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207-119
New Plugback Esets 8/13/2024 Well Name API Number PTD Number ESet Number Date 1E-28A 50-029-20832-01-00 213-095 T39403 5-15-2014 1E-112 50-029-23211-70-00 204-091 T39404 10-19-2004 3N-14APB1 50-029-21589-70-00 207-119 T39405 2-3-2009 Nikaitchuq 3 PB1 50-629-23242-70-00 205-001 T39406 5-23-2005 Nikaitchuq 3 PB2 50-629-23242-71-00 205-001 T39407 5-23-2005 Nikaitchuq 3 PB3 50-629-23242-72-00 205-001 T39408 5-23-2005 ODSK-41 PB1 50-703-20585-70-00 208-147 T39409 2-27-2009 ODSN-26 PB1 50-703-20642-70-00 211-121 T39410 2-1-2012 ODSN-26 PB2 50-703-20642-71-00 211-121 T39411 2-1-2012 ODSN-29 PB1 50-703-20661-70-00 212-106 T39412 6-12-2013 ODSN-29 PB2 50-703-20661-71-00 212-106 T39413 6-12-2013 Z-05APB1 50-029-22056-70-00 190-078 T39414 10-13-2013 3N-14APB1 50-029-21589-70-00 207-119 T39405 2-3-2009 WELL LOG TRANSMITTAL #905958382 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3N -14A Run Date: 9/6/2019 207119 3 135 9 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3N -14A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21589-01 RECEIVE® OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ` M— Q F— P QF-P ;.n I 1. Operations Abandon ❑ Plug Perforations Fracture Stimulate ❑ ❑ ❑ Pull Tubing ❑ Operations shutdown Performed: Suspend ❑ Perforate Other Stimulate ��^' '.i°'-'' ❑ ❑ Alter Casing ❑ Chas Yoved Own ❑ Plu for Redrill °�'`�" Install g ❑ 'erforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: Install Patch 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 207-119 3. Address: P. O. Box 100360, Anchorage, Alaska Stratigraphic ❑ Service ❑ 6. API Number: 99510 50-029-21589-01 7. Property Designation (Lease Number): e. Well Name and Number: ADL 25521, 25520 KRU 3N -14A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,220 feet Plugs measured None feet true vertical 6,647 feet Junk measured None feet Effective Depth measured 8 218 feet Packer measured 3,372, 7,519 feet true vertical 6,645 feet true vertical 3,371, 6,072 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 feet 16 110' MD 110' MD SURFACE 2,542 feet 10 3/4 " 2,579' MD 2,579' MD PRODUCTION 7,440 feet 7 7,472' MD 6,035' MD 5.5" LINER 4,338 feet 5 1/2 " 7,710' MD 6,228' MD 3.5"LINER 699 feet 3 1/2 " 8,218' MD 6,645' MD Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 7,526' MD 6,078' TVD Packers and SSSV (type, measured and true vertical depth) CHP Liner Top Packer 5.5" x 7" 3,372' MD 3,371' TVD Upper Patch Packer 7,395' MD 5,976' TVD Lower Patch Packer 7,420' MD 5,995' TVD ZXP Liner Top Packer 5.5" x 3.5" 7,519' MD 6,072' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Met Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - _ _ _ Subsequent to operation: 14. Attachments (required per 20 MC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service ❑ Stratigraphic F] Copies of Logs and Surveys Run E116. Well Status after work: Oil D Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Sara Carlisle Contact Name: Sara Carlisle / Rachel Kautz Authorized Title: Well Integrity Contact Email: N2549@conocophilllps.com Specialist `&^Compliance Q Authorized Signature: 9 W `�/ N" ✓� Date: / 1!� Contact Phone: 907-659-7126 Form 10-404 Revised 4/2017 RBDMS.1fA-/SEP 19 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 16, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer 3N -14A (PTD 207-119). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, scv� CM'6�tu Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Date 3N -14A DESCRIPTION OF WORK COMPLETED After a failed TIFL on 3N -14A, a tubing leak was identified and repaired by installing a through tubing patch. The intengrity of the patch was confirmed with a passing CMIT TxIA against the lower patch packer and a passing MIT -T and CMIT TxIA against the upper patch packer. 07/08/19 (AC EVAL) PROACTIVE TIFL (FAILED DUE TO INFLOW & PRESSURE INCREASE). 08/02/19 09/02/19 09/06/19 09/07/19 09/08/19 RUN 1: PERFORM LDL, LEAK FOUND AT 7410'. RUN 2: PERFORM CALIPER FROM TOP OF PLUG AT 7485 TO SURFACE. PULLED 3 1/2" SLIPSTOP CATCHER (RECOVERED PACKOFF ELEMENT) @ 7495' RKB; BRUSH n' FLUSHED PATCH INTERVAL FROM 7380'-7450' RKB; DRIFT W/ 2.75" X 20' DMY PATCH DRIFT DOWN TO 7450' RKB. SET LOWER 2.72" ER PACKER @ 7420' RKB (ME) (CAL 2.87'). PERFORMED CMIT- T x IA TO 2200 PSI w/ ER TEST TOOL **PASS**. CMIT TxIA TO 2200 PSI (PASS) PRE TEST T/I/0= 1675/1500/420 PRESSURE UP W/ 0.6 BBLS INITIAL T/110= 2200/2050/420 15 MIN T/1/0= 220012050/420 30 MIN T/1/0= 2200/2050/420 BLEED BACK TO 1700 PSI SET NEW 2.72" UPPER ER PACKER PATCH ASSEMBLY @ 7395' RKB (26.49" CAL) SET 3.5" ER TEST TOOL IN UPPER PACKER @ SAME. CMIT TBG x IA TO 2200 PSI **PASS**. PULLED 1" GLV @ 6549' RKB, REPLACED w/ OV (1/4" PORT). PULLED 1" GLV @ 3907' RKB, ATTEMPT TO PULL GLV @ 4982' RKB SEVERAL TIMES UNABLE TO LATCH DO TO SCALE, PULLED GLV @ 3908' RKB, SET GLV @ SAME (3/16" PORT/ 1321 TRO), PULLED 1" GLV @ 2590' RKB, SET GLV @ SAME (5/32 /TRO 1280), RAN CHECK SET TO REMOVE SCALE FROM LATCH @ 4982' RKB, PULLED GLV @ SAME. CMIT TxIA TO 2200 PSI (PASS) BUMP UP PRESSURE w/ 1 bbl diesel INITIAL T/I/0= 2220/2140/440 15 MIN T/I/0=2200/2140/440 (-20/-0) 30 MIN T/1/0= 2200/2140/440 (-0/-0) BLEED BACK TO 1700 PSI SET GLV @ 4982' RKB (3/16" PT / TRO 1318), DRAW DOWN TEST ON IA GOOD, MIT TBG 2200 ***PASS***, PULLED 3 1/2 ER TEST TOOL @ 7395' RKB. MIT -T TO 2200 PSI (PASS) PRE TEST T/I/O = 1675/550/420 PRESSURE TUBING WITH 0.1 BBL INITIAL T/I/0= 2225/550/420 15 MIN T/I/0= 2200/5501420 30 MIN T/1/0= 2175/555/420 (-25/+5) 45 MIN T/110= 2175/5551420 (-0/0) BLEED BACK 0.16 BBLS TO 1700 TBG \ KUP PROD WELLNAME 3N -14A WELLBORE 3N-1407 ConocoPhill(ps Well Attributes Max Angle&MD TD Aidska, Inc.Flela Name Wellbom APIIUWI Willook Stalue (XK ncl r) Mp (XKB ptt elmB) J KUPARUK RIVER UNIT 50n29215H9n1 PROD 55,38 5,38428 8,218.0 Comment 833 -NOas. g"n X;n Entl Dale 1111(!6 RIIl Relessapale 4C0 2 SSSV: NIPPLE 11261201] Las1WO: 011012014 39.49 11/1200] the Ike, 4Lion 7711 M IN I Last Tag Peace edeacer(esse, IL4NCEP: R2.0 pnnonewn Last Tag: RK8(Est. 35' of Fill Leaving So to Open Pel(e) pept5 (XNB) Entl Date ],910.09/212019 WellEors 3N-1407 L41 Motl ay zembaej Last Rev Reason AnnnmNon End Dale wenoon Last Mna 9y Rev Reason: Set Patch Assembly, Chax9etl GLI';: 9182019 3N-1407 bV:otlhi Casing Strings CONDunh.P:..lne v ream. eecnp,.on OD(n l0 (in) Top(flKB) Set Daptchrpol) dilutor Il' Tvo.-wel .anp crza. Top TM1r.aE CONDUCTOR 16 15.06 39.5 110.0 110.0 62.50 HAD Laing Descriplfon OD (In) In In Top (XKa) Sal pepifi (flKB) Set Depth (Rp)... WVLen (I... Gretle Top TM1reaE SURFACE 103/4 9]9 37.0 2,5]91 2.578.9 45.50 K-55 BTC NIPPLE;4233 casing excite- Do (in) II(in) Tap (flea) 4¢t Deldpi n Set Depth DMD)... WVLen (I... GyOe Top Th Med PRODUCTION ] 6.28 32.1 ),471.9 6,034.9 26.00 J-55 SITE Cesina Description DD (In) 10 (in) lop(ttKID Sel Depth dtlep SN Depth TVp)... WVLen (I... GnEa Top Tllreatl 512 4.95 3,3]16 7,710.0 8,22]5 15.50 L-80 Hytlri1511 LinerLiner LlnerDe Hs SURFACE i 3)04t,epul- KO PIP Joie, R SA9 Top(NUD Top I((IKa) Top Incl (°) @m pes Co. Nominel l0 p-1 3,3]16 3,371.4 0.49 PACKER BAKER 5.5'X7"LTP"CHP"C-2p,o51ew'6'ssL Est 5.500 5.5° ID use U5i:259p° x Pap J.1". Mea 3,382.6 3,362.4 0.50 HANGER HMC liner hanger -5.5"Vain p Xp (4.98- ID 4.980 C5 Llnesalplion 31/2 IO(In) Top (XKa) Set peplll (XKB) Set DeplM1 (lYp)... WVLen (I... L r.". rop Moore 35 "Liner 31/2 2.99 7,5190 8,218.0 Q645.1 9.20 L-Hn Hytlri1511 Liner Details Top(XKa) Top (TVDuxi Top Incl (°) hem pm Com Nominal 1p (in)) rues PIR 5ea7s des un1 aa.za 7,519.0 6,0719 3257 PA"Ite Baker ZXP LINER TOP PACKER 4.000 7,544.9 6,092.5 36.94 HANGER HMC LINER HANGER 2.910 ."Ies.o Tubing SMngs Tuh ins Cescnplion 3lring Ma... ID(in) Tap (ftKa) Set peplM1 (ft. 3e10eplh WI(IE/!n Grace Top de -en.. TUBING -WO 3112 2.99 22.0 7,526.4 6,)]].8 9.30 L-80 IBTM GAS LIFr; 1,%].9 Completion Details To'(I.) Top Incl Nominal Top (ryK6) (XKa) (°) Ilam Des Com IS (16) 22.0 220 0.00 HANGER FMC GEN 5 HANGER W/PUP y,990 4989 4913.5 0.22 NIPPLE CAMCO Be NIPPLE 2.875 cAsurT;¢54ae 7,4630 6,027.9 38.97 NIPPLE CAMCO D NIPPLE MILLED TO 290"10/112014 2.800 7,510.2 6,064.9 37.79 BAKER BAKERLOCATORSUB 85EgLS 2.990 LOCATOR ].511.4 13,065.9 37.76 SEAL ASSY BULLET SEALS ASSY 0990 Otheir In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) rop(,, Tspin, - UPPERPAClux(NE)1]aesa Tnp(XKa) reel) (°) pea Com Ran Dale IS (in) 7,395.0 5,976.0 41.60 UPPER 2.72" UPR VITRO ER PKRwI PATCH ASSEMBLY ISM 9RI2019 1.750 PACKER(ME) CP350891DP5350057)ON 26.49' sPAcSa PIPEpa95q DAsuF[7,4d>a 7,396.0 5,976.7 4L56 SPACER PIPE 2- 318"SPACER PIPE w1ANCHOR LATCH (OD 2074') 917I2019 1 1]50 Lowes PACKER (MEk 74211 7,420.0 5,994.8 40.51 LOWER 2]2"LWRWI- Eft PKR(SN: CP35005U UAL 2.37 91512019 1 1.750 PACKER (ME) PeeroratbnsBSfots a",xIPPLE: 7u., PRppuorlox:32fa.4119 (HKa) Top TVDl art UVD) as TopTop arm pion MKS) (A.) Unlatch 2N.. N. (s pa Core 7,8900 ],905.0 fi,3]5.4 6,367.6 A-3, 3N-1407 611912009 fi.0 APERF 2"H SC RICK 6D Ueg Phase 7,925.0 7,945.0 6,403.9 6,420.2 A -2,3N -14A 11/82007 6.0 /PERF 25"HJ, 60 deg phase Frac Summary aexFPCOCATOR; 1,5102 3ta,t Date Proppanl Declared (to) Proppanl in F -he -Ii.. (1E) 11/1020107 SEALAS3Y; 1,51fA St9b SIeM1 Gale Top peplM1 (flKB) and PXID Link to Fluid Sister, Vol Veen(US volslumloop 1 11/10200] ],925.0 ],945.0 ) It a1MDate09 Pwppant Dea k -(IE) Proppanl In Finnish- pro, 5126120 atgp 9aM1 pale Top Depth (I alm(ekin Link to Fluid Syalem Vol Close phot) Vol St., abl) 1 5262009 30.0 7,890.0 Mandrel Inserts sI an an ioMIKB) N Ta (2,58 Make vain. Larch least- TRO Ran Motlel OD (in) aery Type Type (In) (pal) Run She Com 2,590. 1 2,590.0 2,5899 CAMCO KBG2- 1 GAS LIFT GLV BTM 0.155 1280.0 9 9/7/2019 11:30 2 3,907.9 3,902.7 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.188 1,321.0 9 9/7/2019 190 55"orv. a3n 6>,nos 3 45829 4,7887 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.188 1,318.0 9 9/82019 500 4 6,549.8 5,502.3 CAMCO KBG-2- 1 GAS LIFT OV BTM 9 0.250 0.0 97/12019 100 5 ],40]6 5.9854 CAMCO KBG-2- 1 GAS LIFT OPEN OPEN 0.000 0.0 81302019 9 Notes: General & Safety Enc Date A-1stion 9/2912007 NOTE: WELLSIDETRACKED .PERF: ].5M.6>,ap50� 111212001 NOTE/ "WARNING" DO NOT EXCEED 2500 psi ON IA DUE TO LINERTOP PACKER 1121/2007 NOTE: CHINA CAP FROM I" UMYLOSTINWELL11Q1200> Feed:79250 512012009 NOTE: VIEW SCHEMATIC wlglaska Schemalic9.0 PERK I..2517,945a 5/112014 NOTE: ISP PARTED ON PULL. LOWER HALF STILL IN HOLE. cS.I.-",751eci Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: n ry/ AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision \6 333 W. 7th Ave, Suite 100 . Anchorage, AK 99501 2071 19 3 107 6 • •00 • 6 -Aug -19 TRANSMITTAL # 06Aug19-JW 01 WELL NAME AN 4 ORDERSERVICE #Color FIELD NAME DESCRIPTIONDELIVERABLE DESCRIPTIONDATA r. TELOGGED Prints CO's 1H-114 1 H•111 1H-105 1H-113 1H-116 3M-19 3G -07A 50-029-23584-00 50.029-23581-00 50-029-20727-01 50-029-23588-00 50-029.23594-00 50-029.21737.00 50.103-20127-01 EOSH-00071 EAI8.00022 E118-00075 E118-00076 E118-00077 E118.00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPAR UK RIVER KUPARURIVER KUPARUK RIVER WL WL WL WL WL WL WL (PROF IPROF-WFL IPROF-WFL IPROF-WFL (PROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD --R NAL NAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19 -Jul -19 20 -Jul -19 21 -Jul -19 22-Ju1-19 23 -Jul -19 1 1 1 1 1 1 1 3G-11 50.103-20133-00 E118.00081 KUPARUK RIVER WL IPROF FINAL FIELD 25 -Jul -19 1 3M-13 1B-16AL1 1A-17 1C-121 3N -14A 3G-08 50-029-21720-00 50-029.22457-60 50-029-22102-00 50-029-23015-00 50.029-21589-01 50-103.20128.00 E118-00084 EDEA -00009 E118-00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL IPROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28 -Jul -19 28 -Jul -19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3 -Aug -19 1 1 1 1 1 1 2N-317 50-103-20266.00 EOSH•00076 KUPARUK RIVER WL LDL FINAL FIELD 4Aug-19 1 15 Please return via courier or sign/scan and email a copy to SCANNED AUG 0 7 2019 and OPAL Schlumberger -Private ATransmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package havebeen verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. 20Z—� c� zGz.{4 '. WELL LOG TRANSMITTAL#902805242 DATA LOGGED l‘AO/201S l. K.BENDER To: Alaska Oil and Gas Conservation Comm. November 6, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC): 3N-14A Run Date: 10/3/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3N-14A Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21589-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ✓a__ uv Image Project Well History File Gover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~' ~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: „wvsaea iiuiiiiiiiimiiii DIGI AL DATA Diskettes, No. ^ Other, No/Type: ae~,~~~ea~ iiuiiiii~iuiiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: r Maria ~_ Date: ~ ~, ,,) ~ ~ f (~ - /s/ r ~( " roofin Project P g ~~ IIIII~IIIIIIIIIIII) BY: Maria Date: 1 D lsl ,~ Scanning Preparation x 30 = ~ ~ ~ + ~ =TOTAL PAGES~~`7 ,. , ude cover sheet) '/J (Count does not i BY: ~ Maria Date: n S~ V I/ I Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: , ~..~ 1 ~ Qg /s/ ,r Y l Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I II II I (III ReScanned III II111111111 IIIII BY: Maria Date: Comments about this file: 1~ o~a„~~e~,ed iuuiiiiiuuiui P 10/6/2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA ALA. 1 OIL AND GAS CONSERVATION COW,.__.TION MAY 1 2 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell P' Rug Perforations r Perforate r Other Alter Casing r Pull Tubing P Stimulate-Frac r Waiver r Time Extension AprOGCC Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 207-119 ' 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21589-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25521,25520 3N-14A ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8220 feet Plugs(measured) 7618 true vertical 6647 feet Junk(measured) none Effective Depth measured 8086' feet Packer(measured) 3372, 7519 true vertical 6535' feet (true vertical) 3371,6072 Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 16 110 110 SURFACE 2542 10.75 2579 2579 PRODUCTION 7440 7 7472 6035 5.5"LINER 4338 5.5 7710 6228 3.5"LINER 699 3.5 8218 6645 Perforation depth: Measured depth: 7890'-7905', 7925'-7945' True Vertical Depth: 6375-6388',6404'-6420' SCANNED MAY 292014 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7521 MD,6086 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 5.5 x 7"LTP PACKER @ 3372 MD and 3371 ND PACKER-BAKER ZXP LINER TOP PACKER @ 7519 MD and 6072 ND NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this workover Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in _ Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F7- Service r Stratigraphic r 16.Well Status after work: Oil r✓ Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Theresa Lee A 263-4837 Email Theresa.M.LeeCa conocophillips.com Printed Name Theresa Lee Title Wells Engineer / ci �' Signature4ee....., Phone:263-4837 Date 9 - VL- F 5/20/14 RBCMS MAY 14 20 4 Form 10-404 Revised 10/2012 "/"j57"/- y Submit Original Only A,- belt` KUP PROD 3N-14A ConocoPhi lips .ffiNms. Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UW1 Field Name Wellbore Status ncl(°) MD(ftEE) Act Btm(ftKB) 500292158901 KUPARUK RIVER UNIT PROD 65.38 5,384.28 8,220.0 "" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-14A,4/320143:59:43 PM SSSV:TRDP 175 11/27/2012 Last WO: 39.49 11/1/2007 • Vertical schematic(actuals Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _........................................................... Last Tag:SLM 7,880.0 4/16/2013 Rev Reason,SET PLUG lehallf 4/3/2014 HANGER;22.1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread • CONDUCTOR 16 15.062 39.5 110.0 110.0 62.50 H-40 Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread • SURFACE 103/4 9.794 37.0 2,579.1 2,578.9 45.50 K-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 7 6276 32.1 7,471.9 6,034.9 26.00 J-55 BTC Casing Description OD(in) 10(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 5.5"Liner 51/2 4.950 3,371.6 7,710.0 6227.5 9.20 L-80 Hydril 511 a -Liner Details Nominal ID CONDUCTOR;39.5110.0 Top(ft(B) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) I 3,371.6 3,371.4 0.49 PACKER BAKER 5.5"X 7"LTP"CHP"C-2 profile w/6'ext. Est 5.500 5.5"ID SAFETY VLV;2,013.0 3,3826 3,382.4 0.50 HANGER HMC liner hanger-5.5"Vern p X p (4.96"ID) 4.960 Casing Description IOD(in) IID(in) Top(ttKB) 'Set Depth(ftKB) 'Set Depth(ND)...'WtlLen(I...I Grade I Top Threatl il 3.5"Liner 31/21 2 2.992 7,5190 8,2180 6,6451 9.20 L-80 Hydril 511 • Liner Details GAS LIFT;2,342.2 Top/ftKB) To Nominal ID Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7.519 0- 6,071.9 37.57 PACKER Baker ZXP LINER TOP PACKER 4.000 7.544.9 6.092.5 36.94 HANGER HMC LINER HANGER 2.910 • Tubing Strings • Tubing Description 'String Ma,,,ID(in) I Top(ftKB) I Set Depth(ft..f Set Depth(ND)(...I WI(Ib/ft) 'Grade I Top Connection SURFACE;azo-2,579.1-� TUBING 31/2 2.992 22.1 7,53641 6,085.7 9.30 L-80 IBTM _ Completion Details Nominal ID Top IttKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 22.1 22.1 0.00 HANGER FMC 3.5"Gen IV Tbg Hanger 3.500 2.013.0 2,013.0 0.88 SAFETY VLV 3.5"SCSSV TRMAXX-5E w/2.812"X profile IBTM Sr# 2.812 HZS-138(LOCKED OUT 3/17/2014) 7,446.6 6,015.2 39.38 NIPPLE 3.5"x 2.75"Camco"D"Nipple EUE 8RD 2.750 • GAS LIFT;3,7075 . /,521 0 6,073.5 37.52 SEAL ASSY Bullets seal assembly 2.980 ACID;300 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) l': .. Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID lin) GAS LIFT;4,981.4a 7,583.0 6,123.1 36.08 SAND DUMP BAILED SILICA SAND ON IBP 3/25/2014 I.•; -- 7,618.0 6,151.6 35.29 PLUG SET BAKER 2.5"IBP 3/24/2014 Perforations&Slots Shot GAS LIFT;6,408.2 a Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type , Com 7,890.0 7,905.0 6,375.4 6,387.6 A-3,3N-14A 6/19/2009 6.0 APERF 2"HSC HMX 60 Deg Phase 7,925.0 7,945.0 6,403 9' 6,420.2 A-2,3N-14A 11/8/2007 6.0 (PERF 2.5"HJ,60 deg phase Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) GAS LIFT;7.396.7 (ftKB) (ftKB) (ttKB) (ftKB) Type Date Com 7,925.0 7,945.0 6,403.9 6,420.2 FRAC 11/10/2007 A2 SAND FRAC,195,046#INTO A2 SAND PERFORATIONS 30.0 7,890.0 30.0 6,375.4 ACID 5/26/2009 TBG scaled pre-PERFs,acid wash w/50 bbls HCL top of PERFS to Surface w/diesel cap NIPPLE,7.446 641 Mandrel Inserts St ati on Top(NO) Valve Latch Port Size TRO Run PRODUCTION;32.1-7471.9 N Top(ttKB) (ftKB) Make Model 9 OD(in) Sery Type Type (in) (psi) Run Date Com 2,3422 2,342.1 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 11/16/2013 2 3,707.5 3,706.6 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 11/16/2013 9 SEAL ASSY;7.521.0 3 4,981.4 4,787.8 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 11/16)2013 9 4 6,408.2 5,440.2 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 10/30/2007 9 5 7,396.7 5,977.2 CAMCO KBG-2- 1 GAS LIFT OPEN 0.000 0.0 11/16/2013 9 Notes:General&Safety End Date Annotation SAND;7,583.0 9/29/2007 NOTE:WELL SIDETRACKED 11/2/2007 NOTE: "WARNING"°DO NOT EXCEED 2500 psi ON IA DUE TO LINER TOP PACKER 11/21/2007 NOTE:CHINA CAP FROM 1"DMY LOST IN WELL 11/21/2007 PLUG;7,618.0 51/2V:22000097 /20)2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 11/1/2013 NOTE:LEAK IN TUBING AT 5030'RKB 12/11/2013 NOTE: Mandrel Orientation: 1)9:00 2)3:00 3)9:00 4)11:30 5)8:00 GLM 3,4,5 updated 322/2014 5.5"Liner;3,371.6-7,710.0 APERF;7,890.0-7,905.0- _ IPERF;7,925.0-7,845 7,925.001 , ]FRAC, 3.5"Liner,7,519.0-8.218.0 ?"' 14A PRE-RIG WELL WORK SUMMARY DATE SUMMARY 2/7/2014 (PRE RWO) T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; FUNCTION TESTED ALL LDS-ALL FUNCTIONAL 2/8/2014 (PRE-RWO) MITOA- PASSED 3/15/2014 BAIL FILL AND PULLED CATCHER @ 7415' SLM; BAIL FILL ON PLUG @ 7447' RKB. IN PROGRESS. 3/16/2014 BAIL FILL & PULLED 2.75" CA-2 PLUG © 7447' RKB; TAG W/2.64 CENT & GAUGES MEASURE BHP © 7464' RKB (301'ABOVE TARGET DEPTH). MAX PRESSURE 3996 psi. ATTEMPT BRUSH n' FLUSH &TBG/IA PSI UP AFTER 2 BBLS. WORKED 2.64" CENT W/2.5" BAILER FROM 7478' TO 7488' SLM. WORKED 2.69" GAUGE RING FROM 7468'TO 7495' SLM (TOP OF LINER © 7519' W/ IBP TARGET DEPTH OF 7631') IN PROGRESS. 3/17/2014 BROACH UP TO 2.47" DOWN TO 7698' SLM; DRIFT FOR IBP DOWN TO 7695' SLM; LOCK OUT TRMAXX-5E SSSV @ 2013' RKB; BROACH FROM 7497' SLM TO 7569' SLM W/2.69" BROACH. (IBP TARGET AREA 7631' RKB) IN PROGRESS. 3/18/2014 BROACHED TBG FROM 7550'TO 7645' SLM UP TO 2.72". READY FOR E-LINE. 3/22/2014 LOG CORRELATED TO TUBING TALLY RECORD DATED NOV. 1, 2007. LOG 24 ARM CALIPER VERIFICATION PASS FROM 150'TO SURFACE. LOG REPEAT PASS FROM 7680' TO 7405'. LOG MAIN PASS FROM 7644'TO 4900'. JOB IN PROGRESS. 3/24/2014 SET 2.5" BAKER RETRIEVABLE PLUG AT 7625'. CCL TO MID ELEMENT OFFSET: 23.7', CCL STOP DEPTH: 7601.3'. LOG CORRELATED TO HES MULTIFINGER CALIPER LOG DATED MAR 22, 2014. READY FOR SLICKLINE. 3/25/2014 TESTED TBG/ IBP 2000 PSI, GOOD. DUMPED 12' SILICA SAND ON IBP. READY TO LOAD WITH BRINE. 3/29/2014 LOADED TBG/ IA WITH 200 BBL INHIB 9.6 PPG BRINE. COMBO MIT 2000 PSI, PASSED. DRAWDOWN TO ZERO, PASSED. COMPLETE. ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 3N-14 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/7/2014 7:30:00 PM Rig Release: 4/10/2014 11:30:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/06/2014 24 hr Summary Begin Rig Move from 1B to 3N pad 22:00 00:00 2.00 MIRU MOVE MOB P Begin rig move from 1B to 3N pad 04/07/2014 Move rig to 3N pad. Hang tree in cellar. Spot rig over well. Spot auxiliary equipment, berm up cellar. Load pits with 9.6 ppg Brine, R/U kill Tank containment. Lubricate out BPV. 00:00 04:00 4.00 MIRU MOVE MOB P Move rig to from 1B to 3N. Currently at 1Q. 04:00 07:30 3.50 MIRU MOVE MOB P Wait on CPAI changeout 07:30 10:30 3.00 MIRU MOVE MOB P Continue moving rig from 1Q access to CPF pullout.3 10:30 13:00 2.50 MIRU MOVE MOB P Allow traffic to pass. Wait on ENI changeout. 13:00 13:30 0.50 MIRU MOVE MOB P Continue move rig to 3C 13:30 14:30 1.00 MIRU MOVE MOB P Wait on Camp 3 to pass 14:30 17:30 3.00 MIRU MOVE MOB P Move on to 3N pad. 17:30 18:30 1.00 MIRU MOVE MOB P Hang Xmas tree in cellar. 18:30 19:30 1.00 MIRU MOVE MOB P Spot rig over well. Rig accepted at 19:30 19:30 21:00 1.50 MIRU MOVE MOB P Shim rig, spot auxiliary equipment. Spot hardline. Berm up cellar. 21:00 22:30 1.50 MIRU MOVE MOB P Load pits with 9.6 ppg brine. R/U kill tank containment 22:30 00:00 1.50 MIRU WHDBO MPSP P PJSM, Lubricate out BPV. 04/08/2014 R/U hard line and PT. ISITP 0 ISCP 0. Circulate 9.6 ppg brine around. Monitor well, static. Set BPV and test. N/D tree. Set blanking plug. N/U BOPE and test. Attempt to pull BPV noted pressure behind. Circulate tubing volume @ 1 bpm. Monitor well, static. Pull BPV. M/U landing joint, BOLDS. Pull hanger to the floor, PU 90K free hanger, PU 125K to free seals. PUW 80K. Reverse circulate 130 bbls. L/D landing joint and hanger. R/U to POOH with completion to 7400'. 00:00 00:30 0.50 MIRU WHDBO MPSP P Continue to lubricate out BPV. 00:30 01:00 0.50 MIRU WHDBO SFTY P Pre-RWO meeting. 01:00 04:00 3.00 MIRU WELCTL CIRC P PJSM R/U and test hard line. (STIP 0 psi, ISICP 0 psi. Circulate 275 bbls 9.6 ppg brine at 4bpm holding 100 psi on the choke. ICP 880 psi; FCP 820. Shut in well. SITP 0, SICP 0. Blow down kill lines. 04:00 04:30 0.50 MIRU WELCTL OWFF P Monitor well. 04:30 05:30 1.00 MIRU WHDBO MPSP P Installed&test BPV to 1000 psi in flow direction . Good test Page 1 of 3 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:00 2.50 MIRU WHDBO NUND P PJSM ND Tree&adaptor flange. MU 3-1/2 eue 8rd working joint into 3-1/2 eue integral on tree. Took 8,000 lb over pull to pull free. Removed work jt set up to pick with bridge cranes&kick out. 08:00 12:00 4.00 MIRU WHDBO NUND P Install blanking plug, NU BOPE. Install riser and shell test BOPE equipment. Note-Installed 11"Long life GK 5,000 annular revision II element. 12:00 15:30 3.50 MIRU WHDBO BOPE P 24 hr Notice was given to AOGCC @ 19:50 hrs on 4-6-14 and right to witness was waived by Chuck Scheave @ 05:00 hrs on 4-8-14. Conduct Initial BOP test @ 250/ 3,000 psi with 3-1/2 test joint. Blinds, Kill,Choke 11,12,4, 3 1/2 IF dart, Hyd TD-pass Blinds, Kill HCR, Choke 7, 9, 10,3, IF floor valve, Man TD-pass Blinds, Man kill, Choke 2,8, 5, 3 1/2"8rd FOSV-Pass LPR, Choke 2, 6, 5-pass Annular, Choke 2,6, 5, Man Kill- Pass UPR, Hyd choke, Man kill-Pass UPR, Man Choke, Man Kill-Pass UPR, Choke 1, Man Kill-pass 15:30 19:30 4.00 COMPZ RPCOM CIRC P Suck stack. Stab mouse hole. PJSM with FMC. M/U XO, R/U to pull BPV. Observe slight pressure behind BPV. R/U and circulate tubing volume conventionally. 19:30 20:00 0.50 COMPZ RPCOM MPSP P Pull BPV. 20:00 20:30 0.50 MIRU RPCOM OWFF P Monitor flow-Static. 20:30 21:30 1.00 COMPZ RPCOM PULL P M/U landing joint BOLDS. Pull hanger to the floor. Hanger free at 90K, Seals pull free at 125K dropping to 90K 21:30 22:30 1.00 MIRU RPCOM CIRC P Reverse circulate 2 tubing volumes at 3 bpm 380 psi. 22:30 23:00 0.50 COMPZ RPCOM OWFF P Monitor well-static. 23:00 00:00 1.00 COMPZ RPCOM PULL P PJSM. R/U and pull de completion from 7521'to 7350'. 04/09/2014 POOH with decompletion from 7400'. 67 SS bands recovered. Load pipeshed. RIH with 3 1/2"Completion as per detail to 4500'. 00:00 03:00 3.00 7,400 5,505 COMPZ RPCOM PULL P POOH with decompletion from 7400' to 5505'. 03:00 03:30 0.50 5,505 5,505 COMPZ RPCOM RURD P L/D SSSV. 60 SS bands recovered. R/D SLB 03:30 11:30 8.00 5,505 0 COMPZ RPCOM PULL P Continue POOH with decompletion from 5505'. PUW 90K. Remaining 7 SS bands stack. Page 2 of 3 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 16:30 5.00 0 0 COMPZ RPCOM OTHR P Continue loading 3.5"completion string. 16:30 00:00 7.50 0 5,500 COMPZ RPCOM RCST P PJSM. R/U and RIH with 3.5" completion as per detail to 550' 34/10/2014 RIH with 3 1/2"completion. Engage seals and tag no-go. Space out 2.13'above no-go. M/U hanger and landing joint. Spot 9.6 ppg Corrosion inhibited brine with 5%CRW-132. Land tubing, RILDS. MIT-T to 3000 psi for 30 min. MIT-IA to 2000 psi with 1000 psi on tubing for 30 minutes-both pass. Shear out SOV at 1864 psi. Set BPV and test. N/D BOPE and inspect ram cavaties. N/U tree. Install production flange. Test 250/5000 psi. Pull BPV. Test tree to 250/5000 psi-pass. R/U and freeze protect well with 70 bbls of diesel and allow to U-tube. Set BPV. RDMO. Rig released at 23:30. 00:00 03:30 3.50 5,500 7,498 COMPZ RPCOM RCST P RIH with 3- 1/2"completion from 5500'to 7498' 03:30 04:30 1.00 7,498 7,532 COMPZ RPCOM HOSO P Break circulation at 1 bpm and observe pressure increase as seals enter. Tag No-Go at 7526.41'. Space out 2.13'above No-Go. M/U Hanger and Landing Joint. 04:30 05:30 1.00 7,500 7,500 COMPZ RPCOM CRIH P R/U and spot 9.6ppg corrosion inhibited brine wit 5%CRW-132 from seals to SOV on IA, chase with 20 bbls 9.6 ppg brine to clear lines. BD choke and kill lines. 05:30 07:00 1.50 7,500 COMPZ RPCOM THGR P Suck out stack. Land tubing hanger. RILDS 07:00 09:00 2.00 COMPZ RPCOM PRTS P PJSM. MIT-T to 3000 psi for 30 minutes, pass. Bleed off to 1000 psi. MIT-IA to 2000 psi while holding 1000 psi on tubing for 30 minutes- pass. Shear out SOV at 1864 psi. R/D hoses. 09:00 10:00 1.00 COMPZ WHDBO MPSP P PJSM. R/U and set BPV. Test to 1000 psi for 10 minutes-pass. 10:00 12:30 2.50 COMPZ WHDBO NUND P Open BOP doors and Inspect. N/D BOP and DSA. 12:30 15:00 2.50 COMPZ WHDBO NUND P N/U adapter and tree. Test pack offs to 250/5000. 15:00 16:30 1.50 COMPZ WHDBO MPSP P PJSM. Pull BPV. Well out of Balance. Bleed of. Install tree Iplug 16:30 17:30 1.00 COMPZ WHDBO PRTS P PJSM. R/U and test tree to 250/5000psi 17:30 21:00 3.50 COMPZ WHDBO FRZP P PJSM. R/U and freeze protect well. Reverse circulate 70 bbls at 1.8 bpm, 1700 psi. Allow to U-tube. 21:00 21:30 0.50 COMPZ WHDBO MPSP P PJSM. Set BPV. 21:30 23:30 2.00 DEMOB MOVE RURD P PJSM. Secure well. Clean up cellar. RDMO. Rig Released at 23:30 Page 3 of 3 14A POST-RIG WELL WORK SUMMAR' r ^ DATE SUMMARY POST RIG WELL WORK 4/30/2014 TAGGED FILL @ 7598' SLM; SET CATCHER © 7463' RKB; PULL SOV& SET OV @ @ 7407' RKB; PULL DV'S © 3908', 4982', & 6550' RKB. SET GLV'S @ 6550' &4982' RKB. IN PROGRESS 5/1/2014 PULL DV @ 2590' RKB; SET GLV'S @ 3908' &2590' RKB; PULL CATCHER @ 7463' RKB & BAIL FILL FROM 7600' -7625' SLM. IN PROGRESS 5/2/2014 BAIL SAND FROM 7622'-7632' SLM; RUN 2.50" IMPRESSION BLOCK DOWN TO 7632' SLM (TOP OF LIB); RIG DOWN FOR RIG MOVE IN AM. IN PROGRESS 5/4/2014 ATTEMPT TO EQUALIZE IBP @ 7618' RKB (JOB SUSPENDED DUE TO HIGH WINDS) IN PROGRESS ,.~. , ~'~ ~~~ ~` ` % ~,~~ ~ :~ ~-" ~, _~ y~_'~~~'~ MICROFILMED 6/30/2010 DO NOT. PLACE ANY. N EW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 14, 2009 RE: Gas Lift Survey: 3N-14A Run Date: 8/27/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-14A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21589-O1 ~ ~~®~ E C 2 ~ 2009 ~~-~r9 ,j~3~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto cvhalliburton.com Date: ", ,; ~~ ;~ ~ I Signed: ~ ~~;~ ~~~'~-®-- ~ l 0 ~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3N-14A Run Date: 6/19/2009 August 27, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-14A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21589-01 k ~. r~~ ,~.wu .y F _ `~~~~, ,~ ~,~,,~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: 6900 Arctic Blvd. ~b~,// ~j 1'fS~/`~~ Anchorage, Alaska 99518 - - - Halliburton Wireline & Perforating Attn: Rafael Barreto Signed: • ~ • STATE OF ALASKA ~~~~~ V G~ ~u~ o s zao~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~~~ska Oil & Gas Con~. Gomrniss~~~~ ~..~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate Q Other ~ ~ Alter Casing ^ Pull Tubing ^ Pertorate New Poo1 ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Driil Number: ConoCOPhillips AI2Ska, InC. Development ~ Exploratory ~ 207-119 /- 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21589-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', AMSL 62' ~ 3N-14A • 8. Property Designation: 10. Field/Pool(s): ADL 25521, 25520 Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8220' feet true vertical 6647' feet Plugs (measured) Effective Depth measured 8086' feet Junk (measured) true vertical 6535' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 73' 16" 110' 110' SURFACE 2542' 10-3/4" 2579' 2579' PRODUCTION 3506' 7" 3543' 3543' 5.5" LINER 4338' 5-1/2" 7710' 6227' 3.5" LINER 699' 3-1/2" 8218' 6645' Perforation depth: Measured depth: 78g0'-7905', 7925'-7945' t?~• E p~~; L ~ ~ ~ ~ ~ ~"~ ~ ~u3 ~ ~,.r U , i.. .~ ~. ~,.~ true vertical depth: 6376'-6388', 6404'-6420' Tubing (size, grade, and measured depth) 3.5", L-80, 7536' MD. Packers & SSSV (type & measured depth) Baker'CHP' pkr @ 3372', Ba ker ZXP pkr @ 7519' TRMAXX-SE SSSV @ 2013' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 30'- 7890' 50 bbls HCI Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 292 716 408 -- 170 Subsequent to operation 320 751 663 - 169 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Weli Operations _X 16. Well Status after work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce Titie Wells Engineer Signature Phone: 265-6471 Date ~~' 8--~~ ` Pre a b h n A//su Dr k 263-4612 7~ ~ ~ / Form 10-404 Revised 04l2006 ~~i ~~„ ~-~ ~~~s~~~ ~~~.~ Su mit Original Only . ,~,~. . ~~ ~~~~~ 3N-14A Well Events Summary DATE SUMMARY • 5/17/09 DRIFTED TBG WITH 5' X 2.5" ER. BROKE THRU BRIDGES @ 6262',6399,6601,6701,& 6768' SLM. UNABLE TO PASS 7793' SLM. PULLED 1250# BIND TO FREE TOOL STRING. *"*RECOVERED ~1 GAL OF FLAKY SCALE""*. IN PROGRESS. 5/18/09 MEASURED SBHP (SHORT OF TARGET) @ 7888' SLM (3417 psi)/ GRADIENT STOP @ 7766' SLM (3372 psi). UNABLE TO DRIFT PAST 6538' SLM WITH 2.79" G.RING & FULL BORE BRUSH.SzA~GE TBG TO 2.67" TO 7886' SLM. RECOVERED ~1 GAL FL.AKY SCALE IN DD BAILER. TURN OVER TO PRODUCTION TO FLOW WELL. 5/26/09 SPOTTED ACID TREATMENT IN PRODUCTION TBG/LINER LEAVING 50 BBLS OF 7.5% HCL FROM TOP OF PER AT 7925' TO SURFACE WITH 5 BBL DIESEL CAP. GOT HUNG UP IN SEAL ASSEMBLY WITH JET BLASTER HAD TO PULL 28K ( 16K OVER STRING WEIGHT) TO PULL FREE,POSSIBLE GLM FISH FROM PREVIOUS WEL~, WORK. TURN WELL OVER TO DSO TO POP AFTER CHANGE OUT 6/2/09 DRIFT W/ 2.70 CENT, 11' 7" X 2.50 DUMMY GUN, 5' X 2.50 DRIVE DOWN BAILER, TAG @ 7921' SLM. READY FOR E-LINE PERF. 6/19/09 RUN IN THE HOLE WITH 2" HSC PERFORATING GUNS, HMX 6 SPF, 60 DEG PHASE AND PERFORATE FROM 7890-7905'. TAG BOTTOM WITH GUN @ 7930' C~onocoPhillips ~~ `~` ... ~u,:,;..,~ f« ~~ SSSV. ~ 013 GAS LIFf, 2.362 SURFACE, 3]-2,519 GAS LIFT, 3.707 ncio, 30 GAS LIFf, 0.981 GAS LIFT GASLIFf, _ 7.397 NIPPLE. 7.617- PRODUCTION, _ 32-].450 SEALASSV. __ ].521 5.5' Linar, _ 3,372-7,7~0 APERF, ],890~],905 IPERF, ].525-].965 \ FRAC,].525 KUP ~ 3N-14A ~ WaIIGOreAPVUWI FieldName WeIlStatus lncl(°) MD(ftKB) AelBtrn(HKB) ~ I 500292758901 KUPARUK RIVER UNIT I I PRODUCING 65.38 5,38428 ~ 8,220.0 IComment H2S (ppm) IOale Mno[a[ion End Date KB-Grd (flf i iRig Release DaM SSSV: TRDP I 160 I 12/132008 ~last WO: I . . ..... .... .. I 39.49 11/1/2007 AnnoGtion ~Dep[h(flKB~ End Data MnoGtion Last Motl By ~';Entl Da~e Last Tag ELMD I 7,930.0 I 6/19/2009 Rev Reason: Acitl Wash, PERFS, TAG l.. Imosbor ~ 6/22/2009 Casin Strin s Gasing Description String 0... String ID ... Top (HKB) Sat Depth (f... Set Depth (ND) ... String Wt... String ... ~ String Top T~rd CONDUCTOR 16 15.062 39.5 110.0 110.0 6250 Hd0 I Gasing Description String 0... String ID ... Top (HKB) Sat Depth (f... Set Depth (ND) ... ' String Wt... String ... String Top ThM SURFACE 10 3/4 9J94 37.0 2,579.1 2,578.9 45.50 K-55 BTC Casing Description String 0... String ID ... Top (flKB) Sat Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.751 32.7 7,449.8 6,017J 26.00 J-55 8TC Casing Dascription String 0... String ID ... Top (flK8) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd S.S" Liner S 1/2 4.950 3,371.6 7,710.0 6,227.6 920 L-SO Hydril511 - ~._. __. _ . . . . 3,371.6 3,371A~ 0.52 PACKER BAKER 5.5" X 7" LTP "CHP" G2 profle w/ 6' ext. Est S.5" ID 5.500 3,382.6 3,382 41 0.52 HANGER HMC liner hanger - 5.5" Vam p X p ( 4.96" ID ) 4.960 Casi,g Description ~ IStrin 0... String ID ... Top (HKB) Set Dapih (f... Set Depih (ND) ... String Ntt... String ... String Top ThN 9 I ~3.5"Liner , 31/2 I 2.992 I 7.519A I 8,278.0 I 6.645.1 I 920 I L-80 Hydril511 Liner Details Top Daplh (TVD) Top Incl Top (flK8) (RKB) (°) Item Desaiption CommaM ~~~~ ID (in~ ~ 7,519.0 6,072A 37.57~PACKER BakerZXPLWERTOPPACKER 4.000 I 7,544.9 6.093.5 37.11 ~HANGER HMC LMER HANGER I, 2 910 i I 7,551.6~ 6,098.8~~~ 36.94~X0-Retlucing ~ 2.900 I Tubin Stnn s g ~ i Oescription T I 7hra __ Strin Wt.' 8J Set f... SetD ..'~String...~,StringTop Str3g ND)... .. 54 T~P TUBIN I I I ' L-80 . IBTM 22. 75364 6085 ~I 930 2 I 2.992 I Com le tion De tails i ToPDept~~ ~_ _'. " - (ND) Top Incl To~(kK8) (HKB~ ~ (°) Nam DaseripHOn Comment ID (in) 22.1 ~ 22.1 i -0_01 HANGER FMC 3.5" Gen IV Tbg Hanger 3.500 2,013.0 _ 2,013.0 0.88 SSSV 3.5' SCSSV TRMAXX-SE w/ 2.872" X profile IBTM Sril HZS-738 2.812 7 446.6 6,0152~ ~ 39.38 NIPPLE 3.5" x 2J5" Camco "D" Nipple EUE 8RD 2J50 J,521 A . 6.073.5~ ~ 37.52 SEAL ASSY Bulletl seal assembiy - 2 980 Perfora _. tions 8 Slots ~ . .. __ _._._ ._....----- .. ._ _. , ', , sna ~ . ' ~ Top (TVOJ Btm (TVD) ' ~^s I ~~ Toe(flK8) ~~~ Bbn (ftKB) I (flK6) (NKB) Zone ' Data (sh... Type CommeM 7,890 '~, 7,905 i 6,375J 6,387.SIA3, 3N-14A ~~6/1912009 6_OIAPERF ~2" HSC HMX 60 Deg Phase I 1 _ ~,925 ` 7,945 ~ I ' 6 404.0 6 4202'A-2, 3N-14A :1 VS/2007 ~ 6.0~ IPERF 25" HJ, 60 deg phase : ~~ , ; ; - _ ~Stimula ~ - - . tions $ .. . . . . Treatments - - - --- ~ _ I Min Top . Max Bbn ~, sonom . Top Daplh DeP~h i Depth 'i Depth : (ND) (ND) '~ ' (flK6) (RKB) ~ (kKB) (HKB) Typa Date CommaM 30.0 7,890.0 30 0 6.375J ACID S126/2009 TBG scaletl pre-PERFs, aciA wash w/50 bbls HCL I top oi PERFS ro SuAace w/diesel cap 7,925.O 7945.0 G.404.0 64202FRAC ~ 11/10/2007A2SANDFRAC,195,046#INTOA2SAND _ i PERFORATIONS Note§: General 8 Safety _._. ._..__' Entl Date ~ ..__ Annotation - 9f292007 -_ _. __ . . ' _'_.'. _- -.._- ~NO~IE:WELLSIDEiRACKED 17/2/2007 NOT~E: '"WARNMG' DO NOT EXCEED 2500 psi ON IA DUE TO LINER TOP PACKER 1 V2 V2007 ~ NOTE~ CHINA CAP FROM 1" DMV LOST IN WELL 1 V27/2007 5/20/2009 NOTE VIEW SCHEMATIC w/Alaska Schematic9A ~ 3.5' • i WELL LOG TRANSMITTAL 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: 3N-14A+PB1 May 22, 2009 AK-MW-527495 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 3N-14A+PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-103-20552-00 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-103-20552-00 Digital Log Images 1 CD Rom 50-103-20552-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling + _ ~ "`~~~r~-~~~ f' ~ {ti .~ Brya}~rn~al~~liburton. com ~ Oi! ~ G C®ns. Commissiorj Date: gn~ta~ ~0~-'/ ~ ~ ~~ ~.~ Signed: ~---'~' l ~l~c~~/ ®- /~%~ • • ~Dt'1CfCC1~11~~1 TRANSMfTTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7"' Ave. Suite 100 Anchorage, Alaska 99501-3539 RE: 3N-14APB1, 3N-14A Date: 1 /28/2009 North Slope, Kuparuk River Unit, Alaska 14A, 3N-14APB1 Report and CDROM Final Well Report, Mud Logging Data, 3N-14A, 3N-14APB1; Epoch, report date: 10/30/2007; table of nts, equipment and crew, well data, geological data, pressure and formation strength,drilling data, daily reports, formation logs; log prints 1 each for 3N-14A, and 3N-14APB1: Formation Log MD &TVD LWD Gombo Log MD &TVD Gas Ratio Log MD &TVD Drilling Dynamics MD &TVD ~~'~~~. e= ~:~ ~ ~~ 200 OM contains: well report, morning reports, LAS data, PDF and tiff format color log image files; DML; FIT files, litholagy remarks; TIFF files. CC: Heather Perfetta, CPAI Geologist ~~~~ ~~ ~ Receipt: Date: F~~ .9 ~ ~(i~~ x. ~I~ska Oil Gss ;~~~~ ~~atvtmi~sRtrs ~~~ GAS-Technical Data Management ~ Conte (Anchorage, Alaska ~ Ph.• 907.265.6947 Sandra.D.LemkeCa~Conoocophiflips com ~~-- ~ I~ ?mss Ya DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071190 Well Name/No. KUPARUK RIV UNIT 3N-14A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21589-01-00 MD 8220 TVD 6647 Completion Date 11/1/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~~ , Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Informat ion: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey ~t Directional Survey D Asc Directional Survey ~pt Directional Survey IS Verification L /~D C Lis E~ 15978!/Induction/Resistivity ' ~ LIS Verification , j~E,p' C Lis 15979 Knduction/Resistivity (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments 28 8220 Open 12/18/2007 28 8220 Open 12/18/2007 28 7768 Open 12/18/2007 PB 1 28 7768 Open 12/18/2007 PB 1 3505 8220 Open 2/29/2008 LIS veri, GR, RPD, RPS, RPM, FET, RPX, ROP 3505 8220 Open 2/29/2008 LIS Veri, GR, RPD, RPS, RPM, FET, RPX, ROP 3505 7768 Open 2/29/2008 P61 LIS Veri, GR, RPD, RPS, RPM, FET, RPX, ROP 3505 7768 Open 2/29/2008 PB1 LIS Veri, GR, RPD, RPS, RPM, FET, RPX, ROP vveu wres~~ampies uuvnnaopn: Name ADDITIONAL INFORM~ON Well Cored? Y N Sample Interval Set Start Stop Sent Received Number Comments Daily History Received?~L'" Chips Received? _eP71v' Formation Tops bY' N Analysis 'PT1Q Received? DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071190 Well Name/No. KUPARUK RIV UNIT 3N-14A Operator CONOCOPHILLIPS ALASKA INC MD 8220 TVD 6647 Completion Date 11/1/2007 Completion Status 1-OIL Current Status 1-OIL Comments: Compliance Reviewed By: API No. 50-029-21589-01-00 UIC N Date: • ~/ • ConocoPh ~ I I ~ ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ao~~ -~a ~`~~ ~~a Enclosed please find a spreadsheet with a list of wells from the Kuparuk f eld (KRL)). 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 October 19, 2008 and the corrosion inhibitor/sealantwas pumped October 21, 2008..The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,l -'~ `, ~~~ MJ L eland ConocoPhillips 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 r1a+p 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbts ft a! 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4"2" 10/19/2008 10.2 10/21!2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-1.19 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 WELL LOG TRANSMITTAL To: State of Alaska February 7, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 3N-14A PB1 AK-MW-5230436 1 LDWG formatted CD Rom with verification listing. API#: 50-029-215 89-70 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 ~- ~ ;, ~ ~ Signed: - ~g ~~~~ a ~. ~ ,~ ~`~ ~~,. ~ ..~..~- WELL LOG TRANSMITTAL To: State of Alaska February 7, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 3N-14A AK-MW-5230436 1 LDWG formatted CD Rom with verification listing. API#: 5,0-029-21589-0 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. Ancho~age~ Ala k ~ 8 i .. ... j ~ -a;-ct~ ~ Date: Signed: ~~~,~~q ~t5~~~ ~ ~ 9 ,~ p+~q~pq STATE OF ALASKA ~ ~~C Y ~ ~~Q7 ALASKA OIL AND GAS CONSERVATION COM I SIO , .. WELL COMPLETION OR RECOMPLETiON ° ~~$~~ 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: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: - ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 1, 2007 ~ 12. Permit to Drill Number: 207-119 / `r 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 4, 2007 ~ 13. API Number: 50-029-21589-01 4a. Location of Well (Governmental Section): Surface: 1561' FSL, 80' FEL, Sec. 29, T13N, R9E, UM ' 7. Date TD Reached: October 28, 2007 ~ 14. Well Name and Number: 3N-14A M Top of Productive Horizon: 736' FSL, 2475' FEL, Sec. 28, T13N, R9E, UM 8. KB (ft above MSL): ~ X28' a KBD ~9 Ground (ft MSL): 62' AMSL .~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 691' FSL, 2288' FEL., Sec. 28, T13N, R9E, UM 9. Plug Back Depth (MD + ND): 8086' MD / 6535' ND Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 518321 $' y- 6013799 ' Zone- 4 10. Total Depth (MD + ND): ~ 8220' MD / 6647 TVD y 16. Property Designation: ADL 25521, 25520 TPI: x- 521210 y- 6012982 Zone- 4 Total Depth: x- 521396 ~ - 6012938 ~ Zone- 4 11. SSSV Depth (MD + ND): 2013' MD / 2013' ND 17. Land Use Permit: 2557, 2556 1 S. 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 (ND): 2580' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ,~-~ ~ ~ ~ t-~7 'F 3 GR/Res ' 22. CASING, LINER AND CEMENTING RECORD r SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 23a sx CS II 10.75" 45.5# K-55 Surf. 2579' Surf. 2579' 13.5" 1150 sx AS III, 150 sx CI G w/100 sx CI G top jo 7" 26# J-55 Surf. 3543' Surf. 3543' 8.5" 660 sx Class G, 175 sx AS I 5.5" 15.5# L-80 3372' 7710' 3372' 6227' 7" 70 sx 11.5 ppg Class G, 8o sx 15.8 ppg Class G 3.5" 9.2# L-80 7519' 8218' 6072' 6645' 4.75" 16 bbls 15.8 ppg Class G 23. Open to production or injection? Yes ^ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 7536' 7519' 7925'-7945' MD 6404'-6420' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7925'-7945' MD 195133# carbolite with 195046# behind pipe 26. PRODUCTION TEST Date First Production December 9, 2007 Method of Operation (Flowing, gas lift, etc.) gas lift oil producer Date of Test 12/9/2007 Hours Tested 7-3/4 hours Production for Test Period --> OIL-BBL 55 GAS-MCF 25 WATER-BBL 248 CHOKE SIZE 10 Bean GAS-OIL RATIO 542 Flow Tubing press. 1100 p Casing Pressure 1235 Calculated 24-Hour Rate -> OIL-BBL 158 GAS-MCF 86 WATER-BBL 763 OIL GRAVITY -API (corr) 20.9 deg. 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 analytigl results per 20 AAC 25.071. g}~~p~ryq f~~e A/~7iY~l ly"LT{T.3 VI~N~ itA1f" y ~~~ NONE ~`" °" 9tE , tea? Form 10-407 Revised 212007 CONTINUED ON REVERSE SIDE ~ /jam ~~.oT ,,,~ ~y/3~~ (; r~ 28. GEOLOGIC MARKERS (List all formations and mark encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1720' 1720' needed, and submit detailed test information per 20 AAC 25.071. Top of A-3 interval 7884' 6371' Top of A-2 interval 7914' 6395' Top of A-1 interval 7958' 6431' N/A 3N-14A PB1 TD 7768' 6232' Formation at total depth: Kuparuk A3 sand 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed N d Thomas Title: Drillino Team Leader s ~ ~'( (f /d 2 ~`~ Signature ~,r~M ( Phone ~ ~ S 6~~.~ Date C INSTRUCTIONS Sharon Allsup-Dreke 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 Ct~np~+~i~~tillip~ A-~a~~r~, 1ne. ~~ 3N-14A API: 500292158901 Wel TUBING SSSV Type: TRDP (a753s, OD:3.500, ID:2ss2) I Annular Fluid: La; ~® 'RODUC710N (0.7440, OD:7.000, wt:zs.oo> Last - - - - An le TS: 34 deg C~ 7777 !007 Angle @ TD: 33 deg @ 8220 Rev Reason: UPDATE SURFACE CSG 65 Interval TVD Zone Status Ft SPF Date Type Comment 7925- 7945 t 6404-6420 i A-2 I i 20 i 6 1 11/8/2007 i IPERF i 2. _ -- 5" HJ. 60 deg phase _- - - Stimulations & Treatments _ Interva! Date T e Comment 7925- 7945_ _ -11/10/2007 FRAC _- A2 SAN - D FRAC, 195,046# -- . INTO A2 SAND PERFORATIONS_ Gas Lift Mand relsNatves _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 2342 2342 CAMCO KBG2-9 GLV 1.0 BTM 0.125 1240 11!22/200 2 3707 3706 CAMCO KBG2-9 GLV 1.0 BTM 0.188 1310 11/22/200 3 4981 4787 CAMCO KBG2-9 OV 1.0 BTM 0.250 0 1/22/200 4 6408 5440 CAMCO KBG2-9 DMY 1.0 BTM 0.000 0 0/30/200 5 7397 5978 CAMCO KBG2-9 DMY 1 0 BTM 0.000 0 11/6/2007 Other (plugs, equip., etc.) -COMPLETION De th TVD T e Descri tion - fD 22 22 HANGER FMC GEN IV TBG HANGER 2.992 2013 2013 SSSV CAMCO TRMAXX-5E SSSV 2.812 7447 6016 NIP CAMCO'D' NIPPLEw/2.75" PROFILE 2.750 7536 Other ( De th 6085 plugs, TVD SEAL equip., etc T e BULLET SEAL ASSEMBLY -TIE BACK _ _ .) -LINER DETAIL _ Descn ion 2.980 ID 3372 3372 PACKER 5.5" LINER'CHP' LINER TOP PACKER C-2 PROFILE 5.500 3383 3383 HANGER 5.5" HMC LINER HANGER 4.960 7519 6072 PACKER 3.5" ZXP LINER TOP PACKER 4.480 7545 6093 HANGER 3.5" HMC LINER HANGER 2.910 8217 Gener Date. 6644 SHOE 3.5" WEATHERFORD 303 FLOAT SHOE 0.000 -_ - --_ al Notes .Note - - 11l2/2007 NOTE: WELL SIDETRACKED 3543' 1/21/200 NOTE: CHINA CAP FROM 1"DMY LOST IN WELL 11/21/2007 FRAC (7925-7945) Perf (7925-7945) LINER (7519-8218, OD:3.500, Wt:9.20) KRU 3N-14A SHOE (8217-8218, OD:3.500) Tubing String -TUBING _ --- Size I Top ~ Bottom TVD i Wt Grade Thread _ _ r 3.500 ~ 0 7536 6085 9.30 L-20 IBTM _ - - - Perforations Summary Halliburton Company Survey Report __ __ Company: ConocoPhillips Alaska Inc. Date: 11/12/2007 Time: 14:47:11 P:,~~c: 1 Field: Kupatuk River Unit Co -ordinate(~h:) Reference: Well: 3N-14. Tr ue North Site: Kuparuk 3N Pad Ve rtical iT~'ll) Re (crcncr. 3N-14A :62.0 ~~ell: 3N-14 Section I ~~Sl Refer ence: Well (0 ODN.O.O OF_,105.78Azi) ~~cllpath: 3N-idA tiu rveyC:+kulatim i )tcrhod: Minimum Curva ture Db: C~racte Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 ~ Geo Datum: NAD27 (Clarke 1866) Map Zoue: Coordinate Sy Alaska, Zone 4 stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 3N-14 Slot Name: Well Position: +N/-S -0.74 ft Northing: 6013799.33 ft Latitude: 70 26 55.949 N +E/-W 374.76 ft Easti ng : 518320.91 ft Longitude: 149 51 1.933 W Position Uncertainty: 0.00 ft Wellpath: 3N-14A Drilled From: 3N-14APB1 500292158901 ~ Tie-on Depth: 3981.31 ft Current Datum: 3N-14A : Height 62.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/25/2007 Declination: 23.07 deg Field Strength: 57620 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 105.78 Survey Program for Definitive Wellpath Date: 11/12/2007 Validated: No Version: 12 Actual From To Survey Toolcode Tool Name ft ft 94.00 3494.00 3N-14 (94.00-7454.00) (0) G CT-MS Schlumberger GCT multishot 3543.00 3981.31 3N-14AP81 (3543.00-7768.00) (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4032.00 8220.00 3N-14A (4032.00-8220.00) MWD+IFR-AK-CAZ-LC MWD+IFR AK CAZ LC Sperry Survey ___ MD incl Azim 1~'I) 5vs'll'D V!S E/W Map1 MapF: Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -34.00 0.00 0.00 6013799.33 ~ 518320.91 -TIE LINE ~ 94.00 0.15 146.70 94.00 32.00 -0.07 0.05 6013799.26 518320.96 GCT-MS 194.00 0.17 148.77 194.00 132.00 -0.31 0.20 6013799.02 518321.11 GCT-MS 294.00 0.20 160.33 294.00 232.00 -0.60 0.33 6013798.73 518321.24 GCT-MS j 394.00 0.20 116.43 394.00 332.00 -0.84 0.55 6013798.49 518321.46 GCT-MS I 494.00 0.22 99.48 494.00 432.00 -0.95 0.89 6013798.38 518321.80 GCT-MS 594:00 0.28 104.45 594.00 532.00 -1.04 1.32 6013798.29 518322.23 GCT-MS j 694.00 0.37 120.77 694.00 632.00 -1.27 1.83 6013798.06 518322.75 GCT-MS 794.00 0.52 141.23 793.99 731.99 -1.79 2.39 6013797.55 518323.31 GCT-MS 894.00 0.50 151.32 893.99 831.99 -2.53 2.89 6013796.81 518323.80 GCT-MS 994.00 0.32 167.92 993.99 931.99 -3.18 3.16 6013796.16 518324.07 GCT-MS 1094.00 0.25 182.45 1093.98 1031.98 -3.67 3.20 6013795.67 518324.12 GCT-MS 1194.00 0.17 181.47 1193.98 1131.98 -4.04 3.19 6013795.30 518324.11 GCT-MS 1294.00 0.12 184.38 1293.98 1231.98 -4.29 3.18 6013795.05 518324.10 GCT-MS 1394.00 0.12 195.50 1393.98 1331.98 -4.50 3.14 6013794.84 518324.06 GCT-MS 1494.00 0.18 234.55 1493.98 1431.98 -4.69 2.99 6013794.65 518323.91 GCT-MS 1594.00 0.30 260.58 1593.98 1531.98 -4.82 2.60 6013794.51 518323.52 GCT-MS 1694.00 0.30 273.67 1693.98 1631.98 -4.85 2.08 6013794.49 518323.00 GCT-MS 1794.00 0.43 331.30 1793.98 1731.98 -4.50 1.64 6013794.83 518322.56 GCT-MS 1894.00 0.80 350.05 1893.97 1831.97 -3.49 1.34 6013795.85 518322.26 GCT-MS 1994.00 0.90 354.15 1993.96 1931.96 -2.02 1.14 6013797.32 518322.05 GCT-MS 2094.00 0.80 351.10 2093.95 2031.95 -0.55 0.95 6013798.79 518321.86 GCT-MS 2194.00 0.80 7.02 2193.94 2131.94 0.84 0.93 6013800.17 518321.84 GCT-MS 2294.00 0.88 34.45 2293.93 2231.93 2.16 1.45 6013801.50 518322.35 GCT-MS 2394.00 0.80 51.82 2393.92 2331.92 3.23 2.43 6013802.56 518323.33 GCT-MS 2494.00 1.18 58.42 2493.91 2431.91 4.20 3.86 6013803.54 518324.76 GCT-MS 2594.00 1.05 62.22 2593.89 2531.89 5.16 5.55 6013804.51 518326.44 GCT-MS 2694.00 0.85 67.98 2693.87 2631.87 5.87 7.04 6013805.22 518327.94 GCT-MS Halliburton Company Survey Report Compan} : CcnocoPhillips Alaska Inc. llate: 11/12/2007 lime: 14:47:11 Pa~c 2 I~icld: Kupatuk Rivet' Uni t Cu-or dinate(NE} 12cfcrcncc: Well: 3N-14 , T rue North Sitc: KupatUk 3N Pad ~cr~ical (TV D) Refcrcncc 3N-14A 62.0 ~~'ell: 3N-14 ticctio n (tS ) Reference: Well (O.OON.O. OOE105.78Azi) ~~ellpath: 3N- 14A __ __ _ Sunc y Calc ulati on Vethod: Minimum C urv ature I)b: Oracle Survey biD Intl Azim TVl) Sr, l P ll V~ti E!~1 ti1apN ~lapE Tooi ft deg deg ft ft ft ft ft ft 2794. 00 0.83 70 .22 2793 .86 2731. 86 6 .39 8. 41 6013805. 74 518329. 31 GCT-MS 2894. 00 0.83 66 .97 2893 .85 2831. 85 6 .92 9. 76 6013806. 27 518330. 65 GCT-MS 2994. 00 0.77 66 .08 2993 .84 2931 .84 7 .48 11. 04 6013806. 83 518331. 93 GCT-MS 3094. 00 0.68 66 .22 3093 .83 3031 .83 7 .99 12 .20 6013807. 35 518333. 09 GCT-MS 3194. 00 0.58 67 .62 3193 .83 3131 .83 8 .42 13. 21 6013807. 78 518334. 10 GCT-MS 3294. 00 0.38 76 .02 3293 .82 3231 .82 8 .69 14 .00 6013808. 06 518334. 89 GCT-MS 3394. 00 0.52 68 .65 3393 .82 3331 .82 8 .94 14 .74 6013808. 30 518335. 63 GCT-MS 3494. 00 0.52 68 .30 3493 .82 3431 .82 9 .27 15 .59 6013808. 64 518336. 47 GCT-MS 3543. 00 2.01 72 .36 3542 .80 3480 .80 9 .61 16 .61 6013808. 98 518337. 50 MWD+IFR-AK-CAZ-SC 3607. 52 4.15 75 .58 3607 .23 3545 .23 10 .54 19 .95 6013809. 92 518340. 84 MWD+IFR-AK-CAZ-SC 3671. 71 6.71 77 .18 3671 .12 3609 .12 11 .95 25 .86 6013811. 34 518346. 74 MWD+IFR-AK-CAZ-SC 3731. 06 9.60 79 .50 3729 .87 3667 .87 13 .62 34 .11 6013813. 03 518354. 98 MWD+-FR-AK-CAZ-SC 3795. 23 11.43 75 .62 3792 .96 3730 .96 16 .18 45 .53 6013815. 62 518366. 40 MWD+IFR-AK-CAZ-SC 3887. 07 14.05 77 .28 3882 .53 3820. 53 20 .89 65. 22 6013820. 38 518386. 08 MWD+IFR-AK-CAZ-SC 3981. 31 17.65 83 .77 3973 .18 3911 .18 24 .96 90 .59 6013824. 51 518411. 43 MWD+IFR-AK-CAZ-SC 4032. 00 19.97 87 .26 4021 .16 3959 .16 26 .21 106. 88 6013825. 80 518427. 72 MWD+IFR-AK-CAZ-LC 4067. 78 18.66 93 .56 4054 .93 3992 .93 26 .15 118 .70 6013825. 77 518439. 53 MWD+IFR-AK-CAZ-LC 4164. 70 22.91 102 .49 4145 .54 4083 .54 21 .10 152 .62 6013820. 80 518473. 46 MWD+IFR-AK-CAZ-LC 4258. 35 25.85 102 .81 4230 .83 4168 .83 12 .63 190 .33 6013812. 43 518511. 19 MWD+IFR-AK-CAZ-LC i 4353. 83 30.66 102 .13 4314 .91 4252 .91 2 .89 234 .46 6013802. 80 518555. 33 MWD+IFR-AK-CAZ-LC 4446. 76 33.71 106 .34 4393 .56 4331 .56 -9 .35 282 .38 6013790. 68 518603. 29 MWD+IFR-AK-CAZ-LC 4540. 51 36.78 104 .87 4470 .12 4408 .12 -23 .87 334 .49 6013776. 28 518655. 42 MWD+IFR-AK-CAZ-LC 4635. 00 38.81 104 .16 4544 .78 4482 .78 -38 .38 390 .55 6013761. 92 518711. 51 MWD+IFR-AK-CAZ-LC 4728. 50 42.29 108 .78 4615 .83 4553 .83 -55 .68 448 .77 6013744. 76 518769. 77 MWD+IFR-AK-CAZ-LC 4823. 12 45.62 109 .80 4683 .94 4621 .94 -77 .39 510 .74 6013723. 21 518831. 79 MWD+IFR-AK-CAZ-LC 4915. 51 49.54 111 .33 4746 .25 4684 .25 -101 .37 574 .57 6013699. 39 518895. 67 MWD+IFR-AK-CAZ-LC 5009. 00 53.35 112 .71 4804 .51 4742 .51 -128 .79 642 .33 6013672. 13 518963. 49 MWD+IFR-AK-CAZ-LC 5103. 62 57.28 113 .16 4858 .35 4796 .35 -159 .11 713 .96 6013641. 99 519035. 19 MWD+IFR-AK-CAZ-LC 5197. 00 61.35 111 .27 4905 .99 4843 .99 -189 .44 788 .30 6013611. 85 519109. 59 MWD+IFR-AK-CAZ-LC 5292. 54 64.02 111 .20 4949 .83 4887 .83 -220 .18 867 .41 6013581. 30 519188. 78 MWD+IFR-AK-CAZ-LC 5384. 29 65.38 110 .99 4989 .04 4927 .04 -250 .04 944 .80 6013551. 64 519266. 23 MWD+IFR-AK-CAZ-LC 5478. 66 64.46 108 .67 5029 .05 4967 .05 -279 .04 1025 .20 6013522. 84 519346. 69 ~ MWD+IFR-AK-CAZ-LC 5573. 29 63.92 108 .99 5070 .25 5008 .25 -306 .53 1105 .83 6013495. 55 519427. 38 MWD+IFR-AK-CAZ-LC 5665. 44 64.27 108 .15 5110 .51 5048 .51 -332 .93 1184 .40 6013469. 35 519506. 01 MWD+IFR-AK-CAZ-LC j 5759. 80 63.26 107 .92 5152 .22 5090 .22 -359 .13 1264 .88 6013443. 34 519586. 54 MWD+IFR-AK-CAZ-LC 5853. 03 64.13 106 .87 5193 .53 5131 .53 -384 .11 1344 .63 6013418. 56 519666. 35 MWD+IFR-AK-CAZ-LC ~ 5947. 24 63.36 107 .71 5235 .21 5173 .21 -409 .22 1425 .31 6013393. 65 519747. 07 MWD+IFR-AK-CAZ-LC 6041. 00 62.92 108 .17 5277 .57 5215 .57 -434 .99 1504 .88 6013368. 09 519826. 71 MWD+IFR-AK-CAZ-LC 6134. 76 63.81 107 .27 5319 .60 5257 .60 -460 .49 1584 .72 6013342. 78 519906. 59 MWD+IFR-AK-CAZ-LC 6227. 50 63.45 108 .40 5360 .80 5298 .80 -485 .94 1663 .81 6013317. 53 519985. 74 MWD+IFR-AK-CAZ-LC 6319. 86 64.43 106 .26 5401 .37 5339 .37 -510 .64 1743 .01 6013293. 02 520065. 00 MWD+IFR-AK-CAZ-LC 6413. 25 63.39 107 .50 5442 .45 5380 .45 -534 .99 1823 .27 6013268. 87 520145. 31 MWD+IFR-AK-CAZ-LC 6506. 61 64.50 106 .48 5483 .45 5421 .45 -559 .50 1903 .48 6013244. 57 520225. 57 MWD+IFR-AK-CAZ-LC 6600. 57 63.00 106 .80 5525 .01 5463 .01 -583 .63 1984 .22 6013220. 64 520306. 36 MWD+IFR-AK-CAZ-LC 6695. 16 62.73 106 .98 5568 .15 5506 .15 -608 .08 2064 .76 6013196. 38 520386. 96 MWD+IFR-AK-CAZ-LC i 6789. 50 63.02 105 .91 5611 .17 5549 .17 -631 .85 2145 .29 6013172. 82 520467. 53 MWD+IFR-AK-CAZ-LC I 6882. 58 61.10 107 .38 5654 .78 5592 .78 -655 .40 2224 .07 6013149. 47 520546. 37 MWD+IFR-AK-CAZ-LC I 6976. 02 55.81 106 .91 5703 .65 5641 .65 -678 .87 2300 .14 6013126. 18 520622. 48 MWD+IFR-AK-CAZ-LC 7070. 83 53.14 107 .12 5758 .73 5696 .73 -701 .45 2373 .91 6013103. 79 520696. 31 MWD+IFR-AK-CAZ-LC 7164. 89 50.65 103 .99 5816 .78 5754 .78 -721 .32 2445 .19 6013084. 09 520767. 62 MWD+IFR-AK-CAZ-LC 7258. 89 46.93 104 .59 5878 .70 5816 .70 -738 .76 2513 .71 6013066. 82 520836. 17 MWD+IFR-AK-CAZ-LC 7352. 00 43.48 101 .43 5944 .30 5882 .30 -753 .68 2578 .04 6013052. 06 520900. 54 MWD+IFR-AK-CAZ-LC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 11/12/2007 Tin,c 14:47:11 P:,;,~c: 3 Field: Ku parF~k Fiver Unit ('u-ordinate(\ E:) Rcfcre~ce: Well: 3N-14. Tn ie North - Sitc Ku parak <3N Pad Vci~tical (TVll) Reference: 3N-14A :620 ~1'cll: 3N -14 5ccfio n (VS) Keferenm: Well (0-OON.D.O OE,105.78Azi) ~lelipalh: 3N-1~3A tiuwey Cakcdati on Method: Minimum Curva ture - Ilh: Oracle Survey MD Incl Azim TVl) S}, l VD N/S E/W Map~~ ~tapT? "Cool ft deg deg ft ft ft ft ft ft 7445.00 39.42 101.05 6013.99 5951.99 -765.69 2638.41 6013040.20 520960.93 MWD+IFR-AK-CAZ-LC 7538.40 37.09 101.96 6087.33 6025.33 -777.21 2695.08 6013028.82 521017.62 MWD+IFR-AK-CAZ-LC 7632.09 34.97 104.43 6163.10 6101.10 -789.76 2748.73 6013016.41 521071.30 MWD+IFR-AK-CAZ-LC 7678.20 33.84 104.75 6201.14 6139.14 -796.32 2773.94 6013009.91 521096.52 MWD+IFR-AK-CAZ-LC 7744.32 34.23 103.68 6255.94 6193.94 -805.41 2809.81 6013000.91 521132.41 MWD+IFR-AK-CAZ-LC 7781.64 33.96 103.88 6286.84 6224.84 -810.39 2830.13 6012995.98 521152.74 MWD+IFR-AK-CAZ-LC 7845.60 35.72 104.04 6339.33 6277.33 -819.20 2865.59 6012987.25 521188.22 MWD+IFR-AK-CAZ-LC 7875.74 35.56 104.04 6363.83 6301.83 -823.46 2882.63 6012983.04 521205.27 MWD+IFR-AK-CAZ-LC 7970.00 35.61 102.94 6440.49 6378.49 -836.26 2935.96 6012970.37 521258.63 MWD+IFR-AK-CAZ-LC 8063.61 35.19 103.27 6516.79 6454.79 -848.55 2988.78 6012958.21 521311.47 MWD+IFR-AK-CAZ-LC 8157.24 33.43 103.75 6594.13 6532.13 -860.88 3040.09 6012946.01 521362.81 MWD+IFR-AK-CAZ-LC 8183.55 32.83 102.67 6616.16 6554.16 -864.16 3054.09 6012942.76 521376.81 MWD+IFR-AK-CAZ-LC y 8220.00 32.83 102.67 6646.79 ~ 6584.79 -868.50 3073.37 6012938.47 ~ 521396.10 • MWD+IFR-AK-CAZ-LC Halliburton Company Survey Report Cumpanc: ConocaPhillips Alaska lnc. Uatc: 1 1 /1 2120 07 Time: 14:25:29 Pn~e: Field: Kuparuk River Unlt ('o -ordinate(NE)Refercncc Well: 3N-14, Tru e North Site Kuparuk 3N Pad ~e rtical{'FE'D} Re tereacc 3N-14A: 52.0 ~VeIL 3N-14 Section I~~S) ReCer encc Well (0-OON.O.OOE,105.75Azi) 1~~cllp:ith: 3N-14APB1 Survey Cakuiation Method: Minimum Curva ture I)h: Orade ~ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 3N-14 I Slot Name: i Well Position: +N/-S -0.74 ft Northing: 6013799.33 ft Latitude: 70 26 55.949 N ~ +E/-W 374.76 ft Easti ng : 518320.91 ft Longitude: 149 51 1.933 W Position Uncertainty: 0.00 ft Wellpath: 3N-14AP61 Drilled From: 3N-14 500292158970 Tie-on Depth: 3494.00 ft Current Datum: 3N-14A: Height 62.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/25/2007 Declination: 23.07 deg Field Strength: 57620 nT Mag Dip Angl e: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 105.75 Survey Program for Definitive Wellpath Date: 11/12/2007 Validated: No Version: 7 Actual From To Survey Toolcode Tool Name ft ft 94.00 3494.00 3N-14 (94 .00-7454.00) (0) GCT-MS Schlumberger GCT multishot 3543.00 7768.00 3N-14AP61 (3543.00-7768.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl Azim TVII Stis'Il"f) V!S F:,'11 )l:~p~~ )la~ik: fool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -34.00 0.00 0.00 6013799.33 518320.91 TIE LINE ~ 94.00 0.15 146.70 94.00 32.00 -0.07 0.05 6013799.26 518320.96 GCT-MS 194.00 0.17 148.77 194.00 132.00 -0.31 0.20 6013799.02 518321.11 GCT-MS 294.00 0.20 160.33 294.00 232.00 -0.60 0.33 6013798.73 518321.24 GCT-MS 394.00 0.20 116.43 394.00 332.00 -0.84 0.55 6013798.49 518321.46 GCT-MS 494.00 0.22 99.48 494.00 432.00 -0.95 0.89 6013798.38 518321.80 GCT-MS 594.00 0.28 104.45 594.00 532.00 -1.04 1.32 6013798.29 518322.23 GCT-MS 694.00 0.37 120.77 694.00 632.00 -1.27 1.83 6013798.06 518322.75 GCT-MS 794.00 0.52 141.23 793.99 731.99 -1.79 2.39 6013797.55 518323.31 GCT-MS 894.00 0.50 151.32 893.99 831.99 -2.53 2.89 6013796.81 518323.80 GCT-MS 994.00 0.32 167.92 993.99 931.99 -3.18 3.16 6013796.16 518324.07 GCT-MS 1094.00 0.25 182.45 1093.98 1031.98 -3.67 3.20 6013795.67 518324.12 GCT-MS 1194.00 0.17 181.47 1193.98 1131.98 -4.04 3.19 6013795.30 518324.11 GCT-MS 1294.00 0.12 184.38 1293.98 1231.98 -4.29 3.18 6013795.05 518324.10 GCT-MS 1394.00 0.12 195.50 1393.98 1331.98 -4.50 3.14 6013794.84 518324.06 GCT-MS 1494.00 0.18 234.55 1493.98 1431.98 -4.69 2.99 6013794.65 518323.91 GCT-MS 1594.00 0.30 260.58 1593.98 1531.98 -4.82 2.60 6013794.51 518323.52 GCT-MS 1694.00 0.30 273.67 1693.98 1631.98 -4.85 2.08 6013794.49 518323.00 GCT-MS 1794.00 0.43 331.30 1793.98 1731.98 -4.50 1.64 6013794.83 518322.56 GCT-MS 1894.00 0.80 350.05 1893.97 1831.97 -3.49 1.34 6013795.85 518322.26 GCT-MS 1994.00 0.90 354.15 1993.96 1931.96 -2.02 1.14 6013797.32 518322.05 GCT-MS 2094.00 0.80 351.10 2093.95 2031.95 -0.55 0.95 6013798.79 518321.86 GCT-MS 2194.00 0.80 7.02 2193.94 2131.94 0.84 0.93 6013800.17 518321.84 GCT-MS 2294.00 0.88 34.45 2293.93 2231.93 2.16 1.45 6013801.50 518322.35 GCT-MS 2394.00 0.80 51.82 2393.92 2331.92 3.23 2.43 6013802.56 518323.33 GCT-MS 2494.00 1.18 58.42 2493.91 2431.91 4.20 3.86 6013803.54 518324.76 GCT-MS 2594.00 1.05 62.22 2593.89 2531.89 5.16 5.55 6013804.51 518326.44 GCT-MS 2694.00 0.85 67.98 2693.87 2631.87 5.87 7.04 6013805.22 518327.94 GCT-MS 2794.00 0.83 70.22 2793.86 2731.86 6.39 8.41 6013805.74 518329.31 GCT-MS Halliburton Company Survey Report Company Field: ~ih: ~~ell: ~~ellpath: tiurcr~ ~~il) ft : ConocoPhillips Alaska Inc Kuparuk River Unit Kuparuk 3N Pad 3N-14 3N-14APB1 Incl ~cim 7'~D deg deg ft s'f~'D ft S ft 1)atr. 1 111 21200 7 Co-nrdinale(~E) Reference: Vertical (Il'U) Reference tiection t ~~ti) Reference: tiurccy Calculation Method: F.'~~' ~IapA ft ft Time_ 14:2529 f'a;;c: 2 Well: 3N-14, True NOrth 3N-14A: 62.0 Well (O.OON,O.OOE,105.75Az1) Minimum Curvature Db: Oracle __ MapE Cool ft 2894. 00 0. 83 66 .97 2893. 85 2831 .85 6. 92 9 .76 6013806. 27 518330. 65 GCT-MS 2994. 00 0. 77 66 .08 2993. 84 2931 .84 7. 48 11 .04 6013806. 83 518331. 93 GCT-MS 3094. 00 0. 68 66 .22 3093. 83 3031 .83 7. 99 12 .20 6013807. 35 518333. 09 GCT-MS 3194. 00 0. 58 67 .62 3193. 83 3131 .83 8. 42 13 .21 6013807. 78 518334. 10 GCT-MS 3294. 00 0. 38 76 .02 3293. 82 3231 .82 8. 69 14 .00 6013808. 06 518334. 89 GCT-MS 3394. 00 0. 52 68 .65 3393. 82 3331 .82 8. 94 14 .74 6013808. 30 518335. 63 GCT-MS 3494. 00 0. 52 68 .30 3493. 82 3431 .82 9. 27 15 .59 6013808. 64 518336. 47 GCT-MS 3543. 00 2. 01 72 .36 3542. 80 3480 .80 9. 61 16 .61 6013808. 98 518337. 50 MWD+IFR-AK-CAZ-SC 3607. 52 4. 15 75 .58 3607. 23 3545 .23 10. 54 19 .95 6013809. 92 518340. 84 MWD+IFR-AK-CAZ-SC 3671. 71 6. 71 77 .18 3671. 12 3609 .12 11. 95 25 .86 6013811. 34 518346. 74 MWD+IFR-AK-CAZ-SC 3731. 06 9. 60 79 .50 3729. 87 3667 .87 13. 62 34 .11 6013813. 03 518354. 98 MWD+IFR-AK-CAZ-SC 3795. 23 11. 43 75 .62 3792. 96 3730 .96 16. 18 45 .53 6013815. 62 518366. 40 MWD+IFR-AK-CAZ-SC 3887. 07 14. 05 77 .28 3882. 53 3820 .53 20. 89 65 .22 6013820. 38 518386. 08 MWD+IFR-AK-CAZ-SC 3981. 31 17. 65 83 .77 3973. 18 3911 .18 24. 96 90 .59 6013824. 51 518411. 43 MWD+IFR-AK-CAZ-SC 4074. 26 21. 95 89 .62 4060. 62 3998 .62 26. 61 121 .99 6013826. 23 518442. 82 MWD+IFR-AK-CAZ-SC 4170. 84 27. 13 94 .91 4148. 46 4086 .46 24. 84 162 .01 6013824. 57 518482. 85 MWD+IFR-AK-CAZ-SC 4263. 92 32. 72 97 .45 4229. 10 4167 .10 19. 76 208 .14 6013819. 60 518528. 98 MWD+IFR-AK-CAZ-SC 4358. 38 35. 33 97 .38 4307. 38 4245 .38 12. 94 260 .55 6013812. 91 518581. 40 MWD+IFR-AK-CAZ-SC 4451. 70 37. 90 98 .39 4382. 28 4320 .28 5. 29 315 .68 6013805. 39 518636. 54 MWD+IFR-AK-CAZ-SC 4545. 77 41. 24 100 .58 4454. 79 4392 .79 -4. 62 374 .76 6013795. 63 518695. 64 MWD+IFR-AK-CAZ-SC 4638. 00 46. 24 102 .58 4521. 40 4459 .40 -17. 47 437 .19 6013782. 94 518758. 10 MWD+IFR-AK-CAZ-SC 4731. 87 49. 71 104 .70 4584. 24 4522 .24 -33. 94 504 .93 6013766. 63 518825. 87 MWD+IFR-AK-CAZ-SC 4825. 26 54. 84 106 .76 4641. 37 4579 .37 -54. 00 575 .99 6013746. 75 518896. 97 MWD+IFR-AK-CAZ-SC 4918. 73 59. 65 108 .63 4691. 93 4629 .93 -77. 92 650 .84 6013723. 02 518971. 87 MWD+IFR-AK-CAZ-SC 5013. 23 63. 25 108 .88 4737. 08 4675 .08 -104. 61 729 .43 6013696. 53 519050. 52 MWD+IFR-AK-CAZ-SC 5106. 97 64. 43 108 .49 4778. 41 4716 .41 -131. 56 809 .13 6013669. 77 519130. 28 MWD+IFR-AK-CAZ-SC 5200. 56 63. 62 108 .07 4819. 40 4757 .40 -157. 95 889 .02 6013643. 58 519210. 22 MWD+IFR-AK-CAZ-SC 5295. 45 62. 65 107 .68 4862. 28 4800 .28 -183. 93 969 .58 6013617. 80 519290. 84 MWD+IFR-AK-CAZ-SC 5388. 76 63. 89 107 .03 4904. 25 4842 .25 -208. 79 1049 .12 6013593. 14 519370. 44 MWD+IFR-AK-CAZ-SC 5482. 67 62. 51 108 .13 4946. 59 4884 .59 -234. 10 1129 .03 6013568. 03 519450. 40 MWD+(FR-AK-CAZ-SC 5576. 50 63. 33 108 .20 4989. 31 4927 .31 -260. 15 1208 .41 6013542. 18 519529. 83 MWD+IFR-AK-CAZ-SC 5670. 66 62. 37 109 .62 5032. 27 4970 .27 -287. 30 1287 .67 6013515. 23 519609. 15 MWD+IFR-AK-CAZ-SC 5763. 77 62. 57 111 .72 5075. 32 5013 .32 -316. 44 1364 .91 6013486. 28 519686. 46 MWD+IFR-AK-CAZ-SC 5857. 83 62. 71 112 .07 5118. 54 5056 .54 -347. 59 1442 .42 6013455. 32 519764. 04 MWD+IFR-AK-CAZ-SC ~ j 5947. 61 63. 04 110 .47 5159. 48 5097 .48 -376. 57 1516 .88 6013426. 52 519838. 56 MWD+IFR-AK-CAZ-SC j 6041. 91 63. 27 111 .73 5202. 06 5140 .06 -406. 86 1595 .38 6013396. 43 519917. 12 MWD+IFR-AK-CAZ-SC 6136. 12 62. 92 110 .66 5244. 70 5182 .70 -437. 24 1673 .70 6013366. 25 519995. 52 MWD+IFR-AK-CAZ-SC 6230. 45 63. 44 109 .77 5287. 26 5225 .26 -466. 33 1752 .70 6013337. 36 520074. 58 MWD+IFR-AK-CAZ-SC 6324. 37 63. 34 109 .91 5329. 33 5267 .33 -494. 83 1831 .69 6013309. 06 520153. 63 MWD+IFR-AK-CAZ-SC 6418. 15 63. 25 108 .96 5371. 47 5309 .47 -522. 70 1910 .69 6013281. 38 520232. 69 MWD+IFR-AK-CAZ-SC 6510. 70 62. 98 107 .41 5413. 32 5351 .32 -548. 46 1989 .11 6013255. 81 520311. 16 MWD+IFR-AK-CAZ-SC 6605. 34 62. 63 108 .21 5456. 58 5394 .58 -574. 21 2069 .25 6013230. 27 520391. 36 MWD+IFR-AK-CAZ-SC 6699. 37 61. 64 107 .85 5500. 53 5438 .53 -599. 94 2148 .30 6013204. 73 520470. 46 MWD+IFR-AK-CAZ-SC 6793. 49 58. 50 105 .41 5547. 49 5485 .49 -623. 30 2226 .43 6013181. 56 520548. 64 MWD+IFR-AK-CAZ-SC 6881. 49 57. 46 106 .65 5594. 14 5532 .14 -643. 90 2298 .14 6013161. 14 520620. 39 MWD+IFR-AK-CAZ-SC 6976. 48 53. 61 106 .44 5647. 89 5585 .89 -666. 20 2373 .19 6013139. 03 520695. 50 MWD+IFR-AK-CAZ-SC 7070. 76 53. 58 105 .76 5703. 84 5641 .84 -687. 24 2446 .10 6013118. 17 520768. 45 MWD+IFR-AK-CAZ-SC 7165. 07 51. 02 104 .49 5761. 51 5699 .51 -706. 73 2518 .12 6013098. 87 520840. 51 MWD+IFR-AK-CAZ-SC 7257. 13 49. 34 106 .50 5820. 47 5758 .47 -725. 60 2586 .25 6013080. 16 520908. 68 MWD+IFR-AK-CAZ-SC 7350. 29 44. 02 106 .28 5884. 36 5822 .36 -744. 72 2651 .25 6013061. 20 520973. 72 MWD+IFR-AK-CAZ-SC ~ i 7442. 96 38. 13 105 .74 5954. 19 5892 .19 -761. 52 2709 .75 6013044. 54 521032. 25 MWD+IFR-AK-CAZ-SC 7537. 81 32. 29 105 .01 6031. 65 5969 .65 -776. 04 2762 .45 6013030. 16 521084. 98 i MWD+IFR-AK-CAZ-SC '; --- - - Halliburton Company Survey Report Cumpanc: ConocoPhilli¢s Alaska Inc. Uatc 11112!2007 Time: '14:25:29 Page; 3 field: Kuparuk River Unit (b-ordin:~tc((YE)krScrencc: Well: 3N-14, True North tiitc: Kuparuk 3N Pad ~'crtical(7~D)Rcfcrcncc: 3N-14A:62.0 ~1cIL• 3N-74 Sectiun LVS) Refereucc Well (0-OON.O-OOE,105.75Azi) Wetlpath: 3N-14APB1 5une~ C;akutation tite[hod: Mintrttum Curvature Ub; Oracle S ll r\ C~ ~iD fncl ~zim Ill) tip,"f~D \iti F.!w ~1apV 11tipF. fuol ft deg deg ft ft ft ft ft ft 7631.81 28.83 107.99 6112.59 6050.59 -789.55 2808.27 6013016.76 521130.83 MWD+IFR-AK-CAZ-SC 7725.78 28.40 107.90 6195.08 6133.08 -803.42 2851.09 6013003.01 521173.68 MWD+IFR-AK-CAZ-SC 7768.00 28.40 107.90 6232.22 6170.22 -809.59 2870.20 6012996.88 521192.80 MWD+IFR-AK-CAZ-SC Ca-nocoPhitlis Time Log Summary Wellv~ew Web Reporting - -- Well Name: 3N-14 Job Type: DRILLING SIDETRACK - - ---, Time Logs I ---- -- - Date From To D r S De th E. De th Phase Code Subcode T COM 09/29/2007 00:00 02:00 2.00 0 0 MIRU MOVE RURD P _ _ Blow down all lines -Prep modules for move. 02:00 03:30 1.50 0 0 MIRU MOVE RURD P Pull all enter connects -Prep to se erate modules 03:30 06:00 2.50 0 0 MIRU MOVE RURD P Pull back V-Door chute -Jack up - Pull out and Stag the pipe shed halfs on East side of ad. 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Jack up -Pull Out and stage on East side of pad, Boiler, Engine, Pump and Pit modules. 09:00 13:00 4.00 0 0 MIRU MOVE MOB P Notify Security and Mob 4 utility modules off 2Z pad moving to 3N pad . Reture Sows to 2Z pad. ""`NOTE"'* 10.75 mile Move 13:00 14:00 1.00 0 0 MIRU MOVE RURD P Pull sub off 2Z-01A -Prep for road - 14:00 17:00 3.00 0 0 MIRU MOVE MOB P Notify Security -Move off 2Z pad to 3N pad with sub base, 2 truck Toads e ui ment and both halfs of i e shed. 17:00 21:00 4.00 0 0 MIRU MOVE RURD P Set malts -Spot sub over 3N-14 & set 4 utility modules. Spot up pipe shed. Lower V-door chute. 21:00 00:00 3.00 0 0 MIRU MOVE RURD P Rig Up -Connect all service lines between modules. Lay herculite and spot up Rock washer. Start loading 4" DP into pipe shed. *"NOTE*'" Rig acce t Midni ht 2400 hrs 9/29/07 09/30/2007 00:00 00:30 0.50 0 0 SURFA MOVE MOB P Rig Accept 00:00 hrs 9/30/07 -Walk thru ri acce t check list"OK" 00:30 02:00 1.50 0 0 SURFA DRILL PULD P Load Pipe Shed with 4" XT 39 DP 204 'ts and stra same. 02:00 02:30 0.50 0 0 SURFA DRILL RURD P PU & Install mousehole -Secure in cellar 02:30 09:00 6.50 0 0 SURFA DRILL PULD P PU 68 stds 4" XT39 Dp and std back in derrick. 09:00 12:00 3.00 0 0 SURFA DRILL RURD P Rig up hard line to flow back manifold - Choke house -Tiger Tank. RU to tree to kill well. 1700 psi on Tbg, 1650 psi on IA 12:00 15:00 3.00 0 0 SURFA DRILL DHEQ P PJSM and Con't to RU to kill well - Take on 13.1 ppg KWM (450 bbls)- Prime mud pumps -test mud lines to 2500 si "OK" 15:00 18:45 3.75 0 0 SURFA DRILL RURD P Test flow back and kill lines w/diesel to 4000 psi. -Install lubricator and pull BPV from Tbg. RU VR lubricator and ull VR lu . ~ e o 4'~ge 1 tai ~~ ~~..~._.._...__ ~~ Time Lois _ `___ __ i Date From _To ____ Dur _ S,_D~th EDepth Phase Code Subcode_ T COM 09/30/2007 18:45 19:15 0.50 0 0 SURFA DRILL SFTY P PJSM -Discuss planned well kill and procedure. Explain procedure and told each crew member what his responsibility was and answered any uestions. 19:15 21:00 1.75 0 0 SURFA WELCT KLWL P Open Well and start Kill Procedure - Trg psi 1150 psi, IA 950 psi. Bring pump to SPR (25 SPM) ICP 1900 psi - KWM to bit FCP 388 psi .388 psi was held until KWM to surface. Shut down 0 tbg pressure, 0 IA psi. OA 350 psi. Blow down choke and kill lines to Ti er Tank. 21:00 22:30 1.50 0 0 SURFA WELC OWFF P Shut well in for 45 min "NO Build" - Open choke "NO psi" , No returns. Well is static -Set BPV 22:30 00:00 1.50 0 0 SURFA WELCT NUND P RD Kill Line - ND Tree -Install blankin lu - NU ada ter flan e 10/01/2007 00:00 06:00 6.00 0 0 SURFA WELCT NUND T After tree was ND it was noted that the well head is 2.5' higher than what is normally rigged upon. The Rig bridge crane could not pick high enought to set the BOPS on the 7.0625 - 5k tbg flange as it is configured. CPAI Co Rep called and informed the AOGCC of the problem. He explained the problem and ask if he could go ahead and drop out the bttm set of rams and use a DSA to make up to the tbg head. Being we are in a WO mode this is allowed under the regs. Co Rep stated that the complete well is displaced with 13.1 KWM and Static. He explained that he could move ahead with some progress and still gather up the equipment to mate up to the tbg head. AOGCC rep said that the plan sounded resonable but that prior to cutting the window that the BOPS would have to be back in the proper configuration. CPAI Co rep agreed and proceeded. The Team leader was called and he gave his a royal to roceed. 06:00 08:00 2.00 0 0 SURFA RIGMN RGRP T An oil drip was noted on the Top Drive and the rig mechanic was trying to locate the scorse. He could not. Will need to be repaired when we can set it down low. 08:00 12:00 4.00 0 0 SURFA WELCT BOPE T RU test joint -Because of height it will need to be modified to be able to test 2 7/8" rams. (Shorten 9.5' & install baffle plate and test port. MU XO for test 'oint. ~~ i~a~~ 2 of ~~ J Time Logs _ __ __ _ _ _ __ _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM 10/02/2007 08:00 14:00 6.00 0 0 SURFA RPCOh TRIP P Cont. to POOH LD 2 7/8" completion, LD an add. 160 jts of tbg and 5 GLM's, Total POOH & LD 193 jts and 1-cut piesce, 5 GLM's and SSSV, NORM tbg and tree and ck'd ok (recovered 6040' of tubin ). 14:00 15:30 1.50 0 0 SURFA RPCOh RURD P RD tbg handling equip. and cleared and cleaned rig floor. Loaded pipe shed with 9-Dc's and 15 jts HWDP and strapped same. Monitor well - static. 15:30 16:45 1.25 0 0 SURFA RPCOh PULD P PU & MU Bit Scapper and XO's & float sub. Single in drill collars and HWDP, building 3 stands of hybrid drill collars. POOH and stand back to change out rams. 16:45 17:00 0.25 0 0 SURFA WELCT SFTY P PJSM -Change out rams 17:00 18:30 1.50 0 0 SURFA WELC NUND P Drain stack, ciose blind rams and change out top pipe rams to 1.5"x6" VBRs. 18:30 19:15 0.75 0 0 SURFA WELCT BOPE P Set test plug, fill stack wlwater and test VBRs, 250# low & 5000# high, 5 minutes each. Pull test plug, lay down test 'oint and monitor well -static. 19:15 21:30 2.25 0 0 SURFA RPCOM1 TRIP P RIH w/BHA, single in 3 5"drill collars, 12 4" HWDP. RIH to 2621', fill DP and break circulation @ 5059'. PU 100k, SO 95k, Rotating Wt 98k, Torque @ 30 m 1-2k. 21:30 22:15 0.75 0 0 SURFA RPCOh CIRC P CBU @ 278 GPM, 1100 PSI. Max gas 64 units. Monitor well -static. Pump slu & blow down TD. 22:15 00:00 1.75 0 0 SURFA RPCOh TRIP P POOH 10/03/2007 00:00 00:15 0.25 0 0 SURFA RPCOti TRIP P Fin POOH & LD bit & scraper 00:15 00:30 0.25 0 0 SURFA EVAL SFTY P Held PJSM with Schlumberger (SWS) on RU of E-line. 00:30 01:45 1.25 0 0 SURFA EVAL RURD P RU SWS a-line and scheaves then MU Baker CIBP onto a-line with GR/CCL 01:45 03:15 1.50 0 0 SURFA EVALVb ELOG P RIH with CIBP and set same at 3,569', POOH with a-line & RD. 03:15 03:30 0.25 0 0 SURFA CASINC DHEQ P Tested 7" csg and CIBP to 3,000 psi for 15 min, ood test. 03:30 05:30 2.00 0 0 SURFA WELCT NUND P ND BOP stack 05:30 10:00 4.50 0 0 SURFA WELCT NUND P Changed out tbg head and 7" packoff. Installed Gen IV 11" 3M x 7 1/16" 5M tbg head, (note when packoff was removed csg did not move.) Tested seals and void to 3,000 psi for 10 min. 1st test failed, removed tbg head and C/O seal, re-installed and re-tested and ck'd ok. - ~~..~...____.~. ~ ?~a~k ~ cif ~<; • Time Logs Date_ From To Dur S~Depth E:_Depth Phase Code Subcode__T COM _ 10/04/2007 17:30 19:00 1.50 0 0 SURFA STK PULD P Clear rig floor, pull wear bushing, flush stack and reset wear bushin . 19:00 22:15 3.25 0 0 INTRM1 DRILL PULD P PU & MU BHA #2. Orient and upload. 22:15 00:00 1.75 0 1,786 INTRM1 DRILL TRIP P PU HWDP, jars and single in hole. 10/05/2007 00:00 01:15 1.25 1,786 3,470 INTRM1 DRILL TRIP P RIH from 1,786' to 3,470' 01:15 04:30 3.25 3,470 3,470 INTRM1 DRILL SRVY T RU Gyro and RIH to orient motor, tagged up at 3,270', tagging up at XO to NMFDC's, POOH and circ hole in attempt to clear obstruction, RIH a second time and tagged up at the same s ot. 04:30 07:00 2.50 3,470 201 INTRM1 DRILL TRIP T POOH from 3,470 to 201' and found a 3 1!8" x 1 1/4" teflon spacer in the top box of NMFDC's and just below the XO to 4" DP. Spacers are sometimes used to hold floats in place below MWD. No idea where it came from and how it of stuck in the NMFDC. 07:00 08:00 1.00 201 201 INTRMI DRILL SRVY T Held PJSM then RU gyro and made test run from 201' and ck'd ok. 08:00 09:00 .1.00 201 3,470 INTRM1 DRILL TRIP T RIH from 201' to 3,470' 09:00 11:30 2.50 3,470 3,563 INTRM1 DRILL SRVY P RIH with gyro and oriented motor to high side, POOH, RIH thru the window to 3,563' with no problems, (TOW @ 3,543') ran 2nd gyro for ck shot to confirm motor orientation. 11:30 12:00 0.50 3,563 3,576 INTRM1 DRILL REAM P Washed down from 3,563' to btm at 3, 576'. 12:00 15:15 3.25 3,576 3,659 INTRM2 DRILL DDRL P Drilled 4 3/4" x 7" hole from 3,576' to 3,659' MD/3,659' TVD (83') ART .44 hrs, AST 1.42 hrs = 1.86 hrs ADT. 15:15 16:15 1.00 3,659 3,659 INTRM2 DRILL SRVY P Ran gyro survey for orientation check shot. 16:15 16:45 0.50 3,659 3,659 INTRM2 RIGMN SVRG P Serviced top drive. 16:45 18:00 1.25 3,659 3,752 INTRM2 DRILL DDRL P Drill ahead. ART .62 hrs, AST .58 hrs, ADT 1.2 hrs 18:00 19:30 1.50 3,752 3,752 INTRM2 DRILL SRVY P Stop drilling for gyro survey. 19:30 20:30 1.00 3,752 3,846 INTRM2 DRILL DDRL P Drill ahead until statisfied with kick off. ART .76 hrs, AST .27 hrs, ADT 1.03 hrs. Max as 75 units, ECDs 11.4. 20:30 21:30 1.00 3,846 3,846 INTRM2 DRILL CIRC P Mix & pump dry job, rig down gyro, take slow um rates. 21:30 00:00 2.50 3,846 0 INTRM2 DRILL TRIP P POOH to reset motor from 1.83 to 1.5 de ree bend. 10/06/2007 00:00 04:00 4.00 0 3,846 INTRM2 DRILL TRIP P Download MWD, LD collars and UBHO, change motor bend from 1.85 degrees to 1.5 degrees. RIH till bit out of window, orient and wash to bottom. 04:00 12:00 8.00 3,846 4,211 INTRM2 DRILL DDRL P Drill ahead. ART 2.78 hrs, AST 3.54 hrs, ADT 6.32 hrs. ~ ~ _ taage ~ of ~~~ C~ n Time Logs __ _ ____ __ Date From To Dur S. De th E. De th Phase Code Subcgd e T COM 10/06/2007 12:00 00:00 12.00 4,211 4,689 INTRM2 DRILL _ _ DDRL P Crew change, PJSM & continue drilling. Pumped 30 bbl sweep containing MI Drill Zone for bit balling at 4370' MD. Sweep was effective. ART 5.96 hrs, AST 3.75 hrs, ADT 9.71 hrs 10/07/2007 00:00 12:00 12.00 4,689 5,348 INTRM2 DRILL DDRL P Drill ahead. Pumped 20 bbl sweep containing 10ppb nutplug for bit balling at 4911' MD. Sweep was effective. ART 3.99 hrs, AST 5.39 hrs, ADT 9.28 hrs. Max as 55 units. 12:00 00:00 12.00 5,348 5,985 INTRM2 DRILL DDRL P Drill ahead. ART 6.55 hrs, AST 3.04 hrs, ADT 9.59 hrs. Max as 58 units. 10/08/2007 00:00 12:00 12.00 5,985 6,565 INTRM2 DRILL DDRL P Drill ahead. ART 6.74 hrs, AST 2.71 hrs, ADT 9.45 hrs. ECDs 11.13 ppg. Max as 35 units. 12:00 20:00 8.00 6,565 6,810 INTRM2 DRILL DDRL P Drill ahead. 20:00 22:45 2.75 6,810 6,835 INTRM2 DRILL DDRL P brill ahead, rotating, ROP slowed to ~4 fph. Pumped 25 bbl nut plug sweep and a 30 bbl nut plug /drill zone sweep. No change to ROP. Regained 200psi differential pressure after second sweep. Correlated depth with log from 3N-14 and found a hard shale layer at this depth. Continued drilling and broke out at 6835' MD / 5562' TVD. 22:45 00:00 1.25 6,835 6,844 INTRM2 DRILL DDRL P Drill ahead, rotating, ROP 40-60 fph. ART 5.24 hrs, AST 4.13 hrs, ADT 9.37 hrs. ECDs 11.46 ppg. Max gas 27 units. 10/09/2007 00:00 06:00 6.00 6,844 6,882 INTRM2 DRILL DDRL P Drilled from 6,844' to 6,882' MD/ 5,595' TVD (38') ART 1.44 hrs, AST 2.68 hrs. 10.0 ppg MW ave ECD 11.4 ppg, while sliding, making ~4 fph. Pumped nut plug sweeps at 00:30 & 01:30, no improvement. Saw 200 psi increase in stand pipe pressure. Rotate for 10', still poor ROP. Continue sliding, slow ROPs. Pumped nut plug sweep while rotating, no improvement. Prepare to ull out of hole. 06:00 06:30 0.50 6,882 6,882 INTRM2 DRILL CIRC T Circ btms up at 345 gpm at 3,250 psi 06:30 06:45 0.25 6,882 6,882 INTRM2 DRILL OWFF T Monitored well-static 06:45 10:30 3.75 6,882 100 INTRM2 DRILL TRIP T POOH wet 10 stds and hole took talc fill or no problems, pumped dry job and blew down top drive, cont to POOH standing back HWDP, jars and NMFDC's. ~ -- ~ - - Wage ? o~~ 29 l • C~ Time Logs _ _ _ _ Date From To Dur S D th E. De th Pha e Code Subcode T COM 10/09/2007 10:30 12:00 1.50 100 0 INTRM2 DRILL _ PULD T _ Down loaded MWD and LD motor and bit, found 4 3/4" pilot bit to have 2 plugged jets, bits cutters and RWD reamer looked ok and was in gauge. found flapper from float had broken off. Calc fill on trip out 42 bbls, actual fill 45 bbls. 12:00 14:30 2.50 0 660 INTRM2 DRILL PULD T Changed out jets on 4 3/4" pilot bit from 4-11' to 4-12's leaving 2-11's in the reamer, MU bit to motor and re-set motor to 1.5 deg's, MU MWD leaving out UBHO sub, oriented and uploaded same, RIH with NMFDC's, HWDP and 'ars. 14:30 17:00 2.50 660 6,752 INTRM2 DRILL TRIP T RIH with BHA #4 to window. Window free, no obstruction. Resume RIH. Break circ 3658, 6752 ft. 17:00 17:30 0.50 6,752 6,882 INTRM2 DRILL CIRC T Washed to btm while circ btms up with 30 bbl drill zone /SAP sweep. BU as 100 units. 17:30 00:00 6.50 6,882 6,983 INTRM2 DRILL DDRL P Drill ahead 7" hole dretnl 6882 - 6983 ft. TVD 5649, AST = 2 hrs, ART = 2.74 hrs.ECD 11.3, up 125, do 104, rot 110, t 3000, max as 22 units. 10/10/2007 00:00 12:00 12.00 6,983 7,066 INTRM2 DRILL DDRL P Dir. Drilled 4 3/4" x 7" hole from 6,983' to 7,066' MD/5,704' TVD (83') ART 2.8 hrs, AST 6.82 hrs, ADT 9.62 hrs., ave MW 10.0 ppg ECD 11.16 ppg, ave BGG 8 units, max gas 20. Seeing hi vibration on MWD tool, Pumped 35 bbl lotorque sweep to help reduce same and varied pump rates and RPM's to hel lower vibration. 12:00 00:00 12.00 7,066 7,217 INTRM2 DRILL DDRL P Dir drill 4-3/4 X 7 hole 7066 - 7217 ft. 5790 TVD, AST 4.99, ART 4.91, ADT 9.90, ECD 11.3, BGG 40 units, max 45 units. 10/11/2007 00:00 09:00 9.00 7,217 7,319 INTRM2 DRILL DDRL P Dir. Drilled 4 3/4" x 7" hole from 7,217' to 7,319' MD/5,861' TVD (102') ART 2.79 hrs, AST 4.34 hrs, ADT 7.22 hrs, ROP slowed while attempting to slide and began to see vibration in the MWD tool again. Decision was made to POOH for a bit than e. 09:00 09:30 0.50 7,319 7,319 INTRM2 DRILL CIRC T CBU at 280 gpm at 1,800 psi and 90 m's. 09:30 09:45 0.25 7,319 7,319 INTRM2 DRILL OWFF T Monitored well-static 09:45 13:15 3.50 7,319 550 INTRM2 DRILL TRIP T POOH wet 10 stds and hole took talc fill with no problems, pumped dry job and cont. to POOH standing back HWDP, jars and NMFDC's. No drag, swab, correct hole fill. l~~ge 8 ref ~9 C~ Time Logs _ Date From To __ Dur _5 De th E_ Depth Phase Code Subcode T COM ____ 10/11/2007 13:15 17:00 3.75 550 0 INTRM2 DRILL PULD T Flow check, handle BHA #4, download MWD. Inspect BHA. Washout in motor body 5 ft from bit. Break /grade bit. Some heat checking. Cutter structure /matrix good cond. Bit balled, 4 lu ed ~ets. 17:00 19:30 2.50 0 0 INTRM2 RIGMN' SVRG P PJSM, slip / cut drlg line, service rig. 19:30 22:00 2.50 0 0 INTRM2 DRILL PULD T MU BHA #5, upload MWD, PU dretnl assy, torque, orient /scribe and record data. 22:00 00:00 2.00 0 3,735 INTRM2 DRILL TRIP T PJSM, flow check, R1H BHA #5 /bit #2, follow with 4" DP to csg window, pass window, no obstruction. fill pipe, resume RIH. 3735 ft. 10/12/2007 00:00 01:30 1.50 3,735 7,295 INTRM2 DRILL TRIP T Cont. to RIH with BHA #5 from 3,735' to 7,295'. 01:30 02:00 0.50 7,295 7,319 INTRM2 DRILL REAM T Precautionary washed down from 7,295' to btm at 7,319', washed down at 280 gpm, 2,800 psi, 60 rpm's with 4K ft-Ibs torque, no problems RIH or excessive for ue on btm from new bit. 02:00 12:00 10.00 7,319 7,642 INTRM2 DRILL DDRL P Cont. to dir. drill 4 3/4" x 7" hole from 7,319' to 7,642' MD/6,122' TVD, (323') ART 2.99 hrs, AST 4.67 hrs, ADT 7.66 hrs, ave MW 10.3 ppg, ave ECD 11.6 max as 135 units. 12:00 15:30 3.50 7,642 7,768 INTRM2 DRILL DDRL P Cont. to drill from 7,642' to 7,768' MD/6,232' TVD (T. D.) (126') ART 2.77 hrs, AST 0.51 hrs, ADT 3.28 hrs, 10.25 ppg MW, ECD 11.57 ppg, um ed 35 bbl hi vis swee at TD. 15:30 16:45 1.25 7,768 7,768 INTRM2 DRILL CIRC P Fin. circ sweep out of hole, had a slight increase in cuttings back from the sweep, cont. to circ an add 1.5X btms up and was clean at the shakers, circ 81 spm, 280 gpm at 2,650 psi, rotating at 90 rpm's with 4K ft-Ibs for ue 16:45 17:00 0.25 7,768 7,768 INTRM2 DRILL OWFF P Monitored well-static, took SPR's. 17:00 18:45 1.75 7,768 7,768 INTRM2 DRILL WPRT P Wiper trip 15 stds 7768 - 6297 ft. No dra /swab. RIH no brid a /fill. 18:45 21:15 2.50 7,768 7,768 INTRM2 DRILL CIRC P C/C fluids for liner run. Shaker clean, no addtnl cuttings return with sweep. Fluid tali er = au a hole. 21:15 21:45 0.50 7,768 7,768 INTRM2 DRILL OTHR P Flow check, LD single DP, drop 2" rabbit, blow do lines. 21:45 00:00 2.25 7,763 4,860 INTRM2 DRILL TRIP P PJSM, POH (SLM), 4" DP 7763 - 4860 for liner run. 10/13/2007 00:00 01:30 1.50 4,860 200 INTRM2 DRILL TRIP P Cont. to POOH from 4,860' ,stood back HWDP and 'ars 01:30 04:15 2.75 200 0 INTRM2 DRILL PULD P POOH LD NMFDC's then downloaded MWD and fin. LD BHA #5. Cleared and cleaned ri floor. 04:15 04:45 0.50 0 0 INTRM2 DRILL PULD P Pulled wear bushing ~ F~age ~ f ~~ ~ ~_ • • Time Logs _ _ _ _ _ _ Date From To Dur S Depth E. Depth Phase Code Subcode T COM ____ ____ _ 10/13/2007 04:45 05:30 0.75 0 0 INTRM2 CASIN( RURD P RU to run 5 1/2" liner 05:30 05:45 0.25 0 0 INTRM2 CASIN( SFTY P Held PJSM on liner detail and the associated hazards. 05:45 13:00 7.25 0 3,520 INTRM2 CASIN PUTB P RIH with 5 1/2", 15.5#, L-80 Hydril 511 liner to 3,520' (TOW @ 3,543'), MU float shoe, 2-jts liner, flt collar and 1 jt liner with insert landing collar on pin end, thread locked and circ thru same checking floats and ck'd ok, cont. to RIH slow with liner, RIH with 83 jts of 5 1/2", 15.5# L-80 Hydril liner, ran 13 standoff bands on stops, 1 every other jt to jt# 25, st wt up 70K, do wt 70K. Had full returns while RIH to TOW. 13:00 14:30 1.50 3,520 3,520 INTRM2 CASIN CIRC P Circ 1 liner cap. above TOW, staged pump rate up to 2 bpm at 600 psi with full returns. 14:30 16:00 1.50 3,520 4,389 INTRM2 CASINC PUTB P Cont. RIH with 5 1/2" liner to 4,389', RIH with a total of 104 'ts. 16:00 17:00 1.00 4,389 4,462 INTRM2 CASIN PUTB P MU Baker HMC liner hanger with "CHP" liner top packer &RIH with XO, pup jt and 1-full jt of 4" XT-39 DP RIH to 4,462'. 17:00 17:45 0.75 4,462 4,462 INTRM2 CASIN CIRC P Circ btms upstaging pump rate up to 2 bpm at 650 psi, st wt up 78K, do 70K, pumped 50 bbls total and lost 3.5 bbls while circ. 17:45 00:00 6.25 4,462 6,995 INTRM2 CASIN RUNL P RIH with 5 1/2" liner on 4" DP from 4,462' at 9-10 min/std, est. circ 6995 ft. 10/14/2007 00:00 01:00 1.00 6,995 7,274 INTRM2 CASINC RUNL P RIH 5-1/2 liner to 6955 ft. Fill pipe, wash to 7274 ft. 1.5 bpm / 340 psi. Attempt estab PU wt, no go, pipe stuck. Can not re-ci u nor dn. 01:00 05:00 4.00 7,274 2,864 INTRM2 CASIN CIRC T Break circ, 5 bpm / 840 psi. 100% returns. Work pipe while spot 7% tube pill to 5-1/2 X 7 open hole annulus. Cont work pipe to max 240K up wt. 50K dn. Final pull to 220K, wt decrease to 170K, string pull free, and lost pump press briefly. Note press return to 800 psi with 100% returns. Stand back one stand, prepare to C/C fluids. 05:00 06:00 1.00 2,864 2,864 INTRM2 CASIN CIRC T Circ hole evening MW in hole in and out at 10.0 ppg, circ at 5 bpm at 840 si, st wt u 73K. 06:00 08:30 2.50 2,864 0 INTRM2 CASINC RUNL T Monitored well-static, POOH and found we had pulled off liner hanger and LD liner running tool, LD single from cement head and LD 1 std of 4" DP, 1 jt was bent when running tool came loose. _____ - ~ Pa~€~ ~7 ~~ taf ~9 • • Time Logs- - - - --~ -- -- ---- - Date From To Dur S. Depth E D~th Phase Code Subcode T COM ______ 10/14/2007 08:30 10:30 2.00 0 2,864 INTRM2 FISH TRIP T MU Baker pack-off on 3 1/2" mule shoe and RIH on 4" DP, tagged top of liner at 2,864', st wt up 70K, do wt 73K. float shoe is at 7,273' MD/5,831' TVd at 48 de 's. 10:30 12:45 2.25 2,864 7,273 INTRM2 FISH OTHR T RU and attempted to test annulus to determine if packer was set, pressured up to 600 psi and held, attempted to circ the long way and after 3 bbls had no returns, pressured up on annulus a 2nd time and hole began to take fluid at 630 psi and pumped 1.5 bbls with no increase in pressure. RU and pumped down the DP a 2nd time and after pumping 2 bbls was able to regain circ and verified acker wasn't set. 12:45 14:30 1.75 2,864 2,864 INTRM2 FISH CIRC T Circ hole lowering MW in and out to 10.0 ppg, staged pump rate up to 4 bpm at 575 psi. had 10K wt down on ackoff. 14:30 14:45 0.25 2,864 2,864 INTRM2 FISH OTHR T Monitored well-static 14:45 16:15 1.50 2,864 0 INTRM2 FISH TRIP T POOH and LD Baker packoff. seals looked new. 16:15 18:45 2.50 0 324 INTRM2 FISH PULD T PU and MU Baker spear assembly on fishing BHA #6 and RIH PU 9-4 3/4" DC's to 324'. 18:45 20:30 1.75 324 2,864 INTRM2 FISH TRIP T Follow fish assy with 4" DP to tag liner h rat 2864 ft. 20:30 00:00 3.50 2,864 2,864 INTRM2 FISH JAR T Estab circ, engage liner hgr with spear, continued circ 4.5 bpm / 925 psi, 100% returns. Work pipe, jar up with 150K, do wt to 50K. Max pull 220K. Cont attem t work free. 10/15/2007 00:00 03:30 3.50 2,864 2,864 INTRM2 FISH JAR T Cont. to attempt to circ hole and jar liner loose, was unable to re-est. circ orjar liner loose pulling 220-300K. Varied parameters, during multiple attem ts. No success. 03:30 04:00 0.50 2,864 2,864 INTRM2 FISH OTHR T Released spear from liner and LD sin le 't of DP, monitored well-static 04:00 05:00 1.00 2,864 324 INTRM2 FISH TRIP T POOH to BHA at 324 ft. 05:00 06:30 1.50 324 0 INTRM2 FISH PULD T POOH LD 1 std of 4 3/4" Dc's and stood back the other 2 stds, LD jars ands ear assembl 06:30 08:30 2.00 0 0 INTRM2 FISH RURD T RD riser and MU 13 5/8" x 7" shooting flan e 08:30 09:30 1.00 0 0 INTRM2 FISH OTHR T Cleared rig floor and prep. for a-line, serviced ri 09:30 10:30 1.00 0 0 INTRM2 FISH WOEQ T Waited on lubricator extension 10:30 14:45 4.25 0 0 INTRM2 FISH RURD T Held PJSM then RU Schlumberger e-line, RU scheaves and 5 112" x 7" lubricator then MU 4 7/16" chemical cutter and to in strin . _e ~~.. ~ ~a~ ~ 1 of 2~ Time Logs _ _ Date From To Dur 5 De th E. De th Phase Code Subcode T CO M 10/16/2007 12:30 14:00 1.50 0 326 INTRM2 FISH PULD T _ _ Held PJSM with cregw & BOT fishing rep. Make up BHA #8, spear assembly with 4.961 Grapple. Total BHA len th = 326'. 14:00 15:15 1.25 326 2,864 INTRM2 FISH TRIP T Trip in hole from. 326' - 2864'. UP Wt = 78K, SO WT = 78K Observed proper dis lacement. 15:15 15:45 0.50 2,864 2,864 INTRM2 FISH FISH T Establish fishing parameters. Pumps at 16 SPM - 600 PSI. Observed 80% losses to well. Engage spear grapple and pull to verify catch. Pull to 200K over. Allow jars to fire, repeat. Fish not free. Observed 12 BBLS pumped away while fishin . 15:45 16:00 0.25 2,864 2,864 INTRM2 FISH FISH T Release spear grapple. POOH laying down a single. Blow down Top drive. Monitor well -static. 16:00 17:00 1.00 2,864 326 INTRM2 FISH TRIP T POOH from 2864' - 326'. Observed ro er hole fill. 17:00 17:45 0.75 0 0 INTRM2 FISH PULD T Breakout & lay down BHA #8. rack back drill collars. 17:45 19:15 1.50 0 0 INTRM2 FISH ELNE T Nipple down flow riser. Nipple up shootin flan eon to of BOP annular. 19:15 21:30 2.25 0 0 INTRM2 FISH ELNE T Held PJSM with crew &SWS reps. Rig up SWS wireliners and hang sheaves. MAke up 4.15" Jet cutter as tanned. 21:30 23:30 2.00 0 0 INTRM2 FISH ELNE T WLIH with Jet cutter assembly. Spot cutter and make cut at 5212' WLM. WLOH, and lay down cutter assembl . 23:30 00:00 0.50 0 0 INTRM2 FISH ELNE T Breakout jet cutter. Make up #2 Jet cutter. Monitor well. Total fluid losses of 77 BBLS for the da .Crew Chan e 10/17/2007 00:00 01:00 1.00 0 0 INTRM2 FISH ELNE T WLIH to spot second 4.15" jet cutter at 3520' as planned. Attempt to cut. Sus ect misfire. WLOH 01:00 02:00 1.00 0 0 INTRM2 FISH ELNE T WLOH. Pull jet cutter assembly & inspect same. Cutter misfired due to bad detonator. No fluid losses observed. 02:00 03:00 1.00 0 0 INTRM2 FISH ELNE T Make up same 4.15" Jet cutter assembly changing out detonator. test same. WLIH to spot cutter in same position at 3520 WLM, fire and observe indications of fired cutter. WLOH. 03:00 03:45 0.75 0 0 INTRM2 FISH ELNE T Lay down & inspect cutter. Rig down SWS wireliners and sheaves. 03:45 04:30 0.75 0 0 INTRM2 FISH ELNE T Nipple down shooting flange. Nipple up flow riser. 04:30 05:30 1.00 0 326 INTRM2 FISH PULD T Held PJSM with crew and BOT fishing rep. Discuss safety & hazard recognition issues. Make up BHA #9, Spear assembly with 4.961" Grapple. Total BHA = 326'. _._ f~a€1~ 13 ~f 2~ C~ Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T COM 10/17/2007 05:30 06:30 1.00 326 2,859 INTRM2 _ FISH TRIP T __ Trip in hole from 326' - 2859'. Observed proper displacement. Tag & engage fish. UP WT -77K. SO WT = 77K. Pull to verify catch, observing added 8K in u wei ht verif in fish on. 06:30 07:00 0.50 2,859 2,859 INTRM2 FISH TRIP T Blow down Top Drive. Lay down 1 sin le. Monitor well -static. 07:00 10:30 3.50 2,859 326 INTRM2 FISH TRIP T POOH with proper hole fill. to 1546'. Observed hole swabbing. Continue trip out pumping every other stand out of hole to BHA. 10:30 11:30 1.00 326 0 INTRM2 FISH PULD T Rack back Drill collars. Lay down 3 DC's. 11:30 12:00 0.50 0 0 INTRM2 FISH PULD T Pull fish to rig floor. Attempt to release spear grapple. Unsuccessful. Crew Chan e 12:00 13:15 1.25 0 0 INTRM2 FISH PULD T Breakout & fay down packer assembly with spear engaged. Continue breakout & lay down fish. recovered 15 joints of 5 1/2" liner, and cutjoint. Toptal fish recovered = 655.67'. New to offish = 3520' MD. 13:15 13:45 0.50 0 0 INTRM2 FISH PULD T Clear & clean rig floor. Send tools out. Decision to test BOP's as per scheduled test. 13:45 19:00 5.25 0 0 INTRM2 WELCT BOPE P Rig up. & test BOP stack, choke manifold, HCR's, manulas, and all floor valves. test BOP"S with 3.5", 4", and 5.5" tests joints as per AOGCC. All test to 250 PSI low, 5000 PSI High and recorded on chart. Accumulator test, first 200 PSI in 34 seconds, with full 3000 PSI pressure in 2 minutes, 44 seconds. Average pressure in 5 nitrogen bottles = 2150 PSI. Rig down test equipment. Install wear bushing.Witness of test waived by AOGCC re -Jeff Jones 19:00 21:15 2.25 0 329 INTRM2 FISH PULD T Pull tools to rig floor. Held PJSM. Make up BHA #10. Spear assembly with 4.961" Gra le. Total BHA = 329'. 21:15 22:45 1.50 329 3,517 INTRM2 FISH TRIP T Trip in hole from 329' - 3517'. Observed proper displacement. Fill drill string eve 25 stands. 22:45 00:00 1.25 3,517 3,517 INTRM2 FISH FISH T Establish fishinig parameters with UP WT = 85K, SO WT = 90K. Tag & engage fish @ 3517' MD - 2' High. Pull to verify catch to 50K over. Fire jars staging up to 100K over to fire. Straight pull to 245K over. Fish not free. Pumps at 5 BPM - 500 PSI, with full circulation & no losses. Continue with 'arrin o erations. ~ Page 1~ F ~9 ~~.._ ~ Time Logs __ _ _ _ Date From To Dur S. De th E_ D~th Phase _ Code Subcode T __ COM __ 10/18/2007 13:00 14:45 1.75 3,517 0 INTRM2 FISH TRIP T Trip out of hole from 3517' - 329', observing proper hole fill. Rack back drill collars, breakout & la down BHA. 14:45 15:45 1.00 0 0 INTRM2 FISH ELNE T Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procwedure to make up shotting flange and RU E line. Nipple down flow riser, ni le u shootin flan e. 15:45 17:15 1.50 0 0 INTRM2 FISH ELNE T Rig up SWS wireline crew, and lubricator. hang sheaves. Make up 4.15" Jet cutter assembl . 17:15 19:00 1.75 0 0 INTRM2 FISH ELNE T WLIH to locate cutter at 5040' WLM, as the assembly would not go deeper in the hole. Fire jet cutter with good indications of cut. 19:00 20:45 1.75 0 0 INTRM2 FISH ELNE T WLOH, lay down tools. Good fire on 'et cutter. Make u #4 'et cutter. 20:45 22:15 1.50 0 0 INTRM2 FISH ELNE T WLIH, locate & fire cutter at 4310 as tanned. Observed misfire. 22:15 23:45 1.50 0 0 INTRM2 FISH ELNE T WLOH, Lay down & inspect tools.Observed failed detonator. Make u new detonator with same 'et cutter. 23:45 00:00 0.25 0 0 INTRM2 FISH ELNE T WLIH with 4.15" Jet cutter. No fluid losses for the tour. 10/19/2007 00:00 00:30 0.50 0 0 INTRM2 FISH ELNE T Continue WLIH to locate & fire cutter at 4310' WLM. Observed misfire a ain. 00:30 01:30 1.00 0 0 INTRM2 FISH ELNE T Trouble shoot tools and attempt to fire jet cutter numerous times with 500 volts. No success. 01:30 02:00 0.50 0 0 INTRM2 FISH ELNE T WLOH, breakout & lay down tools. Inspect tools, observing dry, and perform ohm testing detonator. Observed all batch numbers of detonators on location the same. bad batch as er wireline su ervisor. 02:00 03:30 1.50 0 0 INTRM2 FISH ELNE T Break down & inspect tools in unit. Wait on new detonators coming from Prudhoe. Make up new tools with same 4.15" ~et cutter. 03:30 05:30 2.00 0 0 INTRM2 FISH ELNE T WLIH to locate jet cutter at 4310' as planned. Fire cutter, observing good cut. WLOH to surface. Pull & lay down tools, inspecting, and observing cutter fired. 05:30 06:30 1.00 0 0 INTRM2 FISH ELNE T Rig down SWS wireliners, and sheaves. Nipple down shooting flange, and ni le u flow riser. 06:30 09:00 2.50 329 3,520 INTRM2 FISH TRIP T MU BHA #12. Total BHA Length = 329'. RIH to 3517' - PU single to 3520' MD 09:00 09:15 0.25 3,520 3,520 INTRM2 FISH PULD T Establish fishiong parameters. UP WT = 85K, SO WT = 90K. Tag & engage fish @ 3520' -Jar one hit at 65K over, ull to 90K over -Fish came free. 09:15 09:30 0.25 3,520 3,520 INTRM2 FISH FISH T Monotor well -Static -Blow down Top Drive. La down sin le. gage 'If f 2~ d_J ~~ Time Logs Date From To Dur S. De th E. Depth Phase Code. Subcode T COM _ 10/20/2007 17:00 17:30 0.50 3,560 4,032 INTRM2 DRILL TRIP T Trip in hole to tag cement at 4032' MD. Set down 10K, verify hard cement. 17:30 17:45 0.25 4,032 4,032 INTRM2 DRILL CIRC T Circulate & establish parameters. orient tool face to 115 deg right with 275 GPM's - 1650 PSI. Trough hole for kick off. Obtain slow um rates. 17:45 00:00 6.25 4,032 4,325 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 4032' - 4325' MD. ND = 4293'. ART = 1.21 HRS. AST = 2.94 HRS. ADT = 4.15 HRS. ECD = 10.36 PPG clean hole. MAx Gas observed = 143 Units. 10/21/2007 00:00 06:00 6.00 4,325 4,651 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 4325' - 4651' MD. TVD = 4557'. ART = 2.55 HRS. AST = 2.46 HRS. ADT = 5.01 HRS. ECD = 10.98 PPG .Max Gas observed = 37 Units. 06:00 12:00 6.00 4,651 4,939 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 4651' - 4939' MD. TVD = 4762'. ART = 1.64 HRS. AST = 3.09 HRS. ADT = 4.73 HRS. ECD = 10.98 PPG .Max Gas observed = 37 Units. Crew Chan e 12:00 18:00 6.00 4,939 5,231 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 4939' - 5231' MD. TVD = 4922'. ART = 2.06 HRS. AST = 2.29 HRS. ADT = 4.45 HRS. ECD = 11.27 PPG .Max Gas observed = 43 Units. 18:00 00:00 6.00 5,231 5,630 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 5231' - 5630' MD. TVD = 5094'. ART = 2.06 HRS. AST = 2.29 HRS. ADT = 4.45 HRS. ECD = 11.27 PPG .Max Gas observed = 39 Units. Crew Chan e 10/22/2007 00:00 06:00 6.00 5,630 6,049 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 5630' - 6049' MD. TVD = 5280'. ART = 4.58 HRS. AST = .79 HRS. ADT = 5.37 HRS. ECD = 11.50 PPG .Max Gas observed = 57 Units. 06:00 12:00 6.00 6,049 6,422 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 6049' - 6422' MD. TVD = 5444'. ART = 3.68 HRS. AST = .69 HRS. ADT = 4.37 HRS. ECD = 11.34 PPG .Max Gas observed = 51 Units. Crew Chan e 12:00 18:00 6.00 6,422 6,820 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 6422' - 6820' MD. TVD = 5625'. ART = 4.83 HRS. AST = .42 HRS. ADT = 5.25 HRS. ECD = 11.38 PPG .Max Gas observed = 131 Units. 18:00 00:00 6.00 6,820 7,051 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 6820' - 7051' MD. TVD = 5748'. ART = 1.89 HRS. AST = 2.68 HRS. ADT = 4.57 HRS. ECD = 11.50 PPG .Max Gas observed = 156 Units. 1 ~.._._..._ ~m e 1~i3 d~'~~* '~ k$ Cat ~:~ ~ J Time Logs _ __ _ __ Date From To Dur S. De th E. De th Phase Code Subcod T COM e 10/23/2007 00:00 06:00 6.00 7,051 7,386 INTRM2 DRILL _ ____ DDRL _ T Directional drill 6" x 7"INT hole from 7,051' to 7,386' MD / 5,969' TVD. ART = 3.7 HRS, AST = 1.65 HRS, ADT = 5.35 HRS, ECD = 11.3 PPG. Max Gas observed = 156 Units. 06:00 12:00 6.00 7,386 7,703 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 7,386' to 7,703' MD / 6,221' TVD. ART = 3.28 HRS, AST = 1.37 HRS, ADT = 4.65 HRS, ECD = 11.2 PPG. Max Gas observed = 123 Units. 12:00 12:15 0.25 7,703 7,715 INTRM2 DRILL DDRL T Directional drill 6" x 7" INT hole from 7,703' to 7,715' MD / 6,232' TVD. ART = 0.19 HRS, AST = 0 HRS, ADT = 0.19 HRS, ECD = 11.2 PPG. Max Gas observed = 133 Units. 12:15 12:45 0.50 7,715 7,715 INTRM2 DRILL CIRC T Pump 35 bbl Hi-Vis sweep @ 275 gpm, 77 spm, 2200 psi, 80 rpm, Trq 3k ft*Ibs. 20% increase in returns. Take survey off btm -Driller obtained SPR's. 12:45 13:00 0.25 7,715 7,715 INTRM2 DRILL OWFF T Monitor well -Static -Blow down TD. 13:00 13:45 0.75 7,715 6,732 INTRM2 DRILL TRIP T POOH on elevators from 7,715' to 6,732' MD (10 std short trip). No roblems encountered. 13:45 14:15 0.50 6,732 7,715 INTRM2 DRILL TRIP T Monitor well -Static - RIH to 7,715' MD and to btm. 14:15 15:45 1.50 7,715 7,715 INTRM2 DRILL CIRC T Pump Hi-Vis sweep @ 275 gpm, 77 spm, 2200 psi, 80 rpm, Trq 3k ft"Ibs. 5% increase in cuttings, received 133 units of as with bottoms u . 15:45 16:00 0.25 7,715 7,715 INTRM2 DRILL OWFF T Monitor well -Static. Pump dry job - Blowdown TD. 16:00 19:45 3.75 7,715 640 INTRM2 DRILL TRIP T POOH on elevators from 7,715' to 640' MD. Stand back HWDP and Collars. Calculated fill = 42.4 bbls, actual fill 47.6 bbls. 19:45 21:00 1.25 640 640 INTRM2 DRILL OTHR T Download MWD. 21:00 22:00 1.00 640 0 INTRM2 DRILL PULD T LD BHA #14. Bit Grade = 1,2, CT,C,X, I, LT,TD. 22:00 22:15 0.25 0 0 INTRM2 DRILL OTHR T Clean and clear rig floor. 22:15 00:00 1.75 0 578 INTRM2 DRILL PULD T MU BHA #15 to 578' MD - 6.125" Roller Cone, NMFDC, Stab, HWDP, and Jars. 10/24/2007 00:00 05:00 5.00 578 7,715 INTRM2 DRILL REAM T TIH from 578' to 3,826' MD. Wash and ream from 3,826' to 7,715' MD. PU single of 4" DP. 100 RPM, Trq 3k ft"Ibs, 95 s m, 1750 si. 05:00 06:45 1.75 7,715 7,715 INTRM2 DRILL CIRC T Circulate hole clean, 95 spm, 1750 psi. Spot 110 bbl tube pill. Displace. Pum d ~ob. 06:45 07:00 0.25 7,700 INTRM2 DRILL OTHR T LD Single 4" DP -Flow check well - Static. Blow dwn top drive and drop 2" rabbit on wire for drift. ~~ - Pzc~e ~~ of 29 i Time Logs - -- - -7 Date From To Dur _S. Depth E_ Depth Phase Code Subcode__T COM 10/24/2007 07:00 10:00 3.00 7,700 578 INTRM2 DRILL TRIP T POOH on elevators from 7,700' to 578' MD. SLM out of hole 7,122.59' -Pipe tall 7,122.62'. 10:00 11:00 1.00 578 0 INTRM2 DRILL PULD T LD BHA: 10 jts of 4" HWDP, Jars, 4 jts 4" HWDP, 2 NMDC's, NM Pony Flex, Stab, 1 NMDC, Near bit IBS, and bit. 11:00 11:15 0.25 0 INTRM2 DRILL OTHR T Clear and clean rig floor. 11:15 12:00 0.75 INTRM2 CASINC RURD T PU + RU 5-1/2" casing running tools. 12:00 19:30 7.50 0 4,345 INTRM2 CASINC RNCS T PJSM - PU from shed and run 5.5" 15.5# L80 Hyd 511 Liner per detail to 4,319' MD: Weatherford 303 Float shoe, 2 jts, Weatherford 403 Flt Clr, 1 jt, Baker landing collar, 99 jts. (Total of 202 jts ran, 25 stand off bands run in the middle of jts # 1 - 25, 50 stop rings). PU Baker Hanger and setting tool assembly to 4,345' MD. PU Wt = 85k, SO = 80k. Calculated fill 23.5 bbls, Actual fill 19.6 bbls. 19:30 21:00 1.50 4,345 4,345 INTRM2 CASINC OTHR T PU 1 Stand of 4" DP and continue to RIH with liner on DP: Encountered trouble going through wellhead (OD on Baker tool = 6.09" and ID of wear bushing = 6.375"). Appears that XO Pup jt collar lip is hanging up. Drain stack -Found to be full of wall cake. Line up and pump through annulus at 10 bpm, 500 psi. Continue to work hanger through wellhead -pull over with snubbing line to assist in lining up evenly through wellhead. Hanger made it through the wellhead/thin wall wear bushin . PU Wt = 80k, SO Wt = 78k. 21:00 22:15 1.25 4,345 4,532 INTRM2 CASINC CIRC T Break circulation and pump 10 spm, 500 psi. Increase to 22 spm, 600 psi. Wash down from 4,439' to 4,532' MD. 22:15 00:00 1.75 4,532 5,095 INTRM2 CASIN RUNL T Continue running 5-1/2" liner on 4" DP from 4,532' to 5,095' MD: Washing down 1 stand for every 5 at 22 spm, 600 psi. Recording Up and Dwn wts eve 5 stands. 10/25/2007 00:00 01:45 1.75 5,095 7,710 INTRM2 CASINC RUNL T Continue to TIH with liner on 4" DP from 5,095' to 7,710' MD. Circulate down 1 stand eve 5 at 2 bbls/min. 01:45 02:00 0.25 7,710 7,710 INTRM2 CEME~ RURD P RU Cement head. 02:00 04:30 2.50 7,710 7,710 INTRM2 CEME~ CIRC P Circulate and condition mud -Stage um s from 2 b m to 4.5 b m. 04:30 04:45 0.25 INTRM2 CEME~ SFTY P PJSM to review hazards and job rocedures. ~~~~ ~'i ~sf ~9 • l J Time Logs Date From To Dur S Depth E Depth Phase Code Subcode T COM_ 10/25/2007 04:45 07:00 2.25 INTRM2 CEME~ OTHR NP Dowell SLB begins to batch up. Finds communication failure with computer system. Troubleshooting equipment while waiting on a tech to arrive. Circulate and reci ricate i e. 07:00 09:30 2.50 INTRM2 CEME CIRC T Start to see losses while circulating (waiting on DS). Pumped LCM into mud system and reduced circ rate to 3 bpm. Total loss while circulating 53 bbls. Decision made to use cellophane flakes in cement, waiting on material to arrive from KOC. DS continues to batch up cement and re for 'ob. 09:30 11:00 1.50 INTRM2 CEME~ CIRC P .Pump cement per plan: 10 bbls water - test lines to 3500 psi - 15 bbls chemical wash CW100 at 3.5 bpm, 800 psi - 15 bbls 10.5 ppg mud push at 2.8 bpm, 700 psi - 41 bbls 11.5 ppg Lead Slurry at 3.5 bpm, 800 psi - 17 bbls 15.8 ppg Tail slurry at 3.5 bpm, 600 psi. Dropped Baker Dart and begin displacement. Pumped mud at 3.5 bpm, 375 psi. Reduced rate to see Dart entering 5-1/2" liner top at calculated volume. Increase pump rate and continue to displace with mud at 3.5 bpm, 500 - 200 psi. Plug bumped at 2900 psi with CIP at 1100 hrs. Displaced with 4.6 bbls of fresh water and 133 bbls of 9.5 ppg mud for a total of 137.7 bbls dis lacement. 11:00 11:30 0.50 7,710 3,372 INTRM2 CEME~ OTHR P Set Hanger with 3400 psi and 25k dwn wt. Bleed off pressure and check floats. Released from setting tool with 15 rt hand turns. PU 2' and mechanically set packer. Circ 20 bbls with stinger in tie back sleeve. Final Depths: TOL at 3372' MD, LC at 7,756' MD, FC @ 7,621' MD, and Shoe at 7,710' MD. Overall liner lap 171.43' M D. 11:30 12:00 0.50 3,372 3,372 INTRM2 CEME~ CIRC P Circulate a btm's up at 5 bpm and 500 si. 12:00 12:30 0.50 3,372 3,281 INTRM2 CEME~ RURD P RD Cement head and stand back 1 stand to 3281'. 12:30 13:00 0.50 3,281 3,281 INTRM2 CEME~ CIRC P Reverse circulate string volume at 2 bpm, 200 psi to clear DP of cement residue. 13:00 13:15 0.25 3,281 3,281 INTRM2 CASIN( OTHR P Monitor well static. 13:15 15:00 1.75 3,281 0 INTRM2 CASIN RUNL P POOH on elevators from 3,281' to surface. LD Baker runnin tool. 15:00 15:30 0.50 0 INTRM2 CASIN( RURD P Clean and clear rig floor of equipment. ~~ ~~c~~ 2~ e~~ ~~ ~ l~ Time Logs _ __ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 10/25/2007 15:30 16:30 1.00 578 INTRM2 CASIN( OTHR P Pulled wear bushing after several attempts. Damaged and will need to be replaced. Upper lip is curved inwards with ~ 2" piece missing with deformit of overall sha e. 16:30 16:45 0.25 INTRM2 WELCT SFTY P PJSM and hazard analysis on chan in lower rams. 16:45 17:45 1.00 INTRM2 WELC EORP P Pull btm set of 4" Rams from BOPE stack and install 2-7/8" rams. 17:45 20:00 2.25 INTRM2 WELCT BOPE P RU and test BTM 2-7/8" pipe rams, 2-7/8" floor and dart valves 250 psi low and 5000 psi high. Tested annular to 250 psi low and 3500 psi high. Tested all to 5 min each on chart. 20:00 20:30 0.50 INTRM2 WELCT OTHR P Pull test plug -Install new wear bushin with same 6-3/8" ID. 20:30 21:30 1.00 INTRM1 DRILL RURD P Clear rig floor of all unnecessary tools. PU 2-7/8" handlin tools from slide. 21:30 22:00 0.50 INTRM2 DRILL RURD P RU Power tongs and 2-7/8" rig tongs and elevators. 22:00 00:00 2.00 INTRM2 DRILL RURD P PJSM - MU BHA # 16 - PU 4-3/4" PDC Bit and MU to MWD HOC -Dies slipping on crummies -replace same. In ro ress. 10/26/2007 00:00 01:00 1.00 0 81 INTRM2 DRILL PULD P PJSM - Retorque bit, motor, flt sub, stab, xo, MWD. PU MWD EWR, Flow tube, NM XO. 01:00 02:30 1.50 81 81 INTRM2 DRILL OTHR P Plug in and upload MWD. 02:30 04:45 2.25 81 600 INTRM2 DRILL TRIP P Continue MU BHA #16. RIH to 600' M D. 04:45 05:45 1.00 600 600 INTRM2 DRILL DHEQ P SHT MWD - 29 spm, 1130 psi. Weak test with no detection. Decision made to rih 500' and re-test. 05:45 06:30 0.75 600 1,104 INTRM2 DRILL TRIP P Continue to RIH picking up 2-7/8" tbg to 1,104' M D. 06:30 08:00 1.50 1,104 1,104 INTRM2 DRILL DHEQ P SHT MWD @ 1,104' MD. First test at 22 spm, 740 psi with weak signal. Increased rate to 44 spm at 2450 psi. Good test. Concern over high pump pressure -Discuss with town eng - Decision to POOH and verify condtion of bit and BHA. 08:00 10:00 2.00 1,104 0 INTRM2 DRILL TRIP T POOH wet -from 1,104' to surface. 10:00 12:00 2.00 0 81 INTRM2 DRILL PULD T Break off bit and change out motor. Break flt sub. Bit and BHA look good - MWD changed out orifice in pulser. Orient motor to MWD. 12:00 13:30 1.50 81 1,000 INTRM2 DRILL TRIP T PJSM -Continue to RIH with BHA - SPT @ 400' MD, pumping 29 spm @ 1130 psi. Continue to RIH - SPT @ 1000', pumping 22 spm @ 800 psi. Blow down TD. Montior well -Static. .._. ~_~ _ ~~__.___ ~~g~ 23 _ot ?~ C~ Time Logs Date __ From To Dur S De th E, Depth Phase Code Subcode T COM 10/26/2007 13:30 19:00 5.50 1,000 _ 5,292 _ INTRM2 DRILL ___ TRIP P Continue RIH picking up 2-7/8" DP. Fill DP @ 3,100' & 5,292' MD. Picked up a total of 156 jts. Record T & D info with 2-7/8" tbg: PU wt 81 k, SO Wt 76k, Rot Wt 80k, Trq @ 30 rpm = 1 k ft`Ibs. RD power tongs and clear rig floor. 19:00 19:45 0.75 5,292 7,577 INTRM2 DRILL TRIP P Continue to RIH with 4" DP from ODS. Break circulation at 7,540' MD and tag Cement dart/plug @ 7,577' MD. Record T & D info: PU wt 110k, SO Wt 91 k, Rot Wt 100k, Trq @ 40 rpm = 2k ft*Ibs. 19:45 21:00 1.25 7,577 7,477 INTRM2 DRILL CIRC P PU 100' to 7,477 for csg test. Circulate air out of DS. MW = 9.5 21:00 22:30 1.50 7,477 7,477 INTRM2 DRILL DHEQ P RU chart recorder and manifold to test csg. Test to 3500 psi for 30 min and record on chart. Solid test. 22:30 00:00 1.50 7,477 7,585 INTRM2 CEME~ DRLG P Drill plugs and landing collar for 30 minutes. WOB 2-3k, 40 rpm, Trq 2k ft"Ibs, 110 gpm, 2100 psi. Continue drilling cement to 7,585' MD. Drilling at 118 m, 2350 si. 10/27/2007 00:00 02:00 2.00 7,585 7,715 INTRM2 CEME~ DRLG P Continue drilling out float collar, shoe track. 02:00 03:30 1.50 7,715 7,735 INTRM2 DRILL DDRL P Drlg 20' of new hole from 7,715' to 7,735' MD. ADT/ART = 0.95 hrs. Up Wt 107k, Dwn wt 90, Rot Wt 102, Trq 2.51k ft"Ibs. Record slow um rates. 03:30 04:30 1.00 7,735 7,670 INTRM2 DRILL CIRC P Pull up into the casing and recipricate pipe. Condition mud at 33 spm, 2300 psi, 50 rpm, Trq 2k -Mud Wt In/Out 9.5 04:30 05:00 0.50 7,670 7,670 INTRM2 DRILL LOT P RU & perform LOT to EMW 16 ppg. Record on Chart. RD. 05:00 06:30 1.50 7,670 7,670 INTRM2 DRILL CIRC P Displace mud system to 12.7 ppg LSND. 06:30 12:00 5.50 7,670 7,818 PROD1 DRILL DDRL P Drill 4-3/4" prod. hole f/ 7,735' t/ 7,818' MD. (83') ADT 4.01, ART 2.92, AST 1.09. Jar Hrs 4.96. Max as 347 units. 12:00 12:30 0.50 7,818 7,818 PROD1 DRILL SFTY P PJSM -Check kill rates with 12.7 ppg mud. Perform a BOP drill with the crew. 12:30 00:00 11.50 7,818 8,099 PROD1 DRILL DDRL P Continue to drill 4-3/4" prod. hole from 7,818' to 8,099' MD ! 6,546' TVD. (281') ADT = 8.91, ART = 5.70, AST = 3.21. Jar Hrs 13.87. Max gas 1307 units. 10/28/2007 00:00 06:45 6.75 8,099 8,220 PROD1 DRILL DDRL P Continue to drill 4-3/4" prod. hole from 8,099' to 8,220' MD / 6,647' TVD. (121') ADT = 5.8, ART = 4.51, AST = 1.29. Jar Hrs 19.67. Max gas xxx units. Survey on btm, Record slow um rates, Flow check -static. I ~~~ me ~ ~ s.~ r ~~ 24 eat 29 .f, i ~7 Time Logs Date From To __ Dur___ S_Depth E, Depth Pose Code Subcode T COM_ _ _ 10/31/2007 09:15 12:00 2.75 7,515 7,515 COMPZ RPCOh CIRC P Displace tbg and annulus to seawater. Pump at 6-3/4 bpm @ 1500 psi. PU Wt 76k, SO Wt 65k. Circ clean with 1st load of brine -Displace with 2nd load of brine till clean returns. Spot 10 bbls of 1 % CRW-132 corrosion inhibitor on the backside above the SBE. 12:00 13:00 1.00 7,515 7,423 COMPZ RPCOh PULD P PJSM - LD 3 jts of tbg. Blow Down TD, choke & kill lines. Calculate s ace out. 13:00 15:30 2.50 7,423 7,500 COMPZ RPCOb PULD P Continue with completion: PU three 3-1/2" 9.3# IBTM pup jts for space out - 1 jt - XO pup jt. (Final total of 234 jts tbg) PU Landing jt & RU pump lines. MU Hanger and connect SSSV control line. Test control line with 5500 psi for 10 mins. (Total of 66 SS Bands f/SSSV to han er . 15:30 16:00 0.50 7,500 7,536 COMPZ RPCOh HOSO P PU Wt 85k, SO Wt 72k. Land Tbg with 37k on hanger. Bottom of seals at 7,536' MD .Run in LDS. 16:00 17:30 1.50 COMPZ RPCOh DHEQ P Test Tbg with 2500 psi for 15 mins. Bleed down tbg to 1500 psi. Pressure up the IA to 2900 psi for 30 mins. Bleed off tbg and sheared ann-tbg shear vlv at 1000 psi. Pressure the Tbg/IA to 2500 psi. Close the SSSV and bleed tbg to test from below with 2500 psi for 15 mins. Bleed of IA and leave SSSV closed. 17:30 19:00 1.50 COMPZ RPCOh RURD P Blow down - RD pump lines -Back out LD -Vac out Stack -FMC set BPV - Clear ri floor. 19:00 21:00 2.00 COMPZ RPCOti NUND P ND BOPE and adaptor. 21:00 00:00 3.00 COMPZ RPCOh NUND P NU Adaptor and tree. 11/01/2007 00:00 01:45 1.75 COMPZ RPCOh NUND P PJSM; Continue to nipple up tree - stab & hammer up all flanges; Adapter to tubing hanger seals tested and held 250psi low & 5000psi high. ull, instal- test lu 01:45 02:45 1.00 COMPZ RPCOh NUND P Install scaffolding around well head 02:45 03:15 0.50 COMPZ RPCO DHEQ P Install pump in flange on tubing wing valve, fill with diesel and test tree. Tree tested and passed @ 250 PSI low and 5000 PSI high; removed test lu 03:15 03:30 0.25 COMPZ RPCOti DHEQ P Camco/Schlumberger opened SSSV & tested line @ 5000 PSI for 10 min. test ood 03:30 05:00 1.50 COMPZ RPCOti FRZP P . Rig up and freeze protect well with 100 BBLs of diesel; pumped at 2.2 BBLs/min. 1400 PSI initial pressure to 1750 PSI final ressure. ~a ~~ - ~ ~'a~t~ 2~ oaf ~9 C; Time Logs _ - Date From__ To Dur ----- S De th E. Depth Phase Code Subcode T COM __ 11/01/2007 05:00 07:00 2.00 COMPZ RPCOh FRZP P Connected tbg to IA and allowed well to U tube the diesel. 07:00 08:30 1.50 COMPZ RPCO RURD P Blow down lines, Rig up BPV with lubricator, fin. cleanin mud its. 08:30 09:00 0.50 COMPZ RPCOIb OTHR P Rig down scaffolding ,secure well, SICP = 0, SITP = 0, outer annulus = 50 PSI RIG RELEASE 09:OOhrs 11/1/07 e_ .® e~ ® ~ ~~gs ~~ oaf 3N-14A Summary of Events Post -Rig DATE Summary 11/6/07 ASSISTED WITH BPV REMOVAL. TAGGED D NIPPLE @ 7439' SLM, 7447' RKB. TAGGED BOTTOM @ 8095' SLM. SET CATCHER @ 7447' RKB. PULLED SOV @ 7397' RKB, SET DV. TESTED IA 2500 PSI, TBG TO 3500 PSI, GOOD. PULLED CATCHER. DRIFTED TO 8000 RKB WITH 20' x 2.5" DUMMY GUN. 11/8/07 PERFORATED WELL WITH 2-1/2" HYPERJET GUNS FROM 7925'-7945'. HAD 1000 PSI WELLHEAD PRESSURE ON WELL WHEN FIRING GUNS. WELLHEAD PRESSURE INCREASED TO 1250 PSI WITHIN MINUTES OF FIRING. 11/9/07 SET 2.30 ID ISO SLEEVE IN SSSV @ 2013' RKB. GAUGED THROUGH TREE TO 20' SLM WITH 2.90 SWAGE. READY FOR FRAC. 11/10/07 SUCCESSFULLY COMPLETED A SAND FRACTURE STIMULATION. PUMPED A TOTAL OF 195133# OF CARBOLITE WITH 195046# BEHIND PIPE. COMPLETED FRAC WITH 10 PPA ON FORMATION. PUMPED A TOTAL OF 1861 BBLS OF SW @ AN AVERAGE PRESSURE OF 5082 PSI. FRAC PUMPED TO COMPLETION. WELL FLUSHED WITH 30 BBLS SW AND 33 BBLS OF DIESEL FREEZE PROTECT. 11/11/07 USED 2" JSN, SLICK DIESEL AND DIESEL GEL TO CLEANOUT FRAC SAND AND HEAVY DRILLING FLUID FROM 7597' TO 8088' CTMD, EST. 140' OF RATHOLE. WELL LEFT SI AND FREEZE PROTECTED. 11/20/07 PULLED FRAC SLEEVE @ 2013' RKB. TAGGED @ 8086' SLM. BRUSH AND FLUSH TBG TO D-NIP @ 7447' RKB. PULLED GLVs FRAOM STA#1 & 2. 11/22/07 PULLED 1" DMY VLV @ 2342' RKB. REPLACED WITH GLV. SET 1/4" OV @ 4981' RKB. SET GLV @ 3707 RKB. 04-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3N-14A Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,981.00' MD Window /Kickoff Survey 4,032.00' MD (if applicable) Projected Survey: 8,220.00' 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 ~! Date ~~ Si ned Please call me at 273-3534 if you have any questions or concerns Regards, Timothy Allen Survey Manager Attachment(s) ~o~-~~ q • 04-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3N-14A PB1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,494.00' MD Window /Kickoff Survey 3,543.00' MD (if applicable) Projected Survey: 7,768.00' 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 _ ~ _ Date ~ ~ ~1~-~ ~~try~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~~~Lq 3N-14A PTD# 207-119 Maunder, Thomas E (DOA) Page 1 of 2 From: Brink, Jason A [Jason.Brink@conocophillips.com] Sent: Friday, October 19, 2007 9:20 AM To: Maunder, Thomas E (DOA) Cc: Thomas, Randy L; Doyon 141 Company Man rn,, ~ Subject: RE: 3N-14A PTD# 207-119 /~,~` ' Y"I Tom I want to update you on this fishing operation and the planned change in sidetrack depth. As of this morning, Doyon 141 has cut the stuck 5-1/2" liner at 4310' MD and is on the way in the hole to spear and pull the liner from that depth. 5-1l2" liner will be left behind from 4310' MD - 7274' MD. A 400' cement kick off plug will be set from 4310' MD to 3910' MD. This interval will be re-drilled to 40' above the Kuparuk C sand and 5-1/2" liner will be re-run. The Kuparuk sands have not been penetrated as stated below. Please respond if there are any questions. Jason Brink Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6419 Cell :907-748-4826 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Monday, October 15, 2007 10:03 AM To: Brink, Jason A Cc: Nordic 3 Company Man; Thomas, Randy L Subject: RE: 3N-14A PTD# 207-119 Jason, Thanks for the information and plan forward. Good luck with the operations. will place a copy of this message in the file. Nothing further is needed. Tom Maunder, PE AOGCC From: Brink, Jason A [mailto:Jason.Brink@conocophillips.com] Sent: Monday, October 15, 2007 9:58 AM To: Maunder, Thomas E (DOA) Cc: Nordic 3 Company Man; Thomas, Randy L Subject: 3N-14A PTD# 207-119 10/19/2007 3N-14A PTD# 207-119 Tom Page 2 of 2 Doyon 141 has 5-1/2" liner stuck at 7274' MD. This hole section was drilled to casing point at 7768' MD. Casing point is about 40' MD above the top of the Kuparuk C sand. The Kuparuk C was not penetrated. The plan is to cut 5-1/2" liner at 6835' MD and pull the same to surface. 5-1/2" liner front the cut down to the shoe at 7235' MD will be left in the hole. A 250' cement plug will be spotted above the cut and used for sidetrack kickoff. The interval will be re-drilled to 40' MD above the Kuparuk C sand. Jason Brink Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6419 Cell :907-748-4826 Fax :907-265-1535 10!19/2007 • • d o ~ ~ ~ SARAH PALIN, GOVERNOR ~ilt~~7~~ OI~ ~ ~ 333 W. 7dtAVENUE, SUITE 100 COIITSER~A1'IOrIT COMMISSIOI~T 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 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-14A ConocoPhillips Alaska, Inc. Permit No: 207-119 Surface Location: 1561' FSL, 80' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 657' FSL, 2195' FEL, SEC. 28, T13N, 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 (907) 659-3607 (pager). Sincerely, Dan T. Seamount Commissioner DATED this day of September, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.I.thomas~conocophillips.com August 23, 2007 Alaska Oil and Gas Conservation Commission 333 West 7~` Avenue Suite 100 Anchorage, Alaska 99501 (907)279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3N-14A Dear Commissioner: .~~~ ~.~ I ~ r ~ 9 2tlt~ l .sI ..,'a .~ ;.~?3 ~.t3f4:~,. ~ptT11'CtISSIa(I 4~~cii~r~ge ConocoPhillips Alaska, Inc. hereby applies for a Permit to DrilUSidetrack an onshore Producer well, KRU 3N-14A, a development well. It is planned to abandon the original wellbore with a CIPB set at +/- 3,575' MD and place a permanent whipstock on top of the CIBP with the whipstock at +/- 3,550' MD.' Sidetrack operations will then cut and mill a window in the existing 7" production casing with a planned KOP point from the 7" casing +/- 3,550' MD. = ' The existing 7.0" casing cement job from the original wellbore did not bring the top of cement up as high as the window. The current plan is to mill the window and perform aFIT /LOT. If the LOT is low, a squeeze cement job will be performed placing cement on top of the whipstock and in the milled window and a second FIT/LOT will be performed. After a successful FIT/LOT test, the intermediate section will be drilled with a 6" bi-center bit, opening up to 7", to intermediate 5- 1/2" casing point above the Kuparuk C sand at 7734' MD / 6242' TVD. The 5-1/2" casing shoe will be drilled out using 2- 7/8" DP and a 4-3/4" bit to TD @ 8386' MD / 6806' TVD. A 3-1/2" liner will be run and cemented across the Kuparuk C and A sands. The spud date is expected to be approximately October 13'i', 2007. If you have any questions or require any further information, please contact Jason Brink at 265-6419. Sincerely, Randy Thomas GKA Drilling Team Leader • STATE OF ALASKA ~ ~~~~~~ q•~•o'~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~\ ~~ ~ 2 g 20~,~ PERMIT TO DRILL 20 AAC 25.005 ~tlaska Oil & Gas Cans. Commission 1a. Type of Work: Drill ~ Re-drill Re-entry ^ .Current Well Class: Exploratory ^ Development Oil Q r Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is propo~(~Orage Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 3N-14A -~ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8386' ND: 6806' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1561' FSL, 80' FEL, Sec. 29, T13N, R9E, UM 7. Property Designation: ADL 25521, 25520 Kuparuk Oil Pool Top of Productive Horizon: 722' FSL, 2435' FEL, Sec. 28, T13N, R9E, UM S. Land Use Permit: ALK 2557, 2556 13. Approximate Spud Date: 10!13/2007 Total Depth: 657' FSL, 2195' FEL, Sec. 28, T13N, R9E, UM ' 9. Acres in Property: 2560 14. Distance to Nearest Property: > 1 mile ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 518321 ~ y- 6013799 - Zone- 4 10. KB Elevation (Height above GL): 62' AMSL ~ feet 15. Distance to Nearest Well within Pool: 3N-15 , 1571' ~ 8375' 16. Deviated wells: Kickoff depth: 3550 - ft. Maximum Hole Angle: 61.5° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4396 psig Surface: 3685 psig ~ 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 7" 26# J-55 BTC 3550' 110' 110' 3550' ~ 3550' ~ window 7" 5.5" 15.5# L-80 Hydril 511 4184' 3350' 3350' 7734' ~ 6242' - 70 sx LiteCRETE, 80 sx GasBLOK 4.75" 3.5" 9.3# L-80 Hydril 511 766' 7534' 6070' 8386' - 6806' ~ 70 sx GasBLOK w/ Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 7460' Total Depth ND (ft): 6687' Plugs (measured) none Effective Depth MD (ff): 6659' Effective Depth ND (ft): 6105' Junk (measured) 6615' Casing Length Size Cement Volume MD ND Conductor/Structural 80' 16" 238 sx CS II 110' 110' Surface 2537' 9.625" 1150 sx ASIII, 150 sx CI G, 2579' 2579' Intermediate 100 sx Class G Top job Production 7405' 7" 660 sx Class G, 175 sx AS I 7440' 6673' Liner Perforation Depth MD {ft): 7104', 7106', 7108', 7128'-7148', 7155', 7168'-7202' Perforation Depth ND (ft): 6429', 6431', 6432', 6447'-6461', 6466', 6476'-6500' 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program 0 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 Jason Brink @ 265-6419 Printed Name Randy Thomas Title Drilling Team Leader Signature ~ ~~,~__,~ Phone -Z-6 S 6~ jp Date ~/Z'3~~J7 h n All u Dr Commission Use Only Permit to Drill Number: ~~ ?'"~l~ API Number: 50- QZq- ~,~5~-- ~/ Permit Approval Date: ~ • a' • ~ 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 methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [v~ Other: H2S measures: Yes [r+~No ^ Directional svy req'd: Yes [f No ^ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revise7i 12/2005 ~! ~ ~ ~ % f ~~ ~ ~ ,~, Submit in Duplicate -`''~' ~`-''' ~ F• ~ a7 ~~ Application for Permit to Drill, Well 3N-14A Revision No.O Saved: 24-Aug-07 Permit It - Kuparuk We113N-14A Application for Permit to Drill Document y~~tt ys~~u~ 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.OOS(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 25.005(c)(8) ........................................................................................................ .4 9. Abnormally Pressured Formation Information ............................................................ 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ . 5 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 .................................. 7 ~t~~~7fl~E~-1~ 3N-14A PERMIT IT Page 1 of 6 • Application for Permit to Drill, Weil 3N-14A Revision No.O Saved: 24-Aug-07 Requirements of 20 AAC 25.005 (c)(14) ....................................................................................................... 7 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 25.005 (fl Each well must be identified by a unique nanse designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be iaentified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3N-14A. 2. Location Summary Requirements of 20 AAC 25.005(c) (2) 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: (2) a plat identifying 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 surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey an the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1561' FSL, 81' FEL, Sec. 29,. T13N, R9E, UM ' NGS Coordinates RKB Elevation 62.0' AMSL Northings: 6, 013, 799 Eastings: 518, 320 Pad Elevation 34.0' AMSL Location at Top of 722' FSL, 2435' FEL, Sec. 28, T13N, R9E, UM Productive Interval (Ku aruk A-4 Sand NGS Coordinates Measured Depth, RKB: 7,890' Northings: 6,012,968 Eastings: 521,250 Total Vertical Depth, RKB: 6,377' Total Vertical Depth, SS: 6,315' Location at Total De th 657' FSL, 2195' FEL, Sec. 28, T13N, R9E, UM ' NGS Coordinates Measured Depth, RKB: 8,386' Northings: 6,012,904 Eastings: 521,490 Total Vertical De th, RKB: 6,806' Total Vertical De th, SS: 6,744' and (D) other n~form~ation required by 20 AAC 2~.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, flue application for a Permit to Drill (Form 10-401) must (1) i~aclude a plat, draiv~z to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed ia~ellbore (A) list floe names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been fiu~nished a copy of the applicatio~z by certifred mail; or (B) state that the applicant is the only affected oia-net. The Applicant is the only affected owner. 0~ I61NAL 3N-14A PERMIT IT Page 2 of 6 C 3. Blowout Prevention Equipment Information Application for Permit to Drill, Well 3N-14A Revision No.O Saved: 24-Aug-07 Requirements of 20 AAC 25.005(c)(3) 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 idenhfted in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) 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) 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 ident~ed in the application: (4) information on drilling hazards, including (A) the maximum doi~~nhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; ~- i BHP data on 3N-14 motherbore indicates that the expected reservoir pressure for 3N-14A is 4,402 psi at 6,465' TVD. Equivalent Mud Weight @TD = 4402 psi =13.1 ppg 6465'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 3N-14A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6,465' TVD. MPSP = (GradientMud - Gradient~aS TVD GradientMud =13.lppg x 0.052 = 0.68 f t t Gradient~ps ~= 0.11 f t t TVD = 6465 ft MPSP = 0.68 pst - 0.11 pst 6465 ft = 3685psi ~ ft ft BJ data on potential gas .:ones; 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 st~~ata, lost circulation pones, and .ones 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)(5) fIn 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: (S) a description of the~procedure for conductingforneation i~ategrity tests, as required under 20 AAC 25.030(fl; ~~ ~~ 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 7" 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 identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner; pre perforated liner, or screen to be installed OR161NAL 3N-14A PERMIT IT Page 3 of 6 C~ Casin and Cementin Pro ram Application for Permit to Drill, Well 3N-14A Revision No.O Saved: 24-Aug-07 Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Pro am Ori final Wellbore 3N-14 10-3/4" 13-1/2 45.5 J-55 2,579' surface 2,579' / 2,579' 1150 sx ASIII & 150 sx Class G Top Job w/ 100 sx Class G 7" 8-1/2 26 J-55 BTC 7,440' surface 7,440' / 6,673' 660 sx Class G & 175 sx AS I Est TOC 5,280' MD 2-7/8" 6.5 J-55 EUE 6,929' surface 6,929' / 6,302' Tubing 8rd AB Mod 3N-14A Sidetrack Plan 7" window 26 J-55 BTC 3,550' surface 3,550' / 3,550' 70 sx 11.Oppg LiteCRETE, 3.30 5.5" flush jt 7" 15.5 L-80 H511i1 4,184' 3,350'./ 3,350' 7,734'/ 6,242' 3 0/sx 15.8 GasBLOK w/ Class G, 1.17 ft3/sk Hydril ' ' ' ' ' 70 sx 15.8 GasBLOCK w/ Class 3-1/2" flush jt 4.75" 9.3 L-80 511 766 7,534 / 6,070 / 6,806 8,386 G, 1.17 ft3/sk 7. Diverter System Information Requirements of 20 AAC 25.OOS(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on f le with the commission and identified in the application.• (7) R 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 25.035(h)(2); This rotary sidetrack will exit pre-existing casing at +/- 3,550' 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, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drillingfluid 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 3550' - 7734' 7734' - 8386' Density (ppg) 9.0 - 10.3 13.1 Yield Point (cP) 20 - 25 20 - 25 pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) 4 - 5 <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. 3N-14A PERMlT IT !` `f ~ Page 4 of 6 9. Abnormally Pressured Formation Information Application for Permit to Drill, Well 3N-14A Revision No.0 Saved: 24-Aug-07 Requirements of 20 AAC 25.005 (c)(9) 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 identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.0330; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) 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: (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, except for an item already on file with the commission and identified in the application: (1 t) for a well drilled from an offshore platform, mobile bottom 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 must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}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, except for an 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. Current well has large gravel fill inside the tubing string @ 6652' MD which coiled tubing has been unsuccessful in clean out attempts. Squeezing perforations with cement will be unsuccessful. 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. RU SL and pull DV at 6485'. Drift tubing. Leave pocket open. Circ well around to SW. 3. RU E-line. RIH and set 2 7/8" CIBP at 6630' MD. 4. Perform a CMIT. 5. Perforate tubing at 6600' with E-line. 6. RU CT and lay in balanced plug from 6550' to top of CIBP. Allow cement to enter backside for annular plug (4 bbls = 110') 7. Wait 24 hrs and PT. 8. RU E-line and cut tubing at 6300' (jet cutter). 9. Ensure well is dead. 10. Set BPV and VR plug. Current Wellhead: FMC Gen III, 11"x 3K, 7-1/16" x SK ~1 3N-14A PERMIT /T Page 5 of 6 • Rig Work: Application for Permit to Drill, Well 3N-14A Revision No.O Saved: 24-Aug-07 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. 5. Pu112-7/8" tubing. 6. Install 7" storm packer. ND BOP. 7. Break tubing head from casing head flange. Replace leaking packoffs. 8. Install tubing head and NU BOP on 7-1/16" SK flange. Test BOP to 5000 psi. *YJ1~ c~~g~c-~..` (~(,_~~- 9. PU mill, casing scraper, and 4" DP and RIH to top of tubing stub. POOH. 10. RU wireline set a CIBP inside the 7" casing at +/- 3,575' 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 7" casing and CIBP to 3000 psi and hold for 15 min. 11. 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 3,575' MD. 12. Orient whipstock, shear off, and POOH. 13. Displace Brine from hole with 9.6 ppg LSND new mud to mill window. Mill window and dri1120' new formation. Dress window. Pump super sweep pill. 14. Perform FIT/LOT. POOH and LD window mill etc. ~~~ ~~~ 5., PU bi-center bit & BHA, 4.0" DP, and RIH. ~~~ 16. Drill to casing point (7734' MD / 6242' TVD). MW expected to be 10.3 ppg. 17. PU 5.5" flush joint liner and RIH. Liner overlap into 7" casing needs to be +/- 200'. 18. Reciprocate the liner while circulating and cementing. R/U Dowell and cement the liner. 19. Release from liner. Set packer. 20. Pull and lay down 4" DP. Pick up 2-7/8" DP. Change out BOP rams and test to 5000 psi. 21. Weight up to 13.1 ppg LSND. 22. Pick up and run 4-3/4" bit, 3-1/8" BHA, and 2-7/8" DP. 23. Tag cement. Drill out and perform anFIT/LOT. 24. Dri114-3/4" Production hole to TD @ 8386' MD / 6806' TVD. ' 25. 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. 26. Release from liner. Set packer. ~s ~~~ DIAL 3N-14A PERMIT IT Page 6 of 6 • • Application for Permit to Drill, Well 3N-14A Revision No.O Saved: 24-Aug-07 27. Displace the well above the liner top with seawater until the returns are clean. Check for flow. POOH. LD/DP. 28. RU and RIH with 3-1/2" production tubing. Space out and land. RILD's. 29. Test tubing, PBR and liner to 2500 psi with the IA open for 15 minutes. Bleed the tubing down to 1500 psi. Test the IA, PBR and liner top to 2500 psi for 30 minutes (chart test). Bleed tubing pressure to zero psi. With tubing open, annulus pressure should shear dump kill valve (2000 psi casing to tubing shear). Bleed pressures to zero. 30. Install BPV and blanking plug. ND BOPE. NU and test the 3-1/8" SK tree to 5000 psi. 31. Pull the blanking plug and BPV. 32. Displace the well with diesel freeze protect fluid. 33. 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 "A" sand as directed. RD E-Line. ~ 6. Install new "S" riser. 7. Frac and flowback "A" sand producer. 8. Turn over to Production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit Io Drill music be accompanied by each of the following items, except for an item ab~eady on frle with the commission and identified in the application: (14) a general descripfion of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request aut7aori~ation under 20 A,4C 25.080 for an annular disposal operation in the well.; 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 ORIGINAL 3N-14A PERMIT IT Page 7 of 6 t nocoPhilli s Alaska, Inc • P CPAI Plan Report Company: __ ___ ConocoPhillips Alaska Inc. --- Date: 8/15/2007 Time: 10:07:34 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3N-14, True North Site: Kuparuk 3N Pad Vertical (TVD) Reference: 3N-14Awp03 62.0 R'ell: 3N-14 Section (VS) Reference: Well (O.OON,O.OOE,105.90Azi) R'ellpath: Plan: 3N-14A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 3N-14Awp05 Date Composed: 8/7/2007 KO below West Sak Version: 1 Principal: Yes Tied-to: From: Definitive Path Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 3N Pad Site Position: Northing: 6013799.17 ft Latitude: 70 26 55.957 N From: Map Easting: 517946.19 ft Longitude: 149 51 12.938 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.14 deg Well: 3N-14 Slot Name: Well Position: +N/-S -0.74 ft Northing: 6013799.33 ft Latitude: 70 26 55.949 N +E/-W 374.76 ft Easting : 518320.91 ft Longitude: 149 51 1.933 W Position Uncertainty: 0.00 ft Wellpath: Plan: 3N-14A Drilled From: 3N-14 500292158900 Tie-on Depth: 3550.00 ft Current Datum: 3N-14Awp03 Height 62.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/15/2001 Declination: 26.17 deg Field Strength: 57434 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 105.90 Survey Program for Definitive Wellpath Date: 8/7/2007 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information _-_ _ - M D In cl ft deg 3550. 00 0 .46 3562. 60 2 .38 3582. 60 2 .38 4905. 68 61 .50 6721. 71 61 .50 7622. 41 30 .00 7642. 41 30 .00 7890. 67 30 .00 7917. 23 30 .00 7959. 95 30 .00 8015. 38 30 .00 8386. 04 30 .00 :1zim deg TVD ft +N/-S ft +E/-1V ft 72. 59 3549. 81 9. 47 16. 02 72. 59 3562. 41 9. 56 16. 31 72. 59 3582. 39 9. 81 17. 11 106. 78 4657. 55 -165. 92 658. 79 106. 78 5524. 05 -626. 69 2186. 80 105. 00 6144. 68 -803. 73 2798. 74 105. 00 6162. 00 -806. 32 2808 .40 105. 00 6377. 00 -838. 44 2928. 30 105. 00 6400. 00 -841. 88 2941. 12 105. 00 6437. 00 -847. 41 2961. 76 105. 00 6485. 00 -854. 58 2988. 53 105. 00 6806. 00 -902 .55 3167 .54 DLS Build Turn deg/100ft deg/100ft deg/100ft 0.00 0.00 0.00 15.24 15.24 0.00 0.00 0.00 0.00 4.50 4.47 2.58 0.00 0.00 0.00 3.50 -3.50 -0.20 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ITO Target deg 0.00 0.00 0.00 34.95 0.00 -178.30 0.00 3N-14Awp03 T1 0.00 3N-14Awp03 TZ 0.00 3N-14Awp03 T3 0.00 3N-14Awp03 T4 0.00 3N-14Awp03 T5 0.00 3N-14Awp03 TD OR!r.~nlnl. 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M N -~ rZ N M dV' L ` 3 ~~ ~ ~ i I I I I i I I I I ~-~~ _ Nz II I C~ NOMOG _ M Z 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O ~ O~ O~ O~ 0 0 0 0 0 0 0 0 0 0 0 0 F' .. y ~ N V3 r O N~ [~ O~ O~ O O OO¢ 0 0 0 0 0 0 F ~ •--~ .-• •--~ •--~ N N M M ~ V: ~O SY 00 G1 O N ~ ~ 00 ^ ir> > y ~ ... .~ `o !/j L v e d / a+ O 0, . L'q C~. y ~ O e ~ o_ ..r .,.~ . ,, ~ / ~ m ~-~ O O 00 i~ i~~% ~.. `~ (~ O v, M `~ ~~~~ ~ ~ ~~~ GMT '~ '~ V F z o. E == d u O ~ / U ;y > CQ eo O Off. r O ~ 9 •~ r _ a ~~~" ~ ~ E ~ ~~ ~ ~\ _ __ `u e U M N e `> g g sa,8°~ a ~~B gE O ~ ~ z' ~ .°~°~ M N ~ ~ u Suy ~r ~~~~ .-~ ~ ~ a2 ~3u a~ "~a=~ M O O O~ N 0 0 ~ O O M ~ s ~~r=~~x °~°g3 ~ N ~ ~ S ~ ~ ~ M,~ M ~ N ~ u ~ f~~~~ cYp ~ oe~- -----~F ' M M u IIIIIIIIIIII ~OCOPh11Ii s Alaska, Inc. P CPAI Plan Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 3N Pad Fell: 3N-14 «'ellpath: PIan:3N-14A Sure c~ _.- 111D ft 2573.11 3550.00 3562.60 3582.60 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 4700.00 4800.00 4900.00 4905.68 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6721.71 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7439.87 7500.00 7566.80 7600.00 7622.41 7642.41 7695.52 7700.00 Date: 8/15/2007 Time: 10:07:34 Pa~c: 2 Co-ordinatc(NE) Keference: Well: 3N-14, True North Vertical (TVD) Reference: 3N-14Awp03 62.0 Section (VS) Reference: WeII (O.OON,O.OOE,105.90Azi) Surve~~ Calculation Method: Minimum Curvature Dh: Oracle Incl Azim TVD Svs TVD 5/S E/W deg deg ft ft ft ft 1.08 61.35 2573.00 2511.00 4.98 5.20 0.46 72.59 3549.81 3487.81 9.47 16.02 2.38 72.59 3562.41 3500.41 9.56 16.31 2.38 72.59 3582.39 3520.39 9.81 17.11 3.06 81.03 3599.77 3537.77 9.99 17.91 7.36 96.90 3699.34 3637.34 9.64 26.91 11.81 100.98 3797.92 3735.92 6.92 43.33 16.29 102.85 3894.90 3832.90 1.85 67.07 20.78 103.92 3989.69 3927.69 -5.54 97.98 25.27 104.63 4081.70 4019.70 -15.21 135.87 29.76 105.13 4170.37 4108.37 -27.08 180.51 34.26 105.52 4255.14 4193.14 -41.10 231.62 38.76 105.82 4335.49 4273.49 -57.18 288.88 43.25 106.07 4410.94 4348.94 -75.20 351.95 47.75 106.28 4481.01 4419.01 -95.07 420.44 52.25 106.47 4545.27 4483.27 -116.67 493.91 56.75 106.63 4603.33 4541.33 -139.85 571.93 61.25 106.77 4654.82 4592.82 -164.48 654.01 61.50 106.78 4657.55 4595.55 -165.92 658.79 61.50 106.78 4702.55 4640.55 -189.85 738.14 61.50 106.78 4750.26 4688.26 -215.22 822.28 61.50 106.78 4797.98 4735.98 -240.59 906.42 61.50 106.78 4845.69 4783.69 -265.97 990.56 61.50 106.78 4893.41 4831.41 -291.34 1074.70 61.50 106.78 4941.12 4879.12 -316.71 1158.84 61.50 106.78 4988.83 4926.83 -342.08 1242.98 61.50 106.78 5036.55 4974.55 -367.46 1327.12 61.50 106.78 5084.26 5022.26 -392.83 1411.27 61.50 106.78 5131.98 5069.98 -418.20 1495.41 61.50 106.78 5179.69 5117.69 -443.58 1579.55 61.50 106.78 5227.41 5165.41 -468.95 1663.69 61.50 106.78 5275.12 5213.12 -494.32 1747.83 61.50 106.78 5322,83 5260.83 -519.69 1831.97 61.50 106.78 5370.55 5308.55 -545.07 1916.11 61.50 106.78 5418,26 5356.26 -570.44 2000.25 61.50 106.78 5465.98 5403.98 -595.81 2084.39 61.50 106.78 5513.69 5451.69 -621.19 2168.53 61.50 106.78 5524.05 5462.05 -626.69 2186.80 58.76 106.69 5563.03 5501.03 -646.24 2251.80 55.26 106.56 5617.47 5555.47 -670.23 2332.17 51.77 106.41 5676.92 5614.92 -693,04 2409.25 48.27 106.26 5741.17 5679.17 -714.59 2482.77 44.77 106.08 5809.97 5747.97 -734.80 2552.44 41.27 105.89 5883.07 5821.07 -753,59 2618.02 37.78 105.66 5960.19 5898.19 -770.90 2679.25 36.38 105.56 5992.00 5930.00 -777.37 2702.40 34.28 105.40 6041.05 5979.05 -786.65 2735.91 31.94 105.19 6097.00 6035.00 -796.27 2771.11 30.78 105.08 6125.35 6063.35 -800.79 2787.79 30.00 105.00 6144.68 6082.68 -803.73 2798.74 30.00 105.00 6162.00 6100.00 -806.32 2808.40 30.00 105.00 6208.00 6146.00 -813.19 2834.05 30.00 105.00 6211.88 6149.88 -813.77 2836.21 MapN Iti1apE DI,S FE''O Commcn ft ft deg/100ft deg 6013804.32 518326. 10 0.00 _ 0.00 -- -- 9 5/8" x 12 1/4" 6013808.84 518336. 90 0.06 171.76 7" x 8 1/2" 6013808.93 518337. 20 15.24 0.00 6013809.18 518337. 99 0.00 0.00 6013809.37 518338. 79 4.50 34.95 6013809.03 518347. 80 4.50 26.52 6013806.35 518364. 22 4.50 10.71 6013801.34 518387. 97 4.50 6.68 6013794.03 518418. 89 4.50 4.87 6013784.46 518456. 80 4.50 3.85 6013772.69 518501. 46 4.50 3.20 6013758.80 518552. 60 4.50 2.75 6013742.87 518609. 90 4.50 2.43 6013725.00 518673. 01 4.50 2.18 6013705.30 518741. 54 4.50 1.99 6013683.89 518815. 06 4.50 1.84 6013660.90 518893. 13 4.50 1.73 6013636.48 518975. 26 4.50 1.63 6013635.05 518980. 04 4.50 1.56 6013611.32 519059. 44 0.00 0.00 6013586.15 519143. 64 0.00 0.00 6013560.99 519227. 83 0.00 0.00 6013535.83 519312. 03 0.00 0.00 6013510.66 519396. 22 0.00 0.00 6013485.50 519480. 41 0.00 0.00 6013460.34 519564. 61 0.00 0.00 6013435.17 519648. 80 0.00 0.00 6013410.01 519733. 00 0.00 0.00 6013384.85 519817. 19 0.00 0.00 6013359.68 519901. 38 0.00 0.00 6013334.52 519985. 58 0.00 0.00 6013309.36 520069. 77 0.00 0.00 6013284.19 520153. 97 0.00 0.00 6013259.03 520238. 16 0.00 0.00 6013233.87 520322. 35 0.00 0.00 6013208.70 520406. 55 0.00 0.00 6013183.54 520490. 74 0.00 0.00 6013178.08 520509. 02 0.00 0.00 6013158.69 520574. 07 3.50 181.70 6013134.90 520654 .48 3.50 181.75 6013112.28 520731. 62 3.50 181.82 6013090.91 520805. 18 3.50 181.91 6013070.88 520874 .90 3.50 182.01 6013052.25 520940 .52 3.50 182.13 6013035.10 521001 .78 3.50 182.27 6013028.69 521024 .95 3.50 182.44 upper_kalubik 6013019.49 521058 .48 3.50 182.52 6013009.95 521093 .69 3.50 182.66 lower_kalubik 6013005.48 521110 .38 3.50 182.83 6013002.56 521121 .34 3.50 182.93 6013000.00 521131 .00 0.00 0.00 3N-14Awp03 T1 6012993.19 521156 .67 0.00 0.00 d/top kuparuk 6012992.62 521158 .83 0.00 0.00 ~~~~_ ~ocoPhillips Alaska, Inc. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 8/15/2007 Time: 10:07:34 Page: 3 Field: Kuparuk River Unit Co-ord inate(NF,) Reference: Well: 3 N-14, True North Site: Kuparuk 3N Pad Vertica l (TVD) Reference: 3N-14Awp03 62.0 Fell: 3N-14 Section (VS) Reference: Well (O .OON,O.OOE,105.90Azi) VVellpath: Plan: 3N-14A Survey Calculation Vfethod: Minimu m Curvature Db: Oracle Sw~'c~ _ _ ~~ID Incl... ---, Azim _- TVD Svs'~VD __ N/5 E/~V p _ p I11a N Via E ULS TFO Comment ft deg deg ft ft ft ft ft ft deg/100ft deg _ __ 7734.78 30.00 105.00 __ - 6242.00 6180.00 _ -818.27 2853.01 6012988.16 521175.64 0.00 0.00 5 1/2" x 6 1/8" 7770.58 30.00 105.00 6273.00 6211.00 -822.90 2870.30 6012983.57 521192.94 0.00 0.00 C 7800.00 30.00 105.00 6298.48 6236.48 -826.71 2884.51 6012979.79 521207.15 0.00 0.00 7815.61 30.00 105.00 6312.00 6250.00 -828.73 2892.05 6012977.79 521214.70 0.00 0.00 B 7881.43 30.00 105.00 6369.00 6307.00 -837.25 2923.84 6012969.35 521246.50 0.00 0.00 A6 7882.59 30.00 105.00 6370.00 6308.00 -837.40 2924.39 6012969.21 521247.06 0.00 0.00 A5 7890.67 30.00 105.00 6377.00 6315.00 -838.44 2928.30 6012968.17 521250.97 0.00 0.00 3N-14Awp03 T2 7900.00 30.00 105.00 6385.08 6323.08 -839.65 2932.80 6012966.97 521255.48 0.00 0.00 7917.23 30.00 105.00 6400.00 6338.00 -841.88 2941.12 6012964.77 521263.80 0.00 0.00 3N-14Awp03 T3 7959.95 30.00 105.00 6437.00 6375.00 -847.41 2961.76 6012959.29 521284.45 0.00 0.00 . 3N-14Awp03 T4 8000.00 30.00 105.00 6471.68 6409.68 -852.59 2981.10 6012954.15 521303.80 0.00 0.00 8014.22 30.00 105.00 6484.00 6422.00 -854.43 2987.97 6012952.33 521310.67 0.00 0.00 Miluveach 8015.38 30.00 105.00 6485.00 6423.00 -854.58 2988.53 6012952.18 521311.23 0.00 0.00 3N-14Awp03 T5 8100.00 30.00 105.00 6558.29 6496.29 -865.53 3029.40 6012941.33 521352.12 0.00 0.00 8200.00 30.00 105.00 6644.89 6582.89 -878.47 3077.69 6012928.51 521400.45 0.00 0.00 8300.00 30.00 105.00 6731.49 6669.49 -891.42 3125.99 6012915.69 521448.77 0.00 0.00 8386.04 30.00 105.00 6806.00 6744.00 -902.55 3167.54 6012904.66 521490.34 0.00 0.00 3N-14Awp03 TD Targets - - __ ___ Map Map <--- - Latitude ----> <--- Longitude ---> V~ame Description TVD +N/-S +L/-~V Sorthing Casting Deg Dtin Sec Ueg Min Sec Dip. llir. ft ft ft ft ft 3N-14Awp03 T1 6162.00 -806.32 2808.40 6013000.00 521131.00 70 26 48.014 N 149 49 39.471 W -Circle (Radius: 150) -Plan hit target ` 3N-14Awp03 T2 6377.00 -846.67 2952.31 6012960.00 521275.00 70 26 47.617 N 149 49 35.246 W -Circle (Radius: 150) -Plan out by 25.39 at 6377.00 -838.44 2928.30 6012968.17 521250.97 70 26 47.698 N 149 49 35.951 W 3N-14Awp03 T3 6400.00 -850.71 2965.30 6012956.00 521288.00 70 26 47.577 N 149 49 34.864 W -Circle (Radios: 150) -Plan out by 25.74 at 6400.00 -841.88 2941.12 6012964.77 521263.80 70 26 47.664 N 149 49 35.574 W 3N-14Awp03 T4 6437.00 -855.76 2986.29 6012951.00 521309.00 70 26 47.527 N 149 49 34.248 W -Circle (Radius: 150) -Plan out by 25.92 at 6437.00 -847.41 2961.76 6012959.29 521284.45 70 26 47.609 N 149 49 34.968 W 3N-14Awp03 T5 6485.00 -862.83 3014.28 6012944.00 521337.00 70 26 47.457 N 149 49 33.426 W -Plan out by 27.04 at 6485.00 -854.58 2988.53 6012952.18 521311.23 70 26 47.539 N 149 49 34.182 W 3N-14Awp03 TD 6806.00 -910.29 3199.18 6012897.00 521522.00 70 26 46.990 N 149 49 27.998 W -Circle (Radius: 150) -Plan out by 32.57 at 6806.00 -902.55 3167.54 6012904.66 521490.34 70 26 47.066 N 149 49 28.927 W Annotation ~- Vfll TVD ft ft 3550.00 3549.81 KOP Casing Points MD "['VU I)iamctc r Ilole Size Aame ft ft in in 2573.11 2573.00 9.625 12.250 9 5/8" x 12 1 /4" 3550.00 3549.81 7.000 8.500 7" x 8 1/2" 7734.78 6242.00 5.500 6.125 5 1/2" x 6 1/8" 8386.04 6806.00 3.500 4.750 3 112" x 4 3/4" ,"IGINAL OCOPhllli s Alaska Inc. P CPAI Plan Report Company: ConocoPhillips Alaska inc. Date: 8!15/2007 _ - -- Time: 10:07:34 Page: ~ Field: Kuparuk River Unit Co-ordinate(NF.) Reference: Well: 3N-14, True North Site: Kuparuk 3N Pad Vertical ('TVD) Reference: 3N-14Awp03 62.0 Nell: 3N-14 Section (VS) Reference: Well (O.OON,O.OOE,105.90Azi) N'ellpath: Plan: 3N-14A Survey Calculation ~'[ethod: Minimum Curvature Db: Oracle Formations NID TVD ft ft 0.00 0.00 0.00 0.00 7439.87 5992.00 7566.80 6097.00 7695.52 6208.00 7734.78 6242.00 7770.58 6273.00 7815.61 6312.00 7881.43 6369.00 7882.59 6370.00 7890.67 6377.00 7890.67 6377.00 7917.23 6400.00 7959.95 6437.00 8014.22 6484.00 Formations Permafrost Top Ugnu C Top West Sak D base west sak upper_kalubik lower_kalubik d/top kuparuk topset point in D shale C B A6 A5 A4 A3 A2 Al Miluveach I,ithology Dip Angle Dip Direction deg deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 OR161NAL ~OCOPhllli s Alaska, Inc. P Anticollision Report Company: ConocoPhillips Alaska Inc. Datr. 8/7/2007 "Time: 11:2454 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 3N P ad Co-ordinate(~~1~,) Reference: Well: 3N- 14, True No rth Reference Wcll: 3N-14 Vertical (TY ll) Reference: 3N-14Awp03 62.0 Reference ~A'ellpaUr Plan: 3N-14A llh: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 3N-14Awp05 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 3550.00 to 8386.04 ft Scan Method: Trav Cylinder North Maximum Radius: 1035.80 ft Error Surface: Ellipse + Casing Casing Points __ AID 'I'Vll Diameter Hole Size Name ft ft in in 2573.11 2573.00 9.625 12.250 9 5/8" x 12 1 /4" 3550.00 3549.81 7.000 8.500 7" x 8 1/2" 7734.78 6242.00 5.500 6.125 5 1/2" x 6 1/8" 8386.04 6806.00 3.500 4.750 3 1/2" x 4 3/4" Plan: 3N-14Awp05 Date Composed: 8/7/2007 KO below West Sak Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary <___ _______________ Offset Wellpath ---- -------------> Reference Offset C tr-Ch' \o-Go Allowable Site Well Wellpath AID A1D D~stancc Area Deviation Warning ft ft ft ft ft Kuparuk 3N Pad 3N-05 3N-05 V1 3552.27 3725.00 868.77 57.58 811.19 Pass: Major Risk Kuparuk 3N Pad 3N-06 3N-06 V1 3554.98 3675.00 590.87 62.15 528.72 Pass: Major Risk Kuparuk 3N Pad 3N-07 3N-07 V1 3567.38 3625.00 325.00 53.20 271.80 Pass: Major Risk Kuparuk 3N Pad 3N-08 3N-08 V8 3560.88 3575.00 152.87 54.55 98.32 Pass: Major Risk Kuparuk 3N Pad 3N-08 3N-08A V4 3560.88 3575.00 152.87 54.55 98.32 Pass: Major Risk Kuparuk 3N Pad 3N-13 3N-13 V1. 3564.35 3675.00 439.17 56.09 , 383.07 Pass: Major Risk, Kuparuk 3N Pad 3N-14 3N-14 V1 3568.99 3575.00 0.44 47.00 -46.56 FAIL: Major Risk Kuparuk 3N Pad 3N-15 3N-15 V1 Out of range Kuparuk 3N Pad 3N-19 3N-19 PB1 V12 5911.20 3575.00 412.35 66.02 346.32 Pass: Major Risk Kuparuk 3N Pad 3N-19 3N-19 V4 5911.20 3575.00 412.35 65.91 346.43 Pass: Major Risk Site: Kuparuk 3N Pad Well: 3N-05 Rule Assigned: Major Risk Wellpath: 3N-05 V1 Inter-Sit e Error: 0.00 ft Reference Offs et Semi-VlajorAxis Ctr-Ctr No-Go Allowable 11ID TVD b1D TVD Ref Offset TF(}+A ZI TFO-HS Casing/H~Distance Area Deviation AA'arning ft ft ft ft ft ft deg deg in ft ft ft 3552.27 3552.08 3725.00 3569.08 2.10 7.51 264.32 191.73 868.77 57.58 811.19 Pass 3557.90 3557.71 3750.00 3587.94 2.11 7.55 264.24 191.65 885.53 57.58 827.95 Pass 3565.28 3565.09 3775.00 3606.85 2.11 7.58 264.15 191.56 902.50 57.45 845.04 Pass 3583.17 3582.97 3800.00 3625.81 2.11 7.62 264.07 191.13 919.51 57.64 861.87 Pass 3594.08 3593.86 3825.00 3644.77 2.11 7.68 264.00 185.39 936.62 57.77 878.84 Pass 3600.00 3599.77 3850.00 3663.67 2.11 7.75 263.94 182.90 953.94 57.88 896.05 Pass 3615.33 3615.08 3875.00 3682.52 2.12 7.81 263.88 178.06 971.41 58.02 913.39 Pass 3625.68 3625.40 3900.00 3701.32 2.12 7.88 263.83 175.60 989.10 58.14 930.96 Pass 3635.83 3635.52 3925.00 3720.05 2.12 8.03 263.78 173.65 1006.99 58.41 948.58 Pass 3645.77 3645.43 3950.00 3738.68 2.12 8.18 263.74 172.07 1025.11 58.69 966.43 Pass Site: Kuparuk 3N Pad Well: 3N-06 Rule Assigned: Major Risk Wellpath: 3N-06 V1 Inter-Site Error: 0.00 ft - _ - __ Reference Offset Semi-Major Axis Ctr-Ctr \o-Go Allowable A1D TVD VID TVD Ref Offset '1'PO+A71 "IFO-HS Casing_/HSDistance Area Deviation AA'arning ft ft ft ft ft ft deg deg in ft ft ft 3554.98 3554.79 3675.00 3569.86 2.10 8.69 215.70 143.11 590.87 62.15 528.72 Pass 3565.23 3565.03 3700.00 3590.01 2.11 8.83 215.16 142.57 604.90 62.30 542.60 Pass 3584.69 3584.48 3725.00 3610.08 2.11 8.97 214.65 140.80 619.19 62.75 556.44 Pass 3601.96 3601.73 3750.00 3630.12 2.11 9.11 214.17 132.42 633.61 63.15 570.46 Pass 3619.20 3618.94 3775.00 3650.10 2.12 9.25 213.74 126.95 648.20 63.56 584.64 Pass 3636.42 3636.11 3800.00 3670.05 2.12 9.38 213.35 123.12 662.94 63.96 598.97 Pass 3653.54 3653.16 3825.00 3689.87 2.12 9.52 212.98 120.28 677.90 64.37 613.53 Pass SRAM OR161NAL • • 3N-14A Drilling Hazards 6-1/8" Hole Event Risk Level Miti ation 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 properties in line with mud rogram. 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 ation 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 Moderate 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. `~..$ 6 ~ ~ l~ ! l~ ~3N-14A 070609 Window 7 inch Topset Plan Schematic 3N-14A SIDETRACK TOPSET COMPLETION wp05 Circulate corrosion inhibitor before landing tubing hanger. Inhibit corrosion up to bottom Original completion RKB 68' Doyon Rig 9 GLM. 10-3/4" x 7" annulus arctic packed 5!1986 w/ 29 bbls cmt & 60 bbls diesel. Est TOC 1235' MD. 10-3/4" 45.5# K-55 BTC casing Set @ 2579' MD / 2579' ND (Original LO7 11.5 ppg EMV~ 5.5" X 7" Liner Top TO BE @ 3350' MD / 3350' TVI Sidetrack KOP w/ window in 7" @ 3550' MD / 3550' TVD Whipstock Orientation to be XX degrees from high side Baker "K-1" CIBP below set point for whipstock @ +/- 3575' MD 2-7/8" tbg cut and pulled from +/- xxxx' above the packer. To of cmt P&A plug @ XXXX'. 2-7/8" SSSV Cad 1790' MD! TOC est. 5882' MD PKR 6859' MD Original Wellbore 7.0" csg 26.0# J-55 @ 7440' MD lonocoPhiltips 3'/z" FMC Gen 3 Tubing Hanger, 3'/z' L-80 IBT Mod pin down 3'/z" 9.3# L-80 IBT Mod Spaceout Pups as Required 3'/~' 9.3# L-80 IBT Mod Tubing 3'/2' Camco SCSSSV TRMAXX-5E with 2.812 Profile Nipple Bore set at +/- 2000' MD/ 2000' ND 3'/2' x 6' L-80 handling pups installed above and below, IBT Mod 3'/z' 9.3# L-80 IBT Mod tubing 3'/2' x 1"Camco'KBG-2- 9' mandrels 3'/s" x 6' L-80 handling pups installed above and below, IBT Mod 3'/2' x 1" Camco'KBG-2- 9' mandrel w/ shear valve, pinned for 2000 psi shear (casing to tubing differential), 3 Yz' x 6' L-80 handling pups installed above and below, IBT Mod GLM # ND-RKB MD-RKB 1 x x 2 x x ~ x x 4 x x ~ points above nipple profile 3'/s" Camco'D' nipple w/ 2.75" No-Go profile TWO joints above seal assembly. 3'/i' x 6' L-80 IBT Mod spaceout pup installed above, 3'/s" x 6' handling pup installed below 5-'/~" liner Assembly: 5-1/2" 15.5# Hydril 511 Liner @ 7642' MD / 6162' ND 3-'/~" liner Assembly: 3-1/2" 9.3# Hydril 511 Liner @ 8386' MD / 6806' ND Topset Point: 5-1/2" 15.5# Hydril 511 Liner 7734' MD / 6242' ND 5-'/=" Centrilization: 5-19/32" x 6-1/8" rigid stand off band between stop collars 1 per joint TD: 3-1 /2" 9.3# Hydril 511 Liner @ 8386' MD / 6806' ND - 3'/:" Centrilization: Formation TVD SS ft TVD MD fl RKB=62 Permafrost 1658 1720 1720.02 To U nu C 2512 2574 2574.11 To West Sak D 3070 3132 3132,17 base west sak 3475 3537 3537.18 To HRZ 5,820 7,300 5,883 u er kalubik 5930 5992 7439.87 lower kalubik 6035 6097 7566.8 dlto ku aruk 6146 6208 7695.52 to set pint in D shale 6180 6242 7734.78 C 6211 6273 7770.58 B 6250 6312 7815.61 q6 6307 6369 7881.43 AS 6308 6370 7882.59 A4 6315 6377 7890.67 q3 6315 6377 7890.67 A2 6338 6400 7917.23 A7 6375 6437 7959.95 Miluveach 6422 6484 8014.22 TD 6669 6731 8300 LWD Loaaina: 6- 1/8" hole: GR/RES 4- 3/4" hole: GR/RES BHP Est.: 13.09 ppg EMW @ 6465' ND / 7980' MD 4402 PSI on 6/11/07 JAB 8/9/07 ORIGINAL i~ i CemCADE Preliminary Job Design Schlamherger 5 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 8/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < Liner Top at 3,350' MD Previous Csg. 7", 26.0# casing at 3,550' MD < Top of Lead at 5,734' MD < Top of Tail at 7,234' MD < 5 1/2", 15.5# casing in 7" OH TD at 7,734' MD (6,242' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 4.5"- 20.0# drill string. Cement job is designed to bring cement 2000' above casing shoe. The max ECDs for this job is expected to be 12.5 ppg. Lead Slurry Minimum thickening time: 150 min. (pump time plus 120 min.) LiteCRETE @ 11.0 ppg - 3.30 ft3/sk Annular Volume: 0.1023 ft3/ft x (1500') x 1.50 (50% excess) = 230.2 ft3 Totals: 230.2 ft3 = 230.2 ft3 230.2 ft3/ 3.3ft3/sk = 69.8 sks Round up to 70 sks Tail Slurry Minimum thickening time: 150 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1% 6155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk Annular Volume: 0.1023 ft3/ft x (500') x 1.50 (50% excess) = 76.7 ft3 Shoe Volume: 0.1336 ft3/ft x 80' x 1.00 (no excess) = 10.7 ft3 Totals: 3 3+ft3= ~~~rt ~C7.1 -~ 87.4ft 76 1¢7~Ft~'/sk = ~~ ~„~ ~ ~T74.7 sks ound up to 80 sks /1 ai"1 BHST = 129, Estimated BHCT = 112. ~'"'1^'~~~"S (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 15 3.0 3.0 Start Pumping Wash MudPUSH II 6 15 2.5 5.5 Start Pumping Spacer Lead Slurry 6 41 6.8 12.3 Tail Slurry 6 17 2.8 15.1 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 18.1 Displacement 6 131 21.8 39.9 Start Displacement Slow Rate 4.5 15 3.3 43.2 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ~ 19-22, TY = 22-29 Centralizers: Recommend 2 per joint from Previous Casing to TD. OR161NAL i~ i CemCADE Prelimina Job Design Schlumberger 3 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 8/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 7,334' MD < Liner Top at 7,534' MD Previous Csg. 5 1/2", 15.5# casing at 7,734' MD < 3 1/2", 9.3# casing in 4 1/2" OH TD at 8,386' MD (8,802' TVD) R Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 2.9"- 10.4# drill string. Cementjob is designed to seal off liner top by bringing cement 200' above liner top, with 15.8 ppg G cement (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 15.7 ppg. Tail Slurry Minimum thickening time: 130 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 200' x 1.00 (no excess) = 17.7 ft3 Liner Lap: 0.0668 ft3/ft x (7734' - 7534') x 1.00- (no excess) = 13.4 ft3 Annular Volume: 0.0436 ft3/ft x (8386' - 7734') x 1.50 (50% excess) = 42.6 ft3 Shoe Volume: 0.0488 ft3/ft x 80' x 1.00 (no excess) = 4.4 ft3 Totals: 17.7 ft3+13.4ft3+42.6ft3+4.4ft3= 78.1 ft3 78.1 ft3/ 1.17 ft3/sk = 66.8 sks Round up to 70 sks BHST = 142, Estimated BHCT = 130. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Volume Time Stage (bpm) (bbl) (min) (min) Comments MudPUSH II 5 15 3.0 3.0 Start Pumping Spacer Tail Slurry 5 15 3.0 6.0 .Mix and Pump Tail Slurry Drop Wiper Dart 3.0 9.0 Displacement 6 31 5.2 14.2 Start Displacement Displacement 3 10 3.3 17.5 Slow to Bump MUD REMOVAL Recommended Mud Properties: 13.1 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 14.5 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint from Previous Casing to TD. ''RIGINAL ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad n: 1/4 Mile Pool Scan S erry . Tilling Services August 27, 2007 ~Iw.:: ~ .a...... ... ~' i~~Y~<ra«r «~.u~{Y~..~• R ill 117 - ««..i r« .. ~'..>.. .. ~l.~w HALL1 IJRON Drllling and Formation Evaluation • Closest in POOL '''''~gg''~~/ ./OJ Closest A roach: Reference Well: 3N-14A w 05 Plan ~i:f~~~ ~~3t; m ' J Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) vew VS Meas. Subsea N(+)/S(-) Vew VS Distance. De th Ind. An le TRUE Azi. TVD E + /W _ 105.9° Comments De th Ind. An le TRUE Azi, TVD E + NN - 105.9° Comments in istance (1570.7 ft) in POOL (6644 - 6744.03 POOL Min Distance (1570.7 ft) in ~ TVDss) to 3N-15 POOL (6644 - 6744.03 TVDss) to (6545 - 6645.48 3N-14A (wp05) Plan (6545 - 157~." 8386.04 30 105 6744.03 6012904.5 521490.7 3293.639 TVDss) 8375 39.21 79.05 6542.48 6013571.8 522898.2 4443.06 6645.48 TVDss) Closest A roach: Reference Well: 3N-14A w 05 Plan Offset ell: SN -16 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) Yew VS Meas, Subsea N(+)/S(-) vew VS Distance. De th Ind. An le TRUE Azi. TVD E + M/ _ 105,9° Comments De th Ind. An le TRUE Azi. TVD E + /W _ 105.9° Comments in is nce (2577.14 ft) in POOL (6644 - 6744.03 POOL Min Distance (2577.14 ft) in TVDss) to 3N-16 POOL (6644 - 6744.03 TVDss) to (6691 - 6791.22 3N-14A (wp05) Plan (6691 - 2577.74 8386.04 30 105 6744.03 6012904.5 521490.7 3293.639 TVDss) 9100 37.1 115.55 6676.37 6010869 523069.9 5366.36 6791.22 TVDss) • ~ ~ POOL Summary.~ds 8/27/2007 11:02 AM r -1? ~~1 Plan: 3N-14A (~vp05} (3N-1~IPlan: 3N-1~:~} 1 • ~:4~ V r N-19 PB1, 3N-1~ tWP45~ ~'1 •19 PBl, 3N-19 PB1 ~'1Z --~ 3N-16, 3N-16, 3N-16 t'1 i "-"' 9 d l ~ I}y.. _ F ~ ~ .~ LEI FS ~\ 3N-15.3N-1 i. 3N-15 4F1 Alaska Department of Natural Resources Land Administration System Page 1 of 2 • • ~ ..,;.~ ~ -;r . ,~ ,,t;,i;, E~~~ .:,~,;'v Searc;3 State Catains 1~1~#il~~ 1~D~11'~S Alaska aNR Case Summary File Type: A~~. __ File Number: 25520 ~ ~ Printable Case F.l.e._Surrtmary See Township, Range, Section and Acreage? ~` Yes ~"` No J~New Search !_A~ !Uenu I Case Abstract I Case Detail I rand Abstract ~~. File: AUL 2520 '~~~'- Search for Status Piat Updates ~s c,f 0'29; 200 Custoiri~r: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER POBOX 100360 ANCHORAGE AK 995100360 Case Type: 7~3~ OIL & GAS LEASE COMP DNR Unit.• 780 OIL AND GAS File Location: DOG DIV a1L ANDGAS Case Status: 35 ISSUED Status Date: 01/25/1965 Total Acres: 2560.000 Date Initiated: 11/02/1964 Office of Primaf~y Res~onsibiliry: DOG DIV OIL AND GAS Last T~af7saction Date: 12/0712005 Ccxse Subtype: ~S NORTH SLOPE Last Trarisactio~a: DR DOCUMENT RECORDED ,11~~rhlrun: l_! 7~~tirn.tihip: 013N Rari,~~c.~ 009E :Cecliuj7: 27 .S'E~c7rnn Acres' 640 Search flats '1~1C/'lt~[a31: ~~ IOl1'17.C{71jJ.' OIiN Ru/l,~r: ~)O~)!. ,~eC~/Ui7: ~~ ~~~C'CIlU11ACrc',~~: 6=11) :~IL'Ylc~lclJl.' O l(>}I~~1S'~1L~)' ~))_i~] ~L7)7~rC': U~)91", SeC/ll)Jl: ii .~~eCIlUiI_`~CYE',4: ~~~~) ;llc~ri~lrun.~ l1 7olvnship: O1 ,N Raj~~~e: 009E ,Sc~~linn: ~~ S'ectiuri :~lc~res: 6~0 Lel;al Description 11-02-196-~ * * * SALE NOTICE LEGAL DESCRIPTION U-3-1-17 ALI SECTION 27, T13N, R9E, UM 6~0 ALL SECTION 28, " " " 6~0 ALL SECTION 33. " " " 610 ALL SECTION 3-~, " " " 6~0 CUNT 4INING 2, ~ 60 ACRES, MORE OR LESS. End ~ Cast sc~imir»~r~ http://www.dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=25 520&... 8/29/2007 Alaska Department of Natural Resources Land Administration System Page 1 of 2 • • v ~ ~ (.:~ •;,~;- ,r : ,~ ~ , . F~~_fs: i=~~arde~`s search State Cabins ~Ii~ 3~41f"GES ~-_.__-.... ~~aa N t11t11ar File Type ADL File Number: 25521 ~ Printable Case File._Summary. See Township, Range, Section and Acreage? C!` Yes No New Searchy~ LA5 MenE~ i Case Abstract i Case Detail i Land Abstract Prle: ADL 25521 ~''''`'~''~~ Search for Status Plat Updates -1~ of0~?9;2007 Customer: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Corse Type: OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Staters: 35 ISSUED Status Date: 01/25/1965 Total Acres: 2555.000 Date Initiated: 11 /02/1964 Office of Primary Responsibility : DOG DIV OIL AND GAS Last Transaction Date: 12/07/2005 Case. Subtype : 3~S NORTH SLOPE Last Transaction: DR DOCUMENT RECORDED ;Ll~ridiun.~ l~ To~t~r~sltij~: 013N Range: 009E :S'~~cliurr: ~'9 .S'~~ctinnAcr<~s°°: 6=~0 Search Plats .l~IC/'[dlail: ~~ T011'11,1~~71~7: ~)iiN RUllr;c': 009E ~5('CllOit: i0 ,SLCIi(>77,'~CY~'.S': ~)3~? a1ClT'1c11[rll.' ~_~ Ti)li'i1.S~71j7: ~~i_iN J'iCJrt~~~: ~)~)9F ~SCChp/1.~ ? ~ ~S~:C'/IIi71 ~I~'PC'.1': ~)i9 IIcJ'Idl[U1.' ~~ ~(lU'f1.Pj11~): ~~iiN ~aY1~iE': ~)~)9E ~SNCfIU{l.~ _~~ .~EChU11.~Cr2S: ~~Q Legal Uescrii~tion 11-02-1964 * * * SALE NOTICE L EGAL DESCRIPTION TRACT NU. U-3-1-18 T13N., R9E., UM SECTION 29: ALL 640 ACRES SECTION 30: ALL 636 ACRES SECTION 31: ALL 639 ACRES SECTION 32: ALL 640 ACRES http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=25521 &... 8/29/2007 Alaska Department of Natural Resources Land Administration System Page 2 of 2 CONTAINING Z, SSS ACRES, MORE OR LESS. ~ 111 C O ~c"~'S~ '.~ t,ll 61't m r71"f Last updated on 08/29/2007. Not sure who to contact? Have a question about DNR? Visit the Public Inforrna~on Center. Report technical problems with this page to the V~lebmaster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all C3®IES must be accepted. State_ofAlaska Natural_Resources LAS Home Copyright Privacy System_S#atus http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=25521 &... 8/29/2007 • • 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 last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and. logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /infect is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 ~ • ^^ ai O f6 , ~ i i ~ ~ ~ ~ ~, ~ ~ ~ ~ U' , N• ~ ~ i U. o, w, N' ~ N. ; a' ~ ; d ~ Ol ; , o, ~: ~, ~ 3. _ , 4 ~ ~, N , Z, ~ ~ f0~ ~ a~ N~ ~ ~ ~, O. ~, , W' ~ ~ O, O' ~ c, Qj ~ ~ ~ ~ o o, ~ ~ N: ~ ~ E O ~ Z; ~ m; ; a ~, o. ~ o i ~ r a~~ c` t ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ m. ~ ~, ~ ~~ ~ ~ w~ ~. _~ d ~ v y U. •3; p. p, ~ ~ ; ~. ~ uoi, ; ~ ; m. 3 3 ; ~ >, ur r, n, c, ~ ~; a ~ :3. ~, a. ~ ~, a, of ~ a~ m , Q. ~ (6. p ~ ~ M, C. S N' J O' U y c' o, ~, _ _, ~ ~ ~, c' m. ~, w N' c> _ ~, rn ~ v: a m M o: i o, ~o; o, ~ O m ~, °~~ r ~ N, ~ ~ ~ U, ~ ~ ~~ N, N. 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U; ¢ ~ "~ Q "_; o; m; m; U ~' ~'; ~ a, o; ~, ~, U ~ ~ _ ~ r N M~ to (p f~ 00 O r O r r N r M r d' r ~ O~ ~I r r r r O O O r r N N N N M~ N N ~ O h W N N N N r O O N M M N M s}' M M M ~fI O M M n O M M O M U p V _- _._-__- -__ - __ _-__.-__ __ - -- _ . - __-_~ ___-_____- ~ 0 :3 ^ °o ~ :+ ~ ° N ~ ~ °3 °o .. ~ ~ 0 0 N ~' ~ 01 l0 ~ f6 N ~ ~' ~~ o W ° N ~ ° ° u' J ° N ~ I ~ ~ U' E J # C L 0 ~ ~ ~ O Q. ~ U ? ~ Q Q N ~ W Q H 7 Q N 7 0 . ( t • • 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 intomiation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. K 3n-14apbl.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 05 15:24:47 2008 Reel Header Service name .............LISTPE Date . ...................08/02/05 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/05 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS Lis writing Library. Scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: 3N-14A PB1 API NUMBER: 500292158970 OPERATOR: conocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 05-FEB-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0005230436 w-0005230436 w-0005230436 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: P. WILSON P. WILSON P. WILSON MWD RUN 4 JOB NUMBER: w-0005230436 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: P. WILSON SURFACE LOCATION SECTION: 29 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 1561 FEL: 80 FWL: Page 1 ~ i 3n-14apbl.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 62.00 GROUND LEVEL: 34.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 7.000 7.000 3543.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 3N-14 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 3543`MD/3543'TVD. THE WHIPSTOCK WAS POSITIONED AND THE WINDOW WAS MILLED PRIOR TO PICKING UP MWD TOOLS. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CALL BETWEEN LISA WRIGHT, CONOCOPHILLIPS ALASKA, INC., AND BUSTER BRYANT (SDS) ON 2/5/2008. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 3N-14A PB1 WITH API#: 50-029-21589-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7768`MD/6232'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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 FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 Page 2 3n-14apbl.tapx File Type. ............LO Previous File Name.......STSL26.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET RPX ROP S 1 clipped curves; all bit runs merged. .5000 START DEPTH 3505.5 3535.0 3535.0 3535.0 3535.0 3535.0 3576.5 STOP DEPTH 7711.5 7718.5 7718.5 7718.5 7718.5 7718.5 7768.0 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 1 3505.5 3846.0 2 3846.0 6882.0 3 6882.0 7319.0 4 7319.0 7768.5 REMARKS: MERGED MAIN PASS. 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 HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Page 3 3n-14apbl.tapx Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3505.5 7768 5636.75 8526 3505.5 7768 RPD MWD OHMM 0.61 1911.08 4.71389 8368 3535 7718.5 RPM MWD OHMM 0.5 2000 4.09988 8368 3535 7718.5 RPS MWD OHMM 0.65 973.3 3.35345 8368 3535 7718.5 RPX MWD OHMM 0.65 928.81 3.1692 8368 3535 7718.5 FET MWD HOUR 0.53 23.48 2.59265 8368 3535 7718.5 GR MwD API 46.1 525.57 125.071 8413 3505.5 7711.5 ROP MWD FT/H 0.03 375.11 67.0141 8384 3576.5 7768 First Reading For Entire File..........3505.5 Last Reading For Entire File...........7768 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSL2B.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Le~rel Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5Li6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3505.5 3775.5 RPD 3535.0 3783.0 RPM 3535.0 3783.0 RPx 3535.0 3783.0 RPS 3535.0 3783.0 FET 3535.0 3783.0 RoP 3576.5 3846.0 LOG HEADER DATA DATE LOGGED: 05-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3846.0 Page 4 3n-14apbl.tapx TOP LOG INTERVAL (FT): 3576.0 BOTTOM LOG INTERVAL (FT): 3846.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 2,0 MAXIMUM ANGLE: 11.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10911222 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.000 DRILLER'S CASING DEPTH (FT): 3543.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 42.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.600 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .150 79.0 MUD FILTRATE AT MT: 2.400 72.0 MUD CAKE AT MT: 2.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 Page 5 3n-14apbl.tapx a First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3505.5 3846 3675.75 682 3505.5 3846 RPD MWDO10 OHMM 0.61 1911.08 30.5425 497 3535 3783 RPM MWDO10 OHMM 0.5 2000 21.1478 497 3535 3783 RPS MWD010 OHMM 0.65 973.3 9.41155 497 3535 3783 RPX MWDO10 OHMM 0.65 928.81 6.75596 497 3535 3783 FET MWDO10 HOUR 0.66 4.44 2.24139 497 3535 3783 GR MWDO10 API 46.1 126.81 94.1755 541 3505.5 3775.5 ROP MWDO10 FT/H 0.64 375.11 95.611 540 3576.5 3846 First Reading For Entire File..........3505.5 Last Reading For Entire File...........3846 File Trailer service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 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.......08/02/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6,002 Comment Record FILE HEADER FILE NUMBER: 3 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 3776.0 6811.5 RPx 3783.5 6818.5 FET 3783.5 6818.5 RPM 3783.5 6818.5 RPD 3783.5 6818.5 RPS 3783.5 6818.5 ROP 3846.5 6882.0 LOG HEADER DATA DATE LOGGED: 09-OCT-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite Page 6 :~ 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) 3n-14apbl.tapx 74.11 Memory 6882.0 3846.0 6882.0 14.1 63.9 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10911222 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.000 DRILLER'S CASING DEPTH (FT): 3543.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 41.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.440 132.8 MUD FILTRATE AT MT: 2.900 65.0 MUD CAKE AT MT: 2.600 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 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 HOUR 4 1 68 20 6 Page 7 r ~ 3n-14apbl.tapx GR MWD020 API 4 1 68 24 7 RoP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3776 6882 5329 6213 3776 6882 RPD MWD020 OHMM 1.22 6.36 3.27712 6071 3783.5 6818.5 RPM MWD020 OHMM 1.15 7.36 3.2104 6071 3783.5 6818.5 RPS MWD020 OHMM 1.17 7.73 3.14874 6071 3783.5 6818.5 RPX MWD020 OHMM 1.16 9.52 3.11307 6071 3783.5 6818.5 FET MwD020 HOUR 0.53 8.84 1.61061 6071 3783.5 6818.5 GR MWD020 API 55.94 173.36 119.751 6072 3776 6811.5 ROP MWD020 FT/H 0.03 181.5 72.3386 6072 3846.5 6882 First Reading For Entire File..........3776 Last Reading For Entire File...........6882 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......sTSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6812.0 7246.5 RPS 6819.0 7253.5 FET 6819.0 7253.5 RPM 6819.0 7253.5 RPx 6819.0 7253.5 RPD 6819.0 7253.5 ROP 6882.5 7319.0 LOG HEADER DATA Page 8 3n-14apbl.tapx DATE LOGGED: 11-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7319.0 TOP LOG INTERVAL (FT): 6882.0 BOTTOM LOG INTERVAL (FT): 7319.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 49.3 MAXIMUM ANGLE: 57.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10911222 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.000 DRILLER'S CASING DEPTH (FT): 3543.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (5): 41.0 MUD PH; 9.6 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.800 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.680 129.2 MUD FILTRATE AT MT: 2.900 75.0 MUD CAKE AT MT: 2.600 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 Page 9 1 3n 84apbl.tapx RPS MWD030 OHMM 4 6 1 l2 4 RPX MWD030 OHMM 4 1 68 16 5 FET MwD030 HOUR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6812 7319 7065.5 1015 6812 7319 RPD MwD030 OHMM 1.33 11.91 2.79077 870 6819 7253.5 RPM MwD030 OHMM 1.26 16.55 2.74729 870 6819 7253.5 RPS MWD030 OHMM 1.15 22.13 2.69456 870 6819 7253.5 RPX MWD030 OHMM 1.1 26.34 2.69051 870 6819 7253.5 FET MwD030 HOUR 3.06 20.22 7.63219 870 6819 7253.5 GR MwD030 API 80.56 218.85 132.516 870 6812 7246.5 ROP MwD030 FT/H 0.1 110.68 21.8101 874 6882.5 7319 First Reading For Entire File..........6812 Last Reading For Entire File...........7319 File Trailer Service name... .......STSLIB.004 service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7247.0 7711.5 RPM 7254.0 7718.5 RPx 7254.0 7718.5 RPS 7254.0 7718.5 RPD 7254.0 7718.5 FET 7254.0 7718.5 ROP 7319.5 7768.5 Page 10 3n-14apbl.tapx 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 DGR DUAL GAMMA RAY $wR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 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): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ........,.0 Data Specification Block Type.....0 Loging 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 12-OCT-07 Insite 74.11 Memory 7768.0 7319.0 7768.0 28.4 44.0 TOOL NUMBER 203301 130908 7.000 3543.0 Polymer 10.20 46.0 9.6 200 3.2 2.800 78.0 1.660 136.4 2.900 78.0 2.600 78.0 Name service order units size Nsam Rep code offset Channel Page 11 3n-14apbl.tapx 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 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7247 7768.5 7507.75 1044 7247 7768.5 RPD MWD040 OHMM 1.03 5 2.08913 930 7254 7718.5 RPM MWD040 OHMM 1.02 5.89 2.06114 930 7254 7718.5 RPS MWD040 OHMM 1.06 6.58 2.06863 930 7254 7718.5 RPX MWD040 OHMM 1.06 7.26 2.06663 930 7254 7718.5 FET MWD040 HOUR 0.76 23.48 4.47664 930 7254 7718.5 GR MWD040 API 69.64 525.57 170.814 930 7247 7711.5 ROP MWD040 FT/H 3.02 114.97 57.7969 899 7319.5 7768.5 First Reading For Entire File..........7247 Last Reading For Entire File...........7768.5 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/05 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Library. Scientific Technical services Service name .............LISTPE Date . ...................08/02/05 Ori gin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF Page 12 • • 3n-14apbl.tapx Physical EOF End Of LIS File Page 13 3n-14a.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 05 16:05:47 2008 Reel Header Service name .............LISTPE Date . ...................08/02/05 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/05 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments..... .............STS LIS Writing Library. scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: 3N-14A API NUMBER: 500292158901 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 05-FEB-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 5 Job NUMBER: w-0005230436 w-0005230436 w-0005230436 LOGGING ENGINEER: P. ORTH P. ORTH T. GALVIN OPERATOR WITNESS: P. WILSON P. WILSON D. GLADDEN MWD RUN 6 Job NUMBER: w-0005230436 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 29 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 1561 FEL: 80 FWL: Page 1 a~,~~1~9 ~ ~~~~ • 3n-14a.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 62.00 GROUND LEVEL: 34.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 7.000 7.000 3543.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING 3N-14A PB1 AT 4032'MD/ 4021'TVD. 4. MWD RUNS 1,2,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 1,2,5 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CALL BETWEEN LISA WRIGHT, CONOCOPHILLIPS ALASKA, INC., AND BUSTER BRYANT (SDS) ON 2/5/2008. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2,5,6 REPRESENT WELL 3N-14A WITH API#: 50-029-21589-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8220'MD/6647'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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 FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Page 2 ~ ~ Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET R PX ROP 1 3n-14a.tapx clipped curves; all bit runs merged. .5000 START DEPTH 3505.5 3535.0 3535.0 3535.0 3535.0 3535.0 3576.5 STOP DEPTH 8161.0 8172.0 8172.0 8172.0 8172.0 8172.0 8220.0 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 1 3505.5 2 3846.0 5 4032.5 6 7715.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3846.0 4032.0 7715.0 8220.0 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 HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3505.5 8220 5862.75 9430 3505.5 8220 Page 3 ~ ~ 3n-14a.tapx RPD MWD OHMM 0.61 2000 17.4424 9275 3535 8172 RPM MWD OHMM 0.5 2000 14.427 9275 3535 8172 RPS MWD OHMM 0.65 2000 16.0228 9275 3535 8172 RPX MWD OHMM 0.65 1731.06 7.84434 9275 3535 8172 FET MWD HOUR 0.37 347.51 2.34752 9275 3535 8172 GR MWD API 33.68 545.96 120.299 9312 3505.5 8161 ROP MWD FT/H 0.64 375.11 80.3821 9288 3576.5 8220 First Reading For Entire File..........3505 Last Reading For Entire File...........8220 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3505.5 3775.5 RPD 3535.0 3783.0 RPM 3535.0 3783.0 RPx 3535.0 3783.0 RPS 3535.0 3783.0 FET 3535.0 3783.0 ROP 3576.5 3846.0 LOG HEADER DATA DATE LOGGED: 05-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3846.0 TOP LOG INTERVAL (FT): 3576.0 BOTTOM LOG INTERVAL (FT): 3846.0 Page 4 ~ ~ 3n-14a.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 2,0 MAXIMUM ANGLE: 11.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10911222 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.000 DRILLER'S CASING DEPTH (FT): 3543.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9,70 MUD VISCOSITY (S): 42.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.600 72.0 MUD AT MAX CIRCULATING TERMPERATURE: .150 79.0 MUD FILTRATE AT MT: 2.400 72.0 MUD CAKE AT MT: 2.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPx MWDO10 oHMM 4 1 68 16 5 FET MWDO10 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 Page 5 3n-14a.tapx First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3505.5 3846 3675.75 682 3505.5 3846 RPD MWDO10 OHMM 0.61 1911.08 30.5425 497 3535 3783 RPM MWDO10 OHMM 0.5 2000 21.1478 497 3535 3783 RPS MWDO10 OHMM 0.65 973.3 9.41155 497 3535 3783 RPX MWDO10 OHMM 0.65 928.81 6.75596 497 3535 3783 FET MWDO10 HOUR 0.66 4.44 2.24139 497 3535 3783 GR MWDO10 API 46.1 126.81 94.1755 541 3505.5 3775.5 ROP MWDO10 FT/H 0.64 375.11 95.611 540 3576.5 3846 First Reading For Entire File..........3505.5 Last Reading For Entire File...........3846 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.002 comment Record FILE HEADER FILE NUMBER: 3 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 3776.0 4032.0 RPX 3783.5 4032.0 FET 3783.5 4032.0 RPM 3783.5 4032.0 RPD 3783.5 4032.0 RPS 3783.5 4032.0 OP 3846.5 4032.0 $ LOG HEADER DATA DATE LOGGED: 09-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 6 • 3n-14a.tapx TD DRILLER (FT): 4032.0 TOP LOG INTERVAL (FT): 3846.0 BOTTOM LOG INTERVAL (FT): 4032.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 14.1 MAXIMUM ANGLE: 63.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10911222 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.000 DRILLER'S CASING DEPTH (FT): 3543.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 41.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.440 132.8 MUD FILTRATE AT MT: 2.900 65.0 MUD CAKE AT MT: 2,600 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny 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 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Page 7 ~ ~ 3n-14a.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3776 4032 3904 513 3776 4032 RPD MWD020 OHMM 1.22 6.36 2.87293 498 3783.5 4032 RPM MWD020 OHMM 1.15 7.36 2.81819 498 3783.5 4032 RPS MWD020 OHMM 1.17 7.73 2.83787 498 3783.5 4032 RPX MWD020 OHMM 1.16 9.52 2.87229 498 3783.5 4032 FET MWD020 HOUR 0.53 8.35 3.18285 498 3783.5 4032 GR MWD020 API 69.72 126.7 106.809 513 3776 4032 ROP MWD020 FT/H 5.66 181.5 84.7134 372 3846.5 4032 First Reading For Entire File..........3776 Last Reading For Entire File...........4032 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 4032.5 7665.5 FET 4032.5 7665.5 RPM 4032.5 7665.5 RPx 4032.5 7665.5 GR 4032.5 7658.5 RPD 4032.5 7665.5 ROP 4032.5 7715.0 LOG HEADER DATA DATE LOGGED: 23-OCT-07 SOFTWARE Page 8 ~ ~ 3n-14a.tapx SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7715.0 TOP LOG INTERVAL (FT): 4032.0 BOTTOM LOG INTERVAL (FT): 7715.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.7 MAXIMUM ANGLE: 65.4 #' TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EwR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 7.000 DRILLER's CASING DEPTH (FT): 3543.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 45.0 MUD PH: 10.1 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .650 136.0 MUD FILTRATE AT MT: 1.000 70.0 MUD CAKE AT MT: 1.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggingg 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 Page 9 3n-14a.tapx FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4032.5 7715 5873.75 7366 4032.5 7715 RPD MWD050 OHMM 1.06 8.88 2.99757 7267 4032.5 7665.5 RPM MwD050 OHMM 1.02 9.03 2.93244 7267 4032.5 7665.5 RPS MWD050 OHMM 0.97 9.99 2.87178 7267 4032.5 7665.5 RPX MWD050 OHMM 0.92 11.34 2.7959 7267 4032.5 7665.5 FET MWD050 HOUR 0.37 347.51 1.05617 7267 4032.5 7665.5 GR MwD050 API 54.24 545.96 127.744 7253 4032.5 7658.5 ROP MWD050 FT/H .7.59 223.76 84.9943 7366 4032.5 7715 First Reading For Entire File..........4032.5 Last Reading For Entire File...........7715 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7659.0 8161.0 RPM 7666.0 8172.0 RPx 7666.0 8172.0 RPS 7666.0 8172.0 RPD 7666.0 8172.0 FET 7666.0 8172.0 ROP 7715.5 8220.0 Page 10 3n-14a.tapx LOG HEADER DATA DATE LOGGED: 28-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8220.0 TOP LOG INTERVAL (FT): 7715.0 BOTTOM LOG INTERVAL (FT): 8220.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.0 MAXIMUM ANGLE: 35.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 10811224 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.750 DRILLER'S CASING DEPTH (FT): 7710.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 12.70 MUD VISCOSITY (S): 46.0 MUD PH: 10.3 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3): 2.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.400 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .760 135.0 MUD FILTRATE AT MT: 1.800 70.0 MUD CAKE AT MT: 3.000 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 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 MWD060 OHMM 4 1 68 4 2 Page 11 • 14a.tapx 6 RPM MWD060 OHMM 4 1 8 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7659 8220 7939.5 1123 7659 8220 RPD MWD060 OHMM 1.66 2000 121.801 1013 7666 8172 RPM MWD060 OHMM 0.87 2000 99.296 1013 7666 8172 RPS MWD060 OHMM 1.52 2000 120.09 1013 7666 8172 RPX MWD060 OHMM 1.55 1731.06 47.0388 1013 7666 8172 FET MWD060 HOUR 1.08 93.44 11.2528 1013 7666 8172 GR MWD060 API 33.68 132.03 87.5186 1005 7659 8161 ROP MWD060 FT/H 0.65 109.83 37.0076 1010 7715.5 8220 First Reading For Entire File..........7659 Last Reading For Entire File...........8220 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/05 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/05 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/02/05 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF writing Library. writing Library. Page 12 scientific Technical services scientific Technical services 3n-14a.tapx Physical EOF End Of LIS File Page 13 ConocoPhiliips Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA 3N-14A 3N-14A PB1 Provided by: ~ EPOCH Approved by: Lisa Wright Compiled. by: John D. Lundy Harry E. Bleys Nic Moir Date: 10/30/07 Distribution: 12/29/08 ~b-~-~~~ ~~s~ia Conoc Phillips Ai~ska, inc. 3N-14A, 3N14A PB1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ............................................. ...................................................2 1.1 Equipment Summary ..................................................................... ...................................................2 1.2 Crew .............................................................................................. ................................................... 2 2 WELL DETAILS .................................................................................. ...................................................3 2.1 Well Summary ............................................................................... ...................................................3 2.2 Hole Data ...................................................................................... ................................................... 3 2.3 Daily Activity Summary .................................................................. ...................................................4 3 GEOLOGICAL DATA .......................................................................... ...................................................7 3.1 Lithostratigraphy ............................................................................ ...................................................7 3.2 Mudlog Summary .......................................................................... ................................................... 7 3.3 Connection Gases & Swabs (s) .................................................... ...:............................................... 9 3.4 Trip (Wiper) Gases ........................................................................ ...................................................9 4 PRESSURE /FORMATION STRENGTH DATA ................................ ................................................. 10 4.1 Pore Pressure Evaluation .............................................................. .................................................10 5 DRILLING DATA ................................................................................. .................................................11 5.1 Survey Data ................................................................................... .................................................11 5.2 Bit Record ...................................................................................... ................................................. 13 5.3 Mud Record ................................................................................... .................................................14 6 MORNING REPORTS ........................................................................ .................................................15 Enclosures • 2"/100' Formation Log (MD) 2"/100' Gas Ratio Log 2"/100' Drilling Dynamics Log 2"/100' LWD / Lithology Log ~ E~ EPOCH C: • ConvcoPhiilips Alaska. Inc. 3N-14A, 3N14A PB1 1 MUDLOGGING EQUIPMENT 8~ CREW 1.1 Equipment Summary Parameter Equipment Type /Position Total Downtime Comments QGM Agitator (Mounted in possum Ditch gas belly) 1 Hour Flame ionization total gas & chromato rah . Hook Load / Wei ht on bit Totco WITS Feed 0 Mud Flow In Derived from Strokes/Minute and 0 Pum Out ut Mud Flow Out Totco WITS Feed 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 s stem Ri watch) Mudlo m unit DAC box gg g In-unit data collection/distribution 0 center Pit Volumes, Pit Gain/Loss Totco WITS Feed 0 Pum Pressure Totco WITS Feed 0 Pump stroke counters Totco WITS Feed 0 Totco Well Monitoring Totco computer networked in 0 Com onents Mudlo in Unit Rate of enetration Totco WITS Feed 0 RPM Totco WITS Feed 0 Torque Totco WITS Feed 0 1.2 Crew Mudloggers Years •, Days •2 Sample Catchers Years Days Technician Days John Lund 16 13 Nick Moir 1 5 Dan Lee 3 Har Ble s 5 10 Mike Marsh 1 10 3 Allen Williams 1 3 Unit Type Unit Number ~ ML030 'Years experience as Mudlogger '~ Days at wellsite between spud and total depth of well E~~~1Z 2 ConocciPhillip~ A4'~s4ca, Inc. 3N-14A, 3N14A PB1 2 WELL DETAILS 2.1 Well Summary Wefl: 3N-14A, 3N-14A P61 API Index #: 50-029-21589-01 50-029-21589-70 Field: Kuparuk River Field Surface Co- Coordinates: 1561' FSL, 81' FEL SEC 29-T 13N-R 9E UM Borough: North Slope Primary Target Depth: 8085' MD State: Alaska TD Depth: 8820' MD Rig Name /Type: Doyon 141, Arctic Triple Suspension Date: 10/30/07 Primary Target: Kuparuk A Sands License: Spud Date: 10/7/2007 Ground Elevation: 34' AMSL Completion Date: 10/20/2007 RT Elevation: 62.0' RKB Completion Status: Plug back and bypass at 4030'. Secondary Target: De the None Classification: Production TD Date: 10/20/2007 TD Formation: Kuparuk D Days Testing: NONE Days Drilling: 13 Well plugged 10/20/2007 2.2 Hole Data Maximum De th Mud Shoe De th LO Hole Section MD TVDSS TD Formation Weight Dev. o. (mc) Corin g / Liner MD TVDSS T (ppg) ft ft (ppg) ft ft 7" 7768' 6116 Base 11 3 27.87 none 5.5" 3710 3190 14.3 Ku aruk . Additional Comments The 3N14-A was drilled by setting a whipstock in the existing 7" casing of the original well (3N14) and milling a window. TOW = 3543' BOW = 3556'. 40' new formation was drilled to 3763' and aFIT = 14.3 EQMW was established. Wits data feed was established to supply data to Epoch at 11:05 hrs October 6 2007 at 4152'MD. TD for intermediate casing liner was reached at 7768' and a 15 stand wiper trip was made with no problems. Liner was made up and run into the hole, becoming differentially stuck 500 ft off bottom. An effort was made to free the stuck linerwithout success. During this attempt the liner became packed off. Linerwas chemically cut at 6867' and an attempt to free the upper section was made without success. The liner was again chemically cut at 5885' and a second attempt was made to retrieve the fish. Additional cuts were made after retrieving the hanger and packer assembly and the upper portion of the fish was eventually retrieved. A cement plug was put in place and this well bypassed at 4035' MD. ~ E-1 EPOCH 3 ConocoPhillips 3N-14A, 3N14A PB1 2.3 Daily Activity Summary 10/06/2007: Finish Rig Up Epoch Unit. Wait on Phone Line. Phone Line installed, and Totco WITS feed setup Rig nippling up and testing BOP. 10/07/2007: Download MWD. Lay down TM collar and UBHO. Change motor, bend to 1.5 degree. Pick up TM, UBHo upload. RIH to 3755'. Wash to bottom. Drill from 3848' to 4211' MD, 4184' TVD. PJSM. Continue drilling from 4211' MD to 4689' at midnight. Continue drilling to 4858' at 0300hrs. 10/08/2007 Drilling from 4689' to 5985'. 10/09/2007: Drilling from 5985' to 6565' MD, 5432' TVD. PJSM. Drilling from 6565' to 6844' TVD 5571' 10/10/2007: Drilling from 6844 to 6882', 5595' TVD. Circulate bottoms up. Monitorwell (static). Pull out ofthe hole ten stands. OK. Pump dry job. Pull out of the hole to BHA. Stand back HWDP and jars to 110'. Lay down BHA to collar. Pull up and break off bit. PJSM. C/O & set motor to 1 .5 degrees. C/O float. Make up bit and pick up HOC. Program MWD (monitor well static). Run in hole with BHA #4. Enter window clean. Break circulation at 3658'. Test MWD and continue to run in hole. Break circulation at 6752'. Wash and ream 6752 to 6882', TVD 5648'. Drill. 10/11/2007: Drilling ahead. Pumped tube pill at 7000 ft. and a sweep at 7075 ft. Max gas 40 u. Continuing to drill at report time. 10/12/2007: Replaced bit and made up bottom hole assembly. Picked up tools and tripped into hole to 7318 ft. Circulated gases and commenced drilling ahead. Still drilling at report time. • 10/13/2007: Drill to 7768' MD and TD for liner. Circulate bottoms up and pull out of hole15 stands short trip to wipe hole clean. Run in hole to bottom and circulate bottoms up. • 10/14/2007: Pull out of hole to BHA. Download MWD and lay down BHA. Clean and clear rig floor. Pull wear bushing. Rig up and run 83 joints of m5.5" liner. Circulate cap, staging pumps to 3500 psi. Run remaining 21 joints of liner 4389', total of 104 joints 15.5 Ib liner. Circulate bottoms up, staging pumps to 23 SPM/650 psi. Run into hole with liner on 4" drill pipe. Circulated liner volume, still circulating at report time. 10/15/2007: Attempted to free liner string, spot 9.9 ppg 6% Lube pill in open hole annulus. Lower mud weight to 10.0 ppg. Liner string parted at running tool. Pulled out of hole & laid down running tool. Made up fishing assembly and ran in hole. Latched onto fish and established circulation. Worked fish. Hole packed off and circulation lost. Worked fish 10/16/2007 Continued to work pipe pulling up to 225 over, without jarring. Established a max of 6% returns, pumping 1.5 BPM @600 psi for about 15 minutes. Then returns went away. Fired jars several times and continued to work. Reduced pump rate to 1 BPM 650 psi, then pulled up 225 k over and chained down for hour, no change. Released grapple and laid down 1 single. While monitoring well, had a slight flow back up the drill pipe. Kelly up and circulate 5 BPM @ 300psi. Check mud weight at 10.PPG. in 10.1 PPG back. Circulate until mud weight even at 10.Oppg. Monitor well OK. Pull out of hole to 324'. Lay down jars and 3.5" Drill collars, stand back 2 stands of drill collars and lay down grapple. Clean and clear drill floor. PJSM. Rig down nipple and rig up shooting flange. PJSM. Rig up wireline. Remove shooting flange. Nipple up riser. Make up BHA #8, Baker trip #3, with 4.961 grapple to 326'. Run in hole with pipe from derrick to 2859'. Pick up single and fished to TOL @ 2864'. PU=78, SO =78. Establish pump rate at 16 SPM, 600psi. (Losing 80%) Set grapple in the fish. Pull 200K over, no luck, release grapple. {Pushed away 12 BBLS mud while fishing) Lay down 1 single. Blow down and monitor well static. Pull out of hole on elevators from 2859' to 326'. Stand back 2 stands drill collars and lay down BHA #8. Nipple down riser, nipple up flange. Rig up SWS, sheaves, e- line, lubricator and jet cutter. Pick up new jet cutter. ~~~~H ConocoPhiUips Alaska, inc. 3N-14A, 3N14A PB1 • 10/17/2007 Performed job safety meeting concerning wireline operations. Reloaded cutter and ran in hole to make a cut at 3520 ft., wire depth. Pulled out of hole due to detonator misfire. Shot not made. Make-up new charge and run in hole to repeat procedure. Good shot. Cut made. Pull out of h ole and rig down wireline equipment. Rig down shooting flange and rig up bell nipple riser. Makeup bottom hole assembly and pick up three five inch collars and grapple. Run in hole to 2859 ft. and pick up single tag fish at 2864 ft. Set grapple and pickup before 77 thousand pull weight. Pull eight thousand over limit. With fish attached to bottom tools began pulling at 86 thousand pounds. Laid down single and monitored well. Pulled out of hole with good fill to to 1546 ft. Hole started to swab. Picked up Kelly and pumped every other stand out of hole. To 326 ft. Packer would not allow circulation while pumping. Filled OK, and flow checked out OK too. Rack back two stands of 5 inch collars and laid down three collars. Pulled fish to floor and released grapple. Laid down spear assembly and fish. Packer unable to release grapple. Fifteen joints and one cut off recovered. Clear and clean rig floor. Rig up and test Blowout Preventers per Doyon guide lines. The AOGCC John Crip waived witnessing. Test choke manifold valves, manual upper and lower rams, blind rams, floor and dart valves. Tested upper and lower Blowout Preventers to 250 psi at low range to 5000 psi at high range for five minutes each on chart. Annular tested to 3500 psi. Tested w/3 joints sizes at 3.5,4, and 5 inch at a total of 12 tests. Picked up tools for slide and make up to 329 ft. Run in hole from derrick to 3517 ft. and pick up single from fished to 3529 ft. Estimated PR's 48 strokes per minute at 400 psi. Gotten good returns. Jared several times at 85 thousand over pick up weight. Pulled 190 thousand over Pick up weight, up to 275 thousand pounds. No luck fish not moving. 10/18/2007 Continued to jar pulling over straight pull to 215K over. Circulating at 5.5 barrel per minute. At 500 psi. Fish still not moving. Set and try to jar at 85K over. Jars failed to fire. Pull 140K over and Jars fired. Slack off and reset and try to jar at 85K over. Again no fire. Continue to work pipe with straight pull up to 215K overwhile circulating. Gradually lower mud weight to 9.5 ppg. Pump nut plug sweep at 30 BBLS of 9.5 ppg of 50 Ibs nut plug to determine cut location. Continue to work pipe and circulate staging up pumps slowly from 5.5 BPM at 500 psi to 7bpm at 900psi. Holes shows good circulation. Chain down with 240K over and circulate a 8bpm trying to wash a new fluid path around pipe. Continue to work pipe every hour. Still no fluid loses. Spot 50 barrel black magic pill of 9.5 ppg through cut at 5212 ft. Release grapple and lay down single. Monitor well and work on top drive. Pull out of hole from 3517 ft. Noticed good hole fill. Rack back 3 5 inch collars and come out with jars and grapple. Make up bottom hole assembly and run in hole to 3517 ft. Pickup single spear fish at 3529 and start to jar at 85K over. Working up to 80Kover straight pull or up to 190K over. Break circulation every 30 minutes. Jar several times firing 75K over Pick up weight. Pulling 240K over Pick up weight. Decision made to release grapple and pull out of hole. Laid down single to 3517 ft. blow down to TD and monitor well. Pull out of hole on elevators to 329 ft. Stand back collars and laydown bottom hole assembly number eleven.. Perform a job safety hazard assessment for ND riser, S. flange, sheaves, a-line lubricator, and jet cutter. Rig up and run in hole with jet cuter on E-line to 5040 ft. Pull out of hole and make up new charge. Run in hole to 4310 ft. Had misfire. Pulled out of hole with misfired shot. Laid down tool and made up new charge. A bad detonator. Run in hole with cutter. 10/19/2007 Performed job safety analysis. Continue to run in hole with wireline for cut at 4310 ft. Second misfire. Pull out of hole with wireline. Check system of tool head by ohm readings. Determined bad batch of detonators. Standby for arrival of new detonators. Run in hole with wireline and new detonators. Good shot at 4310 ft. Pull out of hole and lay down wireline and equipment. Perform safety job analysis and rig down shooting flange. Rig up bell nipple and riser. Make up bottom hole assembly number 12 and run in hole to 3517 ft. Pick up single to 3520 ft. Latch onto fish at 3520 ft. Jar once at 65K over pick up weight. Pull 90K over. Fish came free. String 9000 Ibs heavier. Monitor well. Static blow down T.D. and lay down single to 3517 ft. Pull out of hole from 3517 ft. to 2674 ft. Circulate one string volume at 23 SPM and 250 psi. Continue to pull out of the hole on elevators from2674 ft. to 1268 ft. Continue to pull out to 329 ft, and lay down collars. Rig up five 5 inch casing equipment. Hold safety job analysis on laying down Hydril, and 18 joints of liner, and two cutoffs with an overall length of 779.81 ft. Clear Drill floor and lay tools down slide. Pick up spear assembly and cut piece. Release grapple and lay down cut off, and remaining Baker tools. Pickup 3.5 inch casing tools from slide. Rig up 3.5 inch casing equipment. Hold job safety analysis meeting and make up 2 7/8 inch joint EUE and Mule Shoe., xo,16 3.5 inch joints EUE, x-o and x-o to 535 ft. Run in hole from derrick to 3723 ft. Crew change out. Held new crews Job safety analysis meeting. Continue to trip in hole to 4335 ft. M.D. Circulate at 6 bbl/ min with no losses-at 550 psi. Condition mud for cement plug. ~~~~K 5 Conoto~Phillips Alaska. Inc. 3N-14A, 3N14A PB1 10/20/2007 Pull out of hole to 4260 ft. Hold job safety analysis meeting for cement plug job. Rig up. Batch up pump 5 BBLS H2O. Test lines to 300psi. Than pump 10 BBLS H2O and 21.4 BBLS of cement at 17 ppg and d4.9 BBLS H2O displace with rig pumps 405 strokes at 34.4 BBLS. Pull out of hole to 3800 ft. Circulate 2920 strokes at 56 stk/min. at 410 psi long way and 1558 stk/min and 340 psi. Blow down flow line and check static. Pull out of hole to 535 ft. Perform safety analysis meeting for casing job. Rig up casing tools and lay down 2 cross overs and 16 joints of 3.5 inch tubing plus 2 7/8 inch tubing with mule shoe. Rig down casing tools. Clear and clean rig floor. Pick up and make up Bottom Hoie Assembly #14 with bi-center bit, mtf,flt,sub,nmflt,sub dm hoc, smart stab, slimphase 4 with DGR PWD, TM HOC. :Plug in and up load MWD. Continue to makeup Bottom Hole Assembly #14, all the cross overs and Drill collars. Trip in hole from 640 ft. to 3450 ft. Hold job safety analysis meeting, Slip and cut drill line. Lube top drive. Continue to trip in hole. Wash and ream to 3860 ft. Attempt to tag cement at 3860 ft. No cement. Circulate bottoms up watching for cement. Cement still green. Pull out of hole to 3560 ft. Keeping bit out Side of window. Circulate at 22 sks/min, 80 gpm, 225 psi WOC. Run in hole and tag cement at 4032 ft. Set down 10K. Line up tool face 115R, PR 275 GPM, 79spm, 1650 psi through a few time. Drill ahead from 4032 ft. to 4325 ft on bypass well 3N14A_BP1 ~J ~ E~ EPOCH • ConocoPhillips 3N-14A, 3N14A PB1 3 GEOLOGICAL DATA 3.1 Lithostratiaraphy LWD tops refer to provisional picks by the ConocoPhillips Geologist; all depths are referenced to RKB. PROGNOSED LWD PICK FORMATION MD ft TVD ft MD ft TVD (ft Top HRZ 7300 5883 7374 5902 Base HRZ 7440 5992 7501 6002 K Marker 7567 6097 7615 6098 Top D Shale 7696 6208 Not logged Not logged Topset Point in the D Shale 7735 6242 7768 6232 3.2 Mudlog Summary Casing Point to top HRZ 3543' to 7374' MD (3543' to 5902' TVD RKB) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 218 2.7 68.4 67 1 13.8 This interval includes siltstone, claystone, sand, and sandstone, until approximately 5020', when where claystone largely drops out and the formation becomes predominantly sand/sandstone and siltstone, with occasional thin claystone, ash and calcareous tuff interbeds. The first carbonaceous shale of the HRZ litho type occurred at 7285' (MD). Traces of oil occurred at 5250' to 5260' and at 7500-7715', as dull to very dull greenish fluorescence with a slight crush cut, no show.'. Sand/sandstones of this interval were typically fairly thickly bedded with numerous thinner interbeds within the associated shales, siltstones and claystones. Generally individual sand/sandstone beds were medium to light gray with a slight to pronounced brownish secondary hue, were moderately well to well sorted, in the fine to medium sand range with local variations into the very fine and coarse grain sizes. Beds were vertically sorted, fining upward and typically grain supported with at least some degree of matrix. Individual grains are primarily quartz or chemically related volcanics in various hues with minor to occasionally dominant lithic sand. Mafic mineral and dark lithic grains are present but in minority amounts. Material is primarily silica cemented with occasional slightly too moderately calcareous zones. Occasional trace petroleum fluorescence was noted but none were considered to be strong enough to indicate a show. siltstones/claystones were typically light to medium gray with brownish to greenish secondary hues, consistently occurred as small lumpy/clayey masses at the shaker and varied from clean to sandy and clayey/shaly agreeable to there gradational relationship with the associated sands. This material exhibited both silica and calcite cementation in varying degree, was generally at least partially hydrophilic and is under-represented in samples due to a propensity to go into solution during circulation and sample preparation. ~~~~~ ConocaPhillips ~~~ 3N-14A, 3N14A P61 C. • • Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 5561 57 9578 229 115 33 64 28 35 6975 68 10750 361 138 75 87 84 73 7323 72 11322 365 150 34 61 26 19 7475 82 13777 612 238 39 71 21 22 Top of HRZ to K-1 Marker 7374' to 7615' MD (5883' to 6097' TVD RKB) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 74 11 39 72 1 14.1 The HRZ includes carbonaceous shales and some interbedded sands and minor ash fall tuff. The shale is typical HRZ, variably organic with thinly interbedded varicolored siltstone. siltstone is shaly, variably carbonaceous and locally very calcareous, particularly in the interval just above toe K1 marker and contains traces of pyrite associated with the carbon matter. Some thin interbeds of sandstone, and ash, also variable carbonaceous are also noted. Peaks De th TG C1 C2 C3 C41 C4N C51 C5N 7475 82 13777 612 238 39 71 21 22 K-1 Marker (Kalubik Shale) to Kuparuk "D" 7615' to 7696' MD (6098' to 6208' TVD RKB) Drill Rate ftlhr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 119 13 67 82 11 43 This is primarily a shale section with dark grayish brown to dark brownish gray to brown shales, carbonaceous in part, and some slightly to moderately calcareous grading to mudstone. Occasional interbedded siltstone and sandstone, and traces of calcite fracture fill were noted. A trace of very dull greenish oil fluorescence was noted in most samples through this section but does not constitute a show. Peaks De th TG C1 C2 C3 C41 C4N C51 CSN 6469 290 38373 4000 2067 303 657 200 211 6487 1900 280616 20043 8613 1199 2768 924 784 6510 417 62910 4307 1600 208 422 138 144 ~~~C~ ConvccaPhitlips Alaska,lnc. 3N-14A, 3N14A P61 • 3.3 Connection Gases 8~ Swabs (s) 1unit = 0.05% Methane Eauivalent De th Gas over BGG De th Gas over BGG feet units feet units 4800 8 6940 19 7405 19 swab 7435 23 swab 7585 35 3.4 Trip (Wiper) Gases 1unit = 0.05% Methane Eauivalent De th Tri to Gas Downtime feet feet units hours 6882 0 100 8 7320 0 52 10 ~~~~~ .. ~onocoPhllllps AEaska,fr~. 3N-14A, 3N14A P61 4 PRESSURE /FORMATION STRENGTH DATA Connection gas were rare through most of the drilling, peaks, where present were consistently sharp and dropped out quickly indicating an overbalanced condition. Consistently low background gas bears this out. Estimated pore pressure is well below the mud weight. No connection gas was encountered before 4800' drilling with a 9.7 ppg mud, and disappeared until 6800' but eventually showing up as small sharp peaks. Therefore, pore pressure is estimated to have increased from 9.5 to 9.6 at kickoff to 9.9 at HRZ TD. 4.1 Pore Pressure Evaluation F ti Primary Secondary Interval To s Pore Pressure EMW T d orma on Lithology Lithology MD TVD Min Max ren Interval Trend Indicators ("~o) (%j ft ft Kick off Point CI st/Sh 50% Sltst/Sst 50% 4030 7292 9.4 9.7 Sli Dn BG,CG HRZ Sh/Sltst 80% Sst 20% 7292 7790 9.6 9..9 U BG,CG,SG ~~~C~ 10 • Corot©Phillips Alaska, Inc. 3N-14A, 3N14A PB1 DRILLING DATA • 5.1 Survey Data (Tie into Oris~inal Well 3N14 at 3795.23' MD-3792.96' TVD) Measured Depth ft Incl. () Azom. () True Vertical De th ft Latitude (ft) N + , S - Departure (ft) E + , W _ Vertical Section ft Dogleg Rate °/100ft 28 0 0 28 0 0 0 0 94 0.15 146.7 94 -0.07 0.05 0.07 0.23 194 0.17 148.77 194 -0.31 0.20 0.27 0.02 294 0.2 160.33 294 -0.6 0.33 0.48 0.05 394 0.2 116.43 394 -0.84 0.55 0.76 0.15 494 0.22 99.48 494 -0.95 0.89 1.12 0.06 594 0.28 104.45 594 -1.04 1.32 1.55 0.06 694 0.37 120.77 694 -1.27 1.83 2.11 0.13 794 0.52 141.23 793.99 -1.79 2.39 2.79 0.22 894 0.5 151.32 893.99 -2.53 2.89 3.47 0.09 994 0.32 167.92 993.99 -3.18 3.16 3.91 0.21 1094 0.25 182.45 1093.98 -3.67 3.20 4.09 0.10 1194 0.17 181.47 1193.98 -4.04 3.19 4.18 0.08 1294 0.12 184.38 1293.98 -4.29 3.18 4.23 0.05 1394 0.12 195.50 1393.98 -4.5 3.14 4.26 0.02 1494 0.18 234.55 1493.98 -4.69 2.99 4.16 0.12 1594 0.3 260.58 1593.98 -4.82 2.60 3.82 0.16 1694 0.3 273.67 1693.98 -4.85 2.08 3.33 0.07 1794 0.43 331.30 1793.98 -4.5 1.64 2.81 0.37 1894 0.8 350.05 1893.97 -3.49 1.34 2.24 0.42 1994 0.9 354.15 1993.96 -2.02 1.14 1.65 0.12 2094 0.8 351.10 2093.95 -0.55 0.95 1.06 0.11 2194 0.8 7.02 2193.94 0.84 0.93 0.66 0.22 2294 0.88 34.45 2293.93 2.16 1.45 0.80 0.41 2394 0.8 51.82 2393.92 3.23 2.43 1.45 0.27 2494 1.18 58.42 2493.91 4.2 3.86 2.56 0.40 2594 1.05 62.22 2593.89 5.16 5.55 3.92 0.15 2694 0.85 67.98 2693.87 5.87 7.04 5.17 0.22 2794 0.83 70.22 2793.86 6.39 8.41 6.34 0.04 2894 0.83 66.97 2893.85 6.92 9.76 7.49 0.05 2994 0.77 66.08 2993.84 7.48 11.04 8.57 0.06 3094 0.68 66.22 3093.83 7.99 12.20 9.54 0.09 3194 0.58 67.62 3193.83 8.42 13.21 10.4 0.10 3294 0.38 76.02 3293.82 8.69 14.00 11.08 0.21 3394 0.52 68.65 3393.82 8.94 14.74 11.73 0.15 3494 0.52 68.30 3493.82 9.27 15.59 12.45 0.00 3543 2.01 72.36 3542.80 9.61 16.61 13.34 3.04 3607.52 4.15 75.58 3607.23 10.54 19.95 16.30 3.33 3671.71 6.71 77.18 3671.12 11.95 25.86 21.60 3.99 ~~~ ~~ 11 Conocot'hitlips Alaska, lnc. 3N-14A, 3N14A P61 r~ • 3731.06 9.6 79.50 3729.87 13.62 34.11 29.07 4.90 3795.23 11.43 75.62 3792.96 16.18 45.53 39.36 3.06 3887.07 14.05 77.28 3882.53 20.89 65.22 57.00 2.88 3981.31 17.65 83.77 3973.18 24.96 90.59 80.29 4.25 4074.26 21.95 89.62 4060.62 26.61 121.99 110.04 5.09 4170.84 27.13 94.91 4148.46 24.84 162.01 149.01 5.82 4263.92 32.72 97.45 4229.10 19.76 208.14 194.77 6.16 4358.38 35.33 97.38 4307.38 12.94 260.55 247.04 2.76 4451.70 37.90 98.39 4382.28 5.29 315.68 302.15 2.83 4545.77 41.24 100.58 4454.79 -4.62 374.76 361.69 3.85 4638.00 46.24 102.58 4521.40 -17.47 437.19 425.25 5.62 4731.87 49.71 104.70 4584.24 -33.94 504.93 494.91 4.06 4825.26 54.84 106.76 4641.37 -54.00 575.99 568.75 5.76 4918.73 59.65 108.63 4691.93 -77.92 650.84 647.29 5.41 5013.23 63.25 108.88 4737.08 -104.61 729.43 730.18 3.82 5106.97 64.43 108.49 4778.41 -131.56 809.13 814.21 1.31 5200.56 63.62 108.07 4819.40 -157.95 889.02 898.28 0.95 5295.45 62.65 107.68 4862.28 -183.94 969.58 982.87 1.09 5388.76 63.89 107.03 4904.25 -208.79 1049.12 1066.18 1.47 5482.67 62.51 108.13 4946.59 -234.10 1129.03 1149.97 1.800 5576.50 63.33 108.20 4989.31 -260.15 1208.41 1233.44 0.88 5670.66 62.37 109.62 5032.27 -287.30 1287.67 1317.11 1.69 5763.77 62.57 111.72 5075.31 -316.44 1364.91 1399.38 2.01 5857.83 62.71 112.07 5118.54 -347.59 1442.42 1482.47 0.36 5947.61 63.04 110.47 5159.48 -376.58 1516.88 1562.02 1.63 6041.91 63.27 111.73 5202.06 -406.87 1595.38 1645.80 1.22 6136.12 62.92 110.66 5244.70 -437.24 1673.70 1729.46 1.08 6230.45 63.44 109.77 5287.26 -466.33 1752.70 1813.40 1.01 6324.37 63.34 109.91 5329.32 -494.83 1831.69 1897.17 0.17 6418.15 63.25 108.96 5371.47 -522.70 1910.69 1980.79 0.91 6510.70 62.98 107.41 5413.32 -548.46 1989.11 2063.27 1.52 6605.34 62.63 108.21 5456.58 -574.21 2069.25 2147.40 0.84 6699.37 61.64 107.85 5500.52 -599.94 2148.30 2230.47 1.11 6793.49 58.50 105.41 5547.48 -623.30 2226.43 2312.01 4.02 6881.49 57.46 106.65 5594.14 -643.90 2298.14 2386.62 1.68 6976.48 53.61 106.44 5647.89 -666.20 2373.19 2464.91 4.06 7070.76 53.58 105.76 5703.84 -687.25 2446.10 2540.79 0.58 7165.07 51.02 104.49 5761.51 -706.73 2518.12 2615.40 2.92 7257.13 49.34 106.50 5820.47 -725.60 2586.25 2686.09 2.48 7350.29 44.02 106.28 5884.36 -744.72 2651.25 2753.84 5.71 7442.96 38.13 105.74 5954.19 -761.53 2709.75 2814.70 6.37 7537.81 32.29 105.01 6031.65 -776.04 2762.45 2869.37 6.17 7631.81 28.83 107.99 6112.59 -789.55 2808.27 2917.14 4.02 7725.78 28.40 107.90 6195.08 -803.42 2851.09 2962.11 0.46 P 7768 28.40 107.90 6232.22 -809.59 2870.20 2982.18 0.00 12 ~~~~~ 5.2 Bit Record ConocoPhillips Alaska,tnc. 3N-14A, 3N14A P61 Depth In Total Bit Aug' WOB PP Bit Size Make Type / S# Jets / TFA MD / Footage Hrs R Oh (Klbs) RPM (psi) Wear BHA f t/ r 6" x7° Hughes 0-0-NO-A-X-I-NO- 1 (PDC Bi- Christensen HCM 404 5-11 S 3846 3036 76.4 0-30 70 2500 BHA Center 2 6" x7" Hughes Total 0-0-BU-A-X-I-NN- 1 RR (PDC Bi- Christensen HCM 404 5-11 S 6882 436 hrs: 24.7 0-35 45 3000 W0- Center 72:02 3 6"x7" (bi- Reed, CSDX213S-A/ 1X14,2X10, 7318 450 59 4 2 - 32 60 2600 1-2-ct-ct-x-i-It-td 2 center H calo 3317683 RR 2X9 . ~~~~~ 13 5.3 Mud Record Contractor: MI SWACO Mud T e: LSND CanocoPhillips ~~, ~~. 3N-14A, 3N14A P61 Date Depth MW lPP9) ECD ~PP91 VIS ~s/qt) PV YP Gels FL (cc) FC Sols (%) O/W Ratio Sd (%) pH CI (ml/I) Ca (ml/I) 10/6/07 4689 9.7 10.44 40 10 16 5/6/6 .0 2 7 /93 .125 10.3 250 68 10/7/07 6032 9.7 10.66 40 15 17 5/6/8 3.9 2 8 /92 .125 9.8 250 80 10/8/07 6855 9.6 10.91 41 14 15 4/5/5 3.7 2 8 /92 .125 9.6 300 88 10/9/07 6995 10.0 11.07 41 15 16 5/6/7 3.2 2 9 /94 .125 9.6 300 104 10/10/07 7205 10.2 11.28 43 1$ 15 4/5/7 3.6 2 9 /91 .25 9.7 200 20 10/11/07 7319 10.2 10.2 43 18 14 5/7/8 3.2 2 10.5 /89 .25 9.4 200 20 10/12/07 7768 10.2 10.3 43 18 16 5/7/8 2.8 2 10.5 /89 .2 9.5 200 20 10/13/07 7768 10.2 10.2 42 18 13 5/6/7 3.2 2 10.0 /89 0.2 9.5 200 20 10/14/07 7768 10.0 10.0 38 10 9 3/3/3 2.8 2 9 2/89 0.25 8.7 200 20 10/15/07 7768 10.0 10.0 37 10 9 3/3/3 1.0 2 9 2/89 0.25 9.0 200 20 10/16/07 7768 10.0 10.0 47 11 14 3/3/3 3.4 2 10.0 2/88 0.1 9.5 200 20 10/17/07 7768 10.0 10.0 47 11 14 3/3/3 3.4 2 10.0 2/88 0.1 9.5 200 20 10/18/07 7768 10.0 10.0 44 9 12 3/3/3 3.4 2 9.5 2/89 0.1 9.5 200 20 10/19/07 7768 9.5 9.5 40 7 9 2/3/3 0.0 2 9.0 2/92 0.2 9.0 200 20 10/20/07 4340 9.5 9.94 41 14 12 3/4/6 4.6 2 6.5 2/92 0.25 10.2 200 20 10/21/07 5670 9.5 10.62 46 12 16 6/7/8 3.6 2 7 3/91 0.15 9.92 150 40 10/22/07 7070 9.5 10.68 47 13 19 8/10/15 .0 2 8 1/91 0.2 10.1 100 20 10/23/07 7715 9.5 9.5 45 15 17 8/11/17 2.6 2 8 3/89 0.2 10.1 100 20 Abbreviations MW =Mud Weight WL =Water or Filtrate Loss Ca =Hardness Calcium YP =Yield Point Gels =Gel Strength Sd =Sand content ECD =Effective Circulating Density CI =Chlorides VIS =Funnel Viscosity FC =Filter Cake PV =Plastic Viscosity Sols =Solids O/W =Oil to Water ratio ~~0~~ 14 • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE Oct 07, 2007 DEPTH 4858.00000 PRESENT OPERATION DRILLING TIME 0300 YESTERDAY 4200.00000 24 HOUR FOOTAGE 658 CASING INFORMATION 7"@3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6" PDC-BI CNTR 3543 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 162.9 @ 4458.00000 6.8 @ 4319.00000 70.8 110.68749 FT/HR SURFACE TORQUE 4 @ 4839.00000 0 @ 4411.00000 2.1 3.36025 AMPS WEIGHT ON BIT 17 @ 4311.00000 -5 @ 4247.00000 7.2 4.43160 KLBS ROTARY RPM 93 @ 4735.00000 78 @ 4377.00000. 67.2 90.11353 RPM PUMP PRESSURE 2521 @ 4768.00000 1879 @ 4411.00000 2200.5 2438.52002 PSI DRILLING MUD REPORT DEPTH 4689/4597 MW 9.6 VIS 41 PV 10 YP 15 FL 5.5 Gels 5/6/6 CL- 2150 FC 2 SOL 7 SD 0.125 OIL /93 MBL 10 pH 10.1 Ca+ 68 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 33 @ 4480.00000 3 @ 4323.00000 14.3 TRIP GAS CUTTING GAS 0 @ 4858.00000 0 @ 4858.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) 5436 @ 4856.00000 338 @ 4421.00000 2300.9 CONNECTION GAS HIGH 8u ETHANE (C-2) 53 @ 4847.00000 2 @ 4385.00000 22.4 AVG TR PROPANE (C-3) 15 @ 4847.00000 0 @ 4373.00000 5.3 CURRENT?R BUTANE (C-4) 9 @ 4856.00000 0 @ 4575.00000 1.9 CURRENT BACKGROUND/AVG 15-18u PENTANE (C-5) 0 @ 4858.00000 0 @ 4858.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SANDSTONE, SILTSTONE AND CLAYSTONE WIDTH TRACE CARBONACEOUS INTERBEDS PRESENT LITHOLOGY 20% CLAYSTONE, 30% SILTSTOINE, 50% SAND/SANDSTONE DAILY ACTIVITY Download MWD. Lay down TM collar and UBHO. Change motor, bend to 1.5 degree. Pick up TM, UBHo upload. RIH tto SUMMARY 3755'. Wash to bottom. Drill from 3848'. to 4211' MD, 4184' ND. PJSM. Continue drilling from 4211' MD to 4689' at midnight. Continue drilling to 4858' at 0300hrs. EPOCH PERSONNEL ON BOARD 2 DAILY COST 2135 REPORT BY John Lundy • file://C:\Documents%20and%20Settings~Administrator\My%20Documents\NIy%20 Wells\CONO... .1/10/2009 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPQCH 3N-14A REPORT FOR Pete Wilson DATE Oct 08, 2007 DEPTH 6136 PRESENT OPERATION Drilling TIME 03:16:59 YESTERDAY 4996 24 HOUR FOOTAGE 1140 CASING INFORMATION 7" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 6" PDC/BI CNTR 6-1s 3534 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 218.3 @ 5007.00000 11.8 @ 6006.00000 86.7 89.55892 FT/HR SURFACE TORQUE. 5 @ 5799.00000 0 @ 5483.00000 3.1 4.55999 AMPS WEIGHT ON BIT 21 @ 5678.00000 -2 @ 5943.00000 7.6 7.41750 KLBS ROTARY RPM 96 @ 6032.00000 3 @ 5665.00000 73.8 95.10717 RPM PUMP PRESSURE 2834 @ 6136.00000 2230 @ 5001.00000 2353.9 2834.99194 PSI DRILLING MUD REPORT DEPTH 6032/5197 MW 9.6 VIS 41 PV 12 YP 16 FL 3.9 Gels 4/5/5 CL- 250 FC 2 SOL 8 SD 0.125 OIL /92 MBL 25 pH 9.5 Ca+ 68 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 @ 5561.00000 0 @ 5748.00000 12.8 TRIP GAS CUTTING GAS 0 @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 9677 @ 5714.00000 -88 @ 5748.00000 2628.5 CONNECTION GAS HIGH ETHANE (C-2) 228 @ 5561.00000 0 @ 5748.00000 45.2 AVG PROPANE (C-3) 147 @ 5714.00000 -1 @ 5748.00000 27.8 CURRENT BUTANE (C-4) 124 @ 5714.00000 -1 @ 5748.00000 23.5 CURRENT BACKGROUND/AVG 11-13 PENTANE (C-5) 86 @ 5714.00000 0 @ 5748.00000 16.5 HYDROCARBON SHOWS TRACE FLUORESCENCE AT 5300', NO SHOW INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY sANDSTON E INTERBEDDED WITH SILTSTONE AND THIN CARBONACEOUS SHALES PRESENT LITHOLOGY 70% SANDSTONE/SAND; 30 % SILTSTONE DAILY ACTIVITY SUMMARY DRILLING FROM 4689 TO 5985' AT MIDNIGHT EPOCH PERSONNEL ON BOARD 2 DAILY COST 2135.00 REPORT BY JOHN LUNDY • file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20Wells\CONO... 1 /10/2009 Daily Report • • Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR MIKE WILSON DATE Oct 09, 2007 DEPTH 6869 PRESENT OPERATION DRILLING TIME 03:55:28 YESTERDAY 6289 24 HOUR FOOTAGE 580 CASING INFORMATION 7" @ 3543' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6" PDC-BI-CNTR 6-11s 3534 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG. RATE OF PENETRATION 217.1 @ 6696.00000 2.7 @ 6858.00000 .63.2 5:28002. FT/HR SURFACE TORQUE 6 @ 6422.00000 0 @ 6669.00000. 3.6 0.00000 AMPS WEIGHT ON BIT 30 @ 6850.00000 -5 @ 6382.00000 8.2 19.10557 KLBS ROTARY RPM 96 @ 6458.00000 75 @ 6690.00000 75.0 0.00000 RPM PUMP PRESSURE 3364 @ 6862.00000 51 @ 6382.00000 2814.3 3262.64795 PSI DRILLING MUD REPORT DEPTH 7000/5580 MW 10.0 VIS 41 PV 14 YP 17 FL 3.6 Gels 5/5/6 CL- 250 FC 2 SOL 9 SD 0.125 OIL /91 MBL 30 pH 9.6 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW .AVERAGE DITCH GAS 26 @ 6476.00000 2 @ 6382.00000 11.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 4024 @ 6467.00000 428 @ 6382.00000 1904.6 CONNECTION GAS HIGH ETHANE (C-2) 92 @ 6467.00000 9 @ 6382.00000 42.0 AVG PROPANE (C-3) 27 @ 6467.00000 3 @ 6382.00000 1.2.3 CURRENT BUTANE (C-4) 22 @ 6291.00000 2 @ 6382.00000 8.6 CURRENT BACKGROUND/AVG 6u PENTANE (C-5) 18 @ 6357.00000 1 @ 6857.00000 7.7 HYDROCARBON SHOWS HONE INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SAND/SANDSTONE, SHALE AND SILTSTONE PRESENT LITHOLOGY 40% SAND, 40% SILTSTONE, 20% SHALE DAILY ACTIVITY SUMMARY DRILLING FROM 5985' TO 6565' MD, 5432' ND. PJSM. DRILLING FROM 6565' TO 6844' ND 5571' EPOCH PERSONNEL ON BOARD 2 DAILY COST 2135.00 REPORT BY JOHN LUNDY • file://C:\Documents%ZOand%20Settings\Administrator\1VIy%20DocumentsuVly%20Wells\CONO... 1 /10/2009 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE Oct 10, 2007 DEPTH 7002.00000 PRESENT OPERATION DRILLING TIME 03:30:20 YESTERDAY 6878.00000 24 HOUR FOOTAGE 124 CASING INFORMATION 7" @ 3543' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 6" PDC BI-CNTR (7") 6-11s 3543 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 115.9 @ 6969.00000 5.1 @ 6998.00000 34.9 8.33310 FT/HR SURFACE TORQUE 5 @ 6916.00000 0 @ 6943.00000 2.7 4.66331 AMPS WEIGHT ON BIT 27 @ 6939.00000 9 @ 6969.00000 17.4 14.93840 KLBS ROTARY RPM 98 @ 6878.00000 43 @ .6993.00000 52.3 64.51823 RPM PUMP PRESSURE 3275 @ 6880.00000 2695 @ 6970.00000 2878.1 2883.47900 PSI DRILLING MUD REPORT DEPTH 6995/5656 MW 10.0 VIS 43 PV 13 YP 15 FL 3.2 Gels 4/5/6 CL- 250 FC 2 SOL 9.5 SD 0.125 OIL /91 MBL 35 pH 10.0 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 67 @ 6974.00000 3 @ 7002.00000 24.8 TRIP GAS 100 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY swab 15u METHANE (C-1) 0 @ 7002.00000 0 @ 7002.00000 0.0 CONNECTION GAS HIGH 19 ETHANE (C-2) 0 @ 7002.00000 0 @ 7002.00000 0.0 AVG 19 PROPANE (C-3) 0 @ 7002.00000 0 @ 7002.00000 0.0 CURRENT 19 BUTANE (C-4) 0 @ 7002.00000 0 @ 7002.00000 0.0 CURRENT BACKGROUND/AVG 9 PENTANE (C-5) 0 @ 7002.00000 0 @ 7002.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LlTHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SAND/SANDSTONE; SILTSTONE AND SHALE WITH TRACE CARBONACEOUS INTERBEDS PRESENT LITHOLOGY 20% SAND/SANDSTONE; 50% SILTSTONE; 30% SHALE DRILLING FROM 6844 TO 6882', 5595' ND. CIRCULATE BOTTOMS UP. MONITOR WELL (STATIC): PULL OUT OF THE DAILY HOLE TEN STANDS. OK. OK PUMP DRY JOB. PULL OUT OF THE HOLE TO BHA. STAND BACK HWDP AND JARS TO ACTIVITY 110'. LAY DOWN BHA TO COLLAR. PULL UP AND BREAK OFF BIT. PJSM. C/O & SET MOTOR TO 1.5 DEGREES. C/O SUMMARY FLOAT. MAKE UP BIT AND PICKUP HOC. PROGRAM MWD (MONITOR WELL STATIC). RUN IN HOLE WITH BHA #4. ENTER WINDOW CLEAN. BREAK CIRCULATION AT 3658'. TEST MWD AND CONTINUE TO RUN IN HOLE. BREAK CIRCULATION AT 6752'. WASH AND REAM 6752 TO 6882', ND 5648'. DRILL. EPOCH PERSONNEL ON BOARD 2 DAILY COST 2135 REPORT BY JOHN LUNDY • file://C:\Documents%20and%20 S ettings\Administrator\My%20Documents\My%20 Wells\CONO... 1 / 10/2009 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE Oct 11, 2007 DEPTH 7279.00000 PRESENT OPERATI ON DRILLING AHEAD. TIME 06:00:03 YESTERDAY 7002.00000 24 HOUR FOOTAGE 277 CASING INFORMATION 7"@3543" DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7165.07 51.02 104.70 5761.51 BIT INFORMATION .INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 6" PDC BI-CENTER 7" 6X11 3543' 1362' 76.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 73.9 @ 7256.00000 4.5 @ 7195.00000 20.9 18.76085 FT/HR SURFACE TORQUE 5 @ 7078.00000 0 @ 7072.00000 2.6 0.00000 AMPS WEIGHT ON BIT 34 @ 7154.00000 3 @ 7267.00000 20.9 15.89340 KLBS ROTARY RPM 95 @ 7004.00000 0 @ 7148.00000 43.9 0.00000 RPM PUMP PRESSURE 3026 @ 7183.00000 1950 @ 7013.00000 . .2598.0 .2311.64404 PSI DRILLING MUD REPORT DEPTH MW 10.2 VIS 43 PV 18 YP 15 FL 112 Gels 4/5/7 CL- 200 FC 2/ SOL 9.0 SD 0,25 OIL 1/91 MBL 30.0 pH 9.7 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 7187.00000 1 @ 7272.00000 13.8 TRIP GAS 0 CUTTING GAS 0 @ 7279.00000 0 @ 7279.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm} SURVEY 0 METHANE (C-1) 6691 @ 7222.00000 321 @ 7003.00000 2203.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 200 @ 7222.00000 8 @ 7003.00000 65.9 AVG 0 PROPANE (C-3) 64 @ 7187.00000 3 @ 7003.00000 22.7 CURRENT 13 BUTANE (C-4) 34 @ .7187.00000 3 @ 7003.00000 12.1 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 18 @ 7187.00000 2 @ 7089.00000 7.5 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SILTY/BRACES TO SHALES WITH SAND/SANDSTONE LAYERS. PRESENT LITHOLOGY SHALE 40%, SILTSTONE D40%, SAND 10%, AND SANDSTONE 10%. DAILY ACTIVITY DRILLING AHEAD. PUMPED CUBE PILL AT 7000 FT. AND A SWEEP AT 7075 FT. MAX GAS 40 u. CONTINUING SUMMARY TO DRILL AT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E. BLEYS • file://C:\Documents%20and%20 Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1/10/2009 Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPQCH 3N-14A REPORT FOR PETE WILSON DATE Oct 12, 2007 DEPTH 7361.00000 PRESENT OPERATION DRILLING AHEAD TIME 06:00:16 YESTERDAY 7279.00000 24 HOUR FOOTAGE 82 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7165..07 51.02 104.70 5761.51 BIT INFORMATION INTERVAL CONDITION REASON N0. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.00 HYCALOG PDC BI-CENTER 3317683 1X14,2X10,2X9 7319 82 3.06 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 60.0 @ 7287.00000 3.9 @ 7317.00000 19.7 11.68934 FT/HR SURFACE TORQUE 5 @ 7321.00000 0 @ 7339.00000 1.2 0.00000 AMPS WEIGHT ON BIT 24 @ 7316.00000 3 @ 7320.00000 13.3 22.57242 KLBS ROTARY RPM 85 @ 7305.00000 12 @ 7318.00000 .20.3 0.00000 RPM PUMP PRESSURE 23030 @ 7280.00000 2219 @ 7317.00000 6434.6 2876.58398 PSI DRILLING MUD REPORT DEPTH MW 10.2 VIS 43 PV 18 YP 14 FL 108 Gels 5/7/8 CL- 200 FC 2/ SOL 10.5 SD 0.25 OIL 0.0 MBL 30 pH 10.5 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 72 @ 7322.00000 9 @ 7344.00000 24.1 TRIP GAS 38 CUTTING GAS 0 @ 7361.00000 0 @ 7361.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 11321 @ 7322.00000 1739 @ 7310.00000 3943.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 365 @ 7322.00000 51 @ 7329.00000 132.9 AVG 0 PROPANE (C-3) .150 @ 7322.00000 18 @ 7329.00000 54.4 CURRENT 20.0 BUTANE (C-4) 95 @ 7322.00000 11 ca 7337.00000 33.4 CURRENT BACKGROUND/AVG 12 PENTANE (C-5) 44 @ 7322.00000 2 @ 7331.00000 14.4 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SAND AND SANDSTONES WITH SILTSTONE AND SHALES. PRESENT LITHOLOGY SILTSTONE 50%, SAND 20%, SANDSTONE 20%, AND SHALE 10%. DAILY ACTIVITY REPLACED BIT AND MADE UP BOTTOM HOLE ASSEMBLY. PICKED UP TOOLS AND TRIPPED INTO HOLE TO 7318 SUMMARY FT. CIRCULATED GASES AND COMMENCED DRILLING AHEAD. STILL DRILLING AT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E. BLEYS • file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1 /10/2009 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE OCT 13 2007 DEPTH 7767.00000 PRESENT OP ERATION TRIPPING OUT OF HOLE. TIME 12:00:00 YESTERDAY 7361.00000 24 HOUR FOOTAGE 406 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.40 107.90 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.00" HYCALOG PDC BI-CENTER 3317683 1X14, 2X10, 2X9 7319' 488' 10.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 120.0 @ 7681,00000 10.8 @ 7758.00000 63.8 55.32500 FT/HR SURFACE TORQUE 6 @ 7758.00000 0 @ 7586.00000 3.8 5.53100 AMPS WEIGHT ON BIT 32 @ 7578.00000 -2 @ 7506.00000 9.2 6.96300. KLBS ROTARY RPM 87 @ 7689.00000 61 @ 7759.00000 62.8 80.68200 RPM PUMP PRESSURE 2998 @ 7710.00000 2282 @ 7759.00000 2659.4 2830.02600 PSI DRILLING MUD REPORT DEPTH MW 10.2 VIS 43 PV 18 YP 16 FL 95 Gels 5/7/8 CL- 200 FC 2/ SOL 10.5 SD 0.2 OIL 0.0 MBL 32.5 pH 10.5 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 82 @ 7475.00000 11 @ 7383.00000 43.6 TRIP GAS 0 CUTTING GAS 0 @ 7767.00000 0 @ 7767.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 14329 @ 7473.00000 3178 @ .7458.00000 7552.7 CONNECTION GAS HIGH 55 ETHANE (C-2) 634 @ 7473.00000 131 @ 7458.00000 316.6 AVG 31.6 PROPANE (C-3) 253 @ 7707.00000 49 @ 7458.00000 133.1 CURRENT 0 BUTANE (C-4) 147 @ 7707.00000 22 @ 7458.00000 64.9 CURRENT BACKGROUND/AVG 16 PENTANE (C-5) 63 @ 7707.00000 6 @ 7413.00000 26.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SHALE 60%, AND SILSTONE 40%. DAILY ACTIVITY DRILLED TO 7767 FT. PUMPED HIGH VISCOUS SWEEP. PULLED FIFTEEN STAND SHORT TRIP. PUMPED HIGH SUMMARY VISCOUS SWEEP. COMMENCED PULLING OUT OF THE MOLE. STILL PULLING OUT AT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E. BLEYS • file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1/10/2009 • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE 10/14/07 DEPTH 7767.00000 PRESENT OPERATION CIRCULATING TIME 5:15:00 YESTERDAY 7767,00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.4 107.9 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.00" HYCALOG PDC BI-CENTER 3317683 1X14, 2X10, 2X9 7319 488 10.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ pSl DRILLING MUD REPORT DEPTH 7767 MW 10.2 VIS 42 PV 18 YP 13 FL MBL Gels 5/6/7 CL- 200 FC 2/ SOL 10 SD .2 OIL 0.0 MBL 30 pH 9.5 Ca+ 20 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 96 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 18 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 14 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SHALE 60% AND SILTSTONE 40% DAILY ACTIVITY Pulled out of hole and laid down BHA. Rigged up tools for liner and run in hole with liner. Circulated liner volume @ 3520' SUMMARY MD. Made up liner hanger and ran in hole on drill pipe. Circulated liner volume, still circulating at report time. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY Michael Marsh file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1 /10/2009 • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE 10/15/07 DEPTH 7767.00000 PRESENT OPERATION TRIPPING OUT TIME 05:30:00 YESTERDAY 7767.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.4 107.9 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.00" HYCALOG PDC BI-CENTER 3317683 1X14, 2X10, 2X9 .7319 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7767 MW 10 VIS 38 PV 10 YP 9 FL 2.8 Gels 3/3/3 CL- 200 FC /2 SOL 9 SD .25 OIL 0 MBL 20 pH 8.7 Ca+ 20 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 33 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 10 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SHALE 6 0% AND SILTSTONE 40% DAILY ACTIVITY Attempted to free liner string, spot 9.9 ppg 6% Lube pill in open hole annulus. Lower mud weight to 10.0 ppg. Liner string - hole: Latched onto Parted at running tool. Pulled out of hole & laid down running tool. Made up fishing assembly and ran in SUMMARY fish and established circulation. Worked fish. Hole packed off and circulation lost. Worked fish. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY Mike Marsh • file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1/10/2009 • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR PETE WILSON DATE 1.0/16/07 DEPTH 7767.00000 PRESENT OPERATION TRIPPING OUT TIME 05:15:00 YESTERDAY 7767.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.4 107.9 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6.00" HYCALOG PDC BI-CENTER 3317683 1X14, 2X10, 2X9 7319 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7767 MW 10.0 VIS 37 PV 10 YP 9 FL 2.8 .Gels 3/3/3 CL- 200 FC /2 SOL 9 SD .25 OIL 0 MBL 25 pH 9.0 Ca+ 20 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 101 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 21 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SHALE 60% AND SILTSTONE 40% DAILY ACTIVITY Continued to work fish with no returns. Released from fish and pulled out of hole. Made up shooting flange. Ran in hole with SUMMARY wireline and cut liner at 6867' measured depth. Laid down wireline. Made up fishing assembly and ran into hole. Latched onto fish and worked with minimal returns. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY Mike Marsh • file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1 / 10/2009 Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR DEARL GLADDEN . DATE 10/18/07 DEPTH 7767.00000 PRESENT OPERATION FISHING TIME 05:15:00 YESTERDAY 7767.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.4 107.9 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7767 MW 10.0 VIS 44 PV 9 YP 12 FL 3.4 Gels .3/3/3 CL- 200 FC /2 SOL 9.5 SD .1 OIL 2/89. MBL 25 pH 9.5 Ca+ 20 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT. 1 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 9 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SHALE 60% AND SILTSTONE 40% DAILY Made up second cutter. Ran in hole. Attempted cut (misfired). Pulled out of hole. Made up new charge: Ran in hole and cut ACTIVITY liner at 3520' measured depth. Pulled out of hole. Rigged dowh wireline. Made up fishing assembly. Ran in hole. Latched onto SUMMARY fish number 1. Pulled out of hole. Laid down bore head assembly and fish (656'). Tested blow out preventers. Made up fishing assembly. Ran in hole. Worked on fish number 2. Began lowering mud weight to 9.5 ppg. Max gas 164 total units. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY Mike Marsh file://C:\Documents%20and%20Settings\Administrator\My%20Documents\My%20 Wells\CONO... 1/10/2009 • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPQCH 3N-14A REPORT FOR DEARL GLA DDEN DATE 10/19/07 DEPTH 7767.00000 PRESENT OPERATION RUNNING WIRELINE TIME 05:15:00 YESTERDAY 7767.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.4 107.9 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7767 MW 9.5 VIS 40 PV 7 YP 9 FL 4.2 Gels 2/3/3 CL- 200 FC /2 SOL 7 SD .2 OIL 2/92 MBL 22.5 pH 9.0 Ca+ 20 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SHALE 60% AND SILTSTONE 40% Continued to work fish #2. Pumped nut plug marker pill to verify circulation depth. Spotted black magic pill in open hole DAILY annulus. Pulled out of hole. Changed out jars. Ran in hole and worked fish witho ut success. Pulled out of hole. Laid down ACTIVITY fishing assembly. Rigged up and ran in hole with wireline. Cut liner at 5040'. Pull ed out of hole. Made up new cutter. Ran in SUMMARY hole. Attempted cut (misfire). Pulled out of hole. Changed out cutter. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY Mike Marsh file://C:~Documents%20and%20 Settings~Administrator~lVly%20Documents~lVly%20 Wells\CONO... 1 / 10/2009 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR DEARL GLADDEN DATE 10/20/07 .DEPTH 7767.00000 PRESENT OPERATION TRIPPING OUT TIME 05:15:00 YESTERDAY 7767.00000 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7725 28.4 107.9 6195.08 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7767 MW 9.5 VIS 40 PV 7 YP 10 FL 4 Gels 2/3/3 CL- 200 FC /2 SOL 7 SD .2 OIL 2/92 MBL 17.5 pH 9.0 Ca+ 20 CCI 0 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE INTERBEDDED WITH TUFFACEOUS SILTSTONE. PRESENT LITHOLOGY SH ALE 60% AND SILTSTONE 40% Ran into hole with wireline. Attempted cut at 4310' measured depth (misfired). Pulled out of hole. Changed out cutter. DAILY Ran in hole. Attempted cut (misfired). Pulled out of hole. Changed out cutter. Ran in hole. Cut liner at 4310' measured ACTIVITY depth. Pulle d out of hole. Rigged down wirellne. Made up fishing assembly . Ran in hole. Latched onto fish. Pulled fish SUMMARY free. Pulled out of hole. Laid down fishing assembly and liner. Picked up 3. 5"cement stringer. Ran in hole. Cleaned out 25' liner inner diameter. Conditioned mud for cement job. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY MIKE MARSH file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/20/2007 • s Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT r-+,~QC;H 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 21, 2007 DEPTH 4378.00000 PRESENT OPERATION DRILLING AHEAD. TIME 00:53:18 YESTERDAY 3901.00000 24 HOUR FOOTAGE 477 CASING INFORMATION 7"@3543' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4353 30.7 102.1 4313.9 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 7"CUT 6.0" OD HYCALOG PDC BI CENTER 3318248 1X12,2X11,2X9 4032' 47T 6.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 208.5 @ 4246.00000 26.4 @ 4032.00000 62.4 67.87458 FT/HR SURFACE TORQUE 4 @ 4374.00000 0 @ 4119.00000 0.9 2.95001 AMPS WEIGHT ON BIT 16 @ 4376.00000 0 @ 4119.00000 5.8 12.32096 KLBS ROTARY RPM 81 @ 4376.00000 48 @ 4263.00000 18.0 79.69012 RPM PUMP PRESSURE 2231 @ 4375.00000 1547 @ 4038.00000 1300.8 2093.28101 PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 41 PV 14 YP 12 FL 4.6 Gels 3/4/6 CL- 200 FC /2 SOL 6.5 SD 0.25 OIL 2/92 MBL 17.5 pH 10.2 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 146 @ 4241.00000 0 @ 4200.00000 12.4 TRIP GAS 0 CUTTING GAS 0 @ 4378.00000 0 @ 4378.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 6545 @ 4272.00000 1340 @ 4326.00000 937.1 CONNECTION GAS HIGH 0 ETHANE (C-2) 26 @ 4370.00000 0 @ 4248.00000 3.5 AVG 0 PROPANE (C-3) 1 @ 4378.00000 0 @ 4248.00000 0.2 CURRENT 34 BUTANE (C-4) 0 @ 4378.00000 0 @ 4378.00000 0.0 CURRENT BACKGROUND/AVG 28 PENTANE (C-5) 0 @ 4378.00000 0 @ 4378.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SILTSTONE, SAND, SANDSTONE, AND CLAYSTONE PRESENT LITHOLOGY SAND 50%, SILTSTONE 30%, SANDSTONE 10%, AND CLAYSTONE 10%. DAILY ACTIVITY TRIPPED IN HOLE TAGGED CEMENT AND PULLED UP TO WAIT FOR CEMENT TO CURE. DRILLED OFF SUMMARY INTO FORMATION AT 4032 FT. BEGAN SLIDING AND ROTATING TO GAIN ANGLE. STILL DRILLING AT REPORT TIME. EPOCH PERSONNEL ON BOARD 3 DAILY COST $2515.00 REPORT BY HARRY E. BLEYS • file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/21/2007 ~~ Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 22, 2007 DEPTH 5900.00000 PRESENT OPERATION DRILLING AHEAD. TIME 05:15:02 YESTERDAY 4378.00000 24 HOUR FOOTAGE 1522 CASING INFORMATION 7"@3543' DEPTH INCLINATION AZIMUTH. VERTICAL DEPTH SURVEY DATA 5853 64.13 106.87 5193.53 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 7"cut 6"OD Hycalog PDC BI-CENTER 3318248 1X12,2X11,2X9 4032 1999 26.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 982.0 @ 5616.00000 4.7 @ 4584.00000 88.5 31.68568 FT/HR SURFACE TORQUE 6 @ 5390.00000 0 @ 5040.00000 0.9 0.07601 AMPS WEIGHT ON BIT 24 @ 5477.00000 0 @ 4434.00000 13.8 12.91910. KLBS ROTARY RPM 94 @ 5724.00000 7 @ 5162.00000 62.0 89.97381 RPM PUMP PRESSURE 2827 @ 5801.00000 1843 @ 4445.00000 2398.7 2802.33789 PSI DRILLING MUD REPORT DEPTH MW 9.5 VIS 46 PV 46 YP 12 FL 3.6 Gels 6/7/8 CL- 150 FC /2 SOL 7 SD 0.15 OIL 3/91 MBL 20.0 pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 40 @ 5110.00000 1 @ 4747.00000 16.5 TRIP GAS 0 CUTTING GAS 0 @ 5900.00000 0 @ 5900.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7706 @ 5110.00000 332 @ 4747.00000 2950.0 CONNECTION GAS HIGH 14 ETHANE (C-2) 136 @ 5476.00000 1 @ 4634.00000 38.6 AVG 7.3 PROPANE (C-3) 47 @ 5476.00000 0 @ 4580.00000 14.5 CURRENT 3 BUTANE (C-4) 38 @ 5110.00000 0 @ 4635.00000 9.8 CURRENT BACKGROUND/AVG 8 PENTANE (C-5) 23 @ .5459.00000 0 @ 4754.00000 6.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SANDS AND 51LTSTONES. PRESENT LITHOLOGY SAND 60%, AND SILTSTONE 40% DAILY ACTIVITY DRILLED BY ROTATING AND SLIDING FROM 4032 FT TO 5900 FT. PUMPED SWEEP AT 18:00 HOURS. SUMMARY STILL DRILLING AT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E. BLEYS file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/22/2007 • • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT F,PQCH 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 23, 2007 DEPTH 7171.00000 PRESENT OPERATION DRILLING AHEAD. TIME 05:15:00 YESTERDAY 5900.00000 24 HOUR FOOTAGE 1271 CASING INFORMATION 7"@3543 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7070 53.14 107.12 5758.73 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 6" HYCALOG PD C BI-CENTER 3318248 1X12,2X11,2X9 4032 3270 45 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 189.8 @ 6637.00000 6.3 @ 6925.00000 82.8 57.30750 FT/HR SURFACE TORQUE 5 @ 6473.00000 0 @ 7030.00000 2.3 3.85575 AMPS WEIGHT ON BIT 29 @ 6936.00000 4 @ 6854.00000 13.7 11.69890. KLBS ROTARY RPM 94 @ 7140.00000 0 @ 6938.00000 79.1 93.09607 RPM PUMP PRESSURE 3187 @ 7100.00000 2253 @ 6007.00000 2883.7 2995.66992. PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 36 @ 7009.00000 0 @ 6558.00000 15.6 TRIP GAS 0 CUTTING GAS 0 @ 7171.00000 0 @ 7171.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 6383 @ 7009.00000. 184 @ 6558.00000 2998.4 CONNECTION GAS HIGH 20 ETHANE (C-2) 141 @ 7161.00000 4 @ 6558.00000 62.4 AVG 13 PROPANE (C-3) 37 @ 7161.00000 1 @ 6558.00000 16.9 CURRENT 28 BUTANE (C-4) 139 @ 6248.00000 0 @ 6804.00000 25.7 CURRENT BACKGROUND/AVG 19 PENTANE (C-5) 4 @ 5952.00000 0 @ 6066.00000. 0.3 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SILTSTONE, SAND ,AND SANDSTONE PRESENT LITHOLOGY S ILTSTONE 8J0%, SAND 10%, AND SANDSTONE 10%. DAILY ACTIVITY CONTINUING TO DRILL AND SLIDE FROM 5900 FT. TO 717,1 FT. STILL DRILLING AT REPORT SUMMARY TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E. BLEYS • file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/23/2007 `..~ • Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPD~H 3N-14A BP1 REPORT FOR DEARL GLADDEN PRESENT TRIPPING IN HOLE WITH CLEANING BHA TO Oct 24, DATE DEPTH 7715.00000 OPERATION BOTTOM. 2007 TIME 05:15:00 YESTERDAY 7171.00000 24 HOUR 544 FOOTAGE CASING INFORMATION 7" @ 3543 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7678 33.75 104.38 6201.14 INTERVAL CONDITION REASON BIT INFORMATION S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NO. SIZE TYPE 3 6" HYCALOG PDC BI-CENTER 3318248 1X12,2X11,2X9 4032 3814 51.4 CASING TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 190.6 @ 7704.00000 11.0 @ 7552.00000 79.4 94.6521.5 FT/HR SURFACE TORQUE 6 @ 7704.00000 0 @ 7593.00000. 3.6 5.51261 AMPS WEIGHT ON BIT 26 @ 7593.00000 1 @ 7698.00000 10.4 5.80110 KLBS ROTARY RPM 94 @ 7426.00000 9 @ 7676.00000 73.9 90.42761 RPM PUMP PRESSURE 3232 @ 7189.00000 2627 @ 7387.00000 2994.7 2952.19604 PSI DRILLING MUD REPORT DEPTH 7715 MW 9.5 VIS 45 PV 15 YP 17 FL 2.5 Gels .7/10/16 CL- 100 FC 1/ SOL 8 SD 0.2 OIL 3/89 MBL 40 pH 10.1 Ca+ 100 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 91 @ 7380.00000 15 @ 7198.00000 43.7 TRIP GAS 0 CUTTING GAS 0 @ 7715.00000 0 @ 7715.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 15667 @ 7415.00000 2449 @ 7198.00000 7717.9 CONNECTION GAS HIGH 46 ETHANE (C-2) 610 @ 7415.00000 73 @ 7633.00000 260.0 AVG 30 PROPANE (C-3) 207 @ 7415.00000 20 @ 7198.00000 92.6 CURRENT 20 4 C 00000 7 @ 7198.00000 49.4 104 @ 7662 CURRENT BACKGROUND/AVG 19 ) - BUTANE ( . PENTANE (C-5) 27 @ 7415.00000 0 @ 7627.00000 7.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SHALE AND SILTSTONE PRESENT LITHOLOGY 60% SILTSTONE, 30% SHALE AND 10% SANDSTONE DAILY ACTIVITY Continue drilling and sliding from 7171 ft. to 7715 ft. Pump hi-vis sweep, short trip (15 stands), pump hi-vis SUMMARY sweep, POOH, L/D BHA, M/U clean out BHA„ run in hole. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895 REPORT BY HARRY E. BLEYS file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/24/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR Dearl Glad den DATE Oct 25, 2007 DEPTH 7715 PRESENT OPERATION RIH W 5.5" liner TIME 03:20:39 YESTERDAY 7715 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3543' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7715/6232 MW 9.5 VIS 47 PV 16 YP 14 FL 2.6 Gels .7/19/14 CL- 100 FC /2 SOL 7 SD 2 OIL .3/90 MBL 35 pH 9.8 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 37 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 18 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SHALE AND SITLSTONE PRESENT LITHOLOGY SILTSTONE 60% SHALE 30% AND SANDSTONE 10% DAILY ACTIVITY Continue tirip into hole with liner on 4" drill pipe circulating down 1 stand every 5 at 20 spm/500 psi to SUMMARY 3281' EPOCH PERSONNEL ON BOARD 4 DAILY COST 2895.00 REPORT BY Harry Bleys • file://C:\Documents%20and%20Settings\Administrator\Desktop\20071027.htm 11/7/2007 • Daily Report Page 1 of 2 CONOCOPHILLIPS DAILY WELLSITE REPORT E' PQCH 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 26, 2007 DEPTH 7715.00000 PRESENT OPERATION MAKING UP BOTTOM HOLE ASSEMBLY. TIME 5:15:00 YESTERDAY 7715.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7"@3543' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7678' 33.75 104.38 6021.14 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.6 VIS 46 PV 20 YP 21 FL 3.6 Gels 6/7/8 CL- 1100 FC 1/ SOL 18 SD 0 OIL 0.5/81.5 MBL 5 pH 5 Ca+ 600 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SHALE AND SILTSTONE. PRESENT LITHOLOGY SILTSTONE 60%, SHALE 30%. AND SANDSTONE 10%. Continue to trip in hole with liner on 4" drill pipe. Circulate down every 5th stand at 2 BBLS/min. Rig up cement head. Circulate and condition mud, staged up to 4.5 BBLS/min. Performed pre-job safety meeting on cement job. Had trouble (0430-0700). During circulation, waited on cementers, started having losses, pumped LCM @ reduced rate of 3 BBLS/min (total loss while circulating = 53 BBLS). Cement, 10 BBLS H2O, test lines 3500 psi, 15 BBLS cement, wash, 15 BBLS 10.5 ppg mud push, 41 BBLS. Lead, 17 BBLS tail, 5 BBLS H2O, 137.7 displace CIP @ 1100 hours. Set DAILY hanger with 3400 psi, 25K down weight, released from tool with 15 right hand turns. Pick up two foot. Circulate 20 BBLS ACTIVITY with stinger in tie black sleeve. Circulate bottoms up at 5 BBLS/min 500 psi. Rig down cement head, stand one stand to SUMMARY 3281'. Reverse circulate string volume at 2 BPM, 2000 psi. Monitor well static. Pull out of hole on elevators from 3281' to surface, lay down running tool. Clear and clean floor. Wear bushing took several attempts to pull, conditions fouled. Pre job safety meeting and hazard assesment on changing rams. Pull bottom set of 4" rams from bore stack and install 2 7/8" rams in their place. Rig up and test bottom 2 7/8" pipe rams, 2 7/8" floor and dart valves 250psi low, 5000psi high, 2 7/8" and annular 250 psi low, 3500 psi high. 5 min each, on chart. Pull test plug, install new wear bushings with same 6 3/8" ID. Clearfloor of all unnecessary tools. Pickup 2 7/8" handling tools from slide. Pick up 2 7/8"tools from slide. Rig file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/26/2007 Daily Report Page 2 of 2 up power tongs, 2 7/8" rig tongs and elevators. Conduct pre job safety meeting and make up bottom hole assembly number 16 to MWD HOC, dies slipping on crummies, replace same. r~ • EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E: BLEYS file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/26/2007 Daily Report Page 1 of 2 CONOCOPHILLIPS DAILY WELLSITE REPORT EPQCH 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 27, 2007. DEPTH 7715.00000 PRESENT OPERATION COMMENCED DRILLING INTO NEW FORMATION TIME 05:00:21 YESTERDAY 7715.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7"@3543" 5.5"@3372' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7678 33.75 104.38 6021:14 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 4.750. HUGHES HC 404ZX 7010257 7715 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW 12.7 VIS 48 PV 21 YP 20 FL 3.5 Gels 6/7/8 CL- 1100 FC 2 SOL 7.5 SD 0.0 OIL 1/82 MBL 5.0 pH 10.0 Ca+ 580 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 00 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SILTSTONE, SHALE AND SANDSTONE. PRESENT LITHOLOGY SILTSTONE 60%, SHALE 30%, AND SANDSTONE 10%: Perform job safety meeting. Retorque bit and make up bottom hole assembly as float sub, stabilizer,crossovers, mwd tools and pick up mwd sssewr, mwd flow tub and nim crossover. Plug in and upload mwd. Continue to make up bottom hole assembly. Tested mwd at 29 strokes per minute at 1130 psi and recieved weak test. Will try deeper. Pick up 24 joints of 2 7/8 pipe. Tested mwd again. 1104 psi at 44 stks/ min 2450 psi good test. Pull out of hole wet from 1104 ft. to DAILY bit. Hold pre safety job meeting. Run in hole with bha at 400 ft. with 29 sks/min, 1130 psi, and blow down and monitor ACTIVITY well static. Continue to run in hole and pick up 2 7/8 drill pipe. Fill drill pipe at 31.00 ft. and at 5292 ft. A 156 joints total. SUMMARY Pick up 81 K over pulling weight of 76K right 80k, torque at 30 rpm, 1 k-1900psi@30spm. Rig down power tongs and clean floor. Run in hole with 4 inch drill pipe. Break circulation @7540 and tag @ L.C. @7577 ft. Pick up weight of 110k over weight of 91 k rt wt. Circulate ari out 130 gpm /2800psi. (.5 muc weight in and out. Pull out of hole to 7540 ft. Blow down T.D. Rig up and test casing at 2500 psi for thirty minutes. Rig down blow down. Drill plugs at LC for thirty minutes at WOB of 2-3 k of 40 RPM@2k torque 110 gpmand 2100psi. Continue to drill cement to 7585 ft. with 118 gpm and 2350 psi. Drilled out of cement into formation. No samples back yet. Continuing to drill ahead for 10 - 20 ft. file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/27/2007 Daily Report. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895 REPORT BY HARRY E. BLEYS Page 2 of 2 file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/27/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT El ~~H 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 28, 2007 DEPTH 8130.00000 PRESEN T OPERATION DRILLING AHEAD. TIME 05:00:55 YESTERDAY 7715.00000 24 HOUR FOOTAGE 415 CASING INFORMATION 7"@3543 5.5@4338' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8063 35.2 103.3 6516.4 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 4.75 Hughs HC 404ZX 7010257 7716 415 15 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 94.7 @ 7715.00000 4.6 @ 7797.00000 38.8 42.20800 FT/HR SURFACE TORQUE 5 @ 7715.00000 0 @ 7824.00000 2.7 2.43524 AMPS WEIGHT ON BIT 34 @ 8100.00000 0 @ .7810.00000 8.0 21.11000 KLBS ROTARY RPM 99 @ 7724.00000 11 @ 7948.00000 54.5 67.99543 RPM PUMP PRESSURE 3324 @ 8112.00000 1646 @ 7724.00000 3069.5 3222.16211 PSI DRILLING MUD REPORT DEPTH MW 12.8 VIS 46 PV 19 YP 21 FL 0.0 Gels 5/6/7 CL- 1200 FC 2/ SOL 19 SD 0.1 OIL 2/79 MBL 7.5 pH 10.3 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1302 @ 7925.00000 0 @ 7719.00000 207.9 TRIP GAS 0 CUTTING GAS 0 @ 8130.00000 0 @ 8130.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 205566 @ 7925.00000 35 @ 7719.00000. 32176.7 CONNECTION GAS HIGH 50 ETHANE (C-2) 15430 @ 7926.00000 1 @ 7719.00000 1959.8 AVG 50 PROPANE (C-3) 8274 @ 7926.00000 0 @ 7738.00000 1015.1 CURRENT 33 BUTANE (C-4) 4630 @ 7926.00000 0 @ 7738.00000 640.7 CURRENT BACKGROUND/AVG 28 PENTANE (C-5) 2424. @ 7925.00000 0 @ 7738.00000 338.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SHALE AND SILTSTONE INTERBEDDED. PRESENT LITHOLOGY SHALE 50%, SILTSTONE 40%, AND SAND 10%. Drilled out collar and 20 ft. of new hole. Pulled up in shoe and circulated until mud is uniform in and out at 33 strokes DAILY Per minute. Rig up and perform LOT EMW= 16ppg. Than rigdown. Displace to 12.6 ppg. Recondition mud while ACTIVITY drilling to 12.7 ppg. Continue to drill to 7818 Ft. Hold pre job safety meeting. Commence drilling from7818 Ft. Still SUMMARY drilling at report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST $2895.00 REPORT BY HARRY E. BLEYS file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/28/2007 ~~ ~J • Daily Report Page 1 of 2 CONOCOPHILLIPS DAILY WELLSITE REPORT E' PQCH 3N-14A BP1 REPORT FOR DEARL GLADDEN DATE Oct 29, 2007 DEPTH 8220 PRESENT OPERATION Run in hole with liner TIME 05:00 YESTERDAY 8130 24 HOUR FOOTAGE 90 CASING INFORMATION 7" @ 3543', 5.5" @ 4438' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8220 32.83 102.67 6646.79 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 4.75 Hughs HC 404ZX 7010257 7716 8220 504 17.3 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 83.9 @ 8159.00000 6.0 @ 8204.00000 36.5 9.66700 FT/HR SURFACE TORQUE 3 @ 8192.00000 2 @ 8130.00000 2.7 2.60100 AMPS WEIGHT ON BIT 29 @ 8198.00000 17 @ 8220.00000 22.4 17.75400 KLBS ROTARY RPM 69 @ 8150.00000 64 @ 8208.00000 59.2 67.09700 RPM PUMP PRESSURE 3318 @ 8186.00000 3027 @ 8220.00000 3260.3 3027.41400 PSI DRILLING MUD REPORT DEPTH 8220/6646 MW 12.8 VIS 45 PV 19 YP 22 FL 3.4 Gels 7/8/9 CL- 1400 FC 1/ SOL 19 SD 0.25 OIL 3/78 MBL 10 pH 10.1 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 71 @ 8142.00000 18 @ 8181.00000 42.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 22287 @ 8156.00000 .3995 @ 8219.00000 11518.9 CONNECTION GAS HIGH 33 ETHANE (C-2) 1124 @ 8156.00000 190 @ 8181.00000 554.9 AVG 33 PROPANE (C-3) 601. @ 8156.00000 110 @ 8181.00000 296.4 CURRENT 0 BUTANE (C-4) 374 @ 8156.00000 67 @ 8215.00000 183.9 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 222 @ 8142.00000 30 @ 8181.00000 102.4 HYDROCARBON Oil show, 8140-8170' SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 8140-8170' 50% Sand/sandstone, max LIGHT BROWN ASH/SILT; BRIWN COLOR MAY BE DUE TO SLIGHT OIL remainder =shale and 72 STAIN;100% OF THE FINE SAND = MED BRN TO GRAY BRN siltstone units GENERALLY MATRIX SUPPORTED, TR GRAIN SUPPORT SLIGHT BROWN STAIN 100% FLUORESCES DULL TO VERY DULL YELLOW; SLOW UNASSISTED CUT TO YELLOW WHITE IMPROVED ON CRUSH; NO ODOR. LITHOLOGY .INTERBEDDED SILTSTONE, SHALE AND SANDSTONE PRESENT LITHOLOGY .SAND/SANDSTONE 30%, SHALE 40%, SILTSTONE 30% Drilled from 8099' to 8220'. Circulate hi vis sweep and hole clean (total 3250 strokes at 120 gals/min). Flow check (static), short trip from 8220' to 7692'. Flow check at 7692' (static). Trip in hole to 8220'. Hole fill (out) calculation = 2.65 DAILY barrels, actual = 3.25 barrels. Pump hi vis sweep bottoms up. Pre-job safety meeting, monitor well (static). Short trip (5 ACTIVITY stands), circulate and recip bottoms up (max gas 325 units), monitor well (static). Pump 35 barrels, tube pill and spot file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/29/2007 Daily Report Page 2 of 2 SUMMARY with 50 barrels. Including slug. Monitor well static. Blow down. Pull out of hole to 5292', monitor well (static). Displace 3 barrels, long. Rig up 2 7/8" tools and clean floor, conduct BOP drill. Continue to pull out of hole with 2 7/8"drill pipe, to BHA. Monitor well static (displace 4 barrels, long). Lay down 6 DC's, jars and bumper sub, XO's and 2 flex DC's. Download MWD, clean floor. Break off bit and lay down MWD tools and motor. Clear floor EPOCH PERSONNEL ON BOARD 4 DAILY COST 3090.00 REPORT BY HICK mOIR • file://C:\DOCUMENTS AND SETTINGS\RIGUSER\MY DOCUMENTS\MY WELLS\... 10/29/2007 Daily Report Page 1 of 2 C~ CONOCOPHILLIPS DAILY WELLSITE REPORT EPOCH 3N-14A REPORT FOR Dearl Gladden DATE Oct 30th, 2007 , DEPTH 8220 PRESENT OPERATION Circulating bottoms up to remove cement. TIME 0600 YESTERDAY 8220 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 3543', 5.5 @ 5.5" @ 4438'. SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 4.75 Hughs HC 404ZX 7010257 7716 8220 504 17.3 TD reached DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8220 MW 12.8 VIS 45 PV 19 YP 22 FL 3.4 Gels 7/8/9 CL- ..1400 FC 1/ SOL 19 SD 0.25 OIL 3/78 MBL 10 pH 10.1 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS Average = 680u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY INTERBEDDED SILTSTONE, SHALE AND SANDSTONE. PRESENT LITHOLOGY SAND/SANDSTONE 30%, SHALE 40% AND SILTSTONE 30% Pre-job safety meeting on 3.5" liner. Pick up and make up 3.5"liner as per detail. Total of 21 SO bands and 42 stops. Pick up and make up liner hanger, XPF packer and 3.5" running tool (fill with PAL fluid and let same set up). Pick up 81 joints, 2 7/8"drill pipe from shed (drift with 1.40 rabbit) circulate liner volume at 1022' and break circulation at 1718'. Continue to trip in hole with 2 7/8" stands from derrick from 3263' to 4499' breaking circulation at 3548'. At 4499' DAILY circulate until mud weight reaches 12.7 ppg in and out. Continue to trip in hole to 5070'. Pick up 72K. Conduct pre-job ACTIVITY safety meeting and continue to run in hole with liner. Circulate to bottoms up at 6400' (max gas = 532 units). Continue to SUMMARY run in hole to 7636 pick up single, make up XO and lay down single. Circulate bottoms up at 7636' (max gas = 643 units). Mud weight in and out 12.7 ppg. Make up cement head on single and hand off -pick up weight at shoe S/O "weight. 80K monitor well (static). Run in hole to 8205', pick up cement head on single, break circulation at 1 BPM/1100psi, wash and tag at 8221'. Circulate and recip, stage pump rate up to 2 BPM/1500psi. Conduct pre job safety meeting for cement job. file://D:\20071030.htm 10/30/2007 Daily Report • EPOCH PERSONNEL ON BOARD 2 DAILY COST 4510.00 REPORT BY Nic Moir • • Page 2 of 2 file://D:\20071030.htm 10/30/2007
