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210-007
New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 • Image Project Well History File Cover age 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 Cb�y direct inspection of the file. c2 L. 0 - 0 0 _7 Well History File Identifier Organizing (done) ❑ Two -sided 11111111 1111 ❑ Rescan Needed II I IIII RE CAN DIGITAL DATA OVERSIZED (Scannable) V Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: /� BY: Maria Date: / ' _ / :J Project Proofing 11 IIII YriP BY: Maria Date: 1751/ /s/ Scanning Preparation 1 x 30 = 0 + / 6 = TOTAL PAGES 7- (Count does not include cover sheet) -+ BY:ft Date: / �a /s/ fyl Production Scanning 1 IIIIIIII 1111 Stage 1 Page Count from Scanned File: 17 6 (Count does include cov sheet) Pa.e Count Matches Number in Scanning Preparation: YES NO BY: Date: //g/1 /s/ 'j Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I ill IIIIII 1111 ReScanned I III IIIIII 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III IIII III 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10/17/2011 Permit to Drill 2100070 Well Name /No. KUPARUK RIV UNIT 1E- 12L2 -01 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 20736 -63 -00 MD 9350 TVD 6376 Completion Date 3/13/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey - DATA INFORMATION Types Electric or Other Logs Run: GR / RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: • Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med /Frmt Numbere Scale Media No Start Stop CH Received Comments D C Lis 19677 duction /Resistivity 6852 9350 Open 5/24/2010 EWR LIS/TAP, PB1 EWR LIS/TAP logs and PDF and TIFF graphics og / Induction /Resistivity 2 Col 7200 9350 Open 5/24/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7200 9350 Open 5/24/2010 MD MPR, GR Log Induction /Resistivity 5 Col 7200 9350 Open 5/24/2010 TVD MPR, GR Log i Induction /Resistivity 2 Col 7200 7745 Open 5/24/2010 PB1 MD MPR, GR Log Induction /Resistivity 5 Col 7200 7745 Open 5/24/2010 PB1 MD MPR, GR Log Induction /Resistivity 5 Col 7200 7745 Open 5/24/2010 PB1 TVD MPR, GR e , C Directional Survey 7535 9350 Open Rpt l Directional Survey 7535 9350 Open ED C / Directional Survey 7260 7745 Open PB1 • / L pt Directional Survey 7260 7745 Open PB1 Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ^ Well Cored? Y// N) Daily History Received? (( 6 N Chips Received? l 'r�#.4 Formation Tops Ci4 N Analysis —.J.41 -- Received? DATA SUBMITTAL COMPLIANCE REPORT 10/17/2011 Permit to Drill 2100070 Well Name /No. KUPARUK RIV UNIT 1E- 12L2 -01 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 20736 -63 -00 MD 9350 TVD 6376 Completion Date 3/13/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N Comments: Compliance Reviewed By: Date: • • • STATE OF ALASKA OIL AND GAS CONSeg SION WELL COMPLETION OR RECOMPLOrIPORT AND LOG la. Well Status: Oil Q Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ..i �- l 1b. Well Class: 20A1)0& Development IN Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completion Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: March 13, 2010 210 - 0070 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 March 4, 2010 50 029 - 20736 - 63 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 804' FSL, 811' FEL, Sec. 16, T11 N, R10E, UM March 7, 2010 1E / 1 E 12L2 - 01 PB1 Top of Productive Horizon: 8. KB (ft above MSL): 105.7 RKB 15. Field /Pool(s): 2602' FNL, 2474' FEL, Sec. 16, T11 N, R10E, UM GL (ft above MSL): 80' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1459' FSL, 1811' FEL, Sec. 16, T11 N, R10E, UM 9350' MD / 6376' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 549710 y 5960390 Zone 4 9350' MD / 6376' TVD ADL 25651 TPI: x - 548031 y - 5962252 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 548704 y 5961038 Zone 4 nipple @ 482' MD / 482' TVD 469 18. Directional Survey: Yes El No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1900' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD GR/ Res 7265' MD / 6360' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 65# H-40 Surf. 80' Surf. 80' 24" 217 sx AS II 10.75" 45.5# K -55 Surf. 2501' Surf. 2500' 13.5" 1050 sx AS III, 250 sx AS II 7" 26# K -55 Surf. 7510' Surf. 6573' 8.75" 963 sx Class G 5.5" 15.5# L -80 Surf. 6765' Surf. 5959' 8.75" scab liner 2.375" 4.7# L -80 7434' 9350' 6367' 6376' 3" slotted liner 24. Open to production or injection? Yes Q No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7140' 6779' MD / 5970' TVD alternating solid /slotted liner from 7434' -8225' MD 6367-6385' TVD alternating solid /slotted liner from 8245' -9347' MD 6385' -6376' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 19, 2010 gas lift oil Date of Test Hours Tested Production for OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GAS - OIL RATIO 4/1/2010 9 hours Test Period - > 266 634 664 176 Bean 2722 Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 254 psi 1327 24 -Hour Rate -> 635 1729 1711 23.5 deg. 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ' , " ° ( P ) P P , rY Yt P �(at�e,, � a i t��t , 1 , 3. - Ilii 10 NONE _ ,.�. I -, r - Form 10-407 Revised 7/2009 CONTINUED ON REVERSE Submit original only RBDMS APR 1' 6 2V, "Z 4 i•z-v1 o `Morro C> _to 28. GEOLOGIC MARKERS (List all formations and markers ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 3321' 3306' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk A4 7265' 6360' Kuparuk A4 9350' 6376' N/A 1 E- 12L2 -01 PB1 TD 7745' 6364' Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263 - 4093 ' ,1' Printed Na V. Ca a Title: Alaska Wells Manager C `1 Signature -. Phone 265 - 6306 Date14910 6 S haron Allsup -Drake INSTRUCTIONS 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 la: 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 levet. 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 7/2009 Iv- _� KUP • 1E- 12L2 -01 Co oPhith ps Ma Angle & MD TD Well Attributes 9 Al :,n,i, SK; Wellbore APVUWI I Field Name Well Status Inc! (•) MD (ft6B) Act Bbn (ftKB) (A+xxttnll4la 500292073663 KUPARUK III IFI UNIT PROD 97.63 /,41565 93500 Comment H25 Dale Annotation End Date KB - Grd Rig { pt ) ( ft) Ri Release Date weu cp fig IE 12L2 -01 4/20201042054674 SSSV NIPPLE 15 ' 9/26/2004 Last WO: 10/14/2007 40 71 6/13/1982 SGiematic , - AGUaj Annotation Depth (6508) End Date Annotation Last Mod.. End Date Last Tag- SLM 7,14/ 0 2M/2010 Rev Reason: ADD 4 LATERALS I mosbor _ 3/22/2010 HANGER, 28 ice. g P —_— B 9 lion ) I Depth ( I Depth (TVD) . g 9 ... -_ -. 9 P �, Casin Stnn s C in Des Top Depth String n O. Str ID ._ To (HKB Set De th f... Set De ih St Wt. String String Top Thrd I 1. I _: liner l Detaiil l S D) Top lnel 1 � I�, 7.410.0 9350.0 4 60 L 80 S I L NOmL. . Top (ftKB) (ftKB) r) Rem Description Comment ID (in) 7,410.0 6,370.4 97.14 Anchor B IIel 2.625 Alluminum Billet with OH anchor 1 1.995 /,433.4 6,367.6 96.86 Deployment Deployment Sleeve Baker Torque Thru I '� 1.995 CONDUCTOR, sleeve 32-80 — - i EF1 ' 8244.0 6,384.61 92.85 Deployment 'Deployment Sleeve Baker Torque Thru 1 1.995' NIPPLE, 482 r Perforations & Slots ,'% snot f Top (TVD) Btm (TVD( Dens Top (ftKB) Bhn (ftKB (ftKB) (ftKB) Zone Date ( Type Comment 7,434 8,225 6,367.4 6385.1 A -4, 1E- 12L2 -01 3/9/2010 32.0 SLOTS Alternating solid /slotted pipe - 0.125 "x2.5" @ 4 circumferential GAS LIFT, z,aso _ adjacent rows, 3" centers staggered 18 deg, 3' non - sloped ends SURFACE, ,♦ + . 46,.. 8 9 6 6 375.9 A 4 1 E- 12L2 -01 3/9/2010 32.0 SLOTS Alternating solid /slotted pipe - 31 - 2,501 _ 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends GAS LIFT, Notes: General & Safety 3,61] . End Date Annotation 9/10/2000 NOTE VIEW SCHIOSIA'IC w /9.0 & Reference V sio Multi -tat drawing attached 3/14/2010 NOTE: 4 LATERALS DRILLED L. GAS LIFT, _ -. _- _ - -- 5,088 titE GAS LIFT, 6,115 IV GASL664IFT1 , 4 0 LOCATOR, 6,693 SEAL, 6,696 SCAB 27R, J L-6,6,E65 3 -- - -j PBR,6,765 - - -- _ -i'_ PACKER, 6,779 _ SLEEVE, 6,926 BLAST RING, 6,939 AP ,939 7,010 - ERR, Cement, 7,010 PACKER, 7,137 SBE,7,140 A -7149 7, NIPPLE, 7,155 WLEG, ERR, RPERF, ERR, I 7,200-7,208 IPERF, I ..: 7,200-7,209 _ CEMENT SQUEEZE, I 7,150 PRODUCTION, 32 -7,510 ;?. if .i SLOTS, 4 7,434-8,225 7,263 -e,530 Mandrel Detail ' .;. ' ° 4 Top Depth Top Port (6508) I OD Ty Latch Sine I TRO Run if Stn Top (ryK6•L (ft ('1 KB) ( °) Make Model (in) sera pe TYP (in) lPal Run Dab Com... 1 2,489.8 2,488 5 3 19 Camco KBG -2 -9 1 GAS LIFT I GLV INT 0.156 1,317.0 3/17/2010 2 3,817.2 3,752.1 31.24 Camco KBG -2 -9 1IGAS LIFT IGLV ' 0188 1,342.0 3/17/2010 3 5,087.7 4,690.1 44.32 Camco KBG -2 -9 1 GAS LIFT 1 1,OV I BTM 1 0.250 0.0 3/16/2010 4 6,114.7 5,444.6 38.70 Camco KBG -2 -9 1 Gas Lift DMY INT 0.000 0.0 10/3/2008 5 6,641.7 5,859.5 36.75 Camco KBG -2 -9 1 Gas Lift DMY INT 0.000 0.0 10/3/2008 SLOTS, 8,245 - 9,347 " + L2 -01 L'ner, 7,410 -9,350 TD (1E- 12L2 -01), 9,350 1E -12 L1, L1 -01, L2, and L2 -01 Sidetracks 3-1/2" Camco DS nipple @ 482' MD Rig Accept: 02/15/10 Rig Release: 03/14/10 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface ..i_____ J 3 -1/2" Camco KBG -2 -9 gas lift mandrels © 2490', 3817, 5088', 6115', 6641' 116 "65 #H -4O shoe @80'MD 1 • J 3 -1/2" tubing wl seals stabbed into 5" joint in the 5 -1/2" scab liner 5 -1/2" scab liner from surface to 6765' MD, seals stabbed into top of FHL PBR Baker 3 -112' PBR © 6765' MD 10 -3/4" 45.511 K -55 shoe @ 2501' MD Baker FHL packer 0 6779' MD IP 3 -1/2" CMU sliding sleeve © 6926' MD (2.812" min ID) Baker F -1 packer @ 7137' MD (2.99" ID) BakerSBE @714O'MD r •_ C -sand perfs 7010' - 7090' MD I 3-1/2" Camco D landing nipple @ 7155' MD (2.75" min ID, No -Go) i 3 -1/2" tubing tail @ 7156' MD (7158' ELM - PDC log) Liner Top @7129' — ._ - . - 1 E - L1 - OH Anchored (A5 sand, Northwest) Billet @ 7540' Kickoff from 1E-12 L1 @ 7510' Top of cement in tubing @ 7139' MDI i• - - - -- 1E L2 - PB1 di Shorty deployment Sleeve @ 7129' _ _ (A4, Southeast) 1 E - L2 Slotted liner to 8725' OH Anchored (A5 sand, Southeast) _ TD @ 8725' Billet 7410' ! TD @ 7745' Kickoff from 1E -12 7200' @ i _ _ '' i ` , N--".. Top @ 7540' ` Anchored Billet Set @ 7265' Slot — — Slotted liner to 8429' , __—_—__ ____ .___________, / _ \\ \ \\ / / — _ _ -- TD @8460' i _.Q� //, \ � \ Inadvertent Liner Top Billet @ -- �i � \ \� i 7610' % i \��- bill ST @ 7858' e (no t) 1E - 12 L2 PB1 _ i (A4 /A5 sand, Southeast) OH Anchored i TD @ 9840' �'- ' Billet @7265' iMI... I / Upper whipstock = 7200' MD 1E Lt A4 sand, Northwest - Lower whipstock= 7h25'Mk --) ( ) / ` ` -- (Baker monobore whipstock trays Kickoff from 1E-12 L2 -01 @ 7410' 1E L1 PB1 It' - on openhole anchors) -- Liner-top Billet 0 7510' (A4 sand, Northwest) 1E L2 Slotted liner to 9002' Kickoff from 1E -12 0 7225' 2.80" pilot hole in cement drilled 50 (A4 sand, Southeast) TD @ 9002' TD @ 7626' 7265' MD Kickoff from 1E -12 L2 @ 7265' Anchored Billet Set @ 7410' Slotted liner to 9350' TD 0 9350' ConocPhiIIips Alaska s • ConocoPhilli Alaska p� ) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-12L2-01 50- 029 - 20736 -63 Baker Hughes INTEQ ill • Definitive Survey Report BAKER Y p HUGHES 16 March, 2010 ,--- ConocoPhillips ConocoPhiflips Definitive Survey Report BAKER ES Alaska 1 Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E - 12 i I Project: Kuparuk River Unit TVD Reference: 1E-12 @ 105.70ft (1E-12) Site: Kuparuk 1E Pad MD Reference: 1E-12 @ 105.70ft (1E-12) I Well: 1E - 12 North Reference: TRUE Wellbore: 1E Survey Calculation Method: Minimum Curvature Design: 1E -12 Database: EDM Alaska Prod v16 1 Project Kuparuk River Unit I Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 1 Weil 1E Well Position +N/ 0.00 ft Northing: 5,960,390.22ft Latitude: 70° 18' 9.229 N +E / - 0.00 ft Easting: 549,710.20ft Longitude: 149° 35' 50.464 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1E 12L2 - 01 __ �.�_�_ --_.. — _ ^ _ � __ ___ Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) ( °) (nT) BGGM2009 3/5/2010 17.35 79.80 57,369 Design 1E- 12L2 -01 — — I Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,535.78 Vertical Section: Depth From (TVD) +N/-5 +E/ -W Direction (ft), (ft) (ft) ( °) } 34.60 0.00 0.00 303.17 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,200.00 1E -12 (1E -12) FINDER -MS SDC Finder muitishot 8/25/2000 7,230.53 7,260.59 1E- 12L2PB1 (1E- 12L2PB1) MWD MWD - Standard 2/23/2010 2/27/2010 7,265.00 7,535.78 1 E- 12L2 -01 PB1 (1 E- 12L2 -01 PB1) MWD MWD - Standard 3/4/2010 3/4/2010 7,540.00 9,312.61 1E- 12L2 -01 (1E- 12L2 -01) MWD MWD - Standard 3/5/2010 3/7/2010 3/16/2010 2:49:39PM Page 2 COMPASS 2003.16 Build 69 i lll I v.-- ConocoPhillips BAKER ConocoPhillips Definitive Survey Report HUGHES Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E I Project: Kuparuk River Unit TVD Reference: 1E-12 @ 105.70ft (1E-12) Site: Kuparuk 1E Pad MD Reference: 1E-12 @ 105.70ft (1E-12) i Well: 1E North Reference: TRUE Wellbore: 1E Survey Calculation Method: Minimum Curvature Design: 1E - 12 Database: EDM Alaska Prod v16 I Survey Map Map Vert MD Inc Azi ND TVDSS +N/-S DLS Northing Easting Section ion Surve Tool Name Annotation (ft) el (1 (ft) (ft) (ft) (ft) (ft) (ft) ( (ft) Y 7,535.78 90.95 59.59 6,360.88 6,255.18 2,104.65 - 1,668.32 5,962,483.58 548,028.15 53.48 2,547.91 MWD (3) TIP 1E - 12L2 - 01PB1 7,540.00 91.59 61.37 6,360.79 6,255.09 2,106.73 - 1,664.65 5,962,485.69 548,031.81 44.81 2,545.98 MWD (4) KOP; Top of Billet 7,560.57 84.96 67.15 6,361.40 6,255.71 2,115.65 - 1,646.15 5,962,494.73 548,050.25 42.74 2,535.37 MWD (4) 7,590.35 86.90 76.26 6,363.52 6,257.82 2,124.96 - 1,617.98 5,962,504.23 548,078.36 31.20 2,516.88 MWD (4) 7,625.57 88.13 87.92 6,365.06 6,259.36 2,129.80 - 1,583.19 5,962,509.29 548,113.11 33.26 2,490.40 MWD (4) 7,654.90 89.02 94.55 6,365.79 6,260.09 2,129.16 - 1,553.89 5,962,508.85 548,142.41 22.80 2,465.53 MWD (4) 7,685.50 87.61 102.89 6,366.69 6,260.99 2,124.53 - 1,523.68 5,962,504.42 548,172.64 27.63 2,437.71 MWD (4) 7,715.55 88.80 118.45 6,367.63 6,261.93 2,113.96 - 1,495.67 5,962,494.04 548,200.72 51.91 2,408.48 MWD (4) 7,745.94 88.01 125.03 6,368.48 6,262.78 2,097.99 - 1,469.85 5,962,478.24 548,226.65 21.80 2,378.12 MWD (4) 7,775.79 85.27 135.31 6,370.23 6,264.53 2,078.80 - 1,447.11 5,962,459.20 548,249.51 35.58 2,348.59 MWD (4) 7,805.99 85.76 145.37 6,372.60 6,266.90 2,055.65 - 1,427.92 5,962,436.18 548,268.85 33.25 2,319.86 MWD (4) 7,835.15 85.27 155.98 6,374.89 6,269.19 2,030.34 - 1,413.70 5,962,410.97 548,283.24 36.31 2,294.12 MWD (4) 7,865.10 88.07 168.04 6,376.63 6,270.94 2,001.96 - 1,404.49 5,962,382.65 548,292.63 41.27 2,270.88 MWD (4) 7,895.32 85.24 172.87 6,378.40 6,272.70 1,972.22 - 1,399.49 5,962,352.95 548,297.83 18.50 2,250.42 MWD (4) 7,925.37 85.27 177.37 6,380.89 6,275.19 1,942.39 - 1,396.94 5,962,323.14 548,300.58 14.92 2,231.97 MWD (4) 7,955.48 84.81 181.77 6,383.49 6,277.79 1,912.40 - 1,396.71 5,962,293.15 548,301.00 14.64 2,215.38 MWD (4) 7,985.52 84.43 186.55 6,386.31 6,280.61 1,882.58 - 1,398.88 5,962,263.32 548,299.03 15.89 2,200.88 MWD (4) 8,025.52 87.97 189.84 6,388.96 6,283.26 1,843.09 - 1,404.57 5,962,223.80 548,293.60 12.07 2,184.04 MWD (4) • 8,055.29 91.38 194.42 6,389.13 6,283.43 1,814.00 - 1,410.82 5,962,194.67 548,287.54 19.18 2,173.36 MWD (4) 8,085.20 92.18 198.90 6,388.20 6,282.50 1,785.36 - 1,419.39 5,962,165.98 548,279.16 15.21 2,164.86 MWD (4) ( 8,115.06 91.63 196.17 6,387.21 6,281.51 1,756.91 - 1,428.38 5,962,137.47 548,270.36 9.32 2,156.82 MWD (4) 8,142.35 91.26 192.70 6,386.52 6,280.82 1,730.49 - 1,435.18 5,962,111.01 548,263.74 12.78 2,148.06 MWD (4) 8,175.19 90.40 187.75 6,386.04 6,280.34 1,698.19 - 1,441.01 5,962,078.67 548,258.13 15.30 2,135.27 MWD (4) 8,210.38 91.41 182.88 6,385.49 6,279.79 1,663.16 - 1,444.27 5,962,043.63 548,255.10 14.13 2,118.84 MWD (4) 8,240.46 91.57 177.73 6,384.70 6,279.00 1,633.10 - 1,444.43 5,962,013.57 548,255.14 17.12 2,102.53 MWD (4) 8,270.45 93.75 174.13 6,383.31 6,277.61 1,603.23 - 1,442.30 5,961,983.72 548,257.46 14.02 2,084.40 MWD (4) 8,300.09 94.76 171.01 6,381.11 6,275.41 1,573.92 - 1,438.48 5,961,954.44 548,261.48 11.04 2,065.17 MWD (4) 8,330.12 96.12 167.33 6,378.26 6,272.56 1,544.57 - 1,432.87 5,961,925.12 548,267.28 13.01 2,044.41 MWD (4) 8,360.03 96.27 163.35 6,375.03 6,269.34 1,515.81 - 1,425.34 5,961,896.41 548,275.00 13.24 2,022.38 MWD (4) 8,390.02 96.37 158.77 6,371.73 6,266.03 1,487.62 1,415.67 5,961,868.30 548,284.86 15.18 1,998.87 MWD (4) 3/16/2010 2:49:39PM Page 3 COMPASS 2003.16 Build 69 ,,- ConocoPhillips ConocoPhillips Definitive Survey Report HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E - 12 Project: Kuparuk River Unit ND Reference: 1E-12 @ 105.70ft (1E-12) Site: Kuparuk 1E Pad MD Reference: 1E-12 @ 105.70ft (1E-12) Well: 1B12 North Reference: TRUE I Wellbore: 1E Survey Calculation Method: Minimum Curvature I Design: 1E-12 Database: EDM Alaska Prod v16 { Survey Map Map Vertical MD Inc Azi ND NDSS ++N/4 �yy S +_ DL3 Northing Easting Section Survey Tool Name Annotation (ft) ( °) (') (ft) (ft) (ft) (ft) (ft) (ft) ( /100') (ft) • 8,420.27 94.76 155.92 6,368.80 6,263.10 1,459.84 - 1,404.07 5,961,840.60 548,296.63 10.78 1,973.96 MWD (4) 8,450.32 93.56 152.52 6,366.62 6,260.92 1,432.86 - 1,391.04 5,961,813.70 548,309.84 11.97 1,948.29 MWD (4) 8,480.28 93.35 148.71 6,364.81 6,259.11 1,406.80 - 1,376.37 5,961,787.75 548,324.69 12.71 1,921.76 MWD (4) 8,510.06 92.70 144.77 6,363.24 6,257.54 1,381.94 - 1,360.06 5,961,763.00 548,341.16 13.39 1,894.50 MWD (4) 8,544.92 91.72 142.61 6,361.89 6,256.19 1,353.87 - 1,339.44 5,961,735.07 548,361.96 6.80 1,861.88 MWD (4) 8,580.22 91.84 146.07 6,360.80 6,255.10 1,325.21 - 1,318.87 5,961,706.55 548,382.72 9.80 1,828.99 MWD (4) 8,615.60 94.94 151.34 6,358.70 6,253.00 1,295.05 - 1,300.53 5,961,676.51 548,401.25 17.26 1,797.13 MWD (4) 8,645.17 95.69 156.11 6,355.96 6,250.26 1,268.65 - 1,287.50 5,961,650.20 548,414.46 16.26 1,771.79 MWD (4) 8,675.28 95.78 160.93 6,352.95 6,247.25 1,240.78 - 1,276.53 5,961,622.41 548,425.61 15.93 1,747.36 MWD (4) 8,705.19 95.34 164.69 6,350.05 6,244.35 1,212.35 - 1,267.74 5,961,594.04 548,434.59 12.60 1,724.44 MWD (4) 8,739.74 94.36 169.22 6,347.13 6,241.43 1,178.82 - 1,259.97 5,961,560.56 548,442.58 13.37 1,699.60 MWD (4) 8,765.55 92.30 171.78 6,345.63 6,239.93 1,153.41 - 1,255.72 5,961,535.19 548,447.00 12.72 1,682.14 MWD (4) 8,797.15 90.06 174.48 6,344.98 6,239.28 1,122.05 - 1,251.94 5,961,503.85 548,450.98 11.10 1,661.82 MWD (4) 8,825.48 87.27 176.10 6,345.64 6,239.94 1,093.83 - 1,249.62 5,961,475.65 548,453.50 11.39 1,644.43 MWD (4) 8,860.37 83.97 174.19 6,348.31 6,242.61 1,059.17 - 1,246.67 5,961,441.02 548,456.67 10.92 1,623.01 MWD (4) 8,890.62 82.71 170.89 6,351.82 6,246.12 1,029.38 - 1,242.77 5,961,411.26 548,460.76 11.61 1,603.45 MWD (4) 8,920.83 86.32 168.03 6,354.70 6,249.00 999.83 - 1,237.27 5,961,381.74 548,466.46 15.22 1,582.68 MWD (4) 8,960.22 87.39 162.62 6,356.87 6,251.17 961.79 - 1,227.31 5,961,343.78 548,476.67 13.98 1,553.53 MWD (4) ill 8,990.87 84.83 160.59 6,358.94 6,253.25 932.78 - 1,217.66 5,961,314.83 548,486.51 10.65 1,529.59 MWD (4) 9,026.03 84.56 156.90 6,362.20 6,256.50 900.16 - 1,204.97 5,961,282.30 548,499.41 10.48 1,501.12 MWD (4) 9,060.76 84.87 152.63 6,365.40 6,259.70 868.88 - 1,190.23 5,961,251.13 548,514.36 12.28 1,471.67 MWD (4) 9,090.49 87.45 150.27 6,367.39 6,261.69 842.83 - 1,176.06 5,961,225.17 548,528.70 11.75 1,445.55 MWD (4) 9,120.49 90.43 148.59 6,367.94 6,262.24 817.01 - 1,160.81 5,961,199.45 548,544.13 11.40 1,418.66 MWD (4) 9,150.62 89.94 144.93 6,367.85 6,262.15 791.81 - 1,144.29 5,961,174.37 548,560.80 12.26 1,391.05 MWD (4) 9,180.08 90.98 142.50 6,367.61 6,261.91 768.07 - 1,126.86 5,961,150.74 548,578.39 8.97 1,363.47 MWD (4) 9,210.57 89.94 139.02 6,367.36 6,261.66 744.46 - 1,107.58 5,961,127.26 548,597.83 11.91 1,334.41 MWD (4) 9,240.34 85.76 134.70 6,368.48 6,262.78 722.76 - 1,087.25 5,961,105.70 548,618.30 20.18 1,305.52 MWD (4) 9,270.47 85.42 130.84 6,370.80 6,265.10 702.37 - 1,065.20 5,961,085.46 548,640.48 12.82 1,275.91 MWD (4) 9,300.40 85.89 127.02 6,373.07 6,267.37 683.62 - 1,041.99 5,961,066.86 548,663.81 12.82 1,246.22 MWD (4) 9,312.61 86.68 125.56 6,373.86 6,268.16 676.41 - 1,032.17 5,961,059.72 548,673.68 13.57 1,234.05 MWD (4) 9,350.00 86.68 125.56 6,376.02 6,270.32 654.70 - 1,001.80 5,961,038.21 548,704.19 0.00 1,196.76 PROJECTED to TD 3/16/2010 2:49:39PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Alaska ConocoPhilli ps (Alaska ) Inc. • Kuparuk River Unit Kuparuk 1E Pad 1 E- 12L2 -01PB1 50- 029 - 20736 -72 Baker Hughes INTEQ NM 0 Definitive Survey Report BKR HUGHES 16 March, 2010 ., ConocoPhillips EIS ConocoPhlllips Definitive Survey Report BAKER HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference; 1E I Project: Kuparuk River Unit ND Reference: 1E-12 @ 105.70ft (1E-12) I Site: Kuparuk 1E Pad MD Reference: 1E-12 @ 105.70ft (1E-12) Well: 1E - 12 North Reference: TRUE Wellbore: 1E Survey Calculation Method: Minimum Curvature 1 Design: 1E-12 Database: EDM Alaska Prod v16 Project Kuparuk River Unit { Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Illo Well —�_ 1E 1 Well Position +N /-S 0.00 ft Northing: 5,960,390.22ft Latitude: 70° 18' 9.229 N +E / - 0.00 ft Easting: 549,710.20ft Longitude: 149° 35' 50.464 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft J 1 ir Wellbore 1E 12L2 - 01PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength it (°) (°) (nT) BGGM2009 3/4/2010 17.35 79.80 57,369 Design 1 E- 12L2 -01 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,260.59 Vertical Section: Depth From (ND) +N/-5 +E/-W Direction (ft) (ft) (ft) ( °) 4111k 1 34.60 0.00 0.00 324.32 L_ 4 i Survey Program Date ^ 1 From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,200.00 1E-12 (1E-12) FINDER -MS SDC Finder muitishot 8/25/2000 7,230.53 7,260.59 1E- 12L2PB1 (1E- 12L2PB1) MWD MWD - Standard 2/23/2010 2/27/2010 i 7,265.00 7,715.20 1E- 12L2 -01PB1 (1E- 12L2- 01PB1) MWD MWD - Standard 3/4/2010 3/4/2010 3/16/2010 2:51:21 PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Fria Conoco Phillips BAKER i Definitive Survey Report HUGHES Alaska { Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E Project: Kuparuk River Unit TVD Reference: 1E-12 @ 105.70ft (1E-12) ! Site: Kuparuk 1E Pad MD Reference: 1E-12 @ 105.70ft (1E-12) Well: 1E North Reference: TRUE Weilbore: 1E Survey Calculation Method: Minimum Curvature Design: 1E �✓ Database: EDM Alaska Prod v16 _____I _____ Survey Map Map Vertical MD Inc Azl TVD TVDSS +N/-S +E/-W Northing Easting DLS Section Survey Tool Name Annotation (ft) (°1 C) (ft) (ft) (ft) (ft) (ft) (ft) (loo') (ft) ! 7,260.59 56.70 331.85 6,357.90 6,252.20 1,869.77 - 1,665.03 5,962,248.75 548,033.00 36.77 2,489.93 MWD (2) Interpolated AZI - TIP 1E 7,265.00 58.19 331.65 6,360.27 6,254.57 1,873.04 - 1,666.78 5,962,252.01 548,031.22 34.00 2,493.62 MWD (3) KOP; Top of Billet 7,295.09 73.35 328.72 6,372.59 6,266.89 1,896.76 - 1,680.42 5,962,275.63 548,017.43 51.15 2,520.83 MWD (3) 7,325.25 87.54 322.77 6,377.59 6,271.89 1,921.25 - 1,697.14 5,962,300.01 548,000.55 50.89 2,550.48 MWD (3) 7,355.53 97.36 334.35 6,376.29 6,270.59 1,946.98 - 1,712.88 5,962,325.63 547,984.64 50.08 2,580.56 MWD (3) 7,385.92 95.07 348.46 6,372.98 6,267.28 1,975.54 - 1,722.48 5,962,354.13 547,974.85 46.76 2,609.36 MWD (3) 7,415.66 97.63 1.53 6,369.68 6,263.98 2,004.91 - 1,725.06 5,962,383.48 547,972.08 44.51 2,634.73 MWD (3) 7,445.60 96.08 15.16 6,366.09 6,260.39 2,034.25 - 1,720.75 5,962,412.85 547,976.19 45.49 2,656.04 MWD (3) 7,475.44 94.18 28.95 6,363.41 6,257.71 2,061.73 - 1,709.62 5,962,440.39 547,987.15 46.46 2,671.87 MWD (3) 7,505.67 92.21 43.53 6,361.71 6,256.01 2,086.00 - 1,691.82 5,962,464.78 548,004.78 48.59 2,681.20 MWD (3) 7,535.78 90.95 59.59 6,360.88 6,255.18 2,104.65 - 1,668.32 5,962,483.58 548,028.15 53.48 2,682.65 MWD (3) 7,565.65 95.44 72.25 6,359.21 6,253.51 2,116.80 - 1,641.16 5,962,495.91 548,055.23 44.90 2,676.67 MWD (3) 7,595.89 94.67 84.81 6,356.53 6,250.83 2,122.77 - 1,611.70 5,962,502.08 548,084.65 41.45 2,664.34 MWD (3) 7,625.49 90.46 93.51 6,355.21 6,249.51 2,123.20 - 1,582.17 5,962,502.70 548,114.17 32.62 2,647.46 MWD (3) 7,655.69 86.26 107.31 6,356.07 6,250.37 2,117.77 - 1,552.55 5,962,497.46 548,143.82 47.74 2,625.77 MWD (3) 7,685.43 85.39 121.51 6,358.25 6,252.55 2,105.54 - 1,525.61 5,962,485.42 548,170.84 47.71 2,600.13 MWD (3) 7,715.20 84.31 137.44 6,360.94 6,255.24 2,086.76 - 1,502.80 5,962,466.79 548,193.77 53.42 2,571.57 MWD (3) 1 7,745.00 84.31 137.44 6,363.89 6,258.19 2,064.92 - 1,482.74 5,962,445.08 548,213.97 0.00 2,542.13 PROJECTED to TD 3/16/2010 2:51:21PM Page 3 COMPASS 2003.16 Build 69 410 1E-12 Pre and Post Rig Summary II DATE SUMMARY 11/24/09 DRIFT 2.73" x 6' BARBELL AND 2.63" x 17' -11" WHIPSTOCK DRIFT TO 7225' SLM. WELL LEFT SI FOR UPCOMING SBHPS. 11/27/09 TAGGED TD @ 7295' SLM ( EST. 22' OF RAT HOLE / OBTAINED SAMPLE ). LOGGED CASING FROM 7271' RKB UP INTO TTL @ 7156' RKB. 11/30/09 PERFORMED 30 MIN SBHPS @ 7131' RKB = 2508 PSI, 159 DEG F. 15 MIN GRADIENT STOP MADE @ 7010' = 2463 PSI. 1/21/10 MEASURED BHP @ 7225' RKB(2456 psi). GRADIENT @ 7104' RKB(2414 psi). JOB COMPLETE. 1/22/10 PRE CTD, T -POT ( PASSED ), T -PPPOT ( PASSED ), IC -POT ( PASSED ), IC -PPPOT ( PASSED ), LOWER IC -POT ( PASSED ), LOWER IC -PPPOT ( PASSED ). 1/23/10 DRIFTED TBG WITH 11' X 2.64" DMY GUN & TAG FILL @ 7271' SLM. SET CAT STANDING VLV @ 7155' RKB. TESTED CAT TO 2000 #. * *PASS * *. PULLED GLV'S @ 2490' & 3817' RKB's. REPLACED WITH DMY VLV's. PULLED ORIFICE VLV @ 5087' RKB. CIRC OUT TBG & IA WITH 160 BBLS DIESEL. FP FLOWLINE WITH 50 BBLS 60/40. CALLED VLV CREW TO SERVICE TREE VLVS. IN PROGRESS. 1/24/10 SET DMY VLV w/ INT LATCH @ 5088' RKB. MITIA TO 2500 #. ** *PASS * * *. PULLED CAT STANDING VLV @ 7155' RKB. READY FOR E -LINE. 1/26/10 PERFORATED TUBING AT INTERVAL 7147.0' TO 7149.0' WITH 2 -FT GUN, LOADED 6 -SPF, 60 -DEG PHASED, HMX BH CHARGES. 1/27/10 MILL 2.75" D NIPPLE @ 7155' RKB TO 2.80 ", IN PROGRESS. 1/28/10 LOAD WELL WITH HOT SEAWATER AND ESTABISHED A BASE INJECTION RATE OF 380 PSI @ .25 BPM. LAY IN 25 BBLS 17 PPG CEMENT. PERFORM HESITATION SQZ IN 500 PSI INCREMENTS TO 2000 PSI. FINAL SQZ PRESSURE OF 1720 PSI (1340 PSI OVER BASE INJECTION PRESSURE) CLEAN OUT EXTRA CEMENT & LEAVE TOP © 7150' RKB. FREEZE PROTECT WELL W/ DIESEL TO 2500' CTMD. 2/6/10 GAUGED TBG TO 2.795" TO 7147' SLM. IN PROGRESS. 2/7/10 TESTED CMT PLUG TO 2000 PSI, GOOD. GAUGED TBG TO CMU @ 6926' RKB, 6938' SLM. TAGGED CEMENT @ 7149' SLM, EST. 7137' RKB. BAILED — GAL OF CEMENT OFF HARD PLUG @ 7149' SLM, EST. 7137' RKB. COMPLETE. 2/9/10 PRE -CTD MITOA- PASSED; PT& DD MV- PASSED; PT& DD SV- PASSED; 3/16/10 DRIFT TBG TO 2.72" & TAGGED LINER TOP @ 7129' RKB. SET CATCHER @ SAME. PERFORMED 30 MIN SBHP @ 7100' RKB =3068 PSI, 153 DEG F & 15 MIN GRADIENT @ 6979' RKB =3019 PSI. PULL DV's @ 5088' & 3817' RKB. SET 1/4" OV @ 5088' RKB. IN PROGRESS. 3/17/10 PULL DMY VLV @ 2490' RKB. SET GLV'S @ 3824' RKB & 2490' RKB. PULL CATCHER @ 7129' RKB. COMPLETE I • ConocoPhiIIips Time Log & Summary WellWew Web Reporting Report Well Name: 1E -12 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 2/15/2010 10:00:00 AM Rig Release: 3/14/2010 11:00:00 AM `, Time Logs Dur 5 _Depth, E' Depth Phase J. Code " Subcode T Comment 02/14/2010 24 hr Summary Rig down rig and mobilize to 1 E 12:00 17:00 5.00 MIRU MOVE MOB P Rig down rig 17:00 00:00 7.00 MIRU MOVE MOB P Mobilize to 1E 02/15/2010 Mobilize rig from 31 to 1E, RU /NU, BOP testing, Repair reel *** Exempt move due to grade being over 5% on access road. * * ** 00:00 01:00 1.00 MIRU MOVE MOB P Moving rig to 1E 01:00 05:00 4.00 MIRU MOVE MOB P From 11:30 - 2:30 had to utilize three Sows to move Mud module around corner and up grade behind CPF1 access road. Able to continue moving Mud module while dispatched CAT from Peak to move sub structure. Also had graders' scratch the road around corners and access road. 05:00 06:00 1.00 MIRU MOVE MOB P Continue mobilizing to 1 E 06:00 06:15 0.25 MIRU MOVE MOB P On location, Crew change, PJSM 06:15 10:00 3.75 MIRU MOVE NUND P Spot rig over well, NU BOP's, set down stairs, plumb modules together 10:00 13:30 3.50 MIRU WHDBO NUND P Nu BOP's, Install IA valves and work on reel. 13:30 18:00 4.50 MI RU WHDBO BOPE P Rig Accepted * * * * ** *Start BOP testing * ** Witness waived by the state. Working on reel to P/U and change out Pillow block bearings. 18:00 18:30 0.50 MIRU WHDBO BOPE P Crew change/ PJSM 18:30 00:00 5.50 MIRU WHDBO BOPE P Continue BOP testing, working on reel. Upper Blind rams failed. repair. Take on SW into pts for Bio & well displacement. 02/16/2010 Completed Bop Test & Reel Repairs, made tie -in w /GR to PDC log.Started milling pilot hole w /3% kcl with 2ppb biozan. 00:00 01:00 1.00 MIRU WHDBO BOPE P Continue with BOP test 250/3500 psi. Replaced upper Blind /Shear rams - tested. Complete cleaning up the tools inside reel and move cart over well to test inner reel iron & valves. Migged cable & tested good. 01:00 01:30 0.50 MIRU WHDBO BOPE P Start filling CT with SW to pressure test inner reel iron, injector & valves. Page 1 of 33 , Time togs Date From To =` Dur° S.: Depth E: Depth = Phase = -Code Subcode _ T _ Comment 01:30 04:30 3.00 MIRU WHDBO BOPE T Inner reel valve not holding, grease and re -test. * *Over 12 hour BOP test time.*" Air in CT, re- position CT over well for better rate. Good test on Inner reel iron & inner reel valve. BOP test completed. ** *3 Hours Billable Rig Repair time * ** 04:30 06:30 2.00 MIRU WHDBO SEQP P Rig off injector and R/U & test lubricator to Pull BPV. Crew change on rig. 06:30 09:00 2.50 PROD1 WHPST PRTS P Pressure test both PDL to 2500 psi. Complete valve checklist on rig. 09:00 11:00 2.00 PROD1 WHPST EQRP T Went to pressure test Tiger tank line and found it to be frozen. Break down lines & rig up new line. * * *2 hours of billable rig repair time * ** 11:00 12:00 1.00 PROD1 WHPST CIRC P Purge air through and pressure test TT line. Pressure test to 1500 psi. 12:00 12:30 0.50 PROD1 WHPST CTOP P M/U injector over well & open Master Swab valves to monitor well for flow. Zero pressure on well, no flow at shakers. 12:30 13:00 0.50 PROD1 WHPST SFTY P Safety meeting for BHA deploying and quick pre -spud for first run. Talked about reel inspection, BHA clearance, CMU sliding sleeve, Tiger tank returns, cement sheath and tie in points with first BHA. 13:00 14:00 1.00 62 62 PROD1 WHPST PULD P P/U BHA # 1 with .9 AKO and 2.80" D331 Mill. 14:00 15:00 1.00 62 6,916 PROD1 WHPST TRIP P RIH with EDC open circulating SW to Tiger tank. perfrom weight check @ 1000' to inspect reel. 15:00 18:00 3.00 6,916 7,135 PROD1 WHPST DLOG P Done with tie -in w/ GR to PDC log @ 6916' . Had -27' corrections. perform wt ck =27k. rih wt =16k. Continue in hole to tag top of cement. 18:00 19:30 1.50 7,135 7,065 PROD1 WHPST CIRC P Tag top of cement @ 7135'. Puh to 7065' to swap hole over to milling fluid. Up wt= 27k / pump rate= 1.55 bpm / ctp =2510 psi / whp= 45 psi. 19:30 19:45 0.25 7,065 7,065 PROD1 WHPST CIRC P Done swapping over to milling fluid.Close EDC. 19:45 19:51 0.10 7,065 7,135 PROD1 WHPST MILL P RIH and to top of cement and start drilling pilot hole with toolface @ 20 deg ROHS. CTP= 3200 psi ( free spin) (a, 1.5 bpm / whp= 20 psi. 19:51 20:00 0.15 7,135 7,137 PROD1 WHPST MILL P Seen 3.5" tubing wall contact @ 7137'. ROP @ 10.2 / WOB 2K / CTP= 3535 @ 1.43 bpm / whp =20 psi. Page 2 of 33 • Time Logs Date From To Dur` - S. Depth E: Depth Phase Code Subcode T = Comment . 20:00 20:45 0.75 7,137 7,138 PROD1 WHPST MILL P Had three stalls @ 7137' appears mill is tracking the side of casing. Seen no trace of metal at shaker, justcement. Slow speed down and increase pump rate to 1.5 bpm / ctp= 3280 / whp =18 / ROP= 11.0 20:45 21:15 0.50 7,138 6,955 PROD1 WHPST DLOG P Had a total of 4 stalls @ 7137.7' Call town Engineer about changing tool face. Perform another tie -in with GR to PDC log to double check tie- in depth again. 21:15 21:45 0.50 6,955 6,775 PROD1 WHPST DLOG P Had the same -27' corrections with GR to PDC log. Perform CCL log TIE -IN @ 16 fpm from 6850' to 6775' to catch Pup joint @ ( 6788' & 6761' ) . 21:45 22:15 0.50 6,775 7,145 PROD1 WHPST MILL P Change tool face 180 deg. Back on top of cement milling. CTP =3312 @ 1.5 bpm / whp =18 / WOB= 0.92 / ROP =3.2 22:15 23:30 1.25 7,145 7,150 PROD1 WHPST MILL P Start rolling tool face back to 20deg @ 7149.7'. CTP =3555 @ 1.45 bpm / whp =18 / WOB =2.5 / ROP =12.2. 23:30 00:00 0.50 7,150 7,154 PROD1 WHPST MILL P Tool face back to 20deg ROHS. CTP =3564 @ 1.43 bpm / whp =17 psi /WOB 2.47 / ROP 12.2 02/17/2010 Completed milling cement down to 7265'. Perform Dummy WS run down to 7250'. 00:00 00:15 0.25 7,154 7,155 PROD1 WHPST MILL P Continue milling pilot hole @ 1.4 bpm / CTP =3340 / WHP =17 psi / 20 deg tool face. ROP =10 / WOB 1.6.Stall on D- nipple @ 7156.26' 00:15 00:30 0.25 7,155 7,157 PROD1 WHPST MILL P Mill passed D- nipple. Lower rate to .50 bpm & puh to 7135' to make sure 3.5" tubing wall is clean from changing tool face. Rih again pumping @ 1.40 bpm / ctp and wt looks good. Repeat process 2 more times. Up Wt= 27k / Rih Wt =11 k 00:30 00:45 0.25 7,157 7,168 PROD1 WHPST MILL P Rih to 7157' & start milling pilot hole again with toolface @ 20 deg. CTP =3230 @ 1.40 bpm / whp =17 psi / ROP =15 / WOB =1.6 ** casing wll contact made @ 7164.2' * * ** 00:45 02:45 2.00 7,168 7,192 PROD1 WHPST MILL P Still milling on hard cement @ 1.5 bpm. ROP down to 5.0 / ctp =3560 / whp =19 / WOB =1.64. 02:45 06:45 4.00 7,192 7,217 PROD1 WHPST MILL P ROP up to 15.0 / WOB =2.3 / CTP =3540 @ 1.5 bpm / whp =23 psi. Good cement returns all night. 06:45 10:30 3.75 7,217 7,265 PROD1 WHPST MILL P Had two stalls @ 7217.8' Slow ROP 10 fph, 1.45 bpm, circ press 3500psi, WOB 1.8, BHP 3600psi. Conitnue milling ahead. Good cement returns no metal shaving on magnets. Page 3 of 33 Time L=ogs Date From To Dur Sc -Depth =E. Depth �Phase = °Code Subcode T Comment 10:30 11:00 0.50 7,265 7,265 PROD1 WHPST ELOG P TD cement Pilot - P/U weight 26K, Looked clean through cement & nipple. Tie in +1 ft correction. CT weight dry on P/U 32K 11:00 14:00 3.00 7,264 7,264 PROD1 WHPST REAM P Dry tag / drift area. Small weight bobble @ 7169' - dry tag bottom @ 7263.5'. Backream area starting @ 7175' @ lfpm 160 LOHS. Light motor work @ 7171' up to 7157'. RIH 5 fpm down to 7178', cleaner on second pass. Performed 4 passes last two looked very clean. Dry run last trip in. No weight bobbles RIH. Flo -test when doing dry run. No -flo 14:00 16:00 2.00 7,260 71 PROD1 WHPST TRIP P POOH past Sliding Sleeve. Perform flo -test good - POOH 80 fpm pumping @ 1.2 bpm. 16:00 17:00 1.00 71 0 PROD1 WHPST PULD P No flow @ surface, lay down BHA. Mill guaged 2.80" go - 2.79" no -go. Cleaned injector gripper blocks. P/U BHA* 2 Dummy WS 17:00 18:00 1.00 0 0 PROD1 WHPST SFTY P Hold pre -spud meeting & crew change. 18:00 19:00 1.00 0 71 PROD1 RPEQP1 PULD P PU Baker whipstock dummy for drift. 19:00 20:30 1.50 71 6,935 PROD1 RPEQP1TRIP P RIH W /Dummy Whipstock @ 80 fpm / ctp =1470 psi @ 0.40 bpm / whp =13 psi / Rih Wt= 2k 20:30 20:45 0.25 6,935 6,959 PROD1 RPEQP1DLOG P Wt Ck 28k / RIH Wt= 11k CTP= 1780psi @ .40 bpm /WHP= 12 psi.Start Tie -In log @ 2.5 fpm from 6935' to 6985' had -27' correction.(New Bit Depth 6958.60 ) 20:45 21:00 0.25 6,959 7,250 PROD1 RPEQP1TRIP P Continue in hole Dummy Whipstock Drift. Rih Wt =13K. Good drift to set depth, no problem with weight. 21:00 22:45 1.75 7,250 0 PROD1 RPEQP1TRIP P POOH. Up Wt= 28K 22:45 00:00 1.25 0 0 PROD1 RPEQPI PULD P OOH. No flow @ surface.Safety Meeting. lay down dummy whipstock. P/U BHA #3. 32/18/2010 Set Whipstock. Completed Window Milling (Lower Window) 00:00 01:00 1.00 0 71 PROD1 RPEQPI PULD P Continue to MU BHA #3 W/ Whipstock. 01:00 02:45 1.75 71 6,945 PROD1 RPEQP1TRIP P Done MU Whipstock. RIH W /EDC open.RIH WT= -4K 02:45 03:15 0.50 6,945 6,960 PROD1 RPEQPI DLOG P Perform Tie -In with GR.RIH wt =13k / CTP =1845 @ 0.55 bpm /WHP =13 psi (6945' to 6986.85) - 27' Corrections. New Depth 6959.85 Up WT= 27k 03:15 03:30 0.25 6,960 7,234 PROD1 RPEQP1WPST P Down on pump.Close EDC / Continue in hole to Whipstock Set Depth.Rlh Wt =13k. Set TOWS @ 7225' 0 deg high -side ( 7234.3' Bit Depth) Psi to set 4758 psi / Seen 6k WOB during set. Set down wt to ensure good set on slips. Page 4 of33 • Ti Logs = Date From To Dur - S. Depth E. Depth - `Phase "Code _ Subcode T Comment 03:30 05:00 1.50 7,234 0 PROD1 RPEQP1TRIP P POOH. Up Wt= 27k / pumping @ 1.0 bpm keeping hole full of milling fluid. CTP =2270 / whp =15 psi. 05:00 06:00 1.00 0 0 PROD1 RPEQP1 SFTY P Hold Pre -Spud Meeting & Crew Change. 06:00 07:30 1.50 0 73 PROD 1 WHPST PULD P Lay down BHA# 3, setting tool looked good. P/U Milling BHA # 4 with 2.80" mill. 07:30 09:30 2.00 73 7,227 PROD1 WHPST TRIP P RIH pumping .3bpm Tie in @ 6945' ( -27) correction. Stop pumping - RIH to 7170' weight check. up - 28K, RIH 11K. Dry tag @ 7227' - some weight bobbles prior to tagging @ 7223'. P/U weight dry @ 31K. 09:30 10:00 0.50 7,227 7,226 PROD1 WHPST MILL P Bring pumps up to 1.40 bpm, circ. press 3500psi, RIH slowly wet tag softly @ 7226.3' motor work/stall. P/U and begin window milling process. 10:00 15:00 5.00 7,226 7,229 PROD1 WHPST MILL P Start window milling, two light stalls @ 7226.2', Good motor work from 7226.3' 1.4 bpm, circ press. 3550, WOB 1.2K, Ct weight 9.2K, WHP 10, returns 1.36 bpm. Some metal cutting to surface @ 7228', Motor work still detected but weight transfer is light at times. WOB 2.8 K @ 1 fph 15:00 16:30 1.50 7,229 7,231 PROD1 WHPST MILL P Conitnue milling with better weight transfer, better metal returns to surface @ 7229.5'. Not setting down as much WOB as per procedure near casing exit 1.2 WOB. Ct weight 4K, 1.40 bpm, circ press. 3480, BHP 4080 psi. (a7 1 fph. 16:30 17:30 1.00 7,231 7,231 PROD1 WHPST MILL P Had a stall @ 7230.8'. Shut down, P/U weight 28K, re- orient TF to HS, slowly start back into it. Continue milling 1 fph. Grab a B/U sample for GEO. Free -spin 4080. Exit may be @ 7230.5'. Two more light stalls @ 7230.8 & 7230.9' Samples indicate formation 10 - 18 %. 17:30 19:00 1.50 7,231 7,231 PROD1 WHPST MILL P Motor work picked up @ 7231' sting mill on casing.Done milling done to bottom window @ 7231.2 19:00 20:00 1.00 7,231 7,241 PROD1 WHPST DRLG P Completed milling 10' of formation down to 7241' 20:00 20:30 0.50 7,241 7,241 PROD1 WHPST DRLG P Start reaming passes from 7241 up to TOWS.Up wt =28k / Rih Wt 9k / CTP =3660 @ 1.5 bpm. Seen clean pick -up weight & rih wt. Made two reaming passes and made pass down thru window not pumping to 7241'. Window looked clean after dry tag. Start swapping wellbore over to 9.5 ppg Flo -Pro. Page 5 of 33 • • Date " From To Dar S "Depth E. DeptlS` Phase Code Subcode T ='= Comment 20:30 22:00 1.50 7,241 0 PROD1 WHPST TRIP P Flo -Pro @ Bit. Open EDC and Start POOH holding a target ECD of 11.6 ppg.Up Wt =29K / CTP= 2700 @ 1.5 bpm / whp =0 22:00 22:15 0.25 0 0 PROD1 DRILL SFTY P OOH & tagged up with bha.Close EDC. Watch for no -flow. Safety meeting. 22:15 00:00 1.75 0 0 PROD1 DRILL PULD P LD BHA #4 & PU Drilling BHA. 02/19/2010 Landed Build @ 7360' / 6291' tvd. Drill ahead to 7405' for final survey & turn. Lost 52 bbls for 24 hours. 00:00 00:30 0.50 0 0 PROD1 DRILL PULD P Done Making Up & Testing BHA #5. PT Lubricator Connection. 00:30 01:45 1.25 0 6,965 PROD1 DRILL TRIP P Tag -Up and Get BHA depth enter @ 62.19'. Open EDC and Rih 01:45 02:00 0.25 6,965 6,979 PROD1 DRILL DLOG P Tie -In Log To GR @ 2.5 fpm. RIH WT =12k. CTP =1450 @ .5 bpm / WHP =12 psi.Up WT =24k / close EDC. Add -26.5' correction. ( New Depth 6952.82' ) 02:00 02:15 0.25 6,979 7,240 PROD1 DRILL TRIP P Continue tripping in hole pumping @ min rate. 02:15 04:00 1.75 7,240 7,277 PROD1 DRILL DRLG P Seen no Problem thru window. Start drilling the build @ 1.5 bpm CTP =3400 psi free spin. Whp =15 psi . RIH WT= 10K ECD =11.6 ppg. WOB= 1.0 - 1.5 / ROP= 25 to 30. 04:00 06:00 2.00 7,277 7,280 PROD1 DRILL DRLG P Drilling into hard section. ROP down from 25 to 3.0. WOB =3.1 / CTP =3650 @ 1.5 bpm / whp =18. 06:00 09:00 3.00 7,280 7,310 PROD1 DRILL DRLG P Drilling break then hard stall @ 7286'. BHA popped out of window. Continue drilling ahead. CT weight 10k, circ. press 3300psi, 1.40 bpm, BHP 3800 psi, ECD 11.70, ROP 15 fph but slowed to 3 fph @ 7295' - Drilling through stringers off /on. 2 bbls an hour losses. 09:00 12:00 3.00 7,310 7,330 PROD1 DRILL DRLG P Drilling ahead with slow ROP, shale 1%, light cement & 90% siltstone in samples. ROP 10 fph, 1.40 bpm, circ 3400, BHP 3822, ECD 11.72 © 7330'. Bit may be pluggin up. 27 bbls loss from Midnight to Noon. 12:00 13:00 1.00 7,330 7,335 PROD1 DRILL DRLG P 7334' P/U off bottom, have not made much footage in last hour. P/U weight 26K. Wiper up to window to clean up. RIH and zero WOB sensor. Good hard WOB indication. WOB 2.3K, CT weight 9.3, ROP 4 fph, 1.45 bpm, 3600 psi, BHP 3840, ECD 11.81. Drilled 1 ft and took off, ROP 60 fph. Losing roughly 4 bbls /hour. Page 6 of 33 I Time L Date ' =`From To Dur S. Depth- E. Depth ` Phase _Code Subcode T ° Comment 13:00 15:00 2.00 7,335 7,345 PROD1 DRILL DRLG P High Clay percentage in samples. Bit could be balling up or plugging up. Make up a pill of drill zone to prevent bit balling. ROP 20 fph. Good survey @ 7315'. P/U slowly and pump a 10 bbls pill. 15:00 16:00 1.00 7,345 7,360 PROD1 DRILL DRLG P Good ROP with 10 bbls Drill Zone sweep, 70 fph, after it pushed out ROP went back down to 20 fph. Sample at surface is 99% clay returns. Pump final 15 bbls of sweep. Good ROP 70 fph 16:00 17:00 1.00 7,360 7,405 PROD1 DRILL DRLG P Landed Build @ 7360 MD & 6291 _ TVD, continue drilling ahead until 7405' for a final survey & turn. Hit a hard bottom @ 7378' (possible fault). Drill through @ 7380' Back to ROP 30 fph. 17:00 19:30 2.50 7,405 0 PROD1 DRILL TRIP P Complete build section, POOH . Saw a light weight bobble when top of BHA came through window. Open EDC @ 7200' Continue POOH Pumping 1.3 bpm to clean hole. 19:30 19:45 0.25 0 0 PROD1 DRILL SFTY P OOH. close edc /check for no -flow @ surface for 15 mins. safety meeting.inspect injector while removing bha. 19:45 21:45 2.00 0 0 PROD1 DRILL PULD P Still No -flow @ surface or pits.lay down Bha #5 and pu bha #6 for horizontal section.Seen two small marks between the DGS & DPS, picture on s- drive, also the bit look, no broken buttons / had 1 pluged port. Call CTD Engineer and discuss marks & plan forward. Decision was made to carry on with horizontal section. 21:45 23:15 1.50 0 6,975 PROD1 DRILL TRIP P Done making up BHA #6. Tag w/ bha. add depth ( 71.77') open EDC & RIH pumping @ min rate. 23:15 23:21 0.10 6,975 6,988 PROD1 DRILL DLOG P Log GR Tie -In from 6975' to 6988.08 @ 4 fpm / RIH Wt =13k. -26' correction ( new corrected depth 6962.08' feet ) 23:21 23:30 0.15 6,988 7,255 PROD1 DRILL TRIP P Close EDC. Continue RIH. 23:30 23:36 0.10 7,255 7,275 PROD1 DRILL DLOG P Log RA Marker from 7255' to @ 4 fpm.Seen small bobble going thru window. 23:36 00:00 0.40 7,275 7,380 PROD1 DRILL TRIP P Continue RIH & tagged up @ 7368' pu & rih again.29k on up wt.Able rih in build section @ 7 fpm.(total losses for last 24 hrs 52 bbls) 02/20/2010 Drilling on Lateral Section. 8.0 hrs of Weather Hold due to Phase 3 condition. Total of 70 bbls loss in 24 hour 00:00 00:30 0.50 7,380 7,405 PROD1 DRILL TRIP P Still having problems. sitting down from 7368' to 7394'. Hard shale section. • Page 7 of 33 • • Time Logs Date From To Dur S Depth _ E. PhaSe =i Subcode T ° Comment 00:30 01:30 1.00 7,405 7,406 PROD1 DRILL DRLG P Dilling Lateral. CTP =3800 @ 1.4 bpm / whp =20 psi / Rop= 10 - 15 / wop= 2.5 to 3.0. 01:30 01:45 0.25 7,406 7,290 PROD1 DRILL WPRT P Made little or no footage.puh and make wiper trip. up wt= 29k / _ ctp =3888 @ 1.4 BPM / whp =20 psi. 01:45 02:00 0.25 7,290 7,406 PROD1 DRILL TRIP P Run back in hole to last depth. Seen over pulls with motor stalls @.7395 & 7374 02:00 03:45 1.75 7,406 7,443 PROD1 DRILL DRLG P Back on bottom drilling hard shale @ 1.4 bpm ctp =3460 / whp =19 psi.rih wt =13k / WOB =2.1 / ROP 4.1. 03:45 04:30 0.75 7,443 7,450 PROD1 DRILL DRLG P Drilling ahead @ 1.4 bpm / ctp =3520 / whp =21 psi. WOB =1.8 to 2.3 / ROP up to 33. ECD -11.8 04:30 06:30 2.00 7,450 7,512 PROD1 DRILL DRLG P Call for Sample. Continue with drilling operation. WOB =1.8 / ROP =27. CTP =3600 @ 1.4 bpm / WHP =20 psi. ECD 11.9. Sample = 50% siltstone, 40% shale , 10% sand. 06:30 07:00 0.50 7,512 7,100 PROD1 DRILL WPRT P Pull a wiper to see if ROP increases on bottom. ROP was 33 fph. P/U weight 27K, perform a MAD PASS. Having overpull @ 7318' RIH slack off weight. P/U dragged through with no problems. Decide to Pull up through window and clean up to TOC. Lots of Shale coming over shakers. 07:00 07:30 0.50 7,100 7,380 PROD1 DRILL WPRT P RIH - seen slight weight bobble, 7380' to 7390' pumping .4 bpm. Ran past & increase pump rate - Pull back through to backream area TF HS to clean up area. Stacking out when trying to RIH with slow pump rate. Sticky formation. ECD 11.7, BHP 3840 psi. 07:30 08:00 0.50 7,380 7,050 PROD1 DRILL WPRT P Having a hard time in tight area, P/U into cased hole Due to Phase 3 weather conditions. Pulled heavy @ 7315'. Work it free, Continue POOH to 7050' Trap pressure WHP 600 psi, BHP 3800 psi. Open EDC. Sit for 15 minutes. 08:00 12:30 4.50 7,050 7,050 PROD1 DRILL CIRC T 15 minute shut in test. WHP 600, BHP 3800, Circ 1100, depth 7050', ECD 11.5. After 15 minutes. WHP - 500 psi, BHP 3460, Circ 780 psi, ECD 10.93. Start circ fluid keeping BHP @ 3700 psi. @ 1bpm. Added up to 12# Kla -gaurd & .5 % Drillzone. 12:30 15:00 2.50 7,050 1,500 PROD1 DRILL TRIP T Move CT up hole pumping 1.5 bpm following MPL to clean up well while waiting on weather. heavy returns of shale started coming over the shakers @ 6000' and up. Choke plugging off @ 2000' from surface. Cleaning up, circ two bottoms up. RIH Page 8 of 33 • • Time Logs Date ' • From ` To Dui S. Depth -- E. Depth Phase "'Code - "Subcode T Comment 15:00 16:00 1.00 1,500 7,000 PROD1 DRILL TRIP T RIH - pumping 1.5 bpm, following MPL. 16:00 16:30 0.50 7,000 7,270 PROD1 DRILL TRIP P Phase 3 lifted - RIH, close EDC. and tie into PIP tag, Zero foot correction. Trapped 3800 psi on BHP, 550 WHP. pressure leaked off into formation while RIH through window. 16:30 17:30 1.00 7,270 7,055 PROD1 DRILL WPRT P RIH saw small weight bobble @ 7380' - RIH to 7415', P/U to window to clean OH. P/U weight 26K. 1.5 bpm, 3500 psi. Overpull @ 7387', Pump press. climbed up to 400 psi, Work through area, by pump rates and RIH /POOH. made it up to next bad spot of 7320'. Magic rate seems 1 bpm, Speed 5 - 7 fpm. 17:30 18:30 1.00 7,055 7,508 PROD1 DRILL TRIP P Done w /wiper trip. Close EDC. Start rih again @ min rate thru TOC. Shut down pump and trap psi to run thru TOWS & Window section.Seeing wt bobble 7468',7485' and 7492'. Stack out 7508' can't work passed lateral section.Puh and sweep lateral section again.Up wt =27k / ctp =3700 @ 1.45 by / whp= l6psi. Continue to try different rates and speed to reach end of lateral section to continue drilling operations. 18:30 20:30 2.00 7,508 7,516 PROD1 DRILL DRLG P Finally back on bottom drilling.CTP =3955 @ 1.4 bpm / whp =18 psi / WOB= 2.0 -2.5 / ECD= 11.9 / ROP =13.0. 20:30 21:30 1.00 7,516 7,525 PROD1 DRILL DRLG P Started a high -low vise pill @ 7516' ( 5 &5)ctp= 3900 @1.4 bpm / whp =l7psi / ECD 12.2.WOB= 2.8. ROP= 7.0.Continue drilling ahead slowly. Still seeing a good amount of shale in returns. 21:30 22:45 1.25 7,525 7,570 PROD1 DRILL DRLG P ROP picked up after high -low visc was pump around.ROP @ 35 / WOB =1.72 / ECD =12.1 / CTP =3840 @ 1.40 bpm / whp =15 psi.Continue drilling ahead.Started another high -low visc pill 22:45 23:30 0.75 7,570 7,245 PROD1 DRILL WPRT P High -low visc sweep around & headed up. PUH for @ 10 fpm wiper trip.Up wt =27k. CTP =3500 @ 1.4 bpm / whp =16 psi.Clean pick -off bottom.Seen overpulls @ 7380,7340,7330, &7315.Stall @ 7330' 23:30 00:00 0.50 7,245 7,570 PROD1 DRILL TRIP P RIH again after wiper. Sat down @ 7330',7380',7398, &7540' no stalls.Had to work passed tight spot @ 7540' Seen heavy overpulls and set weight before getting passed.Total Losses to Fm for the day =68 bbls. • Page 9 of 33 T Date Frain To' - { E. Depth Phase Code S`bcdde'-' Comment 02/21/2010 o*hrSummary Unable to re-enter drill section @ 7626' feet due to collapse or hole angle. Decision was made to set another WS. 00:00 00:15 0.25 7.570 7,625 PROD1 DRILL DRLG P Back on bottom drilling ahead. CTP=3720 @ 1.4 bpm / whp=18)mx}a~1.9 /ROP~25'30 fph. ECD 12.0. Next wiper trip @ 7620' feet. Start unloading new load ofS.5ppg FP-SF w/12ppbK3e-Gond. Started another High-low visc ( 5 & 5 follow with the new 9.5 ppg drilling pill. &12ppgK|u'Gand.~~Mud Swap** 00:15 02:15 2.00 7.625 7.250 PROD1 DRILL WPRT P High-Low visa sweeps out and headed up hole & New drilling pill @ bit. PUH for wiper trip. Up wt=27k. CTP~3800 @1.4bpm/VVMP=16 psi.Seen several overpulls & weight bobble during wiper thp.(7530'to 73OO') 0215 0615 4.00 7,250 7.380 PROD1 DRILL 'TRIP T RIH after wiper trip.Se down (7373 to 7377') Fought tight spo & could not get past 7380'. Multiple speeds/pump rates etc. 7330' bigger hole problems, Weight and circ pressure increases. No luck. 08:15 08:15 3.00 7.380 7.275 PROD1 DRILL CIRC T P/U above window and open EDC to Circulate B/U. while discuss with town. Plan forward to ease into OH and try to gain more information regarding top of A-3 and Bottom of A-4, while they discuss anotehr window depth. Circulated 8/U and Shale cutting to surface, normal fine cuttings. 08:15 09:15 1.00 7,375 7,375 PROD1 DRILL WPRT T Close EDC RIH through window, no problems. Start pumping. 3 bpm. Made it down to733O'Nnweight problems 'dvoP/U25K.VmHP3OO. BHP 3800, ECD 11.8. RIH down to 735O' weight bobble. Attempts ~7375' stacked out @0. bpm - P/U clean 25K to 7320', 7375' stacked out @.Obpm.P/Uclean 26K, to 7320, 7375.3 @ 1.2 bpm stacked out, P/U 26K, light drag, then overpull @ 7310', Ann pressure built up, RIH, lower pump to .4 bpm and worked CT free. POOH above window. 09:15 1015 1.00 7,375 3.600 PROD1 DRILL TRIP T Open EDC, circulate B/U - call tow to discuss possible hole failure or not finding original lateral @ 7375'& getting packed off above BHA. Possible AKO change got large samples of small shale rolling over shakers. `. .� � }'.�`� ��Pme1Uof83_ I • Time Logs Date From To = Dur S. Depth _ E: Depth _ Phase ='Code ` ` Subcode T Comment 10:15 13:15 3.00 3,600 71 PROD1 DRILL TRIP T POOH following MPD for whipstock run. Started getting pebble sized shale chunks over the shakers © 3200ft. Flush choke. Continue POOH, getting more chunks @ 2200'. Flush & POOH 13:15 14:45 1.50 71 0 PROD1 DRILL PULD T Ct © surface, flush the choke once more. Safety meeting for Undeploying BHA. While undeploying the WHP would leak off from 600 psi to 400 psi in 7 minutes anytime the pump was shut down. Pumped 15 bbls while undeploying to try and keep 600 pis on WHP. 14:45 16:15 1.50 0 71 PROD1 WHPST PULD T P/U Dummy Whipstock BHA to RIH and drift well and clean any debris from well. Serviced injector and checked all fluid levels 16:15 18:30 2.25 71 6,970 PROD1 RPEQP1TRIP T RIH following MPD with BHA * currently in Phase 2 conditions* 18:30 18:45 0.25 6,970 6,987 PROD1 RPEQP1DLOG T Tie -log @ 3fpm.R1h Wt =12k. -26.5 feet correction.(6960' new corrected depth) 18:45 19:00 0.25 6,987 7,220 PROD1 RPEQP1TRIP T Rih w/ for dummy whipstock drift. 19:00 20:30 1.50 7,220 0 PROD1 RPEQPITRIP T No problem drifting down to 7220' .POOH.Up Wt =24k. CTP =3230 psi @ 1.4 bpm / WHP =170 psi . 20:30 21:30 1.00 0 0 PROD1 RPEQP1PULD T OOH.PJSM.Un- Deploy Dummy Whipstock BHA Drift. Inspected Injector & Chains. 21:30 21:45 0.25 0 0 PROD1 RPEQP1 SFTY T Safety Meeting W/ BOT before Making up Whipstock BHA. 21:45 22:45 1.00 0 0 PROD1 RPEQP1 PULD T Start Making Up BHA & Whipstock. 22:45 00:00 1.25 0 3,800 PROD1 RPEQP1TRIP P Done making up BHA #7 w/ whipstock.Rih following MPD © 60 fpm. 02/22/2010 Made 2 Dummy WS Drift to Confirmed well was clear & clean of any debris. RIH & Set TOWS @ 7200'. Total losses for 24 hours 142 bbls 00:00 00:15 0.25 3,800 5,000 PROD1 RPEQP1TRIP P Continue to RIH with Whipstock @ 60 fpm. RIh Wt =6k / CTP =1560 @ .25 bpm / WHP =400 psi. 00:15 00:45 0.50 5,000 5,600 PROD1 RPEQP1TRIP P Lost return to pits while tripping. Pump rate still the same / rih wt =10k / whp= 5 -10 psi. Swap over to other choke system.Still no flow to pits. Looks like well starting to drink. Wt Ck 17k.Continue to rih w/ whipstock. 00:45 01:00 0.25 5,600 4,800 PROD1 RPEQP1TRIP T PUH. Annular psi is climbing / Bore PSI is climbing/ CTP is climbing. Not seeing any returns at shaker. CTP climbed from 1560 to 1890 psi in 100'.Checked all surface lines for blockage (all good at surface). Page 11 of 33 • • Time Logs Date - From = To . - Dur S Depth" E. Depth_ Phase -- Code = Subcode T -= Comment 01:00 02:00 1.00 4,800 5,600 PROD1 RPEQP1TRIP T Try rih again. Annular & Bore psi start climbing with the circulations psi. Still very little returns. (Still losing) 02:00 02:30 0.50 5,600 0 PROD1 RPEQP1TRIP T Seeing heavy thick fluid in returns now. ECD still climbing with all the other pressure. Call town engineer about problems. Start pooh.Losing .5 bpm to formation.Up Wt =18k / ctp =3150 @ 1.0 bpm / ECD =15.3 / Whp =53 psi. 02:30 04:15 1.75 0 0 PROD1 RPEQP1SFTY T OOH.Trapped WH psi. Safety meeting before Un- Deployment. 04:15 06:15 2.00 0 0 PROD1 RPEQP1PULD T Start Un- Deploy of Whipstock to make up Dummy Whipstock. 06:15 09:15 3.00 0 0 PROD1 RPEQP1PULD T Crew change and P/U .9 AKO with 2.79" D331 mill to clean out well. 09:15 12:15 3.00 0 7,210 PROD1 RPEQP1TRIP T RIH - noticed our BHP is about 250 psi higher @ 5700'. Stop and slowly move pipe while pumping a B/U monitoring returns, looked good RIH. Slowed pump rate to .3 bpm RIH through CMU & tie in - - 27 ft correction. Weight check - 23K. RIH 20 R through cement pilot pumping .3 bpm down to 7210' . Clean return the entire way down. 12:15 13:15 1.00 7,210 7,210 PROD1 RPEQP1CIRC T P/U weight is clean 25K, pumping .4 bpm off bottom increase to . 6 until TOC. Holding MPD schedule, opened EDC @ 6100. Curculate B/U @ 1.5 bpm to ensure hole is clean. 1.5 bpm, returns 1.42, Circ 3300, BHP 3830, WHP 80, ECD 12.05. Returns were clean. 13:15 14:45 1.50 7,210 71 PROD1 RPEQP1TRIP T POOH following MPD, pumping through EDC. 14:45 16:15 1.50 71 0 PROD1 RPEQP1PULD T Undeploy BHA. Losing about 2 bph while holding MP @ surface. 16:15 19:00 2.75 0 0 PROD1 RPEQP1PULD T P/U Whipstock BHA and deploy. 19:00 21:00 2.00 0 6,970 PROD1 RPEQP1TRIP P RIH with Whipstock @ 60 fpm - following MP schedule. 21:00 21:15 0.25 6,970 6,985 PROD1 RPEQP1DLOG P Perform Tie-In W/ GR @ 2 fpm from 6970' to 6985'. RIH Wt =13k / CTP =1950 @ 0.50 bpm / WHP =310 psi . Had a -26 feet correction. (new depth 6959') Wt Ck =23k. Trap psi on wellbore /down on pump.Close EDC 21:15 21:21 0.10 6,985 7,209 PROD1 RPEQP1TRIP P Continue in with Whipstock.Rih Wt= 11k.WHP =340 psi 21:21 21:30 0.15 7,209 7,209 PROD1 RPEQP1WPST P On Depth @ 7209' BOW / TOWS @ 7200'. On Line with pump to set Whipstock @ 0 deg High Side.Seen Good Set. Set down 3k WOB to Confirmed.Seen clean pick -up. - - Page 12 of 33 • • Time L Y: Date From To Dui S Depth E. Depth Phase Code ` ` Subcode T Comment 21:30 22:45 1.25 7,209 0 PROD1 RPEQP1TRIP P Pooh, Following MP Schedule.Up WT= 24k.CTP =2650 @ 1 bpm / wh =320 psi P P 22:45 23:00 0.25 0 0 PROD1 RPEQPISFTY P OOH.Safety Meeting before Un- Deploy BHA 23:00 00:00 1.00 0 0 PROD1 RPEQP1PULD P Un- Deploy BHA #10 X2/23/2010 Finished Milling Window.Started Drill the Build Section. Total Losses for 24 Hours =76 bbls. 00:00 01:15 1.25 0 0 PROD1 WHPST PULD P Continue to Un- Deploy & Deploy Bha. 01:15 02:45 1.50 0 6,975 PROD1 WHPST TRIP P Rih with BHA #11 following MP Schedule. 02:45 02:51 0.10 6,975 6,985 PROD1 WHPST DLOG P Tie -in Log W/ GR @ 2.0 fpm from 6975 -6985. Had -25' correction. New depth (6960') Wt Ck =22k / RIH Wt =13k CTP =1840 @ 0.55 bpm / WHP =280 psi /Annular =3750 psi. 02:51 03:00 0.16 6,985 7,200 PROD1 WHPST TRIP P Continue to Whipstock depth. CLosed EDC @ 7100'. Tagged TOWS @ 7200.78' PUH Wt= 26k. Biozan on location. 03:00 04:15 1.25 7,200 7,201 PROD1 WHPST MILL P Puh 10' feet. On line with pump @ 1.5 bpm / ctp =3800 / whp =20 psi / RIH= 10k.Annular =3785 psi / ECD =11.8 / Differential= 400 psi.On Line w/ Biozan @ 03:30 04:15 06:15 2.00 7,201 7,203 PROD1 WHPST MILL P Started Time Milling @ 7201' 06:15 09:15 3.00 7,203 7,205 PROD1 WHPST MILL P Stall @ 7202.6', P/U and reset - WOB 1.5K, CT weight 9.2K, 1.40 bpm, circ 3800 psi, WHP 100, ECD 12, BHP 3861. Continue time milling. Getting good metal shavings to surface. 09:15 11:00 1.75 7,205 7,215 PROD1 WHPST MILL P Looks like exit casing, controll mill @ 1 ft / hour with 1K WOB. 1.40 bpm, circ 3700 psi, WHP 100, BHP 3866, ECD 12.1, slight weight transfer. - 11:00 12:18 1.30 7,215 7,215 PROD1 WHPST MILL P Ream window and drift with pump down. Window drifted clean. Swap well to flo -pro mud 12:18 13:54 1.60 7,215 0 PROD1 WHPST TRIP P POOH 13:54 14:06 0.20 0 PROD1 WHPST SFTY P PJSM for undeploy 14:06 15:54 1.80 0 0 PROD1 WHPST PULD P Undeploy BHA # 11. Mill and string reamer guage 2.80 go, 2.79 no -go. 15:54 16:06 0.20 0 0 PROD1 WHPST SFTY P PJSM for deploy 16:06 17:30 1.40 0 0 PROD1 WHPST PULD P Done with Deploy.Crew change. 17:30 19:15 1.75 0 6,960 PROD1 WHPST TRIP P RIH With Bha #12.Following MP Schedule. 19:15 19:30 0.25 6,960 6,974 PROD1 WHPST DLOG P TIE -In With GR @ 2 fpm from 6960' -6974' .Had -26' correction new depth (6948.31).Close EDC.Rih Wt =12k / Up Wt =26k Page 13 of 33- • • Time'Logs Date - From To ` - Dur -- S Depth: E Depth Phase.: Code ' Subcode =.T -` Comment 19:30 19:45 0.25 6,974 7,212 PROD1 WHPST TRIP P Continue in hole with EDC close.RIH Wt =12K. 19:45 22:15 2.50 7,212 7,365 PROD1 WHPST DRLG P Start drilling the build. Free spin 3500 psi @ 1.4 bpm /WHP= 24psi / ECD =11.80 / PBIT =3798 psi / WOB =1.5 22:15 22:21 0.10 7,365 7,220 PROD1 WHPST WPRT P Drill build section down to 7265' feet. PUH for wiper trip to 7220' @ 20 fpm . Had sample taken every 50' from 7215'. Up wt =26k / ECD =11.83 / PBIT =3858 / ctp =3610 @ 1.4 bpm / whp =23 psi. 22:21 22:27 0.10 7,220 7,365 PROD1 WHPST TRIP P Rih following MP Schedule. Rlh Wt= 13k 22:27 23:59 1.54 7,365 7,458 PROD1 WHPST DRLG P Back on bottom Drilling. WOB 1.5 - 2.0 / ECD =11.87 / CTP =3870 @ 1.4 bpm / WHP =23 psi. 32/24/2010 Completed the Build / Turn Section.Drill 71' feet of Lateral Section. Total Losses for Last 24 hrs = 24 bbls. 00:00 01:15 1.25 7,458 7,515 PROD1 WHPST DRLG P Current Depth @ Midnight 7458'. WOB= 1.5 -2.5 / ECD =11.88 / P- BIT =3877 psi / CTP =3780 @ 1.40 bpm / WHP =23 / ROP =58 fph. 01:15 01:21 0.10 7,515 7,226 PROD1 WHPST WPRT P Drill down to 7515'.PUH for wiper. Up wt =27K. ECD= 11.85 / P -Bit= 3860 psi. 01:21 01:30 0.15 7,226 7,515 PROD1 DRILL TRIP P Rih Back down to 7515'. Rih Wt =13k 01:30 03:30 2.00 7,515 7,665 PROD1 DRILL DRLG P Back On Bottom Drilling. ECD =11.9 / WOB =1.5- 2.5 / ROP =48 fph / CTP =3800 psi / WHP =30 psi. 03:30 03:45 0.25 7,665 7,215 PROD1 DRILL WPRT P Drill down to 7665'. PUH for wiper @ 15fpm.Up Wt =28k / CTP =3435 @ 1.4 bpm / ECD =11.89 / P- Bit =3890 psi. 03:45 04:00 0.25 7,215 7,233 PROD1 DRILL DLOG P Perform Tie -In to RA Marker @ 2 fpm.RIH Wt =12K. Seen good tie -in. 04:00 04:06 0.11 7,233 7,665 PROD1 DRILL TRIP P Continue back in hole, following MP Schedule. 04:06 06:06 2.00 7,665 7,815 PROD1 DRILL DRLG P Back on bottom Drilling.CTP =3760 @1.4 bpm /WHP =30 psi/ ECD =11.98 / WOB= 1.2 -2.0 / P- Bit =3898 psi. 06:06 07:06 1.00 7,815 7,815 PROD1 DRILL WPRT P Wiper trip to window, 25K PUW 07:06 09:36 2.50 7,815 7,866 PROD1 DRILL DRLG P Continue drilling, 10K RIW, 1.40 BPM @ 3500 CTP, 3900 BHP, 36 WHP w /open choke, 09:36 12:06 2.50 7,866 0 PROD1 DRILL TRIP P POOH for BHA, 31K PUW off bottom, dropped back to 26K. Wipe down to TD and PU clean. Open EDC in TT and Continue POOH. Lots of cutting in returns, tag up, RIH to 400', and PUH to retag. 12:06 15:54 3.80 0 0 PROD1 DRILL PULD P Undeploy BHA # 13, deploy BHA # 14, RSM and Resistivity for drilling lateral. 15:54 17:18 1.40 0 6,965 PROD1 DRILL TRIP P RIH BHA #13 - Page 14 of 33 -- • • Time_Logs Date - From To bur S. Depth E. Depth Phase Code ' Subcode T = Comment 17:18 17:24 0.11 6,965 6,991 PROD1 DRILL DLOG P Log GR Tie -In. -26' Correction.( New Depth 6954') Close EDC. Wt Ck =24K / RIH Wt =10k. 17:24 17:30 0.10 6,991 7,225 PROD1 DRILL TRIP P RIH. Saw 500 lb Bobble @ Window. 17:30 17:39 0.15 7,225 7,240 PROD1 DRILL DLOG P LOG RA Marker @ 7206'.( TOWS= 7200)(BO W =7207) (RA Marker =7206) 17:39 18:58 1.33 7,240 7,867 PROD1 DRILL TRIP P Rlh, Tagging @ 7856' Lower rate & Worked down thru tight spot. 18:58 20:13 1.25 7,867 7,868 PROD1 DRILL DRLG P Drilling On Lateral.CTP =3700 @ 1.4 bpm / WHP =23 psi / WOB =2.5 to 3.2 / ECD =11.8 to 12.0 / P- Bit =3900 psi.ROP =2.5 fph 20:13 23:58 3.75 7,868 7,938 PROD1 DRILL DRLG P PUH to 7800' Up Wt= 37k.off bottom,wt level out to 26k.Seeing very little drag while puh with rib tool retracted.Rlh to bottom and continue drilling. Very slow ROP.RIH Wt =9k / ECD =11.99 / P- Bit =3894 / CTP =3720 @ 1.4 bpm / WHP =24 psi No problem @ 7856' this time.Dilling ahead a couple feet w /rib steer off.Started Rib Steer @ 7871'. WOB =3.0- 3.8 / ROP alot better, up to 16 now. 32/25/2010 Drilling Lateral. Catching Sample every 50' and Wiper Trips every 150'. 24 hr Losses= 11 bbls. 00:00 00:45 0.75 7,938 7,950 PROD1 DRILL DRLG P At Midnight.drilling Lateral @ 17fph / WOB =1.7 to 2.5 / P- Bit =3920 / CTP =3645 @ 1.4 bpm / WHP =23 psi 00:45 01:30 0.75 7,950 8,000 PROD1 DRILL DRLG P 50' Sample @ 7950'.ROP =28 / WOB =2.8 / ECD =12 / P -Bit= 3940 psi / CTP =3850 @ 1.4 bpm / WHP =22 psi. 01:30 01:45 0.25 8,000 8,015 PROD1 DRILL DRLG P 50' Sample @ 8000'.ROP =80 / WOB =2.0 / ECD =12.2 / P- Bit =3980 psi / CTP =4080 @ 1.4 bpm / WHP =23 psi. 8,015 7,875 PROD1 DRILL WPRT P Turn Rib Steer Off.PUH for Wiper trip.Up Wt= 27k. CTP =3650 @ 1.4 bpm / WHP =22 psi / ECD =12.1 / P- Bit =3930 psi. 01:45 01:51 0.10 7,875 7,215 PROD1 DRILL DLOG P Start MAD Pass at 4fpm from 7875' to 7211'.Up Wt =24k 01:51 04:45 2.90 7,215 8,015 PROD1 DRILL TRIP P Done With Wiper & Mad Pass. Lower Pump & RIH follow MP Schedule. Down Wt =11 k / ECD =11.94 04:45 06:00 1.25 8,015 8,060 PROD1 DRILL DRLG P Back On Bottom Drilling Ahead. 06:00 07:12 1.20 8,060 8,162 PROD1 DRILL DRLG P Continue drilling ahead, 1.4 BPM @ 3600 CTP, 3910 BHP, 30 WHP with open choke. 1.5K WOB for 90 ROP and 200 PSI motor work. - 2 Bbls. per hour losses. Page 15of33 fit • Time Logs Date From = To Dur S. Depth' E. Depth= Phase "Code Subcode T, Comment 07:12 08:12 1.00 8,162 8,162 PROD1 DRILL WPRT P Wiper trip to window. Started to stack weight. 27K PUW. Slight over pulls with some motor work at 7855' and 7800'. 14K RIW below window. 08:12 11:36 3.40 8,162 8,315 PROD1 DRILL DRLG P 9K RIW, continue drilling. Swap to new mud system. 1.4 BPM @ 3620 CTP, 3940 BHP, 30 WHP with open choke. 1.5K WOB for 90 ROP and 200 PSI motor work. 11:36 12:24 0.80 8,315 7,230 PROD1 DRILL WPRT P Wiper to window, 24K PUW 12:24 12:30 0.10 7,230 7,260 PROD1 DRILL DLOG P Tie in, 0 correction. 12:30 13:06 0.60 7,260 8,315 PROD1 DRILL WPRT P Wiper back inhole, 12K RIW 13:06 15:12 2.10 8,315 8,465 PROD1 DRILL DRLG P 9K RIW, continue drilling. 1.4 BPM @ 3550 CTP, 3920 BHP, 20 WHP with open choke. 1.5K WOB for 75 ROP and 200 PSI motor work. 15:12 16:24 1.20 8,465 8,465 PROD1 DRILL WPRT P Wiper trip to window, 25K PUW 16:24 20:00 3.60 8,465 8,615 PROD1 DRILL DRLG P 9K RIW, continue drilling. 1.4 BPM @ 3550 CTP, 3920 BHP, 20 WHP with open choke. 1.5K WOB for 50 ROP and 200 PSI motor work. 20:00 22:15 2.25 8,615 8,615 PROD1 DRILL WPRT P Turn RIG Steer Motor off. Wiper trip to window, 30k PU WT off bottom. 22:15 00:00 1.75 8,615 8,684 PROD1 DRILL DRLG P 10K RIW, Continue drilling on Lateral.CTP =3980 @ 1.4 BPM, 4020 BHP, WHP =22 w /open choke,1.5 -2.0 WOB, ROP =48. 02/26/2010 Drilled to 8989', Unable to get angle to drop w/ rib steer. Undeploy RSM & Deploy 1.0 deg motor w/ bicenter. Total 24 hr losses = 43bbls 00:00 01:00 1.00 8,684 8,761 PROD1 DRILL DRLG P Depth @ midnight= 8684', RIH Wt =6k, WOB= 1.5 -2.0, ECD =12.2, P= Bit =4032 psi / CTP =3900 @ 1.4 bpm / WHP =15, wide open choke. Next wipe= 8767' 01:00 02:15 1.25 8,761 7,100 PROD1 DRILL WPRT P PUH for Wiper.Up Wt= 26k.Slow Rate At Window & PUH to 7100' 02:15 02:30 0.25 7,100 7,100 PROD1 DRILL SVRG P Inspect Injector & Chains. 02:30 04:00 1.50 7,100 8,761 PROD1 DRILL WPRT P Injector look good. Rih Back to Bottom. RIH Wt =14k, seen small weight bobble at window.Tie -In @ 4fpm from 7225' to 7241'. + 1.5' correction.Continue in hole. 04:00 05:48 1.80 8,761 8,910 PROD1 DRILL DRLG P Back on bottom drilling ahead. CTP =3750 @ 1.4 bpm, WHP =14 psi wide open choke, WOB= 1.5 -1.8, ROP =35 -100 fph / BHP =3995 psi 05:48 08:48 3.00 8,910 8,910 PROD1 DRILL WPRT P Wiper to window, 25K PUW. While RIH had to work through area from 8540 to 8640. Dropped pump rate to get past, then backream at full pump rate, three times. - Page 16 of 33 • • Time Logs Date From =TO Due S. Depth= E. Depth Phase Code - Subcode T`_.= Comment 08:48 10:06 1.30 8,910 8,989 PROD1 DRILL DRLG P Back on bottom drilling ahead. CTP =3750 @ 1.4 bpm, WHP =14 psi wide open choke, WOB= 1.5 -1.8, ROP =35 -90 fph / BHP =3995 psi. Attempting to drop angle, trying various parameters to do so. Not working... 10:06 13:54 3.80 8,989 0 PROD1 DRILL TRIP T POOH for conventional BHA. Trip to window looked good. Lots of shale to shaker. In /Out jog at surface to 300' 13:54 15:00 1.10 0 0 PROD1 DRILL PULD T Undeploy BHA #13 15:00 16:12 1.20 0 72 PROD1 DRILL PULD T Deploy BHA # 14, 1 Deg. motor and rebuilt Razor bit 16:12 19:15 3.05 72 8,989 PROD1 DRILL TRIP T RIH W /BHA #14.Log GR- tie -in from 6970' -6959' @ 4fpm -26' Correction.Wt Ck =26k / Close EDC.Continue thru window with pump off.Set down @ 7862' -7865 able to work passed.Continue down last drilled depth. 19:15 23:15 4.00 8,989 9,140 PROD1 DRILL DRLG P Back on bottom drilling. CTP =3645 @ 1.35 bpm / WHP =12 w/ wide ope choke, WOB =2.25 / ECD =12.2 / ROP =47 fph / BHP =3980 psi. 23:15 00:00 0.75 9,140 7,231 PROD1 DRILL WPRT P Wiper Trip to Window. Up Wt= 29k.Seen Overpulls @ 8680', 8602' & 8560' 02/27/2010 Drilled to 9140'. After wiper trip, was unable to get passed tight area at 7864', ended up side tracking from 7861'. Develop new well plan & drill ahead.Total losses last 24 hrs =30 bbls 00:00 01:45 1.75 7,231 7,864 . PROD1 DRILL WPRT P Seen another overpull @ 7884' during wiper trip.Up Wt =21 k. Rih Wt below window =l lk.Had trouble getting passes 7856' -7864' 01:45 03:45 2.00 7,864 7,864 PROD1 DRILL WPRT T Made several attempts to worked passed 7860' to 7864'. Make short trip back to Window.Up Wt= 23k.Call town engineer about plan forward. 03:45 05:45 2.00 7,864 7,864 PROD1 DRILL WPRT T Plan forward is to pump a High -low vis sweep with clay -guard 05:45 07:00 1.25 7,864 7,280 PROD1 DRILL TRIP T Unable to work passed tight area after pumping pill. (9.5 ppg SFFP w/ 14ppg Kla -gard & 4.6% LO -TORQ) PU Circulating. 07:00 09:00 2.00 7,280 7,855 PROD1 DRILL WPRT T Plugging off above BHA, drop pump rate and RIH. Pump to /hi vis sweeps from 7855' to window. Numerous stacking and over pulls throughout the build area. 09 :00 12:00 3.00 7,855 7,851 PROD1 DRILL WPRT T After pumping two sets of to -hi vis sweeps followed by a mud swap attempted to get past 7861' at -90 to +90 TF and with pump at 0 - .5 BPM. PUH and discuss options Page 17 of 33 �� ���� 12:00 15:00 3.00 7,851 7.858 PROD1 DRILL REAM T Attempt toreamdown. Tagging and stalling at786Oat1.5BPM,380O CTP, 3875 BHP, 23 PUW 5-6K RIW, ream down austo1FPM. Appears to have sidetracked at about 7DOO' 15:00 16:45 1.75 7,858 7,875 PROD1 DRILL WPRT T PUHto7840' and R|Hto7875'clean. PUH calculate TF to follow old hole. 16:45 20:00 3.25 7,875 8.000 PROD1 DRILL DRLG P Back nn bottom d,i||ing.CTP~3O5O@ 1.43bpm.VVOB~2.8'3.0.BHP~3860 psi, WHP=18 psi, ECD=11.91, ROP= 40-60 fph 20:00 20:15 0.25 8.000 8.010 PROD1 DRILL DRLG P Start Low-High Vis Sweep. CTP~3855.@15bpmVVOB=2.7. ECD=11 9s.ROP~oO'3U.BHP~3D95 psi, VVHP=21 psi. Continue 0odrill ahead. 20:15 21:00 075 8.010 7,225 PROD1 DRILL WPRT P Sweep @oit.PUM for Wiper ot1O fpm to let sweep come around.Up Wt=25k. 21:00 21:30 0.50 7.225 8.010 PROD1 DRILL WPRT P Sweep @ surface. Seeing sample of clay, no shale.Tie-In (+3.5 correction ) Continue back in hole follow K8Pochedu|e.R|M1Nt=1Uk. Seen Wt Bobble #78UO' coming up &"oinqdown. 21:80 23:30 2.00 8.010 8.100 PROD1 DRILL DRLG P Back on bottom drifling. Seen no problems getting back down to last depth. CTP~370O@1.45bpm/ VVMP=50.VVDo~17'2.3. BHP=3950, ECD=12.1, ROP=30-50 fph. 23:50 00:00 0.50 8.100 8.112 PROD1 DRILL DRLG P Start anothe Low-high Vis Sweep. CTP=39aO psi @D1.abpm.VVHP=3O psi, VvOB~2.5-3.0. ROP=35'45 fph. ECD=12.1, BHP=3940 psi. 32/28/2010 TD open hole sidetrack @ 8460'. Tagged @ 7346' after wiper trip, POOH for BHA. .Able to work back down to TD&Baohroam&C|aanpmb|omaneoTota| mud losses in last 24 hrs. 11bb|a. 00:00 02:00 2D0 8,112 8.160 PROD1 DRILL DRLG P Current depth @ Midnight 8112'. VYOB~2.5'3.0. ROP=45-80 fph. ECD=11 9.CTP=32OO@1.5bpm. WHP=38 psi, BHP=3890 psi. See Larger Pieces of shale now (est: 8130') & alot of it. 02:00 02:45 0.75 8.160 7,229 PROD1 DRILL WPRT P Shale has taper off atshakerStart onotho low-high visowaap.up wt=24k, CTP=3680 @ 1.5 bpm.BMP=3892 psisCD=12.1.PUM for Wiper.Seen Overpull @ 7834'.7403' 02:45 0315 0.50 7,229 8.160 PROD1 DRILL WPRT P Rih Back to last drill depth.R|M VVt=12k.Set down @741T.Seen small wt bobble @78s8. 03:15 05:45 2.50 8.180 8.310 PROD1 DRILL DRLG P Back on bottom drilling.CTP3935 @ 1.sbpm.VVHP=48 psi, VVOB~2.5. ROP=35'50 fph.ECD=12.1. BHP=3990 psi. ����� ' `�� � � �� ` ������ ` ��,r Page 18ov33 • • �� » hate , Fn���To���;Ur' PhoSo::: Subcode _T COmMmn��''�� ��/'������' 05:45 08:30 2.75 8,310 8.310 PROD1 DRILL WPRT P Pump lo-hi visuwaapeandwiperthp. Up Wt=25k, Clean wiper to window and back to bottom. 08:30 11:42 320 8.310 8.460 PROD1 DRILL DRLG P Dh|ing ahead, 11KR|VK1.5BPM. 89OOCTP.39O5 BHP, 5OVVMP. 1.5-2.5KVVOB.2OD4UO psi motor work and 40-70 ROP. Pump as lo-hi sweep at 8385' 11:42 12:56 0.80 8.400 7.225 PROD1 DRILL WPRT P Pump lo-hi sweep and wiperto window. 25K PUW 12:36 12:48 020 7,225 7.346 PROD1 DRILL DLOG P Tie in, +2' correction 12:48 14:48 2.00 7,346 7.200 PROD1 DRILL WPRT T VWperin hole, 15KR|VVotwindow. Tagged at 7346' Attempt to get by with zero pump rate up to 1.3 BPM. Foe , slow and really slow RIH speeds. Appears to be at the bit, motor work and WOB. Circulate lo-hi vis sweep. 14:48 16:18 1.50 7.200 0 PROD1 DRILL TRIP T POOH 16:18 18:00 170 0 0 PROD1 DRILL PULD T Undeploy drilling BHA 18:00 19:45 1.75 0 62 PROD1 DRILL PULD T Crew Change, Deploy BHA #15. 19:45 21:15 1o0 62 8.960 PROD1 DRILL TRIP T Rih 21:15 21:30 025 6,960 6.877 PROD1 DRILL DLOG T Start Tie-In Log @ 2 fpm from 6960' tnO37T.'27'oorrecuinn.(ne*depth U848.g8') Rih mVt=12k. 21:30 22:15 0.75 6.977 8.480 PROD1 DRILL TRIP T Off Line w/pump. Close EDC. Continue in hole.Seen WT bobble @ 7546' and stack out 0y7354' Pick-up, Pull heavy to 34k wt fell off, able to rih no problem after that. 22:15 23:00 075 8.460 7.300 PROD1 DRILL REAM P Able to work down to TD. PU8Wait on town for next step?UP Wt=24k. Puhto73U5' and back eemm73OU' @ 60 deg rt sides of tools face,to ream problem area. 23:00 23:15 0.25 7.300 7,385 PROD1 DRILL REAM P Rih Back in hole. To Ream backup @ 60 deg Ieft side of tool face.RIH wt= 10h/Upwu=24k.NoProblem RIH. 23:15 00:00 0.75 7.385 8.460 PROD1 DRILL TRIP P RIH to TD.Done with both back reaming runs. Seen smaU bobble @ 7345'&7350'a|H~t=11k 03/01/2010 Bockmam problem area in lateral. Run 230'' Liner, TDL=7232''BOL=D4o9'PU&R|H and set OH Billet w/ OH Anchor @0( Top= 72Us') (Bottom of Anchor 7275') with Spacer Pup to72So.58' 24 hr losses to formation = 17 bbls. 00:00 01:15 1.25 8.460 8.460 PROD1 DRILL WPRT P RIH for Iow-high vis sweep follow by wiper trip. 01:15 01:80 0.25 8.460 7.860 PROD1 DRILL WPRT P Low-High Vis sweep is headed up hole. Start PUH to window for Wiper Trip. UpWt~24k.CTP=5D9O@1.5 bpm.BMP=39OO psi /VVMP~13 psiECD~11.90. .`� -(. � ��� �� �� ����� `! ��.� / �� � ' Page 1mof3y �N�^ �� �� g er==-:o-, = ��������t��������Q����� - F`�����nu���' FZDepth|P6ase Code Subdo6e - ����6R����������������`'�'���� 01:30 02:00 0.50 7.860 7,230 PROD1 DRILL WPRT P Pill Sweep @ Shaker. Up1Nt=24h/ CTP~4000 @ 1.5 bpm , WHP=58 / ECD=12.10 / BHP= 3980 psi. Seen N* Bobble @7S10'&7831' Returns looked good @ pits. 02:00 02:30 0.50 7.230 8.460 PROD1 DRILL WPRT P At Window. RIH Again to drift thru lateral aection.R|MVVt=11k/ BHP=3890 psi. Se down @ 7864'. PU Hole and slow speed down to 15 fpm from 30 fpm and had no problem.Made another pass thru area again, still no problem. 02:30 04:30 2.00 8.460 7,190 PROD1 DRILL DISP P Circulate 12 bbls Liner Pill, 2 bbls spacer, follow by KWF. Start PUH laying pill. UpVVt=25k.POOM 04:30 05:30 1.00 7.190 0 PROD1 DRILL TRIP P AboveVWndmw.PDOM 05:30 06:00 0.50 0 0 PROD1 DRILL SFTY P At Surface. Watch for flow-no flow.PJSM / Crew Change. 06:00 07:00 1.00 0 0 PROD1 DRILL 'PULD P Lay down drilling BHA 07:00 08:00 1.00 0 0 COMPZ CASING PUTB P RU for running liner 08:00 08:12 0.20 0 0 COW1PZ CASING 8FTY P PJSM for liner running ops 0812 10:18 2.10 0 1,139 COK4PZ CASING PUTB P PU shoe, 36 joints slotted liner and deployment sleeve. 10:18 10:48 0.50 1,139 1.184 COMPZ CASING PUTB P MUBOT and |nteqtools 10:48 12:48 2.00 1,184 7,084 {OMPZ{ASINGRUNL P RIH at 60 FPM, .3BPM 12:48 13:36 0.80 7,084 8,429 COMPZ CASING RUNL P Stop at flag and correct depth, -2T. Close EDC. Weight check, 27K PUW, 15K RIW. Continue RIH Satcked weight at 7345 and 7355', 7580', 7860', made it through without having to pick up. 13:36 15:06 1.50 8.429 0 COMPZ CASING RUNL P Online with pump at 1.4 8PM. PU at 24K. Log RA, +3'. Deployment sleeve is at 7293' POOH 15:06 16:00 0.90 0 0 COMPZ CASING PULD P Lay down liner running BHA and PU anchored biliet BHA 16:00 17:15 1.25 0 0 PROD2 STK PULD P PU Anchored billetwith guide shoe and two pup joints 17:15 19:15 2.00 30 6.990 PROD2 STK TRIP P R|M Anchored billet v/ guide shoe. 19:15 18:30 0.25 6.390 7.001 PROD2 STK DLOG P Tie-in Log @2 fpm from US8O''7U01' '20' correction. ( New Depth OS75') Down On Pump. Close EDC.RIH 19:30 20:00 0.50 7.001 7.292 PROD2 STK WPST P On Depth to set OH Biliet with OH Anchor. Set TOP=72Os'/ Bottom of Anchor=7275'/ Bit Depth @setting Depth=7292'.PUH Above TOC and swap well over to FP. Up Wt=25k. 20:00 22:15 2.25 7,292 7.120 PROD2 STK CIRC P Pump 10bb|aVlo Sweep. Follow 5 bbl Seawater spacer, the FIo-Pro. 22:15 23:30 1.25 7.120 0 PROD2 STK TRIP P Done Circulating KWF to surface. POOH, following MP Schedule. Up Wt=22k .°�--_ `-` ���3 -Time Logs .. Date From ,To = Dur- S. Depth E. Depth Phase Code Subcode T Comment 03/01/2010 24 hr Summary Backream problem area in lateral. Run 2 3/8" Liner, TOL =7292' - BOL= 8429'. PU & RIH and set OH Billet w/ OH Anchor @ ( Top= 7265') (Bottom of Anchor 7275' ) with Spacer Pup to 7292.58'. 24 hr losses to formation = 17 bbls. 23:30 00:00 0.50 0 0 PROD2 STK PULD P OOH.HoId PJSM. Start Un- Deployment Operation. 03/02/2010 Undeploy BHA #17, Start BOP testing, Repair Injector Head 00:00 01:30 1.50 0 0 PROD2 STK PULD P Un- Deploy BHA #17 01:30 03:00 1.50 0 0 PROD2 WHDBO SLPC P Cut Off CT Connector.Start Slack mgmt. Flush Surface piping. Start reverse circulating. 03:00 03:45 0.75 0 0 PROD2 WHDBO SVRG P Grease Crew On Location to service Tree valve & Stack. 03:45 08:00 4.25 0 0 PROD2 WHDBO BOPE P Started BOP test. * *4 HOURS OF BOP TEST TIME USED ** 08:00 20:00 12.00 0 0 PROD2 WHDBO RGRP T Stopped testing BOP to get started on the injector repairs. Nabors has 12 hours of billable repair time left for the month of March. * *ALL 12 hours of BILLABLE REPAIR TIME USED ** 20:00 00:00 4.00 0 0 PROD2 WHDBO RGRP T Continue repairing Injector Head ** * *4 hours Nabors Non Billable Repair time *** 03/03/2010 Complete Repair of injector head, Complete BOP testing, Cut 250' of CT for pipe management, pump slackmanagement, Rebuild B4 HCR valve on stack. Sidetrack for L2 -01 00:00 02:00 2.00 0 0 PROD2 WHDBO RGRP T Continue Repairing Injector Head. ** 2 HOURS OF NABORS NON - BILLABLE REPAIR TIME ** 02:00 07:00 5.00 0 0 PROD2 WHDBO BOPE P Continue BOP testing. Continue working on getting the injector prepared to stab CT. * *NABORS ON BOP TEST TIME ** 9.25 hours for BOP testing 07:00 10:30 3.50 0 0 PROD2 DRILL SLPC P BOP Test complete. Clean rig floor and move injector over floor to cut 250' of CT. 10:30 13:48 3.30 0 0 PROD2 DRILL SLPC P Make up lubricator sections and coil connector. Pull test to 25K. Rehead E -Line, PT to 4200 PSI. Stab onto well and circulate water out of coil. 13:48 14:00 0.20 0 0 PROD2 STK SFTY P PJSM for pressure deploy 14:00 16:00 2.00 0 0 PROD2 STK PULD P Deploy BHA # 18 16:00 20:00 4.00 0 0 PROD2 STK RGRP T Hydraulic leak on HCR, Valve B4 * * *NABORS ON NON - BILLABLE REPAIR TIME *** Page 21 of 33 Time Logs • From To= = `" Dur S. Depth E. Depth` Phase`- Code Subcode Date ode T -° Comment -_ = -- 20:00 20:30 0.50 0 0 PROD2 STK RGRP T Pressure test valve, 250/3500. Charted. 20:30 21:00 0.50 0 0 PROD2 STK PULD T Deploy BHA # 19, - 5 HOURS NABORS NON - BILLABLE REPAIR TIME** 21:00 21:15 0.25 0 0 PROD2 STK PULD P Continue Deploying BHA # 19 21:15 23:15 2.00 0 6,921 PROD2 STK TRIP P RIH, checking goosneck alignment at 500' and every 1000' after. Gooseneck alignement looks good 23:15 23:24 0.15 6,921 6,941 PROD2 STK DLOG P Tie in depth -21' correction 23:24 23:39 0.25 6,941 7,265 PROD2 STK TRIP P RIH to side track, tag billet at 7265.07, PUH online with pumps 1.4 BPM, orient TF to 30 left. RIH 23:39 00:00 0.35 7,265 7,265 PROD2 STK KOST P RIH until seeing slight motor work, Set auto driller to 1' /hour X3/04/2010 Sidetrack L2 -01off OH anchored billet from 7265- 7267'. Drill Build section from 7267' to 7745' drilling into shale. Attempt OHST at 7540' with drilling BHA. Decission to POOH for OH anchored billet. 00:00 00:51 0.85 7,265 7,266 PROD2 STK KOST P Continue drilling 1' /hour 00:51 01:24 0.55 7,266 7,267 PROD2 STK KOST P Increase ROP to 2' /hour for 1' 01:24 01:42 0.30 7,267 7,268 PROD2 STK KOST P Increase ROP to 3' /hour for 1' 01:42 02:12 0.50 7,268 7,273 PROD2 STK KOST P Increase ROP to 10' /hour for 5' 02:12 02:27 0.25 7,273 7,277 PROD2 STK KOST P Increase ROP to 20' /hour for 4' 02:27 02:33 0.10 7,277 7,277 PROD2 STK KOST P Pick up drifting sidetrack without pumps. Looks good. RIH to drill ahead 02:33 05:00 2.45 7,277 7,400 PROD2 DRILL DRLG P Drill Ahead 40 -80 FPH, 1.34 BPM in, 1.24 BPM out, 5K CTW, 1 -2K DHWOB, 11.9 ECD, 3878 BHP. 05:00 05:18 0.30 7,415 7,415 PROD2 DRILL WPRT P Wiper to window 05:18 07:00 1.70 7,415 7,565 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3400 CTP, 3900 BHP, 0 WHP, 7500 RIW, 1.5 -2.5K WOB and 200 -300 psi motor work. ROP increasing to 100 FPH 07:00 07:30 0.50 7,565 7,565 PROD2 DRILL WPRT P Wiper to window. Adjusting gooseneck rollers. 07:30 11:18 3.80 7,565 7,725 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3450 CTP, 3940 BHP, 0 WHP, 13K RIW, 1.5 -3K WOB and 200 -300 psi motor work. 11:18 12:30 1.20 7,725 6,900 PROD2 DRILL WPRT P Wiper to below billet and back to bottom. Slight weight stacking and over pulls at 7705'. Clean the rest of the way. Pull up through widow and open EDC. discussed with town and decided to drill ahead another 20 feet to get through what appears to be the uppper A4 12:30 12:42 0.20 6,900 6,950 PROD2 DRILL DLOG P Tie in to formation , +3' 12:42 13:30 0.80 6,950 7,725 PROD2 DRILL WPRT P Wiper to TD, Close EDC. - Page 22 of 33 • Time Logs Date From To - - Dur S. Depth E: Depth = Phase _Code Subcode T == Comment _ 13:30 14:12 0.70 7,725 7,745 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3450 CTP, 3940 BHP, 0 WHP, 13K RIW, 1.5 -3K WOB and 200 -300 psi motor work. 14:12 16:12 2.00 7,745 7,100 PROD2 DRILL WPRT P Over pull at 7725'. Ream hole from 7745 up to 7700 three times, fourth pass looks clean, continue wiper to window 16:12 16:27 0.25 7,100 5,800 PROD2 DRILL TRIP X Close EDC and POOH 16:27 16:48 0.35 5,800 7,500 PROD2 STK KOST X Decision to OHST with drilling assembly, RIH to OHST with current BHA 16:48 18:33 1.75 7,500 7,540 PROD2 STK KOST X Back ream trench, Begin OHST 18:33 20:33 2.00 7,540 0 PROD2 STK TRIP X Decision to POOH to PU Billet w /OH Anchor to sidetrack to achieve lower DLS in build. POOH 20:33 23:33 3.00 0 0 PROD2 STK PULD X At surface, Undeploy BHA 19, Deploy BHA 20 -OH anchor with Billet 23:33 00:00 0.45 73 3,000 PROD2 STK TRIP X RIH, with EDC open, pumping .5 BPM 33/05/2010 Set OH anchored billet on depth 7551' bit depth, 7540' TOB. ST L2 -01 off billet, drilling build to 7875'. POOH for AKO change. Drill L2 -01 Lateral 00:00 01:00 1.00 3,000 6,966 PROD2 STK TRIP X Continue RIH with OH anchored billet 01:00 01:15 0.25 6,966 6,961 PROD2 STK DLOG X Tie in depth with gamma -23', RIH to TOC, Closed EDC. Record up and down weights, 12K down, 25K up. 01:15 01:30 0.25 6,961 7,100 PROD2 STK TRIP X RIH to setting depth 01:30 01:39 0.15 7,200 7,551 PROD2 STK WPST X On depth with OH billet. Online with pumps 4600psi OH anchor set. 7K DHWOB 01:39 03:09 1.50 7,551 0 PROD2 STK TRIP X POOH 03:09 03:24 0.25 0 0 PROD2 STK SFTY X PJSM on undeployment 03:24 05:54 2.50 0 0 PROD2 STK PULD X Undeploy BHA 20, Deploy BHA 21, 2 deg AKO, HCC Bi- Center 05:54 06:54 1.00 0 6,900 PROD2 STK TRIP X RIH 06:54 07:06 0.20 6,900 7,000 PROD2 STK DLOG X Tie in 07:06 07:24 0.30 7,000 7,540 PROD2 STK TRIP X RIH to tag billet 07:24 10:18 2.90 7,540 7,553 PROD2 STK KOST X Tag billet at 7540.6, PUH and start time milling at 7539.2, 1.5 BPM, 3600 CTP, 3900 BHP, 0 WHP. 25K PUW, 15K RIW 1 FPH for 1 Foot 2 FPH for 1 Foot 3 FPH for 1 Foot 10 FPH for 5' 20 FPH for 5' 10:18 10:30 0.20 7,553 7,553 PROD2 STK KOST X PU past billet at .3 BPM, drift with pump down, clean 10:30 12:42 2.20 7,553 7,745 PROD2 DRILL DRLG X Drilling Build., 1.5 BPM, 3600 CTP, 3950 BHP, 25K PUW, 13K RIW. 1- 2K WOB, 200 -300 psi motor work. Page 23 of 33 • • Time Logs Date From To Dur S Depth `E. Depth Phase Code Subcode = T " Comment 12:42 13:24 0.70 7,745 7,745 PROD2 DRILL WPRT X Wiper trip to window. 25K PUW. Pumped 10 Bbls. low vis, 10 Bbls. high vis followed by new mud. 13:24 15:00 1.60 7,745 7,875 PROD2 DRILL DRLG P Drilling Build., 1.5 BPM, 3550 CTP, 3860 BHP, 12K RIW. 2 -3K WOB, 200 -300 psi motor work. 15:00 17:30 2.50 7,875 0 PROD2 DRILL TRIP P Pump lo/hi vis sweeps and POOH 17:30 18:00 0.50 0 0 PROD2 DRILL SFTY P Crew change, PJSM undeploy /deploy 18:00 21:30 3.50 0 0 PROD2 DRILL PULD P Undeploy BHA 21, deploy BHA 22 Replace pop off valve on locking portion of 2 3/8" deployment rams. 21:30 23:00 1.50 72 6,960 PROD2 DRILL TRIP P RIH 23:00 23:15 0.25 6,960 6,963 PROD2 DRILL DLOG P Tie in depth -28' correction, offline with pumps, shut in psi, close EDC 23:15 23:45 0.50 6,963 7,875 PROD2 DRILL TRIP P RIH to TD to drill 23:45 00:00 0.25 7,875 7,885 PROD2 DRILL DRLG P Drill Ahead, 3550 off bottom CTP, 1.5 BPM 6K CTW, 3900 on bottom CTP, 4K CTW, 1 -2K WOB, 60 -100 FPH, 3860 BHP, 11.9 ECD, 21 WHP 33/06/2010 Drill L2 -01 Lateral 7875' to 8665'. Stuck pipe 4 hrs. Pump Mineral Oil to get free. 00:00 01:30 1.50 7,885 8,030 PROD2 DRILL DRLG P Drill Ahead, 3550 off bottom CTP, 1.5 BPM 6K CTW, 3900 on bottom CTP, 4K CTW, 1 -2K WOB, 60 -100 FPH, 3860 BHP, 11.9 ECD, 21 WHP 01:30 01:42 0.20 8,030 7,875 PROD2 DRILL WPRT P Wiper trip back to window, 22K PUW 01:42 02:42 1.00 7,910 7,290 PROD2 DRILL DLOG P MAD pass 7910' to 7290' at 10' /minute 02:42 02:54 0.20 7,290 -7,230 PROD2 DRILL WPRT P Continue wiper trip back to window 02:54 03:30 0.60 7,200 8,030 PROD2 DRILL WPRT P RIH to Drill, Unable to get through window, hanging up at bottom of window. PUH orient 15 left, 10 rt at 15' /min tag up. Orient HS RIH 20' /min, pop through window. Hang up at billet #1 oriented 30 left 15' /min. PUH, check BHA assuring TF is correct with CoilTrack. RIH 20' /min 30 left TF. pop through. RIH, no problem with billet #2. 03:30 05:30 2.00 8,030 8,180 PROD2 DRILL DRLG P Drill Ahead 1.5 BPM in, 1.43 BPM out, 80 -100 FPH, 1.5K WOB, 4 -5K CTW, 3980 CTP, 3879 BHP, 11.9 ECD, 21 WHP 05:30 06:30 1.00 8,180 8,180 PROD2 DRILL WPRT P Wiper to window, 23K PUW. 06:30 07:30 1.00 8,180 8,330 PROD2 DRILL DRLG P Continue Drilling Ahead. 11K RIW, 1.5 BPM, 3450 CTP, 3920 BHP, 0 WHP. 1 -3K WOB, 200 -400 psi motor work, 120 -150 ROP 07:30 08:12 0.70 8,330 7,225 PROD2 DRILL WPRT P Wiper to window 08:12 08:18 0.10 7,225 7,250 PROD2 DRILL DLOG P Tie in to RA, +2.5' correction Page24of33 4� 1 � � _ ������������������������« Date Tb'����Dur S: Depth E. nepthPhase Code' ,!Gvbonde 'T- 'Comment '^ 08:18 09:00 0.70 7.250 8,330 PROD2 DRILL WPRT P VWFer to bottom, 13K RIW, Clean 09:00 10:24 1.40 8.830 8.480 PROD2 DRILL DRLG P Continue DriIIing Ahead. 11KRIW, 1.4 BPM, 3375 CTP, 3920 BHP, 0 VVMP. 1-3KVVOB.2OO4O0psi motor work, 12O'15OROP - 10:24 12:00 1.60 8.480 8.480 PROD2 DRILL WPRT P mxpe,m window, 23KPUNL Clean trip out and in. 12:00 13:24 1.40 8.480 8.630 PROD2 DRILL DRLG P Continue Drilting Ahead. 9K RIW, 1.4 BPM, 3500 CTP 3927 BHP, 0 VVMP. 1'3KVVOB.2DO-48Opsi motor work, 8O'15UROP 13:24 15:06 170 8.630 8,630 PROD2 DRILL WPRT P vVipe, trip m the window, 23KPUVV 15:06 15:24 0.30 8.880 8.656 PROD2 DRILL DRLG P Continue Drilling Ahead. 6K RIW, 1.33 BPM, 3460 CTP, 3950 BHP, 0 WHP. 1-3K WOB, 200-400 psi motor work, 80'150 ROP 15:24 15:54 0.50 8.656 8.640 PROD2 DRILL DRLG T Pulled up3oK(1OK over pull) after a staU, continued PUHoo855O'and started lo/hi vis sweeps down coil. Ran back in hole and stacked out at 8640', no motor work or WOB indicated. Pulled up to 27K, then set back down to -1 OK with no movement. Worked pipe with no movement. -1Ok ot8646' . 55K at 8635' No motor work or WOB changes Circulation pressures and BHP norami and full returns 15:54 17:00 1.10 8.840 8.640 PROD2 DRILL DRLG T Circulated sweeps around BHA and back to surface while working pipe with no movement. Shut in well and park coil at neutral weight, relax for 20 min. 17:00 18:30 1.50 8.640 8.640 PROD2 DRILL DRLG T Attempt topull, no luck. Wait on mineral oil. 18:30 18:45 0.25 8.640 8.843 PROD2 DRILL DRLG T RIH to 0 CTW offline with pumps, shut in choke holding 3850 BHP 470 WHP, 880 CTP, BHP bleed down to 3s50. Try to pull free 5ak.nnluck. Online with pumps, maintain 3900 BHP. Loading Mineral oil into pits. RIH to neutral weight 18:45 19:45 1.00 8.643 8.643 PROD2 DRILL DRLG T Start pumping mineral oil DH. 5 bbrl high vis spacer, 14 bbrls mineral oil, 5 bbrl high vis spacer down CT pumping 5 bbrls mineral oil out CT and Iet soak. CTm/1K. OVVOB. 1.8 8PM in. 1.24 BPM out, 3436 CTP, 3960 BHP, 12.2 ECD 19:45 20:00 025 8,643 8.843 PROD2 DRILL DRLG T 5 bbrls mineral oil out CT. RIH Page 25 of 33 • Time Logs Date = From To Dur S. Depth epth -E. Depth -_ Phase LI Code' -= = Subcode T- Comment 20:00 21:15 1.25 8,643 7,246 PROD2 DRILL WPRT P Try to RIH to -8K CTW, Seemed to pop free. PUH 60K POP FREE. Continue to pick up hole recovering Mineral Oil. When popped free, BHP 3490, no pump rate, 11.2 ECD, 60K CTW, 224 WHP 21:15 21:51 0.60 7,246 7,890 PROD2 DRILL WPRT P Tie into RA marker +7 correction, RIH to TD 21:51 22:06 0.25 7,890 7,950 PROD2 DRILL WPRT P Tag 7890', top of A4 silty formation. PUH 35K. Pop free. RIH, get through bottom of silty A4. PUH backream 10' /min 22:06 22:42 0.60 7,950 8,658 PROD2 DRILL WPRT P RIH to TD, conditioning hole, pump 5 bbrl sweep to have at bit when reach TD Tag 8040' PUH to 7880' backreaming, RIH 22:42 23:42 1.00 8,658 8,652 PROD2 DRILL WPRT P Tag TD, PUH to 7880' chasing High Vis sweep, conditioning hole through silty A4 sections. 23:42 23:57 0.25 8,653 8,653 PROD2 DRILL WPRT P Set down weight, no motor work, nothing on WOB, PUH BHA wiper. 22K CTW 23:57 00:00 0.05 8,653 8,665 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM in, 1.3 BPM out, 3800 CTP, 1.5 -2K WOB, 40 -60 FPH, 0-1K CTW, 4000 BHP, 12.4 ECD. Formation drilling ratty /grabby, motor wants to stall, lots of reactive torq seen on TF 03/07/2010 Drill L2 -01 Lateral 8665' to 9350' TD. Condition hole lay in liner pill and killing well POOH. 00:00 00:15 0.25 8,665 8,675 PROD2 DRILL DRLG P Drill Ahead 1.4 BPM in, 1.3 BPM out, 3800 CTP, 1.5 -2K WOB, 40 -60 FPH, 0-1K CTW, 4000 BHP, 12.4 ECD. Formation drilling ratty /grabby, motor wants to stall, lots of reactive torq seen on TF New mud at the bit. 00:15 01:30 1.25 8,675 8,775 PROD2 DRILL DRLG P Drilling Ahead 90 -100 FPH 1 -1.5K WOB, 1.4 BPM in, 1.3 BPM out, Good drilling, possibly drilled through fault #3, causing pressure drop, causing the differentially stuck pipe. 01:30 01:42 0.20 8,775 8,775 PROD2 DRILL WPRT P Stall, PUH 25K Orienter not taking commands. Cycle power, All good. RIH 01:42 02:27 0.75 8,775 8,830 PROD2 DRILL DRLG P Drill Ahead 30-40 FPH, 2 -3K WOB, 3880 BHP, 11.9 ECD, 1.46 BPM in, 1.42 BPM out, 3650 CTP, -2K CTW 02:27 03:27 1.00 8,830 8,830 PROD2 DRILL WPRT P Wiper Trip to window 22K PUW 03:27 03:42 0.25 8,830 7,247 PROD2 DRILL DLOG P Tie in with RA marker due to BHI screen freezing up. -15' corretion 03:42 04:42 1.00 7,247 8,804 PROD2 DRILL WPRT P RIH to TD Page 26 of 33 �NN� ���0 ���� �w� ~� ` ��������@��������� Date From To rmr���Depth E. Depth Phase Code Suboode - T�- Comment- ��'�}�/����'��`1��'f _ _ = 04:42 07:18 2.60 8.804 8.980 PROD2 DRILL DRLG P Drill Ahead 0U-9OFPM.1'1.5KVVOB. 3960 BHP, 12.2 ECD, 1.5 BPM in, 1.*BPNout38bOCTP.2KCT\m 07:18 09:18 2.00 8.960 8.960 PROD2 DRILL WPRT - � Wiper trip to window, 28KPUVK clean trip up to window and back in. 08:18 11:12 1.90 8.860 8.110 PROD2 DRILL DRLG P Drill Ahead, 38aO off bottom CTP.1.4 BPM 3K CTW, 4000 BHP with 140 VVHP.1-2KVVOB.2OD4O0 psi motor work 11:12 12:24 120 9.110 6,225 PROD2 DRILL WPRT P VWper»owindow. 26K PUW 12:24 12:36 0.20 6.225 6.250 PROD2 DRILL DLOG P Tie in, +3' 12:36 13:30 0.90 6,250 9.110 - 11O PROD2 DRILL WPRT P VViporbockin hole. Clean trip. 13:30 14:24 0.90 9.110 9.188 PROD2 - DRILL DRLG P Drill Ahead, 3600 off bottom CTP, 1.4 BPM2KCT\N4U4V BHP with 145 VVHP, 1-2K WOB, 200-400 psi motor work 14:24 15:12 0.80 3.188 9.188 PROD2 DRILL WPRT P GanYWper 15:12 16:42 1.50 9.188 9.260 PROD2 DRILL DRLG P Drill Ahead, 3650 off bottom CTP, 1.5 BPK81KCllm 4000 BHP with 40 VVHP.1'2KVVOg.2UO-4O0 psi motor work 16:42 19:00 2.30 9.260 9.200 PROD2 DRILL WPRT P Wiper to window, 13:00 20:30 1.50 9.260 9.350 PROD2 DRILL DRLG P Drill Ahead, 80sO off bottom CTP. 3850 on bottom CTP, 1.4 BPM in, 1.348PM out 1KCTVV4O82BHP with 21 WHP, 1'2KVVOB.2OU4OO psi motor work 20:30 22:00 1s0 9.350 9.350 PROD2 DRILL WPRT P TD L2-01. Wiper trip back to window 22:00 22:15 025 9.350 7.250 PROD2 DRILL DLOG P Tie in Depth, �3' correction 22:15 00:00 1.75 9.350 7.250 PROD2 DRILL WPRT P R|H tagging TDS350' POOH laying in Alpine beaded liner pill. 33/08/2010 RIH with L2-01 liner tagging at 7445' POOH, lay down liner. PU/ MU bent sub on liner. Set liner on bottom 835O TD. TOL8244' POOH PU second segment of liner. 00:00 02:00 2.00 7.250 0 PROD2 DRILL TRIP P POOH Killing Well. Oo:OO 02:15 025 0 0 PROD2 DRILL SFTY P Perfbnn flow check, Hold PJGM laying down BHA. 02:15 03:45 1.50 0 0 PROD2 DRILL PULD P Laydowri BHA22, RU to run liner 03:45 04:00 0.25 0 0 COMPZ CASING GFTY P Hold Safety meeting on MU ofliner 04:00 08:08 4.10 0 1.370 CnK8PZ CASING PUTs P PU liner, clear floor, PU|nteqTGand Injector 08:00 09:36 1.50 1.370 7.100 COMPZ CASING RUNL P R|M with liner 09:36 09:54 0.30 7,100 7,445 COMPZ CASING RUNL P Correct depth to flag, -28', continue RIH 03:54 10:30 0.00 7,445 7.445 COKoPZ CASING nUNL T Stacking weight at7445' Attempt to work past at various speeds. PUH through wiridow and try again at various speeds. No luck. 10:30 12:00 1.50 7,445 1.370 COK8PZ CASING RUNL T POOH, pumping down backsideto fill void. Paint EOP flag at 5700' EOP. ' � ' `.,�, , Page 2rofo3 • • Time Logs Date == From TO Dur S. Depth E. Depth' Phase Code Subcode T - Comment 12:00 14:30 2.50 1,370 0 COMPZ CASING PUTB T Lay down inteq BHA and 42 Joints liner. 14:30 16:45 2.25 0 0 COMPZ CASING PUTB T PU guide shoe, .81' pup joint, 2 deg. bent sub and 35 Joints liner. PU BOT 16:45 17:57 1.20 0 7,100 COMPZ CASING RUNL T RIH with Liner 17:57 18:03 0.10 7,100 7,445 COMPZ CASING RUNL T Tie in to EOP flag - 30.8'. RIH tagging at 7445' 18:03 18:45 0.70 7,445 7,445 COMPZ CASING RUNL T PUH orient around in 90deg quadrants to try and pass 7445' with liner, No luck. 18:45 19:27 0.70 7,445 9,350 COMPZ CASING RUNL P Start at 90R orienting 15 deg increments trying to pass 7445'. • Pass through 165 deg TF. RIH to TD 19:27 20:27 1.00 9,350 6,900 COMPZ CASING RUNL P Liner on bottom with 4K WOB on tag. Pump to release off liner. PUH 20K Liner released. POOH pumping across top keeping hole full keeping beads in OH. 20:27 22:27 2.00 6,900 0 COMPZ CASING RUNL P Tie in with gamma. -1 ' correction POOH painting EOP flag 6200' 22:27 22:57 0.50 0 0 COMPZ CASING RUNL P At surface, perform flow check, hold PJSM for running liner 22:57 00:00 1.05 0 0 COMPZ CASING PULD P Start running Liner 33/09/2010 RIH with Liner assembly, then OH anchored Billet. Set TOB @ 7409'. POOH & P/U drilling BHA. KOB from 7409' - 7424', dry tag looked clean. Drilling ahead. Total of 38 bbls losses for 24 hours. 00:00 00:30 0.50 0 0 COMPZ CASING PULD P Finish PU liner 00:30 01:30 1.00 0 0 COMPZ CASING RURD P Rig down from running liner, Hold PJSM PU Coil Track, MU to liner. 01:30 03:30 2.00 0 7,066 COMPZ CASING RUNL P RIH with liner 03:30 04:12 0.70 7,066 8,271 COMPZ CASING RUNL P Correct depth to flag at 6200 EOP, 7066.36'. 17 K PUW, 7K RIW. Continue RIH. Stacked weight at 7230', PU and clean second time. Clean run to hard tag at 8272'. On line with pump down coil. 13 Bbls to fill coil, 1.2 BPM, 3800 CTP. released from liner. 04:12 04:42 0.50 8,271 7,240 COMPZ CASING RUNL P PUH and tie in to RA, -27' correction. Liner top is 7433'. 04:42 06:12 1.50 7,240 0 COMPZ CASING RUNL P POOH 06:12 07:18 1.10 0 0 PROD3 STK PULD P Lay down BHA # 25, PU BHA # 26, anchored billet 07:18 09:18 2.00 0 6,950 PROD3 STK TRIP P RIH 09:18 09:33 0.25 6,950 6,950 PROD3 STK DLOG P Tie in depth - 30'. Close EDC, 09:33 10:03 0.50 6,950 7,433 PROD3 STK TRIP P RIH to TD, Tag 7433', Online with pumps setting OH anchor, 4200psi. 6.7K WOB. PUH 10:03 11:33 1.50 7,433 0 PROD3 STK TRIP P POOH, TOB set set at 7410'. 11:33 12:33 1.00 0 0 PROD3 STK PULD P At surface, hold PJSM, LD BHA 26, Page 28 of 33 • • Time Logs Date From To Dur S. Depth E. Depth_Phase Code Subcode T -- Comment 12:33 13:18 0.75 0 0 PROD3 STK PULD P Perform 1 week function test on BOP's. PU /MU BHA 27, Check stripper rubber. 13:18 14:33 1.25 0 6,950 PROD3 STK TRIP P RIH 14:33 14:48 0.25 6,950 6,950 PROD3 STK DLOG P Tie in depth 29' correction 14:48 16:33 1.75 7,200 7,200 PROD3 STK CIRC P Circulate KWF Out of well 16:33 16:48 0.25 7,200 7,409 PROD3 STK KOST P RIH to dry tag billet 7408.7'. PUH 16:48 18:48 2.00 7,409 7,412 PROD3 STK KOST P Start milling 1' /hour on Auto Driller. Al. in returns. _ Stall X 1 18:48 20:00 1.20 7,412 7,423 PROD3 STK KOST P By -pass MP choke. Increase to 3 ft/hour @ 7411.5, increase to 10 ft/hour @ 7412.6'. Plenty of Al. shaving in returns. Increase to 20 fph @ 7418'. Drill down to 7424' Looks good. 20:00 20:30 0.50 7,423 7,442 PROD3 DRILL DRLG P 100% formation in returns, P/U and dry run through Billet. Looks clean. Set back up on choke and begin drilling ahead. 1.45 bpm, circ. 3750, BHP 3860, ECD 11.8, WHP 0, WOB 1.3, ROP 60 fph. 20:30 21:00 0.50 7,442 7,442 PROD3 DRILL WPRT P Good indication of Rez tool through billet - Wiper trip, - ROP dropped off to 20 fph. P/U weight 20K, slight weight bobble coming up @ 7350', clean up /down from window. 21:00 22:30 1.50 7,442 7,560 PROD3 DRILL DRLG P Drilling ahead - 1.44 bpm, circ. 3800psi, BHP 3870, ECD 11.9, ROP 30 fph, WOB 1.8. Drilling break @ 7450'. ROP 90 fph. losing 3 to 4 bbls /hour. 22:30 23:18 0.80 7,560 7,560 PROD3 DRILL WPRT P Wiper trip - P/U weight 21k, clean trip. 23:18 00:00 0.70 7,560 7,643 PROD3 DRILL DRLG P Drilling ahead, start pumping new mud. 38 bbls loss for 24 hours. 33/10/2010 Drilling ahead - mud swap @ 7700ft with 940 drilled footage on system. 60 bbls of losses for 24 hours. 00:00 00:30 0.50 7,643 7,710 PROD3 DRILL DRLG P Drilling ahead, new mud pumped around. 948 ft drilled on old mud system. 1.45 bpm, 3680psi, BHP 3800, ECD 11.8, ROP 75, WOB 2.1, WHP 90 psi. 00:30 01:30 1.00 7,710 7,710 PROD3 DRILL WPRT P P/U weight 22K - lots of cutting over 9 9 shakers with wiper & new mud. 01:30 03:00 1.50 7,710 7,860 PROD3 DRILL DRLG P Drilling ahead - 1.47 bpm, circ 3650 psi, BHP 3850, ECD 11.8, WHP 70, ROP 90 fph, CT weight 7K. Drilled through Silt formation @ 7785'. Start steering down. 03:00 04:00 1.00 7,860 7,860 PROD3 DRILL WPRT P Wiper trip, 22k P /U. +2 ft correction on tie in. Page 29 of 33 • Time Log , Date From TO Dur S. Depth E. Depth Phase Code Subcode_ T =- Comment 04:00 05:30 1.50 7,860 8,010 PROD3 DRILL DRLG P Drilling ahead- 1.5 bpm, circ 3870, BHP 3830, ECD 11.8, WHP 40, ROP 90 fph, CT weight 7k, WOB 2.2. Fault or drilling change @ 7900'. 05:30 06:30 1.00 8,010 8,010 PROD3 DRILL WPRT P Wiper trip to window 06:30 08:00 1.50 8,010 8,097 PROD3 DRILL DRLG P Drilling ahead- 1.5 bpm, circ 3870, BHP 3830, ECD 11.8, WHP 40, ROP 100 -150 fph, CT weight 4 -7k, WOB 2.2 -3K. 08:00 09:15 1.25 7,200 7,200 PROD3 DRILL WPRT P Lose power on rig, PUH to repair, Pull Wiper trip back to window 09:15 10:39 1.40 8,097 8,252 PROD3 DRILL DRLG P Drilling ahead- 1.5 bpm, circ 3960, BHP 3870, ECD 11.9, WHP 24, ROP 100 -150 fph, CT weight 4 -7k, WOB 2.2 -3K. 10:39 11:27 0.80 8,252 7,200 PROD3 DRILL WPRT P Wiper trip to window 21K CTW. 11:27 11:33 0.10 7,200 7,200 PROD3 DRILL DLOG P Tie in depth to RA marker. +3' correction, 11:33 12:03 0.50 7,200 8,252 PROD3 DRILL WPRT P RIH 12:03 14:33 2.50 8,252 8,400 PROD3 DRILL DRLG P Drilling ahead- 1.5 bpm, circ 3930, BHP 3880, ECD 11.9, WHP 21, ROP 100 -150 fph, CT weight 4 -7k, WOB 2.2 -3K. 14:33 16:18 1.75 8,400 7,174 PROD3 DRILL WPRT P Wiper trip to window 22K CTW 16:18 18:30 2.20 8,400 8,550 PROD3 DRILL DRLG P Drilling ahead- 1.5 bpm, circ4041, BHP 3960, ECD 12.1, WHP 26, ROP 100 -150 fph, CT weight 4 -7k, WOB 1 -2K. 18:30 20:00 1.50 8,550 8,550 PROD3 DRILL WPRT P Wiper trip - reduce pump rates through 7900 - 8000 ft. 20:00 21:00 1.00 8,550 8,715 PROD3 DRILL DRLG P Drilling ahead - 1.4 bpm, 3900 psi, BHP 3960, ECD 12.1, WHP 0, CT weight 4K, ROP 100 fph. 21:00 23:00 2.00 8,715 8,715 PROD3 DRILL WPRT P Wiper trip to window - P/U weight 22K. reduce pump rate through 800'- 7900'. Tie in +3 ft correction. 23:00 00:00 1.00 8,715 8,811 PROD3 DRILL DRLG P Drilling ahead - 1.4 bpm, 3800 psi, BHP 4000, ECD 12.1, ROP 100, CT weight 3K. 33/11/2010 TD lateral @ 9002', Pump liner pill & KWF while POOH. P/U liner & Billet top assembly. RIH set from 9001.5 to TOB @ 7509'. POOH P/U drilling assembly. 00:00 00:30 0.50 8,811 8,865 PROD3 DRILL DRLG P Drilling ahead 00 :30 02:30 2.00 8,865 8,865 PROD3 DRILL WPRT P Wiper trip - 22K off bottom. Hole is clean. 02:30 06:45 4.25 8,865 8,970 PROD3 DRILL DRLG P Drilling ahead Hit a hard spot @ 8880'. 1.40 bpm, 3700psi, BHP 3990, ECD 12.2, WHP 0, ROP 10, WOB 2.4, CT weight 2K. 06:45 06:51 0.10 8,970 8,970 PROD3 DRILL DRLG P Pump Hi /Low vis for TD wiper 06:51 07:15 0.40 8,970 9,000 PROD3 DRILL DRLG P TD well, 07:15 08:48 1.55 9,000 7,230 PROD3 DRILL WPRT P Sweep at bit, Wiper trip back to window. 22K CTW Page 30 of 33 IP • Time Logs = Date From To Dur= S. Depth E. Depth Phase Code Subcode T, Comment - 08:48 09:00 0.20 7,230 7,244 PROD3 DRILL DLOG P Tie in depth with RA marker.+ 3' correction 09:00 10:00 1.00 7,244 9,000 PROD3 DRILL WPRT P RIH to TD 10:00 11:15 1.25 9,002 7,200 PRODS DRILL WPRT P Tag TD 9002.4'. POOH laying in Liner pill to window 11:15 12:45 1.50 7,200 0 PROD3 DRILL TRIP P POOH laying in KWF, Perform Jog down to 500'. 12:45 14:15 1.50 0 0 PROD3 DRILL PULD P PJSM, LD BHA, RU rig floor to run Liner 14:15 17:00 2.75 0 1,536 COMPZ CASING PUTB P PU/MU Liner 17:00 18:00 1.00 1,536 7,100 COMPZ CASING TRIP P RIH Pumping . 3 bpm through EDC. 18:00 19:00 1.00 9,002 9,002 COMPZ CASING TRIP P Stop above window, P/U weight 21 K, Close EDC & flag tie in. RIH weight 10K, WOB - 3K. RIH was smooth through OH and window. Tag bottom @ 9001.5 - Sit down 5 K WOB, CT weight -4K @ surface. Start pumping 1.5 bpm, P/U weight 19K POOH 30ft stop pumping, Pump down backside up through window. 19:00 21:00 2.00 7,212 7,216 COMPZ CASING TRIP P Stop @ window. Tie in and correct depth to +4ft. Billet top roughly @ 7509'. POOH pumping KWF through CT @ .5 bpm. 21:00 22:30 1.50 7,216 0 PROD4 STK PULD P Ct @ surface, flo- check. Lay down BHA & P/U drilling BHA. 22:30 00:00 1.50 0 7,000 PROD4 STK TRIP P RIH with Sidetrack BHA. 33/12/2010 KO Billet top @ 7509.5' Continue drilling ahead. Mud swap with 1400 ft on mud system. 00:00 01:30 1.50 7,000 7,000 PROD4 STK CIRC P Circulate out KWF & tie in with +23 ft correction. 01:30 02:00 0.50 7,509 7,509 PROD4 STK TRIP P RIH and dry tag billet top @ 7509.5, P/U - 21 K, CT weight. 02:00 04:30 2.50 7,509 7,511 PROD4 STK KOST P Start KOB - 7508.8' 1.4 bpm, 3800 psi, BHP 3920, ECD 12.1, WOB .8. Drill @ 1 fph. to 7510.5'. No stalls 04:30 05:45 1.25 7,511 7,517 PROD4 STK KOST P Increase to 2 fph - 7511, 3 fph 7512, 10 fph to 7517' 05:45 06:00 0.25 7,517 7,517 PROD4 STK KOST P Perform dry run through sidetrack. Looks good. 06:00 07:45 1.75 7,517 7,660 PROD4 DRILL DRLG P Drill Ahead 80 -100 FPH, 2 -2.5K WOB, 1.4 BPM in, 1.3 BPM out, 0 WHP, 4000 CTP, 6K CTW. 07:45 08:30 0.75 7,660 7,660 PROD4 DRILL WPRT P Wiper trip to window, 22K CTW 08:30 10:15 1.75 7,660 7,810 PROD4 DRILL DRLG P Drill Ahead 80 -100 FPH, 2 -2.5K WOB, 1.4 BPM in, 1.3 BPM out, 0 WHP, 4000 CTP, 8K CTW. 10:15 11:00 0.75 7,810 7,810 PROD4 DRILL WPRT P Wiper trip to window, 22K CTW 11:00 11:30 0.50 7,810 7,850 PROD4 DRILL WPRT P Drill Ahead 80 -100 FPH, 2 -2.5K WOB, 1.4 BPM in, 1.3 BPM out, 0 WHP, 4000 CTP, 8K CTW. 12.1 ECD Page 31 of 33 . • Time L "ogs Date From To • 'Dur S. Depth E. Depth = Phase = Code _ Subcode'' T Comment - - - 11:30 13:15 1.75 7,850 7,960 PROD4 DRILL DRLG P Drill Ahead 70 -80 FPH, 2 -2.5K WOB, 1.5 BPM in, 1.43 BPM out, 19 WHP, 3860 CTP, 8K CTW, 11.8 ECD On New mud system 13:15 14:00 0.75 7,960 7,960 PROD4 DRILL WPRT P Wiper trip to the window 21K CTW 14:00 14:12 0.20 7,250 7,250 PROD4 DRILL DLOG P Tie in depth to RA marker, +3' correction 14:12 14:33 0.35 7,250 7,960 PROD4 DRILL WPRT P RIH 14:33 16:33 2.00 7,960 8,110 PROD4 DRILL DRLG P Drill Ahead 70 -80 FPH, 2 -2.5K WOB, 1.5 BPM in, 1.43 BPM out, 19 WHP, 3860 CTP, 8K CTW, 11.8 ECD 16:33 17:33 1.00 8,110 8,110 PROD4 DRILL WPRT P Wiper trip 17:33 20:00 2.45 8,110 8,260 PROD4 DRILL DRLG P Drilling ahead - 1.44 bpm, 3900 psi, BHP 3900, ECD 12.1, ROP 80, WHP 50, start steering down. 20:00 21:00 1.00 8,260 8,260 PROD4 DRILL WPRT P Wiper trip, P/U weight 22K - Clean wiper trip. 21:00 22:00 1.00 8,260 8,328 PROD4 DRILL DRLG P Drilling ahead - 140 bpm, 3700psi, BHP 3870, WHp 0, WOB 2K, Ct weight 8K, ROP 90, ECD 11.9. 22:00 22:30 0.50 8,328 8,328 PROD4 DRILL WPRT P BHI Software crashed. P/U off bottom 21K, and POOH slowly 100' - RIH. 22:30 23:30 1.00 8,328 8,410 PROD4 DRILL DRLG P Continue drilling ahead 100 fph. 23:30 00:00 0.50 8,410 8,410 PROD4 DRILL WPRT P Wiper trip, P/U weight 22k - Tie in _ Wiper. 33/13/2010 TD lateral @ 8725', Pump liner pill & KWF. P/U Liner assembly, RIH and set liner from 8725 - 7125' (Liner top). 00:00 01:00 1.00 8,410 8,410 PROD4 DRILL WPRT P Wiper trip with + 2 ft correction on tie in. 01:00 03:30 2.50 8,410 8,575 PROD4 DRILL DRLG P Drilling ahead - 1.40 bpm, 3700psi, BHP 3880, ECD 12, ROP 90, WOB 2K, CT weight 7K,. Getting good formation @ 8530'. 03:30 05:30 2.00 8,575 8,575 PROD4 DRILL WPRT P Wiper trip - P/U weight 24K. Small weight spike @ 7973' while POOH. 05:30 08:30 3.00 8,575 8,725 PROD4 DRILL DRLG P Drilling ahead - 1.40 bpm, 3700psi, BHP 3880, ECD 12, ROP 90, WOB 2K, CT weight 7K,. Getting good formation @ 8530'. Pump 5bbrls high /low sweep. 08:30 09:15 0.75 8,725 8,725 PROD4 DRILL WPRT P TD L1 -01 Lateral Wiper trip back to window chasing sweeps. 09:15 09:30 0.25 7,250 7,250 PROD4 DRILL DLOG P Tie in depth with RA marker. +.5'. 09:30 10:30 1.00 7,250 8,725 PROD4 DRILL WPRT P RIH to TD 10:30 11:00 0.50 8,725 7,057 PROD4 DRILL WPRT P POOH laying in liner pill to window 11:00 12:45 1.75 7,057 0 PROD4 DRILL TRIP P Paint EOP flag. POOH displacing KWF 12:45 13:00 0.25 0 0 PROD4 DRILL SIPB P At surface, Flow chwck good Page 32 of 33 • �� ���� `�. `�. T ime Date ` To Pi6oe Suboode Conmori `I = `�'��/�^�`��:n 13:00 13:30 0.50 0 0 PROD4 DRILL PULD P LD BHA 13:30 14:00 0.50 0 0 COMPZ CASING OTMR P RU floor toPUliner 14:00 17:00 3.00 0 1.839 COMPo CAG|NGPUT8 P PU8NU liner 17:00 18:30 1.50 1,639 7.000 COMPZ CASING TRIP P Rlh with liner assembly, correct tn flag. Weight chec of22K.Shut down pumps & close EDO. 18:30 18:80 1.00 7.000 8.725 COMPZ CASING TRIP P RIH no problems, sat down weight @ 8725' Top of Liner 7129' Bring pumps up to 1.4 bpm. P/U weight 21 K. Pull up to Tie point, Zero correction, swtich to Sw and start pumpinn8w down CT. 13:30 21:00 1.50 8.735 3.000 COMPZ CASING TRIP P POOH pumping GvV Pumping .8 bpm/70 fpm, following MP schedule. Safety meeting with LRS and heat up _ diesel to 70 degree. 21:00 22:30 1.50 3.000 40 COMPZCA8|NGTR|P P Start pumping diesel, SW@ surface. Pump 30 bbls, POOH displacing Diesel to surface. CT @ surface, diesel returns to Tiger tank. Hold pre-job for Undeploying. 22:30 00:00 1.50 40 0 COMPZ CASING PULD P Bring in BPV Iubricator to warm up. Begin Undeploying BHA. 03/14/2010 Freeze protect well, Set 8PV&RDMO. Rig Released @11:0OHRS. 00:00 03:00 3.00 0 0 COMPZ CASING PUTo P Lay down BHA & Flush choke and blow down stack. **~ Move clocks ahead 1 hour"*** 05:00 04:80 1.50 0 0 DEMOB VVHDBODHEQ P Rig up, tes Lubricator & set BPV. Diesel packed. 04:30 08:80 2.00 0 0 DEMOB MOVE CTOP P Start purging CT and stack with air. 06:30 11:00 4.50 0 0 DEMOB MOVE CTOP P Blow down steam lines/Nipple down/Rig down Nabors is changing out the Skates on the lnjector Head this rig move. Rig Release 11:00 AM Page 33of88 i SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Von Cawvey Alaska Well Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E- 12L2 -01 ConocoPhillips Alaska Inc. Permit No: 210 -007 Surface Location: 804' FSL, 811' FEL, SEC. 16, Ti 1N, R10E, UM Bottomhole Location: 1467' FSL, 1733' FEL, SEC. 16, T11N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Kuparuk River Unit 1E -12, Permit No. 1820600, API No. 50- 029 - 20736- 00 -00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. A c) Chair DATED this Z- of January, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) • Ill RECEIVED STATE OF ALASKA JAN 2 0 201Q ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska 0ft&Gas Celts. Commission 20 AAC 25.005 / / ?'2 ' Anchorage la. Type of Work: • 1 b. Proposed Well Class: Development - Oil El .- Service - Winj ❑ Single Zone d lc. Specify if well is proposed for: Drill ❑ Re -drill El Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: a Blanket ❑ Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 1E 12L2 - 01 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9225' . TVD: 6232' . Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Surface: 804' FSL, 811' FEL, Sec. 16, T11N, R10E UM • ADL 25651 • Kuparuk River Oil Pool - Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2649' FSL, 2453' FEL, Sec. 16, T11N, R10E, UM 469 2/16/2010 • Total Depth: 9. Acres in Property: 14. Distance to 1467' FSL, 1733' FEL, Sec. 16, T11N, R10E, UM 2560 Nearest Property: 23800' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 106 feet 15. Distance to Nearest Well Open Surface: x - 549710 • y - 5960390 • Zone 4 GL Elevation above MSL: 80 feet to Same Pool: 1E-25 , 550 • 16. Deviated wells: Kickoff depth: 8100 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101 ° • deg Downhole: 2563 psig Surface: 1909 psig . 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L - 80 ST - L 2075' 7150' 6169' 9225' 6232' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 7512' 6575' 7427' 6504' Casing Length Size Cement Volume MD . TVD Conductor /Structural 80' 16" 217 sx AS II 80' 80' Surface 2470' 10.75" 1050 sx AS III, 250 sx AS II 2501' 2500' Intermediate Production 7478' 7" 963 sx Class G 7510' 6573' Liner 6734' 5.5" 6765' 5957' Perforation Depth MD (ft): Perforation Depth TVD (ft): 7200'- 7209', 7222'- 7245', 7253' -7259' 6316'- 6323', 6334' - 6353', 6360' -6365' 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program gi Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program is 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Jill Long @ 263 - 4093 1 6 Printed Name V. Cawvey Title Alaska Wells Manager 00 Signature 'Z,.., Phone 5 , 4e 097, Date /O Commision Use Only Permit to Drill API Num . Permit AppJ oval / See cover letter Number: ,G / ( ` ;>7`= 50- C, 2--/ - 2' L ° Date /ga 6 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: 1 3 500 lafi: Q b P -7 Samples req'd: Yes ❑ No R Mud log req'd: Yes ❑ No []/ Other *, 2 Sacs �s4 / hww�w C....� measures: Yes [✓] No El Directional svy req'd: Yes Q No El I ��i � 0� APPROVED BY THE COMMISSION //22- DATE: / , COMMISSIONER -401 d 7/2009) This permit is valid for 24 months fr• the ate of approval (20 AAC 25.005(g)) Submit in Duplicate ( -L z. /a /� / O /. / 2../•/6 Permto Drill Summary of Opeltions KRU 1E-12 L1, 1E-12 L1 -01, 1E-12 L2 and 1E-12 L2 -01 Coiled Tubing Drilling Well History: Well 1E -12 is an A -sand producing, straddle completion well equipped with 3 -1/2" tubing (from surface to 7157' MD and a 7" production liner (from surface to 7510' MD). The well was a single completion, A -only producer from 1982 -1988. In 1988 the C sand was perforated and the well became and A/C comingled producer. By mid -1997 the WC had increased to 97% (due to the C sand) and so the C sand was cement isolated and the A sand re- perfed. A workover was performed in 2007 to mechanically isolate the C sand via a straddle packer completion (after the C sand cement isolation was suspected to have failed). Thus, the upper completion consists of a straddle packer completion with five gas lift mandrels, a 2.75" D nipple in the tubing tail, and a 2.875" DS nipple at -482'. Due to a casing leak, there is a 5" scab liner from the surface to the upper packer. Prior to the arrival of the CTD rig, the existing A -sand perforations in the 1 E -12 completion will be plugged and abandoned with cement. The two casing exits on this well will be via whipstocks set in a 2.80" cement pilot hole. A Sundry application was submitted on January 13, 2010, for the cement work to be completed pre -rig. Operational Outline Pre -Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Shoot holes in tubing tail to put cement across the tail 3. Mill out the 2.75" D- nipple at 7155' MD to 2.80" with a left-hand motor 4. Load Tubing & IA w/ diesel. Install gas lift valves. Perform MIT -IA. 5. Lay in cement plug from tag depth to the tubing tail. 6. Tag top of cement and then mill cement out of the tubing down to the tubing tail. 7. Prepare welisite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. Set bottom whipstock at 7226' MD. Mill 2.74" window at 7226'. 3. 1E-12 L1 Lateral a. Drill a 2.70" x 3" bi- center lateral to the northwest at a TD of 9150' MD b. Run the 1375' of 2%" slotted liner from TD to -7775' MD. An aluminum liner top billet will be placed at 7775' MD. 4. 1E -12 L1 -01 Lateral a. Kick off of the open -hole aluminum billet at 7775' MD b. Drill a 2.70" x 3" bi- center lateral to the northwest at a TD of 8850' MD c. Run the 1625' of 2 %" slotted liner from TD to -7225' MD. A shorty deployment sleeve will be placed at the top of the liner. 5. Window Milling a. Set the second whipstock at -7200' MD b. Mill 2.74" window off this whipstock 6. 1E-12 L2 Lateral a. Drill 2.70" x 3" bi- center lateral to the southeast at a TD of 9450' MD b. Run the 1350' of 2 slotted liner from TD to 8100'. An aluminum liner top billet will be placed at 8100'. 7. 1E-12 L2 -01 Lateral a. Kick off of the aluminum billet at 8100' MD. b. Drill 2.70" x 3" bi- center lateral to the southeast at a TD of 9225' MD '1" c. Run the -2075' of 2%" slotted liner from TD to just intside the tubing tail (-7150' MD). A shorty P-ro deployment sleeve will be placed at the top of the liner. 8. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Page 1 of 3 ! j 1/19/2010 Permit to Drill Summary of Op•ions Cont. KRU 1E -12 L1, 1.L1 -01, 1E -12 L2, & 1E -12 L2 -01 Post -Rig Work 1. Obtain SBHP 2. Flowback to tanks for well cleanup 3. Begin production Mud Program • Chloride -based Biozan brine (8.6 ppg) for milling operations, and chloride -based Flo -Pro mud (8.6 ppg) for drilling operations. • Kill weight fluid needed while running the completion on this well will be at minimum 11.8 ppg. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 23/4', 4.7 #, L -80, ST -L slotted liner; 1E -12 L1 7775' 9150' 6287' 6333' aluminum billet on top. 1E -12 L1 -01 7225' 8850' 6231' 6279' 2' /a 4.7 #, L -80, ST -L slotted liner; deployment sleeve on top. 1E-12 L2 8100' 9450' 6252' 6287' 2 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 1 E -12 L2 -01 7150' 9225' 6169' 6232' 2 4.7 #, L -80, ST -L slotted liner; deployment sleeve on top. Existing Completion Details: Weig Burst Collapse Top Btm Top Btm Category OD ht Grade Connection MD MD TVD TVD psi psi (ppf) Conductor 16" 65 H-40 Welded 0 80 0 80 1640 630 Surface 10 3 /" 45.5 K -55 BTC 0 2501 0 2500 3580 2090 Casing 7" 26 L -80 & BTC SML R -3 0 7510 0 6573 4980 4330 K -55 Scab Liner 5 /" 15.5 L -80 511 Hydril 0 6765 0 5959 7000 4990 Tubing 3 %2 " 9.3 L -80 ABM -EUE 0 7157 0 6280 10160 10540 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure is 3080 psi assuming a gas gradient to surface based on the highest bottom hole pressure in offset well 1 E -15 (3720 psi at 6344' TVD/ 7676' MD on January 4, 2010). • The annular preventer will be tested to 250 psi and 2500 psi. Page2of3 ORIGINAL 1/19/2010 Permit to Drill Summary of OAllfions Cont. KRU 1E -12 L1, 1E410-01, 1E -12 L2, & 1E -12 L2 -01 Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1E-12 L1 24650 1E -12 L1 -01 25050 1E-12 L2 23450 1E-12 L2 -01 23800 • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 1E-12 L1 500 1E-10 1E-12 L1-01 500 1E-10 1E-12 L2 375 1E-25 1E-12 L2 -01 550 1E-25 Logging MWD directional, resistivity, and gamma ray will be run over the entire open - hole sections. Hazards • The most recent H reading on 1E-12 was taken on 09/26/04 and read 15 ppm. The highest H reading on the 1E pad in 2009 was 130 ppm on well 1E-24A. All H monitoring equipment will be operational while drilling the 1E-12 laterals. • Shale stability is a concern while crossing the A4 /A5 interface as well as at the landing points in the A3. • WOB limitations are a concern and the agitator is expected to be used on the L2 and L2 -01 laterals. • There is a fault crossing in both build sections which could throw sand against shale. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The well will be loaded with overbalanced fluid prior to running the completions. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The target MPD ECD is 11.8 ppg. The reservoir pressure at the first KOP is estimated to be 2,563 psi (7226' MD/ 6337' TVD). Reservoir Pressure Wells 1E-15 and 1E-08 are the primary injection wells that support 1E-12. The most recent static bottom hole pressure readings in each well are as follows: Well name Pressure (psi) SSTVD of Est. Measured Date EMW (ppg) 1E-15 3719 6238 1/4/2010 11.3 1E-08 3021 6218 2/15/2008 9.3 Page 3 of 3 1 .. � L g 1/19/2010 1E-12 Proposed CTD Sidetrack 3 -1/2" Camco DS nipple @ 482' MD 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 3 -1/2" Camco KBG -2 -9 gas lift mandrels @ 2490', 3817', 5088', 6115', 6641' 16 "65 #H- 40 shoe @ 80' MD 3 -1/2" tubing w/ seals stabbed into 5" joint in the 5 -1/2" scab liner 5 -1/2" scab liner from surface to 6765' MD, seals stabbed into top of FHL PBR 10 -3/4" 45.5# K- " 55 shoe @ 2501' Baker 3 -1/2" PBR @ 6765' MD 0 MD Baker FHL packer @ 6779' MD e `,;;4h° 3 -1/2" CMU sliding sleeve @ 6926' MD (2.812" min ID) C - C -sand perfs ` "� 7010' - 7090' MD —.. . """" " Baker F-1 packer @ 7137' MD (2.99" ID) a) Baker SBE @ 7140' MD ` t, _ 3 -1/2" Camco D landing nipple @ 7155' MD (2.75" min ID, No -Go) in 3 -1/2" tubing tail @ 7156' MD ( I Top of cement at KOP #2 at 7200' MD tubing tail at 7155' MD L2 -01 Lateral (A5 sand, southeast) KOP #1 at 7226' MD \ \ TD = 9225' Baker monobore whipstock trays Liner top at 7150' on openhole anchors at 7208' & 7234' � \ e N — — — — — — — L2 Lateral (A4 sand, southeast) 2.80" pilot hole in cement drilled ( �� TD — 9450' to 7275' MD / / — — / / Billet at 8100' A-sand perfs ^ Ph, L1 -01 Lateral (A5 sand, northwest) (sqz'd) 7200' TD = 8850' 7259' MD . --- Liner top at 7225' 7" 26# J -55 shoe ``��� ) L1 Sidetrack (A4 sand, Northwest) @ 7510' MD w TD = 9150' —.MI , �^^ Billet at 7775' • • Nabors CIDR -2AC Kuparuk Managed Pres: ure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing ' Lubricator Riser r D Annular Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator ` • above BHA ram I i 1 � Choke 1 2 -3/8" Pipe / Slip (BHA) Choke -- Equalize Manifold 2 -3/8" Pipe / Slip (BHA) / _.: _. -. 1 L sL Kill • > < > < � Q—. / i 1 I B 8 lind / Shear 2" Pipe / Slip (CT) Choke 2 i -I Swab Valves JIM Wing Valves 4 444 Tree Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi Master valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser: 7- 1/16 ", 5M psi, C062 Union ORIGINAL • Cono A Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E -12 1E-12L2-01 Plan: 1 E- 12L2 -01 wp04 Standard Planning Report 19 January, 2010 ra11111 BAKER HUGHES r „ • IIII ConocoPhillips rake ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: = Well 1 E -12 Company - . . ConocoPhillips(Alaska) Inc. TVD Reference: _ Mean Sea Level 4 Project - Kuparuk River Unit MD Reference - = - 1E @ 105.70ft (1 E - 12) Site . Kuparuk 1 E Pad North Reference - True a Well � 1E Surrey Calculation Meth d Minimum Curvature Wellbore: 1E-12L2-01 Desigtl 1E-12L2-01 wp04 - Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site ' Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70° 18' 3.022 N From: Map Easting: 549,889.51 ft Longitude: 149° 35' 45.358 W Position Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.38 ° Welt 1E-12 Well Position +N/-S 0.00 ft Northing: 5,960,390.22ft Latitude: 70° 18' 9.229 N +E/ - 0.00 ft Easting: 549,710.20 ft Longitude: 149° 35' 50.464 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft i Welibore' - 1E-12L2-01 Magnetics Model Name -- Sample Date Declination Dip Angle _ --: , Field Strength __ - (°) - - -= - ?_ _ (°) Pa) - ` BGGM2009 3/4/2010 21.86 80.84 57,656 Design - 1 E- 12L2 -01 wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,100.00 Vertical Section: Depth From (TVD) +N/ - +E/ - Direction - - - _ - 71.10 0.00 0.00 149.00 Plan Sections - Measured - - - TVD Below Dogleg Build Turn - - Depth Inclination _ Azimuth _ System +14/4 +E/4/ Rate Rate ° . =Rate TFO . - > (ft) (% - - r) (ft) (ft) _ _ _ (ft) (° /100R - - (°MOOft)- (' /100ft) - (°) ..-__ . Target 8,100.00 90.94 178.24 6,251.64 1,586.83 - 1,474.50 0.00 0.00 0.00 0.00 8,150.00 98.44 178.24 6,247.56 1,537.06 - 1,472.98 15.00 15.00 0.00 0.00 8,170.00 101.03 176.72 6,244.18 1,517.37 - 1,472.11 15.00 12.97 -7.64 330.00 8,200.00 98.89 172.70 6,238.99 1,487.96 - 1,469.38 15.00 -7.13 -13.40 242.00 8,400.00 91.79 143.40 6,219.97 1,305.53 - 1,395.53 15.00 -3.55 -14.65 258.00 8,550.00 91.73 120.89 6,215.31 1,205.57 - 1,285.08 15.00 -0.04 -15.01 270.20 8,775.00 90.05 154.60 6,211.72 1,041.44 - 1,136.00 15.00 -0.75 14.98 92.50 8,890.00 86.66 171.53 6,215.05 931.90 - 1,102.63 15.00 -2.95 14.72 101.50 9,225.00 87.86 121.23 6,232.18 662.22 - 923.20 15.00 0.36 -15.01 270.00 1/19/2010 12:47:55PM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips ill Conoco i Planning Report BAKER HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 E - 12 Company: ConocoPhillips(Alaska) Inc. 1VD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: -- - 1E @ 105.70ft (1E-12) Site Kuparuk 1 E Pad North Reference: True Welt 1 E - 12 Survey Calculation Method: -: Minimum Curvature Wellbore: 1 E- 12L2 -01 Design -' : , = 1 E - 12L2 01_wp04 Planned Survey_-__ Measured, TVD Below Vertical=:: = Dogleg Toolface Map~ Map -=_ -_ Depth Inclination Azimuth System +N/ -S +E/ \W // Section MOM Azimuth Northing Easting (ft) - el ("} (ft) _ (R1 - (ft) 00 ( °N W I ) ( - 00 _ 00 8,100.00 90.94 178.24 6,251.64 1,586.83 - 1,474.50 - 2,119.61 0.00 0.00 5,961,967.11 548,225.37 TIP / KOP 1E - 12L2 8,150.00 98.44 178.24 6,247.56 1,537.06 - 1,472.98 - 2,076.16 15.00 0.00 5,961,917.35 548,227.23 2 8,170.00 101.03 176.72 6,244.18 1,517.37 - 1,472.11 - 2,058.83 15.00 - 30.00 5,961,897.67 548,228.22 3 8,200.00 98.89 172.70 6,238.99 1,487.96 - 1,469.38 - 2,032.22 15.00 - 118.00 5,961,868.28 548,231.15 4 8,300.00 95.52 157.96 6,226.38 1,392.28 - 1,444.29 - 1,937.28 15.00 - 102.00 5,961,772.78 548,256.88 8,400.00 91.79 143.40 6,219.97 1,305.53 - 1,395.53 - 1,837.81 15.00 - 103.86 5,961,686.36 548,306.19 5 8,500.00 91.78 128.39 6,216.85 1,233.96 - 1,326.17 - 1,740.74 15.00 -89.80 5,961,615.26 548,376.02 8,550.00 91.73 120.89 6,215.31 1,205.57 - 1,285.08 - 1,695.25 15.00 -90.27 5,961,587.15 548,417.29 6 8,600.00 91.39 128.38 6,213.95 1,177.19 - 1,243.99 - 1,649.75 15.00 92.50 5,961,559.04 548,458.57 8,700.00 90.64 143.37 6,212.18 1,105.62 - 1,174.58 - 1,552.65 15.00 92.70 5,961,487.93 548,528.44 8,775.00 90.05 154.60 6,211.72 1,041.44 - 1,136.00 - 1,477.77 15.00 92.97 5,961,424.02 548,567.45 7 8,800.00 89.30 158.28 6,211.87 1,018.53 - 1,126.01 - 1,452.99 15.00 101.50 5,961,401.18 548,577.59 8,890.00 86.66 171.53 6,215.05 931.90 - 1,102.63 - 1,366.69 15.00 101.48 5,961,314.71 548,601.54 8 8,900.00 86.66 170.02 6,215.64 922.04 - 1,101.03 - 1,357.42 15.00 -90.00 5,961,304.87 548,603.20 9,000.00 86.79 155.00 6,221.38 827.10 - 1,071.11 - 1,260.62 15.00 -89.91 5,961,210.13 548,633.75 9,100.00 87.15 139.98 6,226.69 743.13 - 1,017.59 - 1,161.08 15.00 -89.05 5,961,126.53 548,687.81 9,200.00 87.70 124.98 6,231.21 675.86 - 944.13 - 1,065.58 15.00 -88.25 5,961,059.75 548,761.71 9,225.00 87.86 121.23 6,232.18 662.22 - 923.20 - 1,043.12 15.00 -87.57 5,961,046.25 548,782.72 TD 1/19/2010 12:47:55PM Page 3 COMPASS 2003.16 Build 69 n r....? 1 1 1 • • ConocoPhillips Irdki ConocoPhillips Planning Report N�HE 'i Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E - 12 Company: °'= ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: = 1E-12 © 105.70ft (1E-12) Site = _ _ Kuparuk 1E Pad North-Reference: : True Well - 1 E - 12 Survey Calculation Method . .; ; Minimum Curvature Wellborn: =- 1E-12L2-01 n-, .- 1 E- 12L2 -01 04 ks Des 1E-12L2-01_w p04 i9 .-Targets Target Name hitlmiss target Dip Angie Dip Dir. TVD ,+W3 +E -W Northing- Easting - Shape (°) (°) (ft) (ft)-f- (ft) (ft) - (ft) Latitude- ° 1E-12L2-01 t3.4 (cop 0.00 0.00 6,232.00 670.62 - 920.61 5,961,054.67 548,785.26 70° 18' 15.824 N 149° 36' 17.308 W - plan misses target center by 8.53ft at 9222.57ft MD (6232.09 TVD, 663.48 N, - 925.27 E) - Point 1E-12L2 Polygon (cos 0.00 0.00 0.00 1,759.81 - 1,686.48 5,962,138.66 548,012.28 70° 18' 26.535 N 149° 36' 39.648 W - plan misses target center by 6241.92ft at 8300.00ft MD (6226.38 TVD, 1392.28 N, - 1444.29 E) - Polygon Point 1 0.00 1,759.81 - 1,686.48 5,962,138.66 548,012.28 Point 2 0.00 1,962.34 - 1,763.16 5,962,340.66 547,934.27 Point 3 0.00 2,173.57 - 1,642.76 5,962,552.66 548,053.26 Point 4 0.00 2,162.04 - 1,409.81 5,962,542.67 548,286.26 Point 5 0.00 1,984.28 - 1,296.96 5,962,365.68 548,400.27 Point6 0.00 1,534.31 - 1,309.92 5,961,915.68 548,390.29 Point 7 0.00 509.13 - 539.55 5,960,895.72 549,167.35 Point 8 0.00 229.86 - 655.40 5,960,615.71 549,053.36 Point 9 0.00 381.88 - 960.44 5,960,765.70 548,747.35 Point 10 0.00 1,370.37 - 1,627.03 5,961,749.66 548,074.30 Point 11 0.00 1,851.93 - 1,550.86 5,962,231.66 548,147.27 Point 12 0.00 1,774.44 - 1,629.38 5,962,153.66 548,069.28 Point 13 0.00 1,759.81 - 1,686.48 5,962,138.66 548,012.28 1E -12L2 fault 3 (copy; 0.00 0.00 0.00 1,317.85 - 1,549.39 5,961,697.67 548,152.27 70° 18' 22.189 N 149° 36' 35.647 W - plan misses target center by 6221.35ft at 8479.49ft MD (6217.48 TVD, 1247.12 N, - 1341.89 E) - Polygon Point 1 0.00 1,317.85 - 1,549.39 5,961,697.67 548,152.27 Point 2 0.00 1,303.45 - 1,336.30 5,961,684.68 548,365.43 Point 3 0.00 1,295.94 - 1,106.48 5,961,678.69 548,595.28 Point 4 0.00 1,303.45 - 1,336.30 5,961,684.68 548,365.43 1E- 12L2 -01 t1.4 (cop 0.00 0.00 6,220.00 1,337.69 - 1,373.24 5,961,718.66 548,328.27 70° 18' 22.384 N 149° 36' 30.510 W - plan misses target center by 36.99ft at 8382.87ft MD (6220.61 TVD, 1319.49 N, - 1405.44 E) - Point 1E- 12L2 -01 t2.4 (cop 0.00 0.00 6,211.00 1,049.17 - 1,148.13 5,961,431.67 548,555.27 70° 18' 19.547 N 149° 36' 23.944 W - plan misses target center by 7.50ft at 8762.12ft MD (6211.75 TVD, 1052.99 N, - 1141.72 E) - Point 1E-12L2-01 KOP (col 0.00 0.00 6,252.00 1,587.38 - 1,474.60 5,961,967.66 548,225.27 70° 18' 24.840 N 149° 36' 33.468 W - plan hits target center - Point Casing Points _ Measured Vertical _ - Casing Hole - Depth - Depth Diameter Diameter (ft) (ft) -- Name - r " - ( •• ( ••) 9,225.00 6,232.18 2 -3/8" 2 -3/8 3 1/19/2010 12:47:55PM Page 4 COMPASS 2003.16 Build 69 I • Conoco Phillips Fan Conoco Phillips Planning Report BAKER Alaska HUGHES Database: -- EDM Alaska Prod v16 Local Co-ordinate Reference: ' Well 1E , -__ s Company : ConocoPhillips(Alaska) Inc. TVD Reference: - ' . - ----.--, Mean Sea Level - s = s , . Project: ,' "- Kuparuk River Unit MD Referenc _ : i ._ - ,,,_ - 1E-12 © 105.70ft (1E-12) ..._ ?Site:3_: , 4 , Kuparuk 1 E Pad North Reference:7 - . -.. True Well: = ' r 1E-12 Survey Calculation Method: 3 Minimum Curvature Wellbonc _74 1E Design:- -:,- -- 1 E-12L2-01_wp04 Plan Annotations Measured Vertical - - - : Local Coordinates Depth"- -- -- Depth -'--:-:= +W-S ,r -, - -- --' 1 ' +El-W- - ?:;-__.,. _ (ft) MY (ft) _., (ft) Comment 8,100.00 6,251.64 1,586.83 -1,474.50 TIP / KOP 1E-12L2 8,150.00 6,247.56 1,537.06 -1,472.98 2 8,170.00 6,244.18 1,517.37 -1,472.11 3 8,200.00 6,238.99 1,487.96 -1,469.38 4 8,400.00 6,219.97 1,305.53 -1,395.53 5 8,550.00 6,215.31 1,205.57 -1,285.08 6 • 8,775.00 6,211.72 1,041.44 -1,136.00 7 8,890.00 6,215.05 931.90 -1,102.63 8 9,225.00 6,232.18 662.22 -923.20 TD 1/19/2010 12:47:55PM Page 5 COMPASS 2003.16 Build 69 pz.wasmrru.tmnh WELLBORE DETAILS: 1E- 12L2 -01 REFERENCE INFORMATION P®' grot Project: Kuparuk RiverUnit Magnetic Norlh'21.8 Site: Kuparuk 1 E Pad Coorcfmate (N/E) Reference: Well 1E -12, True North ✓ MwWH P arent Wellbore: 1E - 12L2 Section (VS) Reference Slot TVD Reference: Mean Sea Level Well: 1E -12 gametal s7a.3<n 1 1 BAKER Wellbore: 1E- 12L2 -01 Tie on MD: 81D0 / ',, OpMgk e08a° Slot - (O.00N, 0.00E) �� �41'1000Pk11��1�35 PIan:1E- 121201 wp04(1E- 12,1E- 12L2 -01) xna�lecc - MeasuredDepmReMrence: lE- 12 HUGHES Calculation Method: Minimum Curvature 1800 -' - - 1700- - - • WELL DETAILS: 1E -12 TIP / KOP IE -12L2 ' Ground Level. 0.00 1600- ' 2 - - +N /-S +E/ -W Nothing Easting Latitude Longitude Slot - - - 0.00 0.00 5980390.22 549710.20 70° 18' 9.229 N 149° 35' 50.484 W 3 - - - - ' 1500 1, SECTION DETAILS ANNOTATIONS 1400- 1 ' Sec MD Inc Azi TVD +NIS +E/-W DLeg TFace VSec Target Annotation ' \ k : 1 8100.00 90.94 178.24 6251.64 1586.83 - 1474.50 0.00 0.00 - 2119.61 TIP /KOP1E -12L2 1300 2 8150.00 98.44 17824 6247.56 1537.06 - 1472.98 15.00 0.00 - 2076.16 2 , 3 8170.00 101.03 176.72 6244.18 1517.37 - 1472.11 15.00 330.00 - 2058.83 3 C \\ 4 8200.00 98.89 172.70 6238.99 1487.96 - 1469.38 15.00 242.00 - 2032.22 4 . 1200- 5 5 6400.00 91.79 143.40 6219.97 1305.53 -1395.53 15.00 258.00 -1837.81 5 6 8550.00 91.73 120.89 6215.31 1205.57 - 1285.08 15.00 27020 - 1695.25 6 01100- 7 8775.00 90.05 154.60 6211.72 1041.44 -1136.00 15.00 92.50 -1477.77 7 - 6 ! 8 8890.00 86.66 171.53 6215.05 931.90 - 1102.63 15.00 101.50 - 1366.69 8 - , IIIP 9 9225.00 87.86 12123 6232.18 66222 - 92320 15.00 270.00 - 1043.12 TD + 1000- ,� 0 900- 7 \ \ � 8 800- .1 0 700- ' TD 600- - --- - - -- -- -- 500- 1E- 12/16- 12L2 -01 - \ , 400- • F' 1E-1211E-12L2.1 gc.. mesa 300- : . o , -2100 -2000 -]900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1]00 -1000 -900 -800 -700 -600 -500 -400 -300 M 6000- West( - )/East( +) (100 ft/in) 6040- 6080- . - �� 6]20 C - 6160 - : TIP /KOPIE -12L2 6 7 8 N Z 6200- 4 5 ! 2 3 • • 6240- - - -' - - i- - -- - -- ' t § 6280- : - - - - - _ - - - i • 2 4) 6320- 1 • ' 1E- 12/ 1 ;2L2 -01 1E- 12/1E 12L2 6360 - : I 6400 64401 0 20 - - .. -1 0 - - ;. -1640 r . - - r 1 0 - ... -. 40 60 -1120 -1080 -1040 -1000 9 -$ 0 0 -2240 -2200 -2160 -2120 -2080 -2040 -2000 1960 -1920 1880 1840 -1800 -1760 -1720 -1680 -1640 -1600 -1560 -1520 -1480 1440 -1400 -1360 -1320 -1280 12 -1200 -11 - 60 -920 80 -840 -800 -760 -720 Vertical Section at 149.00° (40 ft /in) I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 /71).'3'' J la. Type of Work: lb. Proposed Well Class: Development - Oil 0 Service - Winj ❑ Single Zone lc. Sp : if well is proposed for Drill ❑ Re -drill Q Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Co •ed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket U Single W- 111. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 52 180. 1E 12AL2 - 01 r 3. Address: 6. Proposed Depth: /, v ) 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 9225' 32' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation - Number() Surface: 804' FSL, 811' FEL, Sec. 16, T11N, R10E, UM . Al 1 ' • Kuparuk River Oil Pool , Top of Productive Horizon: 8. Land Use Pert: `; 13. Approximate Spud Date: 2649' FSL, 2453' FEL, Sec. 16, T11N, R10E, UM 46 1 2/16/2010 • Total Depth: 9. Acres in Pro.. rty: - 7 14. Distance to 1467' FSL, 1733' FEL, Sec. 16, T11N, R10E, UM 2 60 Nearest Property: 23800' • 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. I: ation abo MSL: • 106 feet 15. Distance to Nearest Well Open Surface: x - 549710 • y - 5960390 • Zone 4\ ' L - evation above MSL: • 80 feet to Same Pool: 1E-25 , 550 • 16. Deviated wells: Kickoff depth: 8100 • ft. X 17. , aximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101 (,dam Downhole: 2563 psig ' Surface: 1909 psig • 18. Casing Program: Specifications `-- Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length` MD ND MD ND (including stage data) 3" 2.375" 4.7# L -80 ST -L ( 2• 5' 7150' 6169' 9225' 6232' slotted liner 19 PRESENT WELL COND b \.; MMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth ND (ft): PI •s (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) 7512' 6575' 7427' 6504' Casing Length Size Cement Volume MD TVD Conductor /Structural 80' 16" 217 sx AS II 80' 80' Surface 2470' 10.75" 1050 sx AS III, 250 sx AS II 2501' 2500' Intermediate Production 7478' 7" 963 sx Class G 7510' 6573' Liner 67 4' 5.5" 6765' 5957' I Perforation Depth MD (ft): Perforation Depth TVD (ft): 7200'- 7209', 72 , '- 7245', 7253' -7259' 6316'- 6323', 6334'- 6353', 6360' -6365' 20. Attachments: Property Plat ' BOP Sketch 0 Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commis- on Representative: Date: Lb 22. I hereby certify that the f. regoing is true and correct. Contact Jill Long @ 263 - 4093 11 .11 0 Printed Name V. Cawvey Title Alaska Wells Manager Signature Phone 245 ,-.,43.6 6 Date ' A-z.../A) Commission Use Only Permit to Drill API ber: T / _ Permit Approval See cover letter Number: %. Az, c f c 7 50 - (iZQ- 2. C1736 � j v -L4' Date: 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: U Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No RI' Other: H2S measures: Yes ['No ❑ Directional svy req'd: Yes 2' No ❑ APPROVED BY THE COMMISSION DATE' , COMMISSIONER b . : Form 10-401 (Revised 7/2009) This permit is v. t�s�r�rrXtlie date -ef approval (20 AAC 25.005(g)) � � /� y�mit i� �up� to Conoco Phillips : Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 January 12, 2010f� Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits permit to drill applications for four lateral sidetracks out of Kuparuk Well 1E-12 (PTD# 182 -060) using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 1E -12 as early as late February 2010. The CTD objective is to drill four A-sand lateral sidetracks (1E-12 A, 1E-12 ALA, 1E-12 AL2, and 1E-12 AL2 -01). The original wellbore perforations will be plugged and abandoned with cement prior to CTD operations (Sundry application is attached). Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1E-12 A, 1E-12 AL1, 1E-12 AL2, 1E-12 AL2 -01 — Proposed Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — Sundry application If you have any questions or require additional information please contact me at my office 907 - 263 -4093. Sincerely, • Jill Li g Coiled Tubing Drilling Eng eer I Permit to Drill Summary of Operations KRU 1E-12 A, 1E-12 AL1, 1E-12 AL2 and 1E-12 AL2 -01 Coiled Tubing Drilling Well History: Well 1E-12 is an A -sand producing, straddle completion well equipped with 3 -1/2" tubing (from surface to 7157' MD and a 7" production liner (from surface to 7510' MD). The well was a single completion, A -only producer from 1982 -1988. In 1988 the C sand was perforated and the well became and A/C comingled producer. By mid -1997 the WC had increased to 97% (due to the C sand) and so the C sand was cement isolated and the A sand re- perfed. A workover was performed in 2007 to mechanically isolate the C sand via a straddle packer completion. Thus, the upper completion consists of a straddle packer completion with five gas lift mandrels, a 2.75" D nipple in the tubing tail, and a 2.875" DS nipple at -482'. Due to a casing leak, there is a 5" scab liner from the surface to the upper packer. Prior to the arrival of the CTD rig, the existing A -sand perforations in the 1E-12 completion will be plugged and abandoned with cement. The two casing exits on this well will be via whipstocks set in a 2.80" cement pilot hole. A Sundry application is attached for the cement work to be completed pre -rig. Operational Outline Pre -Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Shoot holes in tubing tail to put cement across the tail 3. Mill out the 2.75" D- nipple at 7155' MD to 2.80" with a left-hand motor 4. Load Tubing & IA w/ diesel. Install gas lift valves. Perform MIT -IA. 5. Lay in cement plug from tag depth to the tubing tail. 6. Tag top of cement and then mill cement out of the tubing down to the tubing tail. 7. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU BOPE and test. 2. Mill cement pilot hole. Set bottom whipstock at 7226' MD. Mill 2.74" window at 7226'. 3. 1E-12 A Lateral a. Drill a 2.70" x 3" bi- center lateral to the northwest at a TD of 9150' MD b. Run the 1375' of 2 %" slotted liner from TD to -7775' MD. An aluminum liner top billet will be placed at 7775' MD. 4. 1E-12 AL1 Lateral a. Kick off of the open -hole aluminum billet at 7775' MD b. Drill a 2.70" x 3" bi- center lateral to the northwest at a TD of 8850' MD c. Run the 1625' of 2%" slotted liner from TD to -7225' MD. A shorty deployment sleeve will be placed at the top of the liner. 5. Window Milling a. Set the second whipstock at -7200' MD b. Mill 2.74" window off this whipstock 6. 1 E -12 A L2 Lateral a. Drill 2.70" x 3" bi- center lateral to the southeast at a TD of 9450' MD b. Run the 1350' of 2%" slotted liner from TD to 8100'. An aluminum liner top billet will be placed at 8100'. 7. 1B-17 L2 -01 Lateral a. Kick off of the aluminum billet at 8100' MD. b. Drill 2.70" x 3" bi- center lateral to the southeast at a TD of 9225' MD • c. Run the -2075' of 2%" slotted liner from TD to just intside the tubing tail (-7150' MD). A shorty deployment sleeve will be placed at the top of the liner. 8. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Page 1 of 3 - ! 1/12/2010 i • Permit to Drill Summary of Operations Cont. KRU 1E -12 A, 1E -12 AL1, 1E -12 AL2, & 1E -12 L2 -01 Post - Rig Work 1. Obtain SBHP 2. Flowback to tanks for well cleanup 3. Begin production Mud Program • Chloride -based Biozan brine (8.6 ppg) for milling operations, and chloride -based Flo -Pro mud (8.6 ppg) for drilling operations. • Kill weight fluid needed while running the completion on this well will be at minimum 11.8 ppg. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. New Completion Details: Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD SSTVD SSTVD 1 E -12 A 7775' 9150' 6287' 6333' 2% ", 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 1 E -12 A L1 7225' 8850' 6231' 6279' 2 , 4.7 #, L -80, ST -L slotted liner; deployment sleeve on top. 1 E -12 A L2 8100' 9450' 6252' 6287' 2 ", 4.7 #, L -80, ST -L slotted liner; aluminum billet on top. 1 E -12 A L2 -01 7150' 9225' 6169' 6232' 2 ", 4.7 #, L -80, ST -L slotted liner; deployment sleeve on top. Existing Completion Details: Wei To Btm To Btm Burst Collapse Category OD ht Grade Connection MD MD TVD TVD psi psi Conductor 16" 65 H -40 Welded 0 80 0 80 1640 630 Surface 10 %" 45.5 K -55 BTC 0 2501 0 2500 3580 2090 Casing 7" 26 L -80 & BTC SML R -3 0 7510 0 6573 4980 4330 K -55 Scab Liner 5'/" 15.5 L -80 511 Hydril 0 6765 0 5959 7000 4990 Tubing 3 %" 9.3 L -80 ABM -EUE 0 7157 0 6280 10160 10540 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid • may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure is 3080 psi assuming a gas gradient to surface based on the highest bottom hole pressure in offset well 1E-15 (3720 psi at 6344' TVD/ 7676' MD on January 4, 2010). • The annular preventer will be tested to 250 psi and 2500 psi. Page 2 of 3 �. 1/12/2010 I ` R S I I Permit to Drill Summary of Operations Cont. KRU 1E -12 A, 1E -12 AL1, 1E -12 AL2, & 1E -12 L2 -01 Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1E-12 A 24650 1E-12 A L1 25050 1E-12 A L2 23450 1E-12 A L2 -01 23800 • Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Offset Well 1E-12 A 500 1E-10 1E-12 A L1 500 1E-10 1E-12 A L2 375 1E-25 1E-12 A L2 -01 550 1 E -25 Logging MWD directional, resistivity, and gamma ray will be run over the entire open - hole sections. Hazards • The most recent H reading on 1E-12 was taken on 09/26/04 and read 15 ppm. The highest H - reading on the 1E pad in 2009 was 130 ppm on well 1E-24A. All H monitoring equipment will be operational while drilling the 1E-12 laterals. • Shale stability is a concern while crossing the A4 /A5 interface as well as at the landing points in the A3. • WOB limitations are a concern and the agitator is expected to be used on the L2 and L2 -01 laterals. • There is a fault crossing in both build sections which could throw sand against shale. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by , using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows for the use of less expensive drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The well will be loaded with overbalanced fluid prior to running the completions. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The target MPD ECD is 11.8 ppg. The reservoir pressure at the first KOP is estimated to be 2,563 psi (7226' MD/ 6337' TVD). Reservoir Pressure Wells 1E-15 and 1E-08 are the primary injection wells that support 1E-12. The most recent static bottom hole pressure readings in each well are as follows: Well name Pressure (psi) SSTVD of Est. Measured Date EMW (ppg) 1E -15 3719 6238 1/4/2010 11.3 1E-08 3021 6218 2/15/2008 9.3 Page 3 of 3 # a_ ! 1/12/2010 a a 9 a ti 1 1E-12 Proposed CTD Sidetrack 3 -1/2" Camco DS nipple @ 482' MD 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 3 -1/2" Camco KBG -2 -9 gas lift mandrels © 2490', 3817', 5088', 6115', 6641' 16 "65 #H- t 40 shoe @ 80' MD 3 -1/2" tubing w/ seals stabbed into 5" joint in the 5 -1/2" scab liner 5 -1/2" scab liner from surface to 6765' MD, seals stabbed into top of FHL PBR 10-3/4" 45.5# K- - 55 shoe @ 2501' Baker 3 -1/2" PBR © 6765' MD • MD Baker FHL packer @ 6779' MD "- '— 3 -1/2" CMU sliding sleeve @ 6926' MD (2.812" min ID) C -sand perfs - Baker F-1 packer @ 7137' MD (2.99" ID) 7010' - 7090' MD Baker SBE @ 7140' MD a _ 3 - 1/2" Camco D landing nipple @ 7155' MD (2.75" min ID, No -Go) 3 -1/2" tubing tail @ 7156' MD 1 Top of cement at KOP #2 at 7200' MD 1 I tubing tail at 7155' MD AL2 01 Lateral (A5 sand, southeast) KOP #1 at 7226' MD \ TD = 9225' - NW Baker monobore whipstock trays \ \ 1 Liner top at 7150' o • n openhole anchors at 7208' & \ 7234' �,\ — — — AL2 Lateral (A4 sand, southeast 2.80" pilot hole in cement drilled ----, _ — TD = 9450' ( ) to 7275' MD e — 7_,. j Billet at 8100' !i —— - -— ) A sand perfs N� �, AU Lateral (A5 sand, northwest) (sgz'd) 7200' - 7259' MD TD = 8850' . , Liner top at 7225' 7" 26# J-55 shoe A Sidetrack (A4 sand, Northwest) ..1.N. >� TD = 9150' @ 7510' MD Billet at 7775' ._moo • Nov Conoch liii s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-12 1 E- 12AL2 -01 Plan: 1 E- 12AL2 -01 wp04 Standard Planning Report 05 January, 2010 BAKER HUGHES k III III r 1,..- ConocoPhillips ICA11 ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1E-12 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-12 © 105.70ft (1E-12) ° Site: Kuparuk 1E Pad North Reference: True Well: 1E-12 Survey Calculation Method: Minimum Curvature Wellbore: 1 E- 12AL2 -01 Design: 1 E- 12AL2 -01 wp04 Project aruk River Unit olect P Ku Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70° 18' 3.022 N From: Map Easting: 549,889.51 ft Longitude: 149° 35' 45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38 ° Well 1E-12 Well Position +NI-S 0.00 ft Northing: 5,960,390.22 ft • Latitude: 70°18' 9.229 N +El -W 0.00 ft Easting: 549,710.20 ft • Longitude: 149° 35' 50.464 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Welibore 1 E- 12AL2 -01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) - (°) . - -- (nT) _ - BGGM2009 3/4/2010 17.35 79.80 57,369 Design 1 E- 12AL2 -01 wp04 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,100.00 Vertical Section: - Depth From (TVD) +NI-S +E/ -W Direction (ft) ( (ft) (°) -71.10 0.00 0.00 149.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination : Azimuth System +NL$ +E! W Rate Rate Rate TFO (ft) (°) el (ft) (ft) (ft) (° /100ft) (1100ft) rt100tt) (°) Target 8,100.00 90.94 178.24 6,251.64 1,586.83 - 1,474.50 0.00 0.00 0.00 0.00 8,150.00 98.44 178.24 6,247.56 1,537.06 - 1,472.98 15.00 15.00 0.00 0.00 8,170.00 101.03 176.72 6,244.18 1,517.37 - 1,472.11 15.00 12.97 -7.64 330.00 8,200.00 98.89 172.70 6,238.99 1,487.96 - 1,469.38 15.00 -7.13 -13.40 242.00 8,400.00 91.79 143.40 6,219.97 1,305.53 - 1,395.53 15.00 -3.55 -14.65 258.00 8,550.00 91.73 120.89 6,215.31 1,205.57 - 1,285.08 15.00 -0.04 -15.01 270.20 8,775.00 90.05 154.60 6,211.72 1,041.44 - 1,136.00 15.00 -0.75 14.98 92.50 8,890.00 86.66 171.53 6,215.05 931.90 - 1,102.63 15.00 -2.95 14.72 101.50 9,225.00 87.86 121.23 6,232.18 662.22 - 923.20 15.00 0.36 -15.01 270.00 1/5/2010 9:27:29AM Page 2 COMPASS 2003.16 Build 69 III r,-` • ConocoPhillips ralgill ConocoPh Planning Report HUGHES Alaska Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1E-12 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1E -12 © 105.70ft (1E -12) Site: Kuparuk 1E Pad North Reference: True Well 1E-12 Survey Calculation Method: Minimum Curvature Wellbore: 1 E- 12AL2 -01 Design: 1 E- 12AL2 -01 wp04 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth inclination Azimuth - - System +N i -S + N Section - Rate Azimuth Northing - Easting (ft) (°) (°) (ft) (ft) (ft) (ft) ( °tl0Oft) - - ( °) (f*) (ft) 8,100.00 90.94 178.24 6,251.64 1,586.83 - 1,474.50 - 2,119.61 0.00 0.00 5,961,967.11 548,225.37 TIP / KOP 1 E -12AL2 8,150.00 98.44 178.24 6,247.56 1,537.06 -1,472.98 -2,076.16 15.00 0.00 5,961,917.35 548 , 227.23 2 8,170.00 101.03 176.72 6,244.18 1,517.37 - 1,472.11 - 2,058.83 15.00 -30.00 5,961,897.67 548,228.22 3 8,200.00 98.89 172.70 6,238.99 1,487.96 - 1,469.38 - 2,032.22 15.00 - 118.00 5,961,868.28 548,231.15 4 8,300.00 95.52 157.96 6,226.38 1,392.28 - 1,444.29 - 1,937.28 15.00 - 102.00 5,961,772.78 548,256.88 8,400.00 91.79 143.40 6,219.97 1,305.53 - 1,395.53 - 1,837.81 15.00 - 103.86 5,961,686.36 548,306.19 5 8,500.00 91.78 128.39 6,216.85 1,233.96 - 1,326.17 - 1,740.74 15.00 -89.80 5,961,615.26 548,376.02 8,550.00 91.73 120.89 6,215.31 1,205.57 - 1,285.08 - 1,695.25 15.00 -90.27 5,961,587.15 548,417.29 6 8,600.00 91.39 128.38 6,213.95 1,177.19 - 1,243.99 - 1,649.75 15.00 92.50 5,961,559.04 548,458.57 8,700.00 90.64 143.37 6,212.18 1,105.62 - 1,174.58 - 1,552.65 15.00 92.70 5,961,487.93 548,528.44 8,775.00 90.05 154.60 6,211.72 1,041.44 - 1,136.00 - 1,477.77 15.00 92.97 5,961,424.02 548,567.45 7 8,800.00 89.30 158.28 6,211.87 1,018.53 - 1,126.01 - 1,452.99 15.00 101.50 5,961,401.18 548,577.59 8,890.00 86.66 171.53 6,215.05 931.90 - 1,102.63 - 1,366.69 15.00 101.48 5,961,314.71 548,601.54 8 8,900.00 86.66 170.02 6,215.64 922.04 - 1,101.03 - 1,357.42 15.00 -90.00 5,961,304.87 548,603.20 9,000.00 86.79 155.00 6,221.38 827.10 - 1,071.11 - 1,260.62 15.00 -89.91 5,961,210.13 548,633.75 9,100.00 87.15 139.98 6,226.69 743.13 - 1,017.59 - 1,161.08 15.00 -89.05 5,961,126.53 548,687.81 9,200.00 87.70 124.98 6,231.21 675.86 - 944.13 - 1,065.58 15.00 -88.25 5,961,059.75 548,761.71 9,225.00 .. 87.86 121.23 6,232.18 • 662.22 - 923.20 - 1,043.12 15.00 -87.57 5,961,046.25 548,782.72 TD 1/5/2010 9:27:29AM Page 3 COMPASS 2003.16 Build 69 PP IN AL • r-� ConocoPhillips id I ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 E -12 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E -12 © 105.70ft (1E -12) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E -12 Survey Calculation Method: Minimum Curvature Welibore: 1E-12AL2-01 Design: 1 E 12AL2 - 01 wp04 Targets Target Name - hit/miss target D ip Angle Dip Dir. TVD +Nl-S +E/-W Northing Easting - Shape (°) (') (ft) (R) (ft) (ft) (ft) Latitude Longitude 1E- 12AL2 -01 t2.4 0.00 0.00 6,211.00 1,049.17 - 1,148.13 5,961,431.67 548,555.27 70° 18' 19.547 N 149° 36' 23.944 W - plan misses target center by 7.50ft at 8762.12ft MD (6211.75 TVD, 1052.99 N, - 1141.72 E) - Point 1E -12AL2 Polygon 0.00 0.00 0.00 1,759.81 - 1,686.48 5,962,138.66 548,012.28 70° 18' 26.535 N 149° 36' 39.648 W - plan misses target center by 6241.92ft at 8300.00ft MD (6226.38 TVD, 1392.28 N, - 1444.29 E) - Polygon Point 1 0.00 1,759.81 - 1,686.48 5,962,138.66 548,012.28 Point2 0.00 1,962.34 - 1,763.16 5,962,340.66 547,934.27 Point 3 0.00 2,173.57 - 1,642.76 5,962,552.66 548,053.26 Point 4 0.00 2,162.04 - 1,409.81 5,962,542.67 548,286.26 Point 5 0.00 1,984.28 - 1,296.96 5,962,365.68 548,400.27 Point 6 0.00 1,534.31 - 1,309.92 5,961,915.68 548,390.29 Point 7 0.00 509.13 - 539.55 5,960,895.72 549,167.35 Point 8 0.00 229.86 -655.40 5,960,615.71 549,053.36 Point 9 0.00 381.88 - 960.44 5,960,765.70 548,747.35 Point 10 0.00 1,370.37 - 1,627.03 5,961,749.66 548,074.30 Point 11 0.00 1,851.93 - 1,550.86 5,962,231.66 548,147.27 Point 12 0.00 1,774.44 - 1,629.38 5,962,153.66 548,069.28 Point 13 0.00 1,759.81 - 1,686.48 5,962,138.66 548,012.28 1E- 12AL2 -01 t1.4 0.00 0.00 6,220.00 1,337.69 - 1,373.24 5,961,718.66 548,328.27 70° 18' 22.384 N 149° 36' 30.510 W - plan misses target center by 36.99ft at 8382.87ft MD (6220.61 TVD, 1319.49 N, - 1405.44 E) - Point 1E- 12AL2 -01 t3.4 0.00 0.00 6,232.00 670.62 - 920.61 5,961,054.67 548,785.26 70° 18' 15.824 N 149° 36' 17.308 W - plan misses target center by 8.53ft at 9222.57ft MD (6232.09 ND, 663.48 N, - 925.27 E) - Point 1E- 12AL2 -01 KOP 0.00 0.00 6,252.00 1,587.38 - 1,474.60 5,961,967.66 548,225.27 70° 18' 24.840 N 149° 36' 33.468 W - plan hits target center - Point 1E -12AL2 fault 3 0.00 0.00 0.00 1,317.85 - 1,549.39 5,961,697.67 548,152.27 70° 18' 22.189 N 149° 36' 35.647 W - plan misses target center by 6221.35ft at 8479.49ft MD (6217.48 ND, 1247.12 N, - 1341.89 E) - Polygon Point 1 0.00 1,317.85 - 1,549.39 5,961,697.67 548,152.27 Point 2 0.00 1,303.45 - 1,336.30 5,961,684.68 548,365.43 Point 3 0.00 1,295.94 - 1,106.48 5,961,678.69 548,595.28 Point4 0.00 1,303.45 - 1,336.30 5,961,684.68 548,365.43 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (R) Name ( ) 9,225.00 6,232.18 2 -3/8" 2 -3/8 3 1/512010 9 :27:29AM Page 4 COMPASS 2003.16 Build 69 + III • r 1,•' ConocoPhillips ® /.f ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1E-12 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: - 1E -12 @ 105.70ft (1E -12) Site: Kuparuk 1 E Pad North Reference: True Welk 1E-12 Survey Calculation Method: Minimum Curvature Wellbore: 1 E- 12AL2 -01 Design: 1 E- 12AL2- 01_wp04 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E(-W (ft) (ft) (ft} (ft) Comment 8,100.00 6,251.64 1,586.83 - 1,474.50 TIP / KOP 1E -12AL2 8,150.00 6,247.56 1,537.06 - 1,472.98 2 8,170.00 6,244.18 1,517.37 - 1,472.11 3 8,200.00 6,238.99 1,487.96 - 1,469.38 4 8,400.00 6,219.97 1,305.53 - 1,395.53 5 8,550.00 6,215.31 1,205.57 - 1,285.08 6 8,775.00 6,211.72 1,041.44 - 1,136.00 7 8,890.00 6,215.05 931.90 - 1,102.63 8 9,225.00 6,232.18 662.22 - 923.20 TD 115/2010 9:27 :29AM Page 5 COMPASS 2003.16 Build 69 r)Pfriki Al Rf AxmmAhStoTrue North WELLBORE DETAILS: 1E- 12AL2 -01 REFERENCE INFORMATION /�°- Project: Kuparuk River Pad nit roagneto Nmh:21,85• rrir I Site: Kuparuk 1E Pad MegnetbrieW Parent Wellbore: 1E -I2AL2 Co•ordinate(NIE) Reference: Well 1E-12, True North �/� Fr Well: 1E -12 Slrenut:576553snT Tie on MD: 8100.00 Vertical (TVD) Reference: Mean Sea Level BARER Con Wellbore: 1E - 12AL2.01 :80 84 Section (VS}Reference: Sbf•(O.00N, O.DOE) /� t! ngleWlaio Measured Depth Reference 1E•12 105.7011 (tE -12) o'co "1 fillips Plan: 9E- 12AL2. re: 1E -12AL E•12AL2 -01) Dip Anasnmaetec[xa2ma Calculation Method. MmimumCuvature HUGHES 1800- 2222. 1700-- -- -.._ -- -- _.. -__.- - - -- - - - - -- ° ___ --- WELL DETAILS: 1E - 12 TIP; KOPIB - I2AL2 1 Ground Level: 0.00 1600 - - ___._ ___ +NI •S +E / -W Northing Easting Latittude Longitude Slot 2 0.00 0.00 5960390.22 549710.20 70° 18' 9.229 N 149° 35' 50.464 W 3 - 1500___ _. -___ - \1 _ -_ SECTION DETAILS ANNOTATIONS 4 \ 1400 I Sec MD Inc Azi TVD +NI -S +E/ -W DLeg TFace VSec Target Annotation -1474.50 0.00 0.00 -2119.61 TIP /KOP1E -12AL2 1 8100.00 90.94 17824 6251.64 1586.83 I 1 1300 - - ±- -.__ -.. ..--- -- - - - - - - -_ .- ..____ -.- - - - - -'- 2 8150.00 98.44 17824 6247.56 1537.06 - 1472.98 15.00 0.00 - 2076.16 2 - 3 8170.00 101.03 176.72 6244.18 1517.37 - 1472.11 15.00 330.00 •2058.83 3 4 8200.00 98.89 172.70 6238.93 5487.96 1469.38 95.00 242.00 -2032.22 4 ^ 1200 5' - I 5 8400.00 91.79 143.40 6219.97 1305.53 - 1395.53 15.00 268600 - 1837.81 5 6 8550.00 91.73 120.89 6215.31 1205.57 -1285.08 15.00 270.20 -1695.25 6 01100 Nt. 7 8775,00 90.05 155.60 6211,72 1041.44 •1136.00 15.00 92.50 - 1477.77 7 6 - ' 8 8890.00 86.66 171.53 6215.05 931.90 -1102.63 15.00 101.50 -1366.69 8 ( - ' 9 9225.00 87.86 12123 6232.18 66222 -92320 15.00 270.00 - 1043.12 TD -1 - -. .__. - - --_- -_ j 1 - -__ 7 2_2 - - - -- - O 900 - --- � - -1 " - D 800 - 2222 --- - --- - -- 8 I1/ 0 700 - - - -- - - - . - -- - - - --- - - -- 600 • 7D ......■., - I 11. -12 IL 1 -01 ��_ . -._ soo ± . , 400 - - - - -- - - -- - - - -F i _ -_ - ---- - - -_.. - - -_ -_+ _ 300 - -- -- - - -- - - - --- - - - - - - -- !.._ - -1r 1211 12AI2 , - - -- - -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 600 ' - - -- W est(-)/East( +) (100 ft/in) 604 -- - - -- -- -- - -- - --- - -- --- - -' - - ---- --- 4 ■ I 6080 - - - - t _. i T W 6120- - - -- - - -- I y - -- - - -- - - - - - -- ' .. i ' .. 6160: - --r - 'N 7 TIlk`KOP(E I2AL2 6 8 --, - ' - -_... 11 _ 6200 - -r- 5 6240 - -. _ _ - - - -- - - - -- -- - -- ---._ _.. _ - - ---. -. -- - ----t- - Si ` __ U n ( r 628 63 T �_ - ___-, 20 1 - - 1 F . - E -12 '1 E IAL2 -01 - - - 1 12/IE 12.012 6360} - -_ - - - 6400 , I 6440 --t - I I I ( -2240 -2200 -2160 -2120 -2080 -2040 -2000 -1960 -1920 -1880 -1840 -1800 -1760 -1720 -I680 -1640 -1600 -1560 152.0 -1480 -1440 -1400 -1360 -1 -1240 -1200 -1160 -1120 -1080 - 1040 -1000 -960 -920 -880 -840 -800 -760 -720 Vertical Section at 149.00° (40 ft/in) • • Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N Lubricator t Riser \AnnuIar Blind / Shear 2" Pipe / Slip (CT) Pump into Lubricator J ,.. ■ above BHA rams - 10 7 Choke 1 11 2 -3/8" Pipe / Slip (BHA) IN Choke Equalize Manifold 11 2 -3/8" Pipe / Slip (BHA) ' J L J -- L Kill ► > >C Q ► fir , = III 1 r Blind / Shear I ' 2" Pipe / Slip (CT) I' 11 Choke 2 11 Swab Valves ." al Wing Valves �Q ^ Tree Flow Cross 1 r 4 Surface Safety Valve BOPE: 7- 1/16 ", 5M psi, TOT Choke Line: 2- 1/16 ", 5M psi XI Master Valve Kill Line: 2- 1/16 ", 5M psi Equalizing Lines: 2- 1/16 ", 5M psi Choke Manifold: 3 -1/8 ", 5M psi Riser. 7- 1/16 ", 5M psi, C062 Union QR'GN • • TRANSMITTAL LETTER CHECKLIST WELL NAME Kuparuk River Unit 1E- 12L2 -01 PTD# 2100070 X Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: KUPARUK RIVER OIL KUPARUK RIVER P OOL: POOL Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well Kuparuk River Unit 1E -12, Permit No. 1820600, X (If last two digits in API No. 50 -029- 20736- 00 -00. Production should continue to API number are be reported as a function of the original API number stated above. between 60 -69) PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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 program. Rev: 1/11/2008 , t. Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 1E-12L1-01 Program DEV -- — -- Well bore seg MI PTD #:2100050 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type DEV / PEND GeoArea 890 Unit 11160 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Top prod interval & TD in ADL 025651. 13 Unique well name and number Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 5 miles 7 Sufficient acreage available in drilling unit Yes from an external property line where ownership or landownership changes. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes SFD 1/21/2010 I 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA • 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.0306.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor casing set in 1E-12 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 1E-12 120 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 1 E -12 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 1 E -12 22 CMT will cover all known productive horizons No OH slotted liner completion 23 Casing designs adequate for C, T, B & permafrost Yes 1 24 Adequate tankage or reserve pit Yes Rig equipped with steel Pits. All waste to approved disposal wells._ 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 310 -005 26 Adequate wellbore separation proposed Yes Proximity analysis performed . No issues. 1 27 If diverter required, does it meet regulations NA Wellhead and tree in place. BOP Stack installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max Fm pressure = 2563 psi (7.77 ppg EMW) Will drill with 8.6 ppg mud utilizing MPD for shale control. GLS 1/22/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 1909 psi Will test BOP to 3500 psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1E pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 7.8 ppg. This wellbore will be drilled using coiled tubing Appr Date 37 Seismic analysis of shallow gas zones NA tubing and 8.6 ppg with Managed Pressure Drilling Techniques to maintain downhole pressure of SFD 1/21/2010 1,38 Seabed condition survey (if off - shore) NA 11.8 ppg ECD. 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering P • lic Spoke development wellbore targeting Kuparuk A -5 sand. Date: Date Date Commissioner: Commissioner: Co . • � _ / Z —/D
