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Home My WebLink About206-176New Plugback Esets 6/27/2024 Well Name API Number PTD Number ESet Number Date 1J-118 PB1 50-029-23337-70-00 206-176 T39063 2-4-2009 1J-118 PB2 50-029-23337-71-00 206-176 T39064 2-4-2009 1J-136L1 PB1 50-029-23331-71-00 206-155 T39065 2-21-2007 1J-136L1 PB2 50-029-23331-72-00 206-155 T39066 2-21-2007 CD2-76 PB1 50-103-20603-70-00 209-098 T39067 1-13-2010 CD2-76 PB2 50-103-20603-71-00 209-098 T39068 1-13-2010 CD4-24 PB1 50-103-20602-70-00 209-097 T39069 3-24-2010 CD4-24 PB2 50-103-20602-71-00 209-097 T39070 3-24-2010 L-203L3 PB1 50-029-23416-70-00 209-112 T39071 9-24-2010 L-203L3 PB2 50-029-23416-71-00 209-112 T39072 9-24-2010 OP03-P05 PB1 50-029-23396-70-00 208-137 T39073 2-23-2009 OP03-P05 PB2 50-029-23396-71-00 208-137 T39074 2-23-2009 1J-118 PB1 50-029-23337-70-00 206-176 T39063 2-4-2009 1J-118 PB2 50-029-23337-71-00 206-176 T39064 2-4-2009 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-118 KUPARUK RIV U WSAK 1J-118 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-118 50-029-23337-00-00 206-176-0 W SPT 3595 2061760 1500 425 427 425 426 138 142 142 141 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-118 Inspection Date: Tubing OA Packer Depth 1010 2010 1980 1980IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509105512 BBL Pumped:1 BBL Returned:1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:03:26 -08'00' ! "##$ % & '()'(' )) "()'*"+,-'( )'*+,-.& )) ' ' ' ./ ' )')''' 0 !' () ! (.(( ! '(' ) ('1 )) 23 3 +( ) '4( ./'('( ( ) '(( )!' ' ' . 5+ ! + ! # 26$#2$ 6 )4 41 . 4 + ! 5(7!48' ( By Samantha Carlisle at 8:48 am, Mar 30, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.03.27 06:40:14-08'00' Foxit PhantomPDF Version: 10.1.0 Roger Mouser !"#$#$%& '( #)*+,*+" "("'"-+.+/+($ ! "!#!$%%&'&&'()%!&%*%!(*+%'*,-!&&%&!-#-&-&%&!!"!'$%%&'&&((%%%!'(%$&'+!#*,-!&&%&!(-&-&%&!!."!!*$%%&'&---)%%&%(!)('$&-*,-!&&%&!$!-&-&%&!&/"-!-$%!%-&%&))%%!'*&!'0&!,#&*&%!'*-&#&%&!&1"#!$%!%-&%)'%%%&!*!$!%-#,$ !%,)-!&%&%&-&#&%&!&"&%*$%!%-&%$!*%%&%$!*))(,%$!&,-&-&%&!*!-&-&%&!&"-)$%!%-&%&&)%%!'$!%!-%,%&%&(,-&-&%&!')-&-&%&! #"-%# $%!%-&%$$$%% &%)!-& &%+$%2#*, -&#&%&! !% -&#&%&! Regg, James B (CED) PT`6 70(v l7(,e-) From: NSK West Sak Prod Engr <n1638@conocophiIli ps.com> Sent: Saturday, March 13, 2021 5:08 AMT 3'1S'2pZ( To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Operations Superintendent; Braun, Michael (Alaska); Thomson, Stephanie; NSK West Sak Prod Engr; Lyons, Kelly A Subject: LPP/SSV Returned to Service on CPAI Well 1J-118 on 3/12/2021 Jim, The low pressure pilot (LPP) on well 1J-118 (PTD #206-176, #206-177, #206-178) was returned to service and removed from the "Facility Defeated Safety Device Log" on 3/12/2021, as the injection pressure increased above the LPP setpoint due to sustained injection in the pattern. The well is currently injecting 2010 BWPD at 270 psi wellhead pressure. The LPP had been defeated on 2/1/2021 after the well had been returned to injection post surface casing repair. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Thank you, Toon Toon Changklungdee / Kelly Lyons CPF1 / WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 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 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 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: 2061760 E-Set: 34724 MEMORANDUM TO: Jim Regg Vie' P.I. Supervisor FROM: Austin McLeod Petroleum Inspector 1,? 5( 76z,� NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Wednesday, February 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. I1-118 KUPARUK RIV U WSAK IJ -118 Src: Inspector Reviewed By:� P.I. Suprv� Comm Well Name KUPARUK RIV U WSAK IJ -118 API Well Number 50-029-23337-00-00 Inspector Name: Austin McLeod Permit Number: 206-176-0 Inspection Date: 2/11/2021 Insp Num: mitSAM210212181152 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PTD uns Type TypTestsPT TVDs9s Test - 'Tubing z zz122 2 00 I9902061760 - 123lnJ 990. � — i - BBL Pumped: I -IBBd: 492 492- 1 492 �- -- _--- Interval OTHER P/F P Notes: Tubing patch. 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The well is currently injecting 1,500 BWPD at a wellhead pressure of 52 psi. 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. Thanks, Toon Toon Changklungdee / Stephanie Thomson WestSak Production Engineer Office: (907) 659-7234 Cell: (303) 564-7586 Pager: (907) 659-7000 pp 497 ! " # " $%& ' () * + ,&! - *' ./ !0 1"!! 2/ ./ 34354-04 6. 0 " * ' 7%,248 -5-8 +%2518 ( ' -5- -%7,8 +%52-8 +%5258 9 1%2518#7%,758 : +%1,18#+%25-8 . ;%% 0 75< /#14 -%2489' +%,4+8:' $ :. *% 0 -%7,89' +%5258:' 3 =; * !6 & . 0 !6 + = 5" $ ' * " () * ' / * ," $ > "'/ ( ' > >&!?@/@> *!!6 () ! ; ( 6336343 +34#725 ;! ; ( ( 7 .= 34354-4%354-%A3531 "&!?"> -&* * *$ 9 6 " 23-B ,52#-54, "& * ##### ##### !6 ' * &C ' #D > #9 " #D D$E/ $ / ,%1+28 75< 7%,248 +%2518 148 34< 418 418 1%2338 -,5< 1%2728 +%1,18 +%+3-8 4-5< +%+518 3%318 $ !6 F$6" $ ?$ 34,#-, 54#432#3+++-#44#44 '/4435,546'/4435,, D)44,+4%% $22541 (/F /F&/!'>!( :&!99&&! !!"#$%! &'!# 3 ! ! 7" D"$ 5 ' ! 4#747 +63434 " +4* By Samantha Carlisle at 9:10 am, Jan 25, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021-01-22 16:50:23 Foxit PhantomPDF Version: 10.0.0 Roger Mouser 14,698 SFD 1/26/2021RBDMS HEW 1/27/2021 SFD 1/26/2021 VTL 02/18/2021 DSR01/27/21 ! "##$ % &' () )' *& + ,' -&"-.( /0*12 3(34, * - ! 3$#($ 3' 5 , - !6 +!7& *& + , Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021-01-22 16:49:26 Foxit PhantomPDF Version: 10.0.0 Roger Mouser !!"#!$ %"&' ! !"#$%&'$%( ) *+ * , ,*- #./0#1121345&61&%(175(8 9 99 +++ * ,, 9)9*: ;) +< 93), 9 9=)9 .$21&%0 1&?%(1$ ), *< +/>)+) 9 Originated:Delivered to:8-Jan-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 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 6-Dec-20 0 1 2 1A-01 50-029-20590-00 n/a Kuparuk River Packer Setting Record Field- Final 7-Dec-20 0 1 3 1C-25 50-029-22941-00 906866139 Kuparuk River Packer Setting Record Field- Final 15-Dec-20 0 1 4 1H-108B 50-029-23608-02 906811421 Kuparuk River Water Flow Record Field- Final 12-Nov-20 0 1 5 1H-109 50-029-23595-00 906810847 Kuparuk River Injection Profile Field & Processed 14-Nov-20 0 1 6 1H-111 50-02923581-00 906831134 Kuparuk River Injection Profile Field & Processed 21-Nov-20 0 1 7 1H-115 50-029-23605-00 906832402 Kuparuk River Injection Profile Field & Processed 23-Nov-20 0 1 8 1H-117 50-029-23602-00 906810277 Kuparuk River Injection Profile Field & Processed 20-Nov-20 0 1 9 1J-118 50-029-23337-00 906798402 Kuparuk River Plug Setting Record Field- Final 1-Nov-20 0 1 10 1Y-19 50-029-22391-00 906849383 Kuparuk River Leak Detect Log Field- Final 7-Dec-20 0 1 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 01/08/2021 01/11/2021 Abby Bell PTD: 2061760 E-Set: 34545 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 14690 NA NA Casing Collapse Conductor NA Surface NA Production NA Liner NA Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:12/4/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity & Compliance Specialist Jan Byrne / Dusty Freeborn n1617@conocophillips.com 6839 8922 108 108 14690 8949 80 20 10.75 7.65 3327 Length TVD Burst 7190 MD NA NA NA NA 2218 3868 3958 3358 3958 7157 PRESENT WELL CONDITION SUMMARY 3597 7157 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025650/ ADL 0025661 206-176 P.O. Box 100630, Anchorage, Alaska 99508 50029233370000' ConocoPhillips Alaska, Inc. KRU 1J-118 Kuparuk River/ West Sak COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3868 - 3957 Perforation Depth TVD (ft):Tubing Size: Slotted liner: 8958 - 14645 Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7224 Baker SXP Liner Top Packer No SSSV 7146 MD / 3595 TVD Size 4.5 Authorized Signature: 12/25/2020 4.5 Perforation Depth MD (ft): L-80 m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 4:09 pm, Dec 04, 2020 320-511 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孳孰孴孵孰孳孷季孴孹孽孳孴孽孵學安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne VTL 12/10/20 X 10-404 SFD 12/7/2020 X DSR-12/7/2020Comm 12/14/2020 dts 12/14/2020 JLC 12/14/2020 RBDMS HEW 12/15/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 04 December 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1J-118 (PTD 206-176) to set a retrievable tubing patch over a known tubing leak. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孳孰孴孵孰孳孷季孴孹孽孳孳孽孳孼安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne Proposal Summary KRU 1J-118 was reported to the AOGCC on 10/30/20 for fluids in the cellar. Diagnostics located a surface casing leak which is being repaired under sundry # 320-495. During the well secure it was TxIA communication was discovered. Diagnostics culminated in an LDL locating a leak around the CMD at 7110’. CPAI intends to set a 4.5”, Paragon 2 Packer, ~34’ OAL, retrievable patch over the tubing leak. Below is the planned work, which may change slightly as wellbore conditions dictate. Well Work Justification & Objectives (and date required if appropriate): 1J-118 has OAxAtmosphere and TxIA communication. The well was secured and passed a CMIT proving production casing and packer integrity. An LDL was ran and identified the TxIA communication was at the sliding sleeve at 7110'. The sleeve was functioned and an iso sleeve was attempted, but the communication persists. A tubing patch is required to regain integrity and return the well to injection. Risk/Job Concerns: • OAxAtmosphere, shallow surface casing leak, KWF was pumped down OA • TxIA communication, TxIA LLR of 8 GPM at 2500 psi • RBP set at 7157' • LDL indicated TxIA leak at 7110' • S-line verified CMD closed and attempted isolation sleeve over CMD • DO NOT START WORK UNTIL APPROVED 10-403 RECEIVED Steps: Relay 1. RIH to open CMD at 7110'. 2. Circ out well pumping down tubing taking returns off IA to production with 191 bbls (T-70,IA-121) corrosion inhibited seawater (CRW-132 1% by volume) and 104 bbls (T-38,IA-66) diesel. U-tube until fluids have equalized. 3. RIH to pull RBP set at 7157'. 4. RIH to brush and flush patch set area around CMD at 7110'. 5. RIH with lower P2P to set mid element at 7126'. 6. RIH with test tool to sting into lower P2P and perform CMIT to 2500 psi. Record TIOs. 7. RIH with upper P2P to sting into lower P2P. Patch should be 30' element to elemen setting the upper packer mid element at 7096'. 8. Perform MITIA to 2500 psi. Record TIOs. 9. RDMO, turn well over to Operations. Well will require SW MITIA, notify DHD supervisor. Well will require SW MITIA, 1J-118 has OAxAtmosphere and TxIA communication. The well was secured and passed a CMIT proving production casing and packer integrity. An LDL was ran and identified the TxIA communication was at the sliding sleeve at 7110'. The sleeve was functioned and an iso sleeve was attempted, but the communication persists. A tubing patch is required to regain integrity and return the well to injection. CPAI intends to set a 4.5”, Paragon 2 Packer, ~34’ OAL, retrievable patch over the tubing leak. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-118 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set 3.76" RBP 11/1/2020 1J-118 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade K-55 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.5 Set Depth (ftKB) 3,358.0 Set Depth (TVD) … 2,219.9 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.7 Set Depth (ftKB) 8,949.0 Set Depth (TVD) … 3,868.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BUTT Casing Description D WINDOW OD (in) 7 5/8 ID (in) 0.01 Top (ftKB) 7,207.0 Set Depth (ftKB) 7,217.0 Set Depth (TVD) … 3,607.9 Wt/Len (l…Grade Top Thread Casing Description B WINDOW OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 7,766.0 Set Depth (ftKB) 7,776.0 Set Depth (TVD) … 3,694.7 Wt/Len (l…Grade Top Thread Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,146.0 Set Depth (ftKB) 7,344.0 Set Depth (TVD) … 3,630.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,146.0 3,594.9 78.93 PACKER ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 5.750 7,165.1 3,598.4 79.35 SBR 109-47 Casing Seal Bore Receptacle 6.26" OD x 4.75" ID 4.750 7,184.7 3,602.0 79.45 XO BUSHING XO Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 3.910 7,340.8 3,629.9 80.24 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Casing Description D LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,201.5 Set Depth (ftKB) 7,430.0 Set Depth (TVD) … 3,645.3 Wt/Len (l… 11.60 Grade L-80 Top Thread 4.5" BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,201.5 3,605.1 79.54 HANGER Baker Model PZ Hook Hanger 7-5/8" x 4 1/2" (Inside csg) 5.600 7,218.1 3,608.1 79.62 HANGER Baker Model PZ Hook Hanger 7-5/8" x 4 1/2" (Outside csg) 3.970 7,271.5 3,617.6 79.71 ECP Baker Payzone External Casing Packer 3.950 7,399.9 3,640.1 79.94 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.970 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,312.2 Set Depth (ftKB) 7,896.2 Set Depth (TVD) … 3,714.3 Wt/Len (l… 12.60 Grade L80 Top Thread IBTM-SCC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,312.2 3,624.9 79.85 PACKER 7-5/8" x 5-1/2" ZXP liner top packer 4.970 7,330.9 3,628.2 80.10 SBR Casing Seal Bore Receptacle 4.750 7,350.5 3,631.5 80.23 XO BUSHING Cross Over Bushing 3.960 7,752.7 3,691.3 81.58 HANGER LEM (above hook hanger) 3.688 7,762.7 3,692.7 81.57 HANGER LEM (inside hook hanger) 3.688 7,814.0 3,700.3 81.54 NIPPLE DB-6 Nipple 3.562 7,892.9 3,713.7 78.66 SEAL ASSY Seal assembly 3.860 Casing Description B LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,508.3 Set Depth (ftKB) 7,762.7 Set Depth (TVD) … 3,692.7 Wt/Len (l… 11.60 Grade L-80 Top Thread 4-1/2" BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,508.3 3,657.8 81.79 HANGER Baker Model B-1 Hook Hanger (Inside) 5.600 7,525.0 3,660.1 82.20 HANGER Baker Model B-1 Hook Hanger(Out side) 3.970 7,578.1 3,667.0 82.57 ECP External Casing Packer 3.950 Casing Description A-Sand Slotted LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,851.2 Set Depth (ftKB) 14,690.0 Set Depth (TVD) … 3,957.8 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,851.2 3,706.0 80.38 PACKER Baker Liner Top Packer "HRD" ZXP 5.750 7,870.2 3,709.3 79.48 NIPPLE "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.880 7,873.0 3,709.9 79.34 HANGER 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85" ID 4.830 7,882.9 3,711.7 78.85 SBE 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 7,902.5 3,715.6 78.76 XO XO Sub 5.5"Hyd 563 X 4.5", BTC 5.99"OD X 3.94" ID 3.920 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.9 Set Depth (ft… 7,190.4 Set Depth (TVD) (… 3,603.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.9 22.9 0.00 HANGER TUBING HANGER 3.958 502.5 502.2 6.16 NIPPLE CAMCO 'DB' NIPPLE 3.875 7,110.5 3,587.6 77.37 SLEEVE-O BAKER CMD SLIDING SLEEVE 3.812 7,162.0 3,597.9 79.34 LOCATOR BAKER LOCATOR 3.880 7,163.7 3,598.2 79.35 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,157.0 3,596.9 79.31 Bridge plug - retrievable Set 3.76" RBP (OAL 8.67') 11/1/2020 0.000 CPP45021/CP EQ45011 1J-118, 11/2/2020 8:42:07 AM Vertical schematic (actual) A-Sand Slotted LINER; 7,851.2- 14,690.0 SLOTS; 14,515.0-14,645.0 SLOTS; 13,792.0-14,178.0 SLOTS; 12,954.0-13,424.0 SLOTS; 12,074.0-12,544.0 SLOTS; 11,147.0-11,777.0 SLOTS; 10,233.0-10,846.0 SLOTS; 9,416.0-10,039.0 SLOTS; 8,958.0-9,209.0 INTERMEDIATE; 26.7-8,949.0 B LINER LEM; 7,312.2-7,896.2 B WINDOW; 7,766.0-7,776.0 B LINER HH; 7,508.3-7,762.7 D LINER HH; 7,201.5-7,430.0 D LINER LEM; 7,146.0-7,344.0 D WINDOW; 7,207.0-7,217.0 SEAL ASSY; 7,163.7 LOCATOR; 7,162.0 Bridge plug - retrievable; 7,157.0 SLEEVE-O; 7,110.5 GAS LIFT; 6,007.6 SURFACE; 30.5-3,358.0 GAS LIFT; 2,173.1 NIPPLE; 502.5 CONDUCTOR; 28.0-108.0 HANGER; 22.9 KUP INJ KB-Grd (ft) 32.29 Rig Release Date 3/20/2007 1J-118 ... TD Act Btm (ftKB) 14,822.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292333700 Wellbore Status INJ Max Angle & MD Incl (°) 93.47 MD (ftKB) 11,680.00 WELLNAME WELLBORE1J-118 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,958.0 9,209.0 3,869.0 3,872.1 WS A2, 1J-118 2/23/2007 32.0 SLOTS ALL PERFS IN WELLBORE: Undulating Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 9,416.0 10,039.0 3,877.0 3,890.7 WS A2, 1J-118 2/23/2007 32.0 SLOTS 10,233.0 10,846.0 3,890.7 3,903.3 WS A2, 1J-118 2/23/2007 32.0 SLOTS 11,147.0 11,777.0 3,910.6 3,908.4 WS A2, 1J-118 2/23/2007 32.0 SLOTS 12,074.0 12,544.0 3,909.0 3,913.4 WS A2, 1J-118 2/23/2007 32.0 SLOTS 12,954.0 13,424.0 3,916.7 3,926.9 WS A2, 1J-118 2/23/2007 32.0 SLOTS 13,792.0 14,178.0 3,938.5 3,944.5 WS A2, 1J-118 2/23/2007 32.0 SLOTS 14,515.0 14,645.0 3,953.5 3,957.3 WS A2, 1J-118 2/23/2007 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,173.1 1,816.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/7/2007 2 6,007.6 3,226.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/19/2007 Notes: General & Safety End Date Annotation 8/21/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 3/20/2007 NOTE: MULTI-LATERAL WELL- 1J-118 (A-SAND), 1J-118L1 (B-SAND), 1J-118L2 (D-SAND) 1J-118, 11/2/2020 8:42:08 AM Vertical schematic (actual) A-Sand Slotted LINER; 7,851.2- 14,690.0 SLOTS; 14,515.0-14,645.0 SLOTS; 13,792.0-14,178.0 SLOTS; 12,954.0-13,424.0 SLOTS; 12,074.0-12,544.0 SLOTS; 11,147.0-11,777.0 SLOTS; 10,233.0-10,846.0 SLOTS; 9,416.0-10,039.0 SLOTS; 8,958.0-9,209.0 INTERMEDIATE; 26.7-8,949.0 B LINER LEM; 7,312.2-7,896.2 B WINDOW; 7,766.0-7,776.0 B LINER HH; 7,508.3-7,762.7 D LINER HH; 7,201.5-7,430.0 D LINER LEM; 7,146.0-7,344.0 D WINDOW; 7,207.0-7,217.0 SEAL ASSY; 7,163.7 LOCATOR; 7,162.0 Bridge plug - retrievable; 7,157.0 SLEEVE-O; 7,110.5 GAS LIFT; 6,007.6 SURFACE; 30.5-3,358.0 GAS LIFT; 2,173.1 NIPPLE; 502.5 CONDUCTOR; 28.0-108.0 HANGER; 22.9 KUP INJ 1J-118 ... WELLNAME WELLBORE1J-118 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing SC Repair 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11680' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:11/22/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com 8923' 108'108' 8949' 80'20" 10 3/4" 7 5/8" 3528' Length TVD Burst 7190' MD 2219' 3868' 3558' 14822' PRESENT WELL CONDITION SUMMARY 7157' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650/ADL0025661 206-176 P.O. Box 100630, Anchorage, Alaska 99508 50029233700 ConocoPhillips Alaska, Inc. KPU 1J-118 West Sak Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 3869' - 3957' Perforation Depth TVD (ft):Tubing Size: 8958' -14645' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7506 NA NA NA NA Size Authorized Signature: 11/22/2020 4 1/2" Perforation Depth MD (ft): l-80 m n P s 66 t y t irr c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:07 am, Nov 23, 2020 320-495 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-11-22 08:32:21 Foxit PhantomPDF Version: 10.0.0 Roger Winter Photo document all steps of damage and repair N/A DLB DLB11/23/2020 X DSR-11/23/2020 X 10-404 50-029-23337-00-00 DLB VTL 11/25/20Comm 11/25/2020 dts 11/25/2020 JLC 11/25/2020 RBDMS HEW 11/25/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 22 November 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1J-118 (PTD 206-176) to repair the Surface Casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2020-11-22 08:30:57 Foxit PhantomPDF Version: 10.0.0 Roger Winter P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ConocoPhillips Alaska, Inc. Kuparuk Well 1J-118 (PTD 206-176) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 22, 2020 This application for Sundry approval for Kuparuk well 1J-118 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing. 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to ~20’. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-118 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set 3.76" RBP 11/1/2020 1J-118 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade K-55 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.5 Set Depth (ftKB) 3,358.0 Set Depth (TVD) … 2,219.9 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.7 Set Depth (ftKB) 8,949.0 Set Depth (TVD) … 3,868.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BUTT Casing Description D WINDOW OD (in) 7 5/8 ID (in) 0.01 Top (ftKB) 7,207.0 Set Depth (ftKB) 7,217.0 Set Depth (TVD) … 3,607.9 Wt/Len (l…Grade Top Thread Casing Description B WINDOW OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 7,766.0 Set Depth (ftKB) 7,776.0 Set Depth (TVD) … 3,694.7 Wt/Len (l…Grade Top Thread Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,146.0 Set Depth (ftKB) 7,344.0 Set Depth (TVD) … 3,630.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,146.0 3,594.9 78.93 PACKER ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 5.750 7,165.1 3,598.4 79.35 SBR 109-47 Casing Seal Bore Receptacle 6.26" OD x 4.75" ID 4.750 7,184.7 3,602.0 79.45 XO BUSHING XO Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 3.910 7,340.8 3,629.9 80.24 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Casing Description D LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,201.5 Set Depth (ftKB) 7,430.0 Set Depth (TVD) … 3,645.3 Wt/Len (l… 11.60 Grade L-80 Top Thread 4.5" BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,201.5 3,605.1 79.54 HANGER Baker Model PZ Hook Hanger 7-5/8" x 4 1/2" (Inside csg) 5.600 7,218.1 3,608.1 79.62 HANGER Baker Model PZ Hook Hanger 7-5/8" x 4 1/2" (Outside csg) 3.970 7,271.5 3,617.6 79.71 ECP Baker Payzone External Casing Packer 3.950 7,399.9 3,640.1 79.94 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.970 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,312.2 Set Depth (ftKB) 7,896.2 Set Depth (TVD) … 3,714.3 Wt/Len (l… 12.60 Grade L80 Top Thread IBTM-SCC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,312.2 3,624.9 79.85 PACKER 7-5/8" x 5-1/2" ZXP liner top packer 4.970 7,330.9 3,628.2 80.10 SBR Casing Seal Bore Receptacle 4.750 7,350.5 3,631.5 80.23 XO BUSHING Cross Over Bushing 3.960 7,752.7 3,691.3 81.58 HANGER LEM (above hook hanger) 3.688 7,762.7 3,692.7 81.57 HANGER LEM (inside hook hanger) 3.688 7,814.0 3,700.3 81.54 NIPPLE DB-6 Nipple 3.562 7,892.9 3,713.7 78.66 SEAL ASSY Seal assembly 3.860 Casing Description B LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,508.3 Set Depth (ftKB) 7,762.7 Set Depth (TVD) … 3,692.7 Wt/Len (l… 11.60 Grade L-80 Top Thread 4-1/2" BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,508.3 3,657.8 81.79 HANGER Baker Model B-1 Hook Hanger (Inside) 5.600 7,525.0 3,660.1 82.20 HANGER Baker Model B-1 Hook Hanger(Out side) 3.970 7,578.1 3,667.0 82.57 ECP External Casing Packer 3.950 Casing Description A-Sand Slotted LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,851.2 Set Depth (ftKB) 14,690.0 Set Depth (TVD) … 3,957.8 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,851.2 3,706.0 80.38 PACKER Baker Liner Top Packer "HRD" ZXP 5.750 7,870.2 3,709.3 79.48 NIPPLE "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.880 7,873.0 3,709.9 79.34 HANGER 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85" ID 4.830 7,882.9 3,711.7 78.85 SBE 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 7,902.5 3,715.6 78.76 XO XO Sub 5.5"Hyd 563 X 4.5", BTC 5.99"OD X 3.94" ID 3.920 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.9 Set Depth (ft… 7,190.4 Set Depth (TVD) (… 3,603.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.9 22.9 0.00 HANGER TUBING HANGER 3.958 502.5 502.2 6.16 NIPPLE CAMCO 'DB' NIPPLE 3.875 7,110.5 3,587.6 77.37 SLEEVE-O BAKER CMD SLIDING SLEEVE 3.812 7,162.0 3,597.9 79.34 LOCATOR BAKER LOCATOR 3.880 7,163.7 3,598.2 79.35 SEAL ASSY BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.880 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,157.0 3,596.9 79.31 Bridge plug - retrievable Set 3.76" RBP (OAL 8.67') 11/1/2020 0.000 CPP45021/CP EQ45011 1J-118, 11/2/2020 8:42:07 AM Vertical schematic (actual) A-Sand Slotted LINER; 7,851.2- 14,690.0 SLOTS; 14,515.0-14,645.0 SLOTS; 13,792.0-14,178.0 SLOTS; 12,954.0-13,424.0 SLOTS; 12,074.0-12,544.0 SLOTS; 11,147.0-11,777.0 SLOTS; 10,233.0-10,846.0 SLOTS; 9,416.0-10,039.0 SLOTS; 8,958.0-9,209.0 INTERMEDIATE; 26.7-8,949.0 B LINER LEM; 7,312.2-7,896.2 B WINDOW; 7,766.0-7,776.0 B LINER HH; 7,508.3-7,762.7 D LINER HH; 7,201.5-7,430.0 D LINER LEM; 7,146.0-7,344.0 D WINDOW; 7,207.0-7,217.0 SEAL ASSY; 7,163.7 LOCATOR; 7,162.0 Bridge plug - retrievable; 7,157.0 SLEEVE-O; 7,110.5 GAS LIFT; 6,007.6 SURFACE; 30.5-3,358.0 GAS LIFT; 2,173.1 NIPPLE; 502.5 CONDUCTOR; 28.0-108.0 HANGER; 22.9 KUP INJ KB-Grd (ft) 32.29 Rig Release Date 3/20/2007 1J-118 ... TD Act Btm (ftKB) 14,822.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292333700 Wellbore Status INJ Max Angle & MD Incl (°) 93.47 MD (ftKB) 11,680.00 WELLNAME WELLBORE1J-118 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,958.0 9,209.0 3,869.0 3,872.1 WS A2, 1J-118 2/23/2007 32.0 SLOTS ALL PERFS IN WELLBORE: Undulating Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 9,416.0 10,039.0 3,877.0 3,890.7 WS A2, 1J-118 2/23/2007 32.0 SLOTS 10,233.0 10,846.0 3,890.7 3,903.3 WS A2, 1J-118 2/23/2007 32.0 SLOTS 11,147.0 11,777.0 3,910.6 3,908.4 WS A2, 1J-118 2/23/2007 32.0 SLOTS 12,074.0 12,544.0 3,909.0 3,913.4 WS A2, 1J-118 2/23/2007 32.0 SLOTS 12,954.0 13,424.0 3,916.7 3,926.9 WS A2, 1J-118 2/23/2007 32.0 SLOTS 13,792.0 14,178.0 3,938.5 3,944.5 WS A2, 1J-118 2/23/2007 32.0 SLOTS 14,515.0 14,645.0 3,953.5 3,957.3 WS A2, 1J-118 2/23/2007 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,173.1 1,816.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/7/2007 2 6,007.6 3,226.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 3/19/2007 Notes: General & Safety End Date Annotation 8/21/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 3/20/2007 NOTE: MULTI-LATERAL WELL- 1J-118 (A-SAND), 1J-118L1 (B-SAND), 1J-118L2 (D-SAND) 1J-118, 11/2/2020 8:42:08 AM Vertical schematic (actual) A-Sand Slotted LINER; 7,851.2- 14,690.0 SLOTS; 14,515.0-14,645.0 SLOTS; 13,792.0-14,178.0 SLOTS; 12,954.0-13,424.0 SLOTS; 12,074.0-12,544.0 SLOTS; 11,147.0-11,777.0 SLOTS; 10,233.0-10,846.0 SLOTS; 9,416.0-10,039.0 SLOTS; 8,958.0-9,209.0 INTERMEDIATE; 26.7-8,949.0 B LINER LEM; 7,312.2-7,896.2 B WINDOW; 7,766.0-7,776.0 B LINER HH; 7,508.3-7,762.7 D LINER HH; 7,201.5-7,430.0 D LINER LEM; 7,146.0-7,344.0 D WINDOW; 7,207.0-7,217.0 SEAL ASSY; 7,163.7 LOCATOR; 7,162.0 Bridge plug - retrievable; 7,157.0 SLEEVE-O; 7,110.5 GAS LIFT; 6,007.6 SURFACE; 30.5-3,358.0 GAS LIFT; 2,173.1 NIPPLE; 502.5 CONDUCTOR; 28.0-108.0 HANGER; 22.9 KUP INJ 1J-118 ... WELLNAME WELLBORE1J-118 ORIGINATED TRANSMITTAL DATE:11/16/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3210 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3210 1J-118 50-029-23337-00 24 Multi-Finger Caliper Log 11/13/2020 3210 1J-118 50-029-23337-00 Leak Detect Log GR/CCL 11/12/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 tom.osterkamp@conocophillips.com Received By: Print Name Signature Date AOGCC 1 0 0 ATTN: Natural Resources Technician II abby.bell@alaska.gov Received By: Print Name Signature Date DNR 1 0 0 Natural Resource Tech II DOG.Redata@alaska.gov Recevied By: Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 11/16/2020 Abby Bell Abby Bell 11/16/2020 PTD: 2061760 E-Set: 34264 ORIGINATED TRANSMITTAL DATE:11/16/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3210 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3210 1J-118 50-029-23337-00 24 Multi-Finger Caliper Log 11/13/2020 3210 1J-118 50-029-23337-00 Leak Detect Log GR/CCL 11/12/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 tom.osterkamp@conocophillips.com Received By: Print Name Signature Date AOGCC 1 0 0 ATTN: Natural Resources Technician II abby.bell@alaska.gov Received By: Print Name Signature Date DNR 1 0 0 Natural Resource Tech II DOG.Redata@alaska.gov Recevied By: Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 11/16/2020 Abby Bell Abby Bell 11/16/2020 PTD: 2061760 E-Set: 34263 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Sunday, November 15, 2020 6:42 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: KRU 1J-118 (PTD 206-176) Report of surface casing leak update Attachments: 1J-118 90 Day TIO trend 15 Nov 20.xlsm Chris, KRU 11-118 (PTD# 206-176) diagnostics have progressed and this email serves as an update to the condition of the current well status. The well passed the tubing and IC pack off tests but failed the diagnostic MIT -IA when verifying barriers. The well was immediately secured with a down hole plug and passed a diagnostic CMIT-TxIA. The subsequent leak detect log identified the leak to be at the Baker CMD sliding sleeve. CPAI intends to set a temporary isolation sleeve into the CMD sliding sleeve in an attempt to regain TxIA integrity. If the isolation sleeve is successful it will remain in place for the remainder of the SC leak diagnostics and repair. If it is unsuccessful an evaluation for a tubing patch will occur. As for the condition of the OA, CPAI conducted a surface casing leak detect which verified there is currently a SC leak but due to the complication of an open shoe, DHD was unable to identify the leak depth. An OA injectivity test was performed to evaluate the possibility of pumping an OA shoe but was unsuccessful due to fluid returns to surface. CPAI opted to pump kill weight fluid down the OA to mitigate the possibility of fluid returns to atmosphere from the open shoe via the SC leak. At this point in time the current well head pressures are T/1/0= 200/152/0 psi. The OA pressure and fluid level are being closely monitored until the repair options have been evaluated and completed. CPAI will submit the proper paperwork for repair once the path forward has been defined. Attached is the current 90 day TIO pressure trends. Please let me know if you have any questions or disagree with the plan forward. Cheers, Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 .#WELLS TEAM onocaPwllips From: Well Integrity Compliance Specialist CPF1 & 2 Sent: Friday, October 30, 2020 3:47 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: KRU 1J-118 (PTD 206-176) Report of surface casing leak Chris, KRU 11-118 (PTD 206-176) was reported by Operations to have fluids in the cellar yesterday. DHD was mobilized to the well this morning and ongoing diagnostics have demonstrated the well suffers OA x Atmosphere communication. Subsequent diagnostics today the well will be shut in and freeze protected. Further diagnostics will Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, October 30, 2020 3:47 PM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: KRU 1J-118 (PTD 206 1 Report of surface casing leak Attachments: 1J-118.pdf; 11-118 90 day TIO trend 10.30.20.pdf Chris, KRU 1J-118 (PTD 206-176) was reported by Operations to have fluids in the cellar yesterday. DHD was mobilized to the well this morning and ongoing diagnostics have demonstrated the well suffers OA x Atmosphere communication. Subsequent diagnostics today the well will be shut in and freeze protected. Further diagnostics will continue tomorrow with an MITIA, pack off testing, and additional surface casing leak diagnostics. The proper paperwork for continued injection or corrective action will be submitted upon completion of diagnostics and determination of a path forward. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 WELLS TEAM Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Monday, March 23, 2020 6:55 AM l 3� 25l z&W To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI Well 1J-118 on 3/23/2020 Jim, The low pressure pilot (LPP) on well 1J-118 (PTD #206-176, #206-177, #206-178) was returned to service and removed from the "Facility Defeated Safety Device Log" today 3/23/2020, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 1830 BWPD at 272 psi wellhead pressure. The LPP had been defeated on 2/27/2020 when the well was converted from gas injection to water injection. 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 Marina's Cell: (907) 399-7791 Pager: (907) 659-7000 #497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ WINJ t0 WAG ❑' 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory El Stratigraphic ❑ Service m 206-176 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029233370000 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1 J-1 18 ADL 25661, 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): NA 10. Field/Poo"")* Ku aruk River Field / West Salk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,690 feet Plugs measured None feet true vertical 3,958 feet Junk measured None feet Effective Depth measured 14,645 feet Packer measured 7,146 feet true vertical 3,957 feet true vertical 3,595 feet Casing Length Size MD TVD Buret Collapse Conductor 80' 20" 108' 108' Surface 3,327' 10.75" 3,358' 2,218' Production 8,922' 7.625" 8,949' 3,868' Liner 6,839' 4.5" 14,690' 3,958' Tubing (size, grade, measured and true vertical depth) 4.5" L-80 7,190' MD 3,604' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker SXP Liner Top Packer 7,146' MD 3,595' TVD SSSV TYPE: NA NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operetion: 0 0 1900 psi 1300 psi 500 psi Subsequent to operation: 0 1000 Mscfd 0 700 psi 1450 psi 14. Attachments (required per 20 MC 25,070, 25,071, a 25,283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development ❑ 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 I] GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct t0 the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-430 Authorized Name: Sydney Autry Contact Name: Sydney Autry Authorized Title: Senior Petroleum Engineer Contact Email: sydney.autry@Cop.com CC� �� CJ--d Authorized Signature: Contac Phone: 907-265-6813 yZ- Date: vrc DEC 2 0 2 5 30MS AJDEL L 4 1019 AOGCC Form 10-404 Revised 4/2017 Submit Original Only 1J-118 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/26/191 Pump 5 bbls Methanol down Tbg for WAG, 25 bbls Methanol down flowline for F/P 11/27119 WAG 1J-118 from Seawater Inj to MI UN STD zLr��o Regg, James B (CED) From: NSK West Sak Prod Engr <nl638@conocophiIlips.com> Sent: Thursday, February 27, 2020 11:48 AM I\�pL� �12i2e� To: Regg, James B (CED) l Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: Defeated LPP/SSV on CPA[ Well 11-118 on 2/27/2020 Jim, The low pressure pilot (LPP) on well 1J-118 (PTD #206-176, #206-177, #206-178) was defeated today, 2/27/2020, after the well was converted from gas injection to water injection. The well is currently injecting 2,099 BWPD at a wellhead pressure of 249 psi. 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. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Sydney Autry Senior Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-118 Permit to Drill Number: 206-176 Sundry Number: 319-430 Dear Ms. Autry: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the 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, Chair DATED this --'7 day of October, 2019. RBDMS f""xOCT 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n nnc 9a 9nn Cr •) , n-, I`— L U it 1. Type of Request: Abandon LJ Plug PerforationsEl Fracture Stimulate Ll Repair Well LJ Operations shutdown Ll Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ WINJ to WAG Other: El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConOCOPhllll s Alaska Inc. Exploratory ❑ Development ❑ Stra[igraphic ❑ Service Q 206-176 3. Address: 6. API Number: , P. 0. Box 100360, Anchorage, Alaska 99510 50029233370000 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ V PL i 1,1-118 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661, 25650 + Kuparuk River Field /West Salk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,690' 3,958' 14645 3957 1897 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 3,327' 10.75" 3,358' 2,218' Intermediate x x x x Production 8,922' 7.625" 8,949' 3,868' Liner 6,839' 4.5" 14,690' 3,958' Perforation Depth MD (ft) IPerforation Depth ND (R): Tubing Size. Tubing Grade: Tubing MD (ft): Slotted liner 8958'-14645' 3868'- 3957' 4.5" L-80 7,190' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): No SSSV, Baker SXP Liner Top Packer Packer: 7146 MD, 3,595' ND 12. Attachments: Proposal Summary ❑ Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1 -Oct -19 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sydney Autry Sydney Autry Contact Name: Authorized Title: Senior Production Engineer Contact Email: sydney.autryo@cop.com Contact Phone: 907-265-6813 Authorized Signature: Date: 2U/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: C1 - H 30 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other:z__yZ/' YLtj" �p Post Initial Injection MIT Req'd? Yes E:1No IBDMS IPoCT 10 2019 Spacing Exception Required?/^y/'IYYees Li No V Subsequent Form Required: 10 —g� z� / r I 1 APPROVED BY /n/ Approved by: ��/(�w COMMISSIONER THE COMMISSION Date: 'G �l�l r 10- 03 Revised /20 ] V7-1- le>141110RIGINAL Submit Form and Approved application is valid for 12 months from the date of approval. gnachments"Ipn�u}��licate �s ConocoPhillips September 20, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 ConocoPhillips Alaska, Inc. requests approval to convert Kuparak River Unit Well 1J-118 from Water Injection service to Water Alternating Gas Injection service. Enclosed you will find 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1J-118, 1J -118L1 & 1J -118L2 (PTD 206-176, 206-177, & 206-178). Also attached are supporting documentation, including a map of the target injection area. 1J-118 was completed as a (pre -produced) injector on 3/19/2007. No rig workovers have been completed at 1J- 118 since being drilled & completed. Well integrity testing since completion includes: • PC & SC Passed 3000 psi MIT before drilling out cement (on rig) • 08/21/07 —Passing MITIA to 3000 psi • 09/18/07 — Passing State Witnessed MITIA • 05/24/09 — Passing State Witnessed MITIA to 2490 psi • 05/14/10 — Passing State Witnessed MITIA to 1790 psi • 05/15/14 — Passing State Witnessed MITIA to 2000 psi • 04/20/18 — Passing MITIA to 1825 psi • 05/09/18 — Passing State Witnessed MITIA to 2000 psi Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 IJ -118 Sundry Proposal ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-118 (PTD# 206-176) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1J-118 was completed as an injector on 3/19/2007 to provide injection support into the reservoir to increase the ultimate recovery of oil. This well supports existing producers 1J-115 and 1J-120. The top of the Ugnu C sand was found at 5,474' MD / 3,026' TVD The top of the Ugnu B sand was found at 5,908' MD / 3,191' TVD The top of the Ugnu A sand was found at 6,327' MD / 3,345TVD The top of the West Sak D sand was found at 7,207' MD / 3,606' TVD Area Map with 1/< mile radius around target injection zone (see attached): The map attached shows that, in addition to the offset supported producers (1J-115 and 1J-120), there are two Kuparuk wells (1D-36 and 1J-03) and five West Sak wells (1D-102, 1D-138, 1D-141, 1D -141A, and 1J- 107) that have penetrations in the West Sak interval located within a 1/4 mile radius of the 1J-118 penetrations of the West Sak interval. Mechanical Condition of Well to be Converted: ----------------------------- The mechanical condition of West Sak injector 1J-118 is good. The injection tubing/casing annulus is isolated via a Baker ZXP liner top packer located at 7,146' MD (3,595' ND). The last state -witnessed MITIA was performed on May 9, 2018 to 2000 psi. CBL and interpretation of the cement quality: See attached AOR detail for U-1 and offset well condition. Conditions for approval (if applicable): ADL025651 Well Pad Well Trajectory 1J-118, Open Interval 1J-118PB1, Open Interval 1J-118PB2, Open Interval Q1J-118 01 Quartermile Buffer — West Sak Well West Sak Well WS Interval "i– West Sak Base in non -West Sak Wells Non -West Sak Well West Sak PA CPAI Leases Y ConocoPhillips Alaska 1J-118 Injection Sundry ADL025650 co 00 r � r r N v Co a 00 r o � N l" ADL025661 0 0 0.2 0.4 0.6 Miles 1 ADL028243 I ADL028248 o; 0 0 VL: r, ADL: A $$ p 3 8a9?= Va.`-n So e$$3 £So ipnt�°8 "a Sm£ry cakn o�ga8 Cpne F.TrB i :-n >�i� ksB�o F£ aPJ NTaVFn_ F 3S„E �Qax aE sin $.ea ��n"I� go`�• c`:R ;,e "Y x`• „ s” agHsB Y8� �^& �a uT ^ =F9 `n"am `4^ &eti ?�£t F��Z°• -`- y�g ean" s,ya m s a�'^➢ g3 _ -x' �a£;Yo � 5pp�e?6 :? m^='Rai :" -P�^g^9- „des° - S _.cE _-amu vE yZe92u_ jFinan g Fai�Y .n m= R"'-n'E `n aZ6„ aZ dn�P`p- =[ 'S�jm � 9G9a ogMZm n s s s„ `F 6 y 3 d 9 8 K F F � 9 $ g •� ^� KUP_ 1J-118 Conol:0Philfip5 Weuif-utes --- -- - --- --- NaSM.Lx anon -rbHe ,-- wellbore aruuwl 50029 PnWO0 __._ {laid Name _.-.�---...-. IWEST BAK Max An le & MD wen shw¢ and C) mo(rt%BI INJ 93.47 11 80.00 TD -Btm'mr., 14,822.0 Comment H351ppm) pate gnnotNlon Enda. tw-a (%) SSSV'. NIPPLE Lasl WO: 32.29 Fl Relearn nNe 320/2007 ./xt,� --------- --- CONDUCTOR N ing NIPPLE, oo3 2Asupr. ?n3 SURFACEi 01$358 OFT, O Sunn ELE.vEo. ;CIO O TOR nisi ar"LqEiai Dvn%Dow, 7.201-7'211 D LINER LEM, 7lQ-7.3U D LINER HH, 7mn4iD 7,"1.7H, 75reo... evn%o0w. 100-7,77C a 7n'2 LM NTERMEDIgTE, z7e ws MUCTs. _ S a 95aa,ms t _ SLOTS Ra1610A39 _ scars 1I 1O.it,m .mist tx.malgsw ' SLOTS, II.95aI]AN ¢LOTS. 4]�4aI79 _ - 14EIS1aea5 m .longe\ >,esi ua coli TD n an --- -- - `AS _ _ - = - " + 1 s... _-' N... �� 4 Annotdllon peplx (flK8) can nNe Last Tag: gnnotati.. LastMW SY and Diane Rev Reason: SHOW PERE SECTIONS Bsboit 5116/2013 Casin Stria s Casing oe¢eripti string o... strias lo... TOPIflRa) set -Oft lr.. sat DeplM1lrvDl... scone Val serine.:. CONDUCTOR 20 19.124 28.0 100.0 108.0 94.00 KS5 ffiNns Top Tnra WELDED Casln90e¢oripNon Shilq 0.. .tang ID... Top(.Kul Set Depth IT SNDeamlrk.l. String W1. stria,... string Top The SURFACE 103/4 9.950 30.5 3,358.0 2,218.4 45.50 L-80 BTC casing Denudation String D... string lo... Top lnKel sND.NM1Ie.. set DeAn(rvol... snhg wi... minE....,ran, INTERMEDIATE 7518 6.875 26.7 8,949.0 3,867.8 29.JO L-80 Top rma BUTT Casing Description String 0... strinDlDPSS) se ._ Tat D.,mV-Set negro(111 ... String WL.. sbing...tun DWINDOW 75/8 0.007 7,207.0 7,217.0 3,601 sg Tap TNd Cd¢Ing pesarlp4on Stling O... Siring lD... Top IflKB) SN neplx lf... SN neptM1(NDI... .[ring Wt.. s4ing... BWINDOW 7518 6.875 7766.0 7,776.0 3,696.2 Siang lop Tnrtl Caaln90e¢crlP[lon String 0.., skiing ln... ToP(ryKal sNpePtM1(L..swuepinlTVD1... string WC.. Siring... DLINER LEM 4112 3.958 _7,166.1 7,344.0 3,6304 12.60 L-80 String Top TxM IBTM Liner Details To (%KB) TOP Depth (NO)Tap Incl (June (°) Ihm neacri,sion Comment No I... 10 (in) 7,146.1 3,594.9 79.26 PACKER ZXPS12"x7-5/e" Lirler Top PackerTOP 5.750 7,165.1 3,599.2 80.12 SBR 109-07 Casing Seal Bore Receptacle 6.26' OD x dJ5" ID 4.750 7,184.7 3,602.5 80.05 X0 BUSHING X0 Rushing 5-12"Hytlri1563x412"IBT 3.910 7,340.8 3,629.9 80.24 SEAL ASSY Baker Seal Assembly 4-12"STL Box up 3.880 casing neecription String 0... String ID... Top (must set Depth R.. at Death (1VD1... String Wt... String... D LINER HH d 12 3.476 _ 7,2015 7,430.0 3,615.3 11.60 L-90 .hm, Is TM1N 4.5" BTC __ - Liner Details _ - Top Depth Irvm)))rop Incl To (%KBI Rude) CI Ihm niecriplion Comment - - Nomi... ID(In) 7,201.5 3,605.4 ]9.98 HANGER Baker Model PZH HeHenger7518"x412"(Insidecsg) 5.600 7,218.1 3,608.2 ]9.92 HANGER Baker MOdeI PZ-.1,Haner7- g 518' x 412" (Outside csg) 3.970 7271.5 3,617.5 ]9.29 ECP Baker nation Exiemal Casing Packer 3.950 7,399.9 3,640.1 79.94 RENT JT 4112",12.Eppf,L-80 STI BENT Ioint Blank Casing 3.9]0 Casing De¢criptlon 5[rin D._ ..n In... To %NB Set De M1I. set Daptx ITVDI_.sRing WL.. skiing... 1 9 PI 1 Pi ( SEINER LEM 4112 3.958 7,3122 ],896.2 3,714.3 12.60 L80 .hing Tap TxM IBTM-SCC Liner Details mP D.wx IWO) Topincl To %KB) IRKS) (°l %em Damerption Comment Nonni. .. ID (mi 7,312.2 3,624.9 79.85 PACKER 7-518"x5-112"ZXP I'mertop packer 4.970 7,330.9 3,628.1 80.10 SBR Casing Seal Bore Receptacle 4.750 7,350.5 $631.3 79.76 X0 BUSHING Crass Over Bushing 3.960 7752.7 $6947 84.38 HANGER LEM (above hook banger) 3.688 77627 3,695.2 83.97 HANGER RE (inside rook hanger) 3.688 ],1314.0 3,700.3 81.89 NIPPLE DB -6 Nipple 3.562 7,892.9 $]13.7 78.66 SEAL ASSY Seal assembly 3.860 casing DescrInum" siring 0... string ID... Tap(%KB) Set Oeptx(E...N OepIM1 WOE.. String Wf... String .. B LINER HH 412_ 3.476 ],508.3 7,]62.]_ 3,695.2 11.60 L-80 SMng Top Tnrtl 4_112"BTC Liner Details -- - ----"-- TOP Caleb (rvpl Top incl Top (ryKBI (flK8) (°I an Descriatm Comment Nomi... ID (in) 7,508.3 3,657.9 82.40 HANGER Baker Model B-1 Hook Hanger (inside) 5,600 7,525.1 3,660.1 32.4,1 HANGER Baker Model &1 Hook Hanger(Oul side) 3.970 7,578.1 3,667.0 8260 ECP External Casing Packer 3.950 casing Dascdpron string ASand Slogan! LINER o... 61/2 _--�-" serine l0 ... 3.476 Toplfllt0) 7,851.2 sN p¢p1M1 le.. 14,690.0 sN DeptM1(WE)... 3,957.8 string Wt.. 11.60 string.., L-80 string Top Thre BTC - - Liner Details IrvD) TOP InervomLTop (ttK0 (RKBI (°)on Comment _. - Tap Depen _0'*;j ---- ].851.2 3,706.0 803Baker Liner Top Packer"HRD'ZXP 7,870.2 3,709.1 ]8.4^RS' Packoif Seal Nipple,6.07"OO 14.87"ID 4.880 7,873.0 3,709.7 JB.45.5"X7.63"'Flex-Lock"Liner Hg46.59"0014.85"ID 4.830 ],882.9 3.711) 78.5190-0] Seal Bore EM, 8.29"OO14.75"ID 6.75scars, 7,902.5 3,715.5 78.]XO SubS5"Hyd 563X4.5", BTC5.99"OOX3.96"ID 3.920 Tublnq Strias Laos, 0rne"ption Shing O... s,rin91D... TOP IRK.) $et DepiM1lr... set Deptb(WD)-. String Wt_ String... String To P TM1M TUBING 61/2 3.958 22.9 7,190.4 3,603.5 12.60 L-80 IBT Completion Detalis _P.. 1, Death IryD) Top Incl To (ryKBI (aK8) (°) arm Desce Ion Comment Nomi to (in) 22.9 22.9 -0.Ofi HANGER TUBING HANGER 3.958 502.5 502.2 6.15 NIPPLE CAMCO'DB'NIPPLE 3.875 7,110.5 3,588.1 79.085LEEVE-0 BAKER CMD SLIDING SLEEVE -RUN OPEN 3,812 7,162.0 3,598.7 80.13 LOCATOR BAKER LOCATOR 3.880 7,163.7 3,599.0 80.13 SEAL ASSY BAKER GBH -22 LOCATING $EALASSEMBLY 3.880 Mandrel Details Top Depih IrvD) TOP I%NSI flKa Top -- Joel 00 (°) Make Motlel Iin1 valve Lakin Sery iYPe TYpe - P. sba To.SL.TERun I , IP¢II Run nate Com... 1 2,173.1 1,8167 ]043 LAMCO KBMG 1 GAS LIFT DMV BK -5 0.000 0.0 80/2097 2 6,OOZfi 3,226.] fi8.74 CAMCO KBMG 1 GAS LIFT DMV BK -5 0.000 0.0 31192007 ►rya KUP 11-118 4 oncacurnnnPs wnvH2uu, RgReease ai __yS 2012007 HI.NGEP-23v -------- --- ---.—aerto nations &Blots - _ S.at Top I(B) BIm pans CONDUCTOR. Mi sad - Top IflKB Bim IRKS) IRKBI (RKS) KB) Zone D. IsR.. Type Comment 8,958.0 9,209.0 3,868.4 3.873.3 WS A2, 1J-118 22312007 32.0 SLOTS ALL PERFS IN WELLBORE: Lee UFT, Z1]3 Undulating Alternating solidlsloded Pipe- 2S -Z2.5 " 4 eBRfAD B, umfemntferentia adjacent rows, 3° a+ 3 cAsueT' n Centers staggered 18 deg. 3- non-slodetl ends Yb C O, 7.110 OCPTOR. 9,416.0 10,039.0 3,876.7 3 892.3 WSA2,17118 21232007 32 OTS0 SL z+B3 SEALASSY. 10,233.0 10,846.0 3,890) 3,903.5 WS A2, iJ-118 2231200] 32.0 SLOTS [+aa 11,147.0 11,777.0 3.910.6 3,908.2 WS A2, 1J-118 22312007 32.0 SLOTS 12,074.0 12,544.0 3,909.0 3,913.4 WSA2, 1J-118 212312007 32.0 SLOTS 12,954.0 13,424.0 3,916.] 3,928.6 WSA2 JJ -118 2232007 32.0 SLOTS o oow. 13,792.0 14,178.0 3,93fi.9 3,944.0 WSA2, 1J-118 2232007 32.0 SLOTS 14,515.0 14,645.0 3,954.2 3,95].3 WS A2, 1J-118 2123/200] 32.0 SLOTS Nates: General & Safety — Red Dr. 3/201200] NOTE:MULTI-LATERAL WELL-1J-118(ASANp),1J-11 AONOLame SLI (ISI --_._ iJ-118L2 (OSANO) 61212003 NOTE: VIEW SCHEMATIC w/Alaska Schematir9.0 O LINER LEM, ],14&],3U D LINER HH, 7..,436 B LINER NH, 1XIS A6 tiesi, ].] 777rfi B LINER LEM, )313].006 NTERMEOIATE. PA.9<3 LOTS. 0.9569,A6 '0 1 -1 I SLOTS, SA+SID.O]s - SLOTS 1QY3310,e16 -- i OLD., 11,+47.1+,- eL.TS. 12,074-1Z. ' slats, 1a,asa-1a,4u 417 14 13,]53 14,1]9 LOTS . usII a�s est LINER, Test 14.. T rot+++lel. teeae _ x y� BEy�o `088 _ uS=dfEd c,i'a wwo ..�q �g aY`1 m00 r.3 'cg'o^d = ue"o W _ m J a aE =3'u° 0 m m mw ifc _ y m E x of J x-Ot m� - qw= YN zt p = mJ a^hl iUS. O� of Em co ; a Y 1 a0 E9 m= UJ m a y _ W a - wp r OIT V O Op a E' rm Fp �� •�COG .� ca = jY zm s nm e \ a co m° pq L N p N O m r °' o` ° G N e p )o u nm ui E m \ ma'o a m a` _ p 2^ s FLp NE.3 iF ig i0. 9R5 � Z d a 2• %^ dM ca :aY O E 9 = O F ££ M f nx YE> rvi E up %� n N f„ Y mu° J co Cp rcp6` 9aq 'u \ ¢. O� j% L O Qnu 6 ev } M 00 70 3 wB M o mRn xwm ^ LL, My 'VO hro Loepp, Victoria T (CED) From: Autry, Sydney<Sydney.Autry@conocophillips.com> Sent: Thursday, October 3, 2019 3:16 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 11-118, 11-176 Victoria, Regarding your note below, the AIO allowing WAG injection at West Sak is AIO 2B (Conservation Order 406). For well 1J-176, there are no offset Kuparuk wells are two Kuparuk wells in the AOR (1J-03 & 1D-36). • 1D-36 4 Surface casing is set at 7,047' MD below the top of the West Sak D sd) • 1J-03 4 Surface casing is set at 7,784' MD below the top of the West Sak D sd) in the AOR. For IJ -118 there (reaching 1,243'MD/618'TVD (reaching 1,612'MD/673'TVD Please let me know if you have any additional questions. Thanks, Sydney Autry West Sak 1E/1J Drillsite Engineer + GKA RWO Coordinator ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Autry, Sydney Sent: Saturday, September 28, 2019 6:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 11-118, iJ-176 Victoria, Sorry for the slow reply - I have been on the slope the last few days and will be up here until Wednesday. I am aiming to send you an updated AOR in the next couple days. Thank you, Sydney Autry From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Wednesday, September 25, 2019 10:55 AM To: Autry, Sydney <Svdnev.Autry@conocophillips.com> Subject: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Sydney, For any Kuparuk wells identified in the AOR of these wells, is the surface shoe above or below the WSak? 1 Please identify which AIO allows this WAG injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCoialaska.aov CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended reciplent(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeipo@olaska.gov MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 14,2018 TO: Jim Regg � +Zt�l,g P.I.Supervisor '\ Y SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1J-118 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-118 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry '�-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-118 API Well Number 50-029-23337-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-176-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510144120 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-118 - Type Inj W 'TVD 3595 Tubing 617 -1 617 - 617 - 617 PTD l 2061760 Type Test SPT 'Test psi 1500 IA 1230 2000 - 1950 - 1950' BBL Pumped: L BBL Returned: 1 OA 169 ' L_ 186 _ 175 - 172 Interval p 4YRTST 1P/F - P 1 1 Notes: SCANNED JUN U Ut Monday,May 14,2018 Page 1 of 1 • • 0w r w1 vi inN- xo ai m ‘13 ' / ° °rte 0 D 0 fa 7 > o (` <p � N on y U w v 0 v0 - o N U +, > 0c ' fa vovc a c C c co -15 H tt O co oo v a co Q Q w , c a 6 m in Q W n N- N- 1,- . 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Q a N J N N Cl Cl VI _ N 1 ,-' L w C �' fa v) OCO3 a LO Q F- a` a Q 7061 0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com>� Sent: Wednesday, July 20, 2016 3:39 PM 1(1-1)(14" To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr Specialist; CPF1 Prod Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV's returned to service on CPAI well 1J-118 Jim, The low pressure pilot(LPP) on well 1-118 (PTD#206:170206-177, 206-178)was returned to service today, 7/20/16. The well is currently stabilizing at a wellheadinjection pressure of 525 psig and rate at 960 BWPD, and has been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 NEti JAN 1 1 2017. n1638@conocophillips.com 1 • • I 'I- I I Regg, James B (DOA) - ' 76 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, July 17, 2016 7:57 AM c69/61 /WIC, To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI 1J wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110, 206-111, 206-112) • 1J-118 PTD#20.- • 206-177, 206-178) i 1J-122 (PTD#207-070, 207-071, 207-072) SCANNED JAN 1 2 2017 1J-127 (PTD#206-047,206-048, 206-049) 1J-136 (PTD#206-154, 206-155) 1J-154(PTD#205-035, 205-036, 205-037) 1J-156(PTD#206-067, 206-068, 206-069) The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • • 1 WELL LOG TRANSMITTAL DATA LOGGED /81206 K.BENDER To: Alaska Oil and Gas Conservation Comm. September 14, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 r % y Anchorage, Alaska 99501 k s RE: Water Flow Log: 1J-118 Run Date: 8/16/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1J-118 Digital Data in LAS format, Digital Log file, 1 CD Rom 50-029-23337-00 Waterflow Log 1 Color Log 50-029-23337-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. SCANNED Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: itvilLei.474Ld4.%) 15—e/441e linage Pa'~ject Ul/elf Hilt®ry f=ile ®~r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Well History File Identifier ~.._ - 1'~ III II ~I N II ~ II~~ ~ Or anizin (done) 9 g ~WO-sided III II~II II IIIIII ~~III ^ Rescan Needed RESCAN DI AL DATA OVERSIZED (Scannable) 4~~lor Items: Diskettes, No.~~j ^ Maps: 1^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: P BY. Maria Date: ,S, ) Pro'ect Proofing III II~I~) I~III II III BY: Maria Date: ~s~ Scannin Preparation g x 30 = ~ ~ + 1' =TOTAL PAGES ~ ~ `T (Count does not include cover sheet) BY: _ Maria ~ Date: '-f'" ~ ~~~. ~ (~ ~ /s/ Production Scanning """"""" ' Stage 1 Page Count from Scanned File: ~~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,YES NO BY: Maria Date: ~ ~ C ~s/ 1~~~ YES NO Stage 1 If NO in stage 1, page(s) dlscrepancles were found: BY: Maria Date: /s/ IIIIIII Scanning is complete at this point unless rescanning is required. II I II ~I II I II ReScanned III II'II) II III I I III BY: Maria Date: /s~ Comments about this file: Quality Checked III II'lII III II'I III 10/6/2005 Well History File Cover Page.doc • • 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) 1J-105 (207- 027,207- 028,207 -029) 345 639 1J-118 16 -17. 206 - 177,206 -178) 327 1020 1 J -127 (206- 047,206 -048, 206 -049) 337 934 1J-154 (205- 036,205 -037) 369 623 1 J -160 (207- 015,207- 016,207 -017) 352 568 1J-164 (205- 144,205 -145, 205 -146) 479 1082 1J-180 (206- 150,206 -151) 537 478 1 J -184 (206- 044,206 -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 55 t 1e'`+Ii-- , 9g .. Pid .`.L�' 9/19/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 19, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile / Water Flow Log: 1J -118 Run Date: 10/1/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Minton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -118 Digital Data in DLIS /LAS format, Digital Log file, Interpretation Report 1 CD Rom 50- 029 - 23337 -00 Water Flow Log 1 Color Log 50- 029 - 23337 -00 NG' 5 Zulu Injection Profile Log 1 Color Log 50- 029 - 23337 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating i Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 - 3527 ,,\\ Fax: 907 - 273 -3535 klinton.wood halliburton.com Date: Signed: ,_J • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile /Water Flow Log: 1J-118 Run Date: 8/3/2010 ~~ August 23, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J-118 Digital Data in DLIS/LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-23337-00 Water Flow Log 1 Color Log 50-029-23337-00 Injection Profile Log 1 Color Log 50-029-23337-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood Ohl iburto~~c~~o , ,, , ~ _ ... ~ , g _ Date: .~ ~ ~u ~ ~=~ " '' ~~~/` ~~~ Signed: MEMORANDUM • TO: Jim Regg P.I. Supervisor ' >el(~ ~''~'~I~ FROM: BOi) NOble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 16, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-118 KUPARUK RIV U WSAK 1J-118 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv --~.~ Comm Well Name: KUPARUK RIV U WSAK 1J-118 API Well Number: 50-029-23337-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100516134054 Permit Number: 206-176- 0 Inspection Date: 5/14/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- Well 1J-]ts r~TYpe Inj. W TVD 3s9s ' IA~ lloo ~ --rtT-- -r--t P.T.D 2061~6o LTypeTest SPT ~ Test psi ]soo y pA j Ins ~ v9o - 192 ]~so ]~so .T --- - -; ---f -- 177 ]~s ~_ 4YRTST Interval P/F P 'Tllbl~s~ I g ---- -1 658 ---- ~-- 658 6s8 i --~~- ---- -- -- ---- Notes: °~.t ~~~.~~. t. e,. 2G~'. Wednesday, June 16, 2010 Page 1 of 1 .~~~ ~~, ~- ~~ ~" ~ ~ :. ~ ~' ~~~ e ~~~~ MICROFILMED 6/3 0/2.010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 To: Jim Re k~ 6lilje P.I. Supgrvisor ~kt%C1 ` SUBJECT: Mechanical Integrity Tests l~ ~ CONOCOPHILLIPS ALASKA INC 1J-118 i+Itoivt: Bob Noble KUPARUK RIV U WSAK IJ-118 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1J-118 Insp Num: mitRCN100516134054 Rel Insp Num: API Well Number: 50-029-23337-00-00 Permit Number: 206-176-0 Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-u8 ~ Type Inj. ~' ` TVD 3611 ~ IA uoo 1790 178 t7so ~ P.T.D 2061760 ~ TypeTest ~PT Test psi 1790 QA 175 192 177 ~ 175 ~ Interval a~rRTST p~F P i Tubing --- 6s7 6s8 - 6s8 6s8 --- ~~--1-- - - -- Notes: ~~, ~ . f e<~ ~ --- ~S ~- i ~~~5; ',J4~4`~ `M~~R _ _~ .. _.-v ~ - 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: ConocoPhillips Alaska Inc. ~J FIELD /UNIT /PAD: Kuparuk /KRU / 1J ~ (_•~ ~- DATE: 05/14/10 ~ ly OPERATOR REP: Colee /Phillips - AES AOGCC REP: Bob Noble S ~ ~~ 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 Casin 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 3,43T Tubin 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' Tubin 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 MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s '~ V • 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 V V ,~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s U MEMORANDUM To: Jim Regg ~~ ~j2~1 J~ 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 1J-118 KUPARUK RIV U WSAK 1J-118 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -J~~.~-- Comm Well Name: KUPARUK RIV U WSAK 1J-118 Insp Num: mitRCN090526111945 Rel Insp Num: API Well Number: 50-029-23337-00-00 Permit Number: 206-176-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IJals Type Inj. W TVD 3599 IA 1850 2490 2480 2480 P.T.D 2061760 TypeTOSt SPT Test psi 2490 QA 178 187 179 179 Interval 4YRTST per, P '~ Tubing 628 627 628 627 Notes: Wednesday, May 27, 2009 Page 1 of 1 ~! r ~ t DATA SUBMITTAL COMPLIANCE RE PORT 3/26/2009 Permit to Drill 2061760 Well Name/No. KUPARUK RIV U WSAK 1J-118 Operator CONOCOPHI LLIPS ALASKA I NC API No. 50-029-23337-00-00 MD 14698 TVD 3958 Completion Date 3/19/2007 Completion Status 1-OIL Current Status 1WINJ UIC REQUIRED INFORMATION f Y `-~ Mud Log IVo Samples No Directional Survey Yes DATA INFORMAT ION Types Electric or Other Logs Run: GR/Res, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Cement Evaluation 5 Col 3500 8910 Case 3/22/2007 USIT, MaxVac tractor 'ED C Lis ~ 15182~Induction/Resistivity 3318 11846 Open 6/12/2007 conveyance 22-Feb-2007 P62 LIS Veri, GR, FET, ROP w/Graphics oRpt 15182 LIS Verification 3318 11846 Open 6/12/2007 PB2 LIS Veri, GR, FET, ROP / ED C Lis 15190~nduction/Resistivity 3318 14698 Open 6/12/2007 LIS Veri, GR, FET, ROP w/Graphics t 15190~IS Verification 3318 14698 Open 6/12/2007 LIS Veri, GR, FET, ROP ED C Lis. 15191 Induction/Resistivity 3318 8935 Open 6/12/2007 P61 LIS Veri, GR, FET, ~ ROP w/Graphics _ ~Rpt 15191 LIS Verification 3318 8935 Open 6/12/2007 PB1 LIS Veri, GR, FET, ROP D D Asc Directional Survey 28 14698 Open 6/12/2007 ED D Asc Directional Survey 0 8982 Open 6/12/2007 PB 1 D Asc Directional Survey 8631 11846 Open 6/12/2007 PB 2 og Injection Profile 2 Blu 6911 7891 Case 9/8/2008 Mem Injection Pro, GR, ' CCL, Pres, Temp, Spin 17- D C Pds //~ 16864~Injection Profile 6911 7891 Case 9/8/2008 Aug-2008 Mem Injection Pro, GR, CCL, Pres, Temp, Spin 17- ~ Aug-2008 DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061760 Well Name/No. KUPARUK RIV U WSAK 1J-118 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23337-00-00 MD 14698 TVD 3958 Completion Date 3/19/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y E6g Induction/Resistivity 25 Col 108 14698 tCase~ 2/4/2009 MD ROP, DGR, EWR 21- Log Induction/Resistivity 25 Col 108 3958 ~~~ ,+ cs~s~ 2/4/2009 Feb-2007 TVD DGR, EWR 21-Feb- 2007 v ~1l~ `^ og Induction/Resistivity 25 Col 108 8982 .~a~e 2/4/2009 P61 MD ROP, DGR, EWR 14-Feb-2007 '~og Induction/Resistivity 25 Col 108 3861 J ne`^ LaS€ 2/4/2009 P61 TVD DGR, EWR 14- Feb-2007 og Induction/Resistivity 25 Coi 108 11846 4~ s~ 2/4/2009 PB3 MD ROP, DGR, EWR 14-Feb-2007 Cog Induction/Resistivity 25 Col 108 3902 c~ lO c~ ,CaS€ 2/4/2009 PB3 TVD DGR, EWR 14- / ~ ~ N 0 0 2/4/2 Feb-2007 i EWR l f O PB1 ~ED C 17566 See otes G nLy~ I- 009 or rg ogs nal, and P62 in EMF, CGM and PDS graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~yII Chips Received? `~{-N' Analysis ~4`hN- Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Compliance Reviewed By: ___________ Daily History Received? ~ N Formation Tops ~ N WELL LOG TRANSMITTAL 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-118+L1+L2+PB1+PB2 January 20, 2009 AK-MW-4884845 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-118+L1+L2+PB1+pB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-2333 7-00,60,61,70,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 5 0-029-23 3 3 7-00, 60, 61, 70, 71 Digital Log Images 50-029-23337-00,70,71 50-029-23337-60 50-029-23337-61 1 Color Log 1 Color Log 3 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax:907a273-35 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ ~oL- ~'~lv 1~3~~ Bry~t~~~nda;2i halli~iur~un.com UZ~ ~dCo' ~'~~ C~'SC~~ u~~~to- ~~ c~~~~5 +°i ~ f Date. ~ Signed ~-----" 5~ LPP/SSV defeated on 1J-118 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Rutledge, Kristen S [Kristen.Rutledge@conocophillips.comj Sent: Monday, September 22, 2008 10:57 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; CPF1 Prod Engr; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Targac, Gary Subject: LPP/SSV defeated on 1J-118 Tom /Jim, The low pressure pilot (LPP) on 1J-118 (PTD 206-176) was defeated on 9/22/2008 when the well was returned to service after being shut in for reservoir management during the 1J-120 workover. The well was brought online to support production. Current wellhead pressure is 495 psig; injection rate is 2239 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Lag." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Thanks, Kristen Rutledge Production Engineer, EDP ConocoPhillips Alaska, Inc Phone: (907) 659-7061 Email: Kristen.Rutledge@conocophillips.com 9/22/2008 LPP/SSV enabled on 1J-I 18 Page 1 of 1 Maunder, Thomas E (DOA) From: Rutledge, Kristen S [Kristen.Rutledge@conocophillips.comj Sent: Tuesday, September 23, 2008 10:53 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; CPF1 Prod Engr; NSK Problem Well Supv; NSK West Sak Prod Engr; Targac, Gary; Pierson, Chris R Subject: LPP/SSV enabled on 1 J-118 Tom /Jim, The {ow pressure pilot (LPP). on 1J-118 P~TD 2~06-176} was defeated on 9/22!2008 and was returned to service on 9/23/2008. Current wellhead pressure is 537 psg injection rate is 2336 bwpd. The LPP/SSV function has returned to normal. Please let me know if you have any questions. Thanks, Kristen Rutledge Production Engineer, EDP ConocoPhillips Alaska, inc Phone: (807) 659-7061 Email: Kristen.Rutledge@conocophillips.com 9/23/2008 -~J ~~ ~~'~ ~~~~ $C~I~1111~L1'C~e~' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # n~ , Log Description try N0. 4861 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 iJ-127 12096529 INJECTION PROFILE ~p - 08/14/08 1 1 1 R-11 12096530 PRODUCTION PROFILE °a- 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17/08 1 1 iJ-122 12066542 MEM INJECTION PROFILE / lv3 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE / ~(- ~ ~p 08/19/08 1 1 iJ-105 12066543 MEM INJECTION PROFILE ~,1Q'}- /(O 08/19/08 1 1 2E-12 11996653 SBHP SURVEY ~ - 08!21/08 1 1 1J-156 12080419 INJECTION PROFILE ( 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -( 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ~ ` 08/22/08 1 1 2D-05 12080422 INJ PROF/LDL ' ,~(p ~ 08/23/08 1 1 iH-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 2B-03A 11996656 PRODUCTION PROFILE ~ 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY apps ^' /~ / 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE / = ~ sQ 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE ~ '- Oa L/~ 08/30/08 1 1 2E-13 12080431 SBHP SURVEY ~ - G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY L(•- 08/31/08 1 1 iB-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 1 H-18 11996666 INJECTION PROFILE - ~( 09/03/08 1 1 9 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 1G-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ao~- i7~ \~. ~~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1 J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1 J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1 J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9!6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 RE: LPP/SSV defeated on 1 J- i l 8 • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophiltips.com] Sent: Wednesday, December 19, 200711:15 AM To: Hollar, Eric Andrew; Maunder, Thomas E (DOA); Regg, James B (DOA} Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Rodgers, James T Subject: RE: LPP/SSV defeated on 1J-118 Tom/Jim, Page 1 of 2 The 1 J-118 LPPlSSV was returned to normal on 12/12/07 as wellhead injection pressure built up to above 500 psi. Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com From: Hollar, Eric Andrew Senn Saturday, September 01, 2007 4:17 AM To: Maunder, Thomas E (tom.maunderC~alaska.gov); Regg, James B (jim.regg@alaslca.gov) CC: CPFi DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr, Rodgers, James T Subjecfi: LPP/SSV defeated on ll-118 Tam /Jim, Injection commenced into 1J-118 on 31 Aug-2007 at a rate of 1200 BWPD. The tow pressure pilot (LPP) for this well has been defeated because of {ow wellhead injection pressure. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The permit to drill numbers for the 1 J-118 are as follows: 206-176, 206-177, 206-178. The AOGCC wilt be notified when the injection pressure has increased to at~ve 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Eric Hollar 12l19l20Q7 MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~ ~p l ~2 i'i~~ 7 FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Com~ DATE: Wednesday, September 19, 2 i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-I18 KUPARUK RIV U WSAK 1J-l l8 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `'~,~ Comm Well Name: KUPARUK RIV U WSAK 1J-118 Insp Num• mitRCN070918165330 Rel Insp Num: API Well Number 50-029-23337-00-00 Permit Number 206-176-0 ' Inspector Name: Bob Noble Inspection Date: 9/18/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-lls !TypeInj. ~'~' ~ TVD 3595 ~ IA ' 660 zozo , 69 o i 1960 j p.T j zo6v6o ~TypeTest ~ SPT ' Test psi I zo2o ~ OA ~ 170 ~ zzo i 18o j l so Interval IIVITAL P/F P -'' Tubing ~ ss ss ss ~ ss Notes: Wednesday, September 19, 2007 Page ] of 1 ~ ~ ~EiVED STATE OF ALASKA ~ ~ ~ ~ ~ 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil ~ ~~s Cons Cornfni5sian REPORT OF SUNDRY WELL OPERATIONS Af~ch®ra~~ 1, Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other /^ Prod to WINJ 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: ConocoPhillips Alaska, Inc. ~ D l t ^ .~ ~ 5. Permit to Drill Number: E l 3. Address: eve opmen . xp oratory ' 206-176 / P. O. Box 100360, Anchorage Alaska 99510 Stratigraphic ^ Service ^ 6. API Number: , 50-029 23337 00 7. KB Elevation (ft): - - RKB 109' ~ 9. Well Name and Number: ,, 1J-118 8. Property Designat~n: ~ ADL 25661 &ADL 25650 10. Field/Pool(s): Kuparuk River Field !West Sak Oil Pool - 11. Present Well Condition Summary: .Total Depth measured. 14698' feet true vertical 3958' ' feet Plugs (measured). Effective Depth measured 14690 "` feet Junk (measured) true vertical 3957 feet 4-1/2" Casing Length Size MD _ ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' ..SURFACE 3249' 10-3/4" 3358' 2221' INTERMEDIATE 8840' 7-5/8" 8949' 3867 WINDOW L2 1° 7-5/8" 7208' 3606' WINDOW L1 1' 7-5/8" 776T Perforation depth:. Measured depth: 7958' - 14645' true vertical depth: 3869'- 3957 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7190' MD. Packers &SSSV (type & measured depth) PKRS = BAKER'ZXP~ LINER TOP PACKERS PKR = 7146; 7312'; 7851' SSSV= NIP SSSV= 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~' ~~~ SFP 2 ~ ~~D~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Prior to well operation Oil-Bbl 1.396 Gas-Mcf 1584 Water-Bbl Casin Pressure Tubin Pressure S b t 45 80& 272 u sequen to operation 14. Attachments 1503 526 229 15. Well Class after proposed work: .Copies of Logs and Surveys run Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge . Sundry Numberor N/A if C.O. Exempt Contact Bob Christensen /Bob Buchholz 307-147 ~ Printed Name o D. Chr' tense Title Production Engineering Technician Signature Phone 659-7535 Date ~ ~_T ~ , F 1 4 orm 0- 04 Revised 04!2004 ~r!;_, ~ , . _ . 1J-118 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/31/07 Commenced Water Injection Service LPP/SSV defeated on 1J-i 18 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Hollar, Eric Andrew (Eric.A.Hollarc~conocophillips.comJ Sent: Saturday, September 01, 2047 9:17 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Rodgers, James T Subject: LPP/SSV defeated on 1J-118 Tom /Jim, Injection commenced into 1J-118 on 31-Aug-2007 at a rate of 1200 BWPD. The low pressure pilot (LPP) for this well has been defeated because of tow wellhead injection pressure. The LPPs and SSVs have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The permit to drill numbers for the 1J-118 are as follows:'~t~S, 206-177, 206-178. 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 4068.001." Please let me know if you have any questions. Regards, Eric Hollar Eric Hollar /Peter Nezaticky / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7573 Pager 907-659-7000 x791 9/1/2007 WELI. L®G T'R.~1Sld'II'I'T':~L T'®: State of Alaska ~'Iay 31, 2U0? Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7r" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-118 PB2 AK-'VIW-488485 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23337-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGIVZNG AND RETUR~VTNG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 :.~ , Date,; - Signed: ~„ .. ~iYu-3 • i T'o: Mate of Alaska -~~.~ ~®G ~R~~S~>«TT~>c. Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MVVD Formation Evaluation Logs 1J-118 ~Iav ~ 1, 2t~0 AK 1'VI~~'-4884845 1 LD~1VG formatted CD Rom with verification Iisting. API#: ~0-029-23337-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUR'~TING A COPY OF THE TR4NS11ITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,,J,fl~ Date: ~ = .. . _ ... ' ., ;~ , 1 Signed: ~~i~~ ~ l~f~Q ~b ~~-ALL L®~ -~R.~NS~-~I~~~. T®: State of Alaska flay 3I, ?00 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-118 PB1 AK-MW-4884845 1 LDWG formatted CD Rom with verification listing. API#; 50-029-23337-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING Al~1D RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~-- Date: Signed: 11-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-1.18 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. 2 d°' Tie-on Survey: 2~9~" 4' MD Window /Kickoff Survey 2,999.00' MD (if applicable) Projected Survey: ~' MD !Y ~ 9 p,v~ 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 /;~ ~,,,,,,~,, ~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~_ ~~~ 11-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-118 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 8,982.00' 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. J Anchorage, AK 99518 ,/~ / ~/ n D9 ~ Date ~~~~ ~~ 7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a b~ -r7~ 11-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-118 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,631.79' MD Window /Kickoff Survey 8,650.00' MD (if applicable) Projected Survey: 11,846.00' 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 ,~/ ~ ,,h~~ ate ~~ ~ ...,~aZ.>I~17 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~-~~~ - SARAH PALIN, GOVERNOR oii0-7~~ ®~I ~i`~ ~®1~T~ERQ~7`IOIQ CO1~II~SIOlOT Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-118 Sundry Number: 307-147 Dear Mr. Christensen: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED this ~, day of May, 2007 Encl. cn3-s,2'01 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED °~ a APR 3 0 2007 APPLICATION FOR SUNDRY APPROVALAiaska oil & Gas Cons. Commission 20 AAC 25.280 4nchorage 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time F~ctension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Producer to Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development^ Exploratory ^ 206-176 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23337-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes NO^ 1J-118 9. Property Designation: ( ~ ~~ y ~ ~ ~~ ~l 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit i ~ - o e RKB 109' Kuparuk River Field /West Sak Oil Pool 12. .r,~7.o PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14698' 3958' 14690' 3957' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 108' 108' SURFACE 3249' 10-3/4" 3358' 2221' INTERMEDIATE 8840 7-5/8" 8949' 3867' WINDOW L2 1' 7-5/8" 7208' 3606' WINDOW L1 1' 7-5/8" 7767' 3694' Slotted Liner 6783' 4-1/2" 14690' 3957' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7958' -14645' 3869' - 3957' 4-1 /2" L-80 7190' Packers and SSSV Type: Packers and SSSV MD (ft) PKRS = BAKER'2.XP' LINER TOP PACKERS PKR = 7146'; 7312'; 7851' SSSV= NIP SSSV= 503' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: May 7, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ^ / WDSPL ^ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Nam RO ert D. Chr' tensen Title: Production Engineering Technician Signature Phone 659-7535 Date ~ ~~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test `~ Location Clearance ^ Other: ~''~Xrt-C~~~o~S~~t~ GtLt'.JC~ W / A l~~ ~j Subsequent Form Required: („_`O APPROVED BY Approved b . COMMISSIONER I N Date: Form 10-403 Revised 06/2006 (~ ~ ~ V I I V ~~ ~~~ ~R'°' mHr 9p ~ lUU/ Submit in Dupli r ey~9 ~~~'~~ 1J-118 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-118. This well has been pre-produced for 30 days in order to recover Oil based ''~ drilling fluids prior to putting the well on injection. 1J-118 will provide pressure support for the West Sak A sands. The 10-3/4" Surface casing (3358' and / 2221' tvd) was cemented with 575 sx AS Lite followed by 180 sx LiteCRETE. The 7-5/8" Intermediate casing (8949' and / 3867' tvd) was cemented with 525 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7146' and / 3595' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7312' and / 3625' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7851' and / 3706' tvd. The top of West Sak D sand was found at 7207' and / 3606' tvd. D sand Lateral window top is located @ 7207' and / 3606' tvd. The top of West Sak B sand was found at 7763' and / 3693' tvd. B sand Lateral window top is located @ 7766' and / 3693' tvd. The top of West Sak A sand was found at 8902' and / 3867' tvd. LOCATOR (7162-7164, OD:5.500) SEAL plsaal9o, OD:4.740) Perf (8958-14645) ConocoPhillips Alaska, Inc. KRU 1J-118 1J-118 API: 50029233 3700 Well Type: SVC Angle @ TS; deg @ SSSV Type: . __ NIPPLE Orig Com letion: ____ 3/20/2007 Angle @ TD: _ 89 deg @ 14698 Annular Fluid: Last W/O: Rev Reason: NEW GLV DESIGN Reference L 28' RKB Ref Lo~c Date: Last U ate: 4/2/2007 La s t Ta TD: 14960 ftK8 _ _ Last Ta Date: ___ _ _ _ Max Hole An le: 93 de 11680 Casin Stri__ng=ALL STRINGS Descrlptlon Slze To Bottom ND -- Wt Grade Thread _ _ CONDUCTOR 20.000 0 80 80 94.00 K55 WELD I I SURFACE 10.750 0 3358 2219 45.50 L-80 BTC --- - -- INTERMEDIATE 7.625 0 8949 ____ - 3869 29.70 L-80 BTC-M WINDOW L2 7.625 7207 7208 3606 0.00 WINDOW L1 7.625 7766 7767 3694 0.00 A-SAND LINER - Undulatin 4.500 7851 14690 3958 11.60 L-80 BTC Tubin Strin -TUBING Slze To Bottom TVD Wt Grade Thread ___ 4.500 _ 0 7180 3601 _ _ 12.60 L-80 IBT Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 8958 - 14645 3869 - 3957 WS 5687 32 2/23/2007 SLOTS Alernating solid/slotted pipe A2,WS A3,WS A2, W $ A3,WS A2,WS A3,WS A2,WS A3,WSA2 Gas Lift Mandrels/Valves St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2173 1816 CAMCO KBMG GLV 1.0 BK-5 0.156 1430 3/31/2007 2 6008 3227 CAMCO KBMG DMY 1.0 BK-5 0.000 0 3/19/2007 Other lu s e ui etc,~_- C_ O_MPLETION De th 23 N 23 Tye HANGER Descrl tlon TUBING HANGER ID 4.500 503 503 _ NIP CAMCO'DB' NIPPLE 3.875 7110 3587 SLEEVE-O BAKER CMD SLIDING SLEEVE -RUN OPEN 3.810 7162 7164 3598 35_98 LOCATOR ~_ SEAL BAKER LOCATOR BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.880 3.880 Other Depth 7146 (plugs,, TVD 3595 equi .etc Type- __ PACKER . -LINER DETAILS _ _ Descrl tlon ID 4.950 D-SAND LEM LINER TOP PAC KER 7165 ~ 3598 _ SBR _ _ D-SAND LEM 109-47 CASING SEAL BORE RECEPTACLE 4.750 7185_ _3602 _ _XO D-SAND LEM CROSSOVER BUSHING 3.910 7194 3604 HANGER D-SAND LEM ABOVE HOOK HANGER 3.980 7201 ~ 3605 ~ HANGER D-SAND LEM INSIDE HOOK HANGER 3.688 7312 ~ 3625 PACKER 8-SAND LEM ZXP LINER TOP PACKER 4.950 7331 3628 ~ - SBR -- - B-SAND LEM 109-47 CASING SEAL BORE RECEPTACLE 4.750 7351 3632 ~ XO B-SAND LEM CROSSOVER BU SHING 3.940 7753 3691 HANGER _ _ B-SAND LEM ABOVE HOOK HANGER 3.940 7763 3693 HANGER B-SAND LEM INSIDE HOOK HANGER 3.688 7851 3706 PACKER A-SAND BAKER'HRD' LINER TOP PACKER 5.750 7870 3710 NIP A-SAND'RS' PACKOFF SEAL NIPPLE 4.870 7873 3710 HANGER A-SAND FLEX-LOCK LINER HANGER 4.850 7883 3712 SBE A-SAND SEAL BORE EXTENSION 4.750 7903 3716 XO A-SAND CROSSOVER 3.940 _ 14688 3958 SHOE _ _ A-SAND SILVER BULLET SHOE 3.958 General Notes Date Note 3/20/2007 NOTE: MULTI-LATERAL WELL - 1J-118 A-SAND 1J-118L1 B-SAND 1J-118L2 D-SAND Fw: numbers in from HQ for Class II 1425 pram Subject:Fw: numbers infromHQ for Class II1425 program From; Cutler.Thor@epamail.epa.gov Date:Tue, Ol May 2007 11:08:25'-0700 To: jimre`~`~i~r~idmin.statc.ak.us CG Cutler."[~h~~r~cr~epamail.e~~a.~ov To: James Regg, AOGCC RE: State of Alaska Grant Application for July 1, 2007- June 30, 2008 State Application Iddentifer: G-000320 Stamped in April 19, 2007 James, I received your application for the UIC Class II 1425 program grant money for 2007-8 requesting 130,200 dollars when I returned to the office on April 25, based on a projected amount of the grant as of 3/21/07. The HQ allocation for the Alaska 1425 program is less than the previously projected amount, and tops out at $127,217.00. This is less than the $ 131,700.00 that was available last year. This, my guess, is related to a general overall drop in UIC funds. Please re-submit the paperwork to reflect a federal dollar amount not to exceed $ 127,217. Sorry for the inconvenience. In the interim, I have forwarded the grant material to Greg Luchie with the current numbers but informed him that the numbers will change to a slightly lower figure. My goals were to get the grant into the system (queue) asap so that the award can be quicker, in speite of the fact that numbers will be adjusted lower. I will continue to coordinate the grant processing, and if there are other needs from the Grants Management Program, then I will get back to you. I want to make sure that the activities are in place when I am out of town. If you have questions regarding the 1425 grant, please call. Sincerely, Thor Cutler Please note new fax floor, and mailstop: Thor Cutler, LEG, LHG, LG, CPG EPA (mailstop: OCE-127) (12th floor} 1200 Sixth Avenue Seattle Wa 98101 Phone: 206-553-1673 Fax 206-553-8509 Email cutler.thor @epa.gov ----- Forwarded by Thor Cutler/R10/USEPA/US on 05/01/2007 08:44 AM ----- Thor Cutler/R10/USEPA /US James Regg To 04/27/2007 02:23 cc PM Thor Cutler/R10/USEPA/US@EPA Subject numbers in from HQ for Class II 1425 program 1 of 2 5/1!2007 11:29 AM :,~Li, DAT=- ~'C~.~Tca.L :. ~~.. ~/ L c S 1:: ?,~ : ~ '~/ ~j~ _.::e. ~~~ ~rrEGRI°~~ ~~ ~oF.T - ~~~. T~ , 1 ~~~ ~ i-S). ~~tJ ~ TV`D ; . B TD : ~ ~ ~ i~ ?~ ~~5 '1 T~ID Shoe . ~~-~ ~ZS~eI Tti~ ; li J . ~ ~" ?~ ~'~ _ ~~i Shoe : ~ T`~il ; :C '•~ T'i~ 1 " .~o~,v ~"~~~ PaCxer 1~4C, ''~ ole S~ce ~,(~ ana ~Cr.~?1_C~~, INTEGRTT`~ - Pa.~RT # T"J'?i Set at P e r f s ~... ~- vs`.e~ck~,~ o ~ c~-C~ ~, _nr:ulus Press Test• =~ 15 u'"Iin ~0 min Comments: J<<s -~`Z ~~~~~ ~1~~~S~y,h~y\v°> •~® ~-~~DSt wh~~' ~~~~ Ito ~L~~S~ r- ~'CHpNIC~ ~. INTEGRIT ~ - PART # 2 ~----~C a~aj =~a~ hh~S Cement Volumes :• Amt. Liner Cs~~SOS~ ; DV ~~ C.~ t -J o l t o cove r o e r= ; ~• ,~OZ ~ i~ S ~ ~~ S~ h~~ ~ c.©~.~ec L ~- v.~`.c~C7o~J p~JS ~~ ~ _ eoretical TOC ~ ~~~ ~~ `~~j C.. ~== '-~ S~C~ Cement Bond Log (Yes or No) ~~5 In AOGCC Fi? e CAS C3L Bvaluation, cone aoove perfs ~,~: E~c~ r--- Production Log: Type CONC-LUS ~ ONS : Part = 1 ?art T2. Evaluation ~cs~a o~ w ConocoPhillips April 17, 2007 ~~C~I~~~ Commissioner APR 2 ~ State of Alaska 2Q07 Alaska Oil & Gas Conservation Commission Alaska Dil ~ Gas Cons. Commission 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-118, 1J-118L1 and 1J-118L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-118, 1J-118L1, 1J-118L2. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, ~ ~. ~ l R. Thomas Kuparuk Drilling Team Leader CPAI Drilling Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "a ~ X007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG"'~• Ctxnmission 1a. Well Status: Oil a Gas Plugged ^ Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WiNJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: 3~;, "1 Development 0 ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, tnc. 5. Date Comp., Susp., ~ 7 oraband.: March /~ 2 O~A 12. Permit to Drill Number: 206-176 / ~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: February 6, 2007 ~ 13. API Number: 50-029-23337-00 ~ 4a. Location of Well (Governmental Section): Surface: 1914' FSL, 2366' FEL, Sec. 35, T11N, R10E, UMW 7. Date TD Reached: February 21, 2007 ' 14. Well Name and Number: 1J-118 % Top of Productive Horizon: 268' FNL, 2210' FWL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): ~~9~y Ground (ft MSL): 81' ,07 15. Field/Pool(s): Kuparuk River Field Total Depth: 231' FSL, 2031' FWL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 14690' MD / 3957' TVD West Sak Oil Pool ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558844 ~ y- 5945727' Zone- 4 10. Total Depth (MD + TVD): i 14698' MD / 3958' TVD ~ 16. Property Designation: ADL 25661, 25650 ' TPI: x- 563393 y- 5948861 Zone- 4 Total Depth: x- 563162 ~ - 5954638 ~ Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 503' 17. Land Use Permit: 471, 468 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 3566' MD / 2304' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~~ Sa /JyJj~ JrD ~?"7/,d GR/Res, USIT ~ 3D . ~7 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" x 34" 78.6# H-40 28' 108' 28' 108' 42" 360 sx AS 1 10.75" 45.5# L-80 28' 3358' 28' 2221' 13.5" 575 sx AS Lite, 18o sx LiteCRETE 7-5/8" 29.7# L-80 28' 8949' 28' 3867' 9-7/8" 525 sx DeepCRETE 4.5" 11.6# L-80 7907' 14690' 3716' 3957' 6.75" slotted liner 23. Open to production or injection? Yes ^ - No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7190' 7851' slotted liner from 7908'-8958', 9210'-9416', 10039'-10233', 10847'-11147', 11777'-12074', 12544'-12954', 13424'-13792' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14179'-14515' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production April 7, 2007 Method of Operation (Flowing, gas lift, etc.) flowback Date of Test 4/7/2007 Hours Tested 6.5 hours Production for Test Period --> OIL-BBL 643 GAS-MCF 659 WATER-BBL 0 CHOKE SIZE 30 Bean GAS-OIL RATIO 85 Flow Tubing press. 526 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL / 2273 GAS-MCF 2512 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. , NONE - ~~ ~f~~. t i .i ~FY-6L7 ,,,.. ' Form 10-407 Revised 2/2007 ORIGINn' CONT ESIDE ~ ~ fO•~J . ~a~ c~ ~ 200 ~-5 f ~_ ~ yl~a~.~ r~ 28. GEOLOGIC MARKERS (List all formations and marke encountered): 29. ' FORMATION TESTS NAME MD TVD r Well tested? ^ Yes 0 No If yes, list intervals and formations tested, Permafrost -Top P f B ~3bg6'1,~' ~ ~ ~ s? ' ~~ 7 ' briefly summarizing test results. Attach separate sheets to this form, if er 20 AAC 25 071 needed and submit detailed test information erma rost - ottom 3566 ~• _! y~,D 2304 . . , p West Sak A2 Top i 8902' 3867' West Sak A2 Bottom 14446' 3949' 1J-118PB1 TD 8982' 3862' 1J-118PB2 TD 11846' 3903' N/A / Formation at total depth: W 14698 ' 3958' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey,slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Na Randy Thomas Title: Drillino Team Leader ~~'~'-' " `~ `~ ~ ` '~ Signature -r ,one _~ ~ ~ ~ ~ S ~1 Date INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole welt design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing toot. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, end a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 r: ~onoc~Phi[lips Time Log Summary w'ettvlew W'eb ReAOrYfrt9 Well Name: 1J-118 Job Type: DRILLING ORIGINAL Time Logs _ Daie Frorn To Dur S De th E Depth Phase Code Subcode T COfv1 _ 02/05/2007 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Prepared rig for move while waiting on Peak trucks 18:00 20:00 2.00 0 0 MIRU MOVE DMOB P Disconnected rigs service loops and lines and blew down same 20:00 22:15 2.25 0 0 MIRU MOVE DMOB P Moved rig complex's off location and s otted on end of ad. 22:15 00:00 1.75 0 0 MIRU MOVE MOB P Moved sub base off 1J-137 WO and moved to well 1J-118 and began to s of over well. 02/06/2007 00:00 00:30 0.50 0 0 MIRU MOVE MOB P Fin. spotting sub base over 1J-118 00:30 03:30 3.00 0 0 MIRU MOVE MOB P Set in rig's complex's 03:30 06:00 2.50 0 0 MIRU MOVE RURD P Set in cuttings tank and bermed around same and rock washer. Connected service lines and got water and steam around rig. Completed rig acceptance checklist and ACCEPTED RIG 06:00 hrs 2/6/07 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Fin. NU 21 1/4"diverter and riser. Sim-Ops: loaded pipe shed with 5" DP and strapped same, began to mix spud mud. NOTE: Rig went onto hi hline at 09:00 hrs. 09:00 14:45 5.75 0 0 MIRU MOVE OTHR P PU and stood back 53 stds of 5" DP 14:45 16:00 1.25 0 0 MIRU MOVE OTHR P Function tested diverter, knife valve, koomey unit and PVT system and checked ok. Note: Jeff Jones with AOGCC witnessed the test. 16:00 16:30 0.50 0 0 MIRU MOVE OTHR P PU and stood back 6 stds of 5" HWDP and 'ars. 16:30 18:00 1.50 0 0 SURFA DRILL PULD P MU 13 1/2" bit #1 on 8" motor with 1.5 deg bend with stab. and flt sub RIH to 63'. 18:00 18:45 0.75 0 0 SURFA DRILL OTHR P Flooded conductor and checked surface lines for leaks, pressure tested lines to 3,000 si and ck'd ok. 18:45 19:30 0.75 0 0 SURFA DRILL CIRC P RIH from 63' and tagged cement inside conductor at 100', cleaned out to btm at 108' 19:30 21:30 2.00 0 222 SURFA DRILL DRLG P Spudded well drilling 13 1/2" hole from 108' to 222' 114' ADT 2 hrs 21:30 22:00 0.50 222 0 SURFA DRILL TRIP P POOH from 222' to fin. MU BHA #1 22:00 00:00 2.00 0 75 SURFA DRILL PULD P Began to MU BHA #1, MU MWD and UBHO sub, oriented and uploading MWD Time Logs - --- - ~ Date__ From To Dur S Depth _E. Depth Phase - Code Subcade _T _ COM ____ _ _ __ 02/09/2007 10:00 16:15 6.25 85 3,360 SURFA CASIN( RNCS P Cont. RIH with 10 3/4" 45.5#, L-80, BTC csg and landed same at 3,360', no problems RIH, ran 79 jts csg then MU 20' pup and 1 more Jt csg then MU Vetco Gray hanger and landed csg in the hanger, initial st wt up 160K, do wt 60K. Ran a total of 83 jts and 1 pup jt, total with hanger and float equip is 3,329.49', Ran 23 bowspring cent. with 2 stop rings per well plan, 2 per jt 1 st jt, then 1~t next 21 jts, and 2 cent. inside of the conductor, Landed 10 3/4"csg in the han er. St wt u 160K, do wt 60K 16:15 17:30 1.25 3,360 3,360 SURFA CEME~ CIRC P Circ btms up thru Franks fill up tool staging pump rate up to 50 spm, 5 bpm at 300 psi, reciprocated pipe with a st. wt u of 165K, do wt 88K 17:30 18:00 0.50 3,360 3,360 SURFA CEME~ RURD P RD Franks fill up tool and MU Dowell cement head. 18:00 20:15 2.25 3,360 3,360 SURFA CEME~ CIRC P Cont to Circ and cond mud for cementing, staged pump rate up to 6 bpm at 250 psi then to 70 spm, 7 bpm at 350 psi, st wt up 168K, do wt 88K, initial mud was 9.4 ppg, 275 vis, PV 36 and YP of 71 and gels 23/39, conditioned mud to 9.0 ppg, 40 vis, PV 21 and YP 14 and gels 2/4, held PJSM with crew, Dowell and ASRC vac truck drivers on cement job while circ. Seeing more sand back than on revious wells while circ. 20:15 22:30 2.25 3,360 3,358 SURFA CEME DISP P Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,500 psi, cont to pump 40 add. bbls of CW 100 at 8.3 ppg, pumped 49 bbls of 10.5 ppg mudpush with red dye, ave 4 bpm at 100 psi. Dropped btm plug. Mixed and pumped 464 bbls, 575 sxs of Arctic set lite cement at 10.7 ppg and 4,51 yield with additives, ave 7 bpm at 20 psi, followed with 79 bbls, 180 sxs of Deepcrete cement at 12.0 ppg and 2.49 yield with additives, ave 4 bpm at 230 psi. Note: At 22:20 hrs stuck csg approx 2' off of hanger while reciprocating, had 181 bbls of lead cmt out of the shoe and was 40 bbls into tail cmt, had full returns. Shut down and dro ed to lu . ~ ~__~ ~'® T _ ._s~ _ ~~~®~ ~~c~~ ~ ~a~ 2~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM __ _ __ 02/09/2007 22:30 23:30 1.00 3,358 3,358 SURFA CEME DISP P Dowell chased plug with 20 bbls of water then turned it over to the rig and rig cont. to displace cement with 9.0 ppg mud, ave 7 bpm, initial pressure was 500 psi, max pressure at 7 bpm was 800 psi, bumped plug on talc displacement of 31.5 bbls, pressured up to 1,500 psi and held for a few minutes, bled off and checked floats and ck'd ok. CIP at 23:23 hrs, had 108 bbls of good 10.7 ppg cement back at surface. 23:30 00:00 0.50 3,358 3,358 SURFA CEME~ OTHR P Flushed out diverter and drained same 02/10!2007 00:00 02:00 2.00 0 0 SURFA WELCT NUND P Held PJSM then ND diverter, 16" diverter line and knife valve, PU on diverter. 02:00 02:45 0.75 0 0 SURFA WELC OTHR NP Set 10 3/4" emergency csg slips, set sli s with 65K over blk wt. 02:45 03:45 1.00 0 0 SURFA WELCT OTHR NP Drained 10 3/4" csg, made rough cut. (cut off 2.01" of 4.88" pup below han er 03:45 05:00 1.25 0 0 SURFA WELC NUND NP LD cutoff with hanger, held PJSM then ND diverter and starting head and removed from cellar. 05:00 08:00 3.00 0 0 SURFA WELC OTHR NP Made final cut on csg and welded on cs head ada ter. 08:00 15:00 7.00 0 0 SURFA WELC OTHR NP Waited on wellhead to cool down. Sim-Ops, LD 4 stds of 5" HWDP out of the derrick, PU and stood back 37 stds of 5" DP, changed out lower set of pipe rams from 4 1!2" to 7 5/8", serviced top drive and inspected saver sub. 15:00 16:00 1.00 0 0 SURFA WELC OTHR NP Tested weld on adapter and had slight leak, welded leak and re-tested to 500 si and ck'd ok 16:00 17:45 1.75 0 0 SURFA WELC NUND P MU Vetco Gray threaded adapter flange then oriented and NU MB 222 wellhead, tested seals to 5,000 psi for 10 min and ck'd ok. 17:45 20:00 2.25 0 0 SURFA WELC NUND P NU BOP stack and installed riser 20:00 00:00 4.00 0 0 SURFA WELCT BOPE P Installed long wear bushing, RU and began testing BOPE, tested rams, valves, manifold and annular to 250 psi low and 3,000 psi high, tested with 5" DP. Note Chuck Scheve W/AOGCC waived witnessin of the test. 02/11/2007 00:00 01:45 1.75 0 0 SURFA WELCT BOPE P Fin. testing BOPE, tested rams, valves, manifold and annular to 250 psi low and 3,000 psi high, tested with 4" and 5" DP and 7 5/8" test jt. Note Chuck Scheve W/AOGCC waived witnessin of the test. 01:45 02:15 0.50 0 0 SURFA DRILL OTHR P Installed wear bushing. ~_.___. ~_m ~~ Pa~~ ~a ~# €_. Time Logs - - Da#e From To Dur____ S_Depth_E,_Depth Phase Code SUbcode T COM _ 02/11/2007 02:15 02:30 0.25 0 0 SURFA DRILL SFTY P Held PJSM with rig crew and Sperry Sun on MU BHA, discussed tool lengths and skate operations with short tool to be icked u . 02:30 04:45 2.25 0 356 SURFA DRILL PULD P MU 9 7/8" BHA #2 RIH to 356', MU bit #2 on 7" motor with 1.5 deg bend and MWD, oriented and uploaded tool, RIH PU 3-NMFDC's and shallow tested MWD. 04:45 05:15 0.50 356 356 SURFA RIGMN' SVRG P Serviced top drive, adjusted pipe handlers ace out. 05:15 06:30 1.25 356 3,262 SURFA DRILL TRIP P RIH from 356' and washed down tagging TOC above float collar at 3,262' FC 3,273' . 06:30 07:00 0.50 3,262 3,262 SURFA DRILL CIRC P Circ btms up for csg test, circ at 500 gpm, 1,550 psi, rot wt 80K, up wt 100K, do wt 65K. 07:00 08:00 1.00 3,262 3,262 SURFA CASIN DHEO P RU and tested 10 3/4" csg to 3,000 si for 30 min, charted test. 08:00 09:00 1.00 3,262 3,365 SURFA CEME COCF P Drilled out plugs and float collar at 3,273', shoe track and float shoe at 3,358'. 09:00 09:15 0.25 3,365 3,385 SURFA DRILL DDRL P Drilled 20' of new hole to 3,385' MD/2,232' TVD. Drilled out at 5-10K WOB, 60 r m's, 500 mat 1,400 si. 09:15 09:45 0.50 3,385 3,385 SURFA DRILL CIRC P Displaced hole over to reconditioned 9.0 LSND mud 09:45 10:30 0.75 3,385 3,385 SURFA DRILL LOT P RU and performed a LOT to 13.7 ppg EMW, 528 psi, 9.1 ppg MW and 2,221' ND 10:30 11:30 1.00 3,385 3,385 INTRM1 DRILL WOEO NP Waited on vac truck, 2 trucks had been called out and one truck was late. 11:30 00:00 12.50 3,385 4,937 INTRM1 DRILL DDRL P Drilled 9 7/8" hole per directional plan with 1.5 deg motor from 3,385' to 4,937' MD/ 2,832' TVD (1,552') ART 5.02 hrs, AST 2.31 hrs, ADT 7.33 hrs, clean hole ECD with 9.0 ppg MW is 9.4 ppg, ave ECD was 9.7 ppg, ave bgg 30 units, max gas 283 units, pumped 35 bbl wt'd hi vis sweep (2# over MW) at 4,935' and had 20# increase in cuttings back from the swee . 02/12/2007 00:00 00:15 0.25 4,937 5,050 INTRM1 DRILL DDRL P Drilled 9 7/8" hole from 4,937' to 5,050' MD/2,875' (113') (50' TVD above top of U nu ART .13 hrs, AST .44 hrs. 00:15 00:45 0.50 5,050 5,050 INTRM1 DRILL CIRC P Circ bottoms up for OH LOT, circ at 600 mat 1,650 si and 95 r m's. 00:45 01:30 0.75 5,050 5,050 INTRM1 DRILL LOT P RU and performed OH LOT to 12.4 ppg EMW, shoe ND is 2,221' with 400 si and 8.9 MW. e _ _ ~ ~ac~e ~ ~s# 2~ Time Logs _ Date From To Dur S Depth E._Depth Phase Code Subcode T . _____ COM 02/12/2007 _ 01:30 12:00 10.50 5,050 6,024 INTRM1 DRILL DDRL _ P __ _ Drilled 9 7/8" hole per directional plan from 5,050' to 6,024' MD/3,229' TVD (974'), ART 2.12 hrs, AST 4.35 hrs, ADT 6.47 hrs. 8.9 ppg MW, ave ECD 10.0 ppg, ave BGG 35 units, max gas 168 units. 12:00 20:30 8.50 6,024 6,683 INTRM1 DRILL DDRL P Drilled 9 7/8" hole per directional plan from 6,024' to 6,683' MD/3,475' ND (659'), ART 1.62 hrs, AST 2.96 hrs, ADT 4.58 hrs. Pumped wt'd hi vis swee 2# over M 20:30 21:30 1.00 6,683 6,683 INTRM1 DRILL CIRC P POOH 50' standing 1 std back and fin circ sweep out of the hole, had 40-50% increase in cuttings back from the sweep. Circ at 600 gpm at 1,700 si and 95 r m's, RIH to btm 21:30 00:00 2.50 6,683 6,818 INTRM1 DRILL DDRL P Drilled 9 7/8" hole per directional plan from 6,683' to 6,818' MD/3,510' TVD (135'), ART .57 hrs, AST .91 hrs, ADT 1.48 hrs. 8.9 ppg MW, ave ECD 10.0 ppg, ave BGG 35 units, max gas 297 units. 02/13/2007 00:00 12:00 12.00 6,818 7,714 INTRM1 DRILL DDRL P Directional drill 9 7/8" Intermediate hole from 6618'- 7714' MD. 3685' TVD. ADT = 8.16 HRS. ECD = 10.15 PPG 12:00 00:00 12.00 7,714 8,118 INTRM1 DRILL DDRL P Directional drill 9 7/8" Intermediate hole from 7714' - 8118' MD. 3749' TVD. ADT = 7.41 HRS. ECD = 9.80 PPG 02/14/2007 00:00 00:15 0.25 8,118 8,118 INTRM1 DRILL SFTY P PJSM with crew. Discuss safety hazard recd nition issues. 00:15 10:45 10.50 8,118 8,962 INTRM1 DRILL DDRL P Continue driectional drill 9 7/8" Intermediate hole from 8118' - 8982' MD. 3862 TVD. 10:45 11:30 0.75 8,962 8,627 INTRM1 DRILL TRIP T POOH from 8982' - 8627' MD. Decision to POOH & sidetrack for Geolo 11:30 12:00 0.50 8,627 8,650 INTRM1 DRILL OTHR T Perform troughing operation for low side sidetrack. Trough from 8627' - 8650' MD. Crew Chan e 12:00 12:45 0.75 8,627 8,650 INTRM1 DRILL OTHR T Continue troughing from 8627' - 8650' MD. 12:45 15:15 2.50 8,650 8,675 INTRM1 DRILL DDRL T Sidetrack well from 8650' - 8675'. Obtain checkshot surveys to verify sidetrack as er DD. 15:15 21:15 6.00 8,675 8,950 INTRM1 DRILL DDRL T Directional drill 9 7/8" hole from 8675' - 8950' MD. TVD = 3867'. Geologist called TD 8950' MD. 21:15 21:30 0.25 8,950 8,950 INTRMI DRILL CIRC P Obtain surveys @ TD. Obtain Slow um rates. 21:30 21:45 0.25 8,950 8,950 INTRM1 DRILL OWFF P Monitor well -static. 21:45 00:00 2.25 8,950 7,575 INTRM1 DRILL REAM P BROOH from 8950' - 7575' @ 500 GPM's - 1700 PSI. 80 RPM's - 10K Tor ue 45-50 ft/min P<~cl~ 5 =~f .'.~3 ~ Time Logs ~ Date From__ To____. Dur ___ S_ Dg th E. De th Phase___ Code__TSubcode T COM _ 02/15/2007 00:00 04:15 4.25 7,575 3,350 INTRM1 DRILL REAM P Continue BROOH from 7575' - 3350'. Observed hole looked good, and unloadin hole while back reamin . 04:15 05:00 0.75 3,350 3,350 INTRM1 DRILL CIRC P Pump Hi Visc weighted sweep at the shoe. Circulate until sweep returned and well bore clean. 05:00 06:30 1.50 3,350 350 INTRM1 DRILL TRIP P Pump dry job, Blow down lines & top drive. Continue POOH from 3350' - 350'. 06:30 07:15 0.75 350 0 INTRM1 DRILL PULD P Rig up. Lay down 5" HWDP, Drilling 'ars and NMDC's. 07:15 08:00 0.75 0 0 INTRM1 DRILL OTHR P Plug in and download MWD assembl . 08:00 08:45 0.75 0 0 INTRM1 DRILL PULD P Continue breakout & lay down BHA. Inspect & grade bit to 3/6/WT/A/E/4/RGITD 08:45 09:15 0.50 0 0 INTRM1 DRILL OTHR P Clean & clear rig floor area. Send tools outside. 09:15 09:30 0.25 0 0 INTRM1 CASIN OTHR P Rig up, BOLDS and pull wear bushing. 09:30 11:00 1.50 0 0 INTRM1 CASIN RURD P Rig up to run 7 5/8" casing. 11:00 12:00 1.00 0 80 INTRM1 CASIN RNCS P Held PJSM with crew. Discuss safety 7 hazard recognition issues. Make up shoe joint & threadlock joint. Make up for ue 8000 fUlbs. Crew Chan e 12:00 14:00 2.00 80 1,722 INTRM1 CASIN RNCS P Continue make up shoe track assembly. Fill casing & check floats, floats held. Continue run casing to 1722'. make u for ue - 8000 ft/Ibs. 14:00 14:45 0.75 1,722 1,640 INTRM1 CASIN( RNCS NP POOH from 1722' - 1640'. Install 7 5/8" u 'oint. 14:45 17:00 2.25 1,640 3,350 INTRM1 CASIN RNCS P Continue run 7 5/8" casing from 1640' - 3350'. 17:00 18:30 1.50 3,350 3,350 INTRM1 CASIN CIRC P Circulate & condition mud at the shoe. um s 4 BPM - 370 PSI. 18:30 00:00 5.50 3,350 7,044 INTRM1 CASIN( RNCS P Continue run 7 5/8" casing from 3350' - 7044'. Run 10 joints, circulate 1 joint down slow.Observe fair hole conditions working through a couple of spots 6620' and 6850'. Crew Chan e 02/16/2007 00:00 02:30 2.50 7,044 8,949 INTRM1 CASIN RNCS P Continue run 7 5/8" casing from 7044' to tag bottom @ 8958'. Verify bottom observing hard tag & pressure increase. Work through tight spots @ 8827' - 8830'. SIMOPS: Rig up Dowell cemeters & line up Vac trucks for OBM dis lacement. 02:30 03:45 1.25 8,949 8,949 INTRM1 CASIN RNCS P Lay down joint # 210. Install 20' pup. Breakout & lay down Franks Fill up tool. Install 7 5/8" cement head & lines. t - _~ ~~ _ Ea~l~* ~ €~f 2H Time Lois ___ _ __ __ __ i Date From To Dur S De th E. De th Phase Code Subcode T COM ~ 02!16/2007 03:45 06:00 2.25 8,949 8,949 INTRM1 CEME~ CIRC P _ Circulate & condition mud. Stage pumps to 6 BPM - 580 PSI. Reciprcate casing string in 20' increments.UP WT = 210K, SO WT = 65K. Pre cement mud = 9.0 PPG, YP-10, PV-12, Gels - 7/8/10. 06:00 07:30 1.50 8,949 8,949 INTRM1 CEME~ DISP P Turn rig over to Dowell. Pump 10 BBLS of CW100. Test lines to 3500 PSI. Pump 65 BBLS of CW100. Pump 75 BBLS of 11.0# Mud Push II, Drop Plug. Pump a total of 220.5 BBLS of 12.5 Tail Cement. Drop Plug, pump 2 BBLS water to flush lines to ri floor. 07:30 09:00 1.50 8,949 8,949 INTRM1 CEME~ DISP P Turn over to Rig pumps. Displace cement with 8.4 PPG MOBM @ 7 BPM, slowing pumps to 3 BPM, observe bumping plug with 4039 STKS (406 BBLS) with 1100 PSI. Pressure to 1600 PSI & hold for 5 minutes. Bleed pressure and check floats. Floats held. CIP 0840 HRS. 09:00 09:30 0.50 8,949 0 INTRM1 CEME RURD P Rig down Cement head & lines. Nipple down BOP stack & wellhead. 09:30 09:45 0.25 0 0 INTRM1 CASIN RNCS P Set 7 5/8" Emergency slips as per Vteco Gray rep with 70K pulled on casin . 09:45 11:00 1.25 0 0 INTRM1 CASINO RNCS P Rig up cutter & cut casing as per Vetco rep. Cut off joint = 11.67' as tanned in detail. Install ackoff. 11:00 12:00 1.00 0 0 INTRM1 CASINO NUND P Nipple up wellhead & BOP stack. Crew Chan e 12:00 12:15 0.25 0 0 INTRMI CASINO DHEQ P Rig up lines to OA. Test packoff as per Vetco rep to 80% of burst @ 3850 PSI - 10 minutes. 12:15 12:30 0.25 0 0 INTRM1 CASIN NUND P Install Turnbuckles on BOP stack. Air up riser boots. Clean cellar area. Rig u Little Red Services. 12:30 14:00 1.50 0 0 INTRM1 CASIN( CIRC P Perform Infectivity test pumping down OA, with chart picking MWE @ 11.5 PPG. Flush annulus with 40 BBLs of water, continuing to pump freeze protect diesel @ 2.75 BPM - 800 PSI when shut in. All pumping recorded on chart. SIMOPS: Rig up short bales on Top Drive, install mousehole, and rig u to la down 5" DP. 14:00 14:15 0.25 0 0 INTRM1 DRILL PULD P Install Wear bushing. RILDS. 14:15 17:00 2.75 0 0 INTRMI DRILL PULD P Breakout & lay down 5" DP from the derrick. 17:00 17:45 0.75 0 0 INTRM1 DRILL PULD P Pull thread protectors and tools to rig floor. 17:45 23:30 5.75 0 0 INTRM1 DRILL PULD P Continue breakout & lay down 5" DP from the derrick.layed down 90 stands total. SIMOPS: Level ri . e®a _~~~~ ~~c~~ $ of 28 ~ ~ Time Logs Date_ From To Dur S. De th E. De th Phase Code Subcode T COM 02/16/2007 23:30 00:00 0.50 0 0 INTRM1 DRILL OTHR P __ _ Change elevators, pick up 3 1/2" IF handling tools to rig floor. Crew Chan e 02/17/2007 00:00 00:15 0.25 0 0 INTRM1 DRILL PULD P Pick up MWD tools and make break on tools for re build. 00:15 00:30 0.25 0 0 INTRM1 RIGMN SFTY P PJSM with crew. Discuss safety & hazard recognition issues. Discuss rocedure for Sli & cut. 00:30 02:00 1.50 0 0 INTRM1 RIGMN SVRG P Slip & cut 273' of drilling line. Inspect & ad~ust brakes. 02:00 02:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM with crew. Discuss procedure for ickin u 4" DP from shed. 02:15 07:45 5.50 0 2,925 INTRM1 DRILL PULD P Pick up 4" drill pipe from shed. Picked up 30 jnts 4" DP, 14 stands of Hybrid Push Pipe, 21 jnts of 4" DP, installed 135 Su er Sliders on DP on TIH. 07:45 08:00 0.25 2,925 2,925 INTRM1 DRILL PULD P Clean & clear rig floor of thread rotectors. 08:00 10:00 2.00 2,925 0 INTRM1 DRILL TRIP P POOH racking back DP in derrick. 10:00 10:30 0.50 0 0 INTRM1 DRILL PULD P Clean & Clear rig floor area of OBM. Pull tools to floor for next BHA. 10:30 12:00 1.50 0 0 INTRM1 RIGMN SVRG P Change out saver sub on Top Drive to 4" XT 39. Crew Chan e 12:00 12:30 0.50 0 0 INTRM1 RIGMN SVRG P Continue change out saver sub. Wire tie same. 12:30 14:45 2.25 0 92 INTRM1 DRILL PULD P Clean rig floor. Held PJSM with crew. Discuss safety issues and procedure for making up BHA. MAke up BHA #3 as er DD &MWD re s. 14:45 15:30 0.75 92 92 INTRM1 DRILL OTHR P Plug in and upload MWD assembly. 15:30 16:45 1.25 92 220 INTRM1 DRILL PULD P Continue make up remaining BHA. Pick up new non mag flex drill collars, makin break twice for new make u . 16:45 17:45 1.00 220 220 INTRM1 DRILL OTHR P Pick up 1 stand of DP, perform shallow pulse test with pumps @ 285 GPM's - 1150 PSI. RPMs' 10-50. Observed PWD tool only intermittenly working. Break in Geo Pilot assembly. Bfow down To Drive & lines. 17:45 18:00 0.25 220 500 INTRM1 DRILL TRIP P Single in hole picking up 4" Dp from i e shed. 18:00 18:15 0.25 500 500 INTRM1 DRILL OTHR P Perform shallow pulse test again to check PWD tool. Good test. 18:15 22:00 3.75 500 5,035 INTRM1 DRILL TRIP P Continue trip in hole picking up 4" DP from pipe shed to 5035' MD. Fill drill strin eve 25 stands. 22:00 23:00 1.00 5,035 5,035 INTRM1 DRILL SFTY P Held BOP Drill & table top Stripping Drill & Well Kill Drill with crew. Discuss safety & hazard recognition issues, and proper procedures to kill well, and strip the drill string into hole. All hands artici ated. 23:00 00:00 1.00 5,035 5,968 INTRM1 DRILL TRIP P Continue trip in hole picking up singles of 4" DP from shed to 5968' MD. Crew Chan e ~________ _~_ -®~_ ~~ ~ ~ ~a~~~ ~ ~~~f 2II~ l Time Lo s --___ Date___ From To Dur 5 Depth E__Depth Phase Code Subcode T COM __ 02/18/2007 00:00 01:30 1.50 5,968 8,860 INTRM1 DRILL TRIP P Continue trip in hole picking up singles of 4" DP from shed to tag Float eu i ment 8860' MD. 01:30 02:30 1.00 8,860 8,860 INTRM1 DRILL CIRC P Circulate bottoms up with OBM. 3200 Strokes. 8.4 PPG. Attempt to gain signal of PWD tool. Failed. Called Engineer. Decision to drill shoe track & 20' of new hole. Attempt to gain si nal. 02:30 03:15 0.75 8,860 8,860 INTRM1 DRILL FIT P Rig up and test casing to 3000 PSI - 30 minutes. Record on chart. Good test. Ri down test a ui ment. 03:15 05:30 2.25 8,860 8,950 INTRM1 CEMEP COCF P Drill through float equipment & shoe track from 8860 ' - 8949'. 05:30 06:15 0.75 8,975 8,975 INTRM1 DRILL CIRC P Circulate & condition mud for LOT. 06:15 06:30 0.25 8,950 8,975 INTRM1 DRILL DDRL P Drill 25' of new hole to 8975' MD. 06:30 07:15 0.75 8,975 8,975 INTRM1 DRILL LOT P Rig up lines and perform LOT to EMW of 12.9 PPG. Bleed pressures. Monitor well -static. 07:15 12:00 4.75 8,975 9,232 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A lateral from 8975' - 9232' MD. TVD = 3871'. ADT = 2.7 HRS. Crew Chan e 12:00 00:00 12.00 9,232 10,310 PROD1 DRILL DDRL P Continue Directional drill in the A lateral from 9232' - 10310' MD. TVD = 3891'. ADT = 8.5 HRS. traotat of 62' of concretions drilled. Crew Chan e 02/19/2007 00:00 00:15 0.25 10,310 10,310 PROD1 DRILL SFTY P PJSM -Hazard Recognition on Drlg 00:15 12:00 11.75 10,310 11,630 PROD1 DRILL DRLG P Drlg w/ Geo-Pilot f/10,310' MD to 11,630' TVD 12:00 13:00 1.00 11,630 11,752 PROD1 DRILL DRLG P Drlg w/ Geo-Pilot f/11,630' MD to 11,752' MD / 3906' TVD -Ream and Survey - BROOH 1 stand and set back in derrick. 13:00 14:45 1.75 11,752 11,752 PROD1 DRILL CIRC P Circu & Recip -Pump &Circu 30 bbl Hi Vis sweep around RPMs 130 / PR 310 -Returns showed 10% increase - Ream back to bttm. 14:45 15:45 1.00 11,752 11,846 PROD1 DRILL DRLG P Drlg w/ Geo-Pilot f/11,752' MD to 11,846' MD / 3903' TVD *""` Out Of Zone - Back u to sidetrack. 15:45 17:15 1.50 11,846 11,680 PROD1 DRILL REAM NP BROOH from 11846' - 11655'. Trough hole from 11655' - 11680' MD. 17:15 20:30 3.25 11,680 11,698 PROD1 DRILL DDRL NP Time drill for sidetrack from 11680' - 11698' (18'). ABI surveys indicating ood kickoff. 20:30 22:45 2.25 11,698 11,846 PROD1 DRILL DDRL NP Continue driectional drill from 11698' - 11846'. 22:45 00:00 1.25 11,846 11,910 PROD1 DRILL DDRL P Continue driectional drill from 11846' - 11910' MD. TVD = 3910'. Total Bit Hrs = 26.4. 02/20/2007 00:00 00:15 0.25 11,910 11,910 PROD1 DRILL SFTY P PJSM -Hazard recognition while drillin . 00:15 12:00 11.75 11,910 12,780 PROD1 DRILL DDRL P Continue driectional drill from 11910' to 12,780' MD./ 3911' TVD'. ~~ ~-__-~- ~~~ 3~ ~f e~ ,~ Time Logs Date From To Dur _S. De th E. DE,pth, Phase_ Code Subcod~__T COM _ 02/20/2007 12:00 12:15 0.25 12,780 12,780 PROD1 DRILL SFTY P PJSM -Hazard recognition whiie drillin . 12:15 00:00 11.75 12,780 13,807 PROD1 DRILL DDRL P Continue driectional drill from 12,780 to 13,807' MD.! 3937' ND. Pumped 30 bbl Hi Vis sweep @ 13,000' 10% increase on returns BU 02/21/2007 00:00 00:15 0.25 13,807 13,807 PROD1 DRILL SFTY P PJSM :Hazard recognition while drillin 00:15 01:30 1.25 13,807 13,991 PROD1 DRILL DDRL P Drlg w/ Geo-pilot f/ 13,807' MD to 13,991 MD 01:30 03:00 1.50 13,991 13,991 PROD1 DRILL CIRC P Con't to circu Hi/Vis sweep out of hole X 1 BU 318 GPM, 130 RPMs, PP 3400 PSI - Reci full 90' std. 03:00 11:30 8.50 13,991 14,698 PROD1 DRILL DDRL P Drlg w/ Geo-pilot f/ 13,991' MD to 1.4,698' MD / 3955' TVD -Pump sweep while drilling last std. ***NOTE*** Well TD- 14,698' MD 13955' TVD 11:30 12:00 0.50 14,698 14,698 PROD1 DRILL CIRC P Finish circu sweep out of hole -10% increase @ BU -Survey -Record SPRs 12:00 20:00 8.00 14,698 8,935 PROD1 DRILL TRIP P BROOH f/ 14,698' MD to 9141' MD - 300GPM, 130 RPMs (Pulled ever other stand as hole permitted) Had slight pack off problem @ 12,325 and 11,910' 10-15k over pull. -Pull 9141' - 8935' ulled clean. 20:00 22:00 2.00 8,935 8,935 PROD1 DRILL CIRC P Circu and condition -Recip string full 90', Pump sweep, FR 310 GPM, 110 RPMs - 0 increase at BU circu BU+ 22:00 00:00 2.00 8,935 10,735 PROD1 DRILL TRIP P TIH - (Tight @ 9590' and 9640' -SOW 38-40k Ream 10,040' MD to 10,355' MD 02/22/2007 00:00 06:30 6.50 10,355 14,698 PROD1 DRILL TRIP P TIH f/ 10,355 MD to 11,915' MD Ran out of down wt. Rotate down from 11,915' MD to 14,698' MD - PR 2 bpm, PP 500 psi, RPM's 100-Washed and Reamed last std down at drilling rate 100 RPMs, 85 SPM( 7.23 bpm) PP 3500 "* NOTE**** Several thrust collars on the WWT SS had loose bolts. All bolts were checked and re-tor ued to s ec. 06:30 09:00 2.50 14,698 14,698 PROD1 DRILL CIRC P Pumped HiNis sweep @ 130 RPM, 90 spm, 3800 psi recip full 90' -Had 5% increase excess cuttings on BU - Con't circu 2 X BU strokes with cutting cleanin u . 09:00 10:30 1.50 14,698 14,698 PROD1 DRILL CIRC P Change out to SFOBM - PR 321 GPM, 130 RPMs -Recip full 90' during chan a out. 10:30 12:00 1.50 14,698 13,623 PROD1 DRILL TRIP P Flow Check well "Static" -Blow down top drive -Drop 1 3/4"drift w/wire tail - POOH on elevators f/ 14,698' MD to 13,623' MD - SLM out of hole 12:00 12:15 0.25 13,623 13,623 PROD1 DRILL SFTY P PJSM -Tripping out of hole Hazard Reco nition &SLM ~ ~m -- - ~ ®~ E~~~ ;" t~f 2~ C~ Time Logs Date Fram To Dur S. be th E _D_epth Phase Code Subcode T __.__ COM 02/22/2007 12:15 19:00 6.75 _ 13,623 156 PROD1 DRILL TRIP P Con't POOH on Elevators (SLM) f/ 13,623' MD to 156' MD -Std bk HWDP, Jars & Flex DCs, UD stab & Flt sub -Monitor well "Static" *** Note *** Hole fill PW calcuation 15.6 bbls over, SLM 3.09 over DP tall . 19:00 19:30 0.50 156 156 PROD1 DRILL SRVY P Down Load MWD - SIOPS -Clean rig floor -Grease Crown 19:30 21:00 1.50 156 0 PROD1 DRILL PULD P UD MWD, Short DC, Geo-Pilot & Bit - Remove all tools and clean ri floor. 21:00 21:15 0.25 0 0 COMPZ DRILL SFTY P PJSM -Hazard recognition & Hazard Assessment on RU Schlumberger wire line and runnin USIT to s. 21:15 22:45 1.50 0 0 COMPZ EVALVI~ PULD P P/U and R/U Schlumberger Tools, Sheeves & Logging tool to rig floor. R/U same. 22:45 23:30 0.75 0 0 COMPZ EVALUb ELOG P TIH w/ E-line USIT tools & Tractor tool -Tractor tool showed failure on 1 of 3 at 400'. POH and UD 1 tractor 23:30 00:00 0.50 0 0 COMPZ EVAL ELOG P Running in hole with logging tools. 02/23/2007 00:00 00:15 0.25 0 0 COMPZ EVAL SFTY P PJSM -Discuss hazards associated with wire line to in 00:15 05:30 5.25 0 0 COMPZ EVAL ELOG P Run USIT log f/ 8950' to 4500' MD +/- - Logging went well -Log went in to 6950' and then had to tractor to bttm 8950' -Total time from PJSM until R/D WL = 9:15 min. 05:30 06:15 0.75 0 0 COMPZ CASIN RURD P PJSM on running liner- R/U to run Liner 06:15 07:00 0.75 0 0 COMPZ EVALVb PULD P R/D wire line equipment and remove from ri floor. 07:00 11:45 4.75 0 0 COMPZ CASIN PUTB P RIH PU 4.5" 11.6# L80 BTC Slotted & Blank liner per detail (161 jts total ). Constrictor packers placed in 8 de ths. Listed on detail 11:45 12:00 0.25 0 58 COMPZ CASIN PUTS P Start PU & MU Baker "HRD" ZXP liner to acker ass . 12:00 12:30 0.50 58 6,839 COMPZ CASIN PUTB P Con't PU & MU Baker "HRD" ZXP liner top packer assy. Total length of liner 6,838.84' Up wt 82K, Dn wt 62K - R/D cs tools 12:30 19:30 7.00 6,839 14,698 COMPZ CASIN( RUNL P RIH w/ Liner on DP f/ 6852' to 8906' Interm shoe 8949') Up wt 108K, Dn wt 60K- @ 20 RPMs =Rot wt 65K. -RIH to 13,144' and ran out of SO weight. - Rotate liner @ 20 RPMs, Torq 8-10k - Stopped rotation @ 13,174', 13,661', 14,435', 14,459'. We did tag Bttm @ 14,698' and pulled back to 14,690' Liner Settin De th. Dro ed Ball 19:30 20:30 1.00 14,690 14,690 COMPZ CASIN( PUTB P Ball on seat -Pressure up to 3000 psi and set hanger & packer hold 5 min. Pressure up to 4200 psi and release liner. Liner To 7851' MD 20:30 00:00 3.50 7,851 0 COMPZ CASIN RUNL P TOH w/ Baker running tools & LD same. ~_._ __ w_..__ ~.-~ Pac~x. i2 of Zf3 ~- ~~` ~~ • Time Logs __ -- _- - Date From To Dur S ~eLtti E. Depth Phase Code Subcode T COM 02/24/2007 00:00 00:45 0.75 0 0 COMPZ CASINC RURD P Remove all tools from rig floor and clean same. 00:45 02:00 .1.25 0 0 COMPZ RIGMN SVRG P Slip & Cut Drill Line 72' cut, Service TD, Ck saver sub "OK" 02:00 03:00 1.00 0 0 COMPZ DRILL PULD P PU Baker tools from beaver slide. Sta eon ri floor. 03:00 06:30 3.50 0 90 PROD2 DRILL PULD P MU BHA #4 - MU Stop sub w/ liner seals, Unloader sub, 1 jt 3.5" Dp, 2 pup jts (14.62' + 9.78') Blank sub, Trip anchor, Safety disconnect, Drain sub, Debris cover sub, Whip stock, Window mill, Lower mill, Upper Full Guage mill, 1 jt 3.5" HWDP, Flt sub, Su er Slim MWD 06:30 07:00 0.50 90 90 PROD2 DRILL SRVY P Up Load MWD 07:00 07:45 0.75 90 370 PROD2 DRILL PULD P Con't PU BHA #4 - PU Bumper sub, XO, 2 stds Hybrid Push Pipe -Shallow Test MWD 370"'OK" 07:45 12:00 4.25 370 6,504 PROD2 DRILL TRIP P RIH f/ 370' to 6504' MD - Up wt 124K, Dn wt 74K ***NOTE*** Using slick DP only. No WWT SS because of steel cuttin could dama a sleeves. 12:00 12:30 0.50 6,504 6,720 PROD2 DRILL SFTY P PJSM & Con't Tripping in hole. Mad pass for K-13 tie in, 6680' to 6720' MD 12:30 13:30 1.00 6,720 7,857 PROD2 DRILL TRIP P Con't RIH to 7792' MD - MU std - Up wt 140K, Dn wt 70K- Tag TOL @ 7857' w/ 15K -Set whipstock 16 deg Left & confirmed set w/ 10K over ull. 13:30 14:15 0.75 7,857 7,765 PROD2 DRILL CIRC P Shear off Whipstock -Displace hole over to drillin OBM. 8.4+ 14:15 16:30 2.25 7,765 7,779 PROD2 DRILL MILL P Mill "B" lat. window from 7766' to 7779' - WOM 2-3K, RPM 100, PR 285 GPM, PP2400psi, Torq 6K -Pumped ~~ 30 bbl hi vis sweep (20% increase in cuttin TOW 7766' & BOW 7779' MD 16:30 19:00 2.50 7,779 7,797 PROD2 DRILL MILL P Mill 7779' to 7797' MD (Leaves Full guage hole to 7784') 5' outside window. 19:00 19:45 0.75 7,797 7,797 PROD2 DRILL MILL P Pump sweep and circu around -Dress window area (Made 4 passes thru window with pump and the last pass without pump.) Pu wt 128K, Dn wt 85K, Rot wt 95K ,Torq 4K, Monitor well, Pum slu ,Blow down TD 19:45 22:00 2.25 7,797 0 PROD2 DRILL TRIP P POOH w/Milling assy -Std Bk Push Pi e & H brid DCs 22:00 00:00 2.00 0 0 PROD2 DRILL PULD P UD Bumper sub, Dn Load MWD, UD Milling asst. Guaged upper mill "Full Gua e" 02/25/2007 00:00 00:30 0.50 0 0 PROD2 DRILL PULD P Clean all tools from rig floor - BOLDS- Pull wear bushin ®~ m _~ _e_ ~~c~~ i ~ o~ 2~ r~ I Time L s '. Date From To Dur S. De th E. De th Phase Code Subcode T COM 02/25/2007 00:30 01:00 0.50 0 0 PROD2 DRILL CIRC P PU Flushing tool -Flush all BOPS components by circu thru tool and rotating, working up and down thru 'stack to remove metal milling cuttings. Function all Rams & Annular. 01:00 02:00 1.00 0 0 PROD2 WELCT BOPE P RU BOP Test Equipment 02:00 06:00 4.00 0 0 PROD2 WELCT ROPE P Test BOPs 250 psi Lo - 3000 psi High - Test witnessed by AOGCC rep Jeff Jones - Tested all BOP components and Choke manifold. Gas and H2s alarms tested "All OK" 06:00 06:30 0.50 0 0 PROD2 WELCT NUND P Set wear bushing - RILDS 06:30 07:45 1.25 0 94 PROD2 DRILL PULD P PJSM - MU BHA #5 per DD &MWD detail. 07:45 08:30 0.75 94 94 PROD2 DRILL SRVY P Upload MWD 08:30 09:30 1.00 94 371 PROD2 DRILL PULD P Con't PU BHA #5 -Shallow test MWD 371' "OK" 09:30 12:00 2.50 371 5,149 PROD2 DRILL TRIP P RIH to 1512' - PU XO, Agitator & Shock sub, XO, Test same "OK". AG Tool @ 1600', 80 SPM, 284 GPM, 2240 psi -Blow do TD - Con't RIH to 5149' MD 12:00 13:00 1.00 5,149 7,797 PROD2 DRILL REAM P PJSM - RIH to 7668' MD break circu - Orient to Hi side and wash to 7759' Up wt 108K, Dn wt 69K) Slide clean without pump to 7785' (Top of full guage hole) & open hole to 7797' Bttm of pilot hole) Clean hole ECDs 9.40 13:00 00:00 11.00 7,797 8,297 PROD2 DRILL DDRL P Drlg & Slid 6 3/4" hole w/ Motor 7797' to 8297' MD / 3711' TVD. ** Note"' Drilled total of 125' of concretions this tour. 02/26(2007 00:00 12:00 12.00 8,297 8,786 PROD2 DRILL DDRL P Drlg & Slide w/Motor f/ 8297' MD to 8786' MD / 3717' TVD. Up wt 119K, Dn wt 65K, Rot wt 83K, Torq on & off 7K, Max gas 83 units, Jar hrs 67.28. Drilled total of 89' of concretions. ART 8.88 hrs, AST .35 hrs =Total ADT 9.23 hrs, ECDs 9.68 12:00 12:15 0.25 8,786 8,786 PROD2 DRILL SFTY P PJSM -Drilling & Conections pinch oints -hazard reco nition. 12:15 00:00 11.75 8,786 9,786 PROD2 DRILL DDRL P Drlg & Slide w/ Motor f/ 8786' MD to 9786' MD / 3740' TVD. Up wt 120K, Dn wt 60K, Rot wt 85K, Torq on 7K off 8K, Max gas 159 units, Jar hrs 75.05. Drilled total of 87.0' of concretions. ART 8.88 hrs, AST .35 hrs =Total ADT 9.23 hrs, ECDs 10.01 I €~ax~e 14 of 28 i ' Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 02/27/2007 00:00 12:00 12.00 9,786 10,576 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with 1.5 deg mud motor from 9,786' to 10,576' MD/3,750' TVD i (790') ART 5.55 hrs, AST 1.69 hrs, ADT 7.24 hrs, MW 8.45 ppg, ave ECD 10.0 ppg, ave BGG 45 units, max gas 95 units, drilled thru 4 concretions for 42'. 12:00 00:00 12.00 10,576 11,485 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with 1.5 deg mud motor from 10,576' to 11,485' MD/3,760' TVD (909') ART 6.89 hrs, AST 1.14 hrs, ADT 8.03 hrs, MW 8.45 ppg, ave ECD 10.3 ppg, ave BGG 45 units, max gas 142 units, drilled thru 10 concretions for 97' 14 total last 24 hrs for 139'). 02/28/2007 00:00 10:45 10.75 11,485 12,240 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with 1.5 deg mud motor from 11,485' to 12,240' MD/3,762' TVD (755'} ART 8.13 hrs, AST .29 hrs, ADT 8.42 hrs, MW 8.45 ppg, ave ECD 10.35 ppg, ave BGG 50 units, max gas 193 units, drilled thru 5 concretions for 60'. Decision was made to POOH and PU Geo ilot. 10:45 12:00 1.25 12,240 12,240 PROD2 DRILL CIRC NP Pumped 30 bbl hi vis sweep and circ out of hole, had 5% increase in cuttings back from the sweep. Reset iron roughneck on track after repairing same. 12:00 16:00 4.00 12,240 7,760 PROD2 DRILL REAM NP Held PJSM then backreamed out of hole 10 stds from 12,240' to 11,400' then BROOH every other std to 7,948', then POOH thru the window to 7,760'. (TOW at 7,766') BROOH at 90 rpm's, 300 gpm, ICP 3,250 psi, FCP 2,800 si, no roblems BROOH. 16:00 16:30 0.50 7,760 7,760 PROD2 DRILL OWFF NP Monitored well-static, pumped dry job and blew down to drive. 16:30 19:30 3.00 7,760 91 PROD2 DRILL TRIP NP POOH from 7,760' to MWD at 91', LD shock tool and agitator then stood back HWDP, jars and NMFDC's on trip out. Hole took 4.5 bbls over talc hole fill. 19:30 21:00 1.50 91 0 PROD2 DRILL PULD NP Downloaded MWD then fin. LD BHA #5, LD MWD and motor 21:00 22:00 1.00 0 0 PROD2 DRILL OTHR NP Cleared and cleaned rig floor 22:00 22:30 0.50 0 0 PROD2 RIGMN SVRG NP Serviced top drive and drawworks 22:30 00:00 1.50 0 40 PROD2 DRILL PULD NP Began to MU BHA #6, MU bit on Geopilot, pony flex DC, smart stabilizer and DM HOC 03/01/2007 00:00 02:15 2.25 40 456 PROD2 DRILL PULD NP Fin MU geopilot BHA #6, MU MWD and uploaded same, RIH with BHA and 1 std of 4" DP to 456' and shallow tested MWD and eo ilot. I Page 15 of 23 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/01/2007 02:15 07:00 4.75 456 11,849 PROD2 DRILL TRIP NP RIH from 456' to 11,849' and lost down wt., no problems RIH thru window at i 7, 766' 07:00 08:00 1.00 11,849 12,240 PROD2 DRILL REAM NP Washed and reamed from 11,849'to btm at 12,240' with no problems, washed down at 50 spm, 177 gpm at 1,280 psi, 100 r m's 9K ft-Ibs for ue. 08:00 00:00 16.00 12,240 13,560 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 12,240' to 13,560' MDl3,774' TVD (1,320') ADT 11.2 hrs, 8.45 ppg MOBM, ave ECD 10.9 ppg, pumped hi vis sweep at 12,900' and had 5% increase in cuttings back from the sweep, ave BGG 50 units, max gas 125 units. Drilled thru 8 concretions for 106'. 03/02/2007 00:00 12:00 12.00 13,560 13,996 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 13,560' to 13,996' MD/3,787' TVD (436') ADT 9.68 hrs, 8.45 ppg MOBM, ave ECD 10.9 ppg, 10.5 ppg while on concretion, ave BGG 50 units, max gas 93 units. Drilled thru 5 concretions for 42'. 12:00 00:00 12.00 13,996 14,551 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 13,996' to 14,551' MD/3,800' TVD (555') ADT 9.12 hrs, 8.45 ppg MOBM, ave ECD 11.0 ppg, 10.5 ppg while on concretion, ave BGG 50 units, max gas 111 units. Drilled thru 9 concretions for 71'. (14 total for 113') No swee s 03/03/2007 00:00 02:30 2.50 14,551 14,795 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 14,551' to 14,795' MD/3,802' TVD 244') ADT 2.28 hrs, "B" lat T.D 02:30 02:45 0.25 14,795 14,795 PROD2 DRILL OWFF P Monitored well-static, took SPR's 02:45 12:00 9.25 14,795 7,756 PROD2 DRILL REAM P Backreamed out of hole from 14,795' to above TOW to 7,756', (TOW @ 7,766') BROOH at 130 rpm's, 320 gpm, ICP at 3,500 psi, FCP 2,600 psi, pulled thru window with 5-10K drag and had no other problems BROOH. 12:00 13:15 1.25 7,756 7,756 PROD2 DRILL CIRC P Pumped 35 bbl wt'd hi vis sweep (2# over MW) and circ hole clean, had 15% increase in cuttings back from the sweep, circ hole clean at 130 rpm's, 5k ft-Ibs torque, 320 gpm at 2,600 si. 13:15 15:45 2.50 7,756 12,409 PROD2 DRILL TRIP P RIH from 7,756' to 12,409' when we lost all down wt. Pax3e 1 S off 2$ j r~ Time Lo s I Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/03/2007 15:45 ~ 18:30 2.75 12,409 14,795 ~PROD2 I DRILL REAM P Washed and reamed from 12,409' to I ~ ~ I I i btm at 14,795', washed down at 80 ~ i rpm's, 8K ft-Ibs torque, 185 gpm at 1,375 psi. No problems RIH or ~ ~ washin to btm. 18:30 20:45 2.25 14,795 14,795 PROD2 DRILL CIRC P Pumped 35 bbl, 9.1 ppg hi vis sweep and circ hole clean, had no increase in cuttings back from the sweep, circ hole at 320 gpm, 3,750 psi, 130 rpm's with 9K ft-Ibs torque 20:45 22:15 1.50 14,795 14,795 PROD2 DRILL CIRC P Dislpaced hole over from 8.45 ppg MOBM to 8.45 ppg SFMOBM, 320 pm at 3,750 psi. 22:15 22:30 0.25 14,795 14,795 PROD2 DRILL OWFF P Monitored well-static 22:30 00:00 1.50 14,795 14,265 PROD2 DRILL TRIP P POOH on elevators from 14,795' to 14,265', POOH w/3 stds hybrid push pipe then dropped 1 7/8" rabbit on wire, cont. to POOH on elevators to 14,265' 03/04/2007 00:00 08:15 8.25 14,265 371 PROD2 DRILL TRIP P Cont to POOH on elevators from 14,265' to BHA at 371'. While pulling thru window made 3 attempts at pulling 15K over w/no success, rotated thru window then went down thru pulling back thru wino rotation and had only 10K drag, cont. POOH to BHA, calc hole fill 85 bbls, actual fill 104 bbls. 08:15 11:00 2.75 371 0 PROD2 DRILL PULD P POOH LD BHA #6, stood back HWDP, jars and NMFDC's, downloaded MWD then fin. LD BHA and cleared ri floor. 11:00 11:45 0.75 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner 11:45 12:00 0.25 0 0 COMPZ CASIN SFTY P Held PJSM on running of 4 1/2" liner. 12:00 16:45 4.75 0 6,834 COMPZ CASIN( RNCS P PU and RIH with 4 1/2", 11.6 ppf, L-80 liner to 3,822', RIH with 4 1!2" guide shoe, 47 jts of slotted BTC, 87 jts of blank BTC, XO to 15 jts of blank Hydril 521 and 15 jts of slotted, spaced out per well plan, used 80 torque rings, 163 stop rings with 163 Hydraform centralizers floating below stop rings. MU Baker liner setting sleeve and running tool RIH to 6,834', st wt up 88K, do wt 60K, rotated at 20 rpm's with 2K ft-Ibs for ue and 70K rot wt. 16:45 17:15 0.50 6,834 6,834 COMPZ CASIN RURD P RD liner running tools and cleared rig floor. Page 17 of 2e3 Time Logs -- ~ Date 03/04/200 Fram 7 17:15__ To 19:45 Dur 2.50 S Depth ~ 6,834 E. Dept 11,700 h Phase ICOMPZ Code Subcode CASINC RUNL T ~P ---- COM _ _ __ RIH with 4 112" liner on 4" DP from i i ~ I ~ I 6,834' to 11,700' when we lost a(I I I ~ I j ~ down wt., no problems going thru the i j window. st wt up 130K, est rotation at i 20 rpm's, 8K ft-Ibs torque and 75K rot wt. (Note: set torque limiter at 9K ft-Ibs) 19:45 00:00 4.25 11,700 14,081 COMPZ CASIN C RUNL P Rotated liner in the hole from 11,700' to 14,081'., ave 15-20 rpm's with 9K ft-Ibs torque, at 14,081' PU wt 170K, rot wt 70K, rot do wt 55K, increased for ue limit to 11 K ft-Ibs. 03/05/2007 00:00 01:00 1.00 14,081 14,795 ICOMPZ CASIN C RUNL P Cont to rotate 4 1/2" liner in the hole, rotated from 14,081' and tagged btm at 14,795', ave 11 K ft-Ibs torque with 10-20 rpm's with torque limiter set at 13K st wt up 200K, rot do wt 50-55K , rot wt 95K. 01:00 01:45 0.75 14,795 14,788 COMPZ CASIN C RUNL P Dropped 29!32" ball and set liner on depth with top of setting sleeve at 7,961' and shoe at 14,788', pumped ball down and with ball on seat pressured up to 2,500 to release running tool then pressured up to 4,500 psi and sheared ball seat, st up wt 150K after releasin liner. 01:45 02:15 0.50 7,961 7,779 COMPZ DRILL TRIP P POOH from 7,961' to 7,779' to btm of window 02:15 02:45 0.50 7,779 7,779 COMPZ DRILL CIRC P Circ a btms up across WS slide to clean slot, circ at 326 gpm at 2,400 psi. 02:45 03:30 0.75 7,779 7,030 COMPZ DRILL TRIP P POOH with hybrid push pipe from 7,779' to 7,030' 03:30 06:30 3.00 7,030 7,030 COMPZ RIGMN RGRP T Changed out O-ring on the top drives goose neck then changed out swivel packin . 06:30 08:00 1.50 7,030 7,030 COMPZ RIGMN $VRG P Held PJSM then slip and cut 214' of drl line. 08:00 15:30 7.50 7,030 0 COMPZ DRILL TRIP P POOH from 7,030' with liner running too( and LD same, inspected WWT sliders on trip out and moved down 1' on DP, changed out 6 collars and 3 sleeves all others checked ok. (WWT re on loc.} cleared ri floor. 15:30 17:00 1.50 0 60 COMPZ FISH PULD P MU whipstock retrieving hook on f ishin BHA #7 RIH to 60'. 17:00 20:15 3.25 60 7,771 COMPZ FISH TRIP P RIH with BHA #7 from 60' to WS slot at 7,771', st wt up 140K, do 80K 20:15 00:00 3.75 7,771 7,771 COMPZ FISH FISH P Latched onto whipstock slot and jarred whipstock loose ,was able to hook s lot and jar on WS, would come out of s lot then would need to re-hook, jarred u p to 130K over st wt when whipstock c ame free, (cycled jars 14X) monitored well and took 3 bbls to fill h ole. PU and at wt up was 150K, M onitored well-static. Pape t8 of 28 • 'Time Logs Date From To Dur 5. De th E. De th Phase Code Subcode T COM __ _ _ i _ 03/06/200 7 00:00 03:45 3.75 17.771 60 ICOMPZ I~ FISH ~ TRIP j P POOH with BHA #7 from 7,771' to j I ( I I ~ i 1 i i BHA at 60' 03:45 06:00 2.25 60 I 0 COMPZ FISH ~ PULD I P POOH LD BHA #7, LD whipstock and i i seal assembly, cleared and cleaned ri floor. 06:00 07:00 1.00 0 i 0 ICOMPZ I CASIN G KURD P RU to run hook hanger assembly 07:00 07:30 0.50 0 0 COMPZ CASIN G SFTY P Held PJSM on MU hook hanger r assembl with slim hole MWD 07:30 09:30 2.00 0 262 COMPZ CASIN G PUTB P MU "B" lat Hook Hanger assembly with ECP packer and slim hole MWD RIH to 262', oriented MWD and shallow tested same. 09:30 13:00 3.50 262 7,766 COMPZ CASING RUNL P RIH with hook hanger assembly on 4" DP from 262' and tagged up on XO of "A" lat, PU to TOW at 7,766', st wt up 140K, do wt 85K 13:00 17:00 4.00 7,766 7,763 COMPZ CASING OTHR P Rotated hook hanger, est circ and oriented hook and RIH hooking hanger at the btm of the window at 7,779', PU, rotated hook, RIH and tagged up on "B" lat XO at 8,023', PU and rehooked at btm of the window, dropped 1 3/4" ball and pumped down to seat, pressured up to 1,000 psi then to 4,000 psi, took .25 bbls to inflate ECP paker, set top of hook hanger at 7,762.69' and btm of mule shoe at 8,01 T. PU and released from hook, st wt up 159K, took several attempts to release running tool, worked tool with and without 1,000 psi pressure then tool came free. 17:00 17:15 0.25 7,763 7,763 COMPZ CASING OTHR P Monitored well-static, blew down top drive. 17:15 20:30 3.25 7,763 20 COMPZ CASING RUNL P POOH with liner running tool from 7,763' to tool at 20' 20:30 21:30 1.00 20 0 COMPZ CASING OTHR P LD Baker running tool and slim hole MWD tool, cleared ri floor 21:30 22:15 0.75 0 0 COMPZ RPCOh KURD P RU to run LEM assembly 22:15 22:30 0.25 0 0 COMPZ RPCOti SFTY P Held PJSM on picking up and running of LEM 22:30 00:00 1.50 0 142 COMPZ RPCOh PULD P Began to MU "B" lat. LEM assembly RIH to 142' 03/07/2007 00:00 01:30 1.50 142 599 COMPZ RPCOI~ PULD P Fin MU "B" Lat. LEM assembly with ZXP pkr and slim hole MWD R{H to 599', st wt u 45K, do wt 45K 01:30 05:00 3.50 599 7,755 COMPZ RPCOh TRIP P RIH W/LEM from 599' to 7,755', shallow tested MWD at 690', st wt up 135K, do wt 83K -~' v Page'1B of 28 Time Logs ~ Date From To Dur S. De th E. Uet~th Phase Code Subcode T COM _ 03/07/200 _ 7 05:00 07:15 2.25 i 7,755 7:312 'COMPZ _ ~ RPCO h OTHR I P Cont to RIH with LEM from 7,755', ~ I I ( tagged top of hook at 7,763', rotated ~ i ~ I off and cont. RIH and tagged TOL to ~ ~ "A° lat at 7,851', oriented LEM to 16 ~ ~ ~ ' deg left of high side, cont. RIH and saw seals enter SBE, st up wt 140K, cin wt 80K, cont to go dn, taking 10K do wt to push seals thru SBE, tagged up with LEM and staged wt do on hook up to 35K and saw AZ swing from 16L to 75R indicating LEM was in place, PU 15K over PU wt to make sure LEM was latched. Dropped 1 3/4" ball and pumped do to seat, press. up to 2,800 psi to set hanger then to 4,200 psi to release from LEM, PU 3' and was free, st wt up 130K. Set top of "B" lat ZXP pkr at 7,312' with btm of the seals at 7,896' (6.5' above "A" lat XO 07:15 07:45 0.50 7,312 7,312 COMPZ RPCOh DHEO P RU and tested ZXP packer and csg to 2,500 si for 5 min, ood test. 07:45 10:30 2.75 7,312 20 COMPZ RPCOti TRIP P POOH from 7,312' to Baker running tool at 20' 10:30 12:00 1.50 20 0 COMPZ RPCON PULD P POOH LD running fool and slim hole MWD, cleared and cleaned rig floor. calc fill on trip out 49 bbls, actual fill 49 bbls. 12:00 12:15 0.25 0 0 PROD3 STK OTHR P Held PJSM on MU of whipstock assembl 12:15 16:00 3.75 0 206 PROD3 STK PULD P MU milling BHA #8, MU space out seal assembly, whipstock and mills then MU MWD and uploaded same RIH to 206' 16:00 17:00 1.00 206 396 PROD3 STK TRIP P RIH from 206' to 396' and shallow tested MWD, blew down top drive. 17:00 18:15 1.25 396 396 PROD3 RIGMN SVRG P Serviced top drive and changed out saver sub. 18:15 00:00 5.75 396 6,980 PROD3 STK TRIP P RIH with milling BHA #8 from 396' to 6,980', MADD passed K-13 to correlate MWD while RIH. ""`NOTE~"~Attachment to file - Orentation of LEM. & Hook Han er. 03/08/2007 00:00 00:30 0.50 6,980 7,206 PROD3 STK TRIP P Cont RIH with whipstock BHA #8 RIH from 6,980', RIH and oriented WS to 13L of high side, tagged "B" lat ZXP at 7,312', set WS and sheared off from same with top of WS at 7,206', st wt up 135K, do wt 80K 00:30 01:00 0.50 7,206 7,206 PROD3 STK CIRC P Began to displace hole over from 8.45 ppg SFMOBM to 8.45 ppg MOBM (to fin. u w/millin ) Pads 20 gf Z& \~~ ~~ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/08/2007 01:00 08:45 7.75 7,206 7,248 PRO03 STK WPST P Milled window in "D" lateral from 7,206' 1 i ~ i ~ to 7,218' then milled to 7,248' MD/ ~ ~ ~ 1 . ~ ~ 3,612' TVD with gauge hole to 7,238', milled at 2-10K WOM, 100 rpm's, I I ' I ~ ~ 4-8K ft-Ibs torque, 283 gpm at 2,280 1 psi. 08:45 09:45 1.00 7,248 7,248 PROD3 STK CIRC P Pumped wt'd hi vis sweep (2# over MW) and polished window while circ out sweep, went thru window several times with no pump and had no problems, st wt up no pump 126K, do wt 95K 09:45 10:00 0.25 7,248 7,248 PROD3 STK OTHR P Monitored well-static, pumped dry job and blew down to drive. 10:00 12:45 2.75 7,248 180 PROD3 STK TRIP P POOH with milling assembly from 7,248' to BHA at 180'. 12:45 15:00 2.25 180 0 PROD3 STK PULD P POOH LD BHA #8, LD mills and MWD, upper mill was in gauge, cleared ri floor 15:00 15:30 0.50 0 0 PROD3 STK OTHR P RU and flushed out BOP stack after millin window. 15:30 15:45 0.25 0 0 PROD3 DRILL PULD P Pulled wear bushing and installed test lu . 15:45 21:00 5.25 0 0 PROD3 WELCT BOPE P RU and tested BOPE, tested valves, manifold and rams including annular to 250 psi low and 3,000 psi high, tested with 4" and 4 1 /2" test jts. Tested rig alarms and koomey, initial press. 3,000 psi, after closing rams, 1,900 psi, took 42 sec. to gain 200 psi and 3:00 min for full recovery, have 5-nitrogen bottles ave 2,150 psi. NOTE: Chuck Scheve with AOGCC waived witnessin of the test. 21:00 21:30 0.50 0 0 PROD3 DRILL PULD P Installed wear bushing 21:30 22:30 1.00 0 0 PROD3 RIGMN SVRG P Held PJSM then slip and cut 78' of drl line. 22:30 22:45 0.25 0 0 PROD3 DRILL SFTY P Held PJSM with rig crew and Sperry Sun reps on PU and MU of Geopilot BHA. 22:45 00:00 1.25 0 60 PROD3 DRILL PULD P Began MU 6 3/4" BHA #9 with Geo ilot and MWD RIH to 60' 03/09/2007 00:00 02:15 2.25 60 370 PROD3 DRILL PULD P Fin MU Geopilot BHA #9 RIH to 370', MU MWD and uploaded same then RIH with NMFDC's, HWDP and ~ars. 02:15 03:15 1.00 370 370 PROD3 DRILL OTHR T Trouble shoot problem with Geospan, found to be froze u in a valve. 03:15 03:30 0.25 370 370 PROD3 DRILL DHEQ P Shallow tested MWD and broke in eo ilot. 03:30 06:30 3.00 370 7,248 PROD3 DRILL TRIP P RIH from 370' to 7,180' (TOW 7,206') RIH thru window with no problems then RIH washing down from 7,235' to 7,248'. Page. 2t o€ Z8 Time Logs Date From To bur S. De th E De th Phase Code Subcode T COM 03/09!2007 06:30 12:00 5.50 7,248 7,925 PRODS DRILL DDRL P I Directionally drilled 6 3!4" hole in "D" j ~ I sand lateral with geopilot from 7,248' to 7,925' MD/3,638' TVD (67T) ADT i i 3.16 hrs. ave 8.5 ppg MOBM MW and ave 9.95 ppg ECD, ave 60 units BGG, max as 117 units. 12:00 00:00 12.00 7,925 9,186 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 7,925' to 9,186' MD/3,662' TVD (1,261') ADT 6.34 hrs. ave 8.5 ppg MOBM MW, ECD ave 10.2 ppg, ave 60 units BGG, max as 224 units. 03/10/2007 00:00 09:15 9.25 9,186 9,720 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 9,186' to 9,720' MD/3,675' TVD (534') ADT 6.45 hrs. ave 8.45 ppg MOBM MW, ECD ave 10.0 ppg, ave 50 units BGG, max gas 160 units. Drilled thru 3 concretions for 40'. 09:15 10:00 0.75 9,720 9,720 PRODS RIGMN RGRP T Re-aligned torque tube for top drive. 10:00 00:00 14.00 9,720 10,631 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 9,720' to 10,631' MD/3,681' TVD (911') ADT 9.25 hrs. ave 8.40 ppg MOBM MW, ECD ave 10.2 ppg, ave 50 units BGG, max gas 100 units. drilled thru 10 concretions for 90'. 03/11/2007 00:00 12:00 12.00 10,631 11,566 PRODS DRILL DDRL P Directionally drilled 6 314" hole in "D" sand lateral with geopilot from 10,631' to 11,566' MD/3,701' TVD (935') ADT 7.7 hrs. ave 8.45 ppg MOBM MW, ECD ave 10.5 ppg; max ECD 10.75 ppg ave 60 units BGG, max gas 107 units. drilled thru 5 concretions for 59'. 12:00 00:00 12.00 11,566 12,126 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 11,566' to 12,126' MD/3,706' TVD (560') ADT 8.4 hrs. ave 8.45 ppg MOBM MW, ECD ave 10.45 ppg, max ECD 10.60 ppg ave 60 units BGG, max gas 93 units. drilled thru 8 concretions for 81'. 03/12/2007 00:00 01:15 1.25 12,126 12,174 PRODS DRILL DDRL P Drilled from 12,126'to 12,174' MD/3,709' TVD 48' ADT 1.3 hrs 01:15 01:45 0.50 12,174 12,174 PRODS DRILL DHEQ T Trouble shoot weak MWD signal, cleaned screens, swapped mud pumps and checked pulsation dam Hers. 1 #~age 22 of 2S 3 Time Lo s ~~ Date From To Dur S. De th E. De th Phase Code Subcode T COM i 03/12!2007 01:45 03:15 1.50 12,174 12,217 ~PROD3 f DRILL DDRL P Drilled from 12,174' to 12,217 i MD/3,711' TVD (43') ADT .80 hrs, ' i' ! cont. to trouble shoot MWD while ~ ~ I drilling on concretion, on last Conn. i ~ i ~ had picked up 1st std of HWDP and I saw a increase of 200 psi on the standpipe press., stood back std HWDP and PU 1 std of slick DP and had no change in pressure or signal. drilled thru 2 concretions for 21'. 03:15 05:45 2.50 12,217 12,217 PROD3 DRILL DHEQ T Cont. to trouble shoot MWD with no success in getting a good signal. Decision was made to POOH. 05:45 09:45 4.00 12,217 9,328 PROD3 DRILL REAM T Backreamed out of hole 5 stds from 12,217' to 11,750', then cont to POOH 2 stds and backreaming 1 to 9,328', pulled tight at 10,575' and backreamed thru w/no problems, hole took 1.5 bbls over talc hole fill BROOH, BROOH at 300 gpm, 2,40 psi and 120 pm's, st wt u 130K, do wt 55K. 09:45 11:00 1.25 9,328 7,180 PROD3 DRILL TRIP T POOH on elevators from 9,328' to above TOW to 7,180' (TOW @ 7,206') hole took 1 bbl over talc fill. 11:00 12:30 1.50 7,180 7,180 PROD3 DRILL CIRC T Pumped 30 bbl wt'd (2# over mw) hi vis sweep and circ out of hole, had 5% increase in cuttings (mostly wt material), circ at 300 gpm, 2,400 psi, rot at 100 rpm's with SK ft-Ibs torque, while circ sweep MWD began to work and decision was made to RIH. 12:30 14:00 1.50 7,180 9,888 PROD3 DRILL TRIP T RIH from 7,180' to 9,888' and lost all do wt, filled pipe while RIH and MWD ck'd ok. 14:00 14:30 0.50 9,888 10,075 PROD3 DRILL REAM T Began washing down from 9,888' and at 10,075' MWD tool lost it's si nal. 14:30 14:45 0.25 10,075 10,075 PROD3 DRILL OWFF T Monitored well-static, blew down top drive 14:45 19:00 4.25 10,075 370 PROD3 DRILL TRIP T POOH on elevators from 10,075' to BHA at 370'. 19:00 22:00 .3.00 370 0 PROD3 DRILL PULD T Stood back HWDP, jars and NMFDC's, downloaded MWD then LD MWD and bit, inspected BHA and found no obstructions or visible signs of MWD failure. 22:00 22:30 0.50 0 0 PROD3 DRILL OTHR T Serviced geopilot and inspected NM on flex DC and all ck'd ok. 22:30 00:00 1.50 0 85 PROD3 DRILL PULD T Began MU BHA #10 RIH to 85', MU bit #6 on geopilot and MU BHA to MWD tool. 03/13/2007 00:00 00:15 0.25 85 85 PROD3 DRILL PULD T Continue to MU BHA #10 00:15 01:15 1.00 85 85 PROD3 DRILL PULD T Upload MWD I O'1:15 1 02:00 0.75 85 1 370 i PROD3 I DRILL TRIP T RIH, Shallow test MWD, downlink geo-pilot Page 23 of 23 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 03!13/2007 02:00 06:30 4.50 370 10,169 ~PROD3 DRILL TRIP T RIH to window, slide thru window with ~ ( ~ no problems. Continue to RIH until run I i ~ out of S/O wei ht. ,06:30 09:00 2.50 10,169 12,217 iPROD3 DRILL REAM T (Ream in hole, pumping 180gpm, ~ ~ ' 1150 si, rotatin 100r m 09:00 12:00 3.00 12,217 12,390 PROD3 DRILL DDRL P Drill ahead until crew change. Drilled 4 concretions, total 10'. ART 1.8hrs, max as 93 units, ECDs 10.74 12:00 00:00 12.00 12,390 13,124 PROD3 DRILL DDRL P Drill ahead: 8 concretions totaling 49'. ART 7.5hrs, max gas 97 units, ECDs 10.82 03/14/2007 00:00 12:00 12.00 13,124 14,013 PROD3 DRILL DDRL P Drill ahead. ART 7.7 hrs, max gas 127 units, ECDs 10.8. 6 concretions for total of 42'. 12:00 00:00 12.00 14,013 14,684 PROD3 DRILL DDRL P Drill ahead. ART 7.5 hrs, max gas 131 units, ECDs 11.18. 6concretions - total of 35'. 03/15/2007 00:00 01:30 1.50 14,684 14,822 PROD3 DRILL DDRL P Drtlg to TD - 14,822' MD / 3742' TVD, ART 1.2 hrs, Max as 55 units 01:30 02:00 0.50 14,822 14,822 PROD3 DRILL SRVY P Circu 10 min -Survey TD -Record SPR's -Monitor Well 02:00 06:30 4.50 14,822 12,200 PROD3 DRILL REAM P BROOH at drilling rates to last trip point. PR 315 gpm, 130 RPMs. Pull last 2 stds slow to let hole clean up. Max as 85 units 06:30 09:45 3.25 12,200 14,822 PROD3 DRILL REAM P Monitor well "Static" -Wash and Ream bk to bttm. PR 180 gpm, RPM's 100 09:45 12:00 2.25 14,822 14,822 PROD3 DRILL CIRC P Pump wt/hi vis sweep, PR 300 gpm, 135 RPMs, Recip string full 94', Saw 30% cutting increase on BU- Con't Circu at iven rates. Crew Chan e 12:00 15:45 3.75 14,822 14,822 PROD3 DRILL CIRC P Circu total 4 BU -Shakers clean - PR 300 m, 135 RPMs, Reci strip 94' 15:45 17:15 1.50 14,822 14,822 PROD3 DRILL CIRC P Disp well over to SFMOBM - PR 300 gpm, 135 RPMs, Recip drill string 94' - Pum ed total 620 bbls. 17:15 17:30 0.25 14,822 14,822 PROD3 DRILL TRIP P PJSM tripping hazards -Observe well "Static" 17:30 00:00 6.50 14,822 4,755 PROD3 DRILL TRIP P POOH on elevators -Dropped 1-13/16" drift w/wire tail. Up wt 220k, Dn wt 42k 03/16/2007 00:00 02:00 2.00 4,755 370 PROD3 DRILL TRIP P Continue to POOH 02:00 03:00 1.00 370 75 PROD3 DRILL TRIP P UD BHA, HWDP, JARS and Drill collars 03:00 04:00 1.00 75 75 PROD3 DRILL TRIP P Download BHA 04:00 05:00 1.00 75 0 PROD3 DRILL TRIP P Continue to UD BHA 05:00 05:30 0.50 0 0 COMPZ RIGMN SVRG P Clear and clean rig floor 05:30 07:00 1.50 0 0 COMPZ RIGMN SVRG P Slip and cut 80' drilling line. Inspect saver sub. 07:00 07:30 0.50 0 0 COMPZ CASIN( RURD P RU casing equipment Page 2~ of 28 Time Logs Date From Te Dur S. De th E. De th Phase Code Subcode T COM 03/16/2007 07:30 OT45 ~ 0.25 0 0 COMPZ CASINC SFTY P i PJSM-Haxxard recognition 07:45 112:00 4.25 0 4.968 COMPZ CASINC RUNL P Run 4 1/2" liner. Calculated ~ displacement 20.16 BBLS, actual ! displacement 16.2 BBLS. 12:00 12:15 0.25 4,968 4,698 COMPZ CASINC SFTY P Crew change, PJSM 12:15 14:00 1.75 4,698 7,372 COMPZ CASINC RUNL P Continue running liner 14:00 14:45 0.75 7,372 7,446 COMPZ CASINC RUNL P PU and RIH with tieback assembly 14:45 21:30 6.75 7,446 14,815 COMPZ CASINC RUNL P RIH with liner on DP. Lost S/O weight at 10,900. Started rotating. Rotate IH, one small tight spot @ 14,636' MD, Work thru and tag bttm. Pick up to 7379' MD TOL (Bttm @ 14,815' MD. Up wt 245K, Rot wt down 80K, Torq 10-11 K. 21:30 22:15 0.75 14,815 7,379 COMPZ CASINC RUNL P Drop ball and pump down. Ball on seat, pressure up to 3000 PSI and release liner, Up wt 145K. Top of tie back @ 7379' MD. Shear ball seat @ 4250 si -Monitor well "Static" 22:15 00:00 1.75 7,379 4,150 COMPZ DRILL TRIP P POOH @ 4150' MD 03/17/2007 00:00 02:00 2.00 4,949 0 COMPZ DRILL TRIP P PJSM on Tripping -POOH 4949' to Surface -Make all service breaks on runnin tools. UD same. 02:00 02:30 0.50 0 0 COMPZ CASINC RUNL P Clean & Clear rig floor 02:30 03:00 0.50 0 271 COMPZ DRILL PULD P MU Whipstock retreiving tool,1 jt 3 1/2" HWDP, Bumper Sub, Oil Jars, Flt sub, XO, 2 stds Push i e 03:00 06:15 3.25 271 7,211 COMPZ DRILL TRIP P TIH w/ Whipstock Retv too! t/ 7193' MD - Up wt 140k, Dn wt 82k, PU 1 single & wash to 7211' MD -Hook set on first attem t. 06:15 06:45 0.50 7,211 7,211 COMPZ DRILL OTHR P Hook Whipstock and fired jars 5 times staging up to 65K overpull. Pulled free Pu wt 120K -Hole took 2 bbls fluid. 06:45 07:30 0.75 7,211 7,193 COMPZ DRILL CIRC P Pull to 7193' MD - CBU - PR 255 gpm- Max as 41 units 07:30 12:00 4.50 7,193 60 COMPZ DRILL TRIP P Monitor Well -Blow Down Top Drive - UD single -POOH t/ 60.0' MD ***** Crew Chan e 12:00 13:00 1.00 60 0 COMPZ DRILL PULD P PJSM - UD Oil Jars -Bumper sub- Whi stock and tale ass . 13:00 13:45 0.75 0 0 COMPZ CASINC RUNL P Clean & Clear Rig floor 13:45 14:00 0.25 0 0 COMPZ CASINC RUNL P PJSM -Hazard Recognition picking up Hook Han er 14:00 16:00 2.00 0 236 COMPZ CASINC PUTB P PU Hook Hanger assy. per detail - PU and orient MWD 16:00 16:30 0.50 236 329 I COMPZ CASINC RURD P TIH @ 329' Shallow test MWD - "OK" -Blow down To Drive. rage 25 of 28 ~ '7 Time Lo s I Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/17/2007 16:30 20:00 3.50 329 7,351 COMPZ CASINC PUTB P TIH w/ Hook Hanger assy. First attempt tag mother bore @ 7351' MD - J ~ I PU above window and apply 3 3/4 right ~ I I ~ hand raps. When out window on third attempt. Up wt 145K, Dn wt 90K 20:00 20:30 0.50 7,351 7,430 COMPZ CASINC RUNL P Orient & hook 16R at 7430'. PU 15' orient 180 deg. and tag at 7438' -liner nogo. PU 25' reorient and rehook at 7430'. 20:30 21:00 0.50 7,430 7,430 COMPZ CASINC RUNL P Drop ball. Seated at 702 strokes. Pressure up to 2000psi. Monitor then increase to 2600psi. ESP inflated. Bleed down and stabilized at 950psi. Pressure back up to 2600psi. Pressure held. Increased pressure to 3000psi then bleed off pressure. PU to 160k, 15k over ull, did not release. 21:00 21:30 0.50 7,430 7,430 COMPZ CASINC RUNL T SO to 30k and attempt to shear ball seat, pressured up to 4500psi. Did not shear. Bleed off pressure and PU to 160k. Made several attempts to release working pipe up to 155k and SO at 45k. Would not release. 21:30 22:45 1.25 7,430 7,430 COMPZ CASINC RUNL T Attempt safety release. 1 1/4 turns 5000# lefthand torque. Recip pipe attempting to work torque down to tools. Unable to work torque down to tools. 22:45 00:00 1.25 7,430 7,430 COMPZ CASINC RUNL T PJSM-LD single, blowdown top drive. RU test pump manifold and cement line on 10' pup joint. SO to 40k. Pressure up to 3500psi with rig pump, isolate from mud line and pressure up to 5000psi with test pump. Ball seat would not shear. Continue working i e. 03/18/2007 00:00 02:00 2.00 7,430 7,427 COMPZ CASINC RUNL T Continue attempts to release from hook hanger. Called town for recommendations. Advised to pull to 175k. Tools released. PU 3' and circulate to confirm release. 02:00 05:30 3.50 7,427 0 COMPZ CASINC RUNL P Monitor well. Slowdown topdrive. POOH. 05:30 06:00 0.50 0 0 COMPZ CASINC RUNL P Service brake, lay down running tools and MWD. An examination of the running toot found the ball seat had sheared and the lefthand safety release had released. There were metal shavin sin the tools. 06:00 06:30 0.50 0 0 COMPZ CASINC RUNL P Clear and clean rig floor. 06:30 07:00 0.50 0 0 COMPZ CASINC RUNL P RU 4 1/2" casing tools 07:00 07:15 0.25 0 0 COMPZ CASINC RUNL P PJSM-running LEM 07:15 09:00 1.75 0 50 COMPZ CASINC RUNL P PU and orient LEM assembly 3'age 2& of 28 i Time Lo s t Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/18{2007 09:00 09:15 0.25 50 225 COMPZ CASING RUNL P RIH and shallow test MWD at 225', 40s m, 650 si. 09:15 12:00 2.75 225 3,989 iCOMPZ ~ CASINC RUNL P RIH with LEM 12:00 12:15 0.25 ~ 3,989 3,989 COMPZ CASINC RUNL P Crew change. PJSM-running in hole, ~ ~ hazard reco nition. 12:15 14:00 1.75 3,989 7,346 COMPZ CASINC RUNL P Tag 10k at 7200'. PU 145k - SO 85k. Pickup, rotate 1.5 turns and entered I sealbore to 7332'. Stacked 15k. Twice PU @ 160k. Break circulation @ 3bpm, 80psi. Wash down clean to 7346. Latch and stack 30k, 31degrees right. PU and came free at 170k. SO to 7346' and stack 30k, 28degrees ri ht. 14:00 15:00 1.00 7,346 7,346 COMPZ CASINC RUNL P Drop and pump ball. 592 strokes to seat. Pressure up to 2300psi, pause and continue up to 4000psi. Bleed off and test back side of packer with 2500psi for 10 minutes. bleed off and pickup. Pulled free at 140k. (T.O.L. @ 7146' MD). Monitor well-static. Slowdown to drive 15:00 17:45 2.75 7,346 50 COMPZ CASINC RUNL P POOH 17:45 18:30 0.75 50 0 COMPZ CASINC RUNL P LD MWD. break out and lay down runnin tools. 18:30 19:00 0.50 0 0 COMPZ CASINC RUNL P Pull wear ring. 19:00 20:30 1.50 0 0 COMPZ CASINC RUNL P RU to run 4 1/2" tubing. 20:30 20:45 0.25 0 0 COMPZ RPCOR RCST P PJSM-running tubing 20:45 00:00 3.25 0 3,083 COMPZ RPCOti RCST P RIH with 4 1/2" completion 03/19/2007 00:00 03:30 3.50 3,083 7,193 COMPZ RPCOh RCST P PJSM running Tbg - Con't to run 4.5 12.6# L80 IBT Tb f/ 'ts 100 - 229 03:30 05:00 1.50 7,185 7,185 COMPZ RPCOR CIRC P PU above seals and circu 2 BU to clean up tbg and hole. PR 320 gpm, PP 860 PSI, (Loss 3.3 bbls) 05:00 05:30 0.50 7,193 7,193 COMPZ RPCOh RCST P Tag No Go w/ 10k @ 7193.33' - Up wt 85K, Dn wt 55k 05:30 06:00 0.50 7,185 7,185 COMPZ RPCOh HOSO P PU tubing hanger, space out w/9.82' u 06:00 08:00 2.00 7,185 7,190 COMPZ RPCOh RCST P Land tubing @ 7190.3 / RILDS. Test hanger seals to 5000 psi for 10 minutes. 08:00 08:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM - ND BOP 08:15 09:30 1.25 0 0 COMPZ RPCOti NUND P ND BOP 09:30 12:00 2.50 0 0 COMPZ RPCOh NUND P NU tree and RU to test 12:00 12:15 0.25 0 0 COMPZ RPCOh SFTY P Crew change. PJSM 12:15 13:00 0.75 0 0 COMPZ RPCOR SFEQ P Test tree w/5000 psi for 10 minutes. Pull 2-wa check valve. Paps 27 of 28 Time logs ~ ~ n.,a„ C....,,, T., n. ~. C flont4. G rlonth Phxo Cnr{c G ihrn('la T (~:(~fiA 03/19/2007 13:00 16:00 ~ 3.00 0 0 COMPZ RPCOh FRZP P Pressure test lines w/3000 psi. Pump I I 1315 bbls diesel @ 2 bpm. Full returns. i Shut in and blowdown lines. 16:00 18:45 2.75 0 0 COMPZ RPCOh RURD P RU scaffolding and PU lubricator. ~ I Install back pressure valve. RD scaffoldin and set mouse hole. 18:45 19:00 0.25 0 0 COMPZ RPCOh SFTY P PJSM -pinch point recognition. 19:00 22:00 3.00 0 0 COMPZ RPCOh PULD P LD 135 joints of drillpipe with sliders. Remove sliders in the pipe shed. LD 24 'oints of slick drill i e. 22:00 00:00 2.00 0 0 COMPZ RPCOti PULD P LD 25 WXDP and 8 DCs 03/20/2007 00:00 08:30 8.50 0 0 COMPZ RPCOh PULD P Continue LD hybrid DC and 276 joints of slick drill i e. Clear ri floor. 08:30 10:00 1.50 0 0 COMPZ RPCOh PULD P Change out geo-span, due to hours. Finish cleaning pits. RELEASE RIG 10:00 3/20. Halliburton Company Survey Report __ Compauv: ConocoPhillips Alaska Inc . Date: 4/11/2007 Timc: -09:20:02 Page: t Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-118, T rue North ' Site: Kuparuk iJ Pad Vertical (TVD)Re ference: 1J-118: 109.0 , Well: 1J-118 Section (VS)12eference: Well (O.OON,O:OOE,O.OOAzi) Wellpath: 1 J-118 Survey Cakulat;on Method: 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-118 -- Slot Name: -- - - Well Position: +N/-S -192.83 ft Northing: 5945727.24 ft Latitude: 70 15 44.361 N +E/-W 52.25 ft Easting : 558843.70 ft Longitude: 149 31 27.486 W Position Uncertainty: 0.00 ft Wellpath: 1J-118 Drilled From: 1J-118P62 ~ 500292333700 Tie-on Depth: 11621.70 ft Current Datum: 1 J-118: Height 109.00 ft Above System Datum: Mean Sea Level i Magnetic Data: 2/2/2007 Declination: 23.63 deg Field Strength: 57618 nT Mag Dip Angle: 80.81 deg i~ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg j ' 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 4/10/2007 Validated: No Version: 7 Actual From To Survey Toolcode Tool Name ft ft 50.00 917.00 1J-118P61 gyro (50. 00-917.00) CB-GYRO-SS Camera based gyro single shot 952.48 8631.79 1 J-118P61 (952.48- 8930.79) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8650.00 11621.70 1J-118P62 (8650.00-11808.00) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ ' 11680.00 14659.54 1J-118 (11 680.00-14659.54) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC I Survey __ - MD ' Incl Azim TVD Sys TVD N/S E/W >V1apN MHpE "Ibol ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945727.24 ` 558843.70 ~ TIE LINE 50.00 0.26 178.55 50.00 -59.00 -0.05 0.00 5945727.19 558843.70 CB-GYRO-SS 100.00 0.35 185.44 100.00 -9.00 -0.32 -0.01 5945726.92 558843.69 CB-GYRO-SS 172.00 0.41 204.37 172.00 63.00 -0.77 -0.14 5945726.47 558843.57 CB-GYRO-SS 264.00 0.53 206.73 263.99 154.99 -1.45 -0.46 5945725.79 558843.25 CB-GYRO-SS 356.00 1.13 107.26 355.99 246.99 -2.10 0.21 5945725.14 558843.93 CB-GYRO-SS 447.00 4.18 84.03 446.88 337.88 -2.02 4.37 5945725.26 558848.08 CB-GYRO-SS 535.00 7.32 80.59 534.43 425.43 -0.77 13.09 5945726.57 558856.79 CB-GYRO-SS 629.00 10.71 78.99 627.25 518.25 1.88 27.57 5945729.33 558871.26 CB-GYRO-SS ~~ 732.00 14.71 84.31 727.71 618.71 5.00 49.99 5945732.63 558893.65 CB-GYRO-SS 826.00 16.54 84.61 818.23 709.23 7.45 75.19 5945735.27 558918.82 CB-GYRO-SS 917.00 18.07 85.00 905.11 796.11 9.89 102.15 5945737.93 558945.76 CB-GYRO-SS 952.48 18.85 83.37 938.77 829.77 11.03 113.32 5945739.16 558956.92 +F - MWD I - AZ- R AK C SC 1043.68 21.78 85.65 1024.29 915.29 14.02 144.84 5945742.39 558988.41 MWD+IFR-AK-CAZ-SC 1143.62 25.49 86.25 1115.83 1006.83 16.83 184.80 5945745.51 559028.34 MWD+IFR-AK-CAZ-SC 1236.06 27.56 88.80 1198.54 1089.54 18.58 226.03 5945747.59 559069.56 MWD+IFR-AK-CAZ-SC 1285.00 28.16 89.95 1241.80 1132.80 18.83 248.90 5945748.01 559092.42 MWD+IFR-AK-CAZ-SC 1330.98 31.33 89.47 1281.72 1172.72 18.95 271.71 5945748.31 559115.23 MWD+IFR-AK-CAZ-SC 1374.40 35.57 89.81 1317.94 1208.94 19.10 295.64 5945748.64 559139.15 MWD+IFR-AK-CAZ-SC 1427.82 37.21 89.42 1360.94 1251.94 19.31 327.33 5945749.11 559170.83 MWD+IFR-AK-CAZ-SC 1 22.61 5 37.43 90.02 14 .32 36 13 2 27.3 1 4.79 9.59 38 59 74.3 559228.29 45 9 8 MWD+IFR-AK-CAZ-SC it 1616.90 41.63 90.66 1509.03 1400.03 19.22 444.79 5945749.93 559288.28 MWD+IFR-AK-CAZ-SC 1669.94 46.39 89.61 1547.17 1438.17 19.15 481.63 5945750.15 559325.12 MWD+IFR-AK-CAZ-SC 1710.91 50.31 89.47 1574.39 1465.39 19.39 512.24 5945750.63 559355.72 MWD+IFR-AK-CAZ-SC 1755.08 51.00 89.71 1602.40 1493.40 19.64 546.40 5945751.14 559389.87 MWD+IFR-AK-CAZ-SC 1805.44 51.68 90.37 1633.86 1524.86 19.61 585.72 5945751.42 559429.19 MWD+IFR-AK-CAZ-SC 1853.81 54.16 90.34 1663.02 1554.02 19.37 624.30 5945751.49 559467.77 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConecoPhillips Alaska Inc. 1?~ate: 4/11/2007 Time: 09:20:02 f'rgc: 2 Field: Ku paru k River Unit Co-or dinate (NE) Reference: WeII: 1J-11 8, Tr ue North Site: Ku paru k i J Pad Vertical (TVD) Reference: 1J-118: 109.0 Well: 1J -118 Section (VS) Reference: Well (O.OON>O.OOE,OAOAzi) ~Ye1lpRth: 1J -118 Survey Calc ulation Rlethod: Minimum C urva ture- Db: Oracle Sur~~ey IVtD Fnc l :~cim TVD S}, "1 ~ll V iS E/W MupN MapF 'Tool ft deg deg ft ft ft ft ft ft 1902.80 54. 95 90.90 1691. 43 1582.43 18. 94 664. 21 5945751. 37 559507. 68 MWD+IFR-AK-CAZ-SC 1937.72 57. 64 90.44 1710. 80 1601.80 18. 60 693. 26 5945751. 25 559536. 72 MWD+IFR-AK-CAZ-SC 1998.89 59. 84 91.39 1742. 54 1633.54 17. 76 745. 54 5945750. 82 559589. 00 MWD+IFR-AK-CAZ-SC ~ 2030.52 62. 36 91.96 1757. 83 1648.83 16. 95 773. 21 5945750. 23 559616. 68 MWD+IFR-AK-CAZ-SC 2092.99 64. 67 94.04 1785. 69 1676.69 14. 01 829. 04 5945747. 73 559672. 53 MWD+IFR-AK-CAZ-SC 2189.09 70. 82 95.06 1822. 07 1713.07 6. 94 917. 66 5945741. 35 559761. 19 MWD+IFR-AK-CAZ-SC i 2286.70 73. 19 95.06 1852. 22 1743.22 -1. 24 1010. 12 5945733. 89 559853. 71 MWD+IFR-AK-CAZ-SC 2382.12 71. 05 95.20 1881. 52 1772.52 -9. 36 1100. 57 5945726. 48 559944. 20 MWD+IFR-AK-CAZ-SC 2476.11 71. 26 93.38 1911. 88 1802.88 -16. 02 1189. 26 5945720. 52 560032. 94 MWD+IFR-AK-CAZ-SC 2568.26 70. 85 91.35 1941. 80 1832.80 -19. 61 1276. 34 5945717. 60 560120. 03 MWD+IFR-AK-CAZ-SC 2664.04 71. 27 92.79 1972. 89 1863.89 -22. 89 1366. 87 5945715. 04 560210. 58 MWD+IFR-AK-CAZ-SC '; 2756.26 69. 10 91.04 2004. 15 1895.15 -25. 80 1453. 58 5945712. 81 560297. 29 MWD+IFR-AK-CAZ-SC 2847.00 69. 97 92.62 2035. 88 1926.88 -28. 51 1538. 54 5945710 .75 560382. 27 MWD+IFR-AK-CAZ-SC 2943.26 71. 58 91.70 2067. 57 1958.57 -31. 94 1629. 37 5945708. 04 560473. 11 MWD+IFR-AK-CAZ-SC i 3039.70 70. 63 92.26 2098. 80 1989.80 -35. 09 1720. 55 5945705. 60 560564. 31 MWD+IFR-AK-CAZ-SC 3134.18 70. 26 92.17 2130. 43 2021.43 -38. 53 1809. 52 5945702. 86 560653. 29 MWD+IFR-AK-CAZ-SC 3200.94 68. 25 91.59 2154. 07 2045.07 -40. 58 1871. 91 5945701. 29 560715. 69 MWD+IFR-AK-CAZ-SC 3229.87 66. 58 92.72 2165. 18 2056.18 -41. 58 1898. 60 5945700. 50 560742. 39 MWD+IFR-AK-CAZ-SC I 3295.41 64. 01 92.70 2192. 57 2083.57 -44. 40 1958. 07 5945698. 15 560801. 87 MWD+IFR-AK-CAZ-SC 3313.70 63. 85 92.94 2200. 61 2091.61 -45. 20 1974. 48 5945697 .47 560818. 28 MWD+IFR-AK-CAZ-SC ~ 3453.41 65. 79 93.79 2260. 05 2151.05 -52. 63 2100. 69 5945691 .03 560944. 53 MWD+IFR-AK-CAZ-SC 3547.91 67. 44 94.37 2297. 56 2188.56 -58. 81 2187. 20 5945685 .53 561031. 09 MWD+IFR-AK-CAZ-SC 3641.45 67 .18 94.71 2333. 64 2224.64 -65. 64 2273. 23 5945679 .37 561117. 16 MWD+IFR-AK-CAZ-SC ii 3737.18 66 .21 95.04 2371. 51 2262.51 -73. 11 2360. 83 5945672 .59 561204 .81 MWD+IFR-AK-CAZ-SC 3834.00 67 .24 92.42 2409. 78 2300.78 -78. 88 2449. 57 5945667 .51 561293 .58 MWD+IFR-AK-CAZ-SC 3930.20 66 .62 92.98 2447. 47 2338.47 -83. 05 2537. 98 5945664 .03 561382 .01 MWD+IFR-AK-CAZ-SC 4025.99 67 .73 92.76 2484. 63 2375.63 -87. 47 2626. 16 5945660 .30 561470 .21 MWD+IFR-AK-CAZ-SC 4120.47 67 .61 93.16 2520. 53 2411.53 -91. 99 2713. 44 5945656 .47 561557 .51 MWD+IFR-AK-CAZ-SC 4213.33 66. 69 93.72 2556. 59 2447.59 -97. 12 2798. 85 5945652 .00 561642. 96 MWD+IFR-AK-CAZ-SC 4310.21 67. 42 92.38 2594. 36 2485.36 -101. 86 2887. 94 5945647 .96 561732. 07 MWD+IFR-AK-CAZ-SC 4404.86 67. 62 92.21 2630. 55 2521.55 -105. 37 2975. 33 5945645 .14 561819. 47 MWD+tFR-AK-CAZ-SC 4499.68 67 .33 92.60 2666. 87 2557.87 -109. 04 3062. 84 5945642 .15 561907. 00 MWD+IFR-AK-CAZ-SC it 4591.05 67 .62 92.95 2701. 87 2592.87 -113. 13 3147. 14 5945638 .72 561991. 32 MWD+IFR-AK-CAZ-SC 4686.19 68 .23 92.11 2737. 63 2628.63 -117. 02 3235. 21 5945635 .52 562079 .42 MWD+IFR-AK-CAZ-SC i ' , 4780.87 68 .23 88.09 2772. 76 2663.76 -117. 17 3323. 12 5945636 .05 562167 .31 MWD+IFR-AK-CAZ-SC 4874.94 67 .42 86.84 2808. 26 2699.26 -113. 32 3410. 14 5945640 .58 562254 .30 MWD+IFR-AK-CAZ-SC 4968.89 67 .91 83.86 2843. 97 2734.97 -106. 27 3496. 75 5945648 .30 562340 .83 MWD+IFR-AK-CAZ-SC 5064.95 67 .63 81.22 2880. 32 2771.32 -94. 73 3584. 90 5945660 .53 562428 .89 MWD+IFR-AK-CAZ-SC 5160.91 69 .51 76.53 2915. 40 2806.40 -77. 48 3672. 51 5945678 .47 562516 .35 MWD+IFR-AK-CAZ-SC 5253.70 69 .49 70.42 2947. 92 2838.92 -52. 77 3755. 79 5945703 .82 562599 .42 MWD+IFR-AK-CAZ-SC 5351.34 69 .70 66.02 2981. 98 2872.98 -18. 83 3840. 74 5945738 .43 562684 .10 MWD+IFR-AK-CAZ-SC i 5448.46 68 .60 62.73 3016. 55 2907.55 20. 41 3922. 56 5945778 .30 562765 .61 MWD+IFR-AK-CAZ-SC 5544.21 67 .75 57.64 3052. 17 2943.17 64. 58 3999. 66 5945823 .06 562842 .34 MWD+IFR-AK-CAZ-SC 5638.68 67 .85 53.26 3087. 88 2978.88 114. 17 4071. 67 5945873 .21 562913 .97 MWD+IFR-AK-CAZ-SC 5735.67 68 .05 48.42 3124. 31 3015.31 170. 91 4141. 35 5945930 .49 562983 .19 MWD+IFR-AK-CAZ-SC i 5830.70 66 .10 44.27 3161. 34 3052.34 231. 30 4204. 67 5945991 .36 563046 .03 MWD+IFR-AK-CAZ-SC 5924.22 69 .30 39.64 3196. 84 3087.84 295. 64 4262. 46 5946056 .15 563103 .31 MWD+IFR-AK-CAZ-SC 6015.21 68 .68 35.42 3229. 47 3120.47 362. 98 4314. 19 5946123 .88 563154 .51 MWD+IFR-AK-CAZ-SC 6110.16 67 .87 32.60 3264. 62 3155.62 436. 08 4363. 53 5946197 .36 563203 .27 MWD+IFR-AK-CAZ-SC I 6205.26 68 .40 29.72 3300. 05 3191.05 511. 60 4409. 18 5946273 .23 563248 .33 MWD+IFR-AK-CAZ-SC 6301.73 68 .32 27.60 3335. 63 3226.63 590. 28 4452. 19 5946352 .23 563290 .71 MWD+IFR-AK-CAZ-SC i 6397.50 66 .91 23.40 3372. 11 3263.11 670. 17 4490. 31 5946432 .41 563328 .21 MWD+IFR-AK-CAZ-SC 6492.22 66 .44 20.99 3409. 62 3300.62 750. 70 4523. 17 5946513 .19 563360 .43 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska tnc. llate: 4/11!2007 rFimc: 09:20:02 Yage: 3 Field: Kuparuk River Unit Co-oi•dinate(NE) Reference: Well: 1J-118, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-118: 109.0 Well: 1 J-118"' Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-118 sun~ey F~akulation Method: Minimum Curvature Db: oracle __ ~ur~c~ >1t) Inc! Aim TVD ~CvsTVD N/S EIIV R1apN MapE Tuul ft deg deg ft ft ft ft ft ft 6588.77 70.38 16.05 3445.16 3336.16 835.79 4551.62 5946598.49 563388.21 MWD+IFR-AK-CAZ-SC 6681.74 72.83 12.14 3474.50 3365.50 921.33 4573.08 5946684.19 563409.00 MWD+IFR-AK-CAZ-SC 6777.79 74.24 7.05 3501.74 3392.74 1012.12 4588.41 5946775.09 563423.62 MWD+IFR-AK-CAZ-SC 6869.50 73.93 2.38 3526.90 3417.90 1099.99 4595.66 5946863.00 563430.18 MWD+IFR-AK-CAZ-SC 6964.12 75.87 358.76 3551.56 3442.56 1191.31 4596.55 5946954.32 563430.36 MWD+IFR-AK-CAZ-SC 7058.97 75.11 358.72 3575.32 3466.32 1283.12 4594.54 5947046.10 563427.63 MWD+IFR-AK-CAZ-SC i 7154.43 79.30 358.11 3596.46 3487.46 1376.15 4591.96 5947139.10 563424.32 MWD+IFR-AK-CAZ-SC 7251.26 79.79 357.34 3614.03 3505.03 1471.30 4588.18 5947234.20 563419.80 MWD+IFR-AK-CAZ-SC 7295.62 79.62 357.13 3621.96 3512.96 1514.89 4586.07 5947277.77 563417.35 MWD+IFR-AK-CAZ-SC 7344.66 80.29 355.45 3630.51 3521.51 1563.08 4582.95 5947325.93 563413.85 MWD+IFR-AK-CAZ-SC 7385.41 79.89 355.14 3637.53 3528.53 1603.08 4579.65 5947365.90 563410.25 MWD+IFR-AK-CAZ-SC 7439.36 80.09 357.91 3646.91 3537.91 1656.11 4576.43 5947418.90 563406.61 MWD+IFR-AK-CAZ-SC 7535.83 82.47 0.07 3661.53 3552.53 1751.44 4574.76 5947514.20 563404.19 MWD+IFR-AK-CAZ-SC ~ 7580.51 82.58 1.02 3667.34 3558.34 1795.73 4575.18 5947558.50 563404.27 MWD+IFR-AK-CAZ-SC I 7632.34 82.24 1.50 3674.19 3565.19 1847.10 4576.31 5947609.86 563405.00 MWD+IFR-AK-CAZ-SC 7726.90 81.59 1.19 3687.49 3578.49 1940.69 4578.51 5947703.46 563406.46 MWD+IFR-AK-CAZ-SC 7822.62 81.54 1.10 3701.53 3592.53 2035.36 4580.40 5947798.13 563407.62 MWD+IFR-AK-CAZ-SC 7856.07 80.18 0.91 3706.84 3597.84 2068.37 4580.98 5947831.15 563407.94 MWD+IFR-AK-CAZ-SC 7887.78 78.61 0.97 3712.68 3603.68 2099.54 4581.49 5947862.31 563408.20 MWD+IFR-AK-CAZ-SC 7916.96 78.91 1.50 3718.37 3609.37 2128.15 4582.11 5947890.93 563408.60 MWD+IFR-AK-CAZ-SC 8011.30 81.05 1.67 3734.78 3625.78 2221.01 4584.68 5947983.80 563410.44 MWD+IFR-AK-CAZ-SC 8106.89 80.80 2.05 3749.86 3640.86 2315.36 4587.74 5948078.15 563412.77 MWD+IFR-AK-CAZ-SC 8202.94 80.72 1.74 3765.28 3656.28 2410.11 4590.88 5948172.92 563415.16 MWD+IFR-AK-CAZ-SC 8297.55 79.10 2.16 3781.86 3672.86 2503.20 4594.04 5948266.02 563417.60 MWD+IFR-AK-CAZ-SC 8393.56 79.09 0.99 3800.02 3691.02 2597.44 4596.64 5948360.26 563419.46 MWD+IFR-AK-CAZ-SC 8489.36 78.27 0.53 3818.82 3709.82 2691.36 4597.88 5948454.19 563419.97 MWD+IFR-AK-CAZ-SC 8522.98 79.22 0.38 3825.39 3716.39 2724.33 4598.14 5948487.16 563419.97 MWD+IFR-AK-CAZ-SC ~~ 8584.85 82.13 0.27 3835.41 3726.41 2785.38 4598.49 5948548.20 563419.84 MWD+IFR-AK-CAZ-SC 8631.79 82.72 0.17 3841.60 3732.60 2831.91 4598.67 5948594.72 563419.66 MWD+IFR-AK-CAZ-SC 8650.00 82.99 359.96 3843.86 3734.86 2849.98 4598.69 5948612.79 563419.54 MWD+IFR-AK-CAZ-SC 8711.87 81.57 356.32 3852.18 3743.18 2911.24 4596.70 5948674.03 563417.07 MWD+IFR-AK-CAZ-SC 8744.52 82.93 355.08 3856.58 3747.58 2943.50 4594.28 5948706.27 563414.39 MWD+IFR-AK-CAZ-SC 8808.00 86.14 352.92 3862.62 3753.62 3006.33 4587.67 5948769.04 563407.30 MWD+IFR-AK-CAZ-SC 8867.25 87.83 350.68 3865.74 3756.74 3064.89 4579.23 5948827.53 563398.40 MWD+IFR-AK-CAZ-SC 8907.20 87.93 349.80 3867.22 3758.22 3104.24 4572.46 5948866.81 563391.33 MWD+IFR-AK-CAZ-SC 9005.00 88.08 350.40 3870.62 3761.62 3200.52 4555.66 5948962.95 563373.77 MWD+IFR-AK-CAZ-SC 9099.49 89.70 351.06 3872.45 3763.45 3293.76 4540.44 5949056.06 563357.83 MWD+IFR-AK-CAZ-SC 9191.86 90.56 349.31 3872.24 3763.24 3384.77 4524.70 5949146.94 563341.37 MWD+IFR-AK-CAZ-SC ~I 9286.64 89.08 350.16 3872.54 3763.54 3478.03 4507.81 5949240.05 563323.76 MWD+IFR-AK-CAZ-SC ~ 9379.45 87.35 350.23 3875.43 3766.43 3569.43 4492.01 5949331.32 563307.25 MWD+IFR-AK-CAZ-SC I 9473.30 88.03 350.62 3879.22 3770.22 3661.90 4476.41 5949423.66 563290.93 MWD+IFR-AK-CAZ-SC ~I 9566.09 88.96 352.25 3881.65 3772.65 3753.62 4462.60 5949515.26 563276.40 MWD+IFR-AK-CAZ-SC ~ 9659.69 88.65 352.61 3883.60 3774.60 3846.38 4450.27 5949607.91 563263.35 MWD+IFR-AK-CAZ-SC 9753.04 88.53 352.37 3885.90 3776.90 3938.91 4438.07 5949700.33 563250.43 MWD+IFR-AK-CAZ-SC 9847.19 88.83 354.24 3888.07 3779.07 4032.38 4427.10 5949793.71 563238.73 MWD+IFR-AK-CAZ-SC 9939.68 88.89 357.01 3889.91 3780.91 4124.58 4420.05 5949885.83 563230.96 MWD+IFR-AK-CAZ-SC 10033.24 90.07 358.56 3890.76 3781.76 4218.06 4416.43 5949979.28 563226.61 MWD+IFR-AK-CAZ-SC 10126.56 90.38 358.03 3890.39 3781.39 4311.34 4413.65 5950072.52 563223.11 MWD+IFR-AK-CAZ-SC 10219.85 89.45 357.14 3890.53 3781.53 4404.54 4409.72 5950165.68 563218.45 MWD+IFR-AK-CAZ-SC 10312.18 88.77 355.79 3891.97 3782.97 4496.68 4404.03 5950257.77 563212.04 MWD+IFR-AK-CAZ-SC I 10406.60 88.52 355.74 3894.20 3785.20 4590.82 4397.06 5950351.84 563204.33 MWD+IFR-AK-CAZ-SC 10499.20 89.39 355.63 3895.89 3786.89 4683.14 4390.10 5950444.09 563196.65 MWD+IFR-AK-CAZ-SC ~ --- - Halliburton Company Survey Report Company: ConocoPhillips Alaska Inca Field: Kuparuk River Unit Site: Kuparuk 1J Pad 'Well: 1 J-118 Wellpath: 1 J-11 ° Survey llate: 4!11/2007 Time: 09:20.02 Y:~};c: -t Co-ordinate(NE)Retereoce: Well: 1J-118, True North Vertical (T VD) Reference: 1J-118: 109.0 Section (VS)Reference: Well (O.OOtJ,0.00E,0.00Azi) Survey Calculation Method: -Minimum Curvature llb: Oracfe __ MD Fncl :~zim TVD.' Sys TV U NIS ft deg deg ft ft ft 10593.33 88.40 355.91 3897.70 3788.70 4776.99 10686.35 89.08 357.19 3899.75 3790.75 4869.82 10781.03 88.40 357.82 3901.83 3792.83 4964.39 10873.11 89.33 358.31 3903.65 3794.65 5056.40 10966.85 88.28 357.25 3905.61 3796.61 5150.04 11056.75 88.65 358.02 3908.02 3799.02 5239.83 11150.08 88.09 359.52 3910.67 3801.67 5333.10 11246.11 89.45 0.88 3912.73 3803.73 5429.10 11342.16 87.29 359.59 3915.47 3806.47 5525.11 11433.65 88.83 358.86 3918.56 3809.56 5616.53 11527.10 91.37 0.81 3918.40 3809.40 5709.97 11621.70 93.28 2.67 3914.56 3805.56 5804.44 11680.00 93.47 3.13 3911.13 3802.13 5862.56 11714.21 91.67 3.03 3909.60 3800.60 5896.69 11808.24 89.88 1.38 3908.32 3799.32 5990.63 11899.27 90.44 356.93 3908.07 3799.07 6081.63 11991.22 89.51 355.17 3908.11 3799.11 6173.36 12086.22 89.20 355.69 3909.18 3800.18 6268.05 12182.01 89.76 358.06 3910.05 3801.05 6363.68 12275.02 89.94 359.20 3910.29 3801.29 6456.67 12368.52 88.77 356.58 3911.35 3802.35 6550.09 12461.51 89.45 358.65 3912.79 3803.79 6642.98 12555.92 89.70 2.46 3913.49 3804.49 6737.36 12648.48 90.38 2.71 3913.43 3804.43 6829.83 12741.38 90.07 2.75 3913.06 3804.06 6922.62 12836.19 88.28 1.79 3914.43 3805.43 7017.34 12930.26 89.33 1.59 3916.39 3807.39 7111.35 13022.99 89.08 0.75 3917.67 3808.67 7204.05 13116.56 87.72 358.08 3920.29 3811.29 7297.57 13209.38 88.46 359.90 3923.38 3814.38 7390.32 13302.73 89.33 1.19 3925.18 3816.18 7483.65 13396.42 89.08 1.98 3926.48 3817.48 7577.29 13490.12 89.88 2.73 3927.33 3818.33 7670.91 13583.85 88.09 2.92 3928.99 3819.99 7764.50 13676.45 87.91 2.52 3932.22 3823.22 7856.94 13769.72 86.12 1.53 3937.08 3828.08 7950.02 13862.01 87.41 1.33 3942.29 3833.29 8042.13 13952.57 89.76 2.00 3944.53 3835.53 8132.62 14041.41 90.25 0.62 3944.52 3835.52 8221.44 14132.90 89.94 359.92 3944.37 3835.37 8312.92 14224.59 89.39 0.37 3944.90 3835.90 8404.61 14314.72 90.38 1.00 3945.08 3836.08 8494.73 14404.62 87.10 0.06 3947.06 3838.06 8584.59 14496.51 86.24 0.35 3952.40 3843.40 8676.33 14587.12 88.84 0.39 3956.29 3847.29 8766.84 14659.54 89.33 0.46 3957.44 3848.44 8839.25 ,14698.00 89.33 0.46 3957.89 ~ 3848.89 8877.71 -_ _ -_ E/~V Map,A Maps tuol ft ft ft 4383.15 5950537.88 563188.97 MWD+IFR-AK-CAZ-SC 4377.56 5950630.65 563182.65 MWD+IFR-AK-CAZ-SC 4373.44 5950725.17 563177.79 MWD+IFR-AK-CAZ-SC 4370.33 5950817.15 563173.96 MWD+IFR-AK-CAZ-SC 4366.70 5950910.75 563169.60 MWD+IFR-AK-CAZ-SC 4362,99 5951000.50 563165.19 MWD+IFR-AK-CAZ-SC 4360,99 5951093.74 563162.46 MWD+IFR-AK-CAZ-SC 4361.32 5951189.74 563162.05 MWD+IFR-AK-CAZ-SC 4361.72 5951285.73 563161.69 MWD+IFR-AK-CAZ-SC 4360.48 5951377.13 563159.74 MWD+IFR-AK-CAZ-SC 4360.21 5951470.56 563158.74 MWD+IFR-AK-CAZ-SC 4363.08 5951565.04 563160.87 MWD+IFR-AK-CAZ-SC 4366.02 5951623.18 563163.36 MWD+IFR-AK-CAZ-SC 4367.86 5951657.31 563164.93 MWD+IFR-AK-CAZ-SC 4371.48 5951751.27 563167.81 MWD+IFR-AK-CAZ-SC 4370.13 5951842.25 563165.76 MWD+IFR-AK-CAZ-SC 4363.80 5951933.91 563158.71 MWD+IFR-AK-CAZ-SC 4356.23 5952028.53 563150.40 MWD+IFR-AK-CAZ-SC 4351.01 5952124.12 563144.43 MWD+IFR-AK-CAZ-SC 4348.79 5952217.07 563141.48 MWD+IFR-AK-CAZ-SC 4345.35 5952310.45 563137.31 MWD+IFR-AK-CAZ-SC 4341.48 5952403.30 563132.72 MWD+IFR-AK-CAZ-SC 4342.39 5952497.68 563132.90 MWD+IFR-AK-CAZ-SC 4346.57 5952590.17 563136.35 MWD+IFR-AK-CAZ-SC 4350.99 5952682.99 563140.05 MWD+IFR-AK-CAZ-SC 4354.75 5952777.72 563143.06 MWD+IFR-AK-CAZ-SC 4357.52 5952871.74 563145.10 MWD+IFR-AK-CAZ-SC 4359.41 5952964.45 563146.27 MWD+IFR-AK-CAZ-SC 4358.46 5953057,94 563144.58 MWD+IFR-AK-CAZ-SC 4356.82 5953150,67 563142.22 MWD+IFR-AK-CAZ-SC 4357.71 5953243,99 563142.38 MWD+IFR-AK-CAZ-SC 4360.30 5953337.64 563144.24 MWD+IFR-AK-CAZ-SC 4364.15 5953431.28 563147.36 MWD+IFR-AK-CAZ-SC 4368.77 5953524.90 563151.25 MWD+IFR-AK-CAZ-SC 4373.16 5953617.36 563154.91 MWD+IFR-AK-CAZ-SC 4376.45 5953710.45 563157.48 MWD+IFR-AK-CAZ-SC 4378.75 5953802.57 563159.06 MWD+IFR-AK-CAZ-SC 4381.38 5953893.07 563160.98 MWD+IFR-AK-CAZ-SC 4383.42 5953981.89 563162.32 MWD+IFR-AK-CAZ-SC 4383.85 5954073.37 563162,03 MWD+IFR-AK-CAZ-SC 4384.08 5954165.05 563161.55 MWD+IFR-AK-CAZ-SC 4385.16 5954255.16 563161,92 MWD+IFR-AK-CAZ-SC 4385.99 5954345.02 563162,05 MWD+IFR-AK-CAZ-SC 4386.32 5954436.74 563161.66 MWD+IFR-AK-CAZ-SC 4386.90 5954527.25 563161.54 MWD+IFR-AK-CAZ-SC 4387.44 5954599.66 563161.51 MWD+IFR-AK-CAZ-SC 4387.75 5954638.11 ' 563161.52 - PROJECTED to TD Halliburton Company Survey Report Zbmpany: ConoooPhillips Alaska InC . Date: 4/10/2007 Time: 14:21:36 Pale: 1 Field: Kuparuk River Unit Co -ordinate(NE) Refereuce: WeIL 1J-t 18, Tr ue North Sitr. Kuparuk 1J Pad Ve rtical (TVD)Re ferencc: 1J-1f8PB1:109.0 Well: 1 J-118 Section (VS) Refer ence: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-118PB1 Su rveyCalculation Method: 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 ~ II Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Well Centre Geomagnetic Model: bggm2006 ~ Well: 1 J-118 Slot Name: Well Position: +N/-S -192.83 ft Northing: 5945727.24 ft Latitude: 70 15 44.361 N +E/-W 52.25 ft Easti ng : 558843.70 ft Longitude: 149 31 27.486 W Position Uncertainty: 0.00 ft Wellpath: 1J-118P61 Drilled From: Well Ref. Point 500292333770 Tie-on Depth: 28.00 ft Current Datum: 1 J-118PB1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/2/2007 Declination: 23.63 deg Field Strength: 57618 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath ', Date: 2/20/2007 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ~ ft ft 50.00 917.00 1 J-118PB1 gyro (50. 00-917.00) C B-GYRO-SS Camera based gyro single shot 952.48 8930.79 1 J-118P61 (952.48-8930.79) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey MD Incl ~cim TVD S~ll'D N/S E/~V ~IapN 1tapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 __ 5945727.24 558843.70 TIE LINE 50.00 0.26 178.55 50.00 -59.00 -0.05 0.00 5945727.19 558843.70 CB-GYRO-SS 100.00 0.35 185.44 100.00 -9.00 -0.32 -0.01 5945726.92 558843.69 CB-GYRO-SS 172.00 0.41 204.37 172.00 63.00 -0.77 -0.14 5945726.47 558843.57 CB-GYRO-SS 264.00 0.53 206.73 263.99 154.99 -1.45 -0.46 5945725.79 558843.25 CB-GYRO-SS 356.00 1.13 107.26 355.99 246.99 -2.10 0.21 5945725.14 558843.93 CB-GYRO-SS 447.00 4.18 84.03 446.88 337.88 -2.02 4.37 5945725.26 558848.08 CB-GYRO-SS !, 535.00 7.32 80.59 534.43 425.43 -0.77 13.09 5945726.57 558856.79 CB-GYRO-SS ii 629.00 10.71 78.99 627.25 518.25 1.88 27.57 5945729.33 558871.26 CB-GYRO-SS 732.00 14.71 84.31 727.71 618.71 5.00 49.99 5945732.63 558893.65 CB-GYRO-SS 826.00 16.54 84.61 818.23 709.23 7.45 75.19 5945735.27 558918.82 CB-GYRO-SS 917.00 18.07 85.00 905.11 796.11 9.89 102.15 5945737.93 558945.76 CB-GYRO-SS 952.48 18.85 83.37 938.77 829.77 11.03 113.32 5945739.16 558956.92 MWD+IFR-AK-CAZ-SC 1043.68 21.78 85.65 1024.29 915.29 14.02 144.84 5945742.39 558988.41 MWD+IFR-AK-CAZ-SC 1143.62 25.49 86.25 1115.83 1006.83 16.83 184.80 5945745.51 559028.34 I MWD+IFR-AK-CAZ-SC 1236.06 27.56 88.80 1198.54 1089.54 18.58 226.03 5945747.59 559069.56 MWD+IFR-AK-CAZ-SC j 1285.00 28.16 89.95 1241.80 1132.80 18.83 248.90 5945748.01 559092.42 MWD+IFR-AK-CAZ-SC 1330.98 31.33 89.47 1281.72 1172.72 18.95 271.71 5945748.31 559115.23 MWD+IFR-AK-CAZ-SC 1374.40 35.57 89.81 1317.94 1208.94 19.10 295.64 5945748.64 559139.15 MWD+IFR-AK-CAZ-SC 1427.82 37.21 89.42 1360.94 1251.94 19.31 327.33 5945749.11 559170.83 MWD+IFR-AK-CAZ-SC 1522.61 37.43 90.02 1436.32 1327.32 19.59 384.79 5945749.83 559228.29 MWD+IFR-AK-CAZ-SC 1616.90 41.63 90.66 1509.03 1400.03 19.22 444.79 5945749.93 559288.28 MWD+IFR-AK-CAZ-SC '~ 1669.94 46.39 89.61 1547.17 1438.17 19.15 481.63 5945750.15 559325.12 MWD+IFR-AK-CAZ-SC 1710.91 50.31 89.47 1574.39 1465.39 19.39 512.24 5945750.63 559355.72 MWD+IFR-AK-CAZ-SC i 1755.08 51.00 89.71 1602.40 1493.40 19.64 546.40 5945751.14 559389.87 MWD+IFR-AK-CAZ-SC 1805.44 51.68 90.37 1633.86 1524.86 19.61 585.72 5945751.42 559429.19 MWD+IFR-AK-CAZ-SC ~i 1853.81 54.16 90.34 1663.02 1554.02 19.37 624.30 5945751.49 559467.77 MWD+IFR-AK-CAZ-SC 1902.80 54.95 90.90 1691.43 1582.43 18.94 664.21 5945751.37 559507.68 MWD+IFR-AK-CAZ-SC 1937.72 57.64 90.44 1710.80 1601.80 18.60 693.26 5945751.25 559536.72 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: Coa~ocoPhillips Alaska Inc. Date: 4/1 012 00 7 Time: 14:21:36 ____ Page: ?. Field: Kuparuk River Unit Co-or din:~te(NE}Reference: Well: 1J-11 8, Tr ue North Site:... Ku paruk 1J Pad Vertical (TV D) Re ference: 1J-118PB1 : 109 .0 Well: iJ -T18 .Section (VS) Reter ence: Well (O.OON,O.OOE,O.OOAzi) N'ellhath: 1J -118PB1 Surrey Calc ulation Method: Minimum C urvat ure Dh: Oracle Surve~~ - - _ DLD hul Azim TVll Sps TV D N/S _ - E/W MapN 1apE Tonl ft deg deg ft __ ft - ft ft _ _ ft - ft 1998. 89 59.84 91.39 1742. 54 1633 .54 17. 76 745. 54 5945750. 82 559589. 00 MWD+IFR-AK-CAZ-SC 2030. 52 62.36 91.96 1757. 83 1648 .83 16. 95 773. 21 5945750. 23 559616. 68 MWD+IFR-AK-CAZ-SC 2092. 99 64.67 94.04 1785. 69 1676 .69 14. 01 829. 04 5945747. 73 559672. 53 MWD+IFR-AK-CAZ-SC I 2189. 09 70.82 95.06 1822. 07 1713 .07 6. 94 917. 66 5945741. 35 559761. 19 MWD+IFR-AK-CAZ-SC 2286. 70 73.19 95.06 1852. 22 1743 .22 -1. 24 1010. 12 5945733. 89 559853. 71 MWD+IFR-AK-CAZ-SC 2382. 12 71.05 95.20 1881. 52 1772 .52 -9. 36 1100. 57 5945726. 48 559944. 20 MWD+IFR-AK-CAZ-SC 2476. 11 71.26 93.38 1911. 88 1802 .88 -16. 02 1189. 26 5945720. 52 560032. 94 MWD+IFR-AK-CAZ-SC 2568. 26 70.85 91.35 1941. 80 1832 .80 -19. 61 1276. 34 5945717. 60 560120. 03 MWD+IFR-AK-CAZ-SC 2664. 04 71.27 92.79 1972. 89 1863 .89 -22. 89 1366. 87 5945715. 04 560210. 58 - MWD+IFR-AK-CAZ-SC 2756. 26 69.10 91.04 2004. 15 1895 .15 -25. 80 1453. 58 5945712. 81 560297. 29 MWD+IFR-AK-CAZ-SC j 2847. 00 69.97 92.62 2035. 88 1926 .88 -28. 51 1538. 54 5945710. 75 560382. 27 MWD+IFR-AK-CAZ-SC 2943. 26 71.58 91.70 2067. 57 1958 .57 -31. 94 1629. 37 5945708. 04 560473. 11 MWD+IFR-AK-CAZ-SC I 3039. 70 70.63 92.26 2098. 80 1989 .80 -35. 09 1720. 55 5945705. 60 560564. 31 MWD+IFR-AK-CAZ-SC 3134 .18 70.26 92.17 2130. 43 2021 .43 -38. 53 1809. 52 5945702. 86 560653. 29 MWD+IFR-AK-CAZ-SC 3200. 94 68.25 91.59 2154. 07 2045 .07 -40. 58 1871. 91 5945701. 29 560715. 69 MWD+IFR-AK-CAZ-SC 3229. 87 66.58 92.72 2165. 18 2056 .18 -41. 58 1898. 60 5945700. 50 560742. 39 MWD+IFR-AK-CAZ-SC 3295. 41 64.01 92.70 2192. 57 2083 .57 -44. 40 1958. 07 5945698. 15 560801. 87 MWD+IFR-AK-CAZ-SC 3313. 70 63.85 92.94 2200. 61 2091 .61 -45. 20 1974. 48 5945697. 47 560818. 28 MWD+IFR-AK-CAZ-SC 3453. 41 65.79 93.79 2260. 05 2151 .05 -52. 63 2100. 69 5945691. 03 560944. 53 MWD+IFR-AK-CAZ-SC 3547. 91 67.44 94.37 2297. 56 2188 .56 -58. 81 2187. 20 5945685. 53 561031. 09 MWD+IFR-AK-CAZ-SC 3641. 45 67.18 94.71 2333. 64 2224 .64 -65. 64 2273. 23 5945679. 37 561117. 16 MWD+IFR-AK-CAZ-SC 3737. 18 66.21 95.04 2371. 51 2262 .51 -73. 11 2360. 83 5945672. 59 561204 .81 MWD+IFR-AK-CAZ-SC 3834. 00 67.24 92.42 2409. 78 2300 .78 -78. 88 2449. 57 5945667. 51 561293 .58 MWD+IFR-AK-CAZ-SC 3930. 20 66.62 92.98 2447. 47 2338 .47 -83. 05 2537. 98 5945664. 03 561382 .01 MWD+IFR-AK-CAZ-SC 4025 .99 67.73 92.76 2484. 63 2375 .63 -87. 47 2626. 16 5945660. 30 561470 .21 MWD+IFR-AK-CAZ-SC 4120 i .47 67.61 93.16 2520. 53 2411 .53 -91. 99 2713. 44 5945656. 47 561557 .51 MWD+IFR-AK-CAZ-SC 4213. 33 66.69 93.72 255&. 59 2447 .59 -97. 12 2798. 85 5945652. 00 561642 .96 MWD+IFR-AK-CAZ-SC 4310. 21 67.42 92.38 2594. 36 2485 .36 -101. 86 2887. 94 5945647. 96 561732. 07 MWD+IFR-AK-CAZ-SC 4404. 86 67.62 92.21 2630. 55 2521 .55 -105. 37 2975. 33 5945645. 14 561819. 47 MWD+IFR-AK-CAZ-SC 4499. 68 67.33 92.60 2666. 87 2557 .87 -109. 04 3062. 84 5945642. 15 561907. 00 MWD+IFR-AK-CAZ-SC 4591. 05 67.62 92.95 2701. 87 2592 .87 -113. 13 3147. 14 5945638. 72 561991 .32 MWD+IFR-AK-CAZ-SC 4686. 19 68.23 92.11 2737. 63 2628 .63 -117. 02 3235. 21 5945635. 52 562079 .42 MWD+IFR-AK-CAZ-SC 4780. 87 68.23 88.09 2772. 76 2663 .76 -117. 17 3323. 12 5945636. 05 562167 .31 MWD+IFR-AK-CAZ-SC 4874. 94 67.42 86.84 2808. 26 2699 .26 -113. 32 3410. 14 5945640. 58 562254 .30 MWD+IFR-AK-CAZ-SC 4968. 89 67.91 83.86 2843. 97 2734 .97 -106. 27 3496. 75 5945648. 30 562340 .83 MWD+IFR-AK-CAZ-SC 5064 .95 67.63 81.22 2880. 32 2771 .32 -94. 73 3584. 90 5945660. 53 562428 .89 MWD+IFR-AK-CAZ-SC ~I 5160 .91 69.51 76.53 2915. 40 2806 .40 -77. 48 3672. 51 5945678. 47 562516 .35 MWD+IFR-AK-CAZ-SC 5253 .70 69.49 70.42 2947. 92 2838 .92 -52. 77 3755. 79 5945703. 82 562599 .42 MWD+IFR-AK-CAZ-SC 5351 .34 69.70 66.02 2981. 98 2872 .98 -18. 83 3840. 74 5945738. 43 562684 .10 MWD+IFR-AK-CAZ-SC 5448 .46 68.60 62.73 3016. 55 2907 .55 20. 41 3922. 56 5945778 .30 562765 .61 MWD+IFR-AK-CAZ-SC 5544. 21 67.75 57.64 3052. 17 2943 .17 64. 58 3999. 66 5945823. 06. 562842 .34 MWD+IFR-AK-CAZ-SC ~ 5638. 68 67.85 53.26 3087. 88 2978 .88 114. 17 4071. 67 5945873. 21 562913 .97 MWD+IFR-AK-CAZ-SC 5735. 67 68.05 48.42 3124. 31 3015 .31 170. 91 4141. 35 5945930. 49 562983 .19 MWD+IFR-AK-CAZ-SC 5830 .70 66.10 44.27 3161. 34 3052 .34 231. 30 4204. 67 5945991. 36 563046 .03 MWD+IFR-AK-CAZ-SC ~ ' 5924 .22 69.30 39.64 3196. 84 3087 .84 295. 64 4262. 46 5946056 .15 563103 .31 MWD+IFR-AK-CAZ-SC 6015 .21 68.68 35.42 3229. 47 3120 .47 362. 98 4314. 19 5946123. 88 563154 .51 MWD+IFR-AK-CAZ-SC 6110 .16 67.87 32.60 3264. 62 3155 .62 436. 08 4363. 53 5946197 .36 563203 .27 MWD+IFR-AK-CAZ-SC 6205 .26 68.40 29.72 3300. 05 3191 .05 511. 60 4409. 18 5946273 .23 563248 .33 MWD+IFR-AK-CAZ-SC 6301 .73 68.32 27.60 3335. 63 3226 .63 590. 28 4452. 19 5946352 .23 563290 .71 MWD+IFR-AK-CAZ-SC 6397 .50 66.91 23.40 3372. 11 3263 .11 670. 17 4490. 31 5946432 .41 563328 .21 MWD+IFR-AK-CAZ-SC 6492 .22 66.44 20.99 3409. 62 3300 .62 750. 70 4523. 17 5946513 .19 563360 .43 MWD+IFR-AK-CAZ-SC 6588 .77 70.38 16.05 3445. 16 3336 .16 835. 79 4551. 62 5946598 .49 563388 .21 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/1 012 0 0 7 Time: 14:21:36 Nage: 3 Field: Kuparuk River Unit Co-ordinate(NE)'Reference: Well: 1J-118, Tn~e North Sitc: KuparuklJPad Vertical (1'VD)Reference: 1J-118PB1:109:0 ~~cll: 1J-118 Section (VS)Reference: Well (O.OON,O.OOE,O.OOAzi) WeltpaYh: 1J-118PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVI1 tins TVD N/S E/V1' A1apN ~IapE Tool ft deg deg ft ft ft ft ft ft 6681.74 72.83 12.14 3474.50 3365.50 921.33 4573.08 5946684.19 563409.00 MWD+IFR-AK-CAZ-SC '~~ 6777.79 74.24 7.05 3501.74 3392.74 1012.12 4588.41 5946775.09 563423.62 MWD+IFR-AK-CAZ-SC 6869.50 73:93 2.38 3526.90 3417.90 1099.99 4595.66 5946863.00 563430.18 MWD+IFR-AK-CAZ-SC 6964.12 75.87 358.76 3551.56 3442.56 1191.31 4596.55 5946954.32 563430.36 MWD+IFR-AK-CAZ-SC 7058.97 75.11 358.72 3575.32 3466.32 1283.12 4594.54 5947046.10 563427.63 MWD+IFR-AK-CAZ-SC 7154.43 79.30 358.11 3596.46 3487.46 1376.15 4591.96 5947139.10 563424.32 MWD+IFR-AK-CAZ-SC 7251.26 79.79 357.34 3614.03 3505.03 1471.30 4588.18 5947234.20 563419.80 MWD+IFR-AK-CAZ-SC 7295.62 79.62 357.13 3621.96 3512.96 1514.89 4586.07 5947277.77 563417.35 MWD+IFR-AK-CAZ-SC 7344.66 80.29 355.45 3630.51 3521.51 1563.08 4582.95 5947325.93 563413.85 MWD+IFR-AK-CAZ-SC 7385.41 79.89 355.14 3637.53 3528.53 1603.08 4579.65 5947365.90 563410.25 MWD+IFR-AK-CAZ-SC 7439.36 80.09 357.91 3646.91 3537.91 1656.11 4576.43 5947418.90 563406.61 MWD+IFR-AK-CAZ-SC 7535.83 82.47 0.07 3661.53 3552.53 1751.44 4574.76 5947514.20 563404.19 MWD+IFR-AK-CAZ-SC 7580.51 82.58 1.02 3667.34 3558.34 1795.73 4575.18 5947558.50 563404.27 MWD+IFR-AK-CAZ-SC 7632.34 82.24 1.50 3674.19 3565.19 1847.10 4576.31 5947609.86 563405.00 MWD+IFR-AK-CAZ-SC 7726.90 81.59 1.19 3687.49 3578.49 1940.69 4578.51 5947703.46 563406.46 MWD+IFR-AK-CAZ-SC 7822.62 81.54 1.10 3701.53 3592.53 2035.36 4580.40 5947798.13 563407.62 MWD+IFR-AK-CAZ-SC 7856.07 80.18 0.91 3706.84 3597.84 2068.37 4580.98 5947831.15 563407.94 MWD+IFR-AK-CAZ-SC 7887.78 78.61 0.97 3712.68 3603.68 2099.54 4581.49 5947862.31 563408.20 MWD+IFR-AK-CAZ-SC 7916.96 78.91 1.50 3718.37 3609.37 2128.15 4582.11 5947890.93 563408.60 MWD+IFR-AK-CAZ-SC 8011.30 81.05 1.67 3734.78 3625.78 2221.01 4584.68 5947983.80 563410.44 MWD+IFR-AK-CAZ-SC 8106.89 80.80 2.05 3749.86 3640.86 2315.36 4587.74 5948078.15 563412.77 MWD+IFR-AK-CAZ-SC 8202.94 80.72 1.74 3765.28 3656.28 2410.11 4590.88 5948172.92 563415.16 MWD+IFR-AK-CAZ-SC 8297.55 79.10 2.16 3781.86 3672.86 2503.20 4594.04 5948266.02 563417.60 MWD+IFR-AK-CAZ-SC 8393.56 79.09 0.99 3800.02 3691.02 2597.44 4596.64 5948360.26 563419.46 MWD+IFR-AK-CAZ-SC 8489.36 78.27 0.53 3818.82 3709.82 2691.36 4597.88 5948454.19 563419.97 MWD+IFR-AK-CAZ-SC 8522.98 79.22 0.38 3825.39 3716.39 2724.33 4598.14 5948487.16 563419.97 MWD+IFR-AK-CAZ-SC 8584.85 82.13 0.27 3835.41 3726.41 2785.38 4598.49 5948548.20 563419.84 MWD+IFR-AK-CAZ-SC 8631.79 82.72 0.17 3841.60 3732.60 2831.91 4598.67 5948594.72 563419.66 MWD+IFR-AK-CAZ-SC 8679.49 83.42 359.61 3847.35 3738.35 2879.26 4598.58 5948642.07 563419.20 MWD+IFR-AK-CAZ-SC 8733.44 85.45 358.79 3852.58 3743.58 2932.95 4597.83 5948695.74 563418.03 MWD+IFR-AK-CAZ-SC j 8774.83 86.03 357.44 3855.66 3746.66 2974.20 4596.47 5948736.98 563416.35 MWD+IFR-AK-CAZ-SC I 8868.39 88.55 353.37 3860.08 3751.08 3067.33 4588.98 5948830.04 563408.13 MWD+IFR-AK-CAZ-SC 8899.11 89.13 352.69 3860.71 3751.71 3097.81 4585.25 5948860.49 563404.17 MWD+IFR-AK-CAZ-SC 8930.79 89.47 351.61 3861.09 3752.09 3129.19 4580.93 5948891.83 563399.60 MWD+IFR-AK-CAZ-SC 8982.00 89.47 351.61 3861.57 3752.57 3179.85 4573.46 5948942.43 563391.73 PROJECTED to TD Halliburton Company Survey Report Cumpany: ConocoPhillips Alaska Inc. Date: 4/10/2007 'Time. 15:28:27 Page: 1 Field: Kuparuk River Unit Co -ordinate(':VE)Reference: WeII: 1J-118, Tr ue North Site: Kuparuk 1J Pad Vc rtical(TVD)Referencc: 1J-118PB2: 109.0 WeII: 1J-118 Section (VS)Reference: WeII (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-118PB2 Su rvey Calculation Alcthod: 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 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre j Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ! Well: 1J-118 Slot Name: Well Position: +N/-S -192.83 ft Northing: 5945727.24 ft Latitude: 70 15 44.361 N +E/-W 52.25 ft Easting : 558843.70 ft Longitude: 149 31 27.486 W Position Uncertainty: 0.00 ft Wellpath: 1J-118P62 Drilled From: 1J-118P61 500292333771 Tie-on Depth: 8631.79 ft Current Datum: 1J-118PB2: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/2/2007 Declination: 23.63 deg Field Strength: 57618 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 ~ __ Survey Program For Definitive Wellpath _ -' I Date: 4/10/2007 Validated: No Version: 1 Actual From To Survey ft Toolcode Tool Name - - - 50.00 917.00 1J-118PB1 gyro (50.00-917.00) 952.48 8631.79 1J-118P61 (952.48-8930.79) (3) CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8650.00 11808.00 1J-118PB2 (8650.00-11808.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey -- - - __ A1D Ind Azim TVD Sys TVD N/S E/W ;v1apN MapE Tnnl ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945727.24 558843.70 TIE LINE i ~ 50.00 0.26 178.55 50.00 -59.00 -0.05 0.00 5945727.19 558843.70 CB-GYRO-SS 100.00 0.35 185.44 100.00 -9.00 -0.32 -0.01 5945726.92 558843.69 CB-GYRO-SS 172.00 0.41 204.37 172.00 63.00 -0.77 -0.14 5945726.47 558843.57 CB-GYRO-SS 264.00 0.53 206.73 263.99 154.99 -1.45 -0.46 5945725.79 558843.25 CB-GYRO-SS 356.00 1.13 107.26 355.99 246.99 -2.10 0.21 5945725.14 558843.93 CB-GYRO-SS 447.00 4.18 84.03 446.88 337.88 -2.02 4.37 5945725.26 558848.08 CB-GYRO-SS 535.00 7.32 80.59 534.43 425.43 -0.77 13.09 5945726.57 558856.79 CB-GYRO-SS 629.00 10.71 78.99 627.25 518.25 1.88 27.57 5945729.33 558871.26 CB-GYRO-SS 732.00 14.71 84.31 727.71 618.71 5.00 49.99 5945732.63 558893.65 CB-GYRO-SS 826.00 16.54 84.61 818.23 709.23 7.45 75.19 5945735.27 558918.82 CB-GYRO-SS 917.00 18.07 85.00 905.11 796.11 9.89 102.15 5945737.93 558945.76 CB-GYRO-SS 952.48 18.85 83.37 938.77 829.77 11.03 113.32 5945739.16 558956.92 MWD+IFR-AK-CAZ-SC 1043.68 21.78 85.65 1024.29 915.29 14.02 144.84 5945742.39 558988.41 MWD+IFR-AK-CAZ-SC 1143.62 25.49 86.25 1115.83 1006.83 16.83 184.80 5945745.51 559028.34 MWD+IFR-AK-CAZ-SC 1236.06 27.56 88.80 1198.54 1089.54 18.58 226.03 5945747.59 559069.56 MWD+IFR-AK-CAZ-SC 1285.00 28.16 89.95 1241.80 1132.80 18.83 248.90 5945748.01 559092.42 MWD+IFR-AK-CAZ-SC 1330.98 31.33 89.47 1281.72 1172.72 18.95 271.71 5945748.31 559115.23 MWD+IFR-AK-CAZ-SC ~ ' 1374.40 35.57 89.81 1317.94 1208.94 19.10 295.64 5945748.64 559139.15 MWD+IFR-AK-CAZ-SC 1427.82 37.21 89.42 1360.94 1251.94 19.31 327.33 5945749.11 559170.83 MWD+IFR-AK-CAZ-SC 1522.61 37.43 90.02 1436.32 1327.32 19.59 384.79 5945749.83 559228.29 MWD+IFR-AK-CAZ-SC 1616.90 41.63 90.66 1509.03 1400.03 19.22 444.79 5945749.93 559288.28 MWD+IFR-AK-CAZ-SC 1669.94 46.39 89.61 1547.17 1438.17 19.15 481.63 5945750.15 559325.12 MWD+IFR-AK-CAZ-SC 1710.91 50.31 89.47 1574.39 1465.39 19.39 512.24 5945750.63 559355.72 MWD+IFR-AK-CAZ-SC 1755.08 51.00 89.71 1602.40 1493.40 19.64 546.40 5945751.14 559389.87 MWD+IFR-AK-CAZ-SC 1805.44 51.68 90.37 1633.86 1524.86 19.61 585.72 5945751.42 559429.19 MWD+IFR-AK-CAZ-SC 1853.81 54.16 90.34 1663.02 1554.02 19.37 624.30 5945751.49 559467.77 MWD+IFR-AK-CAZ-SC 1902.80 54.95 90.90 1691.43 1582.43 18.94 664.21 5945751.37 559507.68 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report • Company: ConocoPhillips Alaska Inc. ' Date: 4/10/2007 __ Time: 15:28:27 Yage: 2 Field: Ku paru K'River Uni t - Co-ordinate(NE) Reference: `Well: 1 J-11 8, Tr ue North Sitc: Ku pani k 1 J Pad Vertical (TVD)Re ference: 1 J-11'8PB2: 109 .0 Well: 1 J- 113 Sectio n (VS) Reference: Welt (O.OON,O.OOE,O.OOAzi) Wcllpath: 1J- 118PB2 Surve y Calculation ;Method: . Minimum C urvat ure Db: Oracle Survey __ - MD _ Inc l - Azim _ TVD Sys TV _ D _ N/S - - E/V1' n1apN _ __ 11apE Tnnl ', ft deg de g ft ft ft ft ft ft ' 1937.72 57. 64 90 .44 1710. 80 1601. 80 18. 60 693.26 5945751. 25 559536. 72 MWD+IFR-AK-CAZ-SC 1998.89 59. 84 91 .39 1742. 54 1633 .54 17. 76 745.54 5945750. 82 559589. 00 MWD+IFR-AK-CAZ-SC ~ 2030.52 62. 36 91 .96 1757. 83 1648 .83 16. 95 773.21 5945750. 23 559616. 68 MWD+IFR-AK-CAZ-SC 2092.99 64. 67 94 .04 1785. 69 1676 .69 14. 01 829.04 5945747. 73 559672. 53 MWD+IFR-AK-CAZ-SC 2189.09 70. 82 95 .06 1822. 07 1713 .07 6. 94 917.66 5945741. 35 559761. 19 MWD+IFR-AK-CAZ-SC 2286.70 73. 19 95 .06 1852. 22 1743 .22 -1. 24 1010.12 5945733. 89 559853. 71 MWD+IFR-AK-CAZ-SC 2382.12 71. 05 95 .20 1881. 52 1772 .52 -9. 36 1100.57 5945726. 48 559944. 20 MWD+IFR-AK-CAZ-SC 2476.11 71. 26 93 .38 1911. 88 1802 .88 -16. 02 1189.26 5945720. 52 560032. 94 MWD+IFR-AK-CAZ-SC 2568.26 70. 85 91 .35 1941. 80 1832 .80 -19. 61 1276.34 5945717. 60 560120. 03 MWD+IFR-AK-CAZ-SC 2664.04 71. 27 92 .79 1972. 89 1863 .89 -22. 89 1366.87 5945715. 04 560210. 58 MWD+IFR-AK-CAZ-SC 2756.26 69. 10 91 .04 2004. 15 1895 .15 -25. 80 1453.58 5945712. 81 560297. 29 MWD+IFR-AK-CAZ-SC 2847.00 69. 97 92 .62 2035. 88 1926 .88 -28. 51 1538.54 5945710. 75 560382. 27 MWD+IFR-AK-CAZ-SC 2943.26 71. 58 91 .70 2067. 57 1958 .57 -31. 94 1629.37 5945708. 04 560473. 11 MWD+IFR-AK-CAZ-SC 3039.70 70. 63 92 .26 2098. 80 1989 .80 -35. 09 1720.55 5945705. 60 560564. 31 MWD+IFR-AK-CAZ-SC 3134.18 70. 26 92 .17 2130. 43 2021 .43 -38. 53 1809.52 5945702. 86 560653. 29 MWD+IFR-AK-CAZ-SC ~ 3200.94 68. 25 91 .59 2154. 07 2045 .07 -40. 58 1871.91 5945701. 29 560715. 69 MWD+IFR-AK-CAZ-SC ~ 3229.87 i 66. 58 92 .72 2165. 18 2056 .18 -41. 58 1898.60 5945700. 50 560742. 39 MWD+IFR-AK-CAZ-SC ~ 3295.41 64. 01 92 .70 2192. 57 2083 .57 -44. 40 1958.07 5945698. 15 560801. 87 MWD+IFR-AK-CAZ-SC 3313.70 63. 85 92 .94 2200. 61 2091 .61 -45. 20 1974.48 5945697. 47 560818. 28 MWD+IFR-AK-CAZ-SC 3453.41 65. 79 93 .79 2260. 05 2151 .05 -52. 63 2100.69 5945691. 03 560944. 53 MWD+IFR-AK-CAZ-SC 3547.91 67. 44 94 .37 2297. 56 2188 .56 -58. 81 2187.20 5945685. 53 561031. 09 MWD+IFR-AK-CAZ-SC 3641.45 67. 18 94 .71 2333. 64 2224 .64 -65. 64 2273.23 5945679. 37 561117. 16 MWD+IFR-AK-CAZ-SC 3737.18 66. 21 95 .04 2371. 51 2262 .51 -73. 11 2360.83 5945672. 59 561204. 81 MWD+IFR-AK-CAZ-SC 3834.00 67. 24 92 .42 2409. 78 2300 .78 -78. 88 2449.57 5945667. 51 561293. 58 MWD+IFR-AK-CAZ-SC ~ 3930.20 66. 62 92 .98 2447. 47 2338 .47 -83. 05 2537.98 5945664. 03 561382. 01 MWD+IFR-AK-CAZ-SC 4025.99 67. 73 92 .76 2484. 63 2375 .63 -87. 47 2626.16 5945660. 30 561470. 21 MWD+IFR-AK-CAZ-SC 4120.47 67. 61 93 .16 2520. 53 2411 .53 -91. 99 2713.44 5945656. 47 561557. 51 MWD+IFR-AK-CAZ-SC ' j 4213.33 66. 69 93 .72 2556. 59 2447 .59 -97. 12 2798.85 5945652. 00 561642. 96 MWD+IFR-AK-CAZ-SC ~ 4310.21 67. 42 92 .38 2594. 36 2485 .36 -101. 86 2887.94 5945647. 96 561732. 07 MWD+IFR-AK-CAZ-SC 4404.86 67. 62 92 .21 2630. 55 2521 .55 -105. 37 2975.33 5945645. 14 561819. 47 MWD+IFR-AK-CAZ-SC 4499.68 67. 33 92 .60 2666. 87 2557 .87 -109. 04 3062.84 5945642. 15 561907. 00 MWD+IFR-AK-CAZ-SC 4591.05 67. 62 92 .95 2701. 87 2592 .87 -113. 13 3147.14 5945638. 72 561991. 32 MWD+IFR-AK-CAZ-SC 4686.19 68. 23 92 .11 2737. 63 2628 .63 -117. 02 3235.21 5945635. 52 562079. 42 MWD+IFR-AK-CAZ-SC 4780.87 68. 23 88 .09 2772. 76 2663 .76 -117. 17 3323.12 5945636. 05 562167. 31 MWD+IFR-AK-CAZ-SC 4874.94 67. 42 86 .84 2808. 26 2699 .26 -113. 32 3410.14 5945640. 58 562254. 30 MWD+IFR-AK-CAZ-SC 4968.89 67. 91 83 .86 2843. 97 2734 .97 -106. 27 3496.75 5945648. 30 562340. 83 MWD+IFR-AK-CAZ-SC 5064.95 67. 63 81 .22 2880. 32 2771 .32 -94. 73 3584.90 5945660. 53 562428. 89 MWD+IFR-AK-CAZ-SC 5160.91 69. 51 76 .53 2915. 40 2806 .40 -77. 48 3672.51 5945678. 47 562516. 35 MWD+IFR-AK-CAZ-SC 5253.70 69. 49 70 .42 2947. 92 2838 .92 -52. 77 3755.79 5945703. 82 562599. 42 MWD+IFR-AK-CAZ-SC 5351.34 69 .70 66 .02 2981. 98 2872 .98 -18. 83 3840.74 5945738. 43 562684. 10 MWD+IFR-AK-CAZ-SC 5448.46 68. 60 62 .73 3016. 55 2907 .55 20. 41 3922.56 5945778. 30 562765. 61 MWD+IFR-AK-CAZ-SC 5544.21 67 .75 57 .64 3052. 17 2943 .17 64. 58 3999.66 5945823. 06 562842. 34 MWD+IFR-AK-CAZ-SC 5638.68 67. 85 53 .26 3087. 88 2978 .88 114. 17 4071.67 5945873. 21 562913. 97 MWD+IFR-AK-CAZ-SC i 5735.67 68. 05 48 .42 3124. 31 3015 .31 170. 91 4141.35 5945930. 49 562983. 19 MWD+IFR-AK-CAZ-SC ', 5830.70 66. 10 44 .27 3161. 34 3052 .34 231. 30 4204.67 5945991. 36 563046. 03 MWD+IFR-AK-CAZ-SC ' 5924.22 69. 30 39 .64 3196. 84 3087 .84 295. 64 4262.46 5946056. 15 563103. 31 MWD+IFR-AK-CAZ-SC 6015.21 68. 68 35 .42 3229. 47 3120 .47 362. 98 4314.19 5946123. 88 563154. 51 MWD+IFR-AK-CAZ-SC 6110.16 67. 87 32 .60 3264. 62 3155 .62 436. 08 4363.53 5946197. 36 563203. 27 MWD+IFR-AK-CAZ-SC 6205.26 68 .40 29 .72 3300. 05 3191 .05 511. 60 4409.18 5946273. 23 563248. 33 MWD+IFR-AK-CAZ-SC 6301.73 68 .32 27 .60 3335. 63 3226 .63 590. 28 4452.19 5946352. 23 563290. 71 MWD+IFR-AK-CAZ-SC 6397.50 66 .91 23 .40 3372. 11 3263 .11 670. 17 4490.31 5946432. 41 563328. 21 MWD+IFR-AK-CAZ-SC 6492.22 66 .44 20 .99 3409. 62 3300 .62 750. 70 4523.17 5946513. 19 563360 .43 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/10/2007 'time: 15:28:27 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-118, True North Site: Kuparuk 1J Pad Vertical("I'VD)Rcference: 1J-118P62: 109.0 ~VeII: 1 J-118 Section (VS) Reference: Well (O.OON,OIOOE,O.OOAzi) R'ellpath: 1J-118PB2 Sunny Calculation ~7ethod: Minimum Curvature Db: Oracle __ __ Survey IbfD Incl lzim TVD Sys TVD N/S E/V1' A~fapN MapE Tnol ft deg deg ft ft ft ft- ft ft 6588.77 70.38 16.05 3445.16 3336.16 835.79 4551.62 5946598.49 563388.21 MWD+IFR-AK-CAZ-SC 6681.74 72.83 12.14 3474.50 3365.50 921.33 4573.08 5946684.19 563409.00 MWD+IFR-AK-CAZ-SC 6777.79 74.24 7.05 3501.74 3392.74 1012.12 4588.41 5946775.09 563423.62 MWD+IFR-AK-CAZ-SC 6869.50 73.93 2.38 3526.90 3417.90 1099.99 4595.66 5946863.00 563430.18 MWD+IFR-AK-CAZ-SC 6964.12 75.87 358.76 3551.56 3442.56 1191.31 4596.55 5946954.32 563430.36 MWD+IFR-AK-CAZ-SC 7058.97 75.11 358.72 3575.32 3466.32 1283.12 4594.54 5947046.10 563427.63 MWD+IFR-AK-CAZ-SC 7154.43 79.30 358.11 3596.46 3487.46 1376.15 4591.96 5947139.10 563424.32 MWD+IFR-AK-CAZ-SC 7251.26 79.79 357.34 3614.03 3505.03 1471.30 4588.18 5947234.20 563419.80 MWD+IFR-AK-CAZ-SC 7295.62 79.62 357.13 3621.96 3512.96 1514.89 4586.07 5947277.77 563417.35 MWD+IFR-AK-CAZ-SC 7344.66 80.29 355.45 3630.51 3521.51 1563.08 4582.95 5947325.93 563413.85 MWD+IFR-AK-CAZ-SC 7385.41 79.89 355.14 3637.53 3528.53 1603.08 4579.65 5947365.90 563410.25 MWD+IFR-AK-CAZ-SC 7439.36 80.09 357.91 3646.91 3537.91 1656.11 4576.43 5947418.90 563406.61 MWD+IFR-AK-CAZ-SC 7535.83 82.47 0.07 3661.53 3552.53 1751.44 4574.76 5947514.20 563404.19 MWD+IFR-AK-CAZ-SC 7580.51 82.58 1.02 3667.34 3558.34 1795.73 4575.18 5947558.50 563404.27 MWD+IFR-AK-CAZ-SC 7632.34 82.24 1.50 3674.19 3565.19 1847.10 4576.31 5947609.86 563405.00 MWD+IFR-AK-CAZ-SC I 7726.90 81.59 1.19 3687.49 3578.49 1940.69 4578.51 5947703.46 563406.46 MWD+IFR-AK-CAZ-SC 7822.62 81.54 1.10 3701.53 3592.53 2035.36 4580.40 5947798.13 563407.62 MWD+IFR-AK-CAZ-SC i 7856.07 80.18 0.91 3706.84 3597.84 2068.37 4580.98 5947831.15 563407.94 MWD+IFR-AK-CAZ-SC 7887.78 78.61 0.97 3712.68 3603.68 2099.54 4581.49 5947862.31 563408.20 MWD+IFR-AK-CAZ-SC 7916.96 78.91 1.50 3718.37 3609.37 2128.15 4582.11 5947890.93 563408.60 MWD+IFR-AK-CAZ-SC 8011.30 81.05 1.67 3734.78 3625.78 2221.01 4584.68 5947983.80 563410.44 MWD+IFR-AK-CAZ-SC 8106.89 80.80 2.05 3749.86 3640.86 2315.36 4587.74 5948078.15 563412.77 MWD+IFR-AK-CAZ-SC 8202.94 80.72 1.74 3765.28 3656.28 2410.11 4590.88 5948172.92 563415.16 MWD+IFR-AK-CAZ-SC 8297.55 79.10 2.16 3781.86 3672.86 2503.20 4594.04 5948266.02 563417.60 MWD+IFR-AK-CAZ-SC ~~ 8393.56 79.09 0.99 3800.02 3691.02 2597.44 4596.64 5948360.26 563419.46 MWD+IFR-AK-CAZ-SC ~ 8489.36 78.27 0.53 3818.82 3709.82 2691.36 4597.88 5948454.19 563419.97 MWD+IFR-AK-CAZ-SC 8522.98 79.22 0.38 3825.39 3716.39 2724.33 4598.14 5948487.16 563419.97 MWD+IFR-AK-CAZ-SC 8584.85 82.13 0.27 3835.41 3726.41 2785.38 4598.49 5948548.20 563419.84 MWD+IFR-AK-CAZ-SC 8631.79 82.72 0.17 3841.60 3732.60 2831.91 4598.67 5948594.72 563419.66 MWD+IFR-AK-CAZ-SC 8650.00 82.99 359.96 3843.86 3734.86 2849.98 4598.69 5948612.79 563419.54 MWD+IFR-AK-CAZ-SC 8711.87 81.57 356.32 3852.18 3743.18 2911.24 4596.70 5948674.03 563417.07 MWD+IFR-AK-CAZ-SC 8744.52 82.93 355.08 3856.58 3747.58 2943.50 4594.28 5948706.27 563414.39 MWD+IFR-AK-CAZ-SC 8808.00 86.14 352.92 3862.62 3753.62 3006.33 4587.67 5948769.04 563407.30 MWD+IFR-AK-CAZ-SC 8867.25 87.83 350.68 3865.74 3756.74 3064.89 4579.23 5948827.53 563398.40 MWD+IFR-AK-CAZ-SC 8907.20 87.93 349.80 3867.22 3758.22 3104.24 4572.46 5948866.81 563391.33 MWD+IFR-AK-CAZ-SC 9005.00 88.08 350.40 3870.62 3761.62 3200.52 4555.66 5948962.95 563373.77 MWD+IFR-AK-CAZ-SC 9099.49 89.70 351.06 3872.45 3763.45 3293.76 4540.44 5949056.06 563357.83 MWD+IFR-AK-CAZ-SC 9191.86 90.56 349.31 3872.24 3763.24 3384.77 4524.70 5949146.94 563341.37 MWD+IFR-AK-CAZ-SC 9286.64 89.08 350.16 3872.54 3763.54 3478.03 4507.81 5949240.05 563323.76 MWD+IFR-AK-CAZ-SC 9379.45 87.35 350.23 3875.43 3766.43 3569.43 4492.01 5949331.32 563307.25 MWD+IFR-AK-CAZ-SC 9473.30 88.03 350.62 3879.22 3770.22 3661.90 4476.41 5949423.66 563290.93 MWD+IFR-AK-CAZ-SC it 9566.09 88.96 352.25 3881.65 3772.65 3753.62 4462.60 5949515.26 563276.40 MWD+IFR-AK-CAZ-SC 9659.69 88.65 352.61 3883.60 3774.60 3846.38 4450.27 5949607.91 563263.35 MWD+IFR-AK-CAZ-SC 9753.04 88.53 352.37 3885.90 3776.90 3938.91 4438.07 5949700.33 563250.43 MWD+IFR-AK-CAZ-SC li 9847.19 88.83 354.24 3888.07 3779.07 4032.38 4427.10 5949793.71 563238.73 MWD+IFR-AK-CAZ-SC i i 9939.68 88.89 357.01 3889.91 3780.91 4124.58 4420.05 5949885.83 563230.96 MWD+IFR-AK-CAZ-SC 10033.24 90.07 358.56 3890.76 3781.76 4218.06 4416.43 5949979.28 563226.61 MWD+IFR-AK-CAZ-SC 10126.56 90.38 358.03 3890.39 3781.39 4311.34 4413.65 5950072.52 563223.11 MWD+IFR-AK-CAZ-SC 10219.85 89.45 357.14 3890.53 3781.53 4404.54 4409.72 5950165.68 563218.45 MWD+iFR-AK-CAZ-SC 10312.18 88.77 355.79 3891.97 3782.97 4496.68 4404.03 5950257.77 563212.04 MWD+IFR-AK-CAZ-SC 10406.60 88.52 355.74 3894.20 3785.20 4590.82 4397.06 5950351.84 563204.33 MWD+IFR-AK-CAZ-SC 10499.20 89.39 355.63 3895.89 3786.89 4683.14 4390.10 5950444.09 563196.65 MWD+IFR-AK-CAZ-SC ~ 'i 10593.33 88.40 355.91 3897.70 3788.70 4776.99 4383.15 5950537.88 563188.97 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/10/2007 Time: 15:28:27 __ __ Page: 4 Field: Ku paruk Riv er Unit Co-or dinate(NE) Reference: Well: 1J-118,T rue North Site: Ku paruk 1J Pad Vectical(TVD) Reference: 1J-118PB2: 109.0 Nell: 1J -118 Section (VS) Keference: Well (O.OON,O.O OE,O.OOAzi) Wellpath: 1J -118PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Suitie~ ibiD lncl A~iin TVD Sys TVD N/S E/~V ?11ap~V 11IapE Tool ft deg deg ft ft ft ft ft ft 10686.35 89.08 357.19 3899.75 3790.75 4869.82 4377.56 5950630.65 563182.65 MWD+IFR-AK-CAZ-SC I 10781.03 88.40 357.82 3901.83 3792.83 4964.39 4373.44 5950725.17 563177.79 MWD+IFR-AK-CAZ-SC 10873.11 89.33 358.31 3903.65 3794.65 5056.40 4370.33 5950817.15 563173.96 MWD+IFR-AK-CAZ-SC 10966.85 88.28 357.25 3905.61 3796.61 5150.04 4366.70 5950910.75 563169.60 MWD+IFR-AK-CAZ-SC 11056.75 88.65 358.02 3908.02 3799.02 5239.83 4362.99 5951000.50 563165.19 MWD+IFR-AK-CAZ-SC 11150.08 88.09 359.52 3910.67 3801.67 5333.10 4360.99 5951093.74 563162.46 MWD+IFR-AK-CAZ-SC 11246.11 i 89.45 0.88 3912.73 3803.73 5429.10 4361.32 5951189.74 563162.05 MWD+IFR-AK-CAZ-SC 11342.16 87.29 359.59 3915.47 3806.47 5525.11 4361.72 5951285.73 563161.69 MWD+IFR-AK-CAZ-SC 11433.65 88.83 358.86 3918.56 3809.56 5616.53 4360.48 .5951377.13 563159.74 MWD+IFR-AK-CAZ-SC 11527.10 91.37 0.81 3918.40 3809.40 5709.97 4360.21 5951470.56 563158.74 MWD+IFR-AK-CAZ-SC 11621.70 93.28 2.67 3914.56 3805.56 5804.44 4363.08 5951565.04 563160.87 MWD+IFR-AK-CAZ-SC 11714.70 93.59 3.40 3908.99 3799.99 5897.14 4367.99 5951657.77 563165.06 MWD+IFR-AK-CAZ-SC j i 11808.00 92.10 0.76 3904.36 3795.36 5990.25 4371.37 5951750.89 563167.71 MWD+IFR-AK-CAZ-SC ~'I 11846.00 92.10 0.76 3902.97 3793.97. 6028.22 4371.88 5951788.86 563167.92 PROJECTED to TD 1J-118'A' Sand Liner Detail well:. 1J-118 ~°''! 4-7/Z" Slotted and Blank Liner ~ Dater 2/23/2007 ~~`~~~~~~~~~~ w/ Constrictor Packers ~Fa~x~. in~> DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS. 7837.71 7837.71 ...~ .::.:.;.;. ::,... . 7837.71 7837.71 4" DP to SurFace =_> 7837.71 XO 3 1/2 IF x 4" HT 39 2:00 . 7837.71 Baker Liner setting tool with pup jt 11.45 7839.71 5.5"x 7.63" Baker "H RD" ZXP Liner Top Pkr 19.02- 7857.16 "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 2.85 7870.18 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/4.85" ID 9.83 7873.03 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 19.65 7882.86 XO Sub 5.5"Hyd 563 X 4.5", BTC 5.99"OD X 3.94" ID 1.44 7902.51 4 1/2" Pup Jt, 12.6 ppf, L-80 3:84 7903.95 7907.79 7907.79 Jts 137 to 161 25 Jts 4-1/2" BTC 11.6 ppf, L-80 Casin *(Blanks) 1049.93 7907.79 Jts 135 to 136 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 83.72 8957.72 Jts 134 to 134 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.23 9041.44 Jts 133 to 133 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 39.07 9084.67 Jts 132 to 132 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.07. 9123.74 Jts 131 to 131 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.00 9166.81 Jts 126 to 130 5 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 206.48 9209.81 Jts 125 to 125 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.08 9416.29 Jts 124 to 124 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.20 9459.37 Jts 123 to 123 1 Jts 4-1/2" BTC 11.6 p f, L-80 Slotted Casing 43.06 9502.57 Jts 122 to 122 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.41 9545.63 Jts 121 to 121 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.83 9589.04 Jts 12o to 120 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing*(Blanks) 41.99 9630.87 Jts 119#0 119 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.03 - 9672.86 Jts 118 to 118 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 40.17 9715.89 Jts 117 to 117 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 39.92 9756.06 Jts 116 to 116 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 37.88 9795.98 Jts 115 to 115 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.39 9833.86 Jts 114 to 114 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 37..44 9877.25 Jts 113 to 113 1 JtS 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.47 9914.69 Jts 1.12 to 112 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.36 9956.16 Jts 111 to 111 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 40.80 9998.52 Jts losto 110 5 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 193.77 10039.32 Ran total of 1 15 'ts Blank 4797.04' and 47 jts Slotted 2026.55', Slots are 0:125" wide Up Wt 148k w/ 32) 2.5" long x .125" 4 Circumferential ad'acent rows, 3" Centers Dn Wt 0 k sta erect 18 de ., 3 ft. non-slotted ends. Ran Constrictor ackers .14,490' Block Wt 35k .14,216', 13,738', 13,447', 13,00T, 12,635', 9,395', 9,216' = 8 total Ran shoe joint slick. Tor ued liner w/o for ue rings to 3000 ft-Ibs, w/ torque rings to 5800 ft/Ibs used Kura-N-Seal tnread compound on all connections. All drafted w/ 3.875" rabbit. Supervisors: G.R. Whitlock/Dear/ W. Gladden/Dan Lowe Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 105 to 105 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 37.84 10233.09 Jts 104 to 104 1 Jts 4-1 /2" BTC 11.6 ppf,. L-80 Casing *(Blanks) 40.05 10270,93 Jts 103 to 103 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.06 10310.98 Jts 1o2to 102 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 36.84 10354.04 Jts 101 to 101 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 42.89 10390.88 Jts 10o to 100 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 38.50 10433.77 Jts 99 to 99 1 JtS 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.26 10472.27 Jts 9a to 9$ 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Bianks) 40.24 10515.53 Jts 97 to 97 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.63 10555.77 Jts 96 to 96 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 37.47 10599.40 Jts 95 to 95 1 JtS 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.49 10636.87 Jts 94 to 94 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.08 10679,36 Jts 93 to 93 1 Jts 4-1/2".BTC 1.1.6 ppf, L-80 Slotted Casing 4320 10722.44 Jts 92 to 92 1 JtS 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 40.80 10765.64 Jts 91 to 91 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 40.10 10806.44 Jts 84 to 90 7 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 300.32 10846.54 Jts 83 to s3 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.05 11146.86 Jts $2 to a2 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43:32 11189.91 Jts $1 to s1 1 Jts 4-1/2".BTC 11.6 ppf, L-80 Slotted Casing - 43.04 11233.23 Jts so to so 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Gasing *(Blanks) 42.92 11276.27 Jts 79 to 79 1 Jts 4-1/2" BTC 11,6 ppf, L-80 Slotted Casing 41.51 11319.19 Jts 7s to 7s 1 Jts 4-1/2" BTC 11.6-ppf,- L-80 Casing *(Blanks) 42.93 11360..70 Jts 77 to 77 1 Jts 4-1/2" BTC 11.6. ppf, L-80 Slotted Casing 43.00 11403.63 Jts 76 to 76 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.22 .11446.63 Jts 75 to 75 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 36.59 11489.85 Jts 74 to 74 1 JtS 4-1 /2" BTC 11.6. ppf, L-80 Casing *(Blanks) 43.46 11526.44 Jts 73 to 73 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 36.70 11569.90 Jts 72 to 72 1 Jts 4-1/2" BTC -11.6_ ppf, L-80 Casing *(Blanks) 42.89 11606.60 Jts 71 to 71 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.26 11649.49 Jts 7o to 70 1 Jts 4-1/2" BTC 11.6 ppf, t-80 Casing *(Blanks) ,` 42.93 .11692.75. Jts 6ato 69 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 40.91 11735.68 Jts 62 to 6$ 7 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 297.36 11776.59 Jts 61 to 61 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.51 12073.95 Jts 6o to 60 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.85 12117.46 Jts 5s to 5s 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.23 12160.31 Jts 58 to 5s 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.88 12201.54 Jts 57 to 57 1 JtS 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.65 12244.42 Jts 56 to 56 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 39.75 12288.07 Remarks: Run 1 spiroglider per it from Jt#2 thru #153 =Total 153 -Stop ring in the middle of each joint. Total 153 Ran out of down weight 13,700' -Rotate to bttm. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN. Page 3 LENGTH TOPS- Jts s5 to 55 1 Jts 4=1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.49 12327.82 Jts 54 to 54 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.70 12371.31 Jts 53 to 53 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.63 12414.01 Jts 52 to 52 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.09 12457.64 Jts 51 to 51 1 Jts 4-1/2" BTC 11..6 ppf, L-80 Slotted Casing 43.11 12500.73 Jts 41 to 50 10 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 409.94 12543.84 Jts 4o to 40 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.26 12953.78 Jts 39 to 39 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.89 12996.04 Jts 38 to 38 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.26 13038.93 Jts 37 to 37 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.39 13082.19 Jts 36 to 36 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.51 13125.58 Jts 35 to 35 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 41.61 13169.09 Jts 34 to 34 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.21 13210.70 Jts 33 to 33 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.41 13253.91. Jts 32 to 32 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.29 13297.32 Jts 31 to 31 1 Jts 4-1/2"'BTC 11.6 ppf, L-80 Casing *(Blanks) 43.38 13340.61 ,Jts 3o to 30 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 40.03 13383.99 Jts 21 to 29 9 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 367.93 13424.02 Jts 20 to 20 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.66. 13791.95 Jts 19 to 19 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.71 13834.61 Jts lsto 18 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.65 13877.32 Jts 17 to 17 1 JtS 4-1/2"BTC 11.6 ppf, L-80 Casing *(Blanks) 42.80 13920.97 Jts 16 to 16 , 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.34 13963.77 Jts 15 to 15 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.79 14007.11 Jts 14 to 14 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.20 14049.90 Jts 13 to 13 1 Jts 4-1/2" BTC 11.6ppf, L-80 Casing *(BFanks) 42.78 14093.10 Jts 12 to 12 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.05 .14135.88 Jts 4 to 11 8 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 336.17 14178.93 Jts 3 to 3 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.30 14515.10 Jts 2 to 2 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.41 14558.40 Jts 1 to 1 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.20 14601.81 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blank shoe joint) 43.30 14645.01 4 1/2" Silver Bullet Shoe 1.69 14688.31 BOTTOM OF SHOE __> 14690.00 Remarks: RE: 1J-118 (PTD 206-176) pressure test clarification and gas lift thr... • • Subject: RE: 1J-118 (PTD 206-176) pressure test clarificationand gas lift thru open sleeve... From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 27 Mar 2007 08:56:17 -0800 To: Thomas ~~1aunder ~~~-ton1 maunder(~t~admin.statc.ak.us~- CC:.lames R~~~~ ~=;jim re~~~~~r:;adn~in.state.ak.us= Tflm, Thanks for the clarification. CPAI will proceed to temporarily pre-produce 1 J-118 for 30 days with gas lift thru the open sleeve without any additional pressure #esting. Yes, 1 J-118 is the same situation as discussed last week in regard to gas lifting 1 J-180 thru the open sleeve, To be consistent regarding these wells, CPAI will continue to verify that leaving the sleeves open to temporarily gas lift the wells for pre-production is acceptable to avoid any confusion on which wells are operating with TxIA communication. It is fairly easy to determine that with the west sak packerless ESPs; but it might not be as obvious when a packer has been installed. The subsequent MITfA post conversion to injection would close the loop for each well, Thanks, Marie From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 27, 2007 8:31 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 17-118 (PTD 206-176) pressure test clarification and gas lift thru open sleeve. Marie, We exchanged a message regarding a similar situation for 1J-180 last week. The integrity of the casing is demonstrated when the packer is set on drill pipe. With regard to tubing integrity, it appears that it will be demonstrated by initializing gas lift where in order to work properly, the IA pressure must be greater than the tubing pressure. Following is the message we exchanged. As noted the situation is similar. The sliding sleeve is located proximate to the packer and for gas to enter the tubing by default little to no liquid will be in the annulus. It is acceptable to produce the well. So far as T x IA communication is concerned in this and similar cases, it is a fact of lifting the well. It is a much different situation where communication between the IA and T has been realized by compromising some part of the completion equipment. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 3/27/2007 8:05 AM: Tom, !, New West Sak injector 1 J-118 (PTD 2061760) is being prep'd fora 30 day pre-production period. The completion has a packer with a sliding sleeve (CMD) and one GLM above the packer. To lift the well as deep as possible, a gaslift valve will be installed in the GLM and the sliding sleeve will be opened 1 of 2 5/1/2007 11:29 AM RE: 1 J-118 (PTD 206-176) pressure test clarification and gas lift thr... • • as the bottom lifting point. With the sliding sleeve open, there will be TxIA communication. The annulus (IA) will not be isolated from produced fluids per 20 AAC 25.200 (d) while on pre-production; however, gas lift will be injected down the IA, minimizing or preventing produced fluids from entering the IA. Permission is requested to pre-produce 1J-118 with the sliding sleeve above the packer during the pre-production period. The pre-production is tentatively scheduled to start later this week. Additionally, clarification on regulatory required pressure tests prior to production start up is requested. As a standard, CPAI performs an MITIA during post rig wellwork on all new welts before start up. That MITIA satisfies CO 494's requirement to pressure test tubulars and completion equipment at installation to demonstrate sufficient integrity to prevent an uncontrolled release during well operation. In the case of the west sak injection wells, the sliding sleeve is left open when the tubing string is installed, so the tbg can not be tested by the drilling rig after installation. The rig performs a pressure test of the liner top packer after the last lateral is drilled, just prior to running the tubing string. Since the wells are highly deviated, to obtain an MITIA a coiled tubing unit is required to shift the sleeve closed, then open again, adding an extra 1-2 days to the post rig wellwork and about $50-80M in additional wellwork costs. It would be more efficient to wait until after the pre-production period and complete the MITIA when the well is being converted to injection. Since the wells are pre-produced with the sleeve open and have direct TxIA communication, the production casing and surface casing are the 2 barriers to prevent an uncontrolled release, similar to the packerless ESP wells. Both the production and surface casings are tested to 3000 psi (30 min charted test) after installation, before drilling out the cmt shoe. Are the rig pressure tests of the production and surface casing sufficient to satisfy the requirements of CO 494 for pre-produced west sak injectors, or is an MITIA to test the tbg required? If an MITIA is required, could a temporary variance be obtained for the pre-production period for 1 J-118? The rig pressure test details for 1 J-118 are listed below for reference: T-PO details: Test hanger seals to 5000 psi for 10 minutes. Test tree w/5000 psi for 10 minutes. (3/19/07 drlg report) LEM Packer test: Bleed off and test back side of packer with 2500psi for 10 minutes. (3/18/07 drlg report) Prod csg MIT: Rig up and test 7-5/8" casing to 3000 PSI - 30 minutes. Record on chart. Good test. (2/18/07 drlg report) SC MIT: Tested 10 3/4" csg to 3,000 psi for 30 min, charted test. (2/11/07 drlg report) IC PO details: MU Vetco Gray threaded adapter flange, tested seals to 5,000 psi for 10 min and ck'd ok. (2/10/07 drlg report) Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617coocopilGps,com 2 oft 5/1!2007 11:29 AM ~~r~~~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # - ~, C~~~~~ ` ~, ~~~~ a ~. , Log Description ,'~ '~ ~? 03/05/07 NO. 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 02115/07 1 1R-08 11628971 INJECTION PROFILE 02115/07 1 1F-17 11638827 SBHP SURVEY 02/17/07 1 1F-14 11638826 SBHP SURVEY 02/17/07 1 1F-19 11638828 SBHP SURVEY 02119/07 1 1C-13 11628977 SBHP SURVEY 02119/07 1 1C-02 11628978 SBHP SURVEY 02/19/07 1 2M-02 11628979 INJECTION PROFILE 02/20107 1 3S-26 11638813 INJECTION PROFILE 01/21107 1 1C-121 11665391 INJECTION PROFILE 02/05/07 1 1J-180 11665390 USIT 02106/07 1 3J-14 11638825 PROD PROFILE 02116107 1 1J-118 11665392 USIT 02/22107 1 1D-11 11665393 INJECTION PROFILE 02/24107 1 2M-05 11665400 INJECTION PROFILE 03/01107 1 2M-04 11665399 INJECTION PROFILE 03/01107 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. s ,Qd~, RE: lJ-1 18 Intermediate Casing Bond Log Subject: RE: 1J-11~ Intermediate using bond Log Promo "Hartwig, Dennis D"Dennis.D.Hartwig@conocophillips.com> Date: Mon, 05 Mar 2007 12:12:23 -0900 To: Thomas. Maunder <torn maunder@adminatate.ak.us> Tom, 1.~-~l~s a~6_ ~~ ~ I sat down with Robin Smyth (schlumberger} this morning and revisited the USIT log from the 1J-118 Intermediate. Robin's interpretation is as follows; Excellent zonal isolation between the West-Sak Production Intervals ie...A2, B, & D (~ A2 top at Aproximately 8899'md ~ B top @ approximately 7763'md D D top at approximately 7201'md Further, @ Cement bond across the B window (7766-7779'md) was good, but not excellent and same for the D-window (7201-7214'md) QJ Zonal isolation Between the Upper West Sak (West Sak D - 7201'md) production interval and the Ugnu sands (Ugnu A - 6445'md) is excellent. ~ Zonal Isolation between the Ugnu Intervals including the upper most hydrocarbon contact (Ugnu C- 5485'md) is also excellent. o Ugnu Atop - 6445'md o Ugnu Btop - 6364'md o Ugnu Ctop - 5485'md O In excess of 500' of excellent cement bond above the Ugnu C. Your other question related to reciprocating the drill-string during cementation. It is my understanding that once the cement turned the corner no reciprocation was possible. Please contact me if t may provide further information. Regards... Dennis Dennis Hartwig Drilling Engineer ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 02, 2007 7:55 AM To: Hartwig, Dennis D Subject: Re: 1J-118 Intermediate Casing Bond Log 1 of 2 5/1/2007 11:20 AM RE: 1J-118 [ntermediate Casing Bond LoQ • Dennis, Thanks for the information. One item I am curious about is was the pipe reciprocated during cementing It says it was during the circulation. I will look forward to the Schlumberger interpretation you mention. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/1/2007 ~:Ol PM: «1J-118 Ops Report.pdf» «1J-118 Geo Morning Report.xls» «USIT_MAXTRAC_1 J-118_23-FEB-2007.zip» Tom, Attached is the Schlumberger USIT log for the 1 J-118 as well as the operations summary for 7 5/8" casing and cementation interval West Sak B-sand window is from 7766' - 7779' md. West Sak D-sand window will be from approximately 7201'- 7214' and t have also attached the latest Geologic summary which lists formation tops of the Ugnu Sands. (Top of Ugnu C at 5485'MD). I have a verbal interpretation of the log from Schlumberger, a formal interpretation is forthcoming. Regards...Dennis Dennis Hartwig Drilling engineer ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 2 of 2 5/ 1 /2007 11:20 AM ,. _.._.._ .............._................__.__...._........................._......_...._._._......................._..............................~............_....... . . . ~ ~ ....~..._................__....___.. _................._......_...............__.............. .._................_.........._.~._........_......_.___....._..._..._..._..__..........._......._..__._.._.._........_.~.~...._._..._........._...._................._......._.._...............__...._.._, ~~~~ ~ ~! ~ F ~ ~~+~~~~i~~i~r~ Daily Drilling Printed:3l1120~7 F Report ~ ~~~~ ~~~ ~~~r~~~~ ~ ~ ~~ ~~~~~ ~ ~ ~ ~~ . ~ .~ ~ . ,:. ~ yti~ , Well: Report Date: Job Tvpe: Network: Report # Daily Cost: C~~~*+ ~~~t• 1J-118 02/15/2007 DRILLING 10163824 11 : ORIGINAL Field: Riq Name: Rig Supervisor: Rig Accept: Rig Release: WEST SAK DOYON 141 Steve 2/6/200 7 6:00:00 ShultzlDearl AM 24 hr Summary- Continue BROOH to shoe. Pump Hi Visc weighted sweep, POOH lay down BHA. Rig up & run 7 5/8" casing. Summarv (c~ Rpt Time: Circulating & conditioning mud for cement job. 24 hr Forecast: Continue run 7 5!8" casing. Circulate & condition mud. Perform Cement job. Set casing in slips. ~~~ ~~., ..' ' ,~~,^~ \ ~ .:., ., ~; S ';. .. . ' ` n..R'R~d'9~':. '~ M~ 3 . .~ ~ ,„~~~~'. . 3R`P ~, i °,~~'~[{~~ r ~ : ' ~ „~~. ~ ~~ ~ ~ '. :''~, ~~~~ ~b c:s^`y^ S ~ ~ ~.1;~' , ."'ea:~,. . 00:00 04:15 425 INTRM1 DRILL REAM P Continue BROOH from 7575' - 3350'. Observed hole looked ood, and unloadin hole while back reamin . 04:15 05:00 0.75 INTRM1 DRILL CIRC P Pump Hi Visc weighted sweep at the shoe. Circulate until swee returned and well bore clean. 05:OQ 06:30 1.50 INTRMI DRfLL TRIP P Pump dry job, Bfow down lines & top drive. Continue POOH from 3350' - 350'. 06:30 07:15 0.75 INTRM1 DRILL PULD P Rig up. Lay down 5" HWDP, Drilling jars and NMDCs. Q7:15 08:00 0.75 IN1RM1 DRILL OTHR F' Plug in and download MWD assembly. 08:OQ 08:45 0.75 II~TRM1 DRII.L PULD P Continue breakout & lay down BHA. Inspect & grade bit to 3/6/WT/A/E/4/RG/TD 08:45 09:15 0.50 INTRM1 DRILL OTHR P Clean & clear rig floor area. Send tools outside. 09:1a 09:30 0.25 INTRM1 CASING OTHR P Rig up, BOLDS and pull wear bushing. 09:30 11:00 1.50 INTRM1 CASING RURD P Rig up to run 7 5/8" casing. 11:00 12:00 1.00 INTRM1 CASING RNCS P Held PJSM with crew. Discuss safety 7 hazard recognition issues. Make up shoe joint & threadlock 'oint. Make u tor ue 8000 ft/Ibs. Crew Chan e 12:00 14:00 2.00 INTRAl11 CASING RNCS P Continue make up shoe track assembly. Fill casing & check floats, floats held. Continue run casing to 1722'. make u tor ue - 8000 ft/Ibs. 14:00 14:45 0.75 INTRMI CASING RNCS NP POOH from 1722' - 1640'. Install 7 5/8" pup joint. 14:45 17:00 2.25 INTRMI CASING RNCS P Continue run 7 5/8" casing from 1640' - 3350'. 17:00 98:30 1.50 INTRM9 CASlNG CIRC P Circulate & condition mud at the shoe. pumps @ 4 BPM - 370 PSI. 18:30 00:00 5.50 INTRM1 CASING RNCS P Continue run 7 5/8" casing from 3350' - 7044'. Run 10 joints, circulate 1 joint down slow.Observe fair hole conditions working through a couple of spots 6620' and 6850'. Crew Chan e 24 hr Summary: Continue run 7 5/8" casing. Circulate & condition mud. Perform 220 BBL Cement job. Set casing in slips with 70K. Perform Injectivity test. flush ann, and freeze protect. Lay down all 5" Dp from derrick. Summarv Ca? Rpt Time: Picking up 4 1/2" Drillpipe from pipe shed. 24 hr Forecast: Pick up 4" DP with Super Sliders, and all DP needed for next lateral. RAck in derrick. MU BHA, TIH picking up DP. '>, ~• ~~~ '.. :. > ; , .,~... ~ , '.~~~. \'~ ~ ri . F'.i.~. ~ : .' .v_ <:. ~` . , ';~: `i.... ~~ .. <:~ , ci ..,.~ ~.,, k .~ ... '~. "~*. i *~a, . ~k ., , ~.~:; ~.~i. ~~y ~Q ~~ ~ 'G~~ ~~-1JVfA~ ~.e ~ i~ ~\ ~~i. ~.s Q0:00 02:30 2.50 INTRMI CASING RNCS P Continue run 7 5/8" casing from 7044' to tag bottom @ 8958'. Verify bottom observing hard tag & pressure increase. Work through tight spots @ 8827' - 8830'. SIMOPS: Rig up Dowell cemeters & fine up Vac trucks for OBM displacement. 02:30 03:45 1.25 INTRM1 CASING RNCS P Lay down joint # 210. Install 20' pup. Breakout & lay down Franks Fill up tool. Install 7 5/8" cement head & lines. 03:45 06:00 2.25 INTRM1 CEM~NT CiRC P Circulate & condition mud. Stage pumps to 6 BPM - 580 PSI. Reciprcate casing string in 20' increments.UP WT = 210K, SO WT = 65K. Pre cement mud = 9.0 PPG, YP-10, PV-12, Gels - 7!8/10. 06:00 07:30 1.50 INTRM1 CEMENT DISP P Tum rig over to Dowell. Pump 10 BBLS of CW100. Test lines to 3500 PSI. Pump 65 BBLS of CW100. Pump 75 BBLS of 11.0# Mud Push II, Drop Plug. Pump a total of 220.5 BBLS of 12.5 Tail Cement. Drop Plug, pump 2 BBLS water to flush lines to ri floor. 07:30 09:00 1.50 INTRM1 CEMENT DISP P Turn over to Rig pumps. Displace cement with 8.4 PPG MOBM @ 7 BPM, slowing pumps to 3 BPM, observe bumping plug with 4039 STKS (406 BBLS) with 1100 PSI. Pressure to 1600 PSI & hold for 5 minutes. Bleed pressure and check floats. Floafs held. CtP @ 0840 H RS. 09:00 09:30 0.50 INTRM1 CEMENT RURD P Rig down Cement head & lines. Nipple down BOP stack & wellhead. 09:30 09:45 0.25 INTRMI CASING RNCS P Set 7 5/8" Emergency slips as per Vteco Gray rep with 70K ulled on casin . 09:45 11:00 125 INTRM1 CASING RNCS P Rig up cutter & cut casing as per Vetco rep. Cut off ~oint = 11.67' as lanned in detail. Install ackoff. 11:00 12:00 1.00 INTRM1 CASING NUND P Nipple up wellhead & BOP stack. Crew Change 12:00 12:15 025 INTRM1 CASING DHEQ P Rig up lines to OA. Test packoff as per Vetco rep to 80% of burst 3850 PSI - 10 minutes. 12:15 12:30 0.25 INTRM1 CASING NUND P Install Turnbuckles on BOP stack. Air up riser boots. Clean cellar area. Ri u Little Red Services. • • 12:30 14 00 1.50 INTRM1 CASING CIRC P Perform Injectivity test pumping down OA, with chart picking MWE @ 11.5 PPG. Flush annulus with 40 BBLs of water, continuing to pump freeze protect diesel @ 2.75 BPM - 800 PSl when shut in. All pumping recorded on chart. SIMOPS: Rig up short bales on Top Drive, install mousehole, and ri u to la down 5" DP. 14:00 14:15 0.25 INTRM1 DRILL PULD P Install Wear bushing. RILDS. 14:15 17:00 2.75 INTRM1 DRILL PULD P Breakout & fay down 5" DP from the derrick. 17:00 17:45 0.75 INTRM1 DRILL Pt1LD P Pull thread protectors and tools to rig floor. 17:45 23:30 5.75 INTRM1 DRILL PU~D P Continue breakout & lay down 5" DP from the derrick.la ed down 90 stands total. SIMOPS: Level ri . 23:30 D0:00 0.50 INTRM1 DRILL OTHR P Change elevators, pick up 3 1/2" IF handling tools to rig floor. Crew Chan e ,... . ~~ ~y W.'"5~,.. ,,.'~~,.~3~~.....~ ~\~ ~~~;;_? kl..i.::i ,^~'~,..,z .'~.:.~'1r/.~ '„ ,~~„5~,y' „ „~,~,~. ; -. •. . .r:.-;",~y~ ...v:... ... ;~~4 ~1~ . .. ' ~ ~ ~ ~u X ,~r .~~ 5~e ly~}+'J~{~~ ~ ; ('~ ~y::~.~~ ~ '~~rxsv~ : Ll~~ ~ '~ ' p{J ~y ~~ €" Y ~: ~I- ~i ~ ~py ¢~Q~ i ' ~ S F~ ~,', ~` ~ Y ~~3~ y '1~V~ ~~ ~G' ~' mi~ , , ; „ , . .. . ....~:,,~., a.. .. _a..:: . .. : . ... . ,- . .. . . . i . . .. .. n. •. t ..n'v ~. z~," , ,t , . ... . . ~ :~eu. . .. ... , ~ ....; .. .. • ~~. 16:00 Oil Base Pit 8,950 8.5 OA 45.4 13 1.00 8.00 18.00 18.0 4.40 0.00. 23'GO Oil Base Pit 8,950 8.5 0.0 45.4 13 1.00 8.00 18.00 18.0 4.40 O.OQ r ,. ~ ~ y - ~; ~LAS81i OIL ~D ~.S C011TSERQATIOI~T COMI~IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk, West Sak Oil Pool 1J-118 ConocoPhillips (Alaska), Inc. Permit No: 206-176 Surface Location: 1914' FSL, 2366' FEL, Sec. 35, T11N, R10E, UM Bottomhole Location: 230' FSL, 2024' FWL, Sec. 24, T 11 N, R l OE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development 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 (paler). DATED this day of December, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoP~iillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email; Randy.L.ThomasC~conocophillips.com December 5, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~E~EIVEQ D F C 1 3 2006 Alaska Oil & Gas Cons. Commission Anchorage Re: Applications for Permit to Drill, West Sak Injector, iJ-118, 1J-118 L1, 1J-118 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a trilateral horizontal well in the West Sak "A2", "B"and "D" sands. The main bore of the well will be designated 1]- 118, and the lateral bores of the well will be designated 1J-118L1 and 1J-118L2. 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-118 is January 15, 2007. If you have any questions or require any further information, please contact David Nugent at 265-6862. Sincerely, ,~ ....~.,~\~-tit- s'°'~.+ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ l ~E~EIVED DEC 1 3 2006 PERMIT TO DRILL 20 AAC 2s.oos Alaska Oil & Gas Cons. Commission enehnraae 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^/ Development Gas ^ Multiple Zone^ Single Zone ^/ - 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-118 - 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14571' ND: 3920' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1914' FSL, 2366' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 ~ 25650 ^ West Sak Oil Pool ' Top of Productive Horizon: 706' FNL, 2278' FWL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471 8~ 468 13. Approximate Spud Date: 1/15/2007 Total Depth: 230' FSL, 2024' FWL, Sec. 24, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558844 y- 5945727 ' Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 D-138 , 961' 16. Deviated wells: Kickoff depth: 300 ~ tt. Maximum Hole Angle: g0° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1764 psig ' Surface: 1333 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' ' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3222' 28' 28' 3222' - 2200' ~ 560 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8338' 28' 28' 8338' ~ 3848' ~ 450 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 7148' 7423' 3694' 14571' . 3920' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DBVid Nugent @ 265-6862 Printed Name Rand-y--Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~~~~~~.~ ~ \~...~,,._..-._ - Phone ~~-,g~ ~~ SG, Date (~ ~ tv~~ ~ P nAl D k Commission Use Only Permit to Drill Number: ~, " ~?~p API Number: 50- O Z % ~ 23 33 7 ~ (~/ Permit Approval e Date: ~ ~:`, ~ ~ =~;i See cover letter for other requirements Conditions of approval : If box is checked, well ma not be used to explore for, test, or produce combedrm~ethane; gas hydrates, o s contained in shales: ©Q~ ~S`~ ~S~Q ~~~- G.S O ~G~.nv~~~ Samples req'd: Yes ^ No L~ M og r 'd: Yes ^ No [y]' Other: \ H2S measures: Yes ^ No ~ Dir n I svy q'd: Yes [~ No ^ \~~ ~^Q ~~" VCa~~ `p ~(~ ~ VED BY THE COMMISSION DATE j ~~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ubmit in Duplicate G' ~L . /f!. 04 ~~tN~~ • Ap~on for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 Permit It -West Sak Well #1J-118 Application for hermit to Dril/ Document kldximix~ Y1~11 YaluB Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC25.005 (fJ ......-• .......................................................................:....................... 2 2. Location Summary ..............................................................................................:.... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ...........: ...:....................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) •-• .............................................:.................................................. 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ....................................................... .......... 4 ........... Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information .....................................................:............................. 4 Requirements of 20 AAC 25.005(c)(7) ...........................................................•-•---...................:.............. 4 8. Drilling Fluid Program .............................................................. ..... 4 Requirements of 20 AAC 25.005(c)t'8) • ........................................................................:......................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ....................................................e...................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .......................:.......................................................................... 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10)....., ............................,.............................-.-............................. 5 11.Seabed Condition Analysis ........................................................:............................ 6 Requirements of 20 AAC 25.005 (c)(11) ...........................................................................................:.... 6 1J-118 PERMIT IT Page 1 of 8 Printed: 4-Dec-O6 ORIGINAL Ap~n for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 12. Evidence of Bonding ........................................................................... .......:........ 6 ... Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program .................................................... .... 6 ............................. Requirements of 20 AAC 25.005 (c)(13) ...........................................................:.................................... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ..................................:............................................................. 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan .....................................................................................:.......................... 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ...........................................................................•----..................._........... 8 Attachment 5 1/4 Mile Radius Effect for Injector ....................................:..........:.................:....8 1. Wetl Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 217 AAC.25. t740(b). For a we/l with mu/tip/e we/l branches, each branch must similarly be identifed by a unique name and API number by adding a suffix to the name designated for t/re well by the operator and to the number assigned to the we// by the COmmisS/On. The well for which this Application is submitted .will be designated as iJ-118. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri/1 must be accompanied by each of the fo/%w/ng /tams, except for an item already on fi/e with the commission and identified r'n the application; (2) a p/at identifying the property and the properly's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at tots/depth, referenced to governments/section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordnate system for this state as maintained 6y the Nations/ Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the propased depth of the we// at the top of each objective formation and at tots/ depth; Location at Surface _ 1,914' FSL, 2,366' FEL, Section 35, T11N, R10E ' ASPZone 9 NAD 27 Coordinates RKB Elevat/on 109.0' AMSL ' Northings: 5,945,727 Eastings: 558,844 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak °A2" Sand 706' FNL, 2,278' FWL, Section 36, Ti1N, R10E ASPZone 4 NAD27Coord/Hates Measured De th RKB: 8,338 Northings; 5,948,423 Eastings: 563,464 Tots/ l/erticalDe th, RKB: 3,848 Tots/ l/ertica/De th, SS.- 3,739 Location at Total De th 230' FSL, 2 024' FWL, Section 24, T11N, R10E ASP Zone 4 NAD 27 Coord/Hates MeaSUred De th, RKB.' 14, 571 ~' Northings: 5,954,637 Eastings: 563,156 Total l/ertica/De th, RKB; 3,920 Tots/ vertical De th, SS.• 3 811 1J-118 PERMIT /T Page 2 of 8 ®~ ~ ~ Printed: 4-Dec-06 ~~~L • Ap~n for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 and (ta) other information required by 20 AAC 25.Q5®(b}; Requirements of 20 AAC 25.050(b) Ifa wel/ is to be intentiona!/y deviated, the application for a Permit to Dril/ (Form .111-401) must (1J include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, inc/uding a{! adjacent wellbares within 200 feet of any portion raf the proposed well; Please see Attachment 1: Directional Plan and (2) for al! wef/s within 200 feet of the proposed we/!bore (A) list the names of the operators of those wells, 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 mai/; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Dril! must be accompanied by each of the fo/%wing items, except far an item already on file with the commission and identified in the application; (3) a diagram and description of the b/owout prevention equipment (f3CJPE) as required by 20 AAC 25..!135, 20 AAC 25.036, or 20 AAC 25.037, as applica6/e; An API 13-5/8" x 5,000 psi BOP stack- (RSRRA) will be utilized to drill and complete well iJ-118o For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permif to L)ril! must be accompanied by each of the fol/ow/ng items,.. except for an item already on file with the commission and identified in the application: (4) information on driffing hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sark pressure gradient. '_' The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is .1,333 psi, calculated thusly: MPSP = (3,920 ft TVD)(0.45 - 0.11 psi/ft) = 1,333 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. ^~ and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-118 Drilling Hazards Summary. 1J-118 PERMIT IT Page 3 of 8 Printed: 4-Dec-06 • Ap~n for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permif to Dri// must be accompanied by each of the fo!/owing items, except for an item a/ready on ~/e with the commission and identified m the application: (5) a description of the procedure far conducting formation integrity tests, as required under 20 AAC 25.030(f); iJ-118 will be completed with 7-5/8" intermediate casing landed at'the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhiHips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item a/ready on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC25.030, ands description of any slotted /finer, pre- perforated liner, or screen to be installed; Casing and Cementing Program ,~~~,~`~ See also Attachment 3: Cement Summary t ` l Hole Top Btm sg/Tbg Size Weigh Length MD/TVD MD/TVD D in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108. Cemented to surface with . 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 speciaF 3,222 28 / 28 3,222 /2,200 560 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 8,338 28 / 28 8,338 / 3,848 4.700' MD / 2,756' TVD. Cemented w/ 450 sx Dee CRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 7,148 7,423 / 3,694. .14,571 / 3,920' Slotted- no cement Slotted Lateral (iJ-118) B Sand 11.6 L-80 7,343 7,323 / 3,677. 14,666 / 3,774 Slotted- no Slotted .Lateral (1J-.118 Ll) 4-1/2 6-3/4" D Sand 11.6 L-$0 BTC 7,717 6,961 / 3,597 14,678 / 3,713 .Slotted- no cement Slotted Lateral (1J-118 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri!/ must be accompanied by each of the fn/lowing items, except for an item already on fi/e with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the ..drilling of iJ-118. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilliing Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to ,Uri1! must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description c?f the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-118 PERMIT IT Page 4 of 8 Printed: 4-Dec-06 • Surface Hote Mud Program (extended bentonite) Ap~n for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 S ud to Base of Permafrost Base of Permafrost to IO-3/4"Casin Point Initial Value Final Value Initial Value Final Value Density (PP9) 8.9 9.2 9.5 9.6 Funnel viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 cP Plastic Viscostiy 20 45 15 20 Ib/100 s PH 8.5 9.0 8.5 9.0 API Filt{ate NC 8 0 5 0 7 0 cc / 30 min . . . *9.6 ppg if hydrates are encountered ~ Intermediate Hole Mud Program (LSND) 10-3/4" Cs Shoe to 7-5/8" Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity seconds 45 - 60 Plastic Viscostiy Ib/100 s 12 - 18 Yield Point cP 26 - 35 API Filtrate cc / 30 min 4 - 6 Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) AIB/D sand laterals Value Densit pp 8.6 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18 - 28 cP HTHP Fluid loss (ml/30 min @ <4.0 200psi & 150° Oil /Water Ratio 70 / 30 Electrical >600 Stabilit ~ ~r Ct°~ f~~C:.~ ~~a ~ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with. the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to ®rr/l must be accompanied by each of the following items, except for an item already on file .with the commission and identified in the application: (9) for an exploratary or stratigraphic test we/l, a tabulation setting out the depths of predicted abnormafly geo pressured strata as requires! by 21J AAC25. tt33(t); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/icatian far a Permit to t~rifl must be accompanied by each of the fallowing items, except far an item already an fi/e with the commissian and identified in the application: (101 for an exploratary ar stratigraphic test well, a seismic refraction or reflection ana/ysis as required by Zf7 ft,QC 25.061(x),• Not applicable: Application is not for an exploratory or stratigraphic test well 1J-118 PERMIT IT .Page 5 of 8 Q ~ ~ ~ ~ ~ Printed: 4-Dec-06 Ap~n for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Oril/ must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the app/ication; - (X I) for a we!/ drilled from an offshore platform, mobile bottom-faunded structure, jack-up rrg, or tJoating drilling vess% an ana/ysis ofseabed conditions as required by 2f1 AAC25. tT61(bJ; 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 CJril/ must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the application; (12) evidence showing that the requirements of20AAC25.1125 {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 ®ril/ must be accompanied by each of the following items, except for an item already on frfe with the commission and identified in the application; The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install .cellar box, set and cement 20" x 34" insulated conductor to +/- i08' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4" Annular with 16"diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 3,222' MD / 2,200' TVD as per directional plan. Run MWD tools as required for directional monitoring.- 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required, 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test.. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment.. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 8,338' MD / 3,848' TVD, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with- mud (top of cement to be 4,700' MD / 2,756' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install. wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel 12. PU 6-3/4'° PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging 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. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 -ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 14,571' MD / 3,920' TVD as per directional plan. , 1J-118 PERMIT IT Page 6 of 8 Printed: 4-Dec-06 ORIGINAL • Ap~n for Permit to Drill, Well 1J-118 Revision No.O Saved: 4-Dec-06 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. ~- 16. Run USIT log for cement bond. ~~.ZS ~~~" 17. PU and run 4-1/2" slo ed liner. 18. Land liner, set liner hanger @ +/- 7,423' MD / 3,694' TVD. POOH. Note: Remaining .operations are covered under the 1J-118L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of +/- 7,323' MD / 3,677' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at +/- 14,666' MD / 3,774' TVD, as per directional .plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. ~(Q _ ~~~ 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly POOH. _ __v Note: Remaining operations are covered under the 1J-118L2 Application for Permit to Drill, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,961' MD / 3,597' TVD, the top of the D sand. 30. Mill 6-3/4"window.. POOH.. ~~ ~'- ~~~ 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH.- 32. Drill to TD of D sand lateral at +/- 14,678' MD / _3,713' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 39. POOH, laying down drill. pipe as required. 40. PU completion and ESP as required and RIH to depth. Land tubing. Set BPV. 41. Nipple down BOPE, nipple up tree and test. Pull BPV. ORIGINAL 1J-118 PERMIT IT Page 7 of 8 Printed: 4-Dec-O6 42. Freeze protect well with diesel. 43. Set BPV and move rig off. Ap~on for Permit to Drill, Well 1J-118 ~1' Revision No.O Saved: 5-Dec-06 14. Discussion of -Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/r""cation far a Permit to Drill must be accampanied by each of the following items, except far an item a/ready on fi/e with the cammission and identified in the application; (14) a genera/ description of haw the operator plans to disease of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.1180 far an annular dispasal aperation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids ' into a permitted annulus on i] Pad, or by hauling the fluids to a KRtJ Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1) 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 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic Attachment 5 % Mile Radius Scan 1J-118 PERMIT IT ®~ ~ ~ ~ Page 8 of 8 } Printed: 5-Dec-06 ~ ~ ConocoPhillips Alaska Co~ocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-118 1J-118 Local Coordinate Origin: Centered on Well Plan 1J-118 Viewing Datum: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet 1 ..:. ~... ~ ~... ...._.... ~.~ .;~ ,~~; ~~. - I Sperry Drilling Services ORIGINAL Halliburton Energy Services LLtR~r t Conoe aPhillips Planning Report -Geographic ortut~g a.,a Forn,actdn Alaska e~®t~®t~o~ I Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-118 Company: ConocoPhillips Alaska, Inc. TVD Reference: D Lyon 141 (28+81) @ 109.OOft (Doyen 141 (28+81)) ~ Project: Kuparuk River Unit MD Reference: Doyen 141 (28+81) @ 109.OOft (Doyen 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: 1 rue Well: Plan 1J-118 Survey Calculation Method: Minimum Curvature Wellbore: 1J-118 Design: 1J-118 (wp05) ct I:uparuk Rivcr Unit IJ ~rth I ~~ AL3sKa, iJnited States System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level )atum: NAD 1927 (NADCON CONUS) Using Well Reference Point ?one: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-118 Well Position +N/-S 0.00 ft Northing: 5,945,728.90 ft Latitude: 70° 15' 44.358" N +E/-W 0.00 ft Easting: 558,844.00 ft ' Longitude: 149° 31' 27.477" W Position Uncertainty 0.00 ft .Wellhead Elevation: ft .Ground Level: 0.00 ft Wellbore 1J-118 Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2005 11/18/2004 24.65 80.75 57,553 - ~~ Design .~-, 1 i 1 tf3 (wp051 Audit Notes: Version: 26 Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +Nl-S +E/-W Direction (ft) (ft) (ft) ("} 28.00 0.00 0.00 0.00 11/2/2006 9:51:11AM Page 2 of 7 COMPASS 2003.11 Build 50 ~~~~~~ • ConocoPhi[(ips Alaska Halliburton Energy Services Planning Report -Geographic L~ Drilling end Formation Evaluation Database: _EDM_2003.11_b48 Company: Conoco Phillips Alaska , Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J- 118 Wellbore: 1J-118 Design: 1J-118 (wp05) Plan Summary Measured Ve Dep[h Inclination Azimuth D 28.00 0.00 0.00 2 300.00 0.00 0.00 3 702.06 10.05 87.72 7 1,629.31 47.14 87.72 1,5 1,729.31 47.14 87.72 1,5 2,138.78 67.61 87.73 1,7 5,157.36 67.61 87.73 2,9 6,859.61 77.00 357.70 3,5 6,959.61 77.00 357.70 3,5 7,199.22 77.00 2.00 3,6 7,248.22 77.00 2.00 3,6 7,323.22 80.00 2.00 3,6 8,213.22 80.00 2.00 3,8 8,338.22 85.00 2.00 3, 8,358.22 85.00 2.00 3, 8,569.73 89.14. 352.25 3, 10,177.04 89.14 352.25 3, 10,309.31 88.81 358.86 3, 10,559.31 88.81 358.86 3, 10,583.60 89.15 359.51 3, 11,159.52. 89.15 359.51 3, 11,180.67 89.75 359.72 3, 12,258.73 89.75 359.72 3, 12,269.69 90.07 359.73 3, 13,058.87 90.07 359.73 3, 13,072.98 89.65 359.76 3, 13,724.99 89.65 359.76 3, 13,739.86 89.22 359.67 3, 14,459.20 89.22 359.67 3, 14,571.27 89.76 3.91 3, Local Co-ordinate Reference: z'.'ell Plan 1J-118 TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature rtical Dogleg Build Turn pth +N/-S +EI-W Rate Rate Rate ft) (ft) (ft) (°I100ft) (°1100ft) (°1100ft) 8.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.40 35.15 2.50 2.50 0.00 00.00 18.75 470.92 4.00 4.00 0.00 68.02 21.67 544.16 0.00 0.00 0.00 87.58 35:29 886.93 5.00 5.00 0.00 37.16 146.03 3,675.85 0.00 0.00 0.00 74.50 1,208.94 4,606.71 5.00 0.55 -5.29. 97.00 1,306.30 4,602.79 0.00 0.00 0.00 50.92 1,539.70 4,602.17 1.75 0.00 1.80 61.95 1,587.42 4,603.84 0.00 0.00 0.00 76.90 1,660.86 4,606.40 4.00 4.00' 0.00., 31.44 2,536.80 4,636.99 0.00 0.00 0.00 47.75 2,660.62 4,641.32 4.00 4.00 0.00 49.50 2,680.53 4,642.01 0.00 0.00 0.00 60.33 2,891.20 4,631.40 5.00 1.96 -4.61 84.44 4,483.66 4,414.79 0.00 0.00 0.00 86.81 4,615.44 4,404.55 5.00 -0.25 4.99 92.00 4,865.34 4,399.58 0.00 0.00. 0.00 92.43 4,889.63 4,399.23 3.00 1.39 2.66 01.00 5,465.45 4,394.26 0.00 0:00 0.00 01.20 5,486.61 4,394.12 3.00 2.82 1.01 06.00 6,564.64 4,388.85 0.00 0.00 0.00 06.02 6,575.60 4,388.80 3.00 3.00 0.11 05.00 7,364.77 4,385.10 0.00 0.00 0.00. 05.03 7,378.88 4,385.04. 3.00 -2.99 0.20 09.00 8,030.87 4,382.31 0.00 0.00 0.00 09.15 8,045.75 4,382.23 3.00 -2.93 -0.63 19.00 8,765.00 4,378.04 0.00. 0.00 0.00 20.00 8,876.99 4,381.54 3.82 0.49. e 0 0 8 8 8 8 8 8 8 9 9 9 9 9 9 9 9 9 3.79 9 TFO 0.00 0.00 87.72 0.00 0.00 0.02 0:00 -102.06 0.00 90.48 0.00 0.00 0.00 0.00 0.00 -67.26 0.00 92.92 0.00 62.41 0.00 19.71 0.00 2.04 0.00 176.18 0.00 -167.89 0.00 82.67 11/2/2006 9:51:11AM ORIGINAL COMPASS 2003.11 Build 50 Cono coPhillips Alaska Datahase: _EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 Wellbore: 1J-118 Design: 1J-118 (wp05) ~~ Plam~ed Survey 1 J-11c^^~ ai~ li;) Map Map MD I nclination Azimuth ND SSTVD +NI-5 +E/-W Northing Easting DLSEV Vert Section (ft) (~) (°) lft) (ft) (ft) lft) (~) (ft) (°I100it) Ift) 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,726.90 558,844.00 0.00 0.00 SHL: 1914' FS L, 2366' FEL - Sec35-T11 N-R10E - '" 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,726.90 558,844.00 0.00 0.00 702.06 10.05 87.72 700.00 591.00 1.40 35.15 5,945,728.57 558,879.13. 2.50 1:40 1,629.31 47.14 87.72 1,500.00 1,391.00 18.75 470.92 5,945,749.33 559,314.71. 4.00 18.75 1,642.55 47.14 87.72 1,509.00 1,400.00 19.14 480.61 5,945,749.79 559,324.40. 0.00 19.14. Base Perm 1,729.31 47.14 87.72 1,568.02 1,459.02 21.67 544.16 5,945,752.81 .559,387.92 0.00 21.67 .1,868.73 54.11. 87.72 1,656.40 1,547.40 25.95 651.78 5,945,757.94 559,495.50 5.00 25.95 T3 2,138.78 67.61 87.73 1,787.58 1,678.58 35,29 886.93 5,945,769:12 559,730.54 5.00 35.29 2,593.93 67.61 87.73 1,960.92 1,851.92 51.99 1,307.45 5,945,789.10 560,150.88 0.00 51.99 K15 3,221.71 67.61 87.73 2,200.00 2,091.00 75.02 1,887.47 5,945,816.66 560,730.64. 0.00 75.02 10 3/4" CSG 3222' MD, 2200' TVD: 1989' FSL, 479' FE L - Sec35-T11 N-R10E - 10 3/4" 3,269.23 67.61 87.73 2,218.10 2,109.10 76.76 1,931.37 5,945,818.75 560,774.53 0.00 76.76 T3 + 550 5,124.43 67.61 87.73 2,924.61 2,815.61 144.82 3,645.42 5,945,900.19 562,487.83 0.00. 144.82 Ugnu C 5,157.36 67.61 87.73 2,937.16 2,828.16 146.03 3,675.85 5,945,901.64 562,518.24. 0.00 146.03 5,737.52 64.74 56.10 3,176.55 3,067.55. 306.43 4,172.25 5,946,065.89 563,013.33 5.00 306.43 Ugnu B 5,921.10 65.24 45.98 3,254.33 3,145.33. 410.87 4,301.37 5,946,171.33 563,141.62 5.00. 410.87 Ugnu A 6,335,21 68.77 23.79 3,417.81 3,308.81 721.50 4,516.80 5,946,483.60 563,354.59 5.00 721.50 K13 6,815.56 76.19 359.80 3,564.29 3,455.29 1,166.10 4,607.64 5,946,928,86 563,441.95 5.00 1,166.10 WSAK D 6,859.61 77.00 357.70 3,574.50 3,465.50 1,208.94 4,606.71 5,946,971.68 563,440.68 5.00.. 1,208.94 6,959.61 77.00_ 357.70 3,597.00 3,488.00 1,306.30 4,602.79 5,947,069.00 563,436.00 0.00 1,306.30 1J-118 DTop 7,006.71 76.99 358.54 3,607.60 3,498.60 1,352.16 4,601.28 5,947,114.85 563,434.14 1.75 1,352.16 WSAK C 7,151.24 76.99 1.14 3,640.13 3,531.13 1,492.97 4,600.89 5,947,255.64 .563,432.64 1.75 1,492.97 WSAK B 7,199.22 77.00 2.00. 3,650.92 3,541.92 1,539.70 4,602.17 5,947,302.37 563,433.56 1:75 1,539.70 7,248.22 77.00 2.00 3,661.95 3,552.95 1,587.42 4,603.84 5,947,350.09 563,434.85 0.00 1,587.42 7,323.22 80.00 2.00 3,676.90 3,567.90 1,660.86 4,606.40. 5,947,423.54 563,436.84. 4.00 1,660.86 7,412.44 80.00 2.00 3,692.39 3,583.39 1,748.67 4,609.47 5,947,511.37 563,439.22 0.00 .1,748.67 WSAK A4 11/2/2006 9:51:11AM /'~ P(a~ge 4 of 7 COMPASS 2003.11 Build 50 Local Co-ordinate Reference: cVell Plan 1J-118 TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: F:linimum Curvature Halliburton Energy Services ~~~-rsv Planning Report -Geographic or•iinns and Formation Evaluation ,, Halliburton Energy Services al~L> Ins C011000PI11III 5 p Planning Report -Geographic ornttng era Forr.,eeto~ Alaska evalue~cion Database: _EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-118 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-118 Survey Calculation Method: P:linimum Curvature Wellbore; 1J-118 '. Design: 1J-118 (wp05) Planned Survey 1J-1 1: iwp05) ...Map Map MD Inclination Azimuth TVD SSTVD +NI-S +N-W Northing Easting DLSEV Vert Section (ftl (~) (') ift) ift) (ft) (ft) Ift) (ft) (,~/100ft) lft) 7,654.31 80.00 2.00 3,734.39 3,625.39 1,986.72 4,617.78 5,947,749.45 563,445.67 0.00 1,986.72 WSAK A3 8,213.22 80.00 2.00 3,831.44 3,722.44 2,536.80 4,636.99 5,948,299.62 563,460.58 0.00 2,536.80 8,223.61 80.42 2.00 3,833.21 3,724.21 2,547.04 4,637.35 5,948,309.85 563,460.86 4.00 2,547.04 WSAK A2 8,338.22 85.00 2.00 3,847.75 3,738.75 2,660.62 4,641.32 5,948,423.45 563,463.94 4.00 2,660.62 7 5l8" CSG 8 338' MD, 3848' TVD: 706' FNL, 2278' FWL - Sec38-T11N-R10E - 7 5/8" 8,346.31 85.00 2.00 .3,848.46 3,739.46 2,668.67 4,641.60 5,948,431.51 563,464.16 0.00 2,668.67 1J-118 wp05 Top A2 8,358.22 85.00 2.00 3,849.50 3,740.50 2,680.53 4,642.01 5,948,443.37 563,464.48 0.00. 2,680.53 8,569.73 89.14 352.25 3,860.33 3,751.33 2,891.20 4,631.40 5,948,653.92 563,452.23 5.00 2,891.20 8,707.59 89.14 352.25 3,862.40 3,753.40 3,027.79 4,612.82 5,948,790.35 563,432.58 0.00 3,027.79 1 J-118 wp05 T3 10,177.04 89.14 352.25 3,884.44 3,775.44 4,483.66 4,414.79 5,950,244.49 563,223-19 0.00 4,483.66 10,309.31 88.81 358.86 3,886.81 3,777.81 4,615.44 4,404.55 5,950,376.17 563,211.92 .5.00 4,615.44 10,559.31 88.81 358.86 3,892.00 3,783.00 4,865.34 4,399.58 5,950,626.00 563,205.00 0.00 4,865.34 1J-118 wp05 T4 8/1/06 10,583.60. 89.15 359.51 3,892.43 3,783.43 4,889.63 4,399.23 5,950,650.28 563,204.46 3.00 4,889.63 11,159.52 89.15 359.51 3,901.00 3,792.00 5,465.45 4,394.26 5,951,226.00 563,195.00 0.00 5,465.45. 1J-118 wp05 TS 8/1/06 11,180.67. 89.75 359.72 3,901.20 3,792.20 5,486.61 4,394.12 5,951,247.15 .563,194.69 3.00 5,486.61 12,258.73 89.75 359.72 3,906.00 3,797.00 6,564.64 4,388.85 5,952,325.00 563,181.00 0.00 6,564.64 1J-118 wp05 T6 8/1/06 12,269.69 90.07 359.73 3,906.02 3,797.02 6,575.60 4,388.80 5,952,335.96 563,180.86 3.00 6,575.60 13,058.87 90.07 359.73 3,905.00 3,796.00 7,364.77 4,385.10 5,953,125.00 563,171,00 0.00 7,364.77 1J-118 wp05 T7 8/1/06 13,072.98 89.65 359.76 3,905.03 3,796.03 7,378.88 4,385.04 5,953,139.11 563,170.83 3.00 7,378.88 13,724.99 89.65 359.76 3,909.00 3,800.00 8,030.87 4,382.31 5,953,791.00 563,163.00 0.00 8,030.87 1J-118 wp05 T8 8/1/06 13,739.86 89.22 359.67 3,909.15 3,800.15 8,045.75 4,382.23 5,953,805.87 563,162.81 3.00 8,045.75 14,459.20 89.22 359.67 3,919.00 3,810.00 8,765.00 4,378.04 5,954,525.00 563,153.00 0.00 8,765.00 1J-118 wp05 T9 8/1/06 14,571.27 89.76 3.91 3,920.00 3,811.00. 8,876.99 4,381.54 5,954,637.00 563,155.62 3.82.. 8,876.99 BHL 14571' MD, 3920' TVD: 230' FSL, 2024' FWL - Sec24-T11 N-R10E - 4 1/2" - 1J-118 A_Toe 8/1/06 - r 11/2/2006 9:51:11AM Page 5 of 7 COMPASS 2003.11 Build 50 ~~~'~,~~ r • r Cono~aPhillips Alaska I Database: EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 Wellk~ore: 1 J-118 Design: 1J-118 (wp05) Halliburton Energy Services Planning Report -Geographic LL16f 111 Grilling and Format€on Evaluation Local Co-ordinate Reference: Well Plan 1J-118 TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) MD Reference: Doyon 141 (28+81) @ 109.OOft(Doyon 141 (28+81)) North Reference: Tiue Survey Calculation Method: trlinimum Curvature Geologic Targets 1J-11c7 I ND ~ ;t. ,. 3,919.00 1J-118 wp05 T9 811106 - Point 3,920.00 1J-118 A Toe 811106 - Point 3,848.46 1J-118 wp45 Top A2 - Point 3,905.00 1J-118 wp05 T7 8!1106 - Point 3,906.00 iJ-118 wp05 T6 8/1/06 - Point 3,862.40 1J-118 wp05 T3 -Point 3,909.00 1J-118 wp05 T8 81V06 - Point 3,597.00 1J-118 Drop - Point 3,901.00 1J-118 wp05 T5 811/06 - Point 3,892.00 1J-118 wp45 74 811106 - Point +NI-S +EI-W Northing Eastiny ft ft (ft) (ft) 8,765.00 4,378.04 5,954,525.00 563,153.00 8,876.99 4,381.54 5,954,637.00 563,155.62 2,668.67 4,641.60 5,948,431.51 563,464.16 7,364.77 4,385.10 5,953,125.00 563,171.00 6,564.64 4,388.85 5,952,325.00 563,181.00 3,565.66. 4,539.66- 5,949,327.58 563,355.22 8,030.87 4,382.31 ' 5,953,791.00 563,163.00 1,306.30 4,602.79 5,947,069.00 563,436.00 5,465.45 4,394.26 5,951,226.00 563,195.00 4,865.34 4,399.58 5,950,626.00 563,205.00 i __ - -- --- Prognosed Casing Points - __ ___ ------- - Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (~~) (~~) 3,221.71 2,200.00 10-3/4 13-1 /2 8,338.16 3,847.75 7-5/8 9-7/8 14,571.26 3,920.00 4-1/2 6-314 11/2/2006 9:51:11AM Page 6 of 7 COMPASS 2003.11 Build 50 ~~~ ®1'I000PI'IIIIIpS Halliburton Energy Services ~ar~~~ n~ Planning Report -Geographic Oriiling and Formation Alaska Evacuation Database: _EDM_2003.11_b48 Local Co-ordinate Reference: l^.'ell Plan 1J-118 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: ;True Well: Plan 1J-118 Survey Calculation Method: F:linimum Curvature Wellbore: 1J-118 Design: 1J-118 (wp05) Prognosed Formation Intersection Points Measured Vertical Depth Inclinafion Azimuth Depth +Nl-E +E/-W (ft) (°~ ~°) (ft) lftl (ft) 1,642.55 47.14 87.72 1,509.00 19.14 480.61 1,868.73 54.11 87.72 1,656.40 25.95 651.78 2,593.93 67.61 87.73 1,960.92 51.99 1,307.45 3,269.23 67.61 87.73 2,218.10 76.76 .1,931.37 5,124.43 67.61 87.73 2,924.61 144.82 3,645.42 5,737.52 64.74 56.10 3,176.55 306.43 4,172.25 5,921.10 65.24 45.98 3,254.33 410.87 4,301.37 6,335.21 68.77 23.79 3,417.81 721.50 4,516.80 6,815.56 76.19 359.80 3,564.29 1,166.10 4,607.64 7,006.71 76.99 358.54 3,607.60 1;352.16 4,601.28 7,151.24 76.99 1.14 3,640.13 1,492.97 4,600.89 7,412.44 80.00 2.00 3,692.39 1,748.67 4,609.47 7,654.31 80.00 2,00 3,734,39 1,986.72 4,617.78 8,223.61 80.42 2.00 3,833.21 2,547.04 4,637.35 i~mr, Base Perm T3 K15 T3 + 550 Ugnu C Ugnu B Ugnu A K13 WSAK D WSAK C WSAK B WSAK A4 WSAK A3 WSAK A2 r Plan Annotations Measured Vertical Local Coordinates Depth Depth +N!-S +E/-W Comment (ft) (ft) (ft) (ft) 28.00 28.00 0.00 0.00 SHL: 1914' FSL, 2366' FEL - Sec35-T11N-R10E 3,221.71 2,200.00 75.02 1,887.47 10 3/4" CSG 3222' MD, 2200' TVD: 1989' FSL, 479' FEL - Sec35-T11 N-R10E 8,338.22 3,847.76 2,660.62 4,641.32 7 5/8" CSG 8338' MD, 3848' TVD: 706' FNL, 2278' FWL - Sec36-T11 N-R10E 14,571.26 3,920.00 8,876.98 .4,381.54 BHL 14571' MD, 3920' TVD: 230' FSL, 2024'. FWL - Sec24-T11 N-R10E 11/2/2006 9:51:11AM Page 7 of 7 COMPASS 2003.11 Build 50 ~~~~~~~ .~ 1J-118 illin Hazards Su~mar (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use wei hted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole l 7-S/8" Casing Interval 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 6-3/4" Open Hole / 4-1/2" Liner Interval 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 weight 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 ORIGINAL 1J-118 Drilling Hazards Summary prepared by David A. Nugent 12/4/2006 2:32 PM CemCADE Preliminary Job Design 10 3/4" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11/3/2006 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrieQslb.com < TOC at Surface ? Previous Csg. < 20", 91.5# casing at 80' fv1D < Base of Permafrost at 1,630' MD (1,400' N D) < Top of Tail at 2,422' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 3,222' MD (2,210' TV D) R 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 of 2,422' MD. Lead Slurry Minimum pump time: 230 min. (pump time plus 90 min.) ARCTICSET Lite @ i0.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 1.09.2 ft3 0.3637 ft3/ft x (1630' - 80') x 3.50 (250% excess) = 1973.1 ft3 0.3637 ft3/ft x (2421.7 - 1630' x 1.35 (35% excess) = 388.7 ft3 109.2 ft3 + 1973.1-ft3+ 388.7 ft = 2471 ft3 2471 ft3/ 4.45 ft3/sk = 555.3 sks Round up to 560 sks. Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time:- 160 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2..47 ft3/sk 0.3637 ft3/ft x (3221.7 - 2421.7) x 1.35 (35% excess) _ 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3/ 2.47 ft3/sk = 176.5 sks Round up to 180 sks BHST = 51 ~, Estimated BHCT = 66`1=. (BHST calculated using a gradient of 2.6/100 fte below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time .Cumulative Stage (bpm) Volume (min) Time (bbll fminl CW 100 5 50 10.0 10.0 Drop. Bottom Plug 15.0 25.0 MudPUSH 11 5 0 0.0 25.0 Lead Slurry 7 444 63.4 88.4 Tail Slurry 6 79 13.2 101.6 Drop Top Plug 8.0 109.6 Displacement 6 287 47.8 157.4 Slow Rate 3 15 5.0 162.4 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 1 per joint across zones of interest for proper cement placement. ORIGINAL CemCADE Preliminary Job Design 7.625" Intermediate Casing Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 11/3/2006 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com w ;, Previous Csg. ' < 10 3/4", 45.5# casing at 3,222' MD < Top of Tail at 4,700' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 8,338' MD (3,900' TV D) Preliminary Job Design based on limited input data. For estimate purposes only c~~mherger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 800' MD above target - (3638' MD annular length). Tail Slurry Minimum thickening time: 200 min. (Pump time plus 90 min.) DeepCRETE @ 12.5. ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3638' x 1.25 (25% excess) = 976.8 ft3 0.2578 ft3/ft x 80' (Shoe Joint) _ 20.6 ft3 976.8 ft3 + 20.6 ft3 = 997.4 ft3 997.4 ft3/ 2.25 ft3/sk = 443.3 sks Round up to 450 sks BHST = 95`F, Estimated BHCT = 79~. (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) (min) CW 1-00 5 30 6.0 6.0 Drop Bottom Plug 10.0 16.0 MudPUSH II 5 30 6.0 22.0 Tail Slurry 5 180 36.0 58.0 ' Drop Top Plug 10.0 68.0 Displacement 6 359 59.8 127.8 Slow Rate 3 20 6.7 134.5 MUD REMOVAL Recommended Mud Properties: 8.9 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 1 per joint across zones of interest for proper cement -placement. ~'8~61NAL • ' 'a/ ~' O .: 1 20" 94.0# x 34" Insulated Conductor, K-55, set at +/. 80' 10.3/4" x 4-1/2" Wellhead, S,OOD psi \~~~~ g 10-314", 68#, BTC DZ .,` '' 1~~- CMD Sliding Sleeve, w/ 3.81" DB Nipple, 72 deg, +/- 1 jt Shoe set @ 3222' MD, ~ above seals 2200' TVD , ~ ~* Casing Sealbore Receptacle, 20' Length Tubing String ~,.~ 4-1 /2" 12.6#, L-80, IBTM ~ Lateral Entry Module(LEM) 3.958" ID, 3.833" Drift ~''. / D-sand Window t ssso' MD, 3597• rvD 'D' Sand Lateral 5-112" X 7-5/8" ZXP Liner Top Packer wl Hold Seal Assembly ~'. 4.112" 11.6# L-80 Slotted Downs 4.75" Seal OD „~ Payzone ECP Liner Every Other Joint 4.1/2" X 7.518" Seal Bores Model'B' HOOK Hanger 3.68" ID 5.112" X 7.5/8" ZXP Liner Top Packer wl Hold Downs Tubing, 4.1/2", 12.6#, IBTM, Special Drift to +/_ 500' 3.875" DB Nipple, for Possible SSSV, +/.500' West Sak 7-5~8" Injector GLM, Camco KBG-2, 4-1/2" X 1" 1 ~ -118 r 1~'', GLM, Camco KBG-2, 4-1 /2" X 1", 70 deg, +/- 1 jt above Trl-Lateral Completion ' ~ °r--~- slidin sleeve ' ~ ,~. ~ ~ 4-112" Guide Shoe Lateral Entrv Module (LEMI e -~ Assembly fr ~ t~ 5-112" X 7-5/8" ZXP Liner Top z ~ 5 Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID OrienOng Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correll Location Seal Bore for Lateral Isolation - 3.66" ID Access Window PosiOve Laterel Access Via Thru-Tubing Diverter Seal Bore for Laterel Isolation - 3.65" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID r~~` ` 4-1 /2" Liner Shoe, 11.6#, L-80 BTC i 5-112" Tieback Sleeve y Set @ 14678' MD, 3713' TVD t4.1/2" bent muleshoe Seal Assembly 4.75" Seal OD ' . ,Lateral Entry Module(LEM) / ~~ B-sand Window Casing Sealbore at 7323' MD, 3677' TVD 'B' Sand Lateral Receptacle 20' Length ~ ~ ~ pa zone ECP 4-112" 11.6# L$0 Slotted .~~ y Liner Every Other Joint 4-112" X 7.518" - ,. Model'B' HOOK Hancer Seal Bore 3.68" ID 41/2" 12.6# Tubin~ 3.833" Drift 3.958" ID 5-1/2" X 7.5/8" : Liner TOp PaI with Hold Dm Liner Hanger /Packer Assembly at +/-7423' MD, 3694' TVD Ct~nr~c~ips b-112" Tieback Sleeve 4-112" bent muleshoe 3.562" DB Nipple pan ~~.^ NY611E5 Baker Oil Tools Lateral Entrv Module (LEMI With Diverter s and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Laterel Drift) (2.50° ID Mainbore Ddk) ' ' GS Profile for f lR tri in R i l Coil Connector ' ev 1 f unn ng e g ~1 (1.00 Length) I Snap In/Snap Out ~ reaek Pressure Valve d Positive Locafing ti i°} (1.60' Length) ~ Collet . ._ Lateral Isolation ~~ r Flow-Thm Swivel ~ Seals : ~ ' (1.25' Length) - ¢ ~ '. ~ Lateral Diverter ~ ~/ Hydreulic 1 Ramp ~ Disconnect f-- \l IsolatioN Mainbore (1.50' Length) J '\ Diverter Sleeve _ _ !~ GS Spear ~ ~~ (1.50' Length) Lateral Isolation J Seals 6.85 k Approx OAL• J~ I 1 'Jars may be required in highly deviated 18.5' Diverter Lengfh 18.5' Sleeve Length or deep applications (6' approx length). 1 Guide Shoe 4.1/2" Liner Shoe, 11.6#, L-80 BTC Set @ 1466x' MD, 3774' TVD Eauipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter. 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drill, w/diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module 5-1/2" X 7-5/8" `, Flex Lock Liner Hanger \ Casing Sealbore Receptacle, 20' Length 0 Baker Hughes 2005. This document may not be reproduced or dlstdbut¢d, In whol¢ or In part, In any form or by any means electronic or mechanical, including photocopying, recording, or by anX Informatlon storage and retrieval System now known or her¢ak¢r Inventetl, without written permission from Baker Hughes Inc. ~. ~ _ ~ ~„ {' Mainbore Drift: 3.65" ~7V( Ma re Drift, wl isolation sleeve: 2.50" Seal Assembly L al Drift, w/ coil diverter: 3.00" 4.75" Seal OD OD iverter and Sleeve: +l- 3.89" 'A' Sand Undulating Lateral Divertera Sleeve Length:+l-18.5' 4.112" 11.5# L-80 Slotted Liner Every Other Joint 4-112" Eccentric `.4 ~` Guide Shoe ~ ~ ~.,~ °`'~"""'"r"""'"y ~ ' J' 4-1 /2" Casing Shoe, 11.6#, L-60 B C ~r~ ,~, Set na 14571' MD, 3920' TVD " -5/8" 40# CasingTaer67Gp( Set at @ 8338' MD, 3848' TVD (85 deg) Wect Sak 7d/6" Td-lateral Completion -Infector November 1, 2008 Drawn By. Marc D. Kuck I • i• +~ar~t~ca~illi ~~~5~`~ ....,.~... _ :.. ~. _.._.. ~: r _.. ~; __ _ ~_ . -- ,....~ _ ..- -°. -- ---- -- - . -- - DriFling and Formation Evaluation Closest in POOL Closest A roach: Reference Well: 1J-11 8 L2 wp0.5 Plan Offset ell: 113-138 Coords. - Coords.- . ASP ASP 3-D ctr-ctr Meas: Subsea N(+)IS(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. TVD E + /W _ 0° Comments De th Incl. An le TRUE Azi. TVD E + /W - 0° Comments POOL Min Distance POOL Min Distance (960.72 ft) in POOL (960.72 ft) in POOL (6815.56 - 14678.45 (6815.56 - 14678.45 MD) to 1 J-118 L2 MD) to 1 D-138 (3558 (wp05) Plan (3558 - 980<72 14678.45 89.55 3,60 3604.345 5954774.9 563151.1 9013.886 4098.41 NDss) 6286.4 23.36 134.69 3860.188 5955699.8 563197.1 9936.832 4098.41 NDss) Closest Ap roach: Reference Well: 1J-118 L2 w 05 Plan sefi Well: 1 -141 L1 Coords. - Coords. - ASP ASP 3-D ctrctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. ND E + /N/ _ 0° Comments Depth Incl. An le TRUE Azi. TVD E + /W - 0° Comments POOL in istance POOL Min Distance (1084.38 ft) in POOL (1084.38 ft) in POOL (6815.56 - 14678.45 (6815.56 - 14678.45 MD) to 1J-118 L2 MD) to 1D-141L1 (wp05) Plan (5885 - 1084.38 14678.45 89.55 360 3604.345 5954774:9 863151.1 9013.886 (5885 - 9480 MD) 9480 89.69 181.54 3633.074 5954939.2 564222.5 9167.848 9480 MD) Closest Ap roach: Reference Well: 1J-118 L2 w 05 Plan C3ffset eNN: 1J-115 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. TVD E + /W _ 0° Comments Depth Incl. An le TRUE Azi. ND E + /W - 0° Comments POOL Min Distance POOL Min Distance (1105.11 ft) in POOL (1105.11 ft) in POOL {6815.56 - 14678.45 (6815.56 - 14678.45 MD) to 1J-118 L2 MD) to 1J-115 L1 (wp05) Plan (6085 - 1105.11 6875 77 357.7 3469.27 5946986.8 563440.3 1223.783. (6085 - 10702.84 MD) 6106.21 77.01 355.82 3447.429 5946947.3 562336.1 1192.952 10702.84 MD) Closest A roach: Reference Well: 1J-118 L2 w 05 Plan Offset ell: 1~3 -1#1L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. An le TRUE Azi. ND E + /N/ _ 0° Comments Depth Incl. An le TRUE Azi. ND E + /W - 0° Comments POOL in istance POOL Min Distance (1243.79 ft) in POOL (1243.79 ft) in POOL (6815.56 - 14678.45 (6815.56 - 14678.45 MD) to 1J-118 L2 MD) to 1 D-102L1 (wp05) Plan (4762 - 1243J9 14678.45 89.55 360 3604.345 5954774.9 563151.1 9013.886 (4762 - 7407 MD) 7407 93.58 . 175.35 3545.093 5955461 562115.3. 9706.971 7407 MD) POOL Summary118.x1s 11/2/2006 4:15 PM 1ZE: [Fwd: 7-S18" Cement Record--1J-11S] • • Subject: RE: [Fwd: 7-5/8" Cement Record--1J-115] From: "Greener, Mike R." <Mike.R.Greener@conocophillips.coln> Date: Wed, 20 Dec 200613:31:57 -0900 'I'o: Thomas Viaunder ~ =tommaunder(u;admin.state.ak.us--. "Reilly, Patrick .~" Patrick.J.Rcill~i~'conocophilliPs.com=~~- CC: "T~honu~s, Randy L" <Randy.L,Thomas(a conocophiilips.com=~ Here is tl~e daily reports. I am still trying to get the cement report in a format to send to you. It wrill be coming. -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, December 20, 2006 1:24 PM To: Greener, Mike R.; Reilly, Patrick J Cc: Thomas, Randy L Subject: [Fwd: 7-5/8" Cement Record--iJ-115] All, I am taking the shotgun approach here. I haven't heard back from David so I wanted to make sure someone was checking on this information. Thanks, Tom Maunder, PE AOGCC -------- Original Message -------- Subject:7-5/8" Cement Record--1J-115 Date:Tue, 19 Dec 2006 16:25:04 -0900 From:Thomas Maunder <tom maunder~u?admin.state.ak.us> Organization:State of Alaska To:David Nugent <Da~ricl.A.Nu~ent~conocophillis.com> David, I am reviewing the application for 1J-118. Since this is an injector, I need to review the wells within 1/4 mile that penetrate the WS. I have been able to do all wells except 1J-115. I don't believe the 407 has been filed yet, at least it is not in our file. I was wondering if you could send some sort of summary regarding that cement job. Essentially I like to see the last bit of drilling and then the operations up through the next LOT. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: 1J-115 intermediate.pdf 1J-115 intermediate.pdf Content-Type: application octet-stream 'Content-Encoding: base64 1 of 1 12/21/2006 1:03 PM C7 r - - - ~--. SHARON K. ALLSUP-DRAKE 1165 CONOCOPHILLIPS ATO i 530 / ~~~,~j 700 G ST. DaTE ~ ( ~u'' ~ ~`" ss-Ts51/44~ i ANCHORAGE AK 99501 PAY TO THE G ~ /~O ~ D ST~Tc F ~~5,~ d ~~~~~ ORDER Of / ! ,,pp,, ~ ~ ~~ ~ ~ ! ,_ ~c / DOLLARS U ~~..,.., ~~,~ JPMorganChase ~ valid uP TO 500o u0uars JPMorgan Chase Bank, N.A. Columbus, OH ` ~~~ ~ ~ ~P MEMO --- -- ---- - --- I ~:044LL55LL~:528747L90792711'LL65 ~, ~~ T'R..~~i Si®'IIT'~':~~., UTTER C'HEC'KI,I~T ~evedopment f Ser`~ice Expdoratory~ Stratigraphic Test lion-Conventional W"ell C'irede .-~~propriate better /Paragraphs to be dncls:ded in Transmittal Letter CHECK .=ADD-OwS TEXT FOR ~PPROVaL LETTER W'H1AT (OPTIONS j APPLIES ~~ MULTI LATERAL ~ The permit is for a new wellbore segment of existing well ;' (If last two digits API number in ! Permit No. .:API No. ~0- - - . between 60-69) are ,Production should continue to be reported as a function of the original AP[ number stated above. PILOT HOLE In accordance with 20 A.AC 25.00~(f), all records, data and logs 'acquired for the pilot hole mint be clearly differentiated in both well name ( PH) and API number '~ (~0- - -_~ from records, data and logs '. ~ ~ acquired for well !~ SPACI?vG !The permit is approved subject to full compliance with ?0 AAC 'EXCEPTION ~ 2~.0>j. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing ;' exception. assumes the liability of any protest to the spacing exception that may occur. ;DRY DITCH ;All dry ditch sample sets submitted to the Commission must be in '~ i SAMPLE no greater than 30' sample intervals from below the permafrost or ' ;from where samples are first caught and 10' sample intervals through target zones. r ion-Conventional 'Please note the following special condition of this permit: ;production or production testing of coal bed methane is- not allowed 'Well 'for (name of well) until after (Com~anv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Companv Name) must contact the Commission to obtain advance approval of such water well testing j Rev: ! 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'm '°' ° Q p c Q ,o o f v ° ~ ~ 7 ,7 ° = ~ C ° ~ ~ ~ N a ~ ~ m fp ~ ~-I ~ w o, - ;3 3 3 ' o ° ,~ 9 ~ ,~ c m ~ ,Q ,p o c~ ~~ o C y 7 ,p ,~ ~ .m ,o a ~ .o a Z T. ~ ~ ° m N N m A ~ ~ ~ ~ , . ~-. ~ .o ~ a ~ i o o ~° ~ m <' ,~ 3 ~ ~ it ° ~ ~ °~ ~y 7 ~ ~ ~~ y a ~ ,m ~sp ~ ~ c„~ m 'a ,Q ° m ° ° o ~ y ~°~ - ~ o r , .y ~ .y w y m .z 3 ° a 'v w 2~ ? ~ ° ~ y a ~ T v _ ~ ~ ; io fD z 7 ~ ~ ~ ~ ~ ~ ~ ~ ~ 3 ~ ~ 7 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o ~, 7 ... n V+ ~ N ~ ~ ~ ,O ' ' ' ' ~ D m m D D '01 'V+ m o m m m m 'y ~ 'y 'y 'y 'y m m 'y 'y m y m D m m o o m ,y ~ 'y Qp ~ 'y ~ 'y o m m m ,y ~y ,y m m m m m o m m m m m y ~y ~y Rp 'y ~ 'y 'y ~y 'y ,y m m ~y ~y ~~ ~ ~ ~~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ x ~ ,N .D w ,a ~ o 'D D ~ ,~ D ~ ~ m ~ c c Z x- a a m ~ ,f0 ,N .x ,x -~ 7- v ~ w ' ~ ~ 7 fl a , a. p m D ~ m ,~ cn m ~ c ,~ m a. °- c _ ~ .o' ~ o y 'o rn ~~ ° Z . • O (p O ,p ~~ ,y ~ ~L ~ ~ ~ ~ ~ ~Q ~ ip ~ ,~- ~~ 7 ~ O ,N ~ ~ ~ Q ~V1 7 (D 7 ~ pp C 'C ~fD ~ W p ~ ~ W ° ~ ,~. ~ y j y ~ ''~ ~p1 ~~ Z N O ~~ ~p fn 'p O D -I 3 n p .y ~N• ~ ~~ ~~ ~ W 3 ~ ° ~ ,. p .o ~~ ~ ,~ ~ ,Q ,O ~ ~ ~ , ~ ~ ~ U ,N y ~y ~ '° C ~ 7 Q- BOO ~ O a ~ ~ N p' ,~ ~ ~ j ,8 ~ ,n ~ ~ .O ~N ,W ~ ~ < ~. ~ ~~ ~~ ~ ~ a ` a D ~ , N (D ~ C ~ ~Q O ~ ~ ~ ,y ~ 7 ,~ ,, ,v < O ~ ~ ~ ~ ~ 7 y ~ ~~ 3 ~ O ~ x ~ ~ N '~ ' ~-~ , p ~~ ~ y ~ ~ ~ ~ ~ ~ ~ 'v ~ ~ ~y = LO ~ , ~ , 7 ~ co ° ~ 4D ~Q ~ ~ ~ ~~ ~ .3 ~ dD ~ ~ ~ ~ i ~ ~ ~~p ,~ ~ ° 7 .3 ~ ~ ~ O - (D ,ry dD ~ N ~ ~ ~y ~O (D ~ ~_ ~ ~ 7 ~ ,n ~ Q ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ p 7 N ~~ Q ~j Q U1 W ~ ~ N (D ,O ,7 ~ yy. ° ~~ ~ v ~ ,~ ~ ~ ~ ~ ~° ~ ~~ ,A ~ ~ ~~ O ~~ O ~-I 41 d ~~ ~ 7 ~ ~ V ~ ~~ ~ ~ ~~p ~~ ~ y ~ y ~ ~ i ~Q N ~ ~ ~ . ~~ ~ ~ ~ ~ A ~ ~ a Q 7 ~~ ~ ~~ 0 fD ~ r ~~ ~ ,gyp co ~ ~ y c 3 ~ - ~~ ~~ ~° ~~ ~, ~~ ~c ,~ r' ~ ~ ,~ ~ v ~W ~ D ~p . ~ ~ a ' ' ~~ ~ ' N ~ N 1 ~ ~O (D N ~ 7 ~ y ~~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ,~ ~ ~~ ~ ~ ~ ~ .'f7 n~ ~ 3 v Q ,j a ,rn y ~ 7 d '° 7 'O o • ~ ~ o ~ , ~ ~° ,° g ~ v ~ ~ v v ~ ; ~ ~ I , n Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1J118PB1O02142007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 21 09:29:11 2007 Reel Header Service name ............. LISTPE Date . ................... 07/05/21 Ori9in ................... STs Reel Name. .... ........ UNKNOWN continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Tape Header Service name ............. LISTPE Date . ................... 07/05/21 Origin ................... STS Tape Name. .... ........ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. 5T5 LIS Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA writing Library. writing Library. • scientific Technical services Scientific Technical Services 1]-118 P61 500292333770 ConocoPhillips Alaska, Inc Sperry Drilling Services 21-MAY-07 MWD RUN 2 JOB NUMBER: w-0004884845 LOGGING ENGINEER: R. REPLOGLE OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 11N l0E 1914 2366 109.00 81.00 WELL CASING RECORD Page 1 adCo -- l ~~O ~' t51~-.1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J118PB1o021420075SN.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 3358.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DG R) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2 REPRESENT WELL 1J-118 PBl WITH API#: 50-029-23337-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8982'MD/3861'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.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY Page 2 17118PB100214200755N.txt PBU TOOL CODE START DEPTH STOP DEPTH GR 3318.0 8935.0 RPD 3340.0 8927.5 RPM 3340.0 8927.5 RPS 3340.0 8927.5 RPX 3340.0 8927.5 FET 3340.0 8927.5 ROP 3366.5 8982.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3318.0 8982.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 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 3318 8982 6150 11329 3318 8982 RPD MWD OHMM 1.98 2000 19.6383 11176 3340 8927.5 RPM MWD OHMM 2.9 1766.9 13.5548 11176 3340 8927.5 RPS MWD OHMM 1.08 1764.47 13.2531 11176 3340 8927.5 RPX MWD OHMM 0.99 1786.61 12.4245 11176 3340 8927.5 FET MWD HOUR 0.17 62.12 0.998628 11176 3340 8927.5 GR MwD API 20.82 156.11 73.0832 11235 3318 8935 ROP MWD FT/H 2.74 417.03 197.286 11232 3366.5 8982 First Reading For Entire File..........3318 Last Reading For Entire File...........8982 Page 3 i • 17118P61o021420075SN.txt File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3318.0 RPD 3340.0 RPM 3340.0 RPS 3340.0 RPX 3340.0 FET 3340.0 ROP 3366.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 STOP DEPTH 8935.0 8927.5 8927.5 8927.5 8927.5 8927.5 8982.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA 14-FEB-07 Insite 74.11 Memory 8982.0 3365.0 8982.0 64.1 89.5 TOOL NUMBER 124724 228272 Page 4 i • 17118P6100214200755N.txt OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3358.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 93.200 .O MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MwD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3318 8982 6150 11329 3318 8982 RPD MwD020 OHMM 1.98 2000 19.6383 11176 3340 8927.5 RPM MwD020 OHMM 2.9 1766.9 13.5548 11176 3340 8927.5 RPS MWD020 OHMM 1.08 1764.47 13.2531 11176 3340 8927.5 RPX MWD020 OHMM 0.99 1786.61 12.4245 11176 3340 8927.5 FET MWD020 HOUR 0.17 62.12 0.998628 11176 3340 8927.5 GR MWD020 API 20.82 156.11 73.0832 11235 3318 8935 ROP MWD020 FT/H 2.74 417.03 197.286 11232 3366.5 8982 Page 5 17118PB1o0214200755N.txt First Reading For Entire File..........3318 Last Reading For Entire File...........8982 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 gate of Generation.......07/05/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF Tape Trailer service name .............LISTPE gate . ...................07/05/21 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ....................07/05/21 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File • Scientific Technical Services Scientific Technical Services Page 6 h 1J118PB200219200755N.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 21 12:10:36 2007 Reel Header Service name .............LISTPE Date . ...................07/05/21 Ori 9in ...................STs Reei Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library Tape Header Service name .............LISTPE Date . ...................07/05/21 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Scientific Technical services Scientific Technical services 1J-118 P62 500292333771 ConocoPhillips Alaska, Inc Sperry Drilling Services 21-MAY-07 MWD RUN 2 MWD RUN 3 MWD RUN 4 w-0004884845 w-0004884845 w-0004884845 R. REPLOGLE R. REPLOGLE R. REPLOGLE D. GLADDEN D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 35 11N l0E 1914 2366 109.00 81.00 Page 1 • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J118PB2o0219200755N.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 3358.0 6.750 7.625 8949.0 • 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 1J-118 PB1 WELLBORE AT 8650'MD/3843'TVD, WITHIN THE MWD RUN 2 INTERVAL. 4, MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (G P). 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 1-4 REPRESENT WELL 1J-118 PB2 WITH API#: 50-029-23337-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11846'MD/3903'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.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record Page 2 :7 FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 17118PB200219200755N.txt 1 L~ clipped curves; all bit runs merged. .5000 START DEPTH 3318.0 3340.0 3340.0 3340.0 3340.0 3340.0 3366.5 STOP DEPTH 11788.0 11795.5 11795.5 11795.5 11795.5 11795.5 11846.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 3318.0 8650.0 MwD 3 8650.5 8950.0 MwD 4 8950.0 11846.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 3318 11846 7582 17057 3318 RPD MWD OHMM 0.02 2000 30.8536 16904 3340 RPM MWD OHMM 0.06 2000 20.7177 16904 3340 RPS MWD OHMM 0.06 1764.47 18.983 16904 3340 Page 3 Last Reading 11846 11795.5 11795.5 11795.5 • 1]118PB2o02192007SSN.txt RPX MWD OHMM 0.05 1786.61 18.4941 16904 3340 11795.5 FET MWD HOUR 0.17 82.8 1.36773 16904 3340 11795.5 GR MWD API 20.82 156.11 69.7582 16941 3318 11788 ROP MWD FT/H 0.39 417.03 191.223 16960 3366.5 11846 First Reading For Entire File..........3318 Last Reading For Entire File...........11846 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 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.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3318.0 8650.0 FET 3340.0 8650.0 RPX 3340.0 8650.0 RPS 3340.0 8650.0 RPM 3340.0 8650.0 RPD 3340.0 8650.0 RoP 3366.5 8650.0 LOG HEADER DATA DATE LOGGED: 14-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8650.0 TOP LOG INTERVAL (FT): 3365.0 BOTTOM LOG INTERVAL (FT): 8650.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.1 Page 4 17118P62002192007SSN.txt MAXIMUM ANGLE: 89.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3358.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 70.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 MUD AT MAX CIRCULATING TERMPERATURE: 93.200 MUD FILTRATE AT MT: 6.500 MUD CAKE AT MT: 2.800 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 MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 3318 8650 5984 10665 Page 5 63.0 .0 63.0 63.0 First Last Reading Reading 3318 8650 • 17118P6200219200755N.txt RPD MWD020 OHMM 1.98 2000 20.2657 10621 3340 8650 RPM MWD020 OHMM 2.9 1766.9 13.8837 10621 3340 8650 RPS MWD020 OHMM 1.08 1764.47 13.5768 10621 3340 8650 RPX MWD020 OHMM 0.99 1786.61 12.7199 10621 3340 8650 FET MWD020 HOUR 0.17 62.12 1.00428 10621 3340 8650 GR MWD020 API 20.82 156.11 72.2121 10665 3318 8650 ROP MWD020 FT/H 2.74 417.03 200.426 10568 3366.5 8650 First Reading For Entire File..........3318 Last Reading For Entire File...........8650 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLiB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8650.5 8895.0 RPS 8650.5 8895.0 GR 8650.5 8903.0 RPx 8650.5 8895.0 RPM 8650.5 8895.0 RPD 8650.5 8895.0 ROP 8650.5 8950.0 LOG HEADER DATA DATE LOGGED: 15-FEB-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8950.0 TOP LOG INTERVAL (FT): 8650.0 BOTTOM LOG INTERVAL (FT): 8950.0 Page 6 • BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 • 17118PB200219200755N.txt BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 81.6 87.9 TOOL NUMBER 124724 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3358.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 70.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 92.3 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 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 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 Page 7 CJ 1]118P62o02192007SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8650.5 8950 8800.25 600 8650.5 8950 RPD MWD030 OHMM 5.46 23.09 8.03949 490 8650.5 8895 RPM MWD030 OHMM 5.02 15.42 6.87753 490 8650.5 8895 RPS MWD030 OHMM 5.06 12.64 6.4129 490 8650.5 8895 RPX MWD030 OHMM 4.91 12.51 6.0409 490 8650.5 8895 FET MWD030 HOUR 0.88 11.22 1.21957 490 8650.5 8895 GR MWD030 API 64.1 105.23 90.2226 506 8650.5 8903 ROP MWD030 FT/H 0.39 257.71 86.854 600 8650.5 8950 First Reading For Entire File..........8650.5 Last Reading For Entire File...........8950 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8899.5 11795.5 RPx 8899.5 11795.5 RPD 8899.5 11795.5 FET 8899.5 11795.5 RPS 8899.5 11795.5 GR 8903.5 11788.0 ROP 8950.5 11846.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Page 8 19-FEB-07 Insite 74.11 Memory • 17118P62o021920075SN.txt TD DRILLER (FT): 11846.0 TOP LOG INTERVAL (FT): 8950.0 BOTTOM LOG INTERVAL (FT): 11846.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.3 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8949.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 82.0 MUD PH: .O MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 120.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging 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 Page 9 • 1~118P62002192007SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8899.5 11846 10372.8 5894 8899.5 11846 RPD MWD040 OHMM 0.02 2000 52.1955 5793 8899.5 11795.5 RPM MWD040 OHMM 0.06 2000 34.418 5793 8899.5 11795.5 RPS MWD040 OHMM 0.06 95.28 29.9581 5793 8899.5 11795.5 RPX MWD040 OHMM 0.05 67.43 30.1342 5793 8899.5 11795.5 FET MwD040 HOUR 0.19 82.8 2.04661 5793 8899.5 11795.5 GR MWD040 API 31.44 107.01 63.4279 5770 8903.5 11788 ROP MWD040 FT/H 2.27 347.15 185.244 5792 8950.5 11846 First Reading For Entire File..........8899.5 Last Reading For Entire File...........11846 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/21 origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date . ...................07/05/21 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services End Of LIS File Page 10 1J118002212007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 18 14:05:15 2007 Reel Header Service name .............LISTPE Date . ...................07/05/18 Ori 9in ...................5T5 Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/05/18 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Scientific Technical services Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: 1J-118 API NUMBER: 500292333700 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Systems TAPE CREATION DATE: 18-MAY-07 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004884845 W-0004884845 W-0004884845 LOGGING ENGINEER: R. REPLOGLE R. REPLOGLE R. REPLOGLE OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 5 JOB NUMBER: w-0004884845 LOGGING ENGINEER: R. REPLOGLE OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1914 FEL: 2366 FWL: Page 1 ~o~' c~-~ #~sigo ~. ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J11800221200755N.txt 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3358.0 2ND STRING 6.750 7.625 8949.0 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 1J-118 PB2 WELLBORE AT 11680'MD/3910'TVD, WITHIN THE MWD RUN 4 INTERVAL. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4 & 5 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1-5 REPRESENT WELL 1J-118 WITH API#: 50-029-23337-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14698'MD/3958'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.......07/05/18 Page 2 17118002212007SSN.txt Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3318.0 3340.0 3340.0 3340.0 3340.0 3340.0 3366.5 STOP DEPTH 14640.0 14647.5 14647.5 14647.5 14647.5 14647.5 14698.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 3318.0 3 8650.5 4 8950.0 5 11680.5 REMARKS: MERGED MAIN PASS. MERGE BASE 8650.0 8950.0 11680.0 14698.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 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 Page 3 1711800221200755N.txt First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3318 14698 9008 22761 3318 14698 RPD MWD OHMM 0.02 2000 28.5817 22608 3340 14647.5 RPM MWD OHMM 0.06 2000 20.7278 22608 3340 14647.5 RPS MWD OHMM 0.06 1764.47 18.4536 22608 3340 14647.5 RPX MWD OHMM 0.05 1786.61 17.987 22608 3340 14647.5 FET MWD HOUR 0.17 82.8 1.18463 22608 3340 14647.5 GR MWD API 20.82 156.11 71.5529 22645 3318 14640 ROP MWD FT/H 0.39 417.03 177.01 22664 3366.5 14698 First Reading For Entire File..........3318 Last Reading For Entire File...........14698 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3318.0 8650.0 RPD 3340.0 8650.0 RPM 3340.0 8650.0 RPx 3340.0 8650.0 RPS 3340.0 8650.0 FET 3340.0 8650.0 ROP 3366.5 8650.0 LOG HEADER DATA DATE LOGGED: 14-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 4 TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17118002212007SSN.txt 8650.0 3365.0 8650.0 64.1 89.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3358.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 70.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 93.200 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 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 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Page 5 i • 171180022120075SN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3318 8650 5984 10665 3318 8650 RPD MWD020 OHMM 1.98 2000 20.2657 10621 3340 8650 RPM MWD020 OHMM 2.9 1766.9 13.8837 10621 3340 8650 RPS MWD020 OHMM 1.08 1764.47 13.5768 10621 3340 8650 RPX MWD020 OHMM 0.99 1786.61 12.7199 10621 3340 8650 FET MWD020 HOUR 0.17 62.12 1.00428 10621 3340 8650 GR MWD020 API 20.82 156.11 72.2121 10665 3318 8650 ROP MWD020 FT/H 2.74 417.03 200.426 10568 3366.5 8650 First Reading For Entire File..........3318 Last Reading For Entire File...........8650 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 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.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 8650.5 8895.0 FET 8650.5 8895.0 ROP 8650.5 8950.0 GR 8650.5 8903.0 RPM 8650.5 8895.0 RPD 8650.5 8895.0 RPS 8650.5 8895.0 LOG HEADER DATA DATE LOGGED: 15-FEB-07 SOFTWARE Page 6 ~ ~ 17118002212007SSN.txt SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8950.0 TOP LOG INTERVAL (FT): 8650.0 BOTTOM LOG INTERVAL (FT): 8950.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.6 MAXIMUM ANGLE: 87.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3358.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 70.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 92.3 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 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 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 Page 7 17118002212 007SSN.txt 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 8650.5 8950 8800.25 600 8650.5 8950 RPD MwD030 OHMM 5.46 23.09 8.03949 490 8650.5 8895 RPM MwD030 OHMM 5.02 15.42 6.87753 490 8650.5 8895 RPS MWD030 OHMM 5.06 12.64 6.4129 490 8650.5 8895 RPX MWD030 OHMM 4.91 12.51 6.0409 490 8650.5 8895 FET MwD030 HOUR 0.88 11.22 1.21957 490 8650.5 8895 GR MwD030 API 64.1 105.23 90.2226 506 8650.5 8903 ROP MWD030 FT/H 0.39 257.71 86.854 600 8650.5 8950 First Reading For Entire File..........8650.5 Last Reading For Entire File...........8950 File Trailer Service name... .......STSLIB.003 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 8899.5 11680.0 FET 8899.5 11680.0 RPM 8899.5 11680.0 RPx 8899.5 11680.0 RPD 8899.5 11680.0 GR 8903.5 11680.0 ROP 8950.5 11680.0 Page 8 17118002212007SSN.txt LOG HEADER DATA DATE LOGGED: 19-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11680.0 TOP LOG INTERVAL (FT): 8950.0 BOTTOM LOG INTERVAL (FT): 11680.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.3 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8949.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 82.0 MUD PH: .O MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... 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 Page 9 17118002212 00755N.txt 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 8899.5 11680 10289.8 5562 8899.5 11680 RPD MwD040 OHMM 0.02 2000 53.3464 5562 8899.5 11680 RPM MWD040 OHMM 0.06 2000 34.7965 5562 8899.5 11680 RPS MWD040 OHMM 0.06 95.28 30.3077 5562 8899.5 11680 RPX MWD040 OHMM 0.05 67.43 30.5309 5562 8899.5 11680 FET MwD040 HOUR 0.19 82.8 2.07375 5562 8899.5 11680 GR MwD040 API 31.44 102.5 63.1082 5554 8903.5 11680 ROP MWD040 FT/H 2.27 347.15 187.968 5460 8950.5 11680 First Reading For Entire Fiie..........8899.5 Last Reading For Entire File...........11680 File Trailer Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................L0 N2xt Flle Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 11680.5 14647.5 ROP 11680.5 14698.0 RPX 11680.5 14647.5 RPS 11680.5 14647.5 RPD 11680.5 14647.5 GR 11680.5 14640.0 Page 10 i ~ 17118002212007SSN.txt FET 11680.5 14647.5 LOG HEADER DATA DATE LOGGED: 21-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14698.0 TOP LOG INTERVAL (FT): 11680.0 BOTTOM LOG INTERVAL (FT): 14698.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIMUM ANGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8949.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 80.0 MUD PH: 2.6 MUD CHLORIDES (PPM): 35000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Page 11 17118O0221200755N.txt Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MwD050 OHMM 4 1 68 8 3 RPS MwD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Mdx Mean Nsam Reading Redding DEPT FT 11680.5 14698 13189.3 6036 11680.5 14698 RPD MwD050 OHMM 4.71 1803.57 21.9512 5935 11680.5 14647.5 RPM MWD050 OHMM 4.55 1699.57 20.9345 5935 11680.5 14647.5 RPS MWD050 OHMM 4.41 339.09 17.0658 5935 11680.5 14647.5 RPX MWD050 OHMM 4.13 43.44 16.6434 5935 11680.5 14647.5 FET MwD050 HOUR 0.25 9.38 0.671264 5935 11680.5 14647.5 GR MwD050 API 48.26 119.25 76.6921 5920 11680.5 14640 ROP MWD050 FT/H 2.08 303.88 135.062 6036 11680.5 14698 First Reading For Entire File..........11680.5 Last Reading For Entire File...........14698 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/18 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................07/05/18 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services writing Library. Scientific Technical Services Page 12 Physical EOF Physical EOF End Of LIS File 17118002212007SSN.txt Page 13