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207-017
Image Pect UVell Dist®ry File Cr Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - Q ~~ Well History File Identifier III II'l ll II III (~ I ~~~ ICI ~I~ II~II~ 0 ~ II Or anizing (done) 9- Two-Sided I ^ Rescan Needed RESCAN DIGIT L DATA OVERSIZED (Scannable) ~olor Items: iskettes, No. 1 ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: `~j ~~~ ~ /s/ Pro "ect Proogn I g I) I II'I ~I I I III I (III BY: Maria Date: J~ ~ /s/ ti P ~ x 30 = ~ + / ~~ =TOTAL PAGES on repara Scanning . ver s eK et (Count does not include co ) I BY: Maria ~ Date: \~ , ~. ~~ /s/ Production Scanning Stage 1 Page Count from Scanned File: _ ~~ (Count does include coffer sheet) n Matches Number in Scanni Preparation: V YES NO Page Cou t 9 BY: Maria Date: ~~ ~~.-. ~ ~ /s/ I ~ I/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 1 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I~I (I IIII III (I I~ III ReScanned BY: Maria Comments about this file: Date: Quality Checked iiiuuuiiiuu 10/6/2005 Well History File Cover Page.doc i ~ ~~ ~~ .~}~ ~~ ~~: ... :n ~~ _~ k ~ ~ "~' ~~ RAY ~ b > MICROFILMED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 02, 2009 12:42 PM To: 'NSK Prod Engr SpecialisY Subject: RE: 1J-160L2 (207-017) Darrell, I have reviewed the file and see what Eric wrote about. There was no penetration drilled out of the 9-5/8" casing that was set at 9150'. The "B" or L1 lateral exited the casing at -8750' and the "D" or L2 lateral exited the casing at ~8391. Based on the depths provided in the sundries I have, the L1 lateral was isolated as indicated by Eric. After further review, it may not be necessary to send in new 404s. I think it will be possible to make the corrections by hand. Please give me a call. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, July 02, 2009 8:04 AM c,, ,~~~ ~~~ ~ To: 'NSK Prod Engr Specialist' ~~ ~ ' .~ ~r ~Q~~ Subject: RE: iJ-160L2 (207-017) Darrell, Thanks for looking into this. When you send in the new 404s, please put a note somewhere that these documents are revised. Tom From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Thursday, July 02, 2009 6:21 AM To: Maunder, Thomas E (DOA) Subject: FW: 1J-160L2 (207-017) Tom- as you can see from below it looks like we filed the 404 for the wrong sand. You are not going nuts. I will correct the 404 for isolating the B sand and resubmit it. You should have it in the next couple of days. Darrell From: Hollar, Eric Andrew Sent: Wednesday, July 01, 2009 3:05 PM To: NSK Prod Engr Specialist Subject: RE: 1J-160L2 (207-017) Darrell, This well is a little unusual in that--according to the multilat drawing--it was drilled in the traditional tri-lateral way with a motherbore extending to the A sand. However, no lateral was completed in the A sand. I am going to assume that Tom's reference to the L2 matches a full tri-lateral (motherbore = A sand, L1 = B sand, L2 = D sand), even though this well isn't really a full tri-lateral well. The D sand (L2) isn't isolated in this well. A plug is set in a nipple at 8443' MD, which is below the D sand lateral junction. If we filed that the L2 was isolated, we should amend it. The B sand (L1) was isolated due to rapid water injection breakthrough. 7/2/2009 • ~ Page 2 of 2 Eric Hollar West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-265-6525 Cell 907-748-0181 From: NSK Prod Engr Specialist Sent: Wednesday, July 01, 2009 2:38 PM To: Hollar, Eric Andrew Subject: FW: 1J-160L2 (207-017) Eric, would you be able to provide some insight to Tom's question? thanks Darrell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 01, 2009 9:28 AM To: NSK Prod Engr Specialist Subject: 1J-160L2 (207-017) Bob and Darrell, I am revieyving the series of 404s submitted for this 1J-160L2 and the other segments reporting the isolation of 1J- 160L2. Do you have additional information as to why this lateral was isolated? I don't have any emails and did not find any new information in the well file. Thanks in advance. Tom Maunder, PE AOGCC 7/2/2009 - ~. .,,,, ~ ,r~-c~„ LA J • • ~~ 2 ~ ~~09 i , ~laska ~al c~ Gas ~'aa~~, ~' STATE OF ALASKA ~a~lnllssio~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~~~~}'~' REPORT OF SUNDRY WELL OPERATIONS iJ \~op ~,, t. operations PerFormed: Abandon ^ Repair Well ^ P~ug PerforaUons ~ Stimulate ^ Other ^~ Isolate Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time E~ension ^ '~' sand Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Deveiopment ^ Exploratory ^ 207-017 /~ 3. Address: Stratigraphic ^ Service Q' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-61 - 7. KB Elsvation (ft): 9. Wefl Name and Number: RKB 122' • 1 J-160L2 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25663~ Kuparuk River Field / West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 13067' • feet true vertical 3194' feet Plugs (measured) 8443' Effective Depth measured 13059 feet Junk (measured) true vertical 3194 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3428` 13-3/8" 3550' 219T INTERMEDIATE 9028' 9-5/8" 9150' 3343' WINDOW D-SAN 1' 9-5/8" 8392' 3224' D-SANDSLOTTE4456' 4-1/2" 1 3061' Perforation depth: MeasurerJ depth: 8668' - 13017' true vertical depth: 3239' - 3196' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8357' MD. Packers & SSSV (type & measured depth) PKR = SLZXP Liner top pkr PKR = 8324' SSSV= NIP SSSV= 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Sda~ ~~! ~~~ ~~ ~ 13. Representative Daily Average Prod uction or Injection ;J(J( ~ Oil-Bbl Gas-M~f Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1227 • 1221 957 Subsequent to operation 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~• Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ 0• WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. F~cempt: N/A contact Bob Christensen / Darrell Humphrey Printed Name Rob D. Christe sen Titie Production Engineering Technician Signature Phone 659-7535 Date ~/~~ ~ ~ ~? U K I~ I~~f H L ~-~'~ ~~~-,~~'/-~- Form 10-404 Revised 04/2004 Submit Ori ' • . 1J-160L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary PERFORM FINAL RUN FOR IPROF IN B-LAT TO 12151 CTMD, SET 3.562 CS LOCK & PRONG IN DB-NIPPLE @ 8443 RKB. WELL IS FREEZE PROTECTED & SHUTIN. . . . ~ KUP 1J -160L2 ConocoPhillips Well Attribut es Max An le & MD TD , :~.~,..,~.~ I, . Welibore APIIUWI Fleltl Nema 500292334461 WEST SAK Well Status INJECTING Incl (°) 94.72 MO (RKB) 8,599.48 Act 8Im ~fiK9~ 13,067.0 wen con : Mun b libnN ~ IJ4fi012 &1 U/1W3 6Od 01 PM Comment SSSV: NIPPLE H25 (ppm) Dele Mnatatlon last WO: End Dete NB-0rtl (tt) 43.01 Rlp Releasa Dat 4/10/2007 m~~. i Mnotation DapN ~fIKB) Entl D~b Mnotation ~a~t Motl By Entl ~ata . Last Tag Rev Reason: Set CS LocWProng Imosbor 6l10Y2009 ,,,,~Q,6~ " ~~ Casin Strin s rop oapm CONDUCTOR. ~TVD) 7opInG1 ~~~Z~ Top~/tl(8) IRKe) ~°) ~psmOescrlptlon Commant niPP~E, sos i~ 8,662.3 3,2382 90.65 XO S.Sx4.5 5 1Y2" Hydril 521 Pia X 4 1/2" BTC Pin X/O (3.96" I.D.) cns uFr. Perforations 8 Slots z,zao sno~ Top (TVD) Blm ~TVD) Dens Top~ftKB) BUn(RNB) ~RKB) (RKB) Zone Date (°h~~~ T pe C 8,668 9,131 3,238.1 3,233.0 WS D, WS B, 4l4/2007 32.0 SLOTS Altemating solic SURFACE, 58-3 557 ~~-~COLZ ?.S~X.~ZS° SIOCS , 9,373 9,897 3,243.2 3,247.6 WS C, WS D, 4/4/2007 32.0 SLOTS Altemating solic 1J-160L2 2.5'x.125" slots SLEEVE~O, e,asi ~p ~d5 in aea ~~~a n ~~no n ws n i i.~ani ~ eiennm ~~ n ~i nr~ ~ ~ ~i~P~~,ar~,,,, ~„r~ s~ors. io,sa-i~.an SLOTS,~ . ~op~eV~n iep ~~,5~~.~z,~35 (TVD) Incl OD Valw LaOC~ Stn Too1RNB1 ~RKB) ~~) Make MoEel (~~) Serv Typa Typs ~~ V l~J~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,~;, C~~r ~; JUN 1 9 20G9 ~asica Oil ~ ~ Cons. ~orrurlissic~r No. 5284 Anch®ra~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 06/17/09 1 B-19 ANHY-00091 PRODUCTION PROFILE t- < 05/27/09 1 1 3K-16 ANHY-00094 GLS J 05/29/09 1 1 3G-10 B04C-00058 INJECTION PROFILE L( 05/31/09 1 1 1J-160 62WY-00006 MEMORY INJECTION PROFILE ~ - - 05/31/09 1 1 iJ-164 B2WY-00009 MEMORY INJECTION PROFILE 06/01/09 1 1 iJ-160L2 AXBD-00028 MEMORY INJECTION PROFILED 06/07/09 1 1 1 A-04A 604C-00040 RST ~ C 05/05/09 1 1 3M-03A AZJZ-00011 CH EDIT SFRT ~ 01/11/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1"L p,M DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070170 Well Name/No. KUPARUK RIV U WSAK 1J-160L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23344-61-00 MD 13067 TVD 3194 Completion Date 4/9/2007 Completion Status 1WINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION c/ Mud Log No Samples No Directional Survey ___ DATA INFORMATION Types Electric or Other Logs Run: GR/Res, USIT Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D. Asc I Directional Survey 'icE~ C Lis i 15188 induction/Resistivity ', Rp t 15188 LIS Verification / IEb C 17994 ~ o es . t ,, Mpg Induction/Resistivity „~og _. Induction/Resistivity __ __ Well Cores/Sampl es Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? 471 Analysis Y / N Received? (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH 1 Scale Media No Start Stop CH Received Comments 8340 13064 Open 5/8/2007 ~! 3525 13067 Open 6/12/2007 LIS Veri, GR, NPHI, NCNT, DRHO, RHOB, ROP w/Graphics ~~ 3525 13067 Open 6/12/2007 LIS Veri, GR, NPHI, NCNT, DRHO, RHOS, ROP 0 0 5/5/2009 EWR Logs in EMF, CGM and PDS graphics o (aim 25 Col 121 13067 ,rash 5/5/2009 MD ROP, EWR, DGR 25 Col 121 3193 use 5/5/2009 TVD EWR, DGR Sample Set Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~ N • DATA SUBMITTAL COMPLIANCE REPORT 517/2009 Permit to Drill 2070170 Well Name/No. KUPARUK RIV U WSAK 1J-160L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23344-61-00 MD 13067 ND 3194 Completion Date 4/9/2007 Completion Status 1WINJ Current Status 1WINJ UIC Y Comments: __ __ __ _- ___ __ ___ Compliance Reviewed By: Dater ~- • ~ i WLLL LDS T1~SM~T'J'A~, T®: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: M WD Formation Evaluation Logs: 1 J-160+L 1 +L 1 PB 1 +L2 Apri129, 2009 AK-MW-4877337 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 flJ-160+L1+L1PB1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 344-00,60,61,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 344-00,60,61,70 Digital Log Images 4 CD Rom 50-029-23344-00,60,61,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling ~ Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burnda@halliburton.com Date.. Signed: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 u ,ie ate- -v < ~ I`~-~; t ~~g~a ~~4~~ -1`'~~ ~~ L,/A i IvIJ • uviv4a~lvu vaa ai a ac.9 ~.iu~ av ~....~ ~ :.. ... ~ ~.. ~-.. .. Maunder, Thomas E (DOA) __ From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 - __0 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPFl Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, iJ-102, 1J-127, 1J-164, 1J-180 Tom ;Jim, The LPP/SSV's on all of the West Salc DS1 E and DS1J wells are now bac{c in service as their wellhead injection pressures have increased to above 500 psi. The 'rollowing wells had been defeated; permit to drill numbers are also listed. 1 ~n~asn't sure if yo! i +rranted the permit to drill number for the mainbore only or the laterals as well so included both. WELL ID Permit to Drill No. 1E-112 7_04-091 (MAINBORE), 204-092 (L1), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1}, 206-'112 (L2) 1J-105 207-027 (MAiNBORE), 207-028 (L1 ), 207-029 (L2) 1J-'127 206-047 (MAINBORE), 206-048 (L1 ), 206-049 (L2} ~---~ 1J-160 207-015 (MAii~1BORE}, 207-016 (L1), 207-0"17 (L2) 1J-164 205-144 (MAINBORE), 205-145 (L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-'151 (L1) Note: 1 J-105 and 1 J-160 were defeated in early July 2007, before the CPF"I ESQ, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Flai Hunt /Pete Nezaticky !Eric Hollar NSK Nlest Sa!< Production Engineer ConocoPhillips Alaska, lnc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com ~ ~E~EwED STATE OF ALASKA ~U~ Q ~ ZOO7 ALASKA OIL AND GAS CONSERVATION COMMISSION 8Sk8 OiI & Gas COILS. Cammissiott REPORT OF SUNDRY WELL OPERATION ft-.-L--_e_ 1. Operations Performed: .Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ Prod to WINJ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name:. 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, lnc. Development ~ Expbratory ^ 207-017 / - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-61 7. KB Elevation (ft): 9. WeII Name and Number: RKB 122' G 1J-160L2 8. Property Designation: 10. Field/Pool(s): ,~_n Kuparuk River Unit ~~~ ~s~IW j ZSl~(i?l~~, ~$ ~7 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13067 feet _ true vertical 3194' feet Pitags (measured) Effective Depth measured 13059 - feet Junk,(measured) true vertical 3194 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR " 120' 20" 120' 120' SURFACE 3428' 13-3/8" 3550' ' 219'f' INTERMEDIATE 9028' 9-518" 9150' - 3343' . WINDOW D-SAN 1' 9-5/8" 8392' ' 3224' D-SANDSLOTTE4456' 4-1/2" 13061' Perforation depth: Measured depth: 8668' - 13017 true vertical depth: 3239' - 3196' Tubing (size, grade, and measured depth) 4-112" , L-80, 8357 MD. Packers &SSSV (type & measured depth) PKR = SLZXP Liner top pkr PKR = 8324' .SSSV= NIP SSSV= 506' 12. Stimulation or cement squeeze. summary: Intervals treated (meastired) ~~ Jul. `~ ~ Zfl~~ Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl ~ Casiri Pressure Tubin Pressure Prior to well operation 702 100 23 1011 207 Subsequent to operation 327 1339 932 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ - Development ^ Service^ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o: Exempt: 307-185 contact Bob Christensen /Bob Buchholz Printed Name ob D. Chri ensen Title Production Engineering Technician Signature Phone 659-7535 Date ~ yc~ Form 10-404 Revised 04/2004 ~ R ~ ~' 1 ~ A ~ ~/~~17 Submit a On~~~1 1J-160L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/01/07 Commenced Water Injection Service 1_ J `FELL L®G TRA~S~IgTTAI. ~~ U 'I'o: Chevron Jung 1, Z00 7 Attn.: Tim E. Rodriguez P.O. Box 196247 Anchorage, Alaska 99519 RE: MV~~ Formation Evaluation Logs 1J-160 L2 AK-MW-4877337 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23344-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNIl~'G AiVD RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anc~hor,~~ka; 9~5~~$ ,~ Date: Signed: ~ZC, ~o~-old ~ I Sl~~ SARAH PALIN, GOVERNOR O~ ~ ~ 333 W. 7th AVENUE, SUITE 100 C011tSERQA~`I011T COMl~'I158IO1~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-160L2 Sundry Number: 307-185 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of June, 2007 Encl. fiincPrPly - - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 i DECEIVED ,~~ 1 !lJN 0 5 2007 Alaska ~aii & Gas Cons. Commissiol ~nchoraae 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time f=xtension ^ Chan e a roved ro ram g pp P g ^ Pull Tubing ^ Perforate New Pool ^ Producer to _ Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 207-017 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-61 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q 1J-160L2 9. Property Designation: ,~ bt- 2~/v(PL~ 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit ~ D t- ZSL(p "3 ~ ~ ~- /e'~ RKB 122' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13067 - 3194' 13059' 3194' Casing Length Size MD TiID Burst Collapse CONDUCTOR 120' 20" 120' 120' SURFACE 3428' 13-3/8" .3550' 2191' INTERMEDIATE 9028' 9-5/8" 9150' 3343' WINDOW D-SAND 1' 9-5/8" 8392' 3224' D-SAND SLOTTED LINER 4456' 4-1/2" 13061' 3194' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8668' -13017' 3239' - 3196' 4-1 /2" L-80 8357' Packers and SSSV Type: Packers and SSSV MD (ft) PKR = SLZXP Liner top pkr PKR = 8324' SSSV= NIP SSSV= 506' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 20, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert D. Christensen Title: Production Engineering Technician Signature Phone 659-7535 Date C~ Commission Use Onl Conditions of a roval: Notif Commission so that a re resentative ma witness Sundry Number: ~ pp y p y . , Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: t~ `.~ ~K.~~ d ~e~~~\®~ ~/~ ~9.C ~~ ~' ~ ~ ~ ~` ~ Subsequent Form Required: ~®~ ~5 IDF~ JAN 0 S 2(]0~ APPROVED BY )~/%.O Approved by: OMMISSIONER THE COMMISSION - Date: o Form 10-403 Revised 06/200 ~ ~ r~ ~~- Submit in~Duplicate • • 1J-160L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-160L2. This well has been pre-produced for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1J-160L2 will provide pressure support for the West Sak D sands. The 13-3/8" Surface casing (3551' and / 2190' tvd) was cemented with 667 sx Class 'G'. The 9• 5/8" Intermediate casing (9150' and / 3340' tvd) was cemented with 735 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand SLZXP 7" x 9- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 8324' and / 3212' tvd, Upper B sand HRD ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 8519' and / 3247' tvd. The top of West Sak D sand was found at 8387' and / 3223' tvd. D sand Lateral window top is located @ 8391' and / 3224' tvd. The top of West Sak B sand was found at 8767' and / 3289' tvd. B sand Lateral window top is located @ 8750' and / 3286' tvd. The top of West Sak A sand was found at 10241' and / 3454' tvd. • ConocoPhillips June 1, 2007 C~ Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907}659-7535 Fax: 659-7314 IREDEIVED Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7t" Ave. Ste. 100 Anchorage, AK 99501 JUN d 5 2007 Alaska Qil & bas Cons. Commission Anchorage Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk West Sak wells 1J-160 (PTD 207-015), 1J-160L1 (PTD 207-016), and 1J-160L2 (PTD 207-017) from Oil Production to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 1J-160, 1J-160L1, and 1J-160L2. If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, Robert D. Christensen Attachments • TUBING (0-8357, OD:4.500, ID:3.958) LOCATOR (8342-8343, OD:5.200) XO (8345-8347, OD:7.670) XO Bushing (8366-8368, OD:6.000) PUP (a3sa63n, OD:5.210) HANGER (8413-8414, OD:8.530) NIP 1443-8444, OD:5.210) ConocoPhillips Alaska, Inc. KRU 1 J-160L2 1J-160L2 API: 500292334461 Well T e: SVC An le TS: d SSSV T e: NIPPLE Ori Com letion: 4/10/2007 An le TD: 92 d 13067 Annular Fluid: Last W/O: Rev Reason: GLV C/O Ref e rence L 40' RKB Ref L Date: Last U date: 4/26/2007 _ _ Last Ta TD: 13067 ftK6 Last Ta Date: Max Hde An le: 95 d 8599 Casin Strin -ALL S TRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR - - _ 2 0.00 0 -- 0 120 120 94.00 H-40 WELDED SURFACE _ _ _ 13.375 0 3550 2191 68.00 L-80 BTC INTERMEDIATE _ 9.625 0 9150 3233 40.00 L-_80 _ _BT__C__ M _ WINDOW D-SAND 9.625 8391 8392 3224 0.00 _ D-SAND SLOTTED LINER 4.500 8605 13061 3194 11.60 L-80 BTC Tubing Strin -TUBI NG - - __ Size _ Top Bottom _ T_VD - Wt Grade _ __Thread__ __ _ 4.500 0 8357 3218 12.60 L-80 IBTM Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 8668 - 9131 3239 - 3233 WS D,WS B 463 32 4/4/2007 SLOTS Alternating slid/slotted pipe, 2.5"x.125" slots 9373 - 9897 3243 - 3243 WS C,WS D 524 32 4/4/2007 SLOTS Alternating slid/slotted pipe, 2.5"x.125" slots 10145 - 10646 3226 - 3209 W S D 501 32 4/4/2007 SLOTS Alternating sdid/slotted pipe, 2.5"x.125" slots 10904 - 11377 3211 - 3207 WS D 473 32 4/4/2007 SLOTS Alternating sdid/slotted pipe, 2.5"x.125" slots 11671 - 12135 3211 - 3211 WS D 464 32 4/4/2007 SLOTS Alternating sdid/slotted pipe, 2.5"x.125" slots 12390 - 13017 3203 - 3196 WS D 627 32 4/4/2007 SLOTS Alternating sdid/slotted pipe, 2.5"x.125" slots Gas Lift MandrelsNal St MD TVD Man Mfr 1 2280 1859 CAMCO ves Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv _ _ Cmnt KBMG GLV 1.0 BK-5 0.188 1415 4/25/2007 Other lu s, a ui ., etc. -COMPLETION Depth TVD Type Description ID 36 36 HANGER __ VETCO GRAY TUBING HANGER 4.500 506 504 NIP CAMCO DB-6 NIPPLE w/NO GO PROFILE 3.875 8290 3206 SLEEVE-O BAKER CMD SLIDING SLEEVE w/OPEN PROFILE 3.812 8342 3215 LOCATOR BAKER LOCATOR 3.940 8343 3216 SEAL BAKER SEAL ASSEMBLY PBR/SBR 3.880 8357 3218 SHOE __ 3.958 Other lu s, a ui ., etc. -LINER DETAIL Depth TVD T e Description ID 8324 3212 PACKER _ D-SAND SLZXP LINER TOP PACKER 7.500 8345 3216 XO D-SAND LEM CROSSOVER 7" x 5.5" 4.920 8347 3216 CSG SBR D-SAND LEM 190-47 CASING SEAL BORE RECEPTACLE 4.750 8366 3220 XO Bushin D-SAND CROSSOVER BUSHING 3.940 8368 3220 PUP 3.958 8377 3221 HANGER D-SAND LEM ABOVE HOOK HANGER 3.960 8391 3224 HANGER D-SAND BAKER MODEL'B' LEM HOOK HANGER INSIDE CSG 7.470 8413 3228 HANGER D-SAND BAKER MODEL 'B' LEM HOOK HANGER OUTSIDE CSG 7.470 8443 3232 NIP D-SAND CAMCO 'DB-6' NIPPLE 3.563 8559 3241 PACKER D-SAND BAKER PAYZONE EXTERNAL CASING PACKER 3.900 8559 3241 SEAL D-SAND BAKER SEAL ASSEMBLY 3.880 8605 3242 SLEEVE D-SAND BAKER'HR' LINER SETTING SLEEVE 5.750 8656 3240 SHOE D-SAND FULL MULE SHOE 3.958 General Not es Date Note 4/10/2007 _ NOTE: MULTILAT W ELL - 1J-160 NO PERFS , 1J-160L1 B-SAND , 1J-160L2 D-SAND ~- ~:.J ~'~ :-~ _ `IL ~~ . ~~ -~~-- _ Packer ~ ~'v~, Sew at _o~~ S~~e and ~~_~s ~o r:::u~~s ?_ess Test: _~ ; 'J LJ.11-1 :;0 min Ca~ents . '~'CI'~FNIC~~, INTEGRI-rY _ PST #2 ~~~~;~~ ' gy~S4jh,cS . Cement Voltmmes: Amt. Liner ~~ ; Csg ~~~5~ DV Q~1.t~ cc ~~ C.uc 'sot to cover oer=s ~~ b~\s ~~4'~c:~Ea~~ ~ CG~~~ ~~ Wit~t~`ii'oJ''~SC'~.,' ~U>c~, - ='eoretical :.OC ~ jai=~Q,k~ ~.y~~~ ~~.'~:~~.~~ ~~~ ~~~~~~ Cement Bond Log (Yes or Nc) ~~~ In AOGCC File L~5 CBL Evaluation, gone aoove o_ errs ~,0.1.~er~~s s~~~c c~~~- ~~~>~; Producti an Log: Tpve CCNGLJSICt1S Part #l: ~ci ~ TL: Evaluation ~~v~o • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~,r~'`( 1 4 2007 WELL COMPLETION OR RECOMPLETION REPORT • 'on 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ~ • WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. V1/ I ass:" Anehrf~1rf Development ^ Ek~ratory ^ Service ~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., S ~ p orAband.: April , 2007 12. Permit to Drill Number: 207-017 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~~pp March~007 Cri~'~'l 13. API Number: 50-029-23344-61 4a. Location of Well (Governmental Section): Surface: 2016' FSL, 2541' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: April 3, 2007 14. Well Name and Number: 1J-160L2 Top of Productive Horizon: 762' FSL, 1778' FWL, Sec. 34, T11 N, R10E, UM 8. KB (ft above MSL): 122.5' AMSL Ground (ft MSL): 81' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1403' FSL, 1788' FWL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 13059' MD / 3194' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558668.6 y- 5945827.5 Zone- 4 10. Total Depth (MD + ND): 13067' MD / 3194' TVD 16. Property Designatign: ALK 25660, 25661, 25663 • TPI: x- 552439 y- 5944527 Zone- 4 Total Depth: x- 552490 ~ - 5939890. Zone- 4 11. SSSV Depth (MD + ND): nipple @ 505' ND / 498' TVD 17. Land Use Permit: 470, 472 18. Directional Survey: Yes ^~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 2183' TVD ` 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ?^ Lt3 ~' ~ im~i 3 ZZ~ ~~ GR/RES, USIT ~ D ,r,Zg.o7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 40' 120' 40' 120' 42" 365 sx AS 1 13.375" 68# L-80 40' 3551' 40' 2190' 16" 513 sx Class G, 106 sx Class G, 48 sx Class G 9.625" 40# L-80 40' 9150' 40' 3340' 12.25" 735 sx DeepCRETE 4.5" 11.6# L-80 8605' 13061' 3242' 3193' 6.75" slotted/blank liner 23. Open to production or injection? Yes 0 No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE ~- DEPTH SET (MD) PACKER SET tubing in L1 lateral 8357' 8324', 8559' alternating slotted liner from: 8668'-9131' MD 3240'-3233' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9373'-9897' MD 3243'-3241' ND DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10145'-10646' MD 3226'-3209' TVD na 10904'-11377' MD 3211'-3207' ND 11671'-12135' MD 3211'-3210' ND 12390'-13017' MD 3203'-3195' ND 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) pre-producing injector -shares injection with 1J-160L1 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No Q • Sidewall Cores Acquired? Yes ^ No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. s NONE ~ ~ 9.07 ~'i , - Form 10-407 Revised 2/2007 ~ ~ CONTINUED ON REVERS S ~F~ MAY ~ ~ 2047 ~~ ~,~, 07 7 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3519' 2183' ~ needed, and submit detailed test information per 20 AAC 25.071. T3 3519' 2183' K15 3519' 2183' Ugnu C 5973' 2709' Ugnu B 6742' 2873' Ugnu A 6924' 2913' K13 7622' 3067 West Sak D 8387' 3223' N/A Formation at total depth: West Sak 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nam Rand homa Title: Drillino Team Leader , S Ala to 7 ~ Signature e ~ S (, ~ 30 Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report ___ Company: ConocoPhillips Alaska Inc. Date: 4!2612007 1'imr: 15:3:46 Pays: I Field: Kuparuk River Unit Co -ordin:~te(NE)Reference: Well: 1J-160, Tr ue North Site: Kuparuk 1J Pad Ve rtical ("1'VD) Re ference: 1J-t60L2: 122.3 Wrll: 1J-160 Section (VS) References Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-160L2 Sun°ey Calculation Method: Minimum Curvat ure Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States ~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Coordinate System: Well Centre Geomagnetic Model: bggm2006 i I Well: 1 J-160 Slot Name: Well Position: +N/-S -91.18 ft Northing: 5945827.52 ft Latitude: 70 15 45.361 N +E/-W -122.08 ft Easti ng : 55866 8.60 ft Longitude: 149 31 32.559 W Position Uncertainty: 0.00 ft - Wellpath: 1J-160L2 - --- Drilled From: 1J-160 ! 5002923344661 Tie-on Depth: 8340.39 ft Current Datum: 1J-160L2: Height 122.29 ft Above System Datum: Mean Sea Level Magnetic Data: 2/27/2007 Declination: 23.61 deg Field Strength: 57619 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.29 0.00 0.00 180.00 __ II Survey rro ramg for Definitive Wellpath Date: 4/26!2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 100.00 600.00 1J-160 gyro (100.00-600.00) (0 CB-GYRO-SS Camera based gyro single shot 666.10 8340.39 1J-160 (666.10-10241.22) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8391.00 13029.15 1J-160L2 (8391.00-13029.15) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC _ _ 1 Survey titD - Inc! Arim TVD> SysTVD K/S E/N' MapiY ~fapE 'Pool ft deg deg ft ft ft ft ft ft 41.29 0.00 0.00 41.29 -81.00 0.00 0.00 5945827.52 558668.60 TIE LINE ~ 100.00 0.15 293.36 100.00 -22.29 0.03 -0.07 5945827.55 558668.53 CB-GYRO-SS 200.00 0.59 243.72 200.00 77.71 -0.15 -0.65 5945827.37 558667.95 CB-GYRO-SS 300.00 3.54 277.00 299.92 177.63 0.00 -4.18 5945827.49 558664.42 CB-GYRO-SS 400.00 6.99 280.33 399.49 277.20 1.47 -13.23 5945828.89 558655.36 CB-GYRO-SS I 500.00 10.60 279.01 498.29 376.00 4.00 -28.31 5945831.30 558640.26 CB-GYRO-SS ~ 600.00 12.77 273.73 596.22 473.93 6.16 -48.42 5945833.30 558620.14 CB-GYRO-SS 666.10 15.31 273.65 660.34 538.05 7.19 -64.42 5945834.21 558604.13 MWD+IFR-AK-CAZ-SC 761.80 19.50 270.99 751.64 629.35 8.27 -93.02 5945835.07 558575.53 MWD+IFR-AK-CAZ-SC 856.80 21.31 271.11 840.67 718.38 8.88 -126.13 5945835.42 558542.41 MWD+IFR-AK-CAZ-SC 951.55 22.79 271.51 928.49 806.20 9.70 -161.69 5945835.96 558506.85 MWD+IFR-AK-CAZ-SC 1046.43 26.48 271,02 1014.72 892.43 10.56 -201.22 5945836.51 558467.32 MWD+IFR-AK-CAZ-SC 1140.73 28.46 269.82 1098.39 976.10 10.86 -244.72 5945836.48 558423.83 MWD+IFR-AK-CAZ-SC 1236.43 30.07 270.84 1181.87 1059.58 11.14 -291.50 5945836.39 558377.05 MWD+IFR-AK-CAZ-SC !, 1331.29 34.01 271.18 1262.26 1139.97 12.04 -341.80 5945836.90 558326.75 MWD+IFR-AK-CAZ-SC 1427.82 38.94 273.79 1339.87 1217.58 14.60 -399.10 5945839.01 558269.43 MWD+IFR-AK-CAZ-SC 1522.70 40.38 275.76 1412.91 1290.62 19.66 -459.44 5945843.60 558209.07 MWD+IFR-AK-CAZ-SC 1616.58 42.50 273.46 1483.29 1361.00 24.63 -521.36 5945848.08 558147.11 MWD+IFR-AK-CAZ-SC 1712.58 43.81 274.04 1553.32 1431.03 28.92 -586.88 5945851.87 558081.57 MWD+IFR-AK-CAZ-SC 1807.77 49.26 274.61 1618.78 1496.49 34.15 -655.74 5945856.55 558012.67 MWD+IFR-AK-CAZ-SC i 1903.13 51.56 271.96 1679.55 1557.26 38.33 -729.09 5945860.16 557939.30 MWD+IFR-AK-CAZ-SC 1996.53 56.44 269.59 1734.44 1612.15 39.30 -804.62 5945860.55 557863.78 MWD+IFR-AK-CAZ-SC 2093.62 61.82 270.96 1784.24 1661.95 39.73 -887.92 5945860.33 557780.49 MWD+IFR-AK-CAZ-SC 2187.20 66.18 272.62 1825.25 1702.96 42.38 -971.96 5945862.32 557696.43 MWD+IFR-AK-CAZ-SC 2282.89 70.74 274.59 1860.38 1738.09 48.00 -1060.76 5945867.25 557607.60 MWD+IFR-AK-CAZ-SC 2378.18 73.48 273.77 1889.65 1767.36 54.60 -1151.19 5945873.15 557517.13 MWD+IFR-AK-CAZ-SC 2473.19 76.25 274.34 1914.45 1792.16 61.09 -1242.67 5945878.92 557425.61 MWD+IFR-AK-CAZ-SC i 2569.11 75.19 274.37 1938.11 1815.82 68.15 -1335.36 5945885.26 557332.88 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/2612007 ' t'ime: 15:33:46 Page: 2 Field:- Ku paruk River Uni t Co-ordinate(NE)Reference: Well: 1J-160; Tru e Nofth Site: Ku paruk 1J Pad Verti cal (TVD) Re ference: 1J-160L2: 1 22.3 R'ell: 1J -160 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAZi) ~Vellpath; 1J-16012 Survey Calculation \7ethod: Minimum C urvat ure' Dhr Oracle ___ Sunny ~fD Incl Azim TVD Sys TVD N/S F./~V MapN MapE Tool ft deg-_ deg ft ft ft ft ft ft 2664. 24 76.14 275 .44 1961. 67 1839. 38 76. 03 -1427.18 5945892. 42 557241. 00 MWD+IFR-AK-CAZ-SC i 2758. 57 75.86 274 .88 1984. 49 1862. 20 84. 26 -1518.34 5945899. 94 557149. 80 MWD+IFR-AK-CAZ-SC 2851. 96 74.81 273 .90 2008. 13 1885 .84 91. 18 -1608.42 5945906. 16 557059. 67 MWD+IFR-AK-CAZ-SC 2948. 15 75.36 275 .64 2032. 89 1910 .60 98. 91 -1701.04 5945913. 17 556967. 00 MWD+IFR-AK-CAZ-SC 3044. 30 75.45 275. 64 2057. 12 1934. 83 108. 06 -1793.64 5945921. 59 556874. 35 MWD+IFR-AK-CAZ-SC 3139. 49 70.69 275. 49 2084. 83 1962. 54 116. 89 -1884.25 5945929. 71 556783. 68 MWD+IFR-AK-CAZ-SC 3208. 76 73.20 274. 22 2106. 30 1984. 01 122. 45 -1949.86 5945934. 77 556718. 03 MWD+IFR-AK-CAZ-SC 3232. 39 74.16 273 .99 2112. 94 1990. 65 124. 08 -1972.48 5945936. 21 556695. 40 MWD+IFR-AK-CAZ-SC ~ 3327. 00 76.38 273 .00 2136. 99 2014 .70 129. 65 -2063.81 5945941. 07 556604. 04 MWD+IFR-AK-CAZ-SC ~ 3422. 91 77.13 270 .67 2158. 97 2036. 68 132. 64 -2157.11 5945943. 33 556510. 73 MWD+IFR-AK-CAZ-SC 3505. 57 74.33 271 .00 2179. 34 2057. 05 133. 80 -2237.20 5945943. 88 556430. 64 MWD+IFR-AK-CAZ-SC 3585. 63 76.30 269 .24 2199. 64 2077 .35 133. 96 -2314.64 5945943. 43 556353. 21 MWD+IFR-AK-CAZ-SC 3682. 35 78.55 269 .66 2220. 70 2098 .41 133. 05 -2409.03 5945941. 79 556258. 84 MWD+IFR-AK-CAZ-SC 3775. 98 79.30 270 .21 2238. 68 2116 .39 132. 95 -2500.92 5945940. 97 556166. 96 MWD+IFR-AK-CAZ-SC 3871. 49 77.27 268 .63 2258. 07 2135 .78 132. 01 -2594.42 5945939. 30 556073. 48 MWD+IFR-AK-CAZ-SC 3966. 38 76.90 270 .39 2279. 28 2156. 99 131. 22 -2686.91 5945937. 79 555981. 01 MWD+IFR-AK-CAZ-SC 4061. 25 77.27 270 .60 2300. 49 2178 .20 132. 02 -2779.37 5945937. 87 555888. 55 MWD+IFR-AK-CAZ-SC 4156. 45 78.17 272 .30 2320. 74 2198 .45 134. 37 -2872.36 5945939. 50 555795. 56 MWD+IFR-AK-CAZ-SC 4252. 44 78.17 271 .32 2340. 42 2218 .13 137. 34 -2966.26 5945941. 73 555701. 64 MWD+IFR-AK-CAZ-SC ~ 4346. 85 78.17 271 .73 2359. 77 2237 .48 139. 80 -3058.63 5945943. 47 555609. 26 MWD+IFR-AK-CAZ-SC 4440. 64 77.21 270 .93 2379. 77 2257 .48 141. 93 -3150.24 5945944. 89 555517. 65 MWD+IFR-AK-CAZ-SC 4536. 81 76.27 271 .04 2401. 83 2279 .54 143. 54 -3243.83 5945945. 77 555424. 06 MWD+IFR-AK-CAZ-SC 4632. 22 77.79 271 .66 2423. 24 2300 .95 145. 73 -3336.78 5945947. 23 555331. 11 MWD+IFR-AK-CAZ-SC 4726. 71 77.53 272 .00 2443. 43 2321 .14 148. 68 -3429.04 5945949. 46 555238. 84 MWD+IFR-AK-CAZ-SC 4821. 96 76.83 273 .07 2464. 57 2342 .28 152. 78 -3521.82 5945952. 84 555146. 03 MWD+IFR-AK-CAZ-SC ~ 4916. 93 78.61 274 .80 2484. 77 2362 .48 159. 15 -3614.39 5945958. 49 555053. 43 MWD+IFR-AK-CAZ-SC ~ 5011. 45 78.41 274 .77 2503. 60 2381 .31 166. 88 -3706.69 5945965. 50 554961. 07 MWD+IFR-AK-CAZ-SC 5106. 28 77.10 275 .39 2523. 71 2401 .42 175. 09 -3799.00 5945972. 99 554868. 72 MWD+IFR-AK-CAZ-SC 5202. 19 78.22 275 .38 2544. 21 2421 .92 183. 88 -3892.28 5945981. 05 554775. 38 MWD+IFR-AK-CAZ-SC 5296. 10 78.29 274 .82 2563. 32 2441 .03 192. 05 -3983.86 5945988. 51 554683. 75 MWD+IFR-AK-CAZ-SC 5388. 25 77.28 274 .64 2582. 82 2460 .53 199. 48 -4073.62 5945995. 24 554593. 95 MWD+IFR-AK-CAZ-SC 5485. 00 77.47 274 .47 2603. 97 2481 .68 206. 98 -4167.73 5946002. 00 554499. 79 MWD+IFR-AK-CAZ-SC j 5583. 88 77.34 273 .88 2625. 53 2503 .24 214. 00 -4263.97 5946008. 27 554403. 50 MWD+IFR-AK-CAZ-SC i 5678. 36 77.98 273 .66 2645. 72 2523 .43 220. 07 -4356.07 5946013. 62 554311. 37 MWD+IFR-AK-CAZ-SC 5777. 05 78.04 269 .67 2666. 23 2543 .94 222. 87 -4452.54 5946015. 68 554214. 88 MWD+IFR-AK-CAZ-SC ~ I 5868. 89 77.16 266 .73 2685. 95 2563 .66 220. 06 -4542.19 5946012. 16 554125. 27 MWD+IFR-AK-CAZ-SC 5963 .84 77.66 265 .63 2706. 65 2584 .36 213. 89 -4634.64 5946005. 27 554032. 88 MWD+IFR-AK-CAZ-SC 6059. 13 77.55 263 .42 2727. 11 2604 .82 205. 01 -4727.28 5945995. 67 553940. 32 MWD+IFR-AK-CAZ-SC 6154. 34 77.86 262 .17 2747. 38 2625 .09 193. 34 -4819.57 5945983. 29 553848. 13 MWD+IFR-AK-CAZ-SC 6249. 56 77.92 260 .43 2767. 36 2645 .07 179. 26 -4911.60 5945968. 49 553756. 23 MWD+IFR-AK-CAZ-SC j 6344. 64 77.66 256 .98 2787. 47 2665 .18 161. 06 -5002.71 5945949. 58 553665. 27 MWD+IFR-AK-CAZ-SC 6439. 37 77.83 253 .45 2807. 59 2685 .30 137. 44 -5092.20 5945925. 27 553575. 97 MWD+IFR-AK-CAZ-SC 6534. 39 77.79 248 .57 2827. 66 2705 .37 107. 23 -5180.00 5945894. 38 553488. 42 MWD+IFR-AK-CAZ-SC 6630 .46 77.47 244 .65 2848. 25 2725 .96 69. 98 -5266.11 5945856. 47 553402. 61 MWD+IFR-AK-CAZ-SC 6725 .46 77.34 241 .24 2868. 97 2746 .68 27. 82 -5348.66 5945813. 67 553320. 40 MWD+IFR-AK-CAZ-SC 6819 .15 77.27 238 .32 2889. 57 2767 .28 -18. 18 -5427.63 5945767. 06 553241. 80 MWD+IFR-AK-CAZ-SC 6914 .80 76.77 235 .22 2911. 06 2788 .77 -69. 24 -5505.59 5945715 .39 553164. 25 MWD+IFR-AK-CAZ-SC ~ 7010 91 77 79 233 52 2932 22 2809 93 -123. 86 -5581.78 5945660 .19 553088. 49 MWD+IFR-AK-CAZ-SC . 7105. 85 . 76.88 231 . .23 . 2953. 04 2830 . .75 -180. 40 -5655.14 5945603. 08 553015. 58 MWD+IFR-AK-CAZ-SC 7201. 03 76.96 228 .08 2974. 58 2852 .29 -240. 41 -5725.79 5945542. 53 552945. 40 MWD+IFR-AK-CAZ-SC ~i 7295. 69 77.80 223 .74 2995. 27 2872 .98 -304. 67 -5792.12 5945477. 76 552879. 59 MWD+IFR-AK-CAZ-SC 7391 .01 77.53 220 .85 3015. 64 2893 .35 -373. 54 -5854.78 5945408. 41 552817. 47 MWD+fFR-AK-CAZ-SC - -- __ ! ~ Halliburton Company Survey Report __ - __ Company: ConocoPhillips Alaska inc. Date: 4/2612007. Time: 15:33:46 Pa€e: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-160', True North Site: Ku{~aruk 1J Pad Vertical (TVD)Rcfcrcnce: 1J-160L2: 122.3 «'ell: 1 J-160 Section (VS) Reference: Wekl (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-160L2 Survey Calculation Dlethod: MinimumCurvature Db: Oracle Sw~~ey MD Incl lzim TVD Sys TVD V/S E/V1' MapN 11apE Tool ft deg deg ft ft ft ft ft ft 7485.86 77.16 218.95 3036.42 2914.13 -444.54 -5914.14 5945336.96 552758.67 MWD+IFR-AK-CAZ-SC 7579.69 77.15 216.43 3057.29 2935.00 -516.92 -5970.06 5945264.15 552703.32 MWD+IFR-AK-CAZ-SC 7674.68 77.28 211.84 3078.32 2956.03 -593.58 -6022.03 5945187.10 552651.96 MWD+IFR-AK-CAZ-SC 7770.42 77.15 207.30 3099.51 2977.22 -674.76 -6068.09 5945105.57 552606.53 MWD+IFR-AK-CAZ-SC 7866.83 77.27 203.67 3120.86 2998.57 -759.61 -6108.54 5945020.41 552566.75 MWD+IFR-AK-CAZ-SC 7962.10 77.22 200.77 3141.90 3019.61 -845.62 -6143.67 5944934.14 552532.29 MWD+IFR-AK-CAZ-SC 8056.00 77.79 196.74 3162.23 3039.94 -932.41 -6173.14 5944847.13 552503.51 MWD+IFR-AK-CAZ-SC 8151.22 78.98 192.83 3181.40 3059.11 -1022.57 -6196.93 5944756.80 552480.42 MWD+IFR-AK-CAZ-SC j 8246.11 79.80 190.56 3198.88 3076.59 -1113.90 -6215.83 5944665.34 552462.23 MWD+IFR-AK-CAZ-SC 8340.39 80.30 189.08 3215.17 3092.88 -1205.40 -6231.67 5944573.73 552447.11 MWD+IFR-AK-CAZ-SC • 8391.00 79.94 189.38 3223.85 3101.56 -1254.61 -6239.66 5944524.46 552439.50 MWD+IFR-AK-CAZ-SC 8423.52 80.91 190.02 3229.26 3106.97 -1286.22 -6245.07 5944492.81 552434.34 MWD+IFR-AK-CAZ-SC 8501.16 82,91 191.54 3240.19 3117.90 -1361.72 -6259.44 5944417.20 552420.56 MWD+IFR-AK-CAZ-SC 8599.48 94.72 193.44 3242.22 3119.93 -1457.52 -6280.67 5944321.25 552400.08 MWD+IFR-AK-CAZ-SC 8698.35 90.45 195.34 3237.76 3115.47 -1553.16 -6305.21 5944225.43 552376.29 MWD+IFR-AK-CAZ-SC 8797.38 89.90 196.77 3237.46 3115.17 -1648.33 -6332.60 5944130.06 552349.65 MWD+IFR-AK-CAZ-SC 8896.19 93.23 199.04 3234.76 3112.47 -1742.30 -6362.96 5944035.87 552320.02 MWD+IFR-AK-CAZ-SC 8994.72 90.39 199.02 3231.65 3109.36 -1835.39 -6395.06 5943942.54 552288.64 MWD+IFR-AK-CAZ-SC ~i 9093.14 88.85 194.25 3232.30 3110.01 -1929.66 -6423.23 5943848.07 552261.22 MWD+IFR-AK-CAZ-SC II 9191.30 88.97 186.18 3234.17 3111.88 -2026.16 -6440.62 5943751.44 552244.58 MWD+IFR-AK-CAZ-SC 9290.53 86.56 182.60 3238.04 3115.75 -2125.00 -6448.21 5943652.55 552237.76 MWD+IFR-AK-CAZ-SC 9389.30 86.26 180.52 3244.23 3121.94 -2223.54 -6450.89 5943554.01 552235.84 MWD+IFR-AK-CAZ-SC 9484.72 91.14 179.73 3246.39 3124.10 -2318.90 -6451.10 5943458.65 552236.38 MWD+IFR-AK-CAZ-SC 9579.77 91.69 175.05 3244.04 3121.75 -2413.80 -6446.78 5943363.80 552241.44 MWD+IFR-AK-CAZ-SC 9674.73 86.81 170.68 3245.28 3122.99 -2507.96 -6434.99 5943269.74 552253.96 MWD+IFR-AK-CAZ-SC 9770.57 89.96 170.51 3247.99 3125.70 -2602.47 -6419.34 5943175.37 552270.35 MWD+IFR-AK-CAZ-SC 9864.76 94.04 171.90 3244.70 3122.41 -2695.47 -6404.95 5943082.49 552285.46 MWD+IFR-AK-CAZ-SC 9959.69 93.42 173.71 3238.52 3116.23 -2789.45 -6393.08 5942988.62 552298.06 MWD+IFR-AK-CAZ-SC 10055.71 94.35 174.34 3232.02 3109.73 -2884.72 -6383.11 5942893.43 552308.77 MWD+IFR-AK-CAZ-SC ' ~, 10150.69 93.30 175.78 3225.68 3103.39 -2979.14 -6374.95 5942799.09 552317.66 MWD+IFR-AK-CAZ-SC ' i ' 10246.24 91.63 174.95 3221.57 3099.28 -3074.28 -6367.24 5942704.02 552326.12 MWD+IFR-AK-CAZ-SC 10341.14 92.74 174.14 3217.95 3095.66 -3168.68 -6358.22 5942609.70 552335.87 MWD+IFR-AK-CAZ-SC 10435.96 93.36 174.16 3212.91 3090.62 -3262.87 -6348.57 5942515.60 552346.25 MWD+IFR-AK-CAZ-SC 10531.14 90.27 173.34 3209.89 3087.60 -3357.43 -6338.22 5942421.14 552357.34 MWD+IFR-AK-CAZ-SC 10626.23 90.58 172.04 3209.19 3086.90 -3451.74 -6326.12 5942326.93 552370.17 MWD+IFR-AK-CAZ-SC ~ 10721.28 89.71 173.63 3208.95 3086.66 -3546.04 -6314.26 5942232.73 552382.76 MWD+IFR-AK-CAZ-SC I 10816.37 89.22 176.37 3209.84 3087.55 -3640.76 -6305.98 5942138.09 552391.79 MWD+IFR-AK-CAZ-SC 10911.11 89.16 178.18 3211.18 3088.89 -3735.38 -6301.47 5942043.52 552397.03 MWD+IFR-AK-CAZ-SC ~ 11006.62 91.14 177.68 3210.93 3088.64 -3830.82 -6298.02 5941948.12 552401.22 MWD+IFR-AK-CAZ-SC 11101.84 91.07 176.51 3209.09 3086.80 -3925.90 -6293.20 5941853.09 552406.78 MWD+IFR-AK-CAZ-SC 1, 11196.51 91.63 177.38 3206.86 3084.57 -4020.41 -6288.15 5941758.63 552412.56 MWD+IFR-AK-CAZ-SC 11292.20 88.66 177.19 3206.62 3084.33 -4115.98 -6283.62 5941663.11 552417.84 MWD+IFR-AK-CAZ-SC 11387.62 90.52 177.76 3207.30 3085.01 -4211.30 -6279.42 5941567.83 552422.78 MWD+tFR-AK-CAZ-SC 11482.99 89.34 176.69 3207.42 3085.13 -4306.55 -6274.80 5941472.62 552428.14 MWD+IFR-AK-CAZ-SC 11578.28 88.85 177.06 3208.92 3086.63 -4401.69 -6269.61 5941377.54 552434.08 MWD+IFR-AK-CAZ-SC 11673.09 88.29 175.95 3211.29 3089.00 -4496.29 -6263.83 5941283.00 552440.59 MWD+IFR-AK-CAZ-SC 11768.09 90.77 179.05 3212.07 3089.78 -4591.18 -6259.69 5941188.15 552445.47 MWD+IFR-AK-CAZ-SC 11861.96 88.79 179.92 3212.43 3090.14 -4685.04 -6258.84 5941094.31 552447.05 MWD+IFR-AK-CAZ-SC 11956.69 90.95 179.22 3212.64 3090.35 -4779.76 -6258.13 5940999.61 552448.50 MWD+IFR-AK-CAZ-SC 12050.12 89.65 179.30 3212.15 3089.86 -4873.18 -6256.93 5940906.21 552450.43 MWD+IFR-AK-CAZ-SC ' ', 12148.10 92.43 176.61 3210.37 3088.08 -4971.06 -6253.43 5940808.37 '552454.69 MWD+IFR-AK-CAZ-SC 12241.82 92.87 176.41 3206.04 3083.75 -5064.51 -6247.73 5940714.98 552461.11 MWD+IFR-AK-CAZ-SC 12336.83 90.52 174.96 3203.23 3080.94 -5159.20 -6240.59 5940620.35 552469.00 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4!2612007 Timc: 15:33:46 __ __ 1'arc: 4 i Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-160, TR 1e Nofth Site: Kuparuk 1J Pad Vertical (TVD)Refcrence: 1J-160L2: 122:3 Well: 1J-160 Section (VS) Reference: Well (O.OON,O.OOE;180.OOAzi) Wellpath: 1J-160L2 Survey CakulationMethod: Minimum Curvat ure Db: Oracle SU R'l'~' bID 'fuel Azim TVA SvsTVA niS E/W biapN A1apF Tool ft deg deg ft ft ft ft ft ft 12431.85 90.09 176.61 3202.72 3080.43 -5253.96 -6233.60 5940525.66 552476.72 MWD+IFR-AK-CAZ-SC 12527.49 91.81 178.76 3201.14 3078.85 -5349.50 -6229.74 5940430.16 552481.32 MWD+IFR-AK-CAZ-SC 12622.86 93.43 180.59 3196.78 3074.49 -5444.76 -6229.20 5940334.92 552482.61 MWD+IFR-AK-CAZ-SC 12716.47 90.52 179.72 3193.55 3071.26 -5538.30 -6229.45 5940241.39 552483.08 MWD+IFR-AK-CAZ-SC 12812.46 89.28 179.37 3193.72 3071.43 -5634.29 -6228.69 5940145.42 552484.59 MWD+IFR-AK-CAZ-SC ~ 12907.75 88.11 178.61 3195.89 3073.60 -5729.53 -6227.01 5940050.20 552487.01 MWD+IFR-AK-CAZ-SC 13003.46 91.75 179.19 3196.01 3073.72 -5825.21 -6225.17 5939954.55 552489.60 MWD+IFR-AK-CAZ-SC 13029.15 91.88 179.17 3195.19 3072.90 -5850.88 -6224.81 5939928.88 552490.16 MWD+IFR-AK-CAZ-SC 13067.00 91.88 179.17 3193.95 3071.66 -5888.71 -6224.26 5939891.06 552491.01 PROJECTED to TD Time Lis DateFrom To Dur 5 De th E. De th Phase Code __ Subcode T COM __ 03/29/2007 06:00 10:15 4.25 5,590 0 COMPZ CASIN RUNL P Continue POOH with Liner tuning & setting tools from 5590' -surface. Observed ro er hole fill. 10:15 10:45 0.50 0 0 COMPZ CASINC RUNL P Breakou, Inspect and lay down running & setting tools as per BOT re . 10:45 11:15 0.50 0 0 COMPZ EVAL RURD P PJSM with crew &SWS reps. Rig up SWS wireline crew & e ui ment. 11:15 12:45 1.50 0 103 COMPZ EVAL RURD P Make up wireline tools with tractors and USIT rotatin sub. 12:45 17:15 4.50 103 8,474 COMPZ EVALVb ELOG P WLIH with tractors and USIT logging tools from 103' - 8474' MD. Observed no issues on WLIH. 17:15 18:00 0.75 8,474 7,300 COMPZ EVALVI~ ELOG P WLOH with tools logging from 8474' - 7300'. Crew Chan e 18:00 20:00 2.00 7,300 0 COMPZ EVALVI~ ELOG P Continue WLOH with tools logging from 7300' - 4300'. WLOH to surface. Monitor well -static. 20:00 21:00 1.00 0 0 COMPZ EVALVb RURD P Rig down SWS wireline tools and e ui ment. 21:00 21:45 0.75 0 0 COMPZ STK PULD P Clear & clean rig floor area. Monitor well -static. 21:45 22:15 0.50 0 0 PROD3 STK OTHR P Hld PJSM with rig crew, Sperry sun rep, and BOT rep. Discuss safety & hazard recognition issues. Discuss makin u Whi stock assembl . 22:15 23:00 0.75 0 0 PROD3 STK PULD P Pull all tools & lift subs to rig floor, re tools in i e shed for ickin u . 23:00 00:00 1.00 0 0 PROD3 STK PULD P Make up mills & flex joint. Lay down same in pipe shed. Make up Seal assembly & locator sub with space out i e and unloader sub. 03/30/2007 00:00 02:45 2.75 0 310 PROD3 STK PULD P Continue make up remaining whipstock BHA. Total length = 310.29'. 02:45 03:00 0.25 310 400 PROD3 STK OTHR P Make up first stand of DP, top drive connection. Perform Shallow pulse test @ 450 GPMs- 850 PSI. Good test. Blow down To Drive & lines. 03:00 06:00 3.00 400 3,766 PROD3 STK TRIP P Trip in hole with Whipstock assembly from 400' - 3766' @ 90 seconds / stand as per BOT rep.. Fill drill string eve 25 stands. Crew Chan e 06:00 10:00 4.00 3,766 7,748 PROD3 STK TRIP P Continue trip in hole with Whipstock assembly from 3766' - 7748' MD @ 90 seconds /stand as per BOT rep. Fill drill string every 25 stands. Observed proper hole fill. Rig back on Hi-Line ower 0930 HRS. 10:00 10:45 0.75 7,748 7,799 PROD3 STK TRIP P Perform MAD PASS from 7748' - 7799'. Trouble shoot MWD detection. Network roblems. 10:45 11:45 1.00 7,748 7,799 PROD3 STK TRIP P Perform MAD PASS again from 7748' - 7799'. 11:45 12:00 0.25 7,799 7,992 PROD3 STK TRIP P Continue trip in hole with Whipstock assembl from 7799' - 7992'. ~~. ~®~ ~~- ~;~~e~: ~~ ref ~(7 Time Logs Date From Ta Dur S. Dep_t_h E Depth Phase Code _ Subcode T COM -- -- _ 03/30/2007 12:00 12:15 0.25 7,992 8,393 PRODS STK TRIP P Continue trip in hole with whipstock assembl from 7992' - 8393'. 12:15 13:15 1.00 8,393 8,520 PRODS STK CIRC P Establish circulation & orient whipstock face to 12 degrees left of high side as per DD & BOT reps. TIH tagging top od B lateral liner @ 8520 (2' low), setting seals into liner top. UP WT = 180K, SO WT = 110K. Set down 18k to set BTA, pull 10 K over to verify set. Set down 35K to shear bolt. Pick up to neutral position. Rotate free of whipstock. Top of whi stock = 8391' MD. 13:15 18:00 4.75 8,520 8,416 PRODS STK MILL P Mitf window from 8391' - 8408' in 4.41 HRS.Continue mill in open hole to 8416'. Crew Chan e 18:00 20:00 2.00 8,416 8,431 PRODS STK MILL P Continue mill in open hole from 8416' - 8431' MD. 60 - 100 RPM's. 2 - 10K WOB, Pumps @ 500 GPM's - 2000 PSI. Total millin time = 6.33 HRS. 20:00 21:15 1.25 8,431 8,431 PRODS STK MILL P Work mills through window area while pumping Hi-Visc sweep. Continue work mills until observed good clean window. 21:15 21:45 0.50 8,431 8,431 PRODS STK OWFF P Monitor well -static. Pump dry job, and blow down To Drive & lines. 21:45 22:45 1.00 8,431 7,197 PRODS STK TRIP P Trip out of hole from 8431' - 7197'. lay down 24 joints of 5" DP for allowance of 4" DP to be icked u . 22:45 00:00 1.25 7,197 4,625 PRODS STK TRIP P Continue POOH from 7197' - 4625'. Observed ro er hole fill. 03/31/2007 00:00 06:00 6.00 4,625 180 PRODS STK TRIP P Continue POOH with milling assembly from 4625' - 180'. Reposition super sliders 1 foot down and inspect same. Wrap super sliders and LoTads for target zero issues. Observed well takin about 36 BBLS. Crew Chan e 06:00 07:15 1.25 180 0 PRODS STK PULD P Breakout, inspect & lay down milling assembl .Mills in au e. 07:15 07:45 0.50 0 0 PRODS STK PULD P Clean & clear rig floor area. Send out tools. 07:45 08:30 0.75 0 0 PRODS STK OTHR P Pull wear bushing, Make up Stack washing tools, and flush BOP stack of iron cuttings. Install wear bushing & RILDS. 08:30 09:00 0.50 0 0 PRODS STK OTHR P Perform weekly BOP function test. Record on IADC. Blow down Kill & choke lines. 09:00 09:30 0.50 0 0 PRODS DRILL PULD P Clean & clear rig floor area, pull tools to ri floor. 09:30 09:45 0.25 0 0 PRODS DRILL PULD P Make up CCV valve & ball catcher. La down same in i e shed. 09:45 10:15 0.50 0 0 PRODS DRILL SFTY P Held PJSM with crew, DD & MWD reps. Discuss safety & hazard recognition issues. Discuss procedure for makin u and runnin BHA #10. .;Time Logs ~_D_at~____ Fro m_ To Dur S De th E Depth Phase Code Subcode T COM 03/31/2007 10:15 12:00 1.75 0 93 PROD3 DRILL PULD P Make up BHA #10 with 6 34" Security bit RR & 6 3/4" Geo ilot assembl . 12:00 12:45 0.75 93 280 PROD3 DRILL PULD P Continue MU BHA #10. Plug in and U load MWD assembl . 12:45 13:00 0.25 280 280 PROD3 DRILL PULD P Perform shallow pulse test on MWD assembly with 6.5 BPM - 1100 PSI. Good test. Rotate drill string at 30 RPM's for break in seals on GeoPilot. 13:00 13:45 0.75 280 280 PROD3 DRILL PULD P Blow down Top drive & lines. Inspect to drive & travelin a ui ment. 13:45 15:45 2.00 280 4,492 PROD3 DRILL TRIP P Trip in hole with BHA #10 from 280' - 4492' MD. Fill drill strin at 2708'. 15:45 16:00 0.25 4,492 4,762 PROD3 DRILL PULD P Pick up 9 more joints of 4" DP from i e shed. 16:00 16:30 0.50 4,762 4,762 PROD3 DRILL PULD P Change out drill pipe elevators and equipment from 4" DP to 5" DP. Install CCV valve & crossovers. 16:30 18:00 1.50 4,762 7,028 PROD3 DRILL TRIP P Trip in hole with BHA #10 from 4762' - 7028' MD. UP WT = 120K, SO WT = 102K. Fill drill string every 25 stands. Observed proper hole fill. Fill drill string, and rotate 30 RPM's for break in of Geopilot bearings & seals. Crew Chan e 18:00 19:45 1.75 7,028 8,308 PROD3 DRILL TRIP P Continue trip in hole with BHA #10 from 7028' - 8308'. UP WT = 160K, SO WT = 115K. Fill drill string. Observed proper hole fill. Blow down Top drive & lines. Install TIW valve in drill strin . 19:45 21:15 1.50 8,308 8,308 PROD3 RIGMN SVRG P Held PJSM. Discuss safety & hazard recognition issues. Slip & cut 142' of drilling line.lnspect & adjust draw works brakes & linka e. 21:15 22:00 0.75 8,308 8,308 PROD3 RIGMN SVRG P PJSM, Change out saver sub. 22:00 23:00 1.00 8,308 8,308 PROD3 RIGMN SVRG P Service Top Drive, Crown & blocks. 23:00 00:00 1.00 8,308 8,308 PROD3 RIGMN RGRP T Work on leaking Hydraulic hose in Top Drive. Check all Hydraulic hoses & connections. 04/01/2007 00:00 03:15 3.25 8,308 8,308 PROD3 RIGMN RGRP T Work on leaking Hydraulic hose & failed O ring in Shot pin maifold assembly. in Top Drive. Check all H draulic hoses & connections. 03:15 03:30 0.25 8,308 8,308 PROD3 DRILL CIRC P Remove TIW Valve & Establish circulation rates. 03:30 06:00 2.50 8,430 8,538 PROD3 DRILL DDRL P Slack off and run Geo Pilot assembly through window with no issues to 8430' MD. Directional drill 6 3/4" hole in the D lateral from 8430' - 8538' MD. TVD = 3249'. Crew Chan e 06:00 12:00 6.00 8,538 8,781 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 8538' - 8781' MD. TVD = 3291'. ~ ~ Time Logs Date From To Dur S De th E. De th Phase Code S~~bcode T COM 04/01/2007 12:00 18:00 6.00 8,781 9,229 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 8781' - 9229' MD. TVD = 3237'. Crew Chan e 18:00 00:00 6.00 9,229 9,545 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 9229' - 9545' MD. TVD = 3243'. Total Bit HRS = 15.15. 04/02/2007 00:00 06:00 6.00 9,545 9,997 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 9545' - 9997' MD. TVD = 3228'. ADT = 4.90 HRS. 06:00 12:00 6.00 9,997 11,003 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 9997' - 11003' MD. TVD = 3212'. ADT = 3.70 HRS. 12:00 18:00 6.00 11,003 11,929 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 11003' -11929' MD. TVD = 3204'. ADT = 3.88 HRS. 18:00 00:00 6.00 11,929 12,661 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 11929' - 12661' MD. TVD = 3194'. ADT = 4.42 HRS. 04/03/2007 00:00 02:30 2.50 12,661 13,067 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 12661' - 13067' MD. TVD = 3194'. ADT = 1.41 HRS. 02:30 03:00 0.50 13,067 13,067 PROD3 DRILL CIRC P Pump Hi Visc sweep to the bit while reci rocate & rotate drill strin . 03:00 06:00 3.00 13,067 11,713 PROD3 DRILL REAM P BROOH from 13067' - 1171.3' MD BROOH at 10-20' ft/min until sweep back. Continue BROOH 50-60 fUmin. Crew Chan e 06:00 10:45 4.75 11,713 8,350 PROD3 DRILL REAM P Continue BROOH from 11713' - 8350' MD -above top of window. Observed good hole conditions with proper hole fill. 10:45 12:00 1.25 8,350 8,350 PROD3 DRILL CIRC P Pump Hi Visc sweep, circulate & condition mud while reciprocating & rotatin drill strip . 12:00 13:45 1.75 8,350 8,350 PROD3 DRILL CIRC P Continue pump Hi Visc sweep, circulate & condition mud while reci rocatin &rotatin drill strip . 13:45 14:15 0.50 8,350 8,350 PROD3 RIGMN SVRG P Service Top Drive & blocks. 14:15 17:00 2.75 8,350 13,067 PROD3 DRILL TRIP P Trip in hole from 8350' - 13067' MD. Observed good hole condiitons. Fill Drill string every 25 stands. Obtain T&D arameters as er ri en ineer. 17:00 18:00 1.00 13,067 13,067 PROD3 DRILL CIRC P Establish circulation, pumping Hi Visc sweep while reciprocate & rotate drill strip .Crew Chan e 18:00 20:15 2.25 13,067 13,067 PROD3 DRILL CIRC P Continue circulate until sweep in casing. Drop ball openeing CCV Valve. Increase circulation rate to 900 GPM's- 3100 PSI. Observed slight increase in cuttings when sweep across shakers. ~ ~ Time Logs Date From To Dur _ 5 Depth E. De th Phase Code Subcode_ T COM 04/03/2007 20:15 _ 22:45 __ 2.50 13,067 13,067 PROD3 DRILL CIRC P __ Drop second ball to close CCV Valve. Held PJSM with crew, mud engineer and vac truck drivers. Discuss safety & hazard recognition issues. Rig up and displace well bore with SFMOBM while reci rocate & rotate drill strip . 22:45 23:00 0.25 13,067 13,067 PROD3 DRILL OWFF P Monitor well -static. 23:00 23:30 0.50 13,067 12,569 PROD3 DRILL TRIP P POOH with 5 stands from 13067' - 12569' MD, observing well taking fluid and no swabbin issues. 23:30 23:45 0.25 12,569 12,569 PROD3 DRILL CIRC P Drop ball, opening CCV valve, and circulate veri in o en valve. 23:45 00:00 0.25 12,569 12,569 PROD3 DRILL OWFF P Monitor well -static. Blow down top drive & lines. 04/04/2007 00:00 06:00 6.00 12,569 5,183 PROD3 DRILL TRIP P POOH on elevators from 12569' - 5183'. Obtain SLM & T&D parameters as per rig engineer. Wrap top 2 Lotads & Super sliders with absorbent for tar et zero issues. Crew Chan e 06:00 06:30 0.50 5,183 4,887 PROD3 DRILL TRIP P Continue POOH from 5183' - 4887'. Observed proper hole fill. Obtain SLM & T&D parameters as per rig engineer. Observed no issues when assembly throu h window area. 06:30 07:30 1.00 4,887 4,887 PROD3 DRILL PULD P Change ou DP elevators from 5" to 4". Ri u to u114" DP. 07:30 10:00 2.50 4,887 371 PROD3 DRILL TRIP P Continue POOH from 4887' - 371' (BHA). Obtain SLM & T&D parameters as per rig emgineer. SLM good - no corrections made. 10:00 11:00 1.00 371 0 PROD3 DRILL PULD P Breakout & lay down BHA, flex collars to i e shed. 11:00 12:00 1.00 0 0 PROD3 DRILL PULD P Plug in and down load MWD assembl . 12:00 13:30 1.50 0 0 PROD3 DRILL PULD P Continue breakout & lay down BHA. Inspect & grade bit to 1 /1 /BT/A/X/I/CT/TD 13:30 14:30 1.00 0 0 COMPZ DRILL PULD P Clear & clean rig floor area. Send tools out. Monitor well -static. 14:30 15:15 0.75 0 0 COMPZ CASINC RURD P Rig up GBR casing running e ui ment. 15:15 18:00 2.75 0 3,935 COMPZ CASINC RNCS P Held PJSM with crew, BOT reps, GBR reps. Discuss safety & hazard recogniiton issues. Make up 4 1/2" Float shoe joint & continue RIH from pipe shed with 4 1/2" Slotted /blank liner as per detail. Run a total of 95 joints. Obtain T&D parameters as per ri en ineer. Crew Chan e 18:00 18:15 0.25 3,935 4,465 COMPZ CASINC RNCS P Continue run 4 1/2" liner form pipe shed for a total of 105 joints picked u. 18:15 19:15 1.00 4,465 4,650 COMPZ CASINC RNCS P Change out elevators, MU crossover. Run 3 stands of 4" DP. MU Crossover. Chan a out elevators to 5" DP. - - °-- - m m~ ~.e __ a ~ Time Logs Date From To Dur S Depth_ - _E_Depth _Phas_e Code Subcode -- T - COM 04/04/2007 19:15 00:00 4.75 4,650 11,291 COMPZ CASIN( RUNL P Continue RIH with 4 1/2" slotted liner form 4650' - 11291'. Observed proper hole fill. Obtain T&D parameters as per rig engineer. Running speed = 75 seconds /stand. 04/05/2007 00:00 00:45 0.75 11,291 11,861 COMPZ CASINC RUNL P Continue run 4 1/2" slotted liner as per detail from 11291' - 11861'. Ran out of weight. UP WT = 195K, SO WT = 75K, ROT WT = 150K 00:45 02:30 1.75 11,861 13,068 COMPZ CASINC RUNL P Rotate liner down from 11861' - 13061'. Tag bottom @ 13068' while rotating. Max for ue = 11 K 02:30 03:30 1.00 13,068 13,061 COMPZ CASINC RUNL P Pull up to tool joint. Drop 29/32" ball. Pump down @ 3 BPM setting liner on depth as per detail @ 13061'. Allow ball to seat with 1435 strokes. Pressure to 2500 PSI. Set down 50K, continue pressure to 4000 PSI observing string movement. Pulled up to verify free of liner. Set down tagging to of liner 8605.25'. MD. 03:30 05:00 1.50 8,605 8,400 COMPZ CASIN CIRC P POOH with 2 stands to position bottom of tools at the window area for washing face of whipstock while CBU 5 BPM - 350 PSI. 05:00 05:15 0.25 8,400 8,400 COMPZ CASINC OTHR P Monitor well -static. 05:15 06:00 0.75 8,400 6,255 COMPZ CASINC RUNL P POOH from 8400' - 6255' with liner running & setting tools. Observed ro er hole fill. Crew Chan e 06:00 10:15 4.25 6,255 0 COMPZ CASIN RUNL P Continue POOH with liner running & setting tools from 6255' to surface. Observed proper hole fill. Wrap Lotads & su er sliders for tar et zero issues. 10:15 10:45 0.50 0 0 COMPZ CASINC RUNL P Breakout, Inspect & lay down running & setting tools as per BOT rep. All tools looked ood. 10:45 12:00 1.25 0 0 COMPZ STK PULD P PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Make up whipstock retrieval assembl . 12:00 13:00 1.00 0 0 COMPZ STK PULD NP Lay down retrieving assembly to pipe shed. Decision to test BOP's. 13:00 15:00 2.00 0 0 COMPZ WELCT BOPE P PJSM with rig crew & TP. Rig up to test BOP's. Grease Choke manifold. Drain BOP stack. BOLDS & pull wear bushing. Install test plug. Fill stack with water & ri u chart recorder. 15:00 18:00 3.00 0 0 COMPZ WELCT BOPE P Test BOP's with AOGCC rep Jeff Jones witnessing test. Test to 250 / 3000 PSI on all valves and floor valves. Crew Chan e ~.__" F~~~ 3~ o~ ~£d ~ ~ Time Logs -- Date From To Dur S D~th E. Depth Phase___ _Code__ _ _Subcode - T COM _ 04/05/2007 18:00 00:00 6.00 0 0 COMPZ WELCT BOPE P Continue test BOP's with AOGCC rep Jeff Jones witnessing test. Test to 250 / 3000 PSI on all valves and floor valves. perform draw down test with 200 psi increase in 40 secs, and full charge at 3 min 16 secs. Avg nitrogen bottle ressure = 2000 si. 04/06/2007 00:00 00:30 0.50 0 0 COMPZ WELCT BOPE P Pull test plug. Install wear bushing. RILDS> Blow down lines, choke & kill line. Rig down test equipment & chart recorder. 00:30 01:15 0.75 0 154 COMPZ STK PULD P PJSM with rig crew & BOT rep. Discuss safety & hazard recognition issues. Make up Whipstock retreiving BHA. Total len th = 154'. 01:15 05:30 4.25 154 8,397 COMPZ STK TRIP P Trip in hole with whipstock retrieving BHA from 154' - 8397'. Observed proper hole fill. Float installed in assembly. UP WT = 198K, SO WT = 105K. 05:30 06:00 0.50 8,397 8,397 COMPZ STK OTHR P Locate slot in slide with retrieving hook on depth @ 8397' DPM. Engage slot, set down to cock jars, and pull to 80K over to fire jars. Repeat 4 times to observe anchor released & pulled free @ 150K over staright pull. Crew Chan e. 06:00 06:30 0.50 8,397 8,270 COMPZ STK TRIP P Lay down a single of DP. Pull 1 stand slow observin fluid fallin in hole. 06:30 08:15 1.75 8,270 8,270 COMPZ STK CIRC P Circulate bottoms up. Hole took 5.5 BBLS to fill. No fluid loss on circulation. Circulate through headpin & hose @ 70 SPM - 750 PSI while change out swivel packing on top drive. 08:15 09:00 0.75 8,270 8,270 COMPZ STK CIRC P Rig down hose &headpin. Blow down lines and top drive. Monitor well - static. 09:00 12:00 3.00 8,270 3,610 COMPZ STK TRIP P POOH with whipstock assembly ensuring no down movement in DP string from 8270 - 3610'. Observed ro er hole fill. 12:00 14:45 2.75 3,610 0 COMPZ STK TRIP P Continue POOH with whipstock assembly ensuring no down movement in DP string from 3610' - hook.. Observed ro er hole fill. 14:45 18:00 3.25 0 0 COMPZ STK PULD P Held PJSM with crew & BOT reps. Discuss safety & hazard recognition issues. Breakout & lay down whipstock assembly with jewelry & s ace out i e. Crew Chan e 18:00 18:45 0.75 0 0 COMPZ RPCOA RURD P Rig up casing equipment to run Hook Han er com letion assembl . 18:45 20:00 1.25 0 272 COMPZ RPCOti PULD P Make up Hook Hanger assembly with ECP and MWD. Orient MWD to Hok Han er hook 180 de tees out. . ~e._ ®~ ® _ ® p^y p J ` X l~~L 3~i C2a~ HU ~ ~ Time Logs ' - Date From T_o___ Dur_____ S _Depth E. Depth Phase Code Subcode T COM__ _- - - _ 04/06/2007 20:00 21:00 1.00 272 272 COMPZ RPCO PULD P Clean floor & clear tools for trip in hole. Chan a out elevators to 5" DP. 21:00 21:30 0.50 272 569 COMPZ RPCOh TRIP P Trip in hole from 272' - 569'. Perform Shallow pulse test @ 120 GPM's - 450 PSI. 21:30 00:00 2.50 569 6,148 COMPZ RPCOCV TRIP P Trip in hole with Hook Hanger assembly from 569' - 6148' MD. Observed ro er hole fill. 04/07/2007 00:00 00:45 0.75 6,148 8,323 COMPZ RPCO TRIP P Trip in hole with Hook Hanger assembly from 6148' - 8323'. Observed ro er hole fill. 00:45 02:45 2.00 8,323 8,391 COMPZ RPCOh HOSO P Slack off & verify top of crossover bushing in lower B lateral @ 8550'. Pull 2 stands, putting 1/4 to 1/2 RH turns in sdrill string to orient bent joint for window, Repeat 4 times. Bent joint throu h window on 5th attem t. 02:45 04:15 1.50 8,391 8,640 COMPZ RPCOh HOSO P TIH from 8391' - 8640' MD. Pump down drill string @ 120 GPM's - 700 PSI to obtain good tool face surveys. After repeated attempts to sting into D lateral liner top, rotate slow with 8K surface torque to rotate into liner top. Continue slack off with high side toolface to locate & hang Hook Hanger at 8412.5' DPM. (4' LOVE. Obtain Toolfaces surveys to verify hooked at 6 degrees left of high side. Pull up releasing hook hanger, and work 1/2 turn into string to obtain hook 180 Degrees out from window slot. Slack off and work Hook Hanger past window bottom 6' to verify depth by tagging on crossover. Pick up, work 1/2 turn into drill string and re-hook Hook Hanger on depth @ 8412.5' with Tail @ 8656.84'. Set 35K on Hook Hanger as er BOT re . 04:15 05:15 1.00 8,640 8,412 COMPZ RPCOh HOSO P Drop 29/32" ball down drill string, pump down @ 3 BPM - 700 PSI. Observed ball landed & seated. 05:15 06:00 0.75 8,381 8,381 COMPZ RPCOh PACK P Pressure to 1500 PSI. Then in 200 PSI increments to 2800 PSI to inflate ECP to full gauge of hole calculated @ 7.2" by .403 BBLS pumped. Pressure to 4100 PSI to shear circulation sub & release from hook hanger. Pull free. Crew Chan e 06:00 06:45 0.75 8,381 8,300 COMPZ RPCOh TRIP P POOH from 8381', 1 stand. Monitor well -static. Blow down Top drive & lines. ( _ - ~_.__~ ~~ze~ 37 ~~ -t ~ ~ Time Logs Date From To Dur 5. De th E De th Phase Code Subcode T COM _ __ 04/07/2007 06:45 09:45 3.00 8,300 8,300 COMPZ RIGMN _ SVRG P Prepare rig floor for service. Held PJSM discuss safety & hazard recognition issues: Slip & cut drilling line. Inspect & adjust draw works brakes, & linkage. Check and adjust gap on weight sensor. Service Top Drive, and crown section. Perform derrick ins ection. 09:45 12:00 2.25 8,300 4,923 COMPZ RPCOh TRIP P POOH from 8300' - 4923'. Obtain T&D parameters as per rig engineer. Observed ro er hole fill. 12:00 14:45 2.75 4,923 0 COMPZ RPCOR TRIP P POOH from 4923' -surface. Obtain T&D parameters as per rig engineer. Observed ro er hole fill. 14:45 16:00 1.25 0 0 COMPZ RPCOh PULD P Inspect, breakout & lay down BOT running & setting tools, and MWD assembl . 16:00 16:30 0.50 0 0 COMPZ RPCOh OTHR P Clear & clean rig floor area. Send tools out. Brin tools u for next run. 16:30 17:45 1.25 0 250 COMPZ RPCO PULD P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss making up BHA. Make up LEM assembly as per BOT re ,with MWD assembl . 17:45 18:00 0.25 250 448 COMPZ RPCOh TRIP P Trip in hole from 250' - 448'. Make Top drive connection. Crew Chan e 18:00 18:30 0.50 448 448 COMPZ RPCOti TRIP P Perform Shallow pulse test on MWD assembl 100 GPM's - 450 PSI> 18:30 23:00 4.50 448 8,485 COMPZ RPCOh TRIP P Continue trip in hole with LEM completion assembly & ZXP packer from 448' - 8485'. Fill drill string every 10 stands.Obtain T&D parameters as per rig engineer. Observed proper hole fill. 23:00 00:00 1.00 8,485 8,391 COMPZ RPCOh HOSO P Make Top drive connection. UP WT - 210K, SO WT = 105K. Pumps @ 120 GPM's - 650 PSI> Obtain MWD toolfaces at 80 deg right. Work drill string and orient to 16 deg Right. Locate & latch up LEM assembly @ 8391' as per detail. Pump up numerous surveys to verify orientation at 11 degrees left of high side. Note: Hook Hanger @ 6 Degrees left of high side. 04/08!2007 00:00 00:30 0.50 8,561 8,561 COMPZ RPCOh HOSO P Pull out of latch observing 25K overpull to come free. Re-latch LEM assembly. Pu1120K to verify latched. Set all wei ht down on latch. 00:30 01:15 0.75 8,561 8,561 COMPZ RPCOti HOSO P Drop 1 3/4" Ball down drill string. Pump @ 120 GPM - 650 PSI. Allow ball to seat @ 1140 stks. Pressure to 2500 PSI to set packer. Continue pressure to 4000 PSI to release runnin & settin tools. ~® ~ ~ a ~ ®e~®e. m e~ i • Time Logs Date From To Dur S. De th E. nth Phase Code Subcode T COM ___ _ ~ 04/08/2007 01:15 02:30 1.25 8,561 8,561 COMPZ RPCOti DHEQ P Rig up, close pipe rams. Pressure test down annulus fora 2500 PSI - 30 minute test recorded on chart. Good test. 02:30 03:00 0.50 8,561 8,391 COMPZ RPCOh TRIP P Pull running tools from packer assembly verifying free. Monitor well - static. Blow down Kill line, top drive & lines. 03:00 04:30 1.50 8,391 4,793 COMPZ RPCOh TRIP P POOH from 8391' - 4793'. Observed ro er hole fill. 04:30 06:00 1.50 4,793 3,607 COMPZ RPCOb TRIP P Continue POOH with running tools from 4793' - 3607'. Remove Super Sliders and Lo-tads. Crew Chan e 06:00 12:00 6.00 3,607 1,136 COMPZ RPCOh TRIP P Continue POOH with running tools from 3607' - 1136'. Remove Super Sliders and Lo-tads. 12:00 13:15 1.25 1,136 0 COMPZ RPCOh TRIP P Continue POOH with running tools from 1136' to surface.. Remove Super Sliders and Lo-tads. Total layed down = 45 lotads & 120 super sliders. Inspect, breakout & lay down running & settin tools. 13:15 15:30 2.25 0 0 COMPZ RPCO PULD P Clean & clear rig floor area.Send out all Super sliders &lotads. Send all runnin tools, and a ui ment out. 15:30 16:15 0.75 0 0 COMPZ RPCOh RURD P Rig GBR tubing running equipment. Brin tools to floor. 16:15 16:30 0.25 0 0 COMPZ RPCOI~ SFTY P Held PJSM with crew, BOT rep, and GBR reps. Discuss safety & hazard recognition issues. Discuss make up and run 4 1/2" com letion strip . 16:30 18:00 1.50 0 2,471 COMPZ RPCO PULD P Make up 4 1/2" 12.6# IBTM completion tubing as per detail. Trip in hole to 2471'. Crew Chan e 18:00 23:00 5.00 2,471 8,357 COMPZ RPCOh PULD P Continue RIH with 4 1/2" completion string from 2471' - 8356'. Observed ro er hole fill. 23:00 00:00 1.00 8,357 8,357 COMPZ RPCOh RURD P Land seals in CSB, and space out. Used no pups to space out. Make up Tubing hanger as per Vetco rep. MU landing joint. RIH land tubing hanger on depth with seals engaged and mule shoe 3.88' above XO in assembly @8357.02'. Tubing hanger landed @ midnight with TWC previously installed b re . 04/09/2007 00:00 00:45 0.75 0 0 COMPZ RPCO PULD P RILDS. Test upper and lower packoff seals to 5000 PSI - 10 minutes. Back out & la down landin 'oint. 00:45 03:45 3.00 0 0 COMPZ WELCT NUND P Held PJSM with crew. Discuss safety & hazard recognition issues. Nipple down BOP stack, choke & kill lines, flow nipple & lines. Clean out drip pan under rota table. 03:45 06:00 2.25 0 0 COMPZ WELC7 NUND P Nipple up Vetco Gray MB-222 Tree as per reps. Test flange & void to 5000 PSI - 10 minutes. Crew Chan e • i Time Logs Date From To Dur S _Depth_ E. Depth PhasE _ _Code_ Subcode T COM 04/09/2007 06:00 07:15 1.25 0 0 COMPZ RPCOti OTHROTHR P Rig up Lubricator. Pull TWC. RD Lubricator. la down Belt ni le. 07:15 08:00 0.75 0 0 COMPZ RPCOh FRZP P Rig up Little Red to freeze protect well. SIMOPS: RU to lay down DP from derrick. 08:00 09:45 1.75 0 0 COMPZ RPCOh OTHR P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss laying down DP from derrick. Lay down drill i e from derrick. 09:45 11:30 1.75 0 0 COMPZ RPCOR FRZP P Continue lay down DP from derrick. SIMOPS: Held PJSM with Little Red and hands. Pump down annulus to freeze protect IA & tubing.Pumped a total of 640 BBLS with no fluid losses observed. 11:30 16:00 4.50 0 0 COMPZ RPCOh OTHR P Continue lay down 5" DP from derrick. NOTE: Left 16 stands of 5" DP in derrick for ri move. 16:00 18:00 2.00 0 0 COMPZ RPCOh OTHR P Change out elevators to 4" DP. Lay down 4" DP from derrick. Crew Chan e 18:00 21:00 3.00 0 0 COMPZ RPCOh OTHR P Continue lay down 4" DP from derrick. 21:00 22:30 1.50 0 0 COMPZ RPCOh OTHR P Make up Lubricator as Vetco Gray rep. Set BPV. Lay down Lubricator & install tree cap & gauges. Final shut in pressures, TBG = 0 PSI. IA = 200 PSI, OA = 150 PSI. 22:30 00:00 1.50 0 0 COMPZ RPCOh OTHR P Secure well, clean out cellar box, cuttings tanks, and drip pan under rota table. 04/10/2007 00:00 06:00 6.00 0 0 COMPZ RPCOh OTHR P Continue clean out cellar box, cuttings tanks, and drip pan under rotary table. Fiinsh cleaning pits &rockwasher. Remove drill pipe from shed. Prep rig for Demob. 06:00 10:00 4.00 0 0 COMPZ MOVE DMOB P Preparing rig for moving to the other side of the pad. Move f/ 1 J-160 to 1 J-135. Skid rig floor. Blow down steam and water. Remove remaining joints of drill pipe from pipe shed. Move rockwasher. Note: Rig released from 1J-160 @ 1000 hrs 4/10/2007 f/ move to 1J-135 on the other side of ad. ~ac,~°e -t" uF ~#5 l~.....~..___ ~..~ • • Description of Casing Well: 1J-160 L2 C01"1QCOPI11~I1~'JS Slotted and Blank Liner Date: 414107 niaska; ~n~. Supervisors: Mike Thornton /Scott Heim Rig: Doyon 15 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS Plop & Drop 8598.81 "B" Lateral ZXP @ 8518' / XO @ 3241' 8598.81 "D" lateral window top @ 8391'/ Btm @ 8408.45' 8598.81 '~~~ ~ ' TOL 196.80' out in open hole @ 8,605.25' 8598.81 8598.81 8598.81 5" DP to Surtace =_> 8598.81 Liner Runnin Tool 5" Does not sta in hole 6.44 8598.81 5 112" Baker "HR" Liner Setting Sleeve (6.41" O.D. x 5.75" I.D.) 12.68 8605.25 51/2", 15.5 ppf, L-80, Hydril 521 Pup joint 7.30 8617.93 5 1/2", 15.5 ppf, L-80, Hydril 521 37.09 8625.23 5 1/2" Hydril 521 Pin X 4 1/2" BTC Pin X/O (3.96" I.D.) 1.40 8662.32 4-112", 11.6 ppf, L-80, BTC PUP Jt. 3.82 8663.72 Jts 104 to 10 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.51 8667.54 Jts 103 to 10 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.33 8711.05 Jts 102 to 10 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.05 8754.38 Jts 101 to 101 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 39.98 8797.43 Jts 100 to 10 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.39 8837.41 Jts 99 to 99 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.18 8880.80 Jts 98 to 98 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.23 8922.98 Jts 97 to 97 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 35.68 8966.21 Jts 96 to 96 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.51 9001.89 Jts 95 to 95 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.21 9045.40 Jts 94 to 94 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.59 9088.61 Jts 88 to 93 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 241.59 9131.20 Jts 87 to 87 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.31 9372.79 Jts 86 to 86 1 Jts 4-1/2", 11.6 ppf, L$0, BTC Blank Casing 40.45 9416.10 Jts 85 to 85 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 38.86 9456.55 Jts 84 to 84 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 36.87 9495.41 Jts 83 to 83 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.36 9532.28 Jts 82 to 82 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.03 9575.64 Jts 81 to 81 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.27 9615.67 Jts ao to so 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.33 9658.94 Jts 79 to 79 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 36.77 9699.27 Jts 78 to 78 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 37.53 9736.04 Jts 77 to 77 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.22 9773.57 Jts 76 to 76 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 39.97 9815.79 Jts 75 to 75 1 Jts 4-1/2",11.6 ppf, L$0, BTC Slotted Casing 40.79 9855.76 4-1/2": Ran total of 65 Jts Blank= 2,695.52' and 40 Jts Slotted= 1,697.25'. Up Wt 225K Slots are w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, Dn Wt OK 3" Centers Staggered 18 deg., 3 ft. non-slotted ends. Block Wt 70K Used Run-N-Seal thread compound on all connections. Rot Wt 150K Drifted 4-1/2" to 3.885 w/ teflon rabbit. • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 69 to 74 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 248.91 9896.55 Jts s7 to ss 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 86.71 10145.46 Jts 66 to 66 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.09 10232.17 Jts 65 to 65 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.39 10272.26 Jts 64 to 64 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 36.95 10315.65 Jts 63 to 63 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.33 10352.60 Jts 62 to 62 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 36.82 10392.93 Jts 61 to 61 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.20 10429.75 Jts so to so 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.78 10472.95 Jts 59 to 59 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.33 10515.73 Jts 58 to 58 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.14 10559.06 Jts 57 to 57 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.49 10602.20 Jts 51 to 56 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 258.14 10645.69 Jts 50 to 50 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.38 10903.83 Jts 49 to 49 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.31 10946.21 Jts 4s to 48 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.31 10989.52 Jts 47 to 47 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.86 11032.83 Jts 46 to 46 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.01 11075.69 Jts 45 to 45 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.35 11118.70 Jts 44 to 44 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.46 . 11162.05 Jts 43 to 43 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.90 11205.51 Jts 42 to 42 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.28 11248.41 Jts 41 to 41 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.59 11291.69 Jts ao to ao 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.38 11334.28 Jts 33 to 39 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 295.26 11376.66 Jts 32 to 32 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.47 11671.92 Jts 31 to 31 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 41.12 11715.39 Jts 3o to 30 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.25 11756.51 Jts 29 to 29 1 Jts 4-1/2", 11.6 ppf, L$0, BTC Blank Casing 43.32 11799.76 Jts 28 to 28 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.89 11843.08 Jts 27 to 27 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 38.81 11885.97 Jts 26 to 26 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.37 11924.78 Jts 25 to 25 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.89 11968.15 Jts 24 to 24 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.30 12011.04 Jts 23 to 23 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.62 12054.34 Jts 22 to 22 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 36.92 12097.96 Jts 16 to 21 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 255.20 12134.88 Jts 15 to 15 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.68 12390.08 Remarks: Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 14 to 14 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 40.94 12430.76 Jts 13 to 13 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.11 12471.70 Jts 12 to 12 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.51 12513.81 Jts 11 to 11 1 Jts 4-1/2",11.6 ppf, L$0, BTC Slotted Casing 43.26 12557.32 Jts 10 to 10 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.69 12600.58 Jts 9 to 9 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.31 12643.27 Jts 8 to 8 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 36.85 12686.58 Jts 7 to 7 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.63 12723.43 Jts 6 to 6 1 Jts 4-1/2",11.6 ppf, L$0, BTC Blank Casing 41.23 12767.06 Jts 5 to 5 1 Jts 4-1/2",11.6 ppf, L$0, BTC Slotted Casing 43.32 12808.29 Jts 4 to 4 1 Jts 4-1/2", 11.6 ppf, L$0, BTC Blank Casing 42.55 12851.61 Jts 3 to 3 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 38.13 12894.16 Jts 2 to 2 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 41.09 12932.29 Jts 1 to 1 1 Jts 4-1/2",11.6 ppf, L$0, BTC Slotted Casing 43.48 12973.38 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.74 13016.86 4-1/2", BTC Baker Float Shoe 1.78 13059.60 13061.38 13061.38 13061.38 TD 6 3/4" hole @ 13,067' MD / 3,193' TVD 13061.38 4-1/2" Shoe @ 13,061.38' MD / 3,193' TVD 13061.38 (Rathole 5.62') 13061.38 13061.38 Total Parts used: 13061.38 104 - 4-1/2"x 6.13" HydroFORM (#80549) Cent.. 13061.38 13061.38 Run 1 HydroFORM every jt. Floating on each joint 13061.38 JTS #1 - #104 13061.38 13061.38 Run torque rings from joint 74 thru 104 13061.38 Total of 31- 4-1/2" torque rings. 13061.38 13061.38 13061.38 13061.38 13061.38 13061.38 13061.38 13061.38 Remarks: 07-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-160 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,340.39' MD Window /Kickoff Survey 8,391.00' MD (if applicable) Projected Survey: 13,064.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~-~~~ Re: IJ-160 Update • Subject: Re: 1J-160 Update From: Thomas Maunder <tom_m~under(cv.admin.state.ak.us> Date: Fri, 16 Mar 2007 13:31:05 -000 To: "Hartwig, Deimis D" <Deruiis.D.Hartwig%rconocophillip~.cc~n~- Dennis, ~ ~ C~~ ` ~ ~ `~ This information is sufficient for 1J-160L1 and -L2. I will place a copy of this message in the files. In our call you indicated that 1J-176 has yet to be permitted. Nothing is needed for that well at this time. Call or message with any questions. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/16/2007 1:21 PM: Tom, I am covering the 1J-160 while Mike Greener is taking some much earned vacation. I thought I would update you on some current activities and forward plans on the 1J-160 being drilled by Doyon 15. As you already know, the West Sak A-Lateral;was. wet and thus the A-sand lateral will not be drilled. .. . Further, Both the B & D laterals-will be shortened by approximately 1500' (moved 1500' to the North). Shortening the laterals by 1500' allows for a much simpler Intermediate casing /cementing on the offset well to the South (1J-176). The new 1J-176 Intermediate will be landed approximately 1500' further North making it a much more feasible well. If shortening the 1J-160 B & D lateral requires any change to permitting etc... please contact me. Thanks and have a good weekend... Dennis Dennis Hartwig Drilling Engineer ', ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 1 of 1 3/16/2007 1:35 PM Re: 1J-160 status as of 3/13/07 Subject: Re: 1J-160 status as of 3/13/07 From: Thomas Maunder <tom maunder~i~admin.state.ak.us> Date: Tue, ] 3 Mar 2007 09:36:01 -0800 ~~~ - 'f~o: "( greener, Mihc EZ." ~ Mike.R:Gr~enrr~;u e~~nocophillip~.re111=- CC: "l~hr,n~as. IZ~~~n{~~ 1." ~Rand~~.l . I~hunrisucunocophillips.c~~m=. "llari~tii~~_ lhnni, D~~ <Dennis.D.Hartwig ~r canocophillips.cem>, Steve Davies ~~ steve_da~ ids ~i',~clmin.state.ak.us. Thanks Mike. Your plan should effect isolation from the water. This situation poses an interesting situation since this well was intended to be a tri-lateral and what would have been the motherbore penetration will essentially be plugged. In order to avoid what likely would be significant paperwork, it is probably best that the originally planned naming convention continue with 11-I60L1 in the B sand and 1J-160L2 in the D sand. 1J-160 still needs to be "on the books" since all lateral production is reported against the motherbore that has the -00- suffix in the API number. Lets all be aware of the situation on this well. It is probably appropriate to be sure that your other colleagues (especially Sharon) are aware of this well. Call or message with any questions. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 3/13/2007 9:19 AM: l_,ast night w-c li_nislled our drilling ofthe intermediate section fo~• this well. 'e drilled t0 a measured depth. of 10,271' tI ~" 3"~55' T' slur ~l~ is in the A? sand. `ale ~2 sand is wet. T'he D and sands are oil bearing. Cur plan f`c)r~~~ard is to set out• it~termecliat casing (t~-~/~") at ~, I5C1' 1I~, 3,30' T~:'L). ~l~he top ol'thed 13 sand. is at x,750' MD, 3,25' T4'1~. 'e ~~~ill cttt a window to access the 3 sand. F3~% setting our slue at x,150" MD we expect to isolate ant- water froze the: A2 Sand. :Mike. Greener «Greener, Mike R..vcf» 1 of 1 3/13/2007 9:37 AM • y~T ®~i ~r Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SAR~,e~ ~~L~~, oot/~R~o~ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907} 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-160L2 ConocoPhillips Alaska, Inc. Permit No: 207-017 Surface Location: 2016' FSL, 2541' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 96' FNL, 1842' FWL, SEC. 10, T l ON, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1J-160, Permit No 207-015, API No. 50-029-23344-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this G/ day of February, 2007 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSEF~VATION COMMISSI PERMIT TO DRILL ~-~~ 20 AAC 25.005 1! G® J~ ~'` ~ ~ 2007 1 a. Type of Work: 1 b. Current Well Class: Exploratory Development Oil ^ 1 c. SpfJ~~~~ fY i waps t$ p o~osed for: 5 t11IT1 3 Ofl '1 ~~ ~ ~~d ~ € • Drill Q ~ Re-drill ^ StratigraphicTest ^ Service ^~ Development Gas ^ ~ SH Btes Coal6 lsth G e^ - Re-entry ^ Multiple Zone^ Single Zone ^ R; ~ ~~I ~hale~Gasr~1 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-160L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14457' ND: 3173' - Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2016' FSL, 2541' FEL, Sec. 35, T11 N, R10E, UM ADL 25660 & 25663 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 791' FSL, 1738' FWL, Sec. 34, T11 N, R10E, UM ALK 470 & 472 2/28/2007 Total Depth: 9. Acres in Property: 14. Distance to /([QIiL,. ap~vi•eltorr ~ 96' FNLJ1842' FWL, Sec. 10, T10N, R10E, UM ' 2560 Nearest Property: 5a-mit~'jL7~a. ~.a~,o 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 558668 y- 5945827 ~ Zone- 4 (Height above GL): 28' RKB feet Well within Pool: f~pr+e , ~, ;/, 16. Deviated wells: Kickoff depth: 8273 ' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.os5) Maximum Hole Angle: g3° deg Downhole: 1472 psig Surface: 1112 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Si ca ons pec T B tt k ze om op o c. f. or sac s Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3226' 28' 28' 3226' 2135' 650 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9704' 28' 28' 9704'- 3472' ~ 790 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 6184' 8273' 3234' 14457' • 3173' 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 Dffpth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): ~ Perforation Depth TVD (ft): `~ 1 ~~ 20. Attachments: Filing Fee BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature \ '~~-emu- ~`"'-~,~~ ~ Phone .~ C S 6~ ~ ~, Date l ~2` ~U'7 ~- rl.. t P d b ha n All Drak Commission Use Only Permit to Drill ~ API Number: Q / ~~~~ / Permit Approval See cover letter i t Number: ~ ? " ~ ~ 50- V Z` ~ (p Date: ~ ~ ~ remen s for other requ Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas tes, or gas contained in shales: 5~~ ~..~- ~to~ Ca-OTC)\S~ Samples req'd: Yes ^ No ~ ud log req'd: Yes ^ No [.~ Other: ~~~,.~ S` ~Q ~ ~~~ ~~ C,~~ _ \H2S measures: Yes ~ nal svy req'd: Yes [v~ No ^ ,P ` ~~~JJJ ~j d ~ APPROVED BY THE COMMISSION DATE: r ,COMMISSIONER Form 10-401 Revised 12!2005 ~ ~.ar) t ~~ a } ~ ~ ` -` ~~ ~~ ~ Submit in Duplicate'~~a7 Ott .I ~~*G~.. ~ i•ai•o~ • App~n for Permit to Drill, Well 1J-160 L2 Revision No.0 Saved: 29-Jan-07 Permit It -West Sak Well #1J-160 L2 Application for Permit to Drill Document M+}ximiap XMeli Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ........................................Error! Bookmark not defined. Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c) (8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 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 1J-160L2 PERMIT IT Page 1 of 6 ,~"~~. ~~ ~ ~, ~ ~ ~ Pnnted:29-Jan-07 • Apn for Permit to Drill, Well 1J-160 L2 Revision No.0 Saved: 29-Jan-07 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-160 L2. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) 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: (2) a plat identifying the property and the propertys owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) 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 National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2 016' FSL, 2,541' FEL, Section 35, T11N R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,827 Eastings: 558,668 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak ~~D" Sand 791' FSL, 1,738' FWL, Section 34, T11N, R10E ASP Zone 4 NAD 27 Coordinates MeaSUred De th, RKB: 8,273 Northings: 5,944,556 Eastings: 552,399 Total Vertical De th, RKB: 3,233 Total Vertical De th, SS: 3,112 Location at Total De th 96' FNL, 1,842' FWL, Section 10, T10N R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 14,457 Northings: 5,938,390 Eastings: 552,557 Total Vertical De th, RKB: 3,173 Total Vertical De th, SS: 3,052 and (D) other information required by 20 AAC 25.050(b); 1J-160L2 PERMIT IT Page 2 of 6 Printed: 29-Jan-07 ..,~ ' App~n for Permit to Drill, Well 1 J-160 L2 Revision No.O Saved: 29-Jan-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-40i) must (i) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1J-160L2 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) 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 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: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak ~~D" sand formation is 1,112 psi, calculated thusly: , MPSP = (3,271 ft TVD)(0.45 - 0.11 psi/ft) = 1,112 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iJ-160L2 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 following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; The parent wellbore, iJ-160, will be completed with 9-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-160L2 PERMIT /T Page 3 of 6 Printed: 29-Jan-07 App~n for Permit to Drill, Well 1 J-160 L2 Revision No.O Saved: 29-Jan-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by ZO AAC 25.030, and a description of any slotted liner, pre- pertorated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in) (in) t (Ib/ft) Grade Connection ft (ft) (ft) Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 3,226 28 / 28 3,226 /2,135 650 sx ASLite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 5,300' 9-5/8 12-1/4 40 L-80 BTCM 9,704 28 / 28 9,704 / 3,472 MD / 2,561' TVD. Cemented w/ , , 790 sx DeepCRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 5,715 8,773 / 3,323 14,478 / 3,407 Slotted- no cement slotted Lateral (iJ-160) 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 5,803 8,663 / 3,309 14,466 / 3,249 Slotted- no cement Lateral(iJ-160 Ll) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 6,184 8,273 / 3,234 14,457 / 3,173 Slotted- no cement Slotted Lateral (1J-160 L2) Diverter System Information - ~-- Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on iJ-160 L2. 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 description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density ( ) 8.8 Plastic Viscostiy (Ib/100 sf7 15 - 25 Yield Point cP) 18 - 28 HTHP Fluid loss (ml/30 min 200psi & 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stability 650-900 1J-160L2 PERMIT IT Page 4 of 6 ~'° ~ ~~t a ~~~ ~: ~ Printed: 29-Jan-07 t ~ i ~:..~~ ~ t s:~ss • Apn for Permit to Drill, Well 1J-160 L2 Revision No.0 Saved: 29-Jan-07 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to 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: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the iJ-160 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 8,273' MD / 3,233' TVD, the top of the top of the D sand. 2. Mill 6-3/4"window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at +/- 14,457' MD / 3,173' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 1J-160L2 PERMIT IT Page 5 of 6 ;~, ~" y w ,~ ~ ~ ~ ~ Printed: 29-Jan-07 ~. , • App~n for Permit to Drill, Well 1 J-160 L2 Revision No.O Saved: 29-Jan-07 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH, laying down drill pipe as required. 12. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. - 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-160L2 PERMIT IT Page 6 of 6 Printed: 29-Jan-07 ~+^~ ~ y F.»~p f t u '"~ ti ~s, ,. • ~ ConocoPhillips Alaska Plan: 1J-160 L2 (wp06) Sperry Drilling Services Proposal Report -Geographic 26 January, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-160 Plan 1J-160 L2 Local Coordinate Origin: Centered on Well Plan 1J-160 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet Sperry Drilling Servic®~ HALL tBURTON Project: Kuparuk River Unit wb:LLDrTA1LS rlan a-uoL2 Site: Kuparuk 1J Pad GroutxlCzvel: 81.00 Sperry drilling Services Well: Plan 1 J-160 +,;/-s +1?/-w Northing eas6ng L~tiaatk Longituclc slot Wellbore: Plan 1J-160 L2 0.(10 0'0(1 '94'827.52 558668.60 70°15'45,361 N149°31'32.559W Plan: 1J-160 L2 (wp06) REFERENCE INFORMATION Co-0rdinate (N/E) Reference: Well Plan 1J-160, True North 1000 Vertical (TVD) Reference: Doyon 15 (40+g7) @ 121.OOft (Doyon 15 (40+81)) Measured Depth Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Calculation Method: Minimum Curvature 5(10 ° 0 I3 3/8" 0 r ~ t ~, ~ i , 25(1 ~ ~ \ 4 C 1J O ~ ~ G G \ -5(10 ~, ~ ~ ~ ~ SHL-2016'FSL, 2541'FHL-Scc35-TIIN-RIUL' 9 >/8" TOW ~ I ? 31x" ('.eg (r{ }7I T MD. 2153' TVD - 1988' k+SL, 74T FWL - Sec35-TIIN-RI OL[ -1000 3 ~5~ ~~ ~ L2: 9518"TOW (q R274'MU, 7274'TVD-791'I~SL, 1718'PWL-Scc34-TI IN-R1(11~: 9 5/8" TO W -1500 - ~ ~ L7: 9 5/8" TOW (<1 8(64' MD 3309' TVD - 419' I'SL, 1651' hWL - Scc34-TI IN-R I OG -200(1 -2500 ~ 9 5/tt^ -30011 _3500 c o N -~~ + -4500 C 0 -5(100 s 0 -5500 -60(10 L2: BI1L (r~ 144ST MD, 3175 TVD - 9(i fNL, 1842' I'WL - Scc I OTI(1N-R IOb; -6500 -7(1110 BHL (tu 14478'MD. 34(17TVD-9(; PN L, 1842'fWL-Su;10 -TIUN-8108 ~ 41/2" ,~' ___ _ T - - - _ ~ M Azimuths to True North 07 Magnetic North: 24.65° -750(1 ~ ` ~ Magnetic Field ` Strength:57552.4nT ' IJ-160 Ll (u3~06) ~ 1J-160 (wp06) t Dip Angle: 80.75' -8110(1 ~ Date: 11/18/2004 ~ , Model: BGGM2005 I7-160 L2 (wp06) _850(1 -9000 CASING DETAILS No MD TVD TVDss Nan1c Sizc `)500 l 14478.35 3407.01 3286.01 4112" 4-I/2 2 9704.44 3472.53 3351.53 9 5/R" 9-5/R 3 3317.26 2153.28 2032.28 13 3/R" 13-3/R -I(H)00 -7500 -7000 -6500 I -6000 -550(1 -5000 -4500 -4000 -3500 -300(1 -2500 I -2000 -1500 -1000 -500 0 SOU 1000 ~ ~~si~.1/~a~(+~ (1~.~5(1 ft/in) ~(( __ ~OfIOCOPI'liI~1~J5 Alaska '/ Halliburton Company C~Jf'~CK©~I~~15 Planning Report -Geographic iM~ ~~,t_~ ~I~iRT` ~p®rry ~ril'[ing Sertric~s µ~~ Database: Compass 2003.11' Local Co-ordinate Reference: Well Plan 1J-160 Company: ConocoPhillips Alaska, Ino. ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True - I Well: Pien 1J-160 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-160 L2 Design: 1J-160 L2 (wp06) Project Kuparuk River ~ ~~~ t Pdorth Slope Alasra. U nited 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-160 Well Position +N/-S 0.00 ft Northing: 5,945,827.52ft Latitude: 70° 15' 45.361" N +E/-W 0.00 ft Easting: 558,668.60ft ~ Longitude: 149° 31' 32.559" W Position Uncerta inty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore Plan 1J-160 L2 Magnetics Model Name Sampte Date Declination Dip Angle Field Strength bggm2005 8/8/2006 24.00 80.78 57,564 Design 1J-1f;rr L ~!w~F~06) Audit Notes: Version: Phase: PLAN Tie On Depth: 8,273.57 Vertical Section: Depth Frorn (ND) +NI-S +EI-W Direction (ft) (ft) lft) C') ~~ 40.00 0.00 0.00 180.00 1/26/2007 4:14:19PM Page 2 of 8 COMPASS 2003.11 Build 48 ~ • CcmocoP'h~tlps Alaska Halliburton Company Planning Report -Geographic Srperr~ Ctriliir~+g Services Database: Compass 2003.11 Company: ConocoPhillips Alaska. Inc. Project: I<uparuk River Unit Site: I<uparuk 1J Pad Well: Plan 1J-160 Wellbore: Plan 1J-160 L2 Design: 1J-160 L2 (wp06) Local Co-ordinate Reference: Well Plan 1J-160 TVD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) MD Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary `Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/_S +E/-W Rate Rate Rate TFO (ft) O (°) (ft) (ft) (ft) ('1100ft) (°1100it)' ("!100ftj ~~) 8,273.57 78.54 199.10 3,233.88 -1,222.64 -6,279.52 0.00 0.00 0.00 0.00 8,290.07 80.48 197.96 3,236.88 -1,238.02 -6,284.67 13.60 11.79 -6.89 -30.00 8,310.07 80.48 197.96 3,240.19 -1,256.79 -6,290.75 0.00 0.00 0.00 0.00 8,560.63 92.09 184.76 3,256.46 -1,501.00 -6,339.62 7.00 4.63 -5.27 -49.23 8,849.83 92.09 184.76 3,245.90 -1,789.01 -6,363.59 0.00 0.00 0.00 0.00 8,953.76 90.00 180.00 3,244.01 -1,892.80 -6,367.90 5.00 -2.01 -4.58 -113.67 9,180.55 85.21 175.16 3,253.48 -2,119.06 -6,358.35 3.00 -2.11 -2.13 -134.77 9,311.22 85.21 175.16 3,264.38 -2,248.80 -6,347.37 0.00 0.00 0.00 0.00 9,565.52 92.25 178.11 3,270.01 -2,502.42 -6,332.46 3.00 2.77 1.16 22.80 9,565.98 92.25 178.11 3,269.99 -2,502.88 -6,332.44 1.00 -0.24 -0.97 -103.99 10,355.52 92.25 178.11 3,239.01 -3,291.38 -6,306.36 0.00 0.00 0.00 0.00 10,638.55 89.42 178.08 3,234.89 -3,574.19 -6,296.95 1.00 -1.00 -0.01 -179.48 11,340.27 89.42 178.08 3,242.01 -4,275.48 -6,273.44 0.00 0.00 0.00 0.00 11,521.27 93.04 178.13 3,238.13 -4,456.31 -6,267.45 2.00 2.00 0.03 0.78 11,598.99 93.04 178.13 3,234.01 -4,533.88 -6,264.92 0.00 0.00 0.00 0.00 11,605.18 92.87 178.21 3,233.69 -4,540.06 -6,264.72 3.00 -2.73 1.24 155.57 11,989.62 92.87 178.21 3,214.44 -4,923.83 -6,252.70 0.00 0.00 0.00 0.00 12,090.75 89.84 178.04 3,212.05 -5,024.87 -6,249.39 3.00 -3.00 -0.16 -176.86 12,790.75 89.84 178.04 3,214.01 -5,724.45 -6,225.45 0.00 0.00 0.00 0.00 12,945.55 91.39 178.04 3,212.35 -5,879.15 -6,220.15 1.00 1.00 0.00 -0.09 13,289.92 91.39 178.04 3,204.01 -6,223.21 -6,208.36 0.00 0.00 0.00 0.00 13,370.44 92.19 178.14 3,201.50 -6,303.65 -6,205.68 1.00 0.99 0.13 7.42 13,671.57 92.19 178.14 3,190.01 -6,604.41 -6,195.92 0.00 0.00 0.00 0.00 13,772.85 91.17 178.10 3,187.04 -6,705.58 -6,192.60 1.00 -1.00 -0.05 -177.41 14,457.20 91.17 178.10 3,173.01 -7,389.41 -6,169.86 0.00 0.00 0.00 0.00 1/26/2007 4:14:19PM Page 3 of 8 COMPASS 2003.11 Build 48 ~~~~ r ~~ ~ ~' ` Halliburton Company a®e~~.~ "1">~7i f)C100 0 11 ~~5 ' Alaska Planning Report -Geog raphic Sperm Ciri tling Services Database: Compass 2003.11 Local Co-o rdinate Refer ence: Well Plan 1 J-160 Company: ConocoPhillips Al aska, Inc. TVD Refere nce: Doyon 15 ( 40+81) @ 121 .OOft (Doyon 15 (40+81)) ~~ Project: K uparuk River Un it MD Referen ce: Doyon 15 ( a0+81) @ 121 .OOft (Doyon 15 (40+81)) Site: K uparuk 1J Pad North Reference: True Well: .Pl an 1J-160 Survey Calculation Method: Minimum Curvature Wellbore: Pl an 1J-160 L2 Design: IJ -1(i0 L2 (wp06) Planned Survey 1J-160 L2 ( wp06) Map Map MD Inclination Azimuth TVb SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ff) ~~~ (~) (ft) (fti (ft) eft) (ft) (ft) (°I100ft) (ft1 8,273.57 78.54 199.10 3,233.88 3,112.88 -1,222.64 -6,279.52 5,944,556.11 552,399.41 0.00 1,222.64 L2: 9 5/8" TOW @ 8274' MD, 3234' TVD - 791' FSL, 1738' FWL - Sec34-T11 N-R10E - 9 5/8" TOW 8,273.77 78.54 199.10 3,233.92 3,112.92 -1,222.83 -6,279.58 5,944,555.93 552,399.35 0.00 1,222.83 1J-160 D Heel 1/19!07 8,290.07 80.48 197.96 3,236.88 3,115.88 -1,238.02 -6,284.67 5,944,540.69 552,394.38 13.77 1,238.02 8,296.87 80.48 197.96 3,238.01 3,117.01 -1,244.40 -6,286.74 5,944,534.30 552,392.36 0.00 1,244.40 1J-160 D CP01 10/27/06 8,300.00 80.48 197.96 3,238.52 3,117.52 -1,247.34 -6,287.69 5,944,531.35 552,391.43 0.00 1,247.34 8,310.07 80.48 197.96 3,240.19 3,119.19 -1,256.79 -6,290.75 5,944,521.88 552,388.45 0.00 1,256.79 8,400.00 84.62 193.17 3,251.85 3,130.85 -1,342.65 -6,314.66 5,944,435.85 552,365.22 7.00 1,342.65 8,500.00 89.27 187.93 3,257.18 3,136.17 -1,440.76 -6,332.92 5,944,337.61 552,347.72 7.00 1,440.76 8,560.63 92.09 184.76 3,256.46 3,135.46 -1,501.00 -6,339.62 5,944,277.32 552,341.49 7.00 1,501.00 8,600.00 92.09 184.76 3,255.02 3,134.02 -1,540.21 -6,342.88 5,944,238.09 552,338.53 0.00 1,540.21 8,700.00 92.09 184.76 3,251.37 3,130.37 -1,639.80 -6,351.17 5,944,138.45 552,331.02. 0.00 1,639.80 8,800.00 92.09 184.76 3,247.72 3,126.72 -1,739.38 -6,359.46 5,944,038.81 552,323.51 0.00 1,739.38 8,849.83 92.09 184.76 3,245.90 3,124.90 -1,789.01 -6,363.59 5,943,989.16 552,319.76 0.00 1,789.01 8,900.00 91.08 182.46 3,244.51 3,123.51 -1,839.06 -6,366.75 5,943,939.10 552,317.00 5.00 1,839.06 8,953.76 90.00 180.00 3,244.01 3,123.01 -1,892.80 -6,367.90 5,943,885.35 552,316.26 5.00 1,892.80 1J-160 D CP02 10/27/06 9,000.00 89.02 179.02 3,244.40 3,123.40 -1,939.03 -6,367.51 5,943,839.13 552,317.02 3.00 1,939.03 9,100.00 86.91 176.88 3,247.95 3,126.95 -2,038.89 -6,363.93 5,943,739.31 552,321.37 3.00 2,038.89 9,180.55 85.21 175.16 3,253.48 3,132.48 -2,119.06 -6,358.35 5,943,659.20 552,327.57 3.00 2,119.06 9,200.00 85.21 175.16 3,255.10 3,134.10 -2,138.37 -6,356.72 5,943,639.90 552,329.36 0.00 2,138.37 9,300.00 85.21 175.16 3,263.45 3,142.44 -2,237.66 -6,348.31 5,943,540.69 552,338.54 0.00 2,237.66 9,311.22 85.21 175.16 3,264.38 3,143.38 -2,248.80 -6,347.37 5,943,529.55 552,339.57 0.00 2,248.80 9,400.00 87.67 176.19 3,269.89 3,148.89 -2,337.15 -6,340.68 5,943,441.27 552,346.94 3.00 2,337.15 9,500.00 90.44 177.35 3,271.54 3,150.54 -2,436.97 -6,335.05 5,943,341.51 552,353.35 3.00 2,436.97 9,565.52 92.25 178.11 3,270.01 3,149.01 -2,502.42 -6,332.46 5,943,276.09 552,356.45 3.00 2,502.42 1J-160 D CP03 10!27/06 9,565.98 92.25 178.11 3,269.99 3,148.99 -2,502.88 -6,332.44 5,943,275.63 552,356.47 1.00 2,502.88 9,600.00 92.25 178.11 3,268.65 3,147.65 -2,536.85 -6,331.32 5,943,241.67 552,357.86 0.00 2,536.85 9,700.00 92.25 178.11 3,264.73 3,143.73 -2,636.72 -6,328.02 5,943,141.84 552,361.94 0.00 2,636.72 9,800.00 92.25 178.11 3,260.81 3,139.81 -2,736.59 -6,324.71 5,943,042.01 552,366.02 0.00 2,736.59 9,900.00 92.25 178.11 3,256.88 3,135.88 -2,836.46 -6,321.41 5,942,942.18 552,370.10 0.00 2,836.46 10,000.00 92.25 178.11 3,252.96 3,131.96 -2,936.32 -6,318.11 5,942,842.35 552,374.18 0.00 2,936.32 10,100.00 92.25 178.11 3,249.03 3,128.03 -3,036.19 -6,314.80 5,942,742.52 552,378.26 0.00 3,036.19 10,200.00 92.25 178.11 3,245.11 3,124.11 -3,136.06 -6,311.50 5,942,642.69 552,382.34 0.00 3,136.06 10,300.00 92.25 178.11 3,241.19 3,120.19 -3,235.93 -6,308.20 5,942,542.86 552,386.42 0.00 3,235.93 10,355.52 92.25 178.11 3,239.01 3,118.01 -3,291.38 -6,306.36 5,942,487.43 552,388.69 0.00 3,291.38 1J-160 D CP04 10/27/06 10,400.00 91.80 178.10 3,237.43 3,116.43 -3,335.80 -6,304.89 5,942,443.02 552,390.51 1.00 3,335.80 10,500.00 90.80 178.09 3,235.16 3,114.16 -3,435.72 -6,301.57 5,942,343.14 552,394.60 1.00 3,435.72 10,600.00 89.80 178.08 3,234.63 3,113.63 -3,535.66 -6,298.24 5,942,243.24 552,398.72 1.00 3,535.66 10,638.55 89.42 178.08 3,234.89 3,113.89 -3,574.19 -6,296.95 5,942,204.73 552,400.31 1.00 3,574.19 10,700.00 89.42 178.08 3,235.51 3,114.51 -3,635.60 -6,294.89 5,942,143.34 552,402.85 0.00 3,635.60 1/26/2007 4:14:19PM Page 4 of 8 COMPASS 2003.11 Build 48 b Cc~ru~c~I~illips Aias4ca • Halliburton Company Planning Report -Geographic HA~..~~E~URTt'~ Sperry Drihing Services Database: Company: i Project: i Site: Well: Wellborei Design: Compass 2003.11 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 L2 1 J-160 L2' (wp06) Local Co-ordinate Reference:. Well Plan 1J-160 ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature .Planned Survey 1J-160 L ,.dpOF) Map Map MD Inclination Azimuth ND SSND +NI-S +E/-W Northing Eastin9 DLSEV Vert Section (ft) ~~) (~) (ft) Ift) (ft1 (ft) (ft) lft) (°1100ft) (1t) 10,800.00 89.42 178.08 3,236.53 3,115.53 -3,735.54 -6,291.54 5,942,043.44 552,406.98 0.00 3,735.54 10,900.00 89.42 178.08 3,237.54 3,116.54 -3,835.48 -6,288.19 5,941,943.54 552,411.10 0.00 3,835.48 11,000.00 89.42 178.08 3,238.55 3,117.55 -3,935.42 -6,284.84 5,941,843.64 552,415.23 0.00 3,935.42 11,100.00 89.42 178.08 3,239.57 3,118.57 -4,035.36 -6,281.49 5,941,743.74 552,419.36 0.00 4,035.36 11,200.00 89.42 178.08 3,240.58 3,119.58 -4,135.30 -6,278.14 5,941,643.84 552,423.49 0.00 4,135.30 11,300.00 89.42 178.08 3,241.60 3,120.60 -4,235.24 -6,274.78 5,941,543.94 552,427.62 0.00 4,235.24 11,340.27 89.42 178.08 3,242.01 3,121.01 -4,275.48 -6,273.44 5,941,503.71 552,429.28 0.00 4,275.48 1J-160 D CP05 10/27!06 11,400.00 90.61 178.10 3,241.99 3,120.99 -4,335.18 -6,271.44 5,941,444.04 552,431.74 2.00 4,335.18 11,500.00 92.61 178.12 3,239.17 3,118.17 -4,435.08 -6,268.15 5,941,344.18 552,435.81 2.00 4,435.08 11,521.27 93.04 178.13 3,238.13 3,117.13 -4,456.31 -6,267.45 5,941,322.95 552,436.67 2.00 4,456.31 11,598.99 93.04 178.13 3,234.01 3,113.01 -4,533.88 -6,264.92 5,941,245.41 552,439.81 0.00 4,533.88 1J-160 D CP06 10/27/06 11,600.00 93.01 178.14 3,233.95 3,112.95 -4,534.89 -6,264.89 5,941,244.41 .552,439.85 3.00 4,534.89 11,605.18 92.87 178.21 3,233.69 3,112.69 -4,540.06 -6,264.72 5,941,239.24 552,440.06 3.00 4,540.06 11,700.00 92.87 178.21 3,228.94 3,107.94 -4,634.71 -6,261.76 5,941,144.62 552,443.76 0.00 4,634.71 11,800.00 92.87 178.21 3,223.93 3,102.93 -4,734.54 -6,258.63 5,941,044.83 552,447.66 0.00 4,734.54 11,900.00 92.87 178.21 3,218.93 3,097.93 -4,834.36 -6,255.50 5,940,945.04 552,451.56 0.00 4,834.36 11,989.62 92.87 178.21 3,214.44 3,093.44 -4,923.83 -6,252.70 5,940,855.61 552,455.06 0.00 4,923.83 12,000.00 92.56 178.19 3,213.95 3,092.95 -4,934.19 -6,252.37 5,940,845.25 552,455.47 3.00 4,934.19 12,090.75 89.84 178.04 3,212.05 3,091.05 -5,024.87 -6,249.39 5,940,754.61 552,459.16 3.00 5,024.87 12,100.00 89.84 178.04 3,212.08 3,091.08 -5,034.11 -6,249.07 5,940,745.37 552,459.55 0.00 5,034.11 12,200.00 89.84 178.04 3,212.36 3,091.36 -5,134.05 -6,245.65 5,940,645.47 552,463.75 0.00 5,134.05 12,300.00 89.84 178.04 3,212.64 3,091.64 -5,233.99 -6,242.23 5,940,545.57 552,467.95 0.00 5,233.99 12,400.00 89.84 178.04 3,212.92 3,091.92 -5,333.93 -6,238.81 5,940,445.67 552,472.14 0.00 5,333.93 12,500.00 89.84 178.04 3,213.19 3,092.19 -5,433.87 -6,235.39 5,940,345.77 552,476.34 0.00 5,433.87 12,600.00 89.84 178.04 3,213.47 3,092.47 -5,533.81 -6,231.97 5,940,245.86 552,480.54 0.00 5,533.81 12,700.00 89.84 178.04 3,213.75 3,092.75 -5,633.75 -6,228.55 5,940,145.96 552,484.74 0.00 5,633.75 12,790.75 89.84 178.04 3,214.01 3,093.01 -5,724.45 -6,225.45 5,940,055.30 552,488.55 0.00 5,724.45 1J-160 D CP08 10/27/06 12,800.00 89.93 178.04 3,214.02 3,093.02 -5,733.70 -6,225.13 5,940,046.06 552,488.94 1.00 5,733.70 12,900.00 90.93 178.04 3,213.27 3,092.27 -5,833.63 -6,221.71 5,939,946.16 552,493.14 1.00 5,833.63 12,945.55 91.39 178.04 3,212.35 3,091.35 -5,879.15 -6,220.15 5,939,900.67 552,495.05 1.00 5,879.15 13,000.00 91.39 178.04 3,211.03 3,090.03 -5,933.55 -6,218.29 5,939,846.29 552,497.34 0.00 5,933.55 13,100.00 91.39 178.04 3,208.61 3,087.61 -6,033.46 -6,214.86 5,939,746.41 552,501.54 0.00 6,033.46 13,200.00 91.39 178.04 3,206.18 3,085.18 -6,133.37 -6,211.44 5,939,646.54 552,505.74 0.00 6,133.37 13,289.92 91.39 178.04 3,204.01 3,083.01 -6,223.21 -6,208.36 5,939,556.74 552,509.52 0.00 6,223.21 1J-160 D CP09 10/27/06 13,300.00 91.49 178.05 3,203.75 3,082.75 -6,233.29 -6,208.02 5,939,546.67 552,509.94 1.00 6,233.29 13,370.44 92.19 178.14 3,201.50 3,080.49 -6,303.65 -6,205.68 5,939,476.33 552,512.83 1.00 6,303.65 13,400.00 92.19 178.14 3,200.37 3,079.37 -6,333.17 -6,204.72 5,939,446.82 552,514.02 0.00 6,333.17 13,500.00 92.19 178.14 3,196.55 3,075.55 -6,433.05 -6,201.48 5,939,346.98 552,518.04 0.00 6,433.05 13,600.00 92.19 178.14 3,192.74 3,071.74 -6,532.92 -6,198.24 5,939,247.15 552,522.05 0.00 6,532.92 13,671.57 92.19 178.14 3,190.01 3,069.01 -6,604.41 -6,195.92 5,939,175.69 552,524.93 0.00 6,604.41 1J-160 D CP10 10!27/06 13,700.00 91.90 178.13 3,188.99 3,067.99 -6,632.80 -6,195.00 5,939,147.31 552,526.08 1.00 6,632.80 1/26/2007 4:14:19PM Page 5 of 8 COMPASS 2003.11 Build 48 ~~~ 'rM' COYtOCQPf'1~~I1pS Alaska Halliburton Company Planning Report -Geographic • i-~i -~..La ~3~TC31l S~Serry Qriliing Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-160 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: ' Plan 1J-160 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-160 L2 Design: ~~ 1J-160 L2 (wp06) Planned Survey 1J-160 12 (wp06) Map Map Mb Inclination Azimuth TVD SSTVD +Nl-S +E/_yy Northing Fasting DLSEV Vert Section (ftl (~) (°) Ift? Ift) (ft) (ft) 1ftl (ft) (°I100ft1 (ftl 13,772.85 91.17 178.10 3,187.04 3,066.04 -6,705.58 -6,192.60 5,939,074.55 552,529.04 1.00 6,705.58 13,800.00 91.17 178.10 3,186.48 3,065.48 -6,732.71 -6,191.69 5,939,047.43 552,530.15 0.00 6,732.71 13,900.00 91.17 178.10 3,184.43 3,063.43 -6,832.64 -6,188.37 5,938,947.55 552,534.25 0.00 6,832.64 14,000.00 91.17 178.10 3,182.38 3,061.38 -6,932.56 -6,185.05 5,938,847.66 552,538.35 0.00 6,932.56 14,100.00 91.17 178.10 3,180.33 3,059.33 -7,032.48 -6,181.73 5,938,747.78 552,542.45 0.00 7,032.48 14,200.00 91.17 178.10 3,178.28 3,057.28 -7,132.41 -6,178.41 5,938,647.89 552,546.55 0.00 7,132.41 14,300.00 91.17 178.10 3,176.23 3,055.23 -7,232.33 -6,175.08 5,938,548.01 552,550.65 0.00 7,232.33 14,400.00 91.17 178.10 3,174.18 3,053.18 -7,332.25 -6,171.76 5,938,448.12 552,554.75 0.00 7,332.25 14,457.04 91.17 178.10 3,173.01 3,052.01 -7,389.25 -6,169.87 5,938,391.15 552,557.09 0.00 7,389.25 L2: BHL @ 14457' MD, 3173' TVD - 96' FNL, 1842' FWL - S ec10-T10N-R10E - 4 112" 14,457.20 91.17 178.10 3,173.01 3,052.01 -7,389.41 -6,169.86 5,938,390.99 552,557.10 0.00 7,389.41 1 J-160 D Toe 10/27!06 1/26/2007 4:14:19PM Page 6 of8 COMPASS 2003.11 Build 48 ~"E ~ A ;~' Cot~ocoi[lips Alaska Halliburton Company Planning Report -Geographic ~~Ir~~~~3~RT Sperry C.iriitirtg Services Database: Compass 2003.11 Local Co-ordinate Reference: .Well Plan 1J-160 Company: ConocoPhillips Alaska. Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: " Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Sitc: Kuparuk 1J Pad North Reference: True Wcll: Plan 1J-160 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-160 L2 Design: 1J-160 L2 (wp06) Geologic Targets Plan 1J-160 L2 TVD Target Name +N/-S +EI-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,219.00 1J-160 D_Top 10/27/06 -1,154.00 -6,375.33 5,944,624.00 552,303.08 - Point 3,238.01 1J-160 D_CP01 10/27/06 -1,629.04 -6,362.03 5,944,149.12 552,320.08 - Polygon Point 1 0.00 0.00 5,944,149.12 552,320.08 Point 2 -263.77 8.93 5,943,885.45 552,331.06 3,233.92 1J-160 D_Heel 1/19/07 -1,222.82 -6,279.58 5,944,555.94 552,399.35 - Polygon Point 1 0.00 0.00 5,944,555.94 552,399.35 Point2 -406.35 -82.53 5,944,149.00 552,320.00 3,228.00 1J-160 D_Top 1/19/07 -1,195.36 -6,269.83 5,944,583.47 552,408.89 - Point 3,173.01 1J-160 D_Toe 10/27/06 -7,389.41 -6,169.86 5,938,390.99 552,557.10 - Point 3,214.01 1J-160 D_CP08 10/27/06 -5,724.45 -6,225.45 5,940,055.30 552,488.55 -Polygon Point 1 0.00 0.00 5,940,055.30 552,488.55 Point 2 -498.76 17.09 5,939,556.74 552,509.52 3,242.01 1J-160 D_CP05 10/27/06 -4,275.48 -6,273.44 5,941,503.71 552,429.28 - Polygon Point 1 0.00 0.00 5,941,503.71 552,429.28 Point 2 -258.40 8.52 5,941,245.41 552,439.81 3,270.01 1J-160 D_CP03 10/27/06 -2,502.42 -6,332.46 5,943,276.09 552,356.45 -Polygon Point 1 0.00 0.00 5,943,276.09 552,356.45 Point 2 -788.96 26.10 5,942,487.43 552,388.69 3,204.01 1J-160 D_CP09 10/27/06 -6,223.21 -6,208.36 5,939,556.74 552,509.52 - Polygon Point 1 0.00 0.00 5,939,556.74 552,509.52 Point 2 -381.20 12.44 5,939,175.69 552,524.93 3,212.01 1J-160 D_CP07 10/27/06 -5,025.33 -6,248.71 5,940,754.15 552,459.84 - Polygon Point 1 0.00 0.00 5,940,754.15 552,459.84 Point 2 -699.12 23.27 5,940,055.30 552,488.55 3,234.01 1J-160 D_CP06 10/27/06 -4,533.88 -6,264.92 5,941,245.41 552,439.81 - Polygon Point 1 0.00 0.00 5,941,245.41 552,439.81 Point 2 -491.45 16.20 5,940,754.15 552,459.84 3,244.01 1J-160 D_CPOZ 10/27/06 -1,892.82 -6,353.10 5,943,885.45 552,331.06 -Point 3,190.01 1J-160 D_CP10 10/27/06 -6,604.41 -6,195.92 5,939,175.69 552,524.93 - Polygon Point 1 0.00 0.00 5,939,175.69 552,524.93 Point 2 -785.00 26.06 5 938 390.99 552 557.10 1/26/2007 4: 14:19PM Page 7 of 8 COMPASS 2003.11 Build 48 . '~ ~ , • Ccfr~col~itlps Alaska • Halliburton Company Planning Report -Geographic ~,~,l~..L.~tE3UT Sperry Driliir+g Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-160 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-160 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-160 L2 Design: 1J-160 L2 (wp06) 3,239.01 1J-160 D_CP04 10/27/06 -3,291.38 -6,306.36 5,942,487.43 552,388.69 - Polygon Point 1 0.00 0.00 5,942,487.43 552,388.69 Point 2 -984.10 32.93 5,941,503.71 552,429.28 r-- Prognosed Casing Points - Measured Vertical Casing Hole Depth Depth Diameter Diameter eft) eft) (~~) (") 3,317.26 2,153.28 13-318 16 8,273.59 3,233.88 9-518 12-1/4 14,457.04 3,173.01 4-1 /2 6-314 Prognosed Fomration Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +EI-W N {ft) (') (°) (ft) (ft) (ft) ame 1,667.19 47.14 267.00 1,525.76 -26.12 -498.36 Pfrost 1,856.80 50.93 267.67 1,651.58 -32.96 -639.99 T3 2,423.51 67.82 269.98 1,939.25 -42.06 -1,125.76 K15 3,317.26 78.11 271.11 2,153.28 -28.39 -1,992.03 Casing Pt 5,863.51 78.11 271.11 2,678.05 19.98 -4,483.15 Ugnu C 6,672.60 75.95 247.57 2,861.21 -115.83 -5,253.24 Ugnu B 6,925.75 75.73 239.74 2,923.21 -224.64 -5,473.03 Ugnu A 7,595.32 76.38 219.05 3,086.20 -645.11 -5,963.32 K 13 8,244.03 78.50 200.00 3,228.00 -1,195.36 -6,269.83 W Sak D Plan Annotations Measured Vertical Local Coor dinates Depth Depth +N/-S +E/-W Comment (ft) (ft) (ft) (~) 8,273.59 3,233.88 -1,222.66 -6,279.52 L2: 9 5/8" TOW @ 8274' MD, 3234' ND - 791' FSL, 1738' FWL - Sec34-T111 14,457.04 3,173.01 -7,389.25 -6,169.87 L2: BHL @ 14457' MD, 3173' TVD - 96' FNL, 1842' FWL - Sec10-T10N-R10E 1/26/2007 4:14:19PM Page 8 of 8 COMPASS 2003.11 Build 48 • ~ ConocoPhillips Alaska Plan: 1J-160 L2 (wp06) Sperry Drilling Services Anticollision Summary 26 January, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-160 Plan 1J-160 L2 Local Coordinate Origin: Centered on Well Plan 1J-160 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet Sperry Qriiiing Services ~. _~ ~~ SURVEY PROGRAM Date: 2007-01-19700:00:00 Validated: Yes Version: Depth FromDepth To Survey/Plan 'Pool X0.00 1000.00 C'B-CYRO-SS 1000.00 3929.01 MR'D+IFR-AK-CA~SC 3929.01 8273.57 M1V1}+IFR-Ali-CA~SC 8273.57 1.1456.97 IJ-160 L2 (wp06) MW'D 1J-160 (wp06) 0 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 8273.57 To 14457.045001! Maximum Range:1641.70449215573 Reference: Plan: 1J-160 L2(wp06) 1J-160 (wp06) 1J-160 L1 (wp06) 1J-160 L1 (tn 270 1J-174 (wp0 180 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation (150 fl in ~ NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-160 Ground Level: 0.00 +N/-S+E/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 5945827.52 558668.60 70°15'45.361N 149°31'32.565W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-160, True North Vertical (TVD) Reference: Doyon 15 (40+g1) @ 121.00([ (Doyon 15 (40+81)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Doyon 15(40+g1) @ 121.OOft (Doyon 15(40+81)) Calculation Method: Minimum Curvature COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 50 From Colour To MD 0 8000 8000 8500 8500 9000 9000 9500 9500 10000 loooo - 11000 11000 12000 12000 ---` 1300D 13000 14000 14000 0 180 90 Travelling Cylinder Azium[h (TFO+ALI) ~°) vs Centre to Cen[re Separation )SU ft/ink SECTION DETAILS Sec MD Aa ND ~W-S ~EI~W DLe9 TFace VSec Target 82]35) )854 199.09 323)92 -122280 -fi2]9.10 0.00 000 122280 2 8290.0) 80.d9 19]95 32]6.92 ~12J8.19 -fi281.53 13.60 3000 1238.19 3 BJ100) BO.d9 19]95 )24023 -125695 -629061 000 000 1256.95 BSfi029 9209 184.]9 3256 d) -1500.82 -63J94fi )00 49.15 150082 5 884915 9209 184.)9 324592 -1]88.48 -fiJ6354 000 000 1]8848 fi 895361 9000 160.00 3244.01 -1892.80 -635]90 500 -113.5] 1892.60 1J-160 D_CP02 1021:06 9182.08 65.19 1]5.11 3253.W -2120.]3 -6358.19 3.00 -134.63 2120]3 8 9309.]2 85.19 1]511 326430 -224]45 634]35 000 0.00 224145 95653] 92.25 1)B 11 32]0 Ot -250240 -BJ32.26 2;06 250240 1 11160 D_CPOJ 1012J~06 0 956593 92.25 1)811 3269.99 -2502.66 -6)32.24 -103.98 250286 11 10355.3] 92.25 1]611 3239.01 -)29136 -6)0616 0.00 0.00 3291.]6 1J-160 D CP04 10/2106 12 1063839 8942 1)808 )23489 -35)4.1) -6296.]5 1.00 -1]946 35)4.1) _ 13 11340.12 8042 1)8.08 )24201 -42]54) -62]324 0.00 0.00 42]54) 1411521.12 9304 1)8.13 J2J8.13 -0456.]0 -62fi]25 2.00 0]B 445630 1J-160 D_CP051012]106 IS 1159884 93.04 1]8.13 323401 4533 B6 ~6264.>2 0.00 0.00 d53386 1J-160 D_CPO6 10/2)/Ofi 16 1160503 928] 1]8.21 323369 -054004 626452 3.00 155.5] 454004 1] 1198946 928] 1]8.21 3214.44 492381 625250 0.00 0.00 4923.81 1812090 fi0 8984 1]8.04 321205 -502485 -6249.19 300 -1]68fi 5024.85 19 12]9060 69.84 1]804 321401 5]2444 6225.25 0.00 0.00 5)2444 2012945.39 91.39 1]604 321235 58]9.13 6219.95 1.00 -0.09 58)9.13 1J-160 D_CPO610/2]/06 21 13289.]6 91.39 1]8.04 320401 ~622J.19 -6208.16 0.00 0.00 622).19 32 133]029 92.19 1)814 320150 -630363 -6205.48 100 ]42 630363 iJ-160 D_CP091012]106 23136)142 92.19 t)8 t4 ]19p Ot {40439 -6195.]2 000 000 660439 1J-160 D_CP101012)/O6 24 1]])2.]0 91.1) 1)B t0 J18T04 -6]05.5) -619240 100 -1]]41 6]055] 25 1445]05 91.1] 1)8.10 ]1)301 -)38939 -6169.66 0.00 0.00 ]389.39 1J-160D Toe 1d2]I06 r ~OI'1QCQ~11~~1~5 Alaska Halliburton Company Anticollision Report [-~ll.,~+.~..t..1 ~ t.1C3 Sperry Drilling Seir•vices Company: ConocoPhillipsAlaska, Inc. Local Co-ordinate Reference: Well Plan 1J-160 Project: Kuparuk River Unit TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Reference Sito: Kuparuk 1J Pad MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-160 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma ' Reference Wellbore Plan 1J-160 L2 Database: Compass 2003.11 Reference Design: 1J-160 L2 (wp06) Offset TVD Reference: Offset Datum Reference 4J-'Ir~O L2 iwpOr3i Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 8,273.57 to 14,457.05ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,641.70ft Error Surface: Elliptical Conic Warning Levels eva luated at: 0.00 Sigma Survey Tool Program Date 1%%5x2007 From To (ft) (ft) Survey (Wellbore) 40.00 1,000.00 1J-160 (wp06) (Plan 1J-160) 1,000.00 3,929.01 1J-160 (wp06) (Plan 1J-160) 3,929.01 8,273.57 1J-160 (wp06) (Plan 1J-160) 8,273.57 14,456.97 1J-160 L2 (wp06) (Plan 1J-160 L2) CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/26/2007 1:38:54PM Page 2 of 3 COMPASS 2003. i 1 Build 48 y '~ t p ~ _:. ~' Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD -Standard Cor~C ~"1I~~1~5 Alaska Halliburton Company H,Al..L~I~.r~R"~"~li~ Anticollision Report Sperry Driiiirsg ~®rvices Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-160 Project: Kuparuk River Unit ND Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Reference Site: Kuparuk 1J Pad MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-160 Survey Calculation Method: Minimum Curvature Well Error: O.OOft' Output errors are at 2.00 sigma Reference Wellbore Flan 1J-160 L2 Database: Compass 2003.11 Reference Design: 1J-160 L2 (wp06) Offset TVD Reference: Offset Datum Summary Site Name Offset Well -Wellbore -Design Kuparuk 1J Pad 1J-109 - 1J-109 - 1J-109 1J-152 - 1J-152 - 1J-152 1J-152 - 1J-152 L1 - 1J-152 L1 1 J-152 - 1 J-152 L2 - 1 J-152 L2 1J-152 - 1J-152 PB2 - 1J-152 PB2 1J-154 - 1J-154 - 1J-154 1J-154 - 1J-154 L1 - 1J-154 L1 1J-154 - 1J-154 L2 - 1J-154 L2 1J-156 - 1J-156 - 1J-156 1J-156 - 1J-156L1 - 1J-156L1 1J-156 - 1J-156L1PB1 - 1J-156L1PB1 1J-156 - 1J-156L2 - 1J-156L2 1 J-159 - 1 J-159 - 1 J-159 1J-159 - 1J-159 L1 - 1J-159 L1 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 1 J-159 - 1 J-159 L2 - 1 J-159 L2 1J-159 - 1J-159 PB1 - 1J-159 PB1 Plan 1 J-105 - 1 J-105 - 1 J-105 (wp03) Plan 1J-105 - 1J-105 L1 - 1J-105 L1 (wp03) Plan 1J-105 - 1J-105 L2 - 1J-105 L2 (wp03) Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp03) Plan 1J-107 -Plan 1J-107 L1 - 1J-107 L1 (wp03) Plan 1J-107 -Plan 1J-107 L2 (wp03) - 1J-107 L2 i Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Plan 1J-158 - 1J-158 - 1J-158 (wp06) Plan 1J-158 - 1J-158 L1 - 1J-158 L1 (wp06) Plan 1J-158 - 1J-158 L2 - 1J-158 L2 (wp06) Plan 1J-160 -Plan 1J-160 - 1J-160 (wp06) Plan 1J-160 -Plan 1J-160 L1 - 1J-160 L1 (wp06) Plan 1J-162 - 1J-162 - 1J-162 (wp05) Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) Plan 1J-174 (01 Phase 2) - 1J-174 - 1J-174 (wp0 Plan 1J-174 (01 Phase 2) - 1J-174 L1 - 1J-174 L1 Plan 1J-176 (Q2 Phase 2) - 1J-176 - 1J-176 (wp0: Plan 1J-176 (Q2 Phase 2) - 1J-176 L1 - 1J-176 L1 Rig: 1J-103 - 1J-103 - 1J-103 Rig: 1 J-103 - 1 J-103 L1 - 1 J-103 L1 Rig: 1J-103 - 1J-103 L1 PB1 - 1J-103 L1 (wp10) Rig: 1 J-103 - 1 J-103 L2 - 1 J-103 L2 Rig: 1 J-103 - 1 J-103 L2 - 1 J-103 L2 Pilot Toe (wp Rig: 1 J-103 - 1 J-103 L2 Pilot Toe - 1 J-103 L2 Pilo Rig: 1J-103 - 1J-103PB3 - 1J-103PB3 Reference Offset Centre to No•Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ff) Ift) (ff) (ft) Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 8,600.02 7,900.00 1,424.83 ~ 122.16 1,302.67 Pass -Major Risk 8,605.72 7,900.00 1,413.00 ' 121.24 1,291.76 Pass -Major Risk 13,521.59 12,650.00 1,641.20 ~ 458.92 1,182.28 Pass -Major Risk 8,275.00 8,275.00 0.00 0.47 -0.47 FAIL - No Errors 8,275.00 8,275.00 0.00 0.68 -0.68 FAIL - No Errors 8,926.59 10,299.98 1,580.71 123.53 1,457.18 Pass -Major Risk 8,279.66 9,025.00 1,557.94 145.51 1,412.43 Pass -Major Risk 8,279.66 9,025.00 1,557.94: 145,51 1,412.43 Pass -Major Risk 13,524.96 10,275.00 426.96 265.80 161.16 Pass -Major Risk 13,524.96 10,275.00 426.96 265.89 161.07 Pass -Major Risk 14,457.05 10,425.00 330.56 0.73 329.83 Pass -Minor 1/200 14,457.05 10,425.00 330.56 0.68 329.88 Pass -Minor 1/200 Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/26/2007 1:38:54PM Page 3 of 3 COMPASS 2003.11 Build 48 C7 • TRANSMITTALS LpETTER CHECKLIST WELL NAME ~~/C. ~ ~ •d '" ~~~ L• Z-' PTD# ~-~ ? ^- C~ ~ Development / Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new w ellbore segment of existing T - well F~~ ~1I '' ~~p~ , (If last two digits in permit No. L' - 2.3 _ a~ ~ "~~ ,API No. 50- API number are ~ between 60-69) 'Production should continue to be reported as a function of the original API number stated above. ~ PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent ~ upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after ~Compan NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1 /25/06 C:~jody\transmittat_checklist C7 • ~_~o N mp a~ a , y ~ , ~ ~ ~o . , p „ c ~Q o ~ ; : ~ , ~. ~ ~ 3 c v m, , j N J• ~ ~ D: O C ~ ~ ~ ~ ~ ~ ~ ~ O. ~ c, ~ ~ ~ ~ ~ ~~ ~ a U N LLl ~ O .~ C' n ~ , ~ : ~ ~ ~ ~ ~ ~ p: ~, ~ ~ ~ ~~ o N y, ~, v. ~ ~ ~ ~, ~ ~ . ~~ a, m c , o' I- y. N, m' a~: fl, y' ~, ~ c c' ~ m . ~ n m ui ~, a c m m 4 E' o, , a O V~ N. ~ ~~ C. C• ~ ~ ~ ~ ~ ~ y. ~ ~ ~ y, ~ ~ W, ~ ~, ~ N L, a ~ : o Q' ~~ c~ >; a a ~ ~~ a~' ~ ~~ ~ ~ ~ ~ o~~ ~ ~ ~ ~ Q. ~ ~~~ ~ ~~ a. a~ y ~ 1 ~~ 3 r a ~ a' m' .O~ X• ~~ m a~' m p, ~ ~ _, ~ ~ M. ~ ~ ~ ~ ~ ~ ~ U. ~ ~ G ~ ~ ~~ ~~ '3, O. -O~ ~ a~ , 3 ~ ' O C N C' 0, > 'f..b Q ~ ~ 'a. ~ ~ ~ C, ~~ ~ a '~ ~~ ~ p, . 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W a _ ~ ~- N M V ~ CO f~ W O O ~ ~ ~ ~ ~ ~~ ~ r- N ~~ N N N M N ~ N ~ CO N N I~ W N N O O .- N M M N M V M M M ~ O M M ~ W M M O M p V _ _.___._. ____.-__. ____..._ __. ____ _. ___ __. ___._.__~ ______ _.- _ - ~ U ++ ~ N r ~ O ~ ~ w N V C O w C • N O M '', ~ lC ~ N il'I ~ ~ f6 ~ O O y O 0 ~ . C . N ., M .-- p '~ a N ~ ~ ~ ~ ~ ~ Q E W o E a. o ', ~ a. ~ i ~ Q. ~ U ~ ~ a a ~ W a ~ ~ a~ a . • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plrfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1J160L200403200755N.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Fri May 25 17:03:16 2007 Reel Header Service name .............LISTPE Date . ...................07/05/25 Ori in ...................5T5 Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/25 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 Job NUMBER: w-0004877337 LOGGING ENGINEER: T. MCGUIRE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services scientific Technical services 1J-160 L2 500292334461 ConocoPhillips Alaska Inc. Sperry Drilling Services 25-MAY-07 MWD RUN 8 MWD RUN 9 w-0004877337 w-0004877337 S. POLAK 5. POLAK F. HERBERT F. HERBERT 35 11N l0E 2016 2541 122.29 81.00 Page 1 U= ~ 2a~- ~-C~c~- ~ t 5t'~'~ • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J160L200403200755N.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3551.0 6.750 9.625 8391.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8391' MD/3223'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-160 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 8. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). POROSITY LOG DATA ACQUIRED OVER THE MWD RUN 3 INTERVAL ARE PRESENTED WITH THE 1J-160 LOGS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,8,9 REPRESENT WELL 1J-160 L2 WITH API#: 50-029-23344-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13067'MD/3194'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number...........1.0.0 Page 2 17160L200403200755N.txt Date of Generatio n.......07/05/25 Maximum Physical Record..65535 File Type. .... ........LO Previous File Nam e.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3525.0 13009.5 NPHI 3540.0 8391.0 FCNT 3540.0 8391.0 NCNT 3540.0 8391.0 PEF 3540.0 8391.0 RPS 3540.0 13016.5 DRHO 3540.0 8391.0 FET 3540.0 13016.5 RPD 3540:0 13016.5 RPx 3540.0 13016.5 RPM 3540.0 13016.5 GALA 3540.0 8391.0 RHOB 3540.0 8391.0 RoP 3561.5 13067.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3525.0 8391.0 MWD 8 8391.5 8417.0 MWD 9 8417.0 13067.0 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 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 Page 3 1]160L2004032007SSN.txt RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3525 13067 8296 19085 3525 13067 GALA MWD INCH 10.18 13.75 12.2493 9703 3540 8391 FONT MWD CNTS 548.07 3672.06 1048.59 9703 3540 8391 NCNT MWD CNTS 127381 225203 172185 9703 3540 8391 RHOB MWD G/CM 0.071 2.889 2.12267 9703 3540 8391 DRHO MWD G/CM -4.72 0.289 0.0505538 9703 3540 8391 RPD MWD OHMM 5.49 2000 40.5605 18954 3540 13016.5 RPM MWD OHMM 4.75 1857.77 37.595 18954 3540 13016.5 RPS MWD OHMM 4.6 1960.97 36.0152 18954 3540 13016.5 RPX MWD OHMM 3.3 2000 40.4734 18954 3540 13016.5 FET MWD HOUR 0.1 428.27 0.835538 18954 3540 13016.5 GR MWD API 19.59 121.33 66.3636 18970 3525 13009.5 PEF MWD BARN -0.32 12.99 2.11249 9703 3540 8391 ROP MWD FT/H 1.38 4109.98 243.962 19012 3561.5 13067 NPHI MwD PU-s 9.25 107.7 41.0181 9703 3540 8391 First Reading For Entire File..........3525 Last Reading For Entire File...........13067 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Ty e ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Page 4 17160L2o0403200755N.txt 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 GR 3525.0 8391.0 PEF 3540.0 8391.0 FET 3540.0 8391.0 RPx 3540.0 8391.0 NPHI 3540.0 8391.0 RPS 3540.0 8391.0 RHOB 3540.0 8391.0 GALA 3540.0 8391.0 RPD 3540.0 8391.0 FONT 3540.0 8391.0 DRHO 3540.0 8391.0 RPM 3540.0 8391.0 NCNT 3540.0 8391.0 RoP 3561.5 8391.0 LOG HEADER DATA DATE LOGGED: 13-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8391.0 TOP LOG INTERVAL (FT): 3560.0 BOTTOM LOG INTERVAL (FT): 8391.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 87.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 EWR4 ELECTROMAG. RES IS. 4 78633 CTN COMP THERMAL NE UTRON 158416 ALD Azimuthal Litho -Dens 220637 ACAL Acoustic Calipe r 727406 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3551.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.430 116.6 MUD FILTRATE AT MT: 2.600 70.0 MUD CAKE AT MT: 3.000 70.0 NEUTRON TOOL Page 5 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 17160L2o040320075SN.txt 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 l CALA MWD030 INCH 4 1 68 4 2 FCNT MWD030 CNTS 4 1 68 8 3 NCNT MWD030 CNTS 4 1 68 12 4 RHOB MwD030 G/CM 4 1 68 16 5 DRHO MwD030 G/CM 4 1 68 20 6 RPD MwD030 OHMM 4 1 68 24 7 RPM MwD030 OHMM 4 1 68 28 8 RPS MwD030 oHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MwD030 HOUR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MwD030 BARN 4 1 68 48 13 RoP MwD030 FT/H 4 1 68 52 14 NPHI MwD030 Pu-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3525 8391 5958 9733 3525 8391 GALA MWD030 INCH 10.18 13.75 12.2493 9703 3540 8391 FONT MWD030 CNTS 548.07 3672.06 1048.59 9703 3540 8391 NCNT MWD030 CNTS 127381 225203 172185 9703 3540 8391 RHOB MwD030 G/CM 0.071 2.889 2.12267 9703 3540 8391 DRHO MWD030 G/CM -4.72 0.289 0.0505538 9703 3540 8391 RPD MwD030 OHMM 5.49 2000 15.5629 9703 3540 8391 RPM MwD030 OHMM 4.75 1258.18 14.2141 9703 3540 8391 RPS MWD030 OHMM 4.6 95.29 13.0511 9703 3540 8391 RPX MWD030 OHMM 3.3 37.4 10.8519 9703 3540 8391 FET MwD030 HOUR 0.1 100.94 0.867055 9703 3540 8391 GR MwD030 API 19.59 121.33 68.2312 9733 3525 8391 PEF MwD030 BARN -0.32 12.99 2.11249 9703 3540 8391 ROP MWD030 FT/H 4.97 1068.15 232.229 9660 3561.5 8391 NPHI MwD030 Pu-5 9.25 107.7 41.0181 9703 3540 8391 First Reading For Entire File..........3525 Last Reading For Entire File...........8391 Page 6 a +~ 17160L2004032007ssN.txt File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 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.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SROP 8391.5 8417.0 LOG HEADER DATA DATE LOGGED: 30-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8417.0 TOP LOG INTERVAL (FT): 8391.0 BOTTOM LOG INTERVAL (FT): 8417.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8391.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): .00 MUD VISCOSITY (S): .0 Page 7 1]160L2o0403200755N.txt MUD PH: .O MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .11N 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 MWD080 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8391.5 8417 8404.25 52 8391.5 8417 ROP MWD080 FT/H 1.38 13.94 4.85346 52 8391.5 8417 First Reading For Entire File..........8391.5 Last Reading For Entire File...........8417 File Trailer Service name... .......STSLIB.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header service name .............STSLI6.004 Page 8 17160L200403200755N.txt service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/05/25 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SESP 8391.5 13016.5 SGRC 8391.5 13009.5 SFXE 8391.5 13016.5 SEXP 8391.5 13016.5 SEDP 8391.5 13016.5 SEMP 8391.5 13016.5 SROP 8417.5 13067.0 LOG HEADER DATA DATE LOGGED: 03-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13067.0 TOP LOG INTERVAL (FT): 8417.0 BOTTOM LOG INTERVAL (FT): 13067.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.9 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resi s. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8391.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 63.0 MUD PH: 1.6 MUD CHLORIDES (PPM): 29500 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 102.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 Page 9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 1]160L2O0403200755N.txt Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8391.5 13067 10729.3 9352 8391.5 13067 RPD MWD090 OHMM 8.19 2000 66.7796 9251 8391.5 13016.5 RPM MWD090 OHMM 9.33 1857.77 62.1182 9251 8391.5 13016.5 RPS MWD090 OHMM 9.42 1960.97 60.1014 9251 8391.5 13016.5 RPX MWD090 OHMM 7.92 2000 71.5423 9251 8391.5 13016.5 FET MWD090 HOUR 0.14 428.27 0.802482 9251 8391.5 13016.5 GR MWD090 API 33.06 110.38 64.3957 9237 8391.5 13009.5 ROP MWD090 FT/H 3.93 4109.98 257.486 9300 8417.5 13067 First Reading For Entire File..........8391.5 Last Reading For Entire File...........13067 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSLIB.005 Physical EOF Page 10 17160L2o040320075SN.txt Tape Trailer Service name .............LISTPE gate . ...................07/05/25 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE gate . ...................07/05/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File e: scientific Technical services Scientific Technical Services Page 11
