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206-150
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-180 KUPARUK RIV U WSAK 1J-180 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-180 50-029-23329-00-00 206-150-0 W SPT 3290 2061500 1500 505 505 505 505 32 37 37 37 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-180 Inspection Date: Tubing OA Packer Depth 1140 2000 1960 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509092729 BBL Pumped:2.1 BBL Returned:1.9 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:28:56 -08'00' Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2061500 E-Set: 34729 (C2c4 j T- 1So <S�JJ Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophiIli ps.com> �7(� ��31 1 Sent: Thursday, May 30, 2019 5:39 PM Z I q To: Regg, James B (CED) Cc: Braun, Michael (Alaska); Autry, Sydney; CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Subject: LPP/SSV Returned to Service on CPAI Well 1J-180 Jim, The low pressure pilot (LPP) on well 1J-180 (PTD# 206-150, 206-151) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 5/30/2019, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 717 BWPD at 292 psi wellhead pressure. The LPP had been defeated on 4/19/2019 after the well was returned to service after a short shut-in period for facility maintenance. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 6, 2019 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7"' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: aoc0- I5a RECEIVED MAY 0 8 2019 AOGCC 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Kuparuk Field Date 5/612019 1J & 1H Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of Cement top off cement date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls It gal U-180 50029233290000 2061500 20'9" 2.80 1'5" 5/4/2019 5 5/5/2019 1H-101 50029235850000 2171380 210" 0.70 9" 5/4/2019 2.2 5/5/2019 1H-102 50029235800000 2170970 2'9" 0.65 8" 5/4/2019 1.7 5/5/2019 1H-103 50029235930000 2180030 2'2.5" 0.45 9" 5/4/2019 2.2 5/5/2019 1H-104 50029236100000 2180840 2'.5" 0.40 9" 5/4/2019 2.2 5/5/2019 1H -108B 50029236080200 2180820 3'8" 0.80 10" 5/4/2019 2.5 5/5/2019 11-1-109 50029235950000 2180130 2'3" 0.40 9" 5/4/2019 2.2 5/5/2019 1 H-110 50029236010000 2180310 2'6.5" 0.65 8.5" 5/4/2019 2 5/5/2019 1 H-111 50029235810000 2171330 2' 0.35 9" 5/4/2019 2.2 5/5/2019 1H-113 50029235880000 2171680 2'1" 0.40 8" 5/4/2019 1.7 5/5/2019 1H-114 50029235840000 2171360 1'11" 0.25 7.5" 5/4/2019 1.8 5/5/2019 1H-115 50029236050000 2180530 2'2.5" 0.35 8.5" 5/4/2019 2 5/5/2019 1H-116 50029235940000 2180120 17" 0.25 7" 5/4/2019 1.7 5/5/2019 11-1-117 50029236020000 2180320 1'11" 0.35 7" 5/4/2019 1.7 5/5/2019 1H-118 50029235780000 2170840 2'4" 0.50 8.5" 5/4/2019 2 5/5/2019 1 H-119 50029235910000 2171780 3' 0.80 8" 5/4/2019 1.8 5/5/2019 KRA IJ -lam PM 2v(c 650 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, April 19, 2019 4:10 PM To: Regg, James B (DOA) l Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1 &2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI well 1J-180 on 4/19/2019 Jim, The low pressure pilot (LPP) on well 1J-180 (PTD# 206-150, 206-151) was defeated this afternoon, 4/19/2019. The well was returned to service after a STP facility maintenance. The well is currentlyin�ec g 1,065 BWPD at 240 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 406B.001." Please let me know if you have any questions. Thank you, Toon Changklungdee Toon Changklungdee / Marina Krysinski WestSak Production Engineer Office: (907) 659-7234 Pager: (907) 659-7000 pp 497 ��ri✓u � -� p7b 2,06 1 soc Regg, James B (DOA) From: NSK West Sak Prod Engr <nl638@conocophill ips.com> Sent: Saturday, April 6, 2019 11:05 AM To: Regg, James B (DOA) Cc: CPF1 Ops Supv; CPF1 DS Lead Techs; CPF1 &2 Ops Supt; NSK Optimization Engr; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara Subject: LPP/SSV Returned to Service on CPAI Well 1J-180 Jim, The low pressure pilot (LPP) on well 1J-180 (PTD# 206-150, 206-151) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 4/6/2019, after the LPP setpoint was adjusted to accommodate sustained reduced wellhead pressure. The well is currently injecting 986 BWPD at 299 psi wellhead pressure. The LPP had been defeated on 2/10/2019 after the well was returned to service after an extended shut-in period to execute a casing repair. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 leo Regg, James B (DOA) From: NSK West Salk Prod Engr <nl638@conocophillips.com> Sent: Monday, February 11, 2019 7:57 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; NSK Optimization Engr Subject: Defeated LPP/SSV on CPAI well 1J-180 on 2/10/2019 Jim, The low pressure pilot (LPP) on well 1J-180 (PTD# 206-150, 206-151) was defeated last night, 2/10/2019, after the well was returned to service after an extended shut-in period for a casing repair. The eTi✓ i'li`s currently injecting 1,224 BWPD at 235 psi wellhead pressure. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the 'Faci�efeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative — Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MCULI SALE) JAN 2 9 20i9 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Performed: Suspend Perforate ❑ Other Stimulate El Pull Tubing ❑ Operations, 8 utdown �, After Casing Change Approvedrdgram Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: SC Repair Q 2. Operator ConocoPhillips Alaska, Inc. 14. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Stratigraphic ❑ Exploratory ❑ Service ❑✓ 206-150 3. Address: P. 0. Box 100360, Anchorage, 6. API Number: Alaska 99510 500292332900-00 7. Property Designation (Lease Number) 8. Well Name and Number: KRU U-180 ALD0025661/ADL0025662/ADL0025663/ADLO385172 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Poo'is). Ku aruk River Field / West Salk Oil Pool 11. Present Well Condition Summary: Total Depth measured 17834' feet Plugs measured 523' feet true vertical 3351' feet Junk measured 10102' feet Effective Depth measured 17789, feet Packer measured 9992' feet true vertical 3351' feet true vertical 3291' feet Casing Length Size MD TvD Burst Collapse Conductor 80' 20' 120' 120' Surface 3963' 13.375" 4001' 2227' Production 10804' 9 5/8 " 10845' 3378' Tubing (size, grade, measured and true vertical depth) 4.5" L-80 10010' MD 3293' TVD Packers and SSSV (type, measured and true vertical depth) Seal assembly Baker 190-47 9992' MD 3291' TVD No SSSV,Camco DB Nipple 523' MD 521' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: I N/A N/A INIA N/A INIA 14. Attachments (inquired per20 AAC 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development p ❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUG e 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-542 Contact Name: Roger Mouser / Roger Winter Authorized Name: Roger Mouser Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@conocophillips.com Authorized Signature: Dat Contact Phone: 907-659-7506 1/25/2019 Form 10404 Revised 4/2017 RBDM"FEB 0 12019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 25`h, 2019 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7ch Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 1J-180 (PTD 206-150) for surface casing repair. If you need additional information, please contact us at your convenience. Sincerely, Roger Mouser / Roger Winter Well Field Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7506 WELLS TEAM ?►*!vz Date Event Summary 1-3-19 100% CORROSION LOCATED @ 16' Y BELOW WELLHEAD CONNECTION. 1-18-19Welders fit & weld 4" x 3" bottom & 3" x 2" top double stack collars made from 16" X65.375 wall pipe. Kakivik UT & MT collars. 1-19-19 Fit and weld 20' of 16" X65 .500 wall pipe to X65.375 collars. 1-21-19 AOGCC rep Brian Bixby witnesses SC repair welds, Pressured OA with N2 with no signs of external leak at 190 psi, 1-22-19 Install/ Welded 212" of 20" conductor. 1-24-19 Pull shoring box and stairs. Begin backfill operations. ,z { . i �,`� X '� 4 `t: d �: y; "a1Cuy�.. r �i F:?� �"� � ,;�;. . i; '� .' ,.,f,�.-' �•.a', ♦ .. vay, Mr 1 ' t"�r`, Ibj.`SF_ 1 L � i y ` ^3� __ m.: r ..� moi. .. ,z { . i �,`� X '� 4 `t: d �: y; "a1Cuy�.. r �i F:?� �"� � ,;�;. . i; '� .' ,.,f,�.-' �•.a', ♦ .. vay, Mr a 's, . I MEMORANDUM S State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,May 14,2018 Jim Regg Supervisor k Zvisor p q i g SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1J-180 FROM: Lou Laubenstein KUPARUK RIV U WSAK IJ-180 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J��- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-180 API Well Number 50-029-23329-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-150-0 Inspection Date: 5/9/2018 vInsp Num: mitLOL180510145513 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-180 Type Inj j W TVD I 3290 . Tubing 599 596 - 596 597 - PTD 2061500 Type Test SPT Test psi; 1500 - , IA 1470 2200 2180 ' 2180 BBL Pumped: T 1.6 BBL Returned: ! 1.4 - 1 OA 4 - 5 5 5 Interval 4YRTST P/F P V Notes: JUN 0 4 2018 P elof1 Monday,May 14,2018 ag oytO Nen 0 • 1cu -- T 1 in o v 2 N ' - 3 WSW (1.) -CL' h �To Up 4-' >4 (0 CD N Z f6 4- -0 CO o W 4c o v E — J m C 1n U N {-+ > (6 +� O Ln v I-• Y SJ d a C E C off,! c °+.' m •C ' m o a a m QW r N- N- N- N- < V+ ) i :.v., a m J O m cc m m s p v, L C ~ OONNN0 "6 0 4Z QZ Q °J > op a:Q r — COCF- v (aOI— (aN n u W 0 0 0 0 0 i i a J J J J J - C `- U w ILIWWWW N 'C F- LL LL LL LL LLa) -0 UI- J J J J J v C i� G t a Z Z Z Z Z N t U 0 N • C)iii LL LL LL LL LL CC --. .B > t0 0, Z a U Iw 0 o N 1`, o-r f0 O f6 F L t CV cc• O• U Q N a C co v C a j ).,4Sr+ O a m Li_ u u u "1:1 ( Z , m -1 W PI v a > W U rt J \ N !��o > O V 2x0 < vs x1 � Lai s...., ._ ... m CO `o o>c EE3 3 1 gza � W a 0111-,P .-91 v W LIJWWW ' > > > > > .a w w w w 0 Z Y Y Y Y Y p Q' d' Q' Q' CY Y Y Y Y Y T CI W Q Q Q Q Q > > aaa A o LIJI tivc@ Nce U W coM y co r co X n03 CC O O O O O NMI O O O O O C E W 00000 QO > 00000 fn fn fn N N @ W m < x H 00000 0 ra u 63 0 0 0 0 0 0 0 0 0 0 C oA a .,..... v v v N 7, E (r1 It W C) N M C N 0 0 N M M M M eU N+ a N N N N N L _O 0 <.Q O O O O O N vi p N N N N N t 01 O O O O O 3 v O O O O O a+ 0 N an ccLA en R E u > U LCID Y 94 Wc c 9 ~ d ti o Tr `r° CO0To y vai 0C/3 n. $a � H a E. TT 76.6 ),szo Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �C��� if 11 i(0 Sent: Sunday, January 17, 2016 4:40 PM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael;Jensen, Marc D; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; Haakinson, David Subject: LPP/SSV on well 1J-180 was returned to service Jim: The low pressure pilot(LPP) on well 1J-180 PTD#206-150 206-151)was returned to service and removed from the safety defeat log today, January 17th, 16, after the we ead injection pressure increased above the LPP trip point of 500 PSI. This notification is in accordance with "Administrative Approval No. CO 4066.001." The current wellhead injection pressure is 530 psi at an injection rate of 1,300 BWPD. Please let me know if you have any questions. Kind Regards, Tyler Hall / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. SCANNED Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • +5o 21v--5 33 WELL LOG TRANSMITTAL#902831745 To: Alaska Oil and Gas Conservation Comm. December 3, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 t2i3Di2015 g � '�, K.BENDER 1 dd A 4 „y S 4n` •` RE: Multi Finger Caliper(MFC): 1J-180 Run Date: 10/15/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1.1-180 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23329-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: /'2vaga.ozczeit STATE OF ALASKA • 1 _ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon j Plug Perforations 1— Fracture Stimulate 1— Pull Tubing Iv Operations Shutdown [— Performed: Suspend E Perforate r Other Stimulate 1— v Alter Casing r Change Approved Program I Plug for Red rill E Perforate New Pool r Repair Well r Re-enter Susp Well r 0 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r...... 206-150 3.Address: 6.API Number: Stratigraphic r Service [V- P. P. O. Box 100360,Anchorage,Alaska 99510 50-029-23329-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25662,25663,385172 KRU 1J-180 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17834 feet Plugs(measured) None true vertical 3351 feet Junk(measured) None Effective Depth measured 17832 feet Packer(9989, 10168 MD) 0 true vertical 3350 feet (3290,3314 tvdl) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 SURFACE 3963 13.375 4001 2227 INTERMEDIATE 10804 9.625 10845 3378 B-SAND LINER 7666 8.43 17834 3351 SCAM$E�1 APR 0 S 2010 ° Perforation depth: Measured depth: 10878-12852, 13110-14330, 14582-15833, 16132-16604,16904-17789 DEC 0 1 2015 True Vertical Depth: 3380-3387, 3377-3368, 3361-3352, 3351-3345, 3350-3351 "� AOGCC Tubing(size,grade, MD,and TVD) 4.5, L-80, 10010, 329 3 Packers&SSSV(type,MD,and TVD) ZXP Liner Top Packer 9989=MD, 3290=TVD, HRD ZXP Liner Top Packer 10168=MD, 3314=TVD SSSV: NIPPLE 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 Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations i. . Exploratory F Development 3_... Service k Stratigraphic Copies of Logs and Surveys Run n 16.Well Status after work: Oil 1— Gas I WDSPL [— Printed and Electronic Fracture Stimulation Data (— GSTOR j.... WINJ WAG I GINJ I— SUSP 7 SPLUG 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: 315-620 Contact Danny Kane@265-6048 Email Danny.Kane a(�conocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature i t Phone:265-6048 Date v 311Ill Form 10-404 Revised 5/2015 `J RBDMS DEC 0 2 2015 Submit Original Only • KUP 0 1J-180 COtt©Ct311ll1{35 _ Well Attribute Max Angle&MD TD ',, Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,lm. ColwCo3h1g11tt 500292332900 WEST SAK INJ 93.60 14,694.65 17,835.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-11-180,12/1/2015 11,26-.20 AM SSSV:NIPPLE Last WO: • 10/26/2015 43.51 2/27/2007 Vertical schema9c:(apWa)): Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;36.0 :tlr Last Tag: Rev Reason:WORKOVER,GLV CIO,removed lehallf 11/13/2015 ISO Sleeve Casing Strings Casing Description OD ID TopftKB Set Depth ftKB Set Depth(TVD)... WtlLen(I...Grade TopThread 9 P (in) (in) ( I P ( ) P ( ) CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 WELDED -titi CONDUCTOR;400-120.0 Casing Description OD(in) 113(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread NIPPLE;522.7 SURFACE 13 3/8 12415 37.7 4,000.6 2,226.6 68.00 L-80 Buttress 11 4. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread GAS LIFT;2,3094 -411, INTERMEDIATE 95/8 8.835 40.6 10,844.5 3,377.6 40.00 L-80 BTC-M 1. SURFACE;37.74,000.6 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D LINER LEM 41/2 3.958 9,988.9 10,212.1 3,319.2 12.60 L-80 IBT-mod SLEEVE;9,9/3.2 - Liner Details Nominal ID am Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) LOCATOR;9,991.4 : G. 9,988.9 3,2902 8266 PACKER ZXP LINER TOP PACKER 7.500 SEAL ASSY;9,992.4 a_, 10,011.5 3,293.2 82.56 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 Val 10,031.1 3,295.7 82.53 XO BUSHING CROSSOVER BUSHING 3.950 ® 10,036.3 3,296.4 82.52 HANGER PZ LEM ABOVE Hook Hanger 3.950 f'Iffi�' 10,048.5 3,298.0 82.49 HANGER PZ LEM INSIDE Hook Hanger 3.688 • 1 10,102.1 3,305.0 82.44 NIPPLE CAMCO DB-6 NIPPLE 3.562 10,208.9 3,318.8 82.90 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread fir D LINER HH 41/2 3.476 10,048.5 10,312.5 3,330.7 11.60 L-80 BTC a Liner Details D LINER LEM;9,988.9-10,212.1 Nominal ID 2 Top(ftKB) Top(TVD)(ftKB) Top Inoi(°) (tem Des Com (in) 10,048.5 3,298.0 82.49 HANGER Baker Model PZ Hook Hanger inside 9-5/8" 7.720 10,070.0 3,300.8 82.45 HANGER Baker Model PZ Hook Hanger outside 9-5/8" 5.020 D LINER HH;10,048.510,3125 I 10,077.2 3,301.7 82.44 XO Reducing CROSSOVER 5.5"04.5" 3.930 INTERMEDIATE;40.6-10,841.5 10,214.5 3,319.5 82.97 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.900 _ _ 10,282.5 3,327.3 83.73 BENT JT 3.960 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)...WVLen(I...Grade 'Top Thread - - B-SAND LINER 4 1/2 3.476 10,168.5 17,834.0 11.60 L-80 Hydril SLOTS;10,078.0-11,336.0 Liner Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(°) Item Des Com (in) _ _ 10,168.5 3,313.7 82.56 PACKER HRD ZXP Liner Top Packer 8.430 _ _ 10,1873 3,316.1 82.64 NIPPLE RS PACKOFF SEAL NIPPLE 6.220 10,190.1 3,316.5 82.67 HANGER FLEXLOCK LINER HANGER 6.270 SLOTS;11,586.0-12,099.0 _ _ 10,198.9 3,317.6 82.78 XO BUSHING CROSSOVER BUSHING 4.900 10,200.3 3,317.8 82.80 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 10,219.9 3,320.2 83.04 XO BUSHING CROSSOVER BUSHING 3.910 - - Tubing Strings SLOTS;12,352.0.12,852.0 - - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection WORKOVER 4-1/2 41/2 3.958 36.0 10,010.0 3,293.0 12.60 L-80 IBTM Completion 2015 _ _ Completion Details -i _ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) - - 36.0' 36.0 0.00 HANGER Vetco Gray 13-5/8 x 10-3/4 False TBG hanger bowl w/10 3.958 -3/4 x 4-1/2 TBG hanger wl 4.909"MCA top threads and SLOTS;13,110.0.13,576.0 - - 4-1/2 IBTM bottom threads. - - 522.6 521.0 10.88'NIPPLE Camco 4-1/2"DB-6 Nipple with 3.875"No-Go Profile SN- 3.875 T051422 9,943.2 3,284.8 83.62 SLEEVE Baker 4-1/2"CMU Sliding Sleeve W/3.813"X Profile- 3.813 - - Ran in Closed Position SLOTS;13,866.0.14,330.0 9,991.4 3,290.6 82.61 LOCATOR BAKER 4-1/2",12.6#,L-80,IBTM Pup joint 3.958 9.992.4' 3,290.7 82.60 SEAL ASSY Baker 190-47 20-ft Seal assembly with 4-ft spaceout 3.840 - - Perforations&Slots Shot Den - - Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(0103) (ftKB) (ftKB) Zone Date ft) Type Com SLOTS;14,502.0-15110.0 - 10,878.0 11,336.0 3,380.2 3,386.5 WS B,1J-180 2/7/2007 32.0 SLOTS ALL PERFS IN WELLBORE:Alternating - - solid/slotted pipe- 0.125"x2.5"@ 4 - - circumferential adjacent - rows,3"centers staggered 18 deg,3'non - - -slotted ends SLOTS;15,370.0-15633.0 11,586.0 12,099.0 3,388.8 3,385.2 WS B,1J-180 2/7/2007 32.0 SLOTS _ _ 12,352.0 12,852.0 3,382.1 3,387.3 WS B,1J-180 2/7/2007 32.0 SLOTS 13,110.0 13,578.0 3,376.9 3,369.3 WS B,1J-180 2/7/2007 32.0 SLOTS _ - 13,866.0 14,330.0 3,367.7 3,367.7 WS B,1J-180 2/7/2007 32.0 SLOTS SLOTS;16,1325-16,604.0 _ _ 14,582.0 15,119.0 3,360.9 3,349.8 WS B,1J-180 2/7/2007 32.0 SLOTS _ - 15,370.0 15,833.0 3,357.5 3,352.5 WS B,1J-180 2/7/2007 32.0 SLOTS _ _ 16,132.0 16,604.0 3,351.0 3,344.9 WS B,1J-180 2/7/2007 32.0 SLOTS - - 16,904.0 17,789.0 3,350.2 3,351.4 WS B,1J-180 2/7/2007 32.0 SLOTS - - Mandrel Inserts - - St au - - on Top(ND) Valve Latch Port Size TRO Run SLOTS;18,904.0.17,789.0 _ _ N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 2,309.4 1,891.2 Camco KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/3/2015 B-SAND LINER,10,1%5- 17,834.0 0,168.517,834.0�_. KUP e • 1J-180 ConocoPhillips 1., • Alaska.Inc. COIX.C4 iltips ,. Njukpla Laterals-1J-180,7211!2015 17:2827 AM Vmt1cal rGlemaRc(actual) HANGER,36.0 1iq. Notes:General&Safety U • ' 3/2/2007 End Date Annotation -ham CONDUCTOR;40.0-120.0 � NOTE:MULTI-LATERAL WELL 1J-180(B-SAND),1J-180L1(D-SAND) NIPPLE:522.7 GAS LIFT;2,309.4 - - . SURFACE;37.7-4,030.6 L SLEEVE;9,943.2 IT• I tor LOCATOR 9,991.4 9 i SEAL ASSY;9,992.4 gg� >31 '1 I' a a t D LINER LEM;9,988.9-10,212.1 D LINER HH;10,018.5-10,312.5 INTERMEDIATE;40.8-10,844.5 SLOTS;10,878.0-11,338.0 SLOTS;11.5880-12,099.0 SLOTS;12,352.0-12,852.0 .� SLOTS;13,110.0-13,578.0.—r— SLOTS;13,888.0.14,330.0 SLOTS,14,582.0-15,119.0 SLOTS;15,370.0-15,833.0 s,o'S 16 132.0-16,604.0 — SLOTS,16,904.0-17,789.0 B-SAND LINER;10,168.5 17,834.0-\ • • =' Daily Operations Summary (with Depth Cost MW) 1J-180 ConoccAlinmps Rig: NABORS 9ES Job: RECOMPLETION Dens Last Depth Progress Mud Field Est Mud Start Date End Date Last 24hr Sum End Depth(ftKB) (ft) Daily Cost Total(Cost) Cum Cost(Cost) (Cost) Cum Mud Cost(Cost) (Ib/gal) 10/19/2015 10/20/2015 Pull Pit module away 0.0 442,424.84 442,424.84 from sub and transport to 1J pad. Lay derrick over and prep sub in preparation for Pad to Pad move. Road rig off 1D pad onto spine for 1/10th of a mile then right hand turn onto 1J Access road. Travel down 1J access towards 1J Pad. 10/20/2015 10/21/2015 Continue to move rig 0.0 233,049.94 675,474.78 58,031.78 58,031.78 9.90 to location,Spot, MIRU and Berm up. Accept rig Nabors 9ES at 15:00 hrs. Kill well, 10/21/2015 10/22/2015 Continue to kill well 0.0 132,913.61 808,388.39 28,320.56 86,352.34 9.90 and monitor for flow. Shoot fluid level-1st shot=50-ft,2nd Shot=60-ft. Set BPV. ND Tree. 10/22/2015 10/23/2015 ND SSV and install 0.0 127,668.72 936,057.11 29,744.17 116,096.51 9.90 1502 integral on Production wing valve. NU BOP and Test,24 hr Notice was given @ 07:09 hrs on 10-19-15 and Witnessed by Lou Grimaldi. Pull blanking plug and BPV. Pull seals from SBR @ 10,012-ft. POOH to 8,945-ft and PU storm packer and set at 118-ft. Test to 500 psi for barrier test. 10/23/2015 10/24/2015 Pull mouse hole, 0.0 99,785.71 1,035,842.82 2,078.31 118,174.82 9.84 Riser and ND BOP. ND and Pull Well head and swap out do to bad lock down pins. NU and Shell test break. Recover storm packer and continue to POOH from 8,945-ft to 4,081-ft 64K Up wt, 53K Dn wt. Page 1/2 Report Printed: 11/30/2015 • • Daily Operations Summary (with Depth Cost MW) rt 1J-180 ConootWhillips Rig: NABORS 9ES Job: RECOMPLETION Dens Last Depth Progress Mud Field Est Mud Start Date End Date Last 24hr Sum End Depth(ftKB) (ft) Daily Cost Total(Cost) Cum Cost(Cost) (Cost) Cum Mud Cost(Cost) (lb/gal) 10/24/2015 10/25/2015 Contninue to POOH 0.0 98,908.36 1,134,751.18 2,078.31 120,253.13 9.80 laying down 4-1/2 De completion from 4,081-ft to seal assembly. Load pipe shed with remaining 124 jts and Completion components. RIH as per Run order to 4,334-ft 65K Up wt, 54K Dn wt and AVE MU torque=3,800 ft/lbs 10/25/2015 10/26/2015 Continue to RIH as 0.0 125,951.55 1,260,702.73 7,117.02 127,370.15 9.90 per Run order from 4,334-ft 65K Up wt, 54K Dn wt and AVE MU torque=3,800 ft/lbs. to 10,014-ft and locate SBE and No-Go. Space out, MU TBG hanger and load IA with CI 9.9 ppg Brine to 10,014- ft. Land hanger, RILDS and PT IA to 2,500 psi for 30 minutes. Bleed off and ramp up to 3,500 psi and shear out SOV @ 2,297-ft±. Conduct BWM. 10/26/2015 10/26/2015 ND BOPE and NU 0.0 135,928.08 1,396,630.81 251.52 127,621.67 9.90 Tree. FP to 2,300-ft ± RDMO. Release Nabors 9ES @ 12:00 hrs on 10-26-15 Page 2/2 Report Printed: 11/30/2015 • • Operations Summary (with Timelog Depths) cr dei : 1J-180 CononoPhiiiiiips 05tmks Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/19/2015 10/19/2015 10.00 MIRU MOVE RURD P Bridle up and lower bridle lines. Tie 10:00 20:00 back service loop in derrick. Remove pins from blocks and pin bridle lines to blocks. Raise blocks with bridle lines. Remove torque tube pins,lower upper and lower cattle chute. Inspect derrick. Remove A leg pins and lower mast. Secure lines in derrick for transport.PJSM with Peak driver and pusher. Pull pits away from Sub. Install jeep and transport pits to 1J Pad and stage. Pull rig off of well 1 D- 123. Clean and clear area in preparation of environmental handover. 10/19/2015 10/20/2015 4.00 MIRU MOVE MOB P Road rig off 1D pad onto spine for 20:00 00:00 1/10th of a mile then right hand turn onto 1J Access road. Travel down 1J access towards 1J Pad. 10/20/2015 10/20/2015 1.00 MIRU MOVE MOB P Road rig down 1J access to 1J Pad. 00:00 01:00 10/20/2015 10/20/2015 0.50 MIRU MOVE MOB P Set mats around cellar and lay out 30 01:00 01:30 x 30 pit liner. 10/20/2015 10/20/2015 2.50 MIRU MOVE MOB P Pull rig over well,sit down. 01:30 04:00 Sim ops-Set kill tanks 10/20/2015 10/20/2015 1.50 MIRU MOVE MOB P PJSM with Truck driver,Spot pit 04:00 05:30 module. Sim ops-Continue to set kill tanks 10/20/2015 10/20/2015 2.50 MIRU MOVE RURD P Berm up,raise derrick and set cattle 05:30 08:00 chute. Set choke house and lay kill lines from well to kill tank. Set and berm LEPD Fuel tank. Load pits with 9.9 ppg 3%KCL/NaCI brine w/.06% by volume safe lube. PT kill lines to 250/3,500 psi. 10/20/2015 10/20/2015 9.00 MIRU MOVE RURD P Raise derrick and set cattle chute. 08:00 17:00 Drlg toolhouse Sim ops-Set choke house and lay kill lines from well to kill tank. RU inter-connect Set and berm LEPD Fuel tank. Load pits with 9.9 ppg 3%KCL/NaCI brine w/.06%by volume safe lube. 10/20/2015 10/20/2015 0.50 MIRU MOVE SFTY P Accept Nabors 9ES @ 15:00 hrs and 17:00 17:30 hold Pre spud with Night crew for 1J- 180, 10/20/2015 10/20/2015 2.25 MIRU WELCTL MPSP P Open well,PU,RU and PT lubricator 17:30 19:45 to 1,000 psi. Pull BPV with lubricator. RD Lubricator. Obtain pressures- SITP= 400,SICP=380,SIOCP= 10/20/2015 10/20/2015 1.25 MIRU WELCTL RURD P RU and PT kill lines to 250/3,500 psi. 19:45 21:00 10/20/2015 10/21/2015 3.00 MIRU WELCTL KLWL P PJSM,Bleed TBG Psi from 400 psi to 21:00 00:00 260 psi through choke house to kill tank#1. 101 bbls of diesel total- SIP's=260 psi 10/21/2015 10/21/2015 1.25 MIRU WELCTL OWFF P Shut well in and monitor pressures. 0.0 0.0 00:00 01:15 Disconnect lines. SITP=260 psi. SICP=260 psi Page 1/7 Report Printed: 3/15/2016 • 0 Operations Summary (with Timelog Depths) . &Wetly. 1J-180 conocaPhitlips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/21/2015 10/21/2015 0.25 MIRU WELCTL SFTY P Pre-job meeting with crew and truck 0.0 0.0 01:15 01:30 drivers 10/21/2015 10/21/2015 0.25 MIRU WELCTL SEQP P Pressure test lines and surface 0.0 0.0 01:30 01:45 equipmet to 3500 psi. Blow down lines 10/21/2015 10/21/2015 3.25 MIRU WELCTL KLWL P Reverse circulate to kill well. Pump 0.0 0.0 01:45 05:00 down IA taking returns to tiger tanks. Initial volume in tank=101 bbl. Initial rate 5 bpm @ 780 psi. Final rate 4 bpm @ 171 gpm. Final fluid weight= 9.7+ppg. Pumped a total of 1004 bbl. Final tank volume=702 bbl. SIDP= 38 psi,SICP=65 psi 10/21/2015 10/21/2015 0.25 MIRU WELCTL RURD P Blow down lines 0.0 0.0 05:00 05:15 10/21/2015 10/21/2015 1.25 MIRU WELCTL OWFF P Monitor well while waiting for brine. 0.0 0.0 05:15 06:30 SICP=65 psi, SITP=38 psi 10/21/2015 10/21/2015 0.50 MIRU WELCTL OWFF P Open IA to Tiger Tank while taking 0.0 0.0 06:30 07:00 straps and pressure readings every 5 mionute4s. SWI. SITP=2;SICP= 110;SIOCP=8. Recovered 32 bbls of 9.9 ppg brine while bleeding off pressure for 30 minutes. 10/21/2015 10/21/2015 8.00 MIRU WELCTL WAIT T Monitor well pressures while waiting 0.0 0.0 07:00 15:00 for KWF to arrive from Dead horse. Starting SIPs= 10 PSI TBG, 130 PSI IA and 8 PSI OA. Ending SIP's=24 PSI TBG, 150 PSI IA and 16 PSI OA. after 8 hrs. Sim-ops- Continue to load,drift to 3.90"and rack and tally 4-1/2, 12.6#,L -80 IBTM R2 Tubing in the pipe shed. 10/21/2015 10/21/2015 1.50 MIRU WELCTL KLWL T PJSM,RU to take returns to the kill 0.0 0.0 15:00 16:30 tank. PT lines at 250/3,500 psi- good test. Pumped 150 bbls at 4 bpm at 260 psi ICP and 310 FCP. Recovered 109 bbls at the kill tank. 10/21/2015 10/21/2015 0.50 MIRU WELCTL RURD T RU to take returns from the tree to the 0.0 0.0 16:30 17:00 mud pits. Fill up pits in preparation for circulating. Monitor well. IA psi=0 and tbg psi=0. 10/21/2015 10/21/2015 4.00 MIRU WELCTL KLWL T PJSM,circulate 903 bbls of 9.9 ppg 0.0 0.0 17:00 21:00 Brine @ 4 bpm @ 280 psi w/65 BPH Fluid losses. 10/21/2015 10/21/2015 0.50 MIRU WELCTL OWFF T Monitor well for flow- well on vac. 0.0 0.0 21:00 21:30 Call out DHD for FL shot. 10/21/2015 10/21/2015 0.50 MIRU WELCTL KLWL T Shoot fluid level-1st shot 21:30 hrs= 0.0 0.0 21:30 22:00 50-ft,2nd shot @ 22:00 hrs=60-ft. 10/21/2015 10/21/2015 1.25 MIRU WELCTL RURD P PJSM,RD circulating equipment in the 0.0 0.0 22:00 23:15 cellar. 10/21/2015 10/21/2015 0.25 MIRU WHDBOP MPSP P Dry rod in BPV 0.0 0.0 23:15 23:30 10/21/2015 10/22/2015 0.50 MIRU WHDBOP NUND P PJSM,ND Tree 0.0 0.0 23:30 00:00 10/22/2015 10/22/2015 2.50 MIRU WHDBOP NUND P PJSM,Remove Surface safety valve 0.0 0.0 00:00 02:30 from production wing and install 1502 Integral adapter. ND tree,pull tree with traveling blocks. Remove the tree and hang back. Page 2/7 Report Printed: 3/15/2016 • • ,,i, ... ....3 Operations Summary (with Timelog Depths) .0 rpt 1J-180 ConocoPhillips A.C.I. Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/22/2015 10/22/2015 0.50 MIRU WHDBOP OTHR P Inspect lock downs for failure during 0.0 0.0 02:30 03:00 function testing Pre-rig. Install Blanking plug and gather measurements for clearance during ram closure. 10/22/2015 10/22/2015 2.50 MIRU WHDBOP NUND P NU 13-5/8 5M BOPE onto 13-5/8 5M 0.0 0.0 03:00 05:30 well head flange. 10/22/2015 10/22/2015 0.50 MIRU WHDBOP RURD P PJSM,RU testing equipment. PU test 0.0 0.0 05:30 06:00 joint,MU 4"Dart valve and 4:HT FOSV,MU X-O's on 4-1/2 EUE 8rd FOSV,line up on choke,post signs and fill BOP stack- look for leaks- Good Purge manifold and hoses. Page 3/7 Report Printed: 3/15/2016 • OP ing Operations Summary (with Timelog Depths) 1J-180 Cona�coPPhiHips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 8.75 MIRU WHDBOP BOPE P Conduct Initial BOP test @ 250/ 0.0 0.0 06:00 14:45 3,500 psi with 4"and 4-1/2 test joints. 24 hr notice was given @ 7:09 hrs on 10-19-15. Test was witnessed by Lou Grimaldi. Test#1 Blinds,choke valves 1,2,3,16 and Demco kill,Upper IBOP,Mud manifold Test#2 Choke Valves 4,5,6. HCR Kill,Lower IBOP Test#3 Choke Valves 7,8,9. Manual Kill,4- 1/2 TIW Test#4 Manual and Hydraulic Choke,HCR Kill. Test#5 Choke Valves 10&11 Test#6 Choke Valves 12,13,14. Install 4"test joint and close LPR's. Test#7 Choke Valves 15. Annular,dart and HCR Kill. Test to 3,500 psi in order to make valves used in test count. Test#8 TIW,Top Rams and HCR Choke. Test#9 Manual Choke Test#10 TIW Valve,Install 4-1/2"test joint and close LPR's. Koomey test Koomey Pressure=2,975 psi. After Function=1,600 psi. 200 psi gain=31 seconds Full pressure= 154 seconds 6 Bottles @ 2,054 psi Test#11 LPR's TIW,HCR Choke and Kill and change test hose to Choke Test#12 Annular,TIW,Outer test spool and HCR Kill. Test#13 UPR's TIW and Inner test spool and HCR Kill. Blow down all test equipment and pull blanking plug 10/22/2015 10/22/2015 0.25 MIRU WHDBOP MPSP P Dry rod out BPV-Well on a vacuum 0.0 0.0 14:45 15:00 10/22/2015 10/22/2015 1.50 COMPZN RPCOMP RURD P PJSM, RU Weatherford Running 0.0 0.0 15:00 16:30 services tongs and equipment. 10/22/2015 10/22/2015 1.00 COMPZN RPCOMP PULL P PU,MU and un land TBG hanger at 0.0 0.0 16:30 17:30 196K Page 4/7 Report Printed: 3/15/2016 • • Operations Summary (with Timeiog Depths) &Wet :. 1J-180 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/22/2015 10/22/2015 3.00 COMPZN RPCOMP PULL P Pull hanger to rig floor and break out, 10,014.0 8,945.0 17:30 20:30 crimped pup jt under hanger-prep for shipping. Continue to POOH with 4- 1/2, 12.6#, IBTM Tubing from 10,014- ft to 8,945-ft 96K Up wt,53K Dn wt. 10/22/2015 10/22/2015 2.50 COMPZN RPCOMP MPSP X PU, MU and RIH 118-ft w/9-5/8 40# 8,945.0 9,063.0 20:30 23:00 Baker Storm packer and set with TBG tail @ 9,063-ft. Release from storm packer and POOH w/setting tool.84 Up wt,56K Dn wt. 10/22/2015 10/23/2015 1.00 COMPZN RPCOMP MPSP X Pjsm, PT against storm packer to 500 118.0 118.0 23:00 00:00 psi for 15 minutes-Good Test. 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP OWFF X Monitor well for flow-No flow 118.0 118.0 00:00 00:30 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP OWFF X Drain stack thru the IA valve,and blow 118.0 118.0 00:30 01:00 down lines. Open OA to cuttings box- bleed 16 psi 10/23/2015 10/23/2015 2.00 COMPZN RPCOMP NUND X ND BOPE and rack back 118.0 118.0 01:00 03:00 10/23/2015 10/23/2015 2.50 COMPZN RPCOMP NUND X ND Vetco Gray West Sak MB 222A 03:00 05:30 Big Bore Injector well head. Remove Horizontal 4-1/16 5M Production and IA valves. Prep wellhead -remove studs while bleeding OA to cuttings box. 10/23/2015 10/23/2015 0.25 COMPZN RPCOMP SFTY X PJSM with all on removal and 05:30 05:45 replacement of well head with assistance of Boom truck,Loader with stinger and Bridge crane in cellar. 10/23/2015 10/23/2015 1.75 COMPZN RPCOMP NUND X Prep area for well head recovery and 05:45 07:30 pull well head off starting head.Load Replacement head in cellar with loader assistance. 10/23/2015 10/23/2015 1.75 COMPZN RPCOMP NUND X Install and NU Replacement well head 07:30 09:15 and side port valves. PT Starting head pack off @ 2,400 psi for 10 minutes. 10/23/2015 10/23/2015 2.75 COMPZN RPCOMP NUND X NU BOPE. Install riser,mouse hole 09:15 12:00 and turn buckles.Set test plug and fill stack. 10/23/2015 10/23/2015 1.50 COMPZN RPCOMP BOPE X Shell test BOP flange/Well head 12:00 13:30 break©250/3,500 psi. Passed. RD Bop test equipment and clean and clear floor of testing equipment. 10/23/2015 10/23/2015 2.00 COMPZN RPCOMP MPSP X PU 3 jts of DP and retrieving tool. 13:30 15:30 RIH,locate and engage Storm packer. Check for pressure below packer- None. Release stormp acker and POOH. Lay Down the same. 10/23/2015 10/23/2015 0.50 COMPZN RPCOMP RURD X Change over elevators and floor 15:30 16:00 equipment for POOH and laying 4-1/2 IBTM tubing. Page 5/7 Report Printed: 3/15/2016 • • Eliokdi Operations Summary (with Timelog Depths) 0n 1J-180 ConocoPhillips Ai.k..5 Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/23/2015 10/24/2015 8.00 COMPZN RPCOMP PULL P Continue to POOH,laying down 4-1/2 8,945.0 4,081.0 16:00 00:00 12.6#,L-80 IBT-M Tubing from 8,945- ft88KUpwt,55KDnwt. to 4,081-ft 64K Up wt,53K Dn wt. Found hole in jt 157 @ 4,882-ft and jt# 178 had corroded threads 10/24/2015 10/24/2015 7.50 COMPZN RPCOMP PULL P Continue to POOH,laying down 4-1/2 4,081.0 0.0 00:00 07:30 12.6#,L-80 IBT-M Tubing from 4,882- ft 64K Up wt,53K Dn wt. to seal assembly 10/24/2015 10/24/2015 0.50 COMPZN RPCOMP SVRG P Service draw works and equipment 0.0 0.0 07:30 08:00 10/24/2015 10/24/2015 8.00 COMPZN RPCOMP OTHR P Load,drift,rack and Tally 124 joints of 0.0 0.0 08:00 16:00 4-1/2, 12.6#,L-80 IBTM R2 Tubing for Total of 350 joints. Load completion equipment and double measurements and placement. 10/24/2015 10/24/2015 0.50 COMPZN RPCOMP SFTY P Held PJSM with all involved in the 0.0 0.0 16:00 16:30 running of the 4-1/2 recompletion string to 10,014-ft. 10/24/2015 10/25/2015 7.50 COMPZN RPCOMP PUTB P PU,MU and RIH w/4-1/2 Completion 0.0 4,334.0 16:30 00:00 string as per run order to 4,334-ft 65K Up wt,54K Dn wt.and AVE MU ' torque=3,800 fUlbs 10/25/2015 10/25/2015 9.25 COMPZN RPCOMP PUTB P Continue to PU,MU and RIH w/4-1/2 4,334.0 10,010.0 00:00 09:15 Completion string as per run order from 4,334-ft 65K Up wt,54K Dn wt. and AVE MU torque=3,800 ft/lbs to 10,014-ft and No-Go.Space out 4-ft afetr break over, mark pipe and lay down 3 joints add 2 pups=15.52-ft (9.85+5.67)and 346 joints @ 28.48- ft long average. 10/25/2015 10/25/2015 6.25 COMPZN RPCOMP CRIH P With mule shoe @ 9,985-ft. Pumped 9,985.0 9,985.0 09:15 15:30 562 bbls of CI 9.9 ppg 3%KCL/NaCI @ 3 bpm @ 290 psi. Blow down lines and drain BOPE stack ' 10/25/2015 10/25/2015 1.00 COMPZN RPCOMP THGR P Land TBG hanger and RILDS. 9,985.0 10,010.0 15:30 16:30 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP THGR P Test upper and lower hanger seals @ 0.0 0.0 16:30 17:00 250/5,000 psi as per Vetco Gray. 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP RURD P RD cement hose,head pin,and 0.0 0.0 17:00 17:30 landing joint. 10/25/2015 10/25/2015 0.50 COMPZN RPCOMP SFTY P PJSM with all involved for PT IA @ 0.0 0.0 17:30 18:00 2,500 psi shearing of the SOV. 10/25/2015 10/25/2015 1.50 COMPZN RPCOMP PRTS P Purge lines,fill hole and PT lines to 0.0 0.0 18:00 19:30 2,500 psi and chart for 30 minutes. Bleed IA and TBG to 0 psi. Pressure IA to 3,900 psi to shear SOV-No shear. Bleed pressure off,pressure back up and seen shear @ 3,650 psi. Reverse circulate @ 2 bpm @ 400 psi thru valve. Switch over and circulate @ 2 bpm @ 170 psi to verify shear out. 10/25/2015 10/25/2015 0.25 COMPZN RPCOMP OWFF P Monitor well for flow for 15 minutes. 0.0 0.0 19:30 19:45 No flow. 10/25/2015 10/25/2015 0.25 COMPZN WHDBOP MPSP P Install 3"BPV as per Vetco Gray 0.0 0.0 19:45 20:00 Page 6/7 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) 1J-180 ConocoPtriilliips AFsal..; Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 20:00 21:00 Pull riser and BWM on Annular preventer with 4"test joint. Function annular-annular element in good condition with no defects. Observed, no key seating noted at this time. 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 21:00 22:00 Break bolts,open upper ram doors. Inspect 2-7/8 x 5"VBR rams. Close doors and install studs 10/25/2015 10/25/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 22:00 23:00 Break bolts,open upper ram doors. Inspect Blind rams. Close doors and install studs 10/25/2015 10/26/2015 1.00 COMPZN WHDBOP SVRG P Conduct between wells maintenance 0.0 0.0 23:00 00:00 Break bolts,open lower ram doors. Inspect 2-7/8 x 5"VBR rams. Close doors and install studs 10/26/2015 10/26/2015 1.50 COMPZN WHDBOP NUND P Pull riser,disconnect turn buckles,pull 0.0 0.0 00:00 01:30 mouse hole. ND and set 13-5/8 5M BOP Stack. 10/26/2015 10/26/2015 1.50 COMPZN WHDBOP NUND P PU and land 13-5/8 5M Adapter and 0.0 0.0 01:30 03:00 Vetco Gray Horizontal Tree. NU same. 10/26/2015 10/26/2015 1.00 COMPZN WHDBOP MPSP P Pull BPV and Install TWC for testing of 0.0 0.0 03:00 04:00 the tree flanges. 10/26/2015 10/26/2015 2.00 COMPZN WHDBOP PRTS P Pressure test tree flanges-Good test. 0.0 0.0 04:00 06:00 Test hanger adapter seals @ 250/ 5,000 psi-All good tests. 10/26/2015 10/26/2015 0.50 COMPZN WHDBOP MPSP P Pull TWC with dry rod 0.0 0.0 06:00 06:30 10/26/2015 10/26/2015 3.75 COMPZN WHDBOP FRZP P RU Little Red Services,PT Lines at 0.0 0.0 06:30 10:15 2,000 psi. Pump 120 bbls into the!A attempting to take returns from the tubing. Recovered 77 bbls. Shut in tubing and bullhead 55 bbls due to volume to circ point and difference between 6.5 ppg diesel and 9.9 ppg Brine. Close well in. RD LRS. RU to Allow the TBG to swap with the IA. Allow 15 minutes for well swap. Ending pressure was=100 psi 10/26/2015 10/26/2015 1.00 COMPZN WHDBOP MPSP P PU lubricator and lubricate in the BPV 0.0 0.0 10:15 11:15 10/26/2015 10/26/2015 0.75 DEMOB MOVE RURD P RD berming around LEPD tank,tail 0.0 0.0 11:15 12:00 roll out LEPD tank.Clean and dress the tree. SIP's=TBG-100 psi, IA- 100 psi and OA-0 psi. Finish removing berming from around the rig. Pull off well. Release Nabors 9ES @ 12:00 hrs on 10-26-15 Page 7/7 Report Printed: 3/15/2016 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 30,2015 TO: Jim Regg �\ � ICI30i iS P.I.Supervisor �� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-180 FROM: Bob Noble KUPARUK RIV U WSAK 1J-I80 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv1 ' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-180 API Well Number 50-029-23329-00-00 Inspector Name: Bob Noble Permit Number: 206-150-0 Inspection Date: 11/20/2015 Insp Num: mitRCN151120180338 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 21/1 1J-180 `Type Inj ®TVD 3290 - Tubing 393 395 - 394 - 395 - t I'TD 2061500 'Type Test iiiTest psi 1500 - IA 1410 2000 - 1985 - 1985 - I nterval INITAL - P/F P ' OA 40 58 - 59 - 60 • Notes: Post Rig Workover. SCANNED SEP 16 2016; Monday,November 30,2015 Page 1 of 1 OF Tyi� • • ww�� I%% ,9 THE STATE Alaska Oil and Gas o fAT AASKA. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 94"ALASI4Q' Fax: 907.276.7542 www.aogcc.alaska.gov Danny Kane � � 1 `: Sr. Wells Engineer ConocoPhillips Alaska, Inc. )o ' 5 Z) P.O. Box 100360 VV Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-180 Sundry Number: 315-620 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this gay of October, 2015 Encl. RBDMS tic I ca Z015 STATE OF ALASKA ALXSKA OIL AND GAS CONSERVATION COMM SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing Operations Shutdown r Suspend r Perforate fl Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill fl Perforate New Pool Repair Well 17 Re-enter Susp Well r Other: 1- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory Development f 206-150- 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23329-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes 1— No r J KRU 1J-180 r 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662,25663,385172 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ' 17834 • 3351 • 17832' - 3350' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' SURFACE 3963 13.375 4001' 2227' r INTERMEDIATE 10804 9.625 10845' 3378' B-SAND LINER 7666 8.43 17834' 3351' u (Ns tol?(c5 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slots from 10878-17789 • slots from 3380-3351 4.5 L-80 10014 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=9989 TVD=3290 ' PACKER-HRD ZXP LINER TOP PACKER MD=10168 TVD=3314 NIPPLE-4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. MD=514 TVD=512 . 12.Attachments: Description Summary of Proposal 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic rDevelopment r Service • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/19/2015 OIL r WINJ r WDSPL fl Suspended 16.Verbal Approval: Date: GAS r' WAG p • GSTOR fl SPLUG f Commission Representative: GINJ r Op Shutdown fl Abandoned 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Danny.KaneAconocophillips.com Printed Name Danny Kane Title: Sr. Wells Engineer Signature Phone:265-6048 Date 05Z_pc-r_ad)(S Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness '216 -• (422-C) Plug Integrity BOP Test "` Mechanical Integrity Test Location Clearance Other: en_I 'P�� -)` -7 5-(7 0 fl 5 I.yam' (4/1/0 5,I) / - l '5 4- 1 5 1-g �-n -z v/4-f'' /fi re- v<vs f t✓ t`t-5 -1" / z vo /25 e . -_.71__4A-c., 0/l- -55.ed 44 IT-1 A rr v''std c-1, -V---t-✓ 1-4' 6-1 %f rcf c)1(1 le.117 ) Spacing Exception Required? Yes 0 No 1:421/ Subsequent Form Required: /11, 4D 4 APPROVED BY T- Approved by: COMMISSIONER THE COMMISSION Date:& �' S A r e I t I v Id or 12 months tro the date of approval. 5- Submit Form and Form 10-403 Revised 5/2015 pp I G �N � � iG)� S pp RBDMS.111EI,on71015)C i/TL L®l -1/1/ '-- . /od/,— • • C ConocoPhillips OCT G 2 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 2,2015 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover West Sak Injector KRU 1J-180/ 1J-180 L1 (PTD#206-150/206-151). KRU 1J-180/1J-180 L1 was spudded in January 2007 and completed as a dual-lateral West Sak B-&D-sand injector. However, after receiving permission from the AOGCC to the well through an open sliding sleeve,the well was initially pre-produced for a few months before finally coming online as a water injector in June 2007. In 2009,the well failed an MIT-IA and was shut-in. After performing diagnostic work,the sliding sleeve in the 4-'/2" upper completion was cycled open and after being closed,the well passed a MIT-IA. The well was then brought back on water injection service. In 2014, after a few months where the IA was tracking higher than the tubing pressure while on water injection, operations attempted to pressure up on the IA to create a positive IA to tubing differential pressure but was unable to build pressure within the IA. The well was shut-in at that time and after performing additional diagnostic work, multiple tubing leaks were identified in the 4-'/2"upper completion at 5,062',5,148',&5,300'MD. The proposed rig work-over of 1J-180/ 1J-180 L1 will consist of pulling the entire existing 4-'/2"upper completion to the seal assembly and replacing with a new 4-'/2"upper completion to bring the well back on water-alternating-gas injection. / This Sundry is intended to document the proposed rig workover on KRU 1J-180/ 1J-180 L1 where the intent is to pull tubing and to request approval to workover this well. If you have any questions or require any further information, please call me at 265-6048 or email me at dannv.kane@conocophillips.com. Sincerely, Danny Kane Senior Wells Engineer CPAI Drilling and Wells KUP INJ i 1J-180 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl i') MD(ftKB) Act Btm(ftKB) cr.,rarnn,inp, 500292332900 WEST SAK INJ 93.60 14,694.65 17,835.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date Multiple Laterals-1J-t80,6/24/20158'.05'.12 PM SSSV:NIPPLE _ Last WO: 43.51 2/27/2007 Vertical hem 1 (actual) _- Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER; Last Tag: Rev Reason'SET ISO SLEEVE lehallf 6/24/2015 36.0 I • Casing Strings Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 WELDED ..A.A.,CONDUCTOR;40.0.120.0• - �� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread NIPPLE;513.6 SURFACE 133/8 12.415 37.7 4,000.6 2,226.6 68.00 L-80 Buttress ame GAS LIFT;2,280.6 AI Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread INTERMEDIATE 95/8 8.835 40.6 10,844.5 3,377.6 40.00 L-80 BTC-M 1 Casing Description OD(in) ID 50) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE,377-4,000.6-- D LINER LEM 41/2 3.958 9,988.9 10,212.1 3,319.2 12.60 L-80 IBT-mod SLEEVE-C,9,948.2 1:11Liner Details Nominal ID LOCATOR.9,995.8 • � Top(ftKB) Top(TVD)(ftKB) Top!not CI Item Des Com (in) SEAL ASSY;9,996.4 et 9,988.9 3,290.2 82.66 PACKER ZXP LINER TOP PACKER 7.500 10,011.5 3,293.2 82.56 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 ' I3 10,031.1 3,295.7 82.53 XO BUSHING CROSSOVER BUSHING 3.950 I, { 10,036.3 3,296.4- 82.52 HANGER PZ LEM ABOVE Hook Hanger 3.950 10,048.5 3,298.0 82.49 HANGER PZ LEM INSIDE Hook Hanger 3.688 10,102.1 3,305.0 82.44 NIPPLE CAMCO DB-6 NIPPLE W ISO SLEEVE(6/21/2015) 2.125 ID 2.125" I 10,208.9 3,318.8 82.90 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 'M r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D LINER HH 4 1/2 3.476 10,048.5 10,312.5 3,330.7 11.60 L-80 BTC D LINER LEM;9,988.9.10,212.1 Liner Details li I Nominal ID Top(ftKB) i Top(TVD)(ftKB) Top Incl r) Item Des Com (in) D LINER HH;10,048.5-10312.5 ar 10,046.5 3,298.0 82.49 HANGER Baker Model PZ Hook Hanger inside 9-5/8" 7.720 10,070.0 3,300.8 82.45 HANGER Baker Model PZ Hook Hanger outside 9-5/8" 5.020 INTERMEDIATE',40.6-10.844.5 10,077.2 3,301.7 82.44 XO Reducing CROSSOVER 5.5"x4.5" 3.930 _ 10,214.5 3,319.5 82.97 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.900 10,282.5, 3,327.3 83.73 BENT JT 3.960 SLOTS:10,878.0-11,335.0 _ Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread B-SAND LINER 41/2 3.476 10,168.5 17,834.0 11.60 L-80 Hydril Liner Details - - Nominal ID - Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) - _ , 10,168.5 3,313.7 82.56 PACKER HRD ZXP Liner Top Packer 8.430 10,1873 3,316.1 82.64 NIPPLE RS PACKOFF SEAL NIPPLE 6220 SLOTS,11,5860-12,0990 - 10,190.1 3,316.5 82.67 HANGER FLEXLOCK LINER HANGER 6.270 10,198.9 3,317.6 82.78 XO BUSHING CROSSOVER BUSHING 4.900 - _ 10,200.3 3,317.8 82.80 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 10,219.9 3,320.2 83.04 XO BUSHING CROSSOVER BUSHING 3.910 SLOTS;12.352.0.1z.85z.o - Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection - - TUBING 41/2 3.958 36.0 10,013.8 3,293.5 12.60 L-80 IBT-m - - Completion Details - Nominal ID _ _ Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Com (in) 36.0 36.0 0.00 HANGER VETCO GRAY TUBING HANGER 11"x 4-1/2" 3.900 SLOTS;13,110.0-13.578.0 _ _ 513.6 512.1 10.51 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 - _ 9,948.2 3,285.3 83.51 SLEEVE-C Baker Model"CMD"sliding Sleeve w/Camco 3.812"DB 3.813 profile(CLOSED 3/19/2007) - - 9,995.8 3,291.1 82.59 LOCATOR GBH-22,OD 523",ID 3.95", 3.950 9,996.4 3,291.2 82.59 SEAL ASSY "Baker GBH-22",4.74"OD SBE assembly.w/5.5"IBT 3.880 SLOTS;13.866.0.14.330.0 - _ box up ID 3.88".Size 192-47 _ _ Perforations&Slots Shot - - Dens - - Top(ND) Min(ND) (shots/f Top(ftKB) Btm(ftKB) IRKS) (ftKB) Zone Date t) Type Com _ _ 10,878.0 11,336.0 3,380.2 3,386.5 WS B,1J-180 2/7/2007 32.0 SLOTS ALLPERFS IN SLOTS,14,582.ais,119.0 WELLBORE:Altemating solid/slotted pipe- 0.125"x2.5"@ 4 - - circumferential adjacent rows,3"centers staggered 18 deg,3'non - - -slotted ends 11,586.0 12,099.0 3,388.8 3,385.2 WS B,1J-180 2/7/2007 32.0 SLOTS SLOTS,15,370.0-15.833.0 - 12,352.0 12,852.0 3,382.1 3,387.3 WS B,1J-180 2/7/2007 32.0 SLOTS 13,110.0 13,578,0 3,376.9 3,369.3 WS B,1J-180 2/7/2007 32.0 SLOTS 13,866.0 14,330.0 3,367.7 3,367.7 WS B,1J-180 2/7/2007 32.0 SLOTS _ _ 14,582.0- 15,119.0 3,360.9 3,349.8 WS B,1J-180 2/7/2007 32.0 SLOTS 15,370.0 15,833.0 3,357.5 3,352.5 WS B,1J-180 2/7/2007 32.0 SLOTS SLOTS,16,132.0.16,604.0 - 16,132.0 16,604.0 3,351.0 3,344.9 WS B,1J-180 2/7/2007 32.0 SLOTS - - 16,904.0 17,789.0 3,350.2 3,351.4 WS B,1J-180 2/7/2007 32.0 SLOTS Mandrel Inserts - - St ati _ _ Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com - - 2280.6 1,878.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/25/2007 SLOTS,16,904.0-17,7890 - Notes:General&Safety End Date Annotation - - 3/2/2007 NOTE:MULTI-LATERAL WELL 1J-180(B-SAND),1J-180L1(D-SAND) B-SAND LINER;10,168.5- 17,B34.01 • • KRU 1J-180 (& 1J-180 L1)—Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-150 (& 206-151) Current Status: KRU 1J-180(& 1J-180 L1),a West Sak B-&D-sand dual-lateral injector,is currently shut-in after failing multiple MIT-IAs as a result of a tubing leaks identified at 5,062',5,148' &5,300'MD. Please see below for the well integrity history of 1J-180,including the aforementioned failure which required the well to be shut-in: o 2007–The KRU 1J-180& 1J-180 L1 dual lateral injector was drilled and completed. o 2009–Failed a MIT-IA(24-May-2009). • Shifted the Baker CMD sliding sleeve at 9,948'MD open&close. Re-tested&passed a MIT-IA. o 2015–Operations noticed that the IA would not hold pressure. • With the IA tracking above the tubing pressure for a few months,operations attempted to reestablish a positive IA differential pressure over the tubing but were unable to after establish a positive differential when the IA failed to build pressure. Failed tubing integrity was suspected with the IA test pressure leaking through the tubing and into the reservoir. • The tubing&IC Pack-Offs were pressure-tested successfully. Failed tubing integrity confirmed. • The Baker CMD sliding sleeve was opened&closed twice,each time with a follow-up failed MIT-IA. Tubing leak suspected. • Leak Detect Log(22-Jun-2015)confirmed loss of tubing integrity through multiple tubing leaks. ■ Leaks identified at 5,062',5,148,&5,300'MD. • CMIT-TxIA passed—confirmed production casing integrity. Scope of Work: Pull the 4-1/2"upper completion&run new 4-1/2"upper completion. General Well Info: Well Type: Injector MPSP: 1,454 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. Reservoir Pressure/TVD: West Sak B/D–1,788 psi/3,323' TVD(10.6 ppg EMW) Wellhead Type/Pressure Rating: Vetco Gray Horizontal(5M Tubing&Casing Heads) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 20-Apr-2015 Last Passed 15-May-2014 CMIT-TxIA Passed 30-Sep-2015 Production Casing Integrity Confirmed MIT-OA–Open Shoe Earliest Estimated Start Date: 19-Oct-2015 Production Engineer: Michael Sullivan Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. RU Coiled Tubing. a. Set an Isolation Sleeve across the D-Sand LEM to isolate the D-Sand lateral. b. Set a 3.562"DB Plug within the DB Nipple at 10,102'MD to isolate from the B-Sand lateral. c. Perform a CMIT-TxIA to confirm that the Isolation Sleeve&DB plug are set&holding pressure. d. Open the Baker CMD sliding sleeve at 9,948'MD. e. RD Coiled Tubing. 2. Set the BPV. • • • KRU 1J-180 (& 1J-180 L1)—Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-150 (& 206-151) Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull the BPV. Circulate seawater around through the open Baker CMD sliding sleeve at 9,948' MD. Obtain SITP & SICP; if pressure is still observed at surface, calculate the required KWF and circulate around as necessary. Verify the well is static. 3. Set the BPV,ND the tree,set the blanking plug,NU BOPE,&test BOPE to 250/3000 psi low/high. 4. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat the tubing hanger. 5. P/U on the tubing&pull the tubing hanger to the rig floor. Verify that the well is static&TOH laying down the existing 4-1/2"upper completion(entire upper completion to the base of the locating seal assembly). 6. M/U&TIH with the new 4-1/2"upper completion as per design to just above the casing sealbore receptacle. 7. Engage the seal assembly until fully-located into the casing sealbore receptacle. P/U from fully-located,space- out 7',&mark the pipe at surface. 8. Space-out the completion with tubing pups and M/U the tubing hanger, 9. Swap the well over to corrosion-inhibited seawater across the upper completion. 10. Land the tubing hanger&RILDS. 11. Pressure-test the tubing&IA. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV(IA to tubing shear). 12. Back-out the landing joint&install the BPV. 13. ND BOPE,NU the tree,install the tree test plug,&pressure test the tree to 250/5,000 psi. Pull tree test plug. 14. Freeze protect the well through the SOV in GLM#1. 15. Set the BPV. 16. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull the BPV. 2. RU Coiled Tubing: a. Remove the SOV from GLM#1 &replace with a DV. b. Pull the Isolation Sleeve from across the D-Sand LEM c. Pull the 3.562"DB Plug set within the DB Nipple at 10,102'MD. d. RD Coiled Tubing. 3. Reset well house(s)&re-attach flow line(s). 4. Turn the well over to operations. • • Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Thursday, October 08, 2015 11:30 AM To: Loepp,Victoria T(DOA) Subject: KRU 1J-180&1J-180 Ll - PTD 206-150&206-151 - 10-403 Sundry Request Amendment Victoria, While putting together the Sundry Request for KRU 1J-184–very similar to the submitted Sundry Request for KRU 11- 180—that I wrote down the wrong BOPE high test pressure. For the KRU 11-180&KRU U-180 L1 Sundry Requests,the planned BOPE test pressure will be 250/3500 psi in order to bring this dual lateral injector back online for MWAG service. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 1 • • 0 t, a��oo Z.6 h d O -- ,. 1 of ' �d8 m M7+ 2 xt22o o t" ` >'_ 2= = = o=��° M oar 2 E o t. a ` ❑2 '6.--.- , i-- j . S t m d21. 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L o 7,.., a : L'''2 u � � QN � ..... v� IIIM '�.� c m d a ❑ OCI y Q 0.° 9 0 c 2 V T l01 , t ❑J C IX C2 01- a qt o f oa ,. \ J t m w F ry Q � dcFZ aXu 3 T. ul a ul a w°' <4( / NaN s a ja, oaJ "\ 4= ° X ;le c Edo Xax Ln Nma yH1- ”- gypi'm -y _ ycL -m < mU / X y 734 m m^ pl_ `C Y ❑Y� 0 J V d d ° „,,,‘,706. r NO ,.Si 9. d cF 40 .17' \ J �. U i,,'A' um�i'"e3 ❑ ., \ X n a �N U v a t I- I p�3 ❑ J m N N Y m `II ❑ N w H 2 p R .13 ?+q J \ N m LTi OH 'w -(12 U N. Nl m p flN p fl in .r o. 4 'o TXxA Eo st 72°2 m '”" a'o ;.°,'.3'? u1 3-a Y N 1^ . aLeHia`tt 4 o 1n H N N oH :3 • m CQN ^ U�H% u on 1 w a1 ',1,-! a -w .3..3, ❑y❑ 2 'JCN 3CV _ 1 1 111 nK Tra NI.:-.'.0 20- F-T-GiyI m,pal ¢1 1. Jm w # vO JnKV ,c-g.28 jV`" a N= — __ 2.�fl2� WELL LOG TRANSMITTAL II• PRoAcrive DiAgnosriATA LOGGED c SERViCES, INC.INc. i16i2015 K BENDER To: AOGCC ''It : �+a.. V ED Makana Bender '7t z " 5.l' 333 West 7th Avenue JUL 07 "GU i, Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED 1) Leak Detection 22-Jun-15 1J-180 CD 50-029-23329-00 2) Signed : ✓Q � t!3.4'ti Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Achives'MasterTemplateFdes\Templates\Distnbution\TransmittalSheets\ConocoPhillips_Transmit docs Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, April 21, 2015 10:53 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of possible TxIA communication 1J-180 (PTD#206-150)4-18-15 Update: 4-21-15 Attachments: 1J-180 schematic.pdf; 1J-180 90 day TIO 4-18-15.JPG Chris, Diagnostic work was begun with passing packoff testing on 4/19 and the MITIA performed yesterday on 4/20. The MIT failed due to the inability to pressure the IA greater than 1040psi. The well was SI and freeze protected yesterday with intervention work with Slickline/Eline/Coil currently being planned. The well will be added to the monthly report. Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager (907)659-7000 pgr 909 SCANNED APR? 2 3 2015 From: NSK Problem Well Supv Sent: Saturday, April 18, 2015 8:56 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of possible TxIA communication 1J-180 (PTD# 206-150) 4-18-15 Chris, West Sak injector 1J-180(PTD#206-150) is experiencing possible TxIA communication. The IA pressure has been maintaining a^200psi pressure above the tubing for many months now. Yesterday, operations attempted to establish a greater T& IA differential by pressuring up the IA even further above the tubing pressure, but was unsuccessful. Tomorrow DHD is scheduled to perform initial diagnostics to include an MITIA and POTs. The well will be SI and freeze protected as soon as possible with follow-up Slickline/Eline intervention work as necessary if the MITIA fails. At that point the well would be placed on the monthly report. However, if the tests are able to pass, the well will be left online water-only injection and monitored for 30 days with sufficient differential pressures established. An email will be sent at the conclusion of the diagnostic monitor period. Attached are the schematic and 90 day TIO plot. 1 411 Well Name 1J-180 Notes: Start Date 1/1812015 Days 90 End Date 411812015 SCC - - — 1E _WHP Annular Communication Surveillance UP 5CC — _OAP OAP 4YHT — 7CG — 12 cCC — 11 ECO - — 1C 400 — Sd IP � ?CG — SC 2CC — 7C 1GG .'-�'� — 0 EC Jan-1E Jan-1E Jan-1E Feb-1E Feb-1E Feb-1E Mar-1E Mar-15 Mar-15 Apr-15 Apr-15 Apr-1E emliosolvoomvortimiommiesioommommyii• 2 Jan-15 Jan-1E Jan-1E Feb-1E Feb-1E Feb-1E Mar-1E Mar-15 Mar-15 Apr-15 Apr-15 Apr-15 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday,April 18, 2015 8:56 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of possible TxIA communication 1J-180 (PTD# 206-150)4-18-15 Attachments: 1J-180 schematic.pdf; 1J-180 90 day TIO 4-18-15.JPG Chris, West Sak injector 1J-180(PTD#206-150) is experiencing possible TxIA communication. The IA pressure has been maintaining a"200psi pressure above the tubing for many months now. Yesterday, operations attempted to establish a greater T& IA differential by pressuring up the IA even further above the tubing pressure, but was unsuccessful. Tomorrow DHD is scheduled to perform initial diagnostics to include an MITIA and POTs. The well will be SI and freeze protected as soon as possible with follow-up Slickline/Eline intervention work as necessary if the MITIA fails. At that point the well would be placed on the monthly report. However, if the tests are able to pass, the well will be left online water-only injection and monitored for 30 days with sufficient differential pressures established. An email will be sent at the conclusion of the diagnostic monitor period. Attached are the schematic and 90 day TIO plot. SCANNED APR 2 3 2015 • Well Name 1J-180 Notes: Start Date 1/1812015 Days 90 End Date 4118(2015 900 __ _ 1` WHP Annular Communication Surveillance to P — 14 800 — _OAP - —' WNHT — 13 700 ECO 12 11 E00 - Y 10 400 - 9d ?00 — 80 200 — 70 100 - 60 0 E0 Jan-1,E Jan-15 Jan-15 Feb-15 Feb-1E F et-1E E Mar-15 Mar-15 Mar-15 Apr-1E Apr-1E Apr-1E e T , Jan-1E Jan-1E Jan-1E Feb-1F Feb-1E Feb-1E Mar-1E Mar-15 Mar-15 Apr-15 Apr-15 Apr-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 2 I.- KUP 1J-180 ConocoPhillips 411111 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) LnnoT.oPr„n�ps 500292332900 WEST SAK INJ 93.60 14,694.65 17,834.0 Comment H28(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 43.51 2/27/2007 Well Contg:MultipleIs-1J-180,424/2011 4:52:52 PM - -- - ane-180:24/2011 Annotation Depth(ftKB) End Dab Annotation Last Mod By End Date ---- - -Last Tag: . Rev Reason:FORMAT UPDATE Imosbor 4/24/2011 HANGER,38 i Casing Strings Casing D ption String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 WELDED CONOucloR, =In Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 40-120 SURFACE 133/8 12.415 37.7 4,000.6 2,227.0 68.00 L-80 Buttress NIPPLE,514 -- Casing Description String 0... String ID...Top MB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd GAS LIFT, lir INTERMEDIATE 95/8 8.835 40.6 10,844.5 3,375.8 40.00 L-80 BTC-M 2,281 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd D LINER LEM 5.21 3.980 9,988.9 10,212.1 3,320.3 12.60 L-80 IBT-mod SURFACE. 384,001 Liner Details SLEEVE-C, s Top Depth 9,948 a� (ND) Top Incl Nomi... LOCATOR, , � Top(ftKB) (ftKB) (°) Item Deseriptbn Comment ID(In) 9,998 _ _ 9,988.9 3,290.2 82.66 PACKER ZXP LINER TOP PACKER 7.500 SEAL ASSY, 9,996 10,011.5 3,292.9 82.29 SBR 190-47 CASING SEAL BORE RECEPTACLE_ 4.750 10,031.1 3,295.6W 82.33 XO BUSHING "CROSSOVER BUSHING 3.950 10,036.3 3,296.3 82.33 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID 3.960 10,048.5 3,297.9 82.35 HANGER PZ LEM above Hook Hanger 7.65"x 3.68"ID 3.688 10,102.1 3,305.0 82.44 NIPPLE CAMCO OB-6 NIPPLE 3.562 10,208.9 3,320.0 84.33 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description String 0... String ID...Top(flf(B) Set Depth(f...Set Depth(TVD(...String Wt...String...String Top Thrd _ D LINER HH 4 1/2 4.000 10,048.5 10,312.5 3,331.1 11.60 L-80 BTC 1nii1 1 M , Liner Details D LINER LEM. Top Depth 9989-10.212 ' IMi (TVD) Top Incl Nomi... Top(ftKB) (ftKB) (") Item Description Comment ID(in) 10,048.5 3,297.9 82.35 HANGER Baker Model PZ Hook Hanger inside 9-5/8" 7.720 D LINER HH, 10,070.0 3,300.8 82.39 HANGER Baker Model PZ Hook Hanger outside 9-5/8" 5.020 10.040.+0,3+3 10,077.2 3,301.7 82.40 XO Reducing CROSSOVER 5.5"x4.5" 3.930 NTERMEDIATE, • 10,214.5 3,320.5 84.28 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.900 41-10.845 10,282.5 3,328.3 83.96 BENT JT 3.960 Casing Description String 0... String ID...Top(01KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd B-SAND LINER 4 1/2 3.476 10,168.5 17,834.0 11.60 L-80 Hydril Liner Details Top Depth SLOTS. (TVD) Top Incl Nomi... 11.317-11.507 -� Top(ftKB) (ftKB) 1"1 Item Description Comment ID(in) 1 I 10,168.5 3,313.7 82.56 PACKER HRD ZXP Liner Top Packer 8.430 1 1 10,187.3 3,318.2 84.50 NIPPLE 'RS packoff Seal Nipple 6.220 10,190.1 3,318.4 84.48 HANGER 'Flexlock Liner Hanger 6.270 j 10,198.9 3,319.2 84.41 XO BUSHING Crossover Bushing 4.900 SLOTS, 1 12,100-12.353 10,200.3 3,319.3 84.40 SBE 190-47 Casing Seal Bore Extension '4.750 10,219.9 3,321.0 84.24 XO BUSHING Crossover Bushing 3.910 I = Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String String Top Thrd TUBING 41/2 3.958 36.0 10,013.8 3,293.2 12.60 L-80 IBT-m SLOTS, 12,583.13.110 _� Completion Details Top Depth (ND) Top 1801 Nomi... Top(fIKB) (ftKB) el Item Description Comment ID(In) 36.0 36.0 -0.03 HANGER VETCOGRAY TUBING HANGER 11"x4-12" 3.900 i 513.6 512.1 10.51 NIPPLE 412"Camco"DB-6"Nipple w/3.875"No-Go Profile. 3.875 [ 1 SLOTS. _ i 9,948.2 3,285.7 83.51 SLEEVE-C Baker Model"CMD"sliding Sleeve w/Camco 3.812"DB profile 3.813 13,578-13.888 (CLOSED 3/19/2007) } 9,995.8 3,290.8 82.27 LOCATOR GBH-22,OD 5.23",ID 3.95", 3.950 tf 9,996.5 3,290.8 82.27 SEAL ASSY "Baker GBH-22",4.74"OD SBE assembly.w/5.5"IBT box up ID 3.88". 3.880 Size 192-47 q[ i SLOTS, ! Perforations&Slots 14.310.14.582 { Shot Top(TVD) Btm(TVD) Dens Top(NCB) Bbn(MB) I4KB) (ftKB) Zone Dab (sh.-- Type Comment 11,337.0 11,587.0 3,386.2 3,389.0 WS B,1J-180 2/7/2007 32.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends SLOTS. _ y 15 119-15 370 - 12,100.0" 12,353.0' 3,385.1 3,382.2 WS B,1J-180 2/72007 32.0 SLOTS I12,583.0 13,110.0 3,382.3 3,376.8 WS B,1J-180 202007 32.0 SLOTS' d Y 13,578.0' 13,866.0 3,369.0 3,367.7 WS B,1,1-180 2/72007 32.0 SLOTS 14,330.0 14,582.0 3,367.7 3,360.9 WS B,1J-180 2/72007 32.0 SLOTS 15,119.0 15,370.0 3,350.1 3,353.6 WS B,1J-180 2/72007 32.0 SLOTS SLOTS, 15.83416,132 E - 15,834.0 16,132.0 3,352.4 3,351.0 WS B,1J-180 2/7/2007 32.0 SLOTS 16,604.0 16,905.0' 3,345.3 3,350.2 WS B,1..1-180 2/72007 32.0 SLOTS" Notes:General&Safety End Date Annotation 322007 NOTE:MULTI-LATERAL WELL 1J-180(B-SAND),1J-180L1(D-SAND) SLOTS, e 16,604-16.905 Mandrel Details Top Depth Top Port 1¢1¢ (ND) I Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) I (°) Make Model (In) Sery Type Type (In) (psi) Run Date Com... BSAND 1 2,280.6 1,878.3 62.89 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2252007 , i 1 LINER, 10,88-17,8341 T�(117834 \ 17,834 • 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. ~~ ~ - ~ ~ ~,J' Well History File Identifier Organizing (aone> ~o-sided III II'III II III II III ^ Rescan Needed III II'III II II III III RE AN DI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ /s/ I Project Proofing II I II II II I (III I I III BY: Maria Date: ~ /s/ L~ Scanning Preparation ~ x 30 = + ~ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: ~ C' /s! Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~ ~ ~. ~ /sl Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. R.~~a~~ed III!IIIIIIIIVIIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III Ilil III 10/6/2005 Well History File Cover Page.doc • • Page 1 of ' Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Saturday, September 17, 2011 6:21 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RE: RLPP /SSV defeated on 1J -156 West Sak injectors and returned to service for 1J -180 and 1J- 184: 17- Sept -2011 Tom and Jim, The low pressure pilot (LPP) on the following well was defeated on 09/17/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV has been tagged and the status is recorded in the "Facility Defeated Safety Device Log" since the wells is below 500 psi. As of 1800 hrs on 09/17/2011, wellhead injection pressure and injection rates are as follows for the well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1 J -156 (206- 067,206- 068,206 -069) 437 899 The AOGCC will be notified when the injection pressure on this well has increased so as to remain above 500 psi and the LPP /SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi and the LPP /SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1 J -180 (206 - 150 206 -151) 555 471 1 J -184 (206- 044,206 -045) 539 640 Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com ' k 1 ' 659 -7493 pager 659 -7000 765 CPF1 Prod Engr Sent: r.. e.tember 16, 2011 6:44 PM To: 'tom.maunIe : - ka.gov'; 'jim.regg @alaska.gov' Cc: CPF1 DS Lead Techs; • - •.s Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; = Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J - • injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09 • 111 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging face odifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Devic- •" since the 9/19/2011 • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 16, 2011 6:44 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1 J -105 (207- 027,207- 028,207 -029) 345 639 1J-118 (206- 176,206- 177,206 -178) 327 1020 1J-127 (206- 047,206 -048, 206 -049) 337 934 1 J -154 (205- 036,205 -037) 369 623 1J-160 (207- 015,207- 016,207 -017) 352 568 1J-164 (205- 144.205 -145, 205 -146) 479 1082 -180 06 -15 206 -151) 537 478 1J-184 (206 -0 4,206 -045) 502 646 The AOGCC will be notified when the injection pressures have increased so as to remain above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 pager 659 -7000 765 9/19/2011 ~` ~„, . _. . ,„ ,~ ~~`- °~ ~~~,~ ti ~~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc MEMORANDUM • TO: Jim Regg ~ ~ ~ ~ f 1 p P.I. Supervisor ` FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-180 KUPARUK RIV U WSAK 1J-180 Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv J Comm Well Name: KUPARUK RIV U WSAK 1J-180 Insp Num: mitRCN1005161s4s39 Rel Insp Num: API Well Number: 50-029-23329-00-00 Permit Number: 206-150-0 Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well a-]so Type Inj. ~' TVD 3290 IA 1050 1690 1680 1680 p.T.D~ 2061500 ' TypeTCSt SPT Test psi 1690 ~ QA 145 226 225 224 Interval aYRTST p/F P •' Tubing ssa saa s8s ss~ Notes: I~l'~ ~ , rc~'d -leak ' ~S f ~ €~~ • 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@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J 05/14/10 Colee /Phillips - AES Bob Noble ~~ r f ~ ~~O 1~ ~~ ,•~ ~~ 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 V a~ MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 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 MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s '`~/ ~~ V INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 12, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: C~ F~~~EIVED FEB 1 6 2010 A{aske 0~ i~ bas Cans. Commission Ancharag~e °` 2d'l t ~~ ~-© _ ~ $n ~~ 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 corrosion inhibitor/sealant was pumped February 9~' &10~', 2010. 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. ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date Pad 1 H. 1 J& 1 R Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ff al 1 H-15 50029223280000 1930030 23" n/a 23" n/a 4.2 2/9/2010 1 H-16 50029223150000 1921310 25" n/a 25" n/a 4.8 2/9/2010 1H-19 50029223120000 1921280 22" n/a 22" n!a 4 2/10/2010 1 H-20 50029223130000 1921290 25" n/a 25" n/a 4.6 2/10/2010 1 H-22 50029223640000 1930600 22" n/a 22" n/a 4.2 2/9/2010 1H-105 50029207270100 2042280 3" n/a 3" n/a 3.4 2/9/2010 1J-180 50029233290000 2061500 18" n/a 18" n/a 3.8 2/9/2010 1J-182 50029233210000 2061320 17.5" n/a 17.5" n/a 3.6 2/9/2010 1R-21 50029222110000 1911130 24" n/a 24" n/a 4.6 2/9/2010 LPP/SSV no longer defeated on 1J-180 - 12-JULY-09 Page 1 of 1 ~ ~ IlAaunder, Thoma~ E (D4A~ From; CPF1 Prod Engr [n1269 c(~'~conocophiliips.comj Sent: Mar~d~~r, July 13, ~009 6:23 AM To: Maunder, Thomas E(O~A}; Regg, Jemes B(DOA) Ga: CP~1 l~S Lead T~chs; ~PF1 Pr~f ~upt; N~K Prablerrt Wel{ Supv; J~;nkins, Lubbie AEt~n; ~angl, Mei~ssa A; Hibler, Kaycee; NSK West Sak Prc~ct Engr; Pierson, Chris R Subjecx, LPA/S~~/ no long~r defeated on 1 J-181J - 12-JULY-09 Tom f Jim, The Ic~w pressur~ pilot (LPPj on 1J-1$0 (208-150 and 206-151) was r~turned to service on 7/12/20A9. Current w~lihead pressure is 532 psi, injection rate is 63U bwpd. Please let m~ know if you hav~ any questions. David I.loyd L~g~Nef/Kenneth Lloyd M~rkin CPF1 Produ~tion Engineers n 1269@cono~ophilliPs.eom 659-7493 pager 659-7QQQ 765 ~~~~~~~~' .?~,.iL _.. ~ ~~~~' 7/1 ~12009 RE: LPP/SSV defeated on 1J-180 - 06-JLTLY-09 Page 1 of 1 ~ • Maur~d~r, Thcarr~~s E (DOA} Frorn: CPF1 Procf Engr [n1269~ccjri~ophillips.com] Sent: MaRefay, July Q6, 2~09 4:Q1 PM To; Maunder, ThQm~s E(QC3A); RQgg, James B(~C7A) Gc: CPF~ C?S l.ead TeeE~s; CPF1 Pead Su~t; N~K Problem 1Nelt ~upv; Jenkins, Lubbie All~n; ~~nc~l, Mefissa A; Hibier, Kayc~e; NSK Wesf Sak Rrod ~ngr; Pi~rson, ~hris R Subjec#: RE: LPPi~SV defsated on 1J-180 - t~-JULY-O~ Tom f ,~im, The low pre~sur~ pilot (LPP) c~n 1J-180 2fl6-9~0 and 206-931 j was defe~t~d on 7/U6/2f34~ when th+~ ws11 ~~s returned to injQCtion service after t~$ing s ut ir~ or 29 days. Current wellhead press~ure is 4~4 psi; inj~~tipn rat~ is 1325 bwpd, We expect fic~ have the LPRs return~d tp service in approxim~t~ly ~8 hc~urs. 7Fie LE~P ~nd ~~V hsv~; been tac~ged and their statu~ ~s recorded in the "~acility pefeatec! ;afety [~evi~e Log." The A~GCC will be nr~tified wMen th~s injeetion pressure has increased to abav~ 54A p~i ~nd th~ LPP/~SV function is return~;d to normal, in accordance with "Adminis#rative Apprvval No. CQ 4068.0~1." Ptease lefi me knornr if yau have any questions. David Lloyd i..ag~rle#/I~enneth Llayd Martin CPF1 Production En~ineers n1263(~car~c~cophiltips.com F~59-7493 pager 659-70U~ 765 ~~:~:'`~~~~~ ,~+~"~ ~ v~ 20U~ 7/l3/2QQ9 CJ MEMORANDiJM ~ 'ro: Jim Regg ~l ~l~ 7(ZZ jp -~r' P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLII'S ALASKA INC 1J-180 KUPARLJK RIV U WSAK 1J-180 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RN U WSAK 1J-180 Insp Num: mitCS090605071334 Rel Insp Num: API Well Number: 50-029-23329-00-00 Permit Number: 206-I50-0 ~ Inspector Name: Chuck Scheve Inspection Date: 6/4/2009 acker Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~7~/ell 1J-180 Type Inj. W 'rvD 3290 IA 1420 2540 ~ 2465 2455 P.T.D 2061500 TypeTest SPT Test psi 1500 QA 300 350 350 350 Interval 4YRTST P~ P j Tubing 610 610 610 610 NOtes' Pretest pressures observed and found stable. .. ~~ ~~ _ . ;~ , ~t7~ _ Wednesday, June 10, 2009 Page I of 1 Page 1 of 1 Regg, James B (DOA) From: NSK DHD Tech [n1656@conocophillips.com] Sent: Sunday, May 24, 2009 2:42 PM ~~C ~'~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv Attachments: 1J-180.pdf; 1J-180 90 day TIO plot.png (~`~ Zf?(p -~ i Jim t/ Kuparuk Water injector 1J-180 (PTD 206-150) is suspected of having TxIA due to the fluid volume pumped during the state witnessed MITIA today. The well will be shut in and freeze protected. The well will be added to the monthly report and DHD will perform diagnostics. Attached is the wellbore schematic and 90 day TIO plot. f Please contact Problem Wells Supervisor if you have any questions. Ron Bates Lead DHD Technician Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. «1J-180.pdf» «1J-180 90 day TIO plot.png» 5/26/2009 KRU 1J-180 PTD 206-150 5/24/2009 TIO Pressures ~~ , Cor~oc~P~illips ,AI~$k~, lnc. 1 J-180 API: 500292332900 Well T e: INJ TUBING SSSV T e: NIPPLE Ori Com letion: 2/27/2007 (0-10013, ~ ~ Annular Fluid: Last W/O: OD:4.5o0, I Reference Lo :40.65' RKB Ref Lo Date: ID:3.958) ~ I ~c~ T~n• Tr1~ '17AZd Rl(R SURFACE (0-4000, OD;13.375, Wt:68.00) TERMEDIATE (0-10844, OD:9.625, wt:ao.oo> PACKER (9989-9990, OD:8.430) LOCATOR (9996-9997, OD:5.160) HANGER X10036-10048, OD:8.510) HANGER ;10048-10071, OD:7.640) PACKER ;10169-10187, OD:8.430) NIP ;10187-10190, OD:8.430) HANGER ;10190-10199, OD:8.320) SBE ;10200-10220, OD:6.270) LINER B-SAND ;10168-17834, OD:4.500, Wt:11.60) Perf ;10678-17789) ~. I o.?. i i Casing String -ALL STRINGS KRU 4.500 0 _ _ _. .1_0.013 ~ 3293 . _ _.. 12.60 L 80 __ 'erforations Summary Interval TVD Zone Status i Ft SPF Date Type_ -- - - - - - - V ~~in - 17789 3380 - 3351 WS B ~__ _ ~ 6911 32 i 2/7!2007 ~_ SLOTS aas Lift Mandre__IsNalves__ _ ___ _ _ _ St MD TVD Mart Mfr Man Type V Mfr V Type V OD Latch Port 1 2281 1878 CAMCO KBMr DMY 1.0 BK-5 y 0.000 ether (plugs, equip., etc.) -COMPLETION DETAIL _ _ _ ~ 1 ~ Il1U3L SY`Jb I'UY U-JHNU YUF' , I'I ~ I 10036 3296 HANGER D-SAND PZ LEM ABOVE HOOK HAP r' ~ X10048 3298 HANrFR D-SAND PZ LEM INSIDE HOOK HAt` I ~ _, ' Other plugs, equip. et - B-SAND LINER DETAIL c~ i ~ De th TVD T e _ _ ~ I ~: ; .' 10169 3314 PACKER B-SAND LINER'HRD' LINER TOP PE 1_', ~ ~ ~I 10187 3316 u^NIPr^ B-SAND LINER'RS' PACKOFF SEAL General Notes ii~ V 4~y ^I ~~'~ . I ~. ~r ' ±~~ , i _~ ~I :; , - i ~.~ ~~ 1J-180 IBTM ner 1 MEMORANDUM To: Jim Regg ~~~q ~(z~(~9 P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 J-180 KUPARUK R1V U WSAK 1J-180 Src: Inspector NON-CONFIDENTIAL Reviewed Be~y--:nn P.I. Suprv~lG.e- Comm Well Name: KUPARUK RN U WSAK 1J-180 API Well Number: 50-029-23329-00-00 Inspector Name: Bob Noble Insp Num: mitRCN090526121541 Permit Number: 206-150-0 Inspection Date: 5/24/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-18o Type Inj. w 'I'mo 3290 ~ IA sao P.T.D 2o61soo TypeTest SPT Test psi tsoo OA 161 Interval aYxTST p~ F Tubing boa NOtes• Pumped IS bbls and well failed to pressure up :~~~~ ,.E.~r ~- ~,4: ~,GC.~ Wednesday, May 27, 2009 Page 1 of 1 a~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061500 Well Name/No. KUPARUK RIV U WSAK 1J-180 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23329-00-00 MD 17834 TVD 3351 Completion Date 2/2/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey i DATA INFORMATION Types Electric or Other Logs Run: GR/RES, DENS/NEU, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name -_ _ ___. og • Cement Evaluation D Asc Directional Survey ~D D Asc Directional Survey og Production I I~ C Lis 15110o/(nduction/Resistivity ', pt 15110 LIS Verification ~',~Cog Injection Profile i C Lis 16301~ection Profile Well Cores/Samples Information: Name ADDITIONAL INFORMA ION Well Cored? Y~N Chips Received? '1~~ Analysis '1`/-P1- Received? Daily History Received? ~ N Formation Tops ~/ N (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments 5 Col 3430 10230 Case 3/22/2007 USIT, GR, CCL, Welltec ,I Tractor 6-Feb-2007 40 17834 Open 4/13/2007 40 2969 Open PB 1 5 Blu 1 9900 10140 Open 5/4/2007 PPL wlDeft, Ghost, WeIITec Tractor 20-Apr- 2007 3951 17834 Open 5/8/2007 LIS Veri, FET, GR, ROP 3951 17834 Open 5/8/2007 LIS Veri, FET, GR, ROP 2 Blu 9900 10063 Open 5/23/2008 Injection Pro w/MaxTrac 19-i May-2008 9900 10063 Open 5/23/2008 Injection Pro w/MaxTrac 19-~ May-2008 -- ---- Sample Interval Set Start Stop Sent Received Number Comments Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061500 Well Name/No. KUPARUK RIV U WSAK 1J-180 Operator CONOCOPHILLIPS ALASKA INC MD 17834 ND 3351 Completion Date 2/2/2007 Completion Status 1-OIL Current Status 1WINJ Compliance Reviewed By: Date: API No. 50-029-23329-00-00 UIC Y ~ ~ 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-180+L1+L1PB1 November 14, 2008 AK-MW-4794615 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-180+L1+L1PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 329-00,60, 71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23329-00 Digital Log Images 1 CD Rom 50-029-23329-00,60,71 L1 AND L1PB1 HAS NO TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99~ 18 907-273-3536 Date: WELL L®G TRANSMITTAL BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 n ~ V .l.C.. ~~ (0 -- /~ U (fi J I J Signed: VZC.-~b(v-l5 ( '~31~ 1~3r~- ~~ 11~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~„~-'`~ 05/22/08 NO. 4717 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeri 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD iJ-180 1E-168 1J-160 1A-01 11964605 11964601 11964603 11996636 INJECTION PROFILE - GLS ~ - INJECTION PROFILE _ s PRODUCTION PROFILE w/FSI !-' 05/19/08 05/15/08 05/17/08 05/14/08 1 1 1 1 1 1 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. t Ll l / VV • ~.LV IVKI.Vi1 Vll la./ i i~r~~ vn..~ au ar• ~ au a.. .• ~.. ... .. ~ _ '~O~ - ~- - Maunder, Thomas E (DOQ) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180 Thanks Hai, While we will file this information in the main wellbore fife, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPFi DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, iJ-102, 1J-127, iJ-164, iJ-180 Tom ;Jim, The LPP/SSV's on all of the ~JVest Sak DS1 E and DS1 J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defieated; permit to drill numbers are also listed. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as well so I included both. WELL ID Permit to Drill No. 1 E-112 204-G91 (MAINBORE}, 204-092 (L1), 204-093 (L2) 1J-102 206-110 (MAINBORE}, 206-111 (L1}, 206-112 (L2) 1J-105 207-027 (MAINBORE}, 207-028 (L1), 207-029 (L2) 1J-127 206-047 (MAlNBORE), 206-048 (L1), 206-049 (L2'~ 1J-160 207-015 (MAiNBORE}, 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAlNBORE}, 205-145 (L1), 205-146 (L2) ---~ 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early Jufy 2007, before the CPF1 ESD, because they were new injectors (notification for these we{Is was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907} 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 LYl"/JJ V 11G1CQLGU Uil 1~-11G~1VG~ 1J-1G/~ 1J-1V`F~ 1J-lOV ~ r[l~'G 1 VL 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, August 15, 2007 2:01 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hoilar, Eric Andrew; Rodgers, James T Subject: LPP/SSV defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180- aC3 ~" l 5 Tom i Jim, ~ ~~fCa~~~'"'l'Z The Low Pressure Pilots (LPP) for West Sak Water Injectors 1E-112, 1J-102, 1J-127, 1J-164, and 1J-180 were defeated because of low wellhead injection pressure. These wells were shut in for a few days starting August 9 (CPF1 ESD/Coalescer shut down), allowing bottom hole pressure to fall off. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." We expect the bottom hole pressures to build back up in a few days. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please !et me know if you have any questions or concerns. Regards, Hai Hunt Hai Hunt /Eric Hoilar! Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com R/16/2007 West Sak LPP Defeat Update• • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, July 09, 2007 4:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK West Sak Prod Engr Subject: West Sak LPP Defeat Update Tom /Jim This email is to notify the AOGCC that 1 J-105 and 1 J-160 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been defeated 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: 1J-105 Converted from pre-production to injection 07/06/2007, LPP defeated 7/6/2007. Injecting 2200 bwpd at 0 psi. 1J-160 Converted from pre-production to injection 07/01/2007, LPP defeated 7/6/2007. Injecting 1250 bwpd at 80 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. This email is also to notify the AOGCC that 1J-180 and 1J-136 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been placed back in service ~~ a0~- ~SC~. 1J-180 LPP defeated 06/09/2007, back in service 06/28/2007 1J-136 LPP defeated 06/08/2007, back in service 07/01/2007 Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 7/10/2007 MEMORANDUM TO~ Jim Regg P.I. Supervisor ~~'y~, ~(~l ~~i~~t 7 FROM: Bob Noble Petroleum Inspector State of Alaska L Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 27, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lJ-I80 KUPARUK RIV UNIT 1J-I80 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprvJ Comm Well Name: KUPARUK RIV UNIT iJ-180 API Well Number: 50-029-23329-40-00 Inspector Name: Bob Noble Insp Num: mitRCN070627092816 permit Number: 206-150-0 Inspection Date: 6/26/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well iJ-180 ;Type Inj. j W TVD 3?9 I soo I I99s 1955 ~ I95o T P.T.D~ 2061500 "I`ype'I'eSt SPT ~ TeSt pSl ,~ I99s ~ QA ~ 460 600 ~ ~ 600 ~ 600 -- Interval 1N1T~ P/F P --- -- ,/ Tubing soo soo ~ soo 'I soo Notes: (~~;~j',;;~ -~~°~- ~.~'~5~~~~e_ 1~2%~; Wednesday, June 27, 2007 Page 1 of 1 _- _ J i7:~/?-07 ~ ~J I'd 1 9 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '"``~ ;..`:;, ~''~ U8S ~,OnS. Commission REPORT OF SUNDRY WELL OPERATIONS ~rtci`cf~rage 1. Operations Performed: Abandon. ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other 0 Pre-Prod toinj. Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 206-150 / 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23329-00 "' 7. KB Elevation (ft): 9. Well Name and Number: RKB 121' ~ 1J-180 r 8. Property Designation: Zt~ j ~ , O7 10. Field/Pool(s): Z ? Kuparuk River Unit !a~L 3Y~1 ~Z `~ Kuparuk River Field! West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17834' feet true vertical 3351' ' feet Plugs (measured) Effective Depth measured 17832 feet Junk (measured) true vertical 3351' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3879' 13-3/8" 4000' 222T INTERMEDIATE 10723' 9-5/8" 10844' 3378' WINDOW L1 1' 9-5/8" 10051' 3298' LINER B-SAND 7666' 4-1/2" 17834' 3351' Perforation depth: Measured depth: 10878' - 17789' true vertical depth: 3380' - 3351' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10013' MD. Packers &SSSV (type & measured depth) B-SAND HRD ZXP LINER TOP PACKER w/HD PKR= 10169' SSSV=NIP SSSV= 514' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 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 774 1642 24 1189 303 Subsequent to operation 2942 1213 262 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. J hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ `- ,, ~( contact Bob Christensen /Bob Buchholz Printed. Name Robert W. Buchholz Title Production Engineering Technician Signature hone 659-7535 Date ~ /j//j5~ b / / v /A~ a ~'~ JUL ZOUI ~ `, 2~ ~~ Form 10-404 Revised 04/2004 ^ R ~ ~ ~ N ~.~i L ~~ Submit Original Only o/ 1J-180 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/09/07 Commenced Water Injection '~, Notification of LPP Defeat on West Sak Pre-Produced Injectors Subject: Notification of LPP Defeat on West Sak Pre-Produced Injectors From: NSK West Sak Prod Engr <n1638@conocophillips.com> Date: Mon, 11 Jun 2007 15:44:53 -0800 To: Jim Regg <jim_regg@admin.state.ak.us>, Tom Maunder <tom_maunder@adminstate.ak.us> CC: NSK West Sak Prod Engr <n1638@conocophillips.com> Tom /Jim, ao~~~sti ao~-~.~o -~--- This email is to notify the AOGCC that 1J-136 and 1J-180 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been defeated 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". 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: 1J-136: Converted from pre-production to injection 06/08/2007. Injecting 1900 bwpd at 92 psi. 1J-180: Converted from pre-production to injection 06/09/2007. Injecting 1050 bwpd at 17 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 6/12/2007 1:34 PM ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Apri124, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-180_L1_Ll PBl, AK-MW-4794615 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23329-00, 60, 71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ,~r~;~~fi Dat : Signed: ~.n ~~~~~ 5~~s~aK .tam ~~ c7d (o ~- l SC7 ~ 1 `J-11 p a~ - l 5l ~` r5 l U i Schlumberger -DCS ~ ~ ~ ~'~~ a~, I~~ ~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ^O~ + ~ ~O ATTN: Beth fi~:~~ ~ ~ ~~~~~ ~J Well Job # Log Description NO. 4239 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field; Date BL Kuparuk Color CD 04/20/07 2F-17 11632699 INJECTION PROFILE 04130/07 1 1 G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25107 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04124/07 1 1J-180 11632690 PRODUCTION PROFILE 04120107 1 2X-11 11632700 PRODUCTION PROFILE 05101/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. P O ~ ~ Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener~conocophillips.com] Sent: Tuesday, April 17, 2007 3:19 PM To: Reilly, Patrick J; Thomas Maunder Subject: RE: 1J-180 Volume pumped for the tail was 96.2 bbls with a yield of 2.47 cuft/sk -----Original Message----- From: Reilly, Patrick J Sent: Tuesday, April 17, 2007 3:11 PM To: ' Thomas Maunder' ; Greener, Mike R. ~ ©~ -~ ~,~ ~-{ Subject: RE: 1J-180 \ Tom, I think Mike was watching that well. Mike, Would you address this? Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J.Reilly@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, April 17, 2007 2:51 PM To: Reilly, Patrick J Subject: 1J-180 Fat, I am reviewing this well's completion report. Would you please help reconcile the surface tail cement volume. The sack count listed on the 401 does not give the volume listed on page 7 of the report. Thanks, Tom 1 SARAH PALIN, GOVERNOR 4a10~7~ OII/ Dist ~S 333 W. 7th AVENUE, SUITE 100 CO1~T5I'iRQA'1`IO1Q CO1rIl-II55IO1Q ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-180 Sundry Number: 307-124 Dear Mr. Christensen 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. DATED this !~ day of April, 2007 Encl. Sincerely, f ~ ~ ~ RECEIVED c STATE OF ALASKA / ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION `C~ APR '~ 9 ZOO7 APPLICATION FOR SUNDRY APPROVA~laska Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repairwell ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram 9 PP P 9 ^ Pull Tubing ^ Perforate. New Pool ^ Re-enter Oil to Winj Suspended Well - ^ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhillips Alaska, Inc. Development. ~ ~ Exploratory ^ ~ 206-150 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O, Box 100360, Anchorage, Alaska 9951.0 - 50-029-23329-00 7. If perforating; Closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership orlandownership changes: Spacing ExceptiorjRequired? YeS ^ NO 0 ~ 1J-180 9. PropertyDesigna#ion: 10. KB Elevation (ft): 11is.Field/Paoi(s): Kuparuk River-Unit ,~1vc. z;~3, Zs"66L~ 385x72 ~o• RKB 121' Kuparuk River.Field /WestSak Oil Pool 12. PRESENT WELL CONDITFON' SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective. Depth TVD {ft)::" Plugs (measured): Junk {measured):. '17834'" _ 3351'. ~ 17832 3351' Casing length Size MD " . TVp Burst Collapse. CONDUCTOR: 120' 20" ~ 120'.. ; 1:2Q _ SURFACE' 3879' 13-3/8" 4000' 2227 - INTERMEDIATE 10723' 9-5/8" 10844' -' 3378 WINDOW L1 1 9-5/8„ 10051' " ';398 LINER B-SAND, 7666' 4-1/2" 17834.' ,. 351 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size` Tubing Grade:: Tubing MD (ft): 10878' - 17789' . 3380' -3351' _ 4-112" ~.-80 . ' 1 OQ13' Packers and SSSV Type: Packers and SSSV MD (ft) , ~ '~ ~ ' B-SAND HRD ZXP LINER TOP PAC(tER w/HD PKR= 10169' SSSV=.NIP SSSV=514'. ~ ~ _ " 13. Attachments: Description Summary of Proposal 0 , _ ,14. Well Class after proposed work, Detailed Operations Program ^ BOP Sketch ^ - Exploratory"'[] ..". / beVelopmerit ^ .Service 15. Estimated Date for 16. Well Status afterpraposed work: Commencing`Operations: -Apri130, 2007 Oil. ^ Gas_ ^ ,~ Plugged ^-~ Abandoned ^" 17. Verbal ApprovaL• Date: WAG ' ^ , ~ GFNJ ^ .~ _ WINJ ^~ ~ , WDSPL ^ Commission Representative: - ~. 18. 1 hereby certify`that the foregoing•is true and correct to the best of my knowledge. .Contact: Bab Christensen /.Bob Buchholz Printed Nam ~ RObert D. ~ChrlSterlSerl Titfe: -'' Production En iheering Technician Signatur ~ Rhone 659,F535 Date 6 0 Commission Use Onf `~, " Sundry Nu ber. Conditions of approval: Notify Commission so that a representative may witness ~ j Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance., ^ ' _ Other: ~~C.,~~~~0~"'~oC-wc~.5e~.- ~ ~' ~~~C"~~C"~C.~--~~~,'~ ~~~~c, APR 17 2007 Subsequent Form Required: ~~~` APPROVED BY /~ /f~ Approved by: -A. l.:/d_ ~M IONER THE COMMISSION ~ Date: '~/ Form 10-403 Revised 06/2006 1 0 ~ ~~ Submi u~~t~~U f! /d~y~ • ' 1J-180 DESCRIPTION SUMMARY OF PROPOSAL .+ ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Multi-lateral Well 1J-180, This well was pre-produced in order to recover Oil based drilling fluids prior to putting the well on injection. Well 1 J-180 will provide pressure support for the West Sak B sands....... The 13-3/8" Surface casing _( 4001' and / 222T tvd) was cemented with 680 sx AS Lite followed by 335 sx DeepCrete. The 9-5/8" Intermediate casing (10844' and /3378' tvd) was: cemented with 835 sx DeepCrete. The injection.tubing/casing annwlus is isolated via 9-5/8" HRD ZXP Liner Top Packer with HD located @.10169' and / 3314' tvd_ The top of West Sak B sand was found at 1 Q79'4' and / 3374' tvd ~' .. M . ~s~c~~~~''~~Mt~s ~4la~~a~ ~~~x s'Is>>>> TUBING API: 50029233 (atoal3, SSSV T e: NIPPLE oD:4.5o0, Annular Fluid: ID:3.958) _., _- Reference Loa: 40.65' RK SURFACE (a4ooo, OD:13.375, Wt:68.00) TERMEDIATE (a1o64a, 1 OD:9.625, I Wt40.00) LOCATOR (9996-9997, OD:5.160) __ Well T KRU TS: 1 J-180 Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 4000 2227 68.00 L-80 BTC INTERMEDIATE 9.625 0 10844 3378 40.00 L-80 BTCM WINDOW L1 9.625 10050 10051 3298 0.00 LINER B-SAND 4.500 10168 17834 17834 11.60 L-80 BTC i...... .. ..... Size Top 4.500 0 ~~rf;~ra#ions Summary -- ~ Bottom 10013 i _ TVD 3293 Wt Grade 12.60 L-80 _ Thread IBTM Interval TVD Zone Status Ft _ SPF_I_ Date Type Comment 10878 - 17789 3380 - 3351 WS B 6911 32 ~ 2/7/2007 SLOTS Alternating slottedlsolid liner - aas''Lift Mad~c~ISJ~/~I~eS':::: '::: _ :: _ _ -- - - ` St MD TVD Man Man Type V Mfr V Type V OD Latch Port - TRO - Date Run Vlv Mfr Cmnt 1 2281 1878 CAMCO KBMG GLV 1 0 BK 5 0.188 1450 3122!2007 !f~ther...l.u, s, u)( , _ _. ;... ... a#c::=::±G~MPLET:EON DETRIL`` .. _ _ - De th TVD T e Descri tion ID 36 36 HANGER VETCO GRAYTUBING HANGER 4.500 514 512 NIP CAMCO'DB-6' NIPPLE w/3.875 NO GO PROFILE 3.875 9948 3286 SLEEVE-O BAKER CMD SLIDING SLEEVE wlCAMCO 3.813'DB' PROFILE -OPEN 3.813 9989 3290 PACKER D-SAND LEM ZXP LINER TOP PACKER 7.500 9996 3291 LOCATOR BAKER LOCATOR 3.950 10031 3296 XO D-SAND LEM CROSSOVER ~~ ~ ' 10032 3296 PUP HANGER { 10036 3296 HANGER D-SAND PZ LEM ABOVE HOOK HANGER (10036-10048, 10048 3__298 HANGER D-SAND PZ LEM INSIDE HOOK HANGER OD:8.510) ether, ~ " s, equ~ , etc:) B Si~tN[3 #.:I~V~Ft .a~~,~41t~...: '' HANGER De th TVD T e Descri tion (10048-10071, OD 7 640 10169 3314 PACKER B-SAND LINER'HRD' LINER TOP PACKER : . ) 10187 3316 NIP B-SAND LINER'RS' PACKOFFSEAL NIPPLE 10190 3316 HANGER B-SAND LINER FLEXLOCK LINER HANGER 10199 3317 XO Bushin B-SAND LINER CROSSOVER BUSHING 10200 3318 SBE B-SAND LINER 190-47 CASING SEAL BORE EXTENSION 10220 3320 XO Bushin B-SAND LINER CROSSOVER BUSHING 17832 3351 SHOE B-SAND LINER BTC SILVER BULLET FLOAT SHOE ,. PACKER (10169-10187, OD:8.430) NIP (10187-10190, OD:8.430) 3.950 3.688 LINER B-SAND (10168-17834, OD:4.500, Wt:11.60) • i~'C:3AANICAL INTEGRITY :ZEPORT ~ ~~~` ~~ UD ~ =_ . ~ : ~ OPER ~ FIELD ~.~ ~ \ ~LJ~~~ =.G r~~I~.,D. ~ r~LL NUMFER ~~'`~SO - ~~ ,~~ LL DA' ~_ TD : .?~.. TVD ; ?BTD : ?-ID TVD ~Casi^g:_ ~~(~ Shoe: ~~~~~ 33`1~TVD; li~~: tJ.p, ~ T~~ ._:,er . Shoe : '~ T~TD ; =C~P : t-~ ~'iD --.b'-- S Packer ~ TVD; Set at 1,.~1 .,.~~ o ~ ' - ~ ~ (,..~ ` ~OQ~ tt :ole S«e ~ ana Perfs to 1 ~:,'c?.t~?~.C<<, INTEGRTTY - PART #? rn::ulus Press Test: _~ 15 min .?,0 min Comments : i '.~"CHI~NIC~s, ~ NTEGRITY - PART # 2 ~ ~ ~ bh1~5 Cement Volumes :~ Amt. Liner ~~ CsQ ~s~si[ DV ~.~ Cmt -rol to cover oers ~yhh~s~ ~~Zo`~~ ~ c~ yCC- ~ ~-. ,,.,~~o,,~ -~ Sip ~ ~ c __:eoretical TOC ~ ~J~~~1~C,S ~~~~ ~~ P~~ \pC V ~ lT a f6-t~~ Cement Bond Log (Yes or No) jES In AOGCC File ~~5 C3L Evaluation, gone above perfs ~~ os~C~-~e C~~~~ F ?roduction Log: Type Evalu~ti on CONCLJSIONS: ?art :1: Part #2: ~~ ~~ ~~~ ~~ryv1°l ~-ccr~--~~ • ConocoPhillips March 30, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~ ~~~ ~ ~ gaol Alaska Oil ~ Gas Dons. Corranission Anchorage Subject: Well Completion Reports for 1J-180 and 1J-180L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-180 and 1J-180L1. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~ ~~~~ ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~'v f ~ STATE OF ALASKA ~ APR 0 4 Zd07 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOF~"I~`~'~~Commission 1a. Well Status: Oil Q ~ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: ' "' Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: February 27, 2007 ~ 12. Permit to Drill Number: 206-150 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 7, 2007 13. API Number: 50-029-23329-00 R 4a. Location of Well (Govern ntal Section): Surface: ~SL, 2443' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: February 3, 2007 ~ 14. Well Name and Number: 1J-180 ` At Top Productive ~ ~ ~•~,0~ Horizon: 2006' FNL, 166' FEL, Sec. 10, T10N, R10E, UM 8. KB Elevation (ff): 40.7' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1520' FSL, 85' FEL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17832' MD / 3350' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558770 y- 5945420 Zone- 4 10. Total Depth (MD + TVD): ~ 17834' MD ! 3351' TVD ~ 16. Property Designation: ADL 25662, 25663, 385172 TPI: x- 555845 y- 5936505 Zone- 4 Total Depth: x- 555989 ' y- 5929473 Zone- 4 11. Depth where SSSV set: nipple @ 514' 17. Land Use Permit: ALK 2177, 472, 2181 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1697' MD 21. Logs Run: GR/Res, Dens/Neu, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 78.6# H-40 Surf. 121' Surf. 121' 42" 355 sx AS 1 ~ ' 13.375" 68# L-80 Surf. 4001' Surf. 2226' 16" 68o sx ASLite, sx DeepCRETE 9-5/8" 40# L-80 Surf. 10843' Surf. 3377' 12.25" 835 sx DeepCRETE 4.5" 11.6# L-80 10168' 17834' 3314' 3350' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 10014' 10169' slotted liner from: 17834'-17789', 16904'-16604', 16132'-15833', 15369'-15118' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14581'-14329', 13865'-13578', 13110'-12852', 12352'-12099' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11586'-11336', 10873'-10220' MD n/a 26. PRODUCTION TEST Date First Production March 25, 2007 - Method of Operation (Flowing, gas lift, etc.) pre-produced injector -flowback to facility Date of Test 3/25/2007 Hours Tested not available Production for Test Period --> OIL-BBL 2300 GAS-MCF 2600 WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 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". a ~rjgxni T ; ~ i ~~~{jM F Q # NONE ~ ~+-~"Z-~---~ t 8 Form 10-407 Revised 12/2003 .;RIGINAL CONTINU ~1~~ ~ ~ ~•°~ ,~ y~sr~ za. zs. 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-180 West Sak B 10794' 3374' Base West Sak B ~ 17834' 3351' 1 J-180P61 N/A TD 2969' 2045' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nar~e_,-„Rand Thomas_ Title: Greater Kugaruk Area Drillino Team Leader ~ ~ ~3 Q ~O Signature ~'~-mot, 1 L> ~' C, -~ SU Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 C~ Cono~caPhilips Time Log Summary YL'e!luiera ttieb ReAOrting Well Name: 1 J-180 Job Type: DRILLING ORIGINAL . __ - Time Logs Date __ From To Dur S. D epth E. De th Phase Code Subcode T COM 01/04/2007 00:00 06:00 6.00 _ __ 0 0 MIRU MOVE DMOB P Continue Demob rig for move. Rig down and blow down all Hydraulic, steam, and water lines. Move rockwasher away from pit module and spot away from rig. Move change room house to shop & connect electrical s stem. 06:00 12:00 6.00 0 0 MIRU MOVE DMOB P Skid rig floor, Disconnect all lines between modules. Run Hydraulic system allowing fluid to warm up. Check 'ackin s stem. 12:00 18:00 6.00 0 0 MIRU MOVE MOB P Move pit module away from sub module. Observed hydraulic seal leak in jacking piston. NO SPILLS. Move sub module from 1J-136 to 1J-180. No S ills or incidents. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Continue move sub module onto matting boards on 1J-180. Spot sub module over well. Begin move pit module to 1J-180. Observed leak stopped on jacking piston. Circulate steam in sub module, warming up the rig. position portable air heaters in cellar to warm u diverter a ui ment. 01/05/2007 00:00 02:00 2.00 0 0 MIRU MOVE PSIT P Continue move pit module, position & s of module. 02:00 03:00 1.00 0 0 MIRU MOVE MOB P Skid rig floor over well center. 03:00 06:00 3.00 0 0 MIRU MOVE RURD P Install handrails. Connect all lines between modules. Set Beaver slide in place.Lay pit liner. Move & set rock washer in place. Position & set cuttings tanks. Set Beaver slide in place. Set stairs in place around rig and grip strut grates. Instal- stairs and continue rig up for acceptance. Crew Chan e 06:00 12:00 6.00 0 0 MIRU MOVE RURD P Contiue spot & rig up rockwasher module. Continue connecting all lines in between modules. Rig up Diverter equipment, flowlines, hole fill lines. Berm around pit & sub modules. Demob old hydraulic unit on rig floor. Dress sahkers. Prep pits for taking on s ud mud. Dress rockwasher shakers. i~<~~t~ 1 tat d5 ~_._.. a l I Time Logs Date From To Dur _ S. De tp h E. Depth Phase _ Code__ S~bcode T _ - CO'M --_ - - 01/05/2007 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Continue demobilize old hydraulic unit on rig floor. Finish rig up all lines & electrical between modules. Fininsh dressing all shakers. Fininsh rig up diverter system. Complete berming of entire rig modules. On hi-Line power @ 1615 HRS. perform rig acceptance walkthrough. Rig accepted @ 1800 HRS. Crew Chan e. 18:00 00:00 6.00 0 0 MIRU RIGMN RGRP P Continue prepare rig for spud. Take on 580 BBLS of spud mud to pits. Clear rig floor. Hang blocks and top drive. Pull guards on draw works. Remove old brake bands. Slip & cut 136' of drilling line. Perform Derrick ins ection. 01/06/2007 00:00 06:00 6.00 0 0 MIRU RIGMN RGRP P Continue replace brake bands & adjust same. Replace guards on draw works. Inspect saver sub on top drive. Load & strap 225 joints of 5" in pipe shed. Prepare for picking up 5" DP from shed. Crew Chan e 06:00 12:00 6.00 0 0 MIRU DRILL RURD P Pick up & install mousehole in rotary table. Pick up 5" Drill pipe from pipe shed, racking back stands in derrick. Drift DP to 2 3/8" Drift. 12:00 17:00 5.00 0 0 MIRU DRILL RURD P Continue pick up 5" Drill pipe from pipe shed, racking back stands in derrick. Drift DP to 2 3/8" Drift. Total of 75 stands, and 3 stands of 5" HWDP with 'ars. 17:00 18:00 1.00 0 0 MIRU DRILL RURD P Pull mouse hole from rotary table. While make up last 2 stands of 5" HWDP, tag bottom in the conductor @ 103' DPM. Rack back stands, and install mousehole in proper position. Crew Chan e 18:00 20:15 2.25 0 0 MIRU WELCT BOPE P Put Accumulator on line, pressure lines & Diverter system. Perform Function test. Observe pressure form 3100 PSI to 1800 for closed position of annular. Observe 200 PSI increase in .pressure when opened in 34 seconds, and then 2 minutes, 26 seconds for full pressure @ 3100 PSI. Average nitrogen bottle pressure = 2250 PSI - 6 bottles. Witness of test waived by AOGCC rep -Lou Grimaldi. Test witnessed b Co. Man & TP. 20:15 21:00 0.75 0 0 MIRU DRILL CIRC P Flood conductor and pump mud through all lines. Check system for any leaks. Pressure test lines and manifold to 3000 PSI. Good test. 21:00 22:00 1.00 0 0 MIRU DRILL RURD P Held PJSM with crew. Discuss safety issues and procedure for rigging up and running GYRO unit. Rig up GYRO with sheaves. Pull tools to floor. f~a~~~ ~ at ~~ ~~ Time Logs -- ~,_Date From To ___ Dur _ S De th E. Depth Phase _ Code Subcode T _COM 01/06/2007 22:00 23:00 1.00 0 0 T SURFA DRILL PULD P Held PJSM with crew and Sperry Sun reps. Discuss afety issues and procedure for making up BHA #1. Make up 16" bit with Drilling assembl . 23:00 00:00 1.00 0 0 SURFA DRILL OTHR P Plug in and up load MWD assembly. Pick u remainder of BHA #1. 01/07/2007 00:00 00:30 0.50 0 121 SURFA DRILL CIRC P Pumps on. Wash down in conductor from 103' - 121' DPM. Observe flow lines stem for leaks. 00:30 06:00 5.50 121 397 SURFA DRILL DDRL P Spud well At 0030 HRS. Directional drill 16" Surface hole from 121' - 397' MD. ND = 397'. Utilize GYRO suroe s. Crew Chan e 06:00 12:00 6.00 397 814 SURFA DRILL DDRL P Continue Directional drill 16" Surface hole from 397' - 830' MD. ND = 814'. 12:00 18:00 6.00 814 1,328 SURFA DRILL DDRL P Continue Directional drill 16" Surface hole from 830' - 1328' MD. ND = 1240'. Crew Chan e 18:00 00:00 6.00 1,328 1,774 SURFA DRILL DDRL P Continue Directional drill 16" Surface hole from 1328' - 1774' MD. ND = 1584'. 01/08/2007 00:00 06:00 6.00 1,774 2,125 SURFA DRILL DDRL P Continue Directional drill 16" Surface hole from 1774' - 2125' MD. ND = 1805'. ADT = 2.83 HRS Crew Chan e .06:00 10:30 4.50 2,175 2,175 SURFA DRILL WOEQ NP POOH Rack back 1 stand. Rotate & Reciprocate drill string cleaning hole & conditioning mud, while wait on Super suckers & vac trucks. 10:30 11:30 1.00 2,125 2,175 SURFA DRILL DDRL P Continue Directional drill from 2125' - 2175' MD. 1827' ND. Observe excessive fluid loss over shaker screens. Trucks couod not kee u . 11:30 12:00 0.50 2,175 2,180 SURFA DRILL DDRL P Contniue directional drill from 2175' - 2180' MD. ND = 1830'. ADT = .44 12:00 18:00 6.00 2,180 2,636 SURFA DRILL DDRL P Continue Directional drill from 2180' - 2636' MD. ND = 1994'. ADT = 3.78 HRS. Crew Chan e 18:00 20:30 2.50 2,636 2,740 SURFA DRILL DDRL P Continue Directional drill from 2636' - 2740' MD. Observe excessive fluid loss once again over shakers, clay blinding them off. Trucks could not kee u .Rack back one stand. 20:30 22:30 2.00 2,740 2,740 SURFA DRILL WOEQ NP Rotate & Reciprocate drill string cleaning hole & conditioning mud, while wait on Super suckers & vac trucks. 22:30 00:00 1.50 2,740 2,826 SURFA DRILL DDRL P Continue directional drill from 2740' - 2826' MD. ND = 2032'. ADT = 2.24 HRS. 01/09/2007 00:00 00:45 0.75 2,826 2,870 SURFA DRILL DDRL P Continue Directional drill from 2826' - 2870' MD. Observed loss of 500 PSI, and ROP slowin to 40-60 FT/HR. ~.-_~. ®_ FBacJz~ ~ .'st ~~ I • Time Logs Date From To Dur S Depth E. De th Phase Code Subcode T COM 01/09/2007 00:45 01:45 1.00 2,870 2,870 SURFA DRILL OTHR NP Trouble shoot pressure loss & ROP issues. Rack back 1 stand. Shut in pressure test surface equipment. Good test. Clean suction screens on mud pumps. Observed 95% packed off. Make u stand. 01:45 03:30 1.75 2,870 2,969 SURFA DRILL DDRL P Continue drirectional drill observing pump pressures same as earlier. ROP increased to 80 - 115 FT/HR. Suspect choke in Pressure drop sub may have washed out. Continue drilling. Pressure stayed steady @ 1900 PSI - 650 GPM's Drill from 2870' - 2969' MD. Observe inclination increase to 85 Deg. giving undesirable dogleg. Rack back 1 stand. 03:30 06:00 2.50 2,969 2,969 SURFA DRILL CIRC NP Reciprocate & rotate drill string to clean hole & condition mud, work drill string to attempt to wipe out excess do le .Crew Chan e 06:00 07:30 1.50 2,969 2,969 SURFA DRILL CIRC NP Continue attempt to wipe out Dog leg. Discuss options with town. Decision to POOH. 07:30 07:45 0.25 2,969 2,969 SURFA DRILL CIRC NP Monitor well -static. Fill trip tank, blow down To Drive & lines. 07:45 10:45 3.00 2,969 451 SURFA DRILL TRIP NP POOH on elevators from 2920' - 451'. Observed good hole fill. No swabbing issues. Hole looked ood. 10:45 12:00 1.25 451 0 SURFA DRILL PULD NP Breakout & lay down BHA #1. 12:00 12:15 0.25 0 0 SURFA DRILL PULD NP Continue Breakout & lay down BHA #1. 12:15 13:00 0.75 0 0 SURFA DRILL PULD NP Plug in and down load MWD assembl . 13:00 14:00 1.00 0 0 SURFA DRILL PULD NP Continue breakout & lay down BHA #1. Inspect & gauge bit to 1/2/ER/A/E/O/NO/BHA. Verified Choke in Pressure drop sub washed out. 14:00 15:00 1.00 0 0 SURFA DRILL PULD NP Clean & clear rig floor from wet trip. Send tools out. 15:00 17:00 2.00 0 0 SURFA RIGMN' SVRG NP Serice top drive. Inspect saver sub & dra works drive chaains. Adjust drawworks brakes. Ins ect linka e. 17:00 18:00 .1.00 0 0 SURFA DRILL PULD NP Make up BHA #2. 16"Bit & drilling assembly with 1.83 deg motor. Re run bit. Crew Chan e 18:00 18:45 0.75 0 0 SURFA DRILL PULD NP Plug in and upload MWD assembly. 18:45 19:45 1.00 0 450 SURFA DRILL PULD NP Continue MU BHA #2. Picking up flex drill collaars, ~ars & HWDP. 19:45 20:15 0.50 450 566 SURFA DRILL TRIP NP TIH from 450' - 566'. perform Shallow pulse test @ 650 GPM's - 1950 PSI. Good test. I P~~P, $ Cad ~~ l I Time Logs Date From To __ Dur S Debi E. De th Phase ___ Code Subcode T COM 01/09/2007 20:15 21:45 1.50 566 _ 1,877 SURFA DRILL TRIP NP Continue TIH from 566' - 1877'. Observed assembly taking weight @ 1040', wash down from 1040' - 1877'. Ta ed brid a with full strip wei ht. 21:45 22:15 0.50 1,877 1,900 SURFA DRILL REAM NP Tagged bridge. Wash & ream through area,from 1815' to 1900'. 22:15 22:45 0.50 1,900 1,900 SURFA DRILL CIRC NP Circulate hole until cleaned up. Observed 350 Visc mud returns and trouble staying on shaker screens, with clay & shale. Reciprocate & rotate drill strip . 22:45 23:15 0.50 1,900 1,967 SURFA DRILL REAM NP Observed trouble @ 1900', could not get assembly through with repeated attempts. Attempted to begin sidetrack here, and then assembly tracked back into original well bore after washing 67', from 1900 - 1967'. Worked assembly through this area until cleaned u . 23:15 00:00 0.75 1,967 1,779 SURFA DRILL REAM NP BROOH from 1967' - 1779'. Obtain check shot surveys to verify drilling asembly in original well bore and not sidetracked. 01/10/2007 00:00 02:30 2.50 1,779 2,790 SURFA DRILL TRIP NP Continue trip in hole from 1779' - 2790'. Observed washing down last 6 stands as we were tagging bridges, utilizing pumps and rotation to work throu h the s ots. 02:30 03:30 1.00 2,790 2,790 SURFA DRILL CIRC NP Circulate 1 1/2 bottoms up to clean up well bore, and allowing shakers to handle the cuttings loads, increasing pump rates to 750 GPM's - 3000 PSI. Reci rocate & rotate drill strip . 03:30 06:00 2.50 2,790 2,818 SURFA DRILL DDRL P Begin troughing well from 2790' - 2818'. Work drill string, time drilling to obtain kickoff. Crew Chan e 06:00 07:00 1.00 2,818 2,818 SURFA DRILL DDRL P Continune troughing well from 2790' - 2818'. Work drill string, time drilling to obtain kickoff. 07:00 12:00 5.00 2,818 2,885 SURFA DRILL DDRL P Directional Drill Surface hole from 2818' - 2885' MD. ADT = 2.82 HRS. 12:00 18:00 6.00 2,885 3,158 SURFA DRILL DDRL P Continue Directional drill Surface hole from 2885' - 3158'. ADT = 3.49 HRS Crew Chan e 18:00 00:00 6.00 3,158 3,590 SURFA DRILL DDRL P Continue Directional drill Surface hole from 3158' - 3590'. ADT = 3.26 HRS 01/11/2007 00:00 06:00 6.00 3,590 3,868 SURFA DRILL DDRL P Continue Directional drill Surface hole from 3590' - 3868'. ADT = 3.72 HRS Grew Chan e 06:00 10:45 4.75 3,868 4,021 SURFA DRILL DDRL P Continue Driectional Drill Surface hole from 3868' - 4021'. Observed inclination dro . TD called. ADT = 2.60 10:45 12:00 1.25 4,021 4,021 SURFA DRILL CIRC P Circulate bottoms up 2 times with rates at 800 GPM's - 3530 PSI. Reci rocate & rotate drill strip . • Time Logs Date From To Dur S De th E Depth. Phase Code Subcode T COM 01/11/2007 12:00 12:45 0.75 4,021 4,021 SURFA DRILL CIRC P Circulate bottoms up 2 times with rates at 800 GPM's - 3530 PSI. Reci rotate & rotate drill strin . 12:45 16:45 4.00 4,021 1,018 SURFA DRILL REAM P BROOH form 4021' - 1018'. Observe good hole, and unloading cuttings cleanin u . 16:45 17:15 0.50 1,018 448 SURFA DRILL TRIP P POOH on elevators from 1018' - 448' MD. Observed good hole conditions, no swabbin ,and ro er hole fill. 17:15 18:00 0.75 448 0 SURFA DRILL PULD P Breakout & lay down BHA #2. Crew Chan e 18:00 19:15 1.25 0 0 SURFA DRILL PULD P Continue breakout & lay down BHA #2. Plug in and download MWD assembly. Drain mud motor. Break out, inspect and gauge bit to 1 /2MIT/A/E/I/ST/TD. 19:15 20:00 0.75 0 0 SURFA DRILL PULD P Clean & clear floor area of tools. 20:00 20:30 0.50 0 0 SURFA CASIN RURD P Rig down short bales on top drive. Lay down 5" DP elevators. 20:30 21:00 0.50 0 0 SURFA RIGMN SVRG P Service Draw works. Adjust & inspect brakes. Ins ect chains on draw works. 21:00 22:45 1.75 0 0 SURFA CASIN RURD P Pull tools to rig floor. Rig up to run 13 3/8 casin as er GBR Re s. 22:45 23:15 0.50 0 0 SURFA CASIN( SFTY P PJSM with crew &GBR reps. Discuss safety issues and procedure for running 13 3/8" casing. Identify hazards, and function test stabbing board with GBR stabber. 23:15 00:00 0.75 0 423 SURFA CASINC RNCS P Make up shoe joint & shoe, threadlock joint, and Float collar & joint. Baker lot threads. MU to 10000 FT/LBS. Fill pipe & check floats. Continue RIH installing Bowspring centralizers as er detail. 01/12/2007 00:00 06:00 6.00 423 2,661 SURFA CASINC RNCS P Continue RIH with 13 3/8" casing installing Bowspring centralizers as per detail. AVG MU Torque = 10K FT/LBS. Crew Chan e 06:00 09:30 3.50 2,661 3,850 SURFA CASIN RNCS P Continue run 13 3/8 casing from 2661' - 3850'. Install Bowspring centralizers on joints 95 & 96. Make up Torque = 10K FT/LBS. 09:30 10:30 1.00 3,850 3,850 SURFA CASIN RNCS P Attempt to make up hanger & pup. No success in make u of han er. 10:30 12:15 1.75 3,850 3,850 SURFA CASINC RNCS NP Continue attempt to make up casing hanger & pup. Unsuccessful. Lay down hanger & pup. MU one more joint of 13 3/8" casing. Verify threads in collar ood. Work casin strip . 12:15 13:45 1.50 4,000 4,000 SURFA CEMEf` PULD P Make up cement head with plugs installed, and all lines. ~_ ~~€~e ~ ~f ~~ Time Logs Date From To Dur S: Depth E. Depth _ Phase Code.. Subcode T __ COM - - - --- 01/12/2007 13:45 17:30 3.75 4,000 4,000 SURFA CEME CIRC P Establish circulation @ 4 BPM - 190 PSI, building to 7 BPM - 230 PSI. Reciprocate casing string with UP WT - 310K, SO WT - 98K. Circulate & condition mud for pre cementing properties 9.4 PPG, Visc = 55, PV = 26, YP = 14, Gels = 7/10. 17:30 18:00 0.50 4,000 4,000 SURFA CEME~ SFTY P Held PJSM with entire crew, truck drivers and Dowell hands. Discuss safety issues and procedure for rigging up and pumping cement. Designate spill champion. Continue reciprocate casin strin .Crew Chan e 18:00 18:45 0.75 4,000 4,000 SURFA CEME~ CIRC P Contniue circulate & condition mud. Dowell hatching up. Reciprocate casing string in 10' increments. UP WT = 300K, SO WT = 90K. 18:45 21:00 2.25 4,000 3,999 SURFA CEME~ CIRC P Turn rig over to Dowell Cementers. Pump 10 BBLS CW 100.. Test Lines to 2500 PSI. Good test. Contiue pump 40 BBLs CW 100, 50 BBLS Mud Push II, Drop Bottom plug. pump a total of 554.79 BBLS of Lead Cement, and 96.18 BBLS of Tail. Drop Top plug. Pump 20 BBLS of water. NOTE: Movement of casing became sticky when MudPUSH at the shoe, Land casin , sto reci vocation. 21:00 22:45 1.75 3,999 3,999 SURFA CEME~ DISP P Turn over to rig pumps. Displace cement with up to 7 BPM - 200 PSI. Slow pumps to 3 BPM - 500 PSI @ 5500 stks. Bumped plug @ 5658 Stks = 570 BBLS. Continue pressure to 1000 PSI. Hold pressure for 5 minutes. Check floats. Floats held. CMIP @ 2230 HRS. Observed a total of 220 BBLS of good cement returns to surface. 22:45 00:00 1.25 3,999 3,999 SURFA CASINC RURD P Blow down & Rig down Cement head & lines. Break out & lay down crossover to cement head. Vac out fluid from inside 13 3/8" casing, for cutting. begin nipple down diverter stack for installation of 13 3!8" sli s. 01/13/2007 00:00 03:15 3.25 3,999 3,999 SURFA CASINC RURD P Continue nipple down diverter stack & riser for installation of 13 3/8" slips. Pull 60K on casin & hold tension. 03:15 04:30 1.25 3,999 0 SURFA CASIN RNCS NP Rig up Porta powerjacks, with cellar adapter tool. Jack 13 3/8" casing to center of bowl. Install casing slips. Set down weight of string, 60K in the slips. RD Porta ower'ackin a ui ment. 04:30 05:30 1.00 0 0 SURFA CASINC OTHR NP Make rough cut in casing to drain mud.Lay down Cement head & Landin 'oint. __-_ --- ----°--- _.~._._ ~Fa:N3 7 of ~;~~ l J Time Lois - -- - Date From To Dur S. De th E. Depth Phase Code Subcode T COM _ 01/13/2007 05:30 06:00 0.50 0 0 SURFA WELCT NUND P Set BOP Stack on starting head, secure for racking back and nipple down. Crew Chan e 06:00 10:00 4.00 0 0 SURFA WELCT NUND P Lay down Surface riser. ND Hydril from diverter spool & starting head. re cellar for weldin on head. 10:00 12:00 2.00 0 0 SURFA CASINC OTHR NP Weld on starting head for wellhead. SIMOPs: Continue rig down all equipment on rig floor. Lay down long bales. Pick up & install short bales. Install & adjust link Tilt linkage. Install 5" DP elevators, and pick up 5" DP pup. Set in rotary table, MU Top Drive, and hang blocks for draw works brake ad'ustment. 12:00 12:45 0.75 0 0 SURFA CASINC OTHR NP Continue weld head on 20" Conductor. Wrap head with insulation. Allowing head to cool as er welder. 12:45 17:45 5.00 0 0 SURFA CASINC OTHR NP Allow wellhead to cool. SIMOPS: load pipe shed with 120 joints of 5" drill pipe. Install 1 super slider per joint. Adjust draw works brakes. Continue clean pits #1 . Sevice centrifuge. Dress shakers 3,4,&5. Clean & service Desilter. Replace drive chain on high gear of draw works. Grease choke manifold. 17:45 18:00 0.25 0 0 SURFA CASIN OTHR NP Rig up test pump. Test weld on starting head. Hold pressure for @ 500 PSI for 5 minutes as per Vetco Gray re .Good test. Crew Chan e 18:00 19:00 1.00 0 0 SURFA WELCT NUND P Nipple up, orient Vetco Gray M-222a 13 3/8 x 4 1!2" wellhead. Test to 5000 PSI as per rep. Good test witnessed b Co. Man. 19:00 00:00 5.00 0 0 SURFA WELCT NUND P Nipple up BOP stack, choke & kill lines. Load test joints for upcoming test. 01/14/2007 00:00 01:00 1.00 0 0 SURFA WELCT BOPE P Rig up test equipment. Fill stack & lines, check for leaks. 01:00 06:00 5.00 0 0 SURFA WELCT BOPE P Perform BOP test. Witness of test waived by AOGCC rep Jeff Jones. BOP test held for each size of expected sizes needed, 4", 4 1/2", 5", 5 1/2" & 9 5/8". Crew Chan e 06:00 11:00 5.00 0 0 SURFA WELCT BOPE P Continue testing BOP's. BOP test held for each size of expected string sizes needed, 4", 4 1/2", 5", 5 1/2" & 9 5/8". Perform Koomey test. 200 PSI increase in 37 seconds, with full charge @ 3 min, 23 seconds. Avg pressure in 6 bottles = 2275 PSI. Test all floor valves. All test recorded on chart. 250 PSI Low, 3000 PSI High test. I ~ _~.i..__ P<jy~ ~ f ~~~ ~~ C-~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/14/2007 11:00 12:00 1.00 0 0 SURFA WELCT BOPE P Pull test plug. Install long wear bushing. RILDS. Blow down all surface lines, and choke manifold. 12:00 12:45 0.75 0 0 SURFA WELCT BOPE P Continue blow down all fines. & rig down testin a ui ment. 12:45 14:15 1.50 0 0 SURFA RIGMN SVRG P Change out saver sub on Top Drive. 14:15 18:00 3.75 0 0 SURFA DRILL PULD P Pick up and stand back 29 stands of 5" DP with super sliders installed. One er'oint. Crew Chan e 18:00 20:00 2.00 0 0 SURFA DRILL PULD P Continue Pick up and stand back 11 stands of 5" DP with super sliders installed. One perjoint. 40 stands total. 20:00 20:30 0.50 0 0 SURFA DRILL PULD P Clear & clean rig floor. Pull tools to floor. Held PJSM with crew & Sperry reps. Discuss safety issues and rocedure for makin u BHA #3. 20:30 22:15 1.75 0 101 SURFA DRILL PULD P Make u p BHA #3, with Hughes 12 1/4" MX1-L1 bit. & 8" Sperry Motor. Make u MWD assembl . 22:15 22:45 0.50 101 101 SURFA DRILL PULD P Plug in , dowload MWD assembly. 22:45 23:00 0.25 101 482 SURFA DRILL PULD P Continue make up remaining BHA #3. Total len th of BHA = 482.61'. 23:00 00:00 1.00 482 1,529 SURFA DRILL TRIP P Trip in hole from 482' - 1529'. Obtain SLM while TIH. 01/15/2007 00:00 00:15 0.25 1,529 1,909 SURFA DRILL TRIP P Contiue TIH from 1529' - 1909'. 00:15 00:45 0.50 1,909 1,909 SURFA DRILL CIRC P Make top drive connection. Obtain pump pressures before MU Agitator. Before agitator installed 600 GPM's - 1140 PSI. 850 GPM's - 1940 PSI. 00:45 01:15 0.50 1,909 1,997 SURFA DRILL PULD P Make up Agitaor & shock sub with crossovers with 2 joints 5" HWDP. Total len th = 87.75'. 01:15 01:45 0.50 1,997 1,997 SURFA DRILL CIRC P Make top drive connection. Obtain pump pressures after MU Agitator. 600 GPM's - 1540 PSI, 850 GPM's - 2580 PSI. 01:45 02:45 1.00 1,997 3,900 SURFA DRILL TRIP P Continue trip in hole from 1997' - 3900' 02:45 03:15 0.50 3,900 3,900 SURFA DRILL CIRC P Make Top drive connection. Circulate bottoms up @ 800 GPM's - 2580 PSI. Fill lines. 03:15 03:45 0.50 3,900 3,900 SURFA DRILL PULD P Fill lines. Rig up testing equipment & lines for casin test. 03:45 04:45 1.00 3,900 3,900 SURFA DRILL DHEO P Pump down DP & Annulus, to 3000 PSI. Hold test for 30 minutes. Record on chart. 04:45 05:15 0.50 3,900 3,900 SURFA DRILL PULD P Rig down all testing equipment & lines. 05:15 06:00 0.75 3,900 3,980 SURFA CEME COCF P Tag Float equipment @ 3910' DPM. Drill Float collar & shoe track from 3910' - 3980' Crew Chan e 06:00 07:30 1.50 3,980 4,021 SURFA CEME~ COCF P Continue drill Shoe track & float e ui ment from 3980' - 4021'. I _~ _~ s _® _ .~~~ 1. CI Time Logs _ _ _ Date Frorn To Dur S. De th E. De th PhaSe Code Subcod e T COM 01/15/2007 07:30 08:30 1.00 4,021 4,041 SURFA DRILL _ DRLG P _ Continue drill open hole from 4021' -4041'. 20' of new hole . 08:30 09:45 1.25 4,041 4,041 SURFA DRILL CIRC P Displace well with 9.0 PPG LSND mud. 09:45 10:45 1.00 4,041 4,041 SURFA DRILL LOT P Rig up and perform LOT to 12.5 MWE as er Co. Re .Recorded on chart. 10:45 11:00 0.25 4,041 4,041 INTRM1 DRILL CIRC P Circulate & obtain baseline cleanhole ECD 9.2 PPG 11:00 12:00 1.00 4,041 4,150 INTRM1 DRILL DDRL P Directional drill from 4041' - 4150' . ADT = .93 HRS. 12:00 15:45 3.75 4,150 4,463 INTRM1 DRILL DDRL P Directional drill from 4150' - 4463' . ADT = 2.0 HRS 15:45 16:45 1.00 4,463 4,463 INTRM1 DRILL REAM NP Wash & ream hole to reduce unwanted do loe 4463' as er DD. 16:45 18:00 1.25 4,463 4,563 INTRMI DRILL DDRL P Directional drill from 4463' - 4563'. ADT .56 HRS. Crew Chan e 18:00 00:00 6.00 4,563 5,043 INTRM1 DRILL DDRL P Continue driectional drilling from 4563' - 5043'. ADT 3.00 HRS. Obtain checkshot surveys every 30 ft while slidin as er DD. 01!16/2007 00:00 06:00 6.00 5,043 5,509 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole 06:00 08:45 2.75 5,509 5,700 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. 08:45 10:30 1.75 5,700 5,700 INTRM1 DRILL REAM P Wash and ream to reduce inclination as er directional driller. 10:30 12:00 1.50 5,700 5,819 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. 12:00 18:00 6.00 5,819 6,292 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. 18:00 21:30 3.50 6,292 6,557 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. 21:30 00:00 2.50 6,557 6,557 INTRM1 RIGMN RGRP NP Remove broken clamp on standpipe in derrick. Reciprocate drill string. Pum in slow! . 01/17/2007 00:00 02:00 2.00 6,557 6,652 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. Jar hours 130.95 hrs. 02:00 03:45 1.75 6,652 6,652 INTRM1 RIGMN RGRP NP Install fixed stand pipe clamp to derrick and stand pipe. Circ @ 3bpm w/ 240 psi. Reciprocate slow while fixin . 03:45 06:00 2.25 6,652 6,769 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. Jar hours 132.19 hrs. 06:00 12:00 6.00 6,769 7,127 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. Jar hours 135.53 hrs. Max as 60 units. 12:00 13:15 1.25 7,127 7,222 INTRM1 DRILL DDRL P Continue driectional drill 12 1/4" Intermediate hole. 13:15 13:45 0.50 7,168 7,124 INTRM1 DRILL OTHR P MAD pass logging. Traveling speed 3 ft er min as er S er Sun MWD. _ ~ ~ ~e ~e__---- m_ss~~~ v ~ <;;_~~ ;~ of 4~J • l I Time Logs Date From To Dur S Depth E. De th Phase Code SubCOde T COM 01/17!2007 13:45 18:00 4.25 7,222 7,506 INTRM1 DRILL DDRL P _____ _ __ Continue driectional dri{I 12 114" Intermediate hole. Jar hours 138.56 hrs. Max gas 60 units. Pumped 30 bbls 11 ppg, 107 vis sweep while drilling @ 7420'. No increase in cuttin s observed. 18:00 00:00 6.00 7,506 7,836 INTRM1 DRILL DDRL P Gontinue driectional drill 12 1/4" Intermediate hole. Jar hours 141.23 hrs. Max as 16 units. 01/18/2007 00:00 15:30 15.50 7,836 8,932 INTRM1 DRILL DDRL P Continue driectional drill 12 1!4" Intermediate hole. Jar hours 149.45 hrs. Max as 50 units. 15:30 17:00 1.50 8,932 8,932 INTRM1 DRILL CIRC P Pump sweep (11 ppg, 145 vis). Circulate bottoms u . 17:00 00:00 7.00 8,932 5,700 INTRM1 DRILL REAM P Backream out of hole. Pull on elevators every other stand. Inspect clamps on stand pipe every 10 stands. Inspect super sliders. Pulling speed 40-45 ft er min. 01/19/2007 00:00 06:00 6.00 5,700 3,900 INTRM1 DRILL REAM P Continue backreaming out of hole. Ream every stand due to high torque (15-22k ft Ib). Tried to pull on elevators every so often, no luck- pulling tight. Pulling speed 7-20 ft per min. 120 RPM. Increase flow rate to 500 gpm w/ 1400 psi. Inspect clamps on stand i e eve 10 stands. 06:00 08:00 2.00 3,900 3,900 INTRM1 RIGMN RGRP NP Preventative maint. Install new clamp at to of stand i e. 08:00 10:45 2.75 3,900 3,900 INTRM1 DRILL CIRC P Pump a 30 bbl high weight/ Hi vis sweep (11 ppg/ 107 vis) with 50 increase in cuttings with sweep. Follow with three bottoms up. Pump a d 'ob. 10:45 12:00 1.25 3,900 3,900 INTRM1 RIGMN' RGRP NP Preventative maint. Inspect clamps on stand i e. 12:00 13:00 1.00 3,900 1,513 INTRM1 DRILL TRIP P Pull out of hole on elevators. Record PU and SO wt's every 10 stands inside of casin . 13:00 13:30 0.50 1,513 1,425 INTRM1 DRILL PULD P Lay down 8" Anderguage agitator and shock sub and 2 jts of dp and crossovers. 13:30 14:15 0.75 1,425 482 INTRM1 DRILL TRIP P Continue pulling out of hole with BHA #3 to BHA. 14:15 15:00 0.75 482 103 INTRM1 DRILL TRIP P Pull out and stand back 3 stands of 5" heavy weight drill pipe, Stand back a stand of 8" flex drill collars. 15:00 15:30 0.50 103 0 INTRM1 DRILL TRIP P Pull last stand, drain Sperrydrill motor, break off hu hes 12-1/4" bit. 15:30 16:15 0.75 0 89 INTRM1 DRILL OTHR P Run stand in hole, download Sperry Sun MWD. Inspect derrick (ODS) while downloadin tools. 16:15 17:00 0.75 89 0 INTRM1 DRILL PULD P Lay down BHA #3. 17:00 17:30 0.50 0 0 INTRM1 DRILL OTHR P Clear and clean rig floor. • • Time Logs _ DateFrom To Dur _ S Depth E Depth Phase Code Subcode T COM 01/23/2007 03:30 03:45 025 6,641 6,641 INTRM1 RIGMN RGRP P Inspect standpipe clamps and tighten bolts. 03:45 04:45 1.00 6,641 6,166 INTRM1 DRILL REAM P Continue backreaming 04:45 05:15 0.50 6,166 6,261 INTRM1 DRILL CIRC P Hole swabbing, RIH, circulate to cleanu . 05:15 09:15 4.00 6,261 3,800 INTRM1 DRILL REAM P Continue backreaming 09:15 10:00 0.75 3,800 3,800 INTRM1 DRILL CIRC P CBU above shoe 500 BBLS. Reciprocating pipe 90'. Blow down to drive, monitor well -static 10:00 10:45 0.75 3,800 2,550 INTRM1 DRILL TRIP P POOH on elevators 10:45 12:45 2.00 2,550 2,370 INTRM1 DRILL TRIP P RU and LD agitator assembly 12:45 13:00 0.25 2,370 2,370 INTRM1 DRILL SFTY P PJSM on changing bolts in standpipe clam s 13:00 14:45 1.75 2,370 2,370 INTRM1 RIGMN RGRP NP Changeout bolts on standpipe clamps 14:45 15:45 1.00 2,370 3,980 INTRM1 DRILL TRIP P RIH w/5" DP 15:45 17:45 2.00 3,980 3,980 INTRM1 DRILL CIRC P CBU 3x. Reciprocating pipe 90'. Observe well. Slowdown to drive 17:45 18:00 0.25 3,980 4,600 INTRM1 DRILL TRIP P TIH for wiper trip 18:00 19:00 1.00 4,600 5,600 INTRM1 DRILL TRIP P TIH & fill pipe 19:00 21:15 2.25 5,600 6,277 INTRM1 DRILL TRIP P TIH, circulate thru areas with low down wei ht 21:15 21:30 0.25 6,277 6,277 INTRM1 DRILL CIRC P Circulate and condition mud 21:30 00:00 2.50 6,277 7,597 INTRM1 DRILL TRIP P TIH, circulate thru areas with low down wei ht 01/24/2007 00:00 02:00 2.00 7,597 8,834 INTRM1 DRILL TRIP P TIH, circulate thru areas with low down weight. Record PU and SO wt's every 5 stands. 02:00 02:30 0.50 8,834 8,834 INTRM1 DRILL CIRC P Circulate. Rotate 120 rpm w/ 12-14k ft Ib torque. Working UP only while circulating, to avoid sidetracking well. ECD's 9.96 02:30 04:00 1.50 8,834 9,976 INTRM1 DRILL TRIP P TIH, circulate thru areas with low down weight. Record PU and SO wt's every 5 stands. 04:00 04:30 0.50 9,976 9,976 INTRM1 DRILL CIRC P Circulate. Rotate 120 rpm w/ 12-13k ft Ib torque. Working UP only while circulating, to avoid sidetracking well. ECD's 9.86 . Pum 150 bbls. 04:30 05:30 1.00 9,976 10,833 INTRM1 DRILL TRIP P TIH, circulate thru areas with low down weight. Record PU and SO wt's every 5 stands. 05:30 06:00 0.50 10,833 10,850 INTRM1 DRILL TRIP P Pick up single. Tag bottom. PU wt 205k, SO wt 80k. 06:00 07:30 1.50 10,850 10,850 INTRM1 DRILL CIRC P Circulate and reciprocate pipe 93'. While circ first BU, stage rate from 650 gpm to 800 gpm. Obtain slow um rates. ~'<~~~ 33 r~`~5 i _ _____i • • Time Logs Date From _To Dur S. Depth E. De th Phase Code Subcode T__COM____ _ ____ 01/25/2007 16:00 17:00 1.00 443 INTRM1 DRILL PULD P Attempt to pull wear bushing. 17:00 18:15 1.25 0 0 INTRM1 DRILL PULD T Wear bushing stuck. Suspect fine cuttings have "cemented" it in place. Flowed into 13 3/8 x 9 5/8 annulus to clean out. 18:15 20:30 2.25 0 0 INTRMI CASIN RURD P rig up to run 9 5/8 casing 20:30 20:45 0.25 0 0 INTRM1 CASIN SFTY P PJSM on running casing 20:45 00:00 3.25 0 443 INTRM1 CASIN RNCS P RIH with 9 5/8 casing. Establish circulation thru float a ui ment 01/26/2007 00:00 06:30 6.50 443 3,893 INTRM1 CASINC RNCS P RIH w/ 9-5/8" intermediate casing. Record PU and SO wt's eve 10 ~ts. 06:30 07:45 1.25 3,983 3,983 INTRM1 CASINC CIRC P Circulate w/ 9-5/8" casing close to the 13-3/8" shoe usin Frank's fillu tool. 07:45 08:45 1.00 3,983 3,983 INTRM1 CASIN CIRC P Spot Alpine tube beads in the 240 bbl annulus. 8 ppb. No change in PU and SO wt's taken before and after. 08:45 12:00 3.25 3,983 6,200 INTRM1 CASINC RNCS P RIH w/ 9-5/8" intermediate casing. Record PU and SO wt's eve 10 'ts. 12:00 13:00 1.00 6,200 6,200 INTRM1 CASINC CIRC P Circulate bottoms up w/ Frank's fillup tool.. Reci rocate i e 30'. 13:00 16:30 3.50 6,200 8,150 INTRM1 CASINC RNCS P RIH w/ 9-5/8" intermediate casing. Record PU and SO wt's eve 10 'ts. 16:30 18:00 1.50 8,150 8,150 INTRM1 CASINC CIRC P Circulate bottoms up w/ Frank's fillup tool.. Reci rocate i e 15'. 18:00 21:00 3.00 8,150 9,736 INTRM1 CASINC RNCS P RIH w/ 9-5/8" intermediate casing. Record PU and SO wt's eve 10 'ts. 21:00 21:30 0.50 9,736 9,736 INTRM1 CASINC CIRC P Circulate 150 bbls w/ Frank's fillup tool. Reci 20'. 21:30 00:00 2.50 9,736 10,850 INTRM1 CASINC RNCS P RIH w/ 9-5/8" intermediate casing. Record PU and SO wt's eve 10 'ts. 01/27/2007 00:00 00:15 0.25 10,850 10,850 INTRM1 CEME CIRC P Circulate and condition mud and hole w/ Frank's fillup tool while recip casing f/ 10850' to 10820' (30' stroke). Initial circ rate 5 bpm w/ 450-460 psi. Pump 100 bbls. Clear and clean floor. Lay down some casing tools. Circulate a total of 620 bbls (BU+). Initial PU wt 320-300k, final 290-300k. Initial SO wt 110k, final SO wt 105-100k. 00:15 01:00 0.75 10,850 10,850 INTRM1 CEME~ RURD P Break and lay down Frank's fillup tool. Blow down top drive. MU Dowell Cementin head. ~'a~~ 95 oaf ~ • Time Logs --- - _ Date ____ _From - To I~ur__ S,_Depth E Depth - Phase Code - - Subcode T COM _ _ 01/27/2007 01:00 05:30 4.50 10,850 10,850 INTRM1 CEME~ CIRC P __ __ Circulate and condition mud and hole f/ cement Reciprocate 30' w/ Initial PU wt 320-300k, final 305-315k. Initial SO wt 110k, final SO wt 100-105k. Initial circ rate f/ first 160 bbls was 5 bpm then went to 6 bpm w/ 370 psi. After pumping a total of 355 bbls through cementing head increased rate to 7 bpm w/ 420 psi initial and 390 psi final. Pumped a total of 2000 bbls (3 BU+). Held PJSM on cementing @ 0515 hrs while circulating. Mud properties prior to conditioning mud f/ cement job: 9.2 ppg, vis 60, PV 12, YP 24, 10 sec gel's 8, 10 min gels 15. Mud properties after conditioning mud f/ cement job: 9.1+ppg, vis 50, PV 11, YP 14, 10 sec gel's 5, 10 min els 8. 05:30 07:30 2.00 10,850 10,850 INTRM1 CEME~ OTHR P Dowell pump 10 bbls CW100 (8.34 ppg), pressure test lines to 3100 psi, pump an additional 40 bbls CW100 (Total of 50 bbls), follow w/ 77.3 bbls mud push (11 ppg), drop bottom plug, follow w/ 334.9 bbls DeepCrete (835 sx) (Yield 2.24 cuft/sx) (7.485 gal/sx water) mixed @ 12.5 ppg, pumped @ 6 bpm, drop top plug, pump 10 bbls water, turn over to rig f/displacement. Reci rocated i e f/ 10850' to 10820'. 07:30 09:30 2.00 10,850 10,845 INTRM1 CEME DISP P Rig displace cement w/ 8.6 ppg MOBM (87 vis and 75 deg temp). Pumping @ 7 bpm until last 10 bbls. Last 10 bbls pumped @ 3 bpm initial circ pressure 700 psi, bump plug (calculated strokes) w/ 1500 psi @ 0915 hrs. Hold f/ 5 min. Bleed off pressure, check floats- holding. CIP @ 0915 hrs 1/27/2007. Displacement was recorded on chart recorder. Reciprocated pipe 20' f/ 10850' to 10830' until 0752 hrs when ran out of down wt. Had displaced 270 bbls mud after dowell's 10 bbls of water on top of top plug (280 bbls behind plug). CW100 was 79 bbls from exitin shoe. 09:30 10:00 0.50 10,845 10,845 INTRM1 CEME~ SFTY P Blow down cementing line. PJSM on sucking fluid out of lastjoint and ni lin down BOPE to set sli s. 10:00 11:00 1.00 10,845 10,845 INTRM1 CASIN RURD P Rig down casing tools 11:00 11:30 0.50 10,845 10,845 INTRMI CEME~ RURD P Rig down cement head and adapter. Working to ready BOP stack to lift same. 11:30 11:45 0.25 10,845 10,845 INTRM1 WELCT SFTY P Pre job safety meeting on raising BOP stack. ®~_ ~_a m ~_ ~®~ ~e- w. Pa~c;~ 4~a ~~ ~ n Time Logs Date From To Dur S D_epth_E__Depth Phase Code Subcode T COM_ ___ 01/27/2007 11:45 13:30 1.75 10,845 10,845 INTRM1 WELCT OTHR P Raise BOP stack 36". Clean out bowl to set slips. PU to 190k on wt indicator. Set 110k on slips. Vetco/Gray use WACKS pneumatic cutter to cut off 9-5/8" casin . 13:30 13:45 0.25 10,845 0 INTRM1 CASINC RURD P Lay down jt # 280 plus cutoff jt #279. 13:45 14:30 0.75 0 0 INTRM1 WELCT NUND P Install packoff. Nipple up BOP stack. 14:30 15:30 1.00 0 0 INTRM1 WELCT OTHR P Vetco Gray rep pumped plastic to energize seal on packoff. Then test packoff to 2500 psi (80% collapse of 9-5/8", 40 ppf, L-80 casing) for 10 min. OK. 15:30 16:45 1.25 0 0 INTRM1 CEME~ LOT P Connect 2" hose to 9-5/8" x 13-3/8" annulus w/ chart recorder. Test lines to 2500 psi. Perform infectivity test. Then pump a total of 30 bbls of water to flush possible cement between the 9-5/8" x 13-3/8". 16:45 17:15 0.50 0 0 INTRM1 WELCT BOPE P 14 day BOP test. Witness of test waived by AOGCC inspector Lou Grimaldi. Test Koomey, bleed down to 1700 psi, 200 build up in 40 seconds, full charge achieved in 2 min 51 seconds. Average precharge on accumulator bottles was 1050 psi. Nitrogen backup 5 bottles was 2275 si. 17:15 18:30 1.25 0 0 INTRM1 WELCT BOPE P PU/MU 5" test joint w/ Vetco Gray test plug. Fill stack with water. RU to test BOPE. 18:30 00:00 5.50 0 0 INTRM1 WELCT BOPE P Test BOPE. Tests w/ 4", 4-1/2" and 5" pipe size. Test floor safety valves both 4" and 5". Test choke manifold, choke and kill lines valves and annular. All tests: low to 250 psi and 3000 psi high. Hold each test 5 min. Chart test. Upper IBOP on top drive failed low test. 01/28/2007 00:00 00:30 0.50 0 0 INTRM1 WELCT BOPE P Finish testing BOPE. Note: IBOP on top drive failed, will be Chan ed out and tested. 00:30 01:30 1.00 0 0 INTRM1 WELCT OTHR P Pull Vetco/Gray test plug. Rig down testing equipment. Blow down kill and choke lines and manifold. 01:30 02:00 0.50 0 0 INTRM1 WELCT OTHR P Install Vetco/Gray wear bushing (13-3/8" OD x 9" ID x 38" long). RILDS as er/ Vetco re . 02:00 02:15 0.25 0 0 INTRM1 RIGMN SFTY P Pre job safety meeting on changing out u er IBOP. 02:15 07:45 5.50 0 0 INTRM1 RIGMN RGRP T Change out upper IBOP on top drive. 7-5/8" Reg Box x Box. Install actuator and new saver sub to 4-1/2" IF pin. 07:45 08:15 0.50 0 0 INTRM1 WELCT BOPE P Test IBOP to 250 psi low and 3000 psi high, OK. Rig down test equipment, clean floor. ~~ _ __m ®~_ P~€~~ ~ r of ~5 ~l • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T COM - - -- 01/28/2007 08:15 08:45 0.50 0 0 INTRM1 RIGMN RGRP T Reassemble torque rings across connections, ri u i e handler. 08:45 10:45 2.00 0 0 INTRM1 DRILL RURD P PU drilling bales and elevators for 4" drill i e. PU/MU Bit # 5 and BHA #6. 10:45 11:00 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting w/ Sperry Sun directional driller and MWD on picking u /makin u BHA # 6. 11:00 13:30 2.50 0 0 INTRM1 DRILL PULD P Picking up/making up BHA # 6. 13:30 14:00 0.50 0 89 INTRM1 DRILL OTHR P Upload Sperry Sun MWD. 14:00 15:15 1.25 89 390 INTRM1 DRILL PULD P Continue picking up/making up BHA # 6. PU 1 't of 4" d . 15:15 16:00 0.75 390 390 INTRM1 DRILL OTHR P Make up 4" XT 39 head pin and accessories to shallow test MWD tools. OK. Pressure test geo pilot skid to 3000 si. Downlink to eo ilot, ok. 16:00 16:30 0.50 390 735 INTRM1 DRILL PULD P PU/MU 4" DP. RIH w/ BHA #6. 16:30 17:45 1.25 735 31 INTRM1 DRILL TRIP NP POOH to change location of smart stabilizer. 17:45 18:00 0.25 31 89 INTRM1 DRILL OTHR NP Upload Sperry Sun MWD. 18:00 18:45 0.75 89 735 INTRM1 DRILL TRIP NP RIH w/ 4 stands of 4"drill pipe and BHA #6. 18:45 22:00 3.25 735 2,614 INTRM1 DRILL PULD P Continue PU/MU 4"drill pipe from pipe shed. Drifted to 2-3/8". 22:00 22:30 0.50 2,614 2,614 INTRM1 DRILL OTHR P Fill pipe. Pump 300 gpm w/ 1850 psi to check MWD and eo ilot. 22:30 00:00 1.50 2,614 4,022 INTRM1 DRILL PULD P Continue PU/MU 4"drill pipe from pipe shed. Drifted to 2-3/8". 01/29/2007 00:00 01:30 1.50 4,022 5,051 INTRM1 DRILL PULD P Continue PU/MU 4"drill pipe from pipe shed. Drifted to 2-3/8". 01:30 01:45 0.25 5,051 5,051 INTRM1 DRILL OTHR P Fill pipe. Check MWD and geo pilot. 01:45 04:45 3.00 5,051 7,397 INTRM1 DRILL PULD P Continue PU/MU 4" drill pipe from pipe shed. Drifted to 2-3/8". 04:45 05:00 0.25 7,397 7,397 INTRM1 DRILL OTHR P Fill pipe. Check MWD and geo pilot. 05:00 05:15 0.25 7,397 7,397 INTRM1 DRILL OTHR P Re-adjust clamps on saver sub to cover across the break of the connection. 05:15 06:00 0.75 7,397 7,397 INTRM1 DRILL OTHR P Change elevators to 5". Install x-o f/ 4" XT39 to 4-1/2" IF. Drift 5" dp w/ 2-7/8" drift. 06:00 08:30 2.50 7,397 8,475 INTRM1 DRILL PULD P PU/MU 36 jts of 5"drill pipe from pipe shed. Drifted to 2-7/8". Rig down pipe skate, clear and clean ri floor. 08:30 09:30 1.00 8,475 7,397 INTRM1 DRILL TRIP P POOH w/ 12 stands of 5" dp. Rack on off driller's side. 09:30 09:45 0.25 7,397 7,508 INTRM1 DRILL PULD P PU/MU stand of 5" dp. Make up centurian circulating valve above first sin le. 09:45 10:45 1.00 7,508 7,508 INTRM1 RIGMN SVRG P Service rig and top drive. Clear rig floor. i ~g p Pa~~ 9 ~ '~~ s4~ C: C. Time Logs Date From To Dur S. De t_h E. DEpth_ Phase Code Subcode T COM ___ ~~ 01/29/2007 10:45 17:00 6.25 7,508 10,749 INTRM1 DRILL TRIP P RIH w/ 5" dp, moving super sliders down on each jt, retorque bolts. Have 40 stands in derrick w/super sliders. Ta ed to of cement 10749'. 17:00 17:45 0.75 10,749 10,742 INTRM1 DRILL TRIP P Stand back a stand. Circulate 315 gpm w/ 2390 psi, Rotate 30 rpm w/ 8K ft Ib torque. Break in seals on geo ilot. 17:45 18:15 0.50 10,742 10,742 INTRM1 DRILL RURD P Blow down top drive. Rig up to test 9-5/8" intermediate casin . 18:15 19:00 0.75 10,742 10,742 INTRM1 DRILL DHEQ P Test 9-5/8" Intermediate casing to 3000 si. Chart test. OK. 19:00 19:15 0.25 10,742 10,742 INTRM1 DRILL OTHR P Blow down top drive. Rig down e ui ment to test casin . 19:15 23:30 4.25 10,742 10,844 INTRM1 CEME~ COCF P Make Top drive connection. Establish circ. Obtain SPR's. Drill. Drill FC, Cement, FS. 23:30 23:45 0.25 10,850 10,875 INTRM1 DRILL DDRL P Drill cement in rat hole, plus 25' of new hole. 23:45 00:00 0.25 10,875 10,836 INTRM1 DRILL TRIP P Pull stand # 112, set back stand to circ rior to erformin leak off test. 01/30/2007 00:00 01:45 1.75 10,836 10,836 INTRM1 DRILL CIRC P Circulate prior to performing LOT. MW in and out to 8.5 01:45 02:30 0.75 10,836 10,836 INTRM1 DRILL RURD P Tool box meeting on performing LOT. Rig up to perform test. RU chart recorder and surface a ui ment. 02:30 03:00 0.50 10,836 10,836 INTRMI DRILL LOT P Perform LOT w/ 8.5 ppg mud. Pump 6 spm, record ressure eve 2 strokes. 03:00 04:15 1.25 10,836 10,836 PROD1 RIGMN SVRG P Service rig, top drive crown and drawworks. Check chains. 04:15 04:30 0.25 10,836 10,836 PROD1 DRILL RURD P Blow down lines. Rig down lines for testin . 04:30 05:30 1.00 10,836 10,850 PROD1 DRILL CIRC P MU stand # 112. Perform PWD baseline test. 250 gpm: Orpm = 9.1 ppg, 50 rpm = 9.16 ppg, 100 rpm = 9.18 ppg, standpipe pressure = 2170 psi. 300 gpm: Orpm = 9.15 ppg, 50 rpm = 9.22 ppg, 100 gpm = 9.26 PP9. standpipe pressure = 3025 psi. 320 gpm: 0 rpm = 9.18 ppg, 50 rpm = 9.27 ppg, 100 rpm = 9.3 ppg, standpipe ressure = 3297 si. 05:30 06:00 0.50 10,875 10,931 PROD1 DRILL DDRL P Drill 6-3/4" hole from 10875' - 10931'. Crew Chan e 06:00 12:00 6.00 10,931 11,312 PROD1 DRILL DDRL P Continue directional drill from 10931' - 11312' MD. ECD = 9.53 PPG. 12:00 18:00 6.00 11,312 11,853 PROD1 DRILL DDRL P Continue directional drill from 11312' - 11853' MD. ECD = 9.53 PPG. Crew Chan e 18:00 00:00 6.00 11,853 12,358 PROD1 DRILL DDRL P Continue directional drill from 11853' - 12358' MD. ECD = 9.78 PPG. 01/31/2007 00:00 06:00 6.00 12,358 12,768 PROD1 DRILL DDRL P Continue directional drill from 12358' - 12768' MD. ECD = 9.78 PPG. ADT - 3.5 HRS. Crew Chan e E A ,p ,~c7L'~L t'~ .',~1~ -§~~.7 r: • Time Lo s --- 9- __- -- _ - Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/31/2007 06:00 12:00 6.00 12,768 13,203 PROD1 DRILL DDRL P Continue directional drill from 12768' - 13203' MD. ECD = 9.96 PPG. ADT - 4.69 HRS. 12:00 14:45 2.75 13,203 13,308 PROD1 DRILL DDRL P Continue directional drill from 13203' - 13308 MD. ECD = 9.90 PPG. ADT - 2.27 HRS. 14:45 18:00 3.25 13,308 13,308 PROD1 DRILL WOW NP Wait on weather conditions to improve. Declared Phase 3 Conditions. Reciprocate & rotate drill string from 13308' - 13215'. Reduced pump rate of 40 GPM's 1020 PSI, after circulate to clean up hole. Made crew change with Heavy Equipment Convo . 18:00 00:00 6.00 13,308 13,308 PROD1 DRILL WOW NP Continue Wait on weather conditions to improve. Declared Phase 3 Conditions. Reciprocate & rotate drill string from 13308' - 13215'. Reduced pump rate of 40 GPM's 1020 PSI. Weather cleared. Decision to continue drillin at midni ht. 02/01/2007 00:00 06:00 6.00 13,308 13,825 PROD1 DRILL DDRL P Continue directional drill from 13308' - 13825' MD. ECD = 9.90 PPG. ADT - 3.10 HRS. Crew Chan e 06:00 12:00 6.00 13,825 14,287 PROD1 DRILL DDRL P Continue directional drill from 13825' - 14287' MD. ECD = 10.38 PPG. ADT - 4.44 HRS. 12:00 18:00 6.00 14,287 14,609 PROD1 DRILL DDRL P Continue directional drill from 14287' - 14609' MD. ECD = 10.49 PPG. ADT - 4.74 HRS. Crew Chan e 18:00 00:00 6.00 14,609 14,922 PROD1 DRILL DDRL P Continue directional drill from 14609' - 14922' MD. ECD = 10.3 PPG. ADT - 4.05 HRS. 02/02/2007 00:00 06:00 6.00 14,922 15,344 PROD1 DRILL DDRL P Continue directional drill from 14922' - 15344' MD. ECD = 10.7 PPG. ADT - 3.07 HRS. 06:00 12:00 6.00 15,344 15,732 PROD1 DRILL DDRL P Continue directional drill from 15344' - 15732' MD. ECD = 10.85 PPG. ADT - 3.62 HRS. 12:00 18:00 6.00 15,732 16,348 PROD1 DRILL DDRL P Continue directional drill from 15732' - 16348' MD. ECD = 10.88 PPG. ADT - 4.02 HRS. 18:00 00:00 6.00 16,348 16,939 PROD1 DRILL DDRL P Continue directional drill from 16348' - 16939' MD. ECD = 11.1 PPG. ADT - 2.75 HRS. 02!03/2007 00:00 06:00 6.00 16,939 17,323 PROD1 DRILL DDRL P Continue directional drill from 16939' - 17323' MD. ECD = 11.1 PPG. ADT - 3.59 HRS. Crew Chan e 06:00 10:45 4.75 17,323 17,834 PROD1 DRILL DDRL P Continue directional drill from 17323' - 17834' MD. ECD = 11.28 PPG. ADT - 2.63 HRS. 10:45 12:00 1.25 17,834 17,834 PROD1 DRILL CIRC P Obtain Slow pump rates. Reciprocate & rotate drill string while pump 30 BBL Hi-Visc wei hted swee to clean hole. 12:00 14:15 2.25 17,834 17,834 PROD1 DRILL CIRC P Continue reciprocate & rotate drill string while pump 30 BBL Hi-Visc wei hted swee to clean hole. F~<~~ 2~ of 4~ ~ ~ Time Logs - --_ __ -- j _ _ _ _ _ Date From To Dur S. De th E Depth Phase Code _ Subcode T COM 02/03/2007 14:15 18:00 3.75 17,834 15,495 PROD1 DRILL REAM P BROOH @ 40 -50 fUmin from 17834' - 15495'. Hole looked clean with no fluid loss. Crew Chan e 18:00 00:00 6.00 17,834 15,495 PROD1 DRILL REAM P Continue BROOH @ 40-50 ft/min from 17834' - 15495'. Hole looked clean with no fluid loss. 02/04/2007 00:00 01:45 1.75 15,495 10,844 PROD1 DRILL REAM P Continue BROOH @ 40-50 ft/min from 15495' - 10844'. Hole looked clean with no fluid loss. 01:45 04:15 2.50 10,844 10,844 PROD1 DRILL CIRC P Reciprocate & rotate drill string while pump 30 BBL Hi-Visc weighted sweep at shoe to clean hole. Observed no significant increase in cuttings when swee returned. 04:15 06:00 1.75 10,844 10,844 PROD1 RIGMN SVRG P Held PJSM with crew. Discuss saftey issues and procedure for Slip & Cut drilling line. Slip & cut drilling line. Install new crown saver block, Service Top Drive. Inspect draworks brakes & linkage. Inspect saver sub. Monitor well -static. Crew Chan e 06:00 07:45 1.75 10,844 12,075 PROD1 DRILL TRIP P Trip in hole from 10844' - 12075. Observed proper hole fill. Ran out of down wei ht with strai ht slack off. 07:45 12:00 4.25 12,075 15,971 PROD1 DRILL REAM P Wash & ream from 12075' - 15971'. Hole looked ood. 12:00 14:00 2.00 15,971 17,834 PROD1 DRILL REAM P Continue wash & ream from 15971' - 17834' TD. 14:00 16:30 2.50 17,834 17,834 PROD1 DRILL CIRC P Reciprocate & rotate drill string while pumping 30 BBL Hi Visc weighted swee . 16:30 17:15 0.75 17,834 17,834 PROD1 DRILL CIRC P Break connection. Drop 2 1/8" STainless steel ball down DP. Pump ball down @ 3 BPM - 900 PSI. Observed ball seated with 950 strokes, continue pressure to 1000 psi too en CCCV Valve. 17:15 18:00 0.75 17,834 17,834 PROD1 DRILL CIRC P Reciprocate & rotate drill string while pumping 30 BBL Hi Visc weighted sweep, with CCV valve positioned at the shoe. Crew chan e. 18:00 19:15 1.25 17,834 17,834 PROD1 DRILL CIRC P Continue reciprocate & rotate drill string while pumping 30 BBL Hi Visc weighted sweep, with CCV valve positioned at the shoe. Observed no fluid loss. 19:15 21:00 1.75 17,834 17,834 PROD1 DRILL CIRC P Break connection, drop 2 1/8" ball down DP to close CCV valve. Reciprocate & rotate drill string while pumping ball down @ 3 BPM - 350 PSI. Observed ball not seated, and valve failed to close with a total of 1800 strokes over calculated to seat. Discuss o tions with en ineer. q i k~~Ui~~" ~~ ref xrJ ~ ~ Time Los _-9-- -- __ Date From To Dur S. De th E. De th Phase Code Subcode T _ COM 02!04/2007 21:00 22:15 1.25 17,834 17,834 PROD1 DRILL CIRC T Break connection, drop second 2 1/8" ball down DP to close CCV valve. Reciprocate & rotate drill string while pumping ball down @ 3 BPM - 350 PSI. Observed ball not seated, and valve failed to close with a total of 1000 strokes over calculated to seat. Discuss options with engineer. Decision to POOH. 22:15 00:00 1.75 17,834 17,508 PROD1 DRILL TRIP T Attempt to POOH on elevators. observed well swabbing when pulling faster than 10 ft/min. Pump out of hole @ 30 -40 ft/min with no rotation observin hole takin ro er fluid. 02/05/2007 00:00 06:00 6.00 17,508 13,595 PROD1 DRILL TRIP T Continue pump out of hole @ 30 -40 ft/min with no rotation from 17508' - 13595' .Observed each time we attempted to POOH on elevators, well would swab. Hole taking 1 BBL / Stand. Total for 6 hrs = 23 BBLS over calculated fill. Crew Chan e 06:00 10:30 4.50 13,595 10,744 PROD1 DRILL TRIP T Continue pump out of hole @ 30 -40 ft/min with no rotation from 13595' - 10744'. Observed each time we attempted to POOH on elevators, well would swab. Hole taking 1 BBL / Stand. 10:30 10:45 0.25 10,744 10,744 PROD1 DRILL TRIP T Monitor well -static. Blow down Top drive & lines. 10:45 12:00 1.25 10,744 8,745 PROD1 DRILL TRIP T POOH on elevators from 10744' - 8745'. Observed hole takin ro er fill. 12:00 13:00 1.00 8,745 7,508 PROD1 DRILL TRIP T Continue POOH on elevators from 8745' - 7508'. 13:00 13:30 0.50 7,508 7,508 PROD1 DRILL PULD T Held PJSM. Discuss safety issues and breaking out CCV valve procedure. Breakout, Inspect and lay down CCV Valve. Observed all 3 balls in tool, junk in tool on to of and around the balls. 13:30 14:00 0.50 7,508 7,508 PROD1 DRILL PULD T Clean & clear floor area of all OBM. 14:00 15:00 1.00 7,508 7,508 PROD1 DRILL CIRC T Circulate bottoms up @ 320 GPMs- 2520 PSI. 15:00 17:00 2.00 7,508 11,200 PROD1 DRILL TRIP T Trip in hole from 7508' - 11200'. Fill drill string every 25 stands. Ran out of down wei ht. 17:00 18:00 1.00 11,200 12,060 PROD1 DRILL REAM T Wash & Ream back in the hole from 11200' - 12060', at 25 SPM - 710 PSI with torques @ 7-10K Fblbs. Crew Chan e 18:00 00:00 6.00 12,060 16,430 PROD1 DRILL REAM T Continue Wash & Ream back in the hole from 12060' - 16430', at 30 SPM - 850 PSI with torques @ 10 - 12K FUlbs 02!06!2007 00:00 02:30 2.50 16,430 17,834 PROD1 DRILL TRIP T Continue Wash & Ream back in the hole from 16430' - 17834', at 30 SPM - 1050 PSI with torques @ 12 - 14K FUlbs ®m ~__ ~ e®_ev 7 P~~~ ~~ of ~5 Time Logs Date From To -- Dur S Depth E,_Depth_ Phase Code Subcode_ T -- COM _ _ 02/06/2007 02:30 02:45 - 0.25 17,834 17,834 PROD1 DRILL SFTY P Held PJSM with crew, Mud engineer, and all Vac truck crew. Discuss ssfaety issues & procedure for displacing well with SFMOBM.Desi Hate S ill Cham ion 02:45 05:45 3.00 17,834 17,834 PROD1 DRILL CIRC P Displace well with SF MOBM @ 325 GPM - 3050 PSI. Reciprocate & rotate drill sring. Total of 1060 BBLs um ed. Observed no fluid loss. 05:45 06:00 0.25 17,834 17,834 PROD1 DRILL OWFF P Monitor well -static. Blow down Top Drive & lines. Crew Chan e 06:00 12:00 6.00 17,834 7,397 PROD1 DRILL TRIP P POOH on elevators from 17834' - 7397'. Obtain T & D parameters every 5 stands in casing, 10 stands in Open hole as per rig engineer. Observed hole takin ro er fill 12:00 15:30 3.50 7,397 362 PROD1 DRILL TRIP P Continue POOH on elevators from 7397' - 362. Obtain T & D parameters every 5 stands in casing, as per rig engineer. Observed hole taking proper fill and total of 52 BBLs over calculated. 15:30 17:00 1.50 362 0 PROD1 DRILL PULD P Stand back HWDP & Drill collars. Breakout & lay down BHA to MWD assembl . 17:00 18:00 1.00 0 0 PROD1 DRILL OTHR P Plug in and download MWD assembly. Clean & clear floor area. Breakout, inspect & lay down Bit while downloadin .Crew Chan e 18:00 19:00 1.00 0 0 PROD1 DRILL PULD P Continue download MWD assembly. Change out booster box as we had trouble with confidence test. 19:00 20:15 1.25 0 0 PROD1 DRILL PULD P Continue breakout & lay down remeaining BHA as epr Sperry Sun MWD & DD. SIMOPS: Rig up Little Red services. Pump 130 BBLs of freeze protect diesel down OA @ 1.5 BPM - 625 PSI. Shut in pressure = 525 PSI. 20:15 21:00 0.75 0 0 COMPZ EVALF OTHR P Clean & clear rig floor of tools and OBM. S of & RU SWS wireline crew. 21:00 21:15 0.25 0 0 COMPZ EVALFI SFTY P Held PJSM with crew, SWS & Welltech. Discuss safety issues and procedure for rigging up and running USIT & tractor on wireline. 21:15 22:30 1.25 0 0 COMPZ EVALFI RURD P Rig up SWS &Welltech. Pull tools to floor, make u same on wireline head. 22:30 00:00 1.50 0 0 COMPZ EVALFI OTHR P WLIH from surface to 2600' MD. Attempt to tractor down. Observed trouble with "power" to tools. Trouble shoot. 02/07/2007 00:00 00:30 0.50 0 0 COMPZ EVALFI OTHR T Continue trouble shoot power issues with Tractor on wireline 2600' MD. 00:30 01:00 0.50 0 0 COMPZ EVALF OTHR T WLOH from 2600'. ~_ ~ e ~e F~~~~ 2~ ~f A a Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM _____ _ 02/07/2007 01:00 02:00 1.00 0 0 COMPZ EVALFI OTHR T Breakout & lay down Tractor assembly. Perform repeated surface tests observing tool recieving good ower. Surface test cable head. 02:00 02:30 0.50 0 0 COMPZ EVALFI OTHR T Make up tools on USIT Assembly. perform repeated tests on tools while han in on wireline. Good test. 02:30 03:00 0.50 0 0 COMPZ EVALFI OTHR T WLIH to 2611' with no issues. Check power issues on Tractor & USITassembl .Good test. 03:00 06:00 3.00 0 0 COMPZ EVALFI OTHR P Continue Tractor in hole with USIT assembly from 2611' - 7500'. Crew Chan e 06:00 12:00 6.00 0 0 COMPZ EVALFI OTHR P Continue Tractor in hole with USIT assembly from 7500' - 10250'. Observed tractor woud not go any dee er. 12:00 15:45 3.75 0 0 COMPZ EVALFI OTHR P Continue with USIT log form 10250' - 3430'. WLOH. Observed cement bond ood to 6510' WLM. 15:45 16:45 1.00 0 0 COMPZ EVALFI RURD P Rig down SWS & Welltec tractor & USIT assembly. Clean & clear rig floor. Observe 5 BBL static fluid loss while wirelinin . 16:45 17:45 1.00 0 0 COMPZ CASINC RURD P Held PJSM with crew &GBR casing hands. Discuss safety issues and procedure for rigging up and running 4 1/2" slotted liner. Ri u to run liner. 17:45 18:00 0.25 0 42 COMPZ CASINC RUNL P Make up 4 1/2" shoe joint with silver bullet guide shoe. Make up torque = 2800 Ft/Ibs. Crew Chan e 18:00 00:00 6.00 42 7,676 COMPZ CASINC RUNL P Held PJSM with new crew. Discuss saftey issues and procedure for runing 4 1/2" liner. Continue run 4 1/2" slotted /blank liner assembly installing spiralgliders on each joint as planned. make up torque = 2800 FUlbs on BTC. Make up torque on torque ring joints = 4-5K. 02/08/2007 00:00 01:00 1.00 7,676 7,676 COMPZ CASIN( RUNL P Make up BOT Casing Seal bore extension with liner hanger & ZXP Packer assembly. Mix & pour PAL mix into Packer as per BOT rep. Allow solution to setup. UP WT = 122K, SO WT = 100K. ROT WT = 102K with 25 RPM's - 3500 ft/Ibs. Rig down GBR Casin runnin a ui ment. 01:00 06:00 5.00 7,676 13,380 COMPZ CASINC RUNL P Continue run 4 1/2" slotted liner on 5" Drill string. Obtain T & D parameters every 5 stands in open hole as per rig en ineer. Crew than e 06:00 11:15 5.25 13,380 17,834 COMPZ CASIN( RUNL P Continue run 4 1/2" slotted liner from 13380' - 17834'. Obtain T & D parameters as per rig engineer every 5 stands in o en hole. a ~; 4 ~ ~ C3 t ^. ';i Time Lo s - - ~, Date _ From _To Dur S, Doh E. (]eoth Phase_ Code Subcode T__ COM_ __ ~ 02/08/2007 11:15 11:30 0:25 17,834 17,830 COMPZ CASINO RUNL P Tag bottom @,17834' while rotating in hole. Pull up & position string at setting depth as per detail with Shoe 17830' MD. 11:30 12:00. 0.50 17,830 10,164 COMPZ CASIN CIRC P Break circulation, drop 1 3/4" ball down drill string, pump ball down allowing to seat. Pressure to 4000 PSI to set liner hanger & packer as per BOT rep. Note: Top of B lateral liner - 10164' MD 12:00 13:00 1.00 10,1.64 10,164 COMPZ CASINO OTHR P Rig up and pressure down annulus to test packer to 1000 PSI - 10 minutes.. Good test. Release from Liner hanger as per BOT rep. Attempt to slack off to verify top of Iliner, no slack off wei ht. 13:00 14:00 1.00 10,164 10,164 COMPZ CASIN CIRC P Circulate bottoms up @ 10 BPM - 1030 PSL Observe no fluid loss. 14:00 18:00 4.00 10,164 2,378 COMPZ CASIN( RUNL P POOH from 10164' - 2378'. Observe. hole taking proper fill. Obtain SLM on TOH. Crew Chan e 18:00 20:00 2.00 2,378 0 COMPZ CASINO RUNL P Continue POOH from 2378' -surface. Observe correct hole fill 20:00 21:00 1.00 0 0 COMPZ CASIN {?IJRD P Breakout, inspect and lay down runnin & settin tools. All tools OK: 21:00 21:30 0.50 0 0 COMPZ STK OTHR P Clean & clear floor area. Held PJSM with crew. Discuss saftey issues and procedure for picking up 42 joints of 5" HWDP and racking back in derrick for whi stock run. 21:30 23:00 1.50 0 1,300 COMPZ STK PULD P Run in hole with 42 joints of 5" HWDP. 23:00 00:00. 1.00 1,300 0 COMPZ STK PULD P POOH, rack back 5" HWDP -14 stands. Obtain SLM on TOH. 02/09/2007 00:00 01:00. 1.00 0 0 COMPZ STK OTHR P Clean & clear rig floor area of OBM. Pull 20 LoTads to rig floor. Strap & caliper same. Pull whipstock tools to ri floor.. 01:00 02:00 1.00 0 0 COMPZ STK OTHR P PJSM with Crew, Sperry Sun reps, and BOT rep. Discuss saftey issues and procedure for making up 9 5/8" whipstock assembly with MWD assembly. Continue pulling io tads to rig floor and rigging up to make up BHA. 02:00 03:15 1.25 0 0 COMPZ .STK OTHR T Pick up 1 stand. of 5" HWDP. joint came in contact with Top Drive when lowering. Lay down joint, inspect Top Drive assembl .Service To Drive 03:15 06:00 2.75 0 202 PROD2 STK PULD P Make up 9 5/8" whipstock assembly with space out pipe as per BOT rep. Make up MWDassembly. Crew Chan e 06:00 06:30 0.50 202 202 PROD2 STK PULD P Continue make up MWD assembly. Orient MWD with high side face of whi stock slide. -- ~s~4* ~'~ of ,._ Time Logs 'Date From To D~~r S Depth E Depth Phase Code Suhcode T CGM 02/09/2007 06:30. 07:15 0.75 202 202 PROD2 STK OTHR P Plug inand-upload MWD assembly. - 07:15 07:30 0.25 202 301 PROD2 STK TRIP P RIH with whipstock assembly from 202' - 301'. Perform shallow pulse test on MWD tools. Good testa 07:30 10:30 3.00 301 2,181 PROD2 STK TRIP P Trip in hole with whipstock-assembly from 301' - 2181'. Install Lo-Tads on drill pipe, 1 perstand. Observe correct dis lacement. 10:30 12:00 1.50 2,181 2,181 PROD2 STK PULD P Pull 30 more Lotads to rig floor. Drift , stra & record serial numbers. " 12:00 16`45 4.75 2,181 5,149 PROD2 STK TRIP P Continue trip in hole from 2181' - 5149'. Install Lotads on drill string, 1 per stand. Total of 50 LoTads installed. Fill drill string every 25 stands. Observe ro er dis lacement. 16:45 17:00 0.25 5,149 5,149 PROD2 STK PULD P Clean & clear rig floor area. lay down . all thread protectors, and install lift subs on racks. 17:00 18:00 1.00 5,149 6,575 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 5149' - 6575'. Crew Chan e 18:00 20:30 2.50 6,575 8,100 PROD2 STK TRIP P Contirue trip in hole from 6575' - 8100'. 20:30 21:00 0.50. 8,100 8,100 PROD2 WELCT SFTY P Held BOP drill. Held safety standown meeting with rig crew, TP's and CPAI reps. Discuss safety issues and incident on ri . 21:00 21:45 0.75 8,100 9,300 PROD2 STK TRIP P Continue trip in hole from 8100' - 9300'. 21:45 22:00 0.25 9,300 9,400 PROD2 STK OTHR P Perform MAD PASS from 9300'- 9400° DPM. pumps @ 600 GPM's - 3050 PSI. 22:00 23:00 1.00 9,400 10,100 PROD2 STK TRIP P Continue trip in hole from 9400' - 10100'. 23:00 00:00 1.00 10,100 10,050 PROD2 STK CIRC P Make Top Drive connection. Pump @ 615 GPM's - 3100 PSI to orient whipstock face at 17 Deg left of high side. UP WT = 235K, SO WT = 100K. Slack off tag top of B lat liner @ 10168' (3' low- Make change on Liner Detail Tally). Set down 25K to set: Bottom trip anchor. Pull 10K over to verify set. Slack off 40k to shear bolt. Pull to neutral position. Attempt to rotate free with 12K plus torque. Stop rotation. Window To = 10050' MD. 02/10/2007 00:00 01:00 1.00 10,050 10,050 PROD2 STK CIRC P Displace well from SF MOBM to OBM 615 GPM's - 3050 PSL 01:00 06:00 5.00 10,050 10,067 PROD2 STK MILL P Mill 8 1/2" window from 10050' - 10067 in 4.58 HRS. Crew Chan e 06:00 07:30 1.50 10,067 10,097 PROD2 STK MILL P Continue mill open hole from 10067 - 10097 in 1,33 HRS. GAuged hole to 10087 as per DD. Top. of window @ 10050'. Bottom of window 10067. e _~ ~~~e 2S of45 Time Logs - - Date From To Dur S Depth E Depth Phase Code Subccd~ T COM i 02!10/2007 07:30.09:1.5 'x_75 10,097 10,097.. PROD2 .STK CIRC P Pump 30 BBLS Hi Visc weighted sweep, while working drill string: to ensure clean wiindow area. Work window withouf rotation or pump: Looked pod. 09:15 09:30 0.25 10,097 1 Q,097 PRODZ STK OWFF P Monitor well -static. 09:30 10:00 0.50 10,097. 10,097 PROD2 STK CIRC P Pump dry job, blow down Top drive & - likes 10;00 11:15 1.25 10,097 8,737 PROD2 STK TRIP P POOH, breakout & lay down first 18 ~oints of 5" HWDP. 11:15 12:00 0.75 8,737 6,172 PROD2 STK TRIP P Continue POOH from 8737` -6172'. Observed pro er hole fill 12:00 17:00 5.00 6,172 84 PROD2 STK TRIP P POOH from 6172'- 84': Observed proper hole fill. Reposition top super slider on each stand #o enable racking back in fingers.'SIMOPS: Test choke manifold on TOH for week) BOP Test. 17:00 17:30 0.50 84 0 PROD2 STK PULD. P Breakout & lay down BHA. 17:30 18:00 0.50 0 0 PROD2 STK PULD P Plug in and download MWD. Breakout- & lay down MWD assembly. Crew Chan e 18:00 18:30 0.50 0 0 PROD2 STK PULD P Continue breakout & lay down MWD assembl 18:30 19:15 0:75 0 0 PROD2 STK PULD P Breakout & lay down mills. Gauge Upper mill to full gauge of 8 1/2". Clean & clear ri floor area. 19:15 21:00 1.75 0 0 PROD2 WELCT OTHR P Pick up 1 stand of DP and stack washer assembly. Flush stack, lay down washer. Rack back stands and ick u test ~oint. 21:00 22:45 1.75 0 0 PROD2 WELCT OTHR P BOLDS & pull wear bushing. Install test plug. Rig up BOP test equipment. Fill BOP stack & choke manifold with water. 22:45 23:00 0.25 0 0 PROD2 WELCT SFTY P Held PJSM with crew. Discuss safety issues and hazard recognition. Discuss BOP testin rocedure: 23:00 00:00 1.00 0 0 PROD2 WELCT BOPE P Test BOP's. AOGCC rep Chuck Sheve on location to witness test. 02/11/2007 00:00 02:45 2.75 0 0 PROD2 WELCT ROPE P Continue test BOP's with AOGCC rep Chuck Sheve witnessing test. test with 4", 4 1/2" & 5" test joints. Perform Accumulator test with 200 PSI increase in 36 sec, and full 3000 PSI in 3 min, 11 sec.__ 02:45 03:45 1.00 0 0 PROD2 WELCT OTHR P Rig-down all BOP#esting equipment. Pull test plug & install wear bushing. RILDS. 03:45 04:00 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with crew. Discuss saftey i ssues, hazard recognitions and procedure for making up 6 3/4" drilling BHA. 04:00 06:00. 2.00 0 0 PROD2 DRILL PULD P Make up 6 3/4" Drilling BHA as per DD &MWD re s. Crew Chan e _m __. ~ _~ _ -- ~_ P~~e ~7 of • ~ Time Logs - - -- - - - Dat~ ~rorn Tc Dur S D nth E Dew Ph3~e__ _Code Subcode T GOPn ---- - - 02/11/2007 06:00 06;30 0:50 0 0 PROD2 DRILL OTHR P .Plug in and Upload MWD assembly Observed bad connection. 06:30 07:15 0.75 0 0 PROD2 DRILL OTHR. P Upload MWD assembly. 07:15 08:00. _ 0.75 0 362 _ PROD2 DRILL PULD P Continue make up remaining BHA. 08:00 0830 0.50 362 453 PROD2 DRILL TRIP P Trip in hole 1 stand and perform shallow pulse test. Check Geo pilot sendin commands. All ood. 08:30 09:15 0.75 453 1,100. PROD2 DRILL PULD P Pick up 21 joints of 4"drill-pipe from i e shed. 09:15 12:00. _2.75 1.,100. 6,200 PROD2 DRILL TRIP P Continue trip in hole with 4" DP from derrick to 6200'. 12:00 14:45 2.75 6,200 10,046 PROD2 DRILL TRIP P Trip in hole from 6200' - 10046'. Top of window. Observed proper. dis lacement. 14:45 16:00 1.25 10,046 10,046 PROD2 RIGMN ' SVRG P Held PJSM. Discuss Hazards & safety issues. Slip & cut drilling line, adjust brakes on draw works & ins ect linka e. 16:00 18:00 2.00 1-0,046 10,046 PROD2 RIGMN SVRG P Change out top Drive saver sub. Service To Drive. Crew Chan e 18:00 00:00. 6.00 10,046 10,575 PROD2 .DRILL DDRL P Observe no issues going through window area. Directional drill in the D lateral from 1009T -10575'. ADT = 3.11 HRS. ECD - 9.70 PPG 02/12/2007 00:00 06:00 6.00 10,575 11,232 PROD2 DRILL DDRL P Directional drill in the D lateral from 10575' - 11232'. ADT = 3.58 HRS. ECD - 10.1 PPG Crew Chan e 06:00 12:00 6.00 11,232 12,102 PROD2 DRILL DDRL P Directional drill in the D lateral from 11232' - 12102'. ADT = 4.04 HRS. ECD -10.2 PPG 12:00 18:00 6.00 12,102 13,014 PROD2 DRILL DDRL P Directional drill in the D lateral from 12102' - 13014'. ADT = 3.79 HRS. ECD - 10.32 PPG Crew chan e 18:00 21:00 3.00 13,014 13,298 PROD2 DRILL DDRL P Directional drill in the D lateral from 13014' - 13298'. ADT = 1.26 HRS. ECD - 10.16 PPG. Observed geo pilot failure. Attempt to trouble shoot. Unsuccessful. 21:00 23:30 2.50 13,298 12,719 PROD2 DRILL REAM. T Pump 30 BBL Hi_Visc sweep while BROOH @ 10 ft./min until sweep returned. Observed no signifcaht increase in cutting upon sweep returnin 23:30 00:00 0.50 12,719 12,125 PROD2 DRILL TRIP T POOH on elevators#rom 12719' - 12125'. Observe clean hole and no swabbin issues. Mix D 'ob. 02/13/2007 00:00 00:15 0.25 12,125 12,125 PROD2 DRILL CIRC T Pump 25 BBt Dry Job. Blow down Top Drive & lines. Monitor well -static. 00:15 07:00 6.75 12,125 360 PROD2 DRILL TRIP T POOH on elevators from 12125' - 2423'. No issues with BHA going through window area. Observed proper hole fill. Open hole looked good with no overpull or swab issues. Layed down Centurian circ valve to pipe shed... ~a~~~2~ -tif ~ -,:~1,~ cS~~cw,y ~.v'7 ~l• ~'~! ~11~v~/5'1 • Halliburton Company Survey Report i Company: ConoCOPhillips Alaska Inc. Dafe: 3!21/2007 Time: 14:45:44 Parc: I Field: Kuparuk River Unit Co-ordinate(NE}Refcrcncc:- Well: 1J-180,. Tr ue North Site: Kuparuk 1'J Pad Vertical(TVD)Re fercncc 1J-180: 121'[4 Wrll: 1J-180 Section (VS)Refer racc: Well (0.0(7N,O.OOE,180.OOAzi) We11{~ath: 1 J-180 Su rvey Cakui~tib n llGhud: Minimum Curva ture Db: Oracle __ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 I Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-180 Slot Name: Well Position: +N/-S -499.40 ft Northing: 5945420.12 ft ' Latitude: 70 15 41.346 N ~ +E/-W -23.60 ft Easting : 558770.25 ft ~ Longitude: 149 31 29.693 W Position Uncertainty: 0.00 ft Wellpath: 1J-180 Drilled From: 1J-180P61 500292332900 Tie-on Depth: 2772.58 ft Current Datum: 1 J-180: Height 121.40 ft Above System Datum: Mean Sea Level Magnetic Data: 1/3/2007 Declination: 23.67 deg Field Strength: 57616 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 40.40 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 3/21/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 80.00 470.00 1J-180PB1 Gyros (80.00-470.00) CB-GYRO-SS Camera based gyro single shot ~ 516.32 2772.58 1J-180P61 (516.32-2867.70) (2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 2790.00 17795.20 1 J-180 (2790.00-17795.20) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey !lll Inc! .lLilll TL'D Sys TVD N/S E/W llapN ~IapE Toot ft deg deg ft ft ft ft ft" ft 40.40 0.00 0.00 40.40 -81.00 0.00 0.00 5945420.12 558770.25 TIE LINE 80.00 0.25 204.54 80.00 -41.40 -0.08 -0.04 5945420.04 558770.21 CB-GYRO-SS 120.00 0.31 93.19 120.00 -1.40 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 195.00 0.31 275.44 195.00 73.60 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 273.00 1.70 207.09 272.99 151.59 -1.17 -0.70 5945418.95 558769.56 CB-GYRO-SS 370.00 4.93 214.60 369.81 248.41 -5.88 -3.72 5945414.21 558766.57 CB-GYRO-SS 470.00 8.58 215.07 469.10 347.70 -15.52 -10.45 5945404.52 558759.92 CB-GYRO-SS 516.32 10.63 215.05 514.77 393.37 -21.85 -14.89 5945398.16 558755.53 MWD+IFR-AK-CAZ-SC 585.68 13.33 214.06 582.61 461.21 -33.71 -23.04 5945386.23 558747.47 MWD+IFR-AK-CAZ-SC 681.16 17.45 210.75 674.65 553.25 -55.15 -36.53 5945364.70 558734.15 MWD+IFR-AK-CAZ-SC 775.68 20.50 207.94 764.03 642.63 -81.95 -51.54 5945337.77 558719.36 MWD+IFR-AK-CAZ-SC 872.00 23.89 207.47 853.20 731.80 -114.17 -68.44 5945305.43 558702.71 MWD+IFR-AK-CAZ-SC 964.80 27.53 210.33 936.80 815.40 -149.37 -87.95 5945270.09 558683.48 MWD+IFR-AK-CAZ-SC 1060.69 31.40 211.51 1020.27 898.87 -189.81 -112.21 5945229.46 558659.54 MWD+IFR-AK-CAZ-SC 1156.07 33.60 212.52 1100.71 979.31 -233.25 -139.38 5945185.81 558632.71 MWD+IFR-AK-CAZ-SC 1249.41 36.08 211.06 1177.31 1055.91 -278.58 -167.45 5945140.27 558604.99 MWD+IFR-AK-CAZ-SC 1345.29 36.19 210.02 1254.75 1133.35 -327.27 -196.18 5945091.36 558576.65 MWD+IFR-AK-CAZ-SC ~ 1440.67 37.63 209.99 1331,01 1209.61 -376.87 -224.82 5945041.54 558548.39 MWD+IFR-AK-CAZ-SC 1536.41 39.59 209.64 1405.82 1284.42 -428.71 -254.52 5944989.48 558519.10 MWD+IFR-AK-CAZ-SC 1631.01 42.74 208.47 1477.03 1355.63 -483.14 -284.74 5944934.82 558489.31 MWD+IFR-AK-CAZ-SC 1725.56 43.94 205.13 1545.80 1424.40 -541.06 -313.97 5944876.68 558460.54 MWD+IFR-AK-CAZ-SC 1821.24 46.86 205.17 1612,98 1491.58 -602.72 -342.92 5944814.80 558432.07 MWD+IFR-AK-CAZ-SC 1915.82 51.32 206.09 1674.90 1553.50 -667.14 -373.85 5944750.15 558401.65 MWD+IFR-AK-CAZ-SC ~ 2010.35 51.48 206.20 1733.87 1612.47 -733.45 -406.40 5944683.59 558369.62 MWD+IFR-AK-CAZ-SC 2106.00 56.34 203.99 1790.21 1668.81 -803.44 -439.13 5944613.35 558337.44 MWD+IFR-AK-CAZ-SC 2200.83 59.85 203.96 1840.32 1718.92 -876.99 -471.84 5944539.56 558305.32 MWD+IFR-AK-CAZ-SC 2295.95 63.63 203.71 1885.35 1763.95 -953.61 -505.69 5944462.68 558272.07 MWD+IFR-AK-CAZ-SC 2391.44 68.25 203.43 1924.27 1802.87 -1033.51 -540.54 5944382.52 558237.85 MWD+IFR-AK-CAZ-SC i Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc Field: Kuparuk River Unit ', Site: Kuparuk 1J Pad WeIL• 1J-180 Wellpath: 1J-180 X11 R'PM' \IU Incl ~tim ft dey deg ____ 2486.93 72.33 203.18 2582.57. 76.51 202.25 2675.82 77.78 199.58 2772.58 79.53 197.43 2790.00 80.44 197.37 2864.94 79.21 197.21 2959.69 80.46 197.21 ~ 3056.41 80.12 198.03 3150.25 80.58 197.20 3244.96 78.36 197.90 3341.20 80.54 197.42 3436.13 80.03 196.90 3531.52 79.12 198.29 ~ 3625.00 81.41 198.40 3719.78 80.65 198.59 3815.77 80.33 198.62 3910.90 82.27 199.47 3968.17 83.70 199.59 4026.70 83.32 199.21 4121.44 80.34 198.42 4215.52 78.26 198.74 4311.51 78.90 199.68 4405.70 79.98 200.54 4500.70 78.33 201.08 4595.30 79.08 200.19 4690.23 78.47 200.08 4785.43 77.84 201.41 ~~ 4883.48 79.16 201.97 4983.15 80.26 201.16 5079.43 79.96 200.85 5174.94 79.72 199.15 5268.30 80.20 197.99 5356.51 81.90 196.57 5451.25 80.85 195.38 5546.69 81.97 196.31 5640.42 82.66 196.96 5735.62 79.48 198.15 5830.71 78.71 199.37 5926.82 80.22 200.87 ~ 6019.81 77.14 200.71 6118.91 78.19 200.34 6213.05 80.66 199.26 6308.88 76.93 199.73 6404.03 79.51 199.07 6499.17 79.20 199.93 6594.06 81.53 199.62 6689.72 82:97 197.25 6783.16 82.16 195.42 6879.42 80.60 195.62 6974.71 79.65 195.84 7069.27 80.22 196.54 7164.01 78.70 196.70 Date: 3/2112007 Time: 14:45.44 f'sgc: 2 Co-ordinate(NE}Reference: Well: 1J-180, True North , Vertical (T'VD) Reference: 1 J-180:.121.4 Section (~'S) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey Calculation Methnd: tvtinimum Curvature Dh: Oracle l ~ D Sys TVD N%ti ft ft ft 1956.46 1835.06 -1116.06 1982.15 1860.75 -1201.02 2002.90 1881.50 -1285.94 2021.93 1900.53 -1375.89 2024.96 1903.56 -1392.26 2038.20 1916.80 -1462.69 2054.92 1933.52 -1551.77 2071.23 1949.83 -1642.63 2086.96 1965.56 -1730.81 2104.27 1982.87 -1819.58 2121.89 2000.49 -1909.73 2137.91 2016.51 -1999.14 2155.17 2033.77 -2088.56 2170.98 2049.58 -2176.00 2185.76 2064.36 -2264.79 2201.61 2080.21 -2354.51 2216.00 2094.60 -2443.40 2223.00 2101.60 -2496.96 2229.61 2108.21 -2551.82 2243.08 2121.68 -2640.57 2260.54 2139.14 -2728.19 2279.55 2158.15 -2817.04 2296.81 2175.41 -2903.99 2314.68 2193.28 -2991.20 2333.21 2211.81 -3078.02 2351.69 2230.29 -3165.44 2371.23 2249.83 -3252.57 2390.78 2269.38 -3341.85 2408.59 2287.19 -3433.05 2425.12 2303.72 -3521.59 2441.97 2320.57 -3609.93 2458.25 2336.85 -3697.08 2471.97 2350.57 -3780.27 2486.18 2364.78 -3870.32 2500.44 2379.04 -3961.10 2512.97 2391.57 -4050.10 2527.75 2406.35 -4139.76 2545.74 2424.34 -4228.17 2563.31 2441.91 -4316.88 2581.56 2460.16 -4402.12 2602.73 2481.33 -4492.78 2620.01 2498.61 -4579.85 2638.62 2517.22 -4668.45 2658.05 2536.65 -4756.30 2675.62 2554.22 -4844.43 2691.50 2570.10 -4932.46 2704.40 2583.00 -5022.38 2716.50 2595.10 -5111.29 2730.92 2609.52 -5202.99 2747.27 2625.87 -5293.35 2763.79 2642.39 -5382.76 2781.12 2659.72 -5472.01 E/W 111apN ft ft -576.09 5944299.71 -611.65 5944214.48 -644.10 5944129.32 -674.20 5944039.14 -679.33 5944022.73 -701.25 5943952.14 -728.85 5943862.85 -757.70 5943771.78 -785.70 5943683.40 -813.77 5943594.42 -842.47 5943504.05 -870.08 5943414.45 -898.43 5943324.81 -927.43 5943237.15 -957.13 5943148.15 -987.33 5943058.20 -1018.02 5942969.09 -1037.02 5942915.38 -1056.34 5942860.38 -1086.58 5942771.40 -1116.03 5942683.56 -1146.99 5942594.48 -1178.83 5942507.30 -1211.97 5942419.84 -1244.66 5942332.78 -1276.72 5942245.12 -1309.72 5942157.74 -1345.23 5942068.20 -1381.27 5941976.73 -1415.27 5941887.93 -1447.42 5941799.35 -1476.70 5941711.99 -1502.58 5941628.60 -1528.36 5941538.36 -1554.12 5941447.39 -1580.72 5941358.19 -1609.07 5941268.33 -1639.10 5941179.70 -1671.60 5941090.74 -1703.97 5941005.26 -1737.91 5940914.34 -1769.25 5940827.05 -1800.61 5940738.21 -1831.55 5940650.13 -1862.76 5940561.76 -1894.41 5940473.50 -1924.37 5940383.36 -1950.43 5940294.26 -1975.90 5940202.37 -2001.35 5940111.82 -2027.31 5940022.22 -2053.95 5939932.78 __ Map F: _ _. Tool ft 558202.94 MWD+IFR-AK-CAZ-SC 558168.05 MWD+IFR-AK-CAZ-SC 558136.27 MWD+IFR-AK-CAZ-SC 558106.87 MWD+IFR-AK-CAZ-SC 558101.87 MWD+IFR-AK-CAZ-SC 558080.50 MWD+IFR-AK-CAZ-SC 558053.61 MWD+IFR-AK-CAZ-SC 558025.46 MWD+IFR-AK-CAZ-SC 557998.16 MWD+IFR-AK-CAZ-SC 557970.78 MWD+IFR-AK-CAZ-SC 557942.79 MWD+IFR-AK-CAZ-SC 557915.88 MWD+IFR-AK-CAZ-SC 557888.23 MWD+IFR-AK-CAZ-SC 557859.92 MWD+IFR-AK-CAZ-SC 557830.92 MWD+IFR-AK-CAZ-SC 557801.42 MWD+IFR-AK-CAZ-SC 557771.43 MWD+IFR-AK-CAZ-SC 557752.85 MWD+IFR-AK-CAZ-SC 557733.96 MWD+IFR-AK-CAZ-SC 557704.41 MWD+IFR-AK-CAZ-SC 557675.65 MWD+IFR-AK-CAZ-SC 557645.39 MWD+IFR-AK-CAZ-SC 557614.23 MWD+IFR-AK-CAZ-SC 557581.77 MWD+IFR-AK-CAZ-SC 557549.76 MWD+IFR-AK-CAZ-SC 557518.40 MWD+IFR-AK-CAZ-SC 557486.08 MWD+IFR-AK-CAZ-SC 557451.27 MWD+IFR-AK-CAZ-SC 557415.94 MWD+IFR-AK-CAZ-SC 557382.64 MWD+IFR-AK-CAZ-SC 557351.18 MWD+IFR-AK-CAZ-SC 557322.59 MWD+IFR-AK-CAZ-SC 557297.36 MWD+IFR-AK-CAZ-SC 557272.29 MWD+IFR-AK-CAZ-SC 557247.24 MWD+IFR-AK-CAZ-SC 557221.34 MWD+IFR-AK-CAZ-SC 557193.69 MWD+IFR-AK-CAZ-SC 557164.35 MWD+IFR-AK-CAZ-SC 557132.55 MWD+IFR-AK-CAZ-SC 557100.85 MWD+IFR-AK-CAZ-SC 557067.62 MWD+IFR-AK-CA2-SC 557036.97 MWD+IFR-AK-CAZ-SC 557006.30 MWD+IFR-AK-CAZ-SC 556976.05 MWD+IFR-AK-CAZ-SC 556945.53 MWD+IFR-AK-CAZ-SC 556914.58 MWD+IFR-AK-CAZ-SC 556885.31 MWD+IFR-AK-CAZ-SC 556859.95 MWD+IFR-AK-CAZ-SC 556835.21 MWD+IFR-AK-CAZ-SC 556810.46 MWD+IFR-AK-CAZ-SC 556785.21 MWD+IFR-AK-CAZ-SC 556759.27 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit ti,tc: Kuparuk 1J Pad Well: 1J-180 Wellpath: 1 J-180 Cnrrev tVID In~i iim - I ~ D ft deg deg ft 7259.22 81.71 197.49 2797.32 7353.88 81.14 197.53 2811.43 7447.35 81.97 198.10 2825.16 7542.43 80.33 197.62 2839.79 7637.54 79.78 197.62 2856.21 7732.51 80.02 197.62 2872.87 7827.90 78.16 197.33 2890.92 7923.25 78.66 196.36 2910.08 8018.36 78.51 197.52 2928.90 8113.72 79.40 198.56 2947.17 8208.78 80.66 198.96 2963.63 8301.64 81.46 199.56 2978.06 8398.12 81.10 200.50 2992.68 8491.81 79.59 200.91 3008.40 8588.99 79.42 201.18 3026.10 8682.68 79.71 201.17 3043.07 8776.52 80.10 201.56 3059.52 8874.12 79.33 201.13 3076.94 8941.46 78.33 201.56 3089.99 9040.32 76.67 202.18 3111.38 9135.52 72.02 202.95 3137.07 9229.84 73.64 203.11 3164.91 9326.06 76.87 201.55 3189.40 9419.65 77.18 201.55 3210.41 9514.40 79.05 202.71 3229.92 9608.12. 82.04 200.40 3245.32 9706.28 82.09 197.39 3258.87 9801.91 83.93 193.96 3270.52 9896.65 84.59 190.13 3279.99 9991.73 82.60 186.83 3290.60 10087.32 82.42 183.81 3303.07 10182.64 82.58 183.49 3315.51 10278.50 83.76 182.68 3326.91 10371.85 83.00 182.76 3337.67 10466.87 81.98 182.15 3350.09 10563.34 84.66 182.68 3361.31 10658.75 88.15 181.05 3367.29 10753.72 86.57 182.03 3371.67 10777.61 86.63 180.82 3373.08 10893.67 85.01 181.67 3381.54 10989.22 88.29 182.88 3387.13 11085.15 92.00 182.77 3386.88 11179.55 92.12 181.79 3383.49 11272.99 87.30 174.41 3383.96 11369.36 88.41 176.73 3387.57 11464.31 90.70 177.99 3388.31 11559.33 89.28 179.81 3388.32 11654.01 86.68 177.96 3391.66 11749.65 91.56 179.37 3393.13 11844.31 92.12 180.27 3390.09 11939.97 91.19 180.26 3387.33 12034.11 90.63 179.23 3385.83 12129.22 90.39 176.81 3384.99 _- Uatc 3/21!2007 lime: 14:45:44 Pay;c: 3 Co-ordinate(NE)Referenee: Well: 1J-180, True North Vertical (TVD)Referencc: 1J=180:121.4 Section (V'S) Reference: We11 (O.OON,O.OOE.18D.OOAzi) Sun~ey Calculation bicthod: Minimum Curvature Db: Oracle ties TF D N/S ft ft' ----- 2675.92 -5561.67 2690.03 -5650.94 2703.76 -5738.96 2718.39 -5828.38 2734.81 -5917.66 2751.47 -6006.77 2769.52 -6096.11 2788.68 -6185.51 2807.50 -6274.69 2825.77 -6363.68 2842.23 -6452.33 2856.66 -6538.92 2871.28 -6628.52 2887.00 -6714.92 2904.70 -6804.10 2921.67 -6890.02 2938.12 -6976.05 2955.54 -7065.50 2968.59 -7127.03 2989.98 -7216.60 3015.67 -7301.23 3043.51 -7384.16 3068.00 -7470.22 3089.01 -7555.04 3108.52 -7640.93 3123.92 -7726.89 3137.47 -7818.87 3149.12 -7910.24 3158.59 -8002.41 3169.20 -8095.84 3181.67 -8190.20 3194.11 -8284.51 3205.51 -8379.55 3216.27 -8472.17 3228.69 -8566.29 3239.91 -8662.01 3245.89 -8757.17 3250.27 -8852.00 3251.68 -8875.84 3260.14 -8991.56 3265.73 -9086.85 3265.48 -9182.65 3262.09 -9276.91 3262.56 -9370.21 3266.17 -9466.21 3266.91 -9561.05 3266.92 -9656.05 3270.26 -9750.64 3271.73 -9846.21 3268.69 -9940.82 3265.93 -10036.44 3264.43 -10130.56 3263.59 -10225.61 EIW MapN ft ft -2081.53 5939842.91 -2109.69 5939753.43 -2137.98 5939665.20 -2166.79 5939575.57 -2195.15 5939486.08 -2223.45 5939396.76 -2251.57 5939307.21 -2278.64 5939217.61 -2305.80 5939128.23 -2334.79 5939039.02 -2364.90 5938950.15 -2395.16 5938863.33 -2427.82 5938773.49 -2460.47 5938686.85 -2494.79 5938597.42 -2528.07 5938511.25 -2561.73 5938424.96 -2596.68 5938335.25 -2620.73 5938273.54 -2656.68 5938183.70 -2691.84 5938098.81 -2727.09 5938015.62 -2762.43 5937929.29 -2795.93 5937844.21 -2830.86 5937758.07 -2864.81 5937671.85 -2896.29 5937579.64 -2921.92 5937488.08 -2941.59 5937395.77 -2955.52 5937302.24 -2964.31 5937207.82 -2970.33 5937113.48 -2975.45 5937018.41 -2979.85 5936925.76 -2983.88 5936831.63 -2987.92 5936735.89 -2991.02 5936640.72 -2993.57 5936545.88 -2994.16 5936522.04 -2996.67 5936406.32 -3000.46 5936311.00 -3005.19 5936215.18 -3008.94 5936120.90 -3005.85 5936027.64 -2998.41 5935931.70 -2994.04 5935836.91 -2992.21 5935741.94 -2990.37 5935647.38 -2988.15 5935551.84 -2987.85 5935457.24 -2988.29 5935361.63 -2987.87 5935267.52 -2984.59 5935172.52 MapE -- Tool ft _ 556732.39 _- - MWD+IFR-AK-CAZ-SC 556704.93 MWD+IFR-AK-CAZ-SC 556677.33 MWD+IFR-AK-CAZ-SC 556649.22 MWD+IFR-AK-CAZ-SC 556621.56 MWD+IFR-AK-CAZ-SC 556593.96 MWD+IFR-AK-CAZ-SC 556566.53 MWD+IFR-AK-CAZ-SC 556540.17 MWD+IFR-AK-CAZ-SC 556513.71 MWD+IFR-AK-CAZ-SC 556485.42 MWD+IFR-AK-CAZ-SC 556456.00 MWD+IFR-AK-CAZ-SC 556426.43 MWD+IFR-AK-CAZ-SC 556394.47 MWD+IFR-AK-CAZ-SC 556362.49 MWD+IFR-AK-CAZ-SC 556328.88 MWD+IFR-AK-CAZ-SC 556296.27 MWD+IFR-AK-CAZ-SC 556263.29 MWD+IFR-AK-CAZ-SC 556229.04 MWD+IFR-AK-CAZ-SC 556205.47 MWD+IFR-AK-CAZ-SC 556170.23 MWD+IFR-AK-CAZ-SC 556135.73 MWD+IFR-AK-CAZ-SC 556101.13 MWD+IFR-AK-CAZ-SC 556066.47 MWD+IFR-AK-CAZ-SC 556033.63 MWD+IFR-AK-CAZ-SC 555999.38 MWD+IFR-AK-CAZ-SC 555966.11 MWD+IFR-AK-CAZ-SC 555935.35 MWD+IFR-AK-CAZ-SC 555910.43 MWD+IFR-AK-CAZ-SC 555891.49 MWD+IFR-AK-CAZ-SC 555878.28 MWD+IFR-AK-CAZ-SC 555870.23 MWD+IFR-AK-CAZ-SC 555864.95 MWD+IFR-AK-CAZ-SC 555860.57 MWD+IFR-AK-CAZ-SC 555856.90 MWD+IFR-AK-CAZ-SC 555853.59 MWD+IFR-AK-CAZ-SC 555850.30 MWD+IFR-AK-CAZ-SC 555847.95 MWD+IFR-AK-CAZ-SC 555846.14 MWD+IFR-AK-CAZ-SC 555845.74 MWD+IFR-AK-CAZ-SC 555844.13 MWD+IFR-AK-CAZ-SC 555841.08 MWD+IFR-AK-CAZ-SC 555837.10 MWD+IFR-AK-CAZ-SC 555834.09 MWD+IFR-AK-CAZ-SC 555837.91 MWD+IFR-AK-CAZ-SC 555846.09 MWD+IFR-AK-CAZ-SC 555851.20 MWD+IFR-AK-CAZ-SC 555853.77 MWD+IFR-AK-CAZ-SC 555856.35 MWD+IFR-AK-CAZ-SC 555859.32 MWD+IFR-AK-CAZ-SC 555860.36 MWD+IFR-AK-CAZ-SC 555860.66 MWD+IFR-AK-CAZ-SC 555861.81 MWD+IFR-AK-CAZ-SC 555865.84 MWD+IFR-AK-CAZ-SC L~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1J Pad Weli: 1 J-180 WeUpath: 1 J-180 Surrev MD Iucl Azim TVD ft deg deg ft -_ _ ____ 12225.14 91.13 177.78 3383.71 12320.08 90.51 176.10 3382.35 12415.32 89.83 176.78 3382.07 12510.61 90.39 178.10 3381.89 12604.99 88.04 176.88 3383.18 12699.38 89.03 178.42 3385.60 12795.97 88.97 178.78 3387.28 12890.51 92.24 181.21 3386.28 12984.96 92.05 182.19 3382.75 13080.31 93.17 181.95 3378.41 13175.49 91.62 179.86 3374.43 13270.72 90.94 178.54 3372.30 13365.40 90.20 180.65 3371.36 13460.04 90.57 178.74 3370.72 13555.28 90.82 178.20 3369.57 13650.41 90.26 178.24 3368.67 13745.55 90.26 178.39 3368.24 13840.74 90.26 178.07 3367.81 13934.37 90.26 178.08 3367.38 14030.38 90.51 178.42 3366.74 14124.88 89.77 178.06 3366.51 14220.38 89.59 178.91 3367.04 14312.41 89.65 177.83 3367.65 14408.48 91.32 178.36 3366.84 14504.13 92.12 182.10 3363.96 14599.28 92.36 184.77 3360.25 14694.64 93.60 182.82 3355.29 14789.80 90.88 181.28 3351.57 14884.66 90.70 183.05 3350.26 14979.14 90.26 185.08 3349.47 15075.38 89.77 181.54 3349.44 15169.47 88.60 180.41 3350.78 15265.22 87.36 174.99 3354.16 15359.65 88.85 176.32 3357.28 15454.54 88.97 174.83 3359.09 15549.81 92.00 177.02 3358.28 15645.31 91.13 178.09 3355.67 15740.49 91.13 178.29 3353.80 15835.67 90.51 179.78 3352.43 15930.67 90.02 179.70 3351.99 16025.56 90.02 181.73 3351.96 16120.93 90.88 182.92 3351.21 16215.31 90.88 180.04 3349.76 16311.20 90.51 178.44 3348.60 16406.35 92.18 178.62 3346.37 16501.70 90.45 180.43 3344.18 16595.53 88.91 180.09 3344.70 16690.10 89.09 179.07 3346.35 16786.77 88.85 178.77 3348.09 16881.97 89.03 180.32 3349.85 16977.17 89.83 178.51 3350.80 17072.48 89.46 178.65 3351.39 Date: 3/21/2007 Time: 14:45:44 Page: -t Co-ordinate(,NE) Reference; Well: 1J-180, True North Vertical ('TVf~) Rcfcrcncr. 1J-180: 121.4 ticctiun l~S) Reference: Well (O.OON,O.OOE,180.OOAzi) Sung (alc~ulation Method: ivlinimum Curvature 11h: Oracle Six"IT'D N/S ft ft 3262.31 -10321.41 3260.95 -10416.20 3260.67 -10511.25 3260.49 -10606.45 3261.78 -10700.72 3264.20 -10794.99 3265.88 -10891.54 3264.88 -10986.06 3261.35 -11080.40 3257.01 -11175.58 3253.03 -11270.66 3250.90 -11365.86 3249.96 -11460.52 3249.32 -11555.15 3248.17 -11650.35 3247.27 -11745.43 3246.84 -11840.53 3246.41 -11935.67 3245.98 -12029.25 3245.34 -12125.21 3245.11 -12219.67 3245.64 -12315.13 3246.25 -12407.12 3245.44 -12503.13 3242.56 -12598.72 3238.85 -12693.62 3233.89 -12788.63 3230.17 -12883.65 3228.86 -12978.43 3228.07 -13072.66 3228.04 -13168.72 3229.38 -13262.79 3232.76 -13358.36 3235.88 -13452.47 3237.69 -13547.05 3236.88 -13642.06 3234.27 -13737.44 3232.40 -13832.55 3231.03 -13927.70 3230.59 -14022.70 3230.56 -14117.58 3229.81 -14212.87 3228.36 -14307.19 3227.20 -14403.06 3224.97 -14498.15 3222.78 -14593.47 3223.30 -14687.29 3224.95 -14781.84 3226.69 -14878.48 3228.45 -14973.66 3229.40 -15068.84 3229.99 -15164.12 E/V1' ft -2980.06 -2974.99 -2969.08 -2964.82 -2960.69 -2956.82 -2954.46 -2954.45 -2957.25 -2960.70 -2962.20 -2960.87 -2960.20 -2959.69 -2957.15 -2954.20 -2951.40 -2948.46 -2945.31 -2942.38 -2939.48 -2936.95 -2934.34 -2931.14 -2931.53 -2937.22 -2943.53 -2946.93 -2950.51 -2957.21 -2962.76 -2964.36 -2960.53 -2953.38 -2946.06 -2939.29 -2935.22 -2932.21 -2930.61 -2930.18 -2931.36 -2935.23 -2937.67 -2936.39 -2933.95 -2933.16 -2933.59 -2932.90 -2931.07 -2930.32 -2929.35 -2926.99 b[apN ft 5935076.76 5934982.02 5934887.03 5934791.88 5934697.65 5934603.42 5934506.90 5934412.40 5934318.05 5934222.84 5934127.77 5934032.60 5933937.95 5933843.33 5933748.16 5933653.12 5933558.06 5933462.95 5933369.41 5933273.48 5933179.06 5933083.63 5932991.67 5932895.70 5932800.12 5932705.19 5932610.14 5932515.11 5932420.31 5932326.04 5932229.94 5932135.88 5932040.34 5931946.31 5931851.79 5931756.85 5931661.51 5931566.44 5931471.31 5931376.32 5931281.45 5931186.15 5931091.81 5930995.96 5930900.90 5930805.61 5930711.79 5930617.26 5930520.65 5930425.49 5930330.32 5930235.07 MapE Tool ft __- - -_ __ 555871.11 MWD+IFR-AK-CAZ-SC 555876.92 MWD+IFR-AK-CAZ-SC 555883.57 MWD+IFR-AK-CAZ-SC 555888.57 MWD+IFR-AK-CAZ-SC 555893.44 MWD+IFR-AK-CAZ-SC 555898.04 MWD+IFR-AK-CAZ-SC 555901.16 MWD+IFR-AK-CAZ-SC 555901.90 MWD+IFR-AK-CAZ-SC 555899.84 MWD+IFR-AK-CAZ-SC 555897.14 MWD+IFR-AK-CAZ-SC 555896.38 MWD+IFR-AK-CAZ-SC 555898.46 MWD+IFR-AK-CAZ-SC 555899.86 MWD+IFR-AK-CAZ-SC 555901.11 MWD+IFR-AK-CAZ-SC 555904.39 MWD+IFR-AK-CAZ-SC 555908.09 MWD+IFR-AK-CAZ-SC 555911.63 MWD+IFR-AK-CAZ-SC 555915.31 MWD+IFR-AK-CAZ-SC 555919.18 MWD+IFR-AK-CAZ-SC 555922.86 MWD+IFR-AK-CAZ-SC 555926.50 MWD+IFR-AK-CAZ-SC 555929.77 MWD+IFR-AK-CAZ-SC 555933.11 MWD+IFR-AK-CAZ-SC 555937.05 MWD+IFR-AK-CAZ-SC 555937.41 MWD+IFR-AK-CAZ-SC 555932.46 MWD+IFR-AK-CAZ-SC 555926.90 MWD+IFR-AK-CAZ-SC 555924.24 MWD+IFR-AK-CAZ-SC 555921.40 MWD+IFR-AK-CAZ-SC 555915.44 MWD+IFR-AK-CAZ-SC 555910.63 MWD+IFR-AK-CAZ-SC 555909.76 MWD+IFR-AK-CAZ-SC 555914.35 MWD+IFR-AK-CAZ-SC 555922.23 MWD+IFR-AK-CAZ-SC 555930.29 MWD+IFR-AK-CAZ-SC 555937.80 MWD+IFR-AK-CAZ-SC 555942.61 MWD+IFR-AK-CAZ-SC 555946.36 MWD+IFR-AK-CAZ-SC 555948.70 MWD+IFR-AK-CAZ-SC 555949.88 MWD+IFR-AK-CAZ-SC 555949.43 MWD+IFR-AK-CAZ-SC 555946.31 MWD+IFR-AK-CAZ-SC 555944.61 MWD+fFR-AK-CAZ-SC 555946.63 MWD+IFR-AK-CAZ-SC 555949.81 MWD+IFR-AK-CAZ-SC 555951.34 MWD+IFR-AK-CAZ-SC 555951.65 MWD+IFR-AK-CAZ-SC 555953.08 MWD+IFR-AK-CAZ-SC 555955.66 MWD+IFR-AK-CAZ-SC 555957.16 MWD+IFR-AK-CAZ-SC 555958.87 MWD+IFR-AK-CAZ-SC 555961.98 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Cnmpan~~: __ ConocoPhillips Alaska Enc. Ficld: Kuparok River Unit Site: Kupa:uk 1J Pad Well: 1J-180 N'ellpatlr. , 7J-180 ' tiu rve~ Date: 3!21!2007 T'imc: 14:45:44 Page: _5 Co-ordinate(NE) Reference: WeIL' 1J-180, True North Vertical (TVD) Rcfennce: 1 J-180: 121.4 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey CalculatiorrMethod: Minimum Curvature llh: Oracle i1D Inc! Azim TVD ties TVD N/S ft deg deg ft ft ft 17167.44 89.96 178.39 3351.87 3230.47 -15259.05 17262.56 89.22 179.23 3352.55 3231.15 -15354.15 17356.09 89.83 178.30 3353.32 3231.92 -15447.65 i 17452.32 89.71 178.47 3353.71 3232.31 -15543.84 i 17547.45 91.01 178.65 3353.11 3231.71 -15638.94 17642.11 89.89 177.84 3352.37 3230.97 -15733.55 17737.13 90.57 178.25 3351.99 3230.59 -15828.51 17795.20 90.76 177.72 3351.31 3229.91 -15886.54 17834.00 90.76 177.72 3350.80 ~ 3229.40 -15925.31 E/R' 11apN MapF. __ Tool ft ft ft -2924.53 -- 5930140.18 - 555965.17 - _ _ MWD+IFR-AK-CAZ-SC -2922.56 5930045.11 555967.89 MWD+IFR-AK-CAZ-SC -2920.54 5929951.63 555970.63 MWD+IFR-AK-CAZ-SC -2917.83 5929855.48 555974.09 MWD+IFR-AK-CAZ-SC -2915.44 5929760.41 555977.23 MWD+IFR-AK-CAZ-SC -2912.54 5929665.84 555980.86 MWD+IFR-AK-CAZ-SC -2909.30 5929570.91 555984.84 MWD+IFR-AK-CAZ-SC -2907.26 5929512.90 555987.34 MWD+IFR-AK-CAZ-SC -2905.71 5929474.15 ~ 555989.18 •PROJECTED to TD • Halliburton Company Survey Report - __ Company: ConocoPhillips Alaska Inc . Date: 3/21/2007 'l'ime: 13:48:10 Page: 1 Field: Kuparuk River Unit Co -ordi»ate(NE} R eference: WeII: 1 J-180, Tr ue North ' Site: Kuparuk 1J Pad Vertical (TVD) Reference. 1J-180PB1: 121 .4 ' Well: 1J-180 Section (VS)Reterence: WeII (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-180PB1 Survey Calculation I~icthod: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska ' United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~ Well: 1J-180 Slot Name: j Well Position: +N/-S -499.40 ft Northing: 5945420.12 ft Latitude: 70 15 41.346 N ' +E/-W -23.60 ft Easti ng : 558770.25 ft Longitude: 149 31 29.693 W Position Uncertainty: 0.00 ft - ~- Wellpath: 1J-180P61 Drilled From: Well Ref. Point ~ 500292332970 Tie-on Depth: 40.40 ft Current Datum: 1 J-180PB1: Height 121.40 ft Above System Datum: Mean Sea Level Magnetic Data: 1/3/2007 Declination: 23.61 deg Field Strength: 57618 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.40 0.00 0.00 180.00 _ Survey Program for Definitive Wellpa th _ Date: 2/20/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft - - 80.00 470.00 1J-180P61 Gyros (80.00-470.00) CB-GYRO-SS Camera based gyro single shot 516.32 2867.70 1J-180PB1 (516.32- 2867.70) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey r _ _ _ - MD [ncl Azim TVD Sys T~'D N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ___ 40.40 0.00 0.00 40.40 -81.00 0.00 0.00 ___ 5945420.12 558770.25 TIE LINE 80.00 0.25 204.54 80.00 -41.40 -0.08 -0.04 5945420.04 558770.21 CB-GYRO-SS 120.00 0.31 93.19 120.00 -1.40 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS 195.00 0.31 275.44 195.00 73.60 -0.16 0.04 5945419.96 558770.29 CB-GYRO-SS ~i 273.00 1.70 207.09 272.99 151.59 -1.17 -0.70 5945418.95 558769.56 CB-GYRO-SS 370.00 4.93 214.60 369.81 248.41 -5.88 -3.72 5945414.21 558766.57 CB-GYRO-SS l i 470.00 8.58 215.07 469.10 347.70 -15.52 -10.45 5945404.52 558759.92 CB-GYRO-SS 516.32 10.63 215.05 514.77 393.37 -21.85 -14.89 5945398.16 558755.53 MWD+IFR-AK-CAZ-SC 585.68 13.33 214.06 582.61 461.21 -33.71 -23.04 5945386.23 558747.47 MWD+IFR-AK-CAZ-SC 681.16 17.45 210.75 674.65 553.25 -55.15 -36.53 5945364.70 558734.15 MWD+IFR-AK-CAZ-SC 775.68 20.50 207.94 764.03 642.63 -81.95 -51.54 5945337.77 558719.36 MWD+IFR-AK-CAZ-SC 872.00 23.89 207.47 853.20 731.80 -114.17 -68.44 5945305.43 558702.71 MWD+IFR-AK-CAZ-SC 964.80 27.53 210.33 936.80 815.40 -149.37 -87.95 5945270.09 558683.48 MWD+IFR-AK-CAZ-SC 1060.69 31.40 211.51 1020.27 898.87 -189.81 -112.21 5945229.46 558659.54 MWD+IFR-AK-CAZ-SC 1156.07 33.60 212.52 1100.71 979.31 -233.25 -139.38 5945185.81 558632.71 MWD+IFR-AK-CAZ-SC 1249.41 36.08 211.06 1177.31 1055.91 -278.58 -167.45 5945140.27 558604.99 MWD+IFR-AK-CAZ-SC 1345.29 36.19 210.02 1254.75 1133.35 -327.27 -196.18 5945091.36 558576.65 MWD+IFR-AK-CAZ-SC 1440.67 37.63 209.99 1331.01 1209.61 -376.87 -224.82 5945041.54 558548.39 MWD+IFR-AK-CAZ-SC i 1536.41 39.59 209.64 1405.82 1284.42 -428.71 -254.52 5944989.48 558519.10 MWD+IFR-AK-CAZ-SC 1631.01 42.74 208.47 1477.03 1355.63 -483.14 -284.74 5944934.82 558489.31 MWD+IFR-AK-CAZ-SC 1725.56 43.94 205.13 1545.80 1424.40 -541.06 -313.97 5944876.68 558460.54 MWD+IFR-AK-CAZ-SC 1821.24 46.86 205.17 1612.98 1491.58 -602.72 -342.92 5944814.80 558432.07 MWD+IFR-AK-CAZ-SC 1915.82 51.32 206.09 1674.90 1553.50 -667.14 -373.85 5944750.15 558401.65 MWD+IFR-AK-CAZ-SC 2010.35 51.48 206.20 1733.87 1612.47 -733.45 -406.40 5944683.59 558369.62 MWD+IFR-AK-CAZ-SC ~ 2106.00 56.34 203.99 1790.21 1668.81 -803.44 -439.13 5944613.35 558337.44 MWD+IFR-AK-CAZ-SC 2200.83 59.85 203.96 1840.32 1718.92 -876.99 -471.84 5944539.56 558305.32 MWD+IFR-AK-CAZ-SC 2295.95 63.63 203.71 1885.35 1763.95 -953.61 -505.69 5944462.68 558272.07 MWD+IFR-AK-CAZ-SC 2391.44 68.25 203.43 1924.27 1802.87 -1033.51 -540.54 5944382.52 558237.85 MWD+IFR-AK-CAZ-SC 2486.93 72.33 203.18 1956.46 1835.06 -1116.06 -576.09 5944299.71 558202.94 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 3/21/2007 Timc: 13:48:10 Pa~c: _' Field: Kuparuk River Unit Co-ordiuate(NE} Reference: WeIL' 1 J-180, True North Site: Kuparuk 1J Pad 1'crtical (I'VU) Reference: 1J-180P$1: 121.4 Wetl: 1J-180 Section (VS) Reference, Well (O.OON,O.OOE,180.OOAzi} Wellpath: 1J-180PB1 Survey Cakulatiou Method: Minimum Curvature - llh: Oracle Cnrvev SID [ncl Azim 'I'VD Sys TVD N/S E/W MapN MupE Tool ft deg deg ft ft ft ft' ft ft 2582.57 76.51 202.25 1982.15 1860.75 -1201.02 -611.65 5944214.48 558168.05 MWD+IFR-AK-CAZ-SC it 2675.82 77.78 199.58 2002.90 1881.50 -1285.94 -644.10 5944129.32 558136.27 MWD+IFR-AK-CAZ-SC 2772.58 79.53 197.43 2021.93 1900.53 -1375.89 -674.20 5944039.14 558106.87 MWD+IFR-AK-CAZ-SC 2867.70 84.52 197.10 2035.12 1913.72 -1465.82 -702.15 5943949.01 558079.63 MWD+IFR-AK-CAZ-SC 2969.00 84.52 197.10 2044.80 1923.40 -1562.20 -731.80 5943852.41 558050.74 PROJECTED to TD ~ 1J-180'8' Sand Liner Detail ~ well: 1J-180 '~` 4 1/2" Slotted .and Blank Liner Date: 2/7/2007 Conoct~P~i1!rps Alaska. ln~. Final DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Paae 1 5" DP to Surface =_> Crossover Liner Running Tool 5" (Does not stav in hole "HRD" ZXP Liner Top Packer 9-5/8" (7.50" X 8.43" "RS" Packoff Seal Nipple 7.00" (6.22" ID x 8.43" 0 FlexLock Liner Hanger 7"x 9-5/8" (6.27" X 8.32") XO Bushing 4.90" ID, 7.68" OD 190-47 Casing Seal Bore Ext. 4.75"ID x 6.27" OD XO Bushing 3.91" ID, 6.04" OD Pup Jt. - 4-1/2", 12.6 ppf, L-80, Hvdril 521 166 to 181 I 16 Jts 4-1/2" Hydr Jts 165 to 165 1 Jts 4-1 /2",11.6 Jts 164 to 164 1 Jts 4-1 /2", 11.6 Jts 163 to 163 1 Jts 4-1 /2",11.6 Jts 162 to 162 1 Jts 4-1 /2", 11.6 Jts 161 to 161 1 Jts 4-1 /2",11.6 Jts 160 to 160 1 Jts 4-1 /2", 11.6 Jts 159 to 159 1 Jts 4-1 /2",11.6 Jts 158 to 158 1 Jts 4-1 /2", 11.6 Jts 157 to 157 1 Jts 4-1 /2",11.6 Jts 156 to 156 1 Jts 4-1 /2", 11.6 Jts 155 to 155 1 Jts 4-1 /2",11.6 Jts 149 to 154 6 Jts 4-1 /2", 11.6 Jts 147 to 148 2 Jts 4-1 /2",11.6 Jts 146 to 146 1 Jts 4-1/2", 11.6 Jts 145 to 145 1 Jts 4-1 /2",11.6 Jts 144 to 144 1 Jts 4-1 /2", 11.6 Jts 143 to 143 1 Jts 4-1 /2",11.6 Jts 142 to 142 1 Jts 4-1 /2", 11.6 Jts 141 to 141 1 Jts 4-1 /2",11.6 Jts 140 to 140 1 Jts 4-1 /2", 11.6 Jts 139 to 139 1 Jts 4-1 /2",11.6 Jts 138 to 138 1 Jts 4-1 /2", 11.6 Jts 137 to 137 1 Jts 4-1 /2",11.6 Jts 131 to 136 6 Jts 4-1 /2", 11.6 Ran total of 103 jts Blank BTC Csg 2614.43', 16 its Hvdril 521 Blank C it 521 box x 4-1 /2" BTC pin Crosso ppf, L-80, BTC Slotted Casing p f, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing pf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing ppf, L-80, BTC Slotted Casing ppf, L-80, BTC Blank Casing = 4340.18' and 62 jts Slotted BTC Cs sg = 651.15' Used Run-N-Seal thread compound on all connections. Drifted casing to 3.833" w/ teflon rabbit. Torque Rings Installed in joints 91 Thru 165 ver 10.78 18.79 2.83 8.80 1.38 19.61 1.44 3.42 651.15 1.75 36.58 42.35 43.34 39.90 43.40 43.17 42.44 42.52 39.47 42.51 43.51 249.88 85.86 42.68 42.89 43.19 42.23 42.67 43.45 42.02 42.59 42.93 42.31 253.06 Up Wt Dn Wt Block Wt Rot Wt 10157.80 10157.80 10168.58 10187.37 10190.20 10199.00 10200.38 10219.99 10221.43 10224.85 10876.00 10877.75 10914.33 10956.68 11000.02 11039.92 11083.32 11126.49 11168.93 11211.45 11250.92 11293.43 11336.94 11586.82 11672.68 11715.36 11758.25 11801.44 11843.67 11886.34 11929.79 11971.81 12014.40 12057.33 12099.64 310K 70K 70K 155 K Supervisors: Mike Thornton /Scott Heim • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 129 to 130 2 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 78.13 12352.70 Jts 128 to 128 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.20 12430.83 Jts 127 to 127 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.38 12474.03 Jts 126 to 126 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.89 12516.41 Jts 125 to 125 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 41.82 12559.30 Jts 124 to 124 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.34 12601.12 Jts 123 to 123 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.04 12643.46 Jts 122 to 122 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 36.88 12686.50 Jts 121 to 121 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.36 12723.38 Jts 120 to 120 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.55 12766.74 Jts 119 to 119 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.41 12809.29 Jts 113 to 118 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 257.61 12852.70 Jts 112 to 112 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.39 13110.31 Jts 111 to 111 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.85 13153.70 Jts 110 to 110 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.61 13196.55 Jts 109 to 109 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 39.24 13240.16 Jts 108 to 108 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.40 13279:40 Jts 107 to 107 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.35 13322.80 Jts 106 to 106 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.07 13365.15 Jts 105 to 105 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.89 13406.22 Jts 104 to 104 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.87 13449.11 Jts 103 to 103 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.90 13491.98 Jts 102 to 102 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casin 43.31 13534.88 Jts 95 to 101 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 287.53 13578.19 Jts 94 to 94 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casin 42.95 13865.72 Jts 93 to 93 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.86 13908.67 Jts 92 to 92 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.43 13951.53 Jts 91 to 91 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.45 13994.96 Jts 90 to 90 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casin 43.40 14035.41 Jts 89 to 89 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.68 14078.81 Jts 88 to 88 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.41 14121.49 Jts 87 to 87 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.69 14164.90 Jts 86 to 86 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.50 14207.59 Jts 85 to 85 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.19 14250.09 Jts 84 to 84 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 36.24 14293.28 Jts 78 to 83 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 252.06 14329.52 Jts 77 to 77 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.05 14581.58 Jts 76 to 76 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.54 14624.63 Remarks: Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 75 to 75 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.30 14667.17 Jts 74 to 74 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 39.97 14709.47 Jts 73 to 73 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 36.01 14749.44 Jts 72 to 72 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 37.74 14785.45 Jts 71 to 71 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 39.61 14823.19 Jts 70 to 70 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.68 14862.80 Jts 69 to 69 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.42 14905.48 Jts 68 to 68 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.55 14948.90 Jts 67 to 67 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.27 . 14991.45 Jts 66 to 66 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.57 15032.72 Jts 65 to 65 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.63 15075.29 Jts 59 to 64 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 250.64 15118.92 Jts 58 to 58 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.48 15369.56 Jts 57 to 57 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.68 15413.04 Jts 56 to 56 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.92 15455.72 Jts 55 to 55 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 37.18 15496.64 Jts 54 to 54 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.50 15533.82 Jts 53 to 53 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.57 15577.32 Jts 52 to 52 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.06 15619.89 Jts 51 to 51 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.36 15662.95 Jts 50 to 50 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.90 15705.31 Jts 49 to 49 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.84 15747.21 Jts 48 to 48 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.69 15790.05 Jts 41 to 47 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 298.51 15833.74 Jts 40 to 40 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.36 16132.25 Jts 39 to 39 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.03 16174.61 Jts 38 to 38 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 42.95 16217.64 Jts 37 to 37 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.02 16260.59 Jts 36 to 36 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.16 16302.61 Jts 35 to 35 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.54 16345.77 Jts 34 to 34 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.65 16388.31 Jts 33 to 33 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.07 16431.96 Jts 32 to 32 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.49 16475.03 Jts 31 to 31 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.53 . 16518.52 Jts 30 to 30 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.05 16561.05 Jts 23 to 29 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 300.68 16604.10 Jts 22 to 22 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.64 16904.78 Jts 21 to 21 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.94 16948.42 Remarks: • • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 4 LENGTH TOPS Jts 20 to 20 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.24 16991.36 Jts 19 to 19 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.92 17032.60 Jts 18 to 18 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.05 17075.52 Jts 17 to 17 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.38 17118.57 Jts 16 to 16 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.22 17158.95 Jts 15 to 15 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.38 17200.17 Jts 14 to 14 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 38.65 17240.55 Jts 13 to 13 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.09 17279.20 Jts 12 to 12 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.58 17322.29 Jts 11 to 11 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.68 17365.87 Jts 10 to 10 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 38.91 17408.55 Jts 9 to 9 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.69 17447.46 Jts 8 to 8 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.37 17490.15 Jts 7 to 7 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.19 17533.52 Jts 6 to 6 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.36 17576.71 Jts 5 to 5 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.08 17620.07 Jts 4 to 4 1 Jts 4-1/2",11.6 ppf, L-80, .BTC Slotted Casing 39.48 17663.15 Jts 3 to 3 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.19 17702.63 Jts 2 to 2 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.64 17745.82 Jts 1 to 1 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.90 17789.46 4-1/2" BTC Silver Bullet Float Shoe 1.68 17832.36 Bttm of Shoe =_> 17834.04 TD 6 3/4" hole 17,834.3' MD / 3,350' TVD 4-1 /2" Shoe 17,834' MD / 3,350' TVD (.30' Rathole) Intermediate 9- 5/8 Shoe 10842' MD/ 3,377' TVD Run 1 spiroglider per joint floating on the BTC (148) Run 1 spiroglider per joint w/ stop ring in the center of the joint on the Hydril 521 (16 total) Total 164 spiroglider Centralizers used Coverage of Centralizers f/ 17789' to 10224' DO NOT RUN CENTRALIZERS ON CONSTRICTOR JOINTS Total of 16 Constrictors 16853', 16603', 16103' 15853',15338',15116',14580',14358',13838',13608', 13088',12858',12338',12109',11588',11357'. Remarks: • 04-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-180 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,772.58' MD Window /Kickoff Survey 2,790.00' MD (if applicable) Projected Survey: 2,969.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ v2-(~"~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 04-Apr-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-180PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 40.40' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 2,969.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~U~l' Signed _ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~5~~~ 5~ ~~~I~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~T. F ~a '• A n ,.f s. 6 .~,hr~~l~s,~ae=~! ~~~-iS~ Well Job # Log Description 1 ,~ ~ 03/05/07 ~,,,.... N0.4173 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2G-03 11638824 INJECTION PROFILE 02/15/07 1 1R-08 11628971 INJECTION PROFILE 02/15/07 1 1F-17 11638827 SBHP SURVEY 02/17/07 1 1F-14 11638826 SBHP SURVEY 02/17/07 1 1F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19107 1 1C-02 11628978 SBHP SURVEY 02119107 1 2M-02 11628979 INJECTION PROFILE 02120/07 1 3S-26 11638813 INJECTION PROFILE 01121/07 1 1C-121 11665391 INJECTION PROFILE 02/05107 1 1J-180 11665390 USIT 02/06107 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1J-118 11665392 USIT 02/22/07 1 1 D-11 11665393 INJECTION PROFILE 02124107 1 2M-05 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1F-13 11665401 INJECTION PROFILE 03102/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1 '~ update on IJ-103 and IJ-180 wells • Subject: update on 1J-103 and 1T-180 wells From: "Greener, Mike R." <Mike.R.Greener@conocophillips.com> Date: Wed, 10 Jan ?007 15:57:22 -0900 I'o: Toi~~ Nlaui~der~~-iom mauncien~a~.adinin.stat~.ak.us> C'C: ""Ihoma~, Randv L" ~~-Randy.L."Ihomasr~i conocophillips.cuiY~~=. "Reilly, P~itrick J" <PaU~iclc.J.R~illy@conocuphillips.com~. I am remiss in that l haven't Kept you up to date on what has happened with the 'I'l.~ depth change on the 1 J-103 Nell in tl~e A lateral. ~i%'hile I am at it 1 also have some info on the 1 J-18() well :for you. J-l 03 The "A" lateral ended up being TD'd at 11.,272' {original. pen~nit depth. was 1.5,094'} Tl~e asset suspected the formation `would be wet if w°e crossed the fault at +/- 11.,400', 'I'bis ores based oil the results that were seen in tl~e offset I J-102 well. The "B" lateral was planned to cross this same fault to determine if the sand in that Lone was ~~~et south of the fault. We discovered that it was and TD's the well at 12,444'. e ran a liner to 1.1,583' and placed t~vo swell packers (one on ea~;h side of the fault which-was at +/- 11,400'}. I~trring the running of the 1.,I11VI {lateral ent~~y module} for the "B" lateral. uIe :have encountered some trouble and. we are currently in the process of retrie~~ulg it and we plan. to run a new one. Then we will move to drilling the "D" lateral. is-iso ~O C~ - l S We are currently drilling the surface section on this well. It looks like this section. will reach the required 'l"~'D depth. of +/- 2,1.42' at a measured depth of +/- 3,500' M1.). We would I_ke to continue drilling on this same path to extend our setting depth of tl~e surface casing to somewhere between 3,800' to 4,100' N1D which would. be 2,1 ~2' to 2,250' TVD. This would help us get our intermediate casing to depth since ~7e would. be able to run. more roller centralizers in tl~e surface x it~ten~nediate annulus to reduce friction. Does this TVD depth change pose a problem from the original pe~-~nit depth for the surface casing of 3,878' ~V1, 2,142' TVD`? Mike Clreener• «Greener, Mike R..vcf» 1 of 1 1/10/2007 4:26 PM LW. t. Vll l.I.LGU L l~l~l~lll 11 J 1V1 1J-1OV ~JJ I~J Subject: RE: CorrectedPERMIT IT's for 1J-180 From: "Greener; Mike R." <Mike.R.Greener@conocophllips.com> Date: Fri, 27 Oct 200b 08:46:58 -0800 To: Thomas Maunder <tam maunderCadmin.state:ak.us> .~ The bond log would be run after we get the liner in the ground on the first lateral to give the cement an appropriate time to eLU•e due to the lo~v temperature of the fol-tnations. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, October 27, 2006 7:34 AM To: Greener, Mike R. Subject: Re: Corrected PERMIT ITs for 1J-180 Mike, What you sent takes care of the hardware of the completion. I don't see where you plan to run a bond log. I also had one other thought concerning the BOP description. I seem to remember that in one of the "versions" out there that there was a description of the ram configuration with DP on top and casing on bottom. If you have that description, it would be appropriate to include it. Thanks for your attention to these requests. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 10/27/2006 6:57 AM: My fault on the pern~_its. I should lace caught that. "I~hanks for the phone call.. I :have attached. the corrected versions. «1 J-180 PERMIT IT.doc» «1 J-180 L1 PERMIT IT.doc» ~~Iil~c Ureerler Th~,a~~~c~~~\~e~~-:o~ S ct.c~~-t~c7 <ot-a~~c`t~~ «Greener, Mike R..vcf» 1 (~ \1JC9-5 ~~R~~ ` ~J--~ t®~~~ Content-Description: 13-5 BOP 3K diagram.pdf 13-5 BOP 3K diagram.polF Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 10/27/2006 8:53 AM ti _ ~ j _. ; ,, ALASSA OIL A1~TD GAS COI~TSERQA'1`IO1~T COMI~IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 • FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-180 ConocoPhillips Alaska, Inc. Permit No: 206-150 Surface Location: 1508' FSL, 2443' FEL, SEC. 35, T 11 N, R l OE, UM Bottomhole Location: 2052' FSL, 184' FEL, SEC. 15, T10N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED thi~ day of October, 2006 cc: Department of Fish 8i; Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com October 17, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, iJ-180, iJ-180 Li Dear Commissioners: A~~''~ ~ ~ ~ I ~ 2006 Al~~k~ Qi1 ~ , u'~' '~t,S, ~s~t~'7~iS~(0~1 ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well, a dual lateral horizontal well in the West Sak ~~B"and "D" sands. The main bore of the well will be designated 1J-180, and the lateral bore of the well will be designated iJ-180L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-180 is December 20, 2006. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, ~ ~ Randy Thomas Greater Kuparuk Area Drilling Team Leader • __.__ __ ..._... ~ ~ REC~ivED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~O'~"t1 PERMIT TO DRILL 20 AAC 25.005 a~iasica ~~! I~~;; ~;~r,~, ~~1?l~i~si~~~ 1a. Type of Work: Drill 0 Re-drill ^ Re-entry ^ 1b. Current Well Class: Expbratory Development Oil ^ Stratigraphic Test ^ Service Q ~ Development Gas ^ Multiple Zone^ Single Zone ^~ 1c. Specify if well is pr `' Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-180 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: • MD: 17961' TVD: 3315' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1508' FSL, 2443' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: O ADL 25662, 25663, / A(„ West Sak Oil Pool Top of Productive Horizon: 1894' FNL, 193' FEL, Sec. 10, T10N, R10E, UM 8. Land Use Permit: ALK 2177, 472, 2181 13. Approximate Spud Date: 12/20/2006 Total Depth: 2052' FSL, 184' FEL, Sec. 15, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Properly: < 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558770 ~ y- 5945420 • Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1J-156L1 , 173' @ 129E 16. Deviated wells: Kickoff depth: ft. Maximum Hole Angl . 91 ! ~~aeg 17. Maximum Anticipated Pressures in psig (see 20 na,C 25.035) Downhole: 1481 psig Surface: 1119 psig • 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ca ons pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 80' 80' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3878' 28' 28' 3878' 2142' 730 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 10784' 28' 28' 10784' - 3412' 700 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTCM 7543' 10418' 3362' 17961' • 3315' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Ptat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program a 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ; ` ~ Phone ~5 (~~3U Date lb~C6l~~ P a h r n 1 D k Commission Use Only Permit to Drily ~ / Number: Z~U t0 ~ ~~ API Number: /1/~ 50- ~" Z 3 329"~~G.J Permit Approval Date: ~ p~3~/O~, See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed meth ne, gas hydrates, or gas contained in shales: 30Qdeg~ QQ~~S~-; Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [.~ Other: ~ ~-~"~` ~~~~ ~va~'~ `p~° H2S measures: Yes ^ No [a' D~ Tonal svy req'd: Yes [•~ No ^ l3 \ ~ wte,.~ oP~cc-cr~~ o~~ ~ ~ c~c~a r~ w ~ 11ip 3- APPROVED BY THE COMMISSION DATE: O ~~ r Q ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ ~ Submit in Duplicate ~tion for Permit to Drill, Well 1 J-180 Revision No.O Saved: 16-Oct-06 Permit It -West Sak Well #1J-180 ""° r.~ 1i Application for Permit to Drill Document r~ ~~I~ M d x i m i=~ bell ~vlue Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ............................................................................................................. 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.OS0(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 .................................................. 3 Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3 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. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 2S.OOS(c)(8) ......................................................................................................... 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 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 .......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(I1) ...................................................................................................... 5 1J-180 PERMIT IT Page 1 of 7 Printed: 16-Oct-O6 ORIGINAL • tion for Permit to Drill, Well 1 J-180 Revision No.O Saved: 16-Oct-06 12. Evidence of Bonding ................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5 13. Proposed Drilling Program ......................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ...................................................................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ...................................................................................................... 7 15. Attachments ............................................................................................................... 7 Attachment 2 Directional Plan .................................................................................................................. 7 Attachment 3 Drilling Hazards Summary ................................................................................................... 7 Attachment 4 CemCADE Summary ............................................................................................................. 7 Attachment S Well Schematic .................................................................................................................... 7 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a miique name designated by the operator and a unique API iiumbei• assigned by the commission under 20 AAC 25.040(6). For a ~~~ell with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the nanze designated for the Nell by fhe operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as IJ-180. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the follrni~ing items, except for an item already on file with the commission and identified in the application: (2) a plat ident~~ing the property and the properg~'s oi+-Hers and shoea~ing (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 is-ell at the surface, referenced to the state plane coordinate system for this state as maintained by the .'r'ational Geodetic Stoney in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formafion and at total depth; Location at Surface 1,508' FSL, 2443' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL ' Northings: 5,945,420 Eastings: 558,770 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 1,894' FNL, 193' FEL, Section 10, T10N, R10E ' Sak "B" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,936,617 Eastings: 555,818 Measured Depth, RKB: 10,785 Total Vertical Depth, RKB: 3,412 Total Vertical De th, SS: 3,291 Location at Total Depth 2,052' FSL, 184' FEL, Section 15, T10N, R10E Measured Depth, RKB: 17,961 " ASP Zone 4 NAD 27 Coordinates 889 N 5 929 443 E ti 555 hi Total Vertical Depth, RKB: 3,315 - , as ngs: , ort ngs: , Total Vertical De th, SS.• 3,194 and (D) other information required by 20 AAC 25.050(6); ORIGINAL 1J-180 PERMIT IT Page 2 of 7 Printed: 16-Oct-O6 • tion for Permit to Drill, Well 1 J-180 Revision No.O Saved: 16-Oct-06 Requirements of 20 AAC 25.OS0(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401J must (k) include a plat, drawn to a suitable scale, showing the path of the proposed ivellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those i~~ells, to the extent that those names are known or 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 is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 2S. 005(c)(3) An application for a Permit to Drill must be accompanied by each of the follo~a-ing 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 (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-180. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-180 area is 0.45 psi/ft, or 8.6 ppg EMW (equivalent `~ mud weight). The maximum potential surface pressure (MPSP) is 1,119 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 3,292'. . The MPSP is: MPSP = (3,292 ft)(0.45 - 0.11 psi/ft) =1,119 psi . (B) data on potential gas pones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation pones, and pones that have a propensity for differential sticking; Please see Attachment 2: 1J-180 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of tlae following items, except for an item ah~eady on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity rests, as rega~ired under 20 AAC 25.030(~J; 1J-180 will be completed with 9-5/8" casing landed at the top of the West Sak "B" sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-180 PERMIT IT Page 3 of 7 Printed: 16-Oct-06 ORIGINAL ApTcation for Permit to Drill, Well 1J-180 Revision No.O Saved: 16-Oct-O6 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accanpanied by each of the follow-ing items, except for an item ah~eady on file with the commission and ident~ed in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; meriting Program See also Attachment 3: Cement Summary h\S t~rcL'ev~~ Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in) (in) (lb/ t) Grade Connection t) t t Cement Pro am 20" 40" 62 5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf . ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,878 28' / 28' 3,878' / 2,142' 730 sx ArcticSet Lite bead, 220 sx Dee CRETE Tail Cement Top planned @ 6,877' 9-5/8" 12-1/4" 40 L-80 BTCM 10,784 28' / 28' 10,784' / 3,412' MD / 2,591' TVD. Cemented w/ 700 sx DeepCRETE 4-1/2 6-3/4" B Sand Lateral 11.6 L-80 BTCM 7,543 10,418' / 3,362' 17,961' / 3,315' Slotted-no cement slotted (1s-l8o) - 6-3/4" D Sand Lateral 11.6 L-80 BTCM 7,544 10,318' / 3,345' 17,862' / 3,246' Slotted- no cement slotted (1J-180 Ll) z 4 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 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 identcfied in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.03, 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 1J- ^~ 180. Please see diagrams of the Doyon 15 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 Drill must be accompanied by each of the following items, except for an item already as file frith the commission and identified in the application: (8) a drilling fluid prop 'am, inclzrdn~g a diao am and description of the drillzng fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Final Value Density (ppgJ 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 (cP) Plastic Viscosty 20-45 20-45 15-20 15-20 (lb/100 s, f) pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate NC-8 0 NC-8.0 5.0-7.0 5.0-7.0 (cc / 30 min)) . *9.6 ppg if hydrates are encountered 1J-180 PERMIT IT ® t'1 ~ /^t ~ ~ t ~ t Page 4 of 7 ELK{, t`•,.j, ~\v{ L Ptinted:16-Oct-O6 • A~tion for Permit to Drill, Well 1 J-180 Revision No.O Saved: 16-Oct-06 Intermediate Hole Mud Program (LSND) 13-3/8 "Casing Shoe to Intermediate Casing Point Initial Value Densi (pp~ 9.0-9.1 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy 12-18 (lb/100 s Yield Point 26-35 (cP) API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/l) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Density (p g) 9.0 Plastic Viscostiy 15-25 (lb/100 s~ Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200psi & 150° Oil /Water Ratio 80:20 Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be acconpanied by each of the following items, except for an item already on file ~~~ith the commission and identified in the applicatio~a: (9) for an exploratory or stratigraphic test well, a tabadation setting out the depths of predicted abnormally geo pressured sh~ata as required by 20 AAC 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of ZO AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item ab~eady on file frith the commissions and identified in the application: (IO) for an exploratory or stratigraphic test i~-ell, a seismic refraction or reflection analysis as required by 20 AAC 25.061(aJ; Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the follrnving iten2s, except for an item already on file it~ith the commission and identified in tla~e application: (11) for a we17 drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floatn~g drilling vessel, an analysis of seabed conditions as rega~ired by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompm~ied by each of the following items, except for an item ah•eady on file with the commission and ident~~ed in the application: (12) evidence showing that the reguirenzents of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by eadz of the folloi~~ing 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, Well Schematics. 1J-180 PERMIT IT Page 5 of 7 Printed: 16-Oct-O6 ORIGINAL • A~tion for Permit to Drill, Well 1 J-180 Revision No.O Saved: 16-Oct-06 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 15. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,878' MD / 2 ',TVD as per directional plan. Run MWD tools as required for directional monitoring. 2l~y ~6bo.t~.~6 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" 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. ~,~ ! z' ~ t~ 11, ~ 8. Directionally drill to 9-5/8" casing point at 10,784' MD / ~,29'1'TVD, the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,877' MD / 2,591' TVD (500' above Ugnu formation). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. PU 4-3/4" drilling assembly, with MWD, and LWD logging tools. 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. 33(x' /S~ tc• ~'~'O~ 14. Directionally dri118-1/2" hole to TD at +/- 17,961' MD / 3 4' TVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. i~~ ~~~s 16. PU and run 4-1/2" slotted liner. 33~ 17. Land liner, set liner hanger @ +/- 10,418' MD / 3 '. POOH. ~~ ~ [ LE.ov~fca~~ C~VG` C~ ~~~ ~~~U.15~`•~ . Scc~ Note: Remaining operations are covered under the IJ--137 LI Application for Permit to Drill, and areprovided her for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 10,318' MD / 3,224' TVD, the top of the "D" sand. 19. Mi118-1/2" window. POOH. 20. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 17,862' MD / 3,125' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. 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. 28. POOH, laying down drill pipe as required. ~ r`~,.~1 Eck ~l 1J-180 PERMIT IT Page 6 of 7 Printed: 16-Oct-O6 ORIGINAL • 29. PU completion as required and RIH to depth. Land tubing. Set BPV. A~tion for Permit to Drill, 11 J-180 vision No.O S ed:16-Oct-O6 30. Nipple down BOPE, nipple up tree and test. Pull BPV. 31. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns equalize. 32. Set BPV and move rig off. ~ O ~ 33. Rig up wire line unit. Pull BPV. 34. Set gas lift valves in mandrels. Operate well on gas lift until ESP fac 35. Rig up wireline. Replace gas lift valves with blank dummy valves. fi 36. Place well on production with ESP. ~J 14. Discussion of Mud and Cuttings Disposal and Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mz~rstc be accompanied by each of the and identified in the application: (14j a general description of how the operator plans to dispose of drillin request authorisation under 20 AAC 25.080 for an annular disposal op~ ready. Disposal tubing and allowing to items, except for an item already on file ti~~ith the commission nsud and cuttings and a statement of whether the operator intends to tiorr in the smell; Waste fluids generated during the drilling process wil a disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluid o a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE ad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for in' ction down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous ubstances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of A ski. ConocoPhillips Alaska may in the future operations. ~ 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Attachment 3 CemCADE Summ Attachment 4 Well Schematic / authorization for the use of this well for annular disposal 1J-180 PERMIT IT Page 7 of 7 Printed: 16-Oct-O6 OR161NAL 29. PU completion as required and RIH to depth. Land tubing. Set BPV. ~tion for Permit to Drill, Well 1J-180 Revision No.O Saved: 27-Oct-06 30. Nipple down BOPE, nipple up tree and test. Pull BPV. 31. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 32. Set BPV and move rig off. 33. Rig up wire line unit. Pull BPV. 34. Set gas lift valves in mandrels. Operate well on gas lift until well clean up is finished. 35. Rig up wireline. Replace gas lift valves with blank dummy valves. 36. Place well on injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) ;~?; fljlj~IZL`fdT; EJTX JiFr' fi E~et"116110 I~~'T~~7flidStft tl8 QCC`1376~JlPfEttfh X71' G'A(7t G.J i~.8./O~rLr~~J7T7*~ CtL'1i:5, Y..CL't'j,F1~(})' Es"d'E i~F>PF7 tf~l'F'f3d~' r'~n ~dS 'vl4lfi tFf6 L'tN~Ykn225:SI131! acrd ;"rfetatijtet! ir. 11ae ~ap~lactainrt: ~~~ t2 ~?~F32£'7?Z~ C~F'.iLa'I~60t2 tJj ~itriti t}2Y.- O~1F`-Y"Flt(3T pltUl,t tL) t~I1~OCd.' aJ !~ titiii~ rirtttf fditl~ (ns#'dPJ~;:S CT7~ Cf SigLfn2elll Oj iN{1P2)fei' IhF.' Of7NYfZt07" Zid tel7~S (0 request attthorizsstion acxder~ 't} ~1 C 25.11811; ~r nn anrrsalsu~ dzzpc~srrl a1re3~ation irz the rro~elr`.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment Z Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 1J-180 PERMITIT-2.doc Page 7 of 7 Printed: 27-Oct-O6 Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular /- To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves F To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~ To be tested to 250 psi and 3,000 psi only before running casing. ~_ Wellhead Valves tested to 3,000 psi upon assembly ~~l ~ Doyon~l'West Sak 3 ksi 13-580P3KSheetrl of~ a~10~0~~1~~1~5 BOP Confi uration prepared by Steve McKeever ;~c`~5~~' g 8/11/2004 • ConocoPhillips Alaska Plan: 1J-180 (wp08) • Sperry Drilling Services Proposal Report -Geographic 11 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-180 Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) N True API - US Survey Feet _t ~ Sperry Drilling Services ORIGINAL I 1 2 3411.76 10784.74 9 5/8" 9-5/8 3 3315.00 17960.69 4 1/2" 4-1/2 SHL: 1508' FSL, 2443' FEL - Sec35-T11N-R10E ~~~0 Project: Kuparuk River Uni Site: Kuparuk 1J Pad Well: Plan 1J-180 Wellbore: Plan 1J-180 Plan: 1J-180 (wp08) ?p~0 s 13 3/8" Casing @ 3878' MD, 2142' TVD: 742' FNL, 1758' FWL 2p?° X880 1-1 0 190° 0 0 CV ____ 180° Z 1J-180 wp08 D Top ~ L 1J-180 wp08 T1 --- 9 5/8" Casing @ 10785' MD, 3412' TVD: 1894' FNL, 193' FEL - Sec10-T10N-R 179° 1J-180 wp08 (West Turn Point) - _, 1J-180 wp08 T2 180° 1J-180 wp08 T3 - - - - 180° 1J-180 wp08 T4 - - 180° 1J-180 wp08 T5 180° T M -.a~~m~~dhs tc TN~°. '1 Magnetic North: 24.65° Magnetic Field Strength: 57552.4nT Dip Angle: 80.75° _ _ _ _ Date: 11/19/2004 1J-180 wp08 T6 180° Model: BGGM2005 1J-180 wp08 T7 180° 1J-180 wp08 Toe ~ BHL @ 17961' MD, 3315' TVD: 2052' FSL, 184' FEL - Sec15-T10N-R1 ConocoPhiUips 1J-180 (wp08)~ ' ia). ;%1 Bvaliwtbr+ For'mDtiOn -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 ORIGINAL V ~~ Project: Kuparuk River Unit CASING DETAILS Site: Kuparuk 1J Pad Well: Plan 1J-180 No TVD MD Name Size Wellbore: Plan 1J-180 1 2142.00 3878.25 13 318" 13-318 Plan: 1J-180 (wp08) 2 3411.76 10784.74 9 518" 9-518 3 3315.00 17960.69 4112" 4112 FORMATION TOP DETAILS -4000 No. TVDPath TVDSS MDPath Formation 1 1546.00 1425 1696.94 Base Perm 2 1645.00 1524 1849.26 K15 3 1948.00 1827 2849.70 T3 -3000 4 2142.00 2021 3878.25 T3 +550 5 2802.00 2681 7377.43 Ugnu C 6 2991.00 2870 8379.70 Ugnu B 7 3066.00 2945 8779.33 Ugnu A -zooo II 3212.00 3091 9570.02 K13 9 3337.00 321610271.42 WSAK D 10 3345.00 322410317.41 WSAK C 11 3372.00 3251 10473.25 WSAK B -1000 SHL: 1508' FSL, 2443' FEL - Sec35-T11 N-R10E - 0 ------ 0° BHL @ 17961' MD, 3315' TVD: 2052' FSL, 184' FEL - Sec15-T10N-I 2p° U ~p0 13 3/8" Casing ~ 3678' MD, 2142' TVD: 74T' FNL, 1758' FWL 1 1 1000 A~ 9 5/8" Casing ~ 10785' MD, 3412' TVD: 1894' FNL, 193' FEL - Sec10-T10N-R10E 1 o asa. ;..,. , O p~ L 0 1 N / - - - - __ - ~ ryO - O O 1 02000 - ------------ _ -- -'+'-- -a o a c - - - - - - - - - - - - - - ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - -. 'O 1 T3+550 i ^ °0 1 a~i - - - Ugnu C ~ - - - - - - - -- -- - - - - - - ~ -- - ~ °° _. - - ;'- , - - - -- - - - - - - - - - - o a - 1J-180 L1 (wp08 - _ Ugnu B X3000 ~ -- _ - -- - - - - _ o. °- - - - - - - - - - - - - - s~ v - _~ -_ - - -_ -_ _ _ _ - -- - - -,t,°- ;- - ----- ---- --- .-~-- - - ,1•/ __ ` __ - UgnuA -- - F ~_ _ - , K13 - ----- -- --- -- - - _ - - - - - -~ - - - - - - - - - -- - - - - - - - ~ ,o - - ~ ,o - ~ 1J-180 (wp08 i ~ ~ m ~ ~ 1 > ~ ~ m o ~ ~ mil ~ \ WSAK D ` ° ° c 1 0° I I °° I °° I ~ 1 ~ I ° ~ ° ~ ° 4Y5Ali L I 1 4 1/2„ o i q \ °° 1 ° I I ° I 1 4000 ,.5-~3 1 I v 1 I I I 1 1 1 I I I I 1 I I 1 \ 1 I I \ 1 I I I I 1 1J-180 wp08 D To ~ ~ \ 1 I I I I 1 I I 1 1 I \ 1 5000 1 I 1 I \ I I I I I 1 I 1 \ 1J-180 wp08 T1 ~ 1J-180 wp08 T 11 1J-180 wp08 T 1 1J-180 wp08 T I~ 1J-180 wp08 T 1J-180 wp08 (West Tum Point 1J-180 wp08 T 7J-180 wp08 T 1J-180 wp08 6000 7000 "'~ t-t ~. L.E.9 E3 L3S-3 T'L:+C\,8 - ConocoPhiilips oP,,,,~fl .,~ Ro~t,~ AlidSk3 iEvmurclon 8000 -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 Verilcal Section al 180.00" (2000 ft/in) ConacoPhillips Alaska Database: _EDM_2003.11_b48 Local Co-ordinate Reference: `JVe{IPIan1J-180 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (QO+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Gafculation Method: P<',~aimum Curvature , Wellbore: Plan 1J-180 Design: 1J-180 (wp08) Project Kuparuk River Unit. Glorth 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-180 Well Position +N/-S 0.00 ft Northing: 5,945,419.90ft Latitude: 70° 15' 41.344" N +E/-W 0.00 ft Fasting: 558,770.OOft Longitude: 149° 31' 29.701" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore Plan 1J-180 Magnetics Model Name Sample Date Declination Dip Anyle Field Strength (°) (°) lnTl bggm2005 11/19/2004 24.65 80.75 57,552 Design 1J-180 (wp08) Audit Notes: Version: 24 Phase: PLAN Tie On Depth: 40.00 i Vertical Section: Depth From (ND) +N/-S +E/-W Direction (ftl (ft) (ft) (°) 40.00 0.00 0.00 180.00 Halliburton Energy Services Planning Report -Geographic _~, a Grilling and Formation Evaluation 10/11/2006 3:20:38PM Page2of10 COMPASS 2003.11 Build 50 ORIGINAL • • Halliburton Energy Services ~OnaC0~1t~R~ Planning Report -Geographic ~x Grilling and Farmat~ Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhlllips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Flan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 Design: 1J-180 (wp08) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NJ-S +E/-W Rate Rate Rate TFO (h) (`) (°) 1ft) (h) (ft) (°/100ft) (°1100ft) (°I100ft) ~~~ 40.00 D.00 D.00 40.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 702.06 10.05 210.00 700.00 -30.46 -17.59 2.50 2.50 0.00 210.00 1,629.31 47.14 210.00 1,500.00 -408.15 -235.64 4.00 4.00 0.00 0.00 1,729.31 47.14 210.00 1,568.02 -471.63 -272.30 0.00 0.00 0.00 0.00 2,383.12 79.13 202.25 1,859.99 -990.43 -520.46 5.00 4.89 -1.18 -14.19 8,023.56 79.13 202.25 2,923.87 -6,117.07 -2,618.14 0.00 0.00 0.00 0.00 10,317.41 80.00 178.94 3,345.00 -8,318.31 -3,029.30 1.00 0.04 -1.02 -89.99 10,451.41 80.00 178.94 3,368.27 -8,450.25 -3,026.86 0.00 0.00 0.00 0.00 10,784.74 85.00 178.94 3,411.76 -8,780.57 -3,020.75 1.50 1.50 0.00 0.00 10,804.74 85.00 178.94 3,413.51 -8,800.49 -3,020.38 0.00 0.00 0.00 0.00 10,925.08 91.02 178.99 3,417.69 -8,920.68 -3,018.20 5.00 5.00 0.04 0.44 11,116.70 91.02 178.99 3,414.28 -9,112.24 -3,014.81 0.00 0.00 0.00 0.00 11,128.99 91.63 178.95 3,414.00 -9,124.53 -3,014.59 5.00 4.98 -0.29 -3.33 11,137.29 91.40 179.05 3,413.78 -9,132.82 -3,014.44 3.00 -2.77 1.15 157.38 11,994.74 91.40 179.05 3,392.83 -9,989.90 -3,000.17 0.00 0.00 0.00 0.00 12,033.62 91.31 180.21 3,391.91 -10,028.77 -2,999.92 3.00 -0.22 2.99 94.28 13,412.06 91.31 180.21 3,360.32 -11,406.83 -3,004.95 0.00 0.00 0.00 0.00 13,429.36 90.84 180.00 3,360.00 -11,424.13 -3,004.98 3.00 -2.75 -1.21 -156.23 14,728.85 90.84 180.00 3,341.00 -12,723.48 -3,004.98 0.00 0.00 0.00 0.00 14,764.74 89.76 180.00 3,340.81 -12,759.37 -3,004.98 3.00 -3.00 0.00 -180.00 15,529.07 89.76 180.00 3,344.00 -13,523.70 -3,004.98 0.00 0.00 0.00 0.00 15,549.98 90.39 180.00 3,343.97 -13,544.61 -3,004.98 3.00 3.00 0.00 0.00 16,726.41 90.39 180.00 3,336.00 -14,721.00 -3,004.98 0.00 0.00 0.00 0.00 16,752.20 91.16 180.00 3,335.65 -14,746.79 -3,004.98 3.00 3.00 0.00 0.00 17,326.68 91.16 180.00 3,324.00 -15,321.16 -3,004.98 0.00 0.00 0.00 0.00 17,338.42 90.81 180.00 3,323.80 -15,332.89 -3,004.98 3.00 -3.00 0.00 179.97 17,960.70 90.81 180.00 3,315.00 -15,955.11 -3,004.98 0.00 0.00 0.00 0.00 10/11/2006 3:20:38PM Page 3 of 10 COMPASS 2003.11 Build 50 lr' CanocoPhillips Alaska Halliburton Energy Services Planning Report -Geographic L.L.~E~L~~s Oriliing and For•matfon Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc_ ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Site: Kuparuk 1J Pad North Reference: True Well: PI-~n 1 _'-130 Survey Calculation Method: Minimum Curvature Wellbore: Flan 1J-I50 Design: 1.J- 1 ~0 ~ :vh0~ i Planned Survey 1J-t80 ~: ~~dp Go; i Map Map MD I nclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section lft) (') ~°) (ftI (ft) (ft) (ft) (ft) (~) (°l1DOft) (ft) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,419.90 558,770.00. 0.00 0.00 SHL: 1508' FS L, 2443' FEL - Sec35-T11 N-R10E - 100.00 0.00 0:00 100.00 -21.00 0.00 0.00 5,945,419.90 558,770.00 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,419.90 558,770.00 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,419.90 558,770.00 0.00 0.00 400.00 2.50 210.00 399.97 278.97 -1.89 -1.09 5,945,418.00 558,768.92 2.50 1.89 500.00 5.00 210.00 499.75 378.75 -7.55 -4.36 5,945,412.31 558,765.70 2.50 7.55 600.00 7.50 210.00 599.14 478.14 -16.98 -9.80 5,945,402.85 558,760.33 2.50 16.98 700.00 10.00 210.00 697.97 576.97 -30.15 -17.41 5,945,389.61 558,752.83 2.50 30.15 702.06 10.05 210.00 700.00 579.00 -30.46 -17.59 5,945,389.30 558,752.65 2.50 30.46 800.00 13.97 210.00 795.78 674.78 -48.11 -27.78 5,945,371.58 558,742.60 4.00 48.11 900.00 17.97 210.00 891.90 770.90 -71.93 -41.53 5,945,347.65 558,729.04 4.00 71.93 1,000.00 21.97 210.00 985.87 864.87 -101.50 -58.60 5,945,317.95 558,712.20 4.00 101.50 1,100.00 25.97 210.00 1,077.23 956.23 -136.68 -78.91 5,945,282.63 558,692.17 4.00 136.68 1,200.00 29.97 210.00 1,165.53 1,044.53 -177.28 -102.35 5,945,241.84 558,669.04 4.00 177.28 1,300.00 33.97 210.00 1,250.34 1,129.34 -223.13 -128.82 5,945,195.80 558,642.93 4.00 223.13 1,400.00 37.97 210.00 1,331.26 1,210.26 -273.98 -158.18 5,945,144.72 558,613.97 4.00 273.98 1,500.00 41.97 210.00 1,407.89 1,286.89 -329.60 -190.30 5,945,088.85 558,582.30 4.00 329.60 1,600.00 45.97 210.00 1,479.84 1,358.84 -389.72 -225.00 5,945,028.48 558,548.07 4.00 389.72 1,629.31 47.14 210.00 1,500.00 1,379.00 -408.15 -235.64 5,945,009.96 558,537.57 4.00 408.15 1,696.94 47.14 210.00 1,546.00 1,425.00 -451.08 -260.43 5,944,966.84 558,513.12 0.00 451.08 Base Perm 1,700.00 47.14 210.00 1,548.08 1,427.08 -453.02 -261.55 5,944,964.89 558,512.02 0.00 453.02 1,729.31 47.14 210.00 1,568.02 1,447.02 -471.63 -272.30 5,944,946.20 558,501.42 0.00 471.63 1,800.00 50.57 208.88 1,614.52 1,493.52 -517.99 -298.44 5,944,899.65 558,475.64 5.00 517.99 1,849.26 52.97 208.16 1,645.00 1,524.00 -551.99 -316.92 5,944,865.51 558,457.43 5.00 551.99 K15 1,900.00 55.45 207.47 1,674.67 1,553.67 -588.39 -336.11 5,944,828.96 558,438.52 5.00 588.39 2,000.00 60.33 206.21 1,727.81 1,606.81 -663.95 -374.33 5,944,753.11 558,400.90 5.00 663.95 2,100.00 65.23 205.08 1,773.54 1,652.54 -744.10 -412.78 5,944,672.68 558,363.08 5.00 744.10 2,200.00 70.13 204.03 1,811.51 1,690.51 -828.22 -451.20 5,944,588.26 558,325.32 5.00 828.22 2,300.00 75.04 203.04 1,841.42 1,720.42 -915.68 -489.27 5,944,500.52 558,287.94 5.00 915.68 2,383.12 79.13 202.25 1,859.99 1,738.99 -990.43 -520.46 5,944,425.53 558,257.34 5.00 990.43 2,400.00 79.13 202.25 1,863.18 1,742.18 -1,005.78 -526.73 5,944,410.14 558,251.18 0.00 1,005.78 2,500.00 79.13 202.25 1,882.04 1,761.04 -1,096.67 -563.92 5,944,318.97 558,214.71 0.00 1,096.67 2,600.00 79.13 202.25 1,900.90 1,779.90 -1,187.56 -601.11 5,944,227.80 558,178.23 0.00 1,187.56 2,700.00 79.13 202.25 1,919.76 1,798.76 -1,278.45 -638.30 5,944,136.63 558,141.75 0.00 1,278.45 2,800.00 79.13 202.25 1,938.63 1,817.63 -1,369.34 -675.49 5,944,045.46 558,105.28 0.00 1,369.34 2,849.70 79.13 202.25 1,948.00 1,827.00 -1,414.51 -693.98 5,944,000.15 558,087.15 0.00 1,414.51 73 2,900.00 79.13 202.25 1,957.49 1,836.49 -1,460.23 -712.68 5,943,954.29 558,068.80 0.00 1,460.23 3,000.00 79.13 202.25 1,976.35 1,855.35 -1,551.12 -749.88 5,943,863.12 558,032.32 0.00 1,551.12 3,100.00 79.13 202.25 1,995.21 1,874.21 -1,642.01 -787.07 5,943,771.95 557,995.85 0.00 1,642.01 3,200.00 79.13 202.25 2,014.07 1,893.07 -1,732.90 -824.26 5,943,680.78 557,959.37 0.00 1,732.90 3,300.00 79.13 202.25 2,032.93 1,911.93 -1,823.79 -861.45 5,943,589.61 557,922.90 0.00 1,823.79 3,400.00 79.13 202.25 2,051.79 1,930.79 -1,914.68 -898.64 5,943,498.45 557,886.42 0.00 1,914.68 10/11/2006 3:20:38PM Page 4 of 10 COMPASS 2003.11 Build 50 ORIGINAL • CanocoPhiliips Alaska Halliburton Energy Services Planning Report -Geographic L~~I °r OriiBng and Formatiw~ Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+g1) @ 12LOOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 Design: 1 J-180 (wp08) Planned Survey 1J-180 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ff) (°) (°) (ftl (ft) eft) eft) (g) (ft) (°/100ft) lft) 3,500.00 79.13 202.25 2,070.66 1,949.66 -2,005.58 -935.83 5,943,407.28 557,849.94 0.00 2,005.58 3,600.00 79.13 202.25 2,089.52 1,968.52 -2,096.47 -973.02 5,943,316.11 557,813.47 0.00 2,096.47 3,700.00 79.13 202.25 2,108.38 1,987.38 -2,187.36 -1,010.21 5,943,224.94 557,776.99 0.00 2,187.36 3,800.00 79.13 202.25 2,127.24 2,006.24 -2,278.25 -1,047.40 5,943,133.77 557,740.52 0.00 2,278.25 3,878.25 79.13 202.25 2,142.00 2,021.00 -2,349.37 -1,076.50 5,943,062.43 557,711.97 0.00 2,349.37 13 3/8" Casing @ 3878' MD, 2142' TVD: 742' FNL, 1758' FWL - T3 +550 -13 3/8" 3,900.00 79.13 202.25 2,146.10 2,025.10 -2,369.14 -1,084.59 5,943,042.60 557,704.04 0.00 2,369.14 4,000.00 79.13 202.25 2,164.96 2,043.96 -2,460.03 -1,121.78 5,942,951.43 557,667.56 0.00 2,460.03 4,100.00 79.13 202.25 2,183.83 2,062.83 -2,550.92 -1,158.97 5,942,860.26 557,631.09 0.00 2,550.92 4,200.00 79.13 202.25 2,202.69 2,081.69 -2,641.81 -1,196.16 5,942,769.09 557,594.61 0.00 2,641.81 4,300.00 79.13 202.25 2,221.55 2,100.55 -2,732.70 -1,233.35 5,942,677.92 557,558.13 0.00 2,732.70 4,400.00 79.13 202.25 2,240.41 2,119.41 -2,823.59 -1,270.54 5,942,586.75 557,521.66 0.00 2,823.59 4,500.00 79.13 202.25 2,259.27 2,138.27 -2,914.48 -1,307.73 5,942,495.58 557,485.18 0.00 2,914.48 4,600.00 79.13 202.25 2,278.13 2,157.13 -3,005.37 -1,344.92 5,942,404.41 557,448.71 0.00 3,005.37 4,700.00 79.13 202.25 2,297.00 2,176.00 -3,096.26 -1,382.11 5,942,313.24 557,412.23 0.00 3,096.26 4,800.00 79.13 202.25 2,315.86 2,194.86 -3,187.16 -1,419.30 5,942,222.07 557,375.75 0.00 3,187.16 4,900.00 79.13 202.25 2,334.72 2,213.72 -3,278.05 -1,456.49 5,942,130.90 557,339.28 0.00 3,278.05 5,000.00 79.13 202.25 2,353.58 2,232.58 -3,368.94 -1,493.68 5,942,039.73 557,302.80 0.00 3,368.94 5,100.00 79.13 202.25 2,372.44 2,251.44 -3,459.83 -1,530.87 5,941,948.56 557,266.33 0.00 3,459.83 5,200.00 79.13 202.25 2,391.30 2,270.30 -3,550.72 -1,568.06 5,941,857.39 557,229.85 0.00 3,550.72 5,300.00 79.13 202.25 2,410.16 2,289.16 -3,641.61 -1,605.25 5,941,766.22 557,193.37 0.00 3,641.61 5,400.00 79.13 202.25 2,429.03 2,308.03 -3,732.50 -1,642.44 5,941,675.05 557,156.90 0.00 3,732.50 5,500.00 79.13 202.25 2,447.89 2,326.89 -3,823.39 -1,679.63 5,941,583.89 557,120.42 0.00 3,823.39 5,600.00 79.13 202.25 2,466.75 2,345.75 -3,914.28 -1,716.82 5,941,492.72 557,083.95 0.00 3,914.28 5,700.00 79.13 202.25 2,485.61 2,364.61 -4,005.17 -1,754.01 5,941,401.55 557,047.47 0.00 4,005.17 5,800.00 79.13 202.25 2,504.47 2,383.47 -4,096.06 -1,791.20 5,941,310.38 557,010.99 0.00 4,096.06 5,900.00 79.13 202.25 2,523.33 2,402.33 -4,186.95 -1,828.39 5,941,219.21 556,974.52 0.00 4,186.95 6,000.00 79.13 202.25 2,542.20 2,421.20 -4,277.84 -1,865.58 5,941,128.04 556,938.04 0.00 4,277.84 6,100.00 79.13 202.25 2,561.06 2,440.06 -4,368.74 -1,902.77 5,941,036.87 556,901.56 0.00 4,368.74 6,200.00 79.13 202.25 2,579.92 2,458.92 -4,459.63 -1,939.96 5,940,945.70 556,865.09 0.00 4,459.63 6,300.00 79.13 202.25 2,598.78 2,477.78 -4,550.52 -1,977.15 5,940,854.53 556,828.61 0.00 4,550.52 6,400.00 79.13 202.25 2,617.64 2,496.64 -4,641.41 -2,014.34 5,940,763.36 556,792.14 0.00 4,641.41 6,500.00 79.13 202.25 2,636.50 2,515.50 -4,732.30 -2,051.53 5,940,672.19 556,755.66 0.00 4,732.30 6,600.00 79.13 202.25 2,655.36 2,534.36 -4,823.19 -2,088.72 5,940,581.02 556,719.18 0.00 4,823.19 6,700.00 79.13 202.25 2,674.23 2,553.23 -4,914.08 -2,125.91 5,940,489.85 556,682.71 0.00 4,914.08 6,800.00 79.13 202.25 2,693.09 2,572.09 -5,004.97 -2,163.10 5,940,398.68 556,646.23 0.00 5,004.97 6,900.00 79.13 202.25 2,711.95 2,590.95 -5,095.86 -2,200.29 5,940,307.51 556,609.76 0.00 5,095.86 7,000.00 79.13 202.25 2,730.81 2,609.81 -5,186.75 -2,237.48 5,940,216.34 556,573.28 0.00 5,186.75 7,100.00 79.13 202.25 2,749.67 2,628.67 -5,277.64 -2,274.67 5,940,125.17 556,536.80 0.00 5,277.64 7,200.00 79.13 202.25 2,768.53 2,647.53 -5,368.53 -2,311.86 5,940,034.00 556,500.33 0.00 5,368.53 7,300.00 79.13 202.25 2,787.40 2,666.40 -5,459.42 -2,349.05 5,939,942.83 556,463.85 0.00 5,459.42 7,377.43 79.13 202.25 2,802.00 2,681.00 -5,529.80 -2,377.85 5,939,872.24 556,435.61 0.00 5,529.80 Ugnu C 7,400.00 79.13 202.25 2,806.26 2,685.26 -5,550.32 -2,386.24 5,939,851.66 556,427.37 0.00 5,550.32 7,500.00 79.13 202.25 2,825.12 2,704.12 -5,641.21 -2,423.43 5,939,760.50 556,390.90 0.00 5,641.21 7,600.00 79.13 202.25 2,843.98 2,722.98 -5,732.10 -2,460.62 5,939,669.33 556,354.42 0.00 5,732.10 7,700.00 79.13 202.25 2,862.84 2,741.84 -5,822.99 -2,497.81 5,939,578.16 556,317.95 0.00 5,822.99 7,800.00 79.13 202.25 2,881.70 2,760.70 -5,913.88 -2,535.00 5,939,486.99 556,281.47 0.00 5,913.88 10/11/2006 3:20:38PM Page 5 of 10 COMPASS 2003.11 Build 50 ORIGINAL • ConocaPhillips Alaska Halliburton Energy Services Planning Report -Geographic I~~ s- Drilling and Farmation Evaluation Database: _EDM_2003.11_b48 Local Co-oMinate Reference: Well Plan 1J-180 Company; ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121 OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True We11: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 Design: 1J-180 (wp08) i Planned Survey 1J-180 (wp08) MD Inclination Azimuth TVD (ft) (°) (°) (ft) 7,900.00 79.13 202.25 2,900.57 8,000.00 79.13 202.25 2,919.43 8,023.56 79.13 202.25 2,923.87 8,100.00 79.13 201.48 2,938.29 8,200.00 79.13 200.46 2,957.14 8,300.00 79.14 199.44 2,975.99 8,379.70 79.15 198.63 2,991.00 Ugnu B 8,400.00 79.15 198.42 2,994.82 8,500.00 79.17 197.40 3,013.63 8,600.00 79.18 196.38 3,032.41 8,700.00 79.21 195.37 3,051.16 8,779.33 79.22 194.56 3,066.00 Ugnu A 8,800.00 79.23 194.35 3,069.86 8,900.00 79.26 193.33 3,088.53 9,000.00 79.29 192.31 3,107.14 9,100.00 79.32 191.30 3,125.70 9,200.00 79.36 190.28 3,144.19 9,300.00 79.40 189.26 3,162.62 9,400.00 79.45 188.25 3,180.98 9,500.00 79.49 187.23 3,199.25 9,570.02 79.53 186.52 3,212.00 K13 9,600.00 79.54 186.22 3,217.45 9,700.00 79.60 185.20 3,235.55 9,800.00 79.65 184.19 3,253.56 9,900.00 79.71 183.17 3,271.46 10,000.00 79.78 182.16 3,289.26 10,100.00 79.84 181.14 3,306.95 10,200.00 79.91 180.13 3,324.52 10,271.42 79.97 179.41 3,337.00 WSAK D 10,300.00 79.99 179.12 3,341.97 10,317.41 80.00 178.94 3,345.00 WSAK C -1J-180 wp08 D Top 10,400.00 80.00 178.94 3,359.34 10,451.41 80.00 178.94 3,368.27 10,473.25 80.33 178.94 3,372.00 WSAK B 10,500.00 80.73 178.94 3,376.40 10,600.00 82.23 178.94 3,391.22 10,605.81 82.32 178.94 3,392.00 1 J-180 wp08 T2 10,700.00 83.73 178.94 3,403.44 Map SSTVD +N/S +E/-W Northing (ft) (ft) (ft) (ft) 2,779.57 -6,004.77 -2,572.19 5,939,395.82 2,798.43 -6,095.66 -2,609.38 5,939,304.65 2,802.87 -6,117.07 -2,618.14 5,939,283.17 2,817.29 -6,186.74 -2,646.10 5,939,213.29 2,836.14 -6,278.45 -2,681.24 5,939,121.32 2,854.99 -6,370.76 -2,714.74 5,939,028.76 2,870.00 -6,444.76 -2,740.27 5,938,954.57 2,873.82 -6,463.66 -2,746.60 5,938,935.62 2,892.63 -6,557.11 -2,776.81 5,938,841.95 2,911.41 -6,651.09 -2,805.35 5,938,747.75 2,930.16 -6,745.57 -2,832.22 5,938,653.08 2,945.00 -6,820.86 -2,852.34 5,938,577.65 2,948.86 -6,840.52 -2,857.40 5,938,557.94 2,967.53 -6,935.91 -2,880.90 5,938,462.38 2,986.14 -7,031.71 -2,902.71 5,938,366.42 3,004.70 -7,127.90 -2,922.81 5,938,270.10 3,023.19 -7,224.43 -2,941.21 5,938,173.43 3,041.62 -7,321.29 -2,957.89 5,938,076.45 3,059.98 -7,418.45 -2,972.85 5,937,979.19 3,078.25 -7,515.87 -2,986.09 5,937,881.68 3,091.00 -7,584.22 -2,994.33 5,937,813.27 3,096.45 -7,613.52 -2,997.60 5,937,783.95 3,114.55 -7,711.38 -3,007.38 5,937,686.03 3,132.56 -7,809.41 -3,015.43 5,937,587.94 3,150.46 -7,907.59 -3,021.74 5,937,489.73 3,168.26 -8,005.89 -3,026.31 5,937,391.41 3,185.95 -8,104.27 -3,029.15 5,937,293.02 3,203.52 -8,202.71 -3,030.24 5,937,194.58 3,216.00 -8,273.03 -3,029.95 5,937,124.28 3,220.97 -8,301.17 -3,029.59 5,937,096.14 3,224.00 -8,318.31 -3,029.30 5,937,079.00 3,238.34 -8,399.63 -3,027.79 5,936,997.70 3,247.27 -8,450.25 -3,026.86 5,936,947.09 3,251.00 -8,471.77 -3,026.46 5,936,925.58 3,255.40 -8,498.15 -3,025.97 5,936,899.21 3,270.22 -8,597.03 -3,024.14 5,936,800.36 3,271.00 -8,602.78 -3,024.04 5,936,794.61 3,282.44 -8,696.26 -3,022.31 5,936,701.16 Map Fasting DLSEV Vert Section (ft) (°/100ft) (ft) 556,244.99 0.00 6,004.77 556,208.52 0.00 6,095.66 556,199.92 0.00 6,117.07 556,172.52 1.00 6,186.74 556,138.10 1.00 6,278.45 556,105.32 1.00 6,370.76 556,080.37 1.00 6,444.76 556,074.19 1.00 6,463.66 556,044.72 1.00 6,557.11 556,016.91 1.00 6,651.09 555,990.78 1.00 6,745.57 555,971.26 1.00 6,820.86 555,966.34 1.00 6,840.52 555,943.59 1.00 6,935.91 555,922.53 1.00 7,031.71 555,903.18 1.00 7,127.90 555,885.54 1.00 7,224.43 555,869.62 1.00 7,321.29 555,855.42 1.00 7,418.45 555,842.94 1.00 7,515.87 555,835.23 1.00 7,584.22 555,832.19 1.00 7,613.52 555,823.18 1.00 7,711.38 555,815.90 1.00 7,809.41 555,810.35 1.00 7,907.59 555,806.55 1.00 8,005.89 555,804.48 1.00 8,104.27 555,804.16 1.00 8,202.71 555,804.99 1.00 8,273.03 555,805.58 1.00 8,301.17 555,806.00 1.00 8,318.31 555,808.14 0.00 8,399.63 555,809.47 0.00 8,450.25 555,810.04 1.50 8,471.77 555,810.73 1.50 8,498.15 555,813.33 1.50 8,597.03 555, 813.48 1.51 8, 602.78 555,815.94 1.50 8,696.26 10/11/2006 3:20:38PM Page 6 of 10 COMPASS 2003.11 Build 50 ORIGINAL t- t~'1,. ~C Halliburton Energy Services ~-~ L~ COnOCQ~~~~lp5 Plannin Re ort - Geo ra hic Grilling and Formatiax+ 9 p 9 P Bvaiuation Database: _EDM_2003.11_b48 Local Co-orcfinata Reference: Well Plan 1J-180 Company: ConocoPhlllips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 Design: 1J-180 (wp08) Planned Survey 1J-180 (wp08) MD Inclination Azimuth TVD SSTVD +N/-S +E/-W (ft) (°) (°) (ff) (ft) (ff) (ft) 10,784.74 85.00 178.94 3,411.76 3,290.76 -8,780.57 -3,020.75 9 518" Casing @ 10785' MD, 3412' TVD : 1894' FNL, 19 3' FEL - Sec10-T10N-R10E - 9 5!8" 10,800.00 85.00 178.94 3,413.09 3,292.09 -8,795.77 -3,020.46 10,804.74 85.00 178.94 3,413.51 3,292.51 -8,800.49 -3,020.38 10,900.00 89.76 178.98 3,417.86 3,296.86 -8,895.61 -3,018.65 10,925.08 91.02 178.99 3,417.69 3,296.69 -8,920.68 -3,018.20 11,000.00 91.02 178.99 3,416.36 3,295.36 -8,995.58 -3,016.88 11,100.00 91.02 178.99 3,414.58 3,293.58 -9,095.55 -3,015.11 11,116.70 91.02 178.99 3,414.28 3,293.28 -9,112.24 -3,014.81 11,128.99 91.63 178.95 3,414.00 3,293.00 -9,124.53 -3,014.59 1J-180 wp08 T1 11,137.29 91.40 179.05 3,413.78 3,292.78 -9,132.82 -3,014.44 11,200.00 91.40 179.05 3,412.25 3,291.25 -9,195.51 -3,013.40 11,300.00 91.40 179.05 3,409.80 3,288.80 -9,295.46 -3,011.73 11,400.00 91.40 179.05 3,407.36 3,286.36 -9,395.42 -3,010.07 11,500.00 91.40 179.05 3,404.92 3,283.92 -9,495.37 -3,008.40 11,600.00 91.40 179.05 3,402.47 3,281.47 -9,595.33 -3,006.74 11,700.00 91.40 179.05 3,400.03 3,279.03 -9,695.29 -3,005.07 11,800.00 91.40 179.05 3,397.59 3,276.59 -9,795.24 -3,003.41 11,900.00 91.40 179.05 3,395.14 3,274.14 -9,895.20 -3,001.75 11,994.74 91.40 179.05 3,392.83 3,271.83 -9,989.90 -3,000.17 1J-180 wp08 (West Turn Point) 12,000.00 91.39 179.20 3,392.70 3,271.70 -9,995.16 -3,000.09 12,033.62 91.31 180.21 3,391.91 3,270.91 -10,028.77 -2,999.92 12,100.00 91.31 180.21 3,390.39 3,269.39 -10,095.13 -3,000.16 12,200.00 91.31 180.21 3,388.10 3,267.10 -10,195.10 -3,000.52 12,300.00 91.31 180.21 3,385.80 3,264.80 -10,295.07 -3,000.89 12,400.00 91.31 180.21 3,383.51 3,262.51 -10,395.05 -3,001.25 12,500.00 91.31 180.21 3,381.22 3,260.22 -10,495.02 -3,001.62 12,600.00 91.31 180.21 3,378.93 3,257.93 -10,594.99 -3,001.98 12,700.00 91.31 180.21 3,376.64 3,255.64 -10,694.97 -3,002.35 12,800.00 91.31 180.21 3,374.35 3,253.35 -10,794.94 -3,002.71 12,900.00 91.31 180.21 3,372.06 3,251.06 -10,894.91 -3,003.08 13,000.00 91.31 180.21 3,369.77 3,248.77 -10,994.89 -3,003.44 13,100.00 91.31 180.21 3,367.47 3,246.47 -11,094.86 -3,003.81 13,200.00 91.31 180.21 3,365.18 3,244.18 -11,194.83 -3,004.17 13,300.00 91.31 180.21 3,362.89 3,241.89 -11,294.80 -3,004.54 13,400.00 91.31 180.21 3,360.60 3,239.60 -11,394.78 -3,004.90 13,412.06 91.31 180.21 3,360.32 3,239.32 -11,406.83 -3,004.95 13,429.36 90.84 180.00 3,360.00 3,239.00 -11,424.13 -3,004.98 7J-180 wp08 T3 13,500.00 90.84 180.00 3,358.97 3,237.97 -11,494.76 -3,004.98 13,600.00 90.84 180.00 3,357.51 3,236.51 -11,594.75 -3,004.98 13,700.00 90.84 180.00 3,356.04 3,235.04 -11,694.74 -3,004.98 13,800.00 90.84 180.00 3,354.58 3,233.58 -11,794.73 -3,004.98 13,900.00 90.84 180.00 3,353.12 3,232.12 -11,894.72 -3,004.98 Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°l100ft) (ft) 5,936,616.86 555,818.16 1.50 8,780.57 5,936,601.67 555,818.56 0.00 8,795.77 5,936,596.95 555,818.68 0.00 8,800.49 5,936,501.86 555,821.16 5.00 8,895.61 5,936,476.80 555,821.80 5.01 8,920.68 5,936,401.92 555,823.71 0.00 8,995.58 5,936,301.97 555,826.26 0.00 9,095.55 5,936,285.28 555,826.68 0.00 9,112.24 5,936,273.00 555,827.00 4.99 9,124.53 5,936,264.71 555,827.21 3.00 9,132.82 5,936,202.04 555,828.74 0.00 9,195.51 5,936,102.11 555,831.19 0.00 9,295.46 5,936,002.18 555,833.63 0.00 9,395.42 5,935,902.25 555,836.08 0.00 9,495.37 5,935,802.32 555,838.52 0.00 9,595.33 5,935,702.39 555,840.97 0.00 9,695.29 5,935,602.46 555,843.41 0.00 9,795.24 5,935,502.53 555,845.86 0.00 9,895.20 5,935,407.85 555,848.17 0.00 9,989.90 5,935,402.60 555,848.29 2.97 9,995.16 5,935,368.99 555,848.73 3.00 10,028.77 5,935,302.64 555,849.00 0.00 10,095.13 5,935,202.67 555,849.42 0.00 10,195.10 5,935,102.71 555,849.83 0.00 10,295.07 5,935,002.75 555,850.25 0.00 10,395.05 5,934,902.78 555,850.66 0.00 10,495.02 5,934,802.82 555,851.08 0.00 10,594.99 5,934,702.86 555,851.49 0.00 10,694.97 5,934,602.89 555,851.91 0.00 10,794.94 5,934,502.93 555,852.32 0.00 10,894.91 5,934,402.97 555,852.74 0.00 10,994.89 5,934,303.00 555,853.15 0.00 11,094.86 5,934,203.04 555,853.57 0.00 11,194.83 5,934,103.08 555,853.98 0.00 11,294.80 5,934,003.11 555,854.40 0.00 11,394.78 5,933,991.06 555,854.45 0.00 11,406.83 5,933,973.76 555,854.55 3.00 11,424.13 5,933,903.14 555,855.10 0.00 11,494.76 5,933,803.16 555,855.88 0.00 11,594.75 5,933,703.19 555,856.66 0.00 11,694.74 5,933,603.21 555,857.45 0.00 11,794.73 5,933,503.23 555,858.23 .0.00 11,894.72 10/11/2006 3:20:38PM Page 7 of 10 COMPASS 2003.11 Build 50 • ~onocc~Phillips Rlaska Halliburton Energy Services Planning Report -Geographic • ~°t Oriliing and Fairmetirn~ Evaluation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: Conoco Phillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81 )) Project: Kuparuk River Unit MD Reference: Doyon 1 S (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 Design: 1J-180 (wp08) Planned Survey 1J-180 (wp 08) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DISEV Vert Section (ft) (°) (°) (ft) (ftl (ft) (ft) (~) off) (°HOOft} (ft1 14,000.00 90.84 180.00 3,351.66 3,230.66 -11,994.71 -3,004.98 5,933,403.26 555,859.01 0.00 11,994.71 14,100.00 90.84 180.00 3,350.19 3,229.19 -12,094.70 -3,004.98 5,933,303.28 555,859.79 0.00 12,094.70 14,200.00 90.84 180.00 3,348.73 3,227.73 -12,194.69 -3,004.98 5,933,203.30 555,860.57 0.00 12,194.69 14,300.00 90.84 180.00 3,347.27 3,226.27 -12,294.68 -3,004.98 5,933,103.33 555,861.35 0.00 12,294.68 14,400.00 90.84 180.00 3,345.81 3,224.81 -12,394.67 -3,004.98 5,933,003.35 555,862.13 0.00 12,394.67 14,500.00 90.84 180.00 3,344.35 3,223.35 -12,494.66 -3,004.98 5,932,903.37 555,862.91 0.00 12,494.66 14,600.00 90.84 180.00 3,342.88 3,221.88 -12,594.65 -3,004.98 5,932,803.40 555,863.69 0.00 12,594.65 14,700.00 90.84 180.00 3,341.42 3,220.42 -12,694.64 -3,004.98 5,932,703.42 555,864.47 0.00 12,694.64 14,728.85 90.84 180.00 3,341.00 3,220.00 -12,723.48 -3,004.98 5,932,674.58 555,864.69 0.00 12,723.48 iJ-180 wp08 T4 14,764.74 89.76 180.00 3,340.81 3,219.81 -12,759.37 -3,004.98 5,932,638.69 555,864.97 3.00 12,759.37 14,800.00 89.76 180.00 3,340.96 3,219.96 -12,794.63 -3,004.98 5,932,603.44 555,865.25 0.00 12,794.63 14,900.00 89.76 180.00 3,341.38 3,220.38 -12,894.63 -3,004.98 5,932,503.45 555,866.03 0.00 12,894.63 15,000.00 89.76 180.00 3,341.79 3,220.79 -12,994.63 -3,004.98 5,932,403.46 555,866.81 0.00 12,994.63 15,100.00 89.76 180.00 3,342.21 3,221.21 -13,094.63 -3,004.98 5,932,303.48 555,867.59 0.00 13,094.63 15,200.00 89.76 180.00 3,342.63 3,221.63 -13,194.63 -3,004.98 5,932,203.49 555,868.37 0.00 13,194.63 15,300.00 89.76 180.00 3,343.04 3,222.04 -13,294.63 -3,004.98 5,932,103.50 555,869.15 0.00 13,294.63 15,400.00 89.76 180.00 3,343.46 3,222.46 -13,394.63 -3,004.98 5,932,003.52 555,869.93 0.00 13,394.63 15,500.00 89.76 180.00 3,343.88 3,222.88 -13,494.62 -3,004.98 5,931,903.53 555,870.71 0.00 13,494.62 15,529.07 89.76 180.00 3,344.00 3,223.00 -13,523.70 -3,004.98 5,931,874.46 555,870.94 0.00 13,523.70 1J-180 wp08 TS 15,549.98 90.39 180.00 3,343.97 3,222.97 -13,544.61 -3,004.98 5,931,853.56 555,871.10 3.00 13,544.61 15,600.00 90.39 180.00 3,343.63 3,222.63 -13,594.62 -3,004.98 5,931,803.55 555,871.49 0.00 13,594.62 15,700.00 90.39 180.00 3,342.96 3,221.96 -13,694.62 -3,004.98 5,931,703.56 555,872.27 0.00 13,694.62 15,800.00 90.39 180.00 3,342.28 3,221.28 -13,794.62 -3,004.98 5,931,603.58 555,873.05 0.00 13,794.62 15,900.00 90.39 180.00 3,341.60 3,220.60 -13,894.62 -3,004.98 5,931,503.59 555,873.83 0.00 13,894.62 16,000.00 90.39 180.00 3,340.92 3,219.92 -13,994.61 -3,004.98 5,931,403.61 555,874.61 0.00 13,994.61 16,100.00 90.39 180.00 3,340.25 3,219.25 -14,094.61 -3,004.98 5,931,303.62 555,875.39 0.00 14,094.61 16,200.00 90.39 180.00 3,339.57 3,218.57 -14,194.61 -3,004.98 5,931,203.64 555,876.17 0.00 14,194.61 16,300.00 90.39 180.00 3,338.89 3,217.89 -14,294.61 -3,004.98 5,931,103.65 555,876.95 0.00 14,294.61 16,400.00 90.39 180.00 3,338.21 3,217.21 -14,394.60 -3,004.98 5,931,003.67 555,877.73 0.00 14,394.60 16,500.00 90.39 180.00 3,337.53 3,216.53 -14,494.60 -3,004.98 5,930,903.68 555,878.51 0.00 14,494.60 16,600.00 90.39 180.00 3,336.86 3,215.86 -14,594.60 -3,004.98 5,930,803.70 555,879.30 0.00 14,594.60 16,700.00 90.39 180.00 3,336.18 3,215.18 -14,694.60 -3,004.98 5,930,703.71 555,880.08 0.00 14,694.60 16,726.41 90.39 180.00 3,336.00 3,215.00 -14,721.00 -3,004.98 5,930,677.31 555,880.28 0.00 14,721.00 1J-180 wp08 T6 16,752.20 91.16 180.00 3,335.65 3,214.65 -14,746.79 -3,004.98 5,930,651.52 555,880.48 3.00 14,746.79 16,800.00 91.16 180.00 3,334.68 3,213.68 -14,794.59 -3,004.98 5,930,603.74 555,880.86 0.00 14,794.59 16,900.00 91.16 180.00 3,332.65 3,211.65 -14,894.56 -3,004.98 5,930,503.77 555,881.64 0.00 14,894.56 17,000.00 91.16 180.00 3,330.63 3,209.63 -14,994.54 -3,004.98 5,930,403.80 555,882.42 0.00 14,994.54 17,100.00 91.16 180.00 3,328.60 3,207.60 -15,094.52 -3,004.98 5,930,303.84 555,883.20 0.00 15,094.52 17,200.00 91.16 180.00 3,326.57 3,205.57 -15,194.50 -3,004.98 5,930,203.87 555,883.98 0.00 15,194.50 17,300.00 91.16 180.00 3,324.54 3,203.54 -15,294.48 -3,004.98 5,930,103.90 555,884.76 0.00 15,294.48 17,326.68 91.16 180.00 3,324.00 3,203.00 -15,321.16 -3,004.98 5,930,077.23 555,884.97 0.00 15,321.16 1J-180 wp0& T7 17,338.42 90.81 180.00 3,323.80 3,202.80 -15,332.89 -3,004.98 5,930,065.50 555,885.06 3.00 15,332.89 10/11/2006 3:20:38PM Page 8 of 10 COMPASS 2003.11 Build 50 ORIGINAL Con~coPhillips Alaska Database: _EDM_2003.11_b48 Locai Co-orciinate Referent®: Well Plan 1J-180.. Company: ConocoPhillips Ala ska, Inc. TVD Reference : Doyon 15 (4 0+g1} @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (4 0+81) @ 121.OOft (Doyon 15 (40+g1)) ~ Site: Kuparuk 1J Pad North Referenc e: True Well: Plan 1J-180 Survey Calcula tion Method: Minimum C urvature Wellbore: Plan 1J-180 Design: 1J-180 (wp08) Planned Survey 1J-180 (wp08) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (1t) (ft) (ft) lft) (ft) lft) (°1100ft) (ft) 17,400.00 90.81 180.00 3,322.93 3,201.93 -15,394.47 -3,004.98 5,930,003.93 555,885.54 0.00 15,394.47 17,500.00 90.81 180.00 3,321.51 3,200.51 -15,494.46 -3,004.98 5,929,903.95 555,886.32 0.00 15,494.46 17,600.00 90.81 180.00 3,320.10 3,199.10 -15,594.45 -3,004.98 5,929,803.97 555,887.10 0.00 15,594.45 17,700.00 90.81 180.00 3,318.69 3,197.69 -15,694.44 -3,004.98 5,929,704.00 555,887.88 0.00 15,694.44 17,800.00 90.81 180.00 3,317.27 3,196.27 -15,794.43 -3,004.98 5,929,604.02 555,888.66 0.00 15,794.43 17,900.00 90.81 180.00 3,315.86 3,194.86 -15,894.42 -3,004.98 5,929,504.04 555,889.44 0.00 15,894.42 17,960.70 90.81 180.00 3,315.00. 3,194.00 -15,955.11 -3,004.98 5,929,443.36 555,889.91 0.00 15,955.11 BHL ~ 17961' MD, 3315' ND: 2052' FS L, 184' FEL - Sec15-T10N-R 10E - 4 1/2" - 1J-180 wp08 Toe Geologic Targets Plan 1J-180 TVD Target Name +Nl-S +E7-W Northing Easting (ft) -Shape ft R (ft) ift) 3,315.00 1J-180 wp08 Toe -15,955.11 -3,004.98 5,929,443.36 555,889.91 - Point 3,345.00 1J-180 wp08 D Top -8,318.31 -3,029.30 5,937,079.00 555,806.00 - Point 3,341.00 1J-180 wp08 T4 -12,723.48 -3,004.98 5,932,674.58 555,864.69 - Point 3,336.00 1J-180 wp08 T6 -14,721.00 -3,004.98 5,930,677.31 555,880.28 - Point 3,392.83 1J-180 wp08 (West Turn Point) -9,989.90 -3,000.17 5,935,407.85 555,848.17 - Point 3,360.00 1J-180 wp08 T3 -11,424.13 -3,004.98 5,933,973.76 555,854.55 - Point 3,324.00 1J-180 wp08 T7 -15,321.16 -3,004.98 5,930,077.23 555,884.97 - Point 3,414.00 1J-180 wp08 T1 -9,124.53 -3,014.59 5,936,273.00 555,827.00 - Point 3,344.00 1J-180 wp08 TS -13,523.70 -3,004.98 5,931,874.46 555,870.94 - Point 3,392.00 1J-180 wp08 T2 -10,023.76 -3,004.98 5,935,373.96 555,843.62 - Point Halliburton Energy Services Planning Report -Geographic Drilling and Formation Evaluation 10/11/2006 3:20:38PM Page 9 of 10 COMPASS 2003.11 Build 50 ORIGINAL ConocoPhillips Alaska Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-180 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-180 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-180 Design: 1J-180 (wp08) Prognosed Casing Points Measured Vertical Casing Hole- Depth Depth Diameter Diameter (ft) (ft) (~~} (~~) 3,878.25 2,142.00 13-3/8 16 10,784.74 3,411.76 9-5/8 12-1/4 17,960.69 3,315.00 4-1/2 6-3/4 i i Prognosed Forma tion Intersect on Po nts Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (~) (°) (°) (ft) {ft) (ft) Name 1,696.94 47.14 210.00 1,546.00 -451.08 -260.43 Base Perm 1,849.26 52.97 208.16 1,645.00 -551.99 -316.92 K15 2,849.70 79.13 202.25 1,948.00 -1,414.51 -693.98 T3 3,878.25 79.13 202.25 2,142.00 -2,349.37 -1,076.50 T3+550 7,377.43 79.13 202.25 2,802.00 -5,529.80 -2,377.85 Ugnu C 8,379.70 79.15 198.63 2,991.00 -6,444.76 -2,740.27 Ugnu B 8,779.33 79.22 194.56 3,066.00 -6,820.86 -2,852.34 Ugnu A 9,570.02 79.53 186.52 3,212.00 -7,584.22 -2,994.33 K13 10,271.42 79.97 179.41 3,337.00 -8,273.03 -3,029.95 WSAK D 10,317.41 80.00 178.94 3,345.00 -8,318.31 -3,029.30 WSAK C 10,473.25 80.33. 178.94 3,372.00 -8,471.77 -3,026.46 WSAK B r - Plan Annotations - - Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (ft) (ftl (ft) (ff) 40.00 40.00 0.00 0.00 SHL: 1508' FSL, 2443' FEL - Sec35-T11 N-R10E 3,878.25 2,142.00 -2,349.37 -1,076.50 13 318" Casing @ 3878' MD, 2142' TVD: 742' FNL, 1758' FWL 10,784.74 3,411.76 -8,780.57 -3,020.75 9 5/8" Casing @ 10785' MD, 3412' TVD: 1894' FNL, 193' FEL - Sec10-T10N-R10E 17,960.69 3,315.00 -15,955.10 -3,004.98 BHL @ 17961' MD, 3315' TVD: 2052' FSL, 184' FEL - Sec15-T10N-R10E Halliburton Energy Services Planning Report -Geographic lir.~ Griming and Poomation Evaluation 10/11/2006 3:20:38PM Page 10 of 10 COMPASS 2003.11 Build 50 ORIGINAL ~ • ConocoPhillips Alaska Plan: 1J-180 (wp08) Sperry Drilling Services Anticollision Summary 13 October, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-180 Plan 1 J-180 Local Coordinate Origin: Centered on Well Plan 1J-180 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet '~ , >z~~~ "~'a. __ '"~>~..{~""; ~ s .rte. ~. _,: , .Yy23 .. ,~.`, ~~:~;y~a, `,t ~ Sperry Drilling Services ~~~~~. SURVEY PROGRAM NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-180 COMPANY DETAILS: ConocoPhillips Alaska, Inc. ANTI-COLLISION SETTINGS Ground Level: 0.00 Engineering Date: ZUWILLIJTW:W:W Validated: Y4•s Vcnion: 21.000 Interpolation Method: MD Interval: 50Stations +N/S +EI-W Northing Easing Latittude Longitude Slot Calculation Method: Minimum Curvature Depth Frum Depth To Sun-cc/Plan Ttrol Depth Range From: 0.00 To 17960.70 0.00 0.00 5945419.90 558770.00 70°15'41.044N 149°71'29.701 W Error System: ISCWSA OJNI 11511.IN1 IJ-1811 (141NIN) C6G1'RO-SS Maximum Range:1986.19070J55859 Scan Method: Trav. Cylinder North II5l1.W l7YLU.7U IJ-180 pr11UN) MWD+IFR-AK-CAZSC Reference: Plan: 1J-180 (wp08) Errw Surface: Elliptical Conic Warning Method: Rules Based 1J-173 Pilot (wpO6) - - ~ 1J-156L1 1 0 ~ i 1J-174(wpO1) 270 1J-176 (wpO 1. 18D I (wpO2) 133 (wp06) •135 (wpO2 -136 (wpOB L1 (wp13) Rig Travelling Cylinder Azimuth (TFO+AZI) [°~ vs Centre to Centre Separation (75 ft/i6fom Colour To MD 0 ~ 250 2750 3000 8000 '!°- 8500 11500 11750 250 500 3000 3500 8500 ' " 9000 11750 - " "~'- 12000 500 750 3500 4000 9000 9500 12000 - 12250 750 1000 4000 4500 9500 9750 12250 12500 1000 1250 4500 5000 9750 ~ 1000012500 12750 1250 1500 5000 5500 10000 10250 12750 13000 REFERENCE INFORMATION 1500 1750 5500 6000 10250 10500 13000 13500 1750 -~ "-'- 2000 6000 6500 10500 10750 13500 14000 Co-ominate (wE) Reference: Well Plan 1J-180, True North Vertical (TVD) Reference: Doyon 15 (4o+8t) @ 121AOtt (Doyon 15 (40+81 )) 2000 -- 2250 6500 - " - 7000 10750 11000 14000 0 Section (VS) Reference: Slot - (O.OON, O.OOE) 2250 - 2500 7000 7500 11000 11250 Measuretl Depth Reterence: Doyon 15 (d0+81) @ 121.OOtt (Doyon 15 (40+81)) Calculation Method: Minimum Curvature 2500 2750 7500 8000 11250 11500 90 84c 8x1 Inc Au TVD +W.B +FJ.W OLa9 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFace Vsec Tvgel 0.00 0.00 2 300.00 0.00 0.00 )00.0° 0.00 0.00 3 ]02.06 10.06 21000 ]00.00 -]048 -1].69 0.00 3.50 0.00 0.00 210% 30.06 d 1629.31 0].14 210.00 1500.00 JOH.i6 -236.66 5 1)29.11 0].14 21000 156801 Jit.bl -28.30 400 000 0.00 608.16 0.00 6)1.63 6 2J8] 12 ]913 201.25 1859.99 A90.03 620.66 ] 8023.56 19.13 202.25 2923.87 .611).0) .2618.10 5.00 000 -14.19 990.43 0.00 611].0] H 1031]41 80.00 1]896 336680 8318.31 -3019.10 9 10051.61 80.00 1)0.94 3368.1] -8650.25 302686 1.00 0.00 8999 8318.]1 11180 wy08°TOp 0.00 8650.25 10 10)86.]6 85.00 1]0.94 3411]6 -8)80.5] 3020.]5 11 10004.]4 85.00 1]8.90 ]013.51 880009 J020.JH 1.60 0.00 0.00 8]80.5] 0.00 880069 12 1092508 91.02 1)8.99 301].69 -0920.68 -3018.20 3 11116]0 91.02 1)099 3616.38 -9112.26 301401 6.00 0.00 O.M 8920.68 0.00 9112.26 1112899 91.6) 1]8.95 3914.00 -91265) 3014.69 15 1113129 91A0 1]9.05 3413.]0 -913282 3010.66 5.00 3.00 .3.33 9126.5] 11180 wp%Ti 1fi).3H 91)2.82 16 11990.]0 91.40 1]9.05 J392.BJ -9989.90 3000.1] 1] 120)).62 91.31 18021 JJ91.91 -10028.]) -2%9.92 0.00 3.00 0.00 9989.90 1)-180 wpOH IWesI TUm Point) 96.38 10028.]] 18 13012.p6 9171 180.21 J3fi0.R -1100683 )004.95 19 13429.36 9084 180.00 SJfi0.00 .11626.13 ]004.98 0.00 9.00 0.00 11406.03 -i%.23 11426.13 1)180 wp08 T3 30 t173a e5 %86 18D.00 ]30100.12123.08 -3004.98 3t 1d)64.74 89.]6 18000 ] -12169.3] 3004.99 000 3.00 000 12]23.48 1}180 wp08 TO -190.00 12]59.3] 12 15539.0] 89]6 18000 J3d4.D0 -13523.]0 3001.% IJ 15509.98 % 18000 330.1.9]-11644.61 300688 0.00 ].00 0.00 13523.70 11180 wp08 TS 0.00 13546.61 Id 16]26.61 90.39 18000 ]3]6.00 14]21.00 3004.98 15 16]53.20 91.16 180.00 3336.65 ~10)0fi.T9 )004.% 0.00 3.00 0.00 1/]21.00 11180 wp0H T6 0.00 16166.]9 16 1]32668 91.16 180.00 3324.00 16321.18 3000.98 0.00 0.00 15321.16 11180 wp08 T) I] 1]]]842 %.H1 180.00 3333.00.15331.89 3000.98 38 1]%° ]0 %.H1 180.00 3315.00 -15956.11 3000.98 J.00 0.00 1)991 1531289 0.00 1595511 11180 wp08 Tce 180 Travelling Cylinder Azimuth (TFO+AGI) (°J vs Centre f0 Centre Separafion X15 ft/inJ Halliburton Com an P Y Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 10/43/2006 time: 13:11:31 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate(NF.) Reference: Well: Pla n 1J-180, Tr ue North Reference Well: Plan 1J-180 ~'crtical (f~~D) Referen ce: Doyon 15 (40+81) 12 1.0 Reference ~1'ellpath: Plan 1J-180 - - Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Princi pal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.00 to 17960.70 ft Scan Method: Trav Cylinder North Maximum Radius: 1992.07 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/17/2006 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 40.00 800.00 Planned: 1 J-180 (wp08) V1 CB-GYRO-SS Camera based g yro single shot 800.00 17960.70 Planned: 1J-180 (wp08) V1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Casing Points ~lU T~°D Diameter Hole Size \'ame ft ft in in 3236.73 2021.00 13.375 16.000 13 3/8" 10784.75 3411.76 9.625 12.250 9 5/8" 17931.82 3315.41 4.500 6.750 41/2" Summary <---------------------- Offset 44"cllpath ----------------------> Reference Offset Ch•-Ctr 1o-Go Allowable Site Well ~i'cllpath AiD MD Distance .Arta Des"iation 4b'arning ft ft ft ft ft Kuparuk 1J Pad 1J-127 1J-127 V4 322.02 325.00 178.20 6.02 172.18 Pass: Major Risk Kuparuk 1J Pad iJ-127 1J-127L1 V1 322.02 325.00 178.20 5.89 172.31 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1PB1 V2 322.02 325.00 178.20 6.13 172.07 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V1 322.02 325.00 178.20 5.89 172.31 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB1 V1 322.02 325.00 178.20 6.13 172.07 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB2 V1 322.02 325.00 178.20 6.13 172.07 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 V2 286.99 275.00 148.23 5.65 142.57 Pass: Major Risk Kuparuk 1J Pad 1J-133 Plan 1J-133 L1 V2 Plan 324.09 325.00 147.83 6.91 140.92 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V10 749.50 725.00 149.24 10.48 138.76 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L1 V2 310.09 300.00 599.46 5.38 594.08 Pass: Major Risk Kuparuk 1J Pad 1J-152 1J-152L2 V1 310.09 300.00 599.46 5.38 594.08 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L1 V1 10319.13 12963.00 78.08 31.47 46.61 Pass: Minor 1/200 Kuparuk 1J Pad 1J-156 1J-156L2 V1 9922.45 12566.00 93.96 32.96 61.00 Pass: Minor 1/200 Kuparuk 1J Pad 1J-168 1J-168 V5 404.13 400.00 240.43 7.51 232.92 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V3 404.13 400.00 240.43 7.38 233.05 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V2 404.13 400.00 240.43 7.38 233.05 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2PB1 V1 404.13 400.00 240.43 7.62 232.81 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V2 286.99 275.00 201.80 5.65 196.15 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V1 286.99 275.00 201.80 5.52 196.28 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V1 286.99 275.00 201.80 5.52 196.28 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P61 V1 286.99 275.00 201.80 5.76 196.04 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P82 V1 286.99 275.00 201.80 5.76 196.04 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184 V5 645.14 625.00 77.39 9.18 68.22 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184L1 V5 645.14 625.00 77.39 9.02 68.37 Pass: Major Risk Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 345.41 350.00 232.34 7.35 224.99 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V2 Plan: 1 300.00 300.00 216.80 6.45 210.35 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V2 Plan: 1 323.52 325.00 158.17 6.95 151.22 Pass: Major Risk Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V2 Plan: 1 323.66 325.00 151.66 6.94 144.72 Pass: Major Risk Kuparuk 1J Pad Plan 1J-132 1J-132 V2 Plan: 1J-132 323.95 325.00 146.27 6.77 139.50 Pass: Major Risk Kuparuk 1J Pad Plan 1J-135 Plan 1J-135 V0 385.82 375.00 158.49 6.60 151.89 Pass: Major Risk Kuparuk 1J Pad Kuparuk 1J Pad Plan 1J-136 Plan 1J-136 1J-136 L1 V1 Plan: 1J- 1J-136 V2 Plan: 1J-136 398.11 398.11 400.00 400.00 167.14 167.14 7.97 8.13 159.17 159.01 Pass: Major Risk Pass: Major Risk Kuparuk 1J Pad Plan 1J-173 1J-73 Kuparuk Producer 347.86 350.00 140.82 6.49 134.33 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V1 Plan: 625.91 625.00 121.03 9.80 111.23 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 VO Plan 625.91 625.00 121.03 9.91 111.12 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan: 1J-176 L1 VO Pla 750.57 750.00 72.13 13.40 58.73 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan: 1J-176 VO Plan: 750.57 750.00 72.13 13.40 58.73 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V2 Pla 621.24 625.00 31.90 9.62 22.28 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V2 Plan: 621.24 625.00 31.90 9.62 22.28 Pass: Major Risk Kuparuk 1J Pad Plan 1J-180 Plan 1J-180 L1 V1 Plan 10300.00 10300.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-L14(BQ) Plan 1J-L14(BO) VO Pla 338.74 325.00 247.71 7.04 240.67 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L15(BP) Plan 1J-L15 D Lateral 288.00 275.00 231.96 5.56 226.40 Pass: Major Risk ORIGIf~~~ lli n om an Ha burto C p y Anticollision Report f Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Rcference~~"ell: PIan1J-180 Reference ~1'ellpaUr Plan 1 J-180 Summary I ~---------------------- Offset yy'cllpath --------------------~ Site ~~'ell ~~'ellpath Kuparuk 1J Pad Kuparuk 1J Pad Kuparuk 1 J Pad Kuparuk 1J Pad Kuparuk 1J Pad Kuparuk 1J Pad Kuparuk 1 J Pad Kuparuk 1J Pad Kuparuk 1J Pad Kuparuk 1 J Pad Kuparuk 1J Pad Kuparuk 1 J Pad Kuparuk 1J Pad Kuparuk 1J Pad Kuparuk 1J Pad Kuparuk 1 J Pad Kuparuk 1J Pad Kuparuk WT Pad Plan 1J-014 (BM) Plan 1J-015(60) Rig: 1 J-137 Rig: 1 J-137 Rig: 1J-137 Rig: 1J-137 Rig: 1 J-182 Rig: 1 J-182 Rig: 1 J-182 Rig: 1J-182 WSP-07 WSP-08 WSP-09 WSP-10 WSP-11 WSP-12 WSP-13 WT-04 1J-014 B Lateral VO PI 1J-015 D Lateral VO PI Rig: 1J-137 L1 PB1 VO Rig: 1J-137 L1 P62 V0 Rig: 1J-137 L1 VO Rig: 1J-137 VO Plan: 1J-182 L1 V5 Pla Plan: 1J-182 V1 Plan: Rig 1J-182PB1 V1 Rig: 1J-182 V7 WSP-07 V1 WSP-08 V2 WSP-09 V1 WSP-10 V1 WSP-11 V1 WSP-12 VO WSP-13 V1 WT-04 VO Uate: 1 0/1 312 006 Time: 13:11:31 Yaffe: 2 I Co-ordinate(NF,) Reference: Well: Plan 1J-180, True North y'ertical ('1'VU) Reference: Doyon 15 (40+81) 121.0 Ub: Oracle Reference Offset Ctr-Ctr V'o-Go Allowable ~1U D1D Uistancc :1rea Deviation Vk'arning ft ft ft ft ft 288.00 275.00 189.23 5.55 183.68 Pass: Major Risk 288.00 275.00 216.83 5.56 211.27 Pass: Major Risk 361.25 350.00 178.60 9.13 169.47 Pass: Major Risk 361.25 350.00 178.60 9.13 169.47 Pass: Major Risk 361.25 350.00 178.60 9.13 169.47 Pass: Major Risk 361.25 350.00 178.60 9.13 169.47 Pass: Major Risk 883.39 875.00 43.30 13.66 29.64 Pass: Major Risk 883.39 875.00 43.30 13.81 29.49 Pass: Major Risk 199.99 200.00 40.78 4.23 36.55 Pass: Major Risk 1010.57 1000.00 43.87 17.54 26.33 Pass: Major Risk 367.35 375.00 228.99 9.80 219.19 Pass: Major Risk 382.41 375.00 198.63 11.70 186.94 Pass: Major Risk 346.19 350.00 182.00 7.98 174.02 Pass: Major Risk 363.29 350.00 185.49 7.94 177.54 Pass: Major Risk 421.17 425.00 206.61 8.71 197.91 Pass: Major Risk 620.58 625.00 245.84 13.70 232.13 Pass: Major Risk 766.86 750.00 280.74 14.45 266.28 Pass: Major Risk Out of range ORIGINAL 10 3/4" ~ CASING DETAILS No TVD MD Name Size 1 2142.00 3878.25 13 3/8" 13-3/8 2 3345.17 10318.41 9 5/8" TOW 9-5/8 i 16" 3 3246.00 17861.90 4 1/2" 4-1/2 o Project: Kuparuk River Uni ~' 700 Site: Kuparuk 1J Pad Well: Plan 1J-180 -100° Wellbore: Plan 1J-180 L1 1a Plan: 1J-180 L1 (wp08) 1~l ?p~0 -2000 s 1l ` 13 3/8" -3000 ?~2 ~ -4000 ~~ i -5000 -6000 3880 / 1J-152 L2 0 L ~~ 0 1J-152 L1 1~----- N 190° Jl =- 9 5/8" TOW J l J - - - - - ~ ___ -- 1J-156L2 o --- Ji Z J ~ 180---~ -- 1J-156L1 t 95/8"----- -------ll '~ 3 ~ / ~ ~ 179 ~' F 180° -lzooo 180° -13000 180° T M 1J-178 L1 (wp01) Magnetic North: 24.09° Magnetic Field -14000 `' ~1l 1 J-178 (w 01) - - - ~ 180° Strength: 57563.7nT Dip Angle: 80.77° p Dale' 5/17/2006 Model: BGGM2005 -lsooo i ' 1J-180 L1 (wp08) 180° - ~ _ 1J-180 (wp08) _ _ _ _ _ ~ _ 180° = " 1 J-182 L1 (wp13) -lsooo ll :41/2 C OtlOCO~'tl)~I S 4 1/2" 182 (w 13) 1J - _ _-_-__- ___. P p - Fonmetion t ~~ Evel uetlon -17000 -8 000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 OR161NAL Drilling sad Formetlo~ Evaluation i i No TVD MD Name Size 1 2142.00 3878.25 13 3/8" 13-3/8 2 3345.17 10318.41 9 5/8" TOW9-5/8 3 3246.00 17861.90 4 1 /2" 4-1 /2 CASING DETAILS 0 ?~~o ~~~0 6~~~ o° ° o0 ~o Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-180 Wellbore: Plan 1J-180 L1 Plan: 1 J-180 L1 (wp08) ConocoPhillips Alaska 7 6p~O / ~~~0 ~~~0 0 -z~ao _-~~~o 6pQ~ g ~ ~ 0 / ~~O O~ ~~~0 ~~~ ~~O ~~ ~~ ~~ N Closest In Pool 1J-180 (wp13) B-Sand ®...® e..~ ~^+ Closest A roach: Reference Well : 1J-180 w 08 Plan Offset Well: 1J -152 L1 Coords, - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. ND E(+)/W(_) (180°) Comments De th Incl. Angle TRUE Azi. ND E(+)/W(-) (180°) Comments POOL Min Distance POOL Min Distance (1726.04 ft) in POOL (1726.04 ft) in POOL (10473.25 - 17960.7 (10473.25 - 17960.7 MD) to 1J-152 L1 (5747 MD) to 1J-1S0 (wp08) 1726.04 10473.25 80.33 178.94 3250.806 5936924 555810.4 8471.908 13408 MD) 13408 90.87 172.05 3314.96 5938174 556999 7231.343 Plan (5747 - 13408 MD) Closest A roach: Reference Well : 1J-180 w 08 Pian Offset Well: 1J -156L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. ND E + /1/V - 180° Comments De th Inci. An le TRUE Azi. ND E + /W - (180° Comments POOL Min Distance POOL Min Distance (172.98 ft) in POOL (172.98 ft) in POOL (10473.25 - 17960.7 (10473.25 - 17960.7 MD) to 1J-156L1 (5747 - MD) to 1 J-180 (wp08) 172.98 " ° 10473.25 80.33 178.94 3250.806 5936924 555810.4 8471.908 12963 MD) 12963 89.81 174.08 3298.752 5937089 555786.3 8307.287 Plan (5747-12963 MD) Closest A roach: Reference Well : 1J-180 w 08 Plan Offset Well: 1J -178 w 01 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - (180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments P OL Min Distance P Min Distance (1326.47 ft) in POOL (1326.47 ft) in POOL (10473.25 - 17960.7 (10473.25 - 17960.7 MD) to 1J-178 (wp01) MD) to 1J-180 (wp08) (10755.79 - 16383.34 Plan (10755.79 - 1326.47 16025 90.39 180 3219.584 5931377 555875.4 14019.76 MD) 16383.34 89.97 179.15 3157.685 5931365 554550.4 14020.97 16383.34 MD) Closes t A roach: Reference Weil : 1J-180 w 08 Plan Offset Well: 1J -182 w 13 Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. ND E(+)/W(-) (180°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(-) (180° Comments P OL Min Distance P L Min Distance (1195.26 ft) in POOL (1195.26 ft) in POOL (10473.25 - 17960.7 (10473.25 - 17960.7 MD) to 1J-182 (wp13) MD) to 1J-180 (wp08) (9766.79 - 17824.43 Plan (9766.79 - 1195.26 11850 91.4 179.05 3275.176 5935551 555845 9845.362 MD) 11450 91.07 179.42 3297.117 5935589 557039.5 9816.738 17824.43 MD) • • 1J-180~rilling Hazards S~nmarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole 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, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Intermediate Hole Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud wei ht Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming ("~ t /1 ~ 1J-180 Drilling Hazards Summary H~-(, 11 1~-1~ 10/4/2006 10:37 AM ~' ' Schlumberger CemCADE Preliminary Job Design 9-5/8" Intermediate Casin V1 - w 06 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 8/15/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com Revious Csg. < 13 3/8", 72.0# casing at 3,878' MD < Top of Tail at 6,877' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 10,785' MD (3,412' TV D) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 3908' MD annular length. Tail Slurry Minimum thickening time: 295 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3908' x 1.25 (25% excess) = 1530.0 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1530.0 ft3 + 34.1 ft3 = 1564.1 ft3 1564.1 ft3/ 2.25 ft3/sk = 695.2 sks Round up to 700 sks BHST = 79~, Estimated BHCT = 69~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (mint CW 100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW 100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 278.6 55.7 95.7 Drop top plug 0.0 0.0 5.0 100.7 Water 5.0 20.0 4.0 104.7 Switch to rig 0.0 0.0 5.0 109.7 Mud 7.0 782.7 111.8 211.7 Slow & bump plug 3.0 9.0 3.0 214.7 MUD REMOVAL Recommended Mud Properties: 9.3 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend • 2 per joint on shoe track • 1-'/ perjoint until 300' and above West Sak • 1 perjoint across all Ugnu OR!GIN4~ Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Casin V1 - wp06 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 8/15/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. ~ < 20", 91.5# casing at 80' MD ~, < Base of Permafrost at 1,697' MD (1,546' TV D) ~{ < Top of Tail at y 3,078' MD l i, < 13 3/8", 72.0# casing in 16" OH I i TD at 3,878' MD ~ (2,142' ND) Mark of Schlumberger 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 3,078' MD. Lead Slurry Minimum pump time: 310 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1697' - 80') x 3.50 (250% excess) = 2380.4 ft3 0.4206 ft3/ft x (3078' - 1697') x 1.35 (35% excess) = 784.1 ft3 81.5 ft3 + 2380.4 ft3+ 784.1 ft3 = 3246 ft3 3246 ft3 / 4.45 ft3/sk = 729.4 sks Round up to 730 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3878' - 3078') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 45`F, Estimated BHCT = 63`F. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW 100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 578.1 82.6 115.9 DeepCRETE 6.0 92.9 15.5 131.4 Drop top plug 0.0 0.0 5.0 136.4 Water 5.0 20.0 4.0 140.6 Switch to rig 0.0 0.0 5.0 145.6 Mud 7.0 539.7 77.1 222.7 Slow & bump plug 3.0 9.0 3.0 225.7 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH'` II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 2 per joint throughout tail slurry column ORIG~~J41 0 z r- • • SHARON K. ALLSUP-DRAKE 1159 CONOCOPHILLIPS ATO 1530 /~ ~G~06°4/G~~f 700 G ST. DATE / ~"~-1551 /441 ANCHORAGE AK 9950y1~ ,c, G ~/~,,y~~ Q ~ y^~ ORDER OFE ~~/l ~(i D/ / / ~~ ~ '/ ' `~''( ~~_~~ I J+ /~~ L.L/ ~~~~Ot~RS LLI ~Mm~ JPMorganChase ~j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH /L` - roP MEMO ------- ---- -------- --- ~:044 L L55 1 L~:S 28747 19079 2711' L L59 • PT®~ ZU(o -~ l~n ®evelopment Ser`•ice Exploratory Stratigraphie 'l'est lion-Conventional W"ell ~'~~iSi~I~'T'~I. UTTER CHEC'KI.I~T • Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK 41~'HAT APPLIES r ADD-ONS (OPTIONS) TEXT FOR APPROVAL LETTER NfULTI LATERAL ~~ The permit is for a new weil6ore segment of existing , well , ~~ (If last two digits in ;Permit No , API No. 30- API number are - - - between 60-69) Production should continue to be reported as a function of the original API number stated above. ,PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both i ;well name ( PH) and API number r ~~0- - -) from records, data and logs I acquired for well i SPACING i The permit is approved subject to full compliance with 20 AAC EXCEPTION ;' 2~.0>j. Approval to perforate and produce i inject is contingent upon issuance of a conservation order approving a ;pacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH A1[ dry ditch sample sets submitted to the Commission must be in SAMPLE ' no greater than 30' sample intervals from below the permafrost or i !from where samples are first caught and 10' sample intervals i i through target zones. I INon-Conventional Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed Welt ~ 0 'for name of well) until after (Com~anv Name) has designed and i implemented a water well testing program to provide baseline data ~~ on water quality and quantity. (Company Name) must contact the ~~ ;Commission to obtain advance approval of such water wel[ testing nrn rtram Rev: l ZS%06 C'jod~`xransmitta! checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL-490150 Well Name: KUPARUK RIV UNIT 1J-180 Program SER _ Well bore seg ^ PTD#:2061500 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER 1 PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Administration 1 Permit_feeattached_____________________________________---.-_ Yes _----_ _______ -- 2 Lease number appropriate_ - - _ _ - - _ - - - No- . Corrected 401for_m: Surface location in_ADL_025661; well_passes through ADL 025662, topprodr~ctive interval-in - 3 Uniquewell_nameandnumber_____________________________________ _Yes_ _,.-_-ADL 025663,andTDinADL385172(ADL25672.expiredin_1994),-__-_____-..__-__,_.-__-_-- 4 Well located in a_d_efned-pool______________________________________ Yes- _- __KuparukRiver,West_SakOilPool-490150,_governed_byCO406B,_--.-,-__ __---_,_______--- 5 Well located proper distance-from drilling unit_boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . . _ _ _ _ _ Well is more than_500 feet from an external property line. _ - - - - - _ _ _ .. - - . - - - - - .. - .. - - - - _ - - - 6 Well located proper distance f[o_m other wells_ Yes - - - - .. CO 406B, Rule 3; no restrictions as-to well spacing except that no-pay shall be gpened in a well closer - - _ . - _ 7 Sufficient acreage available in-drilling unit_ Yes . .. than 500 feet to_an,externaLptoperty line where ownershi or la-ndownershi than es, p P- 9 - 8 If_deviated,is_wellboreplat_included---------------------------- ----- -Yes- _-_____ --..- 9 Operator only affected party -_________ __ _Yes_ _____________________ 10 Ope[atorhas_appropriate_bondinforce--_____--__-_--____._- Yes- _____.-._- 11 Permit_canbeissuedw)thoulconservationorder_______ _____________.___ Yes_ --_____ __--__--_ Appr Date 12 Permitcanbeissuedwithoutadministrative_appr_oval___________________ ____ _Yes_ -_----_______----_--_____.--______..-._ SFD 10/17!2006 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._26 - - . _ 15 All wells within 114_mile area_of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - . _ . - .KRU 1J-156_and laterals, KRt11J-182 and_1J-182L1, - _ - _ _ - _ _ _ _ - - _ _ - . ------------------ 16 Pre-produced injector: duration of pre production less than_ 3 months-(For service well only) Yes . _ _ - - _KRU 1J-Pad_ injection wells are-typically pre-produced 30-45 days for cleanup__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 tJonconven,gasconfcrmstoAS31,04,030Q.1.A),(~.2.A-D)---_______.___-___- -NA__ __________________________________ Engineering 18 Conductorstrin9-provided - - Yes - 19 SurfacecasingprotectsallknownUSDWS---------- ------------------- -NA-_ ___Allaquifers exempted, 30CFR_147.102_(b)(3).-___ _-_----_____ .-- ___ ----___________ 20 CMT_vol-adeguate_to circul_ate.on conductor_& surf_csg _ - - - - Yes - - - - _ - - 21 CMT_vol adequate_to tie-in long string to surfcsg- - - No_ _ - All hydrocarbons fo_be_c_oyered. Annular_disposal_ma _be_ ro osed, Y P p 22 CMT_will cover all knownpro_ductiye horizon_s_ - . - - No_ Slotted linercompletionp/armed.- - - - 23 Casing designs adequate for C,T,B&-petmafrost____________________ Yes_ ____ ------_-_____----_-_ __----________---___._..-______.- --_--_----.-- 24 Adequate tankage_or reserve pit - - - - - - - Yes Rig is_equipped with steelpits. _ No r_eserve_pitplanned, All waste to_approyed annulus or disposal well.- 25 If_a_re-drill,has_a_1.0-403 for abandonment been approved______________________ NA-_ --________-_--_-______..---___-_-.--_-__---_-_.__-_....-_ -__.____--_--_ 26 Adequate wellbore separation-propos-ed- - - - - - - - - - - - - - - --- - - - - - - - - - - - - - - Yes - - - _ . - .Proximity analysis performed, Traveling cylinder path calculated, Gyros likely, - . _ .. _ _ _ _ - _ _ _ _ _ - _ _ _ _ _ 27 Ifdive[terrequired,doesitmeetregulations-_______ ___________________ _Yes_ _________-_--_______---._ __-_-----_____._-..______---_____--_-______-_.. Appr Date 28 Drilling fluid_program schematic & equip list adequate_ . - - - - - - . Yes . . Maximum expected fo[matipn pressure 8,6_EMW._ Planned MW 9.0_ppg. - . _ _ _ T 0612006 29 BOPES, do they meet_ regulation - - Yes _ _ - - - - - . - . - - 30 8OPE-press rating appropriate; test to (put psig incomments)- - . Yes - - _ MASP calculated at 11.19 psi 3K equipment set up an_d test pressure_planned. - - 31 Choke_manifoldcomp_Iiesw/API-RP-53~M_ay 84)_______ ____________________ Yes_ -__--________--_--___-_--______ 32 Work willoccurwithoutoperationshutdown---------- ------------------- -Yes_ _-.-..._ i 33 Is presence-of H2S gas probable- --- - - - - - - - - -- - - - - - - - - - - - - - - - - - -- - -- - No_ _ _ - _ - . - H2S has not_been reported at 1J.pad._ Rig is_equipped with sensors and alarms... _ - - - - - - _ - - - - . - - - _ - 34 Mechanical condition of wells within AOR verified (F9r_service well only) _ - - _ Yes - _ _ _ There are no penetrations into the WS within 1/4 mile. _Any AOR-approach-is in zone. - Geology 35 Permit_can be issued w!o hydrogen_ sulfide measures - - - - - -Yes - - - H2S ha_s not been encountered in W Sak_wells drilled to the_south from 1,1-Pad. _ - - 36 Data_presented on potential overpressure zones _ . _ _ _ - Yes - Expected r_es._pre_ssure is ~8.6ppg EMW, will be drilled with 9.0 ppgoil,based_mud, Nlud weight will be . - _ . _ - Appr Date 37 Seismic analysis_of shallpw gas_zones_ - _ _ - - - - - - - . - - - - - . - - - NA- - . - - - adjusted as needed. No shallow_gas expected. -Mud program notes use-of 9.6 ppg mud if hydrates_ SFD 10/17!2006 38 Seabed condi6onsvrvey-(ifoff-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - _ _ _ _ are encountered. _ - - - - - _ _ - - -- 39 Contact nameJphone for weekly-progress reports_ [exploratory only] . - - - _ NA_ _ Geologic i C i Date: Engineering Date Public Date i l C C i West Sak B sand producer. This is the main wellbore for adual-lateral injection well. SFD om i omm oner: omm ss oner: oner ss ~~~ ~~ f ~n~~ ~ ~-~~-` /o- 3~-v-d" • • Well History File APPENDIX Information of detailed nature that is not particu-arly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 17 17:12:40 2007 Reel Header Service name ........... ..LISTPE Date ................... ..07/04/17 Origin ................. ..STS Reel Name .............. ..UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments ............... ..STS LIS Writing Library Tape Header Service name ........... ..LISTPE Date ................... ..07/04/17 Origin ................. ..STS Tape Name .............. ..UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments ............... ..STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: W-0004794615 LOGGING ENGINEER: R. WILSON OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services 1J-180 500292332900 ConocoPhillips Alaska Inc Sperry Drilling Services 17-APR-07 MWD RUN 4 MWD RUN 6 W-0004794615 W-0004794615 B. HENNINGSE O. OBI M. THORNTON F. HERBERT 35 11N l0E 1608 2443 121.40 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 4000.0 2ND STRING 6.750 9.625 10845.0 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. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 9UC~-~SO ~ t51(O l J • 1J-180 PB1 WELLBORE AT 2790'MD/2024'TVD. 1J-180 PB1 WAS SIDETRACKED DUE TO EXCESSIVE DOG-LEG VALUES. NO DATA ARE PRESENTED FOR THE 1J-180 PB1 WELLBORE. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO MWD DATA WERE ACQUIRED. 5. MWD RUNS 3-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) NO DRILLING WAS ATTEMPTED DURING MWD RUN 5 - THEREFORE, NO MWD DATA WERE ACQUIRED. 6. 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. 7. MWD RUNS 1-6 REPRESENT WELL 1J-180 WITH API#: 50-029-23329-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17834'MD/3351'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 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 3951.5 17776.5 FET 3990.0 17783.5 RPD 3990.0 17783.5 RPS 3990.0 17783.5 RPM 3990.0 17783.5 RPX 3990.0 17783.5 ROP 4021.5 17834.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 MWD 6 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3951.5 8932.0 8932.0 10850.0 10850.0 17834.5 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3951.5 17834.5 10893 27767 3951.5 17834.5 RPD MWD OHMM 0.49 2000 38.6198 27588 3990 17783.5 RPM MWD OHMM 0.1 2000 39.9305 27587 3990 17783.5 RPS MWD OHMM 0.13 2000 39.5299 27588 3990 17783.5 RPX MWD OHMM 3.03 2000 41.6984 27588 3990 17783.5 FET MWD HOUR 0.16 182.178 2.14484 27588 3990 17783.5 GR MWD API 22.33 128.39 70.0193 27651 3951.5 17776.5 ROP MWD FT/H 1.81 971.39 170.124 27627 4021.5 17834.5 First Reading For Entire File..........3951.5 Last Reading For Entire File...........17834.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 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.......07/04/17 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3951.5 FET 3990.0 RPX 3990.0 RPS 3990.0 RPM 3990.0 RPD 3990.0 ROP 4021.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8868.0 8860.0 8860.0 8860.0 8860.0 8860.0 8932.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (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 18-JAN-07 Insite 72.13 Memory 8632.0 4021.0 8632.0 76.9 83.3 TOOL NUMBER 126027 77613 12.250 4000.0 • Fresh Water Gel 9.10 55.0 9.7 150 5.2 1.020 72.0 .730 104.0 .660 72.0 1.570 72.0 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 3951.5 8932 6441.75 9962 3951.5 8932 RPD MWD030 OHMM 0.49 2000 14.1536 9741 3990 8860 RPM MWD030 OHMM 0.1 42.11 12.6249 9741 3990 8860 RPS MWD030 OHMM 0.13 34.51 11.4632 9741 3990 8860 RPX MWD030 OHMM 3.2 21.91 9.3211 9741 3990 8860 FET MWD030 HOUR 0.26 98.17 1.81382 9741 3990 8860 GR MWD030 API 22.33 128.39 69.1082 9834 3951.5 8868 ROP MWD030 FT/H 10.99 971.39 168.739 9822 4021.5 8932 First Reading For En tire File.... ......3951.5 Last Reading For Ent ire File..... ......8932 File Trailer Service name ..... ........STSLIB.002 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......07/04/17 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.......07/04/17 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8860.5 10801.0 RPS 8860.5 10801.0 RPX 8860.5 10801.0 RPM 8860.5 10801.0 RPD 8860.5 10801.0 GR 8868.5 10809.0 ROP 8932.5 10850.0 LOG HEADER DATA DATE LOGGED: 22-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME); Memory TD DRILLER (FT) 10850.0 TOP LOG INTERVAL (FT) 8632.0 BOTTOM LOG INTERVAL (FT) 10850.0 • • BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.0 MAXIMUM ANGLE: 88.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 141029 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 4000.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 74.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.200 75.0 MUD AT MAX CIRCULATING TERMPERATURE: .870 106.0 MUD FILTRATE AT MT: 1.100 70.0 MUD CAKE AT MT: .950 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN}: EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8860.5 10850 9855.25 3980 8860.5 10850 RPD MWD040 OHMM 4.69 112.96 16.7015 3882 8860.5 10801 RPM MWD040 OHMM 3.9 152.12 16.1926 3882 8860.5 10801 RPS MWD040 OHMM 3.53 90.25 13.6987 3882 8860.5 10801 RPX MWD040 OHMM 3.03 40.25 9.76515 3882 8860.5 10801 FET MWD040 HOUR 0.26 53.55 3.14864 3882 8860.5 10801 GR MWD040 API 22.96 120.7 82.0054 3882 8868.5 10809 ROP MWD040 FT/H 3.58 571,3 114.098 3836 8932.5 10850 First Reading For Entire File.........,8860.5 • • Last Reading For Entire File..........,10850 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Previous File Name..... ..STSLIB.004 ..1.0.0 ..07/04/17 ..65535 ..LO ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10801.5 17783.5 RPX 10801.5 17783.5 RPD 10801.5 17783.5 FET 10801.5 17783.5 RPS 10801.5 17783.5 GR 10809.5 17776.5 ROP 10850.5 17834.5 LOG HEADER DATA DATE LOGGED: 03-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17834.0 TOP LOG INTERVAL (FT) 10850.0 BOTTOM LOG INTERVAL (FT) 17834.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 48783 EWR4 ELECTROMAG. RESIS. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 10845.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 113.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefine d Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefine d Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10801.5 17834.5 14318 14067 10801.5 17834.5 RPD MWD060 OHMM 7.58 2000 61.7785 13965 10801.5 17783.5 RPM MWD060 OHMM 6.72 2000 65.5771 13965 10801.5 17783.5 RPS MWD060 OHMM 12.98 2000 66.2878 13965 10801.5 17783.5 RPX MWD060 OHMM 10.92 2000 73.1593 13965 10801.5 17783.5 FET MWD060 HOUR 0.16 182.178 2.09671 13965 10801.5 17783.5 GR MWD060 API 29.16 98.34 67.3233 13935 10809.5 17776.5 ROP MWD060 FT/H 1.81 454.84 186.483 13969 10850.5 17834.5 First Reading For Entire File..........10801.5 Last Reading For Entire File...........17834.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/17 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 .....................07/04/17 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
