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Home My WebLink About205-062 • Carlisle, Samantha J (DOA) 1>Th ao5extiab From: Loepp,Victoria T(DOA) 1 zr- " 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, 1J-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) Regards, SCANNED John Peirce SCAT NED FEB 0 ZL1l 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 i w 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 of T� • • 9w\�\ 1//74' THE STATE Alaska Oil and Gas �� vfA TT ccKA. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 LAr-a' o 1°- Fax: 907.276.7542 www.aogcc.alaska.gov John W. Peirce SCA" SEP 2' 8 2016 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-168L2 Permit to Drill Number: 205-062 Sundry Number: 316-275 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, (Pg ,u`N Cathy . Foerster Chair DATED this Z day of May, 2016. RBDMS IA, MAY 3 1 2016 ii ....41% Yfiw! B6 'RR 0 STATE OF ALASKA • MU 1 9 ZOib ALASKA OIL AND GAS CONSERVATION COMMISSION 5-(z Sp(e> APPLICATION FOR SUNDRY APPROVALS ACI : 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations E Fracture Stimulate E Repair Well w�. Operations Shutdown Suspend E Perforate E Other Stimulate E Pull Tubing EChange Approved Program E Plug for Redrill rj, Perforate New Pool r Re-enter Susp Well la Alter Casing E Other: Crystal Seal MBE Trmt F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory F Development F • 205-062 ` 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service 50-029-23260-61 , 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 1— No 8" ✓ KRU 1J-168L2 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25660 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVDO MPSP(psi): Plugs(MD): Junk(MD): 12,959' 3,424' 11898 3f3 -33./3 970 Casing Length Size MD ND Burst Collapse Structural Conductor 54' 16" 80' 80' Surface 3,664' 18" 3,694' 2,116' Intermediate 8,198' 75/8 8,224' 3,466' D Sand Liner 6,163' 4 1/2 12,943' 3,424' Pgrfor ltionlDDepthMD(ft): t Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8471uug1'Og42iS-11911 3477-3534 4.500" L-80 6,731' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-4.5 ER WFD UPPER PACKER , MD=6200 TVD=3050 PACKER-4.5 ER WFD LOWER PACKER • MD=6222 TVD=3058 PACKER-HRD ZXP Liner Top Packer MD=7097 TVD=3286 SSSV: NONE MD=7246 TVD=3311 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory E Stratigraphic E Development F Service 14.Estimated Date for 5/26/2016 15.Well Status after proposed work: Commencing Operations: OIL 17 WINJ E WDSPL fl Suspended I- 16.Verbal Approval: Date: GAS E WAG EGSTOR SPLUG Commission Representative: GINJ E Op Shutdown r Abandoned E 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 "4. t P — 5/12 /Z0/6 Signature Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 c.e. - 2"i Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No Lh Spacing Exception Required? Yes ❑ No 51 Subsequent Form Required: /0 — 4-a / RBDMS L�/ MAY 3 1 1C 16 n APPROVED BY Approved by: / THE COMMISSION Date:.5-"'477/6and Form U-403 R. sed 1 D1b Rp`r INACCISSIONER ua for 14 mons fr to aate of appr.val. Attachments in Duplicate VT- 5//Ssl/L 9i& $T i�f/s- s-4'67�- KUPOD 1J-16822 Conoco-Phillips .: 8,D= Well Attribulgir Max Anglik1D TD Alamo Inc Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) CoocoPh06ps 500292326061 WEST SAK PROD 93.08 7,079.36 12,959.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date 1J-168L2,5112/20162:4410 PM SSSV:NIPPLE 60 12/16/2013 Last WO: 9/10/2008 31.01 9/26/2005 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'SLM 7,067.0 12/12/2013 Rev Reason'SET PATCH lehalif 2/2/2015 £r,.' Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread D-SAND LINER 4 1/2 3.958 6,780.5 12,942.7 3,423.9 12.60 L-80 IBT Liner Details Nominal ID iH. d[ Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) 6,780.5 3,213.3 75.05 HANGER 1 Baker Mod.B1 Flanged Hk Hng outside casing 5.660 111 window 6,796.9 3,217.4 75.77 HANGER 2 Baker Mod.B1 Flanged Hk Hng outside casing 3.980 window 12,911.5 3,422.7 87.75 XO Reducing 4-1/2"IBT Box x 3-1/2"IBT Pin XO Sub 2.97"ID 2.992 _CONDUCTOR Insulated,26eo.o.0- ,, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl _ Top(ftKB) (ftKB) C) Des Com Run Date ID(in) NIPPLE;499.7 7,158.0 3242.3 89.92 SLEEVE SET ISO SLEEVE ACROSS THE B LAT(OAL 19') 11/17/2014 2.500 /' Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btu)(ftKB) (ftKB) (ftKB) Zone Date R) Type Com SURFACE 30.0-3,893.9 6,811.0 10,721.0 3,220.8 3,324.5 WS D,1J- 9/22/2005 32.0 SLOTS ALL SLOTS:Alternating 168L2 sloped/solid pipe 0.125" x2.5"x32spf@ 4 Circumferential adjacent rows,3"Centers GAS LIFT,4,210.6 C''' staggered 18 deg.,3 ft. non-slotted ends 10,845.0 12,912.0 3,327.1 3,422.8 WS D,1J- 9/22/2005 32.0 SLOTS 168L2 Notes:General&Safety PACKER,6,200.0 0,810.0 End Date Annotation 9/26/2005 NOTE.MULTI-LATERAL WELL:1J-168(A-SAND),1J-168L1(B-SAND),1J-168L2(D-SAND) GAS LIFT;6,203.2 9/16/2008 NOTE:View Schematic w/Alaska Schematic9.0REV I PACKER,6,222.0 NIPPLE,6,649.1 GAUGE,6,650.6 r LOCATOR;6,702.8MB _ INV (°may IMI SEAL ASSY;6,703.9 11 f INTERMEDIATE;28.3-8,224.0 D LINER LEM,6,706.8-7,1280 11 I SLEEVE;7,158.0 :US1I SLOTS;6,811.0-10,721.0 -1 SLOTS,10,845 0-12,912.0 t 0 D-SAND LINER,6.780.5- 1 12 0427 • • 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 1 J-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 simultaneouslystart pumping 1,2,4 p ), 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 1J-168. JWP 5/12/2016 • • Bettis, Patricia K (DOA) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Monday, May 16, 2016 7:31 AM To: Bettis, Patricia K (DOA) Cc: Haggerty-Sherrod, Ann (Northland Staffing Services) Subject: RE: KRU 1J-168L2 (PTD 205-062): Sundry Application Patricia, Your records are correct. The perf depth information as listed in your email, and on the well schematic (attached to 10- 403) are correct. John Peirce Sr Wells Engr CPAI Drilling &Wells (907)-265-6471 office From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, May 13, 2016 1:42 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]KRU 1J-168L2 (PTD 205-062): Sundry Application Good afternoon John, Please verify perforation/slot depths for KRU 1J-168L2. The AOGCC records show 6811-10721, 10845-12912 feet MD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspect/ion of the file. ~- ~ Ip ~. Well History File Identifier Organizing (done) ..~„d~ iiumiiiuiiuui a.s~,~~~ded iuuiiii~iiiiuu RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ^ Logs of various kinds: NOTES: BY: aria Date: ~ D ^ Other:: /s/ Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ ~ /s/ Scanning Preparation ~ x 30 = ~~ + ~ =TOTAL PAGES ' (Count does not include cover sheet) BY: Maria Date: I I ~ ~ I ,~, ~/ ls/ ~/ V 1 Production Scanning Stage 1 Page Count from Scanned File: _~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~' f /~~~~ i'J /sl Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO DIGITAL DATA iskettes, No. ~.,, ^ Other, NolType: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II III IIlII I I I!I ReScanned III(I'II)I'III (IIII Maria Date: /s/ Comments about this file: a~„„~~~.~ iuiumiiiimm 10/6/2005 Well History File Cover Page.doc ~~ 0~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050620 Well Name/No. KUPARUK RIV U WSAK 1J-168L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23260-61-00 MD 12959 TVD 3425 Completion Date 9/26/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes '`r DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Informat ion: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey '1~ED D Asc Directional Survey ~' ED D Lis 13446 " ~nduction/Resistivity ~pt Lis 13446 LIS Verification ~ ~Rp t 13445 LIS Verification /QED D Lis 13445 ~(nduction/Resistivity I ~.%ED C Lis 15030 ~nduction/Resistivity ~D C Li 3 i s 150 Induct on/Resistivit Y Well Cores/Samples Information: Interval Name Start Stop (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run Scale Media No Start Stop OH / CH Received Comments 8625 12959 Open 11/17/2005 Definitive 6731 9435 Open 11/17/2005 PB 1 Definitive 3670 9377 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT PB1 3670 9377 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT PB1 3670 12901 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT 3670 12901 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT 3662 12959 Open 4/17/2007 LIS Veri, FET, GR, ROP w/Graphics PDF, EMF, CGM 3662 9435 Open 4/17/2007 P61 LIS Veri, FET, GR, ROP w/Graphics PDF, EMF, CGM Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050620 Well Name/No. KUPARUK RIV U WSAK 1J-168L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23260-61-00 MD 12959 TVD 3425 ADDITIONAL INFORMATION Well Cored? Y `(M\U Chips Received? ~i`ttd-- Analysis "('/"1V Received? Comments: Compliance Reviewed By: Completion Date 9/26/2005 Completion Status 1-OIL (Current Status 1-OIL UIC N Daily History Received? ~%' N Formation Tops ~ N __._ _-- _ ___ _ -- ---- _ Date: ~__y Uu a~ WELL LOG TRA~iSMITTAI. To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-168, L1, L2 & L2 PBl, April 16, 2007 AK-MW-3877631 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-168, 1J-168 L1,1J-168 L2 & 1J-168 L2 PBl: LIS & Digital Log Images: 50-029-23260-00, 60, 61, 70. ~~ ~~~1 ~J ~. a05=~a ~ ~S6a~ c~OS-b~ I ~ ~Soa~j aos=o~~ ~ 15o3c~ ~ l So3 I 1 CD Rom • • WELL LOG TRANSMITTAL To: State of Alaska January 26, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~o5~o~a RE: MWD Formation Evaluation Logs 1J-168 L2, ~~ 4 ~ ~... AK-MW-3877631 1 LDWG formatted Disc with verification listing. API#: 50-029-23260-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99.518 Date: - 3 Signed: • • WELL LOG TRANSMITTAL To: State of Alaska January 26, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ao5-ot~~ RE: MWD Formation Evaluation Logs 1J-168 L2 PBl, ~.~~4~ AK-MW-3877631 1 LDWG formatted Disc with verification listing. API#: 50-029-23260-70 PLEASE ACKNOWLEDGE RECEIP'T' BY SIGNING AND RE1'IIRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ! al Ofn Signed: • • 26-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-168 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,625.95' MD Window /Kickoff Survey: 8,680.00' MD (if applicable} Projected Survey: 12,959.00' 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 ,, J ~ / , Date o~ / 6~e~r ~lQn~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 26-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-168 L2 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,731.85' MD Window /Kickoff Survey: 6,784.74' MD (if applicable) Projected Survey: 9,435.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ 1 ~~/~,~ai_... Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ a S' - a G ~, ~~t STATE OF ALASKA ALASKA OIL AND GAS CONSERVA O C TI N OMMISSION ~~~ WELL COMPLETION OR RECOMPLETION REPORT AN~~~ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: t;"'"<<"'~• Development a Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: September 26, 20051 12. Permit to Drill Number: 205-062 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~'~ _A,u~ga§YtS;'~005 ,/E~ 13. API Number: 50-029-23260-61 4a. Location of Well (Governmental Section): Surface: 1841' FSL, 2499' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: /C ~ ~° ~-`' S September 20, 2005 14. Well Name and Number: 1 J-168L2 At Top Productive Horizon: 2028' FSL, 1943' FEL, Sec. 34, T11N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 2371' FNL, 1980' FEL, Sec. 27, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 11898' MD / 3373' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558712 y- 5945653 ~ Zone- 4 10. Total Depth (MD + ND): 12959' MD / 3425' TVD ° 16. Property Designation: ADL 25661 & 25660 TPI: x- 553987 y- 5945804 Zone- 4 Total Depth: x- 553895 - 5951965 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 470 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1855' MD 21. Logs Run: ' % ~jL,~G% . C-U l!-' ~~ }~~i9~11~~ ~/~ ~~1 ~l~ GR/Res, Dens/Neu _ / -~~~~'~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 163 sx AS 1 10.75" 45.5# L-80 28' 3694' 28' 2115' 13.5" 66o sx ASLite, 18o sx DeepCrete 7-5/8" 29.7# L-80 28' 8224' 28' 3472' 9-7/8" 490 sx DeepCrete 4.5" 12.6# L-80 6781' 12943' 3213' 3423' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6131' 7246' slotted liner from 6811'-10721', 10845'-12912' 13 constrictor packers 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production October 18, 2005 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1 J-168 and 1 J-168L1 Date of Test 10/21/2005 Hours Tested 4.5 hours Production for Test Period --> OIL-BBL 286 GAS-MCF 52 WATER-BBL 0 CHOKE SIZE not available GAS-OIL RATIO 210 Flow Tubing press. 241 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1477 GAS-MCF 310 WATER-BBL 1 OIL GRAVITY -API (corr) 20.8 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 ~ ~` ~ ~ i Form 10-407 Revised 12/2003 ~ ~ ! ~ ~ ~ V ~ ~ CONTINUED ON REVERSE 28: 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-168L2 West Sak D Sand 6783' 3214' Base West Sak D sand 12959' 3425' N!A 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: Pat Reilly @ 265-6048 Printed Nam Randv Thomas Title: Greater Kuoaruk Area Drilling Team Leader .-,.. i ~ ~ ~r ~~ f ' Signature .~_Phone ~ -~ - 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 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 • ConocoPhillips Alaska Page 1 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number. Date :From - To Hours Code Code ~ Phase Description of Operations 8/13/2005 16:30 - 18:30 2.00 MOVE DMOB MOVE Prep rig for move and disconnected service loops and blow down water and steam lines 18:30 - 20:00 -1.50 MOVE DMOB MOVE Staged rig complex's on 1 E pad, pipe sheds, rock washer, boilers, motors and mud pumps 20:00 - 23:00 3.00 MOVE OTHR MOVE Began to move mud pump complex off pad to access road and broke thru road, laid plywood and moved pumps to middle of road, laid add. plywood and matting boards down on road to 1 E's main road 23:00 - 00:00 1.00 MOVE MOVE MOVE Began moving complex's from 1 E to 1J pad, moving mud pumps, pits, motors and boiler complex's 8/14/2005 00:00 - 02:30 2.50 MOVE MOVE MOVE Cont to move rig's complex's from 1 E pad and spotted on 1 J pad, moved pumps, pits, motors and boilers, trucks returned to 1 E pad 02:30 - 03:00 0.50 MOVE MOVE MOVE Moved sub base off 1 E-117 03:00 - 08:00 5.00 MOVE MOVE MOVE Moved rock washer, pipe sheds and sub base 9 miles from 1 E pad and spotted on 1J pad 08:00 - 08:30 0.50 MOVE POSN MOVE Spotted sub base over well 1 J-168 08:30 - 12:30 4.00 MOVE POSN MOVE Spotted rig complex's, pits, mud pumps, motors, boilers, pipe shed and bermed rock washer and set in same 12:30 - 14:00 1.50 MOVE RURD MOVE Connected rigs service loops, got steam and water around rig and began to mix spud mud, completed rig acceptance check list and ACCEPTED RIG at 14:00 hrs 14:00 - 16:00 2.00 WELCT NUND SURFAC NU riser and knife valve onto 21 1/4"diverter 16:00 - 17:30 1.50 DRILL OTHR SURFAC Loaded pipe shed with 5" DP, HWDP and jars 17:30 - 23:00 5.50 DRILL PULD SURFAC PU and stood back 28 stds of 5" DP, 10 stds 5" HWDP and jars, 1 std of 8" NMFDC's 23:00 - 23:15 0.25 WELCT BOPS SURFAC Function tested diverter, knife valve and accumulator, NOTE:, Chuck Scheve waived witnessing of test 23:15 - 00:00 0.75 DRILL PULD SURFAC PU BHA from beaver slide to rig floor, MU 13 1/2" bit #1 onto 8" motor with 1.83 deg bend 8/15/2005 00:00 - 00:15 0.25 DRILL PULD SURFAC Fin MU float sub and XO onto motor RIH to 35' 00:15 -00:45 0.50 DRILL OTHR SURFAC Flooded conductor checking lines for leaks, pressure tested mud line and standpipe to 2,500 psi and ck ok 00:45 - 01:00 0.25 DRILL CIRC SURFAC RIH from 35' and tagged cement inside conductor at 85', cleaned out to 108' 01:00 - 03:15 2.25 DRILL DRLG SURFAC Spudded well and drilled 13 1/2" hole from 108' to 180' (72') ART 1.61 hrs 03:15 - 03:45 0.50 DRILL ' TRIP SURFAC POOH from 180' to motor at 30' 03:45 - 05:30 1.75 DRILL PULD SURFAC MU BHA #1 RIH to 163', MU MWD, oriented and uploaded same, MU UBHO sub and oriented same, RIH with 1 std of 8" NMFDC's to 163' 05:30 - 06:15 0.75 DRILL SURV SURFAC Ran Sperry Suns surface read out Gyro at 163', RIH to 180' 06:15 - 12:00 5.75 DRILL DRLG SURFAC Drilled 13 1/2" hole from 180' to 478', (298') ART 1.77 hrs, AST 2.31 hrs, 10-12K wob, 40 rprr f s, 120 spm, 509 gpm, 850 psi, ran 3 Gyro's at 256', 348' and 435' and took 1- 114 hrs 12:00 - 00:00 12.00 DRILL DRLG SURFAC Directionally drilled 13 1/2" hole per directional plan from 478' to 1,270' MD/1,205' TVD (792') ART 7.98 hrs, AST 1.43 hrs, 10-25K wab, 40 rpm's, 120 spm, 509 gpm at 1,150 psi, off btm torque 1-5K ft-Ibs, on btm 1-4K ft-Ibs, rot wt 88K, up wt 85K, do wt 81 K, ran 2 Gyro's at 530' 1 and 622' and took 1/2 hr, After Gyro at 622' RD unit at 16:30 hrs 8/16/2005 00:00 - 07:45 7.75 DRILL DRLG SURFAC Continue Directional drill 13 1/2" hole from 1270' - 1936' (666'). TVD = 1552' Upweight = 95K, SO WT = 70K, Rot Wt = 81 K. TO on btm = 5-8K TO off btm = 2-6K. ART = 1.13 HRS. AST = 4.25 HRS ADT = 5.38 HRS. Jars = 86.78 HRS. WOB = 20-35K. 40 RPM's. Pumps @ 535 GPM's with 1600 PSI. 07:45 - 10:15 2.50 DRILL REAM SURFAC BROOH from 1936' - 530' (1406'), to set mud motor @ 1.5 Degrees. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-168 1 J-168 ROT -DRILLING n1334@ppco.com Doyon 141 Date .From - To Hours Code Code Phase 8/16/2005 07:45 - 10:15 2.50 DRILL REAM SURFAC 10:15 - 11:00 0.75 DRILL TRIP SURFAC 11:00 - 12:00 1.00 DRILL PULD SURFAC 12:00 - 13:30 .13:30 - 14:15 14:15 - 00:00 8/17/2005 00:00 - 07:30 1.501 DRILL I PULD I SURFAC 0.751 DRILL TRIP I SURFAC 9.751 DRILL I DRLG SURFAC 7.501 DRILL I DRLG I SURFAC 07:30 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 13:30 13:30 - 14:15 14:15 - 15:45 15:45 - 17:45 17:45 - 20:15 20:15 - 21:00 21:00 - 23:00 23:00 - 00:00 1.001 DRILL !CIRC (SURFAC 1.001 DRILL I REAM {SURFAC 2.50 DR1LL REAM I SURFAC Page 2 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Pumps @ 650 GPM's with 1650 PSI. POOH on elevators from 530' - 51' (479'). POOH ~ lay down UBHO sub. POOH to surface. Clean & inspect bit and orient Mud motor to 1.5 Degrees. !Make up Pressure Drop Sub.Observed that the Retaining orifice had .fallen on top of Mud Motor Stator and damaged Motor. Change out 8" Mud Motors. New motor is Sperry Drill Lobe w/ 4/5 - 5.3 stage, at 1.5 degrees. MU 13 1/2" Hughes MX-1 Roller Cone Bit, with 1 x 13, and 3 x 20 for a TFA of 1.050". Continue MU MWD assembly, 1 -stand 8" NMFC's, crossover, 5" HWDP, JARS, and Ghost Reamer. TIH from 1084' - 1890' (806'). Wash from 1890' - 1936'. (46'), at 623 GPM's with 1700 PSI. Continue Directional drill 13 1/2" hole from 1936' - 3060' (1124'). TVD = 1892`. Upweight = 97K, SO WT = 66K, Rotate Wt = 79K. TQ on bottom = 7.5K off bottom = 6K. ART = 4.43 HRS, AST = 2.02 HRS, ADT = 6.45 HRS. Jars = 93.23 HRS Max Hydrates = 3788 Units @ 2890' MD TVD - 1838'. WOB = 5-20K, 80 RPM's .Pumps @ 708 GPM's with 2025 PSI. Continue Directional drill 13 1/2" hole from 3060' - 3704' (644'). TVD = 2118.44'. Upweight = 125K, SO WT = 57K, Rotate Wt = 86K. TQ on bottom = 10K off bottom = 10-12K. ART = 3.33 HRS, AST = 1.88 HRS> ADT = 5.21 HRS. Jars = 98.44 HRS Max Hydrates = 3088 Units @ 3170' MD TVD - 1928'. WOB = 10-20K, 80 RPM's .Pumps @ 650 GPM's with 2000 PSI. Total Bit Hrs = 32.14. Total Footage = 3596' POOH, rack back 1 stand. CBU @ 3652' while reciprocating string @ 177 SPM, 2150 PSI, 80 RPM's and 8-11 K Torque. Pick up 1 stand Dp, attempt to tag bottom, NO-GO. Wash i£ ream back to tag bottom at 3704' @ 181 SPM, 2350 PSI. 10-12K torque. BROOH, from 3704' - 2321' (1383'). Pumps @ 750 GPM's, 2350 PSI. 80 RPM's, TQ @ 10-12K. 1.50 DRILL REAM SURFAC Continue BROOH, from 2321' - 1084' (1237'). Pumps @ 750 GPM's, 2350 PSI. 80 RPM's, TQ @ 10-12K. 0.75 DRILL PULD SURFAC Rack Back 10 Stands of 5" HWDP and Jars. (917.06') 1.50 DRILL PULD SURFAC Breakout & lay down drilling BHA. Lay do crossover (2.52'), 3 - NMFC's ( 93.05'), Float sub (2.49'), MWD assembly (25.05'), Pressure drop sub ( 2.0'), NM Crossover (2.51'), Sleeve type stabilizer (5.08'), 8" Sperry Mud Motor (28.89'), and Hughes MX1 13 1!2" bit (1.00'). Gauge bit to 2/2/WT/A/0/I/NO/TD 2.00 CASE RURD SURFAC Rig Up to run 10 3/4" 45.5# casing. Held Pre- Job safety meeting. Discuss running order, centralizer placement, and make up torques. 2.50 CASE RUNC SURFAC Make up 10 3!4" shoe joint, w/ Weatherford Mode1303 Sure Seal Float Shoe, 1 JNT 10 3/4" 45.5# casing, and Float collar joint w/ Weatherford Model 402 Sure Seal Float Collar. Continue RIH with 10 3/4" casing as per running order palcing centralizers on 5' above Shoe, 10' Below Float collar, 10' above Float collar, and 1 each on every collar from jnt # 4 - 20. RIH to 1900' Make up Torque = 10K 0.75 CASE CIRC SURFAC CBU @ 2 BPM - 200 PSI, 3 BPM - 225 PSI, 4 BPM - 250 PSI, 5 BPM - 300 PSI while reciprcate string. JNTS # 50 & 51 2.00 CASE RUNC SURFAC Continue RIH w/ 10 3/4" 45.5# casing from 1900' - 3693' (1793'). Make up Landing Joint &RIH to land hanger @ 29.99' RKB to spool. Upweight = 180K . SO weight = 68K 1.00 CASE CIRC SURFAC Circulate & condition mud while reciprocate string 10'. 3.5 BPM = 275 Printed: 10/21!2005 2:52:30 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date -From - To Hours Code Co e ~ Phase 8/17/2005 23:00 - 00:00 8/18/2005 00:00 - 00:15 00:15 - 00:45 00:45 - 02:00 1.00 CASE CIRC SURFAC 0.25 CEMEN CIRC SURFAC 0.501 CEMEN'flPULD (SURFAC 1.251 CEMENIiCIRC (SURFAC 02:00 - 05:15 3.25ICEMEN7iPUMP (SURFAC PULD SURFAC NUND SURFAC NUND SURFAC 05:15 - 06:30 1.25 06:30 - 09:30 3.00 09:30 - 11:00 1.50 11:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 15:45 15:45 - 21:45 1.00 WELC 1.00 WELC 1.00 WELC 1.75 DRILL 6.00 WELC 21:45 - 22:15 22:15 - 00:00 8/19/2005 00:00 - 01:00 01:00 - 06:15 NUND SURFAC NUND SURFAC NUND SURFAC RIRD SURFAC ROPE SURFAC 0.50 DRILL OTHR SURFAC 1.75 DRILL PULD SURFAC 1.001 DRILL I PULD I SURFAC 5.251 DRILL I PULD I SURFAC Page 3 of 29 Spud Date: 8/13/2005 Start: 8/1312005 End: Rig Release: Group: Rig Number: Description of Operations PSI, 4 BPM = 275 PSI, 5 BPM = 300 PSI, and 6 BPM = 350 PSI. ~ Upweight = 160K, SO Weight = 65K with pumps on. Continue circulate ~ condition mud while reciprorate string 10'. 6.5 BPM = 375 PSI, Upweight = 165K, SO Weight = 60K with pumps on. Breakout & lay down Franks Fill UP Tool. Load cement head 8~ MU head and lines to Landing Joint. Continue circulate & condition mud while reciprocate string 10'. 6.5 BPM = 325 PSI, Conditioned mud from a 9.5 PPG, Visc = 260, PV = 41, YP = 54, Gels @ 20151 /70 with a PH of 8.6, to a 9.2 PPG, Visc = 40, PV = 18, YP = 9, Gel @ 1/2/2, with a PH of 8.4. Upweight = 165K, SO Weight = 60K with pumps on. Hold Pre-Job Safety Meeting with entire crew, truck drivers and Cementers. Turned over to Dowell and pumped 10 bbls of CW 100 at 8.35 ppg @ 4 BPM - 50 PSI, pressure tested lines to 3,500 psi, pumped additional 40 bbls of CW 100 (50 bbfs Total) @ 5.4 BPM - 85 PSI, then pumped 50 bbls of 10.5 ppg XL Mudpush with Red Dye, avg 5 bpm at 110 psi, shut down and dropped btm plug, Mix and pump Lead cement, Pumped a total of 531 BBLs of 10.7 ppg Arctic set lite cement with a yield of 4.49, with additives,660 sacks, Avg pumping @ 6.6 BPM 140 PSI. Upweight = 175K, SO WT = 73K. Landed casing in hanger @ 485 BBLS into Lead as we observed reciprocatiion becoming "sticky". Upweight = 190K, SO WT = 65K. Mix & pump 83.6 BBLS of 12.0 PPG Deepcrete Tail Slurry, Yield = 2.47, with additives, 180 sacks, avg 6.1 bpm at 200 psi, shut down and dropped top plug. Dowell pumped 20 bbls, 8.35 PPG FW for flush, and turned over to rig. Rig displaced cmt with 325 bbls of 9.2 ppg mud, ave 7 bpm, initial pressure 680 psi, max pressure 690 psi, slowed to 3 bpm and bumped plug on calc displacement of 325 BBLS = 3227 STKS to 1,000 psi, check floats and floats held, CIP at 05:15, Had 103.4 bbls of 10.7 ppg lead cmt back to surtace. RKB to landing = 29.99' Rig down Cement Equipment. Backout & lay down Landing jnt. Flush stack. Nipple down diverter system. Nipple up wellhead as per Vetco rep. Test Power flange to 5000 PSI. 15 minutes. Nipple up BOP stack, choke & kill lines. Continue Nipple up BOP stack ,choke 8~ kill lines. Change out Lower pipe rams from 5" to 7 5/8" rams. Change out Top Drive saver sub, grabbers, & bell guide to 4". RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, John Crisp with AOGCC witnessed test, recorded on chart. Install wear bushing. RILDS. WB ID = 12 1/4" Pick up & rack back 6 stands of "PUSH PIPE". Stands are made up of 2 jnts of 4 3/4" DC's with 1 JNT of 4" XT-39 HWDP on top. Continue to pick up & rack back 9 stands of "PUSH PIPE". (15 stnds Total) Stands are made up of 2 jnts of 4 3/4" DC's with 1 JNT of 4" XT-39 HWDP on top. Pick up 180 Jnts, (60 stnds) of 4" XT-39 drill pipe and rack back in Derrick. Printed: 70/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 4 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date 'From - To Nours Code 8/19/2005 ~ 06:15 - 07:30 07:30 - 08:00 08:00 - 09:45 09:45 - 10:15 10:15 - 11:00 11:00 -11:30 11:30 - 12:00 12:00 - 13:30 13:30 - 14:00 1.251 DRILL Sub Code IPULD Phase SURFAC 1.75 DRILL IPULD SURFAC 0.50 DRILL PULD SURFAC 0.75 DRILL PULD SURFAC 0.50 {DRILL IPULD ISURFAC 0.501 DRILL IPULD ISURFAC 1.501DRILL (PULD ISURFAC 0.501DRILL (PULD ISURFAC 14:00 -15:00 1.00 CASE DEQT SURFAC 15:00 - 15:15 0.25 DRILL REAM SURFAC 15:15 - 17:45 2.50 DRILL DRLG SURFAC 17:45 - 18:15 I 0.501 DRILL I CIRC ISURFAC 18:15 - 19:00 I 0.751 DRILL I LOT ISURFAC 19:00 - 00:00 5.00 I DRILL I DRLG INTRMI 18/20!2005 100:00 - 12:00 { 12.001 DRILL DRLG I INTRM1 12:00 - 15:30 I 3.501 DRILL I DRLG I INTRMI Description of Operations Rig up and lay down 21 jnts of 5" HWDP from derrick. lay down mousehole. Clean floor area, pull BHA equipment to rig floor from beaver slide. Hold PJSM. "Making up BHA #3 ". Make up 9 7/8" BHA as per Dir Driller. MU 9 7/8" Security FS2653 PDC bit (1.60') with a TFA of 1.845 sq in. 7600 Series Geo-Pilot (20.15'), 6 3/4" Non Mag GP Flex Pony collar (9.20'}, 6.770" Smart Stabilizer (2.18'), 6 3/4" MWD GR / RES / PWD (20.93'), 6.770" Smart Stabilizer (2.16'), 6 3/4" MWD HCIM 6.83'), 6 3/4" MWD TM HOC (9.96'), and Non Mag Float Sub (1.96'). Plug in and upload MWD Equipment. Continue making up BHA picking up 3 -Non Mag Flex Drill collars ( 91.66'), 4 -HWDP (123.4'), 6 1!4" Drilling jars w/ 98.43 Hrs (30.38'), 1 stnd 4" DP. Perform Shallow pulse test MWD /Geo Span @ 538', at 550 GPM's - 1050 PSI. Continue MU 18 JNTS 5" DP (571.29), 6 1/2" Ghost reamer (5.08'), 41 JNTS 5" DP (1237.44'), and a 6 1/2" Ghost Reamer (6.34'). Continue MU 41 JNTS 5" DP (1237.44'), and a 6 1/2" Ghost Reamer 6.34'). RIH to tag Float Collar @ 3609' DPM. Pull up to position bit @ 3586'. CBU @ 650 GPM's - 2050 PSI. Up weight = 115K, SO WT = 53K Rot WT = 79K TQ = 6-8K Rig up and test 10 3/4" casing to 3000 PSI. Held test 30 minutes and recorded on chart. Good test. Bleed Pressure and Rig down test lines. Wash down from 3586' - 3609' (25'). Drill through float equipment. Float collar @ 3613', Shoe track, and Float Shoe @ 3693', Continue drill 20' of 9 7/$" new hole to 3724' MD at TVD of 2128'. ADT = .19 HRS. Up weight = 120K, SO WT = 52K, ROT WT = 80K, RPM's @ 100 Tq on btm = 6-8K, Pumps @ 600, GPM's - 1800 PSI. Obtain SPR's @ 3678' MD, TVD = 2112'. #1 pump 30 SPM - 220 PSI. 40 SPM - 290 PSI. Pump #2 - 30 SPM - 170 PSI, 40 SPM - 220 PSI Circulate 8~ condition mud displacing well with re-conditioned 9.0 PPG mud, @ 600 GPM's - 1800 PSI. On btms up, Density = 9.0 PPG, Gels 10 min = 14 RU lines and Perform LOT to Equivalent Mud Weight of 15.3 ppg, with 691 PSI, 9.0 ppg mud, Shoe TVD 2115' (EMW pick by computer). Record on chart. Bleed all pressures and rig down lines. Directional drill 9 7/8" hole with Geo-Pilot from 3724' - 4184' MD (460'). TVD = 2294' ADT = 2.81 HRS. UP WT = 124K, SO WT = 50K, ROT WT = 75K. Torque on btm = 6-8K, off btm = 7-9K. 100 RPM's, W08 = 10-15K, Pumps @ 550 GPM's - 1500 PSI. Jars = 101.43 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD = 9.8 PPG Total Bit HRS = 3.0 Directional drill 9 718" hole with Geo-Pilot from 4184' - 5362' MD 1178'). TVD = 2752' ART = 7.91 HRS. UP WT = 134K, SO WT = 59K, ROT WT = 81 K. Torque on btm = 9-12K, off btm = 11 K. 60 RPM's, WOB = 5-25K, Pumps @ 450 GPM's - 1250 PSI. Jars = 109.34 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD up to = 10.1 PPG Total Bit HRS = 10.91 The drilling parameters were adjusted to directionally control assembly in the soft formation. Directional drill 9 7/8" hole with Geo-Pilot from 5362' - 5642' MD 280'). TVD = 2842' ADT = 2.29 HRS. UP WT = 132K, SO WT = 55K, Printed: 10/21/2005 2:52:30 PM • Phase ConocoPhillips Alaska Operations Summary Report Lega! Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Start: 8/13/2005 Contractor Name: n1334@ppco.com Rig Release: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Code 8/20/2005 ~ 12:00 - 15:30 ~ 3.50 ~ DRILL ~ DRLG • Page 5 of 29 Spud Date: 8/13/2005 End: Group: Description of Operations INTRMI ROT WT = 80K. Torque on btm = 14K, off btm = 10-12K. 90 RPM's, 15:30 - 19:00 3.50 DRILL TRIP INTRM1 19:00 - 19:30 0.50 DRILL CIRC INTRM1 19:30 - 22:00 2.50 DRILL TRIP INTRM1 22:00-22:45 0.75 DRILL PULD INTRM1 22:45 - 23:15 0.50 DRILL OTHR INTRM1 23:15 - 00:00 0.75 FISH PULD INTRM1 8/21/2005 00:00 - 01:30 1.50 RIGMNT RSRV INTRMI 01:30 - 03:30 2.00 FISH PULD INTRMI 03:30 - 06:15 2,75 FISH TRIP INTRM1 06:15 - 11:00 4.75 FISH WASH INTRM1 11:00 - 12:00 I 1.00 I FISH I FISH I INTRM1 12:00 - 13:00 I 1.001 FISH I PULL I INTRM1 13:00 - 14:00 I 1.00 FISH CIRC INTRM1 14:00 - 15:15 ! 1.25 FISH PULL INTRM1 15:15 - 15:45 f 0.50 FISH CIRC INTRMI 15:45 - 18:30 I 2.75 FISH PULL INTRM1 18:30 - 19:30 1 1.001 FISH (TRIP I INTRM1 WOB = 10-25K, Pumps @ 585 GPM's -1900 PSI. Jars = 111.63 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD up to = 10.1 PPG Total Bit HRS = 13.2. Lost MWD communication, could not regain it. Monitor well, BROOH from 5642' - 3693' Shoe depth (1949'), at 90-100 RPM's 650 GPM's - 1750 PSI. Observed 30 - 40% increase in cuttings over shakers while backreaming Pump Hi Visc sweep and CBU 2 -times @ 700 GPM's - 1750 PSI. 30 - ~ 40% increase in cutting while circulating Monitor well -static. Pump Dry Job, POOH from 3682' -surface. Stand back HWDP, Jars, and NM Flex Collars. Breakout Float sub. Pull up ~ Observed MWD tool broke and parted at the crossover below MWD HCIM and above Smart Stabilizer. Total fish left in hole = 57.90'. The OD Of break = 6.223": Left in hole -Crossover top (1.68'}, 6.70" Smart Stabilizer (2.16'), 6 3/4" MWD GR / RES / PWD (20.93'}, 6.770" Smart Stabilizer (2.18"), Non-Mag GP Flex Pony Collar (9.20'), 7600 Series Geo-Picot (20.15'), and 9 718" Security bit (1.60'). Fishing neck looking up = 1.68' Breakout 8~ lay down MWD TM HOC and HCIM assembly. Clean Rig floor area, and send tools down beaver slide. Load pipe shed with 6 - 6 3/4" Drill collars, strap same. PJSM, Slip & Cut 45 FT of Drilling line. Service Top Drive Make up BHA #1 Fishing Assembly. MU 9 5/8" Series 150 Overshot dressed with a 6 1/4" Grapple and Mill Control packoff, and Guide with tungsten carbide welded on (3.75"), 6 1/4" Pump out sub (2.02'), 6 1/4" Lubricated Bumper Sub (9.00'), 6 1/4" Oif Jar (11.23'), 3 - 6 3/4" Drill Collars (91.83'), and Accelerator Jar (12.91'). Total BHA lenght = 130.74. Trip in hole from 130' - 3732' (3602'). Shoe depth = 3693'. Tag up, taking 5K weight. Upweight = 85K SO WT = 35K Wash & ream through open hole from 3732' - 5575' (1843'}. Observe minimal pressure increases and could not verify that we were pushing fish. Pumps @ 50 SPM - 250 PSI, Up Wt = 110K, SO WT = 40K, Rot WT = 70K, staging pumps up 75 SPM - 600 PSI, and 115 SPM - 800 PSI. Note: Held Pad evacuation drill along with Nordic 2, and Construction. Wash over top of fish at 5588' DPM. 60 SPM - 400 PSI. 40 RPM's. Observed little or no pressure increase, and no increase in up weight when set down 10k, and pull up. Repeat several times to attempt to catch fish. No indication of fish on. Up Wt = 125K, SO WT = 75K TQ = 17K. Attempt to POOH- Hole swabbing, Pump out of hole from 5588' - 5040' ( 548'). Circulate Bottoms up @ 360 GPM's - 500 PSI. Continue Pump Out of hole into shoe from 5040' - 3600' (1440') @ 360 GPM's - 500 PSI. Note; Hole swabbed all the way to the shoe without pump. Circulate Bottoms up @ 420 GPM's - 400 PSI. Momitor well -static. Pump Dry job. POOH from 3600' - 130' (3470'), on elevators. Observe overpull of 55K at shoe. (overshot at shoe) Stand back drill collars and pull 9 5/8" overshot to rig floor. NO-FISH. Breakout & lay down Overshot assembly, Inspect 6 1/4"grapple and mill control packoff. Observed packoff rubber gone, indication marks on Pnntetl: 10/Z7/ZOOb 2:b230 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 ',Common W ell Name: 1J-168 Event Nam e: ROT -D RILLIN G Contractor Name: n1334@ ppco.co m Rig Name: Doyon 1 41 Date From - To Hours Code Phase Code 8/21/2005 18:30 - 19:30 1.00 FISH TRIP INTRMI 19:30 - 20:15 0.75 FISH OTHR INTRM1 20:15 - 20:30 0.25 FISH PULD INTRMI 20:30 - 00:00 3.50 FISH TRIP INTRMI 8/22/2005 00:00 - 00:30 0.50 FISH TRIP INTRM1 00:30 - 00:45 0.25 FISH FISH INTRMI 00:45 - 04:45 4.00 FISH TRIP INTRM1 04:45 - 05:00 0.25 FISH PULD INTRM1 05:00 - 06:00 1.00 FISH PULD INTRMI 06:00 - 09:45 3.75 FISH TRIP INTRM1 09:45 - 12:00 2.25 FISH TRIP INTRM1 Page 6 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations the mill control that we had been over top of fish, and the grapple had definite indications that we had been over the fish and had "spun" the grapple wickers to "DULL". The grapple was also spread open 1/2". The carbide on the guide indicated we were just to the top of the stabilizer, and had a full bite. Pictures were taken and sent to town. Clean rig floor area, lay do tools. Discuss options with town. Decision to run 8 1/8" Overshot with 6 1/4" Grapple, without 6 3/4" drill collars. Strap & make up fishing BHA #2. 8 1/8" Overshot assembly with 6 1/4" Grapple and Mill Control Packoff with carbide on the guide. This will swallow 1.84'. length = 3.60'. Continue make up 6 1/4" Pump out sub 2.02'), 6 1/4" Lubricated Bumper Sub (9.0'), 6 1/4" Oil jar (11.23), 6 - Jnts of 5" HWDP (184.40), and Accelerator Jar (12.91'). Total BHA length = 223.13'. Top fish @ 5584' Trip in hole with BHA #2, from 223' - 5320' (5097). Stop at the Shoe (3693') and obtain parameters. Up Wt - 84K, SO WT = 40K Pumps at 50 SPM - 300 PSI. Continue TIH to 5320' with no issues, and take weight @ 4950'. Screw into TD and wash & rotate @ 30 Rpm's with 450 GPM - 650 PSI, 3 studs to continue in hole. We were able to TIH with little rotation or pumping after that to Tag hard @ 5475'. UP WT = 130K, SO WT = 50K. Continue TIH from 5320' made up to TD and wash & rotate @ 30 Rpm's with 450 GPM - 650 PSI, 3 studs to continue in hole. We were able to TIH with little rotation or pumping after that to Tag hard @ 5475'. UP WT = 125K, SO WT = 52K. Tag hard @ 5475' while washing through open hole with overshot. 30 RPM's. Stop rotating, and straight slackoff to engage fish. Pull up to 200K first pull and fire jars. (75K over) Straight pull to 250K, and fish pulling free with 60-120K drag. We engaged fish 113' higher than expected. Pumps @ 530 GPM's - 1400 PSI. Observe no pressure increase when engage fish. Pump out of hole from 5475', observing overpull of 60-100K. 530 Gpm's - 1400 PSI. Continue POOH pumps off checking well for swabbing, hole taking fluid. Continue pull on elevators to tight spot @ 5140', observe weight falling off to drag at 145K UP WT. Staright pull @ 200K, Slack off to break over free, and pull up to 145K, observed weight fall off, with Upweight now of 125K. Continue POOH to surface. Breakout ~ lay down Overshot assembly. NO FISH. Inspect 8 1/8" overshot. Observed wickers on 61/4" grapple still sharp, slivers of Monel steel in wickers, and good indications inside Top Sub showed overshot bottomed out over fish. Guide looked good but had minimal "flare" on the cut lip. Discuss options with town. Clean floor area, Make up Fishing BHA #3, Strap & make up 8 1/8" Overshot assembly with 6 1/8" Grapple and Mill Control Packoff with carbide on the guide. This will swallow 1.84'. length = 3.60'. Continue make up 6 1/4" Pump out sub (2.02'), 6 1/4" Lubricated Bumper Sub 9.0'), 6 1/4" Oil jar (11.23), 6 - Jnts of 5" HWDP (184.40), and Accelerator Jar (12.91'). Total BHA length = 223.13'. Suspected Top fish @ 5140' TIH to 3638', Break circulation. Up WT = 103K, SO WT = 50K. Pumps @ 530 GPM's - 1425 PSI. RIH to tag fish @ 5140' DPM, and push fish to 5563', then observed 200 PSI increase in pressure. Pull up to 250K 147K over), to observe drag @ 60-100K. ',Pump out of hole with fish on from 5563' - 4292' (1271') observing drag Printed: 10/21/2005 2:52:30 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/22/2005 09:45 - 12:00 12:00 - 12:45 12:45 - 15:30 15:30 - 17:00 1 J-168 1 J-168 ROT -DRILLING Start: 8/13/2005 n1334@ppco.com Rig Release: Doyon 141 Rig Number: Hours Code Code Phase 2.25 FISH TRIP INTRM1 0.75 FISH TRIP INTRM1 2.75 FISH TRIP INTRMI 1.50 FISH PULD INTRMI 17:00 - 17:30 0.50 DRILL PULD INTRM1 17:30 - 18:30 1.00 RIGMNT RSRV INTRM1 18:30 - 21:00 2.50 DRILL PULD INTRM1 21:00 - 21:15 I 0.251 DRILL 1 PULD I INTRMI 21:15 - 21:45 I 0.501 DRILL I PULD I INTRM1 21:45 - 00:00 I 2.251 DRILL I TRIP I INTRM1 18/23/2005 100:00-02:30 02:30 - 10:30 2.501 DRILL I REAM I INTRM1 8.001 DRILL I DRLG (INTRMI 10:30 - 11:00 0.50 WAITON ORDR INTRMI 11:00 - 12:00 1.00 DRILL REAM INTRMI 12:00 - 12:30 0.50 DRILL REAM INTRMI 12:30 - 15:15 2.75 DRILL TRIP INTRM1 15:15 - 16:30 I 7.25 {DRILL 1 PULD I INTRM1 Page 7 of 29 Spud Date: 8/13/2005 End: Group: Description of Operations up to 100K. Pumps @ 80 SPM - 700 PSI Continue Pump out of hole with fish on from 4292' - 3550' (742') observing drag up to 100K, with drag falling off. Pumps @ 340 GPM - 600 PSI Monitor well -static. Pump Dry job, POOH on elevators to surface Breakout & lay down 8 1/8" Overshot assembly, releasing from fish. Lay down fish. Fish = 57.90'. Layed down Crossover top (1.68'), 6.70" Smart Stabilizer (2.16'), 6 3/4" MWD GR /RES /PWD (20.93'), 6.770" Smart Stabilizer (2.18"), Non-Mag GP Flex Pony Collar (9.20'), 7600 Series Geo-Pilot (20.15'), and 9 7/8" Security bit (1.60'). Fishing neck looking up = 1.68' x 6 1/8" Clean floor area, pull tools to rig floor. Insert Vortex jets in bit and orient them to point more ahead of the bit. Service Top Drive and Drawworks. Make up BHA #7. MU 9 7/8" Security FMFX653 Bit w/ TFA of .969 Sq in. (1.40'), Jet Nozzles = 3 x 14's, and 3 x 15's. Continue with 9 7/8" 7600 Geo-Pilot (23.22'), 6 3/4" Non-Mag Pony Collar (9.20'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR /RES /PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 314" MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'), and Non Mag Float Sub (1.96'). Plug in, Up Load MWD assembly. RIH from 68' - 540'. (472'), making up remaing BHA. 3 -Non Mag Flex collars (91.56'), 4 -jnts 5" HWDP (123.24'), 6 1/4" drilling jars with 98.43 HRS (30.38'), and 4 -jnts 5" HWDP (122.76'). Pick up 9 7/8" Ghost reamer( 5.08') on #6 stand of 5"HWDP. Total BHA length = 446.12' Break in Geo-Pilot and pulse test MWD tools. Good test. Pumps @ 500 GPM"S - 875 PSI. Trip in hole from 540' - 3704' (3164'), picking up 9 7/8" Ghost Reamer (6.34') on stand # 19 of 5" DP. UP WT = 115K, SO WT = 50K. Wash & Ream Open Hole from 3704' - 5642' (1938') @ 350 GPM's - 650 -800 PSI. 80 RPM's Torque = 8-10K. Directionally Drill 9 7/8" Intermediate hole from 5642' - 6205' (563'). TVD = 3056' Observe trouble controlling Geo-Pilot assembly, and could not maintain required direction. Pumps @ 450 - 530 GPM's - 1350 - 2150 PSI, UP WT = 163K, SO WT = 55K, ROT WT = 82K. WOB = 15-34K. 60-90 RPM's, TQ = 11-17K. Jars = 117.61 HRS Mud wt = 9.1 PPG. ECD = 9.82 PPG. Directional Drillers discuss with Co. Rep,and town. BROOH from 6205' - 5834' (371'). Pumps @ 650 GPM's - 2500 PSI. TQ = 10 -12K. Continue BROOH from 5834' - 5554' (371'). Pumps @ 650 GPM's - 2500 PSI. TQ = 10 -12K. POOH on elevators From 5554' - 4900' (654'). Pump dry job, Continue POOH to MWD. Plug in and download MWD. Breakout & fay down BHA #7. Layed down Non-Mag float sub (1.96'), 6 3!4" MWD TM HOC (9.96'), 6 3/4" MWD HCIM (6.97'), 6.70" Smart Stabilizer (2.17'), 6 3/4" MWD GR /RES/ PWD (21.02), 6.760" Smart Stabilizer (2.18'), 6 3/4" Non Mag GP Flex Pony (9.20'), 7600 GEO-Pilot (23.22), and the 9 7/8" Security FMFX653 bit (1.40'). Observed 9 7/8" bit had 15 cutters, worn or Pflnted: 7021/ZUVb Z:S2:3U PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/23/2005 15:15 - 16:30 I 1.25 DRILL PULD INTRMI 16:30 - 19:00 2.50 DRILL PULD INTRM1 19:00 - 23:00 I 4.001 DRILL I PULD I INTRMI 23:00 - 00:00 I 1.00 I DRILL I DRLG INTRM1 18/24/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I INTRM1 12:00 - 23:15 I 11.251 DRILL I DRLG I INTRM1 18/25/2005 00:00 - 04:30 4.50 DRILL TRIP I INTRM1 04:30 - 05:30 1.001 DRILL (TRIP INTRM1 05:30 - 06:00 I 0.501 DRILL CIRC I INTRM1 06:00 - 06:30 I 0.501 DRILL (TRIP INTRM1 06:30 - 09:00 2.50 DRILL TRIP INTRM1 09:00 - 10:15 1.25 DRILL PULD INTRM1 10:45 - 12:00 I 10.25 DRILL PULD INTRM1 Page 8 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations broken. Make up BHA #8, Bit #4. Make up 9 7/8" Hughes MXC1 bit with jets of 3 x20's, 1 x 12 for a TFA Of 1.031 sq. in.(.80'), 7" SperryDrill Lobe 7/8 - 6.0 stage (25.40) with a bend configuration of 1.5 degrres. 6 1/2" Non Mag Float sub (1.96'), 6 3/4" Welded Blade Stabilizer (5.62'), 6 3/4" MWD DM HOC (9.02'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR/RES/PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4 MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'). Up load MWD. TIH from 116' - 6205' (6089'). Make up remaining BHA, 3 -NON MAG Flex Collars (91.66'), 4 -JNTS 5" HWDP (123.24'), 6 1/4" Drilling Jars ( 30.38') with 98.43 HRS, 4 -JNTS 5" HWDP (122.76'). Perform shallow pulse test on MWD Assembly -good test @ 550', 525 GPM's - 1050 PSI. Continue TIH, install 9 7/8" Ghost reamer on stand # 6 5.08'), and9 7/8" Ghost Reamer on-stand #19 (6.34'). Continue TIH, observe no issues through Shoe @ 3693', continue to bottom @ 6205', Wash down last stand. Directional Drill 9 7/8" Hole from 6205' - 6253' (48') TVD = 3075'. Pumps @ 550 GPM's - 2050 PSI, WOB = 6-30K 60-80 RPM's. PU WT = 140K, SO WT = 59K, ROT WT = 87K. AST = .40 HRS. ECD = 9.86 PPG. Continue Directional Drill 9 7!8" Hole from 6253' - 7147' (894') TVD = 3298'. Pumps @ 650 GPM's - 2975 PSI, WOB = 25-33K, 60-80 RPM's. PU WT = 166K, SO WT = 58K, ROT WT = 85K. Torque on btm = 11 K, off bottom = 12K, ART =5.98 HRS, AST = 2.24 HRS. ADT = 8.4 HRS. ECD = 10.23 PPG.MAx GAS = 321 units. Jar Hrs = 127.45. SPR's #1 pump = 30 SPM - 370 PSI, 40 SPM - 450 PSI, Pump #2 - 30 SPM -370 PSI, 40 SPM - 450 PSI. Total BIT HRS = 8.8 Mud WT = 9.1 PPG Continue Directional Drill 9 7/8" Hole from 7147' - 8229 ' (3073.80') TVD = 3298'. Pumps @ 650 GPM's - 2975 PSI, WOB = 10-30K, 80 RPM's. PU WT = 130K, SO WT = 65K, ROT WT = 88K. Torque on btm = 11 K, off bottom = 12K, ART =4.63 HRS, AST = 1.90 HRS. ADT = 6.53 HRS. ECD = 10.46 PPG.MAX GAS = 527 units. Jar Hrs = 133.20. Total Bit Hrs = 15.55 MUD WT = 9.1 PPG, Pump HI-VISC weighted sweep on last connection. Continue Circulate sweep out of hole @ 650 GPM's - 2950 PSI. Obtain last surveys at TD, as per DD. Monitor well -Static. BROOH from 8229' - 4627' (3602'). Pumps @ 650 GPM's, - 3000 PSI. UP WT = 135K, SO WT = 65K, ROT WT = 87K with 8K torque. Observed increase in cuttings across shakers 30-40%. We backreamed to get lower Ghost Reamer into shoe area, and saw hole cleaned up. POOH on elevators from 4627' - 3692' (935'). Observed clean hole conditions. UP WT = 110K, SO WT = 55K. Hole taking proper fill. Pump Hi-Visc weighted sweep 9.1 PPG, @ 650 GPM's-1700 PSI., while reciprocating drill string @ 50 RPM's. Observe 70 % increase in cuttings and hole cleaned up. Monitor well -static. Pump dry job, POOH from 3692' - 3130' (562') to stand back remaing 4" DP. POOH, lay down 84 Joints of 5" drill pipe. Breakout & lay down 8 joints 5" HWDP, and drilling jars, (276.38'). Lay down 3 Non-Mag flex drill collars (91.66'), Flush mud motor with water. Plug in ,download MWD assembly. Continue breakout & lay down 9 7/8" Hughes MXC1 bit with jets of 3 PrintecS: '10/2'1/2005 2:52:30 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/25!2005 110:45 - 12:00 I 1.25 ~ DRILL PULD ~ INTRM1 12:00 - 12:30 0.50 DRILL PULD INTRM1 12:30 - 13:00 0.50 CASE OTHR INTRMI 13:00 - 14:30 1.50 CASE RURD INTRM1 14:30 - 18:30 4.00 CASE RUNC INTRM1 18:30 - 18:45 I 0.251 CASE I CIRC I INTRM1 18:45 - 20:15 20:15 - 20:45 1.501 CASE (RUNC INTRMI 0.50 CASE CIRC INTRM1 20:45 - 00:00 18/26/2005 100:00 - 03:00 03:00 -04:45 04:45 - 05:15 05:15 - 07:30 07:30 - 08:30 08:30 - 09:30 3.251 CASE I RUNC I INTRM1 3.001 CASE (RUNC (INTRMI 1.751 CASE I CIRC I INTRM1 0.501 CEMENlIPULD I INTRM1 2.251 CEMENTCIRC I INTRMI 1.001 CEMENI~PUMP I INTRM1 1.001 CEMENIiPUMP I INTRM1 Page 9 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group:. Rig Number: Description of Operations x20's, 1 x 12 for a TFA Of 1.031 sq. in.(.80'), 7" SperryDrill Lobe 7/8 - 6.0 stage (25.40) with a bend configuration of 1.5 degrres. 6 1/2" Non Mag Float sub (1.96'), 6 3!4" Welded Blade Stabilizer (5.62'), 63!4" MWD DM HOC (9.02'), 6.760" Smart Stabilizer (2.18'), 6 314" MWD - GR/RES/PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4 MWD HCIM (6.97'),.6 3/4" MWD TM HOC (9.96'). Inspect & grade bit to I / I / WT/A/E/I/NO/TD Clean floor area, and lay down all 5" handling tools. Rig up. BOLDS and pull wear ring. Rig up to run 7 5/8" 29.7# casing. Hold PJSM. Discuss "running detail as planned" and safety issues. Make up Float shoe joint, # 2 jint and Float collarjoint-all baker locked, and check floats. Continue RIH with 7 5/8" casing installing tandem rise centralizers 10' from each end ofjoints #1-#9, then install 1 centalizer on center of joints #10 -#80, and 1 each 10' from end on joints #81-#82. All centralizers are over "Stop Collars". RIH to 2100'. AVG make-up torque = 8500 FT/LBS Circulate bottoms up through Franks fill up tool @ 215 GPM's - 250 PSI. Continue RIH with 7 5/8" casing from 2100' - 3700' (1600'). Circulate bottoms up through Franks fill up tool @ 215 GPM's - 300 PSI. Continue RIH with 7 5/8" casing from 3700' - 6116', (2416'). Avg Make up Torque = 8500 FT/LBS. Continue RIH with 7 5/8" casing from 6116' - 8224, (2108'). AVG Make up torque = 8500 FT/LBS. We ran 7 5/8" Weatherford Model 303 Sure Seal Float Shoe (1.50'), 2 jts 7 5/8" BTC-M casing (85.25), 7 5/8" Weatherford Model 402 Sure Seal Float Collar (1.31'), 22 jts of 7 5/8" BTC-M casing (936.18'), 7 5/8" Casing Pup Jt (20.21'), 8 jts 7 5/8" Casing (339.79'), 7 5/8" Casing Pup Jt (21.46'), 158 Jts 7 5/8" BTC-M casing (6768.45'), and Jt # 191 to set in slips and cut off. RKB = 26.31'. The window Jts were spaced to allow tops of collars at 7136.45, and 6774.78. We ran a total of 82 Tandem Rise centralizers & stop rings. 2 per joint - 10' from each end on jts #1 -#9, 1 per joint on center of each joint #10 -#80, and 2 per joint on each end of jnts # 81 - #82. Centralizer spacing from 4761' - 8224'. Circulate bottoms up through Franks Tool staging up to 5 BPM - 450 PSI, while reciprocating string. UP WT = 185K, SO WT = 68K. Mud wt = 9.2+ PPG, PV= 12, YP = 20. Breakout & lay down Franks Fill up tool. Make up crossover and Cement Head. Continue Circulate & condition while reciprocating string, and RU Dowell Cement crew. Condition mud to pre cement properties of 9.0 PPG, PV = 11, and YP of 11. Held PJSM with entire crew and truck drivers. Discuss Cement Job, Fluid transfers, and safety. Circulating @ 6 BPM - 500 PSI UP WT = 205K, SO WT = 68K. Turn over to Dowell. Pump 5 BBLS of 8.36 PPG water @ 5.1 BBUMIN, Pressure test lines to 3500 PSI. Good Test. Pump 40 BBLS of 8.35 PPG CW100 @ 5 BBUMIN, 40 BBIs of 10.2 PPG MudPush @ 5 BBLS/MIN, Drop Bottom Plug, Pump 193 BBLS of 12.5 PPG Tail Slurry @ 6 BBLS/MIN, Drop Top Plug, and flush lines. While reciprocating string, Displace well with 9.0 PPG MOBM @ 7.5 Printed: 1021x2005 2:52:30 PM • • ConocoPhillips Alaska Page 10 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code ~ Phase 8/26/2005 ~ 08:30 - 09:30 ~ 1.00 ~ CEMENl~ PUMP ~ INTRM1 09:30 - 11:15 1.75 ~ CEMENI~RURD INTRMI 11:15 - 12:00 0.75 CASE OTHR INTRM1 12:00 - 14:00 2.00 CASE OTHR INTRMI 14:00 - 14:30 0.50 CASE OTHR INTRM1 14:30 - 14:45 0.25 CASE NUND INTRM1 14:45 - 15:00 0.25 CASE OTHR INTRM1 15:00 - 16:00 1.00 CASE OTHR INTRM1 16:00 - 17:45 1.75 CMPLTN OTHR INTRM1 17:45 - 19:00 1.251 WELCTL BOPE INTRM1 19:00 - 00:00 I 5.001 DRILL I PULD I PROD 18/27/2005 100:00 - 03:00 I 3.00 DRILL PULD ~ INTRM1 03:00 - 06:30 I 3.501 DRILL I PULD I INTRM1 06:30 - 10:45 I 4.251 DRILL (TRIP I INTRM1 10:45 - 12:00 1.25 DRILL TRIP INTRM1 12:00 - 12:15 0.25 DRILL TRIP INTRM1 12:15 - 13:15 1.00 RIGMNT RSRV INTRMI 13:15 - 13:30 0.25 DRILL TRIP INTRM1 13:30 - 17:45 4.25 DRILL DEQT INTRM1 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations BBLS/MIN to 3500 stks. Parked casing at 307 BBL into displacement. LAst UP WT = 215K, SO WT = 40K. We then slow pumps to 3.5 BBLS/MIN @ 360 BBLS into displacement, to bump plug at calculated 3725 STKS (375.10 BBLS). Recorded Cement in place at 09:25 HRS. Circulating pressure before bump 600 PSI. Pressure to 1100 PSI, hold for 5 minutes. Open valves and check floats - OK. Float shoe @ 8224' MD 3472' TVD Rig down cement head and lines. Nipple down & lift BOP stack for setting slips. Set 7 5/8" csg slips with 100K block wt, 65K set on slips. Rig up & make cold cut using WACHS casing cutter and POOH LD cut piece of 7 5/8" casing (17.59'), Dress stump, and install pack-off. Remaing casing jt #191 in slips = 23.54') Rig up and lower packoff on to stump. Nipple up BOP stack & choke line. Rig up and pressure test 7 5/8" packoff to 4200 PSI. Hold for 10 Minutes. Good test. Rig up and perform Casing annulus infectivity test w 9.1 PPG Mud. Pump down 7 5/8" x 10 3/4" annulus to flush with 175 BBLS of water @ 2 BPM - 900 PSI. Rig up and test BOP's, and flange breaks. Test to 250 PSI for Low test, and 3000 PSI, recoreded on chart. Bleed pressures. Rig down all test equipment. Rig up and make up Lo-Tads on 4" Dp in derrick. Stand back same. Obtain SLM on each stand, picked up 41 of 65 stands needed. NOTE: Little Red Services rigged up and pumped 90 BBLS freeze protect diesel down 7 5/8" x 10 3/4" casing @ 1.9 BBLS/MIN. Final shut in pressure = 600 PSI. Diesel to 2267' Continue make up Lo-Tads on 4" Dp in derrick. Stand back same. Obtain SLM on each stand, picked up 24 of 65 stands needed. Note: Blind Ram Function test. Held PJSM. Discuss BHA & Safety. Make up BHA #9. Make up 6 3/4" SDBS FSF 2641 PDC bit (1.20') w/ 3 x 15 Jets for a TFA of .518 sq in. 6 314" 5200 Geo-Piiot (16.22), 4 3/4" Non-Mag Flex (battery) (11.55'), 4 3/4" DM Collar (8.03'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/DGR (24.39'), 4 3/4" PWD Collar (10.77'), 4 3/4" TM HOC (11.28'), 4.710" Non-Mag Float Sub w/ valve(2.35'), 4 3/4" Non-mag IBS Stabilizer (5.33'), 3 - 4.630" Non-Mag Flex Drill Collars 93.17'), 4.90" - 4" XT 39 x 3 1/2" IF Crossover sub (1.72'), 1 -Jt 4" HWDP (30.33'), 4 3/4" Drilling jars (28.90, 4 - JTs 4" HWDP. Total BHA = 369.68'. Pulse test MWD @ 250 GPM"S - 1050 PSI. Break in Geo-Pilot bearings. PU WT = 45K, SO WT = 42K, ROT WT = 42K, 70 RPM"S Trip. in hole picking up 165 joints of 4" DP from pipe shed. Fill every 20 stands. Checked MWD @ 2892' and 5507' with 180 GPM's - 800 PSI. Cont trip in hole from 5507' - 7537' (2030'). Continue trip in hole from 7537' - 8114' (577'). Slip & Cut Drilling line. Service Top Drive, while CBU. Wash down from 8114' - 8136' (22'), to tag Float Collar @ 8136'. Rig up & perform 7 5/8" casing test to 3000 PSI. Record on chart. Pressure bled off 150 PSI in 30 Minutes. Reposition drill string and repeat test. Pressure bled 150 psi in 30 Minutes. Change out "easy turn" valve & perform Re-test. Pressure bled 150 PSi in 30 Minutes. Rig Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 11 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 I Date From - To Hours Code Phase Code 8/27/2005 13:30 - 17:45 4.25 DRILL DEQT INTRM1 17:45 - 20:45 3.00 DRILL DRLG INTRM1 20:45 - 22:00 1.25 FRMTST CIRC INTRMI 22:00 - 22:45 22:45 - 00:00 0.751 FRMTSTI OTHR I INTRM1 1.251 DRILL I DRLG I PROD 18/28/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD 12:00 - 00:00 I 12.00 I DRILL I DRLG I PROD 18/29/2005 100:00 - 12:00 I 12.001 DRILL I DRLG PROD 12:00 - 16:45 I 4.751 DRILL I DRLG I PROD 16:45 - 17:30 I 0.751 DRILL I CIRC I PROD Spud Date: 8113!2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations down test equipment. Circulate 15 minutes. Rig up test equipment. Perform Re-test to 3000 PSI.2850 psi after 30 min Test -Recorded on chart. Drill Float equipment. FC @ 8136', and Flaot shoe at 8224'. Drill 20' of new hole to 8249'. Pull up into shoe track, and circulate & condition mud @ 250 GPM's - 1950 PSI for LOT. Mud wt = 9.0 PPG, Visc = 75, YP = 14 Gels @ 18/28, in & out of hole. Rig up and fill all lines with mud. Pump at 7 strokes I minute to 66 stks. 5 1/2" Liners in pumps. Pump output = .085. Calculated Leak off @ 986 PSI for a calculated EMW = 14.46 PPG. Rig down all test equipment & lines. Recorded on chart. Directional Drill 6 3/4" hole from 8249' - 8308' (59'). TVD = 3472". ADT _ .60 HRS. PU WT = 125K, SO WT = 60K, ROT WT = 81 K. Torque on bottom = 6K, off bottom = 7K. 100 Rpm's. WOB = 6-10K. Pumps at 250 GPM's - 2000 PSI. Clean hole ECD = 10.37 PPG. Slow pump rates @ #1 pump 20 SPM - 380 PSI. 30 SPM - 680 PSI. #2 Pump , 20 SPM - 330 PSI, 30 SPM - 520 PSI. Directional Drill 6 3/4" hole from 8308 - 9408' (1100'). TVD = 3503". ADT = 7.67 HRS. PU WT = 125K, SO WT = 60K, ROT WT = 81 K. Torque on bottom = 6K, off bottom = 7K. 120 Rpm's. WOB = 5-10K. Pumps at 280 GPM's - 2600 PSI. ECD = 10.75 PPG. Max Gas = 90 Units. MOBM @ 9.0 PPG Vis = 75, YP = 19, Gels = 18132, Total BIT HRS = 8.27 Continue Directional Drill 6 3/4" hole from 9408' - 10602' (1194'). TVD = 3583". ADT = 7.46 HRS. PU WT = 136K, SO WT = 54K, ROT WT = 86K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 280 GPM's - 2825 PSI. ECD = 11.50 PPG. Max Gas = 189 Gnits.Jar = 15.73 HRS, Total Bit HRS = 15.73, MOBM @ 9.0 PPG Vis = 86, YP = 21, Gels = 19/31 '"`*"'Note: We drilled +/- 230 feet of shale out of shoe, then 150' of sand, and back into shale for +/- 200 tt. Geologist stopped and re-evaluated 3 times, discussing plan with town. Decision to keep drilling as per Geo. Also observed ABI tool readings 2.88 degrees avg, OFF from MWD surveys. DD's compensated for this. SPR's= Pump#1 - 20 SPM - 720 PSI, 30 SPM = 860 PSI. Pump #2 - 20 SPM = 530 PSI, 30 SPM = 700 PSI. Continue Directional Drill 6 3/4" hole from 10602' - 11705' (1103'). TVD = 3561". ADT = 7.15 HRS. PU WT = 150K, SO WT = 50K, ROT WT = 82K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 291 GPM's - 3050 PSI. ECD = 11.70 PPG. Max Gas = 264 Units.Jars = 22.88 HRS, Total Bit HRS = 22.88, MOBM @ 9.0 PPG Vis = 84, YP = 21, Gels = 25/33 104 BBLS fluid loss Pumping Hi-Visc weighted sweeps to clean hole & control ECD MAx ECD = 12.3 PPG. Continue Directional Drill 6 3/4" hole from 11705 - 12150' (1075'). TVD = 3580' ADT = 3.63 HRS. PU WT = 158K, SO WT = 55K, ROT WT = 90K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 295 GPM's - 3400 PSI. ECD = 12.3 PPG. Max Gas = 264 Units, MOBM @ 9.0 PPG Con't to Pump Hi- Visc weighted sweep @ 295 GPM's - 3400 PSI to clean hole and control ECD's. Observed 250% increase in cuttings on shakers and hole parameters cleaned up. ECD @ 11.56 PPG Printed: 70/21lZVVS 2:52:;iV PM ConocoPhillips Alaska Operations Summary Report Legal Welj Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code ! Phase 8/29/2005 17:30 - 23:15 5.75 DRILL DRLG PROD 23:15 - 00:00 0.75 DRILL CIRC PROD 18/30/2005 100:00 - 04:15 I 4.25 DRILL I DRLG I PROD 04:15 - 05:45 1.501 DRILL I CIRC I PROD 05:45 - 06:00 0.25 DRILL OBSV PROD 06:00 - 13:45 7.75 DRILL REAM PROD 13:45 - 15:30 I 1.751 DRILL I CIRC I PROD 18/31 /2005 18:30 - 19:45 1.25 DRILL I C RI C PROD 19:45 - 21:30 1.75 DRILL CIRC PROD 21:30 - 21:45 0.25 DRILL OBSV PROD 21:45 - 00:00 2.25 DRILL TRIP PROD 00:00 - 04:00 4.00 DRILL TRIP PROD 04:00 - 06:30 I 2.501 DRILL I PULD I PROD 06:30 - 07:00 0.50 CASE RURD CMPLTN 07:00 - 07:15 0.25 CASE SFTY If CMPLTN 07:15 - 12:30 5.25 CASE PULR CMPLTN 12:30 - 13:00 I 0.501 CASE I PULR I CMPLTN Page 12 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Continue Directional Drill 6 3/4" hole from 12150' - 12602' (452'). TVD = 3605' ADT = 4.14 HRS. PU WT = 173K, SO WT = 62K, ROT WT = 103K. Torque on bottom = 9K, off bottom = 10K. 120 Rpm's. WOB = 4-8K. Pumps at 295 GPM's - 3650 PSI. ECD = 11.74 PPG. Max Gas = 212 Units. Jars = 30.64 HRS, Total Bit HRS = 30.64, MOBM @ 9.0 PPG Vis = 78, YP = 21, Gels = 25/33 Pumping Hi-Visc weighted sweeps to clean hole & control ECD MAX ECD = 12.3 PPG. Slow pump Rates @ 12240'. TVD = 3585'. #1 = 20 SPM - 680 PSI, 30 SPM - 880 PSI. #2 = 20 SPM - 610 PSI, 30 SPM - 800 PSI. Con't to Pump Hi- Visc weighted sweep @ 295 GPM's - 3600 PSI to clean hole and control ECD's. Observed 300% increase in cuttings at shakers, and hole parameters cleaned up. ECD @ 11.74 PPG Drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 12,602'to 12,995' MD/ 3,654' TVD (393') (T.D.) ADT 2.89 hrs, 4-8K wob, 120 rpm's, 83 spm, 295 gpm at 3,800 psi, off btm torque 10K ft-Ibs, on btm 9K fl-Ibs, rot wt 105K, up wt 195K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 90 units, max gas 195 units Pumped 35 bbl weighted hi vis sweep and circ out of hole, circ hole at 295 gpm, 3,800 psi and 120 rpm's with 10K ft-Ibs torque, ECD 11.8 ppg after circ out sweep Monitored well-static, took SPR's Backreamed out of hole from 12,995' to 8,214' with no problems (csg shoe @ 8,224'), BROOH at 120 rpm's, 9-10K ft-Ibs torque, 295 gpm, initial circ press 3,700 psi, final circ press 2,700 psi Pumped 35 bbl weighted hi vis sweep at csg shoe and circ hole clean, had 50% increase in cuttings back from sweep, circ a total of 3X btms up and was clean at shakers, circ at 295 gpm at 2,600 psi, monitored well-static RIH from 8,214' to btm at 12,995' with no problems Pumped 35 bbl weighted hi vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ hole at 295 gpm, 4,000 psi and 120 rpm's Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, rotated DP at 120 rpm's and circ at 295 gpm at 4,000 psi Monitored well-static, dropped 1 3/4" rabbit on a wire POOH on elevators with BHA #9 from 12,995' to 10,341' Cont POOH with BHA #9 from 10,431' to BHA at 370', monitored well at shoe, well-static Stood back HWDP and jars, downloaded MWD and LD same with Geo-pilot, cleared rig floor, talc fill on trip out of hole 91 bbls, actual fill 98 bbls RU Doyon's 4 1/2" liner running equipment Held PJSM on running of liner PU and ran 4 1/2" liner per well program to 5,673', ran 4 1/2" ROT silver bullet guide shoe with no float, 184 jts, (5,673') of 4 1 /2" 12.6#, L-80, BTCM liner, placed blank liners across shale sections per geology, ran 90 jts (2,782') of blank liner and 94 jts (2,889') of slotted liner, ran 152- 4 1/2" x 6 114" spiralgtide centralizers 1/jt jt #1 to Jt #165, ran 13 constrictor packers placed on blank liner to isolate shale sections per geology, did not run any centralizers on jts with constrictor packers. MU Baker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" Z:XP liner top packer and RIH to 5,741', st wt up 75K, do wt 55K (blk wt 35K) Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 13 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date :From - To Hours Code Code'. Phase 8/31/2005 113:00 - 14:15 I 1.251 CASE I RUNL ~ CMPLTN 14:15 - 14:30 I 0.251 CASE I CIRC I CMPLTN 14:30 - 17:30 I 3.00 I CASE I RUNL ~ CMPLTN 17:30 - 18:30 I 1.001 CASE I OTHR I CMPLTN 18:30 - 18:45 0.25 CASE DEQT CMPLTN 18:45 - 19:00 0.25 CASE OTHR CMPLTN 19:00 - 20:15 1.25 DRILL TRIP CMPLTN 20:15 - 21:15 1.00 RIGMNT RSRV CMPLTN 21:15 - 23:15 2.00 DRILL TRIP CMPLTN 23:15 - 00:00 0.75 DRILL PULD CMPLTN 19/1/2005 00:00 - 00:30 0.50 DRILL ~ PULD CMPLTN 00:30 - 01:00 0.50 WELCT OTHR CMPLTN 01:00 - 05:00 4.00 WELCT BOPE CMPLTN 05:00 - 05:30 0.50 WELCT OTHR CMPLTN 05:30 - 05:45 0.25 WINDO FTY CMPLTN 05:45 - 09:00 3.25 WINDO ULD PROD2 703:45 - 14:30 0.75 WINDO~THR PROD2 14:30 - 15:15 I 0.751 WINDOVVTRIP I PROD2 15:15 - 16:00 I 0.751 WINDOV~SETW PROD2 16:00 - 17:00 I 1.001 WINDOVYICIRC I PROD2 17:00 - 00:00 I 7.001 WINDOVY/STWP I PROD2 9/2/2005 00:00 - 01:00 I 1.00 ~ WINDOVy/CIRC I PROD2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations __ _ _ _ RIH with liner on 4" XT-39 DP from 5,741' to 8,160' (7 5/8" Csg shoe @ 8,224') Circ a DP cap at csg shoe, pumped 40 bbls of 9.0 ppg SFMOBM at 180 gpm at 350 psi, st wt up 98K, do wt 55K Cont to run 4 1/2" liner in open hole, RIH from 8,160' and tagged btm at 12,995' with no problems, PU to 12,975', st wt up 160K, do wt 60K, Note: RIH with 65 stds of 4" DP with Lo-Tads, 13 stds of Hybrid push pipe and 1 std of slick DP to set 4 1 /2" liner Dropped 1 3/4" ball and pumped down to seat, pumped at 2 bpm at 300 psi, with ball on seat pressured up to 1,600 psi to set Flexlock hanger, slacked off 25K, cunt to set packer, pressured up to 4,000 psi and set ZXP packer, no problems setting hanger/packer, set "A2" sand liner with TOL @ 7,246' MD/ 3,311' TVD and shoe at 12,975' MD 3,653' TVD; st wt up after setting liner 125K, lost 35K st wt RU & tested annulus above ZXP packer to 1,000 psi for 5 min and ck ok Monitored well-static POOH from 7,246' to 4,800' Slipped and cut 78' of drlg line Cont to POOH with liner running tool from 4,800' to 40' Made service breaks and LD Baker Liner running tool, calc fill on trip out of hole 51 bbls, actual 54 bbls Fin LD Baker liner running tool and cleared rig floor Pulled wear bushing RU & Tested BOP's, tested annular, rams, valves and manifold to 250 psi low and 3,000 psi high, no problems, NOTE: Chuck Scheve with AOGCC waived witnessing of test Pulled test plug and installed wear bushing Held PJSM on PU & MU of whipstock milling assembly MU Baker 7 5/8" whipstock assembly BHA #10 and RIH to 389', MU milling assembly and LD same, PU seal assembly, locator sub, flex pup jt, 2-jts 3 1/2" DP and unloader sub for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 2-bumper subs and 2 stds 4" Hybrid push pipe to 389' RIH with whipstock assembly from 389' to 6,405' Made MADD pass from 6,405' to 6,483' (6,230' to 6,310' sensor depth) and correlated MWD to K-13 sand RIH with whipstock assembly from 6,483' to 7,200', st wt up 130K, do wt 82K Oriented whipstock to 6 deg left of high side, RIH, tagged TOL at 7,246', set whipstock and sheared off from same, set top of whipstock at 7,145' Displaced hole over from 9.0 ppg SFMOBM to 9.0 ppg MOBM, Circ at 250 gpm at 2,000 psi Milled window in 7 5/8" csg for "B" Lateral, top of window at 7,145', btm of window at 7,157', drilled 6 3/4".hole to 7,187' MD/ 3,300' TVD (42'), 2-8K wob, 78-95 rpm's, 275 gpm, 2,500 psi, rot wt 92K, up wt 130K, do wt 82K, 5-8K ft-Ibs torque, pumped 2-15 bbl weighted hi vis sweeps while milling window with no increase in cuttings back. Pumped 35 bbl weighted hi vis sweep and circ hole clean after milling window, worked mills thru window while circ hole clean, circ at 266 gpm at 2,200 psi, rot wt 95K, up wt 125K, do wt 83K, no increase in cuttings rnn[ea: -i we u~~~o t:oco~rm • • ConocoPhillips Alaska Page 14 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date .From - To Hours Code Coe Phase 9/2/2005 00:00 - 01:00 1.00 WINDO IRC PROD2 01:00 - 01:15 0.25 WINDO THR PROD2 01:15 - 04:00 2.75 WINDO RIP PROD2 04:00 - 05:30 I 1.50 I WINDOVUPULD I PROD2 05:30 - 07:00 1.501 WINDOV~/OTHR I PROD2 07:00 - 08:30 1.50 RIGMNT RSRV PROD2 08:30 - 11:45 3.25 DRILL PULD PROD2 11:45 - 15:00 3.25 DRILL TRIP PROD2 15:00 - 15:15 0.25 DRILL REAM PROD2 15:15 - 00:00 I 8.751 DRILL I DRLG I PROD2 19/3/2005 100:00 - 12:00 12.001 DRILL DRLG PROD2 12:00 - 00:00 I 12.00 I DRILL I DRLG I PROD2 19/4/2005 100:00 - 12:00 I 12.00 I DRILL I DRLG I PROD2 12:00 - 00:00 I 12.00 I DRILL DRLG I PROD2 9/5/2005 100:00 - 12:00 ~ 12.00 ~ DRILL ~ DRLG I PROD2 12:00 - 00:00 ~ 12.00 ~ DRILL I DRLG ~ PROD2 Spud Date: 8/13/2005 Start: 8/13/2005 End:. Rig Release: Group: Rig Number: Description of Operations back from sweep Monitored well-static, took spr's and pumped dry job POOH with BHA #10 from 7,187', stood back hybrid push pipe POOH to MWD at 38' Downloaded MWD and LD same along with milling assembly, upper mill was in gauge Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing Changed out 4" XT-39 saver sub on top drive and serviced same MU 6 3/4" Geo-pilot BHA #11 and RIH to 370', MU new bit #6, Geo-pilot with MWD only, uploaded MWD and RIH with NMFDC's, HWDP and jars to 370' RIH with BHA #11 from 370' to 7,088' (TOW @ 7,145') Washed down from 7,088' thru top of window at 7,145' and cont to btm at 7,187', no problems going thru window, rot wt 79K, up wt 99K, do wt 65K Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 7,187' to 7,540' MD/ 3,317' TVD (353'), ADT 7.05 hrs, 5-14K wob, 120 'rpm's, 83 spm, 295 gpm, 2,650 psi, off btm torque 7K ft-Ibs, on btm 6K ft-Ibs, rot wt 79K, up wt 122K, do wt 55K, 9.05 ppg MOBM, ave ECD 10.8 ppg, ave BGG 25 units, max gas 66 units, drilling thru numerous concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 7,540' to 8,463' MD/ 3,338' TVD (923'), ADT 9.04 hrs, 5-8K wob, 120 rpm's, 84 spm, 298 gpm, 2,800 psi, off btm torque 8K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 125K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.2 ppg, ave BGG 25 units, max gas 83 units Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 8,463' to 9,081' MD/ 3,355' TVD (618'), ADT 10.08 hrs, 5-17K wob, 120 rpm's, 84 spm, 298 gpm, 2,900 psi, off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 78K, up wt 133K, do wt 53K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 40 units, max gas 105 units, cont to drill thru numerous concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 9,081' to 9,901' MD/ 3,383' TVD (820'), ADT 9.22 hrs, 5-15K wob, 120 rpm's, 84 spm, 298 gpm, 3,000 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 135K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.45 ppg, ave BGG 30 units, max gas 403 units from apprx 9,470'. NOTE: Rig off highline at 02:00 hrs and back on highline at 10:00 hrs Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 9,901' to 10,895' MD/ 3,406' TVD (994'), ADT 8.99 hrs, 5-17K wob, 120 rpm's, 84 spm, 298 gpm, 3,150 psi, off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt 77K, up wt 140K, do wt 53K, 9.05 ppg MOBM, ave ECD 11.8 ppg, ave BGG 40 units, max gas 166 units, pumped 30 bbl wt'd hi vis sweep at 10,532' with no increase in cuttings back from the sweep, cont to drill thru concretions, approx 15% of "B" lateral has been concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 10,895' to 11,531' MD/ 3,418' TVD (636'), ADT 9.62 hrs, 5-15K wob, 120 rpm's, 84 spm, 298 gpm, 3,125 psi, off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt SOK, up wt 145K, do wt 48K, 9.0 ppg MOBM, ave ECD 11.8 ppg, ave BGG 40 units, max gas 204 units Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 15 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code' Phase __ _ _. 9/5/2005 112:00 - 00:00 12.00 DRILL I DRLG I PROD2 9/6/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 12:15 0.25 DRILL OBSV PROD2 12:15 - 20:45 I 8.501 DRILL REAM PROD2 20:45 - 22:15 1.501 DRILL CIRC ~ PROD2 22:15 - 23:15 1.00 RIGMNT RSRV PROD2 23:15 - 00:00 0.75 DRILL TRIP PROD2 19/7/2005 100:00 - 04:30 I 4.501 DRILL I TRIP I PROD2 04:30 - 04:45 0.251 DRILL I REAM I PROD2 04:45 - 07:00 I 2.25 DRILL CIRC PR002 07:00 - 09:00 2.001 DRILL I CIRC PROD2 09:00 - 09:15 0.25 DRILL OBSV PROD2 09:15 - 13:45 4.50 DRILL TRIP PROD2 13:45 - 14:00 0.25 DRILL OBSV PROD2 14:00 - 16:00 2.00 DRILL TRIP PROD2 16:00 - 18:45 2.75 DRILL PULD PROD2 Description of Operations 11,531' to 12,431' MD/ 3,456' ND (900'), ADT 8.17 hrs, 4-17K wob, 120 rpm's, 84 spm, 298 gpm, 3,450 psi, off btm torque 11 K ft-Ibs, on btm 9.5K ft-Ibs, rot wt 90K, up wt 163K, do wt 50K, 9.05 ppg MOBM, ave ECD 12.0 ppg, ave BGG 40 units, max gas 86 units, began using hybrid push pipe at 11,878', cont to drill thru concretions, approx 12% of "B" lateral has been concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 12,431' to 12,967' MD/ 3,480' TVD (536'), (T.D.) ADT 8.2 hrs, 4-17K wob, 120 -130 rpm's, 79 spm, 281 gpm, 3,200 psi, off btm torque 11 K ft-Ibs, on btm 10K ft-Ibs, rot wt 95K, up wt 165K, do wt 50K, 9.0 ppg MOBM, ave ECD 11.75 ppg, ave BGG 30 units, max gas 75 units, TD well with hybrid push pipe, cont to drill thru concretions, approx 11 % of "B" lateral was concretions (621'), pumped weight hi vis sweep on last std and had 20-30% increase in cuttings back from sweep, crossed fault at 12,050' and while drilling below 12,550' began to have slight mud losses slowed pump rate and losses decreased, Geo-pilot began having trouble holding tool face from 12,512' to TD, was able to TD well in the target Monitored well for 15 min, well breathed back 19 bbls of mud, initial rate was 5 bpm, final rate after 15 min .3 bpm Backreamed out of hole from 12,967' to 7,245', then pumped out of hole to 7,100' to above TOW at 7,145', no problems pulling thru window, BROOH at 120 rpm's and 225 gpm at 2,350 psi, no problems BROOH, monitored well every 1,000' and well was breathing Blighty up to 8,092' where well was static, talc fill 45.5 bbls actual fill 70 bbls Pumped 30 bbl weighted hi vis sweep and circ hole clean above TOW, circ at 265 gpm, 2,200 psi and 120 rpm's with 7K ft-Ibs torque, had no increase in cuttings back from sweep and circ an add. btms up after sweep was out of the hole and was clean at shakers, rot wt 79K, up wt 117K, do wt 64K 'Slip and cut 56' of drlg line and service top drive, monitored well while servicing rig and well was static RIH slow from 7,100' thru window at 7,145' with no problems and cont RIH to 7,440', lost 258 bbls of 9.0 ppg MOBM to hole last 24 hrs Cont RIH from 7,440' and set down at 12,602', washed down 1 std to 12,694' and cunt RIH to 12,879' with no problems Washed and reamed down from 12,879' to btm at 12,967' (88'), washed down at 62 spm, 220 gpm at 2,450 psi, 120 rpm' with 10K ft-Ibs torque Pumped 35 bbl weighted (1 Ib over) hi vis sweep and circ out of hole, had no increase in cuttings back from the sweep, circ an add. btms up and was clean at shakers, circ at 220 gpm at 2,500 psi, 120 rpm's with 10K ft-Ibs torque, rot wt 95K, up wt 170K, do wt 45K with pumps on, Held PJSM with rig crew and ASRC vac truck drivers on changing over to SFMOBM Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 220 gpm at 2,200 psi and 120 rpm's Monitored well-static, took SPR's POOH wet on elevators from 12,967' to 6,883', no problems pulling thru window at 7,145' Monitored well at 6,883' and well was static Cont POOH with BHA #11 from 6,883' to BHA at 369' POOH standing back HWDP, jars and NMFDC's, downloaded MWD and LD same along with Geo-pilot and bit, cleared rig floor, talc fill on rnnte°: iuinrzuu5 z:ozsu rm • ConocoPhillips Alaska Page 16 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code'. Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9R/2005 16:00 - 18:45 2.75 DRILL PULD PROD2 trip out of hole 87.75 bbls, actual 110.5 bbls 18:45 - 19:30 0.75 FISH PULD CMPLT2 MU whipstock retrieving BHA #12 and RIH to 60' 19:30 - 22:30 3.00 FISH TRIP CMPLT2 RIH with BHA #12 from 60' to 7,100', st wt up 127K, do wt 71 K, RIH with BHA on 4 stds of hybrid push pipe, 65 stds of 4" DP with to-tads and 5 stds of hybrid push pipe 22:30 - 00:00 1.50 FISH FISH CMPLT2 Worked and rotated retrieving hook attempting to engage hook and after 16 attempts est. circ and washed around top of whipstock after 2nd attempt engaged whipstock slot at 7,144' and worked jars up to 200K, (73K over) then pulled up to 215K after jars went off and after 2nd hit on jars whipstock came free 9/8/2005 00:00 - 00:45 0.75 FISH CIRC CMPLT2 Circ btms up after pulling whipstock loose, circ at 242 gpm at 1,100 psi, st wt up 135K 00:45 - 01:00 0.25 FISH OTHR CMPLT2 Monitored well-static, dropped 1 13/16" rabbit on a wire 01`.00 - 05:00 -4.00 FISH TRIP CMPLT2 POOH with whipstock assembly from 7,145' to 60' 05:00 - 07:00 2.00 FISH PULD CMPLT2 LD whipstock retrieving BHA #12 then LD whipstock assembly with 2 jts of 3 1/2" DP and seal assembly, cleared rig floor, talc fill on trip out of hole 39 bbls, actual 46 bbls 07:00 - 07:45 0.75 CASE RURD CMPLT2 RU Doyon's 4 1/2" liner running equipment 07:45 - 08:00 0.25 CASE SFTY CMPLT2 Held PJSM with rig crew, tong operator and Baker Rep on liner running detail and associated hazards 08:00 - 12:30 4.50 CASE PULR CMPLT2 PU &RIH with 4 1/2" liner per well plan to 5,768', ran 3 1/2" ROT guide shoe, 1 bent jt of 3 1/2" 9.3# L-80 Liner with XO to 4 1/2", ran 24 jts (738') of 4 1/2" 12.6#, L-80 slotted liner, 5 jts (155') of 4 1/2" 12.6#, L-80 blank liner with 2-constrictor packers, then RIH with 156 jts slotted (4,792') and 2 pups and 1 jt of 4 1/2" blank liner (50'), ran 1-4 1/2" x 6 1/4" x 8" straight blade aluminum centralizer per jt (184 total) total liner RIH 5,768'. 12:30 - 13:15 0.75 CASE PULR CMPLT2 MU Bakers 7 5/8" x 4 1/2" hook hanger assembly ~ RIH to 5,809', st wt up 78K, do wt 54K, RD liner running equip. 13:15 - 17:45 4.50 CASE RUNL CMPLT2 RIH with 4 1/2" liner on 4" DP from 5,809', RIH thru window at 7,145' on 1st attempt, cont RIH and liner stopped at 11,044', st wt up 128K, do wt 35K (blk wt) 17:45 - 19:30 1.75 CASE OTHR CMPLT2 Attempted to work liner thru hard spot at 11,044' with no success, POOH 5 stds with liner to 10,644' to PU add. wt pipe and Lo-tads 19:30 - 20:00 0.50 CASE OTHR CMPLT2 PU add. Lo-tads to rig floor and strapped HWDP in pipe shed 20:00 - 22:45 2.75 CASE RUNL CMPLT2 Cont RIH with 4 1/2" liner from 10,644' to 11,617', st wt up 165K, do wt 35-40K, PU a total of 8 stds of HWDP with 2 Lo-Tads per std while RIH to 11,617', having to work liner down, liner went thru spot at 11,044' ok then sat down solid at 11,170, worked thru and sat down again at 11,468' and worked thru after approx 15 min's, cont to work liner to 11,617', decision was made to POOH and inspect liner. 22:45 - 00:00 1.25 CASE OTHR CMPLT2 POOH with 4 1/2" liner from 11,617' to 11,033', having to remove 1-Lo-tad per std of HWDP in order to set back NOTE: Rig off highline at 0800 hrs and back on highline at 18:15 hrs to install VSM's on J pad 9/9/2005 00:00 - 02:30 2.50 CASE RUNL CMPLT2 Cont POOH with 4 1/2" liner on 4" DP from 11,033' to 5,809' (hook hanger) 02:30 - 03:00 0.50 CASE OTHR CMPLT2 LD excess Lo-tads from rig floor 03:00 - 03:30 0.50 CASE RURD CMPLT2 RU Doyon's 4 1/2" liner handling equip, and held PJSM on LD liner 03:30 - 11:30 8.00 CASE OTHR CMPLT2 POOH LD Bakers 7 5/8" x 4 1/2" hook hanger and 186 jts of 4 1/2" liner, recovered 178 of 184 aliminum centralizers RIH, left in hole 3 full and 3 half pieces of centralizers (Total of 9 halfs), recovered both constrictor ', packers, they were in good condition and hadn't moved on the pipe 11:30 - 12:30 1.00 CASE RURD CMPLT2 RD Doyon's 4 1/2" liner handling equip. and cleared rig floor rnncea: wicvzwo [:az:av rm • • ConocoPhillips Alaska Page 17 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date 'From - To Hours Code Phase Code 9/9/2005 12:30 - 14:15 1.75 FISH PULD CMPLT2 14:15 - 16:45 2.50 FISH TRIP CMPLT2 16:45 - 17:15 0.50 FISH WASH CMPLT2 17:15 - 18:15 1.00 FISH CIRC CMPLT2 18:15 - 18:45 0.50 FISH CIRC CMPLT2 18:45 - 19:00. 0.25 FISH CIRC CMPLT2 19:00 - 21:15 2.25 FISH TRIP CMPLT2 21:15 - 22:30 1.25 FISH PULD CMPLT2 22:30 - 00:00 1.50 FISH OTHR CMPLT2 9/10/2005 00:00 - 00:30 0.50 CASE RURD CMPLT2 00:30 - 00:45 0.25 CASE SFTY CMPLT2 00:45 - 04:00 3.25 CASE PULR CMPLT2 04:00 - 04:30 0.50 CASE PULR CMPLT2 04:30 - 05:00 0.50 CASE RURD CMPLT2 05:00 - 09:45 4.75 CASE RUNL CMPLT2 09:45 - 11:30 1.75 CASE RUNL CMPLT2 11:30 - 12:30 1.00 CASE CIRC CMPLT2 12:30 - 12:45 0.25 CASE RUNL CMPLT2 12:45 - 13:30 0.75 CASE CIRC CMPLT2 13:30 - 13:45 0.25 CASE OTHR CMPLT2 13:45 - 16:00 2.25 CASE RUNL CMPLT2 16:00 - 16:30 0.50 CASE OTHR CMPLT2 16:30 - 17:30 1.00 RIGMNT RSRV CMPLT2 17:30 - 18:45 1.25 FISH PULD CMPLT2 Description of Operations MU Baker fishing BHA #13 and RIH to 137', MU 6 3/4" rev junk basket with 3 boot baskets and bumperjars, 2-4 3/4" Dc's and 1 jt of HWDP RIH with BHA #13 from 137' and set down at btm of window at 7,157' Reamed thru tight spot at 7,157' to 7,159', 3-4K wob, 25 rpm's, 47 spm, 167 gpm at 600 psi, 4-5K torque, rot wt 75K, up wt 103K, do wt 63K Dropped 7/8" steel ball and cunt to circ ball on seat while washing down from 7,159' and tagged top of A2 liner at 7,246', set 5K wt down on TOL with 25 rpm's and 4-7K torque and would not drill off, circ at 71 spm, 252 gpm at 1,600 psi Cont to circ hole working junk baskets, cycled pumps 8 times Pumped out of hole from 7,246' to 7,062' to work junk basket to above TOW at 7,145', circ at 252 gpm at 1,600 psi Monitored well-static, POOH with BHA #13 from 7,062' to BHA at 137' Stood back HDP and Dc's and LD BHA #13, recovered several-large pieces of aluminum centralizers from rev junk basket, no recovery in boot baskets, junk weighted approx 8 Ibs or equivelant to 1 1/4 centralizer, cleared rig floor Pulled wear bushing and installed test plug, drained stack and functioned rams checking forjunk in stack and found none, pulled test plug and installed wear bushing RU Doyon's 4 1/2" liner running equipment Held PJSM with rig crew, tong operator and Baker rep on liner detail and potential hazards PU &RIH with 4 1/2" liner per well plan to 5,557', ran 3 1/2" ROT guide shoe, 1 bent jt of 3 1/2" 9.3# L-80 Liner with XO to 4 1/2", ran 25 jts (769') of 4 1/2" 12.6#, L-80 slotted liner, 4 jts (124') of 4 1/2" 12.6#, L-80 blank liner with 2-constrictor packers, then RIH with 150 jts slotted (4,602') and 3 blank pups for spacing out, total liner RIH 5,557'. MU Baker 5 1/2" x 4 1/2" setting sleeve and RIH to 5,316', st wt up 74K, do wt 54K, rotated liner at 20 rpm's with 2K ft-fbs torque RU Doyon's 4 1/2" liner running equipment and cleared rig floor RIH with 4 1/2" liner on 4" DP from 5,613' to 11,617', no problems RIH thru window, went thru on 1st attempt, cont RIH to 11,617', st wt up at TOW (7,136') 75K, do wt 54K, rotated liner at 20 rpm's with 3K ft-Ibs torque, Note: 11,617' was the deepest liner was ran on 1st trip. Cont RIH with liner from 11,617' to btm at 12,967', RIH with no problems or rotation, st wt up 165K, do 63K, NOTE: Held Pad Evacuation drill with rig and construction crews Dropped 29/32" ball and pumped down to seat, pumped down at 3 bpm at 525 psi, with ball on seat pressured up to 2,600 psi to release HR running tool, slacked off then pressured up to 3,900 psi to blow ball seat, PU and was released from liner, st wt up 135K, slacked off and tagged TOL at 7,362' POOH from 7,362' to 7,094', POOH thru window with no problems (TOW @ 7,145') Circ btms up at 7,094' above TOW, circ at 213 gpm at 1,000 psi Monitored well-static POOH with running tool from 7,094' to running tool at 28' LD liner running tool and cleared rig floor, calc fill on trip out of hole 48 bbls, actual 52 bbls Slip and cut 72' of drilling line and serviced top drive MU Baker fishing BHA #14 and RIH to 137', MU 6 3/4" rev junk basket with 3 boot baskets and bumper jars, 2-4 3/4" Dc's and 1 jt of HWDP Nnntea: ~uilv~uw l:sL:su rnn • • ConocoPhillips Alaska Page 18 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/10/2005 118:45 - 20:45 2.00 ~ FISH ~ TRIP ~ CMPLT2 20:45 - 21:30 0.751 FISH WASH CMPLT2 21:30 - 21:45 0.25 FISH CIRC CMPLT2 21:45 - 22:00 0.25 FISH OTHR CMPLT2 22:00 - 00:00 2.00 FISH TRIP CMPLT2 9/11/2005 00:00 - 00:30 0.50 FISH TRIP CMPLT2 00:30 - 01:30 1.00 FISH PULD CMPLT2 01:30 - 03:00 I 1_.501 FISH I PULD CMPLT2 03:00 - 05:30 I 2.50 I FISH TRIP I CMPLT2 05:30 - 06:30 1.001 FISH WASH CMPLT2 06:30 - 06:45 0.25 FISH OTHR CMPLT2 06:45 - 09:30 2.75 FISH TRIP CMPLT2 09:30 - 12:00 2.50 FISH PULD CMPLT2 12:00 - 12:30 0.50 CASE RURD CMPLT2 12:30 - 12:45 0.25 CASE SFTY CMPLT2 12:45 - 15:00 2.251 CASE PULR CMPLT2 15:00 - 18:30 3.501 CASE RUNL CMPLT2 18:30 - 20:45 I 2.251 CASE I OTHR I CMPLT2 20:45 - 00:00 3.251 CASE OTHR CMPLT2 9/12/2005 100:00 - 00:45 I 0.751 CASE I CIRC I CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations RIH with BHA #14 from 137' to 7,070', (TOW @ 7,145') st wt up 108K, do wt 62K, rot wt 76K, 25 rpm's with 5K torque Washed down from 7,070' and tagged top of liner at 7,246', didn't see anything at BOW at 7,157', worked reverse junk basket on TOL with 5K wob, 25 rpm's, 5-7K torque and wouldn't drill off, circ at 337 gpm at 2,800 psi Pumped out of hole from 7,246' to above TOW to 7,130' Monitored well-static POOH with BHA #14 from 7,130' to 2,425' Cont POOH with 6 3/4" rev junk basket on BHA #14 from 2,425' to 137' Stood back 1 std of hybrid push pipe and LD 6 3/4" reverse junk basket, had no recovery in basket, broke out 6 3/4" basket and LD same MU 4 5/8" reverse junk basket on BHA #15 and RIH to 197', MU reverse junkbasket onto 2 jts of 2 7/8" PAC DP and RIH with 3-boot baskets; jars and 1 std of hybrid push pipe. RIH with BHA #15 ftom 197' to 7,220', est circ and rotation, circ at 163 gpm at 700 psi, 25 rpm's with 5K ft-Ibs torque, st wt up 110K, do wt 60K rot 76K Washed and rotated down from 7,220' thru TOL at 7,246' to 7,250', washed down only from 7,250' and started to take 2-3K wt down, PU to 7,250' and washed and rotated down from 7,250' and tagged XO below CSR at 7,297', set 3K wt down on XO and wouldn't drill off, washed down at 71 spm, 252 gpm at 1,450 psi, 25 rpm's with 4-6K torque, PU and washed down to XO again with no fill, pumped out of hole to 7,223' to above TOL at 7,246' Monitored well-static POOH with BHA #15 from 7,223' to BHA at 197' Stood back 1 std of hybrid push pipe and LD 4 5/8" reverse junk basket, had no recovery in basket, broke out and LD remaining BHA, recovered 2 cups of fine sand, small pieces of metal and aluminum in boot baskets, cleared rig floor RU Doyon's liner running equipment Held PJSM with rig crew and Baker rep on running of hook hanger assembly MU 7 5/8" x 4 1 /2" hook hanger assembly with ECP packer and 90' of 2 3/8" inner string RIH to 265' RIH with hook hanger assembly from 265' and tagged XO below AZ lateral CSR at 7,302.5', (5.49' low), wt up 130K, do wt 78K, PU to top of window at 7,145' Worked hook hanger and bent jt from top of window at 7,145' tagging up on XO of A2 lateral at 7,302.5', after 9 attempts worked hook hanger assembly thru window RIH with hook hanger assembly and tagged up on XO of 5 1/2" setting sleeve at 7,405' (0.13' low) PU and attempted to hook hanger on calc depth with no hook, RIH and hooked hanger 7.53' low after several attempts, after hooking hanger, unhooked and re-hooked 5 times while tagging up on XO each time after unhooking, set 40K down on hook leaving hook assembly bent joint spaced out 2.5' above fully located from 5 1/2" x 4 1/2" XO. Top of hook hanger at 7,148' with end of bent jt at 7,403' Began circ btms up with top of hook hanger at 7,148', circ at 23 spm, 82 gpm at 400 psi, circ while talking to town about setting hook and ECP packer, decision was made to set same. Pnntea: iu2vzuuo rozsurm • • ConocoPhillips Alaska Page 19 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code' Phase 9/12/2005 00:45-01:30 ~ 0.75~CASECIRCCMPLT2 I 101:30 - 02:15 1 0.751 CASE I OTHR I CMPLT2 02:15 - 03:00 I 0.751 CASE I CIRC I CMPLT2 19/13/2005 03:00 - 07:00 4.00 CASE RUNL CMPLT2 07:00 - 08:30 1.50 CASE RUNL CMPLT2 08:30 - 09:45 I 1.251 CASE I PULR I CMPLT2 09:45 - 10:15 0.50 CASE RURD CMPLT2 10:15 - 14:00 3.75 CASE RUNL CMPLT2 14:00 - 15:45 I 1.751 CASE I RUNL I CMPLT2 15:45 - 17:30 1.75 CASE CIRC CMPLT2 17:30 - 17:45 0.25 CASE OTHR CMPLT2 17:45 - 21:30 3.75 CASE RUNL CMPLT2 21:30 - 22:00 0.50 DRILL RIRD CMPLT2 22:00 - 23:00 1.00 CASE PULR CMPLT2 23:00 - 23:30 0.50 CASE RURD CMPLT2 23:30 - 00:00 0.50 WELCT EORP CMPLT2 00:00 - 04:30 4.50 WELCT BOPE CMPLT2 04:30 - 06:15 1.75 CASE OTHR CMPLT2 06:15 - 07:00 0.75 CASE OTHR CMPLT2 07:00 - 09:45 2.75 CASE OTHR CMPLT2 09:45 - 10:15 I 0.501 CASE I OTHR I CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Dropped 29!32" ball and pumped down to seat, began circ at 105 gpm at 475 psi and slowed to 63 gpm at 175 psi, with ball on seat pressured up to 530 psi. Turned over to Dowell and pressure tested lines to 4,500 psi, then pressured up in 300 psi increments and opened up by-pass on ECP at 2,700 psi, pressure decreased to 1,600 psi and by pass closed, monitored for 5 min with no decrease in pressure, bled off to 530 psi and checked tank volume and took .75 bbls to inflate ECP, pressured up to 4,700 psi and blew the ball seat. PU to 7,140' and circ a btms up, circ at 400 gpm at 3,000 psi, monitored well-static POOH with hook hanger running tool from 7,140' to 121' POOH LD running tool and 2 3/8" tubing inner string and cleared rig floor MU "B" sand LEM assembly with ZXP packer, hanger, CSR, LEM and 2 jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, RIH to 217' RD Doyon's 4 1/2" liner running tools RIH with LEM assembly on 4" DP from 217' and tagged up at 7,167', st wt up 135K, do wt 80K Attempted to RIH thru hook hanger and was unable to go deeper than 7,172', made 4 attempts by turning LEM 4 full turns and 2-3/4 turns and was able to work LEM down to 7,167', cont to work LEM by turning at 1/4 turn increments and after 10-1/4 turns work down to 7,172' setting 30-40K st wt down, made 20 additional 1/8 turns and was unable to go deeper, Tagged up a couple times @ 7,153'. Decision was made to ~~ POOH with LEM PU to 7,170' and circ btms up at 30 spm, 106 gpm at 350 psi Monitored well-static POOH with LEM assembly from 7,170' to 217', SLM out with no correction, talc fill on trip out of hole 50 bbls, actual fill 52 bbls RU Doyon's 4 1/2" liner running tools POOH LD ZXP packer, hanger, CSR and LEM, LD 2 jts of 4 1/2" liner with seals, Z:XP and LEM looked new, found mule shoe on seals to be damaged with gouges on OD ~ ID, 4.71" OD mule shoe was egg shaped to approx 4.5", had scarring above mule shoe up into seal area to coincide with gouges on OD of shoe, jt above seals looked ok. RD Doyon's 4 1/2" liner running tools Pulled wear bushing Install test plug. Test BOP's, IBOP's, Floor & Dart Valves, & Choke Manifold Valves. Pull Test plug and install wear bushing. RILDS. Witness of test waived by AOGCC rep John Spaulding. Make up "DUMMY LATCH "assembly on MWD tools. Orient to latch. Make up LEM (14.94'), Crossover (1.42), 4 3/4"Integral Blade stabilizer (5.55'), NM Float sub (2.14'), NM Float Sub (2.35'), DM HOC (8.55'), MWD Gamma ! RES (24.18'), TM HOC (11.28'), and Cross over (1.66). Plug in and upload MWD assembly. Trip in hole with Dummy Latch assembly from 205' - 7156' (6951'). UP WT = 127K. SO WT = 84K. 178 GPM - 1000 PSI. Orient to 86 degrees right, and slack off to observe latch up @ 7156' with 20K set down wt, with orientation reading 11 Degrees left of H.S. Pull up and unlatch @ 23K over, and orient to 107 degrees right of H.S. Slack off, observe latch up @ 7156' with orientation of 8 Degrees left of Printed: 10/21/2005 2:52:30 PM c: ConocoPhillips Alaska Page 20 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/13/2005 ~ 09:45 - 10:15 ~ 0.50 ~ CASE ~ OTHR CMPLT2 I 10:15 - 11:00 I 0.751 CASE i CIRC CMPLT2 11:00 - 12:00 1.00 CASE OTHR CMPLT2 12:00 - 13:45 1.75 CASE OTHR CMPLT2 13:45 - 14:30 0.751 CASE OTHR CMPLT2 14:30 - 14:45 0.25 CASE OTHR CMPLT2 14:45 - 17:00 2.25 CASE OTHR CMPLT2 17:00 - 17:30 0.50 CASE OTHR CMPLT2 17:30 - 18:00 0.50 CASE OTHR CMPLT2 18:00 - 20:45 I 2.751 CASE I OTHR I CMPLT2 20:45 - 00:00 I 3.251 CASE I OTHR I CMPLT2 19/14/2005 100:00 - 00:15 I 0.251 CASE I OTHR CMPLT2 00:15 - 01:00 0.75 CASE CIRC CMPLT2 01:00 - 04:30 3.50 CASE OTHR CMPLT2 04:30 - 06:30 2.00 CASE OTHR CMPLT2 06:30 - 07:00 0.50 CASE OTHR CMPLT2 07:00 - 07:30 0.50 CASE RURD CMPLT2 07:30 - 09:30 2.00 CASE RUNC CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations H.S. Pull up to unlatch with 23K overpull, and orient to 130 Degrees right of H.S., Slack off to observe latch up @ 7156'with a 5 degrees left of H.S. reading, and 20K set down wt. Pull up to 23K over and unlatch again. Total of 3 times with indication of proper orientation of Hook Hanger. Circulate Bottoms up @ 81 SPM, 288 GPM's - 2200 PSI. Obtain Slow pump rates. #1 pump - 20 SPM - 210 PSI, 30 SPM - 400 PSI. #2 Pump - 20 SPM - 190 PSI, 30 -SPM - 390 PSI. Moitor well -Static. POOH from 7156' - 6230' (926'). Observed proper hole fill. Continue POOH with Dummy Latch assembly from 6230' - 72' (6158'). Calculated hole fill = 50 BBLS, actual fill = 55 BBLS. Breakout & Lay down crossover, MWD assembly, and Dummy Latch assembly. BHA total = 72.07' Clean ~ clear floor area, from wet trip. Pull tools to rig floor. Make up 4 1!4" tapered mill assembly. Make up 4 1/4" Tapered mill 2.06'), Crossover (1.43'), 2 - jnts 2 7/8" PAC drill pipe (62.44'), crossover (3.58'), 4 3/4" String Mill (4.34'), 3 - jnts 2 7/8" PAC drill pipe 9 94.07'), crossover to 3 1/2 IF (1.78'), Crossover to 3 1/2 REG 1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover( 2.85'), 4 3/4" Bumper jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover to XT39 1.66') Total BHA = 205.61 Trip in hole from 205' - 1349' (1144'). Check pump pressures. ID of tools = 1". 30 SPM -1000 PSI, then pressure climbed to 2600 PSI. Unplug jet in mill to observe pressure @ 3400 PSI w/ 48 SPM. jTIH to pressure check @ 2992'. 55 SPM - 3300 PSI. TIH to 5023'. 55 SPM - 2800 PSI. TIH to 5893'. 55 SPM - 2900 PSI. TIH to 6815'. 55 SPM - 3400 PSI. Un plugged jet & 58 SPM - 2250 PSI. Tlh to 7162'. Tagged @ 7162 DPM. UP WT = 125K, SO WT = 80K, ROT WT = 95K. 25 RPM's w/ 4-5K torque. Rotate @ 25 rpm's to work through spot @ 7162' with no issues. Observe lithe or no torque increase and continue down to tag crossover in seal bore @ 7302' DPM. Work mills from 7302' - 7271', while circulate btms up. POOH to above Hook Hanger @ 7130', and RIH to tag again at 7162', working mill through with no issues, continuing in hole to tag again at 7302'. POOH to above Hook Hanger @ 7130', and RIH to tag again at 7162', working mill through with no issues, continuing in hole to tag again at 7302'. UP WT = 130K, SO WT = 84K 252 GPM's - 3000 PSI. Circulate bottoms up @ 250 GPM's - 3000 PSI. Monitor well -Static POOH from 7302' - 205' (7097'). Hole taking proper fill. Break out and lay down BHA. Layed down 4 1/4" tapered mill assembly. 4 1/4" Tapered mill (2.06'), Crossover (1.43'), 2 - jnts 2 7/8" PAC drill pipe (62.44'), crossover (3.58'), 4 3/4" String Mill (4.34'), 3 -jnts 2 7!8" PAC drill pipe 9 94.07'), crossover to 3 1 /2 IF (1.78'), Crossover to 3 1/2 REG (1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover( 2.85'), 4 3/4" Bumperjar (7.87'), 4 3/4" Oil jar (11.14'), and crossover to XT39 ( 1.66') Total BHA = 205.61 Observed Little or no wear on mills. Clean and Clear floor area. Pull tools to rig floor. Rig up casing running equipment, tongs, elevators-and slips. Make up B Lateral LEM assembly. Run #2. Make up Seal assembly with bent joint. Change out 5.2" collar to a 4.94" collar (3.27', 43.03'), 1 -jnt 4 1/2 12.6# tbg (30.09'), Camco "D" Nipple (1.52'), 1 -jnt 4 1/2 Printed: 10212005 2:52:30 PM • ConocoPhillips Alaska Page 21 of 29 • Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-168 1 J-168 ROT -DRILLING n1334@ppco.com Doyon 141 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Date From - To Hours Code Code Phase 9/14/2005 107:30 - 09:30 I 2.00 I CASE I RUNG CMPLT2 09:30 - 10:00 10:00 - 12:00 12:00 - 13:45 13:45 - 15:45 15:45 - 19:30 19:30 - 21:30 0.50 CASE RURD CMPLT2 2.00 CASE RUNC CMPLT2 1.75 CASE RUNC CMPLT2 2.001 CASE I RUNC I CMPLT2 3.75 CASE I RUNC CMPLT2 Description of Operations 12.6# tbg (30.82'), 2 - 4 1/2" Pups (3.81', 7.80'), LEM assembly inside Hook Hnager (24.48'), LEM above Hook hanger (10.65"), 2 - 4 1/2" Pup jnts (3.80', 3.82'), Baker casing Swivel (2.45'), XO bushiing 51/2 Hydril x 4 1/2 IBT (1.33'), 109-47 Casing Seal Bore 6.26" OD x 4.75" ID (19.11'), ZXP 5 1/2" x 7 5/8" Liner top Packer (19.05'), Baker Hydraulic setting tool (5.20'), Baker running tool (5.70'), and XO to DP XT39 1.66'). Rig down casing running Equipment, and clear floor. RIH with LEM assembly on DP, from 218' - 3199' (2994'). Continue RIH with LEM assembly on DP from 3199' - 7166' (3967'). Tagged up @ 7166'. UP WT = 127K, SO WT = 82K. Work through spot @ 7166' and continue down to tag again at 7174' DPM. Attempt to work Mule shoe through, could not get down setting down to 25K. Repeat attempts several times to verify Mule Shoe would not pass through spot, while pumping 106 GPM's - 325 PSI. POOH with LEM assembly from 7172' - 217' (6955'). Hole took proper 2.00 ~ CASE ~ RUNC ~ CMPLT2 ~ Rig up casing Equipment. Tongs, elevators and slips. Lay down entire 21:30 - 22:00 0.50 CASE RURD CMPLT2 22:00 - 23:30 1.50 RIGMNT RSRV CMPLT2 23:30 - 00:00 0.50 CASE OTHR CMPLT2 9/15/2005 00:00 - 02:45 2.75 CASE RURD CMPLT2 02:45 - 05:00 2.25 CASE OTHR CMPLT2 05:00 - 08:00 3.00 CASE OTHR CMPLT2 08:00 - 09:45 1.75 CASE OTHR CMPLT2 09:45 - 12:00 2.25 CASE OTHR CMPLT2 12:00 - 13:00 1.00 CASE OTHR CMPLT2 13:00 - 15:45 2.75 CASE OTNR CMPLT2 15:45 - 18:00 2.25 CASE OTHR CMPLT2 .LEM assembly and breakout Casing Swivel form Packer assembly. Observe Mule shoe "pinched" down to 4 1/4" OD, egg shaped and little junk cut damage to OD of mule shoe, and seals. Pictures were taken and sent to town. Rig down casing running Equipment, and clear floor. Slip & cut drilling line, Service Top Drive and inspect saver sub. OK. Pull tools to rig floor and rig up to run 2 7/8 PAC DP for next BHA, Mill run. Clean & Clear rig floor area, Wait on mills from Baker, and pull tools to rig floor. Strap & make up BHA -Milling Assembly. Make up 4 1/4" Tapered mill ( 2.06'), Crossover (1.43'), 2 - jnts 2 7/8" PAC DP (62.44'), Crossover 3.58'), 5 1/4" String Mill (4.36'), Crossover (3.55'), 5 1/4" String Mill 4.75'), Crossover (1.78'), 4 3/4" Float Sub (2.14'), XT39 Crossover 1.65'), 3 - jnts DP (93.36'), Crossover (1.64'), Crossover (1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover (2.85'), 4 3/4" Bumper jar 7.87'), 4 3/4" Oil Jar (11.14'), and Crossover (1.66'). Trip in hole from 218' - 7194' (6976'). Pump down @ 70 SPM - 1900 PSI, while rotating 20-100 RPM's multiple times tagging at 7164' .Observe torque @ 5-6K while rotating. Mill through spot @ 7164' until free. Work mills through spot until free travel with no pumps or rotation. Continue work mills through spot between 7228' - 7236' continuously until observed free travel with no pumps or rotation. Continue RIH to tag crossover in SBE @ 7302'. UP WT = 119 K, SO WT = 78K, ROT WT = 92K, TQ = 4-6K. Continue work string up to 7116' and down to 7206', and tag Crossover at 7302'. UP WT = 125K, SO WT = 80K, ROT WT = 100K. TQ = 5-6K, using pumps at 70 SPM - 1900 PSI. Work up and down with and without pump or rotation to verify clean hole conditions. Pull back to 7190', and RIH to tag crossover again @ 7302', observe clean hole, no tag. Monitor well -static. POOH from 7302' - 218' (7084'). Observe proper hole fill. Breakout & lay down milling BHA. Lay down entire assembly as above, rnncea: iuinizuvo Z:JZ 3V YM • ConocoPhillips Alaska Page 22 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date :From - To Hours Code Code Phase 9/15/2005 15:45 - 18:00 2.25 CASE OTHR CMPLT2 18:00 - 19:30 1.50 CASE RURD CMPLT2 19:30 - 22:45 22:45 - 00:00 9/16/2005 00:00 - 00:15 00:15 - 00:45 00:45 - 01:00 01:00 - 03:45 03:45 - 04:15 04:15 - 04:45 04:45 - 10:00 10:00 - 12:00 12:00 - 14:30 14:30 - 15:15 15:15 - 15:30 3.25 I CASE I RUNC I CMPLT2 1.251 CASE RUNC CMPLT2 0.251 CASE RUNC CMPLT2 0.50 I CASE I RUNC I CMPLT2 0.25 CASE DEQT CMPLT2 2.75 CASE RUNC CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number. Description of Operations and clean junk baskets. Recovered approximately 1/2 cup of metal shavings, and piece of twisted iron 2" long. Mills in gauge to 5 1/4" and in good shape. Clean floor area, RU casing running equipment. Make up B Lateral LEM assembly. Run #3. Make up Seal assembly with bent joint. Change out 5.2" collar to a 4.94" collar (3.27', 43.47'), 1 - In 4 g 30.12'), Camco "D" Nipple (1.52'), 1 -jnt 4 1/2 12.6# tbg (30.84'), 2 - 4 1/2" Pups (3.80', 7.80'), LEM assembly inside Hook Hanger (24.48'), LEM above Hook hanger (10.65"), 2 - 4 1/2" Pup jnts (3.80', 3.82'), XO bushiing 5 1/2 Hydril x 4 1/2 IBT (1.43'), 109-47 Casing Seal Bore 6.26" OD x 4.75" ID (19.11'), ZXP 5 1/2" x 7 5/8" Liner top Packer 19.05'), Baker Hydraulic setting tool (5.21'), Baker running tool (5.70'), and XO to DP XT39 (1.66'). Total BHA = 215.73' Rig down casing running equipment: Trip in hole with B lateral LEM assembly from 216' - 7174' (6958'). Tag up at 7164', and work mule shoe through spot setting down max weight of 20K to get through. Work approximately 1/2 hour. UP WT = 120K, SO WT = 79K. Continue work LEM assembly down to 7290' with no tagging issues. UP WT = 128K, SO WT = 80K. Pick up 1 single of DP to get to bottom. Continue RIH w/ LEM assembly to tag and latch up on Hook Hanger at 7154.56'. Observed this depth = 6' low. Pull up to 15K over upweight to verify good latch up. Slack off to neutral position. UP WT =128K, SO WT = 82K. Seals positioned @ 7299.86'. (3' above crossover). Rig up and drop 1 1!2" Ball down DP pumping @ 3 1!2 BPM - 250 PSI, until ball seated at 55 BBLS pumped. Continue pressure up to 4300 PSI as per BOT rep to set ZXP packer. Hold 5 minutes and bleed pressure. Rig up. Close Annular and test casing pumping down annulus to 1000 PSI for 10 minutes. Record on chart. Good test. Bleed pressure. Momitor well -static. Pick up above ZXP to allow dogs to kick out on running tool and then slack off to tag and verify top of ZXP @ 7096.70' DPM. Repeat tag. (ZXP = 6.63' Low) POOH. Observed proper hole fill. 0.50 CASE OTHR CMPLT2 Breakout & Lay down Baker Hydraulic Setting tool and Running tool. Inspect tools and all looked good. 0.50 CASE OTHR CMPLT2 Clean & Clear floor area, lay down tools. 5.25 WINDO ULD PROD3 Pull toots to rig floor and make up 7 5/8" Whipstock assembly with space out pipe. Made up Seal assembly (2.83'), Stop Sub (1.92'), 4 3/4 Unloader (4.88'), 9 -juts 3 1/2" DP (281.50'), Blanking sub (1.03'), BTA (3.23'), Safety Disconnect (3.23'), Ported drain sub (1.50'), Debris barrier sub w/ cup (2.02'), 7 5/8" Whipstock (14.36'), 6.125" Starting Mill (1.50'), 6 1/8" Lower Mill (5.52'), 6.750" Upper Mill (5.84'), 1 - Jnt 3 1/2 HWDP (29.83'), Float sub (2.35'), Float sub (2.14'), MWD assembly (44.01'), Bumper jar { 7.87'), Bumper Jar (7.83'), Crossover 1.66'), and 2 stands Hybrid Collars (179.70'). Up load MWD and perform shallow pulse test. 70 SPM -700 PSI. 2.00 WINDO R1P PROD3 Trip in hole at 2 minutes 1 stand as per BOT rep, from 601' - 2999' 2300'). Obatain SLM on TIH. 2.50 WINDO RIP PROD3 Continue trip in hole from 2999' - 6626' (3627'), at 2 minutes /stand. UP WT = 122K SO WT = 75K. 0.75 WINDO RIP PROD3 Perform MAD PASS Log from 6626' - 6712' (86'), AT 250 gpm's - 1650 PSI, at 250 FT/HR. 0.25 WINDO RIP PROD3 Continue trip in hole at 2 minutes /stand to 7098'. UP WT = 135K, SO Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 23 of 29 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 1 J-168 1 J-168 ROT -DRILLING n1334@ppco.com Doyon 141 Date From - To Hours Code Code Phase 9/16/2005 15:30 - 16:15 0.751 WIN 16:15 - 17:00 0.75 WIN 17:00 - 20:00 3.00 WIN 20:00 - 21:30 1.50 WIN 21:30 - 00:00 9/17/2005 00:00 - 01:15 01:15 - 03:00 03:00 - 04:15 04:15 - 04:45 04:45 - 08:30 08:30- 12:00 12:00 - 12:15 2.50 W 1.25 W 1.75 W 1.25 W rrRIP PROD3 ISETW PROD3 ~CIRC PROD3 ~OTHR PROD3 ~CIRC PROD3 TRIP PROD3 TRIP PROD3 PULD PROD3 EQRP I PROD3 0.50 RIGMNT RSRV PROD3 3.75 DRILL PULD PROD3 3.50DRILL (TRIP PROD3 0.25IDRILL (TRIP PROD3 12:15 - 00:00 I 11.751 DRILL I DRLG I PROD3 9/18/2005 100:00 - 12;00 I 12.00 I DRILL I DRLH I PROD3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations WT = 84K. Orient whipstock face to 7 Degrees left of high side as per DD and BOT rep. Slack off and tag top of ZXP at 7098' and set down to set BTA at 10k. Pull up 10K over to verify set and slack off to shear bolt at 30K. Pick up to neutral position and rotate free of whipstock. Top of whipstock at 6784". The "D" sand top is at 6783". Displace well from SFMOBM to 9.0 PPG MOBM @ 250 GPM's - 1950 PSI. Mill window from 6785' - 6797' (12') in 1.66 HRS. Continue mill OPEN HOLE from 6797' - 6826' (29') in 1.34 HRS for a total milling time of 3.0 HRS, with 20' of gauged hole as per plan. 100 RPM's with torque at 6-8K avg. Pump Hi -Visc sweep at 250 GPM's - 1950 PSI, while dressing window area with mills until window looked clean. PU WT = 125K, SO WT = 80K, ROT WT = 92K. Obtain SPR's at 6787 MD TVD = 3215'. MW = 9.0 PPG. #2 pump - 20 SPM - 330 PSI, 30 SPM - 460 PSI. Monitor well -static, pump dry job. POOH with milling assembly. Continue POOH from 2255'-287' (1968'). Breakout & lay down last 10 Lo-Tads in hole for drilling run. Rack back 2 stands Push pipe. Breakout and lay down Milling BHA. Lay down Crossover (1.66'), 2 - 4 3/4" Bumper Jar (7.83', 7.87'), MWD assembly (44.01'), 2 -Float subs (2.14', 2.35'), 1-jnt 3 1/2" HWDP 29.83'), 6 3/4" Upper mill (5.84'), 6 1/8" Lower mill (5.52'), and starting mill (1.5'). Observed upper mill in full gauge of 6.750". BOLDS and pull wear bushing. Make up stack washer and RIH to flush BOP stack. Function test all rams. Install wear bushng and RILDS. Service Top Drive. Inspect saver sub. OK. Make up BHA #22. Make up 6 3/4" Security FSF2641 bit with TFA of .920 sq in. (1.26'), 5200 Geo-Pilot Assembly (16.18'), 4.68" NM Flex Pony (11.55'), DM Collar (8.29'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR (24.51'), PWD collar (10.77'), TM HOC (10.96'), Non Mag float sub (2.35'), NM IBS Stabilizer (5.33'), 3 - NM Flex Drill collars (93.17'), XO sub (1.66'), 1 - 4" HWDP (30.33'), $ 3/4 tilling jars ( 28.90'), 4 - 4" HWDP (120.85'). Orient and perform shallow pulse test. OK. Trip in hole from 370' - 6565' (6195'). Change out bad Lo-tad on stand # 67. Continue TIH from 6565'-6814' (261'). Pass through window area with no issues. Wash ii< Ream down undergauge hole to 6826'. Clean hole ECD = 10.2 PPG Drill 6 3/4 D Lateral from 6826' - 7755' (929'). TVD = 3246'. ADT = 7.97 HRS. PU WT = 118K, SO WT = 55K, ROT WT = 80K. Torque on = 6K, off = 7K. RPM's = 120. Pump at 300 GPM's-2600 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 16, Visc = 77, Gels 21/28/29. Max gas units observed = 198 units. Jars = 111.87 HRS total. Total bit Hrs = 7.97. Slow pump rates #1 - 20 SPM -340 PSI, 30 SPM - 560 PSI. #2 pump - 20 SPM - 350 PSI, 30 SPM - 530 PSI. Drill 6 3/4 "D" Lateral from 7755 - 9395' (1640'). TVD = 3289'. ADT = 7.78 HRS. PU WT = 145K, SO WT = 43K, ROT WT = 76K. Torque on = 7-8K, off = 6-8K. RPM's = 120. Pump at 300 GPM's-2720 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 21/28/33. Max gas units observed = 236 units. WOB = 5-14K. Jars = 119.95 HRS total. Total bit Hrs = 15.75. Slow pump rates #1 - 20 SPM - 400 PSI, 30 Printed: 10/21/2005 2:52:30 PM • ConocoPhil{ips A{aska Page 24 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/18/2005 100:00 -12:00 I 12.00 I DRILL I DRLH I PROD3 12:00 - 12:15 12:15 - 12:30 12:30 - 13:30 13:30 - 15:45 15:45 - 21:45 0.251 DRILL I DRLH I PROD3 0.251 DRILL I CIRC I PROD3 1.001 DRILL (TRIP IPROD3 2.25 DRILL DRLH PROD3 6.00 DRILL DRLH PROD3 21:45 - 00:00 19!19/2005 100:00 - 04:00 04:00 - 04:30 04:30 - 12:00 12:00 - 17:45 17:45 - 20:00 20:00 - 00:00 2.251 DRILL I DRLH I PROD3 4.00 I DRILL I DRLH I PROD3 0.501 DRILL I CIRC I PROD3 7.50 I DRILL I DRLH I PROD3 5.75 I DRILL I DRLH I PROD3 2.251 DRILL I CIRC I PROD3 4.00 I DRILL DRLH I PROD3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations SPM - 620 PSI. #2 pump - 20 SPM - 420 PSI, 30 SPM - 630 PSI. ECD @ 11.46 PPG. Pump Hi Visc sweep at 8275'. Observe minimal incresae in cuttings at shakers when sweep returned. Continue drill 6 314 "D" Lateral From 9395' - 9435' (40'). TVD -3293'. Stopped Drilling as we are out of zone as per Geologist. Observed Fault @ 8846' MD with throw 10 -12' down. ADT .45 HRS. Allow Hi Visc sweep to come back, circulating @ 300 GPM's 2720 PSI. while reciprocating drill string. BROOH 2 stands. Pull 5 stands out on elevators from 9435' - 8664' 771') Trough with 6 3/4" Geo-pilot assembly from 8664' - 8680 (16'). Perform sidetrack and drill 6 3/4" hole from 8680' - 9435' (755'). ADT = 5.16 HRS. UP WT = 127K, SO WT = 50K. ROT WT = 80K Torque On/OFF BTM = 8K. Drill 6 3/4 "D" Lateral from 9395' - 9629'. (234'). TVD = 3306'. ADT = 1.83 HRS. PU WT = 130K, SO WT = 50K, ROT WT = 77K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2700 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 22/30/33. Max gas units observed = 223 units. WOB = 5-10K. Jars = 126.09 HRS total. Total bit Hrs = 22.19. Slow pump rates @ 9049'. TVD - 3281'. #1 - 20 SPM - 420 PSI, 30 SPM - 620 PSI. #2 pump - 20 SPM - 450 PSI, 30 SPM - 640 PSI. MAX ECD @ 11.8 PPG. Pump Hi Visc sweep. Observed 15 - 20 %incresae in cuttings at shakers. Drill 6 3!4 "D" Lateral from 9629' - 10112' (483'). TVD = 3322'. ADT = 3.49 HRS. PU WT = 135K, SO WT = 49K, ROT WT = 75K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2700 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 20, Visc = 77, Gels 21/33. Max gas units observed = 177 units. WOB = 5-10K. Jars = 129.58 HRS total. Total bit Hrs = 25.68. MAX ECD @ 11.8 PPG. Pump 35 BBL Hi Visc sweep. Observed 15 - 20 %incresae in cuttings at shakers. Complete circulating #2 Hi Visc sweep while reciprocating drill string at 300 GPM's - 2700 PSI. ECD's @ 11.8 PPG ,down to 11.3 PPG. Observed 20-30% increase in cuttings at shakers. Drill 6 3/4 "D" Lateral from 10112' -10886'. (774'). TVD = 3324'. ADT = 4.21 HRS. PU WT = 144K, SO WT = 42K, ROT WT = 75K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2975 PSt. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 22/30/33. Max gas units observed = 177 units. WOB = 5-10K. Jars = 133.89 HRS total. Total bit Hrs = 29.89. Slow pump rates @ 10209'. TVD - 3323'. #1 - 20 SPM - 520 PSI, 30 SPM - 710 PSI. #2 pump - 20 SPM - 530 PSI, 30 SPM - 720 PSI. MAX ECD @ 12.01 PPG. Pump Hi Visc sweep. Concretions @ 10013' - 10016' (3'). Continue Drill 6 3/4 "D" Lateral from 10886' - 11369'. (483'). TVD = 3348'. ADT = 2.95 HRS. PU WT = 146K, SO WT = 38K, ROT WT = 84K. Torque on = 11 K, off = 11 K. RPM's = 120. Pump at 300 GPM's-3150 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 21, Visc = 82, Gels 25!37. Max gas units observed = 135 units. WOB = 5-15K. Jars = 136.84 HRS total. Total bit Hrs = 32.84. MAX ECD @ 12.2 PPG. Pump Hi Visc sweep. Change out GEO -SPAN on rig floor, valve failed. Complete circulating Hi Visc sweep while BROOH and stand back 1 stand, at 300 GPM's - 3200 PSI. ECD's @ 12.2 PPG ,down to .11.8 PPG. Observed 20% increase in cuttings at shakers. Continue Drill 6 3/4 "D" Lateral from 11369' - 11709'. (340'). TVD = Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 25 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/19/2005 120:00 - 00:00 9/20/2005 100:00 - 12:00 12:00 - 15:00 4.00 I DRILL I DRLH I PROD3 12.00 I DRILL DRLH PROD3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 3365'. ADT = 2.12 HRS. PU WT = 148K, SO WT = 36K, ROT WT = 84K. Torque on = 11 K, off = 11 K. RPM's = 120. Pump at 300 GPM's-3200 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 21, Visc = 82, Gels 25/37. Max gas units observed = 135 units. WOB = 5-15K. Jars = 138.96 HRS total. Total bit Hrs =34.96. Slow pump rates @ 11274'. TVD - 3351'. #1 - 20 SPM - 710 PSI, 30 SPM - 890 PSI. #2 pump - 20 SPM - 720 PSI, 30 SPM - 930 PSI. MAX ECD @ 12.2 PPG. Pump Hi Visc sweep as neede to control ECD. Concretions @ 11647'-11652' (5'), 11656'-11660' (4'). Continue Drill 6 3/4 "D" Lateral from 11709' - 12796. (1087'). TVD = 3416'. ADT = 7.95 HRS. PU WT = 174K, SO WT = 35K, ROT WT = 93K. Torque on = 11.5K, off = 10K. RPM's = 125. Pump at 300 GPM's-3900 PSI. 85 SPM. Mud weight = 9.0+ ppg, YP = 20, Visc = 74, Gels 22/29. Max gas units observed = 161 units. WOB = 5-15K. Jars = 146.91 HRS total. Total bit Hrs = 42.91. Slow pump rates @ 12297'. TVD - 3391'. #1 - 20 SPM - 620 PSI, 30 SPM - 820 PSI. #2 pump - 20 SPM - 650 PSI, 30 SPM - 830 PSI. MAX ECD @ 12.2 PPG. Concretions @ 11735'-11737' (2'), 11780'-11781' (1'), 11881' - 11882' 1'), 12220' - 12240' (20'), 12583' - 12593' (10'), 12658' - 12686' (28'). 3.00 ~ DRILL ~ DRLH ~ PROD3 ~ Continue Dril16 3/4 "D" Lateral from 12796 - 12959' MD (163'). TVD = 15:00 - 00:00 9.00 DRILL WIPR PROD3 9/21/2005 00:00 - 01:30 1.50 DRILL WIPR PROD3 01:30 - 03:00 1.50 DRILL CIRC PROD3 03:00 - 04:15 1.25 RIGMNT RSRV PROD3 04:15 - 08:30 4.25 DRILL WIPR PROD3 3424'. ADT = 2.0 HRS. PU WT = 165K, SO WT = 55K, ROT WT = 100K. Torque on = 10.5K, off = 11 K. RPM's = 125. Pump at 300 GPM's-2900 PSI. 70 SPM. Mud weight = 9.2 ppg, YP = 22, Visc = 83, Gels 22/32. Max gas units observed = 102 units. WOB = 2-5K. Jars = 148.91 HRS total. Total bit Hrs = 44.91. Slow pump rates @ 12297'. TVD - 3391'. #1 - 20 SPM - 620 PSI, 30 SPM - 820 PSI. #2 pump - 20 SPM - 650 PSI, 30 SPM - 830 PSI. MAX ECD @ 12.2 PPG. Pump Hi Visc weighted sweep @ 12842' ECD @ 11.8 PPG Observe 20°l° increase in cuttings at shakers when sweep out of hole. 12959' = TD we TD'd the well with lower flow rates of 67 SPM (240 gpm)-due to losses. 132 BBLS total fluid loss. Obtain Surveys, Monitor well -Static. BROOH from 12959' - 7697' 5262'). Average back reamming speed @ 25 - 40 ft/minute. Staged pump rates up from 230 GPM's - 2700 PSI, 285 GPM's, and back to 300 GPM's - 2800 PSI, as we BROOH. Losses seemed to slow down ~ upon reaching window. Obtain Surveys, Monitor well -Static. BROOH from 7697'-6924' (773'). Average back reamming speed @ 25 - 40 ft/minute. Staged pump rates up from 230 GPM's - 2700 PSI, 285 GPM's, and back to 300 GPM's - 2800 PSI, as we BROOH. Losses seemed to slow down. upon reaching window. Observed no issues when BHA going through window area. While BROOH, calculated displacement = 47.3 BBLS. Hole fill was 80.3 BBLS. Pump Hi Visc weighted sweep @ 300 GPM's - 2300 PSI. Observed 25% increase in cuttings on shakers. Reciprocate drill string while circulating at 120 RPM's with torque @ 5K. UP WT = 112 K, SO WT = 60K. Slip & cut 72' od drilling line. Inspect and service Top Drive & Drawworks. POOH with last 3 stands of Lo-Tads on DP. Inspect and change out 8 Total Lo-Tads on stands # 66,68,69,70,71,73,86, and 87. Lo-Tads had flat rollers and plastic insert washed out. Trip in hole to 10974' (4340'). Printed: 10/21/2005 2:52:30 PM r1 • ConocoPhillips Alaska Page 26 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Phase Code 9/21/2005 04:15 - 08:30 4.25 DRILL WIPR PROD3 08:30 - 12:00 3.50 DRILL WIPR PROD3 12:00 - 12:15 0.25 DRILL WIPR PROD3 12:15 - 15:00 2.751 DRILL I CIRC I PROD3 15:00 - 16:45 I 1.75 {DRILL I CIRC I PROD3 16:45 - 00:00 7.251 DRILL I TRIP PROD3 19/22/2005 00:00 - 00:45 0.75 DRILL TRIP PROD3 00:45 - 04:00 3.25 DRILL PULD PROD3 04:00 - 04:45 0.751 WINDOV'{IPULD CMPLT3 04:45 - 07:15 I 2.501 WINDOV'UrRIP I CMPLT3 07:15 - 07:45 I 0.501 WINDOVVOTHR I CMPLT3 07:45 - 08:30 I 0.751 WINDOWCIRC I CMPLT3 08:30 - 09:15 0.75 WINDO RIP CMPLT3 09:15 - 09:45 0.50 WINDO RIP CMPLT3 09:45 - 12:00 2.25. WINDO RIP CMPLT3 12:00 - 14:30 I 2.501 WINDOWTRIP I CMPLT3 14:30 - 16:30 I 2.001 WINDOWPULD I CMPLT3 16:30 - 17:00 I 0.501 WINDOWPULD I CMPLT3 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Observed no downweight left. Wash & rotate down from 10974' - 12846' (1872'), with pumps at 64 SPM, 227 GPM - 2500 PSI. 110 RPM's with torque at 8.5K. UP WT = 160K, SO WT = 52K, ROT WT = 105K. Wash & rotate down from 12846' - 12959' (113'), with pumps at 64 SPM, 230 GPM.- 2825 PSI. 110 RPM's with torque at 8.5K. UP WT = 160K, SO WT = 52K, ROT WT = 105K. Pump Hi Visc weighted sweep and circulate out plus 1 bottoms up @ 230 GPM's - 2825 PSI, while reciprocate drill string @ 120 RPM's - 8K TO. Held PJSM, discuss Safety and Spill Prevention. RU and displace MOBM with SFMOBM @ 230 GPM's - 2825 PSI. Monitor well -static. POOH on elevators from 12959' - 2237' (10722'), with no swabbing observed. End of tour PU WT = 62K, SO WT = 52K. Total fluid loss this tour = 105 BBLS. Drop 1 3/4" Steel Hollow drift in DP on POOH. Continue POOH, from 2237' - 369' (1868'). Breakout & lay down BHA. Download MWD tools. Lay down BHA #22, 6 3/4" Security FSF2641 bit with TFA of .920 sq in. (1.26'), 5200 Geo-Pilot Assembly (16.18'), 4.68" NM Flex Pony (11.55'), DM Collar 8.29'), 4 3/4" Smart Stabilizer (3.59'), 4 3!4" Slimphase 4 w/ DGR 24.51'), PWD collar (10.77'), TM HOC (10.96'), Non Mag float sub 2.35'), NM IBS Stabilizer (5.33'), 3 - NM Flex Drill collars (93.17'), XO sub (1.66'), 1 - 4" HWDP (30.33'), 6 3/4 tlrilling jars (28.90'), 4 - 4" HWDP (120.85'). Gauge bit to I / I / CT / N / X / I / NO / TD MAke up BHA # 23, Whipstock retrieving assembly. Make up Retrieving Hook (7.5'), 1 -jnt 3 1/2 HWDP (29.85), 4 3/4" Float sub (2.35'), 4 3/4" Bumperjar (7.86'), 4 3/4" Oil Jar (11.13'), crossover (1.66), 3 - stands Hybrid Push Pipe (270.26). Retrieving slot @ 6789'. TIH from 330' - 6769' (6439'). UP WT = 107K, SO WT = 61 K. Pumps at 124 GPM's - 300 PSI. 35 SPM. Attempt to hook slot @ 6782' DPM. Work 1/4 turns in string 4 times to wash slot and hook whipstock slot. Slack off and confirm hook in slot .with set down weight 10K. Pull up from 127K, up to 200K cocking and firing jars to release whipstock and observe 9K increase in upweight. Now UP WT = 116K. NOTE: Found slot @ 6782' = 7' higher. Circulate bottoms up @ 170 GPM's - 575 PSI @ 6764'. Monitor well - static. POOH from 6764' - 6302' (462'). Observed swabbed in 1 BBL. Close rams and pump 3 BBLs into DP. Pull 1 stand @ 5 FT/MIN with proper hole fill. Pull 4 stands @ 25 FT/MIN w/ proper hole fill. Continue POOH to 4004' observing proper hole fill. Continue POOH with whipstock asembly observing proper hole fill form 4004' - 330' (3674'). Calculated hole fill @ 89 BBLS, actual fill = 91 BBLS. POOH, breakoput & lay down Whipstock retrieving assembly as above. Continue POOH breakout and lay down 7 5/8" Whipstock assembly with space out pipe. Seal assembly (2.83'), Stop Sub (1.92'), 4 3/4 Unloader (4.88'), 9 - jnts 3 1/2" DP (281.50'), Blanking sub (1.03'), BTA (3.23'), Safety Disconnect (3.23'), Ported drain sub (1.50'), Debris barrier sub wJ cup (2.02'), 7 5/8" Whipstock (14.36'), Clean floor area, and lay down tools on beaver slide. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 27 of 29 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-168 1 J-168 ROT -DRILLING n1334@ppco.com Doyon 141 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Date From - To 9/22/2005 117:00 - 22:00 Hours Code Code Phase -- 5.001 CASE I RUNC I CMPLT3 22:00 - 00:00 2.00 CASE I RUNC I CMPLT3 19/23/2005 100:00 - 00:30 0.50 CASE RURD CMPLT3 00:30 - 05:00 4.50 CASE RUNC CMPLT3 05:00- 09:30 4.50 CASE RUNC CMPLT3 09:30 - 11:15 1.75 CASE I RUNC CMPLT3 11:15 - 12:00 0.75 CASE RUNC CMPLT3 12:00 - 15:00 3.00 CASE RUNC CMPLT3 15:00 - 15:45 0.75 CASE RURD CMPLT3 15:45 - 16:15 0.50 CASE RURD CMPLT3 16:15 - 17:15 1.00 CASE OTHR CMPLT3 17:15 - 00:00 6.75 CASE OTHR CMPLT3 9/24/2005 00:00 - 01:00 1.00 CASE SFTY I CMPLT3 01:00 - 08:30 I 7.501 CASE OTHR CMPLT3 08:30 - 09:00 I 0.501 CMPLTNI RURD I CMPLT3 Description of Operations Held PJSM, discuss Safety & running detail. Rig up casing running tools. Make up 4 1!2" Bent joint with crossover (30.65'). Continue RIH with 4 1/2 L-80 IBT Slotted Liner assembly,Average MU torque = 5700 - 6000 FT/LBS. Held PJSM with entire crew.( New crew /Change out day) Discuss safety and procedure to make up 3 1/8" Super Slim MWD tool on inner string of Hook Hanger.BOT Hook Hanger BOT Model B1 Hook hanger to MWD to Hook (180 degrees out). MWD offset = 161.45 degrees. UP WT = 79K, SO WT = 52K. Pull Lo-Tads to floor to add to string. Rig down casing running equipment. TIH, installing 2 - Lo-Tads on stands #1- #7 as per TAD engineer. Perform Shallow pulse test on MWD at 6265' w/ 33 SPM -575 PSI, 120 GPM. Continue TIH to attempt getting bent joint through window, tagged up @ 339' down on crossover bushing @ 7135'. Pull up above window, putting 1/4 RH turns in string for a total of 6 attempts before finally rotating at 5 RPM's, 3K torque to observe bent joint through window. Continue trip in hole from bottom of 7 5/8" window @ 6796' - 12929' 6133'). We did not have to rotate string to get to bottom. Pumps on, attempt to orient with MWD tool, and we could not move pipe down. Rack back 1 stand, work pipe until verify free movement, and RIH w/ orientation of 8 Degrres left of high side. Hook Hanger. Pull free and orient to 180 degrees out, and run in hole past the window with Hook. Pull back and re-orient to 7 degrres left to hook, Hook Hanger. Good latch up, and several tool faces were pumped up to verify orientation. Drop 29/32" ball and allow to seat, pumping 2 BBIs a minute, 400 PSI .Pressure to 4190 PSI, to shear out ball seat & release from Hook Hanger. Pull up high enough to observe Setting tool released and 55K weight loss. Bottom of window = 6796'. Hook on depth. Monitor well -static. POOH from 6771' - 6423' (348'). PU WT = 137K, SO WT = 86K. Continue POOH from 6423'. Breakout & lay down Lo-Tads off of stands #1 -#7. Breakout & Lay down running and setting tools, inspect same. All good. Breakout & lay dowm 3 1/8" MWD assembly & crossovers. Clean & clear floor area. Remove Lo-Tads and Rig down all casing running equipment, and Baker tools. Rig up. Breakout & lay down 15 stands of Hybrid push pipe in derrick. Continue breakout and lay down 33 stands of 4" XT39 Drill Pipe. Making room in derrick for 4 1/2" completion tbg. Note: Held scheduled Safety Shutdown at rig camp with all drilling supervisors, rig hands, including service contractors. Topic: Pinch Points. Held safety. Stand down with Kuparuk Team Leader and entire Rig Team, including service contractors, and HSE reps. Topic - "Pinch Points". Continue Lay down 32 stands of 4" DP, 8 stands of 4" HWDP w/ Lo-Tads, and 34 stands 4" DP w/ Lo-tads. 74 stands total and 42 Lo-Tads. Clear and clean Rig Floor area. Lay down all uneccessary tools. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 28 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 9/24/2005 09:00 - 09:30 0.50 CMPLTN RUNT CMPLT3 09:30 - 12:00 2.50 CMPLTN RUNT CMPLT3 12;00 -15:45 15:45 - 16:45 16:45 - 17:15 17:15 - 21:15 21:15 - 21:45 21:45 - 00:00 9/25/2005 00:00 - 01:30 3.75 CMPLTNI PULD I CMPLT3 1.00 CMPLTN RURD CMPLT3 0.50 CMPLTN RURD CMPLT3 4.00 I CMPLT~ PULD CMPLT3 0.50 CMPLTN RURD CMPLT3 2.25 CMPLTN RURD CMPLT3 1.50 I CMPLTNI RURD I CMPLT3 01:30 - 03:30 03:30 - 06:45 06:45 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 12:45 12:45 - 17:00 I 2.00 I CMPLTNI RUNT I CMPLT3 3.25 I CMPLTNI RUNT t CMPLT3 3.251 CMPLTNI RUNT I CMPLT3 0.50 CMPLTN RUNT CMPLT3 1.50 CMPLTN RUNT CMPLT3 0.75 CMPLTN RUNT CMPLT3 4.251 CMPLTNI RUNT I CMPLT3 Description of Operations Rig up tubing running equipment, tongs, elevators etc.. Pick up singles of 4.1/2, 12.6#, L-80, IBTM SCC tubing from shed and RIH with 31 joints. Make up Torque = 3400 FT/LBS. Continue Pick up singles of 4 1/2, 12.6#, L-80, IBTM SCC tubing from shed and RIH with 155 joints. Total ran in hole = 186 or 62 stands. Make up Torque =3400 FT/LBS. Rig Down tubing tongs and rig up Double stack tongs. Attempt to repair Double stack tongs. Could not repair gauge or Hydraulic hose. Lay down and replace tongs. POOH, stand back 62 stands of 4 1/2 tbg. 186 Joints total. Clear and clean rig floor area. Held PJSM, discuss rigging up Centrilift equipment,and running procedure. Load Centrilift Motor, Tandem Seal section, and TTC crossover with Screen Intake, GLM's, in pipe shed. Rig up Spooling Unit, and pull all tools to rig floor. Pull 100 Cannon Clamps, 3 -Flat Guards, and SS Flat bands to rig floor, and double check count. Double check count on 4 1/2" tubing in shed. 240 Joints total. Continue Rig up Centrilift equipment. Pull 100 Cannon Clamps to rig floor. Visually inspect and strap all equipment to be run. Hold PJSM with crew& Centrilift Rep.. Discuss Safety & Running Procedures and Installation Procedure of all Clamps. Pick up a 5.62" OD Motor 418 HP-KMFER - 2610/98 Serial # 21 K68696 (33.90') with an A-Well I Pump gauge 4.50" OD Serial# 216 (2.09'). Make up a 6" OD Motor Centralizer Serial # 63569 (1.98') on bottom of A-Well Pump Gauge. Load motor with Centrilift CL-5 oil, and continue Make up 5.13" OD Tandem Seal Section GSB 3 DB AB/HSN (13.82'). Verify free rotation travel in Motor and load TSS with CL-5 oil. Make up TTC Crossover w/ Screen Intake 5.13" OD (10,60') with 4 1/2 12.6# L-80 IBTM SCC tubing pup (5.84'). Continue fill with oil and check all vent, construction 8~ drain plugs, to be tight. Check resistivity in Motor @ .6 OHMS. After not being install pulled back up and Install 3 Flatguards on line and secure same, with 3 Proctetolizer guards. The Centrilift hand said he got ahead of himself. Rig up, and hang ESP line Sheave, Make up ESP line and 1/4" control line to A-Well Gauge and Motor using Stainless Steel Flat bands and Cannon Clamps for attachment. Meaure OD of of Cannon Clamps on Motor @ 5 7/8", on 7SS @ 5 13/16", and on TTC @ 5 3/4". Measure OD of Cannon Clamp on tubing collars at 5 13/16". Run 2 -jnts 4 1/2" TBG, and Centrilift A-Well Discharge Pressure Sub. Attach 1/4" control line to same with Cannon Clamp and measure OD @ 5 13/16". RIH with 4 1!2" Tubing stands from derrick installing Cannon Clamps on every otherjoint. Run 8 stands (738.12'), and install Camco GLM KBG-2 4 1/2" x 1" w/ 1/4" Orifice Valve BK-5 Latch and pups (18.84'). Test ESP line evrey 1000'. Continue run 4 1/2" tbg from derrick. Test line on stand #20, and ESP line failed test. (2742'). Continue attempt to get good test on ESP line. No Good. POOH, looking for bad cable from 2742' - 2006'. Rack back 8 stands. Continue POOH looking for failed line, and observe "bad spot" in line at the first GLM. The ESP line was clamped improperly on the side of the GLM, and was dragging on low side of hole causing a wear spot causing ESP line to fail. . Centrilift hand cut and removed 120' of bad line, and spliced line back together. Test line to good test. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 29 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Welt Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code, Phase Description of Operations 9/25/2005 117:00- 18:45 1.75 CMPLTN RUNT CMPLT3 Continue RIH with 4 1/2" tbg from derrick installing Cannon Clamps on 18:45 - 00:00 5.25 CMPL 9/26/2005 00:00 - 02:00 2.00 CMPL 02:00 - 02:30 0.50 CMPL' 02:30 - 06:00 3.50 CMPL' 06:00 - 08:00 2.00 CMPL' 08:00 - 09:30 1.50 CMPL" 09:30 - 10:00 0.50 CMPL' 10:00 - 11:00 1.00 CMPL- 11:00 - 12:00 1.00 CMPLI 12:00 - 12:30 0.50 CMPLI 12:30 - 13:00 0.50 CMPLI 13:00 - 16:00 3.00 CMPLI 16:00 - 17:15 1.25 CMPLI 17:15 - 19:15 2.00 CMPLI 19:15 - 19:45 0.50 CMPLI 19:45 - 20:30 0.75 CMPLT 20:30 - 22:30 2.00 CMPLT 22:30 - 00:00 I 1.501 CMPLT every otherjoint. Test ESP line at 20 stands. Good test. ~ RUNT CMPLT3 Continue RIH with 4 1/2" tbg from derrick installing Cannon Clamps on every otherjoint. Test ESP line every 1000 feet. Good test. 55 stands total in hole at midnight. I RUNT CMPLT3 Continue RIH with 4 1/2" tbg from pipe shed installing Cannon Clamps on every otherjoint. Test ESP line. Good test. Run 2 -jnts 4 1/2" tbg, Camco GLM KBG-2 4 1/2" x 1"with Dummy and pups (18.91'), 1 - jnt 4 1/2" tbg (30.85'), Camco GLM KBG-2 4 1/2" x 1"with Dummy and pups (18.87'), 1 -jnt 4 1/2" tbg (31.05'), 2 - 4 1/2" tbg space out pups 5.76', 7.81'). Avg MU torque = 3400 FULBS I RUNT CMPLT3 Pick up landing joint, and Vetco Gray 11" x 4 1/2" hanger with a joint of 4 1/2" tbg made up on it (32.57'). Make up joint and hanger. UP WT = 92K, SO WT = 60K. Lower hanger to rotary table, installing Stainless Steel Flat clamps. I RUNT CMPLT3 Install Penetration sub in hanger. Centrilift hand splicing ESP line, and make up pigtail to hanger.Test same. Good Test. I RUNT CMPLT3 RIH land Tbg hanger as per Vetco Gray rep. UP WT = 92K, SO WT = 60K. Run in lock down screws. Test hanger seals, upper and lower to 250 PSI -low test. 5000 PSI -high test for 15 minutes. NUND CMPLT3 Nipple down BOP stack NUND CMPLT3 Remove hold down cap on tubing hanger. NUND CMPLT3 Clear floor area, and test ECP cable with Centrilift. Good test. Hang Tree on tugger. NUND CMPLT3 Nipple up Tree as per Vetco rep. SEAT CMPLT3 Rig up and test Tree void to 250 PSI low, 10 minutes. 5000 PSI high for 15 minutes. SEOT CMPLT3 Tets Tree Flanges to 250 PSI low -10 minutes, 5000 PSI high - 15 minutes. Centrilift rep tested Penetrator Sub and ESP line. All good tests. FRZP CMPLT3 Held PJSM. Discuss Safety and procedure to displace. Rig up Little Red Serices and pump 250 BBLS of Diesel @ 2.75 BBUMIN , 300 -500 PSI, down annulus for freeze protecting the well. Rig down Little Red and secure valves. RURD CMPLT3 Breakout & lay down last 21 stands of 4" XT39 DP in derrick with Lo-Tads. RURD CMPLT3 Lay down Bales form Top Drive. Change out Saver Sub, while rig up scaffolding in cellar area. OTHR CMPLT3 Install BPV as per Vetco Rep. Begin cleaning pits and rockwasher pits. RURD CMPLT3 Continue Change out saver sub while break down and remove scaffolding from cellar area. NUND CMPLT3 Nipple up Actuator Valve on tree and secure well. Record shut in pressures. TBG Pressure = 225 PSI. Inner Annulus Pressure = 250 PSI. Outer Annulus Pressure = 0 PSI. OTHR CMPLT3 Clean up cellar area, Suck out all fluids with super sucker truck, and wipe down tree. Rig Released @ 2400 HRS. Printed: 10!21!2005 2:5230 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1J Pad 1 J-168L2 Job No. AK ZZ-0003877631, Surveyed: 20 September, 2005 Survey Report 4 October, 2005 Your Ref 500292326061 • Surface Coordinates: 5945652.97 N, 558712.01 E (70° 15' 43.6408" N, 149° 31' 31.3352" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 945652.97 N, 58712.01E (GNd) Sun`ace Coordinates relative to Structure: 266.05 S, 80.03 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelty Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~ ~ ~..... ~ Survey Ref.- svy2220 A H a (ikbgrtari CStrr~'~~ty Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-188L2 Your Ref.• 500292328061 Job No. AK ZZ-0003877631, Surveyed: 20 September, 2005 Wesfem 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) 8625.95 88.230 356.270 3154.39 3263.39 2024.03 N 4753.85 W 5947639.87 N 553942.52E 2024.03 Tie-On Point 8680.00 88.610 358.380 3155.89 3264.89 2077.99 N 4756.37 W 5947693.81 N 553939.58E 3.965 2077.99 Window Point 8722.94 85.190 358.460 3158.21 3267.21 2120.85 N 4757.55 W 5947736.66 N 553938.06E 7.967 2120.85 8820.07 84.950 1.690 3166.56 3275.56 2217.61 N 4757.43 W 5947833.41 N 553937.44E 3.322 2217.61 8918.19 88.010 4.940 3172.58 3281.58 2315.35 N 4751.76 W 5947931.20 N 553942.34E 4.545 2315.35 9014.51 87.490 3.400 3176.36 3285.36 2411.34 N 4744.76 W 5948027.24 N 553948.59E 1.686 2411.34 9109.91 89.170 2.720 3179.14 3288.14 2506.56 N 4739.67 W 5948122.50 N 553952.94E 1.900 2506.56 9206.44 88.540 357.970 3181.07 3290.07 2603.04 N 4739.09 W 5948218.98 N 553952.77E 4.963 2603.04 9303.84 87.050 356.530 3184.82 3293.82 2700.25 N 4743.76 W 5948316.15 N 553947.34E 2.127 2700.25 9400.99 87.680 358.810 3189.29 3298.29 2797.21 N 4747.70 W 5948413.08 N 553942.64E 2.432 2797.21 9497.48 88.360 1.390 3192.62 3301.62 2893.63 N 4747.54 W 5948509.50 N 553942.06E 2.764 2893.63 9595.05 87.920 4.410 3195.79 3304.79 2991.02 N 4742.60 W 5948606.92 N 553946.23E 3.126 2991.02 9687.39 87.310 3.690 3199.63 3308.63 3083.04 N 4736.09 W 5948698.99 N 553952.03E 1.021 3083.04 9786.40 89.480 356.230 3202.41 3311.41 3181.94 N 4736.16 W 5948797.89 N 553951.18E 7.844 3181.94 9883.66 87.240 359.900 3205.19 3314.19 3279.08 N 4739.44 W 5948895.00 N 553947.14E 4.419 3279.08 9978.52 87.860 357.600 3209.25 3318.25 3373.83 N 4741.51 W 5948989.72 N 553944.34E 2.509 3373.83 10077.76 88.550 356.670 3212.36 3321.36 3472.89 N 4746.47 W 5949088.75 N 553938.61E 1.167 3472.89 10175.41 89.720 357.650 3213.83 3322.83 3570.41 N 4751.31 W 5949186.22 N 553933.01E 1.563 3570.41 10270.10 89.650 359.270 3214.35 3323.35 3665.06 N 4753.85 W 5949280.85 N 553929.73E 1.712 3665.06 10367.23 89.280 358.790 3215.26 3324.26 3762.17 N 4755.49 W 5949377.95 N 553927.33E 0.624 3762.17 10462.43 90.530 357.730 3215.42 3324.42 3857.32 N 4758.39 W 5949473.07 N 553923.69E 1.722 3857.32 10560.68 90.640 356.370 3214.41 3323.41 3955.44 N 4763.44 W 5949571.14 N 553917.87E 1.389 3955.44 10656.63 89.090 358.560 3214.64 3323.64 4051.28 N 4767.68 W 5949666.96 N 553912.88E 2.796 4051.28 10754.48 89.590 358.600 3215.77 3324.77 4149.10 N 4770.11 W 5949764.75 N 553909.69E 0.513 4149.10 10852.07 87.300 358.870 3218.42 3327.42 4246.62 N 4772.26 W 5949862.25 N 553906.78E 2.363 4246.62 10947.64 88.740 359.390 3221.72 3330.72 4342.12 N 4773.71 W 5949957.74 N 553904.59E 1.602 4342.12 11044.16 88.170 358.800 3224.32 3333.32 4438.59 N 4775.24 W 5950054.19 N 553902.31E 0.850 4438.59 11141.31 86.060 356.430 3229.21 3338.21 4535.52 N 4779.27 W 5950151.09 N 553897.52E 3.264 4535.52 11236.80 86.500 358.880 3235.41 3344.41 4630.72 N 4783.17 W 5950246.26 N 553892.88E 2.601 4630.72 11334.64 88.990 3.080 3239.26 3348.26 4728.44 N 4781.50 W 5950343.99 N 553893.79E 4.987 4728.44 11430.58 87.730 3.060 3242.00 3351.00 4824.20 N 4776.36 W 5950439.79 N 553898.18E 1.313 4824.20 11527.70 87.730 358.580 3245.85 3354.85 4921.21 N 4774.97 W 5950536.80 N 553898.81E 4.609 4921.21 11624.31 86.430 358.560 3250.77 3359.77 5017.67 N 4777.38 W 5950633.23 N 553895.65E 1.346 5017.67 11721.00 87.250 357.650 3256.10 3365.10 5114.15 N 4780.57 W 5950729.69 N 553891.71E 1.266 5114.15 11808.91 87.180 1.500 3260.38 3369.38 5201.94 N 4781.22 W 5950817.47 N 553890.37E 4.375 5201.94 L_J • 4 October, 2005 - 16:14 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-168L2 Your Ref 500292326061 Job No. AK 2Z-0003877631, Surveyed: 20 September, 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) 11899.71 87.680 1.590 3264.45 3373.45 5292.62 N 4778.78 W 5950908.16 N 553892.11E 0.559 5292.62 11989.64 87.420 2.070 3268.29 3377.29 5382.42 N 4775.91 W 5950997.99 N 553894.28E 0.607 5382.42 12082.52 87.610 358.710 3272.32 3381.32 5475.19 N 4775.28 W 5951090.77 N 553894.19E 3.620 5475.19 12171.52 87.370 355.680 3276.22 3385.22 5563.99 N 4779.63 W 5951179.53 N 553889.14E 3.412 5563.99 12261.70 88.120 0.720 3279.77 3388.77 5654.03 N 4782.46 W 5951269.54 N 553885.61E 5.646 5654.03 12351.56 86.360 0.860 3284.10 3393.10 5743.77 N 4781.22 W 5951359.29 N 553886.15E 1.965 5743.77 12443.54 87.380 358.750 3289.12 3398.12 5835.61 N 4781.53 W 5951451.12 N 553885.12E 2.545 5835.61 12533.82 85.690 358.340 3294.58 3403.58 5925.69 N 4783.82 W 5951541.18 N 553882.13E 1.926 5925.69 12622.30 87.310 1.690 3299.98 3408.98 6013.99 N 4783.79 W 5951629.48 N 553881.47E 4.199 6013.99 12715.02 87.490 4.830 3304.19 3413.19 6106.45 N 4778.53 W 5951721.98 N 553886.02E 3.389 6106.45 12807.43 86.870 2.810 3308.73 3417.73 6198.54 N 4772.38 W 5951814.11 N 553891.45E 2.284 6198.54 12898.73 87.500 2.160 3313.22 3422.22 6289.64 N 4768.42 W 5951905.24 N 553894.69E 0.991 6289.64 12924.68 88.000 1.050 3314.23 3423.23 6315.56 N 4767.70 W 5951931.17 N 553895.21E 4.688 6315.56 _ 12959.00 88.000 1.050 3315.43 3424.43 ~ 6349.86 N 4767.07 W 5951965.46 N 553895.57 E - 0.000 6349.86 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12959.OOft., The Bottom Hole Displacement is 7940.13ft., in the Direction of 323.103° (True). ~~ • 4 October, 2005 -16:14 Page 3 of 4 DrillQuest 3.03.06.008 Western North Slope Comments Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-168L2 Your Ref.• 500292326061 Job No. AK ZZ-0003877631, Surveyed: 20 September, 2005 Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8625.95 3263.39 2024.03 N 4753.85 W 8680.00 3264.89 2077.99 N 4756.37 W 12959.00 3424.43 6349.86 N 4767.07 W Survey tool program for 1J-168L2 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 540.30 539.50 To Measured Vertical Depth Depth (ft) (ft) 540.30 539.50 12959.00 3424.43 Comment Tie-On Point Window Point Projected Survey Survey Tool Description CB-SS-Gyro (1J-168) MWD+IIFR+MS+SAG (1J-168) ConocoPhillips • • 4 October, 2005 - 16:14 Page 4 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1 J-168L2P61 Job No. AK ZZ-0003877631, Su-veyed: 18 September, 2005 Survey Report 4 October, 2005 Your Ref.• 500292326070 • Surtace Coordinates: 5945652.97 N, 558712.01 E (70° 15' 43.6408" N, 149° 31' 31.3352" VN) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surtace Coordinates relative to Project H Reference: 945652.97 N, 58712.01E (Grid) Surtace Coordinates relative to Structure: 266.05 S, 80.03 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ii~E'?'~t~1-~Ut"1 ~ ~ ~ ~- t- ~ _.__~ ~ ~,___,~ Survey Ref.• svy2219 A Hallkburtan Company Halliburton Sperry-Sun Surrey Report for Kuparuk 1J Pad -1J-188L2P81 Your Ref.• 500292328070 Job No. AK-ZZ-0003877631, Surveyed: 18 September, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local C oordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 6731.85 75.480 347.550 3091.90 3200.90 139.88 N 4712.76 W 5945756.10 N 553998.30E 139.88 Tie-On Point -- 6784.74 75.010 347.540 3105.37 3214.37 ~ 189.83 N 4723.79 W 5945805.96 N 553986.88E 0.889 189.83 Window Point 6887.34 81.440 351.820 3126.31 3235.31 288.57 N 4741.73 W 5945904.56 N 553968.18E 7.479 288.57 6985.30 87.460 355.170 3135.78 3244.78 385.39 N 4752.75 W 5946001.29 N 553956.40E 7.024 385.39 7079.37 93.080 359.440 3135.34 3244.34 479.29 N 4757.17 W 5946095.16 N 553951.24E 7.502 479.29 7176.01 89.200 359.470 3133.41 3242.41 575.89 N 4758.09 W 5946991.75 N 553949.57E 4.015 575.89 , 7274.70 91.830 359.660 3132.53 3241.53 674.57 N 4758.84 W 5946290.41 N 553948.05E 2.672 674.57 7371.60 91.250 357.410 3129.92 3238.92 771.39 N 4761.32 W 5946387.22 N 553944.82E 2.397 771.39 7466.71 88.770 358.540 3129.91 3238.91 866.43 N 4764.68 W 5946482.23 N 553940.72E 2.865 866.43 7562.23 89.600 358.910 3131.26 3240.26 961.92 N 4766.80 W 5946577.69 N 553937.85E 0.951 961.92 7659.02 88.220 0.660 3133.11 3242.11 1058.69 N 4767.17 W 5946674.45 N 553936.73E 2.302 1058.69 7755.71 89.890 0.490 3134.70 3243.70 1155.35 N 4766.20 W 5946771.13 N 553936.95E 1.736 1155.35 7853.74 88.720 2.790 3135.89 3244.89 1253.33 N 4763.39 W 5946869.12 N 553938.99E 2.632 1253.33 7949.69 88.170 4.110 3138.49 3247.49 1349.07 N 4757.62 W 5946964.90 N 553944.01E 1.490 1349.07 8044.25 89.100 4.990 3140.75 3249.75 1443.30 N 4750.12 W 5947059.19 N 553950.78E 1.354 1443.30 8143.48 89.160 3.320 3142.25 3251.25 1542.26 N 4742.93 W 5947158.20 N 553957.20E 1.684 1542.26 8239.68 88.970 1.780 3143.82 3252.82 1638.34 N 4738.65 W 5947254.32 N 553960.73E 1.613 1638.34 8334.47 88.480 358.540 3145.93 3254.93 1733.10 N 4738.39 W 5947349.07 N 553960.25E 3.456 1733.10 8430.90 87.860 356.730 3149.01 3258.01 1829.39 N 4742.37 W 5947445.33 N 553955.52E 1.983 1829.39 8527.10 88.790 356.750 3151.82 3260.82 1925.39 N 4747.83 W 5947541.29 N 553949.31E 0.967 1925.39 8625.95 88.230 356.270 3154.39 3263.39 2024.03 N 4753.85 W 5947639.87 N 553942.52E 0.746 2024.03 8722.84 88.920 0.060 3156.81 3265.81 2120.82 N 4756.95 W 5947736.63 N 553938.67E 3.975 2120.82 8819.55 88.230 356.400 3159.21 3268.21 2217.44 N 4759.94 W 5947833.22 N 553934.93E 3.850 2217.44 • ~ 8916.19 89.230 355.470 3161.35 3270.35 2313.81 N 4766.78 W 5947929.54 N 553927.33E 1.413 2313.81 9012.75 89.900 355.600 3162.09 3271.09 2410.07 N 4774.30 W 5948025.74 N 553919.06E 0.707 2410.07 9106.88 87.600 355.690 3164.14 3273.14 2503.90 N 4781.45 W 5948119.51 N 553911.19E 2.445 2503.90 9206.46 87.930 358.320 3168.02 3277.02 2603.26 N 4786.65 W 5948218.83 N 553905.21E 2.660 2603.26 9300.39 86.180 5.110 3172.85 3281.85 2696.96 N 4783.84 W 5948312.55 N 553907.28E 7.455 2696.96 9400.48 85.250 4.150 3180.33 3289.33 2796.45 N 4775.79 W 5948412.09 N 553914.56E 1.333 2796.45 9435.00 85.250 4.150 3183.19 3292.19 2830.76 N 4773.30 W 5948446.42 N 553916.79E 0.000 2830.76 Projected Survey All data is in Feet (US Su rvey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are re lative to Well. Global Northings and Eastings are relative to NAD2 7 Ataska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Surrey). Vertical Section is from Well and calculated along a n Azimuth of 0. 000° (True). 4 October, 2005 -16:05 Page 2 of 3 DrillQuest 3.03.08.008 Ha/liburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-188L2P61 Your Ref.•500292326070 Job No. AK ZZ-0003877831, Surveyed: 18 September, 2005 Western North Slope Based upon Minimum Curvature type calculations, at a Measured Depth of 9435.OOft., The Bottom Hole Displacement is 5549.55ft., in the Direction of 300.670° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 6731.85 3200.90 139.88 N 4712.76 W Tie-On Point 6784.74 3214.37 189.83 N 4723.79 W Window Point 9435.00 3292.19 2830.76 N 4773.30 W Projected Survey Survey tool program for 1J-168L2PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 540.30 539.50 To Measured Vertical Depth Depth (ft) (ft) 540.30 539.50 9435.00 3292.19 Survey Toof Description CB-SS-Gyro (1J-168) MWD+IIFR+MS+SAG (1J-168) ConocoPhillips • \_J 4 October, 2005 -16:05 Page 3 of 3 DrillQuest 3.03.06.008 yJ~'^ ~ Y `~ $ j ~ ~ ~ , ~ ~ FRANK H. MURKOWSKI, GOVERNOR ti J~ ~-7SA OIL A1~TD (zA5 333 W, 7~" AVENUE, SUITE 100 CO1~T5IriRQA'1'IO1~T COMh'II551011T ,:~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 27&7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0350 Re: Kuparuk 1J-168L~ ~ ConocoPhillips Alaska, Inc. Permit No: 205-062 Surface Location: 1841' FSL, 2499' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 2370' FNL, 2027' FEL, SEC. 27, Tl 1N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-168, Permit No 205-060, API 50-029-23260-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does nonexempt 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. Pl e provide at least twenty-four (24) hours notice for a representative of the Commission witn ss any required test. Contact the Commission's petroleum field inspector at ~~ 6 ger). K. N~ DATED this day of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. L_J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEI\/EU `~fi~ APR - $ ZQ05 1a. Type of Work: Drill / Redrill Re-entry ^ 1b. Curcent Well Class: Exploratory Developr~gpt.Qil ~~~ ~~(~~ Stratigraphic Test ^ Service ^ Development Gas Single Zone ^/ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well ame and umber: 1J-168L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12942' ND: 3453' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1841' FSL, 2499' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25660 West Sak Oil Pool Top of Productive Horizon: 2098' FSL, 1946' FEL, Sec. 34, T11 N, R10E, UM '~ 8. Land Use Permit: ALK 471 & 470 13. Approximate Spud Date: 6/23/2005 Total Depth: 2370' FNL, 2027' FEL, Sec. 27, T11N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to ~ jf.YO` ~/ Nearest Property: ay~tufa~e-~11~' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558712 ~ y- 5945653 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest /° y ~~~~ N" Well within Pool: 1~(„-10.~68'~ r7 ~ 16. Deviated wells: Kickoff depth: 6865 ~ ft. Maximum Hole Angle: gp° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1481 psig Surface: 1134 psig ~ ~~ t 18. Casing Program if S ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3527' 28' 28' 3555' 2118' 640 sx ASLite, 180 sx DeepGRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8181' 28' 28' 8209' 3481' 480 sx DeepGRETE 6.75" 4.5" 12.6# L-80 BTCM 6107' 6835' 3229' 12942' 3453' 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 ND Structural Conductor Surface Intermediate Production Perforation Depth MD (ft): Pertoration Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Cloninger @ 265-6829 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature \ Phone ~,S'6$3o Date Y/(a~aS P r n II Commission Use Only Permit to Drill Number: ~ ~-~j ~ APl Number: ~ / 50- d G-~- ~ 3Z,~~--~ ~ Permit Approval Date: ~. ~. ~ ~~ See cover letter for other requirements Conditions of approval : am les required Yes ^ No ~ Mud log required Yes ^ No rogen sulfide measures Yes ^ No ~ Directional survey required Yes ~ No ^ Other. ` '-~ it~-`J ~,, F~~ ~,~,51 APPROVED BY Approved b : THE COMMISSION Date: j (~l~ S' vs ~s Form 1~ 1 Revi es d 06/2004 - ~.'~~~ /Submit in Duplicate • ~tion for Permit to Drill, Well 1J-168L2 Revision No.O March 31, 2005 Permit- West Sak #1 J-168L2 Producer ("D" Sand) Application for Permit to Drill Document Mdxirriia~ t4ell 5foluE Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(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 oi20 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 ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12} ................................................................................................ 5 E u ~ ~ :,~: Permit for 1J-168L2 Producer Page 1 of 6 Printed: March 31, 2005 s ~ation for Permit to Drill, Well 1 J-168L2 Revision No.0 March 31, 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 ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1. Well Name Requirements of 20 AAC 25.005 (~ Each we// 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(b). For a wet! with multiple well branchc>s, each branch must similaNy be identified by a unique name and API number try adding a sufFx to the name designated for the we'I 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 1)-168L2. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a p/at identifying the property and the property's owners aid showing (A)the coordinates of the proposed location of the well at the s~un`ace, at the top of each objective formation, and at Iota! depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the .surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Nat iona/ Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at SurFace FSL 1841' ,FEL 2499', Sec.35, T11 N/R10E ° ASPZone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5945653 Eastings: 558712 Pad Elevation 81' AMSL Location at Top of Productive Interval FSL 2098', FEL 1946', Sec 34, T11N/R10E West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB.' 6835' Northings: 5945874 Eastings: 553983 Tota! Iertical De th, RKB: 3229' Total Vertical D~th, SS.' _ _ 3120' _ Location at Total Depth FNL 2370', FEL 2027', Sec 27, T11 NiR10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12942' Northings: 5951965 Eastings: 553998 Total Vertical De th, RKB: 3453' Total Vertical De th, SS,' 3344' and (D} other information required by 20 AAC15.050(b); Requirements of 20 AAC 25.05O(b) If a we!/ is to be intentional/y deviated, the application for a Permit to Dril! (Form 10-401} must (1) include a p/at, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent we//bores within 200 feet of any portion of the proposed wel% ORIGINAL Permit for 1J-168L2 Producer Page 2 of 6 Printed: March 31, 2005 ~ation for Permit to Drill, Well 1J-168L2 Revision No.O March 31, 2005 Please see Attachment 1: Directional Plan and (2) for al/ we//s within 200 feet of the proposed weltbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Ori// must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-168L2. Due to the formation pressures being far less then the rating of the BOPE, 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 Dri// must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine /t, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J-168L2 area vary from 0.44 to 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 D sand formation is 1134 psi, calculated thusly: MPSP =(3150 ft)(0.47 - 0.11 psi/ft} =1134 psi (B) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. ~ and (C) data concerning potentia/ causes of ho% problems such as abnormally geo-pressured strata, lost dreulation zones, and zones that have a propensity for differentia/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 Drill must be accompanied by each of the fo1/owing r`tems, except for an item a/ready on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1J-168, will be completed with 7 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 performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. ~~~Y Permit for 1J-168L2 Producer Page 3 of 6 Printed: March 31, 2005 ,~ ~ation for Permit to Drill, Well 1J-168L2 Revision No.0 March 31, 2005 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Dri/l 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: (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 insta/led; Casing and Cementing Program See also Attachment 3 APD for 1J-168L2: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TI/D MD/TI/D OD in in /b/ft Grade Connection ft ft ft Cement Pro ram 20" 40" 94 K55 Welded 80' 28' / 28' 108' / 108' Cemented to surface with 260 cf ArcticCRETE 10 3/4" 13 1/2" 45.5# L-80 BTC 3527' 28'/28' 3555'/2118' Cemented to Surface with 640sx ASLite Lead, 180sx Dee CRETE Tail 7 5/8" 9 7/8" 29.7# L-80 BTCM 8181' 28'/28' 8209`/3481' Cement Top planned @ 4778' MD/' TVD. Cemented w/ 480 sx Dee CRETE 4 1/2" 6 3/4" °A" 12.6# L-80 BTCM 4766' 8209'/3481' 12975'/3658' Slotted- no cement slotted Lateral 4 1/2" 6 3!4" °8" 12.6# L-80 BTCM 5767' 7185'/3310' 12952'/3512' Slotted- no cement slotted Lateral 4 1/2" 6 3/4" "D" . 12.6# L-80 BTCM 6107' 6835/3229' 12942'/3453' Slotted-no cement slotted Lateral 1 J-168 L NA 12.6# L-80 IBTM 6807' 28'/28' Production T tubin 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by eat:h of the following 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 require~~ by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of iJ-168L2. Please see diagrams of the Doyon 141 diverter system on file with the Commission. Permit for 1J-168L2 Producer Page 4 of 6 Printed.' March 31, 2005 ORIGINAL • ~tion for Permit to Drill, Well 1J-168L2 Revision No.0 March 31, 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 following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and descript%on 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: Pro erties Production Mud Tye MI VersaPro Mineral Oil Base Density (ppg) 9.0 Funnel Viscosity seconds) 60 Yield Point (cP 18-28 Electric Stability 650-900 Chlorides (m /I) NA pH NA API filtrate (cc / 30 min) <4 "*HTHP filtrate (cc / 30 min) <10 Drilling fluid practices will be in accordance with 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 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri// must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpredicted abnorma//y geo pressured strata as required by 20 AAC25.033(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 Dri// must be accompanied by evch of the following items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (10) for an exp/oratory or stratigraphic test weU, a seismic refraction or reflection analysis as required by 20 AAC25.061(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 Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application: (i1) for a we// dri/(ed from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dri/ling vess% an analysis ofseabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by ea,:h of the following items, except for an item already on file with the commission and identified in the app/ication: (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. Permit for 7J-168L2 Producer Page 5 of 6 Printed: March 31, 2005 cation for Permit to Drill, Well 1 J-168L2 Revision No.O March 31.2005 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dril/ must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: The proposed drilling program for 1J-168L2 after the B-Sand has been completed is listed below: 1. Run and set Baker WindowMaster whipstock system, at window point of 6835' MD/ 3229' TVD, the top of the "D" sand. 2. Mill 6 3/4" window. POOH. 3. Pick up drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 12942' MD / 3453' TVD, as per directional plan. ~ 5. Back ream out of lateral to casing window. RIH to TD and change over to solids-free OBM. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4 1/2" slotted liner. ' 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. 10. POOH and lay down drill pipe. 11. RU and run a 4 1/2" ESP completion with backup gaslift. 12. Space out tubing and land tubing in tubinghead. 13. Nipple down BOPE, nipple up tree and test, change over the hole to diesel, 14. Set BPV and RDMO Doyon 141. 15. Rig up wire line unit. Pull BPV. 16. Circulate out well with diesel through the ESP. 17. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 18. Replace gas lift valves with blank dummy valves. 19. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri1! mustc be accompanied by each of the following items, except far an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC Z5.08~9 for an annu/ar disposal operation in the wel%; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ 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 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Permit for 1J-168L2 Producer Page 6 of 6 ~v~ ~ ~ Printed: March 31, 2005 { ~ t d e xs • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-168 (L3) 1 J-168 L2 Plan: 1 J-1 fib L2 (wp08) Proposal Report 30 March, 2005 1-IALLI~URTC~IV Sperry Drilling Services ~1 ., -1000 Top of Window - 6835ft MD, 3228ft TVD : 2098ft FSL 8: 1946ft FEL -Sec 34-T11 N-R70l~ I Bottom of Whipstock : 6847ft MD, 3232ft TVD~~ ~- - -500 ~ ~ Begin Dir ~ 6.0°HOOft, 6865ft MD, 3236ft TV~ I ~ - ~ ~ Continue Dir ~ 5.00°/t00ft, 7098ft MD, 3263ft TVDi - Sail ~ 89.80°Inc 8 2.19°Azi : 7342ft MD, 3263ft TVD 0 I I / ~gln Dir ~ 4.0°/100ft, 7802ft MD, 3265ft Begin Geosteering In D -Lateral -Target 15' TVD Below Top of D-Sand : 7867ft MD, 3266ft TV[ c o o, o. ..® ~- O 3/4" TD ~ 12942ft MD, 3453ft TVD : 2370ft FNL & 2027ft FEL -Sec 27-T11 N-R10 D-Sand ~1J-168 L2 Faultlntersectl 1J-168 L2 Tce 1 1J-168 L2 T2 ~1J-168 L2 T4 (v4)-168 L2 T4 (v4) 1J-188 L2 T5 1J-168 L2 T3 (v4) MALLIBUgTON Sperry Drilling Services -1500 -1000 -500 0 500 1J-168 L2 T6 (v4) 1J-168 L2 T7 (v4)~ 1~J-168 L2 T8 tv41 1J-168 L2 T9 LEGEND -~ Plan 1J-168 (L3), 1J-168, 1J-168 (wp08) VO $ Plan 1J-168 (L3), 1J-168 L1, 1J-168 L1 (wp08) $ 1 J-168 L2 (wp08) 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Vertical Section at 0.00' (1000 fVin) r~ T West(-)/East(+) (1000 ft/in) -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 7D00 MALLIBUFITON `~ so..y o.amq s.Me« TD ~ 129428 MD, 3463ft ND : 23708 FNL & 202M FEL -Sec 27-T11 N-R10E ~i ~ 1`(H'1000~71~~I p5 - - - 7000 . , ._ . / 4112„ 6500 / 1J-168 L2 Toe (v4) i 6500 6000 1J-168 LI T9 (v4) 6000 3 ° L J-168 L2 TB (v4) tJ-188 L2 Fautt Intersect ~ 1J 188 L2 T7 4 5500 - - (v ) - -- - --- 5500 1J-168 L2 TB (v4) 5000 36 ° 5000 4500 Begin Geosteering in D -Lateral -Target 15' ND Below Top of D-Sand :78678 MD, 3266ft ND 4500 1J-168 L2 T5 (v4) - -- - - - Begin Dir ~ 4.0°I100ft, 7802ft MD, 32658 ND 4000 4000 rSail ~ 89.80°Inc & 2.19°Azi : 7342ft MD, 3263ft ND ~ 3500 ' 1J-168 L2 T4 (vd)J ~ / 3500 3000 3000 ~ 1J-168 L2 T3 (v4) '. Continue Dir ~ID_5.00°I100ft, 70988 MD, 3263ft ND - - J ° T 60 O 2500 °o __ 2500 1J-168 L2 T2 (v4) ' >_ ~ Begin Dir ~ 6.0°/100ft, 68658 MD, 323611 ND ~ 2000 0 360° ~ 2000 ~ / 1500 ~ I11J~168 L2 Tt (v4) ' 0° 1500 Bottom of whipstock : 6847ft MD, 32328 ND 1000 2° -'~ 1000 500 0° Top of Window • 6835ft MD, 3229ft ND :20988 FSL 8 19468 FEL -Sec 34T11 N-R10E ~ ~- - 500 - _~ -- ~ 0 0 ~L~' `S, ~'l$ -500 -500 ~ w ~ ~ N -1000 -1000 -1500 LEGEND -1500 $ Plan 1J-168 (L3), 1J-168, 1J-168 (wp08) VO -2000 $ 1 J-168 L2 (wp08) -2000 -2500 -2500 -60 00 -5500 -5000 -4500 -0000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 West(-)/East(+) (1000 ft/in) ORIGINAL -" ~ Halliburton Company HALLIBURTON Conoco Philiips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-prdinate Reference: Well Plan 1J-168 (L3) Company: ConocoPhiltips Alaska (Kuparuk) TVD Reference: iJ-168 (28+81) ~ 109.OOft (Doyon 141 @ 28') Project: Kuparuk River Unit MD Reference: 1J-1.68 (28+8~) @ 109:OOft (Doyon 141 @ 28') Site: Kuparuk 1J Pad North Reference: Tnae ~ Well: Plan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Wellbore: 1J-168 L2 Design: 1J-168 L2 (wp08) 'Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) ~ Using Well Reference Point Map Zone: Alaska Zone 04 - Using geodetic scale factor Well Plan 1J-168 (L3) Well Position +N/-S 0.00 ft Northing: 6,946,663.00 ft Latitude: 70° 15' 43.641" N +E/•W 0.00 ft Easting: 668,712.00 ft ~ Longitude: 149° 31' 31.336" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wellbore 1J-168 L2 1 Magnetics Model Name Sample Date Declinetlon Dip Angle Field Strength bggm2004 9/1/2004 24.64 80.72 -_- --_ -- -. _ 57,570 -_---- - 1 Design 1J-168 L2 (wp08) _ I Audit Notes: Version: Phase: PLAN Tie On Depth: 6,834.85 Vertical Section: Depth from (TVDj +N/S +E/-W Direction _(ft) _(ft) (ft) (°) I 26.00 0.00 0.00 0.00 3/30/2005 4:28:4fiPM Page 2 of 8 ~5 tj COMPASS 2003,11 Build 48 ConotoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-168 (L3) Wellbore: 1J-168 L2 Design: 1 J-168 L2 (Wp08)> ~ Hailiburton Company HALLlBUFiTGN Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Re€erence: WeH Plan 1J-168 (L3) ND Reference: 1J-1:68 (28+81) @ 109.OOft (Doyon 141 @ 28') MD Reference: 1J-168 (28+81)>~ 109:OOft (Doyon 141 @ 28') North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NlS +gi-W Rate Rate Rate TFO (ft) (°) (°) lft) (ft) (g) (°l100ft) (°/100ft) (°/100ft) (') 6,834.85 75.00 345.00 3,229.36 258.30 -4,727.93 0.00 0.00 0.00 0.00 6,846.85 76.91 345.00 3,232.27 269.55 -4,730.94 15.90 15.90 0.00 0.00 6,864.85 76.91 345.00 3,236.35 286.48 -4,735.48 0.00 0.00 0.00 0.00 7,088.16 90.00 350.00 3,262.91 512.24 -4,785.39 6.00 5.61 2.14 21.12 7,342.09 89.80 2.19 3,263.34 755.14 -4,801.97 5.00 -0.08 5.00 90.95 7,801.61 89.80 2.19 3,264.95 1,214.33 -4,784.37 0.00 0.00 0.00 0.00 7,866.84 88.81 359.78 3,265.74 1,279.53 -4,783.24 4.00 -1:52 -3.70 -112.28 8,071.84 88.81 359.78 3,270.00 1,484.49 -4,784.03 0.00 0.00 0.00 0.00 8,077.43 88.96 359.85 3,270.11 1,490.08 -4,784.05 3,00 2.75 1.19 23.43 9,122.17 88.96 359.85 3,289.00 2,534.64 -4,786.84 0.00 0.00 0.00 0.00 9,155.25 87.98 359.71 3,289.88 2,567.71 -4,786.97 3.00 -2.97 -0.43 -171.82 9,357.35 87.98 359.71 3,297.00 2,769.68 -4,788.01 0.00 0.00 0.00 0.00 9,368.42 87.83 360.00 3,297.41 2,780.75 -4,788.04 3.00 -1.41 2.65 118.04 10,121.99 87.83 360.00 3,326.00 3,533.78 -4,788.05 0.00 0.00 0.00 0.00 10,130.46 87.57 0.01 3,326.34 3,542.23 -4,788.05 3.00 -3.00 0.14 177.30 11,042.94 87.57 0.01 3,365.00 4,453.89 -4,787.88 0.00 0.00 0.00 0.00 11,051.87 87.59 359.74 3,365.38 4,462.82 -4,787.90 3.00 0.24 -2.99 -85.43 12,186.25 87.59 359.74 3,413.02 5,596.18 -4,792.88 0.00 0.00 0,00 0.00 12,200.44 87.52 359.28 3,413.62 5,610.36 -4,793.10 3.30 -0.50 -3.26 -98.75 12,336.65 87.52 359.28 3,419.51 5,746.43 -4,794.81 0.00 0.00 0.00 0.00 12,384.86 86.16 358.80 3,422.17 5,794.57 -4,795.62 3.00 -2.83 -1.00 -160.50 12,621.97 86.16 358.80 3,438.05 6,031,08 -4,600.59 0.00 0.00 0.00 0.00 12,637.09 85.75 358.61 3,439.12 6,046.16 -4,800.93 3.00 -2.72 -1.26 -155.15 12,716.39 85.75 358.61 3,445.00 6,125.22 -4,802.85 0.00 0.00 0.00 0.00 12,848.77 88.89 356.17 3,451.19 6,257.29 -4,808.88 3.00 2.37 -1.84 -37.75 12,942.04 88.89 356.17 3,453.00 6,350.34 -4,815.10 0.00 0.00 0.00 0.00 3/30/'1005 4:28:46PM Page 3 of 8 COMPASS 2003.11 Build 48 ORIGINAL ConocoPhillips Alaska Database: EDM 2003,11 Single UserDb Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad' Well: Plan 1J-168 (l_3) Weilbore: 1J-168 L2 Design: 1J-168 L2 {wp08) Planned Survey 1J-168 L2 (wp08) Halliburton Company PI n ' R rt G h' HALLIBURTQN a Wing epo - eograp Ic Sperry Drilling Servicss Local Co-ordinate Reference: Well Plan 1J-1&8 (L3) TVD Reference: 1J-168 (213+81) @ 109.OOft (Doyon 141 @ 28') MD Reference: 1J-168 {28+81) @ 109.OOft (Doyon 141 @ 28') North Reference: True Survey Calculation Method: Minimum Curvature - - - - - - - - Map Map I I MD Inclination Azimuth TVD SSTVD +Nig +E/.W Northing Easting DLSEV Vert Section ~ (~ (°) (°) (ft) (ft) (ftJ (ft) (ft) (ft) (°/100ft) (ft) I i 6,834.85 75.00 345.00 3,229.36 3,120.36 258.30 -4,727.93 5,945,874.41 553,982.65 0.00 258.30 II Top of Window - 683bft MD, 3229ft TVD : 2098ft FSL & 19468 FEL -Sec 34-T1 f N-R10E - 7518" Window Top 6,846.85 76.91 345.00 3,232.27 ~ 3,123.27 269.55 -4,730.94 5,945,885.63 553,979.55 15.90 269.55 ~ Bottom of Whipstock : 6847ft MD, 3232ft TVD 6,864.85 76.91 345.00 3,236.35 3,127.35 286.48 -4,735.48 5,945,902.53 553,974.88 0.00 286.48 i Begin Dir ~ 6.0°/100ft, 686bft MD, 3236ft TVD 6,900.00 78.87 345.77 3,243.72 3,134.72 319.74 -4,744.15 5,945,935.71 553,965.96 6.00 319.74 ~ 6,906.73 79.25 345.92 3,245.00 i 3,136.00 326.15 -4,745.77 5,945,942.10 553,964.29 6.02 326.15 7,000.00 84.48 347.93 3,258.19 3,149.19 416.05 -4,766.64 5,946,031.83 553,942.72 6.00 416.05 I 7,098.16 90.00 350.00 3,262.91 3,153.91 512.24 -4,785.39 5,946,127.87 553,923.22 6.00 512.24 Continue Dir ~ 8.00°I100ft, 7098ft MD, 3263ft TVD 7,100.00 90.00 350.09 3,262.91 3,153.91 514.05 -4,785.71 5,946,129.68 553,922.89 4.92 514.05 7,200.00 89.92 355.09 3,262.98 3,153.98 613.19 -4,798.60 5,946,228.70 553,909.22 5.00 613.19 7,300.00 89.83 0.09 3,263.20 3,154.20 713.07 -4,802.80 5,946,328.53 553,904.24 5.00 713.07 7,342.09 89.80 2.19 3,263.34 3,154.34 755.14 -4,801.97 5,946,370.61 553,904.75 5.00 755.14 Sall ~ 89.80°Inc & 2.f 9°Azi : 7342ft MD, S263ft TVD 7,400.00 89.80 2.19 3,263.54 3,154.54 813.01 -4,799.75 5,946,428.49 553,906.52 0.00 813.01 ~ 7,500.00 89.80 2.19 3,263.89 3,154.88 912.94 -4,795.92 5,946,528.43 553,909.57 0.00 912.94 i 7,600.00 89.80 2.19 3,264.24 3,155.24 1,012.86 -4,792.09 5,946,628.37 553,912.62 0.00 1,012.86 7,700.00 89.80 2.19 3,264.59 3,155.59 1,112.79 -4,788.26 5,946,728.32 553,915.67 0.00 1,112.79 7,800.00 89.80 2.19 3,264.94 3,155.94 1,212.72 -4,784.43 5,946,828.26 553,918.72 0.00 1,212.72 7,801.61 89.80 2.19 3,264.95 3,155.95 1,214.33 -4,784.37 5,946,829.87 553,918.77 0.00 1,214.33 I, Begin Dir ~ 4.0°I100ft, 7802ft MD, 3266ft TVD 7,866.84 88.81 359.78 3,265.74 3,156.74 1,279.53 -4,783.24 5,946,895.08 553,919.38 4.00 1,279.53 7,866.95 88.81 359.78 3,265.74 3,156.74 1,279.64 -4,783.24 5,946,895.19 553,919.38 0.00 1,279.64 ~ Begin Geostaering in D • Lateral -Target 16' TVD Below Top of D-Sand : 7867ft MD, 3266ft TVD 7,900.00 88.81 359.78 3,266.43 3,157.43 1,312.69 -4,783.37 5,946,928.23 553,919.00 0.00 1,312.69 8,000.00 88.81 359.78 3,268.51 3,159.51 1,412.66 -4,783.76 5,947,028.19 553,917.84 0.00 1,412.66 II 8,071.84 88.81 359.78 3,270.00 3,161.00 1,484.49 -4,784.03 5,947,100.00 553,917.00 0.00 1,484.49 'I 1J-768 L2 T1 (v4) 8,077.43 88.98 359.85 3,270.11 3,161.11 1,490.08 -4,784.05 5,947,105.59 553,916.94 3.00 1,490.08 ~ 8,100.00 88.96 359.85 3,270.52 3,161.52 1,512.64 -4,784.11 5,947,128.15 553,916.70 0.00 1,512.64 8,200.00 88.96 359.85 3,272.32 3,163.32 1,612.63 -4,784.38 5,947,228.12 553,915.65 0.00 1,612.63 8,300.00 88.96 359.85 3,274.13 3,165.13 1,712.61 -4,784.64 5,947,328.09 553,914.61 0.00 1,712.61 8,400.00 88.96 359.85 3,275.94 3,166.94 1,812.59 -4,784.91 5,947,428.D6 553,913.56 0.00 1,812.59 ~ 8,500.00 88.96 359.85 3,277.75 3,168.75 1,912.58 -4,785.18 5,947,528.03 553,912.51 0.00 1,912.58 ~ 8,600.00 88.96 359.85 3,279.56 3,170.56 2,012.56 -4,785.45 5,947,628.00 553,911.47 0.00 2,012.56 ~~ 8,700.00 88.96 359.85 3,281.37 3,172.37 2,112.54 -4,785.71 5,947,727.96 553,910.42 0.00 2,112.54 8,800.00 88.96 359.85 3,283.17 3,174.17 2,212.53 -4,785.98 5,947,827.93 553,909.37 0.00 2,212.53 ' 8,900.00 88.96 359.85 3,284.98 3,175.98 2,312.51 -4,786.25 5,947,927.90 553,908.33 0.00 2,312.51 9,000.00 88.96 359.85 3,286.79 3,177.79 2,412.49 -4,786.52 5,948,027.87 553,907.28 0.00 2,412.49 9,100.00 88.96 359,85 3,288.60 3,179.60 2,512.48 -4,786.78 5,948,127.84 553,906.23 0.00 2,512.48 9,122.17 88.96 359.85 3,289.00 3,180.00 2,534.64 -4,786.84 5,848,150.00 553,906.00 0.00 2,534,64 1J-168 L2 T2 (v4) 3/30/2005 4:28:46PM a 4 f ~ COMPASS 2003.1 J Buikf 48 ~~ ~-' ' Haliiburton Company COI 1oco Phillips Planning Report -Geographic Alaska Database: 6DM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: KuparukRiver Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-168 (L3) Survey Calculation Method: Wellbore: fJ-168 L2 Design: 1J-168 L2 (wp08) Planned Survey 1J-168 L2 (wp08) MD Inclination Azimuth 9,155.25 87.98 359.71 9,200.00 87.98 359.71 9,300.00 87.98 359.71 9,357.35 87.98 359.71 1J-168 L2 T3 (v4) 9,368.42 87.83 360.00 9,400.00 87.83 360.00 9,500.00 87.83 360.00 9,600.00 87.83 380.00 9,700.00 87.83 360.00 9,800.00 87.83 360.00 9,900.00 87.83 360.00 10,000.00 87.83 360.00 10,100.00 87.83 360.00 10,121.99 87.83 360.00 1J-188 L2 T4 (v4) 10,130.46 87.57 0.01 10,200.00 87.57 0.01 10,300.00 87.57 0.01 10,400.00 87.57 0.01 10,500.00 87.57 0.01 10,600.00 87.57 0.01 10,700.00 87.57 0.01 10,800.00 87.57 0.01 10,900.00 87.57 0.01 11, 000.00 87.57 0.01 11,042.94 87.57 0.01 1J-188 L2 TS (v4) 11,051.87 87.59 359.74 11,100.00 87.59 359.74 11,200.00 87.59 359.74 11,300.00 87.59 359.74 11,400.00 $7.59 359.74 11,500.00 87.59 359.74 11,600.00 87.59 359.74 11,700.00 87.59 359.74 11,800.00 87.59 359.74 11,900.00 87.59 359.74 12,000.00 87.59 359.74 12,100.00 87.59 359.74 12,186.25 87.59 359.74 1J-168 L2 T8 (v4) 12,200.00 87.52 359.29 12,200.44 87.52 359.28 12,300.00 87.52 359.28 12,336.65 87.52 359.28 1J-168 L2 T7 (v4) 12,384.86 86.16 358.80 r1 ~~ TVD t1'~) 3,289.88 3,291.46 3, 294.98 3,297.00 HALtIBUR70N Sperry Drilling Services Well Plan 1J-168 (L3) 1J-168 (28+81)`(ca~ 109:OOft (Doyon 141 @ 28') 1 J=168 (28+g1) @ 109:OOft (Doyan 141 @ 28') True Minimum Curvature Map Map SSTVD +NI-S +EI-W Northing Easting DLSEV Vert Section {ft} (ft) (ft) (ft) (ft) (°l100ft) (ft- 3,180.88 2,567.71 -4,786.97 5,948,183.07 553,905.61 3.00 2,567.71 3,182.46 2,612.43 -4,787.20 5,948,227.78 553,905.03 0.00 2,612.43 3,185.98 2,712.37 -4,787.72 5,948,327.70 553,903.74 0.00 2,712.37 3,188.00 2,769.68 -4,788.01 5,948,385.00 553,903.00 0.00 2,769.68 3,297.41 3,188.41 2,780.75 -4,788.04 5,948,396.07 553,902.89 3.00 2,780.75 3,298.60 3,189.60 2,812.30 -4,788.04 5,948,427.62 553,902.64 0.00 2,812.30 3,302.40 3,193.40 2,912.23 -4,788.04 5,948,527.53 553,901.86 0.00 2,912.23 3,306.19 3,197.18 3,012.16 -4,788.04 5,948,627.45 553,901.08 0.00 3,012.16 3,309.99 3,200.98 3,112,09 -4,788.05 5,948,727.36 553,900.30 0.00 3,112.09 3,313.78 3,204.78 3,212.01 -4,788.05 5,948,827.28 553,899.51 0.00 3,212.01 3,317.58 3,208.58 3,311.94 -4,788.05 5,948,927.19 553,898.73 0.00 3,311.94 3,321.37 3,212.37 3,411.87 -4,788.05 5,949,027.11 553,897.95 0.00 3,411,87 3,325.17 3,216.17 3,511.80 -4,788.05 5,949,127.02 553,897.17 0.00 3,511.80 3,326.00 3,217.00 3,533.78 -4,788.05 5,949,149.00 553,897,00 0.00 3,533.78 3,326.34 3,217.34 3,542.23 -4,788.05 5,949,157.45 553,896.93 3.00 3,542.23 3,329.29 3,220.29 3,611.71 -4,788.04 5,949,226.93 553,896.41 0.00 3,611.71 3,333.52 3,224.52 3,711.62 -4,788.02 5,949,326.82 553,895.65 0.00 3,711.62 3,337.76 3,228.76 3,811.53 -4,788.00 5,949,426.72 553,894.89 0.00 3,811.53 3,342.00 3,233.00 3,911.44 -4,787.98 5,949,526.62 553,894.13 0.00 3,911.44 3,346.23 3,237.23 4,011.35 -4,787.96 5,949,626.52 553,893.37 0.00 4,011.35 3,350.47 3,241.47 4,111.26 -4,787.95 5,949,726.41 553,892.61 0.00 4,111.26 3,354.71 3,245.71 4,211.17 -4,787.93 5,949,826.31 553,891.85 0.00 4,211.17 3,358.94 3,249.94 4,311.08 -4,787.91 5,949,926.21 553,891.09 0.00 4,311.08 3,363.18 3,254.18 4,410.99 -4,787.89 5,950,026.11 553,890.33 0.00 4,410.99 3,365.00 3,256.00 4,453.89 -4,787.88 5,950,069.00 553,890.00 0.00 4,453.89 3,365.38 3,256.38 4,462.82 -4,787.90 5,950,077.93 553,889.91 3.00 4,462.82 3,367.40 3,258.40 4,510.90 -4,788.12 5,950,126.00 553,889.32 0.00 4,510.90 3,371.60 3,262.60 4,610.82 -4,788.56 5,950,225.90 553,888.09 0.00 4,610.82 3,375.80 3,266.80 4,710.73 -4,789.01 5,950,325.79 553,886.87 0.00 4,710.73 3,380.00 3,271.00 4,810.64 -4,789.46 5,950,425.69 553,885.64 0.00 4,810.64 3,384,20 3,275.20 4,910.55 -4,789.91 5,950,525.58 553,884.42 0.00 4,910.55 3,388.40 3,279.40 5,010.46 -4,790.35 5,950,625.48 553,883.19 0.00 5,010.46 3,392.60 3,283.60 5,110.37 -4,790.80 5,950,725.37 553,881.96 0.00 5,110.37 3,398.79 3,287.79 5,210.28 -4,791.25 5,950,825.27 553,880.74 0.00 5,210.28 3,400.99 3,291.99 5,310.19 -4,791.70 5,950,925.16 553,879.51 0.00 5,310.19 3,405.19 3,296.19 5,410.10 -4,792.14 5,951,025.06 553,878.28 0.00 5,410.10 3,409.39 3,300.39 5,510.01 -4,792.59 5,951,124.95 553,877.06 0.00 5,510.01 3,413.02 3,304.02 5,596.18 -4,792.98 5,951,211.11 553,876.00 0.00 5,596.18 3,413.60 3,304.60 5,609.92 -4,793.09 5,951,224.84 553,875.78 3.30 5,609.92 3,413.62 3,304.62 5,610.36 -4,793.10 5,951,225.28 553,875.77 3.30 5,610.36 3,417.82 3,308.92 5,709.82 -4,794.35 5,951,324.72 553,873.74 0.00 5,709.82 3,419.51 3,310.51 5,746.43 -4,794.81 5,951,361.32 553,873.00 0.00 5,746.43 3,422.17 3,313.17 5,794.57 -4,795.62 5,951,409.44 3/30/2005 4:28:46PM Page 5 of 8 553,871.81 3.00 5,794.57 COMPASS 2003.1 J Build 48 ~~~~ ~4- . ~ a ('~ it ~.. / Halliburton Company COI'1000 Phiilips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kupanak) TVD Reference: Project: Kuparuk River Unif MD Reference: Site: Kupanak 1J Pad North Reference: Well: Plan 1J-168 (L3} Survey Galcula6on Method: Wellbore: 1J-168 L2 Design: 1J-168 L2 (wp08) ~~ Planned Survey 1J-168 L2 (wp08) MD Inclination Azimuth TVD SSTVD +N!-S +E/-W (ft) (°) 1°) (ft) t~) (~) (ft) 12,400.00 86.16 358.80 3,423.18 3,314.18 5,809.67 -4,795.93 12,500.00 86.16 358.80 3,429.88 3,320.88 5,909.42 -4,798.03 12,561.49 86.16 358.80 3,434.00 3,325.00 5,970.75 -4,799.32 HALLIBURTON Sperry Dritltng Serotaes Well Plan 1 J-168 (L3} 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') 1 J-168 (28+81 } @ 109.OOft (Doyon 141 @ 28') True Minimum'Curvature Map Map Northing Easting DLSEV Vert Section (ft) (ft) (°I100ft) Ift) 5,951,424.54 553,871.38 0.00 5,809.67 5,951,524.26 553,868.51 0.00 5,909.42 5,951,585.58 553,866.74 0.00 5,970.75 12,600.00 86.16 358.80 3,436.58 3,327.58 6,009.17 -4,800.12 5,951,623.99 12,621.97 86.18 358.80 3,438.05 3,329.05 6,031.08 -4,800.58 5,951,645.89 1J-168 L2 T8 (v4) 12,637.09 85.75 358.61 3,439.12 3,330.12 6,046.16 -4,800.93 5,951,660.97 12,700.00 85.75 358.61 3,443.78 3,334.78 6,108.88 -4,802.45 5,951,723.67 12,716.39 85.75 358.61 3,445.00 3,336.00 6,125.22 -4,802.85 5,951,740.00 1J-168 L2 T8 (v4) 12,800.00 87.73 357.07 3,449.76 3,340.76 6,208.63 -4,806.00 5,951,823.38 12,848.77 88.89 356.17 3,451.19 3,342.19 6,257.29 -4,808.88 5,951,872.01 12,900.00 88.89 356.17 3,452.19 3,343.19 6,308.40 -4,812.29 5,951,923.09 ,, 12,942.04 88.88 356.17 3,453.00 - 3,344.00 6,350.34 -4,815.10 5,951,965.00 TD ~ 12942ft MD, 3463ft TVD : 23708 FNL 8 2027ft FEL -Sec 27-T11 N-R10E - 4112" -1J-168 L2 Toe (v4) 553,865.63 0.00 6,009.17 553,865.00 0.00 6,031.08 553,864.54 3.00 6,046.16 553,862.53 0.00 6,108.88 553,862.00 0.00 6,125.22 553,858.20 3.00 6,208.63 553,854.95 3.00 6,257.29 553,851.13 0.00 6,308.40 553,848.00 0.00 6,350.34 3/30/2005 4:28:46PM Page 6 of 8 COMPASS 2003.11 Build 48 r1 ~_J ~ p I'"~- ~ 1 ~f ~~ ~ ~ gbTt~N# ~ ~ ~ / Hailit)urton Company P h ll HALLIBUR TON Conoco i ips Planning Report -Geographic Alaska gory Drilling Services Database: EOM 2003,11 Single llserDb Local Co-ordinate Reference: Well"Plan 1J-1:68 (L3) Company: ConocoPhillipsAlaska (Kuparuk) TVD Reference: 1J-168 (28+g1) @ 109:OOft {Ooyon 141 @ 28') Project: Kuparuk River Unit MD Reference: 1J-168 (28+g1) @ 109:OOft (Doyon 141 @ 28') Site: KuparuK1J Pad North Reference: True .Well: Plan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Weltbore: 1J-168 L2 Design: 1J-168 L2 (wp08) ~ Geologic Targets 1J-168 L2 - - -~ I I ! TVD Target Name +N!-S +E!-W Northing Easting III I (ft) -Shape ft ft (~) i (ft) 3,365.00 1J-168 L2 T6 (v4) 4,453.89 -4,787.88 5,950,069.00 553,890.00 3,289.00 1J-16812 T2 (v4) 2,534.64 -4,786.84 5,948,150.00 553,906.00 3,453.00 1J-168 L2 Toe (v4) 6,350.34 -4,815.10 5,951,965.00 553,848.00 3,413.00 1J-168 L2 T7 (v4) 5,748.11 -4,794.81 5,951,361.00 553,873.00 3,442.00 1J-168 L2 T8 (v4) 6,031.19 -4,800.59 5,951,646.00 553,865.00 3,297.00 1J-168 L2 T3 (v4) 2,769.68 -4,788.07 5,945,385.00 553,903.00 3,245.00 1J-168 L2 Heel(v4) 284.30 -4,779.39 5,945,900.00 553,931.00 3,408.00 1J-168 L2 T6 {v4) 3,445.00 1J-168 L2 T9 (v4) 3,326.00 1J-168 L2 T4 (v4) 3,270.00 1J-168 L2 T7 (v4) 3,434.00 1J-168 L2 Faultlntersect 5,596.08 -4,792.98 5,951,211. 00 553,876.00 6,125.22 -4,802.85 5,951,740. 00 553,862.00 3,533.78 -4,788.05 5,949,149. 00 553,897.00 1,484.49 -4,784.03 5,947,100. 00 553,917.00 5,711.10 -4,794.08 5,951,326. 00 553,874.00 3/30/2005 4:28:96PM Page 7 of 8 COMPASS 2003.11 Build 48 y~ ~ "°'~ tai w °t ~ ~ws~ 5 ~ 5 Halliburton Company ~ Hgfr.L~BUR7QN ConocoPhillips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: WeU Plan 1J-168 (L3) Company: ConocoPhi!lips Alaska (Kuparuk} ND Reference: 1J-168 (28+81) ~ 109.OOft (Doyon 141 @ 28') Project: Kuparuk River Unit MD Reference: 1J-168 (28+g1) @ 109.OOft (Doyon 141 @ 28') Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Wellbore: 1J-168 L2 Design: 1J-168 L2 (wpD8) r___.--__--- ---- ------ --__-__~ Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ('7 l") 3,554.53 I 2,118.00 10-314 13-112 I 6,834.86 ~ 3,229.36 7-518 9-718 j 12,942.03 3,453.00 4112 6-314 3130/'1005 4:28:46PM Page 8 of 8 COMPASS 2003.11 Build 48 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-168 (L3) 1 J-168 L2 1 J-168 L2 (wp08) Anticollision Report 30 March, 2005 HA.LLIBURTQIV Sperry Drilling Services ~~ ~ ~ . r~ ~ < , h xro SURVEY PROGRAM ConocoPhillips AWska (Kuparuk Date: 2rI0S03-30TIIO:OO:Iq Validated: Yex Version: Engineering West Sak Depth From Depth To Sun~ey/Plan Tool 2A.U11 AINI.Iq CB-GYRO-SS Calculation Method: Minimum Curvature f1W.W 6ft3J.1i-S MWD+IFR-AK-CA7.SC Error System: ISCWSA 683}.!{5 12942.W IJ-168 L2 (wplpl) MWD+IFR-AK-CAZSC Scan Method: Trav. Cylinder North Error SuRace: Elliptical Conic Warning Method: Rules Basetl 0 ~~ :..9 i ^! D 270 90 180 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation )100 ft/in) ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 6834.85 To 12952.3 Maximum Range:5000 Reference: Plan: 1J-168 L2 (wp08) REFERENCE INFORMATION Co-onlinate (N/E) Reference: Well Plan 1J-168 (L3), Tme North Vertical (ND) Reference: 1J-168 (28+81) @ 109.OOfl (Doyon 141 ~ 28') Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: iJ-168 (28+81) ~ 109.OOfl (Doyon 141 ~ 28') Calculation Method: Minimum Curvature WELL DETAILS: Plan 1J-168 (L3) Ground Level: 81.00 +N/-S +EI-W Northing Easting Latittude Longitude Slot 0.00 0.18945653.00 558712.0070°15'43.6411419°31'31.336W From Colour To MD 0 100 100 200 200 300 300 550 550 ---_._. ._ 800 800 1050 1050 --'_-- -- 1550 1550 2050 2050 2550 2550. _.. .___ 3050 3050 3550 3550 5050 5050 -------- 6550 6550 - - 8050 8050 9550 9550 11050 11050 12550 12550 13000 LEGEND --[}--~ tE-112,1E-112.1E-112 V1 ---#-- tE-112,1E-112L1,1E-112L1 V0 -~~~~~ tE-112. tE-112L2,1E-112L2 V1 ~- tE-t 26. 1E-126.1E-126 V1 tE-126.1E-128L1.1E-126Li V1 tE-126.1E-IML2. IE-128L2 V1 --~- IE-36,1E-35, 1E35 V1 -~-- 1E-35. 1Ea5A, 1E-354 (wp02)VO 1110.1110. 1110 V] -~ Ran 1J-111(M121. PYn IJ#1121a1 A, %an lJ-M12 LelA VO ~- PIen IJ-1150.9). Pbn iJ-L9 Vi A, Pbn1X9LetA VO PMn 1J-f 18 (L10), Pbn 1J-L10 Lat A. PMn iJ-L10 V! A VO -yE--- Pbn 11120(L11). Plan 1J-L11 Lat A. PMn 1J-L11 letA VO ~I~ Pbn 111221L121, Pbn 1Jii2 La[A, Pbn 1J-L1I La1A VO Pbn 1J-1240.13). Pbn 1J-Lf3Lat A, %en iJ-L13 LatA VO a Pbn 1J-12] (LB). Pbn 11L8latA. Pbn 1J-LB V M V0 ...[:1 pyn 11129(G131. Pbn iJ-013 BLai. Plan iJ pl3BLetW ~- Pbn 11158 (rM).Pbn 111MALat.PMn 1J#W AISIW %en 1J-157 (C-KuP7, 1J-C (KUP1. 1JL (KU~ VeriO A V4 %an IJ-1581M3), 11M3 A lafanl, iJ-M3 A LeleM1l Verst2A 1 $- Pbn 1J-1591M]).11159.1J-159 (wp031 V0 I Pbn 11159 (Al]).1J-159 L1.1J 159L1 (wpD31 VO -~~--- PMn 1J-1591M]), iJ-159 L2. 1J-159L21wp031 V0 PMn iJ-160 (M21, Pbn 11M21a1 A. Pbn 11M2 LM A VO -~ Prn 1116211A1). 11162. 1J-182 (wp03.1 NOM Heap VO Plan iJ-162 (Mt). 11182 L1, 11162 L1 (wp3.1) VO $ PMn 1J-162 (M1), 111132 L2, 11162 L2 (wP3.1) VO %an 11164 (L61, 111 W, iJ16A Lat Iwp03) VO -~- Plan 11160 (1.8).1J-164 LI, 1J~164L1 (wp03)VO --8' PMn 11184 (L6).1J-161 L2, 1J-164 L21wp03)VO -$--~ %en 11188 (LS),11166. 1J-1%(wp03)VO -8- Plan 111660.51.iJ-186Lt, 1J~166 L1 (wp03)VO -~- %en 11166 (LS), 1J-166 L2, 1J-166 L2 (wp03) VO -~~-- Pbn iJ-i]00.q. PMn 1J-L4 LaM. PMn 1J-LO lnM Vo -~ PMn 111]d 1G1),Pbn 1J-01 Blot. %en 1J-01 BLal vo --Q- Plan 111]5(A-KUp).1J-A (KWI. 1J-A (KLIP)VerlOA V3 Pbn 111]8(02). %an iJ-02BLa1.Pbn 1J-02BLel VO - Pbn iJ-i]8 (G31, %an 1J-03Blal. Plan 11G3B UtVO PMn 111 n11B~KUP). 1J-B (KUPI. IJ-B (KUf') VarM.A VB --~- Plen 111801G4). %an iJ-04 a Lat. PMn 1J-04 B Let VO -~- WSP-03, WSP-03, WSP-03 V1 -~ WSP-00, WSP-04, WSP-01 Vi -~ WSP-05, WSP~OS, WSPJ)5 V1 -$- WSP-06. WSP-O6, WSP-08 V1 --~fy WSP-0], WSP~O], WSP-0]V1 -$- WSP-08, W6P~00, WSP-08 V1 -~- WSP-20, W9P~20,WSP-20 V1 -~ 1J-188 LZ (wpOB) 0 180 Travelling Cylinder Azimuth (TFO+A7.1) ~°) vs Centre to Centre Separaton X40 ft/ink 9. • I SECTION DETAILS e Sec MD Inc Azi ND +N/-S +E/-W 1 6834.85 75.00 345.00 3229.38 258.30 -4727.93 2 6846.85 76.91 345.00 3232.27 269.55 -4730.94 3 6864.85 76.91 345.00 3236.35 288.48 -4735.48 4 7098.16 90.00 350.00 3262.91 512.24 -4785.39 5 7342.09 89.80 2.19 3263.34 755.14 -4801.97 6 7801.61 69.80 2.19 3264.95 1214.33 -4784.37 7 7866.84 88.81 359.78 3265.74 1279.53 -4783.24 8 8071.84 88.81 359.78 3270.00 1484.49 -4784.03 9 8077.43 88.96 359.85 3270.11 1490.08 -4784.05 10 9122.17 88.96 359.85 3289.00 2534.64 -4786 84 11 9155.25 87.98 359.71 3289.88 2567.71 -4786.97 12 9357.35 87.98 359.71 3297.00 2769.88 -4788.01 13 9368.42 87.83 360.00 3297.41 2780.75 -4788.04 14 10121.99 87.83 360.00 3326.00 3533.78 -4788.05 15 10130.46 87.57 0.01 3326.34 3542.23 -4788.05 16 11042.94 87.57 0.01 3365.00 4453.89 -4787.88 17 11051.87 87.59 359.74 3365.38 4462.82 -4787.90 18 12186.25 87.59 359.74 3413.02 5596.18 -4792.98 19 12200.44 87.52 359.28 3413.62 5610.36 -4793.10 20 12336.65 87.52 359.28 3419.51 5748.43 -4794.81 21 12384.86 86.16 358.80 3422.17 5794.57 -4795 62 2212621.97 86.16 358.80 3438.05 6031.08 -4800.59 2312637.09 85.75 358.61 3439.12 6046.16 -4800.93 DLeg TFace VSec Talget 0.00 0.00 258.30 15.90 0.00 289.55 0.00 0.00 288.48 6.00 21.12 512.24 5.00 90.95 755.14 0.00 0.00 1214.33 4.00 -112.28 1279.53 0.00 0.00 1484.49 iJ-168 L2 T1 (v4) 3.00 23.43 1490.08 0.00 0.00 2534.64 iJ-168 L2 T2 (v4) 3.00 -171.82 2567.71 0.00 0.00 2769.88 1J-168 L2 T3 (v4) 3.00 118.04 2780.75 0.00 0.00 3533.78 1 J-188 L2 T4 (v4) 3.00 177.30 3542.23 0.00 0.00 4453.89 1J-188 L2 T5 (v4) 3.00 -85 43 4462.82 0.00 0.00 5596.18 1J-168 L2 T6 (v4) 3.30 -98.75 5810.36 0.00 0.00 5748.43 iJ-168 L2 T7 (vd) 3.00 -160.50 5794.57 0.00 0.00 6031.08 1 J-188 L2 T8 (v4) 3.00 -155.15 6046.18 ~ '/ Halliburton Company ConocoPh illips Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit. . TVD Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1J-168 (L3) Survey Calculation Method: Well Error. O:OOft Output errors are at Reference Wellbore 1J-168 i2' Database: .Reference Design: 1 J-168 L2 (wp08) Offset TVD Reference: HALLIBURTON Spsrry Drilling Services Well Plan 1J-168 (L3) 1J-168 (28+g1} @ 109:OOft (Doyon 141 @ 28') 1J-168 (28+81") @ 109.OOft,(Doyon 141 @ 28') True Minimum Curvature 1.96 sigma " EDM 2003.11 Single User Db Offset Datum Reference 1J-168 L2 (wp08) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 6,834.85 to 12,952.30ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 5,000.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3/30/2005 From To (ft) (ft) Survey (VYellbore) 28.00 800.00 1J-168 (wp08) (1J-168) 800.00 6,834.85 1J-168 (wp08) (1J-168) 6,834.85 12,942.04 1J-168 L2 (wp08) (1J-168 L2) Tool Name CB-GYRO-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Description Camera based gyro single shot MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC Summary Site Name Offset Well - Welltwre -Design Kuparuk 1E"Pad 1 E-35 - 1 E-35 - 1 E-35 1 E-35 - 1 E-35A -1 E-35A (wp02) Kuparuk 1J Pad 1 J-10 - 1 J-10 - 1 J-10 Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 Lat A Plan 1J-118 (L10) -Plan 1J-L10 Lat A -Plan 1J-L10 Plan 1J-120 (L11) -Plan 1J-L11 LatA-Plan 1J-L11 Plan 1 J-122 (L12) -Plan 1 J-L12 Lat A -Plan 1 J-L12 Plan 1J-124 (L13) -Plan 1J-L13 Lat A-Plan 1J-L13 Plan 1J-127 (L8)-Plan 1J-L8 LatA -Plan 1J-L8 LatA Plan 1J-157 (C-Kup) - 1J-C (KUP) - 1J-C (KUP) Ver# Plan 1J-162 (M1) - 1J-162 - 1J-162 (wp03.1-North Heel Plan 1J-162 (M1) - 1J-162 L1 - 1J-162 L1 (wp3.1) Plan 1J-162 (M1) - 1J-162 L2 - 1J-162 L2 (wp3.1) Plan 1 J-164 (L6) - 1 J-164 -1 J-L6 A Lat (wp03) Plan 1J-164 (L6) - 1J-164 L1 - 1J-164 L1 (wp03) Plan 1J-164 (L6) - 1J-164 L2- 1J-164 L2 (wp03) Plan 1J-166 (LS) - 1J-166 - 1J-166 (wp03) Plan 1J-166 (LS)- 1J-166 L1 - 1J-166 L1 (wp03) Plan 1 J-166 (L5) - 1 J-166 L2 - 1 J-166 L2 (wp03) Plan 1J-170 (L4) -Plan 1J-L4 LatA-Plan 1J-L4 LatA Plan 1J-175 (A-Kup) - 1J-A (KUP) - 1J-A (KUP) Ver# Plan 1J-179 (B-Kup) - 1J-B (KUP) - 1J-B (KUP) Ver# Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance {ft) from Plan ~ 12,933.28 10,525.00 2,193.32 157.27 2,036.05 I Pass-Major Risk 12,929.75 10,425.00 1,510.81 147.33 1,363.48 Pass-Major Risk I 9,084.03 6,875.00 767.84 109.93 657.91 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range 10,336.48 10,849.03 3,082.84 116.26 2,966.58 Pass -Major Risk 6,854.71 7,425.00 1,888.33 96.95 1,791.38 Pass- Major Risk 6,854.71 7,425.00 1,888.33 96.85 1,791.48 Pass-Major Risk 6,854.71 7,425.00 1,888.33 96.85 1,791.48 Pass- Major Risk 12,749.84 8,825.00 4,243.83 226.80 4,017.02 Pass -Major Risk 12,716.39 8,750.00 4,234.56 209.58 4,024.99 Pass -Major Risk 12,742.42 8,799.96 4,234.99 213.13 4,021.86 Pass -Major Risk 12,446.61 9,350.00 2,939.94 217.38 2,722.56 Pass- Major Risk 12,359.52 9,250.00 2,926.52 201.83 2,724.69 Pass -Major Risk 12,363.87 9,250.00 2,925.20 205.09 2,720.11 Pass -Major Risk 12,761.15 12,081.58 1,465.45 241.31 1,224.14 Pass -Major Risk Out of range 7,076.36 13,199.95 2,964.65 116.70 2,847.95 Pass -Major Risk CC -Min cenVe to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/30/2005 4:31:42PM Page 2 of 64 COMPASS 2003.11 Build 48 e ~~ .: 5 a . c:' e • 1~- Drillinc 6 3/4'° Open Hole / 4 1/2" Liner Interval • Is Summa Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, Shut-in drills, Increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD Tools, Hole O ener, 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 7J-168L2 Drilling Hazards Summary prepared by Shane Cioninger March 31, 2005 3' ~ ~ ~ > V V I~ Ire Tubing String: 4-1/2" 12.6#, L-80, IBTM, Spec. Clearance Couplings, (4.920" OD) 10-3/4" Casing, L-80, ' BTC set @ +/- 3555' MD, 2118' TVD, 13-1/2" hole 5-1/2" X 7-5/8" Model'B' HOOK Hanger (2) Gas Lift Mandrels, 4-1/2" X 1" Electric Submersible Pu p, FC6000 WL Deployetl Pump Sa6d Window +/- 6835' MD, 3229' TVD _ _ 6-3/4" Lateral TD @ 12942' MD, 3453' TVD 'D' Sand Lateral ~^ r'niGt~s Baker Oil Tools Latera With D l Entry Module (LEM1 iverters and Isolation Lateral Access Divener Lateral Isolation Divener GS Running Tool Strkmg Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector I f Running/Retdevirg ~ (1.00'Length) Snap In/Snap Out ~ Poskive Locating ti ~ r Back Pressure Valve C ll (1.60' Length) I o et Laterellsolation ~ r Fbw-Thm Swivel Seale (1.25' Length) / Lateral Divener i Hydraulic Ramp I Disconnect ' Isolatbn/Mainbore ~~ (1.50 Length) Diverter Sleeve ~ i ~- GS Spear ` I I (1.50' Length) Lateral Isolation Seals ; 6.85 h Approx. OAL' I II J ~ ' 'Jars may be required kr highly deviated 18.5' Diverter Len ~i 9th 18.5' Sleeve Length or deep applications (8' approx length). 4-1/2" 12.6#, LAO, Slotted Liner . SOS-OG~ 5-112" X 75/8" ZXP __. Liner Top Packer \ with Hold Downs Lateral Entrv Module (LEMZ ~, Assembly 5-112" X 7518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID -- Tubing Swivel, 4-112" --- Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access window Positive Lateral Aecess Via Thru-Tubing Divener Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbore Receptacle 4-112" X 7-518" Model 'B' HOOK Hanger ' Ensure LEM Position #1 is used. Tubing, 4112" 12.6a<, / from LEM to A2 Liner, w/ seal -~ stem and 3.562" DB Nipple 'B' Sand Lateral 4-1/2" 12.6#, LAO, Slotted Liner 3.562" DB Nipple 5-112" X 7-518" ZXP Liner Top Packer /r with Hold Downs / Liner Hanger /Packer 5-1/2" X 75/8" Flex Lock Assembly Top at ~iner Hanger +/- 7261' MD, 3323' TVD Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +/- 8306' MD, Baker Huehea 1003. Thia aocumanl mry nol be reproaucM or aiatributea, in whole w in pan, in any farm « 3483' TV D, Set @ 80 deg, ey any mean. Neuronic or m«nanica, inaaair,s vhor«ovvme, r«omma. or ay ary ~morm,em amraBe ana p retrieval system paw Ynown or hereana inventM, vaamur wrinen permifaion hom Baker xuehes Inc 9-7/8" HDIe. Equipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LatereUMainbore Divener OD: 6.75" 4-1 /2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Divener and Sleeve: +l- 3.89" Divener and Sleeve Length: il- 18.5' 6-3/4" Lateral TD @ 12975' MD, 3658' TVD. 1J-188 Tri-lateral Completion -Producer Down ar: - aeai.ian xa.: D 2005 Marc D. Kuck ConocoPhillips West Sak 1J-168 Producer 7-5/8" Tri-Lateral Completion at +/- 7185' MD, 3310' TVD 6-3/4" Lateral TD @ 12952' MD, 3512' TVD 'A' Sand Undulating Lateral 4-112" 12.6#, LAO, slots over sand, blank over shales, constrictors for isolation r tE-i,~ / ~ ~ ID-132 1 10 X38 ~ E-28 1u G -2z 10 t 1D-1270-131 -t 2~ 1D-07 1D-134 ~' 1 1 1 °-°B n~n~n~, KRU 1 J-168L2 fE-3tP I -tOSPBI ____ - _~ 4 2 Zs Proposed 1-Oil i tE 119 - 1• ~ E West Sak "D" Sand ,09 ~~28 ~ , '~~i I 34 1'E=1'~~ ' -'~ • 2050620 , ~I ' 'E-sa +E-3z 1 1 -18;8L2 ~~ tJ-1sa ~ Slotted Liner Confidential wells are red ~ _ SFD 4/13/2005 ~ 2000 1 ~.''0~1 L-29 s ,E-~~ ' • - ~~~~ ... • 1J-1`-. - ~ 34 35 ~-~_ -~ - 1L-za4 l'1 COQ ~ t n •. ~ • 1 1L-21D ~ 8000 ~ ` a, ~ ~ -' T11 N ~'10E, UNl a p v7 N ~ ~' ,~ 'Y 1~ R ,~~ir~t. ' '~ !S'~ -1 t i 1 . I , i I~ r~ , ', i T 10N, X11 E, Cii~T N Feet D 1 ,DOD 2,DD0 3,x00 4,DOD N-154Lt • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO SE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~~' ~~ /~~ ~ ~- PTD# ~--~ ~ ~ ~~ ~" CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ,~/~~ ~-P"~~~ Permit No,~~ =v~API No. ~°~ ~: ~°' ~ (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pig records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~'~~ Rev: 04/01/05 C\jody\trans m ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-168L2 Program DEV Well bore seg 0 PTD#:2050620 Company CONOCOPHILLIP$ ALASKA INC Initial Classlfype DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached_ _ _ _ - - - NA_ _ - _ - -West Sak D Sand multilateral well segment; fee-waived per 20 AAC 25:005(e), 2 Lease number appropriate______________________ _________ ________Yes____ _Top-productive interval andTD_inADL025ti60.____-.__--__-.--__--_----.---_- 3 Uniquewell_nameandnumber_ _________ __ _____ _ ___ ____Yes_--- ---------.,..____ -------------------------------------------------- 4 Well located in_a_d_efined_pool _ _ . _ - _ _ - . _ - , Yes - KRU West_Sak Oil Pool, goyerned_by Conservation_Order_No, 4066_ _ - _ _ _ . _ _ _ _ 5 Well located proper distance_ from drilling unitboundary_ - - Yes _ _ - - - _ Well is more_than500 feet from an external property line. _ _ - - _ . , - . _ , 6 Well located p[operdistance_fro_motherwells_-_--_-.--__________ ___ _____Yes______ _No[esttictionsas_to well spacing in CO.4066.____.,_.-__-______-___.___._ 7 Sufficient acreage available in-drilling unit... _ - - _ _ . Yes _ _ - - _ - No restrictions as,to well spacing except that no-p_ay shall be opened in a well closer _ _ - - _ - 8 If deviated, is_wellbore platincluded - - - - _ . _ _ - _ _ - _ _ , Yes - - - - . - -than 50.0 feet to-an external_prope[ty line._ -- - 9 Operator only affected party. - - - - - Yes - - - - - - 10 Operatorhas_appropriate-bond in force - - -- -- --- --_- ._..-_.-Yes ---- - -- - ---- ---- ------ ---------------- ------- ----------- --.. 11 Permit can be issued without conservation order Yes -- - -- - Appr Date 12 Pe[mitcanbeissuedwithou/administrative-approyal__ ____________ ______._Yes____-- ----_._____-_-.--_-______-_____ ------------------------------------- SFD 4!13/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthorizedbylnjectionOrder#(put_1O#in_comments)-(FQr_ NA______ ______________---___________---.______-__--________--_--_-______- 15 All wells within1/4-milearea_of[eyiewidentified(Forservicewe//only)______ _________ NA_-_--_. _____-____.-...--__--____.__-_:__-_____--.______-_ ------------------ 16 Pre-produced injector: duration of pre production less than_ 3 months_(For servi ce well only) NA_ . _ _ _ . _ _ - 17 AC_M_P-Finding of Consistency-has been issued_for-this project_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ - - - - Engineering 18 Conductor string-provided-______,______-__-._--._______ _________ NA_____ _Conductorset_inmotherbore1J-168(205-060)._--_----_______--__--_..__ -------------- 19 Su_rfacecasing-protectsall_knownUSDWs_________ ____________ _________ NA____--- _Allaquifersexempted,40CFR,147.102(b)~3).__--_-__________-.-__________________-__ 20 CMT_vol_adequate_to circul_ate_on conductor& surf_csg _ _ - . _ NA- - _ _ _ - - .Surface casin set in 1J-168._ g- -- - --- 21 CMT_vol_ adeguate_to tie-in long string to surf csg_ - _ - - _ - _ _ NA_ - _ - - . - Produ_clion_casing set in-1J-168. All_hydrocarbon formations planned to_be-covered. _ _ . 22 CMT_will coyer all known_productiye horizon_s_ ~ _ - - _ - No_ Slatted liner completion planned.. - _ . , _ _ 23 Casing designs adequatef_orC,_T,13&_permafrost--------- ------- ---------Yes----. -------------------------------------------------------------- 24 Adequate tankage_or reserve pit _ - _ _ _ - . - - - . _ Yes Rig is_e-quipped with steel.pits. _ No rese_rve_pitplanned, All waste to approved annulus or disposal wells. - _ _ _ _ _ 25 Ifa_re-drill,hasa_1.0-403 for abandonment been approved____________ _________ NA_--____ ._____-__--_.._____-_.-____________--_---________---_____-__---__ 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - _ Proximity. analysis perf_o[med, Traveling cylinderplot provided. Nearest wellbore is B lateral X110' tyd_ below _ - - _ 27 Ifdiverterrequired,doesitmeetregulations_____________________ _________ NA_--___, _BOPstackwillalready_beinplace,-_-_--_________-__--_______.-_.-__-_____-__-,__ Appr Date 28 Drilling fluid_ program schematic & equip listadequate . . . . . .. . . . ..... Yes - - _ . - - Maximum expect formation pressu-re 9.9 EMW. _Planned MW up-to 9.0 in WS._ _ . _ _ - _ - . - _ _ _ _ - . - - - . _ TE 4/14/ 005 29 _B_OPEs, do they meetregu_lotion - - - - - - - Yes - - - - - - - - - - - - - - 30 BOPE_press rating appropriate; test to,(pu_t p&ig in comments)- .. - - - - - -Yes MASP calculated at 11.34 psi, 3000_psi_appr_opriate. CPAI normal tests to 5000-psi, - _ _ . _ _ 31 Choke_manifoldcomplieswlAPLRf?-53(May84)___________________ _________Yes____-- __-__._____ 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - . _ 33 Is presence-of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- - - _ _ - - _ No production_on_pad, but_H2S_has not been reported in WS production. _Rig has sensorsand alarms, _ - - _ - - - 34 Mechanical_condition of wells within AOR verified GForservice well only) _ - - _ _ . _ NA_ Geology 35 Permit_can be issued w!o hydrogen-sulfide measures - - - .. - . - . _ - - - - . - - , Yes _ _ - - _ - ------------------------------------------------------------- 36 Data-presented on_ potential overpressure zones - - - - - - - - - - - - - - _ _ ,Yes . - Expected reservoirpressure is 8,6-- 9,0_ppg EMW; will_be drilled with 9.Oppg mud.. _ - . _ - _ - - - - - - _ - - - Appr Date 37 Seismic analysis of shallow gas zones__________ ____________ ________ NA_-____. -_-,__ -------------------------------------------------------------- SFD 4113!2005 38 Seabed condition survey_(ifgff-shore) - _ _ _ _ - _ - - . - - -- ~A- - - - -- - - ---- - 39 -Contact namelphone for weekly progress-reports (exploratory only]_ _ - _ NA. - Geologic Engineering Pub Commissioner: Date: Commissioner: Date o s' ne Dat (~rS ~1 ~~~~ ~ ~_/y-oS ~~~ C • Wel! History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision; 3 $ LisLib $Revision: 4 $ Wed Jan 25 14:47:16 2006 Reel Header Service name ............ .LISTPE Date .................... .06/01/25 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Tape Header Service name ............ .LISTPE Date .................... .06/01/25 Origin .................. .STS Tape Name ............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: MW0003877631 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: M, THORTON MWD RUN 10 JOB NUMBER: MW0003877631 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: M. THORTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • 13 44s a05-~~ Scientific Technical Services Scientific Technical Services 1J-168 L2 500292326061 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-JAN-06 MWD RUN 4 MWD RUN 5 MW0003877631 MW0003877631 T. GALVIN P. ORTH M. THORTON D. GLADDEN MWD RUN 11 MWD RUN 12 MW0003877631 MW0003877631 P. ORTH P. ORTH M. THORNTON M. THORTON 35 11N l0E 1841 2499 109.00 81,00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE {IN) DEPTH (FT) 1ST STRING 9.875 10.750 3693.0 2ND STRING 6.750 7.875 6785.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF AN OPENHOLE SIDETRACK AT 8680'MD/ 3264'TVD WITHIN THE RUN 11 INTERVAL OF THE 1J-168 L2 PB1 WELLBORE. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5,11,12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4,11,12 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 9 WAS TO CHECK THE ORIENTATION OF THE LATERAL ENTRY MODULE (LEM) - NO MWD DATA WERE ACQUIRED. THE WHIPSTOCK (FOR 1J-168 L2 PB1) WAS POSITIONED DURING MWD RUN 10, ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 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 3-5,10-12 REPRESENT WELL 1J-168 L2 WITH API#:50-029-23260-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12959'MD / 3424'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING}. SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 3662.0 RPM 3662.0 RPX 3662.0 RPD 3662.0 RPS 3662.0 GR 3670.0 all bit runs merged. STOP DEPTH 12908.0 12908.0 12908.0 12908.0 12908.0 12901.0 • ROP 3704.5 12959.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 3662. 0 5642.0 4 5642. 0 6205.0 5 6205. 0 6785.0 10 6785. 5 6826.0 11 6826. 0 8680.0 12 8680. 5 12959.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3662 12959 8310.5 18595 3662 12959 RPD MWD OHMM 0.94 2000 65.419 18493 3662 12908 RPM MWD OHMM 3.28 1809.23 59.0504 18493 3662 12908 RPS MWD OHMM 5.7 2000 58.1288 18493 3662 12908 RPX MWD OHMM 0.48 354.29 53.7543 18493 3662 12908 FET MWD HOUR 0.12 580.79 1.43264 18493 3662 12908 GR MWD API 24.54 118.68 73.7912 18463 3670 12901 ROP MWD FT/H 1.01 679.83 191.784 18510 3704.5 12959 First Reading For Entire File..........3662 Last Reading For Entire File...........12959 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header • Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 3662.0 5600.0 RPD 3662.0 5600.0 RPM 3662.0 5600.0 RPX 3662.0 5600.0 FET 3662.0 5600.0 GR 3670.0 5607.5 ROP 3704.5 5642.0 LOG HEADER DATA DATE LOGGED: 20-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5642.0 TOP LOG INTERVAL (FT) 3704.0 BOTTOM LOG INTERVAL (FT) 5642.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.5 MAXIMUM ANGLE: 71.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 52.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.910 91.0 MUD FILTRATE AT MT: 4.800 68.0 MUD CAKE AT MT: 3.250 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record • Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3662 5642 4652 3961 3662 5642 RPD MWD030 OHMM 0.94 2000 41.1991 3877 3662 5600 RPM MWD030 OHMM 3.28 1809.23 18.3042 3877 3662 5600 RPS MWD030 OHMM 5.7 1112.47 14.3103 3877 3662 5600 RPX MWD030 OHMM 0.48 40.61 13.3675 3877 3662 5600 FET MWD030 HOUR 0.12 59.83 1.7642 3877 3662 5600 GR MWD030 API 24.54 118.68 65.9548 3876 3670 5607.5 ROP MWD030 FT/H 1.46 679.83 195.606 3876 3704.5 5642 First Reading For Entire File..........3662 Last Reading For Entire File...........5642 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5600.5 6159.5 RPX 5600.5 6159.5 RPD 5600.5 6159.5 RPS 5600.5 6159.5 RPM 5600.5 6159.5 GR 5608.0 6167.5 ROP 5642.5 6205.0 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) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE $IT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9,10 MUD VISCOSITY (S) 57.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 MUD AT MAX CIRCULATING TERMPERATURE: 3.310 MUD FILTRATE AT MT: 4.800 MUD CAKE AT MT: 3.250 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: Data Format Specification Re cord 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 Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 23-AUG-OS Insite 66.37 Memory 6205.0 5642.0 6205.0 66.4 70.8 TOOL NUMBER 124725 121079 • 68.0 79.0 68.0 68.0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5600.5 6205 5902.75 1210 5600.5 6205 RPD MWD040 OHMM 9.51 19.25 14,1124 1119 5600.5 6159.5 RPM MWD040 OHMM 8.72 20.31 13.8028 1119 5600.5 6159.5 RPS MWD040 OHMM 7.97 20.93 13.6461 1119 5600.5 6159.5 RPX MWD040 OHMM 7.67 20.72 13.4856 1119 5600.5 6159.5 FET MWD040 HOUR 0.19 60.1 5.1829 1119 5600.5 6159.5 GR MWD040 API 28.83 103.96 65.2015 1120 5608 6167.5 ROP MWD040 FT/H 11.54 552.69 145.563 1126 5642.5 6205 First Reading For Entire File..........5600.5 Last Reading For Entire File...........6205 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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..... ..06/01/25 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; 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6160.0 6785.0 RPX 6160.0 6785.0 RPS 6160.0 6785.0 RPM 6160.0 6785.0 RPD 6160.0 6785.0 GR 6168.0 6785.0 ROP 6205.5 6785.0 LOG HEADER DATA DATE LOGGED: 24-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6785.0 TOP LOG INTERVAL (FT) 6205.0 BOTTOM LOG INTERVAL (FT) 6785.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.8 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G); 9.10 MUD VISCOSITY (S) 49.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.560 109.4 MUD FILTRATE AT MT: 4.650 70.0 MUD CAKE AT MT: 3.150 70.0 NEUTRON TOOL MATRIX; MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: Da ta Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6160 6785 6472.5 1251 6160 6785 RPD MWDO50 OHMM 7.23 64.6 14.9971 1251 6160 6785 RPM MWDO50 OHMM 6.86 69.26 14.5013 1251 6160 6785 RPS MWDO50 OHMM 6.41 72.75 14.0487 1251 6160 6785 RPX MWDO50 OHMM 6.04 72.22 13.359 1251 6160 6785 FET MWDO50 HOUR 0.25 13.37 1.75364 1251 6160 6785 GR MWDO50 API 25.85 106.63 74.8432 1235 6168 6785 ROP MWDO50 FT/H 5.04 554.65 134.951 1160 6205.5 6785 First Reading For Entire File..........6160 Last Reading For Entire File...........6785 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO • Next File Name...........STSLIB.005 Physical EOF File Header Service name.~............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6785.5 6826.0 LOG HEADER DATA DATE LOGGED: 16-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME}: Memory TD DRILLER (FT) 6826.0 TOP LOG INTERVAL (FT) 6785.0 BOTTOM LOG INTERVAL (FT) 6826.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.5 MAXIMUM ANGLE: 75.0 TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6785.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 89.0 MUD PH: .0 MUD CHLORIDES (PPM): 67500 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 81.2 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 DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 6785.5 6826 6805.75 82 6785.5 ROP MWD100 FT/H 3.21 36.66 21.9029 82 6785.5 First Reading For Entire File..........6785.5 Last Reading For Entire File...........6826 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................L0 Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit r un in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6785.5 8680 .0 FET 6785.5 8680 .0 RPX 6785.5 8680 .0 RPM 6785.5 8680 .0 RPS 6785.5 8680 .0 RPD 6785.5 8680 .0 ROP 6826.5 8680 .0 LOG HEADER DATA DATE LOGGED: 18-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8680.0 TOP LOG INTERVAL (FT) 6826.0 BOTTOM LOG INTERVAL (FT) 8680.0 Last Reading 6826 6826 • BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.0 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYP E TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73764 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT ) 6785.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 86.0 MUD PH: .0 MUD CHLORIDES (PPM): 52000 FLUID LOSS (C3) 1.8 RESISTIVITY (OHMM) AT TEMP ERATURE (DEGF) MUD AT MEASURED TEMPERA TURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....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 N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM ,4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6785.5 8680 7732.75 3790 6785.5 8680 RPD MWD110 OHMM 20.7 163.9 96.7751 3790 6785.5 8680 RPM MWD110 OHMM 18.9 226.54 94.8842 3790 6785.5 8680 RPS MWD110 OHMM 18.61 2000 95.7633 3790 6785.5 8680 RPX MWD110 OHMM 7.08 186.79 86.8343 3790 6785.5 8680 FET MWD110 HOUR 0.18 580.79 1.14664 3790 6785.5 8680 GR MWD110 API 48.31 106.11 71.5009 3790 6785.5 8680 ROP MWD110 FT/H 1.01 356.35 221.964 3708 6826.5 8680 First Reading For Entire File..........6785.5 . • Last Reading For Entire File...........8680 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8680.5 12908.0 RPD 8680.5 12908.0 GR 8680.5 12901.0 ROP 8680.5 12959.0 RPS 8680.5 12908.0 RPX 8680.5 12908.0 FET 8680.5 12908.0 LOG HEADER DATA DATE LOGGED: 20-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12959.0 TOP LOG INTERVAL (FT) 8680.0 BOTTOM LOG INTERVAL (FT) 12959.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 90.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73764 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6785.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 78.0 MUD PH: .0 MUD CHLORIDES (PPM): 43500 FLUID LOSS (C3) 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) • MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.6 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 RPD MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 S 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8680.5 12959 10819.8 8558 8680.5 12959 RPD MWD120 OHMM 30.47 151.14 76.7187 8456 8680.5 12908 RPM MWD120 OHMM 24.95 147.34 74.2499 8456 8680.5 12908 RPS MWD120 OHMM 21.47 2000 73.7592 8456 8680.5 12908 RPX MWD120 OHMM 19.12 354.29 68.7498 8456 8680.5 12908 FET MWD120 HOUR 0.2 9.47 0.865044 8456 8680.5 12908 GR MWD120 API 51.09 109.16 79.4031 8442 8680.5 12901 ROP MWD120 FT/H 3.63 348.89 192.388 8558 8680.5 12959 First Reading For Entire File..........8680.5 Last Reading For Entire File...........12959 File Trailer Service name............ Service Sub Level Name.. Version Number.......... Date of Generation...... Maximum Physical Record. File Type ............... Next File Name.......... Physical EOF Tape Trailer STSLIB.007 1.0.0 06/01/25 65535 LO STSLIB.008 Service name ............. LISTPE Date ..................... 06/01/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 Next Tape Name........... UNKNOWN . • Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/01/25 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 e • Sperry-Sun Drilling Services LIS Scan Utility $Rev ision: 3 $ LisLib $ Revision: 4 $ Wed Jan 25 16:05:18 2006 1344-1,p Reel Header n(\~ ~. Q~ Service name ......... ....LISTPE ~yLV Date ................. ....06/01/25 Origin ............... ....STS Reel Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Reel Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library. Scientific Technical Services Tape Header Service name ......... ....LISTPE Date ................. ....06/01/25 Origin ............... ....STS Tape Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Tape Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-168 L2 PB1 API NUMBER: 500292326070 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 25-JAN-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0003877631 MW0003877631 MW0003877631 LOGGING ENGINEER: T. GALVIN T. GALVIN P. ORTH OPERATOR WITNESS: M. THORTON M. THORTON D. GLADDEN MWD RUN 10 MWD RUN 11 JOB NUMBER: MW0003877631 MW0003877631 LOGGING ENGINEER: P. ORTH P. ORTH OPERATOR WITNESS: M. THORTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1841 FEL: 2499 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3693.0 2ND STRING 6.750 7.875 6785.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 6785'MD/3214'TVD WITHIN THE RUN 5 INTERVAL OF THE 1J-168 WELLBORE. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGE MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4,11 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUN 9 WAS TO CHECK THE ORIENTATION OF THE LATERAL ENTRY MODULE (LEM) - NO MWD DATA WERE ACQUIRED. THE WHIPSTOCK WAS POSITIONED DURING MWD RUN 10, ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 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 3-5,10,11 REPRESENT WELL 1J-168 L2 PB1 WITH API#:50-029-23260-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9435'MD / 3292`TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH RPM 3662.0 RPX 3662,0 FET 3662,0 RPD 3662.0 RPS 3662.0 GR 3670.0 all bit runs merged. STOP DEPTH 9384.0 9384.0 9384.0 9384.0 9384.0 9377.0 • • ROP 3704.5 9435.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 3662.0 4 5642.0 5 6205.0 10 6785.5 11 6826.0 MERGE BASE 5642.0 6205.0 6785.0 6826.0 9435.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3662 9435 6548.5 11547 3662 9435 RPD MWD OHMM 0.94 2000 54,3066 11445 3662 9384 RPM MWD OHMM 3.28 1809.23 45,4771 11445 3662 9384 RPS MWD OHMM 5.7 2000 44.1636 11445 3662 9384 RPX MWD OHMM 0.48 2000 40.8492 11445 3662 9384 FET MWD HOUR 0.12 580.79 1.7225 11445 3662 9384 GR MWD API 24.54 118.68 71.0764 11415 3670 93'77 ROP MWD FT/H 1.01 679.83 193.506 11462 3704.5 9435 First Reading For Entire File..........3662 Last Reading For Entire File...........9435 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 • • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 3662.0 5600.0 FET 3662.0 5600.0 RPS 3662.0 5600.0 RPX 3662.0 5600.0 RPM 3662.0 5600.0 GR 3670.0 5607.5 ROP 3704.5 5642.0 LOG HEADER DATA DATE LOGGED: 20-AUG-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5642.0 TOP LOG INTERVAL (FT) 3704.0 BOTTOM LOG INTERVAL (FT) 5642.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.5 MAXIMUM ANGLE: 71.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 52.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMMj AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 68.0 MUD AT MAX CIRCULATING TERMPER ATURE: 2.910 91.0 MUD FILTRATE AT MT: 4.800 68.0 MUD CAKE AT MT: 3.250 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 • • Data Specification Block Type.....0 Logging Direction ......... ........DOwn Optical log depth units... ........Feet Data Reference Point ...... ........Undefined Frame Spacing ............. ........60 .lIN Max frames per record ..... ........Undefined Absent value .............. ........-999 Depth Units ............... ........ Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3662 5642 4652 3961 3662 5642 RPD MWD030 OHMM 0.94 2000 41.1991 3877 3662 5600 RPM MWD030 OHMM 3.28 1809.23 18.3042 3877 3662 5600 RPS MWD030 OHMM 5.7 1112.47 14.3103 3877 3662 5600 RPX MWD030 OHMM 0.48 40.61 13.3675 3877 3662 5600 FET MWD030 HOUR 0.12 59.83 1.7642 3877 3662 5600 GR MWD030 API 24.54 118.68 65.9548 3876 3670 5607.5 ROP MWD030 FT/H 1.46 679.83 195.606 3876 3704.5 5642 First Reading For Entire File..........3662 Last Reading For Entire File...........5642 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5600.5 6159.5 RPD 5600.5 6159.5 RPS 5600.5 6159.5 RPX 5600.5 6159.5 RPM 5600.5 6159.5 GR 5608.0 6167.5 • • ROP 5642.5 6205.0 LOG HEADER DATA DATE LOGGED: 23-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6205.0 TOP LOG INTERVAL (FT) 5642.0 BOTTOM LOG INTERVAL (FT) 6205.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.4 MAXIMUM ANGLE: 70.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMB ER DGR DUAL GAMMA R AY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 57.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERAT URE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 68.0 MUD AT MAX CIRCULATING TERM PERATURE: 3.310 79.0 MUD FILTRATE AT MT: 4.800 68.0 MUD CAKE AT MT: 3.250 68.0 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-typ e...0 Name Service Order Units Size Nsam Rep Code Offset Channe l DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 I6 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5600.5 6205 5902.75 1210 5600.5 6205 RPD MWD040 OHMM 9.51 19.25 14.1124 1119 5600.5 6159.5 RPM MWD040 OHMM 8.72 20.31 13.8028 1119 5600.5 6159.5 RPS MWD040 OHMM 7.97 20.93 13.6461 1119 5600.5 6159.5 RPX MWD040 OHMM 7.67 20.72 13.4856 1119 5600.5 6159.5 FET MWD040 HOUR 0.19 60.1 5.1829 1119 5600.5 6159.5 GR MWD040 API 28.83 103.96 65.2015 1120 5608 6167.5 ROP MWD040 FT/H 11.54 552.69 145.563 1126 5642.5 6205 First Reading For Entire File..........5600.5 Last Reading For Entire File...........6205 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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.......06/01/25 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6160.0 6785.0 RPS 6160.0 6785.0 FET 6160.0 6785.0 RPM 6160.0 6785.0 RPD 6160.0 6785.0 GR 6168.0 6785.0 ROP 6205.5 6785.0 LOG HEADER DATA DATE LOGGED: 24-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME):. Memory TD DRILLER (FT) 6785.0 TOP LOG INTERVAL (FT) 6205.0 BOTTOM LOG INTERVAL (FT) 6785.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.8 MAXIMUM ANGLE: 84.6. TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 • • BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT): 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 49.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.700 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.560 109.4 MUD FILTRATE AT MT: 4.650 70.0 MUD CAKE AT MT: 3.150 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6160 6785 6472.5 1251 6160 6785 RPD MWDO50 OHMM 7.23 64.6 14.9971 1251 6160 6785 RPM MWDO50 OHMM 6.86 69.26 14.5013 1251 6160 6785 RPS MWDO50 OHMM 6.41 72.75 14.0487 1251 6160 6785 RPX MWDO50 OHMM 6.04 72.22 13.359 1251 6160 6785 FET MWDO50 HOUR 0.25 13.37 1.75364 1251 6160 6785 GR MWDO50 API 25.85 106.63 74.8432 1235 6168 6785 ROP MWDO50 FT/H 5.04 554.65 134.951 1160 6205.5 6785 First Reading For Entire File..........6160 Last Reading For Entire File...........6785 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 • • Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6785.5 6826.0 LOG HEADER DATA DATE LOGGED: 16-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6826.0 TOP LOG INTERVAL (FT) 6785.0 BOTTOM LOG INTERVAL (FT) 6826.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.5 MAXIMUM ANGLE: 75.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6785.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 89.0 MUD PH: .0 MUD CHLORIDES (PPM): 67500 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 81.2 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 DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 Name Service Unit Min Max DEPT FT 6785.5 6826 ROP MWD100 FT/H 3.21 36.66 First Last Mean Nsam Reading Reading 6805.75 82 6785.5 6826 21.9029 82 6785.5 6826 First Reading For Entire File..........6785.5 Last Reading For Entire File...........6826 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0,0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type .........:......LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number..........,1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit r un in separate files. BZT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 6785.5 9384 .0 FET 6785.5 9384 .0 RPM 6785.5 9384 .0 RPX 6785.5 9384 .0 GR 6785.5 9377 .0 RPS 6785.5 9384 .0 ROP 6826.5 9435 .0 LOG HEADER DATA DATE LOGGED: 18-SEP-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9435.0 TOP LOG INTERVAL (FT) 6826.0 BOTTOM LOG INTERVAL (FT} 9435.0 BIT ROTATING SPEED (RPM): • • HOLE INCLINATION (DEG MINIMUM ANGLE: 75.0 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electroma g Resis. 4 73764 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6785.0 BOREHOLE CONDITIONS MUD TYPE: pil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 86.0 MUD PH: .0 MUD CHLORIDES (PPM): 52000 FLUID LOSS (C3) 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING T ERMPERATURE : .000 100.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefin ed Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefin ed Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6785.5 9435 8110.25 5300 6785.5 9435 RPD MWD110 OHMM 20.07 163.9 82.1963 5198 6785.5 9384 RPM MWD110 OHMM 18.68 226.54 80.018 5198 6785.5 9384 RPS MWD110 OHMM 18.15 2000 80.2476 5198 6785.5 9384 RPX MWD110 OHMM 7.08 2000 73.8535 5198 6785.5 9384 FET MWD110 HOUR 0.18 580.79 0.938969 5198 6785.5 9384 GR MWD110 API 48.31 115.45 75.2777 5184 6785.5 9377 ROP MWD110 FT/H 1.01 384.61 218.006 5218 6826.5 9435 First Reading For Entire File..........6785.5 Last Reading For Entire File...........9435 • • File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 06/01/25 Maximum Physical Record.. 65535 File Type ................ LO Next File Name........... STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/01/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/01/25 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