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205-035
Originated: Delivered to:10-Oct-24 Alaska Oil & Gas Conservation Commiss 10Oct24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3T-621 50-103-20882-00-00 224-022 Kuparuk River WL FMI-MSIP-PEX-ZAIT-XPT FINAL FIELD 11-Mar-24 3S-722 50-103-20886-00-00 224-066 Kuparuk River WL HSD FINAL FIELD 18-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL TTiX-IPROF FINAL FIELD 22-Sep-24 1J-154 50-029-23254-00-00 205-035 Kuparuk River WL TTiX-WFL FINAL FIELD 25-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL IPROF FINAL FIELD 27-Sep-24 1D-05 50-029-20417-00-00 179-095 Kuparuk River WL SCMT FINAL FIELD 28-Sep-24 2K-07 50-029-21351-00-00 189-071 Kuparuk River WL PPROF FINAL FIELD 1-Oct-24 1R-08 50-029-21333-00-00 185-073 Kuparuk River WL IPROF FINAL FIELD 5-Oct-24 1R-10 50-029-21351-00-00 185-096 Kuparuk River WL IPROF FINAL FIELD 6-Oct-24 3S-722 50-103-20886-00-00 224-066 Kuparuk River WL TTiX-Perf FINAL FIELD 9-Oct-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39651 T39652 T39652 T39653 T39653 T39654 T39655 T39656 T39657 T39658 1J-154 50-029-23254-00-00 205-035 Kuparuk River WL TTiX-WFL FINAL FIELD 25-Sep-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.11 08:44:58 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-154 KUPARUK RIV U WSAK 1J-154 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-154 50-029-23254-00-00 205-035-0 W SPT 3438 2050350 1500 517 518 518 518 623 624 624 624 4YRTST P Adam Earl 5/7/2022 MIT IA 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 1J-154 Inspection Date: Tubing OA Packer Depth 1200 2010 1965 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509111503 BBL Pumped:0.5 BBL Returned:0.5 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:13:06 -08'00' Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, October 26, 2019 11:10 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1J-154 (PTD 205-035) Report of 30 day monitor completion. Attachments: 7154 90 Day TIO plot.JPG Chris, KRU West Sak water injector 1J-154 (PTD 205-035) has completed the 30 -day monitor period for the unexplained IA pressure fall off. During the initial set of diagnostics, DHD identified a leaking needle valve stem on the surface jewelry. The stem packing was repaired and the well passed an MIT -IA, tubing and inner casing pack off tests. The well has since shown no indications of IA pressure fall off. CPAI intends to return the well to normal injection status. Please let us know if you have any questions or disagree with the results. Attached is a copy of the current 90 -day TO plot. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM c�nocw svuivs From: Well Integrity Compliance Specialist CPF1 & 2 t: Tuesday, September 24, 2019 9:02 AM To: cqris.waIlace @alaska.gov' <chris.wallace@alaska.gov> Cc: CPA ells Supt <n1030@conocophillips.com> Subject: K11113.1.1-154 (PTD 205-035) Report of suspect IA pressure decrease Chris, KRU West Sak water injecto -154 (PTD 205-035) is exhibiting unexplained IA pressure decrease. DHD will mobilize to the well to perform initial diagno 'cs after which the well will be put on a 30 day monitor. The proper paperwork for continued injection or corrective acts will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attac Please let us know if you disagree or have any quesflops with this plan Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, September 24, 2019 9:02 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1J-154 (PTD 205-035) Report of suspect IA pressure decrease Attachments: 1J-154.pdf; 1J-154 90 day TIO trend 9.24.19.pdf Chris, KRU West Sak water injector 1J-154 (PTD 205-035) is exhibiting unexplained IA pressure decrease. DHD will mobilize to the well to perform initial diagnostics after which the well will be put on a 30 day monitor. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 51kWELLS ccorwooN. '.�TE.4M Originated: Schlumberger PTS-PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Deliveredto: r AOGCC a 1 TTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision ' 333 W. 7th Ave, Suite 100 w Anchorage, AK 99501 205035 TRANSMITTAL DATE TRANSMITTAL# , me return via courier or sign/scan and email a copy to Date mberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 14,2018 TO: Jim Regg P.I.Supervisor l 517-l'f e SUBJECT: Mechanical Integrity Tests t CONOCOPHILLIPS ALASKA,INC. 1J-154 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-154 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry � � NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-154 API Well Number 50-029-23254-00-00 Inspector Name: Lou Laubenstein Permit Number: 205-035-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510144909 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -------- -- Well 1J-154 'Type Inj W' TVD 3438 - Tubing 0 0 0 0 PTD 2050350 !Type Test SPT Test psi 1500 IA 1570 2210 2165 - 2165 — BBL Pumped: 1 0.4 "BBL Returned: 0.4 OA 378 j 378 - 378- 378 - Interval 4YRTST P/F P V Notes: Tubing was on a vac during this test. SCANNED JUN 0 4'20'18 i Monday,May 14,2018 Page 1 of 1 • • t<2-ut ,J= 1s4 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, May 10, 2018 7:44 AM Rep 5-14/g To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK Optimization Engr Subject: LPP/SSV Returned to Service on CPAI Well 1J-154 on 5/9/2018 Jim, The low pressure pilot (LPP) on well 1J-154(PTD#205- 205-036,205-037)was returned to service and removed from the "Facility Defeated Safety Device Log" last night, 5/9/2018, after the well was shut-in following the completion of wellwork. The LPP had been defeated on 5/2/2018 when the well was returned to service to perform wellwork.This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 SCANNED MAY 2 4 2018 • T ZO ,ço Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday, May 2, 2018 3:45 PM 17 To: Regg,James B (DOA) Cc: 51���� Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; CPF1&2 Ops Supt;Autry, Sydney; Braun, Michael (Alaska); Fox, Pete B; Sudan, Hari Hara; NSK Optimization Engr Subject: LPP/SSV Defeated on CPAI Well 1J-154 Jim, Today we returned well 1J-154(PTD#205-035k 205-036,205-037), a WestSak seawater injector,to service. The well iS taking at our recommended injection rate of 3000bwpd at zero wellhead pressure, so the low pressure pilot(LPP/SSV)' had to be defeated. The LPP and surface safety valves(SSV) have been tagged and their status is recorded in the "Facility D.-We-RR Safety Device Log." The AOGCC will be notified when 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. Michael Braun for Marina Krysinski / Courtney Gallo West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 SCANNED Pager: (907) 659-7000 #497 i ! S r0 Lt) LC) rr rrr H h r r r r r r r x m a M 0 ° � 3 Ln bp T `° h rn 0 � ca oa) C CD N Uu L. ro Y CU > 0Vra C, m .).- =a Q -1 W W CO 00 CO CO CO CO CO +4 N C p 6 m J Q '. ,04- r W W O r ' ' ' r ' VI _C N U L N 0as as Q Q Q Q Q Q Q Q Q ,- -6 N L J g E Q Q Q Q Q Q Q Q Q C L c C Vt < N M M r r O r N M cn 0@ i C N Z - Q u "6 O u Z Q ❑ 2 >ci) N cc O C L F- c v QJ 0 L ❑ ❑ ❑ ❑❑ ❑ ❑ ❑ ❑ ❑ ❑ J J J J J J J J J J J CIOC O r,} W W W W W W W W W W W '�n N 'C U 9— F- LL U. LL LL LL LL U. LL LL LL LL 4-+ a) a v -0 Q J J J J J J J J J J J2. J > +, N -Q Q Q Q Q Q Q Q Q Q Q a.) o ° 4 `- • Z Z Z Z Z Z Z Z Z Z Z ut a) ° '- C a) v LL U. LL L. U. LL Ll. U. 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Q. id QI- Q a Q • mut I -I54 • h Zo5D3) Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, April 5, 2018 8:39 AM 4'a 4 f liG To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Had Hara Subject: LPP/SSV Returned to Service on CPAI well 1J-154 -4/4/2018 Jim, The low pressure pilot (LPP) on well 1J-154(PTD#205-035,#20436,#205-037) was returned to service and removed from the "Facility Defeated Safety Device Log" last night,4/4/2018, after the well was shut-in following the completion of wellwork. The LPP had been defeated on 3/30/2018 when the well was returned to service to perform wellwork.This notification is in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Sydney Autry for Marina Krysinski West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 S(ANNEL) snoiq Ki4AILTls4- • • ( -)S P Zo‘Ta Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, March 30, 2018 5:43 PM `� To: Regg,James B (DOA) 1� �, /�'�o Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Autry, Sydney;Targac, Gary; Fox, Pete B; Sudan, Hari Hara Subject: Defeated LPP/SSV on CPAI Well 1J-154 on 3/30/2018 Jim, 1.2r The low pressure pilot(LPP) on well; J-154(PTD#205-0 ,#205-036,#205-037) was defeated today, 3/30/2018, after the well was returned to service to perform wellwork.The well is currently injecting 1036 6WPD at 369 psi wellhead pressure.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 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. Marina Krysinski/Mitch Autrey West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1 ML y° I- T ` " o , 3 0 04 z D p'�W vO E Ti) cnm N N , > o c vc o �Cl S ul o OU ) Q Q E a a m 0 —) UJ r r r ti r N 0 Q E � L o n Q 0 1C 1C CO @ @ L 'a ut C (0 u L Ili C N LO O r- N M O C @ 4 G Z Q N N N U a) E U Z ❑cz " N O co H aa C u1 cu 0 u w J J J J J .� 0 C .0 U 0 TWWW W W 4, v v v -a s H LL LL LL LL LL a .p > CN 0 1- 0 0 0 Q Q u (0 Ili N 0 Z o) , ❑ Z Z Z Z Z K L > 01 LL LL LL LL LL U N c c ate+ u > C a) _ Q1 L O S1 5 0E N u cu p g is C O @ r C+ O Q HcV > rua OS?.. O O c' Z 0 ^ Q Ili a v, C a T� a a V a _ m J J J J d 4 03 >-- O —I- Q ill Un b - 11'rte, w > a, o Z ,s 2 S xS gza Irer g R' a' eGa' ce W W W W W > > > > > MCGCCCLCe .L Y Y Y Y Y > > > > > ' WfXa+ 4 Q Q Q Q Q Al z O a a a a a @ a > > > > > O i t Y Y Y Y Y to O �., x in — M V CO N o0 co ` O O O O O — ] O 0 O 0 0 V O O O O O CU O O O O O O @ _ V t0nth 0000 _> W N V lnfntoNV) • Q c ❑ ❑ ❑ ❑ ❑ V ac O5 � V @ oNo WQ O O O O O O OO O Oo0 ; rrLv v N) IX gt M N M VI MM N 4, ._ a E L N N N N N N N • L gft C) O C) C) C) C O a0 p NNNNN Q v 01 O O O O O Y o a. 00 O O O O O a. -C CO C C CO 1n N In 1n u Cla OG ri _ C ' U Cin E oc .V) a W <1L -0 @ @ CD U Q �� Y 1l1 c Y Y JOI 9 Z 6J d ."4 0 Q r- O in Tr N. co � en �co cu �., V N rtCmJ � � � z .� as O ; d � � � � C z 00 0 To .= 1 u ., 3 c 2 `0 E O Ni kb a I I _ C. a r t- Vg-UL u 1S4 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, July 22, 2016 12:43 PM ,T2,0 7(Z7/10 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr Specialist; CPF1 Prod Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on CPAI well 1J-154 Jim, The low pressure pilot (LPP) on well J-154 PTD#205-035 205-036,205-037)was returned to service today, 7/22/16. The well is currently stabilizing at aellhead injection pressure of 520 psig and rate at 975 BWPD, and has been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers . cANNED JAN a 1 7017 ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 Regg, James B (DOA) v%055 035 From: NSK West Sak Prod Engr <n1638@conocophillips.com> / Sent: Sunday,July 17, 2016 7:57 AM e11 6 611(‘' To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI 1J wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110, 206-111, 206-112) 1J-118 (PTD#206-176, 206-177,206-178) 1J-122 (PTD#207-070, 207-071, 207-072) 1J-127 (PTD#206-047,206-048, 206-049) SCANNEDJAN 1 22017 1J-136 (PTD#206-154 206-155 •, 1J-154(PTD#205-035 205-036,205-037) 1J-156(PTD#206-067,206-0• :, s•-s • • The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's 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. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- ~~~ Well History File Identifier Organizing (done) ~wo-sided III IIIIII II III II III RESCAN DIGITAL DATA ~olor Items: Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: Ae..~~ n~aea III IIIIII011111111 OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ` Maria Date: ~ ~3~~0~ lsl ~/ Y Project Proofing III ()IIII VIII II III BY: Maria Date: I I ~D/ ~~ ~s~ __ _ ,/ / - r - ~ Scanning Preparation ~ x 30 = ~ + ~ =TOTAL PAGES----C~~ (Count does not include cover sheet) BY: ~ Maria Date: 113 O D ~ lsl ~~ ~ .~ Production Scanning III II'llll~lll Illll Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~/~~ / Q~ /s/ J ~~ Stage 1 If /VO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. II I II I~ ~I I I) ~ I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III 10/6!2005 Well History File Cover Page.doc MEMORANDUM TO: Jim Regg ~~~~~ ~II (r,,, P.I. Supervisor FROM: $Ob NObie Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IJ-154 KUPARUK RIV U WSAK 1J-154 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~J Comm Well Name: KUPARUK RIV U WSAK 1J-154 API Well Number: 50-029-23254-00-00 Insp Num: mitRCN100516141958 Permit Number: 205-035-0 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 1J-154 ~'' y e In~ ° T~ID ~- 3428 `~ i IA 1098 1850 ~ - - 1840 1840 f _ P.T.D 2050350' TypeTCSt SPT I - TCSt pSl 1850 _ OA ~ 527 527 527 527 Interval 4YRTST p~ P -/ Tubing 624 i 624 624 624 Notes: ~l n {~q~~ -~d-- i ~Og s; ~C~~i, r'.:F.:_ ~ ' i .. .._., Monday, May 24, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska2gov OPERATOR: ConocoPhillips Alaska Inc. ~,~ ~3~ FIELD /UNIT /PAD: Kuparuk /KRU / 1J ~~ DATE: 05/14/10 OPERATOR REP: Colee /Phillips - AES AOGCC REP: Bob Noble 5 ~ ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casing 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 Well 1J-127 Type Inj. W TVD 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 Type test P Test psi 1500 Casing 1,020 1,700 1,680 1,680 P/F P Notes: OA 206 273 260 253 Well 1J-136 Type Inj. N TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 Type test P Test psi 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 183 182 180 Well 1J-154 Type Inj. W TVD 3,437' Tubing 624 624 624 624 Interval 4 P.T.D. 2050350 Type test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Well 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubing 626 626 626 S~ 625 Interval 4 P.T.D. 2070150 Type test P Test psi 1500 Casing 925 1,680 1,650 1,640 P/F P Notes: OA 332 333 333 334 ~ F ~ ~, ,~ tta . Y ~~r.* ~ ~ ; l MIT Report Form BFL 11/27!07 KRU 1J pad 05-14-10.xts o/ -.~ V v~ V Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubin 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P!F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P!F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test V '/ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s MEMORANDUM To: Jim Regg ~~~C sjZ~~~~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector n LJ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-ls4 KUPARUK RIV U WSAK 1J-154 • Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~ Comm Well Name: KUPARUK RIV U WSAK IJ-154 Insp Num: mitRCN090526114457 Rel Insp Num: API Well Number: 50-029-23254-00-00 permit Number: 205-035-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-154 Type Inj. W TVD 3437 IA 980 1530 1500 1s00 P.T.D 2050350 TypeTCSt SPT Test psi 1s30 - QA 610 610 610 610 Interval axRTST p~ P / Tubing 7so Tso 7so Aso Notes: Wednesday, May 27, 2009 Page 1 of 1 ~ • • • ConocoPh i I 1 s ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission ~~~ _ ~ ~~ 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~N~~ SEP ~ ~ 208 Dear Mr. Maunder: 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 August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept S-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei 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 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1 J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6!2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9/6/2008 MICRt3FLLMED a3/a 1 /ZOQ8 DCJ NQT PLACE ..ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc 3 C~ ~ tt u fie) ry 7 DATA SUBMITTAL COMPLIANCE REPORT 11/23/2007 Permit to Drill 2050350 Well Name/No. KUPARUK RIV U WSAK 1J-154 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23254-00-00 MD 9063 TVD 3643 Completion Date 10/30/2005 Completion Status 1-OIL Current Status 1 W1NJ UIC Y REQUIRED INFORMATION Mud Log No Sampies No Directional Surve Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Logl Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments r - --- - - - ---------- -- ---- - --- ~d~6g Spade C~~,,,~~ ~~~~ 5 Col 1 2200 5050 Case 11/18/2005 USIT Cement Bond Log 12 Oct 2005 ~ D D Asc Directional Survey 0 9063 Open 1/9/2006 Production 5 Blu 1 208 4109 Case 2/22/2006 PRODUCTION LOG WITH TRACTOR PSPT/GR/CAL/SPIN/MAX TRAC c;~u D Lis 13784 Induction/Resistivity 2256 9005 Open 3/9/2006 ASLD GR EWR4 CNP ~ SLD ROP ACAL OWD GeoPilot pt 13784 LI5 Verification 2256 9005 Open 3/9/2006 ASLD GR EWR4 CNP SLD ROP ACAL OWD GeoPilot C Lis 15014 Induction/Resistivity 2256 9063 Open 4/17/2007 LIS Veri, GR, FET, NPHI, FCNT, NCNT, RHOB, DRHO, CALA, ROP w/Graphics CGM, EMF, PDF Welt Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050350 Well Name/No. KUPARUK RIV U WSAK 1J-154 Operator CONOCOPHILLIPS ALASKA INC MD 9063 TVD 3643 Completion Date 10/30/2005 Completion Status 1-OIL Current Status 1WINJ ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/ N <.---~' Chips Received? Y / N Formation Tops Y N Analysis ~1`-9'I~ Received? Comments: Compliance Reviewed By _ _ ___ __ __ __ Date:- _~~ API No. 50-029-23254-00-00 UIC Y • WELL LOG TRANS'VIITTAL, To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-154, L1 & L2, April 13, 2007 AK-MW-3956462 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-154, 1J-154 L1,1J-154 L2: LIS & Digital Log Images: 50-029-23254-00, 60, 61. G. U ,:LC ao5- 03 S~ ~ ISO t~( =~ ,~ ~X ,j ,,_~, 'Li~~ ~ ~~ ~9J 4~~ ~~i ~~' U ~C a o5 =03~ CIS--~(5 1 CD Rom i.J 1~ 9-05 =D3~ ~~Sa~~ iy Subject: LPP Defeated On Wes''fSak Injectors at DS1J From: NSK West Sak Prod Engr <n1638@conocophillips.com> Date: Sun, 14 Jan 200710:08:32 -0900 To: "Tom Maunder:" <tom_maunder@admin.state.ak.us>, "Jim Regg:" <jim_regg@admin.state,ak,us> CC; CPFl DS Lead Techs <n1140@eonocophillips.com>, CPF1 Prod Supt <n 1132@conocophillips.com> Tom /Jim, aO s- ~'--~~1 1) The Low Pressure Pilot (LPP) for 1J-164 was defeated on 1/8/07 in accordance with "Administrative Approval No. CO 4066.001.°' The LPP and SSV have been tagged and recorded on the "Facility Defeated Safety Device Log." Wellhead pressure dropped below 500 psi on 1/8/07 after a foreign object became lodged in the restriction orifice (injection choke). The foreign object was removed on 1/13/07 (yesterday) and injection rate was returned to normal. The wellhead pressure is now 468 psi (1634 bwpd) and is building back up to where it was before the 1/8/07 event. I anticipate we will need to keep the LPP defeated for ~1 week. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. 2} The Low Pressure Pilots for 1J-127, 1J-154, 1J-156, and 1J-170 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: 1J-127 1517 BWPD, 548 PSI 1J-154 1406 BWPD, 612 PSI 1J-156 3613 BWPD, 586 PSI 1J-170 2737 BWPD, 540 PSI Regards, Hai Hai Hunt /Pete Nezaticky a0~-~~'~ a C7S-035 '~- ar~~-~~ NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 1 of 1 6/12/2007 1:32 PM LPP Defeated On West Sak Injectors 1J- Subject: LPP Defeated On West Sak Injectors 1J- Froth: NSK'~~'est Sak Prod-Engr <i~ 1 G3~~u c~nocophillps.con~> Date:' Tue, ?? .<~u~ ?UU6 07:>>:59 -O~OO TO: "T0111 ~'1dllllCiel':" <tOlll_Ill~llllCiel'(Cl!$CjTlllCl.Stlte.ak115>. ".~ll~l RC's-r,~:n ~:_)lill re~~~l,a(iR]lI1.Stall',.3k.US-~ CC: CPFl DS Lcad Techs ~~ nl 140fa;conocophillips.com>, NSK Wcst Sak Vrod Enbr ~~n 1 ~38~i'conocophi llips.com? Tom /Jim, This email is to notify the AOGCC that 1 J-154 and 1 J-164 West Sak injectors, LPP (Low Pressure Pilot) have been defeated on 08/21/06 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". Both wells required anon-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: T"'7 ~~ 5 _ d ~ S 1J-154: Converted from pre-production to injection 04!10/06. Injecting 530 bwpd at 480 psi. 1J-164: Converted from pre-production to injection 04/02/06. Injecting 1850 bwpd at 480 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 8/31/2006 10:08 AM MEMORANDUM • State of Alaska Al k ~d G i i C as a as Conservat on omm ssion DATE: Monday, May 22, 2006 To~ JimRegg ~ ~~23~~,t<r ~~J~~ P I Su i SUBJECT: Mechanical Integrity Tests . . perv sor CONOCOPHII.LIPS ALASKA INC 1J-154 FROM: j,OU GI'lm3lCl1 KUPARUK RIV U WSAK IJ-154 Petroleum Inspector Src: Inspector ~~~ NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK iJ-154 Insp Num mitLG060425135445 Rel Insp Num MITOPOOOOOI104 API Well Number Permit Number 50-029-23254-00-00 205-035-0 Inspector Name• Lou Grimaldi Inspection Date 4/25/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 1J-154 (Type Inj. W TVD li 3437 i IA 545 ~ ]650 ~ 1595 1590 P.T. ~ 2050350 'I'ypeTBSt SPT j Test psi j 1500 ~ DA 515 ; 515 ~ 515 j 515 Interval Iait;ai Tess p~F Pass Tubing ~ 60 ~ 60 ~ bo ~ 60 NOteS Initial MIT on new well. Monday, May 22, 2006 Page 1 of I ~i'~' 1 9 10u~~ STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil cat !:i!~,~ ~OItS. ~,OI11fTIISSiOn REPORT OF SUNDRY WELL OPERATIONS ~'~~~tl•a~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other Q Prod to WINJ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ E2e-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5, Permit to Drill Number: ConocoPhillips Alaska, lnC. Development ^ Exploratory ^ 205-035. 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23254-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1 J-154 - 8. Property Designation: 10: Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 9068' feet true vertical 3643' - feet Plugs (measured) Effective Depth measured 9068' feet Junk (measured) true vertical 3643' feet 4-112" Casing length Size MD TVD Burst - Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2191' 10-3J4" 2300' 2199' L2 WINDOW 1' 7-5/8" 4092' 3452' PROD. CASING 1' 7-5/8" 4371' 3512' INTERMEDIATE 5056' 7-5/8° 5165' Perforation depth: Measured depth: 5412' - 8071' Slotted true vertical depth: 3661' - 3628' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4047' MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 490' 12. Stimulation or cement squeeze summary: ~~ ~ ~~~ ~~ ~ ~` ~~~~' Intervals treated (measured) none ~' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well-operation 2044 2851 750 335 Subsequent to operation 2649 437 332 14. Attachments 15. Well Class after proposed work:. Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~© f _ O f~ O (~ Contact Robert W. Buchholz Printed Name n - ®` Title Production Engineering Technician ~ Signature ~~ib~~~ `~' ~S~N~r~~ Phone 907-659-7535 Date ~~/..~/O 6' Form 10-404 Revised 04/2004 ~ ~A ~N17 ~ Sub 't Ori in 1 Only OR1~I~A ~~~. 1 J-154 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/10/2006 Commenced Water Injection Service ~ 1J-154 West Sak LPP Defeated Notification per CO 406B.001 Subject: 1J-154 West Sak LPP Defeated Notification per CO 406B.001 From: CPF1 Prod Engr <n1269@conocoplullaps.com> Date: Wed, 12 Apr 2006 08:04:11 -0800 To: tom_maunder@admin.state.ak.us, jim_regg@admin.state.ak.us CC: NSK West Sak Prod Engr <n163$@conocophillips.com>, NSK Problem Well Supv <n1617@conocophillips.com>, CPF1 DS Lead Techs <n1140@conocoplullips.corn> Tom /Jim, _~ ~©~ _Q~ ~ This email is to notify the AOGCC that 1 J-154, a West Sak pre-produced injector has been placed on injection April 10, 2006 and is currently injecting 2700 bwpd on a vacuum. The LPP (Low Pressure Pilot) has been defeated and in accordance with "Administrative Approval No. CO 4068.001", the LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Thanks, Denise Titus Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 6112/2007 1:32 PM WELL LOG TRANSMITTAL To: State of Alaska March 03, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-154, AK-MW-3956460 1 LDWG formatted Disc with verification listing. API#: 50-029-23254-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Date: Signed: ~~ dug a3s ~`l~ • ~: ~ ~ ~, ~ ~ ~~ ALASSA OIL A1QD GAS COI~TSERQA7`IO1~T CO1rIIrIISSIOI~T Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, 1J-154 Sundry Number: 306-066 Dear Mr. Buchholz: L ~7f FRANK H. MURKOWSKI, GOVERNOR ~~ f ~~ 333 W. 7T"AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. c; r,.o,.o~« DATED this~day of February, 2006 Encl. Chairman RECEIVED ~ 1~~ FEB 2 1 2006 STATE OF ALASKA 7 ' ALASKA OIL AND GAS CONSERVATION COMMISSION AIBSka OIL $t Ga3 COt13. Conxnl$$ion APPLICATION FOR SUNDRY APPROVAL Anchorage 20 AAC 25280 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repairwell ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill mber: ConoCOPhillips Alaska, Inc. Development Q Exploratory ^ ~ 205-035 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23254-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1 J-154 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Poot 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9068' 3643' 9068' 3643' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2191' 10-3/4" 2300' 2199' L2 WINDOW 1' 7-5/8" 4092' 3452' L1 WINDOW 1' 7-5/8" 4371' 3512' INTERMEDIATE 5056' 7-5/8" 5165' 3649' A Sand Slotted Liner 2659' 4-1/2" 8071' 3628' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5412' - 8071' Slotted 3661' - 3628' 4-112" L-80 4047' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 490' 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 03/10/06 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert W. Buchholz Printed Name Robert W. B ch hol z u Title: Production Engineering Technician ~~,1y~~ ~ ~ / ~ Signature ~j'~%~ "'y '' .~ Phone 659-7535 Date ~ Z `~/(~~ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Te st ~ Location Clearance ^ Other: ~ ~~5~`~~ ~fc. CC <<~~ ~-+~Q. ~-.~~.`~ WG:~S iI ~. -Subsequent Form Required: t--, ~~~ ~~~ ~ ~ ~~Q~ APPROVED BY 'I Approved by: COMMISSIONER THE COMMISSION Date: ` 0 Form 10-403 Revised 0~005`~~` ~ ~ [ t ~ Submit in Dupl~ to • 1 J-154 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska .Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-154. This well was pre-produced fora 52 day period in order to recover Solids Free Oil based drilling fluids prior to putting the well on injection. Lateral 1J-154 will provide pressure support for the West Sak A sands. The 10-3/4" Surface casing (2300' and / 2199' tvd) was cemented with 470 sx AS Lite followed by 149 sx DeepCrete. The 7-5/8" Intermediate casing (5165' and / 3628' tvd) was cemented with 360 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer D- Lateral Hook Hanger LEM w/isolation Seal Bore located @ 4071' and / 3448' tvd. This well also contains a Lower A sand 5-1/2" x 7-5/8" ZXP Liner Top Packer w / HRD located @ 4464' and / 3529' tvd. The top of West Sak D sand was found at 4107'md / 3454' tvd. The top of West Sak B sand was found at 4406'md / 3517' tvd. The top of West Sak A sand was found at 5412'md / 3661' tvd. ~d~-~~~ v~~~ • r`~ C:~i.A2dICAL INTEGRITY REPORT ~~,~ °UD U'.:= : - ~~~-g(`j j` -~ OPER ~ FIELD C~I--~-~ \` ~~ :.~G ~S~C~..S. ~ ~~~-~t;--GS i.~LL NiJMBF.R ' ;~ 1~~~ - `-•~~. '\_~. n ~ LL DAT ~_ TD : 4Gb~~.?-~.. ~(,~~ TVD ; ? BTD : ?-ID TVD Casing : "l_~ Shoe : ~~16~ MD ~_TVD ; liV : ~(~,,.. ?~ ~ ~. T~~i _..,e.. S~o~cc~ Shoe . 'TD T`~ ; ~'CP . ?•ID 'iD -moo"~ ~.S Packer ~ TVD; Set et o l e S =c e ,~ ~ and ; P e Y~ s L ~ ~.~.~-~ ~ c~ ~. y O'l- ~. l.. ~ -.i~.~c,c~, t o t•13'l ~ - '-t'#5 ~S~o~c ~ 1 ~ S ~'"~C'r'.r17~=CST, INTEGRTTY - ??1ZT #? nnulus Press Test• _~ ?5 nin ~0 min Cormoents : ~~~t+.£ <`c ~`-'l\T ~~r~~ ~ - r ~~, 'cam i ~CH_QNIC~1, 1NTEGR2-rv _ p~~?T #Z ~ ~~~~J~)~S Cement Volumes :~ A.mt. Liner ~ Q Cs~ ~ DV N ~ C~.t -JOl to cover oers ~~\ ~j~1a, < \~1~., S~~ o~_ CE~~41~ •F ~\ ~' -~~ co ~G r ~ ~ vs~•~c~ ~ - ~ ~,~ t C. 3~Za l~ S _ _: e o r e t i c a l T O C _ . ~i,.,~ir~c ~ t= ~ c. ~ ~~~ t~ rA~- Sv CSc E t®~ r~ -O~ Cement Bond Log (Yes or No) ~ES ; In AOGCC FLle_ C3L Evaluation, gone above perfs ~~~cZC ~~ ~~ '~c.~~ v~~-- -~-~~~<~0~~ Production Log: Tyve Evaluation CONCLUS?ONS: ?azt i 1 . ?ar~ lz: 02/21 /06 Sehlumber~er Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~B ~ 2 ~~9~ ,.~, 1u~„~. ;,vH1tI1t851~;t :~:~~"~ Log Description NO. 3691 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL Kuparuk Color CD 16-17 /94-045 11216283 SBHP SURVEY 02/18/06 1 1E-36 /98-0?/ 11216282 SBHP SURVEY 02/18/06 1 3H-07 / - 11217023 LDL 02/11/06 1 3H-07 ~~ ~~ 11166757 STATIC SURVEY 01120106 1 2A-09 / 11154126 PRODUCTION PROFILE 02/09/06 'I 1A-10 / - 11213710 INJECTION PROFILE 02/08/06 1 2M-14 - 11154127 INJECTION PROFILE 02/10!06 1 1 E-05 / - 11166747 PRODUCTION PROFILE W/DEFT 12/25/05 1 2H-12 / 5- (p 11154128 PRODUCTION PROFILE W/DEFT 02/11/06 1 1C-21 11154131 PRODUCTION PROFILE W/DEFT/GHOST 02/14/06 1 3G-18 GjQ- 11154129 PRODUCTION PROFILE W/DEFT 02/12/06 1 1 E-119 11217025 INJECTION PROFILE 02/13/06 1 2U-13 g4-a 11166753 PRODUCTION PROFILE 01/14!06 1 1Y-09 /g - 11213128 INJECTION PROFILE 02106106 1 1E-105 11162832 MEMORY INJECTION PROFILE 01/28/06 1 2C-08 /g -(~j 11141255 INJECTION PROFILE 01/28/06 1 2C-02 / - 11213129 INJECTION PROFILE 02/07/06 1 1C-25 /q~j-03 11144074 GLS 02/02/06 1 2C-14 / - /Q 11166759 PRODUCTION PROFILE 01/25/06 1 2C-10 / g- 11144067 PRODUCTION PROFILE 01126/06 1 1A-18 / - 11144070 PRODUCTION PROFILE 01/29/06 1 2C-01 /83-~ 11213709 INJECTION PROFILE 02/07/06 1 1D-32 y 11141252 LEAK DETECTION LOG 01/25/06 1 2C-12 / Q-~~ 11141260 PRODUCTION PROFILE 02/02/06 1 2C-15 /g~j - 6 11141254 PRODUCTION PROFILE 01/27/06 1 1J-154 05-6 N/A PRODUCTION LOG W/TRACTOR 02/05/06 1 1E-104 11217024 INJECTION PROFILE 02/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~/~~~J • ConocoPhillips December 29, 2005 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Jaw o g zoo6 Commissioner State of Alaska laiska Oil & Gas Cons. Commission Alaska Oil & Gas Conservation Commission Anchorage 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-154, 1 J-154L1 and 1 J-154L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-154, 1J-154L1, 1J-154L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincer I , r-- ~~ ~-~ ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~1~~~ JAN 0 ~ 2006 WELL COMPLETION OR RECOMPLETtON REPORa~~~b+~@c~Q~_ [",nrnn,;ce;nn 1a. Well Status: Oil O Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Al1C~ttIP$ ~ Development a Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 30, 2005 ~ 12. Permit to Drill Number: 205-035 / ~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 30, 2005 ~ 13. API Number: ~ 50-029-23254-00 4a. Location of Well (Governmental Section): Surface: 2133' FSL, 2569' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: October 10, 2005 ' 14. Well Name and Number: 1J-154 At Top Productive Horizon: 290' FSL, 2180' FWL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB / 108' AMSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 1861' FSL, 2179' FWL, Sec. 2, T10N, R10E, UM 9. Plug Beck Depth (MD + ND): 9x63 MD / 3643' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): ` 1~,bd Surface: x- 558640 ' y- 5945944 ' Zone- 4 10. Tota~Depth (M + ND): ~~' 3 ' MD / 3643' TVD ~ 16. Property Designation: ~ ~ ADL 25661 & 25662 TPI: x- 558125 y- 5944097 Zone- 4 Total Depth: x- 558157 ~ - 5940389 Zone- 4 11. Depth where SSSV set: Camco nipple @ 490' 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes 0 No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1582' MD 21. Logs Run: GR/Res, CBL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 169 sx ASI 10.75" 45.5# L-80 28' 2300' 28' 2201' 13.5" 47o sx AS Lite, 149 sx DeepCrete 7-5/8" 29.7# L-80 28' 5165' 28' 3649' 9-7/8" 360 sx DeepCrete 4.5" 12.6# L-80 4516' 8126' 3539' 3627' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 4048' 4464'/8080' slotted liner: 5412'-6124', 6433'-6869', 7054'-7486', 7825'-8071' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 25, 2005 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1J-154L1 and 1J-154L2 Date of Test 12/28/2005 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1121 GAS-MCF 974 WATER-BBL 1 CHOKE SIZE 53 Bean GAS-OIL RATIO 869 Flow Tubing press. 319 ps Casing Pressure 1180 Calculated 24-Hour Rate -> OIL-BBL 2241 GAS-MCF 1948 WATER-BBL 3 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". - NONE ~ ~~~ Q~~N ~ 2DOG b~ r Form 10-407 Revised 12/2003 ~ ~ ~ ~ CONTINUED ON REVERSE GI~AL G i 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-154 Top West Sak A2 5351' 3659' Base West Sak A2 9063' 3643' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name and Tomas Title: Greater Kuoaruk Area Drilling Team Leader ~ , F 6 Signature Phone Date ~j r'"-- Prepared by Sharon Allsup-Drake --~~~ ~~it. G~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • ConocoPhillips Alaska Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 1 J-154 1J-154 ROT -DRILLING n 1334@ppco. com Doyon 141 Date From - To Hours Code Coe Phase 9/27/2005 00:00 - 03:00 3.00 MOVE 03:00 - 04:30 1.50 MOVE 04:30 - 05:00 0.50 MOVE 05:00 - 07:00 2.00 MOVE 07:00 - 08:00 1.00 MOVE 08:00 - 11:30 3.50 MOVE 9/30/2005 00:00 - 01:00 1.00 RIGM 01:00 - 02:30 1.50 WELC 02:30 - 04:00 1.50 DRILL 04:00 - 08:00 4.00 DRILL 08:00 - 09:00 1.00 DRILL 09:00 - 09:45 0.75 WELC 09:45 - 11:00 1.25 DRILL 11:00 - 12:00 1.00 DRILL 12:00 - 12:45 0.75 DRILL 12:45 - 14:30 1.75 DRILL 14:30 - 15:30 1.00 DRILL 15:30 - 15:45 0.25 DRILL 15:45 - 17:45 2.00 DRILL 17:45 - 21:00 3.25 DRILL 21:00 - 21:30 0.50 DRILL 21:30 - 22:30 1.00 DRILL 22:30 - 23:00 0.50 DRILL 23:00 - 00:00 1.00 DRILL 10/1/2005 00:00 - 12:00 12.00 DRILL 12:00 - 19:30 I 7.501 DRILL Start: 9/30/2005 Rig Release: 10/30/2005 Rig Number: Page 1 of 21 Spud Date: 9/30/2005 End: 10/31 /2005 Group: Description of Operations DMOB MOVE Disconnected service loops between complex's and .blow down lines MOVE MOVE Moved rigs complex's off well and spotted on pad, moved off boilers, motors, pumps, pits and pipe sheds MOVE MOVE Moved sub base off well 1J-168 OTHR MOVE Removed steering arm and bracket aloud with spare tire on side of sub base, had to remove to set sub over well due to close proximity of well 1 J-09 POSN MOVE Spotted sub base on well 1J-154 MOVE MOVE Set in rigs complex's and connected service loops, set rock washer by rig for maintenance and fin rigging up. NOTE: Rig off highline at 00:30 hrs and back on highline at 11:30 hrs Turnkey inline move. ****Special Note**" The Rig will now go on Summer Maintanace T RSRV SURFAC Slip and cut 65' of drilling line. NOTE: Accepted rig at 00:01 hrs 9/30/2005 T NUND SURFAC Installed riser and hydraulic control lines to diverter, MU turnbuckles and knife valve OTHR SURFAC Loaded pipe shed with BHA and 5" DP and strapped same PULD SURFAC PU and stood back out of pipe shed 10 stds of 5" HWDP and jars then 15 stds of 5" DP PULD SURFAC PU 13 1/2" BHA tools to rig floor BOPE SURFAC Function tested diverter and Kommey unit, test witnessed by John Crisp with AOGCC, added 1 more jt of 16" diverter line to clear flow line manifold (105' total length) PULD SURFAC MU 13 1/2" bit #1 on 8" motor with 1.5 deg bend and 1 std HWDP, RIH and tagged fill inside conductor at 97' OTHR SURFAC Flooded conductor checking for leaks and ck ok, pressure tested standpipe and manifold to 3,000 psi DRLG SURFAC Cleaned out conductor from 97' to 108', spudded well and drilled 13 1/2" hole from 108' to 144'. ADT .76 hrs when flowline plugged off OTHR SURFAC Took apart flowline and unplugged same, loaded with large pieces of cement and gravel DRLG SURFAC Drilled 13 1/2" hole from 144' to 219', ADT 1.08 hrs TRIP SURFAC POOH from 219' to 38' PULD SURFAC MU 13 1/2" BHA #1 with 8" MWD and UBHO sub, oriented and uploaded MWD, RIH with NMFDC's to 219', RU Gyro DRLG SURFAC Drilled 13 1/2" hole from 219' to 495' (276') ADT 2.4 hrs SURV SURFAC Ran surface read out gyro at 495', (determined rig team had left out 1 NMFDC out of BHA) TRIP SURFAC POOH from 495' to 133', PU additional NMFDC and RIH to 495' DRLG SURFAC Drilled 13 1/2" hole from 495' to 525' (30') ADT .3 hrs, drilled with 8-12K wob, 60-80 rpm's, 130 spm, 550 gpm at 1,050 psi, off btm torque 1 K ft-Ibs, on btm 1.5K ft-Ibs, rot wt 62K, up wt 60K, do wt 64K SURV SURFAC Ran surface read out gyro's at 444', 344', 244', 144' and 50' DRLG SURFAC Directionally drilled 13 1!2" hole per directional plan from 525' to 1,458' MDl1,427' TVD (933') ART 2.94 hrs, AST 4.45 hrs, 15-25K wob, 80 rpm's, 144 spm, 610 gpm, off btm pressure 1,600 psi, on btm 1,800 psi, off btm torque 2K ft-Ibs, on btm 3.5K ft-Ibs, rot wt 95K, up wt 93K, do wt 93K. NOTE: Took gyro survey's at 617', 709' and 801', took 85 minutes to gyro including RD DRLG SURFAC I Directionally drilled 13 1/2" hole per directional plan from 1,458' to N T ~ 2,302' MD/2,201' TVD (844') (10 3/4" Csg Pt.) ART 2.07 hrs, AST 2.95 Printed: 12/92005 3:20:17 PM • ConocoPhillips Alaska Page 2 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1 J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 1 013 012 0 0 5 Group: Rig Number: Description of Operations 10/1/2005 12:00 - 19:30 7.50 DRILL DRLG SURFAC hrs, 4-20K wob, 80-85 rpm's, while sliding would pump at 147 spm, 625 gpm, off btm pressure 1,650 psi, on btm 1,900 psi, while rotating would increase pump rate to 650 gpm at 2,000 psi, off btm torque 2.5K ft-Ibs, on btm 4K ft-Ibs, rot wt 106K, up wt 110K, do wt 102K. No gas hydrates seen on surface hole. 19:30 - 20:15 0.75 DRILL CIRC SURFAC Pumped weighted hi vis sweep and circ out of hole, had 15-20% increase in cuttings back from sweep, circ at 155 spm, 650 gpm at 1,825 psi and 85 rpm's 20:15 - 22:45 2.50 DRILL REAM SURFAC Backreamed out of hole from 2,302' to HWDP at 1,070', BROOH at 85 1 rpm's, 155 spm, 650 gpm at 1,825 psi, pumped out of hole 3 stds of HWDP to 795' at 530 gpm at 1,200 psi, no problems BROOH 22:45 - 00:00 1.25 DRILL TRIP SURFAC Cont to POOH standing back remaining 7 stds of HWDP and jars, POOH to BHA and NMFDC's at 163' 10/2/2005 00:00 - 01:45 1.75 DRILL PULD SURFAC Cont. POOH from 163' LD BHA #1, LD 3-NMFDC's, MWD and motor, cleared rig floor 01:45 - 03:15 1.50 CASE RURD SURFAC RU Doyon's 10 3/4" csg equipment with Franks fill up tool and changed out elevator bales 03:15 - 03:30 0.25 CASE SFTY SURFAC. Held PJSM with rig crew and discussed running order and hazards, also discussed operation with new hands and people working in new positions 03:30 - 08:00 4.50 CASE RUNC SURFAC Ran 10 3/4" csg 2,300' per well plan, MU 10 3i4 Weatherford Model 303 float shoe, 2 joints 45.5#, L-80, BTC csg and Weatherford model 402 FC, (1) joint 45.5#, L-80, BTC casing, baker locked btm 3 conn. and pumped thru checking float equipment, cont RIH with 10 3/4" csg and tagged btm at 2,302', RIH with an add 55 jts (58 total) of 10 3/4", 45.5#, L-80, BTC csg, Total ran 2,309', ran 17 bow spring centralizers on 1st 17 jts. No problems RIH, st wt up 130K, down wt 103K 08:00 - 09:00 1.00 CEMEN CIRC SURFAC Circ btms up thru Franks fill up tool while conditioning mud for cementing, reciprocated pipe 35' and staged pump rate up to 4 bpm at 200 psi 09:00 - 09:30 0.50 CEMEN RURD SURFAC RD Franks fill up tool and MU Dowell cement head 09:30 - 11:00 1.50 CEMENT CIRC SURFAC Fin circ and cond mud for cementing, staged pump rate up to 6.5 bpm at 380 psi, reciprocating pipe 35' with 160K up wt and 105K do wt, circ and cond mud to 9.2 ppg and lowered PV to 13 and YP to 5, held PJSM on cement job with Dowell, ASRC and rig crew while circ and cond mud. 11:00 - 13:15 2.25 CEMENT PUMP SURFAC Turned over to Dowell and cemented 10 3/4" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 370.5 bbls (470 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6 bpm at 110 psi, followed with 66 bbls (149 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 5.5 bpm at 180 psi, reciprocated csg and had full returns, shut down and dropped top plug and Dowell pumped 5 bbls fresh water then turned over to rig. 13:15 - 14:00 0.75 CEMENT DISP SURFAC Rig displaced cement with 206.5 bbls (2045 stks) of 9.2 ppg mud, ~ displaced cmt at 6.5 bpm, initial circ pressure 350 psi, max pressure ! 640 psi, slowed rate to 3 bpm and bumped plug on talc displacement, I pressured up to 1000 psi, held 5 min, checked floats and held, CIP I 14:03 hrs, had full returns during job and had 46.5 bbls of 10.7+ ppg cmt back to surface, reciprocated csg throught job, st wt up 140K, do ~ ; wt 100K, cont to tag btm at 2,302' while reciprocating pipe and PU and Printed: 72/92005 3:20:17 NM C, ConocoPhillips Alaska Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To 1J-154 1J-154 ROT -D n1334@ Doyon 1 Hours RILLIN ppco.co 41 Code G m Sub Code hase 10/2/2005 13:15 - 14:00 0.75 CEMEN> f DISP SURFAC 14:00 - 14:30 0.50 CEMEN RURD SURFAC 14:30 - 16:15 1.75 WELCT NUND SURFAC 16:15 - 17:00 0.75 WELCT EORP SURFAC 17:00 - 18:30 1.50 WELCT NUND SURFAC 18:30 - 21:00 2.50 WELCT EORP SURFAC 21:00 - 00:00 3.00 RIGMNT RSRV SURFAC 10/3/2005 00:00 - 04:15 4.25 WELCT EORP SURFAC 04:15 - 04:30 0.25 WELCT OTHR SURFAC 04:30 - 05:45 1.25 WELCT NUND SURFAC 05:45 - 08:30 2.75 WELCT NUND SURFAC 08:30 - 16:15 7.75 WELCT ROPE SURFAC 16:15 - 16:30 0.25 DRILL PULD SURFAC 16:30 - 16:45 0.25 DRILL PULD SURFAC 16:45 - 17:15 0.50 RIGMNT RSRV SURFAC 17:15 - 20:15 3.00 DRILL PULD SURFAC 20:15 - 21:00 0.75 DRILL OTHR SURFAC 21:00 - 21:45 0.75 DRILL PULD SURFAC 21:45 - 23:00 1.25 DRILL TRIP SURFAC 23:00 - 23:45 0.75 DRILL CIRC SURFAC 23:45 - 00:00 0.25 CASE RURD SURFAC 10/4/2005 00:00 - 01:00 1.00 CASE DEOT SURFAC 01:00 - 02:00 1.00 CEMEN DSHO SURFAC 02:00 - 02:45 0.75 DRILL CIRC SURFAC 02:45 - 03:45. 1.00 DRILL LOT SURFAC 03:45 - 12:00 8.25 DRILL DRLG INTRM1 12:00 - 18:45 6.75 I DRILL ~ DRLG i I INTRMT Start: 9/30/2005 Rig Release: 10/30/2005 Rig Number: Page 3 of 21 Spud. Date: 9/30/2005 End: 10/31 /2005 Group:. Description of Operations landed csg with float shoe at 2,300' and float collar at 2,217' RD Dowell cement head and csg slips Flushed out diverter and flowline, ND diverter and knife valve, PU on diverter PU on csg to 150K and set 10 3/4" emergecy slips with 50K aver final down wt, made rough cut on csg and set diverter back down, LD landing jt and RD csg elevators and bales ND riser, diverter mud cross and conductor mud cross and set out diverter Made final cut on 10 3/4" csg and welded on Vetca Gray 11" x 5M wellhead adapter flange While waiting on welhead to cool down, installed Totco's revolution counter for K-revs onto top drive and iron roughneck extensions, RU mousehole to PU 5" DP PU 35 stds of 5" DP while waiting on 11" x 5M adapter flange to cool down Tested weld on adapter flange to 2,000 psi for 10 min and ck ok (80% of collapse) Oriented and NU Vetco Gray 11" x 5" MB 228 wellhead, tested seals to 5,000 psi for 10 min, good test NU 13 5/8" x 5M BOP stack to 13 5/8" x 11" 5M adapter spool, had to adjust bell nipp{e RU and tested BOPE, tested rams, valves, manifold and annular to 250 psi low and 3,000 psi high, tested rams with 4" and 5" DP along with 7 5/8" csg test jts. NOTE: John Crisp W/AOGCC witnessed test Installed wear bushing PU and stood back 3 additional stds of 5" DP Leveled sub base MU 9 7!8" BHA #2 RIH to 171, MU 9 718" bit #2 on 6 314" motor with 1.5 deg bend, oriented MWD and uploaded same, RIH with 2 NMFDC's and shallow tested MWD, did not get a signal Trouble shoot MWD signal, found problem in computer, tool ck'd ok Fin MU BHA #2 RIH to 567', MU 1 add. NMFDC, loaded radioactive sources and RIH with HWDP and jars RIH with BHA #2 from 56T to 2,210' (above Flt Collar @ 2,21 T) Circ hole for casing test evening MW irr and out at 9.4 ppg, circ at 550 gpm at 1,275 psi, 25 rpm's, 4-6Kft-Ibs off btm torque, rot wt 90K, up wt 98K, do wt 85K RU to test 10 3/4" csg Tested 10 3/4" csg to 3,000 psi for 30 min, good test Drilled out float collar at 2,217', shoe track and float shoe at 2,300', cleaned out to TD at 2,302', drilled 20' of new formation to 2,322', drilled out at 10-12K wob, 30 rpm's, 454 gpm at 1,100 psi, rot wt 90K, up wt 98K, do wt 85K Displaced out spud mud with re-conditioned 9.0 ppg mud, evened MW in and out at 9.0 ppg, circ hole at 454 gpm at 1,100 psi RU and performed LOT to 14.7 ppg EMW, 650 psi at 2,201' TVD with 9.0 ppg MW Directionally Drilled 9 7/8"hole from 2,322' to 3,126' MD/2,976' TVD, (804'), ART 1.99 hrs, AST 3.72 hrs, 4-17K wob, 70-75 rpm's, 141 spm, 598 gpm, off btm pressure 1,600 psi, on btm pressure 1,700 psi, off btm torque 2-6K ft-Ibs, on btm 4-5K, rot wt 107K, up wt 117K, do wt 96K Directionally drilled 9 7/8" hole from. 3,126' to 3,816' MD/ 3,384' TVD, Printed: 12/9/2005 3:20:17 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/4/2005 12:00 - 18:45 6.75 DRILL DRLG INTRM1 18:45 -19:15 0.50 RIGMNT RSRV INTRM1 19:15 - 00:00 ~ 4.751 DRILL ~ DRLG INTRM1 10/5/2005 100:00 - 12:00 12.00 I DRILL I DRLG INTRM1 12:00 - 14:45 J 2.751 DRILL DRLG I INTRMI 14:45 - 16:30 I 1.751 DRILL I CIRC INTRM1 16:30 - 18:30 2.001 DRILL REAM INTRM1 18:30 - 19:00 0.501 DRILL ~ CIRC INTRM1 19:00 - 20:45 I 1.75 I DRILL I REAM I INTRM1 20:45 - 22:15 1.501 DRILL CIRC INTRM1 22:15 - 00:00 I 1.751 DRILL I TRIP I LNTRMI 110/6/2005 100:00 - 00:45 I 0.751 DRILL I PULD I INTRM1 00:45 - 01:15 I 0.501 DRILL- i PULD I INTRMI 01:15- 02:45 1.50 DRILL I PULD INTRM1 02:45 - 04:15 1.50 DRILL PULD INTRMI 04:15 - 04:30 0.25 DRILL PULD INTRM1 04:30 - 05:45 1.25 CASE ~ RURD INTRMI 05:45 - 06:00 0.25 CASE I SFTY INTRM1 06:00 - 06:45 0.75 CASE , RUNC INTRM1 Page 4 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005. Group: Rig Number: Description of Operations (690') ART 2.37 hrs, AST 2.69 hrs. Removed turnbuckle assembly used for centering of top drive torque tube, bolt on turnbuckle was snagging top drive blower duct work Directionally Drilled 9 7/8" hole from 3,816' to 4,102' MD/3,447' TVD, (286'), ART 1.39 hrs, AST 3.28 hrs, 4-20K wob, 80 rpm's, while sliding pumped at 600 gpm and while rotating circ at 650 gpm, off btm pressure 2,050 psi, on btm pressure 2,200 psi, off btm torque 4-7K ff-Ibs, on btm 5-6K, rot wt 107K, up wt 117K, do wt 98K, ave BGG 30 units, max gas 137 units, 9.05 ppg MW, ave ECD 10.0 ppg Directionally Drilled 9 7/8" hole from 4,102' to 4,871' MD/3,604' TVD, (769'), ART 6.3 hrs, AST 3.01 hrs, 7-20K wob, 80 rpm's, 153 spm, 650 gpm, off btm pressure 2,200 psi, on btm pressure 2,300 psi, off btm torque 4-7K ft-Ibs, on btm 5-6K, rot wt 106K, up wt 120K, do wt 96K, ave BGG 75 units, max gas 501 units, 9.2 ppg MW, ave .ECD 10.2 ppg, pumped wt'd hi vis sweep at 4,102' with 10% increase in cuttings back from sweep Directionally Drilled 9 7/8" hole from 4,871' to 5,172' MD/3,651' TVD, (301'), (7 5/8" Csg Pt.) ART 1.45 hrs, AST .33 hrs, 10-20K wob, 80 rpm's, 153 spm, 650 gpm, off btm pressure 2,250 psi, on btm pressure 2,400 psi, off btm torque 3-7K ft-Ibs, on btm 5-6K, rot wt 106K, up wt 124K, do wt 96K, ave BGG 100 units, max gas 433 units, 9.3 ppg MW, ave ECD 10.4 ppg Pumped weighted hi vis sweep and circ hole clean while geologist evaluated logs, geologist and town ok'd 5,172' as 7 5/8" csg pt. circ hole at 650 gpm, 2,300 psi, 80 rpm's with 4-5K ff-Ibs off btm torque, had no increase in cuttings back from sweep and circ a total of 3x btms up Monitored well-static, backreamed out of hole from 5,172' to 3,915', pumped weighted hi vis sweep on last std, BROOH at 80 rpm's, 153 spm, 650 gpm 2,250 psi Fin circ out sweep and had 100% increase in cuttings back from sweep, decided to cont BROOH to 10 3/4" csg shoe Cont to BROOH from 3,915' to inside 10 3/4" shoe to 2,285', BROOH at 80 rpm's, 650 gpm at 1,850 psi, BROOH of 20-25'/min at 35-40'/min would attempt to pack-off, no other problems BROOH Pumped weighted hi vis sweep at 2,285' and circ out of hole, had 50% increase in cuttings back from sweep, mainly silver dollar sized clay patties, mixed and pumped 2nd sweep and shakers were clean, circ sweep out of hole and had a 10% increase in cuttings, circ an add. btms up and shakers were clean, circ hole at 600 gpm at 1,825 psi and 80 rpm's, rot wt 95K up wt 97K, do wt 90K, 9.3 ppg MW Monitored well-static, POOH from 2,285' wet 5 stds and hole took calc fill, pumped dry job and cunt POOH to BHA #2 at 567' POOH from 567' to 140', POOH LD 11 jts of 5" HWDP and jars,. LD 1-NMFDC Held PJSM and removed radioactive sources, POOH to 78' LD 2-NMFDC's Downloaded MWD Fin POOH from 78' LD BHA #2, MWDlLWD and motor, cleared rig floor Pulled wear bushing RU Doyon's 7 5/8" csg handling equipment with Franks fill up tool, changed oul elevator bales Held PJSM with rig crew and tong operator on running of 7 5/8" csg Ran 7 5/8" Csg to 217', MU 7 5/8" Weatherford float shoe, 2 jts 7 5/8", Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/6/2005 106:00 -06:45 06:45 - 07:45 07:45 - 10:30 10:30 - 10:45 0.75 ~ CASE 1 RUNC ~ iNTRM 1 1.00 RIGMNT RGRP INTRM1 2.75 CASE RUNC INTRM1 0.25 CASE CIRC INTRMI 10:45 - 13:45 3.OOICASE (RUNC IINTRM1 13:45 - 14:15 0:50 CEMENl `CIRC I INTRMI 14:15 -15:00 0.75 CEMEN RURD INTRM1 15:00 - 16:00 1.00 CEMEN CIRC INTRM1 16:00 - 17:00 1.00 CEMEN~ f PUMP INTRMI 17:00 - 17:45 I 0.751 CEMEN7IDISP I INTRM1 17:45 - 18:00 0.25 CEMEN RURD INTRM1 18:00 - 19:00 1.00 CASE NUND INTRM1 19:00 - 20:45 1.75 CASE OTHR INTRMI 20:45 - 21:15 0.50 CASE NUND INTRMI 21:15 - 21:30 0.25 CASE DEOT INTRM1 21:30 - 21:45 0.25 DRILL ~ PULD INTRM1 21:45 - 22:45 1.00 CMPLTN OTHR INTRM1 22:45 - 23:30 23:30 - 00:00 10/7/2005 00:00 - 06:00 0.751 CMPLTNI OTHR I INTRM1 0.50 DRILL I PULD INTRM1 6.00 DRILL PULD .INTRM1 Page 5 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 .Group: Rig Number. Description of Operations 29.7#, L-80, BTCM csg, float shoe and thread locked btm 3 conn, circ thru float equip and ck ok, RIH with 2 add jts csg to 217' and had problems with the pipe skate Repaired pipe skate, cable on traveling drum had gotten crossed Cont RIH with 7 5/8" csg from 217' to 2,278', (9 5/8" csg shoe at 2,300') Circ btms up at 2,278', circ at 5 bpm at 320 psi, st wt up 100K, do wt 86K Fin RIH with 7 5/8" csg from 2,278' and tagged btm at 5, 172', no problems RIH to btm, ran a total of 121 jts and 2-pup jts of 7 5/8", 29.7#, L-80, BTCM csg, total RIH including float equipment 5,165', ran 60 tandem rise centralizers on 1st 62 jts, 1st 3 over stops, the remaining over collars, did not run any centralizers on both window jts, st wt up 164K, do wt 102K Circ btms up thru Franks filF up tool while conditioning mud for cementing, staged pump rate up to 6.5 bpm at 525 psi, st wt up 145K, do wt 95K RD Franks fill up tool and MU Dowell's cement head Fin circ and cond mud for cementing, circ at 6.5 bpm at 375 psi, st wt up 165K, do 105K, initial MW out, 9.4 ppg, 66 vis, PV 18, YP 27, Conditioned mud to final MW of 9.05 ppg, 38 vis, 10 YP and 13 PV, Held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementing csg while circ hole Dowell pumped 5 bbls CW 100 at 8.3 ppg at rate of 4 bpm @ 230 psi, Pressure tested lines to 3,500 psi, Then pumped 35 add. bbls of CW 100 at rate of 5 bpm @ 320 psi, Pumped 40 bbls of MudPush at 10.5 'ppg at rate of 4.6 bpm @ 160 psi, Dropped btm plug then pumped ~~ 144.2 bbls, (360 sxs - 25% over caliper) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 330 psi, Reciprocated pipe with full returns. Drop top plug and Dowell kicked top plug out with 5 bbls fresh water. Rig displaced cement with 9.0 ppg OBM, Bumped plug on talc displacement after pumping 229.4 bbls OBM (Total of 234.4 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Max pressure 1050 psi, Slowed pump rate to 3 bpm (650 psi) with 10 bbls left to pump and bumped plug to 1150 psi, ck floats and held. CIP at 17:35 hrs, 10-6-05. Reciprocated pipe until 134 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 5165.00', Float Collar @ 5075', Calc TOC @ 2529', Had full returns thru out job with a trace of CW 100 back at surface. Well static after shut down. RD cement head ND Btm flange on BOP stack and lifted up same Installed 10 3/4" csg slips, set slips with 75K st wt, cut off csg and LD cut offjt and installed pack-off NU BOP stack Tested 7 5/8" pack-offto 3,500 psi for 10 min, good test Installed wear bushing RU on 10 3/4" x 7 5/8" annulus and performed Infectivity test /LOT to 13.8 ppg EMW, assuming 9.0 ppg MW at 2,201' ND and 550 psi Began to flush 10 3/4" x 7 5/8" annulus, pumped 40 bbls water, ave 1 bpm at 850 psi Held PJSM and began LD 5" HWDP derrick LD 6 stds of HWDP and 53 stds of 5" DP down out of derrick thru Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1 J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/7/2005 00:00 - 06:00 6.00 DRILL PULD INTRM1 06:00 -07:30 .1.50 DRILL RIRD INTRM1 07:30 - 10:15 2.75 DRILL OTHR WTRM1 10:15 - 11:30 1.25 RIGMNT RSRV INTRM1 11:30 - 12:00 0.50 WELCT BOPE INTRM1 12:00 - 12:15 0.25 DRILL SFTY INTRM1 12:15 - 17:15 5.00 DRILL PULD INTRM1 17:15 - 20:30 3.25 DRILL PULD INTRM1 20:30 - 00:00 3.50 DRILL PULD INTRMI 10/8/2005 00:00 - 01:30 1.50 DRILL PULD INTRM1 01:30 - 02:00 0.50 DRILL PULD INTRMI 02:00 - 05:30 3.50 DRILL PULD INTRM1 05:30 - 09:45 4.25 DRILL TRIP INTRM1 09:45 - 10:15 -0.50 DRILL CIRC INTRM1 10:15 - 12:00 1.75 CASE DEOT INTRM1 12:00 - 14:30 2.50 CEMEN DSHO INTRM1 14:30 - 15:00 0.50 DRILL CIRC INTRMI 15:00 - 15:30 0.50 DRILL LOT INTRMI 15:30 - 00:00 8.50 DRILL DRLG PROD 10/9/2005 00:00 - 12:00 12.00 DRILL DRLG PROD .12:00 - 00:00 12.00 DRILL DRLG I PROD Start: .9/30/2005 Rig Release: 1 013 012 0 0 5 Rig Number: Page 6 of 21 Spud Date: 9/30/2005 End: 10/31 /2005 Group: Description of Operations mousehole , at 01:45 hrs, 2 hrs from initial 40 bbl water flush, pumped an additional 10 bbls of water down 10 3/4" x 7 5/8" annulus at 1.5 bpm at 850 psi RU Sperry Sun's Geo-Span unit on rig floor, At 06:15 hrs (12.75 hrs after bumping plug) finished flushing annulus with 100 bbls of water, ave 2 bpm, max pressure 900 psi, ave 825 psi, flushed annulus with 154 bbls water total Changed over top drive saver sub to 4" XT-39 Slip and cut 38' of drilling line, serviced top drive and drawworks Tested 4" floor valve and dart valve to 250 psi low and 3,000 psi high, 1st dart valve test failed, tested back-up dart valve and tested ok Held PJSM on PU DP and installing Lo-Tads RIH with 90 jts of 4" DP, POOH installing 30 Lo-tads. At 13:30 RU little Red on 10 3/4" x 7 5/8" annulus and freeze protected same with,80 bbls , diesel, ave 1 bpm at 1,050 psi. Strapped and stood back 6 stds of hybrid push pipe with 2-4 3/4" Dc's and 1 HWDP on top, then PU and stood back 7 stds of 4" HWDP PU out of pipe shed 138 jts of 4" DP and RIH, preparing to POOH & stand back same POOH and stood back 46 stds of 4" DP PU 6 3/4" BHA to rig floor MU 6 3/4" BHA #3 and RIH to 369', MU 6 3/4" bit #3 with 4 3/4" model 5200 Geo-pilot and MWD, uploaded MWD and RIH PU 3-NMFDC's, '.HWDP and jars, shallow tested MWD and broke in Geo-pilot RIH with BHA #3 from 369' PU 4" DP, PU 147 jts of DP RIH to 5,034' Circ btms up at 5,034', circ at 327 gpm at 2,800 psi, st wt up 96K, do wt 73K RU and tested 7 5/8" csg to 3,000 psi for 30 min, pressure bled down 130 psi in 30 min, bled off pressure and re-pressured up to 3,050 psi and held for 15 min and held ok Drilled out float collar at 5,075', shoe track and float collar at 5,165', cleaned out to TD at 5,172' then drilled 20' of new formation to 5,192', drilled out at 2-10K wob, 90 rpm's, 70 spm, 248 gpm, 1,850 psi Circ btms up for LOT, circ at 320 gpm at 2,900 psi, 90 rpm's and 4K ft-Ibs torque, rot wt 85K, up wt 97K, do wt 72K, 8.9 ppg MOBM MW in & out with 10.0 ppg clean hole ECD Performed LOT to 13.6 ppg EMW, 900 psi at 3,649' TVD with 8.9 ppg. MOBM Directionally drilled 6 3/4".hole in A2 sand lateral with Geo-pilot assembly from 5,192' to 5,769' MD/3,652' TVD (577') ART 6.29 hrs, 4-10K wob, 120 rpm's, 84 spm, 300 gpm, off btm pressure 2,500 psi, on btm 2,600 psi, off btm torque 4K ft-Ibs, on btm 4K ft-Ibs, rot wt 82K up wt 97K, do wt 68K, 8.95 ppg MOBM, ave ECD 9.9 ppg, ave BGG 25 units, max gas 66 units, drilled thru 8 concretions for a total of 50' in length Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 5,769' to 7,043' MD/3,636' TVD (1,274') ADT 8.59 hrs, 5-15K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,000 psi, on btm 3,050 psi, off btm torque 4.5K ft-Ibs, on btm 5K ft-Ibs, rot wt 81 K up wt 108K, do wt 62K, 9.0 ppg MOBM, ave ECD 10.6 ppg, ave BGG 25 units, max gas 118 units, drilled thru 10 concretions for a total of 80' in length Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot Printetl: 1L92005 320:1 ~ F'M L~ ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-1.54 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/9/2005 ~ 12:00 - 00:00 ~ 12.00 ~ DRILL ~ DRLG ~ PROD 110/10/2005 100:00 - 07:00 I 7.00 I DRILL I DRLG I PROD 07:00 - 07:30 0.50 DRILL CIRC PROD 07:30 - 08:00 0.50 DRILL ~ DRLG PROD 08:00 - 09:30 1.50 DRILL CIRC PROD 09:30 - 15:00 5.501 DRILL REAM ~ PROD 15:00 - 16:00 I 1.001 DRILL I CIRC I PROD 16:00 - 18:00 2.00 DRILL TRIP PROD 18:00 - 19:30 1.50 DRILL CIRC PROD 19:30 - 20:15 0.751 DRILL {CIRC I PROD 20:15 - 00:00 3.75 DRILL TRIP PROD 10/11/2005 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 01:00 0.50 DRILL PULD PROD 01:00 - 02:00 1.00 DRILL PULD I PROD 02:00 - 03:00 1.00 DRILL PULD .,PROD 03:00 - 03:30 0.50 DRILL 'PULD CMPLTN 03:30 - 03:45 0.25 LOG SFTY CMPLTN Page 7 of 21 Spud Date: 9/30/2005 Start: 9/30/2005. End:. 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations assembly from 7,043' to 8,321' MD/3,635' TVD (1,278') ADT 8.46 hrs, 4-10K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,125 psi, on btm 3,150 psi, off btm torque 5.5K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 80K up wt 110K, do wt 54K, 9,0 ppg MOBM, ave ECD 11.15 ppg, ave BGG 30 units, max gas 97 units, pumped weighted hi vis sweeps at 7,650' with a 50% increase in cuttings and 7,837' with 25% increase in cuttings Directionally drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 8,321' to 8,997' MD/3,642' TVD (671') ADT 5.12 hrs, 5-12K wob, 130 rpm's, 93 spm, 330 gpm, off btm pressure 3,150 psi, on btm 3,200 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 82K up wt 120K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.25 ppg, ave BGG 30 units, max gas 76 units, pumped weighted hi vis sweep at 8,415' with a 10°!o increase in cuttings Trouble shoot problem. with MWD computer, reboot same and ck ok Directionally drilled 6 3/4" hole from 8,997' to 9,063' MD/3,643' TVD (66') ADT .36 hrs, determined to have crossed fault at 8,370' and zone below fault was wet, decision was made to stop drilling on A2 lateral Pumped 35 bbl weighted hi vis sweep and circ out of hole, circ at 330 gpm, 3,200 psi and 130 rpm's, rot wt 83K up wt 120K, do wt 55K, monitored well-static Backreamed out of hole from 9,063' to to 5,130' (7 5/8" shoe @ 5,165') BROOH at 130 rpm's, 330 gpm, initial circ pressure 3,200 psi, final circ pressure 2,800 psi, no problems BROOH to 5,130' rot wt 83K, up wt 110K, do wt 60K Pumped 35 bbl weighted hi vis sweep and circ hole clean at 5,130', had 5% increase in cuttings back from sweep, circ at 330 gpm, 2,550 psi and 130 rpm's with 3.5K ft-Ibs torque, circ 3X btms up and was clean at shakers, monitored well-static ~! RIH from 5,103' to 9,000', washed 63' to btm at 9,063' with no problems Pumped weighted hi vis sweep and circ out of hole, had no increase in cuttings back from sweep and was clean at shakers, circ at 330 gpm, 3,200 psi, 130 rpm's with 5.5K ft-Ibs torque Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 330 gpm at 3,350 psi, 130 rpm's and 5.5K ft-Ibs torque, rot wt 85K, up wt 117K, do wt 57K gpm, monitored well-static POOH wet from 9,063' to 1,768', POOH 5 stds and hole took talc fill, dropped 1 7/8" rabbit on a wire and cont POOH to 1,768' Continue POOH from 1768' - 368' (1400'). POOH, breakout & lay down BHA. Rack Back HWDP with Jars and NMDC's. Download MWD assembly. Continue lay down 6 3i4" PDC Security FSF2641 bit w! .5591 restrictor (1.26') TFA = 1.015 Sq In, 4 3/4" 5200 Geo-Pilot (16.20'), GP Non-Mag Flex Pony Collar (11.54'), DM Collar (8.56'), 4 3/4" Smart Stabilizer 3.59'), 4 3/4" Slimphase 4 with DGR & EWR Phase (24.16'), PWD collar (10.76'), TM HOC (11.12'), Non-Mag Float sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'), 3 -Non Mag Flex drill collars (92.76'), Crossover sub (1.07'), 2 -stands of 4" HWDP with jars (180.27'). Bit Gauged at 1 /1 /CT/G/011/EC/TD Clean Floor area, and lay down tools at beaver slide. Held PJSM with crew and Schlumberger hands. Discuss Safety and wireline PU/LD procedures. Printed: 12/9/2005 3:20:17 PM • 0.50 LOG I ELOG I CMPLTN ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1 J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/11 /2005 03:45 - 06:00 ~ 2.25 ~ LOG ~ PULD ~ CMPLTN 06:00 - 07:30 I 1.50 I LOG ; ELOG I CMPLTN 07:30 - 12:00 I 4.501 LOG I ELOG I CMPLTN 12:00 - 14:30 I 2.501 LOG I OTHR I CMPLTN 14:30 - 15:00 I 0.501 LOG I OTHR I CMPLTN 15:00 - 15:30 0.50 LOG ELOG CMPLTN 15:30 - 16:30. 1.00. LOG ELOG .CMPLTN 16:30 - 17:00 17:00 - 18:00 18:00 - 00:00 10/12/2005 00:00 - 01:00 01:00 - 01:30 0.501 LOG I ELOG I CMPLTN 1.00 LOG ELOG CMPLTN 6.00 LOG ELOG CMPLTN 1.001 LOG I ELOG (CMPLTN 0.501 LOG ELOG CMPLTN 01:30 - 02:00 02:00 - 02:45 02:45 - 03:45 03:45 - 05:00 05:00 - 06:30 06:30 - 09:15 09:15 - 11:15 11:15 - 12:00 12:00 - 15:00 15:00 - 16:00 .16:00 - 19:30 19:30 - 20:15 0.75 LOG ELOG CMPLTN 1.00 LOG ELOG CMPLTN 1.25 LOG ELOG CMPLTN 1.50 LOG ELOG CMPLTN 2.75 LOG ELOG CMPLTN 2.00 LOG ELOG CMPLTN 0.75 CASE RURD CMPLTN 3.00 CASE RUNC CMPLTN 1.001 CASE I RUNC I CMPLTN 3.50 ~ CASE ~ RUNL ~ CMPLTN • Start: 9/30/2005 Rig Release: 10/30/2005 Rig Number: Page 8 of 21 Spud Date: 9/30/2005 End: 10/31/2005 Group: Description of Operations Rig up Schlumberger wireliners, and equipment. Pull tools to rig floor and make up same. Wireline in hole with USIT bond logging tools on Welltec tractor, to 4000' where observed tractor failure. Communication through tractor failed to logging tools. Could not "start" tractor. POOH with USIT logging tools and tractor. Lay down tractor and tools, and trouble shoot problem. Note: Make a trip in to Deadhorse to retrieve test cable. Continue troubleshoot Welltec tractor problem. Suspect oil viscosity not correct and observe burnt head. Install correct oil, and change head. Make up USIT bond logging tools with Welltec tractor. Perform surface test and tools tested good. WLIH with tools and tractor to 5051'. Turn on Logging tools, all OK. Attempt to log from 5051' to 4010' (1041'), Tools failed (No log acquired). Unable to get Logging tools to work, trouble shoot and attempt to gain. communication. WLOH from 4010' to surface. Breakout and lay down tools. Change out transducer. Trouble shoot tractor. Observed wires were damaged and tractor had leaky tool wires. Rebuild tool, installing longer wires in head, install oil. Perform surface test. Continue change out transducer. Trouble shoot tractor. Observed wires were damaged and tractor had leaky tool wires. Rebuild tool, installing longer wires in head, install oil. Perform surface test. PJSM with crew: Discuss Safety and handling procedures. Pull Well Tech tractor to rig floor. MU on wireline USIT logging tools and surface test same. Good test. WLIH from surface to 1700'. Observe tool failure. No Communication through tractor. WLOH, breakout & lay down Well Tech Tractor. Prep Schlumberger Tractor. Pull tractor to floor and MU to E-Line tools. Surface test same. Good Test. WLIH to 5055' WLM. Tractor working fine. Locate & perform USIT Bon Log from 5050' - 2200' (2850'). WLOH to surface, breakout & lay down E-Line USIT logging tools. Rig up Liner running equipment, slips, power tongs etc... Make up 4 1/2"joint (30.83') blanked off on end with crossover (2:03') and Swell Packer with pups (19:55'), and crossover (2.07'). Pick up 4 1/2 slotted /blank liner assembly, RIH to 3610'. Run total of 57 blank joints, 59 slotted joints with a total of 7 constrictor packers spaced out to be at 7815', 7484', 7035', 6885', 6425', 6135', and 5415'. Make up 4 3/4" Casing Seal Bore Ext. and Crossover Bushing with pups (24.83'), Flexlock Liner Hanger 5.5" x 7.6" (9.82'), 5 112" "RS" packoff Seal Nipple (2.55'), and "HRD" ZXP Liner top Packer (19.05'), with Liner Running Tool and XO (11.04'). Add PAL mix as per BOT Rep. RIH with 4 1/2" Liner assembly on 4" DP from 3673'.- 8125' (4452') with SLM, and 1 7/8" Drift in Drill Pipe. PU WT = 120K, SO WT = 80K. 0.75 CASE RUNL CMPLTN Locate bottom of liner at 8126', drop b1 7/16" Ball, alloow to fall and pump down at 35 SPM, 375 PSI, until observed ball seated. Pressure j up to 1300 PSI, set Liner Hanger, and continue Pressure up to 4000 Printed: 12/9!2005 3:20:17 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code C~dP Phase Page 9 of 21 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations 10/12/2005 19:30 - 20:15 0.75 CASE RUNL CMPLTN 20:15 - 21:00 0.75 CASE RUNC CMPLTN 21:00 - 21:30 I 0.501 CASE I CIRC I CMPLTN 21:30 - 23:30 2.00 CASE RUNC CMPLTN 23:30 - 00:00 0.50 CASE RUNC CMPLTN 10/13/2005 00:00 - 00:30 0.50 WINDO ULD PROD2 00:30 - 03:00 2.50 WINDO ULD PROD2 03:00 - 04:00 1.00 WINDO THR PROD2 04:00 - 04:30 0.50 WINDO ULD PROD2 04:30 - 04:45 I 0.251 WINDOWOTHR I PROD2 04:45 - 07:15 I 2.501 WINDOWfRIP I PROD2 07:15 - 08:15 1.00 WINDOI/V/OTHR PROD2 08:15 -09:15 1.00 WINDOV~/SETW PROD2 09:15 - 09:45 I 0.501 WINDOVVCIRC I PROD2 09:45 - 12:00 ~ 2.251 WINDOVV/STWP I PROD2 12:00 - 14:45 2.75 ~ WINDOWSTWP ~ PROD2 14:45 - 15:45 I 1.001 WINDOWSTWP I PROD2 15:45 - 18:30 2.75 WINDOWTRIP PROD2 18:30 - 20:00 1.50 WINDOWPULD PROD2 PSI to set ZXP PKR. Observe "bobble" on weight indicator at 3500 PSI. Bleed pressure. Rig up to test. Pump down annulus to pressure test to 1000 PSI for 10 minutes. Good test. All pressures and test recorded on chart. Pull out of ZXP PKR to allow "dogs" to kick out and Slack off to verify Top of Liner at 4464' DPM. Repeat. PU WT = 105K, SO WT = 90K. Pull out of Liner assembly with setting tools and CBU at 83 SPM - 1400 PSI. Monitor well -Static. POOH from 4394' - 15'. Observe well taking proper fill. Breakout & lay down running tool. Inspect seals and breaks, all looked good as per BOT rep. Clean floor area, Pull tools to rig floor. Held PJSM. Discuss Safety and Whipstock assembly make up procedure. Make up 7 5/8" Whipstock assmy. MU 5 11/16" Sear assmy with No-Go Locator Sub (4.76'), 4.5/8" Unloader sub (5.19'), 3 - 3 1/2" IF pup joints (4.72', 6.52', 16.46'), 1 -jnt 3 1/2 DP (31.21'), Blanking sub (1.28'), 7 518" Bottom Trip Anchor (3.23'), 4 5/8" Shear Disconnect Sub (2.69'), 4 3/4" Ported drain Sub (1.47'), 4 11/16" Debris Barrier sub with cup (1.86'), & 5/8" Whipstock Slide (14.42'), 6.156" Starting Mill (1.08'), 6.30" Lower Mill (5.46'), 6 3/4" Upper Mill (5.81'), 1 - jnt 3 1/2" HWDP (29.84'), 2 - 4 3/4" Float subs (2.49', 2.14' ), 4 3/4" MWD assembly (43.43'), 2 - 4 3/4" Bumper Jars (7:85', 7.86' ), 4 3/4" Crossover. Install 35K shear Bolt on starting mill. BTA shear setting = 14K. Plug In & Upload MWD assembly. Make up remaining BHA. PU 2 -stands Hybrid Push Pipe (178.98). Total BHA = 378.5T. Screw into string with TD, and perform Shallow pulse test. Good test. 300 GPM's - 1000 PSI. Trip in hole with whipstock assembly from 378' - 3622' (3244') at 2 minutes per stand as per BOT rep. PU WT = 92K, SO WT = 82K Perform MAD PASS log from 3622' - 3822 ' (200') @ 240' FT/HR Continue TIH from 3822' - 4465' (643'). Orient Whipstock Face as per DD and Co. Rep to 10 Degrees Left of High Side. Slack off and tag Top of Liner with Seals @ 4465' DPM. Set BTA, and verify set by pulling 10K over up weight. Slack off and shear bolt @ 35K down weight. Pull to Neutral position and obtain free rotation. PU WT = 104K, SO WT = 87K, ROT WT = 82K, TO = 2-5K. Displace well from 9.0 PPG SFMOBM to 9.0 PPG MOBM @ 300 GPM's - 2100 PSI. Mill window from 4374' - 4381', @ 300 GPM's - 2100 PSI, 80 RPM's and 2-5K torque. Mud Wt = 8.9 PPG, Visc = 74 and YP = 16 Continue mill window from 4381'- 4386'. Continue mill in open hole to 4416' allowing 20' of gauged hole out of bottom of window; @ 300 GPM's - 2100 PSI, 80 RPM's and 2-5K torque. Mill 12' WINDOW IN 4.93 HRS for an avg ROP of 4.36 FT/HR Pump Hi Visc sweep @ 4416'. Circulate out while working mills through window until clean. Window {ooked good. Monitor well -static. Pump dry job. Pooh from 4416'.- 378' (4038'). Breakout & lay down Milling BHA. Lay down 6.156" Starting Mill (1.08'), 6.30" Lower Mill (5.46'), 6 3/4" Upper Mill (5.81'), 1 -jnt 3 1/2" HWDP 29.84'), 2 - 4 3/4" Float subs (2.49', 2.14' ), 4 3/4" MWD assembly 43.43'), 2 - 4 3/4" Bumper Jars (7.85', 7.86' ), 4 3/4" Crossover. Gauge Printed: 12/9/2005 3:20:17 PM • • ConocoPhillips Alaska Page 10 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Phase Code 10/13/2005 18:30 - 20:00 1.50 WINDOV ~IPULD PROD2 20:00 - 20:15 0.25 WINDO THR PROD2 20:15 - 20:45 0.50 WINDO THR PROD2 20:45 - 00:00 . 3.25 WELCT BOPE PROD2 10/14/2005 100:00 - 01:00 I 1.00 01:00 - 01:30 0:50 WELL 01:30 - 02:45 1.25 DRILL BOPE I PROD2 BOPS- PROD2 PULD PROD2 02:45 - 03:30 0.75 DRILL OTHR PROD2 03:30 - 04:30 1.00 DRILL OTHR PROD2 04:30 - 06:15 I 1.751 DRILL I TRIP I PROD2 06:15 - 06:45 I 0.501 DRILL I TRIP I PROD2 06:45 - 12:00 5.251 DRILL I DRLG I PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 I Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations Upper mlll to full gauge of 6 3!4". BOLDS and pull wear bushing. Make up stack washing tool and flush stack. Rig down same. Install test plug. Test BOP stack and all choke manifold valves, Upper & lower IBOP on TD, HCR -, Choke and Kill, Manual Choke and Kill, Dart valve and floor safety valve. Perform Accumulator function test to 3:47 Minutes. All. test 250 PSI low, 3000 PSI high. All test recorded on chart and witnessed by Co. Rep and Tool Pusher. AOGCC waived witness of test. Chuck Sheave. Continue Perform Accumulator function test to recovery of 3:47 Minutes. Test Annular, and Blind rams. All test 250 PSI low, 3000 PSI high. All test recorded on chart and witnessed by Co. Rep and Tool Pusher. AOGCC waived witness of test. Chuck Sheave. Rig Down test equipment, Install Wear Bushing, RILDS-- PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA. Pull tools to floor. Make up 6 3/4" Reed Hycalog PDC CRXE1005 Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill .Lobe 7/8 - 6.0 stage with a 1.5 degree bend in motor (32.50'), 4 3/4" Non Mag float sub (2.49'), 4 3/4" Integral Blade stabilizer (5.24'), DM HOC (8.49'), Slimphase 4 w/ DGR & RES (23.82'), PWD Collar (10.76'), TM HOC (11.12'), 3 - 4 3/4" Non Mag Flex Drill Collars 92.76'), 4 7/8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.13'), 4 3/4" Drilling jars (177.63 Hrs on 10/10/05) (28.90'), 4 - Jnts 4" HWDP 121.24'). Total BHA length = 369.32'. Plug in and upload MWD assembly. RIH & RU. Perform Shallow pulse test @ 86 SPM, 305 GPM's - 1700 PSI. Trip in hole from 369' - 4290' (3921'). Orient bit & motor to High side above top of window area @ 4374'. Work 6 3/4" Bit and drilling assembly through window area from 4374' to 4386' DPM. Observed tag at 9' down whipstock to take 8K in downweight. Pull up above window, RIH to observe little or no tag and continue in through window to open hole depth at 4400'. Suspect cement chunks on slide. Wash down from 4400' - 4416' (16'). PU WT = 91 K, SO WT = 75K. Baker rep on floor to witness Drilling assembly through whipstock. Directional drill 6 3/4" Hole from 4416' - 4508' MD (92'). TVD = 3514'. ART = 1.94 HRS, AST = 2.64 HRS, ADT = 4.58 HRS. PU WT = 93K, SO WT = 72K, ROT WT = 81 K, Torque off btm = 3K, Torque on bottom = 4K. WOB = 2-10K, RPM's = 80, Pumps @ 85 SPM, 300 GPM's - 2300 PSI. Total Jar Hrs = 182.21. Total Bit Hrs = 4.58. Clean hole ECD at 9.8 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 4400' MD, 3514' TVD. Pump #1 - 25 SPM - 420 PSI, 35 SPM - 590 PSI. Pump #2 - 25 SPM - 430 PSI, 35 SPM - 650 PSI. Observed Drilling through Concretion at 4453'.- 4501' (48'). Continue Directional drill 6 314" Hole from 4508' - 5224' MD (716'). TVD = 3516'. ART = 3.14 HRS, AST = 2.74 HRS, ADT = 5.88 HRS. PU WT = 100K, SO WT = 64K, ROT WT = 83K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-10K, RPM's = 80, Pumps @ 93 SPM, 330 GPM's - 2300 PSI. Total Jar Hrs = 188.09. Total Bit Hrs = 10.45 ECD at 9.3 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 5029' MD, 3524' TVD. Pump #1 - 20 SPM - 360 PSI, 30 SPM - 540 PSI. Pump #2 - 20 SPM - 400 PSI, 30 SPM - 560 PSI. Observed Drilling Printed: 12/9!2005 3:20:17 PM • • ConocoPhillips Alaska Page 11 of 21 Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Coe Pf~ase 10/14/2005 112:00 - 00:00 I 12.00 I DRILL I DRLG I PROD2 10!15/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:40- 00:00. 12.00 DRILL DRLG PROD2 10/16/2005 ~ 00:00 - 07:45 ~ 7.75 ~ DRILL ~ DRLG ~ PROD2 07:45 - 08:45 1.001 DRILL CIRC PROD2 08:45 - 11:15 ; 2.501 DRILL I TRIP I PROD2 11:15 - 12:00 0.751 DRILL TRIP PROD2 13:30 - 14:00 0.50 DRILL TRIP I PROD2 14:00 - 14:30 I 0.50 DRILL OTHR fi PROD2 14:30 - 16:00 ~ 1.50 DRILL PULD I PROD2 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations through Concretions at 4602' - 44614' (12'), 4618' - 4628' (10'), 4633'-4640' (7'), 5223' - 5231' (8'), 5236' - 5248' (12'), 5259' - 5268' 9'). Encountered Fault @ 4697 MD, with a 12' down throw. Continue Directional drill 6 3/4" Hole from 5224' - 6130 MD (906'). TVD = 3501'. ART = 5.65 HRS, AST = 1.94 HRS, ADT = 7.59 HRS. PU WT = 105K, SO WT = 62K, ROT WT = 80K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-1 OK, RPM's = 80, Pumps @ 93 SPM, 330 GPM's - 2800 PSI. Total Jar Hrs = 195.68. Total Bit Hrs = 18.65 ECD at 102 PPG. Mud WT = 8.9 PPG Viscosity = 77, YP = 19. SPR's @ 5968' MD, 3512' TVD. Pump #1 - 25 SPM - 420 PSI, 35 SPM - 580 PSI. Pump #2 - 25 SPM - 520 PSI, 35 SPM - 610 PSI. Observed Drilling through no Concretions this tour. Survey @ 6014' MD ,'3506 TVD -Inc = 92.8 Deg. AZ = 176 Deg. Continue Directional drill 6 3/4" Hole from 6130' -.7187 MD (105T). TVD = 3482'. ART = 6.77 HRS, AST = .47 HRS, ADT = 7.24 HRS. PU WT = 105K, SO WT = 60K, ROT WT = 83K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-5K, RPM's = 80, Pumps @ 86 SPM, 302 GPM's - 2700 PSI. Total Jar Hrs = 202.92 Total Bit Hrs = 25.29 ECD at 10.4 PPG. Mud WT = 8.9 PPG Viscosity = 67, YP = 19. SPR's @ 6949' MD, 3484' TVD. Pump #1 - 25 SPM - 450 PSI, 35 SPM - 640 PSI. Pump #2 - 25 SPM - 480 PSI, 35 SPM - 690 PSI. Observed Drilling through concretions @ 7099' - 7110' (11'). Survey @ 7043' MD 3484 TVD -Inc = 91.1 Deg. AZ = 180 Deg. Continue Directional drill 6 3/4" Hole from 7187' - 7691' MD (504'). TVD = 3472'. ART = 4.4 HRS, AST = .97 HRS, ADT = 5.37 HRS. PU WT = 106K, SO WT = 56K, ROT WT = 80K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-18K, RPM's = 80, Pumps @ 86 SPM, 302 GPM's - 2700 PSI. Total Jar Hrs = 208.29 Total Bit Hrs = 30.66 ECD at 10.4 PPG. Mud WT = 8.9 PPG Viscosity = 68, YP = 19. SPR's @ 7641' MD, 3474' TVD. Pump #1 - 25 SPM - 480 PSI, 35 SPM - 650 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 650 PSI. Observed Drilling through concretions @ 7261' - 7280' (19'),7299' - 7306' (7'), 7312' - 7319' (T), 7339' - 7348' (9'), 7354' - 7360' (6'), 7457 - 7459' (2'), 7470'- 7487 (17'), 7524' - 7528' (4'), 7639' - 7655' (16'). Survey @ 7623' MD 3474 TVD -Inc = 91.06 Deg. AZ = 180 Deg. Observed running out of down weight to Slide as per DD. Decision to POOH fo BHA change. Pump Weighted sweep @ 93 SPM, 340 GPM's, 3100 PSI while reciprocating drill string at 80 RPM's with TO @ 5K. Observed 15% increase in cuttings at shaker when sweep returned. POOH from 7691' - 4374' (3317'). Added NRP Super Sliders to Lo-Tad stands on stands # 78,77,76,75,74,73. 1 perjoint as reccomended. Pulled assembly through window area with no issues. Observed clean hole conditions while POOH and proper hole fill. Monitor well -static. Pump dry job, and blow down TD. Continue POOH to 4289'. Continue POOH from 4289' - 369' (3920') Monitor well. POOH stand back Drilling Jars, HWDP and NM Flex drill collars. Total Length = 274.10'. Plug in and down load MWD assembly. POOH, breakout & lay down remaining BHA. Layed down 4.60" TM HOC (11.12'), PWD Collar (10.76'), 4 3/4" Slimphase 4 w/ DGR & RES (23.82'), DM HOC (8.49'), 4 3!4" Integral Blade stabilizer (524'), 4 3/4" Non Mag Float sub (2:49'), 5" Sperry Drill lobe 7/8 -6.0 Stage Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 12 of 2~ Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Descripticn of Operations 10/16/2005 14:30 - 16:00 1.50 DRILL PULD PROD2 32.50), and 6 3/4" Reed Hycalog PDC CRXE1005 Bit. Gauge bit to 1 / 1 / NO /ALL / / 1/ NO ! PR NOTE: Pictures of Bit sent to Engineer 16:00 - 16:30 0.50 DRILL PULD PROD2 Clean & clear rig floor area, lay down tools. 16:30 - 18:00 1.50 DRILL PULD PROD2 PJSM with crew. Discuss Safety Issues and BHA pick up procedure. MU BHA #6. Make up 6 3!4" SDBS FAF2641Z bit w/ 3x21 jets for a TFA of 1.105 (1.26'), 4 3/4" Geo-Pilot 5200 (16.20'), 4 3/4" GP Non Mag Flex Pony Collar (11.56'), DM Collar (8.56'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR & EWR phase 4 23.82'), PWD Collar (10.76'), TM HOC (10.07'), 4 3/4" Non Mag Float Sub (2.37'), 4 3/4" Integral Blade Stabilizer (5.24'). Total = 90.28'). 18:00 - 18:30 0.50 DRILL OTHR PROD2 Plug in and down load MWD assembly. 18:30 - 19:15 0.75 DRILL PULD PROD2 Continue MU BHA #6 picking up 3-jnts Non Mag Flex Drill Collars 92.76'), Crossover sub (1.07'), 1 - jnt 4" HWDP (30.13'), 4 3/4 Drilling Jars { 28.90'), and 4 jnts 4" HWDP.( 121.24'). 19:15 - 20:00 0.75 DRILL OTHR PROD2 Perform shallow pulse test and test Geo-Pilot.:. 20:00 - 21:30 1.50 DRILL TRIP PROD2 Trip in hole from 367' - 4288' (3921'). Fill DP every 25 stands. 21:30 - 23:00 1.50 RIGMNT RSRV PROD2 PJSM, RU and Slip & Cut 72' of Drilling line. Inspect and adjust brakes on draw works. 23:00 - 00:00 1.00 DRILL TRIP PROD2 Fill Drill string and RIH from 4288' - 4611' (323'). Pump to check Geo -Pilot tools. Observed no issues with BHA assembly passing through window area from 4374' - 4386'. 10/17/2005 00:00 - 01:15 1.25 DRILL TRIP PROD2 Tag Spot @ 4611 DPM. MU Top Drive and rotate & pump through spot with no issues. Continue TIH form 4611' - 7573' (2962'), with little or no issues. 01:15 - 02:00 0.75 DRILL REAM PROD2 Wash & Ream hole from 7573' -7691' (118'), to tag bottom on depth. Pumps @ 300 GPM's, 84 SPM -2650 PSI. 80 RPM's and 5K Torque. Down Link Geo -Pilot tool. 02:00 - 12:00 10.00 DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole from 7691' - 8691' MD (1000'). TVD = 3479'. ART = 6.56 HRS, PU WT = 116K, SO WT = 50K, ROT WT = 80K, Torque off btm = 5.5K, Torque on bottom = 6K. WOB = 2-5K, RPM's = 80 - 120, Pumps @ 93 SPM, 330 GPM's - 3200 PSI. Total Jar Hrs = 213.85 Total Bit Hrs = 5.56 ECD at 11.03 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 19. SPR's @ 7765' MD, 3469' TVD. Pump #1 - 25 SPM - 470 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 470 PSI, 35 SPM - 620 PSI. Observed Drilling through concretions @ 7690' - 7702' (12'), 7712' - 7714' (2'), 7745' - 7750' (5'), 7764' - 7767' (3'), 8509' - 8514' (5'), 8526' - 8530' (5'),.8538' - 8540' 2'), 8582' - 8591' (9'), 8621' - 8624' (3'). Survey @ 8698' MD , 3482 TVD -Inc = 88.4 Deg. AZ = 182.4 Deg. Pumping weighted sweeps to control ECD and clean hole. 12:00 - 00:00 12.00 DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole from 8691' - 10081' MD (1390'). TVD = 3470'. ART = 8.01 HRS, PU WT = 120K, SO WT = 45K, ROT WT = 80K, Torque off btm = 6K, Torque on bottom = 7K. WOB = 2-5K, RPM's = 80 - 120, Pumps @ 93 SPM, 330 GPM's - 3250 PSI. Total Jar Hrs = 221.86 Total Bit Hrs = 14.57 ECD at 11.04 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 19. SPR's @ 8733' MD, 3483' TVD. Pump #1 - 25 SPM - 480 PSI, 35 SPM - 660 PSI. Pump #2 - 25 SPM - 510 i PSI, 35 SPM - 740 PSI. Observed Drilling through concretions @ 8708' - 8720' (12'), 8732' - 8741' (9'), 8768' - 8772' (4'), 8797 - 8812' (15'). Survey @ 10045' MD , 3468.5 TVD -Inc = 89.10 Deg. AZ = 183.74 Deg. Pumping weighted sweeps to control ECD and clean hole. .10/18/2005 00:00 - 08:45 ~ 8.75 DRILL DRLG PROD2 i Continue Directional drill 6 3/4" Hole from 10081' - 11285' MD (1204'). I TVD = 3455'. ART = 5.37 HRS, PU WT = 145K, SO WT = 40K, ROT rnncea: iua~~~~o sa~:v rm • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Start: 9/30/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 10/18/2005 00:00 - 08:45 8.75 DRILL DRLG PROD2 08:45 - 10:15 1.50 DRILL CIRC PROD2 10:15 - 12:00 1.75 DRILL WIPR PROD2 12:00 - 14:00 2.00 DRILL WIPR PROD2 14:00 - 15:00 1.00 DRILL CIRC PROD2 15:00 - 20:00 5.00 DRILL WIPR PROD2 20:00 - 23:30 3.50 DRILL REAM PROD2 23:30 - 00:00 0.50 DRILL CIRC PROD2 10/19/2005 00:00 - 01:30 1.50 DRILL CIRC PROD2 01:30 - 03:15 1.75 DRILL CIRC PROD2 03:15 - 12:00 8.75 DRILL TRIP PROD2 12:00 - 13:00 1.00 DRILL PULD PROD2 13:00 - 14:00 1.00 DRILL OTHR PROD2 14:00 - 15:00 1.00 DRILL ~ PULD PROD2 Page T 3 of 21 Spud Date: 9/30/2005 End: 10/31 /2005. Group: Description of Operations WT = 95K, Torque off btm = 8K, Torque on bottom = 8K. WOB = 5-10K, RPM's = 80 -120, Pumps @ 93 SPM, 330 GPM's - 3900 PSI. Total Jar Hrs = 227.23 Total Bit Hrs = 19.93 ECD at 11.55 PPG. Mud WT = 8.9 PPG Viscosity = 68, YP = 18. SPR's @ 11262' MD, 3455' TVD. Pump #1 - 25 SPM - 650 PSI, 35 SPM - 840 PSI. Pump #2 - 25 SPM - 600 PSI; 35 SPM - 820 PSI. Survey @ 11285' MD , 3455.63 TVD -Inc = 90.53 Deg. AZ = 172.41 Deg. MAX GAS = 107 Units. Pumping weighted sweeps to control ECD and clean hole. Rack Back 1 stand DP. Pump Hi Visc weighted sweep @ 92 SPM - 330 GPM - 3900 PSI, while reciprocate & rotate drill string. Observed 10% increase in cutting across shakers. Monitor well -static. POOH on elevators from 11285' - 10538' (747'). Observed Hole taking proper fill and no swabbing, hole conditions looked good with minimal drag of 5K-15K. , - Continue POOH on elevators from 10538' - 4350' (6188'). Observed Hole taking proper fill and no swabbing, hole conditions looked good with minimal drag of 5K-15K. Pull to above top of window @ 4374'. MU top Drive and Pump Hi Visc weighted sweep @ 92 SPM - 330 GPM - 3900 PSI, while reciprocate & rotate drill string. Observed 10% increase in cutting across shakers. Monitor well -static. Trip back in hole from 4350' - 9123' (4773'). Observe clean hole conditions,no hanging up issues, but ran out of down weight to continue in on elevators. MU top drive on each stand and wash & ream from 9123' - 11284' 2161') @ 2-3 minutes per stand. Observed no hole condition issues and I, string went to bottom good @ 62 SPM - 1600 PSI, 60 RPM's - 5K torque. Circulate @ 93 SPM - 4150 PSI on Pump #1. Reciprocate & rotate drill string. Rack back 1 stand. Continue circulate pumping Hi Visc weighted sweep @ 11266' working string. Continue Circulate @ 93 SPM - 4150 PSI on Pump #1. Reciprocate & rotate drill string, pumping Hi Visc weighted sweep + 1 Bottoms up @ 11266' working string. Observe 10% increase in cuttings across shakers when sweep returned. Displace well with 8.9 PPG SFMOBM @ 88 SPM -.4150 PSI. Vac truck broke down and we slowed pumps to 60 SPM - 2200 PSI on last 70 BBIs of displacement. Obtain Slow pump rates @ 11266' MD 3455 TVD. Pump #1 - 25 SPM - 560 PSI. 35 SPM - 750 PSI. Pump #2 - 25 SPM - 510 PSI, 35 SPM - 670 PSI. PU WT = 145K, SO WT = 35K, ROT WT = 92K. 140 RPM's - 7.5K TO Monitor well -static. POOH from 11266' - 367' (10900'). Install Super Sliders in the middle of each joint of Lo-Tad stands on TOH. Total installed = 90. Change out drilling jars and rack back HWDP & NM Flex Drill collars: (181.27) Plug in and download MWD assembly: Breakout & lay down remaining BHA #7. 6 3/4" SDBS FAF2641Z bit w/ 3x21 jets for a TFA of 1.105 (1.26'), 4 3/4" Geo-Pilot 5200 (16.20'), 4 3/4" GP Non Mag Flex Pony Collar (11.56'), DM Collar (8.56'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR & EWR phase 4 23.82'), PWD Collar (10.76'), TM HOC (10.07'), 4 3/4" Non Mag Float Sub (2.37), 4 3/4" Integral Blade Stabilizer (5.24'). Total = 90.28'). Bit Gaugedto3/1 /WT/N/X/I/ER/TD. Pnntetl: 7L92009 3:2U:7/ PM • • ConocoPhillips Alaska Page 14 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 10/19/2005 ~ 15:30 - 18:30 3.00 WINDO RIP CMPLT2 18:30 - 19:00 ~ 0.50 WINDOV'VOTHR CMPLT2 19:00 - 19:30 I 0.501 WINDOWCIRC (CMPLT2 CMPLT2 10/20/2005 100:00 - 01:00 1.00 WINDOWPULD CMPLT2 01:00 - 01:30 0.50 WINDO ULD CMPLT2 01:30 - 02:15 0.75 CMPLTN RURD CMPLT2 02:15 - 02:30 0.25 CMPLTN SFTY CMPLT2 02:30 - 09:15 I 6.751 CMPLTN( RUNT CMPLT2 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations Clean & Clear Rig Floor area, lay down all tools. PJSM with crew. Discuss safety issues and procedure for BHA make. up. Make up 7 5/8" Whipstock retrieving tools. Make up Fixed Lug retrieving tool (7.49'), 1 jnt 3 1/2 HWDP (29.84'), 4 3/4" Float sub 2.49'), 4 3/4" Bumper jar (7.85'), 4 3/4" Oil Jar (11.13'), Crossover sub ( 1.66'), and 18 jnts 4" HWDP (543.62'). Total BHA = 604.08'. Trip in hole with BHA above top of whipstock. UP WT = 94K, SO WT = 73K. Slack off and locate slot washing down past slot to clean it up. Pull up to observe hooked whipstock slide. Located slot @ 4377' per BOT rep. Pull to 150K to observe jars fire and assembly free. Observe 5K increase in upweight. Pull up hole 30' verify swabbing. Circulate bottoms up @ 71 SPM - 920 PSI. Verify no gas and monitor well -static. POOH slow at 10-15 ft/minute for 15 stands with proper hole fill as we observed swabbing by pulling faster. Cup wore out and continue POOH at an increased rate observing hole taking proper hole fill PuIlWhipstock slide to rotary table. PJSM with crew. Mill marks on slide indicated milling down to 10' on slide. Continue breakout & lay down 7 5/8" Whipstock assembly and space out pipe. Clean & Clear Rig floor area, and send tools down slide. Rig up Liner running equipment, power tongs, slips, elevators etc.. Pull 89 HydroFORM centalizers to rig floor. PJSM with crew, and BOT reps. Discuss safety issues and procedure to run 4 1/2" IBT liner and Hook Hanger assembly. Verify joint placement in pipe shed in correct running order. Make up 3 1/2" Bent joint with Open guide shoe (20.42'). Breakout pack off bushing from top of joint. Install IBT Crossover (1.45'), and continue RIH making up 4 1!2" 12.6# IBT slotted /blank liner assembly as per detail, installing HydroFORM molded centralizers on each joint of liner from Jnt#1 - #96, except on the joints with constrictor packers. Make up torque = 3200 - 3400 FT/LBS. Total number of constrictor packers = 18, spaced out for tops calculated @ 10750',10518',10010', 9716', 9208',8974', 8465',8170',7542',7313',6804',6 572',6065',5775',5360',5156',4865', and 4568'. RIH to 4353'. Rotate 3/4 turn to attempt to go through window @ 4374'. NOGO, tag up on A2 liner at 4496.5'. Pull back to 4353', rotate 3/4 turn to observe Guide shoe through window. Continue RIH with remaining liner to 6882'. Total BHA = 6894.41'. No issues in open hole. PU WT = 76K, SO WT = 56K. 09:15 - 09:30 0.251 CMPLTN( RUNT ~ CMPLT2 09:30 - 11:30 2.00 CMPLTN( RUNT ~ CMPLT2 11:30 - 12:00 ~ 0.50 (CMPLTN RUNT I CMPLT2 12:00 - 15:00 3.00, CMPLTN RUNT CMPLT2 15:00 - 17:00 ~ 2.00 ~ CMPLTN OTHR j CMPLT2 Make up Baker Casing Swivel & Pup Jnt Assembly with Baker Model 61 FHH Hook Hanger & Running tool (48.22'). Pull 2 7/8 tools to floor. PJSM with crew. Discuss Safety Issues and procedure for making up MWD assembly on inner string. Make up 3 1/4" Slimhole MWD assembly on BOT Shear sub and Ball seat (inner string), and Orient MWD to Hook - 180 Degrees out. MAke up Hook Hanger assembly. TIH from 6895' - 6950' (55'): Perform Shallow pulse test on MWD assembly. Good. Continue RIH with 4 1!2" 12.6# IBT slotted /blank liner assembly from 6950' - 11176' (4226'). RU and break circulation @ 11176'. 34 SPM - 700 PSI. UP WT = 143K, SO WT = 55K. Orient with MWD assembly to 10 Degrees left of high ranted: izisrzooo s:zu:~i rM • ConocoPhillips Alaska Page 15 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/20/2005 115:00 - 17:00 17:00 - 19:15 19:15 - 20:15 2.00 CMPLTNI OTHR CMPLT2 2.25 CMPLTN TRIP CMPLT2 1.00 CMPLTN RURD CMPLT2 20:15 - 20:45 0.50 CMPLTN RURD CMPLT2 ....20:45 - 21:15 0..50. CMPLTN RURD CMPLT2 21:15 - 23:00 I 1:751 CMPLTNI RUNT CMPLT2 23:00 - 00:00 1.00 CMPLTN RUNT CMPLT2 10/21/2005 00:00 - 02:00 2.00 CMPLTN TRIP CMPLTN 02:00 - 02:15 0.25 CMPLTN PCKR CMPLTN 02:15 - 02:45 I 0.50 I CMPLTNI PCKR I CMPLTN 02:45 - 05:15 I 2.50 I CMPLTNI TRIP I CMPLTN 05:15 - 05:45 0.50 WINDOWPULD PROD3 05:45 - 07:45 2.00 WINDOVVPULD PROD3 Spud Date: 9/30/2005 Start: 9/30/2005 End:: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations side. RIH to tag up @ 11253' DPM. Set down 30K. Pull up 20' and rotate string 90 Deg, and Slack off to pass through window with Hook Hanger assembly. Pull back up hole, and re-orient with MWD to 10 degrees left of high side. Land Hook on bottom of window as planned on depth @ 4386'. Drop 1 112" Ball and chase with 3 BPM - 700 PSI, slowing pumps to 1.5 BPM - 330 PSI to observe ball seated. Pressure to 3000 PSI to set Hook Hanger and shear with 4300 PSI. Pull up to observe weight loss and Runnng tool free. Monitor well -static. Open Guide shoe depth = 11252'. Top of Hook Hanger = 4370'. POOH to running tools. Observe well taking proper hole fill. Breakout, Visually Inspect and lay down Hook Hanger Running tools and MWD assembly. All Good. Clean & Clear Rig Floor area. Send tools outside. PJSM with crew. Discuss Safety Issues and procedure to make up. LEM asembly. Double check .running order in pipe shed. Make up LEM assembly. MU BOT Seal assembly (3.26'), and 4 1/2" 12.6# L80 XO joint to IBT (43.12').1 - jnt 4 1!2" tubing (30.12'), Camco "DB-6" nipple w/ 3.563" ID (1.52'), 1 -jnt 4 1/2" tubing (30.84').4 1/2" TBG pup (7.86', LEM assembly (35.13'), 4 -jnts 4 1/2" TBG (123.61'), 4 1/2" TBG pup (3.78'), Baker Casing Swivel (2.73'), XO Bushing 5 1/2" Hydril 563 x 4 1/2" IBT (1.37'), 109-47 Casing Seal Bore Receptacle 6.26" x 4.75" (19.39'), 5 1/2" x 7 5/8" ZXP Liner top PKR 19:0'), and Baker Hydraulic Setting tool (5.29'), Baker Running tool 6.16'), and XO to DP (1.66'). Total BHA = 334.84' Install Ball Catcher & Shear sub as per BOT rep. Rig down all tubing running equipment, and clear floor of tools. Trip in hole w/ Lem Assembly from 804' - 4225' (4216'). Fill DP. Continue TIH to tag top of Hook Hanger @ 4368' DPM. PU WT =105K, SO WT = 85K. Pull up 20', rotate 1/4 turn RH, and slack of to tag again. Pull up, rotate 1/4 turn and observe shoe pass through top of Hook Hanger and RIH to observe LEM latch up to Hook Hanger on depth @ 4370'. Pull to 15K over upweight to verify latch up, slack off to neutral weight. Baker seal assembly @ 4511.20' RU & Drop 1 1/2" ball down drill string & chase with 3 BPM - 475 PSI, slowing pumps to 2 BPM to observe ball seat @ 335 Strokes pumped. Pressure up to 3000 PSI to set ZJCP Packer, and continue to 4300 PSI to release from LEM. Hold 5 minutes. Bleed pressure. Close annular and fill all lines. Pressure test down annulus to test ZXP ~ @ 1000 PSI f/ 10 Minutes. Record on chart. Good test. Bleed all pressure. Pull up to allow "dogs" to kick out & slack off to verify top of liner @ 4189'. Monitor well -static. UP WT = 100K, SO WT = 86K. POOH from 4189' to surface. Breakout, Inspect and lay down running and setting tools. Clean & clear rig floor area, send tools out. Pull tools to rig floor. PJSM with crew. Discuss Safety issues, and procedure to pick up Whipstock assembly. MU 5 3/4" Seal Assembly, 6 1/2" No-go sub 1.92'), 4 5/8" Unloader Sub (5.20'), 3 1/2" Pup Jnt (16.46'), 2 -jnts of 3 1/2" Dp (62.44'), Balanking Sub (1.08'), Bottom Trip Anchor (3.21'), Shear Disconnect sub (2.63'), Ported drain sub (1.02'), Debris Barrier Sub (1.71'), Whipstock Slide (15.49'), 6 3/16" Starting Mill (1.08'), 6 5/16" Lower string Mill (5.47'), 6 3/4" Upper String Mill (5.84'), 1 -jnt 3 1/2" HWDP (29.84'), 4 3/4" Float sub (2.49'), MWD assembly (42.45'), 4 3/4" Bumper Jar (7.85'), Crossover sub (1.66') and 6 stands of Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 16 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Spud Date: 9/30/2005 Event Nam e: ROT -D RILLIN G Start:. 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ ppco.co m Rig Release: 10/30/2005 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/21/2005 . 05:45 - 07:45 2.00 WINDO II WPULD PRODS push pipe (543.62'). Total BHA = 751.46'. 07:45 - 08:30 0.75 WINDO THR PRODS Plug in and upload MWD assembly 08:30 - 09:00 0.50 WINDO RIP PRODS TIH to 895', and perform Shallow pulse test. Good pulses @ 78 SPM - 820 PSI. 09:00 - 11:30 2.50 WINDO R1P PRODS Trip in hole with Whipstock assembly from 895' - 3780' (2885'). Run @ 2 minutes per stand as per BOT rep. 11:30 - 12:00 0.50 WINDO RIP PRODS Fill drill pipe, perform MAD PASS for K13 from 3780'.- 4018' (238'), @ 200 ft/hr. Pumps at 285 GPM's - 1750 PSI. UP WT = 105K, SO WT = 82K. Continue TIH to 4140'. 12:00 - 12:30 0.50 WINDO ETW PRODS Pump down drill string to Orient Whipstock face at 10 degrees left of high side as per DD. Tag top of ZXP @ 4190' DPM. Set BTA, Pull 10K over to verify set. Shear bolt @ 35K down weight,and pull to neutral positon. Obtain free rotation. 12:30 -.13:30 1.00 WINDO IRC PRODS . Displace well with 8.9 PPG MOBM, from 9.0_SFMOBM. Pumps at 300 GPM's - 1800 PSL 13:30 - 17:15 3.75 WINDO TWP PRODS Mill window from 4079' - 4091' (12'), and continue mill open hole from 4091' - 4107' (15'). Avg WOM = 2K, 295 GPM's - 1750 PSI. Work mills through window until clean. 17:15 - 18:15 1.00 WINDO IRC PRODS Pump Hi Visc weighted sweep until clean, while working window with no noticeable increase in cuttings across shakers. Momitor Well -static. Pump dry job. 18:15 - 20:15 2.00 WINDO RIP PRODS POOH with milling assembly from 4107' - 639` (3467'). 20:15 - 21:00 0.75 WINDO THR PRODS Change elevators, Pull up and plug in to download MWD assembly. 21:00 - 21:30 0.50 WINDO ULD PRODS POOH, breakout & lay down Milling Asembly. Lay down 6 3/16" Starting Mill (1.08'), 6 5/16" Lower string Mill (5.47'), 6 3/4" Upper String Mill 5.84'), 1 -jnt 3 1!2" HWDP (29.84'), 4 3/4" Float sub (2.49'), MWD assembly (42.45'), 4 3/4" umper Jar (7.85'), Crossover sub (1.66' ) and rack back 6 stands of push pipe (543.62'). Upper string mill in gauge @ 6.750". 21:30 - 22:00 0.50 WINDO ULD PRODS Clean & clear floor area. Send tools outside. BOT rep released. 22:00 - 23:00 1.00 RIGMNT RGRP PRODS PJSM with crew. Discuss safet issues and procedure. Change out washpipe assembly on top drive. 23:00 - 00:00 1.00 RIGMNT RGRP PRODS PJSM with crew. Discuss safety issues and procedure. Change out Saver Sub on top drive. 10/22/2005 00:00 - 01:15 1.25 RIGMNT RGRP PRODS Continue Change out Saver Sub on the Top Drive. 01:15 - 02:30 1.25 DRILL OTHR PRODS PU 5" test joint -wear ring puller, BOLDS, pull wear bushing. Lay down same. MU 4" DP jnt with stack washer & RIH to flush BOP stack. Lay down stack washer & install WB. RILDS. 02:30 - 03:30 1.00 DRILL PULD PRODS PJSM with crew. Discuss Safety Issues and MU procedure for BHA. MU BHA #10, Pull tools to floor. Make up 6 3/4" Reed Hycalog PDC CRXE1005 Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 7/8 - 6.0 stage with a 1.5 degree bend in motor 32.44'), 4 3/4" Non Mag float sub (2.49'), 4 3/4" Integral Blade stabilizer ( 5.24'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (23.82'), PWD Collar (10.76'), TM HOC (11.12'). 03:30 - 04:30 1,00 DRILL OTHR PRODS Plug in and upload MWD assembly. 04:30 - 05:15 0:75 DRILL PULD PRODS Continue Make up remaining BHA, 3 - 4 3/4" Non Mag Flex Drill Collars (92.76'), 4 7/8" Crossover sub (1.66'), 1 - Jnt of 4" HWDP 30.13'), 4 3/4" Drilling jars (28.59'), 4 - Jnts 4" HWDP (121.24'). Total BHA length = 369.61'. 05:15 - 05:30 0.25 DRILL TRIP PRODS Perform Shallow pulse test @ 75 SPM - 1600 PSI. Good test. 05:30 - 06:15 0.75 DRILL TRIP PRODS Trip in hole from 369' - 1956' (1587). 06:15 - 06:45 0.50 DRILL j PULD PRODS Make up 4 3/4" Andergauge Agitator sub (8.71), IF - XT39 Crossover Printed: 12/9/2005 3:20:17 PM • ConocoPhiilips Alaska Page 17 of 21 Operations Summary Report Legal We{I Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code Spud Date: 9/30/2005 Start: 9/30!2005 End: 10/31/2005 Rig Release: 10/30/2005 Group: Rig Number: Description of Operations 10/22/2005 06:15 - 06:45 0.50 DRILL PULD PROD3 06:45 - 07:30 0.75 DRILL TRIP PROD3 07:30 - 08:30 1.00 RIGMNT RSRV PROD3 08:30 - 08:45 0.25 DRILL TRIP PROD3 08:45 - 12:00 3.251 DRILL DRLG PROD3 12:00 - 00:00 12.00 DRILL DRLG PROD3 10/23/2005 100:00 - 12:00 1 12.001 DRILL I DRLG I PROD3 12:00 - 00:00 I 12.00 I DRILL I DRLG I PROD3 (1.64'), 4 3/4" Shock sub (7.00'), and Crossover XT39 - IF (1.07'). Continue TIH from 1974' - 4026' (2052'). Fill drill string with mud @ 2721'. 82 SPM - 3400 PSI. Slip & Cut 71' of drilling line. Inspect Brakes. Orient bit 8 motor to 10 Degrees left of high side. Pass through window area from 4079' - 4091' with no issues and tag at 4097' DPM. UP WT = 80K, SO WT = 76K, ROT WT 80K, 5K torque. Observed hole fill on trip = proper displacement, 24 BBLs. Directional Drill 6 3/4" hole in "D" Lateral from 4097' - 4308' MD (211'). TVD = 3458'. ADT = 1.54 HRS, AST =.92 HRS, ART = .62 HRS. Pumps @ 86 SPM (total) - 3500 PSI. Pump # 1 @ 45 SPM. Pump # 2 @ 41 SPM. UP WT = 90K, SO WT = 70K, ROT WT = 80K. WOB = 5-10K RPM's = 90. Torque on bottom = 3K, Torque off bottom = 3K. MUD_WT = 8.9 PPG, VISC.= 77, YP = 18. Establish ECD Baseline .@ 9.72 PPG EMW, Jar Hrs total = 1.54. Bit Hrs total = 1.54. Obtain SPR's @ 4168' MD, 3470 TVD. Pump #1 = 20 SPM - 420 PSI, 30 SPM - 720 PSI. Pump #2 = 20 SPM - 400, 30 SPM -720 PSI. Survey @ 4292' MD, 3456' TVD. INC = 93.13 DEG, AZ = 179.74 DEG. Continue Directional Drill 6 3/4" hole in "D" Lateral from 4308' - 4775' MD (467'). TVD = 3475'. ADT = 7.44 HRS, AST =4.62 HRS, ART = 3.41 HRS. Pumps @ 93 SPM - 3640 PSI. Pump # 1 @ 93 SPM. UP WT = 94K, SO WT = 70K, ROT WT = 80K. WOB = 5-10K. RPM"S = 90. Torque on bottom = 5K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 9.92 PPG EMW. Jar Hrs total = 8.98. Bit Hrs total = 8.98 Obtain SPR's @ 4772' MD, 3468 TVD. Pump #1 = 20 SPM - 380 PSI, 30 SPM - 610 PSI. Pump #2 = 20 SPM - 390, 30 SPM -610 PSI. Survey @ 4633' MD, 3456' TVD. INC = 86.79 DEG, AZ = 181.16 DEG. Observed Concretions @ 4282' - 4284' (2'), 4395' - 4413' (18'), 4422' -4446' (24'), 4450' - 4460' (10'), 4505' - 4508' (3'), 4722' - 4743' (21'), 4745' - 4756' (1'), 4760' - 4769' (9'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 4775' - 5969' MD (1194'). TVD = 3430'. ADT = 8.19 HRS, AST = 2.93 HRS, ART = 5.26 HRS. Pumps @ 88 SPM - 3450 PSI. Pump # 1 @ 88 SPM. Pump sweeps as needed to clean hole. UP WT = 92K, SO WT = 65K, ROT WT = 80K. WOB = 5-10K: RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD @ 10.4 PPG EMW. Jar Hrs total = 16.10. Bit Hrs total = 16.10 Obtain SPR's @ 5800' MD, 3446 TVD. Pump #1 = 20 SPM - 440 PSI, 30 SPM - 670 PSI. Pump #2 = 20 SPM - 460, 30 SPM -680 PSI. Survey @ 5844' MD, 3434' TVD. INC = 93.21 DEG, AZ = 179.78 DEG. Observed Concretions @ 4836' - 4839' (3'), 4982' - 4987' (15'), 5787' - 5790' (3'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 5969' - 7138' MD (1169'). TVD = 3404'. ADT = 6.06 HRS, AST = 1.90 HRS, ART = 4.16 HRS. Pumps @ 85 SPM - 3250 PSI. Pump # 2 @ 85 SPM. Pump sweeps as needed to clean holee UP WT = 103K, SO WT = 56K, ROT WT = 80K. WOB = 2-10K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 73, YP = 18. ECD @ 10.3 PPG EMW. Jar Hrs total = 22.16. Bit Hrs total = 22.16 Obtain SPR's @ 6828' MD, 3410 TVD. Pump #1 = 20 SPM - 460 PSI, 30 SPM - 780 PSI. Pump #2 = 20 SPM - 500, 30 SPM -780 PSI. Survey @ 6966' MD, 3406' TVD. INC = 90.84 DEG, AZ = 179.98 DEG. Observed Concretions @ 6624' - 6628' (4'), 6653' - 6657' (4'), 6768' - Printed: 12/9/2005 3:20:17 PM • • ConocoPhillips Alaska Page ? 8 cf 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 10/23/2005 112:00 - 00:00 10/24/2005 100:00 - 12:00 12:00 - 00:00 10/25/2005 100:00 - 12:00 12:00 - 00:00 12.001 DRILL I DRLG I PROD3 12.001 DRILL I DRLG I PROD3 12.001 DRILL I DRLG I PROD3 12.00 I DRILL I DRLG i PROD3 12.00 l DRILL I DRLG I PROD3 10/26/2005 100:00 - 12:45 I 12.75 I DRILL !DRLG I PROD3 Spud Date: 9/30/2005 Start: 9/30/2005 End: 10/31/2005 Rig Release: 10/30!2005 Group: Rig Number: Description of Operations 6780' (12'). Max Gas units = 179. Observed 35% increase in cuttings at shakers when sweep returned. Continue Directional Drill 6 3/4" hole in "D" Lateral from 7138' - 8195' MD (1057'). ND = 3407'. ADT = 6.35 HRS, AST = 1.06 HRS, ART = 5.29 HRS. Pumps @ 86 SPM - 3800 PSi. Pump # 1 @ 86 SPM. Pump sweeps as needed to clean hole. UP WT = 107K, SO WT = 56K, ROT WT = 79K. WOB = 2-12K. RPM"S = 90. Torque on bottom = 4K, Torque off bottom = 4K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 10.5 PPG EMW. Jar Hrs total= 28.51. Bit Hrs total = 28.51 Obtain SPR's @ 8173' MD, 3405 TVD. Pump #1 = 20 SPM - 510 PSI, 30 SPM - 750 PSI. Pump #2 = 20 SPM - 520, 30 SPM -720 PSI. Survey @ 8027' MD, 3396' TVD. INC = 87.5 DEG, AZ = 178.3 DEG. Observed Concretions @ 7449' - 7456' (7'), 7774' - 7780' (6'), 8132' - 8140' (8'). Max Gas units = 135.. Observed 40% increase in cuttings at shakers when sweep returned from 7322'. Sweep @ 7883', 15% increase in cuttings. Continue Directional drill 6 3/4" hole in "D" Lateral from 8195' - 8879 MD (784'). TVD = 3404'. ADT = 7.21 HRS, AST = 2.52 HRS, ART = 4.69 HRS. Pumps @ 84 SPM - 3400 PSI. Pump # 1 @ 84 SPM. Pump sweeps as needed to clean hole. UP WT = 110K, SO WT = 52K, ROT WT = 82K. WOB = 2-12K. RPM"S = 90. Torque on bottom = 6K, Torque off bottom = 5K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD @ 10.67 PPG EMW. Jar Hrs total = 35.72. Bit Hrs total = 35.72 Obtain SPR's @ 8850' MD, 3408 TVD. Pump #1 = 20 SPM - 480 PSI, 30 SPM - 800 PSI. Pump #2 = 20 SPM - 500, 30 SPM -810 PSI.Survey @ 8899' MD, 3408' TVD. INC = 92.89 DEG, AZ = 181.25 DEG. Observed Concretions @ 8342' - 8349' (7'), 8381' - 8401' (20'), Max Gas units = 182. Observed 25% increase in cuttings at shakers when sweep returned from 8947'. Continue Directional Drill 6 3!4" hole in "D" Lateral from 8879' - 9721' MD (842'). TVD = 3359'. ADT = 7.43 HRS, AST = 2.64 HRS, ART = 4.79 HRS. 309 GPM @ 3750 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 115K, SO WT = 45K, ROT WT = 80K. WOB = 2-15K. RPM"S = 90. Torque on bottom = 6.5K, Torque off bottom = 6.5K. MUD WT = 8.9 PPG, VISC = 68, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 43.77. Bit Hrs total = 43.77 Obtain SPR's @ 9524' MD, 3372 TVD. Pump #1 = 20 SPM - 560 PSI, 30 SPM - 790 PSI. Pump #2 = 20 SPM - 550, 30 SPM -780 PSI. Observed Concretions @ 9288' - 9291' (3'), 9311' - 9318' (7'), 9331'-9343' (12'), 9380'-9394' (14'), 9421'-9429' (8'), 9435'-9440' (5'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 9721' - 10286' MD (565'). TVD = 3379'. ADT = 6.42 HRS„AST = 2.07 HRS, ART = 4.35 HRS. 318 GPM @ 3850 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 125K, SO WT = 42K, ROT WT = 87K. WOB = 2-12K. RPM"S = 100. Torque on bottom = 6.OK, Torque off bottom = 5.4K. MUD WT = 8.9 PPG, VISC = 67, YP = 18. EGD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 50.19. Bit Hrs total= 50.19 Obtain SPR's @ 10283' MD, 3379 TVD. Pump #1 = 20 SPM - 570 PSI, 30 SPM - 800 PSI. Pump #2 = 20 SPM - 570, 30 SPM -820 PSI. Observed Concretions @ 9940' - 9946' (6'), 10188' -10195' (7'}, 10230'-10250' (20'). Continue Directional Drill 6 3/4" hole in "D" Lateral from 10286' - 10964' MD (TD) (678'). TVD = 3356'. ADT = 9.36 HRS, AST = 4.49 HRS, ART Printed: 12/9!2005 3:20:17 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-154 Common Well Name: 1J-154 Event Name: ROT -DRILLING Start: 9/30/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Rig Name: Doyon 141 .Rig Number: Date From - To Hours Code Code Phase 10/26/2005 , 00:00 - 12:45 I 12.751 DRILL I DRLG ~ PRODS 12:45 - 14:30 1.75 DRILL CIRC PRODS 14:30 - 16:30 2.00 DRILL WIPR PRODS 16:30 - 19:45 3.25 DRILL -WIPR. _PRODS 19:45 - 22:45 3.00 DRILL WIPR PRODS 22:45 - 00:00 1.251 DRILL CIRC PRODS 10/27/2005 00:00 - 00:30 0.50 RIGMNT RSRV PRODS 00:30 - 03:30 .3.00 DRILL WIPR PRODS 03:30 - 05:15 1.75 DRILL WIPR PRODS 05:15 - 08:00 2.75 DRILL CIRC PRODS 08:00 - 09:45 110!28/2005 1.751 DRILL I CIRC I PRODS 09:45 - 16:30 6.75 DRILL TRIP PRODS 16:30 - 17:00 0.50 DRILL PULD PRODS 17:00 - 18:00 1.00 DRILL TRIP PRODS 18:00 - 18:30 0.50 DRILL PULD PRODS 18:30 - 19:45 1.25 DRILL PULD PRODS 19:45 - 20:45 1.00 DRILL PULD PRODS 20:45 - 21:15 0.50 DRILL SFTY CMPLT3 21:15 - 22:00 0.75 WINDO ULD CMPLT3 22:00 - 00:00 2.00 WINDOV' ITRIP CMPLT3 00:00 - 00:30 0.50 WINDOW TRIP CMPLT3 00:30 - 01:00 0.50 WINDOW OTHR CMPLT3 01:00 - 01:30 0.50 WINDOV~ /CIRC CMPLT3 01:30 - 04:00 2.50 WINDO RIP CMPLT3 04:00 - 06:30 2.50 WINDO ULD CMPLT3 06:30 - 07:00 0.50 DRILL SFTY CMPLT3 07:00 - 11:00 4.00 WELCT BOPE CMPLT3 11:00 - 18:15 7.251 CASE PULR CMPLT3 Page ~19 of 21 Spud Date: 9/30/2005 End: 10/31 /2005 Group: Description of Operations = 4.87 HRS: 309 GPM @ 4000 PSI. Pump # 1 @ 87 SPM. Pump sweeps as needed to clean hole. UP WT = 135K, SO WT = 45K, ROT WT = 89K. WOB = 2-15K. RPM"S = 100. Torque on bottom = 7.OK, Torque off bottom = 7.OK. MUD WT = 8.9 PPG, VISC = 67, YP = 18. ECD's @ 10.7 to 11.2 PPG EMW. Jar Hrs total = 60.55. Bit Hrs total = 60.55 Obtain SPR's @ 10851' MD, 3365 TVD. Pump #1 = 20 SPM - .610 PSI, 30 SPM - 860 PSI. Pump #2 = 20 SPM - 610, 30 SPM -850 PSI. Observed Concretions @ 10290' - 10299' (9'), 10319' - 10322' (23'), 10364'-10367' (3'), 10846- 10850 (4'). Pump Hi-vis weighted sweep around and 1 btm's up at rate of 300 gpm @ 3950 psi, Observe well, Pump up survey. POOH on elevators f/ 10,964' to 10,195', Pump dry job & continue to POOH to 9,543' (Pulled 20K over @ 9,543') Make up top drive). .Back ream out of hole.. f/ 9,627 to 8,369' with no problems at cafe of_330_ gpm @ 3900 psi w/ 100 RPM. POOH on elevators f/ 8,369' to 7,629', Pump dry job, Continue to POOH to 4,028' (Window @ 4,079'), No problems POOH or Pulling thru window. Pump Hi-vis weighted sweep & circ 3 times btm's up at rate of 330 gpm @ 3400 psi w/ 100 RPM. Service top drive RIH with no problems f/ 4,028' to 9,723' (Ran out of weight) Wash & Ream f/ 9,723' to 10,964' w/ 128 GPM @ 1200 PSI & 50 RPM. Pump 35 bbl Hi-vis weighted sweep &Circ 3 times btm's up at rate of 288 GPM @ 4100 PSI, 100 RPM. Change well over f/ MOBM to SFOBM at rate of 288 GPM @ 4100 PSI w/ 100 RPM, Obtain SPR's, Monitor well- OK. POOH on elevators with no problems. Lay down Agitator & Shock sub. Continue to POOH to BHA. Lay down DC's. Down load MW D tools. Finish laying down BHA. Clear 8~ Clean rig floor, Bring Whipstock retrieving tools to rig floor. Make up Baker Whipstock retrieving tools. RIH w/ BHA to 2,539', Fill pipe - 50 SPM @ 550 PSI. Continue RIH to 4,083' Work & Hook whipstock @ 4,083', Pull loose w/ 70K over, Pull 1 stand drill pipe. Circ btm's up at rate of 6 bpm @ 1200 psi. Drop 1-3/4" rabbit, POOH to whipstock. lay down whipstock & Baker retrieving tools. Clear tools from rig floor, Clean rig floor. Pull wear bushing, Rig & test all BOPE to 250 psi low & 3000 psi high, Test waived by AOGCC Jeff Jones, Install wear bushing. PJSM, Rig & Make up 3 1/2" Bentjoint X 4-1/2" with Open guide shoe as shoe jt.. Breakout pack off bushing from,top of joint, Continue RIH making up 4 112" 12.6# IBT slotted /blank liner assembly as per detail, installing HydroFORM molded centralizers on each joint of liner from Jnt#1 - #116, except on the joints with constrictor packers. Make up torque = 3200 - 3400 FT/LBS. Total number of constrictor packers = 18, spaced out for tops calculated @ 10555', 10356', 9855', 9605', 9105', 8855', 8352', 8105', 7755', 7505', 7005', 6755', 6255', 6005', Printed: 1Z/9l2005 3:20:17 PM • ConocoPhillips Alaska Page 20 of 21 Operations Summary Report Legal Well Name: 1J-154 Common W ell Name: 1J-154 Spud Date: 9!30/2005 Event Nam e: ROT -D RILLING Start: 9/30/2005 End:.. 10/31/2005 Contractor Name: n1334@ ppco.co m Rig Release: 10/30/2005 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/28/2005 11:00 - 18:15 7:25 CASE PULR CMPLT3 5557, 5302', 4805' and 4555'. RIH and enter btm of window @ 4091'. Continue RIH with remaining liner to 6,820'. Total BHA = 6,843.47'. No issues in open hole. PU WT = 75K, SO WT = 68K. 18:15 - 19:45 1.50 CASE PULR CMPLT3 Pull 2 7/8 tools to floor. PJSM with crew. Discuss Safety Issues and procedure for making up MWD assembly on inner string. Make up 3 1/4" Slimhole MWD assembly on BOT Shear sub and Ball seat (inner string), and Orient MWD to Hook - 180 Degrees out. MAke up Hook Hanger assembly. 19:45 - 22:45 3.00 CASE RUNL CMPLT3 RIH w/ 4-1/2" liner f/ 6843' to 10,877', Perform Shallow pulse test on MWD assembly. Good. 22:45 - 00:00 1.25 CASE OTHR CMPLT3 Break circulation @ 10,877'. 37 SPM - 1000 PSI. UP WT = 145K, SO WT = 65K. Orient with MWD assembly to 12 Degrees left of high side. RIH to tag up w/shoe @ 10,917.80' -Hook btm of window @ 4,091' - - - - - (Measurements exact), Toolface oriented So 4 Degress Left .-Set down- 30K. Pull up 20' and rotate string 180 Deg, and Slack off to pass through window with Hook Hanger assembly. Pull back up hole, and re-orient with MWD to 12 degrees left of high side. Land Hook on bottom of window as planned on depth @ 4,091' and Toolface again pulled around to 4 Degress left of high side. Top of Hook Hanger @ 4,074.33', Shoe @ 10,917.80' 10/29/2005 00:00 - 00:30 0.50 CASE OTHR CMPLT3 Drop ball & pump down at rate of 130 gpm @ 1000 psi. Pressure up release f/ liner & shear out ball w/ 4400 psi. 00:30 - 01:00 0.50 CASE CIRC CMPLT3 Pick up & circ btm's up at rate of 5 bpm @ 700 psi. 01:00 - 03:45 2.75 CASE RUNL CMPLT3 POOH, Break & lay down liner running tools &MWD. 03:45 - 04:15 0.50 CASE OTHR CMPLT3 Lay down tools from beaver slide, Clean rig floor. 04:15 - 13:00 8.75 DRILL PULD CMPLT3 Rig & lay down 95 std's 4" drill pipe f/ off drillers side. 13:00 - 14:15 1.25 RIGMNT RSRV CMPLT3 Slip & cut drilling line 70', Service top drive. 14:15 - 14:45 0.50 CMPLTN RURD CMPLT3 Rig casing tools to run LEM Assembly. 14:45 - 16:15 1.50 CMPLTN PULD CMPLT3 PJSM, Make up LEM assembly as per detail, UP 37K, DN 40K, Rig down cagingf tools. 16:15 - 19:00 2.75 CMPLTN TRIP CMPLT3 RIH to 4200', UP 110K, DN 92K, Slack off and latch LEM (On depth), Pull test latch 20K over twice-OK, Slack off 40K. 19:00 - 19:45 0.75 CMPLTN CIRC CMPLT3 Drop ball & pump down at 163 gpm @ 700 psi, Seat ball & pressure up to 4000, Bleed pressure, Test ZXP to 1000 psi f/ 10 min-OK. 19:45 - 22:15 2.50 CMPLTN TRIP CMPLT3 Monitor well, POOH to running tools. 22:15 - 22:45 0.50 CMPLTN PULD CMPLT3 Lay down running tools. 22:45 - 00:00 1.25 CMPLTN RURD CMPLT3 Pull wear bushing, Rig to run 4-1/2" completion string, PSJM. 10130!2005 00:00 - 03:30 3.50 CMPLT RUNT CMPLT3 Run Baker 4.75" Seal assembly, 1 jt. 4-1/2", 12.6#, L-80, IBT Tubing, Baker4-1/2" CMU Sliding sleeve (In Open position), 6jts. 4-1/2", 12.6#, L-80, IBT tubing, Camco 4-1/2"x 1"- KBMG GLM, 44 jts. tbg, Camco 4-1/2"x 1"-KBMG GLM, 62 jts. tbg, Camco 4-1/2" DB Nipple w/ 3.875" Profile, 15 jts tbg., Tag No-Go @ 4,025.13' w/ Tail @ 4,051.78' (2.75' High with tubing measurements). Note: Day Light savings time 1 hour back. 03:30 - 04:30 1.00 CMPLTN SOHO CMPLT3 Make up Vetco Gray 4-1/2" x 11"Tubing hanger & land tubing 4.23' i ' above fully located position w/ Tail @ 4,047.55', Attempt to test seals on hanger- No Good, Pull hanger, Change O-rings and reland hanger, Test hanger seals to 250 low and 5000 psi high- OK. 04:30 - 06:00 1.50 CMPLTN. NUND ~ CMPLT3 Nipple down BOPE. 06:00 - 07:30 1.50 CMPLTN NUND CMPLT3 Nipple up Vetco Gray Tree and test same to 250 psi low & 5000 psi high. 07:30 - 13:00 5.50 CMPLTN PULD CMPLT3 , Lay down all 4" HWDP, DC's, Drill pipe w/ Lo-Tad's & Sliders, Rig down mouse hole. Printed: 12/9/2005 3:20:17 PM • ConocoPhillips Alaska Page 21 of 21 Operations Summary Report Legal Well Name: 1J-154 Common Well Name: 1 J-154 Spud Date: 9/30/2005 Event Name: ROT -DRILLING Start: 9/30/2005 End: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 10/30/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase Description of Operations 10/30/2005 13:00 - 16:00 3.00 CMPLTN FRZP CMPLT3 Rig Little Red service and freeze protect well with 166 bbls diesel thru sliding sleeve @ 3,971', Remove all tools and equip. from rig floor, Change liners in pumps to 6". 16:00 - 16:30 0.50 CMPLTN NUND CMPLT3 Rig lubricator and set BPV: 16:30 - 19:00 2.50 CMPLTN PULD CMPLT3 Rig mouse hole finish laying down 4" drill pipe, Lo-Tad's & Sliders, Rig down mouse hole. 19:00 - 00:00 5.00 CMPLTN OTHR CMPLT3 Clean pits, Rock washer, Cuttings boxes. Release rig @ 2400 hrs. 10/30/05 Printed: 12/9!2005 3:20:17 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1 J-154 Job No, AK-ZZ-0003956462, Surveyed: 10 October, 2005 Survey Report 9 November, 2005 Your Ref.• API 500292325400 Surtace Coordinates: 5945944.17 N, 558639.59E (70° 15' 46.5105" N, 149° 31' 33.3768" VN) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 945944.17 N, 58839.59E (Grid) Surtace Coordinates relative to Structure: 25.70 N, 150.17 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level - Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~~C-s~~..IJC'1 ~- ~ ~ _ ~ ~'~' ~ Survey Ref, svy2131 A F4atllburtor~ Gomp~ry Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J--154 Your Ref: API 500292325400 Job No. AK-ZZ-0003956462, Surveyed: 10 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -109.00 0.00 0.00 N 0.00 E 28.00 0.000 0.000 -81.00 28.00 0.00 N 0.00 E 50.00 0.360 342.180 -59.00 50.00 0.07 N 0.02 W 100.00 0.740 15.200 -9.00 100.00 0.53 N 0.02 E 200.00 0.640 32.890 90.99 199.99 1.62 N 0.49 E 300.00 0.950 41.940 190.98 299.98 2.70 IV 1.35 E 400.00 1.410 47.920 290.96 399.96 4.15 N 2.81 E 443.00 1.840 47.690 333.94 442.94 4.97 N 3.72 E 536.00 1.670 50.390 426.90 535.90 6.83 N 5.86 E 627.00 1.910 11.600 517.86 626.86 9.17 N 7.19 E 719.00 5.220 337.720 609.67 718.67 14.54 N 5.91 E 752.73 5.810 335.090 643.25 752.25 17.51 N 4.61 E 797.29 7.060 331.080 687.53 796.53 21.95 N 2.34 E 842.05 7.260 329.220 731.94 840.94 26.79 N 0.44 W 887.94 7.960 327.700 777.42 886.42 31.97 N 3.62 W 931.41 10.420 327.380 820.33 929.33 37.82 N 7.35 W 976.36 12.130 328.180 864.41 973.41 45.26 N 12.03 W 1026.56 13.980 328.870 913.31 1022.31 54.93 N 17.95 W 1068.29 14.830 329.160 953.73 1062.73 63.83 N 23.29 W 1121.11 15.380 327.400 1004.73 1113.73 75.54 N 30.53 W 1215.99 16.910 325.120 1095.86 1204.86 97.46 N 45.20 W 1312.48 21.770 325.940 1186.88 1295.88 123.81 N 63.26 W 1407.71 22.160 325.770 1275.20 1384.20 153.29 N 83.25 W 1503.23 24.940 326.000 1362.75 1471.75 184.89 N 104.65 W 1597.71 24.460 325.960 1448.59 1557.59 217.61 N 126.74 W 1693.00 27.360 325.950 1534.29 1643.29 252.11 N 150.05 W 1787.53 27.610 325.870 1618.15 1727.15 288.24 N 174.50 W 1882.96 27.490 319.270 1702.78 1811.78 323.24 N 201.29 W 1978.08 24.640 315.520 1788.22 1897.22 354.03 N 229.51 W 2027.51 23.320 312.410 1833.39 1942.39 367.98 N 243.96 W 2073.28 21.800 309.810 1875.66 1984.66 379.54 N 257.17 W 2168.35 19.120 300.300 1964.74 2073.74 398.70 N 284.19 W 2221.22 18.040 296.100 2014.86 2123.86 406.67 N 299.02 W 2252.38 16.970 293.320 2044.58 2153.58 410.60 N 307.53 W 2293.34 16.300 287.180 2083.83 2192.83 414.66 N 318.51 W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5945944.17 N ~ 558639.59E ~ 5945944.17 N 558639.59E 0.000 5945944.24 N 558639.57E 1.636 5945944.70 N 558639.60E 0.960 5945945.79 N 558640.07E 0.234 5945946.89 N 558640.91E 0.334 5945948.34 N 558642.37E 0.476 5945949.16 N 558643.27E 1.000 5945951.05 N 558645.40E 0.203 5945953.39 N 558646.71E 1.330 5945958.76 N 558645.39E 4.116 5945961.72 N 558644.06E 1.902 5945966.14 N 558641.76E 2.979 5945970.96 N 558638.94E 0.684 5945976.11 N 558635.72E 1.587 5945981.93 N 558631.94E 5.660 5945989.34 N 558627.21E 3.820 5945998.96 N 558621.21E 3.698 5946007.82 N 558615.80E 2.044 5946019.47 N 558608.47E 1.356 5946041.27 N 558593.63E 1.745 5946067.48 N 558575.37E 5.045 5946096.81 N 558555.15E 0.415 5946128.24 N 558533.50E 2.912 5946160.79 N 558511.16E 0.508 5946195.10 N 558487.58E .3.043 5946231.04 N 558462.85E 0.267 5946265.83 N 558435.79E 3.200 5946296.40 N 558407.33E 3.460 5946310.24 N 558392.78E 3.696 5946321.69 N 558379.47E 3.971 5946340.65 N 558352.30E 4.483 5946348.50 N 558337.41E 3.251 5946352.36 N 558328.87E 4.357 5946356.34 N 558317.86E 4.590 ConocoPhi/lips Vertical Section Comment 0.00 CB-SS-Gyro 0.00 -0.07 -0.53 -1.62 -2.70 -4.15 -4.97 -6.83 -9.17 -14.54 MWD+IIFR+M5+SAG -17.51 -21.95 -26.79 -31.97 • -37.82 -45.26 -54.93 -63.83 -75.54 -97.46 -123.81 -153.29 -184.89 -217.61 • -252.11 -288.24 -323.24 -354.03 -367.98 -379.54 -398.70 X06.67 -410.60 -414.66 9 November, 2005 - 12:57 Page 2 of 5 prillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1 J Pad - 1J-154 Your Ref.• API 500292325400 Job No. AK-ZZ-0003956462, Surveyed: 10 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 2384.09 14.300 270.440 2171.40 2280.40 418.51 N 341.90 W 5946360.01 N 558294.44E 5.319 -418.51 2476.96 12.180 248.710 2261.85 2370.85 415.04 N 362.51 W 5946356.37 N 558273.86E 5.781 -415.04 2569.30 14.390 228.380 2351.76 2460.76 403.87 N 380.18 W 5946345.07 N 558256.28E 5.559 -403.87 2662.40 17,090 215.330 2441.39 2550.39 385.02 N 396.74 W 5946326.09 N 558239.86E 4.765 -385.02 2755.49 20.780 206.560 2529.45 2638.45 359.08 N 412.05 W 5946300.03 N 558224.76E 4.996 -359.08 2846.42 22.980 205.190 2613.82 2722.82 328.58 N 426.82 W 5946269.42 N 558210.23E 2.484 -328.58 2940.94 26.510 199.910 2699.66 2808.66 292.04 N 441.86 W 5946232.76 N 558195.47E 4.403 -292.04 3032.76 31.020 192.720 2780.15 2889.15 249.66 N 454.06 W 5946190.28 N 558183.60E 6.183 -249.66 3127.49 35.630 189.900 2859.29 2968.29 198.63 N 464.18 W 5946139.18 N 558173.88E 5.133 -198.63 3220.06 40.730 188.350 2932.04 3041.04 142.15 N 473.21 W 5946082.63 N 558165.29E 5.605 -142.15 3312.84 44.990 187.950 3000.03 3109.03 79.69 N 482.14 W 5946020.11 N 558156.84E 4.601 -79.69 3405.26 51.160 188.030 3061.75 3170.75 11.63 N 491.70 W 5945951.97 N 558147.81E 6.676 -11.63 3497.82 53.640 188.210 3118.22 3227.22 60.96 S 502.06 W 5945879.30 N 558138.02E 2.684 60.96 3590.62 57.880 187.050 3170.43 3279.43 136.98 S 512.22 W 5945803.20 N 558128.45E 4.684 136.98 3683.36 61.480 185.500 3217.24 3326.24 216.54 S 520.95 W 5945723.58 N 558120.34E 4.141 216.54 3776.72 66.480 183.520 3258.18 3367.18 300.15 S 527.52 W 5945639.92 N 558114.43E 5.684 300.15 3872.53 72.080 181.390 3292.07 3401.07 389.64 S 531.32 W 5945550.40 N 558111.32E 6.203 389.64 3967.66 77.280 180.170 3317.20 3426.20 481.35 S 532.56 W 5945458.69 N 558110.80E 5.604 481.35 4062.53 78.370 178.300 3337.21 3446.21 574.07 S 531.32 W 5945365.98 N 558112.76E 2.243 574.07 4156.37 76.400 178.100 3357.70 3466.70 665.59 S 528.44 W 5945274.48 N 558116.35E 2.110 665.59 4252.96 76.260 177.560 3380.53 3489.53 759.38 S 524.89 W 5945180.72 N 558120.63E 0.562 759.38 4346.92 80.890 177.190 3399.13 3508.13 851.36 S 520.67 W 5945088.78 N 558125.57E 4.943 851.36 4442.44 78.520 179.320 3416.21 3525.21 945.28 S 517.80 W 5944994.88 N 558129.17E 3.312 945.2$ 4537.79 79.850 179.040 3434.10 3543.10 1038.93 S 516.46 W 5944901.25 N 558131.24E 1.424 1038.93 4631.91 79.630 177.610 3450.86 3559.86 1131.50 S 513.75 W 5944808.70 N 558134.66E 1.513 1131.50 4727.53 79.700 178.580 3468.02 3577.02 1225.52 S 510.63 W 5944714.72 N 558138.52E 1.001 1225.52 4822.57 79.050 178.630 3485.54 3594.54 1318.90 S 508.35 W 5944621.35 N 558141.52E 0.686 1318.90 4918.60 80.400 181.360 3502.67 3611.67 1413.38 S 508.35 W 5944526.88 N 558142.26E 3.131 1413.38 5013.85 81.350 182.810 3517.78 3626.78 1507.35 S 511.77 W 5944432.88 N 558139.57E 1.804 1507.35 5109.37 81.090 182.900 3532.36 3641.36 1601.64 S 516.47 W 5944338.56 N 558135.61E 0.288 1601.64 5185.06 84.050 182.930 3542.15 3651.15 1676.59 S 520.29 W 5944263.58 N 558132.37E 3.911 1676.59 5278.89 88.380 182.960 3548.34 3657.34 1770.07 S 525.10 W 5944170.07 N 558128.29E 4.615 1770.07 5372.22 88.300 182.990 3551.04 3660.04 1863.23 S 529.94 W 5944076.87 N 558124.18E 0.092 1863.23 5465.88 89.850 183.020 3552.55 3661.55 1956.75 S 534.85 W 5943983.32 N 558119.99E 1.655 1956.75 5558.90 90.340 183.360 3552.40 3661.40 2049.62 S 540.03 W 5943890.40 N 558115.54E 0.641 2049.62 ConocoPhillips Comment • L 9 November, 2005 - 12:57 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J--154 Your Ref.• API 500292325400 Job No. AK ZZ-0003956462, Surveyed: 10 October, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 5652.27 92.210 183.300 3550.32 3659.32 2142.81 S 545.45 W 5943797.18 N 558110.85E 2.004 2142.81 5744.62 93.500 182.320 3545.72 3654.72 2234.93 S 549.97 W 5943705.03 N 558107.04E 1.753 2234.93 5839.16 91.740 179.780 3541.40 3650.40 2329.34 S 551.70 W 5943610.60 N 558106.05E 3.266 2329.34 5932.88 92.510 181.850 3537.92 3646.92 2422.98 S 553.03 W 5943516.95 N 558105.45E 2.355 2422.98 6025.67 91.570 179.920 3534.62 3643.62 2515.70 S 554.46 W 5943424.23 N 558104.74E 2.312 2515.70 6119.11 91.760 175.770 3531.91 3640.91 2609.01 S 550.95 W 5943330.95 N 558108.97E 4.444 2609.01 6213.54 91.390 174.250 3529.31 3638.31 2703.05 S 542.74 W 5943236.98 N 558117.92E 1.656 2703.05 6307.25 88.590 175.950 3529.33 3638.33 2796.40 S 534.74 W 5943143.69 N 558126.65E 3.495 2796.40 6400.00 88.360 172.190 3531.80 3640.80 2888.61 S 525.16 W 5943051.56 N 558136.94E 4.060 2888.61 6494.09 89.920 175.910 3533.21 3642.21 2982.16 S 515.41 W 5942958.09 N 558147.42E 4.287 2982.16 6587.63 80.900 180.040 3532.54 3641.54 3075.62 S 512.11 W 5942864.66 N 558151.45E 4.538 3075.62 6680.91 90.090 180.790 3531.73 3640.73 3168.89 S 512.78 W 5942771.38 N 558151.50E 1.183 3168.89 6774.31 90.840 185.970 3530.97 3639.97 3262.09 S 518.29 W 5942678.14 N 558146.72E 5.604 3262.09 6862.76 91.140 187.050 3529.45 3638.45 3349.96 S 528.31 W 5942590.20 N 558137.38E 1.267 3349.96 6959.99 91.390 187.150 3527.30 3636.30 3446.42 S 540.33 W 5942493.65 N 558126.12E 0.277 3446.42 7054.27 88.470 180.790 3527.41 3636.41 3540.41 S 546.85 W 5942399.61 N 558120.33E 7.422 3540.41 7147.86 89.480 180.660 3529.09 3638.09 3633.98 S 548.04 W 5942306.03 N 558119.87E 1.088 3633.98 7241.47 89.780 181.200 3529.69 3638.69 3727.57 S 549.55 W 5942212.43 N 558119.08E 0.660 3727.57 7335.16 90.030 181.780 3529.85 3638.85 3821.23 S 551.99 W 5942118.76 N 558117.37E 0.674 3821.23 7428.55 90.150 177.070 3529.70 3638.70 3914.59 S 551.05 W 5942025.41 N 558119.04E 5.045 3914.59 7521.90 88.780 175.430 3530.57 3639.57 4007.73 S 544.95 W 5941932.32 N 558125.87E 2.289 4007.73 7614.92 90.910 175.490 3530.82 3639.82 4100.45 S 537.59 W 5941839.65 N 558133.95E 2.291 4100.45 7709.16 90.020 175.470 3530.06 3639.06 4194.40 S 530.16 W 5941745.77 N 558142.11E 0.945 4194.40 7802.39 93.010 181.940 3527.59 3636.59 4287.51 S 528.05 W 5941652.68 N 558144.94E 7.642 4287.51 7900.84 92.810 178.080 3522.59 3631.59 4385.81 S 528.07 W 5941554.38 N 558145.69E 3.921 4385.81 7996.69 90.200 176.430 3520.08 3629.08 4481.51 S 523.48 W 5941458.72 N 558151.03E 3.221 4481.51 8093.39 91.330 178.940 3518.78 3627.78 4578.11 S 519.57 W 5941362.15 N 558155.69E 2.846 4578.11 8190.50 88.720 180.770 3518.74 3627.74 4675.21 S 519.33 W 5941265.06 N 558156.69E 3.282 4675.21 8285.84 92.710 177.150 3517.55 3626.55 4770.49 S 517.60 W 5941169.79 N 558159.16E 5.650 4770.49 8382.04 91.810 178.000 3513.76 3622.76 4866.53 S 513.53 W 5941073.79 N 558163.97E 1.286 4866.53 8479.17 87.910 176.800 3514.00 3623.00 4963.54 S 509.13 W 5940976.82 N 558169.13E 4.201 4963.54 8574.62 81.760 183.380 3522.59 3631.59 5058.50 S 509.25 W 5940881.86 N 558169.75E 9.413 5058.50 8671.12 87.280 181.000 3531.81 3640.81 5154.45 S 512.91 W 5940785.89 N 558166.84E 6.224 5154.45 8767.39 87.810 181.940 3535.93 3644.93 5250.60 S 515.38 W 5940689.72 N 558165.12E 1.120 5250.60 8863.91 91.840 183.760 3536.23 3645.23 5346.97 S 520.18 W 5940593.31 N 558161.07E 4.581 5346.97 ConocoPhillips Comment • • 9 November, 2005 - 12:57 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Surrey Report for Kuparuk 1 J Pad -1 J--154 Your Ref.• API 500292325400 Job No. AK-ZZ-0003956462, Surveyed: 10 October, 2005 Wesfem North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 8962.55 90.830 181.810 3533.93 3642.93 5445.46 S 524.97 W 5940494.78 N 558157.05E 2.226 9028.36 89.520 179.890 3533.73 3642.73 5511.26 S 525.94 W 5940428.98 N 558156.58E 3.532 ~-~ 9063.00 89.520 179.890 3534.02 3643.02 ~ 5545.90 S 525.88 W 5940394.34 N ~ 558156.92E ' 0.000 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. c 1' ~ r° Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9063.OOft., The Bottom Hole Displacement is 5570.78ft., in the Direction of 185.417° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9063.00 3643.02 5545.90 S 525.88 W Projected Survey Survey tool program for 1J-154 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 719.00 718.67 To Measured Vertical Depth Depth (ft) (ft) 719.00 718.67 9063.00 3643.02 Survey Tool Description C B-SS-Gyro MW D+I I FR+MS+SAG ConocoPhilllps Vertical Section Comment 5445.46 5511.26 5545.90 Projected Survey • • 9 November, 2005 - 12:57 Page 5 of 5 DrillQuest 3.03.06.008 Message ~ ~ Maunder, Thoma~ E (DQA) Page 1 of 2 Fromc NSK Prod Engr Tech jn~ 13J c`(,,~conqcophiilips.com] Sent: Tu€~sday, D~c~mber 2Q, 20Q5 10:~4 AM Tc>: Thomas Maunder; Alisup-flrake, Sharon K Cc; NSK Freblem Well Supv; Spencee, Jeffrey A; Rodger~s, J~r~nes T; St~v~ McMains; GR~1 F'rc~d ~ngr; CPF2 Prod Engr~; GPF3 Prod Engrs; N~K West Sak Prod Engr Subje~t: RE: 1 J-154 and 1 J-164 e# a1 T~m, I have attempted to contact 5haron but have been unsuccessful. !t is possible that the 10-407's are already in the maif as iniectors. i have notifed Nai Hunt of verbaf appraval to b~gin pracfucing tt~e following wells: 1J-'154 (20~-03515002923254d0 1J-154L1 (205-(33~j 5(302923254~0 1J-154L2 [205-037] 500292325461 & 1J-~64 [205-144] 5Q0292327800 1,l-9f~4L1 [205-145} ~dt32923~7860 1J-154L2 {205-146~ 500292327861 In the even# of your recei~# of the 1D-40r's ~ompleted as inJectors please contact Bob 8uchhoiz ta r~enera#e 1fl- 403's for these welis. SNARON, PZease adjust you work process as described in this thread. 8ab 8uchhoiz ! Bob Christensen Greater Kuparuk Area Products~n Engineer€ng Technician Office (907) 659-7535 NSK-69 Pager {9(~7) 659-7000 (924) s~g P1~`'`' Cr~ i `, bq ~r. ,Si €.. %./ L ~.~ i ~'~~~~~~:~ ~..r'.... u~ ~ ia. -----Qriginal Mes~age----- From; Thorr~as Maund~r jmailto;tom_maundera~admin.state.ak.us] Sent; Tuesday, ~ecember 20, 2A05 iD:02 AM To: NSK Prc~d Enc~r Tech Cc: NSK Probl~m Well Supv; Spencer, Jeffrey A; Rc~dger~, James'F; Steve McMains 'auajeck: Re: 1]-f54 and 1J-164 et al Bob, Based Qn aur most recent discussion, I wanted to confirm wha# we discuss~d on 1J-154 [2QS-Q3S] (and laterals) and 1J-164 [205-144] {and laterals). Both of the~e welis are ultimate y p anr~e to be injeetion wells and were permitted as such. As a folivw-on tQ aur earlier eall, you have inforrned me that it is intended to "preproduce" botl~ of these welis for up ta 90 days. I hav~ c~ecked o~ur records and the connpletion~ reports (Form 4~7) have not been filed. ~Vh~n the completion reports are filed, the status should be 1-0IL. When it is d~termined to c~nvert fil~e welis ta injeeto~rs, tlie process outlinec~ in your original rr~essa~e should be followed. Thanks for checking on this matter. Again, please be sure that ~l~aron in Drilling is aware of this. Call ar message with any questions. Tom Ma~d~r, PE A()GCC Thomas Maunder wrote, On 12/20/2005 9:14 AM: ._ ~~-'~~.J ~-~.~~~ 716/2009 Message Page 2 of 2 ~ • Bob, This xs as we discuss~d. Tl~ere really isn't any approva~ to err~pioy tl~is pro~e~;ss so fa~r as I ean see. This proce~s will work, based on what I understand is CFAI's intent ta preprodu~e ali injec~ors. That intent makes the initial cornpletion 1-QIL as yQU not~, Please be sure that I?rilling Managem~nt and Sharan Allsup-Drake in drilling are awarE of this process. Sharon files the 407'~. Call ar message with any questions. Tom Maunder, PE AO~"rCC NSK Prad Engr Tech wirote, Qn 12/2Q/2005 9;05 AlV1: 'Tom, Per our discussian yesterday pertaining to the sundry proeess ~rorkflc~w for Wsak Pr~ Produced Inje~tors„ I am requesting the foNeau~Eng appraval to reduce canfusion and paperwork fQr these cases. 1) TMe permi# to drill 1~-401 is obt~ir~ed as an lnjectar (SVC) w~lt. 2) Th~ uvetl comple#ion 1~-407 will designate the w~tl ~s a Dev~lopment weli (i- 41L). 3) A~ubsequent Sundry Appiication 10-4~Q3 eonversion from 1-(?IL ta 9RWINJ will be obtain~:d prior to commencement o# Inj~ction. 4) A subsequsr~fi Sundry Report t0-404 (Injection) will be filed withi~ 3Q days post coriversion. f3asically ! would like to substitut~ the 1fl-4p7 #or a 1fl-443. Thi~ wil! s~op any c~nfusion and witl reduce the reporting by 9~ocument. Rleas~ let us knaw if we can proceed with this ehange in th~ proc~ss as so~n as possibie. Sob Suchhoiz / Bob Cttristensen Greater Kuparuk Area PrQduction En~ineerit~g Techr~ician Office (907} 659-7535 NSK-69 Pager (907) 659-7000 (924) ?!6/2Uf39 • • 05-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-154 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 9,063.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~. 10/31/05 ~lC~l~~~~h~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 3513 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 1R-16 11015756 PRODUCTION PROFILE 10124105 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1D-128 11015759 INJECTION PROFILE 10127/05 1 3J-06 11072927 SBHP SURVEY 10!30/05 1 3J-07A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10!23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10115/05 1 2Z-07 11022936 PRODUCTION PROFILE 10116/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 REDO 11015722 PRODUCTION PROFILE 08/29/05 1 2C-04 11022934 INJECTION PROFILE 10/14/05 1 M-07 REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10126/05 1 1R-10 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10124/05 1 1E-170 11015750 USIT 10/19105 1 1J-154 11022931 USIT 10/12105 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 SIGNED: (r[ DATE: J (~~~~! ,d` (? ~t ~'`- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • Re: USIT Files for 1J-154 • • Subject: Re: USIT Files for 1J-1 >4 From: Thomas Malu~iler ~'tc~m ~7uiunder c~,admin.state.ak.us=~~ Date: Thu,13`Ort ?OQS I x:19: I ~ -U~00 G 3 ~ To: "Greener, ~1ike R." <~~'like.RGreener<<i::conocophillihs.com~:> ~~s-~~ Thanks Mike. Looks like you set 7-5/8" a little longer than planned. Except for the sorry stuff around your surface shoe (which I think you want to be sorry) it looks pretty good. Goad slurry and good practices give good results. Tom Maunder, PE AOGCC - - Greener, Mike R. wrote, On 10!13/2005 1:10 PM: C'errlent band lob for the l.J-1.54. ~~'e reciprocated the pipe. up to 30` algid kept the pipe n~ovin~ up until the last 10 bbls before the plug bumped. -~----Original Message----- From: Doyon 141 Company Man Sent: Wednesday, October 12, 2005 9:44 AM To: Greener, Mike R. Subject: USIT Files <~~USI Cement_031.zip» «USI_Composite_031.zip» 114'ike Thornton /Scott Heim Doyon 141 Company Man O fee; 907-659-7170 Cell,- 907-943-1054 Fcxx; 907-659-7103 ` ~~ 1 of 1 1/9/2006 8:10 AM I\~~ ~ t ~ ~ ~ ~ ~l a ' ~ ]'1~ jl r~ i~. a J ~ r} { ~ a1 ~ ;~ ~ ld ~~ ~ ~ I! ~~ i~ '~ ~) ~ ~ a'~ a ~ ~~ ~ ~ ~ ~) ~ ~ ~ , ~ ~ ~, ~ ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~+ ~ t~~ n niJO-7~ O~ ~ l ' >' ' 333 W. 7'" AVENUE, SUITE 100 COI~TSFiRQA'1`IOI~1 COMr'IISSIOI~ ;.y ANCHORAGE, ALASKA 99501-3539 PHONE (907} 279-1433 ' FAX (907) 276-7542 Randy Thomas IJreater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. l?.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1 J-154 ConocoPhillips Alaska, Inc. Permit No: 205-035 Surface Location: 2133' FSL, 2569" FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1937' FNL, 2184' FWL, SEC. 11, TlON, R10E, UM Dear Mr. Thomas: Inclosed 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 approvals required t>y law from other governmental agencies, and does not authorize conducting drilling operations tultil 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission witness any required test. Contact the Commission's petroleum field inspector at (907) 65 X60 (pager). L)ATED this day of March, 2005 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 March 3, 2005 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 l MAC 0 '~ 2a~5 Alaakw Oil ~ Gas Ct?ns. Ctammileaien Anchorage Re: Applications for Permit to Drill, West Sak Injector, iJ-154, 1J-154 Li, 1J-154 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well, a trilateral horizontal well in the West Sak "A2", "B"and "D" sands. The main bore of the well will be designated iJ- :L54, and the lateral bores of the well will be designated iJ-154L1 and 1J-154L2. 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. l"he expected spud date of 1J-154 is April 26, 2005. If you have any questions or require any further information, please contact Shane Cloninger at 265- 6829. Sincerely, ~~~ ~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RE~~111 p~,' Mr~R Q ~ 205 1a. Type of Work: Drill ~ RedriN Re-entry ^ 1b. Current Weli Class: Exploratory Developm Multiply Zone f4k i! & ~iBS Cale °f~~~a,~ Slratigraphic Test ^ Service 0 Development Gas 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Na r: 1J-154 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12872' ~ ND: 3588' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2133' FSL, 2569' FEL, Sec. 35, T11N, R10E, UM ~ 7. Property Designation: ADL 25661 & 25662 West Sak Oil Pool Top of Productive Horizon: 218' FSL, 2190' FWL, Sec. 35, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 4/2612005 Total Depth: 1937 FNL, 2184' FWL, Sec. 11, T10N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to .,.- Zf w+a r~+a- K" Nearest Property: --~3-mites h~c=;> 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558640 ` y- 5945944 ~ Zone- 4 10. KB Elevation (Height above GL): 108' AMSL feet 15. Distance to Nearest ~ .+. ~ ~ Well within Poo -1 /,~Q~29- 16. Deviated wells: Kickoff depth: 700 ft. ' Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Downhole: 1652 psig Surface: 1248 psig ~ ~O~ 4y5 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2273' 28' 28' 2301' 2203' 470 sx AS Lite, 140 sx DeepCrete 9-718" 7-518" 29.7# L-80 BTCM 5322' 28' 28' 5350' 3671' 360 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 8432' 4440' 3526' 12872' 3588' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrilt and Re-Entry Operations) Total Depth MD (ft): Total Depth NO (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): Perforation Depth ND (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 Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Cloninger @ 265-6829 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature l ~ Phone ~5--6-~ 3a Date ''j/~rp,s" P nA D Commission Use Only Permit to Dr-il?l ` ` Number: G,v ~ ^t:.i~ 5~ API Number: ~f ~ 50- ~ ~~' -° Z~ ZS ~ L~ Permit Approval Date: See cover letter for other requirements Conditions of approval Samples required Yes ^ No ~ Mud log required Yes ^ No ,~ Hydrogen sulfide measures Yes ^ No ~1' `Dirercti-onal survey required Yes ~ No ^ Other: ~©Q r ~ ~CS~ . M ~T~CfiMC.~C,~JC~\lt~~ ~p~. 'tom. ~j~.~~~ot`, ©Q2~oc~S ~r a~~ / A~~3.~ APPROVED App THE COMMISSION Date: ~ Z Form -401 evis 06/2004 1 1 ~( ~ ~ ~ ~~~ F E / / Submit in Duplicate r~ :lt+..~ • Application for Permit to Drilt, Well 1J-154 Revision No.O Saved: 1-Mar-05 Permit It -West Sak Well #1J-154 App/ication for Permit to Dril/ Document Well llvlue Table of Contents 1. Well Name .................................................................................................................2 Requirements of 20 AAC 25.005 (1J ....................................................................................................... 2 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 Hazards Information ....................................................................................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 ....................................................................................4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Dri{ling Fluid Program ..............................................................................................4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Sun`ace Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ......................................................................................................5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-154 PERMIT 1T.doc Page 1 of 8 Printed: 1-Mar-05 ORIGINAL • Application for Permit to Drill, Well 1J-154 Revision No.0 Saved: 1-Mar-05 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 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ................................................................................................ 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ................................................................................................................ 8 Attachment 5 1/4 Mile Radius Effect for Injector ......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (f) Each weJ/ must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.04Q(b). For a wel! with multiple we/!branches, each branch must similarly be identified by a unique name and API number by adding a sufi<x to the name designated for the weli by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1]-154. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Dril! must be accompanied by each of the following items, except for an r'tem already on fete with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section Lines (B) the coordinates of the proposed location of the we// 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; (CJ the proposed depth of the we// at the top of each objective formation and at tota/depth; Location at Surtace 2 133' FSL 2 569` FEL Section 35 T11N R10E ' ASPZone 4 NAD 27 Coordinates RKB Elevation 108.0` AMSL Northingr 5,945,944 Eastings: 558,640 ~ Pad Elevation 80.0' AMSL Location at Top of Productive Interval West Sak "A2" Sand 218' FSL, 2,190' FWL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB•• 5 436 Northings: 5,944,025 Eastings: 558,135 Total Vertical De th RKB•• 3 671 Tota! 1/ertical De th SS.• 3 564 Location at Total De th 1 937' FNL 2 184' FWL Section 11 T10N R10E ASPZone 4 NAD 27 coordinates Measured De th RKB.• 12 872 Northings: 5,936,591 Eastings: 558,195 Total 1/ertica/De th RKB.• 3 588 Total I/ertica/ De th SS.• 3 480 1J-154 PERMIT IT.doc Page 2 of 8 Printed: 1-Mar-05 OR161NAL • and (D) other information required by 20 AAC25.050(b); Application for Permit to Drill, Well 1 J-154 Revision No.O Saved: 1-Mar-05 Requirements of 20 AAC 25.050(b) If a well is to be intentiana/ty deviated, the applicatian for a Permit to Dri/1(Form i0-40i) must (1) inc/ude a plat, drawn to a suitable sca/e, showing the path of the proposed wel/bore, indudirtg at1 adjacent we//bores within Z00 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for a/I wells within 200 feet of the proposed we!/bore (A) list the names of the operators of those wel/s, 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 application by certified mail; or (B) state that the applicant rs 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 Dri/1 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: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 A~4C 25.035, ZQ AAC 25.035, or 2f1 AAC25.037, as applicable,• An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-154. For all operations the stack will be equipped with ~-1/2" bo 6" variabie bore rams in the uppermost rain cavity, blind rams in the m'kidle cavity, and 7-5j8" rams in the bwerrrllost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug 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 shelf and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An applicatian for a Permit to Dri// must be accompanied by each of the following items, except for an item a/ready on fr/e with the commission and identified in the app/icatron: (4) information on dr111ing hazards, including (A) the maximum downho% 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 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. 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 A2 sand formation is 1,248 psi, calculated thusly: MPSP =(3,671 ft TVD)(0.45 - 0.11 psi/ft) =1,248 psi (&) data on potentia! gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes ofhale problems such as abnormally geo pressured strata, lost circutatian zones, and zanes that have a propensity for differential sticking; Please see Attachment 2: 1J-154 Drilling Hazards Summary. 1J-154 PERMIT lT.doc Page 3 of 8 Printed: 1-Mar-05 t„~ 6 ~ ~ ~ 1 6 ~4 i~1 s Application for Permit to Drill, Well 1 J-154 Revision No.O Saved: 1-Mar-05 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An appication for a Permit to Dri// must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(!?; 1J-154 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 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. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dri/l must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.1130, and a description ofany slotted /finer, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csgfrbg Size Weigh Length MD/TVD MD/TVD OD in in t Ibfft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCREfE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,273 28 / 28 2,301 /2,203 470 sx ASLite Lead, drift 140 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 5,322 28 / 28 5,350 / 3,671 2.531' MD / 2,427 TVD. Cemented w/ 360 sx Dee RETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 8,432 4,440 / 3,526 12,872 J 3,588 Slotted- no cement Slotted Lateral (1J-154) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 6,912 4,364/ 3,513 11,276 / 3,439 Slotted- no cement Slotted Lateral (1J-154 Li) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 6,922 4,048/ 3,441 10,970 / 3,366 Slotted- no cement Slotted Lateral (iJ-154 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drii/ must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the application; (7) a diagram and description of the diverter system as required by 20 AAC25.035, unless this requirement is waived by the commission under 20 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 iJ-154. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Dril! must be accompanied by each of the fol/awing items, except for an item already an file with the commission and identified in the applicatioon; (8) a dri/ling fluid program, including a diagram and description of the drilling flur"d system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-154 PERMIT IT.doc Page 4 of 8 Printed: 1-Mar-05 ORIGINAL • Surface Hole Mud Program (extended bentonite) Application for Permit to Drill, Well 1J-154 Revision No.O Saved: 1-Mar-05 Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9,6 Funnel Viscosity 150 250 200 300 seconds yield Point cP 50-70 50-70 30-50 30-50 Plastic Viscostiy lb/100 s 20-45 20-45 15-20 15-20 pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 APl Filtrate cc / 30 min NC-8.0 NC-8.0 5.0-7.0 5.0-7.0 *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4"Casing Shoe to 7-S/8" Casin Point Initial Value Density (ppg) 9.0-9.1 Funnel Viscosity. 45-60 (seconds) Plastic Viscostiy 12-18 (Ib/100 sf) Yield Point 26-35 (cP) API Filtrate 4-6 (cc / 30 min) Chlorides (mg/I) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) AIBID sand laterals Value Densit } 9.0 Plastic Viscostiy 15-25 Ib/100 s Yield Point 18-28 cP) HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical >600 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 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the appiicatr`on.~ (9) for an exploratory or stratigraphic test we/% a tabulation setting aut the depths of predicted abnormal/y geo pressured strata as required by 20 AAC 25, 0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on frle with the commission and identified in the app/ication; (10) for an exploratory or stratigraphic test we!>, a seismic refraction or reflection analysis as required by 20 AAC 25.051(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-154 PERMITIT.doc Page 5 of 8 Printed: 1-Mar-05 ORIGINAL • Application for Permit to Drill, Well 1J-154 Revision No.O Saved: 1-Mar-05 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on fife with the commission and identified in the app/ication: (I i) for a wet/ drilled from an offshore p/atform, mobile bottom-founded structure, jack-up rig, or floating dril/ing vessel, an analysts ofseabed conditions as required by ZOAAC15.t761(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/icatton for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application; (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Dril{ing Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except For an item already on file with the commission and identified in the application; The proposed drilling program is listed below. Please refer also to Attachment 4, Weil Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,301' MD / 2,203' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, 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 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 his before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. 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. (ECD's modeled to be less than 11.0 ppg} 8. Directionally drill to 7-5/8" casing point at 5,350 MD / 3,671' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 2,531' MD / 2,427' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging toots. RIH, clean out cement to 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 mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +j- 12,872' MD / 3,588' T~/D as per directional plan. 1J-154 PERMIT/T.doc Page 6 of 8 Printed: 1-Mar-05 s Application for Permit to Drill, Well 1J-154 Revision No.O Saved: 1-Mar-05 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. Run USIT log for cement bond. 17. PU and run 4-1/2" slotted liner. 18. Land finer, set liner hanger @ +/- 4,440' MD / 3,526' TVD. POOH. Note: Remaining operations are covered under the 1J-154L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 4,364' MD / 3,513' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 22. Dril! to TD of B sand lateral at 11,276' MD J 3,439' ND, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH, on elevators. 24. RIH. with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2" slotted liner. 26, RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and, set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 1J-154L2 Application for Permit to Dritl, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 4,048' MD / 3,411' TVD, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 10,970' MD / 3,366' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oi{ based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2"slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 39. POOH, laying down drill pipe as required. 40. PU completion as required and RIH to depth. Land tubing. Set BPV. 41. Nipple down BOPE, nipple up tree and test. Pull BPV. 1J-154 PERMIT 1T.doc Page 7 of 8 Printed: 1-Mar-05 Application for Permit to Drill, Well 1J-154 Revision No.0 Saved: 1-Mar-0S 42. Freeze protect well with diesel. 43. Set BPV and move rig off. 44. Rig up wire fine unit. Pull BPV. 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 46. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An appfr"cation for a Permit to Dri1/ must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application,' (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 2d AAC X5.080 far an annular disposal 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 iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated wilt be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay ~ Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal welt, 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. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic Attachment 5 % Mile Radius Effect for Injector 1J-154 PERMIT lT.doc Page 8 of 8 Printed: 1-Mar-05 ORIGINAL i- u (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-112" Open Hole / 10-3/4" Carina 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 Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 9-7/8" Open Hole / 7-5/8" Carina Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. 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 wei ht Abnormal Reservoir ~ Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, proper ho{e filling (use of trip sheets um in out 6-3/4" Open Hole / 4-112" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ORIGINAL 1J-154 Drilling Hazards Summary.doc prepared by Shane Cioninger 2/28/2005 9:03 AM • ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 J Pad Plan 1J-154 (M6) 1 J-154 Plan: 1 J-154 (wp05) Proposal Report 13 February, 2005 • QRtL4.1NG SERVECES ~. _ ~ _ ,._ A Halliburton Company OR161NAL '~~~~ °~.,J `F l `o G Conocophilli s p Alaska c w n O ig r d SHL @ 2133'FSL 8 2569' FEL -Sect 35 - T 11 N - R10F KOP :Begin Dir @ 4.00°/ 1 42" - Base of Permafrost /T3 / / K15 '~/ _ _- T3 + 550 --- - T3 + 675 _d Ugnu C Ugnu B / Ugnu A ~~ K13 =- West Sak D s_` _-~= C -- - ~- - \ B A4 A2 A3 B-Sand @ 80.00° Inc- Sail , 4364 ft MD, 3513 ft ND Land in A2-Sand @ 91.28°Inc - Geo Steer in Upper Lobe of A2 : 5436 ft MD, 3672 ft TVD 4 1/2" ____ Build @4.00°/100ft , 5154 ft MD, 3650 ft ND ~ 1 - BHL : 1937 FNL 8 2184' FWL -Sect 11 T10N - R10E 12871.92 ft MD, 3588.00 ft ND 7 5/8" Csg Pt :304' FSL & 2190' FWL - Sed 35 - T11 N - R10E : 5350.00 ft MD, 3670.85 ft ND F -1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 6250 6875 7500 8125 8750 9375 Vertical Section of 180.00° (1250 ft/in) Site: Kuparuk 1J Pad Well: Plan 1J-154 (NI6) WelliSOre: 1J-154 Plan: 1J-154 (wp06) LEGEND $ Plan 1J-154 (M6), 1J-154 L1, 1J-154 L1 (wp06) VO ~ Plan 1J-154 (M6), 1J-154 L2, 1J-154 L2 (wp06) VO $ 1J-154 (wp06) Begin Sail @ 25.25° Inc & 326.50° Azi, 1331 ft MD, 1311 ft ND Continue Dir @ 4.00°/t00ft , 1717 ft MD, 1660 ft ND Begin Sail @ 23.68° Inc & 326.17° Azi, 1756 ft MD, 1696 ft ND Continue Dir @ 5.00°/100ft , 2030 ft MD, 1947 ft ND 100ft, 700 ft MD, 700 ft TVD Continue Build @ 4 00°/100ft 950 ft MD 949 ft TVD Intersect D-Sand @ 76.00° Inc, 4048 ft MD, 3441 ft ND Build @3.00°/100ft , 4231 ft MD, 3485 ft TVD Begin Sail @ 76.00° Inc & 179.97° Azi, 3948 ft MD, 3417 ft ND 10 3/4" / ~- Project' nuparuK rtwar gnu ~OI'lOCO{~II~~IPS Site: Kuparuk 1J Pad ;~: =H., Well: Plan 1J-154 (M6) Wellbore: 1J-154 Plan: 1J-154 (wp06) West(-)/East(+) (1250 ft/in) -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 Continue Dir @ 5.00°/1 OOft , 2030 ft MD, 1947 ft TVD 10 3/4" Begin Sail @ 23.68° Inc & 326.17° Azi, 1756 ft MD, 1696 ft TVD 625 625 Continue Dir @ 4.00°/100ft, 1717 ft MD, 1660 ft TVD Begin Sail @ 76.00° Inc 8 179.97° Azi, 3948 ft MD, 3417 ft TVD ~2~ 0 27~, 1 Begin Sail @ 25.25° Inc & 326.50° Azi, 1331 ft MD, 1311 ft TVD 0 Intersect DSand @ 76.00° Inc, 4048 ft MD, 3441 ft TVD 42" 180° Continue Build @ 4.00°/100ft , 950 ft MD, 949 ft TVD -625 guild @3.00°/100ft , 4231 ft MD, 3485 ft TVD -1250 Intersect BSand @ 80.00° Inc -Sail , 4364 ft MD, 3513 ft TVD 180° Build @4.00°/1008 , 5154 ft MD, 3650 ft ND J -1875 180° -31 T ~imuths to True North Magnetic North: 25.01 ° Magnetic Field Strength: 57541.4nT Dip Angle: 80.71 ° Date: 10/30/2003 Model: BGGM2004 c 0 N L r 0 Z L 0 4 1/2" -625 KOP :Begin Dir @ 4.00°/100ft, 700 ft MD, 700 ft TVD -1250 SHL @ 2133'FSL & 2569' FEL -Sea 35 , T11 N - R10E -1875 5/8" Csg Pt :304' FSL & 2190' FVvL -Sect 35 - T11 N - R10E : 5350.00 ft M D, 3670.85 ft TVD 91.28°Inc - Geo Steer in Upper Labe of A2 : 5436 ft MD, 3672 ft TVD ~ o c 3 Z 0 N O c~ 3' BHL : 193T FNL & 2184' FWL -Sect 11 - T10N - R10E : 12871.92 ft MD, 3588.00 ft TVD -3125 -2500 -1875 -1250 -625 0 625 1250 West(-)/East(+) (1250 ft/in) 180° 160° 180° 180° 180° 180° 178° 180° 3125 3750 4375 125 ORIGINAL w • ~ Philli C Halliburton Company 5p@I'~I'~y-~UI'l onoco ps Planning Report -Geographic t v Alaska A Halliburton Company Database: EDM 2003:11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska Ina(Kuparuk) TVD Reference: Wellhead(108');~ 108.OOft (Wellhead(108'p Project: KuparukRiver Unit MD Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Site: Kuparuk 1J Pad North Reference: True ' Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-154 Design: 1 J-154 (wp06) 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 -- Well Plan 1J-154 (M6) Well Position +N/-S 0.00 ft Northing: 8,948,944.10 ft Latitude: 70° 15' 46.510" N +E/-W 0.00 ft Easting: 888,839.80 ft Longitude: 149° 31' 33.379" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft I Wellbore 1J-154 -~ ~ Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°1 InT) BGGM2004 10/30/2003 25.01 80.71 57,541 Design 1J-154 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +Nl-S +EI-W Direction (ft) Ift) (ftl (°) 28.00 0.00 0.00 180.00 2H3/2005 3:00.•12PM Page 2 of 10 COMPASS 2003.11 Build 50 ~~~~ / Philli C Halliburton Company ~p~ry-5U1'1 onoco ps Planning Report -Geographic ~ i ~ Alaska A Haweuno~ company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillipsAlaska Ina(Kuparuk) TVDReference: Wellhead(108').@108.OOft(Welihead(108'p Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108.OOft (Wellhead(108'p Site: Kuparuk 1J Pad North Reference: True ~ Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wetlbore: 1 J-154 Design: 1 J-154 (wp06} Plan Summary Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NI-S +EI_yy Rate Rate Rate TFO (~) ( °) (° ) (ftl (~) eft) (°/100ft) (°f100ft) (°/100ft) (°) 28.00 0. 00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0. 00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 0.00 950.00 10 .00 326 .50 948.73 18.15 -12.01 4.00 4.00 0.00 326.50 1,331.25 25 .25 326 .50 1,311.01 114.12 -75.54 4.00 4.00 0.00 0.00 1,716.67 25 .25 326 .50 1,659.61 251.22 -166.28 0.00. 0.00 0.00 0.00 1,756.13 23 .68 326 .17 1,695.53 264.82 -175.34 4.00 -3.99 -0.83 -175.21 2,030.48 23 .68 326 .17 1,946.78 356.34 -236.67 0.00 0.00 0.00 0.00 3,947.85 76 .00 179 .97 3,416.81 -452.09 -519.89 5.00 2.73 -7.63 -147.14 4,047.85 76 .00 179 .97 3,441.00 -549.12 -519.84 0.00 0.00 0.00 0.00 4,230.85 76 .00 179. .97 3,485.27 -726.69 -519.75 0.00 0.00 0.00 0.00 4,364.24 80 .00 179 .97 3,513.00 -857.14 -519.68 3.00 3.00 0.00 0.00 5,153.74 80 .00 179 .97 3,650.10 -1,634.64 -519.27 0.00 0.00 0.00 0.00 5,435.75 91 .28 180 .06 3,671.50 -1,915.38 -519.36 4.00 4.00 0.03 0.47 5,715.77 91 .38 180 .06 3,665.00 -2,195.33 -519.66 0.04 0.04 0.00 0.00 5,727.88 91 .74 180 .03 3,664.67 -2,207.43 -519.67 3.00 2.98 -0.30 -5.78 6,671.33 91 .74 180 .03 3,636.00 -3,150.45 -520.10 0.00 0.00 0.00 0.00 6,705.01 90 .74 179 .93 3,635.27 -3,184.12 -520.08 3.00 -2.99 -0.30 -174.33 7,115.43 90 .74 179 .93 3,630.00 -3,594.51 -519.56 0.00 0.00 0.00 0.00 7,125.78 91 .04 180 .00 3,629.84 -3,604.86 -519.55 3.00 2.91 0.74 14.34 7,890.66 91 .04 180 .00 3,616.00 -4,369.61 -519.59 0.00 0.00 0.00 0.00 7,987.36 88 .14 180 .05 3,616.70 -4,466.29 -519.63 3.00 -3.00 0.05 179.14 8,315.77 88 .14 180 .05 3,627.38 -4,794.53 -519.90 0.00 0.00 0.00 0.00 8,429.11 .91 .54 180 .12 3,627.70 -4,907.85 -520.07 3.00 3.00 0.07 1.31 9,015.20 91 .54 180 .12 3,612.00 -5,493.73 -521.35 0.00 0.00 0.00 0.00 9,051.46 90 .45 180 .06 3,611.37 -5,529.98 -521.40 3.00 -2.99 -0.18 -176.47 9,608.30 90 .45 180 .06 3,607.00 -6,086.80 -521.97 0.00 0.00 0.00 0.00 9,609.23. 90 .46 180 .03 3,606.99 -6,087.73 -521.97 3.00 0.77 -2.90 -75.21 10,987.51 90 .46 180 .03 3,596.00 -7,465.97 -522.71 0.00 0.00 0.00 0.00 11,045.10 89 .95 178 .38 3,595.79 -7,523.56 -521.91 3.00 -0.88 -2.87 -107.01 11,287.71 89 .95 178 .38 3,596.00 -7,766.07 -515.04 0.00 0.00 0.00 0.00 11,346.78 90. 30 180 .12 3,595.87 -7,825.13 -514.27 3.00 0.58 2.94 78.80 12,871.93 90 .30 180 .12 3,588.00 -9,350.25 -517.38 0.00 0.00 0.00 0.00 2/13/2005 3:00:12PM Page 3 of 10 COMPASS 2003.11 Build 50 OnI~IPIAL ~ Philii C Halliburton Company ~p~-,r,y_~,,, onoco ps Planning Report -Geographic Alaska A Halll6unon Company Database: EDM2003.11 Singie User Db Local Coordinate Reference: Weli Plan 1J-154 (Mlip Company: ConocoPhillips Alaska Ina(Kuparuk) TVD Reference: Wellhead(108') !~ 108.OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108:OOft (Wellhead(108')) Site: Kuparuk 1JPad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Welibore: 1 J-154 Design: 1J-154 (wp06) Planned Survey 1J-154 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +EI-W Northing Easting DLSEV Vert Section ' i (ftl (°) 1°) fft) (ftl (ft) Ift) (ft) Ift) 1°HOOft) Iftl 28.00 0.00 0.00 28.00 -80.00 0.00 0.00 5,945,944.10 ~ 558,639.50 0.00 0.00 SHL ~ 2133'FSL & 2569' FEL -Sect 35 - T71 N - R10E 80.00 0.00 0.00 80.00 -28.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 ~,. 100.00 0.00 0.00 100.00 -8.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 200.00 0.00 0.00 200.00 92.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 300.00 0.00 0.00 300.00 192.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 400.00 0.00 0.00 400.00 292.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 500.00 0.00 0.00 500.00 392.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 600.00 0.00 0.00 600.00 492.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 700.00 0.00 0.00 700.00 592.00 0.00 0.00 5,945,944.10 558,639.50 0.00 0.00 KOP :Begin Dir ~ 4.00°I1 00ft, 700 ft MD, 700 ft TVD 800.00 4.00 326.50 799.92 691.92 2.91 -1.93 5,945,946.99 558,637.55 4.00 -2.91 900.00 8.00 326.50 899.35 791.35 11.62 -7.69 5,945,955.66 558,631.72 4.00 -11.62 950.00 10.00 326.50 948.73 840.73 18.15 -12.01 5,945,962.15 558,627.35 4.00 -18.15 Continue Build ~ 4.00°1100ft , 950 ft MD, 949 ft TVD 1,000.00 12.00 326.50 997.81 889.81 26.10 -17.28 5,945,970.06 558,622.02 4.00 -26.10 1,100.00 16.00 326.50 1,094.82 986.82 46.27 -30.63 5,945,990.13 558,608.52 4.00 -46.27 1,200.00 20.00 326.50 1,189.91 1,081.91 72.03 -47.68 5,946,015.75 558,591.27 4.00 -72.03 1,300.00 24.00 326.50 1,282.61 1,174.61 103.27 -68.35 5,946,046.82 558,570.35 4.00 -103.27 1,331.25 25.25 326.50 1,311.01 1,203.01 114.12 -75.54 5,946,057.62 558,563.08 4.00 -114.12 Begin Sall ~ 25.25° Inc 8 326.80° Azi, 1331 ft MD,1311 ft TVD 1,400.00 25.25 326.50 1,373.20 1,265.20 138.58 -91.72 5,946,081.95 558,546.71 0.00 -138.58 1,500.00 25.25 326.50 1,463.64 1,355.64 174.15 -115.27 5,946,117.33 558,522.89 0.00 -174.15 1,582.21 25.25 326.50 1,538.00 1,430.00 203.39 -134.62 5,946,146.42 558,503.31 0.00 -203.39 Base of Permafrost 1,600.00 25.25 326.50 1,554.09 1,446.09 209.72 -138.81 5,946,152.71 558,499.07 0.00 -209.72 1,700.00 25.25 326.50 1,644.53 1,536.53 245.29 -162.36 5,946,188.10 558,475.26 0.00 -245.29 1,704.94 25.25 326.50 1,649.00 1,541.00 247.05 -163.52 5,946,189.84 558,474.08 0,00 -247.05 T3 1,716.67 25.25 326.50 1,659.61 1,551.61 251.22 -166.28 5,946,193.99 558,471.29 0.00 -251.22 Continue Dir ~ 4.00°HOOft,1717 ft MD, 1660 ft TVD 1,756.13 23.68 326.17 1,695.53 1,587.53 264.82 -175.34 5,946,207.52 558,462.12 4.00 -264.82 Begin Sail ~ 23.68° Inc & 326.17° Azi, 1756 ft MD,1696 ft TVD 1,800.00 23.68 326.17 1,735.70 1,627.70 279.46 -185.14 5,946,222.08 558,452.20 0.00 -279.46 1,900.00 23.68 326.17 1,827.29 1,719.29 312.82 -207.50 5,946,255.26 558,429.59 0.00 -312.82 2,000.00 23.68 326.17 1,918.87 1,810.87 346.18 -229.86 5,946,288.44 558,406.98 0.00 -346.18 2,016.52 23.68 326.17 1,934.00 1,826.00 351.69 -233.55 5,946,293.93 558,403.24 0.00 -351.69 K75 2,030.48 23.68 326.17 1,946.78 1,838.78 356.34 -236.67 5,946,298.56 558,400.08 0.00 -356.34 Continue Dir ~ 5.00°I100ft , 2030 ft MD,1947 ft TVD 2,100.00 20.84 320.87 2,011.12 1,903.12 377.54 -252.25 5,946,319.63 558,384.34 5.00 -377.54 2,200.00 17.15 310.43 2,105.69 1,997.69 400.91 -274.71 5,946,342.82 558,361.70 5.00 -400.91 2,300.00 14.25 295.27 2,201.99 2,093.99 415.74 -297.08 5,946,357.47 558,339.22 5.00 -415.74 2/13/2005 3:00:12PM Page 4 0/ 10 COMPASS 2003.11 Build 50 ORIGINAL s • ~ Halliburton Company 5pe~-+ry-~U1~1 Co110co Phillips Planning Report -Geographic i AI2SI(cl A HallibuROn Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Weil Plan 1J-154 (M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) ND Reference: Weilhead(108') ~ 108.OOft (Well head(108')) Project: KuparukRivet Unit MD Reference: VVellhead(108') @ 108.OOft (Weil head(108')) Site: Kuparuk TJ Pad No rth Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-154 Design: 1J-154 (wp06) Planned Survey 1J-154 (wp06) Map Map MD I nclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section Iftl (°) (°) Ift) Ift- (ft) (ft) (ft) Ift) (°/100ft) Ift) 2,301.04 14.23 295.08 2,203.00 2,095.00 415.85 -297.31 5,946,357.58 558,338.99 5.04 -415.85 T3 +550 -10 314" Casing Pt 2,400.00 12.70 274.74 2,299.29 2,191.29 421.90 -319.19 5,946,363.46 558,317.07 5.00 -421.90 2,427.38 12.59 268.50 2,326.00 2,218.00 422.07 -325.17 5,946,363.59 558,311.09 5.00 -422.07 T3 + 875 2,500.00 12.99 252.15 2,396.84 2,288.84 419.36 -340.86 5,946,360.76 558,295.42 5.00 -419.36 2,600.00 15.01 233.12 2,493.92 2,385.92 408.14 -361.93 5,946,349.37 558,274.43 5.00 -408.14 2,700.00 18.20 219.55 2,589.77 2,481.77 388.31 -382.25 5,946,329.38 558,254.27 5.00 -388.31 2,800.00 22.05 210.23 2,683.67 2,575.67 360.03 -401.66 5,946,300.95 558,235.09 5.00 -360.03 2,900.00 26.27 203.67 2,774.91 2,666.91 323.51 -420.00 5,946,264.30 558,217.03 5.00 -323.51 3,000.00 30.72 198.85 2,862.78 2,754.78 279.04 -437.15 5,946,219.70 558,200.23 5.00 -279.04 3,031.91 32.17 197.57 2,890.00 2,782.00 263.23 -442.35 5,946,203.85 558,195.16 5.00 -263.23 Ugnu C 3,100.00 35.30 195.16 2,946.62 2,838.62 226.95 -452.97 5,946,167.49 558,184.82 5.00 -226.95 3,200.00 39.97 192.23 3,025.80 2,917.80 167.63 -467.33 5,946,108.07 558,170.92 5.00 -167.63 3,300.00 44.70 189.82 3,099.71 2,991.71 101.54 -480.14 5,946,041.89 558,158.63 5.00 -101.54 3,314.57 45.39 189.50 3,110.00 3,002.00 91.38 -481.87 5,946,031.71 558,156.98 5.00 -91.38 Ugnu B 3,400.00 49.47 187.78 3,167.78 .3,059.78 29.19 -491.29 5,945,969.46 558;148.04 5.00 -29.19 3,425.28 50.68 187.31 3,184.00 3,076.00 9.97 -493.84 5,945,950.23 558,145.65 5.00 -9.97 Ugnu A 3,500.00 54.28 186.02 3,229.50 3,121.50 -48.89 -500.70 5,945,891.32 558,139.24 5.00 48.89 3,600.00 59.10 184.46 3,284.41 3,176.41 -132.08 -508.29 5,945,808.08 558,132.30 5.00 132.08 3,641.32 61.10 183.86 3,305.00 3,197.00 -167.81 -510.89 5,945,772.34 558,129.98 5.00 167.81 K13 3,700.00 63.95 183.05 3,332.07 3,224.07 -219.77 -514.02 5,945,720.36 558,127.26 5.00 219.77 3,800.00 68.80 181.75 3,372.13 3,264.13 -311.28 -517.83 5,945,628.83 558,124.16 5.00 311.28 3,900.00 73.67 180.53 3,404.29 3,296.29 -405.91 -519.69 5,945,534.19 558,123.03 5.00 405.91 3,947.85 76.00 179.97 3,416.81 3,308.81 -452.09 -519.89 5,945,488.02 558,123.19 5.00 452.09 Begin Sail ~ 78.00° Inc & 179.87° Azi, 3948 ft MD, 3417 ft ND 4,000.00 76.00 179.97 3,429.42 3,321.42 -502.70 -519.87 5,945,437.42 558,123.61 0.00 502.70 4,047.85 76.00 179.97 3,441.00 3,333.00 -549.12 -519.84 5,945,391.00 558,124.00 0.00 549.12 Intersect D-Sa nd ~ 78.00° Inc, 4048 ft MD, 3441 ft N D -West Sak D -1 J-164 Otop (v3) 4,100.00 76.00 179.97 3,453.62 3,345.62 -599.73 ~~~-519.82 5,945,340.40 558,124.42 0.00 599.73 4,200.00 76.00 179.97 3,477.81 3,369.81 -696.75 -519.76 5,945,243.39 558,125.23 0.00 696.75 4,209.06 76.00 179.97 3,480.00 3,372.00 -705.54 -519.76 5,945,234.60 558,125.30 0.00 705.54 C 4,230.85 76.00 179.97 3,485.27 3,377.27 -726.69 -519.75 5,945,213.46 558,125.48 0.00 726.69 Build 03.00°/100tt, 4231 ft MD, 3485 ft ND 4,300.00 78.07 179.97 3,500.78 3,392.78 -794.07 -519.71 5,945,146.08 558,126.04 3.00 794.07 4,364.24 80.00 179.97 3,513.00 3,405.00 -857.14 -519.68 5,945,083.02 558,126.56 3.00 857.14 Intersect BSa nd ~ 80.00° Inc -Sail , 4384 ft MD, 3513 ft ND 4,400.00 80.00 179.97 3,519.21 3,411.21 -892.35 -519.66 5,945,047.81 558,126.85 0.00 892.35 4,500.00 80.00 179.97 3,536.57 3,428.57 -990.83 -519.61 5,944,949.34 558,127.67 0.00 990.83 2/13/2005 3:00:12PM Page 5 of 10 COMPASS 2003.11 Build 50 ORIGINAL ~ C Philli Hallibutton Company ~~7@rl~'~l/-SL.N'1 onoco ps Planning Report -Geographic Alaska A hlalllhunon Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: WeII Plan 1J-154 {M6) Company: ConocoPhillips Alaska lna(Kuparuk) ND Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Site: Koparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-154 Design: 1J-154 (wp06) Planned Survey iJ-154 (wp06} Map Map MD Inclination Azimuth TVD SSTVD +W-S +EI-W Northing Easting DLSEV Vert Section (ft) (°) (°) Ift) (ftl Ift) (ft) (ft) Iftl t°MOOft) (ftl 4,600.00 80.00 179.97 3,553.94 3,445.94 -1,089.32 -519.56 5,944,850.88 558,128.49 0.00 1,089.32 4,606.11 80.00 179.97 3,555.00 3,447.00 -1,095.33 -519.56 5,944,844.86 558,128.54 0.00 1,095.33 A4 4,700.00 80.00 179.97 3,571.30 3,463.30 -1,187.80 -519.51 5,944,752.41 558,129.31 0.00 1,187.80 4,800.00 80.00 179.97 3,588.67 3,480.67 -1,286.28 -519.46 5,944,653.94 558,130.13 0.00 1,286.28 4,836.46 80.00 179.97 3,595.00 3,487.00 -1,322.18 -519.44 5,944,618.04 558,130.42 0.00 1,322.18 A3 4,900.00 80.00 179.97 3,606.03 3,498.03 -1,384.76 -519.40 5,944,555.47 558,130.94 0.00 1,384.76 4,922.84 80.00 179.97 3,610.00 3,502.00 -1,407.25 -519.39 5,944,532.98 558,131.13 0.00 1,407.25 5,000.00 80.00 179.97 3,623.40 3,515.40 -1,483.24 -519.35 5,944,457.00 5,043.77 80.00 179.97 3,631.00 3,523.00 -1,526.35 -519.33 5,944,413.90 5,100.00 80.00 179.97 3,640.76 3,532.76 -1,581.72 -519.30 5,944,358.54 5,153.74 80.00 179.97 3,650.10 3,542.10 -1,634.64 -519.27 5,944,305.62 Build X4.00°NOOft , 5154 ft MD, 3850 ft TVD 5,200.00 81.85 179.99 3,657.39 3,549.39 -1,680.32 -519.26 5,944,259.95 5,300.00 85.85 180.02 3,668.10 3,560.10 -1,779.73 -519.26 5,944,160.56 5,350.00 87.85 180.03 3,670.85 3,562.85 -1,829.65 -519.28 5,944,110.64 7 5/8" Csg Pt :304' FSL & 2190' FWL -Sect 35 - T11 N - R10E : 5350.00 ft MD, 3870.85 ft TVD - A2 5,400.00 89.85 180.05 3,671.85 3,563.85 -1,879.64 -519.32 5,944,060.66 5,435.75 91.28 180.06 3,671.50 3,563.50 -1,915.38 -519.36 5,944,024.92 Land in A2-Sand ~ 91.28°Inc - Geo Steer in Upper Lobe of A2 : 5436 ft MD, 3572 ft TVD 5,500.00 91.30 180.06 3,670.05 3,562.05 -1,979.62 -519.43 5,943,960.69 5,600.00 91.34 180.06 3,667.75 3,559.75 -2,079.59 -519.53 5,943,860.73 5,700.00 91.37 180.06 3,665.38 3,557.38 -2,179.56 -519.64 5,943,760.77 5,715.77 91.38 180.06 3,665.00 3,557.00 -2,195.33 -519.66 5,943,745.00 5,727.88 91.74 180.03 3,664.67 3,556.67 -2,207.43 -519.67 5,943,732.90 5,800.00 91.74 180.03 3,662.48 3,554.48 -2,279.52 -519.70 5,943,660.82 5,900.00 91.74 180.03 3,659.44 3,551.44 -2,379.47 -519.75 5,943,560.88 6,000.00 91.74 180.03 3,656.40 3,548.40 -2,479.43 -519.79 5,943,460.94 6,100.00 91.74 180.03 3,653.36 3,545.36 -2,579.38 -519.84 5,943,361.00 6,200.00 91.74 180.03 3,650.32 3,542.32 -2,679.33 -519.88 5,943,261.06 6,300.00 91.74 180.03 3,647.28 3,539.28 -2,779.29 -519.93 5,943,161.11 6,400.00 91.74 180.03 3,644.25 3,536.25 -2,879.24 -519.98 5,943,061.17 6,500.00 91.74 180.03 3,641.21 3,533.21 -2,979.20 -520.02 5,942,961.23 6,600.00 91.74 180.03 3,638.17 3,530.17 -3,079.15 -520.07 5,942,861.29 6,671.33 91.74 180.03 3,636.00 3,528.00 -3,150.45 -520.10 5,942,790.00 1J-154 TS (v3) 6,700.00 90.89 179.94 3,635.34 3,527.34 -3,179.11 -520.09 5,942,761.34 6,705.01 90.74 179.93 3,635.27 3,527.27 -3,184.12 -520.08 5,942,756.33 6,800.00 90.74 179.93. 3,634.05 3,526.05 -3,279.10 -519.96 5,942,661.37 6,900.00 90.74 179.93 3,632.77 3,524.77 -3,379.09 -519.83 5,942,561.39 7,000.00 90.74 179.93 3,631.48 3,523.48 -3,479.08 -519.71 5,942,461.41 7,100.00 90.74 179.93 3,630.20 3,522.20 -3,579.08 -519.58 5,942,361.43 558,131 .76 0.00 1,483.24 558,132 .12 0.00 1,526.35 558,132 .58 0.00 1,581.72 558,133 .02 0.00 1,634.64 558,133 .39 4.00 1,680.32 558,134 .17 4.00 1,779.73 558,134 .53 4.00 1,829.65 558,134 .88 4.00 1,879.64 558,135 .13 4.00 1,915.38 558,135 .56 0.04 1,979.62 558,136 .23 0.04 2,079.59 558,136 .89 0.04 2,179.56 558,137 .00 0.04 2,195.33 558,137 .08 3.00 2,207.43 558,137 .61 0.00 2,279.52 558,138 .35 0.00 2,379.47 558,139 .08 0.00 2,479.43 558,139 .81 0.00 2,579.38 558,140 .55 0.00 2,679.33 558,141 .28 0.00 2,779.29 558,142 .01 0.00 2,879.24 558,142 .74 0.00 2,979.20 558,143 .48 0.00 3,079.15 558,144 .00 0.00 3,150.45 558,144 .23 3.00 3,179.11 558,144 .28 3.00 3,184.12 558,145 .14 0.00 3,279.10 558,146 .05 0.00 3,379.09 558,146 .95 0.00 3,479.08 558,147 .86 0.00 3,579.08 2/13/2005 3:00:12PM Page 6 of 10 COMPASS 2003.11 Build 50 OR!r,IpJAL • ~-' II C ~ Halliburton Company ~p~ry-gun OIIOCO IpS I Planning Report -Geographic t Alaska A wIIlEUnon Company Database: EDM 2003.11 Single UserDb LocaPCo-oMinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: Wellhead(108') @ 108.OOft (Vllellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108.OOft (Wellhead(108'))s Site: Kuparuk 1J Pad North Reference: True Well: PIan,1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J 154 Design: 1J-154 (wp06) Planned Survey 1J-154 (wp06) j Map Map MD Inclination Azimuth TVD SSTVO +NI-S +EI-W Northing Easting DLSEV Vert Section (ft- (°) (°) I1t1 Ift- (~) (ft) Iff) Iftl 1°/100ft1 Iftl 7,115.43 90.74 179.93 3,630.00 3,522.00 -3,594.51 -519.56 5,942,346.00 558,148.00 0.00 3,594.51 1J-154 T4 (v3) 7,125.78 91.04 180.00 3,629.84 3,521.84 -3,604.86 -519.55 5,942,335.65 558,148.09 3.00 3,604.86 7,200.00 91.04 180.00 3,628.50 3,520.50 -3,679.06 -519.55 5,942,261.46 558,148.66 0.00 3,679.06 7,300.00 91.04 180.00 3,626.69 3,518.69 -3,779.04 -519.56 5,942,161.49 558,149.43 0.00 3,779.04 7,400.00 91.04 180.00 3,624.88 3,516.88 -3,879.03 -519.57 5,942,061.52 558,150.21 0.00 3,879.03 7,500.00 91.04 180.00 3,623.07 3,515.07 -3,979.01 -519.57 5,941,961.55 558,150.98 0.00 3,979.01 7,600.00 91.04 180.00 3,621.26 3,513.26 -4,079.00 -519.58 5,941,861.57 558,151.75 0.00 4,079.00 7,700.00 91.04 180.00 3,619.45 3,511.45 -4,178.98 -519.58 5,941,761.60 558,152.53 0.00 4,178.98 7,800.00 91.04 180.00 3,617.64 3,509.64 -4,278.96 -519.59 5,941,661.63 558,153.30 0.00 4,278.96 7,890.66 91.04 180.00 3,616.00 3,508.00 -4,369.61 -519.59 5,941,571.00 558,154.00 0.00 4,369.61 1J-154 TS (v3) 7,900.00 90.76 180.01 3,615.85 3,507.85 -4,378.95 -519.59 5,941,561.66 558,154.07 2.99 4,378.95 7,987.36 88.14 180.05 3,616.70 3,508.70 -4,466.29 -519.63 5,941,474.32 558,154.71 3.00 4,466.29 8,000.00 88.14 180.05 3,617.11 3,509.11 -4,478.93 -519.65 5,941,461.69 558,154.80 0.00 4,478.93 8,100.00 88.14 180.05 3,620.36 3,512.36 -4,578.88 -519.73 5,941,361.76 558,155.50 0.00 4,578.88 8,200.00 88.14 180.05 3,623.61 3,515.61 -4,678.82 -519.81 5,941,261.82 558,156.19 0.00 4,678.82 8,300.00 88.14 180.05 3,626.87 3,518.87 -4,778.77 -519.89 5,941,161.89 558,156.89 0.00 4,778.77 8,315.77 88.14 180.05 3,627.38 3,519.38 -4,794.53 -519.90 5,941,146.13 558,157.00 0.00 4,794.53 1J-154 T7 (v3) 8,400.00 90.66 180.10 3,628.26 3,520.26 -4,878.75 -520.01 5,941,061.92 558,157.54 3.00 4,878.75 8,429.11 91.54 180.12 3,627.70 3,519.70 -4,907.85 -520.07 5,941,032.82 558,157.71 3.00 4,907.85 8,500.00 91.54 180.12 3,625.80 3,517.80 -4,978.72 -520.23 5,940,961.96 558,158.11 0.00 4,978.72 8,600.00 91.54 180.12 3,623.13 3,515.13 -5,078.68 -520.44 5,940,862.01 558,158.67 0.00 5,078.68 8,700.00 91.54 180.12 3,620.45 3,512.45 -5,178.65 -520.66 5,940,762.05 558,159.23 0.00 5,178.65 8,800.00 91.54 180.12 3,617.77 3,509.77 -5,278.61 -520.88 5,940,662.10 558,159.79 0.00 5,278.61 8,900.00 91.54 180.12 3,615.09 3,507.09 -5,378.57 -521.10 5,940,562.15 558,160.35 0.00 5,378.57 9,000.00 91.54 180.12 3,612.41 3,504.41 -5,478.54 -521.31 5,940,462.20 558,160.91 0.00 5,478.54 9,015.20 91.54 180.12 3,612.00 3,504.00 -5,493.73 -521.35 5,940,447.00 558,161.00 0.00 5,493.73 1J-154 TS (v3) 9,051.46 90.45 180.06 3,611.37 3,503.37 -5,529.98 -521.40 5,940,410.76 558,161.22 3.00 5,529.98 9,100.00 90.45 180.06 3,610.99 3,502.99 -5,578.52 -521.45 5,940,362.22 558,161.55 0.00 5,578.52 9,200.00 90.45 180.06 3,610.21 3,502.21 -5,678.52 -521.55 5,940,262.24 558,162.23 0.00 5,678.52 9,300.00 90.45 180.06 3,609.42 3,501.42 -5,778.52 -521.65 5,940,162.25 558,162.91 0.00 5,778.52 9,400.00 90.45 180.06 3,608.64 3,500.64 -5,878.51 -521.76 5,940,062.27 558,163.59 0.00 5,878.51 9,500.00 90.45 180.06 3,607.85 3,499.85 -5,978.51 -521.86 5,939,962.28 558,164.27 0.00 5,978.51 9,600.00 90.45 180.06 3,607.07 3,499.07 -6,078.51 -521.96 5,939,862.30 558,164.94 0.00 6,078.51 9,608.30 90.45 180.06 3,607.00 3,499.00 -6,086.80 -521.97 5,939,854.00 558,165.00 0.00 6,086.80 1J-154 T9 (v3) 9,609.23 90.46 180.03 3,606.99 3,498.99 -6,087.73 -521.97 5,939,853.07 558,165.01 3.00 6,087.73 9,700.00 90.46 180.03 3,606.27 3,498.27 -6,178.51 -522.01 5,939,762.31 558,165.66 0.00 6,178.51 9,800.00 90.46 180.03 3,605.47 3,497.47 -6,278.50 -522.07 5,939,662.33 558,166.39 0.00 6,278.50 9,900.00 90.46 180.03 3,604.67 3,496.67 -6,378.50 -522.12 5,939,562.34 558,167.11 0.00 6,378.50 10,000.00 90.46 180.03 3,603.88 3,495.88 -6,478.50 -522.18 5,939,462.36 558,167.84 0.00 6,478.50 10,100.00 90.46 180.03 3,603.08 3,495.08 -6,578.49 -522.23 5,939,362.37 558,168.56 0.00 6,578.49 10,200.00 90.46 180.03 3,602.28 3,494.28 -6,678.49 -522.28 5,939,262.39 558,169.29 0.00 6,678.49 10,300.00 90.46 180.03 3,601.48 3,493.48 -6,778.49 -522.34 5,939,162.40 558,170.02 0.00 6,778.49 10,400.00 90.46 180.03 3,600.69 3,492.69 -6,878.48 -522.39 5,939,062.42 558,170.74 0.00 6,878.48 2/13/2005 3:00:12PM Page 7 of 10 COMPASS 2003.11 Build 50 ORI'311VAL • ConocoPhillips Alaska Database: EDM 2003:11 Single User Db Company: ConocoPhillips Alaska Inc.(Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-154 (M6) Welllwre: 1 J-1.54 Design: 1J-154 (wp06) Planned Survey 1J-154 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E/_yy Northing Easting DLSEV Vert Section Iftl (°) (°) Ift) Ift) (ft) (ft) Ift) Ift) (°HOOft) Ift) 10,500.00 90.46 180.03 3,599.89 3,491.89 -6,978.48 -522.44 5,938,962.43 558,171.47 0.00 6,978.48 10,600.00 90.46 180.03 3,599.09 3,491.09 -7,078.48 -522.50 5,938,862.45 558,172.19 0.00 7,078.48 10,700.00 90.46 180.03 3,598.29 3,490.29 -7,178.47 -522.55 5,938,762.46 558,172.92 0.00 7,178.47 10,800.00 90.46 180.03 3,597.50 3,489.50 -7,278.47 -522.60 5,938,662.48 558,173.64 0.00 7,278.47 10,900.00 90.46 180.03 3,596.70 3,488.70 -7,378.47 -522.66 5,938,562.50 558,174.37 0.00 7,378.47 10,987.51 90.46 180.03 3,596.00 3,488.00 -7,465.97 -522.71 5,938,475.00 558,175.00 0.00 7,465.97 1J-154 Dtoe (v3) 11,000.00 90.35 179.67 3,595.91 3,487.91 -7,478.46 -522.67 5,938,462.51 558,175.13 2.99 7,478.46 11,045.10 89.95 178.38 3,595.79 3,487.79 -7,523.56 -521.91 5,938,417.43 558,176.25 3.00 7,523.56 11,100.00 89.95 178.38 3,595.84 3,487.84 -7,578.43 -520.35 5,938,362.57 558,178.23 0.00 7,578.43 11,200.00 89.95 178.38 3,595.93 3,487.93 -7,678.39 -517.52 5,938,262.65 558,181.84 0.00 7,678.39 11,287.71 89.95 178.38 3,596.00 3,488.00 -7,766.07 -515.04 5,938,175.00 558,185.00 0.00 7,766.07 1J•1S4 Btoe (v3) 11,300.00 90.02 178.74 3,596.00 3,488.00 -7,778.36 -514.73 5,938,162.72 558,185.40 2.99 7,778.36 11,346.78 90.30 180.12 3,595.87 3,487.87 -7,825.13 -514.27 5,938,115.95 558,186.24 3.00 7,825.13 11,400.00 90.30 180.12 3,595.60 3,487.60 -7,878.35 -514.37 5,938,062.74 558,186.54 0.00 7,878.35 11,500.00 90.30 180.12 3,595.08 3,487.08 -7,978.35 -514.58 5,937,962.75 558,187.12 0.00 7,978.35 11,600.00 90.30 180.12 3,594.57 3,486.57 -8,078.35 -514.78 5,937,862.77 558,187.69 0.00 8,078.35 11,700.00 90.30 180.12 3,594.05 3,486.05 -8,178.35 -514.99 5,937,762.78 558,188.27 0.00 8,178.35 11,800.00 90.30 180.12 3,593.53 3,485.53 -8,278.34 -515.19 5,937,662.79 558,188.84 0.00 8,278.34 11,900.00 90.30 180.12 3,593.02 3,485.02 -8,378.34 -515.39 5,937,562.80 558,189.41 0.00 8,378.34 12,000.00 90.30 180.12 3,592.50 3,484.50 -8,478.34 -515.60 5,937,462.82 558,189.99 0.00 8,478.34 12,100.00 90.30 180.12 3,591.98 3,483.98 -8,578.34 -515.80 5,937,362.83 558,190.56 0.00 8,578.34 12,200.00 90.30 180.12 3,591.47 3,483.47 -8,678.34 -516.01 5,937,262.84 558,191.14 0.00 8,678.34 12,300.00 90.30 180.12 3,590.95 3,482.95 -8,778.34 -516.21 5,937,162.85 558,191.71 0.00 8,778.34 12,400.00 90.30 180.12 3,590.44 3,482.44 -8,878.34 -516.41 5,937,062.87 558,192.29 0.00 8,878.34 12,500.00 90.30 180.12 3,589.92 3,481.92 -8,978.33 -516.62 5,936,962.88 558,192.86 0.00 8,978.33 12,600.00 90.30 180.12 3,589.40 3,481.40 -9,078.33 -516.82 5,936,862.89 558,193.44 0.00 9,078.33 12,700.00 90.30 180.12 3,588.89 3,480.89 -9,178.33 -517.03 5,936,762.90 558,194.01 0.00 9,178.33 12,800.00 90.30 180.12 3,588.37 3,480.37 -9,278.33 -517.23 5,936,662.92 558,194.59 0.00 9,278.33 ~ 12,871.93 90.30 180.12 3,588.00 / 3,480.00 -9,350.25 -517.38 5,936,591.00 558,195.00 0.00 9,350.25 BHL :1937' FNL 8 2184' FWL -Sect 11 - T10N - R10E : 12871.92 ft MD, 3588.00 ft TVD - 41/2" -1J•154 Toe (v3) Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • sp~rry-~~ otlt~~taa s~RV~c~s A Halllburton Company Well Plan 1J-1.54 (M6) Wellhead(108') @ 108.OOft (Welihead(1 o8'p Wellhead(108') @ 108.OOft (Wellhead(108')) True ~ Minimum Curvature 2/13/2005 3:00:12PM Page 8 of 10 COMPASS 2003.11 Build 50 S s ~ ~ Halliburton Company ~,~,-+y_~~.,~", Conoco Phillips Planning Report -Geographic Alaska A Halllburton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Pian 1J-154 (M6) Company: ConocoPhiliips Alaska Inc.(Kuparuk) ND Reference: Wellhead(108') @ 108.OOft (Welihead(108'))' Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108.OOft (Weilhead(108')) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-154 (M6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-154 Design: 1J-154 (wp06) Geologic Targets 1J-154 -_- -- -- ND Target Name +N/-S +EI-W Northing Easting (ff) ' $haPe ft ft (ftl lft) 3,607.00 1J-154 T9 (v3) -6,086.80 -521.97 5,939,854.00 558,165.00 - Point 3,588.00 1J-154 Toe (v3) -9,350.25 -517.38 5,936,591.00 558,195.00 - Point 3,675.00 1J-154 T1 (v3) -1,749.28 -519.19 5,944,191.00 558,134.00 - Paint 3,610.00 1J-154 T6 (v3) -4,594.63 -520.35 5,941,346.00 558,155.00 - Paint 3,596.00 1J-154 Dtoe (v3) -7,465.97 -522.71 5,938,475.00 558,175.00 - Point 3,441.00 1J-154 Dtop (v3) -549.12 -519.84 5,945,391.00 558,124.00 -Circle (radius 100.00) 3,631.00 1J-754Prognosed Fault intersection -4,812.58 -530.04 5,941,128.00 558,147.00 - Point 3,636.00 1J-154 T3 (v3) -3,150.45 -520.10 5,942,790.00 558,144.00 - Point 3,612.00 1J-154 T8 (v3) -5,493.73 -521.35 5,940,447.00 558,161.00 - Point 3,665.00 1J-154TZ(v3) -2,195.33 -519.66 5,943,745.00 558,137.00 - Point 3,616.00 1J-154 TS (v3) -4,369.61 -519.59 5,941,571.00 558,154.00 - Point 3,596.00 1J-154 Btoe (v3) -7,766.07 -515.04 5,938,175.00 558,185.00 - Point 3,633.00 1J-154 T7 (v3) -4,794.66 -519.90 5,941,146.00 558,157.00 - Point 3,630.00 iJ-154 T4 (v3) -3,594.51 -519.56 5,942,346.00 558,148.00 - Point Prognosed Casing Points Measured Vertical Caaing Hole ii j Depth Depth Diameter Diameter eo.oo 80.00 4z a2 2,301.04 2,203.00 10-314 13-112 5,350.00 3,670.85 7-518 9-718 12,871.92 3,588.00 4-112 8-314 2/13/2005 3:00:12PM Page 9 of 10 COMPASS 2003.11 Build 50 ~~~~ I `' COI'IOCOPhIIII S Halliburton Company ~p~-,ny..~~„ p Planning Report -Geographic Alaska A HaalEurton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-154 (M6) Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Project: Kuparuk River Unit MD Reference: Wellhead(108') @ 108.OOft (Wellhead(108')) Site: Kuparuk 1J Pad North Reference: True Well• Plan 1J-154 (M6) Surve C I I ti n M th d• nn..,...,...., r•,,,.,~.,,.e • y acua o e o . Wellbore: 1 J-154 Design: 1J-154 (wp06)- Prognosed Formation Intersection Points Measured Depth Inclination Azimuth 1,582.21 25.25 326 .50 1,704.94 25.25 326 .50 2,016.52 23.68 326 .17 2,301.04 14.23 295. 08 2,427.38 12.59 268. 50 3, 031.91 32.17 197. 57 3,314.57 45.39 189. 50 3,425.28 50.68 187. 31 3,641.32 61.10 183. 86 4,047.85 76.00 179. 97 4,209.06 76.00 179. 97 4,364.24 80.00 179. 97 4,606.11 80.00 179. 97 4,836.46 80.00 179. 97 5,350.00 87.85 180. 03 Vertical Depth tNl-E +EI-W (ft) lR! tft! 1,538.00 203.39 -134. 62 1,649.00 247.05 -163. 52 1,934.00 351.69 -233. 55 2,203.00 415.85 -297. 31 2,326.00 422.07 -325. 17 2,890.00 263.23 -442. 35 3,110.00 91.38 -481. 87 3,184.00 9.97 -493. 84 3,305.00 -167.81 -510. 89 3,441.00 -549.12 -519. 84 3,480.00 -705.54 -519. 76 3,513.00 -857.14 -519. 68 3,555.00 -1,095.33 -519. 56 3,595.00 -1,322.18 -519. 44 3,670.85 -1,829.65 -519. 28 Name Base of Permafrost T3 K16 T3 +5611 T3 + 675 Ugnu C Ugnu B Ugnu A K13 West Sak D C B A4 A3 A2 2/13/2005 3:00:12PM Page 10 of 10 COMPASS 2003.11 Build 50 `~° • • Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc.. Date: 2/22/2005 Time: 16:06:39 Page: 1 I Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate(~'E) Refer ence: Well: Plan 1J-154, Tr ue North j Reference Well: Plan 1J-154 Vertical (TV D) Reference: Plans: 108.0 Reference Wellpath: 1J-154 Db: Orate NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Plan: 1 J-154 (wp06) & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.00 to 12872.47 ft Scan Method: Trav Cylinder North Maximum Radius: 1500.00 ft Error Surface: Ellipse + Casing Casing Points MD 'R'D Diameter Hole Size Name ft ft in In 80.00 80.00 42.000 42.000 42" 2301.04 2203.00 10.750 13.500 10 3/4" Casing Pt 5350.01 3670.85 7.625 9.875 7 5/8" Casing Pt 12871.95 3588.00 4.500 6.750 4 1 /2" Plan: 1 J-154 (wp06) Date Composed: 1 /1 /1990 Version: 2 Principal: Yes Tied-to: From Well Ref. Point Summary <_-~_~~~~~ Offset Wellpath ---------------> Reference' Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-03 1J-03 V5 191.86 200.00 153.68 4.81 148.88 Pass: Major Risk Kuparuk 1J Pad 1J-09 1J-09 V7 317.92 325.00 20.85 7.91 12.94 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V7 716.60 725.00 138.96 18.43 120.53 Pass: Major Risk Kuparuk 1J Pad Plan 1J-101 Plan 1J-L7 A Lat VO 1077.88 1075.00 171.27 23.99 147.28 Pass: Major Risk Kuparuk 1J Pad Plan 1J-102 1J-102 L1 V2 Plan: 1J- 649.99 650.00 166.89 18.60 148.29 Pass: Major Risk Kuparuk 1J Pad Plan 1J-102 1J-102 L2 V2 Plan: 1J- 649.99 650.00 166.89 18.60 148.29 Pass: Major Risk Kuparuk 1J Pad Plan 1J-102 1J-102 V1 Plan: 1J-102 649.99 650.00 166.89 18.73 148.16 Pass: Major Risk Kuparuk 1J Pad Plan 1J-103 Plan 1J-M9 VO 499.99 500.00 158.34 13.15 145.19 Pass: Major Risk Kuparuk 1J Pad Plan 1J-105 Plan 1J-M10 LatA VO 449.99 450.00 147.82 11.84 135.99 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-M11 LatA VO 325.00 325.00 147.47 8.57 138.90 Pass: Major Risk Kuparuk 1J Pad Plan 1J-109 Plan 1J-M13 LatA VO 299.99 300.00 167.24 7.88 159.36 Pass: Major Risk Kuparuk 1J Pad Plan 1J-111 Plan 1J-M12 LatA VO 349.99 350.00 189.74 9.19 180.55 Pass: Major Risk Kuparuk 1J Pad Plan 1J-115 Plan 1J-L9 LatA VO 574.98 575.00 248.71 15.05 233.66 Pass: Major Risk Kuparuk 1J Pad Plan 1J-137 1J-137 L1 (wp03) VO Pl 349.99 350.00 657.09 9.72 647.38 Pass: Major Risk Kuparuk 1J Pad Plan 1J-137 1J-137 V2 Plan: 1J-137 349.99 350.00 657.09 9.87 647.22 Pass: Major Risk Kuparuk 1J Pad Plan 1J-150 Plan 1J-UgnuDisposal V 349.99 350.00 100.40 9.23 91.16 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 L1 V1 Plan: 1J- 449.99 450.00 60.64 12.96 47.68 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 L2 V1 Plan: 1J- 449.99 450.00 60.64 12.96 47.68 Pass: Major Risk Kuparuk 1J Pad Plan 1J-152 1J-152 V1 Plan: 1J-152 449.99 450.00 60.64 12.96 47.68 Pass: Major Risk Kuparuk 1J Pad Plan 1J-156 Plan 1J-M4 A Lat VO 624.48 625.00 41.32 16.46 24.86 Pass: Major Risk Kuparuk 1J Pad Plan 1J-158 Plan 1J-M3 Lat A VO 623.30 625.00 78.33 16.48 61.85 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 L1 V1 Plan: 1J- 723.46 725.00 100.25 20.78 79.47 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 L2 V1 Plan: 1J- 723.46 725.00 100.25 20.78 79.47 Pass: Major Risk Kuparuk 1J Pad Plan 1J-159 1J-159 VO Plan: 1J-159 723.46 725.00 100.25 20.78 79.47 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Plan 1J-M2 LatA VO 596.33 600.00 117.84 15.87 101.98 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 1J-162 V3 Plan: 1J-162 619.49 625.00 175.71 17.49 158.22 Pass: Major Risk Kuparuk 1J Pad Plan 1J-164 1J-164 L1 V2 Plan: 1J- 2823.82 2925.00 79.93 50.08 29.85 Pass: Major Risk Kuparuk 1J Pad Plan 1J-164 1J-164 L2 V1 Plan: 1J- 2823.82 2925.00 79.93 50.08 29.85 Pass: Major Risk Kuparuk 1J Pad Plan 1J-164 1J-164 V1 Plan: 1J-164 2823.82 2925.00 79.93 50.08 29.85 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L1 V1 Plan: 1J- 762.71 775.00 255.36 20.64 234.71 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 L2 V2 Plan: 1J- 762.71 775.00 255.36 20.64 234.71 Pass: Major Risk Kuparuk 1J Pad Plan 1J-166 1J-166 V3 Plan: 1J-166 762.71 775.00 255.36 20.64 234.71 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 L1 V1 Plan: 1J- 374.98 375.00 581.15 10.42 570.73 Pass: Major Risk Kuparuk 1J Pad Plan 1J-182 1J-182 VO Plan: 1J-182 374.98 375.00 581.15 10.42 570.73 Pass: Major Risk Kuparuk 1J Pad Plan 1J-184 1J-184 L1 VO Plan: 1J- 11768.07 9000.00 257.88 121.82 136.06 Pass: Minor 1/5000 Kuparuk 1J Pad Plan 1J-184 1J-184 V1 Plan: 1J-184 12083.48 9325.00 210.35 157.13 53.22 Pass: Minor 1/5000 Kuparuk 1J Pad WSP-02 WSP-02 V4 714.37 725.00 209.92 17.05 192.86 Pass: Major Risk Kuparuk 1J Pad WSP-03 WSP-03 V1 724.35 725.00 243.09 23.98 219.11 Pass: Major Risk Kuparuk 1J Pad WSP-05 WSP-05 V1 729.29 750.00 335.67 24.51 311.16 Pass: Major Risk Kuparuk 1J Pad WSP-06 WSP-06 V1 3730.06 3525.00 61.04 33.67 27.37 Pass: Minor 1/2000 Kuparuk 1J Pad WSP-07 WSP-07 V1 3876.46 3550.00 387.08 81.13 305.95 Pass: Major Risk Kuparuk 1J Pad WSP-10 WSP-10 V1 4298.61 3600.00 269.31 97.49 171.82 Pass: Major Risk Kuparuk 1J Pad WSP-14 WSP-14 V1 4850.24 3750.00 647.55 123.37 524.18 Pass: Major Risk Kuparuk 1J Pad WSP-15 WSP-15 V1 757.00 775.00 187.18 22.85 164.32 Pass: Major Risk Kuparuk 1J Pad WSP-1 S WSP-1 S V2 908.57 925.00 185.93 41.14 144.80 Pass: Major Risk GRA ORIGINAL ~ • Halliburton Company Anticollision Report Company: ConocoPhilGps Alaska Inc. Date: 2!22/2005 .Time: 16:06:39 Fage: ` 2 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinaterNE) Reference: Well: Plan 1J-154,. True North Reference Well:. Plan 1J-154 Vertieal(TVD)Reference: Plans: 108.0 Reference~i'ellpath: 1J-154 I~6: Orade Summary <------------------ Offset WeRpat6 --------------> Reference Offset Ctr-Ctr do-Go Allowable Site WeII Wellpath MD MD' Distance Area Deviation Warning. '' ft ft ft ft ft Kuparuk 1J Pad WSP-20 WSP-20 V1 724.64 725.00 223.45 19.61 203.84 Pass: Major Risk Kuparuk River Unit N West Sak 5 West Sak 5 V5 12860.13 3575.00 175.22 155.00 20.22 Pass: Minor 1/1000 ~' ~ . SURVEY PROGRAM Dale: 2005-02-OBTW:00:(10 V9hdaled: Ycs Verson: Frum DcptA TD Surv03/Plan T~1 2AAp ROO.W 1J-151 (44'p0fi) CB-GYROSS BIN).W 12671.75 IJ-ISJ Ixp06) MWD+IFR-AIN-CAZSC' Enpn calwa6w 9klekaJatw ~ cw.ae.. Ertv sy4len, sw~ rwem0a: tt>w. cy9rt6a. w.m Ertw 9urlace'. EIIipBCL Lanic yycw~g Me6od: Ruka Bated Interpolation Method: MD Interval: 25Statfons Depfh Range From: 28.00 To 12871.93 Ma>amum Range:1814.24 Reference: Plan: 1,1-154 (wp06) 90 1„~~~ r. 180 - too ntre iD Centre Separation CIS ft/ink C ° e ~ Ys Tt~R$Iling Cylinder Azimuth (TFO+AZI) ~ aoo soo - looo 1500 BECTICIN °ETAIL6 200Q Sac M° ~ T/D «ys .Ei-y.J °Laq TFaw VSec Tarye1 Sao 090 000 2500 2e ao 9m 9a0 zaoo 000 000 z ]00.00 aoo Sao 1oD.ao 9aD Sao Sao Sao 000 15 1201 400 32650 -10.15 18 3000 . 3 95000 1000 32650 9d8.]3 4 1)3115 2515 33650 131101 114.12 -]`154 400 000 -11412 22 -106.28 000 000 -25132 61 251 350Q . 5 1]166] 25.25 326.50 1fi59 6 1156.13 2368 326.1] 1695.53 26182 -1]330 400 -11511 ~26d 82 ]8 )5634 -236.6] 000 000 '356.34 ] 203048 2368 )261] 1946 ]600 1]99] 311681 15208 519.69 SOD -141.14 15209 15401op (vJ) 13 1J aQOO - B )94].85 9 404185 ]600 1]9.9] 344100 -549.12 -519.84 0.00 OOD 549. )5 OOD n00 ]26~ 19 . 10 4130.85 ]600 1]99] 31051] 12669 -5 W Zi aSQD ( 000 000 16JI 12 50.154 ]4 8000 1]991 9650 '16N 64 519 93 1J-151 T21h) 00 2195 1 50~ . 95.3) 51966 004 0 14 5115]] 91.30 10006 386500 -2 ]d 180.03 3864.6] -220].43 51961 300 -518 220]43 00 000 )15045 1J-151 T31'~J1 60 91 5 5]21 6000 . . 1 16 96]133 9111 1800) 363000 -)150.45 -520.10 0 42 -52000 300 -1]4)3 3184.12 )164 1 J . - ) 11 6]0501 901d 1]9.93 ?6)51 14 11993 )63000 -359451 -51956 000 000 3594.51 1}154 T1 (v 543 90 86 3d 380< 700Q . . 18 111 19 ]125]8 910d 180.00 3629&1 -3604.86 -51955 300 14 29 1}154 TS 1`A) 0 0 6 BQQQ 4466. J00 1]9. 1 2201 ]]90]36 80.14 18005 3616.0 -4466.29 -519. Id IBD OS 362]]8 )]94.53 -51990 000 OOD 4]94.53 1J-154 T]NJ) B 900Q . 32 8315]] B 5d 100.12 J612W -549) TJ 52135 n00 OOD 549333 1}154 T8 (h) 98 10QQQ 24 901520 91 25 905146 90.15 X60.06 3611.3] 553990 -52140 300 1]64] 5529 06 Jfi0]Op -BDB6.Bp -521.9] 000 000 6085.00 1J-t 51 T9 (VJ) 9p45 80 fi08]]3 11 QQQ ~ yip . 21 96091) 90.46 4BD OJ 360fi 99 6081.13 -521.91 3.00 -]321 9046 1800) 35%00 ~Id639] 522]1 000 000 Id65.9] 1J-151 pw (v3) 3 56 . 201098151 29 1104510 8995 1]638 3595.]9 ]52356 -521 91 ]00 -10101 152 3503 1J-15d Bbe (v3) 31 0 ~ 12000 700 ]660 18 1J 514. 5 )011348]8 90.30 180.13 3595.8 102 120]193 9030 180.12 358800 -9350.25 51138 000 000 9350.25 1J-154 TOe (v3) 13000 32 c 0 ~_ c 0 .~ L C~ ~. L •.+ U 0 ~. U • 1000 2000 3000 4000 5000 6000 Measured Depth [ ] OOOft/in] ~Rlr;inia~ CemCADE Preliminary Job Design 7-5/8" Intermediate Casing on purposes Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 2/25/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 10 3/4", 45.5# casing at 2,301' MD < Top of Tail at 2,531' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 5,350' MD (3,671' TVD) Volume Calculations and Cement Systems Volumes are based on 30% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (2819' MD annular length). Tail Slurry Minimum thickening time: 160 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.2148 ft3/ft x 2819' x 1.30 (30% excess) = 787.2 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 787.2 ft3 + 20.6 ft3 = 807.8 ft3 807.8 ft3/ 2.26 ft3/sk = 357.4 sks Round up to 360 sks BHST = 81°F, Estimated BHCT = 70°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time Ibbl1 (mint CW100 5.0 10.0 2.0 2.0 Pause 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Pause 0.0 0.0 5.0 23.0 MUDPUSH II 6.0 40.0 6.7 29.7 DeepCRETE 6.0 143.8 24.0 53.7 Pause 0.0 0.0 5.0 58.7 Mud 7.0 227.0 32.4 91.1 Mud 3.0 15.0 5.0 96.1 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 ? 19-22, TY ? 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. oR~r_,iNai.. CemCADE Preliminary Job Design 10 3/4" Surface Pipe Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 2/23/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,583' MD (1,538' TVD) Schl~6@P~ 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 1,701' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (1583' - 80') x 3.50 (250% excess) = 1913.2 ft3 0.3637 ft3/ft x (1701' - 1583') x 1.35 (35% excess) = 57.9 ft3 109.2 ft3 + 1913.2 ft3+ 57.9 ft3 = 2080.3 ft3 2080.3 ft3 / 4.45 ft3/sk = 467.5 sks Round up to 470 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 140 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.3637 ft3/ft x (2301' - 1701') x 1.35 (35% excess) = 294.6 ft3 0.5400 ft3/ft x 80' 3(Shoe Joint) = 43.2 ft3 294.6 ft3 + 43.2 ft = 337.8 ft3 337.8 ft3/ 2.52 ft3/sk = 134 sks Round up to 140 sks BHST = 42°F, Estimated BHCT = 61°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 1,701' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,301' MD (2,203' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 Drop bottom plug 0.0 0.0 5.0 33.3 ASL 7.0 370.5 52.9 86.2 DeepCRETE 5.0 60.2 12.0 98.2 Drop top plug 0.0 0.0 5.0 103.2 Water 5.0 20.0 4.0 107.2 Switch to rig 0.0 0.0 5.0 112.2 Mud 7.0 178.6 25.5 137.7 Slow & bump plug 3.0 15.0 5.0 142.2 MUD REMOVAL Recommended Mud Properties: 9.1 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~~~~ 'Tubing Head Assy, 13-5/8" X 4.112". 'Tubing Hanger, concentric, no penetrations. 10-3/4" Casing Shoe,D~ set ~ 2301' MD, 2203' TVD / Tubing String 4-112" 12.8#, L-80, 18TM 3.958" ID, 3.833" Drift 5-712" X 7318" ZXP Seal Assemt Liner Top Packer 4.75" Seal O with Hold Downs 3.875" ID 17' Length V ~ ~~ Tubing Swivel, Tubing, Special Drlftto+1.500' MD ConoCOPhillips DB Nipple, for Possible SSSV, set at +/- 500' MD West Sak 7-518" Injector GLM, Camco 1" KBG-2 1 J-154 GLM, Camco 1" KBG-2 Tri-Lateral Completion CMU Sliding Sleeve, w/ DB Nipple, set at 70 deg maX inclination Casing Sealbore Receptacle _ 4.75" ID, 6.25" OD 20' Length / Lateral Entry Module(LEM) Orienting Profile D-sand Window ~/ at 4048' MD, 3441' TVD 4-112" 72.8# L~0 Slotted Liner Swivel Liner Every Other Joint Seal Assembly 4.75" Seal OD i 3.875" ID 2' Length 4-112" X 7518" Seal Bores Model 'B' HOOK Hanger 3.68" ID 5-112" X 7316" ZXP Liner Top Packer with Hold Downs Lateral Entr~.Module (LEM1 rn Assembly t~ - 5-112" X 7518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID - Tubing Swivel, 4-712" Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Divener Seal Bore for Lateral Isolation - 3.68" ID ~~ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing SealborE Receptacle 4.75" ID, 6.25" OD 20' Length 4-112" X ' ' _. __ 7318" HO Model B OK Hanger Seal Bores_ 3.68" ID 4-112" 12.8# Tut 3.833" Drift 3.958" ID 'D' Sand Lateral 3-112" Bent Joint 1 3-112" Guide Shce 4-112" Casing Shoe, 12.8#, L-80 IBTM Set ~ 10970' MD, 3366' TVD Packvff Bushing Swivel, 4-712" ~ateral Entry Module(LEM Orienting Profile B-sand Window fat 4364' MD, 3513' TVD Liner Swivel pi:^ XKUGFIES Baker Oil'1'ools With Diverters and Isolation Lateral Access Diverter Lateral ladatbn DiverOer GS Runnirg Tod String Installed Installed (3.00" Lateral DrBI) (2.50" ID Maintwr e DriTt) 'GS' Profile for Coil Connector ~Running/Retrieving Li (1.00' Length) ~, I Snap InSnap Out ~~, ~ ~~ i ~ fPosltive LOCaBng~ ~~Back Pressure Valve Collet I I Lateral IsoWtion ~ Fkaw-Thru Swivel '• I Seals ~, (1.25' Length) `/ Lateral Diverter ~ ~ yd H raulic / Ramp , ._ D IsoW50N Malnbore~ ' .50' Length) (1 Diverter Sleeve ~~ GS Spear ' ~. Lateral Isolatbn l ~~ Length) (1.50 Seals 8.85 n Approx. OAL' ~ 'B' Sand Lateral '"'"°`"°""""°°~'° 4-112" 72.8# L-80 Slotted Liner Every Other Joint 3-112" Bent Joint ~~ __ 3-112" Guide Shoe DB Nipple Pack-off Bushing 5-112" X 7318" ZXP Liner Top Packer t with Hold Downs / 5-112" X 7318" Flex Lock / Liner Hanger I Packer Assembly at Liner Hanger +1-4440' MD Casing Sealbore Receptacle 4.75" ID, 6.25" OD 20' Length ®9aker Hughes 4003. This document may not be reproduced or distributed, In whole or In part, In any form or by any means Neetronlc or meehanlcal, including photocopying, recoMlnq, or by any Informatlon storage and retrieval system now known or hereafter Invented, without written permisslon from Baker Hughes Inc. hly deviate0 18.5' Diverter Length 18.5' Sleeve Length roz length). 4.1/2" Casing Shoe, 12.8#, L-80 IBTM Set @ 11276' MD, 3439' TVD Seal Assembly 4.75" Seal OD ' 3.875" ID 'A' Sand Undulating Lateral 2' Length 4-112" 12.8# L-80 Stoned Liner Every Other Joint 4-112" Eccentric / .Guide Shce Eguiament Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drih, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaleroOMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drik, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +I- 3.89" Diverter and Sleeve Length: +1-18.5' 4.1/2" Casing Shoe, 12.8#, L-80 IBTM Set ~ 12872' MD, 3588' TVD / Pack-oH Bushing 7-5/8" Casing Shoe, Set at ~ _._- - _ ----- 5350' MD, 3670' TVD, 80 de °'vvgTiOe~ g 4003 West Sak 73/8" TrHateral Completlon -Infector • • ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-154 (M6) 1 J-154 1 J-154 (wp06) Anticollision Report 22 February, 2005 • HALL~BURTQN Sperry Drilling Services {,. ~ .a> • ConocoPhillips Alaska Company: ConocoPhillips Alaska Inc.(Kuparuk) Project: Kuparuk River Unite Reference Site: Kuparuk 1J Pad Site Error: O:OOft Reference Well: Plan 1J-t54 (M6) Well Error: O:OOft Reference Wellbore 1J-154 Reference Design: 1J-154 (wp06) Halliburton Company HALLIBURTON Anticollision Report Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-154 (M6) TVD Reference: Wellheaii(108') @ 108:OOft (Wellhead(108')) MD Reference: Wellhead(108') @ 108.OOft (We4head(108')) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003:11 Single User Db Offset TVp Reference: Offset Datum Reference 1J-154 (wp06) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 4,047.85 to 12,871.75ft Scan Method: Horizontal Plane Results Limited by: Maximum center-center distance of 1,320.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Daie 2/22/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description 0.00 800.00 1J-154 (wp06) (1J-154) CB-GYRO-SS Camera based gyro single shot 800.00 12,871.75 1J-154 (wp06) (1J-154) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 Out of range 1J-09 - 1 J-09 - 1J-09 Out of range 1J-10 - 1J-10 - 1J-10 Out of range 1J-14 - 1J-14 - 1J-14 Out of range WSP-02 -WSP-02 -WSP-02 4,047.85 3,487.62 788.59 66.43 722.17 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 Out of range WSP-04 -WSP-04 -WSP-04 4,047.85 3,473.57 1,042.35 73.18 969.17 Pass -Major Risk WSP-05 -WSP-05 -WSP-OS 4,047.85 3,503.41 726.11 72.31 653.80 Pass -Major Risk WSP-06 -WSP-06 -WSP-06 4,047.85 3,636.64 312.45 64.25 248.20 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 4,047.85 3,505.68 429.48 83.22 346.26 Pass -Major Risk WSP-OS -WSP-08 -WSP-08 4,047.85 3,440.28 823.47 241.01 582.47 Pass -Major Risk WSP-09 -WSP-09 -WSP-09 4,047.85 3,509.60 1,238.72 91.95 1,146.77 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 4,297.85 3,591.01 269.53 98.04 171.49 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 Out of range WSP-12 -WSP-12 -WSP-12 4,372.85 3,549.91 719.55 105.54 614.01 Pass -Major Risk WSP-13 -WSP-13 -WSP-13 4,447.85 3,559.99 1,189.09 101.07 1,088.02 Pass -Major Risk WSP-14 -WSP-14 -WSP-14 4,847.85 3,693.15 649.51 123.39 526.12 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 Out of range WSP-1 S -WSP-1 S -WSP-1 S 4,047.85 3,450.53 953.01 X06.74 746.27 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 4,047.85 3,498.59 974.17 86.69 887.48 Pass -Major Risk Kuparuk RiverUnitNon Pad West Sak 5 -West Sak 5 -West Sak 5 12,871.75 3,577.57 175.63 355.23 -179.61 FAIL -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -.min ellipse separation 2/22/2005 8:15:22PM COMPASS 2003.11 Build 48 1J-1541/4 MILE EFFECT r _~ _..-,.fir `'"~~.~. ~~,^" ~.os~r, Evaluation of West Sak isolation in existing 1J area wellbores - - • 2400 sx Arctic Set 12.2 ppg lead, 485 sx G + adds 15.8 ppg tail; lost retums 210 bbl into WSP-1S P8A Ivishak Yes 3 468 3 468 333 3 3 333 Zone of interest not logged (only 9-5/8" @ 13-3/8" to 3900' displ; bumped plug; didn't recip pipe; w/full OKfrom CMTjob , , , , Bottom) retums, cmt should have been at or near surface when retums were lost; likely cmt covering Wsak 8 Ugnu but could be Set 7" at 3494' for OH GP of Wsak. Cmt w/ 850 WS/UG not logged (TD log = 3377'). Logged sx Arcticset 12.2 ppg lead, 100 sx G + adds 15.8 WSP-2D P&A West Sak Yes 3 526 3 488 -3 372 3 488 interval above WS/UG indicates good to very 7" at Top WSak PP9 tail; bump plug &recip thruout; lost returns OK from CBL and CMTjob , , , , good bond. Indicative of further good 50 bbl into disp, hole stayed full; w/ full cementation below, yet not definitive. retums, cmtshou/d have been at surface when returns were lost; 325 Sx G + adds; wt 13.4 yield 1.79; recip csg; WSP-4 P&A West Sak No 3,522 3,498 3,378 3,356 7" at Base WSak bump plug; full rtns thruout; no cmt @ surf (need OK from CMT job washout <15°~ for cmt surf) WSP-5 P&A West Sak Yes 3,539 3,489 3,385 3,341 -2900 Excellent Bond blwn WS/UG 7" at Base WSak OK from CBL WSP-61 P&A West Sak Yes 3,647 3,465 3,478 3,301 -32/3300 Good to Very Good Bond btwn WS/UG 7" at Base WSak OK from CBL / ve close to in' First arrival amplitude very low and transit Set 7" at 4109', cmt w/ 875 sx Arcticset 12.2 ppg WSP-7 P&A West Sak Yes 3 524 3 473 3 377 3 329 time missing over large logged interval. 7" at Base WSak lead, 275 sx G + adds 15.9 ppg, bump plug, pipe OK from CBL and CMT job , , , , probable cause excentralisation. VDL sticky but good circ, circ 123 bbl cmt to surf, indicates good to excellent cement. CBL oval claims good CMT to 720' Patchy bond micro-annulus between WS & Date of CBL? Dec. '84 step rate test broke down WSP-81 P&A West Sak Yes 3,468 3,468 3,333 3,333 -2300 , Ugnu; CBL is pre-cement breakdown and 7" at Base WSak CMT, 3 sqz to repair. 1/3/85 CBL. After sqz, no OK from injection data/profiles remedial cement squeeze out of zone injection for duration of pilot, up to 1150 psi WHIP WSP-9 P&A West Sak Yes 3,555 3,500 3,403 3,350 -3084 A arentl excellent bond btwn WS/UG 7" at Base WSak OK from CBL, nearer to rod WSP-10 P8A West Sak Yes 3,533 3,439 3,317 3,225 -2765 Good Bond btwn WS/UG 7" at Base WSak OK from CBL / ve close to inj Surf csa: tail slurry 15.9 ppg G + adds; good circ Another suspicious log. Unusual transition thruout job; circ 74 bbl cmt to surf (TD 3253'); WSP-12 P&A West Sak Yes 3 487 3 467 3 347 3 330 -3460 from very good cement to free pipe above 7" at Base WSak Prod csa: 15.9 ppg G + adds; good circ until OK from CMT job, squeeze , , , , WS/UG formation top. last few bbla; recip pipe thruout; did not bump ' and operational data ; CBL interp TOC ~ 3460 ; plug; talc TOC 2800 Workover: pert WSP-13 P&A West Sak Yes 3,509 3,475 3,361 3,331 -2900 Excellent Bond btwn WS/UG 7" at Base WSak OK from CBL, nearer to rod WSP-141 P&A West Sak Yes 3,559 3,479 3,413 3,336 -3050 Excellent Bond btwn WS/UG 7" at Base WSak OK from CBL WSP-20 P&A West Sak Yes 3,557 3,491 3,393 3,342 -2200 Fair to Ve ood bond btwn WS/UG 7" at Base WSak OK from CBL Surf csa: 9-5/8" csg to 2421', cmt w/ 1450 sx Arcticset @ 15.1 ppg, circ 129 bbl cmt to surf; West Sak 5 P&A Kuparuk No 3,324 3,324 3,175 3,175 Prod csa: 7" liner 2106'-6677'; cmt w/ 546 sx G OK from CMT job neat; liner lap PT @ 400 psi failed; RTTS sqz liner lap from 1989' w/ 250 sx (52 bbl) Arcticset 15.2 PP9; PT **The 1320' radius scan was applied to existing wells over the TVD ranges of the 1J-154 West Sak producing zone (3366-3671' TVD). **The attached plot shows all existing wells that violate the 1320' raduis. **14 wells shown above are withjp the 1320' radius. ~ `yam ~i,~ ~~ • West(-)/East(+) (1320 ft/in) _na~n _zoan _zznn _~aan _~qRn -'1390 -660 0 660 1320 1980 2640 3300 3960 N 0 c Z 0 w N O 7 0 CIRIGINAL -4620 -3960 -3300 -2640 -1980 -1320 -660 U bbU 13LV iao~ wyu .+.+w ..~~~ _ ;.~' •.~~ .~ L-04 I I ~ 2 ~~I fit--.. ft ~~~ i1-09 IL-28 ~~ 1 E 36 1 32 1L-201E-24 t 0 ~ - -~ ~~'-- - I J-10 `~, 1 L-2CW - `^`--~ 1L-21 -1"~`~-t2~--`` 1L-11 34 IE ~ 1 J-fr7 ISE+I~TPS ll Area of Review L-}24 b~ Slotted liner >oo ~ - - ~ - \ ;oo >ooo > > ooo 11 ~zooo 4i SLY f) . . '.V 1J-154 • • SHARON K. ALLSUP-DRAKE ~ ~L , CONOCOPHILLIPS ATO 1530 1096 700 G SL ANCHORAGE AK 99501 'I` DATE f~i r(~ PAY TO THE ~ ri~~~ d~ ~Li¢S ORDER OF -1 ~ `r K~ ~D~C~ $ (~ OCR =~ .CHASE Chase ManhattanBank USA; N.A, /OO ~V~LARS ,.. od nFe,~,m. ;oa canna ~,~ ~e~,e, o,.. „~,~,~. aE ,e,,, Valid Up To 5000 Dollars MEMO ,~ ~ ~ 0 ~ ------_ ---------~~~'= 3 ~ ~o __ _ _1__ ~ .~ . ~ ~,4`4~. 2 L84 7 190.79 2?6n^ ~~ _---- ,_. ,. 96 =s-.~ ~~_...i . -...0. :..a..~~::.~. r. . . ~lrr:L :~~ - . v.~....1 .....r i .fie .~.- .... • • T]~ANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPAR.AGR.APHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~G~ ~~ /SSA r1v# ~S- ~ 3S L?evelopment Service Exploration Stratigraphic CHECK WART ADD-OHS "CLUE'! APPLIES OPTION • MULTI - The permit is for a new wellbore segment of LATERAL, existing weU . Permit No, ~ API No. . (lf API number Production. should continue io be reported as last two. (2) digits a function•of the original API number stated are between 60-69) above. • • PILOT 1:]OLE In accordance with ~ 20 AAC 25.0050, all (P~ records, data and logs acquired, for the pilot - - bole must be clearly differentiated 'in both • name (same on permit plus PH) and API number (50 70/80) from records., data and logs acquired • • !or well (name on permit). SPACING The permit is approved subject •io full EXCEPTION compliance with 20 AAC 25.055. Approval io perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ e=ception. (Comaanv Name) assumes ibe IiabiBty of any • protest to the spacing •e=ception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in ao greater than 30' sample intervals from below ibe permafrost or from where samples are first caught and ] 0' sample intervals through target zones. WELL PERMIT CHEC}(LIST Field & Pool KUPARUK RIVER, WEST SAK OIL-490150 Well Name: KUPARUK RIV U WSAK 1J-154 Program SER Well bore seg ^ PTD#:2050350 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER 1 PEND GeoArea 890 _ Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Permit_fee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ -- - - - 2 Lease number appropriate_ - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Surface location and top productive interval in ADL 025661;- TD in ADL 025662._ . - _ - - _ - - - - - - 3 Uniqueweil_nameandnumber_____________________________ _________Yes_ ____.._...- 4 Well located ina_defnedpool___________________ __________ _________Yes_ -____KRUWest_Sak OilPool~governedbyConservation_Order_No,4066_____-.___-________--.___-_- 5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - - - - - - - - Yes Well is more than-500 feet from an external property line. _ _ - . _ _ _ _ _ _ _ _ _ _ _ _ _ , 6 Well located proper distance from otherwells- - Yes . ...... No restrictions as_to well spacing in CO-4066-- - - - - - - - - - - - - - -------------------------- 7 Sufficient acreageayailablein-drilling unit_______________________ ____-_--Yes_ _______-__-._ - - -- 8 If deviated,is_wellboreplat_included__________________________ _________Yes_ __-__________-__--__.__----___-__--__---__--_ - -- 9 Operator gnly affected party- - - - - - - - - - - - - Yes - - - - - - 10 Operakorhas-appropriate-bond in force________________________ _________Yes_ __......_.__._______.._ 11 Permit-can be issued withoutcenservaiionorder___________________ _________Yes_ _________.--_--_--__-- Appr Date 12 Permitcan be issued without administraiive_approval _ _ - _ - _ ---------- _ _ Yes _ --- _ _ - - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ - - - - _ _ _ - - _ - -- -- -- SFD 3111!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Order # (put1O# in-comments)-(For_ Yes _ _ _ _ _ _ _ Area Injection Order No.-2B _ _ - _ _ _ _ _ ------------------------------------------- 15 All wells within 1l4.mile area of review ldeniified (For service well gnly) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ ..West Sak 5,.WSP-14, WSP-10, WSP-12_ _ _ . _ _ _ . _ _ - . _ . _ _ _ . _ _ _ _ _ .. _ ------------------ 16 Pre-produced injector: duration of pre production Less than- 3 months_(FOrservice well only) - -Yes - Well will be cleaned up for 30 - 60 days_prior to injection, - - - - - - - - - - - - - - - - - - - 17 ACMP_Finding of Consistency-has been issued-forthis project_ - - - _ _ NA- - - - - - - - - - - - - - - - - _ _ - - - _ - - -- - - Engineering 18 Conductorstring_provided--_---__-.-__-_--_--_--_-_____ _________Yes_ _-_---------__--_-_-_-___----_ - - - - -- - 19 Surface casing_protects altknewn USDWS _ - - NA_ _ - _ _ - - _ All aquifers exempted 40 CFR 147.102(b)(3) : . . . .. . ...... . . . . . 20 CMTyoladequate_tocircul_ate_oncond_uctor&surf_csg-__________-- -__--_--_Yes__ _________________________________________________--__ _---_--------- 21 CMT-vol adequate_to tie-in long string to surf csg_ No_ - _ _ - - -All hydrocarbons will be covered- - - - - - - - - - - - - - - 22 CMT_will coverall know_n_productiye horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - No- - - Slatted linercom-letion lanned.- p P 23 Casing designs adequate for C, T B &_permafrost- - - - - - - - - - - - - - - - - - _ - . - - - - _ Yes _ _ - - -- 24 Adequate tankage_or reserve pit _ Yes _ . - _ _ - Rig is_equipped with steelpits.-NO rese_rve_pitplanned, All waste to approved annulus or disposal well.- _ _ _ _ _ _ 25 Ifa_re-drill,has-a-10-403forabandonment been app_roved_____________ _________ NA_-- -_-:--___----____-- -- -- - - 26 Adequate wellbore_ separationproposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ Yes _ . _ ... _ Proximity analysis performed, Close approaches identified.- Traveling cylinder plot provided. _ _ _ _ _ _ . _ _ _ _ _ - ~ 27 Ifdiverterrequired,doesitmeetregula_tions______________________ _________ Yes__ ___-_____.-___-_ Appr Date 1 28 Drilling fluid-program schematic & equip list adequate- - - - - - -------- - - - - - - - - - -Yes Expected reservoirpressure $.7 EMW. -Planned mud weight 9:Oppg in West Sak, - - - - _ _ _ - _ _ - TEM 311412005 29 B_OPEs,_dothe meet_reulation__ y 9 Yes _ ~,(~' 30 BOPE-press rating appropriate; test to (put prig in comments)- _ _ . _ __ Yes ___ _______ ______,-.----_-_----__---_--- _ MA$P calculated at 1248 psi. 3000_psi_appr_opriate. - - - - - - - -- - -- ~ ;~/ 31 Choke_manifoldcomplieswlAPI_RP-53(May84)_-_---_--_________ _________Yes_- --_..__.....__-___ - -- - -- - - 32 Work willoccu[withoutoperationshutdow.n______________________ _________Yes-_ -__..__.-_-._-__-_ ------------------------------------------------------ 33 Ispresence.ofH?Sgas-probable____________________________ _________ No___ -__-.H2Shas notbeenreportedinWS,--...............--___-__-__----____--__---..- 34 Mechanical condition of wells within AOR verified fFor service well only) - - _ _ - _ - - - - _ -Yes Exam)ned all wells on W$ Pitot and W. Sak 05. Initial cementing and P8As acceptable.. No exceptions_noted, Geology 35 Permitcan be issued w/o hydrogen sulfide measures . . ............ . . . . . . . . .Yes Expected resen!oirpressure is 8,7_ppg EMW; will be drilled with 9.0 ppg mud. - . - - . - ... - - . - . . - 36 _Data_presented on potential overpressure zones - - - - - - tVA_ - - _ - , - Will.be drilled from same pad as fhe-original West Sak-Pilot-Project wells. _ - Appr Date 37 Sei_smic_analysis ofshallow gas zones_ _ _ - _ _ _ _ _ NA_ - - Hydrates_may-be encountered,.mitigation measured discussed in Drilling Hazards-Summary_ _ _ _ _ _ _ ___ _ _ _ _ SFD 3111!2005 38 Seabed condition survey-(ifoff-share) - - _ NA -- - -------------------------------------------------------- I39 . Contac# name/phone for weekly progress.reports (exploratory only]- - - - - - - hlA_ Geologic Engineering ublic Commissioner: Date: Commissioner: Date issioner Date ors ~I~s~ `3z~ o • • ~1 Well History File APPENDIX • Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify t'inding information, information of this nature is accumulated at the end of tl~e file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 02 11:27:28 2006 Reel Header Service name .......... ...LISTPE Date .................. ...06/03/02 Origin ................ ...STS Reel Name ............. ...UNKNOWN Continuation Number... ...01 Previous Reel Name.... ...UNKNOWN Comments .............. ...STS LIS Writing Library Tape Header Service name .......... ...LISTPE Date .................. ...06/03/02 Origin ................ ...STS Tape Name ............. ...UNKNOWN Continuation Number... ...01 Previous Tape Name.... ...UNKNOWN Comments .............. ...STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000395646 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • ~0 ~~~ Scientific Technical Services Scientific Technical Services 1J-154 500292325400 ConocoPhillips Alaska, Inc. Sperry Drilling Services 02-MAR-06 MWD RUN 3 MW-000395646 P. ORTH M. THORNTON 35 11N l0E 2133 2569 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2302.0 2ND STRING 6.750 7.875 5165.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE • ~ PRESENTED, 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED RECORDED-ONLY COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL STABILIZED LITHO-DENSITY (ASLD), AND ACOUSTIC CALIPER (ACAL). MWD RUN 3 INCLUDED GEO-PILOT ROTARY-STEERABLE BHA (GP), 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 1J-154 WITH API#:50-029-23254-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9063'MD/3643'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 (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 9.875" BIT MUD WEIGHT: 9.0-9.2 PPG MUD SALINITY: 200 PPM CHLORIDES FORMATION WATER SALINITY: 14545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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 2256.5 9005.5 RPS 2280.0 9013.0 RPM 2280.0 9013.0 FET 2280.0 9013.0 RPX 2280.0 9013.0 RPD 2280.0 9013.0 NPHI 2296.5 5077.5 FONT 2296.5 5077.5 PEF 2296.5 5091.5 NCNT 2296.5 5077.5 RHOB 2296.5 5091.5 DRHO 2296.5 5091.5 CALA 2296.5 5080.5 ROP 2302.5 9063.0 • 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 2256.5 5172.0 MWD 3 5172.0 9063.0 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 GALA MWD INCH 4 1 68 4 2 FONT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD GfCM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 L 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2256.5 9063 5659.75 13614 2256.5 9063 GALA MWD INCH 8.85 13.38 10.2575 5548 2296.5 5080.5 FCNT MWD CNTS 459 2858 832.646 5532 2296.5 5077.5 NCNT MWD CNTS 106558 173804 128962 5532 2296.5 5077.5 RHOB MWD G/CM 1.064 2.748 2.1811 5591 2296.5 5091.5 DRHO MWD G/CM -0.539 0.616 0.0838133 5591 2296.5 5091.5 RPD MWD OHMM 0.51 2000 21.056 13467 2280 9013 RPM MWD OHMM 4.01 2000 18.119 13467 2280 9013 • .7 RPS MWD OHMM 3.73 2000 17.1288 13467 2280 9013 RPX MWD OHMM 3.46 2000 14.6441 13460 2280 9013 FET MWD HOUR 0.2 73.43 1.37416 13467 2280 9013 GR MWD API 22.41 115.29 70.48 13499 2256.5 9005.5 PEF MWD BARN 0.25 7.71 1.78734 5591 2296.5 5091.5 ROP MWD FT/H 1.34 580.58 169.285 13522 2302.5 9063 NPHI MWD PU-S 10.74 82.16 36.0644 5532 2296.5 5077.5 First Reading For Entire File..........2256.5 Last Reading For Entire File...........9063 File Trailer Service name .......... ...STSLIB.001 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/03/02 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.......06/03/02 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 2256.5 5125.5 FET 2280.0 5118.0 RPX 2280.0 5118.0 RPS 2280.0 5118.0 RPM 2280.0 5118.0 RPD 2280.0 5118.0 PEF 2296.5 5091.5 NPHI 2296.5 5077.5 RHOB 2296.5 5091.5 CALA 2296.5 5080.5 DRHO 2296.5 5091.5 FONT 2296.5 5077.5 NCNT 2296.5 5077.5 ROP 2302.5 5172.0 LOG HEADER DATA DATE LOGGED: OS-OCT-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5172.0 TOP LOG INTERVAL (FT) 2302.0 BOTTOM LOG INTERVAL (FT) 5172.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 12.2 MAXIMUM ANGLE: 81.4 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 SLD STABILIZED LITHO DEN 126970 CTN COMP THERMAL NEUTRON 10509011 ACAL Acoustic Caliper 143795 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2302.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.05 MUD VISCOSITY (S) 61.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.300 67 .0 MUD AT MAX CIRCULATING TERMPERATURE: 2.390 95 .0 MUD FILTRATE AT MT: 4.500 67 .0 MUD CAKE AT MT: 3.000 67 .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 CALA MWD020 INCH 4 1 68 4 2 FONT MWD020 CNTS 4 1 68 8 3 NCNT MWD020 CNTS 4 1 68 12 4 RHOB MWD020 G/CM 4 1 68 16 5 DRHO MWD020 G/CM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 RPM MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 RPX MWD020 OHMM 4 1 68 36 10 FET MWD020 HOUR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 PEF MWD020 BARN 4 1 68 48 13 ROP MWD020 FT/H 4 1 68 52 14 NPHI MWD020 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2256.5 5172 3714.25 5832 2256.5 5172 CALA MWD020 INCH 8.85 1 3.38 10.2575 5548 2296.5 5080.5 FCNT MWD020 CNTS 459 2858 832.646 5532 2296.5 5077.5 NCNT MWD020 CNTS 106558 17 3804 128962 5532 2296.5 5077.5 RHOB MWD020 G/CM 1.064 2 .748 2.1811 5591 2296.5 5091.5 DRHO MWD020 G/CM -0.539 0 .616 0.0838133 5591 2296.5 5091.5 RPD MWD020 OHMM 2.92 2000 18.4828 5677 2280 5118 RPM MWD020 OHMM 4.01 1743.45 15.3911 5677 2280 5118 RPS MWD020 OHMM 3.73 2000 14.4377 5677 2280 5118 RPX MWD020 OHMM 3.46 1043.9 12.3401 5677 2280 5118 FET MWD020 HOUR 0.2 56.81 1.13934 5677 2280 5118 GR MWD020 API 22.41 115.29 69.3712 5739 2256.5 5125.5 PEF MWD020 BARN 0.25 7.71 1.78734 5591 2296.5 5091.5 ROP MWD020 FT/H 1.34 580.58 162.542 5740 2302.5 5172 NPHI MWD020 PU-S 10.74 82.16 36.0644 5532 2296.5 5077.5 First Reading For Entire File..........2256.5 Last Reading For Entire File...........5172 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name ........... ..STSLIB.003 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/03/02 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.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 RPS 5118.5 9013.0 FET 5118.5 9013.0 RPD 5118.5 9013.0 RPM 5118.5 9013.0 RPX 5122.0 9013.0 GR 5126.0 9005.5 ROP 5172.5 9063.0 LOG HEADER DATA DATE LOGGED: 10-OCT-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9063.0 TOP LOG INTERVAL (FT) 5172.0 BOTTOM LOG INTERVAL (FT) 9063.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.8 MAXIMUM ANGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 148579 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 6.750 5165.0 • Mineral Oil Base 8.90 85.0 .0 39000 3.0 000 .0 000 120.0 000 .0 000 .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 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5118.5 9063 7090.75 7890 5118.5 9063 RPD MWD030 OHMM 0.51 2000 22.9311 7790 5118.5 9013 RPM MWD030 OHMM 4.4 2000 20.1069 7790 5118.5 9013 RPS MWD030 OHMM 3.96 2000 19.0899 7790 5118.5 9013 RPX MWD030 OHMM 3.58 2000 16.3247 7783 5122 9013 FET MWD030 HOUR 0.22 73.43 1.54529 7790 5118.5 9013 GR MWD030 API 43.39 111.83 71.3001 7760 5126 9005.5 ROP MWD030 FT/H 1.83 568.04 174.26 7782 5172.5 9063 First Reading For Entire File..........5118.5 Last Reading For Entire File...........9063 File Trailer Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/03/02 Maximum Physical Recor d..65535 File Type ............. ...LO Next File Name........ ...STSLIB.004 • ~ Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/02 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 .....................06/03/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
