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Home My WebLink About205-146Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ (~.. ~ Well History File Identifier Organizing (done) „~v,,aa Illllllllllllilllll Re=~,~~eea,a uumiuuuuii RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: DIGITAL DATA Diskettes, No. ~, ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing III ~~ it II I I III I I ~II BY: Maria Date: ~ /s/ Scanning Preparation _~ x 30 = ~ + ~~ =TOTAL PAGES~~' (Count does not include cover sheet) BY: Maria Date: ~) `~ ~O D /s! Production Scanning Stage 1 Page Count from Scanned File: ~ ~ (Count does include cov r sheet) Pa a Count Matches Number in Scanning Preparation: YES NO g BY: Maria Date: ~ ~~ Og /s/ ~~/' Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I I{ II I (II~ ~s~,~~.o iiiiiimiiiiiiu BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III III III 10!6/2005 Well History File Cover Page.doc ~`~~~~~~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051460 Well Name/No. KUPARUK RIV U WSAK 1J-164L2 Operator CONOCOPHILLIPS ALASKA INC MD 11524 ND 3562 Completion Date 12/5/2005 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Log s Run: GR/Res, Dens/New Well Log Information: Log/ Electr Data Digital Dataset Type: 1Ned/Frmt Number Name D Lis 13767 Induction/Resistivity D Asc Directional Survey D Asc Directional Survey 13767 LIS Verification D Li 13768 ti /R ti it I d i s n uc on es s v y '~ 13768 LIS Verification C Li 1 r? s ~. D 5026 Induction/Resistivity C Lis 15027 Induction/Resistivity Well Cores/Samples Information: Completion Status 1-OIL Current Status 1WINJ API No. 50-029-2327J8-61-00 UI Y/ Samples No Directional Survey -__ (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run Scale Media No Start Stop OH / CH Received Comments 2297 11458 Open 4/6/2006 GR EWR4 ABI ROP ACAL PWD GeoPilot 0 0 Open 1/17/2006 DEFINITIVE SURVEY 0 0 Open 1/17/2006 DEFINITIVE SURVEY PB1 ~~, 2297 11458 Open 4/6/2006 GR EWR4 ABI ROP ACAL PWD GeoPilot 2297 6097 Open 4/6/2006 PB 1 GR EWR4 ABI ROP ACAL PWD GeoPilot 2297 6097 Open 4/6/2006 PB 1 GR EWR4 ABI ROP ACAL PWD GeoPilot 2297 11524 Open 4/17/2007 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF i 2297 6155 Open 4/17/2007 PB 1 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051460 Well Name/No. KUPARUK RIV U WSAK 1J-164L2 Operator CONOCOPHILLIPS ALASKA INC MD 11524 TVD 3562 Completion Date 12/5/2005 Completion Status 1-OIL Current Status 1WINJ ADDITIONAL INFORM~~A''T~~ION Well Cored? Y~ Daily History Received? ~ N Chips Received? ,,~C1.~,_ _ Formation Tops Y / N Analysis ~ Received? Comments: Compliance Reviewed By: _ - _ _ _ _- API No. 50-029-23278-61-00 UIC Y ._ _- - -- -- - _. \. - -Date: ~ ~ J --- -- e tJt a ivv r uvlvuwu vu .~..1 , ...~ ~... ~.~ ... ...., ~ ... ~.. .~ .., _., .. ~, 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 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180 - -o- - -- 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 8 (DOA) Cc: CPFl DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, iJ-127, iJ-164, iJ-180 Tom !Jim, The LPP/SSV's on all ofi the West Sak DS1 E and DS'IJ wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also lisi~d. 1 ~niasn't sure ii you wanted the permit to drill number for the mainbore only or the laterals as we!I so I included boh. WELL ID Kermit to Drill No. 1E-112 204-091 (iV1AINBORE), 204-092 (L1), 204-093 (L2) 1J-102 206-'110 (MAINBORE), 206-111 (L1 ), 206-'112 (L2) '1J-1t75 207-027 (MAINBORE), 207-028 (L1}, 207-029 (L2) 1J-127 206-047 (MAINBORE), 206-048 (L1 ), 20G-049 (L'Z) 1J-160 207-015 (MAiNBORE), 207-016 (L1), 207-017 (L2) ----~ 1J-1G4 205-144 (MAINBORE}, 205-145 (L1), 205-14G (L2) 1J-180 206-150 (MAiNBORE), 20G-151 (L1) i`lote: 1J-105 and 1J-1 G0 were defeated in early July 2007, before the CPF1 ESQ, because they were ne~N injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK l~lest Sa!< Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1G38@ConocoPhillips.com 8/27/2007 • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-164, L1, L2 & L2 PBI, i April 16, 2007 AK-MW-4025932 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-164, 1J-164 Ll, 1J-164 L2 & 1J-164 L2 PBl: LIS & Digital Log Images: 50-029-23278-00, 60, 61, 70. ~ = y ~, ~: ,~ ~R ~~ ~ ?~~ (u~C aos -Ivy ~ iSoay VAC ~~5 -1~/5 'k 15-b2 S U ~' C ~ 6 5 = /~/~ '~ ~ Sc~ ~ ~ csb~- 1 CD Rom ~.r • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS k`~aeC'~! ~~ ~~ ® , ~ ~q 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ; rod. Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ ~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number:. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 205-146 3. Address: Strati ra hic g p ^ Service / ^ ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-164L2 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11524' feet true vertical 3561' feet Plugs (measured) Effective Depth measured 11501 feet Junk (measured) true vertical 3561 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2223' 10-3/4" 2332' 2203' INTERMEDIATE 5249' 7-5/8" 5358' 3443' PROD. CASING 1' 5-1/2" 4249' 3512' D sand Slotted Lii 7256' 4-1/2" 11502' Perforation depth: Measured depth: None true vertical depth: None Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4221' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 475' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2053 2678 850 360 Subsequent to operation 2115 1000 346 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations `X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^/ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt:,-,©~ _ ~' ~ contact Robert D. Christensen Printed Name Title Production Engineering Technician Signature Phone 907-659-7535 Date c~ ~ D ~~ rs~a ~S ~~1~- APB, d 2006 "' C... /1~ d • ~ ~ • o Form 10-404 Revised 04/2004 1 S~ it~~igin~l /~ ~- e ~/ 1J-164 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/2/2006 Commenced Water Injection Service ~::: C WELL LOG TRANSMITTAL To: State of Alaska March 24, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-164 L2, AK-MW-4025932 1 LDWG formatted Disc with verification listing. API#: 50-029-23278-61 ~ r ~ `~ l9- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~~ Signed: o,-~~ i • WELL LOG TRANSMITTAL To: State of Alaska March 24, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-164 L2 PB1, AK-MW-4025932 1 LDWG formatted Disc with verification listing. API,`: 50-029-23278-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 4r / qq Date:l~ ~~ Signed: • • FRANK H. MURKOWSK/, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River, 1J-164L2 Sundry Number: 306-051 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 ID day of February, 2006 ~ Z.la-ab ~ ~ ~, ~ ~a ~., ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~*- i` ~ APPLICATION FOR SUNDRY APPROVAL FEB 1 0 20 AAC 25.280 2~~~ 1. Type of Request: Abandon ^_ Suspend ^ Operation Shutdown ^ Perforate ^ ~Ot h~~ l~~aS~a~~r~i ~~ ~OnS Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ . ~ Time Extensior~~Orage Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Wet{ ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill tuber. ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-146 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23278-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-164L2 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): . Junk (measured): 11524' 3561' 11501 3561 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 2223' 10-3/4" 2332' 2203 INTERMEDIATE 5249' 7-5/8" 5358' 3443 - WINDOW D-SAND 1' 5-1/2" 4249' 3512 D sand Slotted Liner 7256' 4-1/2" 11502' 3561 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None 4-1/2" L-80 4221' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV=NIP SSSV= 475' 12. Attachments: Description Summary of Proposal ^ 13. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 02/14/06 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: ~ /O6 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: om Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert D. Christensen Printed Name obert . Christense Title: Production Engineering Technician Signature ~ , Phone 659-7535 Date a Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 D - o S Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ Other: S p R7FF1T ~~~ ~ ~ 200 Subsequent Fo ~ it A d APPROVED BY ~~/D fn~C (J'~ pprove CO O THE COMMISSION Date: 1 v -u Form 10-403 Revised 07/2005 Submit in Duplicate 1J-164L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska lnc. requests approval to begin Water Injection service in West Sak Multi-lateral Well 1J-164L2. This well was pre-produced fora 39 day period in order to recover Solids Free Oil based drilling fluids prior to putting the well on injection. Well 1 J-164L2 will provide pressure support for the West Sak D sands. The 10-3/4" Surface casing (2332' and ! 2203' tvd) was cemented with 480 sx AS Lite followed by 145 sx DeepCrete. The 7-5/8" Intermediate casing (5358' and / 3656' tvd) was cemented with 230 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-518" Liner Top Packer D- Lateral Hook Hanger LEM w/isolation Seal Bore located @ 4187' and / 3424' tvd. The top of West Sak D sand was found at 4219'md / 3434' tvd. The top of West Sak B sand was found at 4578'md ! 3509' tvd. The top of West Sak A sand was found at 4770'md / 3548' tvd. .fit" KRU !1J-164L2 API: 500292327861 Well T e:'PROD SSSV T e: NIPPLE Ori Com letion: 12/5/2005 Annular Fluid: Last W/O: ____ Reference Lo 28' RKB Ref Lo Date: Tm Last Ta TD: 11524 ftKB Last Tag Date: Max Hole Angle: 95 deg at?_4718 >;+ ~ - -. ___ ;Casing String -COMMON STRINGS LOCATOR (4183-4184, OD:5.520) PUP (4188-4247, OD:4.500) Pert (a2a5-aaoa) Pert (4719-5306) ................ ~ { ~ ? - Ck. I ~ I: - ,+. 1 J-164L2 Rev Reason: NEW Last U date: 1/29/ CONDUCTOR 20.000 0 108 108 91.50 H-40 WELDED D-SAND LINER 4.500 4246 11502 3561 12.60 L-80 IBTM WINDOW D-SAND - 6.875 4248 - 4249 3443 -- 12.60 L-80 IBTM - ~Tubing5trin~ -TUBING - - --- Size Top Bottom I TVD Wt G ~ _ rade ! Thread 4500 _ 0_ I 4221 ~ 3434 12.60 L-80 IBTM 'Perforations Summary _ _ Interval TVD Zone Status Ft SPF Date T e Comment 4285 -4408 3451 -3475 WS D 123 32 12/4/2005 Slots Alternatn SlottedBlank Pi e 4719 - 5306 3480 -3471 WS D 587 32 12/4/2005 Slots Alternatn SlottedBlank Pi e 5582 - 6133 3466 -3474 WS D 551 32 12/4/2005 Slots Alternatin SlottedBlank Pi e 6412 - 6964 3470 -3467 WS D 552 32 12/4/2005 Slots Alternatn SlottedBlank Pi e 7244 - 7824 3476 -3495 W S D 580 32 12/4/2005 Slots Alternatin SlottedBlank Pi e 8103 - 8629 3500 - 3503 WS D 526 32 12/4/2005 Slots Alternatin SlottedBlank Pi e 9183 - 9739 3476 -3488 WS D 556 32 12/4/2005 Slots Alternatin SlottedBlank Pi e 10018 - 10606 3499 - 3521 WS D 588 32 12/4/2005 Slots Alternatin SlottedBlank Pi e 10883 - 11470 3533 - 3561 WS D ~ 587 32 12/4/2005. Slots Alternating SlottedBlank Pipe Gas Lift Mandrels/Valves - - _ - - - St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 1 2336 2207 CAMCO KBG-2 GLV 1.0 BK-5 0.188 1450 12/24/2005 2 390.2 3335 CAMCO KBG-2 OV 1.0 BK-5 0.250 0 12/24/2005 Other lu s up., etc . -COMMON JEWELRY - - _ - -- - De th TVD T e Descri lion ID 23 23 HANGER TUBING HANGER VETCO GRAYw/4.909" MCA TOP CONNECTION 4.500 475 475 NIP CAMCO'DB-6' NIPPLE NO GO PROFILE 3.875 4137 3409 SLEEVE-C BAKER CMU SLIDING SLEEVE w/3.81" DB PROFILE -CLOSED 12/23/2005 3.812 4183 3423 LOCATOR BAKER LOCATOR GBH-22 SPACED OUT 3.88' ABOVE FULLY INSERTED 3.875 4184 3423 SEAL BAKER SBE SEAL ASSEMBLY 3.875 4221 3434 SHOE - - MULE SHOE - - - _ - 6.875 Other Items, ecui~etc.) - D-SAND LEM _ --_ -- - - De th TVD T e Descri lion ID 4187 3424 PACKER ZXP LINER TOP PACKER 4.960 4188 3424 PUP PUP JOINTS 3.958 4206 3430 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 4226 3436 XO CROSSOVER BUSHING 3.958 4229 3437 SWIVEL CASING SWIVEL 3.920 4236 3439 HANGER LEM ABOVE HOOK HANGER 3.930 4246 3442 HANGER LEM INSIDE HOOK HANGER 3.930 I 4371 3470 SEAL BAKER SEAL ASSEMBLY ---- 3.890 Other lugs equipetc .) - D-SAND LINER JEWELRY --- - - _ be th TVD T e Descri lion ID 8638 3502 PACKER SWELL PACKER 0.000 9158 3477 PACKER SWELL PACKER 0.000 11501 3561 SHOE BAKER 3.5" GUIDE SHOE (NO FLOAT _ _ 0.0_00__ General Notes - -- _ Date _ - - ~ Note 12/4/2005 MULTI-LATERAL WELL: A-SAND (1J-164), B-SAND (1J-164L1), D-SAND (1J-154L2) { '. ~ S '' ~.>~ ~ .a Re: Verbal approval to convert Wsak 1J-164 from Preproduction to... Subject: Re: Vexbal appro~~al to convert Wsak IJ-164 from Preproduction to WIND Frorn: Thomas Maunder ~ -tom_mar~nder@admin.statc.ak.us > Date: ~1'cd; 08 Feb ~OU6 09:? 1:4~ -09U0 To: NSK Prod Fn~~r Tcch ~'nl li~r~r.~coi~ocophillips.conl> C'C: NtiK ~~`est Sak Prod I-'n`or ~ n1(~S~a-ron~~cohhillips.com=~. AOGCC' North dope Office <ao~~cc~~rudhocbayr~i!ad~ni n.state.ak. us> Bob, c~ ~ ~ - ~ y, I have completed my assessment of the cement isolation for IJ-164, -L1 and -L2 and determined that the well construction meets the requirements for conversion to injection. By copy of this email, you have verbal approval to proceed as planned. I will look forward to seeing the three 403s sometime next week. I do not show having received a copy of the MIT you refer to in your message. Please send that in to Bob Fleckenstein/Jim Regg as usual. Once the well is warmed up, you should contact the Inspector for a witnessed MIT. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2/8/2006 7:52 AM: Bob, I have to do a little paperwork in here. I will get back with you later this morning. Tom Maunder NSK Prod Engr Tech wrote, On 2/8/2006 7:42 AM: Tom, We have completed the Preproduction phase to recover the oil based drilling muds in Wsak 1J-164/L1/L2 (PTD#'s: 205-144, 205-145, 205-146) . Well 1J-164 was originally permitted as a WINJ well. The 10-407 was completed with the well as a Oil producer for the preproduction period. An MITIA was performed on 12/21/05; MITIA 3000 psi, 30 minutes, Passed. We intend to turn the well to WINJ on or about 02/14/06. I am currently working up the 10-403 conversion application but due to the timing I am requesting a verbal approval to proceed with the conversion. Bob Buchholz /Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician Office (907} 659-7535 NSK-69 Pager (907) 659-7000 (924} 1 of 1 2/8/2006 9:23 AM I'. C:iANICAL INTEGRITY RrPaRT ~ T `~ ~ 1 y I \ tiJ PUD D..-._~ : - t ~~iA ~iS,~- OPER ~ FIELD ~~' ~~ ~L2y ~-~ S = c r ~ ~ ~~_.. ~ .. ~j~co ~ ;, ALL Nt~r•~a ER ~ ~ ~- 1 C~ `'\ ~-~--.~... - ~.._ .~ ~ LL DAT ~_ TD : ~ ~ 3o1S5 ?~.. 3~~-tS TVD ; ? BTD : ?'ID TVD Casing : ~h~~ Shoe : ~.,5~, MD j(o~C~TVD ; liV : ~~ ?~ ~-~ T~`i _.ae.. Shoe . '~D '?'VD ; :CP . ?•~D _'iD -moo'-,v Packer :-+~ T~TD; Set at -~nsR as~,~s.,.~ ole S~Le ~~~~5 and ; Perfs ~~_ '-`~= C'r'.t'?~ =Cr.T, INTEGRITY - ~A.RT # ~ r_nnulus Press Test: ~? 15 nin Cor~ents to ~0 min '_-'~'CH~NIC~~.., INTEGRITY - PA~'T #2 ~" ~ ~ J .L~ f 3 r~ ~ ~~ ties Cement Volumes:. Amt. L iner Cs~ ~3~5~ DV ~A Cwt -sot to cover oer~s ~ ~~~ `1lS ~0~ ~,~ ~+ Cpv~~-~ tD wt~~~5~a - =eoretical TOC t%3~~o~-S ~~C."=-~~~C}~ ~~,~~.~oC ~.. ~~ Cement Bond Log (Yes or No) ~{Ls In AOGCC File ~~S C5L Evaluation, lone above perfs ~~t~ too~S co© .~~-~ ~~~~~~~ s~OE ~~t~~ Production 'Log : '?'y-p e Evaluation CONCLJS~ONS: Part #1: ~ ar ~ T Z : ~~ ~~ ~~< ro ~ . f~ STATE OF ALASKA ~- !RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AI's ~~~os 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ ~~ ~~,,S~ff+±±~~~w~wS COnS~ Development h~ra({~~-ppEx~I~S10~1] Service ~SRatigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., - orAband.: December 5, 2005 12. Permit to Drill Number: 205-146 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: 21 /~ November , 2005 '~•[a~ 13. API Number: 50-029-23278-61 4a. Location of Well (Governmental Section): Surface: 1919' FSL, 2517' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: December 1, 2005 ~ 14. Well Name and Number: 1J-164L2 At Top Productive Horizon: 1596' FNL, 2204' FWL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (tt): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 392' FSL, 2163' FWL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 11501' MD 13561' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558693 ~ y- 5945730 Zone- 4 10. Total Depth (MD + TVD): .11524' MD / 3562' TVD • 16. Property Designation: , ADL 25661, 25650 TPI: x- 558119 y- 5947490 Zone- 4 Total Depth: x- 558014' - 5954757 Zone- 4 11. Depth where SSSV set: nipple @ 475' 17. Land Use Permit: ALK 471, 468 18. Directional Survey: Yes ^~ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3077' MD 21. Logs Run:. k~ ~ y~~ Z~$ ~ 13l,T~l 3 L ~ 7y-b ~ I - ~8•~. GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.58# H-40 28' 108' 28' 108' 42" 325 sx AS1 10.75" 45.5# L-80 28' 2333' 28' 2202' 13.5" 480 sx AS Lite, 145 sx DeepCrete 7-5/8" 29.7# L-80 28' 5358' 28' 3656' 9-7/8" 230 sx DeepCrete 4.5" 12.6# L-80 4246' 11502' 3442' 3561' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 4703' slotted liner from 4285'-11470' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, E7C. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 31, 2005 Method of Operation (Flowing, gas lift, etc.) Production shared with 1J-164 and 1J-164L1 Date of Test 1/4/2006 Hours Tested 15.5 hours Production for Test Period --> 694 GAS-MCF 844 WATER-BBL 0 CHOKE SIZE 176 bean GAS-OIL RATIO 1292 Flow Tubing press. 693 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1025 GAS-MCF 1324 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". _ ~NIS 61=~ E~~~ ~, ?DO6 ~ `l~ ~:;, G~ NONE ~°w ,~ _~ x Form 10-407 Revised 12/2003 _ -~ 3 CONTINUED ON REVERSE ,)~~ ~"~ j`~i ~ G r~ 2a. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-164L2 West Sak D 4219' 3434' Base West Sak D 11524' 3561' NfA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Na Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader i. ~.S~D6 Signature 26 5-~ 3 ~ Date INSTRUCTIONS Prepared by Sharon Alisup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Start: 10/31!2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Rig Name: Doyon 141 Rig Number: Page 1 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Date ;From - To ~ Hours Code i, Code Phase Description of Operations 10/31/2005 00:00 - 02:30 2.50 WAITON EOIP 'MOVE 'Change top drive saver sub to 4-1 /2" IF. 11 /1 /2005 11 /2/2005 02:30 - 03:00 0.50 WAITON EOIP MOVE Service top drive & Drawworks. 03:00 - 03:30 0.50 WAITON EOIP MOVE ~ Change Iron Rough Neck, Elvators, Dog collar Etc. over to 5" Handling i tools. 03:30 - 07:00 3.50 MOVE DMOB MOVE Rig down rig for move. 07:00 - 12:00 5.00 MOVE ~ MOVE MOVE ~ ..Move rig f/ 1 J-154 to 1 J-164 12:00 - 12:30 ~ 0.50 MOVE MOVE ; MOVE Spot Sub over 1J-164 12:30 - 15:30 3.00 MOVE MOVE MOVE Lay Mats and Spot Pits, Pumps, Motors, Boilers, Lay herculite and Spot ~ . Rock Washer and Pipe sheds. 15:30 - 18:00 ; 2.50 MOVE RURD ~ RIGUP Hook up all service lines, Steam, Air & Water lines, Work on rig acceptance check list. 18:00 - 20:30 2.50! DRILL PULD RIGUP ; Accept rig @ 18:00 hrs 10/31/05, Load Pipe shed with 45 jts. 5" drill ' pipe, 29 jts. HWDP & jars, Strap same, Begin mixing spud mud. 20:30 - 22:30 I 2.00 WELCT NUND RIGUP Nipple up 20 1/4" Diverter, All lines, Bell nipple, Diverter line, Apply ~ i steam to warm up diverter, Continue to mix spud mud. 22:30 - 00:00 1.50 DRILL PULD ~ RIGUP Pick up 21 jts. 5" drill pipe and stand back in derrick, Continue to mix spud mud. 00:00 - 02:15 2.25 DRILL ~ PULD RIGUP Finish picking up total of 15 stands 5" drill pipe, 10 stands HWDP ! (Including Jars). 02:15 - 02:45 0.50 DRILL PULD RIGUP Bring lifters, Stab, UBHO sub, Crossover subs, to floor thru beaver slide. 02:45 - 03:45 1.00 DRILL PULD RIGUP '~ Pick up 3-Non Mag DC's and stand back in derrick, Lay down mouse ' hole. 03:45 - 04:00 0.25 WELCTL BOPE RIGUP Function test Diverter system, Test waived by AOGCC Jeff Jones. 04:00 - 05:00 1.00 DRILL PULD SURFAC ' Make up Bit, Motor, 1 stand HWDP, Flood conductor and check for leaks, Pressure test mud lines to 3000 psi-OK, Tag ice plug @ 80', Clean out to 108'. 05:00 - 06:30 1.501 DRILL DRLG SURFAC Spud well @ 05:00 hrs 11/1/05, Drill f/ 108' to 212' MD, 212' TVD (104'), ADT 1.00 hrs, 420 gpm @ 525 psi, 55 RPM. 06:30 - 07:00 0.501 DRILL ; TRIP SURFAC POOH f/ 212' to 30'. 07:00 - 08:00 i 1.00 DRILL PULD I SURFAC Finish picking up BHA #1, Pick up Stab, X/O subs, MWD, Orient Motor ' ~ w! MWD. 08:00 - 08:30 0.50; DRILL ' RIRD SURFAC PJSM, Rig up Sperry-Sun GYRO & Wire unit. 08:30 - 09:00 , 0.50 DRILL TRIP SURFAC RIH to 212'. 09:00 - 12:00 3.00 DRILL DRLG I SURFAC ~ Drill f/ 212' to 349' MD, 349' TVD (13T), ADT 2.38 hrs, 5/7K WOB, 504 ' gpm @ 1100 psi, 65 RPM. ;12:00 - 00:00 ; 12.00 DRILL DRLG ,SURFAC ~ Drill 13-1/2" Hole f/ 349' to 1,096' MD, 1,087 TVD (74T), ART= 2.66 hrs, AST= 6.69 hrs, ADT= 9.35 hrs., 560 gpm @ 1400 psi, WOB 20-25K, RPM 60- 70, UP 94K, DN 90K, ROT 89K, TQ on 3500 ft/Ib, TO off 1500 ft/Ib, Ran GYRO #1 @ 50', 100', 200', 300', 355', #2 @ 443', i ~ #3 @ 533', Sliding 70' and Rotating 20' per stand, Mud wt 8.9, Vis 300. ' ' ' ' 00:00 - 12:00 12.00 DRILL DRLG SURFAC ), ADT= 8.74 to 2,170 MD, 2,060 TVD (1,074 Drill 13-1/2" Hole f/ 1,096 ~ I hrs, ART= 1.5 hrs, AST= 7.24 hrs., 721 gpm @ 2100 psi, WOB 10-20K, {RPM 75, UP 110K, DN 100K, ROT 105K, TQ on 3000 ft/Ib, TO off 2000 ft/Ib, Sliding 70' and Rotating 20' per stand, Mud vut 8.9, Vis 300. ;12:00 - 13:30 I 1.50 DRILL DRLG SURFAC I Drill 13-1/2" Hole f! 2,170' to 2,342' MD, 2,212' TVD (172'), ADT= 1.08 ' hrs, ART= 0.61 hrs, AST= 0.47 hrs., 763 gpm @ 2300 psi, WOB 0-25K, RPM 75, UP 120K, DN 104K, ROT 109K, TO on 5/ 6000 ft/Ib, TO off 5000 ft/Ib, Mud wt 8.9, Vis 300. 13:30 - 14:00 0.50 DRILL CIRC 'SURFAC ' Circ btm's up at rate of 763 gpm @ 2300 psi, 80 RPM, TQ 5500 ft/Ib, Reciprocate pipe f/ 2,342' to 2,285' while circ. 14:00 - 17:00 ; 3.00 DRILL TRIP SURFAC Back Ream out of hole at rate of 763 gpm @ 2300 psi, 80 RPM, 25 to ` ~ j 35 fUmin., Slowed down to 5 to 10 ft/min. and let hole clean up after Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Page 2 of 24 Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To ,Hours '! Code ~ Code'i, Phase 11 /2/2005 11 /3/2005 14:00 - 17:00 3.00 DRILL TRIP ~! SURFAC 17:00 - 17:30 ' 0.50 DRILL TRIP i SURFAC 17:30 - 19:30 2.00 DRILL PULD SURFAC 19:30 - 21:00 1.501 CASE RURD SURFAC 21:00 - 00:00 3.00 CASE RUNC ~ SURFAC 00:00 - 00:15 0.25 CASE RUNC SURFAC 00:15 - 00:45 0.50 ~ CASE ~ CIRC ~ SURFAC 00:45 - 01:30 I 0.75 ~ CEMENT , PULD SURFAC 01:30 - 02:30 ~ 1.00 CEMENI ~CIRC ~ SURFAC 02:30 - 05:30 ! 3.00 i CEMENTPUMP I SURFAC 05:30 - 07:30 2.00 CEMEN PULD ;SURFAC ~ I 07:30 - 09:00 1.50 1 CASE .RURD SURFAC 09:00 - 11:00 ; 2.00 ~ WELCT i NUND ,~ SURFAC 11:00 - 13:15 2.25 WELCT NUND I SURFAC 13:15 - 16:30 3.25 WELCT NUND SURFAC 16:30 - 18:00 ~ 1.50 ~ WELCT BOPE .SURFAC Description... of Operations ~ pulling 8 stands f/ 1,549' to 1,363' -Hole unloaded large amounts of Clay and Sand, Continue to Back Ream out to 895' -Hole cleaned up. POOH on elevators & rack back HWDP & Jars. Lay down BHA #1, NMDC's, UBHO sub, X/O, MWD, Motor, Bit. Rig to Run 10-3/4" Casing, Held PJSM with all personnel running casing. Run 55 jts of 57 jts of 10 3/4", 45.5#, L-80 BTC csg to 2,225' per well plan, MU 10 3/4 Weatherford Model 303 float shoe, 2 joints 45.5#, L-80, BTC csg and Weatherford model 402 FC, (1) joint 45.5#, L-80, BTC casing, baker locked btm 3 corm. and pumped thru checking float ' equipment, cont RIH with 10 314" csg to 2,225' at 00:00 hrs, Ran 19 bow spring centralizers on 1st 17 jts ran 1 cent on jt. # 56 @ 20" conductor @ 108' (Total of 20 centralizers and 3 stops). No problems RIH, st wt up 130K, down wt 110K Finish running 10-3/4" casing (Total 57 jts.), Pick up Vetco Gray casing hanger and land w/ Shoe @ 2,332.83', Float collar @ 2,249.12'. Circ btm's up, Stage rate up to 6.0 bpm @ 250 psi, Reciprocate pipe ' 10'-15' Up 130K, Dn 107K. Rig down Frank's fill up tool, Blow down top drive, Rig up Dowell cement head. 'Finish circ and cond mud for cementing, staged pump rate up to 6.5 bpm at 280 psi, reciprocating pipe 15' with 130K up wt and 107K do wt, circ and cond mud to 8.9 ppg and lowered PV to 21 and YP to 16, held PJSM on cement job with Dowell, ASRC and rig crew while circ and ;cond mud. Turned over to Dowell and cemented 10 3/4" csg, Pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an ,additional 40 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 380.4 bbls (480 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.7 bpm at 225 psi, Followed with 63.7 bbls (145 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 4.4 bpm at 230 psi, reciprocated csg 10 to 15' and had full returns, shut down and dropped top plug, Kick plug out ~ with 20 bbls fresh water. Rig displaced cement with 194.2 bbls (Total 214.2 bbls to bump) of 8.9 ppg mud, displaced cmt at 7.0 bpm, initial circ pressure 420 psi, max pressure 650 psi, Observed red dye at shakers after pumping 40.2 bbls mud, slowed rate to 3 bpm @ 425 psi and bumped plug, Pressured up to 1000 psi, held 5 min, checked floats and held, CIP @ 05:10 hrs .11/3/05, Reciprocated casing until 56 bbls cement around shoe then ,pipe became tight and land pipe on hanger, Up 130K, Dn 107K, Float shoe at 2,332' and Float collar at 2,249' Had full returns during job with 58.3 bbls of 10.7+ ppg cmt back to surface- Note; Hanger plugged as ! cmt came to surface- picked pipe up 1" to unplug, then set back down- IIOK Flush out diverter system with fresh water, Wash cement from flow line '~, & drip pans, Rig down Dowell cement head, Lay down landing joint. Rig down all casing tools, Clear rig floor. ~! Nipple down Diverter system. Nipple up Vetco Gray 13-5/8" Wellhead & test to 5000 psi. 'Nipple up BOPE Rig & Test Lower 7-5/8" Rams, Annular, Choke valves 1, 12,13,14, Printed: 12/29!2005 9:54:06 AM • ConocoPhillips Alaska Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date Operations Summary Report From - To Hours ' Code Code Phase ~ 16:30 - 18:00 ~ 1.50 ~ WELCT BOPE SURFAC 11 /3/2005 11/4/2005 11!5/2005 11 /6/2005 18:00 - 19:00 1.00 WELCTL I BOPE SURFAC 19:00 - 20:15 , 1.25' i WELCT ~ BOPE SURFAC 20:15 - 21:00 0.75 WELCT BOPE SURFAC 21:00 - 00:00. 3.00 i I WELCTL BOPE i SURFAC 00:00 - 01:00 1.00 WELCT , BOPE ,SURFAC 01:00 - 03:00 i 2.00' DRILL ' PULD ~ SURFAC 03:00 - 08:00 5.00 DRILL PULD SURFAC 08:00 - 12:00 4.00 DRILL PULD ,SURFAC j 12:00 - 13:30 1.50 DRILL TRIP SURFAC 13:30 -14:00 0.50 DRILL CIRC SURFAC 14:00 - 15:15 i 1.25 DRILL ' DEQT SURFAC 15:15 - 16:15 1.00 DRILL DRLG SURFAC 16:15 - 16:45 0.50 i DRILL ; CIRC ~ SURFAC 16:45 - 17:30 0.75 DRILL LOT SURFAC 17:30 - 00:00 ' 6.50 i DRILL DRLG INTRM1 00:00 - 12:00 12.00 I DRILL i DRLG ~ INTRMI i 12:00 - 00:00 12.00 DRILL i i DRLG INTRM1 00:00 - 00:30 0.50 ~ DRILL DRLG ~ INTRM1 1 i 00:30 - 01:15 , 0.75 DRILL CIRC INTRMI 01:15 - 01:45 ~! 0.50 DRILL DRLG i INTRM1 01:45 - 02:45 1.00 DRILL I CIRC INTRM1 02:45 - 05:00 2.25, DRILL j TRIP ~ INTRMI Start: 10/31 /2005 Rig Release: 12/5/2005 Rig Number: Page 3 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Description of Operations HCR Kill, 5" Inside dart to 250 psi Low & 3500 psi High, Note: Upper Varible Rams Failed Test. AOGCC Chuck Scheve waived test. Open top doors on BOP Stack and remove 3-1/2"x 6" varible Rams. Continue testing BOPE, Annular w/ 5", Manule Kill valves 4,5,6,7,8,9,10,11, 5" floor safety valve, Upper IBOP. Open top doors on BOP & Install 3-112" x 6" varible Rames. Continue testing BOPE, Top Rams w/ 4" & 5", Lower IBOP, Manule Choke valves 2 ii< 3, 4" Floor valves, Blind Rams, Annular w! 4", HCR Choke, Choke valves 2 & 3, Rig down test equip. Install wear bushing. Change top drive saver sub to 4" XT-39. Pick up 35 stands 4" drill pipe and stand back in derrick. Make up 9-7/8 MXC1 Bit, Motor w/ 1.5 deg. bend, Stab, Float sub, MWD, Orient same, GR/RES/PWD/HCIM/ACALlTM HOC, Up load MWD tools, NMDC's, Surface test MWD- OK. RIH & Tag Float collar @ 2249'. Circ btm's up at rate of 600 gpm @ 1800 psi. Rig ~ Test 10-3/4" casing to 3000 psi f/ 30 min.- OK. Drill out Float Collar @ 2,249', Cement, Float Shoe @ 2,332' and drill 20' new hole to 2,362', 600 gpm @ 1700 psi, 50 RPM, TO 5K. Pump Hi-vis weighted sweep, Change over to LSND Mud, Had 511 units gas on btm's up, Cric hole clean w/ 650 gpm @ 2000 psi, 50 RPM, TO 6K. Rig & Perform LOT of 15.4 EMW w/ 9.0 ppg mud, 737 psi @ 2202' TVD. Drill 9-7/8" Hole f/ 2,362' to 3,063' MD, 2,831' TVD (701'), ADT= 3.43 hrs, ART= 1.22 hrs, AST= 2.21 hrs, WOB 5-10K, 606 gpm @ 1900 psi, 85 RPM, TO on 6 to 8,000 ft/lb, Up 130K, Dn 91 K, ROT 105K, Pump 1 Hi-vis weighted sweep w/ 20% increase in cuttings, Max ECD's 9.65, Max gas 58 units. Drill 9-7/8" Hole f/ 3,063' to 4,184' MD, 3,423' TVD (1121'), ADT= 9.91 hrs, ART= 6.28 hrs, AST= 2.91 hrs, WOB 5-20K, 625 gpm @ 2580 psi, 85 RPM, Up 127K, Dn 85K, ROT 101 K, TO on btm 6 to 7,000 ft/Ib, TO off btm 6 to 7,000 ft/Ib, Pump 2 Hi-vis weighted sweeps w/ 20% increase in cuttings on 1st one and 10% on the 2nd, Max ECD's 9.7, Max gas 78 units. Drill 9-7/8" Hole f/ 4,184' to 5,226" MD, 3,632' TVD (1042'), ADT= 8.76 hrs, ART= 5.85 hrs, AST= 2.91 hrs, WOB 5-25K, 657 gpm @ 2850 psi, 85 RPM, Up 109K, Dn 83K, ROT 94K, TO on btm 6500 ft/Ib, TO off btm 5500 ft/Ib, Pump 1 Hi-vis weighted sweep w/ 10% increase in cuttings, Max ECD's 10.0, Max gas 155 units. Drill 9-7/8" Hole f/ 5,226' to 5,305' MD, 3,648' TVD (79'), ADT= 0.36 hrs, ART= 0.36 hrs, AST= 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, Dn 83K, ROT 94K, TO on btm 6500 fUlb, TO off btm 5500 ft/Ib, Max ECD's 10.1. Pump Hi-vis weighted sweep &Circ 2 x Btm's up to evaluate logs. Drill 9-7/8" Hole f/ 5,305' to 5,358' MD, 3,656' TVD (53'), ADT= 0.36 hrs, ART= 0.36 hrs, AST= 0 hrs, WOB 5-25K, 650 gpm @ 2900 psi, 85 RPM, Up 109K, Dn 83K, ROT 94K, TO on btm 6500 ft/Ib, TO off btm 5500 ft/lb, Max ECD's 10.1. Circ 2 x Btm's up at rate of 655 gpm @ 2800 psi w/ 85 RPM, TO 5000 fUlb. Monitor well, Back Ream out of hole f/ 5,358' to 4187' at drilling rate of Printed: 12!29!2005 9:54:06 AM • ConocoPhillips Alaska. Page 4 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From.- To Hours Code I Code LPhase 11/6/2005 102:45 - 05:00 2.25 ~ DRILL TRIP INTRMI :05:00 - 06:30 1.50; DRILL TRIP 1NTRM1 06:30 - 09:15 2.75 DRILL TRIP INTRM1 :09:15 - 11:15 2.00 ~ DRILL TRIP INTRMI 11:15 - 12:00 ' 0.75 DRILL ~ PULD ~ INTRM1 ' 12:00 - 14:30 2.50 CASE RURD INTRM1 14:30 - 17:15 2.75 CASE j RUNC , INTRM1 ' 17:15 - 17:45 0.50 ~ CASE CIRC INTRM1 17:45 - 20:30 2.75 CASE ~ RUNC I INTRM1 '20:30 - 21:00 0.50' CEMEN~PULD INTRM1 21:00 - 23:00 2.00, CEMENl~CIRC INTRMI 23:00 - 00:00 1.00 CEMEN~ PUMP INTRMI i I r 11!7!2005 00:00 - 01:00 ~ 1.00 CEMENT PUMP INTRM1 i i r ' i 01:00 - 01:15 0.25' CEMENT PULD INTRMI 01:15 - 04:30 ~ 3.25 CASE , NUND 1 INTRMI 04:30 - 04:45 ' 0.25 CASE OTHR I INTRMI 04:45 - 05:45 1.00' DRILL LOT INTRM1 ~ 05:45 - 09:15 i 3.50 DRILL a PULD ~, INTRM1 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 650 gpm @ 2800 psi w/ 85 RPM, Pulling speed of 35 to 45 ft/min. Slowed pulling speed to 3-5 ft/min. while circ 2 x Btm's up & hole clean f/ 4,187' to 4000'. Monitor well, POOH w/ 3 std's to check f/ swabbing-OK, Pump dry job, POOH to Shoe @ 2332' (Hole in very good shape). POOH 8 Lay down 5" drill pipe, 5" HWDP & Jars. Lay down NMDC's, Down load MWD tools, Lay down remainder of BHA #2. Lay down BHA tools from rig floor, Clean rig floor. Pull wear bushing (1 hr. to pull), Rig to run 7-5/8" casing. Ran 7 5/8" Weatherford float shoe, 2 jts 7 5/8", 29.7#, L-80, BTCM csg, float shoe and thread locked btm 3 corm, circ thru float equip and ck ok, RIH with 7 5/8" csg to 2,315', Ran 60 tandem rise centralizers on 1st 60 jts, 1-5' above shoe over stops 8~ 1 -10' above and below float collar, the remaining over collars, did not run any centralizers on both window jts. Circ btm's up, Stage rate f/ 3 bpm @ 300 psi to 5 bpm @ 350 psi. RIH w/ 7-5/8" csg to 3,860' with no problems, Break circ at rate of 3 bpm @ 500 psi-OK, Continue to RIH 8~ Tag btm @ 5,358' Rig down Frank's fill up toot, Blow down top drive, Rig up Dowell cement head. 'Circ & Cond. mud, Stage rate up f/ 3.5 bpm @ 450 psi to 6.5 bpm @ 425 psi, Reciprocate pipe 30' to 35' while circ Up 160K, Dn 95K. Held PJSM wf all rig personnel for cement job, initial MW out, 9.9 ppg, 75 vis, PV 18, YP 22, Conditioned mud to final MW of 9.2 ppg, 44 vis, PV 7andPVof13. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4 bpm @ 550 psi, 'Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100 at rate of 4 bpm @ 570 psi, Pumped 50 bbls of MudPush at 11.0 ,ppg at rate of 4.0 bpm @ 550 psi, Dropped btm plug then pumped 92.3 bbls, (230 sxs - 10% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, ave 4.8 bpm at 550 psi, Reciprocated pipe with full returns 30' to 35'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water. i Rig displaced cement with 9.0 ppg OBM, Bumped plug after pumping 234.2 bbls OBM (Total of 244.2 bbls) (96% pump eff.) ave 7 bpm while displacing cmt, Observed lift pressure f/ 500 psi to 800 psi prior to slowing pump rate to 3 bpm, Slowed pump rate to 3 bpm @ 550 psi with 10 bbls left to pump and bumped plug to 1100 psi, ck floats and held. CIP at 01:00 hrs, 11-7-05. Reciprocated pipe 30' to 35' until MudPUSH at shoe, then recip. 20' until Cmt at shoe, then recip. 10' 'until fast 30 bbls, then recip. 5' until last 10 bbls then stopped pipe, Landed csg with Shoe @ 5358', Float Collar @ 5268', Calc TOC @ 3052', Had full returns thru out job. Well static after shut down. 'Rig down cement head and equip. Installed 7-5/8" csg slips, Set slips with 60K over string weight (150K on slips), Cut off csg and LD cut off jt and installed pack-off, Test Packoff to 250 low & 3500 psi high f/ 10 min. Install wear bushing. Rig 8~ at 05:00 hrs. Perform LOT on 10-3l4"x 7-5/8" annulus of 440 psi, 9.2 ppg mud, 2202' TVD @ 10-3/4" shoe, = 13.0 ppg EMW used 5 bbls to perform test., Pump additional 25 bbls down annulus to insure no cement in annulus at rate of 2 bpm @ 680 psi. PJSM, Pick up & RIH w/ 120 jts. 4" drill pipe, Note; At 07:00 hrs, Printed: 12!29/2005 9:54.06 AM • ConocoPhiUips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 'From - To ~ Hours Code 'Sub.. Code 11/7/2005 ~ 05:45 - 09:15 ~ 3.501 DRILL PULD 09:15 - 10:15 ~ 1.00 10:15 - 18:00 7.75 18:00 - 21:00 3.00 21:00 - 00:00 ! 3.00 11/8/2005 ! 00:00 - 00:45 .00:45 - 03:30 03:30 - 04:00 i 04:00 - 04:30 04:30 - 05:30 05:30 - 06:45 06:45 - 07:45 07:45 - 11:00 11:00 - 12:00 0.75 2.75 0.50 0.50 1.00 1.25 1.00 3.25 1.00 0.50 11.50 112:00 - 12:30 12:30 - 00:00 DRILL PULD DRILL PULD DRILL PULD DRILL PULD DRILL PULD DRILL TRIP DRILL !TRIP Page 5 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Phase ~ Description of Operations INTRMI ~ Flushed 10-3/4"x 7-5/8" annulus with 120 bbls fresh water at rate of 2 bpm @ 660 psi (Total 150 bbls fresh water to flush annulus). INTRM1 Pick up Lo-Tad's and Sliders to rig floor f/ beaver slide. INTRMI ~ POOH picking up to-Tads (1 per std.) & Slides (3 per stand) & Rack back same, Note: At 10:23 hrs, Rig Little red service and freeze protect 10-314"x 7-5/8" annulus with 85 bbls diesel. INTRM1 'Pick up & RIH w/ 7 stands 4" HWDP, 6 stands 4-3l4" DC's & 4" HWDP Hybrid Push pipe, POOH & Stand back same. INTRM1 ;Make up BHA #3, 6-3/4" Bit, 4-3/4" 5200 GeoPiolt, NM Pony collar, DM collar, Stab, MWD tools, NMDC's, 1-HWDP, Jars, 4- HWDP, Upload MWD tools, Surface test MWD tools. INTRM1 ;Continue Make up BHA # 3. Make up 1 - jnt 4 1!2" Non Mag flex drill collar (30.79'), Crossover (1.07'), 1 - 4" HWDP (30.33'), 4 3/4" Drilling Jars (28.59'), and 4 - 4" HWDP (120.96'). Jars = 60.55 HRS to start. INTRM1 !Trip in hole from 367' - 3908' (3541), picking up singles of 4" DP XT-39 from pipe shed. INTRM1 Continue trip in hole running from derrick from 3908' - 5241' (1333') to j tag cement at 5241'. CEMENl?DSHO ~ INTRMI Drill hard cement from 5241' - 5268' (2T). Drill with 60 RPM's @ 3K torque, 250 GPM's - 1550 PSI. PU WT = 100K, SO WT = 75K, ROT WT = 85K. DRILL ~ CIRC INTRM1 Circulate bottoms up @ 60 SPM, 250 GPMs - 1400 PSI. RIGMNT RSRV INTRM1 RU and Slip & Cut 60' of driNing line. Inspect brakes, and service Top , 'Drive. CASE ' DEQT INTRM1 RU & test casing to 3000 PSI for 30 minutes. Record on chart. Good Test. Bleed pressures and RD test equipment. CEMEN DSHO , INTRM1 ~ Drill out Float equipment and shoe track f/ 5268' to 5358' and 20' of new hole from 5358' - 5378' .Parameters @ 70 SPM - 250 GPM's - 1900 PSI. 60 RPM's - 3K Torque. ART = .59 HRS. DRILL ..CIRC INTRM1 ' Circulate Bottoms up @ 330 GPM's - 3000 PSI. 92 SPM, Reciprocating & rotate drill string 60 RPM's - 3k Free torque. PU WT = 100K, SO WT = 75K, ROT WT = 85K. Jars @ 61.14 Total HRS, Bit Hrs = .59. Mud ' WT = 9.0 PPG, YP = 18, Visc = 90 DRILL LOT INTRM1 RU & and pump down drill pipe annulus to perform LOT to EMW of 14.9 , PPG wJ 9.0 ppg mud, 1123 psi & 3656' TVD. Bleed DRILL ;DRLG i PROD Directional drill 6 3/4" Hole in the "A" Lateral from 5378' - 6711' (1333'). TVD = 3671'. ART = 7.36 HRS, PU WT = 106K, SO WT = 66K, ROT WT = 84K, Torque off btm = 4K, Torque on bottom = 4.5K. WOB = 5-7K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3025 PSI. Total Jar Hrs = 68.5 Total Bit Hrs = 7.95 ECD at 10.6 PPG. Mud WT = 9.0 PPG Viscosity = 82, YP = 17. SPR's @ 6338' MD, 3670' TVD. Pump #1 - 25 SPM - 440 PSI, 35 SPM - 630 PSI. Pump #2 - 25 SPM - 440 PSI, 35 SPM - 640 PSI. Survey @ 6583' MD , 3670 TVD -Inc = 89.10 Deg. AZ = 3.31 Deg. MAX GAS = 65 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% increase in cuttings when sweep returned. 11 /9/2005 00:00 - 12:00 12.001 DRILL I DRLG I PROD 'Continue Directional drill 6 3/4" Hole in the "A" Lateral from 6711' - i 8411 (1700'). TVD = 3690'. ART = 8.32 HRS, PU WT = 107K, SO WT = 68K, ROT WT = 84K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3100 PSI. Total Jar Hrs = 76.82 Total Bit Hrs = 16.60 ECD at 11.1 ;PPG. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. SPR's @ 7772' MD, 3696' TVD. Pump #1 - 25 SPM - 490 PSI, 35 SPM - 690 PSI. Pump #2 Printed: 12/29/2005 9:54:06 AM ConocoPhillips Alaska Operations Summary Report Page 6 of 24 Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name:. Doyon 141 Rig Number: Date 11/9/2005 From - To 'Hours Code 'Code Phase 00:00 - 12:00 12.00 ~ DRILL DRLG I PROD 12:00 - 13:00 13:00 - 13:15 13:15 - 16:15 16:15 - 16:30 16:30 - 18:15 18:15 - 18:45 18:45 - 00:00 1.00 DRILL DRLG 0.25 DRILL OTHR 3.00 I DRILL I DRLG 0.251 DRILL I OTHR 1.751 DRILL DRLG 0.50 i DRILL ~ OTHR 5.251 DRILL ;DRLG 11!10/2005 00:00 - 12:00 12.00 DRILL I, DRLG PROD PROD PROD PROD PROD PROD PROD PROD Description.. of Operations - 25 SPM - 490 PSI, 35 SPM - 700 PSI. Survey @ 8220' MD , 3687 TVD -Inc = 86.66 Deg. AZ = 359.29 Deg. MAX GAS = 57 Units. Pumping weighted sweeps to control ECD and clean hole @ 7192', 7390', 7582', 8260'. Observe 10% - 20% increases in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 8411' - 8617' (206'). TVD = 3696'. ART = 1.0 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3100 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 69 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Stop drilling for Geologists to evaluate logs. Crossed fault @ 8855 MD 3710 TVD. Observed fault bigger than expected. 50' Throw. Continue Directional drill 6 314" Hole in the "A" Lateral from 8617' - 8933' (316'). ND = 3711'. ART = 2.05 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3200 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 71 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Also observed bigger sized shale cuttings in sweep. Stop drilling for Geologists to evaluate logs with town, as we went from sand to shale. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 8933' - 9127' (194'). TVD = 3702'. ART = .90 HRS, Torque off btm = 5K, Torque on bottom = 5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3400 PSI. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. MAX GAS = 71 Units. Pumping weighted sweeps to control ECD and clean hole. Observe 10% - 20% increases in cuttings when sweep returned. Stop drilling for Geologists to evaluate logs with town on orders for proceeding. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 9127' - 9752' (625'). ND = 3674'. ART = 3.52 HRS, PU WT = 129K, SO WT = 56K, ROT WT = 85K, Torque off btm = 5.5K, Torque on bottom = 5.5K. WOB = 5-20K, RPM's = 130 - 140, Pumps @ 93 SPM, 330 GPM's - 3400 PSI. Total Jar Hrs = 84.29 Total Bit Hrs = 24.07 ECD at 11.5 PPG. Mud WT = 9.0 PPG Viscosity = 68, YP = 17. Gels @ 19/27. SPR's @ 9707' MD, 3672' TVD. Pump #1 - 25 SPM - 550 PSI, 35 SPM - 750 PSI. Pump #2 - 25 SPM - 540 PSI, 35 SPM - 760 PSI. Survey @ 9671' MD , 3678 TVD -Inc = 92.18 Deg. AZ = 3.04 Deg. MAX GAS = 169 Units. BGG = 48 units. Pumping weighted sweeps to control ECD and clean hole @ 9513'. Observe 10% - 20% increases in cuttings when sweep returned. Continue Directional dri{I 6 3!4" Hole in the "A" Lateral from 9752' - 10971' (1219'). TVD = 3718'. ART = 7.10 HRS, PU WT = 145K, SO WT = 45K, ROT WT = 89K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 5-10K, RPM's = 130, Pumps @ 93 SPM, 330 GPM's - 3650 PSI. Total Jar Hrs = 91.39 Total Bit Hrs = 31.41 ECD at 12.19 PPG. Mud WT = 9.0 PPG Viscosity = 71, YP = 19. Gels @ 20130. SPR's @ 10673' MD, 3702' ND. Pump #1 - 25 SPM - 690 PSI, 35 SPM - 860 PSI. Pump #2 - 25 SPM - 690 PSI, 35 SPM - 850 PSI. Survey @ 10911' MD , 3718 TVD -Inc = 88.68 Deg. AZ = 356.33 Deg. printed: 12/29!2005 9:54:06 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Page 7 of 24 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date Fram - Ta ', Hours Code ~' Code .Phase 11/10/2005 00:00 - 12:00 12:00 - 15:15 15:15 - 16:45 16:45 - 20:00 20:00 - 00:00 11/11!2005 100:00 - 01:00 01:00 - 04:00 04:00 - 04:15 04:15 - 06:30 I 06:30 - 08:00 08:00 - 12:00 12:00 - 13:00 13:00 - 13:45 13:45 - 14:30 ';14:30-15:30 _- ~ -_ __ 12.00! DRILL DRLG I PROD 3.251 DRILL I DRLG 1.50? DRILL ICIRC 3.251 DRILL I WIPR 4.00! DRILL WIPR 1.00! DRILL ICIRC 3.001 DRILL I WIPR 0.251 DRILL I REAM 2.251 DRILL .ICIRC 1.501 DRILL ICIRC 4.001 DRILL (TRIP 1.00 DRILL 'TRIP 0.75 DRILL PULD 0.75 DRILL OTHR 1.00 DRILL PULD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD Description of Operations MAX GAS = 132 Units. Pumping weighted sweeps to control ECD and clean hole @ 9822', 10094', 10190', 10382'. Observe 10°I° - 20% increases in cuttings when sweep returned. Continue Directional drill 6 3/4" Hole in the "A" Lateral from 10971' - 11400 MD (429'). TVD = 3742'. ART = 2.59 HRS, PU WT = 150K, SO WT = 60K, ROT WT = 93K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 5-10K, RPM's = 130, Pumps @ 93 SPM, 330 GPM's - 4000 PSI. Total Jar Hrs = 94.22 Total Sit Hrs =34.0, ECD at 12.30 PPG. Mud WT = 8.9+ PPG Viscosity = 75, YP = 19. Gels @ 21 /28. SPR's @ 11400' MD, 3745' TVD. Pump #1 - 25 SPM - 860 PSI, 35 SPM - 1080 PSI. Pump #2 - 25 SPM - 860 PSI, 35 SPM - 1080 PSI. Survey @ 11400' MD , 3745.43 TVD -Inc = 86.38 Deg. AZ = 358.75 Deg. MAX GAS = 104 Units. Pumping weighted sweeps to control ECD and clean hole @ 11320'. Observe 10% - 20°to increases in cuttings when sweep returned. Pump 35 BBLS Hi Visc weighted sweep, and two bottoms up @ 93 SPM, 330 GPM - 4000 PSI. Rotate & Reciprocate drill string @ 130 RPM's with 6K torque. Obtain SPR's. Monitor well -Static. POOH on elevators observiing well taking proper hole fill and normal drag of 15 - 20K from 11400' - 7939' (3461'). Observed little overpull @ 9175' and weight fell off. At 7939' observed 20K overpull, 3 times. Attempt to wipe through spot without success. Screw into TD and BROOH from 7939' - 5358' (2581') =Shoe depth. Back ream at 93 SPM, 330 GPM's - 3150 PSI. RPM's of 130 with 6K torque. PU WT = 95K, SO WT = 75K, ROT WT = 85K @ 5850'. Pump a 35 BBL Hi Visc weighted sweep @ 93 SPM, 330 GPM - 2700 PSI, and 3 Bottoms up to observe 10-15% increase in cutting when sweep returned. Trip back in hole on elevators, observing clean hole conditions, and filling drill string every 25 stands. We did not need to pump into the hole as we had downweight of 55-60K. Make up top drive, wash & ream from 11259' -11400' (141'). Pumps @ 93 SPM, 330 GPM - 3950 PSI. Pump a 35 BBL Hi Visc sweep @ 93 SPM, 330 GPM - 3950 PSI, and 2 bottoms up observing 10% increase in cuttings at shakers and cleaned up. PU WT = 140K, SO WT = 65K, ROT WT = 65K, RPM's at 130 with 3-5K torque. Displace well from 8.9 PPG MOBM, to 8.8+ PPG SFMOBM, at 7 BPM - 84 SPM - 4000 PSI. Observed good displacement, no spills. Obtain SPR's @ 11395' MD, 3745' ND. Pump #1 = 25 SPM - 610 PSI. 35 SPM - 830 PSI. Pump #2 = 25 SPM - 650 PSI. 35 SPM - 840 PSI. Monitor well -static. POOH on elevators observing good clean hole conditions taking proper hole fill. Monitor well @ shoe 5358', static. Continue POOH to 2048'. (9352'). Continue POOH from 2048' - 366' (1682'). Rack back in derrick 4 jnts 4" HWDP (102.96'), 4 3/4" Drilling Jars 28.59'), 1 - jnt 4" HWDP (30.33'), crossover (1.07'), 3 - NMFC's (92.80'), breakout & lay down 4.688" Integral Blade Stabilizer (5.46'). Plug in and download MWD assembly. Continue breakout & lay down remaining BHA. Lay down 4 3/4" TM hang off collar (10.90'), 4 3/4" PWD collar (10.73'), 4 3/4" Slimphase 4 w/ DGR & EWR (24.18'), 4.3/4" Smart Stabilizer (3.59'), 4 3/4" DM Collar (8.56'), 4 3/4" GP NM Flex Pony collar (11.54'), 5200 series Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page s of 24 Operations Summary Report Legal Well Name: 1 J-164 Common Well Name: 1 J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n 1334@ppco.co m Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date From- To Hours Code Phase Description of Operations .. Code 11/11/2005 14:30 - 15:30 1.00 DRILL PULD PROD ~ Geo-Pilot (16.20 and Security DBS 6 3/4" FM2641 Bit (1.26'). Bit grade@ 1/1/RG/N/0/1/NO/TD. 15:30 - 16:00 0.50 DRILL RIRD ~ CMPLTN Clean and clear rig floor area, lay down tools. 16:00 - 17:45 1.75 LOG RURD CMPLTN PJSM with entire crew and SWS wireline crew. Discuss Safety issues and procedure. Rig up SWS wireliners, pull tools to rig floor, Make up USIT bond logging tools and test same. ,17:45 - 18:15 0.50 LOG ELOG CMPLTN Wirline in hole to 700' WLM, observe loss of telemetry. No ~ ~ i Communication with tools. " 18:15 - 20:00 1.75 LOG ELOG CMPLTN ; Knuckle WLOH with tools. Inspect & trouble shoot same. Observe Joint" on Centralizer failed and flooded tool. Remove Knuckle Joint and , replace Centralizer. Test tools. OK 20:00 - 00:00 4.00 LOG ELOG CMPLTN ' WLIH with USIT bond logging tools to locate and log form 5280' - 3080'. Logs indicated TOC @ 3360'. Effective TOC @ 3450'. 11/12/2005 00:00 - 00:15 0.25 LOG ELOG CMPLTN , Continue with USIT bond log. Logged from 5280' - 3080'. Logs indicated TOC @ 3360'. Effective TOC @ 3450'. Sent copy of logs to town engineer. 00:15 - 02:00 1.75 LOG . RURD CMPLTN ~ WLOH with tools, and lay down same. Rig down all logging equipment, and tools. Clear floor area. 02:00 - 02:30 0.50 CASE RURD CMPLTN Pull tools to floor and Rig up casing running equipment. Verify all ' equipment in pipe shed ready to run. ~ 02:30 - 02:45 0.25 ~ CASE SFTY , CMPLTN PJSM with entire crew. Discuss safety, and liner running procedure. 02:45 - 09:30 6.75 CASE PULR CMPLTN I Pick up 4 1/2" L80, 12.6# IBT slotted /blank liner assembly and RIH. Make up torque =3000 FUlbs. Run liner as per detail. MU Blank joint with ROT Silver Bullet Guide shoe and pup. Continue with blanks and '; slots space out as per engineer, with Swell packers installed @ 8555', and 9072'. Run 214 Jnts = 6696.97', with Spiral glider centralizers ~ floating on each jnt except the Constrictor packer jnts. (177 total) ' 09:30 - 10:30 1..00 ,CASE PULR CMPLTN ' Make up XO Bushing, Casing Seal Bore Ext, Flexlock Liner Hanger, RS Packoff Seal nipple, and HRD ZXP Liner Top PKR, with BOT running ; tools. 17 Total Constrictor packers run. Total BHA length of liner assembly = 6707.90'. PU WT = 85K, SO WT = 65K. i 10:30 - 12:00 1.50 CASE RUNL CMPLTN Continue RIH with Liner on Drill Pipe from 6708' - 8341' (1633'). PU WT = 92K, SO WT = 66K. Observed no issues when going through shoe area into open hole. i 12:00 - 14:30 2.50 CASE ' RUNL CMPLTN Continue RIH with Liner on Drill Pipe from 8341`- 11400' (3059'). Observed string taking weight at depths of 10280', 10644', 10915'and i ~ ~ 11005' having to work free each time to free up and RIH to tag bottom @ 11413' Liner Measurements. Position string with Guide Shoe at planned depth of 11400'. Constrictor Packer depths area as follows, Jnt # 7 - 11175', Jnt # 25 - 10615', Jnt # 36 - 10285', Jnt # 52 - 9785', Jnt # 55 - 9685', Jnt# 63 - 9445', Swell Packer @ 9072', and 8555', Jnt # 104 - 8125', Jnt # 115 - 7785', Jnt # 124 - 7505', Jnt # 146 - 6845', Jnt # 161 - 6383', Jnt # 171 - 6055', Jnt # - 179 - 5804', Jnt # 183 - 5708', Jnt # 187' - 5565', Jnt # 191 - 5445', and Jnt # 193 - 5375'. 14:30 - 15:15 0.75 CASE ~ OTHR CMPLTN ~ Lay down 1 Lo-Tad in connection at rig floor. PU WT = 140K, SO WT = 70K. Drop 1 1/2" ball, chasing with pump to 400 stks and pressure up to 2000 PSI. Set down 55K to set slips as per BOT rep, continue pressure up to 4200 PSI, to complete setting PKR. Bleed pressure and pull up to 115K allowing "dogs" to kick out. Re-Tag liner top to verify for space i out. Liner top = 4703.62'. 15:15 - 16:30 1.25 CASE CIRC . CMPLTN Rig up and pressure test down annulus to test PKR at 1000 PSI - 5 ! ~ , Minutes. Stand back one stand and CBU - 2000 STks @ 63 SPM -1000 PSI. Blow down Top Drive and Kill Line. Monitor well -Static. Printed: 12/29/2005 9:54:06 AM • ConocoPhiNips Alaska Operations Summary Report Legal WeNI Name: 1 J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Start: 10/31/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Rig Name: Doyon 141 Rig Number: Page 9 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Date From ' To ,Hours ;Code Code Phase Description of Operations 11/12/2005 16:30 - 21:30 5.00 CASE RUNL 'CMPLTN POOH, breakout and lay down all 40 Lo-Tads on drill string, leaving 30 stands of Sliders on Drillers side, and 10 stands of Slick DP on Off Drillers Side. Make Breaks, inspect BOT running tool assembly. 121:30 - 22:30 ~ 1.00 ~ CASE RURD ;CMPLTN Clean up all Lo-Tads, drained and wiped off for Target Zero, and 22:30 - 00:00 11 /13/2005 100:00 - 01:45 01:45 - 02:45 02:45 - 03:15 03:15 - 05:45 05:45 - 06:45 06:45 - 07:30 07:30 - 08:15 08:15 - 12:00 12:00 - 12:45 and lay down 80T remove from Rig Floor area. Clean & Clear floor , ~ running tools. 1.50' WINDO THR CMPLTN PJSM with entire crew and BOT rep, Sperry Sun MWD 8~ DD. Discuss Safety issues, and whipstock pick up procedure. Change elevators and 'pull tools to rig floor. 1.75 j WINDOV'I IPULD PROD2 PJSM with entire crew 8 BOT rep. Discuss Safety Issues and i Whipstock Make up Procedure. Make up Whipstock assembly & space out pipe. MU Seal Assembly with Stop Sub (1.92'), 4 5/8" Untoader Sub (5.20'), 2 - 3 1/2 IF pups (11.85', 4.75'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.08'),Bottom Trip Anchor (3.22'), Safety :Disconnect (2.70'), Ported Drain Sub (1.02'), Debris Barrier sub w/ Cup ~ (1.69'), & 5/8" Whipstock slide (15.47'). 6.156" Starting Mill (1.14'), 6.30" Lower Mill (5.51'), 6.750" Upper mill (5.82'), 1 - jnt 3 112" HWDP ~ (29.8'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR & RES (24.18'), TM HOC (10.90'), 2 - 4 3/4" Bumper jars (7.84', ~ 7.5T). 1.00 WINDO THR PROD2 Plug in and Up load MWD assembly. 0.50 WINDOV ~PULD PROD2 'Make up 2 stands of Hybrid Drill Collars (180.94') and Crossover (1.0T) i and MU Top Drive. Perform shallow pulse test on MWD with 78 SPM - ' 850 PSI, 275 GPM s. Good Test 2.50 WINDOVJ ITRIP PROD2 TIH at 2 minutes /stand as per BOT rep, from 395' - 4259'. (3864). 1.00 WINDOW OTHR ! PROD2 Perform Mad Pass from 4259' - 4325' (66') as per GEO @ 86 SPM - i 300 GPM , 1850 PSI. Orient whipstock face to 8 degrees left of high side while Mad Pass. 0.75 WINDO ETW ; PROD2 Continue TIH from 4325' - 4703' (378'). PU WT = 125K, SO WT = ~ 114K. Orient Whipstock face to 5 Degrres left of high side as per DD & Co. Rep. Tag top of A2 liner @ 4703' and set bottom trip anchor with 15k Set down. Pull 10K over to verify set. Shear bolt setting down 35-45K, 3 times, and pull up to neutral position. Rotate free at 4-6K free ~ ,Torque. Top of window = 4593'. Bottom = 4605'. 0.75' WINDO IRC ~ PROD2 Displace well from 8.9 PPG SFMOBM to 8.9 PPG MOBM @ 93 SPM - ' 330 GPM s , 2350 PSI. Mud @ YP - 19, Visc - 66. Totaf displacement ~ j = 183 BBLS. 3.75 WINDO TWP PROD2 Mill window as per BOT rep from 4593' - 4605' (12'), and open hole from 4605' - 4632' (27'), leaving 20' of gauged hole as per plan. Avg mill j speed through window = 5.50 ft/hr. Avg Weight on mills = 2-7K, with torque at 3-8K at 50-110 RPM's. 93 SPM - 330 GPM's and 2350 PSI. Obtain SPR's @ 4593 MD 3510 TVD Pump #1 = 25 SPM - 300 PSI, 35 ;SPM - 460 PSI. Pump #2 = 25 SPM - 310 PSI, 35 SPM - 450 PSI. PU WT = 105K, SO WT = 80K, ROT WT = 80K. 0.75 WINDOW STWP ~~ PROD2 Wash & ream through window area, while pump sweep to clean window. Work window with and without pump to verify good & clean. Pump sweep @ 90 SPM - 330 GPM, 2170 PSI, with 110 RPM's - 3-4K torque. 12:45 - 13:45 1.00 WINDOV~ICIRC PROD2 !Monitor well -static. Pump dry job, and blow down Top Drive. 13:45 - 15:30 ~ 1.75; WINDOWTRIP PROD2 POOH with milling assembly, monitor well at BHA -static. 15:30 - 16:00 0.50 WINDOWPULD ~ PROD2 PJSM, discuss Safety and Lay down procedure. Lay down both Bumper jars. 16:00 - 16:30 ~ 0.501, WINDOVVIOTHR ~ PROD2 Plug in and download MWD assembly Printed: 12/29!2005 9:54:06 AM ConocoPhillips Alaska Opera#ions Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11 /13/2005 11!14!2005 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon141 I From - To '! Hours ' Code 'Sub 'phase ~Code~' __ _ __ ~ __ ~~~I,I-- 16:30 - 17:15 0.75 ~ WINDOWI'ULD ~ PROD2 17:15 - 18:30 i 1.251 WINDOWPULD I PROD2 18:30 - 20:15 1.75 WELCT~ BOPE PROD2 20:15 - 23:00 2.75 i WELCT BOPE ; PROD2 23:00 - 00:00 I 1.001 WELCTLI BOPE I PROD2 00:00 - 00:30 0.50 DRILL PULD PROD2 00:30 - 01:45 , 1.25 DRILL .PULD I PROD2 01:45 - 02:45 1.00 ~ DRILL OTHR ~ PROD2 02:45 - 03:15 ; 0.50 I DRILL .TRIP i PROD2 03:15 - 05:30 i 2.25 I DRILL TRIP PROD2 05:30 - 07:00 ' 1.501 RIGMNT RSRV PROD2 07:00 - 07:15 0.25! DRILL TRIP PROD2 07:15 - 07:30 0.25 I DRILL I REAM PROD2 07:30 - 12:00 ; 4.501 DRILL I DRLG I PROD2 12:00 - 00:00 I 12.00! DRILL I DRLG I. PROD2 Page 10 of 24 Spud Dater 11!1!2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations Continue Breakout & lay down remaining BHA. Lay down 6.156" Starting Milt (1.14'), 6.30" Lower Mill (5.51'), 6.750" Upper mill (5.82'), 1 -jnt 3 1/2" HWDP (29.8'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 w/ DGR &RES (24.18'), TM HOC (10.90'). Upper mill gauged to full 6.750". Clean & clear rig floor. Send tools out. Pull stack washer to rig floor. RU, BOLDS 8~ pull wear bushing. MU stack washer and flush stack. Lay do stack washer. Rig up to test BOP's. Install test plug. Fill stack i~ lines. Test BOP stack, HCR's & manual valves. Test Choke mainfold valves, upper & lower IBOP valves, floor safety valve & dart valve. Pull test joint & test Blind rams. All tests 250 PSI Low / 3500 PSI High. Recorded on chart. Perform Accumulator test @ 1900 PSI after close, 2minutes -36 sec. 3000 PSI -3 minutes -12 sec. John Crisp with AOGCC waived witness of test. Pull test plug, install wear bushing & RILDS. Rig down all test equipment. Blow down equipment. Clean & Clear Rig Floor area. Send tools out. Pull tools to Rig Floor. PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA #6. Make up 6 314" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.83'), 4 3/4" Non Mag float sub (1.41'), 4 3/4" Integral Blade stabilizer (5.46'), DM HOC (8.52'), S{imphase 4 w! DGR &RES (24.18'), PWD Collar (10.73'), TM HOC (10.90'), 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.66'), 1 - Jnt of 4" HWDP (30.33'), 4 314" Drilling jars 94.55 Hrs on 11/11/05) (28.59'), 4 - Jnts 4" HWDP (120.96'). Total BHA length =369.17'. Plug In and Upload MWD assembly RIH to 369' and perform shallow pulse test @ 85 SPM - 300 GPM - 2225 PSI. Continue Trip In hole from 369' - 1953' (1584'). MU 4 3/4" Andergauge Agitator and Shock Sub with crossovers. Agitator = 1975.55' from bit. Continue TlH to 4588'. Slip & Cut 60' of drilling line. Inspect Saver sub. Good. PU WT = 95K, SO WT = 75K. Orient toolface to High Side, pumps off, slide through window area from 4592' - 4605' with no issues to bottom of gauged hole @4623'. Pumps on @ 300 GPM's - 3450 PSI. Obtain clean hole ECD @ 9.64 PPG before begin drilling. MW = 9.0 PPG. YP = 17, Visc = 72 Wash 8~ Ream from 4623' - 4632' (9'). Pumps @ 86 SPM, 300 GPM's - 3450 PSI. Directional drill 6 3/4" Hole in the "B" lateral from 4632' - 4962' MD (330'). ND = 3523'. ART = 1.18 HRS, AST = 1.64 HRS, ADT = 2.82 HRS. PU WT = 95K, SO WT = 72K, ROT WT = 83K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 5-10K, RPM's = 80, Pumps @ 86 SPM, 300 GPM's - 3450 PSI. Total Jar Hrs = 97.04. Total Bit Hrs = 2.82 ECD at 9.72 PPG. Mud WT = 8.9 PPG Viscosity = 72, YP = 18. SPR's @ 4679' MD, 3526' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 890 PSI. Pump #2 - 25 SPM - 630 PSI, 30 SPM - 870 PSI. Continue Directional drill 6 3/4" Hote in the "B" lateral from 4962' - 5581' MD (889'). TVD = 3523'. ART = 9.50 HRS, AST = .60 HRS, ADT = 10.10 HRS. PU WT = 96K, SO WT = 71 K, ROT WT = 83K, Torque off Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page 11 of 24 Operations Summary Report Legal Well Name: 1 J-164 Common W eII Name: 1 J-164 Spud Date: 11/1/2005 Event Nam e: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n 1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To ' Hours Code I Code I Phase ! Description of Operations 11 /14/2005 12:00 - 00:00 12.00 DRILL ;DRLG i PROD2 ~~ btm = 4K, Torque on bottom = 4-5K. WOB = 2-12K, RPM's = 75-80, i 'Pumps @ 86 SPM, 300 GPM's - 3550 PSI. Total Jar Hrs = 109.96. Total Bit Hrs = 12.92 ECD at 9.81 PPG. Mud WT = 8.9 PPG Viscosity = 71, YP = 18. SPR's @ 5333' MD, 3532' TVD. Pump #1 - 25 SPM - ' ' 600 PSI, 35 SPM - 880 PSI. Pump #2 - 25 SPM - 620 PSI, 30 SPM - ' ' ' 910 PSI. Observed Drilling through Concretions at 5082 - 5090 (8 ), ~ ~ 5106' - 5128' (22'), 5235'-5248' (13'), 5440' - 5445' (5'). Max Gas units = ' 135 11/15/2005 00:00 - 12:00 12.00' DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole in the "B" lateral from 5581' - ~ 6581' MD (1000'). ND = 3528'. ART = 7.90 HRS, AST = 2.30 HRS, 'ADT = 9.39 HRS. PU WT = 100K, SO WT = 69K, ROT WT = 81 K, ` Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-15K, RPM's = 75-80, Pumps @ 86 SPM, 300 GPM's - 3700 PSI. Total Jar Hrs = ' 119.35. Total Bit Hrs = 22.31 ECD at 10.20 PPG. Mud WT = 8.8 PPG Viscosity = 65, YP = 18. SPR's @ 6264' MD, 3527' TVD. Pump #1 - 25 SPM - 630 PSI, 35 SPM - 810 PSI. Pump #2 - 25 SPM - 630 PSI, 30 'SPM - 860 PSI. Observed Drilling through Concretions at 5581' - 5589' ~ ' (8'), 5702' - 5705' (3'), 5778'-5782' (4'), 5784' - 5793' (9'), 5809'-5822' (13'), 5993'-6001' (8'), 6240'-6243' (3'), 6436'-6440' (4'), 6506'-6518' ~ (12'), 6524'-6533' (9'). Max Gas units = 131. Survey @ 6499' MD, 3525' ~ ' ~ TVD = 89.73 Deg Inc, AZ - 358 Deg. , 12:00 - 00:00 12.00 DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole in the "B" lateral from 6581'-7655' ~ MD (1074'). ND = 3541'. ART = 6.85 HRS, AST = .62 HRS, ADT = ' ~ 7.47 HRS. PU WT = 106K, SO WT = 64K, ROT WT = 84K, Torque off btm = 4K, Torque on bottom = 4-5K. WOB = 2-15K, RPM's = 75-80, ' j ,Pumps @ 91 SPM, 320 GPM's - 3750 PSI. Total Jar Hrs = 126.82. Total Bit Hrs = 29.13 ECD at 10.34 PPG. Mud WT = 8.8 PPG Viscosity ~ = 66, YP = 18. SPR's @ 7480' MD, 3535' TVD. Pump #1 - 25 SPM - i 630 PSI, 35 SPM -840 PSI. Pump #2 - 25 SPM - 690 PSI, 30 SPM - 910 PSI. Observed Drilling through Concretions at 6809' - 6814' (5'), 6774' - 6784' (10'), 6983' - 6986' (3'), 7634'-7640' (6'). Max Gas units = + ~ 248. Survey @ 7526' MD, 3536' ND = 87.86 Deg Inc, AZ - 1.91 Deg. 11/16/2005 00:00 - 12:00 12.00 ;DRILL DRLG PROD2 ~ Continue Directional drill 6 3/4" Hole in the "B" lateral from 7655' -8813' ~ i MD (1158'). ND = 3575'. ART = 6.87 HRS, AST = 1.82 HRS, ADT = 8.69 HRS. PU WT = 103K, SO WT = 65K, ROT WT = 81 K, Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-15K, RPM's = 90, Pumps @ 91 SPM, 320 GPM's - 3900 PSI. Total Jar Hrs = 135.51. Total Bit Hrs = 37.82 ECD at 10.41 PPG. Mud WT = 8.8 PPG Viscosity = 63, YP = 18. Gels 17/25 SPR's @ 8320' MD, 3550' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 850 PSI. Pump #2 - 25 SPM - 650 PSI, 30 ' '~ SPM - 860 PSI. Observed Drilling through Concretions at 7702' - 7709' ~ (7'), 7989' - 7998' (9'), 8225' - 8232' (7'), 8236'-8260' (24'), 8476'-8492' (16'), 8682'-8700' (18'), 8705'-8723' (18'), 8749'-8755' (6'). Max Gas ~ ;units = 243. Survey @ 8645' MD, 3570' TVD = 87.68 Deg Inc, AZ - i ~ I~ 357.0 Deg. 12:00 - 00:00 12.00 DRILL DRLG PROD2 Continue Directional drill 6 3/4" Hole in the "B" lateral from 8813' - 9880' MD (1067). ND = 3575'. ART = 5.60 HRS, AST = 1.94 HRS, I 'ADT = 7.54 HRS. PU WT = 110K, SO WT = 60K, ROT WT = 84K, ~ Torque off btm = 5K, Torque on bottom = 5K. WOB = 2-15K, RPM's = 90, Pumps @ 88 SPM, 310 GPM's - 3850 PSI. Total Jar Hrs = 143.05. i Total Bit Hrs = 45.20 ECD at 11.0 PPG. Mud WT = 8.85 PPG Viscosity i = 62, YP = 18. Gels 17/25 SPR's @ 9722' MD, 3536' TVD. Pump #1 - ~ 25 SPM - 650 PSI, 35 SPM - 900 PSI. Pump #2 - 25 SPM - 680 PSI, 30 Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page 12 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT - DI Contractor Name: n1334@ Rig Name: Doyon 1~ Date 11 /16/2005 11 /17/2005 11 /18/2005 From - To Hours 12:00 - 00:00 12.00 i 00:00 - 12:00 i 12.00 12:00 - 00:00 ! 12.00 00:00 - 01:15 !, 1.25 01:15 - 05:30 '~ 4.25 05:30 - 06:30 1.00 06:30 - 08:00 1.50 08:00 - 10:30 ~ 2.50 10:30 - 12:00 1.50 12:00 - 18:00 i 6.00 18:00 - 18:30 0.50 i Spud Date: 11/1/2005 BILLING Start: 10/31/2005 End: 12/5/2005 ~pco.com Rig Release: 12/5/2005 Group: ~1 Rig Number: Code 'Code',, Phase Description of Operations DRILL DRLG ~ PROD2 SPM - 920 PSI. Observed Drilling through Concretions at 9600' - 9606' (6'). Max Gas units = 167. Survey @ 9770' MD, 3536' ND = 91.14 Deg ! . 'Inc, AZ - 358.45 Deg. DRILL ' DRLG i PROD2 Continue Directional drill 6 3/4" Hole in the "B" lateral from 9880' - 10748' MD (868'). ND = 3591'. ART = 7.57 HRS, AST = .95 HRS, ADT = 8.52 HRS. PU WT = 118K, SO WT = 57K, ROT WT = 82K, Torque off btm = 6K, Torque on bottom = 6K. WOB = 2-15K, RPM's = 95, Pumps @ 86 SPM, 300 GPM's - 3900 PSI. Total Jar Hrs = 151.57. Total Bit Hrs = 53.72 ECD at 10.92 PPG. Mud WT = 8.8 PPG Viscosity = 66, YP = 17. Gels 17!26 SPR's @ 10189' MD, 3557 ND. Pump #1 - 25 SPM - 770 PSI, 35 SPM - 920 PSI. Pump #2 - 25 SPM - 710 PSI, 30 SPM - 970 PSI. Observed Drilling through Concretions at 9942' - 9956' (12'), 10146'-10150' (4'), 10184'-10191' (7'), 10264'-10281' (17'), ;10376'-10381' (5'), 10395'-10460' (65'), 10471'-10495 (24'). Max Gas i ~ units = 85. Survey @ 10607' MD, 3580' ND = 85.40 Deg Inc, AZ - 359.00 Deg. DRILL DRLG PROD2 I, Continue Directional dri116 3/4" Hole in the "B" lateral to TD from i 10748'-11472' MD (724'). TVD = 3612'. ART = 7.45 HRS, AST = .69 ' HRS, ADT = 8.14 HRS. PU WT = 140K, SO WT = 55K, ROT WT = 90K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 2-15K, RPM's = 95, Pumps @ 86 SPM, 300 GPM's - 4000 PSI. Total Jar Hrs = 159.71. Total Bit Hrs = 61.86 ECD at 11.34 PPG. Mud WT = 8.85 PPG Viscosity = 70, YP = 17. Gels 17/26 SPR'S @ 11017' MD, 3596' ND. Pump #1 - 25 SPM - 760 PSI, 35 SPM - 1040 PSI. Pump #2 - 25 SPM - 790 PSI, 30 SPM - 1080 PSI. Observed Drilling through 'Concretions at 10497 - 10503' (6'), 10513'-10525' (12'), 10582'-10600' (18'), 10699'-10715' (16'), 10780'-10800' (20'), 11095'-11102' (7'), 11186'-11188' (2'), 11297'-11303' (6'), 11325'-11327' (2'), 11338'-11345' (T). Max Gas units = 75. Survey @ 11472' MD, 3612' TVD = 83.37 Deg Inc, AZ - 2.88 Deg. Last survey @ TD and projected Inc and AZ. DRILL CIRC PROD2 Pump 35 BBL Hi Visc weighted sweep + 2 Btms up @ 84 SPM- 300 ' ~, GPM's - 4100 PSI. Reciprocate & Rotate drill dtring @ 100 RPM's, 6K Torque. PU WT = 140K, SO WT = 55K, ROT WT = 81 K. Observe 15% increase in cutting when sweep across shakers, and shakers clean. DRILL WIPR PROD2 Monitor well -Static. BROOH from 11472' - 8791' (2681'). Back ream rate at 86 SPM - 300 GPM's - 3900 PSI. Torque = 6K. 80 RPM's. PU WT = 107K, SO WT = 64K @ 8791'. Observed clean hole and no issues. Finish circulating bottoms up and shakers clean. Hole took ' ,proper fill RIGMNT RGRP PROD2 ;Observed Swivel packing leaking. Change out swivel packing. DRILL WIPR PROD2 Trip back in hole on elevators from 8791' - 11472' (2681'). Observed clean hole conditions. PU WT = 125K, SO WT = 52K. DRILL ~ CIRC ' PROD2 Pump 35 BBL Hi Visc weighted sweep + 2 Btms up @ 85 SPM- 300 ii GPM's - 4000 PSI. Reciprocate & Rotate drill dtring @ 95 RPM's, 6K ~ Torque. PU WT = 140K, SO WT = 55K, ROT WT = 81 K. Observe 15% i increase in cutting when sweep across shakers, and shakers clean. DRILL CIRC ~ PROD2 !Displace well from 8.85 PPG MOBM to 8.80 PPG SFMOBM @ 81 'SPM -4000 PSI. 95 RPM's, 5-6K torque. DRILL ~, TRIP PROD2 POOH on elevators form 11472' - 1975' (9497). Observe clean hole ,conditions and hole taking proper fill. DRILL TRIP 'i PROD2 !Make up Top drive and pump down drill string to verify Anderguage ~ Agitator working. Observe Agitator working with "LESS" vibration than normal or expected. Breakout and lay down Agitator & Shock Sub with Printed: 12/29!2005 9:54:06 AM • ConocoPhillips Alaska Page 13 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date 11 /18/2005 From - To j Hours' 18:00 - 18:30 0.50 18:30 - 20:15 1.75 Code 'Sub. ..Code DRILL TRIP DRILL PULD 20:15 - 21:15 1.00 DRILL ' OTHR 21:15 - 22:00 0.75 DRILL PULD 22:00 - 22:30 I 0.50 DRILL I PULD 22:30 - 23:00 ~ 0.50 RIGMNT' RSRV 23:00 - 23:30 0.50, WINDO ULD 23:30 - 00:00 i 0.50 j WINDO ULD 11/19/2005 00:00 - 00:45 0.75 WINDOV'I IPULD 00:45 - 05:15 05:15 - 05:30 05:30 - 06:15 06:15 - 06:45 06:45 - 07:30 07:30 - 10:15 10:15 - 11:15 11:15 - 12:00 12:00 - 12:30 4.50 0.25 0.75 0.50 0.75 2.75 1.00 0.75 0.50 12:30 - 13:30 ! 1.00 13:30-14:30 1.00 P P P P C P WINDO ~ ULD WINDO~ULD CMPLTNI FCO Phase Description of Operations PROD2 PROD2 PROD2 PROD2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLTNI FCO I CMPLT2 14:30 - 16:30 2.00 CMPLTN! TRIP 'CMPLT2 16:30 - 18:00 1.50 CMPLTNI FCO CMPLT2 crossovers. Continue POOH from 1975' - 95' (1880'). Stand back 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.66'), 1 - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars (159.71 Hrs on 11/18/05) 28.59'), 4 - Jnts 4" HWDP (120.96'). Plug in and download MWD assembly. Continue POOH, breakout and lay down BHA #6. Lay down 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.83'), 4 3/4" Non Mag float sub (1.41'), 4 3/4" Integral Blade stabilizer (5.46'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES ( 24.18'), PWD Collar (10.73'), TM HOC (10.90'). Bit Gauged to 2 / 2 / WT/T/X/I/NO/TD. Clear & Clean Rig Floor area. Send tools outside. Service Top Drive, and Lubricate rig. Inspect Swivel packing. Pull tools to rig floor for next BHA. PJSM with crew & BOT REP. Discuss safety issues, new hands on rig crew, and procedure for picking up next BHA. PJSM -New Crew, Discuss Safety issues, weather @ -34 Degrees and Procedure for PU whipstock retrieving assembly. MU BHA. MU Retrieving Hook (7.5'), 1 -jnt 3 1/2" HWDP (29.50'), 4 3/4" NM Float sub (1.41'), 2 - 4 3/4" Bumper jars (7.84', 7.57'), 4 3/4"Oil Jars 11.14'), Crossover (1.66'), 2 -stands Hybrid Push Pipe (180.94'). Trip in hole from 248' - 3051' (2803'), stopping on each joint to reposition and inspect, and retorque each super slider, 90 total. Fill drill string with mud, and blow down Top Drive. . Continue TIH from 3051' - 4600' (1549'). PU WT = 102K, SO WT = 80K. Pump @ 313 GPMs - 1650 PSI. Locate & hook whipstock @ 4596' (slot). Pull up to 50K over to jar 3 times and observe assembly pull free @ 190K, @ 4597' Circulate Bottoms up @ 313 GPM's - 1600 PSI. No Gas observed, well static. Biow down Top Drive. PU WT = 108K. POOH from 4597' - 247' (4350'), slow at first to observe well taking correct hole fill, not swabbing. Breakout 8~ lay down Retrieving Hook assembly. Breakout & lay down whipstock and space out assembly. Crew change. Continue Breakout & lay down whipstock and space out assembly. Observe debris, sand ,shale above and below Debris Barrier cup, with quite a bit of clay and sand on Space out pipe as well. Observed Debris cup folded over. Recovered a "Small Fitting" on cup. ??? Pictures sent to town. Clean & clear rig floor area. perform thorough Inspection of Top Drive. Observed no missing fittings. Pull tools to rig floor. MU clean out BHA. MU 6 3/4" HTC STR09 Roller Cone insert Bit (.80'), Bit sub (2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'), 4 3/4" Drilling Jar (156.52 HRS on 11/18/05) (28.59'), and 4 -jnts 4" HWDP (120.96'). Total BHA = 282.62'. Trip in hole from 283' - 4575' (4292'). Break circulation @ 80 SPM - 1290 PSI, UP WT = 103K, SO WT = 80K, ROT WT = 84K. Wash down from 4575' - 4703' (128'). Continue rotate and wash from TOW @ 4593' back down to top of PKR at 4703'. Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Page 14 of 24 Legal Well Name: 1 J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 .End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date 11/19/2005 ` From - To , Hours j Code ' Code ', Phase - - _ _ ~_ .. _- _ I 16:30 - 18:00 1.50 CMPLTN FCO 18:00 - 21:00 3.00 CMPLTNI TRIP 21:00 - 23:30 2.50, RIGMNT RSRV 23:30 - 00:00 I 0.501 CMPLTN RURD 11 /20/2005 i 00:00 - 04:15 04:15 - 04:30 04:30 - 07:00 07:00 - 08:30 08:30 - 12:00 12:00 - 13:00 13:00 - 15:30 4.25; CMPLTNI RUNT 0.251 CMPLTN' RUNT i 2.50 CMPLTN RUNT 1.50 CMPLTN RUNT 3.50 CMPLTN, TRIP 1.00 CMPLTN~TRIP 2.50 CMPLTN, OTHR CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 15:30 - 17:30 I, 2.00' CMPLTNI TRIP !CMPLT2 17:30 - 18:30 i 1.00 CMPLTN RURD CMPLT2 18:30 - 19:30 ~ 1.00 CMPLTN RURD CMPLT2 19:30 - 20:00 20:00 - 21:30 0.50 CMPLTNI SFTY CMPLT2 1.501 CMPLTN: PULD CMPLT2 Description of Operations Observed lots of sand across shakers at bottoms up, work drill string and circulate until shakers clean. Trip out of hole from 4703' - 383' (4420'). Breakout & lay down clean out assembly. Lay down 6 3/4" HTC STR09 Roller Cone insert Bit .80'), Bit sub (2.02'), 4 3/4" Integral Blade Stabilizer (5.46'), 3 - NM Flex drill collars (92.80'), Crossover Sub (1.66'), 1 - 4" HWDP (30.33'), 4 3/4" Drilling Jar (156.52 HRS on 11/18!05) (28.59'), and 4 -jnts 4" HWDP 120.96'). Total BHA = 282.62'. Clear & clean rig floor area. Change out Saver sub on Top Drive. Pull tools to floor & RU casing running equipment. Check out afl Liner running order, pups, and Hook hanger assembly in Pipe shed. PJSM with new crew. Discuss safety issues and procecure for PU 4 1/2" Liner assembly. Make up Guide shoe joint with ROT Silver Bullet Guide shoe and crossover (31.86'). Continue RIH with 4 1/2" Blanks / Slots as per liner detail. Run a total of 109 Blanks, 109 Slots, with 2 Swell packers spaced out to locate at 9462' & 8804'. We tagged the A2 liner top Crossover, and pulled back to rotate 1/2 RH turn in string and went through window on second attempt. Continue RIH picking up 4 1/2" liner as per detail, from 4595' - 6833' (2238'}. PJSM. Discuss safety issues and procedure for making up Slim Hole MWD assmy. Make up Baker Model B1 FHH Hook Hanger assembly, pups, with crossoverjoint, Casing Swivel, running and setting tools. Make up Ball seat shear sub and Slimhole MWD assembly, oriented 180 DEG from Hook on hanger. Total Hook Hanger assembly = 55.70'. Continue TIH with liner assembly on drill pipe from 6877' - 9681' (2804'). Perform pulse test on MWD assembly, good test, and fill drill string every 10 stands @ 128 GPM's -700 PSI. Continue TIH with liner on Drill pipe from 9681' - 11421' (1740'). Fill every 10 stands. Break circulation at 125 GPM - 1100 PSI. Orient to 10 Degrees left of high side, slack off to liner depth at 11452'. Hook window. PU and orient 180 degrees out and slack off to RIH past bottom of window to liner depth of 11460'. Pull Back up, reorient to 10 degrees left of high side and land Hook Hanger on bottom of window @ 4605'. Set down 30K. Drop 1 3/4" ball and chase with 3 BPM - 1100 PSI. Slow pump to 1 BPM -observe ball land & seat, pressure to 2800 PSI. Shear off & pull up to 110K. Attempt to shear ball with pressure to 4200 PSI. Not sheared. Pull 1 stand, RU test pump and shear ball at 4800 PSI. Rig do test pump & blow down lines. Top of hook hanger @ 4587.37' POOH with running and setting tools. Breakout, lay down and inspect running and setting tools. Clean & clear rig floor area. Pull tools to floor. RU casing running equipment for LEM run. PJSM with entire crew, BOT rep. Discuss safety Issues and procedure for LEM make up with 2 7/8" inner string. Make up LEM assembly. Baker Seal assembly (3.26'), Crossover joint IBT x STL (42.74'), 4 112" IBT pup (30.84'), Camco "DB" Nippie 3.563" ID (1.52'), 4 1/2" IBT JNT (31.09'), 3 - 4 1/2" IBT pups (14.08',9.83',3.82'), LEM assembly (34.62'), 6 - JNTs of 4 1/2" IBT (182.35'), 4 1/2" IBT pup (5.80'), Baker Casing Swivel (2.81'), XO Bushing (1.41'), 109-47 Casing Seal Bore receptacle (19.65'). Set low Printed: 12!29/2005 9:54:06 AM • ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon141 Date ,From - To !Hours' _- _~ 11/20/2005 20:00 - 21:30 1.50 21:30 - 00:00 ~ 2.50 , i 11 /21 /2005 00:00 - 00:30 I 0.50 00:30 - 01:15 01:15 - 01:45 01:45 - 02:30 02:30 - 03:15 03:15 - 05:15 05:15 - 08:30 08:30 - 11:15 11:15 - 12:00 12:00 - 12:30 12:30 - 14:15 14:15 - 16:30 16:30 - 17:00 17:00 - 17:30 17:30 - 19:00 Code ~, Code Phase -- __ CMPLTN PULD CMPLT2 CMPLTN PULD ~ CMPLT2 i CMPLTN PULD CMPLT2 0.75 I CMPLTNI PULD 0.501 CMPLTN PULD 0.75 RIGMNT RSRV 0.75 RIGMNT RSRV 2.00, WAITON; EOIP 3.251 CMPLTNI PULD 2.751 CMPLTNTRIP 0.75 I CMPLTNI RUNT 0.501 CMPLTNI PCKR 1.75 CMPLTN TRIP 2.25 CMPLTN PULD CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 CMPLT2 0.50 I CMPLTNI PULD 'CMPLT2 0.501 WINDOWPULD I PROD3 1.50'; WINDOWPULD PROD3 Page 15 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations in slips for inner string. RU 2 7/8" inner string tools. MU Ball seat and XO (2.49'), on first joint. Observe joint galded when torque applied. Breakout ~ change out joint and inspect crossover. Good. Make up first joint. MU torque = 1500 ft/Ibs. RIH with 5 joints of 2 7/8" 8.7# inner string tubing. Continue RU 2 7!8" inner string tools. MU torque = 1500 ft!{bs. RIH with 3 more joints of 2 7/8" 8.7# inner string tubing. Observe Tag up solid on inner string. Calculate that the Collars on 2 7/8" tbg were 3.68" OD. ID of LEM = 3.68", and DB nipple ID = 3.56". We tagged with the Shear Sub (3.66") on the LEM. Rig Up & POOH with 8 joints of 2 7/8" Inner String. Breakout & lay down Shear Sub assembly. Rig down 2 7/8" equipment to run inner string.Clear & clean floor area. Slip & Cut drilling line. Inspect brakes on draw works. Service Top Drive. 'Wait on 2 3/8" inner string pipe, and equipment form Baker Fishing shop. Load pipe shed with 2 3/8" DP. Pull handling tools to rig floor. Strap all !tools and pipe. MU Mule shoe & Shear Sub assembly with 11 jnts of 2 3/8" spaced out to 13' below seals. MU ZXP packer assembly (18.90'). PU WT = 45k, SO WT = 45K. Total BHA = 420.97' TIH with LEM assembly & inner string from 421' -4685' (4264'). PU WT = 118K, SO WT = 93K. Rig up and pump down string @ 160 GPMs- 850 PSI to wash from 4685' -4748' (63'). wITH pumps off, seals going into CSB and observe "LAtch Up" on Hook Hanger with LEM @ 4749' as per detail. Drop 1 3/4" ball down string. Allow ball to fall chase with 2 BPM and observe ball landed. Pressure up to 3000 PSI to set ZXP packer, continue pressure to 4000 PSI to !release setting tool. Pull up to 115K, bleed pressure. RU and pump down annulus to pressure test ZXP to 1000 PSI for 5 Minutes. Record on chart. Bleed all pressures and blow down lines. B Lateral Liner top { @ 4345.76'. POOH with LEM Running and setting tools, from 4345' - 384' (3961'). PJSM, discuss safety issues, and procedure for laying down tools. Lay ,down & inspect running tool. Rig up and lay down 2 3/8" inner string ' with shear sub and mule shoe. Clean & clear floor area, lay down all 2 3/8 handling equipment and .tools. PJSM with crew, MWD and BOT reps. Discuss Safety issues and procedure for PU Whipstock assembly and space out pipe. Pull all tools and equipment to rig floor. 'Make up D Lateral whipstock assembly. Make up Whipstock assembly ~ & space out pipe. MU Seal Assembly with Stop Sub (1.92'), 4 5/8" Unloader Sub (5.18'), Kelly saver sub (2.70'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.00'), Bottom Trip Anchor (3.22'), Safety ~ Disconnect (2.63'), Ported Drain Sub (1.50'), Debris Barrier sub w/ Cup (1.55'), & 5/8" Whipstock slide (14.10'). 6.156" Starting Mill (1.14'), 16.30" Lower Mill (5.46'), 6.750" Upper miN (5.84'), 1- jnt 3 1/2" HWDP (29.50'), 4 3/4" NM Float sub (1.41'), DM HOC (8.56'), Slimphase 4 wl DGR & RES (24.18'), TM HOC (10.90'), 2 - 4 3/4" Bumper jars (7.84', 7.57')Crossover IF x XT39 (1.66'), 2 stands 4 3/4" Hybrid Push j pipe(180.94'). Total BHA = 381.43' Printed: 12/29/2005 9:54:06 AM • CanocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 11/21/2005 19:00 - 19:45 19:45 - 20:45 20:45 - 00:00 11 /22/2005 00:00 - 01:15 01:15 - 01:45 101:45 - 02:15 02:15 - 03:00 03:00 - 09:00 09:00 - 09:45 09:45 - 13:30 13:30 - 14:00 14:00 - 16:00 16:00 - 19:15 19:15 - 21:00 21:00 - 21:30 21:30 - 00:00 11 /23/2005 00:00 - 12:00 12:00 - 21:00 21:00 - 21:30 r 21:30 - 00:00 11/24/2005 00:00 - 01:30 01:30 - 05:30 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon 141 Hours '; Code Phase ~ ,Code ~ 0.75 _- WINDO THR ~ ____ PROD3 1.00 WINDO RIP PROD3 3.25 WINDOV~ ITRIP PROD3 1.251 WINDO W TRIP i PROD3 0.50 WINDO RIP PROD3 0.50 WINDO ETW PROD3 0.751 WINDOW CIRC iPROD3 6.00 WINDOV ~STWP PROD3 0.75 WINDO i IRC PROD3 3.75 ~ WINDO ~RIP ~ PROD3 0.50, 2.00 WINDOW WINDOW OTHR OTHR PROD3 PROD3 3.25 DRILL PULD PROD3 1.75 ~ DRILL ' TRIP ; PROD3 0.50 DRILL REAM PROD3 2.50 ~ DRILL ~ DRLH PROD3 i 12.00 i i DRILL DRLH PROD3 9.00 i DRILL .DRLH PROD3 0.50 DRILL 2.50 DRILL 1.50 DRILL 4.00 WELCTL ~DEOT IPROD3 TRIP PROD3 .TRIP PROD3 BOPEIPROD3 Page 16 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations Plug in and up load MWD assembly Pick up last stand of push pipe and perform shallow pulse test @ 300 Gpms - 1000 PSI. TIH with whipstock assembly and space out pipe at 2 minutes /stand as per BOT rep. from 381' - 3548' (3167'). Fill drill string @ 2250'. Wash & MADD Pass K-13 f/ 3,361' to 3,542'. Continue to RIH to 4,212'. Orient Whipstock to 11 deg. left of highside, Set same @ 4,248', Up wt. 110K, Dn 87K. Change over to 8.8 ppg MOBM at rate of 298 gpm @ 2200 psi. Mill 6-3/4" window f/ 4,248' to 4,260', Continue to mill to 4,294' with 6-3/4" gauged hole to 4,284'. Pump Hi-vis weighted sweep & Circ hole clean at rate of 302 gpm @ 2000 psi, 60 RPM, Up 105K, Dn 93K, Rot 97K. POOH, Lay down Jars & Bumper sub, Down load MWD tool, Lay down & gauge mill- OK. Lay down tools from floor, Clean floor. Pull wear bushing, Flush out stack, Function all rams, Reflush stack, Rig down ,Set wear bushing. PJSM, Pick up 6-3/4" HTC, HCM 5052 Bit, 5200 series GeoPilot, Load MWD tools, Shallow test tools. RIH to 4,196', Fill pipe & Check MWD @ 2,700'. Break circ, Work thru window @ 4,248' to 4,260' - No Problem, RIH to 4,284', Ream out of gauge hole to 4,294'. Drill 6-3/4" hole w/ GeoPilot f/ 4,294' to 4,476' MD 3,479' TVD (182'), ADT= 1.83 hrs, WOB 10/20K, 95 RPM, 265 gpm @ 1700 psi, Up 100K, Dn 78K, Rot 90K, TO on 4500 ft/Ib, TO off 4000 ft/Ib, PWD Clean hole ECD= 9.8 ppg, PWD ECD 9.97 ppg, Max Gas 68 units, Drilled concretion f/ 4,302' to 4,310'. Drill 6-3/4" hole w/ GeoPilot f/ 4,476' to 5,555' MD 3,462' TVD (1,079'), ADT= 8.32 hrs, WOB 10/20K, 120 RPM, 302 gpm @ 2200 psi, Up 98K, Dn 76K, Rot 86K, TO on 4000 ft/Ib, TO off 4000 ft/Ib, Ave. ECD's 9.9 ppg, Max Gas 125 units, Drilled concretions f/ 4933' to 4955', 5037' to 5051', 5084' to 5097', 5156' to 5176', 5433' to 5447', 5453' to 5456'. Drill 6-3/4" hole w/ GeoPilot f/ 5,555' to 5,947' MD 3,465' TVD (392'), ADT= 3.79 hrs, WOB 8/25K, 80!130 RPM, 310 gpm @ 2300 psi, Up 100K, Dn 75K, Rot 86K, TO on 5000 ft/Ib, TO off 4000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 110 units, Drilled concretions f/ 5542' to 5560', 5626' to 5628', 5674' to 5682', 5697' to 5700', 5832' to 5835'. After drilling on asumed concretion for 4 hours, Lost 200 psi pump pressure, Sent command to GeoPilot and regained 200 psi then lost 200 psi again, Picked up off btm and lost 350 psi, Tagged btm and gained 500 psi, Perp to POOH. POOH on elevators, No problems- Hole in good shape. POOH (GeoPilot & Bit Twisted off), Down load MWD, Lay down Tools, Clean rig floor. Note; Fish in hole= Bit, Bit sub stab, GeoPilot (Total 15.80'), TOF @ 5931'. Rig & test BOP to 250 psi low & 3500 psi High, Choke & kill valves and maniflod, Top & Blind rams Hydrill & floor valves. Note; Unable to contact AOGCC, Left messages with Slope pager & Anchorage number, Also sent a-mail. Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Page 17 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10/31/2005 End: 12/5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Date From - To 'Hours 11/24/2005 ~ 05:30 - 06:30 1.00 06:30 - 09:15 i 2.75 ~ 09:15 - 09:30 ~ 0.25 09:30 - 14:30: 5.00 14:30 - 15:00 0.50 , 15:00-17:15 2.25 17:15 - 17:45 0.50 ' i 17:45 - 21:30 3.75 21:30 - 23:00 1.50 23:00 - 00:00 . 1.00 11 /25/2005 ! 00:00 - 00:15 i 0.25 00:15-01:15 1.00 01:15 - 01:45 0.50 01:45 - 02:00 ; 0.25 02:00 - 05:00 3.00 05:00 - 05:15 0.25 05:15 - 08:15 3.00 08:15 - 09:00 0.75 09:00 - 12:00. 3.00 12:00 - 12:45 I 0.75 12:45 - 15:00 2.25 15:00 - 17:45 2.75 Code ;Sub ' Phase Code! '-~_ FISH PULD PROD3 FISH TRIP PROD3 FISH ;FISH PROD3 FISH I TRIP PROD3 FISH PULD PROD3 FISH TRIP PROD3 FISH ;FISH ' PROD3 ; ; FISH i TRIP ' PROD3 FISH PULD PROD3 DRILL PULD PROD3 DRILL PULD PROD3 DRILL ~ PULD ' PROD3 DRILL PULD PROD3 DRILL DEQT PROD3 DRILL 'TRIP ~PROD3 DRILL REAM PROD3 DRILL DRLH PROD3 DRILL ~ OTHR ~ PROD3 i DRILL TRIP PROD3 DRILL OTHR FISH PULD FISH ;TRIP 17:45 - 18:00 ! 0.251 FISH 18:00 - 21:30 3.50 FISH i~ 21:30 - 22:30 1.00 FISH 22:30 - 00:00 1.50 DRILL 11!26/2005 00:00 - 00:45 0.75' DRILL 00:45 - 02:15 1.501 DRILL PROD3 PROD3 PROD3 FISH PROD3 TRIP PROD3 PULD PROD3 PULD PROD3 PULD ': PROD3 PULD PROD3 02:15 - 03:15 I 1.00! DRILL I PULD I PROD3 03:15 - 04:00 0.75 I DRILL PULD ' PROD3 04:00 - 04:15 0.25 DRILL DEQT PROD3 04:15 - 07:15 3.00 DRILL TRIP PROD3 07:15 - 08:45 1.50 ~ DRILL ~ SURV ,, PROD3 08:45 - 09:15 0.501 DRILL ~I TRIP PROD3 Description of Operations Make up Baker fishing tools 6-1/4" Overshot w/ 5-1/4" grapple. RIH w/ fishing tools to 5901'. Break circ w/ 2.5 bpm @ 300 psi, 25 rpm w/ 3K TO, Work over fish & had 200 psi pump increase, 6K TO, Set Dn w/ 20K, Pick up off bttm w/ 5 to 10K drag off bttm. Monitor well, POOH to 4221', Monitor well, POOH- No fish recovery, Break out and inspect grapple (Showed scaring and signs that fish was inside overshot), Clean rig floor. Make up Baker fishing tools 6-1/4" Overshot w/ 5-1/8" grapple. RIH w! fishing tools to 5901'. Break circ w/ 2.5 bpm @ 320 psi, Up 98K, Dn 75K, 30 rpm w/ 4K TO, Work over fish @ 5931' & had no pump increase, Set Dn w/ 30K & Stalled top drive, Pick up off bttm w/ 115K & Broke back to 105K, Set back down w/ 30K. POOH w/ fish- No problems. Lay down fish and fishing tools, Clear & clean rig floor. Make up BHA #13, 6-3/4" Bit &GeoPilot. Continue to make up BHA #13. Program MWD Tools. Continue to make up BHA #13. Pulse test MWD tools, Break in GeoPilot bearings, 300 gpm @ 1550 psi, Stage rpm f/ 5 to 55. RIH with no problems to 5,876', Filled pipe @ 2702' & 5036'. Precautionary wash & ream to bttm @ 5,947'. Drill 6-3/4" hole w/ GeoPilot f/ 5,947' to 6,155' MD 3,458' TVD (208'), ADT= 1.83 hrs, WOB 5/7K, 120 RPM, 313 gpm @ 2600 psi, Up 105K, Dn 65K, Rot 85K, TO on 5000 ftllb, TO off 4000 fUlb, Ave. ECD's 10.1 ppg, Max Gas 99 units. At 6,155' Down linked to GeoPilot and observed 1500 psi pressure loss in pump pressure, Checked surface equipment- OK, Prep to POOH, Monitor well, Blow down top drive. POOH looking for wash out- Found Drilling Jars had parted at lower body section -(Total fish in hole= 220.66', TOF @ 5934'), Lay down upper jar section. Clear & Clean rig floor. Pick up & Make up 6-3/8" Over shot, Jars & Bumper sub, 1 std HWDP. RIH with no problems to 5939', Up 95K, Dn 68K, 30 rpm w! 3500 ft/Ib TO. Engage fish f/ 5,939' to 5,945', 2.5 bpm @ 350 psi, 30 rpm, Set down 18K, Gained 7K extra wt. POOH w/ fish, Had 25K drag @ 5,685'. Lay down remainder of broken Jars, Lay down fishing tools. Lay down 4-HWDP, X-O, 3-NMDC's, Float sub, Stab. Finish laying down BHA #13. Pick up & Make all new BHA #15, MWD tools, Stabs, PWD, Float sub, X/O sub. Program MWD tools. Pick up 3 new NMDC's, 4- HWDP, Jars, 1-HWDP. Shallow test MWD tools, Blow down top drive. RIH to 5,940' with no problems, Filled pipe @ 270' & 5035'. Take check shot surveys every 30' f/ 5940' to 6153' -Found 22.18 deg. dogleg @ 5933'. POOH to 5,460' & Resurvey for open hole side track. Printed: 12/29/2005 9:54:06 AM ConocoPhillips Alaska Page 1s of 24 Operations Summary Report Legal Well Name: 1 J-164 Common Well Name: 1J-164 Spud Date: 11/1/2005 Event Name: ROT -DRILLING Start: 10!31/2005 End: 12!5/2005 Contractor Name: n1334@ppco.com Rig Release: 12/5/2005 Group: Rig Name: Doyon 141 Rig Number: Dat 11/26/2005 11/27/2005 From - To Hours Code Sub Phase ': _ , Code ~~ __ -_ -_ - 09:15 - 11:30 I 2.251 DRILL ~ DRLH ~ PROD3 11:30 - 18:30 I 7.00 18:30 - 00:00 I 5.50 00:00 - 12:00 I 12.00 DRILL DRILL DRILL DRLH IPROD3 DRLH DRLH 1 12:00 - 00:00 ' 12.001 DRILL DRLH 11/28/2005 1 i 00:00 - 02:30 2.50, DRILL DRLH 02:30 - 03:45 ; '. 1.25 DRILL DEQT 03:45 - 08:45 5.00 DRILL TRIP 08:45 - 09:30 ! 0.75 DRILL , TRIP 09:30 - 10:15 0.75 DRILL j PULD 10:15 - 10:45 0.50 DRILL OTHR 10:45 - 12:00 1.25, DRILL PULD 12:00 - 13:45 11 /29/2005 13:45 - 15:00 15:00 - 16:15 16:15 - 18:30 18:30 - 20:00 20:00 - 00:00 00:00 - 06:30 1.751 DRILL I PULD 1.25) DRILL TRIP 1.25' RIGMNT RSRV 2.25 DRILL TRIP 1.50 DRILL REAM 4.00! DRILL DRLH PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 6.50 ~ DRILL I DRLG ~ PROD3 Description of Operations Trough w/ GeoPilot f/ 5,460' to 5,470' in order to side track well, Up 102K, Dn 72K, Rot 84K, 300 gpm @ 2250 psi, 120 rpm, 5000 ftllb TO. Drill 6-3/4" hole w/ GeoPilot f/ 5,470' to 6,155' MD 3,473' TVD (685'), ADT= 5.44 hrs, WOB 8/17K, 100 RPM, 284 gpm @ 2300 psi, Up 105K, Dn 73K, Rot 86K, TO on 5000 ft/Ib, TO off 4000 ft/Ib. Drill 6-3/4" hole w/ GeoPilot f/ 6,155' to 6,560' MD 3,467' TVD (405'), ADT= 3.67 hrs, WOB 8/15K, 120 RPM, 313 gpm @ 2500 psi, Up 112K, Dn 69K, Rot 85K, TO on 5500 ft/Ib, TO off 5000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 83 units. Drill 6-3/4" hole w/ GeoPilot f/ 6,560' to 7,577' MD 3,486' TVD (1,017'), ADT= 8.58 hrs, WOB 3/15K, 115 RPM, 305 gpm @ 2550 psi, Up 112K, Dn 69K, Rot 86K, TO on 5500 ft/Ib, TO off 5000 fUlb, Ave. ECD's 10.1 ppg, Max Gas 99 units, 6533' to 6573', 6584' to 6609', 7264' to 7267', 7278' to 7282', 7326' to 7332', 7366' to 7374', 7442' to 7444', 7467' to 7479'. Drill 6-3/4" hole w/ GeoPilot f/ 7,577' to 8,512' MD 3,506' TVD (935'), ADT= 9.41 hrs, WOB 5/18K, 100/120 RPM, 316 gpm @ 2800 psi, Up 125K, Dn 62K, Rot 85K, TO on 7000 ft/Ib, TO off 6000 ft/Ib, Ave. ECD's 10.4 ppg, Max Gas 99 units, 7594' to 7603', 7683' to 7685', 7745' to 7747', 7791' to 7794', 7826' to 7830', 7908' to 7915', 7955' to 7964', 8122' to 8131', 8137' to 8150', 8160' to 8171', 8180' to 8188', 8195' to 8200', 8430' to 8435'. Drill 6-3/4" hole w/ GeoPilot f/ 8,512' to 8,620' MD 3,504' TVD (108'), ADT= 2.73 hrs, WOB 7/14K, 90 RPM, 270 gpm @ 2200 psi, Up 122K, Dn 66K, Rot 83K, TO on 7000 ft/Ib, TO off 6000 ft/Ib, Ave. ECD's 10.1 ppg, Max Gas 99 units. GeoPilot failure- Circ & Attempt to reestablish communication with GeoPilot. POOH to 7650' (No swabbing -Good fill), Observe well, Pump Dry job, POOH to BHA & Stand back same. Down load MWD Lay down hangoff collar, PWD, MWD, Stab, GeoPilot, Bit. Clear and clean rig floor. Pick up Bit, GeoPilot, Pony collar, DM collar, Smart stab, SlimPhase 4 w/DGR, PWD, Hangoff collar. Program MWD tools, RIH w/ NMDC's, HWDP, Jars, Surface test MWD tools. RIH to 4192'. Slip & cut drilling line, Service top drive and drawworks. RIH with no problems to 8211' (Pipe stopped-Ran out of weight). Wash & ream f/ 8211' to 8620'. Drill 6-3/4" hole w/ GeoPilot f/ 8,620' to 8,955' MD 3,494' TVD (335'), ADT= 2.41 hrs, WOB 8/12K, 120 RPM, 330 gpm @ 3200 psi, Up 134K, Dn OK, Rot 85K, TO on 6000 ft/Ib, TO off 5000 ft/Ib, Ave. ECD's 11.0 ppg, Max Gas 57 units. No Concretions. Continue Directional drill 6 3/4" Hole in the "D" lateral from 8955'-9474' MD (519'). TVD = 3479'. ADT = 5.34 HRS. PU WT = 130K, SO WT = 60K, ROT WT = 85K, Torque off btm = 5K, Torque on bottom = 5.5K. WOB = 5-20K, RPM's = 120, Pumps @ 92 SPM, 327 GPM's - 3100 PSI. Total Jar Hrs = 37.58 Total Bit Hrs = 7.75 ECD at 10.94 PPG. Mud WT = 8.8 PPG Viscosity = 79, YP = 17. Gels 15/22. Max Gas units = 79. Survey @ 9388' MD, 3475.3' TVD = 88.56 Deg Inc, AZ - 7.78 Deg. Observed drilling through concretions @ 9259' - 9262' (3'), Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon141 Date From - To I Hours Code ,Code' Phas 11/29/2005 ~ 00:00 - 06:30 6.50 ~' DRILL ~ DRLG PROD3 06:30 - 08:15 I 1.75 DRILL OTHR PROD3 08:15 - 12:00 j 3.75 12:00 - 13:00 1.00 13:00 - 14:15 i 1.25 DRILL TRIP PROD3 DRILL ,TRIP PROD3 DRILL PULD PROD3 14:15 - 16:30 i 2.251 DRILL I PULD I PROD3 16:30 - 21:00 ' 4.50 21:00-21:15 0.25 DRILL TRIP PROD3 DRILL REAM , PROD3 21:15 - 22:00 0.75 ;DRILL REAM ! PROD3 22:00 - 00:00 2.00 I DRILL !.DRLG I PROD3 11/30/2005 100:00-12:00 12.001 DRILL DRLG PROD3 Page 19 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 9279'-9290' (11'), 9430'-9434' (4'), 9464'-9474' (10') = 28' total concretions. Observed MWD failure. Attempted to restart MWD, cycle pumps ;multiple times, adding 20K to WOB as per DD pulling from 9474' - 9239'. No success achieved. Monitor well -static. Pump dry job. POOH from 9239' - 4196' (5043'). Monitor well at window depth. Static. Continue POOH from 4196' - 368' (3828'). Calculated hole fill at 50 BBLs, Actual hole fill @ 56 BBLS. Rack back 4" HWDP & Jars, NM Flex Drill collars. Lay down Stabilizer & Float sub. Plug in and download MWD assembly. Lay down TM, PWD, Slimphase 4 w/ DGR & EWR, Smart Stabilizer, DM Pony Collar Geo Pilot and Bit. PJSM with crew. Discuss Safety Issues and PU procedure for Drilling BHA #17. Make up 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA = ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.75'), 4 3/4" Non Mag float sub (2.34'), 4 3/4" Integral Blade stabilizer (4.58'), DM HOC (8.52'), Slimphase 4 w/ DGR ~ RES (24.38'), PWD Collar (10.78'), TM !HOC (10.90'), 3 - 4 3/4" Non Mag Flex Drill Collars (92.80'), 4 7!8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars 37.58 Hrs on 11/29/05) (28.88'), 4 - Jnts 4" HWDP (121.21').Total BHA length = 369.34'. Perform Shallow pulse test @ 84 SPM - 1900 ';PSI. Good Test. Trip in hole from 369' - 8727' (8358'). Run 17 stands of 4" DP(1587.96'), Install Crossover sub (1.64'), Andergauge Agitator (8.73'), Shock Sub (8.37'), and Crossover Sub (1.66').Fill drill string every 20 stands. 'Continue TIH to 8727. PU WT = 92K, SO WT = 80K, Orient and observe no issues going through window area. Wash & Ream from 8727' - 8793' (66'), @ 40 SPM, 142 GPM's - 1500 ;PSI, 70 RPM's Torque @ 6K. Observe correct hole fill. Continue RIH to 9354' on elevators. Wash & Ream from 9354' - 9474' (120'). Continue Directional drill 6 3/4" Hole in the "D" lateral from 9474' - 9496' MD (18'). TVD = 3478'. ADT = .85 HRS. AST = .38 HRS. ART = .47 HRS. PU WT = 110K, SO WT = 47K, ROT WT = 77K, Torque off btm = 5K, Torque on bottom = 6K. WOB = 5-12K, RPM's = 75, Pumps @ 81 SPM, 287 GPM's - 3800 PSI. Total Jar Hrs = 38.43 Total Bit Hrs _ .85 ECD at 10.39 PPG. Mud WT = 8.85 PPG Viscosity = 88, YP = 18. Gels 16/24. Max Gas units = 30, BGG = 17 units. Survey @ 9388' i MD, 3475.3' TVD = 88.56 Deg Inc, AZ - 7.78 Deg. Observed drilling through concretions @ 9474' - 9480' (6') = 6' total concretions. SPR's @ 9537' MD, 3481' TVD. Pump #1 - 25 SPM - 740 PSI, 35 SPM - 1060 PSI. Pump #2 - 25 SPM - 840 PSI, 30 SPM - 1190 PSI. Continue Directional drill 6 3/4" Hole in the "D" lateral from 9496'-10070' MD (574'). TVD = 3501'. ADT = 7.84 HRS. AST = 1.48 HRS. ART = 6.36 HRS. PU WT = 110K, SO WT = 50K, ROT WT = 79K, Torque off btm = 5K, Torque on bottom = 6K. WOB = 3-15K, RPM's = 75, Pumps @ 82 SPM, 291 GPM's -3800 PSI. Total Jar Hrs = 46.27 Total Bit Hrs = 8.69 ECD at 10.83 PPG. Mud WT = 8.85 PPG Viscosity = 80, YP = 18. Gels 15/24. Max Gas units = 65, BGG = 15 !units. Survey @ 9957' MD, 3497.41' TVD = 87.6 Deg Inc, AZ - 357.82 ~ Deg. Observed drilling through concretions @ 9492' - 9505` (13'), Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date 'From - To Nours ' Code ', Sub.. Phase 11/30/2005 .00:00 - 12:00 12/1 /2005 Coded ~_ _~_ -- 12.001 DRILL DRLG ~ PROD3 12:00 - 00:00 12.00 00:00 - 05:30 05:30 - 07:30 07:30 - 09:15 09:15 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 18:15 18:15 - 19:00 19:00 - 20:30 20:30 - 21:45 5.50 DRILL ';DRLG DRILL I DRLG 2.00 DRILL !CIRC 1.75 DRILL WIPR 0.25 DRILL jWIPR 1.00 DRILL ~ WIPR 1.50:. DRILL WIPR 6.25 DRILL iWIPR PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 0.751 DRILL I CIRC I PROD3 1.501 DRILL (WIPR IPROD3 1.251 DRILL IWIPR !PROD3 Start: 10/31 /2005 Rig Release: 12/5/2005 Rig Number: Page 20 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Description of Operations 9574'-9580' (6'), 9585'-9591' (6'), 9600'-9604' (4'), 9610'-9620' (10'), 9628'-9632' (4'), 9640'-9675' (35'), 9714'-9721' (7') = 85' total concretions. SPR's @ 10005' MD, 3504' TVD. Pump #1 - 25 SPM - 660 PSI, 35 SPM - 920 PSI. Pump #2 - 25 SPM - 640 PSI, 30 SPM - 910 PSI. Continue Directional drill 6 3/4" Hole in the "D" lateral from 10070' - 11047' MD (977'). TVD = 3541'. ADT = 7.02 HRS. AST = 5.92 HRS. ART = 1.10 HRS. PU WT = 122K, SO WT = 50K, ROT WT = 81 K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 3-10K, RPM's = 80, Pumps @ 81 SPM, 287 GPM's - 3975 PSI. Total Jar Hrs = 53.29 Total Bit Hrs = 15.71 ECD at 11.06 PPG. Mud WT = 8.90 PPG 'Viscosity = 80, YP = 17. Gels 15/22. Max Gas units = 94, BGG = 11 units. Survey @ 10974' MD, 3537.11' TVD = 87.22 Deg Inc, AZ - 357.39 Deg. Observed drilling through no concretions this tour. SPR's i @ 10929' MD, 3532' TVD. Pump #1 - 25 SPM - 820 PSI, 35 SPM - 1160 PSI. Pump #2 - 25 SPM - 810 PSI, 30 SPM - 1140 PSI. Pump 35 BBL Hi Visc weighted sweep, observed 25% increase in cuttings on shakers when sweep returned. ,Continue Directional drill 6 3/4" Hole in the "D" lateral from 11047' - 11524' MD (477'). ND = 3561'. ADT = 3.35 HRS. AST = .29 HRS. ART = 3.06 HRS. PU WT = 132K, SO WT = 45K, ROT WT = 92K, Torque off btm = 7K, Torque on bottom = 7K. WOB = 4-6K, RPM's = 85, ;Pumps @ 80 SPM, 284 GPM's - 4100 PSI. Total Jar Hrs = 56.64 Total Bit Hrs = 19.37 ECD at 11.23 PPG. Mud WT = 8.80 PPG Viscosity = 81, YP = 18. Gels 16/24. Max Gas units = 87. Survey @ 11524' MD, 3561.5' TVD = 89.03 Deg Inc, AZ - 358.56 Deg. Observed drilling ;through concretions @ 11509' -11514' (5'). SPR's @ 10929' MD, 3532' `TVD. Pump #1 - 20 SPM - 750 PSI, 30 SPM - 950 PSI. Pump #2 - 20 SPM - 740 PSI, 30 SPM - 940 PSI. Pump 35 BBL Hi Visc weighted sweep, observed 25% increase in cuttings on shakers when sweep 'returned. Pump a 35 BBL Hi Visc sweep @ 80 SPM - 284 GPM's - 4100 PSI. Observed 20% increase in cuttings on shakers. Monitor well -static. POOH on elevators from 11524' - 10102' (1422'). PU WT = 150K, SO WT = 60K. Flow check -static. Pump dry job, blow down Top Drive & Lines. .Continue POOH from 10102' - 8980' (1122'). ;Pulled into cutings bed. RU & BROOH from 8980' - 8793' (18T), @ 281 GPM - 3500 PSI, 90 RPM's - 6K torque. Continue BROOH from 8793' - 8682' (101'), observing hole packing off.. ,Work string to clean up hole and continue BROOH from 8682' - 4404' 4278') with no issues. Back ream @ 85 SPM - 302 GPM - 3825 PSI. 90 RPM's with 5K torque. Pull on elevators from 4404' - 4218' observing no issues through window area. Pump a 35 BBL Hi Visc weighted sweep + 3 Bottoms up @ 93 SPM - 330 GPM's - 3500 PSI. Observed 10% increase in cuttings on shakers. PU WT = 91 K, SO WT = 81 K. ;Orient and TIH through window with no issues, and continue TIH on 'elevators to tag up at 6150' DPM. Obtain survey and verify we had traveled into OLD hole. Survey indicated oriented at 35 degrees left of high side. POOH from 6150' - 5430' (720'). Orient to low side at 168 degrees right j and RIH slowly to bit depth of 5602' to obtain and compare surveys to Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 12/1/2005 12/2/2005 1 J-164 1 J-164 ROT -DRILLING n1334@ppco.com Doyon 141 From - To 'Hours Code 20:30 - 21:45 1.25 DRILL 21:45 - 00:00 2.25 DRILL 00:00 - 03:00 3.00 DRILL 03:00 - 05:45 05:45 - 07:00 07:00 - 07:30 07:30 - 12:00 12:00 - 15:00 2.751 DRILL 1.25 DRILL 0.50 DRILL 4.50 DRILL 3.00 DRILL 15:00 - 17:00 2.001 DRILL Sub Phase Code WIPR PROD3 WIPR ',PROD3 WIPR iPROD3 CIRC I PROD3 CIRC i PROD3 I OBSV PROD3 TRIP i PROD3 I TRIP ~ PROD3 PULD IPROD3 17:00 - 17:30 i 0.50 DRILL PULD CMPLT3 17:30 - 19:45 i 2.25 DRILL PULD CMPLT3 19:45 - 20:30 0.75 WINDO ULD CMPLT3 20:30 - 22:15 ~ 1.75 j W I N 22:15 - 22:45 I I I 0.501 W I N 22:45-23:15 ~ i 0.50~ WIN 23:15 - 00:00 12/3/2005 00:00 - 02:30 02:30 - 03:45 RIP CMPLT3 THR CMPLT3 IRC CMPLT3 0.75' WINDOWTRIP 2.50; WIND0INTRIP ~ ~I 1.25 i W INDOVVIPULD CMPLT3 CMPLT3 CMPLT3 Start: 10/31 /2005 Rig Release: 12/5/2005 Rig Number: Page 21 of 24 Spud Date: 11/1/2005 End: 12/5/2005 Group: Description of Operations verify traveling into new hole back to 6150'. Continue TIH on elevators from 6150' - 9890' (3740'). Wash & Ream from 9890' - 11524' (1634') @ 90 RPM's,6K torque, 270 GPM - 4100 PSI. Pump 35 BBL Hi Visc weighted sweep + 2 Bottoms up @ 275 GPM's - 4100 PSI. Observed 10% increase in cuttings at shakers when sweep returned. Displace well with 8.9 PPG SFMOBM @ 275 GPM's - 4100 PSI. ECD = 11.64 PPG. Obtain SPR's. #2 pump - 20 SPM - 910 PSI, 30SPM - 1210 PSI. Monitor well -static. Drop 1 7/8" drift in drill pipe. POOH on elevators from 11524' - 5710' (5814'). Observe no swabbing and hole taking correct hole fill. Continue POOH on elevators from 5710' - 369' (5341'). Observe no swabbing and hole taking correct hole fill. Stop @ top of window, monitor well -static. Breakout & lay down BHA #17. Lay down after plug in and download MWD assembly, 6 3/4" Reed Hycalog PDC CRXE1005H Bit (.80') TFA _ ...749 with Jets of 4 x 10's & 4 x 12's, 5" Sperry Drill Lobe 6/7 - 6.0 stage with a 1.5 degree bend in motor (32.75'), 4 3/4" Non Mag float sub (2.34'), 4 3/4" Integral Blade stabilizer (4.58'), DM HOC (8.52'), Slimphase 4 w/ DGR & RES (24.38'), PWD Collar (10.78'), TM HOC 10.90'), Rack back 3 - 4 314" Non Mag Flex Drill Collars (92.80'), 4 7/8" Crossover sub (1.07'), 1 - Jnt of 4" HWDP (30.33'), 4 3/4" Drilling jars 37.58 Hrs on 11129/05) (28.88'), 4 - Jnts 4" HWDP (121.21').Total BHA length = 369.34'. Gauge Bit to 1 / 1 / CT / G / X / I / NO / TD Clean & clear rig floor area. Send tools outside. Pick up 9 stands of Push Pipe from pipe shed. (2 -4 3/4" DC's and 1 - 4" DP). Pick up 1 more stand of 4" HWDP, for upcoming 4 1/2" liner run. Rack back all stands in derrick. PJSM with crew & BOT rep. Discuss safety and Procedure for picking up BHA. Make up Whipstock retrieving BHA as per BOT rep. MU Hook (7.50'), 4 3/4" Bumper jar (7.30), 4 3/4" Oil Jar (11.25'), 4 3/4" Float sub (2.34'), 2 -stands of 4" HWDP (181.56'), and crossover (1.04'). Total BHA = 210.99' TIH with retrieving assembly, fill drill string every 25 stands. Obtain parametrs @ 4178'. PU WT = 125K, SO WT = 104K. Locate & hook window slot by working drill string and putting 1/8 turns in DP to hook. Pull up to 200K to fire jars, repeat 2 times, and pull to 250K to observe assembly free and moving up hole with 7K increase in upweight. Observe well swabbing. Circulate Bottoms up @ 248 GPM's - 1300 PSI. Observe 27 BBL loss of fluid as we CBU. Monitor well -static. POOH slow @ 10 ft/minute observe swabbing for 3 stands and then hole taking fluid. Slowly increase string speed as we wore out cup on the assembly. Observe hole taking proper fill after 3 full stands pulled. Continue POOH with whipstock retrievinig assembly from 3906' - 210' (3696'). Breakout & lay down Whipstock retrieving assembly. Layed down Hook (7.50'), 4 3/4" Bumper jar (7.30), 4 3/4" Oil Jar (11.25'), 4 3/4" Float sub (2.34'), 2 -stands of 4" HWDP (181.56'), and crossover (1.04'). Total BHA = 210.99'. Continue POOH lay down whipstock and space out assembly. Layed down Seal Assembly with Stop Sub (1.92'), 4 5/8" Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska... Page 22 of 24 Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To 'Hours Code ' Code ~ Phase -_ - _ -_ - - 12/3/2005 02:30 - 03:45 ~ 1.25 WINDO ~ ULD II CMPLT3 03:45 - 04:15 ' 0.50 WINDO ~ ULD CMPLT3 04:15 - 05:15 1.00; CMPLTNYRURD ~ CMPLT3 05:15 - 09:30 4.25 CMPLTN RUNT :..CMPLT3 i I 09:30 - 09:45 ~ 0.25 CMPLTN RUNT CMPLT3 09:45 - 10:15 0.50 ~ CMPLTN RUNT i CMPLT3 i 10:15 - 10:45 0.50 CMPLTN RUNT CMPLT3 i 10:45 - 12:00 1.25 !CMPLTN RUNT ~ CMPLT3 12:00 - 13:00 1.00 CMPLTN RUNT CMPLT3 13:00 - 14:15 ' 1.25 CMPLTN' RUNT CMPLT3 i 14:15 - 16:30 2.25 CMPLTN TRIP CMPLT3 16:30 - 18:00 ' 1.50 CMPLTN' OTHR CMPLT3 18:00 - 18:15 ~ 0.25 CMPLTN. OTHR CMPLT3 i 18:15 - 19:00 ; 0.75 CMPLTN CIRC CMPLT3 ~ 19:00 - 21:00 ~ 2.00 CMPLTN TRIP CMPLT3 21:00 - 22:00 i 1.00 CMPLTN PULD CMPLT3 22:00 - 23:15 1.25 RIGMNT RSRV CMPLT3 23:15 - 00:00 0.75 CMPLTN RURD 'CMPLT3 I 12/4/2005 00:00 - 00:45 0.75 CMPLTN RUNT ~ CMPLT3 I Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 RIg Release: 12!5/2005 Group: Rig Number: Description of Operations Unloader Sub (5.20'), 2 - 3 1/2 IF pups (11.85', 4.75'), 2- jnts 3 1/2 DP (31.33', 31.28'), Blanking Sub (1.08'),Bottom Trip Anchor (3.22'), Safety Disconnect (2.70'), Ported Drain Sub (1.02'), Debris Barrier sub w/ Cup (1.69'), & 5/8" Whipstock slide (15.47'). Clear & Clean rig floor area, send tools outside. Rig up casing equipment, power tongs, slips, elevators etc... Hold PJSM with crew and BOT rep. Discuss safety issues and procedure for picking up 4 1/2 slotted liner assembly. Pick up Baker 3 1/2" Guide shoe & bent joint with crossover. Continue RIH with 130 joints 4 1/2" L80 IBT 12.6# slotted /blank liner as per detail. PU Swell packers spaced out @ 9158' & 8637'. Install 150, 6 1/8" x 4 1/2" HydroForm Centralizers & stop rings on each joint except constrictor joints, all as per running detail. Constrictors space out to depths of , 10858', 10608', 10008', 9758', 8078', 7828', 7238', 6988', 6398', 6148', 5558', 5308', 4718', and 4418'. Total of 14 constrictors. Pull 2 7/8" tools and handling equipment to floor. Continue RIH with Liner assembly. Ran by window with bent joint to tag lower liner XO @ 4384' (Took 2 attempts to get thru window). Pull assembly back to above window top, orient to slack off and RIH to observe going into open hole. `Continue RIH with 176 joints total liner from 4248' - 5522' (1274'). PU WT = 80K, SO WT = 64K. Crew Change. PJSM. (Note; 4 joints prior to side track @ 5460' turned pipe 1-1/2 turns to the right to turn bent joint 'to 180 deg.) Continue RIH with liner from 5522' - 7225' (1703'). 231 joints total ran. Make up 3 1/8" Slimhole MWD assembly with BOT shear sub ~ assembly, on inner string of Hook Hanger. Orient MWD to high side of 'Hook. Make up Hook Hanger assembly. Perform shallow pulse test @ 117 GPM - 650 PSI. PU WT = 86K, SO WT = 63K. Trip in hole with drill string, and push pipe as calculated for weight, from 7268' - 11417' (4149'). Observe no issues getting liner down in open hole. PU WT = 175K, SO WT = 65K. Orient with MWD assembly to 11 degrees left of high side @ 124 GPM - 1100 PSI, slack off to hook window @ 4263' (3' deep). Pull up 40', and orient to low side, slack off to pass bottom of window to 4276'. Pull up 140', re-orient to window @ 11 deg left, slack off to observe hooking window. Set down 30k to verify set. Repeat. Shoe depth @ 11502'. ~ Final survey @ 2 Degrees left of high side. RU & drop a 29/32" ball, pumping down @ 124 GPM - 1100 PSI, slowing pumps until observed ball on seat. Pressure to 4200 PSI. Pull up 90' to 11412' & verify release. Bleed pressure. PU WT = 125K, SO WT = 50K Circulate bottoms up @ 124 GPM - 1100 PSI. Monitor well -static. POOH with BOT setting and releasing tool. Observed correct hole fill @ 36 BBIs. Breakout, inspect and lay down running and setting tools. Breakout & lay down MWD assembly & shear sub assembly. All tools looked good. i Slip & cut 220' of drilling line. Service top drive. '~ Rig up casing equipment for 4 1/2" LEM run. PJSM, Discuss & verify running order of tools. PU Seal Assembly with bent joint & first joint of tubing. Crew Change. i Continue RIH with LEM Assembly. Run 4 1/2" Baker Seal Assembly (3.26'), 4 1/2" Bent Joint STL x IBT (31.04'), 1-Jnt 4 1/2" IBT (31.02'), 4 Printed: 12/29/2005 9:54:06 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ', Hours Code Code Phase 12/4/2005 100:00 - 00:45 ~ 0.75 ~ CMPLTNI RUNT I CMPLT3 00:45 - 03:30 03:30 -04:00 04:00 - 04:30 04:30 - 07:00 07:00 - 07:45 07:45 - 12:00 12:00 - 19:30 19:30 - 19:45 19:45 - 20:15 20:15 - 00:00 12/5/2005 100:00 - 00:30 00:30 - 01:00 01:00 - 03:00 03:00 - 04:30 04:30 - 09:00 2.75 I CMPLTNI TRIP I CMPLT3 0.50 I CMPLTNI PCKR I CMPLT3 0.501 CMPLTNI PCKR I CMPLT3 2.501 CMPLTNI TRIP I CMPLT3 0.751CMPLTMTRIP (CMPLT3 4.25~CMPLTN~TRIP CMPLT3 7.501 CMPLTNjTRIP CMPLT3 0.25 J CMPLTN~~ RURD ~ CMPLT3 0.50 i CMPLTNI RURD ;CMPLT3 3.75 CMPLTNI RUNT CMPLT3 0.50 I CMPLTNI RUNT I CMPLTN 0.50 I CMPLTNI SOHO I CMPLTN 2.00 CMPLTNI SEOT CMPLTN 1.501 CMPLTNI NUND I CMPLTN 4.501 CMPLTNI NUND I CMPLTN Page 23 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 1/2" IBT pup (7.85'), 1-Jnt 4 12/" IBT (31.0'), LEM below Hook Hanger (24.52'), LEM above Hook Hanger (10.61'), 4 1/2" IBT pup (3.83'), 4 1/2" Casing Swivel (2.74'), 4 1/2" IBT pup (2.02'), XO Bushing 5 1/2" Hydril x 4 1/2" IBT (1.41'), 190-47 Casing Seal Bore Receptacle 19.68'), 7 5/8" x 5 1/2" ZXP Liner top Packer (18.90'), Install shear sub assembly, and MU Baker Hydraulic & Setting tools, with crossover sub (17.26'). Make Up Torque = 3500 Ft /Lbs Trip in hole with LEM assembly from 205' - 4375' (4170'). Work seals past Hook Hanger & bottom of window, observing seals going into liner top and Latching up on Hook Hanger@ 4246' as planned. Pull 10K over to verify Latch up. UP WT = 124K, SO WT = 105k. Seals spaced out to land @ 4375.01, inside Seal bore 10.35'. Drop 1 3/4" Ball and chase with 350 stks @ 3 BPM - 600 PSI to observe ball seated. Pressure up to 2500 PSI to allowZXP to set, continue pressure up to 4000 PSI to neutralize and release. Bleed pressure. Rig up and fill lines. Test down annulus 1000 PSI for 10 minutes, on chart to ensure packer integrity. Bleed pressure. Monitor well - static.Pull up and & retag top of ZXP to verify depth @ 4187' as planned. POOH from 4187' - 40' (4147'). Breakout & lay down & inspect Running & Setting tool assembly. All tools looked good. Clear & clean rig floor area, send tools outside. Rig up to lay down driN string. PJSM with crew. Discuss safety issues and plan for laying down drill string. Lay down entire drill string from derrick removing all Super Sliders, allowing for them to drain as per Target Zero. Crew Change. Continue Lay down entire drill string from derrick removing all Super Sliders, allowing for them to drain as per Target Zero. 90 Total. Rig up. BOLDS and pull wear bushing. Clean & clear rig floor area. Rig up equipment to run 4 1/2" completion string. Verify all tools in order in pipe shed. PJSM with crew. Discuss Safety issues, and procedure to run 4 1/2" completion string. MU Baker 4 3/4" SBE Seal assembly and continue RIH with 4 1/2" L80 12.6# IBT Tubing to 3960'. Install Baker 4 1/2" CMU Sliding Sleeve (OPEN) spaced out to 4137.87', 2 -Camco GLM's with Dummy BK-5 Latch space out to 3902.53, 2336.46', and a Camco DB-6 Nipple with 3 .875" NO-GO profile spaced out at 475.13'. Make up Torque = 3500 Ft /Lbs NOTE: SIMOPS -Change out mud pump liners from 5 1/2" to 6", & cleaning pits. Continue Run 4 1/2" Completion string to 4225.71'. Make up torque = 3500 FU Lbs. Tag XO @ 4225.83' with mule shoe and Pull up to install space out pups, to locate mule shoe @ 4221.83' as planned. PU WT = 74K, SO WT = 70K. Make up Vetco Gray 11" x 4 1/2" tubing hanger with 2 -way check installed. Mu Landing joint, RIH to locate and land hanger. RKB = 22.53'. Run in all lock down screws. Test upper and lower Hanger seals to 5000 PSI. 10 minutes each test. PJSM with crew. Discuss safety and cold weather issues. Discuss procedure for ND / NU. Nipple down BOP stack and all lines. Nipple up Vetco Gray Tree and actuator valve. Test Void to 5000 PSI - Printed: 12!29/2005 9:54:06 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-164 Common Well Name: 1 J-164 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To '-Hours ' Code Sub ,Phase _ _ _ 'Code! 12/5/2005 104:30 - 09:00 ~ 4.501 CMPLTN NUND i CMPLTN 09:00 - 10:00 1.00 10:00 - 12:00 ! 2.00 12:00 - 14:00 ~ 2.00 CMPLTN FRZP CMPLTN CMPLTN OTHR CMPLTN i CMPLTN; OTHR CMPLTN Page 24 of 24 Spud Date: 11/1/2005 Start: 10/31/2005 End: 12/5/2005 Rig Release: 12/5/2005 Group: Rig Number: Description of Operations 10 minutes. Test tree to 250 PSI low, 5000 PSI high - 10 minutes. Pull 2 -way check. Note: SIMOPS - RU scaffolding in cellar & RU Little Red for freeze protection services. PJSM with crew and Little Red reps. Discuss safety issues and spill prevention. Displace well with 190 BBLS of freeze protect diesel @ 5 BPM - 800 PSI. Rig Up Lubricator & set BPV. Repeat with no success. RU & put Steam on tree. NOTE : SIMOPS -Suck out cellar box with Super Sucker truck. Continue attempt to set BPV. Set BPV. Rig down lubricator Simops -Rig Down pipe shed skate, remove & clean all pits. Shut down all Glycol heaters. Blow down all steam ,glycol, and H2O lines. Rig Released @ 1400 HRS Printed: 12!29!2005 9:54:06 AM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1J Pad 1 J-164L2PB1 Job No. AK ZZ-0004025932, Surveyed: 26 November, 2005 Survey Report 28 December, 2005 Your Ref.• AP1500292327870 Surface Coordinates: 5945730.87 N, 558693.02E (70° 15'44.4085" N, 149° 31' 31.8702" VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative fo Projecf H Reference: 945730.87 N, 58693.02E (Grid) Surface Coordinates relative to Structure: 188.01 S, 98.41 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~ ' ~ ~ Survey Ref.• svy2232 A HaN~tturtna~ Gompgny Ha/liburton Sperry-Sun Survey Report forKuparuk 1J Pad -1J-164L2P61 Your Ref.• API 500292327870 Job No. AK-ZZ-0004025932, Surveyed: 26 November, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 4238.22 72.750 357.510 3330.61 3439.61 1782.63 N 561.07 W 5947509.07 N 558118.07E 1782.63 Tie-On Point ..~ 4248.00 73.050 357.690 3333.49 3442.49 - 1791.97 N 561.46 W 5947518.41 N 558117.61E 3.536 1791.97 Window Point 4345.41 79.410 1.230 3356.67 3465.67 1886.51 N 562.31 W 5947612.94 N 558116.02E 7.421 1886.51 4436.73 82.560 4.460 3370.98 3479.98 1976.56 N 557.83 W 5947703.03 N 558119.81E 4.909 1976.56 4532.50 88.520 9.320 3378.43 3487.43 2071.28 N 546.36 W 5947797.83 N 558130.53E 8.019 2071.28 4580.51 91.290 7.130 3378.51 3487.51 2118.79 N 539.50 W 5947845.39 N 558137.03E 7.355 2118.79 4626.56 92.630 7.590 3376.93 3485.93 2164.43 N 533.60 W 5947891.08 N 558142.56E 3.076 2164.43 4717.59 94.860 7.340 3370.99 3479.99 2254.49 N 521.80 W 5947981.23 N 558153.66E 2.465 2254.49 4810.65 94.840 5.100 3363.12 3472.12 2346.67 N 511.75 W 5948073.48 N 558162.99E 2.399 2346.67 4904.44 92.710 2.030 3356.94 3465.94 2440.06 N 505.94 W 5948166.91 N 558168.08E 3.978 2440.06 4995.53 89.390 356.830 3355.27 3464.27 2531.08 N 506.85 W 5948257.93 N 558166.46E 6.771 2531.08 5090.82 89.900 358.710 3355.86 3464.86 2626.29 N 510.55 W 5948353.11 N 558162.01E 2.044 2626.29 5184.37 85.360 358.270 3359.73 3468.73 2719.71 N 513.02 W 5948446.50 N 558158.82E 4.876 2719.71 5277.62 90.480 358.980 3363.12 3472.12 2812.84 N 515.25 W 5948539.61 N 558155.86E 5.543 2812.84 5369.81 94.250 359.950 3359.31 3468.31 2904.93 N 516.11 W 5948631.69 N 558154.28E 4.222 2904.93 5462.46 91.860 356.940 3354.37 3463.37 2997.39 N 518.62 W 5948724.13 N 558151.05E 4.145 2997.39 5557.30 92.490 355.120 3350.77 3459.77 3091.93 N 525.18 W 5948818.62 N 558143.75E 2.029 3091.93 5650.62 90.440 355.600 3348.39 3457.39 3184.91 N 532.73 W 5948911.53 N 558135.48E 2.256 3184.91 5744.30 89.900 355.520 3348.11 3457.11 3278.31 N 539.98 W 5949004.87 N 558127.50E 0.583 3278.31 5836.65 87.790 354.050 3349.97 3458.97 3370.25 N 548.37 W 5949096.75 N 558118.39E 2.784 3370.25 5906.94 87.880 353.730 3352.63 3461.63 3440.09 N 555.85 W 5949166.53 N 558110.37E 0.473 3440.09 5933.24 91.790 358.060 3352.70 3461.70 3466.31 N 557.73 W 5949192.73 N 558108.29E 22.181 3466.31 5963.96 93.380 359.840 3351.32 3460.32 3497.00 N 558.29 W 5949223.41 N 558107.48E 7.765 3497.00 5996.07 92.560 359.910 3349.65 3458.65 3529.06 N 558.36 W 5949255.47 N 558107.16E 2.563 3529.06 6023.16 91.520 358.770 3348.69 3457.69 3556.13 N 558.68 W 5949282.54 N 558106.64E 5.694 3556.13 6058.13 90.210 1.320 3348.16 3457.16 3591.09 N 558.65 W 5949317.50 N 558106.40E 8.197 3591.09 6089.21 89.100 2.310 3348.35 3457.35 3622.16 N 557.66 W 5949348.57 N 558107.14E 4.785 3622.16 6119.98 88.800 4.960 3348.91 3457.91 3652.86 N 555.71 W 5949379.28 N 558108.85E 8.666 3652.86 6155.00 88.800 4.960 3349.65 3458.65 3687.74 N 552.69 W 5949414.19 N 558111.60E .0.000 3687.74 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to Prue North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6155.OOft., • • 28 December, 2005 - 15:41 Page 2 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparvk 1J Pad -1 J-184L2P61 Your Ref.' API 500292327870 Job No. AK ZZ-0004025932, Surveyed: 26 November, 2005 Western North Slope The Bottom Hole Displacement is 3728.92ft., in the Direction of 351.476° (True). Comments Measured Station Coordinates Depth ND Northings Eastings Comment (ft) (ft) (ft) (ft) 4238.22 3439.61 1782.63 N 561.07 W Tie-On Point 4248.00 3442.49 1791.97 N 561.46 W Window Point 6155.00 3458.65 3687.74 N 552.69 W Projected Survey Survey tool program for 1J-164L2PB1 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 533.00 532.98 To Measured Vertical Depth Depth (ft) (ft) 533.00 532.98 6155.00 3458.65 Survey Tool Description CB-SS-Gyro (1J-164) MWD+IIFR+MS+SAG (1J-164L2PB1) ConocoPhillips • • 28 December, 2005.15:41 Page 3 of 3 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1 J-164L2 Job No. AK ZZ-0004025932, Surveyed: 1 December, 2005 Survey Report 28 December, 2005 Your Ref.• API 500292327861 Surface Coordinates: 5945730.87 N, 558693.02E (70° 15' 44.4085" N, 149° 31' 31.8702" VU) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 945730.87 N, 58693.02E (Grid) Surface Coordinates relative to Structure: 188.01 S, 98.41 W (True) Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure ~ ~ ~?~! E ~' Survey Ref.• svy2260 A 3iHNIbuYt+. ti CPM~b~fty Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J-184!.2 Your Ref.• API 500292327861 Job No. AK ZZ-0004025932, Surveyed: 1 December, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 5462.46 91.860 356.940 3354.37 3463.37 2997.39 N 518.62 W 5948724.13 N 558151.05E 2997.39 Tie-On Point 5470.00 91.910 356.800 3354.13 3463.13 3004.92 N 519.04 W 5948731.65 N 558150.58E 1.971 3004.92 Open Hole Sidetrack Point 5558.20 86.060 359.080 3355.69 3464.69 3093.00 N 522.21 W 5948819.71 N 558146.72E 7.118 3093.00 5651.29 86.150 0.490 3362.01 3471.01 3185.88 N 522.55 W 5948912.58 N 558145.65E 1.514 3185.88 5744.56 89.200 4.330 3365.80 3474.80 3278.96 N 518.63 W 5949005.69 N 558148.84E 5.255 3278.96 5838.24 89.610 3.860 3366.77 3475.77 3372.39 N 511.94 W 5949099.17 N 558154.81E 0.666 3372.39 • 5931.53 89.670 2.970 3367.35 3476.35 3465.52 N 506.39 W 5949192.33 N 558159.64E 0.956 3465.52 6024.60 90.910 1.010 3366.88 3475.88 3558.52 N 503.15 W 5949285.36 N 558162.14E 2.492 3558.52 6118.10 91.340 1.720 3365.05 3474.05 3651.98 N 500.93 W 5949378.83 N 558163.64E 0.888 3651.98 6212.06 92.650 2.140 3361.78 3470.78 3745.82 N 497.77 W 5949472.70 N 558166.07E 1.464 3745.82 6305.30 89.530 359.520 3360.00 3469.00 3839.02 N 496.42 W 5949565.90 N 558166.69E 4.369 3839.02 6397.94 88.800 352.970 3361.35 3470.35 3931.40 N 502.48 W 5949658.23 N 558159.91E 7.113 3931.40 6491.36 91.350 351.940 3361.23 3470.23 4024.00 N 514.74 W 5949750.74 N 558146.93E 2.944 4024.00 6584.08 91.650 349.670 3358.81 3467.81 4115.49 N 529.55 W 5949842.11 N 558131.40E 2.469 4115.49 6678.09 91.210 352.960 3356.46 3465.46 4208.38 N 543.74 W 5949934.88 N 558116.49E 3.530 4208.38 6770.43 90.100 354.220 3355.40 3464.40 4300.13 N 554.05 W 5950026.56 N 558105.47E 1.818 4300.13 6865.25 88.740 356.640 3356.36 3465.36 4394.64 N 561.61 W 5950121.00 N 558097.18E 2.927 4394.64 6957.01 89.490 1.110 3357.78 3466.78 4486.35 N 563.41 W 5950212.69 N 558094.66E 4.939 4486.35 7051.44 88.370 3.560 3359.54 3468.54 4580.67 N 559.56 W 5950307.04 N 558097.77E 2.852 4580.67 7145.47 87.510 4.150 3362.92 3471.92 4674.43 N 553.24 W 5950400.84 N 558103.36E 1.109 4674.43 7237.92 87.390 5.630 3367.04 3476.04 4766.45 N 545.37 W 5950492.92 N 558110.51E 1.605 4766.45 7332.20 90.740 11.600 3368.58 3477.58 4859.60 N 531.26 W 5950586.18 N 558123.90E 7.259 4859.60 7397.39 88.850 9.400 3368.81 3477.81 4923.69 N 519.38 W 5950650.36 N 558135.28E 4.449 4923.69 • 7468.74 86.930 5.240 3371.44 3480.44 4994.39 N 510.29 W 5950721.13 N 558143.81E 6.418 4994.39 7517.68 86.830 3.220 3374.10 3483.10 5043.12 N 506.69 W 5950769.89 N 558147.04E 4.126 5043.12 7569.02 87.710 3.770 3376.55 3485.55 5094.31 N 503.56 W 5950821.10 N 558149.76E 2.021 5094.31 7612.16 87.190 5.110 3378.47 3487.47 5137.27 N 500.23 W 5950864.09 N 558152.77E 3.329 5137.27 7705.22 87.950 3.620 3382.41 3491.41 5229.98 N 493.15 W 5950956.84 N 558159.12E 1.796 5229.98 7798.68 87.880 358.810 3385.82 3494.82 5323.33 N 491.17 W 5951050.21 N 558160.37E 5.144 5323.33 7892.25 89.680 355.240 3387.81 3496.81 5416.73 N 496.03 W 5951143.57 N 558154.79E 4.272 5416.73 7985.08 88.990 352.420 3388.89 3497.89 5509.01 N 506.00 W 5951235.76 N 558144.09E 3.127 5509.01 8078.97 89.490 353.220 3390.13 3499.13 5602.15 N 517.73 W 5951328.81 N 558131.63E 1.005 5602.15 8172.49 87.250 349.410 3392.79 3501.79 5694.54 N 531.85 W 5951421.09 N 558116.80E 4.724 5694.54 8265.80 87.020 350.220 3397.46 3506.46 5786.26 N 548.32 W 5951512.68 N 558099.61E 0.901 5786.26 8359.27 90.310 350.560 3399.63 3508.63 5878.38 N 563.92 W 5951604.68 N 558083.30E 3.539 5878.38 28 December, 2005 - 15:47 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-164L2 Your Ref.' API 500292327861 Job No. AK-ZZ-0004025932, Surveyed: 1 December, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 8451.11 91.100 351.340 3398.50 3507.50 5969.07 N 578.37 W 5951695.25 N 558068.14E 1.209 5969.07 8548.38 90.440 350.640 3397.20 3506.20 6065.13 N 593.60 W 5951791.19 N 558052.16E 0.989 6065.13 8581.95 92.240 353.240 3396.41 3505.41 6098.36 N 598.30 W 5951824.38 N 558047.20E 9.418 6098.36 8640.53 94.390 358.200 3393.02 3502.02 6156.65 N 602.67 W 5951882.64 N 558042.38E 9.215 6156.65 8733.24 93.680 359.870 3386.50 3495.50 6249.12 N 604.23 W 5951975.09 N 558040.10E 1.953 6249.12 8827.07 91.020 2.740 3382.65 3491.65 6342.82 N 602.09 W 5952068.81 N 558041.51E 4.168 6342.82 • 8919.64 93.280 5.270 3379.18 3488.18 6435.09 N 595.63 W 5952161.12 N 558047.25E 3.663 6435.09 9013.45 92.510 4.240 3374.44 3483.44 6528.46 N 587.87 W 5952254.55 N 558054.29E 1.370 6528.46 9105.75 92.700 6.200 3370.24 3479.24 6620.27 N 579.48 W 5952346.43 N 558061.96E 2.131 6620.27 9199.54 92.390 6.920 3366.08 3475.08 6713.36 N 568.77 W 5952439.59 N 558071.94E 0.835 6713.36 9291.83 89.540 5.130 3364.52 3473.52 6805.11 N 559.09 W 5952531.42 N 558080.90E 3.646 6805.11 9388.45 88.560 7.780 3366.13 3475.13 6901.10 N 548.23 W 5952627.48 N 558091.02E 2.924 6901.10 9490.25 87.090 5.830 3369.99 3478.99 7002.10 N 536.18 W 5952728.58 N 558102.28E 2.398 7002.10 9585.15 88.940 2.470 3373.28 3482.28 7096.67 N 529.32 W 5952823.20 N 558108.40E 4.040 7096.67 9678.54 87.090 1.230 3376.51 3485.51 7189.95 N 526.30 W 5952916.50 N 558110.69E 2.384 7189.95 9768.69 88.510 359.950 3379.97 3488.97 7280.03 N 525.37 W 5953006.58 N 558110.92E 2.120 7280.03 9865.88 86.820 358.140 3383.93 3492.93 7377.12 N 526.99 W 5953103.65 N 558108.54E 2.547 7377.12 9957.93 87.600 357.820 3388.41 3497.41 7469.00 N 530.23 W 5953195.51 N 558104.59E 0.916 7469.00 10053.50 88.700 356.330 3391.50 3500.50 7564.39 N 535.11 W 5953290.86 N 558098.97E 1.937 7564.39 10145.09 86.580 357.040 3395.27 3504.27 7655.74 N 540.40 W 5953382.17 N 558092.96E 2.441 7655.74 10239.93 87.650 355.820 3400.04 3509.04 7750.28 N 546.30 W 5953476.65 N 558086.33E 1.710 7750.28 10334.09 88.930 355.830 3402.85 3511.85 7844.14 N 553.15 W 5953570.46 N 558078.75E 1.359 7844.14 10426.50 87.110 356.850 3406.05 3515.05. 7936.31 N 559.04 W 5953662.58 N 558072.13E 2.257 7936.31 • 10518.36 87.970 356.760 3409.99 3518.99 8027.94 N 564.16 W 5953754.17 N 558066.30E 0.941 8027.94 10610.53 89.050 356.800 3412.39 3521.39 8119.93 N 569.34 W 5953846.11 N 558060.41E 1.173 8119.93 10698.91 86.850 356.850 3415.55 3524.55 8208.11 N 574.23 W 5953934.26 N 558054.83E 2.490 8208.11 10790.18 87.780 356.360 3419.82 3528.82 8299.12 N 579.63 W 5954025.22 N 558048.72E 1.151 8299.12 10882.73 87.350 356.950 3423.76 3532.76 8391.43 N 585.02 W 5954117.48 N 558042.61E 0.788 8391.43 10974.79 87.220 357.390 3428.12 3537.12 8483.27 N 589.56 W 5954209.29 N 558037.35E 0.498 8483.27 11062.75 86.540 357.180 3432.90 3541.90 8571.00 N 593.72 W 5954296.98 N 558032.51E 0.809 8571.00 11150.04 86.600 358.590 3438.13 3547.13 8658.07 N 596.94 W 5954384.03 N 558028.61E 1.614 8658.07 11243.27 87.040 357.990 3443.30 3552.30 8751.12 N 599.72 W 5954477.05 N 558025.11E 0.797 8751.12 11336.37 87.660 357.530 3447.60 3556.60 8844.05 N 603.35 W 5954569.95 N 558020.75E 0.829 8844.05 11427.65 88.510 358.490 3450.65 3559.65 8935.22 N 606.52 W 5954661.09 N 558016.87E 1.404 8935.22 11477.53 89.030 358.560 3451.72 3560.72 8985.07 N 607.80 W 5954710.93 N 558015.20E 1.052 8985.07 28 December, 2005 - 15:47 Page 3 of 4 DrillQuest 3.03.06.008 Ha/liburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-164L2 Your Ref: API 500292327861 Job No. AK ZZ-0004025932, Surveyed: 1 December, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical -Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) - 11524.00 89.030 358.560 3452.51 3561.51 9031.52 N 608.97 W 5954757.37 N 558013.67 E ~ 0.000 9031.52 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). • Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11524.OOft., The Bottom Bole Displacement is 9052.03ft., in the Direction of 356.143° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 5462.46 3463.37 2997.39 N 518.62 W Tie-On Point 5470.00 3463.13 3004.92 N 519.04 W Open Hoie Sidetrack Point 11524.00 3561.51 9031.52 N 608.97 W Projected Survey S t l 164L2 f 1J oo urvey program or - Fro m To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 533.00 532.98 CB-SS-Gyro (1J-164) 533.00 532.98 11524.00 3561.51 MWD+IIFR+MS+SAG (1J-164) 28 December, 2005 - 15:47 Page 4 of 4 Dr111Quest 3.03.06.008 • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-164 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,462.46' MD Window /Kickoff Survey: 5,470.00' MD (if applicable) Projected Survey: 11,524.00' MD 10-Jan-06 2,05 - r 9-~ PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date I ~ Signed-~ Please call me at 273-3545 if you have any qu ons or concerns. Regards, Carl Ulrich Survey Manager ~1 f~ J Attachment(s) • • AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-164 L2 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,238.22' MD Window /Kickoff Survey: 4,248.00' MD (if applicable) Projected Survey: 6,155.00' MD 10-Jan-06 ~o~- ~~ PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date l~- ~I`7~n(~ Signed~~~Q,~-1 Please call me at 273-3545 if you have any questions or concerns Regards, Carl Ulrich Survey Manager Attachment(s) ~., ~ ~ ~ a ' , , ' `~ ~i ~ ~ ,, ~ ~ ;~' ~"'~ ~ ~~ FRANK H. MURKOWSKI GOVERNOR s , ~_ ~ a , ~ t~ ~~ OII/ ~ ~ ~~ " COI~TSER~ATIO~T CODIIKI 1 333 W. T AVENUE, SUITE 100 SSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: KRU West Sak 1J-164L2 ConocoPhillips Alaska, Inc. Permit No: 205-146 Surface Location: 1919' FSL, 2517' FEL, Sec. 35, T11N, R10E, UM Bottomhole Location: 541' FSL, 2212' FWL, Sec. 23, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-164, Permit No. 204-144, API No. 50.-.029-223.2:78-00. 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 approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and. conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). • BY ORDER THE COMMISSION DATED this day of October, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Rio t ! ~® 1a. Type of Work: Drill / Redrill Re-entry ^ 1b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Stratigraphic Test ^ Service0 Development Gas ^ Single Zone ^/ " 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 °' 11. Well Name and Number: 1J-164L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11658' ~ ND: 3570' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1919' FSL, 2517' FEL, Sec. 35, T11N, R10E, UM ' 7. Property Designation: ADL 25661, 25650 West Sak Oil Pool Top of Productive Horizon: 1579' FNL, 2203' FWL, Sec. 35, T11N, R10E, UM ~- 8. Land Use Permit: ALK 471, 468 13. Approximate Spud Date: 11/5/2005 Total Depth: 541' FSL, 2212' FWL, Sec. 23, T11N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1919' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558693 "' y- 5945730 `" Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: ~~~ ~ ~nT-~ ~~ '-`---T^°` 16. Deviated wells: Kickoff depth: 4250 " ft. Maximum Hole Angle: 91 ° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.oa5) a" Downhole: 1607 psig ~ Surface: 1214 psig * ~ ~ 18. Casing Program ecificati n S Setting Depth Quantity of Cement Size p o s Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2318' 28' 28' 2318' 2197' 480 sx ASLite, 140 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 5419' 28' 28' 5419' 3600' 380 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 7408' 4250' 3446' 11658' 3570' slotted liner 19 PRESENT WELL CONDITION SUMMARY (TO be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): t / a Perforation Depth TVD (ft): "°` A _ _ S. ~+_ fi/ ~f11(~ ~+um 20. Attachments: Filing Fee ~ ~ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~ ` _ _ _ Phone ~S b?i3U Date `3 ~ ~ <~.i ----- P d h n k Commission Use Only Permit to Drill Number: ~~~ j ~~ API Number: ~j j 50- ~Z~ '~ ~32~~ ~~ 1 Permit Approval Date: See cover letter for other requirements Conditions of approval a ples required Yes ^ No „~ Mud log required Yes ^ No drogen sulfide measures Yes ^ No ~' Directional survey required Yesq l~* No ^ Other: © ~5~ QS D~G°n°~~ ~ v ~~~~~~ ~ PF-~~lZO'~S~lr~ Ct.000C-U ~/ ~~~ a-~ APPROVED BY +~ Appr THE COMMISSION Date: ~ o -.~.. ~~~~. Form 10-401 Revised 06/2004 t ~ ` ` ~ ~'~'~ ~ Submit in Duplicate ~~ ~lication for Permit to Drill, Well 1J-164 L2 Revision No.O Saved: 22-Sep-05 Permit It -West Sak Well #1J-164 L2 •~,.d r.~ +'t Application for Permit to Drill Document ~, (~I+~~W~II M~ x i m i z@ W@II Vpl~e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25..005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 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 ................................................................................... 4 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-164L2 PERMIT /T.doc Page 1 of 6 Printed: 22-Sep-05 G~IG!~~A~ ~lication for Permit to Drill, Well 1J-164 L2 Revision No.O Saved: 22-Sep-05 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 (f} Each wel/ must be identified by a unique name designated by the operator and a unique API number assigned by the commission under ZO AAC 25.040(6). Far a well with multip/e we/l 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-164 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (2) a p/at identifying the property and the property`s owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at Iota/ depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/ Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the tap of each objective formation and at total depth; Location at Surface 1,919' FSL, 2 517' FEL, Section 35 T11N R10E '' ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,730 Eastings: 558,693 '' Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak ~~D" Sand 1,579' FNL, 2,203' FWL, Section 35, T11N, R10E - ASP Zone 4 NAD 27 Coordinates Measured De th RKB; 4 250 Northings: 5,947,507 Eastings; 558,117 Total 1/erticaf De th, RKB: 3,446 Tota/ l/ertica/ De th SS.• 3 337 Location at Total De th 541' FSL 2,212' FWL Section 23 T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 11, 658 Northings; 5,954,906 Eastings; 558,061 Total t/ertica/De th, RKB; 3,570 Tots/ I/ertica/ De th, SS.• 3,461 and (D) other information required by 20 AAC 25.050(6); Q~I~INAL 1J-164L2 PERMIT /T.doc Page 2 of 6 Printed: 22-Sep-05 ~lication for Permit to Drill, Well 1J-164 L2 Revision No.O Saved: 22-Sep-05 Requirements of 20 AAC 25.050(b) Ifa well is to be intentiona/ly deviated, the application for a Permit to Dril1(Form 10-401) must (1) include a plat, drawn to a suitab/e scale, showing the path of the proposed wel/bore, including a/l adjacent wellbores within 200 feet of any portion of the proposed we/l; Please see Attachment 1: Directional Plan and (2) for a// 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 /n public records, and show that each named operator has been furnished a copy of the app/ication by certified mail; ar (B) state that the app/icant is the on/y 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 Dri!/must be accompanied by each of the fol/owing items, except for an item already on fife with the commission and identified in the application: (3) a diagram and description of the b/owout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC25,036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-54 L2. Please see information on Doyon 141 blowout prevention equipment placed on fife 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 fallowing items, except for an item already on file with the commission and identified in the application: (4) information on dri//ing hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ 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 1,214 psi, calculated thusly: MPSP =(3,570 ft TVD)(0.45 - 0.11 psi/ft) =1,214 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia! causes of ho% problems such as abnormal/y geo-pressured strata, lost cireuNation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-164 L2 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dri/l must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation Integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1J-164, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-164L2 PERMIT IT.doc Page 3 of 6 ~ t k ]~ ~ Printed: 22-Sep-05 ~lication for Permit to Drill, Well 1J-164 L2 Revision No.O Saved: 22-Sep-05 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (6) a complete proposed casing and cementing program as required by 20 AAC 2s. 030, and a description of any slotted /iner, pre- perforated liner, or screen to be instal/ed; Casin and Cementin Pro ram C c~ ~~.~-~~yt~ 7. Diverter System Inrormation Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fo/lowing 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. D35, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2),• No diverter system will be utilized during operations on 1J-164 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 fo/%wing items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densify ( g) 8.6 -~ Plastic Viscostiy 15 - 25 Ib/100 s fl Yield Point 18 - 28 (cP) HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical 650-900 Stabilit Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. ^RIGINAL Ho% Top etm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD (in (in) t (lb/ft Grade Connection ft) ft (ft) Cement Pro ram 4-1/2 6-3/4" A Sand 1J-164 12.6 L-80 IBTM 7,005 4,673 / 3,530 11,678 / 3,768 slotted- no cement 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,082 4,583/ 3,518 11,665 / 3,619 slotted- no cement Slotted Lateral (1J-164 Ll) 4- slotted I Slotted - n Lateral (1J-164 L2) `°`~'°""-,°, "' L-80 IBTM 7,408 4,250/ 3,44 Slotted- no ceme 1J-164L2 PERMIT tTdoc Page 4 of 6 Printed: 22-Sep-05 ~lication for Permit to Drill, Well 1 J-164 L2 Revision No.O Saved: 22-Sep-05 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the app/ication: (9) for an exploratory or stratigraphic test wel% a tabu/ation setting out the depths of predicted abnormal/y geo pressured strata as required by 20 AAC 25.033(fJ; 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 Dril/ must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (1 D) for an exploratory or stratigraphic test wel% a seismic refraction or reflection ana/ysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore p/atform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed 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 fol%wing 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 1J-164 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 4,250' MD / 3,446' TVD, 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 11,658' MD / 3,570' 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. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-964L2 PERM/T /T.doc Page 5 of 6 Printed: 22-Sep-05 1~~ • ~lication for Permit to Drill, Well 1J-164 L2 Revision No.0 Saved: 22-Sep-05 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. il. POOH, laying down drill pipe as required. 12. PU 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. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to ©ri// mustc be accompanied by each of the fol%wing items, except loran item a/ready on fi/e with the commission and identified in the application: (14) a genera/ 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 we/%; 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 1J 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. ConocoPhiilips 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-164L2 PERMIT IT.doc Page 6 of 6 Printed: 22-Sep-05 u ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 1 J-164 L2 Plan: 1J-164 L2 (wp06) Proposal Report 13 September, 2005 c: HAL.~1.~11.1R'TQN Sperry Drilling Services ~~~~ ;` `~ ConocoPhillips Al~~ka -1000 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-164 (L6) Wellbore: 1J-164 L2 Plan: 1J-164 L2 (wp06) LEGEND ~~ Plan 1J-164 (L6), 1J-164 Lt, 1J-164 L1 (wp06 VO ~- Plan 1J-164 (L6), 1J-164, 1J-164 (wp06) VO $ 1J-164 L2 (wp06) TOW @ 4250ft MD, 3446ft TVD 1579ft FNL 8 2203ft FWL -Sec 35-T11N-R10E L._ _ BOW ~ 4262ft MD, 3448tt TVD - Drill 30' lRa End Rathols -Build @ 8'NOOft, 4282tt MD, 3154tt TV I Sail ~ 91.27° Inc : 4498tt MD, 3471ft TVD FoItMAnoN roP DETaLs N3YDPath MDPath Formation 1 1613.00 tb93.06 Base of Pennatrost 2 1844.001703.47 T3 3 1836.00 2026.77 K16 4 2203.00 2320.66 T3 • 660 (CSG PT) ti 2922.00 3162.82 Ugnu C 6 3110.00 3434.03 Ugnu B 7 3149.00 3487.27 Ugnu A 8 3283.00 3747.36 K-13 9 3146.00 4260.33 lMest Sak D (77°) CASING DETAILS No TVD MD Name Size 1 2203.00 2324.56 10 314" 10-314 2 3446.00 4250.34 7 5/8" 7-518 3 3570.0011657.71 41/2" 4-1/2 Continue Build ~ 5°I100tt , 4977tt MD, 3481tt TV Begin GeoSteer In D-Sand 6003tt MD, 3481tt 1 Base Pe ---T3 -- K16 T3 t 660 (CSG PT \ Ugnu C _ _ Ugnu B _ _ _ _ _ 3000 Ugnu K-13 - --- -- 3500 West Sak D (77° - - - - ~ - r - r~~~~L _ l - i - - - - - - - - - i- - ~ -~ - - - - -L--~ ~-~ i _° i i i ~ ~~ i , , ~~ ~ i ~ , ~ ~' ~ i i ~ ~ ~ i i i i , i i i i ~ ~' ~ ' 1J-164 L2 T12 (wp06) 1J-164 L2 T1 (wp06) ~ 1J-164 L2 T3 (wp06) 1J-164 L2 T8 (wp06) ~ 1J-164 L2 T11 (wp06) 1J-164 L2 T51wP~) 1J-164 L2 T7 (wp06) ~ ~~ 1J-164 L2 T13 (wp06) 1J-164 L2 T2 (wp06) 1J-164 L2 T4 (wp06) 1J-164 L2 T10 w 6 1J-164 L2 T6 (wp06) 1J-164 L2 T8 (wp06) l PO ) -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 Vertical Section at 0.00° (1000 ft/in) BHL ~ 11658ft MD, 35708 TVD - 541ft FSL & 22128 FWL -Sec 23-T11N-R10E 1J-164 L2 Toe (wp06) Build ~ 3'HOOtt -Exit Sand High Prior to Crossing Fault, 8853ft MD, 3499tt TV Project: Kuparuk River Unit T ~ ConocoPhilli s p M Site: Kuparuk 1J Pad muths to True North z L , Well: Plan 1J-164 ( 6) 10625 Alaska Wellbore: 1J-164 L2 agnetic North: 24.64° Plan: 1J-164 L2 (wp06) Magnetic Field Strength: 57570.3nT Dip Angle: 80.72° 10000 Date: 9/1/2004 Model: BGGM2004 1J-164 LZ Toe (wp06j 9375 - - ,BHL@ i',658ftMC.35708TVD-541flFSL&22i2ftFWL-Sec 23-Ti1N-RtOE 1J-164 L2 T13 (wp06 0° 8750 360' 1J-164 L2 T'12 (wp06[ 360° 8125 1J-164 L~ 2 T'11 (wp06~ ~ ~ 0° - - -------- 60° 7500 1J-164 LZ T10 (wp06 - - _ - - - - - _ - _. - - 0° - - - _ ° 0 6875 i 1J-164 LZ T9 (wp06 _ _ _ _ - _ - 360° _ _ _ _ _ _ - 60° Builtl ~ 3'/tOlxt -Exit Sand High Prior to Crossing Fault, t3653ft MD, 3499ft ND 1J-164 L2 TB (wp06 - _ _ _ - - - - _ - - - 6250 _ _ I tJ-164 L2 n (wp06 _ _ _ - - - - _ = ^ _ 0 i 1 J-164 L2 T6 (wp06) _ _ - - 5625 11J-16411 L2 Tb (wp06)' c 0' 5000 ~ 1J•164 L2 T4 (wp06 N _ - - 60° - .., 1J-164 L2 T3 (wp06 ~ _ - - - + Begin GeoSteer in D-Sand 50038 MD. 3461ft TVD 4375 = r 360' 0 Z 1J-164 L2 T2 (wp06 - - 3750 J= 0° 0 0° 3125 1J•164 L2 T1 (wp06J, - 360' (Continue Build ~ 5°/100ft, 4977ft MD, 3461ft TVD 360° 2500 0° 0, Sall ~ 91.27• Ine :44988 MD, 3471tt TVD End Rathole - Bulld ~ 8'/100f1, 4292ft MD, 3454ft ND 1875 ----- 360° ~ - - -. BOW ®4262tt MD. 3448ft TVD -Drill 30' Rathole •i 1250 TOW @ 4250f; MD. 3446f; TVD '5798 FNL & 2203ft FWL -Sec 35-T11 N-RiGE 625 ~°` ,~g0 0 CASING DETAILS -625 No ND MD Name Size 1 2203.00 2324.56 10 3/4" 10314 2 3446.00 4250.34 7 518" TOW 7-5/8 3 3570.0011657.71 4112" 4.1/2 -1250 -4375 -3750 -3125 -2500 -1875 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 West - /East +'. 1250 fUin V 1~ 1 V i i Y! 1 ~--. . • ~ ~t~11fK0~'11~~Ip5 Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhiliips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Weil: Plan 1J-164 (L6) Wellbore: 1J-164 L2 Design: iJ-164 L2 (wp06) i Halliburton Company HAILLI~Ui~TC1N Planning Report -Geographic - -- - - ~f*Y OritNnp Services Local Co-ordinate-Reference: WeIIPIan 1J-164 (L6) TVD Reference: 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) MD Reference: 1J-164 (28'+81'} @ 109.OOft (D141 (28GL.+ 81'RF)) North Reference: True l Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using We{I Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor - - -- 'Well .Plan 1J-164 (L6) _ - , - Weil Position +N/-S 0.00 ft Northing: 5,945,730.87 ft `~ Latitude: 70° 1 5' 44.408" N +E/-W 0.00 ft Easting: 558,693.02 ft Longitude: 149° 31' 31.870" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 81.OOft i--- Welibore 1J-164 L2 Magnetics Model;Name Sample Date Declination Dip Angle Field Strength bggm2004 9/1/2004 24.64 80.72 57,570 Design 1J-164 L2 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 4,250.33 Vertical Section: Depth From (TVD) +Nt-S +El-W Direction (ft) fft) (ft) (°) 2s.oo o.oo o.oo o.oo 9/132t?05 2;54:24PM Page 2 of 8 COMPASS 2003.11 Build 48 r _,. a ~~~~~ . ~ ~-' Halliburton Company ~ ~A11flCC~~'11~~1p5 Alaska Planning Report - Geographi Database: EDM 2003.11 Single User Db Loca1 Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-164 (L6) Survey Calculation Method: Wellbore: 1J-164 L2 Design: 1J-164 L2 (wp06) r-r~l-~~ref<u~rrc~n~ Srt~rnt DrilrMa Services Well Plan 1J-164 (L6) 1J-164{28'+81') @ 109.OOft (D141 (2$GL + 81'RF)) 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) True Minimum Curvature' Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ftl (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 4,250.33 77.00 0.07 3,446.00 1,780.72 -561.21 0.00 0.00 0.00 0.00 4,262.33 78.91 0.07 3,448.50 1,792.46 -561.20 15.90 15.90 0.00 0.00 4,292.33 78.91 0.07 3,454.27 1,821.90 -561.17 0.00 0.00 0.00 0.00 4,498.33 91.27 0.00 3,471.88 2,026.74 -561.05 6.00 6.00 -0.03 -0.30 4,977.48 91.27 0.00 3,461.28 2,505.78 -561.05 0.00 0.00 0.00 0.00 5,002.83 90.00 359.99 3,461.00 2,531.12 -561.05 5.00 -5.00 -0.04 -179.54 5,252.83 90.00 359.99 3,461.00 2,781.12 -561.09 0.00 0.00 0.00 0.00 5,254.69 90.00 0.03 3,461.00 2,782.98 -561.09 2.00 0.00 2.00 90.00 6,252.68 90.00 0.03 3,461.00 3,780.98 -560.62 0.00 0.00 0.00 0.00 6,287.72 89.30 359.99 3,461.21 3,816.02 -560.62 2.00 -2.00 -0.11 -176.76 7,252.88 89.30 359.99 3,473.00 4,781.11 -560.83 0.00 0.00 0.00 0.00 7,261.41 89.14 0.05 3,473.12 4,789.63 -560.82 2.00 -1.88 0.68 160.03 8,253.12 89.14 0.05 3,488.00 5,781.23 -560.03 0.00 0.00 0.00 0.00 8,290.66 88.39 0.02 3,488.81 5,818.76 -560.01 2.00 -2.00 -0.08 -177.69 8,653.32 88.39 0.02 3,499.00 6,181.28 -559.91 0.00 0.00 0.00 0.00 8,841.30 94.03 359.96 3,495.03 6,369.14 -559.95 3.00 3.00 -0.03 -0.56 9,254.54 94.03 359.96 3,466.00 6,781.35 -560.24 0.00 0.00 0.00 0.00 9,439.69 88.48 0.08 3,461.96 6,966.39 -560.17 3.00 -3.00 0.07 178.73 9,854.87 88.48 0.08 3,473.00 7,381.42 -559.56 0.00 0.00 0.00 0.00 9,906.71 86.94 359.84 3,475.07 7,433.22 -559.59 3.00 -2.96 -0.47 -171.09 10,055.15 86.94 359.84 3,483.00 7,581.45 -560.00 0.00 0.00 0.00 0.00 10,072.34 86.85 0.17 3,483.93 7,598.61 -560.00 2.00 -0.53 1.93 105.34 10,255.48 86.85 0.17 3,494.00 7,781.47 -559.44 0.00 0.00 0.00 0.00 10,265.19 86.79 359.99 3,494.54 7,791.17 -559.43 2.00 -0.55 -1.93 -105.97 11,257.17 86.79 359.99 3,550.00 8,781.60 -559.65 0.00 0.00 0.00 0.00 11,274.77 87.15 0.02 3,550.93 8,799.18 -559.65 2.00 1.99 0.17 4.92 11,657.72 87.15 0.02 3,570.00 9,181.65 -559.53 0.00 0.00 0.00 0.00 9/13/2005 2:54:24PM Page 3 of 8 COMPASS 2003.11 Build 48 ~,~~.: ,~,~ ContKOPhiltips Alaska Database: EDM 2003.11: Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: .Plan 1J-164 (L6) WeNbore: 1J-164 L2 Design: 1J-164 L2 (wp06) Planned Survey 1J-164 L2 (wp06) Halliburton Company Planning Report -Geographic Locat Co-ordinate Reference: Np Reference: MD Re#erence: North Reference: Survey Calculation Method: • HALLfBfJATOfV _m _., . ~ ...~. Sperry Qriiling Services WeII Plan 1 J-164 (L6) - 1J-.164 (28'+81') @ 109.OOft (D149 (28GL + 81'RF)) 1J-164. (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) True Minimum Curvature Map Map MD Inclination Azimuth ND SSND +Ni-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (~) (ft) (ft) 4,250.33 77.00 0.07 3,446.00 3,337.00 1,780.72 -561.21 5,947,507.00 558,118.00 TOW Q 4250ft MD, 3446ft TVD : 1578ft FNL & 2203ft FWL -Sec 35-T71 N-R10E -West Sak D (77°) - 75/8" 4,262.33 78.91 0.07 3,448.50 3,339.50 1,792.46 -561.20 5,947,518.73 558,117.92 BOW ~ 4262ft MD, 3448ft ND -Drill 30' Rathole 4,292:33 78.91 0.07 3,454.27 3,345.27 1,821.90 -561.17 5,947,548.17 558,117.73 End Rathole - Build ~ 8°/100ft, 4292ft MD, 3454ft ND 4,300.00 79.37 0.06 3,455.72 3,346.72 1,829.43 -561.16 5,947,555.70 558,117.68 4,360.57 83.00 0.04 3,465.00 3,356.00 1,889.27 -561.10 5,947,615.53 558,117.26 4,400.00 85.37 0.03 3,468:99 3,359.99 4,498.33 91.27 0.00 3,471.88 3,362.88 Sail ~ 91.27° Inc : 4498ft MD, 3471ft ND 4,500.00 91.27 0.00 3,471.84 3,362.84 4,600.00 91.27 0.00 3,469.63 3,360.63 4,700.00 91.27 0.00 3,467.42 3,358.42 4,800.00 91.27 0.00 3,465.21 3,356.21 4,900.00 91.27 0.00 3,462.99 3,353.99 4,977.48 91.27 0.00 3,461.28 3,352.28 Continua Build ~ 6°l100ft , 4977ft MD, 34818 ND 5,000.00 90.14 359.99 3,461.00 3,352.00 5,002.83 90.00 359.99 3,461.00 3,352.00 Begln (3eoStaer in DSand 5003ft MD, 3461ft ND 5;100.00 90.00 359.99 3,461.00 3,352.00 5,200.00 90.00 359.99 3,461.00 3,352.00 5,252.83 90.00 359.99 3,461.00 3,352.00 1J-184 L2 T1 (wp06) 5,254.69 90.00 0.03 3,461.00 3,352.00 5,300.00 90.00 0.03 3,461.00 3,352.00 5,400.00 90.00 0.03 3,461.00 3,352.00 5,500.00 90.00 0.03 3,461.00 3,352.00 5,600.00 90.00 0.03 3,461.00 3,352.00 .5,700.00 90.00 0.03 3,461.00 3,352.00 5,800.00 90.00 0.03 3,461.00 3,352.00 5,900.00 90.00 0.03 3,461.00 3,352.00 6,000.00 90.00 0.03 3,461.00 3,352.00 6,100.00 90.00 0.03 3,461.00 3,352.00 6,200.00 90.00 0.03 3,461.00 3,352.00 6,252.68 90.00 0.03 3,461.00 3,352.00 1J-164 L2 T2 (wp06) 6,287.72 89.30 359.99 3,461.21 3,352.21 6,300.00 89.30 359.99 3,461.36 3,352.36 6,400.00 89.30 359.99 3,462.59 3,353.59 6,500.00 89.30 359.99 3,463.81 3,354.81 6,600.00 89.30 359.99 3,465.03 3,356.03 6,700.00 89.30 359.99 3,466.25 3,357.25 6,800.00 89.30 359.99 3,467.47 3,358.47 DLSEV Vert Section (°i100ft) (ft) 0.00 1,780.72 15.90 1,792.46 0.00 1,821.90 5.99 1,829.43 6.00 1,889.27 1,928.50 -561.08 5,947,654.75 558,116.98 6.00 1,928.50 2,026.74 -561.05 5,947,752.98 558,116.24 6.00 2,026.74 2,028.41 -561.05 5,947,754.66 558,116.23 0.00 2,028.41 2,128.39 -561.05 5,947,854.62 558,115.45 0.00 2,128.39 2,228.37 -561.05 5,947,954.58 558,114.67 0.00 2,228.37 2,328.34 -561.05 5,948,054.54 558,113.89 0.00 2,328.34 2,428.32 -561.05 5,948,154.51 558,113.12 0.00 2,428.32 2,505.78 -561.05 5,948,231.96 558,112.51 0.00 2,505.78 2,528.30 -561.05 5,948,254.47 558,112.33 5.00 2,528.30 2,531.12 -561.05 5,948,257.30 558,112.31 5.00 2,531.12 2,628.30 -561.07 5,948,354.46 558,111.54 0.00 2,628.30 2,728.30 -561.09 5,948,454.45 558,110.74 0.00 2,728.30 2,781.12 -561.09 5,948,507.27 558,110.32 0.00 2,781.12 2,782.98 -561.09 5,948,509.13 558,110.31 2.00 2,782.98 2,828.30 -561.07 5,948,554.44 558,109.97 0.00 2,828.30 2,928.30 -561.03 5,948,654.42 558,109.24 0.00 2,928.30 3,028.30 -560.98 5,948,754.41 558,108.51 0.00 3,028.30 3,128.30 -560.93 5,948,854.40 558,107.78 0.00 3,128.30 3,228.30 -560.88 5,948,954.39 558,107.05 0.00 3,228.30 3,328.30 -560.84 5,949,054.37 558,106.31 0.00 3,328.30 3,428.30 -560.79 5,949;154.36 558,105.58 0.00 3,428.30 3,528.30 -560.74 5,949,254.35 558,104.85 0.00 3,528.30 3,628.30 -560.69 5,949,354.34 558,104.12 0.00 3,628.30 3,728.30 -560.65 5,949,454.32 558,103.39 0.00 3,728.30 3,780.98 -560.62 5,949,507.00 558,103.00 0.00 3,780.98 3,816.02 -560.62 5,949,542.03 558,102.73 2.00 3,816.02 3,828.29 -560.62 5,949,554.31 558,102.63 0.00 3,828.29 3,928.29 -560.64 5,949,654.29 558,101.83 0.00 3,928.29 4,028.28 -560.66 5,949,754.27 558,101.03 0.00 4,028.28 4,128.27 -560.69 5,949,854.25 558,100.23 0.00 4,128.27 4,228.26 -560.71 5,949,954.23 558,099.43 0.00 4,228.26 4,328.26 -560.73 5,950,054.21 558,098.63 0.00 4,328.26 9!13!2005 2:54:24PM Page 4 of 8 COMPASS 2003.118ui1d 48 r.' ~ Halliburton Company ConocOPhil11 HALI~.~suRTON Planning Report -Geographic - - - ---- p,~~ Sperry Drilllrty Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-164 (L6) Company: ConocoPhillips Alaska (Kuparuk) TVt]-Reference: 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) Project: Kuparuk: River Unit MD Reference: 1J-464 (28'+8t~ @ 109.OOft (D141 (28GL+ 81'RF)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-164 (L6) Survey Calculation Method: Minimum Curvature Welibore: 1J-164 L2 Design: 1J-1$4 L2 (wp06) 'I Planned Survey 1J-164 L2 (wp06) Map Map I MD Inclination Azimuth TVD SSTVD +N/-g +EI-W Northing Easting DLSEV Vert Section ~I (ft) (°) (°) (ft) (ft) (ft) , (tt) (ft) (ft) (°/100ft) (ft) 6,900.00 89.30 359.99 3,468.69 3,359.69 4,428.25 -560.75 5,950,154.19 558,097.83 0.00 4,428.25 7,000.00 89.30 359.99 3,469.91 3,360.91 4,528.24 -560.77 5,950,254.17 558,097.03 0.00 4,528.24 7,100.00 89.30 359.99 3,471.13 3,362.13 4,628.23 -560.79 5,950,354.15 558,096.22 0.00 4,628.23 7,200.00 89.30 359.99 3,472.35 3,363.35 4,728.23 -560.82 5,950,454.13 558,095.42 0.00 4,728.23 7,252.88 89.30 359.99 3,473.00 3,364.00 4,781.11 -560.83 5,950,507.00 558,095.00 0.00 4,781.11 1J-164 L2 T3 (wp06) 7,261.41 89.14 0.05 3,473.12 3,364.12 4,789.63 -560.82 5,950,515.52 558,094.94 2.00 4,789.63 7,300.00 89.14 0.05 3,473.70 3,364.70 4,828.22 -560.79 5,950,554.11 558,094.67 0.00 4,828.22 7,400.00 89.14 0.05 3,475.20 3,366.20 4,928.21 -560.71 5,950,654.08 558,093.97 0.00 4,928.21 7,500.00 89.14 0.05 3,476.70 3,367.70 5,028.20 -560.63 5,950,754.06 558,093.27 0.00 5,028.20 7,600.00 89.14 0.05 3,478.20 3,369.20 5,128.18 -560.55 5;950,854.04 558,092.57 0.00 5,128.18 7,700.00 89.14 0.05 3,479.70 3,370.70 5,228.17 -560.47 5,950,954.01 558,091.87 0.00 5,228.17 7,800.00 89.14 0.05 3,481.20 3,372.20 5,328.16 -560.39 5,951,053.99 558,091.17` 0.00 5,328.16 7,900.00 89.14 0.05 3,482.70 3,373.70 5,428.15 -560.31 5,951,153.97 558,090.47 0.00 5,428.15 8,000.00 89.14 0.05 3,484.20 3,375.20 5,528.14 -560.23 5,951,253.94 558,089.77 0.00 5,528.14 8,100.00 89.14 0.05 3,485.70 3,376.70 5,628.13 -560.15 5,951,353.92 558,089.07 0.00 5,628.13 8,200.00 89.14 0.05 3,487.20 3,378.20 5,728.12 -560.07 5,951,453.90 558,088.37 0.00 5,728.12 8,253.12 89.14 0.05 3,488.00 3,379.00 5,781.23 -560.03 5,951,507.00 558,088.00 0.00 5,781.23 1J-164 L2 T4 (wp06) 8,290.66 88.39 0.02 3,488.81 3,379.81 5,818.76 -560.01 5,951,544.53 558,087.73 2.00 5,818.76 8,300.00 88.39 0.02 3,489.07 3,380.07 5,828.10 -560.01 5,951,553.87 558,087.66 0.00 5,828.10 8,400.00 88.39 0.02 3,491.88 3,382.88 5,928.06 -559.98 5,951,653.81 558,086.91 0.00 5,928.06 8,500.00 88.39 0.02 3,494.69 3,385.69 6,028.02 -559.96 5,951,753.76 558,086.15 0.00 6,028.02 8,546.56 88.39 0.02 3,496.00 3,387.00 6,074.56 -559.94 5,951,800.29 558,085.80 0.00 6,074.56 1J-164 L2 T5 (wp06) 8,600.00 88.39 0.02 3,497.50 3,388.50 6,127.98 -559.93 5,951,853.71 558,085.40 0.00 6,127.98 8,653.32 88.39 0.02 3,499.00 3,390.00 6,181.28 -559.91 5,951,907.00 558,085.00 0.00 6,181.28 Build ~ 3°/100ft -Exit Sand High Prior to Crossing Fault, 8653ft MD, 3499ft TVD -1J-164 L2 T6 (wp06) 8,700.00 89.79 0.00 3,499.74 3,390.74 6,227.95 -559.91 5,951,953.67 558,084.64 3.00 6,227.95 .8,800.00 92.79 359.97 3,497.49 3,388.49 6,327.91 -559.93 5,952,053.62 558,083.84 3.00 6,327.91 8,841.30 94.03 359.96 3,495.03 3,386.03 6,369.14 -559.95 5,952,094.84 558,083.50 3.00 6,369.14 8,900.00 94.03 359.96 3,490.91 3,381.91 6,427.69 -559.99 5,952,153.39 558,083.00 0.00 6,427.69 9,000.00 94.03 359.96 3,483.88 3,374.88 6,527.45 -560.06 5,952,253.13 558,082.15 0.00 6,527.45 9,100.00 94.03 359.96 3,476.86 3,367.56 6,627.20 -560.13 5,952,352.87 558,081.31 0.00 6,627.20 9,200.00 94.03 359.96 3,469.83 3,360.83 6,726.95 -560.20 5,952,452.61 558,080.46 0.00 6,726.95 9,254.54 94.03 359.96 3,466.00 3,357.00 6,781.35 -560.24 5,952,507.00 558,080.00 0.00 6,781.35 1 J-164 L2 T9 (wp06) 9,300.00 92.67 359.99 3,463.35 3,354.35 6,826.74 -560.26 5,952,552.38 558,079.63 3.00 6,826.74 9,400.00 89.67 0.06 3,461.31 3,352.31 6,926.71 -560.21 5,952,652.34 558,078.89 3.00 6,926.71 9,439.69 88.48 0.08 3,461.96 3,352.96 6,966.39 -560.17 5,952,692.02 558,078.63 3.00 6,966.39 9,500.00 88.48 0.08 3,463.56 3,354.56 7,026.68 -560.08 5,952,752.30 558,078.25 0.00 7,026.68 9,600.00 88.48 0.08 3,466.22 3,357.22 7,126.65 -559.93 5,952,852.25 558,077.61 0.00 7,126.65 9,700.00 88.48 0.08 3,468.88 3,359.88 7,226.61 -559.79 5,952,952.20 558,076.98 0.00 7,226.61 9,800.00 88.48 0.08 3,471.54 3,362.54 7,326.57 -559.64 5,953,052.16 558,076.35 0.00 7,326.57 9,854.87 88.48 0.08 3,473.00 3,364.00 7,381.42 -559.56 5,953,107.00 558,076.00 0.00 7,381.42 1J-164 L2 T70 (wp06) 9,900.00 87.14 359.87 3,474.73 3,365.73 7,426.52 -559.58 5,953,152.09 558,075.63 3.00 7,426.52 9/13/2005 2:54:24PM Page 5 of 8 COMPASS 2003.11 Build 48 ~~~~!~~ ~ ~-' Halliburton Company COI'lOCO~il~~lp5 Alaska Planning Report -Geographic Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) ND Reference: Project: Kuparuk River Unit MD Reference: Site: .Kuparuk 1J Pad North Reference: Well: Plan 1J-164 (L6) Survey Calculation Method: Wellbore: 1J-164 L2 Design: 1J-164 L2 (wp06) HAL4f8UATON Speery Drilling Sfrvicers Well Plan 1J-1.64 (L6) 1J-164 (28'+81') C~2109.OOft (D141 (28GL + 81'RF)) 1 J-164.(28'+81') @ 109:OOft (D141 (28GL + 81'R7=)) True Minimum Curvature Planned Survey 1J-164 L2 (wp06) Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting pLSEV Vert Section (ft} (°) (°) (ft} (ft1 (~) (~) (ft) (ft) (°/100ft) (ft) 9,906.71 86.94 359.84 3,475.07 3,366.07 7,433.22 -559.59 5,953,158.79 558,075.56 3.00 7,433.22 10,000.00 86.94 359.84 3,480.05 3,371.05 7,526.38 -559.85 5,953,251.93 558,074.58 0.00 7,526.38 10,055.15 86.94 359.84 3,483.00 3,374.00 7,581.45 -560.00 5,953,307.00 558,074.00 0.00 7,581.45 1J-164 L2 T11 (wp06) 10,072.34 86.85 0.17 3,483.93 3,374.93 7,598.61 -560.00 5,953,324.16 558,073.87 2.00 7,598.61 10,100.00 86.85 0.17 3,485.45 3,376.45 7,626.23 -559.91 5,953,351.77 558,073.74 0.00 7,626.23 10,200.00 86.85 0.17 3,490.95 3,381.95 7,726.08 -559.61 5,953,451.61 558,073.26 0.00 7,726.08 10,255.48 86.85 0.17 3,494.00 3,385.00 7,781.47 -559.44 5,953,507.00 558,073.00 0.00 7,781.47 iJ-164 L2 T12 (wp06) 10,265.19 86.79 359.99 3,494.54 3,385.54 7,791.17 -559.43 5,953,516.70 558,072.94 2.00 7,791.17 10,300.00 86.79 359.99 3,496.48 3,387.48 7,825.93 -559.44 5,953,551.45 558,072.66 0.00 7,825.93 10,400.00 86.79 359.99 3,502.08 3,393.08 7,925.77 -559.46 5,953,651.28 558,071.86 0.00 7,925.77 10,500.00 86.79 359.99 3,507.67 3,398.67 8,025.61 -559.48 5,953,751.11 558,071.06 0.00 8,025.61 10,523.85 86.79 359.99 3,509.00 3,400.00 8,049.43 -559.48 5,953,774.92 558,070.87 0.00 8,049.43 10,600.00 86.79 359.99 3,513.26 3,404.26 8,125.46 -559.50 5,953,850.94 10,700.00 86.79 359.99 3,518.85 3,409.85 8,225.30 -559.52 5,953,950.77 10,800.00 86.79 359.99 3,524.44 3,415.44 8,325.14 -559.55 5,954,050.60 10,900.00 86.79 359.99 3,530.03 3,421.03 8,424.99 -559.57 5,954,150.43 11,000.00 86.79 359.99 3,535.62 3,426.62 8,524.83 -559.59 5,954,250.26 11,100.00 86.79 359.99 3,541.21 3,432.21 8,624.65 -559.61 5,954,350.09 11,200.00 86:79 359.99 3,546.80 3,437.80 8,724.52 -559.63 5,954,449.92 11,257.17 86.79 359.99 3,550.00 3,441.00 8,781.60 -559.65 5,954,507.00 1J-164 L2 T13 (wp06) 11,274.77 87.15 0.02 3,550.93 3,441.93 8,799.18 -559.65 5,954,524.57 11,300.00 87.15 0.02 3,552.19 3,443.19 8,824.37 -559.64 5,954,549.77 11,400.00 87.15 0.02 3,557.17 3,448.17 8,924.25 -559.61 5,954,649.63 11,500.00 87.15 0.02 3,562.15 3,453.15 9,024.13 -559.58 5,954,749.49 11,600.00 87.15 0.02 3,567.13 3,458.13 9,124.00 -559.55 5,954,849.36 ~, 11,657.72 87.15 0.02 3,570.00 3,461.00 9,181.65 -559.53 5,954,907.00 BHL ~ 11668ft MD, 3570ft ND - 541ft FSL 8~ 2212it FWL -Sec 23-T71 N-R10E - 41/2" 558,070.26 0.00 8,125.46 558,069.46 0.00 8,225.30 558,068.66 0.00 8,325.14 558,067.86 0.00 8,424.99 558,067.06 0.00 8,524.83 558,066.26 0.00 8,624.68 558,065.46 0.00 8,724.52 558,065.00 0.00 8,781.60 558,064.86 2.00 8,799.18 558,064.68 0.00 8,824.37 558,063.93 0.00 8,924.25 558,063.18 0.00 9,024.13 558,062.43 0.00 9,124.00 558,062.00 0.00 9,181.65 9/1312005 2:54:24PM Page 6 of 8 COMPASS 2003.11 Build 48 ~ • ~' Halliburton Company ' , CanaCa~ill~ps Pl i R hi t G t-taLLt~URT ON __ ~ ann ng epor eograp - c Alaska SEwrry aHilino S~rvla~s Database: EDM 2003.11 Single User Db Local:Co-ordinate Reference: Well Plan 1J-164 (L6) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-164 (28'+81');ea 1Q9.OOft (D141 (28GL`+ 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164(28'+81'} ~ 109.OOft (D141 (28GL + 81'RF)) Site: Kuparuk 1J Pad North Reference:' True Well: Plan 1J-164 (L6) Survey Calculation Method: Minimum Curvature Wellbore: 1J-164 L2 Design: 1J-164 L2 (wp06) Geologic Targets 1J-164 L2 I TVD Target Name +N/-S +E!-W Northing Easting (ft) -Shape ft ft (ft) lft) 1 3,570.00 1J-164 L2 Toe (wp06) 9,181.65 -559.53 5,954,907.00 558,062.00 - Point 3,483.00 1J-164 L2 T11 (wp06} 7,581.45 -560.00 5,953,307.00 558,074.00 i - Point 3,473.00 1J-164 L2 T3 (wp06) 4,781.11 -560.83 5,950,507.00 558,095.00 - Point ~ 3,461.00 1J-164 L2 T2 (wp06) 3,780.98 -560.62 5,949,507.00 558,103.00 - Point 3,465.00 1J-164 L2 T8 (wp06) 6,581.33 -559.80 5,952,307.00 558,082.00 - Point 3,509.00 1J-164 L2 T6 (wp06) 6,181.28 -559.91 5,951,907.00 558,085.00 - Point 3,494.00 1J-164 L2 T12 (wp06) 7,781.47 -559.44 5,953,507.00 558,073.00 - Point 3,496.00 1J-164 L2 T5 (wp06) 6,081.27 -560.69 5,951,807.00 558,085.00 - Point 3,509.00 1J-164 L2 T7 (wp06) 6,481.32 -560.58 5,952,207.00 558,082.00 - Point 3,461.00 1J-164 L2 T1 (wp06) 2,780.86 -561.42 5,948,507.00 558,110.00 - Point 3,466.00 1J-164 L2 T9 (wp06) 6,781.35 -560.24 5,952,507.00 558,080.00 - Point 3,488.00 1J-164 L2 T4 (wp06) 5,781.23 -560.03 5,951,507.00 558,088.00 - Point 3,473.00 1J-164 L2 T10 (wp06} 7,381.42 -559.56 5,953,107.00 558,076.00 - Point 3,550.00 1J-164 L2 T13 (wp06) 8,781.60 -559.65 5,954,507.00 558,065.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Qiameter Diameter (ft) fft) C') (") 2,324.56 2,203.00 10-3/4 13-1/2 4,250.34 3,446.00 7-5/8 9-7/8 11,657.71 3,570.00 4-1/2 6-3/4 9/13/2005 2:54:24PM Page 7 of 8 COMPASS 2003.11 Build 48 ~~~~~ • rr' Halliburton Company ~OI"10CO~~ii~~i S p i r hi Pl R rt G NALt_IBUAT©N - ann ng epo eog ap c - ~ ices S siia ~ erv Dril ~ Database: EDM 2003.11 Single User Db LoCa{ Co-ordinate Reference: Well Plan 1J-164 (L6) Company: ConocoPhillips Alaska (Kuparuk) 7YD Reference: 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) Project: Kuparuk River Unit MD Reference: 1J-164 (28'+81') @ 109.OOft (D141 (28GL + 81'RF)) Site: Kuparuk 1J Pad North Reference:.- True Well: Plan 1J-164 (L6) Survey Calculation Method: Minimum Curvature: Wellbore: 1J-164 L2 Design: 1 J-164 L2 (wp06) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) (ft) (ft) (ft) Name 1,593.05 23.79. 343.04 1,543.00 285.84 4.64 Base of Permafrost 1,703.47 24.02 332.14 1,644.00 327.04 -12.37 T3 2,025.77 26.24 314.23 1,935.00 431.61 -102.06 K15 2,324.56 26.24 314.23 2,203.00 523.73 -196.72 T3 + 550 (CSG P71 3,162.82 41.39 339.41 2.,922.00 863.85 -442.30 Ugnu C 3,434.03 50.80 346.95 3,110.00 1,050.71 -497.73 Ugnu B 3,497.27 53.05 348.41 3,149.00 1,099.34 -508.34 Ugnu A 3,747.36 62.11 353.45 3,283.00 1,307.57 -541.10 K-13 4,250.33 77.00 0.07 3,446.00 1,780.72 -561.21 West Sak D (77°) 9/13/2005 2:54:24PM Page 8 of 8 COMPASS 2003.118ui1d 48 ! 6 r~ ~~~~ ~ ~__ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-164 1 J-164 L2 • Anticollision Summary 13 September, 2005 HAL.1~1 ~31.1R'Tt Sperry Drilling Services ~~~ ~~ ~ `' _ ~ 3 ~ ~ ~ .~.~ SURVEY PROGRAM NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-164 (L6) ConocoPhillips AWska (Kuparuk) ANTI-COLLISION SETTINGS Date: 201L5-IN-119TUII:INF.a1 ValidatM: Yes Version: Ground Level: 81.00 Engineering Interpolation Method: MD Irrterval: 50Stations +N/S +FJ-W Northing EasOng Latittude Longitude Slot West Sak Depth Fmm Depth Ta Sunet/Plan Tool Depth Range From: 4250.33 To 11657.72 0.00 0.00 6945730.87 558691.02 70°15'44.408N 149°31'31.87W 211.00 NINI.00 CB-GYRO-SS Maaimun Range:5000 Calcuation Method: Minimum Curvature 81N1.00 J241.33 MWMIFR-AK-CAZSC Reference: Plan: 7J-164 L2 (wp08) Error System: ISCWSA iL51133 11657_511 IJ-16J L2 (wp%) MWDfIFR-AK-CA~SC Scan Method: Trav. Cylinder North -- - ---- -- Error Surtace: Elliptical Conic SQ Warning Method: Rules Based 330 25 n vo 1J-09 ; 5375 From Colour To MD 0 250 250 500 500 750 Plan 1J-12 : 4256'M~ 750 1000 180 1000 1250 1250 --- 1500 1500 - 1750 1750 2000 'Travelling Cylinder Azimuth (TFO+AJI) ~°~ vs Centre to Centre Separation X200 ft/ink 2000 - 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 REFERENCE INFORMATION 8000 9000 Coordinate (N/E) Reference: Well Plan 1J-164 (L6), True North 9000 10000 Vertical (TVD) Reference: 1J-t 64 (28'+81') @ 109.0011 (D141 (28GL + 81'RF)) 10000 11000 Section (VS) Reference: Slot - (O.OON, O.OOE) 11000 12000 Measured Depth Reference: tJ-164 (28'+81') ~ 109.OOft (D141 (28GL + 81'RF)) Calculation Method: Minimum Curvature ~~~ 240 210 ~ i \\° 90 120 150 30 180 Travelling Cylinder Azimuth (TFO+AZI) i°i Vs Centre t° Centre Separation 115 Wini SECTION DETAILS Sec MD Inc Azi TVD +N/S +E/-W DLeg TFace VSec Target 1 4250.13 77.00 0.07 3446.00 1780.72 561.21 0.00 0.00 1780.72 2 4262.33 78.91 0.07 3448.60 1792.46 561.20 15.90 0.00 1792.46 3 4292.31 78.91 0.07 3454.27 1821.90 561.17 0.00 0.00 1827.90 4 4498.33 91.27 0.00 Sd71.88 2026.74 567.05 6.00 -0.30 2026.74 5 4977.48 97.27 0.00 3461.28 2505.78 561.05 0.00 0.00 2505.78 6 5002.83 90.00 159.99 3461.00 2531.12 561.05 5.00 -179.64 2537.72 7 5252.83 90.00 159.99 3461.00 2781.12 561.09 0.00 0.00 2781.72 1J-764 L2 Tt (wp06) 8 5264.69 90.00 0.03 3467.00 2782.98 561.09 2.00 90.00 2782.98 9 6252.68 90.00 0.03 3467.00 3780.98 560.62 0.00 0.00 3780.98 1J-164 L2 T2 (wp06) 10 6287.72 89.10 359.99 3d61.21 1816.02 560.62 2.00 -176.76 3816.02 11 7152.88 89.30 359.% 3473.00 4781.11 560.83 0.00 0.00 d781.11 1J-164 L2 TS (wp08) 12 7261.41 69.14 0.05 3473.12 4789.61 360.82 2.00 160.03 4789.63 73 8253.12 89.74 0.05 3488.00 5781.21 560.01 0.00 0.00 5787.23 tJ-164 L2 T4 (wp06) 14 8290.66 88.39 0.02 1488.81 5818.76 560.01 2.00 -777.69 8818.76 15 8653.32 88.39 0.02 3499.00 6181.28 559.91 0.00 0.00 6181.28 1J-764 L2 T6 (wp06) 16 88d1.30 94.03 359.% 3495.03 6369.74 559.95 3.00 -0.56 6369.1d t7 9254.56 90.03 359.% 3466.00 6781.35 -560.24 0.00 0.00 6781.35 1J-166 L2 T9 (wp06) 18 9439.69 88.48 0.08 3461.96 6966.19 560.17 3.00 778.71 6966.39 19 9854.87 88.48 0.08 3473.00 7381.42 559.66 0.00 0.00 7381.42 7J-16d l2 T10 (wp06) 20 9906.71 86.% 359.84 3475.07 7411.22 -559.59 3.00 -171.09 7413.22 21 10055.15 86.94 359.84 3483.00 7581.45 560.00 0.00 0.00 7581.45 1J-16d L2 T71 (wp%) 2210072.34 86.85 0.17 3483.93 7598.61 560.00 2.00 105.14 7598.61 21 10255.d8 86.85 0.17 3494.00 7781.47 369.44 0.00 0.00 7781.d7 1J-164 L2 T12 (wp06) 24 10265.19 86.79 159.% 3494.54 7791.17 559.43 2.00 -105.97 7791.17 25 11257.17 86.79 359.% 3550.00 8781.60 559.65 0.00 0.00 8781.60 1J-164 L2 T71 (wp06) 2611274.77 87.15 0.02 3550.93 8799.18 559.65 2.00 d.92 8799.18 27 11657.72 87.15 0.02 1570.00 9787.65 559.53 0.00 0.00 9181.65 1J-t6d L2 Tce (wp06) Conoco~illips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-164 (L6) Well Error: O.OOft Reference Wellbore 1J-164 L2 Reference Design: 1J-164 L2 (wp06) Halliburton Company Anticoliision Report Local Co-ordinate Reference: TVD Reference: MD Reference: .North Reference• Survey Calculation: Method: Output errors are at Database: OffsetTVD Reference: • HALLIBUATaN ~Itry Drllllt~ S~Irvtc~s Well Plan 1J-164'(L6) 1 J-164 (28'+81') @ 109`.OOft (D141 (28GL + 81'RF)) 1 J-164 (28'+81') C«~ 109.OOft (D141 (28GL + g1'RF)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single UserDb Offset Datum -_ _- _- _- Reference 1J-164 L2 (wp06) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 4,250.33 to 11,657.72ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 5,OOO.OOft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 9/13!2005 From To ft O ft Surve We{Ibore) O Y( Toot Name Description 28.00 800.00 1J-164 (wp06) (1J-164) CB-GYRO-SS Camera based gyro single shot 800.00 4,250.33 1J-164 (wp06) (1J-164) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4,250.33 11,657.50 1J-164 L2 (wp06) (1J-164 L2) MWD+IFR-AK-GAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depot. Deptt- Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft)_ (ft) Kuparuk 1J Pad 1J-03 - 1J-03 - 1J-03 4,266.33 5,200.00 3,757.92 101.15 3,656.77 Pass -Major Risk 1 J-09 - 1 J-09 - 1 J-09 5,375.46 4,700.00 314.18 141.06 173.12 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 4,260.34 5,500.00 2,752.30 99.59 2,652.71 Pass -Major Risk Plan 1J-101 (L7) -Plan 1J-L7 A Lat -Plan 1J-L7 P 11,590.98 11,600.00 1,260.44 319.58 940.87 Pass -Major Risk Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1J-L9 L 11,402.05 13,095.45 3,747.28 318.35 3,428.93 Pass -Major Risk Plan 1J-118 (L10) -Plan 1J-L10 Lat A-Plan 1J-L' Out of range Plan 1J-12 -Plan 1J-12 (K2 Prelim) - 1J-12 (K2 Pr 4,256.41 4,499.98 390.72 72.50 318.22 Pass -Major Risk Plan 1J-120 (L11) -Plan 1J-L11 Lat A -Plan 1 J-L' Out of range Plan 1J-122 (L12) -Plan 1J-L12 Lat A -Plan 1J-L' Out of range Plan 1J-124 (L13) -Plan 1 J-L13 Lat A -Plan 1 J-L' Out of range Plan 1J-166 (L5) - 1J-166 - 1J-166 (wp03) 11,474.94 12,533.12 1,280.34 323.20 957.14 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 L1 - 1J-166 L1 (wp03) 11,466.33 12,508.16 1,267.60 349.81 917.79 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 L2 - 1J-166 L2 (wp03) 11,463.89 12,498.71 1,268.26 354.52 913.74 Pass -Major Risk Plan 1J-168 - 1J-168 - 1J-168 (wp10 -Revised 8/ 8,561.88 12,799.95 4,078.04 235.76 3,842.29 Pass -Major Risk Plan 1J-168 - 1J-168 - 1J-168 Rig 8,739.98 12,995.00 4,064.03 224.12 3,839.92 Pass -Major Risk Plan 1J-168 - 1J-168 L1 - 1J-168 L1 Rig 8,745.06 12,967.00 4,215.32 230.97 3,984.35 Pass -Major Risk Plan 1J-168 - 1J-168 L1 - 1J-168 L1(wp10 - Revis 8,479.39 12,699.95 4,223.63 259.62 3,964.00 Pass -Major Risk Plan 1J-168 - 1J-168 L2 - 1J-168 L2 (wp10 - Revi; 8,532.38 12,750.00 4,225.41 261.95 3,963.46 Pass -Major Risk Plan 1J-170 (L4) -Plan 1J-L4 LatA-Plan 1J-L4 L. 8,611.47 12,081.58 2,784.55 256.11 2,528.44 Pass -Major Risk Plan 1J-50 (Ugnu Disposal) -Plan 1J-UgnuDispos 4,548.50 3,600.00 1,522.00 91.35 1,430.65 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S Out of range CG -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9/132005 3:05:38PM Page 2 of 2 COMPASS 2003.11 Build 48 0~~~`Ii~AL 1J-164~t Drilling H umm (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-112" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips .Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-164L2 Drilling Hazards Summary.doc ~q prepared by Shane Cloninger ~ g ~ # h,~ ~ ~ ^ 9/21/2005 1:18 PM 4 ~; . n (,~ insulated Conductor n Casi nf5, 20", 94#, K55 x ~~ 34", 0.312" WT @ +/- BO' MD ~. 10-3/4", 68#, L80, BTC, R3 @2,318'MD/2,193'TVD ~~ (r_i? 26.24 degrees TD 13-3/8" hole Top of Ugnu C a(7, 3,163' MD / 2,922' TVD - -~ 'r1 °' t+1 F ~ C" S W . 'OIL ~ ~ o' /~ o m o 3 ~ ~' ^. A U i c, Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer above. Top of West Sak B 3,434' MD / 3,110' TVD ~- ' ~ B' o o ~~ n4 ti~2_ N^~\ Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/x", 5,000 ksi Tubing String: 4-1/2", 12.6 #, L-80, IBTM (I) 3.875" DB nipple set @ 500' (1)Gas Lift Mandrel, CAMCO 4-I/2"x l" ModeIKBG- 2, one(1) set at 67 deg X,XXX' MD, X,XXh TVD. (I) Gas Lift Mandrel, CAMCO 4-1/2" x I" Model KBG- 2, one (1) set at 68 deg, X,XXX' MD, X.XXX' TVD. (I)Sliding Sleeve, with 3.812"nipple, one (1)joint above ~ packer- X_XXS' MD, X.XXX' TVD ~~ 164 L2 "D" Sand Window 77 de' "D" Liner, 4-I/2", 12.8#, L80, BTCM, R3 ~~ (0.125" z 2.5" slots, 32 per foot, 5.9%open area) ~~~ ass- ~ Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. ~-~ endow - @4,239'MD/3,446'TVD - ~ ~ 77 dey~ees "B" Liner, 4-1/2", 12.8#, L80, BTCM, R3 ~ (0.125" x 2.5" slots, 32 per foot, 5.9% open area) ~ T. ,~ ' Top of West Sak A ~ ~ 3,49TMD/3,149'TVD ~ ~~',,,, Tubing, 4-'/" IBTM, from LEM to A2 Liner, with seal stem and - AZ Sand Liner, 4-1/2", 12 8#, L80, CAMCO 3.562" "DB" nipple. ~ , -~ BTCM, R3 '/ slotted and''/z blank, ~1 cun.+vriclrrs fcr ia~dnlion Seal bore and ZXP packer for A2 liner +/- 90' below "B" window 7-5/8", 40#, L-80, BTCM, R3 Csg @ 5,419' MD / 3,670' TVD @ 80 degrees TD 9-5/8" hole IE-105 FINAL: nsp Nnu n na.~~nK swsal ntiI' NAI) 27 Nontung.. 5!l39!lWi I'ad I?Icvntii~n. RG. I' nMSI. Doyon Rig 141 Rig Floor (RF) (a?, 0' Elevation: 94.1' AMSI. \ I1-164 L2: 1~S/4" D sand lateml TD 11,648' MD / 3,570' TVD ~ Angle 87 de~ees - ~._ 6-3/4" "B" sand lateral TD 11,655' MD / 3,619' TVD Angle 87 degrees I J-164: 6-3/4 A2 sand lateral TD 11,667' MU / 3,793' TVD 1 Angle 87 degrees • • • r TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRA/N'SMI``TTA/L LETTTER /l WELL NAME ~~G~ (~J ~~~ ~`~ PTD# Z~S- ~ ~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbor segment of LATERAL existing well ~/~L ~°~ /~ ~ ' Permit No;--ate ~'S~~API No. S~ ~~z~ .`" ~ ~- , ~ ,,~`~ (If API number Production should continue to be reported as t/ last two (2) digits a function. of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (ply records,-data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to produce/infect is contingent perforate and , upon issuance of a conservation order approving a spacing exception. (Company Name) assumes _ the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 8 a~ Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLfST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-164L2 -Program SER Well bore seg ^~ PTD#:2051460 Company GONOCOPHILLIPS ALASKA INC ' '~~' ~'°cc!Type SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Pemlitfee attached- , - - No_ West Sak D Sand multilateral well segmen#; fee_waivetl per 20 AAC 25A05(e), - - _ - 2 Lease number appropriate--------__-________________________ _____Yes_ --_-__ - - - - 3 Unique well-name andnumbe[_________________________________ _____Yes- _-__-_-_-___-.._- -------------------------------------------------------- 4 Well located in_a-defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ - _ _ Yes _ _ _ _ _ _ _ KRU West-Sak Oil Pool, goyerned_by Conservation_Qrder No, 4068, _ _ _ - _ - _ _ - _ _ _ _ _ _ _ 5 Well located proper distance from drilling unit_bounda[y_ - Yes _ . . - Well is moCe_than_500 feet from an external property line.. - - - . - - 6 Well located proper distance from other wells- _ - _ _ _ Yes - - . - - _ No restrictions as_to well spacing in CQ_406B.- _ - - - 7 Sufficient acreage available in dril_linq unit- _ - - _ - - _ - - - Yes - - - - Nq restrictions as-to well spacing except that no_pay shall be opened in a well closer _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 IfdeYiated,is_wellboreplat_included_________________________,___ --__-Yes_ --__-than 500fee1to_anexternal-propertylkne.__-__-___-__-_--_-__-__.__-_,__-__-_-_- 9 Ope[ator only affected party. - - - - - Yes - - - - - - - - - - - - - 10 OpeCakorhas-appropriate-bondknforce--- - ---- -- - -- -- - --Yes- -- - -- -- -- -- --------~--- -- - ------ - --- - ---- ---- 11 Permit_canbeissuedwithoutconseryationorder___--_-____-__-_____ _--__Yes- __-___.____-__.-__-__-_-_____-__-__-__-_.-___-__-____-___-__-_- Appr Date 12 Permit can be issued without administrativ_e_approva_I_-.--__-__________ _____Yes_ _-__,__-__-__-__-__-_.-_-__-_-_--_-__-__-__-_-_--___.__-___-__._-_-___ SFD 10!5/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized ky_InjQCtion Order # (put_IQ# in-comments)- (For- Yes _ _ - . _ Area Injection Order No._26- - _ _ _ _ . - _ - - - _ - - - - - 15 Allwells-within1/4_mileareaof[eyiewidentified(Forsetvicewellonly)---------- -----Yes- ____._KRU1D-131_is750'away,.-_---_-_-_-,---_--_-_--_--_-,_----_--_-__--.----- 16 Pre-produced injector: duration of pre production Less than- 3 months-(For service well only) - _Yes - - -Mike Greener, CPAI,_ 1.0-5.05; well will be pre-produced for about 1 month.- _ _ - _ - 17 ACMP_FindingofConsistency_hasbeenissued_forthispr_oject_______________ _-__ NA__ _-__-__,-_-_-__-__-_--____-__-__-____-__-__-__________-_-__________-_ Engineering 18 Conductor string-p_rovided __--______________________________ _____ NA_- __-__-C4nductorset_in mot_herb4re,_1J,164(205-144)._-_--_-__---___--__---___-__-___ 19 Surface casing_protectsallknownUSDWS_________________________ ____ NA__ __-__-Altaquifers exempted, 40CFR_147.102_(b)_(3).-_______-__-_____-__-____-_- --__ - 20 CMT-vol_ adeguate_to circulate-on conductor & surf-csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ _ _ _ -Surface casing set in_ motherbore. _ - _ _ - _ _ 21 CMT_vol-adequate-to tie-in long string tosurf csg - No - - - - - - - - - - 22 C_MT will cover all kno_wnproductiye horizons- _ - . - - _ - - _N_o- _ _ Slotted liner completion planned.- Any hydrocarbon_zones abov_e_WSwill be cemented, 23 Casing designs adequate for C, T B &-permafrost- _ - - - _ - - _ NA- M4therbore tubulars meetdesign requirements.- NA for slotted liner.~ 24 Adequate tankage_or reserve pit - - - _ - - _ - _ - - - . - _Yes _ - - - Rig is_equipped with steetpits.. No reserve-p_itplanned, All waste to approved annulus_or disposal well. 25 Ifa_re-drill,has-a 10.403 for abandonment peen aRP-roved--____--__-- --_ -_- NA_ -__-_--__-_-_-___-___-_-___--__--_-_--______________________ 26 Adequate wellbore separation-proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ . _ _ _ _ _ Proximit analysisperformed. _yearest wellbore is 6_lateral-~70 tvd below.- Vertical separation increases, - - - _ , - 27 If diverterrequired,doesitmeetregulatigns__----__-_-_-.__--____- _--- N_A-- _-___BOPstackwillal[eady-be in place___________________________--_--_-___-_-_-_,_ Appr Date 28 Drilling fluid-program Schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ - _ _ - _ Maximum expected fo[matipn pressure ~$.7 EMW._ 8.6 ±ppg planned in WS.-Weight adjusted as_necessary._ . - TEM 101612005 29 BOPEs, do they meet-regulation - - - - - - - Yes - - - - - - - - - - - - - - - - '~ 30 BOPE.press ralinq appropriate; test to-(put prig to comments)- - _ _ - - - _ . _Yes _ _ - - - MASP calculated at 1214 psi. 3000-psi_BQP_ testproposed.. - - - - - - - - - - - - - - 31 Choke manifold complies wJAPI_RP-53 (May 84). - - Yes - - - - 32 Work willoccurwithoutoperationshutdown__-______________________ _-_-Yes_ _-__--_-__-_--__-_-_--_--_,__-_-__-__---,_._ - - - - - 33 Is presence-of ti2S gas prcbable_ _ - _ _ - . _ - _ _ _ - - - - - - - - - - - - - - - - - _ - - No- _ _ _ _ - - H2$ has notbeen reported in WS._ Rig is equipped_with sensors and ala[ms, - _ - _ _ - - _ - _ _ _ - _ _ - _ . _ - - 34 Mechanical_contl_ition of wells within AOR verified (Fors_eNice well gnly) - - - _ - - Yes _ - _ - _ 2 wells in-AQR._ No issues identified. - _ _ - _ _ _ - - _ _ _ - _ _ _ - _ _ - _ - _ - _ _ _ - _ _ - _ - _ - _ - _ - Geology 35 Pe[mit_eanbeissuedw/ohydrogen_sulfidemeasures-_-__-___.-___-_, -_-_Yes_ _----------------_-__--__--_ -------------------------------------------- 36 l)ata_presented on potential overpressure zones Yes - Extimated reservoir pressure is $.7 gpg_EMW.- - - - - - - - - , - - - - - - , _ Appr Date 37 Seismic analysis of shallow gas-zones - - - - - - - NA - - - - - - - - - - - - - - - - - - SFD 101512005 38 Seabed condition survey_(if off--shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - _ NA- _ _ - 39 -Contact name/phor?e_for weekly progress_reports [exploratory only]- - - - _ _ - - - NA_ _ - Geologic Commissioner: Date: Engineering Date Public Commissioner: Commi Date West Sak D Sand multilateral injection well segment. ~7~- ,~®-~~DS /o -~~-0~ • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and io simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 23 10:41:23 2006 Reel Header Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • ~1~~' Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-164 L2 API NUMBER: 500292327861 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 23-MAR-06 JOB DATA MWD RUN 2 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0004025932 MW0004025932 MW0004025932 LOGGING ENGINEER: T. CALVIN P. ORTH P. ORTH OPERATOR WITNESS: M. THORTON D. GLADDEN D. GLADDEN MWD RUN 10 MWD RUN 11 MWD RUN 12 JOB NUMBER: MW0004025932 MW0004025932 MW0004025932 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN M. THORTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1919 FEL: 2517 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLER S ~ 6r- l~~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2332.0 2ND STRING 6.750 7.875 4248.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF AN OPENHOLE SIDETRACK AT 5470'MD/ 3463'TVD WITHIN THE RUN 8 INTERVAL OF THE 1J-164 L2 PBl WELLBORE. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,8,10-12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 {EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED ACOUSTIC CALIPER (ACAL) THE PURPOSE OF MWD RUN 7 WAS TO POSITION THE WHIPSTOCK (THE TOP OF WHICH WAS AT 4248'MD/3442'TVD), MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. MWD RUNS 8,10,11 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP AND RUNS 8,10-12 INCLUDED AT-BIT INCLINATION (ABI). 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 1,2,7,8,10-12 REPRESENT WELL 1J-164 L2 WITH API#:50-029-23278-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11524'MD/3561'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 • Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2297.0 11458.5 RPS 2310.0 11465.5 FET 2310.0 11465.5 RPD 2310.0 11465.5 RPX 2310.0 11465.5 RPM 2310.0 11465.5 ROP 2342.5 11524.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2297.0 7 4248.5 8 4294.0 10 5470.0 11 8620.0 12 9474.0 REMARKS: MERGED MAIN PASS. MERGE BASE 4248.0 4294.0 5470.0 8620.0 9474.0 11524.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 11524 6910.5 18455 2297 11524 RPD MWD OHMM 4.06 2000 62.668 18312 2310 11465.5 RPM MWD OHMM 0.41 354.58 51.4538 18312 2310 11465.5 RPS MWD OHMM 3.75 1217.56 53.4082 18312 2310 11465.5 ! r RPX MWD OHMM 2.2 2000 51.593 18312 2310 FET MWD HOUR 0.16 417.56 2.4164 18312 2310 GR MWD API 22.29 126.23 68.8933 18324 2297 ROP MWD FT/H 0.39 641.18 178.84 18364 2342.5 First Reading For Entire File..........2297 Last Reading For Entire File...........11524 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2297.0 4248.0 RPD 2310.0 4248.0 RPX 2310.0 4248.0 FET 2310.0 4248.0 RPS 2310.0 4248.0 RPM 2310.0 4248.0 ROP 2342.5 4248.0 LOG HEADER DATA DATE LOGGED: 06-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4248.0 TOP LOG INTERVAL {FT) 2342.0 BOTTOM LOG INTERVAL (FT) 4248.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.4 MAXIMUM ANGLE: 81.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 11465.5 11465.5 11458.5 11524 • EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2332.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 115.0 MUD FILTRATE AT MT: 3.500 72.0 MUD CAKE AT MT: 3.000 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 4248 3272.5 3903 2297 4248 RPD MWD020 OHMM 4.06 2000 33.9563 3877 2310 4248 RPM MWD020 OHMM 0.41 114.25 11.8559 3877 2310 4248 RPS MWD020 OHMM 3.75 1217.56 12.0985 3877 2310 4248 RPX MWD020 OHMM 2.2 37.96 10.9591 3877 2310 4248 FET MWD020 HOUR 0.2 52.32 1.45092 3877 2310 4248 GR MWD020 API 22.29 110.97 67.0719 3903 2297 4248 ROP MWD020 FT/H 7.32 641.18 180.896 3812 2342.5 4248 First Reading For Entire File..........2297 • Last Reading For Entire File...........4248 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER • FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4248.5 4294.0 LOG HEADER DATA DATE LOGGED: 22-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4294.0 TOP LOG INTERVAL (FT) 4248.0 BOTTOM LOG INTERVAL (FT) 4294.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: •0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT) 2332.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 66.0 MUD PH: •0 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) r ~ ~ J MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) REMARKS: .000 .000 .000 .000 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 Name Service Unit Min Max DEPT FT 4248.5 4294 ROP MWD070 FT/H 6.44 67.19 First Reading For Entire File..........4248.5 Last Reading For Entire File...........4294 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation....,..06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Mean Nsam 4271.25 92 22.0794 92 r~ ~J .0 106.0 .0 .0 First Reading 4248.5 4248.5 Last Reading 4294 4294 Comment Record FILE HEADER ~ • FILE NUMBER: 4 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 RPM 4248.5 5470.0 RPS 4248.5 5470.0 GR 4248.5 5470.0 FET 4248.5 5470.0 RPD 4248.5 5470.0 RPX 4248.5 5470.0 ROP 4294.5 5470.0 LOG HEADER DATA DATE LOGGED: 23-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5470.0 TOP LOG INTERVAL (FT) 4294.0 BOTTOM LOG INTERVAL (FT) 5470.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.8 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2332.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 88.0 MUD PH: •0 MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.5 MUD FILTRATE AT MT: ,000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4248.5 5470 4859.25 2444 4248.5 5470 RPD MWD080 OHMM 8.5 173.36 54.3471 2444 4248.5 5470 RPM MWD080 OHMM 7.78 354.58 49.833 2444 4248.5 5470 RPS MWD080 OHMM 7.48 333.78 48.6434 2444 4248.5 5470 RPX MWD080 OHMM 7.4 2000 49.8138 2444 4248.5 5470 FET MWD080 HOUR 0.25 417.56 5.85838 2444 4248.5 5470 GR MWD080 API 50.2 122.02 74.3719 2444 4248.5 5470 ROP MWD080 FT/H 8.92 279.51 151.829 2352 4294.5 5470 First Reading For Entire File..........4248.5 Last Reading For Entire File...........5470 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER; 5 RAW MWD Curves and log header data BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. • VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5419.5 8569.5 FET 5470.5 8569.5 ROP 5470.5 8620.0 GR 5470.5 8562.5 RPM 5470.5 8569.5 RPX 5470.5 8569.5 RPD 5470.5 8569.5 LO G HEADER DATA DATE LOGGED: 28-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8620.0 TOP LOG INTERVAL (FT) 5470.0 BOTTOM LOG INTERVAL (FT) 8620.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.9 MAXIMUM ANGLE: 92.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5358.0 BOREHOLE CONDITIONS • MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... • • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5419.5 8620 7019.75 6402 5419.5 8620 RPD MWD100 OHMM 32.16 155.15 68.7949 6199 5470.5 8569.5 RPM MWD100 OHMM 28.25 140.58 61.9712 6199 5470.5 8569.5 RPS MWD100 OHMM 27.98 269.45 61.3924 6301 5419.5 8569.5 RPX MWD100 OHMM 28.71 708.59 63.1567 6199 5470.5 8569.5 FET MWD100 HOUR 0.16 75.17 2.61066 6199 5470.5 8569.5 GR MWD100 API 42.88 97.65 68.1938 6185 5470.5 8562.5 ROP MWD100 FT/H 1.23 444.27 209.833 6300 5470.5 8620 First Reading For Entire File..........5419.5 Last Reading For Entire File...........8620 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8563.0 9416.0 FET 8570.0 9423.5 RPX 8570.0 9423.5 RPS 8570.0 9423.5 RPD 8570.0 9423.5 RPM 8570.0 9423.5 • ROP 8620.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9474.0 • 29-NOV-05 Insite 66.37 Memory 9474.0 8620.0 9474.0 88.6 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 135134 73634 6.750 5358.0 Mineral Oil Base 8.80 79.0 .0 30000 3.4 .000 .0 .000 115.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 • • RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8563 9474 9018.5 1823 8563 9474 RPD MWD110 OHMM 9.83 149.85 46.6936 1708 8570 9423.5 RPM MWD110 OHMM 9.28 143.89 42.0341 1708 8570 9423.5 RPS MWD110 OHMM 8.98 166.98 40.0489 1708 8570 9423.5 RPX MWD110 OHMM 8.73 174.81 37.5754 1708 8570 9423.5 FET MWD110 HOUR 0.26 18.33 1.68893 1708 8570 9423.5 GR MWD110 API 52.57 126.23 84.2412 1707 8563 9416 ROP MWD110 FT/H 0.39 244.76 159.033 1708 8620.5 9474 First Reading For Entire File..........8563 Last Reading For Entire File...........9474 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9416.5 11458.5 RPX 9424.0 11465.5 RPD 9424.0 11465.5 FET 9424.0 11465.5 RPM 9424.0 11465.5 RPS 9424.0 11465.5 ROP 9474.5 11524.0 LOG HEADER DATA DATE LOGGED: 02-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD120 RPM MWD120 RPS MWD120 RPX MWD120 FET MWD120 GR MWD120 ROP MWD120 66.37 Memory 11524.0 9474.0 11524.0 85.1 89.1 TOOL NUMBER 178505 159439 6.750 5358.0 Mineral Oil Base 8.80 82.0 .0 26000 3.1 .000 .0 .000 115.0 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9416.5 11524 10470.3 4216 9416.5 11524 RPD MWD120 OHMM 64.55 166.87 92.2847 4084 9424 11465.5 RPM MWD120 OHMM 54.56 125.97 77.9899 4084 9424 11465.5 RPS MWD120 OHMM 54.57 160.64 89.3984 4084 9424 11465.5 RPX MWD120 OHMM 45.17 508.02 79.5421 4084 9424 11465.5 FET MWD120 HOUR 0.29 18.2 1.28252 4084 9424 11465.5 GR MWD120 API 45.78 81.64 62.0013 4085 9416.5 11458.5 ROP MWD120 FT/H 2.19 350.14 156.571 4100 9474.5 11524 First Reading For Entire File..........9416.5 Last Reading For Entire File...........11524 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 23 11:18:02 2006 Reel Header Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library ~~~~8 Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOG:i WELL NAME: 1J-164 L2 PB1 API NUMBER: 500292327870 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COM}?ANY: Sperry Drilling Services TAPE CREATION DATE: 23-MAR-06 JOB DATA MWD RUN 2 MWD RUN 7 MWD RUN 8 JOB NUMB}3R: MW0004025932 MW0004025932 MW0004025932 LOGGING ENGINEER: T. GALVIN P. ORTH P. ORTH OPERATOR WITNESS: M. THORTON D. GLADDEN D. GLADDEN MWD RUN 9 JOB NUMBER: MW0004025932 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1919 FEL: 2517 FWL: ELEVATIO]V (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~o ~ -1 ~~ • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2332.0 2ND STRING 6.750 7.875 4248.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,8,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED ACOUSTIC CALIPER (ACAL) THE PURPOSE OF MWD RUN 7 WAS TO POSITION THE WHIPSTOCK (THE TOP OF WHICH WAS AT 4248'MD/3442'TVD), MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. MWD RUNS 8,9 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2,7-9 REPRESENT WELL 1J-164 L2 PB1 WITH API#:50-029-23278-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6155'MD/3459'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03j23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2297.0 FET 2310.0 RPM 2310.0 RPS 2310.0 RPD 2310.0 RPX 2310.0 ROP 2342.5 all bit runs merged. STOP DEPTH 6097.5 6104.5 6104.5 6104.5 6104.5 6104.5 6155.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2297.0 424$.0 7 4248.5 4294.0 8 4294.0 5947.0 9 5947.0 6155.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 6155 4226 7717 2297 6155 RPD MWD OHMM 4.06 2000 46.4997 7590 2310 6104.5 RPM MWD OHMM 0.41 354.58 32.5272 7590 2310 6104.5 RPS MWD OHMM 3.75 1217.56 31.7392 7590 2310 6104.5 RPX MWD OHMM 2.2 2000 30.6259 7490 2310 6104.5 FET MWD HOUR 0.2 417.56 3.24623 7590 2310 6104.5 GR MWD API 22.29 122.02 70.088 7602 2297 6097.5 ROP MWD FT/H 1.85 641.18 169.955 7626 2342.5 6155 First Reading For Entire File..........2297 • Last Reading For Entire File...........6155 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2297.0 4248.0 RPD 2310.0 4248.0 RPX 2310.0 4248.0 RPM 2310.0 4248.0 FET 2310.0 4248.0 RPS 2310.0 4248.0 ROP 2342.5 4248.0 LOG HEADER DATA DATE LOGGED: 06-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4248.0 TOP LOG INTERVAL (FT) 2342.0 BOTTOM LOG INTERVAL (FT) 4248.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.4 MAXIMUM ANGLE: 81.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT) 2332.0 • • BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 44.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) 2.900 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 115.0 MUD FILTRATE AT MT: 3.500 72.0 MUD CAKE AT MT: 3.000 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2297 4248 3272.5 3903 2297 4248 RPD MWD020 OHMM 4.06 2000 33.9563 3877 2310 4248 RPM MWD020 OHMM 0.41 114.25 11.8559 3877 2310 4248 RPS MWD020 OHMM 3.75 1217.56 12.0985 3877 2310 4248 RPX MWD020 OHMM 2.2 37.96 10.9591 3877 2310 4248 FET MWD020 HOUR 0.2 52.32 1.45092 3877 2310 4248 GR MWD020 API 22.29 110.97 67.0719 3903 2297 4248 ROP MWD020 FT/H 7.32 641.18 180.896 3812 2342.5 4248 First Reading For Entire File..........2297 Last Reading For Entire File...........4248 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 • ~ Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4248.5 4294.0 LOG HEADER DATA DATE LOGGED: 22-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4294.0 TOP LOG INTERVAL (FT) 4248.0 BOTTOM LOG INTERVAL (FT) 4294.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: •0 MAXIMUM ANGLE: •0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4248.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 66.0 MUD PH: •0 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 106.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: • MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4248.5 4294 4271.25 92 4248.5 4294 ROP MWD070 FT/H 6.44 67.19 22.0794 92 4248.5 4294 First Reading For Entire File..........4248.5 Last Reading For Entire File...........4294 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4248.5 5889.5 FET 4248.5 5896.5 RPX 4248.5 5896.5 RPM 4248.5 5896.5 RPD 4248.5 5896.5 RPS 4248.5 5896.5 ROP 4294.5 5947.0 LOG HEADER DATA DATE LOGGED: 23-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5947.0 TOP LOG INTERVAL (FT) 4294.0 BOTTOM LOG INTERVAL (FT) 5947.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.8 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4248.0 BOREHOLE CONDITIONS r: MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 88.0 MUD PH: •0 MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS; Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4248.5 5947 5097.75 3398 4248.5 5947 RPD MWD080 OHMM 8.5 173.36 58.2485 3297 4248.5 5896.5 RPM MWD080 OHMM 7.78 354.58 52.7618 3297 4248.5 5896.5 RPS MWD080 OHMM 7.48 333.78 50.4975 3297 4248.5 5896.5 RPX MWD080 OHMM 7.4 2000 50.4894 3297 4248.5 5896.5 FET MWD080 HOUR 0.23 417.56 4.48873 3297 4248.5 5896.5 GR MWD080 API 48.96 122.02 73.7763 3283 4248.5 5889.5 ROP MWD080 FT/H 8.43 279.51 159.236 3306 4294.5 5947 First Reading For Entire File..........4248.5 Last Reading For Entire File...........5947 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03f23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5890.0 6097.5 RPX 5897.0 6104.5 RPD 5897.0 6104.5 FET 5897.0 6104.5 RPM 5897.0 6104.5 RPS 5897.0 6104.5 ROP 5947.5 6155.0 LOG HEADER DATA DATE LOGGED: 25-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6155.0 TOP LOG INTERVAL (FT) 5947.0 BOTTOM LOG INTERVAL (FT) 6155.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.0 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178513 EWR4 Electromag Resis. 4 159439 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4248.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size 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 5890 6155 6022.5 531 5890 6155 RPD MWD090 OHMM 56.51 110.5 70.2845 416 5897 6104.5 RPM MWD090 OHMM 49.09 101.14 64.8081 416 5897 6104.5 RPS MWD090 OHMM 39.9 104.54 66.1158 416 5897 6104.5 RPX MWD090 OHMM 36.22 110.65 70.311 416 5897 6104.5 FET MWD090 HOUR 0.23 39.53 10.1306 416 5897 6104.5 GR MWD090 API 53.53 87.09 69.2772 416 5890 6097.5 ROP MWD090 FT/H 1.85 230.19 187.588 416 5947.5 6155 First Reading For Entire File..........5890 Last Reading For Entire File...........6155 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/03/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/03/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File