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Home My WebLink About208-115MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-103 KUPARUK RIV U WSAK 3K-103 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-103 50-029-23392-00-00 208-115-0 W SPT 3440 2081150 1500 440 440 438 437 185 212 186 185 4YRTST P Josh Hunt 5/9/2025 This well is a dual string completion, the tubing pressures listed in the chart are for string "B". D string was as follows. Pre-457 Initial-458 15-458 30-459 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 3K-103 Inspection Date: Tubing OA Packer Depth 1070 2020 1945 1935IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510100408 BBL Pumped:2.3 BBL Returned:1.3 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 99 9 9 9 dual string completion tubing pressures listed in the chart are for string "B D string was as follows James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 14:11:44 -08'00' New Plugback Esets 6/21/2024 Well Name API Number PTD Number ESet Number Date Kaladachabuna 2 PB1 50-283-20169-70-00 212-157 T38946 5-3-2013 Kaladachabuna 2 PB2 50-283-20169-71-00 212-157 T38947 5-3-2013 Kaladachabuna 2 PB3 50-283-20169-72-00 212-157 T38948 5-3-2013 Kaladachabuna 2 PB4 50-283-20169-73-00 212-157 T38949 5-3-2013 ODSN-18 PB1 50-703-20624-70-00 210-142 T38950 2-18-2011 ODSN-18 PB2 50-703-20624-71-00 210-142 T38951 2-18-2011 ODSN-18 PB3 50-703-20624-72-00 210-142 T38952 2-18-2011 ODSN-18 PB4 50-703-20624-73-00 210-142 T38953 2-18-2011 ODSN-18 PB5 50-703-20624-74-00 210-142 T38954 2-18-2011 ODSN-24 PB1 50-703-20662-70-00 212-178 T38955 6-13-2013 ODSN-24 PB2 50-703-20662-71-00 212-178 T38956 6-13-2013 PBU 18-27E PB2 50-029-22321-72-00 212-131 T38957 2-12-2013 PBU 18-27E PH 50-029-22321-71-00 212-131 T38958 2-12-2013 Redoubt Unit 7 PB1 50-733-20526-70-00 203-150 T38959 10-22-2003 SP18-N05 PB1 50-629-23453-70-00 211-101 T38960 7-11-2016 3K-103 PB1 50-029-23392-70-00 208-115 T38961 2-3-2009 3K-103 PB2 50-029-23392-71-00 208-115 T38962 2-3-2009 3K-103 PB3 50-029-23392-72-00 208-115 T38963 2-3-2009 3K-103 PB4 50-029-23392-73-00 208-115 T38964 2-3-2009 3K-103 PB5 50-029-23392-74-00 208-115 T38965 2-3-2009 ODSN-25 PB1 50-703-20656-70-00 212-030 T38966 8-11-2012 ODSN-25 PB2 50-703-20656-71-00 212-030 T38967 8-11-2012 ODSN-25 PB3 50-703-20656-72-00 212-030 T38968 8-11-2012 ODSN-25 PB4 50-703-20656-73-00 212-030 T38969 8-11-2012 3K-103 PB1 50-029-23392-70-00 208-115 T38961 2-3-2009 3K-103 PB2 50-029-23392-71-00 208-115 T38962 2-3-2009 3K-103 PB3 50-029-23392-72-00 208-115 T38963 2-3-2009 3K-103 PB4 50-029-23392-73-00 208-115 T38964 2-3-2009 3K-103 PB5 50-029-23392-74-00 208-115 T38965 2-3-2009 MEMORANDUM TO: JimReggz� P.I. Supervisor L l FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 11, 2021 SUBJECT: Mechanical Integrity Tests ConomPhillips Alaska, Inc. 3K-103 KUPARUK RIV U WSAK 3K-103 Src: Inspector Reviewed By: P.I. Supry1Y e — Comm Well Name KUPARUK RIV U WSAK 3K-103 API Well Number 50-029-23392-00-00 Inspector Name: Lou Laubenstein Permit Number: 208-115-0 Inspection Date: 5/42021 Insp Num: mitLOL210505082814 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Miu 45 Min 60 Min Well 3K-103 Type Inl W TVD 344° "Tubing 618 618 618 - 618 - PTD 208u5o Type Test SPT Test psi 1500 IA 1340 1800 1760 " 1750 - BBL Pumped: 0.7 ' BBL Returned: 0.7 OA 190 190' 190 — 190 - Interval 4YRTST IPIF P ✓ Notes: Tuesday, May I1, 2021 Pdgc I of I kelt 34—(o3 P;t-s Z6eu50 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Thursday, November 7, 2019 11:08 AM ( c To: Regg, James B (CED) Cc: NSK Prod Engr Specialist; Valentine, Doug K; CPF3 Prod Engrs Subject: 3K-103 Reinstated LPP/SSV --(PTD# 208-115) per CO 4066.001 Mr. Regg, The low pressure pilot supporting injection well 3K-103 (PTD# 208-115) has been reinstated as the well head pressure is currently operating above 300 psi with 890 bwpd injection rate. The "Facility Defeated Safety Device Log' has been ✓ updated actor Ins y Please contact me if there are any question I can help with. Kindly, Pete Fox (CPF3 PE fill-in) O: (907) 659-7871 From: CPF3 Prod Engrs Sent: Sunday, September 8, 2019 5:14 PM To: jim.regg@alaska.gov Cc: NSK Prod Engr Specialist <n1139@conocophillips.com>; Valentine, Doug K <Doug.K.Valentine@conocophillips.com> Subject: 3K-103 Defeated LPP/SSV --(PTD# 208-115) per CO 4066.001 Mr. Regg, The low pressure pilot (LPP) on injection well 3K-103 (PTD# 208-115) is defeated today, Sunday September 8, 2019. 3K-103 had been shut in since July 4, 2019 due to the CPF3 Seawater Tank preventing SW injection. We are ramping up injection slowly to the West Sak injectors at DS 3K. 3K-103 is currently at wellhead injection pressure of 20 psig and injection rate of about 300 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log', where it is referred to as 3K -303D. The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any concerns or questions, Thanks, Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Pry 2&,Qasr, Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Sunday, September 8, 2019 5:14 PM To: Regg, James B (CED) Cc: NSK Prod Engr Specialist; Valentine, Doug K Subject: 3K-103 Defeated LPP/SSV --(PTD# 208-115) per CO 4066.001 Mr. Regg, The low pressure pilot (LPP) on injection well 3K-103 (PTD# 208-115) is defeated today, Sunday September 8, 2019 3K-103 had been shut in since July 4, 2019 due to the CPF3 Seawater Tank preventing SW injection. We are ramping up injection slowly to the West Sak injectors at DS 3K. 3K-103 is currently at wellhead injection pressure of 20 psig and injection rate of about 300 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log", where it is referred to as 3K -103D. The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any concerns or questions, Thanks, Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp# 328 Pig ZDV it 5-0 Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> ,VGi� t q (j,hllj9 Sent: Monday, April 22, 2019 5:11 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Supv CPF3 and WNS; NSK Prod Engr Specialist; NSK Optimization Engr; NSK West Sak Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; CPF3 Maint Supv; Valentine, Doug K; Jolley, Liz C; Martin, Kenneth Lloyd; Plunkett, Ethan T Subject: Defeated LPP/SSV on well 3K-1031-1 Mr. Regg, l03 2-D£��ils The low pressure pilot (LPP) on injection well 3K -18C1 (PTD# 208-1t6) was defeated late Saturday evening, 4/20/2019. 3K -103L1 had been shut in for 6 days due to a flooding conformance treatment. After the initial treatment setup period, returning the well to injection at a reduced rate to monitor the treatment, the wellhead pressure did not rise high enough to place the low pressure pilot in service. 3K-1031-1 is currently at wellhead injection pressure of 331 psi and injection rate of 700 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable during scheduled water injection line pigging today, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 4068.001". Best regards, Ethan Plunkett / Kenneth Lloyd Martin CPF3 Production Engineer I Office x7871 I Cell (918) 812-2294 1 Pager x328 I Radio 343 2:08115 WELL LOG TRANSMITTAL #905369790 3032 4 To: Alaska Oil and Gas Conservation Comm. January 14, 2019 Arm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Multi Finger Caliper and Jewelry Log: 3K-103 FEB 0 5 2019 Run Date: 12/28/2018 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 3K-103 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23392-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: �` CJ / Signed: • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,May 16,2017 Jim Regg P.I.Supervisor R eeJ</ it' it(7 SUBJECT: Mechanical Integrity Tests CC CONOCOPHILLIPS ALASKA INC 3K-103 FROM: Chuck Scheve KUPARUK RIV U WSAK 3K-I03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv��6�— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3K-103 API Well Number 50-029-23392-00-00 Inspector Name: Chuck Scheve Permit Number: 208-115-0 Inspection Date: 5/10/2017 Insp Num: mitCS170510161843 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-103 - Type Inj W 'TVD 3440 - Tubing 580 583 - 583 - 582 - PTD 2081150 ' Type Test SPT Test psi 1500 IA 1580 2510 - 2450 2440 BBL Pumped: 1.5 BBL Returned: 1.4 OA 187 � 208 188 _ 188 - Interval 4YRTST P/F L P Notes: SCANNED j L . 2017, Tuesday,May 16,2017 Page I of 1 ID • 213 O I I a, M `o c co N O > `� _ q w C7-0 o s 3 � r h o <�m X 4- 75 a- QTY; V O Y E 1 o-. o C N a- - r- .- ro � O Y N 0 a a C C c ,0 W rroo O v a c Q D Q', 0 m m CO CO co cc m m cc co r▪ r a) u o < r-- a a a- a- t• '-' 4C -0 Ln Q �- O o 0) U U U U U 0 U U ;,�- = CO,_ N W-1 (0000000009 c co U a1 a N N N M aS cD r tb O OU -0 13 O i u � N y0 ro O ro a1 -O ,� U M1a. 0000000000c ,_ (3) 0 O w J J J J J J J J J J C "= 0 w- ' a WW W W W W W W W W ocDC ' F LL LL LL LL LL U.. 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O O O o O o O `q 0 0 0 0 0 0 0 ro = N coVm m H H coVcoVa) ]� cm �,� 0 0 0 0 0 0 0 •a `J a c J� ) p co o 0 0 0 0 U al N- o 0 o 0 0 0 0 E N f� 6J! 0 N N M t0 T 4-, O co N1 O N N COt0 Q M M N 0 N f0 N M M 0 N 0 N N +' •_ �^ ry N N N N N N N �' _ Q N N N N N 0 N N tth • L 0) 0 0 0 0 — 0 0 c 0- 6 O O O O O O O co U O LI) N 1n I[) 0 1l) N y 0 VIM CO c w 0 0 O C CID LL) a+ Y 0a) ' E E • ,ice u Q ,1 Q n Mo to v O m a 'a fl3 (0 1 QJ r7 z C' C. 0 0 N w C i �c _▪ � d Q p N W �.•) N M r r E Z N O O .� V .-t u n 3 E v E E • //AA '3V--lo sicc, Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Friday, April 22, 2016 7:59 PM IZ��i� To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Prod Engr Specialist; NSK Optimization Engr; Sullivan, Michael; NSK West Sak Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 DS Lead Techs; CPF3 DS Lead Techs Subject: Return to service of LPP/SSV on well 3K-103 Mr Regg, Well 3K-103 (PTD 208-115-0) is now injecting at 305 psig, and the low pressure pilot controlled safety system was placed in service this morning (22-Apr-16) with a pilot setting of 250 psiig. Both sides/laterals of the well now have their safety systems in service. Please let me know if you have any questions, Thanks, Xen" .efayd S CANNED SEP_2 6 2016 Kenneth Lloyd Martin/Toon Changklungdee PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp#328 From: CPF3 Prod Engrs Sent:Tuesday, April 19, 2016 2:39 PM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: NSK Problem Well Supv<n1617@conocophillips.com>; NSK Prod Engr Specialist<n1139@conocophillips.com>; NSK Optimization Engr<n2046@conocophillips.com>; Sullivan, Michael <Michael.Sullivan@conocophillips.com>; NSK West Sak Prod Engr<n1638@conocophillips.com>; CPF3 Ops Supv(n2070@conocophillips.com) <n2070@conocophillips.com>; CPF3 Ops & DOT Pipelines Supt (n1175@conocophillips.com) <n1175@conocophillips.com>; CPF3 DS Lead Techs<n1105@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com> Subject: Return to service of LPP/SSV on well 3K-103L1 Mr. Regg, The L1 side of well 3K-103 (PTD 208-116-0) is now injecting at 384 psig, and the low pressure pilot controlled safety system was placed in service this morning (19-April-16) with a pilot setting of 250 psig. The other tubing string and completion, 3K-103 (PTD 208-115-0), still has the low pressure pilot defeated (and logged and tagged as appropriate), but has only increased in wellhead pressure to 200 psig. The AOGCC will be notified when the injection pressure has increased to above 250 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. 1 • 41111 Pm 2-6(31« Regg, James B (DOA) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Monday, April 18, 2016 8:43 PM < l f'4(Y To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Prod Engr Specialist; NSK Optimization Engr; Sullivan, Michael; NSK West Sok Prod Engr; CPF3 Ops Supv; CPF3 Ops & DOT Pipelines Supt; CPF3 Prod Engrs; CPF3 DS Lead Techs; CPF3 DS Lead Techs Subject: Defeated LPP/SSV on well 3K-103D Mr. Regg, The low pressure pilot(LPP) on injection well 3K-103 (PTD#208-115-0, 208-116-0)was defeated 16-Apr-16. The well had been shut in due the repair of the seawater supply line to the drill site and after initial monitoring on the morning of 17- April, the wellhead pressure did not rise high enough to place the low pressure pilot in service. The well is currently at a wellhead injection pressure of 175 psig and rate at 1100 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Xamet/t 2.1,aid Kenneth Lloyd Martin/Toon Changklungdee PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp#328 SCANNED SEP 2 6 2016 Ima a Pro~ct Well History File Cov~age 9 1 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 o S- ~ 1 S_ We11 History File Identifier Organiz-ng (done) RESC N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: gY: Maria Project Proofing gY: Mari Scanning Preparation gY: Maria Production Scanning ar, iuiuuimiuuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date:3 3 /a Date: ~ ~ I ~_ x 30 ~ s Date d Stage 1 Page Count from Scanned File: ~3 (count does include cov r sheet) ' NO Page Count Matches Number in Scanning Preparation: YES Date: 3 3 ~ /s/ gY: Maria / Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO Date: !s/ BY: Maria II I II'II) I II II I I III Scanning is complete at this point unless rescanning is required. IIIIIIIIIIIIIIIIIII ReScanned Date: /s/ gY: Maria Quality Checked III II~IIIIII II'llll Comments about this file: ^ Rescan Needed III II'IIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ lsl + ~ ~ =TOTAL PAGES (Count does not include cover sheet) /s/ 10/6/2005 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 15,2013 TO: Jim Regg •- v P.I.Supervisor Lei/ 1-7113 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-103 FROM: Bob Noble KUPARUK RIV U WSAK 3K-103 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J6E- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3K-103 API Well Number 50-029-23392-00-00 Inspector Name: Bob Noble Permit Number: 208-115-0 Inspection Date: 5/12/2013 Insp Num: mitRCN130513060459 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 2081150 Type Inj sPT 1500 180 2010 1950 . I 1950 3K-103 W•ITVD i 3440 IA 1320 PTD 1Type Test Test psi - ! OA 210 180 , ', ]so Interval 4YRTST 1P/F ' P - Tubing 600 600 1. 600 1 600 Notes: Dule comp.Short string prissures were 650,650,650,650. SCAM° FEB 2 0 2D14 Wednesday,May 15,2013 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 _ fF` F P/~ {~y~ ~ .. .. C.1, eaf. C.. 11 ~' RE: Water Flow Log /Injection Profile: 3K-103 Run Date: 3/15/2010 Apri18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-103 Digital Data in DLIS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23392-00 Spectra Flow Log 1 Color Log 50-029-23392-00 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. v ` L, Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273 rafael.barreto ~~~ ~ '~ ~~ 3rr 20~, 1 t ~~ ~ qi 5~l ~ Date: ail :~+a Signed: • DATA SUBMITTAL COMPLIANCE REPORT 2/23/2010 Permit to Drill 2081150 Well Name/No. KUPARUK RIV U WSAK 3K-103 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23392-00-00 MD 12411 TVD 3651 Completion Date 11/19/2008 Completion Status 1WINJ Current Status 1WINJ UIC REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / 7 e nnearrrmt rvumcer Name acme mea~a no Start Stop Vri Keceivea comments Log Cement Evaluation 5 Col 2000 5400 Case 11/7/2008 UCEL w/Welltrac Conveyance 6-Oct-2008 GAD C Pds 17061 ~ ement Evaluation 2000 5400 Case 11/7/2008 UCEL w/Welltrac I~ Conveyance 6-Oct-2008 )<6g Induction/Resistivity 25 Cot 120 12411 Open 2/3/2009 MD ROP, DGR, EWR 1- 4' Nov-2008 I i (,~,L~og Induction/Resistivity 25 Col 120 3651 Open 2/3/2009 ND ROP, DGR, EWR 1- i Nov-2008 frL`og Induction/Resistivity 25 Col 120 4410 Open 2/3/2009 PB1 MD ROP, DGR, EWR ~,~~'~ /~ 28-Sep-2008 Log Induction/Resistivity 25 Col 120 3415 Open 2/3/2009 P61 TVD ROP, DGR, EWR 28-Sep-2008 og Induction/Resistivity 25 Col 120 4527 Open 2/3/2009 P62 MD ROP, DGR, EWR 29-Sep-2008 ~I Log InductionlResistivity 25 Col 120 3461 Open 2/3/2009 PB2 TVD ROP, DGR, EWR 29-Sep-2008 i ~Xog Induction/Resistivity 25 Col 120 3569 Open 2/3/2009 P63 TVD DGR, EWR 8- Oct 2008 Log Induction/Resistivity 25 Col 120 6540 Open 2/3/2009 P63 MD DGR, EWR 8-Oct 2008 ~g Induction/Resistivity 25 Col 120 12373 Open 2/3/2009 P65 MD ROP, DGR, EWR 13-Oct 2008 ' Log Induction/Resistivity 25 Col 120 3545 Open 2/3/2009 P64 ND DGR, EWR 11- Oct 2008 J 1~ DATA SUBMITTAL COMPLIANCE REPORT 2/23!2010 Permit to Drill 2081150 Well Name/No. KUPARUK RIV U WSAK 3K-103 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23392-00-00 it4 i i i vu ano i I.OmPIeLlOfl U8i6 i u roi~uva ~.ornpieuvn ~~aws i vvu~~ wnem ~iaius i vvirv~ vn. r log Induction/Resistivity 25 Col 120 8794 Open 2/3/2009 PB4 MD ROP, DGR, EWR ~ i 11-Oct 2008 ~ og Induction/Resistivity 25 Col 120 3644 Open 2/3/2009 PB5 TVD ROP, DGR, EWR 13-Oct 2008 ED C 17562~duction/Resistivity 120 12411 Open 2/3/2009 EWR for Orginal Well, P61, PB2, P63, PB4 and P65 in PDS, EMF and CGM graphics D C Las ~ ~~ 17595r/Injection Profile 5499 12412 Case 2/20/2009 Injection Pro in TVD, Spin, Temp, GR, CCL, Pres Injection Profile 1 Col 5536 12086 Case 2/20/2009 Injection Pro, MPL, Pres, i GR, CCL, ILS, Temp, CFG ~pt LIS Verification 2506 12352 Sas2 1/13/2010 Lis Veri GR, FET, RPS, ~ ~ r~ RPD, RPM, RPX, ROP Rpt LIS Verification 2506 4527 fast; 1/13/2010 P62 Lis Veri GR, FET, c,~-- RPS, RPD, RPM, RPX, ROP Rpt LIS Verification 2506 6540 Cas~ 1/13/2010 P63 Lis Veri GR, FET, 6 ~--- RPS, RPD, RPM, RPX, ROP Rpt LIS Verification 2506 8794 Cash 1/13/2010 PB4 Lis Veri GR, FET, ~^~,r-~ RPS, RPD, RPM, RPX, ROP Rpt LIS Verification 2506 12373 Vie= 1/13/2010 P65 Lis Veri GR, FET, c,.~-w- RPS, RPD, RPM, RPX, ' S ROP C 19149 Notes 0 0 ~~~,,~ 1/13/2010 LIS ir~cis-for multiple plugbacks J Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/23!2010 Permit to Drill 2081150 Well Name/No. KUPARUK RIV U WSAK 3K-103 Operator CONOCOPHILLIPS ALASKA INC MD 12411 TVD 3651 ADDITIONAL INFORMATION Welt Cored? Y ~N Chips Received? '''f7Tf~ Analysis Y / N Received? Comments: Completion Date 11119/2008 Completion Status 1 WINJ Current Status 1 WINJ Daily History Received? ~ N Formation Tops Q~ N API No. 50-029-23392-00-00 UIC Y Compliance Reviewed By: __._._.-__ Date: ~_,~ r~~~ ~/ • i WELL LOG TRANSMITTAL To: State of Alaska January 4, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7"' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: 3K-103+L1+PB1+PB2+PB3+PB4+PB5 AK-MW-0006005291 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3K-103+PB1 +PB2+PB3+PB4+PB5 Digital Log Images &LWDG-formatted LIS Data w/verification listing; 1 CD Rom 50-029-23392-00, 70, 71, 72, 73, 74 3K-103 L1 Digital Log Images &LWDG-formatted LIS Data w/verification listing; 1 CD Rom 50-029-23392-60 Please acknowledge receipt by signing and returning/faxing the attached copies of the transmittal letter to the attention of: Speny Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.BurindaCc~halliburton.com \~., n . ~,. e r .:.~ '. vs~ ~a~s-~~S 19i~~9 u~~ ~o~s-irk t ~t r'S~ Date: '~-~'' ~~ _ _~,~~'~ Signed: ConocoPhillips P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: °vlJ'~ ~ ZOC1 .~~~~,~ .. ~ . ,f~J ~ti~ . 4~~r~msson ~f3ChOf~gE~ ~~~ ~ ~Jr 2,' ~ d3 3 ~< ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 20th and October 13th 2009. The corrosion inhibitor/sealant was pumped October 15th and 31St + November 1St and 2"d 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. mcerely, Perry Klein n ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C. 2D. 2Z & 3K Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15!2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/1/2009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11 /1 /2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1!2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01 A 50029209530100 2071110 14" NA 14" NA 1.7 11 /1 /2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11 /2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9!20/2009 2.12 11/1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11 /1 /2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330. 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 MEMORANDUM To: Jim Regg ~~'~~ (.,`~'fj j P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-]03 KUPARUK RIV U WSAK 3K-103 Src: Inspector Reviewed By: P.I. Suprv 1~L- ~InI~I_/-'/1NL'Tf~L`ATT7 ~ i Well Name: KUPARUK RN U WSAK 3K-103 Insp Num: mitCS090515170954 Rel Insp Num: API Well Number: so-o29-23392-00-0o Inspector Name: Chuck Scheve Permit Number: 208-115-0 Inspection Date: 5/l5/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-103 Type Inj. W 'j'Vp 3440 IA Izso zzso 2zzo zzzo P.T.D zosns° TypeTest SPT Test psi Isoo OA Iss zto Iss Iss Interval 4YRTST pn-, P '~ Tubing soo sso sso sso Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. Wednesday, May 20, 2009 Page 1 of I ~ ~ l'l4'.4/U~NI/7~AL ~; - - --- {, ProActive Diagnostic Services, Inc. To: AOC~C Christane Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) F59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A, Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245.8952 1) Injection Profile 06-FebX79 3K 103 1 Color og / E~ 50-029-23392-00 2) v~ c 2o5r-~r 5 , ~ s 9 5_ ~.~~~ ~~~ '.:, Signed : Date '' Print Name: , ..~~~„1,~;~~ PROACTIVE DIAGNOSTIC SERVICES, M1C„ 130 W. INTERNATIONAL AIRPORT RQ SUITE C, ANCHORAGE, AK 98518 PHONE: (807)245-8951 Fax: (907)245-88952 E-MAIL: ptisanteh€ara~e(arn~rnos*13ssg.rt3rrt WEBSITE:w~v+N.rt§ea~a~rii3os~.Lt3:~'3 C:\Docume~, and Settings\Owne~lDesktop\Tcens~nit Conoco.doc~t .Page 1 of 3 Maunder, Thomas E (DOA) From: CPF3 Prod Engrs [n1223@conocophillips.com] Sent: Thursday, February 05, 2009 3:35 PM To: Maunder, Thomas E (DOA); CPF3 DS Lead Techs Cc: CPF3 Prod Supt; Regg, James B (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: "NE West Sak Injector 3K-108 (208-130)". ~ ®~_ ~~~ ~Q~_ ~~°~ Tom, Sorry for any confusion. It was indeed the pilau for both strings; 3K-108 LPP and HPP & 3K-108L1 LPP and HPP that were taken out and then put back into service. You are correct that both the 3k103 and 3k-108 are dual tubing string injectors. Therefore, each string has a HPP and LPP. We will try to be more specific and use the nomenclature as you have described below. Please call ar message if you have any questions or need mare information. Thank you John Gondio /Tim Nelson CanocoPhilfips Alaska, lnc. CPF3 Production Engineers Email: N1223@conacophiliips.com Ph. {907) 659-7871 Fax. (907) 659-7806 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 05, 2009 12:00 PM To: CPF3 DS Lead Techs Cc: CPF3 Prod Engrs; CPF3 Prod Supt; Regg, James B (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Wayne, et al, I have had a chance to review the files. It appears that there are two individual tubing strings here, one for 3K- 108 and the other far 3K-108L1. Were the low pressure pilots defeated for both strings? If that is the case, the messages should have included the information for both stringslvalves. This could have also been the case for 3K-103 and 3K-103L1. If you or one of the engineers could provide the information for the pilots that were defeated and then placed back in service for each string, it will be appreciated. Just reply to this message. Equipping these wells with dual strings makes the reporting a bit more complicated when the pilots are defeated. It seems appropriate where dual strings are involved to make sure that the specific string with the defeated pilot is clearly identified (-108 or 108L1) or send separate messages for each string. Call or message with any questions. I look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, February 03, 2009 4:58 PM 2/13/2009 . • Page 2 of 3 To: 'CPF3 DS Lead Techs' Cc: CPF3 Prod Engrs; CPF3 Prod Supt Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Wayne, et al, I will have to check the files tomorrow. It appears I have messages regarding both 3K-108 and 3K-103. Tom Maunder, PE AOGCC From: CPF3 DS Lead Techs [mailto:n1105@conocophillips.com] Sent: Tuesday, February 03, 2009 4:41 PM To: Maunder, Thomas E (DOA) Cc: CPF3 Prod Engrs; CPF3 Prod Supt; CPF3 DS Lead Techs Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Tom, I hope I am sending this to the correct person; As we don°t currently have one of our P,E.'s on the slope; 3K-108 LPP's where satisfied and put back in service 2103109 ~ 16:30 if I need to do something else please let me know. Thank you very much. Wayne Griebel CPF3 DS Lead From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 03, 2009 3:02 PM To: CPF3 Prod Engrs; Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: RE: Tim, When you send a message such as this, please include a title. Specifically for a well with a defeated safety valve the title should in this case read "NE West Sak Injector 3K-108 {208-130)". Thanks in advance. Call or message with any questions. Tom Maunder, PE From: CPF3 Prod Engrs [mailto:n1223@conocophillips.com] Sent: Monday, February 02, 2009 6:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: Tom /Jim, This email is to notify the AOGCC that the North East West Sak (NEWS) Injector 3K-108 Low Pressure Pilots (LPP) are defeated as of 2/2/2009. This is in accordance with "Administrative Approval No. CO 4066.001" The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." The 3K-108 was brought on injection today, 2/02/2009. It is anticipated that injection pressure will increase above 250 psi within a few days. Current injection rate is 640 BWPD at 200 psi injection pressure in the B lateral and 430 BWPD at 235 psi injection pressure in the D lateral. 2/13/2009 • • Page 3 of 3 The AOGCC will be notified when the injection pressure has increased above 250 psi and the LPP functions are returned to normal. Tim Nelson /John Condio ConocoPhillips Alaska, Inc. CPF3 Production Engineers Email: N1223@conocophillips.com Ph. (907) 659-7871 Fax. (907) 659-7806 2/13/2009 NE West Sak Injector 3K-103 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: CPF3 Prod Engrs [n1223@conocophillips.com] Sent: Monday, February 02, 2009 5:19 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: NE West Sak Injector 3K-103 Tom /Jim, This email is to notify the AOGCC that the North East West Sak (NEWS) Injector 3K-103 Low Pressure Pilots (LPP) have been reactivated as of 1/23/09. This is in accordance with "Administrative Approval No. CO 4066.001 ". The LPP and SSV (Surface Safety Valve) have been removed from the "Facility Defeated Safety Device Log." The 3K-103 B lateral is currently injecting 830 bwpd at 550 psi and the 3K-103 D lateral is injecting 760 bwpd at 645 psi. Tim Nelson /John Condio ConocoPhillips Alaska, Inc. CPF3 Production Engineers Email: N1223@conocophillips.com Ph. (907) 659-7871 Fax. (907) 659-7806 2/3/2009 • WELL LOG TRANSMITTAL To: State of Alaska January 30, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-103+L1+PB1+PB2+PB3+PB4+PB5 AK-MW-6005291 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3K-103+Ll+PBl+PB2+PB3+PB4+PB5 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-233 92-00,60,70,71,72,73,74 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23392-00,60,70,71,72,73,74 Digital Log Images 2 CD Rom 50-029-23392-00,70,71,72,73,74 50-029-23392-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burin a@halliburton.com i ~ Date: ~ ' Signed ~T~ av~_`c~ c~5~3 3 ~~ A From: Maunder, Thomas E (DOA) Sent: Tuesday, January 27, 2009 1:37 PM To: Sale, Julie J Cc: Wharton, Paul K; Downey, Allison; Spenceley, Neil; Machal, Gloria; Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) and 3K-1031 (208-116) Yes, Julie that is correct. Call or message with any questions. Tom Maunder, PE AOGCC From: Sale, Julie J [mailto:Julie.J.Sale@conocophillips.com] Sent: Tuesday, January 27, 2009 1:26 PM To: Maunder, Thomas E (DOA) Cc: Wharton, Paul K; Downey, Allison; Spenceley, Neil; Machal, Gloria Subject: RE: 3K-103 (208-115) Thomas, Does this give you the information yoga are needing from ConocoPhillips? Proposed......R..eportng_M ethod On the AOGCC Monthly Injection Report (10-406), we typically report well level injection for multi-laterals because all injection goes through one meter at the surface. In this case we will have separate surface injection meters for each string so we have the ability to report at the wellbore/string level. Julie J. Sale ConocoPhillips Supervisor Revenue and Regulatory Upstream Accounting Alaska 930 G POB / Bartlesville, OK 74004 918-661-3523 (w) /918-914-3669 (c) • 918-662-1702 (fax) -• 620-778-4906 (personal-cell) Julie.j.saleC~conocophillips.com From: Spenceley, Neil Sent: Tuesday, January 27, 2009 11:31 AM To: Maunder, Thomas E (DOA) Cc: Wharton, Paul K; Downey, Allison; Sale, Julie J Subject: RE: 3K-103 (208-115) Tom, As per our conversation we will report the 3K injection volumes as follows: 2/5/2009 3K-103 - Doyon 15 - Current~us Page 2 of The well will be split in two (3K-i03 and 3K-103L1) to be reported as separate rate streams injecting into the West Sak oil pool. Please let me know if you would like to see it reported. differently. Thanks. Neil From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 27, 2009 8:14 AM To: Spenceley, Neil Subject: FW: 3K-103 (208-115) Here is that message trail. From: Downey, Allison [mailto:Allison.Downey@ConocoPhillips.com] Sent: Tuesday, January 13, 2009 8:47 AM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA); Hartwig, Dennis D; Sale, Julie J Subject: RE: 3K-103 (208-115) Tom, I am working the 3K-103 reporting issue with the Revenue Accounting group. We will have an answer for you soon on how the dual string injection will be reported. The well is not in service yet but is expected to start injection this week. Allison Allison Downey GIS Technical Data Management ConocoPhillips Alaska, Inc. 907-263-4299 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 12, 2009 3:00 PM To: Hartwig, Dennis D; Downey, Allison Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Dennis, Thanks. We will look forward to Allison's contact. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, January 12, 2009 2:56 PM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) 2/5/2009 3K-103 - Doyon 15 -Current ~s ~ Page 3 of Tom, I have forwarded on your questions to Allison Downey (Allison.dowrneXcr Conoco hill~s.com). Allison has been tasked with setting. up ATDB to store the lateral speeif c injection data separately as opposed to commingled. I left a phone message for Allison and. w-i11 continue to follow up until. your questions are answered. liegards...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConoeoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7109 Fay :907-265-1535 From: Maunder, Thomas E-(DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 12, 2009 1:40 PM To: Hartwig, Dennis D Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Thanks Dennis.. Also,. do you know if the well has been placed in operation? As we have looked into the particulars for this well.. several ques6ans regarding the injection reporting have come; up. To our knowledge, this is the first dual tubing, multi-lateral well into the V1lS and likely on the slope. l believe there are a few other dual tubing single penetration V1lS wells. In most cases, neither production nor injection is credited" to laterals since everything is eornmi:ngled in the wellbore. That is not.. the case here where the separate volumes in each string: can. be determined. lam not sure who would be the one to comment on haw the injection volumes. would be reported, however it appears that is a question that should be asked:. t'd appreciate if you could forward this portion of the message on for comment. Call or message with any questions. TQm Maunder, PE AOGCG From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, January 12, 2009 12:42 PM To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 (208-115) T011I, I will look into these issues and get back. to you ASAP...Denns Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConoeoPhillips Alasl£a - ATO-1592 Offce :907-265-b862 2/5/2009 3K-103 (PTD 208-115) LPP/S~ defeated ~ Page 1 of 1 Maunder, Thomas E (DOA) From: CPF3 Prod Engrs [n1223@conocophillips.com] Sent: Tuesday, January 20, 2009 9:47 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF3 Prod Engrs; CPF3 Prod Supt; NSK Problem Well Supv; CPF3 DS Lead Techs; NSK Well Integrity Proj Subject: 3K-103 (PTD 208-115) LPP/SSV defeated Attachments: 3K-103 (PTD 208-115) LPP/SSV defeated Tom/Jim, The low pressure pilot (LPP) on 3K-103 (PTD 208-115) was defeated on 01/19/09. The well is a dual tubing string completion with LPP devises on both strings. The second tubing string, 3K-103 D-Sand Lateral, was brought on line in seawater injection service for the first time on 1/19109 anct has a every low injection well head pressure (135 psi). The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001". Please note that the year was incorrect in the previous notification attached. The LPP on the Main Bore tubing string of 3K-103 (B-Sand) was defeated 01/19/2009. Please let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «3K-103 (PTD 208-115) LPP/SSV defeated» 1 /20/2009 3K-103 (PTD 208-115) LPP/S~ defeated ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Monday, January 19, 2009 3:42 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF3 Prod Engrs; CPF3 Prod Supt; NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 DS Lead Techs Subject: 3K-103 (PTD 208-115) LPP/SSV defeated Tom/Jim, b The low pressure pilot (LPP) on 3K-103 (PTD 208-115) was defeated on 01/19/f~ The well was brought on line in seawater injection service for the first time yesterday and has a very low injection well head pressure 0135 psi). The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device ~~ og. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Oft:lce (907) 659-7043 Cell (907) 943-1687 1 /20/2009 3K-103 - Doyon 15 -Current ~s Maunder, Thomas E (DOA) Page 1 of 2 From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, January 13, 2009 4:20 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Regg, James B (DOA); McKeever, Steve; Allsup-Drake, Sharon K Subject: RE: 3K-103 (208-115) Attachments: 3K-103 13.375 Casing Test.pdf; Wellhead Packoff test.ppt; 3K-103 as completed.pdf Tom, I have reviewed the 3K-103 operations and have addressed. your questions below with corresponding numbers to your questions. 1. On our daily reports, it was recorded that on September 26, the 13-3/8" casing was tested to 3125 psi for 30 minutes and over that 3Q minutes the pressure bled off 25 psi. The casing test was deemed good. Our documented practice is to perform the surface casing test to 3000 psi for 30 minutes and record same on a chart. While the BOP rating is 5000 psi, it is our practice to test as close to 3000 as possible. However, slight adjustments with the test pump can result in a testing pressure which is slightly above 3000 psi. After inspecting the charted pressure, (see attached 3K-103 13-3/8" casing test chart) the chart indicates a test pressure of what I would call between 3050 to 3025 psi over the duration of the test. The disparity between the report and chart may be due to slight difference in readings between the digital gauge and the chart recorder. 2. For all West Sak wells we set intermediate casing on slips to ensure that the string is in tension and avoid any leaks that may occur if the buttress thread were in compression. In order to set slips, cut casing and set the packoff, the wellhead is broken or rippled down between the casing head and the tubing head. After installing slips and packoff, the tubing head connection is again made up to the casing head. Through a test port the following components are tested; packoff to well head seal, intermediate casing to packoff seals and the flange connection between the tubing head and casing head. This test is conducted at 80% of intermediate collapse rating. Prior to drilling out the shoe, we again test the casing to 3000 psi which further tests the packoff to casing and packoff to wellhead seals. In effect the packoff and associated seals are the sealing mechanism for the break between the tubing and casing head.. I have attached a diagram which illustrates the break and testing points. 3. The final completion diagram is attached with all pertinent depths. I would be happy to run over an elaborate on any of the items above. . Thx...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7109 Fax :907-265-1535 2/5/2009 3K-103 - Doyon 15 - Current~us • Page 2 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 12, 2009 11:49 AM To: Hartwig, Dennis D Cc: Alvord, Chip; Regg, James B (DOA) Subject: RE: 3K-103 (208-115) Dennis, I have reviewed the completion report from the well and have some questions/observations. 1. On September 26, the 13-3/8" casing was tested. It is stated that the casing was pressured to 3125 psi which is greater than the BOP test pressure of earlier that day. Although the BOP rating was SK, it seems unusual to conduct such a test in excess of the test pressure. Please comment on this. 2. On October 5, after setting the 9-5/8" casing it was necessary to ND to cut the casing, set the slips and install the packoff. Nothing is mentioned in the operations summary about shell testing the BOP to verify the "break". It is noted that the choke line was tested, but not the stack. Please look into this and determine if the stack was shell tested. Provide appropriate documentation. 3. This well and the lateral were completed with dedicated tubing strings. While you have included drawings of 3K-103 and 3K-103L1 and they reflect the individual penetrations, unless one is familiar with the wells, it is not clearly shown that the well is equipped with 2 tubing strings. A drawing similar to that supplied with the permit to drill should be provided with the appropriate depths noted. I look forward to your reply. Please note for item 2, the Commission reserves the right to pursue an enforcement action if the BOP stack was not pressure tested after re-NU. Call or message with any questions. Tom Maunder, PE AOGCC 2/5/2009 1.-'. ~olrro~a-(~hil I i ps 48a•Mo- z.e7s•'DS Nlplae 2008 West Sak Dual Injector System 477'M0.2.87fi"D9 Nlpge with Level 5 Rotating self-Aligning Multilateral (RAMTM) System 4292' MD CMD Sllding Sleeve, }%" x 2.Btl" B%Pro91e {393' MD- GLM, Camco, }%^ x t" KBG2-9 West Sa k ,3-3/B•' ~a,ing Shoe 3K-103 2540' MD, 2217' TVD (43 deg) ~ 4588' MD-Anti-Rotation Clamp Dual Tubing Strings ~ 4670' M6 Adjustable Sub wdh Rotational Lock 3-%" 8.3q IBT wISCC L-80, 2.992" ID, 2.887" Drift %~~ 4621' MD- 2.750" D Nipple 4689' M0. }'/," x e-file" GT Dual Packer 4617 M6 2.871" DS Nipple ~, / ~ 0.Sand Casing Exit / 4675' MD, 3454' TVD 1839' M0. }%" x }%" x 9-618" Dual /r (80 deg) Seal Mod We for RAM Hangar / 1883' M0. 7"x9318" RAM Hanger Equipment SDecifi 7" X 9-5/8" RAM Junction Mainbore Drift: 3.68" Lateral Drift: 5.80" RAM HangerlSeal Bore Diverter OD: 8.375" Overall Length of RAM Junction: 38.1 h Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tpol: HRD-E 3-'/=" x 3-%" 9-5/S" Dual Seal Module OSM OD: 7.62" Lateral Seal Assembly OD: 3.75" Lateral lD: 2,69" Mainbore Seal Stinger OD: 3.08" Mainbore ID: 2.69" 1888' M0. 4%" x 9-518" RAM 8ea1 Bore Dlvarler jSBD) fq Dual Seal Module 4%" 12.8a IBTM a Hytlnl 521 Tu 1712' M0. 7" 8-fi/B" Ml: Liner Han er Packer 4740' M0. Seallrore RewPtade 0.76" ID 'D' Sand Lateral }'/." 9.3a Llnar with Hydrll fie3 and SLHT connactlons 4720' MD- MLHR Production Anchor IGi~ ~~ Baker Oil Tools As Completed Liner Shos 12338' MD, 3574' ND _. (88 deg) TD 12375' MD, 3578' TVD (68 deg) 1743' MD Seal ~ ~ `~~ Assemdy t.7fi" Seal OD 2 ~J 3.876"ID 'B' Sand Lateral 1`/," 9.3f1 Llnar WIM Hydr6 s83 and SLNT connactlona TD 12411' MD, 3651' TVD (88 deg) u, 71 .. ?f ^s 9-5/8" Casing Shoe, 5437' MD, 3551' TVD 40.Oif, L-80 BTC (88 deg) I owe m.: ~ 2008 Wast Sak Dual Labs Canpl ~~ Dab: - f0.awn aY: n.r 19°, 2009 lan Togm Liner Shoe 12324' MD, 3844' TVD (88 deg) q,.ana a,: Nion • InjecNr ~~WNabn Nw: :hP Iq:- _. y ~ 1 1 • • Packoff to casing seals ..,~ ~ ' ' `" _. ~ ~ ~~ f- Casing spool I-+~'C:3AIZICAL INTEGRITY REPORT ~~~ ~ -- OPER ~ FZELD ~ I~ ~~ I,~-:~~~3~'J ALL HtTMBER `j~" ~ ~~ ntLL DAT~_ TD : ?~.. T'VD ; ?BTD : ?ID TVD using \~`~s Shoe. J~13~ ~ 35~~ TVD; liV• N~?~ -T~r~i n`.1T } -~ -==,e.: Shoe : '~ '?'`ID ; :ter . _ ~; _~ol~- pzcicer :-+~ ?'STD; Cer ~t • ~ i L.. ~. ~-.~.~.~}©w C~ tica~~ : . =ole S«e ~~ ~y and ; perfs to ~C'r'..e~?~.C~?, INTEGRITY - ? a~T # czrulus ?ress Test: _? 15 nin ~0 min Comments '~* CRI~?1ICr~ INTEGR2'r'`v - PART # Z ~--mot '~"1~ ~~~ S Cement Volt~es :• Amt. Liner Csg `'`~~ Sc~` DV Cmt -rol to cove= oer=s ~ 3~?Cy.~ ~~ h~,\ ~, ~E~ ~® c~yCc i ~~ ~ 1 s~~ ©~J °~~ fit, ~L~ - - eoretical TOC ~ ~~Za~S ~...'~®(e(] -' VS~T ~~~ 4,~U Cement Band Log (Yes or No)--; In AOGCC File--~-- C9L Evaluation, gone above perfs ~v.C~-~~E~~ ~Do~~'~ production Log: Tyoue CONGLJS ~ OIdS : ?art :1 : • Evaluation ~nr~ jL: ~.1--~ ~.5 ~n ~-~l ~,, 3 ConocoPhillips December 23, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 3K-103 and 3K-103L1 Dear Commissioner: RECEIVED DEC 2 4 2008 Alaska Oil ~ Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 3K-103 and 3K-103L1. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, (/"~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 GCA/skad ~ RECE[VED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 4 2008 WELL COMPLETION OR RECOMPLETION ~~~ ~,jVD,,,~.0~: 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ~• WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. ne I Class: De rd~ Exploratory ^ Service ^/ ~ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 19, 2008 12. Permit to Drill Number: 208-115 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 23, 2008 13. API Number: 50-029-23392-00 . 4a. Location of Well (Governmental Section): Surface: 885' FSL, 314' FWL, Sec. 35, T13N, R09E, UM 7. Date TD Reached: November 1, 2008 14. Well Name and Number: 3K-103 Top of Productive Horizon: 2469' FSL, 2217' FEL, Sec. 35, T13N, R09E, UM 8. KB (ft above MSL): 74.6' RKB Ground (ft MSL): 33.8' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1829' FSL, 554' FEL, Sec. 36, T13N, R09E, UM 9. Plug Back Depth (MD + ND): 12322' MD / 3648' TVD West Sak Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529305 y- 6007879 • Zone- 4 10. Total Depth (MD + ND): 12411' MD / 3651' ND 16. Property Designation: ALK 25519 ' TPI: x- 532045 y- 6009474 Zone- 4 Total Depth: x- 538991 - 6008867 Zone- 4 11. SSSV Depth (MD + ND): landing nipple @ 470' MD / 470' TVD 17. Land Use Permit: 2555 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): approx. 1638' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GRlRES, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" x 34" 94# 40' 120' 40' 120' 42" 151 sx ASI 13.375" 68# L-80 43' 2540' 43' 2217' 16" 628 sx AS Lite, 156 sx DeepCRETE 9.625" 40# L-80 40' 5437' 40' 3551' 12.25" 430 sx LiteCRETE 3.5" 9.2# L-80 4712' 12324' 3460' 3648' 6.75" 3.5 Reslnject Screens 23. Open to production or injection? Yes ^ No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 5674'-5705' MD 3559'-3559' ND 10181'-10212' MD 3585'-3585' 3.5" 4692' 4593' 6408'-6440' MD 3574'-3576' ND 6937'-6966' MD 3583'-3582' ND 10488'-10519' MD 3590'-3590' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7373'-7404' MD 3583'-3583' ND DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7869'-7900' MD 3581'-3579' ND 11290'-11322' MD 3597'-3598' 3K-103PB5 5437'-12373' 150 bbls, 17 ppg 8463'-8494' MD 3558'-3557' ND 8964'-8995' MD 3569'-3569' ND 12135'-12166' MD 3643'-3643' 9526'-9558' MD 3586'-3587' ND 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facillity hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (core) 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 9Jy11J LLy:.(~~n ILif9 ~ ~FSk Se `~: {:~+ ~Ft. ,~~N :~ ~. ~OQ9 NONE ~ ijl` r I a I Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Pemlafrost -Bottom 1762' 1638' needed, and submit detailed test information per 20 AAC 25.071. Ugnu C 3200' 2709' Ugnu B 3664' 3032' Ugnu A 3836' 3140' N-sand 4113' 3286' K-13 4155' 3305' West Sak D 4677' 3454' West Sak C 4916' 3496' West Sak B 5378' 3546' 3K-103PB1 TD 4410' 3416' 3K-103P62 N/A • TD 4527' 3462' 3K-103PB3 TD 6540' 3570' 3K-103P64 TD 8794' 3545' 3K-103PB5 TD 12373' 3645' Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify th8t the foregoing is true and correct to the best of my knowledge. Contact: Des Hartwig @ 265-6862 Tp'~] Printed Name /~G-~. C. Alv--ord Title: Drilling Team Leader p~ ~.D U Date ~ L~Z-; t1f/\l1f/\ Phone Si t ~t! .. ~_ ~ f ~ gna ure , INSTRUCTIONS Sharon Altsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • ~ KUP 3K-103 ~(~~(,)~~`~~~ (Well Attributes _ Max An le & MD TD a~SFt3, InG. Wellbore APIIUWI Field Name Well Status Prorillnj Type Incl (°) MD (ftKB) Act Btm (ftKB) 500292339200 WEST SAK INJ SWI 93.33 6,927.03 12,411.0 "' Well Confiq MULTIPLE LATERALS - 3K-103 1. ;"/2008 Comment H2S (ppm) SSSV: NIPPLE 0 10:56:09 AM Date Annotation End Date KB-Grd (ft) 7/1/2008 Last WO: Rig Release Dat End Date schem a! c Ac[oal A nnotation Depth (ftKB) End Date Annotation _ ~""'"-' `,' L ast Tag; Rev Reason: NEW WELL 12/6/2008 Casin Strin s __ _ C asing Description OD (in) ID (in) Top (ftKB) Set Depth (f... Set Depth (TVD) ... Wt (Ibs/ft) Grade Top Connection CONDUCTOR 20 19.124 0.0 80.0 80.0 94.00 C asing Description OD (in) ID (in) Top (ftKB) Set Depth (f... Set Depth (TVD) ... Wt (Ibs/ft) Grade Top Connection SURFACE 13 3l8 12.415 0.0 2,540.2 2,217.1 68.00 L-80 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (f... Set Depth (TVD) ... Wt (Ibs/ft) Grade Top Connection coriDUCroR I NTERMEDIATE 9 5/8 8.835 0.0 5,437.0 3,551.3 40.00 L-80 BTC-m , 0-9o Casing Description OD (in) ID (in) Top (ftKB) Set Depth (f... Set Depth (TVD) ... Wt (Ibs/ft) Grade Top Connection Seal Bore Diverter 7 4.790 4,667.7 4,756.6 3,466.9 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (f... Set Depth (TVD) ... Wt (Ibs/ft) Grade Top Connection B-SAND LINER 3 1/2 2.992 4,711.5 12,323.7 3,648.4 9.20 L-80 Hyd 563 Liner De tails lop (ftK6) Item Description Comment ID (in) 4,711.5 PACKER Baker MLZXP liner Hanger Packer- above collet OD 8.30" / ID 6.184" 6.184 4,724.3 PACKER Baker MLZXP liner Hanger Packer- below collet OD 8.43" /ID 6.184" 6.184 4,732.8 HANGER Baker Flex-Lock Hanger 7" x 9-5/8" 8.29" OD x 6.18" ID 6.180 4,738.0 XO -Reducing Crossover 7" Hyd 563 box x 5-1/2" Hyd 563 pin, 7.66" OD x 4.88" ID 4.880 4,739.5 SBR 190-47 Casing Sealbore receptacle w/ (2) 3l8" hole @ 180 deg apart 6.3" OD x 4.75" 4.750 ID.Holes are 9' down from top of box. SURFACE, o-z,sao 4,806.2 XO -Reducing Crossover 5-1/2" hyd 563 box x 3-1/2" hyd 563 pin 6.05" OD x 2.992" ID 2.992 Tubin Strln s - Top Connection Tubing Description OD (in) ID (In) Top (ftKB) Set Depth (f... Set Depth (TVDj ... WS (Ibs/ft) Gr^dc TUBING B-SAND 3 1/2 2.992 36.3 4,692.9 3,456 ~+ 9.20 L "0 IBTM Com letion Details - Top (ftKB) Item Description Comment ID (In) 36.3 HANGER Vetco Gray Dual 13-3/8" x 3-1/2" x 3-1/2" w/ 3.725" MCA Top Connection 3.500 470.9 NIPPLE 3-1/2" Camco "DS" Nipple w/ 2.875" Profile (EUE 8rd) (4.265" O.D.) 2.875 4,586.8 Packer -Dual Baker "GT' Dual Packer Mandrel (3-1/2" NU 10rd Box x Pin) 2.930 GAS LIFT, 4,589.0 Packer -Dual Baker 9-5/8" x 3-1/2" "GT' Retrievable Dual Packer (40K Shear Release) 2.920 a,2sz 4 592 6 Packer -Dual Baker "GT" Dual Packer Mandrel (3-1/2" NU 10rd Box x Pin) 2.920 Seal Bore , . Diverter, a,sssa,757 4,616.8 NIPPLE 3-1/2" Camco "DS" Nipple w/ 2.812" No-Go Profile (EUE 8rd P x B) 2.812 JTERMEDIATE, o-s,a37 4,625.1 Extension Jt Baker 3.38", L-80, "DSM" Extension Joint (3.220" SSDS Box x Pin) 2.690 Screen, s,s7a-5,7os _ 4,633.7 Extension Jt Baker 3.38", L-80, "DSM" Extension Joint Mandrel (3.220" SSDS Box x Pin) 2.690 Screen, s,aos-s,aao 4,639.2 Dual Seal Module Baker 7" x 9-5/8" "Ram" Dual Seal Module (Above Collet) 2.690 Screen, s,s37~,sss 4,665.7 Dual Seal Module Baker 7" x 9-5/8" "Ram" Dual Seal Module (Below Collet) 2.690 Screen, 7,373-7,404 4,671.6 Extension Jt "DSM" Extension Joint Mandrel Travel (Travel 21.27' /Over all 29.84') 2.690 Screen, 7,ess-7,soo 4,692.9 TTL BAKER SLICK STINGER TTL 2.705 Screen, 8,463-9,494 screen, ' PerforatlOnS 8,964-8,995 _ Shot Screen, 9,526-9,558 Screen, Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftK6) Zone Date Dens (sh••• Type Comment 1o,te1-1o,z1z 673 8 5 704 5 5 3 558.7 3,558.9 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens Screen, . , . , , 1o,aea-1o,s1s 408 2 6 6 439 6 574.4 3 575.5 3 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens Screen, . , , . , , 11,zsa11,322 937 2 6 965 8 6 3 582.5 3,581.7 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens Screen; . , . , , iz,135-1z,1ss 7 372 6 7 404 0 583.1 3 583.3 3 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens BRAND , . , . , , LINER, 7 868 6 0 7 900 7 3 580 578.5 3 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens 4,712-12,324 , . , . , . , D3AND 462 7 8 494 1 8 3 557 6 3 556.8 3K-103 WS B 11/5/2008 99.0 Screen Alternating solid pipe/screens LINER, . , . , , . , , 4,663-12,336 8,963.5 8,994.9 3,568.3 3,568.8 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens 9,526.3 9,557.7 3,586.2 3,586.5 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens 10,180.9 10,212.3 3,584.7 3,584.8 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens - 10,487.8 10,519.2 3,589.5 3,590.1 WS B, 3K-103 11/5/2008 99.0 Screen Altemating solid pipe/screens ,~ 11,290.3 11,321.7 3,597.3 3,597.7 WS B, 3K-103 11/5/2008 99.0 Screen Alternating solid pipe/screens 12,134.5 12,165.9 3,643.1 3,643.1 WS B, 3K-103 11/5/2008 99.0 Screen Altemating solid pipe/screens :; -T Notes: General & Safe )° End Date Annotation * 1 2/612 00 8 NOTE: VIEW-SCHEMATIC w/Alaska Schematic9.0 12/6/2008 NOTE: Multi-Lateral Well 3K-103 (B-SAND) 3K-103L1 (D-SAND) w/Dual TBG Strings - Mandrel Details' _ - Port _ _ Valve Latch Size TRO Run Stn Top (ftKB) Make Model OD (in) Serv Type Type (inT (psi) Run Date Comment 1 4,291.6 CAMCO KBG-9-2 1 Gas Lift SOV INT 0 0.0 11/16/2008 DCK-3 `; `_~ ~_ E~ -. 1 _ ~ - TD (3K-103), ~ - . ~ ~~ ~"-~ ' 12,411 • Cor~oCQP~tillps Time Log & Summary WetNfew Web Repontng Report Well Name: 3K-103 Rig Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 9/23/20081:00:00 AM Rig Release: 11/19/2008 10:00:00 PM Time Logs _ Date From To Dur S. De th E. D th Ph e Code Subcode T Comment 9/22/2008 2a hr summary Move rig from 3K-108 to 3K-103, rig up. Ri acts ted 0100 h rs 9/2 3/2008. 06:00 07:00 1.00 0 0 MIRU RIGMNT SVRG P Pre job safety meeting. Slip and cut 130' of 1-3/8" drillin line. 07:00 07:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting. 07:15 09:00 1.75 0 0 MIRU MOVE RURD P Disconnect lines to skid floor to center of module. 09:00 09:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting 09:15 09:45 0.50 0 0 MIRU MOVE SKID P Skid rig floor to moving position. 09:45 10:00 0.25 0 0 MIRU MOVE RURD P Raise support feet on cantilever. 10:00 10:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting 10:15 10:45 0.50 0 0 MIRU MOVE MOB P Move pit module away from sub module. 10:45 11:15 0.50 0 0 MIRU MOVE MOB P Moving mats and prepare to move sub module. 11:15 11:30 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting 11:30 12:00 0.50 0 0 MIRU MOVE MOB P Move rig off of 3K-108. 12:00 15:30 3.50 0 0 MIRU MOVE MOB P Move sub down pad, spot over well 3K-103. 15:30 18:00 2.50 0 0 MIRU MOVE MOB P Move pits down pad to sub module. Set stompers, preload stompers to 750 psi, skid rig floor. Prep beaver slide to than a out doors. 18:00 21:00 3.00 0 0 MIRU MOVE MOB P Continue to move pit complex onto mats, then spot next to sub. Welder working on beaver slide door. Lay out herculite for rockwasher. 21:00 22:30 1.50 0 0 MIRU MOVE MOB P Working on secondary containment around rig, spot rockwasher. Installing beaver slide doors. Apply roof ca son i e shed. 22:30 00:00 1.50 0 0 MIRU MOVE MOB P Set cutting boxes for rock washer. Working on pre acceptance check list. Acce ted ri 0100 hrs 9/2 9/23/2008 Completed pre-acceptance ch ecklist. RIG ACCEPTed @ 01:00. Loaded and picked up 5" HWDP and 5"drill pipe. Installed riser and function tested diverter. Flooded conductor and spudded well @ 15:00. Began drilling 16" surface hole. S'~ye 1 of 7~ Time Logs _ _ __ __ Date From To Dur S De th E. De th Ph e Code Subcode _T Comment _ 00:00 01:00 1.00 0 0 MIRU MOVE RURD P Set cutting boxes for rock washer. Working on pre acceptance check list. Udate well sign, plumb bob center of hole-good, handrails in place, air- water- steam -fuel lines hooked up, drains lines to drip pans hooked up, cellar pump and alarm hooked up. Acce ted ri 0100 hrs 9/23/2008. 01:00 04:00 3.00 0 0 MIRU DRILL OTHR P Load pipe shed with 24 joints of 5" drill pipe, 14 joints of 5" HWDP, jars, BHA #1.Fill pits with spud mud. Work on door f/the beaver slide. 04:00 06:00 2.00 0 0 MIRU WELCTI NUND P Pickup riser for the diverter, lower through rotarty table to hook up. Problem with a stud hole on diverter. 06:00 08:45 2.75 0 0 MIRU WELCTL NUND P Continue to nipple up diverter. 08:45 09:15 0.50 0 0 MIRU WELCTt BOPE P Function test diverter system. Open knife valve - 8 seconds, bag closed 27 seconds. Drawdown test starting pressure 3000 psi, drawdown 1700 psi, build 200 psi in 54 seconds, full charge 2 minutes 35 seconds. Witness waived b Chcuk Sheve. 09:15 09:30 0.25 0 0 MIRU DRILL TRIP P RIH and tag bottom @ 104' MD. 09:30 11:00 1.50 0 0 MIRU DRILL PULD P Rig up and pick up 4 stands 5" HWDP and 8 stands 5" DP. 11:00 11:45 0.75 0 0 MIRU RIGMNT SVRG P Lubricate and service rig. 11:45 12:30 0.75 0 0 MIRU DRILL RURD P Rig up gyro tools. 12:30 13:45 1.25 0 0 SURFA( DRILL PULD P Pick up and make up drilling BHA (bit, motor, float sub, non mag XO, DM HOC, stabilizer, HCIM collar, TM HOC and UBHO sub . 13:45 14:15 0.50 0 0 SURFA( DRILL PULD P Upload MWD. 14:15 14:45 0.50 0 0 SURFA( DRILL PULD P Continue to make up BHA. 14:45 15:00 0.25 0 0 SURFA( DRILL CIRC P Flood conductor and pressure test lines to 3000 si. 15:00 15:15 0.25 0 0 SURFAt DRILL CIRC P Drill out conductor with water then swa over to s ud mud. 15:15 17:15 2.00 0 278 SURFA( DRILL DDRL P e., 17:15 18:00 0.75 278 278 SURFA( DRILL TRIP P POOH, pick up remaining BHA and tri back in to TD. 18:00 00:00 6.00 278 711 SURFAt DRILL DDRL P Drill surface hole. 9/24/2008 TD16" surface at 2,550' MD and 2,224' TVD. Circulate and condition hole and drilling fluid. Back ream out of hole with 750 gpm and pulling 45 feet per minute up to 1,900' and from 1,900' to 624' with 550 gpm. Pull from 624' with elevators to bit, la down 2 'ts hwd , 'ars, and rack back collars. Break bit, down load MWD data. 00:00 06:00 6.00 711 1,203 SURFA( DRILL DDRL P Drilling surface F/ 717' MDT/1,203' MD, 1,166' TVD 06:00 12:00 6.00 1,203 1,859 SURFA( DRILL DDRL P Drilling surface F/ 1,203' T/ 1,859' MD, 1,713' TVD 12:00 17:30 5.50 1,859 2,550 SURFA( DRILL DDRL P Drilling surface F/ 1,859' T/TD @ 2,550' MD D F~ag~ ~ cif ~2 Time Logs _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 17:30 19:00 1.50 2,224 2,550 SURFA( DRILL CIRC P Circulate two bottoms up @ TD, condition hole and drillin fluid 19:00 19:15 0.25 2,550 2,550 SURFA( DRILL OWFF P Monitor Well for flow (STATIC) 19:15 22:00 2.75 2,550 624 SURFA( DRILL REAM P BROOH F/ 2,550' T/ 1,900' with 750 gpm @ 2300 psi; BROOH F/ 1,900' T/ 624' with 550 m 1290 si 22:00 23:30 1.50 624 360 SURFA( DRILL TRIP P POOH on elevators F/ 624' T/ 360' 23:30 00:00 0.50 360 0 SURFA( DRILL SRVY P Download MWD 9/25/2008 Lay down directional tools, safety meeting rigging up TESCO unit, pick up and rig up TESCO unit. PJSM on running 13 3/8" casing, run 13 3/8" casing, landed at 2540' MD and 2224' TVD @ 44 degrees inclination. Rig down TESCO unit, PJSM rigging up cementers, rig up cement head, circulate two bottoms up, cement casing. Pumped 498 bbls lead, 69 bbls tail, bumped plug on calculated strokes, held 1000 psi for 10 minutes. 207 bbls cement back to surface. Rig down cement head and landing joint, nipple down diverter and flow lines. Ni le u well head. 00:00 01:00 1.00 0 0 SURFA( DRILL TRIP P Lay down BHA 01:00 01:30 0.50 0 0 SURFA( RIGMNT SVRG P Clean and clear rig floor 01:30 02:00 0.50 0 0 SURFA( RIGMNT RURD P Rig down short bails, and bail guide. 02:00 02:30 0.50 0 0 SURFA( CASING SFTY P PJSM pick up and rig up Tesco unit. 02:30 03:15 0.75 0 0 SURFA( CASING RURD P Pick up and rig up Tesco unit. 03:15 03:45 0.50 0 0 SURFA( CASING SFTY P Post job review on rigging up Tesco unit and a PJSM on running 13 3/8" casin . 03:45 04:15 0.50 0 170 SURFA( CASING RNCS P Pick up run 13 3/8" casing (68 ppf, L-80, BTC . 04:15 04:30 0.25 170 170 SURFA( CASING CIRC P Circulate and check float equipment um in 4 bbl/min. 04:30 07:30 3.00 170 1,272 SURFA( CASING RNCS P Running surface casing. Casing sticking at 500' MD, washed down 1 joint and continued running without roblems. 07:30 08:00 0.50 1,272 1,272 SURFA( CASING CIRC P Circulate bottoms up pumping 6 b m, 100 si. 08:00 10:00 2.00 1,272 2,540 SURFA( CASING RNCS P Running surface casing. 10:00 10:45 0.75 2,540 2,540 SURFA( CASING RNCS P Make up hanger, handling sub, and landin 'oint. 10:45 12:00 1.25 2,540 2,540 SURFA( CASING RURD P Rig down Tesco unit and rig up cement head. 12:00 15:00 3.00 2,540 2,540 SURFA( CEMEN" CIRC P Circulate and condition mud for, cement. Pumped two bottoms up, staging rate up to 7 bpm @ 240 psi. PU wt 238K, SO wt 185K, No losses. ~~ Faye 3 of TZ • T+me Logs _ __ __ Date From To Dur S. De th E. De th Pha; e Code Subcode T Comment 15:00 18:30 3.50 2,540 2,540 SURFA( CEMEN" CIRC P Turn over to Dowell, Pumped 5 bbls CW100, Shut down ,Test lines to 3000 psi, Continue to pump total of 75 bbls CW100 @ 8.3 ppg at rate of 6.3 bpm @ 128 psi„ Followed by 75 bbls MUDPUSH II mixed @ 10.5 ppg w/ 2 gals.of red marker dye at rate of 5.5 bpm @ 100 psi. Dropped bottom plug, Mix & pump 628 sxs, 498.4 bbls. @ 10.7 ppg of ARCTICSET Lite Lead cement, Followed by 156 sxs, 68.7 bbls. @ 12 ppg. of DeepCRETE tail cement., Cement pumped at rate of 6 bpm @ 100 psi, Drop top plug, Displace cement w/ 10 bbls Fresh water followed by 358.6 bbls 9.1 ppg mud at rate of 7.5 bpm @ 290 to 510 psi, Reciprocate casing 10' to 30' until 224.9 bbls. of cement went around the shoe, became stick . Landed casing in load shoulder, Slowed rate to 3 bpm @ 360 psi for last 10 bbls, Bumped plug w/ 1000 psi, Had full returns thru out job with 207.7 bbls o0 surface, C.I.P. 18:30 hrs 9/25/08 18:30 19:00 0.50 0 0 SURFA( CEMEN" CIRC P Flush stack with water, function bag. 19:00 20:00 1.00 0 0 SURFAt CEMEN" RURD P Rig down cement head and landing 'oint. 20:00 22:45 2.75 0 0 SURFA( WELCTL NUND P Nipple down riser, bag, speed head, and diverter line. 22:45 23:00 0.25 0 0 SURFA( WELCTL SFTY P PJSM, nipple up BOPE. 23:00 00:00 1.00 0 0 SURFA( WELCTL NUND P Nipple up well head, install 4" caps on conducter, install thread on flan e, and seal sub. 9/26/2008 Nipple up wellhead and BOPE. Test BOPE. Test witnessed by AOGCC Bob Noble. Passed. Pickup and run in hole with 12-1/4" bit and BHA. Single in hole with 5"drill pipe, tagged cement, circulated bottoms up and erformed casin test. Good test. 00:00 01:15 1.25 0 0 SURFA( WELCTI NUND P Continue nippling up wellhead. Test connection to 5000 psi for 10 mins. Good test. 01:15 01:30 0.25 0 0 SURFA( WELCTL SFTY P PJSM -nipple up ROPE 01:30 07:30 6.00 0 0 SURFAt WELCTL NUND P Nipple up BOP stack, riser, choke and kill line, bell nipple, flow line and turn buckles, and dri an. 07:30 08:15 0.75 0 0 SURFA( WELCTL BOPE P Rig up BOPE test equipment. Pare ~ esf 72 Time Logs _ __ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 08:15 12:30 4.25 0 0 SURFA( WELCTL BOPE P Test B~, OPE (250 psi low, 3000 psi high). Test witnessed by AOGCC inspector Bob Noble. 35 components tested. Manual choke valve failed, greased and cycled vale and retested ok. Tested annular preventer with 3-1/2" & 9-5/8" and VBRs with 3-1/2", 4" & 5". Accumulator drawdown test starting pressure 3000 psi, draw down to 1600 psi. 47 seconds for 200 psi increase and 2 minutes 52 seconds to full charge. 5 bottle avera a ressure 2450 si. 12:30 13:15 0.75 0 0 SURFA( WELCTL BOPE P Remove test plug and install wear bushin . 13:15 13:45 0.50 0 0 SURFAC WELCTI BOPE P Blow down lines and choke manifold. Line u valves. 13:45 14:15 0.50 0 0 SURFAC RIGMNT SVRG P Service crown, drawworks and top drive. 14:15 14:45 0.50 0 0 SURFA( DRILL PULD P Bring BHA subs to rig floor per Directional Driller. 14:45 15:30 0.75 0 0 SURFAC DRILL RURD P Rig up short bails, link tilt, 5" elevators and ton s. 15:30 15:45 0.25 0 0 SURFA( DRILL SFTY P PJSM -picking up and making up BHA 15:45 17:15 1.50 0 0 SURFA( DRILL PULD P Make up BHA per Directional Driller & MWD. 17:15 18:30 1.25 0 0 SURFAI DRILL PULD P Upload MWD 18:30 19:15 0.75 0 368 SURFAC DRILL TRIP P TIH with BHA (MWD, collars, jars and HWDP 19:15 19:45 0.50 368 368 SURFA( DRILL DHEQ P Shallow pulse test MWD pumping 700 m, 1160 si. Good test. 19:45 21:45 2.00 368 2,444 SURFA( DRILL TRIP P Single in hole with 5"drill pipe (30 joints with wear socks + 36 joints slick) Tag upon cement @ 2444' MD pumping 3 bpm, 250 psi. Set down 10k. PU wt 150k, SO wt 120k. 21:45 22:15 0.50 2,444 2,427 SURFA( DRILL CIRC P Circulate bottoms up at 625 gpm, 1240 si rotatin 50 m. 22:15 22:30 0.25 2,427 2,427 SURFA( CASING RURD P Rig up for casing test using BOP test um . 22:30 23:30 1.00 2,427 2,427 SURFAC CASING DHEQ T Close bag and pressure up to 2000 psi. Annulus valve leaking. Bleed off pressure, open bag, tighten flange and rease valve. 23:30 00:00 0.50 2,427 2,427 SURFAC CASING DHEQ P Close ba prPCSUr . un to 3125 psi using BOP test um .Held for. 30 minutes, lost 25 si. Good test. 9/27/2008 Drilled out cement and plugs, drilled 20 feet formation and pulled back into shoe. Performed LOT, test resulted in a EMW of 12.8. Drilled from 2,570 feet to 4,052 feet. BHA not building as needed. Discuss options with town. Decision made to trip out and change motor bend and bit. Pump sweep and bottoms up and tri out of hole, ulled ti ht 2,938 feet and back reamed to surface casin shoe. 00:00 01:00 1.00 2,427 2,427 SURFA( DRILL RURD P Finish casing test and rig down test e ui ment, flush lines with water. 01:00 01:15 0.25 2,427 2,427 SURFA( RIGMNT SFTY P PJSM -changing saver sub. Pag~a ~ €~f 72 • • Time Logs _ __ te From To Dur S. De th E. De th Da Phase Coe Subco e T Comment ~ __ 01:15 02:45 1.50 2,427 2,427 SURFA( RIGMNT RURD P Change out 4 1/2" IF saver sub and dies in rabber. 02:45 03:15 0.50 2,427 2,427 SURFA( RIGMNT SVRG P Service top drive, swivel packing, and blocks. 03:15 04:15 1.00 2,427 2,550 SURFA( CEMEN" DRLG P TIH, drill plugs, cement and 20 feet of new hole. Ta ed u on de th. 04:15 04:45 0.50 2,550 2,570 SURFA( DRILL DRLG P Drill 20 feet of new hole 04:45 05:30 0.75 2,570 2,570 SURFA( DRILL CIRC P Displace well over to LSND(9.1 ppg, 50 vis) and circulate bottoms up pumping 750 gpm, 1440 psi. PU wt 155k, SO wt 120k 05:30 05:45 0.25 2,570 2,521 SURFA( DRILL TRIP P Pull up into casing and, rig up for LOT with test um . 05:45 07:30 1.75 2,521 2,521 SURFA( DRILL LOT P Perform leak off test. at 2521 feet MD and 2442 feet TVD, with 9.1 ppg, 50 vis mud. LOT pressure at 425 psi with EMW of 12.8 07:30 07:45 0.25 2,521 2,570 INTRM1 DRILL TRIP P Rig down test equipment. TIH to 2570 feet. 07:45 12:00 4.25 2,570 3,126 INTRM1 DRILL DDRL P Drilling 12-1/4" intermediate hole from 2,570 feet to 3,126 feet MD, 2,644 feet TVD. 12:00 18:00 6.00 3,126 3,791 INTRM1 DRILL DDRL P Drilling from 3,126 feet to 3,791 feet MD, 3,121 feetTVD. 18:00 21:00 3.00 3,791 4,052 INTRM1 DRILL DDRL P Drilling from 3,791 feet to 4,052 feet MD and 3,271 feet TVD. BHA not buildin as planned. Discuss options with town. 21:00 21:45 0.75 4,052 4,052 INTRMI DRILL CIRC T Continue discussing options with town. Prepare to POOH for BHA. Circulate bottoms up pumping 60 bbl high viscosity sweep at 900 gpm 2360 si. 21:45 22:15 0.50 4,052 3,889 INTRM1 DRILL REAM T BROOH 2 stands while working on options with town. Decision made to POOH and change bit and motor bend from 1.15 to 1.5. 22:15 22:30 0.25 3,889 3,889 INTRM1 DRILL OWFF T Monitor well, well static. 22:30 23:30 1.00 3,889 2,938 INTRM1 DRILL TRIP T Pull out of hole on elevators from 3,889 feet to 2,938 feet, drag encountered and ullin 25k over. 23:30 00:00 0.50 2,938 2,525 INTRM1 DRILL REAM T BROOH to casing shoe 9/28/2008 Circulated casing clean, tripped out of hole to change BHA motor bend and bit. Trip in hole with BHA #3 and resumed drilling 12-1/4" intermediate hole. BHA building excessive dog legs. Washed and reamed to reduce dog legs. While reaming hole inadvertently side tracked well at 4,260' MD. Discussed options with town and made decision to continue drillin . 00:00 00:15 0.25 2,525 2,525 INTRM1 DRILL TRIP T BROOH to casing shoe. 00:15 00:30 0.25 2,525 2,525 INTRM1 DRILL OWFF T Monitor well for flow, well static. 00:30 01:45 1.25 2,525 2,525 INTRM1 DRILL CIRC T Circulate casing bottoms up with 50 bbl high vis sweep, 250 vis, 900 gpm at 2180 psi, scalpers and shakers overrun with heavy clay, pump second 50 bbl vis sweep, 270 vis, 900 m, at 1950 si. P~r~~ 6 of 71 C J • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:45 02:00 0.25 2,525 2,525 INTRM1 DRILL OWFF T Monitor well for flow, well static. Sim o s PJSM for POOH. 02:00 02:30 0.50 2,525 2,525 INTRM1 DRILL CIRC T Pump 15 bbl dry job, 10.9 ppg, 51 vis, and blow down to drive. 02:30 03:30 1.00 2,525 368 INTRM1 DRILL TRIP T POOH on elevators from 2525 feet to 368 feet. 03:30 03:45 0.25 368 368 INTRM1 DRILL CIRC T Monitor well for flow, falling. 03:45 04:15 0.50 368 85 INTRM1 DRILL TRIP T POOH handling BHA. 04:15 04:45 0.50 85 85 INTRM1 DRILL TRIP T Down load MWD. 04:45 06:00 1.25 85 0 INTRM1 DRILL TRIP T POOH to bit. 06:00 06:30 0.50 0 0 INTRM1 DRILL TRIP T Change out ABI (at bit inclination) sensor. 06:30 08:00 1.50 0 0 INTRM1 DRILL PULD T Pick up, make up BHA # 3. 08:00 08:30 0.50 0 0 INTRM1 DRILL TRIP T Upload MWD. 08:30 09:15 0.75 0 368 INTRM1 DRILL TRIP T Trip in hole with BHA #3 to 368 feet. 09:15 09:30 0.25 368 368 INTRM1 DRILL TRIP T Shallow test MWD with 700 gpm, 310 si. 09:30 10:00 0.50 368 2,460 INTRM1 DRILL TRIP T Trip in hole from 368 feet to 2,460 feet. 10:00 10:30 0.50 2,460 2,460 INTRM1 RIGMNT SVRG P Service rig, lubricate and inspect. 10:30 11:00 0.50 2,460 3,125 INTRM1 DRILL TRIP T Trip in hole from 2,460 feet to 3,125 feet. 11:00 11:30 0.50 3,125 3,125 INTRM1 DRILL CIRC T Check shot survey at 3,125 feet. 11:30 12:00 0.50 3,125 4,052 INTRM1 DRILL TRIP T Trip in hole from 3,125 feet to 4,052 feet. 12:00 12:15 0.25 4,052 4,052 INTRM1 DRILL CIRC T Obtain slow pump rate at 4,052 feet. 12:15 17:00 4.75 4,052 4,362 INTRMI DRILL DDRL P Drilling from 4,052 feet to 4 362 feet, ~ ~-~ 339T TVD . 17:00 17:15 0.25 4,362 4,270 INTRM1 DRILL TRIP P Inclination to high. POOH on, elevators from 4,362 feet to 4,270 feet. 17:15 18:15 1.00 4,270 4,175 INTRM1 DRILL REAM P Wash and ream hole from 4,270 feet to 4,175 feet to reduce inclination. 18:15 18:45 0.50 4,175 4,362 INTRM1 DRILL REAM P Wash and ream back to bottom from 4,175 feet to 4,362 feet. 18:45 19:30 0.75 4,362 4,410 INTRM1 DRILL DDRL P Drilling from 4,362 feet to 4410 feet MD and 3,414 TVD. 19:30 20:00 0.50 4,410 4,160 INTRM1 DRILL TRIP P POOH from 4,410 feet to 4,160 feet, to wash and ream for high of inclination. 20:00 22:00 2.00 4,160 4,260 INTRM1 DRILL REAM P ash and ream to reduce inclination from 4,160 feet to 4,270 feet. Inadverte feet while attempting to ream out excessive dog legs. Call town to discuss options. Decision made to drill ahead. 22:00 00:00 2.00 4,260 4,408 INTRM1 DRILL DDRL P Drilling from 4,260 feet to 4,408 feet MD, and 3,418 feet TVD. P~qe 7 of 7~ Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 9/29/2008 2a hr Summary Experienced directional trouble drilling 12-1/4" intermediate hole. Discussed options with town. Decision was made to drill down to confirm the top of the West Sak formation, pull out of hole and plug back for a sidetrack. Pulled out of hole with drilling assembly and ran in with cement stinger on drill pipe. Serviced and inspected ri while waitin on cement. 00:00 00:30 0.50 4,408 4,410 INTRM1 DRILL DDRL P Drilling 12-14" intermediate hole 00:30 01:15 0.75 4,410 4,410 INTRM1 DRILL CIRC T Continue to have trouble makin turn. Lost some of the build in the sidetrack. Top of the D sand predicted to come in 10'. Circulate and service rig while discussing o lions with town 01:15 02:45 1.50 4,410 4,270 INTRM1 DRILL REAM T Pull off bottom and pump sweep. Slowing BROOH while making plan forward. No increase in cuttings when swee returned. 02:45 03:00 0.25 4,270 4,410 INTRM1 DRILL TRIP T Decision made to~rill ahead and - confirm_the top of the D sand while Directional Planners work on o lions. r 03:00 04:45 1.75 4,410 4,527 INTRM1 DRILL DDRL P Drill intermediate hole into until MWD tools in the D sand. D sand top 3443' TVD, 10' TVD hi h from ro nosis. 04:45 06:00 1.25 4,527 4,527 INTRM1 DRILL CIRC Pull off bottom, reciprocate and circulate while discussing options with town. Decision made to plug back and sidetrack. 06:00 06:15 0.25 4,527 4,527 INTRM1 DRILL OWFF T Monitor well -static 06:15 08:45 2.50 4,527 2,462 INTRM1 DRILL TRIP T POOH on elevators to casing shoe. 08:45 09:45 1.00 2,462 2,462 INTRM1 DRILL CIRC T CBU pumping 900 gpm, 2800 psi, rotating 110 rpm. Pumped high vis sweep. No increase in cuttings observed. 09:45 10:00 0.25 2,462 2,462 INTRM1 DRILL OWFF T Monitor well -static 10:00 11:00 1.00 2,462 368 INTRM1 DRILL TRIP T POOH on elevators to BHA. 11:00 11:45 0.75 368 87 INTRM1 DRILL TRIP T Stand back HWDP, jars and flex collars. 11:45 12:30 0.75 87 87 INTRMI DRILL PULD T Download MWD 12:30 13:45 1.25 87 0 INTRM1 DRILL PULD T Lay down remaining BHA. 13:45 14:15 0.50 0 0 INTRM1 DRILL RURD T Clear and clean rig floor of BHA handlin tools. 14:15 14:45 0.50 0 0 INTRM1 DRILL RURD T Pick up and rig up 2-7/8" hydrill 511 handling tools in preparation to set cement lu . 14:45 15:00 0.25 0 0 INTRM1 DRILL SFTY T PJSM -singling in hole with 2-7/8" i e. 15:00 16:00 1.00 0 0 INTRM1 RIGMNT SVRG P Service topdrive and blocks. 16:00 18:00 2.00 0 899 INTRM1 CEMEN" TRIP T Sin le in hole with 30 'oints 2-7/8" tubin . 18:00 18:45 0.75 899 899 INTRM1 CEMEN" PULD T Make up cross ovens to 5" drill pipe. page 3 of 72 • Time Logs Date From To Dur S. De th E De th Phase Code Subc_ode T Comment 18:45 19:30 0.75 899 2,514 INTRM1 CEMEN' TRIP T TIH with cement stinger on 5"drill pipe to surface casing shoe. PU wt 110k, SO wt 110k. 19:30 21:15 1.75 2,514 2,514 INTRM1 CEMEN" CIRC T Circulate bottoms up 21:15 00:00 2.75 2,514 2,514 INTRM1 RIGMNT WOC T Service rig while waiting on cement, inspect and lubricate EZ-TO's, drawworks, clean suction screens in um . 9/30/2008 Serviced rig while waiting on cement. Pumped 2 127.5 bbl cement plugs circulating hole clean after each lu .Pulled and la ed down cement stin er and be an ickin u drillin BHA. 00:00 03:30 3.50 2,514 2,514 INTRM1 RIGMNT WOC T Continue to service rig while waiting on cement. Perform derrick inspection, inspect and lubricate rota table. 03:30 04:45 1.25 2,514 4,512 INTRM1 CEMEN" TRIP T TIH with cement stringer while spotting cement trucks and loading silos. Took weight at 3760' MD, established circulation and washed past. Tagged bottom on depth, 4527' MD. POOH and rack back one stand. 04:45 05:15 0.50 4,512 4,512 INTRM1 CEMEN" CIRC T CBU while rigging up cementers. 05:15 05:30 0.25 4,512 4,512 INTRM1 CEMEN" SFTY T PJSM -pumping cement plugs. 05:30 05:45 0.25 4,512 4,512 INTRMI CEMEN" CIRC T RU cement lines and establish circulation with ri um s. 05:45 06:45 1.00 4,512 4,512 INTRM1 CEMEN' OTHR T Pump 1st cement lu 20 bbls of water followed by 127.5 bbls of 17 ppg cement followed by 3 bbls of water and displced with 57 bbls of mud um ed b the ri . 06:45 07:45 1.00 4,512 3,815 INTRM1 CEMEN' TRIP T Pull stinger out of cement plug, 7 stands + single. PU wt 145k, So wt 120k. 07:45 10:30 2.75 3,815 3,815 INTRM1 CEMEN" CIRC T CBU to clean up well for 2nd cement plug pumping 10 bpm, 990 psi. Trace of cement and excessive clays on bottom up. Clay plugged off scalpers, possum belly and flow line. Cleared lines and circulated 2nd bottoms u . 10:30 11:15 0.75 3,815 3,815 INTRM1 CEMEN" OTHR T Pum 2nd cement lu , 20 bbls of water followed by 127.5 bbls of 17 ppg cement followed by 3 bbls of water and displced with 44 bbls of mud um ed b the ri . 11:15 12:45 1.50 3,815 2,898 INTRM1 CEMEN' TRIP T Pull stinger out of cement plug, 10 stands. PU wt 120k, SO wt 110k. 12:45 16:00 3.25 2,898 2,898 INTRM1 CEMEN" CIRC T CBU pumping 10 bpm, 770 psi. Excessive clay with bottoms up. Continued circulating until hole clean, total ~5 bottoms u . 16:00 16:15 0.25 2,898 2,898 INTRM1 CEMEN" OTHR T Monitor well -static 16:15 16:30 0.25 2,898 2,898 INTRM1 CEMEN" SFTY T PJSM -Pulling out of hole. 16:30 21:00 4.50 2,898 0 INTRM1 CEMEN" TRIP T POOH with 2-7/8" cement stinger and 5"drill i e. Page ~3 of T2 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 21:30 0.50 0 0 INTRM1 DRILL RURD T Rig up handling equipment for drilling BHA. 21:30 21:45 0.25 0 0 INTRM1 DRILL SFTY T PJSM -picking up and making up BHA. 21:45 22:00 0.25 53 212 INTRMI DRILL PULD T Continue picking up BHA. 22:00 23:30 1.50 0 53 INTRM1 DRILL PULD T PU 12-1/4" intermediate hole drilling BHA er DD and MWD. 23:30 00:00 0.50 53 53 INTRMI DRILL DHEQ T Upload MWD. 10/01/2008 Picked up drilling BHA and tripped in hole. Circulated bottoms up at casing shoe and tagged up at 2904' MD. Sidetracked well and resumed drillin 12-1/4" intermediate hole. 00:00 00:15 0.25 212 366 INTRM1 DRILL PULD T Continue picking up 12-1/4" intermediate hole drill BHA. 00:15 00:45 0.50 366 366 INTRM1 DRILL DHEO T Shallow pulse test MWD -good test. 00:45 01:45 1.00 366 2,530 INTRM1 DRILL TRIP T TIH to surface casing shoe 01:45 02:30 0.75 2,530 2,530 INTRM1 DRILL CIRC T Circulate bottoms up pumping 800 gpm, 1900 psi rotating 30 rpm. Substantial clay cuttings returned with bottoms u . 02:30 03:30 1.00 2,530 2,904 INTRMI DRILL TRIP T TIH taking surveys per DD &MWD. Calculated TOC at 3127' MD. Tagged up earl at 2904' MD and set down 30k. 03:30 06:00 2.50 2,904 2,970 INTRM1 STK KOST T Wash and ream in hole. Intermediate sidetr k d. 06:00 12:00 6.00 2,970 3,471 INTRM1 DRILL DDRL T Drill 12-1/4" intermediate hole 12:00 15:15 3.25 3,471 3,887 INTRM1 DRILL DDRL T Drill 12-1/4" intermediate hole 15:15 21:15 6.00 3,887 3,983 INTRM1 DRILL DDRL T Drill 12-1/4" intermediate hole 21:15 22:15 1.00 3,983 4,172 INTRM1 DRILL DDRL T Drill 12-1/4" intermediate hole 22:15 23:45 1.50 4,172 4,172 INTRM1 DRILL CIRC T Pulled tight while backreaming stand. Observed increase in torque and no increase in standpipe pressure. Worked pipe and backreamed while circulating sweep. No significant increase in cuttings from swee . 23:45 00:00 0.25 4,172 4,172 INTRM1 DRILL TRIP T Trip back to bottom. 10/02/2008 Drilling 12-1/4" intermediate hole. Backreamed to clean hole up from 4363' MD to surface casing shoe 2540' MD. Circulated casin clean, tri ed back to bottom and resumed drillin . 00:00 03:00 3.00 4,172 4,363 INTRMI DRILL DDRL T Drill 12-1/4" intermediate hole. 03:00 04:00 1.00 4,363 4,363 INTRM1 DRILL CIRC T Circulate 55 bbl hig vis sweep at 760 gpm, 2000 psi, rotating 80 rpm.No increase in cuttings returned with swee . Pane 1C3 of i 2 C~ L~ Time Logs _ Date From To Dur S. De th E. De th _ Phase Code Subcode T Comment 04:00 10:15 6.25 4,363 2,525 INTRM1 DRILL REAM T Precautionary BROOH to surface casing shoe. Pumping 850 gpm, rotating 80 rpm, pulling speed 15 minutes /stand. Pumped sweep at 3501' MD. Observed 20% increase in cuttings returned w/sweep. Pulled tight at 3210' MD and stalled topdrive. Worked thru tight spot then ran back through with no pumps or rotation. PU wt 170k, SO wt 130k, rotatin wt 145k, ECDs 9.75 10:15 11:15 1.00 2,525 2,525 INTRMI DRILL CIRC T Pumped 50 bbl high vis sweep plus bottoms up inside surface casing at 875 gpm, 1960 psi, rotating 80 rpm. Observed 75% increase in cuttings retumed with sweep. PU wt 150k, SO wt 120k, rotating wt 125k, ECDs 9.45 11:15 11:30 0.25 2,525 2,525 INTRM1 DRILL OWFF T Monitor well -static 11:30 12:45 1.25 2,525 2,525 INTRM1 RIGMNT SVRG T Blow down top drive and service rig. Changed actuator on upper IBOP, greased blocks, swivel packing, to drive and drawworks. 12:45 14:15 1.50 2,525 4,363 INTRMI DRILL TRIP T TIH monitoring displacement via trip tank. Lost 2.8 bbls on trip. PU wt 182k, SO wt 130k. 14:15 18:00 3.75 4,363 4,649 INTRM1 DRILL DDRL T Drill 12-1/4" intermediate hole. 18:00 00:00 6.00 4,649 5,028 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole. 10/03/2008 Drilled 12-1 /4" intermediate hole to TD, 5442' MD, 3552 TVD. Backreamed to surface casing shoe to clean the hole. Layed down BHA and rigged up Tesco tool to run casing. 20 joints of 9-5/8" casing in hole at midni ht. 00:00 04:45 4.75 5,028 5,442 INTRM1 DRILL DDRL P Drill 12-1/4" intermediate hole to TD, 5442' MD 3552' TV 04:45 06:00 1.25 5,442 5,442 INTRM1 DRILL CIRC P Pump 45 bbl high vis sweep at 770 gpm, 2050 psi, rotating 80 rpm. No increase in cuttin s from swee . 06:00 12:15 6.25 5,442 2,525 INTRM1 DRILL REAM P BROOH to surface casing shoe pumping 850 gpm rotating 80 rpm. PU wt 160k, SO wt 120k, rotating wt, 140k ECDs 9.78 12:15 12:30 0.25 2,525 2,525 INTRM1 DRILL OWFF P Monitor well -static 12:30 13:30 1.00 2,525 2,525 INTRM1 DRILL CIRC P Pump 45 bbl high vis sweep at 850 gpm, 1790 psi, rotating 80 rpm. PU wt 160k, SO wt 120k, rotating wt 140k. ECDs 9.63 ppg after circulatin . 13:30 13:45 0.25 2,525 2,525 INTRM1 DRILL OWFF P Monitor well - fallin ,blow down top drive. 13:45 15:00 1.25 2,525 369 INTRM1 DRILL TRIP P POOH on elevators to BHA. Monitor hole fill via trip tank. PU wt 160k, SO wt 120k 15:00 15:15 0.25 369 369 INTRM1 DRILL OWFF P Monitor well -falling 15:15 16:00 0.75 369 65 INTRM1 DRILL PULD P Lay down BHA, HWDP, jars & non-ma flex collars. !'ac~~ 19 s~f ; 2 • Time Logs Date _ From To Dur S. De th E. De th Phase Code Suhcode T _Comment 16:00 16:30 0.50 65 65 INTRM1 DRILL PULD P Download MWD 16:30 17:30 1.00 65 0 INTRM1 DRILL PULD P Lay down remainder of BHA, MWD, stabilizer, motor & bit. Hole took 28.1 bbls Burin tri out. 17:30 18:00 0.50 0 0 INTRM1 DRILL PULD P Clear and clean rig floor of BHA and handlin tools. 18:00 19:30 1.50 0 0 INTRM1 CASING RURD P Pick up and rig up Tesco casing tools. 19:30 20:30 1.00 0 0 INTRM1 CASING RURD P Rig up and pull wear bushing. 20:30 20:45 0.25 0 0 INTRM1 CASING SFTY P PJSM -running 9-5/8" intermediate casin . 20:45 00:00 3.25 0 808 INTRMI CASING RNCS P Run 9-5/8" intermediate casing strip . 10/04/2008 Ran 9-5/8" intermediate casing to TD using Tesco's casing drive tools. Cemented casing and landed casing on sli s. 00:00 03:00 3.00 808 2,508 INTRMI CASING RNCS P Running 9-5/8" intermediate casing. PU wt 175k, SO wt 125k. 03:00 04:00 1.00 2,508 2,508 INTRM1 CASING CIRC P CBU at surface casing shoe. Pump 4 bpm, 110 psi. PU wt 170k, So wt 128k. 04:00 07:00 3.00 2,508 3,908 INTRM1 CASING RNCS P Run 9-5/8" intermediate casing. PU wt 230k, SO wt 150k. 07:00 09:00 2.00 3,908 3,908 INTRM1 CASING CIRC P CBU staging pumps to 6 bpm, 140 si. PU wt 230k, SO wt 150k 09:00 11:15 2.25 3,908 5,437 INTRM1 CASING RNCS P Run 9-5/8" casing to TD. PU wt 250, SO wt 152k. Lost 13.2 bbls during TIH. 11:15 12:00 0.75 5,437 5,437 INTRM1 CASING CIRC P Break circulation pumping 3.5 bpm, 250 si. 12:00 12:15 0.25 5,437 5,437 INTRM1 CASING RURD P Blow down top drive. 12:15 12:45 0.50 5,437 5,437 INTRM1 CASING RURD P Rig down and lay down Tesco casing tool. 12:45 15:15 2.50 5,437 5,437 INTRM1 CEMEN" CIRC P Reciprocating pipe while circulating and conditioning mud for cement job. Sta ed um s to 5 b m, 180 si. 15:15 16:45 1.50 5,437 5,437 INTRM1 CEMEN" OTHR P Turn over to Dowell to pump cement job. Pumped 5 bbls of water and pressure tested lines to 4000 psi, pressure held. Pumped 50 bbls CW 100, 50 bbls Mud Push, 183 bbls of cement and chased with 9 bbls of water. Casing was reciprocated until pipe became sticky and 153 bbls of cement was out of the shoe. 16:45 19:00 2.25 5,437 5,437 INTRM1 CEMEN" DISP P Displaced cement using mud pumps at 5-6 bpm, reducing rate to 1.5 bpm when plugs pass stage collar. Plugs did not bump at max strokes. Called town and discussed options. Continued with displacement and bumped plug. Pressured up to 1500 psi and held for 5 minutes, bleed off and checked floats. Floats holding. CIP 1840 hrs 10/4/2008. •+~ ~.i `) ~ I L t, ~ l 2 Time Logs _ __ S. D th E. De th Ph se Cade Subcode T Comment _ Date From To Dur 19:00 20:30 _ 1.50 5,437 5,437 INTRM1 CEMEN" CIRC P Load stage collar closing plug. Pressure casing up to 2800 psi and open stage collar. Circulated surface casing clean pumping 5 bottoms up at 12 b m, 510 si 20:30 21:00 0.50 5,437 5,437 INTRM1 CEMEN" CIRC P Dropped closing plug and pumped down to close stage collar. Plug bumped and casing jumped giving good indication that stage collar closed. Pressure up to 1500 psi and held for 5 minutes. 21:00 21:15 0.25 0 0 INTRM1 WELCTL SFTY P PJSM -nipple down & nipple up stack. 21:15 22:30 1.25 0 0 INTRM1 WELCTL NUND P Nipple down stack. Sim ops rigging down cement equipment and cleanin its 22:30 00:00 1.50 0 0 INTRMI CASING RNCS P Put casing intension with 175k on weight indicator and set slips. Rig up casing cutter and cut casing. Sim o s cleanin its. 10/05/2008 Land 9-5/8" casing string on slips. Pick up and run in hole with clean out assembly. Drill & mill out stage collar. Perform casing integrity test. Good test. Freeze protect 13-3/8" x 9-5/8" annulus. Drill out cement equipment and 20' of new hole. Displace well over to Oil Base Mud. Perform Leak Off Test, 14.7 ppg EMW, ood test. 00:00 00:30 0.50 0 0 INTRM1 CASING RNCS P Pull 9-5/8" cut off joint and dress stum . 00:30 01:30 1.00 0 0 INTRM1 CASING RNCS P Install casing packoff. Sim ops rig down long bails, rig up short bails, la down casin sli s, cleanin its 01:30 02:30 1.00 0 0 INTRM1 WELCTI NUND P Nipple u BOPE. Sim ops cleaning its 02:30 02:45 0.25 0 0 INTRM1 CASING RNCS P Energize packoff and test to 2200 psi for 10 minutes. Pressure held. Set wear bushing and run in lock down screws. 02:45 03:00 0.25 0 0 INTRM1 DRILL SFTY P PJSM -picking up clean out BHA. 03:00 04:15 1.25 0 438 INTRM1 DRILL PULD P Pick up and RIH with clean out BHA. Test choke line 250 psf low_'~OnO nsi hi h. Good test. 04:15 05:30 1.25 438 2,532 INTRM1 DRILL TRIP P TIH on elevators, monitoring dis lacement via tri tank 05:30 06:00 0.50 2,532 2,615 INTRM1 DRILL TRIP P Establish circulation, TIH and tag stage collar plug. Set down 10k. Drill out sta a collar with bit. PU wt 140k, SO wt 120k, Rotatin wt 140k 06:00 06:15 0.25 2,615 2,732 INTRM1 DRILL MILL P TIH until mill at stage collar 06:15 09:00 2.75 2,732 2,819 INTRM1 DRILL MILL P Mill throu h stage collar. Pumping 500 gpm, 810 psi, rotating 100 rpm, kee in WOB under 3k. 09:00 09:15 0.25 2,819 2,819 INTRMI CASING RURD P Blow down top drive and rig up to flush annulus with water. P agE ~~ Os ~~ Time Logs _ ~~ _ Date From To Dur S De th E. De th Pha e Code Subcode T Comment 09:15 12:00 2.75 2,819 2,819 INTRM1 CASING CIRC P Fill lines with water and pressure test to 1000 psi. Pressure held. Flush annulus with water pumping 2 bpm. Formation broke at 660 psi. Pumped 155 bbls. Final pump pressure 590 psi, shut in pressure 480 psi, dropping to 460 psi after 10 minutes. Sim ops, service crown, top drive and drawworks. Cleaned dri an. 12:00 14:00 2.00 2,819 5,307 INTRM1 DRILL TRIP P TIH on elevators monitoring displacement via trip tank. PU wt 200k, SO wt 110k, rotating wt 150k. Sim ops, Little Red freeze orotectino 13-3/8" x 9-5/8" annulus. Pumping 2 bpm, initial pressure before pumping diesel 600 psi, final pressure 720 psi, shut in, pressure after 5 minutes was 560 si. Pum ed total of 175 bbls. 14:00 15:00 1.00 5,307 5,295 INTRM1 DRILL CIRC P CBU for casing test. Pumping 12.5 bpm, 1100 psi, rotating 40 rpm. Pick up to 5295' MD for casing test. Blow down to drive. 15:00 16:15 1.25 5,295 5,295 INTRMI CASING DHEQ P Pressure test casing to 3000 psi and hold for 30 minutes. Good test. Rig own test a ui ment. 16:15 19:30 3.25 5,295 5,442 INTRM1 DRILL MILL P TIH to float equipment (5307' MD) and drill up (landing collar, float collar and casing shoe). Begin displacing well to OBM when bit out the shoe. 19:30 20:00 0.50 5,442 5,462 INTRMI DRILL DRLG P Drill and backream 20' of new hole for LOT. 20:00 21:30 1.50 5,462 5,388 INTRM1 DRILL CIRC P Rotate and reciprocate while displacing well over to OBM. Continue circulating until hole clean of cement and contaminated LSND mud. Pumped 550 gpm, 1670 psi, rotating 100 rpm. PU wt 188k, SO wt 128k, rotatin wt 152k. 21:30 21:45 0.25 5,388 5,388 INTRM1 DRILL LOT P Rig up for LOT. 21:45 22:30 0.75 5,388 5,388 INTRM1 DRILL LOT P perform LOT using test pump. Formation broke at 1000 psi, 14.7 EMW. 22:30 22:45 0.25 5,388 5,388 PROD1 DRILL LOT Blown down and rig down test e ui ment. 22:45 23:00 0.25 5,388 5,388 PROD1 DRILL CIRC P Pump 25 bbl dry job. 23:00 23:45 0.75 5,388 5,388 PROD1 DRILL CIRC T Hole fill line frozen, replace line. 23:45 00:00 0.25 5,388 4,625 PROD1 DRILL TRIP P POOH on elevators 10/06/2008 Pulled and layed down clean out BHA. Ran USIT, cement bond, logs on eline with tractor. Top of good cement at 3000' MD. Performed BOPE test, good test and picked up 60 joints of 4"drill pipe with Cuttings Bed Im ellors. 00:00 01:30 1.50 4,625 438 PROD1 DRILL TRIP P Continue POOH on elevators 01:30 02:15 0.75 438 0 PROD1 DRILL PULD P Lay down clean out BHA. Pa~~ 1~ of 72 Time Logs __ _ Date From To Dur S. De th E. De th Phase Coe Subcode T Comment 02:15 02:30 0.25 0 0 PROD1 EVALWE SFTY P PJSM - eline logging intermediate cement. 02:30 03:30 1.00 0 0 PROD1 EVALWE RURD P Rig up eline sheaves and pick up tractor and to in tools. 03:30 07:00 3.50 0 0 PROD1 EVALWE ELOG P Run cement bond Ing tools to 5400' MD and POOH. Tractor in ftom 4250' MD, 67 degrees inclination. Top of good tat 3000' MD. Monitorin hole via tri tank. 07:00 07:15 0.25 0 0 PROD1 EVALWE SFTY P PJSM -rigging down and laying down to in tools and tractor. 07:15 07:45 0.50 0 0 PROD1 EVALWE RURD P Rig down and lay down eline tools. 07:45 08:00 0.25 0 0 PROD1 WELCTL SFTY P PJSM -pulling wear ring and setting test lu for BOPE test. 08:00 10:00 2.00 0 0 PROD1 WELCTL BOPE P Pull wear ring and set test plug. Fill stack with water and rig up test e ui ment. 10:00 16:30 6.50 0 0 PROD1 WELCTL BOPE P Test BOPE (250 psi low, 3000 psi high). Witnessed waived by AOGCC inspector Jeff Jones. 35 components tested. Tested annular preventer with 3-1/2" and VBRs in lower cavity with 3-1/2", 4" & 5". Accumulator drawdown test starting pressure 3050 psi, draw down to 1600 psi. 53 seconds for 200 psi increase and 3 minutes 8 seconds to full charge (3050 psi). 5 bottle average pressure 2475 si. 16:30 18:00 1.50 0 0 PROD1 WELCTL BOPE T Rig down test equipment and attemp to pull testjoint and plug. Lower rams ressure locked in closed position. Test fluid weaping from top of test joint. Toolpusher called Hydrill rep. Hydrill rep recommended closing annular preventer and pressuring up above lower rams to equalize pressure then open rams. Open rams and bleed off pressure, open annular preventer and pulled test 'oint. 18:00 19:15 1.25 0 0 PROD1 WELCTL BOPE T Inspected test joint and test plug. No debris or obstructions found. Run test plug back in and retest rams and accumulator drawdown. Good test. 19:15 20:00 0.75 0 0 PROD1 WELCTL ROPE P Rig down test equipment, blow down lines and install wear bushin . 20:00 20:15 0.25 0 0 PROD1 DRILL SFTY P PJSM -rigging up for 4"drill pipe. Makin u stands in mouse hole. 20:15 21:00 0.75 0 0 PROD1 DRILL RURD P Pick up and rig up 4" handling e ui ment. Install mouse hole. 21:00 23:00 2.00 0 0 PROD1 DRILL PULD P Pick up 60 joints of 4"drill pipe and make up stands with cuttings bed im ellor on the bottom of 10 stands. 23:00 00:00 1.00 0 0 PROD1 WELCTL BOPE T Pull wear bushing and rig up to retest lower rams. I~at~e 1a of 7~ '~, Time Logs _ e T Comment Date From To Dur S. De th E. De th Phase Code Subcod 10/07/2008 _ 2M1 hr summary m_ Test 3-1/2" x 6" lower pipe rams, rig down test equipment, install wear bushing. Pickup BHA #6, shallow test MWD, pickup 4"drill pipe from shed to 5368', make up crossover to 5", wash in the hole from 5368' to 5462', drill 6-3/4" roduction hole with eo ilot to 6418'. 00:00 00:30 0.50 0 0 PROD1 WELCTL BOPE T Restest lower 3-1/2" x 6" variable rams using 5" test joint as recaution. Good test. 00:30 01:00 0.50 0 0 PROD1 WELCTL BOPE T Rig down test equipment, install wear bushin . 01:00 01:15 0.25 0 0 PROD1 DRILL SFTY P PJSM -picking up drilling BHA. 01:15 03:00 1.75 0 0 PROD1 DRILL PULD P Pick up 6-3/4" Geopilot drilling BHA. 03:00 03:30 0.50 0 0 PROD1 DRILL DHEO P Upload MWD. 03:30 04:30 1.00 0 370 PROD1 DRILL PULD P Continue to pick up 6-3/4" Geopilot drillin BHA: 04:30 05:00 0.50 370 370 PROD1 DRILL DHEO P Shallow test MWD 05:00 06:00 1.00 370 1,406 PROD1 DRILL PULD P Blow down the top drive. Pickup 4" drill pipe from pipe shed and run in the hole with BHA #6. Monitor well on the tri tank. 06:00 10:30 4.50 1,406 5,368 PROD1 DRILL PULD P Continue to pickup 4"drill pipe from pipe shed and run in the hole with BHA #6. Monitor well on the trip tank. Fill pipe @ 2723' and 5368'. Break in the seals on the geopilot. Record PU and SO wt's every 10 stands. 10:30 11:15 0.75 5,368 5,368 PROD1 RIGMNT SVRG P Service top drive, blocks and drawworks. Sim ops- Circ and break in the seals on the geopilot. Pumping 300 gpm w! 2210 psi. PU wt 138k, SO wt 105k, Rot wt 122k. Rotate 15 r m w/ 3-4k ft Ibs of for ue. 11:15 11:30 0.25 5,368 5,462 PROD1 DRILL PULD P Pickup/makeup 4" XT39 x 4-1/2" IF crossover, rotate in the hole to 5462'. Pumping 300 gpm w/ 2210 psi. Rotate 15 rpm w/ 3-4k ft Ibs of for ue. 11:30 12:00 0.50 5,462 5,524 PROD1 DRILL DRLG P Drill 6- .w/ Sperry Sun 5200 eo ilot ser # TL015 . 12:00 15:30 3.50 5,524 5,940 PROD1 DRILL DRLG P Continue to drill 6-3/4" "B" lateral w/ Sperry Sun 5200 geopilot (ser # TL015 . 15:30 18:00 2.50 5,940 6,131 PROD1 DRILL DRLG P Continue to drill 6-3/4" "B" lateral w/ Sperry Sun 5200 geopilot (ser # TL015 . 18:00 00:00 6.00 6,131 6,418 PROD1 DRILL DRLG P Continue to drill 6-3/4" "B" lateral w/ Sperry Sun 5200 geopilot (ser # TL015 . 10/08/2008 Continue to drill 6-3/4" production hole with geopilot from 6418' to 6540', trouble shoot geopilot problem, monitor well, pull out of the hole on elevators to 6420', obtain surveys @ 6280', 6299, 6319, 6340', continue to pull out to 5180', pump a dry job, continue to pull out to BHA #6, pickup/makeup BHA #7, shallow test @ 367', continue in the hole to 5463', slip and cut drilling line, trip in to 5900', trough for sidetrack (due to excessive do le ,sidetrack 5940', drill "B" lateral with BHA #7 to 5949'. P aye 16 of i2 Time Logs _ _____ Date From To Dur S._De th E. De th Phase Code Subcode T Comment 00:00 02:00 2.00 6,418 6,540 PROD1 DRILL DDRL P Continue to drill 6-3/4" "B" lateral w/ Sperry Sun 5200 geopilot (ser # TL015 . 02:00 03:45 1.75 6,540 6,540 PROD1 DRILL OTHR T Trouble shoot problem w/ Sperry Sun 5200 geopilot (ser # TL015). Unable to res and to commands. Circulating while trying to make it work. Unsuccessful results. 03:45 04:00 0.25 6,540 6,540 PROD1 DRILL OWFF T Monitor well- static. 04:00 04:15 0.25 6,540 6,420 PROD1 DRILL TRIP T Pull out of the hole on elevators. Monitor well on the trip tank. PU wt 158k, SO wt 110k. 04:15 04:45 0.50 6,420 6,324 PROD1 DRILL SRVY T Obtain MWD surveys on 20' depths. 6280' = 11.48 deg dogleg 6299' = 11.9 deg dogleg 6319' = 10.9 deg dogleg 6340' = 19.69 deg dogleg Concretions drilled: 6270' to 6272' (2') Concretions drilled: 6275' to 6288' (13') Concretions drilled: 6332' to 6345' (13') Concretions drilled: 6352' to 6353' 1' 04:45 05:30 0.75 6,324 5,180 PROD1 DRILL TRIP T Continue to pull out of the hole on elevators, for new geopilot. Monitor well on the trip tank. Hole taking ro er fluid. 05:30 06:00 0.50 5,180 5,180 PROD1 DRILL CIRC T Pump a dry job, blow down the top drive. 06:00 08:15 2.25 5,180 367 PROD1 DRILL TRIP T Continue to pull out of the hole on elevators, for new geopilot. Monitor well on the trip tank. Record PU and SO wt's eve 10 stands. 08:15 09:00 0.75 367 60 PROD1 DRILL TRIP T Rack back BHA #6. Inspect geopilot, rade bit 0!0 . Run in hole to 60'. 09:00 09:45 0.75 60 60 PROD1 DRILL PULD T Download MWD. Monitor well on the tri tank. 09:45 10:15 0.50 60 0 PROD1 DRILL PULD T Lay down BHA #6. Calculated fill for tri 35 bbls, actual 45 bbls. 10:15 11:00 0.75 0 0 PROD1 DRILL PULD T Clear floor. Prepare MWD tools in the shed for BHA #7. Blind rams shut. 11:00 12:00 1.00 0 103 PROD1 DRILL PULD T Pickup BHA #7 (Geopilot ser # TL 050 . Monitor well on the tri tank. 12:00 13:00 1.00 103 103 PROD1 DRILL TRIP T Pull out to 60'. Upload MWD, then run back in to 103'. 13:00 13:30 0.50 103 367 PROD1 DRILL PULD T Continue to make up BHA #7. Monitor well on the tri tank. 13:30 13:45 0.25 367 367 PROD1 DRILL DHEQ T Shallow test MWD and Geopilot. Pum in 315 m w/ 1480 si. 13:45 15:45 2.00 367 5,369 PROD1 DRILL TRIP T Continue trip in the hole w/ BHA #7. Monitor displacement on the trip tank. Record PU and SO wt's every 10 stnads. Fill pipe @ 2724' and 5366'. Wage 17 cif 7~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment. 15:45 16:00 0.25 5,369 5,463 PROD1 DRILL TRIP T Change elevators, then trip in one stand of 5" drill pipe. PU wt 138k, SO wt 110k. 16:00 16:15 0.25 5,463 5,463 PROD1 DRILL SFTY P Pre job safety meeting on slip and cut drillin line. 16:15 17:45 1.50 5,463 5,463 PROD1 RIGMN'T SVRG P Slip and cut 1-3/8" drilling line (129'). Adjust spiral wrap on kelly hose. Repair intake filter on the top drive blower. Monitor well on tri tank. 17:45 18:00 0.25 5,463 5,756 PROD1 DRILL TRIP T Stand back a stand of 5", continue trip in with 4 more stands of 4" drill pipe- two of which had cutting blade im ellars CBI's . 18:00 18:45 0.75 5,756 5,900 PROD1 DRILL TRIP T Continue trip to 5900'._Decision to sidetrack hole @ 5900' due to high _ dogleg @ 6340' (19.69 deg on 20' surve station . 18:45 20:15 1.50 5,900 5,940 PROD1 DRILL KOST T Trough from 5900' to 5940' for sidetrack. Pumping 320 gpm w/ 2290 psi. Rotate 100 rpm w/ 5-6k ft Ibs of torque. Note: Depart original wellbore @ 5940'. Tie in surve 5877.74'. 20:15 00:00 3.75 5,940 5,949 PROD1 DRILL KOST T Time drill from 5940' to 5949' with BHA #7. Drilling with light weight. Pumping 320 gpm w/ 2290 psi. Rotate 100 m w/ 6k ft Ib 10/09/2008 Continue time drilling "B" lateral with BHA #7 from 5949' to 5967' (concretion f/ 5957' to 5967'), keep drilling sidetrack hole to 6412'. 00:00 06:00 6.00 5,949 5,960 PROD1 DRILL KOST T Continue to Time Drill for sidetrack from 5949' to 5960' with BHA #7. Drilling with light weight (2 to 6k). Pumping 320 gpm w/ 2310 psi. Rotate 100 rpm w/ 5k ft Ib. Max gas 42 units. 06:00 09:00 3.00 5,960 5,967 PROD1 DRILL KOST T Continue to Time Drill for sidetrack from 5960' to 5967' with BHA #7. Drilling with light weight (2 to 6k). Pumping 320 gpm w/ 2310 psi. Rotate 100 rpm w/ 5k ft Ib. Note: Drilled Concretion From 5957' to 5967' 10' . 09:00 12:00 3.00 5,967 6,137 PROD1 DRILL DDRL T Continue Drilling sidetrack from 5967' to 6137' with BHA #7. Drilling with normal weight (2 to 8k). Pumping 320 gpm w/ 2380 psi. Rotate 120 rpm w/ 5k ft Ib. PU wt 143k, SO wt 112k, Rot wt 130k. Max as observed 1106 units. ~.~;~~ ,mot 7~ i~ • Time Logs __ __ _ _ _ Date From To Dur S De th E. De th Phase Coe Subcode T Comment _ 12:00 18:00 6.00 6,137 6,358 PROD1 DRILL DDRL T Continue Drilling sidetrack from 6137' to 6358' with BHA #7. Drilling with normal weight (2 to 6k). Pumping 320 gpm w/ 2390 psi. Rotate 120 rpm w/ 5k ft Ib. PU wt 145k, SO wt 112k, Rot wt 128k. Max gas observed 1038 units. Note: Concretion From 6303' to 6304' 1' and 6354' to 6360' 6' . 18:00 00:00 6.00 6,358 6,412 PROD1 DRILL DDRL T Continue Drilling sidetrack from 6358' to 6412'with BHA #7. Drilling with normal weight (2 to 6k). Pumping 320 gpm w/ 2390 psi. Rotate 120 rpm w/ 5k ft Ib., PU wt 145k, SO wt 112k, Rot wt 128k. Max gas observed 1038 units. Note: Concretion From 6394' to 6405' 11' and 6410' to 6416' 6' . 10/10/2008 Continue drilling sidetrack hole of "B" lateral with BHA #7 from 6412' to 6540', continue to drill "B" lateral from 6540' to 7756'. 00:00 06:00 6.00 6,412 6,516 PROD1 DRILL DDRL T Continue Drilling sidetrack from 6412' to 6516' with BHA #7. Drilling with normal weight (2 to 6k). Pumping 320 gpm w/ 2390 psi. Rotate 120 rpm w/ 5k ft Ib. PU wt 150k, SO wt 110k, Rot wt 130k. Max gas observed 512 units. Note: Concretion From 6410' to 6416' 6' and 6425' to 6429' 4' 06:00 06:15 0.25 6,516 6,540 PROD1 DRILL DDRL T Continue Drilling sidetrack from 6516' to 6540' with BHA #7. Drilling with normal weight (2 to 6k). Pumping 320 gpm w/ 2390 psi. Rotate 120 rpm w/ 5k ft Ib. PU wt 150k, SO wt 112k, Rot wt 132k. Max gas observed 510 units. Note: Concretion From 6539' to 6541' 2' 06:15 12:00 5.75 6,540 7,184 PROD1 DRILL DDRL P Continue directional drilling "B" lateral. Max gas observed 510 units. Note: only 1' of concretions- see above. 12:00 18:00 6.00 7,184 7,568 PROD1 DRILL DDRL P Continue directional drilling "B" lateral. Max gas observed 1429 units. Note: Concretion From 7493' to 7495' (2'), 7512' to 7520' (8'), and 7533' to 7538' S' . 18:00 00:00 6.00 7,568 7,756 PROD1 DRILL DDRL P Continue directional drilling "B" lateral. Max gas observed 1193 units. Note: Concretion From 7568' to 7571' 3' , 7727' to 7742' 15' . Page 1 ~ ~f 72 s Time Logs _ Date From To Dur S Depth E._D~th Phase Code Subcode T Comment _ 10/11 /2008 24 hr Summary Continue to drill "B" lateral from 7756' to 8000', circ 2 bottom's up, monitor well, short trip to 4" drill pipe, install 20 stands of 4"with Cutting blade Impellars, install PBL sub on bottom of stand #71, trip to bottom, continue to directional drill the "B" lateral to 8794' (went out top of formation @ 8678'), backream to 8549' for sidetrack. Trough for sidetrack @ 8600' to 8642', sidetrack hole with exit @ 8605', drill to 8751' at midnight. Note: 3K-103P63 is from 5940' to 6540'. Note: 3K-103P64 is from 8605' to 8794'. 00:00 03:30 3.50 7,756 8,000 PROD1 DRILL DDRL P Continue directional drilling "B" lateral. Max gas observed 708 units. Note: Concretion From 7760' to 7764' 4' 03:30 04:30 1.00 8,000 7,948 PROD1 DRILL CIRC P Circulate bottom's up. work pipe from 8000' to 7948'. 04:30 05:15 0.75 7,948 7,853 PROD1 DRILL CIRC P Stand back a stand. Continue to circulate a bottom's up. Pumping 320 gpm w/ 2450 psi. Rotate 90 rpm w/ 5k ftlbs of for ue. 05:15 05:30 0.25 7,853 7,853 PROD1 DRILL OWFF P Monitor well- static. 05:30 06:00 0.50 7,853 6,803 PROD1 DRILL TRIP P Pull out of the hole on elevators to 6803'. Monitor well on the trip tank. Record PU and SO wt's every 5 stands. 06:00 06:45 0.75 6,803 5,854 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators to 5756'. Monitor well on the trip tank. Record PU and SO wt's eve 5 stands. 06:45 07:00 0.25 5,854 5,854 PROD1 DRILL CIRC P Make a top drive connection. Pump 1400 psi w/ 57 strokes per minute, 242 gpm, 30% flow. Establish baseline pump rate/pressure with out PBL sub in strin . 07:00 07:30 0.50 5,854 5,365 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators. Pull last stand of 5", then change elevators and pull 4 stands of 4", two of which have cutting blade impellars to 5365'. Monitor well on the trip tank. Check CBI's for wear- cannot see an wear-OK. 07:30 08:00 0.50 5,365 5,365 PROD1 DRILL OTHR P Clean floor, pull stripper rubbers. 08:00 08:30 0.50 5,365 7,305 PROD1 DRILL TRIP P Run in the hole with 4"drill pipe with CBI's on the stands. Install PBL sub on bottom of stand #71, continue to run 4" stands to 7305 08:30 08:45 0.25 7,305 7,305 PROD1 DRILL OTHR P Change elevators to 5". 08:45 09:15 0.50 7,305 7,405 PROD1 DRILL CIRC P Kelly up on stand #74 (first 5" dp w/ crossover (4-1 /2" IF x XT39). Pump 1400 psi w/ 54 strokes per minute, 30 % flow. Blow down 09:15 09:45 0.50 7,405 7,975 PROD1 DRILL TRIP P Continue trip in the hole to 7975' 09:45 10:00 0.25 7,975 8,000 PROD1 DRILL REAM P Wash to bottom @ 8000'. Pumping 310 gpm w/ 2450 psi. Rotate 120 rpm w/ 4k ft Ibs of torque. PU wt 150k, SO wt 110k, Rot wt 132k. 10:00 10:15 0.25 8,000 8,064 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max as observed 142 units. ;~ Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:15 10:45 0.50 8,064 8,064 PROD1 DRILL SRVY P Perform MADD pass from 8000' to 8064'. Detection not as good as should be. 10:45 12:00 1.25 8,064 8,166 PROD1 DRILL DDRL P Directional Drill6-3/4" "B" lateral. Max as observed 433 units. 12:00 18:00 6.00 8,166 8,547 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max gas observed 1292 units. Note: Concretion From 8226' to 8235' 9' and 8490' to 8493' 3' . 18:00 18:30 0.50 8,547 8,605 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max gas observed 910 units. Drilled out the top of "B sand. Decision to u ac and sidetrack. 18:30 21:00 2.50 8,605 8,794 PROD1 DRILL DDRL P irectiona Drill 6-3/4" "B" lateral. Max gas observed 910 units. Drilled out the top of "B sand. Decision to pull back and sidetrack. Note: Went out of zone 678'--Out the to of "B" sand. 21:00 21:30 0.50 8,794 8,549 PROD1 DRILL REAM Backream out of the hole f/ 8794' to 8549'. Pumping 307 gpm w/ 2600 psi. Rotate 100 rpm w/ 5k ft Ibs of for ue. ECD's 9.88 21:30 22:00 0.50 8,549 8,605 PROD1 DRILL KOST T Trough for sidetrack from 8600' to 8642'. Exit wellbore @ 8605'. Note: 3K-103P64 is from 8605' to 8794' 22:00 00:00 2.00 8,605 8,751 PROD1 DRILL DDRL T Sidetrack well at 8605'. Continue to drill from 8605' to 8751'. 10/12/2008 Continue to drill "B" lateral sidetrack PB4 from 8751' to 8794' (went out top of formation @ 8678'), continue to drill "B" lateral to 11356'. Note: 3K-103P63 is from 5940' to 6540'. Excessive dog leg Note: 3K-103P64 is from 8605' to 8794'. Went out to of formation 8678'. 00:00 00:15 0.25 8,751 8,794 PROD1 DRILL DDRL T Continue to drill sidetrack hole from 8751' to 8794. Maximum gas observed was 873 units. 00:15 06:00 5.75 8,794 9,308 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max as observed 1278 units. 06:00 12:00 6.00 9,308 10,056 PROD1 DRILL DDRL P Directional Dril16-3/4" "B" lateral. Max gas observed 1431 units. Note: Concretion drilled from 9857' to 9858' 1' . 12:00 18:00 6.00 10,056 10,736 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max as observed 1431 units. 18:00 00:00 6.00 10,736 11,356 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max gas observed 1827 units. Note: Concretion drilled from 11444' to 11446' 2' . 10/13/2008 Continue to drill "B" lateral from 11356' to 12373', Circulate/reciprocate from 12373' to 12295', monitor well- static, continue to clean hole- rotate and reciprocate, monitor well, open Downhole Devices circ sub, circulate casing, close circulating sub, monitor well. Note: 3K-103P63 is from 5940' to 6540'. Excessive dog leg Note: 3K-103PB4 is from 8605' to 8794'. Went out to of formation 8678'. 00:00 06:00 6.00 11,356 11,973 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max as observed 1876 units. ~~r~e 21 rt ?2 I ' Time Logs ___ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 06:00 10:30 4.50 11,973 12,373 PROD1 DRILL DDRL P Directional Drill 6-3/4" "B" lateral. Max as observed 1441 units. 10:30 10:45 0.25 12,373 12,373 PROD1 DRILL CIRC P Circulate 300 gpm w/ 2900 psi. Rotate 110 m w/ 8k ft Ibs of for ue. 10:45 11:00 0.25 12,373 12,373 PROD1 DRILL OWFF P Monitor well- static. 11:00 20:15 9.25 12,373 12,373 PROD1 DRILL CIRC P At TD of "B" lateral, circulate 300 gpm w~/ 900 psi. Rotate 110 rpm w/ 8k ft Ibs of torque. Reciprocate from 12373' to 12295'. Pump a 35 bbls sweep (9.2 ppg/ 200 vis). Continue to circulate a total of 4100 bbls. 20:15 20:30 0.25 12,373 12,373 PROD1 DRILL CIRC P Obtain slow pump rates. 20:30 20:45 0.25 12,373 12,373 PROD1 DRILL OWFF P Monitor well- static. 20:45 23:15 2.50 12,373 12,373 PROD1 DRILL CIRC P Drop 1-1/2" torlon ball to open circulating sub. Pump down at 5 bpm w/ 1560 psi for 650 strokes, slow to 1 bpm w/ 430 psi until seated. Ball on seat after 7720 strokes. Observed a pressure loss. Circulated 440 bbls at 500 gpm w/ 1030 psi. Increased rate to 700 gpm w/ 1680 psi and pumped 4 more bottom's up. Then pumped another bottom's up at 500 gpm checking weight --9.2 ppg. Total of 1890 bbls um ed. 23:15 23:45 0.50 12,373 12,373 PROD1 DRILL CIRC P Drop two steel balls 1-318" to close sub. Pump balls down at 5 bpm w/ 210 psi. Ball on seat after 480 strokes. Pressure up to 2765 psi and shear the torlon ball through ,into ball catcher- closed the sub. 23:45 00:00 0.25 12,373 12,373 PROD1 DRILL OWFF P Monitor well- static. 10/14/2008 Pull out of the hole from TD @ 12373' to 11881' on elevators with proper displacement, pump a dry job, continue to pull out of the hole to 7309', clean floor/change elevators and slips for 4", Continue to pull out- remove cutting bed impellars, remove balls from circ sub, continue to pull out of the hole, Lay down BHA #7, makeup and run in the hole with BHA #8, circulate, prejob safety meeting on displacement to 9.3 ppg brine, start displacement 32 bbls LVT 6.8 ppg, 73 bbl transition spacer 9.8 ppg, start pumping 139 bbls turbulant s acer 9.8 00:00 00:30 0.50 12,373 11,881 PROD1 DRILL TRIP P Pull out of the hole on elevators. Hole took proper displacment.PU wt 182k, SO wt 118k. 00:30 01:00 0.50 11,881 11,881 PROD1 DRILL CIRC P Pump a dry job. Blow down the top drive. 01:00 04:15 3.25 11,881 7,309 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators. Monitor well on the trip tank. Record PU and SO wt's every 5 stands. 04:15 04:30 0.25 7,309 7,309 PROD1 DRILL OTHR P Clean floor and change out tools to tri 4"drill i e. ~~ge 22 of 7~ Time Logs ___ __ ~ Date From To Dur S De th E. De th Phase Coe Subcode T Comment ~ 04:30 06:00 1.50 7,309 6,500 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators. Monitor well on the trip tank. Record PU and SO wt's every 5 stands. Laying down cutting bed impellars. Break and remove balls from the circulating sub (2 steel and one Torlon . 06:00 09:00 3.00 6,500 370 PROD1 DRILL TRIP P Continue to pull out of the hole on elevators. Monitor well on the trip tank. Record PU and SO wt's every 5 stands. 09:00 09:30 0.50 370 45 PROD1 DRILL PULD P Lay down BHA #7. 09:30 10:30 1.00 45 45 PROD1 DRILL OTHR P Download MWD. 10:30 11:45 1.25 45 0 PROD1 DRILL PULD P Continue lay down BHA #7. 11:45 12:00 0.25 0 0 COMPZ DRILL OTHR P With the blinds closed. Clean and clear rig floor. Grease crown sheeves. 12:00 12:30 0.50 0 288 COMPZ DRILL PULD P Pickup and makeup BHA # 8 (Hole- o ener. 12:30 15:00 2.50 288 7,181 COMPZ DRILL TRIP P Trip in the hole. Monitor displacement. Fill pipe every 25 stands. 15:00 18:00 3.00 7,181 12,373 COMPZ DRILL TRIP P Continue to trip in the hole. Monitor displacement on the trip tank. Fill i e eve 25 stands. 18:00 22:45 4.75 12,373 12,373 COMPZ DRILL CIRC P Circulate 380 gpm w/ 2780 psi. Rotate 100 r m w/ 8k ft Ibs of for ue. 22:45 23:15 0.50 12,373 12,373 COMPZ DRILL SFTY P Prejob safety meeting on displacement from 9.2 ppg Oil base mud to 9.3 brine. 23:15 23:30 0.25 12,373 12,373 COMPZ DRILL CIRC P Continue to pump while rigging up trucks for displacement. Circulated a total of 3264 bbls includin above. 23:30 23:45 0.25 12,373 11,273 COMPZ DRILL CIRC P Flush mud pumps to rig floor with 9.3 brine. Flush kill line with 9.3 ppg brine w/ 3% KCL and 3% safe tube. 23:45 00:00 0.25 12,373 12,373 COMPZ DRILL CIRC P Start displacement 32 bbls LVT 6.8 ppg, 73 bbl transition spacer 9.8 ppg, start pumping 139 bbls turbulant spacer 9.8 ppg. Pumped LVT at 6.9 bpm w/ 1790 psi 34% flow. Pumped transition spacer at 9.6 bpm w/ 2640 psi 41 flow. Pumped turbulant spacer at 10.1 bpm w/ final pressure of 1950 si 41%. 10/15/2008 Continue displacement to 9.3 ppg brine, monitor well, 10 stand short trip to 11467', run in hole, monitor losses to be 22 bph, rig up for caustic wash, drop ball to open circ sub @ 5368', PJSM, pump and displace caustic wash, monitor well losses 17 bph, remove 3-1 /2" SLHT liner from pipe shed, Install new 3-1 /2" SLHT in the shed, PJSM on acid wash, pump acid wash and displace, circ to pits, drop ball and close circ sub, monitor losses to be 19.2 bph on trip tank. Work string with hole opener @ 12353'. Displace well to 9.1 ppg brine, monitor well- sli ht flow. i~~ge 23 €~f ?2 ~ ~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment ~ 00:00 02:00 2.00 12,373 12,373 COMPZ DRILL CIRC P Continue to displace by pumping a total of 32 bbls LVT 6.8 ppg, 73 bbl transition spacer 9.8 ppg, 139 bbls turbulant spacer 9.8 ppg, 74 bbls transistion spacer, then follow by pumping 9.3 ppg brine with 3% KCL abd 3% safelube. Pumped LVT at 6.9 bpm w/ 1790 psi 34% flow. Pumped transition spacer at 9.6 bpm w/ 2640 psi 41 flow. Pumped turbulant spacer at 10.1 bpm w/ final pressure of 1950 psi 41%.Pumped 9.3 ppg brine with 3% KCL and 3% safelube at 10 bpm w/ ICP 2920 psi and FCP 1830 psi. PU wt 200k, SO wt 100k, Rot wt 150k. Torque increased from 8k to , 12k ft Ibs of for ue. 02:00 02:15 0.25 12,373 12,373 COMPZ DRILL OWFF P onitor well- static. 02:15 03:00 0.75 12,373 11,467 COMPZ DRILL TRIP P Pull out of the hole from 12373' to 11467/ on elevators. Hole took 9 bbls over calculated. 03:00 03:30 0.50 11,467 12,353 COMPZ DRILL TRIP P Trip in the hole. 03:30 03:45 0.25 12,353 12,353 COMPZ DRILL OWFF P Monitor well to determine fluid loss rate to well. 22 b hw Aquire Slow Pum Rates. 03:45 04:45 1.00 12,353 12,353 COMPZ DRILL CIRC P PU a jt of 5", floor safety valve and circ side entry sub with safety valve. Drop 1-1/2" Torlon ball. Pump down at 6 bpm w/ 1020 psi-25 % flow- for 550 strokes. Then slow pumps to 1.6 bpm w/ 120 psi- 9% flow. Ball on seat after pumping 727 strokes. Increased pump rate to 7.5 bpm w/ 340 psi and 32% flow. Note All Purring for Caustic wash and Acid wash are done with circulatin sub o en 5368' MD 04:45 05:00 0.25 12,353 12,353 COMPZ DRILL SFTY P Pre job safety meeting on pumping caustic wash. 05:00 05:15 0.25 12,353 12,353 COMPZ DRILL CIRC P Open valve on wellhead , pump 7.5 bpm to outside open top returns tank. Will not all go to tank without closing annular. Shut down and blow down lines. 05:15 06:45 1.50 12,353 12,353 COMPZ DRILL CIRC P Pump caustic wash: Pumping 69 bbls of 8.45 ppg caustic. Pumping 6 bpm w/ 320 psi and 27% flow. displace with 9.3 ppg brine with 3% KCL and 3%safelube. PU wt 263k, SO wt 75k. F'~ac}~: 2~# of 72 Time Logs _ __ _ _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 06:45 07:45 1.00 12,353 12,353 COMPZ DRILL _ CIRC P After pumping 252 bbls, open wellhead upper annulus, then close bag and take returns to open top tank while continuing to pump 7.5 bpm w/ ICP 510 psi and final circulating pressure of 610 psi. Take a sample in the cellar after pumping 503.5 bbls. PH was 10.4 07:45 09:30 1.75 12,353 12,353 COMPZ DRILL CIRC P Shut down, open annular, close upper annulus valve. Start taking returns to mud pits. Pumping 7.7 bpm w/ 340 psi-33% flow. Losses to hole 30bph. Sim Ops: Remove 3-1 /2"SLHT liner from pipe shed while circulating- Pipe appears out of spec at connections OD too bi /e ed . 09:30 12:00 2.50 12,353 12,353 COMPZ DRILL OWFF P Monitor static losses via tri tp ank. 1.7 . b h. Continue removing 3-1/2" SLHT liner from pipe shed. Clean Pill pits #1 and #2. Clean rockwasher pits #1 and #2. 12:00 13:15 1.25 12,353 12,353 COMPZ DRILL OWFF P Continue monitoring losses at 17 bph. Load new 3-1/2"SLHT liner in the shed. Working on flush of 400 bbls open top tank to prevent reaction of caustic and acid wash in tank. 13:15 13:30 0.25 12,353 12,353 COMPZ DRILL SFTY P Pre job safety meeting on acid wash. 13:30 14:00 0.50 12,353 12,353 COMPZ DRILL RURD P Blow down top drive. RU Dowell/Schlumber er for pumping 15% HCL acid. 14:00 14:45 0.75 12,353 12,353 COMPZ DRILL CIRC P Dowell/Schlumberger pump 3 bb water, pressure test lines to 2500 psi, pump 19.6 bbls of viscosified brine (9.3 ppg), 30 bbls of 15% HCL (8.8 ppg), 52 bbls viscosified brine (9.3 ppg), follow with 9.6 bbls of water. Pumping 4.2 bpm with 400 si. 14:45 15:45 1.00 12,353 12,353 COMPZ DRILL CIRC P Rig displace acid with 9.3 ppg brine w/ 3% KCL and 3% safelube. Pumping 3 bpm 170 psi 16% flow. Pum ed 209 bbls. 15:45 17:15 1.50 12,353 12,353 COMPZ DRILL CIRC P After pumping 209 bbls, open wellhead upper annulus, then close bag and take returns to open top tank while continuing to pump 3 bpm w! 170 psi until a total of 466 bbls were dis laced. )~ag~ 25 of 7~ i. Time Logs To Dur S. D th E. De th Phase Code Subcode T Comment __ _ Date From __ 17:15 18:00 0.75 12,353 12,353 COMPZ DRILL CIRC P Shut down, open annular, close upper annulus valve. Start taking returns to mud pits. Pumping 5 bpm w/ 21 psi-24% flow. _Losses to hole 24 b h. PU wt 215k, So wt 75k, Rot wt 148k. Note All Purring for Caustic wash and Acid wash was done with circulatin sub o en 5368' MD 18:00 19:15 1.25 12,353 12,353 COMPZ DRILL CIRC P Continue to circulate. Pumping 5 bpm w/ 210 psi, 24% flow. Losing 24 bph brine. Rotate 30 rpm w/ 12k ft Ibs of for ue. 19:15 19:30 0.25 12,353 12,353 COMPZ DRILL CIRC P Rig down circulating sub (4-1/2" IF x 4-1 /2" IF x 2"). Drop (2) 1-3/8" steel balls to close circulating sub. Pump balls down @ 5 bpm w/ 220 psi. Ball on seat after pumping 325 strokes. Pressure up to 2200 psi to blow Torlon ball through seat and close circulatin sub. 19:30 19:45 0.25 12,353 12,353 COMPZ DRILL CIRC P Circulate through hole opener @ 12353'. Pumping 5 bpm w/ 950 psi, 17% flow to veri sub closed. 19:45 21:45 2.00 12,353 12,353 COMPZ DRILL OWFF P Monitor well for fluid loss using trip tank. 16 bph losses with 9.2 ppg brine in the hole. 21:45 23:45 2.00 12,353 12,353 COMPZ DRILL CIRC P Displace well from 9.2 ppg brine to 9.1 ppb brine with 3% KCL and 3% safelube. Pumping 10 bpm w/ 3560 psi, 28% flow. Rotate 20 rpm w/ 10k ft Ibs of torque. Losses to well 70 to 80 b h. Mud we ght at bottom's up 12.3 ppg. Max gas units 5000 units. Calcium Garb and oil on bottom's u . 23:45 00:00 0.25 12,353 12,353 COMPZ DRILL OWFF P Monitor well- flowing. Continue to circulate 10/16/2008 Finish circulating 9.1 ppg brine with 3% KCL and 3% safelube until 9.1 ppg in and out. Obtain slow pump rates, monitor well (6 bph loss), pre job safety meeting on displacing open hole to NaCUKCL VersaOut breaker, monitor well, 15 stand short trip to 11023', monitor well, trip in the hole to 12353', circulate 919 bbls @ initial 7.5 bpm with initial 60 bph losses -final 6 bpm w/ 22 bph losses, max gas observed was 900 units, PJSM on displacement to VersOut, displace to 9.5 ppg in the open hole, monitor well-static, pull out of the hole, lay down BHA #8 (6-3/4" hole opener). Clear floor, rig up to run 3-1/2" screen/blank liner f/ the "B" lateral. Pre 'ob safe meetin ,run 40 'ts to 1280' at midni ht. Page 26 of ?2 ~ ~ j Time Logs _ Date From To Dur S. De th E. D th Pha e Code Subcode T Comment 00:00 03:15 3.25 12,353 12,353 COMPZ DRILL CIRC _ P Continue to circulate .Max mud wt out on bottom's up prior to midnight was 12.3 ppg. Finish displacing to 9.1 ppg brine w/ 3% KCL and 3% safelube. Pumping 7 bpm with 1300 psi and 27% flow out. Initial losses were 55 bbl per hour to the formation. Losses were 17 bph when shut down pumping. Max gas units 1809 units. When shut down to monitor well, units of gas were 300. Note: Calculated losses of 9.2 ppg brine to well from yesterday and up to 0200 hrs toda were 4 03:15 03:30 0.25 12,353 12,353 COMPZ DRILL CIRC P Obtain slow pump rates with 9.1 MW in and out. Mud pump #1:20 spm w/ 170 psi, 30 spm w/ 330 psi. Mud pump #2: 20 spm w/ 160 psi, 30 spm w/ 330 si. 03:30 04:15 0.75 12,353 12,353 COMPZ DRILL OWFF P Monitor well on the trip tank. 6 bbl er hour loss rate. 04:15 04:45 0.50 12,353 12,353 COMPZ DRILL SFTY Pre job safety meeting on displacement to NACUKCL VersaOUT Breaker in 6-3/4" open hole. 04:45 06:00 1.25 12,353 12,353 COMPZ DRILL OWFF P Continue to monitor well on the trip tank. Observed 6 to 7 b h loss rate 06:00 06:45 0.75 12,353 12,353 COMPZ DRILL OWFF P Continue to monitor well on the trip tank. Observed 6 to 7 b h loss rate 06:45 07:30 0.75 12,353 12,353 COMPZ DRILL OWFF P Continue to monitor well on the trip tank. Observed 7.5 bph loss rate Mix the Breaker products together into one Peak 325 bbl vac truck. 07:30 07:45 0.25 12,353 12,353 COMPZ DRILL OWFF P Continue to monitor well on the trip tank. Observed 6 to 7 b h loss rate 07:45 08:30 0.75 12,353 11,023 COMPZ DRILL TRIP P Pull out of the hole 15 stands to 11023'. PU wt 225k, SO wt 80k. Monitor well on the tri tank. 08:30 09:00 0.50 11,023 12,353 COMPZ DRILL TRIP P Monitor well- static, Trip in the hole to 12353'. Monitor displacment on the trip tank. Obtain PU and SO wt's every 5 stands. At 11023': PU wt 170k, SO wt 100k. 09:00 11:45 2.75 12,353 12,353 COMPZ DRILL CIRC P Circulate @ 7.5 bpm w/ 1280 psi 30% flow out. Observed 60 bph losses. Slow rate to 5 bpm and then to 4 bpm w/ 560 psi and 18% flow. Losses are 30 bph at 4 bpm rate. Bottoms up MW was 10.3 ppg. Max gas units observed was 900. After bottom's up increase pump rate to 6 bpm w/ 22 bph losses. Circulated a total of 919 bbls. At 12353': PU wt 220k, SO wt 80k 11:45 12:00 0.25 12,353 12,353 COMPZ DRILL SFTY P Pre job safety meeting on displacement to NACUKCL VersaOUT Breaker in 6-3/4" open hole. Page 7~ €~f 72 Time Logs _ _____ ___ __ Subcode T Comment __ ___ Date From To Dur S. De th E. De th Phase Code 12:00 13:15 1.25 12,353 12,353 COMPZ __ DRILL CIRC P Displace 6-3/4" open hole with 9.5 ppg NACUKCL VersaOUT Breaker. Pump 300 bbls of breaker and chase with 80 bbls of 9.1 ppg brine w/ 3% KCL and 3% safelube. Pump at 6 bpm w/ 1550 psi 26% flow out. Use one um /one vac truck. 13:15 13:30 0.25 12,353 12,353 COMPZ DRILL OWFF P Monitor well- static. 13:30 16:15 2.75 12,353 7,181 COMPZ DRILL TRIP P Pull out of the hole on elevators. Monitor displacement on trip tank. Record PU and SO wt's every 5 stands. At depth of 7181': PU 170k, SO 100k. 16:15 16:30 0.25 7,181 7,181 COMPZ DRILL OTHR P Break and lay down 4-1/2" IF x XT39 crossover. Change elevators to 4". Total of 16 bbl loss to here. 16:30 18:00 1.50 7,181 3,684 COMPZ DRILL TRIP P Continue to pull 4" dp out of the hole. Monitor displacement on the trip tank. 18:00 19:00 1.00 3,684 288 COMPZ DRILL TRIP P Continue to pull 4" dp out of the hole. Monitor displacement on the trip tank. Hole took 68 bbls over calculated fill total on tri out of the hole. 19:00 19:45 0.75 288 0 COMPZ DRILL PULD P Pull out of the hole with BHA #8 (hole opener). Stand back jars, HWDP and flex drill collars. Lay down hole opener and float sub. Note: Float flapper was sitting on top of hole opener. Paddle had significant errosion around port and hin a in area. 19:45 20:15 0.50 0 0 COMPZ DRILL OTHR P Clean and clear rig floor. 20:15 20:45 0.50 0 0 COMPZ CASING RURD P Rig up GBR to run "B" lateral liner. Pickup circulating sub from drilling assembly. Break and remove one Torlon ball and two steel balls. Retor ue service break. 20:45 21:00 0.25 0 0 COMPZ CASING RURD P Bring tools to the rig floor. 21:00 21:45 0.75 0 0 COMPZ CASING OTHR P Pickup Sperry Sun Slim MWD tool. Torque crossovers. Lay down MWD to pipe shed. Dressed for flow rate of 100 m f/detection. 21:45 22:00 0.25 0 0 COMPZ CASING SFTY P Pre job safety meeting on running 3-1/2" 9.3 ppf L-80 SLHT and Hydril 563 liner for the "B" lateral. 22:00 00:00 2.00 0 1,280 COMPZ CASING RUNL P Pickup and makeup 3-1/2" 9.3 ppf L-80 SLHT and Hydril 563 liner. 40 jts in the hole @ midnight. Depth 1280'. Hole took 20 bbls over calculated. Note: Total daily loss of fluid to "B" lateral 310 bbls, Total loss of brine to "B" lateral 733 bbls R~g~ 28 of 7Z Time Logs _ _ Date From To Dur S Depth E_Depth Phase Code Subcode_ T Comment 10/17/2008 za hr summary Continue running 3-1/2" screen/blank liner f/the "B" lateral: Run from jt # 40 to #190 3-1/2"SLHT L-80, make up crossover, then run to jt # 219 (6821'), rotate liner on 5" drill pipe to 7676', Pull drill pipe out, attempt to continue picking up and running liner without rotating, ran in to jt # 224 (6965'). Rotate liner in the hole from 6965' to 7565, make up 3-1 /2" pup with inflatable bridge plug, pour 2' of slug-it on top of fishing neck. Make up the rest of liner to the liner hange. PU/MU MWD, makeup hanger, shallow test MWD. Rig down GBR, Rotate liner in the hole on 5" frill pipe from 7785' to 8420'. Work in hole from 8420' to 8493'. Attempt to pull out of the hole. Ti ht s of at 8493'. 00:00 04:15 4.25 1,280 5,951 COMPZ CASING RUNL P Continue to pickup and makeup 3-1/2" 9.3 ppf L-80 SLHT liner. 190 'ts in the hole. De th 5951'. 04:15 06:00 1.75 5,951 6,821 COMPZ CASING RUNL P Continue to pickup and makeup 3-1 /2" 9.3 ppf L-80 Hydril 563 liner. 190 jts in the hole. Depth 1280'. Note: Lost down weight @ 6658'. Working pipe to get to 6821' Note: Total daily loss of fluid to "B" later) 310 bbls, Total loss of brine to "B" lateral 733 bbls 06:00 08:00 2.00 6,821 7,676 COMPZ CASING T Lay down jt # 220, install crossover from 3-1l2" Hyd 563 to 4-1/2" IF. Run 9 stands in with rotation. Rotate 30 rpm w/ torque limit set at 5500 ft lbs. Monitor well on the tri tank. 08:00 08:30 0.50 7,676 6,821 COMPZ CASING T Pull out of the hole 9 stands of 5" drill pipe. Break and lay down crossover. PU wt 142k, SO wt 98k. Monitor well on the tri tank. 08:30 09:45 1.25 6,821 6,965 COMPZ CASING P Change elevators to 3-1/2". Attmept to continue making up and running 3-1/2" liner. Ran jt # 220 and part of jt # 221, then no down wt. Work pipe in the hole (Jt # 221, 222, 223 and 224 to 6965' . 09:45 12:30 2.75 6,965 7,487 COMPZ CASING RUNL P Rotate liner in the hole from 6965' to 487' (Jt # 241 in the hole). Rotate 30 rpm w/ 4k ft Ibs of torque. PU wt 120k, Rot wt 100k. Monitor well on the tri tank. 12:30 14:30 2.00 7,487 7,565 COMPZ CASING RUNL P Make u 3-1/2" pu 't with inflatable bridge plu installed, pour slug-it to 2' over the fishing neck, make up 3-1/2' pup, crossover, jt of 5-1/2" 563, 5-1/2" 563 pup, casing seal bore, crossover to 7" H d 563. 14:30 14:45 0.25 7,565 7,665 COMPZ CASING OTHR P Pickup Sperry Sun slim MWD. Make u to han er./ acker assembl . 14:45 15:15 0.50 7,665 7,597 COMPZ CASING RUNL P Make u Baker MLZXP acker and flex lock han er. 15:15 15:30 0.25 7,597 7,785 COMPZ CASING RUNL P Rotate 5" drill pipe in the hole with liner on bottom. PU wt 132k, SO wt block wt, Rot wt 105k. Monitor well on the tri tank. 15:30 15:45 0.25 7,785 7,785 COMPZ CASING RUNL P Shallow pulse test MWD @ 7785'. Pumping 101 gpm w/ 860 psi, 11 flow. 15:45 16:00 0.25 7,785 7,785 COMPZ CASING OTHR P Rig down GBR. Clean and clear floor. €'ag~ 29 of ~2 Time Logs _ Date From To Dur S. De th E. D~th Phase Code Subcode T Comment 16:00 17:45 1.75 7,785 8,420 COMPZ CASING RUNL P Rotate liner on 5" drill pipe from 7785' to 8420'. Monitor well on the trip tank. PU wt 140k, SO wt 120k. 17:45 18:00 0.25 8,420 8,420 COMPZ CASING RUNL P Attempt to work through a tight spot @ 8420'. PU wt 150k, Rot wt 120k. Monitor well on the tri tank. 18:00 21:30 3.50 8,420 8,493 COMPZ CASING RUNL P Rotate I' r' he hole from 8420' to 8493'. Unable to work ast 8493'. Monitor well on the trip tank - 10-12 b h losses. 21:30 00:00 2.50 8,493 8,471 COMPZ CASING RUNL T Attempt to pull out of the hole with lin r. Work through tight spot at 8493'. Max pull 250k, Rot weight 120k, Down weight 75k. Rotate 60 rpm w/ 5-6k ft Ibs of torque. Note: Total daily loss of fluid to "B" lateral 62 bbls, Total loss of brine to "B" lateral 795 bbls 10/18/2008 Attempting to pull out of the hole with the 3-1/2" screen/ blank liner from 8471' to 8381', Set liner down @ 8409', release liner from Baker MLHR running tool with left hand rotation (Top of liner @ 823'). Pull out of the hole and lay down running tool. clean floor, rig up HOWCO slickline. Bail solids off the top of fishing neck of internal bridge plug set in the 3-1/2" tubing, WLM 936' is the top of fishing neck. Make numerous runs with pump bailer and impression block. Try running equalizing tool but unable to get deep enough. Continue bailing solids. 00:00 06:00 6.00 8,471 8,394 COMPZ CASING RUNL T Attempt to pull out of the hole with liner. Work from 8471' to 8394'. Max pull 270k, Rot weight 110-120k, Down weight 75k. Rotate 60 rpm w/ 6k ft Ibs of torque.Monitor well on the tri tank 2 b h losses . 06:00 08:00 2.00 8,394 8,390 COMPZ CASING RUNL T Continue attempting to Dull liner out of the hole. Work from 8394' to 8390'. Max pull 270k, Rot weight 110-120k, Down weight 75k. Rotate 60 rpm w/ 6k ft Ibs of torque.Monitor well on the tri tank 2 b h losses . 08:00 08:15 0.25 8,391 8,391 COMPZ CASING OTHR T Monitor well. Service drawworks. 08:15 12:00 3.75 8,391 8,386 COMPZ CASING RUNL T ntinue attempting to pull liner out of the hole. Work from 8391' to 8386'. Max pull 270k, Rot weight 110k, Down weight 75k. Rotate 60 rpm w/ 6k ft Ibs of torque. Monitor well on the tri tank 1-1/2 b h losses . 12:00 17:00 5.00 8,386 8,381 COMPZ CASING RUNL T Continue attempting to pull liner out of the hole. Work from 8386' to 8381'. Max pull 270k, Rot weight 110k, Down weight 75k. Rotate 60 rpm w! 6k ft Ibs of torque. Monitor well on the trip tank (1-1 /2 bph losses . 17:00 17:15 0.25 8,381 8,409 COMPZ CASING OTHR T Set liner down to 8409' shoe depth._ Release liner with lefthand torque. To of liner at 823'. 17:15 17:30 0.25 8,409 11 COMPZ FISH SLKL T Pull out of the hole with 9 stands of 5"drill pipe and Baker HR running tools. Rage ~t3 of 72 ~ ~ Time Lomas Date From To Dur S De th E Depth Phase Code Subcod_e T Comment i __._. _~_ ___ _ __m__ .~ - 17:30 18:00 0.50 11 0 COMPZ CASING OTHR T Lay down Baker MLHR running tool. 18:00 18:30 0.50 0 0 COMPZ CASING OTHR T Clear and clean floor. 18:30 19:45 1.25 0 0 COMPZ FISH SLKL T Rig up Halliburton slick line. Rig up lubricator with wireline BOP. Install lubricator in the hole. Position lubricator to use lower pipe rams (3-1/2" x 6" variables). Run in hole with bailer. First run :5' long 2-1l4" OD pump bailer to 934' WLM. Work tools, pull out of the hole. Bailer 1/4 .~_--- full of slu -it. 19:45 20:15 0.50 0 0 COMPZ FISH SLKL T Second run: 10' long 2-1/2" OD pump bailer. Run in to WL depth of 934' , work to 9365'. Pull out of the hole. Recover 1 1/2' in bailer. 20:15 20:45 0.50 0 0 COMPZ FISH SLKL T Third run: 10' long 2-1/2" OD pump bailer. Run in to WL depth of 935' , work to 9365.5'. Work tools. Pull out of the hole. Recover nothin in bailer. 20:45 21:00 0.25 0 0 COMPZ FISH SLKL T 4th run: Run in hole with 2.75" lead impression block. Tag up in the 5-1/2" x 3-1 /2" crossover @ 931' WLM. Unable to work past. Pull out of the hole. Impression on sides of im ression block. 21:00 21:30 0.50 0 0 COMPZ FISH SLKL T 5th run:Run in the hole with 2.82centralizer and 2.4" OD lead impression block. Set down @ the 5-1/2"x3-1/2" crossover. Pull out of the hole. Same ring mark on im ression block. 21:30 22:00 0.50 0 0 COMPZ FISH SLKL T 6th run: Run in the hole with 5' of 2.25" pump bailer. Set down @ 935' WLM. Work tools. Pull out of the hole. Nothing in bailer and no marks on tool. 22:00 22:15 0.25 0 0 COMPZ FISH SLKL T 7th run: Run in the hole with 2.82" centralizer, 3' of stem with 2.75" centralizer and lead impression block. Unable to get by crossover @ 931' WLM 22:15 23:15 1.00 0 0 COMPZ FISH SLKL T 8th run: Install pump in sub and stuffing box. Run in the hole with inflatable bridge plug equalizing tool to 935' wlm. Beat down, pull out of the hole. No indication of getting down past fishing neck. The pins were untouched. Page 31 of 7~ • Time Logs___ _ _ _ Date From To Dur S. De th E. De th Phase Code Subcode T_ Comment __ 23:15 00:00 0.75 0 0 COMPZ FISH SLKL T 9th run: Run in the hole with 10' 2-1/4" pump bailer. Set down @ 935'. Work tool for 25 minutes not making any hole. Pull out of the hole. Bailer full of fluid, no solids. Marks on bailer shoe. Observation of top of the fishing neck. Note: Losses of approx 5 bph @ midnight. Note: Lost 107 bbls of brine to hole today, total loss to "B" lateral 905 bbls. 10!19/2008 Halliburton slick line continue bailing solids on top of inflatable bridge plug @ 936' WLM, run in and latch fishing neck, indication of upward movement, retrieve bridge plug, rig down Halliburton slick line. Pickup and makeup Baker MLHR running/retrieval tool, run into top of fish (3-1/2" screen blank liner f/ "B" lateral), circulate 7 bpm w/ 70 psi, latch in with Baker MLHR running tool collet @ 834' (Shoe @ 8409.81'). Work pipe and liner up to 8377'. Rig up Schlumberger wire line, hold pre job safety meeting. Finish rigging up Schlumberger. Schlumberger run in the hole to 4300' tie in- locate collars, run back in the hole only able to get to 4250'+/-. Chemical cut 3-1/2" liner 3' below box on jt # 133 (108 full jts in the hole + cut jt). Pull out of the hole with wire line, hold pre job safety meeting. Rig down Schlumberger. Pull out of the hole with drillstring and fish from 4202' to 3450'. 00:00 00:15 0.25 0 0 COMPZ FISH SLKL T 10th run: Run in the hole with knuckle joint and internal bridge plug equalizing tool. Set down @ 935'. Beat down for 20 minutes not making any hole. Pull out of the hole. Pins untouched. Note: Losses of approx 5 bph @ midnight. Note: Lost 107 bbls of brine to hole today, total loss to "B" lateral 905 bbls. 00:15 00:45 0.50 0 0 COMPZ FISH SLKL T 11th run: Run in the hole with 2.75" hydraulic bailer with thin disc. Unable to get by crossover @ 931' WLM. Pull out of the hole. Disc sheared, bailer full of fluid. 00:45 02:45 2.00 0 0 COMPZ FISH SLKL T 12th run: Run in the hole with 1.65" hydraulic bailer, run with knuckle joint and also a thin disc. Set down @ 934' WLM. Pull out of the hole. Disc sheared, bailer had 1/2 quart of solids. 02:45 03:15 0.50 0 0 COMPZ FISH SLKL T Slick line crew change. 03:15 04:15 1.00 0 0 COMPZ FISH SLKL T 13th run: Run in the hole with 2.6" hydraulic bailer, run with 3.85" centralizer, 5' of 1.875" stem and bottom centralizer 2.76" and also a thin disc. Set down @ 930' WLM. Unable to work past. Pulling tight. Pull out of the hole. Disc sheared, bailer had 1/2 uart of solids. €~~^;;~ 32 of ~~ Time Lo~c s ______ __ Date From To Dur S De th E. De th Phase Code Subcode T Comment 04:15 05:15 1.00 0 0 COMPZ FISH SLKL T 14th run: Run in the hole with 5' of 2.5" pump bailer with flapper bottomto 936' WLM. Pull out of the hole with approx 1-1/2' of mixed solids. Set down 936' WLM. 05:15 05:45 0.50 0 0 COMPZ FISH SLKL T 15th run: Run in the hole with 5' of 2.5" pump bailer with ball bottom to 936' WLM. Pull out of the hole with approx 6" of solids, mud and slug-its. Set down 936' WLM. 05:45 06:15 0.50 0 0 COMPZ FISH SLKL T 16th run: Run in the hole with knuckle joint and internal bridge plug equalizing tool. Set down @ 936'. Pull out of the hole. Pins untouched. 06:15 06:30 0.25 0 0 COMPZ FISH SLKL T Cut 10' Of .125" wireline. Rehead toolstrin . 06:30 07:15 0.75 0 0 COMPZ FISH SLKL T 17th run: Run in the hole with 2.84" centralizer, 3' of 1.875" stem, 2.74" centralizer, crossover and 2" tool with shear up release to grab fishing neck of inflatable bridge plug. Set 1 down @..6931' WLM. Unable to work through crossover, pull out of the hole. 07:15 07:45 0.50 0 0 COMPZ FISH SLKL T 18th run: Run in the hole with 2.5" pump bailer. set down @ 932' WLM. Worked through to 936' WLM. Pull out of the hole with mostly fluid. Small amount of solids. 07:45 08:30 0.75 0 0 COMPZ FISH SLKL T 19th run: Run in the hole with 2.56" centralizer, 3' of 1.875" stem, 2.5" centralizer and 2" tool with shear up release to grab fishing neck of inflatable bridge plug to 935' WLM. latched and beat up for 20 minutes sheared off, ull out of the hole. 08:30 09:00 0.50 0 0 COMPZ FISH SLKL T Cut 50' of .125" wire, rehead. repin tool. 09:00 09:30 0.50 0 0 COMPZ FISH SLKL T 20th run: Run in the hole with 2.56" centralizer, 3' of 1.875" stem, 2.5" centralizer and 2" tool with shear up release to grab fishing neck of inflatable bridge plug to 934' WLM. latched and worked u sheared off ull out of the hole. 09:30 09:45 0.25 0 0 COMPZ FISH SLKL T Cut 20' of .125" wire, rehead. repin tool. 09:45 10:15 0.50 0 0 COMPZ FISH SLKL T 21st run: Run in the hole with 2.56" centralizer, 3' of 1.875" stem, 2.5" centralizer and 2" tool with shear up release to grab fishing neck of inflatable bridge plug to 934' WLM. latched and worked up, sheared off, ul out of the hole. 10:15 10:45 0.50 0 0 COMPZ FISH SLKL Cut 20' of .125" wire, rehead. repin tool. Decide to run shear down to release tool to pull inflatable bridge lu . ~~~1~ 33 of 72 • Time Logs ___ _ Date From To Dur S. De th E. De th __ Phase Code Subcode T Comment 10:45 11:45 1.00 0 0 COMPZ FISH SLKL T 22nd run: Run in the hole with 2.56" centralizer, 3' of 1.875" stem, 2.5" tantalizer and 2" pulling tool with shear down release to 933' WLM. Beat hard pulling up. Slowly moving u hole. Final fre .Pull out of the hole with the inflatable bridge lu . Note: A 6" long rubber element and a 1" long rubber element missing from inflatable bride lu . 11:45 12:15 0.50 0 0 COMPZ FISH SLKL T Rig down Halliburton wireline. Note: All losses were monitored on the trip tank while running slick line. A rox 4 b h. 12:15 12:45 0.50 0 0 COMPZ FISH PULD T PU Baker MLHR retrieving/running tool and 4-1/2"IF pup joints. Monitorin well- 4 b h losses. 12:45 13:45 1.00 0 796 COMPZ FISH TRIP T Make up Baker MLHR running tool, trip in the hole to 761', pickup a single of 5"drill pipe, (2) 5' pup jts a 10' and 15' u .and another sin le. 13:45 14:00 0.25 796 796 COMPZ FISH CIRC T Circulate ,pumping 7 bpm w/ 70 psi and 30% flow. PU and SO wt 90k. 14:00 14:15 0.25 796 834 COMPZ FISH FISH T Run in the hole and latch collet of top of the packer 834'. PU wt 180k, SO wt 75k (block wei ht ,Rot wt 150k. 14:15 15:15 1.00 8,377 8,409 COMPZ FISH OTHR T Work string while spotting Schlumber er wireline truck. 15:15 15:45 0.50 8,409 8,377 COMPZ FISH TRIP T Lay down a single, 15' and 10' pup joint. Blow down the top drive. Pickup to top of the liner @ 790.6' and shoe depth of 8377.'17' with 15k over ull on strip . 15:45 16:00 0.25 8,377 8,377 COMPZ FISH ELNE T Rig up Schlumberger wireline. Monitor losses on tri tank- 5 b h. 16:00 16:15 0.25 8,377 8,377 COMPZ FISH SFTY T Pre job safety meeting on cutting 3-1/2" L-80 SLHT liner with Schlumberger wireline 2-3/8" chemical cutter. 16:15 17:15 1.00 8,377 8,377 COMPZ FISH RURD T Continue to rig up Schlumberger wireline. Monitor losses on trip tank- s b h. 17:15 21:00 3.75 8,377 8,377 COMPZ FISH ELNE T Schlumberger run in the hole to 4300' tie in/ locate collars, run back in the hole only able to get to 4250'+/-. Bottom centralizer, 2-3/8" severing head, 2" x 72" Chemical cylinder, 2-3/8"anchor body, top centralizer, gas grain sub, safe igniter head, safe head, collar locator, jars, 2.1" rollers, eqf-43, MH-22. Total tool length 38.8'. Maximum string diameter 3.0". Severing tool to collar locator 13.3'. Monitor losses on tri tank- 5 b h. '~~ ~~ 34 of ~2 • j Time Loqs From To Dur S. De th E. De th Phase Code Subcode T Comment Date _ 21:00 22:00 1.00 8,377 4,202 COMPZ FISH ELNE T Chemical cut 3-1l2" liner 3' below box on jt # 133 (108 full jts in the hole + cut jt). Cut 3-1/2" liner 4202' Drill string/liner measurement. Observed positive indication of cut. Pull out of hole with wireline. Note": Recovered the 1" rubber element from the inflatable bridge plug from the toolstring. One six inch rubber element remains in the well. 22:00 22:15 0.25 4,202 4,202 COMPZ FISH SFTY T Pre job safety meeting. 22:15 22:45 0.50 4,202 4,202 COMPZ FISH RURD T Lay down Schlumberger tools. Remove packoff, crossover and sheaves. Rig down wireline. Monitor well on the trip tank- 10 . b h. 22:45 23:30 0.75 4,202 3,450 COMPZ FISH TRIP T Pull out of the hole with 5"drill pie, fishing assembly and liner from 4202' to 3450'. PU wt 115k, SO wt 112k. Monitor well on the tri tank. 23:30 00:00 0.50 3,450 3,450 COMPZ FISH OTHR T Clear and clean rig floor. Monitor well on the trip tank- losses 10 bph. Note: Lost 78 bbls of brine to hole today, total loss to "B" lateral 983 bbls 10/20/2008 Rig up GBR tongs to lay down liner, lay down liner :108 jts + 2.54' cut jt. Layed down 5 Freecaps and 4 screens. Top of fish 4202' with bottom @ 8377'. Rig down GBR, pull wear bushing,rig up to fill hole under test plug with trip tank. Rig up to test BOPE. Test BOPE to 350 psi low and 3000 psi high. Witness of test waived by AOGCC inspector Bob Noble. rig down fill on annulus, monitor well. Pull test plug, set wear bushing. Pickup fishing BHA (3-1/2" overshot with packoff, bumper sub, x-o, oil jar, x-o, 4 stands of 5" HWDP, run in the hole 39 stands of 5" drill pipe to 4105'.Circulate bottom's up. monitor well. Blow down the top drive. Note: 8 freeca s still in the hole+ 8 screens. 00:00 01:30 1.50 3,450 3,450 COMPZ FISH RURD T Rig up GBR double stack tongs., rig up elevators to pull and lay down fish (3-1/2" "B" lateral liner, 108 jts and 2' cutoff joint)- losses 10 bph. Note: Lost 78 bbls of brine to hole today, total loss to "B" lateral 983 bbls 01:30 01:45 0.25 3,450 3,447 COMPZ FISH PULL T Back out 3.5" pup below the 5-1/2" x 3-1/2" crossover. Unable to backout joint with the double stack tongs because of excessive torque on connection. Used rig tongs as a backup. Crushed the tube of the pup with high torque from casing tongs, at the pin end. Note: In prior days report it was stated that Halliburton slickline was having trouble and unable to pass through the crossover with 2.74" tools. Once the pup was backed out, it was identified that the upper end of ` the tubing, in the collar, was only 2.68". I'ag~ 3a of 72 • Time Logs __ _ _ _ Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 01:45 03:00 1.25 3,447 3,447 COMPZ FISH PULD T Attempt to back out the next joint of 3-1 /2"with the double stack tongs. Unable to back out joint. Lay down double stack tongs. Use rig tongs for backup on the collars. Use 7-5/8" casin ton s with 4-1/2" heads. 03:00 06:00 3.00 3,447 1,402 COMPZ FISH PULD T Lay down fish to 1402'. layed down (2) screens): Bottom end cap flanges had bolts sheared. Swell packers had slipped down on the joint (set screws loose). Most connections were overtorqued. Casing power tongs were crushing the tube of the pipe in breakout process. Note: Losses to the hole avg 10 b h. 06:00 08:00 2.00 1,402 0 COMPZ FISH PULD T Continue to lay down fish. Layed down (2) screens, (2) free caps. A total of 108 jts + 2.54' of cutoff on next jt. Measured 4199.82'. A total of 104 hydroforms 3-1/2" x 6-1/8". Note: Losses still 12 b h. 08:00 09:00 1.00 0 0 COMPZ FISH RURD Rig down GBR. Clean and clear floor. Monitor well on the tri tank. 09:00 09:15 0.25 0 0 COMPZ WELCTL OTHR T Pull Vetco/Gray wear bushing. Rig up test plug. Monitor well on trip tank 8 b h losses. 09:15 10:15 1.00 0 0 COMPZ WELCTI OTHR T Establish circulation through secondary kill line from pumps to annulus to monitor well while testing BOPE. 10:15 11:30 1.25 0 0 COMPZ WELCTL OTHR T Rig up to test BOPE. Witness of test waived by AOGCC inspector Bob Noble.All tests to 250 psi low and 3000 psi high. Hold each test 5 minutes. Chart test. 11:30 12:00 0.50 0 0 COMPZ WELCTI BOPE T Test BOPE Equipment. Test using a 3-1 /2" test joint, 4-1/2" floor IBOP, choke valves 9, 16,17, 18. Note: Well taking 15 bph while testin . i:'~s~e 36 ~f 72 • '~ Time Logs Date From To Dur S De th E. De th Pha e Code Subcode T Comment _ _ 12:00 18:00 6.00 0 0 COMPZ WELCTL BOPE T Continue testing. Test #2: HCR kill #12,12,14,15 5" TIW valve. Test # 3: Manual kill, upper IBOP, valves #5,6,10,11. Test #4: Lower IBOP, valves 1,4,7. Test #5: #2, 3,8,4 choke valves, dart valve. Test #6: Lower pipe rams (3-1/2" x 6" variables) with 3-1/2" test joint and 4" XT39 TIW valve. Test #7: Annular with 5" test joint, HCR vavle on choke line. Test #8: Lower pipe rams with 5" test joint. Test #9: Blind rams with manual choke. Accumulator test: initial 3100 psi, after working rams 1600 psi. @00 pis buildup in 45 seconds. Full charge in 2 min47 seconds. % bottles average 2450 si. 18:00 18:15 0.25 0 0 COMPZ WELCTL ROPE T Continue testing BOPE. Test #10: Manual choke. Test #11: Variable lower i e rams with 4" test 'oint. 18:15 18:30 0.25 0 0 COMPZ WELCTL OWFF T Monitor well on the trip tank through annulus valve before pulling test plug. Static. 18:30 19:15 0.75 0 0 COMPZ WELCTL OTHR T Rig down hose in the cellar. Install wear bushing. (13-3/8" OD x 9" ID x 38" Ion .Tun in lockdown screws. 19:15 19:45 0.50 0 0 COMPZ WELCTL OTHR T Rig down testing equipment. Blow down kill and choke lines. 19:45 20:00 0.25 0 0 COMPZ FISH SFTY T Pre 'ob safe meetin on ickin u fishin BHA. 20:00 20:45 0.75 0 25 COMPZ FISH PULD T Pickup, then makeup 7-3/4"Jars, 6-1/4" bumper sub, 3-1 /2" overshot with ackoff. Tor ue same. 20:45 21:15 0.50 393 393 COMPZ FISH TRIP T Run in the hole with 4 stands of 5" hwd to 393' 21:15 23:00 1.75 393 4,105 COMPZ FISH TRIP T Trip in the hole with 5" dp. Monitor displacement on the trip tank. Record PU and SO wt's every 10 stands. PU wt 158K, SO wt 140k. 23:00 23:45 0.75 4,105 4,105 COMPZ FISH CIRC T Circulate bottom's up pumping 14.5 bpm w/ 670 psi. 55% flow out. PU wt 158k, So wt 140k. Circulate 573 bbls. Aquire slow pump rates. MP #1:20 spm =?? psi, 30 spm = ?? psi, MP #2: 20 spm = ??? psi, 30 s m = ??? si. 23:45 00:00 0.25 4,105 4,105 COMPZ FISH OTHR T Monitor well, blow down the top drive. Note: Lost 78 bbls of brine to hole today, total loss to "B" lateral 1157 bbls 10/21 /2008 Slip and cut drilling line. Set down on fish with overshot and attempt to jar free. Liner not coming free. Circulate dye around to estimate circulation point. Rig up Schlumberger wire line and pump tools in hole to 5733'. Unable to get deeper. Cut 3-1/2" liner 2' below box on jt #84. Pull out of the hole and rig down Schlumber er. Circulate bottoms u and ull out of the hole with drillstrin and fish. 00:00 00:15 0.25 4,105 4,105 COMPZ RIGMNT SVRG T Hang the blocks. ~°~at~~a 3? of 72 • Tirne Los g-------- --- - -- - Date From To __ Dur S De th E. Depth Phase Code Subcode T Comment 00:15 00:30 0.25 4,105 4,105 COMPZ RIGMNT SFTY T Prejob safety meeting. 00:30 01:30 1.00 4,105 4,105 COMPZ RIGMNT SVRG T Cut off 123' of drilling line. 01:30 02:15 0.75 4,105 4,208 COMPZ RIGMNT SVRG T Service rig. 02:15 02:45 0.50 4,208 4,208 COMPZ FISH TRIP T Trip in the hole from 4105' to 4208 while circulating 5 bpm w/ 100psi 21 % flow. PU wt 160k, 140k. Set down 10k on fish. Pump pressure increased to 600 psi. Pickup to 200k on wei ht indicator. rs eF"Ti n a ed. 02:45 06:00 3.25 4,208 4,208 COMPZ FISH JAR T Jar on liner while circulating 6 bph, 1260 psi. PU wt 160k, SO wt 140k, rot wt 150k, Torque 5-6k ft lbs. Note 80 bbl of brine lost last 6 hrs. 06:00 08:45 2.75 4,208 4,208 COMPZ FISH JAR T Continue jarring on liner, not coming free. 08:45 10:00 1.25 4,208 4,208 COMPZ FISH CIRC T Circulate with dye in brine in attempt to estimate circulation point. Dye returned at 3650 strokes, approximately bottoms up from screen at 5195' MD. Pumped at 8 b m, 920 si. 10:00 10:15 0.25 4,208 4,208 COMPZ FISH SFTY T PJSM -rigging up wireline and runnin chemical cutter. 10:15 12:00 1.75 4,208 4,208 COMPZ FISH RURD T Rig up wireline tools and arm cutter. 12:00 16:45 4.75 4,208 4,208 COMPZ FISH CPBO T Pump down chemical cutter staging pumps to 15 bpm, 2300 psi. Tools stacking out. After repeated attemps to get deeper cut pipe at 5733' WLM. POOH with wireline tools. 16:45 17:00 0.25 4,208 4,208 COMPZ FISH SFTY T PJSM -laying down wireline tools 17:00 17:45 0.75 4,208 4,208 COMPZ FISH RURD T Rig down/lay down wireline tools. 17:45 18:00 0.25 4,208 5,733 COMPZ FISH CPBO T Pick up to 280k and liner came free. PU wt 190k, So wt 125k. 18:00 19:15 1.25 5,733 5,733 COMPZ FISH CIRC T CBU pumping 9 bpm, 520 psi. Loosin fluid at 60 b h. 19:15 19:30 0.25 5,733 5,733 COMPZ WELCTL OWFF T Monitor well -static 19:30 21:00 1.50 5,733 1,550 COMPZ FISH PULL T POOH with fish. PU wt 100k, SO wt 100k 21:00 21:15 0.25 1,550 1,550 COMPZ FISH SFTY T PJSM -handling BHA. 21:15 23:00 1.75 1,550 1,525 COMPZ FISH PULD T Lay down BHA, jars, bumper sub & crossover. Backoff overshot and lay down. 23:00 23:15 0.25 1,525 1,525 COMPZ FISH SFTY T PJSM -Laying down fish, 3.5" liner. 23:15 00:00 0.75 1,525 900 COMPZ FISH PULL T Lay down 20 joints of 3.5" liner. 10/22/2008 Finish laying down fish, 49 joints total. RIH with cleanout BHA. Tag fish at 5738' MD. Circulate hole clean. Pick up and run in hole with cement retainer for cement squeeze. Set retainer at 5333' MD. Rig up for cement 'ob. 00:00 01:30 1.50 0 0 COMPZ FISH PULL T Continue to lay down 3.5" liner. Total 49 joints pulled. Lost 13.5 bbls of fluid while ullin out of hole. Page ~$ of 72 • Time Logs __ _ __ ____ Date From To Dur S._D_e th E. De th Ph se Code Subcode T Comment 01:30 02:00 0.50 0 0 COMPZ FISH RURD T Rig down GBR 3-1.2" handling tools. 02:00 02:30 0.50 0 0 COMPZ FISH OTHR T Clear and clean rig floor. 02:30 02:45 0.25 0 0 COMPZ DRILL SFTY T PJSM -picking up BHA for clean out run. 02:45 03:45 1.00 0 294 COMPZ DRILL PULD T Pick up and make up clean out BHA. 03:45 06:15 2.50 294 5,627 COMPZ DRILL TRIP T TIH with clean out BHA. PU wt 180k, SO wt 115k. 06:15 07:00 0.75 5,627 5,738 COMPZ DRILL CIRC T Wash down to to of fish pumping 10 bpm, 820 psi. Tagged top of liner at 5738' M D 07:00 08:00 1.00 5,738 5,738 COMPZ DRILL CIRC T Circulating bottoms up at 11 bpm, 1100 psi. Loosing 80 bph. Hole unloaded sand and packed off ossum bell . 08:00 08:30 0.50 5,738 5,437 COMPZ DRILL TRIP T POOH on elevators into intermediate casin shoe. 08:30 12:00 3.50 5,437 5,437 COMPZ DRILL CIRC T Circulate casing clean staging pumps to 12 bpm, 1080 psi, rotating 90 rpm. Max gas on bottoms up 4156 units. 12:00 12:30 0.50 5,437 5,437 COMPZ DRILL CIRC T Circulate 40 bbl hi-vis sweep observed moderate increase in cuttin s. 12:30 13:15 0.75 5,437 5,437 COMPZ DRILL OWFF T Monitor well -flowing .6 bpm to .1 b m after 30 min. 13:15 14:45 1.50 5,437 5,437 COMPZ DRILL CIRC T Circulate sweep at 12 bpm, 960 psi, rotating 120 rpm. No increase in cuttin s when swee returned. 14:45 15:15 0.50 5,437 5,437 COMPZ DRILL OWFF T Monitor well -flowing, then static after 30 min 15:15 17:30 2.25 5,437 294 COMPZ DRILL TRIP T POOH on elevators to BHA. Hole took ro er fill on tri . 17:30 18:30 1.00 294 0 COMPZ DRILL PULD T Lay down BHA. Clear and clean rig floor. 18:30 19:00 0.50 0 0 COMPZ RIGMNT SVRG P Service rig - topdrive, drawworks and blocks. 19:00 19:45 0.75 0 0 COMPZ CEMEN" PULD T Pick up and make up EZSV cement retainer. 19:45 23:00 3.25 0 5,333 COMPZ CEMEN" TRIP T TIH wit cement retainer on drillpipe. PU wt 165k, SO wt 130k. Lost .5 bbls on tri in hole. 23:00 23:30 0.50 5,333 5,327 COMPZ CEMEN" SQEZ T Establish circulation at 3 bpm, 90 psi washing casing where packer to be set. Set packer per Halliburtion. Pull up to 220k to release from packer and set down 15k to confirm packer set. Pick u 5' above acker. 23:30 00:00 0.50 5,327 5,327 COMPZ CEMEN" CIRC T Circulate bottoms up x2 at 15 bpm, 700 si 10/23/2008 Set cement retainer and squeeze 9-5/8" shoe with 150 bbls cement. Pull out of hole and lay down 5"drill pipe with wearsocks. Run in hole with 8-1/2" cleanout BHA. Service ri and be in drillin cement and retainer. 00:00 00:15 0.25 5,327 5,327 COMPZ CEMEN" CIRC T Finish circulating 2 bottoms up at 15 b m, 700 si 00:15 00:30 0.25 5,327 5,327 COMPZ CEMEN" SQEZ T Test retainer with 1500 psi for 5 minutes - ressure held. r age 3~ raf T2 • • Time Logs Date From To Dur S De th E De th Phase Code Subcode T Comment _ 00:30 00:45 0.25 5,327 5,327 COMPZ CEMEN" SFTY T PJSM -Cement squeeze 00:45 01:00 0.25 5,327 5,327 COMPZ CEMEN" SQEZ T Extend cement stinger per Halliburton re . 01:00 01:45 0.75 5,327 5,327 COMPZ CEMEN" SQEZ T Slowdown top drive, and rig up cement lines. Close bag and circulate throught choke at 5 bpm holding 500-600 psi backpressure to determine choke osition. 01:45 02:00 0.25 5,327 5,333 COMPZ CEMEN' SQEZ T Turn over to Dowell. Flood lines, pressure test to 3500 psi -good, bleed off and stab into retainer. Details of cement job recorded in cement re ort section. 02:00 03:15 1.25 5,333 5,333 COMPZ CEMEN" SOEZ T Perform infectivity test. 03:15 09:15 6.00 5,333 5,333 COMPZ CEMEN" SQEZ T Unsting from retainer and load drill pipe with cement. Sting in and continue pumping cement. Start hesitations after 73 bbls of cement out casin shoe. Squeeze 7 stages with 30 minutes between each stage. Final drill i ressue on last stage 475 psi. CIP @ 09:10 (full details of 'ob in cement re ort section 09:15 10:00 0.75 5,333 5,325 COMPZ CEMEN" CIRC T Unsting from retainer. Pick up 8' and reverse out cement at 10 bpm, 1050 psi. Circulate 2 bottoms up. Estimate 5 bbls Chem Wash and 5 bbls cement to surface. 10:00 11:00 1.00 5,325 5,280 COMPZ CEMEN' CIRC T Pu up an arculate 3 bottoms up the Ion wa at 15 b m, 720 si. 11:00 11:30 0.50 5,280 5,280 COMPZ CEMEN" OTHR T Monitor well -static. Blow down top drive and lines 11:30 13:45 2.25 5,280 0 COMPZ CEMEN" TRIP T POOH on elevators. Hole took proper fill on tri . 13:45 14:15 0.50 0 0 COMPZ CEMEN" OTHR T Observed 3" x 4" chunk missing from wearsock. Inspected others and found several were cracked. Pictures taken. 14:15 15:15 1.00 0 0 COMPZ DRILL PULD T Lay down 9 stands of 5"drill pipe with wearsocks. 15:15 16:15 1.00 0 504 COMPZ DRILL PULD T Make ent cleanout BHA with 8-1/2" milltooth bit. 16:15 17:15 1.00 504 1,360 COMPZ DRILL TRIP T Single in hole with 27 joints of 5"drill ie 17:15 19:30 2.25 1,360 5,165 COMPZ DRILL TRIP T TIH with cleanout BHA. PU wt 165k, SO wt 130k, rotatin wt 150k 19:30 20:00 0.50 5,165 5,330 COMPZ DRILL TRIP T Wash down and tag cement at 530' MD pumping 4 bpm, rotating 50 rpm. Set down 10k 20:00 20:15 0.25 5,330 5,330 COMPZ DRILL SFTY T PJSM -displacing well to OBM. 20:15 21:00 0.75 5,330 5,310 COMPZ DRILL CIRC T Pick up and displace well to OBM pumping 14 bpm, 2100 psi, rotating 50 rpm. PU wt 170k, SO wt 135k, rotatin wt 150k. 21:00 21:15 0.25 5,310 5,259 COMPZ DRILL TRIP T Pull up for rig maintenance. P~g~ 40 of 72 Time Logs _ __ _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment ~ --- --:_. T 21:15 ---~__ 21:30 0.25 5,259 5,259 _. _ COMPZ RIGMNT SFTY P PJSM -changing saver sub. 21:30 23:00 1.50 5,259 5,259 COMPZ RIGMNT SVRG P Change out saver sub and grabber dies. Clean suction screens on mud pumps. Service top drive, blocks, crown, drawworks and iron rou hneck. 23:00 00:00 1.00 5,259 5,330 COMPZ DRILL TRIP T TIH and begin drilling cement and retainer. Pumping 14 bpm, 2250 psi, rotating 80 rpm. PU wt 170k, SO wt 135k, rotatin wt 150k. 10/24/2008 Drill up cement retainer, cement and 20' out intermediate casing shoe. Pick up and run in hole with Geopilot drillin BHA. Be in drillin B lateral. 00:00 06:00 6.00 5,330 5,358 COMPZ DRILL OTHR T Drilling cement retainer. Initially pumping 14 bpm, 2250 psi, rotating 80 rpm, 10-15k WOB. Varying parameters after drilling first foot of retainer and not makin hole. 06:00 08:15 2.25 5,358 5,453 COMPZ DRILL OTHR T Pushed retainer down hole and drilled up umping 6 bpm, 530 psi, 10-40k WOB. 08:15 09:45 1.50 5,453 5,453 COMPZ DRILL CIRC T Pump 40 bbl hi vis sweep plus 3 BU at 15 bpm, 2490 psi, rotating 60 rpm. Moderate increase in cuttings returned with swee . 09:45 10:00 0.25 5,453 5,453 COMPZ DRILL OWFF T Monitor well -static 10:00 10:15 0.25 5,453 4,977 COMPZ DRILL TRIP T POOH 5 stands, hole taking proper fill. 10:15 10:30 0.25 4,977 4,977 COMPZ DRILL CIRC T Pump dry job and blow down top drive. 10:30 12:30 2.00 4,977 503 COMPZ DRILL TRIP T POOH on elevators, hole taking ro er fill. 12:30 13:15 0.75 503 0 COMPZ DRILL TRIP T POOH with BHA. 13:15 13:45 0.50 0 0 COMPZ DRILL OTHR T Clear and clean rig floor. Check junk baskets for debris. Two small pieces in baskets. 13:45 16:00 2.25 0 0 COMPZ DRILL PULD T Pick up and make up geopilot BHA. Download MWD. 16:00 16:30 0.50 0 371 COMPZ DRILL PULD T Pick up remaining BHA 16:30 17:15 0.75 371 371 COMPZ DRILL DHEQ T Shallow pulse test MWD & break in Geopilot pumping 275 gpm, 1260 psi - ood test. 17:15 19:00 1.75 371 5,371 COMPZ DRILL TRIP T TIH with Geopilot. PU wt 132k, So wt 110k. 19:00 19:15 0.25 5,371 5,371 COMPZ DRILL SFTY T PJSM - Drilling B Lateral 19:15 19:45 0.50 5,371 5,453 COMPZ DRILL REAM T Wash to bottom pumping 320 gpm, 2570 psi, rotating 30 rpm. PU wt 132k, SO wt 110k, rotatin wt 125k. 19:45 00:00 4.25 5,453 5,806 COMPZ DRILL DDRL T Drillin B Lateral. Take surveys every 10' from 5749' to 5649' for Cassandra surve corrections. 10/25/2008 Drill B sand Lateral to 6418' MD. Geopilot not tracking properly. Pull out of hole and change out Geopilot. Trip back in hole takin 10 checkshot surve son the wa to bottom. Resumed drillin B sand Lateral. F'c~e 4~ €~f 72 ~' Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 5,806 6,228 COMPZ DRILL DDRL{ T Drilling B sand Lateral 06:00 07:30 1.50 6,228 6,418 COMPZ DRILL DDRL T Drilling B sand Lateral. Geopilot not holding deflection, toolface not trackin . 07:30 07:45 0.25 6,418 6,418 COMPZ DRILL OWFF T Monitor well -static 07:45 08:15 0.50 6,418 5,944 COMPZ DRILL TRIP T POOH 5 stands, hole taking proper fill. 08:15 08:30 0.25 5,944 5,944 COMPZ DRILL CIRC T Pump dry job and blow down top drive. 08:30 08:45 0.25 5,944 5,371 COMPZ DRILL TRIP T POOH with 5"drill pipe. 08:45 09:00 0.25 5,371 5,371 COMPZ DRILL TRIP T Change out handling equipment. 09:00 10:30 1.50 5,371 375 COMPZ DRILL TRIP T POOH with 4"drill pipe. 10:30 12:00 1.50 375 0 COMPZ DRILL TRIP T POOH with BHA, break out bit (ringed out) and laydown Geopilot. Download MWD. 12:00 12:15 0.25 0 0 COMPZ DRILL OTHR T Clear and clean rig floor. 12:15 13:30 1.25 0 0 COMPZ DRILL PULD T Make up BHA with new Geopilot and u load MWD 13:30 13:45 0.25 0 371 COMPZ DRILL TRIP T Make up remaining BHA and TIH. 13:45 14:00 0.25 371 371 COMPZ DRILL DHEQ T Shallow pulse test MWD pumping 270 m, 1200 si - ood test 14:00 15:30 1.50 371 5,370 COMPZ DRILL TRIP T TIH with 4"drill pipe. 15:30 15:45 0.25 5,370 5,370 COMPZ DRILL TRIP T Change out handleing equipment 15:45 16:00 0.25 5,370 5,564 COMPZ DRILL TRIP T TIH with 5"drill pipe. 16:00 17:15 1.25 5,564 5,754 COMPZ DRILL SRVY T TIH taking 10 checkshot surveys (5608', 5659', 5679', 5689', 5699', 5709', 5719', 5729', 5739', 5749' . 17:15 18:00 0.75 5,754 6,418 COMPZ DRILL TRIP T TIH, washing down last stand 18:00 00:00 6.00 6,418 6,653 COMPZ DRILL DDRL T Resume drilling B sand Lateral. 10/26/2008 Drill B sand lateral to 8036' MD and short trip to pick up Cuttings Bed Impellers. Tripping in hole at midnight. 00:00 06:00 6.00 6,653 6,895 COMPZ DRILL DDRL T Drilling B sand lateral, concretions 6739-6742, 6855-6857 06:00 06:30 0.50 6,895 6,905 COMPZ DRILL DDRL T Drill B sand lateral. 06:30 08:00 1.50 6,905 6,905 COMPZ DRILL SRVY T Survey showed excessive do le after drilling last concretion. Pull back and shot surveys at 6806', 6816', 6836', 6856', & 6876'. Discuss sidetrack options with town. Decision made to drill ahead. 08:00 12:00 4.00 6,905 7,400 COMPZ DRILL DDRL T Drill B sand lateral 12:00 18:00 6.00 7,400 8,036 COMPZ DRILL DDRL T Drill B sand lateral to planned short tri de th. 18:00 19:00 1.00 8,036 8,036 COMPZ DRILL CIRC T Circulate sweep pumping 320 gpm, 2680 psi, rotating 120 rpm. Observed 10% increase in cuttings returned with swee .record slow um rates 19:00 19:15 0.25 8,036 8,036 COMPZ DRILL OWFF T Monitor well -static '''age 42 ~sf 72 Time Logs _ ___ ~ ____ ___ ~ Date From To Dur S. D , th E. De th Phase Code Subcode T Comment 19:15 19:45 0.50 8,036 7,563 COMPZ DRILL TRIP T POOH 5 stands 5" drill pipe, PU wt 158k, SO wt 120k 19:45 20:00 0.25 7,563 7,563 COMPZ DRILL CIRC T Pump 15 bbl dry job and blow down to drive. 20:00 21:15 1.25 7,563 5,430 COMPZ DRILL TRIP T POOH with 5"drill pipe. PU wt 135k, SO wt 110k. Hole took 2.6 bbls over calculated fill durin tri . 21:15 22:15 1.00 5,430 5,430 COMPZ DRILL CIRC T Circulate bottoms up pumping 320 m, 2690 si 22:15 22:30 0.25 5,430 5,370 COMPZ DRILL TRIP T POOH with 5"drill pipe to 4" XO. 22:30 22:45 0.25 5,370 5,370 COMPZ DRILL TRIP T Blow down top drive 22:45 23:30 0.75 5,370 5,370 COMPZ RIGMNT SVRG P Service rig (top drive, blocks, crown and drawworks 23:30 00:00 0.50 5,370 6,420 COMPZ DRILL TRIP P TIH with 4"drill pipe picking up Cuttings Bed Impellers on the way in hole. 10/27/2008 Trip back to bottom with cuttings bed impellers and circulation sub in 4"drill pipe. Drill B sand lateral to 9473' MD and experienced problems with Geopilot not responding. Attempted to troubleshoot problem and decision made to ull out of hole. 0 hour re lacement Geo ilot on location at 22:30. 00:00 01:15 1.25 6,420 8,036 COMPZ DRILL TRIP T TIH with 4"drill pipe. No losses or ains durin TIH. 01:15 06:00 4.75 8,036 8,365 COMPZ DRILL DDRL T Drilling B sand lateral. 06:00 18:00 12.00 8,365 9,473 COMPZ DRILL DDRL T Drilling B sand lateral. 18:00 18:45 0.75 9,473 9,430 COMPZ DRILL DHEO T Pick up off bottom and troubleshoot Geopilot. Cannot downlink. Prep for POOH. 18:45 19:00 0.25 9,430 9,400 COMPZ DRILL TRIP T Obtain slow pump rates. Monitor well -static 19:00 19:15 0.25 9,400 9,310 COMPZ DRILL TRIP T POOH 1 stand, PU wt 165k, SO wt 110k 19:15 19:30 0.25 9,310 9,310 COMPZ DRILL DHEO T Make another attempt to downlink to Geo ilot. No success 19:30 19:45 0.25 9,310 9,310 COMPZ DRILL TRIP T Monitor well -static and blowdown to drive. 19:45 20:30 0.75 9,310 7,596 COMPZ DRILL TRIP T POOH 18 stands. 20:30 20:45 0.25 7,596 7,596 COMPZ DRILL CIRC T Pump 30 bbl dry job 20:45 21:15 0.50 7,596 7,307 COMPZ DRILL TRIP T POOH to 4" drill pipe and change hadlin a ui ment. 21:15 00:00 2.75 7,307 2,160 COMPZ DRILL TRIP T POOH with 4"drill pipe, laying down circ sub and cuttin s bed im ellers. 10/28/2008 Trip out of hole for Geopilot. Pick up and make up new Geopilot and MWD, run back to bottom and resume drillin B sand lateral. 00:00 00:45 0.75 2,160 368 COMPZ DRILL TRIP T POOH with 4" drill pipe. 00:45 01:45 1.00 368 60 COMPZ DRILL TRIP T Lay down / rackback BHA per Sperry re s. Break out bit. 01:45 02:30 0.75 60 60 COMPZ DRILL PULD T Download MWD 02:30 03:00 0.50 60 0 COMPZ DRILL PULD T Laydown Geopilot and MWD 03:00 03:30 0.50 0 60 COMPZ DRILL PULD T Pick up new Geopilot and MWD 03:30 04:15 0.75 60 60 COMPZ DRILL PULD T Upload MWD f~~ge 43 of 72 Time Logs - _ - --- Date From To Dur S De th E. De th Phase Code Subcode T Comment ___ 04:15 04:30 0.25 60 463 COMPZ DRILL TRIP T TIH with remaining BHA 04:30 05:00 0.50 463 463 COMPZ DRILL DHEQ T Make up crossover and shallow pulse test MWD pumping 305 gpm, 1550 si - ood test. 05:00 08:00 3.00 463 5,365 COMPZ DRILL TRIP T TIH with 4"drill pipe monitoring displacement via trip tank. PU wt 115k, SO wt 108k, rotatin wt 110k. 08:00 08:45 0.75 2,728 5,365 COMPZ RIGMNT SVRG P Service top drive, blocks drawworks and crown 08:45 12:00 3.25 5,365 7,265 COMPZ DRILL TRIP T TIH with 4"drill pipe monitoring displacement via trip tank. PU wt 140k, SO wt 105k, rotating wt 120k. Took 8 checkshot surveys on the way in hole (6036', 6131', 6226', 6321', 6511', 6607', 6702', 6942' 12:00 12:15 0.25 7,265 7,265 COMPZ DRILL TRIP T Change to 5" handling equipment 12:15 14:45 2.50 7,265 9,473 COMPZ DRILL TRIP T TIH with 5" drill pipe monitoring displacement via trip tank. PU wt 165k, SO wt 110k 14:45 18:00 3.25 9,473 9,836 COMPZ DRILL DDRL T Resume drilling B sand lateral 18:00 00:00 6.00 9,836 10,407 COMPZ DRILL DDRL T Drill B sand lateral. 10!29/2008 Drill B sand lateral and experienced problems with Geopilot toolface & deflection not tracking properly. Attem ted to troubleshoot roblem. Decision made to ull out of hole 01:00. 00:00 06:00 6.00 10,407 10,837 COMPZ DRILL DDRL T Drilling B sand lateral 06:00 12:00 6.00 10,837 11,301 COMPZ DRILL DDRL T Drilling B sand lateral. Pumped 40 bbl hi vis sweep while drilling at 11175' MD. Circulated sweep out before makin connection. 12:00 18:00 6.00 11,301 11,528 COMPZ DRILL DDRL T Drilling B sand lateral 18:00 22:00 4.00 11,528 11,698 COMPZ DRILL DDRL T Drilling B sand lateral 22:00 00:00 2.00 11,698 11,698 COMPZ DRILL CIRC T Geopilot showing warning lights on Insite and not holding toolface or deflection setting. Discuss options with Drilling Team. Continue trouble shooting. Decision made to POOH at 01:00. 10/30/2008 Troubleshoot Geopilot toolface/deflection tracking problems. Trip out of hole and lay down Geopilot. Pick up mud mo~ar and run back in hole to the intermediate casing shoe. Service the rig, slip and cut drilling line. Trip back to bottom taking surveys on the way in. Notified by Sperry of survey back corrections moving bottom hole location 220' to the North. Gathered up Drilling Team for conference call. Decision made not to drill ahead until all surve shave been reviewed and corrected. 00:00 00:30 0.50 11,698 11,698 COMPZ DRILL CIRC T Continue troubleshooting Geopilot. Make MAD pass for Geologist while discussin o tions with team. 00:30 01:00 0.50 11,698 11,120 COMPZ DRILL TRIP T POOH 5 stands for Geopilot test 01:00 01:15 0.25 11,120 11,120 COMPZ DRILL CIRC T Make topdrive connection and see if Geopilot will hold toolface and deflection. Would not hold. 01:15 01:45 0.50 11,120 11,120 COMPZ DRILL OWFF T Monitor well -static, pump 30 bbl dry ~ob P~~~}~ 44 of 72 ~, Time Logs _ _ I ____ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment __-- 01:45 05:15 3.50 11,120 __ 368 COMPZ DRILL _ TRIP T POOH on elevators, monitoring well via tri tank. 05:15 05:45 0.50 368 60 COMPZ DRILL TRIP T Rack back HWDP, jars and drill collars 05:45 06:30 0.75 60 60 COMPZ DRILL PULD T Download MWD 06:30 07:15 0.75 60 0 COMPZ DRILL PULD T Lay down Geopilot and MWD. 07:15 09:00 1.75 0 90 COMPZ DRILL PULD T Pick up Mud Motor and MWD. 09:00 09:45 0.75 90 90 COMPZ DRILL PULD T Upload MWD 09:45 10:00 0.25 90 90 COMPZ DRILL SFTY T PJSM- tripping in hole 10:00 10:30 0.50 90 465 COMPZ DRILL TRIP T TIH with BHA and 1 stand of drill i e. 10:30 11:00 0.50 465 465 COMPZ DRILL DHEO T Shallow pulse test MWD pumping 300 gpm, 1720 psi. PU wt 85k, SO wt 88k, rotatin wt 88k. 11:00 13:45 2.75 465 5,370 COMPZ DRILL TRIP T TIH to intermediate casing shoe. PU wt 130k, SO wt 115k, Lost 10 bbls to well Burin TIH. 13:45 14:00 0.25 5,370 5,370 COMPZ RIGMNT SVRG T Blow down top drive and hang blocks. 14:00 14:15 0.25 5,370 5,370 COMPZ RIGMNT SFTY T PJSM -Slip and cut drilling line 14:15 15:30 1.25 5,370 5,370 COMPZ RIGMNT SVRG T Slip and cut 123' of drilling line. 15:30 16:15 0.75 5,370 5,370 COMPZ RIGMNT SVRG T Service top drive, blocks, crown and drawworks. Ins ect saver sub. 16:15 22:30 6.25 5,370 11,697 COMPZ DRILL TRIP T TIH. PU wt 185k, wt 110k. Rig notified @ 20:00 that there were problems with the survey corrections. After corrections were made to last BHA run well position was moved f ll rth A 220' t th N erence ca . con o e o was held with the drilling and survey teams. The team decided not to drill ahead until all surveys from surface to TD for the current wellbore and the plug back were OC'd and corrected. Took 13 checkshot surveys with Mud Motor BHA at 7450', 7544', 8055', 8150', 8245', 11144', 11246', 11340', 11386', 11435', 11486', 11531' and 11697' 22:30 22:45 0.25 11,697 11,697 COMPZ DRILL OWFF T Monitor well -static 22:45 23:30 0.75 11,697 10,386 COMPZ DRILL TRIP T POOH to casing shoe while waiting on surve corrections. 23:30 00:00 0.50 10,386 10,386 COMPZ DRILL SRVY T Take check shot survey 10/31 /2008 Sperry troubleshooting surveys. Pulled out of hole to change directional tools and BHA spacing. Experienced a problem with first directional tool and sent to Deadhorse for another. Made up new BHA and tripped in hole takin surve son the wa to bottom. 6 of 19 surve s taken as of midni ht. 00:00 03:00 3.00 10,386 5,369 COMPZ DRILL TRIP T POOH to casing shoe while Sperry troubleshootin surve s Aare 45 of T~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:00 03:15 0.25 5,369 5,369 COMPZ DRILL CIRC T Circulate drillstring volume to insure dry job clear of pipe. Pumped 165 m, 1010 si. 03:15 06:00 2.75 5,369 5,369 COMPZ DRILL OTHR T Blow down top drive, service blocks, top drive, drawworks, inspect chains on drawworks, clean suction screens on mud pumps, inspect drawworks cooling system and perform derrick inspection while Sperry troubleshootin surve s. 06:00 09:30 3.50 5,369 5,369 COMPZ DRILL OTHR T Work on PMs, grease swivel ring and change oil in spinners on roughneck, service brushes on traction motors, check and adjust pressure on mud pump pulsation dampeners, perform PM on accumulator, scrub wind walls while Sperry troubleshooting surve s. Decision made to chan a out MWD. 09:30 09:45 0.25 5,369 5,369 COMPZ DRILL OWFF T onitor well -static 09:45 10:30 0.75 5,369 5,369 COMPZ DRILL CIRC T Pump 25 bbl dry job @ 5 bpm, 1480 si and blow down to drive. 10:30 12:30 2.00 5,369 372 COMPZ DRILL TRIP T POOH on elevators to BHA. PU wt 80k, SO wt 80k 12:30 12:45 0.25 372 98 COMPZ DRILL TRIP T Rack back HWDP, jars and drill collars. 12:45 13:15 0.50 98 98 COMPZ DRILL PULD T Download MWD 13:15 13:30 0.25 98 0 COMPZ DRILL PULD T Lay down MWD tools 13:30 14:00 0.50 0 0 COMPZ DRILL OTHR T Clean rig floor and drip pan. 14:00 15:00 1.00 0 98 COMPZ DRILL PULD T Pick up MWD tools 15:00 15:45 0.75 98 98 COMPZ DRILL PULD T Upload MWD. Unable to adjust for bias between logging and directional tools. 15:45 16:15 0.50 98 0 COMPZ DRILL PULD T Laydown directional tools 16:15 17:45 1.50 0 0 COMPZ DRILL PULD T Wait on directional tools coming from Deadhorse. 17:45 18:30 0.75 0 60 COMPZ DRILL PULD T Pick up new directional tools and make u BHA. 18:30 19:00 0.50 60 60 COMPZ DRILL PULD T Upload MWD 19:00 19:30 0.50 60 369 COMPZ DRILL TRIP T TIH with drill collars, jars and HWDP. 19:30 19:45 0.25 369 369 COMPZ DRILL DHEO T Shallow pulse test MWD pumping 310 gpm, 1780 psi -good test. PU wt 85k, SO wt 85k. 19:45 23:15 3.50 369 7,263 COMPZ DRILL TRIP T TIH with 4"drill pipe. Take 5 surveys on TIH, 5665', 5715', 5747', 6139', 6234'. 23:15 23:30 0.25 7,263 7,263 COMPZ DRILL TRIP T Change to 5" handling equipment. 23:30 00:00 0.50 7,263 7,456 COMPZ DRILL TRIP T TIH with 5"drill pipe. Take 1 surveys at 7378'. PU wt 140k, SO wt 105k. ~~r~e ~8fi s~f 7~ ~~ a Time Logs _ Date From To Dur S. De th E. Depth Phase Code Subcode T Comment _- - 11 /01 /2008 2a hr summary Trip in hole taking surveys as directed. Circulate bottoms up and trip out of hole to beginning of last Geopilot run. Resurve to TD and resume drillin B sand lateral. Be in circulatin to clean hole for liner run. 00:00 03:15 3.25 7,456 11,644 COMPZ DRILL TRIP T TIH with 5"drill pipe. Take 9 surveys, 7473', 7568', 8079', 8746', 10414', 11270', 11364', 11455', 11555'. PU wt 185k, SO wt 110k. Surveys done, waitin for S er to rocess data. 03:15 04:45 1.50 11,644 11,644 COMPZ DRILL CIRC T Circulate bottoms up pumping 320 gpm, 3430 psi, rotating 40 rpm. PU wt 180k, SO wt 112k, rotating wt 145k. 04:45 05:00 0.25 11,644 11,644 COMPZ DRILL OWFF T Monitor well -falling slowly 05:00 05:15 0.25 11,644 10,978 COMPZ DRILL TRIP T POOH 5 stands, planning to pull up to intermediate casin shoe. 05:15 05:30 0.25 10,978 10,978 COMPZ DRILL OWFF T Monitor well -falling slowly 05:30 06:45 1.25 10,978 9,462 COMPZ DRILL TRIP T Pump 30 bbl dry job and POOH on elevators. 06:45 10:30 3.75 9,462 10,866 COMPZ DRILL TRIP T Decision made to resurvey all of last Geopilot run. TIH taking surveys every stand , 15 total. PU wt 185k, SO wt 105k 10:30 11:15 0.75 10,866 11,698 COMPZ DRILL TRIP T TIH to bottom. PU wt 180k, SO 110k, rotatin wt 150k. 11:15 18:00 6.75 11,698 12,215 COMPZ DRILL DDRL T Drilling B sand lateral. 18:00 21:00 3.00 12,215 12,411 COMPZ DRILL DDRL T Drill B sand lateral to TD - 12411' MD. 21:00 00:00 3.00 12,411 12,411 COMPZ DRILL CIRC T Circulating hole clean. Pumping 310 gpm, 3490 psi, rotating 120 rpm. PU wt 185k, SO wt 115k, rotating wt 150k. Pumped 12900 strokes at midni ht. 11 /02/2008 Circulating through circulation sub to clean casing. Pull out of hole and lay down drilling BHA. Clean pits for brine dis lacement. Be in BOPE test. 00:00 05:15 5.25 12,411 12,411 COMPZ DRILL CIRC T Continue circulating hole clean. Pumping 312 gpm, 3660 psi, rotating 120 rpm. PU wt 165k, SO wt 112k, rotating wt 148k. Pumped fluid caliper using dye to estimate hole washout. Estimate 10% washout. Estimate will be used to calculate volume of Versaout to pump. Circulated a total of 9 bottoms u . 05:15 06:45 1.50 12,411 12,411 COMPZ DRILL CIRC T Drop ball to open circ sub and pump down. Ball landed and sub opened as expected. Staged pump rate up to 800 gpm. Inital circulating pressure 730 psi. Observed 900 psi increase in ressure after 2900 strokes. ~~t~e 47 r.~ 7? • Time Lo s ~--- _ - Date From To Dur S. De th E. De th Ph se Code Subcode T Comment _ 06:45 07:30 0.75 12,411 12,411 COMPZ DRILL CIRC T Shut down, cycled circ sub and resumed circulating at 700 gpm 1900 psi. Suspect #2 mud pump was sucking air and when pump caught up pressure increased. Compared rates and pressure to prior use and 1900 si is in line with ast use. 07:30 08:30 1.00 12,411 12,411 COMPZ DRILL CIRC T Circulated 4 bottoms up thru circ sub to clean casin . 08:30 09:15 0.75 12,411 12,411 COMPZ DRILL CIRC T Dropped closing balls and observed circ sub close. Confirmed by circulating until MWD detecting si nal from tools. 09:15 09:30 0.25 12,411 12,411 COMPZ DRILL OWFF T Monitor well -static 09:30 10:15 0.75 12,411 11,456 COMPZ DRILL TRIP T Pulled 10 stands on elevators. Hole taking proper fill. PU wt 185k, SO wt 112k. 10:15 10:45 0.50 11,456 11,456 COMPZ DRILL CIRC T Pump 30 bbl dry job and blow down to drive. 10:45 13:30 2.75 11,456 7,266 COMPZ DRILL TRIP T POOH on elevators to 4" drill pipe. PU wt 145k, SO wt 108k 13:30 13:45 0.25 7,266 7,266 COMPZ DRILL TRIP T Change over to 4" handling tools 13:45 15:15 1.50 7,266 5,370 COMPZ DRILL TRIP T POOH on elevators to circ sub. Break off sub and remove balls. 15:15 16:45 1.50 5,370 1,032 COMPZ DRILL TRIP T POOH on elevators. 16:45 18:00 1.25 1,032 1,032 COMPZ DRILL OTHR T Clear and clean rig floor. 18:00 18:15 0.25 1,032 1,032 COMPZ DRILL SFTY T PJSM -laying down BHA. 18:15 19:00 0.75 1,032 369 COMPZ DRILL TRIP T POOH on elevators to BHA 19:00 19:15 0.25 369 60 COMPZ DRILL PULD T Lay down BHA, HWDP, jars and collars 19:15 20:00 0.75 60 60 COMPZ DRILL PULD T Download MWD. 20:00 21:00 1.00 60 0 COMPZ DRILL PULD T Lay down MWD and Mud Motor. Break off bit. 21:00 21:30 0.50 0 0 COMPZ DRILL OTHR T Clear and clean rig floor. 21:30 21:45 0.25 0 0 COMPZ WELCTL BOPE T Prep for BOPE test. Pick up test joint and pull wear bushing. Sim ops - cleanin its for dis lacement. 21:45 22:00 0.25 0 0 COMPZ WELCTI SFTY T PJSM -testing BOPE 22:00 22:45 0.75 0 0 COMPZ WELCTL BOPE T Drain stack, make up 3-1/2" test joint to test plug and set test plug in wellhead. Sim ops -cleaning pits for dis lacement. 22:45 00:00 1.25 0 0 COMPZ WELCTL BOPE T Testing BOPE. 11 /03/2008 Tested BOPE. Upper IBOP failed, was replaced and retested good. Ran in hole with cleanout BHA to intermediate casing shoe. Circulated casing clean. Ran in hole to TD and circulated. Max gas on bottoms up 180 units. Pare 43 off 7~ Time Logs _ __ __ From To Dur S De th E. De th Ph se Code Subcode T Comment ___ Date _ 00:00 04:30 4.50 0 0 COMPZ WELCTL BOPE T Continue testing BOPE: 250 psi low, _ 3000 psi high. Testing with 3-1/2", 4" & 5". Tested 3-1/2" x 6" variables with all sizes. Upper IBOP failed to test. Koomey drawdown test 3050 psi starting pressure, 1500 psi after functioning equipment. 1 minunte 8 seconds for 200 psi pressure increase and 3 minute 43 seconds to full char e. 04:30 05:00 0.50 0 0 COMPZ WELCTL BOPE T Rig down test equipment and install wear bushin . 05:00 05:15 0.25 0 0 COMPZ WELCTL SFTY T PJSM -changing Upper IBOP & 4-1 /2" saver sub. 05:15 09:00 3.75 0 0 COMPZ WELCTL EORP T Change out Upper IBOP and make u Lower IBOP. 09:00 09:45 0.75 0 0 COMPZ RIGMNT RGRP T Make up new 4-1/2" saver sub 09:45 10:45 1.00 0 0 COMPZ WELCTL BOPE T Rig up and retest Upper IBOP, 250 si low & 3000 si hi h. 10:45 13:45 3.00 0 0 COMPZ WELCTL EQRP T Make up compression clamps. Change grabber dies and install bell uide. 13:45 14:00 0.25 0 0 COMPZ DRILL SFTY T PJSM -making up cleanout BHA 14:00 14:45 0.75 0 282 COMPZ DRILL PULD T Pick up, make u and RIH with cleanout BHA 14:45 17:30 2.75 282 5,376 COMPZ DRILL TRIP T TIH on a evators to intermediate casin shoe. 17:30 18:45 1.25 5,376 5,376 COMPZ DRILL CIRC T Circulate bottoms up at intermediate casin shoe, blow down to drive. 18:45 22:15 3.50 5,376 12,410 COMPZ DRILL TRIP T TIH on elevators to TD. Recorded PU & SO wts Burin tri in hole. 22:15 00:00 1.75 12,410 12,410 COMPZ DRILL CIRC T Circulate 1st bottoms up pumping 8 bpm, 2550 psi, rotating 95 rpm. Max gas 180 units. Max mud wt 9.3+. Continue circulating. Start mixin destructor 00:10 11 /04/2008 Continue to circulate hole clean prior to pumping breaker, pump versa breaker, monitor well, pull out of hole on elevators to 5187', circulate, clean floor, continue to pull out of the hole with BHA #16, lay down BHA, rig up to run 3-1/2" 9.2 ppf, L-80 SLHT and Hyd 563 liner/screens, MU Sperry sun MWD, pre job safety meeting on runnin liner for the "B" lateral, Run liner er detail to 3390' 'oint 108 in the hole . 00:00 00:15 0.25 12,410 12,410 COMPZ DRILL CIRC T Continue to circulate 1st bottoms up pumping 8 bpm, 2550 psi, rotating 95 rpm w/ 9k ft Ibs of torque. Max gas 180 units. Max mud wt 9.3+. 00:15 03:15 3.00 12,410 12,410 COMPZ DRILL CIRC T Continue to circulate 1st bottoms up pumping 8 bpm, 2550 psi, rotating 95 rpm w/ 9k ft Ibs of torque. Max gas 180 units. Max mud wt 9.3+. Start mixing destructor @ 00:10. Circulated a total of 2360 bbls. ~~ge 9~ a~f ~~ '~ Time Logs _ ur S. De th Date From To D De th Phase Code Subcode T Comment E. 03:15 06:30 _ 3.25 12,410 _ 12,311 COMPZ DRILL CIRC T Pump 25 bbls of LVT, 64 bbls transition spacer, 290 bbls of vis brine, 310 bbls versa out breaker. Pumping @ 5 bpm w/ 870 psi. Rotate 100 rpm w/ 9 to 10k ft Ibs of torque. Reciprocate from 12406' to 12311'. PU wt 185k, SO wt 118k, Rot wt 150k. 06:30 07:00 0.50 12,311 12,311 COMPZ DRILL OWFF T Monitor well. Lossin a little fluid fallin .Blow down to drive. 07:00 10:45 3.75 12,311 7,168 COMPZ DRILL TRIP T Pull out of the hole on elevators. Monitor displacement on the pill pit. Record PU and slackoff wt's every 10 stands. 10:45 11:00 0.25 7,168 7,168 COMPZ DRILL PULD T Change handling tools from 5" to 4". 11:00 12:15 1.25 7,168 5,187 COMPZ DRILL TRIP T Continue to pull out of the hole on elevators. Monitor displacement on the pill pit. Record PU and slackoff wt's eve 10 stands. 12:15 14:00 1.75 5,187 5,092 COMPZ DRILL CIRC T Circulate 9.2 ppg brine while reciprocating from 5187' to 5092'. Pumping 5 bpm w/ 350 psi. Rotate 30 rpm w/ 4k ftlbs of torque. PU wt 132k, SO wt 115k, rot wt 125k. Pum ed a total of 402 bbls. 14:00 16:15 2.25 5,092 5,092 COMPZ DRILL OTHR T Clean and clear rig floor. Clean trip tank. Fill tank with brine. 16:15 17:45 1.50 5,092 282 COMPZ DRILL TRIP T Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and slackoff wt's eve 10 stands. 17:45 18:00 0.25 282 0 COMPZ DRILL PULD T Lay down BHA #16. 18:00 19:00 1.00 0 0 COMPZ CASING RURD T Rig up to run the 3-1/2" SLHT and, H d 563 9.2 f L-80 screen and blank liner for the "B" lateral. 19:00 20:00 1.00 0 0 COMPZ CASING OTHR T Verify super slim MWD crossover connections are for ued. 20:00 20:15 0.25 0 0 COMPZ CASING SFTY T Pre job safety meeting on running liner for the "B" lateral. 20:15 00:00 3.75 0 3,390 COMPZ CASING RUNL T Run the 3-1/2" liner per detail. Record PU and SO wt's every 10 jts. to 3390' at midnight. (108 jts in the hole . Averera a losses of 11 b h. 11 /05/2008 Continue to run the liner f/ "B" lateral from 3390' to 12093', start rotating liner in the hole to 12328', orient, drop Baker Oil Tools 1-3/4" ball, pump to seat with shoe @ 12325' (TOL @ 4713.26'), set flexlock liner hanger/MLZXP packer, test annulus/packer to 2500 psi f/ 5 min (good test). Pickup 7', then tag with dog sub verifying liner top @ 4713.26'. Pull out of hole to 4565', pump a dry job, pull out /lay down running tools and MWD. Clear floor. Remove backup wrench from top drive to perform preventative maintenance (replace seals on grabbers). Prejob safety meeting on PU/MU Whipstock assembly. Bring tools to the floor. MU whipstock assembl for the "D" lateral. Orient ali nment of anchor with whi stock face. 00:00 02:15 2.25 3,390 6,100 COMPZ CASING RUNL T Continue to run the 3-1/2" 9.2 ppf L-80 SLHT connection liner per detail from 3390' to 6100'. Record PU and SO wt's every 10 jts. Avererage losses of 11 b h. Rage fl0 of 72 Time Logs ___ e_ T Comment Date f=rom To Dur S De th E. De th Pha e Code Subcod 02:15 02:30 0.25 6,100 6,100 COMPZ CASING _ RUNL T Make up the crossover to 3-1/2" hyd 563. Change the crossover on floor safe valve. 02:30 03:30 1.00 6,100 7,494 COMPZ CASING RUNL T Continue to run the 3-1/2" 9.2 ppf L-80 Hyd 563 connection liner per detail from 6100' to 7494'. Record PU and SO wt's every 10 jts. Avererage losses of 11 b h. 03:30 04:15 0.75 7,494 7,583 COMPZ CASING RUNL T Make up Baker MXZXP han er/Packer assembl . 04:15 04:30 0.25 7,583 7,583 COMPZ CASING RUNL T a e up perry Sun super slim MWD to liner han er. 04:30 05:00 0.50 7,583 7,620 COMPZ CASING RUNL T Continue to make up Baker liner han er assembl . 05:00 05:15 0.25 7,620 7,620 COMPZ CASING DHEQ T Pickup/makeup stand of 5" drillpipe. Shallow pulse test Sperry Sun MWD. Pumping 100 gpm w/ 910 psi- 12%fiow- Rotate with 30 rpm and 3k ft Ibs of torque. PU wt 110k, SO wt 94k, Rot wt 110k. 05:15 05:30 0.25 7,620 7,710 COMPZ CASING OTHR T Install stripper rubber. Blow down the top drive. Remove crossover from floor safe valve. 05:30 05:45 0.25 7,710 8,488 COMPZ CASING RUNL T Trip in the hole with the liner on 5" drill pipe. Average losses 11 bbls per hour. Monitor displacement on the tri tank. 05:45 06:00 0.25 8,488 8,860 COMPZ CASING RUNL P Continue trip in the hole with the liner on 5"drill pipe. Average losses 11 bbls per hour. Monitor displacement on the tri tank. 06:00 08:45 2.75 8,860 12,093 COMPZ CASING RUNL P Continue trip in the hole with the 3-1/2" SLHT &Hyd 563 9.2ppf L-80 screen/blank "B" lateral liner on 5" drill pipe. Average losses 11 bbls per hour. Monitor displacement on the trip tank. Record PU and SO wt's eve 5 stands. 08:45 12:00 3.25 12,093 12,320 COMPZ CASING RUNL P Continue running liner with rotation starting at 12093' to 12320'.. Rotate 50 RPM w/ 8-10k ft Ibs of torque.Pumping 42 gpm w/ 150 psi. PU wt 175k, SO wt 110k, rot wt 150k. 12:00 13:15 1.25 12,320 12,328 COMPZ CASING RUNL P Continue running liner with rotation starting at 12093' to 12320'.. Rotate 50 RPM w/ 8-10k ft Ibs of torque.Pumping 42 gpm w! 150 psi. PU wt 175k, SO wt 110k, rot wt 150k. 13:15 14:45 1.50 12,328 12,328 COMPZ CASING CIRC P Reciprocate from 12328' to 12308' while pumping 130 gpm with 1200 psi to orient Baker MLZXP liner packer. Oriented packer to 10 deg left of highside. PU wt 175k, SO wt 118k, Rot wt 150k. Pane s1 ~f 72 Time Logs Date From To Dur S. D th E. De th PhaSe Code Subcode_ T Comment __ __ _ 14:45 15:00 0.25 12,328 12,328 COMPZ CASING OTHR P Pull out from 12328' to 12256'. Drop Baker's 1-3/4" ball. Trip back into 12328'. 15:00 15:30 0.50 12,328 12,325 COMPZ CASING OTHR P With liner shoe @ 12325.43' and 120k on wtindicator--pumping ball down with 118 gpm w/ 980 psi. MWD toolface updates showing 10 deg left of highside. Ball on seat with 572 strokes (57.6 bbls). Continue pumping, pressure up to 1800 psi, slack off 50k on hanger, increase pressure to 4000 psi. Observe packer set @ 2600 psi, then neutralize @ 3200 psi. Bleed off ressure. 15:30 15:45 0.25 12,325 12,325 COMPZ CASING DHEQ P Pressure_up backside (Down the kill line with Hydril shut) to test MLZXP packer to 2500 psi for 5 min. Good test. Chart test. 15:45 16:00 0.25 12,325 4,565 COMPZ CASING RUNL Pickup 7', then slack off and tag with dog sub to verify top of liner @ 4713.26'. Continue to pull out of the hole to 4565'. PU wt 155k, So wt 138k. 16:00 16:15 0.25 4,565 4,565 COMPZ CASING CIRC P Pump a dry job. 18 bbls 9.8 ppg. Blow down the to drive. 16:15 17:45 1.50 4,565 67 COMPZ CASING RUNL P Trip out of the hole with liner running tools. Monitor well on the trip tank. Record PU and SO wt's every 10 stands. 17:45 18:30 0.75 67 0 COMPZ CASING OTHR P Lay down Sperry Sun super slim MWD and Baker liner rennin tools. 18:30 19:00 0.50 0 0 COMPZ CASING OTHR P Clean and clear rig floor. Average of 7 b h losses. 19:00 20:30 1.50 0 0 COMPZ RIGMNT RGRP T Remove backup wrench from top drive. Goal is to repair seals on the rabber c tinder. 20:30 20:45 0.25 0 0 PROD2 STK OTHR P Pre job safety meeting on picking up Baker whipstock assembly for the "D" lateral. 20:45 21:45 1.00 0 0 PROD2 STK PULD P Bring tools to the rig floor. 21:45 23:30 1.75 0 49 PROD2 STK PULD P Make up Baker milling assembly. Monitor losses to be average 7 bbl er hour. 23:30 00:00 0.50 49 49 PROD2 STK OTHR P Orient helix of anchor with whipstock face. Oriented to be in alignment with face of whipstock. Note: For the day: While circulating lost 56 bbls to the formation. For the trip lost 58 bbls of 9.2 brine. Wage a2 ssf 72 ~ ~ Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 11 /06/2008 _~~ 24 hr summary Continue to orient alignment of anchor with whipstock face. continue to makeup BHA, orient MWD to whipstock face (offset 236 deg), upload MWD, continue makeup assembly, shallow pulse test, pre job safety meeting on installing backup wrench on the top drive, install same, trip in the hole with assembly to 4208', MAD pass to 4268', continue trip in the hole to 4713', orient to 7 deg left of high side, latch anchor into collet profile of MLZXP profile (30k down), pull 20k over, set down 42k shear bolt, pickup with no over pull, displace well to OBM @ 4671', SPR's and milling parameters, mill from TOW @ 4675.19' to BOW @ 4692.08', continue to mill to 4722' (30' of 8-1/2" hole below BOW), work mills through window-OK, circulate hole clean, rig up for formation integrity test, perform test to 13.1 ppg, rig down equipment, trip out with milling assembly to 1792' at midni ht. 00:00 00:30 0.50 49 49 PROD2 STK OTHR P Orient helix of anchor with whipstock face. Oriented to be in alignment with face of whi stock. No offset. 00:30 01:15 0.75 49 103 PROD2 STK PULD P Continue to make up whipstock BHA. 01:15 02:00 0.75 103 134 PROD2 STK PULD P Makeup Sperry Sun MWD. 02:00 02:30 0.50 134 134 PROD2 STK OTHR P Orient MWD with face of whipstock. Offset is 236.35 degrees to face of the whi stock. 02:30 03:00 0.50 134 134 PROD2 STK OTHR P Upload MWD. 03:00 03:30 0.50 134 233 PROD2 STK PULD P Continue to make up milling assembly- install bumper sub and a stand of 5" HWDP. 03:30 04:00 0.50 233 233 PROD2 STK CIRC P Shallow pulse test Sperry Sun MWD. Pumping 650 gpm w/ 1340 si. Good test. Blow down to drive. 04:00 05:15 1.25 233 233 PROD2 RIGMNT RGRP T Pre job safety meeting on installing back-up wrench on the top drive. Install backup to the top drive after re air of tinder seals. 05:15 05:30 0.25 233 509 PROD2 STK TRIP P Continue to makeup BHA assembly- 3 more stands of 5" HWDP. 05:30 06:00 0.50 509 1,367 PROD2 STK TRIP P Trip in the hole with the whipstock for the "D" lateral on 5"drill i e. 06:00 08:30 2.50 1,367 4,208 PROD2 STK TRIP P Continue trip in the hole with the whipstock for the "D" lateral on 5" drill pipe. Fill pipe @ 2888'. Pumping 530 m w/ 1160 si 44% flow out. 08:30 09:15 0.75 4,208 4,268 PROD2 STK TRIP P Mad Pass logging from 4208' to 4268'. Pumping 518 gpm w/ 1200 psi 40% flow out. PU wt 160k, SO wt 142k. 09:15 09:30 0.25 4,268 4,600 PROD2 STK TRIP P Continue trip in the hole with the whipstock for the "D" lateral on 5" drill pipe. Monitor displacement on the tri tank. 09:30 10:00 0.50 4,600 4,713 PROD2 STK TRIP P Continue trip in the hole with the whipstock for the "D" lateral on 5" drill pipe from 4600' to 4713'. Circulating while orienting whipstock to left of hi hside. Pumping 525 gpm w/ 1260 psi. PU wt 160k, SO wt 142k. P~t~e 53 ~f TZ Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 10:00 10:30 0.50 4,713 4,671 PROD2 STK TRIP P _ Continue trip in the hole with the whipstock for the "D" lateral on 5" drill pipe from 4713' (top of liner). Observed 10k drag @ 4723' (Seals), continue to 4726'. Set down 30k, Pick up to 180k on weight indicator (20K Overpull-latched in with collet), slack off to 100k to shear bolt holding milling assembly to whipstock (45k bolt was installed). Pickup and observe no overpull to 4671'. PU wt 155k, SO wt 138k, rot wt145k. .Note: After tagging with the whipstock/milling assembly, the liner tally was adjusted to reflect depth of tag (1.73' higher). Casing tally reflects top of liner @ 4711.53' with shoe 12323.7' 10:30 11:30 1.00 4,671 4,671 PROD2 STK CIRC P Displace well to 9.2 ppg OBM. Pumping 465 gpm w/ 1570 psi- 47% flow out. Oil base mud to surface after pumping 371 bbls.. PU wt 155k, SO wt 138k, rot wt 145k. 11:30 11:45 0.25 4,671 4,671 PROD2 STK CIRC P Obtain slow pump rates. Set depth on totco, establish milling arameters. 11:45 12:00 0.25 4,671 4,676 PROD2 STK WPST P Trip into top of whipstock @ 4675.19'. Mill lug on whipstock and 8-1/2"window for "D" lateral from ~"' ,~ ~ A ` \ TOW @ 4675.19'. Weight on bit 2 to ~ ~ 4k, 80 rpm, torque off 5k ft Ibs, torque on 6-10k ft Ibs. Pumping 500 m w/ 2110 si, flow out 45% 12:00 18:00 6.00 4,676 4,717 PROD2 STK WPST P Continue to mill window from 4676' to 4717'. Weight on bit 10-12k, 50-60 rpm w/ 5k torque off bottom, 4-8k ft Ibs on bottom. Pumping 350 gpm w/ 960 psi. PU wt 155k, SO wt 140k, Rot wt 145k. 18:00 18:45 0.75 4,717 4,722 PROD2 STK WPST P Continue to mill window from 4717' to 4722'. Weight on bit 10-12k, 50-60 rpm w/ 5k torque off bottom, 4-8k ft Ibs on bottom. Pumping 350 gpm w/ 960 psi. PU wt 155k, SO wt 140k, Rot wt 145k. 18:45 19:15 0.50 4,722 4,722 PROD2 STK CIRC P Work milling assembly thorugh window with and without pumps on. 2-3k dra . 19:15 21:15 2.00 4,722 4,675 PROD2 STK CIRC P Circulate bottom's up @ 4675'. Pumping 444 gpm w/ 1310 psi. Pump a 29 bbls sweep (9.2 ppg/ 127 vis). Increase rate to 510 gpm w/ 1690 psi. Pumped a total of 1094 bbls. 21:15 21:30 0.25 4,675 4,639 PROD2 DRILL FIT P Stand back a stand. Rig up to perform a formation integrity test to 13.1 i'ar~e 54 of 72 Time Logs __ Date From To Dur S De th E. De th Phase Code Subcode T Comment 21:30 22:15 0.75 4,639 4,639 PROD2 DRILL FIT P Perform FIT with BOP test pump. 9.2 ppg mud 710 psi 3454' TVD @ top of window. FIT to 13.1 .Chart test. 22:15 22:30 0.25 4,639 4,639 PROD2 DRILL FIT P Rig down testing equipment. 22:30 22:45 0.25 4,639 4,639 PROD2 STK OTHR P Monitor well- static. 22:45 23:00 0.25 4,639 4,266 PROD2 STK TRIP P Pull out of the hole from 4639' to 4266'. Monitor well on the tri tank. 23:00 23:15 0.25 4,266 4,266 PROD2 STK CIRC P Pump a 24 bbl dry job, then blow down the to drive. 23:15 00:00 0.75 4,266 1,792 PROD2 STK TRIP P Continue to pull out of the hole with 8-1/2" millin assembl to 1792' 11 /07/2008 Continue trip out with milling assembly from 1792', lay down milling assembly, mills full guage, download Sperry MWD, clear floor. Pull Vetco/Gray wearbushing, flush stack, install wear bushing. Pre job safety meeting, PU/MU Drilling assembly for "D" lateral, run in to 4615'. Slip and cut 101' of 1-3l8" drilling line, service rig. Continue to trip past whipstock top @ 4675.19' to BOW @ 4692' to 4722'. Directional drill "D" lateral with 6-3/4" Hu hes PDC and S er Sun motor w/ 1.22 de bend from 4722' to 5666'. 00:00 00:30 0.50 1,792 460 PROD2 STK TRIP P Continue to pull out of the hole with 8-1/2" milling assembly from 1792' to 460'. Hole took proper fill. Monitor well- static. 00:30 01:00 0.50 460 85 PROD2 STK PULD P Lay down BHA. 01:00 01:15 0.25 85 85 PROD2 STK OTHR P Download Sperry Sun MWD. Clean floor. Cleanin its #1, #2 and #5. 01:15 02:00 0.75 85 0 PROD2 STK PULD P Continue to lay down milling BHA. 02:00 02:45 0.75 0 0 PROD2 STK PULD P Clean and clear rig floor of Baker Oil Tools millin a ui ment. 02:45 03:00 0.25 0 0 PROD2 DRILL OTHR P Pull Vetco Gray wear bushing. 03:00 04:00 1.00 0 0 PROD2 DRILL CIRC P Flush stack--pumping 818 gpm w/ 330 si. 04:00 04:30 0.50 0 0 PROD2 DRILL OTHR P Install Vetco Gray wear bushing. 04:30 04:45 0.25 0 0 PROD2 DRILL SFTY P Pre job safety meeting on picking up/ makin u BHA #18. 04:45 06:00 1.25 0 93 PROD2 DRILL PULD P Pickup SperryDrill motor, adjust bend from 1.5 deg to 1.22 deg, PU TM, PWD, Directional, Gamma/Res, stabilizer and float sub. 06:00 08:15 2.25 93 93 PROD2 DRILL PULD P Torque connections to 10k ft Ibs 3-1/2" IF , U load S er Sun MWD. 08:15 08:30 0.25 93 369 PROD2 DRILL TRIP P Continue with BHA #18 (6-3/4" bit, S er Drill motor 1.22 de bend. 08:30 10:00 1.50 369 4,615 PROD2 DRILL TRIP P Trip in the hole w/ BHA #18. Monitor displacement on the trip tank. Record PU and SO wt's every 10 stands. Filled pipe @ 2727' pumping 300 gpm w/ 2410 psi- 36% flow out. Filled pipe @ 4615' pumping 300 gpm w/ 2560 psi- 35% flow out. PU wt 130k, SO wt 115k. 10:00 11:15 1.25 4,615 4,615 PROD2 RIGMNT SVRG P Slip and cut drilling line. Cut 101'. Adjust and inspect brakes. Monitor well on the tri tank. 11:15 12:30 1.25 4,615 4,615 PROD2 RIGMNT SVRG P Service rig, top drive, blocks, drawworks. Pane ~~ ct 7~ Time Logs Date From To Dur S. Ds th E. De th Phase Code Subcode T Comment 12:30 13:15 0.75 4,615 4,722 PROD2 DRILL TRIP P Trip in past whipstock after orienting to high side from 4615' to 4670'. Pumping 300 gpm w/ 2530 psi- 35% flow out. Trip in with out the pumps f/ 4670' to 4713'. Obtain slow pump rates. Orient to highside, then wash to bottom. PU wt 130k, SO wt 115k. 13:15 18:00 4.75 4,722 5,095 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas observed 652 units. 18:00 00:00 6.00 5,095 5,666 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 1082 units. 11 /08/2008 Continue to directional drill "D" lateral with 6-3/4"Hughes PDC and Sperry Sun motor w/ 1.22 deg bend from 5666' to 7908'. 00:00 06:00 6.00 5,666 6,282 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 1515 units. 06:00 12:00 6.00 6,282 6,809 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 1317 units. 12:00 18:00 6.00 6,809 7,474 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 776 units. 18:00 00:00 6.00 7,474 7,908 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 846 units. 11 /09/2008 Continue to directional drill "D" lateral with 6-3/4" Hughes PDC and Sperry Sun motor w/ 1.22 deg bend from 5666' to 7908' to 8140', circ two bottom's up, monitor well, pull out of the hole 37 stands of 5" to 4615', monitor well, change elevators, service rig, ,install 33 stands of 4" drill pipe to 7728', change elevators, install PBL sub after 1 st single of 5"drill pipe, run in the hole to 8045', survey, trip to 8120', survey, wash to bottom 8140', continue to drill the "D lateral from 8140' to 9263'. 00:00 03:00 3.00 7,908 8,140 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 846 units. 03:00 04:30 1.50 8,140 8,000 PROD2 DRILL CIRC P Circulate two bottoms up. Recip pipe from 8140' to 8000'. Pumping 315 gpm w. 2870 psi, 34% flow out. Rotate 120 rpm w/ 6k ft Ibs of torque. Pum ed a total of 623 bbls. 04:30 04:45 0.25 8,000 8,045 PROD2 DRILL OWFF P Monitor well- static. 04:45 05:00 0.25 8,045 7,953 PROD2 DRILL CIRC P Obtain slow pump rates. Pump a 26 bbl dry job (11.2 ppg/78 vis). Blow down the to drive. Page 56 'of 72 ~ ~ Time Lois Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:00 07:30 2.50 7,953 4,615 PROD2 DRILL TRIP P __ __ Pull out of the hole 37 stands of 5" drill pipe -objective is to install 33 more stands of 4"drill pipe and the PBL sub above the first single of 5" drill pipe. Record PU and SO wt's every 5 stands. Monitor well on the trip tank. Depth 4615': PU wt 148k, SO wt 120k. 07:30 07:45 0.25 4,615 4,615 PROD2 DRILL OWFF P Monitor well- static. Change elevators to 4". Clean ri floor. 07:45 08:45 1.00 4,615 4,615 PROD2 RIGMNT SVRG P Service top drive, blocks, drawworks. Monitor well on the tri tank. 08:45 09:45 1.00 4,615 7,255 PROD2 DRILL TRIP P Trip in the hole with 28 stands of 4" drill pipe. PU wt 148k, So wt 110k. Record PU and SO wt's every 5 stands. Monitor well on the tri tank. 09:45 10:00 0.25 7,255 7,727 PROD2 DRILL TRIP P Pickup and make up/run in the hole with 5 stands (15 joints) of 4"drill pipe from the pipe shed. Record PU and SO wt's every 5 stands. Monitor well on the tri tank. 10:00 10:15 0.25 PROD2 DRILL OWFF P Monitor well- static. Change elevators to 5". 10:15 10:45 0.50 7,727 7,836 PROD2 DRILL TRIP P Make up first stand of 5"drill pipe. Break first single and install Downhole Devices circulating sub PBL. 10:45 11:00 0.25 7,836 8,045 PROD2 DRILL TRIP P Continue trip in the hole with 5" drill i e. 11:00 11:45 0.75 8,045 8,140 PROD2 DRILL TRIP P At 8045': Acquire deviation survey, mode switch MW. Continue in the hole to 8120', survey, wash and ream to bottom @ 8140'. Pumping 320 m. PU wt 148k, SO wt 110k. 11:45 12:00 0.25 8,140 8,192 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 406 units. 12:00 18:00 6.00 8,192 8,742 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3l4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 840 units. 18:00 00:00 6.00 8,742 9,263 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 1105 units. 11 /10/2008 Continue to directional drill "D" lateral with 6-3/4" Hughes PDC and Sperry Sun motor w/ 1.22 deg bend from 9263' to 10690', Pump a 40 bbls sweep (11.0 ppg/ 57 vis)-slight increase incuttings, continue to directional drill "D" lateral from 10690' to 11373'. 00:00 06:00 6.00 9,263 9,739 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 1105 units. 06:00 12:00 6.00 9,739 10,392 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 840 units. 1~8L~j@ ~~ £3f f ~ Time logs Date From To Dur S. De th E. De th Phase Code Subco de T Comment 12:00 15:30 3.50 10,392 10,690 _ PROD2 DRILL _ DDRL P _ Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 719 units. 15:30 17:15 1.75 10,690 10,690 PROD2 DRILL CIRC P Pump a 40 bbl sweep (11ppg/ 57 vis). Pumping 315 gpm w/ 3390 psi-34% flow out. Rotate 120 rpm w/ 7k ft Ibs of torque. Pumped a total of 710 bbls. Max gas observed 447 units. Obtain slow pump rates. Note: Slight increase in cuttings. ECD's before 11.52 ppg, after 11.37 17:15 18:00 0.75 10,690 10,785 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 389 units. 18:00 00:00 6.00 10,785 11,373 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 920 units. 11 /11 /2008 Continue to directional drill "D" lateral with 6-3/4" Hughes PDC and Sperry Sun motor w/ 1.22 deg bend from 11373' to 11832', circulate to reduce ECD's from 11.9 to 11.5 ppg, continue to directional drill "D" lateral from 11373' to 12375' (TD of "D" lateral), circulate 6 bottom's up @ 320 gpm w/ 3370 psi, open circulation sub (Downhole Devices- PBL), circulate 6 bottom's up @ up to 800 gpm w/ 1750 psi, drop ball and close circulating sub, monitor well- static, pull out of the hole on elevators to 11454', pump a dry job, blow down top drive, continue to ull out of the hole to 10218' midni ht. 00:00 05:30 5.50 11,373 11,832 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 920 units. 05:30 07:00 1.50 11,832 11,832 PROD2 DRILL CIRC P Circulate to reduce ECD's. Pumping 310 gpm w/ 3350 psi.- 34% flow out. Reciprocate from 11802' to 11738'. Rotate 120 rpm w/ 8k ft Ibs of torque. Initial ECD's 11.9 ppg, final 11.5 ppg. Circualted a total of 622 bbls. 07:00 12:00 5.00 11,832 12,278 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 920 units. 12:00 13:00 1.00 12,278 12,375 PROD2 DRILL DDRL P Directional drill "D" lateral with 6-3/4" Hughes PDC and SperryDrill w/ 1.22 deg bend motor. Max gas obseved 920 units. 13:00 19:15 6.25 12,375 12,375 PROD2 DRILL CIRC P Circulate 6 bottom's up. Pumping 320 gpm w/ 3370 psi- 34% flow out. Reciprocate from 12375 to 12305'. Rotate 120 rpm w/ 8000 ft Ibs of torque. Pumped a totatl of 2812 bbls. Max gas observed was 674 units. Monitor well- static. ~'~gE ~8 of a 2 Time__Logs Date From To Dur S_ . De th E. De th Ph se Code Subcode T Comm ent 19:15 19:30 0.25 12,375 12,375 PROD2 DRILL CIRC P _ Obtain pump parameters. 20 spm 650 psi, 30 spm 850 psi. Drop 2" Torlon ball, then pump down @ 6 bpm w/ 2150 psi- 30% flow out for 575 strokes, slow down to 2bpm w/ 650 psi until ball on seat (600 strokes). Observed the pressure drop from 650 si to 350 si. 19:30 21:15 1.75 12,375 12,375 PROD2 DRILL CIRC P Increase pump rate to 325 gpm w/ 560 psi- 36% flow out, no detection by MWD. Increase rate to 500 gpm w/ 680 psi-44% flow out for one bottom's up (no downhole mud losses observed). Then increased pump rate to 800 gpm w/ 1750 psi- 58%fiow out. Reciprocated pipe from 12375' to 12305'. Every 20 minutes the pipe was rotated 50 rpm for 2 to 3 minutes. Circulated a total of 1451 bbls (6 bottom's up from circulating sub. 21:15 21:30 0.25 12,375 12,375 PROD2 DRILL CIRC P Drop (2) 1-3/8" steel balls to close the Downhole Devices PBL sub. Pumped balls down @ 6 bpm w/ 400 psi- 30% flow out for 414 strokes. Observed the pressure increase to 2700 psi, then drop. Increased rate pump rate to 300 gpm w/ 2820 psi-33% flow out. MWD was detectin ulses. 21:30 21:45 0.25 12,375 12,375 PROD2 DRILL OWFF P Monitor well- static. 21:45 22:30 0.75 12,375 11,454 PROD2 DRILL TRIP P Pull 10 stands out of the hole on elevators. Monitor hole fill- proper displacement. PU wt 190k, SO wt 120k. Obtain PU and SO wt's every 5 stands. 22:30 22:45 0.25 11,454 11,454 PROD2 DRILL CIRC P Pump a dry job. Blow down the top drive. 22:45 00:00 1.25 11,454 10,218 PROD2 DRILL TRIP P Pull out of the hole on elevators. Monitor hole fill- proper displacement. Obtain PU and SO wt's eve 5 stands. 11/12/2008 Continue to pull out of the hole from 10218' to 7730', Retrieve balls from Downhole Devices PBL circulating sub, lay down same, change handling tools to 4", Continue to pull out of the hole to BHA @ 372'. Lay down drilling BHA including download of Sperry Sun. Clean and clear rig floor. Pickup cleanout BHA to 301', trip in the hole on elevators to 7659', pickup two more joints of 4"drill pipe, install crossover to 5", change handling tools to 5", install (2) string magnets, trip in the hole to TD @ 12375', lay down a single, rotate and reciprocate from 12375' to 12280 while VersaOut breaker is being mixed @ MI mud plant in Deadhorse, um in 320 m w/ 2050 si. rage 59 of 72 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 06:00 6.00 10,218 370 PROD2 DRILL TRIP P Continue pulling out of the hole on elevators. Monitor hole on trip tank. Obtain PU and SO wt's every 5 stands in open hole, every 10 stands in casing. Note: Pulled through window good. No overpull. Hole took proper dis lacement. 06:00 07:15 1.25 370 96 PROD2 DRILL PULD P Lay down drilling BHA. 07:15 08:00 0.75 96 96 PROD2 DRILL OTHR P Download MWD. Grease crown, clear and clean floor. 08:00 09:15 1.25 96 0 PROD2 DRILL PULD P Continue to lay down BHA. 09:15 09:30 0.25 0 0 PROD2 DRILL OTHR P Clean and clear rig floor. 09:30 10:30 1.00 0 301 COMPZ DRILL PULD P Pickup/ makeup cleanout BHA. Monitor well on the tri tank. 10:30 13:30 3.00 301 7,659 COMPZ DRILL TRIP P Trip in the hole with 4" drill pipe. PU wt 150k, SO wt 110k 13:30 14:00 0.50 7,659 7,748 COMPZ DRILL PULD P Pickup two joints of 4" drill pipe, makeup the 4" x 5" crossover, change elevators then two string ma nets. 14:00 16:15 2.25 7,748 12,317 COMPZ DRILL TRIP P Continue trip in the hole with 5"drill pipe. Monitor displacement on the trip tank. Fill pipe every 25 stands. Hole took proper displacment. PU wt 182K, SO wt 110k. 16:15 16:45 0.50 12,317 12,375 COMPZ DRILL CIRC P Fill pipe, tag bottom 7' deep, lay down a sin le. TD is 12375'. 16:45 00:00 7.25 12,375 12,375 COMPZ DRILL CIRC P While NaCUKCL VersOut breaker w/ 3%Safelube is being mixed at MI Swaco plant in Deadhorse---Circulate 320 gpm w/ 2050 psi- 34% flow out. Rotate 70 rpm w/ 8k ft Ibs of torque. Max as observed was 180 units. 11 /13/2008 Continue to rotate and reciprocate from 12375' to 12280 while VersaOut breaker is being mixed @ MI mud plant in Deadhorse, pumping 320 gpm w/ 2050 psi, displace well to brine with VersaOut Breaker in open hole, monitor well, trip to 7748', lay down (2) string magnets, crossover and (2) jts of 4" drill pipe to 7656', change handling tools, continue pulling 4" drill pipe to 4450', circulate 9.2 ppg brine above window (PH dropped to 3.9 @ BU-then back up to 7.5), monitor well (cleaned 7 Ibs of iron off magnets), pull out of the hole, lay down cleanout BHA, clean floor, pick up/make up whipstock retieval assembly, run in the hole to 4540', slip and cut drilling line, continue trip to whipstock, wash sloUhook whipstock, circulate bottom's up, pull out of the hole with the whi stock to 3921' midni ht. Losses of 40 bbls /hr. 00:00 03:45 3.75 12,375 12,375 COMPZ DRILL CIRC P While 9.5 ppg, NaCUKCL VersOut breaker w/ 3% Safelube is being mixed at MI Swaco plant in Deadhorse--Continue to circulate 320 gpm w/ 2050 psi- 34% flow out. Rotate 70 rpm w/ 8k ft Ibs of torque. Max gas observed was 180 units, final 13 units. Circulated a total of 4669 bbls. Note: Held prejob safety meeting while circulatin on dis lacement. Page Fi0 of 72 ~ ~ Time Logs Date From To Dur S De th E. De th Phase Code Suhcode T Comment 03:45 04:00 0.25 12,375 12,375 COMPZ DRILL CIRC P Flush surface lines with 9.2 ppg brine. Flush bleeder line, kill line, trip tank line with brine. 04:00 06:30 2.50 12,375 12,375 COMPZ DRILL CIRC P Displace well: Pumped 26 bbls 6.8 ppg LVT, then 63 bbl 9.8 ppg Transition spacer, then 292bb1s 9.2 ppg vicosified brine w! .6%safelube, follow with 334 bbls NACL/KCL VersOut Breaker w/ 3% safelube, follow with 73 bbls 9.2 ppg viscosified brine with .6% safelube. Pumped 6 bpm w/ 1490 psi- 30% flow out. Pumped VersOut @ 5 bpm w/ Rotate 70 rpm w/ 8k ft Ibs of torque. PU wt 175k, SO wt 120k, Rot wt 150k. 06:30 06:45 0.25 12,375 12,220 COMPZ DRILL OWFF P Monitor well, make up a single 5" dril Ipipe, rack back a stand. Blow down the to drive. 06:45 09:15 2.50 12,220 7,748 COMPZ DRILL TRIP P Trip out of the hole on elevators with hole opener/ cleanout assembly on elevators. Monitor well on the trip tank. Record PU and SO wt's every 10 stands. 09:15 09:30 0.25 7,748 7,656 COMPZ DRILL PULD P Lay down (2) string magnets, crossover 4" XT 39 x 4-1/2" IF, (2) 'oints of 4" drill i e. 09:30 09:45 0.25 7,656 7,656 COMPZ DRILL OTHR P Change out handling tools to 4" 09:45 11:30 1.75 7,656 4,450 COMPZ DRILL TRIP P Continue to trip out of the hole with hole opener/ cleanout assembly on elevators. Monitor well on the trip tank. Record PU and SO wt's every 10 stands. 11:30 11:45 0.25 4,450 4,450 COMPZ DRILL OWFF P Monitor well. Prejob safety meeting on circulating 9.2 ppg brine with .6% safelube. 11:45 12:45 1.00 4,453 4,453 COMPZ DRILL CIRC P Circulate 9.2 ppg brine w/ 1.4 safelube.. Pumping 300 gpm w/ 500 psi-31 % flow out. Rotate 30 rpm w/ 2500 ft Ibs of torque. PU wt 130k, SO wt 120k. Note: PH dropped to 3.9 @ bottom's up, then increased to 7.5 shortly after. Loss of 8 bbls while circulatin bottom's u . 12:45 13:00 0.25 4,453 4,453 COMPZ DRILL OWFF P Monitor well. Cleaned approx 7 pounds of metal shavings from ma nets. 13:00 14:15 1.25 4,453 301 COMPZ DRILL TRIP P Continue tripping out with hole o ener/ cleanout assembl . 14:15 15:15 1.00 301 0 COMPZ DRILL PULD P Lay down the hole opener. Monitor well on the trip tank. A total of 18 bbls lost on tri out of the hole. 15:15 15:45 0.50 0 0 COMPZ DRILL OTHR P Clean and clear rig floor. 15:45 17:00 1.25 0 451 COMPZ FISH PULD P Pick up/Make up whipstock retrieval BHA. Remove and clean magnets. Monitor well on the tri tank. P~t~e 61 €~f 7~ i Time Logs Date __ From To Dur _ S De th E. De th Phase Code Subcode T Comment 17:00 18:00 1.00 451 2,546 COMPZ FISH TRIP P Trip in the hole with whipstock retrieval BHA. Fill pipe every 20 stands. Monitor well on the tri tank. 18:00 18:15 0.25 2,546 2,546 COMPZ FISH PULD P Change out a joint of 5"drill pipe bad box . 18:15 19:15 1.00 2,546 4,639 COMPZ FISH TRIP P Continue trip in the hole. Proper dis alcement. 19:15 20:45 1.50 4,639 4,639 COMPZ RIGMN? SVRG P Slip and cut drilling line. Monitor well on the trip tank. 1-1/2 to 2 bph losses while cuttin drillin line.. 20:45 21:45 1.00 4,639 4,639 COMPZ RIGMNT SVRG P Service rig ,top drive and blocks. 21:45 22:00 0.25 4,639 4,678 COMPZ FISH TRIP P Trip in the hole. 22:00 22:30 0.50 4,678 4,670 COMPZ FISH FISH P Obtain parameters. PU wt 167k, SO wt 145k. Wash down to slot pumping 420 gpm w/ 1290 psi- 37% flow out . Work pipe from 4678' to 4681'. Rotate hook a quarter turn right, slack off to 4680' and take weight with hook at the bottom of the slot of the whipstock (pumped a total of 110 bbls). Slacked off 15k, picked up with 20k overpull, then falling off to origninal PU wt of 167k. Slacked back off, tagging up again @ slot (4680'), set down 15k. Pick up to 218k (51k overpull), relase MLZXP anchor. Pickup 10' observed fluid fallin in the BOP stack. Fill hole. 22:30 22:45 0.25 4,670 4,587 COMPZ FISH TRIP P Pull out of the hole two stands bottom of whipstock assembly @ 4587' 22:45 23:15 0.50 4,587 4,587 COMPZ FISH CIRC P Circulate bottom's up +. Pumping 500 gpm w/ 1840 psi- 40% flow out. Lost 74 bph while circulating. On bottom's up 20 units of gas. Circulated a total of 367 bbls Bottom's u 240 bbls . 23:15 23:30 0.25 4,587 4,587 COMPZ DRILL OWFF P Monitor well on the trip tank. Losses are +/- 40 b h. 23:30 00:00 0.50 4,587 3,921 COMPZ FISH TRIP P Pull out of the hole with whipstock assembly. Monitor well on the trip tank. Losses of 29 bph over calculated displacement. _ Note: At 0030 hrs, losses calculated over 35 minutes while pulling pipe (15 stands) are 25 bph over displaement. Losses @ 0300 hrs 31 b h. Page ~2 of 72 ~ ~ Time Logs _ _ Date From To _ Dur S. D~th E. De th Phase Code Subcode T Comment 11/14/2008 24 hr summary Continue to pull out of the hole with the whipstock from 3921' to 490', lay down whipstock BHA and whipstock assembly. Bring tools to floor, rig up GBR to run Seal Bore Diverter, pre job safety meeting, Pickup/Make up/ Orient anchor to Seal Bore offset +/- 10 deg (Diverter Window is 10 deg right of anchor). Run in the hole with Seal Bore Diverter and running in the hole BHA. Run in the hole on 5"drill pipe to 4728', circulate, continue running in to 4756', snap in with 27k, PU 73k over, test seals on anchor isolating holes in the "B" lateral casing seal bore receptacle to 2500 psi, bleed off to 1000 psi, pickup- released from SealBore Diverter. Circulate bottom's up @ 4653', monitor well- static, Pull out of the hole with running tools, lay down Baker running tools ,boot baskets and magnets. clean floor, rig up to run the 3-1/2" screen/blank liner for the "D" lateral, pre job safety meeting. Pickup/make up/ run in the hole with "D" lateral liner per detail, RIH w/ liner on 5"drill pipe to 8127' @ midnight. Note: Losses of 35-40 bbls /hr after pulling whipstock ("B" lateral now open). Losses quit after setting SealBore Diverter. 00:00 01:30 1.50 3,921 490 COMPZ FISH TRIP P Continue to pull out of the hole with whipstock assembly. Monitor well on the trip tank, the hole took 60 bbls over calculated dis lacement. 01:30 04:30 3.00 490 0 COMPZ FISH PULD P Lay down Bottom hole assembly. Verify orientation of whipstock with the anchor, Verify measurements of whipstock assembly. The tracking of the mills on the whipstock indicated the mills walked right somewhat-Lay down tools from the floor. 04:30 05:15 0.75 0 0 COMPZ CASING PUTB P Pick up tools to the rig floor. Rig up GBR. 05:15 05:30 0.25 0 0 COMPZ CASING SFTY P Pre job safety meeting. 05:30 06:00 0.50 0 0 COMPZ CASING OTHR P Clean connections on jewelery items of Seal Bore Diverter, for Baker lock. 06:00 06:45 0.75 0 89 COMPZ CASING PUTB P Pickup the Seal Bore Diverter per detail. Monitor well on the trip tank- 32 b h losses. 06:45 07:45 1.00 89 89 COMPZ CASING OTHR P Orient the face of the Seal Bore Diverter with the MLHR production Anchor. Offset the SealBore Diverter 10 degrees to the right of the Anchor. Note: The "B" lateral MLZXP packer was oriented to 10 degrees left of highside, the tracking of the mills on the whipstock indicated the mills walked right somewhat- therefore the SealBore was oriented to compensate for the righthand walk by 10 degrees. The Sealbore will be set highside when engagedinto collet of MLZXP. 07:45 08:45 1.00 89 544 COMPZ CASING PUTB P Continue to make up running in the hole BHA. Monitor well on the trip tank- 32 BPH losses. 08:45 10:45 2.00 544 4,728 COMPZ CASING RUNL P Run in the hole with the Seal Bore Diverter on 5"drill pipe. Lost a total of 51 bbls on the trip. PU wt 167k, SO wt 142k. 10:45 11:00 0.25 4,728 4,728 COMPZ CASING CIRC P Establish circulation. Shut down um s. gage ~3 of T2 Time Logs_ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:00 11:15 0.25 4,728 4,756 COMPZ CASING RUNL _ P __ Continue to run in the hole. Set down to 115k on the weight indicator (27k set down- collet into the "B" lateral MLZXP packer). Pickup to 240K on the weight indicator (73k overpull), slackoff to 130k on the Wight indicator. Pressure test the seals below the MLHR Production Anchor which are covering the (2) holes in the Casing sealbore receptacle of the "B" lateral- tested against the center of element of the inflatable bridge plug at 4816' in the "B" lateral to 2500 psi. Bleed the pressure to 1000 psi. Pickup to 160k on the weight indicator, then bleed of the pressure to zero. 11:15 11:30 0.25 4,756 4,653 COMPZ CASING RUNL P Pickup 20'- pulling slick stick of diverter running tool out of the seals of the Seal Bore Diverter. Establish circulation. Continue to pickup an additional 20' while circulating. Slick joint @ 4658'--14' above top of the Seal Bore Diverter. 11:30 12:00 0.50 4,653 4,653 COMPZ CASING CIRC P Circulate bottom's up. Pumping 430 gpm w/ 370 psi- 39% flow out. Pum ed a total of 268 bbls. 12:00 12:15 0.25 4,653 4,653 COMPZ CASING OTHR P Monitor well- static. 12:15 13:30 1.25 4,653 455 COMPZ CASING RUNL P Pull out of the hole with running tools. 13:30 14:30 1.00 455 0 COMPZ CASING RURD P Lay down running tools and BHA. Clean ma nets. 14:30 14:45 0.25 0 0 COMPZ CASING OTHR P Clean and clear rig floor. 14:45 15:15 0.50 0 0 COMPZ CASING RURD P Rig up to run the 3-1/2" screen/blank "D" lateral liner. Monitoring well on the tri tank. 15:15 15:30 0.25 0 0 COMPZ CASING SFTY P Pre job safety meeting on running liner. 15:30 18:00 2.50 0 3,163 COMPZ CASING RUNL P Run the "D" lateral 3-1/2" 9.2 ppf L-80 SLHT and Hydril 563 screen blank liner to 3163' (95 jts in the hole . 18:00 22:45 4.75 3,163 7,627 COMPZ CASING RUNL P Continue to run the "D" lateral 3-1/2" 9.2 ppf L-80 SLHT and Hydril 563 screen/blank liner to 3163' (235 jts in the hole). Obtain PU wt's every 15 jts. No obstructions going through window of diverter with shoe 4.98" OD or Freecap swell packers 6.44" OD. Slow down running speed to 40 to 50 ft per minute once liner was in open hole. Loss of 14 bbls of 9.2 ppg brine while runnin in the hole. ~'ag~ 6~ €~f 72 • • Time. Logs Date From To Dur S. De th E. Depth Ph se Code Subcode T Comment 22:45 23:30 0.75 7,627 7,672 COMPZ CASING RUNL P Change elevators to 5" dp. Make up the RAM hanger and ported crossover assembly to the 3-1/2" liner. PU wt with all of liner picked up was 120k u ,slackoff wt 100k. 23:30 00:00 0.50 7,672 8,127 COMPZ CASING RUNL P Make up stand with magnets and boot baskets, lay down a single of 5" drill pipe. Run in the hole with the liner on 4 stands of 5" HWDP 11 /15/2008 Continue to RIH on elevators w/ 3-1/2" 9.2 ppf L-80 SLHT/Hyd 563 blank/screen liner for the "D" lateral on 5" drill pipe from 8127' to 11890', rotate from 11890' to 11920' (30'), run on elevators to 12125', rotate from 12125' to 12160' (35'), run into 12295', wash slot/collet area of the SealBore Diverter with ported sub. Obtain parameters. Confirm depth's-OK, proceed with release of liner --drop 29/32" ball, pressure up, pickup, blow ball seat, pull out of hole leaving a total of 26 stands in the derrick, lay down 5"drill pipe, lay down running tools. Clear floor, lay down 4" drill pipe from derrick. Rig up GBR, pickup/makeup/RIH with 3-1/2" completion tubin to stand back. 111 "oints in the hole midni ht. 00:00 00:15 0.25 8,127 8,220 COMPZ CASING RUNL P Run in the hole with the "D" lateral liner on first stand of 5"drill pipe to 8220'. PU wt 135k, SO wt 115k, Rot wt 125k. Rotate 30 rpm w/ 3500 ft Ibs of for ue. 00:15 05:30 5.25 8,220 12,295 COMPZ CASING RUNL P Continue to run the liner on 5" drill pipe to 12295'. Liner was run on elevators except for rotating @ 11890' to 11920' (30') and again rotating @ 12125' to 12160' (35'). Rotate 30 rpm-Rotating wt 150k with torque limit set @ 9000 ft Ibs, torque of 7-8k ft Ibs.. Obtain PU and SO wt's evety 5 stands. Note: Loss of 31 bbls while runnin liner. 05:30 06:00 0.50 12,295 12,336 COMPZ CASING CIRC P Break circulation @ 12295' to 12307 and wash collet slot with ported sub. Pumping 5 bpm w/ 360 psi- 23 flow out.PU wt 185k, SO wt 125k, Rotating wt 155k with 30 rpm and 9k ft Ibs of torque. Slack off locate into collet, set down to 75k on weight indicator. With shoe @ 12336', collet into SealBore Diverter @ 4670.70' (21' in on a single drill pipe). Pickup to 210k and snap out of collet. Set back down to 75k on weight indicator- again 21' in on single of drill pipe. Pickup to 185k (25k overpull @ collet) to verify latched in). Note:Observed bumper sub travel @ 160k PU wt.and 142k slackoff wt, therefore 25k overpull at collet = 185k on weight indicator. Also, 75k overpull = 160k + 75 = 235k on wei ht indicator. ~~~~ 6~ csf ~~ Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment ~ 06:00 07:00 1.00 12,336 4,650 COMPZ CASING CIRC P Break connection and drop Baker 29/32" ball to release running tool. Pump down @ 160 gpm w/ 210 psi-19% flow out. Slow the pumps to 110 gpm w/ 120 psi- 14% flow out after purring 500 strokes. Ball on seat after pumping 580 strokes. Pressure up to 3000 psi, bleed to zero. Pull out of the hole with liner running tools to above liner. Pressure up to 4300 psi with test pump to blow ball seat. 07:00 07:15 0.25 4,650 4,650 COMPZ DRILL OWFF P Monitor well- static. 07:15 07:45 0.50 4,650 2,760 COMPZ DRILL TRIP P Pull out of the hole, stand back 5" drill i e. 07:45 09:45 2.00 2,760 492 COMPZ DRILL TRIP P Continue to pull out of the hole, laying down 5"drill pipe. Monitor well on the trip tank.. Hole took 4 bbls over calculated. 09:45 11:15 1.50 492 0 COMPZ DRILL PULD P Lay down liner running BHA. Monitor well on the tri tank. 11:15 12:00 0.75 0 0 COMPZ DRILL OWFF P Clean and clear rig floor. of liner running tools. Monitor well on the trip tank. 12:00 13:30 1.50 0 0 COMPZ DRILL PULD P Lay down 6 flex collar, 3 HWDP from derrick. Lay down misc subs for ins ection. 13:30 18:45 5.25 0 0 COMPZ DRILL PULD P Lay down 237 joints (79 stands) of 4" drill i e from the derrick. 18:45 19:15 0.50 0 0 COMPZ RPCOM RURD P Bring tools to the rig floor for 3-1/2" 9.2 ppf L-80 IBT tubing. Unloading 4" drill pipe from pipe shed. Rig up GBR ton s. 19:15 19:30 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on picking up tubing, running in the hole, then pull out- stand back on the Off Driller's Side for the main wellbore. 19:30 20:15 0.75 0 0 COMPZ RPCOM PULD P Pick up/ makeup jts # 151 to #156, stand back in the derrick on the off driller's side. These will be stand # 51 and # 52 for the main well bore. 20:15 00:00 3.75 0 3,423 COMPZ RPCOM TRIP P Pickup/makeup/RIH with 3-1/2 9.2 ppf L-80 IBT-m. One hundred 111 joints picked up and run in the hole midni ht. 11/16/2008 Continue to pickup/makeup/ RIH with 3-1 /2" completion tubing to stand back from 111 joints to 150 jts, bring completion jewery to the floor, POOH stand back tubing on driller's side (Main bore)/ changing seal rings, make up 9 jts RIH, stand back on off driller's side for L1 ("D" lateral), RIH w/ 150 jts, POOH stand back on off driller's side ("D" lateral). rig down GBR casing tools. Pull wear bushing, install Vetco Gray test plug, change upper pipe rams (9-5/8") and lower pipe rams (3-1 /2" x 6" variables) to 3-1/2"dual rams for both upper and lower. Rig up, test to 250 psi low and 3000 psi high test 4" floor safety valve to 250 psi low and 3000 psi high, rig down testing equipment, pull test plug. Rig up to run the 3-1/2"dual completion: Remove link tilt from short bales, remove short bales, install long bales, install link tilt on long bales. Install dual elevators test and adjust link tilt for the derrick board. Make up crossovers on two floor safety valves to 3-1 /2"IBT. Adjust air lines on the elevators. Function test elevators. Ri down dual elevators and install sin le 't 3-1/2"elevators. ~s- F'az~e f6 of T2 • Time Low Date From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 3,423 4,628 COMPZ RPCOM TRIP P Pickup/makeup/RIH with 3-1/2" 9.2 ppf L-80 IBT-m. Run from 111 joints to 150 joints. Monitor well on the trip tank. Loss of 10 bbls on trip in the hole. 01:00 02:00 1.00 4,628 4,628 COMPZ RPCOM PULD P Rig up floor to pull out of the hole and stand back tubing. Bring completion 'ewle to the floor. 02:00 04:45 2.75 4,628 0 COMPZ RPCOM TRIP P Pull out of the hole with the 3-1/2" 9.2 ppf L-80 IBT-m tubing. Replace seal rings in the joints. Rack back for the main bore on the off driller's side. Loss of 12 bbls on tri out. 04:45 05:00 0.25 0 279 COMPZ RPCOM PULD P Rig up to pickup/ makeup/RIH with 9 'oints of tubin . 05:00 05:30 0.50 279 0 COMPZ RPCOM TRIP P Pull out of the hole 3 stands and rack on the driller's side for the L1 "D" lateral . 05:30 10:00 4.50 0 4,602 COMPZ RPCOM TRIP P Pickup/makeup/ run in the hole with 150 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing. Monitor well on the tri tank. 4 bbl loss. 10:00 13:00 3.00 4,602 0 COMPZ RPCOM TRIP P Pull out of the hole with the 3-1/2" 9.2 ppf L-80 IBT-m tubing. Replace seal rings in the joints. Rack back for the L1 ("D" lateral) on the driller's side. 13:00 13:15 0.25 0 0 COMPZ RPCOM RURD P Rig down GBR tools. 13:15 13:45 0.50 0 0 COMPZ WELCTL OTHR P Pull Vetco Gray wear bushing, install test lu . 13:45 15:45 2.00 0 0 COMPZ WELCTL OTHR P Change upper pipe rams from 9-5/8" to 3-1/2"dual rams, change lower pipe rams from 3-1 /2" x 6" variables to 3-1/2"dual rams. Keeping hole full under the test plug with charge um . 15:45 16:30 0.75 0 0 COMPZ WELCTL OTHR P Remove 5" test joint. 16:30 17:15 0.75 0 0 COMPZ WELCTL OTHR P Rig up to test upper and lower 3-1/2" dual rams. 17:15 19:30 2.25 0 0 COMPZ WELCTL BOPE P Test upper and lower rams to 250 psi low and 3000 psi high. Hold each test for 5 minutes. Test another 4" floor safety valve to 250 psi and 3000 si hi h, hold each test 5 minutes. 19:30 20:00 0.50 0 0 COMPZ WELCTL OTHR P Rig down testing equipment. Pull the test lu . Page 57 of 72 • Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Cortiment 20:00 00:00 4.00 0 0 COMPZ RPCOM RURD P Rig up to run the 3-1 /2"dual completion. Remove linkage for the link tilt on the top drive. Remove short bales, install long bales. Install link tilt to the long bales. Install dual elevators, adjust link tilt for the derrick board. Makeup two crossovers for the floor safety valves to 3-1/2" IBT. Make a dummy run past the board and rig up the air lines in the derrick for the elevators. Function test elevators. Rig down dual elevators, install single joint elevators. 11 /17/2008 Pre job safety meeting on running 3-1/2"dual completion. ,run completion to collet profile in the Ram hanger @ 4665.67' (by tubing tally 4666.94'). snap in ,set down 10k, snap out with 19k overpull. Pull out of the hole, stand back a stand from each side. Space out. bring pups to the floor, lubricate rig, prepare to freeze protect in the cellar. Claean pits and drip pans. Note: Spaced put from 1400 hrs to 1600 hrs. Alignment guide on hanger was noticed to be not orientated correctly. Hanger taken to Baker machine shop to have another alignment guide milled into the hanger. Hanger back on rig floor @ 2100hrs. Held pre job safety meeting on makeup of Vetco/Gray hanger. Spot 32 bbls of corrosion inhibited brine to the annulus- chased with 50.7 bbls. Make up hanger to main bore, then make up to L1 ("D lateral), install top late on han er midni ht. 00:00 00:30 0.50 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on running dual completion (3-1/2" 9.2 ppf L-80 IBT-m) with Baker RAM Dual Seal Module. 00:30 04:00 3.50 0 125 COMPZ RPCOM RCST P Pickup Baker equipment to the floor and make up to the "GT' Dual Packer. 04:00 05:00 1.00 125 395 COMPZ RPCOM RCST P Run completion out of the derrick-3 stands each side. 05:00 05:15 0.25 395 407 COMPZ RPCOM RCST P Install 3-1/2" KBG-2-9 GLM assembly with DCK-3 2000 psi casing to tubing shear valve on the main bore side. Install Baker CMD sliding sleeve assembly with 2.813" rofile on the L-1 side. 05:15 06:00 0.75 407 650 COMPZ RPCOM RCST P Continue to run in the hole with tubing from the derrick. Obtain PU and SO wt's every 6 stands, Balance string every 6 stands. Note: Fluid losses are 5 b h. 06:00 07:00 1.00 650 650 COMPZ RPCOM SFTY P Crew change/Pre job safety meeting on running dual completion (3-1 /2" 9.2 ppf L-80 IBT-m) with Baker RAM Dual Seal Module. 07:00 12:00 5.00 650 4,205 COMPZ RPCOM RCST P Run completion from the derrick. Obtain PU and SO wt's every 6 stands, Balance string every 6 stands. 12:00 13:45 1.75 4,205 4,667 COMPZ RPCOM RCST P Continue to run completion from the derrick. Obtain PU and SO wt's every 6 stands, Balance string every 6 stands. Note: Fluid losses 3 to 4 b h. €~~~~ &$ asf 7~ • Time Logs Date From To Dur S De th E. De th Ph se Code Subcode T Comment 13:45 14:00 0.25 4,679 4,602 COMPZ RPCOM RCST P Tagged collet of the Ram Dual Seal Module @ 4666.94' tubing measurements (4665.67' "D" lateral liner measurements) (1.27' deeper on tubing tally). PU wt 139k, SO wt 121 k. Set down 10k with collet. Pick up with 19k overpull to snap out (158k). Pull out of the hole to space out for the hanger and Dual Seal Module. 14:00 16:00 2.00 4,602 4,654 COMPZ RPCOM HOSO P Obtain measurements for the spaceout. Bring pups to the floor. Make up pups and a single on each side. On the Main well bore- need 73.80'+20'-RKB of 36.31' travel-3.15 pup-1.49' hanger= 52.85'. Will use 2.06' pup, then a 9.84' pup, then a 9.83 pup and a joint above the pups with a length of 31.12' below hanger = 52.85' On L1 side ("D" lateral we need 73.61'+20'travel- RKB of 36.31'- 5.12' pup- 1.49' hanger body = 50.69'. Will use 3.65' pup, then a 7.80' pup, then a 7.80 pup and a joint above the pups with a length of 31.45' below han er = 50.70' 16:00 17:00 1.00 4,654 4,654 COMPZ RIGMNT SVRG P Lubricate rig. 17:00 18:00 1.00 4,654 4,654 COMPZ RPCOM RURD P Rig up in the cellar for pumping freeze protection while Vetco Gray ahnger is being taken to Baker Machine shop for a slot milled for orientation. 18:00 21:00 3.00 4,654 4,654 COMPZ RPCOM WOEQ T Waiting on hanger to be machined at Baker Oil Tools. 21:00 21:15 0.25 4,654 4,654 COMPZ RPCOM SFTY P Pre job safety meeting on making up han er. 21:15 22:30 1.25 4,654 4,654 COMPZ RPCOM CIRC P Pumped 32 bbls of inhibited brine, displace with 50.7 bbls of 9.2 ppg brine to spot in the annulus. Pumpe down the L1, pumping 3 bpm w/ 110 si-14% flow out. 22:30 00:00 1.50 4,654 4,654 COMPZ RPCOM HOSO P Make up pup on main bore hanger, make up pup on L1 hanger, attatch to late to the han er. 11 /18/2008 Run dual tubing string to TD. Observed RAM Dual Seal Module collet engage Ram hanger profile on depth and sheared free of the Dual Seal Module with the seal assembly's, tagged and sheared seal assembly shroud, continued to run and land hanger in wellhead. Run in lockdown screws and tested hanger body seals. Installed two way checks and tested upper seals on hanger. Pressure tested seals in the casing seal bore recepticle "B" lateral and seals of the sealbore diverter of "B" lateral and IBP in "B" lateral liner. Attempted to set Baker "GT' packer. Annulus would not hold pressure. Rigged up wireline to check sliding sleeve and "D" lateral tubin .Set lu in mainbore, "B" lateral, tubin and continued attemts to set aaker. ,~.: ,. 69 of T2 l I C~ Time Logs _ __ Date From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 01:00 1.00 4,654 4,654 COMPZ RPCOM HOSO P Finish attatching top plate to the Vetco Gray hanger. Make up landing 'oints. PU wt 140k, SO wt 123k. 01:00 02:00 1.00 4,654 4,691 COMPZ RPCOM HOSO P RIH, observe RAM Dual Seal Module collet engage Ram hanger profile on depth (4665.67' liner tally), pull 10k over, set down 33k and sheared free of the Dual Seal Module with the seal assembly's, continued to come down and tagged and sheared seal assembly shroud (15k down), continued to run 2.5' and land hanger in wellhead 02:00 02:45 0.75 4,691 4,691 COMPZ RPCOM OTHR P Run in lockdown screws, torque 600 ft lbs. Test hanger body seals to 5000 si for 10 minutes. 02:45 04:00 1.25 4,691 4,691 COMPZ RPCOM DHEQ P Pull landing joints, install two way checks. Test upper seals on hanger to 5000 psi for 10 minutes to 5000 psi. Used the blinds and HCR choke line. 04:00 05:00 1.00 4,691 4,691 COMPZ RPCOM OTHR P Drain stack, pull two way check on the main bore. 05:00 05:15 0.25 4,691 4,691 COMPZ RPCOM OTHR P Close blind rams and pressure test the seals which are across the holes in the casing seal bore recepticle "B" lateral and seals of the sealbore diverter of "B" lateral and IBP in "B" lateral liner to 1000 psi. Pressure held 05:15 06:00 0.75 4,691 4,691 COMPZ RPCOM PACK P Continue pressuring up to 2500 psi to set the Baker "GT" packer, hold for 15 minutes. Bleed tubing to 1500 psi and attempt to pressure annulus (testing "GT' packer) to 2500. Packer not holdin ressure 06:00 07:00 1.00 4,691 4,691 COMPZ RPCOM PACK T Grease and function valves. Retest acker, no ood not holdin ressure 07:00 07:30 0.50 4,691 4,691 COMPZ RPCOM PACK T Continue trying to set packer. Pressure up to 4000 psi on mainbore then bleed down to 1500 psi. Pump into annulus at 2 bpm to test packer. Could not build pressure. Pumped 5 bbls awa . 07:30 08:30 1.00 4,691 4,691 COMPZ RPCOM PACK T Bleed tubing pressure to 0 psi, drain stack and pull two way check valve from "D" lateral tubin strip . 08:30 08:45 0.25 4,691 4,691 COMPZ RPCOM PACK T Pump 2 bpm down annulus and observed returns coming up thru "D" lateral tubin . 08:45 12:00 3.25 4,691 4,691 COMPZ RPCOM SLKL T Drain stack and make up landing joint to "D" lateral tubing string. Rig down dual elevators and rig up wireline sheave. RIH with wireline to work slidin sleeve. 12:00 12:30 0.50 4,691 4,691 COMPZ RPCOM SLKL T Work sliding sleeve to insure it is closed. ?;;~_~:• 7i~ of 72 • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 12:30 12:45 0.25 4,691 4,691 COMPZ RPCOM PACK T _ __ Attempt to test packer by pressuring up on annulus, won't hold pressure. POOH with wireline. 12:45 14:45 2.00 4,691 4,691 COMPZ RPCOM SLKL T RIH with plug for D nipple in "D" lateral. Set plug and pressure up to 2500 psi and hold for 15 minutes. Pump down annulus to test packer. no ood still won't hold ressure. 14:45 15:30 0.75 4,691 4,691 COMPZ RPCOM SLKL T POOH with wireline and plug. Rig down wireline. 15:30 16:00 0.50 4,691 4,691 COMPZ WELCTL OTHR T Laydown landing joint and rig up to test BOPE. 16:00 18:45 2.75 4,691 4,691 COMPZ RPCOM SLKL T Pick up landing joint and rig up wireline. RIH with wireline to set plug in DS nipple in mainbore, "B" lateral. Pressure up to 650 psi. POOH with wireline. Plu did not set. 18:45 19:15 0.50 4,691 4,691 COMPZ RPCOM SLKL T Redress slickline plug setting tool. 19:15 21:00 1.75 4,691 4,691 COMPZ RPCOM SLKL T RIH with plug on wireline to DS nipple in mainbore and set plug. POOH, tattle tales indicate lu set. 21:00 00:00 3.00 4,691 4,691 COMPZ RPCOM PACK T Pressure up on mainbore tubing to 2500 psi and hold for 30 minutes to set packer. Pump down annulus to test packer. Packer not set, getting returns thru "D" lateral tubing. Continue pressuring mainbore tubing and pumping down annulus. Surge mainbore tubing working pressure to 4000 psi in attempt to set packer. Packer still not settin 11/19/2008 Set packer and tested. Nipple down BOP stack and nipple up tree. Freeze protect tubing strings and annulus. Set back ressure valves in tubin strip s. Released ri at 22:00. 00:00 01:00 1.00 4,691 4,691 COMPZ RPCOM PACK T Pressure up on mainbore tubing to 4600 psi and hold for 5 minutes to set packer. Pressure up on annulus to 1000 psi. Pressure holding. Bleed annulus to 0 psi and tubing to 1500 psi. Pressure up annulus to 2500 psi and hold for 30 minutes. Pressure held. Bleed off annulus then tubin . 01:00 01:30 0.50 0 0 COMPZ RPCOM SLKL T Rig down slickline 01:30 01:45 0.25 0 0 COMPZ RPCOM RURD P Lay down landing joint and blow down lines. 01:45 02:15 0.50 0 0 COMPZ RPCOM OTHR P Install two way check valves. 02:15 02:45 0.50 0 0 COMPZ RPCOM SFTY P PJSM -nipple down BOP stack. 02:45 06:00 3.25 0 0 COMPZ RPCOM NUND P Nipple down BOP stack. 06:00 08:00 2.00 0 0 COMPZ RPCOM NUND P Nipple up tree per Vetco reps. 08:00 08:30 0.50 0 0 COMPZ RPCOM DHEO P Rig up and test void with 5000 psi for 10 minutes. Good test 08:30 11:00 2.50 0 0 COMPZ RPCOM DHEQ P Rig up and test tree, D-Lat and B-Lat, 250 psi low and 5000 psi high. Good test. gage 71 0~ ~2 ~J Time Logs date From To Dur S De th E. De th Phase Code Subcode T Comment 11:00 11:45 0.75 0 0 COMPZ RPCOM OTHR P Pull two way check valves. 11:45 12:00 0.25 0 0 COMPZ RPCOM FRZP P Rig up Little Red for freeze protecting tubin and annulus. 12:00 16:30 4.50 0 0 COMPZ RPCOM FRZP P Shear out valve in mainbore gas lift mandrel and pump 267 bbls of diesel taking returns up mainbore tubing. Initial circulating pressure 600 psi, final circulating pressure 475 psi. Sim ops -lay down 9 stands of tubing from derrick. lay down long bails. 16:30 17:30 1.00 0 0 COMPZ RPCOM FRZP P Rig up Little Red on D-Lat tubing and bullhead 22 bbls of diesel at 2 bpm. Initial injection pressure 1200 psi. Reduce rate to 1.5 bpm. Final injection ressure 900 si. 17:30 21:00 3.50 0 0 COMPZ RPCOM OTHR P Pick up and make up lubricator. Set backpressure valve in B-Lattubing. Rotate treecap 90 degrees and install BPV in D-Lattubing. Tested breaks to 5000 psi for 10 minutes. Shut-in tubing pressure B-Lat 250 psi, D-Lat 0 psi. Outer annulus 200 psi, inner annulus 0 psi. Sim ops - re for ri move. 21:00 22:00 1.00 0 0 COMPZ RPCOM OTHR P Clean cellar box, rockwasher and its. Ri Released at 22:00 f~ar~e ~2 of 72 • ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103 Permit to Drill 208-115 API 50-029-23392-00 Definitive Survey Report 15 December, 2008 ~. .: . .:~... ~,~tirry t',~riftr~~ ~eruiCBSt Company: ConocoPhiliips(Alaska) Inc Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103 Design: 3K-103 • ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: We113K-103 (E14) ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor --___ j Well 3K-103 (E14) Well Position +N/S 0.0 ft Northing: 6,007,879.03ft Latitude: 70° 25' 57.374 N +E/-W 0.0 ft Easting: 529,305.30 ft Longitude: 149° 45' 40.019 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 33.8ft Wellbore 3K-103 Magnetics Model Name Sample Date BGGM2007 10/20/2008 Design 3K-103 Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (ND) lft) I 40.8 Declination Dip Angle Field Strength 22.52 80-90 57.649 ACTUAL Tie On Depth: 5,395.3 +N/-S +E/-W Direction tft} (ft) (°) o.o o.o sa.oo Survey Program Date From To (ft) (ft) Survey (Wellbore) Too{ Name Description 50.0 621.0 3K-103PB1 SRG (3K-103PB1) GB-GYRO-SS Gamera based gyro single shot 672.5 2,862.2 3K-103PB7 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,925.0 5,395.3 3K-103P63 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,453.0 12,411.0 3K-103 MWD Back Correction 2008-11-(MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Date 9/23/2008 1: 10/31/2008 10!31 /2008 10/30/2008 Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +El-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.8 0.00 ~ 0.00 X10.8 -33.8 0.0 0.0 6,007,879.0' 525,305.3 0.0 U.00 UNDEFINED 50.0 0.20 73.45 50.0 -24.6 0.0 0.0 6,007,879.0 529,305.3 2.2 0.02 CB-GYRO-SS (1) 110.0 0.41 199.34 110.0 35.4 -0.2 0.0 6,007,878.9 529,305.3 0.9 0.04 CB-GYRO-SS (1) 170.0 0.46 75.98 170.0 95.4 -0.3 0.2 6,007,878.7 529,305.5 1.3 0.21 CB-GYRO-SS (1) 265.0 3.37 53.09 264.9 190.3 1.5 2.8 6,007,880.5 529,308.1 3.1 2.81 CB-GYRO-SS (1) 354.0 5.18 54.28 353.7 279.1 5.4 8.2 6,007,884.4 529,313.4 2.0 8.16 CB-GYRO-SS (1) 451.0 6.64 60.62 450.2 375.5 10.7 16.6 6,007,889.8 529,321.9 1.6 16.61 CB-GYRO-SS (1) 541.0 9.92 63.78 539.2 464.6 16.7 28.1 6,007,895.8 529,333.3 3.7 28.10 CB-GYRO-SS (1) 621.0 12.00 68.96 617.8 543.1 22.7 42.0 6,007,901.9 529,347.3 2.9 42.04 CB-GYRO-SS (1) 672.5 13.32 65.33 668.0 593.4 27.1 52.4 6,007,906.3 529,357.6 3.0 52.43 MWD+IFR-AK-CAZ-SC (2) 765.5 16.96 64.65 757.8 683.2 37.4 74.4 6,007,916.7 529,379.6 3.9 74.44 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:14:24PM Page 2 COMPASS 2003.16 Build 42F C onocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Refer ence: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.tift (D15 (33.8+40.82)) Site: 3K-Pad MD Refere nce: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True W®Ilbore: 3K-103 Survey Ca lculation Method: Minimu m Curvature Design: 3K-103 Database: GPAI E DM Production Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E!-W Northing Easting DLS Section Itt) 1~) (~) (ft) (ft) (ft) (ft) (n) (ft) (°11 00') (it) Survey Tool Name ' o6a.5 18.39 80.88 851.1 7%6.5 51.0 100.8 6,007,930.4 .529,405.9 1.5 100.04 MWD+IFR-i~h-Ci;Z-SC (2) 957.8 20.90 58.49 939.9 865.3 67.1 128.2 6,007,946.6 529,433.2 2.8 128.19 MWD+IFR-AK-CAZ-SC (2) 1,053.8 23.56 54.34 1,028.8 954.2 87.2 158.4 6,007,966.8 529,463.3 3.2 158.38 MWD+IFR-AK-CAZ-SC (2) 1,148.4 22.84 49.94 1,115.8 1,041.2 110.0 187.8 6,007,989.8 529,492.7 2.0 187.81 MWD+IFR-AK-CAZ-SC (2) 1,243.1 24.69 45.02 1,202.4 1,127.8 135.8 215.9 6,008,015.7 529,520.6 2.9 215.86 MWD+IFR-AK-CAZ-SC (2) 1,339.0 27.02 43.45 1,288.7 1,214.1 165.8 245.0 6,008,045.8 529,549.6 2.5 245.03 MWD+IFR-AK-CAZ-SC (2) 1,433.5 31.02 39.31 1,371.4 1,296.8 200.3 275.2 6,008,080.4 529,579.7 4.7 275.23 MWD+IFR-AK-CAZ-SC (2) 1,529.2 33.23 38.66 1,452.4 1,377.8 239.8 307.2 6,008,120.0 529,611.5 2.3 307.22 MWD+IFR-AK-CAZ-SC (2) 1,624.9 37.85 38.27 1,530.2 1,455.6 283.4 341.8 6,008,163.7 529,646.0 4.8 341.80 MWD+IFR-AK-CAZ-SC (2) 1,720.6 38.45 39.07 1,605.5 1,530.9 329.5 378.8 6,008,210.0 529,682.7 0.8 378.77 MWD+IFR-AK-CAZ-SC (2) 1,814.3 38.90 39.88 1,678.7 1,604.0 374.7 416.0 6,008,255.4 529,719.8 0.7 415.99 MWD+IFR-AK-CAZ-SC (2) 1,910.5 39.26 39.69 1,753.4 1,678.7 421.4 454.8 6,008,302.1 529,758.4 0.4 454.80 MWD+IFR-AK-CAZ-SC (2) 2,005.8 40.31 41.17 1,826.6 1,752.0 467.8 494.4 6,008,348.7 529,797.8 1.5 494.36 MWD+IFR-AK-CAZ-SC (2) 2,101.3 41.64 41.34 1,898.7 1,824.1 514.8 535.6 6,008,395.9 529,838.9 1.4 535.64 MWD+IFR-AK-CAZ-SC (2) 2,196.1 43.61 37.77 1,968.4 1,893.8 564.3 576.5 6,008,445.6 529,879.5 3.3 576.48 MWD+IFR-AK-CAZ-SC (2) 2,290.7 42.97 34.08 2,037.3 1,962.7 616.8 614.6 6,008,498.2 529,917.4 2.8 614.55 MWD+IFR-AK-CAZ-SC (2) 2,386.6 44.84 35.12 2,106.4 2,031.8 671.6 652.3 6,008,553.1 529,954.9 2.1 652.30 MWD+IFR-AK-CAZ-SC (2) 2,481.6 43.66 35.54 2,174.4 2,099.8 725.6 690.6 6,008,607.3 529,993.0 1.3 690.64 MWD+IFR-AK-CAZ-SC (2) 2,576.8 42.74 35.94 2,243.8 2,169.2 778.5 728.7 6,008,660.3 530,030.9 1.0 728.70 MWD+IFR-AK-CAZ-SC (2) 2,625.3 41.50 36.29 2,279.8 2,205.2 804.8 747.9 6,008,686.7 530,049.9 2.6 747.89 MWD+IFR-AK-CAZ-SC (2) 2,672.1 40.62 35.91 2,315.1 2,240.4 829.6 766.0 6,008,711.6 530,067.9 2.0 765.96 MWD+IFR-AK-CAZ-SC (2) 2,727.0 41.13 34.51 2,356.6 2,282.0 859.0 786.7 6,008,741.0 530,088.5 1.9 786.69 MWD+IFR-AK-CAZ-SC (2) 2,766.7 41.29 33.17 2,386.5 2,311.8 880.7 801.3 6,008,762.8 530,103.0 2.3 801.25 MWD+IFR-AK-CAZ-SC (2) 2,862.2 42.54 33.44 2,457.6 2,382.9 934.0 836.3 6,008,816.3 530,137.8 1.3 836.31 MWD+IFR-AK-CAZ-SC (2) 2,925.0 43.74 32.98 2,503.4 2,428.7 970.0 859.8 6,008,852.3 530,161.2 2.0 859.81 MWD+IFR-AK-CAZ-SC (3) 2,983.4 40.73 32.87 2,546.6 2,472.0 1,002.9 881.2 6,008,885.3 530,182.4 5.2 881.15 MWD+IFR-AK-CAZ-SC (3) 3,035.7 40.60 34.12 2,586.3 2,511.7 1,031.3 900.0 6,008,913.8 530,201.1 1.6 899.96 MWD+IFR-AK-CAZ-SC (3) 3,078.6 41.31 34.30 2,618.7 2,544.1 1,054.6 915.8 6,008,937.1 530,216.8 1.7 915.78 MWD+IFR-AK-CAZ-SC (3) 3,129.7 42.18 35.07 2,656.8 2,582.2 1,082.5 935.1 6,008,965.1 530,236.1 2.0 935.11 MWD+IFR-AK-CAZ-SC (3) 3,173.5 42.07 34.76 2,689.3 2,614.6 1,106.6 951.9 6,008,989.3 530,252.8 0.5 951.92 MWD+IFR-AK-CAZ-SC (3) 3,223.7 43.23 36.23 2,726.2 2,651.6 1,134.4 971.7 6,009,017.1 530,272.4 3.0 971.70 MWD+IFR-AK-CAZ-SC (3) 3,268.4 43.75 37.35 2,758.6 2,684.0 1,159.0 990.1 6,009,041.8 530,290.8 2.1 990.12 MWD+IFR-AK-CAZ-SC (3) 3,318.6 45.07 39.09 2,794.5 2,719.9 1,186.6 1,011.9 6,009,069.5 530,312.4 3.6 1,011.86 MWD+IFR-AK-CAZ-SC (3) 3,363.5 45.85 40.87 2,826.0 2,751.4 1,211.1 1,032.4 6,009,094.0 530,332.8 3.3 1,032.40 MWD+IFR-AK-CAZ-SC (3) 3,414.1 46.24 44.05 2,861.1 2,786.5 1,237.9 1,057.0 6,009,121.0 530,357.3 4.6 1,056.98 MWD+IFR-AK-CAZ-SC (3) 3,459.3 45.87 45.43 2,892.5 2,817.9 1,261.1 1,079.9 6,009,144.2 530,380.1 2.3 1,079.89 MWD+IFR-AK-CAZ-SC (3) 3,508.6 45.94 47.12 2,926.8 2,852.2 1,285.5 1,105.5 6,009,168.8 530,405.6 2.5 1,105.48 MWD+IFR-AK-CAZ-SC (3) 3,554.1 46.35 49.08 2,958.4 2,883.7 1,307.5 1,129.9 6,009,190.8 530,430.0 3.2 1,129.94 MWD+IFR-AK-CAZ-SC (3) 3,604.0 48.00 51.76 2,992.2 2,917.6 1,330.7 1,158.1 6,009,214.2 530,458.1 5.1 1,158.12 MWD+IFR-AK-CAZ-SC (3) 3,648.8 49.11 53.85 3,021.9 2,947.3 1,351.0 1,184.9 6,009,234.6 530,484.7 4.3 1,184.86 MWD+IFR-AK-CAZ-SC (3) 12/95/2008 1:14:24PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-o rdinaie Reference: We113K-103 (E14) Project: Kuparuk River Unit TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Refe rence: True Wellbore: 3K-103 Survey Cal culation Method: Minimum Curvature Design: 3K-103 Database: CPAI E DM Production ~ Survey - - - ~ Map Map Vertical MD Inc Azi TVD TVDSS +N/S +EI-W Northing Easting DL5 Section Iftl (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°11 00') (ft) Survey Tool Name 3,701.5 50.92 56.05 3,055.8 2,581.2 1,374.2 1,217.9 6,009,257.9 530,517.7 4.7 1,217.91 MWD+IFR-AK-CAZ-SC (3) 3,744.4 50.48 57.62 3,082.9 3,008.3 1,392.4 1,245.7 6,009,276.2 530,545.4 3.0 1,245.72 MWD+IFR-AK-CAZ-SC (3) 3,794.4 51.10 59.30 3,114.6 3,039.9 1,412.7 1,278.8 6,009,296.6 530,578.4 2.9 1,278.75 MWD+IFR-AK-CAZ-SC (3) 3,838.6 52.56 60.86 3,141.8 3,067.2 1,430.0 1,308.8 6,009,314.0 530,608.4 4.3 1,308.83 MWD+IFR-AK-CAZ-SC (3) 3,893.7 54.65 62.71 3,174.5 3,099.9 1,450.9 1,347.9 6,009,335.1 530,647.4 4.7 1,347.91 MWD+IFR-AK-CAZ-SC (3) 3,933.5 56.54 64.14 3,197.0 3,122.4 1,465.6 1,377.3 6,009,349.9 530,676.7 5.6 1,377.29 MWD+IFR-AK-CAZ-SC (3) 3,983.5 58.77 67.62 3,223.8 3,149.2 1,482.8 1,415.8 6,009,367.3 530,715.1 7.4 1,415.82 MWD+IFR-AK-CAZ-SC (3) 4,028.2 60.93 69.77 3,246.3 3,171.6 1,496.9 1,457.9 6,009,381.5 530,751.1 6.4 1,451.87 MWD+IFR-AK-CAZ-SC (3) 4,078.4 62.54 72.12 3,270.0 3,195.4 1,511.3 1,493.7 6,009,396.1 530,792.9 5.2 1,493.66 MWD+IFR-AK-CAZ-SC (3) 4,123.8 62.53 73.97 3,291.0 3,216.4 1,523.1 1,532.2 6,009,408.0 530,831.4 3.6 1,532.20 MWD+IFR-AK-CAZ-SC (3) 4,174.4 63.87 75.80 3,313.8 3,239.2 1,534.8 1,575.8 6,009,419.9 530,874.9 4.2 1,575.82 MWD+IFR-AK-CAZ-SC (3) 4,221.2 65.82 77.82 3,333.7 3,259.0 1,544.5 1,617.0 6,009,429.7 530,916.1 5.7 1,617.00 MWD+IFR-AK-CAZ-SC (3) 4,271.6 67.64 79.77 3,353.6 3,279.0 1,553.5 1,662.5 6,009,438.9 530,961.5 5.1 1,662.46 MWD+IFR-AK-CAZ-SC (3) 4,313.9 68.89 80.68 3,369.2 3,294.6 1,560.1 1,701.1 6,009,445.7 531,000.1 3.6 1,701.13 MWD+IFR-AK-CAZ-SC (3) 4,367.9 71.82 83.24 3,387.4 3,312.8 1,567.3 1,751.5 6,009,453.0 531,050.5 7.0 1,751.54 MWD+IFR-AK-CAZ-SC (3) 4,410.6 73.89 84.71 3,400.0 3,325.4 1,571.5 1,792.1 6,009,457.4 531,091.0 5.9 1,792.05 MWD+IFR-AK-CAZ-SC (3) 4,461.4 76.71 87.08 3,412.9 3,338.3 1,575.0 1,841.1 6,009,461.1 531,140.0 7.1 1,841.11 MWD+IFR-AK-CAZ-SC (3) 4,505.5 78.02 88.98 3,422.5 3,347.9 1,576.5 1,884.0 6,009,462.8 531,183.0 5.2 1,884.05 MWD+IFR-AK-CAZ-SC (3) 4,556.0 78.98 90.82 3,432.6 3,358.0 1,576.6 1,933.5 6,009,463.1 531,232.4 4.0 1,933.53 MWD+IFR-AK-CAZ-SC (3) 4,601.1 79.49 91.25 3,441.0 3,366.4 1,575.8 1,977.8 6,009,462.4 531,276.7 1.5 1,977.82 MWD+IFR-AK-CAZ-SC (3) 4,652.4 80.02 92.20 3,450.1 3,375.5 1,574.3 2,028.3 6,009,461.1 531,327.2 2.1 2,028.27 MWD+IFR-AK-CAZ-SC (3) 4,696.2 80.69 91.72 3,457.5 3,382.9 1,572.8 2,071.5 6,009,459.8 531,370.4 1.9 2,071.49 MWD+IFR-AK-CAZ-SC (3) 4,746.5 79.80 91.86 3,466.0 3,391.4 1,571.2 2,121.1 6,009,458.4 531,420.0 1.8 2,121.07 MWD+IFR-AK-CAZ-SC (3) 4,791.8 78.43. 91.66 3,474.6 3,399.9 1,569.9 2,165.5 6,009,457.3 531,464.4 3.1 2,165.51 MWD+IFR-AK-CAZ-SC (3) 4,842.5 79.91 90.24 3,484.1 3,409.5 1,569.1 2,215.2 6,009,456.6 531,514.1 4.0 2,215.23 MWD+IFR-AK-CAZ-SC (3) 4,886.8 80.56 89.28 3,491.6 3,417.0 1,569.2 2,258.9 6,009,457.0 531,557.8 2.6 2,258.91 MWD+IFR-AK-CAZ-SC (3) 4,937.5 81.24 90.19 3,499.6 3,425.0 1,569.5 2,309.0 6,009,457.4 531,607.9 2.2 2,309.00 MWD+IFR-AK-CAZ-SC (3) 4,982.8 81.86 90.10 3,506.3 3,431.7 1,569.4 2,353.8 6,009,457.5 531,652.7 1.4 2,353.80 MWD+IFR-AK-CAZ-SC (3) ~ 5,034.0 81.03 89.18 3,513.9 3,439.3 1,569.7 2,404.5 6,009,458.0 531,703.3 2.4 2,404.47 MWD+IFR-AK-CAZ-SC (3) 5,077.5 82.17 88.73 3,520.3 3,445.6 1,570.5 2,447.5 6,009,458.9 531,746.4 2.8 2,447.48 MWD+IFR-AK-CAZ-SC (3) 5,126.6 85.19 86.98 3,525.6 3,451.0 1,572.3 2,496.2 6,009,461.0 531,795.0 7.1 2,496.18 MWD+IFR-AK-CAZ-SC (3) 5,172.4 85.50 86.56 3,529.4 3,454.8 1,574.9 2,541.8 6,009,463.7 531,840.6 1.2 2,541.81 MWD+IFR-AK-CAZ-SC (3) 5,267.4 85.34 87.16 3,537.0 3,462.3 1,580.1 2,636.3 6,009,469.3 531,935.2 0.7 2,636.34 MWD+IFR-AK-CAZ-SC (3) 5,363.5 84.83 88.08 3,545.2 3,470.6 1,584.0 2,732.0 6,009,473.6 532,030.8 1.1 2,732.00 MWD+IFR-AK-CAZ-SC (3) 5,395.3 85.18 87.61 3,548.0 3,473.3 1,585.2 2,763.7 6,009,475.0 532,062.5 1.8 2,763.70 MWD+IFR-AK-CAZ-SC (3) 5,453.0 85.00 88.72 3,552.9 3,478.3 1,587.1 2,821.1 6,009,477.0 532,119.9 1.9 2,821.12 MWD+IFR-AK-CAZ-SC (4) 5,499.6 87.47 86.67 .3,556:0 3,481.3 1,588.9 2,867.6 6,009,479.1 532,166.3 6.9 2,867.58 MWD+IFR-AK-CAZ-SC (4) 5,547.1 88.88 87.38 3,557.5 3,482.8 1,591.4 2,915.0 6,009,481.7 532,213.7 3.3 2,914.97 MWD+IFR-AK-CAZ-SC (4) 5,593.9 89.56 87.43 3,558.1 3,483.5 1,593.5 2,961.7 6,009,484.0 532,260.4 1.5 2,961.72 MWD+IFR-AK-CAZ-SC (4) 5,689.2 89.56 86.26 3,558.8 3,484.2 1,598.8 3,056.8 6,009,489.6 532,355.5 1.2 3,056.84 MWD+IFR-AK-CAZ-SC (4) 12/15/2008 1:14:24PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. ,Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103 Survey Calculation Method: Minimum Curvature Design: 3K-103 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-5 +E/-W Northing Easting DL5 Section Ift) (~) (~) (ft) (ft) (ft) (ft) (ftl Ift) (°/100') (ft) Survey Tool Name 5,750.2 50.05 86.55 3,559.1 3,4H4.4 1,003.0 3,123.7 6,009,454.1 532,422.4 0.3 3,123.70 MWD+IFR-AK-Cr+Z-SC (4) 5,815.9 90.49 86.81 3,558.8 3,484.2 1,606.4 3,183.4 6,009,497.8 532,482.0 0.9 3,183.38 MWD+IFR-AK-CAZ-SC (4) 5,879.5 90.30 84.59 3,558.3 3,483.7 1,611.2 3,246.8 6,009,502.8 532,545.4 3.5 3,246.81 MWD+IFR-AK-CAZ-SC (4) 5,974.4 87.58 80.79 3,560.1 3,485.5 1,623.3 3,340.9 6,009,515.2 532,639.4 4.9 3,340.86 MWD+IFR-AK-CAZ-SC (4) 6,069.4 88.64 79.31 3,563.2 3,488.6 1,639.7 3,434.3 6,009,532.0 532,732.8 1.9 3,434.32 MWD+IFR-AK-CAZ-SC (4) 6,164.4 88.33 80.71 3,565.7 3,491.1 1,656.1 3,527.9 6,009,548.9 532,826.3 1.5 3,527.91 MWD+IFR-AK-CAZ-SC (4) 6,260.1 87.28 82.20 3,569.4 3,494.8 1,670.4 3,622.5 6,009,563.4 532,920.8 1.9 3,622.50 MWD+IFR-AK-CAZ-SC (4) 6,355.5 88.45 85.24 3,573.0 3,498.3 1,680.8 3,717.2 6,009,574.2 533,015.5 3.4 3,717.20 MWD+IFR-AK-CAZ-SC (4) 6,450.3 87.83 86.60 3,576.0 3,501.4 1,687.5 3,811.7 6,009,581.3 533,110.0 1.6 3,811.73 MWD+IFR-AK-CAZ-SC (4) 6,545.6 87.65 89.26 3,579.8 3,505.2 1,691.0 3,906.9 6,009,585.2 533,205.1 2.8 3,906.88 MWD+IFR-AK-CAZ-SC (4) 6,640.7 87.52 92.49 3,583.8 3,509.2 1,689.5 4,001.8 6,009,584.1 533,300.1 3.4 4,001.85 MWD+IFR-AK-CAZ-SC (4) 6,736.0 88.70 94.35 3,587.0 3,512.3 1,683.8 4,097.0 6,009,578.8 533,395.2 2.3 4,096.98 MWD+IFR-AK-CAZ-SC (4) 6,754.9 87.90 93.72 3,587.5 3,512.9 1,682.5 4,115.7 6,009,577.5 533,414.0 5.4 4,115.74 MWD+IFR-AK-CAZ-SC (4) 6,775.0 88.82 91.37 3,588.1 3,573.5 1,681.6 4,135.9 6,009,576.7 533,434.1 12.5 4,135.89 MWD+IFR-AK-CAZ-SC (4) 6,794.6 89.81 89.90 3,588.3 3,513.7 1,681.4 4,155.5 6,009,576.6 533,453.7 9.1 4,155.46 MWD+IFR-AK-CAZ-SC (4) 6,815.4 90.31 88.06 3,588.3 3,513.7 1,681.8 4,176.2 6,009,577.0 533,474.5 9.2 4,176.24 MWD+IFR-AK-CAZ-SC (4) 6,835.4 91.34 87.57 3,588.0 3,513.4 1,682.5 4,196.2 6,009,577.9 533,494.5 5.7 4,196.23 MWD+IFR-AK-CAZ-SC (4) 6,881.7 92.59 86.85 3,586.4 3,511.8 1,684.8 4,242.4 6,009,580.3 533,540.6 3.1 4,242.39 MWD+IFR-AK-CAZ-SC (4) 6,927.0 93.33 88.35 3,584.1 3,509.5 1,686.7 4,287.7 6,009,582.4 533,585.9 3.7 4,287.67 MWD+IFR-AK-CAZ-SC (4) 7,022.4 90.49 88.23 3,580.9 3,506.3 1,689.5 4,382.9 6,009,585.6 533,681.1 3.0 4,382.89 MWD+IFR-AK-CAZ-SC (4) 7,117.2 89.75 90.04 3,580.7 3,506.1 1,690.9 4,477.7 6,009,587.4 533,775.8 2.1 4,477.67 MWD+IFR-AK-CAZ-SC (4) 7,212.3 89.25 91.57 3,581.5 3,506.9 1,689.6 4,572.8 6,009,586.4 533,871.0 1.7 4,572.81 MWD+IFR-AK-CAZ-SC (4) 7,308.2 89.44 93.14 3,582.6 3,508.0 1,685.7 4,668.6 6,009,582.9 533,966.8 1.6 4,668.61 MWD+IFR-AK-CAZ-SC (4) 7,403.9 89.56 93.65 3,583.5 3,508.9 1,680.0 4,764.1 6,009,577.6 534,062.3 0.5 4,764.13 MWD+IFR-AK-CAZ-SC (4) 7,498.3 89.69 92.80 3,584.1 3,509.5 1,674.7 4,858.4 6,009,572.6 534,156.6 0.9 4,858.36 MWD+IFR-AK-CAZ-SC (4) 7,594.2 90.37 91.64 3,584.0 3,509.4 1,671.0 4,954.2 6,009,569.3 534,252.4 1.4 4,954.20 MWD+IFR-AK-CAZ-SC (4) i 7,689.3 90.67 88.80 3,583.2 3,508.6 1,670.6 5,049.3 6,009,569.3 534,347.5 3.0 5,049.34 MWD+IFR-AK-CAZ-SC (4) 7,783.7 90.43 88.79 3,582.3 3,507.6 1,672.6 5,143.6 6,009,571.7 534,441.8 0.3 5,143.64 MWD+IFR-AK-CAZ-SC (4) 7,879.3 91.73 91.37 3,580.5 3,505.8 1,672.5 5,239.2 6,009,571.9 534,537.4 3.0 5,239.21 MWD+IFR-AK-CAZ-SC (4) 7,973.8 91.35 89.42 3,577.9 3,503.3 1,671.8 5,333.7 6,009,571.6 534,631.9 2.1 5,333.69 MWD+IFR-AK-CAZ-SC (4) i 8,008.5 91.73 90.51 3,577.0 3,502.4 1,671.8 5,368.4 6,009,571.8 534,666.5 3.3 5,368.35 MWD+IFR-AK-CAZ-SC (4) 8,104.3 91.97 90.09 3,573.9 3,499.3 1,671.3 5,464.1 6,009,571.6 534,762.3 0.5 5,464.10 MWD+IFR-AK-CAZ-SC (4) 8,200.5 93.08 91.26 3,569.7 3,495.0 1,670.2 5,560.3 6,009,570.9 534,858.4 1.7 5,560.26 MWD+IFR-AK-CAZ-SC (4) 8,294.7 92.40 89.52 3,565.2 3,490.5 1,669.6 5,654.4 6,009,570.6 534,952.5 2.0 5,654.35 MWD+IFR-AK-CAZ-SC (4) 8,390.6 93.09 90.96 3,560.6 3,485.9 1,669.2 5,750.1 6,009,570.6 535,048.3 1.7 5,750.13 MWD+IFR-AK-CAZ-SC (4) 8,486.3 91.04 92.80 3,557.1 3,482.5 1,666.0 5,845.7 6,009,567.8 535,143.8 2.9 5,845.71 MWD+IFR-AK-CAZ-SC (4) 8,581.3 89.56 94.28 3,556.6 3,482.0 1,660.1 5,940.5 6,009,562.3 535,238.7 2.2 5,940.55 MWD+IFR-AK-CAZ-SC (4) 8,676.6 89.19 95.42 3,557.7 3,483.0 1,652.1 6,035.5 6,009,554.7 535,333.6 1.3 6,035.46 MWD+IFR-AK-CAZ-SC (4) 8,771.9 88.02 95.14 3,560.0 3,485.4 1,643.3 6,130.3 6,009,546.3 535,428.5 1.3 6,130.28 MWD+IFR-AK-CAZ-SC (4) 8,867.1 87.03 95.85 3,564.1 3,489.5 1,634.2 6,225.0 6,009,537.5 535,523.2 1.3 6,225.03 MWD+IFR-AK-CAZ-SC (4) 12/15/2008 1:14:24PM Page 5 COMPASS 2003.16 Buitd 42F ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ord[nate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Refere nce: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103 Survey Cal culation Meth od: Minimum Curvature Design: 3K-103 Database: GPAI EDM Production Survey Map Map Vertical j MD (ft) Inc (°) Azi (°) ND Ift) NDSS (ftl +N/-5 Ift) +E/-W (ft) Northing (ft) Easting DLS (ft) (°1100') Section (ft) Survey Tool Name ,962.3 25.52 98.41 3,567.8 3,493.2 1,622.4 6,315.4 6,009,526.1 535,617.6 3.1 6,319.39 MWD+IFR-AK-CAZ-Sv (4) 9,056.8 88.39 98.79 3,570.3 3,495.7 1,608.3 6,412.8 6,009,512.3 535,711.1 0.4 6,412.80 MWD+IFR-AK-CAZ-SC (4) 9,151.8 87.96 100.48 3,573.4 3,498.7 1,592.4 6,506.4 6,009,496.8 535,804.8 1.8 6,506.42 MWD+IFR-AK-CAZ-SC (4) 9,247.2 88.51 102.28 3,576.3 3,501.7 1,573.6. 6,599.8 6,009,478.4 535,898.2 2.0 6,599.82 MWD+IFR-AK-CAZ-SC (4) 9,342.8 86.22 104.22 3,580.7 3,506.1 1,551.7 6,692.8 6,009,456.9 535,991.3 3.1 6,692.82 MWD+IFR-AK-CAZ-SC (4) 9,391.8 86.73 105.74 3,583.7 3,509.1 1,539.1 6,740.0 6,009,444.4 536,038.6 3.3 6,740.05 MWD+IFR-AK-CAZ-SC (4) 9,485.9 89.87 107.81 3,586.5 3,511.9 1,511.9 6,830.1 6,009,417.6 536,128.7 4.0 6,830.08 MWD+IFR-AK-CAZ-SC (4) 9,582.1 89.87 108.50 3,586.7 3,512.1 1,481.9 6,921.5 6,009,388.0 536,220.2 0.7 6,921.51 MWD+IFR-AK-CAZ-SC (4) 9,677.5 90.30 110.88 3,586.6 3,512.0 1,449.8 7,011.3 6,009,356.2 536,310.2 2.5 7,011.33 MWD+IFR-AK-CAZ-SC (4) 9,773.0 89.43 110.15 3,586.8 3,512.2 1,416.3 7,100.8 6,009,323.1 536,399.7 1.2 7,100.76 MWD+IFR-AK-CAZ-SC (4) 9,868.9 90.24 107.33 3,587.1 3,512.5 1,385.5 7,191.6 6,009,292.6 536,490.7 3.1 7,191.60 MWD+IFR-AK-CAZ-SC (4) 9,964.4 90.48 105.28 3,586.5 3,511.9 1,358.7 7;283.2 6,009,266.2 536,582.4 2.2 7,283.17 MWD+IFR-AK-CAZ-SC (4) 10,058.4 90.61 102.62 3,585.6 3,511.0 1,336.1 7,374.4 6,009,243.9 536,673.7 2.8 7,374.40 MWD+IFR-AK-CAZ-SC (4) 10,153.0 90.24 100.43 3,584.9 3,510.3 1,317.2 7,467.1 6,009,225.4 536,766.4 2.3 7,467.10 MWD+IFR-AK-CAZ-SC (4) 10,248.4 89.62 96.43 3,585.0 3,510.4 1,303.2 7,561.5 6,009,211.8 536,860.8 4.2 7,561.47 MWD+IFR-AK-CAZ-SC (4) 10,344.3 88.69 95.24 3,586.4 3,511.8 1,293.4 7,656.9 6,009,202.4 536,956.3 1.6 7,656.87 MWD+IFR-AK-CAZ-SC (4) 10,439.1 88.75 97.48 3,588.5 3,513.9 1,282.9 7,751.0 6,009,192.3 537,050.4 2.4 7,751.01 MWD+IFR-AK-CAZ-SC (4) 10,534.0 88.76 98.42 3,590.6 3,516.0 1,269.8 7,845.0 6,009,179.5 537,144.4 1.0 7,844.95 MWD+IFR-AK-CAZ-SC (4) 10,629.6 88.57 100.52 3,592.8 3,518.2 1,254.1 7,939.3 6,009,164.2 537,238.8 2.2 7,939.32 MWD+IFR-AK-CAZ-SC (4) 10,684.0 89.31 103.38 3,593.8 3,519.2 1,242.8 7,992.5 6,009,153.1 537,292.0 5.4 7,992.46 MWD+IFR-AK-CAZ-SC (4) 10,703.8 90.42 104.73 3,593.9 3,519.3 1,238.0 8,011.7 6,009,148.4 537,311.3 8.8 8,011.72 MWD+IFR-AK-CAZ-SC (4) 10,724.9 92.09 106.50 3,593.4 3,518.8 1,232.3 8,032.0 6,009,142.8 537,331.6 11.6 8,031.97 MWD+IFR-AK-CAZ-SC (4) 10,748.9 92.34 106.85 3,592.5 3,517.9 1,225.4 8,055.0 6,009,136.0 537,354.6 1.8 8,055.01 MWD+IFR-AK-CAZ-SC (4) 10,774.1 91.54 107.21 3,591.6 3,517.0 1,218.1 8,079.1 6,009,128.7 537,378.7 3.5 8,079.06 MWD+IFR-AK-CAZ-SC (4) 10,820.7 90.67 107.90 3,590.7 3,516.1 1,204.0 8,123.5 6,009,114.8 537,423.2 2.4 8,123.48 MWD+IFR-AK-CAZ-SC (4) 10,914.7 90.24 104.95 3,590.0 3,515.4 1,177.4 8,213.6 6,009,088.6 537,513.4 3.2 8,213.64 MWD+IFR-AK-CAZ-SC (4) 11,009.2 88.76 103.15 3,590.8 3,516.2 1,154.5 8,305.3 6,009,066.1 537,605.1 2.5 8,305.26 MWD+IFR-AK-CAZ-SC (4) 11,098.3 88.57 100.49 3,592.9 3,518.3 1,136.3 8,392.5 6,009,048.2 537,692.4 3.0 8,392.45 MWD+IFR-AK-CAZ-SC (4) 11,200.2 88.51 98.78 3,595.5 3,520.9 1,119.2 8,492.9 6,009,031.5 537,792.9 1.7 8,492.90 MWD+IFR-AK-CAZ-SC (4) 11,294.2 89.06 98.87 3,597.5 3,522.9 1,104.8 8,585.7 6,009,017.4 537,885.8 0.6 8,585.74 MWD+IFR-AK-CAZ-SC (4) 11,390.0 89.37 98.59 3,598.8 3,524.2 1,090.3 8,680.4 6,009,003.3 537,980.5 0.4 8,680.41 MWD+IFR-AK-CAZ-SC (4) ~ 11,485.7 87.71 98.82 3,601.2 3,526.6 1,075.8 8,775.0 6,008,989.2 538,075.2 1.7 8,775.04 MWD+IFR-AK-CAZ-SC (4) 11,580.1 88.20 99.98 3,604.6 3,530.0 1,060.4 8,868.0 6,008,974.1 538,168.2 1.3 8,868.02 MWD+IFR-AK-CAZ-SC (4) 11,620.1 88.08 99.97 3,605.9 3,531.3 1,053.5 8,907.4 6,008,967.4 538,207.6 0.3 8,907.40 MWD+IFR-AK-CAZ-SC (4) 11,700.4 86.11 99.05 3,610.0 3,535.3 1,040.2 8,986.5 6,008,954.4 538,286.8 2.7 8,986.50 MWD+IFR-AK-CAZ-SC (4) 11,762.7 83.50 99.65 3,615.6 3,541.0 1,030.1 9,047.7 6,008,944.6 538,348.0 4.3 9,047.73 MWD+IFR-AK-CAZ-SC (4) 11,810.5 83.44 99.85 3,621.0 3,546.4 1,022.1 9,094.6 6,008,936.7 538,394.9 0.4 9,094.59 MWD+IFR-AK-CAZ-SC (4) 11,858.3 83.38 99.96 3,626.5 3,551.9 1,013.9 9,141.3 6,008,928.8 538,441.7 0.3 9,141.31 MWD+IFR-AK-CAZ-SC (4) 11,953.5 85.93 98.41 3,635.4 3,560.8 998.8 9,234.9 6,008,914.0 538,535.2 3.1 9,234.85 MWD+IFR-AK-CAZ-SC (4) 12,001.3 86.54 96.40 3,638.5 3,563.9 992.6 9,282.1 6,008,908.0 538,582.6 4.4 9,282.15 MWD+IFR-AK-CAZ-SC (4) 12/15/2008 1:14:24PM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Survey Report ::Company: ConocoPhillips(Alaska) Inca Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103 Survey Calculation Meth od: Minimum Curvature Design: 3K-103 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND NDSS +N!-5 +E/-W Northing Easting DLS Section (ft) (°) (°) lft) lftl (ft1 Ift) (ft) (ft) (°1100') (ft) survey Tool Name 12,048.3 88.64 95.24 3,640.5 3,565.9 987.9 9,328.9 6,008,903.5 538,629.4 5.1 9,328.94 MWD+iFR-Ak-GAZ-SG (4) 12,095.6 87.60 94.99 3,642.1 3,567.4 983.7 9,376.0 6,008,899.4 538,676.5 2.3 9,376.03 MWD+IFR-AK-CAZ-SC (4) 12,143.0 89.20 95.51 3,643.4 3,568.8 979.3 9,423.2 6,008,895.3 538,723.6 3.6 9,423.19 MWD+IFR-AK-CAZ-SC (4) 12,239.2 88.08 95.38 3,645.7 3,571.0 970.2 9,518.9 6,008,886.5 538,819.4 1.2 9,518.95 MWD+IFR-AK-CAZ-SC (4) 12,334.3 88.08 97.19 3,648.9 3,574.2 959.8 9,613.4 6,008,876.5 538,913.9 1.9 9,613.42 MWD+IFR-AK-CAZ-SC (4) . 12,411.0 88.08 97.19 3,651.4 3,576.8 950.2 9,689.4 6,008,867.2 ~ 538,990.0 0.0 9,689.43 MWD+IFR-AK-CAZ-SC (4) 12/15/2008 1:14:24PM Page 7 COMPASS 2003.16 Build 42F ~ Q ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103PB1 Permit to Drill: 208-115 API: 50-029-23392-70 ~: ~.. Definitive Survey Report 15 December, 2008 .._.. :~ ';3p~rr}I C~It`illing aBrvic~~ ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. LocaLCo-ordinate Reference::... We113K-103 (E14) Project: Kuparuk River Unit TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103PB1 Survey Calculation Method: Minimum Curvature Design: 3K-103P61 Database: CPAI EDM Production •oject Kuparuk River Unit ap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level so Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point ap Zone: Alaska Zone 04 Using. geodetic scale factor - ell 3K-103 (E14) 'ell Position +N/-S 0.0 ft Northing: 6,007,879.03ft Latitude: 70° 25' 57.374 +E/-W 0.0 ft Easting: 529,305.30 ft Longitude: 149° 45' 40.019 ~sition Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 33.8ft Wellbore 3K-103PB1 ~~~~~~ Magnetics Model Name Sample Date ~ BGGM2007 9/24/2008 Design 3K-103PB1 Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TV D) ' (ft) ~ 4o.s Declination (°1 22..56 ACTUAL +N/-S (ft) o.o Dip Angle Field Strength (°) (nTl 80.90 57.647 Tie On Depth: 40.8 +FJ-W Direction (ft) 1°) 0 0 90.00 Survey Program Date From To i (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 50.0 621.0 3K-103PBi SRG (3K 103P61) CB-GYRO-SS Camera based gyro single shot 5/23/2008 1; 672.5 4,314.2 3K-103P61 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.6 0.00 0.00 40.8 -33.8 0.0 O.U 6,007,875.0 529,305.3 0.0 0.00 UNDEFINED 50.0 0.20 73.45 50.0 -24.6 0.0 0.0 6,007,879.0 529,305.3 2.2 0.02 CB-GYRO-SS (1} 110.0 0.41 199.34 110.0 35.4 -0.2 0.0 6,007,878.9 529,305.3 0.9 0.04 CB-GYRO-SS (1) 170.0 0.46 75.98 170.0 95.4 -0.3 0.2 6,007,878.7 529,305.5 1.3 0.21 CB-GYRO-SS (1) 265.0 3.37 53.09 264.9 190.3 1.5 2.8 6,007,880.5 529,308.1 3.1 2.81 CB-GYRO-SS (1) 354.0 5.18 54.28 353.7 279.1 5.4 8.2 6,007,884.4 529,373.4 2.0 8.16 CB-GYRO-SS (1) ~ 451.0 6.64 60.62 450.2 375.5 10.7 16.6 6,007,889.8 529,321.9 1.6 16.61 CB-GYRO-SS (1) 541.0 9.92 63.78 539.2 464.6 16.7 28.1 6,007,895.8 529,333.3 3.7 28.10 CB-GYRO-SS (1) 621.0 12.00 68.96 617.8 543.1 22.7 42.0 6,007,901.9 529,347.3 2.9 42.04 CB-GYRO-SS (1) 672.5 13.32 65.33 668.0 593.4 27.1 52.4 6,007,906.3 529,357.6 3.0 52.43 MWD+IFR-AK-CAZ-SC (2) 765.5 16.96 64.65 757.8 683.2 37.4 74.4 6,007,916.7 529,379.6 3.9 74.44 MWD+IFR-AK-CAZ-SC (2) 863.5 18.39 60.86 851.1 776.5 51.0 100.8 6,007,930.4 529,405.9 1.9 100.84 MWD+IFR-AK-CAZ-SC (2) ~ 957.8 20.90 58.49 939.9 865.3 67.1 128.2 6,007,946.6 529,433.2 2.8 128.19 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:17 42PM Page 2 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P61 Design: 3K-103P61 Survey • ConocoPhillips Definitive Survey Report Local Co-ordlna#e Reference: We113K-103 (E14) ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production - --- - _ I Map Map Vertical MD Inc Azi ND NDSS +N/-S +Ei-W Northing Easting DLS Section (ft) (~) (~) (ftl lft) 1ft) Ift) (ft) (ft) (°1100') (ft) Survey Tool Name ~ 1,053.8 23.56 54.34 1,028.3 954.2 87.2 158.4 6,007,9b'6.8 525,463.3 3.2 158.38 MWD+IFR-AR-GAZ-SC (2) ~ 1,148.4 22.84 49.94 1,115.8 1,041.2 110.0 187.8 6,007,989.8 529,492.7 2.0 187.81 MWD+IFR-AK-CAZ-SC (2) 1,243.1 24.69 45.02 1,202.4 1,127.8 135.8 215.9 6,008,015.7 529,520.6 2.9 215.86 MWD+IFR-AK-CAZ-SC (2) 1,339.0 27.02 43.45 1,288.7 1,214.1 165.8 245.0 6,008,045.8 529,549.6 2.5 245.03 MWD+IFR-AK-CAZ-SC (2) 1,433.5 31.02 39.31 1,371.4 1,296.8 200.3 275.2 6,008,080.4 529,579.7 4.7 275.23 MWD+IFR-AK-CAZ-SC (2) 1,529.2 33.23 38.66 1,452.4 1,377.8 239.8 307.2 6,008,120.0 529,611.5 2.3 307.22 MWD+IFR-AK-CAZ-SC (2) 1,624.9 37.85 38.27 1,530.2 1,455.6 283.4 341.8 6,008,163.7 529,646.0 4.8 341.80 MWD+IFR-AK-CAZ-SC (2) 1,720.6 38.45 39.07 1,605.5 1,530.9 329.5 378.8 6,008,210.0 529,682.7 0.8 378.77 MWD+IFR-AK-CAZ-SC (2) 1,814.3 38.90 39.88 1,678.7 1,604.0 374.7 416.0 6,008,255.4 529,719.8 0.7 415.99 MWD+IFR-AK-CAZ-SC (2) 1,910.5 39.26 39.69 1,753.4 1,678.7 421.4 454.8 6,008,302.1 529,758.4 0.4 454.80 MWD+IFR-AK-CAZ-SC (2) 2,005.8 40.31 41.17 1,826.6 1,752.0 467.8 494.4 6,008,348.7 529,797.8 1.5 494.36 MWD+IFR-AK-CAZ-SC (2) 2,101.3 41.64 41.34 1,898.7 1,824.1 514.8 535.6 6,008,395.9 529,838.9 1.4 535.64 MWD+IFR-AK-CAZ-SC (2) ~ 2,196.1 43.61 37.77 1,968.4 1,893.8 564.3 576.5 6,008,445.6 529,879.5 3.3 576.48 MWD+IFR-AK-CAZ-SC (2) 2,290.7 42.97 34.08 2,037.3 1,962.7 616.8 614.6 6,008,498.2 529,917.4 2.8 614.55 MWD+IFR-AK-CAZ-SC (2) 2,386.6 44.84 35.12 2,106.4 2,031.8 671.6 652.3 6,008,553.1 529,954.9 2.1 652.30 MWD+IFR-AK-CAZ-SC (2) 2,481.6 43.66 35.54 2,174.4 2,099.8 725.6 690.6 6,008,607.3 529,993.0 1.3 690.64 MWD+IFR-AK-CAZ-SC (2) 2,576.8 42.74 35.94 2,243.8 2,169.2 778.5 728.7 6,008,660.3 530,030.9 1.0 728.70 MWD+IFR-AK-CAZ-SC (2) 2,625.3 41.50 36.29 2,279.8 2,205.2 804.8 747.9 6,008,686.7 530,049.9 2.6 747.89 MWD+IFR-AK-CAZ-SC (2) 2,672.1 40.62 35.91 2,315.1 2,240.4 829.6 766.0 6,008,711.6 530,067.9 2.0 765.96 MWD+IFR-AK-CAZ-SC (2) 2,727.0 41.13 34.51 2,356.6 2,282.0 859.0 786.7 6,008,741.0 530,088.5 1.9 786.69 MWD+IFR-AK-CAZ-SC (2) 2,766.7 41.29 33.17 2,386.5 2,311.8 880.7 801.3 6,008,762.8 530,103.0 2.3 801.25 MWD+IFR-AK-CAZ-SC (2) 2,862.2 42.54 33.44 2,457.6 2,382.9 934.0 836.3 6,008,816.3 530,137.8 1.3 836.31 MWD+IFR-AK-CAZ-SC (2) 2,956.7 44.34 32.75 2,526.1 2,451.5 988.4 871.8 6,008,870.8 530,173.1 2.0 871.76 MWD+IFR-AK-CAZ-SC (2) 3,052.1 43.54 32.38 2,594.9 2,520.3 1,044.3 907.4 6,008,926.8 530,208.5 0.9 907.41 MWD+IFR-AK-CAZ-SC (2) 3,146.9 42.61 31.38 2,664.1 2,589.5 1,099.2 941.6 6,008,981.9 530,242.5 1.2 941.61 MWD+IFR-AK-CAZ-SC (2) 3,241.3 43.07 32.26 2,733.3 2,658.7 1,153.8 975.5 6,009,036.5 530,276.1 0.8 975.45 MWD+IFR-AK-CAZ-SC (2) 3,337.3 44.37 34.34 2,802.7 2,728.1 1,209.2 1,011.9 6,009,092.1 530,312.3 2.0 1,011.88 MWD+IFR-AK-CAZ-SC (2) 3,432.6 45.95 40.56 2,870.0 2,795.3 1,262.8 1,053.0 6,009,145.8 530,353.2 4.9 1,052.98 MWD+IFR-AK-CAZ-SC (2) 3,525.8 45.67 46.28 2,934.9 2,860.3 1,311.3 1,098.8 6,009,194.5 530,398.9 4.4 1,098.84 MWD+IFR-AK-CAZ-SC (2) 3,622.2 45.23 52.79 3,002.6 2,928.0 1,355.8 1,151.1 6,009,239.2 530,450.9 4.8 1,151.06 MWD+IFR-AK-CAZ-SC (2) 3,717.2 45.49 57.55 3,069.4 2,994.7 1,394.4 1,206.5 6,009,278.0 530,506.2 3.6 1,206.50 MWD+IFR-AK-CAZ-SC (2) 3,811.8 48.24 59.28 3,134.0 3,059.4 1,430.5 1,265.3 6,009,314.4 530,564.9 3.2 1,265.33 MWD+IFR-AK-CAZ-SC (2) 3,907.3 53.64 55.14 3,194.2 3,119.6 1,470.8 1,327.6 6,009,354.8 530,626.9 6.6 1,327.56 MWD+IFR-AK-CAZ-SC (2) ~ 3,975.7 58.46 55.38 3,232.4 3,157.8 1,503.1 1,374.2 6,009,387.3 530,673.4 7.1 1,374.17 MWD+IFR-AK-CAZ-SC (2) 4,002.8 60.10 56.69 3,246.2 3,171.6 1,516.1 1,393.5 6,009,400.4 530,692.7 7.4 7,393.49 MWD+IFR-AK-CAZ-SC (2) 4,051.3 61.19 58.72 3,270.0 3,195.4 1,538.7 1,429.3 6,009,423.2 530,728.4 4.3 1,429.25 MWD+IFR-AK-CAZ-SC (2) 4,097.7 61.50 61.86 3,292.3 3,217.7 1,558.9 1,464.6 6,009,443.5 530,763.6 6.0 1,464.60 MWD+IFR-AK-CAZ-SC (2) 4,134.7 62.67 64.82 3,309.6 3,235.0 1,573.5 1,493.8 6,009,458.2 530,792.8 7.8 1,493.79 MWD+IFR-AK-CAZ-SC (2) 4,180.3 64.26 67.80 3,330.0 3,255.3 1,589.9 1,537.1 6,009,474.8 530,830.0 6.8 1,531.11 MWD+IFR-AK-CAZ-SC (2) 4,228.0 66.02 70.95 3,350.0 3,275.4 1,605.1 1,571.7 6,009,490.2 530,870.5 7.0 1,571.67 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:17:42PM Page 3 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P61 Design: 3K-103PB1 _ r . Survey MD Inc Azi TVD TVDSS +N/-S Ift) (°) l°1 Ift} (ft} lft} 4,266.5 64.00 13.96 3,365.1 ?x,290.4 1,615.8 4,314.2 69.52 79.28 3,382.4 3,307.8 1,626.1 4,410.0 69.52 79.28 3,415.9 3,341.3 1,642.8 Local Co-ordinate Reference: We113K-103 (E14) TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Map Map __ - I Vertical +F-i-vv Northing Easting DLS Section (ft) (ft} (ft) (°/100') (ft) Survey Tool Name 1,605.4 6,008,501.0 530,804.2 8.9 1,605.40 MWD+iFR-iaK-CAZ-SG (2) 1,648.7 6,009,511.4 530,947.5 10.9 1,648.72 MWD+IFR-AK-CAZ-SC (2) 1,736.8 6,009,528.5 531,035.5 0.0 1,736.85 PROJECTED to TD 12/15/2008 1:17:42PM Page 4 COMPASS 2003.16 Buifd 42F ;~~ ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103PB2 Permit to Drill: 208-115 API: 50-029-23392-71 ~~~ A Definitive Survey Report 15 December, 2008 ~a:~:. .. a.~. ~::_= ~" : ~~ ~...~ :~3perrY C~rittt-rg ~~rrUic~~ Company: Project: Site: WeII: Wellbore: Design: ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103 (E14) 3K-103PB2 3K-103PB2 ConocoPhillips Definitive Survey Repoli Local Co-ordinate Reference: VVe113K-103 (E14) ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor --- Well 3K-103 (E14) Well Position +N/-S O.O ft Northing: 6,007,879.03ft Latitude: 70° 25' 57.374 N +E/-W 0.0 ft Easting: 529,305.30 ft Longitude: 149° 45' 40.019 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 33.8ft - -- - Wellbore 3K-103PB2 i Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 9/24/2008 2256 80-90 57.647 --- _ ,Design 3K-103P62 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 4,228.0 Vertical Section: Depth From (ND) +N!-S +E/ W Direction (ft) (ftl (ft) (°) 40.8 0.0 0.0 90.00 Survey Program Date From To (ft) (fi) Survey (Wellbore) Tool Name Description Survey Date 50.0 621.0 3K-103P61 SRG (3K-103PB1) CB-GYRO-S5 Camera based gyro single shot 9/23/2008 1: 672.5 4,228.0 3K-103PB1 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 4,260.0 4,451.9 3K-103PB2 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 _- ---- - Survey Map Map Vertical MD Inc Azi ND NDSS +N!-S +E!-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.is 0.00 0.00 40.8 -33.d 0.0 0.0 6,007,E79.0 525,305.3 0.0 0.00 UNDEFINED 50.0 0.20 73.45 50.0 -24.6 0.0 0.0 6,007,879.0 529,305.3 2.2 0.02 CB-GYRO-SS (1) 110.0 0.41 199.34 110.0 35.4 -0.2 0.0 6,007,878.9 529,305.3 0.9 0.04 CB-GYRO-SS (1) 170.0 0.46 75.98 170.0 95.4 -0.3 0.2 6,007,878.7 529,305.5 1.3 0.21 CB-GYRO-SS (1) 265.0 3.37 53.09 264.9 190.3 1.5 2.8 6,007,880.5 529,308.1 3.1 2.81 CB-GYRO-SS (1) 354.0 5.18 54.28 353.7 279.1 5.4 8.2 6,007,884.4 529,313.4 2.0 8.16 CB-GYRO-SS (1) 451.0 6.64 60.62 450.2 375.5 10.7 16.6 6,007,889.8 529,321.9 1.6 16.61 CB-GYRO-SS (1) 541.0 9.92 63.78 539.2 464.6 16.7 28.1 6,007,895.8 529,333.3 3.7 28.10 CB-GYRO-SS (1) 621.0 12.00 68.96 617.8 543.1 22.7 42.0 6,007,901.9 529,347.3 2.9 42.04 CB-GYRO-SS (1) 672.5 13.32 65.33 668.0 593.4 27.1 52.4 6,007,906.3 529,357.6 3.0 52.43 MWD+IFR-AK-CAZ-SC (2) 765.5 16.96 64.65 757.8 683.2 37.4 74.4 6,007,916.7 529,379.6 3.9 74.44 MWD+IFR-AK-CAZ-SC (2) 863.5 18.39 60.86 851.1 776.5 51.0 100.8 6,007,930.4 529,405.9 1.9 100.84 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:19:07PM Page 2 COMPASS 2003.16 Build 42F C onocoP hillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad Mb Refere nce: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103P62 Survey Ca lculation Method: Minimum Curvature Design: 3K-103P62 Database: CPAI EDM Production Survey -- - - - - -- Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E!-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 00') (ft) Survey Tool Name 957.8 20.50 58.49 938.9 865.3 67.1 128.2 6,007,946.6 529,433.2 2.8 122.15 MWD+IFR-AK-CAZ-SC (2) 1,053.8 23.56 54.34 1,028.8 954.2 87.2 158.4 6,007,966.8 529,463.3 3.2 158.38 MWD+IFR-AK-CAZ-SC (2) 1,148.4 22.84 49.94 1,715.8 1,041.2 110.0 187.8 6,007,989.8 529,492.7 2.0 187.81 MWD+IFR-AK-CAZ-SC (2) 1,243.1 24.69 45.02 1,202.4 1,127.8 135.8 215.9 6,008,015.7 529,520.6 2.9 215.86 MWD+IFR-AK-CAZ-SC (2) 1,339.0 27.02 43.45 7,288.7 1,214.1 165.8 245.0 6,008,045.8 529,549.6 2.5 245.03 MWD+IFR-AK-CAZ-SC (2) 1,433.5 31.02 39.31 1,371.4 1,296.8 200.3 275.2 6,008,080.4 529,579.7 4.7 275.23 MWD+IFR-AK-CAZ-SC (2) 1,529.2 33.23 38.66 1,452.4 1,377.8 239.8 307.2 6,008,720.0 529,611.5 2.3 307.22 MWD+IFR-AK-CAZ-SC (2) 1,624.9 37.85 38.27 1,530.2 1,455.6 283.4 341.8 6,008,163.7 529,646.0 4.8 341.80 MWD+IFR-AK-CAZ-SC (2) 1,720.6 38.45 39.07 1,605.5 1,530.9 329.5 378.8 6,008,210.0 529,682.7 0.8 378.77 MWD+IFR-AK-CAZ-SC (2) 1,814.3 38.90 39.88 1,678.7 1,604.0 374.7 416.0 6,008,255.4 529,779.8 0.7 415.99 MWD+IFR-AK-CAZ-SC (2) ~ 1,910.5 39.26 39.69 7,753.4 1,678.7 421.4 454.8 6,008,302.1 529,758.4 0.4 454.80 MWD+IFR-AK-CAZ-SC (2) 2,005.8 40.31 41.17 1,826.6 7,752.0 467.8 494.4 6,008,348.7 529,797.8 1.5 494.36 MWD+IFR-AK-CAZ-SC (2) 2,101.3 41.64 41.34 1,898.7 1,824.1 514.8 535.6 6,008,395.9 529,838.9 1.4 535.64 MWD+IFR-AK-CAZ-SC (2) 2,196.1 43.61 37.77 1,968.4 1,893.8 564.3 576.5 6,008,445.6 529,879.5 3.3 576.48 MWD+IFR-AK-CAZ-SC (2) ~ 2,290.7 42.97 34.08 2,037.3 1,962.7 616.8 614.6 6,008,498.2 529,977.4 2.8 614.55 MWD+IFR-AK-CAZ-SC (2) ~ 2,386.6 44.84 35.12 2,106.4 2,031.8 671.6 652.3 6,008,553.1 529,954.9 2.1 652.30 MWD+IFR-AK-CAZ-SC (2) 2,481.6 43.66 35.54 2,174.4 2,099.8 725.6 690.6 6,008,607.3 529,993.0 1.3 690.64 MWD+IFR-AK-CAZ-SC (2) 2,576.8 42.74 35.94 2,243.8 2,169.2 778.5 728.7 6,008,660.3 530,030.9 7.0 728.70 MWD+IFR-AK-CAZ-SC (2) 2,625.3 41.50 36.29 2,279.8 2,205.2 804.8 747.9 6,008,686.7 530,049.9 2.6 747.89 MWD+IFR-AK-CAZ-SC (2) 2,672.1 40.62 35.91 2,315.1 2,240.4 829.6 766.0 6,008,711.6 530,067.9 2.0 765.96 MWD+IFR-AK-CAZ-SC (2) 2,727.0 41.13 34.51 2,356.6 2,282.0 859.0 786.7 6,008,741.0 530,088.5 1.9 786.69 MWD+IFR-AK-CAZ-SC (2) 2,766.7 41.29 33.17 2,386.5 2,311.8 880.7 801.3 6,008,762.8 530,103.0 2.3 801.25 MWD+IFR-AK-CAZ-SC (2) 2,862.2 42.54 33.44 2,457.6 2,382.9 934.0 836.3 6,008,816.3 530,137.8 1.3 836.31 MWD+IFR-AK-CAZ-SC (2) 2,956.7 44.34 32.75 2,526.1 2,451.5 988.4 871.8 6,008,870.8 530,173.1 2.0 871.76 MWD+IFR-AK-CAZ-SC (2) 3,052.1 43.54 32.38 2,594.9 2,520.3 1,044.3 907.4 6,008,926.8 530,208.5 0.9 907.41 MWD+IFR-AK-CAZ-SC (2) I 3,146.9 42.61 31.38 2,664.1 2,589.5 1,099.2 941.6 6,008,981.9 530,242.5 1.2 941.61 MWD+IFR-AK-CAZ-SC (2) 3,241.3 43.07 32.26 2,733.3 2,658.7 1,153.8 975.5 6,009,036.5 530,276.1 0.8 975.45 MWD+IFR-AK-CAZ-SC (2) 3,337.3 44.37 34.34 2,802.7 2,728.7 1,209.2 1,011.9 6,009,092.1 530,312.3 2.0 1,011.88 MWD+IFR-AK-CAZ-SC (2) 3,432.6 45.95 40.56 2,870.0 2,795.3 1,262.8 7,053.0 6,009,145.8 530,353.2 4.9 1,052.98 MWD+IFR-AK-CAZ-SC (2) 3,525.8 45.67 46.28 2,934.9 2,860.3 1,311.3 1,098.8 6,009,194.5 530,398.9 4.4 1,098.84 MWD+IFR-AK-CAZ-SC (2) 3,622.2 45.23 52.79 3,002.6 2,928.0 1,355.8 1,151.1 6,009,239.2 530,450.9 4.8 1,151.06 MWD+IFR-AK-CAZ-SC (2) 3,717.2 45.49 57.55 3,069.4 2,994.7 1,394.4 1,206.5 6,009,278.0 530,506.2 3.6 1,206.50 MWD+IFR-AK-CAZ-SC (2) 3,817.8 48.24 59.28 3,134.0 3,059.4 1,430.5 1,265.3 6,009,314.4 530,564.9 3.2 1,265.33 MWD+IFR-AK-CAZ-SC (2) 3,907.3 53.64 55.14 3,194.2 3,119.6 1,470.8 1,327.6 6,009,354.8 530,626.9 6.6 7,327.56 MWD+IFR-AK-CAZ-SC (2) 3,975.7 58.46 55.38 3,232.4 3,157.8 1,503.1 1,374.2 6,009,387.3 530,673.4 7.t 1,374.17 MWD+IFR-AK-CAZ-SC (2) 4,002.8 60.10 56.69 3,246.2 3,171.6 1,516.1 1,393.5 6,009,400.4 530,692.7 7.4 1,393.49 MWD+IFR-AK-CAZ-SC (2) 4,051.3 61.19 58.72 3,270.0 3,195.4 1,538.7 1,429.3 6,009,423.2 530,728.4 4.3 1,429.25 MWD+IFR-AK-CAZ-SC (2) 4,097.7 61.50 61.86 3,292.3 3,217.7 1,558.9 1,464.6 6,009,443.5 530,763.6 6.0 1,464.60 MWD+IFR-AK-CAZ-SC (2) 4,134.7 62.67 64.82 3,309.6 3,235.0 1,573.5 1,493.8 6,009,458.2 530,792.8 7.8 1,493.79 MWD+IFR-AK-CAZ-SC (2) 4,180.3 64.26 67.80 3,330.0 3,255.3 1,589.9 1,531.1 6,009,474.8 530,830.0 6.8 1,531.11 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:19:07PM Page 3 COMPASS 2003.16 Burld 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.fift (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103P62 Survey Calculation Met hod: Minimum Curvature Design: 3K-103PB2 _- Database: CPAI EDM Production - Survey I Map Map Vertical MD Inc Azi ND NDSS +N/-5 +E/-W Northing Easting DLS Section lft) (°) (°) Ift) lft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,228.0 66.02 70.95 3,350.0 3,215.4 1,605.1 1,571.7 6,009,490.2 5`30,870.5 7.0 1,571.67 MWD+IFR-AK-CAZ-SC (2) 4,260.0 67.66 73.46 3,362.6 3,288.0 1,614.1 1,599.7 6,009,499.3 530,898.4 8.9 1,599.66 MWD+IFR-AK-CAZ-SC (3) 4,308.4 66.43 73.35 3,381.5 3,306.9 1,626.8 1,642.3 6,009,512.2 530,941.1 2.6 1,642.35 MWD+IFR-AK-CAZ-SC (3) 4,355.8 66.69 75.71 3,400.4 3,325.7 1,638.4 1,684.3 6,009,523.9 530,983.0 4.6 1,684.29 MWD+IFR-AK-CAZ-SC (3) 4,403.2 67.93 77.73 3,418.6 3,344.0 1,648.5 1,726.8 8,009,534.1 531,025.5 4.7 1,726.83 MWD+IFR-AK-CAZ-SC (3) 4,451.9 70.19 80.46 3,436.0 3,361.4 1,657.1 1,771.4 6,009,542.9 531,070.0 7.0 1,771.44 MWD+IFR-AK-CAZ-SC (3) 4,527.0 70.19 80.46 3,461.5 3,386.9 1,668.8 1,841.2 6,009,554.9 531,139.7 0.0 1,841.17 PROJECTED to TD 12/15/2008 1:19:07PM Page 4 COMPASS 2003.16 Build 42F • ~ ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103PB3 Permit to Drill: 208-115 API: 50-029-23392-72 _~ ~_~ Definitive survey Report 15 December, 2008 ..:..~~ 'Sperry C~rill~ng Snrvtcc ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) S(te: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) Narth Reference: True W®Ilbore: 3K-103P63 Survey Calculation Method: Minimum Curvature Design: 3K-103P63 Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 3K-103 (E14) Well Position +N/-S 0.0 ft Northing: 6,007,879.03ft Latitude: 70° 25' 57.374 N +E/-W 0.0 ft Easting: 529,305.30 ft Longitude: 149° 45' 40.019 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 33.8ft Wellbore 3K-103PB3 ~ Magnetics Model Name Sample Date Declin ation Dip Angle Field Strength BGGM2007 9/2412008 22.56 80.90 57,647 Design 3K-103P63 - --- - _- Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,862.2 Vertical Section: Depth From{ND) +N/.S +EI-W D irection (ft) Ift) Ift) (°) 4o.a o.o o.0 90.00 Survey Program Date From To I (ft) (ft) Survey (Weiibore) Tool Name Description Survey Date 50.0 6 21.0 3K-103PB1 SRG (3K-103P61) CB-GYRO-SS Camera based gyro single shot 5/23/2008 1: 672.5 2,862.2 3K-103PB1 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 2,925.0 6,4 50.0 3K-103P63 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 ' Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (#) (ft) (ft) (°1100') (ft) Survey Tool Name 40.8 0.0G 0.00 40.8 -33.8 0.0 0.0 6,007,879.0 529,305.3 0.0 OAO UNDEFINED 50.0 0.20 73.45 50.0 -24.6 0.0 0.0 6,007,879.0 529,305.3 2.2 0.02 CB-GYRO-SS (1) 110.0 0.41 199.34 110.0 35.4 -0.2 0.0 6,007,878.9 529,305.3 0.9 0.04 CB-GYRO-SS (1) 170.0 0.46 75.98 170.0 95.4 -0.3 0.2 6,007,878.7 529,305.5 1.3 0.21 CB-GYRO-SS (1) 265.0 3.37 53.09 264.9 190.3 1.5 2.8 6,007,880.5 529,308.1 3.1 2.81 CB-GYRO-SS (1) 354.0 5.18 54.28 353.7 279.1 5.4 8.2 6,007,884.4 529,313.4 2.0 8.16 CB-GYRO-SS (1) 451.0 6.64 60.62 450.2 375.5 10.7 16.6 6,007,889.8 529,321.9 1.6 16.61 CB-GYRO-SS (1) 541.0 9.92 63.78 539.2 464.6 16.7 28.1 6,007,895.8 529,333.3 3.7 28.10 CB-GYRO-SS (1) 621.0 12.00 68.96 617.8 543.1 22.7 42.0 6,007,901.9 529,347.3 2.9 42.04 CB-GYRO-SS (1) 672.5 13.32 65.33 668.0 593.4 27.1 52.4 6,007,906.3 529,357.6 3.0 52.43 MWD+IFR-AK-CAZ-SC (2) 765.5 16.96 64.65 757.8 683.2 37.4 74.4 6,007,916.7 529,379.6 3.9 74.44 MWD+IFR-AK-CAZ-SC (2) 863.5 18.39 60.86 851.1 776.5 51.0 100.8 6,007,930.4 529,405.9 1.9 100.84 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:20:03PM Page 2 COMPASS 2003.16 Build 42F C onocoP hillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) 'Well: 3K-10 3 (E14) North Reference: True W®Ilbore: 3K-103P63 Survey Ca lculation Met hod: Minimum Curvature Design: 3K-103PB3 Database: - __ CPAI EDM Production - L.. _._ Survey _:._.. _ _ :: Map Map Vertical MD (ft) Inc (°) Azi (°) ND (ft) NDSS (ft) +N/-S (ft) +El-W (ft) Northing (ft) Easting DLS (ft) (°1100') Section (ft) Survey Tool Name 957.3 20.90 58.49 939.9 865.3 67.1 128.2 6,007,946.6 5[9,433.2 2.8 128.19 MWD+IFR-Ah-GAZ-SG (2) 1,053.8 23.56 54.34 1,028.8 954.2 87.2 158.4 6,007,966.8 529,463.3 3.2 158.38 MWD+IFR-AK-CAZ-SC (2) 1,148.4 22.84 49.94 1,175.8 1,041.2 110.0 187.8 6,007,989.8 529,492.7 2.0 187.81 MWD+IFR-AK-CAZ-SC (2) 1,243.1 24.69 45.02 1,202.4 1,127.8 135.8 215.9 6,008,075.7 529,520.6 2.9 215.86 MWD+IFR-AK-CAZ-SC (2) 1,339.0 27.02 43.45 1,288.7 1,214.1 165.8 245.0 6,008,045.8 529,549.6 2.5 245.03 MWD+IFR-AK-CAZ-SC (2) 1,433.5 31.02 39.31 1,371.4 1,296.8 200.3 275.2 6,008,080.4 529,579.7 4.7 275.23 MWD+IFR-AK-CAZ-SC (2) 1,529.2 33.23 38.66 1,452.4 1,377.8 239.8 307.2 6,008,120.0 529,611.5 2.3 307.22 MWD+IFR-AK-CAZ-SC (2) 1,624.9 37.85 38.27 1,530.2 1,455.6 283.4 341.8 6,008,163.7 529,646.0 4.8 341.80 MWD+IFR-AK-CAZ-SC (2) 1,720.6 38.45 39.07 1,605.5 1,530.9 329.5 378.8 6,008,210.0 529,682.7 0.8 378.77 MWD+IFR-AK-CAZ-SC (2) 1,814.3 38.90 39.88 1,678.7 1,604.0 374.7 416.0 6,008,255.4 529,719.8 0.7 415.99 MWD+IFR-AK-CAZ-SC (2) 1,910.5 39.26 39.69 1,753.4 1,678.7 421.4 454.8 6,008,302.1 529,758.4 0.4 454.80 MWD+IFR-AK-CAZ-SC (2) 2,005.8 40.31 41.17 1,826.6 1,752.0 467.8 494.4 6,008,348.7 529,797.8 1.5 494.36 MWD+IFR-AK-CAZ-SC (2) 2,101.3 41.64 41.34 1,898.7 1,824.1 514.8 535.6 6,008,395.9 529,838.9 1.4 535.64 MWD+IFR-AK-CAZ-SC (2) 2,196.1 43.61 37.77 1,968.4 1,893.8 564.3 576.5 6,008,445.6 529,879.5 3.3 576.48 MWD+IFR-AK-CAZ-SC (2) 2,290.7 42.97 34.08 2,037.3 1,962.7 616.8 614.6 6,008,498.2 529,917.4 2.8 614.55 MWD+IFR-AK-CAZ-SC (2) 2,386.6 44.84 35.12 2,106.4 2,031.8 671.6 652.3 6,008,553.1 529,954.9 2.1 652.30 MWD+IFR-AK-CAZ-SC (2) 2,481.6 43.66 35.54 2,174.4 2,099.8 725.6 690.6 6,008,607.3 529,993.0 1.3 690.64 MWD+IFR-AK-CAZ-SC (2) 2,576.8 42.74 35.94 2,243.8 2,169.2 778.5 728.7 6,008,660.3 530,030.9 1.0 728.70 MWD+IFR-AK-CAZ-SC (2) 2,625.3 41.50 36.29 2,279.8 2,205.2 804.8 747.9 6,008,686.7 530,049.9 2.6 747.89 MWD+IFR-AK-CAZ-SC (2) ~ 2,672.1 40.62 35.91 2,315.1 2,240.4 829.6 766.0 6,008,711.6 530,067.9 2.0 765.96 MWD+IFR-AK-CAZ-SC (2) 2,727.0 41.13 34.51 2,356.6 2,282.0 859.0 786.7 6,008,741.0 530,088.5 1.9 786.69 MWD+IFR-AK-CAZ-SC (2) 2,766.7 41.29 33.17 2,386.5 2,311.8 880.7 801.3 6,008,762.8 530,103.0 2.3 801.25 MWD+IFR-AK-CAZ-SC (2) 2,862.2 42.54 33.44 2,457.6 2,382.9 934.0 836.3 6,008,816.3 530,137.8 1.3 836.31 MWD+IFR-AK-CAZ-SC (2) 2,925.0 43.74 32.98 2,503.4 2,428.7 970.0 859.8 6,008,852.3 530,161.2 2.0 859.81 MWD+IFR-AK-CAZ-SC (3) 2,983.4 40.73 32.87 2,546.6 2,472.0 1,002.9 881.2 6,008,885.3 530,182.4 5.2 881.15 MWD+IFR-AK-CAZ-SC (3) 3,035.7 40.60 34.12 2,586.3 2,511.7 1,031.3 900.0 6,008,913.8 530,201.1 1.6 899.96 MWD+IFR-AK-CAZ-SC (3) 3,078.6 41.31 34.30 2,618.7 2,544.1 1,054.6 915.8 6,008,937.1 530,216.8 1.7 915.78 MWD+IFR-AK-CAZ-SC (3) 3,129.7 42.18 35.07 2,656.8 2,582.2 1,082.5 935.1 6,008,965.1 530,236.1 2.0 935.11 MWD+IFR-AK-CAZ-SC (3) 3,173.5 42.07 34.76 2,689.3 2,614.6 1,106.6 951.9 6,008,989.3 530,252.8 0.5 i 951.92 MWD+IFR-AK-CAZ-SC (3) 3,223.7 43.23 36.23 2,726.2 2,651.6 1,134.4 971.7 6,009,017.1 530,272.4 3.0 971.70 MWD+IFR-AK-CAZ-SC (3) 3,268.4 43.75 37.35 2,758.6 2,684.0 1,159.0 990.1 6,009,041.8 530,290.8 2.1 990.72 MWD+IFR-AK-CAZ-SC (3) 3,318.6 45.07 39.09 2,794.5 2,719.9 1,186.6 1,011.9 6,009,069.5 530,312.4 3.6 1,011.86 MWD+IFR-AK-CAZ-SC (3) 3,363.5 45.85 40.87 2,826.0 2,751.4 1,211.1 1,032.4 6,009,094.0 530,332.8 3.3 1,032.40 MWD+IFR-AK-CAZ-SC (3) 3,414.1 46.24 44.05 2,861.1 2,786.5 1,237.9 1,057.0 6,009,121.0 530,357.3 4.6 1,056.98 MWD+IFR-AK-CAZ-SC (3) ~ 3,459.3 45.87 45.43 2,892.5 2,817.9 1,261.1 1,079.9 6,009,144.2 530,380.1 2.3 1,079.89 MWD+IFR-AK-CAZ-SC (3) 3,508.6 45.94 47.12 2,926.8 2,852.2 1,285.5 1,105.5 6,009,168.8 530,405.6 2.5 1,105.48 MWD+IFR-AK-CAZ-SC (3) 3,554.1 46.35 49.08 2,958.4 2,883.7 7,307.5 1,129.9 6,009,190.8 530,430.0 3.2 1,129.94 MWD+IFR-AK-CAZ-SC (3) 3,604.0 48.00 51.76 2,992.2 2,917.6 1,330.7 1,158.1 6,009,214.2 530,458.1 5.1 1,158.12 MWD+IFR-AK-CAZ-SC (3) 3,648.8 49.11 53.85 3,021.9 2,947.3 1,351.0 1,184.9 6,009,234.6 530,484.7 4.3 1,184.86 MWD+IFR-AK-CAZ-SC (3) 3,701.5 50.92 56.05 3,055.8 2,981.2 1,374.2 1,217.9 6,009,257.9 530,577.7 4.7 1,217.94 MWD+IFR-AK-CAZ-SC (3) 12/15/2008 1:20:03PM Page 3 COMPASS 2003.16 Build 42F C onocoP hillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. .Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103P63 Survey Ca lculation Method: Minimum Curvature Design: 3K-103PB3 Database: - CPAI EDM Production -- Survey i Map Map Vertical MD (ft) Inc (°) Azi (°) ND (ft) NDSS (ft) +NIS (ft) +E/-W (ft) Northing (ft) Easting DLS (ft) (°/100') Section (ft) Survey Tool Name 3,744.4 50.48 57.62 3,082.5 3,008.3 1,392.4 1,245.7 6,005,276.2 530,545.4 3A 1,245.72 MWD+IFR-AK-Grp-SC (3) 3,794.4 51.10 59.30 3,114.6 3,039.9 1,412.7 1,278.8 6,009,296.6 530,578.4 2.9 1,278.75 MWD+IFR-AK-CAZ-SC (3) 3,838.6 52.56 60.86 3,141.8 3,067.2 1,430.0 1,308.8 6,009,314.0 530,608.4 4.3 1,308.83 MWD+IFR-AK-CAZ-SC (3) 3,893.7 54.65 62.71 3,174.5 3,099.9 1,450.9 1,347.9 6,009,335.1 530,647.4 4.7 1,347.91 MWD+IFR-AK-CAZ-SC (3) 3,933.5 56.54 64.14 3,197.0 3,122.4 1,465.6 1,377.3 6,009,349.9 530,676.7 5.6 1,377.29 MWD+IFR-AK-CAZ-SC (3) 3,983.5 58.77 67.62 3,223.8 3,149.2 1,482.8 1,415.8 6,009,367.3 530,715.1 7.4 1,415.82 MWD+IFR-AK-CAZ-SC (3) 4,028.2 60.93 69.77 3,246.3 3,171.6 1,496.9 1,451.9 6,009,381.5 530,751.1 6.4 1,451.87 MWD+IFR-AK-CAZ-SC (3) 4,078.4 62.54 72.12 3,270.0 3,195.4 1,511.3 1,493.7 6,009,396.1 530,792.9 5.2 1,493.66 MWD+IFR-AK-CAZ-SC (3) 4,123.8 62.53 73.97 3,291.0 3,216.4 1,523.1 1,532.2 6,009,408.0 530,831.4 3.6 1,532.20 MWD+IFR-AK-CAZ-SC (3) 4,174.4 63.87 75.80 3,313.8 3,239.2 1,534.8 1,575.8 6,009,419.9 530,874.9 4.2 1,575.82 MWD+IFR-AK-CAZ-SC (3) 4,221.2 65.82 77.82 3,333.7 3,259.0 1,544.5 1,617.0 6,009,429.7 530,916.1 5.7 1,617.00 MWD+IFR-AK-CAZ-SC (3) 4,271.6 67.64 79.77 3,353.6 3,279.0 1,553.5 1,662.5 6,009,438.9 530,961.5 5.1 1,662.46 MWD+IFR-AK-CAZ-SC (3) 4,313.9 68.89 80.68 3,369.2 3,294.6 1,560.1 1,701.1 6,009,445.7 531,000.1 3.6 1,701.13 MWD+IFR-AK-CAZ-SC (3) 4,367.9 71.82 83.24 3,387.4 3,312.8 1,567.3 1,751.5 6,009,453.0 537,050.5 7.0 1,751.54 MWD+IFR-AK-CAZ-SC (3) 4,410.6 73.89 84.71 3,400.0 3,325.4 1,571.5 1,792.1 6,009,457.4 531,091.0 5.9 1,792.05 MWD+IFR-AK-CAZ-SC (3) ~ 4,461.4 76.71 87.08 3,412.9 3,338.3 1,575.0 1,841.1 6,009,461.1 531,140.0 7.1 1,841.11 MWD+IFR-AK-CAZ-SC (3) 4,505.5 78.02 88.98 3,422.5 3,347.9 1,576.5 1,884.0 6,009,462.8 531,183.0 5.2 1,884.05 MWD+IFR-AK-CAZ-SC (3) 4,556.0 78.98 90.82 3,432.6 3,358.0 1,576.6 1,933.5 6,009,463.1 531,232.4 4.0 1,933.53 MWD+IFR-AK-CAZ-SC (3) 4,601.1 79.49 91.25 3,441.0 3,366.4 1,575.8 1,977.8 6,009,462.4 531,276.7 1.5 1,977.82 MWD+IFR-AK-CAZ-SC (3) 4,652.4 80.02 92.20 3,450.1 3,375.5 1,574.3 2,028.3 6,009,461.1 531,327.2 2.1 2,028.27 MWD+IFR-AK-CAZ-SC (3) 4,696.2 80.69 91.72 3,457.5 3,382.9 1,572.8 2,071.5 6,009,459.8 531,370.4 1.9 2,071.49 MWD+IFR-AK-CAZ-SC (3) 4,746.5 79.80 91.86 3,466.0 3,391.4 1,571.2 2,121.1 6,009,458.4 531,420.0 1.8 2,121.07 MWD+IFR-AK-CAZ-SC (3) 4,791.8 78.43 91.66 3,474.6 3,399.9 1,569.9 2,165.5 6,009,457.3 531,464.4 3.1 2,165.51 MWD+IFR-AK-CAZ-SC (3) 4,842.5 79.91 90.24 3,484.1 3,409.5 1,569.1 2,215.2 6,009,456.6 531,514.1 4.0 2,215.23 MWD+IFR-AK-CAZ-SC (3) 4,886.8 80.56 89.28 3,491.6 3,417.0 1,569.2 2,258.9 6,009,457.0 531,557.8 2.6 2,258.91 MWD+IFR-AK-CAZ-SC (3) 4,937.5 81.24 90.19 3,499.6 3,425.0 1,569.5 2,309.0 6,009,457.4 531,607.9 2.2 2,309.00 MWD+IFR-AK-CAZ-SC (3) 4,982.8 81.86 90.10 3,506.3 3,431.7 1,569.4 2,353.8 6,009,457.5 531,652.7 1:4 2,353.80 MWD+IFR-AK-CAZ-SC (3) 5,034.0 81.03 89.18 3,513.9 3,439.3 1,569.7 2,404.5 6,009,458.0 531,703.3 2.4 2,404.47 MWD+IFR-AK-CAZ-SC (3) 5,077.5 82.17 88.73 3,520.3 3,445.6 1,570.5 2,447.5 6,009,458.9 531,746.4 2.8 2,447.48 MWD+IFR-AK-CAZ-SC (3) 5,126.6 85.19 86.98 3,525.6 3,451.0 1,572.3 2,496.2 6,009,461.0 531,795.0 7.1 2,496.18 MWD+IFR-AK-CAZ-SC (3) 5,172.4 85.50 86.56 3,529.4 3,454.8 1,574.9 2,541.8 6,009,463.7 531,840.6 1.2 2,541.81 MWD+IFR-AK-CAZ-SC (3) 5,267.4 85.34 87.16 3,537.0 3,462.3 1,580.1 2,636.3 6,009,469.3 531,935.2 0.7 2,636.34 MWD+IFR-AK-CAZ-SC (3) 5,363.5 84.83 88.08 3,545.2 3,470.6 1,584.0 2,732.0 6,009,473.6 532,030.8 1.1 2,732.00 MWD+IFR-AK-CAZ-SC (3) 5,395.3 85.18 87.61 3,548.0 3,473.3 1,585.2 2,763.7 6,009,475.0 532,062.5 1.8 2,763.70 MWD+IFR-AK-CAZ-SC (3) 5,497.1 84.86 89.56 3,556.8 3,482.2 1,587.7 2,865.1 6,009,477.9 532,163.8 1.9 2,865.06 MWD+IFR-AK-CAZ-SC (3) 5,592.4 88.75 91.10 3,562.1 3,487.5 1,587.2 2,960.1 6,009,477.7 532,258.9 4.4 2,960.12 MWD+IFR-AK-CAZ-SC (3) 5,685.4 88.69 91.05 3,564.2 3,489.6 1,585.4 3,053.1 6,009,476.3 532,351.9 0.1 3,053.11 MWD+IFR-AK-CAZ-SC (3) 5,784.0 88.08 91.43 3,567.0 3,492.3 1,583.3 3,151.7 6,009,474.5 532,450.5 0.7 3,151.72 MWD+IFR-AK-CAZ-SC (3) 5,877.7 88.26 89.81 3,570.0 3,495.3 1,582.3 3,245.4 6,009,473.9 532,544.1 1.7 3,245.35 MWD+IFR-AK-CAZ-SC (3) 5,974.2 90.85 91.22 3,570.7 3,496.1 1,581.4 3,341.8 6,009,473.4 532,640.6 3.1 3,341.84 MWD+IFR-AK-CAZ-SC (3) 12/15/2008 1:20:03PM Page 4 COMPASS 2003.16 Build 42F Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P63 Design: 3K-103P63 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: We113K-103 (E14) TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Calculation Method: Minimum Curvature Databaso: CPAI EDM Production Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 6,068.9 90.17 90.52 3,569.9 3,495.2 1,580.0 3,436.5 6,009,472.3 532,735.2 1.0 3,436.46 M`JUD+IFR-AK-CAZ-SC (3) 6,164.0 88.01 89.84 3,571.4 3,496.8 1,579.7 3,531.5 6,009,472.4 532,830.3 2.4 3,531.54 MWD+IFR-AK-CAZ-SC (3) 6,263.3 88.26 92.22 3,574.6 3,500.0 1,577.9 3,630.8 6,009,471.0 532,929.5 2.4 3,630.79 MWD+IFR-AK-CAZ-SC (3) 6,355.2 93.81 92.59 3,572.9 3,498.3 1,574.0 3,722.6 6,009,467.5 533,021.3 6.1 3,722.57 MWD+IFR-AK-CAZ-SC (3) 6,404.2 91.35 91.57 3,570.7 3,496.1 1,572.3 3,771.4 6,009,465.9 533,070.1 5.4 3,771.42 MWD+IFR-AK-CAZ-SC (3) 6,450.0 90.30 90.15 3,570.1 3,495.5 1,571.6 3,817.2 6,009,465.4 533,116.0 3.9 3,817.24 MWD+IFR-AK-CAZ-SC (3) 6,540.0 90.30 90.15 3,569.6 3,495.0 1,571.3 3,907.3 6,009,465.6 533,206.0 0.0 3,907.25 PROJECTED to TD 12/15/2008 1:20:03PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103PB4 Permit to Drill: 208-115 API: 50-029-23392-73 ,, ., ;.~ ~ M Definitive Survey Report 15 December, 2008 ~, ~~~,, . .. ~. '~ a .' L Sperry Clrillr--g a~rvi+c~rs Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P64 Design: 3K-103PB4 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: We113K-103 (E14) ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor -- _ We{{ 3K-103 (E14) Well Position +N/-S 0.0 ft Northing: 6,007,879.03 ft Latitude: 70° 25' 57.374 N +E/-W 0.0 ft Easting: 529,305.30 ft Longitude: 149° 45' 40.019 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 33.8ft Wellbore 3K-103PB4 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 1018/2008 22.54 80.90 57.648 -- Design - -- _- 3K-103PB4 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 5,877.7 Vertical Section: Depth From (ND) +N/-S +E/-W Direction (ft) 1ft) (ft) (°) L aos o.o o.o so.oo Survey Program Date From To (ft) (ft) Survey (Wellbore) Too{ Name Description Survey Date 50.0 621.0 3K-103P61 SRG (3K-103P61) CB-GYRO-SS Camera based gyro single shot 9/23!2008 1; I~ 672.5 2,862.2 3K-103PB1 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 '', 2,925.0 5,877.7 3K-103P63 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/31/2008 5,900.0 8,730.3 3K-103P64 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10!31/2008 Survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W '' Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) , (ft) (°1100') (ft) Survey Tool Name 40.8 0.00 0.00 40.8 -33.8 0.0 0.G 6,007,879.0 529,305.3 0.0 0.00 UNDEFfNED 50.0 0.20 73.45 50.0 -24.6 0.0 0.0 6,007,879.0 529,305.3 2.2 0.02 CB-GYRO-SS (1) 110.0 0.41 199.34 110.0 35.4 -0.2 0.0 6,007,878.9 529,305.3 0.9 0.04 CB-GYRO-SS (1) 170.0 0.46 75.98 170.0 95.4 -0.3 0.2 6,007,878.7 529,305.5 1.3 0.21 CB-GYRO-SS (1) 265.0 3.37 53.09 264.9 190.3 1.5 2.8 6,007,880.5 529,308.1 3.1 2.81 CB-GYRO-SS (1) 354.0 5.18 54.28 353.7 279.1 5.4 8.2 6,007,884.4 529,313.4 2.0 8.16 CB-GYRO-SS (1) 451.0 6.64 60.62 450.2 375.5 10.7 16.6 6,007,889.8 529,321.9 1.6 16.61 CB-GYRO-SS (1) 541.0 9.92 63.78 539.2 464.6 16.7 28.1 6,007,895.8 529,333.3 3.7 28.10 CB-GYRO-SS (1) 621.0 12.00 68.96 617.8 543.1 22.7 42.0 6,007,901.9 529,347.3 2.9 42.04 CB-GYRO-SS (1) 672.5 13.32 65.33 668.0 593.4 27.1 52.4 6,007,906.3 529,357.6 3.0 52.43 MWD+IFR-AK-CAZ-SC (2) 765.5 16.96 64.65 757.8 683.2 37.4 74.4 6,007,916.7 529,379.6 3.9 74.44 MWD+IFR-AK-CAZ-SC (2) 12/152008 1:21:O6PM Page 2 COMPASS 2003.16 Build 42F f Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wel Ibore: 3K-103P64 Design: 3K-103P64 Survey MD Inc Azl ND TVDSS +NI-S (ft) (°1 (°) lft) Iftl lftl 863.5 15.39 60.56 851.1 776.5 51.0 957.8 20.90 58.49 939.9 865.3 67.1 1,053.8 23.56 54.34 1,028.8 954.2 87.2 1,148.4 22.84 49.94 1,115.8 1,041.2 110.0 1,243.1 24.69 45.02 1,202.4 1,127.8 135.8 1,339.0 27.02 43.45 1,288.7 1,214.1 165.8 1,433.5 31.02 39.31 1,371.4 1,296.8 200.3 1,529.2 33.23 38.66 1,452.4 1,377.8 239.8 1,624.9 37.85 38.27 1,530.2 1,455.6 283.4 1,720.6 38.45 39.07 1,605.5 1,530.9 329.5 1,814.3 38.90 39.88 1,678.7 1,604.0 374.7 1,910.5 39.26 39.69 1,753.4 1,678.7 421.4 2,005.8 40.31 41.17 1,826.6 1,752.0 467.8 2,101.3 41.64 41.34 1,898.7 1,824.1 514.8 2,196.1 43.61 37.77 1,968.4 1,893.8 564.3 2,290.7 42.97 34.08 2,037.3 1,962.7 616.8 2,386.6 44.84 35.12 2,106.4 2,031.8 671.6 2,481.6 43.66 35.54 2,174.4 2,099.8 725.6 2,576.8 42.74 35.94 2,243.8 2,169.2 778.5 2,625.3 41.50 36.29 2,279.8 2,205.2 804.8 2,672.1 40.62 35.91 2,315.1 2,240.4 829.6 2,727.0 41.13 34.51 2,356.6 2,282.0 859.0 2,766.7 41.29 33.17 2,386.5 2,311.8 880.7 2,862.2 42.54 33.44 2,457.6 2,382.9 934.0 2,925.0 43.74 32.98 2,503.4 2,428.7 970.0 2,983.4 40.73 32.87 2,546.6 2,472.0 1,002.9 3,035.7 40.60 34.12 2,586.3 2,511.7 1,031.3 3,078.6 41.31 34.30 2,618.7 2,544.1 1,054.6 3,129.7 42.18 35.07 2,656.8 2,582.2 1,082.5 3,173.5 42.07 34.76 2,689.3 2,614.6 1,106.6 3,223.7 43.23 36.23 2,726.2 2,651.6 1,134.4 3,268.4 43.75 37.35 2,758.6 2,684.0 1,159.0 3,318.6 45.07 39.09 2,794.5 2,719.9 1,186.6 3,363.5 45.85 40.87 2,826.0 2,751.4 1,211.1 3,414.1 46.24 44.05 2,861.1 2,786.5 1,237.9 3,459.3 45.87 45.43 2,892.5 2,817.9 1,261.1 3,508.6 45.94 47.12 2,926.8 2,852.2 1,285.5 3,554.1 46.35 49.08 2,958.4 2,883.7 1,307.5 3,604.0 48.00 51.76 2,992.2 2,917.6 1,330.7 3,648.8 49.11 53.85 3,021.9 2,947.3 1,351.0 ConocoPhillips Definitive Survey Report C~ Local Co-ordinate Reference: We113K-103 (E14) TVD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) MD Refere nce: 3K-103 @ 74.6ft (D15 (33.8+40.82)) North Reference: True Survey Ca lculation Meth od: Minimum Curvature Database: CPAI EDM Production Map Map Vertical +E!-W Northing Easting DLS Section (ft) (ft) (ft) (° 1100') (ft) Survey Tool Name 100.8 6,007,930.4 529,405.9 1.9 900.84 MWD+IFR-AK-GAZ-SG (2) 128.2 6,007,946.6 529,433.2 2.8 128.19 MWD+IFR-AK-CAZ-SC (2) 158.4 6,007,966.8 529,463.3 3.2 158.38 MWD+IFR-AK-CAZ-SC (2) 187.8 6,007,989.8 529,492.7 2.0 187.81 MWD+IFR-AK-CAZ-SC (2) i 215.9 6,008,015.7 529,520.6 2.9 215.86 MWD+IFR-AK-CAZ-SC (2) 245.0 6,008,045.8 529,549.6 2.5 245.03 MWD+IFR-AK-CAZ-SC (2) 275.2 6,008,080.4 529,579.7 4.7 275.23 MWD+IFR-AK-CAZ-SC (2) 307.2 6,008,120.0 529,611.5 2.3 307.22 MWD+IFR-AK-CAZ-SC (2) 341.8 6,008,163.7 529,646.0 4.8 341.80 MWD+IFR-AK-CAZ-SC (2) 378.8 6,008,210.0 529,682.7 0.8 378.77 MWD+IFR-AK-CAZ-SC (2) 416.0 6,008,255.4 529,719.8 0.7 415.99 MWD+IFR-AK-CAZ-SC (2) 454.8 6,008,302.1 529,758.4 0.4 454.80 MWD+IFR-AK-CAZ-SC (2) 494.4 6,008,348.7 529,797.8 1.5 494.36 MWD+IFR-AK-CAZ-SC (2) 535.6 6,008,395.9 529,838.9 1.4 535.64 MWD+IFR-AK-CAZ-SC (2) 576.5 6,008,445.6 529,879.5 3.3 576.48 MWD+IFR-AK-CAZ-SC (2) 614.6 6,008,498.2 529,917.4 2.8 614.55 MWD+IFR-AK-CAZ-SC (2) 652.3 6,008,553.1 529,954.9 2.1 652.30 MWD+IFR-AK-CAZ-SC (2) 690.6 6,008,607.3 529,993.0 1.3 690.64 MWD+IFR-AK-CAZ-SC (2) 728.7 6,008,660.3 530,030.9 1.0 728.70 MWD+IFR-AK-CAZ-SC (2) 747.9 6,008,686.7 530,049.9 2.6 747.89 MWD+IFR-AK-CAZ-SC (2) 766.0 6,008,711.6 530,067.9 2.0 765.96 MWD+IFR-AK-CAZ-SC (2) 786.7 6,008,741.0 530,088.5 1.9 786.69 MWD+IFR-AK-CAZ-SC (2) 801.3 6,008,762.8 530,103.0 2.3 801.25 MWD+IFR-AK-CAZ-SC (2) 836.3 6,008,816.3 530,137.8 1.3 836.31 MWD+IFR-AK-CAZ-SC (2) 859.8 6,008,852.3 530,161.2 2.0 859.81 MWD+IFR-AK-CAZ-SC (3) 881.2 6,008,885.3 530,182.4 5.2 881.15 MWD+IFR-AK-CAZ-SC (3) 900.0 6,008,913.8 530,201.1 1.6 899.96 MWD+IFR-AK-CAZ-SC (3) 915.8 6,008,937.1 530,216.8 1.7 915.78 MWD+IFR-AK-CAZ-SC (3) 935.1 6,008,965.1 530,236.1 2.0 935.11 MWD+IFR-AK-CAZ-SC (3) 951.9 6,008,989.3 530,252.8 0.5 951.92 MWD+IFR-AK-CAZ-SC (3) 971.7 6,009,017.1 530,272.4 3.0 971.70 MWD+IFR-AK-CAZ-SC (3) 990.1 6,009,041.8 530,290.8 2.1 990.12 MWD+IFR-AK-CAZ-SC (3) 1,011.9 6,009,069.5 530,312.4 3.6 1,011.86 MWD+IFR-AK-CAZ-SC (3) 1,032.4 6,009,094.0 530,332.8 3.3 1,032.40 MWD+IFR-AK-CAZ-SC (3) 1,057.0 6,009,121.0 530,357.3 4.6 1,056.98 MWD+IFR-AK-CAZ-SC (3) 1,079.9 6,009,144.2 530,380.1 2.3 1,079.89 MWD+IFR-AK-CAZ-SC (3) 1,105.5 6,009,168.8 530,405.6 2.5 1,105.48 MWD+IFR-AK-CAZ-SC (3) 1,129.9 6,009,190.8 530,430.0 3.2 1,129.94 MWD+IFR-AK-CAZ-SC (3) 1,158.1 6,009,214.2 530,458.1 5.1 1,158.12 MWD+IFR-AK-CAZ-SC (3) 1,184.9 6,009,234.6 530,484.7 4.3 1,184.86 MWD+IFR-AK-CAZ-SC (3) 12/15/2008 1:21:O6PM Page 3 COMPASS 2003.16 Build 42F • • C onocoPhillips Definitive Surv ey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference:... We113K-103 (E14) Project: Kuparuk River Unit ND Refer ence: 3K-103 @ 74.6ft (D75 (33.8+40.82)) Site: 3K-Pad MD Refere nce: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E74) North Reference: True Wellbore: 3K-103P64 Survey Ca lculation Meth od: Minimum Curvature Design: 3K-103PB4 Database: CPAI EDM Production Survey Map Map Vertical MD (ft) Inc (°) Azi (°) ND (ft) NDSS (ft) +NI-S (ft) +Ei-W (ft} Northing (ft) Easting DLS (ft) (°1100') Section (ft) Survey Tool Name 3,701.5 50.92 56.05 3,055.3 2,981.2 1,374.2 1,217.9 6,005,257.5 530,517.7 4.7 1,217.94 MWD+IFR-AK-CAZ-SC (3) 3,744.4 50.48 57.62 3,082.9 3,008.3 1,392.4 1,245.7 6,009,276.2 530,545.4 3.0 1,245.72 MWD+IFR-AK-CAZ-SC (3) 3,794.4 51.10 59.30 3,114.6 3,039.9 1,412.7 1,278.8 6,009,296.6 530,578.4 2.9 1,278.75 MWD+IFR-AK-CAZ-SC (3) 3,838.6 52.56 60.86 3,141.8 3,067.2 1,430.0 1,308.8 6,009,314.0 530,608.4 4.3 1,308.83 MWD+IFR-AK-CAZ-SC (3) 3,893.7 54.65 62.71 3,174.5 3,099.9 1,450.9 1,347.9 6,009,335.1 530,647.4 4.7 1,347.91 MWD+IFR-AK-CAZ-SC (3) 3,933.5 56.54 64.14 3,197.0 3,122.4 1,465.6 1,377.3 6,009,349.9 530,676.7 5.6 1,377.29 MWD+IFR-AK-CAZ-SC (3) 3,983.5 58.77 67.62 3,223.8 3,149.2 1,482.8 1,415.8 6,009,367.3 530,715.1 7.4 1,415.82 MWD+IFR-AK-CAZ-SC (3) 4,028.2 60.93 69.77 3,246.3 3,171.6 1,496.9 1,451.9 6,009,381.5 530,751.1 6.4 1,451.87 MWD+IFR-AK-CAZ-SC (3) 4,078.4 62.54 72.12 3,270.0 3,195.4 1,511.3 1,493.7 6,009,396.1 530,792.9 5.2 1,493.66 MWD+IFR-AK-CAZ-SC (3) 4,123.8 62.53 73.97 3,291.0 3,216.4 1,523.1 1,532.2 6,009,408.0 530,831.4 3.6 1,532.20 MWD+IFR-AK-CAZ-SC (3) 4,174.4 63.87 75.80 3,313.8 3,239.2 1,534.8 1,575.8 6,009,419.9 530,874.9 4.2 1,575.82 MWD+IFR-AK-CAZ-SC (3) i 4,221.2 65.82 77.82 3,333.7 3,259.0 1,544.5 1,617.0 6,009,429.7 530,916.1 5.7 1,617.00 MWD+IFR-AK-CAZ-SC (3) 4,271.6 67.64 79.77 3,353.6 3,279.0 1,553.5 1,662.5 6,009,438.9 530,961.5 5.1 1,662.46 MWD+IFR-AK-CAZ-SC (3) 4,313.9 68.89 80.68 3,369.2 3,294.6 1,560.1 1,701.1 6,009,445.7 531,000.1 3.6 1,701.13 MWD+IFR-AK-CAZ-SC (3) 4,367.9 71.82 83.24 3,387.4 3,312.8 1,567.3 1,751.5 6,009,453.0 531,050.5 7.0 1,751.54 MWD+IFR-AK-CAZ-SC (3) 4,410.6 73.89 84.71 3,400.0 3,325.4 1,571.5 1,792.1 6,009,457.4 531,091.0 5.9 1,792.05 MWD+IFR-AK-CAZ-SC (3) 4,461.4 76.71 87.08 3,412.9 3,338.3 1,575.0 1,841.1 6,009,461.1 531,140.0 7.1 1,841.11 MWD+IFR-AK-CAZ-SC (3) 4,505.5 78.02 88.98 3,422.5 3,347.9 1,576.5 1,884.0 6,009,462.8 531,183.0 5.2 1,884.05 MWD+IFR-AK-CAZ-SC (3) 4,556.0 78.98 90.82 3,432.6 3,358.0 1,576.6 1,933.5 6,009,463.1 531,232.4 4.0 1,933.53 MWD+IFR-AK-CAZ-SC (3) 4,601.1 79.49 91.25 3,441.0 3,366.4 1,575.8 1,977.8 6,009,462.4 531,276.7 1.5 1,977.82 MWD+IFR-AK-CAZ-SC (3) 4,652.4 80.02 92.20 3,450.1 3,375.5 1,574.3 2,028.3 6,009,461.1 531,327.2 2.1 2,028.27 MWD+IFR-AK-CAZ-SC (3) I 4,696.2 80.69 91.72 3,457.5 3,382.9 1,572.8 2,071.5 6,009,459.8 531,370.4 1.9 2,071.49 MWD+IFR-AK-CAZ-SC (3) 4,746.5 79.80 91.86 3,466.0 3,391.4 1,571.2 2,121.1 6,009,458.4 531,420.0 1.8 2,121.07 MWD+IFR-AK-CAZ-SC (3) 4,791.8 78.43 91.66 3,474.6 3,399.9 1,569.9 2,165.5 6,009,457.3 531,464.4 3.1 2,165.51 MWD+IFR-AK-CAZ-SC (3) 4,842.5 79.91 90.24 3,484.1 3,409.5 1,569.1 2,215.2 6,009,456.6 531,514.1 4.0 2,215.23 MWD+IFR-AK-CAZ-SC (3) i 4,886.8 80.56 89.28 3,491.6 3,417.0 1,569.2 2,258.9 6,009,457.0 531,557.8 2.6 2,258.91 MWD+IFR-AK-CAZ-SC (3) 4,937.5 81.24 90.19 3,499.6 3,425.0 1,569.5 2,309.0 6,009,457.4 531,607.9 2.2 2,309.00 MWD+IFR-AK-CAZ-SC (3) 4,982.8 81.86 90.10 3,506.3 3,431.7 1,569.4 2,353.8 6,009,457.5 531,652.7 1.4 2,353.80 MWD+IFR-AK-CAZ-SC (3) 5,034.0 81.03 89.18 3,513.9 3,439.3 1,569.7 2,404.5 6,009,458.0 531,703.3 2.4 2,404.47 MWD+IFR-AK-CAZ-SC (3) 5,077.5 82.17 88.73 3,520.3 3,445.6 1,570.5 2,447.5 6,009,458.9 531,746.4 2.8 2,447.48 MWD+IFR-AK-CAZ-SC (3) I 5,126.6 85.19 86.98 3,525.6 3,451.0 1,572.3 2,496.2 6,009,461.0 531,795.0 7.1 2,496.18 MWD+IFR-AK-CAZ-SC (3) 5,172.4 85.50 86.56 3,529.4 3,454.8 1,574.9 2,541.8 6,009,463.7 531,840.6 1.2 2,541.81 MWD+IFR-AK-CAZ-SC (3) 5,267.4 85.34 87.16 3,537.0 3,462.3 1,580.1 2,636.3 6,009,469.3 531,935.2 0.7 2,636.34 MWD+IFR-AK-CAZ-SC (3) 5,363.5 84.83 88.08 3,545.2 3,470.6 1,584.0 2,732.0 6,009,473.6 532,030.8 1.1 2,732.00 MWD+IFR-AK-CAZ-SC (3) 5,395.3 85.18 87.61 3,548.0 3,473.3 1,585.2 2,763.7 6,009,475.0 532,062.5 1.8 2,763.70 MWD+IFR-AK-CAZ-SC (3) i 5,497.1 84.86 89.56 3,556.8 3,482.2 1,587.7 2,865.1 6,009,477.9 532,163.8 1.9 2,865.06 MWD+IFR-AK-CAZ-SC (3) 5,592.4 88.75 91.70 3,562.1 3,487.5 1,587.2 2,960.1 6,009,477.7 532,258.9 4.4 2,960.12 MWD+IFR-AK-CAZ-SC (3) 5,685.4 88.69 91.05 3,564.2 3,489.6 1,585.4 3,053.1 6,009,476.3 532,351.9 0.1 3,053.11 MWD+IFR-AK-CAZ-SC (3) 5,784.0 88.08 91.43 3,567.0 3,492.3 1,583.3 3,151.7 6,009,474.5 532,450.5 0.7 3,151.72 MWD+IFR-AK-CAZ-SC (3) 5,877.7 88.26 89.81 3,570.0 3,495.3 1,582.3 3,245.4 6,009,473.9 532,544.1 1.7 3,245.35 MWD+IFR-AK-CAZ-SC (3) 12/15/2008 1:21:06PM Page 4 COMPASS 2003.16 Build 42F • C onocoPhillips Definitive Survey Report ''Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: We113K-103 (E14) .Project: Kuparuk River Unit ND Refer ence: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Refere nce: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103PB4 Survey Ca lculation Method: Minimum Curvature Design: 3K-103P64 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azl ND NDSS +N/-S +E/-W Northing Easting D LS Section (ft) (°} (°} (ft) (ft) (ft) (ft) (ft) (ft} (°11 00') (ft) Survey Tool Name 5,900.0 88.86 90.13 3,510.5 .1,485.9 1,582.3 3,267.6 6,009,414.0 532,566.3 3.1 3,267.60 MWD+iFR-AK-CAZ-SG (4) 5,980.8 84.92 86.09 3,574.9 3,500.3 1,584.9 3,348.2 6,009,477.0 532,647.0 7.0 3,348.25 MWD+IFR-AK-CAZ-SC (4) 6,075.1 89.86 85.13 3,579.2 3,504.6 1,592.2 3,442.1 6,009,484.5 532,740.8 5.3 3,442.11 MWD+IFR-AK-CAZ-SC (4) 6,124.9 88.87 85.81 3,579.7 3,505.1 1,596.1 3,491.7 6,009,488.7 532,790.4 2.4 3,491.73 MWD+IFR-AK-CAZ-SC (4) 6,165.8 90.91 87.24 3,579.8 3,505.2 1,598.6 3,532.5 6,009,491.3 532,831.2 6.1 3,532.55 MWD+IFR-AK-CAZ-SC (4) 6,211.8 90.17 89.67 3,579.4 3,504.8 1,599.8 3,578.5 6,009,492.7 532,877.2 5.5 3,578.53 MWD+IFR-AK-CAZ-SC (4) 6,264.5 89.18 89.47 3,579.7 3,505.1 1,600.2 3,631.3 6,009,493.3 532,929.9 1.9 3,631.29 MWD+IFR-AK-CAZ-SC (4) 6,308.7 89.55 88.99 3,580.2 3,505.6 1,600.8 3,675.5 6,009,494.1 532,974.1 1.4 3,675.45 MWD+IFR-AK-CAZ-SC (4) 6,362.6 90.05 89.69 3,580.4 3,505.7 1,601.4 3,729.3 6,009,494.9 533,027.9 1.6 3,729.29 MWD+IFR-AK-CAZ-SC (4) 6,454.5 90.67 86.85 3,579.8 3,505.2 1,604.2 3,821.2 6,009,498.1 533,119.7 3.2 3,821.16 MWD+IFR-AK-CAZ-SC (4) 6,551.2 91.59 86.84 3,577.9 3,503.3 1,609.5 3,917.7 6,009,503.8 533,216.3 1.0 3,917.75 MWD+IFR-AK-CAZ-SC (4) 6,648.8 91.47 87.23 3,575.3 3,500.7 1,614.6 4,015.2 6,009,509.2 533,313.7 0.4 4,015.15 MWD+IFR-AK-CAZ-SC (4) 6,742.7 91.16 87.95 3,573.1 3,498.5 1,618.5 4,109.0 6,009,513.5 533,407.5 0.8 4,108.95 MWD+IFR-AK-CAZ-SC (4) 6,838.2 88.94 88.38 3,573.0 3,498.4 1,621.6 4,204.3 6,009,516.9 533,502.8 2.4 4,204.35 MWD+IFR-AK-CAZ-SC (4) 6,932.5 89.74 89.30 3,574.1 3,499.5 1,623.5 4,298.7 6,009,519.2 533,597.2 1.3 4,298.70 MWD+IFR-AK-CAZ-SC (4) 7,027.5 89.43 90.42 3,574.8 3,500.2 1,623.7 4,393.6 6,009,519.8 533,692.1 1.2 4,393.64 MWD+IFR-AK-CAZ-SC (4) 7,121.6 89.00 90.77 3,576.1 3,501.5 1,622.7 4,487.8 6,009,519.2 533,786.2 0.6 4,487.75 MWD+IFR-AK-CAZ-SC (4) 7,216.7 88.32 89.65 3,578.3 3,503.7 1,622.4 4,582.8 6,009,519.2 533,881.3 1.4 4,582.83 MWD+IFR-AK-CAZ-SC (4) 7,310.8 88.01 89.99 3,581.3 3,506.7 1,622.7 4,676.9 6,009,519.9 533,975.3 0.5 4,676.86 MWD+IFR-AK-CAZ-SC (4) 7,406.9 88.57 91.36 3,584.2 3,509.6 1,621.5 4,773.0 6,009,519.2 534,071.4 1.5 4,772.95 MWD+IFR-AK-CAZ-SC (4) 7,502.1 88.75 93.28 3,586.4 3,511.8 1,617.7 4,868.0 6,009,515.7 534,166.4 2.0 4,868.01 MWD+IFR-AK-CAZ-SC (4) 7,597.6 91.04 94.31 3,586.6 3,512.0 1,611.4 4,963.3 6,009,509.7 534,261.8 2.6 4,963.32 MWD+IFR-AK-CAZ-SC (4) 7,693.2 90.05 89.64 3,585.7 3,511.1 1,608.1 5,058.8 6,009,506.8 534,357.3 5.0 5,058.82 MWD+IFR-AK-CAZ-SC (4) 7,788.8 92.52 90.53 3,583.6 3,508.9 1,607.9 5,154.4 6,009,507.0 534,452.8 2.7 5,154.36 MWD+IFR-AK-CAZ-SC (4) 7,837.9 92.15 90.30 3,581.6 3,506.9 1,607.6 5,203.4 6,009,506.9 534,501.8 0.9 5,203.38 MWD+IFR-AK-CAZ-SC (4) 7,883.0 92.33 90.07 3,579.8 3,505.2 1,607.4 5,248.5 6,009,506.9 534,546.9 0.6 5,248.45 MWD+IFR-AK-CAZ-SC (4) 7,937.0 92.52 90.71 3,577.5 3,502.9 1,607.1 5,302.5 6,009,506.8 534,600.9 1.2 5,302.47 MWD+IFR-AK-CAZ-SC (4) 8,009.2 93.01 91.51 3,574.0 3,499.4 1,605.7 5,374.6 6,009,505.7 534,673.0 1.3 5,374.57 MWD+IFR-AK-CAZ-SC (4) 8,107.3 94.44 90.51 3,567.6 3,493.0 1,604.0 5,472.4 6,009,504.3 534,770.9 1.8 5,472.45 MWD+IFR-AK-CAZ-SC (4) ~ 8,198.3 93.94 90.10 3,561.0 3,486.4 1,603.5 5,563.2 6,009,504.2 534,861.6 0.7 5,563.20 MWD+IFR-AK-CAZ-SC (4) 8,292.6 93.08 88.43 3,555.2 3,480.6 1,604.7 5,657.2 6,009,505.8 534,955.6 2.0 5,657.24 MWD+IFR-AK-CAZ-SC (4) 8,388.4 91.78 88.50 3,551.2 3,476.5 1,607.2 5,752.9 6,009,508.7 535,051.3 1.4 5,752.93 MWD+IFR-AK-CAZ-SC (4) 8,486.7 88.57 90.57 3,550.9 3,476.2 1,608.0 5,851.2 6,009,509.9 535,149.6 3.9 5,851.22 MWD+IFR-AK-CAZ-SC (4) 8,577.9 88.63 92.12 3,553.1 3,478.5 1,605.9 5,942.4 6,009,508.1 535,240.7 1.7 5,942.39 MWD+IFR-AK-CAZ-SC (4) 8,675.3 93.01 93.37 3,551.7 3,477.1 1,601.2 6,039.6 6,009,503.8 535,338.0 4.7 6,039.58 MWD+IFR-AK-CAZ-SC (4) 8,730.3 93.14 93.95 3,548.8 3,474.1 1,597.7 6,094.5 6,009,500.5 535,392.8 1.1 6,094.45 MWD+IFR-AK-CAZ-SC (4) 8,794.0 93.14 93.95 3,545.3 3,470.6 1,593.4 6,157.9 6,009,496.4 535,456.3 0.0 6,157.89 PROJECTED to TD 12/15/2008 1:21:O6PM Page 5 COMPASS 2003.16 Build 42F • ConocoPhillips(Alaska) Inc. Kuparuk River Unit 3K-Pad 3K-103PB5 Permit to Drill: 208-115 API: 50-029-23392-74 .3. _ { - , 3~ " .. Definitive Survey Report 15 December, 2008 F~ ~.a>. ...... ~».. ... ... .. Ly Sperry C~riflirtg Sc3r+vlo£~~a • ConocoPhillips Definitive Sulvey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Well: 3K-103 (E14) North Reference: True Wellbore: 3K-103P65 Survey Calculation Method: Minimum Curvature Design: 3K-103PB5 -Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone:. Alaska Zone 04 Using geodetic scale factor WeU 3K-103 (E14) Well Position +N/-S 0.0 ft Northing: 6,007,879.03ft Latitude: 70° 25' 57.374 N +E/-W 0.0 ft Easting: 529,305.30 ft Longitude: 149° 45' 40.019 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 33.8ft ~ Wellbore 3K-103PB5 ~~ ~ Magnetics Model Name Sample Date Decllnatlon (°) BGGM2007 9/24/2008 2256 - --- D®sign 3K-103PB5 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (ND) +N!-S (ft) (ft) i 40.8 0.0 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 50.0 621.0 3K-i03P61 SRG (3K-103PB1) CB-GYRO-SS Gamera based gyro single shot 672.5 2,862.2 3K-103P61 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,925.0 5,877.7 3K-103P63 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,900.0 8,577.9 3K-103PB4 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,600.0 12,310.8 3K-103P65 MWD Back Corrected 2008- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Dip Angle (°) 130.90 Tie On Depth: 8,577.9 +E/-W Direction lft) (°) 0.0 90.00 Field Strength (nT) 57,647 Survey Date 9/23/2008 1: 10/31 /2008 10/31/2008 10/31 /2008 10/11/2008 Survey MD Inc Azi lftl (°) (°) 40.8 0.00 0.00 50.0 0.20 73.45 110.0 0.41 199.34 170.0 0.46 75.98 265.0 3.37 53.09 354.0 5.18 54.28 451.0 6.64 60.62 541.0 9.92 63.78 621.0 12.00 68.96 672.5 13.32 65.33 ND NDSS +N/-S (ft) (ft) (ft) 40.8 X3.8 0.0 50.0 -24.6 0.0 110.0 35.4 -0.2 170.0 95.4 -0.3 264.9 190.3 1.5 353.7 279.1 5.4 450.2 375.5 10.7 539.2 464.6 16.7 617.8 543.1 22.7 668.0 593.4 27.1 Map Map Vertical +Ei-W Northing Easting DLS Section (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 0.0 O,G07,::75.0 529,305.3 0.0 0.00 UNDEFINED 0.0 6,007,879.0 529,305.3 2.2 0.02 CB-GYRO-SS (1) 0.0 6,007,878.9 529,305.3 0.9 0.04 CB-GYRO-SS (1) 0.2 6,007,878.7 529,305.5 1.3 0.21 CB-GYRO-SS (1) 2.8 6,007,880.5 529,308.1 3.1 2.81 CB-GYRO-SS (1) 8.2 6,007,884.4 529,313.4 2.0 8.16 CB-GYRO-SS (1) 16.6 6,007,889.8 529,321.9 1.6 16.61 CB-GYRO-SS (1) 28.1 6,007,895.8 529,333.3 3.7 28.10 CB-GYRO-SS (1) 42.0 6,007,901.9 529,347.3 2.9 42.04 CB-GYRO-SS (1) 52.4 6,007,906.3 529,357.6 3.0 52.43 MWD+IFR-AK-CAZ-SC (2) 12/15/2008 1:22:02PM Page 2 COMPASS 2003. i6 Build 42F Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P65 Design: 3K-103P65 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference ND Reference: MU Reference: North Reference: Survey Calculation Method: Database: MD Inc Azi TVD TVDSS +NI-5 lft) (°) l°) (ft) lftl (ft) 765.5 16.y6 Ei4.ti5 757.8 683.2 37.4 863.5 18.39 60.86 851.1 776.5 51.0 957.8 20.90 58.49 939.9 865.3 67.1 1,053.8 23.56 54.34 1,028.8 954.2 87.2 1,148.4 22.84 49.94 1,115.8 7,041.2 110.0 1,243.1 24.69 45.02 1,202.4 1,127.8 135.8 1,339.0 27.02 43.45 1,288.7 1,214.1 165.8 1,433.5 31.02 39.31 1,371.4 1,296.8 200.3 1,529.2 33.23 38.66 1,452.4 1,377.8 239.8 1,624.9 37.85 38.27 1,530.2 1,455.6 283.4 1,720.6 38.45 39.07 1,605.5 1,530.9 329.5 1,814.3 38.90 39.88 7,678.7 1,604.0 374.7 1,910.5 39.26 39.69 1,753.4 1,678.7 421.4 2,005.8 40.31 41.17 1,826.6 1,752.0 467.8 2,101.3 41.64 41.34 1,898.7 1,824.1 514.8 2,196.1 43.61 37.77 1,968.4 1,893.8 564.3 2,290.7 42.97 34.08 2,037.3 1,962.7 616.8 2,386.6 44.84 35.12 2,106.4 2,031.8 671.6 2,481.6 43.66 35.54 2,174.4 2,099.8 725.6 2,576.8 42.74 35.94 2,243.8 2,169.2 778.5 2,625.3 41.50 36.29 2,279.8 2,205.2 804.8 2,672.1 40.62 35.91 2,315.1 2,240.4 829.6 2,727.0 41.13 34.51 2,356.6 2,282.0 859.0 2,766.7 41.29 33.17 2,386.5 2,311.8 880.7 2,862.2 42.54 33.44 2,457.6 2,382.9 934.0 2,925.0 43.74 32.98 2,503.4 2,428.7 970.0 2,983.4 40.73 32.87 2,546.6 2,472.0 1,002.9 3,035.7 40.60 34.12 2,586.3 2,511.7 1,031.3 3,078.6 41.31 34.30 2,618.7 2,544.1 1,054.6 3,129.7 42.18 35.07 2,656.8 2,582.2 1,082.5 3,173.5 42.07 34.76 2,689.3 2,614.6 1,106.6 3,223.7 43.23 36.23 2,726.2 2,651.6 1,134.4 3,268.4 43.75 37.35 2,758.6 2,684.0 1,159.0 3,318.6 45.07 39.09 2,794.5 2,719.9 1,186.6 3,363.5 45.85 40.87 2,826.0 2,751.4 1,211.1 3,414.1 46.24 44.05 2,861.1 2,786.5 1,237.9 3,459.3 45.87 45.43 2,892.5 2,817.9 1,261.1 3,508.6 45.94 47.12 2,926.8 2,852.2 1,285.5 3,554.1 46.35 49.08 2,958.4 2,883.7 1,307.5 3,604.0 48.00 51.76 2,992.2 2,917.6 1,330.7 Map +EI-W Northing {ft) (ftl 74.4 6,007,916.7 100.8 6,007,930.4 128.2 6,007,946.6 158.4 6,007,966.8 187.8 6,007,989.8 215.9 6,008,015.7 245.0 6,008,045.8 275.2 6,008,080.4 307.2 6,008,120.0 341.8 6,008,763.7 378.8 6,008,210.0 416.0 6,008,255.4 454.8 6,008,302.7 494.4 6,008,348.7 535.6 6,008,395.9 576.5 6,008,445.6 614.6 6,008,498.2 652.3 6,008,553.1 690.6 6,008,607.3 728.7 6,008,660.3 747.9 6,008,686.7 766.0 6,008,711.6 786.7 6,008,741.0 801.3 6,008,762.8 836.3 6,008,816.3 859.8 6,008,852.3 887.2 6,008,885.3 900.0 6,008,913.8 915.8 6,008,937.1 935.1 6,008,965.1 951.9 6,008,989.3 971.7 6,009,017.1 990.1 6,009,041.8 1,011.9 6,009,069.5 1,032.4 6,009,094.0 1,057.0 6,009,121.0 1,079.9 6,009,144.2 1,705.5 6,009,168.8 1,129.9 6,009,190.8 1,158.1 6,009,214.2 Well 3K-103 (E14) 3K-103 @ 74.6ft (D15 (33.8+40.82)) 3K-103 @ 74.6ft (D15 (33.8+40.82)) True Minimum Curvature CPAI EDM Production - I Map Vertical Fasting DLS Section (ft) (°1100') (ft) Survey Tool Name 529,379.6 3.9 74.44 MWD+IFR-AK-CAZ-SC (2) 529,405.9 1.9 100.84 MWD+IFR-AK-CAZ-SC (2) 529,433.2 2.8 128.19 MWD+IFR-AK-CAZ-SC (2) 529,463.3 3.2 158.38 MWD+IFR-AK-CAZ-SC (2) 529,492.7 2.0 187.81 MWD+IFR-AK-CAZ-SC (2) 529,520.6 2.9 215.86 MWD+IFR-AK-CAZ-SC (2) 529,549.6 2.5 245.03 MWD+IFR-AK-CAZ-SC (2) 529,579.7 4.7 275.23 MWD+IFR-AK-CAZ-SC (2) 529,611.5 2.3 307.22 MWD+IFR-AK-CAZ-SC (2) 529,646.0 4.8 341.80 MWD+IFR-AK-CAZ-SC (2) 529,682.7 0.8 378.77 MWD+IFR-AK-CAZ-SC (2) 529,719.8 0.7 415.99 MWD+IFR-AK-CAZ-SC (2) 529,758.4 0.4 454.80 MWD+IFR-AK-CAZ-SC (2) 529,797.8 1.5 494.36 MWD+IFR-AK-CAZ-SC (2) 529,838.9 1.4 535.64 MWD+IFR-AK-CAZ-SC (2) 529,879.5 3.3 576.48 MWD+IFR-AK-CAZ-SC (2) 529,917.4 2.8 614.55 MWD+IFR-AK-CAZ-SC (2) 529,954.9 2.1 652.30 MWD+IFR-AK-CAZ-SC (2) 529,993.0 1.3 690.64 MWD+IFR-AK-CAZ-SC (2) 530,030.9 1.0 728.70 MWD+IFR-AK-CAZ-SC (2) 530,049.9 2.6 747.89 MWD+IFR-AK-CAZ-SC (2) 530,067.9 2.0 765.96 MWD+IFR-AK-CAZ-SC (2) 530,088.5 1.9 786.69 MWD+IFR-AK-CAZ-SC (2) 530,103.0 2.3 801.25 MWD+IFR-AK-CAZ-SC (2) 530,137.8 1.3 836.31 MWD+IFR-AK-CAZ-SC (2) 530,161.2 2.0 859.81 MWD+IFR-AK-CAZ-SC (3) 530,182.4 5.2 881.15 MWD+IFR-AK-CAZ-SC (3) 530,201.1 1.6 899.96 MWD+IFR-AK-CAZ-SC (3) 530,216.8 1.7 915.78 MWD+IFR-AK-CAZ-SC (3) 530,236.1 2.0 935.11 MWD+IFR-AK-CAZ-SC (3) 530,252.8 0.5 951.92 MWD+IFR-AK-CAZ-SC (3) 530,272.4 3.0 971.70 MWD+IFR-AK-CAZ-SC (3) 530,290.8 2.1 990.12 MWD+IFR-AK-CAZ-SC (3) 530,312.4 3.6 1,011.86 MWD+IFR-AK-CAZ-SC (3) 530,332.8 3.3 1,032.40 MWD+IFR-AK-CAZ-SC (3) 530,357.3 4.6 1,056.98 MWD+IFR-AK-CAZ-SC (3) 530,380.1 2.3 1,079.89 MWD+IFR-AK-CAZ-SC (3) 530,405.6 2.5 1,105.48 MWD+IFR-AK-CAZ-SC (3) 530,430.0 3.2 1,129.94 MWD+IFR-AK-CAZ-SC (3) 530,458.1 5.1 1,158.12 MWD+IFR-AK-CAZ-SC (3) 12/15/2008 1:22:02PM Page 3 COMPASS 2003.16 Build 42F • Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P65 Design: 3K-103P65 Survey MD Inc (ft) f°) 3,648.8 49.11 3,701.5 50.92 3,744.4 50.48 3,794.4 51.10 3,838.6 52.56 3,893.7 54.65 3,933.5 56.54 3,983.5 58.77 4,028.2 60.93 4,078.4 62.54 4,123.8 62.53 4,174.4 63.87 4,221.2 65.82 4,271.6 67.64 4,313.9 68.89 4,367.9 71.82 4,410.6 73.89 4,461.4 76.71 4,505.5 78.02 4,556.0 78.98 4,601.1 79.49 4,652.4 80.02 4,696.2 80.69 4,746.5 79.80 4,791.8 78.43 4,842.5 79.91 4,886.8 80.56 4,937.5 81.24 4,982.8 81.86 5,034.0 81.03 5,077.5 82.17 5,126.6 85.19 5,172.4 85.50 5,267.4 85.34 5,363.5 84.83 5,395.3 85.18 5,497.1 84.86 5,592.4 88.75 5,685.4 88.69 5,784.0 88.08 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Azi ND NDSS +N/-S 1`1 (ft) (ft) (ft) 53.65 3,021.9 2,947.3 1,351.0 56.05 3,055.8 2,981.2 1,374.2 57.62 3,082.9 3,008.3 1,392.4 59.30 3,114.6 3,039.9 1,412.7 60.86 3,141.8 3,067.2 1,430.0 62.71 3,174.5 3,099.9 1,450.9 64.14 3,197.0 3,122.4 1,465.6 67.62 3,223.8 3,149.2 1,482.8 69.77 3,246.3 3,171.6 1,496.9 72.12 3,270.0 3,195.4 1,511.3 73.97 3,291.0 3,216.4 1,523.7 75.80 3,313.8 3,239.2 1,534.8 77.82 3,333.7 3,259.0 1,544.5 79.77 3,353.6 3,279.0 1,553.5 80.68 3,369.2 3,294.6 1,560.1 83.24 3,387.4 3,312.8 1,567.3 84.71 3,400.0 3,325.4 1,571.5 87.08 3,412.9 3,338.3 1,575.0 88.98 3,422.5 3,347.9 1,576.5 90.82 3,432.6 3,358.0 1,576.6 91.25 3,441.0 3,366.4 1,575.8 92.20 3,450.1 3,375.5 1,574.3 91.72 3,457.5 3,382.9 1,572.8 91.86 3,466.0 3,391.4 1,571.2 91.66 3,474.6 3,399.9 1,569.9 90.24 3,484.1 3,409.5 1,569.1 89.28 3,491.6 3,417.0 1,569.2 90.19 3,499.6 3,425.0 1,569.5 90.10 3,506.3 3,431.7 1,569.4 89.18 3,513.9 3,439.3 1,569.7 88.73 3,520.3 3,445.6 1,570.5 86.98 3,525.6 3,451.0 1,572.3 86.56 3,529.4 3,454.8 1,574.9 87.16 3,537.0 3,462.3 1,580.1 88.08 3,545.2 3,470.6 1,584.0 87.61 3,548.0 3,473.3 1,585.2 89.56 3,556.8 3,482.2 1,587.7 91.10 3,562.1 3,487.5 1,587.2 91.05 3,564.2 3,489.6 1,585.4 91.43. 3,567.0 3,492.3 1,583.3 Map +E/-W Northing Ift) (ft) 1,184.9 6,009,234.6 1,217.9 6,009,257.9 1,245.7 6,009,276.2 1,278.8 6,009,296.6 1,308.8 6,009,314.0 1,347.9 6,009,335.1 1,377.3 6,009,349.9 1,415.8 6,009,367.3 1,451.9 6,009,381.5 1,493.7 6,009,396.1 1,532.2 6,009,408.0 1,575.8 6,009,419.9 1,617.0 6,009,429.7 1,662.5 6,009,438.9 1,701.1 6,009,445.7 1,751.5 6,009,453.0 1,792.1 6,009,457.4 1,841.1 6,009,461.1 1,884.0 6,009,462.8 1,933.5 6,009,463.1 1,977.8 6,009,462.4 2,028.3 6,009,461.1 2,071.5 6,009,459.8 2,121.1 6,009,458.4 2,165.5 6,009,457.3 2,215.2 6,009,456.6 2,258.9 6,009,457.0 2,309.0 6,009,457.4 2,353.8 6,009,457.5 2,404.5 6,009,458.0 2,447.5 6,009,458.9 2,496.2 6,009,461.0 2,541.8 6,009,463.7 2,636.3 6,009,469.3 2,732.0 6,009,473.6 2,763.7 6,009,475.0 2,865.1 6,009,477.9 2,960.1 6,009,477.7 3,053.1 6,009,476.3 3,151.7 6,009,474.5 C~ We113K-103 (E14) 3K-103 @ 74.6ft (D15 (33.8+40.82)) 3K-103 @ 74.6ft (D15 (33.8+40.82)) True Minimum Curvature CPAI EDM Production -- f Map Vertical Fasting DLS Section (ft) (°1100') (ft) Survey Tool Name 530,484.7 4.3 1,184.86 MWD+IFR-AK-CAZ-SG (3) 530,517.7 4.7 1,217.94 MWD+IFR-AK-CAZ-SC (3) 530,545.4 3.0 1,245.72 MWD+IFR-AK-CAZ-SC (3) 530,578.4 2.9 1,278.75 MWD+IFR-AK-CAZ-SC (3) 530,608.4 4.3 1,308.83 MWD+IFR-AK-CAZ-SC (3) 530,647.4 4.7 1,347.91 MWD+IFR-AK-CAZ-SC (3) 530,676.7 5.6 1,377.29 MWD+IFR-AK-CAZ-SC (3) 530,715.1 7.4 1,415.82 MWD+IFR-AK-CAZ-SC (3) 530,751.1 6.4 1,451.87 MWD+IFR-AK-CAZ-SC (3) 530,792.9 5.2 1,493.66 MWD+IFR-AK-CAZ-SC (3) 530,831.4 3.6 1,532.20 MWD+IFR-AK-CAZ-SC (3) 530,874.9 4.2 1,575.82 MWD+IFR-AK-CAZ-SC (3) 530,916.1 5.7 1,617.00 MWD+IFR-AK-CAZ-SC (3) 530,961.5 5.1 1,662.46 MWD+IFR-AK-CAZ-SC (3) 531,000.1 3.6 1,701.13 MWD+IFR-AK-CAZ-SC (3) 531,050.5 7.0 1,751.54 MWD+IFR-AK-CAZ-SC (3) 531,091.0 5.9 1,792.05 MWD+IFR-AK-CAZ-SC (3) 531,140.0 7.1 1,841.11 MWD+IFR-AK-CAZ-SC (3) 531,183.0 5.2 1,884.05 MWD+IFR-AK-CAZ-SC (3) 531,232.4 4.0 1,933.53 MWD+IFR-AK-CAZ-SC (3) 531,276.7 1.5 1,977.82 MWD+IFR-AK-CAZ-SC (3) 531,327.2 2.1 2,028.27 MWD+IFR-AK-CAZ-SC (3) 531,370.4 1.9 2,071.49 MWD+IFR-AK-CAZ-SC (3) 531,420.0 1.8 2,121.07 MWD+IFR-AK-CAZ-SC (3) 531,464.4 3.1 2,165.51 MWD+IFR-AK-CAZ-SC (3) 531,514.1 4.0 2,215.23 MWD+IFR-AK-CAZ-SC (3) 531,557.8 2.6 2,258.91 MWD+IFR-AK-CAZ-SC (3) 531,607.9 2.2 2,309.00 MWD+IFR-AK-CAZ-SC (3) 531,652.7 1.4 2,353.80 MWD+IFR-AK-CAZ-SC (3) 531,703.3 2.4 2,404.47 MWD+IFR-AK-CAZ-SC (3) 531,746.4 2.8 2,447.48 MWD+IFR-AK-CAZ-SC (3) 531,795.0 7.1 2,496.18 MWD+IFR-AK-CAZ-SC (3) 531,840.6 1.2 2,541.81 MWD+IFR-AK-CAZ-SC (3) 531,935.2 0.7 2,636.34 MWD+IFR-AK-CAZ-SC (3) 532,030.8 1.1 2,732.00 MWD+IFR-AK-CAZ-SC (3) 532,062.5 1.8 2,763.70 MWD+IFR-AK-CAZ-SC (3) 532,163.8 1.9 2,865.06 MWD+IFR-AK-CAZ-SC (3) 532,258.9 4.4 2,960.12 MWD+IFR-AK-CAZ-SC (3) 532,351.9 0.1 3,053.11 MWD+IFR-AK-CAZ-SC (3) 532,450.5 0.7 3,151.72 MWD+IFR-AK-CAZ-SC (3) 12/15/2008 1:22:02PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Definitive Surv ey Report Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Refer ence: We113K-103 (E14) Project: Kuparuk River Unit ND Reference: 3K-103 @ 74.6ft (D15 (33.8+40.82)) Site: 3K-Pad MD Refere nce: 3K-103 @ 74.6ft (D75 (33.8+40.82)) Well: 3K-10 3 (E14) North Reference: True Wellbore: 3K-10 3PB5 Survey Ca lculation Method: Minimum Curvature Design: 3K-103P65 Database: CPAI EDM Production ', Survey Map Map Vertical MD (ft) Inc (°) Azi (°) ND (ft) NDSS (ft) +N/-S (ft) +E!-W (ft) Northing (ft) Easting DLS (ft) (°1100') Section (ft) Survey Tool Name 5,877.7 23.26 29.21 3,570.0 3,495.3 1,582.3 3,245.4 6,005,473.9 532,544.1 1.7 3,245.35 MWp+IFR-AK-CAZ-SG (3) 5,900.0 88.86 90.13 3,570.5 3,495.9 1,582.3 3,267.6 6,009,474.0 532,566.3 3.1 3,267.60 MWD+IFR-AK-CAZ-SC (4) 5,980.8 84.92 86.09 3,574.9 3,500.3 1,584.9 3,348.2 6,009,477.0 532,647.0 7.0 3,348.25 MWD+IFR-AK-CAZ-SC (4) 6,075.1 89.86 85.13 3,579.2 3,504.6 1,592.2 3,442.1 6,009,484.5 532,740.8 5.3 3,442.11 MWD+IFR-AK-CAZ-SC (4) 6,124.9 88.87 85.81 3,579.7 3,505.1 1,596.1 3,491.7 6,009,488.7 532,790.4 2.4 3,491.73 MWD+IFR-AK-CAZ-SC (4) 6,165.8 90.91 87.24 3,579.8 3,505.2 1,598.6 3,532.5 6,009,491.3 532,831.2 6.1 3,532.55 MWD+IFR-AK-CAZ-SC (4) 6,211.8 90.17 89.67 3,579.4 3,504.8 1,599.8 3,578.5 6,009,492.7 532,877.2 5.5 3,578.53 MWD+IFR-AK-CAZ-SC (4) 6,264.5 89.18 89.47 3,579.7 3,505.1 1,600.2 3,631.3 6,009,493.3 532,929.9 1.9 3,631.29 MWD+IFR-AK-CAZ-SC (4) 6,308.7 89.55 88.99 3,580.2 3,505.6 1,600.8 3,675.5 6,009,494.1 532,974.1 1.4 3,675.45 MWD+IFR-AK-CAZ-SC (4) 6,362.6 90.05 89.69 3,580.4 3,505.7 1,601.4 3,729.3 6,009,494.9 533,027.9 1.6 3,729.29 MWD+IFR-AK-CAZ-SC (4) 6,454.5 90.67 86.85 3,579.8 3,505.2 1,604.2 3,821.2 6,009,498.1 533,119.7 3.2 3,821.16 MWD+IFR-AK-CAZ-SC (4) 6,551.2 91.59 86.84 3,577.9 3,503,3 1,609.5 3,917.7 6,009,503.8 533,216.3 1.0 3,917.75 MWD+IFR-AK-CAZ-SC (4) 6,648.8 91.47 87.23 3,575.3 3,500.7 1,614.6 4,015.2 6,009,509.2 533,313.7 0.4 4,015.15 MWD+IFR-AK-CAZ-SC (4) 6,742.7 91.16 87.95 3,573.1 3,498.5 1,618.5 4,109.0 6,009,513.5 533,407.5 0.8 4,108.95 MWD+IFR-AK-CAZ-SC (4} 6,838.2 88.94 88.38 3,573.0 3,498.4 1,621.6 4,204.3 6,009,516.9 533,502.8 2.4 4,204.35 MWD+IFR-AK-CAZ-SC (4) 6,932.5 89.74 89.30 3,574.1 3,499.5 1,623.5 4,298.7 6,009,519.2 533,597.2 1.3 4,298.70 MWD+IFR-AK-CAZ-SC (4) 7,027.5 89.43 90.42 3,574.8 3,500.2 1,623.7 4,393.6 6,009,519.8 533,692.1 1.2 4,393.64 MWD+IFR-AK-CAZ-SC (4) 7,121.6 89.00 90.77 3,576.1 3,501.5 1,622.7 4,487.8 6,009,519.2 533,786.2 0.6 4,487.75 MWD+IFR-AK-CAZ-SC (4) 7,216.7 88.32 89.65 3,578.3 3,503.7 1,622.4 4,582.8 6,009,519.2 533,881.3 1.4 4,582.83 MWD+IFR-AK-CAZ-SC (4) 7,310.8 88.01 89.99 3,581.3 3,506.7 1,622.7 4,676.9 6,009,519.9 533,975.3 0.5 4,676.86 MWD+IFR-AK-CAZ-SC (4) 7,406.9 88.57 91.36 3,584.2 3,509.6 1,621.5 4,773.0 6,009,519.2 534,071.4 1.5 4,772.95 MWD+IFR-AK-CAZ-SC (4) 7,502.1 88.75 93.28 3,586.4 3,511.8 1,617.7 4,868.0 6,009,515.7 534,166.4 2.0 4,868.01 MWD+IFR-AK-CAZ-SC (4) 7,597.6 91.04 94.31 3,586.6 3,512.0 1,611.4 4,963.3 6,009,509.7 534,261.8 2.6 4,963.32 MWD+IFR-AK-CAZ-SC (4) 7,693.2 90.05 89.64 3,585.7 3,511.1 1,608.1 5,058.8 6,009,506.8 534,357.3 5.0 5,058.82 MWD+IFR-AK-CAZ-SC (4) 7,788.8 92.52 90.53 3,583.6 3,508.9 1,607.9 5,154.4 6,009,507.0 534,452.8 2.7 5,154.36 MWD+IFR-AK-CAZ-SC (4) 7,837.9 92.15 90.30 3,581.6 3,506.9 1,607.6 5,203.4 6,009,506.9 534,501.8 0.9 5,203.38 MWD+IFR-AK-CAZ-SC (4) 7,883.0 92.33 90.07 3,579.8 3,505.2 1,607.4 5,248.5 6,009,506.9 534,546.9 0.6 5,248.45 MWD+IFR-AK-CAZ-SC (4) 7,937.0 92.52 90.71 3,577.5 3,502.9 1,607.1 5,302.5 6,009,506.8 534,600.9 1.2 5,302.47 MWD+IFR-AK-CAZ-SC (4) 8,009.2 93.01 91.51 3,574.0 3,499.4 1,605.7 5,374.6 6,009,505.7 534,673.0 1.3 5,374.57 MWD+IFR-AK-CAZ-SC (4) 8,107.3 94.44 90.51 3,567.6 3,493.0 1,604.0 5,472.4 6,009,504.3 534,770.9 1.8 5,472.45 MWD+IFR-AK-CAZ-SC (4) 8,198.3 93.94 90.10 3,561.0 3,486.4 1,603.5 5,563.2 6,009,504.2 534,861.6 0.7 5,563.20 MWD+IFR-AK-CAZ-SC (4) 8,292.6 93.08 88.43 3,555.2 3,480.6 1,604.7 5,657.2 6,009,505.8 534,955.6 2.0 5,657.24 MWD+IFR-AK-CAZ-SC (4) 8,388.4 91.78 88.50 3,551.2 3,476.5 1,607.2 5,752.9 6,009,508.7 535,051.3 1.4 5,752.93 MWD+IFR-AK-CAZ-SC (4) 8,486.7 88.57 90.57 3,550.9 3,476.2 1,608.0 5,851.2 6,009,509.9 535,149.6 3.9 5,851.22 MWD+IFR-AK-CAZ-SC (4) 8,577.9 88.63 92.12 3,553.1 3,478.5 1,605.9 5,942.4 6,009,508.1 535,240.7 1.7 5,942.39 MWD+IFR-AK-CAZ-SC (4) 8,600.0 89.62 92.48 3,553.4 3,478.8 1,605.0 5,964.5 6,009,507.3 535,262.8 4.8 5,964.45 MWD+IFR-AK-CAZ-SC (5) 8,674.6 87.90 93.71 3,555.0 3,480.4 1,601.0 6,038.9 6,009,503.6 535,337.3 2.8 6,038.89 MWD+IFR-AK-CAZ-SC (5) 8,770.6 88.69 95.62 3,557.9 3,483.3 1,593.2 6,134.5 6,009,496.1 535,432.9 2.2 6,134.52 MWD+IFR-AK-CAZ-SC (5) 8,865.7 88.32 99.04 3,560.4 3,485.8 1,581.0 6,228.8 6,009,484.4 535,527.3 3.6 6,228.83 MWD+IFR-AK-CAZ-SC (5) 8,961.5 89.55 99.23 3,562.2 3,487.5 1,565.8 6,323.4 6,009,469.5 535,621.8 1.3 6,323.37 MWD+IFR-AK-CAZ-SC (5) 12/15/2008 1:22:02PM Page 5 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: 3K-Pad Well: 3K-103 (E14) Wellbore: 3K-103P65 Design: 3K-103P65 Survey MD Inc (ft1 1°1 9,055.9 90.36 9,151.3 89.86 9,246.1 88.75 9,341.9 87.39 9,436.9 87.21 9,531.5 89.25 9,627.3 88.75 9,722.2 87.45 9,817.3 87.76 9,916.4 87:58 Azi TVD (ft) 3,562.2 3,562.1 3,563.2 3,566.4 3,570.9 3,573.8 3,575.5 3,578.7 3,582.6 3,586.7 TVDSS lftl 3,467.6 3,487.4 3,488.6 3,491.8 3,496.3 3,499.2 3,500.9 3,504.0 3,508.0 3,512.0 3,512.3 3,509.0 3,507.5 3,508.1 3,510.2 3,573.2 3,514.8 3,514.3 3,513.2 3,513.8 93.99 98.24 97.24 96.04 95.39 95.24 93.81 93.33 93.20 94.53 10,007.0 92.08 95.48 3,586.9 10,103.5 91.90 96.25 3,583.6 10,198.0 89.92 96.32 3,582.1 10,290.4 89.24 96.64 3,582.7 10,388.2 88.32 97.06 3,584.8 10,482.5 88.01 96.91 3,587.8 10,575.6 90.05 97.58 3,589.4 10,671.2 90.60 98.10 3,588.9 10,769.1 90.67 96.29 3,587.8 10,864.3 88.57 93.99 3,588.4 10,959.0 88.44 93.29 3,590.9 11,054.1 87.64 94.66 3,594.2 11,149.7 89.68 96.83 3,596.4 11,248.1 89.55 97.22 3,597.0 11,337.7 88.51 96.11 3,598.6 11,435.6 86.22 97.09 3,603.1 11,529.8 84.43 96.45 3,610.7 11,625.0 84.05 96.82 3,620.3 11,721.3 84.17 96.95 3,630.2 11,815.9 87.89 96.54 3,636.7 11,911.5 89.68 96.98 3,638.8 12,005.7 89.12 96.49 3,639.7 12,101.8 87.33 96.14 3,642.7 12,196.3 89.00 95.71 3,645.7 12,292.4 90.91 96.68 3,645.8 12,310.8 90.85 96.31 3,645.5 12,373.0 90.85 96.31 3,644.6 3,5 t 6.3 3,519.5 3,521.8 3,522.4 3,523.9 3,528.4 3,536.1 3,545.7 3,555.6 3,562.1 3,564.1 3,565.1 3,568.1 3,571.1 3,571.2 +N/-S (ft) 1,550.9 1,536.6 1,523.8 1,512.8 1,503.3 1,494.6 1,487.0 1,481.1 1,475.7 1,469.0 1,461.1 1,451.3 1,440.9 1,430.5 1,418.8 1,407.4 1,395.6 1,382.6 1,370.3 1,361.8 1,355.8 1,349.2 1,339.6 1,327.6 1,317.2 1,305.9 1,294.9 1,283.9 1,272.4 1,261.4 1,250.1 1,239.1 1,228.5 1,218.8 1,208.4 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: +E/-W (ft) 6,416.6 6,511.0 6,604.9 6,699.9 6,794.3 6,888.5 6,984.0 7,078.7 7,173.5 7,272.4 7,362.6 7,458.4 7,552.4 7,644.2 7.741.3 7,834.8 7,927.2 8,021.9 8,119.1 8,213.8 8,308.3 8,403.1 8,498.1 8,595.8 8,684.8 8,782.0 8,875.1 8,969.3 9,064.4 9,158.1 9,253.0 9,346.5 9,442.0 9,535.9 9,631.5 3,570.9 1,206.3 9,649.8 3,570.0 1,199.5 9,711.6 We113K-103 (E14) 3K-103 @ 74.6ft (D15 (33.8+40.82)) 3K-103 @ 74.6ft (D15 (33.8+40.82)) True Minimum Curvature GPAI EDM Production Map Map Vertical Northing Easting DLS Section (ft) (ft) (°/100') (ft) Survey Tool Name 6,009,455.0 535,715.2 0.9 6,416.64 MWD+IFR-FMK-GAZ-SC (5~ 6,009,441.0 535,809.5 0.9 6,510.98 MWD+IFR-AK-CAZ-SC (5) 6,009,428.6 535,903.5 1.6 6,604.87 MWD+IFR-AK-CAZ-SC (5) 6,009,418.0 535,998.6 1.9 6,699.93 MWD+IFR-AK-CAZ-SC (5) 6,009,408.9 536,093.0 0.7 6,794.34 MWD+IFR-AK-CAZ-SC (5) 6,009,400.5 536,187.2 2.2 6,888.48 MWD+IFR-AK-CAZ-SC (5) 6,009,393.3 536,282.7 1.6 6,983.99 MWD+IFR-AK-CAZ-SC (5) 6,009,387.8 536,377.4 1.5 7,078.72 MWD+IFR-AK-CAZ-SC (5) 6,009,382.7 536,472.3 0.4 7,173.53 MWD+IFR-AK-CAZ-SC (5) 6,009,376.5 536,571.1 1.3 7,272.36 MWD+IFR-AK-CAZ-SC (5) 6,009,368.9 536,661.3 5.1 7,362.56 MWD+IFR-AK-CAZ-SC (5) 6,009,359.4 536,757.2 0.8 7,458.45 MWD+IFR-AK-CAZ-SC (5) 6,009,349.5 536,851.2 2.1 7,552.40 MWD+IFR-AK-CAZ-SC (5) 6,009,339.4 536,943.1 0.8 7,644.24 MWD+IFR-AK-CAZ-SC (5) 6,009,328.1 537,040.2 1.0 7,741.33 MWD+IFR-AK-CAZ-SC (5) 6,009,317.0 537,133.7 0.4 7,834.79 MWD+IFR-AK-CAZ-SC (5) 6,009,305.7 537,226.2 2.3 7,927.20 MWD+IFR-AK-CAZ-SC (5) 6,009,293.0 537,320.9 0.8 8,021.92 MWD+IFR-AK-CAZ-SC (5) 6,009,281.1 537,418.1 1.8 8,119.05 MWD+IFR-AK-CAZ-SC (5) 6,009,273.0 537,512.9 3.3 8,213.84 MWD+IFR-AK-CAZ-SC (5) 6,009,267.3 537,607.4 0.8 8,308.29 MWD+IFR-AK-CAZ-SC (5) 6,009,261.1 537,702.2 1.7 8,403.08 MWD+IFR-AK-CAZ-SC (5) 6,009,251.9 537,797.3 3.1 8,498.13 MWD+IFR-AK-CAZ-SC (5) 6,009,240.2 537,895.0 0.4 8,595.79 MWD+IFR-AK-CAZ-SC (5) 6,009,230.2 537,984.0 1.7 8,684.83 MWD+IFR-AK-CAZ-SC (5) 6,009,219.3 538,081.2 2.5 8,781.95 MWD+IFR-AK-CAZ-SC (5) 6,009,208.6 538,174.4 2.0 8,875.14 MWD+IFR-AK-CAZ-SC (5) 6,009,198.0 538,268.6 0.6 8,969.28 MWD+IFR-AK-CAZ-SC (5) 6,009,186.9 538,363.7 0.2 9,064.35 MWD+IFR-AK-CAZ-SC (5) 6,009,176.2 538,457.5 4.0 9,158.09 MWD+IFR-AK-CAZ-SC (5) 6,009,165.4 538,552.4 1.9 9,253.00 MWD+IFR-AK-CAZ-SC (5) 6,009,154.7 538,645.9 0.8 9,346.51 MWD+IFR-AK-CAZ-SC (5) 6,009,144.5 538,741.4 1.9 9,441.96 MWD+IFR-AK-CAZ-SC (5) 6,009,135.1 538,835.4 1.8 9,535.93 MWD+IFR-AK-CAZ-SC (5) 6,009,125.1 538,931.0 2.2 9,631.49 MWD+IFR-AK-CAZ-SC (5) 6,009,123.1 538,949.3 2.0 9,649.76 MWD+IFR-AK-CAZ-SC (5) 6,009,116.5 539,011.1 0.0 9,711.56 PROJECTED to TD 12/15/2008 1:22:02PM Page 6 COMPASS 2003.16 Build 42F 3K-103 PB6 -Permit Number,~8-115 Maunder, Thomas E (DOA) From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Monday, October 27, 2008 9:56 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: 3K-103 PB6 -Permit Number 208-115 Attachments: B-Lateral Cement squeeze.doc Tom, Details of our last plugback are as follows; Well: 3K-103 Rig: Doyon 15 Date: 10/24/2008 Time: 19:45 hrs I.,ast Casing : 9-5/8" set at 5,437'MI) MD of abandoned section: x,453 - 12,373'MD Page i of 1 Our mainbore B-lateral liner became stuck while running at ,., 8,386.55' MD. ~'Ve were able to retrieve some of the liner with top offish tagged at 5,733'MD. We abandoned the fish. and squeezed approximately 145 bbls of 1 ~.8ppg cement in the old hole using a cement retainer set at approximately 5,733'MD. Details of the cement squeeze are attached. «B-Lateral Cement squeeze.doc» Please contact me if further details are required...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConacoPl~illps Alaska - ATO-1592 Office :907-265-6862 Cell :907-980-143 3 Fax :9t)7-26.5-153 1 / 12/2009 Turn over to Schlumberger for cement job. Flooded lines with 10 bbls of brine and pressure tested to 3500 psi. With annular preventor closed sting into retainer and perform infectivity test using 9.1 ppg brine. .5 bpm / 50 psi 1 bpm / 100 psi 1.5 bpm / 180 psi 2 bpm / 245 psi Infectivity test was done three times due to problems with pressure sensors. Pumped total of 51 bbls into formation. Unsting and pump 10 bbls CW 100 followed by 79.5 bbls of cement. Pump at 5 bpm holding backpressure using choke. Stop pumping and sting into retainer. Pump 70.9 bbls of cement at 1.7 bpm. DPP 0 psi. Total of 150.4 bbls cement pumped. Chase cement with 10 bbls of water and 15 bbls of brine at 1.7 bpm, DPP 0 psi. 73.1 bbls cement out intermediate casing shoe Stop displacement and begin hesitations at 04:40 Format of following time, starting DPP pressure brine pumped, pmp rate, ending DPP, bbls cement out shoe 05:15, Opsi 8bbls, 1 bpm, 0 psi, 81 bbls 05:45, 0 psi 8bbls, 1 bpm, 0 psi, 89 bbls 06:15, 0 psi 2 bbls, .5 bpm, 0 psi, 91 bbls 6 bbls, 1 bpm, 0 psi, 97 bbls 06:45, 0 psi 2 bbls, .5 bpm, 0 psi, 99 bbls 6 bbls, 1 bpm, 140 psi, 105 bbls 07:15, 0 psi 2 bbls, .5 bpm, 80 psi, 107 bbls 4 bbls, 1 bpm, 250 psi, 111 bbls 2 bbls, .5 bpm, 220 psi, 113 bbls 07:45, 65 psi 2 bbls, .5 bpm, 220 psi, 115 bbls 4 bbls, 1 bpm, 370 psi, 119 bbls 2 bbls, .5 bpm, 320 psi, 121 bbls 08:15, 150 psi 2 bbls, .5 bpm, 300 psi, 123 bbls 4 bbls, 1 bpm, 470 psi, 127 bbls 2 bbls, .5 bpm, 400 psi, 129 bbls 08:45, 215 psi 1 bbls, .5 bpm, 350 psi, 130 bbls 3 bbls, 1 bpm, 495 psi, 133 bbls 1 bbls, .5 bpm, 435 psi, 134 bbls 09:05, 245 psi 1 bbls, .5 bpm, 380 psi, 135 bbls 3 bbls, 1 bpm, 540 psi, 138 bbls 1 bbls, .5 bpm, 475 psi, 139 bbls CII' @ 09:10 Unsting and reverse out approx 5 bbls CW 100 and 5 bbls cement. Drillpipe vo194.7 bbls Casing vol below retainer 7.6 bbls ~O~-\~S From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Thursday, October 23, 2008 1:47 PM To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 Current plugback Unforntunately not yet -Plan forward is to redrill the Mainbore B-lateral around the fish and then set a whipstock approximately 600' up in the 9-5/8" mill out a window for the Ll. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 23, 2008 1:41 PM To: Hartwig, Dennis D Subject: RE: 3K-103 Current plugback So thus far you haven't "made" it to L1?? From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Thursday, October 23, 2008 1:40 PM To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 Current plugback Thanks Tom, We are going to drill out the retainer and sidetrack the well in the Mainbore so the abandoned section will be called 3K-103 PBS Dennis Dennis Hartwig Drilling Engineer From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 23, 2008 11:02 AM To: Hartwig, Dennis D Subject: RE: 3K-103 Current plugback Dennis, Sorry for listing "108". Tom From: Maunder, Thomas E (DOA) Sent: Thursday, October 23, 2008 10:53 AM To: 'Hartwig, Dennis D' Subject: RE: 3K-103 Current plugback • Yes, it is still a plugback. Is it your intention to drill out the retainer?? The naming depends on if the abandoned section is still in the "mainbore" or if it is in the L1. It seemed from the original information you provided that there were plugbacks in the mainbore which would be named 3K- 108PB1, 3K-108P62, etc. If you are drilling the L1, then the plugbacks would be named 3K- 108L1 PB1, 3K-108L1 PB2, (unfortunately etc.). Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Thursday, October 23, 2008 10:24 AM To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 Current plugback Tom, As mentioned previously we are in the process of abandoning our current lateral in the West Sak B-Sand. The abandonment procedure includes squeezing ~ 150 bbls into the old lateral with a retainer up in the 9-5/8". We will then drill out the retainer and sidetrack around the old wellbore and fish. I will forward details ASAP. I am uncertain of the naming convention for the abandoned lateral? Is it still a Plugback Thank-you...Dennis Drilling Engineer From: Hartwig, Dennis D Sent: Wednesday, October 22, 2008 12:32 PM To: 'Maunder, Thomas E (DOA)' Subject: RE: 3K-103 Current plugback Tom, Thanks for the condolences -our luck has to change soon. Pertaining to PB2, the top of the West Sak D-Sand came in at 4,472' per geology interpretation. Top of l st stage with anticipated 25% excess hole washout would be ,., 3,968'MD Dennis Hartwig Drilling Engineer From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 22, 2008 12:08 PM To: Hartwig, Dennis D Cc: Allsup-Drake, Sharon K Subject: RE: 3K-103 Current plugback • Thanks Dennis. Boy, the snake-bite continues!! Where was the top of the West Sak determined in PB2? Based on the information you have provided, it would appear that the base of the first stage is below the top of the West Sak. Having the plug cover the top of the West Sak satisfies a major regulatory requirement. I sure hope your luck changes. Regards, Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Wednesday, October 22, 2008 12:03 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: 3K-103 Current plugback Tom, PB2 penetrated the West Sak D-Sand while drilling the 12-114" intermediate hole. The specifics of the plug are as follows; • Tripped in with 2-7/8" pipe to TD @ 4,527' then tripped out 1 stands. • Circulated bottoms up then pumped 1St stage cement plug which consisted of 20bbls water and 127.5 bbls of 17ppg cement followed by 3 bbls of water - displaced with 57 bbls of mud pumped by rig. • Pulled stinger out of plug, 7 stands + single. • Circulated bottoms up prior to 2"d stage plug with trace of cement and excessive clays on bottoms up. • Pumped 2"d stage cement plug which consisted of 20 bbls water, 127.5 bbls of 17 ppg cement followed by 3 bbls of water -displaced with 44 bbls of mud pumped by rig. • Pulled stinger out of cement plug 10 stands • Circulated total 5 bottoms up @ approximately 2,898'MD with calculated TOC @ 3127. Top of Ugnu uppermost hydrocarbon @ 3,627'MD • Subsequent BHA tagged up early at 2,904' with sidetrack from old welibore at 2,925' MD PB3 occurred while drilling in the West Sak B lateral section at a depth of 6,450' with the intermediate shoe @ 5,437'MD. An openhole sidetrack was initiated at 5,900'MD around the abandoned hole. Our troubles continue this week as we have stuck our 3-1/2" completion in the B-lateral. We have recovered a partial fish and intend to squeeze ~ 150 bbls plug on top of the fish then sidetrack around the fish and redrill the lateral. TD of the lateral is 12,373' with the bottom of the fish at ~ 8,377'MD and the top of the fish at 5,738'MD. Proposed sidetrack point is 5,550' MD. We plan on setting a cement retainer at 5337'MD (100' inside the 9-5/8") and Squeezing 150 bbls of 15.8 cement in three stages of 50 bbls each in order to remain below the frac pressure. • I will provide a new summary of all plugbacks and details of our current cement plugs shortly. Please contact me if you have any concerns...Dennis Dennis Hartwig Drilling Engineer From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 21, 2008 9:53 AM To: Hartwig, Dennis D Cc: Allsup-Drake, Sharon K Subject: RE: 3K-103 Current plugback Dennis, Looks like you have had more than your share of directional challenges in this well. You might check with Pat Riley and get an example of the note he would send me when the need to sidetrack arose. In particular, when cement is being placed I would appreciate that you contact me with the information. With regard to P62 and PB3, was the West Sak penetrated in either of these segments? What were the specifics of the plug? Do you have a rough sketch of the well paths? Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Tuesday, October 21, 2008 9:31 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: 3K-103 Current plugback Tom, We have had a number of sidetracks relating to our current well 3K-103 -hopefully this may alleviate some of the confusion. Attached is a spreadsheet of the current plugbacks in reference to 3K-103. Please review and give me a ring if you have any questions. «3K-103 Plugback Info.xls» Thanks... Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ~ ~ 3K-103 Plugback Description 10/19/08 Sidetrack Point from Hole Section Plugback # Previous Total Depth (ft) Comments Obtained a high dogleg between 4,266'MD and 4,314'MD. In an attempt to ream and reduce the dogleg the well was inadvertenly Intermediate - 12-1/4" 3K-103 PB1 N/A 4,410' MD sidetracked. Could not achieve the directional objectives of the well. Pulled out of hole to set cement plug above the Ugnu an redrill intermediate Intermediate - 12-1/4" 3K-103 PB2 4,260'MD 4,527'MD hole section. Sidetracked off of cement plug and continued drilling to TD of the intermediate hole section @ 5442'MD. Drilled out 9-5/8" shoe at 5,437 and continued in 6-3/4" lateral hole section until directional tools failed and a high dogleg was revealed. Intermediate - 12-1/4" & POOH to replace directional equipment and Lateral 6-3/4" 3K-103 PB3 2,925' MD 6,540'MD sidetrack around high dogleg. Sidetracked around high dogleg and continued drilling to 8,794 at which time the LWD logs indicated that the assembly had drilled out of the top of the B-sand. Pulled back to initiate an openhole sidetrack and Lateral 6-3/4" 3K-103 PB4 5,900'MD 8,794'MD reaquire sand.. Openhole sidetrack at 8,600'MD and drilled to TD of B-Sand lateral. Current operations Lateral 6-3/4" 3K-103 8,600'MD 12,373'MD -fishing 3-1/2" liner. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~-- NO.4914 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 10/14/08 iL-23 12097405 SBHP SURVEY j 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE ~j - /C O L 09/10/08 1 1 3G-25X 12080437 LDL ~ - '3 L/(o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE G ~ ( 09/14/08 1 1 3M-13 12096541 LDL - (~C.( j ~ 09/10/08 1 1 2Z-13A 12100446 LDL c~b(o- l~0 ~U 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - ~ 5''01 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE ~ p ~ 09/20/08 1 1 30-15 12100452 LDL - ~ Q 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o 09/23/08 1 1 1R-11 11966277 SBHP SURVEY ~- (~ 09/25/08 1 1 1R-35 11966279 SBHP SURVEY _ ~ 09/25/08 1 1 i R-14 11966286 LDL f 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE _ 09/30/08 1 1 iR-34 12080444 GLS ~j~ ~ 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .; L ~~~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ~''~~ ( 10/06/08 1 1 1 H-19 12096548 INJECTION PROFILE L 10/03/08 1 1 1 B-16 12097426 GLS Cj - =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - (~ 10/07/08 1 1 1 B-04 12096552 INJECTION PROFILE -- 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 16-16 12096554 PRODUCTION PROFILE qC' _ G 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ;~'$C . 10/11/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. u~y-,~ • ALA5SA OIL A1~TD GrAS CO1~T5ERQATIOI~T COMI-II55IOI~T Randy Thomas Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 3K-103 ConocoPhillips Alaska Inc. Permit No: 208-115 Surface Location: 885' FSL, 314' FWL, SEC. 35, T13N, R09E, UM Bottomhole Location: 1894' FSL, 551' FEL, SEC. 36, T13N, R09E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. ,S f Chair DATED this3 ~ day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com ~ ~1 ~~~+~ •~ ~C ~ ~ 2~ July 15, 2008 ~- ~,_, , ~, , Alaska Oil and Gas Conservation Commission ~ ~~' ~`,~~an 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 3K-103 and 3K-103L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a dual lateral horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated 3K-103 and the lateral bore of the well will be designated 3K-103L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 3K-103 is September 1, 2008. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA • R~CEPVED JUL I R 200ft ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL '~~~~~ +~ ~~ ~`~~s. c~mmi~s;~n 20 AAC 25.005 ~~~~0~~(~0 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^/ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for. Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 3K-103 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12404' TVD: 3611' 12. Field/Pool(s): Kuparuk River Field 4a. location of Well (Governmental Section): Surface: 885' FSL, 314' FWL, Sec. 35, T13N, R09E, UM 7. Property Designation: ADL 25519 West Sak Oil Pool Top of Productive Horizon: 2485' FSL, 2186' FEL, Sec. 35, T13N, R09E, UM 8. Land Use Permit: ALK 2555 13. Approximate Spud Date: 9/1/2008 Total Depth: 1894' FSL, 551' FEL, Sec. 36, T13N, R09E, UM 9. Acres in Properly: 2560 14. Distance to Nearest Property: 551' 4b. Location of Well (State Base Plane Coordinates): Surface: X- 529305 ~ y- 6007879 Zone- 4 10. KB Elevation 73•$ ~N/SL (Height above Gl.): 34' ~ feet ~• 15~. Distance to Nearest ` Well within Pool: 3K-30 , 100' @ 4900' MD 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1733 psig Surface: 1336 psig ' 18. Casing Program if n S ti Setting Depth Quantity of Cement Size ica pec o s Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (inGuding stage data) 40" 20" x 34" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 2529' 40' 40' 2529' ~ 2200' ' 610 sx AS Lite, 150 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 5441' 40' 40' 5441' - 3546' ~ 480 sx DeepDRETE 6.75" 3.5" 9.3# L-80 Hydrill 563 7607' 4797' 3471' 12404' . 3611 ' screens 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) Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is Vue and correct to the best of my knowledge. Contact Dennis Ha-fwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader Signature ~,~jL 7~~ r ~ L -~ Phone Date III Sj~ba~ ~~tiaa~ /' tom k Commission Use Only Permit to Dril~l/')Q Number: i6.~-iG/ ~ ~/~ API Number~: /~~ 50- ~L~.~ ~ ~ ~~~z ~ c.•C~ Permit Approval Date: ~ '31 • O See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: \~ ~ ~L~~~~ ~~~e~ ~'~ Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No ~' Other: `~~(J H2S measures: Yes ~ No ~ Directional svy req'd: Yes [~ No ^ ~/ ~ ~~~ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ e ~ Submit in Duplicate ~;ation for Permit to Drill, Well 3K-103 Revision No.0 Saved: 15-J u1-08 Permit It -West Sak Well #3K-103 Application for Permit to Dril/ Document MdxirnixE 1M~11 Value Table of Contents 1. Well Name ..........................................................:...................................................... 2 Re uirements of 20 AAC 25.005 .............................. 2 q (fl ......................................................................... 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ..............................................................................:........................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) .................................................~-~--~--.......................................... 3 4. Drilling HazardsInformation ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation. Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .............................:.................................................................... 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 5 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 5 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c) (8) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite) ....................................................................:............. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 10. Seismic Analysis ..................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) ..................................................................:...........:..........,:..... 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 3K-103 PERMIT IT.doc Page 1 of 8 Printed: 15-Jul-08 A~tion for Permit to Drill, Well 3K-103 Revision No.O Saved: 15-Jul-08 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) .............~-~----................................................:..............:............ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Aftachment 1 Directional Plan Aftachment 2 Drilling Hazards Summary Aftachment 3 Doyon 15 West Sak 3ksi BOP Configuration Aftachment 4 Cement Loads and CemCADE Summary Aftachment 5 Well Schematic Aftachment 6 Quarter mile radius Injector effects 1. Well Name Requirements of 20 AAC 25.005 (f) Each Eveti must be identified by a unique name designated by the operator and a unique API number assigned by the commission under ZO AAC 25.040(6). Far a hell with multiple well branches,, each branch must similarly be identified by a unique name and API number by adding a sulfrx to the name designated for the well by the operator and to the number assigned to the. well by the COmmiSSirln, The well for.which this Application is submitted will be designated as 3K-103. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dril/must be accompanied by each of the fatlowr"ng items, except for an r"tem already on file with the commission and identified in the applicatian.~ (2) a plat identifying the property and the property's owners and showing (A)the coordinates of tfae proposed location of the we/1 at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 885' FSL, 314' FWL Section 35 T13N, R09E ASPZone 4 NAD 27 Coordinates RKB Elevation 73.8' AMSL ' Northings 6,007,879' Eastings: 529,305' Pad Elevation 33.8' AMSL Location at Top of Productive Interval 2,485' FSL, 2,186' FEL, Section 35, T13N, R09E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 5 441' Northings; 6,009,491' Eastings; 532,076' Total I/ertica/De th, RKB.• 3,546' Total ~ertica/ De th SS.• 3,471' Location at Total De th 1 894' FSL, 551' FEL Section 36 T13N, R09E ASP Zone 4 NAD 27 Coordinates MedSUred De th, RKB.' 12, 404' Northings: 6,008,932' Eastings: 538,994' Total ~ertica/De th, RKB; 3,611' Total ~ertica/De th, SS.• 3,537 3K-103 PERMIT lT.doc Page 2 of 8 Printed: 15-Jul-08 r ~ation for Permit to Drill, Well 3K-103 Revision No.O Saved: 15-Jul-08 and (D) other information required by70 AAC 25.05®(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application far a Permit to Dril/ (Form 10-401) must (1) inc/ude a plat, drawn to a suitab/e scale, showing the path of the proposed wellbore, including all adjacent we/(bores. within 200 feet of any portion of the proposed well; Please see Attachment 1; Directional Plan 3K-103 and (2) for al/ we!/s within 200 feet of the proposed wel/bare (A) Aist the names of the operators of those we/ls, to the extent that those names are known ar discoverable in public records, and show that each named operator has been furnished a copy of the app/ication by certified mar"l; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to grill must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application; (3) a diagram and description of the b/oavout prevention equipment (BQPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 3K-103. For all drilling, casing and .Liner operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. For the dual 3-1/2" completion operations the stack will be equipped with dual 3-1/2" rams in the uppermost ram cavity, blind rams in the middle cavity, and dual 3-1/2" rams in the lowermost cavity. A second .set of dual 3-1/2" rams is required since the Annular will be ineffective while running dual 3-1/2" strings simultaneously. See attached diagram entitled °°aoyon ZS West Sak 3ksi BOP Corrfr}uratron"for clarification. Upon initial nipple up and at intervals of no more than 14 days thereafter, a testplug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams -will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 9-5/8" OD. Prior to running the dual 3-1/2" completion, a test plug will be installed below the lower most rams, the upper and lower ram cavities will be equipped with dual 3-1/2" rams and tested to 3,000 psi. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with. the Commission. 1. Drilling Hazards Information Requirements of 20 AAC 25.005 (cf (4) An apply"cation for a Permit to ©rill must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 3K area are 0.48 psi/ft, or 9.0 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak ~~B" sand formation is 1,336 psi, calculated thusly: 3K-103 PERMIT IT.doc t ~ ~ ~ ~ ~ Page 3 of 8 !1 Printed: 15-Jul-08 MPSP = (3,611 ft TVD)(0.48 - 0.11 .psi/ft) = 1,336 psi ~C A{l~tion for Permit to Drill, Well 3K-103 Revision No.O Saved: 15-Jul-08 (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circa/anon zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 3K-103 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to £Jril/ must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application,• (5) a description of the procedure for conduoting formation integrity tests, as required under 20 AAC 25. Q3f1(t~; 3K-103 will be completed with a 9-5/8" intermediate casing landed in the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for aPerm/t to Drill must be accompanied by each of the fol/owing r"terns, except for an item already on fife with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 2©AAC 25, f130, and a description of any slotted liner, pre- perforated liner, or screen to be installed; ~ '~ __ --. __-~ _ .~ Casing and Cementing Program ~~~ F~"~~~~ SPP alSn AtFarhmant ~• C'amant Siimmar~i Hole Top etm Csg/Tbg Size Weighf Length MD/TVD MD/TVD OD in in Ib/ft Grade Connection ft ft ft 20 x 34 40 94 K55 Welded 80 40 / 40 120 / 120 Cementf Cem~ 13-3/8 16 68 L-80 BTC 2,529 0/0 2,529 /2,200 6. 15a Cen 9-5/8 12-1/4 40 L-80 BTCM 5,441 0 / 0 5,441 / 3,546 2's Cement 3-1/2 blank 6-3/4" B Sand 9.3 L-80 Hydril 563 x 7,607 4,797 / 3,471 12,404 / 3,611 sc with Lateral (3K- SLHT ResInject l03) screens.. ~_=-•---~-~. 3-1/2 blank 6-3X~"~+,d " 9.3 L-80 Hydril 563 x 7,700. 4,698/.3,454 12,398 / 3,565 u... •_'s ens - no cement with Lateral (3K- SLHT ResInject l03 Ll) screens 3K-103 PERMIT IT.doc ~s ~ X~~ ~ Page 4 of 8 ~"~ a Printed:15-Jul-08 ~ation for Permit to Drill, Well 3K-103 Revision No.0 Saved: 15-Jul-08 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application far a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on frfe with the commissian and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25. tJ35, unless this requirement is waived by the commission under ZO AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 3K-103. Please see diagrams of the Doyon 15 diverter system on file with the Commission 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to ®rit! must be accompanied by each of the following items, except for an item already on fi/e .with the commission and identified in the application; (8) a drilling florid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25. Q33; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) S ud to Base of Permafrost Base of Permafrost to 13-3/8" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.8 9.2 9.2 9.5 Funnel viscosity 150 250 200 300. seconds Yield Point 50 70 30 50 cP Plastic Viscostiy 30 55 15 20 Ib/100 s pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 cc / 30 min Intermediate Hole Mud Program (LSND) 13-3/8"Cs Shoe to 9-5/8"Cs .Point Value Density (ppg) 8.8 - 9.2 Funnel Viscosity 45 - 60 seconds Plastic Viscostiy 12 - 18 Ib/100 s Yield Point 18-24 cP API Filtrate 4 - 6 cc / 30 min Chlorides (mg/I) <500 pH 9.0 - 10.0 MBT < 18.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B & D sand laterals -Value Densit p 9.0 - 9.3 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 15 - 20 cP HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 70 / 20 Electrical 650 - 900 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. OR161NAL 3K-103 PERMIT IT.doc Page 5 of 8 Printed: 15-Jul-08 A{~tion for Permit to Drill, Well 3K-103 Revision No.O Saved: 15-Jul-08 8. Abnormally Pressured. Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to I~rit/ must be accompanied by each of the following items, except for an item already on d/e with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabu/ation setting out the depths of predicted abnarmatfy geo pressured strata as required by 20 AAC' 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to L?ri/l must be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with the commission and identified in the application: (10) far an exploratory or stratigraphic test iveil, a seismic refraction or reflection analysis as required by 20 AAC 25, Ob1(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to ®rilt must be accompanied by each of the fo1/oavmg items, except for an item already on file with the commission and identified in the application. (1~) for a well drilied from an offshore p/atfarm, mobi/e bottom-founded structure, jack-up rig, or ffoatr"ng drilling ~ess% an analysis ofseabed conditions as required by 20 AAC25.061(b); Not applicable: Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Pernut to drift must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the appiication.~ (I2J evidence showing that the requirements of ZO AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file. with the commission and identified in the applicatian; The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 120' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 2,529 MD / 2,200' TVD as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 4. Run and cement'13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 his before test. 6. PU 12-1/4" bit-and 8"drilling assembly, with MWD, LWD, PWD and mud motor. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. _ 8. Directionally drill to 9-5/8" casing point at 5,441' MD / 3,546' TVD, the prognosis top of the B sand. Pull out of hole backreaming to the surface easing shoe. 3K--103 PERMIT /T.doc Page 6 of 8 Printed: 15-Jul-08 ~~~~ /~ation for Permit to Drill, Well 3K-103 Revision No.0 ...Saved: 15-Jul-08 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. (top of cement to be 2,927 MD / 2,779' TVD which corrresponds to 500' above the Ugnu C formation.) 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8"annulus with water, followed by diesel 12. PU 8-1/2" Rock Bit and 6-3/4" cleanout assembly. RIH, clean out cement o top of float equipment. Re- test casing if cement is tagged more than 100 feet above the float collar. 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. 14. POOH with 8-1/2" cleanout assembly. 15. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH and directionally drill 6-3/4" hole to TD at +/- 12,044' MD / 3,611' TVD as per directional plan. 16. At TD Circulate 4 bottoms up with reciprocation and rotation. Open up PBL circulation sub and circulate 9-5/8" casing clean at increased flowrates for 4 bottoms up. Close circ sub & displace to clear weighted brine. Pump out of Hole displacing production interval with weighted brine and breaker. 17. Run USIT log to evaluate cement bond on intermediate casing. _ 18. PU and run 3-1/2" blank liner, ResInject screens and TAM swell packers. ~ ~ `S ~~ ~~~ 19. Land liner, set liner hanger @ +/- 4,797'MD / 3,471'TVD. POOH. Note: Remaining operations are covered under the 3K-102L1 Application for Permit to Drill, and are provided here for information only. 20. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 4,698' MD / 3,454' TVD, the top of the D sand. 21. Mill 8-1/2" window. POOH. 22. Pick up 6-3/4"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 23. Drill to TD of B sand lateral at +/- 12,398 MD / 3,565` TVD, as per directional plan. 24. Circulate 4 bottoms up with reciprocation and rotation. Open up PBL circulation sub and circulate 9-5/8" casing clean at increased flowrates for 4 bottoms. Close circ sub & displace to clear weighted brine. Pump out of Hole if necessary. 25. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 26. RIH and set Baker Seal Bore diverter 27. PU and run 3-1/2" Hydril 563 & SLHT blank liner, ResInject screens and TAM swell packers with Baker Oil Tools RAM Hangar system. 28. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool POOH laying down drill pipe as required. 29. PU 3-1/2" IBTM tubing and rack back in stands in Derrick 30. Install and test dual 3-1/2".RAMS as described above in Section 3. Notify AOGCC 24 hrs before test.. 31. PU 3-1/2" Baker dual seal module, dual GT packer and dual 3-1/2" injection completion and RIH to depth. Land tubing. Set BPV 32. Nipple down BOPE, nipple up tree and test. Pull BPV. R ~ 3K-103 PERMIT IT.doc a ~ ~ G ~ 1\1 ~ ~ Printed.• ~5-Jul-08 A{~ition for Permit to Drill, Well 3K-103 Revision No.O Saved: 15-Jul-08 33. Freeze protect well with diesel by pumping into 3-1/2" x 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 34. Set BPV's and move rig off. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Perrrrit to aril/ rrrust be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the app/ication.• (Z 4) a general description of how the operator plans to dispose of dri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 2Ct AAC 25.(1811 for an annular d/spasal operation in the well., Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids ' into a permitted annulus on 3K Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 3K Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Doyon 15 West Sak 3ksi BOP Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Quarter mile radius Injector effects 3K 103 PERMIT lT.doc ~ Page 8 of 8 i,~; Printed: 15-Jul-08 • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-103 (E14) 3K-103 Plan: 3K-103 (wp08) Standard Proposal Report 27 June, 2008 HAL.l.~E3~J~TClR ~p~rry O~illing Bervices ORIGINAL H,ra~~rtleuArc3Ev Sperry Ori111e>t>o Service. -2500 -7 -1000 -500 0 500 ~ 1000 0 N_ t 1500 d a~ 2000 N SFIL: 885' FSL, 314' FWL -Sec35-T13N-R09E 10Q 15° ~1p00 25 Project: Kuparuk River Unit WELL DETAILS: Plan 3K-103 (E14) NAD 1927 (NADCON CONUS) Alaska Zone 04 Site: Kuparuk 3K Pad Gound Level: 34.30 Well: Plan 3K-103 (E14) +N/-S +E/-W Northing Basting Ia[ittude Longitude Slot Wellbore: 3K-103 0.00 0.00 6007879.01 529305.34 70° 25' 57.374 N 149° 45' 40.018 W Design: 3K-103 (wp08) FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 1572.70 1498.40 1677.06 T3 1639.00 1564.70 1763.61 Pfrost 1796.68 1722.38 1975.98 K15 2394.39 2320.09 2794.83 T3+800 2779.79 2705.49 3322.82 Ugnu C 3028.05 2953.75 3673.57 Ugnu B 3125.19 3050.89 3827.00 Ugnu A 3247.15 3172.85 4047.39 K 13 3453.70 3379.40 4697.86 W Sak D 3499.96 3425.66 4966.48 W Sak C 3548.82 3474.52 5484.88 W Sak B CASING DETAILS TVD TVDSS N1D Size Nune 2200.00 2125.70 2528.52 13-3/8 l3 3/8" 3545.62 3471.32 5441.40 9-5/8 9 5/8" 3G11.50 3537.20 12404.14 3-1/2 31/2" ~~ ~V T3 15 Surface Casing @ 2529' MD 2200' TVD: 1634' FSL, 1005' FWL -Sec35-T13N-R09E BHL @ 12404' MD, 3612' TVD: 1894' FSL, 551' FEL - Sec36-T13N-R09E K75 ,' p3 Int. Casing @ 5441' MD, 3546' TVD: 2485' FSL, 2186' FEL -Sec35-T13N-R09E `~ -T3+800--------- -3~p0 ~~ __- UgnuC--------- - -,j5~0 ~ i i ~ ~ ~ \ 3000 z_UgnuB_______ oo~ ° ____ h ~' 0 0 0 °o o° o~ ~ v _wz==Ugnu A'---- ----- - ~h ~ o ° ----- - ` o~ o uoi o 0 0 0 '~~° ° ~ `r =~K 13--------- - a ro i° tn~ o rn ~ ° ~^ro ^~`~ ~ 3K_703L1 w OB ,~_. (-P ~- 500 _ = - ---- - - ~ ---------- ---- -- --- -- - - -- - ~ J o -- - _ _ =---------- _ - ---- - W Sak C i ' c~ o m i c ii o mo i ° ° i i i 3K-103 (wp08) ` W Sak B ~ ~ 9 5/8" io o ~ p 0 0 o i i i i i i i i i i ' 3 1/2„ ~ 4000 i ~ ~ ~ i ' ' ~ ~ ~ i 3K-103 D Top (03/05/OS) i ~ , 3K-103 CP4 (03/05!08) , i 3K-103 CP2 (03/05/08) ~ i 3K-103 CP6 (03/05/08) ' i x500 3K-103 CP1 (03/05/08) 3K-103 CP3 (03105/08) 3K-103 CP5 (03/05/08) 3K-103 Toe (03/05/08) 5000 5500 6000 ll~~~iiiiiiiiiiiiiiiiii~~~~l~~~~l~~ I~~I~~~III i i -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 1500 8000 8500 9000 9500 10000 10500 11000 Vertical Section at 90.00° (1250 ft/in) ConocoPhillips Alaska C G r HALI_1~ tJATON Project: Kuparuk River Unit WELL DETAILS: Plan3K-103(El4) NAD1927(NADCONCONUS) Alasl:aZone04 Site: Kuparuk 3K Pad °'~•''~Y °''~ u"a ~'~'a•~ Well: Plan 3K-103 (E14) CttoundLevel: 34.30 Wellbore: 3K-103 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 6000 Plan: 3K-103 (wp08) 0.00 0.00 6007879.01 529305.34 70° 25' 57.374 N 149° 45' 40.018 W REFERENCE INFORMATION 00 Co-ordinate (N/E) Reference: Well Plan 3K-t03 (E74), True Norlh 55 Vertical (TVD) Reference: Doyonl5 (34.3+40) @ 74.30ft Measured Depth Reference: Doyonl5 (34.3+40) @ 74.30ft Calculation Method: Minimum Curvature 5000 CASING DETAILS TVD TVDSS MD Size Name 4500 2200.00 2125.70 2528.52 13-3/8 13 3/8" 3545.62 347L32 5441.40 9-5/8 95/8" 3611.50 3537.20 12404.14 3-1/2 31/2" 4000 3500 Int. Casing L 5441' bID, 3546' TVD: 2485' FSL, 2186' FEL -Sec35-T13N-R09E r 3000 i ~ Surface Casing @ 2529' MD 2200' TVD: 1634' FSL, 1005' FWL -Sec35-T13N-R09E ~ BHI. @, 12404' MD, 3612' TVD: 1894' FSL, 551' FEL - Sec36-T13N-R09E C ~ i I ~ ~ 2500 I ' I ` ~ O V7 I I i ~ .N. I r i ~ ~ 2000 I ~` + I °o I ` .G O I rn I rn/ rn a P a ~ i ° ` o° r 1500 C I ° I I ~ I i ~ ~ I I a o ~ a o ` Lv I PO I 9 $/8" I I I I I ~ o ° I ~ a ~ ~ I O I I I I ~ '~ r/] 1001) I II I I I I I I ~'- I ~s~ I I I I ~ i I I `~ 3K-103 (wp08) ~ iK-103 D Top (03/U5H13) 3K-103 CI'1 (03/05/08) ~ 3K-103 CP3 (03/OS/O8) I I II 13 1/2" I I I 500 ?p00 ~ I 3K-103 CP2 (03/05108) 31i- I 103 CP4 (03/05/US) i I II ~~so 13 3/8" I I I I I 3K-lU3 CP5 (03/US/03) I I 0 ~2s ~ I. I o 3K-103 CP6 (03/05/03) I I 31:-IU3 Toe (U3/U5/OS) -500 -1000 SHL: 885'FSL, 314'FWL-Sec35-T13N-R09E T M Azimuths to True North Magnetic North: 17.98° -1500 Magnetic Field Strength:57263.5snT Dip Angle: 79.80° -2000 Date: 10/12/2007 - Model: BGGM2007 -2500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 West(-)/East(+) (1250 t71in) ~"'" ConocoPhillips IUaska ~~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-103 (E14) Wellbore: 3K-103 Design: 3K-103 (wp08) Halliburton -Sperry Standard Proposal Report local Co-ord+nate Reference: Well Plan 3K-103 (E14) TVD Reference: Doyon15 (34.3+40) @ 74.30ft MD Reference: Doyon15 (34.3+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States 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 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70° 26' 2.780 N From: Map Easting: 529,306.18ft Longitude: 149° 45' 39.930 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.23 ° WeII Plan 3K-103 (E14) Well Position +N/-S 0.00 ft Northing: 6,007,879.01 ft Latitude: 70° 25' 57.374 N +E/-W 0.00 ft Easting: 529,305.34 ft Longitude: 149° 45' 40.018 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.30ft , Wellbore 3K-103 Magnetics Model Name Sample Date ~ bggm2007 10/12/2007 Design 3K-103 (v~p08) Audit Notes: Version: 28 Phase: Vertical Section: Depth From (TVD) (ft) I 40.00 Declination Dip Angle Field Strength _ .17.98 79.80 57,263 PLAN Tie On Depth: 40.00 +N/-S +E/-W Direction {ft) (ft) (°) 0.00 0.00 50.00 6/27/2008 10:52:52AM Page 2 COMPASS 2003.16 Build 42F ~~~ • Halliburton -Sperry Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-103 (E14) Company: ConocoPhill ips (Alaska) Inc. -Kup2 TVD Reference: Doyon15 (34.3+40) @ 74.30ft Project: Kuparuk River Unit MD Refere nce: Doyon15 (34.3+40) ~ 74.30ft Site: Kuparuk 3K Pad North Refe rence: True Well: Plan 3K-103 (E14) Survey Cal culation Method: Minim um Curvature Wellbore: 3K-103 Design: 3K-103 (uvp08) ~ Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 40.00 0.00 0.00 40.00 -34.30 0.00 0.00 0.00 0.00 0.00. 0.00 270.00 0.00 0.00 270.00 195.70 0.00 0.00 0.00 0.00 0.00 0.00 703.72 13.01 75.00 700.00 625.70 12.69 47.37 3.00 3.00 0.00 75.00 1,766.83 41.34 37.21 1,641.42 1,567.12 331.57 384.07 3.00 2.66 -3.55 310.00 1,866.83 41.34 37.21 1,716.50 1,642.20 384.18 424.02 0.00 0.00 0.00 0.00 1,915.55 43.12 36.02 1,752.57 1,678.27 410.46 443.54 4.00 3.65 -2.45 -24.76 3,427.86 43.12 36.02 2,856.46 2,782.16 1,246.51 1,051.43 0.00 0.00. 0.00 0.00 4,597.86 80.00 90.01 3,436.34 3,362.04 1,601.17 1,941.38 5.00 3.15 4.61 69.12 4,697.86 80.00 90.01 3,453.70 3,379.40 1,601.15 2,039.86 0.00 0.00 0.00 0.00 4,727.86 80.00 90.01 3,458.91 3,384.61 1,601.14 2,069.40 0.00 0.00 0.00 0.00 4,927.86 80.00 90.01 3,493.64 3,419.34 1,601.10 2,266.36 0.00 0.00 0.00 0.00 5,094.53 85.00 90.01 3,515.39 3,441.09 1,601.07 2,431.55 3.00 3.00 0.00 0.00 5,411.36 85.00 90.01 3,543.00 3,468.70 1,601.01 2,747.17 0.00 0.00 0.00 0.00 5,441.36 85.00 90.01 3,545.61 3,471.31 1,601.00 2,777.06 0.00 0.00 0.00 0.00 5,471.15 86.18 90.05 3,547.91 3,473.61 1,600.99 2,806.76 4.00 3.96 0.13 1.82 5,620.99 86.18 90.05 3,557.89 3,483.59 1,600.86 2,956.26 0.00 0.00 0.00 0.00 5,684.97 88.75 90.01 3,560.72 3,486.42 1,600.83 3,020.18 4.00 4.02 -0.06 -0.87 6,334.97 88.75 90.01 3,574.90 3,500.60 1,600.71 3,670.03 0.00 0.00 0.00 0.00 6,507.48 90.42 90.44 3,576.15 3,501.85 1,600.03 3,842.52 1.00 0.97 0.25 14.50 7,305.11 90.42 90.44 3,570.30 3,496.00 1,593.89 4,640.11 0.00 0.00 0.00 0.00 7,466.29 92.03 90.39 3,566.85 3,492.55 1,592.72 4,801.24 1.00 1.00 -0.03 -1.88 8,336.80 92.03 90.39 3,536.00 3,461.70 1,586.81 5,671.19 0.00 0.00 0.00 0.00 8,643.35 90.91 99.52 3,528.11 3,453.81 1,560.37 5,976.16 3.00 -0.37 2.98 96.86 9,335.55 90.91 99.52 3,517.10 3,442.80 1,445.90 6,658.74 0.00 0.00 0.00 0.00 9,454.76 89.12 97.95 3,517.07 3,442.77 1,427.81 6,776.56 2.00 -1.50 -1.32 -138.66 10,135.19 89.12 97.95 3,527.50 3,453.20 1,333.77 7,450.38 0.00 0.00 0.00 0.00 10,179.27 89.99 98.12 3,527.84 3,453.54 1,327.61 7,494.02 2.00 1.96 0.39 11.21 11,235.71 89.99 98.12 3,528.10 3,453.80 1,178.46 8,539.89 0.00 0.00 0.00 0.00 11,449.42 83.57 98.08 3,540.10 3,465.80 1,148.42 8,751.02 3.00 -3.00 -0.02 -179.64 11,699.97 83.57 98.08 3,568.13 3,493.83 1,113.44 8,997.52 0.00 0.00 0.00 0.00 11,804.14 86.70 98.06 3,576.96 3,502.66 1,098.87 9,100.28 3.00 3.00 -0.02 -0.30 12,404.14 86.70 98.06 3,611.50 3,537.20 1,014.89 9,693.36 0.00 0.00 0.00 0.00 6/27/2008 10:52:52AM ORIGINAL COMPASS 2003.16 Build 42F • • Halliburto n -Sperry ~~"~""~~ Stan dard Pro posal Report Database: EDM 2003.16 Single User Db Local Co-ordinate R eference: Well Plan 3K-103 (E1 4) Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Doyonl5 (34.3+40) (c~ 74.30ft Project: Kuparuk River Unit MD Reference: Doyon15 (34.3+40) @ 74.30ft Site: Kuparuk 3K Pa d Nerth Reference: True Well: Plan 3K-103 (E14) Survey Calculation Method: Minimum Curvature Wellbore: 3K-103 Design: 3K-103 (wp08) Planned Survey Measured Vertical Map Map Depth In clination Azimuth Depth NDss +N/S +E/-W Northing Easting DLS Vert Section (ft) (°) ( °) (ft) ft (ft) (ft) (ft) (ft) -34.30 40.00 0.00 0.00 40.00 -34.30 0.00 0.00 6,007,879.01 529,305.34 0.00 0.00 SHL: 885' FSL, 314' FWL -Sec35-T73N-R09E 100.00 0.00 0.00 100.00 25.70 0.00 0.00 6,007,879.01 529,305.34 0.00 0.00 200.00 0.00 0.00 200.00 125.70 0.00 0.00 6,007,879.01 529,305.34 0.00 0.00 270.00 0.00 0.00 270.00 195.70 0.00 0.00 6,007,879.01 529,305.34 0.00 0.00 300.00 0.90 75.00 300.00 225.70 0.06 0.23 6,007,879.07 529,305.57 3.00 0.23 400.00 3.90 75.00 399.90 325.60 1.14 4.27 6,007,880.17 529,309.61 3.00 4.27 500.00 6.90 75.00 499.44 425.14 3.58 13.36 6,007,882.64 529,318.69 3.00 13.36 600.00 9.90 75.00 598.36 524.06 7.36 27.47 6,007,886.48 529,332.78 3.00 27.47 700.00 12.90 75.00 696.38 622.08 12.48 46.56 6,007,891.67 529,351.85 3.00 46.56 703.72 13.01 75.00 700.00 625.70 12.69 47.37 6,007,891.89 529,352.65 3.00 47.37 800.00 15.03 66.44 793.42 719.12 20.49 69.28 6,007,899.77 529,374.53 3.00 69.28 900.00 17.38 59.75 889.45 815.15 33.20 94.07 6,007,912.57 529,399.27 3.00 94.07 1,000.00 19.90 54.66 984.20 909.90 50.58 120.87 6,007,930.05 529,426.00 3.00 120.87 1,100.00 22.54 50.69 1,077.41 1,003.11 72.57 149.59 6,007,952.16 529,454.63 3.00 149.59 1,200.00 25.25 47.53 1,168.84 1,094.54 99.12 180.16 6,007,978.83 529,485.09 3.00 180.16 1,300.00 28.02 44.94 1,258.22 1,183.92 130.16 212.49 6,008,009.99 529,517.30 3.00 212.49 1,400.00 30.83 42.80 1,345.31 1,271.01 165.60 246.50 6,008,045.56 529,551.17 3.00 246.50 1,500.00 33.67 40.97 1,429.88 1,355.58 205.34 282.10 6,008,085.43 529,586.60 3.00 282.10 1,600.00 36.53 39.41 1,511.68 1,437.38 249.27 319.18 6,008,129.51 529,623.50 3.00 319.18 1,677.06 38.75 38.34 1,572.70 1,498.40 285.91 348.70 6,008,166.26 529,652.88 3.00 348.70 T3 1,700.00 39.41 38.04 1,590.51 1,516.21 297.28 357.64 6,008,177.66 529,661.78 3.00 357.64 1,763.61 41.25 37.25 1,639.00 1,564.70 329.88 382.78 6,008,210.36 529,686.78 3.00 382.78 Pfrost 1,766.83 41.34 37.21 1,641.42 1,567.12 331.57 384.07 6,008,212.05 529,688.06 3.00 384.07 1,800.00 41.34 37.21 1,666.32 1,592.02 349.02 397.32 6,008,229.55 529,701.24 0.00 397.32 1,866.83 41.34 37.21 1,716.50 1,642.20 384.18 424.02 6,008,264.81 529,727.80 0.00 424.02 1,900.00 42.55 36.39 1,741.17 1,666.87 401.93 437.30 6,008,282.62 529,741.01 4.00 437.30 1,915.55 43.12 36.02 1,752.57 1,678.27 410.46 443.54 6,008,291.17 529,747.22 4.00 443.54 1,975.98 43.12 36.02 1,796.68 1,722.38 443.87 467.83 6,008,324.67 529,771.38 0.00 467.83 K15 2,000.00 43.12 36.02 1,814.21 1,739.91 457.15 477.49 6,008,337.98 529,780.98 0.00 477.49 2,100.00 43.12 36.02 1,887.21 1,812.91 512.43 517.68 6,008,393.42 529,820.95 0.00 517.68 2,200.00 43.12 36.02 1,960.20 1,885.90 567.71 557.88 6,008,448.85 529,860.93 0.00 557.88 2,300.00 43.12 36.02 2,033.20 1,958.90 623.00 598.07 6,008,504.29 529,900.90 0.00 598.07 2,400.00 43.12 36.02 2,106.19 2,031.89 678.28 638.27 6,008,559.72 529,940.88 0.00 638.27 2,500.00 43.12 36.02 2,179.18 2,104.88 733.56 678.47 6,008,615.16 529,980.85 0.00 678.47 2,528.52 43.12 36.02 2,200.00 2,125.70 749.33 689.93 6,008,630.97 529,992.25 0.00 689.93 Surface Casing @ 2529' MD 2 200' ND: 1634' FSL, 1:005' FWL -S ec35-T13N-R09E - 13 3/8" 2,600.00 43.12 36.02 2,252.18 2,177.88 788.85 718.66 6,008,670.59 530,020.83 0.00 718.66 2,700.00 43.12 36.02 2,325.17 2,250.87 844.13 758.86 6,008,726.03 530,060.80 0.00 758.86 2,794.83 43.12 36.02 2,394.39 2,320.09 896.55 796.97 6,008,778.60 530,098.71 0.00 796.97 T3+800 2,800.00 43.12 36.02 2,398.16 2,323.86 899.41 799.05 6,008,781.47 530,100.77 0.00 799.05 6/27/2008 10:52:52AM Page 4 COMPASS 2003.16 Build 42F i ~~i~~~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-103 (E14) Wellbore: 3K-103 Design: 3K-103 (wp08) Planned Survey Measured Vertical Depth Inc lination Azimuth Depth (~) (°) (°) (ft) 2,900.00 43.12 36.02 2,471.16 3,000.00 43.12 36.02 2,544.15 3,100.00 43.12 36.02 2,617.15 3,200.00 43.12 36.02 2,690.14 3,300.00 43.12 36.02 2,763.13 3,322.82 43.12 36.02 2,779.79 Ugnu C 3,400.00 43.12 36.02 2,836.13 3,427.86 43.12 36.02 2,856.46 3,500.00 44.51 40.83 2,908.53 3,600.00 46.74 47.09 2,978.50 3,673.57 48.59 51.39 3,028.05 Ugnu B 3,700.00 49.30 52.87 3,045.41 3,800.00 52.12 58.21 3,108.76 3,827.00 52.92 59.58 3,125.19 Ugnu A 3,900.00 55.16 63.14 3,168.06 4,000.00 58.39 67.71 3,222.87 4,047.39 59.97 69.76 3,247.15 K13 4,100.00 61.77 71.96 3,272.76 4,200.00 65.27 75.95 3,317.36 4,300.00 68.87 79.72 3,356.33 4,400.00 72.55 83.30 3,389.37 4,500.00 76.29 86.75 3,416.23 4,597.86 80.00 90.01 3,436.34 4,600.00 80.00 90.01 3,436.71 4,697.86 80.00 90.01 3,453.70 W Sak D - 3K-103 D Top (03/05108) 4,700.00 80.00 90.01 3,454.07 4,727.86 80.00 90.01 3,458.91 4,800.00 80.00 90.01 3,471.44 4,900.00 80.00 90.01 3,488.80 4,927.86 80.00 90.01 3,493.64 4,966.48 81.16 90.01 3,499.96 WSakC 5,000.00 82.16 90.01 3,504.82 5,094.53 85.00 90.01 3,515.39 5,100.00 85.00 90.01 3,515.86 5,200.00 85.00 90.01 3,524.58 5,300.00 85.00 90.01 3,533.29 5,400.00 85.00 90.01 3,542.01 5,411.36 85.00 90.01 3,543.00 5,441.36 85.00 90.01 3,545.61 C~ Hatliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan 3K-103 (E14) Doyon15 (34.3+40) @ 74.30ft Doyon15 (34.3+40) @ 74.30ft True Minimum Curvature Map Map TVDss +N/-S +E/-W Northing Easting DLS Vert Section ft (ft) (ft) (ft) (ft) 2,396.86 2,396.86 954.70 839.25 6,008,836.90 530,140.75 0.00 839.25 2,469.85 1,009.98 879.44 6,008,892.34 530,180.72 0.00 879.44 2,542.85 1,065.26 919.64 6,008,947.77 530,220.70 0.00 919.64 2,615.84 1,120.55 959.84 6,009,003.21 530,260.67 0.00 959.84 2,688.83 1,175.83 1,000.03 6,009,058.64 530,300.65 0.00 1,000.03 2,705.49 1,188.44 1,009.20 6,009,071.29 530,309.77 0.00 1,009.20 2,761.83 1,231.11 1,040.23 6,009,114.08 530,340.62 0.00 1,040.23 2,782.16 1,246.51 1,051.43 6,009,129.52 530,351.76 0.00 1,051.43 2,834.23 1,285.60 1,082.47 6,009,168.72 530,382.64 5.00 1,082.47 2,904.20 1,336.95 1,132.08 6,009,220.26 530,432.05 5.00 1,132.08 2,953.75 1,372.41 1,173.28 6,009,255.89 530,473.10 5.00 1,173.28 2,971.11 1,384.65 1,189.01 6,009,268.18 530,488.79 5.00 1,189.01 3,034.46 1,428.34 1,252.82 6,009,312.12 530,552.42 5.00 1,252.82 3,050.89 1,439.41 1,271.17 6,009,323.26 530,570.72 5.00. 1,271.17 3,093.76 1,467.70 1,323.02 6,009,351.75 530,622.45 5.00 1,323.02 3,148.57 1,502.41 1,399.08 6,009,386.75 530,698.37 5.00 1,399.08 3,172.85 1,517.16 1,437.00 6,009,401.65 530,736.23 5.00 1,437.00 3,198.46 1,532.22 1,480.42 6,009,416.88 530,779.58 5.00 1,480.42 3,243.06 1,556.90 1,566.41 6,009,441.90 530,865.47 5.00 1,566.41 3,282.03 1,576.26 1,656.41 6,009,461.61 530,955.38 5.00 1,656.41 3,315.07 1,590.15 1,749.73 6,009,475.87 531,048.64 5.00 1,749.73 3,341.93 1,598.48 1,845.67 6,009,484.57 531,144.53 5.00 1,845.67 3,362.04 1,601.17 1,941.38 6,009,487.63 531,240.22 5.00 1,941.38 3,362.41 1,601.17 1,943.48 6,009,487.64 531,242.32 0.00 1,943.48 3,379.40 1,601.15 2,039.86 6,009,488.00 531,338.69 0.00 2,039.86 3,379.77 1,601.15 2,041.96 6,009,488.01 531,340.79 0.00 2,041.96 3,384.61 1,601.14 2,069.40 6,009,488.11 531,368.23 0.00 2,069.40 3,397.14 1,601.13 2,140.44 6,009,488.37 531,439.26 0.00 2,140.44 3,414.50 1,601.11 2,238.92 6,009,488.74 531,537.73 0.00 2,238.92 3,419.34 1,601.10 2,266.36 6,009,488.84 531,565.17 0.00 2,266.36 3,425.66 1,601.10 2,304.46 6,009,488.99 531,603.26 3.00 2,304.46 3,430.52 1,601.09 2,337.62 6,009,489.11 531,636.42 3.00 2,337.62 3,441.09 1,601.07 2,431.55 6,009,489.46 531,730.34 3.00 2,431.55 3,441.56 1,601.07 2,437.00 6,009,489.48 531,735.79 0.00 2,437.00 3,450.28 1,601.05 2,536.62 6,009,489.85 531,835.40 0.00 2,536.62 3,458.99 1,601.03 2,636.24 6,009,490.23 531,935.01 0.00 2,636.24 3,467.71 1,601.01 2,735.86 6,009,490.60 532,034.62 0.00 2,735.86 3,468.70 1,601.01 2,747.17 6,009,490.64 532,045.93 0.00 2,747.17 3,471.31 1,601.00 2,777.06 6,009,490.75 532,075.82 0.00 2,777.06 6/27/2008 10:52:52AM Page 5 COMPASS 2003.16 Build 42F a~~~~~~~ ~~ Halliburton -Sperry Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-103 (E14) Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Doyon15 (34.3+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: Doyon15 (34.3+40) @ 74.30ft Site: Kuparuk 3K Pa d North Reference: True Well: Plan 3K-103 (E14) Survey Calculation Method: Minimum Curvature Wellbore: 3K-103 Design: 3K-103 (wp08) ' Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth NDss +NI-S +EI-W Northing Easting DLS Vert Section (ft) (°) ( ~) (ft) ft (fti (ft) (ft) (ft) 3,471.32 5,441.40 85.00 90.01 3,545.62 3,471.32 1,601.00 2,777.10 6,009,490.75 532,075.85 0.00 2,777.10 Int. Casing @ 5441' MD, 3546' ND: 2485' F SL, 2186' F EL - Sec35-T13N-R09E - 9 5/8" 5,471.15 86.18 90.05 3,547.91 3,473.61 1,600.99 2,806.76 6,009,490.85 532,105.51 3.97 2,806.76 5,484.88 86.18 90.05 3,548.82 3,474.52 1,600.98 2,820.46 6,009,490.89 532,119.21 0.00 2,820.46 W Sak B 5,500.00 86.18 90.05 3,549.83 3,475.53 1,600.96 2,835.55 6,009,490.94 532,134.30 0.00 2,835.55 5,600.00 86.18 90.05 3,556.49 3,482.19 1,600.88 2,935.32 6,009,491.25 532,234.06 0.00 2,935.32 5,620.99 86.18 90.05 3,557.89 3,483.59 1,600.86 2,956.26 6,009,491.31 532,255.00 0.00 2,956.26 5,684.97 88.75 90.01 3,560.72 3,486.42 1,600.83 3,020.18 6,009,491.53 532,318.91 4.02 3,020.18 5,700.00 88.75 90.01 3,561.05 3,486.75 1,600.83 3,035.21 6,009,491.59 532,333.93 0.00 3,035.21 5,800.00 88.75 90.01 3,563.23 3,488.93 1,600.81 3,135.18 6,009,491.96 532,433.90 0.00 3,135.18 5,900.00 88.75 90.01 3,565.41 3,491.11 1,600.79 3,235.16 6,009,492.34 532,533.87 0.00 3,235.16 6,000.00 88.75 90.01 3,567.59 3,493.29 1,600.77 3,335.14 6,009,492.71 532,633.83 0.00 3,335.14 6,100.00 88.75 90.01 3,569.77 3,495.47 1,600.76 3,435.11 6,009,493.09 532,733.80 0.00 3,435.11 6,200.00 88.75 90.01 3,571.96 3,497.66 1,600.74 3,535.09 6,009,493.46 532,833.76 0.00 3,535.09 6,300.00 88.75 90.01 3,574.14 3,499.84 1,600.72 3,635.06 6,009,493.84 532,933.73 0.00 3,635.06 6,334.97 88.75 90.01 3,574.90 3,500.60 1,600.71 3,670.03 6,009,493.97 532,968.69 0.00 3,670.03 3K-103 CP1 (03/05/08) 6,400.00 89.38 90.17 3,575.96 3,501.66 1,600.61 3,735.05 6,009,494.12 533,033.70 1.00 3,735.05 6,500.00 90.35 90.42 3,576.20 3,501.90 1,600.09 3,835.04 6,009,493.99 533,133.69 1.00 3,835.04 6,507.48 90.42 90.44 3,576.15 3,501.85 1,600.03 3,842.52 6,009,493.97 533,141.17 1.00 3,842.52 6,600.00 90.42 90.44 3,575.47 3,501.17 1,599.32 3,935.04 6,009,493.62 533,233.68 0.00 3,935.04 6,700.00 90.42 90.44 3,574.74 3,500.44 1,598.55 4,035.03 6,009,493.24 533,333.66 0.00 4,035.03 6,800.00 90.42 90.44 3,574.00 3,499.70 1,597.78 4,135.03 6,009,492.86 533,433.65 0.00 4,135.03 6,900.00 90.42 90.44 3,573.27 3,498.97 1,597.01 4,235.02 6,009,492.48 533,533.64 0.00 4,235.02 7,000.00 90.42 90.44 3,572.54 3,498.24 1,596.24 4,335.02 6,009,492.11 533,633.62 0.00 4,335.02 7,100.00 90.42 90.44 3,571.80 3,497.50 1,595.47 4,435.01 6,009,491.73 533,733.61 0.00 4,435.01 7,200.00 90.42 90.44 3,571.07 3,496.77 1,594.70 4,535.00 6,009,491.35 533,833.60 0.00 4,535.00 7,300.00 90.42 90.44 3,570.34 3,496.04 1,593.92 4,635.00 6,009,490.97 533,933.58 0.00 4,635.00 7,305.11 90.42 90.44 3,570.30 3,496.00 1,593.89 4,640.11 6,009,490.95 533,938.69 0.00 4,640.11 3K-103 CP2 (03/05f08) 7,400.00 91.37 90.41 3,568.82 3,494.52 1,593.18 4,734.98 6,009,490.62 534,033.56 1.00 4,734.98 7,466.29 92.03 90.39 3,566.85 3,492.55 1,592.72 4,801.24 6,009,490.42 534,099.81 1.00 4,801.24 7,500.00 92.03 90.39 3,565.66 3,491.36 1,592.49 4,834.93 6,009,490.32 534,133.50 0.00 4,834.93 7,600.00 92.03 90.39 3,562.11 3,487.81 1,591.81 4,934.86 6,009,490.04 534,233.42 0.00 4,934.86 7,700.00 92.03 90.39 3,558.57 3,484.27 1,591.13 5,034.80 6,009,489.75 534,333.35 0.00 5,034.80 7,800.00 92.03 90.39 3,555.03 3,480.73 1,590.45 5,134.73 6,009,489.46 534,433.28 0.00 5,134.73 7,900.00 92.03 90.39 3,551.48 3,477.18 1,589.78 5,234.67 6,009,489.18 534,533.21 0.00 5,234.67 8,000.00 92.03 90.39 3,547.94 3,473.64 1,589.10 5,334.60 6,009,488.89 534,633.13 0.00 5,334.60 8,100.00 92.03 90.39 3,544.39 3,470.09 1,588.42 5,434.54 6,009,488.61 534,733.06 0.00 5,434.54 8,200.00 92.03 90.39 3,540.85 3,466.55 1,587.74 5,534.47 6,009,488.32 534,832.99 0.00 5,534.47 8,300.00 92.03 90.39 3,537.30 3,463.00 1,587.06 5,634.41 6,009,488.04 534,932.91 0.00 5,634.41 8,336.80 92.03 90.39 3,536.00 3,461.70 1,586.81 5,671.19 6,009,487.93 534,969.69 0.00 5,671.19 3K-103 CP3 (03/05/08) 8,400.00 91.80 92.27 3,533.89 3,459.59 1,585.35 5,734.33 6,009,486.71 535,032.83 3.00 5,734.33 6/27/2008 10:52:52AM Page 6 COMPASS 2003.16 Build 42F i • Halliburton -Sperry ~~~ ~ Sta ndard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-103 (E 14) Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Doyonl5 (34.3+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: Doyon15 (34.3+40) @ 74.30ft Site: Kuparuk 3K Pad North Reference: True Welh Plan 3K-103 (E14) Survey Calculation Method: Minimum Curvature Wellbore: 3K-103 it Design: 3K-103 (wp08) ~ Planned Survey Measured Vertical Map Map Depth In clination Azimuth Depth NDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) ( °) (ft) ff (ft) (ft) (ft) (ft) 3,456.75 8,500.00 91.44 95.25 3,531.05 3,456.75 1,578.79 5,834.06 6,009,480.55 535,132.58 3.00 5,834.06 8,600.00 91.07 98.23 3,528.86 3,454.56 1,567.06 5,933.34 6,009,469.21 535,231.89 3.00 5,933.34 8,643.35 90.91 99.52 3,528.11 3,453.81 1,560.37 5,976.16 6,009,462.69 535,274.73 3.00 5,976.16. 8,700.00 90.91 99.52 3,527.21 3,452.91 1,551.00 6,032.02 6,009,453.54 535,330.63 0.00 6,032.02 8,800.00 90.91 99.52 3,525.62 3,451.32 1,534.47 6,130.63 6,009,437.39 535,429.29 0.00 6,130.63 8,900.00 90.91 99.52 3,524.03 3,449.73 1,517.93 6,229.24 6,009,421.25 535,527.96 0.00 6,22924 9,000.00 90.91 99.52 3,522.44 3,448.14 1,501.39 6,327.85 6,009,405.10 535,626.62 0.00 6,327.85 9,100.00 90.91 99.52 3,520.85 3,446.55 1,484.86 6,426.46 6,009,388.95 535,72528 0.00 6,426.46 9,200.00 90.91 99.52 3,51926 3,444.96 1,468.32 6,525.07 6,009,372:80 535,823.95 0.00 6,525.07 9,300.00 90.91 99.52 3,517.67 3,443.37 1,451.78 6,623.68 6,009,356.66 535,922.61 0.00 6,623.68 9,335.55 90.91 99.52 3,517.10 3,442.80 1,445.90 6,658.74 6,009,350.92 535,957.69 0.00 6,658.74 3K-103 CP4 (03/05/08) 9,400.00 89.94 98.67 3,516.62 3,442.32 1,435.72 6,722.38 6,009,340.98 536,021.36 2.00 6,722.38 9,454.76 89.12 97.95 3,517.07 3,442.77 1,427.81 6,776.56 6,009,33328 536,075.57 2.00 6,776.56 9,500.00 89.12 97.95 3,517.76 3,443.46 1,421.55 6,821.36 6,009,32721 536,120.39 0.00 6,821.36 9,600.00 89.12 97.95 3,51929 3,444.99 1,407.73 6,920.39 6,009,313.78 536,219.46 0.00 6,920.39 9,700.00 89.12 97.95 3,520.83 3,446.53 1,393.91 7,019.42 6,009,300.35 536,318.53 0.00 7,019.42 9,800.00 89.12 97.95 3,522.36 3,448.06 1,380.09 7,118.45 6,009,286.92 536,417.60 0.00 7,118.45 9,900.00 89.12 97.95 3,523.89 3,449.59 1,36627 7,217.47 6,009,273.49 536,516.68 0.00 7,217.47 10,000.00 89.12 97.95 3,525.43 3,451.13 1,352.45 7,316.50 6,009,260.06 536,615.75 0.00 7,316.50 10,100.00 89.12 97.95 3,526.96 3,452.66 1,338.63 7,415.53 6,009,246.63 536,714.82 0.00 7,415.53 10,135.19 89.12 97.95 3,527.50 3,45320 1,333.77 7,450.38 6,009,241.90 536,749.69 0.00 7,450.38 3K-103 CP5 (03/05!08) 10,17927 89.99 98.12 3,527.84 3,453.54 1,327.61 7,494.02 6,009,235.91 536,793.35 2.00 7,494.02 10,200.00 89.99 98.12 3,527.85 3,453.55 1,324.68 7,514.55 6,009,233.07 536,813.88 0.00 7,514.55 10,300.00 89.99 98.12 3,527.87 3,453.57 1,310.56 7,613.55 6,009,219.34 536,912.93 0.00 7,613.55 10,400.00 89.99 98.12 3,527.90 3,453.60 1,296.45 7,712.54 6,009,205.61 537,011.97 0.00 7,712.54 10,500.00 89.99 98.12 3,527.92 3,453.62 1,282.33 7,811.54 6,009,191.88 537,111.01 0.00 7,811.54 10,600.00 89.99 98.12 3,527.95 3,453.65 1,26821 7,910.54 6,009,178.16 537,210.05 0.00 7,910.54 10,700.00 89.99 98.12 3,527.97 3,453.67 1,254.09 8,009.54 6,009,164.43 537,309.10 0.00 8,009.54 10,800.00 89.99 98.12 3,527.99 3,453.69 1,239.97 8,108.54 6,009,150.70 537,408.14 0.00 8,108.54 10,900.00 89.99 98.12 3,528.02 3,453.72 1,225.85 8,207.54 6,009,136.97 537,507.18 0.00 8,207.54 11,000.00 89.99 98.12 3,528.04 3,453.74 1,211.73 8,306.53 6,009,12324 537,60623 0.00 8,306.53 11,100.00 89.99 98.12 3,528.07 3,453.77 1,197.62 8,405.53 6,009,109.52 537,70527 0.00 8,405.53 11,200.00 89.99 98.12 3,528.09 3,453.79 1,183.50 8,504.53 6,009,095.79 537,804.31 0.00 . 8,504.53 11,235.71 89.99 98.12 3,528.10 3,453.80 1,178.46 8,539.89 6,009,090.89 537,839.68 0.00 8,539.89 3K-103 CP6 (03/05(08) 11,300.00 88.06 98.10 3,52920 3,454.90 1,169.39 8,603.52 6,009,082.07 537,903.35 3.00 8,603.52 11,400.00 85.06 98.09 3,53520 3,460.90 1,155.33 8,702.33 6,009,068.40 538,002.20 3.00 8,702.33 11,449.42 83.57 98.08 3,540.10 3,465.80 1,148.42 8,751.02 6,009,061.68 538,050.91 3.00 8,751.02 11,500.00 83.57 98.08 3,545.76 3,471.46 1,141.36 8,800.78 6,009,054.82 538,100.70 0.00 8,800.78 11,600.00 83.57 98.08 3,556.95 3,482.65 1,127.40 8,899.17 6,009,04124 538,199.13 0.00 8,899.17 11,699.97 83.57 98.08 3,568.13 3,493.83 1,113.44 8,997.52 6,009,027.67 538,297.53 0.00 8,997.52 11,700.00 83.57 98.08 3,568.14 3,493.84 1,113.44 8,997.56 6,009,027.67 538,297.56 0.00 8,997.56 11,800.00 86.58 98.06 3,576.72 3,502.42 1,099.45 9,096.19 6,009,014.08 538,39624 3.00 9,096.19 6/27/2008 10:52:52AM Page 7 COMPASS 2003.16 Build 42F ORIGINAL Halliburton -Sperry L ~~ ~ "'~'*~ Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-103 (E14) Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Doyon15 (34.3+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: Doyon15 (34.3+40) @ 74.30ft Site: Kuparuk 3K Pad North Reference: True WeII: Plan 3K-103 (E14) Survey Calculation Method: Minimum Curvature Wellbore: 3K-103 Design: 3K-103 (wp08) Planned Survey Measured Vertical Map Map ~ Depth Inclination Azimuth Depth NDss +N/-S +EI-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ftj 3,502.66 11,804.14 86.70 98.06 3,576.96 3,502.66 1,098.87 9,100.28 6,009,013.51 538,400.33 3.00 9,100.28 11,900.00 86.70 98.06 3,582.48 3,508.18 1,085.46 9,195.04 6,009,000.47 538,495.13 0.00 9,195.04 12,000.00 86.70 98.06 3,588.24 3,513.94 1,071.46 9,293.88 6,008,986.86 538,594.02 0.00 9,293.88 12,100.00 86.70 98.06 3,593.99 3,519.69 1,057.46 9,392.73 6,008,973.25 538,692.92 0.00 9,392.73 12,200.00 86.70 98.06 3,599.75 3,525.45 1,043.46 9,491.58 6,008,959.64 538,791.81 0.00 9,491.58 12,300.00 86.70 98.06 3,605.51 3,531.21 1,029.46 9,590.43 6,008,946.04 538,890.70 0.00 9,590.43 12,400.00 86.70 98.06 3,611.26 3,536.96 1,015.47 9,689.28 6,008,932.43 538,989.59 0.00 9,689.28 12,404.13 86.70 98.06 3,611.50 3,537.20 1,014.89 9,693.36 6,008,931.87 538,993.68 0.00 9,693.36 BHL ~ 12404' IND, 3612' ND: 1894' FSL, 5 51' FEL - Sec36-T13N-R09E ' 12,404.14 86.70 98.06 3.611.50 3,537.20 1,014.89 9,693.36 6,008,931.87 538,993.68 0.00 9,693.36 3K-103 Toe (03105108) Targets Target Name - hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting - Shape (°) (°) lft) (ft) (ft) (ft) (ft) 3K-103 D Top (03/05/08) 1.46 90.02 3,453.70 1,601.15 2,039.86 6,009,488.00 531,338.69 - plan hits target - Point 3K-103 CP3 (03/05!08) -1.09 98.12 3,536.00 1,586.81 5,671.19 6,009,487.93 534,969.69 - plan hits target - Point 3K-103 CP2 (03/05/08) -1.91 90.39 3,570.30 1,593.89 4,640.11 6,009,490.95 533,938.69 - plan hits target - Point 3K-103 CP6 (03/05/08) 4.09 98.07 3,528.10 1,178.46. 8,539.89 6,009,090.89 537,839.68 - plan hits target - Point 3K-103 Toe (03/05/08) 2.06 98.11 3,611.50 1,014.89 9,693.36 6,008,931.87 538,993.68 - plan hits target - Point 3K-103 CP4 (03/05/08) 0.75 98.06 3,517.10 1,445.90 6,658.74 6,009,350.92 535,957.69 - plan hits target - Point 3K-103 CP5 (03/05/08) 0.03 98.11 3,527.50 1,333.77 7,450.38 6,009,241.90 536,749.69 - plan hits target - Point 3K-103 CP1 (03/05/08) -0.27 90.39 3,574.90 1,600.71 3,670.03 6,009,493.97 532,968.69 - plan hits target - Point 6/27/2008 10:52:52AM Page 8 COMPASS 2003.16 Build 42F fi~~~~ i ! Halliburton -Sperry ~~~'~"~ Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-103 (E14) Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Doyon15 (34.3+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: Doyon15 (34.3+40) @ 74.30ft Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-103 (E14) Survey Calculation Method: Minimum Curvature Wellbore: 3K-103 Design: 3K-103 (wp08) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,528.52 2,200.00 13 3/8" 13-3/8 16 5,441.40 3,545.62 9 5/8" 9-5/8 12-1/4 12,404.14 3,611.50 31/2" 3-1/2 6-3/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS pip Direction (ft) (ft) ft Name Lithology (°) (~) 4,047.39 3,247.15 K 13 0.00 5,484.88 3,548.82 W Sak B 0.00 4,966.48 3,499.96 W Sak C 0.00 3,673.57 3,028.05 Ugnu B 0.00 3,827.00 3,125.19 Ugnu A 0.00 2,794.83 2,394.39 T3+g00 0.00 1,763.61 1,639.00 Pfrost 0.00 1,677.06 1,572.70 T3 0.00 4,697.86 3,453.70 W Sak D 0.00 3,322.82 2,779.79 Ugnu C 0.00 1,975.98 1,796.68 K15 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N!-S +E/-W (ft) (ft) (ft) (ft) Comment 40.00 40.00 0.00 0.00 SHL: 885' FSL, 314' FWL -Sec35-T13N-R09E 2,528.52 2,200.00 749.33 689.93 Surface Casing @ 2529' MD 2200' ND: 1634' FSL, 1005' FWL -Sec35-T13 5,441.40 3,545.62 1,601.00 2,777.10 Int. Casing @ 5441' MD, 3546' ND: 2485' FSL, 2186' FEL -Sec35-T13N-RC 12,404.13 3,611.50 1,014.89 9,693.36 BHL @ 12404' MD, 3612' ND: 1894' FSL, 551' FEL - Sec36-T13N-R09E 6/27/2008 10:52:52AM a~e ~ ~ ~ COMPASS 2003.16 Build 42F ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-103 (E14) 3K-103 3K-103 (wp08) ~~arerr C~rl~nc~ S-®rvices ~-, Clearance Summary ~: Anticollision Report ~--° 27 June, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-103 (E14) - 3K-103 - 3K-103 (wp08) Well Coordinates: 6,007,630.94 N, 1,669,336.72E (70° 25' 56.33" N, 149° 45' 51.30" W) Datum Height: Doyon15 (34.3+40) @ 74.30ft Scan Range: 0.00 to 12,404.17 ft. Measured Depth. Scan Radius is 1,436.42 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 M~1-I.ILfBURTOM~1 Sperry Drilling Services SURVEY PROGRAM Date: 2008-0(r15T00:00:00 Validated: Yes Version: 28 Depth From Depth To Survey/Plan 1'001 40.00 1012.00 3Ih 103 (wp08) (3K 103) CIYCYRO-SS 1012.00 12403.89 31i 103 (wp08) (3K-103) MWD+IFR-AK-CAZrSC 3K-10: s)<-~` . 3K-0 " 3K-0 3K-1 - 3K-1 3K-1 3K-1 3K-108(1n ConocoPhillips (Alaska) Inc. -Kup2 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based 90 3K-2 I""°'I /~1' ' ~. 180~.'~, `,- src-~3swptl(I 3K-107 (wls0.} { ~ ` 3K-3 ` ', ~ 3K-3 ~ 3K-101 (wp0 )` ~~ 3K-1 ~ ~ 3K-E20 wp0 ~~, 3K-1 3K-105wp Travelling Cylinder Azimuth (TFO+AZI) ~°J vs Centre to Centre Separation X200 ft/inJ Details: Plan 3K-103 (E74) North American Datum 1983 Alaska Zone 4 Ground Level: 34.30 +NI-S +EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 6007630.94 1689336.72 70° 25' 56.328 N 149° 45' 51.299 W REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Plan 3K-103 (E14), True North Vertical (TVD) Reference: Doyonl5(34.3+40) @ 74.308 Section (VS) Reference: Slot- (O.OON, O.OOE) Measured Depth Reference: Doyonl5(34.3+q0) @ 74.30ft Calculation Method: Minimum Curvature From Colour To MD 40 262 262 512 512 762 762 1012 1012 1262 1262 1512 1512 - - ~ ~ 1762 1762 -- -~ 2012 2012 2262 2262 2512 2512 2762 2762 3012 3012 4012 4012 5012 5012 6012 6012 7012 7012 8012 8012 9012 9012 10012 10012 11012 11012 12012 12012 -- ---- 13012 13012 14012 14012 15012 90 3K-3 Travelling Cylinder Azimuth (TFO+AZI) (°) vs Centre to Centre Separation (50 ft/in) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 ao.oo D.DD o.DO ao.oo D.DD o.oD o.oo a.oD a.oD z z7o.oo o.oD o.DD 270.00 D.oD o.oo D.oo o.oD o.DD 3 703.72 13.01 75.00 700.00 12.69 47.37 3.00 75.00 47.37 4 1766.83 41.34 37.21 1641.42 331.57 384.07 3.00 310.00 384.07 5 1866 83 41.34 37.21 1716.50 384.18 424.02 0.00 0.00 424.02 6 1915.64 43.12 36.01 7752.64 410.51 443.58 4.00 -24.97 443.56 7 3427.75 43.12 36.01 2856.38 1246.58 1051.21 0.00 0.00 1057.21 8 4597.90 80.00 90.01 3436.34 1601.35 1947 22 5.00 69.73 1941.22 9 4697.90 80.00 90.07 3453.70 1601.33 2039.71 0.00 0.00 2039.71 3K-103 D Top (03/05/087 70 4727.90 80.00 90.01 3458.91 1601.32 2069.25 0.00 0.00 2069.25 11 4927.90 80.00 90.01 3493.64 1601.28 2266.21 0.00 0.00 2266.21 12 5094.57 85.00 90.01 3515.39 1601.25 2431.40 3.00 0.00 2431.40 13 5411.40 85.00 90.01 3543.00 1601.19 2747.02 0.00 0.00 2747.02 14 5441.40 85.00 90.01 3545.61 1601.18 2778.91 0.00 0.00 2776.91 15 5470.88 86.18 90.02 3547.68 1601.78 2806.30 4.00 0.20 2806.30 16 5620.74 86.78 90.02 3557.88 1601.14 2955.83 0.00 0.00 2955.83 17 5685.01 88.75 90.01 3560.72 1601.12 3020.03 4.00 -0.12 3020.03 18 6335.01 88.75 90.01 3574.90 1601.01 3669.88 0.00 0.00 3669.88 3K-103 CPi (03/OSi08) 19 6507.40 90.42 90.44 3576.15 1600.33 3842.25 1.00 14.35 3842.25 20 7305.15 90.42 90.44 3570.30 1594.25 4639.95 0.00 0.00 4639.95 3K-103 CP2 (03/OS/OB) 21 7466.34 92.03 90.38 3566.85 1593.09 4801.10 1.00 -7.87 4801.10 22 8336.84 92.03 90.38 3536.00 1587.25 5671.04 0.00 0.00 5671.D4 3K-103 CP3 (03/05/08) 23 8643.39 90.91 99.52 3528.11 1560.83 5976.01 3.00 96.86 5976.01 24 9335.58 90.91 99.52 3517.10 1446.41 6658.60 0.00 0.00 6658.60 3K-103 CP4 (03!05/08) 25 9454.80 69.12 97.94 3517.07 1428.31 6778.42 2.00 -738.66 6778.42 26 10135.23 89.12 97.94 3527.50 1334.32 7450.25 0.00 0.00 7450.25 3K-103 CPS (03/OS/OB) 27 10179.31 89.99 98.11 3527.84 1328.17 7493.89 2.00 11.27 7493.89 28 11235.75 89.99 98.11 3528.10 1179.08 8539.76 0.00 0.00 8539.76 3K-103 CP6 (03/05/08) 29 11449.46 63.57 98.07 3540.10 1149.07 8750.90 3.00 -179.59 8750.90 30 11700.00 83.57 98.07 3568.13 1114.14 8997.41 0.00 0.00 8997.41 31 11804.17 86.70 98.06 3576.96 1099.58 9100.16 3.00 -0.12 9100.76 32 12404.17 86.70 98.06 3611.50 1015.59 9693.25 0.00 0.00 9693.25 3K-103 Toe (03/05/08) Interpolation Method: MD, interval: 50.00 Depth Range From: 40.00 To 12404.17 Centre Distance: 1438.42 Reference: Plan: 3K-103 (wp08) (Plan 3K-103 (E14)/3K-103) 3K-104 (vvp0~;/~ 3K-1 180 3K-2 3K-105 wp 3K-1 ~ j 3K-3 ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTC~tV Kuparuk River Unit Anticollision Report for Plan 3K-103 (E14) - 3K-103 (wp08) linder North Proximity Scan on Current Survey Data (North Reference) C Trav y . Reference Design: Kuparuk 3K Pad -Plan 3K-103 (E14) - 3K-103 - 3K-103 (wp08) Scan Range: 0.00 to 12,404.17 ff. Measured Depth. Scan Radius is 1,436.42 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Se aration Warnin p 9 Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft Kuparuk 3K Pad 557 70 2 109.93 2,557.70 51.29 2,400.00 1.875 Centre Distance Pass -Major Risk 3K-03 - 3K-03 - 3K-03 . , 81 567 4 170.45 4,567.81 43.60 4,275.00 1.344 Clearance Factor Pass -Major Risk 3K-03 - 3K-03 - 3K-03 . , 51 495 1 354.06 1,495.51 323.31 1,425.00 11.514 Centre Distance Pass -Major Risk 3K-06 - 3K-06 - 3K-06 . , 47 517 1 354.23 1,517.47 323.06 1,450.00 11.363 Clearance Factor Pass -Major Risk 3K-06 - 3K-06 - 3K-06 . , 72 728 1 317.93 1,728.72 283.02 1,700.00 9.106 Centre Distance Pass -Major Risk 3K-07 - 3K-07 - 3K-07 . , 95 769 1 318 29 769.95 1 282.78 1,750.00 8.961 Clearance Factor Pass -Major Risk 3K-07 - 3K-07 - 3K-07 . , . , 381 65 1 328.21 1,381.65 292.58 1,325.00 9.212 Centre Distance Pass -Major Risk 3K-08 - 3K-08 - 3K-08 . , 404 49 1 328.56 1,404.49 292.39 1,350.00 9.083 Clearance Factor Pass -Major Risk 3K-08 - 3K-08 - 3K-08 . , 04 1 324 308.17 1,324.04 275.88 1,275.00 9.545 Centre Distance Pass -Major Risk 3K-09 - 3K-09 - 3K-09 ~- , . 347 08 1 308.49 1,347.08 275.67 1,300.00 9.399 Clearance Factor Pass -Major Risk 3K-09 - 3K-09 - 3K-09 . , 324 85 1 309.92 1,324.85 275.58 1,275.00 9.025 Centre Distance Pass -Major Risk 3K-09 - 3K-09A - 3K-09A . , 95 347 1 310 16 347.95 1 275.29 1,300.00 8.894 Clearance Factor Pass -Major Risk 3K-09 - 3K-09A - 3K-09A . , . , 3K-10 - 3K-10 - 3K-10 1,128.54 243.64 1,128.54 219.07 1,100.00 9.915 Centre Distance Pass -Major Risk 56 1 152 243.81 1,152.56 218.85 1,125.00 9.771 Clearance Factor Pass -Major Risk 3K-10 - 3K-10 - 3K-10 , . 50 125 89 24 125.50 22.18 125.00 9.199 Centre Distance Pass -Major Risk 3K-102 - 3K-102 - 3K-102 . 49 250 . 26 05 250.49 20.63 250.00 4.807 Clearance Factor Pass -Major Risk 3K-102 - 3K-102 - 3K-102 . 125 50 . 24 89 125.50 22.18 125.00 9.199 Centre Distance Pass -Major Risk 3K-102 - 3K-102L1 - 3K-102L1 . 250 49 . 05 26 250.49 20.63 250.00 4.807 Clearance Factor Pass -Major Risk 3K-102 - 3K-102L1 - 3K-102L1 . . 3K-102 - 3K-102L1 P61 - 3K-102L1 PB1 125.50 24.89 125.50 22.18 125.00 9.199 Centre Distance Pass -Major Risk 102 - 3K-102L1 PB1 - 3K-102L1 P61 3K 250.49 26.05 250.49 20.63 250.00 4.807 Clearance Factor Pass -Major Risk - 077 64 1 236.26 1,077.64 212.43 1,050.00 9.915 Centre Distance Pass -Major Risk 3K-11 - 3K-11 - 3K-11 . , 44 1 126 236.57 1,126.44 211.88 1,100.00 9.581 Clearance Factor Pass -Major Risk 3K-11 - 3K-11 - 3K-11 , . 047 83 1 207.02 1,047.83 183.78 1,025.00 8.907 Centre Distance Pass -Major Risk 3K-12 - 3K-12 - 3K-12 . , 42 096 1 207 59 096.42 1 183.39 1,075.00 8.578 Clearance Factor Pass -Major Risk 3K-12 - 3K-12 - 3K-12 . , . , 97 915 32 185 915.97 160.41 900.00 7.440 Centre Distance Pass -Major Risk 3K-13 - 3K-13 - 3K-13 . 52 990 . 07 186 990.52 158.94 975.00 6.859 Clearance Factor Pass -Major Risk 3K-13 - 3K-13 - 3K-13 . 20 658 . 82 169 658.20 152.32 650.00 9.702 Centre Distance Pass -Major Risk 3K-14 - 3K-14 - 3K-14 . 885 78 . 49 173 885.78 149.44 875.00 7.213 Clearance Factor Pass -Major Risk 3K-14 - 3K-14 - 3K-14 . . • 27 June, 2008 - 17:21 Page 2 of 7 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTON Kuparuk River Unit Anticollision Report for Plan 3K-103 (E14) - 3K-103 (wp08) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-103 (E14) - 3K-103 - 3K-103 (wp08) Scan Range: 0.00 to 12,404.17 ft. Measured Depth. Scan Radius is 1,436.42 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft 3K-15 - 3K-15 - 3K-15 875.80 126.92 875.80 107.58 875.00 6.565 Centre Distance Pass -Major Risk 3K-15 - 3K-15 - 3K-15 898.69 127.28 898.69 107.44 900.00 6.413 Clearance Factor Pass -Major Risk 3K-16 - 3K-16 - 3K-16 970.15 94.58 970.15 73.30 975.00 4.445 Clearance Factor Pass -Major Risk 3K-17 - 3K-17 - 3K-17 628.69 90.69 628.69 77.04 625.00 6.645 Centre Distance Pass -Major Risk 3K-17 - 3K-17 - 3K-17 652.39 90.88 652.39 76.69 650.00 6.405 Clearance Factor Pass -Major Risk 3K-18 - 3K-18 - 3K-18 775.24 27.06 775.24 10.22 775.00 1.607 Clearance Factor Pass -Major Risk 3K-19 - 3K-19 - Gyro(861) + IFR Projection 3,445.63 324.87 3,445.63 250.98 3,225.00 4.397 Clearance Factor Pass -Major Risk 3K-19 - 3K-19 - 3K-19 3,447.82 324.68 3,447.82 252.79 3,225.00 4.516 Centre Distance Pass -Major Risk 3K-19 - 3K-19 - 3K-19 3,467.91 324.69 3,467.91 252.43 3,250.00 4.493 Clearance Factor Pass -Major Risk 3K-20 - 3K-20 - 3K-20 1,969.42 464.44 1,969.42 430.03 1,675.00 13.499 Centre Distance Pass -Major Risk -~„~ 3K-20 - 3K-20 - 3K-20 1,991.99 464.48 1,991.99 429.76 1,700.00 13.377 Clearance Factor Pass -Major Risk 3K-23 - 3K-23 - 3K-23 3,536.44 165.48 3,536.44 58.25 3,400.00 1.543 Centre Distance Pass -Major Risk 3K-23 - 3K-23 - 3K-23 3,580.54 166.04 3,580.54 57.05 3,450.00 1.524 Clearance Factor Pass -Major Risk 3K-24 - 3K-24 - 3K-24 2,183.51 365.49 2,183.51 313.98 1,925.00 7.096 Centre Distance Pass -Major Risk 3K-24 - 3K-24 - 3K-24 2,233.46 365.96 2,233.46 312.79 1,975.00 6.883 Clearance Factor Pass -Major Risk 3K-26 - 3K-26 - 3K-26 1,848.26 67.90 1,848.26 34.93 1,825.00 2.059 Clearance Factor Pass -Major Risk 3K-27 - 3K-27 - 3K-27 1,828.29 146.05 1,828.29 115.16 1,725.00 4.727 Clearance Factor Pass -Major Risk 3K-30 - 3K-30 - 3K-30 1,576.58 106.36 1,576.58 95.08 1,525.00 9.430 Centre Distance Pass -Minor 1/200 3K-30 - 3K-30 - 3K-30 4,885.86 118.89 4,885.86 64.88 4,650.00 2.202 Clearance Factor Pass -Minor 1/200 3K-31 - 3K-31 - 3K-31 1,115.98 204.84 1,115.98 183.21 1,100.00 9.472 Centre Distance Pass -Major Risk 3K-31 - 3K-31 - 3K-31 1,165.52 205.23 1,165.52 183.08 1,150.00 9.264 Clearance Factor Pass -Major Risk 3K-32 - 3K-32 - 3K-32 1,400.00 64.02 1,400.00 39.19 1,400.00 2.578 Clearance Factor Pass -Major Risk 3K-34 - 3K-34 - 3K-34 1,062.94 64.32 1,062.94 40.82 1,050.00 2.737 Clearance Factor Pass -Major Risk 3K-35 - 3K-35 - 3K-35 997.60 46.62 997.60 27.60 1,000.00 2.450 Clearance Factor Pass -Major Risk Plan 3K-101 (E9) - 3K-101 - 3K-101 (wp04) 487.57 48.23 487.57 37.66 475.00 4.564 Centre Distance Pass -Major Risk Plan 3K-101 (E9) - 3K-101 - 3K-101 (wp04) 635.03 49.15 635.03 35.31 625.00 3.553 Clearance Factor Pass -Major Risk ~ Plan 3K-103 (E14) - 3K-103 L1 - 3K-103 L1 (wp08) Plan 3K-104 (E16) - 3K-104 - 3K-104 (wp07) 262.00 25.00 262.00 19.35 250.00 4.420 Centre Distance Pass -Major Risk Plan 3K-104 (E16) - 3K-104 - 3K-104 (wp07) 386.45 26.17 386.45 17.81 375.00 3.130 Clearance Factor Pass -Major Risk Plan 3K-104 (E16) - 3K-104 L1 - 3K-104 L1 (wp07) 262.00 25.00 262.00 19.35 250.00 4.420 Centre Distance Pass -Major Risk 27 June, 2008 - 17:21 Page 3 of 7 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLI~UR"TC~N Kuparuk River Unit Anticollision Report for Plan 3K-103 (E14) - 3K-103 (wp08) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-103 (E14) - 3K-103 - 3K-103 (wp08) Scan Range: 0.00 to 12,404.17 ft. Measured Depth. Scan Radius is 1,436.42 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Se aration Warnin p g Site Name Depth Distance Depth Separation Depth Factor Minimum Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft Plan 3K-104 (E16) - 3K-104 L1 - 3K-104 L1 (wp07) 386.45 26.17 386.45 17.81 375.00 3.130 Clearance Factor Pass -Major Risk Plan 3K-105 (E15) - 3K-105 - 3K-105 wp04 262.00 50.01 262.00 44.35 250.00 8.840 Centre Distance Pass -Major Risk Plan 3K-105 (E15) - 3K-105 - 3K-105 wp04 460.70 52.13 460.70 42.12 450.00 5.211 Clearance Factor Pass -Major Risk Plan 3K-105 (E15) - 3K-105 L1 - 3K-E15 L1 (wp03) 262.00 50.01 262.00 44.35 250.00 8.840 Centre Distance Pass -Major Risk Plan 3K-105 (E15) - 3K-105 L1 - 3K-E15 L1 (wp03) 460.70 52.13 460.70 42.12 450.00 5.211 Clearance Factor Pass -Major Risk Plan 3K-106 (E6) - 3K-106 - 3K-106(wp01) 262.00 75.01 262.00 69.35 250.00 13.260 Centre Distance Pass -Major Risk Plan 3K-106 (E6) - 3K-106 - 3K-106(wp01) 385.55 76.11 385.55 67.76 375.00 9.116 Clearance Factor Pass -Major Risk Plan 3K-107 (E7) - 3K-107 - 3K-107 (wp02) 262.00 100.01 262.00 94.35 250.00 17.679 Centre Distance Pass -Major Risk Plan 3K-107 (E7) - 3K-107 - 3K-107 (wp02) 336.05 100.42 336.05 93.15 325.00 13.813 Clearance Factor Pass -Major Risk Plan 3K-E10 - 3K-E10 - 3K-E10 wp01 3,136.02 446.39 3,136.02 382.99 2,775.00 7.041 Centre Distance Pass -Major Risk Plan 3K-E10 - 3K-E10 - 3K-E10 wp01 3,181.99 447.02 3,181.99 382.61 2,825.00 6.940 Clearance Factor Pass -Major Risk Plan 3K-E19 - 3K-E19 - 3K-E19 wp01 262.00 112.50 262.00 107.18 250.00 21.113 Centre Distance Pass -Major Risk Plan 3K-E19 - 3K-E19 - 3K-E19 wp01 360.54 113.41 360.54 105.94 350.00 15.168 Clearance Factor Pass -Major Risk Plan 3K-E20 - 3K-E20 - 3K-E20 wp01 262.00 125.00 262.00 119.67 250.00 23.459 Centre Distance Pass -Major Risk Plan 3K-E20 - 3K-E20 - 3K-E20 wp01 335.84 125.42 335.84 118.48 325.00 18.074 Clearance Factor Pass -Major Risk Kuparuk 3R Pad Rendezvous Survev tool grogram From To Survey/Plan Survey Tool (ft) (ft) 40.00 1,012.00 3K-103 (wp08) CB-GYRO-SS 1,012.00 12,403.89 3K-103 (wp08) MWD+IFR-AK-CAZ-SC 27 June, 2008 - 17:29 Page 4 of 7 COMPASS 3K-l0~rillin~ Hazards mammary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud wei ht, use wei hted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), umpin out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Well Collision Low Regyro critical offset wells to decrease positional uncertainty. Utilize travelling cylinder plots for collision avoidance. Shut-in critical offset wells while drilling intermediate hole section. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. .Lost circulation Moderate Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper. hole filling. (use of trip sheets), pumping out 6-3/4" Open Hole / 3-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub and cuttings bed impellers, PWD tools monitoring and analysis, decreased mud wei ht Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during com letion run. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out or backreamin 3K-103 Drilling Hazards Summary.doc prepared by Dennis Hartwig 7/11/20089:28:01 AM Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/2' to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. For Dual 3-'/z" completion operations, 3-'h" dual rams to be installed and tested to 250 psi and 3,000 psi prior to completion run Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves - To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before _ running casing. For Dual 3-'/z" completion operations, 3-'/2" dual rams to be installed and tested to 250 psi and 3,000 psi prior to completion run Wellhead Valves tested to 3,000 psi upon assembly ,.' 13-5 BOP 3K diagram. vsd ConocoPhillips Doyon 15 West Sak 3 ksi Sheet 1 of 1 BOP Configuration prepared by Dennis~008 Alaska • Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/10/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 94# casing at120'MD < Base of Permafrost at 1,734' MD (1,639' TVD) < Top of Tail at 2,028' MD < 13 3/8", 68.0# casing in 16" OH TD at 2,528' MD (2,200' TVD) Mark of Schlumberger Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,028' MD. Lead Slurry Minimum pump time: 300 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1734' - 80') x 3.50 (250% excess) = 2434.9 ft3 0.4206 ft3/ft x (2028' - 1734') x 1.35 (35% excess) = 166.9 ft3 81.5 ft3 + 2434.9 ft3+ 166.9 ft3 = 2683.3 ft3 2683.3 ft3/ 4.45 ft3/sk = 603 sks Round up to 610 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 200 mina (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.46 ft3/sk 0.4206 ft3/ft x (2528' - 2028') x 1.35 (35% excess) = 283.9 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 283.9 ft3 + 66.5 ft3 = 350.4 ft3 350.4 ft3/ 2.46 ft3/sk = 142.4 sks Round up to 150 sks BHST = 42~, Estimated BHCT = 72~. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 5 483 96.6 131.6 Tail Slurry 5 66 13.2 144.8 Drop Top Plug 5.0 149.8 Water 5 20 4.0 153.8 Switch to Rig Pum s 5.0 158.8 Displacement 7 323 46.1 204.9 Slow Rate 3 20 6.7 211.6 MUD REMOVAL Recommended Mud Properties: 9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, T„ = 20-25 Centralizers: Recommend 1 per joint across zones of interest, and 2 per joint for bottom 8 joints for proper cement placement. ^^,IGINAL Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/10/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 13 3/8", 68.0# casing at 2,528' MD < Top of Tail at 2,822' MD < 9 5/8", 40.0#casing in 12 1/4" OH TD at 5,441' MD (3,546' TVD) CemCADE Preliminary Job Design 9.625" Lon string Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 2619' MD above the intermediate casing shoe. Tail Slurry Minimum thickening time: 240 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 2619' x 1.25 (25% excess) = 1025.3 ft3 0.4341 ft3/ft x 80' (Shoe Joint) = 34.7 ft3 1025.3 ft3 + 34.7 ft3 = 1060.0 ft3 1060.0 ft3/ 2.25 ft3/sk = 471.1 sks Round up to 480 sks BHST = 72`F, Estimated BHCT = 61 `F. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Vdume Time Time Stage (bpm) (bbl) (min) (min) Comments CW 100 5 50 10.0 10.0 Start Pumping Wash Drop Bottom Plug 10.0 20.0 MudPUSH I I 5 50 10.0 30.0 Start Pumping Spacer Tail Slurry 5 192 38.4 68.4 Mix and Pump Tail Slurry Drop Top Plug 5.0 73.4 Pump Water 5 20 4.0 77.4 Switch to Rig Pump 5.0 82.4 Displacement 6 374 62.3 144.7 Start Displacement Slow Rate 3 20 6.7 151.4 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. ORIGINAL Insulated Conductor: 20" 94# K-55 x 34" 0.312 WT +1- 80' ConocoPhi I I i ps 2008 West Sak Dual Injector System 2.875" DS Nipple 2.875"DS Nipple with Level 5 Rotating self-Aligning Multilateral (RAMT"") System GLM, Camco, 3-'/." x 1" KBG2-9 GLM, Camco, 3-%" x 1" KBG2-9 W~}est S a k 13-318" Casing Shoe 3 K-103 2628' MD, 2200' TVD \ ~ - Dual Tubing Strings Rotational Alignment Sub 3-%" 9.3#, L-80, 2.992" ID, 2.867" Drift ~~ 2.812" DB Nipple e 3-'/." x 9-5/8" OT Dual Packer - \ / 3-'/." z 3-`/." x 9-5/e`ll~al Seal J Module for RAM Hanger / 7" X 9-5/8" RAM Hanger 7" X 9-518" RAM Junction Mainbore Dritt: 3.68" Lateral Drift: 5.80" RAM HangerlSeal Bore Diverter OD: 8.375" Overall Length of RAM Junction: 39.3 tt Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 3'/:" x 3 '/z' 9-518" Dual Seal Module DSM OD: 7.62" Lateral Seal Assembly OD: 3.75" Lateral lD: 2.69" Mainbore Seal Stinger OD: 3.08" Mainbore ID: 2.69" D-Sand Casing Exit A697' MD, 3454' TVD ($0 deg) 'D' Sand Lateral 3-%" 9.3# Liner with Hydril 567 and ~~~ SLHT connections As Planned Casing Shoe 12398' MD, 3565' TVD 4'/=:" x 9318 RAM Seal Bore Diverter (SBD) for~Dual Seal Module 3-%" 12.6# IBTM Tubing 7" X 9-5/8" MLZXP Liner Hanger Packer rl.. Sealbore Receptacle 4.75" ID t,producpon~ Anclio ~~~~ ~~~ Baker Oil Tools ~., Seal Assembly ~11 \ S ~ ~ `-~ ~T'~:1 ~ e~_ ..~ 4.75" Seal OD 3.875"ID '6' Sand Lateral 3'/:" 9 3# Liner with Hydril 563 and "- ~ ~~ 3LHI wnnacHons "' 9-518" Casing Shoe, 40.0#, L-80 BTC Casing 5441' MD, 3546' TVD (84 deg) 12404' MDr ouy rw: _.. .. .. 1088 West Sak Dual Injector Concept ~ w TVD Conaco hillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3K Pad C~ Plan: 3K-103 (wp08) ~ 1/4 Mile Pool Scan ~ Sperry Drilling Services ~i."`~ a~ru Zs, Zoos T"" HALLIBURTON Drilling and Formation Evaluation Closest in POOL W 03 -° c`3 3K ll h A Referen ce Well: 3K-103 w 0 8 Plan ffset - : e Closest : roac Coords. - Coords. - 3-D ctr-ctr Meas. Subsea ASP N(+)/S(-) View VS 90° Comments Meas. De th I ncl. An le TRUE Azi. Subsea ND ASP N(+)/S(-) E(+)/W(-) ( View VS 90°) Comments Distance. _ De th I ncl. An le TRUE Azi. TVD E + /W - m istance POOL Min Distance (237.59 ft) in POOL (237.59 ft) in POOL (4697.9 - 12398.45 (4697.9 - 12398.45 MD) to 3K-103 L1 MD) to 3K-03 (3359.4 (wp08) Plan (3359.4 - 237 59 4697.9 80 90.01 3305.097 6009239.8 1671371 2040.894 - 3569.2 NDss) 4318 41.74 62.39 3456.07 60090'6.1 1671258 1923.71 3569.2 NDss) . h A Referen ce Well: 3K-103 w 08 Plan Offset W ell: 3K-07 .. Closest : roac Coords. - 3-D ctr-ctr Meas. Subsea Coords. - ASP N(+)/S(-) View VS ° Meas. th D An le Incl TRUE Azi Subsea ND ASP N(+)/S(-) E + IV1/ - View VS 90° Comments tance Di De th Incl. An le TRUE Azi. ND E + /VV - 90 Comments e . . . s POOL Min Distance (1238.93 ft) in POOL POOL Min Distance (4679.9 - 12398.45 (1238.93 ft) in POOL MD) to 3K-103 L1 (4679.9 - 12398.45 (wp08) Plan (3359.4 - 90 01 3305 097 8 6009239 1671371 2040.894 MD) to 3K-07 (3359.4 - 3569.2 NDss) 4225 41.52 94.25 3584.96 6008104 1670963 1626.24 3569.2 TVDss) 1238.93 4697.9 80 . . . 3K ll 19 \ -'~0 h A Referen ce Well : 3K-10 3 w 08 Plan Offset : We - Closest : roac Coords. - Coords. - 3-D ctr-ctr Meas. Subsea ASP N(+)/S(-) /W E View VS (90° Comments Meas. De th Incl. An le TRUE Azi. Subsea ND ASP N(+)/S(-) E + IW(- View VS 90°) Commenn Distance. De th Incl. An le TRUE Azi. ND +) -) istance 94 ft) in POOL (906 POOL Min Distance . (4697.9 - 12398.45 (906.94 ft) in POOL MD) to 3K-103 L1 (4697.9 - 12398.45 4 - (wp08) Plan (3359 MD) to 3K-19 (3359.4 . 2 TVDss) 3569 4825 65 73 48 35 3356.87 6010142.1 1671295 1964.42 3569.2 NDss) 94 906 1 % r ?'i% 4697.9 80 90.01 3305.097 6009239.8 1671371 2040.894 . - . . . Offset Well: 3 K-20 Closest A roach: Referen ce Well: 3K-103 w 08 Plan Coords. - Coords. - ASP 3-D ctr-ctr Meas. Subsea ASP N(+)IS(-) View VS 90° Comments Meas. De th Incl. An le TRUE Azi. Subsea ND N(+)/S(-) E + /W - View VS 90° Comment Distance. De h Incl. An le TRUE Azi. ND E + IW - n istance POOL Min Distance (745.57 ft) in POOL (745.57 ft) in POOL (4697.9 - 12398.45 (4697.9 - 12398.45 MD) to 3K-103 L1 MD) to 3K-20 (3359.4 (wp08) Plan (3359.4 - 825 04 90 90 4 3352 68 6009244.3 1673497 4166.51 - 3569.2 NDss) 6075 63.75 67.69 3352.73 6009989.8 1673488 4156.72 3569.2 NDss) 745.57 i?.Cu 6 . . . ll 3 W 27 K `t °- t~ h A Refere nce Wel l: 3K-10 3 w 08 Plan Offset : e - Closes roac : t Coords. - 3-D ctr-ctr Meas. Subsea Coords. - ASP N(+)/S(-) View VS ° Meas. th D An le Incl TRUE Azi Subsea ND ASP N(+)IS(-) E + /W - View VS 90° Comments Distance. De th Incl. An le TRUE Azi. ND E + /W - 90 Comments e . . POOL Min Distance (980.81 ft) in POOL (980.81 ft) in POOL (4697.9 - 12398.45 (4697.9 - 12398.45 MD) to 3K-103 L1 MD) to 3K-27 (3359.4 (wp08) Plan (3359.4 - 5875 88 72 90 39 3341.35 6009247.2 1672547 3216.66 - 3569.2 TVDss) 5020 55.71 88.34 3390.66 6008267.7 1672542 3205.66 3569.2 ND 980.81 . . 4/2812008 2:33 PM 3K-103 POOL Summa ry Template.xls Closest in POOL ....~... ...--mss ~"' t Closest A roach: Reference Well: 3K-103 w 08 Plan Offset Well: 3K-30 "1 ' ~ ~ Coords. - Coords. - ASP ASP 3-D ctr-ctr : Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth InG. Angle TRUE Azi. ND E + /W(-) (90° Comments Depth Incl. An le TRUE Azi. ND E(+)/W(_ (90°) Comments P in istance POOL Min Distance (100.31 ft) in POOL (100.31 ft) in POOL (4697.9 - 12398.45 (4697.9 - 12398.45 MD) to 3K-103 L1 MD) to 3K-30 (3359.4 (wp08) Plan (3359.4 - 100.31 4900 89.66 87.65 3322.678 6009243.8 1671573 2241.98 - 3569.2 NDss) 4650 52.56 43.56 3349.04 6009340.4 1671567 2235.14 3569.2 NDss) Closest A roach: Reference Well: 3K-103 w 08 Plan Offset Well: 3K-102 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 90° Comments De th Incl. An le TRUE Azi. ND E + /W - 90° Comments POOL Min Distance POOL Min Distance (1223.67 ft) in POOL (1223.67 ft) in POOL (4697.9 - 12398.45 (4697.9 - 12398.45 MD) to 3K-102 MD) to 3K-103 L1 (3359.4 - 3569.2 (wp08) Plan (3359.4 - 1223.67 5050 89.11 89.6 3323.02 6009249.5 1671722 2391.88 NDss) 6725 74.65 88.51 3358 6010472.6 1671727 2401.22 3569.2 NDss) Closest A roach: Reference Well: 3K-103 w 08 Plan Offset Well: 3K-24 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS tistance. De th Incl. An le TRUE Azi. ND E + /W - 90° Comments De th Incl. An le TRUE Azi. ND E + /W - 90° Comments POOL Min Distance POOL Min Distance (1143.03 ft) in POOL (1143.03 ft) in POOL (4697.9 - 12398.45 ' (4697.9 - 12398.45 MD) to 3K-103 L1 MD) to 3K-24 (3359 - (wp08) Plan (3359 - 1143.03 - 4697.9 80 90.01 3305.097 6009239.8 1671371 2040.894 3569 NDss) 4800 54.43 37.35 3358.08 6010369.1 1671203 1876.47 3569 NDss) Closest A roach: Reference Well: 3K-103 w 08 Plan Offset Well: 3 K-23 ``1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 90° Comments De th Incl. An le TRUE Azi. ND E + /W - 90° Comments P L Min Distance POOL Min Distance (695.15 ft) in POOL (695.15 ft) in POOL (4697.9 - 12398.45 (4697.9 - 12398.45 MD) to 3K-103 L1 MD) to 3K-23 (3359.4 (wp08) Plan (3359.4 - 695.15 4697.9 80 90.01 3305.097 6009239.8 1671371 2040.894 - 3569.2 NDss) 4359 42.35 42.42 3493.38 6009515.8 1670762 1429.82 3569.2 NDss) 3K-103 POOL Summary Template.xls 4/28/2008 3:12 PM REFERENCE INFORMATION WELL DETAILS: Plan 3K-103 (EI4) Project: Kuparuk River Unit Site: Kuparuk 3K Pad Co-ortlinate (N/E) Reference: Well Plan 3K-103 (E14), True North Ground LeveC 34.30 Well: Plan 3K-103 (E14) Vertical (TVD) Reference: Mean Sea Level +N/-S +E/-W Northing Fasting Latitlude Longitude Slot Measured Depth Reference: Doyon i5 (34.3+40) ~ 74.30ft 0.00 0.00 6007630.94 1669336.72 70° 25' 56.328 TY49° 45' 51.299 W Wellbore: 3K-103 Calculation Method: Minimum Curvature Plan: 3K-103 (wp08) 9500 9000 8500 8000 7500 7000 6500 6000 ~ 5500 w ~ 5000 t` + 4500 4000 2500- 2000- 1500- 1000 500 0 -500 -1000 -1500 No- • T M Azimuths to True North Magnetic North: 23.08° Magnetic Field Strength:57623.2snT Dip Angle: 80.88° Date: 10/15/2D07 Model: BGGM2007 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 1500( west(->~East(+~ (i7so t~/iD) ConoeoPhillips Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-103 (E14) Wellbore: 3K-103 Plan: 3K-103 (wp08) 0 1500 ; __. 3000 4-500 ~~ool - - REFERENCE INFORMATION Co-ortlinate (N/E) Reference: Well Plan 3K-103 (E74), True North Vertical (TVD) Reference: Mean Sea Level Measuretl Depth Reference: Doyonl5 (34.3+40) (dj 74.30ft Calwlation Method: Minimum Curvature f~............ WELL DETAILS: Plan 3K-103 (EI4) Ground Level: 34.30 +N/-S +E/-W Northing Casting Latittude Longitude 0.00 0.00 0007630.94 I (>69336.72 70° 25' 56.323 T-49° 45' 51.299 W Sbt /' ' ~n ' e~. _.r__ -~ .._. aa..._ i i ~,~ ..s ...,. .p . __ . ~ . _.. , z;: f , z ., , ~ ,~ .. ~. ~------ --r_•-_r... ~,, , _~. , .~.......t. I s ~` .. ' ~ s .~ _~.__...-. r I _ _I .. Page 1 of i ~ ~. Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 30, 2008 2:46 PM To: 'Hartwig, Dennis D' Subject: RE: 3K-103 Proximate Wells in WS Dennis, Thanks for this information. This is exactly what I need and confirms what I had determined by examining the files. Regards, Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Wednesday, July 30, 2008 2:36 PM To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 Proximate Wells in WS Tom, I have reviewed all of the well files of penetrations within 1/4 mile of the 3K-103 production zones and have concluded that integrity of offset wells across the West Sak interval is sound. All historical data indicates no abnormalities with cement jobs across the West Sak interval. These wells include the 3K- 03, 3K-07, 3K-19, 3K-20, 3K-23, 3K-24, 3K-27, 3K-30, 3K-102, 3K-03, 3K-23, 3K-27, 3K-30 utilized 2 stage cement jobs with reports of good returns and lift pressure throughout both stages as well as plugs bumping and floats holding. All casing and subsequent cement jobs for the aforementioned wells cover the West Sak by 500 - 600' TVD 3K-07, 3K-19, 3K-20, 3K-24 utilized single stage cement jobs with reports of plugs bumping and floats holding as well as good returns throughout and excess cement to surface. Again, all casing and subsequent cement jobs for the aforementioned wells cover the West Sak by 500 - 600' TVD. 3K-102 was the lone 3K West Sak well drilled earlier this year. During the intermediate cement job we experienced consistent returns and lift pressure as well as good reciprocation throughout cementing. 3K-102 is the well we are going to support with 3K-103. Let me know if I can provide any further information. Regards...Dennis From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 30, 2008 1:36 PM To: Hartwig, Dennis D Cc: Thomas, Randy L Subject: 3K-103 Proximate Wells in WS Dennis, I am reviewing the information provided regarding the wells penetrating the WS within '/4 mile of the trajectory of 3K-143 and 3K-103L1. We may have talked briefly about these some time ago. It appears you have identified all the wells, however you do not include (or I didn't find) a statement regarding the integrity of the penetrations. 7/30/2008 H2S concerns on 3K-102 Maunder, Thomas E (DOA) Page 1 of 2 From: Davies, Stephen F (DOA) Sent: Monday, July 28, 2008 12:35 PM To: Hartwig, Dennis D Cc: Maunder, Thomas E (DOA) Subject: RE: H2S concerns on 3K-102 Thanks Dennis. Steve Davies AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophitlips.com] Sent: Monday, July 28, 2008 11:53 AM To: Davies, Stephen F (DOA) Subject: H2S concerns on 31<-102 Steve, I have investigated the 3K-102 H2S occurrence (90 units) on 3/21/08. It is likely that the H2S occurrence was a carry over from Kuparuk wells in the test separator. • Both the 3K-35 (160ppm H2S) and the 3K-16 (150 ppm H2S) were run through the test separator prior to running the 3K-102. The practice has been to purge the test separator between tests however, variables such as partially open valves on the Kuparuk wells may have allowed some contamination with the 3K-102 results. • While drilling the 3K-102 mud loggers were utilized and logging did not indicate the presence of H2S. • 3K West Sak area has not been water flood and without the presence of produced water H2S is not anticipated while drilling of either the 3K-103 or the 3K-108. I will continue to dig, but thus far I would have to go with Kuparuk contamination in the test separator as the likely culprit. Regards... Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 7/29/2008 BOPE for dual tubing complet~ Maunder, Thomas E (DOA) From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Monday, June 09, 2008 4:30 PM To: Maunder, Thomas E (DOA) Subject: RE: BOPE for dual tubing completion • Page 1 of~ ~-- The initial completion will be run with Dayon 15 and subsequent warkovers probably by Nordic 3 Dennis From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 09, 2008 4:26 PM To: Hartwig, Dennis D Subject: RE: BOPE for dual tubing completion Thanks Dennis. 1 forgot to ask, what rig. I presume Nordic 3. Tom From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, June 09, 2008 4:00 PM To: Maunder, Thomas E (DOA) Subject: RE: BOPE for dual tubing completion Tom, 3K-103 and 3K-108 are the primary candidates at this time -both are planned as injectors. No -plans as yet to include the dual completion design ~,vith producers. Work involved will be bath the initial completion and warkover. With. the complex directional profile of the well and tight clearances it would. be unlikely that we could. land the second string. if ruin they are run individually. The basis of design far the dual. completion is thus; . allow better access/intervention to the individual laterals • isolate the west sak B and D-sands to allow far vertical eanformance and avoid breakthrough events Pram producer to infector. • Utilize passive flaw control devices in the laterals (Reslrtject screens) to gain lateral conformance and also avail breakthrough events. Thanks Dennis Hartwig Drilling Engineer Greater kugamk. Area GonocoPhilGps Alaska - ATO-T592 Qfl'ice :907-265-ti&b2 Gell :947-980-1433 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 09, 2008 3:17 PM To: Hartwig, Dennis D 2/5/2009 BOPE for dual tubing comple~ ~ Page 2 of~~ Subject: RE: BOPE for dual tubing completion Dennis, Will this work be initial completion orjust workover? Can you identify what wells might be candidates? Are they producers, injectors or could a given well have production in one string and injection in the other? Thanks in advance, Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, June 09, 2008 3:13 PM To: Maunder, Thomas E (DOA) Subject: BOPE for dual tubing completion Tom, Upcoming 3K West Sak work (3rd quarter of 08) will involve dua13-1/2" tubing completions where we will run both strings simultaneously. AOGCC BOPE requirements for drilling operations with an MPSP of less than 3000psi require at least three preventers which include: • Pipe rams Blind rams Annular For our dual tubing case, where the annular will most probably not provide a barrier, will another set of dual rams be acceptable in place of the annular? In that case we would run the following; Top cavity - Dua13-1/2" rams Middle cavity -Blind rams Lower cavity - Dua13-1/2" rams Thank-you Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-2b5-6862 2/5/2009 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 a • TRANSMITTAL LETTER CHECKLIST WELL NAME _ /~~~ ~j` '~ ~~~ PTD# ~ g ` ~~~ ... / Development Service Exploratory Stratigraphic Test Non//Conventional Well FIELD: /~. [~ Q,vc~, ,~ /U~Y POOL: fj(~~=~.~- ~~G~~ ~l t 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 (If last two digits in API number permit No. . API No. 50- are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API cumber (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 contingept 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 throu tar et zones. Non-Conventional please note the following special condition of this permit: Weil production or production testing of coal bed methane is not allowed for (name of welD until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comnanv Name) must contact the Commission to obtain advance approval of such water well testing ro Rev: 1 /112008 WELL PERM{T CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490950 Well Name: KUPARUK RIV U WSAK 3K-103 Program SER Well bore sag ^ PTD#:2081150 Company ~ONOCOPHILLIPS ALASKA INC Initial Class/Type S ER 1 PEND GeoArea $90 Unit 11160 OntOff Shore 9n__ Annular Disposal ^ Administration 1 Perm~_feeattached.__-_____________-___----- ------------- NA__-_ --- -------- ------------------- ------------ 2 LeasensrmbarapproRri;~te -- --- -- -- -- ----- Yes ---------------------------- ---EntilB~ellinADl25519-- ------ -- - -- --- - - -- - 3 Unique well name and number - - - - - - - - - - - . - - - - Y~ - - ----- -- - - - - - - - - - - - - 4 -UYfllilocatedin_adefipedpo4l_________________________ _____________Yes___ ____KupaCUkRiver,WestSakOiiPoai-49015Q,_goyamadbyCO406B_.-_..__-------_-_---_--_- 5 Wall I°cated proper distance from drilling urlit_boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - - - C9 4058, Rulg 3; no restrictions as tg well epacing except that no_pay sha)I be opened in a well close) 6 VYeii located proper distance from other we~s- - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - _ . - _ _ _ - _ - _ than 600-feet to-an eXtemal-property ling where ewnership qr landownership changes, _ _ _ - - _ _ ---------- 7 Sufficient acreage available in_drilling un)t_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ - -Well is slightly more than 5Q0 feet from an extgrnalproperty Itng._ _ _ _ _ _ _ . - _ - _ - - - _ - - - - - - _ -- -- 6 Ifdeviated,is-weilbareRlat_inctuded_--------------------- ------------Yes-- ---------------------------_----- 9 OpgratoranlyaffectgdPa~------ - -------- ..-- -------- Yes-- -- ---- -~ --~ -- - ------- - -~ -- ---- 10 O_pgrafofbas-appropriate_bondinfQrce------_------------- ------------Yes--- -- - -.. ----- --- -----.-------------- ----------------------------------- 11 Pe[mitaanbe[ssuedwithQUtCOnsarvaticnordar---------------- ------------Ygs--- ---------------- -------.----------.----------------------- ---- -- Appr Date 12 Pe[mikcanbeisauadwJthQUtadministrati+ce_approYai------------- ------------Yas.-- --- - -----.-- --- ------------.---------.----------------- -- SFD 7117!2008 13 Canpertn)tbgapprov_edbeforgl5-daY-wait------------------- ------------Yas.-- -------------..--------------------------- -- ----- ------- 14 -Well located within arse and strata auttrorizgd by lojgction 9rder # (put 10# in_cgmmenis)_ (For_ Yes - - _ .. - _ Area Injection Order No.-28 - - - - - - - - - - - - - - - - - - - - - 15 AJlwellswithinll4_mileatea_of[eyigwidentifigd(Forsetviceweliaaly)___ ____________Yes--_ -.-...---.._--..________________.______-_---_ 16 Pre•produced injector, siurati~ of pre-poductioa less than 3 months (For_ sgrvtce well anJy) - - -Pt°- - - - - - - - hUgp clean-up ony - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . 17 _Ptonconven,gas.conformstoAS31,05.03QQ•'l•A),(G2.A-D) -- ---- - ----- ----NA.. -----~ ---- ----- -- - -- ----- --------- ---- ------ --- -- Engineering 18 Conducts[stringprRVidgd-- --- ------ -- -- - - ------- --Yes--- --------- ~ - -- ---- -- --------- - -------~ 19 Su[faceca:£ingprate°tsall_knownUSDWs------------------ ------------NA--- - - -- -- --- --- ---_AllaquifflrsaxemRted,-40CFR-1471Q2(b)(3)•------------------ - --- - - ---- --- - 20 C;VIT_voladequate_tacirculate_onconducicr8ssurfcsg- - -- -- - ----- Y~-- - --...- - - ----- ------ --- ---- -- --- -- 21 CMT_voladequate_totie-inlongstringtasurfcsg --- --- -- - - -- -----NO• --~ - -- ----- --- -- - ~ --~ ---- -- --- -- -- -- -- ~- 22 CMT-will coyer_aJl kn°wn.prodaCtivg hQrizans_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ No_ - _ _ ---- -- ------ _ _ _ _ SCrefln liner c9~npletion planned, _ _ . - _ _ .. - _ - - _ - - - - - . - - - _ - - - - - - - - - - 23 Casingdes~nsadequatetorC,.T,B&.permafrost-- -- -- - - -----Y~--- - - - ----- ------------------------- - ---------- -- 24 __equaietankage_orresgryepit------------------------- ------------ Yes _ - - --- --- - ---- -- - _ - .Rig equipped with steel pits: No_raservg pit p~nrted.- All waste-ip appfaved disRosal well(s)_ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 If_arg-drill,basal0.403for abandonment been aRRrovgd_----_-- _---_----_-- NA---- ,------------------------- -- ---- - --- 26 Adequate_wallhorg separaUon_ptop9sed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ ------ --- --- - ----------- - _ _ .Proximity analysis performed: Traveling cylinder path calculated, Gyros iikely_in suriacebole, - - - . _ _ - _ _ _ . - 27 Ifdlvert8r.required,dQesltmegtrg9ulations------------------- ----------Yas--- --------.--..------------------ ----- - --- Appr Date 28 Drilling fluid program schgmatlc_& equip list adgquate- - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - . - Maximum expected fom~ation pressure 9,0-EMW._ MW planned pp to 9,5 ppg in_ 12,25" bole and 9,2_ppg in_zone. _ TEM 7130/2008 29 BOPES,-do-theymegt rggulation--------------___--__--_ _____-___--Yea--- ------_.-------------- ~' t? 7y`~ (~' 30 BOPE_press rating apptaptiata; fast to_(put pale to commgnts)- - - - - - - - - - - - - - - - - - - -Yes - _ _ ------------------- -- - -- - --. .-. -- - - - - MASP calculated at 1335 psi. 5K steak arran9ementwflh_cgg rams in lower set. 3QQ0_psi_ BQP testplannfld, _ - _ 31 Chake_manifoldsemRlieswlAPIRP-53(May64).-------------- -----------Yes--- ----------------------,-------------- 32 Workwiilaccurwithoutoperaflonshutdown------------------- -----------Yes--- -----------,_----------------------- - -- - --- 33 is pnsence of H2$ gas probable - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - No- _ _ _ -------- --.----- _ _ _ H2S is not_raportgd in 3K WS production. N2$ may be present in lift gas-and Mi. Rig has_ sensors and aiarms• - - 34 -Mechanical-condition of wells within AOR verified (FOrsetvicg well Only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - . - . -All @ Rroximate Kuparuk wails hays surface casUg set below W$.1 new WS_well._ _No-issues iderdifu3d, _ _ _ _ _ _ Geology 35 Petmitcan be issued w(o hydrogen, sulfide measures- - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - _ -Initial-West Sakservicg well from 3K-Pad, na H2S currerdly expectedinthis po~tion_Qf the Vyest.. - - _ _ _ _ _ - - - 36 Data-presented onpotential averpressurezones - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ . - _ - Expected r_eservoirpressure is 9,0_ppg i=MNf; will_be drilled with 8.5 ppg mud. - - - _ . Appr Date 37 Seismic analys~afshallawgaszones-------------------- ------------KA____ - - _ - - _ _ . _ _ _ - _ _ - ____--- ---- SFD 7/1612008 38 Seabedeonditionsurvey_(ifoff-ghore)-------------------- -------------Nq.-- ------- - ------- --- - ----- - - -- --- - ----- 39 Contactnamelphongforwggkly_plQgress_rep9rts_(gxploratoryonty]----- ----------- Nq--- ------------------------- ---- --- - -- - -- - Geologic Commissioner: Engineering Public Date: Comm~sionee Date m ' ner Date West Sak B Sand in' ctor ~ ~~~ ~0 a~ iNelt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efi(or1 has been made to chronologically organize this category of information. • 3k-103.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 17:36:51 2008 Reel Header Service name ............. LISTPE Date. ... ................ 08/12/15 Ori9in ................... STs Reel Name...... ........ UNKNOWN continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Tape Header Service name ............. LISTPE Date . ................... 08/12/15 Origin ................... STS Tape Name...... ........ UNKNOWN continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: Writing Library. Writing Library scientific Technical services scientific Technical services 3K-103 500292339200 ConocoPhillips Alaska Inc. Sperry Drilling Services 15-DEC-08 MWD RUN 2 MWD RUN 5 MWD RUN 6 Mw0006005291 MW0006005291 Mw0006005291 P . ORTH P . ORTH P . ORTH M. THORNTON F. HERBERT F. HERBERT MWD RUN 10 MWD RUN 11 MWD RUN 12 Mw0006005291 Mw0006005291 Mw0006005291 P. ORTH P. ORTH P. ORTH M. THORNTON M. THORNTON F. HERBERT MWD RUN 14 MW0006005291 P . ORTH F. HERBERT 35 Page 1 3k-103.txt TOWNSHIP: 13N RANGE: 9E FNL: FSL: 885 FEL: FWL: 314 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 74.62 GROUND LEVEL: 33.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 2540.0 2ND STRING 6.750 9.625 5435.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 3K-103 P63 WELLBORE BY DRILLING OFF OF CEMENT. THE KOP WAS 5462'MD/3554'TVD, WITHIN THE MWD RUN 6 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,5,6,10-12,14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4), DRILL. STRING DYNAMICS SENSOR-ROTATING (DDS-R), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 2,10-12,14 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUNS 6,10-12,14 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 13 WAS FOR SURVEY DATA ONLY - NO DRILLING WAS PERFORMED. 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 7. MWD RUNS 1,2,5,6,10-12,14 REPRESENT WELL 3K-103 WITH API#: 50-029- 23392-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12411'MD/3651'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW Page 2 SPACING). SEMP = SMOOTHED SPACING). SEDP = SMOOTHED SPACING}. SFXE = SMOOTHED SLIDE = NON-ROT, 3k-103.txt PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM PHASE SHIFT-DERIVED RESISTIVITY (DEEP FORMATION EXPOSURE TIME. 4TED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. .........LO Previous File Name.......ST5LI6.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2506.5 12352.5 FET 2525.0 12359.5 RPS 2525.0 12359.5 RPD 2525.0 12359.5 RPX 2525.0 12359.5 RPM 2525.0 12359.5 ROP 2550.5 12411.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 2506.5 2925.0 MWD 5 2925.5 5443.0 MwD 6 5443.0 5462.0 MwD 10 5462.0 6418.0 MwD 11 6418.0 9478.0 MWD 12 9478.0 11698.0 MWD 14 11698.0 12411.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Page 3 3k-103.txt Data Record Type... ..........0 Data Specification Block Type.....0 Logyin Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .12N Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 12411 7458.75 19810 2506.5 12411 RPD MWD OHMM 0.88 2000 24.6934 19609 2525 12359.5 RPM MWD OHMM 0.52 2000 21.2624 19609 2525 12359.5 RPS MWD OHMM 2.42 2000 19.2724 19609 2525 12359.5 RPX MWD OHMM 2.21 2000 18.547 19609 2525 12359.5 FET MWD HR 0.14 103.59 1.78087 19609 2525 12359.5 GR MWD API 12.04 130.55 70.239 19693 2506.5 12352.5 ROP MWD FPH 0.04 1386.19 216.14 19722 2550.5 12411 First Reading For Entire File..........2506.5 Last Reading For Entire File...........12411 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLI6.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER Page 4 ~i FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE .START DEPTH SGRC 2506.5 SEMP 2525.0 SEDP 2525.0 SESP 2525.0 SFXE 2525.0 SEXP 2525.0 SROP 2550.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 27-SEP-08 Insite 74.11 Memory 2925.0 2550.0 2925.0 40.6 58.7 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 3k-103.txt i~ header data for each bit run in separate files. 2 .5000 2 STOP DEPTH 2925.0 2925.0 2925.0 2925.0 2925.0 2925.0 2925.0 12.250 2540.0 Lignosulfanate 9.05 52.0 8.5 200 4.5 1.900 81.0 1.480 105.8 5.000 81.0 1.500. 81.0 REMARKS: Page 5 3k-103.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value . ....................-999 Depth Units.- .. .. ..... Datum specification Block sub-type...0 Name service order Units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 RoP MwD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 2925 2715.75 838 2506.5 2925 RPD MWD020 OHMM 0.98 2000 25.6799 801 2525 2925 RPM MWD020 OHMM 0.52 31.87 15.9015 801 2525 2925 RPS MWD020 OHMM 2.74 32.59 14.7172 801 2525 2925 RPX MWD020 OHMM 3.09 27.28 11.8377 801 2525 2925 FET MwD020 HR 0.14 62.77 4.76348 801 2525 2925 GR MWD020 API 12.04 101.04 61.0104 838 2506.5 2925 ROP MWD020 FPH 7.71 636.24 297.093 750 2550.5 2925 First Reading For Entire File..........2506.5 Last Reading For Entire File...........2925 File Trailer Service name... .......STSLIB.002 service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLI6.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLIB.002 Page 6 3k-103.txt Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 2925.5 5388.0 SFXE 2925.5 5380.0 SEMP 2925.5 5380.0 5E5P 2925.5 5380.0 SEXP 2925.5 5380.0 SROP 2925.5 5443.0 SEDP 2925.5 5380.0 LOG HEADER DATA DATE LOGGED: 03-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5442.0 TOP LOG INTERVAL (FT): 2925.0 BOTTOM LOG INTERVAL (FT): 5442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 85.5 TOOL STRING, (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfan ate MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 56.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 300 FLUID Loss (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.100 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .950 85.6 MUD FILTRATE AT MT: 1.200 73.0 MUD CAKE AT MT: 1.200 73.0 NEUTRON TOOL. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Page 7 • • EWR FREQUENCY (HZ): REMARKS: 3k-103.txt Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... .......... .60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. ..... Datum specification~Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MwD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 2925.5 5443 4184.25 5036 2925.5 5443 RPD MwD050 OHMM 3.76 841.89 16.1098 4910 2925.5 5380 RPM MWD050 OHMM 3.07 1612.7 16.0214 4910 2925.5 5380 RPS MWD050 OHMM 2.42 104.21 11.5286 4910 2925.5 5380 RPX MWD050 OHMM 2.21 33.49 8.14578 4910 2925.5 5380 FET MwD050 HR 0.28 91.47 1.25186 4910 2925.5 5380 GR MWD050 API 23.44 130.55 80.5042 4926 2925.5 5388 ROP MWD050 FPH 0.39 489.84 190.247 5036 2925.5 5443 First Reading For Entire File..........2925.5 Last Reading For Entire File...........5443 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.004 Physical EoF File Header Service name... .. ...STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Page 8 ~ ~ 3k-103.txt Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH SEDP 5380.5 SEXP 5380.5 SEMP 5380.5 SESP 5380.5 SFXE 5380.5 SGRC 5388.5 SROP 5443.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5462.0 5462.0 5462.0 5462.0 5462.0 5453.0 5453.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: header data for each bit run in separate files. 6 .5000 4 08-OCT-08 Insite 74.11 Memory 5462.0 5442.0 5462.0 84.9 93.8 TOOL NUMBER 184054 90518 6.750 5435.0 Mineral oil Base 9.30 68.0 .0 34000 3.0 .000 .0 .000 95.0 .000 .0 .000 .0 Page 9 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 3k-103.txt Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ............ ... ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MwD060 OHMM 4 1 68 16 5 FET MwD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MwD060 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 5380.5 5462 5421.25 164 5380.5 5462 RPD MwD060 OHMM 0.88 2000 568.117 103 5380.5 5462 RPM MWD060 OHMM 15.89 2000 161.016 103 5380.5 5462 RPS MWD060 OHMM 15.08 2000 52.7383 103 5380.5 5462 RPX MWD060 OHMM 9.78 2000 46.3294 103 5380.5 5462 FET MwD060 HR 40.1 1 03.59 80.4412 103 5380.5 5462 GR MWD060 API 25.2 72.99 44.1275 130 5388.5 5453 ROP MWD060 FPH 228.67 13 86.19 804.334 20 5443.5 5453 First Reading For Entire File..........5380 Last Reading For Entire File......, .....5462 File Trailer Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header. Service name. ..........STSLIB.005 Page 10 ~ ~ 3k-103.txt service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......sTSLI6.004 comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 5404.0 6369.0 SROP 5435.5 6418.0 SEDP 5462.5 6376.0 SFXE 5462.5 6376.0 SEXP 5462.5 6376.0 SEMP 5462.5 6376.0 SESP 5462.5 6376.0 LOG HEADER DATA DATE LOGGED: 25-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6418.0 TOP LOG INTERVAL (FT): 5462.0 BOTTOM LOG INTERVAL (FT): 6418.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 90.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 117.0 MUD PH: .O MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 93.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O Page 11 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 3k-103.txt Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 RoP MwD100 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 5404 6418 5911 2029 5404 6418 RPD MWD100 OHMM 5.66 24.93 15.2704 1828 5462.5 6376 RPM MWD100 OHMM 4.82 24.64 14.4878 1828 5462.5 6376 RPS MWD100 OHMM 4.62 57.38 14.1365 1828 5462.5 6376 RPX MWD100 OHMM 4.4 32.96 14.0153 1828 5462.5 6376 FET MwD100 HR 0.16 1.98 0.498474 1828 5462.5 6376 GR MWD100 API 31.5 - 112.45 74.4692 1931 5404 6369 ROP MWD100 FPH 11.05 613.32 212.348 1966 5435.5 6418 First Reading For Entire File..........5404 Last Reading For Entire File...........6418 File Trailer Service name... .......sTSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.006 Physical EOF Page 12 • 3k-103.txt File Header Service name... .......sTSLIB.006 service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 6369.5 9429.0 sFXE 6376.5 9436.0 SEDP 6376.5 9436.0 SESP 6376.5 9436.0 SEMP 6376.5 9436.0 SEXP 6376.5 9436.0 SROP 6418.5 9478.0 LOG HEADER DATA DATE LOGGED: 27-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9478.0 TOP LOG INTERVAL (FT): 6418.0 BOTTOM LOG INTERVAL (FT): 9478.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 72.0 MUD PH: .O MUD CHLORIDES (PPM): 33000 .FLUID LOSS (C3): 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 109.4 Page 13 3k-103.txt MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MwD110 OHMM 4 1 68 16 5 FET MWD110 HR 4 1 68 20 6 GR MwD110 API 4 1 68 24 7 ROP MWD110 FPH 4 1 68 28 8 s First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6369.5 9478 7923.75 6218 6369..5 9478 RPD MWD110 OHMM 6.14 2000 24.3091 6120 6376.5 9436 RPM MWD110 OHMM 8.49 2000 22.8728 6120 6376.5 9436 RPS MWD110 OHMM 7.95 2000 21.6494 6120 6376.5 9436 RPX MWD110 OHMM 6.95 2000 20.9112 6120 6376.5 9436 FET MwD110 HR 0.14 11.14 0.811704 6120 6376.5 9436 GR MwD110 API 40.77 102.41 66.8204 6120 6369.5 9429 ROP MWD110 FPH 1.71 4 30.96 232.287 6120 6418.5 9478 First Reading For Entire File..........6369.5 Last Reading For Entire File...........9478 File Trailer service name... .......STSLIg.006 service sub Level Name... version Number. .........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLI6.007 Page 14 • 3k-103.txt Physical EOF File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 9429.5 11649.0 SFXE 9436.5 11656.0 SEXP 9436.5 11656.0 SESP 9436.5 11656.0 SEDP 9436.5 .11656.0 SEMP 9436.5 11656.0 SROP 9478.5 11698.0 LOG HEADER DATA DATE LOGGED: 30-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11698.0 TOP LOG INTERVAL (FT): 9478.0 BOTTOM LOG INTERVAL (FT): 11698.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 80.0 MUD PH: .O MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3): 4.5 Page 15 3k-103.txt RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 116.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9429.5 11698 10563.8 4538 9429.5 11698 RPD MWD120 OHMM 5.37 2000 28.152 4440 9436.5 11656 RPM MWD120 OHMM 6.11 2000 26.9011 4440 9436.5 11656 RPS MWD120 OHMM 5.97 2000 27.69 4440 9436.5 11656 RPX MWD120 OHMM 5.88 2000 29.8742 4440 9436.5 11656 FET MWD120 HR 0.15 21.3 1.0189 4440 9436.5 11656 GR MWD120 API 41.88 89.51 62.5197 4440 9429.5 11649 ROP MWD120 FPH 0.04 3 70.57 211.968 4440 9478.5 11698 First Reading For Entire File..........9429.5 Last Reading For Entire File...........11698 File Trailer Service name... .......STSLIg.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 Page 16 3k-103.txt File Type ................LO Next File Name...........sTSLI6.008 Physical EOF File Header service name... .......STSLI6.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type.. ............LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER • FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START-DEPTH STOP DEPTH SGRC 11649.5 12352.5 SEXP 11656.5 12359.5 SEDP 11656.5 12359.5 SFXE 11656.5 12359.5 SESP 11656.5 12359.5 SEMP 11656.5 12359.5 SROP 11698.5 12411.0 LOG HEADER DATA DATE LOGGED: O1-NOV-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12411.0 TOP LOG INTERVAL (FT): 11698.0 BOTTOM LOG INTERVAL (FT): 12411.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.4 MAXIMUM ANGLE: 89.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 82.0 Page 17 3k-103.txt MUD PH: .0 MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction........ .......Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MwD140 HR 4 1 68 20 6 GR MwD140 API 4 1 68 24 7 ROP MWD140 FPH 4 1 68 28 8 ' First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11649.5 12411 12030.3 1524 11649.5 12411 RPD MwD140 OHMM 5.19 42.79 17.3044 1407 11656.5 12359.5 RPM MWD140 OHMM 4.54 45.68 16.3758 1407 11656.5 12359.5 RPS MWD140 OHMM 4.32 46.03 16.2105 1407 11656.5 12359.5 RPX MWD140 OHMM 4.15 58.18 16.49 1407 11656.5 12359.5 FET MWD140 HR 0.22 61.29 4.45677 1407 11656.5 12359.5 GR MWD140 API 47.4 124.18 73.9219 1407 11649.5 12352.5 ROP MWD140 FPH 10.61 695.24 204.897 1426 11698.5 12411 First Reading For Entire File..........11649.5 Last Reading For Entire File...........12411 File Trailer service name... .......STSLI6.008 service sub Level Name... Page 18 3k-103.txt version Number. ........1.0.0 Date of ~eneration.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name .............LiSTPE Date .....................08/12/15 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/12/15 Ori9in ...................STS Reel Name...... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 19 • 3k-103pbl.txt Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 12:05:44 2008 Reel Header Service name .............LISTPE Date .. ..................08/12/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/12/15 origin ...................STS Tape Name. .... ........UNKNOWN .Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical Services Physical EOF comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 Mw0006005291 P. ORTH M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR:, GROUND LEVEL: WELL CASING RECORD 3K-103 PB1 500292339270 ConocoPhillips Alaska Inc. Sperry Drilling Services 15-DEC-08 MWD RUN 3 Mw0006005291 P. ORTH M. THORNTON 35 13N 9E 885 314 74.62 33.80 Page 1 • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3k-103pbl.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12..250 13.375 2540.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-Phase 4), AT-BIT INCLINATION (ABI), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R),AND PRESSURE WHILE DRILLING (PWD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 6. MWD RUNS 1-3 REPRESENT WELL 3K-103 PB1 WITH API#: 50-029-23392-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4410'MD/3416'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Page 2 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD FET RPS RPM RPX ROP 1 3k-103pb1.txt clipped curves; all bit runs merged. .5000 START DEPTH 2506.5 2525.0 2525.0 2525.0 2525.0 2525.0 2550.5 STOP DEPTH 4366.5 4358.5 4358.5 4358.5 4358.5 4358.5 4410.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2506.5 4053.0 MWD 3 4053.0 4410.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... .........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....... .. ... ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 4410 3458.25 3808 2506.5 4410 RPD MWD OHMM 0.87 2000 25.6654 3668 2525 4358.5 RPM MWD OHMM 0.52 1679.69 21.8381 3668 2525 4358.5 Page 3 3k-103pbl.txt RPS MWD OHMM 0.61 156.53 15.0493 3668 2525 4358.5 RPX MWD OHMM 0.61 40.39 11.0225 3668 2525 4358.5 FET MWD HR 0.13 62.77 1..95136 3668 2525 4358.5 GR MWD API 12.04 114.98 68.4096 3721 2506.5 4366.5 ROP MWD FPH 2.75 1308.5 241.229 3720 2550.5 4410 First Reading For Entire File..........2506.5 Last Reading For Entire File...........4410 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ....:...1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................LO Next Fite Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 pate of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2506.5 4009.5 FET 2525.0 4001.5 RPX 2525.0 4001.5 RPS 2525.0 4001.5 RPM 2525.0 4001.5 RPD 2525.-0 4001.5 ROP 2550.5 4053.0 LOG HEADER DATA DATE LOGGED: 26-SEP-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4053.0 TOP LOG INTERVAL (FT): 2550.0 BOTTOM LOG INTERVAL (FT): 4053.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 4 ~ r 3k-103pbl.txt MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 58.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.05 MUD VISCOSITY (s): 52.0 MUD PH: 8.5 MUD CHLORIDES (PPM): O FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 81.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.480 105.8 MUD FILTRATE AT MT: 5.000 81.0 MUD CAKE AT MT: 1.500 81.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logyin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FPH 4 1 68 28 8 First Name Service Unit Min Max .Mean Nsam Reading Page 5 Last Reading ~ ~ 3k-103pbl.txt DEPT FT 2506.5 4053 3279.75 3094 2506.5 4053 RPD MWD020 OHMM 0.87 2000 28.8973 2954 2525 4001.5 RPM MWD020 OHMM 0.52 1679.69 24.0398 2954 2525 4001.5 RPS MWD020 OHMM 0.61 156.53 15..9888 2954 2525 4001.5 RPX MWD020 OHMM 0.61 40.39 11.7159 2954 2525 4001.5 FET MWD020 HR 0.13 62.77 1.62555 2954 2525 4001.5 GR MWD020 API 12.04 114.98 67.0362 3007 2506.5 4009.5 ROP MWD020 FPH 4.61 1308.5 262.6 -3006 2550.5 4053 First Reading For Entire File..........2506 Last Reading For Entire File...........4053 File Trailer Service name.... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD .Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files.. 3 .5000 VENDOR TOOL CODE START DEPTH RPx 4002.0 RPD 4002.0 RPM 4002.0 FET 4002.0 RPS 4002.0 GR 4010.0 ROP 4053.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 4358.5 4358.5 4358.5 4358.5 4358.5 4366.5 4410.0 28-SEP-08 Insite 74.11 Memory 4410.0 4053.0 Page 6 • r 3k-103pbl.txt BOTTOM LOG INTERVAL (FT): 4410..0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.1 MAXIMUM ANGLE: 69.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 50.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 81.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.610 96.8 MUD FILTRATE AT MT: 5.000 81.0 MUD CAKE AT MT: 1.500 81.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type...:.0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .11N Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ......... Datum Specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 Page 7 • • 3k-103pbl.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4002 4410 4206 817 4002 4410 RPD MWD030 OHMM 5.27 83.36 12.2943 714 4002 4358.5 RPM MWD030 OHMM 4.9 103.77 12.729 714 4002 4358.5 RPS MWD030 OHMM 4.55 89.19 11.1621 714 4002 4358.5 RPX MWD030 OHMM 3.92 37.58 8.15413 714 -4002 4358.5 FET MWD030 HR 0.37 16.36 3.29931 714 4002 4358.5 GR MWD030 API 35.47 109.76 74.1933 714 4010 4366.5 ROP MWD030 FPH 2.75 356.55 151.254 714 4053.5 4410 First Reading For Entire Fil e..........4002 Last Reading For Entire File ...........4410 File Trailer Service name... ....... STSLIB.003 service sub Level Name... version Number. ........ 1.0.0 Date of Generation....... 08/12/15 Maximum Physical Record.. 65535 File Type ................ L0 Next File Name........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date . ................... 08/12/15 Origin ................... STS Tape Name. .... ........ UNKNOWN Continuation Number...... 01 Next Tape Name........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date . ............... .. 08/12/15 Ori9in ................... STS Reel Name. .... ........ UNKNOWN continuation Number...... 01 Next Reel Name........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Techn ical services Physical EOF Physical EOF End Of LIS File Page 8 3k-103pb2.txt Sperry-Sun Drilling Services • LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 14:59:41 2008 Reel Header Service name .............LISTPE Date . ...................08/12/15 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................08/12/15 origin... ..............STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: U scientific Technical Services scientific Technical services 3K-103 P62 500292339271 ConocoPhillips Alaska Inc. Sperry Drilling Services 15-DEC-08 MWD RUN 3 MWD RUN 4 Mw0006005291 Mw0006005291 P. ORTH P. ORTH M. THORNTON M. THORNTON MWD RUN 2 Mw0006005291 P . ORTH M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 35 13N 9E 885 314 74.62 33.80 Page 1 ~d~ -ll5 /~/c~~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3k-103pb2.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 2540.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 3K-103 PB1 WELLBORE AT 4260'MD/3362'TVD, WITHIN THE MWD RUN 3 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4), AT-BIT INCLINATION (ABI), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R),AND PRESSURE WHILE DRILLING (PWD). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 7. MWD RUNS 1-4 REPRESENT WELL 3K-103 PB2 WITH API#: 50-029-23392-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4527'MD/3461'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service sub Level Name... Page 2 ~ • 3k-103pb2.txt Version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 2506.5 2525.0 2525.0 2525.0 2525.0 2525.0 2550.5 STOP DEPTH 4483.5 4475.5 4475.5 4475.5 4475.5 4475.5 4527.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2506.5 4053.0 MwD 3 4053.0 4260.0 MwD 4 4260.0 4527.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ... ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 Page 3 3k-103pb2.txt First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 4527 3516.75 4042 2506.5 4527 RPD MWD OHMM 0.87 2000 24.6077 3902 2525 4475.5 RPM MWD OHMM 0.52 1679.69 20.9901 3902 2525 4475.5 RPS MWD OHMM 0.61 156.53 14.5781 3902 2525 4475.5 RPX MWD OHMM 0.61 40.39 10.7331 3902 2525 4475.5 FET MWD HR 0.13 62.77 1.89652 3902 2525 4475.5 GR MWD API 12.04 118.45 70.1709 3955 2506.5 4483.5 ROP MWD FPH 2.75 3719.07 274.927 3954 2550.5 4527 First Reading For Entire File..........2506.5 Last Reading For Entire File...........4527 File Trailer Service name. .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Ty e ................L0 Next Fie Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE SGRC SFXE SEXP SESP SEMP SEDP SROP START DEPTH 2506.5 2525.0 2525.0 2525.0 2525.0 2525.0 2550.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION:. STOP DEPTH 4009.5 4001.5 4001.5 4001.5 4001.5 4001.5 4053.0 26-SEP-08 Insite 74.11 Page 4 Cl DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 .7 3k-103pb2.txt Memory 4053.0 2550.0 4053.0 40.6 58.7 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value......................-999 Depth units ......... .. ... ..... Datum specification Block sub-type...0 Name Service order units size Nsam DEPT FT 4 1 RPD MWD020 OHMM 4 1 RPM MWD020 OHMM 4 1 RPS MWD020 OHMM 4 1 RPX MWD020 OHMM 4 1 FET MWD020 HR 4 1 GR MWD020 API 4 1 TOOL NUMBER 216261 230192 12.250 2540.0 LSND 9.05 52.0 8.5 200 4.5 1.900 81.0 1.480 105.8 5.000 81.0 1.500 81.0 Rep code offset channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 Page 5 • 3k-103pb2.txt ROP MwD020 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 .4053 3279.75 3094 2506.5 4053 RPD MwD020 OHMM 0.87 2000 28.8973 2954 2525 4001.5 RPM MWD020 OHMM 0.52 1679.69 24.0398 2954 2525 4001.5 RP5 MWD020 OHMM 0.61 156.53 15.9888 2954 2525 4001.5 RPX MWD020 OHMM 0.61 40.39 11.7159 2954 2525 4001.5 FET MwD020 HR 0.13 62.77 1.62555 2954 2525 4001.5 GR MWD020 API 12.04 114.98 67.0362 3007 2506.5 4009.5 ROP MWD020 FPH 4.61 1308.5 262.6 3006 2550.5 4053 First Reading For Entire File..........2506.5 Last Reading For Entire File...........4053 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........5T5LIB.003 Physical EOF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 4002.0 4260.0 SESP 4002.0 4260.0 SEXP 4002.0 4260.0 SEMP 4002.0 4260.0 SEDP 4002.0 4260.0 SGRC 4010.0 4260.0 SROP 4053.5 4260.0 LOG HEADER DATA DATE LOGGED: Page 6 28-SEP-08 • 3k-103pb2.txt SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4260.0 TOP LOG INTERVAL (FT): 4053.0 BOTTOM LOG INTERVAL (FT): 4260.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 60.1 MAXIMUM ANGLE: 69.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 50.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 81.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.610 96.8 MUD FILTRATE AT MT: 5.000 81.0 MUD CAKE AT MT: 1.500 81.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction.................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing...... ............60 .12N .... Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ... ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset DEPT FT 4 1 68 0 RPD MWD030 OHMM 4 1 68 4 RPM MWD030 OHMM 4 1 68 8 RPS MWD030 OHMM 4 1 68 12 Page 7 Channel 1 2 3 4 • • 3k-103pb2.txt RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4002 4260 4131 517 4002 4260 RPD MWD030 OHMM 5.27 83.36 14.1975 517 4002 4260 RPM MwD030 OHMM 4.9 103.77 14.8798 517 4002 4260 RPS MWD030 OHMM 4.55 89.19 12.8941 517 4002 4260 RPX MWD030 OHMM 4.15 37.58 9.10234 517 4002 4260 FET MWD030 HR 0.37 16.36 3.85892 517 4002 4260 GR MWD030 API 35.47 92.57 68.8436 501 4010 4260 ROP MWD030 FPH 2.75 356.55 165.875 414 4053..5 4260 First Reading For Entire File..........4002 Last Reading For Entire File...........4260 File Trailer Service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSL2B.004 service sub Level~Name... Version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ....... ...LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEMP 4260.5 4475.5 SEXP 4260.5 4475.5 SROP 4260.5 4527.0 SEDP 4260.5 4475.5 SGRC 4260.5 4483.5 SFXE 4260.5 4475.5 SESP 4260.5 4475.5 Page 8 • 3k-103pb2.txt LOG HEADER DATA DATE LOGGED: 29-SEP-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6540.0 TOP LOG INTERVAL (FT): 4260.0 BOTTOM LOG INTERVAL (FT): 4527.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.4 MAXIMUM ANGLE: 70.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 50.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 81.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.610 96.8 MUD FILTRATE AT MT: 5.000 81.0 MUD CAKE AT MT: 1.500 81.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .12N Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ... ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 9 • 3k-103pb2.txt RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPx MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4260.5 4527 4393.75 534 4260.5 4527 RPD MWD040 OHMM 5.67 -11.44 7.6952 431 4260.5 4475.5 RPM MWD040 OHMM 4.85 10.82 7.4174 431 4260.5 4475.5 RPS MWD040 OHMM 3.9 10.18 6.9294 431 4260.5 4475.5 RPx MWD040 OHMM 3.16 8.64 5.95378 431 4260.5 4475.5 FET MWD040 HR 0.38 7.61 1.39977 431 4260.5 4475.5 GR MWD040 API 59.25 118.45 92.7452 447 4260.5 4483.5 ROP MWD040 FPH 3.27 3719.07 428.867 534 4260.5 4527 First Reading For Entire File..... ....4260.5 Last Reading For Entire File...........4527 File Trailer Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/12/15 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/12/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments ...............-..STS LIS Writing Physical EOF Library. scientific Technical services Library. scientific Technical Services Page 10 3k-103pb2.txt Physical EOF End Of LIS File Page 11 3k-103pb3.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 15:52:51 2008 Reel Header Service name .............LISTPE Date . ...................08/12/15 Ori9in ...................STS Reel Name...... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/12/15 Origin.... .............STS Tape Name. .... ......UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUM~ER: LOGGING ENGINEER: OPERATO{~ WITNESS: MWD RUN 2 Mw0006005291 P. ORTH M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: R,4NGE FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • scientific Technical Services scientific Technical services 3K-103 PB3 500292339272 ConocoPhillips Alaska Inc. Sperry Drilling Services 15-DEC-08 MWD RUN 5 MWD RUN 6 Mw0006005291 Mw0006005291 P. ORTH P. ORTH F. HERBERT F. HERBERT 35 13N 9E 885 314 74.62 33.80 Page 1 (!~~ ~e ~ -1 / ~/~~' 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3k-103pb3.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 2540.0 6.750 9.625 5435.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 3K-103 PB1 WELLBORE BY MEANS OF A CEMENT PLUG. THE KOP WAS 2925'MD/2503'TVD, WITHIN THE MWD RUN 2 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,5,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 6 ALSO INCLUDED GEO-PILOT ROTARY STEER- ABLE BHA (G P). r 1 U 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 7. MWD RUNS 1,2,5,6 REPRESENT WELL 3K-103 PB3 WITH API#: 50-029-23392- 72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6540'MD/3571'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. Page 2 3k-103pb3.txt File Header Service name... .......STSLIB.001 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 2506.5 2525.0 2525.0 2525.0 2525.0 2525.0 2550.5 STOP DEPTH 6492.0 6498.5 6498.5 6498.5 6498.5 6498.5 6540.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2506.5 2925.0 5 2925.5 5443.0 6 5443.0 6540.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type.. ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ......... ...... ..... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 RPD MWD OHMM 4 1 RPM MWD OHMM 4 1 RPS MWD OHMM 4 1 RPX MWD OHMM 4 1 FET MWD HR 4 1 Rep code offset channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 Page 3 3k-103pb3.txt GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 6540 4523.25 8068 2506.5 6540 RPD MWD OHMM 0.88 2000 28.1873 7887 2525 6498.5 RPM MWD OHMM 0.52 2000 21.5515 7887 2525 6498.5 RPS MWD OHMM 2.42 2000 17.2404 7887 2525 6498.5 RPX MWD OHMM 2.21 2000 14.467 7887 2525 6498.5 FET MWD HR 0.14 103.59 2.48267 7887 2525 6498.5 GR MWD API 12.04 140.92 72.428 7972 2506.5 6492 ROP MWD FPH 0.39 1386.19 212.127 7980 2550.5 6540 First Reading For Entire File..........2506.5 Last Reading For Entire File...........6540 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 2506.5 2925.0 SFXE 2525.0 2925.0 SExP .2525.0 2925.0 SESP 2525.0 2925.0 SEMP 2525.0 2925.0 SEDP 2525.0 2925.0 SROP 2550.5 2925.0 LOG HEADER DATA Page 4 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 3k-103pb3.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 27-SEP-08 Insite 74.11 Memory 2925.0 25.50.0 2925.0 40.6 58.7 TOOL NUMBER 216261 230192 12.250 2540.0 Lignosulfanate 9.05 52.0 8.5 200 4.5 1.900 81.0 1.480. 105.8 5.000 81.0 1.500 81.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 Page 5 3k-103pb3.txt RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MwD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 2925 2715.75 838 2506.5 2925 RPD MWD020 OHMM 0.98 2000 25.6799 801 2525 2925 RPM MwD020 OHMM 0.52 31.87 15.9015 801 2525 2925 RPS MWD020 OHMM 2.74 32.59 14.7172 801 2525 2925. RPX MWD020 OHMM 3.09 27.28 11.8377 801 2525 2925 FET MWD020 HR 0.14 62.77 4.76348 801 2525 2925 GR MwD020 API 12.04 101.04 61.0104 838 2506.5 2925 ROP MWD020 FPH 7.71 636.24 297.093 750 2550.5 2925 First Reading For Entire File..........2506 Last Reading For Entire File...........2925 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Ty e ................L0 Next Fl~e Name...........STSLI6.003 Physical EOF File Header service name... .......STSLI6.003 service Sub Level Name... version Number. ......1.0.0 Date of Generation.... .08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 2925.5 5380.0 5E5P 2925.5 5380.0 SGRC 2925.5 5388.0 SEXP 2925.5 5380.0 SEMP 2925.5 5380.0 SEDP 2925.5 5380.0 SROP 2925.5 5443.0 Page 6 C7 3k-103pb3.txt $ LOG HEADER DATA DATE LOGGED: 03-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5442.0 TOP LOG INTERVAL (FT): 2925.0 BOTTOM LOG INTERVAL (FT): 5442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfan ate MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 55.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.100 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .950 85.6 MUD FILTRATE AT MT: 1.200 73.0 MUD CAKE AT MT: 1.200 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .12N Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ... ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel Page 7 3k-103pb3.txt DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPx MwD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2925.5 5443 4184.25 5036 2925.5 5443 RPD MWD050 OHMM 3.76 841.89 16.1098 4910 2925.5 5380 RPM MWD050 OHMM 3.07 1612.7 16.0214 4910 2925.5 5380 RPS MWD050 OHMM 2.42 104.21 11.5286 4910 2925.5 5380 RPx MWD050 OHMM 2.21 33.49 8.14578 4910 2925.5 5380 FET MWD050 HR 0.28 91.47 1.25186 4910 2925.5 5380 GR MWD050 API 23.44 130.55 80.5042 4926 2925.5 5388 ROP MWD050 FPH 0.39 489.84 190.247 5036 2925.5 5443 First Reading For Entire File..........2925.5 Last Reading For Entire File...........5443 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type .. .............LO Previous File Name.......STSLIB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE SEMP SEXP SEDP SFXE header data for each bit run in separate files. 6 .5000 START DEPTH 5380.5 5380.5 5380.5 5380.5 STOP DEPTH 6498.5 6498.5 6498.5 6498.5 Page 8 • • 3k-103pb3.txt 5E5P 5380.5 6498.5 SGRC 5388.5 6492.0 SROP 5443.5 6540.0 LOG HEADER DATA DATE LOGGED: 08-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6540.0 TOP LOG INTERVAL (FT): 5442.0 BOTTOM LOG INTERVAL (FT): 6540.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EwR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 68.0 MUD PH: .0 MUD CHLORIDES (PPM): O FLUID LO55 (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing...... ............60 .lIN .... Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Page 9 3k-103pb3 .txt Datum Spe cificat ion Block sub-type...0 Name service order units Siz e Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MW0060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5380.5 6540 5960.25 2320 5380.5 6540 RPD MWD060 OHMM 0.88 2000 56.3624 2176 5380.5 6498.5 RPM MWD060 OHMM 13.55 2000 36.1096 2176 5380.5 6498.5 RPS MWD060 OHMM 12.9 2000 31.0576 2176 5380.5 6498.5 RPX MWD060 OHMM 9.78 2000 29.6982 2176 5380.5 6498.5 FET MWD060 HR 0.15 103.59 4.42033 2176 5380.5 6498.5 GR MWD060 API 25.2 140.92 58.7434 2208 5388.5 6492 ROP MWD060 FPH 0.67 1386.19 233.305 2194 5443.5 6540 First Reading For Entire File..........5380 Last Reading For Entire File...........6540 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date. ..................08/12/15 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/12/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. writing Library. Page 10 scientific Technical services scientific Technical services 3k-103pb3.txt Physical EOF Physical EOF End Of LIS File Page 11 3k-103pb4.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 16:36:42 2008 Reel Header Service name .............LISTPE Date . ...................08/12/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................08/12/15 origin ...................STs Tape Name...... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: 3K-103 PB4 API NUMBER: 500292339273 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 15-DEC-08 JOB DATA MWD RUN 2 MWD RUN 5 MWD RUN 6 ]oB NUMBER: Mw0006005291 Mw0006005291 Mw0006005291 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON F. HERBERT F. HERBERT MWD RUN 7 JOB NUMBER: MW0006005291 LOGGING ENGINEER: S. POLAK OPERATOR WITNESS:' F. HERBERT SURFACE LOCATION SECTION: 35 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 885 FEL: FWL: 314 Page 1 ~~-11~" 141G/5' ~ ~ 3k-103pb4.txt ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 74.62 GROUND LEVEL: 33.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 2540.0 2ND STRING 6.750 9.625 5435.0 3RD. STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 3K-103 P63 WELLBORE AT 5900'MD/3571'TVD, WITHIN THE MWD RUN 6 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,5-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUNS 6,7 ALSO INCLUDED GEO-PILOT ROTARY STEER- ABLE BHA (G P). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 7. MWD RUNS 1,2,5-7 REPRESENT WELL 3K-103 PB4 WITH API#: 50-029-23392- 73. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8794'MD/3545'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A Page 2 ~ ~ 3k-103pb4.txt WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name:.. .......STSLIB.001 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2506.5 8745.0 RPD 2525.0 8752.0 RPS 2525.0 8752.0 RPM 2525.0 8752.0 FET 2525.0 8752.0 RPx 2525.0 8752.0 ROP 2550.5 8794.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP .MERGE BASE 2 2506.5 2925.0 5 2925.5 5443.0 6 5443.0 5900.0 7 5900.5 8794.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ......... .. ......... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code Offset Channel Page 3 3k-103pb4.txt DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 8794 5650.25 12576 2506.5 8794 RPD MWD OHMM 0.77 2000 29.5017 12394 2525 8752 RPM MWD OHMM 0.38 2000 24.5857 12394 2525 8752 RPS MWD OHMM 0.35 2000 20.6243 12394 2525 8752 RPX MWD OHMM 0.27 2000 19.4073 12394 2525 8752 FET MWD HR 0.14 103.59 2.10888 12394 2525 8752 GR MWD API 12.04 130.55 70.4206 12478 2506.5 8745 ROP MWD FPH 0.02 1386.19 186.739 12488 2550.5 8794 First Reading For Entire File..........2506.5 Last Reading For Entire File... .........8794 File Trailer .Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.002 Physical EoF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC 2506.5 SEDP 2525.0 SEMP 2525.0 SExP 2525.0 STOP DEPTH 2925.0 2925.0 2925.0 2925.0 Page 4 U 3k-103pb4.txt SESP 2525.0 2925.0 SFXE 2525.0 2925.0 SROP 2550.5 2925.0 LOG HEADER DATA DATE LOGGED: 27-SEP-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2925.0 TOP LOG INTERVAL (FT): 2550.0 BOTTOM LOG INTERVAL (FT): 2925.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 58.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.05 MUD VISCOSITY (S): 52.0 'MUD PH: 8.5 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 81.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.480 105.8 MUD FILTRATE AT MT: 5.000 81.0 MUD CAKE AT MT: 1.500 81.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth,units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ....................... Page 5 r 3k-103pb4.txt Datum Spe cificat ion Block sub -type...0 Name service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 2925 2715.75 838 2506.5 2925 RPD MWD020 OHMM 0.98 2000 25.6799 801 2525 2925 RPM MWD020 OHMM 0.52 31.87 15.9015 801 2525 2925 RPS MWD020 OHMM 2.74 32.59 14.7172 801 2525 2925 RPX MWD020 OHMM 3.09 27.28 11.8377 801 2525 2925 FET MWD020 HR 0.14 62.77 4.76348 801 2525 2925 GR MWD020 API 12.04 1 01.04 61.0104 838 2506.5 2925 ROP MWD020 FPH 7.71 6 36.24 297.093 750 2550.5 2925 First Reading For Entire File..........2506.5 Last Reading For Entire File...........2925 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 gate of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLI6.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type .. .............LO Previous File Name.......STSLIB.002 comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 5 .5000 VENDOR TOOL CODE START DEPTH SEXP 2925.5 STOP DEPTH 5380.0 Page 6 3k-103pb4.txt SFXE 2925.5 5380.0 SROP 2925.5 5443.0 SGRC 2925.5 5388.0 SEMP 2925.5 5380.0 SEDP 2925.5 5380.0 SESP 2925.5 5380.0 LOG HEADER DATA DATE LOGGED: 03-OCT-O8 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5442.0 TOP LOG INTERVAL (FT): 2925.0 BOTTOM LOG INTERVAL (FT): 5442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfan ate MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 56.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.100 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .950 85.6 MUD FILTRATE AT MT: 1.200 73.0 MUD CAKE AT MT: 1.200 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame 5pacing .....................60 .lIN Page 7 i i- 3k-103ppb4.txt Max frames per record ..... ........undefined Absent value ... ........... ........-999 Depth Units. .. . . ..... Datum Specifica tion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2925.5 5443 4184.25 5036 2925.5 5443 RPD MWD050 OHMM 3.76 841.89 16.1098 4910 2925.5 5380 RPM MWD050 OHMM 3.07 1612.7 16.0214 4910 2925.5 5380 RPS MWD050 OHMM 2.42 104.21 11.5286 4910 2925.5 5380 RPX MWD050 OHMM 2.21 33.49 8.14578 4910 2925.5 5380 FET MWD050 HR 0.28 91.47 1.25186 4910 2925.5 5380 GR MWD050 API 23.44 130.55 80.5042 4926 2925.5 5388 ROP MWD050 FPH 0.39 489.84 190.247 5036 2925.5 5443 First Reading For Entire File..... ,...2925.5 Last Reading For Entire File...........5443 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name.... ......STSLIB.004 Physical EoF File Header service name... .......STSL2B.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type .. .............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 Page 8 3k-103pb4.txt FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SESP 5380.5 5900.0 SFXE 5380.5 5900.0 SEMP 5380.5 5900.0 SEXP 5380.5 5900.0 SEDP 5380.5 5900.0 SGRC 5388.5 5900.0 SROP 5443.5 5900.0 LOG HEADER DATA DATE LOGGED: 08-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5900.0 TOP LOG INTERVAL (FT): 5442.0 BOTTOM LOG INTERVAL (FT): 5900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 68.0 MUD PH: •0 MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ....... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Page 9 • 3k-103pb4.txt Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. ..... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MwD060 OHMM 4 1 68 16 5 FET MwD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First LdSt Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5380.5 5900 5640.25 1040 5380.5 5900 RPD MWD060 OHMM 0.88 2000 85.921 979 5380.5 5900 RPM MWD060 OHMM 15.89 2000 41.0032 979 5380.5 5900 RPS MWD060 OHMM 15.08 2000 28.8914 979 5380.5 5900 RPX. MWD060 OHMM 9.78 2000 26.1411 979 5380.5 5900 FET MwD060 HR 0.15 1 03.59 8.92593 979 5380.5 5900 GR MWD060 API 25.2 84.34 58.6352 1024 5388.5 5900 ROP MWD060 FPH 54.2 13 86.19 264.55 914 5443.5 5900 First Reading For Entire File..........5380.5 Last Reading For Entire File...........5900 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. Page 10 3k-103pb4.txt BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FIL E SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEMP 5900.5 8752.0 SROP 5900.5 8794.0 SEXP 5900.5 8752.0 SESP 5900.5 8752.0 SEDP 5900.5 8752.0 SGRC 5900.5 8745.0 SFXE 5900.5 8752.0 LOG HEADER DATA DATE LOGGED: 11-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8794.0 TOP LOG INTERVAL (FT): 5900.0 BOTTOM LOG INTERVAL (FT): 8794.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE. TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 68.0 MUD PH: .O MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Page 11 • 3k-103pb4.txt Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MwD070 HR 4 1 68 20 6 GR MwD070 API.: 4 1 68 24 7 ROP MWD070 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5900.5 8794 7347.25 5788 5900.5 8794 RPD MWD070 OHMM 0.77 2000 31.8827 5704 5900.5 8752 RPM MWD070 OHMM 0.38 2000 30.3596 5704 5900.5 8752 RPS MWD070 OHMM 0.35 2000 27.8645 5704 5900.5 8752 RPX MWD070 OHMM 0.27 2000 29.0085 5704 5900.5 8752 FET MwD070 HR 0.18 32.02 1.30378 5704 5900.5 .8752 GR MWD070 API 32.97 1 11.05 65.1979 5690 5900.5 8745 ROP MWD070 FPH 0.02 7 17.03 157.1 5788 5900.5 8794 First Reading For Entire File..........5900.5 Last Reading For Entire File...........8794 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/12/15 Origin ...................STS Tape. Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Reel Trailer Page 12 service name .............LISTPE gate . ...................08/12/15 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 NeXt Reel Name...........UNKNOWN Comments .................STS LIS Physical EoF Physical EOF End Of LIS File 3k-103pb4.txt writing Library. Scientific Technical services Page 13 3k-103pb5.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 15 17:15:27 2008 Reel Header Service name .............LISTPE Date . ...................08/12/15 Ori9in ...................STS Reel Name. ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date. .. .................08/12/15 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. • scientific Technical Services Scientific Technical services Physical EoF comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: 3K-103 P65 API NUMBER: 500292339274 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 15-DEC-08 JOB DATA MWD RUN 2 MWD RUN 5 MWD RUN 6 Job NUMBER: Mw0006005291 Mw0006005291 Mw0006005291 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: M. THORNTON F. HERBERT F. HERBERT MWD RUN 7 MWD RUN 8 JOB NUMBER: Mw0006005291 Mw0006005291 LOGGING ENGINEER: S. POLAK S. POLAK OPERATOR WITNESS: F. HERBERT F. HERBERT SURFACE LOCATION SECTION: 35 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 885 FEL: FWL: 314 Page 1 ~O ~t~<~5~ f ~1 / ~~ • 3k-103pb5.txt ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 74.62 GROUND LEVEL: 33.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 2540.0 2ND STRING 6.750 9.625 5435.0 3RD STRING PRODUCTION STRING REMARKS: C~ 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPEN-HOLE SIDETRACK, EXITING THE 3K-103 P64 WELLBORE AT 8600'MD/3553'TVD, WITHIN THE MWD RUN 7 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,5-8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 2 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUNS 6-8 ALSO INCLUDED GEO-PILOT ROTARY STEER- ABLE BHA (GP). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 7. MWD RUNS 1,2,5-8 REPRESENT WELL 3K-103 PB5 WITH API#: 50-029-23392- 74. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12373'MD/3646'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A Page 2 3k-103pb5.txt WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 Service Sub Level~Name... version Number.. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPX RPM RPD RPS ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 2506.5 2525.0 2525.0 2525.0 2525.0 2525.0 2550.5 STOP DEPTH 12324.0 12331.0 12331.0 12331.0 12331.0 12331.0 12373.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 5 MWD 6 MWD 7 MWD 8 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2506.5 2925.0 2925.5 5443.0 5443.0 5900.0 5900.5 8600.0 8600.5 12373.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ................ ..... Datum Specification Block sub-type...0 Page 3 3k-103pb5.txt Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 12373 7439.75 19734 2506.5 12373 RPD MWD OHMM 0.77 2000 26.8703 19552 2525 12331 RPM MWD OHMM 0.38 2000 23.3518 19552 2525 12331 RPS MWD OHMM 0.35 2000 20.6362 19552 2525 12331 RPX MWD OHMM 0.27 2000 19.8317 19552 2525 12331 FET MWD HR 0.14 103.59 1.48375 19552 2525 12331 GR MWD API 12.04 1 30.55 68.7032 19636 2506.5 12324 ROP MWD FPH 0.02 13 86.19 193.232 19646 2550.5 12373 First Reading For Entire File..........2506.5 Last Reading For Entire File...........12373 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type....... .......LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE SGRC SEDP SEMP START DEPTH 2506.5 2525.0 2525.0 STOP DEPTH 2925.0 2925.0 2925.0 Page 4 ~ ~ 3k-103pb5.txt sEXP 2525.0 2925.0 SESP 2525.0 2925.0 SFXE 2525.0 2925.0 SROP 2550.5 2925.0 LOG HEADER DATA DATE LOGGED: 27-SEP-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2925.0 TOP LOG INTERVAL (FT): 2550.0 BOTTOM LOG INTERVAL (FT): 2925.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 58.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER's CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 9.05 MUD VISCOSITY (S): 52.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.900 81.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.480 105.8 MUD FILTRATE AT MT: 5.000 81.0 MUD CAKE AT MT: 1.500 81.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... .........0 Data Specification Block Type.....0 Loggin Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 5 3k-103pb5.txt Depth units.. .. . . ..... Datum specificat ion Block sub-type...0 Name Service order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MwD020 HR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2506.5 2925 2715.75 838 2506.5 2925 RPD MWD020 OHMM 0.98 2000 25.6799 801 2525 2925 RPM MWD020 OHMM 0.52 31.87 15.9015 801 2525 2925 RPS MWD020 OHMM 2.74 32.59 14.7172 801 2525 2925 RPX MWD020 OHMM 3.09 27.28 11.8377 801 2525 2925 FET MwD020 HR 0.14 62.77 4.76348 801 2525 2925 GR MWD020 API 12.04 101.04 61:0104 838 2506.5 2925 ROP MWD020 FPH 7.71 636.24 297.093 750 2550.5 2925 First Reading For Entire File..........2506.5 Last Reading For Entire File...........2925 File Trailer Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLI6.003 Physical EOF File Header service name... .......STSL26.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 6 3k-103pb5.txt SGRC 2925.5 5388.0 SROP 2925.5 5443.0 SFXE 2925.5 5380.0 SEXP 2925.5 5380.0 SEDP 2925.5 5380.0 SESP 2925.5 5380.0 SEMP 2925.5 5380.0 LOG HEADER DATA DATE LOGGED: 03-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5442.0 TOP LOG INTERVAL (FT): 2925.0 BOTTOM LOG INTERVAL (FT): 5442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 40.6 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2540.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfan ate MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 56.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.100 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .950 85.6 MUD FILTRATE AT MT: 1.200 73.0 MUD CAKE AT MT: 1.200 73.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Page 7 r LJ 3k-103pb5.txt Frame Spacing.. ..... ............60 .lIN Max frames per record .............undefined Absent value... ... ..............-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2925.5 5443 4184.25 5036 2925.5 5443 RPD MWD050 OHMM 3.76 841.89 16.1098 4910 2925.5 5380 RPM MwD050 OHMM 3.07 1612.7 16.0214 4910 2925.5 5380 RPS MWD050 OHMM 2.42 104.21 11.5286 4910 2925.5 5380 RPX MWD050 OHMM 2.21 33.49 8.14578 4910 2925.5 5380 FET MwD050 HR 0.28 91.47 1.25186 4910 2925.5 5380 GR MWD050 API 23.44 130.55 80.5042 4926 2925.5 5388 ROP MWD050 FPH 0.39 489.84 190.247 5036 2925.5 5443 First Reading For Entire File..........2925.5 Last Reading For Entire File...........5443 File Trailer Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File TyPe ................LO Next .File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 Page 8 3k-103pb5.txt FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 5380.5 5900.0 SEMP 5380.5 5900.0 SESP 5380.5 5900.0 SEDP 5380.5 5900.0 SFXE 5380.5 5900.0 SGRC 5388.5 5900.0 SROP 5443.5 5900.0 LOG HEADER DATA DATE LOGGED: 08-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT): 5900.0 TOP LOG INTERVAL (FT): 5442.0 BOTTOM LOG INTERVAL (FT): 5900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Page 9 i 3k-103pb5.txt Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 5380.5 5900 5640.25 1040 5380.5 5900 RPD MWD060 OHMM 0.88 2000 85.921 979 5380.5 5900 RPM MwD060 OHMM 15.89 2000 41.0032 979 5380.5 5900 RPS MWD060 OHMM 15.08 .2000 28.8914 979 5380.5 5900 RPX MWD060 OHMM 9.78 2000 26.1411 979 5380.5 5900 FET MwD060 HR 0.15 1 03.59 8.92593 979 5380.5 5900 GR MwD060 API 25.2 84.34 58.6352 1024 5388.5 5900 ROP MWD060 FPH 54.2 13 86.19 264.55 914 5443.5 5900 First Reading For Entire File..........5380.5 Last Reading For Entire File...........5900 File Trailer Service name... .......STSL2B.004 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EoF File Header Service name... .......STSLIB.005 Service sub Level Name... version Number. ........1.0..0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type.. ...........Lo Previous File.Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 10 • 3k-103pb5.txt curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FIL E SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 5900.5 8600.0 SFXE 5900.5 8600.0 SESP 5900.5 8600.0 SEMP 5900.5 8600.0 SGRC 5900.5 8600.0 SEDP 5900.5 8600.0 SROP 5900.5 8600.0 LOG HEADER DATA DATE LOGGED: 11-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8600.0 TOP LOG INTERVAL (FT): 5900.0 BOTTOM LOG INTERVAL (FT): 8600.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 68.0 MUD PH: .O MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 11 •- i 3k-103pb5.txt Data Format Specification Record Data Record Type... .... .....0 Data specification Block Type .....0 Log~iny Direction ............ .....DOwn optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame spacing....... ....... .....60 .11N Max frames per record ........ .....undefined Absent value ................. .....-999 Depth Units.. .. .. ..... Datum Specification Block sub -type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MwD070 OHMM 4 1 68 12 4 RPX MwD070 OHMM 4 1 68 16 5 FET MwD070 HR 4 1 68 20 6 GR MwD070 API 4 1 68 24 7 ROP MWD070 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5900.5 8600 7250.25 5400 5900.5 8600 RPD MWD070 OHMM 0.77 2000 32.981 5400 5900.5 8600 RPM MwD070 OHMM 0.38 2000 31.4147 5400 5900.5 8600 RPS MWD070 OHMM 0.35 2000 28.81 5400 5900.5 8600 RPX MWD070 OHMM 0.27 2000 30.0255 5400 5900.5 8600 FET MwD070 HR 0.18 32.02 1.34541 5400 5900.5 8600 GR MWD070 API 32.97 111.05 64.2188 5400 5900.5 8600 ROP MWD070 FPH 0.02 717.03. 158.842 5400 5900.5 8600 First Reading For Entire File..........5900.5 Last Reading For Entire File...........8600 File Trailer Service name... .......sT5LI6.005 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........sTSLIB.006 Physical EOF File Header Service name... .......sTSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.005 Comment Record Page 12 • 3k-103pb5.txt FILE HEADER FILE NUMBER: 6 , RAW MWD Curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEMP 8600.5 12331.0 SROP 8600.5 12373.0 5E5P 8600.5 12331.0 SEDP 8600.5 12331.0 SGRC 8600.5 12324.0 SFXE 8600.5 12331.0 SEXP 8600.5 12331.0 LOG HEADER DATA DATE LOGGED: 13-OCT-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12373.0 TOP LOG INTERVAL (FT): 8600.0 BOTTOM LOG INTERVAL (FT): 12373.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.1 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 64004 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 5435.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): 4.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Page 13 REMARKS: 3k-103pb5.txt Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Di rection .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MwD080 OHMM 4 1 68 16 5 FET MWD080 HR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8600.5 12373 10486.8 7546 8600.5 12373 RPD MWD080 OHMM 5.14 68.93 21.9091 7462 8600.5 12331 RPM MWD080 OHMM 4.05 75.99 20.8243 7462 8600.5 12331 RPS MWD080 OHMM 4.24 79.32 20.2662 7462 8600.5 12331 RPX MWD080 OHMM 4.1 88.09 20.1745 7462 8600.5 12331 FET MWD080 HR 0.16 4.21 0.407974 7462 8600.5 12331 GR MWD080 API 42.89 115.01 66.3993 7448 8600.5 12324 ROP MWD080 FPH 2.94 337.89 200.872 7546 8600.5 12373 First Reading For Entire File..........8600.5 Last Reading For Entire File...........12373 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/12/15 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/12/15 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Page 14 3k-103pb5.txt Comments .................5T5 LIS writing Library. Reel Trailer Service name .............LISTPE gate...... ...............08/12/15 Ori in ...................STS Ree~ Name...... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 15