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210-015
New Plugback Esets 6/24/2024 Well Name API Number PTD Number ESet Number Date 1E-15AL2 PB1 50-029-20769-70-00 210-015 T38990 6-17-2010 1E-15AL2 PB2 50-029-20769-71-00 210-015 T38991 6-17-2010 1E-15AL2 PB3 50-029-20769-72-00 210-015 T38992 6-17-2010 3N-16A PB1 50-029-21593-70-00 210-049 T38993 7-8-2010 3N-16A PB2 50-029-21593-71-00 210-049 T38994 7-8-2010 3N-16A PB3 50-029-21593-72-00 210-049 T38995 7-8-2010 CD4-27 PB1 50-103-20644-70-00 211-146 T38996 6-14-2012 CD4-27 PB3 50-103-20644-72-00 211-146 T38997 6-14-2012 ODST-46 PB1 50-703-20631-70-00 210-183 T38998 5-10-2011 ODST-46 PB2 50-703-20631-71-00 210-183 T38999 5-10-2011 ODST-46 PB3 50-703-20631-72-00 210-183 T39000 5-10-2011 W-19AL1 PB1 50-029-22006-70-00 202-235 T39001 6-10-2003 W-19AL1 PB2 50-029-22006-71-00 202-235 T39002 6-10-2003 1E-15AL2 PB1 50-029-20769-70-00 210-015 T38990 6-17-2010 1E-15AL2 PB2 50-029-20769-71-00 210-015 T38991 6-17-2010 1E-15AL2 PB3 50-029-20769-72-00 210-015 T38992 6-17-2010 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a I 0 - S.JJ 5 Well History File Identifier Organizing (done) " Two-sided III 1111111111111111 ❑ Rescan Needed 11 111111 1111111 7 AN DIGITAL DATA OVERSIZED (Scannable) or Items: ❑Diskettes, No. ❑Maps: Greyscale Items: ❑Other, No/Type: ❑ Other Items Scannable by $Ctik a Large Scanner Poor Quality Originals: U, OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: o BY: Mari Date: /s/ 4 P Project Proofing III IIIIIIIIIII 11111 BY: Maria Date: 0,., a,g f / /s/ at P Scanning Preparation 42. x 30 = la 0 + / = TOTAL PAGES 74 '. ( Count does n i nclude cover sheet) p BY: Date: a,, , 8 /s/ 1 Production Scanning 111111111111011111 Stage 1 Page Count from Scanned File: 7 (Count does include cover sheet) Page Count Matches Number in Scanning Prep ration: 1, NO BY: AV Date: l . � /d"' v I I /s/ I JJ imp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III 111111 11111 I ReScanned 11IIIIIIIIIII 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III I 1 2/22/201 1 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 10120/2011 Permit to Drill 2100150 Well Name /No. KUPARUK RIV UNIT 1E -15AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50 -029- 20769 -61 -00 MD 10085 TVD 6425 Completion Date 4/20/2010 Completion Status 1WINJ Current Status WAGIN IC Y REQUIRED INFORMATION Mud Log No Samples No Directional Sury Yes 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 / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments .- ED C Lis 19776•-•11iduction /Resistivity 7363 10101 Open 6/17/2010 EWR LIS plus PDF, CGM, and TIFF Graphics g Induction /Resistivity 2 Col 7557 10085 Open 6/17/2010 MD MPR, GR ''Cog Induction /Resistivity 5 Col 7557 10085 Open 6/17/2010 MD MPR, GR I ✓Co - g Induction /Resistivity 5 Col 7557 10085 Open 6/17/2010 TVD MPR, GR C Lis 19776 Eduction /Resistivity 7363 9836 Open 6/17/2010 PB1 EWR LIS plus PDF, CGM, and TIFF Graphics IJcog Induction /Resistivity 2 Col 7557 9836 Open 6/17/2010 PB1 MD MPR, GR Leg Induction /Resistivity 5 Col 7557 9836 Open 6/17/2010 PB1 MD MPR, GR Log Induction /Resistivity 5 Col 7557 9836 Open 6/17/2010 PB1 TVD MPR, GR .„,.--' ED C Lis 19776 —I11 uction /Resistivity 7363 10136 Open 6/17/2010 PB2 EWR LIS plus PDF, CGM, and TIFF Graphics III og Induction /Resistivity 2 Col 7557 10135 Open 6/17/2010 PB2 MD MPR, GR og Induction /Resistivity 5 Col 7557 10135 Open 6/17/2010 PB2 MD MPR, GR g Induction /Resistivity 5 Col 7557 10135 Open 6/17/2010 PB2 TVD MPR, GR C Lis 19776 l uction /Resistivity 7363 9710 Open 6/17/2010 PB3 EWR LIS plus PDF, ! I CGM, and TIFF Graphics -l!6g Induction /Resistivity 2 Col 7557 9710 Open 6/17/2010 PB3 MD MPR, GR "fig Induction /Resistivity 5 Col 7557 9710 Open 6/17/2010 PB3 MD MPR, serig Induction /Resistivity 5 Col 7557 9710 Open 6/17/2010 PB3 TVD MPR, GR 1,RD C Asc Directional Survey 7830 10085 Open tpt Directional Survey 7830 10085 Open C Asc Directional Survey 7500 9836 Open PB1 t Directional Survey 7500 9836 Open PB1 DATA SUBMITTAL COMPLIANCE REPORT 10/20/2011 Permit to Drill 2100150 Well Name /No. KUPARUK RIV UNIT 1E -15AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 029 - 20769 -61 -00 MD 10085 TVD 6425 Completion Date 4/20/2010 Completion Status 1WINJ Current Status WAGIN UIC Y -el C Asc Directional Survey 8830 10135 Open PB2 .rl/pt Directional Survey 8830 10135 Open PB2 D C Asc Directional Survey 8200 9710 Open PB3 Rpt Directional Survey 8200 9710 Open PB3 Well Cores /Samples Information: Sample • Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Daily History Received? Q/ N Chips Received? Formation Tops `f l Analysis Y Received? Comments: Compliance Reviewed By: Date: 1, III • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS d REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other PI PROD to WAG Alter Casing r Pull Tubing r Perforate New Fool [ i Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F7 Exploratory r 210 -015 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service ❑ 50 - 029 - 20769 - 7. Property Designation: 8. Well Name and Number: ADL 25651 1 E -15AL2 9. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool • 10. Present Well Condition Summary: Total D epth measured 10085 feet Plugs (measured) None true vertical 6425 feet Junk (measured) None Effective Depth measured 10085 feet Packer (measured) 7322, 7663 true vertical 6425 feet (true vertucal) 6066, 6330 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 112 112 0 0 SURFACE 2163 10.75 2193 2193 0 0 WINDOW AL2 -01 7 8 7565 6151 0 0 WINDOW AL1 8 8 7641 6316 0 0 PRODUCTION 8380 7 8410 6916 0 0 LINER AL2 2356 2.625 10058 6425 0 0 Perforation depth: Measured depth: Slots: 7702 -10057 True Vertical Depth: 6381 -6421 Tubing (size, grade, MD, and TVD) 3.5, J -55, 7682 MD, 6340 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 322 and 6066 TVD ~ , r { f Zl� PACKER - BAKER FB -1 PACKER @ 7663 MD and 6330 TVD g 100 SAFETY VLV - CAMCO TRDP -1A @ 1878 MD and 1878 TVD Mk -4118 ' 61a 11. Stimulation or cement squeeze summary: theme Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 231 462 1107 850 194 Subsequent to operation 1877 700 73 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WAG r GASINJ r WINJ I i SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -309 Contact Bob Christensen /Darrell Humphrey Printed Name bert D. Christensen Title Production Engineering Specialist Signature , - =- 4 Phone: 659 - 7535 Date l Q Form 10-404 Revised 7/2009 RBDMS SEP 3 0 Z1�� 3 Sub It Original Onfy ' " • t 1 E -15AL2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/29/10 TAGGED LINER TOP @ 7546' SLM. MEASURED SBHP @ 7400' RKB (2215 PSI) & GRADIENT © 7273' RKB (2211 PSI) SET SS CATCHER @ 3825' RKB. PULLED GLV @ 1948' RKB & OV @ 3690' RKB. IN PROGRESS. 08/31/10 SET DV @ 1948' RKB. PULL CATCHER @ 3825' SLM (PACKED W/ SCALE) BULLHEAD 125 BBLS DIESEL DN IA. SET DMY @ 3690' RKB. MITIA 3000 PSI (PASS) COMPLETE. 09113/10 'Commenced Water Injection Service 09/20/10 IPRE STATE WITNESSED MIT -IA ( PASSED) 09 /21 /101STATE WITNESSED ( JOHN CRISP) MIT -IA ( PASSED ). '14 4 KUP • 1E -15AL2 ConocoPhillips 0 Well Attributes !Max Angle & MD TO Al .74k 1, II1■ Wel!bore API(UWI Field Name Well Status Inc' (°) MD (MB) Act 81m (ft148) Conowr4alips 500292076961 KUPARUK RIVER UNIT INJ 95.56 8,800.49 10,085.0 Comment H25 (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date ••• Well ConM19'. - IE- 15AL2, 91620104.19:38 PM — SSSV: TRDP Last WO: 40.71 8/4/1982 schematic - Actual Annotation Depth (11(8) End Date Annotation Last Mod... End Date Last Tag: SLM Rev Reason: GLV C/O lmosbor 9/6/2010 Casing Strings Casing Description String 0... String ID ... Top (1tKB) Set Depth (1... Set Depth (TVD) ... String Wt.. String ... String Top Thrd • Liner AL2 (off 2 5/8 1.995 7,728.6 10,085.0 6,424.7 4.60 L-80 STL AL2 -01) Liner Details Top Depth (TVD) Top Inc! Nomi... CONDUCTOR, Top (81(8) (RK8) 1 °) Item Description Comment ID (in) 3za1s 7,728.6 6,400.0 49.19 DEPLOY Deployment Sleeve Baker 1.995 SAFETY vLV, o Perforations & Slots 1,878 Shot Top (TVD) 8trr1 (TVD) Dens Top (Po(B) Btm (ftKB) (11(8) (111(8) Zone Data (eh... Type Comment G' 1 1949 7,702 10,057 6,381.3 6,421.1 4/13/2010 32.0 Slots Altemating solid /slotted pipe - . 0.125'x2.5" @ 4 circumferential SURFACE, adjacent rows, 3" centers staggered 30-2.193 18 deg, 3' non - slotted ends GAS LIFT, Notes: General & Safety 3,590 End Date Annotation 4/20/2010 NOTE: SIDETRACK w ATERALS 1E-15A, 15AL1, 15AL2, 15AL2 -01 4/20/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GA5 LIFT, 5,219 GAS LIFT.. 6.256 III GAS LIFT, 6,291 - ... �- GAS LIFT. 7.272 PBR, 7,307 PACKER, 7,322 [ INJECTION, 7,369 INJECTION, 1 7,425 j r 1 t WHIPSTOCK, 7,557 WINDOW AL 75567,565 1 7.5431 1 INJECTION, I 'e 7592 PRODUCTION. 366,410 \ - 5bb, 8,0628,811 5bb, -- 7,868 -9,764 Liner ALT k - - r 7,8238,812 Slob, 7,702 -10557 Liner AL2 -01 (off main eel- 7e), 1 7,542-99,59 7 I Mandrel D Details Top e Top Port (T V D ) Mel Valve Latch Sir TRO Run Stn Top (we) ( 8 ) (') Make Model ( In) Sery Type Type ( Iwil Run Date Com... 1 1,948.5 1,948.4 1.46 CAMCO KBUG 1 GAS LIFT DMY BK 0. 000 0.0 8/31/2010 1 I 2 3,690.5 3,504.9 46.84 CAMCO KBUG 4 6,255.6 5,252.2 43.86 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8131/2010 3 5,218.8 4,525.2 45.86 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 I 1 GAS LIFT DMY BK 0.000 0.0 11/5/1984 I 1 5 6,291.2 5,277.8 43.53 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/311990 6 7,271.9 6,027.0 37.97 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 7 7,359.0 6,095.5 38.22 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 8 7,425.4 6,147.7 38.44 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 Liner AL2 (off AL2 - 0+), 9 7,592.1 6,278.3 38.42 CAMCO KBUG 1 )NJ DMY BK 0.000 0.0 7/20/1993 7,729- 10,085 TD (1 E- 15AL2), 10,065 • • Li [E [F [1. tal-A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Darrell R. Humphrey Production Engineering Specialist I ConocoPhillips Alaska, Inc. g.,10 - P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1E-15AL2 Sundry Number: 310 -309 Dear Mr. Humphrey: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this I day of September, 2010. Encl. r • - . STATE OF ALASKA £0' (fl ��; ' 41. A O ALASKA OIL AND GAS CONSERVATION COMMISSIO A,P ,� APPLICATION FOR SUNDRY APPROVALS oke 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend Ti Rug Forforations r Perforate r Pull Tubing ❑ lime Extension r Operational Shutdown r Re -enter Susp. Well Ti Stimulate r Alter casing r Other:PROD to WINJ I ! • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J1 Exploratory r 210 -015 • 3. Address: Stratigraphic r service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20769 -61 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1E -15AL2 . 9. Property Designation: 10. Field /Pool(s): ADL 25651 Kuparuk River Field / Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10085 ` 6425 • 10085' 6420' none none Casing Length Size MD TVD Burst Collapse LINER AL2 2356 2.625 10058' 6420' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7702 -10057 6378 -6420 0 0 0 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) none none 12. Attachments: Description Summary of Proposal f 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/22/2010 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GIN r WA Ti Abandoned Ti Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Darrell Humphrey Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature a,',. Phone: 659 -7535 Date ct , Is. to Commission Use Only Sundry Number: 310 35? Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test F./Location Clearance r RECI Other: VED SEP 1 7 2010 Subsequent Form Required: /) . - o & f at Cl Gara , issron APPROVED BY ) Y� Approved by: 7 COMMISSIONER THE COMMISSION D ate: ! t i 11131 14, SEP,(21 , �i , , r " ` �,-_ ., • 1.1 Form 10 -403 Revised 1/2010 - 1 ,, i k 11 L • •Z° " -6 Submit in i / i 1 E -15AL2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 1E -15 from Oil Production .r service to Water Injection service.Well 1E -15A CTD was completed in the Kuparuk formation on April 23, 2010 as a pre - producing in'e�ct .with initial production commencing on May 31, 2010. Conversion to Injection service is required due to potential reservoir depletion. Well 1E -15A injection will provide pressure support to offset producers 1E -12, 1F -06, 1F -14 and 1F -19. The 16" Conductor was cemented with 326sx of AS II. The 10 -3/4" Surface casing (2193' and / 2193' tvd) was cemented with 1025sx AS III and 250sx AS II. The 7" Production casing (8410' and / 6916' tvd) was cemented with 605 sx Class "G ". The top of the Kuparuk B1 was found at 7665' and / 6331' tvd. The top of the Kuparuk A6 was found at 7738' and / 6364' tvd. The top of the Kuparuk A5 was found at 7763' and / 6375' tvd. The top of the Kuparuk A4 was found at 9322' and / 6365' tvd. The USIT CBL performed on March 11, 2010 indicates good continuous formation quality bond from 7460' and (6175' tvd) to 7580' and (6269' tvd). The injection tubing/casing annulus is isolated via Baker FHL Packer 6.151" OD x 2.94" ID located @ 7322 and / 6066' tvd. An MIT -IA was last performed on 8/31/10; MITIA 3000 psi, 15 minutes, Passed. MITIA 3000 PSI (PASS) COMPLETE. Initial T/I/O= 1600/0/330: Start T/I/O= 1600/3000/360: 15min. reading T/I/O= 1600/2910/360: 30min. reading T /I/O= 1600/2890/360 KUP • 1 E -15AL2 ConocoPhillips 0 Well Attributes Max Angle & MD TD Alaska, Inc. Wel!bore API /UWI Field Name Well Status Inc! (°) MD MKS) At etm (ft(8) CpwmFWilton 500292076961 KUPARUK RIVER UNIT INJ 95.56 8,800.49 10,085.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: TRDP Last WO: 40.71 8/4/1982 Well Conks - 1E- 15AL2, 9/62910 19: 38 PM 1 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM Rev Reason: GLV C/O Imosbor 9/6/2010 4 ii. Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ._ String Wt... String ... String Top Thrtl 4UnerAL2(off 25/8 1.995 7,728.6 10,085.0 6,424.7 4.60 L - 80 STL Komi... AL2 -01) Liner Details Top Depth (TVD) Top Incl • CONDUCTOR, Top (ftKB) IftKB) ( °) Item Description Comment ID (in) 32 7,728.6 6,400.0 49.19 DEPLOY Deployment Sleeve Baker 1.995 SAFETY VLV, sa Perforations & Slots 1,876 Shot Top (TVD) Btm (TVD) Dens Top (RKB) Btm (ttKB) (ftKB) (ftKO) Zone Date (oh... Type Comment GAS LIFE, It 7,949 7,702 10,057 6,381.3 6,421.1 4/13/2010 32.0 Slots Altemating solid/slotted pipe - 0.125'x2.5" @ 4 circumferential SURFACE, adjacent rows, 3" centers staggered 30 18 deg, 3' non - slotted ends GAS LIFT, Notes: General & Safety 1 3,690 End Date Annotation IIII 4/20/2010 NOTE: SIDETRACKw/LATERALS 1E -15A, 15AL1, 15AL2, 15AL2 -01 4/20/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS UFT, 5,218 r al GAS LIFT, 6,256 GAS LIFT, I.; . 6,291 GAS LIFT, 7,272 708, 7,307 PACKER, 7,322 is I r 4 INJECT1,3ION, 6 59 INJECTION, II t . 7,425 I( l ■ WHIPSTOCK 7,557 WINDOW AL2 -01, 7,559-7,565 Slob, 7,543-7,609 MINN INJECTION, = 7,592 me I‘ , PRODUCTION, 30A,410 Slots, 9.062.8,611 sole, 7,666 -9,764 Liner AL1. 7,623$812 Slots, 7,702-10,057 Liner AL2 -01 (off main lbor 7,542 -9,765 IL Mandrel Details Top O Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (16(8) MD) B) 11 Make Model (In) Sery Type Type (in) (psi) Run Date Con... 1 1,948.5 1,948.4 1.46 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/31/2010 2 3,690.5 3,504.9 46.84 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/31/2010 3 5,218.8 4,525.2 45.86 CAMCO KBUG 1 GAS LIFT DMY $K 0.000 0.0 6/5/1990 I ' 4 6,255.6 5,252.2 43.86 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/5/1984 5 6,291.2 5,277.8 43.53 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/3/1990 6 7,271.9 6,027.0 37.97 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 7 7,359.0 6,095.5 38.22 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 8 7,425.4 6,147.7 38.44 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 Liner AL2 (off AL2 9 7,592.1 6,278.3 38.42 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 7,729. 10,085 TD (1 E- 15AL2), 10,085 ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other WINJ to PROD Alter Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Current Well Status: \,. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210 -015 3. Address: \Q. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service n 50- 029 - 20769 -61 7. Property Designatlgn: 8. Well Name and Number: ADL 25651 \ 1 E -15AL2 9. Field /Pool(s): \ Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 10085 feet Plugs (measured) none true vertical 6425 feet Junk (measured) none Effective Depth measured 10085 feet Packer (measured) 0 true vertical 6420 feet (true vertucal) 0 Casing Length Size MD TVD Burst Collapse LINER AL2 (OFF 2356 2.625 10085 6420 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 Perforation depth: Measured depth: 7702 -10057 True Vertical Depth: 6378 -6420 RECEIVED Tubing (size, grade, MD, and TVD) 0, 0, 0 MD, TVD U N 2 4 Ulu Alaska Oil & Gas Cans. ComrnisSiw Packers & SSSV (type, MD, and TVD) Anchorage 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 479 1100 2020 Subsequent to operation 229 151 1805 914 145 13. Attachments. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development 17 Service r 'I'! Well Status after work: OiI r Gas r WDSPL r Daily Report of Well Operations GSTOR r WAG r GASINJ r WIND r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A Contact Bob Christensen /Darrell Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature .� '61 Phone: 659 -7535 Date to ZZ•ll7 RBDMS JUN 2 4 20'p -It 7-7-/0 Form 10-404 Revised 7/2009 //, % / %Submit Original Only S • 1 E -15AL2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/31/10 Well currently being pre- produced to improve injection quality post CTD sidetrack operations. Put on production at 0732 hours. Well being gas lifted from 1E-31 @ 926 psi, 1000 MSCFD I I I I I I I I I I I I I I I I I I I I • KUP • 1 E -15AL2 ConocoPhillips Or Well Attributes Max Angle & MD TD AI,iSx,r. It 1.: Wellbore API /UWI Field Name Well Status Inc! ( °) MD (MEI) Act Btm (6609) ionxof+„u,ps 500292076961 KUPARUK RIVER UNIT INJ 95.56 8,800.49 10,085.0 Comment H2S (ppm) Date Annotation End Date K8.Grd (R) Rig Release Date Well Coneo.- lE- 15AL2 40512010 9 08.53 AM SSSV: TRDP Last WO: 40.71 8/4/1982 Schemstic - Actual Annotation Depth (MB) End Date Annotation Last Mod ... End Date Last Tag: SLM Rev Reason: GLV C/O Imosbor 4/25/2010 L2 -01 Strings pbon e String 0... String ID ... Top (6609) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Liner L2 off A2-01 25/8 1.995 7,728.6 10,085.0 6,424.7 4.60 L-80 STL 1 A___1 Liner Details Top Depth (TVD) Top Inc! Nomi... CONDUCTOR, Top (MB) )RKB) ( °) Rem Description Comment ID (In) 3z - 112 7,728.6 6,400.0 49.19 DEPLOY Deployment Sleeve Baker 1.995 c SAFETY VLV, p Perforations & Slots 1,878 Shot Top )TVD) Btm (TVO) Dens Top (MB) Btm (R613) (RKB) (RK8) Zon• Dab Oh— Type Comment GAS LIyT - 7,702 10,057 6,381.3 6,421.1 4/13/2010 32.0 Slots Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential SURFACE, adjacent rows, 3" centers staggered 30 18 deg, 3' non - slotted ends GAS LIFT, Notes: General & Safety 3.690 End Date Annotation 4/20/2010 NOTE: SIDETRACKwMTERALS 1E -15A, 15AL1, 15AL2, 15AL2 -01 4/20/2010 NOTE: VIEW SCHEMATIC w /Alaska Schemafc9.0 OAST ,9 21 C - GAS 6..256 256 I M t t GAS ,296 L-4 8,291 a� .. OAS ,272 1 7,272 } PBR, 7,307 H PACKER. 7,322 INJECTION, 7,359 !( INJECT 7 1Z1 6 ION, _■ 7 ION, i WHIPSTOCK, 7,557 WINDOW AL2 -01, 755&7565 Sbb, ] 543 -7,BD8 INJECTION. 7,592 PRODUCTION, 30E,110 Slots, 8.062-8,811 Sbb, 7.98 -9.784 Unsr ALt. 7,8233-0,812 Slots, 7,702.10057 Liner AL2 -01 (of main wel- 7,542-9,765 II Mandrel Details Top Depth Top Port (TVD) Inel OD Valve Latch 510e TRO Run Stn Top (RKB) ) 1609 ) ( °) Make Model (in) Sery Type Type (in) (psi) Run Dab Corn... 1 1,948.5 1,948.4 1.46 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,346.0 4/24/2010 I ' 2 3,690.5 3,504.9 46.84 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 4/24/2010 3 5,218.8 4,525.2 45.86 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 I I 4 6,255.6 5,252.2 43.86 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/5/1984 I I 5 6,291.2 5,277.8 43.53 CAMCO KBUG 6 7,271.9 6,027.0 37.97 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/3/1990 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 7 7,359.0 6,095.5 38.22 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 Liner AL2 (off 8 7,425.4 6,147.7 38.44 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 AL2 01 ). I I 9 7,592.1 6,278.3 38.42 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 7,729.10,295 I ID (1E- 15AL2), 10,0135 I ')1., ,111 j 1 " ledll Company ConocoPhillips, Alaska, Inc. g4c-1 BAKER Well Name -1E-15AL2 b -()( L-- HUGHES Date 6/9/2010 INTEQ ii,47,12‹,titali, rt,,,GA,,,,c1.%hfc.,;(;:;i,„ evmmt ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without 'i-Th r i* OH FINAL OH FINAL , written approval from ConocoPhillips ['' ..' Image files and/or Digital Data :". - .-,,,,., , 1 1-, ,, I: '0,- .1.i'' ■,- ' ; ' i'; ! ! ).. , t -`.':', -', il,..ti:4 contact: Lisa Wright 907 263-4823 t „ . hardcopy prints , t. , .,,, i, , : , 1 h . i ,,,,,., ,,, , , . ■ , : i ;". $ ,:',. ''''-;',.:' .!,":2: ____ ConocoPhillips Alaska, Inc. Ali Sharon Allsup-Drake .. „ ,1'.iri'cj'ilfi', ,• . „ W Drilling Tech, ATO-1530 • ConocoPhillips Alaska, Inc. 1 Hardcopy Print . r,,.,,..1 ,:1-(,i,-,Ii-;,,,,...:., NSK Wells Aide, NSK 69 lf: A: 1„ .-, ',-.1.',Fot El ' ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 ,. ConocoPhillips Alaska, Inc 1 Ricky Elgarico 1 Graphic Image 1 Disk*/ VVell-Data-Specia1-ist File*"/**" Electronic 7-00-G Street, - - '. ' CGM / TIFF LIS Anolloracje 99504 ftp://b2bftp.conocophillips.com AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS .410 BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ ', . ' .. ' • David Douglas in lieu of sepia*" Electronic P.O. Box 196612 ' ' CGM / TIFF LIS Anchorage, Alaska 99519-6612 , 1 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS . , DS Engineer / Rig Foreman TOTAL Hardcopy Prints 4 Page 1 of 4 Company ConocoPhillips, Alaska, Inc. I BAKER Well Name 1E- 15AL2PB1 t ) -74 g HUGI'IES . ' L G 11, , A (.o. At'!X _ -. Date 6/9/2010 n 1 E �[ ConocoPhillips Alaska Greater Kuparuk Area * ** Data Distribution RECIPIENTS ; ' No other distribution is allowed without ej, I , l' OH FINAL OH FINAL j � ° ' t t written approval from ConocoPhillips Image files and /or Digital Data 13 i, contact: Lisa Wright, 907 263 -4823 hardcop prints ConocoPhillips Alaska, Inc. _ ' 1 Sharon Allsup -Drake Drilling Tech, ATO -1530 �' ConocoPhillips Alaska, Inc. ' 1 Hardcopy Print NSK Wells Aide, NSK 69 ; " ' ` ��` ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk * / - - - . , • . ;. . File * * / * ** Electronic , �� I 780 r S1 CGM / TIFF LIS Anchorage, AK 99501. ftp: / /b2bftp.conocophillips.com * * ** AOGCC ? 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk * / ` 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic Anchorage, Alaska 99501 j CGM / TIFF LIS Aiik BP 1 Hardcopy Print, gip Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / f • David Douglas in lieu of sepia ** Electronic` zt `' P.O. Box 196612 { CGM / TIFF LIS Anchorage, Alaska 99519 - 6612 CHEVRON /KRU REP (.. 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk'/ P.O.Box 196247 `; in lieu of sepia ** Electronic Anchorage, Alaska 99519 ;; ! CGM / TIFF LIS Brandon Tucker, NRT ■ State of Alaska; DNR, Div. of Oil and Gas ` 1 Disk * / 550 W. 7th Ave, Suite 800 f Electronic Anchorage, Alaska 99501 -3510 LIS DS Engineer / Rig Foreman TOTAL , Hardcopy Prints � 4 i i..J. �,_e... � Page 1 of 4 , 1,TE ( 9/ 0 --(-_-_)( --) RECE‘ ,,, D grA Company ConocoPhillips, Alaska, Inc. BAKER , / 9 )-= 7 (,,, -, ' 1111\1 / ri 21111 11111014ES Well Name iE-15AL2PB2 Date 6/9/2010 ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without f ..) r. r i : i ,.. Y OH FINAL OH FINAL , , , 41.■,4..4 '...' '' written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. io Sharon Allsup-Drake • Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ; '. •. ,.. . , ATTN: MAIL ROOM .4 1 700 G Street, , . 1 Anchorage, AK 99501 7 ConocoPhillips Alaska, Inc. , Ricky Elgarico 1 Graphic Image 1 Disk*/ ' , , , , . •i Well-Data-Specialist, ATO 1802 File**/*** Electronic ; 700-G-Stre‘et, CGM/TIFF LIS , . Anc,11-GrageA-K-9-9504 ftp://b2bftp.conocophillips.com AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 i n lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS ..., BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk/ ,, , ',, , ',,,,,, ,),,,,, • David Douglas in lieu of sepia** Electronic ' P.O. Box 196612 CGM/TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, ' ' . , ,, , Glenn Fredrick 1 Graphic image file 1 Disk*/ ,. , , r, , , , ,, i P.O.Box 196247 ; in lieu of sepia** Electronic Anchorage, Alaska 99519 : CGM / TIFF LIS -.. Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 ■ Electronic Anchorage, Alaska 99501-3510 , , LIS . DS Engineer / Rig Foreman $ . ' 4 TOTAL Hardcopy Prints 4 , 1 Page 1 of 4 WI 111 Company Conoco Phillips, Alaska, Inc. / ' 7 Well Name iE-15AL2PB3 r 76 F17,,,,,,CtimE1.,,,,,,72,,,,sill.c.ot_C:)011A.KrielliKIEGIINgs ..,------ ( i, Cr„„40s, Date 6/9/2010 ' 0/ 6 '-- All(lifilartt TES ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without ), i , , .c, OH FINAL OH FINAL 1 , : ' 1.‘;.% 1 ., , ,.‘, 1 -)li':1 , :rlortzll written approval from ConocoPhillips Image files andlor Digital Data I - - , .. ' , ' , , contact: Lisa Wright, 907 263-4823 hardcop prints ConocoPhillips Alaska, Inc. ■ .1 , , , ■ Sharon Allsup-Drake • Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 . ATTN: MAIL ROOM , 700 G Street, Anchorage, AK 99501 ConocoPhillips Alaska, Inc. , . Ricky Elgarico , 1 Graphic Image 1 Disk File**/*** Electronic 7O0-See t CGM / TIFF LIS Anohocage,AK-9,9404 ftp://b2bftp.conocophillips.com AOGCC 1 Hardcopy Print, Christine Mahnken " 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 ' in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS ill BP : 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk*/ ' • . . David Douglas tn lieu of sepia** Electronic , P.O. Box 196612 CGM/TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP ' 1 Hardcopy Print, Glenn Fredrick k 1 Graphic image file 1 Disk*/ • • P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 . Electronic ' Anchorage, Alaska 99501-3510 LIS DS Engineer / Rig Foreman TOTAL Hardcopy Prints 4 Page 1 of 4 1 1 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 9 2010 WELL COMPLETION OR RECOMPLETION REPOaon la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other 0 Abandoned ❑ Suspended ❑ 1b. Well Class 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ GINJ ❑ WINJ 0 WAG ❑ WDSPL ❑ No. of Completions: Service El Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 20, 2010 210 - 015 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 6, 2010 50 029 - 20769 - 61 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 444' FSL, 814' FEL, Sec. 16, T11 N, R10E, UM April 13, 2010 1E Top of Productive Horizon: 8. KB (ft above MSL): 105.7' RKB 15. Field /Pool(s): 1286' FSL, 1224' FWL, Sec. 16, T11 N, R10E, UM GL (ft above MSL): 41' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 786' FNL, 2312' FWL, Sec. 21, T11 N, R10E, UM 10058' MD / 6420' 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 5960030 Zone 4 10085' MD / 6425' TVD ADL 25651 TPI: x - 546461 y - 5960851 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 547568 y 5958786 Zone 4 SSSV @ 1878' MD / 1878' TVD 469 18. Directional Survey: Yes Ei 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) 1450' 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 7557' MD / 6251' 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" 62.5# H -40 Surf. 112' Surf. 112' 24" 326 sx AS II 10.75" 45.5# K -55 Surf. 2193' Surf. 2193' 13.5" 1025 sx AS III, 250 sx AS II 7" 26.0# K -55 Surf. 8410' Surf. 6916' 8.75" 605 sx Class G 2.375" 4.7# L -80 7701' 10058' 6378' 6420' 3" slotted liner 24. Open to production or injection? Yes igi 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" 7682' 7321' MD / 6066' TVD alternating solid / slotted liner from 7702'- 10057' MD / 6378' -6420' TVD 7663' MD / 6331' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. r'z _ -- -- , DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 41 f 'ib / "� 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) flowback in progress Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No Ell If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 12/2009 T UED ON REVERSE Submit original only RBDMS MAY 192010 C,-4 /v 6, 6: / /e • 28. GEOLOGIC MARKERS (List all formations and markeencountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes EI 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 3398' 3291' needed, and submit detailed test information per 20 AAC 25.071. Top B3 7572' 6263' Top B2 7614' 6301' Top B1 7644' 6332' Top A6 7679' 6362' Top A5 7690' 6371' Top A4 7713' 6390' 1 E- 15L2 -PB1 TD 9836' 6438' N/A 1 E- 15L2 -PB2 TD 10135' 6454' 1 E- 15AL2 -PB3 TD 9710' 6375' Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations, final directional survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263 - 4172 \Y., Printed N e V `�: a T Ala Wells Manager //py� `\ Signature ir. Ak..� Phone 265 -6306 Date /v �# V Sharon 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 level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 g '. 1 -15AL2 Connc_ _ $ KU Max Angle & MD � 1 TD Well Attributes �dSli$ �, - Wellbore APUUWI Field Name Well Status Inc! ( °) IMD (ftKB) Act Btm OMB) t.rxrxr ,, ,,ua, , 500292076961 ,KUPARUK RIVER UNIT INJ 1 _ 10,085.0 "" Comment 'H2S (pp m) D wen conhg t E -tsn13 x21/2510 2 47 53 Phil notation �ate Annotation End Date KB -Grd (ft) Rig Release Date — - . Last WO: I 40.71 8/4/1982 Schemsnc Ac tua l Last Annotation IDepth(ftK6) End SIDE Last Mod...1 End Date Rev Reason _ DEI RACK w /LATERALS Imosbor 4/20/2010 Casing Strings C Description String 0... String ID ... Top (MB) Set Depth (f_. Set Depth (TVD) .. String Wt... String .. String Top Thrd Liner AL2 (off i 2 5/8 1.995 7,728.6 10,085.0 4.60 l L 80 STL A -01) ___..... .inerDetails Top Depth Nomi... CONDUCTOR, Top (111(13) (011< Tol r' ncl Item Description Comment ID 32-112 - 7,728.6 DEPLOY Deployment Sleeve Baker 1.995 SAFETY VLV, 1,878 _ Perforations Slots __ .... _... Shot Top (TVD) Btm (TVD) Dens Top (ft1O6) Btu (ft(6) (ftK6) MKS) Zone Date (s ° Type Comment GAS LIFT, 969 7,702 10,057 4/13/2010 32.0 Slots Alternating solid /slotted pipe - " "` 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered SURFACE, 30 - 2,193 18 deg, 3' non - slotted ends GAS LIFT, Notes: General & Safety iit'i 3,690 End Date Annotation 4/20/2010 NOTE SIDETRACKw/LATERALS 1E -15A, 15AL1. 15AL2, 15AL2 -01 (2 pg schematic) GAS LIFT, 4/20/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 5,219 NMI* GAS LIFT, -. 6,256 GAS LIFT, 6,291 GAS LIFT, ' 7,272 e- to PBR, 7,307 -- PACKER, 7,322 J INJECTION, 7,359 INJECTION, 7,425 W. WHIPSTOCK, 7,557 WINDOW \ AL2 -01, -- 7,558 -7,565 Slots, 7,513 -7,609 09 INJECTION, 7,592 PRODUCTION, t 30 -8,410 Slots, 8,062 -8,811 . 7, 668-9,764 eer ALI, Liner 7,623 -6,812 Slots, r 57 Lin AL2 01 Liner (off mein elbor wetlbore), _ 7,542 - 9,765 --- Maadr.1 Details_ Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run 1A= = Stn Top (MB) (ftK6) (`) Make Model (in) Sere Tn. TYPe (in) (Psi) Run Date Cam... 1 1,948.5 CAMCO KBUG 1 GAS LIFT DMY bk 0.000 0.0 6/5/1990 MK ewer ee. 2 3,690.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 3 5,218.8 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 4 6,255.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/5/1984 I 5 6291.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6!371990 6 7,271.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/5/1990 7 7,359.0 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 8 7,425.4 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 Liner AL2 (off AL2 - 01), i 1 9 7,592.1 CAMCO KBUG 1 INJ DMY BK 0.000 0.0 7/20/1993 7,729-10,085 TO (1 E- 15Al2), - 10,085 1E-15 CTD Sidetrack - Final Last Updated: 21- Apr -10 3 -1/2" Camco TRDP -1A nipple @ 1878' MD alini 3 -1/2" 9.3# K -55 EUE 8rd Tubing to surface - 3 -1/2" Camco KBUG gas lift mandrels @ 1948', 3690', 5218', 6256', 7271' 16" 65# H -40 shoe @112'MD r,rt Baker 3 -1/2" PBR @ 7307' MD Baker FHL packer @ 7321' MD 3 -1/2" Camco KBUG injection mandrels @ 7354', 7425', 7592' 10-3/4" 45.5# K -55 shoe @ 2193 MD Carbide blast rings 7446' - 7552' (7452' -7538' CBL) Baker FB -1 packer @ 7663' MD w/ Baker SBE ....... _............ 3 -1/2" Camco D landing nipple @ 7676' MD (2.75" min ID, No -Go) 3 -1/2" tubing tail @ 7682' MD C -sand perfs 7478' - 7554' MD , : { Sqz perfs (2/14/10) AL2 -01, TD = 9765' AL2, TD = 10,085' 7550' - 7554' CBL F 2 -3/8" liner 7542' -9765' 2 -3/8" liner 7690'- 10,058' 7618' - 7638' CBL Deployment sleeve at 7542' Billet at 7690' AL2 -PB3, TD = 9710' - , Unintended sidetrack at 7855' KOP #2 at 7557' MD KOP #1 at 7631' MD l •.T �� AL2 -PB2, TD = 10,135' ,,,, 2 -3/8" liner 8200'- 10,135' Baker flow -by monobore N -, Billet at 8200' whipstocks % /i _ i AL2 -PB1, TD - 9835' • N -0,--- 2 -3/8" liner 8864' -9835' Billet at 8855 A -sand perfs 7716' - I = I / / — — AL1 Lateral, TD = 8812' 7796' MD (plugged) - / 7 2 -3/8" liner 7623' - 8812' — —_—_— ----- Liner top at 7623' A Sidetrack, TD = 9800' 7" 26# K -55 shoe CIBP at 7656' ELM 2 -3/8" liner 8323' - 9794' @ (7674' MD, 2/13/10) Billet at 8323' 8410' MD �� _� Conoc�Phillips Alaska s ConocoPhilli Alaska p� ) Inc. Kuparuk River Unit Kuparuk 1E Pad 1 E -15AL2 50- 029 - 20769 -61 Baker Hughes INTEQ Wig Definitive Survey Report BAKER Y p HUGHES 21 April, 2010 °.= ~ Conoco Phillips Vail x_onuocx4nouo Definitive Survey Report BAKER HUGHES Alaska _ ____._ ___ _ _ , . ____ _ ��� Company: ovnvcnPmmpoKuavka Inc. Local Co-ordmatvmeferencm 1s15 / pp4w*t: Kuparuk Rive Unit TVonefemnce: 1E-15 @ 105.70n(1s-15) i ou*: Kuparuk 1E Pad MD Reference: 1s'15 @105.70n(1E-15) / men: 1s'15 North Reference: TRUE Minimum | ��xu w�: 1E-15 mon�xC�cum�vnMwm*u: Curvature i Design: 1e'15 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) uvmowmnno�� Point | Map Alaska Using ��� �_'-___ _--'__ _- --'_-_' _ _--_ �____-_----_____�___ _-____- _---___-_-__--_'___- � ���� �-_' _ ----_ - _- _-_._�_ __-'____-_.-__--_--__-_____--______'__-__-__�'--_'_____-' .°- Well 1E-15 ' Wwxposmon +NI-S 0.00 ft Northing: o.mm.ouo.00n Latitude: 70^18'5.686 m +E/-W 0.00 ft Easting: 5*9.710.0*n Longitude: 1*o^ao'oo.x»ovv � " m Uncertainty 0.00 ft x m�hpnus�vaup� ft m ovvuLov�: 0.00 ft — _ _ vxwnuwre 1s-15Au2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) r} (nT) BGGM2009 3/25o010 21.83 80.84 57,657 , '-_- ----___ -_- --.� _ _,1 ! Design 1s'15xL2 '' -�-'--� - --- ' ---'--' -' —'- ----- -� --� ----� ---- --''-----'---- --'---- - - -------- | Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,830.02 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ` (ft) (ft) (ft) [l 0 | � ! __ 105.70 0.00 0.00 __________ u4o�» ______________] ______ Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,500.00 1E-15 (1E-15) FINDER-MS SDC Finder multishot 8/25/2000 7.557.00 7,830.02 1s'15xm'Po1 (1s'15*L2-po1) MWD MWD - Standard 3/26o010 3u9o010 ro�aoo 10007oo 1E-15AL2 mvvo MWD 4/10/2010 4/13/2010 ' � ' � ' */21m010 10:53:4*AM Page 2 COMPASS 2003 16 Build 69 ConocoPhillips NM Conoco Phillips Definitive Survey Report HUG ES Alaska l Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1 E - 15 Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) S Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) I Well: 1 E - 15 North Reference: TRUE I ! Welibore: 1E Survey Calculation Method: Minimum Curvature 'I Design: 1E Database: EDM Alaska Prod v16 _ - -- _____ Survey 1 Map Map Vertical MD Inc Azi TVD TVDSS +N / +E/-W Northing Easting DLS Section Survey Tool Name Annotation I • (ft) n ( °) (ft) (ft) (ft) (ft) (ft) (ft) (1100') (ft) 7,830.02 93.69 160.68 6,428.83 6,323.13 737.93 - 3,232.69 5,960,746.41 546,472.85 51.24 2,439.80 MWD (2) TIP 1E 7,855.00 94.69 150.82 6,427.00 6,321.30 715.24 - 3,222.47 5,960,723.79 546,483.22 39.57 2,442.19 MWD (3) KOP 7,875.29 94.95 152.65 6,425.30 6,319.60 697.44 - 3,212.90 5,960,706.05 546,492.91 9.08 2,442.72 MWD (3) 7,895.24 94.12 153.46 6,423.72 6,318.02 679.71 - 3,203.89 5,960,688.38 546,502.04 5.80 2,443.70 MWD (3) 7,920.24 93.59 154.36 6,422.04 6,316.34 657.31 - 3,192.92 5,960,666.06 546,513.16 4.17 2,445.30 MWD (3) 7,950.21 92.92 154.53 6,420.34 6,314.64 630.31 - 3,180.01 5,960,639.15 546,526.24 2.31 2,447.49 MWD (3) 7,980.39 92.21 154.11 6,418.99 6,313.29 603.14 - 3,166.94 5,960,612.07 546,539.48 2.73 2,449.64 MWD (3) 8,010.40 91.87 153.09 6,417.92 6,312.22 576.28 - 3,153.61 5,960,585.30 546,552.99 3.58 2,451.40 MWD (3) 8,040.37 90.86 153.31 6,417.20 6,311.50 549.54 - 3,140.10 5,960,558.65 546,566.68 3.45 2,452.96 MWD (3) 8,070.23 91.23 155.48 6,416.66 6,310.96 522.62 - 3,127.20 5,960,531.81 546,579.76 7.37 2,455.12 MWD (3) 8,100.20 90.21 155.60 6,416.28 6,310.58 495.34 - 3,114.79 5,960,504.62 546,592.34 3.43 2,457.89 MWD (3) 8,130.25 89.91 155.31 6,416.25 6,310.55 468.00 - 3,102.31 5,960,477.37 546,605.01 1.39 2,460.63 MWD (3) 8,160.47 89.88 155.45 6,416.31 6,310.61 440.53 - 3,089.72 5,960,449.99 546,617.78 0.47 2,463.34 MWD (3) 8,190.19 90.18 155.79 6,416.29 6,310.59 413.46 - 3,077.45 5,960,423.00 546,630.22 1.53 2,466.13 MWD (3) 8,220.30 90.86 156.48 6,416.02 6,310.32 385.93 - 3,065.27 5,960,395.55 546,642.58 3.22 2,469.22 MWD (3) 8,250.25 90.83 156.79 6,415.58 6,309.88 358.44 - 3,053.39 5,960,368.14 546,654.64 1.04 2,472.56 MWD (3) 8,280.23 91.26 157.28 6,415.03 6,309.33 330.84 - 3,041.70 5,960,340.62 546,666.52 2.17 2,476.11 MWD (3) 8,310.17 91.35 157.56 6,414.35 6,308.65 303.20 - 3,030.20 5,960,313.07 546,678.19 0.98 2,479.86 MWD (3) 8,340.54 92.06 157.97 6,413.44 6,307.74 275.10 - 3,018.72 5,960,285.05 546,689.86 2.70 2,483.84 MWD (3) • 8,370.17 91.63 157.95 6,412.49 6,306.79 247.65 - 3,007.60 5,960,257.67 546,701.16 1.45 2,487.82 MWD (3) 8,400.51 92.85 157.04 6,411.30 6,305.60 219.64 - 2,996.00 5,960,229.75 546,712.94 5.02 2,491.65 MWD (3) 8,430.78 93.47 155.13 6,409.63 6,303.94 192.01 - 2,983.75 5,960,202.20 546,725.38 6.62 2,494.73 MWD (3) 8,460.65 92.67 155.80 6,408.04 6,302.34 164.88 - 2,971.36 5,960,175.15 546,737.94 3.49 2,497.45 MWD (3) 8,490.50 90.49 156.23 6,407.21 6,301.51 137.62 - 2,959.23 5,960,147.98 546,750.25 7.44 2,500.46 MWD (3) { 8,520.31 89.88 155.61 6,407.12 6,301.42 110.40 - 2,947.07 5,960,120.84 546,762.59 2.92 2,503.41 MWD (3) 8,550.41 89.66 156.16 6,407.24 6,301.54 82.93 - 2,934.77 5,960,093.46 546,775.07 1.97 2,506.37 MWD (3) 8,580.56 89.48 156.84 6,407.46 6,301.76 55.28 - 2,922.75 5,960,065.89 546,787.27 2.33 2,509.67 MWD (3) ' 8,610.39 90.40 155.91 6,407.49 6,301.79 27.95 - 2,910.80 5,960,038.64 546,799.40 4.39 2,512.86 MWD (3) 8,640.83 91.10 154.76 6,407.10 6,301.40 0.29 - 2,898.10 5,960,011.07 546,812.29 4.42 2,515.56 MWD (3) I 8,670.68 90.86 154.07 6,406.59 6,300.89 -26.62 - 2,885.21 5,959,984.24 546,825.35 2.45 2,517.74 MWD (3) 4/21/2010 10:53:44AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Rae ConocoPhillips Definitive Survey Report BAKER HUGHES Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E - 15 1 I Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) } I Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) i Well: 1E North Reference: TRUE I Wellbore: 1 E - 15 Survey Calculation Method: Minimum Curvature Design: 1E-15 Database: EDM Alaska Prod v16 _____ .._ __ _____ __ Survey I MD Inc Azi ND TVDSS +N/-S +E/ -W Map Map DLS Vertical Section Survey Tool Name Annotation M (ft) ( °) P) (ft) (ft) (ft) (ft) (ft) (ft) moo') (ft) • 8,700.33 91.14 153.13 6,406.07 6,300.37 -53.18 - 2,872.03 5,959,957.78 546,838.71 3.31 2,519.48 MWD (3) 8,730.29 92.15 152.05 6,405.21 6,299.51 -79.76 - 2,858.24 5,959,931.29 546,852.67 4.93 2,520.71 MWD (3) 8,768.14 94.02 151.58 6,403.17 6,297.47 - 113.08 - 2,840.39 5,959,898.10 546,870.74 5.09 2,521.75 MWD (3) 8,800.48 95.56 151.30 6,400.47 6,294.77 - 141.38 - 2,824.98 5,959,869.90 546,886.33 4.84 2,522.43 MWD (3) 8,830.18 94.58 151.07 6,397.85 6,292.15 - 167.30 - 2,810.72 5,959,844.08 546,900.76 3.39 2,522.92 MWD (3) 8,860.27 93.53 150.93 6,395.72 6,290.02 - 193.55 - 2,796.17 5,959,817.92 546,915.48 3.52 2,523.33 MWD (3) 8,890.19 92.30 151.89 6,394.20 6,288.50 - 219.79 - 2,781.87 5,959,791.78 546,929.95 5.21 2,523.94 MWD (3) 8,920.11 92.30 150.51 6,393.00 6,287.30 - 245.99 - 2,767.47 5,959,765.69 546,944.52 4.61 2,524.44 MWD (3) 8,945.23 91.60 150.30 6,392.14 6,286.44 - 267.82 - 2,755.07 5,959,743.94 546,957.07 2.91 2,524.52 MWD (3) 8,975.48 90.98 149.83 6,391.46 6,285.76 - 294.02 - 2,739.98 5,959,717.84 546,972.33 2.57 2,524.43 MWD (3) 9,010.45 90.74 148.05 6,390.93 6,285.24 - 323.97 - 2,721.94 5,959,688.01 546,990.56 5.14 2,523.64 MWD (3) 9,040.25 90.55 148.02 6,390.60 6,284.90 - 349.25 - 2,706.17 5,959,662.83 547,006.50 0.65 2,522.50 MWD (3) 9,070.14 90.71 146.62 6,390.27 6,284.57 - 374.41 - 2,690.03 5,959,637.79 547,022.81 4.71 2,520.98 MWD (3) 9,101.91 90.49 145.86 6,389.94 6,284.24 - 400.82 - 2,672.38 5,959,611.50 547,040.63 2.49 2,518.77 MWD (3) 9,130.02 90.03 144.26 6,389.81 6,284.11 - 423.86 - 2,656.28 5,959,588.56 547,056.88 5.92 2,516.23 MWD (3) 9,160.10 88.37 143.36 6,390.23 6,284.53 - 448.14 - 2,638.52 5,959,564.41 547,074.80 6.28 2,512.87 MWD (3) 9,189.96 88.16 144.13 6,391.13 6,285.43 - 472.20 - 2,620.87 5,959,540.46 547,092.61 2.67 2,509.49 MWD (3) 9,220.04 88.31 145.39 6,392.06 6,286.36 - 496.76 - 2,603.52 5,959,516.03 547,110.11 4.22 2,506.63 MWD (3) 9,250.03 88.19 146.55 6,392.98 6,287.28 - 521.60 - 2,586.75 5,959,491.30 547,127.05 3.89 2,504.40 MWD (3) • 9,280.10 87.76 148.06 6,394.04 6,288.34 - 546.89 - 2,570.51 5,959,466.12 547,143.45 5.22 2,502.86 MWD (3) 9,310.29 87.79 149.30 6,395.21 6,289.51 - 572.66 - 2,554.83 5,959,440.45 547,159.30 4.11 2,502.04 MWD (3) 9,340.08 87.11 149.27 6,396.54 6,290.84 - 598.25 - 2,539.63 5,959,414.97 547,174.67 2.28 2,501.55 MWD (3) 9,370.40 87.14 148.93 6,398.06 6,292.36 - 624.23 - 2,524.08 5,959,389.09 547,190.39 1.12 2,500.95 MWD (3) 9,400.34 86.53 147.75 6,399.71 6,294.01 - 649.68 - 2,508.39 5,959,363.76 547,206.25 4.43 2,499.97 MWD (3) 9,430.32 86.81 146.25 6,401.45 6,295.75 - 674.78 - 2,492.09 5,959,338.77 547,222.71 5.08 2,498.28 MWD (3) 9,460.48 87.21 145.59 6,403.03 6,297.33 - 699.72 - 2,475.21 5,959,313.94 547,239.75 2.56 2,496.01 MWD (3) 9,490.52 88.00 143.98 6,404.28 6,298.58 - 724.24 - 2,457.91 5,959,289.53 547,257.22 5.97 2,493.16 MWD (3) 9,520.04 89.85 144.74 6,404.83 6,299.14 - 748.23 - 2,440.71 5,959,265.66 547,274.57 6.77 2,490.14 MWD (3) 9,550.31 89.02 143.98 6,405.13 6,299.43 - 772.83 - 2,423.07 5,959,241.19 547,292.37 3.72 2,487.04 MWD (3) 9,580.26 87.64 145.56 6,406.01 6,300.31 - 797.28 - 2,405.80 5,959,216.85 547,309.80 7.00 2,484.19 MWD (3) 9,610.52 88.04 142.61 6,407.15 6,301.45 - 821.77 - 2,388.07 5,959,192.48 547,327.69 9.83 2,480.96 MWD (3) 4/21/2010 10.53:44AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Van ConocoPhillips Definitive Survey Report �6H Alaska 1 Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1 E - 15 I Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) I Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) Well: 1 E - 15 North Reference: TRUE i Weilbore: 1E Survey Calculation Method: Minimum Curvature Design: 1E Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northin g Easting DLS Section (ft) r) (1 (ft) (ft) (ft) (ft) (ft) (ft) g Moo') (ft) Survey Tool Name Annotation • 9,640.47 89.72 141.96 6,407.73 6,302.03 - 845.45 - 2,369.75 5,959,168.92 547,346.16 6.01 2,476.82 MWD (3) 9,671.62 89.63 144.79 6,407.91 6,302.21 - 870.45 - 2,351.17 5,959,144.05 547,364.91 9.09 2,473.10 MWD (3) i 9,700.70 89.63 145.78 6,408.10 6,302.40 - 894.35 - 2,334.61 5,959,120.26 547,381.62 3.40 2,470.59 MWD (3) 9,730.32 87.82 144.52 6,408.76 6,303.06 - 918.65 - 2,317.69 5,959,096.07 547,398.70 7.44 2,467.96 MWD (3) 9,760.25 86.59 146.39 6,410.22 6,304.52 - 943.27 - 2,300.74 5,959,071.57 547,415.82 7.47 2,465.47 MWD (3) 9,790.09 85.70 148.19 6,412.22 6,306.52 - 968.32 - 2,284.65 5,959,046.63 547,432.07 6.72 2,463.94 MWD (3) 9,820.14 87.18 148.20 6,414.09 6,308.39 - 993.81 - 2,268.84 5,959,021.25 547,448.04 4.93 2,462.88 MWD (3) 9,850.22 88.47 148.78 6,415.23 6,309.53 - 1,019.44 - 2,253.13 5,958,995.73 547,463.92 4.70 2,461.96 MWD (3) 9,880.13 88.77 150.06 6,415.95 6,310.25 - 1,045.18 - 2,237.92 5,958,970.09 547,479.30 4.39 2,461.54 MWD (3) 9,907.75 88.93 151.98 6,416.50 6,310.80 - 1,069.33 - 2,224.54 5,958,946.03 547,492.83 6.97 2,461.92 MWD (3) 9,944.53 89.14 153.39 6,417.12 6,311.42 - 1,102.01 - 2,207.67 5,958,913.47 547,509.92 3.88 2,463.49 MWD (3) 9,980.23 89.57 155.54 6,417.53 6,311.83 - 1,134.22 - 2,192.28 5,958,881.36 547,525.52 6.14 2,466.12 MWD (3) iii 10,000.00 89.42 156.61 6,417.70 6,312.00 - 1,152.29 - 2,184.27 5,958,863.35 547,533.66 5.46 2,468.14 MWD (3) 10,031.58 86.38 156.44 6,418.86 6,313.16 - 1,181.23 - 2,171.70 5,958,834.49 547,546.42 9.64 2,471.59 MWD (3) 10,067.38 82.45 156.11 6,422.34 6,316.64 - 1,213.84 - 2,157.36 5,958,801.98 547,560.96 11.02 2,475.34 MWD (3) 10,085.00 82.45 156.11 6,424.66 6,318.96 - 1,229.81 - 2,150.29 5,958,786.06 547,568.14 0.00 2,477.13 PROJECTED to TD • 4/21/2010 10:53:44AM Page 5 COMPASS 2003.16 Build 69 I ConocoPhilli ps Alaska ConocoPhilli p s ( Alaska) Inc. • Kuparuk River Unit Kuparuk 1E Pad 1 E- 15AL2 -PB1 50- 029 - 20769 -70 Baker Hughes INTEQ lid Definitive Survey Report BAKER Y p HUGHES 21 April, 2010 .v Conoco Phillips "f Conoco Phillips Definitive Survey Report B4 ES Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1E , I Project: Kuparuk River Unit TVD Reference: 1E-15 © 105.70ft (1E-15) I Site: Kuparuk 1E Pad MD Reference: 1E-15 © 105.70ft (1E-15) Well: 1E North Reference: TRUE Wellbore: vv 1E Survey Calculation Method: Minimum Curvature Design: 1E-15 Database: EDM Alaska Prod v16 Project Kuparuk River Unit I I Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level I Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point I Map Zone: Alaska Zone 04 Using geodetic scale factor — • Well 1E-15 i Well Position +N/ 0.00 ft Northing: 5,960,029.95ft Latitude: 70° 18' 5.686 N +E/ 0.00 ft Easting: 549,710.04ft Longitude: 149° 35' 50.538 W 1 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft _ i — - 1 Wellbore 1E-15AL2-PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (*) (°) (nT) BGGM2009 3/25/2010 17.33 79.80 57,371 - - - — _ rDesign 1E-15AL2-PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,500.00 Vertical Section: Depth From (TVD) +N/-S +EJ-W Direction (ft) 00 (ft) (1 ________] • 105.70 0.00 0.00 245.86 _ Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,500.00 1E-15 (1E-15) FINDER-MS SDC Finder multishot 8/25/2000 i 7,557.00 9,800.03 1E-15AL2-PB1 (1E-15AL2-PB1) MWD MWD - Standard 3/26/2010 3/29/2010 L 4/21/2010 11:13:19AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Rif Conoco Phillips Definitive Survey Report BAKER M s Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1 E - 15 Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) { Well: 1 E - 15 North Reference: TRUE I Wellbore: 1E Survey Calculation Method: Minimum Curvature Design: 1E Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N /-S +E/-W Northin g Eastin DLS Section (ft) ( °) (1 (ft) (ft) (ft) (ft) (ft) (ft) g (° /100') (ft) Survey Tool Name Annotation 7,500.00 38.43 287.45 6,206.16 6,100.46 860.08 - 3,165.88 5,960,868.98 546,538.85 0.16 2,537.13 MWD (2) TIP 1E - 7,557.00 38.42 287.35 6,250.81 6,145.11 870.67 - 3,199.68 5,960,879.35 546,504.98 0.11 2,563.65 MWD (2) KOP; Top of Window 7,590.40 26.24 281.06 6,278.99 6,173.29 875.20 - 3,216.90 5,960,883.76 546,487.73 37.79 2,577.51 MWD (2) Interpolated AZI 7,620.36 13.37 265.72 6,307.13 6,201.43 876.22 - 3,226.90 5,960,884.71 546,477.72 45.98 2,586.22 MWD (2) 7,650.52 22.24 224.46 6,335.93 6,230.23 871.86 - 3,234.42 5,960,880.31 546,470.24 49.45 2,594.86 MWD (2) 7,680.36 28.50 195.31 6,362.98 6,257.28 860.91 - 3,240.29 5,960,869.32 546,464.45 46.22 2,604.69 MWD (2) 7,710.70 40.92 186.05 6,387.89 6,282.19 843.97 - 3,243.26 5,960,852.36 546,461.59 44.37 2,614.34 MWD (2) 7,741.87 55.33 178.16 6,408.66 6,302.96 820.86 - 3,243.93 5,960,829.25 546,461.07 49.86 2,624.40 MWD (2) 7,770.34 69.37 175.08 6,421.84 6,316.14 795.76 - 3,242.40 5,960,804.16 546,462.76 50.23 2,633.27 MWD (2) 7,800.40 84.99 173.13 6,428.49 6,322.79 766.69 - 3,239.38 5,960,775.12 546,465.97 52.34 2,642.41 MWD (2) 7,830.02 93.69 160.68 6,428.83 6,323.13 737.93 - 3,232.69 5,960,746.41 546,472.85 51.24 2,648.06 MWD (2) 7,860.39 94.89 148.69 6,426.55 6,320.85 710.60 - 3,219.77 5,960,719.17 546,485.96 39.57 2,647.45 MWD (2) 7,890.31 95.62 149.32 6,423.81 6,318.11 685.07 - 3,204.42 5,960,693.73 546,501.47 3.22 2,643.89 MWD (2) 7,920.61 95.41 149.96 6,420.90 6,315.20 659.04 - 3,189.18 5,960,667.81 546,516.88 2.21 2,640.63 MWD (2) 7,950.91 93.81 151.61 6,418.46 6,312.76 632.68 - 3,174.44 5,960,641.56 546,531.79 7.57 2,637.96 MWD (2) 7,980.56 93.35 150.76 6,416.61 6,310.91 606.76 - 3,160.18 5,960,615.73 546,546.23 3.25 2,635.55 MWD (2) i 8,000.28 93.38 151.23 6,415.45 6,309.75 589.54 - 3,150.63 5,960,598.58 546,555.88 2.38 2,633.88 MWD (2) I 8,030.36 92.83 151.01 6,413.82 6,308.13 563.24 - 3,136.13 5,960,572.37 546,570.56 1.97 2,631.40 MWD (2) 8,060.25 91.60 151.73 6,412.67 6,306.97 537.02 - 3,121.81 5,960,546.26 546,585.04 4.77 2,629.06 MWD (2) • 8,090.35 90.43 153.13 6,412.14 6,306.44 510.35 - 3,107.89 5,960,519.68 546,599.15 6.06 2,627.27 MWD (2) 8,120.44 89.79 153.58 6,412.08 6,306.38 483.45 - 3,094.39 5,960,492.87 546,612.82 2.60 2,625.95 MWD (2) 8,140.31 90.03 152.92 6,412.11 6,306.41 465.71 - 3,085.45 5,960,475.19 546,621.88 3.53 2,625.05 MWD (2) 8,170.19 89.39 152.47 6,412.26 6,306.56 439.16 - 3,071.74 5,960,448.73 546,635.76 2.62 2,623.40 MWD (2) 8,200.26 89.79 152.38 6,412.48 6,306.78 412.51 - 3,057.82 5,960,422.18 546,649.85 1.36 2,621.60 MWD (2) 8,230.29 89.85 151.11 6,412.57 6,306.87 386.05 - 3,043.61 5,960,395.82 546,664.24 4.23 2,619.45 MWD (2) 8,260.59 89.75 152.04 6,412.68 6,306.98 359.41 - 3,029.18 5,960,369.27 546,678.84 3.09 2,617.19 MWD (2) 8,290.25 90.00 151.37 6,412.74 6,307.04 333.29 - 3,015.13 5,960,343.25 546,693.07 2.41 2,615.04 MWD (2) 8,320.23 90.15 151.29 6,412.70 6,307.00 306.99 - 3,000.74 5,960,317.05 546,707.62 0.57 2,612.67 MWD (2) 8,350.05 91.11 149.71 6,412.37 6,306.67 281.04 - 2,986.06 5,960,291.20 546,722.48 6.20 2,609.89 MWD (2) 8,380.34 92.24 148.22 6,411.49 6,305.79 255.09 - 2,970.45 5,960,265.36 546,738.26 6.17 2,606.26 MWD (2) 4/21/2010 11:13:19AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips redii Conoco Phillips Definitive Survey Report BAKER Alaska Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) Well: 1E North Reference: TRUE Weilbore: 1E Survey Calculation Method: Minimum Curvature Design: __._ 1 E -15 EDM Alaska Prod v16 _ __ __ __ __ ._ _� Database: _��_ _ _ Survey __ _____� Map Map Vertical MD Inc Az( TVD TVDSS +N/-S + E/ - W Section DLS Northing Easting Survey Tool Name Annotation ° (ft) ( °) ( °) (ft) (ft) (ft) (ft) (g) (ft) ( /100') (ft) y 8,410.37 92.80 147.10 6,410.17 6,304.47 229.75 - 2,954.40 5,960,240.12 546,754.47 4.17 2,601.98 MWD (2) 8,440.17 92.33 147.09 6,408.83 6,303.13 204.75 - 2,938.23 5,960,215.24 546,770.81 1.58 2,597.45 MWD (2) 8,470.17 93.50 146.73 6,407.31 6,301.61 179.65 - 2,921.87 5,960,190.25 546,787.33 4.08 2,592.79 MWD (2) 8,500.42 93.78 147.10 6,405.39 6,299.69 154.36 - 2,905.39 5,960,165.07 546,803.97 1.53 2,588.10 MWD (2) 8,530.30 93.96 147.59 6,403.37 6,297.67 129.26 - 2,889.31 5,960,140.08 546,820.22 1.74 2,583.68 MWD (2) 8,560.37 93.90 147.60 6,401.31 6,295.61 103.93 - 2,873.23 5,960,114.86 546,836.46 0.20 2,579.37 MWD (2) 8,590.36 93.66 148.78 6,399.33 6,293.63 78.50 - 2,857.46 5,960,089.54 546,852.40 4.01 2,575.38 MWD (2) 8,620.36 93.32 149.17 6,397.51 6,291.81 52.84 - 2,842.02 5,960,063.98 546,868.01 1.72 2,571.79 MWD (2) 8,651.50 93.56 149.09 6,395.64 6,289.94 26.16 - 2,826.07 5,960,037.41 546,884.13 0.81 2,568.15 MWD (2) 8,680.35 92.36 149.62 6,394.15 6,288.45 1.37 - 2,811.39 5,960,012.72 546,898.98 4.55 2,564.89 MWD (2) 8,710.35 92.24 149.48 6,392.95 6,287.25 -24.47 - 2,796.20 5,959,986.98 546,914.34 0.61 2,561.60 MWD (2) 8,740.11 92.21 151.40 6,391.79 6,286.09 -50.34 - 2,781.53 5,959,961.22 546,929.18 6.45 2,558.79 MWD (2) 8,770.44 90.28 150.95 6,391.13 6,285.43 -76.90 - 2,766.91 5,959,934.75 546,943.97 6.53 2,556.32 MWD (2) 8,800.48 88.31 151.22 6,391.50 6,285.80 - 103.19 - 2,752.39 5,959,908.56 546,958.66 6.62 2,553.82 MWD (2) 8,830.19 87.23 152.01 6,392.66 6,286.96 - 129.31 - 2,738.27 5,959,882.54 546,972.95 4.50 2,551.62 MWD (2) 8,860.21 86.96 152.96 6,394.18 6,288.48 - 155.90 - 2,724.42 5,959,856.05 546,986.97 3.29 2,549.86 MWD (2) i I 8,890.67 86.71 153.97 6,395.86 6,290.16 - 183.11 - 2,710.84 5,959,828.93 547,000.74 3.41 2,548.59 MWD (2) 8,921.66 87.82 153.92 6,397.34 6,291.64 - 210.92 - 2,697.24 5,959,801.21 547,014.52 3.59 2,547.56 MWD (2) 8,950.63 87.91 153.86 6,398.42 6,292.72 - 236.91 - 2,684.50 5,959,775.31 547,027.43 0.37 2,546.57 MWD (2) ill 8,970.75 87.51 154.76 6,399.22 6,293.52 - 255.03 - 2,675.78 5,959,757.25 547,036.26 4.89 2,546.02 MWD (2) 9,000.35 88.43 154.89 6,400.27 6,294.57 - 281.80 - 2,663.20 5,959,730.56 547,049.02 3.14 2,545.49 MWD (2) 9,030.16 90.12 153.98 6,400.65 6,294.95 - 308.69 - 2,650.34 5,959,703.77 547,062.06 6.44 2,544.75 MWD (2) 9,060.09 89.48 153.66 6,400.75 6,295.05 - 335.55 - 2,637.13 5,959,677.00 547,075.44 2.39 2,543.69 MWD (2) j 9,080.19 87.82 152.96 6,401.23 6,295.53 - 353.50 - 2,628.11 5,959,659.11 547,084.58 8.96 2,542.80 MWD (2) 9,110.28 86.78 153.38 6,402.64 6,296.94 - 380.32 - 2,614.54 5,959,632.38 547,098.32 3.73 2,541.39 MWD (2) 9,140.27 85.76 153.46 6,404.59 6,298.89 - 407.08 - 2,601.15 5,959,605.71 547,111.89 3.41 2,540.12 MWD (2) 9,170.34 85.27 153.75 6,406.94 6,301.25 - 433.94 - 2,587.83 5,959,578.95 547,125.39 1.89 2,538.94 MWD (2) 9,200.25 85.27 154.00 6,409.41 6,303.71 - 460.70 - 2,574.70 5,959,552.27 547,138.69 0.83 2,537.91 MWD (2) 9,230.02 84.03 154.34 6,412.19 6,306.49 - 487.38 - 2,561.79 5,959,525.68 547,151.78 4.32 2,537.04 MWD (2) 9,260.06 82.28 154.63 6,415.77 6,310.07 - 514.29 - 2,548.94 5,959,498.86 547,164.81 5.90 2,536.32 MWD (2) 9,290.22 82.34 153.75 6,419.80 6,314.10 - 541.20 - 2,535.93 5,959,472.04 547,178.00 2.90 2,535.45 MWD (2) 4/21/2010 11:13:19AM Page 4 COMPASS 2003.16 Build 69 v - ConocoPhillips rag ConocoPhillips Definitive Survey Report BAKER HUGHES Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co -ordinate Reference: 1 E - 15 I Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) 111 Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) I Well: 1E North Reference: TRUE 1 Wellbore: 1E Survey Calculation Method: Minimum Curvature I � Design: __._ _.__,1 E Database: EDM Alaska Prod v16 �15 1- -_ '_M _. _____ _._.. _ ____R_ _ _____.__ � Survey ____ , .__J_. _v_ ___ _ �_____ �__ -- _ Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section Survey Tool Name An notation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( /100') (ft) 1110 9,320.02 82.55 153.60 6,423.72 6,318.02 - 567.68 - 2,522.83 5,959,445.65 547,191.27 0.86 2,534.33 MWD (2) 9,350.07 84.68 153.59 6,427.06 6,321.36 - 594.42 - 2,509.55 5,959,418.99 547,204.73 7.09 2,533.15 MWD (2) 9,380.03 86.81 153.97 6,429.29 6,323.59 - 621.23 - 2,496.35 5,959,392.28 547,218.10 7.22 2,532.07 MWD (2) 9,410.08 89.23 154.01 6,430.32 6,324.62 - 648.21 - 2,483.18 5,959,365.39 547,231.45 8.05 2,531.09 MWD (2) 9,440.11 91.72 154.01 6,430.07 6,324.37 - 675.20 - 2,470.02 5,959,338.49 547,244.78 8.29 2,530.12 MWD (2) 9,470.20 94.36 153.40 6,428.48 6,322.78 - 702.14 - 2,456.71 5,959,311.64 547,258.27 9.00 2,529.00 MWD (2) 9,500.19 94.52 153.95 6,426.16 6,320.46 - 728.94 - 2,443.45 5,959,284.93 547,271.70 1.90 2,527.86 MWD (2) 9,530.62 94.27 153.53 6,423.83 6,318.13 - 756.15 - 2,430.03 5,959,257.82 547,285.31 1.60 2,526.74 MWD (2) 9,560.38 91.53 152.77 6,422.32 6,316.62 - 782.66 - 2,416.60 5,959,231.39 547,298.90 9.55 2,525.33 MWD (2) { 9,590.53 90.86 151.66 6,421.69 6,315.99 - 809.33 - 2,402.55 5,959,204.82 547,313.13 4.30 2,523.42 MWD (2) 9,620.32 90.34 151.74 6,421.38 6,315.68 - 835.56 - 2,388.43 5,959,178.69 547,327.42 1.77 2,521.26 MWD (2) 9,650.42 88.96 151.54 6,421.56 6,315.86 - 862.04 - 2,374.13 5,959,152.30 547,341.89 4.63 2,519.05 MWD (2) 9,680.34 88.89 151.93 6,422.12 6,316.42 - 888.39 - 2,359.97 5,959,126.05 547,356.23 1.32 2,516.90 MWD (2) 9,709.95 86.99 153.18 6,423.19 6,317.49 - 914.65 - 2,346.33 5,959,099.88 547,370.04 7.68 2,515.19 MWD (2) 9,740.30 84.99 153.51 6,425.31 6,319.61 - 941.71 - 2,332.75 5,959,072.92 547,383.80 6.68 2,513.87 MWD (2) 9,770.24 83.26 153.70 6,428.38 6,322.68 - 968.39 - 2,319.51 5,959,046.34 547,397.22 5.81 2,512.70 MWD (2) 9,800.03 81.48 154.47 6,432.33 6,326.63 - 994.94 - 2,306.60 5,959,019.87 547,410.29 6.50 2,511.78 MWD (2) 9,836.00 81.48 154.47 6,437.66 6,331.96 - 1,027.04 - 2,291.27 5,958,987.87 547,425.84 0.00 2,510.92 PROJECTED to TD _ • 4/21/2010 11:13:19AM Page 5 COMPASS 2003.16 Build 69 ConocoPhilli Alaska s ConocoPhilli Alaska • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1 E- 15AL2 -PB2 50- 029 - 20769 -71 Baker Hughes INTEQ Van • Definitive Survey Report BAKER Y p HUGHES 21 April, 2010 Conoco Phillips Mal Conoco Phillips Definitive Survey Report BAKER HUGHES Alaska , 1 Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1E I Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) I Well: 1E North Reference: TRUE Wellbore: 1E Survey Calculation Method: Minimum Curvature Design: 1E Database: EDM Alaska Prod v16 ; Project I Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ; Map Zone: Alaska Zone 04 Using geodetic scale factor • — , ,— — — — — ---- — Well 1E-15 I Well Position I +141/ 0.00 ft Northing: 5,960,029.95ft Latitude: 70° 18' 5.686 N i +E/ 0.00 ft Easting: 549,710.04ft Longitude: 149° 35' 50.538 W 1 Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft 1 Wellbore 1E-15AL2-PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1 r) () (nT) 1 BGGM2009 3/25/2010 17.33 79.80 57,371 -- -----1 Design 1E Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,830.19 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (*) al 105.70 0.00 0.00 240.20 — ------ Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,500.00 1E-15 (1E-15) FINDER-MS SDC Finder muitishot 8/25/2000 7,557.00 8,830.19 1E-15AL2-PB1 (1E-15AL2-PB1) MWD MWD - Standard 3/26/2010 3/29/2010 8,848.00 10,090.01 1E-15AL.2-PB2 (1E-15AL2-PB2) MWD MWD - Standard 4/3/2010 4/5/2010 _ I 4/21/2010 11:16:22AM Page 2 COMPASS 2003.16 Build 69 - -` ConocoPhillips rag ConocoPhillips Definitive Survey Report BAKER Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E { Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) I Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) Well: 1E - 15 North Reference: TRUE I Wellbore: 1 E - 15 Survey Calculation Method: Minimum Curvature I Design: 1E-15 Database: EDM Alaska Prod v16 survey ^.".___ _.___ -. _._ _ Map Map Vertical MD Inc Azi TVD TVDSS +14/-S DLS +E/ -W Ve Northing Easting Section Survey Tool Name Annotation • (ft) ( °) (1 (ft) (ft) (ft) (ft) (ft) (ft) (H00') (ft) 8,830.19 87.23 152.01 6,392.66 6,286.96 - 129.31 - 2,738.27 5,959,882.54 546,972.95 4.50 2,440.41 MWD (2) TIP 1E 8,848.00 87.07 152.57 6,393.54 6,287.84 - 145.06 - 2,730.00 5,959,866.85 546,981.32 3.27 2,441.05 MWD (3) KOP; Top of Billet 8,870.66 88.74 147.85 6,394.37 6,288.67 - 164.70 - 2,718.75 5,959,847.28 546,992.70 22.08 2,441.06 MWD (3) Interpolated AZI 8,895.56 89.39 142.66 6,394.78 6,289.08 - 185.15 - 2,704.57 5,959,826.93 547,007.02 21.00 2,438.91 MWD (3) Interpolated AZI 8,925.39 89.82 136.45 6,394.98 6,289.28 - 207.84 - 2,685.23 5,959,804.37 547,026.51 20.87 2,433.41 MWD (3) 8,950.61 90.71 133.41 6,394.87 6,289.17 - 225.65 - 2,667.38 5,959,786.68 547,044.47 12.56 2,426.77 MWD (3) 8,980.27 91.50 130.06 6,394.29 6,288.59 - 245.39 - 2,645.25 5,959,767.09 547,066.73 11.60 2,417.38 MWD (3) 9,010.53 92.06 130.78 6,393.35 6,287.65 - 265.00 - 2,622.22 5,959,747.63 547,089.88 3.01 2,407.14 MWD (3) 9,040.58 92.61 135.06 6,392.13 6,286.43 - 285.44 - 2,600.24 5,959,727.34 547,112.00 14.35 2,398.23 MWD (3) 9,070.17 93.16 139.34 6,390.64 6,284.94 - 307.12 - 2,580.17 5,959,705.80 547,132.21 14.57 2,391.58 MWD (3) 9,100.33 92.58 142.67 6,389.13 6,283.43 - 330.53 - 2,561.22 5,959,682.52 547,151.32 11.19 2,386.77 MWD (3) 9,130.52 93.50 146.98 6,387.53 6,281.83 - 355.16 - 2,543.85 5,959,658.00 547,168.84 14.58 2,383.95 MWD (3) 9,160.38 91.44 149.09 6,386.24 6,280.54 - 380.47 - 2,528.06 5,959,632.80 547,184.80 9.87 2,382.82 MWD (3) 9,190.37 88.65 151.54 6,386.22 6,280.52 - 406.52 - 2,513.21 5,959,606.85 547,199.82 12.38 2,382.88 MWD (3) 9,220.28 88.77 155.36 6,386.89 6,281.19 - 433.26 - 2,499.85 5,959,580.20 547,213.35 12.77 2,384.58 MWD (3) 9,250.41 87.33 158.87 6,387.92 6,282.22 - 461.00 - 2,488.14 5,959,552.54 547,225.25 12.59 2,388.20 MWD (3) 9,280.65 86.13 163.06 6,389.64 6,283.94 - 489.53 - 2,478.30 5,959,524.08 547,235.28 14.39 2,393.84 MWD (3) 9,310.34 86.34 167.07 6,391.59 6,285.89 - 518.15 - 2,470.66 5,959,495.51 547,243.10 13.50 2,401.44 MWD (3) iiik 9,340.17 86.22 171.31 6,393.53 6,287.83 - 547.38 - 2,465.08 5,959,466.32 547,248.87 14.19 2,411.13 MWD (3) ■ 9,370.08 86.77 175.32 6,395.36 6,289.66 - 577.03 - 2,461.61 5,959,436.70 547,252.54 13.51 2,422.84 MWD (3) 9,400.41 87.67 180.13 6,396.83 6,291.13 - 607.29 - 2,460.40 5,959,406.45 547,253.95 16.12 2,436.84 MWD (3) 9,430.21 88.03 175.35 6,397.95 6,292.25 - 637.04 - 2,459.23 5,959,376.72 547,255.32 16.07 2,450.61 MWD (3) 9,459.96 90.31 171.83 6,398.38 6,292.68 - 666.59 - 2,455.91 5,959,347.19 547,258.83 14.10 2,462.41 MWD (3) 9,490.31 91.63 167.68 6,397.86 6,292.17 - 696.45 - 2,450.51 5,959,317.37 547,264.42 14.35 2,472.57 MWD (3) 9,520.20 93.69 163.85 6,396.48 6,290.78 - 725.38 - 2,443.17 5,959,288.49 547,271.95 14.54 2,480.58 MWD (3) 9,550.22 94.86 159.27 6,394.24 6,288.54 - 753.77 - 2,433.71 5,959,260.17 547,281.61 15.71 2,486.48 MWD (3) 9,580.25 96.18 155.13 6,391.35 6,285.65 - 781.32 - 2,422.13 5,959,232.70 547,293.37 14.41 2,490.12 MWD (3) 9,610.26 93.41 153.42 6,388.84 6,283.14 - 808.26 - 2,409.15 5,959,205.85 547,306.52 10.84 2,492.25 MWD (3) ---...] 9,640.32 89.60 153.09 6,388.05 6,282.35 - 835.09 - 2,395.63 5,959,179.11 547,320.22 12.72 2,493.85 MWD (3) 9,670.19 86.50 150.62 6,389.07 6,283.37 - 861.41 - 2,381.55 5,959,152.89 547,334.47 13.27 2,494.71 MWD (3) 4/21/2010 11:16:22AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips E' Conoco Phillips Definitive Survey Report BAKER HUGHES Alaska ! Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E - 15 4 Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) i ' Well; 1E North Reference: TRUE I I • Welibore: 1E - 15 Survey Calculation Method: M inimum Curvature ____i Design: 1E -15 Database: EDM Alaska Prod v16 I Survey MD Inc Azi ND TVDSS +N/-S +E/.W Map Map DLS Vertical Northing Easting ° Section Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) (/100') (ft) • 9,700.26 87.70 147.25 6,390.59 6,284.89 - 887.13 - 2,366.06 5,959,127.28 547,350.13 11.88 2,494.05 MWD (3) 9,730.24 89.14 148.50 6,391.42 6,285.72 - 912.51 - 2,350.12 5,959,102.01 547,366.23 6.36 2,492.83 MWD (3) 9,760.35 90.95 149.93 6,391.39 6,285.69 - 938.37 - 2,334.71 5,959,076.25 547,381.81 7.66 2,492.32 MWD (3) 9,790.58 91.29 155.86 6,390.80 6,285.10 - 965.26 - 2,320.95 5,959,049.45 547,395.75 19.64 2,493.74 MWD (3) 9,820.37 91.78 160.41 6,390.00 6,284.30 - 992.89 - 2,309.86 5,959,021.89 547,407.02 15.36 2,497.85 MWD (3) 9,850.10 90.68 165.09 6,389.36 6,283.66 - 1,021.27 - 2,301.05 5,958,993.58 547,416.02 16.17 2,504.31 MWD (3) 9,880.44 90.43 171.10 6,389.07 6,283.37 - 1,050.94 - 2,294.79 5,958,963.95 547,422.47 19.83 2,513.63 MWD (3) 9,910.55 86.59 171.71 6,389.85 6,284.15 - 1,080.70 - 2,290.30 5,958,934.23 547,427.17 12.91 2,524.51 MWD (3) 9,940.29 82.98 171.15 6,392.55 6,286.86 - 1,109.98 - 2,285.88 5,958,904.98 547,431.77 12.28 2,535.24 MWD (3) 9,970.42 79.34 170.81 6,397.18 6,291.48 - 1,139.38 - 2,281.22 5,958,875.61 547,436.63 12.13 2,545.80 MWD (3) 10,000.24 75.73 170.36 6,403.62 6,297.92 - 1,168.10 - 2,276.45 5,958,846.93 547,441.58 12.20 2,555.94 MWD (3) ( 10,030.25 71.89 170.47 6,411.99 6,306.29 - 1,196.51 - 2,271.66 5,958,818.55 547,446.57 12.80 2,565.90 MWD (3) 10,060.13 68.00 169.81 6,422.23 6,316.53 - 1,224.16 - 2,266.85 5,958,790.94 547,451.56 13.18 2,575.47 MWD (3) 10,090.01 63.66 167.44 6,434.46 6,328.76 - 1,250.88 - 2,261.49 5,958,764.26 547,457.10 16.23 2,584.09 MWD (3) 10,135.00 63.66 167.44 6,454.43 6,348.73 - 1,290.23 - 2,252.72 5,958,724.97 547A66.12 0.00 2,596.04 PROJECTED to TD • 4/21/2010 11:16:22AM Page 4 COMPASS 2003.16 Build 69 v.-- C onocoPhilli Ps Alaska ConocoPhillips(Alaska) Inc. • Kuparuk River Unit Kuparuk 1E Pad 1 E- 15AL2 -PB3 50- 029 - 20769 -72 Baker Hughes INTEQ Fan • Definitive Survey Report BAKER HUGHES 21 April, 2010 1 v-- Conoco Phillips Nil Conoco Phillips Definitive Survey Report BAKER HUGHES Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: 1E-15 Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) ■ Well: 1E-15 North Reference: TRUE Wellbore: 1E-15 Survey Calculation Method: Minimum Curvature i Design: 1E-15 Database: EDM Alaska Prod v16 . --t Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level i Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point I Map Zone: Alaska Zone 04 Using geodetic scale factor • I Well 1E-15 Well Position +N/-S 0.00 ft Northing: 5,960,029.95ft Latitude: 70° 18' 5.686 N +E/-W 0.00 ft Easting: 549,710.04ft Longitude: 149° 35' 50.538 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft ---- . .. . Wellbore 1E-15AL2-PB3 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (*) () (nT) BGGM2009 3/25/2010 17.33 79.80 57,371 Design 1E-15AL2-PB3 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,200.26 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (*) • 105.70 0.00 0.00 250.96 Survey Program Date From To Survey Survey (ft) (ft) Survey (Wellbore) Tool Name Description Start Date End Date 200.00 7,500.00 1E-15 (1E-15) FINDER-MS SDC Finder multishot 8/25/2000 7,557.00 8,200.26 1E-15AL2-PB1 (1E-15AL2-PB1) MWD MWD - Standard 3/26/2010 3/29/2010 8,201.00 9,665.35 1E-15AL2-PB3 (1E-15AL2-PB3) MWD MWD - Standard 4/6/2010 4/8/2010 4/21/2010 11:19:22AM Page 2 COMPASS 2003.16 Build 69 •- ConocoPhillips regki ConocoPhillips Definitive Survey Report HUGHES KER Alaska I Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E I Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) I Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) ! Well: 1E North Reference: TRUE I Wel !bore: 1 E - 15 Datby Calculation Method: Minimum Curvdre Design: : 1E Database: EDM Alaska Prod v16 Survey MD Inc Azi TVD TVDSS +14/-S +E./..W Map Map DLS Vertical Northing Easting Section Survey Tool Name Annotation (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) (ft) ( 0 1100') (ft) • 8,200.26 89.79 152.38 6,412.48 6,306.78 412.51 - 3,057.82 5,960,422.18 546,649.85 1.36 2,756.02 MWD (2) TIP 1E 8,201.00 89.78 152.35 6,412.48 6,306.78 411.85 - 3,057.48 5,960,421.52 546,650.20 4.27 2,755.91 MWD (3) KOP 8,230.37 95.94 147.62 6,411.01 6,305.31 386.47 - 3,042.82 5,960,396.24 546,665.03 26.43 2,750.33 MWD (3) 8,265.48 101.90 141.85 6,405.57 6,299.87 358.16 - 3,022.82 5,960,368.07 546,685.21 23.48 2,740.66 MWD (3) 8,290.50 101.15 134.81 6,400.56 6,294.86 339.87 - 3,006.53 5,960,349.89 546,701.61 27.73 2,731.23 MWD (3) 8,309.99 100.22 129.57 6,396.95 6,291.25 327.01 - 2,992.35 5,960,337.12 546,715.88 26.85 2,722.02 MWD (3) 8,340.55 100.59 125.78 6,391.43 6,285.73 308.64 - 2,968.56 5,960,318.92 546,739.79 12.26 2,705.53 MWD (3) 8,371.78 102.28 123.85 6,385.23 6,279.53 291.17 - 2,943.44 5,960,301.61 546,765.03 8.12 2,687.47 MWD (3) 8,400.39 101.78 130.22 6,379.26 6,273.56 274.32 - 2,921.11 5,960,284.91 546,787.46 21.85 2,671.86 MWD (3) 8,425.51 99.69 137.60 6,374.58 6,268.88 257.21 - 2,903.35 5,960,267.93 546,805.33 30.04 2,660.65 MWD (3) 8,455.26 96.34 140.80 6,370.43 6,264.73 234.92 - 2,884.11 5,960,245.76 546,824.72 15.50 2,649.74 MWD (3) 8,480.29 95.11 147.12 6,367.93 6,262.23 214.79 - 2,869.46 5,960,225.73 546,839.50 25.60 2,642.46 MWD (3) 8,510.38 91.87 152.39 6,366.10 6,260.40 188.85 - 2,854.35 5,960,199.90 546,854.78 20.53 2,636.63 MWD (3) 8,540.48 91.26 160.15 6,365.28 6,259.58 161.33 - 2,842.25 5,960,172.46 546,867.06 25.85 2,634.17 MWD (3) 8,580.37 89.54 169.27 6,365.00 6,259.30 122.90 - 2,831.74 5,960,134.10 546,877.82 23.26 2,636.77 MWD (3) 8,610.43 90.25 175.50 6,365.05 6,259.35 93.12 - 2,827.76 5,960,104.35 546,882.00 20.86 2,642.72 MWD (3) 8,640.29 88.89 182.15 6,365.28 6,259.58 63.28 - 2,827.15 5,960,074.52 546,882.81 22.73 2,651.88 MWD (3) 8,670.38 88.71 184.32 6,365.91 6,260.21 33.25 - 2,828.84 5,960,044.48 546,881.31 7.23 2,663.28 MWD (3) 8,700.37 89.79 178.51 6,366.30 6,260.60 3.28 - 2,829.58 5,960,014.51 546,880.77 19.70 2,673.75 MWD (3) • 8,730.40 90.61 171.37 6,366.19 6,260.49 -26.61 - 2,826.94 5,959,984.64 546,883.62 23.93 2,681.00 MWD (3) 8,760.28 86.53 163.97 6,366.94 6,261.24 -55.77 - 2,820.57 5,959,955.53 546,890.18 28.27 2,684.49 MWD (3) 8,790.51 86.10 155.55 6,368.89 6,263.19 -84.05 - 2,810.14 5,959,927.32 546,900.79 27.83 2,683.86 MWD (3) 8,820.25 88.59 150.55 6,370.27 6,264.57 - 110.52 - 2,796.68 5,959,900.94 546,914.42 18.76 2,679.77 MWD (3) 8,855.35 93.32 145.91 6,369.68 6,263.98 - 140.34 - 2,778.21 5,959,871.25 546,933.09 18.87 2,672.04 MWD (3) 8,885.36 94.27 140.32 6,367.69 6,261.99 - 164.28 - 2,760.25 5,959,847.43 546,951.21 18.85 2,662.86 MWD (3) 8,915.53 90.55 132.76 6,366.42 6,260.72 - 186.14 - 2,739.53 5,959,825.71 546,972.07 27.90 2,650.41 MWD (3) 8,948.30 90.77 125.92 6,366.04 6,260.34 - 206.90 - 2,714.20 5,959,805.12 546,997.53 20.88 2,633.24 MWD (3) $ 8,981.98 90.68 116.10 6,365.62 6,259.92 - 224.23 - 2,685.37 5,959,787.99 547,026.47 29.16 2,611.64 MWD (3) 9,010.64 88.56 109.24 6,365.81 6,260.11 - 235.27 - 2,658.95 5,959,777.12 547,052.97 25.05 2,590.26 MWD (3) 9,040.53 90.21 112.62 6,366.13 6,260.43 - 245.94 - 2,631.04 5,959,766.63 547,080.94 12.58 2,567.35 MWD (3) 4/21/2010 11:19:22AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips teat Conoco Phillips Definitive Survey Report BAKER A IIKIGHES laska 1 Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: 1E j Project: Kuparuk River Unit TVD Reference: 1E-15 @ 105.70ft (1E-15) I Site: Kuparuk 1E Pad MD Reference: 1E-15 @ 105.70ft (1E-15) C Well: 1E North Reference: TRUE Welibore: 1E - 15 Survey Calculation Method: Minimum Curvature I Design: 1E-15 Database: EDM Alaska Prod v16 . __ Survey ..__� _____M___._.._ _ _ _.�____ � Map Map Vertical MD Inc Az! TVD TVDSS +N /-S +EI -W Northing Easting DLS Section Survey Tool Name Annotation (ft) (`) (1 (ft) (ft) (ft) (ft) (ft) (ft) rim (to III 9,070.52 89.72 118.85 6,366.15 6,260.45 - 258.96 - 2,604.03 5,959,753.80 547,108.03 20.84 2,546.08 MWD (3) 9,095.61 87.63 124.99 6,366.73 6,261.03 - 272.21 - 2,582.75 5,959,740.69 547,129.39 25.84 2,530.28 MWD (3) 9,120.05 88.77 130.92 6,367.50 6,261.80 - 287.23 - 2,563.50 5,959,725.80 547,148.74 24.70 2,516.98 MWD (3) 9,150.49 88.89 135.48 6,368.12 6,262.42 - 308.06 - 2,541.32 5,959,705.12 547,171.06 14.98 2,502.81 MWD (3) 9,180.12 86.31 141.51 6,369.36 6,263.66 - 330.21 - 2,521.71 5,959,683.09 547,190.81 22.12 2,491.50 MWD (3) 9,210.49 87.97 148.67 6,370.88 6,265.18 - 355.07 - 2,504.37 5,959,658.35 547,208.32 24.17 2,483.21 MWD (3) 9,240.68 85.21 154.10 6,372.67 6,266.97 - 381.51 - 2,489.94 5,959,632.01 547,222.92 20.15 2,478.20 MWD (3) 9,270.54 84.44 157.57 6,375.37 6,269.67 - 408.64 - 2,477.77 5,959,604.97 547,235.27 11.86 2,475.54 MWD (3) 9,300.44 90.58 160.83 6,376.67 6,270.97 - 436.55 - 2,467.17 5,959,577.13 547,246.05 23.24 2,474.62 MWD (3) 9,330.63 89.82 168.27 6,376.56 6,270.86 - 465.63 - 2,459.13 5,959,548.11 547,254.28 24.77 2,476.51 MWD (3) 9,360.27 89.79 173.99 6,376.66 6,270.96 - 494.90 - 2,454.56 5,959,518.87 547,259.04 19.30 2,481.74 MWD (3) 9,394.74 89.72 185.28 6,376.81 6,271.11 - 529.31 - 2,454.34 5,959,484.46 547,259.49 32.75 2,492.76 MWD (3) 9,425.27 90.34 188.08 6,376.79 6,271.09 - 559.63 - 2,457.90 5,959,454.12 547,256.14 9.39 2,506.01 MWD (3) 9,455.27 90.74 189.79 6,376.51 6,270.81 - 589.27 - 2,462.55 5,959,424.46 547,251.68 5.85 2,520.08 MWD (3) 9,485.49 90.43 185.48 6,376.20 6,270.50 - 619.21 - 2,466.57 5,959,394.50 547,247.86 14.30 2,533.64 MWD (3) 9,515.30 90.49 181.15 6,375.96 6,270.26 - 648.96 - 2,468.29 5,959,364.74 547,246.34 14.53 2,544.97 MWD (3) 9,545.19 90.74 177.25 6,375.64 6,269.94 - 678.84 - 2,467.87 5,959,334.86 547,246.95 13.07 2,554.32 MWD (3) 9,575.16 90.71 172.62 6,375.26 6,269.56 - 708.68 - 2,465.23 5,959,305.04 547,249.79 15.45 2,561.56 MWD (3) 9,605.48 90.74 169.06 6,374.88 6,269.18 - 738.61 - 2,460.40 5,959,275.15 547,254.82 11.74 2,566.76 MWD (3) • 9,635.42 89.60 164.17 6,374.79 6,269.09 - 767.73 - 2,453.48 5,959,246.08 547,261.94 16.77 2,569.71 MWD (3) 9,665.35 89.48 159.59 6,375.03 6,269.33 - 796.16 - 2,444.17 5,959,217.71 547,271.43 15.31 2,570.19 MWD (3) 9,710.00 89.48 159.59 6,375.44 6,269.74 - 838.01 - 2,428.60 5,959,175.97 547,287.27 0.00 2,569.12 PROJECTED to TD 4/21/2010 11:19:22AM Page 4 COMPASS 2003.16 Build 69 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:12 06:42 0.50 0 0 COMPZ CASING SFTY P PJSM, Crew change 06:42 09:42 3.00 0 1,967 COMPZ CASING PUTB P Pick up liner for AL2 -01 lateral. Run 59 Jts. 09:42 10:18 0.60 1,967 1,967 COMPZ CASING SVRG P Service injector and calibrate MM 10:18 11:36 1.30 1,967 7,467 COMPZ CASING RUNL P RIH with liner, closed EDC pumping .2 BPM 11:36 11:48 0.20 7,467 7,467 COMPZ CASING RUNL P Correct depth at flag, +5.65'. PUW 29K, RIW 11K 11:48 12:42 0.90 7,467 10,135 COMPZ CASING RUNL P RIH to TD 12:42 14:12 1.50 10,135 0 COMPZ CASING RUNL P Stacked 5K down and come on line with pump at 1.4 BPM, 4000 psi and PUH to realease liner, 23.5K PUW. POOH. 14:12 14:48 0.60 0 0 COMPZ CASING PULD P Lay down liner running BHA 14:48 15:30 0.70 0 0 PRODS STK PULD P PU anchored billet BHA 15:30 17:12 1.70 0 7,400 PROD5 STK TRIP P RIH 17:12 17:20 0.14 7,400 7,500 PROD5 STK DLOG P Tie in correlation, +2. 17:20 18:45 1.42 7,500 8,213 PRODS STK TRIP P Continue to at 25 FPM. Tag top of liner @ 8213.47'. PU off liner. PUW = 25K. PUH to 8211.25'. RBIH to 8213.3' and bring pump on line. Pressure up to 3800# and set anchor. PU off anchor = 26K. 18:45 20:45 2.00 8,213 0 PROD5 STK TRIP P Begin to POOH keeping hole full with 12.0 ppg KWF. 20:45 21:15 0.50 0 0 PRODS STK PULD P At surface. Monitor well for flow. PJSM. Lay down BHA #20. 21:15 21:23 0.14 0 0 PRODS STK BOPE P Function test BOP's. 21:23 22:59 1.60 0 0 PRODS STK PULD P PJSM. Begin PU BHA #21. Check packoff, all ok. 22:59 23:59 1.00 0 4,838 PROD5 STK TRIP P Open EDC. Begin to RIH. 04/06/2010 Kick off billet @ 8201' - continue to drill ahead. Total fluid losses for 24 hours 75 bbls. 00:00 00:30 0.50 4,838 7,374 PROD5 STK TRIP P Continue to RIH with BHA #21. Pumped a 10 bbl hi -vis pill to help recover KWF. Swap to flo -pro. 00:30 00:36 0.10 7,374 7,374 PRODS STK DLOG P Tie into formation marker @ 7374'. Correction of +2'. 00:36 01:36 1.00 7,374 7,542 PROD5 STK CIRC P RIH to 7542' stop and circ out KWF. Close EDC. 01:36 02:00 0.40 7,542 8,201 PRODS STK TRIP P Continue to RIH. 1.4 BPM, 4000# circ press., 4100 BHP, 450# diff press (free spin). Dry tag billet @ 8201.5'. PUW = 26K. PUH to 8178'. RBIH. 02:00 03:36 1.60 8,201 8,202 PROD5 STK KOST P RBIH. 1.4 BPM, 3875# circ press., 4160# BHP, 440# diff. press free spin. RIH wt = 9K #. Stalled on first two touches @ 8201'. Engaged on third attempt. Begin time drilling at 1' /hr. 03:36 04:06 0.50 8,202 8,203 PRODS STK KOST P Increase ROP to 2' per hour Page 19 of 35 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode - T Comment 04:06 04:30 0.40 8,203 8,204 PROD5 STK KOST P Increase ROP to 3' per hour 04:30 05:00 0.50 8,204 8,210 PROD5 DRILL DRLG P Increase ROP to 10' per hour 05:00 07:12 2.20 8,210 8,353 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM, 3900 CTP, 4140 BHP, 9K RIW, 24K PUW, 1 -3K WOB, 200 -400 motor work, 07:12 08:12 1.00 8,353 8,353 PROD5 DRILL WPRT P Wiper to window 08:12 11:06 2.90 8,353 8,510 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM, 3900 CTP, 4140 BHP, 9K RIW, 24K PUW, 1 -3K WOB, 200 -400 motor work. At 8445', wt. check PU 26K #. PU wt. off bottom = 27K 11:06 12 :42 1.60 8,510 8,510 PROD5 DRILL WPRT P Wiper to window. Above window to swap over from hi -line power to generator (DS work). Swapped over @ 12:00. 12:42 14:42 2.00 8,510 8,660 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM, 3900 CTP, 4140 BHP, 8500 RIW, 25K PUW, 1.5 - 2.5K WOB, 200 -400# motor work, 80 -95 ROP. Swap to new mud @ 8658' (14:40) 14:42 15:54 1.20 8,660 7,575 PROD5 DRILL WPRT P Wiper to window. PU wt. = 25K #. Make short trip to space out new mud at bit when on bottom. PUH to 8294' and RBIH to 8660'. Continue to PUH for wiper trip. 15:54 16:03 0.15 7,575 7,580 PROD5 DRILL DLOG P Tie into RA marker @ 7564. Correction = 0' 16:03 16:45 0.70 7,580 8,660 PROD5 DRILL WPRT P Wiper back to bottom. On way back to bottom stopped at 8600' and ran a MAD pass up to 8585'. 16:45 19:15 2.50 8,660 8,775 PROD5 DRILL DRLG P Continue drilling ahead. 1.42 BPM, 4100 CTP, 8500 RIW, 1 -2 WOB, 100 -300 motor work. PUH to 8000' while we swith from generator to hi -line power. Off of generator power © 18:00. Total generator time = 6 hrs. RBIH and continue drilling. 19:15 21:00 1.75 8,775 8,805 PROD5 DRILL DRLG P ROP slowing down, hard time getting good weight transfer to bottom. CT weight -4K, WOB 1.2, ROP 10 fph. P/U 3 times to get started on bottom. clean P/U weight - 26K. Losign roughly 3-4 bbls /hour. 21:00 23:00 2.00 8,805 8,805 PROD5 DRILL WPRT P Wiper trip - P/U weight 25K 23:00 00:00 1.00 8,805 8,861 PROD5 DRILL DRLG P Drilling ahead - 1.35 bpm, 4000psi, BHP 4150, ECD 12.7, WOB 1.4, CT weight 5K, ROP 50 fph. Total losses for 24 hours = 75 bbls 04/07/2010 Drille ahead to 9405'. POOh and P/U agitator & 1.0 AKO motor. 68 bbls lost for 24 hours. 00:00 01:30 1.50 8,861 8,960 PROD5 DRILL DRLG P Drilling ahead - 1.35 bpm, 4000psi, BHP 4160, ECD 12.7, ROP 70fph, CT weight 5K, WOB 2K. total 4 bbl /hour losses. Page 20 of 35 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 03:00 1.50 8,960 8,960 PROD5 DRILL TRIP P Wiper trip - 25K off bottom. Saw overpull @ 8800' while POOH. Saw 8800' when RIH. Correct TF, RIH with no problems 60 left. 03:00 05:00 2.00 8,960 9,110 PROD5 DRILL DRLG P Drilling ahead - 1.35 bpm, 4050psi, BHP 4180, ECD 12.8, ROP 65, WOB 1.8K, CT weight 4.5K. 05:00 05:54 0.90 9,110 7,580 PROD5 DRILL TRIP P Wiper trip to window. 05:54 06:06 0.20 7,580 7,590 PROD5 DRILL DLOG P Tie -in log. Correction = -2.5'. 06:06 07:00 0.90 7,590 9,110 PROD5 DRILL TRIP P Wiper back to bottom 07:00 13:45 6.75 9,110 9,260 PROD5 DRILL DRLG P Drilling ahead. 1.35 BPM, 4035 psi CTP, 4150 BHP, ECD = 12.94, ROP = 80 -110, WOB 1 - 2.75, CT WT = 2000 #. At 9151', PUW = 31K. RBIH, all ok but CT wt = - 1500 #. Continue drilling ahead. At 9158', 6.9 ROP with 2.75 WOB. PU wt. = 24K. Continue drilling. At 9159', 6.7 ROP. PU WT = 26k. Continue drilling with very low ROP. 13:45 15:45 2.00 9,260 9,260 PROD5 DRILL TRIP P Wiper to window. PU WT = 26.5K 15:45 17:30 1.75 9,260 9,403 PROD5 DRILL DRLG P Drilling ahead - 1.36 BPM, 4000 CTP, 4240 BPH, 13.05 ECD, 500 - 1200CTWT, WOB= 1.4 -2.5, 100- 150 ROP. Have been losing 5 bbls /hr all day. 17:30 20:30 3.00 9,403 71 PROD5 DRILL TRIP P Wiper trip to surface for BHA swap. 20:30 21:30 1.00 71 0 PROD5 DRILL PULD P Undeploy BHA 21:30 22:30 1.00 0 0 PRODS DRILL PULD P Make up BHA # 22 with agitator & 1.0 AKO. 22:30 23:30 1.00 71 71 PRODS DRILL PULD P Deploy BHA 23:30 00:00 0.50 71 9,403 PRODS DRILL TRIP P RIH 04/08/2010 Drilled ahead to 9710'. While RIH after wiper trip could not make it past 7857'. POOH to swap to 1.4 AKO also lost comms with BHA while POOH. P/U new BHA & RIH - could not make it past 7857'. Orientated around in 15 degree increments - no luck. POOH to P/U dummy liner BHA. Total mud losses for past 24 hours = 28 bbls. to the formation. 00:00 02:00 2.00 9,403 9,403 PRODS DRILL TRIP P RIH - Tie in +2 ft correction. Close EDC - RIH; small weight bobble @ 9280. Increased Claygaurd by 1% & lube 776 by .5 % while RIH. 02:00 05:00 3.00 9,403 9,560 PROD5 DRILL DRLG P P/U weight 25K. Start drilling - 1.30 bpm, circ 4300psi, BHP 4220, ECD 12.9, ROP 70, WOB 1k, CT weight 5.5K. Crossed fault @ 9518'. fluid losses slowed to 2 bbl /hour. 05:00 07:15 2.25 9,560 9,560 PRODS DRILL TRIP P Wiper trip - P/U weight 27K. Page 21 of 35 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 10:30 3.25 9,560 9,710 PROD5 DRILL DRLG P Continue drilling - 1.25 BPM, 4250 CTP, 4230 BHP, 13.01 ECD, 1.2 - 1.9 WOB, 40 - 70 ROP, CT WT = -2K - 2K. Stalled @ 9616'. PU WT. = a clean 30K. At 9690' pump 5 bbls each low /high vis sweep. 10:30 13:30 3.00 9,710 7,858 PROD5 DRILL TRIP P Wiper trip - PU wt. = 28K. Space out so that sweeps are at bit when on bottom. All good. Slight increase in returns from sweeps. On way back in the hole stacked wt. @ 7855' (bottom of build section). Make several attempts to pass. PU wts. are clean. Making adjustments to TF each time. Continue to sit down @ 7858'. Shut down pumps and make serveral attempts. Discuss options with town. Pull up into tbg above window and open EDC. Increase pump rates to 1 bpm. 13:30 15:30 2.00 7,858 0 PROD5 DRILL TRIP T Begin to POOH for BHA swap. On way out of hole lost communication with BOT equipment. EDC still open. 15:30 20:00 4.50 0 71 PROD5 DRILL PULD T At surface. Space out BHA such that we can place open EDC below deployment ram. Undeploy BHA #22. Tested electronics. All OK in the CT. Problem area is BOT's equip. Deploy BHA #23. * ** 1.5 hrs of NPT time to BHI for failed BHA at surface * ** 20:00 22:00 2.00 71 7,857 PRODS DRILL TRIP T RIH 300ft & test agitator. Open ECD - RIH. Tie in +2 ft correction. Close EDC. RIH through build pumping .3 bpm. 35 fpm - 60 Left. tagged up @ 7857'. P/U weight 25K. RIH HS, hard tag 7857', 30 right tag 7856.2'. Turn TF on bottom with light tag. P/U and try 180 - 7857' tag, Try 15 degree changes. 22:00 00:00 2.00 7,857 7,857 PROD5 DRILL TRIP T 15 degree changes starting @ 180 degree TF. No luck all the way around, P/U into cased hole and conference call. POOH for BHa change. 04/09/2010 P/U dummy !inner BHA and try to RIH through 7857'. No luck with multiple tries /pump rates. P/U RSM with Bi- center and tried to drill into same lateral with no luck. Start new lateral @ 7855'. Mud losses for the past 24 hours = 12 bbls to the formation. 00:00 02:00 2.00 7,857 77 PRODS DRILL TRIP T POOH for dummy liner assembly. 02:00 04:00 2.00 77 68 PRODS DRILL PULD T Undeploy BHA & P/U dummy Liner assembly (BHA #25). Page 22 of 35 ! • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 68 68 PROD5 DRILL CIRC T EDC open - pump at surface. Higher pressures. cycle EDC - still high pressures. Start undeploy procedure - Close rams - strip off to check ball valves. Fully opened. Strip down, tried to pump down again, still higher pressure. Problem above EDC to CT manifold. Start undeploy to check CT and upper Quick assembly. 05:00 08:45 3.75 68 68 PRODS DRILL PULD T Break off CT - Pumped through CT @ surface - pressures are good. Undeploy BHA. Blow air at 100 psi through BHA with no problem. Inspect fluid ports on guide shoe, and all ok. There are a total of 4 size 16 ports. 08:45 10 :30 1.75 68 7,395 PRODS DRILL TRIP T Begin to RIH. Pumping 0.3 BPM @ 1780 psi. While RIH performed rate test through BHA. During the testing BHP's were held constant via the tripping schedule. Rates /pressure were: 0.3 @1800; 0.5 @1850; 0.72 @2000; 1.0 @2550; and 1.3 @3200. This was with the EDC open. All appear good. 10:30 10:36 0.10 7,395 7,409 PRODS DRILL DLOG T Tie -in correction of +2'. 10:36 11:36 1.00 7,409 7,858 PROD5 DRILL TRIP T Close EDC and continue to RIH. Repeat rate /pressure test now that EDC is closed. Test results: 1.3 @3550 (3780 BHP); 0.75 @2350 (3861 BHP) ; 0.3 @1700 (3700BHP). Tagged up at 7857'. Increase pump rate to 1.3 BPM @ 3600 #. Make several attempts. Back pump rate down to 0.7 and make several attempts. Drop to min at 0.22 BPM for several attempts. Unable to pass trouble spot at 7858'. Total of 24 attempts made. 11:36 14:10 2.57 7,858 0 PRODS DRILL TRIP T Begin to POOH. 14:10 16:04 1.90 0 0 PROD5 DRILL PULD T At surface. PJSM. Undeploy BHA #25. 16:04 18:34 2.50 0 0 PROD5 DRILL SLPC T Prep floor for cutting CT. Cut 150' of CT. Make up CTC. Pull test CTC to 30K. Pressure test CTC to 4K. 18:34 20:34 2.00 0 0 PROD6 STK PULD T Injector inspection & Deploy BHA #26. 20:34 22:34 2.00 0 7,856 PROD6 STK TRIP T RIH pumping .4 bpm, following MPD. Tie +2 ft correction Page 23 of 35 ! i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:34 23:34 1.00 7,856 7,875 PROD6 STK KOST T Tag @ .5 bpm, P/U weight 25K. RIH @ .8 bpm, feather in from 7855'. Circ. press 2600, BHP 4000, Rib steer in off mode. 7855' - seeing WOB .5 K, circ. 3000 psi, BHP 3970, diff 767 psi. P/U & increase to 1.1 bpm - 3100psi free spin - 7855.2 - WOB .6K, - Stall again 4100 psi. P/U try 1.3 bpm. free spin 3580 - 7856.4' - WOB.7K, circ 3700psi, BHP 4088, diff 400psi, CT weight 10K, rib steer ON, ROP 6fph. Stick in nuetral - WOB 2.5 K, circ 3750, diff 600 psi, drilled off. 7856.8 break through - Circ press. dropped - Returns P/U to surface - WOB dropped off to 1K, Drilled to 7859' P/U 30 ft stacked @ 8760' -P /U and drill again. Drilled 15 ft with no indication of main hole - looks like new hole being drilled. ROP 50 fph, 3800psi, diff press 600psi. WOB 2K. 7875' P/U - 25K weight. 23:34 23:59 0.43 7,875 7,875 PROD6 DRILL TRIP T P/U and tried a run with no luck. Decision looks like a new hole is drilled startign @ 7856'. POOH to cased hole to reset parameters on BHI display and DD set up drilling - 04/10/2010 paremeters. Drilled ahead in L2 lateral. Perfromed mud swap & recorded 57 bbls losses for 24 hours. 00:00 01:00 1.00 7,875 7,875 PROD6 DRILL TRIP T POOH slowly to case hole, pump B /U. Sit and reset BHI display and DD work out drilling paremeters. RIH back to bottom. Order new mud. 01:00 04:45 3.75 7,875 8,025 PROD6 DRILL DRLG T Drilling ahead - 1.35 bpm, 4000 psi, BHP 4130, ECD 12.6, WOB 1.57, Ct weight 7.7K, ROP 40. Assumption we are to the right of the original hole. 04:45 05:30 0.75 8,025 8,025 PROD6 DRILL WPRT T Wiper trip - P/U weigth 25K. 05:30 08:30 3.00 8,025 8,175 PROD6 DRILL DRLG T Drilling ahead - 1.35 BPM, 4000 CTP, 4100 BHP, 12.65 ECD, 1.75 -2.75 WOB, 8K CT WT, 30 -60 ROP, 200 -300 motor work. 08:30 09:15 0.75 8,175 8,175 PROD6 DRILL WPRT T Wiper trip to window. PU wt. = 28K (RSM pads still engaged). 09:15 12:39 3.40 8,175 8,325 PROD6 DRILL WPRT T Drilling ahead - 1.35 BPM, 4100 CTP, 4180 BHP, 12.75 ECD, 1.75 - 3 WOB, 3 -7K ct wt, 30 -60 ROP, -200 motor work. 12:39 13:09 0.50 8,325 7,578 PROD6 DRILL WPRT T Wiper trip for tie in. PU wt = 27K. 13:09 13:15 0.10 7,578 7,595 PROD6 DRILL DLOG T Tie in correction = +.5' 13:15 13:45 0.50 7,595 8,325 PROD6 DRILL WPRT T Wiper trip back to bottom. Page 24 of 35 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 16:15 2.50 8,325 8,475 PROD6 DRILL DRLG T Drilling ahead - 1.35 BPM, 4080 CTP, 4275 BHP, 13.05 ECD, 4000 CT WT, 1.5 -3 WOB, 30 -60 ROP, 200 -300 motor work. At 8330' (13:45) swapped to new mud. 16:15 17:00 0.75 8,475 8,475 PROD6 DRILL WPRT T Wiper trip to window. PU wt = 27K. 17:00 19:00 2.00 8,475 8,625 PROD6 DRILL DRLG T Drilling ahead 19:00 20:00 1.00 8,625 8,625 PROD6 DRILL WPRT T Wiper trip to window P/U 26K 20:00 23:00 3.00 8,625 8,775 PROD6 DRILL DRLG T Drilling ahead -1.40 bpm, 4000psi, BHP 4080, ECD 12.5, WOB 2.4, CT weight 2K, ROP 30 - 40. Heavy oil embedded in sand samples from 8500 - 8650'. 23:00 00:00 1.00 8,775 8,775 PROD6 DRILL WPRT T Wiper trip with tie in. - 3ft correction. 04/11/2010 Drilled ahead to 9412' slow drilling from 9100 to 9430'. Pulled up to cased hole to have Safety Discussion with both ric, crews at 17:30 hrs. 25 bbls losses for 24 hours. 00:00 01:00 1.00 8,775 8,775 PROD6 DRILL WPRT T Wiper trip with -3ft correction 01:00 03:30 2.50 8,775 8,925 PROD6 DRILL DRLG T Drilling ahead - 1.40 bpm, 3900psi, BHP 4090, ECD 12.5, ROP 40, WOB 2.1, Ct weight 6K. 03:30 05:30 2.00 8,925 8,925 PROD6 DRILL WPRT T Wiper trip - 28K P/U weight. 05:30 07:15 1.75 8,925 9,075 PROD6 DRILL DRLG T Drilling ahead - 1.43 BPM, 3900 CTP, 4100 BHP, 12.68 ECD, 50 -110 ROP, 1.4 -2.4 WOB, 6K CT WT. 07:15 09:00 1.75 9,075 9,075 PROD6 DRILL WPRT T Wiper trip - 29K PU wt. 09:00 12:40 3.67 9,075 9,225 PROD6 DRILL DRLG T Drilling ahead - 1.40 BPM, 3950 CTP, 4108 BHP, 12.58 ECD, 40 -60 ROP, 2.5 -3.0 WOB, 850 CT WT. 12:40 13:40 1.00 9,225 7,657 PROD6 DRILL WPRT T Wiper trip - 31K PU wt. 13:40 13:55 0.25 7,657 7,600 PROD6 DRILL DLOG T Tie -in correction = -.5' 13:55 14:55 1.00 7,600 9,225 PROD6 DRILL WPRT T Wiper trip back to bottom. 14:55 16:10 1.25 9,225 9,298 PROD6 DRILL DRLG T Drilling ahead - 1.40 BPM, 4155 CTP, 4108 BHP, 12.78 ECD, 40 -60 ROP, 1 -3.0 WOB, 3 -4K CT WT. 16:10 17:28 1.30 9,298 7,530 PROD6 DRILL SFTY P Wiper trip to window for stand up safety meeting 17:28 18:28 1.00 7,530 7,530 PROD6 DRILL SFTY P PJSM, Park CT in cased hole for Stand up safety meeting. Hold managed pressure during meeting pumping 0.5 bpm. 18:28 19:58 1.50 7,530 9,298 PROD6 DRILL SFTY P RIH 19:58 23:59 4.03 9,298 9,412 PROD6 DRILL DRLG T Drilling ahead - 1.32 bpm, 4100psi, BHP 4190, ECD 12.8, ROP 20, WOB 2.2, CT weight 5K. Hit ankerite @ 9300'. Poor drilling most of the night. 04/12/2010 Drilled ahead to 10,013. Mud swap with 1590 ft. drilled on system. Page 25 of 35 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:18 1.30 9,412 9,450 PROD6 DRILL DRLG T Drilling ahead - slow ROP in until we cross the fault @ 9430'. Drilling break @ 9440' 01:18 04:18 3.00 9,450 9,450 PROD6 DRILL WPRT T Wiper trip - P/U weight 32K off bottom - cleaned up to 28K. RIH tagged up early @ 9425'. P/U and RIH slowly. 04:18 08:18 4.00 9,450 9,552 PROD6 DRILL DRLG T Drilling ahead - 1.40 bpm, 4000psi, BHP 4150, ECD 12.8, ROP 6 -50, WOB 2K, CT weight 5.5K. Good Rop until 9525' then slowed to 8 fph. 08:18 08:45 0.45 9,552 9,564 PROD6 DRILL DRLG T Break through Ankerite 08:45 09:00 0.25 9,564 9,620 PROD6 DRILL DRLG T Increased ROP, Drilling ahead - 1.40 bpm, 4130psi, BHP 4222, ECD 12.9, WOB 2K, CT weight 0 -1 K. ROP 75 -100 FPH. 09:00 11:00 2.00 9,620 7,560 PROD6 DRILL WPRT T Wiper trip to window 11:00 11:15 0.25 7,560 7,562 PROD6 DRILL DLOG T Tie in depth to RA marker. Correction= -1.5' 11:15 12:45 1.50 7,562 9,620 PROD6 DRILL WPRT T RIH to Drill 12:45 14:00 1.25 9,620 9,780 PROD6 DRILL DRLG T Drilling ahead - 1.40 bpm, 4130psi, BHP 4222, ECD 12.9, WOB 2K, CT weight 0 -1 K. ROP 75 -100 FPH. 14:00 16:15 2.25 9,780 9,780 PROD6 DRILL WPRT T Wiper Trip to 7875. 16:15 20:15 4.00 9,780 9,940 PROD6 DRILL DRLG T Drilling ahead - 1.40 bpm, 4230psi, BHP 4242, ECD 13, WOB 2K, CT weight 0-1K. ROP 75 -100 FPH. Slower ROP 20 - 30 from 9810', get set up for a mud swap. 20:15 22:30 2.25 9,940 9,940 PROD6 DRILL WPRT T Pump low /high sweep prior to wiper - P/U weight 30K Wiped up to 7900' to stay above shale area. Start pumping new mud RIH due to higher pressures and slow ROP's. (mud .8 % solids 1590 ft drilled). 22:30 00:00 1.50 9,940 10,013 PROD6 DRILL DRLG T Drilling ahead - new mud at bit. 1.40 bpm, 3900 psi, BHP 4140, ECD 12.7, ROP 70, WOB 2.2k, CT weight 6K. Had to P/U and re -boot BHI computer, correct +20ft continue drilling ahead @ 9970'. 04/13/2010 TD Well @ 10085, Run Liner to 10058', TOL @ 7701, Start BOPE Test, Witness waived by Jeff Jones 00:00 02:00 2.00 10,013 10,100 PROD6 DRILL DRLG T Drilling ahead - 1.40 bpm, 4000 psi, BHP 4160, ECD 12.7, ROP 40, WOB 2.6K, Ct weight 4K. Pump High /Low visc sweep on bottom 02:00 04:15 2.25 10,100 7,580 PROD6 DRILL WPRT T Wiper trip chasing sweep. P/U weight 30K. Pulled heavy @ 7830' 04:15 04:36 0.35 7,580 7,900 PROD6 DRILL WPRT T RIH to 7900' .75 BPM, 40FPM, POOH to window, Looks Good 04:36 04:51 0.25 7,900 7,580 PROD6 DRILL DLOG T Tie in Depth to RA marker -17' correction 04:51 06:03 1.20 7,580 10,085 PROD6 DRILL WPRT T RIH to TD. Page 26 of 35 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:03 08:48 2.75 10,085 0 PROD6 DRILL WPRT T Tag TD 10085'. POOH laying in Liner pill with Alpine beads chasing with KWF 08:48 09:03 0.25 0 0 PROD6 DRILL OWFF T Check for flow, Hold PJSM 09:03 10:03 1.00 0 0 PROD6 DRILL PULD T Looks good LD BHA - 10:03 13:33 3.50 0 2,400 COMPZ CASING PUTB T Safety meeting - P/U liner - safety joint drill 4 stands in 2 min. 45 secs. P/U 73 joints of liner in total. 13:33 14:33 1.00 2,400 2,400 COMPZ CASING PULD T P/U Coiltrak BHA - set in rams & strip over injector. 14:33 16:33 2.00 2,400 10,058 COMPZ CASING RUNL T RIH pumping . 3 bpm. Correct @ flag depth EOP. BHI depth + 4.5 ft. P/U weight 27K. above window. smooth through window. CT weight 13K RIH down to 10068' P/U 10 ft, Ct weight 35K.Set depth 10058' bottom & Liner top - 7701' 16:33 17:03 0.50 10,058 7,564 COMPZ CASING DLOG T P/U pump rate to 1.3 bpm, pressure 4200 psi, P/U and release off liner. _ CTT weight 23K. Stop pumping - POOH to RA tag for tie. Correction depth +1 ft. Liner top @ 7701'. Correct BHA depth. 17:03 18:33 1.50 7,564 0 COMPZ CASING TRIP T POOH - pumping KWF 18:33 18:51 0.30 0 0 COMPZ CASING SFTY T PJSM / Monitor well for flow. Well is dead 18:51 19:45 0.90 0 0 COMPZ CASING PULD T Pull off well and lay down BHA 27. 19:45 00:00 4.25 0 PROD7 STK BOPE T Begin Bi Weekly full BOPE witnes waived by Jeff Jones. AOGC 04/14/2010 Complete Full BOPE test. Set Anchored Billit @ 7701, P/U drill by BHA. Time mill off billit, drill build 00:00 04:45 4.75 0 0 PROD7 STK BOPE T Continue testing BOPE Witness waived by Jeff Jones AOGC. Test completed @ 0400, Install Checks back in UQC, Roll Coil back to KWF, Remove injector from well 04:45 06:45 2.00 0 73 PROD7 STK PULD T PJSM, M/U anchored billit BHA and Coil Trak BHA #28 06:45 08:45 2.00 73 7,700 PROD7 STK TRIP T RIH with EDC open pumping .3bpm. Tie in with +2 ft correction. Stop pumping and close the EDC. RIH through window. weight check @ 7695' - 26K. Orientate HS. Tag TOL @ 7700' - TOB @ 7689'. P/U neutral weight and bring pumps online. Anchor set at 3500 psi. POOH to window. 08:45 10:45 2.00 7,700 0 PROD7 STK TRIP T POOH pumping KWF. 10:45 11:45 1.00 0 0 PROD7 STK PULD T Lay down Billet BHA & P/U Build BHA with 2.5 AKO. Billet setting tool looked good, all parts intact. Page 27 of 35 ■...... 1 •"1E-15AL2 (Re-Drill) — AL2 Well Plan 07 1 •40"Parent Well 1E-15 Conoco Ph t357,4 Rae Well 1E-15AL2 Measured Depth Profile illi BAKER HUGHES —0— 1E-15AL2 PB1 —0— 1E-15AL2-01 PB1 —IP— 1E-15AL2-02 PB1 2 IFIC INTEQ Structural Cross-Section Interpretation —Top A6 Top A5 Top A4 -"'"••••■ Top A3 •Faults • Targets Polygon' IP- 6200 - 1 - ; ; ; ; , ; — ; i i i ; ; 4 i : 1 I , • . . I , . : ' ■ ' , : : . , . . . 4 1 -, -.1 : 4 -4 : : 4-- -4- -. Fault # 1 - - - 4__ _: ,_ ' . 1 Northis est I 'r 'r I I I Fault # 2 Southeast , Fault # A ; i -14 DTN I I I 1 i L ' -22' DTS - --•, k6 7 . . . , on-pa . ..."'" ' ■ 1E KOP 1 - i 4 I 4 4 A ■ r r 1- 1 4 , 1 Fq ---„ 7557'D i G ■ - ---"' ' fo werrion-p i 4 -i- -:: '', 1--- 1 1 4 4 ------ „ M/ , „- -, " i i ' - 1111 T ■ 1 I WV f l on _ aPPer Pa - 6225 , , : : , , , , . . . . . . , El n 14 pa ; ; ; ; -:" ; ; ; ' , . , ; . , , . „ , ; ; . „ . , , , 4_ 4_ _:. A4 MI Ind Als i Ill , . . 4 4 . . . 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' i=15 PM 1 1651 T WI ' , 0 __ •,,,; , - i1.6.0:1 00 1.Te d. ,: 010$110 , , 9710'MD/-6270'ss . - --- , ---- 4 ,- : - - - 1 -- : - .'. < ° . 4:'' o o o 0.-0-0o-o--o- ----- — - - - A5 P - 0---*-- . ,0 , _ 41.4 . , . , , P : • __;___ ____,____ -__ • - , on e . , •r , • ..._.....,....-_-„,-_-„,-....„_____,,____-,-_-:+:-=-- ,,__:_-_-_ .-- - ......„--..... • ,..• • , .• . . •• ..-_-_, ' '' 'ez#statilleigagg 6275 ; ; - - - - - - _ _ __ _ __ _ _ _ • ' - .; 1E-I5AL2-01 ., . ., . i ' • ...• . 1.. .•gri°16518 E• . A _ U A4 Pa i y _ _ L•__ Fe , • , . • .1.:2: • ' •.::: ...:::i..2 . 1.1: . L ".. ' - -... _ - i - . - i . _ .•_.1_ • . ' ' ..•,, . : : : . :_./ . : . I - , ;jet 4,,,,,„„ -_,-:,-,•-•NR 4210 - - , , , ; . ; • .1.•. .•. . .. . --4 . • °•...,. . '''.°'!"!'rrisiinu,,i-,' t - 1 1 --4--- 4 B - - - ., .,-..-..-.-• 1E-1 U A4 Pay 5AL2-02 .' ; 9 •`r.T. . . ., . . , . 7 . 7 •''' 7 ` _ • . . if 1 : 1 ' ' 1 - --+ -- - - --',-- --smai---- -.. ‘4.t. •-•-• t -.- • . •-: ..-4. : --- ippilll :• . *•:•:•:•: , • ., L A4 Pay ,.....,',.._ .. _. ..t .. :_..„. : .. U A4 Pay - rtri - - ' • . :-.'-:-;:'-:- wr •j- -3-. str''' Egiampr . _ _ , .... , . :::1::::: irgb •:•..,..,. i:•-..:,:•.•:,...:•.,:.- ..., • Est 1.4 PB1 KOP r ° ... • .., 6300 • M 011. 1, • : . _-._ _ ._ _ _ •ifiWr inwp. '''-‘ " a2.-11 ' . , , ;•• • . • . • . • . • .:• . • . • .} . • . • .1: • . 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A4 Pa , . ____I___ ,imi . . .., , • . , : . - ...no,— • -6325 4- I , , .• 1E-15AL2 - Well Plan 07 1' I 1E-15AL2 — ' , 1 , 1E-15AL2 PB1 TD: - 9 • - - PB1 KOP 9836'MD/-6332'ss ---"' , , .. ir , ;• . , , 1E-15AL2-01 PB1 TD: 4 - -7 1 1 ell A ___A___ ;. , F i 7 7 1 : i i -6350 7400 7600 7800 8000 8200 8400 8600 8800 9000 9200 9400 9600 9800 10000 10200 Vertical Exaggeration: - 8.3 x Measured Depth 4/12/2010 1E-15AL2 re-drill GeoSurvey.xls COI IOCOP�IIllI 5 C >� ll : G H 1\ 1'EQ E 1E-15AL2 Vertical Section (153) �1E -I5AL2 Surveys AL2 Well Plan 07 Parent Well 1E -15 - 1E-15A ■ et) NOT INTERPRETED 1 —0-- 1E-15AL1 — .-1E -15AL2 PB1 t 1E- 15AL2 -01 PB1 — .- 1E- 15AL2 -02 PB1 -6125 . ; , , , , , � i 1 ; ; r r 11, 11 111 111 11 111 -6150 � ' 1 E -15AL2 KOP 1:1 11 r r , 11 — III , ▪ T " -- i J ` f 4 T f, -f l - i 1 r f 1 f S ; - — -6175 lei it r __r . _ r , r 1; r , r i f , r , r T r , if _ _ ____ __ _ __ __ _ 11-1 __ 'rr , _ _ r_ __fit __ _ __. __ ____ Tr I 6200 1 1 I 1 I I t 1 1 1 1 1 1 1 1 I I I 1 1 I I I 1 ' 1 1 .? I I 1 1 1 1 1 1 I 1 1 I I I I I 1 1 1 1 t11 III I11 II 11 111 1E-15A KOP i I ill ▪ r TD: r - 1 , r r , r , r i ; ; i _i__�____ __�_ }__r_ _7__�_ _ __i__�_ r�_i _ i�_ �_i__ _ __r____ _ ; i r I III 6225 lE 15AL1 T ' 53 41 y _ J . ` : J 4 ` 33 S /fit i I 1 A i i r, :r ] - ; r r,, , r i- r , r , r PB1 KOP 1 -ISAL2 PB1 TD: E -02 -6250 ; ; ; I I i i! i - 355 /- 6270'ss 1 r 1E -15A TD o r 1 ... " • 6275 1E- 15AL21 . - III I � � °� ...:�• I Well Plan 07 4234'N 'S/-62 1 � 1E- 15AL2 -02 •. I • ' ` bbb o ; PBl KOP o L i ° a i D 4 i ooOp `: ........ • -6300 • : 1111 41111111k 1 , : 4 4 4 ; 0 lE O P `p i`._ 0 o i �O 1 • f ; 15AL1 K 4� � 1 11*iii: ` II 111 4 i 4 4 I ! 1 1 J 6325 — . , rr , ,r Parent Well 1E -15AL2 + 1E- L 2 PB1 T TD: l S/ 634 27 V - 9'ss IE 15 A ..... - 125 6332 PB1 KOP -6350 . . . . . .. . I . . . i , . . – - . . i , . . i . ' 1 ' -4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 Vertical Section r.'" 1121 —11-1 E -15AL2 L2 Well Plan 07 •Drillers Polygon Con ∎:• N Eb C1511 MN 1E -15AL2 ...is—Parent Well lE -15 - -1E -15A 1E -15AL2 PB1 tic INTEQ Horizontal Plan View _— 1 E- 15AL2 -01 PBI - - -4 1E- 15AL2 -02 PB1 • Faults 1200 mmi -- - - I F.- 15A1,2 KOP - - -- ismini, ly iii 800 Ai An._ iiiili Parent Well ' IE -1S - _~ 1E- t5AL2I J 1 - -- - - - PB1 KOP - - 600 , �tl 4_,,.._,___.,_ -- : --- iiiiii4RE_;_. 444.____,_i___ III _ _4 . v ` � 1E- 15AL2- 02 , 7. FBI KOP 400 H", , : I• 11.11011011 Milli • ! ts !N P ! II 200 • • nm Thro . v....... i sal DTN 1 1E- 15AL2 -01 • blD -�- -�--- _ --- - - - � � C � P81 KOP - -- S".. 200 -- _-_ Fault # t k 4 : - 14' DTN !LL Throw \ Z __ _ _ _ --F-'-'f--+H-",- NM •• t 400 . . , o -- ; L ' -- ',__ :___u_,_,_ Fault # 2 •• _;_; _� — _; Throw , i• _ :-- -; -- -600 _ _ ___ _ _ _ ' �� 21'DTS h V* _ - - ■ 1 � 1E- 15,AL2 -02 PBI TD: , 1F-15AL2 _ -- • -800 � , _838 _ , _ / -2428'E ■ Well Plan 07 ■ • 1E -15AL2 PB1 - _4__ ' ' ' ' ' - 1028'N/- 2291'E —t • A ' Q V O -1200 -- - -- -,- ' - - - - -- $ -- b 1400 TT-1.....011- IE- 15AL2 -01 PB1 TD: • - - --- - • 4-- _ _ - - 1290'N 1- 2253'E -1600 , , , , W W W W W N N N N N -.4 VI W — ‘.0 — L W sO O O O O O O O O O O O O O O O O O O O O O O Easting 1 J ppggqqqq \\ppAA §N L SEAN PARNELL, GOVERNOR - A ' t I .. ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 { FAX (907) 276-7542 Mr. Von Cawvey Alaska Wells Manager ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, Alaska 99510 -0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E -15AL2 ConocoPhillips Alaska Inc. Permit No: 210 -015 Surface Location: 443' FSL, 815' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 729' FNL, 2230' FWL, SEC. 21, Ti 1N, 10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re -drill the above referenced service well. The permit is for a new wellbore segment of existing well Kuparuk River Unit 1E-15A, Permit No. 2100130, API No. 50- 029 - 20769- 01 -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 inspe tor at (907) 659 -3607 (pager). inc - r - 1„ o r rman • mm ssioner DATED this 6° day of February, 2010 cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) . RECEIVED STATE OF ALASKA • JAN 2 6 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Make Oil & Gas Cons'Commissi 20 AAC 25.005 Anchorage la. Type of Work: • lb. Proposed Well Class: Development - Oil ❑ Service - Winj • ‘ Single Zone 0 . 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: U Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • 1 E - 15AL2 • 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 10150' • TVD: 6338' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 443' FSL, 815' FEL, Sec. 16, T11N, R10E, UM • ADL 25651 ' Kuparuk River Oil Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 669' FSL, 1434' FWL, Sec. 16, T11N, R10E, UM 469 3/25/2010 Total Depth: 9. Acres in Property: 14. Distance to ota Dept , 729' FNL, 2230' FWL, Sec. 21, T11N, R10E, UM 2560 Nearest Property: 24400' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 102 feet 15. Distance to Nearest Well Open Surface: x - 549710 ' y - 5960030 • Zone 4 GL Elevation above MSL: 41 feet to Same Pool: 1E-16 @ 675' , 16. Deviated wells: Kickoff depth: 7557 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 95* deg Downhole: 4895 psig Surface: 4264 psig . 18. Casing Procram: 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 1650' 8500' 6276' 10150' 6338' 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) 8435' 6936' 8323' 6848' 7884' Casing Length Size Cement Volume MD TVD Conductor /Structural 112' 16" 326 sx AS 1 112' 112' Surface 2155' 10.75" 1025 sx AS III, 250 sx AS II 2193' 2193' Intermediate Production 8376' 7" 605 sx Class G 8410' 6916' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 7478'- 7554', 7716'- 7739', 7742' -7796' 6190'- 6249', 6375'- 6393', 6396' -6438' 20. Attachments: Property Plat ❑ BOP Sketch 0 Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. G. Eller @ 263 - 4172 \V.,.._ Printed Name V. Cawve Title Alaska Wells Manager Signature )7.0..-00"" A Phon - 6306 Date 1 /Z.41zJf 0 Commission Use Only Permit to Drill API Number: / 1 Date: Permit Approval / See cover letter Number: j�.t6; / (1 50.6)z_.° 0- r✓ ' 4' C6 2� /� } for other requirements Conditions of approval : If box is checked, well - may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: * Selo() pS /. //� —ll P 1 C5 tt— Samples req'd: Yes ❑ No _ Mud log req'd: Yes ❑ No [Y Other: ,L2 J ro o p Ann J evr 7;:v- H2S measures: Yes R No ❑ Directional s req'": Yes [l No ❑ - a -,a... 4t.r.i. ie.. 1; 4 co � I w/ A/O Z J gi(er Flew beu� n (� I j�'� DATE: 1 1 K I I -°t I ,i P.*.VEDBYTHECOMMSION Form 10-401 (Revised 7/2009) This permit is valid for 24 months from t date of approval (20 .E ' (g)) Submit in Duplicate .7 -e.— / t /a / v �.Z /'''" I 2-7 /C RECEIVED ConocoPhillips JAN 2 6 2010 Alaska Alaska 0118 Gas Cena. Commission P.O. BOX 100360 Anchorage ANCHORAGE, ALASKA 99510 -0360 January 25, 2010 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-15 (PTD# 182 -102) using the coiled tubing drilling rig, Nabors CDR2 -AC. Work is scheduled to begin on 1E-15 in late March 2010. The CTD objective is to drill four A -sand lateral sidetracks (1E-15A, 1 E- 15AL1, 1 E- 15AL2, and 1 E- 15AL2 -01). The original wellbore perforations will be plugged with cement and a bridge plug 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-15A, 1 E- 15AL1, 1 E- 15AL2, 1 E- 15AL2 -01 . - Proposed & Current Wellbore Schematic - BOP Schematic - Detailed Summary of Operations - Directional Plans - Sundry application for plugging the KRU 1 E -15 motherbore If you have any questions or require additional information please contact me at my office 907 - 263 -4172. Sincerely, Gary Eller ConocoPh s Alaska Coiled Tubing Drilling Engineer • . KRU 1E -15A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Summary of Operations: Well 1E-15 is a Kuparuk A -sand and C -sand injection well equipped with 31/4" tubing x 7" casing. Four proposed A -sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling, the existing C -sand in 1E -15 will be squeezed with cement and the A -Sand perfs will be plugged with a bridge plug. After squeezing the existing C -sand perfs with cement, a mechanical whipstock will be placed in the 3Y2" tubing at the first kickoff point. The 1E -15A sidetrack will make a 2 -string exit through the 3'/2" tubing and 7" casing at 7635' MD. It will target the A4/5 sand northwest of the existing well with an 1890' lateral. The hole will be completed with a 2%" slotted liner to the TD of 9525' MD with a liner top aluminum billet at 8400' MD. The 1E -15AL1 lateral will kick off from the aluminum billet at 8400' MD and will also target the A4/5 sand northwest of the existing well with a 430' lateral. The hole will be completed with a 2%" slotted liner to the TD of 8830' MD with the final liner top located just inside the 3%2" tubing at 7630' MD. The 1E-15AL2 lateral will make another 2 -string exit through the 3'/2" tubing and 7" casing at 7557' MD via a second mechanical whipstock placed in the 3 %2" tubing. It will target the A4 sand southeast of the existing well with a 2593' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,150' MD with a liner top aluminum billet at 8500' MD. The 1E- 15AL2 -01 lateral will kick off from the aluminum billet at 8500' MD and will target the A4/5 sand southeast of the existing well with a 1575' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,075' MD with the final liner top located just inside the 3'/2" tubing at 7550' MD. CTD Drill and Complete 1E -15: March /April 2010 Pre -Rig Work 1. Test packoffs — T & IC. 2. Positive pressure and drawdown tests on MV, SV, & SSSV. 3. DGLV's, load tbg & IA. MIT -IA. MIT -OA. 4. Obtain updated static BHP on A -sand & C -Sand 5. Pull tubing patch isolating injection mandrel at 7592' 6. Dummy injection mandrels at 7354' & 7452' 7. Set 3'/2" CIBP at 7679' MD to plug off A -sand perfs 8. Shoot squeeze perfs thru the 3'/2" tubing and 7" casing at 7630' & 7552' ELM 9. Lay in cement on top of CIBP isolating A -sand. Squeeze the C -sand perfs with cement. 10. RU slickline. Tag cement top. Pressure test cement squeeze. 11. Drill out cement from the 3'/2" tubing to 7665' using special clearance bi- center bit 12. Run whipstock dummy 13. Set monobore whipstock at 7635' MD with high -side orientation. 14. Prep site for Nabors CDR2 -AC. Page 2 of 5 ORIGINAL January 25, 2010, FINAL • . KRU 1E-15A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7 -1/16" BOPE, test. 2. 1E -15A Lateral (A4/5 sand, northwest) a. Mill 2.74" 2- string window with high -side orientation at 7635' MD. b. Drill 2.70" x 3" bi- center lateral to TD of 9525' MD. c. Run 2%" slotted liner with an aluminum liner -top billet from TD up to 8400' 3. 1E -15AL1 Lateral (A4/5 sand, northwest) a. Kick off of the aluminum billet at 8400' MD b. Drill 2.70" x 3" bi- center lateral to TD of 8830' MD. c. Run 2 slotted liner from TD up to 7630' MD, up inside the 7" casing 4. 1E -15AL2 Lateral (A4 sand, southeast) a. Set 3'/2" monobore whipstock in 3'/2" tubing at 7557' MD with low -side orientation. b. Mill 2.74" 2- string window with low -side orientation at 7557' MD. T hiS c. Drill 2.70" x 3" bi- center lateral to TD of 10,150' MD. ,°T2 d. Run 2 slotted liner with an aluminum liner -top billet from TD up to 8500' 5. 1E- 15AL2 -01 Lateral (A4/5 sand, southeast) a. Kick off of the aluminum billet at 8500' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,075' MD. c. Run 2%" slotted liner from TD up to 7550' MD, up inside the 3 tubing 6. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Post -Ri! Work 1. Obtain static BHP 2. Run GLVs 3. Flow back well to tanks or to the system for clean up prior to putting on injection 4. Conduct MIT -IA 5. Put well on injection Mud Program: • Will use chloride -based Biozan brine or used drilling mud (8.6 ppg) for milling operations, and chloride - based Flo -Pro mud ( -10.0 ppg) for drilling operations. There is a SCSSV installed in 1E -15, so we should not have to kill the well to deploy 2%" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1E -15A: 2% ", 4.7 #, L -80, ST -L slotted/solid liner from 8400' MD to 9525' MD • 1E- 15AL1: 2% ", 4.7 #, L -80, ST -L slotted /solid liner from 7630' MD to 8830' MD • 1E- 15AL2: 2% ", 4.7 #, L -80, ST -L slotted/solid liner from 8500' MD to 10,150' MD • 1E- 15AL2 -01: 2% ", 4.7 #, L -80, ST -L slotted/solid liner from 7550' MD to 10,075' MD Existing Casing/Liner Information Surface: 10 ", K -55, 45.5 ppf Burst 3580 psi; Collapse 2090 psi Production: 7 ", K -55, 26 ppf Burst 4980 psi; Collapse 4320 psi Page 3 of 5 ORIGINAL January 25, 2010, FINAL • • • Tubing KRU 1E -15A, AL1, AL2, AL2 -01 — Coiled g Drillin g Well Control: • Two well bore volumes ( -180 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • 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 5000 psi. Maximum potential surface pressure in 1E -15 is 4264 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity, which is 4895 psi at 7633' MD, 6310 TVD (i.e. 14.9 ppg) from 1E -15 itself in late November 2009. Since that time, the A -sand has been allowed to crossflow to the lower - pressure C -sand, so the formation pressure in the A -sand is now reduced. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 1E -15A, plan #3 2. 1E- 15AL1, plan #3 3. 1E- 15AL2, plan #5 4. 1E- 15AL2 -01, plan #5 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 1E -15 CTD northwestern laterals (A & AL1): —26,100' to property line, —1015' to wells 1E -11 & 1E -13 • 1E -15 CTD southeastern laterals (AL2 & AL2 -01): —24,400' to property line, —675' from well 1E -16 Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 1E -15 was taken January 2010 after allowing the A -sand to cross flow to the lower pressure C -sand for a month. The 72 -hour buildup measured reservoir pressure of 3719 psi at 6238' SSTVD, corresponding to 11.5 ppg EMW. We generally expect to encounter decreasing pressure as the laterals are drilled away from the mother well due to offset producing wells. Hazards • Lost circulation is usually not particularly troublesome in the A -sand, but it is a possibility in 1E -15 since we expect to encounter decreasing formation pressure as the laterals are drilled away from the mother well. • Over - pressured zones are a potential hazard in 1E -15. Even though cross flow to the C -sand has significantly reduced A -sand pressure in the 1E -15 wellbore to 11.5 ppg, there is opportunity to encounter high- pressure stringers (up to 15.0 ppg) while drilling. With 10.0 ppg mud and expected formation pressure, no choke pressure is needed to maintain well control. If high pressure formations are encountered, a combination of mud weight and/or choke could be needed to maintain well control. Use of the SSSV to deploy slotted liner should eliminate the need to spot heavy kill weight fluid, but if the SSSV fails then completion fluids in excess of 13.0 ppg will be needed to kill the well. • Shale stability is a potential problem, particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70° hole angle, and by holding a constant pressure on the formation throughout drilling operations. • Well 1E -15 has no measured H since it is an injection well. Well 1E -31 is located 105' to the right side and 1E -16 is 120' to the left side of the 1E -15 surface location. 1E -16 has no measured H since it also is an injection well. Well 1E -31 has 60 ppm H as measured on 8/6/09. The maximum H level on the pad is 130 ppm from well 1E -24A (8/6/09). All H monitoring equipment will be operational. nn! r Page 4 of 5 CY ! << January 25, 2010, FINAL • • KRU 1E-15A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 1E -15 has a SCSSV, so the well should not have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Expected reservoir pressure is 3711 psi at 7635' MD (6206' SSTVD), or 11.5 ppg EMW. • Expected annular friction losses while circulating: 763 psi (assuming annular friction of 100 psi /1000 ft due to the 3'h" tubing) • Planned mud density of 10.0 ppg equates to 3227 psi hydrostatic bottom hole pressure at 6206' SSTVD • While circulating 10.0 ppg mud, bottom hole circulating pressure is estimated to be 3990 psi or 12.4 ppg EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1E -15. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, —760 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Quarter - Mile Injection Review The following wells lie within one - quarter mile of the proposed 1E -15 CTD laterals. A detailed review will be made of each of these wells separately and subsequently to the submission of the drilling permits. • 1E -15 motherbore (injector) • 1E -15 CTD northwestern laterals (A & ALI): • 1E -11 (injector) • 1E -13 (injector) • 1F -19 (producer) • 1E-15 CTD southeastern laterals (AL2 & AL2 -01): • 1 E -06 (producer) • 1E -14 (producer) • 1E -16 (injector) • 1E -17 (injector) • 1E -30 (injector) Page 5 of 5 fJ Jl / January 25, 2010, FINAL KUP • 1 E -15 ConocoPhillips iNe li A ttributes MaX e M id . I (S r : ; r te r ,- ,p Wellborn API/U WI Field N Well Status Inc/ () MD (ftKB) Act Blm (ftKB) Canoidtl Alaska, )" 7l Ips ^, 500292076900 KUPARUK RIVER UNIT I INJECTING 49.62 3,80000 8,435.0 - -. _ Comment H25 (ppm) Dale Annotation 614 te KB-GM (ft) Rig Release Date "' SSSV: TRDP -- - 0 8/18/2008 Last WO 11/5/1984, 40.71 8/4/1982 _ « WW Ponta -.1-E 1,s-!¢rt44kJk.36'S$.A � Last sdlcnsae &401 -.. ..,.,.;;: A tM Depth MKS) End Date Annotate Mod BY End Dale Last Tag SLM 7,848 0 L6/13 2009 Rev Reason: SET STRADDLE PATCH tnphe) 7/8/2009 - 6a sutg tnn as String OD String ID Set Depth Set Depth (TVD String Wt String Casing Description (in) (in) T.. f9K: (8IKB) . (ftX6) gbe/f0 Grade String Top Turd CONDUCTOR, `+y CONDUCTOR 16 1f. 060 32.0 112.0 V 112.0 65 - 00 H 112 - -- „ SURFACE �10 3/4 9 794 0.0 2,193.0 ' 2,192.9 45.50 K-55 SAFETY VLV, PRODUCTION 7 Y 151 0.0 8 410 0 6,916.2 26 00 K 55 $76 7Ub1'Iiat17rIgS ,..> 'S- W _. r „G r * s- .,,�,,a v ., _,'!a -- mh s` `r GAS LIFT. . Stnng OD String ID Set Depth set Depth (fVD) String Wt String 1,946 - Tubing Descrt to (in) (Inl Top OMB) MS) (ftK8) (Ibs/ff) Grad StnngTop Thrd TUBING 3 1/2 2 992 0.0 7,682.0 6348 6 920 J-55 BTC IPC RFACE._ SU r ett ti / n '"' - :- -. rn�a v 2,193 D oter o H(sie=(4ll. Jewelry. TWbiiikRtifieRetneulk abA ,- . r.. Top Depth . • (TVD) Top Intl GAS 3 90 Top (ftKB) (SKB) (' Descrip9em -_ Comment Run Date ID (5,) 1,878 1.877.9 1.69 SAFETY ?4V Calrlco TROP - to -ENC 11/5/1984 2.813 GAS LIFT, - 1,948 1,947.9 1.46 GAS LIFT CAMCO/KBUG/1IDMY//// Comment: STA 1 6/5/1990 2.875 5216 3,690 3,504.6 46.83 GAS LIFT CAMCO /KBUG /1/DMY //O Comment STA 2 6/5/1990 2.875 5,218 4,524.6 45.86 GAS LIFT CAMCO/KBUG/1/DMY//// Comment STA 3 6/5/1990 2875 GAS LIFT, _ 6,256 5,252.5 43.86 GAS LIFT CAMCO/KBUG/1IDMY//// Comment STA 4 11/5/1984 2.875 6,256 ' lit 6,291 5,277.7 43.53 GAS LIFT CAMCO /KBUG/I/DMY //// Comment STA 5 6/3/1990 2.875 GAS LIFT, 7,271 6,026.3 37.97 GAS LIFT CAMCOIKBUG/1/DMY / /// Comment STA 6 6/5/1990 2.875 - 6291 3 7,307 6,054.7 38.07 PBR Baker PBR - 11/5/1984 3.000 7,321 6,065.7 38.11 PACKER Baker'FHL' PACKER 11/5/1984 3.000 P. GAS LIFT, 9- 7 6,091.6 38.20 INJECTION CAMCO /KBUG /1/DMY / /// Comment CLOSED STA 7 7/20/1993 2.875 7271 ' 7,425 6,147.4 38.44 INJECTION CAMCO/KBUG/1/DMYO/1 Comment CLOSED STA 8 7/20/1993 2.875 7,575 6,264.9 38.42 PACKER PATCH: UPPER WEATHERFORD ER PACKER 2.87" OAL 7/6/2009 1.750 PBR, 7,307 ` -:y (GOOD TEST TO 2500#) 7,578 6,267.0 38.42 PATCH PATCH: SPACER PIPE, SNAP LATCH, SEAL ASSY OAL 7/6/2009 1.750 22.22" OAL (25.09" BETWEEN ELEMENTS) PACKER, 7,321 7,592 6,278.2 38.42 INJECTION - - -- CAMCO/KBUG/1/DMY//// Comment CLOSED STA 9 7/20/1993 2.875 7,602 6,286.4 38.89 PACKER. PATCH: LOWER WEATHERFORD ER PACKER 2 -87" OAL 7/3/2009 1.750 INJECTION, 7,663 6,333.8 38.78 PACKER Baker PACKER 11/5/1984 4.000 .. 7,356 7,676 6,344.0 38.76 NIPPLE Camco'' Nipple NO GO 11/5/1984 2.750 _ D 7,682 6 38.75 SOS Baker 11/5/1984 2.992 INJECTOR, -- ___ __..._ - _ - . - .- 7425 7,682 6,348.6 38.75 TTL 11/5/1984 2.992 a il ` 7,884 6,506.5 38 -52 FISH VANN GUN LOST DOWNHOLE B /12/1993 8/12/1993 0.000 IPERFS. S,5, ; ' x _ _ .. (: yk` �;5 °�v"° 'G ' ..t�"�,.„ F' , ;31 ... rn"a. _,,, - .:.. '. , '" 7A78 -7.556 Yerforaftouis S Shot Top 476(0) Btm (NO Dens PACKER, 7,575 Top (980) 8ten(ft18) (61(8) (6655) Zone Date ( Type „� - Comment PATCH, 7,576 7,478 7,554 6,188.9 6,248.5 C-4, C -3, C-1, 8/12/1982 12.0 IPERFS GEO VANN GUNS UNIT B, 1E -15 4 , INJECTION, - 7,716 7,725 6,375 -2 6,382.2 A5, 1E -15 8/12/1993 4 -0 RPERF 2.5" Titan Follow Carrier guns, 180 7292 deg phase, 96 deg CCW orient 7,723 7,732 6,380.6 6,387.7 A-5, 1E -15 8/12/1982 12.0 IPERFS GEO VANN GUNS PACKER, 7,602 - 7,730 7,739 63861 6,393.1 A-5, A-4, 1E -15 11/5/1984 12.0 RPERF SCHLUMBERGER GUNS ;` - 7,742 7,769 6,395.5 6,416.6 A4, 1E-15 8/12/1993 - 4.0 RPERF 2.5" Titan Hollow Carrier guns, 180 deg phase, 96 deg CCW orient PACKER, 7,663 - -- „ _ 7,749 7,776 6,401.0 6,422.0 A-4, 1E -15 8/12/1982 _ 12.0 IPERFS GEO VANN GUNS 7,756 7,783 6,406.4 6,427.5 A 1E -15 11/5/1984 12.0 RPERF SCHLUMBERGER GUNS NIPPLE, 7,676 7,775 7,782 6,421.3 6,426.7 A-4, 1 E -15 8/12/1993 4.0 RPERF 2.5" Titan Hollow Carrier guns, 180 deg phase, 96 deg CCW orient SOS, 7,662 - Z 7,782 7,789 6,426.7 6,432.2 A4, IE -15 8/12/1982 _ 12.0 IPERFS GEO VANN GUNS TTL, 7.662 7,789 7,796 6,432.2 6,437.7 A 1E -15 11/5/1984 12.0 APERF SCHLUMBERGER GUNS "StllTllll$t1(N Weri gefiar `- ,".-`- te-,. c o,.a- .-.;.., `el 4: it r . ,rc„ RPERF, - - BoHM1 7,716 -7,725 Min Top Max Dim Top Depth Depth I,' - c' Depth Depth (TVD) (TV0) l' . _ - - MEI) (RK8) (ftKB) (ftKB) T 1• - Date Comment IPERFS, :I 7,716.0 7,796.0 6,375 -2 6,437_7 A -SAND 8/19/1993 A4/A5 SAND RE -FRAC, PUMP 193,3978 BEHIND 7,723 RE -FRAC PIPE is 7 ,730.0 7 796 0 6386 1 6,437..7 FRAC 12/17/1984 A -SAND FRAC RPERF,_ Nrx G eneral 8<Sd etV - . _ _ 547 a ^ x ��, r 7.730 -7.739 I - t ! _ i End Date Annotation 5/24/2009 NOTE C - SAND LEAK FOUND @ 7596' ELMD AROUND GLM #9 RPERF, A -SAND .� RE -FRAC, 7,716 IPERFS, 7.7497,776' - - 1 FRAC, 7,730 - RPERF, , . 7,756-7,783 ( RPERF, . - I.. 7,775-7,782 ' ' ERFS, - _ - 7,782 IP -7,789 APERF, f 7,7897,796 7 i t _ FISH, 7,884 _ PRODUCTION. _ Q R1G JNAL ... TD, 8.435 .,......,._ . + 1E-15 Proposed CTD Sidetrack Last Updated: 21- Jan -10 3 -1/2" Camco TRDP -1A nipple @ 1878' MD MIN ItT 3 -1/2" 9.3# K -55 EUE 8rd Tubing to surface Mil 3 -1/2" Camco KBUG gas lift mandrels @ 1948', 3690', 5218', 6256', 7271' 16" 65# H -40 shoe @ 112' MD MT0a1- Baker 3 -1/2" PBR @ 7307' MD Vi a'' tit,- Baker FHL packer @ 7321' MD , -- 3 -1/2" Camco KBUG injection mandrels @ 7354', 7425', 7592' 10 -3/4" 45.5# K -55 shoe @ 2193 MD ■ Carbide blast rings 7446' - 7552' (7452' -7538' CBL) I .=:1 Baker FB -1 packer @ 7575' MD w/ Baker SBE • 1_ 3 -1/2" Camco D landing nipple @ 7676' MD (2.75" min ID, No -Go) 3 -1/2" tubing tail @ 7682' MD II', ?k ,41911 11 CD C-sand perfs 7478' jt Top of cement at injection —yD 7554' MD mandrel #8 for C -sand perfs - I �-- AL2 -01 Lateral (A5 sand, southeast) �� % \ \� TD = 10075' ----® \ Liner top at 7550' «...� KOP #2at7557`MD KOP #k1 of 7635' MD '" Baker flow- by :monobore , % ----_- --------- — AL2 Lateral (A4 sand, southeast) r whipstocks % j . \ 7 TD= 10150' . E — _ _ _ _ — _ Billet at 8500' err : orris- AL1 Lateral (A5 sand, northwest) TD = 8830' A -sand perfs 7716' - I'L Liner top at 7630' 7796' MD (plugged) mow-- A Sidetrack (A4 /A5 sand, Northwest) CIBP at 7679 (y1D a ,. TD = 9525' 7" 26# K -55 shoe @ ,tz1 ` =„ �,, ,,;,, � f ' „3+ �1, , !; Billet at 8400' 8410' MD . 1 Nabors CDR -2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing N l 1 1 1 Lubricator t. \1 Riser r Annular Blind / Shear 2" Pipe / Slip (CT) - Pump into Lubricator� L , • I . r ■ — I , - 1 ■•■ me above BHA rams P � I I Choke l 11 2 -3/8" Pipe / Slip (BHA) IN Choke Equalize Manifold 1 2 -3/8" Pipe / Slip (BHA) ; ' J L - - MI Kill ► > ><><1 'P 4 i [...__.. - - - 1 r 1 10 Blind / Shear 2" Pipe / Slip (CT) IN 11 Choke 2 11 Swab Valves V IN Wing Valves i0 %Iie� Tree Flow Cross 1 r 0 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 • • s Cono oPh i r s Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E -15 1 E -15AL2 Plan: 1 E -15AL2 wp05 Standard Planning Report 13 January, 2010 Sri BAKER HUGH PRIMAL • r ConocoPhillips FAWN Conoco Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1E -15 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1E -15 @ 105.70ft (1E -15) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-15 Survey Calculation Method: Minimum Curvature Wellbore: 1E-15AL2 Design: 1 E- 15AL2_wp05 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 1E Pad Site Position: Northing: 5,959, 60.24ft Latitude: 70° 18' 3.022 N From: Map Easting: 549,889.51ft Longitude: 149° 35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38 ° Well 1E -15 Well Position +N / -S 0.00 ft Northing: ',960,029.95 ft Latitude: 70° 18' 5.686 N +E / -W 0.00 ft Easting: 549,710.04 ft Longitude: 149° 35' 50.538 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1 E -15AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2009 3/25/2010 17.33 79.80 57,371 Design 1 E -15AL2 wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,500.00 V ertical Section: Depth From (TVD) +N / -S +E/ - Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 155.00 1/13/2010 7:52:06AM Page 2 COMPASS 2003.16 Build 69 . L , • • ✓ i ConocoPhillips /'t" 3C143a0� Planning Report �� Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-15 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E -15 @ 105.70ft (1E -15) Site: Kuparuk 1E Pad North Reference: True Well: 1 E -15 Survey Calculation Method: Minimum Curvature Welibore: 1E-15AL2 Design; 1E-15AL2_wp05 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth _ - System +N / -S +V -W Rate Rate - Rate TFO (ft) (°) ( °) (ft) (ft) (ft) ( ° /900ft) (°1100N) (°l10Rft) ( °) Target 7,500.00 38.43 287.45 6,100.46 860.08 - 3,165.88 0.00 0.00 0.00 0.00 7,557.00 38.42 287.35 6,145.11 870.67 - 3,199.68 0.11 -0.02 -0.18 -99.18 7,577.00 36.62 287.35 6,160.97 874.30 - 3,211.31 9.00 -9.00 0.00 180.00 7,607.00 23.12 287.35 6,186.93 878.75 - 3,225.53 45.00 -45.00 0.00 180.00 7,635.00 14.60 257.59 6,213.46 879.63 - 3,234.26 45.00 -30.42 - 106.27 215.00 7,655.00 17.76 226.87 6,232.70 877.00 - 3,238.96 45.00 15.78 - 153.63 275.00 7,675.00 25.30 213.26 6,251.30 871.33 - 3,243.54 45.00 37.71 -68.04 320.00 7,828.78 94.50 213.26 6,323.82 766.72 - 3,312.15 45.00 45.00 0.00 0.00 7,878.78 94.54 190.69 6,319.82 720.80 - 3,330.68 45.00 0.08 -45.14 271.00 8,053.78 94.51 164.35 6,305.77 548.06 - 3,323.20 15.00 -0.02 -15.05 271.00 8,353.78 93.26 119.26 6,284.32 318.96 - 3,142.86 15.00 -0.42 -15.03 270.10 8,553.78 92.82 149.30 6,273.46 181.11 - 3,001.53 15.00 -0.22 15.02 90.00 8,603.78 95.36 156.38 6,269.89 136.77 - 2,978.78 15.00 5.07 14.15 70.00 8,803.78 89.68 126.88 6,260.90 -18.01 - 2,856.08 15.00 -2.84 -14.75 260.00 9,028.78 85.85 160.44 6,269.92 - 196.45 - 2,724.71 15.00 -1.70 14.92 97.00 9,228.78 86.41 130.38 6,283.73 - 358.81 - 2,612.73 15.00 0.28 -15.03 270.00 9,458.78 87.72 164.90 6,295.88 - 549.92 - 2,491.68 15.00 0.57 15.01 88.80 9,658.78 88.03 134.88 6,303.48 - 720.84 - 2,392.57 15.00 0.15 -15.01 270.00 9,958.78 85.07 179.88 6,322.52 - 990.05 - 2,280.18 15.00 -0.99 15.00 95.00 10,150.00 85.68 151.10 6,338.28 - 1,172.61 - 2,232.91 15.00 0.32 -15.05 270.00 111312010 7.;52:06AM Page 3 COMPASS 2003.16 Build 69 t)RG INA L 0 1 10 r.' ConocoPhilli s p FA fig + onoCoPhillip5 Planning Report BAKER Alaska N Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E -15 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level _Project: Kuparuk River Unit MD Reference: 1E -15 @ 105.70ft (1E -15) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E -15 Survey Calculation Method: Minimum Curvature Wellbore: 1E-15AL2 Design: 1E- 15AL2_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NJ-S +E/ -yy Section Rate Azimuth Northing Easting (ft) (0 (0) (ft) (ft) (ft) (ft) (1100ft) ( °) (ft) (ft) 7,500.00 38.43 287.45 6,100.46 860.08 - 3,165.88 - 2,117.45 0.00 0.00 5,960,868.98 546,538.85 TIP 1E-15 • 7,557.00 38.42 287.35 6,145.11 870.67 - 3,199.68 - 2,141.34 0.11 -99.18 5,960,879.35 546,504.98 KOP 7,577.00 36.62 287.35 6,160.97 874.30 - 3,211.31 - 2,149.54 9.00 - 180.00 5,960,882.90 546,493.33 End of DLS 9 7,600.00 26.27 287.35 6,180.57 877.87 - 3,222.74 - 2,157.61 45.00 - 180.00 5,960,886.40 546,481.87 7,607.00 23.12 287.35 6,186.93 878.75 - 3,225.53 - 2,159.58 45.00 - 180.00 5,960,887.25 546,479.08 4 7,635.00 14.60 257.59 6,213.46 879.63 - 3,234.26 - 2,164.08 45.00 - 145.00 5,960,888.08 546,470.34 5 7,655.00 17.76 226.87 6,232.70 877.00 - 3,238.96 - 2,163.67 45.00 -85.00 5,960,885.42 546,465.66 6 7,675.00 25.30 213.26 6,251.30 871.33 - 3,243.54 - 2,160.47 45.00 -40.00 5,960,879.72 546,461.12 7 7,700.00 36.55 213.26 6,272.71 860.60 - 3,250.58 - 2,153.72 45.00 0.00 5,960,868.94 546,454.16 7,800.00 81.55 213.26 6,322.83 790.72 - 3,296.41 - 2,109.76 45.00 0.00 5,960,798.76 546,408.79 7,828.78 94.50 213.26 6,323.82 766.72 - 3,312.15 - 2,094.66 45.00 0.00 5,960,774.67 546,393.21 8 7,878.78 94.54 190.69 6,319.82 720.80 - 3,330.68 - 2,060.87 45.00 -89.00 5,960,728.63 546,374.99 End of DLS 45 7,900.00 94.59 187.49 6,318.14 699.91 - 3,334.02 - 2,043.35 15.00 -89.00 5,960,707.72 546,371.79 8,000.00 94.62 172.45 6,310.06 600.52 - 3,333.97 - 1,953.25 15.00 -89.25 5,960,608.34 546,372.49 8,053.78 94.51 164.35 6,305.77 548.06 - 3,323.20 - 1,901.15 15.00 -90.47 5,960,555.96 546,383.61 10 8,100.00 94.49 157.40 6,302.14 504.54 - 3,308.11 - 1,855.34 15.00 -89.90 5,960,512.55 546,398.98 8,200.00 94.22 142.36 6,294.49 418.55 - 3,258.22 - 1,756.32 15.00 -90.45 5,960,426.89 546,449.44 8,300.00 93.67 127.33 6,287.58 348.40 - 3,187.69 - 1,662.94 15.00 -91.60 5,960,357.22 546,520.43 8,353.78 93.26 119.26 6,284.32 318.96 - 3,142.86 - 1,617.31 15.00 -92.64 5,960,328.08 546,565.44 11 8,400.00 93.24 126.21 6,281.70 294.02 - 3,104.06 - 1,578.31 15.00 90.00 5,960,303.40 546,604.40 8,500.00 93.02 141.23 6,276.21 225.21 - 3,032.10 - 1,485.53 15.00 90.39 5,960,235.08 546,676.81 8,553.78 92.82 149.30 6,273.46 181.11 - 3,001.53 - 1,432.65 15.00 91.22 5,960,191.19 546,707.67 12 8,600.00 95.17 155.84 6,270.24 140.21 - 2,980.30 - 1,386.60 15.00 70.00 5,960,150.43 546,729.17 8,603.78 95.36 156.38 6,269.89 136.77 - 2,978.78 - 1,382.84 15.00 70.46 5,960,147.00 546,730.71 13 8,700.00 92.72 142.15 6,263.08 54.50 - 2,929.84 - 1,287.60 15.00 - 100.00 5,960,065.06 546,780.19 8,800.00 89.79 127.43 6,260.88 -15.73 - 2,859.08 - 1,194.04 15.00 - 101.01 5,959,995.31 546,851.40 8,803.78 89.68 126.88 6,260.90 -18.01 - 2,856.08 - 1,190.71 15.00 - 101.33 5,959,993.05 546,854.42 14 8,900.00 87.95 141.21 6,262.90 -84.72 - 2,78711 - 1,101.10 15.00 97.00 5,959,926.81 546,923.83 9,000.00 86.29 156.14 6,267.95 - 169.78 - 2,735.33 - 1,002.12 15.00 96.70 5,959,842.09 546,976.16 9,028.78 85.85 160.44 6,269.92 - 196.45 - 2,724.71 - 973.47 15.00 95.95 5,959,815.50 546,986.95 15 9,100.00 85.92 149.73 6,275.04 - 260.78 - 2,694.83 - 902.53 15.00 -90.00 5,959,751.37 547,017.26 9,200.00 86.26 134.70 6,281.89 - 339.40 - 2,633.88 - 805.52 15.00 -89.23 5,959,673.16 547,078.72 9,228.78 86.41 130.38 6,283.73 - 358.81 - 2,612.73 - 778.99 15.00 -88.20 5,959,653.89 547,100.00 16 9,300.00 86.69 141.08 6,288.03 - 409.65 - 2,563.17 - 711.97 15.00 88.80 5,959,603.39 547,149.89 9,400.00 87.28 156.09 6,293.31 - 494.63 - 2,511.27 - 613.02 15.00 88.15 5,959,518.77 547,202.34 9,458.78 87.72 164.90 6,295.88 - 549.92 -- - 2,491.68 -554.63 15.00 87.36 5,959,463.61 547 222.29 1/13/2010 7:52:06AM Page 4 COMPASS 2003.16 Build 69 �!7, ,_, • n Philli s • * a co oco p Fria Conoco Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co- ordinate Reference: Well 1 E -15 Company: ConocoPhillips(Alaska) Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E -15 @ 105.70ft (1E -15) Site: Kuparuk 1E Pad North Reference: True Well: 1E-15 Survey Calculation Method: Minimum Curvature Wellbore: 1 E -15AL2 Design: 1 E- 15AL2_wp05 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +tu +E!_W Section Rate Azimuth Northing Easting (ft) (") (') (ft) (ft} (ft) (ft) (°t1Ooft) (°) (ft) (ft) 17 9,500.00 87.73 158.71 6,297.52 - 589.04 - 2,478.83 - 513.75 15.00 -90.00 5,959,424.59 547,235.40 9,600.00 87.87 143.70 6,301.37 - 676.36 - 2,430.84 - 414.33 15.00 -89.75 5,959,337.59 547,283.97 9,658.78 88.03 134.88 6,303.48 - 720.84 - 2,392.57 - 357.84 15.00 -89.18 5,959,293.37 547,322.53 18 9,700.00 87.50 141.05 6,305.09 - 751.42 - 2,365.00 - 318.47 15.00 95.00 5,959,262.97 547,350.30 9,800.00 86.35 156.03 6,310.48 - 836.35 - 2,313.02 - 219.54 15.00 94.76 5,959,178.40 547,402.83 9,900.00 85.46 171.04 6,317.66 - 931.72 - 2,284.82 - 121.18 15.00 93.95 5,959,083.23 547,431.66 9,958.78 85.07 179.88 6,322.52 - 990.05 - 2,280.18 -66.36 15.00 92.87 5,959,024.93 547,436.68 19 10,000.00 85.10 173.67 6,326.06 - 1,031.04 - 2,277.87 -28.23 15.00 -90.00 5,958,983.97 547,439.26 10,100.00 85.40 158.62 6,334.39 - 1,127.51 - 2,254.07 69.26 15.00 -89.47 5,958,887.66 547,463.70 10,150.00 • 85.68 151.10 6,338.28 , - 1,172.61 - 2,232.91 119.07 15.00 -88.21 5,958,842.71 547,485.15 TD 1/13/2010 7:52:06AM Page 5 COMPASS 2003.16 Build 69 ' fir , r ' AgneelNneh2Onr, WELLBORE DETAILS: SE -15AL2 REFERENCE INFORMATION /1'�- Project: Kuparuk River Pad nit M ttegneMONa1n:21.83' Site: Kuparuk 1E Pad Megnetarieu Parent Welibore: 1E -15 Co-ordinate (N!E)Reference: Well 1E- 15, True North irse -. -- Well: 1E Strength 57657,isnT Tie on MD: 7500.00 Vertical (TVD) Reference Mean Sea Level BJ1KER CQ r^��^rl �• ( � ( .� 1t G' Wellbore: 1E•15AL2 Di eo.8a" p, , Sedon(VS) Reference: Slot -(0 ODN, 0.00E) 1 W 4Q F 1 11 l �.7 Pan: 1 E - 15AL2 wp05 (1 E - 15/1 E 15AL2) detBG Measured Depth Reference: 1E -15 @ 105.7011 (1E•15) Calculation Method: Minimum Curvature , l -! 5 IL-15,A l End ofDLS9 1000 _. __ ' - ,__.__ • 5. 4 _f KOP - -_ WELL DETAILS: 1E -15 7 111 111141, 2_ TIP 1E-15 Ground Level: 0.00 801 ; _. - - _ - _._._.. +N / -S +E / -W Northing Easting Latittude Longitude Slot Said ofDLS4S 0.00 0.00 5960029.95 549710.04 70° 18' 5.686 N 149° 35' 50.538 W 601 -- -- - SECTION DETAILS ANNOTATIONS 10 401 , _. Sec MD Inc Azi TVDSS +N( -S +E! -W DLeg TFace VSec Target Annotation 1 7500.00 38.43 287.45 6100.46 860.08 - 3165.88 0.00 0.00 - 2117.45 TIP 1E -15 201 - 11 - 2 7557.00 38.42 287.35 6145.11 870.67 - 3199.68 0.11 -99.18 - 2141.34 KOP - , 3 7577.00 36.62 287.35 6160.97 874.30 - 3211.31 9.00 180.00 - 2149.54 End of DLS 9 ^. 12; 4 7607.00 23.12 287.35 6186.93 878.75 - 3225.53 45.00 180.00 - 2159.58 4 o }- 5 7635.00 14.60 257.59 6213.46 879.63 323426 4500 215.00 -2164.08 5 j 14 6 7655.00 17,76 226.87 6232.70 87700 - 3238.96 45.00 275.00 -2163.67 6 G - t i - 7 7675.00 25.30 213.26 6251.30 871.33 - 324354 45.00 320.00 - 2160.47 7 `-t I B 7828.78 94,50 213.26 6323.82 766.72 - 3312.15 45.00 0.00 - 2094.66 8 t S • 9 7878.78 94.54 190.69 6319.82 720.80 - 3330.68 45.00 271.00 - 2060.87 End of DLS 45 - 41 6' - 10 8053.78 94.51 164.35 6305.77 548.06 - 3323.20 15.00 271.00 - 1901.15 10 . -61 - - - --- -- --- --- - - -- -3142.86 15.00 270.10 -1617.31 11 11 8353.78 93.26 119.26 6284.32 318.96 ---- 12 8553.78 92.82 149.30 6273.46 181.11 - 3001.53 15.00 90.00 - 1432.65 12 13 8603.78 95.36 156.38 6269.89 136.77 - 2978.78 15.00 70.00 - 1382.84 13 ^. 811 Ct 8803.78 89.68 126.88 6260.90 -18.01 - 2856.08 15.00 260.00 - 1190.71 14 I , 1 9028.78 85.85 160.44 6269.92 - 196.45 - 2724.71 15.00 97.00 - 973.47 15 +*• ' � `'"� !✓ 9228.78 86.41 130.38 6283.73 -358.81 -2612.73 15.00 270.00 -778.99 16 0 1011 19 - - 7 9458.78 87.72 164.90 6295.88 - 549.92 - 2491.68 15.00 88.80 - 554.63 17 18 9658.78 88.03 134.88 6303.48 - 720.84 - 2392.57 15.00 270.00 - 357.84 18 1211 ""19 9958.78 85.07 179.88 6322.52 - 990.05 - 2280.18 15.00 95.00 -66.36 19 1F II 15A1 2 TD " r x "4 20 10150.00 85.68 151.10 633828 - 1172.61 - 2232.91 15.00 270.00 119.07 TD .// -141 -- -._ -. - - - -- T - -- ''''''''''ftetwa { Z -1800- _ -__ __ -_ -_ -. _ -_ -_ - -- -- - - - - -.._._ -4400 -4200 -4000 -3800 -3600 -3400 -3200 -- 8 26 00 -2400 -2200 -2000 -1800 -1600 -1 400 -1200 -1000 -800 570(1 - -� 000S st( +) (200 ft/in) - � - - TIP 1E -15 5800 . KOP `. i 5900 - -± -- , - -- - ---- { _ _:._ L_ '- -- - -- - -- r • � ; End of DLS9 � ) ` Z 6000- _.... _ ... _. - - -- - - I . --- 1 O 6100- __._. 6200 1E- 515-15A 5x15 -15A - T - fi , - -_ €ndaf aI_ 45. _ � ..._ �t _. - ( 1F.15 /1 F SA1? '.. • Ct. Tit ` -- 1 - J4 12-'"-----4-1 6 7 t Q 1 6300 /. _ 0 - - - -- - -_..- - -_ -. - -- - 8 - - - --- - }_ .� -._ ._ -._ -- -: -- 2 I l U 6400 a / y 6600 -- f - - - - -- ' - -- -- - -n- - I - Y - -- - - - - - - -- - - - - - -_ 1-. r N i i 6700- ' ! 1 6800 -.. ... ! .- __. - _._- - --� - - : - .__.._ ._ - -_.- - -- - - -_. - -- - - -- -2600 2500 -2400 23 _ -- I ' -- Y - __ - - 00 - 2200 -2100 -2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1000 -900 -8 -7 -6 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 900 1000 1I00 1200 Vertical Section at 155.00° (100 ft /in) a. lainwheg WELLBORE DETAILS: 1E -15AL2 REFERENCE INFORMATION Project: Ku paruk River Unit MegnateNmtlti2r.813' Site: Kuparuk l E Pad MagneecFleu Parent Wellbore: 1E -15 Co- ordinate (NWE) Reference: Well 1E- 15, True North . Well: 1E -15 Strengnala52torT Tie on MD: 7500.00 Vertical ( TVD ) Reference: 1E•15@105.7dt(1E -15) BAKER Wellbore: 1E -15AL2 Plan :1E- 15AL2_wp05(1E•15/1E15AL2) od eau. Section (VS) Reference: Slot - (0.008.0.00) r} De1e Measured Depth Reference. 1E -15 @ 105.7dt (1E•15) Ct7C1(7COPh���tp5 ModelN:eccMZOOS Calculation Method: Minimum Curvature HUGHES IS 12,15 -I2AL1 I 2600 ] —+ -------- - - -._- - _ -- - - - - - - - - - - ---._ - - -- - - -- — _ !— —' 706E ___.._ -. 2400-, 2200- 4'- -... .. _..._. .. 2000- � _ - -- -___ - .___._. 1800- -.. _ - T.— 3.2 i3.Laars6 16(1(1 -. __ , __ -- '- ____ ._.. o- 140 • 1200 loo( j'..q� 80o- __ _ J / coo- — 70 0 w 400 I o i __- C �...... IIZ. [r..�.. o r tln.itTF� ) 0 200 Y A ... ,_ ° -600- -r - ,' C t .. - . .:) -8001 - _... ' \ , .., ' \ \ _1DOt! - . _ _ — _.._ - ____ - __.. tt ,�.}. ft -t SAId fE, t , -1200- __ -. ....._ _:._ -. - ...... -_. _. .. _..- - -_. _ _. - 1'E12.10. . .. ' _.__ N N -14(1(1 _. f) 1 . -02 0 0_ - -' 16(10 - .. i I _.__. ___ -_. _._ ._. .... 1800' I -24001 -. -. - -. - -_____ -.. .. I f - -__ i { - -6400 -6200 -6000 -5800 -5600 -5400 -5200 -5000 -4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1E-15 @ 105.70ft (1E-15) West( - )/East( +) (200 ft/in) • Quarter -Mile Injection Review KRU 1E-15A, AL1, AL2, AL2 -01 — Coiled Tubing Drilling Wells Within 1/4 -Mile of 1E -15 Northwestern Laterals (A & AL1) 1. KRU 1E -15 (motherbore injector) • Completed with 7 ", 26 #, K -55 casing on 7- 31 -82. Included 23 B &W Turbo -fin centralizers. Cemented with 280 sacks of lead + 325 sacks of tail "G" cement. Reciprocated casing for most of the job. No mention in cementing reports of lost returns. • C -sand perfd 7478'- 7554', A -sand perf d 7716'- 7796'. The tubing tail is at 7682' MD and the upper packer is at 7321'. The CBL of 7 -1 -82 shows very good cement around the C -sand but generally poor cement around the A -sand, although there is cement isolation between the two intervals. There is no reason to expect injection out of zone. • Well 1E -15 is currently shut -in awaiting sundry approval to plug the A -sand and C -sand perfs. 2. KRU 1E - 11 (injector, 1001' away) • Completed with 7 ", 26 #, K -55 casing on 5 -4 -82. Target TOC = 6708' MD. Casing became stuck 13' off bottom while attempting to reciprocate casing prior to cement job. Lost full returns when casing got stuck. Cemented with 475 sacks of lead + 600 sacks of tail "G" cement with no returns during the cement job. • The CBL of 5 -5 -82 shows very poor cement around both the Kuparuk C -sand and A -sand. • Following the CBL of 5 -5 -82, they perforated at 7674' (i.e. above the C -sand) and performed a squeeze with 41 bbl "G" cement through a retainer to 1400 psi. Drilled out cement and retainer the following day and tested the squeeze perfs to 1000 psi. • On 10 -17 -84 performed additional squeeze work at 7910' (i.e. above the A -sand perfs) using 200 sacks of 15.9 ppg "G" cement. No bond log was run to assess the success of the squeeze. • 1E -11 was pre - produced in the C/A sands from April 1982 to May 1996, and was converted to injection in May 1996. The A sand was frac'd two different times -- in 1985 and 1991. Both were gelled water frac's. The C sand was never frac'd. The most recent IPROF (May 2007) showed 71% C -sand and 29% A -sand injection. Significant A to C sand crossflow was detected into the injection mandrels at 7577' and 7643' MD. • Present completion: C -sand perfd 7708'- 7794', A -sand perf d 7996'- 8076'. The tubing tail is at 7955' MD and the uppermost packer is at 7491'. Well 1E -11 has been shut in since 2007 due to flowline problems but in 2009 it was put back on miscible gas injection, and water injection is expected to resume in 2011. 3. KRU 1E - 13 (injector, — 1144' away) • Completed with 7 ", 26 4, K -55 & L -80 casing on 7 -1 -82. Included 14 B &W Turbo -fin centralizers. Cemented with 564 sacks of lead + 670 sacks of tail "G" cement. Reciprocated casing for most of the job. No mention in cementing reports of lost returns. • C -sand perf d 7110'- 7192', A -sand perfd 7345'- 7416'. The tubing tail is at 7055' MD and the only packer is at 6976'. The CBL of 7 -1 -82 shows good cement around both the C -sand and A- sand perfs. There is no reason to expect injection out of zone. Well 1E -13 is currently on long term shut in due to flowline problems. Page 1 of 3 February 5, 2010, FINAL • • Quarter -Mile Injection Review KRU 1E-15A, AL1, AL2, AL2-01 — Coiled Tubing Drilling 4. KRU 1F -19 (producer, 1103' away) • Completed with 3 (9.3 ppf, L -80) x 51/2" (15.5 ppf, L -80) tapered production casing on 3- 22 -96. Included 20 centralizers on the 3' /z" portion and 12 centralizers on the 5' /z" portion. Cemented with 230 sacks "G" cement. Calculated TOC was 7114' MD. Reciprocated casing until 20 bbl cement had turned the corner. Poor returns during cementing, but noted a 400 psi increase in pump pressure as cement moved uphole. • A -sand perf'd 9124'- 9198'. There is no packer installed, but there is a 3' /z" sealbore at the 3' /z" x 5%z" crossover at 8772'. The 3 tubing seals stab into this sealbore. The CBL of 4 -12 -96 shows excellent cement adjacent to the A -sand perfs. Well 1F -19 is actively producing from the A -sand. Wells Within 1/4 -Mile of 1E -15 Southeastern Laterals (AL2 & AL2 -01): 1. KRU 1E -06 (producer, —938' away) • Completed with 9% ", 47 #, L -80 casing on 9 -7 -80. No casing detail available. Cemented in 2 stages: first stage out the shoe and the second stage through a DV collar at 7127' MD. Cemented via the shoe with 300 sacks (stage #1) and via the DV collar with 900 sacks (stage #2) of "G" cement. There were no returns during the second stage of cementing through the DV collar. Drilled ahead to 9847' MD, but later the open hole and a portion of the cased hole was plugged back in stages to 7400'. • The CBL of 9 -20 -80 only logged down to 7124' MD, but it shows very poor quality cement across both the C -sand and A -sand perfs. • In December 1984 performed a cement squeeze at 6760' MD (i.e. below the C -sand perfs) through a retainer with 100 sacks of "G" cement ( -80 sacks behind pipe). Achieved a squeeze pressure of 3000 psi. No bond log was run to assess the success of the squeeze, nor did they pressure test the squeeze after drilling out. • The most recent PPROF in 1E -06 was obtained in March 2009. It showed 79% C -sand to 21% A- sand production contributions. No crossflow was detected. Both the A and C sand have been frac'd in this well. The A -sand was a gelled water batch frac in 1985, and the C -sand was frac'd with 71,000 lbs in 1988. • Present completion: C -sand perf'd 6648'- 6710', A -sand pert d 6838'- 6900'. Tubing tail is at 6801' MD, and the uppermost packer is at 6538'. Well 1E -06 is presently shut in due to low productivity, but it is expected to benefit from injection into the 1E -15 CTD laterals. 2. KRU 1E - 14 (producer, — 1430' away) • Completed with 7 ", 26 #, K -55 casing on 7- 16 -82. Included 12 B &W Turbo -fin centralizers on bottom 12 joints, plus 8 more uphole. Cemented with 350 sacks of lead + 425 sacks of tail "G" cement. Reciprocated casing for entire job and maintained full returns. • C -sand perf d 6660'- 6724', A -sand perf'd 6853'- 6888'. The tubing tail is at 6803' MD, and the upper packer is at 6430'. The CBL of 7 -17 -82 shows adequate cement across the C -sand perfs and excellent cement across the A -sand perfs. Another CBL run on 5 -4 -83 only logged down to 6620' and does not add anything significant to this assessment. Well 1E -14 is currently on long term shut in due to flowline problems. Page 2 of 3 February 5, 2010, FINAL • • Quarter -Mile Injection Review KRU 1E-15A, AL1, AL2, AL2-01 — Coiled Tubing Drilling 3. KRU 1E -16 (injector, —646' away) • Completed with 7 ", 26 4, K -55 casing on 8- 13 -82. Included 13 B &W centralizers on bottom 12 joints. Cemented with 355 sacks of lead + 300 sacks of tail "G" cement. Reciprocated casing for most of job, but casing was stuck high for a little while. Maintained full returns entire job. • C -sand pert d 7193'- 7256', A -sand perf d 7396'- 7454'. The tubing tail is at 7319' MD, and the upper packer is at 7043'. The CBL of 8 -13 -82 shows excellent cement throughout the entire Kuparuk sand interval. There is no reason to expect injection out of zone. Well 1E -16 is currently on long term shut in due to flowline problems. 4. KRU 1E - 17 (injector, — 1286' away) • Completed with 7 ", 26 #, K -55 casing on 8- 24 -82. Included 12 B &W Turbo -fin centralizers on the bottom 11 joints. Cemented with 340 sacks of lead + 310 sacks of tail "G" cement. Reciprocated casing for most of job. No mention made of losses or of the quality of returns during cementing. • C -sand perf'd 7373'- 7441', A -sand perf d 7587'- 7636'. The tubing tail is at 7523' MD, and the upper packer is at 7230'. The CBL of 8 -24 -82 shows excellent cement across the C -sand and A- sand perforated interval. There is no reason to expect injection out of zone. Well 1E -17 is currently on long term shut in due to flowline problems. 5. KRU 1E - 30 (injector, — 797' away) • Completed with 7 ", 26 #, K -55 casing on 9- 12 -82. Included 10 B &W Turbo -fin centralizers on the bottom 12 joints, plus 8 more uphole. Cemented with 300 sacks of lead + 350 sacks of tail "G" cement. Reciprocated casing for entire job and maintained good returns. • C -sand perfd 6792'- 6847', A -sand perf'd 6991'- 7042'. The tubing tail is at 6909' MD, and the upper packer is at 6630'. The CBL of 9 -11 -82 shows excellent cement around both the C -sand and A -sand perfs. There is no reason to expect injection out of zone. Well 1E -30 is currently on long term shut in due to flowline problems. Page 3 of 3 February 5, 2010, FINAL la ' Alm,ACb True North WELLBORE DETAILS: 1E -15AL2 REFERENCEINFORMATION 1E -15 s "° Project: Kuparuk Rlver Unit MagneenNoM: 21.83 Site: Kuparuk 1E Pad CoonHnate (WE) R eference' W el 1E45, True Noah gt657 71 8 n P a r ent 0 an MD: 7 5-15 Welk KER - l: Vertical (1VD) Reference: 1 E•15 105.70N (1E - 15) W 1E - 15AL2 ° eAw " M2C09 Tie 7500.00 D,pAryk: 83.94• Section (VS)Refererwe; Slol- (O.ODN, O.00E) COf0GOP ills Date: Measured Depth Reference. lE- 15Q105.70R (1E -15) - _ Plan:tE - 15AL2 wP05(1E 15/1E - 15AL� ` Mcdc eccM2oas HUGHES Calculation Method: Minimum Curvature 1E•12/1E -12•L1 18- l5/1E45A 2400 - - - - - 6366 - - - - - - - - - - - - - - IE -12iRE -122- _4 68 22001 - - - - - - - - -00 ', - - - - - -. IE- 15 /1E -15AL1 2000 - - - - - - - - - - ,..0...)i, - 1800- - - " - - - I - - - - - ,,_ - - ]E 10263 - Lamm - 1600- - -- - - - - -1 - - - - .‘ \ - - -" - - /- 1400- - - - - - - ,\ - - - - - - - - ' - - - - - /• 1200- - -- - ` g 1000- - - - - - - l-r - - - - \ " - i" 11 - -1 ' / Go " I I. I � L. ,.1 ., a 800 - - - - - -- - " - " ,. ` i'n , - - - - - - I E- 1 -12A1,2 600 - - - - - - - - - - - - - - - - - - - SII" O 400- - - / / O 200-1 - -- �? _, ` illi 0 - - - - - - - - - -- — - \ - -- - IE41ni lEa1G T -800 - - -- - - -- - - -- - - - - - - - - � - - - - -- j - -1000 -- - -- - -- - - - - - - - - - - - - �I - - \ l E- 1'�IE -15A 01 / • 1 \\ -1200 - - - - - - - - -- IE-1S / 1E -15AL2 , ' - -- - - - = - - - / - - / - \ 5 -140 - - __ _ -. - / / / f - 1I2 /IF. - �I2 , -1600 - -- - .. - - - - - - - - - - - - - 1 - - - - -1800 - _. . - - .. - - -- - - - - - - - - - - - - I 1 \ - \ 1E47/1E:37 4-- ""k 1 - -2000 - - - -- - - -- - - - - 'rr o c - - -r.„. - - - - - - - - - - 221 1 — - " - - - - - - - - - - - I - - - - - - - \ I 1E- 34/IY -34 -2400 - - - -- - - - - - - - - - - - - - - I - - - - -2600 - - - - - - - - - - - " - - - - - - - . , 1E4)4/1E-04 ( 1E-11/LE-11P131 - 6400 - 6200 - 6000 - 5800 -5600 -5400 -5200 -5000 -4800 -4600 - 4400 - 4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 - 1200 - 1000 - 800 - 600 - 400 - 200 0 200 400 600 800 1000 went( -1 /East( +1 (200 ft/in) . AorumeTnekorin WELLBORE DETAILS: 1E-15A REFEREAraNFORMATION Project: Kuparuk River Unit MapnetioNorth.21.8.3. lakl Site: Kuparuk 16 Pad MapnetcFold Parent We libore: 1 E-15 Co-ordinate (N/E) Reference: Wel 1E-15, True North Well: 16 SbanglIv 57e67.1er Vertical (TVD) Reference: 1E-IS@ 10510(1(1E-15) Conoc Tie on MD: 7600.00 AKER oPhillips Plan 1 Wellbore: 16-15A : 6-15kwp03 (16-15/16 ma Me -15A) DipAngle:80.84. 0101:3125/2010 I/odet ma Section (VS) Reference. Slot - (0.00N, 0.00E) asured Depth Reference: 1E-15 @ 105.7 B 5ft (1E45) • Ctiticulation Method: Minimum Curvature HUGHES - 48001 - . . . . . . 4200- - ' . . . 4000- - . , . . 3800 . . . 6 1E - - \ 3600 1- 3400 - - - - - , 1/41'4 ' III , If -t I F- L'Al ' ■ 3211 - . - \< \ ', • „, \ ., - - 3000 - - . _ _ mir \ .., . . _ \ \ ' ii _ _ . _ - \ , ' 1 . 1E-13/m_n_ , _9' I , IE-15/IE-15A C> 2400 i1 ' i C-1 ,6 2800 . 2. i , 4 1 17' 2200 1/4.....,/ \ . . 0 16-10/16-19 6 1F. ' 1. 6 1 RE.45A1t ,••■ \ .. - _, - \ • \ . V) -- \ - \ - 7 _ ., ,, 1E-102 91-041.71.1 69 8 0 i - - 6 ,. 2. - / 1 .,-_ - - .,,, - ----_ \ 1E-12/1E-12AL2 -,, ,. / -, ----__- 400 - \ . ‘, --- -- --___ . / . - . ,, . --__ - 200- - - . . - - . ---- _ / 0 . _ _ . \ . ____---- - \ , _ 11:-9'/IF-91 -200 - - --- - - - _ . _ . -- _ _ _ . - — — ..-- / ___-- — ' — . ----- 11 ---- - - ' 1E-16/1E-16 , ._,-_----- ____ --- 16 M2/lE-02 . -600 . - - - - - 1E-t4/1E-31 . 1E:-15'1E-15A1 2 -6800 -6600 -6400 -6200 -6000 -5800 -5600 -5400 -5200 -5000 -4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 - 2400 - 2200 - 2000 - 1800 - 1600 - 1400 - 1200 - 1000 - 800 - 600 - 400 - 200 0 — 200 400 600 -- 1E-15 © 105.70ft (1E-15) West(-)/East(+) (200 ft/in) • • TRANSMITTAL LETTER CHECKLIST WELL NAME KUPARUK RIVER UNIT 1E -15AL2 PTD# 2100150 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: KUPARUK POOL: KUPARUK RIVER OIL RIVER 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 -15A, Permit No. X (If last two digits in 2100130, API No. 50- 029 - 20769- 01 -00. Injection should API number are continue to be reported as a function of the original API number between 60 -69) stated above. PILOT HOLE In accordance with 20 AAC 25.005(1), 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 -, ' Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 U U -1 __— Well Name KUPAR KRIV UNIT 1E 5AL2 -- _Program SER Well bore seg Q PTD #: 2100150 Company CONOCOPHILLIPSALASKA INC Initial Class/Type SER / 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 and TD in ADL 25651 3 Unique well name and number Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 4 Well located in a defined pool Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 15 Well located proper distance from drilling unit boundary Yes boundaries and no interwell spacing restrictions. Wellbore will be more than 5 miles 6 Well located proper distance from other wells Yes from an external property line where ownership or landownership changes. 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 111 Permit can be issued without conservation order Yes Appr Date 11 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 1/27/2010 • 11 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes Area Injection Order No. 2B 15 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 1E- 01PB1, KRU 1E-06, KRU 1E -16, KRU 1E-17, KRU 1E -30 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) No Well will be flowed back for cleanup only. 117 Nonconven. gas conforms to AS31.05.030.1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in 1E-15 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 1E-15 11 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in 1E-15 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in 1E-15 22 CMT will cover all known productive horizons No OH slotted liner planned 23 Casing designs adequate for C, T, B & permafrost Yes 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 -023 26 Adequate wellbore separation proposed Yes Proximity analusis performed . No issues. 27 If diverter required, does it meet regulations NA Wellhead in place . BOP installed on tree. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max fm pressure = 4895 psi (14.9 ppg) Expected pressure is 11.5 ppg ...will drillwith 10 ppg and MPD GLS 2/5/2010 1 29 BOPEs, do they meet regulation Yes 130 BOPE press rating appropriate; test to (put prig in comments) Yes MASP =4264 psi Will test BOP to 5000 psi 3 • 1 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 1E pad. Rig has sensors and alarms. 134 Mechanical condition of wells within AOR verified (For service well only) Yes AOR complete for area 1/4 from lateral. -1 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 1E pad are H2S-bearing. H2S measures required. Geology 1 Data presented on potential overpressure zones Yes Expected reservoirpressure is 11.5 ppg EMW; however, 1E -15 was an injector, so pressures Appr Date 137 Seismic analysis of shallow gas zones NA encountered may reach 15.1 ppg. Will be drilled using 1.0.0 ppg mud and managed pressure SFD 1/27/2010 38 Seabed condition survey (if off-shore) NA drilling technique to keep ECD at about 12.4 ppg. Hazards program notes potential for 39 Contact name /phone for weekly progress reports [exploratory only] NA encountering high-pressure (15+ ppg) stringers while drilling. Mitigation measures discussed. 1 Geologic Engineering Public A -sand lateral injector to improve sweep efficiency. ' Commissioner: Date: Commissioner: Date Commissioner Date 0 _ i - 2 /'�
