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Home My WebLink About205-026C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-06-21_21195_KRU_1E-117_InjectionProfile_Updated_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21195 KRU 1E-117 50-029-23251-00 Injection Profile 21-Jun-25 Updated DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC ***Please add the updated data to the original data upload from 21-Jun-25 Attn: Natural Resources Technician Customer requested analysis of data. Update includes Emeraude Files, 333 W. 7th Ave., Suite 100 Processed LAS Files, and Final Report**** Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 205-026 T40761 8/8/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 13:14:49 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\1AP81IBO\2025-06-21_21195_KRU_1E-117_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21195 KRU 1E-117 50-029-23251-00 Injection Profile 21-Jun-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 205-026 T40608 6/23/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.23 12:34:52 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-117 KUPARUK RIV U WSAK 1E-117 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-117 50-029-23251-00-00 205-026-0 W SPT 3392 2050260 1500 630 631 630 630 164 165 164 164 4YRTST P Austin McLeod 6/5/2022 MITIA 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 1E-117 Inspection Date: Tubing OA Packer Depth 1190 1780 1740 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605191216 BBL Pumped:2.1 BBL Returned:2 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:52:47 -08'00' Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 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: 2050260 E-Set: 34722 L O 0, t� v ri I; 0 b--0 Z O�m y �° o J r N a-+ a3 Y h 0�S a u 4 > 0 • a- co ++ O a) O O -� r� n r n n r� r O p m > > > > > > > o O O O E -0 D 0 O kr N — 0 0 0 0 0 0 O Z Z Z Z C u (15 ul Z Z Z Z Z Z Zc co In z N M V In h O T r• ., l ' Ou "d f6 L ��+ O Z s � v > E -o 2 H RS N -0 a) O ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ C a) o ,_ W J J J J J J J J J J J C 4- 0 CL W W W W W W W W W W W v-, a.) 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O O O O O O O O 0 O O �� L -) h CO ' n n N 4 N N c W 0 5 ce > > cr) (nDE 2E0E5 w ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ C 0 x u W = w p O iD O OO 0 0 O O 0C 0 co 0 0 co 0 0 0 0 0 0 CC C n O r O M f0 00 In In •N M CO W N O h 0 0 In L 0@.,E E M N in N Cal M N CO In CO N O U M M M O M M M M M M M N N N N N N N (...1 N N N N t_ - (N (� 6 O) O) C') 0) 0) ) O) O) 6) O) a! 'n po N N N 0 N N N N N N N Q1 O O O *r_.O O O O O O O 3 0 0 0 0 0 0 0 0 0 0 0 F+ O a) go. co C :. N to If) In in In In in In In In 0. U = C9 w In 0) (aa v L z m E v w Y O w cc C = Q o^ 2 O J 4 J r� v v co _@ E ar a a Z a, 1"1 Q CO N N a N O 00 0 In Y it aJ v ma f)') z r r r CO r r r r r r C L f-- /a d Vi 2 N V P = J 7 4 4 4 N LLI 4 W C ra Z a! (6 C Q O w W N W vi Y O C/3 a La Q °1 H a` a Q • • Carlisle, Samantha J (DOA) ?-m9O5 004 0 From: Loepp,Victoria T(DOA) Sent: Friday,July 22, 2016 1:12 PM To: Carlisle, Samantha J (DOA) Subject: FW:Cancelation of 10-403 Approvals for 1E-117 Crystal Seal MBE Treatment Please handle. From: Peirce, John W [mailto:John.W.Peirce©conocophillips.com] Sent: Thursday, June 09, 2016 1:37 PM To: Loepp, Victoria T(DOA) Subject: Re: Cancelation of 10-403 Approvals for 1E-117 Crystal Seal MBE Treatment Hi Victoria, The proposed 1E-117 Crystal Seal MBE treatment recently approved by AOGCC(per 10-403 approvals for: 1E-117, 1E- 117L2, 11-168,and 1J-168L2)was attempted, but we had unexpected problems getting coil tubing through the D Diverter to enter the D lateral (1E-117L2)to pump the Crystal Seal job. After unsuccessful attempts to enter the D lateral we terminated plans to perform a Crystal Seal treatment and left 1E-117 configured with all 3 laterals open. The recent 1E-117 well events are summarized below. Future work options for 1E-117 will be evaluated. Since no Crystal Seal treatment will be pumped,there will be no Crystal Seal treatment to report on 10-404's. Thus, I request that the following 10-403 approvals be canceled: 1E-117 (316-272) 1E-117L2 (316-273) 1J-168 (316-274) 1J-168L2 (316-275) gate FEB 0 6 Z07 Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office Well Events History 1E-117 : 500292325100 : 6/9/2016 Date Event 05/27/2016 B&C CTU#1: RETRIEVE TYPE 1 ISO SLEEVE ACROSS B LEM AT 9706'. ALL SANDS LEFT IN OPEN POSITION. B&C CTU#1: PERFORM DOWNHOLE VIDEO OF D SAND LATERAL LEM 05/26/2016 AT 9706' WITH MEMORY EV VIDEO AND HES N2, TWO RUNS. VIDEO INDICATES DIVERTER KEY NOT ORIENTING CORRECTLY INTO SLOT ON LEM. IN PROGRESS. 05/24/2016 B&C CTU #1: REMOVE PLUG BODY FROM DB NIPPLE AT 9760' WITH BAKER G-FORCE JARS AND INSTALL TYPE 1 ISO SLEEVE ACROSS B 1 RBDMS 1,� �'.f= 2 6 2016 • LEM AT 9706' WITH BAKER HIPP TRIPPER. WILL RETURN IN THE MORNING TO LOG VIDEO OF D LATERAL LEM. IN PROGRESS. B&C CTU #1: PERFORM WEEKLY BOP TEST ON BACK DECK. RETRIEVE 05/23/2016 TYPE 1 ISO SLEEVE ACROSS B LEM AT 9706' AND P PRONG FROM DB PLUG AT 9760' WITH BAKER G-FORCE JARS. WILL RETURN IN THE MORNING TO REMOVE PLUG BODY FROM DB NIPPLE. IN PROGRESS. B&C CTU#1: ATTEMPT TO GET THROUGH DIVERTER WITH SLIM FCO ASSEMBLY WITH 1.7" DJN AND NOTE METAL MARKS ON BOTTOM OF 05/22/2016 NOZZLE. ONE LAST ATTEMPT WITH LARGER 2.7" NOZZLE UNSUCCESSFUL. REMOVE TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER G-FORCE JARS. IN PROGRESS. B&C CTU#1: INSTALL TYPE 2 DIVERTER IN D LEM AT 9385' WITH 05/21/2016 BAKER HIPP TRIPPER. MAKE TWO UNSUCCESSFUL ATTEMPTS TO GET THROUGH DIVERTER WITH DIFFERENT FCO ASSEMBLIES. IN PROGRESS. B&C CTU#1: ATTEMPT FCO OF D LATERAL WITH DJN. UNABLE TO MAKE IT PAST DIVERTER WITH 2 DIFFERENT BHA CONFIGURATIONS. 05/20/2016 REMOVE TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER G-FORCE JARS. JET WASH LEM PROFILE WITH HES PULSONICS NOZZLE. WILL RETURN IN THE MORNING TO RESET DIVERTER AND REATTEMPT FCO. IN PROGRESS. B&C CTU#1: INSTALL TYPE 1 ISO SLEEVE ACROSS B LAT AT 9706' AND 05/19/2016 TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER HIPP TRIPPER. IN PROGRESS. B&C CTU#1: REMOVE TYPE 2 ISO SLEEVE ACROSS D LEM AT 9365' 05/18/2016 AND TYPE 1 DIVERTER IN B LEM AT 9706" WITH BAKER G-FORCE JARS. IN PROGRESS 2 • C1 iE-1t7 ZtrS�' Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday,June 22, 2016 1:07 PM j/i 611/7,(1 c� To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M Subject: LPP/SSV returned to service on well 1E-117 Mr. Regg, The low pressure pilot(LPP) on well -117 (PTD#205-02 , 205-027, 205-028)was returned to service today, 6/22/16, with a pilot setting of 100 psig . The well is currently stabilizing at a wellhead injection pressure of 170 psig and rate at 1750 BWPD. The well has been removed from the"Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson West Sak Production Engineer ConocoPhillips Alaska, Inc. Office: (907) 659-7234 SCANNED DEC 4 2016 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • • KiZi .. 1E-1(1 Jr Z& oz ,0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> �f Sent: Thursday, June 02, 2016 7:58 PM I<e. `t 5/i c 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; Haakinson, David Subject: Defeated LPP/SSV on well 1E-117 Jim, The low pressure pilot(LPP) on welltl E-117 (PTD#205-0205-027, 205-028)was defeated today, 6/2/16, after the injection pressure dropped below 300 psi.The well was brought online on 5/29 after a long term shut in period. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 300 PSIG and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Tyler Hall / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED DEC 1 4 2016 VOF T4 • • g �,��yy�� THE STATE Alaska Oil and Gas ��' �\s�� Of TT A® ccKA Conservation Commission 'w'' X11 1V i �� 333 West Seventh Avenue "or c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 90, 8Y'pw Fax: 907.276.7542 www.aogcc.alaska.gov John W. Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. E3 SEP 2. S 2Q16 P.O. Box 100360 SCA4N Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-117 Permit to Drill Number: 205-026 Sundry Number: 316-272 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, -40i/ "2 A---._ Cathy '. Foerster Chair ' - DATED this 2�5 day of May, 2016. RBDMS (,i/MAY 3 1 Z016 •• ESTATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 12 2016 APPLICATION FOR SUNDRY APPROVALS »5zs//� 20 AAC 25.280 ; OGCC 1.Type of Request: Abandon Plug Perforations E Fracture Stimulate E Repair Well E,',, Operations Shutdown [— Suspend E" Perforate E Other Stimulate fPull Tubing E Change Approved Program Plug for Redrill 1— Perforate New Pool r Re-enter Susp Well r Alter Casing n Other: Crystal Seal MBE TrmntF 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. . Exploratory L Development E 205-026 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23251-00 • 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 I— No Fi KRU 1E-117,, 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 Kuparuk River Field/West Sak 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): 15,774' • 3,415' • 9592 • 3382 1979 9759 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 108' 108' Surface 5,514' 13 3/8 5,544' 2,364' Production 10,546' 9 5/8 10,572' 3,509' Liner 5,370' 5 1/2 15,752' 3,415' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10570-15685 . 3509-3416 4.500" L-80 9,348' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-HRD ZXP Liner Top Packer • 10382 MD=3486 TVD PACKER-ZXP Liner Top Packer i 9647 MD=3392 TVD SSSV:NONE N/A 12.Attachments: Proposal Summary E Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory fl Stratigraphic E Development E Service F • 14.Estimated Date for 5/26/2016 15.Well Status after proposed work: Commencing Operations: OIL r WINJ 9- " WDSPL n Suspended 16.Verbal Approval: Date: GAS r WAG r' GSTOR r SPLUG E Commission Representative: GINJ E Op Shutdown E Abandoned fl 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John,W.Peirce@cop.com Printed Name John W.Peirce Title Sr.Wells Engineer 2,1� - 5/1212.o 1( Signature /--"4 _. Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\( —2`72. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0 — "f-01- RBDMS i/L MAY 3 1 2016 APPROVED BY / Approved by: , to !. . AAMMISSIONER THE COMMISSION Date: c,S� ZS— /6 ' . .FG P IAL Attachments in Duplicate ate Form 10-403 Re ised 11/2015 p valid for 12 months from the datey�epprOVal. Attachments in Duplicate vrG 67i o6ea 3 13 4- -."-/,7(- 6 • • 1E-117L2 to 1J-168L2 `D' MBE Crystal Seal Treatment Proposal 1E-117 injector was shut-in after an MBE occurred to adjacent producer 1J-168. With 1E-117 SI, a decision was made to SI 1E-170 for reservoir and pattern protection. In order to return 1E-170 (750 bopd) to service, 1E-117 must be returned to injection. Diagnostics have been done on the MBE between 1E-117 and 1J-168 as follows: 1. Mainbore (PROF completed in 1E-117 on 1/30/16. IPROF Identified injection splits as 30% D- sand, 60% B-sand, 10% A-sand. (PROF results show majority of injection into the B-sand led team to decide that a B lateral IPROF would determine location of MBE. 2. Set an A Sand Isolation Plug on 1/31/16 in DB Nipple at 9759' RKB. 3. B-sand lateral IPROF completed in 1E-117 on 3/15/16. (PROF got 2000' in lateral (3000' remaining). Logged interval showed no signs of an MBE. Team decided to perform a PPROF in 1J-168 to determine in which lateral the MBE existed. 4. Mainbore PPROF obtained in 1J-168 on 5/8/16. PPROF showed 98% of flow was entering the wellbore from D-sand. Team decided that MBE exists in D-sand lateral. Proposed Procedure - Coil Tubing will perform in 1E-117 & 1E-117L2: 1. RIH & pull the D Iso-Sleeve at 9385' RKB. 2. RIH & pull the B Lat Diverter at 9706' RKB. 3. RIH & set a B Lat Iso-Sleeve at 9706' RKB. 4. RIH & set a D Lat Diverter at 9385' RKB. 5. RIH with Nozzle and perform a D Lat Fluff& Stuff to deep as possible. 6. RIH with memory IPROF BHA and log D Lat IPROF to deep as possible to locate MBE. 7. If D MBE location can be determined from IPROF, RIH with 2" OD Perf Gun to perforate a 5' interval at 6 spf across the MBE location, using 'big hole' charges to provide large inflow area for Crystal Seal to exit slotted liner to the D MBE. If the MBE is not detected on the IPROF, it may be that the MBE exists at depth greater than can be attained with CT, in which case perforating will not be performed. 8. RIH with Down Port Nozzle and park nozzle above all slots at 'safety' (9575' RKB), then pump 0.4 bpm Diesel down CT x Tbg (until Flush is called), and simultaneously start pumping 1,2,4 mm mesh Crystal Seal Slurry at 0.25 lbs Crystal Seal per gallon in 3% KCL Water, or Winter Seawater. Pump slurry down CT at steady rate between 2 - 3 bpm to MBE until target Wellhead Pressure on Tbg x CT annulus reaches 1000 - 1200 psi (near Frac pressure), then call Flush of 5 bbls 3% KCL Water (or Seawater) down CT, followed by 1 CT volume (-47 bbls) Diesel to FP CT, followed by POOH with CT replacing voidage with Diesel. Leave tubing FP to 2200' TVD (4889' RKB) = 75 bbls Diesel. 9. RIH with Down Jet Nozzle to Fluff & Stuff with Seawater through Crystal Seal to deep as possible while injecting all fluid to well. POOH. Return 1E-117L2 to PWI to and D Lateral to evaluate Crystal Seal treatment results at 1E-117 and 1 J-168. JWP 5/12/2016 a. KUP 1E-117 ConocaPhillips 0I Well Attribu Max Angl D TD Alaskd irc Wellbore API/UWI Field Name Wellbore Status ncl r) MD(ftKB) Act Btm(ftKB) Gprroeeaphgli,'; 500292325100 WEST SAK INJ 95.44 14,508.50 15,774.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) l Rig Release Date 1E-117,5/12/20163:06:05 PM SSSV:NIPPLE Last WO: 10/16/2005 31.03 8/13/2005 varboal. abc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,20.1 �'';��r3TO - Last Tag: Rev Reason:SET PLUG,DIVERTOR&ISO pproven 3/19/2016 ( SLEEVE Casing Strings � ani Casing Description OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread j IRE SURFACE 133/8 12.415 29.9 5,543.6 2,364.4 68.00 L-80 BTC CONDUCTOR;30.4108.0-1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 9 5/8 8.835 26.3 10,572.0 3,509.5 40.00 L-80 BTCM NIPPLE;506.0 - i. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len 0...Grade Top Thread 41. 0-SAND LINER HH 51/2 4.950 9,386.0 9,528.3 3,370.5 15.50 L-80 BTCM ME Liner Details GAS LIFT;1,875.5 Mt Top(ftKB) To ) p () Nominal Top(ND)(ftKB), To Incl• Rem Des Corn (in) 9,386.0 3,341.3 78.11 HANGER BAKER B-1 HOOK HANGER 4.950 9,413.3 3,347.0 78.08 XO BUSHING 4.950 SURFACE.29.94,543.6-• 9,455.9 3,355.8 78.16 ECP Baker Payzone External Packer 4.950 IR Casing Description OD(ie) ID(ie) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SLEEVE-C;9.247.7 i i B-SAND LINER HH 5 1/2 4.950 9,706.6 9,840 4 34192 15.50 L-80 BTCM 9,247.7 lit Liner Details Nominal ID 111 Top(MB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) LOCATOR;9,329.5 9,706.6 3,401.0 81.49 HANGER BAKER B-1 LEM Hook Hanger 7x9.625 5.500 SEAL;9,330.2 9,734.0 3,404.9 81.76 XO BUSHING 4.950 9,7562 3,408.1 81.99 ECP BAKER PAYZONE External Casing Packer 4.950 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ISO SLEEVE;8,385.0 A-SAND LINER 51/2 4.950 10,3822 15,751.7 3,415.3 15.50 L-80 BTCM Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 10,382.2 3,486.2 83.11 PACKER HRD ZXP LINER TOP PACKER 7.000 10,400.8 3,488.5 82.81 NIPPLE RS PACKOFF NIPPLE 4.950 D-SAND LINER HH.9,396.0- 10,403.7 3,488.9 82.77 HANGER FLEXLOCK LINER HANGER 7.000 9,528.3 10,415.3 3,490.4 82.59 SBE 190-47 SEAL BORE EXT 4.750 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade (Top Thread B-SAND LINER LEM 4 1/2 3.958 9,647.5 10,429.9 3,492.3 12.60 L-80 I IBTM i W Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) ' ►( 9,647.5 3,391.8 80.68 PACKER ZXP LINER TOP PACKER w/HRD profile 7.500 1IT it 9,667.1 3,394.9 80.95 SBR 190-47 SEAL BORE RECEPTACLE 4.750 DIVERTER;9,706.0 I B 9,686.6 3,397.9 81.21 XO BUSHING CROSSOVER BUSHING 3.940 1 9,688.0 3,398.2 81.23 SWIVEL 3.960 I i1 _ 9,694.3 3,399.1 81.32 HANGER1 LEM Above Hook Hanger 3.980 9,706.7 3,401.0 81.49 HANGER LEM Inside Hook Hanger 3.688 9,759.8 3,408.6 82.02 NIPPLE CAMCO DB NIPPLE 3.563 illit, 10,426.6 3,491.8 82.41 SEAL BAKER SEAL ASSEMBLY 3.870 PLUG,9,759 Tubing Strings 41 IN Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt golf) Grade Top Connection TUBING 41/2 3.958 20.1 9,347.6 3,333.5 12.60 L-80 IBTM Completion Details B-SAND LINER HH;9,706.6- Nominal ID 68404 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 20.1 20.1 0.00 HANGER MB-2 TUBING HANGER 4.500 - 506.0 505.5 7.18 NIPPLE CAMCO DB NIPPLE 3.875 F.=',.. _-� 9,247.7 3,3126 77.68 SLEEVE-C BAKER CMU SLIDING SLEEVE CLOSED 10/28/2005 3.812 5.. r 9,329.5 3,329.7 78.12 LOCATOR BAKER LOCATOR 3.938 e-SAND LINER LEM,9,647.6- 9,330.2 3,329.9 78.12 SEAL BAKER SEAL ASSEMBLY 3.875 106299 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (') Des Corn Run Date ID(in) 9,385.0 3,341.2 78.11 ISO SLEEVE "D"LATERAL ISOLATION SLEEVE(TYPE 2) 2/1/2016 2.500 I 9,706.0 3,400.9 81.48 DIVERTER "B"LEM DIVERTER(TYPE 1) 2/1/2016 3.000 (4.75"X18.7') PRODUCTION;26.3-10,572.0 9,759.0 3,408.5 82.01 PLUG PLUG w/3.562 GB LOCK XO to PLUG BODY& 1/31/2016 0.000 SLOTS,10,570.010,697.0- r I SET PRONG WITH 6'STINGER INTO PLUG 1 Perforations&Slots SLOTS;10,910.0-11,545.0 ) Shot Dens Top(ND) Btm(ND) (shots/ SLOTS;11,879.0-12.874.0-1Top(ftKB) Btm(MKB) (ftKB) (RKB) Zone Date R) Type Corn i 10,570.0 10,697.0 3,5093 3,516.7 WS A,WS 7/10/2005 120.0 SLOTS Alternating blank/slotted A2,1E-117 linerjts SLOTS.13,055.0-13,734.0 -1 1 10,910.0 11,545.0 3,511.9 3,510.2 WS A2,1E- 7/10/2005 120.0 SLOTS Alternating blank/slotted 117 linerjts 11,879.0 12,674.0 3,518.6 3,504.2 WS A2,1E- 7/10/2005 120.0 SLOTS Alternating blank/slotted SLOTS;14,2072.0-14,396.0 - 117 liner(Is -. - 13,055.0 13,734.0 3,483.2 3,488.6 WS A2,1E- 7/10/2005 120.0 SLOTS Alternating blank/slotted 117 linerjts SLOTS;14,8B7.019,0926 14,202.0 14,369.0 3,482.3 3,472.7 WS A2,1E- 7/10/2005 120.0 SLOTS Alternating blank/slotted 117 linerjts ~ 14,887.0 15,092.0 3,439.5 3,432.7 WS A2,1E- 7/10/2005 120.0 SLOTS Alternating blank/slotted y.- 117 linerjts SLOTS;15,265.0-15.65"-*--' - 15,265.0 15,685.0 3,428.9 3,415.8 WS A2,1E- 7/10/2005 120.0 SLOTS Alternating blank/slotted _ 117 linerjts A-SAND LINER;115,751.0,382.27 i I • KUP e 1E-117 ConocoPhillips Alaska,Ina. LamxoPtivlips ti ••• 1E-117,5/12/20163:06:05 PM Vertical schematic(actual) HANGER,20.1 lel g; it.. tt an.re nse 1 mitt, T Valve Latch PortSize TRO Run I ,N Top(ftKB) ((KB) Make Model OD(in) Sery Type Type (in) )poi) Run Date Com 1 1,875. Notes:General&Safety 5 1,500.6 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/20/2006 6:00 CONDUCTOR;30.0.108.0 NIPPLE,506.0 ' - ::.. End Date Annotation tiLl 8/13/2005 NOTE:MULTI-LATERAL WELL:1E-117(A-SAND),1E-117L1(B-SAND),1E-117L2(D-SAND) GAS LIFT;1,875.5 12/28/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SURFACE;29.9-5,543.6 SLEEVE-C;9,247.7 111 LOCATOR,9,329.5 SEAL;9,330.2 ISO SLEEVE;9,385.0 IBa91i ONO D-SAND LINER HO;9,386.0. 9,528.3 i`! rl DIVERTER,9,706.0 �� w I f PLUG;9,759.0IOC"( 13-SAND LINER HH;9,706.6- 98404 1;=Ai 14 34 B-SAND LINER LEM;9,6475 1. 10,429.9 PRODUCTION;26.3-10,572.0 SLOTS;10,570,0-10,697.0 SLOTS;10,910.0.11,545.0 SLOTS;11,879,0-12,674.0 SLOTS;13,055.0-13,734.0 SLOTS;14,202.0-14,369.0 SLOTS;14,887.0-15,082.0 SLOTS;15,285.0-15,685.0 A-SAND LINER,10,3822- 15.751 7 '2 1oc� APR 052016 WELL LOG TRANSMITTAL#7511810 AO CC. To: Alaska Oil and Gas Conservation Comm. March 31, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED 4/1/201Co Anchorage, Alaska 99501 M.K.BENDER RE: Injection Profile : 1E-117 SCANNED Run Date: 1/30/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-117 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23251-00 Injection Profile Log 1 Color Log 50-029-23251-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ✓stL.yrw -� � ./, • (95 -• 02.c, 2Cp4%3 WELL LOG TRANSMITTAL# DATA LOGGED /fib/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 n Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC): 1E-117 Run Date: 10/14/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-117 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23251-00 joatte PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:/ ,, I5eur • • Image Project Well History File hover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~- ~ ~. (~~ Well History File Identifier Organizing (done) RE AN Color items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ,~~,aea uuiiiiuiiiuiiu DIGITAL DATA ~skettes, No. ~, ^ Other, No(Type: Rexa~~e~~ iiiiuiii~uiuiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria ~ Date: ~ ~ ~ ~ [ ~ ~ ~ `~ ~ /s/ `~ Project Proofing ~~~ (~~~~~ ~~~~~ ~) ~~~ BY: Maria Date: ~ ~ ~~ /s/ Scanning Preparation ~ x 30 = 1 ~ ~ + ~ =TOTAL PAGES_ / ~ I ~ ~ % ~ ~ (Count does not include cover sheet) BY: Maria Date: /s! Production Scanning Stage 1 Page Count from Scanned File: L~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~~YES NO BY: Maria Date: ~ ~~~~~~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III I) IIf111111 I I ~~~ ReScanned III (I~I(I I)III I(III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II') III P P 10/6/2005 Well History File Cover Page.doc • Regg, James B (DOA) Z °s ,0 From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Sunday, January 13, 2013 9:17 AM � J I4 ■3 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Targac, Gary; Seitz, Brian; CPF1 &2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; Patterson, Amanda; NSK Prod Engr Specialist; CPF1 Prod Engr Subject: LPP /SSV returned to service on 1E -117, 01/12/13 Jim, The low pressure pilot (LPP) on injector 1E -117 (PTD# 205 -026, 205 -027, and 205 -028) was returned to service on 01/12/2013 after we increased the target injection rate and the wellhead injection pressure increased above 500 psi. The current injection pressure is 522 psi and the injection rate is 1660 bwpd. This pilot had been defeated on 01/11/2013 in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. thanks, Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer SCANNED AP 2013 �� office (907) 659 -7493 Dana .Glessner @conocophillips.com 'rod Engr y, January 12, 2013 5:25 PM aalaska.gov' Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Targac, Gary; Seitz, Brian; CPF1&2 Ops Supt; Jensen, Marc D; Hutcherson, Mark R; Patterson, Amanda; Patterson, Amanda; NSK Prod Engr Specialist PP /SSV defeated on 1E -117 on 01/11/13 Jim: The low pressure pilot (LPP) on injector 1E -117 (PTD# 205 -026, 205 -027, and 205 -028) was defeated on 01/11/2013 when the wellhead injection pressure dropped below 500 psi. A possible breakthrough event is suspected and is being investigated. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. thanks, Dana Glessner /David Lagerlef ConocoPhillips Alaska, Inc Kuparuk CPF1 Production Engineer office (907) 659 -7493 Dana .Glessner @conocophillips.com 1 • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 M F 12 :1_01`, RECEIVED February 14, 2011 FEB Commissioner Dan Seamount GA & Gas Cons. Commission Alaska Oil & Gas Commission 4ncttarage 333 West 7 Avenue, Suite 100 � Anchorage, AK 99501 �a J� Commissioner Dan Seamount: 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 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. spreadsheet corrosion inhibitor/sealant was pumped February 10 -12, 201 1.The attached p readsheet 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, MJ Loveland 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 2/15/2011 " 1B,1D,1E,1Q,1Y /3F,3G,3J PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cements "pumped cement date inhibitor sealant date ft bbls ft gal 1B -01 50029204650000 1800400 SF N/A 19" N/A 1.4 2/11/2011 1D -119 50029228360000 1972220 2" N/A - 23" N/A 4.2 2/10/2011 1 E -117 50029232510000 2050260 12" _ N/A 12" _ WA 4.2 2/12/2011 1E -121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 1Q -21 50029225910000 1 951330 5" N/A - 5" N/A 5.2 2/12/2011 1Q-22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1 971340 6" N/A 6" N/A 5.2 2/12/2011 1Y -08 50029209440000 1830620 6" N/A 6" N /A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N /A 3 2/11/2011 L 3J -17 50029227000000 1961460 SF N/A 19" N/A 3.3 2/11/2011 i David P. Jamieson Supervisor, Reservoir Engineering Greater Kuparuk Area Development ConocoPhiliips Alaska, Inc. Conocor'n An Street Anchorage, AK 99501 phone 907.265.6543 UEt 201 September 23, 2010 Daniel T Seamount, Jr., Commission Chair SEP 2 3 2010 Alaska Oil and Gas Conservation Commission M Pr"' ti " - ° -' 333 W. 7th Ave #100 1 Anchorage, Alaska, 99501 -3539 RE: West Sak Viscosity Reducing Water Alternating Gas Pilot Project Administrative Approval Area Injection Order 213.044 Administrative Approval Conservation Order 4068.009 Dear Mr. Seamount: Enclosed is the West Sak Viscosity Reducing Water Alternating Gas (VRWAG) Pilot Project Status Report for the reporting period of July 1 2009 through June 30 2010. As per conditions described in the pilot approval document, this report was to be submitted to the Commission by September 30, 2010 and contain items specific to the project performance and achievements. Please contact R.Scott Redman (263 - 4514), Mark Hutcherson (265- 1034), or Lubbie Jenkins (265 -6912) if you have questions or require additional information. Sincerely, 1 1A Si iz David Jamie6n Supervisor, Reservoir Engineering Greater Kuparuk Area Development cc: King, Warwick. Jenkins, Lubbie Seitz, Brian Rodgers, James fps -o2� I � Co no coP hi l l ips WS -VRWAG PILOT PROJECT STATUS REPORT REPORTING PERIOD 7/112009 -- 6130/2010 Submitted: 9/30/2010 Prepared By: Mark Hutdierson, west Sak D Petroleum Engineer Reviewed : B Y RAwtt Red , west Salk Reservoir Engineer Approved By: ,/ David Jamieson, GKA Reservoir Engineering Supervisor s � WS -VRWAG Pilot Protect Status Report Executive Summary This document is the annual West Sak Viscosi Reducing Water Alternating Gas (VR Pilot Project Status Report, submitted to the Alaska Oil and Gas Conservation Commission (AOGCC), as required by Area Injection Order 26.044 and Conservation Order 4066,009. The AOGCC, through a letter dated September 9, 2009, requires that the operator provide the Commission with a report on the status of the VRWAG pilot project by September 30 of each year, beginning in 2010. The WS -VRWAG Pilot Project entails injecting hydrocarbon enriched gas for 6 WAG (Water Alternating Gas) cycles in 4 patterns in the West Sak Field 1 E Ddlisite and 1 J Drillsite. An incremental recovery of 3 -6% of the original oil in place is expected in addition to the -20% waterflood recovery estimate. Four injectors were selected for the pilot (1E -102, 1E -117, 1J -122, and U -170) targeting five offset producers on gas lift (1E -121, 1E -170, 1J -168, 1J -166, and U -120). To date none of the 4 targeted ga erns is mature enough in the FOR p[Qiect to show enhanced production. However, t he 1E -102 injector experienced an MBE (Matrix Bypass Event) with the 1 E -121 producer 37 days into the first MI cycle. It is believed that the MBE is unrelated to the pilot project and would have occurred regardless. The other 3 patterns do not show any adverse effects from to the MI and are continuing forward as planned. j0N-P3 I i e -log oo5 - oD(- 1 E - 20 '+ -0`)o i3 -Iaa Introduction The WS -VRWAG Pilot Project is an expansion of the current development plan for the West Sak Reservoir with potential to significantly increase the recovery of oil from the pool. The pilot was approved by the AOGCC on 9/10/09 and the first VR -WAG cycle began 11/23/09 on two of the four patterns, which effectively started the clock on the 36 month planned pilot. The graphic below shows and field overview with the patterns outlined in red'. 37 I 96 31 I — - �9 E -9 2 Are ---• g �, +e"r ", '� � :i\ _ _ d'Z'iz West E. A I fill n R• 1* L a ajrr; ui � i 1 � L w' •••}}}iii��'''��fjjj 1 U 122 Va- 1E -19 71 Qa Are d'° ♦ •" .. f. r i z i • Proiect Performance and Achievements It is still early in the VR -WAG Pilot to detect any uplift or response from the producers. 1 E -102 Pattern Offset producers: 1 E -121 & 1 B -101 (possible) Dual lateral well selected for D lateral injection only (B lateral was previously isolated due to pre -pilot MBE) l ° .�j • Began first MI cycle 11/23/09 e� f Experienced MBE in D lateral on 12/29/09, 37 days after beginning MI, and was shut -in CD Pulled from pilot and remains SI to this date awaiting Q) MBE remediation • Due to the MBE occurring in 1E-102, replacement / candidates are being reviewed. f . No premature breakthrough events detected • No oil production response from FOR detected at offset producers Lh f � ) r o 1 E -117 Pattern r `� W • Offset producers: 1E-170, U-168 & 1E-166 - (Possible) �$ f • Tri- Lateral Injection Well (A, B, and D Sands) ti to • Began first MI cycle 11/23/09 • Completed first MI cycle 3/15/10 and was on produced water injection through the end reporting period of 6/30/10 • No premature breakthrough events detected • No oil production response from FOR detected at offset p roducers /sf LU ,� U-170 Pattern 0 1 , 4 Offset producers: 1J -166 & 1J -168 (Possible) • Tri- Lateral injecting to A & D Sands only (B Sand isolated from pre -pilot MBE to 1J -166) • Began first MI cycle on 4/4/10 I • On first MI cycle through the end of reporting period of 6/30/10 with plans to place back on water injection in July 2010 • No premature breakthrough events detected • No oil production response from FOR detected at offset producers J I tj a .l �. 1J -122 Pattern • Offset producer: 1J -120 • Tri - Lateral injecting to A, B & D Sands • Began first MI cycle on 4/4/10 • On first MI cycle through the end of reporting period of A. 6130/10 with plans to place back on water injection in July 2010 • No premature breakthrough from detected • No oil producition response from FOR detected at offset producers JA i r Injection Performance and FOR Response The VRWAG flood is being managed by injection pressure. Operating rates vary according to geology, well configuration, pore pressure, and injection pressure. Injection rates have been limited to 2.0 MMSCF /d until the maximum operating injection pressure is achieved. At that time, injection rate is controlled by the downhole injection pressure limit. When the wells are converted back to produced water injection (PWI), the downhole pressure remains as the injection rate control limit. The following graphs indicate water /gas injection rates on the 4 pilot injectors and oil production rates and GOR on the 4 primary focus producers and 2 possible response producers. 1E -102 Water /Gas Infection Daily Rates 1500 ■ [nL. vai 2100 1400 I 19W 1300 / 1920 1200 1680 J 1100 1540 1000 1400 < 900 1260 r 100 1110 p / 9eo F D f00 640 500 700 400 560 700 420 200 280 140 p� 0 Jon■ E4111 MM01 Apo My■ Am■ 2066 A"" 6.p■ 0001 Wv■ 61.0 J.10 FAIU Hu10 A1.10 Niy10 An10 1 E -117 Water /Gas Infection Daily Rates 1700 ■ [ - 93 ■ • _ 13 • _ 0 [. .<,i 0 [.t.sam 2006 two 1638 1500 1720 14M 1652 1300 1534 I= 1416 1100 / 12% � � 1000 � ; 1180 1 � 1062 No / 1 c j,& 93 e 9z6 s 6W / SM 995 400 / 472 300 3M 200 100 ' 111 0 0 4 on 01 FA09 Nr■ ►p■ N1y91 An09 AJO9 Aug■ 94p■ 0da N.+■ 0.s0 JON F16" WrN ApN NatrN Aa 10 U-170 Water /Gas Infection Daily Rates 1800 a v.aa_e rw+ ■ v -ao_o rY++ p vaq rrn+ p 2484 1700 2346 1600 2206 1500 2070 1400 1432 1300 1734 1200 5656 > 1100 K 1516 p 1 1380 3 is goo 1242 800 41M 700 y 600 600 690 400 552 800 414 276 100 IV 0 Jen 03 ftb 09 Mar 09 Ap 09 MWW JON "09 09 Sep o9 (W OS N-03 Doe DS Jw 10 Fob 10 M& 10 0 Ap10 um Jmw 1J -122 Water /Gas Infection Daily Rates 1100 t8 unte vn+ p u -�'i,o vn� p 4ezLecai p v- vzomn, � 2526 1000 2650 900 2391 2128 700 1862 � O 1546 m 500 / 1370 Y K 1061 IS S0B a Jan 04 Fab 09 Mr 09 Apr R9 May D9 Ju+09 JJ 09 Aup as sep a9 od as %k OS Cocos SWIG Feb to Mate Ap SO My 10 Jun 18 A � 1E -170 Oil Production Daily Rates 1300 E -170 A OPRI ❑ E -AO 13 OPRI 13 IE -170 D OPRI 1200 1100 1000 800 > 800 a 700 B 600 o` � 500 �'�•�� {� 400 y: .t 300 °�^� ✓'`"". v '. K 200 yH;X 100 0 Jon 09 ftb09 MY09 Ap09 M.09 J-09 Jd 09 Ay09 Ltg00 Dd OD Na09 D-09 J-10 f4b10 M4110 Ap10 M4y1D AmW 1J -168 Oil Production Daily Rates 1300 ® IJ -161 -A OPRI E3 14 MOB OPR/ 0 N-M@ D DPRI 1200 1100 1000 900 > B00 1 400 300 100 0 d4n00 FtAO! M4t08 Apt O! Mr 09 Aar+07 Jd08 Aup08 SOp09 Dd09 Nw09 Dec 09 den 10 FY 10 Net 10 A01 M Arn10 i ! 1J -166 Oil Production Daily Rates 4000 ® IJ'Ka_A OPRt © It KS P OPAI Q L. KS_D OPRI 3000 P K F v!p 2000 d O 1000 0 Jen 09 Fab 09 Mr OB Ap 09 May 09 Jun 09 m 09 Aup m Sto Os oa 09 Nov 09 Dec 09 Jan 10 rob m Ma 10 Apr t0 My W JIn 10 1J -120 Oil Production Daily Rates 1400 93 FJ -ltt_A OPRI ❑ I1it0 8 0PR1 13 F4RQ D OPRI 1300 1200 1100 1000 900 Q no 600 o 500 WJO O V Jan09 Fab09 Ma09 ApO9 May09 Jun09 JJ09 Au009 Stp09 W09 Nov09 Dr_09 Jan10 Fab1O M&IO Ap 10 M #y1 A1n 10 0 ! 1B -101 Oil Production Daily Rates 1600 m101_8 OPRI tB -101_0 OPR1 1500 1100 1300 1200 1100 1000 K O 9O 1m 700 O 600 500 100 300 200 100 0 Jan 09 Fab09 Ma09 AP 09 Ma909 kn09 Jd 09 Aug 09 Sap 09 Od 09 Nw09 Dac09 Jan10 Feb10 Ma10 A010 May10 J-10 1E -121 Oil Production Daily Rates 1000 13 w -1z1_R oPRi 13 10.12Lo OPRI 900 000 700 < 600 m 500 `0 100 700 200 100 Jan09 fab07 Mao► Apo! May09 J1w09 Jd09 Aug09 S.p09 Da09 Mw09 Dac09 Jan10 fab10 Ma10 Ap10 410 J1w10 1E -123 Oil Production Daily Rates 500 ..___ ■ W427 D OPRI K -%27 D OPRt 100 F > 300 , g m S 200 10D Jr109 F409 Mx09 1µr09 Moy09 hn09 Jd09 AqM Sep09 Dd09 Nov09 OK09 Jm10 Fab10 14a Ap10 M Jw10 FOR Response Plots The FOR Response Plots are shown for the following injector /producer well pairs I njector /Producer Open Iniector Zones Open Producer Zones 1E- 102 /1E -121 D Sand D and B Sands 1E- 117/1E -170 D, B and A2 Sands D, B and A2 Sands 1E- 117/1J -168 D, B and A2 Sands D, B and A2 Sands 1 J -170/1 E -166 D and A2 Sands D, B and A2 Sands 1J- 12211J -120 D, B and A2 Sands D, B and A2 Sands 1E- 102/113-101 D Sand D and B Sands 1E- 10211E -123 D Sand D and B Sands Each set of FOR Response Plots includes an Oil Production Plot, a GOR and Watercut Plot and a VRWAG Injection Well Plot on the same page. The injection plot shows the timing of water and gas slugs on the same time scale as the offset production well's Oil Rate, GOR and watercut performance. 1 E -102/1 E -121 VRWAG Response Plots West Sak 1E -121 Oil Production 3000 2500 —oil production �2000 1500 IS 1000 500 _. _...... 0 Jan-05 Jan-06 Jan -07 ,fn.06 Dec-08 Dec-m Dec -1 West Sak 1 E -121 GO and R Watercu t 50 — — 100 45 —QUr 90 4.0 — Watefcutl .___.........._...._...._ . _...... 60 35 70 Q 30. 60 0 20 40 LL '0 CO 1.5 30 1.0 20 0,5 10 0.0 0 Jan-05 Jan-06 Jan -07 JanM Dec-06 Dec-09 Dec -10 West Sak 1 E -102 VRWAG Injection Well 3500 3000 Gas Injection Rate (n 2500 —Water Injection Rate g 2000 LL V N 1500 d to - 1000 .. _..._. 0 SOG 0 Jan-05 Jan-06 Jan-07 Jen-08 Dec-06 Dec-09 Dec -10 1E- 117/1E -170 VRWAG Response Plots West Sak 1E -170 Oil Production 2500 ---- - -..__ _-- - -._ -. 2000 1 -- - 011 -pro duction 1500 N 1000 a 3 soo _ 0 . - °- Jan-05 Jan-06 Jan -07 Jen-06 Oec-08 Dec-09 Dec -1 West Sak 1E -170 Watercut and GOR so - - -- - -- 100 45 QOr 90 —wale rcut a. o e0 p N 3 5 70 O 3.0 60 LL H 2.5 ,; 2,0 40 5 30 1 . _.. .__.. 0.5 - __ ..__.. -_ .___ 10 00 0 Jan -05 J01-M Jen 47 J0n-0B Dec-08 OW-00 Dec -10 West Sak 1E -117 VRWAG Injection Well 4000 — - _ -- 3500 — Gas Injection Rate —Water Injection Rate 3000 N 2500 LL y g 2000 1u 1 K 1000 f 500 _ 0 hn -05 Jen-0B JuW7 Jan-09 DOC-08 Dec-09 Dec -10 • 1E- 117/1J -168 VRWAG Response Plots West Sak U -168 Oil Production 2500 --------------------- 2000 -- --- oli production 1500 N 1000 d 500 Jan-05 Jan-06 Jan -07 Jan-08 Dec-M Dec-09 Dec -1 W est Sak U -168 GOR and Watercut 5.0 ---' ---- - - --- -- 100 4.5 90 40 QOr 80 3.5 - WAtefCUt 70 30 60 ;t LL = N 2.5 50 iii Y»> i dd O 2.0 40 $ 0 15 30 10 20 0.5 - _....: _ 10 00 0 Jan -05 Jan-06 Jan -07 Jan48 Dec-08 Dec-09 Dec -10 West Sak 1E -117 VRWAG Injection Well 4000 - I 3500 —Gas Injection Rate Q — Water Injection Rate 3000 N O a 2500 e N 2000 s 1500 a 1000 8 Sao 0 Jamb JONM Jan -07 Jan-0m Dac48 Dec-M Dec -10 1J- 122/1J -120 VRWAG Response Plots West Sak 1J -120 Oil Production 3000 -- 2500 — production A O 2000 1500 V Y 1000 V 500 .... .... ° Jar: -05 Jen-06 Jan -07 Jan4)8 Dec-08 Dec-09 Dec -7 West Sak 1J -120 GOR and Watercut 5.0 100 4.5 90 40 QOr 80 -- watercut ir 3.5 70 e 9 . 0 6° v � 2,5 SO O 2.0 40 5 1 5 30 10 20 0.5 10 0.0 ° Jan -05 Jan4)6 Jan-07 Jon-M Dec-06 Dec-09 Dec -10 West Sak 1J -122 VRWAG Injection Well 4000 1 it 3500 Q `njec tion Rate 3000 r In ectlon Rste o` Ir 2500 Q U 2000 h 1500 Cr c � t°oo E 500 0 Jan-05 Jan -06 Jai 07 Jan-08 Dec-08 Dec-09 Dec -10 0 . 1J- 17011E -166 VRWAG Response Plots West Sak 1J -166 Oil Production 6000 5000 oil roduction 41m U) 6 3oa� t 2000 1000 Jan-05 Jan-06 Jan -07 Jan-06 Dec-06 Dat-09 Dec -1 West Sak 1J -166 GOR and Watercut 5.0_ - -- - - - - - -- -- 100 4.5 90 410 — watercut 60 35 70 3.0 . _ 60 X 0 � 2.5 50 0 2.0 40 1.5 30 10. 20 05 - io 0 _. _ .0 0 Jan -05 Jan-06 Jan-07 Jan-M Dec-06 Dec-09 Dec -10 West Sak 1J -170 VRWAG Injection Well 4500 — — — 4000 —Gas Injection Rate 3500 —Water Injection Rate 3000 e 2500 2000 v o�c 1500 1000 _ 500 0 .an -05 Jan-06 Jan-07 Jan-09 Dec-08 Dec-09 Dec -1 1 E -102/1 B -101 VRWAG Response Plots West Sak 1B -101 Oil Production 3000 — 2500 — oil production 1500 0 1004 5 500 0 Jan -03 Jan-04 Dec-04 Dec-05 Dec-06 Dec -07 Dec-M Dec-09 Dec -10 West Sak 113-101 GOR and Watercut 20.0 -— 100 150 gO 90 Wo — WaterCUt 60 14.0 70 12.0 60 w U t� 10.0 50 p 60 40 49 6.0 _. - .. __ 30 40 20 2.0 10 00 0 Jen-03 Jen 0ea04 D%C4m DIC-06 Dec -07 Dec-08 Dec-09 Dec -10 West Sak 1E -102 VRWAG Injection Well 4000 -- 3500 — GaslnjectionRate 3000 — Water Injection Rate 0 lS 2500 Q 2000 1500 — - a C 1 000 500 0 32n-03 Jan-04 Dec-04 Dsc-06 Dec-06 Dec -07 Dec-06 Dec-09 Dec -10 • 0 1E- 102 /1E -123 VRWAG Response Plots West Sak 1E -123 Oil Production 4000 - -- ----------------------------- 3500 - -- { � oil production 3000 { P 2500 2000 � 1500 O 1000 500 J an -03 Jan-04 Dec-04 Dec -05 Dec-06 Dec -07 Dec-08 Dec-09 Dec 10 West Sak 1E -123 GOR and Watercut 5 0 — 100 4.5 g O 90 40 FLW11t. rC Ut 80 35 70 30 60 26 - 50 >ti 20. 40 3 1.5 _. _..._. _. 30 10 20 05 10 00 0 JW103 Jan-04 Dec-04 Dec-05 Dec-06 Dec -07 Dec48 Deo49 Dec -10 West Sak 1E -102 VRWAG Injection Well 4000 — - - -- - -- _ -- 3500 as Injection Rate —Water Injection Rate N 3000 g p 2500 ...__...... ____.... Q y 2OW - 1500 1000 �500 0 Jan-03 Jen44 Dec-04 Dec-05 Dec-06 Dec -07 Dec-M Dec-09 Dec -10 Monitorinq and Testinq Per the results of gas sample tests from offset producers, no significant gas breakthrough is detected and, therefore, the VR -WAG cycles will continue as planned on the three remaining VR- WAG injectors. Primary focus for MI producer response monitoring is on wells 1E-170, U -168, U-166, and 1J- 120. A plot of 1E -121 produced gas analysis is also included to show the impact of MI breakthrough from the MBE on gas composition. 1E -121 Produced Gas Samples 1E -121 Gas Analyses 1000 100 — 10 d u IL 0.1 0.01 CO2 N2 C1 C2 C3 I-C4 N -G4 I-05 N-05 C6 C7 C8 Cl/C3 Ratio Component 1135/4109 ®12/29109 1712/31/09 O 1/15110 m 7/2/10 1E -170 Produced Gas Samples 1E -170 Gas Analyses 100 10 d 1 a 0.1 0.01 CO2 N2 C1 C2 C3 I-C4 N -C4 I-05 N•C5 C6 C7 C8 C1 /C3 Ratio Component O 10/17/09 ■ 12/30/09 ❑ 317/10 O 7 /6110 U-168 Produced Gas Samples 1J -168 Gas Analyses 100 10 mr iG 1 2 d IL 0.1 0.01 CO2 N2 C1 C2 C3 I -C4 N -C-4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component W0117/09 ■ 12/30/09 0 317110 o 7/6/10 1J -166 Produced Gas Samples 1J -166 Gas Analyses 100 10 -- 1 _ a 01 - -- 0.01 CO2 N2 C1 C2 C3 MC4 N -C4 I -05 N -05 C6 C7 C6 C1 /C3 Ratio Component 0 5/4/09 ! 5/21/10 0 7/14110 0 1J -120 Produced Gas Samples 1J -120 Gas Analyses 100 — - -- - - - - -- 10 a 0.1 0.01 CO2 N2 C1 C2 C3 I C4 N-C4 I-05 N-05 C6 C7 C8 C1 /03 Ratio Component ❑4/21/10!6/27/10 ❑7/12/10 1E-121 and 1E-123 will be monitored for VR -WAG Pilot- specific response, but none is expected to be observed since MI was active for such a short period of time on the 1E -102. 1B -101 was determined initially to potentially receive support from the 1E -102. The 1B -101 was brought online following a workover on 4/10/10. Following flush production resulting from an extended shut -in period, the well has since gone back to pre- workover rates indicating there is no significant support from the 37 day gas injection period on the 1 E -102. However, the 1 B -101 will continue to be monitored. MBE Development The 1E-102 experienced an MBE shortly after commencing the first VRWAG Pilot gas injection period. It is possible the gas injection cycle accelerated the rate at which the MBE path became fully established, but in all likelihood, the MBE path was nearly developed at the time the VRWAG Pilot began and would have fully developed within a short period of time regardless. The three remaining patterns continue to be monitored closely to determine if the pilot program has affected the likelihood of an MBE to occur. To this date there is no evidence to suggest any change in likelihood. Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Tuesday, September 07, 2010 10:22 PM To: Pierson, Chris R; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: GPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt Subject: LPP/SSV Returned to Service on 1 E-117 - 09-06-2010 Tom /Jim, The low pressure pilot (LPP) on tri-lateral injector 1 E-117 (205-026 / 205-027 L1 / 205-028 L2) was returned to service on 09/06/2010 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 517 psig; injection rate is 778 bwpd. This pilot had been defeated on 08/30/10 in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Daniel Bearden CPF1 Production Engineers n 1269@conocophillips.com 659-7493 pager 659-7000 765 From: Pierson, Chris R Sent: Tuesday, August 31, 2010 7:53 AM To: CPFi Prod Engr; "Maunder, Thomas E'; "Regg, James B' Cc: CPFi DS Lead Techs; CPFl Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF18~2 Ops Supt; Pierson, Chris R Subject: LPP/SSV defeated on 1E-117 - 08-30-2010 Tom /Jim, The low pressure pilot (LPP) on tri-lateral injector 1 E-117 (205-026 / 205-027 L1 ! 205-028 L2) was defeated on 08/30/2010 when the well was returned to injection service after being shut in since 08/26!10. Current wellhead pressure (as of 07:50 08/31/610) is 499 psi; injection rate is 1,030 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 9/8/2010 Page 1 of 1 Maunder, Thomas E (DOA) From: Pierson, Chris R [Chris.R.Pierson@conocophillips.com] Sent: Tuesday, August 31, 2010 7:53 AM To: CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1&2 Ops Supt; Pierson, Chris R Subject: LPP/SSV defeated on 1 E-117 - 08-30-2010 Tom /Jim, The low pressure pilot (LPP) on tri-lateral injector 4E 1'L7 t~!O~i-026 / 205-027 L1 / 205-028 L2) was defeated on 08/30/2010 when the well was returned to injection service after being shut in since 08/26/10. Current wellhead pressure (as of 07:50 08/31/610) is 499 psi; injection rate is 1,030 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Chris Pierson West Sak Production Engineer Conocophillips Alaska, Inc. Office: 265-6112 Cell: 240-5056 ta~o~` a r:4r. . 8/31/2010 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: 1E-117 Run Date: 7/28/2010 August 12, 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 1E-117 Digital Data in DLIS/LAS format, Digital Log file, Interpretation Report 50-029-23251-00 Water Flow Log 50-029-23251-00 ~~; ~~,~~-+ ~! it s~ ~y E.. A'. -4.. ,. i. ~... .... ... Injection Profile Log 50-029-23251-00 1 CD Rom 1 Color Log 1 Color Log 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. _ ~ ~ jfp l Anchorage, Alaska 99518 ~~5 ' C~ Office: 907-273-3527 Fax: 907-273-3535 klinton.woo Date: AUG ~ t~2~10 /lis~ics t~ llt Gas ®ot~. Ca»mi~siot~ ~r+chorage Signed: u MEMORANDUM To: Jim Regg P.I. Supervisor 1 ~ l 7(~~~~~ FROM: Bob Noble Petroleum Inspector •te of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ]E-117 KUPARUK RIV U WSAK 1E-117 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IE-I 17 API Well Number: 50-029-23251-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100628074654 permit Number: 205-026-0 Inspection Date: 6/24/2010 Rel Insp Num: MITOP000003133 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lE 117 Type Inj. W TVD 3392 ~; IA ]200 2450 - 2410 2400 . P.T.D 2050260 TypeTest SPT Test psi 2450 QA 160 160 160 160 Interval Four Year Cycle p~,^ Pass ~ Tubing 590 590 590 590 Notes: ~`, d\ ~~ ~ -~..1~ I ~S, ;~ ~~~ ,ego .. . Monday, July 26, 2010 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 06, 2010 3:32 PM To: Pierson, Chris R Cc: Regg, James B (DOA); Maunder, Thomas E (DOA) Subject: FW: MBE event in West Sak VRWAG project (1 E-102 PTD 204-232) rage i or F Chris, Just got in the 403 sundry to convert to water Injection for 1 E-102. This will effectively ban further MI injection into 1 E-102 until the MBE event(s) has been diagnosed and fixed. As part of the sundry follow-up for the 10-404 please submit the diagnostics results as soon as they are finished. We are keenly interested in what the results may be concerning the nature and type of the MBE. Regards, ~ ~ 6~,~ P.S. could you please forward this to Mellisa Gangl , I don't have her email. i'~ ~ 1 Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) ~~ . __ .. - ~ rj ~ '` ~.~~~ rom: Schwartz, Guy L (DOA) t: Monday, January 04, 2010 3:34 PM To: y, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject. E: MBE event in West Sak VRWAG project hope it is the p leaking in 1 E-102 ... don't think it is likely though as it is a standard DB plug set in a nipple. They don't usually st" start leaking and if they do it would have to be a huge leak in order to restart an MBE in the lower B lateral. 'f it truly is a D lateral MBE... (very rare .. think there is only one other I know of) it doesn't bode well for VR G. Will be interesting to follow the diagnostics on this one........ Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Roby, David S (DOA) Sent: Monday, January 04, 2010 2:53 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, omas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: RE: MBE event in West Sak VRWAG project I just heard more from CPAI on this event. The MBE occurred between the 1 E-1 injection well and the 1 E-121 producer on the 29th. They noticed pressure falling off on the injector and shortly the after the offset producer began producing at higher GOR. They did shut this well in as soon as the noticed a pro m and they also shut in the other well that was injecting gas, the 1 E-117, as part of this project despite the fact that re was no indication of any problems with it or its offset producer. Samples taken from the 1 E-121 well sh MI from the 1 E-102 well. 1 E-121 remains on production with a decreasing GOR. There has not been any indi tion of any sort of containment failure. 7/29/2010 Yage 1 of l Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 04, 2010 3:34 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: RE: MBE event in West Sak VRWAG project I hope it is the plug leaking in 1 E-102 ... don't think it is likely though as it is a standard DB plug set in a nipple. They don't usually "just" start leaking and if they do it would have to be a huge leak in order to restart an MBE in the lower B lateral. So if it truly is a D lateral MBE... (very rare .. think there is only one other I know of) it doesn't bode well for VRWAG. Will be interesting to follow the diagnostics on this one........ Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Roby, David S (DOA) Sent: Monday, January 04, 2010 2:53 PM To: Roby, David S (DOA); Foerster, Catherine P (DOA); Maunder, Thomas E (.DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) ~®11_~3~ ~~_~i„~~ Subject: RE: MBE event in West Sak VRWAG project just heard more from CPAI on this event. The MBE occurred between the 1 E-102 injection well and the 1 E-121 ~~ roducer on the 29th. They noticed pressure falling off on the injector and shortly there after the offset producer began producing at higher GOR. They did shut this well in as soon as the noticed a problem and they also shut in C~! the other well that was in~ectin as, the 1 E-117, as part of this project despite the fact that there was no mica ion o any pro ems wit it or its o et producer. Samples taken from the 1 E-121 well show MI from the 1 E-102 well. 1 E-121 remains on production with a decreasing GOR. There has not been any indication of any ~ sort of containment failure. The 1 E-102 and 1 E-117 both remain shut in. CPAI plans to return the 1 E-117 to gas injection service when they have completed gas analyses from its offset producer to ensure there has been no MI breakthrough in that well. The plan proposed plan forward for the 1 E-102 is to convert it back to produced water injection service so that a(li-t ~~~, they can run logging tools to diagnose the problem. The well had a previous MBE in the lower lateral, the B-sand, which was isolated in October 2006 by installing a plug in the mother bore to shut off injection into this lateral. They need to determine whether this plug is leaking, which would be the easier fix, or if an MBE has occurred in the upper lateral, the D-sand. They will be sending in a 403 to convert the well to water injection and describe in more detail what diagnostic work they plan to do. They also said that they would not have expected a new MBE to occur so quickly, so they are leaning towards a leaking plug that aliawed gas to flow through the existing MBE or an MBE was forming in the D-sand while the well was on water injection and would have still occurred even if the well was not converted to gas injection. Dave Roby (907)793-1232 From: Roby, David S (DOA) Sent: Monday, January 04, 2010 1:08 PM To: Foerster, Catherine P (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Subject: MBE event in West Sak VRWAG project 7/29/2010 rage ~ or ~ I just got a call from Scott Redman with CPAI about a MBE occurring in one of the wells they are injecting gas in as a part of the West Sak VRWAG pilot project. The well was on gas injection for approximately one month prior to the MBE event occurring and is a well that previously had a MBE event when on water injection. At this time they don't know if it is a new MBE channel or if the plug isolating the previous one has failed. They will most likely be switching this well back to water injection so that they can perform diagnostics and determine whether the MBE is a new one or the old one reopened and how to shut it off. I believe he said, but can't remember for certain, that the well was shut in when the MBE was detected. Dave Roby Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 7/29/2010 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit, NSK -69 PO Box 196105 Anchorage, AK 99519 -6105 ConocoMill Phone: (907)659 -7535 Fax: 659 -7314 December, 2009 'REC Tom Maunder, P.E. DEC fl 7 ?009 Senior Petroleum Engineer Alaska Gil & G&S Cons. Commission State of Alaska, Oil & Gas Conservation Commission Anchnolge 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. commenced Viscous Recovery WAG Injection in a West Sak multilateral injection well. Enclosed you will find 10 -404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for wells 1E -117 (PTD 205 -026). 1E -117L1 (PTD 205 -027), and 1E -117L2 (PTD 205 -028). This report records the commencement of VRWAG Injection into the West Sak A, B, and D Sands. If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659 -7535. Sincerely, 2009 4 Robert � D. Chris ensen Attachments 1E-117 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/23/09 Commenced Viscous Recovery WAG Injection KRU 1 E -117 ConocoPhillips Alaska, Inc. API: 500292325100_ Well T e: INJ An le TS: de SSSV Type: NONE Orig Completion: 8/13 /2005 An le TD: 91 deg @ 15774 Annular Fluid: Last W /O: 10/16/2005 Rev Reason: FORMAT UPDATE Reference Log: 28' RKB _ Ref Log Date: Last Update: 12/2712007 Last Tag: _ TD: 15774 ftKB _ L ast Tag Date: Max Hole An le: 95 d 14508 Casing String - COMMON STRING Description Size Top Bottom TVD VVt Grade Thread CONDUCTOR _ _ _ 20.000 0 1 108 94.00 K -55 WELDED _ SURFACE _ _ _ 13.375 0 5543 2364 68.00 1 L -80 I BTC INTERMEDIATE 9.625 1 0 10572 3509 40.00 1 L -80 I BTCM Casin String - A -SAND LINER Alternating jts of Blank /Slotted Liner 1 slots 0 4 row Description Size Top Botto TVD Wt Gr Thread Undulating A -San Slotted Liner 5.500 10382 15751 34 15.50 I BTCM Tubing String - TUBING Size TOP Bottom Wt Grade Thread 4.500 0 9347 3333 1 12.60 L -80 IBTM Interval TVD Zone Status Ft SPF Date Type Comment 10570 - 10697 3508-3516 WS A3, WS 127 120 7/10/2005 Slotted Alternating blank/slotted liner jts A2 10910 - 11545 3512-3510 WS A2 635 120 7/10/2005 Slotted Alternating blank/slotted liner its 11879 - 12674 3519-3504 WS A2 795 120 7/10/2005 Slotted Alternating blank/slotted liner its 13055 - 13734 3483-3488 WS A2 679 120 7/10/2005 Slotted Alternating blank/slotted liner its 14202 - 14369 3482-3473 WS A2 167 120 7/10/2005 Slotted Alternating blank/slotted liner its 14887 - 15092 3440-3433 WS A2_ 205 120 7/10/2005 Slotted Alternating blank/slotted liner'ts 15265 - 15685 3429 - 3416 WS A2 420 1 120 1 7/10/2005 Slotted Alternating blank/slotted liner'ts B - Sand LEM Gas Lift Mandrels/Valves - --- (9647 -9648, St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv 0DA.750) _ __ Cmnt 1 1876 1501 CAMCO KBG -2 -1R DMY 1.0 BK 0.000 0 1/20/2006 Other (plugs, equip., etc. - _COMMON_ J Depth TVD I Type _ Description ID 22 22 1 HANGER T UBING HANGER 3.900 XO 506 505 IN CA_MC 'DB' NIPPLE 10/16/2005 3.875 (9666 -9687, 9248 3313 SLEEVE -C BAKER CMU SLIDING SLEEVE - CLOSED 10/2812005 3.812 oD:6.030) 9330 3330 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 10/16/2005 3.875 PUP 9391 3342 D -Sand D -SAND WINDOW 7.000 (9687 - 10382, Window 0DA.500) 9397 3344 Hook HGR D -SAND BAKER MODEL B -1 HOOK HANGER 7.000 K 9647 3391 B -Sand LEM B -SAND LATERAL ENTRY MODULE 3.880 9648 3392 PACKER B -SAND LINER TOP ZXP PACKER w /HRD PROFILE 7.500 9666 3395 XO 4.940 9667 3395 SBR B -S AND LINER 190-47 CASING SBR _ 4.750 9687 3398 PUP 3.958 9687 3398 BUSHING XO BUSHING 3.940 9688 3398 SWIVEL CASING SWIVEL 3.960 PUP 9706 3401 B -Sand B -SAND WINDOW 7.000 ;10382 - 10571, Window OD:5.500) 9760 3408 NIP CAMCO'DB'NIPPLE 3.563 10382 3486 PUP BLANK PIPE ABOVE SLOTTED LINER 4.950 10401 3489 NIP 'RS' PACKO NIPPLE 0.000 10427 3492 SEAL BAKER SEAL ASSEMBLY 3.870 er I s equip., SAND LINER JEWELRY 12 Constrictor Packers Run for Isolatio Depth TVD Type Description ID SEAL 10382 3486 PACKER A -SAND 'HRD' ZXP LINER TOP PACKER 7.000 ;10427 - 10429, 10401 3489 NIP A -SAND 'RS' PACKOFF SEAL 7" NIPPLE 0.000 0DA.730) 10404 3489 HANGER A -SAND FLEXLOCK LINER HANGER 7.000 10415 3491 SBE A -SAND 19047 CASING SEAL BORE EXTENSION 4.750 I 15750 3415 SHOE A -SAND ROT SILVER BULLET GUIDE SHOE 4.750 1 1 Date Note Perf - -- -- -- 10910- 11545) ' 8/13/2005 NOTE: MULTI - LATERAL WELL: 1E -117 (A-SAND ), 1E - 117L1 B - SAND 1E - 117L2 D - SAND 10/15/2006 RKOV NOTE: WOER RIG PULLED KILL STRING /D -SAND HOOK HANGER & REPLACED 1 1 I 1 1 Perf 11879- 12674) I 1 1 Perf 13055- 13734) I I 1 1 Perf 14202- 14369) I Perf 1 "14887- 15092) __ I Perf 15265- 15685) I �� 'Tubing Head Assy, 20" X 13 -318" X 9 -5/8" X 4 -1/2 ", 13 -5/8" API 5M flange up. R ConocoPhillips BAKE Tubing, Special Drift to +l- 500' MD HU GHES - 506'MD- DBNipple West Sak9 -5/8" Injector Bak -Oil I i -I' 13 -3/8" Casing Shoe, 1 E -117 61 411, J -55, BTC set \\ 5355' MD, 2366' TVD Tri- Lateral Completion 9248' MD - CMU Sliding Sleeve, wl 3.812 DO Profile As Completed 9335 'MD - Casing Sealbore Receptacle Lateral Entry Module (LEM) ubing String 4.75 " ID. 5.75 "OD20'Length With Diverters and Isolation T 4 - 1/2" 12.6 #, L -80, IBTM 9385' MD - Lateral Entry Module (LEM) Lateral Access Divener Lateral Isolation Diverter 3.958" ID, 3.833" Drift Orienting Profile GS Running Tool String Installed Installed D -sand Window at 9391' MD, 'D' Sand Lateral (3.00" Lateral prim (2.50" ID Mainbore Drift) 9588' MD - Bottom 75 deg inc 'GS' Profile for of Seal Assembly 9455' MD - Baker 5! /:" ECP 5 -112" 15.5 #. L40 Slotted Liner Coil Connector r i 'z RimminglRetrieving 4.7 " Seal OD Every Other Joint (1. 00' Length) I Snap In /Snap Out ' 1 . x 3 Length .112" Guide Shoe . - -Back Pressure Valve positive Locating #99 10 g369'MD- Premier Packer 9482'MD -7 "Tieback Sleeve Collet 17 Leng / \_ 5 j (1.60' Length) .� Later anon Seats Flow -Thru Swivel Seals '. 15661' MD - 5 -1/2" Casing Shoe, 15.5 #. (1.25' Length) - Lateral Diverter 9385'MD - 7"X9 - 518" ../ 9528'MD - bottom of 5-1/2" bend joint L- 80BTCM 3208'TVD �- Hydraulic '� Ramp Model'B'HOOK Hanger Seal Bores ` Disconnect �I %77' MD - Bottom of Seal Assembly 475" Seal - Isolation) Mainbore boo ID 3.68" ID OD 3.875" ID 2' Length i .. (1.W' Length) Diverter $leeve 700" Mainbore Window Drlfl � GS Spear ' %47' MD -7" X 9-5�" %87' MD - Tubing Swivel, 4 -112" (1,50' Length( Lateral Isolation ZXP 685 ft A Seals Liner Top Packer %94' MO - Lateral Entry .ppmi with Hold Downs Module(LEM) Orienting Profile 'B' Sand Lateral OAL _ Lateral Entry Module (LEM as 7.500 "Ext ID •Jars may be required in highly dev atetl 19'Diverter Length 9'Sleeve Length %liT MD - Cing 9706' MD - B - sand Window or deep applications (6' approx length). Assembly Sealbore Receptacle 75 deg inc 4.75" ID, 5.75" OD / 5 -112" 15.5 #, L-80 Slotted Liner _ 7" X 9 -5/8" ZXP Liner Top 20' Length ! 9756' MD - Baker 5 -Y" ECP Every Other Joint Packer with Hold Downs 9787'MD - 7" Tieback Sleeve Equ Sp eClflcatlons 7.500" Tieback E#. ID 9706' MO -7" X 9- 518" - 5 -112" Guide Shoe 6.278" Tool Body ID Model'B' HOOK Hanger 7" X 9 -518" HOOK Hanger 6.28" ID Mainbore Drift: 7.00" Casing Sealbore Receptacle 7.00" Mainbore Window Drat 5 -1/2" Casing Shoe, 15.5 #, L -80 BTCM Mainbore Drift, with diverter: 6.25" 4.75" ID, 5.75" OD Seal Bores ___- Set 15675' MD, 3275' TVD _ Lateral Drift, no diverter or LEM: 6.28" 20' Length 3.68" ID 9840' MD •bottom of 5 -112" bentjoint Lateral Drift, w/ diverter, no LEM: 5.12" Tubing Swivel, 4 -112" 4 -1/ 2" 12.6# Tubing -� � - - -- 9759' MD - 3.562" DO Nipple Lateral /Mainbore Diverter OD: 8.50" Automati oti ent of LEM 3.833" Drift 4 - /2 Lateral Ent ry Module 3.958" ID _ Alig nment lig � Positive Latching Collet 7" X 9 -518" ZXP ! Mainbore Drift: 3.68" . Indicates Correct Location Liner Top Packer Mainbore Drift, w/ isolation sleeve: 2.50" 7.500" Ext. ID 10429' MD Bottom of Seal Assembly Lateral Drift, w/ coil diverter: 3.00" Seal Bore for Lateral 1 6.276" Tool ID 0.75" Seal OD 3.875" ID 2' Length OD of Diverter and Sleeve: +/- 3.60" .� Isolation - 3.688" ID \ / Divener and Sleeve Length: +1 -19' Access Window \\ 7 "X9- 518 "Flex Lock 'A' Sand Lateral Positive Lateral Access Via _ _ Liner Hanger 5-1 /2" 15.5#, L-80 Slotted and Thru - Tubing Diverter 10382'MD- Liner Hanger l Packer .276 "ID Blank Liner 1112 "Eccentric Assembly at Guide Shoe Seal Bore for Lateral 10415' MD - Casing Sealbore Re .ptacle 5 -1/2" Casing Shoe, 15.5 #, BTCM Isolation - 3.688" ID 4.75" ID, 5.75" OD Set @ 15751' MD, 3415' TVD .� 20' Length Isolation Seal Asembly 9 -5/8" Casing Shoe, 40.0 #, L -80 BTC PackoM Bushing 4.75" Seal OD 3.875" Seal ID 12 -114" Hole @ 10572' MD, 3510' TVD (J Baker Hu h- 1005. This document ma t be, re oduced or distributed, m w 1O or in n' o b 80 de in ' 2' Length 9 y pr part mar fir ( 9 ) e zoos went sak nwtml complemn- #xe.: any means ele�nom� or m «hanmal. mewein9 pnmgcopym9. reCgmin9. or by any imgrmaoon srorage and Inleglgr relriaval sys rem now known or herealter mvenlM, wRM1OUt written permi . Irom Baker Hughes Inc. tb,ptember 11.1007 p'-" #y. Dave BXrrk M _ N - 1 q: 1 RECEIVED STATE OF ALASKA DEC U ° 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT100 "' E� Gam ° °s• t�mm issio ft 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q ❑ WINJ to WAG Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter kuspended Well ❑ 2. Operator Name: 4. Current Well Status: . Permit to Drill Number. ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 205 -026 3. Address: Stratigraphic ❑ Service NO. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 -23251 -00 _ KB Elevation (ft : Well Name and Number: R B 1 E -117 Property Designation: Field /Pool(s): ADL 25660 & 25651 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured ` 15774' feet true vertical 3415' feet Plugs (measured) Effective Depth measured 9592' feet Junk (measured) true vertical 3382' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13 -3/8" 5543' 2364' INTERMEDIATE 10477' 9 -5/8" 10572' 3510' LINER 5369' 5 -1/2" 15751' 3415' Perforation depth: Measured depth: 10570 - 152685' true vertical depth: 3508 -3416' Tubing (size, grade, and measured depth) 4 -1/2 ", L-80,9347 MD. Packers & SSSV (type & measured depth) ZXP Packer 9648,10832' SSSV =NIP 505' 12. Stimulation or cement squeeze summary. Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf I Water -Bbl Casing Pressure Tubina Pressure Prior to well operation 1 788 1117 576 Subsequent to operation 1810 1 803 1783 14. Attachments 5. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service ❑� Daily Report of Well Operations X 6. Well Status after proposed work: oil[ Gas❑ WAG[] GINJ❑ WINJ ❑ WDSPL❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -050 Contact B. Christensen/ D. Humphrey Printed Name ob ristens Title Production Engineering Specialist Signature Phone: 659 -7535 Date 1- g /2.7•�f ��lt� Form 10-404 Revised 04/2004 Submit Original Only • ~ ~ fi~ ~' ~`~ ~ F ~ `'~ F~h ~ ~ k~ ~ ~ r "4 4 i k h ~ ~g ~ L F e~~'~ ~ `~ ~~ u ki~~~ I7 3E < ye~~ ~~t ~~~~ ar ~~ ~ ~~~9 a ~i ti ~~ ~ r ~ ~ ~r ~ ~ M ~` ~ ;: ~ ~ ~ E ~ ~ t ~ ~ ~ u, ~~ ~~ ~ g~~ ~~ SEAN PARNELL, GOVERNOR ~ p k , tr ~},, ~ ~ ~ y S V, t ~! g ~~. C I '~ ~~ u ~ `~~~~ ~s a " i:-s, ~ ~ i~~.-=.. ~-~.'- i.a~; : s ~~ Ge~.~~ ~,l k ~. ~~ ~: ~ ~ ~-7~~ OI~ ~ V[~-7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ER'QATIOI~T CODi1~IISSIOH ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 , FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 ~ ~ o~.~~f Re: Kuparuk River Unit, West Sak Pool, 1E-117 Sundry Number: 309-050 Dear Mr. Loveland: ~~~~~~ ~~ ~ ~ ~ 2~0~ 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, Cathy P. Foerster Commissioner DATED this .~day of October, 2009 Encl. C~ ~' . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: r ~~~~ z~~.~~ ~~,~.~ ~ . ~EB 1 ~ ~~~~` q1~s~~ ~ii ~: w~~ ~ r;~;~. ~~~~ ;;~;;~~~°~~~ ~n~~~~r~~~ Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Trilateral West Sa.k injection well 1E-117 (205-026), 1E-117L1 (205-027), 1E-117L2 (205-028) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, , ~-~ ~~~ ~~ ~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor / Enclosures ~, '~ ~ ~~~~~v~~ STATE OF ALASKA `br~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~g ~ 7~p09 to' APPLICATION FOR SUNDRY APPROVAL 2o aac 2s.2so Alaska ~li! &~~s G~ns. Commissio~ 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ~ Perforate ^ •~ ~~~ ~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~eve~opment ~ Exploratory ^ 205-026 • 3. Address: Stratigraphic ~ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23251-00 • 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 ^~ 1 E-117 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660 & 25651' RKB 95' Kuparuk River Field / West Sak Oil Pool • 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15774' • 3415' • Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13-3/8" 5543' 2364' INTERMEDIATE 10477' 9-5/8" 10572' 3510' ~ 5369' 5-1 /2" 15751' ~ 3415 Perforation Depth MD (ft): Perforation Depth TYD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 10570-15685' 3508-3416' 4-1/2" L-80 9347' Packers and SSSV Type: Packers and SSSV MD (ft) ZXP packer, 9648, 10832 no SSSV - DB Nipple 505 13. Attachments: Description Summary of Proposal ~ 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 L~ ~/ G' ~ 6 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q• GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland/Per KI ~ Title: Well Integrity Project Supervisor Signature ~'"~ ° 'r~ ~..-°' ~--°~ Phone 659-7043 Date ~~ ~ " Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness "~ ' - a ~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other. G[~"~~~1 s~lc c~~/'~roh i-~. 4cC or~ c.~cT`~ ~IC~ z~• ~ 7 y Subsequent Form Required: ~ ~~ -' ~~'~~ l~ Approved by. ~; COMMI SIONER APPROVED BY ~/~~ T E COMMISSION Date: ~~ Form 10-403 evised 06/20Q6 ~ ' ~^.~/ Submit in Duplicate r ~~,,, ~ { l' 1..a1 ~ ,~p~_7~7~p~ ~S Z. ' (7'Z~ ~~ • ConocoPhillips Alaska, Inc. 1 E-117 (PTD 205-026) & 1 E-117L1 (PTD 205-027) & 1 E-117L2 (PTD 205-028) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in ~ West Sak Injection Well 1 E-117 and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1 E-117 was drilled in July 2005, completed as a pre produced injector in October / 2005, and placed in water only injection service in February 2006. The well was drilled with a 20" conductor to 108'. The surFace hole was drilled with a 16" bit and cased with 13-3/8" casing to a TD of 5544'. The casing was cemented in place with 792 bbl of lead cement and 124 bbl of tail cement. Lost returns with 86 bbl left to pump. Bumped plug and saw mud push at surface. Ran in annulus with 1'/4" Hydril to 264' and pumped 46 bbl cement with good returns to surFace. The intermediate hole was drilled with a 12 1/4" bit and cased to 10572' with 9 5/8" casing. The casing was cemented in place with 324 bbl LiteCrete cement no returns were mentioned. The top of cement is confirmed at 5520' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervals. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1 E-117 2. Injection well 1 E-117 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/ mile of 1 E-117 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in'/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. 2009 WSAK EOR Pattern Targets ,_; f{~~ ~ ,~ '~~ ~ L:; ~ f ' - ~ ~ - , ;. ~ .~ ~ ~ ;~_ _ . ~': ! ~ - ~ + ~ ;;j. - ~'~ ' _ • "- ~' ~--, ~ . 1 E-1 ~2 r , ~ ` ' ~ ~ `~''-~ ~ ,,~ ~ -~-_ ~'- ' ~ .~--- - } ~ 1 , - 3 ~ ~s .• - - ' ..._~ ~' a ' r. .~1 ~' 1~ ~ . .ts~ ~' - ~ r .~' ~ ~ ~ y ~ ~ ~' .~ ~ ~ ~ / 1 ~!" ' _ ~ ' ~ /'~ ! _ i . , i + + T t1 _... ~ - _ .~ . ._ . ~ . ~ ~ _ .. ~... _ _ .. ^~, . ~ ~ ~ { ~' .. _- ~. . - , ; . , --;_. . ~ , _ _ __ ._: . . ~.~ . _ T" ~ ~ ~ - 1 _ ,,, . ~ ! ~ • -r ~ ~,' ~ti ' ' ~ 1.1-1 ~~ __ ~ • _ ' ~ , 4 ' -I- 'i1~'•` / ___ 1 J-170 ~~ `;, _ . _ Y x F ~ k ~ i .~ ~ 7 r L -~ In ' + ~ 1 _ _ ~ ` t r~ ~ - -~ pY .~ ~ ' r ' ~ ,~i ~ , ~ r ~ ~°s' ~ ^~~.~ ~~^ I i,` ~~ ~ + ~ ~ ' ~ ~ , ~ i ~ ~ - i; ~ ' ' ~ ~ ~ ~ ~ , " I ~ - ! ~.p~ne! ~ ~ ~ I E~ ~,~ ~ ~ 1 E-117 ~.4 ~ :~~ '; ~ J __ ~~aZ.~s • i " ~' ws o~.w~anea v+u~ea ! ~4 ` , ~ i i ~ ~ - Oeher KRV Ywell . ~ i ' * ,~ WS hW~cx ~~ Fau1tS ~~F a, ~ • ~ 9 r' + ' - W'' FaWts : y ~ t"aL Produ4e~ { Pres~duaer r ~ ~ 1 ~~ ` ~ ~ ~ ~ ~ ~! _~ ~ I + + SI Produca~ ~a ~ - ~ y~ ~ ~ .~~ ?~ ~ ~ . r P ifk'! A .x ~ y 1 r i ~ ~- ~ ~ ' tn~bOr , tE-102 iF4 rn. BufMer ~ (.~ :. l Raw 1F4 m~ BuMsr ~ ~ ~' N Raw 1 M rn~ But'hb~ Q ROw 1f+C m~ HuffM ~ - ._ . ~n115/t£* BOIJ~y . ~~~ ~ ~ L7 25 4.5 , S 2~ ~ss YN"' PA Boundeuy ~ ~ J 1E-117 injector •Logged from 10,180 to 5,400' Tops UG C 7,077 •Top of cement labeled @-5,520' (above Ugnu) UG B 7,829 •Unable to determine cumulative footage of good bond UG A 7,933 K13 8,522 •Some channeling appears in CBL K13 8,820 D 9,391 10,200-10,030 Bottom interval Top interval 5,680'-5,500' . ~~ bp ~ 2009 WS EOR Well Integrity Review with AOGCC 17 January 21, 2009 ~ ~ w w ~ ~ ' - i ^ - -- - - ~ ~ -i-'~- mEF~ ='r ConocoPhillips •Logged from 10,180 to 5,400' •Top o cemen a e e ~, a ove gnu •Unable to determine cumulative footage of good bond •Some channeling appears in CBL ~~ • ~view with AOGCC Top interval 5,680'-5,500' 10,200-10,030 ~ , . ~ • w ~~ ~C? QC4~ I~~1 S urvei lan e Plans • Baseline API Qil Gravities and gas samples for GC in offset producers to pattern injectors ahead of Startup • Baseline GL GC analysis . • Will obtain at minimum monthly gas samples for hydrocarbon ratio detection post injection startup • Will obtain at a minimum monthly oil samples for oil gravity changes post startup .~ Attempt to obtain Mainbore IPROF's on injectors to assess gas splits ~ ! 2009 WS EOR Well Integrity Review with AOGCC 19 January 21, 2009 ~ ~;,<~:~ ConocoPhillips bp Drillsite 1 E • Producers shown in green • Injectors shown in blue • West Sak Tops (D-Sand) shown as green circles for producers and blue triangles for injectors • Kuparuk and other (non-West Sak) wells show West Sak interval in navy blue • The gray pattern areas represent'/4 mile buffer zones around the subject injectors ~ a 2009 WS EOR Well Integrity Review with AOGCC January 21, 2009 12 . • C~no~oPhillips 1 J-122 Cement Log Rnttnrri intanial Mirirlla intarval Top interval aPretty good bond around immediate vicinity of shoe •Persistent poor bond along wellbore uphoie but intervals of better cement bond are abundant •Top of cement at 5,920' Tops UG C 7,277 •550' of cumulative bond noted from USIT UG B 8,484 UG A 8,979 K13 9,477 2009 WS EOR Well Integrity Review with AOGCC D 10,295 11 c N~ ~'c c~ c ~ oZ ac January 21, 2009 ~ ~ i t r t ~ r ~. # ~ ~~~~~~9~~-1~~91JB~~~~~J~1~~ ~ ~~I~~ of concern ithin 1/~ rn~l~ rad~~~ ~~~~~tt~~~ ~ ~~~ ~ u aruk well penetrations within qua~ter r~~~e r~ ~~~ ~r~~l ~~~~ ~wtored ~nnular pre~~ure~ r~~C~~ 1tV ;~Caf~ 1~l~lf Int~grity Review with AOGCC J~n~.~~r~yJ ~'_~ ;:~~~~~i ~- ! s ~ C~r~ocaPh i I I i ps 2009 WS EOR Well Integrity Review with AOGCC 1 E-117 Pattern .,~~~:Y~p ,~~~ ~ • 1 E-170, KUP 31-11-10, 1J-168, and 1 E-166 all fall within ~/4 mile of 1 E-117 • 1 J-168 GL completion • 1 E-170 to be converted to a GL Completion Jan 09 • 1 E-166 to be converted to a GL completion April 09 • Kup 31-11-10 PA'd-Off Tundra-Primary cement job should have covered the West Sak 16 January 21, 2009 i ~ +~~~~-~~-~h i I I i ~~ 1 E-117 Iniector Cer~°~ent Det~wl~ su~aCe RCanductQr 20" ~nd TD c~ 108' •Surface hole drilled wifh 16" bit, TD ~ 5,~60' •13.375" surface casing TD c~a 5,a43' •Tough #o r~ciprocate, anJy 4' rr~ov~m~nt, set pip~ ~n h~ng~r ~792 bbls of lead ~em~nt antl 124 bbls tail ~~ment •L.osf r~turns w/ 86 bbls left to pump +Bumped plug and saw mud push to sut~a~e 0 bbls c~ment to surf2~ce, could nat r~cipro~~t~ •Ran in annulus w/ 1'14" Hydril to 264', purnp~d 4~6 bbl~ cement w/ goad returns to surfi. •Float equipmer~t top ~ 5,461' > Intermedi~te 0'12 1/4 hole si~~; Tf~ @ 1'q,58Q' •9.625" casing f~a '( 0,~7.2' ' •324 bbl~ ~em~nt pNo mention of r~turns •B;umped plugs, fl~ats lield *TOC 6100' reported, TQG 5$37' calcul~ted 1 Q% wa~hc~ut, , ~TUC 552C?' U51T I~or~ *F'lo~t eauipm~r~t ~c~n deea~r v~t [d? 10.490, ~C~05 V~lS Ef~R Well Integrity Review with AOGCC '17 bp ~~ . ;.z k 4;2 ` January 21, 2009 ~ . . Cono~oPh ~ I I ~ ps •Logged from 10,1 ~30 to 5,400' •Top o cemen a e e , a ove gnu •Unable to determine cumulative footage of good bond •Some channeling appears in CBL ~view with AOGCC Top interval 5,680'-5,500' Bottom interval ~ 10,200-10,030 ~~~~~ ,~ ~ '~.~~.~~ ~=,,,,~,,~;~~; ~ - ~~ ~~~~~~~~ ~~~t~a~~ p~~~u~~r~ ~r~ ~dar~~~~kly ~r vor~NM ~~ ~~r°~~ . ,_ ~~~ ~~ ~~ ~~r~~l~t~~~~~ ~~th p~~~~r~ ~~fc~r~ ~M ~~~~ ~~ ~~ ~~~~~ ~ ~ ~n~~~~~~~ h~~~ ~~~m~r~ ~~m~nt ~~~~rir~~ ~~~ ~~~ - ~~ ! ~~ _ ~~~ f~~~~~~~~~ ~n~ h~v~ ~~~~I~ r~~~ ~~ ~~~w~ ~~~~~~~~ ~~ ~~~~~~~ . / _ ~~~~ ~II p~n~tr~~i~n~ w~~h~~ ~u~~~~~ i~~ ~~~~~~ i~M _~ ~ ~~~~~~~d ~n~~l~~ ~r~~~~r~~ ~ ~~Ua~~ 1t~~.~ E~.~)~ ifel~ll ~~?~~~rity ~~vie~nr with AOC~~ ~I~nta~r•} ~'t ~.~~+?~.+ ~~ ,.. ~ ! ~ ConocoPhillips 2009 WS EC)R Well Integrity Review with AOGCC 1 E-117 Pattern ..~~ + ~p ~,h~ ~ ~~~8~~a • 1E-170, KUP 31-11-10, 1J-168, and 1E-166 all fall within "/4 mile of 1E-117 • 1 J-168 GL completion • 1 E-170 to be converted to a GL Completion Jan 09 • 1 E-166 to be converted to a GL completion April 09 • Kup 31-11-10 PA'd-Off Tundra-Primary cement job should have covered the West Sak 16 January 21, 2009 ~ ~ ~~~~~~~hilli~s _1 -117 Iniector Cern r~t Detail~ . caseng v , ~324 bbls cement •No mentian of returns •Burnped plugs, flaa~ts h~ld •TC~C 61 q0' ~reported; T~?C 583T c~lcul~ted 10% w~shQUt, ~T~JC 5520' IJSIT L~~ ~~:It~at ac~uinm~nt t~n cle~?nc~r v~-t n 10_4An' ~u~a~~ ~Conductar 20" ~r~d T~ a~,? 108' •Surface hol~ drilled with;1~" bit, "fD ~a 5,5~0' ~1~.37~" surface casing TR ~a 5,~4~" ~Tough to r~ciprocat~, only 4' movem~nt, set pip~ an hanger , ~792 bbl~ of le~d cem~nt and 124 bbJs #ail ~~ment •Lo~t returns w/ 86 bbls' left to pump •Bumped plu~ and ~~w rnud pu~h to surfa~e 0 bbls cem~nt ~o surface, cauMd not reciprocat~ - •Ran in annulus w/ 1'/~' Hydril to 2~4', pumped 46 bbl~ cement w/ gOOd returns to surF, •Fioat equipm~nt top @ 5,461' lntermediate •12 1/4 hole siz~; TD @ 10,5$Q' •9 ~25" ' f 10 572' ~n05 WS ~OR Well Integrity Review with AOGCC 17 bp ~~ .p #.~. ~, _ ~.~~F January 21, 2009 `1%~ ConocoPh i I I i ps •Logged from 10,1(30 to 5,400' •Top o cemen a e e , a ove gnu •Unable to determine cumulative footage of good bond •Some channeling appears in CBL ~view with AOGCC Top interval 5,680'-5,500' 10,200-10,030 ~ ~ ~~ ~ ~~/ ~ ~~ ~ 1 -1~ ~ ~ . ~ ~ ~ / ``--'- / ~ ~ I ~ ~ ~ ~ ~ / y_ ~ ' ~ a ~ D Q7 \~ ~ W SAK 24 ~ ~.° ,~ ~o o I ~ ^~% ~ ^% .~6 m A~ I~ ~C p- I ~G/ 1% ~ '- ~v~~ ~ \ o~ 1 C 1~ ~8~02 o i ~_ 5 1 A 1B-0~ I~ ~Qp ~C V ~ ~ ~ ~ ~~~ 9 .71> G~$9 ~ .p1 ~ ~ /~C_ I 1 ~~ m / ~ ' I ~ a'kv ~ /~' N 3 ~ ' ~ ~ ~ ,G~~ ~ ^u~ i ~ V 1G~ U ~ o ~ ~`~ 2~py i ~ ~ ry ~ -~ ) o ~ ~ ~ i ~v~- .__ ~w D..... W ~ -- --.... ' ~ _..___ _ --- -- - r_ - - - - - ~ v ~ , ....._ . ~ ~ ~ ~ ; ~- '' ~ 'o 'Q x ~~i ~ ~ I ' '~ , ~ 1 w~ h ~o Q~~ , ~ ~7 ~ 1~ ; \~ 3, m ~ ~ I~ t .' `--^ - -- - 7 ~o O ~ ~ ~ ~' ~''A o 0 0 ^O/ c ' ~ O F ~'~"~3 ~ b ~F:~ ~. ~.~% E c~ ~ , ~D,~1 1D-115 ° O `Q}` ~ ~ •~s • .~O/ ~ ~ MP ~~7'~~-11 ~ E ~ N 1E 1 1D- 1D~2 0&~'y~9 1D-120 ~ I ~ F ~ i ry~, 9 ~~ , ~ 1D, ~~-OS 1D- 23 cQn 10~ 24 ~: 08 , o I ~~~' I 1 ~ 0 . ~ N ~ / ~ E ~ ~ . 22 I 1~(., ^~p ~ O~~ 126 ~~N ~' ~~~~ ~a~ ` 1 D ~1~~• ~ ^,~~ ~ ~,~ o ~ ~v ~ p O• ~ ~ ~~ /~ . I 1 N w o ~ ~^ ~ ° ' ~ a ~/ .~~ m ' ^ .- ° ~ ~ ~ ~1 - ~ ~f ~ . ~~a ~ .~.0'~ . ,a,,~ _, ..;fl~ ~ .~ ~ .. _... ~ ._. ~ , . W ~ . ~ ' i \ ~ ~ ' ~ ~...~ ~ ~-- . ~,~~ \Q A . . ~ ~ I "' ~ i `_ ~ o I ~ ~ __ W ~ ; ~ ~ ~ ~ ~ ` j ~ - - -_ ~ i ! ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~~ ~>> 1 ~~~/ " 1 L i ~ i o ' ~ " ~ \; i° ; .; _~ _ , , _ ~ 1 1 ~ 'i~ _ _ _~ --- -; I / ' '~I ' d . T~ ~ r ~ ~ 1 I ~ ~ ~ ^~ ~ ~ ' \ 1, 0 I f~ ` ~~ I ~ I 200 m ' W I i i. ~~ I -- J : ~ - r----- - - ~ ~, ~' - , ~ ! % ~~ _ ~. ~ ~ •~ • ~ \ . ._ , , _: __._ . .. ~ ~ I . g Le end ~ ' `~ ' % c ._ ~ / NI ~ ~ f ( _ ~ 1 ~ o ~ ~ ~ O ~ -~--- ~ - +- ? ~ WS Horizontal Producer ~ / 1J ~~ ~ ~ ~ '~ ' N ! ~' ` ~ ~ . WS Horizontal Injector ~ ~ ~ ~~ ~ ~ ~~ o ~,~ , ~° V i WS Deviated Well ~ N ~ ~_~- ~ ~I ~ ~~ ~ ~ ~ ~ ~ _ ' _ ~ Other KRU Well ( ~ ~ ~ ~ _ :_ - _ : ~:; ; ~ _ ~~ ~ _ ~ / .. ~~ ~ ., r~ WS Major Fault ~,r ~ ~ _ _ , _ __ I ~ .~~ _ ~, LIl.I IAl ~ ~ ~ ~ I ~ -~ I ~ ~ ~ I ~~ t t 1I '; T - ~ ~ ~ , , _I , 1 ~ _ ~, _ WS Faults ~ ~ ,, , w ~~ "" ~~ ~~~ ~~ ~ ~~ ~ " , ~ ' ~ ~ ~~~ "' ~~ ~ ~~ ~ ~ " ~ ~ ~ ~ ~ ~ " ~ , " ~ . . ~ ~ w _ - _ ~, ~ . Producer ~ ' ~, ,, ~ , , ~ r~ ~ ~ ~ SI Producer ~ , ~ ~ • Injector ~ ~ ~ ~ P and A - °° ~ 1 E-102 1/4 mi Buffer ~ ~ L Row 1/4 mi Buffer ~ _ ~ N Row 1/4 mi Buffer ~ Q Row 1/4 mi Buffer _/~ ~ ` ,~ _ ; 1 E Injectson Area N ~ ~ ~. ~~ 1 J I n~~ction Area ~-\ ~ 0 V~1S PA Boundary I D ill it B d oun r e ary s 0 0.25 0.5 1.5 2 Mil i ~ + • • MICROFILMED 03/01 /2008 DO NOT PLACE .~~~. ANY NEW MATERIAL UNDER THIS PAGE F:iLa~rFichelC'~rP~s_Inserts\Microfilm Marlcer.~c DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050260 Well Name/No. KUPARUK RIV U WSAK 1E-117 Operator CONOCOPHILLIPS ALASKA I NC API No. 50-029-23251-00-00 MD 15774 TVD 3415 Completion Date 10/6/2005 Completion Status 1-OIL Current Status 1WINJ U REQUIRED INFORMATION Mud Log No Samples No Directional Sunr Yes DATA INFORMATION Types Electric or Other Log s Run: GR/Res, CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey 10771 15774 Open 9/26/2005 IIFR ED D Asc Directional Survey 0 11593 Open 9/26/2005 PB 1 IIFR ~g See Notes 5 Blu 1 5400 10180 Case 9/28/2005 USIT on MaxTrac SAH- Tractor-GR-USIT 11 July ' 2005 D Lis 13419 Induction/Resistivity 5524 11558 Open 1/31/2006 GR/EWR4/CNP/SLD/ROP/ ', ACAUPWD/GEOPILOT ~ I 13419 V, ~~t~.,~ Ind,~~vi' ty ~''._ 5524 11558 Open 1/31/2006 PB1 GR/EWR4/CNP/SLD/ROP/ ACAL/PWD/GEOPILOT PB 1 ! D Lis 13420 Induction/Resistivity 5524 15739 Open 1/31/2006 GR/EWR4/CNP/SLD/ROP/ `~sQr, ~ ~ tv ~\ 4d.~ ACAUPWDIGEOPiLOT ' pt 13420 Indyrtie~es-i'STvity 5524 15739 Open 1/31/2006 GR/EWR4/CNP/SLD/ROP/ ACAL/PWD/GEOPILOT ~~g Injection Profile 5 Blu 1 9200 9872 Case 3/30/2006 Injection Profile w/WeIITec C L~Cs(rcS 14454 lnduction/Resistivity 5517 15774 Open 1/29/2007 Tractor 26 Mar 2006 LIS Veri, FET, GR, ROP, ' NPHI, NCNT, RHOS, ; / DRHO w/Graphics I I (f/ED C J,as ~(S 14454 Induction/Resistivity 5517 11593 Open 1/29/2007 P61 LIS Veri, FET, GR, ROP, NCNT, NPHI, CALA, RHOB, DRHO w/Graphics ; '~ Injection Profile 5 Blu 9210 9875 Case 3/22/2007 Injection Profile w/Welltec Tractor 14-Mar-2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050260 Well Name/No. KUPARUK RIV U WSAK 1E-117 Operator CONOCOPHILLIPS ALASKA INC MD 15774 TVD 3415 Completion Date 10/6/2005 Completion Status 1-OIL Current Status 1WINJ ADDITIONAL INFORM~N Well Cored? Y / Chips Received? cl`?'N-" Analysis ~' Received? Comments: Compliance Reviewed By: Daily History Received? ~'y°' N Formation Tops ~!-N API No. 50-029-23251-00-00 UIC Y - - - - - ___ _ ~ -- _ - ----- - T __ _ _q ,_~ Date: SY\~O ~ v~ ~C~~~~fll~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # -~ ~ ~~ k`'~!!f~" `~ %' ~Q()6 v _1 L° v~ ~ 'C~ CJ' Log Description '~ ~ /: N0.4193 f Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 03/20/07 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03108107 1 1 E-20 11638833 GLS 03/09107 1 1 E-168 11626470 PRODUCTION PROFILE 03/12107 1 1E-117 11626471 INJECTION PROFILE 03!14!07 1 1Q-09 11638839 INJECTION PROFILE 03/16107 1 3S-22 N/A INJECTION PROFILE 03/46/07 1 3M-23 11638840 LDL 03117/07 1 1C-10 11638841 INJECTION PROFILE 03118107 1 2A-23 11628986 INJECTION PROFILE 03118/07 1 1H-21 11638842 GLS 03/19107 1 1D-42 11638843 SBHP SURVEY 03/79107 1 2L-323 11628988 INJECTION PROFILE 03120107 1 .Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. j `.~~ • • WELL LOG TRANSMITTAL To: State of Alaska November 13, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 1 E-117, PB 1, L 1, L 1 PB 1, L2 & L2 PB 1, AK-MW-3775114 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage., AK 99518 1E-117, PBl, L1, Ll PB1, L2 & L2 PBl: ~` Digital Log Images: ~CD Rom 50-029-23251-00, 70, 60, 71, 61 & 72 U~c 2aS -~~~ ~ ~y~~~v ~ ~ C s t t~- l ,~ ~ ( ~ }iv Word hoc sags 4~1~1 t'orZ~' I-3L-- is vui551+aq> ~.J U~c aoS- v ~~ ~ r~ruSS` ~~~ ~o~ ~~- ~ ~~~ v°~~ ac~S -o~~ ~ t~t~i~ 6 MEMORANDUM TO: Jim Re Q gb ~~~~r- r,~f(~I"lt.~- P.I. Supervisor (' FROM: Chuck Scheve Petroleum Inspector State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 07, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lE-1 ]7 KUPARUK RIV U WSAK IE-117 Src: Inspector NON-CONFIDENTIAL S ~ a a~b ~~ Reviewed By: P.I. Suprv~ ~~-- Comm Well Name KUPARUK RIV U WSAK 1E-117 Insp Num: mitCS060605134445 Ret Insp Num API Well Number 50-029-23251-00-00 Permit Number: 205-026-0 Inspector Name: Chuck Scheve Inspection Date: 6/4/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ IE-117Type Inj. ~ W ~ TVD ~ 3392 lA i, 1600 ~~ 2340 ~ 2300 2300 ~ I p.T, i 2050260 IT)'peTCSt ~ SPT ,'l`est pSl ~ 1500 ~QA~ 160 ~ 160 160 160 Interval aYxTST p~ P Tubing s~o s~o s~o s~o NOteS Pretest pressures were observed and found stable. Well demonstrated good mechanical integriy Wednesday, June 07, 2006 Page 1 of I 03/30/06 Sc~~nberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;~o~-d~4 Well Job # N0.3751 ~., f:,. ^~ ~ Company: Alaska Oil ~ Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 1 B-06 11213713 PRODUCTION PROFILE W/DEFT (REDO) 02/27/06 1 2T-19 12213723 PRODUCTION PROFILE W/DEFT 03/24/06 1 1 E-117 11213725 INJECTION PROFILE 03126/06 1 1 H-10 11213726 PRODUCTION PROFILE W/DEFT 03/27/06 1 3M-23 11213727 LDL 03/28/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM Toy Jim Regg P.I. Supervisor ~~CN ~1 l ~'~ State of Alaska Alaska Oii and Gas Conservation Commission DATE: Monday, February O6, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHII,LIPS ALASKA INC 1E-117 FROM: Lou Grimaldi KUPARUK RIV U WSAK lE-I l' I~1 Petroleum Inspector '~ tJ Src: Inspector ~~ ~~~!!! ___ Reviewed By: P.I. Suprv„J~~~ NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV U WSAK lE-I 17 API Well Number 50-029-23251-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060205105812 Permit Number: 205-026-0 Inspection Date: 2!5!2006 Rel Insp Num Packer h Pretest Initial D ept 15 Min. 30 Min. 45 Min. 60 Min. ~7~/ell '~ 1E-117 'Type Inj. ~ W TVD ~ - ~ 3330 I IA ~ 1300 ~ 2000 ~ ~~ 1970 ~~~ 1960 P.T. ~ 2050260 ~TypeTCSt I' SPT Test pSl ~ 832.5 QA 0 170 i ~ 170 ~ 170 ~ interval INITAL p~F P TUbing 15 T 15 ~ 15 ~ 15 ~I NOtes Initial Post startup test. Passed, no problems Monday, February O6, 2006 Page 1 of 1 • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 0 6 2006 Alaska Oil & Gas Cons. Coirunission Anchorage 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: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 205-026 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-117 8. Property Designation: 10. FieldlPool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15774' feet true vertical 3415' feet Plugs (measured) Effective Depth measured 15751' feet Junk (measured) true vertical 3415' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13-3/8" 5543' 2364' INTERMEDIATE 10477' 9-5/8" 10572' 3509' PROD. CASING 5369' 5-1/2" 15751' 3415' Perforation depth: Measured depth: 10570' - 15685' Slotted true vertical depth: 3509' - 3416' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9347' MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none F~~ b f 2DOfi Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1901 526 33 900 328 Subsequent to operation 2795 943 -9 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NtA if C.O. Exempt: Contact Robert W. Buchholz Printed Name Title Production Engineering Technician ~ Signature ~ " ~~ Phone 907-659-7535 Date Z /f / ~ Form 10-404 Revised 04/2004 d R Submit Original Only 1 E-117 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/29/2006 Commenced Water Injection f . r$ ~ a~. ~ ~ „,.: '.,,,~~,: ~ ~,~ ~ ~ f '~ ~ ~ a ° ° "~ FRANK H. MURKOWSKI, GOVERNOR j{[fE T # ~ ® 333 W. 7T" AVENUE, SUITE 100 ~~~~~A~~~ ~® ~~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: KRU 1 E-117 Sundry Number: 306-002 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing.: A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2006 Encl. Sincerely. i ~~ ~ STATE OF ALASKA ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~i~RECEIVED APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 JAN ~ 3 ZQ05 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Waiver~~ ~ Other ^/ Alter casing ^ Repair well ^ Plug Pertorations ^ C ~~~ ^^__ Stimulate ^ Time Extension ^ l.9 h~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ ~ ~~~.}~t Re-enter Suspended Well ^ ~ ~'~J"`~" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ~ ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 205-026/ ~/ 3. Address: Stratigraphic ^ Service ^ 6. API Number: 1 P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-00, 7. KB Elevation (ft): 9. Well Name andJVumber: RKB 95' 1 E-117,x- ~~ t~3 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15774' 3415' 15751' 3625' Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 5448' 13-3/8" 5543' 2364 INTERMEDIATE 1047T 9-5/8" 10572' 3510 A-SAND SLOTTED LINER 5369' S-1/2" 15751' 3415 U &SAND SLOTTED LINER 588g~ 5-1 /2" 15675' 3275 L2 D-SAND SLOTTED LINER 6179' 4-1/2" 15661' 3208 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): A: 10570-15685' Slotted; L1:9845-15631' Slotted; L2: 9580-15517' Slotted A: 341ti-3415'; L1:3412-3416'; L2: 3361-3416' 4-1l2" L-80 9347' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 506' 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 01 /10/06 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert D. Christensen Printed Name Robert D. rlSterlSe Title: Production Engineering Technician Signature ~ Phone 659-7535 Date ~~ ~ ~ Commission Use Onl Sund umber: Conditions of approval: Notify Commission so that a representative may witness -~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: W^~h~~C~~rCC=S S~~rC ~~ `~~~E ~ ~ 7~~h Subsequent For qui A roved b O APPROVED BY /v ~ D pp y. C I I N HE COMMISSION Date: ~3 Form 10-403 Re1>+s~d 07/2005 ~ ~ ~ f ~' ~~ ~ L Submit in Duplicate 1 E-117 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Multi-Lateral Water Injection service in West Sak Well 1 E-117, L1, L2. This well was placed on production service on November 4, 2005. This multi-lateral wellbore will provide pressure support for the West Sak A, B, & D sands. The D sand lateral injection tubing/casing annulus is isolated via a "Baker Payzone External Casing Packer" located @ 9456' and / 3352' tvd. The B sand lateral injection tubing/casing annulus is isolated via a lower ZXP 9-5/8" x 4-1/2" Liner Top Packer w/HRD located @ 9648' and / 3392' tvd. The A sand injection tubing/casing annulus is isolated via lower ZXP 9-5/8" x 4- 1/2" Liner Top Packer w/HRD located @ 10382' and / 3486' tvd. A MITIA was performed prior to placing the well on production service on 10/28/05; MITIA to 3000 psi for 30 minutes, Passed The following is a summary of the proposed plan: 1) Replace 1" x 3/16" GLV w/1" DV. 1) Close sliding sleeve with coif tubing unit and perform MITIA prior to injection. 2) Place well on Injection service. 3) Performed State witnessed MITIA shortly after injection is initiated and submit test results to the AOGCC. °UD u:.=_ ~ • dos-oaf i~'C:3A-NICAL INTEGRITY R :PORT ~ ~ ~~ ^~~ ~- "~c~-~ -- OPER ~ FIELD ~.1~~AS ~~~ ~~ =.. G r S ~ ~ ~ ~ S . ~ h ALL NUt-ID ER t ~ - ~ ` ~ ~ ~--~-. -~~ "~t'• ~ ~ G~Q.~G, .~ ~ LL DAT ~_ TD : .?~.. TVD ; PBTD : ?ID TVD Cas i^g :---~- Shoe : 105't~ 2-ID ~~ TVD ; i~V : ?~ ~T~`~i _.:,e.. Shoe . '-+.D T`TD ; ~'CP . ?•~ "''iD ~.. oi ' . L.~ ~ -c = S ~ Packer ~~'-~ TVD; Set at 1o3~z ole Sice ~~ ~~y and Peril to ~t7`tc . "'`Crt~?~IC~.1, lNTEGRTTY - P?~T #I r_nnulus Press Test• ~~ 15 nin ~l) min Comments `~'CHA?~ICr_I., INTEGRITv - PART # 2 Cement Volumes r Amt. Liner ~---P' ~ 300 b~a~, S Cs~ '~`'1.~ DV C~.t -ro1 to cover pens ~a 3 ~S~ 30~1~S -~•o coy~.~i -1V~w`t ~ c,3 ~s~i ~_:eoretical TOC _ C.° 3QZo 1SS TC~ ~ZS, to~(o 1~ ~w~--cJ Cement Bond Log (Yes or No) ~~.5 In AOtG~CC File~~S t''k C~~,c~,yCS,~~ Q i .per CBL Evaluation, :one above perfs ~~~~~~ r~nEt~cx~ ~,~~_.. ~~~~a~.4~c `'~~i..S eRc , c ~ . ~ Production Log: T_yve Evaluation i 1 CONCLJS ~ Ot1S ~ar~ rl. , Part f2 M=.~ ~ _ ~ r .. `~~~ '1 oC, - ~~ ~' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS )~ ~~,~' ~ 2nn~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ r(f~~ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extensior~R fJ17s. ~p,~~lx s Change Approved Program ^~ Operat. Shutdown^ Perforate ^ r~~$ Re-enter Suspended Well `" 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 205-026 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-117 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15774' feet true vertical 3415' feet Plugs (measured) Effective Depth measured 15751 feet Junk (measured) true vertical 3625 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13-3/8" 5543' 2364' INTERMEDIATE 10477' 9-5/8" 10572' 3510' UNDULATING A- 5369' 5-1/2" 15751' 3415' Perforation depth: Measured depth: A: 10382-15751' slotted, L1:9I87-15675' slotted, L2: 9482-15661' slotted true vertical depth: A: 3486-3415', L1:3412-3416', L2: 3361-3416' Tubing (size, grade, and measured depth) 4-112" , L-80, 9590' MD. Packers &SSSV (type 8~ measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation 2118 989 32 1371 323 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 305-323 Contact Loveland/McConnell, 659-7224 Printed Name Jerry Dethlefs Title Problem Well Superv Signature -w..-~~ Phone 659-7224 Date ~~~i ,/_~Sr Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only it • ConocoPhillips Alaska, Inc. West Sak Well 1E-117 (PTD 2050260) REPORT OF SUNDRY OPERATIONS December 16, 2004 As per Sundry #305-323, the following activities were performed to convert injection well lE- 117 to adevelopment well for a limited period of time. Production rates follow. 10/28/05: Shifted CMU closed with a "B" shifting tool. Tested IA to 3000 psi for 30 min, 57 psi non-linear bleed off, passed. Shifted CMU open. Well left shut in for slickline work. 10/29/05: REPLACED 1" DV @ 1876' RKB W/ 1" X 3/16" GLV (1460 TRO). 30B COMPLETE. 11/04/05: Placed well in production service, gaslift assist 16-DEC-05 09:41 WELL TEST SUMMARY REPORT FORM- - LIFT LIFT ----TEST DS WL END--- CHK FTP FTT OIL WATER %WC FLUID GAS GOR RATE PRES 1E 117 12/13/05 110 323 43 2118 32 1 2150 989 467 1505 1371 1 E 117 12/04/05 110 307 41 2364 38 2 2402 658 .278 1530 1381 1E 117 11/26/05 100 302 43 2341 40 2 2381 653 279 1233 1376 1E 117 11/19/05 130 298 40 2815 51 2 2867 1105 392 1504 1384 1E 117 11/17/05 102 278 40 2991 63 2 3053 328 110 1571 1382 1E 117 11/16/05 80 282 40 2897 1 0 2898 366 126 1710 1391 1E 117 11/13/05 78 315 44 2745 68 2 2813 218 79 1313 1390 1E 117 11/07/05 65 391 38 1676 99 6 1774 0 0 1508 1379 1 E 117 11 /07/05 65 391 1511 1679 100 1780 0 0 1511 1379 1 E 117 11 /06/05 60 410 37 1560 130 8 1690 0 0 1555 1376 NSK Problem Well Supervisor FW: Plans for 1E-117 • SubjectFW: Plans'for 1 E-117 From: NSK Problem Well Supv <n1617~r,conocophilli}~s.co~n> ~~ ~ --r~~ Date: l ri, 1 ~~ Dec 2005 0:58:19 -0900 To: tom i~~~~und~r,ri~adn~in.state.ak.us, "Spenceley, Neil" ~'V!eiLK.Shcil~~l~~yr~r;coru~coT?hillips.com-> CC: NS}~ Problci7~ ~~'ell Suln~ ~'n1G17~~r!conoc~>hhillips.com::-~ Neil and Tom: After reviewing the approved 10-403 {#305-323) to produce 1 E-'117, and from the note received from Tom Maunder about approval to extend the production period, the plan forward will be the following: 1. Produce the well until January 15, 2006; 2. Reconfigure the welE for injection and perForm and MIT; 3. Submit a 10-403 to covert the permit to injection service; 4. Place well on injection; 5. Notify AOGCC Inspector for witnessing the initial M1T. Tom: It appears I owe you a 10-404 and production report, I will get that in the mail. If you find I have missed anything please let me know. Thanks! Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From; Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 15, 2005 4:31 PM To: Spenceley, Neil Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Dethlefs, Jerry C; Paul, Jerome Subject: Re: Plans for 1E-117 Neil, et al, Extending the production period is not a problem. I need to check the paperwork, but prior to returning the well to injection, sundry requests should be filed requesting that change. Jerry is familiar with that process. Call or message with any questions. Tom Maunder, PE AOGCC Spenceley, Neil wrote, On 12/15/2005 3:59 PM: Tom, As we discussed we would like to continue producing the well to enable us to properly diagnose a potential production problem. To accomplish this I request to extend the pre-production period until January 15th, 2006. Please call me if you have any questions or concerns. Thanks. Neil Spenceley, P. Eng Drillsite Petroleum Engineer ConocoPhillips Alaska -Greater Kuparuk Area 1 of 2 1/3/2006 12:48 PM • • WELL LOG TRANS~VIITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs ~4 1E-117, ~p~'~~{v November 18, 2005 AK-MW-3775114 1 LDWG formatted Disc with verification listing. API#: 50-029-23251-00 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND 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: RECEIVED D ~C ~ 7 200' Alaska Ol & Gas Goaa.C,amt Anchorage • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs November 18, 2005 ~~~~~ 1E-117 PBl, ~(~5-~AK-MW-3775114 1 LDWG formatted Disc with verification listing. API#: 50-029-23251-70 PLEASE ACKNOWLEDGE RECEIPT 13Y SIGNING AND RE'I'LJRNING A COPY OF THE TRANSMTTTAT, LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~~' Signed • ConocoPhillips Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 November 11, 2005 pc~~" `~ Commissioner NOV ~ ~ 200 State of Alaska Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Cotrartissian 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 E-117, 1 E-117L1 and 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 E-117, 1 E-117L1, 1 E-117L2. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Mukavitz at 263-4021. Sincerely, R. Thomas ° Kuparuk Drilling Team Leader CPAI Drilling RT/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEI~/ED NOV ~ ~ 2D05 WELL COMPLETION OR RECOMPLETION REPO-1~~9o1L~(5~~1$$1°~ 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other,XXX Pre-Produced Injector ~ 1b. Well Class: ~ Development ^ Exploratory ^ Service 0 Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ or Aband.: October 16, 2005 12. Permit to Drill Number. 205-026 / 305-280 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 21, 2005 13. API Number: 50-029-23251-00 4a. Location of Well (Governmental Section): Surface: 11' FSL, 228' FEL, Sec. 16, T11 N, R10E, UM 7. Date TD Reached: July 9, 2005 " 14. Well Name and Number: 1 E-117 At Top Productive Horizon: 3724' FNL, 3595' FEL, Sec. 27, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB / 95' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 3639` FNL, 3590' FEL, Sec. 34, T11N, R10E, UM 9. Plug Back Depth (MD + ND): 9592' MD / 3382' ND West Sak Oil POOI 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301 ~ ~ y- 5959601 ~ Zone- 4 10. Total Depth (MD + ND): ~ 15774' MD / 3415' TVD ~ 16. Property Designation: ADL 25660, 25651 TPI: x- 552292 y- 5950599 Zone- 4 Total Depth: x- 552344 ' - 5945406 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 470 18. Directional Survey: Yes 0 No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2052' MD 21. Logs Run: GR/Res, CCL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.5# H-40 Surf. 108' Surf. 108' 42" 390 sx AS I 13-3/8" 68# L-80 Surf. 5544' Surf. 2364' 16" 1047 sx AS Lite, 280 sx DeepCrete 9-5/8" 40# L-80 Surf. 10572' Surf. 3510' 12.25" 299 bbls LiteCrete 5.5" 15.5# L-80 10382' 15752' 3486' 3415' 8.5" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 9347' 9369', 9648' slotted liner from 10570'-15685' MD 3508'-3416' ND 10382' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n!a 26. PRODUCTION TEST Date First Production November 4, 2005 Method of Operation (Flowing, gas lift, etc.) Pre-Produced Injector -shares rate with 1 E-117L1 and 1 E-117L2 Date of Test 11/6/2005 Hours Tested 5 hours Production for Test Period --> OIL-BBL 335 GAS-MCF 163 WATER-BBL 27 CHOKE SIZE 60% GAS-OIL RATIO 531 Flow Tubing press. 411 psi Casing Pressure 1376 Calculated 24-Hour Rate -> OIL-BBL 1565 GAS-MCF 783 WATER-BBL 134 OIL GRAVITY -API (cArr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". _ - NONE ~~ ~~~. Ei`~~` ~. ~QQ~J 'x 1`' L~.T~7~5~ e ~_~~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ^~~~4~L 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-117 Top West Sak A2 10574' 3510' Base West Sak A2 15774' 3415' N/A 1 E-117P61 TD 11593' 3506' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitz @ 263-4021 Printed Na Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader 1,1.jrY~~ r ~ Signature •.~-----y Phone ~~-E-~°r~~y Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 • ConocoPhillips Alaska Page 1 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phas 6/20/2005 101:30 - 03:00 I 1.501 MOVE I DMOB ~ MOVE 03:00 - 04:00 1.00 MOVE MOVE MOVE 04:00 - 06:00 2.00 MOVE MOVE MOVE 06:00 - 10:00 4.00 MOVE RURD MOVE 10:00 - 12:00 I 2.00 I WELCT~ NUND RIGUP 12:00 - 15:15 3.25 DRILL OTHR RIGUP 15:15 - 20:00 4.75 DRILL ~ PULD RIGUP 20:00 - 21:15 1.25 DRILL PULD I{RIGUP 21:15 - 21:45 0.50 WELCT BOPE RIGUP 21:45 - 22:30 22:30 - 23:00 23:00 - 23:30 0.751 DRILL PULD RIGUP 0.50 DRILL PULD SURFAC 0.50 DRILL OTHR SURFAC 23:30 - 00:00 16/21/2005 100:00 - 01:15 0.50{DRILL (TRIP ISURFAC 1.25 I DRILL I DRLG ISURFAC 01:15 - 01:30 0.25 DRILL TRIP SURFAC 01:30 - 03:00 1.50 DRILL OTHR SURFAC 03:00 - 03:45 0.75 DRILL OTHR SURFAC 03:45 - 04:15 0.50 DRILL SFTY SURFAC 04:15 - 04:45 0.50 DRILL SURV SURFAC 04:45 - 06:00 1.25 DRILL DRLG SURFAC 06:00 - 06:30 0.50 DRILL SURV SURFAC 06:30 - 08:15 1.75 DRILL DRLG SURFAC 08:30 - 09:45 10.251 DRILL f DRLG ISURFAC 09:45 - 10:00 0.25 DRILL SURV SURFAC 10:00 - 11:15 1.25 DRILL DRLG SURFAC 11:15 - 11:30 0.25 DRILL SURV SURFAC 11:30 -12:00. 0.50 DRILL DRLG SURFAC 12:00 - 12:30 I 0.501 DRILL I DRLG ISURFAC Spud Date: 6/20/2005 Start: 6/20/2005 End: 8113!2005 Rig Release: Group: Rig Number: Description of Operations Disconnected service loops between rig complex's, blow down lines and prep rig for move Moved rig complex's and staged on pad Moved sub base from 1 E-105 and spotted over well Spotted in rig complex's and rigged up, connected service loops and bermed around rig, completed rig acceptance checklist and ACCEPTED RIG at 10:00 Hrs 6/20/2005 NU 21 1/4" 2M diverter and 16" line, loaded pipe shed with 5" DP and took on water in the mud pits Fin loading pipe shed with 5" DP and HWDP and strapped same, began mixing spud mud, rig went on highline at 13:00 hrs PU and stood back 150 jts (50 stds) of 5" DP PU and stood back 29 jts 5" HWDP and jars (10 stds) Function tested diverter, knife valve and accumulator, good test. Note: John Crisp with AOGCC waived witnessing of test, initial pressure 2900 psi, after closing 1800 psi. 200 psi buildup req 45 seconds, full charge 3 min 24 seconds, nitrogen bottles (5) avg 2275 psi. PU and stood back 1 std of 8" NM Flex dc's PU and MU 16" bit #1 on 8" motor with 1.83 deg bend RIH to 32' Flooded conductor with water and checked lines for leaks, pressure tested mudline to 3,500 psi Washed down from 32' and tagged cement inside conductor at 107' and cleaned out to 108', washed down at 30 rpm's, 450 gpm, 325 psi, rot wt 46K, up wt 40K, do wt 44K Drilled 16" hole from 108' to 180' MD/ 180' TVD (72') ART 1.1 hrs, 5-7K wob, 30 rpm's, 448 gpm, 8.8 ppg mw, on btm pressure 450 psi, rot wt 40K, up wt 40K, do wt 40K. POOH f/ 108' to 32'. MU BHA. Plug in and upload Sperry Sun MWD. MU Float sub, UBHO, orient MWD and motor. RIH w. 1 stand NM flex collars to 162'. PJSM. RU Sperry Sun Gyro unit. Run Gyro @ 162'. Drilled 16" hole from 180' to 256' MD/ 256' TVD (76') ART .93 hrs, 10-12K wob, 30-40 rpm's, 440 gpm, 8.9 ppg mw, on btm pressure 1150 psi, rot wt 55K, up wt 55K, do wt 56K. Run Gyro @ 262'. Drilled 16" hole from 256' to 347' MD/ 347' TVD (91') ART .42 hrs, AST 1.22 hrs, 10-12K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1325 psi, rot wt 59K, up wt 57K, do wt 59K. Run Gyro @ 347'. Drilled 16" hole from 347' to 439' MD/ 439' TVD (92') ART .23 hrs, AST 1.08 hrs, 10-15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1400 psi, rot wt 63K, up wt 60K, do wt 63K. Run Gyro @ 439' Drilled 16" hole from 439' to 530' MD/ 529' TVD (92') ART .23 hrs, AST .73 hrs, 10-15K wob, 60 rpm's; 500 gpm, 8.9 ppg mw, on btm pressure 1400 psi, rot wt 63K, up wt 60K, do wt 63K. Run Gyro @ 530'. Drilled 16" hole from 530' to 560' MD/ 559' TVD (30') AST .43 hrs, 15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1425 psi, rot wt 67K, up wt 66K, do wt 67K. Drilled 16" hole from 560' to 621' MD/ 619' TVD (61') ART .15 hrs, AST Printed: 10/28!2005 10:29:27 AM ConocoPhillips Alaska Page 2 of 33 • Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-117 1E-117 ROT -DRILLING Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Date From - To Hours Code Code' Phase 6/21/2005 ~ 12:00 - 12:30 ~ 0.50 ~ DRILL ~ DRLG ~ SURFAC 12:30 - 12:45 0.25 DRILL SURV SURFAC 12:45 - 00:00 11.25 DRILL DRLG SURFAC 00:00 - 07:30 I 7.501 DRILL I DRLG ~ SURFAC 07:30 - 10:30 I 3.00 I DRILL I REAM I SURFAC 10:30 - 12:00 1.50 DRILL TRIP SURFAC 12:00 - 12:30 0.50 DRILL OTHR SURFAC 12:30 - 13:00 0.50 DRILL TRIP SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 14:00 0.50 DRILL REAM SURFAC 14:00 - 00:00 I 10.00 I DRILL I DRLG I SURFAC 16/23/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I SURFAC 12:00 - 13:00 13:00 - 20:15 20:15 - 20:30 20:30 - 00:00 6/24/2005 100:00 - 04:15 1.001 DRILL OTHR SURFAC 7.25 DRILL I DRLG SURFAC Description of Operations .30 hrs, 15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on bttm pressure 1425 psi, rot wt 67K, up wt 66K, do wt 67K. Run Gyro @ 621'. Drilled 16" hole from 621' to 1453' MD/ 1311' TVD (832') ART 1.44 hrs, AST 7.74 hrs, 15-30K wob, 60 rpm's, 508 gpm, 8.9-9.3 ppg mw, on btm pressure 1525-1825 psi, off bttm press 1400-1550 psi, on bttm torque 3-6k, off bttm torque 2-3k, rot wt 70-90K, up wt 69-92K, do wt 67-87K. Drilled 16" hole from 1453' to 1956' MD/ 1528' TVD (503') ART .65 hrs, AST 5.51 hrs, 30-33K wob, 60 rpm's, 508 gpm, 9.2-9.6 ppg mw, on btm pressure 1700-1825 psi, off bttm press 1550-1600 psi, on bttm torque 5k, off bttm torque 4k, rot wt 87-81 K, up wt 92K, do wt 82-73K. Backream out of hole f/ 1956' to 901' w/ 700-800 gpm, 2700 psi, 80 rpm. No problems. POOH f/ 901' to surface on elevators. No problems. Change bend on motor f/ 1.83 deg to 1.5 deg., remove UBHO sub. Trip in hole w! BHA, HWDP and jars to 1082'. Continue trip in hole w! 5" dp f/ 1082' to 1915'. Precautionary wash and ream f/ 1915' to 1956' w/ 80 rpm, 697 gpm, 3700 psi (plugged nozzle), torque 7k. Drilled 16" hole from 1956' to 2800' MD/ 1716' TVD (844') ART 2.24 hrs, AST 3.38 hrs, 10-30K wob, 80 rpm's, 508- 698 gpm, 9.6 ppg mw, on btm pressure 2250-3000 psi, off bttm press 1575-2750 psi, on bttm torque 7-10k, off bttm torque 6k, rot wt 82-75K, up wt 88-90K, do wt 75-64K. Drilled 16" hole from 2800 to 3865' MD/ 1953' TVD (1065') ART 4.10 hrs, AST 3.36 hrs, 10-30K wob, 90-100 rpm's, 554-800 gpm, 9.6 ppg mw, on btm pressure 2050-3700 psi, off bttm press 1850-3700 psi, on bttm torque 7-10k, off bttm torque 7-8k, rot wt 75-78K, up wt 87-100K, do wt 60-65K. Avg BG gas 35 units. Max gas 70 units while drilling @ 3675' Note: While drilling @ 3680'-3772' MD/ 1919'-1937' TVD, oil shows started appearing @ shakers. This would have been f/ approx 3605'-3630' MD/ 1904'-1910' TVD. CBU to clean hole. Lots of cuttings. Screen one shaker w 50's, other two have 140's. Drilled 16" hole from 3865 to 4439' MD/ 2090' TVD (574') ART 2.15 hrs, AST 2.0 hrs, 15-25K wob, 100 rpm's, 664-800 gpm, 9.6 ppg mw, on btm pressure 3100-3700 psi, off bttm press 2950-3700 psi, on bttm torque 10-12k, off bttm torque 7-11 k, rot wt 78-84K, up wt 100-120K, do wt 65-57K. Avg BG gas 50 units. Max gas 151 units while drilling @ 0.25 DRILL. OTHR SURFAC Change one shakerw 38's, other two have 50's. Lost 80 bbls fluid in 20 min to rockwasher prior to change. 3.50 DRILL DRLG SURFAC Drilled 16" hole from 4439' to 4658' MD/ 2133' TVD (219') ART 1.3 hrs, AST .44 hrs, 20-25K wob, 100 rpm's, 664-800 gpm, 9.6 ppg mw, on btm pressure 3100-3700 psi, off bttm press 2950-3600 psi, on bttm torque 11-12k, off bttm torque 10-11 k, rot wt 82K, up wt 122K, do wt 54-52K. Avg BG gas 60 units. Max gas 108 units while drilling @ 4540'. Note: Shaker screens @ midnight :one set of 84's, one set of 50's, one set of 110/110/84. 4.25 DRILL DRLG SURFAC Drilled 16" hole from 4658' to 4886' MD/ 2198' TVD (228') ART 1.83 hrs, AST 1.18 hrs, 0-25K wob, 100 rpm's, 700-800 gpm, 9.6 ppg mw, Printed: 10/2&2005 10:29:27 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-1.17 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date :From - To Hours Code Code Phase 6/24/2005 100:00 - 04:15 I 4.251 DRILL I DRLG I SURFAC 04:15 - 06:15 I 2.001 DRILL I REAM I SURFAC 06:45 - 02:00 I 5.25 DRILL DRLG SURFAC 12:00 - 16:45 I 4.75 DRILL I DRLG SURFAC 16:45 - 00:00 I 7.25 I DRILL I REAM I SURFAC 16/25/2005 100:00 - 04:00 I 4.001 DRILL I REAM I SURFAC 04:00 - 04:30 0.50 DRILL TRIP SURFAC 04:30 - 05:00 0.50 DRILL TRIP SURFAC 05:00 - 06:00 1.00 DRILL OTHR SURFAC 06:00 - 06:45 0.75 DRILL OTHR SURFAC 06:45 - 07:00 0.25 DRILL OTHR SURFAC 07:00 - 07:15 0.25 DRILL TRIP SURFAC 07:15 - 07:45 0.50 RIGMNT RSRV SURFAC 07:45 - 08:15 0.50 RIGMNT RGRP SURFAC 08:15 - 10:45 2.50 DRILL TRIP SURFAC 10:45 -12:00 I 1.25 ~ DRILL I REAM I SURFAC 12:00 - 14:00 2.00 DRILL I DRLG ~ SURFAC 14:00 - 15:45 I 1.751 DRILL. I REAM I SURFAC 15:45 -16:15 0.50 DRILL CIRC SURFAC 16:15 - 19:30 3.25 DRILL TRIP SURFAC 19:30 - 20:00 0.50 DRILL PULD SURFAC 20:00 - 20:45 0.75 DRILL OTHR SURFAC 20:45 - 21:45 1:00 DRILL PULD SURFAC 21:45 - 22:15 0.50 DRILL OTHR SURFAC 22:15 - 22:45 0.50 CASE OTHR SURFAC 22:45 - 00:00 I 1.251 CASE I RURD I SURFAC Page 3 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations on btm pressure 2950-3700 psi, off bttm press 2750-3500 psi, on bttm torque 12k, off bttm torque 10-11 k, rot wt 82K, up wt 122-145K, do wt 52-44K. Avg BG gas 50 units. Max gas 68 units while drilling @ 4820'. Backream out of hole. Pull slow (2-10'/hr), pumping 800 gpm, rotate 100 rpm. Ream f/ 4886' to 4327', torque 12-14k. RIH on elevators f/ 4327' to 4793', orient to high side and RIH to 4886'. Drilled 16" hole from 4886' to 5164' MD/ 2273' TVD (278') ART 1.15 hrs, AST 1.8 hrs, 0-25K wob, 100 rpm's, 700-800 gpm, 9.6 ppg mw, on btm pressure 2950-3700 psi, off bttm press 2750-3500 psi, on bttm torque 12k, off bttm torque 10-11 k, rot wt 82K, up wt 122-145K, do wt 52-44K. Avg BG gas 50 units. Max gas 68 units while drilling @ 4820'. Backream @7' per min. Drilled 16" hole from 5164' to 5361' MD/ 2329.61' TVD (197') ART .4 hrs, AST 1.78 hrs, 15-20K wob, 100 rpm's, 710-800 gpm, 9.6 ppg mw, on btm pressure 3650-3750 psi, .off bttm press 3550-3675 psi, on bttm torque 12-15k, off bttm torque 13-16k, rot wt 85K, up wt 155-175K, do wt 35K. Avg BG gas 160 units. Max gas 475 units white drilling @ 5260'. Backream @ 8' per min. Monitor well. Backream out of hole f/ 5361' to 2200' @ 700 to 800 gpm, 3100-3650 psi, 100 rpm. Pulling slow, 10'/min. Lots of sand returns. Backream out of hole f/ 5361' to 2200' @ 800-550 gpm, 3100-2300 psi, 100 rpm. Pulling slow, 10'/min.Torque 5-9k. Sand and clay and gravel in returns. Pull and stand back stand NM flex drill collar. Pull bit out of hole, clean a little, and grade bit. UD MWD. PU MWD. Remove restrictor to allow more flow w/ less pressure. Upload MWD. Orient MWD and motor. MU stand flex NMDC. Service top drive. Repair hydraulic fitting on top drive. RIH f/ 162' to 5109' with no problems, fill pipe @ HWDP and every 25 stands. Wash thru 5109' w/ no problems. Precautionary ream f! 5258'- 5350', orient high side, wash fl 5350' to 5361' Drilled 16" hole from 5361' to 5560' MD/ 2367' TVD (199') ART .51 hrs, AST .48 hrs, 10-20K wob, 100 rpm's, 795 gpm, 9.6-9.7 ppg mw, on btm pressure 3000 psi, off bttm press 2950 psi, on bttm torque 11-12k, off bttm torque 13k, rot wt 90-K, up wt 160-150K, do wt 60-63K. Avg BG gas 30units. Max gas 40 units while drilling. BU gas max 290 units Backream @ 8' per min. Monitor well. Backream out of hole f/ 5560' to 5074'. 100 rpm's, 867 gpm, 3300 psi, Pump dry job, blow down top drive. POOH on elevators. UD BHA. Download MWD UD MWD, bit and mtr. Calc displ 54.1 bbl, actual 56 bbls. Clean rig floor. Dummy run Vetco/Gray 13 3/8" landing joint and hanger. Load shoulder to rig floor 29.89'. Rig up to run 13 3/8", 68 ppf, L-80 BTC casing. Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To .Hours Code Code Phase 6/26/2005 00:00 - 00:30 0.501 CASE SFTY SURFAC 00:30 - 04:15 3.75 CASE RUNC SURFAC 04:15 - 05:00 I 0.751 CASE I CIRC I SURFAC 05:00 - 07:00 2.00 CASE RUNC SURFAC 07:00 - 07:30 0.50 .CASE OTHR SURFAG 07:30 - 07:45 0.25 CASE RUNC SURFAC 07:45 - 08:15 I 0.50 CASE CIRC SURFAC 08:15 - 09:15 I 1.001 CASE I RUNC I SURFAC 09:15 - 10:15 1.00 CASE RUNC SURFAC 10:15 - 10:45 0.50 CASE RUNC SURFAC 10:45 - 11:15. I 0.501 CASE RUNC I SURFAC 11:15 - 11:30 0.25 CASE RUNC SURFAC 11:30 - 12:00 0.50 CASE RUNC SURFAC 12:00 - 16:15 I 4.251 CEMENIiCIRC I SURFAC 16:45 - 19:45 3.00 CEMEN~PUMP SURFAC 19:45 - 21:45 I 2.001 CEMENIi DISP I SURFAC Page 4 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations PJSM on running 13 3/8", 68 ppf, L-80, BTC. Run 13 318": MU Weatherford model 303 Float Shoe, w/ stop ring 10' above and Weatherford bow centralizer over stop, also on box, MU jt # 2 with stop 10' below box and bow centralizer over stop, Weatherford model 402 Float collar on bottom of jt # 3 (all below joints baker locked to bottom of collar of jt #3. Jts # 3-15 have centralizers on box. Total of 16 centralizers. All casing 13 3/8'; 68 ppf, L-80, BTC casing. Torque to 10,000 ft/Ib. Run to jt # 56 (2187') Record PU & SO wt's every 10 jts. Break circ slow @ 2187', then bring up to 6 bpm w/ 325 psi, work jt 56 down slow, then the same with joint 57 to depth of 2265'. Circ total of 160 bbls. MW out 10 ppg, mw in 9.7 ppg. Final pressure 300 psi @ 6 bpm. PU wt 160k, SO wt 98K Continue running casing f/ jt #58 to jt #88. (2265' to 3525'). Record PU & SO wt's every 10 jts. L/D jt #$9(43.56'). Pin end bad. Replace jt. with spare joint # 141(37.54'). Continue running casing to jt # 89 in hole (3525'-3574'). Break circ @ 4 bpm w/ 290 psi while running jt # 90 and #91( 3574'-3661'). Circ total of 100 bbls. Pl1 wt 245k, SO wt 85k. Continue running casing to jt # jt 114 (3661' - 4600'). PU 295, SO wt 70k Break circ @ 4 bpm w1300 psi while running jt # 115, then 5 bpm 350 psi w/ running jt # 116 (4601'- 4684'). Circ total of 120 bbls. Continue running casing f! 4684' to 5283' Qt #116-# 131). PU wt 350k, ISO vut 70k Tagged up @ 5283' (jt # 131) in hole, work pipe and circ w/ Frank's fillup tool. PU wt 350, SO wt 70k, Pulled to 480k to free up, went down w/ 70-80k. Ran jt # 132 f/ 5283' to 5320'. Continue running casing f/ jt # 131 to jt # 137 (5320- 5510') MU Vetco/Gray hanger and landing jt. Remove casing slips, RIH f/ 5510' to 5543.56' landed. PU wt 350k, So wt 75k, blocks 35k of this wt. Circ and condition mud prior to cement. Reciprocated 9 times w/ only 4' of pipe movement @ surface then hanging upon base of conductor Note; Had no pipe movment and worked pipe to btm after working pipe. 9 times- Set pipe on hanger. Circ @ 7bpm w/ 475 psi. Circ total of 1785 bbls. Mud properties before: wt 9.7 ppg, vis 232, PV 43, YP 73. Mud properties after: wt 9.5 ppg, vis 49, PV 19, YP 14. PJSM prior to cement job. Dowell pump 10 bbls CW 100 (8.3 ppg) @ 4 bpm, test lines to 3500 psi, pump 40 more bbls CW 100 (8.3 ppg) @ 4 bpm w/ 75 psi, pump 50 bbls mudpush w/ Red Dye (10.5 ppg) @ 5.8 bpm ,drop bottom plug, pump 792 bbls (990sx) lead Arctic set lite (10.7 ppg) (yield 4.49 cu ft/sx) @ 7 bpm w/ 73-121 psi, 124 bbls (280sx) tail DeepCrete (12.0 ppg) (yield 2.48 cu ft/sx) @ 7bpm w/ 128-87 psi, drop top plug, pump 20 bbls water through tub. Rig displace cement w/ 9.5-9.6 ppg mud. Pump @ 7.5 bpm until last 82 bbls pumped pressure increasing f/ 400 psi to 820 psi. Lost returns @ 86 bbls left to bump, slowed to 5 bpm 650 psi, until last 10 bbls, then to 3 bpm @ 600 psi. Bump plug @ 7956 strokes (801 bbl) with 1100 psi. Note: Saw mud push @ 4300 strokes into displacement (433 bbls). Mud returns were 10.2+ ppg until losing returns @ 7100 strokes (715 bbls), Did not have any true signs of cement to surface. Unable to precirocate casing due to no movement. Printed: 10/28/2005 10:29:27 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase - _- r 6/26/2005 21:45 - 00:00 2.251 CEMEN OTHR I SURFAC 6/27/2005 ~ 00:00 - 02:00 I 2.001 CEMENlI OTHR I SURFAC 05:00 - 06:00 I 1.00 CEMENl~TR PD SURFAC 06:00 - 06:30 0.50 CEMEN OTHR SURFAC 06:30 -11:30 5.00 CEMEN OTHR SURFAC 11:30 - 12:00 0.50 CEMEN~OTHR SURFAC 12:00 -12:45 0.75 CASE RURD SURFAC 12:45 - 14:15 1.50 WELCT OTHR SURFAC 14:15 - 15:00 0.75 WELCT NUND SURFAC 15:00 - 20:45 5.75 WELCT OTHR SURFAC 20:45 - 21:00 0.25 WELCT NUND SURFAC 21:00 - 22:45 1.75 WELCT NUND SURFAC 22:45 - 23:00 0.25 WELCT OTHR SURFAC 23:00 - 00:00 1.00 WELCT NUND SURFAC 6/28/2005 00:00 - 00:15 0.25 WELCT NUND SURFAC 00:15- 02:00 1.75 WELCT NUND SURFAC 02:00 - 07:00 5.00 WELCT BOPE SURFAC 07:00 - 07:15 0.25 WELCT ROPE SURFAC 07:15 - 09:00 1.75 DRILL PULD SURFAC 09:00 - 10:00 1.00 DRILL PULD SURFAC 10:00 - 12:00 2.00 DRILL PULD SURFAC 12:00 - 15:00 3.00 DRILL PULD SURFAC 15:00 - 18:00 3.00 DRILL TRIP SURFAC 18:00 - 18:15 0.25 DRILL DEQT SURFAC 18:15 - 19:45 1.50 DRILL TRIP SURFAC 19:45 - 20:00 0.25 DRILL TRIP SURFAC Page 5 of 33 Spud Date: 6/20/2005 Start: 6/20!2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Cleaning out diverter stack, trying to catch sample @ Vetco Gray quick connect, thick fluid would not come out 2" valve. UD Dowell cement head. Prepare to UD landing joint. R/D casing equipment, UD landing joint, Flush thick mud f/ stack w/ water usnig 5" dp and rig pumps. N/D diverter line and diverter stack. RIH w/ 1.315" Hydril CS tubing (OD of connection 1.61 "), 2.25 ppf. Run between fluts in hanger and landing ring (1.625" clearance). RIH to 53' RKB. Circ w/ rig water press (70 psi). Returns 10.2+ ppg. RIH 2 more joints to 112' RKB. Circ w/ Rig water pressure thick stuff 10.2+ ppg. POOH w/ 1.315" Hydril CS tubing. Welder cut 4" wide x 4" hole in conductor to take returns to cellar. Rig & run 8 jts 1-114" Hydril tubing to 264' RKB, 80' below ground level in 13-3/8" x 20" annulus (Volume 14.6 bbls) &.156' in 13-3/8" x 16" (11.6 bbls), washing each joint down with fresh water and was unable to make any further progress. Flushed well with 58 bbls fresh water using Dowell. Mixed & pumped a total of 46.0 bbls (57 sacks) Lead cmt mixed @ 10.7 ppg. Had good 10.7 ppg cement returns to surface after pumping 26.1 bbls cement, C.I.P. @ 10:50 hrs 6/27/05. Pulled out of the hole w/ tubing and the fluid level dropped 4". Cleanup cellar box prep f/ welder R/D casing equipment f/ rig floor. Crane removed diverter pieces and set in Vetco/Gray wellhead equip in the cellar area. NU Vetco gray multibowl wellhead. Test seal on graylock. Failed 4 different times. Test failed @ pressures of 4500 psi, 4800 psi, 5000 psi and again 5000 psi. Remove Vetco gray multibowl. Will install bowl assigned to 1J-154. NU Vetco/Gray multibowl (used the one assigned to 1J-154, set up as a producer). Test seal sub to 5000 psi f/ 15 min. OK. Change orientation of valves on Vetco/Gray multibowl. Change orientation of valves on Vetco/Gray multibowl f/ injector well. NU 13 5/8" BOPE. RU and test 13 5/8" BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Test using lower test plug. One test made @ 5000 psi high and 250 psi low to test all valves which were changed around. Only lower annulus valve of multibowl was NOT TESTED. This valve will be tested to 3000 psi when testing casing. Other tests were to 3000 psi. high and 250 psi tow. Install wear bushing - RILDS P/U and single in hole 51 jts 5" DP from pipe shed Stand back these 17 stds in derrick -Clean rig floor M/U BHA #4 -w/ bit & 9.625 Geo -Pilot '* Note"" Had to have Bit rep come over because the bit breaker would not fit the bit. He had the welder do a small modification to where it would fit after he confered with his engineers. Con't PU BHA #4 - Up Load MWD TIH picking up singles from pipe shed. Install ghost reamers @ 824' and 1666' behind bit. Break in Geo Pilot Bearing Con't TIH PU singles from pipe shed TIH w/ DP from derrick - Dn wt 35K -Will need to circu and wash to FC Printed: 1028/2005 70:29:2/ AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date 'From - To Hours Code Phase Code 6/28/2005 20:00 - 22:15 2.25 DRILL REAM SURFAC 22:15 - 23:45 1.50 DRILL DEOT SURFAC 23:45 - 00:00 0.25 RIGMNT RSRV SURFAC 6/29/2005 00:00 - 01:30 1.50 RIGMNT RSRV SURFAC 01:30 - 02:30 1.00 RIGMNT RGRP SURFAC 02:30 - 05:00 2.50 CEMEN DSHO SURFAC 05:00 - 06:15 I 1.251 DRILL I CIRC I SURFAC 06:15 - 07:00 0.75 DRILL LOT SURFAC 07:00 - 12:00 5.00 DRILL DRLG iNTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRMI 00:00 - 11:00 11.00 DRILL I DRLG I INTRM1 11:00 - 12:00 I 1.00 I DRILL I CIRC ~ INTRM1 12:00 - 17:15 I 5.251 DRILL I DRLG I INTRMI 17:15 - 18:30 I 1.251 DRILL I DRLG ~ INTRM1 18:30 - 00:00 I 5.501 DRILL I DRLG I INTRM1 Page 6 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Wash and Ream 4670' to 5450' MD - 500 gpm, PP 1100 psi, RPMs 50, Troq 13-15k -(Surface Float Collar @ 5461' MD) Circu 10 min - RU & Test Csg to 3000 psi on chart for 30 min - No loss Slip & Cut drill line. Con't Slip & Cut drill line (59' cut) -Service Top Drive & Draworks Repair fitting on top drive lobe oil pump cooler Drlg shoe track + 20' new hole f/ 5560' to 5580' MD (2371' TVD) PP 2050, PR SPM 188, 735 gpm, WOB 10 -20k, RPMs 90- No problems noted on drill out. PU to shoe -Circu BU -Condition mud until uniform in and out. -Mud weight 9.1 ppg , Vis 60 RU for & Preform LOT - EMW 13.1 ppg Drlg 12.25" hole 5580' to 6117' MD (2467' TVD) ADT 3.6 hrs - PP 2050 psi, PR 188 SPM, 735 gpm, WOB 10-20k, RPMs 124 -Torg off Bttm 12 -18k, on Bttm 12-18k. Mud. tubes 2.5% (1 % being CO)? - No problems noted - 9.625" Geo-Pilot appears to be hooking up better than the 8" tools of the past as we started drilling, we will see how it preforms as ewe drill.- Drilling Engineer (Pat Reilly) is on site to try and increase our daily ROP by changing some drilling parameters, WOB, Pump rate, RPMs ect,ect. to maximize footage drilled per tour. Drlg 12.25" hole 6117' to 7418' MD (2826' TVD) ADT 8.4 hrs- PP 2100 psi, PR 167 SPM, 700 gpm, WOB 10-20k, RPMs 130 -Torg off Bttm 14-18k, on Bttm 13-17k. Up wt 188k, Dn wt 56k, Rot wt 94k - ECD 9.68 Adding tubes to mud to help with torq. We will try to maintain 2.5-3 tubes (Not Including CO) and see if this helps with high Torqs? -High flow rates had to be reduced to about 700+ gpm to get good preformance from the geo-pilot. This 9.625" OD tool appears to work fairly well and stay hooked up. So far it has shown to give good responce with 40 to 70% deflection if we do not pump faster than 720-730 gpm. The Sperry DD is keeping th FR and RPMs as HIGH as possible to maximize ROPs while still maintaining clean hole. Drlg 12.25" hole 7418' to 8718' MD (3188' TVD) ADT 8.18 hrs - PP 2300 psi, PR 155 SPM, 650 gpm, WOB 5-35k, RPMs 130 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 2.5% No problems noted - 9.625" Geo -Pilot continued to perform well- Observed max gpm's @ 730 before decrease in performance. PU wt = 192K SO wt = 68K ROT WT = 102K Circulate weighted sweep until clean @ 700 GPM's and 2480 PSI RPM's = 130 When sweep at surface, observed 10%- 15% increase in cuttings at shakers. Drlg 12.25" hole 8718' to 9274' MD ADT 7.95. hrs - PP 2100 psi, PR 150 SPM, 635 gpm, WOB 10-35k, RPMs 110 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 2.5% (1 % being CO)? - No problems noted - 9.625" Geo- pilot performing well. PU WT + 207K SO WT = 63K ROT WT = Control drill as per Geologist from 9274' - 9367' MD Geologist neede to evaluate correlated depths. Drlg 12.25" hole 9367' to 9758' MD tvd = 3408' ADT 7.95 hrs - PP 2100 psi, PR 150 SPM, 635 gpm., WOB 10-35k, RPMs 110 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 3.0% - No problems noted - 9.625" Geo- pilot performing well. PU WT + 207K SO WT = 63K ROT WT = 101K Pnntetl: '1D/'Lki/20US 1028:"L/ AM • • ConocoPhillips Alaska Page 7 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase 7/1/2005 `03:30 - 05:00 1.50 DRILL CRC INTRM1 05:00 - 06:45 I 1.751 DRILL I DRLG f INTRMI 06:45 - 07:15 I 0.501 DRILL REAM I INTRMI 07;15 - 07:30 I 0.251 DRILL I DRLG I INTRM1 07:30 - 09:00 I 1.50 -DRILL REAM INTRM1 Description of Operations Continue Drilling From 9758'-10388'. TVD =3486' Con't ciru Hi-Visc weighted sweep. 38 BBL, 11.1 PPG @ 750 GPM's , 2800 PSI. BU of sweep showed a moderate increase in cutting. Continue drill from 10388'-10573 TVD = 3510' Obtain slow pump rates and surveys,. Monitor well, static Back ream out of hole to 10390', at 600 GPM's - 2000 PSI Rotating torque = 14K RIH back to 10573'. Continmue drill from 10573' -10580' MD TVD = 3511' PU wt = 152K Slack off wt = 75K Rot WT = 103K Torque on bottom = 15K torque off bottom = 13K RPM's = 100 Pumps at 600 GPM's w/ 2000 PSI ART = 3.31 HRS Back ream out of hole to 10384'. Stop and circulate @ 600 spm,2200 psi. Reciprocate drill string. 09:00 - 10:15 1.25 RIGMNT RGRP INTRM1 10:15 - 12:00 1.75 DRILL REAM INTRM1 12:00 - 16:00 ~ 4.001 DRILL ~ REAM ~ INTRM1 16:00 - 16:30 I 0.501 DRILL I CIRC I INTRM1 16:30 - 19:00 I 2.501 DRILL (TRIP I INTRM1 19:00 - 22:15 I 3.251 DRILL I CIRC I INTRM1 22:15 - 00:00 I 1.751 DRILL (TRIP INTRM1 17/2/2005 100:00 - 04:00 I 4.001 DRILL STRIP INTRM1 04:00 - 05:00 I 1.001 DRILL I CIRC I INTRM1 05:00 - 05:15 0.25 DRILL TRIP INTRM1 05:15 - 07:45 2.50 DRILL TRIP INTRM1 07:45 - 08:30 0.75 DRILL PULD INTRM1 08:30 - 09:15 0.75 DRILL PULD INTRM1 Repair Top Drive. Change out SHot Pin Assembly on TD. Continue back ream out of hole, from 10384' -9725' Pumps @ 600 GPM's 1975 PSI RPM's = 100, with 12-14k torque. Observed clean hole and no overpull issues. Continue back ream out of hole, from 10384' - 9725' Pumps @ 600 GPM's 1975 PSI RPM's = 100. with 12-14k torque.' PU wt = 145k SO WT = 70K Continued to see no hole problems, or overpull. Circulate and condition hole and mud while reciprocating drill string, pumping at 600 GPM's 1600 PSI, 100 RPM's and 12K free torque. Had several shows of small batches of cutting to surface. Trip in hole from 7112'-10580', observed clean hole conditions. Change out 2 joints of drill pipe as a result' of washouts. Circulate and condition. Pump a 30 BBL Hi-Visc weighted sweep @ 700 GPM's and 2675 PSI. .130 RPMs, and 14K free torque. Observe increase in cuttings on shakers when sweep came back, and observe hole cleaned up. Slowly TOH on elevators. Observed clean hole, and no issues until 9495' MD and work through tight spot. This is where we drilled a concretion earlier, and hole cleaned up by pumping 600 GPM's and 100 RPM's for one stand. We went back through tight spot with no pump or rotation and observed clean holee Continue TOH "slowly" on elevators with no more overpull issues. Displacement was correct and no swabbing occured. Con't TOH on elevators to .9356' - 8720" MD -Tight spot, 40k over pull - M/U top drive and BR tight spot 8750' thru 8628' -Run back thru and wipe until clean - PR 600 gpm, 1500 PSI, 80 RPMs. - Con't TOH 8628' to 5560' MD - Spot tube across casing -Pump 60 bbls tube pill and displace back to 1500' in Ann. 57 bbls mud, 3 sx soda ash and 3 drums EMI 920. PR 600 gpm, PP 1500 psi, 100 RPMs. BDTD - FCW "OK" Con't TOH 5560' to 174' MD UD NM Flex Collars and float sub Down Load MWD Printed: 10/28/2005 1029:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7!2!2005 109:15 - 10:30 I 1.251 DRILL ~PULD I INTRM1 10:30 - 11:00 0.50 CASE OTHR INTRMI 11:00 - 12:00 1.00 CASE RUNC INTRM1 12:00 - 12:45 0.75 CASE RUNG INTRMI 12:45 - 13:30 0.75 CASE SFTY INTRM1 13:30 - 17:30 ~ 4.00 ~ CASE ~ RUNC ~ INTRM1 17:30 - 17:45 I 0.251 CASE I CIRC I INTRM1 17:45 - 20:15 2.50 CASE RUNC INTRM1 20:15 - 21:00 0.75 CASE CIRC INTRM1 21:00 - 23:30 2.50 CASE RUNC INTRMI 23:30 - 00:00 I 0.501 CASE I CIRC I INTRM1 17/3/2005 100:00 - 01:00 I 1.001 CASE CIRC INTRM1 01:00 - 11:30. I 10.501 CASE I RUNC I INTRM1 11:30 - 12:00 0.50 CASE CIRC INTRM1 12:00 - 13:15 1.25 CASE CIRC INTRM1 13:45 - 17:00 3.25 CEMEN~CIRC INTRMI 17:00 - 18:15 I 1.251 CEMENlf PUMP I INTRM1 18:15 - 20:15 I 2.00 CEMEN7~DISP INTRM1 20:15 - 21:15 1.001 CEMENl~ RURD ~ INTRM1 Start: 6/20/2005 Rig Release: Rig Number: Page 8 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations BK and L/D Bit, Geo Pitot, NM GP Flex, GR, Res, PWD and pulser tools. R/U and pull wear bushing -Clean tools from rig floor R/U to run 9 5/8", L80, BCTM Csg Continue to RU to run 9 5/8 csg. PJSM with crew. Discuss safety issues, running procedures and centralizer placement. Make up Shoe jnt and float collar jnt, continue run 9 5/8 casing installing tandem rise centralizers as per plan Circulate BTMS up @ 1933', at 4 BPM - 250 PSI, 6 BPM - 350 PSI, and 8 BPM - 500 PSI PU wt = 106 K So wt = 70 K Continue run 9 5/8 csg form 1933' - 3670', installing tandem rise centralizers as per plan. Circulate BTMS up @ 3670', at 4 BPM - 350 PSI, 6 BPM - 450 PSI, 8 BPM - 600 PSI PU wt = 125 K SO wt = 66 K Continue run 9 5/8 csg form 3670' - 5530'. Shoe depth. Installing tandem rise centralizers as per plan. Circulate and condition mud at the shoe. Pumps at 4 bpm - 400 PSI, 10 BPM - 850 PSI PU wt = 155 K SO wt = 70 K Con't to circu and condition @ surface shoe (5530' MD w/ Csg) PR 400 gpm, 95 SPM, PP 850 psi, Up wt 155k, Dn wt 70k. Circu BU f/ 1800' & 3600' to maximize good mud properties of mud in hole while running casing. Con't running csg 5,530' to 10,530 MD -Fill csg as ran. After every 10 to 12 joints were ran we would circu while coming down slowly with 2 to 3 joints. This kept fresh mud in the well bore so we could run pipe without stopping the job in open hole. PR 190 gpm, PP550. We had a good solid run without any problems. Circu & Condition with Franks tool 1 BUs+- Work pump rate up to 8 bpm slowly. @ 4.5 bpm, Continue Circu & Condition with Franks tool -Work pump rate up to 8 bpm slowly. @ 4.5 bpm, 8.0 BPM - 880 psi Reciprocate string from 10560' -10540' PU WT = 225K SO WT = 60K RD Franks Tool. RU Cement head & Lines. Con't to Circulate & Condition Mud for CMt Job. 80 SPM - 800 PSI. PU WT = 215K SO WT = 55K CMT 9 5/8" Csg -Pump 10 bbl CW100, Test lines to 3500 psi, pump remaining 30 bbls CW100, pump 40 bbls 10.5 ppg MudPush, drop bttm plug, pump 299.4 BBLS of DeepCrete 12.5 PPG tail cmt, Drop Top Plug, kick out plug w/ 3 BBLS of water. Rig displace cmt with 9.1 PPG OBM @ 8 BPM - 425 PSI, reciprocating pipe in 20' strokes. Up WT = 225K Dn WT = 68K. AI1ow mud push, and cement to turn corner, resume working string. Parked casing in place @ 6200 STKS( 122 bbls cmt around corner), Bump plug at 7976 STKS @ 20:15 HRS. Pressure = 780 PSI. Bring Press up to 1300 PSI, Hold for 5 min. Bleed Press. Final Up Wt = 240K DN WT = 40K, Check floats, OK RD Cement Head, ND and lift BOP stack. Printetl: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well. Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/3/2005 ~ 21:15 - 23:30 ~ 2.25 ~ WELCTL~ NUND i INTRMI 23:30 - 00:00 0.50 WELCT NUND INTRM1 7/4/2005 00:00 - 01:00 1.00 WELCT BOPE INTRM1 01:00 - 03:30 I 2.501 WELCTLI BOPE I INTRM1 103:30 - 04:00 0.50 WELCTI I BOPE INTRM1 04:30 - 05:30 10.00 DRILLT I PUND INTRM1 05:30 - 06:30 1.00 DRILL PULD INTRM1 06:30 - 08:30 2.00 DRILL TRIP INTRM1 08:30 - 12:00 3.50 DRILL TRIP INTRM1 12:00 - 15:30 3.50 DRILL TRIP INTRM1 15:30 - 16:30 I 1.00 DRILL ~ TRIP I INTRM1 16:30 - 16:45 0.25 DRILL OTHR INTRM1 16:45 - 18:15 1.50 RIGMNT RSRV INTRM1 18:15 - 19:00 0.75 RIGMNT RGRP INTRMI 19:00 - 22:30 3.50 DRILL TRIP INTRM1 22:30 - 00:00 I 1.501 DRILL ITRIP I INTRM1 17/5/2005 100:00 - 01:00 01:00 - 02:15 02:15 - 03:45 1.001 DRILL (TRIP ~INTRM1 1.251 DRILL I CIRC ~ INTRM1 1.501 DRILL ITRIP I INTRMI 03:45 - 04:00 0.25 DRILL CIRC INTRM1 04:00 - 07:00 3.00 RIGMNT RGRP INTRM1 07:00 - 10:15 3.25 DRILL TRIP INTRM1 10:15 - 10:45 0.50 DRILL CIRC INTRM1 10:45 - 11:30 0.75 CASE DEOT INTRM1 11:30 - 14:45 3.25 CEMENl~DSHO INTRM1 Page 9 of 33 Spud Date: 6!20/2005 Start: 6/20/2005 End` 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Set Emergency slips with 290K pulled on string. = 50K on slips. RU WACHS pneunatic cutter & make final cut on 9 5/8 csg as per Vetco wellhead rep. POOH, lay down cut off joint. Length = 34.82'. Install 9 5/8 csg packoff. NU BOP stack, and Run in Lock down screws. RU to test packoff. RU & Test 9 5/8 csg packoff to 2400 PSI - 10 min. Test witnessed by Co. Rep RU to 13 3/8" X 9 5/8"Annulus, and press test line. Perform infectivity LOT, observe breakover @ 6.9 bbls and 800 psi (EMW 13.8 ppg). Pump 340 bbls of water annulus flush with a FCP of 775 psi. Recorded on chart. Changed BOP rams to 5" during injection. ***NOTE*** Hot Oil came out and pumped freeze protect. Pumped 140 bbls diesel 2413') Install test plug. RU & test 5" rams and body test BOP's. 250 psi low / 3000 psi high Record on chart. Witnessed by Co. Rep & TP RD test equipment. Install W.B - RILDS PU 20 Lo-Tads from beaver slide, set on rig floor. C/O swivel packing on Top Drive Open and inspect Top Drive Saver Sud RIH w! 60 stands of DP from Derrick, w/ mule shoe to 5570' POOH, installing Lo-Tads on DP. 24 Total. Rack in Derrick Continue POOH, installing Lo-Tads on DP back to surface. Rack in derrick PU 18 juts of 5" HWDP for push pipe, and POOH racking back in derrick. Clean floor area of OBM Slip & cut 74' of drilling line. Service TD and draworks. Change out Hydraulic fitting, filter and "O" ring on`TD HYD filter housing MU BHA #5. 8 1/2 BIT, Geo-Pilot assmy, GP pony, stabilizer, MWD, Stabilizer, HCIM, Neu/Den, TM, HOC, Float sub, INMFDC. Plug in and download. RIH to 160' and perform shallow hole pulse test. OK 5 BPM, 890 PSI. Hold PJSM, and load sources. PU 2 NMFDC's, 2 studs of HWDP and jars. RIH picking up new drill pipe. make up, breakout clean and re-make every connection. picked up 24 juts. Cont RIH from 1,146' with 8 1!2" BHA #5 PU new drill pipe, make up, breakout clean and re-make every connection, RIH to 2,384' Broke in bearings on Geo-pilot and shallow tested MWD, had no pulse on MWD, circ a DP cap and regained pulser Cont RIH from 2,384' with 8 1/2" BHA #5 PU new drill pipe, make up, breakout clean and re-make every connection, RIH to 4,010' (PU a total of 114 jts of Weatherfords 5" S-135 DP) Filled DP & re-checked MWD and ck ok Replaced pipe rotating assembly motor on top drive RIH with DP from derrick with BHA #5 from 4,010' and tagged cmt above FC at 10,483' (FC @ 10,490') Circ 50 bbls of mud to clear air from DP for csg test RU and tested 9 5/8" csg to 3,000 psi for 30 min Drilled out plugs and Float collar at 10,490', shoe track and float shoe at 10,572' then cleaned out to btm at 10,580', drilled 25' of new hole to 10,605', ADT .26 hrs, drilled out with 5-8K wob, 100 rpm's, 500 gpm at rnn[ea: -i urtwtuuo _i u:~a:~r wvi • • ConocoPhillips Alaska Page 10 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Date ,From - To Hours Code Code' Phase 2005 11:30 - 14:45 3.25 CEMENI{DSHO INTRM1 14:45 - 15:45 1.00 DRILL II CIRC INTRM1 15:45 - 16:30 I 0.751 DRILL I LOT I INTRM1 17:15 - 17:45 I 0.50 DRILL CIRC I PROD 17:45 - 21:30 I 3.75 I DRILL I DRLG I PROD 21:30 - 23:00 4 1.501 DRILL I CIRC PROD 23:00 - 00:00 I 1.00 I DRILL DRLG ~ PROD 17/6/2005 100:00 - 04:00 I 4.00 ~ DRILL ~ DRLG ~ PROD 04:00 - 05:00 I 1.00 I DRILL I REAM I PROD 05:00 - 08:00 I 3.00 I DRILL I DRLG I PROD 08:00 - 15:30 I 7.501 DRILL I DRLG f PROD 15:30 - 00:00 I 8.501 DRILL I DRLG ~ PROD 7/7/2005 100:00 - 06:00 I 6.00 ~ DRILL ~ DRLG I PROD 06:00 - 06:45 0.75 DRILL CIRC PROD 06:45 -10:15 3.50 DRILL DRLG PROD Description of Operations 2,400 psi and 15-19K ft-Ibs torque, rot uvt 105K, up wt 178K, do wt 66K Circ btms up for LOT, evened MW in and out at 9.1 ppg MOBM, circ hole at 550 gpm, 2,750 psi, 100 rpm's with 14-19K ft-Ibs torque RU and performed LOT to 14.4 ppg EMW with 964 psi, 9.1 ppg MOBM at 3,511' TVD Drilled 8 112" hole in A2 sand from 10,605' to 10,699' (94') ADT .38 hrs Circ hole while geology evaluated logs, circ at 490 gpm, 2,350 psi, 100 rpms and 14-19K ft-Ibs torque Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,699' to 11,143' MD/ 3,493' TVD, (444') ADT 2.16 hrs, 8-15K wob, 100-140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 15-20K ft-Ibs, on btm 10-20K ft-Ibs, rot wt 104K, up wt 200K, do wt 61 K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.3 ppg, ave BGG 150 units, max gas 856 units Circ hole while geology evaluated logs, circ at 550 gpm, 2,775 psi, 100 rpms and 16K ft-Ibs torque, determined to have drilled out the top of A2 sand at 11,040' MD/3,501' TVD Directionally drilled 8 1/2" Hole in A2 sand from 11,143'to 11,189' MD/ 3,493' TVD (46') ADT .29 hrs Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 11,186' to 11,593' MD/ 3,506' TVD, (407') ADT 2.71 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 15-20K ft-Ibs, on btm 10-20K ft-Ibs, rot wt 105K, up wt 205K, do wt 55K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave EGD 11.5 ppg, ave BGG 100 units, max gas 537 units, NOTE decision was made to sidetrack well since drilling out of zone from 11,040' MD/ 3,501' TVD to 11,400' MD/ 3,498' TVD (360' total) Backreamed out at Drlg rate from 11,593' to 11,382' and cunt to Pump out of hole to 10,820', pumped out at 160 gpm at 500 psi, st wt up 200K, do wt 60K Troughed well to preform OH sidetrack from 10,820' to 10,850' then time drilled from 10,850' to 10,860' and sidetracked well. Directionally drilled 8 1!2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,860' to 11,593' MD/ 3,513' TVD, (733') ADT 5.8 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 14-20K ft-Ibs, on btm 9-14K ft-Ibs, rot wt 104K, up wt 221 K, do wt 54K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.8 ppg, ave BGG 120 units, max gas 581 units Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,860' to 11,593' MD/ 3,513' TVD, (997') ADT 6.1 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,750 psi, off btm torque 15-20K ft-Ibs, on btm 8-14K ft-Ibs, rot wt 105K, up wt 220K, do wt 55K, 9.0 ppg MOBM, clean hole ECD is 10.8 ppg, ave ECD 11.7 ppg, ave BGG 140 units, max gas 600 units Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 12590' to 13245' MD/ 3,479' TVD, (655') ADT 4.52 hrs, 5-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,800 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10:7 ppg, ave ECD 12.0 ppg, ave BGG 54 units, max gas 675 units Stop Drilling - PU and circu off bttm to evaluate logs. Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilat and Stratasteer tool from 13245' to 13610' MD/ 3,485' TVD, (365') ADT 1.82 rnntea: iui[urzuuo IU:Zy:Z! HM • ConocoPhillips Alaska Page 11 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours ' Code Phase Description of Operations : Code 7/7/2005 06:45 - 10:15 3.50 DRILL DRLG PROD hrs, 5-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,800 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 54 units, max gas 675 units. While drilling do std pumped Wt/ Hi Vis sweep. 10:15 -10:45 0.50 DRILL CIRC PROD Circu weigthed sweep out of hole -Saw 35% increase in cutting when sweep came to surface 10:45 - 12:00 1.25 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13610' to 13703' MD/ 3,487 TVD, (93') ADT .59 hrs, 5-20K wob, 140 rpm's, 180 spm, 640 gpm, 3,850 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 70 units, max gas 470 units 12:00 - 13:45 1.75 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13703' to 13931' MD/ 3,490'. TVD, (228') ADT 1.34 hrs, 5-20K wob, 140 rpm's, 172 spm, 610 gpm, 3,850 psi, off btm torque 2D-22K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 100K, up wt 245K, do wt 40K, 9.0+ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.1 ppg, ave BGG 55 units, max gas 275 units 13:45 - 14:15 0.50 DRILL CIRC PROD Stop Drilling - PU and circu off bttm to evaluate Iogs.PR 173 SPM, 615 GPM, PP 3700 psi, 130 RPMs 14:15 - 21:30 7.25 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13931' to 14660' MD/ 3,448' TVD, (729') ADT 4.67 hrs, 5-20K wob, 140 rpm's, 175 spm, 620 gpm, 3,850 psi, off btm torque 20-22K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 100K, up wt 245K, do wt 40K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.1 ppg, ave BGG 55 units, max gas 275 units '"` NOTE`* @ 9:30 the #2 mud pump started leaking at the cyclinder head. Pump shut down for repairs. We cannot drill with 1 pump. 21:30 - 00:00 2.50 RIGMNT RGRP PROD While mud pump is repaired we will BROOH to shoe. TIH and be ready to drill when pump is repaired. BROOH PR 110 SPM, 130 RPMs, BR speed slow to allow hole to clean up 7/8/2005 OD:00 - 12:00 12.00 RIGMNT RGRP PROD Slowly BROOH 14,215' to 11,756' MD, PR 103 spm, 362 gpm, PP 1360 psi, RPMs 120, Troq 16-24k Moderate show of cutting at shakers - 10-15 % above drilling rate. Some slight pack off problems sceen if BR rate was to FAST. BGG 89 units 12:00 - 14:15 2.25 RIGMNT RGRP PROD Con't to slowly BROOH 11,756' to 11,510' MD, PR 105 spm, 374 gpm, PP 1400 psi, RPMs 120, Troq 15-19k. BGG 68 units 14:15 - 16:00 1.75 RIGMNT RGRP PROD TIH to 14,573' MD, Dn wt 60k, Up wt 185k - No problems TIH 16:00 - 17:00 1.00 RIGMNT RGRP PROD Wash & Ream 14,573 to 14,660' MD -Run in Pump #2 and ck for leaks - Re-Torq bolts after pressure run in. PR 168 spm, 597 GPM, PP 3700 psi, RPMs 120, Torq 18k 17:00 - 00:00 7.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 14660' to 15303' MD/ 3,427' TVD, (643') ADT 4.63 hrs, 5-15K wob, 120 rpm's,. 164 spm, 585 gpm, 3,850 psi, off btm torque 17-23K ft-Ibs, on btm 16K ft-Ibs, rot wt 112K, up wt 267K, do wt 49K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.8 ppg, ave BGG 75 units, max gas 310 units 7/9/2005 00:00 - 06:00 6.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and. Stratasteer tool from 15,303' to 15,774' MD! 3,415' TVD, (T.D.) (471') ADT 3.6 hrs, 5-12K wob, 120 rpm's, 163 spm, 580 gpm, 3,975 psi, off btm torque 20-23K ft-Ibs, on btm 17-18K ft-Ibs, rot wt 125K, up wt 260K, Printed: 102t32U05 W:Zy:Y/ AM • ConocoPhillips Alaska Page 12 of 33 Operations Summary Report Legal Well Name: 1E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/9!2005 ~ 00:00 - 06:00 I 6.00, DRILL ' DRLG ~ PROD 06:00 - 06:15 0.25 DRILL OBSV PROD 06:15 - 09:30 3.25 DRILL WIPR PROD 09:30 - 10:45 I 1.251 DRILL I WIPR PROD 10:45 -11:15 ` 0.50 RIGMNT RGRP PROD 11:15 - 13:30 I 2.25 DRILL CIRC PROD 13:30 - 15:15 I 1.751 DRILL I CIRC I PROD 15:30 - 21:00 5.50 DRILL ~TORIPV I PROD 17/10/2005 100:00 - 02:00 2.00 DRILL TORIPV PROD 02:00 - 02:30 0.50 DRILL PULD PROD 02:30 - 05:30 3.00 DRILL PULD PROD 05:30 - 06:30 1.00 I DRILL PULD PROD 06:30 - 07:00 0.50 CASE RURD CMPLTN 07:00 - 07:30 0.50 CASE SFTY CMPLTN 07:30 - 11:15 I 3.751 CASE PULR CMPLTN 11:15 -12:30 I 1.251 CASE {PULR I CMPLTN 12:30 - 16:00 3.50 ~ CASE I RUNL I CMPLTN 16:00 - 16:30 I 0.501 CASE CIRC ~ CMPLTN 16:30 - 17:30 1.001 CASE I RUNL CMPLTN 17:30 - 20:00 I 2.501 CASE I RUNL CMPLTN 20:00 - 22:15 2.251 CASE I RUNL I CMPLTN 22a 5 - 23:30 I 1.251 CASE I RUNL I CMPLTN Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations do wt 70K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 50 units Monitored well-static Backreamed out of hole from 15,774' to 14,600' with no problems, BROOH to previous trip at 120 rpm's, 130 spm, 462 gpm at 2,500 psi, RIH from 14,600' to btm at 15,774' with no problems, pumped weighted hi vis weep and #2 mud pump went down Circu & Condition hole -Changed out valve and seat on #2 mud pump Cont to circ out weighted hi vis sweep and circ an additional btms up and was clean at shakers, circ hole clean at 560 gpm at 3,900 psi, 140 rpm's with 18K ft-Ibs torque Changed hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, displaced hole out at 140 rpm's with 25K ft-Ibs torque and 547 gpm at 3,775 psi, rot wt 125K, up wt 295K, do wt 38K Monitored well-static, took SPR's POOH wet on elevators from 15,774' to 10,484' (Csg Shoe @ 10,572') with no problems Monitored well at shoe-static, dropped 2 3/8" rabbit on a wire Cont to POOH wet from 10,484' to 5,496' ~ Con't POOH from 5,496 to BHA at 378', UD 2- 8.5"ghost reamers from string POOH from 378' to 150', LD 5 jts HWDP, Jars and 2 NM FDCs Held PJSM and remove radioactive sources then down Loaded MWD, ca{c fill on trip out of hole 141 bbls, actual fi{I 154 bbls of 9.0 ppg SFMOBM Fin POOH and LD BHA #5, cleaned rig floor RU Doyon's 5 1/2" liner running tools Held PJSM and reviewed liner detail and discuss know hazards, Stressed "Stay Focused" on task at hand. PU and RIH with 5 1/2", 15.5#, L-80, BTCM Liner per well program to 5,311' (125 Jts total), ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 53 jts (2,262') of 5 1/2" 15.5#, L-80, BTCM blank liner and ran 72 jts (3,027') of 5 1/2", 15.5# L-80 BTCM slotted liner per detail sheet, ran 124 - 5 1/2" x 8 1/2" spiralglide centralizers 1/jt, jts #2 thru # 125, ran 12 constrictor packers placed on blank liner to cover shale sections. Micro Slots on liner 120 - 1.5" long X .018" @ 4 rows per/ft. MU Baker 190-47 seal bore ext, 9 5/8" x 7" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,369", st wt up 60K, do wt 57K, RD liner running tools RIH with 5 1/2" liner on DP from 5,369' to 10,554', (csg shoe @ 10,572') RIH slow 30-45 fpm to minimize surge with large OD packer. Circ a DP volume at csg shoe, circ at 300 gpm at 500 psi, st wt up 163K, do wt 53K, set torque limiter on top drive at 8,500 ft-Ibs and attempted to rotate liner and would not rotate RIH with liner from 10,554' to 11,950' when liner began floating and down wt was running 45-35K (blk wt), up wt 175K Worked liner down from 11,950' to 13,366', having to work weight down by reciprocating liner. RIH with liner from 13,366' to 14,706', RIH with 14 stds of HWDP from derrick and MU 1-lo-tad per std while RIH RIH with liner from 14,706' to 15,266', RIH PU 2 additional stds of HWDP with Lo-Tads and 4 stds of 6 3/4" Dc's from pipe shed, st wt up rnntea: iuilo/z~w lUL`J:L/ HM • ConocoPhillips Alaska Page 13 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Phase Description of Operations Code 7/10/2005 22:15 - 23:30 1.25 CASE RUNL GMPLTN 270K, do wt 55K 23:30 - 00:00 0.50 CASE RUNL GMPLTN RIH from 15,266' to 15,742' with slick DP from derrick, st wt up 280K, do wt 40K, NOTE: Ran liner prior to running USIT bond log due to no tractor or personnel on slope 7/11/2005 00:00 - 00:15 0.25 CASE RUNL GMPLTN Fin RIH with liner from 15,742' to 15,752' and placed A2 sand liner on depth with TOL at 10,382' and shoe at 15,752, st wt up 280K, do wt 40K 00:15 - 01:45 1.50 CASE OTHR GMPLTN Dropped 1 3/4" ball and pumped down to seat, initial rate of 4 112" bpm at 550 psi, slowed to 2 bpm at 200 psi and with ball on seat pressured up to 1,700 psi, slacked off on liner and hanger wasn't set, pressured up to 2,150 psi and slacked off and hanger hadn't set, pressured up to 2,200 psi and slacked off to blk wt and hanger was set. Pressured up to 3,000 psi and saw ZXP packer set then pressured up to 4,000 psi to release HR running tool. Set TOL at 10,382' MD/ 3,486' TVD with guide shoe at 15,752' 01:45 - 02:00 0.25 CASE DEQT GMPLTN Pressure tested ZXP pkr and annulus to 1,000 psi for 5 min, good test 02:00 - 02:15 0.25 DRILL TRIP GMPLTN PU 245K and was released from running tool, LD 1-single POOH to 10,350' 02:15 - 03:30 1.25 DRILL CIRC GMPLTN Circ btms up at 10,350' with no gas at btms up, circ at 295 gpm at 950 psi 03:30 - 03:45 0.25 DRILL OBSV GMPLTN Monitored well-static, took SPR's 03:45 - 10:00 6.25 DRILL TRIP GMPLTN POOH with HR liner running tool from 10,350' to 50', while POOH LD 4 stds of 6 3/4" DC's and 2 stds of HWDP with Lo-Tads used to run liner, removed 4 Lo-Tads from HWDP leaving 10 stds of HWDP with Lo-Tads in the derrick 10:00 - 11:00 1.00 DRILL PULD GMPLTN Made service breaks on liner running tool and LD same, cleared and cleaned rig floor, talc fill on trip out of hole 101 bbls, actual fill 111 bbls 11:00 - 11:15 0.25 LOG SFTY GMPLTN Held PJSM with rig crew and Schlumberger wireline (SWS) 11:15 - 12:15 1.00 LOG RURD GMPLTN RU SWS wireline and scheaves, MU USIT logging tools with SWS 2 1/8" tractor tool 12:15 - 20:00 7.75 LOG ELOG GMPLTN RIH with USIT logging tools to 2,080' and tool stopped, powered up SWS tractor tool and cont RIH, tractor and tools stopped at 10,180' and was unable to go deeper, tool was RIH on .46" line and possibly stopped due to weight of line and tool string 20:00 - 22:00 2.00 LOG ELOG GMPLTN Ran USIT bond log from 10,180' to 5,400' then POOH with logging tools, had good cement bond from 10,180' to 5,670' with some cement shown up to 5,520' (13 3/8" Shoe @ 5,546') 22:00 - 23:00 1.00 LOG RURD GMPLTN LD logging tools and RD SWS 23:00 - 23:30 0.50 WELCT OTHR GMPLTN Pulled wear bushing 23:30 - 00:00 0.50 WELCT BOPE GMPLTN RU to test BOP's 7/12/2005 00:00 - 05:15 5.25 WELCT BOPE GMPLTN Tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high, tested annular to 250 psi then 2,800 psi, Lou Grimaldi with AOGCC witnessed testing, RD test equip. and installed wear bushing 05:15 - 07:00 1.75 RIGMNT RSRV GMPLTN Changed out 4 1/2" IF saver sub on top drive 07:00 - 08:00 1.00 RIGMNT RSRV GMPLTN Slip and cut 60' of drlg line 08:00 - 08:30 0.50 RIGMNT RSRV GMPLTN Serviced top drive and greased drawworks 08:30 - 13:00 4.50 WINDO ULD PROD2 PU & MU Whipstock milling assembly BHA #6 and RIH to 870', MU ~ milling assembly and LD, MU seat assembly, locator sub, unloader sub, then PU 20 jts of 5" DP and 2-DP pup jts for spacing out and RIH with seal assembly, MU whipstock and milling assembly with MWD, oriented and uploaded MWD, RIH PU 3 -6 3/4" DC's, RIH to 870', st wt up 65K, do wt 60K rnn[ea: iutzorzwo i~:~a:zi r{in • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code 7/12/2005 13:00 - 15:00 2.00 WINDC 15:00 - 15:15 0.25 WINDO 15:15 - 17:00 1.75 WINDC 17:00 - 17:45 0.75 WINDO 17:45 - 20:15 2.50 WINDO 20:15 - 21:00 0.75 WINDC 21:00 - 22:00 1.00 WINDO 22:00 - 23:30 1.50 WINDO 23:30 - 00:00 0.50 WINDO 7/13/2005 00:00 - 00:45 0.75 WINDO 00:45 - 08:30 7.75 WINDO 08:30 - 09:30 1.00 09:30 - 09:45 0.25 09:45 - 13:45 4.00 13:45 - 14:45 1.00 14:45 - 16:00 I 1.251 WI 16:00 - 18:00 18:00 - 21:45 21:45 - 22:00 22:00 - 00:00 7/14/2005 100:00 - 02:30 Sub Phase Code TRIP PROD2 ~IRC PROD2 TRIP PRODZ DTHR PROD2 TRIP PROD2 ~IRC PROD2 TRIP PROD2 3ETW PROD2 ~IRC PROD2 ~IRC PROD2 3TWP PROD2 ;IRC PROD2 )THR PROD2 RIP PROD2 'ULD PROD2 )THR I PROD2 2.00 I DRILL PULD PROD2 3.751DRILL ITRIP IPROD2 0.251 DRILL I REAM ~ PROD2 2.001 DRILL I DRLG I PROD2 2.501 DRILL I DRLG I PROD2 Page 14 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations RIH slow with whipstock assembly BHA #6 from 870' to 3,158' Shallow tested MWD at 3,158' at 460 gpm at 880 psi and tool ck ok RIH slow with whipstock assembly BHA #6 from 3,158' to 6,250' when highline power went down Highline power to 1 E pad went down at 17:00 hrs, began to bring rig motors on line when highline power was restored at 17:45 RIH slow with whipstock from 6,250' to 9,335' Made MADD pass from 9,335' to 9,241' (sensor depth 8,602' to 8,508') and correlated MWD to K-13, no corr. circ at 500 gpm at 2,050 psi, st wt up 193K, do wt 58K Cont to RIH with whipstock from 9,241' to 10,310', st wt up 220K, do wt 65K Oriented whipstock 13 deg left of high side, RIH from 10310' and tagged TOL at 10,382', set whipstock and sheared off from same, top of whipstock at 9,706' MD/3,401' TVD, RIH with whipstock milling assembly with 24 stds of slick 5" DP, 60 stds of 5" DP with Lo-tads, 14 stds of 5" HWDP (10 W/Lo-Tads), 1 std and a double of 5" DP Began to displace hole over from 9.0 ppg SFMOBM to re-conditioned 9.0 ppg MOBM, circ hole at 500 gpm at 2,550 psi Fin displacing hole over from 9.0 ppg SFMOBM to 9.0 ppg MOBM,circ at 465 gpm at 2,100 psi Milled 8 1/2" window in "B" sand lateral from 9,706' to 9,722', cunt to mill to 9,738' MD/ 3,405' ND, (32' total W/5' of gauge hole out of window) milled at 4-7K wob, 70-90 rpm's, 450 gpm at 1,950 psi, on btm torque 13-20K ft-Ibs, rot wt 120K, up wt 195K, do wt 95K Pumped 30 bbl weighted hi vis sweep and circ hole clean while working mills thru window, circ hole at 550 gpm, 2,800 psi and 100 rpm's, rot wt 120K, up wt 195K, do wt 95K Monitored well-static, pumped dry job POOH with BHA #6 from 9,738' to BHA at 190' POOH LD milling BHA #6, LD 3-6 3/4" dc's, bumper sub, MWD and mills, gauged mills and upper milt was in gauge, talc fill on trip out of hole 90 bbls, actual fill 102 bbls, cleared rig floor Pulled wear bushing and flushed out BOP stack after milling window, ~ re-installed wear bushing MU 8 1/2" BHA #7 RIH to 346', MU RR 8 1/2" insert bit on 7" motor with 1.5 deg bend, float sub and MWD, uploaded MWD and RIH PU 3-NM Flex dc's, HWDP and jars from pipe shed while RIH to 346' RIH with BHA #7 from 346' to 9,597', shallow tested MWD at 2,726' while filling DP and tool ck ok Oriented motor at 9,597' and RIH thru window at 9,706' to 9,726' with no problems, washed down from 9,726' to btm at 9,738', washed down at 450 gpm, 2,100 psi, st wt up 144K, do wt 70K Directionally drilled 8 1/2" hole with motor from 9,738' to 9,769' MD/ 3,409' ND (31'), ART -0-, AST 1.33 hrs, 25 K wob, 126 spm, 450 gpm, 2,300 psi st wt up 144K, do wt 70K, drilling on concretion from 9,759' to 9,769' Directionally drilled 8 1/2" hole with mud motor from 9,769' to 9,849' MD! 3,409' ND (80'), ART .30 hrs, AST 1.74 hrs, 25-28K wob, 60 rpm's, 128 spm, 455 gpm, 2,200 psi, rot wt 95K, up wt 175K, do wt 75K, drilled on concretions from 9,769' to 9,779' (10'), 9,788 to 9,790' (2'), 9,794' to 9,795' (1') and 9,848' to 9,849' (1'), drilled deep enough to line well up in middle of sand and to get Geo-Pilot out into open hole, did PfIfltOtl: 1Ul282UUb 10:Z9:Z/ AM • ConocoPhillips Alaska Page 15 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date 'From - To Hours Code Phase Code 7/14/2005 00:00 - 02:30 2.50 DRILL DRLG PROD2 02:30 - 02:45 0.25 DRILL TRIP PROD2 02:45 - 03:30 0.75 DRILL CIRC PROD2 03:30 - 03:45 0.25 DRILL OBSV PROD2 03:45 - 07:15 3.50 DRILL TRIP PROD2 07:15 - 08:30. 1.25 DRILL PULD PROD2 08:30 - 12:00 3.50 DRILL I PULD PROD2 12:00 - 16:00 4.00 DRILL PULD PROD2 16:00 - 00:00 8.00 DRILL DRLG PROD2 17/15/2005 ~ 00:00 - 12:00 1 12.001 DRILL ~ DRLG 1 PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 17/16/2005 00:00 - 03:15 03:15 - 04:30 04:30 - 05:00 3.251 DRILL DRLG PROD2 1.251 DRILL. I CIRC PROD2 0.501 DRILL f REAM I PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations not drill out of zone. Pumped out of hole from 9,849' to 9,725' then POOH thru window to 9,694' to above top of whipstock, pumped out at 450 gpm at 2,150 psi, no problems pulling thru window Circ btms up at 9,694' and was clean at shakers, circ at 600 gpm at 3,350 psi and 60 rpm's Monitored well-static, pumped dry job POOH with BHA #7 from 9,694' to BHA at 346' LD BHA #7, stood back HWDP, jars and NM flex dc's, LD MWD, motor and bit, cleared rig floor, talc fill on trip out of hole 83 bbls, actual fill 92 bbls PU & MU 8 1/2" BHA #8 &RIH to 384', MU new 8 1/2 PDC bit, GEO-Pilot, MWD with Stratasteer, GR/Res/PWD//Neutron/density, uploaded MWD, held PJSM-and loaded radioactive sources, cont RIH with NM flex dc's, HWDP and jars to 384' ~ RIH with BHA #8 from 384' to btm at 9,849', no problems going thru window or RIH to btm, PU 2 ghost reamers and placed 1-962' back from the bit and 2nd one 1,825' back from the bit Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 9,849' to 10,110' MD/ 3,390' TVD, (261') ADT 3.72 hrs, 7-20K wob, 90-120 rpm's, 169 spm, 600 gpm at 3,100 psi, off btm torque 14-20K ft-Ibs, on btm torque 14-18K ft-Ibs, rot wt 102K, up wt 190K,dn wt 62K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 60 units, max gas 480 units. Drilled thru concretions from 9,849' to 9,862' (13'), 9,869' to 9,888' (19'), 9,966' to 9,979' (13') and 9,988' to to 10,009' (21') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 10,110' to 10,494' MD/ 3,381' TVD, (384') ADT 10.21 hrs, 8-20K wob, 90-140 rpm's, 600 to 640 gpm at 3,100 to 3,300 psi, off btm torque 14-23K ft-Ibs, on btm torque 13-20K ft-Ibs, rot wt 104K, up wt 195K,dn wt 56K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max gas 572 units. Drilled thru concretions from 10,128'-10,132' (4'), 10,158'-10,180' (22'), 10,182'-10,197' (15'), 10,271'-10,281' (10'), 10,295'-10,309' (14'), 10,350'-10,358' (8'), 10,389'-10,407' (18'), 10,425'-10,445', (20') 10,478'-10,490' (12') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and. Stratasteer tool from 10,494' to 11,481' MD/ 3,356' TVD, (987') ADT 9.24 hrs, 5-20K wob, 90-140 rpm's, 660 gpm at 3,750 psi, off btm torque 15-20K ft-Ibs, on btm torque 12-20K ft-Ibs, rot wt 102K, up wt 205K,dn wt 52K, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 90 units, max gas 330 units. Drilled thru concretions from 10,998'-11,018' (20'), 11,070'-11,076' (6'), 11,081'-11,089' (8'), 11,102'-11,109' (7'), 11,121'-11,126' (5'), 11,161'-11,163' (2'), 11,191'-11,193' {2') Directionally drilled 8 1/2" hole in "B".sand lateral with Geo-pilot and Stratasteer toot from 11,481' to 11,853' MD/ 3,342' TVD, (372') ADT 1.82 hrs, 12-19K wob, 110-140 rpm's, 660 gpm at 3,700 psi, off btm torque 15-20K ft-Ibs, on btm torque 13-16K ft-Ibs, rot wt 100K, up wt 200K,dn wt 50K, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 90 units, max gas 162 units. No concretions Circ hole and worked pipe while geologist evaluated logs, appears to either have crossed fault orjust drilled out of zone at 11,766' MD/3,347' TVD, decision was made to sidetrack well Backreamed out of hole from 11,853'. to 11,650', backreamed out at 140 rpm's, 600 gpm at 3,200 psi rnntea; ~ u~~orzwo w:zn.u ram • ConocoPhillips Alaska Page 16 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 17/16/2005 105:00 - 07:45 I 2.751 DRILL I DRLG l PROD2 07:45 - 11:15 3.50 DRILL DRLG PROD2 11:15 - 00;00 12.75 DRILL DRLG PROD2 7/17/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 22:45 10.75 DRILL DRLG PROD2 22:45 - 00:00 7!1812005 100:00 - 00:45 00:45- 01:00 01:00 - 12:00 12:00 - 18:45 1.25 RIGMNTI RGRP PROD2 0.75 I RIGMNTI RGRP I PROD2 0.25 RIGMNT RGRP PROD2 11.00 DRILL DRLH PROD2 6.751 DRILL I DRLH I PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Time drilled and sidetracked well from 11,650' to 11,666', ave 5'/hr with 135 rpm's, 610 gpm at 3,250', sidetracked well at 11,650' Directionally drilled 8 1/2" hole from 11,666' to 11,853' MD/ 3,354' TVD ADT 1.31 hrs. Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 11,853' to 12,769' MD/ 3,342' TVD, (916') ADT 9.74 hrs, 8-20K wob, 110-140 rpm's, 660 gpm at 3,825 psi, off btm torque 15-20K ft-Ibs, on btm torque 13-14K ft-Ibs, rot wt 98K, up wt 204K,dn wt 47K, 9.05 ppg MOBM, ave ECD 11.8 ppg, ave BGG 100 units, max gas 753 units. Drilled thru concretions at 11,233'-11,239' (6'), 11,830'-11,835' (4'), 11,956'-11,962' (6'), 11,969'-12,006' (37'), 12,046'-12,063' (17'), 12,130'-12,138' (8') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and. Stratasteer tool from 12,769' to 13,279' MD/ 3,328' TVD, (510') ADT 10.55 hrs, 10-21 K wob, 110-135 rpm's, 655 gpm at 3,825 psi, off btm torque 17-18K ft-Ibs, on btm torque 13-15K ft-Ibs, rot wt 99K, up wt 200K,dn wt 47K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 70 units, max gas 197 units. Drilled thru concretions at 12,768'-12,772' (4'), 12,837'-12843' (6'), 12,898'-121,913' (15'), 12,948'-12,962' (14'), 12,969'-12,980' (11'), 13,028'-13,034' (6'), 13,145'-13,150' (5') 13,176'-13,183' (T), 13,201'-13,219' (18')13,241'-13,246' (5'), 13,258'-13,268' (10'), 13,277'-13,281' (4') Directionally drilled 8 1/2" hole from 13,279' to 14,085' MD/ 3,306' TVD, (806') ADT 8.4 hrs, 5-21 K wob, 90-135 rpm's, 647 gpm at 3,900 psi, off btm torque 17-20K ft-Ibs, on btm torque 15-16K ft-Ibs, rot wt 97K, up wt 202K,dn wt 37K, 9.0 ppg MOBM, ave ECD 11 e9 ppg, max 12.0 ppg, ave BGG 80 units, max gas 253 units. Drilled thru concretions at ,13,394'-13,400' (6'}, 13,485'-13,490' (5'), 13,510'-13,520' (10'), 13,687'-13,700' (13'), 13,790'-13,796' (6'), 13,804'-13,825' (21'), 13,831'-13,835' (4'), 13,844'-13,846' (2'), 13,923'-13,931' (8'), 13,981'-14,000' (19'). NOTE: 4" Demco valve on kill line failed causing a spill inside rigs secondary containment, spilled was approx 112 bbl with 1 gal leaking outside of rig onto side of the rig and matting board, notified security and spill was cleaned up Worked pipe out of hole slowly from 14,085' to 13,880' while changing out O-ring on 4" Demco valve on kill line, tested and still leaked, began to RU 2" line to circ hole while cont to repair valve. NOTE: Had a medical emergency with a Doyon employee after he had gone off tour, hand was sent to KOC medic then to Anchorage for further evaluation Changed out valve stem (bonnett) on 4" kill line valve and tested, ck ok, circ hole thru 2" line at 3 bpm at 270 psi while slowly working pipe at 13,880' while repairing valve RIH from 13,880' to btm at 14,085' Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 14,085' to 14,336' MD/ 3,299' ND, (251') ADT 9.3 hrs, 10-22K wob, 90-135 rpm's, 642 gpm at 3,800 psi, off btm torque 18-20K ft-Ibs, on btm torque 16-17K ft-Ibs, rot wt 95K, up wt 205K,dn wt 35-40K, 9.0 ppg MOBM, ave ECD 11.9 ppg,_ave BGG 50 units, max gas 132 units. Drilled thru concretions at 14,118'-14,122' (4'), 14,193'-14,205' (12'), 14,201'-14,221' (20'), 14,246'-14,259' (13'), 14,268'-14,278' (10'), 14,292'-14,311' (19'), 14,313'-14,343' (30') Directionally drilled 8 1/2" hole in from 14,336'to 14,566' MD13,294' Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date .From - To Hours Code Sub Code 7/18/2005 112:00 - 18:45 ~ 6.75 DRILL I DRLH Phase PROD2 18:45 - 20:00 1.25 DRILL OBSV PROD2 20:00 - 00:00 4.00 DRILL TRIP PROD2 17!19!2005 100:00 - 05:00 I 5.001 DRILL I TRIP I PROD2 05:00 - 06:00 I 1.00 I DRILL I TRIP { PROD2 06:00 - 10:30 4.501 DRILL I TRIP I PROD2 10:30 - 11:00 0.50 DRILL PULD PROD2 11:00 - 12:00 1.00 DRILL PULD PROD2 12:00 - 14:15 2.25 DRILL PULD PROD2 14:15 - 17:15 I 3.00 I DRILL I PULD I PROD2 17:15 - 21:30 4.25 DRILL TRIP PROD2 21:30 - 21:45 0.25 DRILL TRIP PROD2 21:45 - 23:15 1.50 RIGMNT RSRV PROD2 23:15 - 00:00 0.75 DRILL TRIP. PROD2 17/20!2005 100:00 - 00:30 0.501 DRILL I TRIP I PROD2 00:30 - 02:30 2.00 I DRILL I OTHR PROD2 03:00 - 09:30 6.501 DRILL REAM PROD2 09:30 - 12:00 I 2.501 DRILL I DRLH I PROD2 Page 17 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations TVD, (230') ADT 5.73 hrs, 10-22K wob, 90-135 rpm's, 642 gpm at 3,800 psi, off btm torque 18-20K ft-Ibs, on btm torque 16-17K ft-Ibs, rot wt 95K, up wt 205K,dn wt 35-40K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Drilled thru concretions at 14,394'-14,402' (8'), 14,480'-14,496' (16'), 14,531'-14,539' (8'), 14,541'-14,552' (11'), last 3 concretions from ROP only no logs, penetration rate slowed thru concretions to 2-3'/hr down from 10', decision made to trip for bit Monitored well-static, took SPR's POOH on elevators from 14,566' to 14,261' (3 stds) and hole wasn't taking proper fill, backreamed out of hole from 14,261' to 11,764', backreamed out at 622 gpm at 3,700 psi, 120 rpm's with 17K ft-Ibs torque, initial string speed was 20-25'/min due to torquing up but did not pack-off, increased speed to 25-30'/min, attempted to POOH on elevators at 13,433' and 12,505' and well was not taking any fill and had 30-40K add. drag BROOH from 11764 -10036' . Attempt to POOH on elevators from 10904' to 10518' and hole wasn't taking proper fill, backreamed out of hole from 10036' to 9746', backreamed out at 622 gpm at 3,700 psi, ~' 120 rpm's with 17K ft-Ibs torque. POOH on elevators through window to 9649'. No issues through window. Monitor weN. Static. POOH from 10036' - 8682', observed well taking proper fil. Shut down GEO-PILOT, pump dry job, Continue POOH from 8682' - 106' PJSM, remove radioactive sources from tool string. Plug in and download MWD Continue to download MWD, POOH -lay down HOC, MWD and bit. Grade bit to 0-0-NO-ALL-X-N-NO-ROP Make up BHA #9. Service GEO-PILOT and MU bit, MWD w/ NEU-DEN and HOC. Plug in -Upload MWD and perform shallow hole test. Hold PJSM, and load radiactive sources in tools. Continue MU 1- stnd of NM flex collars, 5 studs of HWDP and Jars. Trip in hole from 383' - 9615' (91' above TOW) Calibrate Caliper logging tool. 126 SPM, 448 GPM's at 1900 PSI. 30 RPM's with 14K free torque 202 K Up weight, 60k down weight 105k rotating weight Slip ~ Cut drilling line. Service Top drive ~ Drawworks. Continue trip in hole to 9914'. No issues going through window w/ drilling assembly. Continue TIH form 9914' - 10112', working pipe through a few tight spots. Perform caliper log coming up hole at 4-5 ft /min from 10112' - 9812'. Pumping at 144 spm, 2500 psi and 60 rpm's. TIH form 9812' - 10264', working pipe in hole at tight spots from 10140' Wash & Ream from 10264' -10683'. Attempt to RIH on elevators, NO-GO. Stacking out and run out of weight. Continue to wasit & ream from 12217', and once again attempt to RIH on elevators to 12495'. Continue wash & ream to tag bottom @ 14482'. 206 k up weight, 47 K down, and 104K rot wt. Torque = 17K, Trip gas 90 units. Directionally drilled 8 1/2" hole w/ Geo-Pilot from 14,482' (Corrected depth 14,482) to 14,645' MD / 3,291' TVD, (163') ADT 1.64 hrs, 10-25K wob, 90-120 rpm's, 575 gpm at 3,900 psi, off btm torque 18-20K ft-Ibs, rnntea: ~uiza2uuo ~u:zy:zi Hm • ~ ConocoPhillips Alaska Page 18 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/20/2005 09:30 - 12:00 2.50 DRILL DRLH PROD2 12:00 - 00:00 12.00 DRILL DRLH PROD2 { 7121 /2005 100:00 - 09:15 09:15 - 09:45 09:45 - 10:30 10:30 - 12:00 12:00- 12:15 9.251 DRILL I DRLH ~ PROD2 0.50 DRILL CIRC PROD2 0.75 RIGMNT RGRP PROD2 1.50 I DRILL I CIRC I PROD2 0.251 DRILL I CIRC I PROD2 12:15 - 13:00 13:00 - 13:15 13:15 - 22:15 22:15 - 23:30 23:30 - 00:00 7/22/2005 00:00 - 01:15 01:15 - 01:30 01:30 - 03:30 03:30 - 06:15 06:15 - 08:30 0.75 RIGMNT RGRP PROD2 0.25 WELCT OBSV PROD2 9.00 DRILL TRIP PROD2 1.251 DRILL I CIRC I PROD2 0.50 RIGMNT RGRP PROD2 1.25 RIGMNT RGRP PROD2 0.251 DRILL I CIRC I PROD2 2.001 DRILL (TRIP IPROD2 2.751DRILL ITRIP IPROD2 2.251 DRILL I CIRC PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations on btm torque 16-18K ft-Ibs, rot wt 104K, up wk 206K,dn wt 47K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Directionally drilled 8 1/2" hole w/ Geo-Pilot from 14,645' to 15268' MD / 3,277' TVD, (623') ADT 10.08 hrs, 10-25K wob, 90-120 rpm's, 575 gpm at 3,900 psi, off btm torque 18-20K ft-Ibs, on btm torque 19-21 K ft-Ibs, rot wt 116K, up wt 230K,dn wt 35K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 49 units, max gas 555 units. Continue Directional drill 8 112" hole with Geo -Pilot from 15268' -15667' TD. (399') TVD = 3275' Drilled through concretions from 15145 - 15159, 15165 -15183, 15190 -15192, 15216 - 15233, 15267 -15276, 15327 - 15344, 15426 - 15437, 15446 - 15482, 15114, and 15598. ART = 7.96 HRS 570 GPM's at 3950 PSI. 140 RPM's, 230k up, 57K dn, 125K rot wt. ECD 11.8,and Tq off btm = 20K, on btm = 17-18K. WOB = 10-25K Jars =220.15 HRS Obtain surveys, and Slow Pump rates. POOH rack back 1 stand. Remove and Repair Top Drive shot pin assembly, while circulate @ 71 spm, w/ 1100 PSI Pump Hi visc weighted sweep at 560 GPM's, 3950 PSI, and 140 RPM's while reciprocate drill string. 230k up, 57K dn, and 125K rot wt. Tq = 20k Continue pump Hi Visc weighted sweep at 560 GPM's, 3950 PSI, and 140 RPM's while reciprocate drill string. 230k up, 57K dn, and 125K rot wt. Tq = 20k Install repaired shot pin assembly on Top Drive. Monitor well, static Attempt to POOH on elevators from 15582' -15391' (191'). Observe 'improper hole fill. BROOH from 15391'-14451 (940') Attempt to POOH on elevators and observed hole swabbing. Continue BROOH to 9690'. (5701' Total) No issues pulling ghost reamer or BHA through window. TOW = 9706' 568 GPM's, 3950 PSI, 125 RPM's, TO = 18K Pump 30 BBL Hi Visc weighted sweep while reciprocate drill string from 9690' - 9624' 140 RPM's, TO = 12-23K, 180 SPM, 640 GPM's, w/ 3200 PSI. Pumped 3 btms up and observed 10 % increase in cuttings and casing clean. Swivel packing on Top Drive failed. Change out swivel packing Swivel packing on Top Drive failed. Change out swivel packing, Test same. Note: Rig Hand reported muscle sprain in back while hammering on Swivel packing. A PIR was generated and he was sent to medic, returned to work. Contimue Circulate while reciprocate drill string from 9690' - 9624'. 140 RPM's, TQ = 12-23K, 180 SPM, 640 GPM's, w/ 3200 PSI. Pumped 3 btms up and observed 10 % increase in cuttings and casing clean. TIH f/ 9690' - 13098'. (3408') No issues through window area with BHA. Tagged up at 13098' .Drill string would not go to bottom on elevators. Wash & ream from 13098' - 15667' TD. (2569') TVD 3275'. Pumps at 72 SPM, 250 GPM's at 1000 PSI. Rotating @ 70 RPM"S w/ 15-17K TO. Attempt to RIH numerous times without wash & ream, and string would not go. 185K up, 67K down Rot wt = 125K Pump Hi Visc weighted sweep @ 575 Gpm's, 4250 PSI. 250K up, 55k dn, Rot wt = 120K TO = 18-20K, 140 RPM's. Observed 20% increase in cuttings and shakers cleaned up. Reciprocate drill string while circulating. Pflflt0tl: 7U/Zd/LWb W:Z8:2/ AM • • ConocoPhillips Alaska Page 19 of 33 Operations Summary Report Legal Well Name: 1E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 7/22/2005 ~ 08:30 - 10:30 ~ 2.00 ~ DRILL ~ CIRC ~ PROD2 Dispalce well with 9.0 PPG SFMOBM @ 121 SPM, 432 GPM"S, w/ 10:30 -12:00 I 1.501 DRILL ITRIP 12:00 - 19:30 I 7.501 DRILL ITRIP 19:30 - 20:15 .0.751 DRILL ITRIP_ 20:15 - 22:00 I 1.75 DRILL ITRIP 22:00 - 23:00 1:00 DRILL TRIP 2500 PSI. Reciprocate drill string while displacing. After dispalcement 275K , 35K dn, rot wt = 124K, TQ = 23-25K with pumps off. PROD2 Obtain slow pump rates. POOH on elevators from 15667' - 14356' (1311') Observe hole clean, no swabbing. PROD2 Continue POOH on elevators from 14356' - 90' (14266') Observe hole clean, no swabbing. Lay down Ghost Reamer. Breakout & lay down bad Lo-Tads off of stand # 92 , 90, 86, and 84. Serial #'s = 260856, 258285, 260862, and 260840. PROD2 Held Pre- Job Safety Meeting with Crew. Removing radioactive sources form BHA .Pull sources from assembly, secure and lay down same. Stand back 1 stand NMDC's. PROD2 Plug into MWD, and download. PROD2 POOH lay down remaining BHA. Breakout Bit, inspect and gauge same. Bit gauge = 0/0/NO/A/X/I/NO/TD 23:00 - 23:15 0.25 DRILL OTHR PROD2 Clear & Clean floor area. 23:15 - 00:00 0.75 CASE RURD CMPLT2 Rig up to run 5 1!2 15.5#, L-80 slotted liner assembly with Baker "HR" liner setting sleeve. RU tongs, slips, and change out elevators. 7/23/2005 00:00 - 00:30 0.50 CASE SFTY CMPLT2 Held PJSM with entire crew. (Picking up 5 1/2 slotted liner assembly) 00:30 - 04:00 3.50 CASE PULR CMPLT2 Make up Guide shoe jnt, and Insert jnt. Continue RIH picking up 138 jnts of 5 1/2" blank -slotted liner assembly. Ran a total of 69 Blank jnts ( 2935.51') and a total of 69 Slotted jnts (2$93.99') with (10) 2.5" long x 1/8" wide,4 circumferential rows, 40 slots per foot. Ran total of 137 5-1/2" x 8" Centralizers, Liner was drifted to 4.825". Liner connections w/ torque rings, and a total of 14 constrictors @ depths of 14959', 14708', 14208', 13959',13459', 13208', 12709', 12461', 11959', 11561', 11108', 10859', 10408', and 10159', when landed. 04:00 - 05:00 1.00 CASE PULR CMPLT2 Make up 1 jnt 7" 26#, with 5 1/2" 15.5# XO jnt. Make up Baker "HR" setting sleeve with a 7" 26# pup and running tool, ball seat assembly crossed over to 4 1/2 IF for Drill pipe. Liner weight = 85 K up, 55K down 05:00 - 07:30 2.50 CASE RUNL CMPLT2 TIH with 5 1/2 liner assembly to TOW @ 9700'. 140K up, 65K dn. Rot wt = 86K, w! 20 RPM's 9K TO, 40 Rpm's 8K TO 07:30 - 09:45 2.25 CASE RUNL CMPLT2 Continue TIH with 5 1/2 Liner, obtaing torque and drag parameters. At 10297' -rot wt = 86K, 20 Rpm's -10K TO, 40 Rpm's -10K TQ. At 10784' -rot wt = 86K, 20 Rpm's - 11 K TO, 40 Rpm's - 13K TQ. At 11169' -rot wt = 85K, 20 Rpm's -11 K TO, 40 Rpm's - 12K TO. At 12114', rot wt = 80K, 20 Rpm's - 13K TQ, 40 Rpm's 15K TO. Fill DP every 20 stands. Stopped at 12626'. No issues running through window. 09:45 - 12:00 2.25 CASE RUNL CMPLT2 Rotate 5 1/2" liner down from 12626' - 14054' (1428'). Rot Wt = 65K, 20 Rpm's 16K Average running speed = 20 ft per minute. 12:00 - 14:00 2.00 CASE RUNL CMPLT2 Continue Rotate 5 1!2" liner in hole from 14054' - 15675' (1621'). 250K up, 40K dn, and 115K rot wt. 19K TQ at 20 Rpm's. Landed 8.71' lower in well. 14:00 - 15:45 1.75 CASE CIRC CMPLT2 Drop ball in Dp, and allow to fall while pumping down DP @ 3 BPM, 250 PSI. 2 BPM @ 150 PSI. Ball landed. 15:45 - 16:30 0.75 CASE OTHR CMPLT2 Pressure up Dp to 1900 PSI to release from 5 1/2" Liner. Continue to pressure up to 3300 PSI to shear ball seat. POOH to 9700' (above TOW @ 9706') 5 1/2" Liner top at 9787.86'. 16:30 - 17:30 1.00 CASE CIRC CMPLT2 Circulate Bottoms up @ 8.3 BPM, 1000 PSI. 225K up, 80K dn, rot wt Printed: 10/282005 10:29:2/ AM ~ • ConocoPhillips Alaska Page 20 cf 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Phase Coe 7/23/2005 16:30 - 17:30 1.00 CASE I CIRG ~ CMPLT2 17:30 - 21:45 4.25 CASE OTHR CMPLT2 21:45 - 22:00 22:00 - 22:15 22:15 - 00:00 7/24/2005 00:00 - 04:00 04:00 - 05:30 05:30 - 07:15 07:15 - 08:15 1.00 08:15 - 08:30 0.25 08:30 - 12:00 3.50 12:00 - 14:30 I 2.501 WIN 14:30- 15:45 I 1.251 WI 15:45 - 17:30 i 1.75 0.25 CASE RURD CMPLT2 0.25 WINDO ULD CMPLT2 1.75 WINDO ULD CMPLT2 4.00 WINDO RIP CMPLT2 1.50 1.75 RSRV CMPLT2 TRIP CMPLT2 'CIRG CMPLT2 OBSV CMPLT2 TRIP CMPLT2 TRIP CMPLT2 PULD CMPLT2 PULD I CMPLT2 17:30 - 18:30 ` 1.00 CASE OTHR CMPLT2 18:30 - 20:45 2.25 CASE PUTB CMPLT2 20:45 - 00:00 17/25/2005 100:00 - 02:45 3.25 I CASE I RUNL I CMPLT2 2.751 CASE I RUNL I CMPLT2 02:45 - 03:15 ~ 0.50 I CASE ~ RUNL ~ CMPLT2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number. Description of Operations = 133K @ 20 Rpm's and 15K TQ Monitor well. Static. POOH from 9700' -surface. On TOH, breakout & lay do Bad Lo-Tads. Pins coming out, rollers flat. Stnd # 63, serial # 258260, Stnd # 49, serial # 258313, and Stnd # 38, serial # 258291. Lo-Tad lengths= 3.80' ea. Pin size on Lo-Tads = 3!8" x 2' long. We left 1 pin in hole. Total layed down = 11.40' from DP tally. Inspect remaing Lo-Tads on TOH. Breakout, lay down & inspect running tool. Small marks on running tool indicated set down on top of liner after released from- liner. Clean floor area, and pull tools to floor. PJSM, with crew. (Picking up BHA) Make up Whipstock retrieving BHA as per BOT Rep. Make up Hook (8.30'), 1 -JNT HWDP(30.86'), Float sub(2.47'), 6 1/4" Bumper Jar(8.70'), 6 1/4" Oil jar(11.53'), Pump Out sub(2.02'), 3 x 6 1/4" Drill Collars(92.13'), and 1 - Stnd of 5" HWDP(92.42'). Total Jenght of BHA = 248.43' TIH with Whipstock retrieving assembly From 248' - 9638' (9390') Fill pipe every 20 stands. Slip & cut Drilling Line. Service TD. replaced Hydaraulic fitting on TD. Continue RIH F/ 9638' - 9722' (84') to position wash slots on Hook at slot in whipstock @ 9712'. Wash slot at 6-7 BPM, - 750 PSI. 210K up, 80K dn. Hook window and pull to 265K to allow jars to bleed open, and continue staright pull to 275K to observe BTA shear and pulling seals from lower liner top. Pull up to 9666', 225K new up weight. Circulate Bottoms up @ 96 SPM, 1100 PSI. No gas. 13 BBL loss. Monitor well, static POOH with whipstock assembly, observe no swabbing. 11 SK upweight. Continue POOH with whipstock assembly to whipstock. Hang in clamp on rig flloor. 'Breakout and lay down whipstock retrieving assembly. Layed down Hook, 1 JNT of 5" HWDP, Float sub, 6 1/4" Bumper Jar & Oil Jar, Pump out sub, 3 - 6 1/4" drill collars, and 1 stand of 5" HWDP. Breakout and lay down whipstock assembly. Inspect whipstock. Layed down Whipstock Slide, Debris barrier cup and sub, drain sub, Shear disconnect, BTA, Blanking sub, 20 JNTS of 5" DP, 1-Flex joint, 1 JNT of 5" DP, Unloader Valve, Crossover sub, Locator sub, and seal assembly. Note: We recovered the lost Lo-Tad pin in the debris barrier cup. Clean & clear floor area. PuN tools to rig floor. PJSM with entire crew and BOT rep. Make up Hook hanger assembly. Picked up 1 JNT 5 1/2" L-80 BENT blank casing, (42.25'), 5 1/2" Pup (5.96'), 5 1/2" Pup (10.09'), Baker Payzone External Casing packer with pups (2.20',23.66' PKR, 6.60'), 5 12/" Pup (10.10'), Model B-1 Hook Hanger assembly with Crossover & pups (4.12',1.33', 27.38'). Make up Crossover to 4 1!2 IF for DP. and Baker running tool. RIH w/ Drill Pipe from derrick at a running speed of 90 ft /minute, as per BOT rep. Continue RIH w/ Hook assembly w! drill pipe from 5920' - 10420' 4500') at a running speed of 90 ft /minute, as per BOT rep. Tag Main Bore Crossover in seal bore. at 10420'. We did not go into "B" lateral on first try. POOH back to 9680'. Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Weil Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - Yo Hours Code Code Phase 7/25/2005 03:15 - 04:45 1.50 CASE RUNL CMPLT2 04:45 - 06:00 1.25 CASE CIRC CMPLT2 06:00 - 06:30 0.501 CASE ~ SFTY ~ CMPLT2 06:30 - 07:30 I 1.001 CASE I MIT I CMPLT2 07:30 - 08:15 I 0.751 DRILL (TRIP I CMPLT2 08:15 - 08:30 0.25 WELCT OBSV CMPLT2 08:30 - 12:00 3.50 DRILL TRIP CMPLT2 12:00 - 12:30 0.50 DRILL TRIP CMPLT2 12:30 - 13:15 0.75 CASE RURD CMPLT2 13:15 - 14:15 1.00 CASE RURD CMPLT2 14:15 - 14:45 0.50 RIGMNT RSRV CMPLT2 14:45 - 16:45 2.00 CASE PULR CMPLT2 16:45 - 17:15 0.501 CASE PULR I CMPLT2 17:15 - 23:30 I 6.25 CASE I RUNL CMPLT2 Page 21 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations Turn drill string 5 1/2 RH turns to orient bent joint to go through window. Slack off to to observe hooked hanger @ 9727.79'. (5.79' below original window cut) Pull up and un-hook hanger, rotate 114 RH turn increments to RIH and tag crossover in TOl_ @ 9845.88'.(1.98' low), and veriy Hook depth. Hooked and Re-hooked a total of 4 times, to finally set @ 9727.79'. Set down 40K on Hook. 215 K up, 75K do Drop 29/32" ball, With Rig, pump to seat 800 stks @ 3 BPM - 325 PSI, 2 BPM -200 PSI. Total of 2311stks to seat ball. Pressure to 450 PSI. and line up to hold pressure on DP. Hold PJSM with entire crew and Schlumberger. Discuss pressure test and procedure of pumping. Line up Pump truck to DP. Pressure test lines to 3500 PSI. Good test. Pressure up to 1000 PSI, Hold 2 min. Check tank level. Pressure to 1500 PSI, Check tank level. Continue pressure-up in 200 PSI increments to observe ECP inflate at 2695 PSI. Pressure bled back to 1700 PSI. Held Pressure 5 min. Bled pressure to 500 PSI. Check tank level, observed .45 BBLS to inflate ECP. Bleed all pressure off. Job went very well. Pull up off of Hanger to 9700'. (27') CBU @ 180 SPM, 2900 PSI. 215K up, 80K do wt. Monitor we11. Static. POOH from 9700'- 2167' (7533'). Inspect for failed Lo-Tads Continue to POOH from 2167' -surface. Lay down entire Hook Hanger running tool assembly. Visually inspect same. Clean and clear Rig Floor. Lay down all runnng tools. Service Top Drive, and inspect threads. PJSM with entire crew. Pull tools to floor, and RU to run LEM assembly. Make up 4 1/2" Baker Seal assembly (3.29') on 1 jnt of 4 1/2" IBT x STL 12.6# L-80 tubing, (43.67'). Seals = 4.73" x 3.87" ID. Make up &RIH w/ 21 jnts of 4 1/2" IBTM 12.6# L-80 tbg, (615.72'). Collar OD = 5.21" x 3.958". Make up Camco "DB" nipple assmy. 4 1!2" IBT tbg pup (5.88'), DB Nipple (1.52') with an ID of 3.563" and profile of 5.21"., 1 jnt 4 1/2" IBT tbg {30.23) 21 jnts of tbg total ran. Make up LEM assembly. Pick up LEM Inside Hook Hanger (22.90') 7.69" x 3.688". MU LEM Above Hook Hanger (12.40') 8.49" x 3.98", 4 112" IBT tbg pup { 3.80') 5.20" OD x 3.98" ID, 4 112 "Casing Swivel, 12.6# IBT (2.52') OD 5.75" x 3.96" ID. Crossover Bushing 5 1/2" Hydril 563 x 5 12/" IBT (1.40') OD 6.03" x 4.75" ID, 190-47 Casing Seal Bore Receptacle (19.45') OD 6.26" x 4.75" ID, Crossover 7" x 5 1/2" Hydril 563 (1.14') 7.67" OD x 4.94" ID, ZXP Liner top PKR 7" x 9 5/8" w/ HRD profile (18.50') OD 8.49" x 7.5" ID, and Baker Hydraulic setting tool 5.10'), and Baker running tool (5.42'). Trip in hole Lem assembly from 792' - 10430' (9638'). Running speed of 60-80 Ft !Min as per BOT rep. Observe seals going into SBR @ 10420' and continue RIH to latch up to Hook Hanger @ 9706.69', Top of ZXP PKR @ 9647.48'. 220K up, 82K do wt. Pull 10K over to veriy latch up. Layed down bad Lo-tads off of Stand # 37 (ser#258293), Stnd # 39 (ser#258289), Stnd # 43 (ser#258290), Stnd # 44 ser#258294), Stnd# 46 (ser#258262), Stnd# 48 (ser#258263), Stnd# 51 (ser#258266), Stnd# 52 (ser#258259), Stnd# 54 (ser#258372), Stnd# 55 (ser#258256), and Stnd# 57 (ser#258315). 11 Total layed down on trip. Nrintea: wiza2uvo IU:Zy:Z/ HM • • ConocoPhillips Alaska Page 22 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7125!2005 17:15 - 23:30 6.25 CASE RUNL CMPLT2 23:30 - 00:00 0.50 CASE RURD CMPLT2 17/26/2005 100:00 - 01:00 01:00 - 01:30 01:30 - 02:30 02:30 - 10:30 1.00 I CASE DEOT I CMPLT2 0.501 CASE I DEQT 1 CMPLT2 1.00 CASE CIRC (CMPLT2 8.00 CASE OTHR CMPLT2 10:30 - 11:00 11:00 - 12:00 12:00 - 12:30 12:30 - 16:30 0.501 CASE I OTHR I CMPLT2 Spud Date: 6/20/2005 Start: 6/20/2005 End:, 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Rig up lines to pump down DP and utilize rig test pump if neccessary. Line up to record on chart. Continue to Rig up lines to pump down DP and utilize rig test pump if neccessary. Line up to record on chart. Drop 1 3/4". Using Rig pump, pump ball do to seat at 3 BPM- 300 PSI. Ball on seat @ 1550 STKS. Pressure to 3000 PSI, then stage pressure up to 4200 PSI to set ZXP Liner Top PKR @ 9647.48' DPM. Pull up 10' to release from PKR and verify set. PJSM, Discuss pressure test and procedure. Close annular and pressure test down annulus to test ZXP @ 1000 PSI. Record on chart and hold 10 minutes. Good test. Rig down test equipment. POOH, lay do 2 - 10; 5" DP pups, and screw into TD. 220K up, 82K do wt. CBU @ 180 SPM,-630 GPM's - 2900 PSI. Monitor well, Static. POOH, Breakout & lay down all Lo-Tads. We shipped out a total of 61 bad Lo-Tads. The 10 Lo-Tads on HWDP were kept on location for re-use as they are in good shape. Note: Bad Lo-Tads consisted of pins falling out, and rollers being "flat". Make service breaks on Running and Setting tools, and lay down same. 1.00 WELCT BOPE CMPLT2 I BOLDS, Pull wear bushing. Install Test plug. RILDS. RU test pump. 0.50 WELCT BOPE CMPLT2 Continue RU test pump and equipment to test BOP's. 4.00 WELCT ROPE CMPLT2 Tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high, tested annular to 250 psi then 2,800 psi. Test Accumulator. Chuck Sheave with AOGCC waived witnessing testing, RD test equip. and installed wear bushing. RILDS 16:30 - 17:00 0.50 WELCT BOPE CMPLT2 RD test equipment, and pull tools to floor. 17:00 - 21:45 4.75 WINDO ULD PROD3 Make up Whipstock Assembly with Space out drill pipe. MU BOT seals (3.43'), Locator sub (1.87'), Crossover 3 1/2 IF x 4 1/2 IF (1.57'), Unloader sub pinned for 60K Shear (6.47'), 7 - JNTS 5" Space out pipe. (216.78'), Blanking sub (1.57'), 9 5/8" Bottom Trip anchor (2.81'), Shear Disconnect sub 120k Shear (2.73'), Ported Drain sub (1.49'), Debris barrier sub w/Cup (1.59'), 9 5/8" Windowmaster Whipstock (18.98'), 8" Starting Mil{ (1.55'), 8" Lower Mill (5.67'), 8.510" Upper Mill (6.17'), 1 - JNT 5" HWDP (30.74'), Float Sub (2.4T), MWD Assmy (42.62'), 6 i 1/4" Bumper Jar (8.70')> 6 - 6 114" Drill Collars (184.48'), 13 -stand 5" HWDP (1194.60'). Total BHA with Whipstock = 1732.85'. Total BHA withou Whipstock = 255.86'. Orient MWD to High side face of Slide. Pulse test MWD assmy, good. Shear Bolt = 45K 21:45 - 00:00 2.25 WINDO ULD PROD3 Trip in hole w/ 9 5/8" Whipstock assembly from 1732' - 2670'. (938') 105K up, 65K do wt. 7/27/2005 00:00 - 02:45 2.75 WINDO RIP PROD3 Continue to TIH from 2670' - 6622' (3952') 90 seconds to 2 minutes per stand as per BOT rep. PU = 160K, SO WT = 53K 02:45 - 07:30 4.75 WINDO RIP PROD3 POOH, after deciding we didn't have enough downweight to shear off and mill window. POOH, from 6622' - 722' (5900') POOH 90 seconds per stand. Reposition HWDP in assembly. 07:30 - 12:00 4.50- WINDO RIP PROD3 TIH with 9 5/8" Whipstock Assembly. from 722' - 4835' (4113'). 90 seconds to 2 minutes per stand as per BOT rep. PU = 110K, SO WT = 55K. Install Lo-Tads on stands # 10,13,16,19,22,25,28,31,34, and 37. Installed a total of 10 Lo-Tads. 12:00 - 14:30 2.50 WINDO RIP PROD3 Continue to TIH from 4835' - 8790'. (3955'). 90 seconds to 2 minutes per stand as per BOT rep. 14:30 - 15:30 1.00 WINDO RIP PROD3 Perform MADD PASS to K-13 for depth check. From 8790' - 8895' rnntea: wizoizuuo iu:~a:u rim • • ConocoPhillips Alaska Page 23 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Event Nam e: ROT -D RILLING Contractor Name: Rig Name: Date From - To Hours Code Phase Code 7/27/2005 14:30 - 15:30 1.00 WINDO RIP PROD3 15:30 - 15:45 0.25 WINDO RIP PROD3 15:45 -16:15 0.50 WINDO ETW PROD3 16:15 - 19:15 3.00 WINDO ETW PROD3 19:15 - 20:00 0.75 WINDO IRC PROD3 20:00 - 21:45 1.75 WINDO ETW PROD3 21:45 - 22:15 0.50 WINDO ETW PROD3 22:15 - 00:00 1.75 WINDO ETW PROD3 7/2812005 00:00 - 00:45 0.75 WINDO ETW PROD3 00:45 - 02:00 f .25 W1ND0 ULD PROD3 02:00 - 02:45 0.75 WINDO ULD PROD3 02:45 - 10:15 7.50 WINDO ULD PROD3 10:15 - 11:00 0.75 WINDOV~ IPULD PROD3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations (105'). Continue TIH with Whipstock assembly from 8895' - 9644' (749'). PU = 215K SO WT = 6$K. RIH to 80' above top of ZXP liner top. Orient 9 5/8 Whipstock face to 12 Degrees left of High side As per Directional Driller and plan. PU = 215k, SO Wt = 68K Slack off to observe Seals going into top of ZXP liner top (3') and set down to 35K to Set BTA. Pull up to 10k over to verify BTA set. PU = 215K , SO WT = 68K. Slack off to 35K to Shear bolt, set for 45K shear. Repeat 3 times. Pull up to neutral position at 160K and attempt to rotate free. NOT free. Continue to work 5 Right Hand turns into drill string, and work torque down to bolt, by slacking off to 35k, and max pull to 215K. Repeat numerous times. No free rotation. Continue attempts to turn free with a max torque of 20,000 ft/Ibs, and pumps at 450 GPM's, 1970 PSI. NOTE: MWD tool face readings indicated 155 degrees left of high side, and holding. We suspect starting mill pinched off in casing, not releasing torque back. Dispalce well from SFMOBM to MOBM at 525 GPM's and 2500 PSI. The decision was made to displace at this time to have the added lubricityin the MOBM possibly help in torque, up/down weights as well as transfer torque to bottom of assembly. This was a planned operation and trucks were ready. Continue attempt to rotate free by working torque to bottom of hole. Observed Bumper Jar movement at 225K UP, and 75K down. Decision from town to MAX Pull to 70K over. We pulled to 285K. Repeat, numerous times. NOTE: The BTA is designed to release @ 60K overpult. The shear disconnect is designed to release with a 120K overpult. We positioned the string in neutral position. Free rotation was obtained by rotaing to a max torque of 28K. Observed 100 RPM's 20K free torque, and we rotated only for 1/2 minute. Stopped Rotation. Discuss options with town, and it was decided to continue with planned operations, start milling. Circulate @ 500 GPM 'S, 2900 psi, no rotation or reciprocating string. String in neutral position, while wait on decision. Attempt to re-establish free rotation. Repeat procedures as above, and could not gain rotation again. This procedure was repeated numerous times, changing variables such as pump speeds, and trying to find the neutral position again. PU WT = 215K SO WT = 68K. Continue Attempt to re-establish free rotation. Repeat procedures as above, and could not gain rotation again. This procedure was repeated numerous times, changing variables such as pump speeds, and trying to find the neutral position again. PU WT = 215K SO WT = 68K. Discuss options with town rig engineers. . Decision to POOH with Whipstock assembly. Work drill string in increments of 25K, working up to a MAx pull of 425K. 75K Down. Assembly pulled free at 410K, and we pulled up hole 60'. Note: BTA designed to release with 60K averpull. Shear disconnect designed to release at 120K overpult. 210K UP WT. , 75K DN WT. POOH, with 1 stand HWDP, and lay down 1 single. Monitor well for swabbing. Hole taking fluid. Up WT = 215K. Pump Dry Job. POOH from 9554' - 88' (9466'). lay down 10 Lo-Tads to reposition them on next TIN. Lay down MWD assembly, Bumper Jar, Float Sub, and drain BOP stack. Clean & clear floor area. rnn[ea: iwroi~w~ w.~au rm • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code Code Phase 7/28/2005 111:00 - 11:30 I 0.501 WINDOV'IIPULD I PROD3 11:30 -12:00 I 0.501 WINDOV'VPULD I PROD3 12:00 - 12:15 I 0.251 WINDOVVPULD I PROD3 12:15 - 12:45 I 0.501 WINDOV'UPULD I PROD3 12:45 - 13:30 I 0.751 WINDOWTRIP I PROD3 13:30 - 18:45 I 5.251 WINDOWTRIP I PROD3 7/29/2005 18:45 - 20:45 I 2.001 WINDOWSETW I PROD3 20:45 - 22:30 I 1.751 WINDOWTRIP f PROD3 22:30 - 00:00 1.50 RIGMNT RSRV PROD3 00:00 - 02:45 2.75 WINDO RIP PROD3 02:45 - 03:45 1.00 WINDO RlP PROD3 03:45 -04;30 0.75 WINDO RIP PROD3 04:30 - 05:30 1.00 WINDO RIP PROD3 05:30 - 12:00 I 6.50 { WINDOV~ITRIP { PROD3 Page 24 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations PJSM, with entire crew, and BOT reps. Discuss procedure to strip Whipstock assembly through BOP stack & rotary table considering it may be sheared. Discuss rigging up a 25' JNT of 9 5/8" 40# casing. *** Special Note ***** CPF 1 ask us to take the Rig off Hi Line @ 11:00 AM. May be off for 8 to 10 days ?? Pick up 1 JNT of 9 5/8" 40# casing cut to a lenght of 25', with tugger, and strip it over 1 JNT of 5" HWDP hanging in blocks. MU HWDP to string hanging in slips. Pull Milting Assembly to floor through 9 5/8" casing. We did not have the whipstock assembly. Clean & Inspect mills. Starting mill showed damage on OD. Indicatiions mill was pinched and pulled by brass pad on slide, and casing drag marks. Broken buttons and damged carbide. Pictures were taken and sent to town. POOH, lay down 9 5/8" casing jnt. Lay down remaing Mill assembly. Layed down 8" Starting Mill (1.55'), 8" Lower mill (5.67'), 8.510" Upper Mill (6.17'), and 1 -JNT 5" HWDP. Pick up Whipstock retrieving assembly. Retrieving Hook (8.3'), 1 -JNT 5" HWDP (30.74'), Float Sub (2.47'), MWD assembly (42.62'), 6 1/4" Bumper Jar (8.70'), 6 1!4" Oil Jar (11.53'), Pump Out Sub {2.02'), 3 - JNTS 6 1/4" Drill Collars (92.13'), 2 -Stands 5" HWDP (184.03'). Orient MWD to whipstock hook. TIH from 416' - 9315' (8899'). Pulse test MWD, Inspect saver sub on Top Drive. Pick up 9 Lo-Tads on TIH. Lo-Tads on Stands #10 (ser#260830), #13 (ser#260851), #16 (ser#260854), #19 (ser#260832), #22 (ser#260852), #25 (ser#260833), #28 (ser#260837), #31 (ser#260861), #34 (ser#260813), and #37 (ser#260819). PU WT = 175K, SO WT = 78K. Orient Hook to 12 Degrees left of High Side. Attempt to engage WHipstock slot @ 9396'. Could not get over top of Whipstock with Hook. Tag top of whipstock @ 9390'. Orient Hook to 180 Degrees opposite @ 177 Deg Right. Slack off to below top of whipstock and re-orient Hook to 19 Deg left Hook Slide and pull up to 205K (25K over) to verify catch. Pump up MWD surveys to verify whipstock still set, and oriented to 19 degrees left of high side. 530 GPM's 2840 PSI. Directional Driller confirmed orientation, and satisfied. Un-Hook from whipstock, and pull up to 60' over top of slide to verify free. 180K PU WT, 70K SO WT. Monitor well, Static. Pump dry job. Obtain parameters. 195K PU WT, 83K SO WT, ROT WT = 120K, 80 RPM's, 13 -15K Free Torque. 530 GPM's, 2840 PSI. POOH from 9390' - 6910' (2480'). PU WT = 150K SO WT = 62K Slip & Cut Drilling Line. Service Top Drive. Continue POOH from 6910' - 198' (6712'). Observe proper hole fill. Breakout & Lay down BHA. Layed down 3 - JNTS 6 1/4" Drill collars 92.13'), Pump out sub (2.02'), 6 1/4" Oil Jar (11.53'), 6 1/4" Bumper Jar (8.70'), MWD assembly (42.62'), Flaot Sub (2.47'), 1 -JNT 5" HWDP (30.74'), Retrieving Hook (8.3'). Clean & clear Rig floor. Pull tools to floor. MU Whipstock Milling BHA. MU GEN 2 window mill (1.24'), 8" Lower mill (5.67'),8.510" Upper Mill (6.17'), 1 -JNT 5" HWDP (30.74'), Float Sub (2.47'), 6 1/4" Bumper Jar (8.70'), 3 - 6 1/4" Drill Collars (92.13'), and 3 -Stands 5" HWDP (275.59'). TIH with Milting BHA, 38 Stands S-135 DP. Make Up Lo-Tads on Stand Pflfl[0tl: 1U!"Lt3ILUUb 1U:1`J:Z/ HM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date 'From - To Hours Code Code' Phase 7/29/2005 05:30 - 12:00 6.50 WINDO~RIP ~ PROD3 12:00 - 13:30 1.50 WINDO RIP PROD3 13:30 - 19:30 I 6.00 I WINDOV'VOTHR I PROD3 19:30 - 20:00 I 0.501 WINDOV'VCIRC I PROD3 20:30 - 00:00 3.50 ~ WINDORIP PROD3 7!30/2005 00:00 - 00:15 0.25 WINDO~RIP PROD3 00:15 - 01:00 0.75 WINDO RIP PROD3 01:00 - 01:30 0.50 WINDO RIP PROD3 01:30 - 02:30 1.00 WINDO THR PROD3 02:30 - 03:30 1.00 DRILL PULD PROD3 03:30 - 03:45 0.25 DRILL DEOT ~ PROD3 03:45 - 07:15 3.50 DRILL TRIP PROD3 07:15 - 08:00 0.75 DRILL TRIP PROD3 08:00 - 10:30 I 2.50 I DRILL I DRLG I PROD3 10:30 - 11:45 1.251 DRILL I TRIP PROD3 11:45 - 12:00 0.25 DRILL OBSV PROD3 12:00 - 15:45 3.75 DRILL TRIP PROD3 15:45 - 17:30 I 1.751 DRILL I PULD I PROD3 Page 25 of 33 Spud .Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations #39. TIH from 422' - 7036'. (6614'). Continue TIH with Milling Assembly from 7036' - 9390' (2354') installing Lo-Tads. Installed a total of 42 Lo-Tads on Stands #39 - #80. PU WT = 168K, SO WT = 87K, Rot WT = 115K. Mill Window from 9390' - 9422' (32'). Milled 16' window in 3.8 HRS. !AVG ROP = 4.2 Ft per hour. Milled open hole in .63 HRS AVG ROP = i 25.26 Feet per hour. Total milting time = 4.83 hrs. AVG Milling Time i Total = 6.62 Feet per hour. Avg Torque in window area = 15K - 17K. 90 RPM's. Mud weight = 9.0 PPG MOBM. YP = 18 VISC = 83. PU WT = ~ 168K SO WT = 87K. Pumps at 500 GPM's 2000 PSI. WOB = 2K - 10K. Milled to ensure 5' of 8 1/2" gauged hole beyond slide. .Work drill string to dress window area until clean. Pumping Hi-Visc sweep. @ 500 GPM's - 2000 PSI. 168K PU WT, 87K SO WT, 90 RPM's TQ = 12-13K _ Continue circulate sweep out of hole. 670 GPM's - 3300 PSI. Obtain Slow pump rates. 30 SPM - 280 PSI 40 SPM - 270 PSI. Pump #1. Monitor well. Static. Pump Dry Job. POOH from 9390' - 2422' 6968') PU WT = 182K SO WT = 92K TOH pipe displacement 1.1 bbls difference from calculated. Continue POOH with window milling assembly from 2422' - 422' (2000') Breakout & Lay down Whipstock Milling BHA. MU GEN 2 window mill 1.24'), 8" Lower mill (5.67'),8.510" Upper Mill (6.17'), 1 - JNT 5" HWDP ( 30.74'), Float Sub (2.47'), 6 1/4" Bumper Jar (8.70'), 3 - 6 1/4" Drill Collars (92.13'), and 3 -Stands 5" HWDP (275.59'). Gauge mill to full 8 1/2". Mills looked good. Clean & clear floor area, pull tools to floor. BOLDS, Pull wear bushing: Make up tools and flush stack. Install wear bushing. RILDS. Make up BHA #15, 8 1/2" Drilling assembly. PU 8 1/2" Roller cone Insert Bit (1.00') (TFA = .746), 7" Sperry drill lobe 7/8 - 6.0 stage motor (25.10'), Non-mag Float sub (2.50'), 6 3/4" MWD DM HOC (8.87'), 6 3/4" Gamma/Res (23.75), 6 3/4" TM HOC (10.0'), 3 - jnts Non Mag flex drill collars (91.54'), 1 -jnt 5" HWDP (30.76'), 6 1/4" Drilling Jar 30:38), and 4 -jnts 5" HWDP (123.28'). Pulse test MWD equipment at 450 GPM's, 1400 PSI. OK Trip in hole w! Drilling assembly from 347' - 9377'. (9030'), Orient toolface to 12 degrees left of high side, to pass through window, down to 9422. Directional Drill 8 1/2" hole from 9422' - 9598'. (176'), to line up in "D" sand for Geo -Pilot Assmy. TVD = 3354'. AST = 1.49 HRS, ART = .3 HRS. ADT= 1.79 HRS. PU WT = 150K, SO WT = 95K, Rot WT = 95K. Torque on bottom = 13-14K, Off Bottom = 15-18K. Pumps @ 500 GPM's - 3000 PSI. Jars = 1.79 HRS POOH with drilling assembly from 9598' - 9377' (221'). Monitor well, static. Note: Window at 9391' - 9407'. Pump dry job, flow check. Continue POOH from 9377' - 347' (9030'). Hole fill 9.0 BBIs more than calculated. Down load MWD, Breakout & Lay do BHA #15, 8 1/2" Drilling assembly. 8 1!2" Roller cone {nsert Bit (1.00') (TFA = .746), 7" Sperry drill lobe 7/8 - 6.0 stage motor (25.10'), Non-mag Float sub (2.50'), 6 3/4" MWD DM HOC (8.87'), 6 3/4" Gamma/Res (23.75), 6 3/4" TM HOC (10.0'), 3 -jnts Non Mag flex drill collars (91.54'), 1 -jnt 5" HWDP rnrneo: iwmrcwo w.c~.c m • • ConocoPhiilips Aiaska Page 26 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date ;From - To Hours Code Code ' Phase 7/30/2005 ~ 15:45 - 17:30 ~ 1.75 ~ DRILL ~ PULD ~ PROD3 17:30 - 18:00 18;00 - 19:30 1.501 RIGMNT RGIRP PROD3 19:30 - 00:00 17/31/2005 100:00-00:30 00:30 -04:00 04:00 - 04:30 04:30 - 12:00 4.501 DRILL {PULD { PROD3 0.501 DRILL (TRIP PROD3 3.501 DRILL (TRIP {PROD3 0.501 DRILL 1 REAM I PROD3 7.501 DRILL I DRLG I PROD3 12:00 - 00:00 { 12.00 {DRILL ~ DRLG { PROD3 8/1/2005 100:00 - 12:00 ~ 12.00 I DRILL I DRLG { PROD3 Spud Date: 6/2012005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations ( 30.76'), 6 114" Drilling Jar (30.38), and 4 - jnts 5" HWDP (123.28'). Bit Gauge=l/I/WT1A/E!I/NO/BHA Clean floor area, lay do tools, pull tools to rig floor. Change ou saver sub on Top Drive. Measure ID of Rotary table., = 27 1/2". ID of wear bushings = 10 3/4". Service Top Drive. MU 8 1!2" Geo -Pilot drilling assembly. PU 8 1/2" PDC FMF2643 wl 1.118 RP, Ser# 5012193RW (TFA = 1.666)(1.60'), 7600 GEO-Pilotw/ top motor stabilizer (23.22), Non MAg GP Flex pony collar (9.21'), Smart Stabilizer (2.20'), 6 3/4" MWD - GR/RES/PWD (21.01'), Smart stabilizer( 1.96'), 6 3/4" MWD HCIM (6.94'), 6 3/4" MWD - NEU /DEN ( 29.92'), 6 3!4" TM HOC (10.0'), Non mag Float sub (2.50), 3 -Non mag Flex drill collars (91.54'), 1 - Jnt 5" HWDP (30.76'), Drilling Jars 30.38'), 4 -JNTS 5" HWDP (123.28'), 16 - 5" Slick DP (508.02), 8 ~ 1 /2" Ghost Reamer (6.9T), 48 -JNTS 5" SLick DP (1427.84'), and a 8 i 1/2" Ghost Reamer (6.95'), Pulse test MWD @ 525 Gpm's-1050 PSI. , i Upload, and break in GEO bearing. PJSM W/entire crew. Install radioactive sources in drilling assembly. Contininue to make up BHA to 385'. TIH w/ drilling assembly from 385' -9521' (9136'), picking up Ghost reamers in BHA @ 508' & 1428'. Fill drillstring @ 2779',5130',7491',and 9327'.. Continue TIH to 9521'. No issues passing asembly through 'window @ 9391'-9407. Wash & Ream down from 9521' -9598' (77'). Observe clean hole. Pumps @ 500 GPM's - 2500 PSl PU WT = 150K, SO WT = 72K, ROT WT = 93K. TQ = 14-15K Directional Drill 8 1/2" hole in the "D" sand from 9598' - 9865' (267'). TVD = 3340'. Drill through Concretion @ 9531' - 9537' (6'). ADT = 5.52 HRS. PU WT = 175K, SO WT = 60K, ROT WT = 90K. TQ on BTM = 15-20K, TQ off BTM = 15-18K, @ 130 RPM"S. JAR HRS = 7.31, 630 GPM's - 3400 PSI ECD = 10.4 PPG. MW = 9.0 PPG YP = 23-25 MAX WOB = 5-15K Continue Directional Drill 8 1/2" hole in the "D" sand from 9865' -10577' (267'). TVD = 3345'. Drill through 16 Concretions @ 9608' - 9615' (7'), 9645' -9654' (9'),9670' - 9678' (8'), 9688' -9700' (12'), 9708' - 9712' (4'), 9761' - 9765' (4'), 9795' - 9798' (3'), 9822' - 9826' (4'), 9860' -9872' (12'), 10041' - 10046' (5'), 10060' -10072' (12'), 10282' - 10289' (7'), 10521' - 10524' (3'), 10540' - 10553' (13'), 10557' - 10563' (6'), 10558' - 10570' (12'). Total of 127' of concretions = 13% of drilled hole.. ADT = 7.86 HRS. PU WT = 200K, SO W7 = 60K, ROT WT = 100K. TQ on BTM = 15-17K, TQ off BTM = 18-20K, @ 135 RPM"S. JAR HRS = 15.1, 635 GPM's - 3550 PSI ECD = 11.5 PPG. MW = 9.0 PPG YP -23-25. MAX WOB = 10-25K Observed Higher Torque up to 23K when 1st Ghost Reamer going through window. Directional Drill 8 1/2" hole in the "D" sand from 10577' - 10979' (402'). TVD = 3308'. Drill through 10 Concretions @ 10586' -10595' (9'), 10602' - 10610' (8'), 10655' - 10670' (15'),10680' -10691' (11'), 10730' - 10745' (15'), 10790' - 10810' (20'), 10845' - 10862' (17'), 10890' - 10914 (24'), 10930' - 10950' (20'), 10968' - 10979' (11'). 150' Total Concretions = 38 °lo of drilled hole. ADT = 8.07 HRS. PU WT = 185K, SO WT = 50K, ROT WT = 85K. TO on BTM = 15-22K, TO off BTM = 17-18K, @ 130 RPM"S. Jars = 23..24 HRS Pumps at 622 GPM's - 3400 PSI ECD = 11.7 PPG. MW = 9.0 PPG YP = 23-25 MAX WOB = 10-30K rnncea: i~ita~uuo iuay:~i ,vrvi • ConocoPhillips Alaska Page 27 of 33 Operations Summary Report Legal Weli Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Phase Code 8/1/2005 12:00 -19:00 7.00 DRILL DRLG PROD3 19:00 - 20:30 1.50 DRILL REAM PROD3 20:30 - 00:00 3.50 DRILL DRLG PROD3 8/2/2005 00:00 - 07:45 7.75 DRILL DRLG PROD3 07:45 - 09:15 1.50 DRILL DRLG PROD3 Description of Operations Continue Directional Drill 8 1/2" hole in the "D" sand from 10979" - 11479' (500'). TVD = 3287'. Drill through 2 Concretions @ 10990' - 11005' (15'), 11086' -11095' (9'). Total of 24' of concretions = 5% of drilled hole.. ADT = 4.91 HRS. PU WT = 185K, SO WT = 50K, ROT WT = 98K. TQ on BTM = 21-22K, TQ off BTM = 21 K, @ 130 RPM"S. JAR HRS = 29.14 HRS, Pumps @ 635 GPM's - 3500 PSI. ECD = 11.62 PPG. MW = 9.0 PPG YP -23-25. MAX WOB = 10-25K Note: MWD Density tool stopped working at 9843' MD, and came back on @ 10663'. Lost - (820'). BROOH from 11479' - 10980' (499'), at drilling rate. Decision with town to pull back and sidetrack as per Geologist. Work drill string from 10980' - 10997', troughing hole to start sidetrack. TVD = 3307'. 135 RPM's 18K TO, 635 GPM's 3500 PSI. ECD @ 11.6 PPG WOB = 0-2K ADT = .99 HRS *** Note*** Deprature point 10,980' MD Directionally Drill 8 1/2" hole in "D" Sand lateral with Geo-Pilot from 10,997' to 11,479', (482') ADT 5.09 hrs Drilled 8 1!2" Hole in "D" sand lateral from 11,479' to 11,609' MD/ 3,291' TVD, (130') ADT .73 hrs, 8-15K wob, 110-130 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 22K ft-Ibs, on btm 18K ft-Ibs, rot wt 95K, up wt 185K, do wt 35K, (Blk Wt), 9.05 mw, ave ECD 12.0 ppg, ave bgg 70 units, max gas 656 units 09:15 - 09:45 0.50 DRILL CIRC PROD3 Circ hole and evaluated logs for geology 09:45 - 14:15 4.50 DRILL DRLG PROD3 Drilled 8 112" Hole in "D" sand lateral from 11,609' to 12,062' MD/ 3,284' TVD, (453') ADT 2.74 hrs, 5-12K wob, 130 rpm's, 178 spm, 630 gpm, 3,650 psi, off btm torque 22K ft-Ibs, on btm 19K ft-Ibs, rot wt 94K, up wt 205K, do wt 37K, 9.05 mw, ave ECD 12.0 ppg, ave bgg 175 units, max gas 807 units, (reed additional Lo-Tads) 14:15 - 17:15 3.00 DRILL REAM PROD3 Backreamed out of hole at drlg rate from 12,062' to 10,487' to install additional Lo-Tads 17:15 - 17:45 0.50 DRILL PULD PROD3 PU add. Lo-tads to rig floor 17:45 - 19:45 2.00 DRILL TRIP PROD3 RIH from 10,487' to 11,780' installing 1-Lo-tad per std, lost down what 11,780' 19:45 - 20:30 0.75 DRILL REAM PROD3 Washed and reamed down from 11,780' to btm at 12,062', installed a total of 16 Lo-tads to 5" DP, (58 total in hole) having to rotate DP down to set slips 20:30 - 00:00 3.50 DRILL DRLG PROD3 Drilled 8 1/2" Hole in "D" sand lateral from 12,062' to 12,390' MD/ 3,280' TVD, (328') ADT 2.21 hrs, 5-10K wob, 130 rpm's, 176 spm, 625 gpm, 3,700 psi, off btm torque 20-22K ft-Ibs, on btm 18K ft-Ibs, rot wt 95K, up wt 200K, do wt 37K, having to rotate DP to set slips due to no slack off wt, 9.0 mw, ave ECD 12.1 ppg, ave bgg 70 units, max gas 135 units, Drilled a few small concretions after sidetracking well and no concretions since 11,200' 8/3/2005 00:00 - 02:15 2.25 DRILL DRLG PROD3 Directionally drilled 8 1/2" hole in "D" sand lateral with Geo-Pilot from 12,390' to 12,665' MD/3,276' TVD (275') ADT 1.62 hrs 02:15 - 03:00 0.75 RIGMNT RGRP PROD3 Circ hole at a reduced rate while changing out valves and seats on #1 mud pump 03:00 - 14:15 11.25 DRILL DRLG PROD3 Drilled 8 1!2" Hole in "D" sand lateral from 12,665' to 13,561' MD/ 3,258' TVD, (896') ADT 7.28 hrs, 10-25K wob, 130 rpm's, 176 spm, 625 gpm, 3,825 psi, off btm torque 20-22K ft-Ibs, on btm 18K ft-Ibs, rot wt 98K, up wt 205K, do wt 35K, 9.05 mw, ave ECD 12.05 ppg, ave bgg 80 units, max gas 190 units, NOTE: A rubber boot on pump in rock washer failed vnnrea: iurzarzuuo ~u:zy:u Hm • • ConocoPhillips Alaska Page ~8 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Sub Code 8/3/2005 ~ 03:00 - 14:15 ~ 11.25 ~ DRILL ~ DRLG Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Phase Description of Operations PROD3 causing 3.6 bbls of MOBM to spill inside secondary containment inside rig, had 1 gal leak onto the secondary containment outside of rock 14:15 - 14:45 0.50 RIGMNT RGRP PROD3 14:45 - 00:00 9.25 DRILL DRLG PROD3 18/4/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD3 12:00 - 17:00 I 5.00 {DRILL {DRLG { PROD3 17:00 - 17:30 0.50 RIGMNT RGRP PROD3 17:30 - 22:00 4.50 DRILL DRLG PROD3 22:00 - 00:00 2.00 DRILL WIPR PROD3 8/5/2005 00:00 - 11:00 11.00 DRILL WIPR PROD3 11:00 - 15:00 I 4.00 I LOG I DLOG { PROD3 15:00 - 17:00 2.00 DRILL WIPR PROD3 17;00 - 00:00 7.00 DRILL REAM PROD3 18/6/2005 100:00 - 01:00 I 1.00 I DRILL {REAM I PROD3 01:00 - 03:15 2.25 {DRILL {CIRC PROD3 03:15 - 04:45 1.50 (DRILL {CIRC { PROD3 Changed out swab on #2 mud pump Drilled 8 1/2" Hole in °'D" sand lateral from 13,561' to 14,340' MD/ 3,236' TVD, (779') ADT 5.6 hrs, 5-10K wob, 130 rpm's, 173 spm, 615 gpm, 4,100 psi, off btm torque 22-23K ft-Ibs, on btm 19-20K ft-Ibs, rot wk 112K, up wt 250K, do wt 35K, (blk wt), still having to rotate DP to set slips due to no down wt, began running 5" HWDP at 13, 422' with no change in do wt, 9.05 ppg mw, ave ECD 12.3 ppg, ave bgg 90 units, max gas 170 units, drilled thru a few concretions last 24 hrs Directionally drilled 8 1/2" Hole in "D" sand lateral with Geo-Pilot from 14,340 to 15,195' MD/ 3,214' TVD, (855') ADT 6.62 hrs, 5-15K wob, 130 rpm's, 169 spm, 600 gpm, 4;100 psi, off btm torque 23-25K ft-Ibs, on btm 22K ft-Ibs, rot wt 100K, up wt with pumps on 205K, do wt 35K, (blk wt) 9.0 mw, ave ECD 12.3 ppg, ave bgg 70 units, max gas 160 units, Note: At 15,078' began taking torque readings with pumps on, still unable to get down wts without rotating Drilled 8 1/2" hole from 15,195' to 15,470' MDI 3,208' TVD (275') ADT 2.67 hrs Circ hole with pump #2 while changing out swab on #1 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 15,470' to 15,661' MD/ 3,208' TVD, (191') (T.D.) ADT 2.6 hrs, 5-15K wob, 120-130 rpm's, 162 spm, 1575 gpm, 4,000 psi, off btm torque 26K ft-Ibs, on btm 25K ft-Ibs, with pumps on rot wt 95K, up wt 230K, do wt 35K, (blk wt) Drilled last 200' with directional only, no log data, ave bgg 50 units, surveyed at TD and monitored well-static. We were able to pump up a surrey using 1 pump @ 360 gpm. Sperry said dropping the #2 pump fessoned the "pump noise" and a good siignal was received to pump up survey. Began backreaming out of hole to window, BROOH from 15,661' to 15,360', BROOH at 110 rpm's 25K ft-Ibs torque, 580 gpm at 4,100 psi Backreamed out of hole from 15,360' to 9,617' MD! 3,352' TVD, BROOH at 110 rpm's, 176 spm, 625 gpm at 4,000 psi, no problems BROOH or packing off MADD pass for caliper log from 9,617' to 9,476', logged at 80 rpm's, 15-24K ft-Ibs torque, 159 gpm, 565 gpm at 2,500 psi, circ hole clean while logging. RIH from 9,476' to 11,453' when we lost all down weight Washed and reamed from 11,453' to 14,946', washed down at 80 rpm's, 15-22K ft-lbs torque, 113 spm, 400 gpm at 2,150 psi, MU an additional 11 stds DP with Lo-Tads while RIH, 69 total Lo-Tads in the hole, attempted several times to RIH with no pump and still had no down wt. Washed and reamed from 14,946' to btm at 15,661', washed down at 80 rpm's, 20-23K ft-Ibs torque, 113 spm, 400 gpm at 2,300 psi Pumped 35 bbl weighted hi vis sweep and circ hole clean at 15,661', had no increase in cuttings back from sweep and circ a total of 2X btms up and was clean at shakers, circ at 572 gpm at 4,100 psi, 140 rpm's with 20-23K ft-Ibs torque, after adding Lo-tads and moving HWDP up hole, torque was down 4-5K ft-Ibs and had good MWD signal. Initial ECD was 12.3 ppg, max during sweep was 12.7 ppg and after circ hole clean was down to 12.0 ppg and no gas Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at YiII'IIBO: Wf'L2S/ZWD IV:Z7.L/ HM • • ConocoPhillips Alaska Page 29 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 8/6!2005 03:15 -04:45 1.50 DRILL CIRC PROD3 04:45 - 05:00 0.25 DRILL OBSV PROD3 05:00 - 09:30 4.50 DRILL TRIP PROD3 09:30 - 10:30 1.00 RIGMNT RSRV PROD3 10:30 - 11:00 0.50 RIGMNT RSRV PROD3 11:00 - 14:45 3.75 DRILL TRIP PROD3 14;45 - 16:00 1.25 DRILL PULD PROD3 16:00 - 19:00 3.00 DRILL PULD PROD3 19:00 - 20:00 1.00 DRILL - PULD PROD3 20:00 - 20:30 0.50 CASE RURD CMPLT3 20:30 - 20:45 0.25 CASE SFTY CMPLT3 20:45 - 00:00 3.25 CASE PULR CMPLT3 8/7/2005 00:00 - 01:00 1.00 CASE PULR CMPLT3 01:00 - 01:30 0.50 CASE PULR CMPLT3 01:30 - 01:45 0.25 CASE RURD CMPLT3 01:45 - 08:30 6.75 CASE RUNL CMPLT3 08:30 - 09:45 1.25 CASE OTHR CMPLT3 09:45 - 10:15 0.50 CASE CIRC CMPLT3 10:15 - 14:15 4.00 CASE RUNL CMPLT3 Spud Date: 6f20/2005 Start: 6/20!2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 572 gpm at 4,100 psi, 140 rpm's, rot wt 100K ,st wt up 280K, off btm torque 24-25K ft-Ibs Monitored well-static Dropped 1 15/16" rabbit and POOH on elevators from 15,661' to 9,230' with no problems, monitored well-static (TOW @ 9,391') Slip and cut 74' of drlg line Serviced top drive POOH from 9,230' to BHA at 385', LD 2-8 1/2" ghost reamers, gauged same and were 1/8" undergauge POOH from 385' to 111', stood back 1 std of HWDP, LD 2 jts HWDP, jars and 2 NMFDC's, held PJSM and removed radioactive sources, LD 1 more NMFDC Downloaded MWD Fin LD BHA #15, LD MWD and Geo-Pilot, cleared rig floor RU Doyons 5 1/2" liner running equipment Held PJSM with rig crew and tong operator on liner running detail and associated hazards PU and RIH with 93 jts of 5 1/2" 15.5 ppf, L-80 slotted/blank liner per detail sheet to 4,000' Cont to PU and RIH with 5 1/2" finer from 4,000' to 6,080', PU a total of 145 jts of 5 1/2", 15.5#, L-80, BTCM Liner with torque rings per well ~ program, RIH to 6,080', ran 5 112" ROT silver bullet guide shoe with no ,float, ran a total of 56 jts (2,384') of 5 1/2" 15.5#, L-80, BTCM blank liner, ran 89 jts (3,738') of 5 1/2", 15.5# L-80 BTCM slotted liner, ran 128 - 5 1/2" x 8 1/4" spiralglide centralizers 1/jt #3 thru #144, ran 14 constrictor packers placed on blank liner to cover shale sections, did not run any centralizers on jts with constrictor packers. Accual Blank & Slot footage counting the 3' blank on each end of slotted joints= 2850' blank 46.8% and 3240' slotted 53.2%. Total of 6090' MU 7" tie-back assembly RIH to 6,191', MU 5 1/2" XO Jt to 7", 1-Jt of 7" csg and tie-back sleeve, st wt up 85K, do wt 52K RD Doyons liner running equipment and cleared rig floor RIH with 5 1/2" liner on 5" DP from 6,191' to btm at 15,661', RIH to 12,476' and worked pipe down to btm, no problems thru whipstock, did not have to rotate liner to get to btm, took torque and drag readings while RIH, st up wt on btm 250K, do wt 45K, rot wt 112K, RIH with liner with 4 stds slick 5" DP, 69 stds DP with Lo-Tads, 11 stds slick and 15 stds of 5" HWDP. Took torque readings at: 6,285', st up wt 85K, do wt 52K, rot wt 65K, 20 rpm's = 3k ft-Ibs torque, 40 rpm's=2-4K ft Ibs 9,363', TOW, st wt up 135K, do wt 57K, rot wt 90K, 20 rpm's = 6,500 ft-Ibs torque, 40 rpm's = 6,500 ft-Ibs 10,534, st wt up 147K, do wt 53K, rot wt 90K, 20 rpm's = 9-11 K ft-Ibs torque, 40 rpm's = 9K ft-Ibs 15,661', st wt up 250K, do wt 45K, rot wt 112K, 40 rpm's = 20K ft-Ibs torque Dropped 29/32" ball and pumped down to seat, pumped down at 4 bpm at 400 psi,slowed to 1 bpm, with ball on seat pressured up l;0 3,000 psi to release running tool, then pressured up to 3,720 psi and blew ball seat, PU and st wt up was 220K, top of 7" tie back sleeve at 9,483' POOH from 9,482 to 9,394', est circ and washed top of whipstock face from 9,394', to 9,302', circ at 420 gpm at 1,400 psi Monitored well-static, POOH wet from 9,302' to HR running too{ at 20', PflMetl: 1U1Lt111UU, 7U:1y:L1 NNI • ConocoPhillips Alaska Page 30 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Cad Phase Description of Operations e 8/7/2005 10:15 - 14:15 4.00 CASE RUNL CMPLT3 talc fill on trip out 87 bbls, actual fill 97 bbls 14:15 - 15:00 0.75 DRILL PULD CMPLT3 LD Baker HR running tool and cleared rig floor 15:00 - 16:15 1.25 FISH PULD CMPLT3 MU whipstock retrieving BHA #16 and RIH to 337', MU retrieving hook, 1 jt HWDP, bumper sub, oil jars, pump out sub, 3-6 3/4" Dc's and 2 stds of 5" HWDP 16:15 - 19:45 3.50 FISH TRIP CMPLT3 RIH with BHA #16 from 337' to 9,352', st wt up 218K, do wt 77K 19:45 - 20:15 0.50 FISH FISH CMPLT3 Hooked whipstock at 9,391' on 6th attempt. PU on whipstock and had 25K drag, did not see btm trip release, possibly due to over pull when pulling milling assembly loose, PU and stood back std, st wt up was 250K, after standing back std string wt dropped to 225K, set back down and tagged up 25' higher 20:15 - 21:15 1.00 FISH CIRC CMPLT3 Stood back 1 std to 9,345' and circ btms up, circ at 420 gpm at 1,500 psi, max gas at btms up 20 units. 21:15 - 00:00 2.75 FISH TRIP CMPLT3 Monitored well-static, POOH slow with whipstock assembly from 9,345'- to 6,324' 8/8/2005 00:00 - 04:00 4.00 FISH TRIP CMPLT3 Cont to POOH with whipstock assembly from 6,324' to BHA #16 at 337' 04:00 - 05:30 1.50 FISH PULD CMPLT3 POOH and stood back 2 stds HWDP - LD 3-6 3/4" dc's, bumper sub, oil jars, pump out sub, 1 jt HWDP and retrieving hook and cleared rig floor of toots 05:30 - 06:30 1.00 FISH PULD CMPLT3 POOH and LD whipstock slide, 7 jts of 5" DP used for space out pipe and seals 06:30 - 07:30 1.00 CASE RURD CMPLT3 RU Doyon's 5 1/2" elevators and tongs, brough pup jts and XO subs to rig floor 07:30 - 07:45 0.25 CASE SFTY CMPLT3 Held PJSM with rig crew and Baker Oil tool rep on MU hook hanger assembly and procedure to hook hanger and pressures required to set ECP packer 07:45 - 08:45 1.00 CASE PULR CMPLT3 MU "D" lateral hook hanger assembly with ECP Pkr RIH to 153', MU 5 1/2" bent jt, 1-5' pup j of 5 1/2" 15.5#, L-80 IBTM blank liner, ECP, 1-6',1-21' and 1-10' pup jts and hook hanger assembly 08:45 - 09:15 0.50 CASE RURD CMPLT3 RD Doyon's 5 1/2" elevators and tongs 09:15 - 14:15 5.00 CASE RUNL CMPLT3 RIH with hook hanger assembly from 153' to above top of window to 9,352', st wt up 200K, do wt 83K (TOW @ 9,391') 14:15 - 17:30 3.25 CASE OTHR CMPLT3 Worked bent jt thru window on 1st attempt setting down 40K at 9,407', did not see ECP Pkr go thru window, attempted to turn hook and go thru window, made approx 30- 112 round turns on DP and was unable to go deeper, stood back 1 std to 9,369' to above TOW 17:30 - 20:00 2.50 CASE OTHR CMPLT3 Increased torque limiter on top drive and and rotated DP 20 turns and was able to work pipe down, worked pipe down to 9,555' well past no go, determined to be in main bore, PU to 9,375' and rotated pipe and after 12 1/4 turns worked hook hanger thru window and tagged no go at 9,535', PU to above TOW and after 8 attempts hooked hanger at BOW at 9,704', unhooked hanger and after several attempts re-hooked hanger setting 45K st wt down on hook, set top of hook hanger at 9,386' with bent jt spaced out 7' above 7" x 5 112" XO at 9,536' 20:00 - 20:45 0.75 CASE CIRC CMPLT3 Dropped 29/32" ball and pumped down to seat, pumped at 3.5 bpm, 375 psi, with ball on seat pressured up to 850 psi and shut.. in j 20:45 - 21:30 0.75 CASE OTHR CMPLT3 RU Dowell and pressure test lines to 5,000 psi, bled down to 850 psi and opened Dowell to DP. Pressured up in 200 psi increments to observe ECP inflate at 2660 psi, pressure bled back to 1580 and stabilized for 5 min. Bled pressure to 850 psi. Check tank level and took .5 bbls to inflate ECP. Pressured up to 4,343 psi and sheared ball seat, bled off pressure. 21:30 - 22:30 1.00 CASE CIRC CMPLT3 PU from top of hook hanger at 9,386' to 9,319', st wt up 225K, do wt rnnieu: wiwicwo n,.ca.~~ ~,~.~ • ConocoPhillips Alaska Page 31 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 8/8/2005 21:30 - 22:30 1.00 CASE CIRC CMPLT3 22:30 - 00:00 1.50 CASE RUNL CMPLT3 8!912005 00:00 - 01:45 1.75 CASE RUNL CMPLT3 01:45 - 02:45 1.00 CASE PULR CMPLT3 02:45 - 03:15 0.50 CMPLTN RURD CMPLT3 03:15 - 03:30 0.25 CMPLTN SFTY CMPLT3 03:30 -04:45 1.25 CMPLT PULD CMPLT3 04:45 - 10:15 5.50 CMPLTN TRIP CMPLT3 10:15 - 12:30 2.25 CMPLT TRIP CMPLT3 12:30 - 16:45 ~ 4.25 ~ CMPLTN TRIP ~ CMPLT3 16:45 - 17:15 I 0.50 CMPLTN RURD CMPLT3 17:15 - 19:00 1.75 CMPLTN PULD CMPLT3 19:00 - 19:15 0.25 WELCT OTHR CMPLT3 19:15 - 23:45 4.50 WELCT BOPE CMPLT3 23:45 - 00:00 0.25 WELCT OTHR CMPLT3 8/10!2005 00:00 - 01:00 1.00 RIGMNT RSRV CMPLT3 01:00 - 01:30 0.50 RIGMNT RSRV CMPLT3 01:30 - 05:45 4.25 DRILL PULD CMPLT3 05:45 - 06:30 0.75 CASE RURD CMPLT3 06:30 - 07:45 1.25 CASE PULR CMPLT3 07:45 - 08:00 0.25 CASE RURD CMPLT3 08:00 - 13:00 5.00 CASE RUNL CMPLT3 13:00 - 16:00 3.001 CASE ~ RUNL ~ CMPLT3 16:00 - 17:45 ~ 1.75 ~ CA5E ~ CIRC ~ CMPLT3 17:45 - 22:30 4.75 CASE RUNL CMPLT3 22:30 - 22:45 0.25 CASE RURD CMPLT3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations 77K, circ btms up from 9,319' at 180 spm, 640 gpm at 2,950 psi, monitored well-static POOH with hook hanger running tool from 9,319' to 6,771'. Cont to POOH with hook hanger running tool from 6,771' to running tool at 40' LD hook hanger running tool and cleared rig floor RU Doyon's 4 1/2" tbg handling tools Held PJSM wiith rig crew and tong operator on running of LEM MU "D" sand LEM assembly with SLZXP packer, hanger, CSR, LEM and 7 jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, RIH to 366' RIH with LEM assembly from 366' to top of hook hanger at 9,86', st wt up 210K, do wt 77K RIH with LEM from 9,386' and set down at 9,460', worked seal assembly approx 12 times trying to get to go thru hook with no success, worked pipe and rotated string at 15 rpm's with 15K ft-Ibs torque while attempting to go thru btm of hook at 9,407', st wt up 210K, do wt 77K rot wt 105K, appears collar above seals is setting down on XO bushing below hook on D fat Monitored well-static, POOH with LEM assembly from 9,460 to LEM at 366' RU Doyon's 4 1/2" tbg handling tools POOH LD LEM assembly with SLZXP packer, hanger, CSR, LEM and 7 jts of 4 1!2" 12.6 ppf, L-80 IBT tubing and seals, found collar above seals to show signs of where it was hitting on XO below hook, ZXP packer element had some scarring, sent packer to Baker to be re-dressed, calc fill on trip out of hole 85 bbls, actual 92 bbls Pulled wear bushing RU and tested valves, rams, annular and manifold to 250 psi low and 3,000 psi high, Note: Jeff Jones with AOGCC waived witnessing of test, RD test equipment Installed wear bushing Slip and cut 71' of drlg line Serviced top drive LD 38 stds of Weatherford 5" S-135 rental DP down from derrick while waiting on SLZXP packer to return from Baker Oil tools RU Doyon's 4 1/2" tbg handling equipment and held PJSM on running of LEM MU "D" sand LEM assembly #2 with SLZXP packer, hanger, CSR, LEM and 7 jts and 2-pup jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, RIH to 365' RD Doyon's 4 1/2" tbg handling equipment RIH with LEM assembly #2 from 365' to 9,343' (Top of Hook Hanger @ 9,386'), st wt up 205K, do wt 80K RIH from 9,343' and set down at 9,447', collar above seals tagging up at XO below hook at 9,413', rotated LEM and oriented seals thru hook after 4th attempt, cont to RIH and set down at 9,589', (87' F/Latching i hook) attempted to work LEM down rotating string vrith no success, rotated at 10 rpm's with 15-17K ft-Ibs torque, st wt up 225K, do wt 75K, rot wt 110K Circ 1 complete circ from 9,589' while working LEM, would not go deeper, circ hole at 265 gpm at 750 psi, monitored well-static POOH with LEM assembly #2 from 9,589' to LEM at 365' RU Doyon's 4 1/2" tbg handling equipment and held PJSM on LD LEM • • ConocoPhillips Alaska Page 32 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date 8/10/2005 ~ 2 From - To Hours Code Sub 'Phase - 00:00 8/11/2005 00:00 - 01:15 01:15 - 02:30 02:30 -06:00 06:00 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 12:45 12:45 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:45 20:45 - 00:00 8/12/2005 00:00 - 00:30 00:30 - 03:30 03:30 - 05:00 05:00 - 05:15 05:15 - 06:45 06:45 - 07:00 Code 1.25 ~ CASE ~ PULR ~ CMPLT3 1.251 CASE {PULR {CMPLT3 1.25 I FISH PULD CMPLT3 3.501 F1SH I TRIP {CMPLT3 1.501 FISH I TRIP I CMPLT3 2.00 I FISH I CIRC CMPLT3 1.00 I FISH OTHR {CMPLT3 2.001 FISH {TRIP (CMPLT3 0.25 ~ FISH OTHR CMPLT3 3.25 FISH TRIP CMPLT3 2.00 FISH PULD CMPLT3 1.00 FISH PULD CMPLT3 1.75 FISH PULD CMPLT3 3.25 FISH TRIP CMPLT3 0.50 FISH TRIP CMPLT3 3.00 {FISH I TRIP {CMPLT3 1.50 ~ FISH ~ CIRC ~ CMPLT3 0.25 DRILL OBSV CMPLT3 1.50 DRILL PULD CMPLT3 0.25 DRILL PULD CMPLT3 Spud Date: 6/20/2005. Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations POOH and LD SLZXP packer, CSR and LEM, pkr, pkr element ck'd ok with only a couple of scratches, LEM had some scratches on upper OD of tool also, POOH to 4 1/2" tbg to 26T, SLM out of hole, no correction Fin POOH from 267' LD remaining 4 112" tbg, POOH and checked seals, had 3-4 seals damaged leaving 8-9 good seals, changed out special clearance collar on seals to 5.2" IBT collar MU dummy run BHA #16 with seal assembly on bent jt, 10 jts 4 1/2" tbg with 7" OD boot basket and RIH to 353' RIH with BHA #16 from 353' and tagged top of hook hanger at 9,386', st wt up 220K, do wt 80K Oriented seal assembly and RIH below hook hanger and tagged up on XO below hook at 9,413', PU and re-oriented seal and on 2nd attempt went thru hook, cont RIH and tagged up at 9,589', same spot as last run, set down 10K wt down, est circ at 6 bpm at 550 psi, est rotation at 15 rpm's with 15-16K ft-Ibs torque and set 10K wt down with no movement, st wt up 220K, do wt 78K, rot wt 115K Circ hole at 9,589' while working junk basket, circ at 150 spm, 533 gpm at 2,050 psi Attempted to work seals deeper, rotated on obstruction at 20 rpm's with 17-18K ft-Ibs torque with 10K wt down and circ hole at 50 spm, 178 gpm at 700 psi was able to go down 3' to 9,592' Attempted to POOH, worked pipe from 9,592' to 9,385' pulling 25-35K over st wt, hole extremly tight possibly due to junk in hole, POOH to 9,331' to above top of hook at 9,386' Monitored well-static POOH from 9,331' to BHA #16 at 353' POOH and LD BHA #16, LD boot basket, 10 jts of 4 1/2" tbg, bent jt with seals, had 1 piece of brass with a few pieces of cement in junk basket, btm 3 collars where shined up with scrathes from iron, guide shoe on seals had 2 indentions on ID of seals PU tools for BHA #17 to rig floor MU reverse junk basket on BHA #17 and RIH to 362', MU 6 3/4" rev. junk basket, 2- 4 11116" boot baskets,3-4 3/4" DC's, and 7 jts of 4" XT-39 DP{ and Rlh to 362' RIH with BHA #17 from 362' to 6,147' RIH with reverse circ junk basket on BHA #17 from 6,147' to 9,341', st wt up 210K, do wt 82K, est circ at 6 bpm at 750 psi, rotated string at 30 rpm's with 13-15K torque, rot wt 105K, do wt 105K, up wt 150K RIH from 9,341' began to see 10-15K drag at 9,398' (TOW @ 9,391') circ hole and worked reverse junk basket down and tagged XO below hook at 9,413', attempted to go out of hook window with BHA #17 with no success, worked pipe approx 30 times and could not get to go thru window, tried numerous combinations trying to go thru window, with and without pumps, rotating pipe up different turns, rotating down etc. and wouldn't go thru. Decision was made to change hole over to brine, run 4 1/2" tbg and move rig off. POOH from.9,413' to above hook to 9,380',. pumped 30 bbls sweep with 9.0 ppg brine and Safe Surf-O then displaced hole over from 9.0 ppg SFMOBM to 9.0 ppg Brine, circ hole at 8 bpm at 1,050 psi, 50 rpm's with 11-13K ft-Ibs torque, circ a total of 700 bbls of brine Monitored well-static, took SPR's POOH with BHA #17 from 9,380' to 8,424' LD 10 stds of 5" HWDP RIH with 5 stds of 5" HWDP to 8,885' rnrneu: iur<or<uvo ,u.ca.u nm r~ r~ J ConocaPhillips Alaska Page 33 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date .From - To Hours Code Code PhasE 8/12/2005 107:00 - 16:30 I 9.501 DRILL I PULD I CMPLT3 16:30 - 19:15 2.75 I DRILL PULD {CMPLT3 19:15 - 21:00 I 1.751 FISH I PULL I CMPLT3 21:00 - 21:30 0.50 CMPLTN PULD CMPLT3 21:.30 - 22:00 0.50 CMPLTN KURD CMPLT3 22:00 - 22:15 0.25 CMPLTN SFTY CMPLT3 22:15 - 00:00 I 1.751 CMPLTNI RUNT I CMPLT3 { 8/13/2005 00:00 - 05:00 I 5.00 I CMPLTNI RUNT CMPLT3 05:00 - 05:45 I 0.751 CMPLTNI RUNT CMPLT3 05:45 - 06:15 I 0.501 CMPLTNI SOHO I CMPLT3 06:15 - 07:00 I 0.75 I CMPLTNI RURD i CMPLT3 07:00 - 11:00 I 4.001 CMPLTNI NUND I CMPLT3 11:00 - 12:00 { 1.001 CMPLTN{ RURD CMPLT3 12:00 - 13:00 I 1.00 RIGMNT RSRV CMPLT3 13:00 - 15:00 j 2.00 RIGMNT RSRV CMPLT3 15:00 - 16:30 I 1.501 CMPLTN{ OTHR {CMPLT3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8!13/2005 Rig Release: Group: Rig Number: Description of Operations POOH with BHA #17 LD HWDP & DP from 8,885' to BHA at 362', LD 5 stds of 5" HWDP, 11 stds 5"slick DP, 69 stds of 5" DP with Lo-Tads and 4 stds of slick 5" DP to BHA (267 jts total) found many Lo-Tads to be worn and rollers flat spotted, cleaned rig floor RU mousehole and LD 37 stds of slick 5" DP out of derrick, LD a total of 408 jts of DP RU 4" handling equipment and POOH LD BHA #17 from 362', LD jars, 7-jts of 4" XT-39 DP, 2-boot baskets and 6 3/4" reverse circ junk basket, had no recovery in reverse circ junk basket or lower boot basket, in upper boot basket had 2 small pieces of metal and approx 1/2 cup of pieces of cement, calc fill on trip out of hole 83 bbls, actual fill 99 bbls Pulled wear bushing RU Doyon's 4 1/2" tbg handling equipment Held PJSM with rig crew and tong operator on running order of 4 1/2" tubing and associated hazards PU seal assembly on 1 bent jt of 4 1/2" 12.6#, L-80 tbg, changed out used collar, then began PU and RIH with 4 1/2" 12.6#, L-80, IBT tubing to hang off in well, RIH with 55 jts of 4 1!2" tbg to 1,737' RIH with 4 1/2" kill string with bent jt and seal assembly from 1,737' to 9,362' (Top of Hook @ 9,386') st wt up 100K, do wt 55K, ran 247 jts of tbg (302 jts total) Cont to RIH and tagged XO below hook at 9,413' with end of seals at 9,446', PU rotating tbg to TOW at 9,391' and on 3rd attempt went thru hook, cunt to RIH and tagged junk in hole at 9,592' PU and spaced out kill string with 2-4 1/2" pup jts (13.65'), MU full jt of tbg above pups and then MU hanger, landed hanger with no problems, landed tbg with end of seals at 9,590', st wt up 100K, do wt 53K (EOT -2' above Junk) RIH with seals, 1-4 1/2" bent jt, 307 jts 4 1!2" 12.6 ppf, L-80 IBT tbg, 2-pup jts,1-jt tbg and hanger, total RIH 9,567.14 (RKB to ULDS 22.74') LD landing jt and RD Doyon's 4 1/2" handling equipment, Vetco Gray tested both upper and lower seals on hanger to 5,000 psi and tested each for 10 min, good test ND BOP's and set off stack, NU Vetco Gray 13 5/8" x 4 1/16" 5M Tree, tested tree and void to 5,000 psi each for 10 min, good test, pulled TWC and installed BPV and secured well Cleared rig floor, LD XO subs and cont to clean mud pits and rock washer, cleaned out cellar box Slip and cut 62' of drlg line Changed out saver sub and serviced top drive while cont. to clean mud pits Fin cleaning mud pits and rock washer, Sim-Ops: moved camp, sewer plant and truck shop to 1 J pad, RELEASED RIG @ 16:30 hrs 8113105, Rig to move to 1J-168 Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 1 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/R ECOM P Start: 9/24/2005 End: Contractor Name. Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Phase Description of Operations Code 9/24/2005 18:00 - 00:00 6.00 MOVE KURD DEMOB Rig down lower derrick and prepare to move to 1 E-117 9/25/2005 00:00 - 03:00 . 3.00 MOVE RURD DEMOB Rig down lower derrick and prepare to move to 1 E-117 i 03:00 - 09:00 6.00 MOVE MOVE DEMOB Move From 1 D to 1 E-117 Spot rig over well 09:00 -13:00 4.00 WAITON OTHR RIGUP Pre-job safety meeting. Prepare to spot rig. Call out BPV crew and install with scaffolding crew also. 13:00 - 16:00 3.00 MOVE RURD DEMOB Spot rig and prep for rig up. 16:00 - 00:00 8.00 WAITON WOW RIGUP Except rig @ 16:00 hrs 9/25/200. Wind speed from 19 MPH to 34 MPH stand by for raising derrick. Chuck Scheavy AOGCC declined to witness BOP test tonight @ 07:OOPM 9!26!2005 00:00 - 06:00 6.00 WELCT NUND DECOMP ND tree and NU BOP's, 13 5/8 with variables 3.5"- 6" 06:00 - 13:00 7.00 WELCT BOPE DECOMP Tower safety meeting continue to NU BOP's BOPE test waived by Chuck Sheavy @ 1900 hrs 9-25-2005. Perform BOPE test 250 PSI low, 3,000 PSI high. 13:00 - 14:00 1.00 WELCT NUND. DECOMP Blow dwn all line and prepare to pull Two way check. 14:00 - 14:30 0.50 WELCT NUND DECOMP Pull Two way check: No pressure on well. 14:30 - 15:30 1.00 FISH SFTY DECOMP Pre-spud program. All hands for meeting. 15:30 - 17:30 2.00 FISH PULL DECOMP Prep rig floor for Pull. Pull hanger to floor. 67K up wt. no overpull while pulling out of hanger bowl. At 24' 15K over pull with normal fallback. Monitor wellbore for conditions. Clean and lay down hanger assym for inspection. Small mark on side. Vetco rep Erick says no problem. 17:30 - 18:00 0.50 FISH SFTY DECOMP Count 220 jts in pipe shed. All that will fit in our current configuration and still be able to lay down 4.5" kill string. BOPE drill. Shot fluid level @ 26' and holding 18:00 - 00:00 6.00 FISH SFTY DECOMP Night shift pre-spud program. Continue to POOH with 4.5" Kill string. Up WT. 72K 9!27/2005 00:00 - 06:00 6.00 FISH PULL DECOMP Continue to POOH with 4.5" kill string 06:00 - 12:00 6.00 FISH PULL DECOMP Pre Tower safety meeting, then continue pulling Kill string. Continue to work with fluid @ 26' below Kelly, DHD will shoot two fluid level shots per day 6:00 and 18:00. 41 bbl loss for the day. 12:00 - 15:00 3.00 FISH PULD DECOMP Out of the hole with the kill string. Strap remainder of pipe pulled, check OD of collars. All collars 5.17-5.20", pipe count /lengths matched run tally. Confer with workover engineer. 15:00 - 20:30 5.50 WAITON EOIP DECOMP Waiting on modifications to be made on mainbore diverter at Baker machine shop. Move remainder of PH-6 workstring into pipe shed and ~ begin strapping, 20:30 - 23:30 3.00 WELLS EQRP DECOMP Ph-6 work-string loaded in pipe shed and strapped. BHA on location begin rigging up. 23:30 - 00:00 0.50 WELLS TRIP DECOMP BHA rigged up consisting of Diverter 5'long, with a 9.48' 4.5 IF pup, 3.5" X 4.5" IF XO 1.90' long, Sperry Sub 3.5" IF 2.89' long, with UBHO inside, a 3.5 IF pup 7.59' long and a XO 3.5" IF to PH-6 1.6T long. Followed by 300 joints of PH-6 work-string to surface UBHO is set to start 12 hours from 11:00 PM Tuesday (or 11:00 AM) and will take samples for 16 hours @ 1 sample per min, until Thursday morning at 2:00 AM. Start tripping in the hole .912812005. . 00:00 - 06:00 6.00 WELLS TRIP DECOMP Continue to trip Sperry's memory UBHO to verify orientation of Main bore Diverter 06:00 - 11:40 5.67 WELLS TRIP DECOMP Pre tower safety meeting, high wind spead +_ 50 MPH Continue to trip Sperry's memory UBHO on 3.5 PH-6 tubing avg. about 26 joints per hour. Fluid level is aprox. 10' down from RKB. 43 bbl loss during for the day. 11:40 - 12:10 0.50 WELLS OTHR DECOMP Tag up at 9386'. PU wgt=75k, RIW=16k. Pick up off hook hanger...clean pickup, no overpull. RBIH and tag same, pick up to Printed: 10/28/2005 10:23:49 AM • ConocoPhillips Alaska Page 2 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Phase Code 9/28/2005 11:40 - 12:10 0.50 WELLS OTHR DECOMP 12:10 - 12:35 0.42 WELLS OTHR DECOMP 12:35 - 13:00 0.42 WELLS OTHR DECOMP 13:00 - 14:45 1.75 WELCT OTHR DECOMP 14:45 - 18:00 3.25 WELLS TRIP DECOMP 18:00 - 00:00 6.00 WELLS TRIP DECOMP 9/29/2005 00:00 - 01:30 1.50 WELLS EORP DECOMP 01:30 - 06:00 4.50 WELLS TRIP DECOMP 06:00 - 08:30 2.50 WELLS TRIP DECOMP I 08:30 - 09:30 1.00 WELLS PERF DECOMP 09:30 - 11:00 1.50 WELLS PERF DECOMP 11:00 - 12:30 1.50 WELLS PERF DECOMP 12:30 - 18:00 5.50 WELLS TRIP DECOMP 18:00 - 23:00 5.00 WELLS TRIP DECOMP 23:00 - 00:00 1.00 WELLS RURD DECOMP 9/30/2005 00:00 - 01:30 1.50 WELLS RURD DECOMP 01:30 - 02:30 1.00 WELLS TRIP DECOMP 02:30 - 03:30 1.00 RIGMNT RSRV DECOMP Description of Operations 103k, latched. Get 5 minute sample. Pick up, see tool unlatch at 100k. PUH 10' and rotate pipe w/ power tongs. 2 turns in (see turn at 4-5k torque), get 1-3/4 back. Get 5 minute sample. Run back in hole and tag same; latch up. Get 5 minute sample. Pick up; see diverter unlatch again at 100k continue out 10'. Attempt to rotate, get 3/4 turn downhole. Get 5 minute sample. Run back in hole and tag same; latch up. Get 5 minute sample. Attempt to pull free; 95k pulling out off hole dragging what appears. to be the hook hanger. Pull up approx. 8'; dragging 95k. Attempt to run back in hole, stacking out. Shut down to confer and call W/O engineer. Discuss options. Decide to attempt to "shuck" off hook hanger. Pull up hole a little quicker, 100-105k#...still just dragging. Run back in hole and re-attempt only puling faster. At 120k pick up weight, see snap latch release leaving. hook hanger at approx. 9374'. Begin puling out of hole racking back workstring, .pumping hole fill.... Shoot fluid level; fluid approx. 175' down. Continue pulling out of hole. Assembly BHA for Schlumberger gun run, consisting of 20.4' pert gun, 28.31' of CS HYD, 2.05' of XO, 14.02' space out pups, HR running tool 22.65', Bumper sub 7.86', XO to PH-6, and PH-6 work string to 9440' RKB to punch 9 holes in ECP. Fill hole with 15 bbls of 8.7 brine this brought the fluid level in the stack but it was dropping slowly. BHA made up ready to start running stands of PH-6 work-string. Fluid level about 90' Tower safety meeting Shoot fluid level to insure stable hole. Continue to RIH with PH-6 and pert gun Averaging 25 stands per HR. Tag up in hook hanger at 5' down on jt. #30. RIW=17k, PUW=75k. Pull up hole to see if latched; slight wgt increase 5-6k# to 80K. Run back in hole and set down in same spot, pull up hole of see if latched, same as previous attempt. Repeat with same results, not conclusive if latched. Install headpin, rig to check for circulation. Establish ability to circulate, 1 bpm @ 200 psi. Drop ball and come online displacing. at 1 bpm. Pert interval spaced out putting top shot at 9466', lower shot at 9468'. Latched HR profile at 9419'. 77 bbls away, see circulating pressure drop, rate increase. Good ~ indication of gun firing. Attempt to run in hole, move freely 4'. Rig down, headpin and begin pulling out of hole. No "bobbles" or drag seen ~ through window, nothing definitive to show packer is on. Note: Sperry hand called to inform he was able to get info from UBHO tool. Sperry tool indicated diverter aligned 100 deg L of high side placing hanger oriented 180 deg R of high side. Averaging about 18-20 stands/hr. Keeping hole full; losing approx 5 bbls/hr. Make crew changeout. Continue to pull fishing string OOH OOH with BHA Hook Hanger on HR running tool, and ECP packer alt shots fired ECP deflated and on surface element intact. Rig up Clean out BHA consisting of a 4-5/8"junk basket, two 3-1/8" collars, 8-5/8" OD string mill, 4 joints 3-1/2" 13.3# HT38 drill pipe, and fishing jars on the 3-1/2" PH6 work string wash to the bottom of the "B" lateral LEM seal bore (4.75" ID; top at 9667' RKB and bottom at 9687'). Continue to rig up Clean out BHA fluid level approximately. 110' RIH with cleanout BHA using 150 stands and 7 joints of 3.5" PH-6 tubing torque to 7000 psi Rig maintenance slipping drill line. Fluid level 90' down, man rig floor Printed: 10/28!2005 10:23:49 AM • ConocoPhillips Alaska Page 3 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20!2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub ' Phase -_ - 9/30/2005 02:30 - 03:30 03:30 - 06:00 Code ---- - 1.OOf RIGMNT RSRV 2.5011 WELLS TRIP 06:00 - 10:00 4.00 WELLS TRIP 10:00 -.11:00 1.00 WELLS MILL 11:00 - 18:00 I 7.001 WELLSI~I RURD 18:00 - 20:00 2AO WELLS RURD 20:00 - 22:00 2.00 WELLS MILL 22:00 - 00:00 2.00 WELLS RURD 10/1/2005 00:00 - 02:30 2.50 WELLS RURD 02:30 -06:00 3.50 WELLS TRIP 06:00 - 18:00 12.00 WELLS TRIP 18:00 - 21:00 3.00 WELLS TRIP 21:00 - 00:00 3.00 WELLS RURD 10/2/2005 00:00 - 03:00. 3.00 WELLS RURD 03:00 - 06:00 3.00 WELLS TRIP 06:00 - 07:30 1.50 WELLS TRIP 07:30 - 15:00 7.50 WELLS TRIP 15:00 - 18:00 3.00 WELLS TRIP 18:00 - 00:00 6.00 WELLS TRIP 10/3/2005 00:00 - 03:30 3.50 WELLS TRIP 03:30 - 05:00 1.50 WELLS TRIP Description of Operations DECOMP and monitor well DECOMP Continue to RIH with fishing string drill line slipped and ready to trip pipe. Hole stable, fluid level 90' from surface. DECOMP Pre tower meeting continue RIH with cleanout string. Fluid loss to well= 73 bbl last 24 hrs, 193 bbts cummulative. Shoot fluid level, 54' from surface. DECOMP Tag up at 9470'. putting depth of string mill at 9400'. PUW = 87k. Pull up hole 10', attempt to rotate with power tongs while moving back in hole. Pipe rotating freely at 3800# of torque while moving. Rih to tag; pipe "torquing" at tag, 5500-6500#. Shut down and prep to rig up power swivel. DECOMP Conduct pre job safety meeting on picking up /rigging up power swivel. Begin rig-up. DECOMP Crew change-out. Shoot fluid level=59' continue to rig up power swivel DECOMP Milling with string mill from 9390'-9396'. PUW = 85k. Pipe rotating at 6000# of torque about 36 RPM pump rate 3 BPM 1100 psi long way, RIH slowly, power swivel stalling out @ about 7000#. Work pipe free and attempt to mill down for two hours with same results making no hole. Concern over losing BHA below string. mill (due to backlash from milling operation) resulted in Shut down milling with this BHA and rigging down power swivel. Circulating resulted in 50 of OBM returns to surface. DECOMP Rig down power swivel and prepare to come out of hole with PH-6 laying down ordered 290 bbls of 8.9 pps brine with 3% KCL. 4" XT-39 drill pipe from Doyon 141 on location load into pipe shed and strap. DECOMP Continue rigging down power swivel and prepare to come out of hole with PH-6 laying down DECOMP Power swivel laid down start pulling PH-6 laying down sideways. Hole ~ fill, pipe displacement plus 3 bbls per 10 JTS. Fluid down approximately 60'. Conduct BOP drill. DECOMP Tower safety meeting continue to trip PH-06 OOH. Shoot fluid level =57'. Filling hole with pipe displacement, adding 2-3 bbls roughly every 5 stands. DECOMP Crew changeout. Continue out of hole with fishing string. DECOMP OOH with BHA, 8 518" string mill showed some scratches on smooth gauge of Mill. Clean floor, load 4" XT-39 dril{ pipe in shed and pick up Kelly. DECOMP Kelly picked up ready set floor up to rig up fishing BHA. Continue loading pipe shed and strapping XT-39 drill pipe. Drift 2.347" DECOMP Assemble Fishing BHA consisting of 8.5"Junk Basket, 8.625" String Mill, 6.25 Oil Jar, One 6" Drill Collar, and 4" XT-39 Drill pipe to surface. DECOMP Tower Safety meeting Ice conditions and safey use of spinner safety topics. Make up BHA and prep to begin RIH with 4" drill pipe, Mill and Junk Basket. Note: Lost 48 bbls to formation in last 24 hrs. DECOMP Pipe skate broken; chain on skate has come apart. Begin hunting down parts, call out mechanic. Pull BHA back to surface. DECOMP Resume running back in hole with 4"drill pipe, milling string. Conduct spill drill. DECOMP Crew changeout. Shoot fluid level= 120'. continue to RIH with 4"drill pipe average 25 jts. hour Rabiting Drill string 2.347" DECOMP Continue running back in hole with 4" drill pipe, milling string. DECOMP Pick up Kelly and tighten connections prepare to rotate through tight spot @ 9400' RKB Printed: 10/28/2005 10:23:49 AM • • ConocoPhillips Alaska Page 4 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/R ECOM P Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/3/2005 05:00 - 07:00 2.00 WELLS MILL DECOMP Tagged obstruction @ 9392' RKB, rotating and working downfrom 938T ~ to dress up window. 60 RPM's pumping 2 BPM long way, torque gauge is not showing any torque, though off zero. 115K# up WT. 34K# down WT , 62K# down WT while rotating. Circulating at 2 bpm. 38 bbls lost in last 24 hrs, 287 bbls cumulative. 07:00 - 08:00 1.00 WELLS MILL DECOMP Mill through to 9407'; see little to no "work" .Pull back through and make 2 more trips backreamming through. Down wgt. 30k, up wgt. 125k. Clean pickups through window. Make trip across window without rotating...clean pick-ups. Kelly buried; stop circulating pick up 10' of pups and work down to 9417'. Resume circulating at 2 bpm. 08:00 - 09:00 1.00 WELLS MILL DECOMP Make 3 additional trips through window at 90 RPM. Trip again across window without rotating, 30k dn, 125k up, 70k rotating...clean pickups. Make 1 more trip back across window at 100 RPM. Stop circulating. .09:00 -1.1:00 - .2.00 WELLS MILL DECOMP Break. out. pups and pick up full jt. Resume circulating 2:0 bpm. Work through to Stop pumping. Begin picking up singles under Kelly and continue running in hole. 11:00 - 12:30 1.50 WELLS CIRC DECOMP Tag up 30' in on Kelly, jt #307 in hole (9646' orig RKB); come back online circulating bottoms up @ 3 bpm. Reciprocate with Kelly off bottom, make 3 trips to bottom while rotating, PUH after tag. 12:30 - 14:30 2.00 WELLS CIRC DECOMP 250 bbls around; break out Kelly and stand back. 14:30 - 18:00 3.50 WELLS TRIP DECOMP Begin pooh with 4" drillpipe, racking back. Begin filling hole across the top on the way out. 18:00 - 00:00 6.00 WELLS TRIP DECOMP 60 stands out of. Losing 3 bbls every 5 stands, swap back to filling pipe displacement, pumping extra every 5 stands. 10/4!2005 00:00 - 01:30 1.50 WELLS TRIP DECOMP POOH with String Mill and Rev. Junk Basket. Junk Basket full of combination of Cement and Metal cuttings some of the cement pieces are 4" to 6" long metal cuttings some 2" to 3" long appear to be from window cutting operation. Rig up floor to start BOP testing. Cont to rig down BHA. 01:30 - 06:00 4.50 WELCT BOPE DECOMP Prepare for weekly BOP test. State witness of BOP test waived by John Crisp @ 3:00 pm 10/3. Function test BOP rams. Press test BOP and choke manifold to 250 / 3000 psi. 06:00 -06:30 0.50 WELCT BOPE DECOMP Tower safety meeting currently BOP testing. 06:30 - 07:30 1.00 WELCT BOPE DECOMP Pressure test Kelly valves to 250 / 3000 psi. 07:30 - 11:00 3.50 WELLS PULD DECOMP BOP Test completed at 07:30. Stand back Kelly and prep to pick up drillpipe. 11:00 - 17:30 6.50 WELLS TRIP DECOMP Pick up and run in hole with Bent jt of 5.5", Xovers and 4" Drill pipe. 17:30 - 18:00 0.50 WELLS SFTY DECOMP Tower safety meeting. Focus on pinch points and incident with floorhand getting finger pinched & fractured between 4" DP and DP Spinner Hawk. 18:00 - 21:30 3.50 WELLS TRIP DECOMP Cont RIH with 4" DP std's from derrick. Weights at 9360' 107 Klbs up/27 Klbs down. 21:30 - 22:00 0.50 WELLS TRIP DECOMP Tag up 6.5" OD x-over above 5.5" Bent joint on 6.25" ID X-over6 ft into 7" Tie-back, at 9506' RKB. Based on above, bottom of Bent joint at 9550'. Tie-back top is at 9500' and 7" x 5.5" X-over at 9553' RKB. L2 "D"-lateral liner is set 17' deeper than reported. 22:00 - 23:00 1.00 WELLS TRIP DECOMP Pull back into main bore, rotate 6 turns, get 1.5 turns back: Trip in hole, take 4-5 Klbs weight from 9655' to hard tag at 9660' RKB. Re-tag same depth and set down 8 Klbs. Estimate 5-6 ft ofjunk above seal bore below ZXP packer. 23:00 - 00:00 1.00 WELLS TRIP DECOMP POH racking 4" DP back stands in derrick Fill hole with displacement + 2-3 bbls everey 10 stands. 17 of 153. stands out at rpt time. 10/5(2005 00:00 - 06:00 6.00 WELLS TRIP DECOMP Continue pooh with 4" DP and 5.5" bent joint assy. Depth at 06.00 hrs= PflMetl: 1028/"LUGS 10:23:49 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: WORKOVER/RECOMP Start: 9/24/2005 Contractor Name: Rig Release: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code' Phase 10/5/2005 00:00 - 06:00 6.00 WELLS TRIP DECOMP 06:00 - 08:30 2.50 WELLS TRIP DECOMP 08:30 - 09:30 1.00 WELLS PULD DECOMP 09:30 - 11:30 2.00 WELLS PULD CMPLT3 11:30 - 12:00 0.50 RIGMNT RSRV CMPLT3 12:00 -16:00 4.00 WELLS PULD CMPLT3 16:00 -17:00 1.00 WELLS OTHR CMPLT3 17:00 - 18:00 1.00 WELLS TRIP CMPLT3 18:00 - 00:00 6.00 WELLS TRIP CMPLT3 10/6/2005 103:00 -.05:30 2.50 WELLS PLGM CMPLT3 05:30 - 09:30 4.00 WELLS PLGM CMPLT3 09:30 - 11:30 2.00 WELLS PLGM CMPLT3 11:30 - 14:30 3.00 WELLS PLGM CMPLT3 14:30 - 19:00 4.50 WELLS CMPLT3 19:00 - 21:00 2.00 WELLS TRIP CMPLT3 21:00 - 00:00 3.00 WELLS TRIP CMPLT3 10!1/2005 100:00 - 02:30 I 2.50 I WELLSI~I TRIP I CMPLT3 Page 5 of 9 Spud Date: 6/20/2005 End: Group: Description of Operations 1600 ff. 120 bbls 8.9 ppg brine 3°!° HCL lost to well last 24 hrs. Tower safety meeting. Cont pooh to surface. Rig up to handle bent joint x-o's, break and lay down same. Clear rig floor. Load pipe shed with Hook Hanger assy and pup joints, bring same to rig floor. Lubricate and service rig. Pick up and make up 5.5" bent jnt, 5.5" pup jnt's, ECP, 5.5" spacer pup jnt's, Model 'B' Hook Hanger and running tool. Details of Hook Hanger BHA under Pipe Tally. Clear and clean rig floor in preparation for tripping in hole. Rih with Hook Hanger BHA on 4" XT DP. Tower safety meeting. Continue rih wih HH BHA on 4" XT Drill Pipe. Depth at rpt time 6331 ff. Cont rih to 9350': Record up/down weights-105 ! 21 Klbs. - Rih and slide to a stop at 9554'. Puh, increase speed dwn and tag 7" x 5,5" x-o in L2 "D" at 9556' rkb w/ full weight of string. Puh to 9550, rih confirm tag at 9556'. Puh w/ 10 Klbs o/pull to 9505', rotate 8 turns, get 5 back, rih set down at 9533'. Puh to 9520' w/ 20 Klbs o/pull. Increase speed down and tag up 9554, puh & see 25 Klbs o/pull at 9549'. Rih tag 9556', puh hang up at 9539'. Rih 10', puh faster and slipped past restr w/ 45 Klbs o/pull, puh to 9520'. Rotate 12 turns, get 7 back. Rih tag 9556', puh hang up at 9543'. Free movement of pipe between 9543' and 9556', make +-30 attempts to pull past restriction av various speeds and and o/pull, max o/pull 75 Klbs (180 Klbs). Evaluate and discuss with town options to free and land hook hanger . Put 5 rounds torque in pipe, held with rig tongs. Worked up and down to work torque down to Hook for orienting Hook in window. Got 2 rounds back. Picked back up to 175K (50K overpull) still stuck but have 13' of travel. Worked up and down atempting to set Hook with no luck. Repeated procedure trying to work torque down to turn the Hook. On !second attempt we got 5 1/2 turns back. Made third attempt putting 8 ~ rounds in without holding torque with rig tongs. Released and got 3 turns back. Worked up and down 6 times, on down stroke of 6th attempt appeared to hook. Picked up to unhook and pulled over to 175K. Wt bled off to 150K, picked back up to 175K, original tight spot. Tried to go back down to where we hooked but could not get all the way back down, 3' higher. Worked pipe up and down attempting to get loose, max pull was 225K. Evaluate and discuss options to free or shear HR. RU head pin. Filled hole. Established circulation.26PM @160 psi. Worked pipe while circulating still stuck no movement. Set weight down, dropped ball, ciruclated ball down at 3 BPM @ 220 psi for 60 bbls. Slowed pump down to 1.5 BPM @ 120 psi. Ball on seat at 85 bbls. Press up to 1400 psi, picked up was not released. Set wt back down press up to 1600 psi, bled off press. Picked up to 150K popped free, pulled free for 4' hung up again pulled up to 225K. Worked pipe up and down and rotating to work free. Pulled up to 235K and pulled free. Note: When released the Hook Hanger the top of hanger @ 9383', Hook @9404' and the mule shoe @ 9543'. Pooh to 8200' laying down 4" DP. Tower safety meeting. Continue pooh laying down 4" DP. Depth at rpt time; 6100'. Lost 48 bbls brine to well last 24 hrs Continue pooh with Hook Hanger Running assy, laying down 4" XT39 Printed: 1028!2005 10:23:49 AM • ConocoPhillips Alaska Page 6 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - ~o Hours Code Code Phase 10/7/2005 00:00 - 02:30 2.50 WELLS TRIP CMPLT3 02:30 - 03:30 1.00 WELLS OTHR CMPLT3 03:30 - 10:30 7.00 WELLS TRIP CMPLT3 10:30 -11:30 1.00 WELLS TRIP CMPLT3 11:30 -16:00 4.50 WELLS OTHR CMPLT3 16:00 -18:00 2.00 WELLS OTHR CMPLT3 18:00 - 21:30 3.50 WELLS PULD CMPLT3 21:30 - 22:00 0.50 WELLS OTHR CMPLT3 - 22:00 - 00:00 2.00 WELLS TRIP CMPLT3 10!812005 00:00 - 05:30 5.50 WELLS TRIP CMPLT3 05:30 - 06:30 1.00 WELLS TRIP CMPLT3 06:30 - 11:00 4.50 WELLS TRIP CMPLT3 11:00 - 15:00 4.00 WELLS TRIP CMPLT3 15:00 - 16:00 1.00 WELLS OTHR CMPLT3 I 16:00 - 18:30 2.50 WELLS OTHR CMPLT3 18:30 - 20:30 2.00 WELLS OTHR CMPLT3 20:30 - 23:00 2.50 WELLS PULD CMPLT3 23:00 - 00:00 1.00 WELLS TRIP CMPLT3 1019/2005 00:00 - 07:30 7.50 WELLS TRIP CMPLT3 07:30 - 09:00 .1.50 WELLS TRIP CMPLT3 09:00 - 13:00 4.00 WAITON EQIP CMPLT3 13:00 - 14:00 1.00 WELLS PULD CMPLT3 14:00 - 20:00 6.00 WELLS TRIP CMPLT3 20:00 - 20:30 0.50 WELLS SFTY CMPLT3 20:30 - 00:00 3.50 WELLS TRIP CMPLT3 10/10/2005 00:00 - 02:30 2.50 WELLS TRIP CMPLT3 Description of Operations DP. Swap 4" DP handling equipment, returning equipment belonging to Doyon 141. Cont pooh and laying down 4" XT39 DP. Lay down Baker HR running tool and associated jewelry. Unload pipe shed and rig floor of all and any Xt-39 drill pipe and handling tools and ship back to rig 141. Began loading pipe shed with 4" HT-38 drill pipe. Strapped all 4"-HT-38. Move BHA and handling equipment to rig floor. Pick up Main Bore Diverter, Sperry UBHO sub, bumper sub, and jars. Set UBHO to start recording at 05.10 hrs AM, 10/08105, recording interval 1 min. Clear and clean rig floor in prep for tripping. Rih picking up 4" HT38-singles from pipe shed. Depth at rpt time 1381 ft. Lost 48 bbls 8.9 ppg brine to formation last 24 hrs. Cont trip in hole with Main Bore Diverter, Sperry UBHO, oil jar and bumper sub, picking up 4" HT38 singles from pipe shed. Tower safety meeting. Focus on drop zones, lock-out procedures and handling DC's. Load remaining 4" HT38 DP into pipe shed and strap same. Cont rih with 4" HT38 DP from 6063' to 8670'. Picked up 15 - 6 1/8" Drill collars and 9 more jts of HT38 drill pipe. Up wt.= 111 K Dwn wt.=48K. Lowered diverted and latched up 9393.65',(top of hook hanger @ 9385' Hook @ 9406'). Set 15K down wait 10 min. PU pulling 115K dragging 10'. Wait 5 min. RIH set down 15K again at same depth, wait 10 min. PU pulling 115K again dragging, wait 5 min. RIH set 30K down at same depth. Wait 10 min. PU pulling 117K dragging. Pulled up 10' to connection, broke connection and set TIW valve. Discuss options with town. Tower safety meeting, focus on handling 6" DC's Rih from 9381', start to take wt @ 9393', set down all wt @ 9398' (18:54 hrs). Wait 10 min, DP slide to regain all down wt 40 Klbs (19:04 hrs). Cont rih with full wt 40 Klbs to 9402' (19:12 hrs, Hook @9414' RKB). Puh to 1st connection 9381' (19:54 hrs) with 90 - 95 Klbs. Reason for loss of up wt unknown. Cont puh to 9350', same up wt but indications of Hook Hanger assy being pulled through window. Pull 4 stands with 90-95 Klbs up wt. Pull and lay down 13 ea 6" XH DC's. Trip out of hole with 4" HT38 DP. Depth at report time 7800'. Lost 82 bbls brine to formation last 24 hrs. Cont pooh from 7800' racking back 4" HT38 DP stands in derrick.. Tower safety meeting, focus on breaking and laying down BHA. Start laying down BHA. Did not recover Hook Hanger. LD Diverter. Discussed options with town Engineers. Wait on Baker HR running tool PU and run in hole with Baker HR Tool (6.80" OD), bumper sub and jars on HT38 drill pipe to fish out Hook Hanger. Rih with 4" HT38 DP to 4800 ft. ~ Kick 1 BOPE drill /audit, followed up by debrief and safety meeting. Cont trip in hole to 8200' with 4" HT38 DP stands from derrick. Lost 93 bbls brine to formation last 24 hrs. Cont rih stands from 8200' to 9345'. Check weights up 87 Klbs /down Printed: 10/28/2005 10:23:49 AM • • ConocoPhillips Alaska Page ~ of 9 Operations Summary Report Lega{ Well Name: 1E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/R ECOM P Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/10/2005 00:00 - 02:30 2.50 WELLS TRIP CMPLT3 27 Klbs. 02:30 - 04:00 1.50 WELLS TRIP CMPLT3 Cont rih to 9600' picking up singles, HR running/pulling tool latch mechanism at 9590'. (Top of ZXP Packer at 9647' MD). No indications of weight fluctuations across window area. Weights up 95 J down 25 Klbs 04:00 - 04:30 0.50 WELLS TRIP CMPLT3 POOH past window to 9300' , no indications of weight fluctuations 04:30 -12:30 8.00 WELLS TRIP CMPLT3 POOH with HR tool, standing back DP. 12:30 - 13:00 0.50 WELLS TRIP CMPLT3 Layed down BHA. 13:00 - 14:00 1.00 WELLS TRIP CMPLT3 Pick up and make up 8-112" Venturi Junk Basket, 8 jts 4" HT 38 drill pipe, bumper sub and oil jar. Tower safety meeting. 14:00 - 21:00 7.00 WELLS TRIP CMPLT3 RIH on 4" HT 38 drill pipe to 9375'. Check weights up 931 down 30 Klbs. 21:00 - 22:30 1.50 WELLS WASH CMPLT3 Cont rih tag up /set down 4 Klbs at 9397'. Pick up full wt at 9393', bumper sub open at 9391'. Rih set down 6000Ibs at 939T. Set back stand, make up single and head pin. Pick up to 9350'. Rih while pumping at 4.6 BPM / 390 psi pump press. Tag up gently at 9397. Repeat wash run same interval 3 times. See gradual incr in p/u weigth, final p/u weight from tag was 110 Klbs, gradually dropping off until normal at +-75 ft above tag. 22:30 - 00:00 1.50 WELLS TRIP CMPLT3 Pooh racking back 4" HT38 DP stands in derrick. Depth at rpt time 6600'. Lost 91 bbls brine to formation last 24 hrs. 10/11/2005 00:00 - 05:00 5.00 WELLS TRIP CMPLT3 Cont pooh from 6600' to 267' standing back4" HT38 DP in derrick. in 05:00 - 07:30 2.50 WELLS PULD CMPLT3 Lay down 8.5" Venturi Jet Junk Basket BHA. Recover Minor cement 'rocks' and 3 pieces of steel, appr L 2" x W 0.4". Pictures of debris on NSK server 07:30 - 09:00 1.50 WELCT BOPE CMPLT3 Make up running tool to test jnt, pull wear ring. 09:00 - 11:30 2.50 WELCT BOPE CMPLT3 Makeup ported pump in sub, dart- & safety valves, test plug. Rih and land same in wellhead. 11:30 - 12:00 0.50 WELCT BOPE CMPLT3 Attempt to test Annular Preventer, leak at Choke Line HCR. Grease seals and re-test, still leaking. Blow down and ready to replace HCR. 12:00 - 15:00 3.00 WELCT BOPE CMPLT3 Rep{ace leaking Choke Line HCR 15:00 - 18:00 3.00 WELCT ROPE CMPLT3 Perform weekly BOPE test to 250 psi / 3000 psi. State witness of BOPE test waived by John Spaulding @ 12:00 pm 10!10!05. 18:00 - 19:00 1.00 WELCT BOPE CMPLT3 Pull test plug, set wear ring in wellhead, lay down test equipm. 19:00 - 21:00 2.00 WELCT BOPE CMPLT3 PJSM. Pick up Kelly, press test upper & lower Kelly valves to 250 psi / 3000 psi. Break out test sub and stand back Kelly. Weekly ROPE test complete. 21:00 - 22:30 1.50 WELLS OTHR CMPLT3 PJSM. Remove BOP test equipm from rig floor- WOO- Clean and clear rig floor. 22:30 - 00:00 1.50 WELLS PULD CMPLT3 Pick up BHA: 3.625" Venturi Jet Junk Basket w/ 4.625" Burning Shoe, Bit Sub, 62 ft of 2.875" PAC DC's, X-O's, 316 ft of 4" HT38 DP, Bumper Sub and Oil Jars. See DIMS Tally for details. Depth at rpt time 443 ft. Lost 101 bbls of 8.9 ppg Brine to formations last 24 hrs. 10!1212005 00:00 - 04:00 4.00 WELLS TRIP CMPLT3 Trip in hole to 7670' with 4.625" Venturi Jet Junk Basket BHA on 4" HT38 DP std's from derrick. 04:00 - 06:00 2.00 RIGMNT RSRV CMPLT3 PJSM. Slip & Cut Drill Line. 06:00 - 08:00 2.00 WELLS TRIP CMPLT3 Continue trip in hole to 7670' with 4.625" Venturi Jet Junk Basket BHA on 4" HT38 DP std's from derrick. 08:00 - 09:15 1.25 FISH WASH CMPLT3 Record up and down wts just above Top of Hook hanger up wt = 98K dwn wt = 37K. Saw no movement of wt indicator when passing top of Hook hanger. Tagged top of ZXP @ 9647', set 5K on it an fell past. Tagged top of SBE Xover @ 9664' set 5K down, no movement, set 10K down, fell thru. Lowered down and tagged bottom of of SBE @ 9687. Printed: 1028!2005 10:23:49 AM • ConocoPhillips Alaska Page 8 of 9 !, I Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9!24!2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase 10/12/2005 108:00 - 09:15 I 1.251 FISH 09:15 -12:30 3.25 12:30 - 19:30 7.00 19:30-21:00 I 1.50 21:00 - 00:00 l 3.00 10/13/2005 02:00 - 09:00 I 7.00 09:00 - 16:00 7.00 WI 16:00 - 17:00 1.00 WI 17:00 - 18:30 I 1.50 18:30 - 20:30 J 2.00 20:30 - 21:00 21:00 - 22:00 22;00 - 00:00 10/14/2005 00:00 - 15:00 15:00 - 19:00 19:00 - 00:00 i 10!15/2005 00:00 - 01:00 01:00 - 02:00 02:00 - 15:15 15:15 - 17:30 0.50 1.00 2.00 15.00 4.00 5.00 WASH I CMPLT3 CIRC CMPLT3 TRIP CMPLT3 PULD CMPLT3 OTHR CMPLT3 PULD CMPLT3 PULD CMPLT3 TRIP CMPLT3 PLGM CMPLT3 PLGM I CMPLT3 PLGM I CMPLT3 DEQT CMPLT3 RURD CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 PULD CMPLT3 1.00 CMPLTNI PULD ~ CMPLT3 13.251 CMPLTNI PULD I CMPLT3 2.25 I CMPLTNI SOHO I CMPLT3 Description of Operations NU headpin establish circulation 36PM @ 810 psi. Run down while pumping and tagged up at same 9687', made this same movement 3 times to clean out. Picked up to 9657' and circulated hole. volume to balance well. Lay down 4 jts 4" HT 38 Drill Pipe and POOH standing back 150 stands. Lay down BHA. Recover 1/6 gal cement lumps in Junk Basket barrel. See pictures on NSK server. Clear and clean rig floor, prep to run completion. Load completion assy's into pipe shed and strap same. Make final preparations to run completion. PJSM for completion. Pick up & make up completion Sub Assy's: Seal Assy, 4.5" tbg Spacer Jnt's, LEM, Premier Packer, Seal Bore Ext, Liner Setting Sleeve and Running Tool - RIH 'D' Lateral LEM assy on 4" HT 38 drill pipe, on bottom at 16:00 Stopped to get up &dwn wts. UP=94K dwn=32K. Lowered LEM slowly past top of Hook @ 9397' clear, lowered past top of ZXP @ 9647' clear. Continued in hole to 9665' set 10k down, no movement. PU UP wt = 97K. Lowered back down tagged same @ 9665' set 10K down again no movement. PU UP wt 97K again. Lowered back down a {ittle faster, tagged again @ 9665' put 10K down wt fell off. RIH to 9667' set 10k down no movement. PU UP wt= 103K. RIH tagged same spot @ 9667', set 15K down wt fell off. RIH steady down to 9675' set down 10K. PU UP 90K RIH set 15K down at same spot 9675'. Shut down activity, call Engineer. PU to UP wt 90K lowered at faster rate, set down at same spot 9675', put 20k wt fell off made 2' (9677'). Set all wt dwn (32K). PU to 110K to confirm Iatch.This put bottom seals in the middle of the "B" lateral LEM seal bore @ 9667'-9687' (9677'). Drop ball and circ same to seat with 80 bbls at 1.6 BPM / 150 psi. Press test surface lines to 4000 psi. Open headpin and pressure up to 4000 i psi to set packer at 9369 ft (top of Premium Retrievable Packer). Clear indication of 2 sets of shear pins in packer shearing. Bled press off to 0 psi, PU to up wt 95K, free, pulled 2'. Close piperams, pressure up Drill Pipe x 9 5/8" csg annulus to 2500 psi / 30 min, good test, recorded on chart. Pump /bleed back 6.5 bbls. R/D Headpin, blow down kill&choke lines and std pipe manifold. Clear and clean rig floor in prep for pooh. PJSM. Pooh with 4" HT38 laying down singles. 108 bbls brine lost to form last 24 hrs. Depth at report time 7900 ft. Continue tripping ooh laying down 4" HT38 DP and BHA. Lay down 2 stands from derrick pull wear ring. Rig down the kelly. PJSM Load remainder of 4.5" tubing in pipe shed and strap same. Replace seal rings and drift all joint's. Lost 108 bbls brine to formation last 24 hrs. Make final preparations to run completion Pick up Seal Assy w/ Muleshoe. Rih 2 ea 4.5" tbg jnt's. Pick up and make up 'CMU' Sliding Sleeve Assy. Rih with 4.5" 12.6# L-80 IBTM tubing joints. Weights UP 77 K /DOWN 27 K Tagged top of liner sleeve with muleshoe on depth @ 9321'. Pick up rotate to get into sleeve. Tagged bottom of crossover below the Liner Printed: 10/28/2005 10:23:49 AM • ConocoPhillips Alaska Page 9 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date :From - To Hours Code Coe Phase Description of Operations 10/15/2005 15:15 -17:30 2.25 CMPLTN SOHO CMPLT3 setting sleeve @ 9332' with locator, end of seals (muleshoe) @ 9349'. 17:30 - 19:30 2.00 CMPLTN CIRC CMPLT3 19:30 - 20:00 0.50 CMPLT SOHO CMPLT3 20:30 - 22:30 2.00 CMPLT SOHO CMPLT3 22:30 - 00:00 1.50 WAITON EOIP CMPLT3 10/16/2005 00:00 - 01:00 1.00 CMPLT SOHO CMPLT3 01:00 - 06:00 5.00 WAITON EQIP CMPLT3 06:00 - 07:30 1.50 CMPLTN SOHO CMPLT3 07:30 - 12:00 4.50 WELLS NUND CMPLT3 12;00 - 12:30 0.50 WELLS PLGM CMPLT3 12:30 - 15:30 3.00 WELLS SEAT CMPLT3 15:30 - 16:00 0.50 WELLS PLGM CMPLT3 16:00 - 00:00 8.00 MOVE MOVE MOVE Set 10K down several times space out 2' off no-go. Layed down 3 jts. Installed space out pups, PU jt 306, make up hanger with head pin to pump corrosion inhibitor. Pumped 25 bbls 8.9 ppg brine with 2% by volume Petrolite CRW-132 (corrosion inhibitor) followed with 120 bbls 8.9 brine to spot. Close annular and bullhead 10 bbls @1.6 BPM 180 psi. Open Annular Preventer. Drain BOP stack. Rih with Tubing Hanger, orient and land same. Make up Lock Down Bolts, back out & lay down landing joint. Press test between seals on Tubing hanger to 4000 psi. Found orientation of Tbg Hanger side outlet to be appr 180 deg oposite flow line outlet on Well Head. B/O Lockdown Bolts. Install landing jnt and pull Tbg Hanger to Rig Floor, confirm orienting slot to be incorrectly machined / no match to wellhead. Locate replacement Tubing Hanger at KCC, wait for same to arrive on location. Lost 95 bbls brine to formation last 24 hrs. Bring replacement Tubing Hanger to rig floor. Attempt to make up lift sub to 4.909" MCA Box top of hanger, no-go, 1 thread entered only. Attempt to m/u landing jnt to 4.909" MCA Box. No-go. Lay down tbg hanger. Hot shot replacement tubing Hanger to Baker Machine Shop, Deadhorse. Machine threads and return to location. MU new tubing hanger, RIH and orient and land same. Confirm side outlet lines up with flow line. RILDS. Set BPV. ND BOPE. NU tree. Set two way check. Test tree to 250 / 5000 psi. Tubing hanger void / packoff to 250 /5000 psi. Pull two way check and set BPV, secure well, clean cellar area. Release rig @1600 hrs 10/16/2005. Prepare rig for move to 1 E-117. Lower derrick at 19.30 hrs -Pull pipe shed & pits away. Move rig from !E-117 to 1E-170. Printed: 10/2812005 10:23:49 AM DEFI~lI~'9VE Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1 E-117 Job No. AK-ZZ-0003775114, Surveyed: 9 July, 2005 Surve y Report 7 September, 2005 Your Ref: API 500292325100 Surface Coordinates: 5959600.86 N, 550300.51E (70° 18' 01.4269" N, 149° 35' 33.4054" Vl/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959600.86 N, 50300.51E (Grid) Surface Coordinates relative to Structure: 162.13 S, 409.92E (True) Kelly Bushing Elevation: 94.90ft above Mean Sea Level Kelly Bushing Elevation: 94.90ft above Project V Reference Kelly Bushing Elevation: 94.90ft above Structure ~t'tl"~lf -SU't-1 OR{LLtNG SERVtGES Survey Ref:svy2158 A Halliburton Company iHalliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117 Your Ref: AP/ 500292325100 Job No. AK-ZZ-0003775114, Surveyed: 9 July, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10771.25 90.860 182.380 3422.07 3516.97 9211.43 S 1927.28E 5950402.53 N 552289.41E 9211.43 Tie-On Point 10850.00 93.270 181.580 3419.24 3514.14 9290.08 S 1924.56E 5950323.87 N 552287.22E 3.224 9290.08 Window Point 10866.43 92.160 182.040 3418.46 3513.36 9306.48 S 1924.04E 5950307.47 N 552286.81E 7.312 9306.48 10963.07 90.910 181.610 3415.87 3510.77 9403.04 S 1920.97E 5950210.89 N 552284.38E 1.368 9403.04 11059.34 91.220 180.240 3414.08 3508.98 9499.28 S 1919.41E 5950114.65 N 552283.47E 1.459 9499.28 11155.46 90.910 178.310 3412.29 3507.19 9595.37 S 1920.63E 5950018.57 N 552285.33E 2.033 9595.37 11252.31 91.350 177.340 3410.38 3505.28 9692.13 S 1924.31E 5949921.83 N 552289.65E 1.100 9692.13 11350.30 89.980 177.710 3409.25 3504.15 9790.02 S 1928.54E 5949823.97 N 552294.54E 1.448 9790.02 11446.78 88.000 177.510 3410.95 3505.85 9886.39 S 1932.56E 5949727.63 N 552299.21E 2.063 9886.39 11539.51 87.020 176.720 3414.97 3509.87 9978.92 S 1937.22E 5949635.14 N 552304.49E 1.357 9978.92 11631.82 87.580 176.920 3419.32 3514.22 10070.98 S 1942.34E 5949543.11 N 552310.22E 0.644 10070.98 11725.09 88.940 176.780 3422.15 3517.05 10164.06 S 1947.46E 5949450.06 N 552315.96E 1.466 10164.06 11819.12 89.740 177.260 3423.24 3518.14 10257.96 S 1952.35E 5949356.20 N 552321.48E 0.992 10257.96 11913.46 89.060 177.640 3424.23 3519.13 10352.20 S 1956.54E 5949261.99 N 552326.31E 0.826 10352.20 12003.97 89.310 178.120 3425.51 3520.41 10442.64 S 1959.89E 5949171.57 N 552330.26E 0.598 10442.64 12096.99 89.490 179.280 3426.49 3521.39 10535.63 S 1962.00E 5949078.60 N 552332.99E 1.262 10535.63 12189.61 91.350 180.510 3425.81 3520.71 10628.24 S 1962.17E 5948985.99 N 552333.78E 2.408 10628.24 12282.60 91.040 180.650 3423.87 3518.77 10721.21 S 1961.23E 5948893.02 N 552333.47E 0.366 10721.21 12376.07 91.530 181.090 3421.77 3516.67 10814.64 S 1959.81E 5948799.58 N 552332.67E 0.704 10814.64 12468.45 92.090 181.360 3418.86 3513.76 10906.95 S 1957.84E 5948707.26 N 552331.32E 0.673 10906.95 12561.06 92.650 181.490 3415.03 3509.93 10999.45 S 1955.54E 5948614.74 N 552329.63E 0.621 10999.45 12651.86 93.080 181.350 3410.49 3505.39 11090.11 S 1953.29E 5948524.07 N 552327.99E 0.498 11090.11 12744.55 92.890 180.780 3405.66 3500.56 11182.66 S 1951.57E 5948431.51 N 552326.89E 0.647 11182.66 12837.63 93.700 179.160 3400.31 3495.21 11275.58 S 1951.62E 5948338.59 N 552327.56E 1.943 11275.58 12931.01 93.380 179.330 3394.54 3489.44 11368.78 S 1952.85E 5948245.41 N 552329.42E 0.388 11368.78 13023.74 92.700 180.640 3389.63 3484.53 11461.37 S 1952.87E 5948152.82 N 552330.06E 1.590 11461.37 13116.30 91.650 180.340 3386.11 3481.01 11553.86 S 1952.08E 5948060.32 N 552329.89E 1.180 11553.86 13209.02 90.780 179.130 3384.15 3479.05 11646.56 S 1952.51E 5947967.63 N 552330.94E 1.607 11646.56 13302.40 89.240 179.730 3384.13 3479.03 11739.93 S 1953.44E 5947874.27 N 552332.49E 1.770 11739.93 13395.99 88.690 181.040 3385.82 3480.72 11833.50 S 1952.81E 5947780.70 N 552332.49E 1.518 11833.50 13487.52 89.680 180.490 3387.12 3482.02 11925.01 S 1951.59E 5947689.18 N 552331.88E 1.237 11925.01 13581.16 88.440 180.180 3388.66 3483.56 12018.63 S 1951.04E 5947595.55 N 552331.96E 1.365 12018.63 13673.16 87.890 180.840 3391.61 3486.51 12110.58 S 1950.22E 5947503.60 N 552331.76E 0.934 12110.58 13766.53 88.450 181.140 3394.59 3489.49 12203.89 S 1948.61E 5947410.29 N 552330.77E 0.680 12203.89 13859.58 89.620 180.490 3396.15 3491.05 12296.92 S 1947.28E 5947317.25 N 552330.07E 1.438 12296.92 • 1 September, 2005 - 15:34 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117 Your Ref: API 500292325100 Job No, AK-ZZ-0003775114, Surveyed: 9 July, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment {ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 13952.07 90.360 180.160 3396.17 3491.07 12389.40 S 1946.76E 5947224.77 N 552330.16E 0.876 12389.40 14045.03 91.600 178.160 3394.58 3489.48 12482.33 S 1948.12E 5947131.85 N 552332.15E 2.531 12482.33 14136.56 92.970 179.070 3390.93 3485.83 12573.76 S 1950.33E 5947040.44 N 552334.97E 1.796 12573.76 14230.65 93.320 177.030 3385.77 3480.67 12667.65 S 1953.53E 5946946.57 N 552338.79E 2.197 12667.65 14322.30 93.260 178.090 3380.51 3475.41 12759.06 S 1957.42E 5946855.18 N 552343.30E 1.157 12759.06 14415.44 93.450 178.310 3375.06 3469.96 12852.00 S 1980.35E 5946762.27 N 552346.84E 0.312 12852.00 14508.49 95.440 177.960 .3367.85 3462.75 12944.72 S 1963.36E 5946669.58 N 552350.48E 2.171 12944.72 14600.42 95.430 178.870 3359.14 3454.04 13036.20 S 1965.90E 5946578.12 N 552353.63E 0.985 13036.20 14691.98 92.510 179.900 3352.80 3447.70 13127.52 S 1966.87E 5946486.80 N 552355.22E 3.381 13127.52 14785.16 92.270 178.600 3348.91 3443.81 13220.61 S 1968.09E 5946393.72 N 552357.06E 1.418 13220.61 14878.17 92.520 180.310 3345.03 3439.93 13313.53 S 1968.98E 5946300.81 N 552358.56E 1.856 13313.53 14969.89 92.580 179.670 3340.95 3435.85 13405.16 S 1968.99E 5946209.18 N 552359.19E 0.700 13405.16 15061.36 90.780 180.200 3338.27 3433.17 13496.59 S 1969.10E 5946117.76 N 552359.91E 2.051 13496.59 15153.05 90.850 181.380 3336.96 3431.86 13588.26 S 1967.83E 5946026.08 N 552359.26E 1.289 13588.26 15242.68 91.970 182.400 3334.76 3429.66 13677.81 S 1964.88E 5945936.51 N 552356.90E 1.690 13677.81 15334.09 92.770 181.600 3330.98 3425.88 13769.08 S 1961.69E 5945845.22 N 552354.33E 1.237 13769.08 15426.95 92.700 181.840 3326.54 3421.44 13861.79 S 1958.91E 5945752.49 N 552352.16E 0.269 13861.79 15520.19 91.590 181.690 3323.05 341.7.95 13954.92 S 1956.04E 5945659.34 N 552349.92E 1.201 13954.92 15610.42 90.480 181.380 3321.43 3416.33 14045.10 S 1953.62E 5945569.15 N 552348.10E 1.277 14045.10 15701.27 90.360 182.010 3320.76 3415.66 14135.91 S 1950.93E 5945478.32 N 552346.03E 0.706 14135.91 15745.30 90.550 182.380 3320.41 3415.31 14179.91 S 1949.25E 5945434.32 N 552344.63E 0.945 14179.91 ^° 15774.00 90.550 182.380 3320.13 3415.03 14208.58 S 1948.05E 5945405.64 N 552343.63E 0.000 14208.58 Projected Survey All data is in Feet (US Survey) unles s otherwise state d. Directions and coordinates are relative to True North. Vertical depths are relativ e to Well. Northings and Eastings are relative to Well. Global North ings and Eas tings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees p er 100 feet (US Survey). vertical Section is from Well and cal culated along an Azimuth of 1 80.000° (True). Based upon Minimum Cu rvature typ e calculations, at a Measured Depth of 15774.OOft., The Bottom Hole Displacement is 14341.50ft., in the Direction of 1 72.193° (True). • • 1 September, 2005 - 15:34 Page 3 of 4 DrillQuesf 3.03.06.008 Y Western North Slope Comments Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117 Your Ref.• APl 500292325100 Job No. AK-ZZ-0003775114, Surveyed: 9 July, 2005 Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 10771.25 3516.97 9211.43 5 1927.28E Tie-On Point 10850.00 3514.14 9290.08 S 1924.56E Window Point 15774.00 3415.03 14208.58 S 1948.05E Projected Survey Survev tool program for 1 E-117 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 534.60 533.84 CB-SS-Gyro (1E-117PB1) 534.60 533.84 15774.00 3415.03 MWD+IIFR+MS+SAG (1E-117PB1} ConocoPhillips • • 1 Sep#ember, 2005 - 15:34 Page 4 of 4 DrigQuest 3.03.06.00& DEFi~I~~°i"~E Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1E 1 E-117P61 Job No. AK-ZZ-3775114, Surveyed: 6 July, 2005 Survey Report 1 September, 2005 Your Ref: API 500292325170 Surface Coordinates: 5959600.86 N, 550300.51E (70° 18' 01.4269" N, 149° 35' 33.4054" VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959600.86 N, 50300.51E (Grid) Surface Coordinates relative to Structure: 162.13 S, 409.92E (True) Kelly Bushing Elevation: 94.90ft above Mean Sea Level Kelly Bushing Elevation: 94.90ft above Project V Reference Kelly Bushing Elevation: 94.90ft above Structure 5 ~C~r~-S'UC"1 E]RILLING SERVICE'S SUrveyRef:SVy2156 A Halfiburton Company • C7 Ha(liburton Sperry-Sun Survey Reporf for Kuparuk 1 E - 1 E-117P81 Your Ref: API 500292325170 Job No. AK-ZZ-3775114, Surveyed: 6 July, 2005 ConocoPhil/ips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -94.90 0.00 0.00 N 0.00E 5959600.86 N 550300.51E 0.00 CB-SS-Gyro 27.32 0.000 0.000 -67.58 27.32 0.00 N 0.00E 5959600.86 N 550300.51E 0.000 0.00 73.90 0.330 313.000 -21.00 73.90 0.09 N 0.10 W 5959600.95 N 550300.41E 0.708 -0.09 169.00 0.500 290.000 74.10 169.00 0.42 N 0.69 W 5959601.28 N 550299.82E 0.247 -0.42 260.70 0.420 285.000 165.79 260.69 0.64 N 1.39 W 5959601.49 N 550299.12E 0.098 -0.64 352.80 1.330 196.400 257.89 352.79 029 S 2.02 W 5959600.55 N 550298.50E 1.504 0.29 443.00 4.750 176.430 347.95 442.85 5.03 S 2.08 W 5959595.82 N 550298.46E 3.913 5.03 534.60 8.290 172.320 438.94 533.84 15.36 S 0.96 W 5959585.49 N 550299.65E 3.896 15.36 MWD+IIFR+MS+SAG 658.23 11.420 166.220 560.73 655.63 36.09 S 3.15E 5959564.80 N 550303.90E 2.665 36.09 753.32 15.570 159.780 653.18 748.08 57.21 S 9.80E 5959543.71 N 550310.70E 4.635 57.21 844.18 22.270 161.150 739.09 833.99 84.98 S 19.59E 5959516.01 N 550320.67E 7.390 84.98 937.40 26.080 158.730 824.12 919.02 120.81 S 32.74E 5959480.27 N 550334.06E 4.222 120.81 1028.15 28.890 155.010 904.62 999.52 159.28 S 49.24E 5959441.92 N 550350.81E 3.627 159.28 1121.12 33.890 158.520 983.97 1078.87 203.78 S 68.23E 5959397.54 N 550370.10E 5.724 203.78 1214.91 43.060 159.470 1057.32 1152.22 258.22 S 89.08E 5959343.24 N .550391.32E 9.797 258.22 1306.84 47.000 159.980 1122.27 1217.17 319.22 S 111.60E 5959282.40 N 550414.25E 4.304 319.22 1398.87 47.130 158.330 1184.96 1279.86 382.18 S 135.58E 5959219.59 N 550438.64E 1.320 382.18 1491.39 53.480 154.310 1244.04 1338.94 447.27 S 164.25E 5959154.70 N 550467.75E 7.632 447.27 1583.91 58.740 155.130 1295.61 1390.51 516.70 S 197.02E 5959085.49 N 550500.99E 5.733 516.70 1677.57 68.870 158.910 1336.91 1431.81 594.00 S 229.67E 5959008.41 N 550534.15E 11.403 594.00 1769.63 69.940 161.360 1369.30 1464.20 675.04 S 258.94E 5958927.57 N 550563.97E 2.749 675.04 1863.17 69.880 159.320 1401.43 1496.33 757.76 S 288.50E 5958845.04 N 550594.07E 2.049 757.76 1953.38 71.550 160.700 1431.23 1526.13 837.78 S 317.60E 595876523 N 550623.71E 2.348 837.78 2048.42 71.330 161.000 1461.48 1556.38 922.89 S 347.15E 5958680.31 N 550653.83E 0.378 922.89 2141.00 80.800 163.780 1483.75 1578.65 1008.44 S 374.26E 5958594.95 N 550681.51E 10.635 1008.44 2233.42 84.410 164.600 1495.65 1590.55 1096.61 S 399.23E 5958506.95 N 550707.07E 4.004 1096.61 2323.44 80.840 160.970 1507.20 1602.10 1181.86 S 425.63E 5958421.87 N 550734.04E 5.632 1181.86 2418.05 78.050 160.060 1524.53 1619.43 1269.54 S 456.64E 5958334.41 N 550765.64E 3.097 1269.54 2510.36 75.570 161.080 1545.60 1640.50 1354.28 S 486.54E 5958249.86 N 550796.11E 2.894 1354.28 2604.14 75.110 162.530 1569.33 1664.23 1440.47 S 514.87E 5958163.87 N 550825.01E 1.574 1440.47 2696.33 74.490 163.080 1593.50 1688.40 1525.46 S 541.17E 5958079.06 N 550851.88E 0.885 1525.46 2789.92 75.400 165.290 1617.81 1712.71 1612.41 S 565.80E 5957992.28 N 550877.09E 2.479 1612.41 2881.43 76.650 166.290 1639.91 1734.81 1698.49 S 587.59E 5957906.34 N 550899.46E 1.729 1698.49 2972.21 75.530 165.780 1661.74 1756.64 1784.00 S 608.86E 5957820.97 N 550921.30E 1.349 1784.00 3067.42 77.820 165.570 1683.68 1778.58 .1873.76 S 631.78E 5957731.37 N 550944.82E 2.415 1873.76 • C 1 September, 2005 - 15:24 Page 2 of 6 Dri1IC1 nest 3.03.06.008 Ha/liburton Sperry-Sun Survey Report for Kuparuk 1 E - 1 E-117P81 Your Ref.• API 500292325170 Job No. AK-ZZ-3775114, Surveyed: 6 July, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 3160.45 76.370 166.020 1704.45 1799.35 1961.67 S 654.03E 5957643.62 N 550967.66E 1.628 1961.67 3252.43 75.070 166.080 1727.14 1822.04 2048.17 S 675.52E 5957557.25 N 550989.73E 1.415 2048.17 3347.23 77.600 167.030 1749.54 1844.44 2137.76 S 696.93E 5957467.82 N 551011.74E 2.841 2137.76 3438.74 76.340 167.670 1770.17 1865.07 2224.75 S 716.46E 5957380.96 N 551031.85E 1.536 2224.75 3531.91 75.510 169.220 1792.83 1887.73 2313.28 S 734.56E 5957292.55 N 551050.54E 1.843 2313.28 3624.54 78.500 168.650 1813.66 1908.56 2401.85 S 751.89E 5957204.10 N 551068.46E 3.283 2401.85 3717.35 79.140 168.830 1831.65 1926.55 2491.15 S 769.66E 5957114.92 N 551086.83E 0.715 2491.15 3810.98 78.940 170.000 1849.45 1944.35 2581.50 S 786.55E 5957024.68 N 551104.32E 1.245 2581.50 3904.85 80.230 167.150 1866.42 1961.32 2671.98 S 804.84E 5956934.32 N 551123.22E 3.287 2671.98 3996.78 79.270 166.190 1882.78 1977.68 2760.01 S 825.70E 5956846.44 N 551144.66E 1.465 2760.01 4090.38 77.670 166.430 1901.49 1996.39 2849.11 S 847.40E 5956757.49 N 551166.96E 1.728 2849.11 4182.17 75.440 167.630 1922.83 2017.73 2936.10 S 867.44E 5956670.63 N 551187.58E 2.742 2936.10 4275.26 74.110 167.950 1947.28 2042.18 3023.89 S 886.44E 5956582.97 N 551207.17E 1.467 3023.89 4369.23 72.320 167.580 1974.41 2069.31 3111.81 S 905.50E 5956495.18 N 551226.82E 1.942 3111.81 4461.32 76.510 168.040 1999.15 2094.05 3198.49 S 924.22E 5956408.63 N 551246.12E 4.575 3198.49 4553.07 78.370 167.030 2019.10 2114.00 3285.93 S 943.55E 5956321.32 N 551266.04E 2.294 3285.93 4645.49 78.100 166.810 2037.95 2132.85 3374.06 S 964.03E 5956233.33 N 551287.11E 0.374 3374.06 4738.03 75.190 164.530 2059.32 2154.22 3461.28 S 986.30E 5956146.26 N 551309.96E 3.954 3461.28 4831.35 70.190 164.750 2087.08 2181.98 3547.17 S 1009.90E 5956060.53 N 551334.13E 5.363 3547.17 4919.56 74.110 166.540 2114.12 2209.02 3628.49 S 1030.69E 5955979.35 N 551355.47E 4.845 3628.49 5015.29 74.790 166.620 2139.78 2234.68 3718.20 S 1052.10E 5955889.79 N 551377.47E 0.715 3718.20 5108.87 75.220 167.780 2163.99 2258.89 3806.35 S 1072.12E 5955801.78 N 551398.09E 1.283 3806.35 5201.39 73.070 168.930 2189.27 2284.17 3893.51 S 1090.09E 5955714.74 N 551416.64E 2.613 3893.51 5292.48 73.510 167.850 2215.46 2310.36 3978.96 S 1107.65E 5955629.40 N 551434.77E 1.234 3978.96 5386.63 76.420 167.980 2239.88 2334.78 4067.87 S 1126.68E 5955540.63 N 551454.40E 3.094 4067.87 5470.90 80.090 166.290 2257.03 2351.93 4148.28 S 1145.06E 5955460.34 N 551473.31E 4.777 4148.28 5532.94 80.190 167.230 2267.66 2362.56 4207.78 S 1159.06E 5955400.93 N 551487.71E 1.501 4207.78 5622.03 80.180 167.450 2282.84 2377.74 4293.43 S 1178.30E 5955315.41 N 551507.52E 0.244 4293.43 5716.00 78.590 166.000 2300.15 2395.05 4383.32 S 1199.50E 5955225.67 N 551529.33E 2.272 4383.32 5808.87 78.980 165.760 2318.22 2413.12 4471.66 S 1221.72E 5955137.47 N 551552.14E 0.491 4471.66 5902.28 78.770 166.480 2336.24 2431.14 4560.64 S 1243.71E 5955048.65 N 551574.72E 0.789 4560.64 5993.39 77.930 167.450 2354.64 2449.54 4647.57 S 1263.84E 5954961.85 N 551595.43E 1.392 4647.57 6086.90 76.310 166.660 2375.48 2470.38 4736.41 S 1284.25E 5954873.15 N 551616.44E 1.918 4736.41 6179.82 75.590 166.360 2398.04 2492.94 4824.06 S 1305.28E 5954785.64 N 551638.06E 0.836 4824.06 6273.91 73.990 166.030 2422.72 2517.62 4912.23 S 1326.95E 5954697.62 N 551660.31E 1.734 4912.23 J • 1 September, 2005 - 15:24 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117P81 Your Ref: APl 500292325170 Job No. AK-ZZ-3775114, Surveyed: 6 July, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°H OOft) 6365.45 72.670 165.400 2448.98 2543.88 4997.21 S 1348.58E 5954612.79 N 551682.51E 1.586 4997.21 6458.06 72.440 165.800 2476.75 2571.65 5082.79 S 1370.55E 5954527.36 N 551705.06E 0.481 5082.79 6550.97 73.670 166.070 2503.83 2598.73 5169.00 S 1392.15E 5954441.30 N 551727.23E 1.353 5169.00 6643.73 75.670 166.020 2528.35 2623.25 5255.81 S 1413.72E 5954354.63 N 551749.38E 2.157 5255.81 6735.30 75.110 164.990 2551.45 2646.35 5341.60 S 1435.90E 5954268.99 N 551772.14E 1.248 5341.60 6828.46 74.870 162.950 2575.58 2670.48 5428.08 S 1460.75E 5954182.68 N 551797.56E 2.131 5428.08 6922.91 75.290 164.720 2599.90 2694.80 5515.73 S 1486.15E 5954095.20 N 551823.55E 1.865 5515.73 7015.00 75.240 164.940 2623.32 2718.22 5601.69 S 1509.46E 5954009.40 N 551847.43E 0.237 5601.69 7108.18 74.330 164.610 2647.77 2742.67 5688.44 S 1533.07E 5953922.81 N 551871.62E 1.035 5688.44 7201.24 74.780 164.250 2672.56 2767.46 5774.85 S 1557.15E 5953836.56 N 551896.28E 0.611 5774.85 7293.60 74.300 162.360 2697.18 2792.08 5860.11 S 1582.72E 5953751.47 N 551922.42E 2.040 5860.11 7385.80 74.200 164.170 2722.21 2817.11 5945.09 S 1608.27E 5953666.67 N 551948.54E 1.893 5945.09 7478.58 74.030 163.580 2747.60 2842.50 6030.82 S 1633.05E 5953581.11 N 551973.90E 0.638 6030.82 7571.40 73.880 165.820 2773.26 2868.16 6116.85 S 1656.59E 5953495.24 N 551998.01E 2.325 6116.85 7664.32 73.600 166.710 2799.28 2894.18 6203.50 S 1677.77E 5953408.73 N 552019.77E 0.968 6203.50 7756.76 74.650 168.530 2824.56 2919.46 6290.34 S 1696.83E 5953322.01 N 552039.41E 2.208 6290.34 7850.68 73.950 169.640 2849.98 2944.88 6379.12 S 1713.95E 5953233.35 N 552057.12E 1.360 6379.12 7943.61 74.990 167.020 2874.86 2969.76 6466.80 S 1732.06E 5953145.80 N 552075.82E 2.938 6466.80 8035.59 75.380 168.110 2898.38 2993.28 6553.63 S 1751.21E 5953059.10 N 552095.55E 1.222 6553.63 8128.82 73.470 167.220 2923.42 3018.32 6641.36 S 1770.39E 5952971.50 N 552115.32E 2.246 6641.36 8221.72 72.360 166.810 2950.71 3045.61 6727.89 S 1790.34E 5952885.11 N 552135.85E 1.267 6727.89 8314.44 70.560 167.380 2980.19 3075.09 6813.57 S 1809.98E 5952799.56 N 552156.06E 2.027 6813.57 8407.54 73.240 168.560 3009.11 3104.01 6900.11 S 1828.41E 5952713.14 N 552175.07E 3.120 6900.11 8500.31 73.310 168.180 3035.81 3130.71 6987.14 S 1846.32E 5952626.24 N 552193.56E 0.399 6987.14 8593.22 74.360 168.680 3061.68 3156.58 7074.56 S 1864.22E 5952538.94 N 552212.04E 1.243 7074.56 8687.04 76.310 170.960 3085.43 3180.33 7163.88 S 1880.25E 5952449.72 N 552228.67E 3.138 7163.88 8779.85 75.470 170.000 3108.06 3202.96 7252.65 S 1895.13E 5952361.06 N 552244.15E 1.351 7252.65 8872.85 75.470 171.400 3131.39 3226.29 7341.49 S 1909.68E 5952272.32 N 552259.29E 1.457 7341.49 8965.91 76.250 172.150 3154.12 3249.02 7430.80 S 1922.59E 5952183.09 N 552272.80E 1.146 7430.80 9058.78 76.750 175.540 3175.81 3270.71 7520.57 S 1932.27E 5952093.39 N 552283.08E 3.590 7520.57 9151.03 77.160 176.150 3196.63 3291.53 7610.20 S 1938.78E 5952003.81 N 552290.19E 0.783 7610.20 9244.16 77.660 175.320 3216.93 3311.83 7700.84 S 1945.54E 5951913.21 N 552297.56E 1.022 7700.84 9337.18 78.160 178.010 3236.42 3331.32 7791.64 S 1950.83E 5951822.46 N 552303.45E 2.878 7791.64 9430.07 78.060 178.130 3255.56 3350.46 7882.48 S 1953.89E 5951731.64 N 552307.12E 0.166 7882.48 9522.37 78.430 179.510 3274.36 3369.26 7972.82 S 1955.75E 5951641.31 N 552309.59E 1.518 7972.82 • • 1 September, 2005 - 15:24 Page 4 of 6 DrfflQuest 3,03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117P81 Your Ref: API 500292325170 Job No. AK-ZZ-3775114, Surveyed: 6 July, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordi nates Global Coo rdinates Dogleg Verti cal Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9615.61 80.250 181.310 3291.61 3386.51 8064.44 S 1955.09E 5951549.68 N 552309.54E 2.722 8064 .44 9706.91 81.490 180.680 3306.10 3401.00 8154.57 S 1953.53E 5951459.55 N 552308.58E 1.519 8154 .57 9799.45 82.420 180.810 3319.05 3413.95 8246.19 S 1952.33E 5951367.92 N 552308.00E 1.015 8246. 19 9892.59 83.410 181.030 3330.53 3425.43 8338.61 S 1950.85E 5951275.50 N 552307.14E 1.088 8338 .61 9985.75 82.940 181.470 3341.61 3436.51 8431.08 S 1948.83E 5951183.01 N 552305.74E 0.689 8431 .08 10078.66 82.600 182.540 3353.30 3448.20 8523.20 S 1945.61E 5951090.88 N 552303.13E 1.200 8523 .20 10170.58 82.550 182.240 3365.18 3460.08 8614.27 S 1941.81E 5950999.78 N 552299.94E 0.328 8614 .27 10263.51 82.680 181.530 3377.12 3472.02 8706.38 S 1938.78E 5950907.66 N 552297.52E 0.770 8706 .38 10358.50 83.480 181.430 3388.57 3483.47 8800.64 S 1936.34E 5950813.38 N 552295.72E .0.849 8800 .64 10449.48 82.050 181.860 3400.02 3494.92 8890.86 S 1933.75E 5950723.15 N 552293.73E 1.640 8890 .86 10542.09 83.650 180.710 3411.55 3506.45 8982.72 S 1931.69E 5950631.27 N 552292.29E 2.122 8982 .72 10674.20 88.030 180.790 3421.13 3516.03 9114.44 S 1929.97E 5950499.54 N 552291.45E 3.316 9114 .44 10771.25 90.860 182.380 3422.07 3516.97 9211.43 S 1927.28E 5950402.53 N 552289.41E 3.345 9211 .43 10868.11 93.830 181.400 3418.11 3513.01 9308.15 S 1924.09E 5950305.80 N 552286.87E 3.229 9308 .15 10965.55 93.690 179.620 3411.72 3506.62 9405.37 S 1923.22E 5950208.57 N 552286.65E 1.828 9405 .37 11059.57 94.380 176.640 3405.10 3500.00 9499.10 S 1926.28E 5950114.87 N 552290.34E 3.246 9499 .10 11158.73 92.320 174.910 3399.31 3494.21 9597.81 S 1933.58E 5950016.21 N 552298.29E 2.711 9597 .81 11253.16 88.760 175.880 3398.42 3493.32 9691.91 S 1941.16E 5949922.16 N 552306.50E 3.907 9691 .91 11348.78 87.510 175.990 3401.53 3496.43 9787.24 S 1947.93E 5949826.88 N 552313.91E 1.312 9787 .24 11444.45 87.770 177.180 3405.47 3500.37 9882.66 S 1953.63E 5949731.50 N 552320.25E 1.272 9882 .66 11536.88 87.580 178.200 3409.22 3504.12 9974.94 S 1957.35E 5949639.25 N 552324.59E 1.122 9974 .94 11593.00 87.580 178.200 3411.59 3506.49 10030.98 S 1959.11E 5949583.22 N 552326.72E 0.000 10030 .98 Projected Survey All data is in Feet (US Survey) unless otherwise state d. Directions and coordinates are relative to True North. Vertical depths are relativ e to Well. N orthings and Eastings are re lative to Well. i Global North ings and Eas tings are rel ative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees pe r 100 feet (US Survey). Vertical Sect ion is from Well and calc ulated along an Azimuth of 180.000° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 11593.OOft., The Bottom Hole Displacement is 10220.50ft., in the Direction of 1 68.949° (True). ~i • 1 September, 2005 - 15:24 Page 5 of 6 DriJJL?uest 3.03.06.00& f Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117P81 Your Ref.• API 500292325170 Job No. AK-ZZ-3775114, Surveyed: 6 July, 2005 Western North Slope Comments Measured Station Coordinates Depth TVD Northings Eastings Comment {ft) {ft) (ft) (ft) 11593.00 3506.49 10030.98 S 1959.11E Projected Survey ConocoPhillips • Survev tool grogram for 1 E-117PB 1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 534.60 533.84 CB-SS-Gyro 534.60 533.84 11593.00 3506.49 MWD+IIFR+MS+SAG 1 September, 2005 - 15:24 Page 6 of 6 DrillQuest 3.03.06.008 • 23-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-117 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,771.25' MD Window /Kickoff Survey: 10,850.00' MD (if applicable) Projected Survey: 15,774.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchoragrre, AK 99518 Date~h ~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a ~ ~ -o~ ~ • 23-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-117 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the `.PTT and *.PDF files. Tie-on Survey: 0.00' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,593.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~, )'- V date o~ TC Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~(~~ -v~6 • • ~'~~ ~ A ~ '°~ ~ ,~ FRANK H. MURKOWSK/, GOVERNOR ~~ O~ ~ ~T~-7 333 W. 7T" AVENUE, SUITE 100 COI~TSI'~iRQA'1`IO1Q COl-IIKI5SI011T ,~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, lnc. P.O. Box 100360 Anchorage, AK 99519 Re: 1E-117 Sundry Number: 305-323 Dear Mr. Dethlefs: 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. Please provide at least twenty-four (24) hours 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, .... r J' ~ 1~ '' .,r s i, Daniel T. Seamount Chairman DATED this ~f day of October, 2005 Encl. 10/21/2005 13:05 9076597 NSK WELLS GROU ~ ~}`l.~ STATE OF AIASfCA ~~~ ~iaska Qi! ~ Gas Cans. ~ammsst Air' SKA QIL AND GAS GQNSERVATI+DN t;QMMISSION S' APPLII ~ATI~N ~C~R SUNDRY APPROVAL A"ch~rage 20 AAC 25.280 7, Type of Request: AbAndon ^ : uspt;nd © QperatlOnal Shutdown ^ Perforate LJ Wdiver ^ Other ^ AItBr Casing ^ Rai air wCll ^ Plug Perforations ^ Stimulate ^ Time Ext6A9i0n Change approved program ^ r'ul 7ubing ^ Perforate New Roal ^ Re.enler Suspended Well ^ 2. Operator Name: 4. Current Well Class; 5, permi# t0 Orill N}tmber: GonocoPYtillips Alaska, Inc. Develgpment ^ Exploratory ^ 205-026 ,~ 3. Address: stratigraphic ^ Senrlce 0 6. API Number: P. (7. Box 100360, Anchors a, Alaska 9951) 50-029-23251-00 7. KB Elevation {ft); 9. Well Name and Number: RKB 95' 1 E-117 13. Property Designation: 10, Field/Pool(s): Kuparuk River Unlt Kuparuk River Field 1 Wes# Sak Oil Pool 91. ~ PRESENT WELL GONDITION SUMMARY 'Total depth MD (ft): Total depth TUD {k): ~fleal re Depth taro (fk); EfFective Depth TVD (ft}: Plugs {measured): Junk (measured): 15774' 3415' 15751 3625 Gaslnst Lentath S{ze N!D TVD Burst Collapse GONDUCTOI~ 10$' 20" 70$' 108 SURFAt;E 5448' 13-318" 5543' 2364 fNTERMEDIATE 1o47T 9.5/S" 10572' 3510 ~ING A-SAND SLO 5369' 5-112" 15751' 3415 PerForakion Depth MD (Ry: PorF~: ~aliort Depth TVD (ft): Tubing Size: Tubing Cyrade: Tubing MD (fty: A: 90382-15751' slotks'd, L1:9I87-15675' slotted, La: 9482-15661' slotted A: 3d 36-3415', f*7 ; 341 ~-347 6', L2: 33fi 7 -349 6' 4-912" L-80 9590' Packers and SSSV Type: PSCkerg and SSSV MD (ft) no packer no SSSV no SSSV 12. Rttachments: Description Summary of Propo,; rl 0 13, Weil Grass after proposed work: Temporary Detailed Operations Program ^ BQP 3ke#Ch ^ Exploratory ^ Developmaitk ^r, Service ^ 14. Estimated Dat® for 15. Well Status after proposed work: Commencing Op®ratlons: Oe obcr 25, 2005 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Dake: WAG ^ GINJ ^ W1NJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing Is true and cu rect to the best of my knowledge, Gentact; i-luntlNezatieky 659-7061 Printed Name Jerry Dethle Title: Problem Well Supervisor Signature ~~~I ' Phone 659-7043 Date ~/ ~/~~-' Commission Ust2 only _ I Conditions of approval: Notify Commission so th; t a representative may witness Plug Integrity ^ BOP Test ^ M`ecl-~ ~nical integrity Test ^ Other: i~o ~ ,~ CUV~ "~~ P-~C~~'~TO C~ Subsequent Form Required; day ~~~ ~~~~L~-`~© ~C~~-- Form 10-403 Revised 7/2005 ,~ R f G I N A L Location Glearance ^ Number: QMS BFI acS ~ ~ ~oo~ APPRQVED BY THE COMMISSION ate• a( Submit ifr Duplicate S 10/ 21 / 2005 13: 05 9076597 hJSK WELLS GROU~ PAGE 03 ConocoPl*allxps A.l~sha, l<nc. West Sak Well 1.E-i17 (P'Tb 2USU26Q) SUNI )1t,Y' NO"CTCE 10-403 VARIANCE REQUEST larzlras Th.e purpose ofthis Sundry Votice is for approval. to temporarily pre-produce West Sak injector 1. E-117. The temporary pro< <uction period is not to exceed 45 days froxr~ th.e tune it is placed in service, q"he well .is new any .has not been. in previous service. 1~.-117 is a high-angle inje~, tia.n well with a shallow gasliR mandrel at 1$76' Mp and a sliding sleeve at 9248' MD. Deepe gasli.ft mandrels were not run due to the ixiabil.ity to operate Slickline tools at the high, ai ~gle_ The shallow gasli.ft mandrel will not provide enough lift for production, so tb.e open si.icl n~ sleeve will be used for .lift gas entry. With the sliding sleeve open there will be lrnown tubing :Inner Annulus com.trtunication during the production periad. A variance from. 20 AAC 25.:i ~a PRODUCTIf3N EQ1J.T.)'.M~.NT {d) is requested for tlYe limited praductfo~n periad. Th.e following is a su.mmar'; of the proposed plan: 1. Sundry 1a-403 approval : equ.est far gasl.i.ft production. not to exceed 45 days with known "C x IA commu.nica.tion (open: sliding sleeve to be used far gaslift); 2_ Perform. CNIIT T x IA or MITIA against a plug to dcn~onstrate the production casing and packer have m.echani.cal ntegrity; 3..Produce well, not to excE, ~d 45 days; 4. Close sliding sleeve with. cai.l tubing unit and ,perform MiTIA prior to injection,; ~. Place well on injection s~: rVice; G. Perform State witnessed ~ /I.ITIA shortly after injection..is initiated. and submit test results to the AQGCC. A~11;er the temporary produc~ ion. status the well will be classified as a Service well. Attached is a wellbare schematic from the : WeII Plan (actual deptY~s nnay be different}, Ltsulated Cmtd~cmr f3 aig, cal', 94i, RSi x +~ AV ~.. ~. 13a.+s•, 611, L-aq a~~, x3 ~~'1-4,537' 7L1g13,~75 TVFI -~ ~~Ja~sm ]hale m ie' ~,' ar w e~e~• ~ ~ F: o ~ ~. ti 7 A A s Baer, with seal6ace sed 2Xp p:rJ~a shave. J E,v] 7S YOr' Q~T.hl.tFD U K~d~~ OBS7RUC71ON~~ ~ - 9,592' Lacers! Ennyaia?u7a ~! (ILFiIE}, Hakes. aihsml Sane ~d Z7~' paelxr aCarntx L2'1) 3andSYiadax 75 &~s 8.8 P?G ®R1NE 1=~i4M TUBING TA]L Td SURFACE- TFfE REST pF THE MOTHER SORE AiVD LATERAi.S COPJ7AIN 9,0 PFG SOLIDS FREE OIL EASED MUD °LY' Liner, SlJ2',15.5:1, L®0. 13TCN, B3 Yatloticdaad'hb]~$ (0.723'x25'sbb, 3Z pra fact. S.~P,'o open area) ' _ aB'Liaer,5-Ill', IS.3d,Z80,1~fG11,R3 /~-'h slatted and YiblaalS (0.125' a 25' ~ / 33 pu food i-4Ya optq aces) Tu6inS, !.};' IDZbi, from L.Fd{ =A X12 Liner, with ;eil stem encl C 1.~C0 3.36Y °i>Bn cripple. Srml Kara and ZRP packer :ar1c2 Gaar ~h'-S9r belavr`B' ciiadaw ~? 3, 9-5~8', del L$4 B1~41, R3 CaB ~+{ IO,i7'6 hiD 13,b75' I'VE? ®~ degree 11] ]2-Ud' ha[e 1.3SsndLiaer, S-YS',15.5it,i.80, HC~N, x3 'b domed and K beak, wwrurcmrt,~r emd~w 47; &L'Z' Dssod`aperil TD li,SSYhfs?l3,399'iW zr 8-V2' °$° sand laeerai: 'YFS l3r67S bSDJ 3,453' TVA &Itl A3sa3dtabertl 'fD F5,352'b1D13,S25"PVD m N N m m Ul W m r~ ~o m m cn ~n Z m r r "U D m m .p 'fumag3leing d-7/1',tZ6*,L~1B1li +1!_5'TUB[NGWRH BENT JOINT AN©SIr4LS ON E~IO sET z~ AsavE UNIWOWN OSSTRUG71dN ~ ._ 9.59fl' L2°fY SzzF d Winbaw ~ 4,}91' - 4,407' 7i degrres . • ''-- C: ~A ~ 1 '~ ~ ~ $ ~ I '1 ~ ~ ~~ ~ ~ ~ J ~~ 1 ~~~ ~ ~ 3 ~ ~ { , ALAS OII, A1QI) G.~S CO1~TSkRQATIOI~T COl~'II-'IISSIOI~T Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: KRU West Sak 1E-117 Sundry Number: 305-280 Dear Mr. Thomas: FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE f00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 a~~~ 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. Please provide at least twenty-four (24) hours 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, ~~-~~1i17~- , John K. Norman Chairman DATED this~Sday of September, 2005 Encl. r ~ " - Randy Thomas GKA Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 ConocoPh i I I i ps Phone: 907-285-6830 September 20, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1 E-117, 1 E-117L1, 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-117, 1 E-117L1 and 1 E-117L2. We are planning to re- enter this well, clean out an obstruction, and run tubing. These wells have been permitted as injectors but we are planning to pre-produce them. We are requesting these sundries to be approved by Friday September 23, 2005. We apologize for the short notice. If this is a problem, please let us know. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, '~ t R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ APPLICATION FOR SUNDRY APPROVAL - - 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other 0 Alter casing ^ Re air well ^ Plu Pertorations ^ p g Stimulate ^ pre-produced ^ Time Extension injector Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ (. -2., 3. Address: Stratigraphic ^ Service O 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', 107' AMSL 1 E-117 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25651 / ALK 470 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ff): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15774' 3415' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 108' 108' SURFACE 5504' 13-3/8" 5544' 2364' INTERMEDIATE Production 10532' 9-5/8" 10572' 3510' Liner 6160' 5.5" 15752' 3415' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 4.5" L-80 9590' Packers and SSSV Type: Packers and SSSV MD (ft) HRD 2.XP Liner pkr @ 10382' no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: pre-produced injector Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 23, 2005 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ~ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 17. f hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitz @ 263-4021 Printed Name Randv Thomas Title: GKA Drilling Team Leader Signature ~ Phone 2.bS6`~3c7 Date ql Z4/d S Commission Use Onl Sundry Number: ~ ~ _^,x r Conditions of approval: Notify Commission so that a representative may witness G "' JZc.~( ) Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~~~0~~ ` ~~'S"a"`\~ ~1,9`\'C tZ'~"l~~~ S 0. \ \~ ~ 4 ~ ~~t ~d~ ~C ~:5~ ~ ~~~. Subsequent Form Required: ~~ ~, SEP ~ ~. 2005 ~ APPROVED BY G~ '~5 / ~~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 7/2005 ~~ ~ ~ ~ ~ 4~ i~ L.. Submit in Duplicate ~~ Rig Workover Procedure Well 1 E-117 West Sak Injector Remove Obstruction and Complete Well Well History and Rig Workover Objectives: 1 E-117 was drilled and completed as a tri-lateral injector in the West Sak A2, B, and D sands by Doyon 141. Doyon 141 spudded the well June 21, 2005. 9-5/8" production casing was set and the two bottom laterals were drilled and slotted 5-1/2" liners run. After drilling the upper "D" sand lateral, running the 5- 1/2' liner, and installing the Baker Model B Hook Hanger junction at 9386', an attempt was made to install the "D" sand Lateral Entry Module (LEM) Assembly. The seal assembly would not pass through the hook hanger into the main wellbore, but instead went out into the "D" lateral, A second attempt was made to set the LEM, this time the seals were successfully oriented through the hook hanger into the main bore, however, the assembly set down at 9589' MD, approximately 78' above the top of the "B" lateral ZXP seal bore at 9667'. Attempts to rotate and work the seals down further were unsuccessful. A subsequent attempt to make a dummy run with a set of seals, junk basket and bent joint again tagged at 9589' MD and the seals were worked down 3' to 9592'. The assembly then pulled tight from 9592' to 9385' (to the top of the hook hanger) with 1 piece of brass and a few pieces of cement recovered form the junk basket when the assembly was pulled. A fourth run with a clean out assembly was unsuccessful in getting through the hook hanger into the main bore, at which time the decision was made to RDMO Doyon 141 and complete the well with Nabors 3S. The well was changed over from 9.0 ppg solids-free OBM to 8.9 ppg NaCI brine at 9380' MD and the clean out assembly was pulled, recovering 2 small pieces of metal and approximately'/2 cup of cement. A 4-112" tubing/kill string with a bent joint on bottom was then run and was rotated through the "D" lateral hook hanger and landed at 9590' MD (2' above the final depth of the obstruction at 9592' MD). The 5K tree was nippled up and tested and Doyon 141 was released on August 13, 2005. The objectives of the rig Workover are as follows: ^ POOH with kill string. Install a Mainbore Diverter in the "D" lateral Hook Hanger with a memory MWD tool in the setting string to confirm the actual orientation of the "D" lateral Hook Hanger (the window was milled between 12 and 19 deg left of high-side) ^ If the Mainbore Diverter cannot be installed, try to install the LEM without the lower seal assembly to help orient the Hook Hanger if it is slightly out of line ^ Attempt to re-install the Mainbore Diverter after running the LEM to provide easier access to the main bore and the obstructioh at 9592' MD. ^ Clean out the obstruction at 9592' down to the bottom of the "B" lateral ZXP seal bore at 9687' MD using the 3-1/2" work string and clean out assembly. ^ Run the "D" lateral LEM assembly and ZXP packer. If the LEM cannot be installed, run a 9-518" Premier packer on the workstring and set approximately 85' above the "D" lateral Hook Hanger. Test packer and casing to 2500 psi. ^ Run the 4-1/2" injection tubing and completion equipment and sting into the ZXP or Premier packer. Nipple up the tree. Page 3 9/20/2005 DRAFT Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchoragae, Alaska 99510 Re: Kuparuk 1 E-117 Sundry Number: 305-232 Dear Mr. Thomas: 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. Please provide at least twenty-four (24) hours 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 decisio o Superior Court unless rehearing has been requested. ~- Sir} r ly John ~K. Norman DATED thisl~ day of August, 2005 Encl. ConocoPhillips August 15, 2005 . Randy Thomas GKA Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner ~~~~ ~ ~ ZQ05 State of Alaska ~~~~~° <x :y€~a ~"ly». Corromi~sia~ Alaska Oil & Gas Conservation Commission ~~~~~~~~~ 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1 E-117, 1 E-117L1, 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-117, 1 E-117L1 and 1 E-117L2. We are planning to shutdown temporarily operations on this well. Please see the attached diagram. There is an unknown obstruction in the mother bore between the top and middle laterals. Our plan forward is as follows: 1. Run video log (non-rig) to obstruction. 2. Evaluate log for rig 3S intervention. 3. MIRU 3S 4. Perform second video log to determine condition of top (D Lateral) liner hanger. 5. Evaluate second video log to determine final completion plan. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~--.. s R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad ~ g~~~-o STATE OF ALASKA ~ Is A~~' ~, ~ ZQ~~ ~ ? ~d'1 ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPR~VAL~i~~~~ ~'~ `''~ "~"``'' ~°~~'~~~~ 20 AAC 25.280 ~iiG~ i0a ~£.' 1. Type of Request: Abandon ^ Sus end ~ p ^ Operational shutdown ^ ^ Perforate ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ 11~~II Re-enter Suspended WeIU 2. Operator Name: 4. Current Well Class: 5. Permit to Drilt Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ ~` V 3. Address: Stratigraphic ^ Service Q 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-00 7. KB Elevation (ft): 9. Well Name and Number: 40' RKB, 107' AMSL 1 E-117 8. Property Designation: 10. Field/Pools(s): ADL 25660, 25651 / ALK 470 Ku aruk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 15774' 3415' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 5504' 13-318" 5544' 2364' intermediate Production 10532' 9-5l8" 10572' 3510' Liner 6160' 5.5" 15752' 3415' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): HRD ZXP Liner pkr pkr @ 10382' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/15/2005 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact pat Reilly Cad 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ t Phone 265-6830 Date ~//S/oj COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: v-~D. ~ c3-3~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance , , ^ 3 s~' 3 ~as1 ~~~~ N..v~-ti. Other: ~ ~jM. ~t,P 'l0 n. C~ O ~ ~E.VCl.~~3G~E ~ EO ~k ~ Q~"~S ~~ rC>,~ h S AFL auG ~ / 2005 Subseq mR ~, O'h~..OM, ~~,T~b'n. P APPROVED BY Ap roved b : s l ~1~~ ~ THE COMMISSION Date: ,b Form 10-403 Revised 11!2004 SUBMIT IN DUPLICATE n 0 Q Insulated Conductor Casing. 20". 94tl. K55 a 34". 9.312" WT ~a "'Q +/- 80' MD D m ~. N d Vf 133/8". 68k. L-80, BTC. R3 n +/- 4637' MD / 2474' rvD -~ a~ 69 degrees TD 16" hole r ~' Ti ~ ~ r. Sri A w ;~• ~ n n ~. S o ~ A is .- y r .. A ~' m J ?; f` S~`- ~~~i ' ~ ~ S ~~n~ <~~~. Wiz. . Baker, with seal bore and ZXP packer above. i r~+istit;i l1sr~~i i!n UNKNOWN OBSTRUCTION @ - 9, 592' Lateral Entcv Modtde qI (LEMI. Acker. with seal bore and ZXP packer atwt~e. 8.9 PPG BRINE FROM TUBING TAIL TO SURFACE- THE REST OF THE MOTHER BORE AND LATERALS CONTAIN 9.0 PPG SOLIDS FREE OIL BASED MUD "D"Liner, 5-1/2", 15,5p, L80, BTCM. R3 slotted and % blank, (0.125" s 2. g' slots, 32 per foot. 5.9 % open area) L2 "D" Sand Window - rn~ 9.706' - 9.727 75 degrees "B"Liner. 5-1/T'. 1 S,SN. L80. BTCM, R3 slotted and'/ blank. ((1125" x 25" slots. 32 per foot. 5.9% open area) Tubing. 4-%" IBTM. from LEM to A2 Liner, tt~idt seal stern and CAMCO 3.56T °DB" nipple. Seal bore and ZXP packer for A2 liner +/- 9(1' below °B" s~indota 9-5/8", 4Uq, L-80. BTCM. R3 Csg rLT. +l- 10.572' MD / 3.675' TVD n 80 degrees TD 12-1 /4" hole Tubing String: 4-1 /2". 12.6 H, L-80. IBTM 4.5"TUBING WITH BENT JOINT AND SEALS ON END SET 2' ABOVE UNKNOWN OBSTRUCTION I @ '- 9, 590' L: "D" Sand Window ?T 9.39I' - 9.407 75 degrees A2 Sand Liner, t-%", 15,SN. L80. BTCM. R3 '/: slotted and '/• blank. constrictors jor isolation L2: 8-1/T' D sand lateral TD 15,662' MD / 3.399' TVD Ll: 8-I/T "B" sand lateral TD 15.675' MD / 3.453' TVD 3-1/2 A: sand lateral TD 15'52' MD / 3,625' TVD Re: FW: 1E-117 Plan Forward -CHANGE • Subject: Re: FW: 1E-117 Plan Forward -CHANGE ~~ ~Q~'.. ~~--~ From: Thomas Maunder <tom maunder@admin.state.ak.us> ~ ~ ~~ Date: Fri, 12 Aug 2005 11:07:19 -0800 To: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> ~ ~ ~a` Pat, The total information here is a little sketchy, however based on the conversations with you and Steve yesterday I understand that there is some mechanical obstruction that is preventing the completion tubing from being run as planned. You all have determined to halt operations and set the well up so further evaluation can be done. You plan to run a tubing string deep in the well to facilitate the evaluations which will also provide a kill string for well control/circulating. After the work plan is determined, the 3S workover rig will move on the well to effect repairs. What you are planning is an "Operational SD" and a sundry will need to be filed. By copy of this email, you plan is acceptable. Please call or message with any questions. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 8/12/2005 10:43 AM: Tom, Thanks for discussing 1 E-117 this morning. Please see the plan forward below. Sharon is out today. As per our conversation, we will prepare the sundry on Monday. Pat Reilly ConocoPhillips Alaska Drilling. & Wells (907} 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J, Reily@canocophillips.com «Patrick.J.Reilly{~conocophiilips.com.vcf» -----Original Message----- From: Reilly, Patrick J Sent: Friday, August 12, 2005 10:34 AM To: Doyon 141 Company Man; Lowe, Dan E Cc: Thomas, Randy L; Spenceley, Neil; Gober, Howard; Davis, Eric R.; Peterson, Erick Martin; Paul, Jerome; McKeever, Steve; Greener, Mike R. Subject: 1E-117 Plan Forward -CHANGE Mike, We worked out a plan to get a video log on the obstruction before 3S moves in, When you leave, the Wells group will run a fiber optic video log down to the obstruction. Howard will have time to evaluate the video fog and plan the 3S intervention. When 3S moves in, the rig will pick up the tubing to the hook hanger depth and get a second video 1 of 3 8116/2005 10:20 AM Re: FW: 1E-117 Plan Forward -CHANGE log ~fi the hook hanger. • 1. Continue POOH laying down DP. 2. Remove the burrs from the bottom of the seal assembly on the bent joint. 3. Run 4.5" IBT tubing (with bent joint and seal assembly on bottom) to just above the obstruction in the mother bore. 4. Space out tubing such that the seal assembly is at least 1-2' above the obstruction but not much higher than that. That should allow Wells to get a good video. 5. Land hanger. Howard is arranging the video log with Mark Chaney. Mark can help at the rig site if you need more information on the space out. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reillyconocophillips.com «Patrick.J.Reilly(a?conocophillips.com.vcf» -----Original Message----- From: Rei11y, Patrick J Sent: Thursday, August 11, 2005 5:26 PM To: Doyon 141 Company Man; Lowe, Dan E Cc: Thomas, Randy L; Spencefey, Neil; Gober, Howard; Davis, Eric R.; Peterson, Erick Martin Subject: 1E-117 Plan Forward Mike, I consulted with Howard Gober and Hal Martens. We came up with the following plan forward after you complete your junk basket run. 6. Displace to 8.9 ppg brine. (Hal is sending the recipe to his mud man on the rig) 7. POOH laying down DP. 8. Run 2,500' of 4.5 IBT tubing as a freeze protect string. (This might change to 3.5" PH6 if the torque required for the workover rig is low enough for PH6). Dan Lowe is running some TAD calculations for Howard. 9. Land hanger. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.ReiRy{o~conocophillips.com 2 of 3 8/16/2005 10:20 AM ~ • • ~ ,~ ~ ~ ~ ~ FRANK H. MURKOWSKi, GOVERNOR ;~ ~ A~IL1-7~ OI~ ~ ~ ' 333 W. 7"' AVENUE, SUITE 100 COI~TSER'QATI011T COMAII5SIOl~t ANCHORAGE, ALASKA 99501-3539 r' PHONE (907) 279-1433 ` FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 1 E-117 ConocoPhillips Alaska, Inc. Permit No: 205-026 Surface Location: 11' FSL, 228' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 1642' FSL, 3540' FEL, SEC. 34, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commissio witness any required test. Contact the Commission's petroleum field inspector at (947) 6 -36 (pager). K. l~Iorman DATED thisa$ day of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips r Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com February 16, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1E-117, 1E-117L1 and 1E-117L2 Dear Commissioners: ~ / ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well, a multilateral horizontal well in the West Sak ~~A", "B" and °D" sands. The main bore of the well will be designated 1E- 117, and the lateral bore of the well will be designated 1E-117L1 t^~B" Sand) and 1E-117L2("D" Sand) Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-117 is 4/12/2005. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, ~~. -___ Randy Thomas Greater Kuparuk Area Drilling Team Leader k.~~ ~ ~ ~ 3 -~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~ ` ~~ 20 AAC 25.005 ~~`1 ta. Type of Work: Drill O Redrill ^ 1b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ^/ Development Gas ^ Single Zone ^/ 2. Operator Name: 5. Bond: Blanket ^ Single Well ^ 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 E-117 ~ 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15752' ~ TVD: 3411' / Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 11' FSL, 228' FEL, Sec. 16, T11N, R10E, UM ~ ~D~ ~~~~~ADL 25660 ,~6 ~`Z~'`~ . `, r West Sak Oil Pool ~ ~+~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 6y ~ 1~z3 1612' FSL, 3538' FEL, Sec. 27, T11N, R10E, UM ALK 470 4!12/2005 Total Depth: 9. Acres in Property: 14. Distance to ~ ~ _,y,« [may, 1642' FSL, 3540' FEL, Sec. 34, T11 N, R10E, UM l 2560 Nearest Property: ~G2~- z- z.3- ~y' 4b. Location of Well (State Base Plane Coordinates): 10. K8 Elevation 15. Distance to Nearest Well i ~ ' Surface: x- 550301 y- 5959601 Zone- 4 (Height above GL): 40' RKB / 107' AMSL Within Pool: ~:,L1.D.-49~F~9' z°2~ 16. Deviated wells: Kickoff depth: 300 ' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5) Maximum Hole Angle: 95 ' deg. Downhole: 1516 psig Surface: 1161 psig 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 Butt 5347' 40' 40' 5387' 2379' 970 sx AS Lite, 260 sx DeepCrete 9-518" 12.25" 40# L-80 BTCM 10455' 40' 40' 10495' 3533' 810 sx DeepCrete 8.5" 5.5" 15.5# L-80 BTCM 6213' 9700' 3422' 15752' 3411' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed 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 TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (tt): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 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 Steve Shultz @ 263-4620 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature -~[-_-~ ""--~~~,~ Phone t.L- ~ ~ -~ 3 ~1 Date Z I 1-~ /a S Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: ~~~~~ --77 fi~•~~r~,~ 50- ~~~"'"L~l'c....U Date: ~~a~Q~ requirements Conditions of approval Samples required Yes ^ No ~ Mud log required Yes ^ No Hydrogen sulfide measures Yes ~ No ^ Directional survey required Yes ~ No ^ Other:3~QSt ~ ~'`~r1~C~vP ~5~~ ~~ ~~~.~f3\~~~~~`~~~~. ` APPROVED BY Approv d b : THE COMMISSION Date: cf For 1 R vised 2004 t ~ ~ ~ ~ ` Su~ it in Duplicate ~~ ttr44~ Application for Permit to Drill, Well 1 E-117 Revision No.O February 16, 2005 Permit- West Sak #1 E-117 Injector ("A" Sand) ~~~~~ a~ ~~1 Application for Permit to Drill Document; I~1~~cW~H M p x i m i x E 14e11 Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10 . Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL 1 E-117 Injector Permit Page 1 of 8 Printed: February 16, 2005 • Appiication for Permit to Drill, Well 1 E-117 Revision No.O February 16, 2005 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic 1. Well Name Requirements of 20 AAC 25.005 (17 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6), for a well with multip/e wel/branches, each branch must Simi/arty be identified by a unique name and API number by adding a suffix to the name designated for the we9 by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as 1E-117. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by earth of the fol%wing items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the wel/ at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state p/one coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surtace FSL 10.5' ,FEL 228', Sec.16, T11N/R10E ASPZone 4 NAD 27 Coordinates RKB Elevation 107' AMSL Northings: 5959600.8 Eastings; 550300 Pad Eievation 67` AMSL Location at Top of Productive Interval West Sak ~~A" Sand FSL 1612', FEL 3538', Sec. 27, R11 NIR10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.• 9700' Northings; 5950656 Eastings: 552349 Total l/ertical De th, RKB.• 3422' Total I/ertica/ De th, SS: 3316' Location at Total Depth FSL 1642` FEL 3540', Sec. 34, T11N1R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB.' 15752' Northings; 5945407 Eastings: 552393 Total 1/ertical De th, RKB: 3411' Total I/ertica/ De th, SS,• 3304` and (D) other information required by ZO AAC 15.050(6),• Requirements of 20 AAC 25.050(6) Ifa well is to be intentionally deviated, the application for a Perr,~it to Drill (Form 10-401) must ORIGINAL .- 1 E-117 Injector Permit Page 2 of 8 Printed: February 16, 2005 Application for Permit to Drill, Well 1 E-117 Revision No.0 February 16, 2005 (1) include a plat, drawn to a suitable scale, showing the pa Fh of the proposed wellbore, inc/uding al/adjacent wellbores within 200 feet of any portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those 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 app/ication 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 app/ication for a Permit to t7ri!/ must be accompanied by each of the following items, except for an item already on fife with the commission and identified in the application: (3) a diagram and description of the blowout prevention equl,~ment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-117. Due to the formation pressures being far less then the rating of the ROPE, CPAI would like to request that the stack be operated under the 3,000 psi BOP guidelines thereby allowing the use of one ram cavity for casing rams and negating an additional BOP test once the intermediate casing has been run. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to ©rill must be accompanied by each of the following items, except far an item already on Fle with the commission and identified in the application: (4) information on drilling hazards, inc/uding (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 1E-117 area vary from 0.0.44 to 0.0.47 ~ psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. 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 A sand formation is 1161 psi, calculated thusly: MPSP =(3225 ft)(0.47 - 0.11 psi/ft) =1161 psi (B) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to ©riD must be accompanied by eaah of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25, 030(17; 1E-117 Injector Permit Page 3 of 8 A ~ Printed: February 16, 2005 • Application for Permit to Drill, Well 1 E-117 Revision No.0 February 16, 2005 The parent wellbore,lE-117, will be completed with 9 5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be pertormed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. ~,,. 6. Casing and Cementing Program Requirements of 20 AAC 25.O05(c)(6) An app/ication for a Permit to Dri!! must be accompanied by each of the following items, except for an item already on fi/e with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be instal/ed; Casing and Cementing Program See also Attachment 3, APD for 1E-117: Cement Summa Hole Top Btm CsglTbg Size Weight Length MD/TVD MD/TVD OD in in Ib/ft Grade Connection ft ft ft Cement Pro ram 20" 40" 94 K55 Welded 80' 40' / 40' 120' / 120' Cemented to surface with 260 cf ArcticCRETE 13 3/8" 16" 68# L-80 Butt 5347' 40'/40' 5387'/2379' Cemented to Surface with 970sx ASLite Lead, 260sx DeepCRETE Tail 12 1/4" 9 5/8" 40# L-80 BTCM 10455` 40'140' 10495'/3533' Cement Top planned @ 6100' MD/' TVD. 810 sx Dee C 5 1/2" 8 1/2" "A" 15.5# L-80 BTCM 6052' 9700'/3422' 15752'(3411' Slotted- no cement slotted Lateral "'~ 8 1 "" - BTCM 6042' 9600'/3408' 42'/3261 o e - e ~Zt'~fi' slotted Lateral 1E-117 L1 5 1!2" 8 1/2""D" 15.5# L-80 BTCM 6289' 9350`j3358` 15639`J3193` Slotted-no cement slotted Lateral 1E-117 L2 4 1/2 NA 12.6# L-80 IBTM 9160' 40'/40' 9200'/3300' Production Tubing tubin 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri/i 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: (7) a diagram and description of the diverter system as required by 20 AAC25.035, unless this requirement is waived by the commission under ZO AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1E-117. Please see diagrams of the Doyon 15 diverter system on file with the Commission. ORIGINAL 1 E-117 Injector Permit Page 4 of 8 Printed: February 16, 2005 Application for Permit to Drill, Well 1 E-117 Revision No.0 February 16, 2005 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Pro erties Surface /ntermediate Production Densit (p) 8.6-9.0 9.0 9.0 Funnel Viscosity (seconds) 150-300 45-60 60 Yield Point (cP) 30-70 26-35 18-28 Electric Stability NA NA 650-900 Chlorides (m A) <500 <500 NA H 8.5-9.0 9.0-9.5 NA API filtrate cc / 30 min) 6-8 4-6 <4 **HTHP filtrate (cc / 30 min) <10 <10 <10 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 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on frle with the commission and identified in the application: (9) for an exploratory or stratigraphic test we/% a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (10) for an exploratory or stratigraphic test we/% a seismic refraction or ret7ection ana/ysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dri!! must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, ar floating drilling vess% an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. ORIGINAL 1E-117 Injector Permit Page 5 of 8 Printed: February 16, 2005 C Application for Permit to Drill, Well 1 E-117 Revision No.O February 16, 2005 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the app/ication: The proposed drilling program for 1E-117 is listed below. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +j-120' RKB. Install landing ring on conductor. 2. Move in J rig up D~ o oyn~. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 5387' MD /2379' T~lD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13 3/8", 68#, L-80, BTC casing to surface. Displace cement with water base mud and, pressure test casing to 3000 psi for 30 minutes and record results. Pertorm top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. 6. PU 12 1/4" bit and 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. $. Directionally drill to 9 5/8" casing point at 10495` MD /3533' TVD. 9. Run 9 5/8", 40# L-80, BTCM Mod casing to surface. Pump cement and displace with oil base mud. 10. Install wellhead 9 5/8" packoff and test to 5000 psi. 11. Flush 13 3/8" x 9 5/8" annulus with water, followed by diesel. 12. PU 8 i/2" Bit and drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes and record results. 13. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 14. Directionally drill 8 i/2" hole to TD at +/-15752' MD /3411' TVD as per directional plan. 15. POOH, back reaming out of lateral to casing point, RIH and change over to solids free OBM, POOH. 16. RU and run the USIT log from the shoe of the 9 5/8' casing to the shoe of the 13 3/8" casing. 17. PU and run 5 1/2" slotte finer. 18. Land liner, set liner hanger POOH. Note: Remaining operations are covered under the 1E-117L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 9629' MD (3408' TVD, the top of the B sand. 20. Mill 8 i/2" window. POOH. ORIGINAL 1 E-117 Injector Permit Page 6 of 8 Printed: February 16, 2005 • Application for Permit to Drill, Well 1 E-117 Revision No.O February 16, 2005 21. Pickup drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 15642' MD /3261' TVD, as per directional plan. 23. POOH, back reaming out of lateral. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4 1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool 28. POOH and prepare for drilling the "B" lateral. Note: Remaining operations are covered under the 1E-117L2 Application for Permit to Drill, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 9350 MD/3358' TVD, the top of the "D" sand. 30. Mill 81/2" window. POOH. 31. Pick up drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of "D" sand lateral at 15639` MD /3193` TVD, as per directional plan. 33. POOH, back reaming out of lateral. POOH. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 5 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. 38. POOH and lay down drill pipe 39. RU and run 4 1/2" injector completion with back up gas lift and a sliding sleeve 40. Space out tubing, stab seals into PBR above upper most lateral and land tubing in tubing head 41. Nipple down BOPE, nipple up tree and test, change over the hole to diesel 42. RDMO Doyon 15 43. Rig up wire line unit. Pull BPV 44. Circulate out well with diesel through sliding sleeve, then close same 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 30 days. 46. Replace gas lift valves with blank dummy valves-~~~`~1 47. Place well on injection v.~cr-\~ si>~~ c3 Sic c~e~~ l~ c~.s t -mac ~ ~ ~}1~~eo~~cr' 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied ay each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: 1 E-> 17 Injector Permit Page 7 of 8 Printed: February 16, 2005 ORIGINAL • Application for Permit to Drill, Well 1 E-117 Revision No.O February 16, 2005 (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC Z5. t~80 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE -- Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 7 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ~~ 1E-1 >7 /njector Permit Page 8 of 8 Printed: February 76, 2005 Injector 1 E-117 KOP:300' \ Build at 3-5 degrees/ 100' ~~ Slimhole Design 16" Hole (8.8 ppg Spud Mud) 13 3!8" Casing 5387' MD 2379' TVD ~~ Note: the interemediate and all laterals are to be drilled with rotary steerable Hydraulics: Surface: 900-1200 gpm Intermediate: 700-900 gpm Laterals: 450-500 gpm Figure on a 50 YP for surface Figure on a 35 YP for intermediate Pore Pressure 1450 psi Figure on a 28 YP for laterals TVDss 3130 ft TVD 3225 ft MWE 8.6 ppg -~ Window C 9352' MD Top of Ugnu ,~'~ "D" Sand (9.0 ppg Oil Base Mud) +/-6600' MD \~-~- 8 /1/2" Hole 5 1/2" Liner J Top of Cement +/-6100' MD 15639' M D 3193' TVD • "B" Sand (9.0 ppg Oil Base Mud) Window C«~ 9635'MD 8 1/2" Hole 5 1I2" Line Tangent Angle: 75 degrees 15642" MD 3261' 'TVD °" j "A-2" Sand (9.0 ppg Oil Base Mud) 81/2" Hole (Undulating) 121/4" Hole (9.0 ppg LSND 5 1/2" Liner 9 5/8" Casing 15752' MD 10,495' M 3411' TVD - ~ 3533' T L80 degrees) I1 L_ J ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-117 1 E-117 Plan: 1 E-117 (wpo~) Proposal Report 09 February, 2005 A Halliburton Company ORIGINAL ~I $ Project; Kuparuk River Unit p Site: Kuparuk 1E Pad {Srts+{ii Well: Plan 1E-117 Wellbore: Plan 1 E-117 Plan: 1 E-117 (wp04) 1 E-117 SHL: 11' FSL 8 228' FEL - Sed 16-T11 N-R 10E ~ KOP :Begin Dir(813.00°/100ft, 300 ft MD, 300 ft TV~ Continue Build ~ 5.00°/100ft , 467 ft MD, 466 ft TVD Build and Tum @5.00°/100ft , 667 ft MD, 663 ft TVD 0 ^~ V ' ~,....- ~y~~ I~ -1800 0 O ~ 1 r ~ _ 3600 Base of Permafrost /.i ~~ ~K15 - - / T3+675- - - - - - Ugnu C -- -- - ~° ~ - Ugnu B _ _ _ - - _ - Ugnu A - - -- `- K13 - - West Sak D \\_ I Continue Build @ 3.00°/100ft , 8782 ft MD, 3233 ft ND West Sak C West Sak B -- ~1 E-117 (wp04) Sail @ 73° Inc 8 160° Azi, 1828 ft MD, 1463 ft TVD Build and Tum X3.00°/100ft , 2228 ft MD, 1580 ft TVD I !Begin Sail ~7bA4° Inc 8166.31° Azi, 2446 ft M0,1640ftTVD ~/ 13 378" Csg Pt -: Drill out 12114" Hole : 5387 ft MD, / Begin Sail ~ 82.00° Inc 8 180.03° Azi, 9635 ft MD, 3413 ft TVD ~- --- - - - - Land in A-Sand @ 92.40°Inc -Begin Undulations , 10731 ft MD, 3542 ft TVD - End Undulations in A-Sand , 15481 ft MD, 3416 ft TVD - - ~~ ~ Ys -~ ---- - - - _ 51/2„ - - - - - -- v. _ - - - ° BHL:15752ftMD,3411ftTVD~ ~ I, 9 5l8" Csg Pt :Drill out 8112" Hole :10495 ft MD, 3533 ft TVD West Sak A4 - - - - - - Be in Sail ~ 78.00° Inc 8 180.03° Azi, 9235 ft MD, 3337 ft TVD ~ _9 - - - - -- - - 6300 West Sak A3 ~ ~ - West Sak A2 I Continue Dir @ 2.00°/100ft , 9435 ft MD, 3379 ft TV~ Contnue Dir @ 4.00°/100(1 , 10471 ft MD, 3530 ft TV~ -1800 -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 9900 10800 11700 12600 13500 14400 15300 Vertical Section at 180.00° (1800 ft/in) i Co~oi'hillips :~~~ti, ~''~^5/-~r1 -4500 -3600 _27p0 1800 West(-)/East(+) (1800 ff/in) ._„ , .~.. -soo o soo ' 900 1800 2700 3600 4500 1E-117 SHL: 11' FSL 8228' FEL - --__ 5400 6300 Sect 16T71N-R10E --- __ - 900 0 -KOP _Begin Dir @ 3 00°/100ft, 300 k MD, 300_ ft TVD ----- Begin Sail @ 73° Inc & 160° -_ _ 0 ------ Azi, 1828 ft MD, 146146 p -- -- -900 CC ue Build @ 5.00°/100ft , Mft764 D, 466 ft TVD Build and Turn 3.00°/100ft , 2228 ft MD, 1580 ft TVD ~ \ -1 Sail @ 75,44° Inc & 166.31 ° Azi, 2446 ft MD, 1640 ft TVD 13 3/8" Csg Pt :Drill out 12114" Hole 5387 ft MD, 2379 ft TVA 'gin Sail @ 78.00° Inc & 180.03° Azi, 9235_ ft MD, 3337 ft TuD -----_ _ _ ~ -- _c o -6300 ao o _7200 i Intersect D-Sand @ 78,Op° Inc, 9335 ft MD, 3358 ft TVD r ~_._._____-- ---- Z ---- -- -- ------ r ~ -8100 --- _ o j Continue Dir @ 2.00^/100ft , 9435 ft MD, 3379 ft TVD ~ ----- - -9000 ~ ~ 9 _ @ -- ~------ Be in Sail 82.00° Inc 8 180.03° Azi, 8635 ft MD, 343413 ft TVD ___~ -9900 i 95!8" Cs9 Ft _ Drill out 81/2^ Nole : 10495 ft MD, 3533 ft TVD -10800 -11700 Land in A-Sand - ---- --- __ @ 92.40°Inc -Begin Undulations , 10731 ft MD, 3542 ft TVD ~ -13soo 51te: Kuparuk 1 E Pad Well: Plan 1E-117 Wellbore: Plan 1E-117 Plan: 1E-117 (wpp4) -14400 5 1/2" Build and Turn @5.00°/100ft , 667 ft MD, 663 ft TVD -1800 ----- Continue Build @ 3.00°/100ft , 8782 ft MD, 3233 ft TVD ~ - -- 1 E-117 (wpp4) Dir @ 4.00°/100ft , 10471 ft MD, 3530 ft TVD N 0 c 6300 S Z 0 '200 0 0 100 ~ 10800 1700 End Undulations in A-Sand , 15481 ft MD, 3416 ft TVD ~-_13500 _ _~-_ _ - - --"" BHL : 15752 ft M 34 ftD 1111 ND i -4500 -3600 -2700 -1800 -900 0 900 1800 2700 3600 4500 5400 6300 West(-)/East(+) (~g00 ft/in) ~~~!NAL A.a~;ka Project: Kuparuk River Unit Site: Kuparuk 1E Pad Well: Plan 1E-117 'ellbore: Plan 1E-117 Vertical Section at 180.00° (1000 ft/in) 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 IG 2625 - _ _ _ Vertical Scale Exaggerated x 4 _ 'Continue Build @ 3.00°/100ft , 8782 ft MD, 3233 ft ND Legin Sail @ 78.00° Inc 8 180.03° Azi, 9235 ft MD, 3337 ft ND 2750 _ _ _ Infect D-Sand @ 78.00° Inc9335 ft MD, 3358 ft N Continue Dir @ 2.00°/100ft , 9435 ft MD, 3379 ft ND ~I 2875 - - ~? - _ ~ / it Begin Sail @ 82.00° Inc & 180.03° Azi, 9635 ft MD, 3413 ft ND] 3125 End Undulations in A-Sand , 15481 ft MD, 3416 ft ND~ o - - - L \ p 3250 _~ / / / \ 5 1/2" ig 1 E-117 T6 (v3) > ~ / 1 E-117 T5 (v3) \ 3375 ~ ~ / 1 E-117 T3 (v3) 1 E-117 T4 (v3) I f- 1 E-117 T2 (v3) - -- 3500 T1(v3) - - - - _ ~F A2-Sand _ _ ,,,,,,~ ~'~ ~ ~BHL : 15752ftMD, 3411 ftND i 3125 m 3250 ~ N 3375 3875 ' 4000 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 Vertical Section at 180.00° (1000 ft/in) [and in A-Sand @ 92.40°Inc -Begin Undulations , 10731 ft MD, 3542 ft ND 9 5/8" Csg Pt • Drill out 8 1/2" Hole : 10495 ft MD, 3533 ft TVD~ Continue Dir @ 4_00°/100ft , 10471 ft MD, 3530 ft / ~ H llib C y rt i 't "t "' Ph ll C a u on ompan ~ ,.5~~ ~ ~ onOCO i ips Planning Report -Geographic Alaska A Haulburtan Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1 E Pad Company: ConocoPhillips Alaska Inc.(Kuparuk) ND Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unlt MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-117 Design: 1 E-117 (wp04) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor fell Plan 1 E-117 Tri -Lateral Injector tell Position +N/-S -162.12 ft Northing: 5,969,600.86 ft Latitude: 70° 18' 01.427" +EI W 409.97 ft Easting: Sb0,300.51 ft Longitude: 149° 35' 33.405" 1 osition Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 66.90 ft Wellbore 1 E-117 Magnetics Model Name bggm2004 f Design 1 E-117 (wp04) Sample Date 12/15/2004 Declination (°) 24.49- - Dip Angle Field Strength iI 80.74 57, 580 Tie On Depth: 40.00 +EI-W Direction (ft) (°) 409.97 180.00 Audit Notes: Version: Vertical Section: Phase: PLAN Depth From (ND) +Nl-S (ft) (ft) 40.00 -162.12 2~J/2005 4:59:27PM Page 2 of 10 COMPASS 2003.11 Build 50 !4 F ~ '@ ,A / ~ y " ' Haliiburton Compan i ~~ r l ~ ~A ConocoPhillips Planning Report -Geographic Alaska A Halllburton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1 E Pad Company: ConocoPhillips Alaska Inc(Kupafuk} ' ND Reference: 66.9 GL + 40RF=1 D6.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk t E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-117 Design: 1 E-117 (wp04) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +EI-W Rate Rate Rate 7FO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°1100ft) (°1100ft) (°) 40.00 0.00 0.00 40.00 -162.12 409.97 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 -162.12 409.97 0.00 0.00 0.00 0.00 466.67 5.00 155.00 466,46 -168.71 413.04 3.00 3.00 0.00 155.00 666.67 15.00 155.00 663.17 -200.14 427.70 5.00 5.00 0.00 0.00 1,827.94 73.00 160.00 1,463.47 -920.89 705.30 5.00 4.99 0.43 5,64 2,227.94 73.00 160.00 1,580.42 -1,280.34 836.13 0.00 0.00 0.00 0.00 2,446.15 75.44 166.31 1,639.82 -1,481.21 896.87 3.00 1.12 2.89 69.00 8,782.03 75.44 166.31 3,232.59 -7,439.49 2,347.87 0.00 0.00 0.00 0.00 9,235.04 78.00 180.03 3,337.11 -7,876.09 2,399.87 3.00 0.57 3.03 80.78 9,335.04 78.00 180.03 3,357.90 -7,973.90 2,399.82 0.00 0.00 0.00 0.00 9,435.04 78.00 180.03 3,378.69 -8,071.72 2,399.77 0.00 0.00 0.00 0.00 9,635.04 82.00 180.03 3,413.41 -8,268.64 2,399.67 2.00 2.00 0.00 360.00 10,470.59 82.00 180.03 3,529.70 -9,096.06 2,399.23 0.00 0.00 0.00 0.00 10,730.64 92.40 179.81 3,542.39 -9,355.45 2,399.60 4.00 4.00 -0.08 -1.22 11,130.64 94.00 179.86 3,520.06 -9,754.81 2,400.74 0.40 0.40 0.01 2.00 11,330.64 94.00 179.86 3,506.11 -9,954.32 2,401.21 0.00 0.00 0.00 0.00 11,730.64 92.00 179.86 3,485.19 -10,353.75 2,402.15 0.50 -0.50 0.00 180.00 12,130.64 88.00 179.86 3,485.19 -10,753.67 2,403.09 1.00 -1.00 0.00 180.00 12,330.64 88.00 179.86 3,492.18 -10,953.55 2,403.56 0.00 0.00 0.00 0.00 12,730.64 90.80 179.86 3,496.37 -11,353.49 2,404.50 0.70 0.70 0.00 0.00 13,130.64 94.60 179.86 3,477.54 -11,752.97 2,405.44 0.95 0.95 0.00 0.00 13,330.64 94.60 179.86 3,461.50 -11,952.32 2,405.91 0.00 0.00 0.00 0.00 13,730.64 92.20 179.86 3,437.79 -12,351.59 2,406.85 0.60 -0.60 0.00 180.00 14,130.64 86.60 179.86 3,441.98 -12,751.41 2,407.80 1.40 -1.40 0.00 180.00 14,230.64 86.60 179.86 3,447.92 -12,851.23 2,408.03 0.00 0.00 0.00 0.00 14,730.64 92.60 179.86 3,451.41 -13,350.99 2,409.21 1.20 1.20 0.00 0.00 14,980.64 93.47 179.86 3,438.17 -13,600.64 2,409.80 0.35 0.35 0.00 0.00 15,080.64 93.47 179.86 3,432.11 -13,700.45 2,410.03 0.00 0.00 0.00 0.00 15,480.64 91.11 180.28 3,416.11 -14,100.10 2,409.52 0.60 -0.59 0.10 170.00 15,751.64 91.11 180.28 3,410.86 -14,371.05 2,408.19 0.00 0.00 0.00 0.00 219/2005 4:59:27PM Page 3 of 10 COMPASS 2003.11 Build 50 Y ~ H llib rt C • "t '7 ' C Ph ll a u on ompan ~ ~ ! -5t..~ Otloco ~ ~ps Planning Report -Geographic Alaska A Halllburlon Company Database: EDM 2003 11 Singie User Db Local Co-ordinate Reference: Site Kuparuk 1 E Pad Company: ConocoPhiNips Alaska Inc.(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk Rlver Unft MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 1 S (66.9GL + 40R Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-117 Design: 1E-117(wp04) Planned Survey 1E-117 (wp04) MD Inclination Azimuth TVD SSTVD +N1-S (ft) (°) (°) !ft) (ftl (ft) 40.00 0.00 0.00 40.00 -66.90 -162.12 1E-117 SHL: 11' FSL 8 228' FEL -Sect 16-T11N-R10E 100.00 0.00 0.00 700.00 -6.90 -162.12 200.00 0.00 0.00 200.00 93.10 -162.12 300.00 0.00 0.00 300.00 193.10 -162.12 KQ#r :Begin Dir ~ 3.00°f1 00ft, 300 ft MD, 300 ft TVD 400.00 3.00 155.00 399.95 293.05 -164.49 466.67 5.00 155.00 466.46 359.56 -168.71 Continue Bu ild ~ 5.00°HOOft, 467 ft MD, 466 ft TVD 500.00 6.67 155.00 499.61 392.71 -171.78 600.00 11.67 155.00 598.31 491.41 -186.21 666.67 15.00 155.00 663.17 556.27 -200.14 Buiid and Tum X6.00°NOOR , 667 R MD, 663 ft TVD 700.00 16.66 155.57 695.23 588.33 -208.40 800.00 21.64 156.77 789.67 682.77 -238.42 900.00 26.63 157.54 880.90 774.00 -276.11 1,000.00 31.63 158.08 968.22 861.32 -321.17 1,100.00 36.62 158.48 1,050.98 944.08 -373.28 1,200.00 41.62 158.81 1,128.53 1,021.63 -432.03 1,300.00 46.61 159.07 1,200.30 1,093.40 -496.97 1,400.00 51.61 159.29 1, 265.74 1,158.84 -567.61 1,500.00 56.61 159.49 1,324.34 1,217.44 -643.42 1,600.00 61.61 159.66 1,375.67 1,268.77 -723.81 1,700.00 66.61 159.82 1,419.32 1,312.42 -808.18 1,800.00 71.60 159.96 1,454.98 1,348.08 -895.88 1,827.94 73.00 160.00 1,463.47 1,356.57 -920.89 Begin Sail ~ 73° Inc & 160° Azi,1828 ft MD, 1463 ft TVD 1,900.00 73.00 160.00 1,484.54 1,377.64 -985,64 2,000.00 73.00 160.00 1,513.78 1,406.88 -1,075.51 2,051.72 73.00 160.00 1,528.90 1,422.00 -1,121.98 Base of Permafrost 2,100.00 73.00 160.00 1,543.02 1,436.12 -1,165.37 2,200.00 73.00 160.00 1,572.25 1,465.35 -1,255.23 2,227.94 73.00 160.00 1,580.42 1,473.52 -1,280.34 Build and Tum X3.00°HOOft , 222811 MD,1580 R TVD 2,300.00 73.79 162.10 1,601.02 1,494.12 -1,345.65 2,400.00 74.91 164.99 1,628.01 1,521.11 -1,437.99 2,446.15 75.44 166.31 1,639.82 1,532.92 -1,481.21 Begin Sail ~ 76.44° Inc 8 166.31° Azi, 2446 ft MD,1640 ft TVD 2,500.00 75.44 166.31 1,653.35 1,546.45 -1,531.85 2,600.00 75.44 166.31 1,678.49 1,571.59 -1,625.89 2,700.00 75.44 166.31 1,703.63 1,596.73 -1,719.93 2,800.00 75.44 166.31 1,728.77 1,621.87 -1,813.97 2,876.10 75.44 166.31 1,747.90 1,641.00 -1,885.54 T3 2,900.00 75.44 166.31 1,753.91 1,647.01 -1,908.01 ~ I Map Map +EI-W Northing Easting DLSEV Vert Section (fty tft) (ft) (°/100ft) fit) 409.97 5,959,600.86 550,300.51 0.00 0.00 409.97 5,959,600.86 550,300.51 0.00 0.00 409.97 5,959,600.86 550,300.51 0.00 0.00 409.97 5,959,600.86 550,300.51 0.00 0.00 411.08 5,959,598.50 550,301.63 3.00 2.37 413.04 5,959,594.29 550,303.62 3.00 6.59 414.48 5,959,591.23 550,305.08 5.00 9.66 421.21 5,959,576.85 550,311.90 5.00 24.09 427.70 5,959,562.96 550,318.49 5.00 38.02 431.50 5,959,554.73 550,322.34 5.00 46.28 444.71 5,959,524.80 550,335.75 5.00 76.30 460.56 5,959,487.22 550,351.85 5.00 113.99 478.92 5,959,442.28 550,370.51 5.00 159.05 499.66 5,959,390.32 550,391.59 5.00 211.16 522.62 5,959,331.73 550,414.94 5.00 269.91 547.63 5,959,266.97 550,440.37 5.00 334.85 574.48 5,959,196.51 550,467.69 5.00 405.49 602.99 5,959,120.90 550,496.70 5.00 481.30 632.93 5,959,040.72 550,527.17 5.00 561.69 664.08 5,958,956.57 550,558.87 5.00 646.06 696.19 5,958,869.09 550,591.56 5.00 733.76 705.30 5,958,844.15 550,600.84 5.00 758.77 728.87 5,958,779.55 550,624.84 0.00 823.52 761.58 5,958,689.92 550,658.14 0.00 913.39 778.49 5,958,643.56 550,675.36 0.00 959.86 794.28 5,958,600.28 550,691.44 0.00 1,003.25 826.99 5,958,510.65 550,724.74 0.00 1,093.11 836.13 5,958,485.60 550,734.04 0.00 1,118.22 858.55 5,958,420.45 550,756.89 3.00 1,183.53 885.81 5,958,328.31 550,784.76 3.00 1,275.86 896.87 5,958,285.16 550,796.11 3.00 1,319.09 909.20 5,958,234.61 550,808.77 0.00 1,369.73 932.10 5,958,140.73 550,832.30 0.00 1,463.77 955.00 5,958,046.86 550,855.62 0.00 1,557.81 977,90 5,957,952.98 550,879.34 0.00 1,651.85 995.33 5,957,881.54 550,897.24 0.00 1,723.42 1,000.81 5,957,859.10 550,902.86 0.00 1,745.89 2/9/7005 4:59:27PM Page 4 of 10 COMPASS 2003.11 Build 50 ~~,~ ~ llib H C y rt " a u on ompan r i -5Ut ConOCOPhillips Panning Report -Geographic A~8SIC1 A Ha1116urton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1 E Pad Company: ConocoPhillips Alas ka Inc.(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 @ 106.9 0ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.9 0ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1E Pad North Reference: True WeH: Plan 1 E-117 Survey Calculation Method; Minimum Curvature Wellbore: 1 E-117 Design: 1 E-117 (wp04) Planned Survey 1 E-117 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section lft) (°) (°) (ft) (ft) (ft) (ft) (ft) lft) (°/100ft) (ft) 3,000.00 75.44 166.31 1,779.05 1,672.15 -2,002.05 1,023.71 5,957,765.23 550,926.39 0.00 1,839.93 3,100.00 75.44 166.31 1,804.18 1,697.28 -2,096.09 1,046.61 5,957,671.35 550,949.91 0.00 1,933.97 3,200.00 75.44 166.31 1,829.32 1,722.42 -2,190.13 1,069.51 5,957,577.47 550,973.43 0.00 2,028.01 3,300.00 75.44 166.31 1,854.46 1,747.56 -2,284.17 1,092.41 5,957,483.60 550,996.96 0.00 2,122.05 3,400.00 75.44 166.31 1,879.60 1,772.70 -2,378.21 1,115.31 5,957,389.72 551,020.48 0.00 2,216.09 3,500.00 75.44 166.31 1,904.74 1,797.84 -2,472.25 1,138.21 5,957,295.84 551,044.00 0.00 2,310.13 3,600.00 75.44 166.31 1,929.88 1,822.98 -2,566.29 1,161.12 5,957,201.96 551,067.53 0.00 2,404.17 3,700.00 75.44 166.31 1,955.02 1,848.12 -2,660.33 1,184.02 5,957,108.09 551,091.05 0.00 2,498.21 3,800.00 75.44 166.31 1,980.16 1,873.26 -2,754.37 1,206.92 5,957,014.21 551,114.57 0.00 2,592.25 3,900.00 75.44 166.31 2,005.30 1,898.40 -2,848.41 1,229.82 5,956,920.33 551,138.09 0.00 2,686.29 3,910.36 75.44 166.31 2,007.90 1,901.00 -2,858.15 1,232.19 5,956,910.61 551,140.53 0.00 2,696.03 K15 4,000.00 75.44 166.31 2,030.43 1,923.53 -2,942.45 1,252.72 5,956,826.46 551,161.62 0.00 2,780.33 4,100.00 75.44 166.31 2,055.57 1,948.67 -3,036.49 1,275.62 5,956,732.58 551,185.14 0.00 2,874.37 4,200.00 75.44 166.31 2,080.71 1,973.81 -3,130.53 1,298.52 5,956,638.70 551,208.66 0.00 2,968.41 4,300.00 75.44 166.31 2,105.85 1,998.95 -3,224.57 1,321.43 5,956,544.83 551,232.19 0.00 3,062.45 4,400.00 75.44 166.31 2,130.99 2,024.09 -3,318.61 1,344.33 5,956,450.95 551,255.71 0.00 3,156.49 4,500.00 75.44 166.31 2,156.13 2,049.23 -3,412.65 1,367.23 5,956,357.07 551,279.23 0.00 3,250.53 4,600.00 75.44 166.31 2,181.27 2,074.37 -3,506.69 1,390.13 5,956,263.19 551,302.75 0.00 3,344.57 4,700.00 75.44 166.31 2,206.41 2,099.51 -3,600.73 1,413.03 5,956,169.32 551,326.28 0.00 3,438.61 4,800.00 75.44 166.31 2,231.55 2,124.65 -3,694.77 1,435.93 5,956,075.44 551,349,80 0.00 3,532.65 4,900.00 75.44 166.31 2,256.69 2,149.79 -3,788.81 1,458.83 5,955,981.56 551,373.32 0.00 3,626.69 5,000.00 75.44 166.31 2,281.82 2,174.92 -3,882.85 1,481.73 5,955,887.69 551,396.85 0.00 3,720.73 5,100.00 75.44 166.31 2,306.96 2,200.06 -3,976.89 1,504.64 5,955,793.81 551,420.37 0.00 3,814.77 5,200.00 75.44 166.31 2,332.10 2,225.20 -4,070.93 1,527.54 5,955,699.93 551,443.89 0.00 3,908.81 5,300.00 75.44 166.31 2,357.24 2,250.34 -4,164.97 1,550.44 5,955,606.06 551,467.42 0.00 4,002.85 5,382.18 75.44 166.31 2,377.90 2,271.00 -4,242.26 1,569.26 5,955,528.91 551,486.75 0.00 4,080.13 13318" Cag Pt -1207'FSL 8; 924'FWI. -Sect 22 - T11N - R10E :Drill out 121/4" Hole : 5382 ft MD, 2378 ft TVD - T3+675 -13 3l8" 5,400.00 75.44 166,31 2,382.38 2,275.48 -4,259.01 1,573.34 5,955,512.18 551,490.94 0.00 4,096.89 5,500.00 75.44 166.31 2,407.52 2,300.62 -4,353.05 1,596.24 5,955,418.30 551,514.46 0.00 4,190.93 5,600.00 75.44 166.31 2,432.66 2,325.76 -4,447.09 1,619.14 5,955,324.43 551,537.98 0.00 4,284.97 5,700.00 75,44 166.31 2,457.80 2,350.90 -4,541.13 1,642.04 5,955,230.55 551,561.51 0.00 4,379.01 5,800.00 75.44 166.31 2,482.94 2,376.04 -4,635.17 1,664.95 5,955,136.67 551,585.03 0.00 4,473.05 5,900.00 75.44 166.31 2,508.07 2,401.17 -4,729.22 1,687.85 5,955,042.79 551,608.55 0.00 4,567.09 6,000.00 75.44 166.31 2,533.21 2,426.31 -4,823.26 1,710.75 5,954,948.92 551,632.08 0.00 4,661.13 6,100.00 75.44 166.31 2,558.35 2,451.45 -4,917.30 1,733.65 5,954,855.04 551,655.60 0.00 4,755.17 6,200.00 75.44 166.31 2,583.49 2,476.59 -5,011.34 1,756.55 5,954,761.16 551,679.12 0.00 4,849.21 6,300.00 75.44 166.31 2,608.63 2,501.73 -5,105.38 1,779.45 5,954,667.29 551,702.65 0.00 4,943.25 6,400.00 75.44 166.31 2,633.77 2,526.87 -5,199.42 1,802.35 5,954,573.41 551,726.17 0.00 5,037.30 6,500.00 75.44 166.31 2,658.91 2,552.01 -5,293.46 1,825.26 5,954,479.53 551,749.69 0.00 5,131.34 6,600.00 75.44 166.31 2,684.05 2,577.15 -5,387.50 1,848.16 5,954,385.66 551,773.21 0.00 5,225.38 6,607.37 75.44 166.31 2,685.90 2,579.00 -5,394.43 1,849.85 5,954,378.73 551,774.95 0.00 5,232.31 Ugnu C 6,700.00 75.44 166.31 2,709.19 2,602.29 -5,481.54 1,871.06 5,954,291.78 551,796.74 0.00 5,319.42 6,800.00 75.44 166.31 2,734.32 2,627.42 -5,575.58 1,893.96 5,954,197.90 551,820.26 0.00 5,413.46 6,900.00 75.44 166.31 2,759.46 2,652.56 -5,669.62 1,916.86 5,954,104.02 551,843.78 0.00 5,507.50 7,000.00 75.44 166.31 2,784.60 2,677.70 -5,763.66 1,939.76 5,954,010.15 551,867.31 0.00 5,601.54 7,100.00 75.44 166.31 2,809.74 2,702.84 -5,857.70 1,962.66 5,953,916.27 551,890.83 0.00 5,695.58 7,200.00 75.44 166.31 2,834.88 2,727.98 -5,951.74 1,985.56 5,953,822.39 551,914.35 0.00 5,789.62 2!9/2005 4:59:27PM Page 5 of 10 COMPASS 2003.11 Build 50 ~~~~ ~;F ~ / • llib H C y rt "1 "'1 ' Ph il C a u on ompan ~ ~ -5UI ~ onoco i ips Planning Report -Geographic AiaSka A HaNlburton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1E Pad Company: ConocoPhillips Alaska Inc.(Kuparuk) ND Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1E-117 Survey Calculation Method: Minimum Curvature Weltbore: 1 E-117 Design: 1 E-117 (wp04) Planned Survey 1 E-117 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E(_yy Northing Fasting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 'i 7,300.00 75.44 166.31 2,860.02 2,753.12 -6,045.78 2,008.47 5,953,728.52 551,937.87 0.00 5,883.66 7,400.00 75.44 166.31 2,885.16 2,778.26 -6,139.82 2,031.37 5,953,634.64 551,961.40 0.00 5,977.70 7,500.00 75.44 166.31 2,910.30 2,803.40 -6,233.86 2,054.27 5,953,540.76 551,984.92 0.00 6,071.74 7,600.00 75.44 166.31 2,935.44 2,828.54 -6,327.90 2,077.17 5,953,446.89 552,008.44 0.00 6,165.78 7,605.82 75.44 166.31 2,936.90 2,830.00 -6,333.38 2,078.50 5,953,441.42 552,009.81 0.00 6,171.26 Ugnu B 7,700.00 75.44 166.31 2,960.57 2,853.67 -6,421.94 2,100.07 5,953,353.01 552,031.97 0.00 6,259.82 7,776.87 75.44 166.31 2,979.90 2,873.00 -6,494.23 2,117.68 5,953,280.84 552,050.05 0.00 6,332.11 Ugnu A 7,800.00 75.44 166.31 2,985.71 2,878.81 -6,515.98 2,122.97 5,953,259.13 552,055.49 0.00 6,353.86 7,900.00 75.44 166.31 3,010.85 2,903.95 -6,610.02 2,145.87 5,953,165.26 552,079.01 0.00 6,447.90 8,000.00 75.44 166.31 3,035.99 2,929.09 -6,704.06 2,168.78 5,953,071.38 552,102.54 0.00 6,541.94 8,100.00 75.44 166.31 3,061.13 2,954.23 -6,798.10 2,191.68 5,952,977.50 552,126.06 0.00 6,635.98 8,200.00 75.44 166.31 3,086.27 2,979.37 -6,892.14 2,214.58 5,952,883.62 552,149.58 0.00 6,730.02 8,300.00 75.44 166.31 3,111.41 3,004.51 -6,986.18 2,237.48 5,952,789.75 552,173.10 0.00 6,824.06 8,400.00 75.44 166.31 3,136.55 3,029.65 -7,080.22 2,260.38 5,952,695.87 552,196.63 0.00 6,918.10 8,492.90 75.44 166.31 3,159.90 3,053.00 -7,167.58 2,281.66 5,952,608.66 552,218.48 0.00 7,005.46 K13 8,500.00 75.44 166.31 3,161.69 3,054.79 -7,174.26 2,283.28 5,952,601.99 552,220.15 0.00 7,012.14 8,600.00 75.44 166.31 3,186.82 3,079.92 -7,268.30 2,306.18 5,952,508.12 552,243.67 0.00 7,106.18 8,700.00 75.44 166.31 3,211.96 3,105.06 -7,362.34 2,328.09 5,952,414.24 552,267.20 0.00 7,200.22 8,782.03 75.44 166.31 3,232.59 3,125.69 -7,439.49 2,347.87 5,952,337.23 552,286.49 0.00 7,277.36 Continue Build ~ 3.00°/100ft , 8782 ft MD, 3233 R 7VD 8,800.00 75.53 166.86 3,237.09 3,130.19 -7,456.40 2,351.91 5,952,320.34 552,290.64 2.99 7,294.28 8,900.00 76.03 169.91 3,261.66 3,154.76 -7,551.34 2,371.41 5,952,225.54 552,310.77 3.00 7,389.22 9,000.00 76.58 172.95 3,285.33 3,178.43 -7,647.41 2,385.88 5,952,129.59 552,325.88 3.00 7,485.28 9,100.00 77.16 175.97 3,308.06 3,201.16 -7,744.32 2,395.28 5,952,032.74 552,335.92 3.00 7,582.20 9,200.00 77.78 178.98 3,329.76 3,222.86 -7,841.83 2,399.58 5,951,935.27 552,340.86 3.00 7,679.71 9,235.04 78.00 180.03 3,337.11 3,230.21 -7,876.09 2,399.87 5,951,901.02 552,341.39 3.00 7,713.97 Begin Sail ~ 78.00° inc & 180.03° Azi, 9236 ft MD, 3337 it TVD 9,300.00 78.00 180.03 3,350.62 3,243.72 -7,939.63 2,399.84 5,951,837.49 552,341.77 0.00 7,777.51 9,335.04 78.00 180.03 3,357.90 3,251.00 -7,973.90 2,399.82 5,951,803.22 552,341.98 0.00 7,811.78 Intersect DSand ~ 78.00° Inc, 9335 ft MD, 3368 ft TVD -West Sak D 9,400.00 78.00 180.03 3,371.41 3,264.51 -8,037.45 2,399.79 5,951,739.68 552,342.37 0.00 7,875.33 9,435.04 78.00 180.03 3,378.69 3,271.79 -8,071.72 2,399.77 5,951,705.42 552,342.58 0.00 7,909.60 Co~rtinue Dir ~ 2.00°f100ft ,9435 ft MD, 3379 ft ND 9,500.00 79.30 180.03 3,391.48 3,284.58 -8,135.41 2,399.74 5,951,641.73 552,342.97 2.00 7,973.29 9,530.04 79.90 180.03 3,396.90 3,290.00 -8,164.96 2,399.72 5,951,612.18 552,343.15 2.00 8,002.84 West Sak C 9,600.00 81.30 180.03 3,408.33 3,301.43 -8,233.98 2,399.68 5,951,543.18 552,343.57 2.00 8,071.85 9,635.04 82.00 180.03 3,413.41 3,306.51 -8,268.64 2,399.67 5,951,508.52 552,343.79 2.00 8,106.52 Begin Sail ~ 82.00° Inc 8 180.03° Azi, 9635 ft MD, 3413 R TVD 9,645.72 82.00 180.03 3,414.90 3,308.00 -8,279.21 2,399.66 5,951,497.94 552,343.85 0.00 8,117.09 West Sak B 9,700.00 82.00 180.03 3,422.45 3,315.55 -8,332.97 2,399.63 5,951,444.19 552,344.18 0.00 8,170.85 2AJ/2005 4:59:27PM Page 6 of 10 COMPASS 2003.11 Build 50 ~~~. ~ . _ __ ~-' • OPh C ll Halliburton Company 5 -~iJ1~1 ~ ° onOC i i ps Pla nning Report -Geographic Alaska A Halllbunon Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1E Pad Company: ConocoPhillips Alaska Ina(Kuparuk) ND Reference: 66.9 GL + 40RF=106.9 @ 106.9 0ft (DOyon 1 5 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.9 0ft (Doyon 1 5 (66.9GL + 40R Site: Kuparuk 1 E Pad No rth Reference: True Well: Plan 1 E-117 Su rvey Calculation Method: Minimum Curvature Wellbore: 1 E-1 17 Design: 1E-1 17 (wp04) Planned Survey 1 E-117 (wp04) Map Map MD Inclination Azimuth ND SSND +N1-S +EI-W Northing Easting DLSEV Vert Section ii (ftl (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) f°HOOft) Ift) 'i 9,800.00 82.00 180.03 3,436.37 3,329.47 -8,432.00 2,399.58 5,951,345.18 552,344.78 0.00 8,269.88 i 9,825.35 82.00 180.03 3,439.90 3,333.00 -8,457.10 2,399.57 5,951,320.08 552,344.94 0.00 8,294.98 West Sak A4 9,900.00 82.00 180.03 3,450.29 3,343.39 -8,531.02 2,399.53 5,951,246.16 552,345.39 0.00 8,368.90 10,000.00 82.00 180.03 3,464.21 3,357.31 -8,630.05 2,399.48 5,951,147.15 552,346.00 0.00 8,467.93 i 10,062.46 82.00 180.03 3,472.90 3,366.00 -8,691.91 2,399.44 5,951,085.30 552,346.37 0.00 8,529.79 West Sak A3 10,100.00 82.00 180.03 3,478.12 3,371.22 -8,729.08 2,399.43 5,951,048.13 552,346.60 0.00 8,566.96 10,200.00 82.00 180.03 3,492.04 3,385.14 -8,828.11 2,399.37 5,950,949.12 552,347.21 0.00 8,665.98 10,300.00 82.00 180.03 3,505.96 3,399.06 -8,927.13 2,399.32 5,950,850.10 552,347.81 0.00 8,765.01 10,400.00 i 82.00 180.03 3,519.88 3,412.98 -9,026.16 2,399.27 5,950,751.09 552,348.42 0.00 8,864.04 10,470.59 82.00 180.03 3,529.70 3,422.80 -9,096.06 2,399.23 5,950,681.19 552,348.85 0.00 8,933.94 Continue Dir ~ 4.00°/1008 , 10471 ft MD, 3530 ft Np 10,495.07 82.98 180.01 3,532.90 3,426.00 -9,120.33 2,399.22 5,950,656.92 552,349.00 4.00 8,958.21 95/8" Csg Pt -1613'FSL & 1742'FWL -Sect 27 - T11 N - R10E :Drill out 81/2" Hole : 10495 ft MD, 3533 ft TVD -West Sak A2 - 95/8" 10,500.00 83.17 180.00 3,533.49 3,426.59 -9,125.23 2,399.22 5,950,652.03 552,349.03 3.97 8,963.10 i 10,600.00 87.17 179.92 3,541.90 3,435.00 -9,224.85 2,399.29 5,950,552.42 552,349.76 4.00 9,062.73 10,700.00 91.17 179.83 3,543.34 3,436.44 -9,324.82 2,399.50 5,950,452.46 552,350.64 4.00 9,162.70 10,730.64 92.40 179.81 3,542.39 3,435.49 -9,355.45 2,399.60 5,950,421.84 552,350.93 4.01 9,193.33 Land in A-Sand ~ 92.40°Inc -Begin Undulations ,10731 ft MD, 3542 R TVD 10,800.00 92.68 179.82 3,539.31 3,432.41 -9,424.74 2,399.82 5,950,352.56 552,351.62 0.40 9,262.61 10,900.00 93.08 179.83 3,534.29 3,427.39 -9,524.61 2,400.13 5,950,252.70 552,352.59 0.40 9,362.49 I 11,000.00 93.48 179.85 3,528.58 3,421.68 -9,624.45 2,400.41 5,950,152.88 552,353.53 0.40 9,462.32 11,100.00 93.88 179.86 3,522.17 3,415.27 -9,724.24 2,400.66 5,950,053.10 552,354.45 0.40 9,562.12 11,130.64 94.00 179.86 3,520.06 3,413.16 -9,754.81 2,400.74 5,950,022.53 552,354.72 0.40 9,592.69 11,200.00 94.00 179.86 3,515.22 3,408.32 -9,824.00 2,400.90 5,949,953.35 552,355.34 0.00 9,661.88 i 11,300.00 94.00 179.86 3,508.25 3,401.35 -9,923.75 2,401.13 5,949,853.61 552,356.24 0.00 9,761.63 11,330.64 94.00 179.86 3,506.11 3,399.21 -9,954.32 2,401.21 5,949,823.04 552,356.52 0.00 9,792.20 11,400.00 93.65 179.86 3,501.49 3,394.59 -10,023.52 2,401.37 5,949,753.85 552,357.14 0.50 9,861.40 11,500.00 93.15 179.86 3,495.55 3,388.65 -10,123.35 2,401.60 5,949,654.04 552,358.04 0.50 9,961.23 11,600.00 92.65 179.86 3,490.49 3,383.59 -10,223.22 2,401.84 5,949,554.19 552,358.94 0.50 10,061.10 11,700.00 92.15 179.86 3,486.30 3,379.40 -10,323.13 2,402.07 5,949,454.29 552,359.83 0.50 10,161.01 11,730.64 92.00 179.86 3,485.19 3,378.29 -10,353.75 2,402.15 5,949,423.67 552,360.11 0.50 10,191.63 11,800.00 91.31 179.86 3,483.19 3,376.29 -10,423.08 2,402.31 5,949,354.35 552,360.73 1.00 10,260.96 11,900.00 90.31 179.86 3,481.78 3,374.88 -10,523.07 2,402.55 5,949,254.38 552,361.63 1.00 10,360.95 12,000.00 89.31 179.86 3,482.12 3,375.22 -10,623.07 2,402.78 5,949,154.39 552,362.53 1.00 10,460.95 i 12,100.00 88.31 179.86 3,484.21 3,377.31 -10,723.04 2,403.02 5,949,054.43 552,363.43 1.00 10,560.92 12,130.64 88.00 179.86 3,485.19 3,378.29 -10,753.67 2,403.09 5,949,023.80 552,363.71 1.00 10,591.55 12,200.00 88.D0 179.86 3,487.62 3,380.72 -10,822.98 2,403.25 5,948,954.50 552,364.33 0.00 10,660.86 12,300.00 88.00 179.86 3,491.11 3,384.21 -10,922.92 2,403.49 5,948,854.58 552,365.23 0.00 10,760.80 12,330.64 88.00 179.86 3,492.18 3,385.28 -10,953.55 2,403.56 5,948,823.95 552,365.50 0.00 10,791.43 12,400.00 88.48 179.86 3,494.31 3,387.41 -11,022.87 2,403.72 5,948,754.64 552,366.13 0.70 10,860.75 12,500.00 89.18 179.86 3,496.34 3,389.44 -11,122.85 2,403.96 5,948,654.68 552,367.03 0.70 10,960.73 12,600.00 89.88 179.86 3,497.15 3,390.25 -11,222.85 2,404.19 5,948,554.69 552,367.93 0.70 11,060.72 12,700.00 90.58 179.86 3,496.74 3,389.84 -11,322.84 2,404.43 5,948,454.71 552,368.83 0.70 11,160.72 i 12,730.64 90.80 179.86 3,496.37 3,389.47 -11,353.49 2,404.50 5,948,424.07 552,369.10 0.70 11,191.37 12,800.00 91.46 179.86 3,495.01 3,388.11 -11,422.83 2,404.67 5,948,354.74 552,369.73 0.95 11,260.71 12,900.00 92.41 179.86 3,491.63 3,384.73 -11,522.77 2,404.90 5,948,254.81 552,370.62 0.95 11,360.65 2/9!2005 4:59:27PM ,a~e,~'q(~ ~ COMPASS 2003.11 Build 50 7 _ J 1 , 1~ • iialiiburton Company ~n -5U1"t ConotoPhdlips Planning Report -Geographic Alaska A Hallibunon Company Database: EDM 2003.11 Single User Db ; Company: ConocoPhillips Alaska Inc(Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 E Pad Well: Pfan 1 E-117 Weilbore: 1 E-117 Design: 1 E-117 (wp04) Planned Survey 1 E-117 (wp04) MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Ift) (°) (°) (ft) Ift) (ft) (ft) 13,000.00 93.36 179.86 3,486.60 3,379.70 -11,622.64 2,405.14 13,100.00 94.31 179.86 3,479.92 3,373.02 -11,722.42 2,405.37 13,130.64 94.60 179.86 3,477.54 3,370.64 -11,752.97 2,405.44 13,200.00 94.60 179.86 3,471.98 3,365.08 -11,822.10 2,405.61 '~ 13,300.00 94.60 179.86 3,463.96 3,357.06 -11,921.78 2,405.84 13,330,64 94.60 179.86 3,461.50 3,354.60 -11,952.32 2,405.91 13,400.00 94.18 179.86 3,456.19 3,349.29 -12,021.48 2,406.08 13,500.00 93.58 179.86 3,449.42 3,342.52 -12,121.25 2,406.31 13,600.00 92.98 179.86 3,443.70 3,336.80 -12,221.08 2,406.55 13,700.00 92.38 179.86 3,439.01 3,332.11 -12,320.97 2,406.78 13,730.64 92.20 179.86 3,437.79 3,330.89 -12,351.59 2,406.85 it 13,800.00 91.23 179.86 3,435.72 3,328.82 -12,420.91 2,407.02 13,900.00 89.83 179.86 3,434.79 3,327.89 -12,520.91 2,407.25 14,000.00 88.43 179.86 3,436.32 3,329.42 -12,620.89 2,407.49 14,100.00 87.03 179.86 3,440.28 3,333.38 -12,720.81 2,407.72 14,130.64 86.60 179.86 3,441.98 3,335.08 -12,751.41 2,407.80 14,200.00 86.60 179.86 3,446.10 3,339.20 -12,820.64 2,407.96 14,230.64 86.60 179.86 3,447.92 3,341.02 -12,851.23 2,408.03 14,300.00 87.43 179.86 3,451.53 3,344.63 -12,920.49 2,408.20 14,400.00 88.63 179.86 3,454.96 3,348.06 -13,020.43 2,408.43 14,500.00 89.83 179.86 3,456.30 3,349.40 -13,120.42 2,408.67 ~ 14,600.00 91.03 179.86 3,455.55 3,348.65 -13,220.41 2,408.90 14,700.00 92.23 179.86 3,452.70 3,345.80 -13,320.37 2,409.14 i 14,730.64 92.60 179.86 3,451.41 3,344.51 -13,350.99 2,409.21 14,800.00 92.84 179.86 3,448.12 3,341.22 -13,420.27 2,409.37 14,900.00 93.19 179.86 3,442.86 3,335.96 -13,520.13 2,409.61 14,980.64 93.47 179.86 3,438.17 3,331.27 -13,600.64 2,409.80 i 15,000.00 93.47 179.86 3,437.00 3,330.10 -13,619.95 2,409.84 15,080.64 93.47 179.86 3,432.11 3,325.21 -13,700.45 2,410.03 15,100.00 93.36 179.89 3,430.96 3,324.06 -13,719.77 2,410.07 i 15,200.00 92.77 179.99 3,425.61 3,318.71 -13,819.63 2,410.18 ~ 15,300.00 92.18 180.09 3,421.30 3,314.40 -13,919.53 2,410.11 15,400.00 91.59 180.20 3,418.01 3,311.11 -14,019.48 2,409.86 15,480.64 91.11 180.28 3,416.11 3,309.21 -14,100.10 2,409.52 End Undulations in A-Sand , 15481 R MD, 3416 it TVD ~ 15,500.00 91.11 180.28 3,415.74 3,308.84 -14,119.45 2,409.42 15,600.00 91.11 18028 3,413.80 3,306.90 -14,219.43 2,408.93 15,700.00 91.11 180.28 3,411.86 3,304.96 -14,319.41 2,408.44 15,751.64 91.11 180.28 3,410.86 3,303.96 -14,371.05 2,408.19 BHL :1642' FSL & 1731' FEL -Sect 34 - T11N - R10E : 1 5752 ft MD, 3411 ft TVD - S 1/2" ~ Site Kuparuk 1 E Pad 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R True Minimum Curvature Map Map Northing Easting DLSEV Vert Section (ft) (ft) f°/100ft) (ft) 5,948,154.95 552,371.52 0.95 11,460.52 5,948,055.19 552,372.42 0.95 11,560.30 5,948,024.64 552,372.70 0.95 11,590.85 5,947,955.52 552,373.32 0.00 11,659.98 5,947,855.86 552,374.21 0.00 11,759.66 5,947,825.31 552,374.49 0.00 11,790.20 5,947,756.17 552,375.11 0.60 11,859.35 5,947,656.42 552,376.01 0.60 11,959.12 5,947,556.59 552,376.91 0.60 12,058.96 5,947,456.72 552,377.80 0.60 12,158.85 5,947,426.10 552,378.08 0.60 12,189.47 5,947,356.79 552,378.70 1.40 12,258.79 5, 947, 256.81 552, 379.60 1.40 12, 358.79 I 5,947,156.84 552,380.50 1.40 12,458.77 ~ 5,947,056.93 552,381.40 1.40 12,558.69 5,947,026.34 552,381.68 1.40 12,589.29 5,946,957.11 552,382.30 0.00 12,658.52 5,946,926.53 552,382.57 0.00 12,689.11 5,946,857.28 552,383.20 1.20 12,758.37 5,946,757.35 552,384.10 1.20 12,858.31 5,946,657.38 552,385.00 1.20 12,958.30 5,946,557.39 552,385.90 1.20 13,058.29 5,946,457.45 552,386.79 1.20 13,158.25 5,946,426.84 552,387.07 1.20 13,188.87 5,946,357.57 552,387.69 0.35 13,258.15 5,946,257.72 552,388.59 0.35 13,358.01 5,946,177.22 552,389.32 0.35 13,438.51 5,946,157.91 552,389.49 0.00 13,457.83 5,946,077.42 552,390.21 0.00 13,538.33 5,946,058.10 552,390.38 0.60 13,557.65 5,945,958.26 552,391.16 0.60 13,657.51 5,945,858.37 552,391.75 0.60 13,757.41 5,945,758.43 552,392.16 0.60 13,857.36 5,945,677.82 552,392.35 0.60 13,937.98 5,945,658.47 552,392.39 0.00 13,957.33 5,945,558.50 552,392.56 0.00 14,057.31 5,945,458.52 552,392.73 0.00 14,157.29 5,945,406.89 552,392.82 0.00 14,208.93 2/9/2005 4:59:27PM Page 8 of 10 COMPASS 2003.118ur1d 50 ~3 ~~~. Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: '/ PhiHi C Halliburton Company Sp~l'~l~-5t..~C'1 onoco ps Planning Report -Geographic Alaska A HatllDUrton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1 E Pad Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1 E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Metflod: Minimum Curvature Wellbore: 1 E-117 Design: 1E-117 (wp04) r--- -- -- jGeologic Targets 1 E-117 l'1/D Target Name +N/-S +E/-W Northing Easting Measured Vertical Casing Hole Depth Depth Diameter Diameter (h) (ft) ('~ (") 5,382.18 2,377.90 133/8 16 10,495.07 3,532.90 9-6/8 12-1/4 15,751.59 3,410.86 6-1/2 8-1/2 2x92005 4:59:27PM Page 9 of 10 COMPASS 2003.118uild 50 y~`~~~ k '; Prognosed Casing Points ~ ~ / Ph N C Haliiburton Company ~1rf n ~ ~ 5L.! onoco ips i Planning Report - Geographic Alaska A HaI1lbuAOn Company Database: EbM 2003.11 Single User Db Local Co-ordinate Reference: Site Kuparuk 1E Pad Company: ConocoPhillips Alaska Inc.(Kuparuk) TVD Reference: 66.9 GL + 40RF=106;9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 6~:9 GL + 40RF=f06,9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-117 Design: 1E-117 (wp04) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E!-W tft1 (°I (°) (ft1 (ftl (ft- Name 2,051.72 73.00 160.00 1,528.90 -1,121.98 778.49 Base of Permafrost 2,876.10 75.44 166.31 1,747.90 -1,885.54 995.33 T3 3,910.36 75.44 166.31 2,007.90 -2,858.15 1,232.19 K15 5,382.18 75.44 166.31 2,377.90 -4,242.26 1,569.26 T3+676 6,607.37 75.44 166.31 2,685.90 -5,394.43 1,849.85 Ugnu C 7,605.82 75.44 166.31 2,936.90 -6,333.38 2,078.50 Ugnu B 7,776.87 75.44 166.31 2,979.90 -6,494.23 2,117.68 UgnuA 8,492.90 75.44 166.31 3,159.90 -7,167.58 2,281.66 K13 9,335.04 78.00 180.03 3,357.90 -7,973.90 2,399.82 WestSakD 9,530.04 79.90 180.03 3,396.90 -8,164.96 2,399.72 WeatSakC 9,645.72 82.00 18D.03 3,414.90 -8,279.21 2,399.66 West Sak B 9,825.35 82.00 180.03 3,439.90 -8,457.10 2,399.57 West Sak A4 10,062.46 82.00 180.03 3,472.90 -8,691.91 2,399.44 West Sak A3 10,495.07 62.98 180.01 3,532.90 -9,120.33 2,399.22 West Sak A2 2AJ/1005 4:59:27PM Page f0 of 10 COMPASS 2003.11 Build 50 SURVEY PROGRAM Date: 7.00.8-0),-09TU0:110:00 Vdida[al: Ves Version: Depth From Depth To Suney/Plan Tool 40.00 8/1U.Ip IE-117 (x~p91) CR-GYR4S5 800.00 15701.60 IE-117 (x'p01) MWD °iO~ 270 /V a+~ avelling Cylinder Azimuth (TFO+AZq (°) vs Centre to CenMe Separafion (50 k/ini ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 40 To 15747 Maximum Range:2500 Reference: Plan: tE-117 (wp04) ', REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1 E-117, True NoM Vertical (fVD) Reference: 66.9 GL+40RF=706.9 ~ 106.90ft (Doyon 15 (66.9GL+40RKa)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 86.9 GL+40RF=106.9 (21106.9011 (Doyon 15 (66.9GL+40RK8)) Calculation Method: Minimum Curvature WELL DETAILS: PWn 1E-117 Ground Level: 66.90 +WS +FJ-W NoMing Fasting Latitude Longitude Sbt 0.00 0.00 5959600.86 550300.51 70°18'1.427N 149°35'33.405W From Colour To MD 40 100 100 200 200 300 300 400 400 500 500 600 600 700 700 800 800 ~~-- -- - ~ - 900 900 1000 1000 1500 1500 2000 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 10000 10000 11000 11000 12000 12000 13000 13000 14000 14000 ~` 15000 15000 16000 90 180 C. LEGEND ~jF 1E-112,1E-112,1E-113 V1 1E-112,1E-112Li, 1E-111L1 VO -- tE-112,1E-112L2, 1E-112L2 V1 - 1E-112.1E-112PB1, tE~112Pa1 V2 -~ tE-11 d,fE-11d. tE-ttd V1 -~ 1E-11 d,fE-11dL1. 1E-114L1 V1 -~- tE-ltd, tE-11dL2.fE~11dL2 V0 ---~- tE-119.1E-tt9. tE-119 V1 tE-tee V1 -~ tE-188 tE~186 Travelling Cylinder Azimuth (TFO+ALI) ~°~ vs Centre to Centre Separation X10 ft/in~ , . 1E-166,1E468L1, tE-166L1 V1 1E-166L1PB1 V2 -- Q~- 1E-166 1E-186L1 PB1 ___ SECTION DETAILS , . ~ tE-166. tE-168L2,tE-166L2 V1 Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target --~- tE-16a.1E-198, tE-tfie V1 1 40.00 0.00 0.00 40.00 0.00 0.00 0.00 0.00 0.00 --j-- tE-188, 1E-168L1.1E-168L1 v3 2 3gp_g0 g.pg p.00 300.00 0.00 0.00 0.00 0.00 0.00 -~- tE-166,1E-168L2.1E-188L2 V1 3 466.67 5.00 155.00 466.46 -8.59 3.07 3.00 155.00 6.59 ~~ 1E46B, tE-168L2PB1, tE-168L2PB1 VD 4 868.67 15.00 155.00 663.17 -38.02 17.73 5.00 0.00 38.02 tE-188,1E-188PB1, tE-168PB1 V3 5 1627.94 73.00 160.00 1463.47 -758.77 295.33 5.00 5.64 75877 -$-- tE-z3.1E-n.1E-z3 V1 6 2227.94 73.00 160.00 7580.42-1178.22 426.18 0.00 0.00 1118.22 -~ tE-z4.1E-2d, tE-2d V4 7 2446.15 75.44 166.37 1639.82-1319.09 486.90 3.00 69.00 1319.09 ~~ 1E-21, tE~2M.1E-24AV1 8 8782.03 75.44 186.31 3232.59-7277.36 1937.90 0.00 0.00 7277.36 -~ tE-25,1E-25.1E-25V1 g 9235.04 78.00 180.03 3337.11 -7713.97 1989.90 3.00 80.78 7713.97 tE-28, tE-26.1E-M Vl 10 9335.04 78.00 180.03 3357.90-7811.78 1989.85 0.00 0.00 7811.78 tE-717 D-top (v3) --;-- 1E-33.1E-33.1E-33 v2 11 9435.04 78.00 180.03 3378.69 -7909.60 1989.80 0.00 0.00 7909.60 -~ tE-33Pa1, tE-33PB1,tE-33PB1 VZ 12 9635.04 82.00 180.03 3413.41 -8106.52 1989.69 2.00 360.00 8108.52 1E35. tE-35.1E-35VI 00 180.03 3529.70-8933.94 1989.26 1310470 59 82 0.00 0.00 8933.94 -~ Plan tE-1 ]o.PYn tE-1 ]O. tE-1 ]0 (wp03)VO Pbn 1E-1 ]0 L1 1E-1]OL1 (wp037 V0 -~- Plen 1E-90 . . 1410730.60 92.40 179.93 3542.38-9193.28 1989.35 4.00 -0.54 9193.28 1E-117 T2 (v3) , , Pun 1E-1 ]o, Plan le-1 ]O 12.1E-nou hipo37 vo 1511130.60 94.00 179.99 3520.06-9592.85 1989.63 00 779.99 3506.11 -9792.76 1989.67 7611330 60 94 0.40 0.00 2.00 9592.65 0.00 9792.16 --~~~ a-to, 1}1o. utov] . . 99 3485.7910791.59 1989.76 1711730 60 92 00 179 0.50 180.0010191.59 ---g-- Plan l}158,1}M3A Lataal, lJ-M3Alete9ai Vars/2AV1 . . . 00 179.99 3485.1970591.51 1989.85 1872130 60 88 1.00 180.0010591.51 Pbn 1}169.PYn 1}M3 Let A. Plan 1J-M2 LetA VO . . 99 3492.1&10791.39 7989.89 60 88 00 179 1912330 0.00 0.0010791.39 --~- Plan 1}162(Mt).1J-182. u-162 (wp03 ,-NOM N«n vo . . . 99 3496.37-11191.32 7989.98 60 90 80 179 2012730 0.70 00011191.32 %an t116I (Mt), 1J-162 Lt, 1J-ffi Lt (wp3.1)VO . . . 60 179.99 3477.5417590.81 1990.06 2113730 60 94 0.95 0.0011590.81 -~ Plen 1J-182 (M1). 1J-182 L2, 1J-162 L2 (wp3.1)VO . . 60 94.80 179.99 3461.5011790.16 1990.10 2213330 0.00 0.0011790.16 --$- Pl.n 1}168.1}166. a-lee twpo3WO . 7912189.43 1990.19 20 179 99 3437 2313730 60 92 080 180.0012189.43 -~-~ PYn 1}16e. u-16eu,1}168u (wPm)vo . . . . 60 179.99 3441.9&12589.25 1990.28 2414130 60 86 1.40 180.0012589.25 1} Pun ulse, a-tee LZ, u-16BUlwoo3)vo . . 60 179.99 3447.91-12689.07 1990.30 2574230 60 86 0.00 0.0012689.07 ! Kuo-3e-n-1w,3an-1o,3tn-lovz ~- WSAK-03. WSAKd13. VJ8GKd%f V0 . . 2674730.60 92.60 179.99 3451.41-73188.83 1990.41 1.20 0.0013168.83 _~ 1e-n](wpop 2714980.60 93.47 779.99 3438.17-13438.48 1990.46 0.35 0.0013438.48 2815080.60 93.47 779.99 3432.11-13538.30 1990.48 0.00 0.0013538.30 2915480.80 91.11 180.40 3416.11-13937.94 7989.11 0.60 170.0013937.94 3015751.60 91.11 180.40 3410.8674208.89 1987.20 0.00 0.0014208.89 ConocoPhillipsAWska Inc.(Kuparuk) Engineering West Sak Calculation Method: Minimum Curvature E1ror System: ISCYYSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic blaming Method: Rules Based •lan: 1E-117 w 04 Plan 1E-117/PIan 1E-117 ~ P )~ ) 0 .Y ~. ~. L ~-. U 0 ... a~ L U Measured Depth [ft] - 1E-112 (1E-112) 1E-112 (1E-112L1) 1E-112 (1E-112L2) 1E-112 (1E-112PB1) - 1E-114 (lE-] 14) 1E-114 (1E-114L1) IE-114 (lE-ll4L2) IE-119 (]E-119) 1E-166 (1E-166) IE-166 (1E-166L1) 1E-166 (1~166L1PB1) 1E-166 (1E-166L2) lE-]68 (1E-168) 1E-168 (1E-168L1) 1E-168 (1E-168L2) 1E-168 (1E-168L2PB1) 1E-168 (1E-168PB1) 1E-23 (1E-23) 1E-24 (1E-24) IE-24 (1E-24A) - 1E-25 (1E-25) 1E-26 (1E-26) 1E-33 (IE-33) 1E-33PB1 (1E-33PB1) - 1E-35 (1E-35) Plan IE-170 (Plan 1E-170 L1) Plan 1E-170 (Plan ]E-170 L2) - - Plan ]E-170 (Plan ]E-170) - IJ-10 (1J-10) Plan 1J-158 (Plan 1J-M3 Lat A) Plan 1J-160 (Plan 1J-M2 Lat A) Plan ]J-162 (1J-162) Plan 1J-168 (1J-168 Ll) Plan 1J-168 (1J-168 L2) Plan 1J-168 (1J-168) KUP 34-II-10-1(KUP 34-11-10-1 - WSAK-03 (WSAK-03) I ~~ Halliburton Com a~ P Y Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 2/9)2005 Time: 18:14:46 Page:. Field: Kuparuk River Unit Reference Site: Kuparuk 1 E Pad Co-ordinate(NE) Refe rence: Well: Pla n 1 E-117, True North Reference ~~'eIL• Reference Wellpatb: Plan 1 E-117 Plan 1E-117 Vertical (TVD) Refere nce; Doyon 15 (40 +66.9) 106.9 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Plan: 1 E-117 (vvp04) & NOT PLANNED P Interpolation Method: MD Interval: 25.000 ft Error Model: ISCWSA Ellipse Depth Range: 40.000 to 15751.935 ft Scan Method: Trav Cylinder North Maximum Radius: 1 752.820 ft Error Surface: Ellipse + Casing Casing Points NID TVD Diameter Hole Size Name ' ft ft in in 5582.180 2428.137 13.375 17.500 13 3/8" 10495.070 3532.859 9.625 12.250 9 5/8" 15751.590 3410.866 5.500 8.500 5112" Plan: 1 E-117 (wp04) Date Composed: 2!9/2005 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Summary ~< ---------------- O ffset Wellpatb ----- -----------------> Reference Offset Ctr-CU' No-Go Allowable ~ Site LVell Weppath MD MD Distance Area Deviation ` Vk'arning I ft ft ft ft ft - _. Kuparuk 1 E Pad 1 E-112 _ 1 E-112 V1 323.031 325.000 180.597 8.587 172.010 Pass: Major Risk Kuparuk 1 E Pad 1 E-112 1 E-112L1 VO 8543.163 1 1296.900 647.293 542.602 104.691 Pass: Major Risk Kuparuk 1E Pad 1E-112 1E-112L2 V1 8536.627 1 1284.900 669.923 563.420 106.503 Pass: Major Risk Kuparuk 1E Pad 1E-112 1E-112PB1 V2 323.031 325.000 180.597 8.322 172.275 Pass: Major Risk Kuparuk 1 E Pad 1 E-114 1 E-114 V1 324.077 325.000 80.743 8.149 72.594 Pass: Major Risk Kuparuk 1 E Pad 1 E-114 1 E-114L1 V1 324.077 325.000 80.743 8.149 72.594 Pass: Major Risk Kuparuk 1 E Pad 1 E-114 1 E-114L2 VO 324.077 325.000 80.743 8.149 72.594 Pass: Major Risk Kuparuk 1 E Pad 1 E-119 1 E-119 V1 174.993 175.000 40.951 4.121 36.830 Pass: Major Risk Kuparuk 1 E Pad 1 E-166 1 E-166 V1 8414.784 9300.000 616.186 375.324 240.862 Pass: Major Risk Kuparuk 1 E Pad 1 E-166 1 E-166L1 V1 8264.929 9150.000 476.551 385.687 90.864 Pass: Major Risk Kuparuk 1 E Pad 1 E-166 1 E-166L1 P61 V2 8082.640 8948.900 435.710 341.815 93.895 Pass: Major Risk Kuparuk 1 E Pad 1 E-166 1 E-166L2 V1 8026.791 8900.000 440.260 369.249 71.010 Pass: Major Risk Kuparuk 1 E Pad 1 E-168 1 E-168 V1 1751.086 1800.000 108.578 47.519 61.059 Pass: Major Risk Kuparuk 1 E Pad 1 E-168 1 E-168L1 V3 1751.086 1800.000 108.578 47.545 61.033 Pass: Major Risk Kuparuk 1 E Pad 1 E-168 1 E-168L2 V1 1751.086 1800.000 108.578 47.519 61.059 Pass: Major Risk Kuparuk 1 E Pad 1 E-168 1 E-168L2PB1 V3 1751.086 1800.000 108.578 47.545 61.033 Pass: Major Risk Kuparuk 1 E Pad 1 E-168 1 E-168P61 V3 1751.086 1800.000 108.578 47.519 61.060 Pass: Major Risk Kuparuk 1E Pad 1E-23 1E-23 V1 322.643 325.000 220.262 8.042 212.220 Pass: Major Risk Kuparuk 1 E Pad 1 E-24 1 E-24 V4 346.283 350.000 157.654 8.560 149.094 Pass: Major Risk Kuparuk 1E Pad 1E-24 1E-24A V1 346.283 350.000 157.654 8.560 149.094 Pass: Major Risk Kuparuk 1 E Pad 1 E-25 1 E-25 V1 323.872 325.000 100.007 9.184 90.823 Pass: Major Risk Kuparuk 1 E Pad 1 E-26 1 E-26 V1 349.063 350.000 40.535 10.177 30.358 Pass: Major Risk Kuparuk 1 E Pad 1 E-33 1 E-33 V2 323.715 325.000 114.670 7.958 106.712 Pass: Major Risk Kuparuk 1 E Pad 1 E-33P61 1 E-33P61 V2 323.717 325.000 114.470 7.958 106.512 Pass: Major Risk Kuparuk 1 E Pad 1 E-35 1 E-35 V1 1030.868 1125.000 390.141 23.424 366.717 Pass: Major Risk Kuparuk 1E Pad Plan 1E-170 Plan 1E-170 L1 V1 Plan 560.979 550.000 488.198 10.223 477.975 Pass: Major Risk Kuparuk 1E Pad Plan 1E-170 Plan 1E-170 L2 V1 Plan 560.979 550.000 488.198 10.223 477.975 Pass: Major Risk Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 VO Plan: 1 560.979 550.000 488.198 10.223 477.975 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V7 12669.728 7825.000 1556.693 419.513 1137.180 Pass: Major Risk Kuparuk 1J Pad Plan 1J-158 Plan 1J-M3 Lat A V0 Out of range Kuparuk 1J Pad Plan 1J-160 Plan 1J-M2 Lat A VO 15737.497 7225.000 604.656 347.426 257.230 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 1J-162 V3 Plan: 1J-162 15612.148 7900.000 989.443 422.941 566.502 Pass: Major Risk Kuparuk 1J Pad Kuparuk 1J Pad Plan 1J-168 Plan 1J-168 1J-168 L1 V2 Plan: 1J- 1J-168 L2 V1 Plan: 1J- 15030.628 15172.373 7200.000 7050.000 1554.412 572.413 1558.902 573.271 981.999 985.630 Pass: Major Risk Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 V1 Plan: 1J-168 15030.628 7200.000 1554.412 572.413 981.999 Pass: Major Risk Kuparuk River Unit N KUP 34-11-10-1 KUP 34-11-10-1 V1 15265.356 3600.000 1196.790 626.433 570.357 Pass: Major Risk Non-Pad WSAK-03 WSAK-03 VO 10243.308 3475.000 839.450 423.258 416.192 Pass: Major Risk Site: Kuparuk 1E Pad Well: 1 E-112 Rule Assigned: Major Risk Wellpatb: 1E-112 V1 Inter-Site Error: 0.000 ft Reference Offset Semi-Ma}or Axis Ctr-Ctr No-Co Allowable MD TVR MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ~GRF k CemCADE Preliminary Job Design 13 3/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: CPAI. Revision Date: 2/15/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 120' MD < Base of Permafrost at 2,052' MD (1,529' TVD) Sdd~nnber~er Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 4,387' MD. Lead Siurrv Minimum pump time: 340 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (120') x 1.00 (no excess) = 122.3 ft3 0.4206 ft3/ft x (2052' - 120') x 3.50 (250% excess) = 2844.1 ft3 0.4206 ft3/ft x (4387' - 2052') x 1.35 (35% excess) = 1325.8 ft3 122.3 ft3 + 2844.1 ft3+ 1325.8 ft3 = 4292.2 ft3 4292.2 ft3 / 4.45 ft3lsk = 964.5 sks Round up to 970 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 0.4206 ft3/ft x (5387' - 4387') x 1.35 (35% excess) = 567.8 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 567.8 ft3 + 66.5 ft3 = 634.3 ft3 634.3 ft3/ 2.52 ft3/sk = 251.7 sks Round up to 260 sks BHST = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (min) < Top of Tail at 4,387' MD < 13 3/8", 72.0# casing in 16" OH TD at 5,387' MD (2,379' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 Drop bottom plug 0.0 0.0 5.0 33.3 ASL 7.0 764.4 109.2 142.5 DeepCRETE 5.0 113.0 22.6 165.1 Drop top plug 0.0 0.0 5.0 170.1 Water 5.0 20.0 4.0 174.1 Switch to rig 0.0 0.0 5.0 179.1 Mud 7.0 750.9 107.3 286.4 Slow & bump plug 3.0 15.0 5.0 291.4 MUD REMOVAL Recommended Mud Properties: 8.8 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 2 per joint on the shoe track, and 1 '/2 through the tail slurry. ~~~ CemCADE Preliminary Job Design 9 5/8" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Ciient: CPAI Revision Date: 2/15/2005 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 13 3/8", 72.0# casing at 5,387' MD < Top of Tail at 6,100' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 10,495' MD (3,533' TVD) S61~Wf1~6P9@P Volume Calculations and Cement Systems Volumes are based on 30% excess. Tail slurry is designed for 500' MD above Top of the Ugnu C - (4395' MD annular length). Tail Slurry Minimum thickening time: 280 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.3132 ft3/ft x 4395' x 1.30 (30% excess) = 1789.5 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1789.5 ft3 + 34.1 ft3 = 1823.6 ft3 1823.6 ft3/ 2.26 ft3/sk = 806.9 sks Round up to 810 sks BHST = 77°F, Estimated BHCT = 68°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl- (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 6.0 40.0 6.7 29.7 DeepCRETE 6.0 324.8 54.1 83.8 Drop top plug 0.0 0.0 5.0 88.8 Water 5.0 20.0 4.0 92.8 Switch to Rig 0.0 0.0 5.0 97.8 Mud 7.0 754.7 107.8 205.6 Slow & bump plug 3.0 15.0 5.0 210.6 MUD REMOVAL Recommended Mud Properties: 9 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 19-22, Ty ? 22-29 Centralizers: Recommend 2 tandem rise bow centralizers per joint on the shoe track and 1 tandem rise through the lateral areas. t ~' ConocoRhillips !~'~aska 1E-117 1!4 Mile at Heel 1E-166, 1E-166, tE-166 V1 1 E-117 1 /4 Mile at Toe 1E-117 00 ~~ ~ 000 ~ ' Ku(~34-11-10-1, 34-11-10, 34-11-10 V2 1J-10, 1J-10, 1J-10 V7 0000 /~ x 1 E-112, 1 E-112, 1 E-112 V1 1 E-35, 1 E-35, 1 E-35 V1 1 /4 Mile Radius - 1 E-117 (wp04) 2°0° \~~~ 3-D view portraying existing wells ° ~ ~~ 0 ~~o `moo °o ~~ o0 SOD ~° O 00 • '+.,.~ S. 3242 3342 3192 3242 3292 3342 3392 3342 3392 3442 -10 c a~ 0 0 0 .c ~ -11 r 0 -12 •1 -1 31 3292 I ~ ~`1i1vt~~~' 3442 3492 3492 3492 3492 3442 3442 3442 Underneath 1 E- 117 3442 Circles of 3492 1320' Radius 3392 1E-117 1/4 Mile Scan 3192' TVD - 3542' TVD 3442 3342 3542 3392 1J-10 Extends Underneath 1 E- 117 92 See 3-D view 3492 a,,y 3342 ^~~,ti~ogti ^~ 3442 3392 ~~~~ 3292 3242 3192 3242 3242 3292 Plan 1J-162 3342 Pla ~~~ 3392 -1000 0 1000 2000 3000 4000 West(-)/East(+) [1000ft/in] • • 1 E-117 Drilling Hazards Summary_ 16" Open Hole / 13 3/8" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 12 1/4" Open Hole / 9 5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Stuck Pipe Low Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 8 1/2" Open Hole / 5 1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnorma{ Reservoir Low Stripping drills, Shut-in drills, Increased Pressure mud wei ht. Stuck Pipe Low Good hole cleaning, PWD Tools, Hole O ener, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo ,LCM Hole Swabbing on Trips Low Trip speeds, Proper hole filling (use of trip sheets , Pum in out 1E-114 Drilling Hazards Summary prepared by Steve Shultz 1/31/2005 1:30 PM SHARON K. ALLSUP-DRAKE 1092 CONOCOPHILLIPS ATO 1530 ~$-- 700 G ST. ~ ~`~ ANCHORAGE AK 99501 DATE 62-14/311 PAY TO THE ~~~! ~ ~/ ~~C ORDER OF G ~/L ~' l .~ /~/' C..C_ D (~ . vlJ ~~ ~ARS L7J ~a~,'~„,M. ® ' CHASE Chase Manhattan BanN USA, N.A. I00 White Cla Cen[er Dr Newark DE 19171 Vat(d Up TO 500o DO~IdfS r y ., . 'k/~~ // / /~/, ' MEMO (/ i / LA ~/~L Y'~ f ~ ~; x:03 L L00 ~44~: 2 L84 7 190 79 2 76ii' L09 2 ~ ~ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K/ZGL /E-//7 PTD# Zo ~ -o .Development Exploration Service Stratigraphic CHECK WHAT ADD-OHS "CLUE"• APPLIES OPTIONS • MULTI The permit is for a new wellbore ~segmeni of LATERAL existing well Permit No, ~ API No. (lf API number Production. should continue to be reported as last two. (2) digits a funciion'of the original API number stated are between 60-69) above. PILOT DOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired, for the pilot • bole must be clearly differentiated 'in both name (name on permit plus P]EI) and API number (50 - 70/80) from records, data and logs acquired • !or well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Hamel assumes ibe liability of any • protest to the spacing ,exception that may occur. . DRY DITCH ~ All dry ditch sample sets submiried to ibe SAMPLE Commission muse be in no greater than 30' • sample intervals from below ibe permafrosd • or from where samples are first cangbt and ] 0' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490150 Well Name: KUPARUK RIV U WSAK 1E-117 Program SER Well bore seg ^ PTD#:2050260 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER 1 PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_feeatkached___-__--__-_-___--_--_-_-__-_____,-_ Yes_ ----------------_-_ ----------------------------------------------------- 2 Lease number appropriate_ _ _ , Yes . . _ . _ Surface Loc in ADL 025651, top_Prod Inte[val_and TD in ADL 025$60, - _ - . , 3 Uniquewell_nameandnumbe[.__..-____________ .................. Yes- -----_ -------------------------------------------------------------------- 4 Well located in a-defined-pool _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ - - _ - Yes _ _ _ _ - - _ KRU West Sak Oil Pool, governed-by Conservation-OrdertJo, 406B_ _ _ _ _ - _ _ - , _ _ - _ _ _ - - _ _ . _ 5 Well located proper distance from drilling unit_boundary_ - - - - - - Yes - _ - - Well is more than_ 500 feet from an external property line.. - . _ - --------------------------- 6 Well located proper distancef[om otherwells- - _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . - No rest[ictions as_to well spacing in CO-4.068 - _ _ . _ _ , - - _ _ _ - _ _ - _ _ _ _ _ - - - _ „ _ _ 7 Sufficient acreageayail_ablein_drillinqunit--___.---._-_-__-___..--.--_. Yes_ _____________________ ------------------------------------------------- 8 If deviated, iswellbore plat_included - - - - - Yes - - - - - - - - 9 Operator only affected party_____-_--------------------- -.--.. Yes- --------------- ---- ---------------------------------------------------- 10 OperatoChas.appropriatebondinforce ------ ---- - ------ - Yes- - -- -- -- -------- -- --- -- -- -- --- -- ----- -- ------- -- - 11 Permit_canbeissuedwithoutconseruationorder_____---_._ Yes_ -____---_,___________________ _ Appr Date 12 Permit can be issued without administraiive_appr_oval _ _ _ - - _ - _ „ - Yes - . _ - - _ - - - - - - SFD 2!2312005 13 Can permit be approved before 15-day wait Yes 14 WeN located within area and strata authorized by_Injection Order # (put1O# in_comments)_(For Yes .. Area Injection Order No._26, _ - _ _ , . 15 Allwells-within 1/4_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ . Kup_34-11,10l1,1E•166 +.Iaterals,1E112 ± laterals, 1J-160,1 J•162,1J-1Q 1 E-35 - - . _ - _ - _ _ _ . , - - . - . _ - 16 Pre-produced injector: duration of pre-pCOduction less than_ 3 months. (For_service well only) - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - ~ - - 17 ACMP-Finding of Consistency-h_aSbee_nissued_fo[thisproject_.--___-_____-_ _- NA- __________-__--_________________ --------------------------------------- Engineering 18 Conductor string_provided - - - - - - _ - Yes - - - - 19 Surface casing_p_rotectsall-known,USDWS___________________________ ___ NA._ __--__Allaquifersexempted,40CFR_147.102~b)(3).__.__--_..__,___-_- _--____---__-__- __ 20 CMT_vol_adequate_tocircul_ateon,conductor&surfcsg--_._-___-__--___-__.__ Yes_ _____-___-___-___ - - 21 CMT_vol adeguate_to tie-in long string tosurf osg- - - - - - - -- - - - - - - - - -- - - -- No. _ All hydrocarbon zones will be_covered, _ _ , 22 CMT_willcoverallknownproductivehorizons--_____________________ _____ No_- -____Slottedlinercompletionplanned.-_--___--__-,-_,-__-_-_-___--_____--___ 23 Casing designs adequate fo[ C, T, B &_pe[mafrost - - - - Yes - - - - - 24 Adequate tankage_or reserve pit _ - _ - Yes - _ - - - -Rig is_equipped with steel-pits, no reserve pit planned. _All wasteto approved annulus or Class II well. 25 If a. re-drill, hasa-10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ NA_ - _ _ _ _ _ _ - - - - -- - - 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - . - - Proximit analysisperformed and close approaches identified.. Traveling_cylinder path_calculated•_ - - - _ - _ - - - - 27 Ifdiverterrequired,doesitmeetregu_latioos-_--------------------.----- Yes- --.----------------------------------------------------------- Appr Date 28 Drillingfluid-program schematic & equip IiSt adequate_ - _ - - - - _ _ _ _ Yes - _ .. Maximum expected formation pressure 9,0-EMW._ Planned _MW 9.Oppg in West Sak- - - - - - - - - - - - - - - - - - TEM 2124/2005 29 BOPES,.do they meet_regulation - - - - - - - Yes - - ~~ 30 BOPE_press rating appropriate; test t_o_(put prig in.comments).. - - .. - - .. - - - Yes - - - - - - - _ .. MASP calculated at 11.61 psi. 3000_psi-appropriate, CPAI_ normally tests to 5000 psi._ . , - - - - - 31 Choke_manifold comp_lieswlAPl_RP-53 Qutay84)_ _ . - _ _ Yes - . _ . - - - - - . . -- --- ------ 32 Work will occur without operatjonshutdown_______________,_-_-_-_- _---_ Yes_ ._---__,___-________ ---------------------------------------------------- 33 Is presence of H2S gas probable - - -- - - - - - - - - -- - - - - - - - - - - - - - -- - Yes H2S has been seen in 1E WS wells, Mud shouldpreclude H2S on rig. Rig has sensorsand alarms, - - . _ - 34 Mechanical condition of wells within AOR verified (Fo[se[vice well only) - - - - Yes - - - - 34-1-10-1 (188-158) is only penetration- in AOR, File review indicztes-well is-properly P&A_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Pe[mit_can be issued wlo hydrogen_sulfiderneasures - - - - - - - - - .. - No_ - _ - _ - KRIt 1E-Pad West Sak wells measured from 22 to 76 ppm H2S in 2004. _ - , - - - - - - _ - 36 Data_presented on potential overpressure zones . - _ - - - - - - - - - - - - - - - Yes _ - - - - Expected cesen!oirpressure is 8,6_- 9,0_ppg EMW; will_be drilled wfih $.6 - 9.Oppg mud. - _ _ _ - - Appr Date 37 Seismiccanalysis_ofshallowgas-zones_._-_____________________________ NA__ __-___-___-______ ------------------------------------------- --- - SFD 212312005 38 Seabed condition survey_(if off_-shore) - - _ _ , - , _ , _ - - , _ _ - _ - NA - -- -- ------ - - 39 -Contact name/phone for_weekly progress_reports [exploratory only]_ _ - NA_ _ _ - - - Geologic Engineering lic Commissioner. Date: Commissioner: Date 'oner D e ~~ ~l ~~~ ~ a,(~ • • C: 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 rending information, information of this nature is accumulated at the end of the file under APPENDIX. No special efforl has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 16 10:12:33 2005 Reel Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/11/16 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: MWD RUN 4 MW0003775114 P. ORTH D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.500 3RD STRING PRODUCTION STRING ~ i3~2~ a0~ O a-Cv Scientific Technical Services Scientific Technical Services 1E-117 500292325100 ConocoPhillips Alaska, Inc. Sperry Drilling Services 15-NOV-05 MWD RUN 5 MWD RUN 6 MW0003775114 MW0003775114 P. ORTH J. MARTIN D. GLADDEN D. GLADDEN 16 11 10 11 228 94.90 66.90 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 5543.0 9.625 10572.0 REMARKS: • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 1E-117 PBl AT 10850'MD/3514'TVD BY MEANS OF AN OPENHOLE SIDETRACK. 4. MWD RUNS 1 - 3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 4 - 6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUNS 5 & 6 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 6 REPRESENT WELL 1E-117 WITH API#: 50-029-23251-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15774'MD/3415'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 - 9.1 PPG MUD SALINITY: 41500 - 47500 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header • • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH FET 5517.0 15731.0 RPX 5517.0 15731.0 RPS 5517.0 15731.0 RPM 5517.0 15731.0 RPD 5517.0 15731.0 GR 5524.5 15739.0 ROP 5560.5 15774.0 NPHI 10492.5 15684.5 FONT 10492.5 15684.5 NCNT 10492.5 15684.5 CALA 10495.0 15688.0 RHOB 10505.5 15698.5 PEF 10505.5 15698.5 DRHO 10505.5 15698.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 4 5517.0 10580.0 5 10580.0 10850.0 6 10850.5 15774.0 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 • • RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 15774 10645.5 20515 5517 15774 ROP MWD FT/H 1.15 431.57 197.64 20428 5560.5 15774 GR MWD API 27.74 132.01 76.8668 20430 5524.5 15739 RPX MWD OHMM 1.76 2000 14.8032 20429 5517 15731 RPS MWD OHMM 2.81 2000 15.8018 20429 5517 15731 RPM MWD OHMM 3.94 1835.59 17.4073 20429 5517 15731 RPD MWD OHMM 1.02 2000 21.1786 20429 5517 15731 FET MWD HOUR 0.13 106.37 1.37905 20429 5517 15731 NPHI MWD PU-S 16.95 44.54 36.8536 10385 10492.5 15684.5 FCNT MWD CNTS 655 2480 900.689 10385 10492.5 15684.5 NCNT MWD CNTS 114652 180491 133485 10385 10492.5 15684.5 RHOB MWD G/CM 0.235 2.706 2.18453 10387 10505.5 15698.5 DRHO MWD G/CM -2.819 0.193 0.00803649 10387 10505.5 15698.5 PEF MWD BARN 0.91 13.06 2.20234 10387 10505.5 15698.5 CALA MWD INCH 8.42 9.92 8.87947 10387 10495 15688 First Reading For Entire File..........5517 Last Reading For Entire File...........15774 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5517.0 10536.0 . • RPS 5517.0 10536.0 RPM 5517.0 10536.0 RPD 5517.0 10536.0 FET 5517.0 10536.0 GR 5524.5 10543.5 ROP 5560.5 10580.0 LOG HEADER DATA DATE LOGGED: O1-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10580.0 TOP LOG INTERVAL (FT) 5560.0 BOTTOM LOG INTERVAL (FT) 10580.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 83.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 5543.0 BOREHOLE CONDITIONS MUD TYPE: Water Based MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S) 63.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 140 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 4.000 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.770 97.0 MUD FILTRATE AT MT: 3.400 65.0 MUD CAKE AT MT: 3.000 65.0 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 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 10580 8048.5 10127 5517 10580 ROP MWD040 FT/H 1.15 430.52 214.067 10040 5560.5 10580 GR MWD040 API 27.74 132.01 74.5101 10039 5524.5 10543.5 RPX MWD040 OHMM 1.76 1345.45 12.9053 10039 5517 10536 RPS MWD040 OHMM 3.06 1234.97 14.9616 10039 5517 10536 RPM MWD040 OHMM 4.81 1835.59 16.9384 10039 5517 10536 RPD MWD040 OHMM 4.99 2000 20.4694 10039 5517 10536 FET MWD040 HOUR 0.14 89.37 1.21598 10039 5517 10536 First Reading For Entire File..........5517 Last Reading For Entire File...........10580 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10492.5 10850.0 FCNT 10492.5 10850.0 NCNT 10492.5 10850.0 CALA 10495.0 10850.0 RHOB 10505.5 10850.0 PEF 10505.5 10850.0 DRHO 10505.5 10850.0 RPD 10536.5 10850.0 r, ~J • FET 10536.5 10850.0 RPS 10536.5 10850.0 RPX 10536.5 10850.0 RPM 10536.5 10850.0 GR 10544.0 10850.0 ROP 10580.5 10850.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10850.0 TOP LOG INTERVAL (FT) 10580.0 BOTTOM LOG INTERVAL (FT) 10850.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 185457 ASLD Azimuthal Litho-Den 728188 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10572.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 73.0 MUD PH: •0 MUD CHLORIDES (PPM): 45000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 119.9 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............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 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWDO50 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 CALA MWD050 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10492.5 10850 10671.3 716 10492.5 10850 ROP MWD050 FT/H 2.12 3 74.41 248.739 540 10580.5 10850 GR MWD050 API 53.92 96.18 71.9842 613 10544 10850 RPX MWD050 OHMM 4.85 2000 44.0032 628 10536.5 10850 RPS MWD050 OHMM 4.66 2000 49.8758 628 10536.5 10850 RPM MWD050 OHMM 4.64 18 09.23 57.7935 628 10536.5 10850 RPD MWD050 OHMM 1.02 2000 118.675 628 10536.5 10850 FET MWD050 HOUR 0.13 1 06.37 15.9027 628 10536.5 10850 NPHI MWD050 PU-S 22.47 44.45 36.3302 716 10492.5 10850 FCNT MWD050 CNTS 677 1502 849.282 716 10492.5 10850 NCNT MWD050 CNTS 114652 1 60418 129628 716 10492.5 10850 RHOB MWD050 G/CM 0.235 2.634 2.08515 690 10505.5 10850 DRHO MWD050 G/CM -2.819 0.171 -0.183319 690 10505.5 10850 PEF MWD050 BARN 1.32 13.06 3.55597 690 10505.5 10850 GALA MWD050 INCH 8.42 9.6 8.82495 711 10495 10850 First Reading For Entire File..........10492.5 Last Reading For Entire File...........10850 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 10850.5 15731.0 CALA 10850.5 15688.0 GR 10850.5 15739.0 RPS 10850.5 15731.0 RPM 10850.5 15731.0 RPD 10850.5 15731.0 FET 10850.5 15731.0 FONT 10850.5 15684.5 NCNT 10850.5 15684.5 RHOB 10850.5 15698.5 PEF 10850.5 15698.5 DRHO 10850.5 15698.5 NPHI 10850.5 15684.5 ROP 10850.5 15774.0 LOG HEADER DATA DATE LOGGED: 09-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 15774.0 TOP LOG INTERVAL (FT) 10850.0 BOTTOM LOG INTERVAL (FT) 15774.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.0 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 185457 ASLD Azimuthal Litho-Den 728188 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10572.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 73.0 MUD PH: •0 MUD CHLORIDES (PPM): 42000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 134.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............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 C: DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 CALA MWD060 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10850.5 15774 13312.3 9848 10850.5 15774 ROP MWD060 FT/H 1.16 4 31.57 178.092 9848 10850.5 15774 GR MWD060 API 44.26 1 10.28 79.5925 9778 10850.5 15739 RPX MWD060 OHMM 5.04 2000 14.8766 9762 10850.5 15731 RPS MWD060 OHMM 2.81 1 34.59 14.4738 9762 10850.5 15731 RPM MWD060 OHMM 3.94 61.72 15.2915 9762 10850.5 15731 RPD MWD060 OHMM 5.86 69.95 15.636 9762 10850.5 15731 FET MWD060 HOUR 0.15 20 0.612431 9762 10850.5 15731 NPHI MWD060 PU-S 16.95 44.54 36.8924 9669 10850.5 15684.5 FCNT MWD060 CNTS 655 2480 904.496 9669 10850.5 15684.5 NCNT MWD060 CNTS 115427 180491 133771 9669 10850.5 15684.5 RHOB MWD060 G/CM 1.447 2.706 2.1916 9697 10850.5 15698.5 DRHO MWD060 G/CM -0.156 0.193 0.0216526 9697 10850.5 15698.5 PEF MWD060 BARN 0.91 7.3 2.10602 9697 10850.5 15698.5 GALA MWD060 INCH 8.51 9.92 8.88347 9676 10850.5 15688 First Reading For Entire File..........10850.5 Last Reading For Entire File...........15774 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 r File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library Writing Library .7 Scientific Technical Services Scientific Technical Services End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revisioh: 3 $ LisLib $Revision: 4 $ Wed Nov 16 15:56:57 2005 Reel Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/11/16 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: MWD RUN 4 MW0003775114 P. ORTH D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.500 3RD STRING PRODUCTION STRING 9~-/q 205 -oaf Scientific Technical Services Scientific Technical Services 1E-117 PB1 500292325170 ConocoPhillips Alaska, Inc. Sperry Drilling Services 16-NOV-05 MWD RUN 5 MW0003775114 P. ORTH D. GLADDEN 16 11 10 11 228 94.90 66.90 CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 5543.0 9.625 10572.0 REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 3 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 4 & 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 5 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL) . 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 - 5 REPRESENT WELL 1E-117 PBl WITH API#: 50-029-23251-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11593'MD/3506'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE LITHOLOGY, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 - 9.1 PPG MUD SALINITY: 42000 - 49000 PPM CHLORIDES FORMATION WATER SALINITY: 11000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 5517.0 11550.0 RPS 5517.0 11550.0 RPM 5517.0 11550.0 RPD 5517.0 11550.0 FET 5517.0 11550.0 GR 5524.5 11558.0 ROP 5560.5 11593.0 NCNT 10492.5 11504.0 FCNT 10492.5 11504.0 NPHI 10492.5 11504.0 CALA 10495.0 11507.0 RHOB 10505.5 11517.5 DRHO 10505.5 11517.5 PEF 10505.5 11517.5 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 4 5517.0 10580.0 MWD 5 10580.0 11593.0 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 GALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 11593 8555 12153 5517 11593 ROP MWD FT/H 1.15 430.52 211.839 12066 5560.5 11593 GR MWD API 27.74 132.01 75.2322 12068 5524.5 11558 RPX MWD OHMM 1.76 2000 15.2793 12067 5517 11550 RPS MWD OHMM 3.06 2000 17.3231 12067 5517 11550 RPM MWD OHMM 4.64 1835.59 20.2757 12067 5517 11550 RPD MWD OHMM 1.02 2000 26.2357 12067 5517 11550 FET MWD HOUR 0.13 106.37 1.89955 12067 5517 11550 NPHI MWD PU-S 22.47 44.45 35.4219 2024 10492.5 11504 FCNT MWD CNTS 677 1502 908.42 2024 10492.5 11504 NCNT MWD CNTS 114652 160418 133398 2024 10492.5 11504 RHOB MWD G/CM 0.235 2.793 2.19285 2025 10505.5 11517.5 DRHO MWD G/CM -2.819 0.212 -0.0466346 2025 10505.5 11517.5 PEF MWD BARN 1.3 13.06 2.6801 2025 10505.5 11517.5 CALA MWD INCH 8.42 9.6 8.81764 2025 10495 11507 First Reading For Entire File..........5517 Last Reading For Entire File...........11593 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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 BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH RPX 5517.0 RPS 5517.0 FET 5517.0 RPD 5517.0 RPM 5517.0 STOP DEPTH 10536.0 10536.0 10536.0 10536.0 10536.0 GR 5524.5 ROP 5560.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) O1-JUL-05 Insite 66.37 Memory 10580.0 5560.0 10580.0 70.6 83.7 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 10543.5 10580.0 12.250 5543.0 Water Based 9.30 63.0 9.0 140 4.8 4.000 65.0 2.770 97.0 3.400 65.0 3.000 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 10580 8048.5 10127 5517 10580 ROP MWD040 FT/H 1.15 430.52 214.067 10040 5560.5 10580 GR MWD040 API 27.74 132.01 74.5101 10039 5524.5 10543.5 RPX MWD040 OHMM 1.76 1345.45 12.9053 10039 5517 10536 RPS MWD040 OHMM 3.06 1234.97 14.9616 10039 5517 10536 RPM MWD040 OHMM 4.81 1835.59 16.9384 10039 5517 10536 RPD MWD040 OHMM 4.99 2000 20.4694 10039 5517 10536 FET MWD040 HOUR 0.14 89.37 1.21598 10039 5517 10536 First Reading For Entire File..........5517 Last Reading For Entire File...........10580 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10492.5 11504.0 FCNT 10492.5 11504.0 NCNT 10492.5 11504.0 CALA 10495.0 11507.0 RHOB 10505.5 11517.5 DRHO 10505.5 11517.5 PEF 10505.5 11517.5 FET 10536.5 11550.0 RPX 10536.5 11550.0 RPS 10536.5 11550.0 RPD 10536.5 11550.0 RPM 10536.5 11550.0 GR 10544.0 11558.0 ROP 10580.5 11593.0 LOG HEADER DATA DATE LOGGED: 06-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11593.0 TOP LOG INTERVAL (FT) 10580.0 BOTTOM LOG INTERVAL (FT) 11593.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.5 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 66259 CTN COMP THERMAL NEUTRON 185457 ALD Azimuth. Litho-Den 10507541 ACAL Acoustic Caliper 728188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 10572.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 73.0 MUD PH: •0 MUD CHLORIDES (PPM): 45000 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 119.9 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............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 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 NPHI MWD050 PU-S 4 1 68 28 8 FCNT MWD050 CNTS 4 1 68 32 9 NCNT MWD050 CNTS 4 1 68 36 10 RHOB MWD050 G/CM 4 1 68 40 11 DRHO MWD050 G/CM 4 1 68 44 12 PEF MWD050 BARN 4 1 68 48 13 CALA MWD050 INCH 4 1 68 52 14 FET MWD050 HOUR 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10492.5 11593 11042.8 2202 10492.5 11593 ROP MWD050 FT/H 2.12 3 74.41 200.799 2026 10580.5 11593 GR MWD050 API 51.36 115.2 78.8051 2029 10544 11558 RPX MWD050 OHMM 4.85 2000 27.0311 2028 10536.5 11550 RPS MWD050 OHMM 4.66 2000 29.0128 2028 10536.5 11550 RPM MWD050 OHMM 4.64 18 09.23 36.7962 2028 10536.5 11550 RPD MWD050 OHMM 1.02 2000 54.7799 2028 10536.5 11550 NPHI MWD050 PU-S 22.47 44.45 35.4219 2024 10492.5 11504 FCNT MWD050 CNTS 677 1502 908.42 2024 10492.5 11504 NCNT MWD050 CNTS 114652 1 60418 133398 2024 10492.5 11504 RHOB MWD050 G/CM 0.235 2.793 2.19285 2025 10505.5 11517.5 DRHO MWD050 G/CM -2.819 0.212 -0.0466346 2025 10505.5 11517.5 PEF MWD050 BARN 1.3 13.06 2.6801 2025 10505.5 11517.5 CALA MWD050 INCH 8.42 9.6 8.81764 2025 10495 11507 FET MWD050 HOUR 0.13 1 06.37 5.28335 2028 10536.5 11550 First Reading For Entire File..........10492.5 Last Reading For Entire File...........11593 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Scientific Technical Services Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File