs: 1 Color Log 50-287-2001 T~~00 7p ~~ s • lg' `~ Digital Log Images: 1 CD Rom 5 0-2 8 7-20017-00, 00-0000 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchgra~ ,~. ; as~~ 445=1.8 --~ 'fir ; c ~ ;~ ;;~ ,; Date: ~. ~ ,., °,,.,_ -- BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~o~ /~lo `~' I Coc7Sd Signed: ~~ WELL LOG TRANSMITTAL To: State of Alaska May 4, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3C-14A AK-MW-568188 1 LDWG formatted CD Rom with verification listing. API#: 50-029-21425-0 l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 :,.~ '.:'6..> . Date~~ - ~ -~~` ~~ Signed: , ~o~-- l~~ ~ l~~C~~ s ~ 21-Apr-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3C-14A Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 4,104.45' MD Window /Kickoff Survey: 4,165.00' MD (if applicable) Projected Survey: 6,953.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ,/) ~ /~ ~ ~ / A Date ~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~-n ~' ConocoPhillips April 9, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3C-14A Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~'~C ~ ~'~ ~ ®2008 Alaska Oil ~ Gas Cons. ~ . Anchor,~a m~ssiorA ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Kuparuk well 3C-14A. If you have any questions regarding this matter, please contact me at 265-6830 or David Nugent at 263-4674. Sincerely, ~~~.-~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad CVEI[~ STATE OF ALASKA ~ APt~ ~ ~ 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO~~p~~G~~• Commis 1a. Well Status: Oil ^/ Gas Plugged ^ Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: e Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: March 14, 2008 12. Permit to Drill Number: 207-175 / 308-042 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 26, 2008 13. API Number: 50-029-21425-01 4a. Location of Well (Governmental Section): Surface: 1251' FNL, 1229' FEL, Sec. 14, T12N, R9E, UM 7. Date TD Reached: February 22, 2008. 14. Well Name and Number: 3C-14A Top of Productive Horizon: 2542' FNL, 42' FWL, Sec. 13, T12N, R9E, UM 8. KB (ft above MSL): KB Ground (ft MSL): y~~8''~MS ~,(. 5. Field/Pool(s): .og, Kuparuk River Field Total Depth: 2611' FSL, 41' FWL, Sec. 13, T12N, R9E, UM 9. Plug Back Depth (MD + TVD): 6854' MD / 6327' TVD Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528346 • y- 5995180 ' Zone- 4 10. Total Depth (MD + TVD): 6953' MD / 6403' TVD 16. Property Designation: ii`D[,/krK'25634 TPI: x- 529622 y- 5993894 Zone- 4 Total Depth: x- 529621 - 5993767 • Zone- 4 11. SSSV Depth (MD + TVD): SSSV @ 2026' MD / 2026' TVD 17. Land Use Permit: 2567 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @x150' GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 38' 116' 38' 116' 24" 188 sx CS II 9-5/8" 36# J-55 38' 4061' 38' 3720' 12.25" 940 sx PF'E', 38o sx PF'C', 125 sx PF'C' 7" 26# J-55 38' 4150' 38' 3787' 8.5" 550 sx Class G, 20o sx PF 'C' 5.5" 15.5# L-80 3924' 6616' 3617' 6116' 7" 153 sx Class G, 57 sx CI G w/GasBLOK 3.5" 9.2# L-80 6316' 6951' 5828' 6401' 4.75" 51 sx Class G 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 6341' 6789' - 6803' MD 6273' -6285' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTANDKIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE ~ ~I..S~.O~ .,~E p~~ , Form 10-407 Revised 2/2007 ORIGINAL CONTINUED ON REVER E I Nt~~ ~ ~~ Zd~~ ~ ~/_/G, p$ ~r~ ~ ~~~ ~~G r~ 28. GEOLOGIC MARKERS (List all formations and mar encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes / No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk D 6654' 6153' Top Kuparuk C4 6731' 6222' Top Kuparuk C3 6764' 6251' Top Kuparuk C2 6778' 6263' Top Kuparuk C1 6788' 6272' Top Kuparuk B 6812' 6292' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4674 Printed Name' Rand Thomas Title: Drillino Team Leader ~~ ~r`1 / 6 a ~ ~ l ~ " ` Signature l Phone -+ -1 (o Z{ j gj Date L.`5 INSTRUCTIONS Sharon Allsu/rDrake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~` KRU 3C-14A Gonacc~Phllps Ataslca, finc. 3C -fi4A'' _ API: 50 029 2 1 4 2 501 Well T e: PROD An le ~ TS: 27 de ai 6731 TueING SSSV Type: TRDP Orig 2/4/2008 Angle @ TD: 42 deg @ 6953 (os3a1, oD:3.5o0, Com letion: ID:3ss2) Annular Fluid: Last W/O: Rev Reason: GLV C/O, TAG, i PERF ~ Reference Lo : 37.72' RKB Ref Lo Date: Last U date: 3/28/2008 Last Ta : 6815 SLM TD: 6953 ftK6 -, Last Ta Date: 3/11/2008 Max Hole An le: 43 deg ral 4188 --- -_~ Casing String -ALL STRINGS i n..~...:...:.... C:~.n i Tnn ~ GrN1~m i T\/n i W1 i (3rorlu i Thrnarl CONDUCTOR 16.000 0 116 116 62.50 H-40 SURFACE 9.625 0 4061 3720 36.00 J-55 PRODUCTION 7.000 0 4150 3787 26.00 J-55 LINER 5.500 3924 6616 6116 15.50 L-80 HYD 511 WINDOW 7.000 4150 4151 3788 0.00 I LINtK - PFtUUUG 1 IUN I 3.bUU I b316 _- I 6yb1 I b4U1 I y.zV I L-utl I rtrtJ a l t ~ --- - Tubin string -TUBING _ _ Size To ~~ Bottom TVD Wt Grade Thread 3 500 _ -- 6341 - 5253 9.30 L 20 _ IBTM ,1?erforations Summary Interval T TVD - Zone Status Ft _ SPF Date Type __ Comment 6789-6803 6273- 6225 C-1 14 6 3/14/?008 (PERF 2-5" PJ 2506 60 Deg Phase Gas Lift MandrelsNalves -- - I C I MD I TVD I Man Mfr Man Type I V Mfr I V Type I V OD I Latch I Port __ I TRO I Date Run I Vhr I 'RODUCTION (0150, OD:7.0(xl, Wt:26.00) __5 _J_ 61721 56871 CAMCO I KBG-2-9 I I OV I 1.0 I INT 10.188 1 0 1 3!5/2008 I I Other plugs, equip., etc.) -COMPLETION _ De th TVD T e Descri ion ID 3R 3A HANGER CAMERON 3.5 GEN IV TUBING HANGER 2.992 _~ - 3y35 3bL5 FiHNCatK 5.5"' LINtK FiMI.: KHNIatK 6252 5766 NIP CAMCO'D' NIPPLEw/NO GO PROFILE 6316 5828 SBE 3.5" LINER BAKER ZXP EXTENSION 6323 5835 LOCATOR BAKER LOCATOR COUPLING - 6335 5847 PACKER 3.5" LINER 'HR' ZXP LINER TOP PACKER 6335 5847 SEAL BAKER BULLET SEAL ASSEMBLY 6341 5853 WLEG WIRELINE ENTRY GUIDE 6344 5856 HANGER 3.5" LINER HMC HANGER 6853 6326 COLLAR 3.5" LINER BAKER 3.5" TYPE 1 LANDING 6886 6353 COLLAR 3.5"LINER WEATHERFORD 403 FLOAT C 6950 16400 I COLLAR 13.5" LINER WEATHERFORD 303 FLOAT 2.930 2.880 2.880 2.880 LINER - ~RODUCTION (6316b951, OD:3.500, Wt:9.20) l J Time Logs _____ Date From To Dur S De th E. De th Ph Code Subcode T COM 01/23/2008 00:00 07:00 7.00 0 0 MIRU WELCT BOPE P Fin. testing BOPE, tested rams, valves and choke manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi low and 3,500 psi, tested stack with both 4" and 2 7/8" test jt, note, had to co clean debris above Cameron's test plug between testing with 4" & 2 7/8" test jts. Note: Chuck Scheve with AOGCC waived witnessing of the BOP test. Phase 3 Weather in effect and rig's air heater shut down due to wind and snow. 07:00 07:30 0.50 0 0 MIRU WELC OTHR P RU and ulled Cameron blankin lu and BPV. 07:30 09:00 1.50 0 0 MIRU RPCOh RURD P RU 2 7/8" tubing handling equipment and Camco reel for SCSSV control line. 09:00 10:00 1.00 7,500 7,475 MIRU RPCO PULD P MU jt of 2 7/8" tbg into tbg hanger, back out LDS then PU 70K st wt and tbg was free, pulled hanger to rig floor and LD same, connected control line to reel. Decision was made to shut down due to PHASE 3 weather. Tbg was cut at 7,500' WLM 10:00 22:00 12.00 7,475 7,475 MIRU RPCO WOW NP Waited on Weather 22:00 00:00 2.00 7,475 6,255 MIRU RPCO PULD P PJSM-POH spooling SCSSV control line & laying down 40 jts, 2 7/8" 6.5# Tubing. Strap all tbg. & components while la in down tb . 01/24/2008 00:00 06:00 6.00 6,255 0 MIRU RPCO TRIP P Fin. POOH LD 2 7/8" completion, LD a total of 244 jts of 2 7/8", 6.5#, J-55, EUE 8rd tbg, 1-SCSSV w/pup jt & 33 SS bands, 1-add. pup jt, 6-GLM's and 1-cut piece. Total reed 7,488'.88' (Note tbg was cut @ 7,500' WLM Tubing & tree were NORM'd & ck'd ok. Visually tbg looked good with no si nificant corrosion roblem. 06:00 07:00 1.00 0 0 MIRU RPCO OTHR P Clear and cleaned rig floor. 07:00 08:00 1.00 0 0 MIRU RPCOh OTHR P Strapped 2 7/8" tbg and removed same from i e shed. 08:00 08:45 0.75 0 8 SURFA RPCOA PULD P PU and MU 6 1/8" tri-cone bit on Baker 7" 26# cs scra er. 08:45 12:30 3.75 8 4,725 SURFA RPCOh TRIP P RIH with bit and scraper PU 150 jts of 4" XT-39 DP from the pipe shed RIH to 4 725'. 12:30 13:30 1.00 4,725 4,725 SURFA RPCO CIRC P Circ hole with seawater at 4,725', circ at 420 gpm at 1,100 psi, circ 3X btms up at 20 rpm's with 2K ft-Ibs torque, rot wt 90K, u wt 95K, do wt 84K. 13:30 15:30 2.00 4,725 0 SURFA RPCOh TRIP P POOH and LD bit and scraper 15:30 16:30 1.00 0 0 SURFA RIGMN SVRG P Serviced rig, top drive, drawworks and crown. F'ag~ 2 esf Z~ 1 Time Logs _ __ _ _ _ Date_ From To Dur S De th E. Depth Phase Code Subcode T COM ^ 01/2412008 16:30 16:45 0.25 0 0 SURFA EVAL SFTY P Held PJSM with Baker, SLB and crew on RU and RIH with CIBP. 16:45 20:00 3.25 0 0 SURFA EVALVI~ RURD P RU SLB a-line and scheaves, MU Baker 7" 26# CIBP. 20:00 23:00 3.00 0 0 SURFA EVAL ELOG P RIH w/ Baker'K-1' CIBP on E-Line w/ collar locator. Locate collar @ 4183.5' WLM & set CIBP @ 4179' MD.Approx 3740' TVD. POH & ri down SWS. 23:00 23:30 0.50 0 0 SURFA EVALVI~ DHEQ P Test Csg. & bridge plug to 1000 psi chart same. Low ressure due to 7" packoff leaking. Held OK. Will pressure to 3,500 psi after swap out of tb . s ool & ackoff. 23:30 00:00 0.50 0 0 SURFA WELC NUND P Begin nipple down BOPE for tbg. s ool & 7" ackoff chan e. 01/25/2008 00:00 01:00 1.00 0 0 SURFA WELCT NUND P Fin. ND BOP stack 01:00 05:00 4.00 0 0 SURFA WELCT EQRP P ND 7 1/16" 5M x 11" 3M Cameron tbg head and removed packoff, took 27K pull to remove packoff, installed new packoff and tbg head testing flange to 3,000 psi for 15 min. No problems C/O tb head. 05:00 08:30 3.50 0 0 SURFA WELCT NUND P NU BOP stack, changed out lower set of pipe rams from 2 7/8" to 4" and re-installed riser. 08:30 09:30 1.00 0 0 SURFA WELC BOPE P RU and tested lower 4" pipe rams and break on stack to 250 psi low and 5,000 si hi h. 09:30 10:30 1.00 0 0 SURFA CASINC DHEO P Tested 7" cs and CIBP to 3,950 psi for 15 min, good test. Blew down lines and installed wear bushin . 10:30 10:45 0.25 0 0 SURFA DRILL SFTY P Held PJSM on MU whipstock mills and PU and standing back hybrid DC's and HWDP. 10:45 13:30 2.75 0 0 SURFA DRILL PULD P MU whipstock mills on 1 jt of 4" HWDP, then RIH MU 8 stds hybrid push pipe with 15 HWDP and 9 DC's. POOH & stood back same. 13:30 13:45 0.25 0 0 SURFA STK OTHR P Held PJSM with Baker and Sperry reps on MU whipstock and MWD assembl . 13:45 15:00 1.25 0 0 SURFA STK PULD P Rig up MWD monitors & pick up whi stock- in w/ 35k shear. 15:00 16:30 1.50 0 190 SURFA STK PULD P Pick up & orient MWD, Bumper sub & RIH. Test MWD 190' & blow down. 16:30 19:30 3.00 190 4,022 SURFA STK TRIP P RIH w/ whipstock & milling assembly to 4022' MD. 19:30 20:30 1.00 4,022 4,150 SURFA STK WPST P Break circ. & orient. Pick up single & tag @ 4168' DPM & set whipstock @ 38L de .Confirm anchor w/ 10k over pull & shear off slide w/ 35k & confirm. To of window @ 4____150' MD. (Bridge lu was set 4179' WLM 20:30 21:30 1.00 4,150 4,150 SURFA STK CIRC P Displace well w/ 10.0# LSND mud. Perform baseline csg. test. Blow down kill line. Page 3 of 25 ~C\~A i ~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM 01/25!2008 21:30 00:00 2.50 4,150 4,153 SURFA STK MILL P Milling window from 4150' MD to 4153' MD. 300 gpm 1550 pp 90 rpm. TO 4000. 01/26/2008 00:00 05:15 5.25 4,153 4,163 SURFA STK MILL P Cont. to mill window in 7" csg from 4,153' to 4,163', milled at 3-5K WOM, 80-90 rpm's, 3-5K torque, 300 gpm, 1,500 si. 05:15 06:30 1.25 4,163 4,193 SURFA STK OTHR P Drilled 30' of new hole from 4,163' to 4,193' MD/3,818' TVD, ADT 1.25 hrs. 06:30 07:30 1.00 4,193 4,099 SURFA STK CIRC P Pumped hi vis sweep and circ hole clean while working mills thru the window, no increase in cuttings from sweep, circ at 300 gpm, 1,500 psi, 90 rpm's, 10.0 MW in and out., POOH to 4,099' 07:30 08:30 1.00 4,099 4,099 SURFA DRILL FIT P RU and performed FIT to 16.1 ppg EMW, 1,210 psi with 10.0 ppg mud at 3,786' TVD. Shut in 10 min's, final pressure 780 psi which is equal to 13.9 psi EMW, performed second FIT with same results. 08:30 09:00 0.50 4,099 4,099 SURFA STK OWFF P Monitored well-static, pumped dry job and blew down lines, st wt up 100K, do wt 85K 09:00 10:00 1.00 4,099 618 SURFA STK TRIP P POOH from 4,099' to BHA at 618' 10:00 12:00 2.00 618 0 SURFA STK PULD P POOH LD BHA#1, LD HWDP, DC's and mills, u er mill was in au e. 12:00 13:15 1.25 0 0 SURFA STK OTHR P Pulled wear bushing and flushed out BOP stack, re-installed wear bushin 13:15 17:00 3.75 0 0 SURFA DRILL PULD P PU &RIH with 63 jts of 4" DP Jars & 2 jts. HWDP out of the pipe shed and POOH standing back same. Pick up & stand back flex dc,s. 17:00 18:15 1.25 0 0 INTRM1 DRILL PULD P PJSM-Pick up BHA #2/MWD tools. 18:15 20:15 2.00 0 275 INTRM1 DRILL OTHR P Program MWD-make up bit & rhino reamer & orient. RIH w/ bha s.p.t. @ 275' & blow down. 20:15 21:45 1.50 275 4,131 INTRM1 DRILL TRIP P RIH w/ BHA #2. Break circ. @ 4131' MD. 21:45 22:00 0.25 4,131 4,173 INTRM1 DRILL DRLG P Orient 38L deg. & slide w/ pumps off 4131' to 4173'. (Pick up wt. 100k slack off wt. 80k. 22:00 22:15 0.25 4,173 4,193 INTRM1 DRILL REAM P Ream 4173' to 4193' (60 rpm 300 gpm 2000 wob 2k rot 90k t 4k. 22:15 22:45 0.50 4,193 4,224 INTRM1 DRILL DDRL P Drlg. 4193' MD to 4224' MD TVD 3838'. ART=.37 ADT .37 ECD 11.55 22:45 00:00 1.25 4,224 4,224 INTRM1 DRILL CIRC P Check kill rates. Circ. & establish clean hole ecd,s. 01/27/2008 00:00 10:15 10.25 4,224 5,017 INTRM1 DRILL DDRL P Directionally drilled 6 1/8" x 7" hole with 1.5 motor & Rhino reamer at bit, drilled from 4,224' to 5,017' MD/4,541' TVD. (793') ART 2.48 hrs, AST 5.03 hrs, total 7.51 hrs., 10.0 ppg MW, ave ECD 11.8 ppg (clean hole ECD with 10.0 MW was est. at 11.5 Paga 4 €~f Za ~-`~.~, • Time Lomas ___`_ _ Date From To Dur S D th E. De th Ph e Code Subcode T COM 01/27/2008 10:15 10:45 0.50 5,017 5,017 INTRM1 RIGMN' RGRP T #1 Generator went down, restarted and ut back on line. 10:45 12:00 1.25 5,017 5,074 INTRMI DRILL DDRL P Drilled from 5,017' to 5,074' MD/ 4,597' TVD (57') ART .34 hrs, AST .19 hrs, total 0.53 hrs. 10.0 ppg mw, ave ECD 11.7 12:00 00:00 12.00 5,074 5,923 INTRM1 DRILL DDRL P PJSM & drlg. 6 1/8" X 7" directional hole from 5074' MD to 5923' MD. ART 6.08 hrs. AST 2.42 hrs. While Dr19• from 5910' to 5923' MD lost 3-4% flow & well took 30 bbls. fluid. reduce rate to 230 gpm & stabilized. Well breathin w/ um off. ADT 8.50 hrs. P/U wt 125k S/o 100k RT 110k TQ 4k ECD 11.6 to 12.4 01/28/2008 00:00 04:30 4.50 5,923 6,112 INTRM1 DRILL DDRL P Drill 6 1/8" x 7" hole from 5,923' to 6,112' MD/ 5,672' TVD (189') ART 3.11 hrs, AST .84 hrs, ADT 3.95 hrs, ave MW 9.75 ,ave ECD 11.6 04:30 05:30 1.00 6,112 6,112 INTRM1 RIGMN RGRP T Trouble shoot problem with top drive. 05:30 12:00 6.50 6,112 6,211 INTRM1 DRILL DDRL P Drilled from 6,112' to 6,211' MD/5,725' TVD (99') ART 2.28 hrs, AST 2.40 hrs, ADT 4.68 hrs, 9.75 MW, ave ECD 11.4 ppg, ave 7 bph mud loss, last 12 hrs lost a rox 110 bbls. 12:00 12:30 0.50 6,211 6,211 INTRM1 RIGMN RGRP T Trouble shoot problem with top drive. Appears cold weather may be causing belt in motor of TD to slip or possibly in the software to TD. 12:30 14:00 1.50 6,211 6,263 INTRM1 DRILL DDRL P Drilled from 6,211' to 6,263' MD/ 5,776' TVD (52') ART -0-, AST 1.12 hrs, ADT 1.12 hrs. Attempting to build and turn, not ettin desired rates. 14:00 14:30 0.50 6,263 6,263 INTRM1 DRILL OWFF P Performed 30 min. breathing test while discussing directional options with town, 1st 5 min's gained 2 bbls, last 15 min ained .25 bbls er each 5 mins. Gained a total of 3.5 bbls in 30 min. 14:30 16:00 1.50 6,263 6,263 INTRM1 DRILL CIRC P Stood back 1 std and circ hole at 250 gpm, 1,850 psi, decision was made to cont. to drill next 100' and attempt to increase build and turn rates. 16:00 00:00 8.00 6,263 6,456 INTRM1 DRILL DDRL P Drlg. 6 1/8" X 7" directional hole from 6263' MD to 6456' MD 5963' TVD. AST 6.15 hrs. ADT 7.27 hrs. P/U 127k S/O 108k RT 118kTq on & off 4-5k ECD,s 11.2 Max as 75 units. 01/29/2008 00:00 04:30 4.50 6,456 6,635 INTRM1 DRILL DDRL P Dir. Drilled 6 1/8" x 7" hole from 6,456' to 6,635' MD/6,133' TVD (179') (csg pt 100' TVD above KUP C), ART -0-, AST 3.71 hrs, 9.8 ppg MW, ave ECD 11.1 ave BGG 60 units Page 5 cif 25 • Time Logs __ _ Date From To Dur S Depth E. De th PhaSe Code Subcode T COM 01/29/2008 04:30 05:45 1.25 6,635 6,635 INTRM1 DRILL CIRC P Pumped 30 bbl hi vis sweep and circ out of the hole, had 15% increase in cuttings from the sweep. circ at 250 gpm, 2,100 psi, 80 rpms and 3K ft-Ibs for ue, 11.0 ECD. 05:45 06:00 0.25 6,635 6,635 INTRM1 DRILL OWFF P Monitored well-static 06:00 11:15 5.25 6,635 4,163 INTRM1 DRILL REAM P BROOH from 6,635' to btm of the window at 4,163', BROOH at 250 gpm, 1,900 psi and 80 rpms with no roblems. 11:15 12:00 0.75 4,163 4,163 INTRM1 DRILL CIRC P Circ btms up at BOW, circ at 250 gpm, 1,700 psi, 80 rpm's, st wt up 92K, do wt 85K, calc fill on trip out 14 bbls, actual fill 22 bbls. monitored well at window and was static, oriented 38L and POOH thru window and back thru w/no roblems. 12:00 13:00 1.00 4,163 6,635 INTRM1 DRILL TRIP P RIH from 4,163' to 6,586' then washed to btm at 6,635' with no roblems. 13:00 15:00 2.00 6,635 6,635 INTRM1 DRILL CIRC P Pumped 25 bbl hi vis sweep and circ out of the hole, had 10% increase in cuttings back from the sweep, circ an add. 2X btms up and was clean at the shakers, circ at 250 gpm, 1,800 psi and 60 rpm's. 9.8 ppg MW ECD 10.86 15:00 15:15 0.25 6,635 6,635 INTRMI DRILL OWFF P Monitored well-static 15:15 18:30 3.25 6,635 558 INTRM1 DRILL TRIP P POOH wet on elevators 10 stds to 5,735', hole took calc fill, pumped dry job and blew down, dropped 2" rabbit on a wire and cont. to POOH to BHA at 558'. Observed proper dis lacement. 18:30 19:30 1.00 558 450 INTRM1 DRILL PULD P Breakout & lay down flex drill collars. Plu in, download MWD assembl . 19:30 21:00 1.50 450 0 INTRM1 DRILL PULD P Breakout & lay dowm MWD assembly. Perform function test on Rhino -Reamer, observing reamewr functioning properly. Blow down lines, continue POOH lay down remaining BHA. Inspect & grade bit to 1/2/ER/S/X/1/BT/TD. Clean & dear rig floor area. Send tools out. 21:00 21:45 0.75 0 0 INTRM1 CASINC RURD P Rig up to run 5 1/2" liner assembl . 21:45 22:00 0.25 0 0 INTRM1 CASINC SFTY P Held PJSM with crew, casing hand, and BOT reps. Discuss safety & hazard recognition issues. Discuss procedure to run 5 1/2" liner assembly, and re for cement'ob. ..,..Page t'r of 25 l ~ Time Logs Date From To Dur S De th E. De_pt_h Pha,,,,~e Code Subcode T COM 01/29/2008 22:00 00:00 2.00 0 700 INTRM1 CASIN( RNCS P Make up 5 1/2" Davis Lynch Guide shoe & shoe track assembly with auto fill Float collar. Continue RIH with 5 1/2" Liner assembly. Make up torque = 2300 FT/LBS. Observed proper dis lacement. Crew Chan e 01/30/2008 00:00 03:15 3.25 700 2,700 INTRM1 CASINC RNCS P Continue run 5 1/2" liner as per detail. Ran 65 joints. Observed proper dis lacement. 03:15 04:15 1.00 2,700 2,708 INTRM1 CASIN RNCS P Make up liner hanger assembly with running tool & liner wiper plug. UP VV7' = 64K, SO WT = 66K. 04:15 05:00 0.75 2,708 2,708 INTRM1 CASINC CIRC P Pick up one stand of DP. Break circulation as per BOT rep. Pumps at 1.5 BPM - 550 PSI. Observed fluid loss with higher rates. Circulate liner volume. 05:00 07:30 2.50 2,708 4,129 INTRM1 CASINC RUNL P Continue trip in hole with liner on DP. Install Hyflo valve & crossovers on top of third stand of DP, continuing trip in hole to the window top at 4150'. UP WT = 80K, SO Wf = 77K 07:30 08:00 0.50 4,129 4,129 INTRM1 CASINC CIRC P CBU thru hyflo valve at 1,131' with pumps at 4 BPM - 150 PSI. Blow down lines & To drive. 08:00 10:45 2.75 4,129 6,631 INTRM1 CASINC RUNL P Continue run in hole with liner on DP, going through window area with no issues. Run to 6099' pumping liner in the hole, then dropping 1 3/8" ball to close Hyflo valve and divert flow. Observed pressure to 3300 PSI to shear. Ta ed u at 6631' M 10:45 12:00 1.25 6,631 6,631 INTRM1 CASINC RUNL P Continue circulate @ 1 BPM - 1650 PSI, attempting to gain better rates and ressure, while reci rocatin liner assembl 6631'. UP WT = 95K, SO WT = 60K. Observed 11 BBL fluid loss while circulatin .Crew Chan e 12:00 12:30 0.50 6,631 6,631 INTRM1 CASINC RUNL P Continue circulate attempting to gain better rates and pressures. Unsuccessful. Decision to Pump out of hole. 12:30 14:30 2.00 6,631 5,375 INTRM1 CASINC RNCS T Pum out of hole at slow rate to 5375' um s 1 BPM - 1600 PSI. 14:30 15:30 1.00 5,375 5,375 INTRM1 CASIN CIRC T Observed pump rates getting better, and full circulation, continue staging pumps to 4 BPM - 750 PSI. Had a max as of 660 units. Ptaye 7 of 2~ ~~ Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T COM 01/30/2008 15:30 18:00 2.50 5,375 5,965 INTRM1 CASINC RNCS T Trip back in hole pumping at 1.5 BPM - 750 PSI. Observed tagging up at 5911' MD. Attempt to work assembly through spot, setting down as much as 40K. Obtained pump rates at 3 BPM - 600 PSI. Worked throuoh 5911', and continued to ta4 up once again at 5965'. Reciprocate string, and attempt to work through, no success. Observed no increase in pump pressure when setting down as much as 40K. No trouble or overpull when ullin u . 18:00 20:00 2.00 5,965 5,965 INTRM1 CASIN RNCS T Continue work liner assembly attempting to get through 5965' MD. No success. UP WT = 104K, SO WT = 85K. Decision to POOH with liner assembly. Observed fluid losses when um sat 3 BPM or more. 20:00 00:00 4.00 5,965 3,276 INTRM1 CASIN RNCS T Pump out of hole at slow rate at 1.5 BPM - 350 PSI, to 3276'. Observed no issues with assembly going through window area. Observed proper dis lacement, but hole breathin back 16 BBLS that was previously lost_ when working string, then proper hole fill. Crew Chan e 01/31/2008 00:00 00:45 0.75 3,276 2,708 INTRM1 CASIN RNCS T Continue pump out of hole at slow rate at 1.5 BPM - 450 PSI, to 2708'. Observed ro er dis lacement. 00:45 01:30 0.75 2,708 2,708 INTRM1 CASIN RNCS T Rig up power tongs. Breakout & lay down Liner hanger assembly as per BOT re s. 01:30 05:30 4.00 2,708 200 INTRM1 CASIN RNCS T Continue POOH & la down 5 1/2" liner. Observed ro er hole fill. 05:30 08:30 3.00 200 0 INTRM1 CASIN RNCS T Rig up WACHS pneumatic pipe cutter. Pull, cut and lay down shoe track 'oints. Made total of 4 cuts. 08:30 09:00 0.50 0 0 INTRM1 CASIN OTHR T Clean & clear floor area. Send tools out. 09:00 10:15 1.25 0 0 INTRM1 FISH PULD T Load BHA in pipe shed and obtain stra s on a ui ment. 10:15 12:00 1.75 0 0 INTRM1 FISH PULD T Make up Hughes 6 1/8" Milltooth bit with Stabilizers, and string magnets and HWDP for BHA # 3. Total length = 420.85'. Crew Chan e 12:00 13:00 1.00 0 4,089 INTRM1 FISH TRIP T Trip in hole to 4089'. UP WT = 84K, SO WT = 80K. Break circulation filling drill string. ROT WT = 85K, with 50 RPM's . 13:00 13:45 0.75 4,089 4,089 INTRMI FISH CIRC T Circulate bottomsup, staging pumps to 250 GPM's - 700 PSI, no losses. Blow down lines and To drive. 13:45 14:45 1.00 4,089 5,690 INTRM1 FISH TRIP T Continue trip in hole to 5690' MD. Break circulation. Page 8 of 2~~ • • I Time Logs Date From To Dur S De th E. Depth Phase Code Subcode T COM 01/31/2008 14:45 15:45 1.00 5,690 5,690 INTRM1 FISH CIRC T Reciprocate i~ rotate drill string while pumping at 250 GPM's - 900 PSI, pumping bottoms up. Obtain arameters. 15:45 16:30 0.75 5,690 5,963 INTRM1 FISH TRIP T Continue trip in hole to tag up at 5860' MD setting down 30K. Break circulation and rotata at 50 RPM's to tag and push junk with 5 - 10K down to 5963' MD. Continue attempt to push 'unk, observin no further movement down hole, and for ue to 5K. 16:30 17:45 1.25 5,963 5,963 INTRM1 FISH CIRC T CBU at 250 GPM's 900 PSI. No losses. Monitor well -static. 17:45 20:45 3.00 5,963 0 INTRM1 FISH TRIP T POOH with 5 stands. Pump dry job. Blow down lines and top drive. POOH to BHA. Breakout & lay down bit. Grade bit to 2/3/ER/S!E/SS/BHA. Observed proper displacement on TOH. Clean off string magents with only small debris recovered. No SOB's or Sto collars. 20:45 21:45 1.00 0 432 INTRM1 FISH PULD T Make up 6" Concave 5 bladedmill with 2 Boot baskets. Total BHA = 432.01'. 21:45 00:00 2.25 432 4,100 INTRM1 FISH TRIP T Trip in hole with BHA #4 to 4100'. (TOW). Fill drill string at 3250'. Observed proper displacement. Crew than e 02/01/2008 00:00 01:15 1.25 4,100 5,955 INTRM1 FISH TRIP T Continue trip in hole from 4100' to tag junk at 5955' MD. Pull up, obtain arameters for millin . 01:15 12:00 10.75 5,955 6,357 INTRM1 FISH MILL T e in millin on 'unk in hole from 5955' at 200 GPM's - 800 PSI, 60 RPM's - 3-5 K Torque. Observed junk breaking up and allowing to mill and push junk down hole, continue chasin &millin to 6357' MD increasing RPM's to 90, with 3-5K Torque. Observed no fluid losses. Observed iron cuttings !shavings across shaker screens. Max gas observed at surface - 200 units. Crew Chan e 12:00 14:15 2.25 6,357 6,635 INTRM1 FISH MILL T Continue chasin and milling 'unk in hole from 6357' - 6635' MD. Observed ti ht s of at 6411'. 14:15 18:00 3.75 6,635 5,515 INTRM1 FISH WASH T Attempt to POOH for short trip on elevators. Pull back to 5515', _ observing tight spot. Wash & ream through until cleaned up. Observed overpull up to 20K at 5968' - 5789', washing and reaming to clean up spot. UP WT = 135K, SO WT = 95K. ~'<ac~~ 9 cf 25 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 02/01/2008 18:00 19:30 1.50 5,515 6,082 INTRM1 FISH WASH T Attempt to trip in hole on elevators from 5515'. Once agin washing & reamin ins ots 5791'-5914'. Continue in hole to 6082' MD. Same parameters as above. Observed no fluid losses or gas issues during cleanout. 19:30 20:00 0.50 6,082 5,705 INTRM1 FISH TRIP T Decision to short trip 4 stands back to 5705'and wipe hole again. Observed good clean hole with no tagging up or ove ull. 20:00 21:00 1.00 5,705 6,635 INTRM1 FISH TRIP T Trip back in hole from 5705' to bottom at 6620' with no issues. Wash & ream from 6620' - 6635' with 3-5K WOB. UP WT = 135K, SO WT = 105K. ill on bottom approximately 1.5' of new hole attem tin to mill u ~unk observing no for ue increase. 21:00 22:00 1.00 6,635 6,635 INTRM1 FISH CIRC T Circulate bottoms up at 250 GPM's - 1200 PSI. Reciprocate & work drill string with no issues. Monitor well 10 minutes -static. 22:00 00:00 2.00 6,635 5,044 INTRM1 FISH TRIP T POOH on elevators observing proper hole fill and no issues. Monitor well - static. Pump dry job. Continue POOH to 5044' MD. Crew Chan e 02/02/2008 00:00 01:45 1.75 5,044 430 INTRM1 FISH TRIP T Continue POOH on elevators observing proper hole fill and no issues. Monitor well at the window - static. Continue POOH to 430' MD. 01:45 03:00 1.25 430 430 INTRM1 FISH PULD T Rack back HWDP & jars. Breakout & lay down mill & boot baskets. Clean off string magnets, observing only little amount of shavings. Clean out boot baskets recovering about 15 Ibs of , shale & iron feces stand off bands & sto collars Observed 90% recovery = shale junks, half dollar sized. Inspect float. Make up Rhino reamer assembly as per Smith rep. Make up boot baskets ma nets, and remainin BHA. Total BHA len th = 437.09'. 03:00 05:00 2.00 430 4,150 INTRM1 FISH TRIP T Trip in hole with BHA # 5 to window @ 4150' Clean out assembly. Fill drill string every 20 stands. Observed ro er dis lacement. 05:00 12:00 7.00 4,150 6,559 INTRMI DRILL REAM T Run Rhino reamer through window and begin washing & rotating from 4200' to 6559' MD. Pumps @ 200 GPM's - 870 PSI. Work through tight spots at 5900', continuing down to 6559' MD with little or no trouble. Staged pumps to 250 GPM's - 1500 PSI rotating at 85 RPM's with 5K TQ. Crew Chan e Fagg 'SA of Z5 r~ ~~ Time Logs ____ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 02/02/2008 12:00 12:15 0.25 6,559 6,621 INTRM1 DRILL REAM T Continue reaming from 6559' - 6621', tagging up on junk. Note: TD= 6635'. Work string to attempt to wash past 6621' with no success. 12:15 14:45 2.50 6,621 6,621 INTRM1 DRILL CIRC T Circulate 30 BBL Hi Visc sweep while reciprocate & rotate drill string with pumps at 250 GPM's - 1500 PSI. Pump second sweep with little or no metal shavings across shakers. Monitor well -static. 14:45 16:45 2.00 6,621 4,170 INTRMI DRILL TRIP T POOH on elevators from 6621' - bottom of window. Observed proper displacement. Drop 2" rabbit on wireline in drill strip . 16:45 17:15 0.50 4,170 4,150 INTRM1 DRILL TRIP T Make up Top Drive and perofrm drag test on Rhino reamer as per Smith rep, bringing reamer into casing with no issues of drag. Monitor well - static. UP WT = 85K, SO WT = 82K. Blow down lines and to drive. 17:15 19:30 2.25 4,150 437 INTRM1 DRILL TRIP T Continue POOH on elevators from 4150' - 437'. Observed proper dis lacement. 19:30 21:00 1.50 437 0 INTRM1 DRILL PULD T Breakout & lay down BHA. Inspect Rhino reamer -all good. Clean boot baskets recovering little metal, and shale. 21:00 21:45 0.75 0 0 INTRM1 DRILL PULD T Clean & clear rig floor. Send tools out. Pull a ui ment to ri floor for liner run. 21:45 22:15 0.50 0 0 INTRM1 CASIN( RURD T Rig up power tongs and equipmemt to run 5 1/2" liner. make u fill u line. 22:15 22:30 0.25 0 0 INTRM1 CASIN SFTY T Held PJSM with crew, BOT rep, and casing hand. Discuss safety & hazard recognition issues. Discuss procedure to run 5 1/2" liner assembl . 22:30 00:00 1.50 0 240 INTRM1 CASIN RNCS T Make up shoe track and baker lock all shoe track joints. Fill liner, and check floats. Continue RIH with 5 1/2" HYD 511 casing, with make up torque to 2300 ft/Ibs. Observed proper dis lacement. Crew Chan e 02/03/2008 00:00 02:45 2.75 240 2,701 INTRM1 CASIN RNCS T Continue RIH with 5 1/2" HYD 511 casing from 240' - 2701', with make up torque to 2300 ft/Ibs. Fill each joint, ran 65 joints total as per detail. Observed ro er dis lacement. 02:45 04:00 1.25 2,701 2,701 INTRM1 CASIN( RNCS T Make up Baker Liner hanger asembly as per BOT rep. Rig up and break circulation to verify liner and tools clean. 04:00 05:00 1.00 2,701 4,120 INTRM1 CASIN RUNL T Run liner on DP from 2701' - 4120' above the window. UP WT = 64K, SO WT = 64K. 05:00 06:00 1.00 4,120 4,120 INTRM1 CASINC CIRC T Circulate DP & liner volume condiitioning mud for cement job. Pum s sta ed to 5 BPM - 800 PSI. ~acJe 11 z~f 25 r~ • Time Logs _~ ___ Date From To Dur S De th E. De th Phase Code Subcode T COM 02/03/2008 06:00 08:30 2.50 4,120 6,620 INTRM1 CASIN( RUNL P Continue run 5 1/2" Liner on DP into open hole, filling every 10 stands to 6558' MD. Circulated liner down to tag at 6620' MD. Set down 20K. 08:30 09:00 0.50 6,620 6,620 INTRM1 CASIN RUNL P Lay down 1 joint of DP, install 10' pup and cement head. Make up lines, and check cement head. 09:00 12:00 3.00 6,620 6,620 INTRM1 CEME CIRC P Circulate & condition mud with pumps staged to 4 BPM - 950 PSI. Reci rocat r' UP WT = 120K, SO WT = 90K. Crew Chan e 12:00 13:00 1.00 6,620 6,620 INTRM1 CEME CIRC P Continue circulate & condition mud with pumps staged to 4 BPM - 950 PSI. Reciprocate string in 15' increments. UP WT = 120K, SO WT = 90K. Rig up Dowell cementing crew. Batch mix. 13:00 15:15 2.25 6,616 6,616 INTRM1 CEME DISP P Dowell pumped 5 bbls of CW 100 then pressure tested lines to 4,500 psi, after beginning to pump, to-torq valve leaked, changed out same and cont. ~ to pumped 35 bbls of add. CW 100 at 8.5 ppg, then pumped 20 bbls of 11.2 ppg mudpush at 3.7 bpm at 800 psi.. Mixed and pumped 60 bbls, 150 sxs of lead cement at 12.5 ppg and 2.11 yield with additives, ave 3.8 bpm at an ave of 400 psi, then batched mix 15 bbls, 60 sxs of class "G" at 15.8 ppg, 1.17 yield with GasBloc and additives, ave 3 bpm at 300 psi reciprocated liner while pumping cement. Dropped Baker pump down wiper plug and Dowell displaced the cement with 9.8 ppg LSND mud at ave 4 bpm, initial pressure was 275 psi, max pressure at 4 bpm was 1,276 psi, slowed to 3 bpm at 1,060 psi and saw LWP plug shear and cont. to pump and bumped LWP on talc displacement 101.7 bbls. Pressured up to 3,600 psi and held for 5 minutes, bled off 1 bbl and checked floats and floats held. Reciprocated liner 30 bbls into displacement with lead cement at the shoe and had good returns through out the job. CIP at 14:52 hrs. Liner set at 6,616' ( 9' off btm due to fill & ossible 'unk 15:15 15:30 0.25 6,616 6,616 INTRM1 CEME OTHR P Set hanger then packer as per BOT re .Pull dogs out of tie back sleeve. Set down 35K to set packer. Observed screws sheared. Top of liner @ 3924' M D. 15:30 16:00 0.50 6,616 6,616 INTRM1 CEME RURD P Lay down 1 joint & cement head & lines. F~~ge 12 of 2~ Time Logs Date From To Dur S. De th E_Depth Phe Code Subcode T COM 02/03/2008 16:00 17:30 1.50 6,463 6,463 INTRM1 CEME CIRC P PU and circ hole the long way at 300 gpm, 1,000 psi, saw CW 100 and 20 bbls Mud Push back at surface, no cement but must be close to top of liner, LD plug head and reversed out 1 complete circulations at 250 gpm at 650 then stood back 1 std and circulate 1 complete circulation the Ion wa while reci rocatin the i e. 17:30 18:15 0.75 6,463 6,463 INTRM1 CEME PULD P Breakout & lay down cement head off of'oint of DP. Monitor well -static. 18:15 20:45 2.50 6,463 0 INTRM1 CEME PULD P POOH on elevators from TOL to surface. Inspect & breakout running tools. La down same. 20:45 21:30 0.75 0 0 INTRMI CEME PULD P Clean & clear rig floor. Send tools out. 21:30 23:00 1.50 0 0 INTRM1 RIGMN' SVRG P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to slip & cut, and new hands. Slip & cut 68' of drillin line. 23:00 23:30 0.50 0 0 COMPZ RPCOh PULD P Decision to suspend well for moving, ri to ex loration. Pull tubing running e ui ment to ri floor. 23:30 00:00 0.50 0 0 COMPZ RPCO PULD P Make up pulling tool for pulling Cameron wear bushing. Drain BOP stack. Crew Chan e 02/04/2008 00:00 00:15 0.25 0 0 COMPZ RPCOh PULD P BOLDS, Pull and lay down wear bushin . 00:15 05:15 5.00 0 6,203 COMPZ RPCO PULD P Make up Slimhole tbg collar on bottom of joint, continue run in hole with 3 1/2" IBTM tubing, picking up from pipe shed. Observed proper displacement. make up torque = 1500 ft/Ibs. Observed no issues going through top of liner at 3924'. Ran a total of 198 ~oints. Tubin tail at 6227'. 05:15 07:00 1.75 6,203 6,227 COMPZ RPCO PULD P Make up 3 1/2" tubing hanger and crossover pup. Make up landing joint. Run in hole to land hanger. RILDS. Install BPV 07:00 08:00 1.00 6,227 6,227 COMPZ RPCO DHEQ P Ri u & Test Liner hanger & casing pSl for 3Q minutes reco~ on chart. 08:00 09:00 1.00 0 0 COMPZ WELC NUND P Change out lower pipe rams, installiing 5" solids. 09:00 10:00 1.00 0 0 COMPZ WELC NUND P Nipple down BOP stack, choke & kill lines. 10:00 11:30 1.50 0 0 COMPZ RPCOb DHEQ P Nipple up Cameron 5K tree as per rep. test hanger void, and flange to 5K - 15 minutes. 11:30 12:00 0.50 0 0 COMPZ RPCO DHEQ P Make up scaffold assembly on tree. Crew chan e 12:00 12:30 0.50 0 0 COMPZ RPCOh DHEQ P Rig up lines, and test tree to 5K - 15 minutes, as er re . Page 13 cat 2 ~~ Time Logs __ Date From To Dur S. De th E: DeUth Ph se Code Subcode T_ COM _ ~ 02/04/2008 12:30 15:00 2.50 0 0 COMPZ RPCO FRZP P Held PJSM with crew & Little Red services rep. Rig up lines. Pump 90 BBLS of freeze protect diesel at 2 BPM -with max ressure to 1000 PSI. 15:00 17:00 2.00 0 0 COMPZ RPCO FRZP P Line up and allow well to U-tube until dead. SIMOPS: Breakout & lay down 4" DP from derrick. Clean its. 17:00 18:30 1.50 0 0 COMPZ RPCO FRZP P Breakout lines in cellar on tree. Install BPV as per rep, and secure well. Shut in pressures = TBG - 0 PSI. IA = 0 PSI. OA = 0 PSI. 18:30 23:30 5.00 0 0 COMPZ RPCO OTHR P Continnue breakout & lay down all 4" DP in derrick. Clean its. 23:30 00:00 0.50 0 0 COMPZ RPCOh OTHR P Remove mousehole from rotary table. Secure well. Rig down scaffolding. Begin change out saver sub on Top Drive. rig released at 2359 HRS. Rig on standby for move to CHAR #1, ex loration. 02/14/2008 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Midnight till rig released from 3K-102 03:00 04:00 .1.00 0 0 MIRU MOVE MOB P Raise feet on sub base, warm up movin sustem on it module 04:00 04:45 0.75 0 0 MIRU MOVE MOB P Move pit module off rig mats. 04:45 05:30 0.75 0 0 MIRU MOVE MOB P Pick up and load out rig mats 05:30 06:00 0.50 0 0 MIRU MOVE MOB P Stage pit module at pad entrance for ri move. 06:00 12:30 6.50 0 0 MIRU MOVE MOB P Begin moving sub and pit modules from 3K to 3C 12:30 14:00 1.50 0 0 MIRU MOVE MOB T Repair drag link on steering 14:00 18:00 4.00 0 0 MIRU MOVE MOB P Continue moving sub and pit modules 18:00 19:00 1.00 0 0 MIRU MOVE MOB P Spot shop and parts trailer on 3C 19:00 22:30 3.50 0 0 MIRU MOVE MOB P Move pit module across rig mats 22:30 00:00 1.50 0 0 MIRU MOVE MOB P Finish laying rig mats and move sub to ed a of mats 02/15/2008 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Move sub onto mats and spot over 3C-14A. 03:00 04:30 1.50 0 0 MIRU MOVE MOB P Move pit module onto mats and spot next to sub 04:30 06:00 1.50 0 0 MIRU MOVE MOB P PJSM -skidding rig floor. Skid floor, install hand rails and spread herculite. Sim ops -Drilling Tool House rigging up tank, choke skid and hard lines for dis lacin freeze rotect diesel. 06:00 06:30 0.50 0 0 MIRU MOVE RURD P Rig up lines and beaver slide. Berm around ri . 06:30 06:30 0.00 0 0 MIRU MOVE OTHR P Rig accepted 06:30 12:30 6.00 0 0 MIRU RPCOh RURD P Rig up on well. ~'~g~ °!4 of 25 ra r~~ Time Logs _ Date From To Dur S. De th E. Depth Ph se Code _Subcode T COM 02/15/2008 12:30 13:00 0.50 0 0 MIRU RPCOh RURD P Load mud for displaceing freeze rotect diesel into its. 13:00 15:30 2.50 0 0 MIRU RPCOh RURD P Ri u lubricator to pull back pressure valve. Pull BPV and rig down lubricator. 15:30 15:45 0.25 0 0 MIRU RPCO SFTY P PJSM -displacing freeze protect diesel. 15:45 17:00 1.25 0 0 MIRU RPCO OTHR P Flood lines and pressure test. 17:00 19:15 2.25 0 0 MIRU RPCO OTHR P Displace freee protect diesel. Pumped 30 bbls mud into annulus and then 110 bbls mud thru tubing. Blow down lines and choke skid. U-tube for 10 min. and check for flow - no flow. Rig down lines from tree and wellhead. 19:15 20:45 1.50 0 0 MIRU RPCOh NUND P Install back ressure valve and dart for two wa the k. 20:45 21:30 0.75 0 0 MIRU RPCO DHEO P Pressure test two way check valve and hanger seals, 250 low/5000 high. Charted test. 21:30 22:30 1.00 0 0 MIRU RPCO NUND P Nipple down tree 22:30 00:00 1.50 0 0 MIRU WELCT NUND P Install double stud adapter, riser and BOP stack. 02/16/2008 00:00 01:00 1.00 0 0 MIRU WELCT NUND NP Lift stack to change bottom rams. Ram doors too close to work platform and won't o en. 01:00 02:00 1.00 0 0 MIRU WELC NUND P Change bottom rams to 2-7/8" 02:00 05:00 3.00 0 0 MIRU WELCT NUND P Set down stack and tighten flanges. Ni le u choke and kill lies 05:00 07:00 2.00 0 0 MIRU WELCT NUND P Change top rams to 3-1/2" x 6" 07:00 10:30 3.50 0 0 MIRU RPCOM1 RURD P Bring tools to rig floor and change out saver sub, bell guide and dies on top drive. Obtain elevations. 10:30 12:00 1.50 0 0 MIRU WELC NUND P Pick up and make up bell nipple with added extension 12:00 12:30 0.50 0 0 MIRU RPCOb RURD P Fill stack 12:30 13:00 0.50 0 0 MIRU WELCT BOPE T Repair test pump controls 13:00 13:30 0.50 0 0 MIRU WELCT BOPE P Be in BOPE test. Witness wavied b AOGCC John Cris . 13:30 14:30 1.00 0 0 MIRU WELC NUND NP Change out Oteco ring, API ring and rotate kill line flange due to shorter stack 14:30 18:30 4.00 0 0 MIRU WELCT BOPE P Testing BOPE 18:30 19:00 0.50 0 0 MIRU WELCT BOPE P Blow down kill line and choke manifold Page 15 caf 25 Time Logs _ _ ' __ Date From To Dur S De th E. De th Phase Code Subcode T COM ~ 02/16!2008 19:00 23:00 4.00 0 0 MIRU WELCT BOPE P Testing BOPE. Z-7l8" not tested. Space out from hanger to bottom pipe rams same length as cross over and pup joint that is on bottom of full 2-7/8" joint. Ordered new equipment and will test after 3-1/2" kill string out of hole. Draw down test, start 3025 psi, function rams 1700 psi, 31 seconds to increase by 200 psi, 2 minutes 34 seconds to full char e 23:00 00:00 1.00 0 0 MIRU WELCT NUND P Rig down test equipment 02/17/2008 00:00 00:30 0.50 0 0 MIRU RPCOti NUND P Pull back pressure valve and 2-way dart valve 00:30 01:30 1.00 6,227 6,210 MIRU RPCOh RURD P Make up landing joint, back out lock down screws and pull hanger. Hanger pulled free at 20k over block weight. PU wt 122k 01:30 03:30 2.00 6,210 6,210 MIRU RPCO CIRC P Rig up head pin and circulate out old mud, um in 298 m, 990 si. 03:30 03:45 0.25 6,210 6,210 MIRU RPCOA OWFF P Monitor well -static 03:45 04:15 0.50 6,210 6,210 MIRU RPCO CIRC P Pump 20 bbl dry job 04:15 08:15 4.00 6,210 0 MIRU RPCOti RCST P PJSM -pull completion. Pull out of hole on elevators, record weigths every 10 stands. Rack tubin in derrick. 08:15 09:00 0.75 0 0 MIRU RPCO OTHR P Clear and clean rig floor 09:00 10:45 1.75 0 0 MIRU WELC BOPE P Ri up and test 2-7/8" rams, rig down test a ui ment 10:45 11:15 0.50 0 0 MIRU DRILL PULD P Install wear bushing 11:15 12:15 1.00 0 0 MIRU DRILL PULD P PJSM -picking up drill pipe. Pick up 27 joints of 4" drill pipe and rack back in derrick. 12:15 13:45 1.50 0 0 PROD1 DRILL PULD P Pick up BHA 13:45 14:15 0.50 0 0 PROD1 DRILL SFTY P Recognition for 1 year with no LTAs 14:15 15:30 1.25 0 85 PROD1 DRILL PULD P Continue to pick up BHA 15:30 15:45 0.25 85 85 PROD1 DRILL DHEO P Rig up to upload MWD 15:45 17:45 2.00 85 85 PROD1 DRILL DHEQ T Upload MWD. Tools not uploading. 17:45 18:15 0.50 85 85 PROD1 DRILL DHEQ T Lay down pulser, BM & TM and pick u back u tools. 18:15 19:15 1.00 85 85 PROD1 DRILL DHEQ T Test tools -tested good, upload MWD 19:15 19:30 0.25 85 85 PROD1 DRILL DHEO P Rig down from uploading MWD 19:30 21:00 1.50 85 198 PROD1 DRILL PULD P Pick up 2 non-mag flex collars, cross over, bumber sub, jars and 1 spiral drill collar P~~~ i6 cif 25 Time Logs Date From To Dur S De th E. De th Phase Code Subcode T _ COM 02/17/2008 21:00 21:30 0.50 198 198 PROD1 DRILL DHEQ _ P Shallow pulse test MWD, pumping 140 m, 940 si. 21:30 21:45 0.25 198 198 PROD1 DRILL PULD P Blow down top drive. 21:45 22:00 0.25 198 258 PROD1 DRILL PULD P Pick up 2 spiral drill collars 22:00 22:30 0.50 258 258 PROD1 DRILL OTHR P Clear and clean rig floor 22:30 00:00 1.50 258 1,027 PROD1 DRILL TRIP P Single in hole with 2-7/8" drill pipe, drifting to 1.32". Monitoring well via trip tank, recording weigths every 5 stands. PU wt 90k, SO wt 90k. 02/18/2008 00:00 00:30 0.50 1,027 1,027 PROD1 DRILL SFTY P Safety recognition, 1 year no LTA's 00:30 03:30 3.00 1,027 3,392 PROD1 DRILL TRIP P Single in hole with 2-7/8"drill pipe, drifting to 1.32". Monitoring well via trip tank, recording weigths every 5 stands. PU wt 112k, SO wt 110k. Fill pipe @ 2630' MD, pumping 131 gpm, 1480 si 03:30 04:45 1.25 3,392 3,392 PROD1 DRILL RURD P Clear and clean rig floor, rig down double stack tongs, change out elevators and sli s. 04:45 06:00 1.25 3,392 4,609 PROD1 DRILL TRIP P Single in hole with 4"drill pipe, drifting to 2.33". Monitoring well via trip tank, recording weigths & torque every 5 stands. PU wt 112k, SO wt 110k, rot wt 110k, Tor ue 2k 30 r m. 06:00 08:45 2.75 4,609 6,296 PROD1 DRILL TRIP P Single in hole with 4"drill pipe, drifting to 2.34". Monitoring well via trip tank, recording weigths & torque every 5 stands. 08:45 09:15 0.50 6,296 6,484 PROD1 DRILL TRIP P Wash down 2 stands, pumping 118 m, 1590 si. Rotatin wt 140k 09:15 10:15 1.00 6,484 6,484 PROD1 DRILL CIRC P Circulate bottoms up, pumping 130 m, 1840 si 10:15 11:45 1.50 6,484 6,484 PROD1 DRILL DHEQ P Blow down top drive, rig up to test casing to 2500 psi for 30 minutes, tested ood. Ri down test a ui ment 11:45 12:00 0.25 6,484 6,541 PROD1 DRILL CIRC P Obtain drilling parameters, tag cement/plugs. Pumping 130 gpm, 1840 psi, rotating 40 rpm, 4k torque. PU 150k, SO 130k, rotatin wt 140k 12:00 14:30 2.50 6,541 6,635 PROD1 CEME COCF P Drill float equipment and shoe track. 14:30 17:00 2.50 6,635 6,667 PROD1 DRILL DDRL P Drill 20' new hole. Pumping 128 gpm, 1730 si. 17:00 18:00 1.00 6,667 6,647 PROD1 DRILL CIRC P Circulate bottoms up, 131 gpm, 1750 si. 18:00 19:30 1.50 6,647 6,600 PROD1 DRILL CIRC P Displace 9.9 ppg LSND with 14.3 ppg Flo-pro. 130 gpm, 1750 psi. Before displacement, PU wt 170k, SO wt 135k, rotating wt 150k. After displacement,PU wt 138k, SO wt 135k, rotating wt 138k. Torque @ 50 r m 3k Page 17 eaf 25 Time Logs ___ __ Date From To Dur S. De th E. De th Ph se Code Subcode T COM 02/21/2008 08:45 10:15 1.50 4,765 6,856 PROD1 DRILL TRIP T TIH on elevators, monitoring well via tri tank. PU wt 155k, SO wt 130k 10:15 14:15 4.00 6,856 6,896 PROD1 DRILL D RL P Drilling 4-3/4" production hole. Observed increase in off bottom stand pipe pressure while trying to get surve . Possibl lu ed 'et. 14:15 15:15 1.00 6,896 6,859 PROD1 DRILL T IP T Pull off bottom to troubleshooting ressure increase. 15:15 16:00 0.75 6,859 6,859 PROD1 DRILL CI C T Pump sweeps, 5 bbl water followed by 10 bbl, 14.2 ppg, 300 vis. Circulate total of 85 bbls, pumping 121 gpm, 3460 si. 16:00 16:30 0.50 6,859 6,896 PROD1 DRILL R M T Rotate back to bottom. Standpipe pressure 3090 psi. Observed 700 psi decrese in off bottom stand pipe ressure while t in to et surve . 16:30 16:45 0.25 6,896 6,888 PROD1 DRILL T IP T Pull off bottom and pressure test surface a ui ment -all ood. 16:45 17:00 0.25 6,888 6,888 PROD1 DRILL O F T Monitor well -static 17:00 18:00 1.00 6,888 5,173 PROD1 DRILL T IP T POOH on elevators, monitoring well via trip tank. PU wt 148k, SO wt 130k. crew than e. 18:00 19:00 1.00 5,173 3,389 PROD1 DRILL T IP T POOH on elevators, monitoring well via tri tank. 19:00 19:45 0.75 3,389 3,389 PROD1 DRILL R RD T Monitor well while rigging down 4" handling equipment and rigging up 2-7/8" 19:45 22:00 2.25 3,389 256 PROD1 DRILL T IP T POOH on elevators, monitoring well via tri tank. 22:00 22:45 0.75 256 0 PROD1 DRILL P LD T Lay down BHA. Found pulser and flow tube washed out. One 'et lu ed. 22:45 00:00 1.25 0 0 PROD1 DRILL P LD T Download MWD. 02/22/2008 00:00 01:00 1.00 0 0 PROD1 DRILL P LD T Continue downloading MWD. 01:00 02:30 1.50 0 0 PROD1 DRILL P LD T Change out pulsar and flow tube - I washed out. 02:30 03:00 0.50 0 0 PROD1 DRILL P LD T Upload MWD 03:00 04:00 1.00 0 253 PROD1 DRILL P LD T Make up BHA and shallow pulse test, pumping 128 gpm, 2100 psi. Tested ood. 04:00 04:15 0.25 253 253 PROD1 DRILL R RD T Rig down slim hole handling tools 04:15 06:00 1.75 253 2,818 PROD1 DRILL TRIP T Trip in hole on elevators with 2-7/8" drill pipe. Fill pipe @ 2230' MD. Blow down top drive. Monitoring dis lacement via tri tank. 06:00 06:45 0.75 2,818 3,389 PROD1 DRILL TRIP T Trip in hole on elevators with 2-7/8" drill pipe. Fill pipe every 25 stands. Monitorin dis lacement via tri tank. 06:45 07:15 0.50 3,389 3,389 PROD1 DRILL RURD T Change out 2-7/8" handling tools. Rig u 4" tools F'ag~ 2~ ~t 25 Time Logs __ _____ _ Date From To Dur S. De th E. De th Phase Code Subcode T COM _ 02/22/2008 07:15 09:15 2.00 3,389 6,858 PROD1 DRILL TRIP T Trip in hole with 4"drill pipe. Fill pipe @ 4985' MD, pumping 126 gpm, 2910 psi. Monitoring displacement via trip tank. 09:15 09:45 0.50 6,858 6,896 PROD1 DRILL REAM T Wash to bottom, pumping 123 gpm, 3500 si 09:45 12:00 2.25 6,896 6,923 PROD1 DRILL DDRL P Resume drilling 4-3/4" production hole 12:00 13:00 1.00 6,923 6,953 PROD1 DRILL DDRL P Drill 4-3/4" roduction hole to TD. 6953.2' MD 6402.8 TVD 13:00 15:30 2.50 6,953 6,953 PROD1 DRILL CIRC P Circulate bottoms up, reciprocating pipe 90'. Pumping 140 gpm, 3730 psi, rotating 50 rpm, torque 3k. Pump 40 bbl hi-vis sweep, circulate sweep out (10% cuttings increase) plus 1 bottoms u . 15:30 15:45 0.25 6,953 6,953 PROD1 DRILL OWFF P Monitor well -static 15:45 16:45 1.00 6,953 6,610 PROD1 DRILL REAM P Pump out of hole. Pumping 120 gpm, 2910 psi. PU wt 148k, SO wt 130k. Monitorin well via active s stem. 16:45 17:00 0.25 6,610 6,610 PROD1 DRILL OWFF P Monitor well -static 17:00 18:00 1.00 6,610 5,360 PROD1 DRILL TRIP P Trip out of hole on elevators, racking back enough 4"drill pipe to support 2-7/8" in derrick. Monitoring hole fill via tri tank. PU wt 130k SO wt 112k. 18:00 18:30 0.50 5,360 4,516 PROD1 DRILL TRIP P Trip out of hole on elevators, racking back enough 4"drill pipe to support 2-7/8" in derrick. Monitoring hole fill via tri tank. PU wt 130k SO wt 112k. 18:30 20:30 2.00 4,516 3,389 PROD1 DRILL TRIP P Trip out of hole on elevators, laying down 4" to pipe shed. Monitoring hole fill via tri tank. 20:30 22:00 1.50 3,389 3,389 PROD1 DRILL RURD P Rig down 4" handling equipment and ri u 2-7/8" 22:00 23:45 1.75 3,389 256 PROD1 DRILL TRIP P Trip out of hole with 2-7/8"drill pipe 23:45 00:00 0.25 256 256 PROD1 DRILL OWFF P Monitor well -static. 02/23/2008 00:00 01:15 1.25 256 0 PROD1 DRILL PULD P Continue laying down BHA#3. 01:15 02:00 0.75 0 0 PROD1 DRILL PULD P Download MWD 02:00 02:45 0.75 0 0 PROD1 DRILL PULD P Break down and lay down BHA per S er Sun Re . 02:45 03:30 0.75 0 0 PROD1 DRILL RURD P Rig down slimhole handling tools and clear r floor 03:30 04:00 0.50 0 0 COMPZ DRILL RURD P Rig up for tools 3-1/2" liner 04:00 04:45 0.75 0 0 COMPZ DRILL RURD P Pick up cement head and make up 15" drill pipe pup to top of cement head. Lower cement head to pipe shed, spin 180 degrees, pick it up and make up 2-7/8" cross over to bottom of cement head. Paga 21 0€25 ~~ Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T COM 02/23/2008 04:45 05:00 0.25 0 0 COMPZ CASIN SFTY P PJSM -with GBR and Baker on runnin 3-1/2" 05:00 06:00 1.00 0 400 COMPZ CASIN( RUNL P TIH with 3-1/2" liner. Check float equipment. Monitor displacement via tri tank. 06:00 06:15 0.25 400 599 COMPZ CASIN RUNL P TIH with 3-1 /2" liner 06:15 06:45 0.50 599 640 COMPZ CASIN RUNL P Pick up ZXP liner top packer and HMC liner han er 06:45 07:15 0.50 640 640 COMPZ CASINC RURD. P Rig down GBR equipment, change out elevators, sfi sand clear ri floor 07:15 07:45 0.50 640 640 COMPZ CASINC RURD P Rig up 2-7/8" handling equipment 07:45 08:15 0.50 640 640 COMPZ CASINC RURD P Rig up line to fill liner from mud manifold 08:15 09:00 0.75 640 640 COMPZ CASINC RUNL P Mix and pour PAL mix into liner sleeve and let setu .Service to drive. 09:00 09:45 0.75 640 735 COMPZ CASIN RUNL P Trip in hole with 3-1/2" liner and one stand of drill pipe. Check floats. Pump 1 bpm - 110 psi, 2 bpm - 180 psi, 3 bpm - 310 psi, 4 b m - 470 si 09:45 12:00 2.25 735 2,537 COMPZ CASIN< RUNL P Trip in hole with 3-1/2" liner on 2-7/8" drill pipe. Filled pipe at 1589' MD, um in 2 b m, 290 si 12:00 18:00 6.00 2,537 5,857 COMPZ CASIN RUNL P Trip in hole with 3-1/2" liner on 2-7/8" drill pipe. Filled pipe at 3485' MD, pumping 2bpm, 720 psi, 4433' MD, pumping 2bpm, 960 psi, 5383' MD, um in 2 b m, 810 si 18:00 18:45 0.75 5,857 6,613 COMPZ CASINC RUNL P Trip in hole with 3-1/2" liner on 2-7/8" drill i e. 18:45 22:30 3.75 6,613 6,613 COMPZ CASINC CIRC P Circulate surface to surface at 5-1/2" shoe. Stage pumps to 1.5 bpm, 1210 si. 22:30 23:00 0.50 6,613 6,951 COMPZ CASINC RUNL P Trip in hole with 3-1 /2" liner on 2-7/8" drill pipe. Tagged bottom on depth. Monitor well via tri tank 23:00 00:00 1.00 6,951 6,951 COMPZ CASIN RUNL P Pick up and make up cement head and lines 02/24/2008 00:00 04:45 4.75 6,951 6,951 COMPZ CEME~ CIRC P Circulate and recpirocate pipe 15'. Stage pumps from .5 bpm to 2bpm. Pump full surface to surface volume. PU wt 135k, SO wt 125k. Pumping .5 bpm, 860 psi 1 bpm, 1110 psi 1.5 bpm, 1340 psi 2 b m, 1570 si 04:45 05:00 0.25 6,951 6,951 COMPZ CEMEC` SFTY P PJSM with Schlumberger and Baker, cementin 3-1/2" liner gage ~2 at Z a • i Time Logs _ _ Date From To Dur S. De th E Depth Phase Code Subco__de T COM _ 02/25/2008 03:45 04:00 0.25 0 0 COMPZ RPCOh SFTY P PJSM -running tubing with Baker and GBR. 04:00 06:00 2.00 0 427 COMPZ RPCOh RCST P Run in hole with 3-1 /2" production tubing from derrick. Monitoring dis lacement via tri tank 06:00 10:30 4.50 427 4,310 COMPZ RPCO RCST P Continue running tubing from derrick. PU wt 100k, SO wt 100k. 10:30 11:30 1.00 4,310 4,317 COMPZ RPCOA RURD P Rig up sheave in derrick to run SSSV control line. Connect control line to SSSV and test line to 5000 psi for 10 minutes. 11:30 16:00 4.50 4,317 6,233 COMPZ RPCOh RCST P Continue running tubing from derrick. PU wt 228k, SO wt 215k. 16:00 18:00 2.00 6,233 6,233 COMPZ RPCO RCST P Run in hole to locate seals for space out. Lay down 3 joints and pick up 3 u s for s ace out 10.07', 9.81', 7.83' 18:00 18:15 0.25 6,233 6,233 COMPZ RPCOti PULD P Make up landing joint to hanger 18:15 18:30 0.25 6,233 6,250 COMPZ RPCOh PULD P Connect SSSV control line to hanger 18:30 19:15 0.75 6,250 6,296 COMPZ RPCOh DHEQ P Pressure test aaker to 2 - held ressure. 19:15 19:45 0.50 6,296 6,296 COMPZ RPCOh RURD P Rig up for displacing well to seawater. 19:45 21:15 1.50 6,296 6,296 COMPZ RPCO CIRC P Displace well to seawater, pumped 270 bbls. Mix and pump 25 bbls corrosion inhibitor mixed with seawater. Chased CI pill with 55 bbls of seawater 21:15 21:30 0.25 6,296 6,296 COMPZ RPCOh OTHR P Blow down kill line. 21:30 22:30 1.00 6,296 6,333 COMPZ RPCOh RCST P Land han er and run in lock down screws. Ri u to test. 22:30 00:00 1.50 COMPZ RPCOh RCST P Test tubin to 2500 si for 15 minutes and 7" x 3-1/2" annulus to 2500 si for 3 minutes. Shur dump valve. Pressure up tubing and annulus and close SSSV. Bleed off tubing and monitor tubing for returns - no returns. Pressure up tubing and open SSSV. All tests charted. 02/26/2008 00:00 01:00 1.00 0 0 COMPZ RPCO RURD P Rig down test equipment and blow down lines 01:00 01:30 0.50 0 0 COMPZ RPCOh RURD P Break out circulating head, pull landing joint and rig down control line sheave. 01:30 02:00 0.50 0 0 COMPZ RPCOti RURD P Set back pressure valve and cut control line 02:00 05:00 3.00 0 0 COMPZ RPCOh RURD P Rig down flow line, pull bell nipple and nipple down BOP. Pull and lay down mouse hole. Bleed koome 05:00 06:00 1.00 0 0 COMPZ RPCOh NUND P P/U Tree and Orient per DSO 06:00 06:30 0.50 0 0 COMPZ RPCOh RURD P R/U to Test Tree & Pack Off rage 2~ gat ~~ i • l ~ Time Logs _ Date From_ To Dur S. Depth E, Depth Phase Code Subcode._. T ___. _ ____ COM ____ __ 02/26/2008 06:30 07:30 1.00 0 0 COMPZ RPCO DHEQ P Test Void of Upper and Lower Tubing Hanger Seals U 250 Psi (Low) & 5,000 Psi (High) -- Good; Test Control Line on SSSV U 5,000 Psi -- Good 07:30 09:00 1.50 0 0 COMPZ RPCOh DHEQ P Test Tree U 250 Psi (Low) & 5,000 Psi Hi h -- Good 09:00 09:30 0.50 0 0 COMPZ RPCOh RURD P R/U to Freeze Protect 3 1/2" X 7" Annulus and 3 1/2" Tubin 09:30 11:00 1.50 0 0 COMPZ RPCOh FRZP P Freeze Protect 3 1/2" X 7"Annulus & 31/2" Tubing w/ 100 Bbl Diesel Pumped @ 1.5 Bpm & 900 Psi; Shut In Annular Pressure after Dis lacement = 0 Psi 11:00 11:30 0.50 0 0 COMPZ RPCOh RURD P Rig Down Little Red Equipment & Blow Down Lines 11:30 12:00 0.50 0 0 COMPZ RPCO OTHR P Install 81ank Flanges on IA and Tubing Annulus Tree Ports 12:00 14:30 2.50 0 0 COMPZ MOVE DMOB P Blow Down water and Steam Lines to Rig Floor; Prep to Skid Floor, Clean Pits; R/D Rock Washer; Rig Released 1430 to Move f/ 3C-14A to 1 D-141A [ ~'~€~~ 2~ of 25 3C-14 Well Summary 3/3/08 GAUGED TBG TO 2.70". RA~25" BAILER TO 6688' SLM. REC SAMP~APPARENT CMT. IN PROGRESS. 3/4/08 SET CATCHER @ 6252' RKB. PULLED SOV @ 2544', REPLACED WITH DV. MITIA 2500 PSI, PASSED. PULLED ALL DVs. SET GLV @ 2544' RKB. IN PROGRESS. 3/5/08 SET NEW GLVs @ 4066', 5082', 5873', OV @ 6172' RKB. PULLED CATCHER @ 6219' SLM. READY FOR CTU FCO. 3/9/08 Perform Fill Clean out, Jet tubing down to PBTD tag @ 6828 CTMD. Displaced tubing with diesel, Turned over to S/L. 3/11/08 DRIFT TUBING W/ 20' OF 2.5" DMY GUN TO 6819' SLM. JOB COMPLETE. 3/14/08 PERFORATED WITH 2.5" POWERJET HSD 6 SPF AND 60 DEG PHASING FROM 6789- 6803'. TUBING PRESSURE 0 PSI BEFORE PERFORATING AND 2000 PSI AFTER PERFORATING. • i ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. NAD83-NAD27 Local Co-ordinate Reference: We113C-14 Project: Kuparuk River Unit ND Reference: 3C-14A (D15) @ 88.45ft (Doyon 15) Site: Kuparuk 3C MD Reference: 3C-14A (D15) @ 88.45ft (Doyon 15) Well: 3C-14 North Reference: True Wellbore: 3C-14A Survey Calculation Method: Minimum Curvature Design: 3C-14A Database; CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3C-14 : -- Well Position +N/S 0.00 ft Northing: 5,995,180.01 ft Latitude: 70° 23' 52.506 N +E/-W 0.00 ft Easting: 528,345.63 ft Longitude: 149° 46' 9.594 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 47.60ft , Wellbore 3C-14A Magnetics Model Name Sample Date Declination Dip Angle Field Strength i BGGM2007 ?/16/2008 6GGM2007 2/16/2008 17.82 17.82 79.78 57.274 79Ju ___ 57,27 Design ___ 3C-14A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,103.45 Vertical Section: Depth From (ND) +N/-S +EI-W Direction (ft) lft) Iftl (°) I 40.5 0.00 0.00 180.00 Survey Program Date From To Survey ~ (ft) (ft) Survey (Wellbore) Tool Name Description Start Date 103.45 4,103.45 3C-14 (3C-14) GCT-MS Schlumberger GCT multishot 03/12/2008 4,162.85 6,598.93 3C-14A MWD*SAG+IIFR+CA+MS Doyo MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 03/12/2008 6,641.41 6,913.77 3C-14A MWD*SAG+IIFR+CA+MS Doyo MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 03/12/2008 Survey Map Map Vertical ', MD Inc Azi ND NDSS +N/-S +El-W Northing Easting DLS Section '~, (ft) (°) (°) (ft) (ft) (ft) {ft) (ft) (ft) (°/100') (ft) Survey Tool Name 40.85 0.00 0.00 40.85 -47.60 / 0.00 0.00 5,995,180.01 528,345.63 0.00 0.00 UNDEFINED 103.45 0.20 225.45 103.45 15.00 -0.08 -0.08 5,995,179.93 528,345.55 0.32 0.08 GCT-MS (1) 203.45 0.18 232.55 203.45 115.00 -0.29 -0.33 5,995,179.71 528,345.30 0.03 0.29 GCT-MS (1) 303.45 0.22 219.62 303.45 215.00 -0.54 -0.57 5,995,179.47 528,345.06 0.06 0.54 GCT-MS (1) 403.45 0.32 207.59 403.45 315.00 -0.93 -0.83 5,995,179.07 528,344.81 0.11 0.93 GCT-MS (1) 503.45 0.42 170.06 503.45 415.00 -1.54 -0.89 5,995,178.46 528,344.74 0.26 1.54 GCT-MS (1) 603.45 0.08 159.73 603.44 514.99 -1.97 -0.80 5,995,178.04 528,344.83 0.34 1.97 GCT-MS (1) 703.45 0.17 168.38 703.44 614.99 -2.18 -0.75 5,995,177.83 528,344.89 0.09 2.18 GCT-MS (1) 803.45 0.52 162.85 803.44 714.99 -2.76 -0.59 5,995,177.25 528,345.05 0.35 2.76 GCT-MS (1) 903.45 0.63 161.31 903.44 814.99 -3.71 -0.28 5,995,176.30 528,345.37 0.11 3.71 GCT-MS (1) 1,003.45 0.73 157.71 1,003.43 914.98 -4.82 0.14 5,995,175.19 528,345.79 0.11 4.82 GCT-MS (1) 3/12/2008 2:31:37PM Page 2 COMPASS 2003. i6 Build 42F C~ Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips Definitive Survey Report ConocoPhillips(Alaska) Inc. NAD83-NAD27 Kuparuk River Unit Kuparuk 3C 3C-14 3C-14A 3C-14A Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS +N/S +E!-W Northing Iftl (°) 1°1 (n) Iftl (ftl (ft) (ft) 1,103.45 0.67 151.13 1,103.42 1,014.57 -5.92 0.66 5,995,174.09 1,203.45 0.67 143.22 1,203.42 1,114.97 -6.90 1.30 5,995,173.17 1,303.45 0.67 142.19 1,303.41 1,214.96 -7.83 2.01 5,995,172.18 1,403.45 0.70 145.57 1,403.40 1,314.95 -8.80 2.71 5,995,171.22 1,503.45 0.77 157.52 1,503.39 1,414.94 -9.93 3.31 5,995,170.10 1,603.45 0.82 162.25 1,603.38 1,514.93 -11.23 3.79 5,995,168.80 1,703.45 0.55 152.74 1,703.38 1,614.93 -12.34 4.23 5,995,167.69 1,803.45 0.28 142.04 1,803.37 1,714.92 -12.95 4.60 5,995,167.07 1,903.45 0.73 133.96 1,903.37 1,814.92 -13.59 5.20 5,995,166.44 2,003.45 4.15 138.73 2,003.26 1,914.81 -16.75 8.05 5,995,163.29 2,103.45 8.25 137.86 2,102.66 2,014.21 -24.80 15.25 5,995,155.27 2,203.45 12.47 135.55 2,201.01 2,112.56 -37.83 27.63 5,995,142.29 2,303.45 16.53 135.90 2,297.80 2,209.35 -55.76 45.10 5,995,124.43 2,403.45 20.97 138.94 2,392.47 2,304.02 -79.48 66.77 5,995,100.79 2,503.45 24.07 139.06 2,484.84 2,396.39 -108.38 91.89 5,995,071.99 2,603.45 24.90 137.93 2,575.84 2,487.39 -139.42 119.36 5,995,041.06 2,703.45 27.90 136.58 2,665.40 2,576.95 -172.05 149.55 5,995,008.55 2,803.45 30.62 142.11 2,752.65 2,664.20 -209.15 187.29 5,994,971.57 2,903.45 33.78 147.02 2,837.28 2,748.83 -252.59 212.07 5,994,928.25 3,003.45 35.83 149.05 2,919.39 2,830.94 -301.02 242.26 5,994,879.94 3,103.45 37.12 143.57 2,999.82 2,911.37 -350.41 275.24 5,994,830.68 3,203.45 39.17 137.40 3,078.49 2,990.04 -397.96 314.56 5,994,783.28 3,303.45 40.80 133.41 3,155.12 3,066.67 -443.67 359.68 5,994,737.75 3,403.45 42.38 134.68 3,229.91 3,141.46 -489.82 407.38 5,994,691.78 3,503.45 42.40 135.55 3,303.77 3,215.32 -537.59 454.96 5,994,644.20 3,603.45 42.32 135.65 3,377.66 3,289.21 -585.73 502.10 5,994,596.25 3,703.45 42.08 135.69 3,451.74 3,363.29 -633.78 549.04 5,994,548.38 3,803.45 41.67 135.73 3,526.20 3,437.75 -681.56 595.65 5,994,500.78 3,903.45 41.17 135.65 3,601.19 3,512.74 -728.90 641.86 5,994,453.62 4,003.45 40.63 135.73 3,676.77 3,588.32 -775.75 687.60 5,994,406.95 4,103.45 40.85 136.04 3,752.54 3,664.09 -822.61 733.03 5,994,360.27 4,162.85 42.04 137.02 3,797.07 3,708.62 -851.14 760.07 5,994,337.84 4,187.52 42.59 137.05 3,815.31 3,726.86 -863.29 771.39 5,994,319.73 4,281.75 38.59 137.17 3,886.85 3,798.40 -908.20 813.11 5,994,274.99 4,376.23 35.89 137.31 3,962.06 3,873.61 -950.18 851.93 5,994,233.17 4,470.55 33.32 137.49 4,039.69 3,951.24 -989.60 888.18 5,994,193.88 4,563.82 29.92 136.84 4,119.10 4,030.65 -1,025.46 921.41 5,994,158.15 4,658.66 26.47 136.29 4,202.67 4,114.22 -1,058.00 952.21 5,994,125.73 4,753.50 22.26 136.02 4,289.05 4,200.60 -1,086.22 979.30 5,994,097.62 4,847.62 17.66 133.12 4,377.49 4,289.04 -1,108.82 1,002.11 5,994,075.11 • Well 3C-14 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88.45ft (Doyon 15) True Minimum Curvature CPAI EDM Production Map Vertical Fasting DLS Section lft) (~/100) (ft) Survey Tool Name 528,346.32 0.10 5.92 GCT-MS (1) 528,346.95 0.09 6.90 GCT-MS (1) 528,347.66 0.01 7.83 GCT-MS (1) 528,348.37 0.05 8.80 GCT-MS (1) 528,348.98 0.17 9.93 GCT-MS (1) 528,349.46 0.08 11.23 GCT-MS (1) 528,349.90 0.29 12.34 GCT-MS (1) 528,350.27 0.28 12.95 GCT-MS (1) 528,350.88 0.45 13.59 GCT-MS (1) 528,353.74 3.42 16.75 GCT-MS (1) 528,360.98 4.10 24.80 GCT-MS (1) 528,373.40 4.24 37.83 GCT-MS (1) 528,390.94 4.06 55.76 GCT-MS (1) 528,412.69 4.54 79.48 GCT-MS (1) 528,437.92 3.10 108.38 GCT-MS (1) 528,465.50 0.95 139.42 GCT-MS (1) 528,495.82 3.06 172.05 GCT-MS (1) 528,527.69 3.83 209.15 GCT-MS (1) 528,558.64 4.10 252.59 GCT-MS (1) 528,589.01 2.35 301.02 GCT-MS (1) 528,622.17 3.50 350.41 GCT-MS (1) 528,661.66 4.33 397.96 GCT-MS (1) 528,706.95 3.04 443.67 GCT-MS (1) 528,754.82 1.79 489.82 GCT-MS (1) 528,802.58 0.59 537.59 GCT-MS (1) 528,849.90 0.10 585.73 GCT-MS (1) 528,897.01 0.24 633.78 GCT-MS (1) 528,943.80 0.41 681.56 GCT-MS (1) 528,990.19 0.50 728.90 GCT-MS (1) 529,036.10 0.54 775.75 GCT-MS (1) 529,081.70 0.30 822.61 GCT-MS (1) 529,108.85 2.28 851.14 MWD+IFR-AK-CAZ-SC (2) 529,120.21 2.23 863.29 MWD+IFR-AK-CAZ-SC (2) 529,162.10 4.25 908.20 MWD+IFR-AK-CAZ-SC (2) 529,201.07 2.86 950.18 MWD+IFR-AK-CAZ-SC (2) 529,237.47 2.73 989.60 MWD+IFR-AK-CAZ-SC (2) 529,270.84 3.66 1,025.46 MWD+IFR-AK-CAZ-SC (2) 529,301.75 3.65 1,058.00 MWD+IFR-AK-CAZ-SC (2) 529,328.95 4.44 1,086.22 MWD+IFR-AK-CAZ-SC (2) 529,351.84 5.00 1,108.82 MWD+IFR-AK-CAZ-SC (2) 3/12/2008 2:31:37PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ' ConocoPhillips(Alaska) Inc. NAD83-NAD27 Project: Kuparuk River Unit Slte: Kuparuk 3C Well: 3C-14 W@Ilbore: 3C-14A Design: 3C-14A Survey Local Co-ordinate Reference: TVD Reference: MD Refer@nce: North Reference: Survey Calculation Method: Database: Map MD Inc TVD TVDSS +E!-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) 4,541.55 13.65 4,466.35 4,379.50 -1,0`21.34 5,994,058.53 5,038.08 10.78 4,562.26 4,473.81 1,037.95 5,994,046.93 5,132.08 8.30 4,654.96 4,566.51 1,051.83 5,994,040.08 5,226.24 7.61 4,748.21 4,659.76 1,064.29 5,994,036.38 5,321.01 7.45 4,842.16 4,753.71 1,076.37 5,994,033.56 5,415.34 7.24 4,935.72 4,847.27 1,088.09 5,994,030.75 5,510.71 7.86 5,030.26 4,941.81 1,100.29 5,994,027.94 5,603.96 7.59 5,122.67 5,034.22 1,112.51 5,994,025.19 5,698.85 8.05 5,216.67 5,128.22 1,125.09 5,994,022.36 5,793.46 6.95 5,310.47 5,222.02 1,137.10 5,994,019.51 5,889.02 6.49 5,405.38 5,316.93 1,147.94 5,994,016.82 5,980.48 5.98 5,496.30 5,407.85 1,157.58 5,994,014.46 6,074.54 5.91 5,589.85 5,501.40 1,167.02 5,994,012.10 6,169.93 7.50 5,684.59 5,596.14 1,177.46 5,994,008.38 6,215.67 8.69 5,729.87 5,641.42 1,183.30 5,994,005.69 6,264.64 10.60 5,778.15 5,689.70 1,190.71 5,994,002.19 6,309.05 12.64 5,821.64 5,733.19 1,198.78 5,993,998.36 6,358.75 14.09 5,870.00 5,781.55 1,208.72 5,993,992.69 6,405.14 15.26 5,914.88 5,826.43 1,217.95 5,993,985.51 6,450.85 16.12 5,958.89 5,870.44 1,226.68 5,993,976.81 6,502.92 17.28 6,008.77 5,920.32 1,236.27 5,993,965.37 6,545.83 18.06 6,049.65 5,961.20 1,243.99 5,993,954.92 6,598.93 18.96 6,100.01 6,011.56 1,253.02 5,993,940.74 6,641.41 20.66 6,139.98 6,051.53 1,259.61 5,993,927.98 6,668.31 22.67 6,164.98 6,076.53 1,263.53 5,993,918.87 6,699.07 24.42 6,193.17 6,104.72 1,267.83 5,993,907.39 6,727.16 26.84 6,218.50 6,130.05 1,271.46 5,993,895.81 6,758.95 28.97 6,246.60 6,158.15 1,274.52 5,993,881.29 6,787.82 30.32 6,271.69 6,183.24 1,276.09 5,993,867.12 6,819.99 32.32 6,299.18 6,210.73 1,276.62 5,993,850.42 6,849.50 35.38 6,323.69 6,235.24 1,275.85 5,993,834.01 6,879.96 38.92 6,347.96 6,259.51 1,274.07 5,993,815.70 6,913.77 42.21 6,373.64 6,285.19 1,272.16 5,993,793.80 6,953.00 42.21 6,402.70. 6,314.25 1,270.46 5,993,767.49 Well 3C-14 3C-14A (D15) @ 88.45ft (Doyon 15) 3C-14A (D15) @ 88.45ft (Doyon 15) True Minimum Curvature CPAI EDM Production Map Fasting DLS (ft) (°1100'} 529,371.13 4.49 529,387.78 3.32 529,401.69 3.29 529,414.16 1.28 529,426.25 529,437.98 529,450.19 529,462.42 529,475.01 529,487.02 529,497.88 529,507.52 529,516.97 529,527.42 529,533.28 529,540.70 529,548.78 529,558.74 529,568.00 529,576.76 529,586.39 529,594.15 529,603.23 529,609.87 529,613.82 529,618.17 529,621.85 529,624.96 529,626.58 529,627.17 529,626.47 529,624.75 529,622.93 529,621.33 0.20 0.22 0.66 0.29 0.49 1.19 0.49 0.56 0.08 2.07 2.62 3.90 4.59 4.70 5.25 3.89 3.29 2.67 3.50 5.68 8.61 6.47 10.35 12.55 8.48 9.94 13.00 12.10 11.03 0.00 Vertical Section (ft) Survey Tool Name 1,125.47 MWD+IFR-Ah-GAZ-SC (2) 1,137.14 MWD+IFR-AK-CAZ-SC (2) 1,144.04 MWD+IFR-AK-CAZ-SC (2) 1,147.78 MWD+IFR-AK-CAZ-SC (2) 1,150.65 MWD+IFR-AK-CAZ-SC (2) 1,153.51 MWD+IFR-AK-CAZ-SC (2) 1,156.37 MWD+IFR-AK-CAZ-SC (2) 1,159.16 MWD+IFR-AK-CAZ-SC (2) 1,162.04 MWD+IFR-AK-CAZ-SC (2) 1,164.93 MWD+IFR-AK-CAZ-SC (2) 1,167.66 MWD+IFR-AK-CAZ-SC (2) 1,170.06 MWD+IFR-AK-CAZ-SC (2) 1,172.46 MWD+IFR-AK-CAZ-SC (2) 1,176.22 MWD+IFR-AK-CAZ-SC (2) 1,178.93 MWD+IFR-AK-CAZ-SC (2) 1,182.46 MWD+IFR-AK-CAZ-SC (2) 1,186.32 MWD+IFR-AK-CAZ-SC (2) 1,192.03 MWD+IFR-AK-CAZ-SC (2) 1,199.25 MWD+IFR-AK-CAZ-SC (2) 1,207.98 MWD+IFR-AK-CAZ-SC (2) 1,219.45 MWD+IFR-AK-CAZ-SC (2) 1,229.94 MWD+IFR-AK-CAZ-SC (2) 1,244.15 MWD+IFR-AK-CAZ-SC (2) 1,256.94 MWD+IFR-AK-CAZ-SC (3) 1,266.06 MWD+IFR-AK-CAZ-SC (3) 7,277.57 MWD+IFR-AK-CAZ-SC (3) 1,289.16 MWD+IFR-AK-CAZ-SC (3) 1,303.69 MWD+IFR-AK-CAZ-SC (3) 1,317.87 MWD+IFR-AK-CAZ-SC (3) 1,334.58 MWD+IFR-AK-CAZ-SC (3) 1,350.98 MWD+IFR-AK-CAZ-SC (3) 1,369.29 MWD+IFR-AK-CAZ-SC (3) 1,391.18 MWD+IFR-AK-CAZ-SC (3) 1,417.49 PROJECTED to TD Azi 128.03 121.35 110.12 102.99 103.73 103.69 102.70 103.03 102.75 104.52 103.70 104.30 104.15 114.33 115.32 115.56 115.67 123.62 132.07 137.83 142.21 144.97 150.09 155.15 158.27 160.64 164.37 171.59 175.72 180.52 184.68 186.38 183.68 183.68 +N/-S (ft} -1,125.47 -1,137.14 -1,144.04 -1,147.78 -1,150.65 -1,153.51 -1,156.37 -1,159.16 -1,162.04 -1,164.93 -1,167.66 -1,170.06 -1,172.46 -1,176.22 -1,178.93 -1,182.46 -1,186.32 -1,192.03 -1 199.25 -1,207.98 -1,219.45 -1,229.94 -1,244.15 -1,256.94 -1,266.06 -1,277.57 -1,289.16 -1,303.69 -1,317.87 -1,334.58 -1,350.98 -1,369.29 -1,391.18 -1,417.49 3/12/2008 2:31:37PM Page 4 COMPASS 2003.16 Build 42F 3C-14A Permit 207-175 Maunder, Thomas E (DOA) From: Maunder, Thomas E {DOA) Sent: Monday, February 11, 2008 10:26 AM To: 'Nugent, David A' Subject: RE: 3C-14A Permit 207-175 Dave, Thanks for the update. Nothing further is needed. I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Nugent, David A [mailto:David.A.Nugent@conocophillips.com] Sent: Monday, February 11, 2008 8:17 AM To: Maunder, Thomas E (DOA) Subject: 3C-14A Permit 207-175 Tom: Page 1 of 1 Doyon 15 will probably finish the 3K-102 well in the next day or so and wilt then move to the 3C-14A well to finish the drilling of that well. We could be on the 3C-14A well by Wednesday, February 13, and begin opera#ions shortly after that. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska, Inc. Anchorage, Alaska 907-263-4674 {office) 907-244-3755 (cell) 918-662-4333 (fax) 2/11/2008 ~~ ~~~ ~~ ~~~ ~ ~ d I ~ ~ ~ SARAH PALIN, GOVERNOR ~aSBA OII/ A1~TD GA5 333 W. 7th AVENUE, SUITE 100 COIQSERQATI01~ COlli11'II55IOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-14A Sundry Number: 308-042 Dear Mr. Thomas: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely. DATED this ~ day of February, 2008 Encl. ~~ ~~~ ~~ ti STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~~ ~ `~~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~aY''t ~(w Alaska Oil ~ Gas Cons, Catnmissiar~ 1. Type of Request: Abandon ^ Suspend Operational Shutdown r Perforate ^ Wa~ ~~~' Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q ~ Exploratory ^ 207-175 , 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21425-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ - 3C-14A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25634, ALK 2567 76' AMSL ~ Kuparuk River Field /Kuparuk Oil Pool - 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6635' 6133' 6616' 6115' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 116' 116' SUR. CASING 4061' 9-5/8" 4061' 3720' INTER. CASING 4150' 7" 4150' 3787' LINER 2692' S.5" 6616' 6115' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none kill Strln 3.5" - 6227' Packers and SSSV Type: Packers and SSSV MD (ft) none none 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: ~P- 3<~r~ f~(c~,«-,Suspended ,ti1~,-t~" ~' Commencing Operat February 4, 2008 Oil ^ Gas ^ ~'~`~ , Plugged ^ Abandoned ^ ~ L" 17. Verbal Approval: Date: WAG ^ WINJ ^ WDSPL ^ GINJ ^ ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 263-4674 Printed Name Rand Thomas ~ Title:. Drilling Team Leader Signature ~ Phone 265-6830 Date L.IY ~a ~ COI'1'1F1'11SSI011 US@ Ong Sundry, Number: ~ Conditions of approval: Notify Commission so that a representative may witness ~ a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ ` Other: ~MC~~~ ^O'CZC~ ~Ot'1L, CYcSuMQ~~ l~ PC ~Or TQ ~ / ~, "" O~ Subsequent Form Required: i~ct r R ~ Q"11 7. «> APPROVED BY ~ g Approved by: SSIONER S-o THE COMMISSION Date: Form 10-403 Revised 06/2006 ~~~~j ~ ~~ A' Av ,, ~~"'s ~""~ I-~L{ ?~ (Q~$ ub i n plicate • Suspension of well activities 3C-14A Kuparuk River Field February 4, 2008 Permit: 207-175 API : 50-029-21425-01 Due to the need to move the Doyon 141 rig to commence drilling operations for the winter exploration program, the 3C-14A well will be suspended before reaching the planned total depth of the well. The well reached a total depth of 6,635'. The 5-1/2" liner was run to 6,619' and cemented with good returns. The top of liner is at 3,924'. The plugs bumped and when we circulated at the top of the liner after the cement job was completed we had mud push spacer in our returns indicating cement at or near the liner top. The liner top hanger and liner top packer both set with no problems. The liner and liner top were tested to 2,500 psi. The decision was made at that point to suspend the well. The suspending operations will consist of running a 3-1/2" kill string to 6,227', leaving the drilling mud in the hole, and freeze protecting the top part of the hole. The BOP's will be rigged down and the tree put on the well. The tree will be tested to 5,000 psi. The rig will be released to move to the first exploration location. Plans are now to use Doyon 15 to finish the drilling of this well beginning sometime in April, 2008. We will be back in contact when this date firms up. ORIGINAL 3C-14A Permit 207-175 ~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Nugent, David A [David.A.Nugent@conocophillips.com] Sent: Monday, February 04, 2008 9:17 AM To: Maunder, Thomas E (DOA) Subject: RE: 3C-14A Permit 207-175 Tom, ~IVe'll work on it right now and I hope I can get it over to you today. David From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 04, 2008 9:14 AM To: Nugent, David A Cc: Thomas, Randy L Subject: RE: 3C-14A Permit 207-175 David, 1t would be appreciated if the sundry could be here as soon as possible. Technically an OSD should be approved prior to accomplishing the operational work to actually SD the operations. Tom Maunder, PE AOGCC From: Nugent, David A [mailto:David.A.Nugent@conocophillips.com] Sent: Monday, February 04, 2008 9:10 AM To: Maunder, Thomas E (DOA) Subject: RE: 3C-14A Permit 207-175 Tom: tl~1e"II begin working on the sundry today and get it over to you in the next few days. David From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 04, 2008 9:00 AM To: Nugent, David A Cc: Thomas, Randy L Subject: RE: 3C-14A Permit 207-175 David, Thanks for the info. A sundry notice will need to be filed for this operational shutdown. Call or message with any questions. Tom Maunder, PE AOGCC From: Nugent, David A [mailto:David.A.Nugent@conocophillips.com] 2/4/2008 3C-14A Permit 207-175 • • Sent: Monday, February 04, 2008 8:52 AM To: Maunder, Thomas E (DOA) Subject: 3C-14A Permit 207-175 Tom: I wanted to inform you of our latest operations and forward plans on the 3C-14A well. Page 2 of 2 We ran and cemented the 5-1/2" liner over the weekend. We ran the liner to 6,619' and the top of the liner is at 3,924'. The cement job went well and we had good returns while cementing. We circulated out at the liner top and got some mud push spacer back to surface, so I feel like we got cement at or close to the liner top. The liner hanger and liner top packer both set without a problem and we tested the liner and liner top to 2,500 psi. Yesterday the decision was made to suspend the well so the Doyon 141 rig can move and start the exploration program for the winter. We ran a 3-1/2" kill string last night and this morning to 6,227' and are presently rigging down the BOP's and will be nippling up the tree in a little while. We will leave the drilling mud in the hole and freeze protect the top part of the hole with diesel. We should release the rig around midnight tonight. Right now plans are for the Doyon 15 rig to move back on the well and finish drilling the 4-3/4" hole section and complete the well. This work should begin around April or so. We will keep you informed. Well: 3C-14A Field: Kuparuk Permit: 207-175 API: 50-029-21425-01 If you have any questions or comments, please let me know. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska, Inc. Anchorage, Alaska 907-263-4674 (office) 907-244-3755 (cell) 918-662-4333 (fax) 2/4/2008 ~~ ~~w I~~ ~ i 'd . ' ~' k~ COI~TSER AATIO CO1rII 5D ,IpH Randy Thomas Drilling Team Leader Conoco Phillips Alaska, Inc PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-14A Conoco Phillips Alaska, Inc Permit No: 207-175 Surface Location: 1251' FNL, 1229' FEL, SEC. 14, T12N, R9E, UM Bottomhole Location: 2911' FNL, 7' FWL, SEC. 13, T12N, R9E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9p7) ~59-3607 (pager). DATED this ~0 day of December, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com December 18, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer 3C-14A Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permit to Drill for an onshore producer well, 3C-14A. Please find attached for the review of the Commission form 10-401 and the information required by 20 ACC 25.005 for this sidetrack of well 3C-14. The expected spud date of 3C-14A is January 4, 2008. If you have any questions or require any further information, please contact David Nugent at 263-4674. Sincerely, .. ,,.,.._, ._._~ f_. Randy Thomas Greater Kuparuk Area Drilling Team Leader ~. ~ ~ ~ p~ :~ ~ 1 ~. F; STATE OF ALASKA ~~~ x~,~ ALASKA OIL AND GAS CONSERVATION COMMISSION \'~ PERMIT TO DRILL ~ ~ J07 20 AAC 25.005 ,~{acls~ {`75i i~,, tvS~K- rr"Yrri« i~'rirwrriiaas,„; 1 a. Type of Work: Drill ^ Re-drill ^ Re-entry ^~ 1 b. Current Well Class: Exploratory ^ Development Oil Q - Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is pr pos~d for. ~ n Coalbed Methane G~s~ Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. ~ 59-52-180 11. Well Name and Number: 3C-14A - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 7088' TVD: 6434' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1251' FNL, 1229' FEL, Sec. 14, T12N, R9E, UM ° 7. Property Designation: ADL 25634 ~ Kuparuk Oil Pool Top of Productive Horizon: 2770' FNL, 7' FWL, Sec. 13, T12N, R9E, UM 8. Land Use Permit: ALK 2567 13. Approximate Spud Date: 1/4/2008 Total Depth: 2911' FNL, 7' FWL, Sec. 13, T12N, R9E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: > 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528346 ~ y- 5995180 Zone- 4 10. KB Elevation (Height above GL): 76' AMSL feet 15. Distance to Nearest Well within Pool: none , 16. Deviated wells: Kickoff depth: 4160' ~ ft. Maximum Hole Angle: 5p° - deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4610ypsig Surface: 3915 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size ica ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 7" 5.5" 15.5# L-80 Hydril 511 3000' 3800' 3523' 6800' 6245' 150 sx Class G, 40 sx GasBLOK 4.75" 3.5" 9.3# L-80 Hydril 511 588' 6500' 6000' 7088' 6434' 50 sx GasBLOK 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 8470' Total Depth TVD (ft): 6884' Plugs (measured) Effective Depth MD (ft): 8313' Effective Depth TVD (ft): Junk (measured) 8178' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 188 sx CS II 116' 116' Surface 4061' 9-5/8" 940 sx Permafrost E & 4061' 3720' Intermediate 380 sx Permafrost C Production 8450' 7" 550 sx Class G 8450' 6870' Liner Perforation Depth MD (ft): 7866'-7896', 8136'-8151', 8163'-8190', 8210'-8223', 8262'-8267' Perforation Depth TVD (ft): 6438'-6461', 6638'-6649', 6658'-6678', 6693'-6703', 6731'-6735' 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ~ Time v. 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 to the best of my knowledge. Contact David Nugent @ 263-4674 Printed Name Randy Thomas Title Drilling Team Leader --.~.. ~ Date t Z j , G` /~O "i Signature "'°"'~> "`"'.t- ..~ .-- Phone ~ ~ S ~. ~ ~ ~ I `'`-'~ 4 h n All D Commission Use Only Permit to Drill Number: ~~ ' ~~~ API Number: 50- ~Zg -Z ~ 7 Z~ ~~ Permit Appr val /. / Date: '~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ne, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ 4,No ~ ~,. M to q'd: Yes ^ No [~ Other. ~~~ ~,`~~ \ i H2$ measures: Yes [~ No 'r svy e ' Yes ~ No ^ ~S~t t9-S"QlCfl~i~d\ ~O) ~ ~Q ~ u ~_ P V BY THE COMMISSION M1 ~ ,COMMISSIONER DATE: t~ ,, C....... ~/1 AAA ~....:.....J ~~]/~]/1/~G CIIL.ml+in I,„nlir~#o Permit It - Kuparuk Well 3C-14A Application for Permit to Drill Document Application for Permit to Drill, Well 3C-14A Revision No.O Saved: 17-Dec-07 .Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ............................................................................................................. 2 2. Location Summary ...................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.050(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ......................................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests ................................................... 3 Requirements of 20 AAC 25.005 (c)(S) ......................................................................................................... 3 6. Casing and Cementing Program .................................................................................. 3 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 3 7. Diverter System Information ....................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) .........................................................................................................4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.OOS(c)(8) .........................................................................................................4 9. Abnormally Pressured Formation Information ............................................................ 4 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ .4 10. Seismic Analysis .......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................... . 5 11. Seabed Condition Analysis .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ...................................................................................................... .5 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... .5 13. Proposed Drilling Program ......................................................................................... 5 . ......................................... Requirements of 20 AAC 25.005 (c)(13) ............................................ ................. . 5 14. Discussion of Mud and Cuttings. Disposal and Annular Disposal .................................. 6 3N-14A PERMIT IT.DOC Page 1 of 6 Application for Permit to Drill, Well 3C-14A Revision No.O Saved: 17-Dec-07 Requirements of 20 AAC 25.005 (c)(14) ....................................................................................................... 6 15. Attachments :............................................................................................................. 7 Attachment 1 Directional Plan ...................................................................................................................7 Attachment 2 Drilling Hazards Summary .................................................................................................... 7 Attachment 3 Well Schematic .....................................................................................................................7 Attachment 4 Cement Summary .................................................................................................................. 7 1. Well Name Requirements of 20 AAC 2S. 005 (~ Each ~a~eld must be identified by a unique name desio gated by the operator mad a unique API nun¢ber assigned by the commission under 20 AAC 25.040(6). For a well kith multiple Nell brmaches, each branch must similarly be identified by a unigare name and API number by adding a w ffix to the name designated for the well by the operator mad to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3C-14A. 2. Location Summary Requirements of 20 AAC 25.ODS(c)(2) An application for a Permit to Drill must be accompanied by each of the folloi>>ing items, except for an item already on file with the commission and ident~ed in the application: (2) a plat ident~ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the s:aface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Arinosplaeric Administration; (C) the proposed depth of the well at the top of each objective fornuztion and at total depth; Location at Surface 1251' FNL, 1229' FEL, Sec 14,. T12N, R9E, UM NGS Coordinates ~ RKB Elevation 76.0' AMSL Northings: S, 995,180Eastings: 528, 346 Pad Elevation 48.0' AMSL Location at Top of 2770' FNL, 7' FWL, Sec. 13, T12N, R9E, UM Productive Interval (Kunaruk C Sandl NGS Coordinates Northings: S, 993, 667 Eastings: 529, 588 Measured Depth, RKB: 6,903' Total Vertical Depth, RKB: 6,230' Total Vertical Depth, SS: 6,315' Location at Total De th 2911' FNL, 7' FWL, Sec. 13, T12N, R9E, UM NGS Coordinates Measured De th, RKB: 7,088' Northings: 5,993,525 Eastings: 529,589 Total Vertical De th, RKB: 6,434' Total Vertical De th, SS: 6,349' and (D) other information regxrired 6y 20 AAC 2.050(6); Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill (Forn:10-401) must (1) include a plat, drawn to a writable scale, shrn~ ing the path of the proposed ivellbore, including all adjacent wellbores within 2f10 feet of may portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells withiaa 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those mm~es are known or discoverable in public records, and show that ead~ named operator has been fzunished a copy of the application by cer7ified mail; or (B) state that the applicant is the only affected oxvaer. The Applicant is the only affected owner. 3N-14A PERMIT IT.DOC '~ ~ 4, ~ ~ ~~ a'~ ~,,, Page 2 of 6 3. Blowout Prevention Equipment Information Application for Permit to Drill, Well 3C-14A Revision No.O Saved: 17-Dec-07 Requirements of 20 AAC 25.005(c) (3) .4n application for a Permit to Drill must be accompanied by each of the following items, except for an item already on ftle with the commission and identified in the application: (3) a diagram and description of the blrnvout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) Atx application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the cornrnission and ident~ed in the application: (4) information on drilling hazards, including (~1) the nuzxin¢unt dola-Whole pressure chat may be encountered, criteria used to determine it and maximum potential surface pressure based on a methane gradient; BHP data on 3C-16 indicates that the expected reservoir pressure for 3C-14A is 4,631 psi at 6,315' TVD. Equivalent Mud Weight @TD = 4631psi 6315'TVD x 0.052 =14.lppg The maximum potential surface pressure (MPSP) while drilling 3N-14C is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C Sand target at 6,315' TVD. MPSP = ~GradientMua - Gradient~aS )TVD GradientMua =14. l ppg x 0.052 = 0.73 f t t Gradient~as = 0.11 f l t TVD = 6315 ft MPSP = 0.73 psa - 0.11 psa 6315 ft = 3915 psi ~ ft ft (B) data on potential gas pones; The well bore is not expected to penetrate any gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation -ones, and pones that have a propensity for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (~) a description of the procedure for conducting fornurtion integrity tests, as required under 20 AAC 25.0300; A procedure is on file with the commission for performing LOT's. For 3N-14A the procedure will be followed after milling the window in T' casing and drilling 20'-50' of new formation. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and ident~ed in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted li~aer, pre perforated liner, or screen to be installed ORIGINAL 3N-14A PERMIT IT.DOC Page 3 of 6 Casing and Cementing Program Application for Permit to Drill, Well 3C-14A Revision No.O Saved: 17-Dec-07 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/ft) Grade Conn. t) (ft) (ft) Cement Program Ori final Wellbore 3C-14 9-5/8" 12-1/4 36 J-55 BTC 4,061 surface 4,061 / 3,720 940 sx Permafrost E & 380 sx Permafrost C 7" 8-1/2 26 J-55 8,450 surface 8,450 / 6,870 550 sx Class G 2-7/8" 6.5 J-55 EUE 7,981 surface 7,981 / 6,523 Tubing 8rd 3C-14A Sidetrack Plan 7" window 26 J-55 BTC 4,160 surface 4,160 / 3,749 150 sx 1205 ppg Class G, 2.25 5.5" flush jt 7" 15.5 L-80 H lal 1 3,000 3,800 / 3 523 6,800 / 6,245 3 / S , sx 15.8 GasBLOK w/ Class G, 0 1.17 ft3/sk „ 3-1/2 flush jt 4.75 9.3 L-80 Hydril 588 6,500 / 6,000 7,088 / 6,434 50 sx 15.8 GasBLOCK w/Class 3 511 G, 1.17 ft /sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the follrnving items, except for an item already on file with the commission and identifted in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.03.1 (h) (2); This rotary sidetrack will exit pre-existing casing at +/- 4,160' MD. BOPE will be installed prior to exiting the casing; therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c) (8) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identifred in the application: (8) a d~•illing fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done using a LSND mud systems having the following properties: Sidetrack Hole mud ro erties Intermediate Interval Production Interval Depth MD 4160' - 6800' 6800' - 7088' Density (ppg) 10.0 -10.3 14.3 Yield Point (cP) 25 - 32 25 - 28 pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) <6 <6 Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 2S. 005 (c)(9) .4n application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identfed in the application: (9) for an ezplorato~y or stratigraphic test ~~ell, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.0330; OR161NAL 3N-14A PERMIT IT.DOC Page 4 of 6 O--t~~' s. N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Application for Permit to Drill, Well 3C-14A Revision No.O Saved: 17-Dec-07 Requirements of 20 AAC 25.005 (c)(10) Art application for a Permit to Drill must be accompanied by each of the following items, except for an item alreadv on file with the commission and identified in tlae application.• (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item alreadv on file with the commission and identified in the application: (11) for a well drilledfrom an offshore platform, mobile bottone founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill nsust be accompmaied by each of the following items, exceptfor an item already on file with the commission and identified in tlae application: (12) evidence showing that the requirements of 20 AAC 2.1.025 (Bondti~g}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor ma item already on file with the commission and identified in the application: Pre-Rig Well Work: Wells Group to Supervise Pre-Rig P&A and will submit a separate Sundry and procedure for P&A. Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI and RU Doyon 141. 2. With BPV installed, remove tree and tubing head adaptor. 3. Install BOP blanking plug and NU BOP on 7-1/16" SK flange. Test BOP to 5000 psi. 4. Ensure well is dead. Pull blanking plug and BPV. Pu112-7/8" tubing. 6. PU mill, casing scraper, and DP and RIH to (4,200' MD. POOH. 7. RU wireline set a CIBP inside the T' casing at 14,180' MD based on casing collar depth. (Note: CIBP must be >_ 2.0' above a casing collar and >_ 20' below a casing collar) POOH, RD SWS. Test T' casing and CIBP to 3000 psi and hold for 15 min. 8. PU and RIH with Baker's "WindowMaster" whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP set at 4,180' MD. 9. Orient whipstock, shear off, and POOH. ~~~? ~`~ 10. Displace Brine from hole with 10.0 ppg LSND new mud to mill window. Mill window and dri1120' new formation. Dress ~~ window. Pump super sweep pill. 11. Perform FIT/LOT. POOH and LD window mill eta ~ ~ ~ ~ ~ ~ ~ 3N-14A PERMIT IT.DOC Page 5 of 6 12. PU bit, Rhino Reamer, & BHA, DP, and RIH. 13. Drill to casing point (f6,800' MD / 4,245' TVD). MW expected to be 10.0 - 10.3 ppg. 14. PU 5.5" flush joint liner and RIH. Liner overlap into 7" casing needs to be f200' - 300'. 15. Reciprocate the liner while circulating and cementing. R/U Dowell and cement the liner. _~.._ _ 16. Release from liner. Set packer. Application for Permit to Drill, Well 3C-14A Revision No.O Saved: 17-Dec-07 17. Pull and lay down DP. Pick up 2-7/8" DP. Change out BOP rams and test to 5000 psi. ~ 18. Weight up to 14.3 ppg LSND. 19. Pick up and run 4-3/4" bit, 3-1/8" BHA, and 2-7/8" DP. 20. Tag cement. Drill out and perform an FIT/I.,OT. 21. Dri114-3/4" Production hole to TD @ 7,088' MD / 6,434' TVD. ~ 22. RU and run 3-1/2" hydri1511 liner. Reciprocate the liner while circulating and cementing. R/U Dowell and cement 3-1/2" hydri1511 liner. ._-- ---- 23. Release from liner. Set packer. 24. Displace the well above the liner top with seawater until the returns are clean. Check for flow. POOH. LD/DP. 25. RU and RIH with 3-1/2" production tubing. Space out and land. RILD's. 26. Test tubing, PBR and liner to 2,500 psi with the IA open for 15 minutes. Bleed the tubing down to 1,500 psi. Test the IA, PBR and liner top to 2,500 psi for 30 minutes (chart test). Bleed tubing pressure to zero psi. With tubing open, annulus pressure should shear dump kill valve (2,000 psi casing to tubing shear). Bleed pressures to zero. 27. Install BPV and blanking plug. ND BOPE. NU and test the 3-1/8" SK tree to 5000 psi. 28. Pull the blanking plug and BPV. 29. Displace the well with diesel freeze protect fluid. 30. Install BPV. RD and MO Doyon Rig 141. Post-Rig Well Work: 1. Pull BPV. 2. RU SL. Drift and tag to PBTD. 3. Dummy-off GLM. RD SL. 4. RU E-Line. 5. Perforate the Kuparuk "C" sand as directed. RD E-Line. % 6. Fflowback "C" sand producer. 7. Turn over to Production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applicatio~r for a Permit to Drill nzustc be accompanied by each of the follotiving items, except for an item already onfrle N~ith the cornrnissio~z and ide~~ttfied in the application: 3N-14A PERMIT IT.DOC Page 6 of 6 Application for Permit to Drill, Well 3C-14A Revision No.0 Saved: 17-Dec-07 (14) a general description of hrnv the operator plans to dispose of drilling ntud and cuttings and a statement of whether the operator intends to request authorisation under 20 AAC 25.080 for an annular disposal operation in the hell.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary '~'~rC.. 3N-14A PERMIT IT.DOC Page 7 of 6 ~ r ConocoPhillips Alaska Plan: 3C-14A (wp08) Sperry Drilling Services Proposal Report -Geographic 10 December, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-14 Plan: 3C-14A Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well 3C-14 3C-14 Q 85.OOft (3C-14) N True API - US Survey Feet .` IHALLIBIJRTON Sperry Grilling 8ervi~ss ORIGINAL E-la4L.LlBURTOIV Spsrry Grilling Services 9 5/8" i i -780 ~~ -840 Project: Kuparuk River Unit Site: Kuparuk 3C Pad Well: 3C-14 Wellbore: PIan:3C-14A Plan: 3C-14A (wp08) _900 ~~ t -960 ~ aoo~ -1020 t -1080 ~~ ~ o 0 ~ o 0 -1140 ~~ h c t v." o -1200 ~ ~. ~ ±. t 7Q -1260 KOP 13.6°/100' @ 4160' MD, 3794' TVD: 2103' FNL, 469' FEIISec 14-T12N-R9 C s ~ -1320 0 1'80 Intermediate Casing @ 6800' MD, 6244.5' TVD: 2694' FNL, 5.6' FWLSecl3-T12N-R9 -1440 WELL DETAILS-14 NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 0.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5995160.01 526345.63 70°23'52.506N 149°46'9.594W REFERENCE INFORMATION Co-oNinate (N/E) Reference: Well 3C-14, True North Vertical (TVD) Reference: 3C-14 ~ BS.OOfl (3C-14) Measuretl Depth Reference: 3C-14 ~ BS.OOfl (3C-14) Calculation Method: Minimum Curvature CASING DETAILS No MD TVD TVDss Name Size 1 4061.00 3719.57 3634.57 9 5/8" 9-5/8 2 6800.00 6244.52 6159.52 61/8" 5-1/2 3 7088.43 6433.99 6348.99 4 3/4" 3-1/2 ~S~ 6000 6 1/8" i II 3C-74A TI wp08 ~'~~ \ 95% conf. BHI, @ 7088' MD, 6434' TVD: 2911' FNL, 6.5' FWL-Sec13-T12N-R9 ~~~ -1680 ~ ~ - 4 3/4" -1740 3C-14A (wp08) T M Azimuths to True North Magnetic North: 23.09° -1800 Magnetic Field Strength: 57618.7nT Dip Angle: 80.86° •k Date: 9/25/2007 ~C' _1860 Model: BGGM2007 , r 660 720 780 840 900 960 1020 1080 1140 1200 1260 1320 1380 1440 1500 1560 1620 1680 17 West(-)/East(+) (150 fUin) ~„~ ConocoPhillips n n ~ r. ~ . ~ w ~ Alaska / Halliburton Company HAL.LtBURTON ConocoPhilllp5 Compass Proposal Report -Geographic Sperry Drilling Services Database: _Sperry EDM .11 Local Co-ordinate Reference: Well 3C-14 Company: ConocoPhillips Alaska, Inc. ND Reference: 3C-14 @ 85.OOft (3C-14) Project: Kuparuk River Unit ' MD Reference: 3C-14 @ 85.OOft (3C-14) Site: Kuparuk 3C Pad North Reference: True Well: 3C-14 Survey Calculation Method: Minimum Curvature Wellbore: FIan:3C-14A Design: 3C-14A (wp08) Project Kuparuk River Unit, North Slope Alaska. Unried States Map System: Geo Datum: US State Plane 1927 (Exact solution) .~ System Datum: NAD 1927 (NADCON CONUS) Mean Sea Level Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3C-14 Well Position +N/-S 0.00 ft Northing: 5,995,180.01 ft ~ Latitude: 70° 23' 52.506" N +E/-W 0.00 ft Easting: 528,345.63 ft - Longitude: 149° 46' 09.594" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore PIan:3C-14A Magnetics Model Name Sample Date Declination Dip Angle Fi eld Strength l°) (°1 (n~ BGGM2007 9/25/2007 23.09 80.86 57,619 Design 3C-14A (wp08) Audit Notes: Version: Phase: PLAN Tie On Depth: 4,160.00 Vertical Sectio n: Depth From (ND) +N/-5 +E!-W Direction (ft1 (ft) (ft) (~) 85.00 0.00 0.00 138.80 Plan Summary _ Measured Dogleg Build Turn Depth In clination Azimuth ND NDSS +NI-S +E/-W Rate Rate Rate TFO (ft) {°) (°) (ft) (ft) (ft) (ft) (°/10~ft) (°1100ft) (`1100ft) (°) 4,160.00 42.27 137.21 3,793.98 3,708.98 -851.48 760.42 O.UO OAO 0.00 0.00 4,176.50 42.52 140.52 3,806.17 3,721.17 -859.86 767.73 13.60 1.47 20.05 85.00 4,196.50 42.52 140.52 3,820.91 3,735.91 -870.29 776.33 0.00 0.00 0.00 0.00 5,093.10 8.27 106.95 4,621.28 4,536.28 -1,131.53 1,039.28 4.00 -3.82 -3.74 -172.20 6,102.15 8.27 106.95 5,619.84 5, 534.84 -1,173.85 1,178.15 0.00 0.00. 0.00 0.00 6,903.31 50.00 180.00 6,315.00 6,230.00 -1,517.94 1,236.75 6.00 5.21 9.12 80.05 7,088.44 50.00 180.00 6,434.00 6,349.00 -1,659.76 1,236.75 0.00 0.00 0.00 0.00 12/11/2007 2:59:02PM Page 2 of 5 COMPASS 2003.11 Build 48 `?RIGINAL `'" Halliburton Company HALLLBURTC~N ConocoPhi111p5 Compass Proposal Report -Geographic Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well 3C-14 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3C-14 @ 85.OOft (3C-14) Project: Kuparuk River Unit MD Reference: ' 3C-14 @ 85.OOft (3C-14) Site: Kuparuk 3C Pad North Reference: Pr' True Well: JC-14 Survey Calculation Method: Minimum Curvature Wellbore: F'Ian:3C-14A Design: ~C-14A (wp08) Planned Survey 3C-14A Iwp02) Map Map MD Incl Azimuth TVD (ft) TVDSS +N/-S +EI-W Northing Easting DLSEV Vert Section (ft) (°) l°) (ftl (ft) 1ft) (ft) lft) (°l100ft) (ft) 4,160.00 42.27 137.21 3,793.98 3708.98 -851.48 760.42 5,994,331.50 529,109.20 0.00 1,141.55 KOP 13.6°/7 00' @ 4160' MD, 3794' TVD: 2103' FNL, 469' FEL-Sec 14-T12N-R9E 4,176.50 42.52 140.52 3,806.17 3721.17 -859.86 767.73 5,994,323.15 529,116.54 13.60 1,152.67 4,196.50 42.52 140.52 3,820.91 3735.91 -870.29 776.33 5,994,312.75 529,125.17 0.00 1,166.18 4,199.98 42.38 140.49 3,823.48 3738.48 -872.11 777.82 5,994,310.94 529,126.68 4.00 1,168.53 4,299.98 38.42 139.62 3,899.62 3814.62 -921.80 819.41 5,994,261.42 529,168.45. 4.00 1,233.31 4,399.98 34.47 138.58 3,980.05 3895.05 -966.70 858.28 5,994,216.66 529,207.48 4.00 1,292.70 4,499.98 30.53 137.30 4,064.38 3979.38 -1,006.60 894.24 5,994,176.91 529,243.59 4.00 1,346.41 4,599.98 26.60 135.69 4,152.19 4067.19 -1,041.30 927.11 5,994,142.34 529,276.59 4.00 1,394.17 4,699.98 22.70 133.56 4,243.06 4158.06 -1,070.63 956.75 5,994,113.12 529,306.34 4.00 1,435.76 4,799.98 18.84 130.62 4,336.54 4251.54 -1,094.45 983.00 5,994,089.41 529,332.67 4.00 1,470.97 4,899.98 15.04 126.24 4,432.19 4347.19 -1,112.64 1,005.73 5,994,071.30 529,355.47 4.00 1,499.63 4,999.98 11.39 119.06 4,529.53 4444.53 -1,125.11 1,024.83 5,994,058.90 529,374.62 4.00 1,521.60 5,093.10 8.27 106.95 4,621.28 4536.28 -1,131.53 1,039.28 5,994,052.54 529,389.09 4.00 1,535.95 5,099.98 8.27 106.95 4,628.09 4543.09 -1,131.82 1,040.23 5,994,052.25 529,390.04 0.00 1,536.79 5,199.98 8.27 106.95 4,727.05 4642.05 -1,136.02 1,053.99 5,994,048.11 529,403.82 0.00 1,549.01 5,299.98 8.27 106.95 4,826.01 4741.01 -1,140.21 1,067.75 5,994,043.97 529,417.59 0.00 1,561.23 5,399.98 8.27 106.95 4,924.97 4839.97 -1,144.40 1,081.51 5,994,039.83 529,431.37 0.00 1,573.45 5,499.98 8.27 106.95 5,023.93 4938.93 -1,148.60 1,095.28 5,994,035.69 529,445.15 0.00 1,585.67 5,599.98 8.27 106.95 5,122.89 5037.89 -1,152.79 1,109.04 5,994,031.55 529,458.92 0.00 1,597.89 5,699.98 8.27 106.95 5,221.85 5136.85 -1,156.99 1,122.80 5,994,027.41 529,472.70 0.00 1,610.11 5,799.98 8.27 106.95 5,320.81 5235.81 -1,161.18 1,136.56 5,994,023.26 529,486.47 0.00 1,622.33 5,899.98 8.27 106.95 5,419.77 5334.77 -1,165.37 1,150.32 5,994,019.12 529,500.25 0.00 1,634.55 5,999.98 8.27 106.95 5,518.72 5433.72 -1,169.57 1,164.08 5,994,014.98 529,514.03 0.00 1,646.77 6,102.15 8.27 106.95 5,619.84 5534.84 -1,173.85 1,178.15 5,994,010.75 529,528.10 0.00 1,659.26 6,149.98 9.21 124.89 5,667.11 5582.11 -1,177.05 1,184.58 5,994,007.58 529,534.54 6.00 1,665.89 6,199.98 10.93 139.04 5,716.35 5631.35 -1,182.91 1,190.96 5,994,001.74 529,540.95 6.00 1,674.52 6,249.98 13.11 148.98 5,765.26 5680.26 -1,191.35 1,197.00 5,993,993.32 529,547.02 6.00 1,684.84 6,299.97 15.56 155.97 5,813.70 5728.70 -1,202.34 1,202.65 5,993,982.35 529,552.71 6.00 1,696.84 6,349.97 18.18 161.06 5,861.54 5776.54 -1,215.85 1,207.92 5,993,968.87 529,558.03 6.00 1,710.47 6,399.97 20.90 164.88 5,908.66 5823.66 -1,231.84 1,212.77 5,993,952.90 529,562.95 6.00 1,725.70 6,439.16 23.07 167.26 5,945.00 5860.00 -1,246.08 1,216.29 5,993,938.68 529,566.52 6.00 1,738.73 Base HRZ 6,449.97 23.68 167.85 5,954.92 5869.92 -1,250.27 1,217.22 5,993,934.49 529,567.46 6.00 1,742.49 6,499.97 26.50 170.22 6,000.20 5915.20 -1,271.08 1,221.23 5,993,913.70 529,571.55 6.00 1,760.79 6,549.97 29.36 172.16 6,044.37 5959.37 -1,294.22 1,224.80 5,993,890.57 529,575.20 6.00 1,780.55 6,568.00 30.40 172.78 6,060.00 5975.00 -1,303.13 1,225.97 5,993,881.67 529,576.41 6.00 1,788.03 K1 6,599.97 32.25 173.78 6,087.32 6002.32 -1,319.63 1,227.91 5,993,865.17 529,578.42 6.00 1,801.73 6,649.97 35.15 175.17 6,128.91 6043.91 -1,347.24 1,230.57 5,993,837.58 529,581.18 6.00 1,824.25 6,683.51 37.10 175.99 6,156.00 6071.00 -1,366.95 1,232.09 5,993,817.88 529,582.77 6.00 1,840.08 Top Kuparuk 6,699.97 38.06 176.36 6,169.05 6084.05 -1,376.97 1,232.76 5,993,807.86 529,583.48 6.00 1,848.06 6,749.97 40.98 177.42 6,207.61 6122.61 -1,408.74 1,234.48 5,993,776.10 529,585.32 6.00 1,873.09 6,789.61 43.31 178.16 6,237.00 6152.00 -1,435.32 1,235.50 5,993,749.53 529,586.44 6.00 1,893.76 C 12/11/2007 2:59:02PM Page 3 of 5 COMPASS 2003.11 Build 48 ORIGINAL ~' i ~% Halliburton Company ConoeoPhiliap5 Compass Proposal Report -Geographic HALLIBURTON IBp®rry Drlliing S®rvices Database: .Sperry EDM .11 Local Co-ordinate Reference: Well 3C-14 Company: ConocoPhillips Alaska, Inc. ND Reference: C-14 @ 85.OOft (3C-14) Project: K:uparuk River Unit MD Reference: ~C-14 @ 85.OOft (3C-14) Site: K.uparuk 3C Pad North Reference: True Well: 3C-14 Survey Calculation Metho d: :Minimum C urvature ~ Wellbore: F'Ian:3C-14A Design: 3C-14A (wp08) Planned Survey 3C-14A (wp08) Map Map MD Incl Azimuth ND (ft) (ft) (°) (°) NDSS (ft) +N/-S +E/-W (ft) (ft) Northing lft) Easting (ft) DLSEV Vert Section (°1100ft) (ft) 6,799.97 43.92 178.35 6,244.50 6159.50 -1,442.46 1,235.72 5,993,742.39 529,586.69 6.00 1,899.28 Intermediate Casing @ 6800' MD, 6244.5' N D: 2694' FNL, 5.6' FWL-Sec13-T12N-R9E - 61/8" 6,849.97 46.86 179.19 6,279.61 6194.61 -1,478.04 1,236.47 5,993,706.82 529,587.58 6.00 1,926.55 6,869.77 48.02 179.50 6,293.00 6208.00 -1,492.62 1,236.64 5,993,692.24 529,587.80 6.00 1,937.63 C1 6,903.31 50.00 180.00 6,315.00 6230.00 -1,517.94 1,236.75 5,993,666.92 529,588.01 6.00 1,956.75 B - 3C-14A T1 wp08 6,999.97 50.00 180.00 6,377.13 6292.13 -1,591.98 1,236.75 5,993,592.89 529,588.29 0.00 2,012.47 :7,088.44 50.00 180.00 6,434.00 ~ 6349.00 -1,659.76 1,236.75 5,993,525.12 529,588.54 0.00 2,063.46 BHL @ 7088' MD, 6434' ND: 2911' FNL, 6.5' FWL-Sec13-T12N-R9E - 4 3/4" , Geologic Targets Plan: ',C-14A ND NDSS Target Name +N/-S +E!-W Northing Easting (ft) (ft) - Shape ft ft (ft) (ft) 6,315.00 3C-14AT1 wp08 -1,517.94 1,256.75 5,993,667. 00 529,608.00 - Ellipse (radii L100.00 W150.00 on 0.00 azi) Prognosed Casing Points Measured Vertical Casing Hofe Depth Depth Diameter Diameter lftl (ft) (") ("} 4,061.00 3,719.57 9-518 12-1/4 6,800.00 6,244.52 5-112 6-118 7,088.43 6,433.99 3-1/2 4-1l2 Prognosed Formation Intersection Points Measured Depth Inclination Azimuth (ft) (°) (°) ND (ft) NDSS +N/-E (ft) (ft) +E/-W (ft) Narne 6,439.16 23.07 167.26 5,945.00 -1,246.08 1,216.29 Base HRZ 6,568.00 30.40 172.78 6,060.00 -1,303.13 1,225.97 K1 6,683.51 37.10 175.99 6,156.00 -1,366.95 1,232.09 Top Kuparuk 6,789.61 43.31 178.16 6,237.00 -1,435.32 1,235.50 C 6,869.77 48.02 179.50 6,293.00 -1,492.62 1,236.64 C1 6,903.31 50.00 180.00 6,315.00 -1,517.94 1,236.75 B 12/11/2007 2:59:02PM Page 4 of 5 COMPASS 2003.11 Build 48 ~?IGINAL ~ i ~'" Halliburton Company HA..LtBURTDN ConocoPhilllp5 Compass Proposal Report -Geographic Sperry Drilling Services Database: Sperry EDM .11 Local Co-ordinate Reference: 'Well 3C-14 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3C-14 @ 85.OOft (3C-14) Project: ~:uparuk River Unit MD Reference: 3C-14 @ 85.OOft (3C-14) Site: I~:uparuk 3C Pad North Reference: 'True Well: °.C-14 Survey Calculation Method: Minimum Curvature Wellbore: F'Ian:3C-14A Design: 3C-14A (wp08) Plan Annotations Measured Vertical Local Coor dinates Depth Depth +N/-S +E(-W Comment eft) lft) (ft) eft) 4,160.00 3,793.98 -851.48 760.42 KOP 13.6°/100' @ 4160' MD, 3794' TVD: 2103' FNL, 469' FEL-Sec 14-T12N-f 6,800.00 6,244.52 -1,442.48 1,235.72 Intermediate Casing @ 6800' MD, 6244.5' TVD: 2694' FNL, 5.6' FWL-Sec13-l 7,088.43 .6,433.99 -1,659.75 1,236.75 BHL @ 7088' MD, 6434' TVD: 2911' FNL, 6.5' FWL-Sec13-T12N-R9E 12/11/2007 2:59:02PM ORIGINAL COMPASS 2003.11 Build 48 ConocoPhillips Alaska Plan: 3C-14A (wp08) Sperry Drilling Services Anticollision Summary 10 December, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3C Pad 3C-14 Plan: 3C-14A ;t`~ ~ ~i SURVEY PROGRAM Date: 2007-12-11TU0:00:0U Validated:l'es Version: Depth From Depth To Survey/Plan Tool IOU.00 4160.00 GCl'-MS 4160A0 7088A4 3C-14A (wpUB) MWD+IFR-AID CAZrSC 0 COMPANY DETAILS: ConocoPhfllips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 4160 To 7088.44227439711 Maximum Range:900.344227439711 Reference: Plan: 3C-14A (wp08) 90 270 180 so Travelling Cylintler Azimuth (TFO+A'L1) ~°~ vs Centre to Centre Separation X200 ft/ink REFERENCEINFORMATiON Co-ordinate (NIE) Reference: Well 3C-14, True North Vertical (TVD) Reference: 3C-14 @ 85.OOft (3C-14) NAD 27 ASP Zone 4 : WELL DETAILS: 3C-14 Section (VS) Reference: Slot- (O.OON, O.OOE) Measured Depth Reference: 3C-14 ~ 85.OOtt(3C-14) Ground Level: 0.00 Calculation Method: Minimum Curvature +W-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5995180.01 528345.63 70°23'52.506N 149°46'9.594W Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Dare: 12/11/2007 Time: 1236:52 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 3C Pad Co-ordinate(NE) Reference: Well 3C-14, True North Reference ~'i'cII: 3C-14 Vertical (T~'D) Reference: 3C-14 85.0 Reference VI'ellpath: Plan: 3C-14A Db: Oracle __ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 4160.00 to 7088.44 ft Scan Method: Trav Cylinder North Maximum Radius: 900.34 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 11/16/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 100.00 4160.00 3C-14 (100.00-8400.00) (0) GCT-MS Schlumberger GCT multishot 4160.00 7088.44 Planned: 3C-14A wp08 V2 MWD MWD -Standard Casing Points 14D T~'D Diameter Holc Size Name ft ft in in 4061.00 3719.57 9.625 12.250 9 5/8" 6900.00 6312.86 4.500 6.125 4.5" Summary Wcll ath > ~ -- Off e ---------- P' --------------- __ _ Reference _. _ _ _ Offset Ctr-Ctr No-Go Allowable ~~~~ ~ ~I t Wellpath MD MD Distance Area Deviation R'arning ft ft ft ft ft Kuparuk 3C Pad 3C-14 3C-14 V2 4174.99 4175.00 0.24 94.19 -93.95 FAIL: Major Risk Kuparuk 3C Pad Plan: 3C-17 3C-17 (wp01) VO Plan: 6818.27 7850.00 228.11 163.02 65.09 Pass: Major Risk ORIGINAL Ground Level: 0.00 ~ Project: Kuparuk River Un HALLI BU RTO N Northing/ASP B: 5 95180.01.OOft (3c-14) Site: Kuparuk 3C Pad Well: 3C-14 Sperry Drilling Services Easting/ASP X: 528345.63 Wellbore: Plan: 3C-14A i ~ ~ Plan: 3C-14A (wp08) 500 6~~0 9 5/8" ..;. ~~ • :~: .,'~ --i.. .~- ._ o ~ 0 ~ 3C-15, 3C-15, 3C-15 V1 _ _ _ _ _ _ 8 6 1/8" O 4 3/4" ~ / ~:~• ~ , ., ~,~ ~ O ~, 3C-14A (wp08) .._ , ~ 3C-14, 3C-14, 3C-14 V2 ._, ~~O 0 >~0 0 ~~ 3C-13, 3C-13, 3C-13 V1 ~ - ;:, ~~ .r' ;~ •: 3C-16, 3C-16, 3C-16 V1 ~~ 3C-16, Plan: 3C-16A, 3C-16A (wp01) VO ~ ~'- .~ -;. ~~ ~~~- 3C-12, 3C-12, 3C-12 V2 .~' 3C-09, 3C-09, 3C-09 V2 '- - - - ConocoPhillips Alaska Site: Kuparuk 3C Pad Coordinate (N/E) Reference: WeA 3C-14, True North Ground Level: 0.00 Sperry Drilling Servfcee Well: 3C-14 Vertical (TVD) Reference: 3C-14 ~ BS.OOft (3C-14) +N/-5 +E/-W Northing Fasting Lalittude Longitude Slot Wellbore: Plan: 3C-14A Measured Depth Reference: 3C-14 (~ 85.OOft (3C-14) 0 ~ 0.00 5995180.01 528345.G3 70°23'S2.SOGN 149°4G'9.594W Plan: 3C-14A (wp08) Calculation Method: Minimum Curvature CASING DETAILS \ No TVD MD Name Size . ~ 1 3719.57 4061.00 9 5/8" 9-5/8 i .~~ ~ 2 6244.526800.00 61/8" 3 6433.99 7088.43 4 3/4" 5-1/2 3-1 /2 ~ ~ I 1200 _._..... _ .._...... i _ - _i ~ ~ _ _....._ __._i ! r 3C-14A Drilling Hazards 6-1/8 x 7"" Hole Event Risk Level Miti anon Strate High ECD and swabbing with Low Condition mud prior to trips. Monitor ECD's with PWD tool. Pump hi her MW's re uired and rotate out on trips as a last resort. Barite Sag Low Use Good drilling practices as documented in well plan and keep track of mud ro erties in line with mud pro am. Differential Sticking High Do not leave pipe static for extended period of time. Proper drilling ractices and kee connection time to minimum. Hole instability while drilling High Use enough MW to stabilize HRZ / Kalubik without sustaining losses HRZ / Kalubik Shale section Lost Circulation Moderate Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree as needed. 4-3/4" Hole Event Risk Level Miti anon Strate High ECD and swabbing with High Condition mud prior to trips. Monitor ECD's with PWD tool while close tolerance and higher drilling across pay interval. Pump and rotate out on trips as a last MW's re uired resort. Abnormal Reservoir Pressure High Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Have spike fluid available. Differential Sticking Moderate Wiper trips as needed. Do not leave pipe static for extended period of time. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology. Use LC decision tree. ORIGINAL 3C-14A SIDETRACK PROPOSED 3C-14A Schematic ConocoPhillips 9-5/8" x 7" annulus 3'/2' Camco SCSSSV TRMAXX-5E with 2.812 Profile Nipple Bore arctic packed sssv set at +/- 2000' MD/ 2000' TVD October1985 w/ 34 bbls cmt & 53.5 bbls Arctic Pack. 0 - 3000'. 3'/z' 9.3# L-80 IBT Mod tubing 5.5" X 7" Liner Top @ +/- 3800' MD / 3523' TVD 9-5/8" 36# J-55 BTC casing Set @ 4061' MD / 3718' TVD (Original FIT 12.5 ppg EMVVj Sidetrack KOP wl window in 7" @ +l- 4160' MD / 3749' TVD GLM # MD-RKB TVD-RKB Number and depth To Be Determined Baker "K-1" CIBP below set point for whipstock @ +/- 4177' MD 2-7/8" tbg cut and pulled from +/- 7600' MD / 6243' TVD Top of cmt P&A plug @ 7700' MD. PKR 7700' MD Perfs 7866' - 7876' MD (Sqz) PKR 7955' MD Perfs: 8163' - 8190' _ 8210' - 8223' _ 8262' - 8267' MD - (Sqz) Original Wellbore 7 7.0" csg 26.0# J-55 @ 8450' MD LWD Loaaina: 3-'/z' D nipple with 6- 1/8" hole: GR/RES 2.75" No Go profile 4- 3/4" hole: GR/RES two joints above the seal assemby 5'/s" liner Assemblv wl 300' liner lao• 5-1 /2" 15.5# Hydril 511 Liner @ 6800' MD / 6245' TVD BHP Es .: 14.1 ppg EMW @ 6903' TVD / 6315' TVD on Nov 07 3'/:" liner Assemblv top w/ 300' liner lap: 3-1/2" 9.3# Hydril 511 Liner @ 7088' MD / 6434' TVD 7088' MD / 6434' TVD ORIGINAL DAN 12/12/ Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska Revision Date: 12/14/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < Top of Lead at 3,700' MD < Liner Top at 3,900' MD Previous Csg. 7", 26.0# casing at 4,100' MD < Top of Tail at 6,300' MD < 5 1/2", 15.5# casing in 7" OH TD at 6,800' MD (6,245' TVD) * Mark of Schlumberger CemCADE Preliminary Job Design 5 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes onl Sehlumberger Volume Calculations and Cement Systems Volumes are based on 35% excess. Displacement is calculated with a 3.5"- 15.5# drill string. Lead Slurry Minimum thickening time: 140 min. (pump time plus 120 min.) Lead Cement Annular Volume: 0.1023 ft3/ft x (1500') x 1.35 (35% excess) = 303.8 ft3 Totals: 303.8 ft3 = 333.5 ft3 333.5 ft3/ 2.25ft3/sk = 148.2 sks Round up to 150 sks Tail Slurry Minimum thickening time: 140 min. (pump time plus 120 min.) LiteCRETE 12.5 ppg - 2.23 ft3/sk Annular Volume: 0.1023 ft3/ft x (500') x 1.35 (35% excess) = 69.1 ft3 Shoe Volume: 0.1336 ft3/ft x 80' x 1.00 (no excess) = 10.7 ft3 Totals: 303.8 ft3 + 333.5 ft3 = 79.8 ft3 69.1 ft3/ 10.7 ft3/sk = 35.8 sks Round up to 40 sks BHST = 134, Estimated BHCT = 107. (BHST calculated using a gradient of 2.2'/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Cumulative Volume Time Time Stage (bpm) (bbl) (min) (min) Comments Chemical Wash 5 40 8.0 8.0 Start Pumping Wash MudPUSH II 6 20 3.3 11.3 Start Pumping Spacer Lead Slurry 6 60 10.0 21.3 Tail Slurry 6 16 2.7 24.0 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 27.0 Displacement 6 70 11.7 38.7 Start Displacement Slow Rate 2 25 12.5 51.2 MUD REMOVAL Recommended Mud Properties: 10 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.5 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 perjoint over zones of interest ORIGINAL Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska Revision Date: 12/14/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 6,400' MD < Liner Top at 6,500' MD Previous Csg. 5 1/2", 15.5# casing at 6,800' MD < 3 1/2", 9.3# casing in 4 3/4" OH TD at 7,088' MD (6,434' ND) Mark of Schlumberger CemCADE Preliminary Job Design 3 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Scnlumberger Volume Calculations and Cement Systems Volumes are based on 35% excess. Displacement is calculated with a 2.9"- 10.4# drill string. Cementjob is designed to seal off liner top by bringing cement 100' above liner top, with 15.8 ppg G cement. Tail Slurry Minimum thickening time: min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk Liner Cap: 0.0886 ft3/ft x 100' x 1.00 (no excess) = 8.9 ft3 Liner Lap: 0.0668 ft3/ft x (' - 6500') x 1.00 (no excess) = 20 ft3 Annular Volume: 0.0562 ft3/ft x (6800' -') x 1.35 (35% excess) = 21.9 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 4.4 ft3 Totals: 8.9ft3+20ft3+21.9 ft3+4.4ft3= 55.2 ft3 55.2 ft3/ 1.17 ft3/sk = 47.2 sks Round up to 50 sks BHST = 139, Estimated BHCT = 117. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments CW 100 4 10 2.5 2.5 MudPUSH II 4 20 5.0 7.5 Start Pumping Spacer Tail Slurry 4 10 2.5 10.0 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 13.0 Displacement 6 24 4.0 17.0 Start Displacement Displacement 3 10 3.3 20.3 Slow to Bump MUD REMOVAL Recommended Mud Properties: 14.5 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 15.0 ppg MudPUSH* I I, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint from Previous Casing to TD. ORIGINAL TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~~ ~~ ~~~~ PTD# ~~ ~ ~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well -- (If fast two digits in permit No. , API No. 50- - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PII.OT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- -^,) from records, data and togs 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 Welt for dame of well) until after (Compan~Name) has designed and implemented a water well testing program to provide baseline data on water gustily and quantity. S,Company Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/13/2007 • ^^ ~ , m , rn ~ , ~ mN m ~ , , ~ , , , , o ~ ~ , , ~ , w , ~ - , ~ , ~ ' ~ ~ ~ ~ ~ ~ , , ' O' Q m ~ ~ ~ ~ ~ , $, ~' ~ ~ ~ ~ G ~ ~ ~ , , ~ N $ ~ ~ , O w o a ~, ~, ~, ~ ~ ~ •~ m :C, ~, ~ .c 3, ~ , n c ~?' ~ csi ~ ~ ~ ~ m' ~ 'a ~, ~ ~ ~' 2; _m,, ~ , c' c' N' c' a c , ~, m, of of ~, ~, a, w, ~ c. o, o. , m c c' m, s, a, G ao `y m rn w ca al m' C, C~ a ~ ~-~ a' ~ r; ~ , m _ , , J, m, N' .- LA , - - - - •a >' r, , c ai , ~ , , 3 c' w s, , m ~ , ~; Z; a a, m, m. 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N ~ r ~ ~ ~ _ ~ m i Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. IJo special effort has been made to chronologically organize this category of information. • • 3C-14A.txt Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Fri May 02 08:56:49 2008 Reel Header Service name .............LISTPE Date . ...................08/05/02 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/05/02 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing scientific Technical Services Library. scientific Technical services Physical EOF comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: 3C-14A API NUMBER: 500292142501 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: O1-MAY-08 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: Mw-000568188 Mw-000568188 Mw-000568188 LOGGING ENGINEER: D. KING B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: P. WILSON M. THORNTON M. THORNTON MWD RUN 5 JOB NUMBER: Mw-000568188 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 14 TOWNSHIP: 12N RANGE: 9E FNL: 2911 FSL: FEL: FWL: 7 Page 1 ~o'~--t~S ~ t(oa(o~ 3C-14A.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 88.45 GROUND LEVEL: 47.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 7.000 7.000 4163.0 2ND STRING 4.750 5.500 6628.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THE INTERMEDIATE HOLE SECTION, MWD RUNS 1-2, WERE DRILLED WITH DRILLING RIG DOYON 141. THE PRODUCTION HOLE SECTION, MWD RUNS 3-5 WERE DRILLED WITH DRILLING RIG DOYON 15. ALL INTERMEDIATE HOLE SECTION INFORMATION HAS BEEN SHIFTED TO REFERENCE THE RKB OF DOYON 15. 4. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 3C-14 WELLBORE. THE TOP OF THE WINDOW WAS AT 4163' MD, 3797' TVD. 5. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 6. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS) AND PRESSURE WHILE DRILLING (PWD). 7. MWD RUN 3-5 COMPRISED DIRECTIONAL, GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILLSTRING DYNAMICS SENSOR (DDS) AND PRESSURE WHILE DRILLING (PWD). 8. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 9. MWD RUNS 1-5 REPRESENT 3C-14A WITH API#: 50-029-21425-01. THIS WELL REACHED A TOTAL DEPTH OF 6953' MD, 6403' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. Page 2 3C-14A.txt SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO S FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4137.5 6893.0 RPD 4158.0 6904.5 RPS 4158.0 6904.5 RPM 4158.0 6904.5 FET 4158.0 6904.5 GR 4158.0 6904.5 ROP 4206.0 6953.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 4137.5 6648.0 3 6648.0 6688.0 4 6688.0 6896.0 5 6896.0 6953.0 REMARKS: MERGED MAIN PASS. Page 3 3C-14A.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4137.5 6953 5545.25 5632 4137.5 6953 RPD MWD OHMM 0.68 2000 8.29827 5421 4158 6904.5 RPM MWD OHMM 0.47 2000 6.78151 5421 4158 6904.5 RPS MWD OHMM 0.42 2000 4.67066 5421 4158 6904.5 RPX MWD OHMM 0.12 1657.59 3.90591 5421 4158 6904.5 FET MWD HR 0.36 521.27 7.8045 5421 4158 6904.5 GR MWD API 44.92 476.45 116.005 5512 4137.5 6893 ROP MWD FPH 0 1038.1 95.4874 5495 4206 6953 First Reading For Entire File..........4137 Last Reading For Entire File...........6953 File Trailer Service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record Page 4 3C-14A.txt FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4137.5 6579.5 RPD 4158.0 6586.5 RPM 4158.0 6586.5 RPx 4158.0 6586.5 RPS 4158.0 6586.5 FET 4158.0 6586.5 OP 4206.0 6648.0 $ LOG HEADER DATA DATE LOGGED: 29-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 5.9 MAXIMUM ANGLE: 42.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 232602 EWR4 EWR Phase-4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.750 DRILLER'S CASING DEPTH (FT): 4162.9 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 48.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 1500 FLUID LOSS (C3): 2.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .970 104.0 MUD FILTRATE AT MT: 1.600 65.0 MUD CAKE AT MT: 1.900 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 5 ~ r REMARKS: 3C-14A.txt Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4137.5 6648 5392.75 5022 4137.5 6648 RPD MWD020 OHMM 0.92 2000 4.73188 4858 4158 6586.5 RPM MwD020 OHMM 0.75 2000 4.69546 4858 4158 6586.5 RPS MWD020 OHMM 0.44 251.1 2.41114 4858 4158 6586.5 RPX MWD020 OHMM 0.89 1619.84 3.10178 4858 4158 6586.5 FET MWD020 HR 0.36 27.4 1.78734 4858 4158 6586.5 GR MWD020 API 44.92 476.45 118.904 4885 4137.5 6579.5 ROP MWD020 FPH 0 1038.1 104.826 4885 4206 6648 First Reading For Entire File..........4137.5 Last Reading For Entire File...........6648 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSLIB.003 Physical EOF File Header service name... .......sTSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type ................L0 Page 6 ~ r 3C-14A.txt Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6580.0 RPx 6623.5 FET 6623.5 RPM 6623.5 RPD 6623.5 RPS 6623.5 ROP 6648.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Gamma Module EWR4 EWR Phase-4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 6628.0 6639.0 6639.0 6639.0 6639.0 6639.0 6688.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): header data for each bit run in separate files. 3 .5000 3 Page 7 19-FEB-08 Insite 4.30 Memory 18.1 20.7 TOOL NUMBER 78005 211047 4.750 6628.0 Polymer 14.30 49.0 9.3 90000 6.1 .100 66.0 .063 108.7 .050 66.0 .300 66.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 3C-14A.txt Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6580 6688 6634 217 6580 6688 RPD MWD030 OHMM 1.17 1949.01 573.658 32 6623.5 6639 RPM MWD030 OHMM 0.85 1607.12 284.737 32 6623.5 6639 RPS MWD030 OHMM 0.75 2000 281.615 32 6623.5 6639 RPX MWD030 OHMM 0.16 1657.59 121.16 32 6623.5 6639 FET MWD030 HR 500.25 503.3 501.367 32 6623.5 6639 GR MWD030 API 56.85 87.03 70.5034 97 6580 6628 ROP MWD030 FPH 0.14 144.62 16.6414 80 6648.5 6688 First Reading For Entire File..........6580 Last Reading For Entire File...........6688 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number...........1.0.0 Page 8 ~ ~ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6628.5 RPS 6639.5 FET 6639.5 RPM 6639.5 RPx 6639.5 RPD 6639.5 oP 6688.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Gamma Module EWR4 EWR Phase-4 3C-14A.txt STOP DEPTH 6836.5 6847.5 6847.5 6847.5 6847.5 6847.5 6896.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: Page 9 21-FEB-08 Insite 4.30 Memory 22.7 32.3 TOOL NUMBER 78005 211047 4.750 6628.0 Polymer 14.30 55.0 9.3 90000 5.8 .100 65.0 .053 129.0 .080 65.0 .180 64.0 . MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 3C-14A.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MwD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6628.5 6896 6762.25 536 6628.5 6896 RPD MWD040 OHMM 0.68 856.62 6.90062 417 6639.5 6847.5 RPM MWD040 OHMM 0.47 1426.54 9.92616 417 6639.5 6847.5 RPS MWD040 OHMM 0.42 1186.92 9.28376 417 6639.5 6847.5 RPX MWD040 OHMM 0.12 11.66 3.66875 417 6639.5 6847.5 FET MWD040 HR 4.75 521.27 36.3108 417 6639.5 6847.5 GR MWD040 API 53.16 162.73 100.931 417 6628.5 6836.5 ROP MWD040 FPH 0 80.64 16.7098 416 6688.5 6896 First Reading For Entire File..........6628 Last Reading For Entire File...........6896 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header Page 10 3C-14A.txt service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/05/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6837.0 6893.0 RPM 6848.0 6904.5 RPx 6848.0 6904.5 RPS 6848.0 6904.5 RPD 6848.0 6904.5 FET 6848.0 6904.5 RoP 6896.5 6953.0 LOG HEADER DATA DATE LOGGED: 22-FEB-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 35.4 MAXIMUM ANGLE: 42.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Gamma Module 78005 EWR4 EWR Phase-4 211047 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.750 DRILLER'S CASING DEPTH (FT): 6628.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 14.30 MUD VISCOSITY (S): 51.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 86000 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .100 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .051 134.0 MUD FILTRATE AT MT: .080 65.0 MUD CAKE AT MT: .180 65.0 Page 11 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): U 3C-14A.txt REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6837 6953 6895 233 6837 6953 RPD MWD050 OHMM 5.56 8.94 6.69184 114 6848 6904.5 RPM MWD050 OHMM 4.75 8.54 6.15123 114 6848 6904.5 RPS MWD050 OHMM 4.82 8.95 6.34509 114 6848 6904.5 RPX MWD050 OHMM 4.4 8.76 6.12719 114 6848 6904.5 FET MWD050 HR 1.79 31.54 21.4031 114 6848 6904.5 GR MWD050 API 70.83 96.01 85.3845 113 6837 6893 ROP MWD050 FPH 0.68 98.78 38.1288 114 6896.5 6953 First Reading For Entire File..........6837 Last Reading For Entire File...........6953 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/05/02 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Page 12 3C-14A.txt Physical EOF Tape Trailer Service name .............LISTPE gate . ...................08/05/02 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................08/05/02 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical Services scientific Technical services Page 13