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Home My WebLink About207-071• s ~~~ ~ ~~~~~~ ~~~ ~~~~~~ ~~~~ ~~~~~ ~~ ~ ~ III III III IIII IIII I II~II I II II~ II IIII I ~r a!7%Zll7 (done) ~ ~ Tuvo-sided ~ I ^ ~2escan Needed RESCA(V DIG AL Dp-TA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing III II'I~I II III II III BY: Maria Date: $ ~ ~S~ ti i P x 30 = ~ ~d +~= TOTAL PAGES~ on repara Scann ng _ ,, ~ /~ ~ (Count does not inciude cover sheet) 1/~, / r ~ BY: Maria ~ Date: s ~ Production Scanning ~" "^"""" ""' Stage 1 Page Count from Scanned File: - I~~ (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ 0 ~S~ 1/ V I P ~l q r Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: n~ iui,~ n^u n n~ Scanning is complete at this point unless rescanning is required. ~@~Cc~//'t 17@CI II I I I'I I( I( I II ( I I I I BY: Maria Date: ~S~ Comments about this file: Quality Checked III II~I~I II~ II'I II) 10/6/2005 Well History File Cover Page.doc ~;_ ~~ "~°~ . `~~ti .. ~. ~•I ~ _ .~' sr ~,qt; a m ;+~a@ *~: ~ a.. ~ ~ { k ~ ~ , ':.~ ~ ~ i R ?.~a¢,. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~~LASKA QfL AND GAS CONSERVATION COMMISS~ RT OF SUNDRY WELL OPERATIONS t. Operations Performed: Abandon ~ Re air well Plu Perforations ~ WINJ to WAG p [ g ("; Stimulate (~ Other ~ g e e Conversion ~p,AA' '~'^"' '~~I~~(g ~l~in .! F~rforate New Fbol ~j Waiver ~ j Time Extension Change Approved ProgralYlperat. Shutdow n ~ Perforate ~ Re-enter Suspended Well ~' 2. Operator Name: 4. Current Well Status: .Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 207-071 3. Address: Stratigraphic ~ Service [ .API Number: P. O. Box 1Q0360, Anchorage, Alaska 99510 50-029-23359-60 7. Property De ' nati 8. Well Name and Number: ALK 25661 & 25650 ~ 1 J-122L1 9. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 13960 feet Plugs (measured) None true vertical 3824 feet Junk (measured) None Effective Depth measured 18068 feet Packer (measured) 10422 true vertical 3797 feet (true verucal) 3702 Casing Length Size MD ND Burst Collapse CONDUCTOR 106 20 106 106 0 0 SURFACE 3610 14.5 3640 2211 0 0 INTERMEDIATE 11902 9.625 11928 3931" " ~ ~ 0 0 "B" lAT SLOTTEI 3122 8.26 13944 3823 0 0 Perforation depth: Measured depth: 11111-13944' ~ ; '; ~ ~ ~ r `F ~' `~ ~ ~ i 4 E~ ~' ` ' True Vertical Depth: 3792-3714' , ~ y!i. °,, t , ~_ , Tubing (size, grade, MD, and TVD) 4.5, L-80, 10299 MD, 3684 TVD vK2~i~, 3vf ~-. i~ Packers &SSSV (type, MD, and TVD) PACKER - B-SAND HRD ZXP LINER TOP PACKER @ 10422 MD and 3702 TVD SSSV =Nipple @ 509 MD and 508 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 284 1188 610 Subsequent to operation 0 1767 0 954 798 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory ~ Development ~ Service .Well Status after work: Oil ~ Gas ~ WDSPL Daily Report of Well Operations X GSTOR ~ WAG ~ GASINJ ~ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: 309-059 Contact Bob Christensen/Darrell Humphrey Printed Name R be t .Chris nsen Title Production Engineering Specialist Signature Phone: 659-7535 Date -~ _ __. _. ~ ~ CJ Form 10-404 Revised 7/20C~BDMS APR 2 2 2010 ~~G!'l_ ~'~' ~. z?~ ~o Submit Original Only • i 1J-122L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/05/10 Commenced WAG injection ~ i ConocoPhillips Alaska, Inc. KRU 1J-122L1 • • ~'~ ~~ ~ ~ „~ ~ ~. ~ ~=z' ~ '~ ~ ~ ~;~r ~ ~ ~ ~ F~. ~~ ~ ~ ~; ; ~~' ~ ~~'~~~`, ~~ ~~°' ~,~~~~ ~~ ~ ~ ~~ ~ ~ ~~~ ,i ~ ~' ~ ~ ~ ~ ~p V ~ ~~ ~~ SEAN PARNELL, GOVERNOR ~~ ~~ ~1~~~ ~ ~.:~~ ~«~s ~:,~ ~ ~~ _ ~k ~. ~~: ~~ ~~.~ ~~ d. ~ ~a~~ OI~ ~`L ~ ~~ ANCHORAGEEAL SKAI9950103539 CO1~TSERQATIOrT CODII~iISSIOrT ~• 9 PHONE (907) 279-1433 ~ FAX (907)276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Rc: Kuparuk Rivcr Unit, Wcst Sak rool, 1J-122L1 Sundry Number: 309-059 Dear Mr. Loveland: ~~''~~N~~ ~~ ~ ~ ~ ZOa~a aa - a i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ Cathy P. Foerster Commissioner ~lt~' DATED this ~ day of October, 2009 Encl. ~ `~ • • ConocoPhillips a~as~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~~~~ ~G~' ,~pp9 ~ ~,~- ~~~ 1 ~ s.~d~, C~~ ~a~~~~. P~~o~~~ p~s Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Trilateral West Sak injection well 1J-122 (207-070), 1J-122L1 (207-071), 1J-122L2 (207-072) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, , ~,~ G~ ~~~~-- ~~i%~ MJ eland ConocoPhillips Well Integrity Projects Supervisor Enclosures ,o`~ ,l'° ~b ~ ~ ~~~~~~~~ STATE OF ALASKA ~Fg 1 ~ ~~09 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO-1dgA~I.Di1 ~ Ca~ cons• CommissE~n 2o aac 2s.2so Anc~ora~e 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other Q Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ~ , Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~eve~opment ~ Exploratory ^ 207-071 ' 3. Address: Stratigraphic ~ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-60 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS NO ~ 1J-122L1 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALK 25661 ~& 25650 ~ RKB 109' • Kuparuk River Field/ West Sak Oil Pool ' 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft):~ Total Depth TVD (ft):, Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 1 t3Q(A 3 ~ ~SLl~ Casing • ~'t• Length =" Size MD ND Burst Collapse CONDUCTOR ~g 20" 106' 106' Surface 3612 13-3/8" 3640 2211' Intermediate 11900 9-5/8" 11928' 3931' Liner L1 B sand 3122 7"x5.5"x4.5" 13944 3931' Hook Hgr assy (B) 257 5.5" 11079 3696' Hook Hgr assy (D) 250 5.5x4.5" 10557 3612' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted and Blank liner 11111-13944' 3792-3714' L-80 L-80 10303 Packers and SSSV Type: Packers and SSSV MD (ft) ZXP Liner top packer, 10422' No SSSV- nipple 509' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^~ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: ~ ~ d/ l..~ ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: ate: WAG Q• GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certiy that the foregoing is true a nd correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland/Per Klein Title: Well Integrity Project Supervisor Signature ~~ Phone 659-7043 Date f`,~ ~~ ,;~ ~~~ Commission Use Onl ~ Sundry Number: Conditions of approval: Notify Commission so that a representative may witness D f~~5~' Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: u t'~' i~*~ ~C e O /' ~ i7 ~~o ti e / ~L 4Ct o-^ ~ t~ .^~'~ Z O. Q~'7 - ~ .. / . s. Subsequent Form Required: ~~°" l`~~ ~'j / APPROVED BY / ~~ Approved by: OM S ONER - TH COMMISSION Date: a( Form 10-403 R ised 06/2006 ' ° ` o~ ~ Submit in Duplicate ti.~~ ~6 'ti t `~ ~ t ~~'~ t~t ~~T~4~ ~~ ;'~7 °''~ • • ConocoPhillips Alaska, Inc. 1J-122 (PTD 207-070) & 1J-122L1 (PTD 207-071) & 1J-122L2 (PTD 207-072) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in , West Sak Injection Well 1J-122 and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of ~ VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1J-122 was drilled as in July 2007 as a trilateral development well and converted to , a water only injector in October 2007. The well was drilled with a 20" conductor to 106'. The surface hole was drilled with a 16" bit and cased with 13-3/8" casing to a TD of 3640'. The casing was cemented in place with 847 bbl of lead cement (Arctic set) and 165 bbl of tail cement (Litecrete). Bumped plug on calculated displacement volume and the floats held. There were good cement returns, 291 bbl recovered. The intermediate hole was drilled with a 12 1/4" bit and cased to 111932' with 9 5/8" casing. The casing was cemented in place with 366 bbl Deepcrete cement plug was not bumped however, good returns were mentioned. The top of cement is confirmed at 5920' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervals. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1J-122 2. Injection well 1J-122 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/4 mile of 1 J-122 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All~ Kuparuk wells with in '/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. 2009 WSAK EOR Pattern Targets .. _~- f--~. __ _ _ ~ ~... 1J-170 ~ r _ ,. . ~ ~. ~ ~ ~ ~ ~ 1E-117 1 J-122 _ c~: ~,roa~ ``~"~-~_ `; i t ~'~.., --~.. -----.__ \ ~ ~ 1 J-122 Cement Log Bottom interval 11,8E GASR MDR Middle interval 9,71 •Pretty good bond around immediate vicinity of shoe •Persistent poor bond along wellbore uphole but intervals of better cement bond are abundant •Top of cement at 5,920' Tops UG C 7,277 •550' of cumulative bond noted from USIT UG B 8,484 UG A 8,979 K13 9,477 D 10,295 ~ N~ ~ ~ ~ ~ ~ • • Top interval 3,870-4,090 ~ ~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070710 Well Name/No. KUPARUK RIV U WSAK 1J-122L1 Operator CONOCOPHILLIPS ALASKA INC MD 13960 ND 3824 Completion Date 7/31/2007 Completion Status 1-OIL Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES, USIT Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / iype meairrmc rvumoer Name scaie meaia No start stop ch rtecervea comments D Asc Directional Survey 0 13960 Open 9/12/2007 pt 15532 LIS Verification 3608 13959 Open 10/12/2007 LIS Veri, GR, RPS, FET, ROP D C Lis 15532 t.~ifiduction/Resistivity 3608 13959 Open 10/12l2007 LIS Veri, GR, RPS, FET, ROP w/PDF and TIF graphics D C 18046 Bee-Neter ~ ~ ~ ~ ~ ~ ~ ~ 0 0 en O 5/21/2009 EWR lo s in CGm EMF ~ ~ cti. ,~,,, ., .~. S ,, , ~ ~ p , g and PDS graphics og Induction/Resistivity 25 Col 108 3823 Open 5/21/2009 "tVD EVNR, DGR og Induction/Resistivity 25 Col 108 13960 Open 5/21/2009 MD ROP EWR, DGR Weil Cores/Samples Information: Name ADDITIONAL II~EORMATION Well Cored? Y~N~ Chips Received? ~fid- Analysis ~~I~ Received? API No. 50-029-23359-60-00 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ Formation Tops ~~ ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2009 Permit to Drill 2070710 Well Name/No. KUPARUK RIV U WSAK 1J-122L1 Operator CONOCOPHILLIPS ALASKA INC MD 13960 TVD 3824 Completion Date 7/31/2007 Completion Status 1-OIL Current Status 1WINJ Comments: Compliance Reviewed By: Date: API No. 50-029-23359-60-00 UIC Y ~~ ~J ~ ~ 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-122+L1+L2 May 14, 2009 AK-MW-5034903 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-122+L1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23359-00,60,61 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-233 59-00,60,61 Digital Log Images 3 CD Rom ~ 50-029-23359-00,60,61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~IG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax:907-273-3535 Bry ~d oi~.com ~ ~. BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 . ~~ ~.. Date: ~~~ ~ ~ 2oU~ Signed: ~~~~i~ ~ ~ ~. ~mr~ss~A~ ~n s~r ~~ ~o~- -~ ~ t~sau~~ ~o~ ~a~.~ ~ ~o~~ ~o-~ _ o~a t ~ ~~ / J ^ ~ • • GonocoPh~ll~ps May 13, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: • J. Eggemeyer Engineering Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phon~: 907-265-6049 ~ ~ a~ 0 ~ ~ ~ ~ ~ D ~ (~ ~~ a ~ ~ ~ ~ ~ ~ ~ ~: a ~ ~ ~ ~ ~ ~ ' ~ ~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 1A-01, CD4-07, 1 J-122, 1 J-122L1, 1 J-122L2, CD4-322, 1 J-162, 1 J-162L1 you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. ~~~~~ ~~~~~ If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, ~ /~~.___-- . Eggemeyer Engineering Team Leader CPAI Drilling JE/skad ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '~ ~-;~ "-, ~~~ ZUL'~~ REPORT OF SUNDRY WELL OPERA~~C~~' ~!^~ ~„~ ~'0"'"~~ _ _ __ _ ____ Y G~ ~ ~ ~ Y~~ FF~ Z ~~OS 1. Operations Performed: Abandon ^ Repair Well ^ Piug Perforations ~ Stimulate ^ p~I~@S ~ Pre-Prod to Inj i ~ ~ N '~ i,~7 ~ ; i Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time E~ension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: Co11oCOPhllllps AlaskB, InC. Development ^ Exploratory ^ 207-071 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-122L1 8. Property Designation: 10. Field/Pool(s): ALK 25661 & 25650 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13960' feet true vertical 3824' feet Plugs (measured) Effective Depth measured 13944' feet Junk (measured) true vertical 3823' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 80' 80' SURFACE 3531' 13-3/8" 3640' 2212' D-SAND WINDOI 1' 9-5/8" 10333' 3690' B-SAND WINDO~ 1' 9-5/8" 10828' 3765' INTERMEDIATE 11819' 9-5/8" 11928' 3931' B-SAND SLOTTED LINER 54~ 7~~ 11090' 3792~ Perforation depth: Measured depth: Slotted Liner 11111' - 13556' true vertical depth: 3792' - 3$11' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10299 ' MD. Packers & SSSV (rype & measured depth) PKR = Baker HRD ZXP LT PKR = 10422' SSSV= NIP SSSV= 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1119 511 60 1000 208 Subsequent to operation 2217 1569 146 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-316 contact Bob Christensen / Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~/~ ,G~~~ ~~~ 7~ ~ ~ ~~ ' Phone 659-7535 Date ~ ~.~ ~ (~ ~ / ? Form 10-404 Revised 04/2004 ~~~'~~~ ~~~' ~~~~ ~ ~ ~~~8 ~ ~y! "~~~'~} Submit Origi ~~1~ ~ ~i 1J-122L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/12/08 Commenced Water In'ection ~ ~ Maunder, Thomas E (DOA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.com] Sent: Wednesday, January 30, 2008 8:13 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. I am sure we can accommodate. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, January 30, 2008 8:07 AM To: Eggemeyer, ]erome C. Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports Page 1 of 1 Thanks Jerome. These aren't urgently needed. Only other request, is send the reports "single sided". When we get double-sided, we have to shoot additional copies in order to scan. Tom From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Tuesday, January 29, 2008 10:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. As soon as Sharon is able to organize the data it will be sent over (hopefully only a few days depending on other activities). Let us know if it is needed more urgently. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, ]anuary 29, 2008 4:38 PM To: Eggemeyer, Jerome C. Cc: Allsup-Drake, Sharon K Subject: Operations Reports Jerome and Sharon, Thanks for sending the more detailed operations reports. I have further reviewed the Commission's files regarding 407's submitted since about August and found that more complete reports are needed for a few other wells. The wells are: 1 J-162, -162L1 207-080, 207-181 CD4-322 207-101 1~SQc~E Z ~ ~~~ 1 J-122, -122L1, -122L2 207-070, 207-071, 207-072 For the multilateral wells, a complete summary is only needed for the main wellbore with only the specific operations needed for the laterals. Your assistance in making the well records complete is appreciated. I will be reviewing the recently submitted sundry reports shortly and will send another message if necessary. Call or message with any questions. Tom Maunder, PE AOGCC ~cJ ~~~ ~~~,C 8/18/2009 ~ ~ : ~ ~ ~ Y ~~ ~~~ ~ ~ ~ ~~ ~ ~ ~ ~$ ~, . ~~ ~. ~ ~. . ~w~ ~.~, AIiA.SSA Du ~1~TD G`~S COI~TSERQ.~~'I011T COMI~IIS5IOI~T Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Fieid, West Sak Oil Pool, 1J-122L1 Sundry Number: 307-316 Dear Mr. Christensen: SARAH PAL/N, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907j 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commissian 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 i.f the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~day of October, 2007 Encl. ,.~ ~.~ ~ c~ ~ ~ Sincerely, ~~~~~~~~ ~_ • ~ o ~ ~~~o-~~~ . ~ ~~ ~ ~ ~ ~ ~ ~ STATE OF ALASKA ~ ~ ' ~ ~'~~- ~ . ., .,.;:: ~~.~ ~~ ~ ~ ~ ~ ~ ~ 1. Type of Request: Abandon ~ p ~ ~ ~ Alter casing ~ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ Chan e a roved ro ram 9 pp P 9 ^ Pull Tubing ^ Perforate New Pool ^ Re-enter S Producer to uspended Well ~ ~ Injector 2. Operator Name: 4. Current Welf Class 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ~^ Exploratory ^ 207-071 ' 3. Address: Stratigraphic ~ Service ~ 6. API Ntlmber: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-60 ° 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Weli Name and Number: where ownership or landownership chang es: Spacing Exception Required? YeS ^ NO Q 1J-122L1 ~" 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALK 25661 & 25650 " RKB 109' ' Kuparuk River Field / West Sak Oil Pool ~ 12.` PRESENT WELL CONDITION SUMMARY Totai depth MD (ft}: Total Depth ND (ft): Effective ~epth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk{measured): 13960' ~' 3824' • 13944' ~ 3823' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20~~ 80' ' " ~0~ SURFAGE . 3531' 13-3/8~, 3640' 2212~. D-SAND WINDOW ~~ 9-5/8" 10333~ ~ 3690' B-SAND WINDOW ~~ 9-5/8" 10828' 3765' INTERMEDIATE 11819' 9-5/8" 11928' 3931' B-saav~ s~orrE~ ~wER 54' 7" 11090' . 3792~ Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 11111' - 13556' 4-1/2" L-80 10299' --- Packers and SSSV Type: - - - Packers and SSSV MD (ft) PKR = Baker HRD ZXP LT PKR = 90422' SSSV= NIP SSSV= 509' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work; Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^~ ~ 15. Estimated Date for 16. Wefl Status after proposed work: Commencing Operations: Nov. 11, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal ApprovaL Da#e; WAG ~ GINJ ^ WINJ ~" WDSPL ~ CommissionRepresentative; ` 18. 4 hereby certi hat the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen ! Bob Buchholz Printed Na bert Christens ~1 Titlec Production Engineering Technician Signatur i Phone 659-7535 Date 1Q ~~ Commission Use Onl Sundry Number: Conditions of approvai: Notify Commission so that a representative may witness ° + Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~ , ~ ~~-'~~ ~ ~~:~ f~~i ~ ~ CA ~L~J C-~ ~ / ~ ~ ~ V c~- ~ > ~ Subsequent Form Required: ~` b~,j ~~a;A !~"E Q~~r ~~ 2~~~ APPROVED BY A IQ~/ ~~,~ pproved by: G SIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 n R~ ,~ ni o~ Submit in Duplicate ~D , i7, a7 - ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~~ ~~~lt~'~"~ ~~~° i~''~~ ~~ 20 AAC 25.280 , . :. Suspend ^ O erational Shutdown PerForate ^ Waiver , Other ./ ~ ~ . ~. 1J-122L2 ~ DESCRIPTION SUMMARY ~ OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water lnjection service in West Sak Tri- lateral Well 1J-122L2. This well has been pre-produced for approximately 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1J-122L2 will provide pressure support for the West Sak D sands. The 13-3/8" Surface casing ( 3640' md / 2212' tvd) was cemented with 1031 sx AS Lite followed by 372 sx LiteCRETE. The 9-5/8" Intermediate casing ( 11928' md / 3931' tvd) was cemented with 920 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand LEM Baker Seal Assembly located @ 10451' md / 3705' tvd, Upper B sand HRD ZXPJ" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 10442' md / 3705' tvd, and an Upper A sand HRD ZXP 7" x 9-5/8" Liner Top Packer located @ 10970' md / 3788' tvd. The top of West Sak D sand was faund at 10295' md / 3684' tvd. D sand Lateral window top is located @ 10332' md / 3689' tvd. = The top of West Sak B sand was found at 10828' md / 3765' tvd. . B sand Lateral window top is located @ 10827' md / 3765' tvd. The top of West Sak A sand was found at 11880' md / 3927' tvd. ''~ , _ f ~ s ; F ~ ~ ,~ ~ ~ t ~ ~ ; ~ ~ ~ - i ~ ~ ~ a '+' ~ • ~ KRU 1J-122L1 ConocoPhillips Alaska, Inc. 1J-122L1 API: 500292335960 Well T e: PROD An le TS: de TUBING ~ SSSV T e: NIPPLE Ori Com letion: 8/1/2007 An le TD: 88 de 13960 (0-10299, Mnular Fluid: Last W/O: Rev Reason: GLV C/O OD:4.500, Reference L: 28' RKB Ref Lo Date: Last U date: 9/13/2007 ID:3.958) Last Ta : __ TD: 13994 ftK8 Last Ta Date: Max Hole An le: 95 de 11229 Casin Strin - ALL STRINGS Description Size To __ Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 80 80 94.00 K-55 WELDED SURFACE 13.375 0 3640 2212 68.00 L-80 BTC INTERMEDIATE 9.625 0 11928 3790 40.00 L-80 BTCM D•SAND WINDOW 10.000 10332 10333 3689 0.00 I I B-SAND WINDOW 10.000 10827 10828 3765 0.00 B-SAND SLOTTED LINER 7.000 11036 11090 3791 26.00 L-80 BTCM B-SAND SLOTTED LINER 5.500 11090 11091 3791 15.50 L-80 BTCM LOCATOR ---- B-SAND SLOTTED LINER 4.500 11091 13944 3523 11.60 L-80 BTCM ;~o2~e-~o2~s, Tubin Strin - TUBING OD:5.500) L= - Size Top __ Bottom TVD _ Wt_ Grade Thread 4.500 0 10299 3684 12.60 L-80 IBT Perforations Summar --- Interval TVD Zone Status Ft SPF Date T e Comment = 11111 - 11581 3792 - 3784 WS B 470 32 7/15f2007 SLOTS Alternating solid/slotted pipe 2.5"x .125, 4 circumferential rows/R 3"centers sta ered 80d 11840 - 12340 3790 - 3795 WS B 500 32 7/15/2007 SLOTS Akernating solid/slotted pipe 2.5" x .125, 4 circumferential rowslft 3" centers sta ered SO de 12595 - 13088 3800 - 3809 WS B 493 32 7/15/2007 SLOTS Alternating solidlslotted pipe 2.5" x .125, 4 circumferential rows/4 3" centers sta ered 80 de 13300 - 13556 3811 - 3811 WS B 256 32 7/15/2007 SLOTS Alternating solid/slotted pipe 2.5" x .125, 4 circumferential rows/ft 3" 3.860 XO Bushing ;10440-10441, OD:7.670) ~ Perf ;12595-13088) Perf ;13300-13556) ~ WELL LOG TRANSMITTAL ~ To: State of Alaska October 3, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-120 L1 AK-MW-5034903 1 LDWG formatted CD Rom~with verification listing. API#: 50-029-23 359-60 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, A1aska 99518 k: ~~~~'',~ ~`~ ; . ~;~'~ ~."~ U ~ ~J C 1. Date: ~~~ ~ ~ ZG"~ € =~i~~2 ~;~1 °.~ ~~ ~,~;~~ ~ ; ~'+~`~F~~~: ~~;'c,~°j;~'.:'~t:~ Signed: ~o~--b~~ ~~55~ ~ "" • • ConocoPh~ll~~as September 14, 2007 RE~~~~~~~`~ Commissioner SEP ~ ~ ;~~7 State of Alaska Alaska Oil & Gas Conservation Commission '~'Al~ska Oii & G~s ~;~~as r;. ~~-~ 333 West 7t" Avenue Suite 100 t~"~°~`'J" 1~ni:~t~t~~~ Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-122, 1 J-122L1, 1 J-122L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1 J-122, 1 J-122L1 and 1J-122L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, : ~.. ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad Ran~sy r:ncmas ~ Kuparuk Drilling Team Leader Drilling & Welis P: O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~Pa~? ~v~;~~ V ~~ ~_.;' ~? ~i 2~~7 WELL COMPLETION OR RECOMPLETION REPORT :AN~~:L~. cammission 1a. Well Status: Oil ~ '~ Gas Plugged Abandoned ~ Suspended ~ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No.ofCompletions: 1b. Well Class: ,~, -;;#'~~~~t~~ Development ~/ ~ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: July 31, 2007 ~ 12. Permit to Drill Number: 207-071 / ` 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: July 9, 2007 ` 13. API Number: 50-029-23359-60 ' 4a. Location of Well (Governmental Section): Surface: 1837' FSL, 2347' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: July 13, 2007 14. Well Name and Number: 1J-122L1 ° Top of Productive Horizon: 1651' FNL, 360' FEL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): 28' RKB Ground (ft MSL): 109' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1475' FSL, 353' FEL, Sec. 25, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): ' 13944' MD / 3823' ND ~ West Sak Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558863 '~ y- 5945649 ' Zone- 4 10. Total Depth (MD + ND): 13960' MD / 3824' ND r 16. Property Designation: ALK 25661 8~ 25650 ~' TPI: x- 566114 y- 5947502 Zone- 4 Total Depth: x- 566093 - 5950627 Zone- 4 11. SSSV Depth (MD + ND): nipple @ 509' MD / 508' ND 17. Land Use Permit: 471 & 468 18. Directional Survey: Yes ^~ No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 2196' ND ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 10827' MD / 3765' ND GR/RES, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 20" x 34" 78.6# H-40 28' 106' 28' 106' 42" 335 sx AS 1 13.375" 68# L-80 28' 3640' 28' 2211' 16" 1031 sx AS Lite, 372 sx LiteCRETE 9.625" 40# L-80 28' 11928' 28' 3931' 12.25" s2o sx DeepCRETE 7" x 5.5" x 4.5" 11.6# L-80 10822' 13944' 3764' 3823' 8.5" slotted liner 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 10422' slotted and blank liner from 11111' - 13944' MD ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) multi-lateral, pre-produced injector Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ ~ Sidewall Cores Acquired? Yes ~ No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence ot oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. C~"dP4ETl~"~ NONE ' ~7 pT (. o ~ VCRtF a ~~ Form 10-407 Revised 2/2007 ~RIGINAL CONTINUED ON REVERSE SIDE -- - _ ~ ~I~~ c~ ~~ ~ R 2ao7 ~SD- 9•2~~°~ ~~~ ~ ~-\ i~ ~~~~ ~ ~ i 28. GEOLOGIC MARKERS (List all formations and mar s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 3595' 2196' ~ needed, and submit detailed test information per 20 AAC 25.071. T3 3595' 2196' K15 3595' 2196' Ugnu C 7277' 3052' Ugnu B 8484' 3313' Ungu A 8979' 3413' K13 9477' 3516' West Sak D 10295' 3684' West Sak B 10828' 3765' West Sak A2 13960' 3824' - N/A Formation at total depth: West Sak B ~ 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner 31. I hereby certify that the toregoing is true and correct to the best of my knowledge. ContaCt: Pat Reilly @ 265-6048 Printed N~ Rand Thomas Titie: Drillina Team Leader ~~c~ jo ~ ~ Signature Phone 2~j~ ~, $~ p Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Sait Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one intervai (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 tnjection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analyticai laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ Halliburton Company Survey Regort Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 09:22:23 Page: 1 Field: Kuparuk River Unit Co-ordina~e(NE) Reference: Well: 1J-122, True North f Site: Kuparuk 1 J Pad Vertical (1'VD) Reference: D141 (28 + 81) 1-09.0 Well: 1J-122 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-122L1 Survey Catculatio n Method: Minimum Curvature ~' Db: f~acle j Field: Kuparuk River Unit I North Slope Alaska United States Map System;US State Plane Coordinate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordiaate System: Wel! Centre I Sys Datum: Mean Sea level Geomagnetic Model: bggm2007 ~ Well: 1 J-122 Slot Na~me: ! Well Position: +N/-S -270.75 ft Northing: 594564 9.48 ft~ Latito~e: 70 15 43.595 N +E/-W 71.32 ft Easti ng : 55886 3.37 ft- Longitude: 149 31 26.931 W Position Uncertainty: 0.00 ft Wellpath: 1J-122L1 Drilled From: 1J-122 API 50-029-23359-60 Tie-on Depth: 10741.25 ft j Current Datum: D141 (28 + 81) Height 10 9.00 ft~ Above System Datum: Mean Sea Level Magnetic Data: 6/16/2007 DeclinaGon: 23.31 deg Field Strength: 57613 nT Mag Dip Angl e: 80J9 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program For Definitive Wellpath Date: 8/14/2007 Validated: Yes Version: 7 i Actual From To Survey Toolcode Tool Name ft ft 50.00 727.00 1J-122 P61 Gyros (50.00-727.00 CB-GYRQ-SS Camera based gyro single shot 826.02 3615.17 1J-122 P61 IIFR+MS+Sag (826.02 MWD+IFR-AK-C AZ-SC MWD+IFR AK CAZ SC C ~ 3643.00 10741.25 1J-122 IIF R+MS+Sag (3643.00-15 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C i 10827.00 13928.44 1J-122 L1 IIFR+MS+Sag (10827.0 MWD+IFR-AK-C AZ-SC MWD+IFR AK CAZ SC C Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tooi ~ ft deg deg ft ft ft ft 'ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945649.48 558863.37 TIE LINE 50.00 0.23 262.51 50.00 -59.00 -0.01 -0_04 5945649.47 558863.33 CB-GYRO-SS 100.00 0.23 207.19 100.00 -9.00 -0.11 -0_19 5945649.37 558863.18 CB-GYRO-SS 168.00 0.10 64.84 168.00 59.00 -0.20 -0.20 5945649.27 558863.17 CB-GYRO-SS 263.00 0.20 43.45 263.00 154.00 -0.05 -0~01 5945649.43 558863.36 CB-GYRO-SS 352.00 2.00 104.21 351.98 242.98 -0.32 1.50 5945649.18 558864.98 CB-GYRO-SS 445.00 5.77 102.92 444.75 335.75 -1.76 7.74 5945647.78 558871.12 CB-GYRO-SS 476.00 6.94 104.70 475.56 366.56 -2.59 11_07 5945646.98 558874.46 CB-GYRO-SS 536.00 8.40 109.85 535.02 426.02 -4.99 18.70 5945644.63 558882.10 CB-GYRO-SS 631.00 12.22 111.49 628.47 519.47 -11.03 34_58 5945638.72 558898.03 CB-GYRO-SS 727.00 16.18 110.43 721.52 612.52 -19.43 56.58 5945630.50 558920.09 CB-GYRO-SS 826.02 19.43 110.75 815.78 706.78 -30.08 84.92 5945620.06 558948.51 MWD+IFR-AK-CAZ-SC 897.82 21.80 107.95 882.98 773.98 -38.42 108.77 5945611.91 558972.43 MWD+IFR-AK-CAZ-SC 957.57 24.53 106.48 937.91 828.91 -45.36 13122 5945605.15 558994.93 MWD+IFR-AK-CAZ'-SC 1053.34 29.27 105.77 1023.29 914.29 -57.37 172.84 5945593.47 559036.64 MWD+IFR-AK-CAZ-SC 1148.67 32.87 106.08 1104.93 995.93 -70.88 220.14 5945580.33 559084.d4 MWD+(FR-AK-CAZ-SC 1244.03 37.37 106.69 1182.91 1073.91 -86.36 272.76 5945565.26 55913677 MWD+fFR-AK-CAZ-SC 1337.57 39.44 104.20 1256.22 1147.22 -101.81 328.76 5945550.26 559192.89 MWD+IFR-AK-CAZ-SC 1432.05 44.32 102.32 1326.54 1217.54 -116.22 390.'!4 5945536.32 559254.37 MWD+IFR-AK-GAZ-SC 1525.77 47.35 102.29 1391.83 1282.83 -130.55 455.82 5945522.51 559320.15 MWD+IFR-AK-CAZ-SC 1619.34 48.76 100.81 1454.38 1345.38 -144.47 524.~0 5945509.12 559388.43 MWD+IFR-AK-CAZ-SC 1714.14 49.71 100.26 1516.28 1407.28 -157.59 594.59 5945496.55 559459.12 MWD+IFR-AK-CA~-SC 1809.00 55.41 100.64 1573.92 1464.92 -171.26 668.63 5945483.47 559533.25 MWD+IFR-AK-CAZ-SC 1904.38 58.52 99.98 1625.91 1516.91 -185.56 747.29 5945469.78 559612.01 MWD+IFR-AK-CAZ-SC 1998.16 64.25 99.90 1670.81 1561.81 -199.76 828.34 5945456.22 559693.17 MWD+IFR-AK-CAZ-SC 2092.66 67.25 101.49 1709.62 1600.62 -215.76 912.99 5945440.88 559777.93 MWD+IFR-AK-CAZ-SC 2187.56 70.00 101.39 1744:20 1635.20 -233.29 999.60 5945424.03 559864.fi7 MWD+IFR-AK-CA2-SC ! i Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 09:22:23 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 4J-122, T rue North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: D141 (28 + 81) 109.0 Well: 1 J-122 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-122L1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2282.44 71.24 100.27 1775 .69 1666.69 -250 .10 1087.51 5945407 .91 559952.69 MWD+IFR-AK-CAZ-SC 2377.66 72.77 100.85 1805 .10 1696.10 -266 .70 1176.53 5945392 .01 560041.84 MWD+IFR-AK-CAZ-SC j 2475.50 72.64 101.61 1834 .19 1725.19 -284. 89 1268.16 5945374 .53 560133.59 MWD+IFR-AK-CAZ-SC 2571.86 70.40 100.87 1864 .73 1755.73 -302. 71 1357.79 5945357 .42 560223.35 MWD+IFR-AK-CAZ-SC ~ 2665.79 70.32 99.86 1896 .30 1787.30 -318. 63 1444.81 5945342 .19 560310.49 MWD+IFR-AK-CAZ-SC 2760.94 71.66 100.55 1927 .30 1818.30 -334. 57 1533.34 5945326 .94 560399.14 MWD+IFR-AK-CAZ-SC 2856.71 71.49 100.03 1957. 56 1848.56 -350. 80 1622.74 5945311 .41 560488.65 MWD+IFR-AK-CAZ-SC 2952.84 71.26 98.74 1988. 27 1879.27 -365. 65 1712.62 5945297 .26 560578.63 MWD+IFR-AK-CAZ-SC 3048.06 71.85 98.09 2018. 39 1909.39 -378. 87 1801.97 5945284 .74 560668.07 MWD+IFR-AK-CAZ-SC 3141.34 71.49 98.07 2047. 73 1938.73 -391. 32 1889.64 5945272 .98 560755.83 MWD+IFR-AK-CAZ-SC 3236.18 70.84 98.20 2078. 35 1969.35 -404. 02 1978.50 5945260 .98 560844.77 MWD+IFR-AK-CAZ-SC 3331.73 73.51 98.65 2107. 59 1998.59 -417. 35 2068.47 5945248 .35 560934.84 MWD+IFR-AK-CAZ-SC 3425.95 72.56 98.11 2135. 09 2026.09 -430. 48 2157.63 5945235 .92 561024.09 MWD+IFR-AK-CAZ-SC 3518.01 67.02 98.46 2166. 88 2057.88 -442. 92 2243.08 5945224 .15 561109.63 MWD+IFR-AK-CAZ-SC 3615.17 69.19 100.33 2203. 11 2094.11 -457. 65 2332.01 5945210 .12 561198.67 MWD+IFR-AK-CAZ-SC 3643.00 69:41 100.69 2212. 95 2103.95 -462. 40 2357.61 5945205 .57 561224.30 MWD+IFR-AK-CAZ-SC 3711.25 70.62 97.13 2236. 28 2127.28 -472. 32 2420.96 5945196 .14 561287.72 MWD+IFR-AK-CAZ-SC 3806.75 71.61 99.08 2267. 19 2158.19 -485. 06 2510.41 5945184 .10 561377.26 MWD+IFR-AK-CAZ-SC 3900.55 72.85 98.63 2295. 82 2186.82 -498. 81 2598.67 5945171 .04 561465.61 MWD+IFR-AK-CAZ-SC 3995.33 73.42 100.00 2323. 32 2214.32 -513. 49 2688.18 5945157 .06 561555.22 MWD+IFR-AK-CAZ-SC 4089.15 75.47 100.58 2348. 48 2239.48 -529. 64 2777.10 5945141 .61 56164426 MWD+IFR-AK-CAZ-SC 4186.11 75.66 100.44 2372. 65 2263.65 -546. 77 2869.42 5945125 .21 561736.71 MWD+IFR-AK-CAZ-SC 4281.20 74.77 100.77 2396. 91 2287.91 -563. 69 2959.80 5945109 .00 561827:20 MWD+IFR-AK-CAZ-SC 4376.04 77.20 100.45 2419. 88 2310.88 -580. 63 3050.23 5945092 .77 561917.75 MWD+IFR-AK-CAZ-SC 4470.83 75.54 98.97 2442. 22 2333.22 -596. 17 3141.03 5945077 .94 562008.66 MWD+IFR-AK-CAZ-SC 4565.83 76.29 99.56 2465. 34 2356.34 -611. 00 3231.97 5945063 .82 562099.70 MWD+IFR-AK-CAZ-SC 4662.92 77.76 99.94 2487. 13 2378.13 -627. 03 3325.21 5945048 .52 562193.06 MWD+IFR-AK-CAZ-SC 4755.99 78.07 99.33 2506. 62 2397.62 -642. 26 3414.93 5945034 .00 562282.89 MWD+IFR-AK-CAZ-SC 4850.72 78.01 99.19 2526. 25 2417.25 -657. 17 3506.40 5945019 .80 562374.46 MWD+IFR-AK-CAZ-SC 4945.03 76.49 99.07 2547. 06 2438.06 -671. 77 3597.21 5945005 .92 562465.38 MWD+IFR-AK-CAZ-SC 5039.28 77.69 99.78 2568. 12 2459.12 -686. 81 3687.84 5944991. 58 562556.11 MWD+IFR-AK-CAZ-SC 5133.03 77.50 100.50 2588. 26 2479.26 -702. 93 3777.97 5944976. 17 562646.36 MWD+IFR-AK-CAZ-SC 5228.34 77.31 100.14 2609. 04 2500.04 -719. 59 3869.48 5944960. 22 562737.99 MWD+IFR-AK-CAZ-SC 5323.79 77.12 100.17 2630. 17 2521.17 -736. 01 3961.11 5944944. 53 562829.73 MWD+IFR-AK-CAZ-SC 5419.10 77.76 100.67 2650. 89 2541.89 -752. 83 4052.60 5944928. 42 562921.34 MWD+IFR-AK-CAZ-SC 5513.28 79.33 100.60 2669. 60 2560.60 -769. 87 4143.32 5944912. 10 563012.18 MWD+IFR-AK-CAZ-SC 5608.22 78.07 100.00 2688. 20 2579.20 -786. 51 4234.91 5944896. 17 563103.89 MWD+IFR-AK-CAZ-SC 5702.95 78.26 100.39 2707. 63 2598.63 -802. 92 4326.16 5944880. 47 563195.26 MWD+IFR-AK-CAZ-SC 5798.24 79.07 100.44 2726. 36 2617.36 -819. 81 4418.06 5944864. 30 563287.27 MWD+IFR-AK-CAZ-SC 5894.04 77.56 99.92 2745. 76 2636.76 -836. 40 4510.39 5944848. 45 563379.73 MWD+IFR-AK-CAZ-SC 5988.48 77.94 99.90 2765. 80 2656.80 -852. 28 4601.30 5944833. 28 563470.75 MWD+IFR-AK-CAZ-SC 6083.44 76.86 99.56 2786. 51 2677.51 -867. 94 4692.64 5944818. 33 563562.20 MWD+IFR=AK-CAZ-SC 6178.39 77.37 99.58 2807. 68 2698.68 -883. 33 4783.91 5944803. 66 563653.58 MWD+IFR-AK-CAZ-SC 6273.69 76.93 98.90 2828. 88 2719.88 -898. 25 4875.62 5944789. 46 563745.39 MWD+IFR-AK-CAZ-SC 6369.18 76.74 99.57 2850. 63 2741.63 -913. 17 4967.39 5944775. 25 563837.27 MWD+IFR-AK-CAZ-SC 6466.04 75.60 99.00 2873. 78 2764.78 -928. 35 5060.21 5944760. 80 563930.20 MWD+IFR-AK-CAZ-SC 6561.04 76.42 99.45 2896. 75 2787.75 -943. 12 5151.20 5944746. 74 564021.29 MWD+~FR-AK-CAZ-SC 6655.80 76.80 98.13 2918. 69 2809.69' -957. 21 5242.30 5944733. 37 564112.49 MWD+IFR-AK-CAZ-SC 6749.05 76.67 96.13 2940. 09 2831.09 -968. 48 5332.35 ~944722. 81 564202.62 MWD+IFR-AK-CAZ-SC 6844.64 77.25 94.88 2961. 66 2852.66 -977. 41 5425.05 5944714. 60 564295.37 MWD+IFR-AK-CAZ-SC 6940.21 78.13 92.82 2982. 04 2873.04 -983. 67 5518.20 5944709. 06 564388.56 MWD+IFR-AK-CAZ-SC 7034.44 78.07 89.87 3001. 47 2892.47 -985. 84 5610.37 5944707. 62 564480.74 MWD+IFR-AK-CAZ-SC ~ 7130.45 78.32 86.51 3021. 12 2912.12 -982. 87 5704.29 5944711. 32 564574.62 MWD+IFR-AK-CAZ-SC • ! Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Date: 8/16/2007 Co-ordinate(NE) Reference: Time: 09:22:23 Page: 3 Well: 1J-122, True North Site: Kuparu k 1J Pad VerticaljTVD) Reference: D141 (28 + 81 ) 109.0 Well: 1J -122 Section (VS) Reference: Well (O.OON,O. OOE,O.OOAzi) Wellpath: 1J -122L1 Survey Calculation Method: Minimum Curvature Db: Orade Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7223.85 77. 94 83.36 3040. 34 2931.34 -974. 80 5795 .32 5944720. 10 564665.58 MWD+IFR-AK-CAZ-SC 7321.06 77. 50 79.87 3061. 02 2952.02 -960 .96 5889 .28 5944734 .68 564759.41 MWD+IFR-AK-CAZ-SC 7416.89 77. 93 76.88 3081. 41 2972.41 -942 .09 5980 .98 5944754 .26 564850.96 MWD+IFR-AK-CAZ-SC 7509.94 77. 87 73.24 3100. 92 2991.92 -918 .64 6068 .87 5944778 .40 564938.65 MWD+IFR-AK-CAZ-SC 7606.20 77. 55 69.61 3121. 42 3012.42 -888 .68 6158 .01 5944809. 04 565027.55 MWD+IFR-AK-CAZ-SC 7701.51 77. 50 66.04 3142. 01 3033.01 -853 .57 6244 .17 5944844. 83 565113.42 MWD+IFR-AK-CAZ-SC 7797.32 77. 25 63.06 3162. 96 3053.96 -813. 40 6328. 58 5944885. 66 565197.51 MWD+IFR-AK-CAZ-SC 7890.97 77. 43 59.93 3183. 49 3074.49 -769. 79 6408. 87 5944929. 88 565277.44 MWD+IFR-AK-CAZ-SC ~ 7989.13 77. 82 56.45 3204. 53 3095.53 -719. 26 6490. 33 5944981. 04 565358.50 MWD+IFR-AK-CAZ-SC 8082.76 77. 12 53.16 3224. 85 3115.85 -666. 59 6565. 01 5945034. 29 565432.76 MWD+IFR-AK-CAZ-SC 8177.99 77. 25 50.55 3245. 98 3136.98 -609. 25 6638. 03 5945092. 20 565505.33 MWD+IFR-AK-CAZ-SC 8273.83 77. 24 47.56 3267. 14 3158.14 -548. 00 6708. 63 5945153. 99 565575.43 MWD+IFR-AK-CAZ-SC 8368.99 77. 43 44.89 3288. 01 3179.01 -483. 77 6775. 66 5945218. 73 565641.96 MWD+IFR-AK-CAZ-SC 8464.35 77. 75 41.57 3308. 51 3199.51 -415. 92 6839. 44 5945287. 07 565705.20 MWD+IFR-AK-CAZ-SC 8560.45 78. 45 37.68 3328. 33 3219.33 -343. 51 6899. 40 5945359. 95 565764.58 MWD+IFR-AK-CAZ-SC 8652.81 77. 75 35.21 3347. 38 3238.38 -270. 81 6953. 08 5945433. 05 565817.69 MWD+IFR-AK-CAZ-SC 8747.98 77. 87 32.75 3367. 48 3258.48 -193. 68 7005. 07 5945510. 58 565869.06 MWD+IFR-AK-CAZ-SC 8843.49 79. 27 30.23 3386. 41 3277.41 -113. 86 7053. 96 5945590. 77 565917.32 MWD+IFR-AK-CAZ-SC 8939.65 78. 38 26.23 3405. 05 3296.05 -30. 76 7098. 57 5945674. 21 565961.29 MWD+IFR-AK-CAZ-SC 9033.80 77. 49 23.05 3424. 73 3315J3 52. 91 7136. 96 5945758. 17 565999.01 MWD+IFR-AK-CAZ-SC 9129.64 78. 20 19.80 3444. 92 3335.92 140. 11 7171. 17 5945845. 63 566032.54 MWD+IFR-AK-CAZ-SC 9224.85 78. 38 17.20 3464. 25 3355.25 228. 52 7200. 75 5945934. 25 566061.42 MWD+IFR-AK-CAZ-SC ~ 9318.79 78. 14 13.57 3483. 37 3374.37 317. 18 7225. 15 5946023. 10 566085.13 MWD+IFR-AK-CAZ-SC 9413.15 78. 01 9.58 3502. 87 3393.87 407. 61 7243. 67 5946113. 65 566102.94 MWD+IFR-AK-CAZ-SC 9509.96 78. 38 6.02 3522. 68 3413.68 501. 47 7256. 53 5946207. 61 566115.06 MWD+IFR-AK-CAZ-SC 9605.12 77. 37 2.87 3542. 68 3433.68 594. 22 7263. 74 5J46300. 40 566121.55 MWD+IFR-AK-CAZ-SG 9693.66 77. 62 2.17 3561. 85 3452.85 68~. 57 7267. 54 5946386 J7 566124.67 MWD+IFR-AK-CAZ-SC 9788.92 78. 01 0.53 3581. 95 3472.95 773. 66 7269. 73 5946479. 86 566126.14 MWD+IFR-AK-CAZ-SC 9884.64 77. 68 359.63 3602. 11 3493.11 867. 23 7269. 87 5946573. 43 566125.54 MWD+IFR-AK-CAZ-SC 9980.13 77. 75 359.26 3622. 43 3513.43 960. 53 7268. 96 5946666. 71 566123.90 MWD+IFR-AK-CAZ-SC 10074.62 78. 13 0.05 3642. 17 3533.17 1052. 93 7268. 41 5946759. 09 566122.63 MWD+IFR-AK-CAZ-SC 10169.85 78. 76 359.38 3661. 25 3552.25 1146. 23 7267. 94 5946852. 37 566121.43 MWD+IFR-AK-CAZ-SC 10263.66 80. 15 358.75 3678. 41 3569.41 1238. 44 7266. 44 5946944. 56 566119.21 MWD+IFR-AK-CAZ-SC 10360.86 81. 71 359.21 3693. 74 3584.74 1334. 41 7264. 73 5947040. 50 566116.75 MWD+IFR-AK-CAZ-SC 10455.06 81. 96 359.79 3707. 11 3598.11 1427. 65 7263. 91 5947133. 72 566115.21 MWD+IFR-AK-CAZ-SC 10551.25 81. 40 0.11 3721. 03 3612,03 1522. 82 7263. 83 5947228. 89 566114.38 MWD+IFR-AK-CAZ-SC 10645.91 81. 20 0.07 3735. 35 3626.35 1616. 39 7263. 98 5947322. 45 566113.79 MWD+IFR-AK-CAZ-SC 10741.25 80. 39 359.98 3750. 60 3641.60 1710. 51 7264. 02 5947416. 55 566113.10 MWD+IFR-AK-CAZ-SC 10827.00 80. 51 0.70 3764. 83 3655.83 1795. 07 7264. 52 5947501. 10 566112.94 MWD+IFR-AK-CAZ-SC 10858.03 80. 92 1.78 3769. 84 3660.84 1825. 68 7265. 18 5J47531. 72 566113.36 MWD+fFR-AK-CA2-SC 10940.16 82. 79 4.62 3781. 47 3672.47 1906. 84 7269. 73 5947612. 91 566117.27 MWD+IFR-AK-CAZ-SC 11036.69 86. 83 7.90 3790. 21 368121 2002. 37 7280. 21 5947708. 50 566127.01 MWD+~FR-AK-CAZ-SC 11132.41 90. 78 6.57 3792. 20 3683.20 2097. 29 7292. 26 5947803. 50 566138.32 MWD+IFR-AK-CAZ-SC 11228.79 94. 55 6.87 3787. 72 3678.72 2192. 88 7303. 53 5947899. 17 566148.83 MWD+IFR-AK-CAZ-SC 11322.59 91. 08 3.21 3783. 11 3674.11 2286. 18 7311. 75 5947992. 52 566156.32 MWD+IFR-AK-CAZ-SC ~ 11417.00 89. 41 3.54 3782. 71 3673.71 2380. 42 7317. 31 5948086. 80 566161.14 MWD+IFR-AK-CAZ-SC ( 11513.23 90. 15 3.54 3783. 08 3674.08 2476. 47 7323. 25 5948182. 87 566166.33 MWD+IFR-AK-CAZ-SC 11557.08 88. 61 2.66 3783. 55 3674.55 2520. 25 7325. 62 5~48226. 67 566168.36 MWD+IFR-AK-CAZ-SC 11606.82 88. 30 1.30 3784. 90 3675.90 2569. 94 7327. 34 5948276. 37 566169.69 MWD+IFR-AK-CAZ-SC 11700.92 88. 92 1.19 3787. 18 3678.18 2663. 99 7329. 38 5948370. 42 566171.00 MWD+IFR-AK-CAZ-SC 11795.58 88. 48 358.66 3789. 33 3680.33 2758. 62 7329. 26 5948465. 04 566170.14 MWD+IFR-AK-CAZ-SC 11889.89 90. 65 358.42 3790. 04 3681.04 2852. 89 7326. 86 6948559. 28 566167.00 MWD+{FR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 092223 Page: 4 Field: Kuparuk River Uni t ~ Co-ordinate(NE) Refereuce: Well: 1J-t22, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: D141 (28 + 81 ) 109.0 Well: 1J -122 Sectio n (VS) Reference: Well (O.OON,O. OOE,O.OOAzi) Wellpath: 1J-122~1 Survey Calcuta tion Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 11985.74 89.66 355 .86 3789. 78 3680. 78 2948.61 7322.07 5948654. 95 566161.47 MWD+IFR-AK-CAZ-SC ~ 12079.97 90.27 357 .93 3789. 84 3680. 84 3042.69 7316.97 59487d8. 98 566155.63 MWD+IFR-AK-CAZ-SC j ~ 12174.07 89.16 356 .30 3790. 31 3681. 31 3136.67 7312.23 5948842. 91 566150.16 MWD+IFR-AK-CAZ-SC i 12269.13 87.93 356 .92 3792 J2 3683. 72 3231.53 7306.61 5948937. 71 566143.80 MWD+IFR-AK-CAZ-SC I 12364.54 88.98 357 .08 3795. 29 3686, 29 3326.77 7301.62 5949032. 90 566138.06 MWD+IFR-AK-CAZ-SC 12459.72 88.92 357 .13 3797. 04 3688. 04 3421.82 7296.82 5949127. 90 566132.52 MWD+IFR-AK-CAZ-SC 12503.95 88.92 357 .73 3797. 87 3688. 87 3465.99 7294.83 5949172. 05 566130.19 MWD+IFR-AK-CAZ-SC 12551.15 88.55 358 .28 3798. 9t 3689. 91 3513.15 7293.19 59492'19. 20 566128.18 MWD+IFR-AK-CAZ-SC 12647.39 89.47 358 .51 3800. 58 3691. 58 3609.34 7290.50 59493i5. 35 566124.73 MWD+IFR-AK-CAZ-SC 12742.20 89.41 358 .86 3801. 50 3692. 50 3704.12 7288.32 59494~0. 10 566121.81 MWD+IFR-AK-CAZ-SC 12837.18 89.47 358 .63 3802. 43 3693. 43 3799.07 7286.24 59495U5. 02 566118.99 MWD+IFR-AK-CAZ-SC 12932.58 87.87 359 .03 3804. 65 3695. 65 3894.42 7284.29 5949600. 35 566116.30 MWD+IFR-AK-CAZ-SC 13027.90 89.04 359 .74 3807. 22 3698. 22 3989.70 7283.27 5949695. 61 566114.53 MWD+IFR-AK-CAZ-SC 13121.86 88.48 359 .22 3809. 25 3700. 25 4083.63 7282.42 5949789. 52 566112.95 MWD+IFR-AK-CAZ-SC 13217.65 89.91 0 .04 3810. 60 3701. 60 4179.41 7281.80 5949885. 28 566111.58 MWD+IFR-AK-CAZ-SC 13312.62 89.29 359 .45 3811. 26 3702. 26 4274.38 7281.38 5949980. 23 566110.41 MWD+IFR-AK-CAZ-SC f 13404.49 88.48 356 .98 3813. 05 3704. 05 4366.18 7278.52 5950072. 00 566106.84 MWD+IFR-AK-CAZ-SC 13496.59 91.89 358 .24 3812. 75 3703. 75 4458.18 7274.68 5950163. 96 566102.28 MWD+IFR-AK-CAZ-SC 13589.50 91.63 359 .49 3809. 90 3700. 90 4551.03 7272.84 5950256. 78 566099.71 MWD+IFR-AK-CAZ-SC 13682.65 87.31 358 .89 3810. 76 3701. 76 4644.14 7271.52 5950349. 87 566097.67 MWD+IFR-AK-CAZ-SC 13775.16 86.88 359 .24 3815. 45 3706. 45 4736.52 7270.01 5950442. 22 566095.44 MWD+IFR-AK-CAZ-SC 13867.07 87.06 359 .35 3820. 30 3711. 30 4828.29 7268.88 5950533. 98 566093.59 MWD+IFR-AK-CAZ-SC 13928.44 88.18 0. 08 3822. 85 3713. 85 4889.61 7268.58 5950595. 28 566092.81 MWD+IFR-AK-CAZ-SC ~13960.00 88.18 0. 08 3823. 85 - 3714. 85 4921.15 7268.62 5950626. 82 566092.61 PROJEC7ED to TD • • ~ , ,~... , _ ~~, _~ . ~; ,~;. , .~ . , ~ - ~ ~.,,., . . ~~ _ „ . ~~~ ~ . ~ ~ ~- ~ . ~~m ~. , ~ ~_ ~ .._,_ ~ ~ ., =s; , _ ~,.., ~ . ~. , , , ~~, :. , , 07/08/2007 2330 00:00 _ 0.50 14,619 14,619 COMPZ CASIN CIRC P Circulate bail down DP at 31 spm, 400 si. 07/09/2007 00:00 01:00 1.00 14,619 14,616 COMPZ CASIN( OTHR P Continue pumping 1-3/4" ball down @ 31 spm, 400 psi - On seat at 1445 stks and 600 psi. Pumped 1.4 bbls to inflate PKR @ 1800 psi. SO to 35k. Pumped to 3715 psi to blow ball seat. PU to release from liner @ 155k. Lined up to pump down the annulus and test to 2500 psi for 5 mins on chart. PU Wt 158k - Dwn Wt 75k. Tag Liner Top @ 10,970' MD - Btm of liner set at 14,616' MD, Swell PRK set at 14,542' M0. 01:00 01:15 0.25~ 10,970 10,934 COMPZ CASIN OTHR P LD Single jt of DP - Flow check well - Static. 01:15 03:00 1.75 10,934 8,312 COMPZ CASINC RUNL P POOH from 10,934' to 9,135' MD. LD 27 jts of HWDP to the pipe shed - SB 2 jts for upcoming window BHA - - POOH to 8312' MD. 03:00 04:30 1.50 8,312 8,312 COMPZ RIGMN' SVRG P Slip and cut 81' of Drill line. Service To Drive. 04:30 08:00 3.50 8,312 72 GOMPZ CASlNC RUNL P Continue POOH from 8,312' to Liner runnin tool. 08:00 08:45 0.75 72 0 COMPZ CASIN PUTB P LD Liner Running tooL 08:45 09:00 0.25 COMPZ CASIN OTHR P Clean and Clear Rig Floor 09:00 09:15 0.25 PROD2 DRILL SFTY P PJSM on PU and MU Whipstock BHA 09:15 12:00 2.75 0 167 PROD2 STK PULD P MU Whipstock assembly BHA: MU Window mill - Lower mill - Flex Jt - Upper Mill - Flt Sub - TM - 1 jt 5" DP - Rack Back. PU Locator sub - XO - Unloader sub - 2 jts 4-1/2" DP - Pup jt - 2 XO's - Blanking Sub - Trip Anchor - Shear Disconnect - Drain sub - Debris Sub - 9-5/8" Window w/17.64' slide. MU Mill Assembl to slide. 12:00 1230 0.50 167 250 PROD2 STK , PULD P PJSM. PU MWD & Bumper Sub. Pro ram MWD. 1230 13:15 0.75 250 533 RROD2 STK PULD P PU 3 jts FIexDCs - PU HWDP - Shallow Pulse test 533' MD. 13:15 16:45 3.50 533 9,648 PROD2 STK TR1P P RIH with Whipstock/Milling Asmbly. Fill DP 3371', 6218' and 9648' MD. 16:45 17:30 0.75 9,648 9,733 PROD2 STK TRIP P Mad Pass from 9,662' to 9,733' MD. Orient toolface at 7 de Left. 1730 18:00 0.50 9,733 10,875 PROD2 STK TRIP P Continue RIH - Break Circulation at 10,875' MD. PU Wt 135k, SO Wt 70k. 18:00 18:45 0.75 10,875 10,875 PROD2 STK WPST P Orient and set whipstock @ 13 deg Left High Side. Pumps on Up Wt 135, SO Wt 70 - Pumps off Up Wt 145k, SO Wt 78k. Shear anchor and confirm with 20k over ull. ~~~ ~~ - ~ ~~ ~ ~, ~ ~ ~ ~ ~~g~ ~B c~f 3&' ' ~ ~ ~,.,. 3 ,~, ~ ~.._. - ,.~ _~ ~ -~~ ~ A ~ :.r ~;,~, ~ ~. , . • • 07/09/2007 18:45 2130 2.75 10,875 10,827 PROD2 STK WPST P Shear off Whipstock - Top of Whipstock set at 10, 827' MD with Btm set at 10,843.5' MD. Inciination at KOP 85 de . 21:30 00:00 2.50 10,827 10,833 PROD2 STK WPST P Milling B Lat Window from 10,827' to 1Q833' MD. Weight on Mill 2-4k, 90-100 rpm, 11-12k Trq, Pumping 500 m 2100 si. 07/10/2007 00:00 04:15 4.25 10,833 10,889 PROD2 STK WPST P Continue milling window @ 509 gpm, 1925 psi, 90 rpm, Trq 9.5k. Milied a total 25' of 8.5" gauged hole to 10,889' M D. 04:15 05:30 1.25 10,889 10,889 PROD2 STK CIRC P Circulate Hi-Vis Sweep plus BU's @ 600 gpm, 90 rpm. Recip to polish milled window. 05:30 05:45 0.25 10,889 10,889 PROD2 STK TRIP P Worked string through window with no um s and rotation smoothl . 05:45 09:30 3.75 10,889 393 PROD2 STK TRIP P Flow check - Static - Pump Dry Job - POOH from 10,889' to 393' MD. 09:30 10:30 4.00 393 107 PROD2 STK PULD P Rack back 1 std HWDP and NMFIex DCs, LD 3'ts HWDP & Bum er Sub. ~I 10:30 11:00 0.50 107 107 PROD2 STK PULD P Down Load MWD Data 11:00 12:00 1.00 107 24 PROD2 STK PULD P LD MWD, Fit Sub, 1 Jt HWDP, 8.5" OD U er Mill. 12:00 1230 0.50 24 0 PROD2 STK PULD P PJSM - Cont LD Flex Jt & 8' Lower Mill & Window Mill. Clear Ri Floor. 12:30 14:00 1.50 0 0 PROD2 DRILL OTHR P Pull Wear Ring & Flush Stack - Problems Setting wear ring - Found piece of rubber shaved off annular element - Set & Pull Wear Rin . 14:00 16:30 2.50 0 0 PROD2 WELCT BOPE NP Set test plug - Fill stack with water - RU & test Hydril to 250 low and 3000 si for 10 minutes. 16:30 17:30 1.00 0 75 PROD2 DRILL PULD P PU BHA #7 - 8.5" Bit, GeoPilot, Pony Flex, MWD, & Float Sub. 1730 18:00 0.50 75 75 PROD2 DRILL OTHR P Program MWD - Lube,Crown. 18:00 19:30 1.50 75 365 PROD2 DRILL PULD P RIH with Flex Dc's - PU Jars and 2 jts HWDP - RIH - Break in GP and Shailow Pulse Test tools. 19:30 21:15 1.75 365 2,241 PROD2 DRILL TRIP P RIH picking up 60 jts of 5" DP from shed to 2,241' MD. Monitor well - Static. 21:15 00:00 2.75 2,241 8,878 PROD2 DRILL TRIP P Cont RIH to 8,878' MD - Fill DP @ 3,186', 6,023', and 8,878' MD. 07/11/2007 00:00 00:15 0.25 8,878 10,868 PROD2 DRILL TRIP P Continue TIH from 8,878'to 10,868' MD. 00:15 00:45 0.50 10,868 10,889 PROD2 DRILL REAM P Ream from 10,868'to 10,889' MD. Take check shot survey. Ream @ 50 rpm, 550 gpm, 2660 psi. Trq 10k, Rot Wt 90k. Ua Wt 145k. SO Wt 70k. • ~ u 07/1 21:00 21:15 21:15 22:45 0.25 10,770 10,770 PROD2 DRILL SFTY 1.50 10,770 10,770 ~PROD2 RIGMN SVRG 07/1 22:45 (00:00 ~ 1.25 ( 10,770 ~ 11,451 ~PROD2 ~ DRILL ~TRIP 00:00 00:45 00:45 01:00 0.75 11,451 13,901 PROD2 DRILL TRIP 025 13,901 13,960 ~PROD2 DRILL CIRC 01:00 ~ 04:00 ~ 3.00 ~ 13,960 ~ 13,960 ~PROD2 ~ DRILL ~ CIRC 04:00 ~06:00 ~ 2.00 ~ 13,960 ~ 13,960 ~PROD2 ~ DRILL ~ CIRC ~06:00 ~08:15 ~ 2.25 ~ 13,960 ~ 10,784 ~PROD2 ~DRILL ~TRIP 08:15 10:00 10:00 12:00 12:00 12:30 12:30 16:45 16:45 19:30 1.75 10,784 10,784 PROD2 RIGMN SVRG 2.00 10,784 10,784 ~PROD2 DRILL CIRC 0:50 10,784 10,784 PROD2 RIGMN SVRG 4.25 10,784 2,244 PROD2 DRILL TRIP 2.75 2,244 75 ~ PROD2 DRILL TRIP ~ P PJSM to review hazards with Slip & Cut DL. P Slip and Cut 69' of drilling line - Service Top Drive - Adjust Drilling brakes - Identified a small Glycol leak on the drillers side of the brake drum. Mechanie inspected - Decision was made to continue with normal o erations. P Continue to RIH'from 10,770' MD without pumps and rotary - Lose Wt and Stack out 15k # just above TOW @ 10,825' MD - Worked string and rotated 1/2 turn without success. Brought Pumps oniine to verify GP was set a 0% deflection. Worked pipe - Rotated 10 rpm, 15K Wt - No success. Rotated 10 RPM with pumps @ 585 gpm, 2540 psi - Stalled at 14K ft-Ibs of torque. PUH - Slide down through window without rotary and pumps @ 585 gpm and 25K WOB. Slide down total of 2 stands through window to 10,975' MD. Continue RIH to 11,451' MD with um s off. P Continue RIH to 13,901' MD. P Break Circulation @ 13,901' MD - Wash and Ream to 13,960' MD - No Fill encountered - Pumped 150 spm @ 3450 si, 110 r m, 12k ft-Ibs of tr . P Pump a 30 BBL HiVis sweep and 3 BU's at 150 spm, 3450 psi, 110 rpm, 12k ft-Ibs of tr . P Displaced weil over to 60/40 8.4 ppg SFOBM - Pumped a total of 961 BBLS Monitor Weli - Static. Obtain SPR's and T&D data on btm. P POOH on elevators to 10,784' MD. Obtain T& D per rig engineer - Pull 50k Dra . T Service Rig - Repair Glycol leak on DrawWorks. P Circulate and condition mude with 3% 776 Lube to reduce trq and drag - Pumped 60 spm, 600 psi, Trq 8-10k ft-Ibs. Reduced Tr from 16k to 9k. P PJSM - Repair DrawWorks leak. P POOH from 10,784' to 2,244' MD - Continue to record T&D data. P LD 60 Jts of 5" DP, 5 Jts HWDP, Jars, and 3 NM Flex Collars. • • 07/14/2007 19:30 21:30 2.00 75 0 PROD2 DRILL PULD P Download MWD - Break Bit, LD MWD & GeoPilot. Inspection of BHA at surface - GP had damage to the rolier blades with a few of the lower rollers missing - Possible Brass Shear Pin from Whipstock Asmbly lodged into one of the cutter blades on GP - Flex Collars had scarin . 21:30 2230 1.00 0 0 COMPZ CASIN RURD P Clear floor - RU equipment to run 4.5" B Lat Liner - PJSM to reveiew rocedures and discuss hazards. 22:30 00:00 1.50 0 899 COMPZ CASINC RNCS P Run 21 jts of 4.5" 11.6 ppf L-80 Slottted & Blank Liner to 899' MD. 07/15/2007 00:00 01:00 1.00 899 2,833 COMPZ CASIN RNCS P PJSM - Continue RIH with 46 jts plus 2 pup jts of 4.5" 11.6 ppf L-80 Slotted & Blank Liner to 2833' MD. Ran total of 67 Jts: 43 Blanks and 24 Slots. Liner included 58 Hydroform Centralizers - 8 TAM FreeCap Constrictor Packers - 27 Torque Rin s. 01:00 02:00 1.00 2,833 2,921 COMPZ CASINC RNCS P PU & RIH with XO, 4.5" Pup, XO, Baker Rec~ptacle Jt, 5.5" Pup, XO, Baker "HR" Liner setting sleeve, Setting tool to 2921' MD. RD Casing E ui ment and clear floor. 02:00 09:00 7.00 2,921 13,949 COMPZ CASINC RUNL P RIH with -iner on 5" DP - Obtain Trq & Drag data every 10 stands. Tag Btm at 13,977.61'. Liner set with shoe @ 13,948.85' MD and TOL @ 11,040.72' MD. PU Wt 175k, SO Wt 60k. 09:00 1030 1.50 13,949 11,041 COMPZ CASINC CIRC P Circulate ball on seat at 1900 strokes, Pressure up to 3600 psi and release from liner. 10:30 11:00 0.50 11,041 10,836 COMPZ CASIN( RUNL P Pull out of liner - PU wt 165k, SO Wt 65k, Rot Wt 115k, Trq 8-10k ft-Ibs. POOH to 10,836' MD 11:00 11:30 0.50 10,836 10,836 COMPZ CASIN CIRC P Wash slot on slide @ 10,836' MD at 7 b m, 650 si. 11:30 12:00 0.50 10,836 10,330 COMPZ CASIN( RUNL P Continue to POOH to 10,330' MD. 12:00 13:00 1.00 10,330 10,330 COMPZ CASIN CIRC P PJSM - Displace from SFOBM to OBM from 10,330' MD (Planned depth for "D" Sand TO 13:00 18:15 5.25 10,330 0 COMPZ CASIN( RUNL P Flow check well - static - POOH to 8,540' MD - Pump slug - Continue to POOH (strapping pipe). LD Baker settin tool. 18:15 18:45 0.50 0 0 COMPZ CASW( RURD P Clean and clear rig floor - Pick up Baker Whipstock Hook Assembly and Tools from beaver slide. 18:45 19:00 0.25 COMPZ FISH SFTY P PJSM - Discuss Hazards and Procedures for RU Fishinca BHA. • • 07/15/2007 19:00 00:00 5.00 0 10,751 COMPZ FISH TRIP P PU Whipstock Hook, 1 Jt H1NDP, Bumper Sub, Oil Jars, Float Sub, 1 Std HWDP. RIH to 10,751' MD(strapping DP). Filled DP @ 2,515', 4,887', 8,808'. 07/16/2007 00:00 00:45 0.75 10,751 10,842 COMPZ FISH PULL P CONT RIH F/ 10751' -10800' MD; PU SINGLE - P/U = 170K, S/O = 63K. WORK PIPE DOWN TO 10,842'. HOOK SLIDE@ 10,840' MD - OVERPULL 90K AND FIRED JARS - PULL TO 290K TO PULL FREE AND RELEASE WHIPSTOCK. MONITOR WELL - STATIC. "" WHIPSTOCK LOCATED 2.83' HIGH "* 00:45 01:15 0.50 10,842 10,340 COMPZ FISH TRIP P POOH TO 10,340' MD. PU WT 182K: LD SINGLE TO SHED. 01:15 02:30 1.25 10,340 10,340 COMPZ FISH CIRC P CIRCULATE BTMS UP ONCE WHIPSTOCK RELEASED - 8 BPM, 900 PSI - MAX GAS OBSERVED 42 UNITS. 02:30 08:15 5.75 10,340 63 COMPZ FISH TRIP P POOH FIRST 15 STANDS MONITORING WELLBORE DISPLACEMENT (INITIAL SWABBING DUE TO DEBRIS CUP) - PUMPED DRY JOB AND PUH ON ELEVATORS WITH PROPER DISPLACEMENT TO 63' MD; CALCULATED DISPLACEMENT 85 BBLS - ACTUAL 82.75 BBLS. 08:15 10:30 225 63 0 COMPZ FISH PULD P LD BHA, OIL JARS, BUMPER SUB, FLT SUB, WHIP STOCK & TRIP ANCHOR ASSY. WHIPSTOCK IN GOOD CONDITION. 10:30 11:30 1.00 COMPZ CASINC OTHR P CLEAN & CLEAR RIG FLOOR 11:30 12:00 0.50 COMPZ CASIN RURD P R/U HOOK HANGER ASSY TOOLS 12:00 12:30 0.50 COMPZ CASIN RURD P P/U BAKER CASWG TONGS AND TOOLS FROM BEAVER SLIDE 12:30 15:00 2.50 COMPZ CASIN RUNL P PJSM; P/U HOOK HANGER BHA AS FOLLOWS; BENT JT, SPACE OUT JTS, ECP, SPACER JTS, INNER STRING, MWD, X-O; ORIENT MWD - RIG DOWN SMALL BAKER CASING TONGS AND CLEAR FLOOR AREA. 15:00 22:15 7.25 0 10,191 COMPZ CASIN RNCS P RIH TO 741' - SHALLOW PRESSURE TEST MWD TOOLS - CONT RIH TO 10,191' MD; UD 7 STDS OF 5" DP FROM DRILL STRING TO SHED (STDS 106 - 112), P/U 10 STDS HWDP FROM SHED AND SINGLE IN VIA MOUSE HOLE. ~ • 07/16/2007 22:15 00:00 1.75 10,191 11,069 COMPZ CASW( RUNL P RIH TO 11,069' MD - TAG'A' SAND LATERAL NO-GO; PUH TO TOW @ 10,826' MD; ROTATE PIPE AND RIH - TAG SAME DEPTH (ON DEPTH WITH PIPE TALLY & CSG DETAILS). ATTEMPT ENTERING'B' LATERAL & CONTINUE TAGGING AT SAME DEPTH. 07/17/2007 00:00 05:15 5.25 11,069 11,069 COMPZ CASIN RUNt P Cont to attempt to go thru "B" lat window with HH assembly with no success, made 12 attempts to go thru window and rotated several times also and cont. to tag up on "A2" lat. XO at 11,069'. Decision was made to POOH and run a different bent jt. Original bent jt was 10" at 16' up on the jt, the next bent jt to be 12" at 16' up on the 't. 05:15 0530 0.25 11,069 11,069 COMPZ CASIN( OTHR T Monitored weli-static, pumped dryjob 05:30 12:00 6.50 11,069 269 COMPZ CASIN( RUNL T POOH from 11,069' to HH assembly at 269', calc fill on trip out 90 bbls, actua196 bbls. 12:Q0 12:30 0.50 269 269 COMPZ CASIN( OTHR T Cieaned rig floor and heid PJSM on LD Hook Han er assembl . 12:30 18:45 6.25 269 0 COMPZ CASIN PUTB T Cont to POOH from 269' LD HH assembly, had problems pulling the cups on the inner string thru ECP, made up 44' of add. innner string and stacked out on XO bushing, was then able to POOH LD inner st. and HH assembly. Note :jt below ECP was a 15.5 ppf whife ECP is 5112" 23# and on next run to change out pup jt below ECP to 23#. ' 18:45 19:15 0.50 0 0 COMPZ CASIN OTHR T Clear and clean floor, 19:15 19:30 0.25 0 0 COMPZ CASIN SFTY T PJSM on changing out Hook Hanger assembl ieces. 1930 21:15 1.75 0 265 COMPZ CASIN PUTB T Change out the 15.5 ppfpup below th ECP packer f/ 15.5 ppf to 23 ppf. change the Bent joint from a 10" bend to 12" bend. Make up inner string w/ MWD, MU hook hanger and orient w/ MWD. 21:15 21:30 0.25 265 265 COMPZ CASINC RURD T Rig down casing tongs and clear floor. 21:30 00:00 2.50 265 3,200 COMPZ CASIN RUNL T Trip in the hole w/the Hook Hanger asembly to 741', shallow test MWD, continue to RIH w/ Hook hanger to 3200'. 07/18/2007 00:00 03:00 3.00 3,200 11,069 COMPZ CASIN RUNL T Cont to RIH with 2nd HH assembly from 3,200' and tagged up at 11,069', same as 1st run, st wt up 180K, dn wt 83K ~ 07 03:00 I 10:30 I 7.50 ( 11,069 I 11,069 u CASIN( RUNL T Cont to attempt to go thru "B" lat window with new bent jt and HH, cont to set down on A lat XO, est circ above and saw an increase in pressure and percentage of flow went from 20% to 13% showing good sign to be pumping below ZXP packer and blank jts on the A2 liner, cont to rotate from above the TOW to below the BOW and did not see any change in torque or any sign of tagging the window. Made numerous attempts. Discussed options with town and decision was made to POOH and MU4 1/2" BTC bent jt with 5 1/2" XO back to 4 3/4" MWD and attempt to o thru window. 10:30 10:45 0.25 11,069 11,069 COMPZ CASIN OTHR T Monitored well-static, pumped dry job. 10:45 16:3d 5.75 11,069 364 COMPZ CASIN( RUNL T POOH with HH assembly from 11,069' to 364', calc fill on trip out 90 bbls, actual fill 98 bbis. Cleared ri floor. 1630 17:45 125 364 364 COMPZ RIGMN SVRG P Held PJSM then slip and cut 100' of drl line. 17:45 21:15 3.50 364 0 COMPZ CASIN PUTB T Cont to POOH from 364' LD HH assembiy and inner string with MWD. Inside of the hook hanger, between inner string jt and ID of hook hanger a small piece of possible Hydril rubber • was brought to surFace with the hook hanger. Also small metal shavings were recovered as well. 21:15 22:00 0.75 0 0 COMPZ CASINC RURD T R/D casing tools, Clean and clear rig floor. PU tools from the beaver slide for next run. i 22:00 22:15 025 0 0 COMPZ CASIN SFTY T PJSM on PU/MU BHA #9. 22:15 23:00 0.75 0 65 COMPZ CASW( PUTB T PU/MU dummy run BHA #9. Made up the 12" bend bent joint of 4.5" L-80 BTC casing with a 4.5" x 5.5" BTC x-o, xo (5.5 LTC x 5.5" BTC), x-o (3-1/2" IF x 5.5" LTC), nm float sub, DM han off collar, TM han off collar. 23:00 23:30 0.50 65 65 COMPZ CASW( OTHR T Install MWD probe. 23:30 23:45 0.25 65 550 COMPZ CASIN RUNL T RIH dummy bentjt w/ MWD assembly on 5 stands of 5" driil i e. 23:45 00:00 0.25 550 550 COMPZ CASIN OTHR T Shallow test MWD tools. Pumping 338 gpm w/ 650 psi. aquired good toolface and ood detection. 07/19/2007 00:00 04:45 4.75 550 10,734 COMPZ CASIN RUNL T Cont. to RIH with BHA #9 from 550', install 2-7" boot baskets at 634' then cont to RIH to 10,734', st wt up 170K, dn wt 83K (TOW (c~ 10,827) ~ • 07/19/2007 04:45 06:45 2.00 10,734 11,085 COMPZ CASW( RUNL T Oriented bentjt to 4 left of high side ( pumping 313 gpm w/ 1250 psi), then shut down pumps, and RIH from 10,734', had slight loss of down wt at 11,060' and cont. to RIH with 5-8K wt dn and tagged up at 11,085' with mule shoe, sat 20K wt dn with no add. movement, PU and sat back down at the same spot, with mule shoe at 11,085', less bentjt and setting sleeve piaces "B" lat TOL at 11,036'. Took survey also and reconfirmed to be in the "B" lat. 06:45 07:30 0.75 11,085 10,960 COMPZ CASINC RUNL T POOH from 11,085' to above TOW to 10,770', oriented bent jt to 142R and RIH tagging up mule shoe at 11,038', no go at 11,001' putting the TOL at 10,970, reconfirmed by est. circ and saw pressure increase and flow decrease as we sat down on no go. Same as previous run. PU to above TOL to 10,960'. 07:30 09:45 2.25 10,960 10,960 COMPZ CASW CIRC T Pumped 35 bbl wYd hi vis sweep (2# over MW of 8.4 ppg MOBM), circ sweep out of hole with no increase in cuttings back from the sweep, circ at 325 m, 1,400 si. 09:45 10:00 0.25 10,960 10,960 COMPZ CASIN( RUNL T Monitored well-static, pumped dry 'ob. 10:00 14:00 4.00 10,960 66 COMPZ CASIN RUNL T POOH with BHA#9 to 66', LD boot basket while POOH (Had no recovery in the baskets . 14:00 15:30 1.50 66 0 COMPZ CASINC PUTB T POOH and LD 4 3/4" MWD and 4 1/2" BTC bent jt, cleared rig floor, bent jt went in hole 12" at 16' and came out 8 1/2" at 16', re-bent't to 11" at 16' 15:30 15:45 0.25 0 0 COMPZ CASIN( SFTY T Held PJSM on MU Hook Hanger assembl with inner strin and MWD. 15:45 17:45 2.00 0 267 COMPZ CASIN( PUTB T MU Hook hanger assembly #3 with inner string and MWD and oriented same RIH to 267'. 17:45 18:00 0.25 267 267 COMPZ CASIN( RURD T Rig down casing tools. 18:00 00:00 6.00 267 10,741 COMPZ CASIN RUNL T RIH w/ Hook Hanger assembly f! the "B" lateral, on 5" drill string from 26T to 10,741' and oriented bent jt, st up wt 170K. dn wt 82K • ! • • Cont to RIH fi/3,544' 8~ tagged up @ 3,968', surveyed & sfiowed to be in 12 1/4" hole, washed down to 4,023' then cont. to RIH to 9,537', washed dn to btm & GBU, drilled from 9;721' to 10,970', worked pipe while repairing #2 mud pump's mud cross, cont. driliing to 11,215' F~rslled 12'iJ4'" hc~[e fram t'f 2~` tc~11 932' ~1~t7 FI5 ~18" c~g p~~ ~£}H tc~ shc~~ &~c~r~hofe clean PCJQ~i ~, ffAitVfl~ $~ E~QWt~tO~ded S~~T1~~ ~rc`~~ ~ ~~, ~ a i ~ ~ ~ r~~~a~ , , ,_. _.. _ ~_ . ?~a.._~~ .,~.. „~~~~~ ,. ~,. ~~.,~r~.. . ,,/, .., , : ~ .~ ,:~~ ~,c . , i ~.~~ ~;'. Fin LD BHA #3, slip & cut drlg line, pulled wear bushing, RU & RIH with 9' S/8" csg to 13 3/8" shoe, CBU & spotted lube pill, cont to RiH with 9 5/8" csg ta8;941' ~ 7 ',7/4/2C 7/8/2007 7/5/2007 7 7/9/2007 Fin POOH & Installing supersliders on 40 stds of 5" DP, tested 9 5/S" csg to 3,000 psi for 30 min. Ml~ 8 1/2" Geopilot BHA #4 & singied in hole 180 jTs 5" DF, then RIM f/derrick to 11,634', slip "& eut drlg line, RIH & tagged up at 11,842`(FC @ 11,848`) drilled out fit collar and drlg shoe track @ 11,917' (FS @ 11,928`J Continue to TIH to 11, 830' MD - Displace to OBM - Pump Hi-Vis Sweep - ROOH - RIH with 5-1/2" Liner io 14,616' MD - Pump Ball to seat. ~ 7/10/2007 ~ p 7 1!2 07 Miil out window from 10,833' to 10,889' MD - POOH - LD BHA - Pull Wear Ring $~ Flush Stack - Tested Annular - I 1-4"' ~ PU BHA #7 RIH to 8 878 MD. -~,. ~ ,: ~ ~ ~ --~ ~ ~ ~ ~ 7t't`t~ t~~}7„ ~~ ~ ~~2~~ ~' ~~ D e 8~1~~ o~~~n~6 rateralweft~~GeoP~takfrorr~'[Q;889 tc~ 898~l~iD ` '~'~~ ~ ~ h ~" ~~~'~;~;~ .... ~~ ... .. .......... . ~,..~~,,,z.~~.~~,. „ ..>.: _ .....~..a ~~.<, ~. ,._, ...,,~~...a . ...::~.. . ,..~. ~... ~~,.~~~~~,,. ~7/12/2007 ~7l13/2007 ~ ~ f \~ j Drilled 8-1/2" hole in B Lateral with GeoPilot from 11,898' to 13,222' MD. , ~.„ , .>. . . ~~., „. .. .. .:~s a_.::. . N<... ,,,,.P.. . . ~ ~~,.... ~.:.~,-~ •,~ ~•~. n, ,._ ~:a~ .. ~~;~: ., ~,, ;.,~ .~ , .~;~,~;~..~~~_~ ~ -- I Page 1/2 Re ort Printed: 9/13/2007, i , Page 2/2 Report Printed: 9/13/2007I . • ~' ~. 1J-122 Slotted and Blank Liner Detail weii: CanoeoPh~llrps °B° Sand Liner Detail - Plop & Drop oace: ktaska;)nc. Rig: Supervisors: Mike Thorntonl Nina Woods / Steve Shultz ~~-~zz~~ 7i~si2on7 Doyon 141 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 OD(in) nominal Max OD(in) actual ID(in) actual LENGTH TOPS < "A" Lateral ZXP LinerTop PKR 10~970' MD I 3,785' TVD [ceserved] [[eservedj :::; (resecved] >"B" lateral window top ~ 10,827' MD / 3,764.8' ND Ireserved~ .;[teserved~ ; ~reserve~j "B" lateral window btm 10~843.5' MD / 3~76Z4' TVD [reseivedj [ies~Ned] z; (rese~vedj ;: TOL 193' out in open hole ~ 11,036' MD/ 3,790' ND ; ; i ; 11023:39 Window ~ 80.5 Deg, Top of B Lat Liner @ 87 deg 11023.39 11023.39 ~.: ::. :; . _:..- :: ::_:. .: =: ; ; :;;~. ; ; •'• ....;: ~ .... .. . ... ... _ 11023.39 11023, 39 1023.39 11023.39 11023. 39 5" DP to Surface =_> 11023.39 Baker Liner setting tool( Does not stay in hole) 12.69 11023.39 7" Baker "HR" Liner Setting Sleeve w/ 6' TBR s.26 a.26 7.5 . 8.42 11036.08 ;:::: ~~ :: ::::.:: .: ::.:-:>;:. .:<;:,.::.»::::.:>;:::: :::::;::>::»:«::«::<:::>:::;:::< >::>:::««<<<:<:::: >::»;: 3~E3:St~b::7:»~iyd;~2'f:>X::~<~~2:>::::I~i.:d::5~'[:;::::>:::<:«_»:«::::::;::»;::>:;:;::::«::«::::<:::::::>::>:::: Y 7.07 7.07 4.s5 1.06 11044.50 5 112", 15.5 f, L-80, H dril 521 Pu joint 5.74 5.74 a.9 3.66 11045.56 5 1/2", 15.5 f, L-80, Hydril 521 Rece tacle Joint) 5.~s 5.73 a.st 41.16 1104922 5 1/2" Hydril 521 Box X 4 1/2" Hydril 521 Pin X/O (3.92" I.DJ 5.72 s.~2 3.s2 1.48 11090.38 4-1/2", 12.6 ppf, L-80, Hydril 521 PUP Jt. 4.73 4.73 3.92 3.73 11091.86 XO Sub 4.5" H d 521 X 4.5", BTCM 4.5 a.5 a 1.64 11095.59 4.5" 11.6ppf L80 BTCM Fups wlTrqRngs(Top 9.81', 3.83') 4.5 5 4 13.64 11097.23 .lts s7 to s7 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg a.s 5 4 41.62 11110.87 ~ts ss to ss 1 Jts 4.5" 11.6 p f L-80 BTCM Blank csg 4.5 5 a 43.20 11152.49 ~ts s5 to s5 1 Jts 4.5" 11.6 f L-80 BTCM Slotted csg a.s 5 4 43.48 11195.69 Jts 64 to 64 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg a.s 5 4 42.95 11239.17 Jts 63 to 63 1 Jts 4.5" 11.6 f L~80 BTCM Slotted csg a.s 5 a 40.58 11282.12 Jts 62 to 62 1 Jts 4.5" 11.6 pf L-80 BTCM Blank csg a:s 5 a 43.38 11322J0 Jts 61 to 61 1 Jts 4.5" 11.6 pf L-80 BTCM Slotted csg 4.5 5 a 41.89 11366.08 Jts 60 to 60 1 Jts 4.5" 11,6 f L-80 BTCM Blank csg a,5 s 4 43.43 11407.97 Jts 59 to 59 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg a.5 s 4 43.39 11451.40 Jts 58 to 58 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg a.5 s a 43.45 11494.79 Jts 57 to 57 1 Jts 4,5" 11.6 f L~0 BTCM Slotted csg a.5 5 4 42.86 11538.24 Jts 51 to 56 6 Jts 4.5" 11.6 f L-80 BTCM Blank cs. a.s ~ a 258.62 14581.10 Jts 49 to 50 2 Jts 4.5" 11.6 f L~0 BTCM Slotted csg 4.5 5 4 82.86 11839.72 Jts 48 to 48 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 ~ 43.05 11922.58 Jts 47 to 47 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg a.s 5 a 40.27 11965.63 Jts 46 to 46 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 a 42.43 12005.90 Jts 45 to 45 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg a.5 5 a 43.06 12048.33 Notes: See btm next page for jewelry. Up Wt. 175K Ran Total of 43 jts. (1842.97') Blank pipe and 24 jts (990.37') Slotted pipe. DIl Wt. 60K 25 Trq Rings in Jts #43 -#67 ROt Wt. 96K Blk Wt. 34k Rot.1'orque 10-11K • . Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 44 to 44 1 Jts 4.5" 11.6 p f L-80 BTCM Blank csg 4.s s 4 43.31 12091.39 Jts 43 to 43 1 Jts 4.5" 11.6 p f L~0 BTCM Slotted csg 4.5 5 a 43.21 12134.70 Jts 42 to 42 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.s s a 42.71 12177.91 Jts 41 to 41 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg a.s e a 35.94 12220.62 Jts 4o to 40 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 a 42.46 12256.56 Jts 39 to 39 1 Jts 4.5" 11.6 f L-80 BTCM Slotted csg 4.5 5 a 41:25 12299.02 Jts 33 to 38 6 Jts 4.5" 11.6 f L-80 BTCM Blank csg a.5 5 4 254.52 12340.27 Jts 31 to 32 2 Jts 4.5" 11.6 f L-80 BTCM Slotted csg 4.5 5 4 74.95 12594.79 Jts 30 to 30 1 Jts 4.5" 11.6 p f L-80 BTCM Blank csg a.5 5 a 43.32 12669.74 Jts 29 to 29 1 Jts 4.5" 11.6 p f L~0 BTCM Slotted csg a.5 5 4 34.83 12713.06 Jts 28 to 28 1 Jts 4.5" 11.6 f L-80 BTCM Blankcsg a.s 5 a 43.31 12747.89 Jts 27 to 27 1 Jts 4.5" 11.6 f L-80 BTCM Slotted Csg 4.5 s a 42.84 12791.20 Jts 26 to 26 1 Jts 4.5" 11.6 p f L-80 BTCM Biank csg a.5 s a 42.38 12834.04 Jts 25 to 25 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg a.5 5 4 43.25 12876.42 Jts 24 to 24 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg a.5 5 4 40.55 12919.67 Jts 23 to 23 1 Jts 4.5" 11.6 f L-80 BTCM Slotted csg a.5 5 4 41.11 12960.22 Jts 22 to 22 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.s s a 43.42 13001.33 Jts 21 to 21 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg a.5 s 4 43.47 13044.75 Jts 16 to 20 5 Jts 4.5" 11.6 p f L-80 BTCM Blank csg a.5 s a 211.80 13088.22 Jts 14 to 15 2 Jts 4.5" 11.6 f L~0 BTCM Slotted Csg 4.5 5 4 82.28 13300.02 Jts 13 to 13 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 • 4 42.56 13382.30 Jts 12 to 12 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg 4.5 5 a 43.61 13425.16 Jts 11 to 11 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 a 43.13 13468.77 Jts 10 to 10 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg 4.5 5 4 43.62 13511.90 Jts 1 to 9 9 Jts 4.5" 11.6 f L-80 BTCM Blank csg a..s 5 4 388.69 13555.52 Bottom of Orange Peeleci Tail =___> 13944.21 13944.21 TAM FreeCa Constrictor PKR's on the following jts: 13944.21 Jt #8 - 23' Down from Box 13620' 13944.21 Jt #9 -17' Down from Box 13580' 13944.21 Jt #16 - 9' Up From Pin 13290' 13944.21 Jt #20 -13' Down from Box 13100' 1394.4.21 Jt #33 - 4' U From Pin 12590' 13944.21 Jt #38 -11' Down from Box. 12350' 13944.21 Jt #51 - 2' Up From Pin 11836' 13944.24 Jt #56 - 20' Down from Box 1160D' 1394421 Ran 58 Total ( 4.5"z6.13° Hydroform Centralizers 13944.21 on all Jts except the 8 w/Tam Pkr's ar~d Jt #1 13944.21 ~ ~ 27-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-122L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,741.25' MD Window / Kickoff Survey: 10,827.00' MD (if applicable) Projected Survey: 13,960.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ 02 Signed ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~o~~ I RE: 1 J-122 Again . Subject: RE: 1J-122 Again From: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.cam> Date: Mon, 11 Jun 2007 10:15:25 -0800 To: Thomas Maunder <tom maunder@admin.sta.te.ak.us> Tom, ~ The LEM is tested to 2500 psi for 30 minutes if the well is an injector and it is the uppermost LEM. I will change future permit applications to reflect that instruction. I apologize for the dimension discrepancy. The TVD of the Ll window is supposed to read 3787 as you noted below. 3969 is the TVD for the intermediate casing. 3787 is the value indicated on the Halliburton paperwork and the Baker Oil Tools schematic. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK t907) 244-5558 CELLULAR (918) 662-8284 FAX TQ E-MAIL Patrick.J.Reilly@conocophillips.com -----Original Message----- From: Thomas Maunder jmailto:tom maunder@admin.state.ak.us Sent: Sunday, June 10, 2007 2:33 PM To: Reilly, Patrick J Subject: Re: 1J-122 Again Pat, Would you please check the tvd on the L1 window. The tvd listed on the permit sheet is 3969 which is the same as the tvd of the casing shoe. Looking at page 3 of 8 of the Halliburton document it would appear the the correct tvd is 3787 at 10779.8 md. Would you please confirm? Thanks, Tom Maunder, PE AQGCC Thomas Maunder wrote, On 6/10/2007 2:07 PM: Pat, One quick question. When the LEM is run in step 38, is the casing x DP annulus tested at that time? If so, that is an instruction that should be mentioned. Call or message with any questions. Tom Maunder, PE AOGCC > 1 of 1 6/11/200? 10:18 AM ~ ~ ~ Q ~ ~ ~ SARAH PAUN, GOVERNOR Re: Kuparuk River Field, West Sak Oil Pool, 1J-122L1 ConocoPhillips Alaska Inc. Permit No: 207-071 Surface Location: 1837' FSL, 2347' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 318' FSL, 422' FEL, SEC. 2~, T11N, R10E, UM ~~ O~ ~~-7 333 W. 7thAVENUE, SUITE 100 C011TSER`QAZ`I011T CO1~II~II5SIOIQ ~ ANCHORAGE,ALASKA 99501-3539 ~ PHONE (907) 279-1433 Randy Thomas F~+x (907) 276-7542 Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1J-122, Permit No 20?- 070, API 50-029-23359-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Fa.ilure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspe~ at (907) 659-360? (pager). DATED this ~~'day of June, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATEOFALASKA ~ RECEiVED ALASKA OIL AND GAS CONSERVATION COMMISSION~ PERMIT TO DRILL ~~~~AY 2 5 2007 20 AAC 25.005 Alaska ~il & Gas Cans. Commissinn 1 a. Type of Work: Drill ^~ • Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ~ Stratigraphic Test ^ Service Q' Development Gas ~ Multiple Zone^ Single Zone ~ 1 c. Specify if well is p~$~p~~Q Coalbed Methane as Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-122L1 ~ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 18039' ~ ND: 3846' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of We11 (Governmental Section): Surface: 1837' FSL, 2347' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25650 ' West Sak Oil Pool . Top of Productive Horizon: 1657' FNL, 359' FEL, Sec. 36, T11 N, R10E, UM . 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 6/23/2007 Total Depth: 318' FSL, 422' FEL, Sec. 24, T11N, R10E, UM • 9. Acres in Property: 2560 14. Distance to Nearest Pro erty: 1 mile (• P s•3 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558863 - y- 5945649 ~ Zone- 4 10. KB Elevation (Height above GL): 1 OJ' RKB ' feet 15. Distance to Nearest Well within Pool: 1J-1o9 , 10840' @ 1711 16. Deviated wells: Kickoff depth: 10779 • ft. Maximum Hole Angle: 93° deg 17. Maximum Anticipated Pressures in psig (see 2o aaC 25.035) Downhole: 1732 psig SurFace: 1308 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size iCa p2C Ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 BTC 4164' 28' 28' 4204' ~ 2265' ' 770 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 11778' 28' 28' 11818' ~ 3969' - 900 sx DeepCrete 8.5" 4.5" 11.6# L-80 BTC CSG 7260' 10779' 18039' 3845' slotted liner RSs G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrili and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD ConductodStructural Surface Intermediate Production Liner Perforation Depth MD (ft): hN ~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis ~ ~ Property Plat U Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ~/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. COntBCt Pat Reilly @ 265-6048 Printed Name r Ra y Thomas Titie Drilling Team Leader Signature ~° ~ ~'~d/y~4-S Phone Date E `-~ O~n All D k Commission Use Only Permit to Drill Number. ~7~'~?/ API Number: 50- ,.. -Z3359-~ Permit Approval Date: •' '~~ See cover letter forotherrequirements Conditi0ns of app~oval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~ ~~5~ ~~~ ~ ` Samples req'd: Yes ^ No Q~ Mud log req'd: Yes ^ No []~ Other: ST ~~ H2S measures: Yes ~ No Dir ' al svy req'd: Yes [~ No ^ Sc~r~ ~d`l-v'Z ~~o~ ~- ~v~~v•.ti~~ 7~~` APPROVED BY THE COMMISSION DATE: ~~/ r _ O / , COMMISSIONER D~I''t. Form 10-401 Revised 12/2005 Submit in Duplicate ,~ ~~~7 /~ s ~ 3~. o ~ ~ Ap~n for Permit to Drill, Well 1J-122 L1 Revision NoA Saved: 23-May-07 Permit It - West Sak Well #1J-122L1 Application fo~ Permit to D~ill Document I'~~tr~~~ll r.a~x~m~ae we~~ va~ue , Table of Contents L Well Name ............................. ............. .......................................................... ..... 2 ... ... ... Requirements of 20 AAC 25.005 (~ ............................................................................................................. 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25:005(c)(2) ........................... o............................................................................. 2 Requirements of20AAC25.OS0(b) ...................................................~----..................---.........................,.-~-~- 2 3. Blowout Prevention Equipment Information .................. ............................................ 3 Requiremef~ts 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 of20AAC25.005 (c)(5) .................................:................•----...................---.---....................... 3 6. Casing and Cementing Program .........................................................................:....... 4 Requirements of 20 AAC 25.005(c)(6) ...............................................e....................'......_.............................. 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. 5eabed Condition Analysis ......................................................................................:... 5 RequiNements of20AAC25.005 (c)(11) ........................:..............................~--~~---....._....-•-~-~-~-~-~-~---............ 5 12. Evidence of Bonding ............................................................... ................. ........ 5 ~~~~~L~~L 1J-122 L1 PERMIT IT Page 1 of 6 Printed: 23-May-07 .,,,~ r.~ ~~ *.~: i Ap~n for Permit to Drill, Well 1J-122 L1 Revision NoA Saved: 23-May-07 Requirements of 20 AAC 25,OOS (c)(12) ........:......,...............o........................-•-•-•---..................................... 5 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) ..............................e......................:................................................ 6 15. Attachments ............................................................................................................... 6 Attachment 1 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) .. Error! Bookmark not defined. Attachment 2 Directional Plan (6 pages) .............................................:........................,............................. 6 Attachment 3 Drilling Haza~ds Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) ............................................................:.......................................... 6 L Well Narne Requirements of 20 AAC 25.005 (~ E'ach well must I~e ideratiTed by cz zenigue eaarne cfestgn~zte~! E~y the o~erntor and a uniqr.ae.Af'I nlamber izssigrze~~ by the corrt»tissznn un~'er- 2(t_4~?C 25.0411(b). F"or-a ~b~ell wit{a r~atiltipte weU brm^tclaes, eacla bt•ancla must sirnalarlv be ar~entif're~l l~y a irftrque rtanze anrl API rzumbzr hy ruldrycg a suffi.x ~~ tu the name designatedfor tlse well tiy the o~c;rutor and ta t{ae xaamber assigned to th~e well hti ~the commissiora. ~ The well for which this Application is submitted will be designated as 1J-122 LL 2. Location Summary Requirements of 20 AAC 25.003(c)(2) ~~n applzcation f'nr u PermiC lo L)ridl must ~~e accompattded fiy each of the fotlowing itertts, ea'r,e~t for an itetra alreacly on file rvith the r,ommissiors and ictentifced in the capplieatzon: ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ (41 a plczt identifying thel~roperty and t7ae p?~aperty's owvrers rznd sfio~+irag (4)tlze coordinates of the praposed IUCation of the tiveld at the, surf'acv_, tzt the top c~f each objective forrnation, craad cat totnl c~efttla, referetzcecl tz~ grlvernrnental secFiora Zzrees. (13j tlxe coor•dinutes of flae proposed location oj tlre well at the sur,face, referencecl to the: stafe ~~lar~e coo~-dzraaGe ,s~v,item for tlris siaTe as~ ernuintz~ined hti~ tlte R'utional Gendetic Survey in tlte Iti~utional aceana'c and .4irnosg~heric Adrrzinisfircltion; (C) the pro~osed c~epth of thn well` at ttae fap of eacla afijective,fof-rnatio~a and rzt total deptJa, Location at Surface 1837' FSL, 234T FEL, Section 35, T11N; R10E ' ASP Zone 4 NAD 27 Coordinates RKI3 Elevzztion 109' AMSL ~ Northings: 5,945,649 Eastings: 558,863 Pad Elevatiori 81' AMSL . Location at Top of Productive Interval (West Sak «B» Sand) 1,65T FNL, 359' FEL, Section 36, T11N; R10E _ ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 10,780 Northings: 5,947,495 Eastings: 566,114 Total Vertical Depth, RKB: 3,797 ~ ~~ Total Vertical Depth, SS: 3,678 Location at Total Depth 318' FSL, 422' FEL, Section 24, T11N, R10E ~ ~ ASP zone 4 NAD 27 Coordinates Measured Depth, RKB: 18,Q39 ' Northings.. 5,954,749 Eastings: 565,988 Totad Vertical Depth, RKB: 3,846 ~ Total Vertical Depth, SS: 3,736 9 cinrl (Q} other iraforrTtatintt requarecf hy'OfIAC-2~.050(f~); Requirements of 20 AAC 25.050(b) If a svell is to be i~rtenti~nadly clnviated, the ap~licatiora_Jor cr Perrnat do I~rill (ForFrt 10-4t11) must ~~~~~~AL 1J-122 L1 PERMIT IT Page 2 of 6 Printed: 23-May-07 ~ Ap~n for Permit to Drill, Weli 1J-122 L1 Revision No.O Saved: 23-May-07 (1) itzelzrde a plat, edr~aw~^t tn u suitrzble .scale, sltoiair~g t]ze padla r~j"the ~taroposec~ welll~or•e, including a1C atljac~rtt v,~el7bores wrt}2in 2dt1 feet c f tzray portivt2 of Phkt ptoposed we1t; Please see Attachment' 1: Directional Plan caracl (?) fbr all wells rvit/ezn Z~J~I feel of the ~aroposed ivellfior•e ~ ~ ~ ~ !~t) tist tDae rzarnes of tl~e opee~rtors oJ those weFls, fr, the extent that those natn~s are IcraowYa or r~iscuuerc~bte in puhlic rer,arc~s, crnd sFao~v that zcach namecf operator has be~ra fuY~~ii~shed a capy of the application Uy certifiecf rnazl,- or ~ ~ ~ ~ ~ fB,l sTate thcit tlae czpplzc•arzt is tdae only affected own~r. ~ ~ ~ ~ ~ The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) ~ An cz~~~lzcrxtron fi~r cr Perrrazd to Pril1 must be accorra~aniecl by Eaclz~of tyie followin~; items, ~ce~t,for ara ite~rE ralreadv on~le w~ilF~ the commi,ssi~~n ~ ~ ~ and ideratified in 'the ap~licatinr~a: ~ ~ ~ ~ ~ {"3) u cJiagrarra rand dES<:r^iptiora of the hl€~wout prr:~ ention equiprnefat [I30PE) as t^ezlarirtd by 20131~C 2S.!)3S, ?OA,4C 25.0_36, or^ 20 ~C?~.EI37, as npplicable; ~ An API 13-5/8" x 5;000 psi BQP stack (RSRRA) will be utilized to drill and com~lete well 1J-122 ~LL ~Please~ see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) ~ ~ ,4iz a~plicc~tiot~ for a I'ermzt to~I~rall nsust be accomj~anic:cl by each of tFt~ f'oltati~~ilag dtems, ea'cept fnr' an itenz alNeudy oiz.fale wtth the cornrnis,si~n ~~~ ~~ antl ic~crttified in the a~plr"calioYz:; ~ ~~ ~ ~ ~ ~ (~) ~inforrr~iatiat~a an clrzliing ysazarcls, inclucldng ~ ~ ~ ~ ~ ~ ~ ~ ,{A) tlze rrac~ximz~rra ca'owt~hole prE>..rsure tltad rrt~ry be encounterec! cr~iterii~ t~sec~ t<r deter~rraine it, and fna:xiFrt2~m~rotentdal surfuce pressure base~ un a metharrc: nruc~ienC: T.he expected reservoirpressure in the West Sak sands in the 1J-122 L1 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) Based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,308 PSI, calculated as follows: The MPSP is: MPSP = (3,849 ft)(0.45 - 011 psi/ft) =1,308 psi _ (1l)z~ataau~c~te~tialgas~~utaes; ~ _ ~~ ~ ~~ ~ ~ ~ The well bore is not expected to penetrate any gas zones. ~~nd (C,;) data coracertzing poteraticrl causes of ho7e pr~blems ,sucfa as ahnurmcilly gea pressured strcrda, losd cir•culatian ~ortE:s, r,~nd z~ne,s thaf have a ~ prc~~rensity f rr dzffereratial stich~i3~ig; ~ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Rer~uirements of 20 AAC 25.005 (c)(5) - An ezp~dicuffon for it Perrnit Zo L7ri11 must be accontpanied b}~ each of zhe f~llowrn,g iterns, execpt,f'or czra item nlr•eaclv c~n file with the c~rrzrnission ancC idet2trfieil dn the ctp~t7iccation: ~ {JJ a deseri~Jtior~i of tl~ie pf-ocerizere for conefuctir~ig forn~alior~ integritY tests, as reqzaired uYader~ 2~ ~tA C 25.030{f); ~ ~ ~ ~ No formation integrity test will be performed in the drilling of 1J-122 L1 1 J-122 L 1 PERMIT lT Page 3 of 6 =~.~ ! r ~ ~ ~ ~ ~ ~ Printed: 23-May-07 ~ Ap~on for Permit to Drill, Well 1J-122 L1 Revision No.O Saved: 24-May-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) .4n a~plicazzotz, for• a Fetmzi to I3rill rrtust be accomp~~znied try each of't,'ze f`ottowir~ag iterns, except for- an itena alYeacTj~ on file witFt the earr2misszor2 ~ a~zd iderafifcerl tFZ the a~plication: (bj a coertplete~~opc~sed cusit2g and eemerttiytg progrcrrn as r'eguared ~tj% 2~ AAC 2.i.f13f1, atul cz clea~cr^iptior2 of aray sl~tteil lii~er, pre-petforc21er1 liraer, or scr~een to be uz,rtalled; ~ ~ ~ ~ ~ ~~ Casing and Cementing Program See als~ Attachment 3~ ('ement Summarv Hole Top Btm Csg/Tbg Size Weight ~ Length tLID/77~D MD/TUD ~ ~ OD (in) (in) lb/ft) Grade Cor~nection (ft) ~ (ft) (ft) ~ ~ Cement Pro ram ~ 20" 40" 62.5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 ~ BTC 4,164 28' / 28' 4,204' 12,265' 770~sx Arericset Lite Lead, ~ ~ 220 sx Dee CRETE Tail Cement Top planned @ 6,750' 9-5/8" 12-I/4'' 40 L-80 BTCM 11 778 28' / 28' 969' 11 818' / 3 MD / 2,860' TVD. Cemented , , , w/ 900 sx Dee CRETE 5-1/2 8-1/2" A2 Sand J-122 15S L-80 BTCM 7 175 10,879' / 3,805' 18,054' / 3,990' Slotted-no cement 4-1/2 8-1/2" B Sand Lateral 11.6 L-80 BTC CSG 7,260 10,779' / 3~3G~ 18,039' / 3,845' Slotted- no cement ~ slotted (11-i~~Li~ , SlOtted -1/2" D Sand L.ateral (1J-122 L2) 11.6 L-80 BTC CSG 7,663' 10,368' / 3,701' 18,031' / 3,778' Slotted- no cement ~ f 7. : Diverter System Information _ Requirernents of 20 AAC 25.005(c)(7) ~ ~ .4r2 ap1~7icatzon for a Pennit to Drill nzu.st be accomlxu~iecJ by each vf #he folJowing zdems, ezcept for an itern alreadv on jilE witla the caminissian ~znc~ tdertt ~ed zn the applzcatiota: ~ ~ ~ ~ ~ (~) c2 daczgram and descriution of the div2rfer systerr2 as reyuir~ed hy 2f1 A.4C 25. (J3~, unless tltis requarem~etaG is wtri~=ed hy the cotrttnission~ une~ep ~ ~r~ ~~,~c z s:o~_s~}~ ~~,~ _ No diverter system will be used during operations on 1J-122 L1 8. Drilling Fluid Program RequiYements of 20 AAC 25.005(e)(8) .An ca~~~~lication f~~r a Per-rnat tn Drill mu.rt f~e accornpunze ~ hy each of the foilowzng items, except fc~r arz iterrz cait^eudy on fzle tvith the cvrr:rriissio~ and d~eral~c:d zn the a~plication: ~ ~ (rS) a drzllzng f7uid F~rogram, inclaEding a tli~zgrartx and descrzptioss of Ltae drzllzng,fTuid systeriz, c~s required hy ~Q _2-4C '_5~tJ33; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) ~ Value ~ Densi ( pg) ~~9A ~ Plastic Viscostiy 15-25 (lb/100 s,~ ~~ YieldPoint (cP) ig 28 HTHP Fluid loss (ml/30 min @ <4A 200psi & 1 SO° Oil / Water Ratio 80:20 ~~~~~~AL 1J-122 L1 PERMIT IT Page 4 of 6 Printed: 24-May-07 ~ Ap~n for Permit to Drill, Well 1 J-122 L1 Revision No.O Saved: 23-May-07 Electrical >600 Stability Drilling fluid practices will be in accorctance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission far diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formatton Information Requirements of 20 AAC 25.005 (c)(9) ,4t2 a~plicatlori, jor a f'ermft to -rill na~itst be t~ceomparaied by eacl~a of tke fol/owirxg izefns, e:xcept f~r art itern ah•eacly on,fle ~wiEh [kre eammzssioyt ~ art~t aden~tifred in tlae applzcation: ~ ~ ~ ~ ~ ~ ~ ~ (~1j far at2 Pxplorat~ry ~r,sCrati~;ra~~F~rie lest well, a tat~ulation seitin~g ozaF tlae clepth,e nf predicteo~ afinorrrtalXy,geo ~~res.rured strata c~s requi~t•ecl F.y ~ ZCi A.AC ?S.(~33(f),' Not applicable: Application is not far an exploratory or stratigraphic test we1L 10. Seismic Analysis Requirements of 20 AAC 25.OOS (c)(10) An applicazion fi~r• a Permit do I~rill must be ace<~nzp«nied bp euch nf'the ~~llotiving iterns, ~rce~7t f~r a7z atem nl~•eacly on fi7e wtth ttae commis~ ivfa ~md i~entzfec~ in llve appdicrztiora: ~ ~ ~ ~ ~ ~ (70) for an exploratciry or str^uti~r^a~~hzc test wetl, ~ scisnaic refrez~t'ion c~t~ reJTeczion anatysis as t•eyuired by 2(? _Af1G 2~.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) f1 rz a~~Xicatiot2, f'or^ a Pe~mit tU 1?ridt rrrt~.ri be acc~m~acinzed Uy each of Ctae f'oJlowing itefr~ts, except fos- an item~ a(re~a~ly ara f'ele with tlte commzssi«r'i ~~ aricl iclenf~~ct fva dhe applzcation: ~ ~ ~ ~ ~ ~ (1'} for a well~ drilled,~-orr an~ Uftshore platform, rra~bile ~otton:,~uarn~Ied .s~tra~ctur^e, jar.k-up r~•ig, ~~r floati~ag drillira~ vessed, an ar~lysis of setthecX ~~ ~ cclnclitiorzs us e-e~juzred by 2(I ~f.AC 25.Ofi1(b); ~ Not applicable: Application is not for an offshore well. ~ _ ~ ~~ ~ ~~ ~ 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) ~4n ap~lzr,aiion for a Permit to 77rili must E~e acce~rrap~nied by each af the following iterns, uzc•ept fc~r~ czx~ a`zem alreczrdy on fzle ~~ith tJ~ae eomrnissio~s ~ aznd zdentzfied in t,7ae applicatiori: (12) evide~2ce showia~g tFtnt t~zc~ reguiremet~ts of 2~.1~2C 2~.Q25 ?Bont~ing}have beera rnet; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. P~oposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) iln applrcation, for a f'ermzl to D~-zll ~raust be crcc~nz,rxrrzied b_y eacd2 ~f the followi~zg iterns, ~xcept for an iterrt alt•eculy nn flle with tJar commzssiora ~ an~~ i~dentf~ed in tlxe application: ~ ~ ~ ~ ~ ~ ~ The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. Notet . Previous operations are covered under the 1J-122 Application for Permit to DriIL L Run and set Baker WindowMaster whipstock system, at window point of 1 Q,779' MD / 3,78T TVD, the top of the "B" sand. ,_---, 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. -' 4. Drill to TD of "B" sand lateral at 18,039' MD / 3,845' TVD, as per directional plan:. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5-U2" 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-122 L1 PERMIT IT Page 5 of6 ~ ~ ~ f"'! ~ ~ ~ ~ Printed: 23-May-07 ~.,1 ~ Ap~ion for Permit to Drill, Well 1J-122 L1 ! Revision NoA Saved: 24-May-07 10. Make up junction isolation / re-entry assembly (Lateral Entry Module ar LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH.. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) ~ ~1 n applicaiian fi~r• a P~rmit to I?r-ill mzrstc be zucompe~taierl hy each ~~f dfie fallowifzg items, except fi~r- an itetn aJr~cacfy o~z,Tle wztla the commission ~~ carul identifiad in the applicati~n: ~ ~ ~~ (14) a,~erteral clescrrption af `how the c~perator plans to dis~~se of c~rzlizng rnud cznr~ cuttira~s arid a staterr.ent of'tivlzether the c~perator zritends to reguesd autharization untler '~ .4AC 2_5_GN~, for ar~ untaula~• dd,sposa( operatir~n in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temparary starage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this we11 far annular disposal operations. 15. Attachments Attachment 1 Directional Plan ~ Attachment 2 Drilling Hazards Summary ~ ~ ~ ~ ~ Attachment 3 Well Schematic 1J-122 L1 PERMIT IT Page 6 of 6 Printed: 24-May-07 ~ ~ ~ ~ ~ ~~ ~ ~ ~ • s CanocoPh ~ I I i ps Alaska ~ Plan: 1J-122 L1 (wp06) Sperry Drilling Services Proposal Report - Geographic 02 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-122 - Slot 1J-122 1J-122 L1 Local Coordinate Origin: Centered on Welf Plan iJ-122 - Slot 1J-122 Viewing Datum: Planned RKB @ 109.OOft (Doyon 141 (28+g1)) ~ TVDs to System: N North Reference: True ~ Unit System: API - US Survey Feet _ HAl.LIBURTC~N Sperry Drilling 8orvioss _ _ I 4~.~~! ~ t ~ ~ ~ ~ ~ HALLIBURTON Project: Kuparuk River Uni WFI,I.DETAIlS PlanU-122 Site: Kuparuk 1J Pad GoundLevel 81.00 Spsrry D~illing Ssrvicsw Well: Plan 1J-122 +Ni-s +~-w Northing ~st~~b ~dcmae Longitude siac Wellbore: 1J-122 L1 ~~ 0.00 594561948 55886337 70°IS'43595N l49°31'26.931W Ud22 Plan: 1 J-122 L1 (wp06) FORMATION TOP DETAILS No.NDPath TVDSS MDPath Formation 1 1504.91 1395.91 1650.33 Pfrost 2 1657.88 1548.88 1893.72 K15 3 1987.83 1878.83 3017.64 T3 4 2265.39 2156.39 4204.89 Casing Pt 5 2975.71 2866.71 724324 Ugnu C 500 6 3275.25 3166.25 8524.50 Ugnu B \\„ / 7 3352.32 3243.32 8854.16 Ugnu A 8 3541.64 3432.64 9663.97 K 13 ,~-~ 9 3701.06 3592.OG 10368.70 W Sak D Yr`it+'~ 10 3751.55 3642.5510600.42 W Sak C 1000 ~~'~~~~Z~ 11 3787.06 3678.0610779 79 W Sak B Ir /~~~. 1500 CASING DETAILS No MD TVD TVDss Naine S~z t 42045~ 2265.30 215G3 l3 3/8" 13-. 2 10779.81 3787 OG 3678.06 9 5/8" TOW 9-5/ 3 18039.15 3845.70 3736.7 4 V2" 4-I/2 ~ ~ ~~~ ~ ~~~ ~ ~ ( 2500 L1 9 5/8" TOW @ 10780' MD, 3797' ND: 1657' FNL, 359' FEL - Sec36-T11 N, R10E L1 BHL @ 18039' MD, 3846' TVD: 318' FSL, 422' FEL - Sec 24-T11 N-R10E ~' ` c , ~ ~ ' ~ ~ ------------- ~ 3000 - - - - - - - - - - - - - - - - r - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - T` - - - - - - - - - - - - - - O ~ ~ ~ O ~ ~ L O- _ - - b- - - - - - - - ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ T _ - - _ _ _ _ _ _ _ _ _ _ ~- - - D- _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - _ - - _ _ _ _ _ _ _ _ a _ O _ _ O___a 03500 - ---~----o- p ° - ° --~ ---~ ---~-----0----o°------------------$-----0----0----o---L°o----------- oa-- ~- ~ o ~ ------- --`° aorn.-_-_--___ .-_-__ N__-iiDr-___ M-_-- ~ w ---------------s~---~----n----^ ° ~`°m _1J-122L2(wp06~-- - -~ -ro~- -- ---------- ------------- -- ------- -- --- -- - :C - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - ~ - - - - ~ ~ ~ ~ ~ ~ - - 1J-122 L1 (wp06) ~ aooo ' ~ A ~' o o ~ `~ 1J-122 (wp06) a~ ' o 0 0 ~ 9 5/8" TOW o 0 H 4 1/2" 5000 5500 6000 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section at 0.00° (1000 ft/in) ~-' ConocoPhillips ~~ HAL~11E3tl.~RT ~1 r 8p~rry 17rilting ~srviwrs C ~ O h N + ~ ~'' ~jO C '~ 7 O ~ Project: Kuparuk River Unit w~~.DET^~s: P~~,~J-lzz Site: Kuparuk 1J Pad ~o~,a~e~: s~.oo Well: Plan 1J-122 +N~-s +E/_W Northing Fasting Iatittude Longitude Slot Wellbore: 1J-122 L1 Plan: 1J-122 L1 (wp06} 0.00 0.00 5945649.48 55886337 70°15'43.595N 149°31'26.931W 1J-122 REFERENCE INFORMATION Co-ordinate (N/E) Reference: weii Pian ~~-i22-sioi ~~-~z2, rn,e Nonn Vertical (7VD) RBfBfenCe: planned RKB (~ 109.OOft (Doyon 141 (28+81)) Measured Depth Reference: aiannea R}ce ~~oa.oon ~~oyon ~a~ ~za+e»~ Calculation Method: Minimum Curvature CASING DETAILS rth I4° eld nT 31° ~07 O6 ~~~~~~~~~ 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 oann innnn inann iinnn iiann West(-)Bast(+) (1250 fi/in) ~~~ ~~,.''~i~~ ~.7~~1 A AlaSka Conocc~hllllps Alaska ~ ~ Halliburton Company Compass Proposal Report - Geographic HALLIBURTQtV Spsrry Driliiny Bs~wtcss 5/2/2007 8:09:54PM Page 2 of 8 COMPASS 2003.11 Build 48 ~~~~~~~~ ~ ~ - 10,779.79 79.06 2.98 3,787.06 3,678.06 1,789.68 7,266.40 0.00 0.00 0.00 0.00 10,796.29 81.30 2.98 3,789.87 3,680.87 1,805.91 7,267.24 13.60 13.60 0.00 0.00 10,826.29 81.30 2.98 3,794.41 3,685.41 1,835.53 7,268.78 0.00 0.00 0.00 0.00 11,029.98 91.22 5.29 3,807.67 3,698.67 2,037.99 7,283.45 5.00 4.87 1.14 13.21 ?1,120:43 91.22 5.29 3,805.74 3,696.74 2,128.03 7,291.79 0.00 0.00 0.00 0.00 11,259.55 89.50 0.00 3,804.86 3,695.86 2,266.95 7,298.22 4.00 -1.24 -3.80 -108.00 12,409.55 89.50 0.00 3,814.90 3,705.90 3,416.91 7,298.26 0.00 0.00 0.00 0.00 12,525.15 89.11 358.91 3,816.30 3,707.30 3,532.49 7,297.17 1.00 -0.34 -0.94 -109.75 13,310.04 89.11 358.91 3,828.50 3,719.50 4,317.14 7,282.30 0.00 0.00 0.00 0.00 13,341.20 88.80 358.89 3,829.07 3,720.07 4,348.29 7,281.70 1.00 -1.00 -0.07 -176.04 14,010.52 88.80 358.89 3,843.10 3,734.10 5,017.34 7,268.77 0.00 0.00 0.00 0.00 14,048.71 89.16 359.02 3,843.78 3,734.78 5,055.52 7,268.07 1.00 0.94 0.34 19.79 14,410.73 89.16 359.02 3,849.10 3,740.10 5,417.44 7,261.90 0.00 0.00 0.00 0.00 14,563.60 92.22 359.01 3,847.27 3,738.27 5,570.26 7,259.28 2.00 2.00 0.00 -0.14 14,811.11 92.22 359.01 3,837.70 3,728.70 5,817.55 7,255.02 0.00 0.00 0.00 0.00 14,885.59 92.95 358.91 3,834.34 3,725.34 5,891.94 7,253.67 1.00 0.99 -0.14 -8.27 15,111.62 92.95 358.91 3,822.70 3,713.70 6,117.63 7,249.37 0.00 0.00 0.00 0.00 15,232.56 90.54 359.04 3,819.02 3,710.02 6,238.48 7,247.20 2.00 -2.00 0.11 176.96 15,511.86 90.54 359.04 3,816.40 3,707.40 6,517.73 7,242.49 0.00 0.00 0.00 0.00 15,635.75 89.30 358.91 3,816.57 3,707.57 6,641.60 7,240.27 1.00 -1.00 -0.10 -174.29 16,412.33 89.30 358.91 3,826.00 3,717.00 7,417.98 7,225.53 0.00 0.00 0.00 0.00 16,429.50 89.14 358.96 3,826.23 3,717.23 7,435.15 7,225.21 1.00 -0.96 0.27 164.62 17,411.87 89.14 358.96 3,841.00 3,732.00 8,417.25 7,207.34 0.00 0.00 0.00 0.00 17,456.77 89.59 358.99 3,841.50 3,732.50 8,462.14 7,206.53 1.00 1.00 0.07 3.80 18,039.16 89.59 358.99 3,845.70 3,736.70 9,044.42 7,196.24 0.00 0.00 0.00 0.00 5/2/2007 8:09:54PM Page 3 of 8 COMPASS 2003.11 Build 48 _'~:„:;' ~ '1 ~ ~ ~ ~ ~t ~ Halliburton Company H LL~BU Tt~!`I COI'lOCO~'11~~~5 Compass Proposal Report - Geographic 9perry Driiling Service~ ConaOPhlliips _. .. _ . ._.__ Alaska ~ ~ Halliburton Company Compass Proposal Report - Geographic HALLIBURTON Sper~-y Drliling S~rviass J10,779.79 79.06 2.98 3,787.06 3678.06 1,789.68 7,266.40 5,947,495.73 566,114.86 L1 9 5/8" TOW @ 10780' MD, 3797' ND: 1657' FNL, 359' FEL - Sec36-T11N, R10E - W Sak B- 9 5/8" TOW 10,796.29 81.30 2.98 3,789.87 3680.87 1,805.91 7,267.24 5,947,511.97 566,115.58 10,800.00 81.30 2.98 3,790.44 3681.44 1,809.58 7,267.43 5,947,515.63 566,115.74 10,820.27 81.30 2.98 3,793.50 3684.50 1,829.58 7,268.47 5,947,535.65 566,116.62 1J-122 MB B Heel 04/13/07 10,826.29 81.30 2.98 3,794.41 3685.41 1,835.53 7,268.78 5,947,541.59 566,116.89 10,900.00 84.89 3.82 3,803.27 3694.27 1,908.56 7,273.13 5,947,614.65 566,120.66 10,907.36 85.25 3.91 3,803.90 3694.90 1,915.88 7,273.62 5,947,621.97 566,121.09 1J-122 MB B CP7 04/13/07 11,000.00 89.76 4.96 3,807.93 3698.93 2,008.13 7,280.77 5,947,714.27 566,127.52 11,029.98 91.22 5.29 3,807.67 3698.67 2,037.99 7,283.45 5,947,744.14 566,129.97 11,100.00 9122 5.29 3,806.18 3697.18 2,107.69 7,289.91 5,947,813.89 566,135.88 11,120.43 91.22 5.29 3,805.74 3696.74 2,128.03 7,291.79 5,947,834.24 566,137.61 11,200.00 90.24 2.27 3,804.73 3695.73 2,207.41 7,297.04 5,947,913.65 566,142.23 11,259.55 89.50 0.00 3,804.86 3695.86 2,266.95 7,298.22 5,947,973.19 566,142.94 11,300.00 89.50 0.00 3,805.22 3696.22 2,307.39 7,298.22 5,948,013.63 566,142.63 11,400.00 89.50 0.00 3,806.09 3697.09 2,407.39 7,298.22 5,948,113.61 566,141.85 11,500.00 89.50 0.00 3,806.96 3697.96 2,507.39 7,298.23 5,948,213.60 566,141.07 11,600.00 89.50 0.00 3,807.84 3698.84 2,607.38 7,298.23 5,948,313.58 566,140.30 11,700.00 89.50 0.00 3,808.71 3699.71 2,707.38 7,298.23 5,948,413.56 566,139.52 11,800.00 89.50 0.00 3,809.58 3700.58 2,807.37 7,298.24 5,948,513.55 566,138.74 11,900.00 89.50 0.00 3,810.45 3701.45 2,907.37 7,298.24 5,948,613.53 566,137.96 12,000.00 89.50 0.00 3,811.33 3702.33 3,007.37 7,298.25 5,948,713.51 566,137.18 12,100.00 89.50 0.00 3,812.20 3703.20 3,107.36 7,298.25 5,948,813.50 566,136.41 12,200.00 89.50 0.00 3,813.07 3704.07 3,207.36 7,298.25 5,948,913.48 566,135.63 12,300.00 89.50 0.00 3,813.94 3704.94 3,307.36 7,298.26 5,949,013.46 566,134.85 12,400.00 89.50 0.00 3,814.82 3705.82 3,407.35 7,298.26 5,949,113.45 566,134.07 12,409.55 89.50 0.00 3,814.90 3705.90 3,416.91 7,298.26 5,949,123.00 566,134.00 1J-122 MB B CP2 04/13/07 12,500.00 89.19 359.15 3,815.93 3706.93 3,507.34 7,297.59 5,949,213.42 566,132.62 12,525.15 89.11 358.91 3,816.30 3707.30 3,532.49 7,297.17 5,949,238.56 566,132.00 12,600.00 89.11 358.91 3,817.47 3708.47 3,607.31 7,295.75 5,949,313.36 566,130.00 12,700.00 89.11 358.91 3,819.02 3710.02 3,707.28 7,293.86 5,949,413.31 566,127.32 12,800.00 89.11 358.91 3,820.57 3711.57 3,807.25 7,291.96 5,949,513.25 566,124.65 12,900:00 89.11 358.91 3,822.13 3713.13 3,907.22 7,290.07 5,949,613.19 566,121.97 13,000.00 89.11 358.91 3,823.68 3714.68 4,007.19 7,288.17 5,949,713.13 566,119.30 13,100.00 89.11 358.91 3,825.24 3716.24 4,107.16 7,286.28 5,949,813.08 566,116.62 13,200.00 89.11 358.91 3,826.79 3717.79 4,207.13 7,284.38 5,949,913.02 566,113.94 13,300.00 89.11 358.91 3,828.34 3719.34 4,307.10 7,282.49 5,950,012.96 566,111.27 13,310.04 89.11 358.91 3,828.50 3719.50 4,317:14 7,282.30 5,950,023.00 566,111.00 1J-722 MB B CP3 04N3f07 13,341.20 88.80 358.89 3,829.07 3720.07 4,348.29 7,281J0 5,950,054.13 566,110.16 13,400.00 88.80 358.89 3,830.30 3721.30 4,407.06 7,280.56 5,950,112.90 566,108.57 13,500.00 88.80 358.89 3,832.40 3723.40 4,507.02 7,278.63 5,950,212.83 566,105.85 13,600.00 88.80 358.89 3,834.49 3725.49 4,606.98 7,276.70 5,950,312.76 566,103.14 ~ 0.00 . 1,789.68 13.60 1,805.91 0.00 1,809.58 0.00 1,829.58 0.00 1,835.53 5.00 1,908.56 5.03 1,915.88 5.00 2,008.13 5.01 2,037.99 0.00 2,107.69 0.00 2,128.03 4.00 2,207.41 4.00 2,266.95 0.00 2,307.39 0.00 2,407.39 0.00 2,507.39 0.00 2,607.38 0.00 2,707.38 0.00 2,807.37 0.00 2,907.37 0.00 3,007.37 0.00 3,107.36 0.00 3,207.36 0.00 3,307.36 0.00 3,407.35 0.00 3,416.91 1.00 3,507.34 1.00 3,532.49 0.00 3,607.31 0.00 3,707.28 0.00 3,807.25 0.00 3,907.22 0.00 4,007.19 0.00 4,107.16 0.00 4,207.13 0.00 4,307.10 0.00 4,317.14 1.00 4,348.29 0.00 4,407.06 0:00 4,507.02 0:00 4,606.98 5!2/2007 8:09:54PM Page 4 of 8 COMPASS 2003.11 Build 48 ~~~~~~~~'~~ ~ ~ ~ 1 J-122-L1 06 ' - ~ ; _ =_- -- ~, - - 3,700.00 8.80 ~~ 358.89 _ _ 3,836.59 ~~ ,~ < 3727.59 --- _ 4,706.94 ,274.77 - 5,950,412.69 - 566,100.43 .00 - 4,706.94 13,800.00 88.80 358.89 3,838.69 3729.69 4,806.90 7,272.84 5,950,512.62 566,097.71 0.00 4,806.90 13,900.00 88.80 358.89 3,840.78 3731.78 4,906.86 7,270.90 5,950,612.55 566,095.00 0.00 4,906.86 14,000.00 88.80 358.89 3,842.88 3733.88 5,006.82 7,268.97 5,950,712.49 566,092.29 0.00 5,006.82 14,010.52 88.80 358.89 3,843.10 3734.10 5,017.34 7,268.77 5,950,723.00 566,092.00 0.00 5,017.34 9J-122 MB 8 CP4 04/13/Q7 14,048.71 89.16 359.02 3,843.78 3734.78 5,055.52 7,268.07 5,950,761.17 566,091.01 1.00 5,055.52 14,100.00 89.16 359.02 3,844.53 3735.53 5,106.79 7,267.20 5,950,812.43 566,089.73 0.00 5,106.79 14,200.00 89.16 359:02 3,846.00 3737.00 5,206.77 7,265.49 5,950,912.38 566,087.24 0.00 5,206.77 14,300.00 89.16 359.02 3,847.47 3738.47 5,306.74 7,263.79 5,951,012.33 566,084.75 0.00 5,306.74 14,400.00 89.16 359.02 3,848.94 3739.94 5,406.72 7,262.08 5,951,112.28 566,082.27 0.00 5,406.72 14,410,73 89.16 359.02 3,849.10 3740.10 5,417.44 7,261.90 5,951,123.00 566,082.00 0.00 5,417.44 1J-122 MB B CP5 04t13/d7 14,500.00 90.94 359.02 3,849.02 3740.02 5,506.70 7,260.37 5,951,212.23 566,079.78 2.00 5,506.70 14,563.60 92.22 359.01 3,847.27 3738.27 5,570.26 7,259.28 5,951,275.77 566,078.19 2.00 5,570.26 14,600.00 92.22 359.01 3,845.86 3736.86 5,606.63 7,258.65 5,951,312.14 566,077.28 0.00 5,606.63 14,700.00 92.22 359.01 3,842.00 3733.00 5,706.54 7,256.93 5,951,412.02 566,074.78 0.00 5,706.54 14,800.00 92.22 359.01 3,838.13 3729.13 5,806.45 7,255.21 5,951,511.90 566,072.28 0.00 5,806.45 14,811.11 92.22 359.01 3,837.70 3728.70 5,817.55 7,255.02 5,951,523.00 566,072.00 0.00 5,817.55 1J-122 MB B CP6 04J13/07 14,885.59 92.95 358.91 3,834.34 3725.34 5,891.94 7,253.67 5,951,597.37 566,070.07 1.00 5,891.94 14,900.00 92.95 358.91 3,833.60 3724.60 5,906.33 7,253.40 5,951,611.76 566,069.68 0.00 5,906.33 15,000.00 92.95 358.91 3,828.45 3719.45 6,006.18 7,251.49 5,951,711.58 566,067.00 0.00 6,006.18 15,100.00 92.95 358.91 3,823.30 3714.30 6,106.03 7,249.59 5,951,811.40 566,064.31 0.00 6,106.03 15,111.62 92.95 358.91 3,822.70 3713.70 6,117.63 7,249.37 5,951,823.00 566,064.00 0.00 6,117.63 1J-122 MB B CP7 04/13/07 15,200.00 91.19 359.00 3,819.51 3710.51 6,205.93 7,247.75 5,951,911.28 566,061.70 2.00 6,205.93 15,232.56 90.54 359.04 3,819.02 3710.02 6,238.48 7,247.20 5,951,943.82 566,060.89 2.00 6,238.48 15,300.00 90.54 359.04 3,818.39 3709.39 6,305.91 7,246.06 5,952,011.23 566,059.22 0.00 6,305.91 15,400.00 90.54 359.04 3,817.45 3708.45 6,405.89 7,244.38 5,952,111.19 566,056.76 0.00 6,405.89 15,500.00 90.54 359.04 3,816.51 3707.51 6,505.88 7,242.69 5,952,211.14 566,054.29 0.00 6,505.88 15,511.86 90.54 359.04 3,816.40 3707.40 6,517.73 7,242.49 5,952,223.00 566,054.00 0.00 6,517.73 1J-122 MB B CP8 04/13/07 15,600.00 89.66 358.95 3,816.25 3707.25 6,605.86 7,240.94 5,952,311.10 566,051.76 1.00 6,605.86 15,635.75 89.30 358.91 3,816.57 3707.57 6,641.60 7,240.27 5,952,346.83 566,050.81 1.00 6,641.60 15,700.00 89.30 358.91 3,817.35 3708.35 6,705.83 7,239.05 5,952,411.05 566,049.09 0.00 6,705.83 15,800.00 89.30 358.91 3,818.57 3709.57 6,805.81 7,237.15 5,952,511.00 566,046.41 0.00 6,805.81 T5,900.00 89.30 358.91 3,819.78 3710.78 6,905.78 7,235.26 5,952,610.94 566,043.73 0.00 6,905.78 16,000.00 89.30 358.91 3,820.99 3711.99 7,005.76 7,233.36 5,952,710.89 566,041.05 0.00 7,005.76 16,100.00 89.30 358.91 3,822.21 3713.21 7,105.73 7,231.46 5,952,810.84 566,038.37 0.00 7,105.73 16,200.00 89.30 358.91 3,823.42 3714.42 7,205.71 7,229.56 5,952,910.79 566,035.69 0.00 7,205.71 16,300.00 89.30 358.91 3,824.64 3715.64 7,305.68 7,227.66 5,953,010.73 566,033.01 0.00 7,305.68 16,400.00 89.30 358.91 3,825.85 3716.85 7,405.66 7,225.76 5,953,110.68 566,030.33 0.00 7,405.66 16,412.33 89.30 358.91 3,826.00 3717.00 7,417.98 7,225.53 5,953,123.00 566,030.00 0.00 7,417.98 1J-122 MB B CP9 04i13/Q7 5/2/2007 8:09:54PM Page 5 of 8 COMPASS 2003.11 Build 48 ~~'°~~~~~z~~~ / Halliburton Company HALLIBURTQN COIlOC0~11~~1~3S Compass Proposal Report - Geographic /~~{~ Spsrry DriHing Serv[ces ~~ ~ 16,429.50 89.14 358.96 3,826.23 3717.23 7,435.15 7,225.21 5,953,140.17 566,029.55 1.00 7,435.15 16,500.00 89.14 358.96 3,827.29 3718.29 7,505.63 7,223.93 5,953,210.63 566,027.71 0.00 7,505.63 16,600.00 89.14 358.96 3,828.80 3719.80 7,605.60 7,222.11 5,953,310.57 566,025.11 0.00 7,605.60 16,700.00 89.14 358.96 3,830.30 3721.30 7,705.57 7,220.29 5,953,410.52 566,022.51 0.00 7,705.57 16,800.00 89.14 358.96 3,831.80 3722.80 7,805.55 7,218.47 5,953,510.46 566,019.91 0.00 7,805.55 16,900.00 89.14 358.96 3,833.31 3724.31 7,905.52 7,216.65 5,953,610.41 566,017.31 0.00 7,905.52 17,000.00 89.14 358.96 3,834.81 3725.81 8,005.49 7,214.83 5,953,710.35 566,014.71 0.00 8,005.49 17,100.00 89.14 358.96 3,836.31 3727.31 8,105.46 7,213.01 5,953,810.30 566,012.11 0.00 8,105.46 17,200.00 89.14 358.96 3,837.82 3728.82 8,205.43 7,211.19 5,953,910.24 566,009.51 0.00 8,205.43 17,300.00 89.14 358.96 3,839.32 3730.32 8,305.41 7,209.37 5,954,010.19 566,006.91 0.00 8,305.41 17,400.00 89.14 358.96 3,840.82 3731.82 8,405.38 7,207.55 5,954,110.13 566,004.31 0.00 8,405.38 17,411.87 89.14 358.96 3,841.00 3732.00 8,417.25 7,207.34 5,954,122.00 566,004.00 0.00 8,417.25 7J-122 MB B CP10 04l13/07 17,456.77 89.59 358.99 3,841.50 3732.50 8,462.14 7,206.53 5,954,166.88 566,002.84 1.00 8,462.14 17,500.00 89.59 358.99 3,841.81 3732.81 8,505.36 7,205.77 5,954,210.08 566,001.74 0.00 8,505.36 17,600.00 89.59 358.99 3,842.53 3733.53 8,605.34 7,204.00 5,954,310.04 565,999.19 0.00 8,605.34 17,700.00 89.59 358.99 3,843.25 3734.25 8,705.32 7,202.23 5,954,410.00 565,996.64 0.00 8,705.32 17;800.00 89.59 358.99 3,843.98 3734.98 8,805.30 7,200.46 5,954,509.95 565,994.10 0.00 8,805.30 17,900.00 89.59 358.99 3,844.70 3735.70 8,905.28 7,198.70 5,954,609.91 565,991.55 0.00 8,905.28 18,000.00 89.59 358.99 3,845.42 3736.42 9,005.27 7,196.93 5,954,709.86 565,989.00 0.00 9,005.27 18,039.16 89.59 358.99 3,&45.70 3736.70 9,044.42 7,196.24 5,954,749.00 565,988.00 0.00 9,044.42 L1 BHL @ 18039' MD, 3846' ND: 318' FSL, 42 2' FEL - Sec 24-T71 N-R10E - 4 1/2" - 1J-122 MB_B_Toe 04/13107 5/2/2007 8:09:54PM Page 6 of 8 COMPASS 2003.11 Build 48 t.~~~~~~~'~~~~„ COn~~/~'„' Halliburton Company HALL~tBURTON ~ Compass Proposal Report - Geographic qpe~.~.y Drillir~~ F~~rviaes M r / Halliburton Company HA~LIBURTON ConocoRhillips Compass Proposal Report - Geographic q~~ Sperry Driliing Serviade 3,843.10 1J-122 MB_B_CP4 04/13/07 5,017.34 7,268.77 5,950,723.00 566,092.00 - Polygon Point 1 0.00 0.00 5,950,723.00 566,092.00 Point 2 400.15 -6.87 5,951,123.00 566,082.00 3,849.10 1J-122 MB B CP5 04/13/07 5,417.44 7,261.90 5,951,123.00 566,082.00 - Polygon Point 1 0.00 0.00 5,951,123.00 566,082.00 Point2 400.27 -6.88 5,951,523.00 566,072.00 3,814.90 1J-122 MB B CP2 04/13/07 3,416.91 7,298.26 5,949,123.00 566,134.00 - Polygon Point 1 0.00 0.00 5,949,123.00 566,134.00 Point2 900.58 -15.97 5,950,023.00 566,111.00 3,828.50 1J-122 MB_B_CP3 04/13/07 4,317.14 7,282.30 5,950,023.00 566,111.00 - Polygon Point 1 0.00 0.00 5,950,023.00 566,111.00 Point 2 700.35 -13.53 5,950,723.00 566,092.00 3,841.00 1J-122 MB_B_CP10 04/13/07 8,417.25 7,207.34 5,954,122.00 566,004.00 - Polygon Point 1 0.00 0.00 5,954,122.00 566,004.00 Point 2 627.18 -11.10 5,954,749.00 565,988.00 3,845.70 1J-122 MB_B_Toe 04/13/07 9,044.42 7,196.24 5,954,749.00 565,988.00 - Point 3,826.00 1J•122 MB_B_CP9 04/13/07 7,417.98 7,225.53 5,953,123.00 566,030.00 - Polygon Point 1 0.00 0.00 5,953,123.00 566,030.00 Point2 999.38 -18.19 5,954,122.00 566,004.00 3,816.40 1J-722 MB_B_CP8 04/13/07 6,517.73 7,242.49 5,952,223.00 566,054.00 - Polygon Point 1 0.00 0.00 5,952,223.00 566,054.00 Point2 900.30 -16.97 5,953,123.00 566,030.00 3,837.70 1J-122 MB_B_CP6 04/13/07 5,817.55 7,255.02 5,951,523.00 566,072.00 - Polygon Point 1 0.00 0.00 5,951,523.00 566,072.00 Point 2 300.46 -5.66 5,951,823.00 566,064.00 3,822.70 1J-122 MB_B_CP7 04/13/07 6,117.63 7,249.37 5,951,823.00 566,064.00 - Polygon Point 1 0.00 0.00 5,951,823.00 566,064.00 Point 2 400.15 -6.87 5,952,223.00 566,054.00 ` 3,793.50 1J-122 MB_B_Heel 04/13/07 1,388.01 7,251.40 5,947,094.00 566,103.00 - Polygon Point 4 0.00 0.00 5,947,094.00 566,103.00 Point 2 772.88 37.05 5,947,867.00 566,134.00 3,803.90 1J-122 MB_B_CP1 04/13/07 2,160.82 7,288.44 5,947,867.00 566,134.00 - Poiygon Point 1 0.00 0.00 5,947,867.00 566,134.00 __ Point 2__ __ 1.256.08 _ 9.82 5 94 12 .00 66 13 .0 5/2l200~-r8:09:54PM Page 7 of 8 COMPASS 2003.11 Build 48 - ~~~~~~ ~ ~ Conocc~'hlll~ps f~laska ~ Halliburton Company Compass Proposal Report - Geographic ~ H;Q-LL'~u~-ro~ Spsrry Driliing ~eMrtc~s 4,204.50 10,779.81 18,039.15 2,265.30 3,787.06 3,845.70 13-3/8 9-5/8 4-1l2 16 12-1/4 6-3l4 ~1,650.33 48.69 101.47 1,504.91 -126.53 494.54 Pfrost ~~ ~ 1,893.72 56.21 100.76 1,657.88 -t63.36 679.93 K15 3,015.12 76.48 99.31 1,987.24 -340.00 1,730.66 T3 4,204.50 76.48 99.31 2,265.30 -527.10 2,871.85 Gasing Pt 7,265.86 76.48 80.48 2,981.00 -917.07 5,814.02 Ugnu C 8,495.41 76.49 40.27 3,268.45 -338.21 6,832.05 Ugnu B 8,822.09 76.48 29.59 3,344.82 -78.20 7,013.66 Ugnu A 9,647.89 76.48 2.59 3,537.88 686.14 7,234.14 K 13 10,368.70 77.41 1.76 3,701.06 1,388.01 7,251.40 W Sak D 10,591.24 77.41 1.76 3,749.55 1,605.10 7,258.07 W SakC 10,779J9 79.06 2.98 3,787.06 1,789.67 7,266.40 W Sak B 5l212007 8:09:54PM Page 8 of 8 ~ COMPASS 2003.11 Build 48 ~ ~: ~ C~~~~~~~~~~.~~ ~ ~ ~ • • CanacoPh ~ I I~ ps Alaska ~ Plan: 1J-122 L1 (wp06) Sperry Drilling Services Anticollision Summary 09 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad P1an 1J-122 1J-122 L1 tocal Coordinate Origin: Centered on Well Plan 1J-122 - Slot 1J-122 Viewing Datum: Planned RKB @ 109.OOft (Doyon 141 (28+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet LLI~ ~ ~ ~TOR~t 8perry Drillir-g Service: ~ ~ ~ ~ ~ ~ ~ ~ ~ N .....~ ~ .~..~ ~ ~ ~ SURVEY PROGRe1M Date: 2007-OS09TU0:00:00 Validared: Yes Version: Depth FromDepth To Survey/Plan Tool 28.00 800.00 CB-GYR4SS 800.OOI077999 MWD+IFR-AK-C~SC 10779.7918039.16 1J-122 LI (wp06) MWU+IFR-AIi-C.~LC z~a 1ao Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Waming Method: Rules Based so Travelling Cylinder Azimuth (TFO+AZI) ~°] vs Centre to Centre Separation ~300 tUin~ I REFERENCE INFORMATION I Co-ordinate (N/E) Reference: Well Plan 1J-122 - Slot 1J-122, True NoRh Vertical (ND) Reference: Planned RKB ~ 109.OOR (Doyon 141 (28+81)) Section (VS) Reference: Slot - 1J-122~O.OON, O.OOE) Measured Depth Reference: Planned RKB ~ 109.OOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature From Colour To MD 0 10000 10000 10250 10250 10500 10500 10750 10750 11000 11000 11250 11250 -- - 11500 11500 11750 11750 12000 12000 12250 12250 -- - 12500 12500 12750 12750 13000 13000 13250 13250 13500 13500 13750 13750 14000 14000 14250 14250 14500 14500 14750 14750 - 15000 15000 15250 15250 15500 15500 15750 15750 16000 16000 16250 16250 16500 issoo ~s~so 16750 17000 17000 -' ~-~ 17250 17250 17500 17500 17750 17750 18000 ~80~0 ~8250 18250 18500 18500 18750 ~ NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-122 ~ Ground Level: 91.00 +NI-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945649.48 558863.37 70°75'43.595N 149°31'26.931W 1J-122 90 s.~ Mn m~ r~~~ rvo .w~s *ei-w 1 101"l9.]9 19.06 2.90 JI81.08 tI898B T18640 o~.o 0.00 h.<. vs.~ r.~o.~ 0.00 1189.88 3 10)96.39 8130 Z99 ]]898] 1805.91 i26)2< a ioazflzs eiw Zsa nsa.n ieass3 nse~e 13.80 oao 0.00 1BOv.91 oao ieassa 4 1102999 91.11 5.29 ]&11.8] 10]199 ]ZB]d5 500 1321 203]99 5 1 f 130.41 91.31 5.39 ]BPi.'!4 311B 03 i391 ]9 6 11359.55 8950 0.00 ]804.l6 33fi6.95 ]39B.32 0.00 4.00 0.00 313B.03 -10B.00 33fi6.95 ] 12409.55 8950 000 3B1d.90 ]d16.91 i29B36 B 135i5.15 89.11 J5B.91 3816.30 JS~l.~9 ]]9].1) 000 1.00 0.00 341691 1}~21M8_B CALOY1101 -108.)5 J5324B 9 1331004 &9.11 J5B.91 ]83B.50 A31).14 I383.J0 10 133C1.I11 BB.80 JSB.09 38390] <XB.]9 ]281 ]0 0.00 1 W 0.00 <311.10 1J-11IM8_8_CPJW110] -1]601 C348.29 1t1i0t0.52 8080 JSB.09 30C~f0 501].34 TlBB.]) 1210008.i1 89.16 35902 380]]8 505552 R60.0] 0.00 1.00 000 501].J4 1J-122MBBCP<01I13I0) 19.i9 505553 1] 1C410T! &9.16 35902 ]BC9.10 SCt]dC ]26190 0.00 000 591]GA 1J-123MB_B_GPSOY1L01 t<1d563.80 92.21 35901 ]BI~.Z] 55]0.26 R59.18 151GB11.11 93.22 35901 383).]0 SB1)55 ]35503 200 0.00 A.1C 551026 0.00 581].55 1J-123MB_B_CP6W1LOl 161dBB5.59 9395 358.9~ 383C.30 5891.BC ]353.6] t] 1511162 9395 J58.91 JBl2]0 611].6] Rd9.]] 1.00 U.00 -0.31 X91.94 0.00 611163 1J-123MB_B_W)OV110] 181523358 90.SC J5901 381903 8338.L8 R<].20 ~9 t55t188 905a J59.6a 3816a0 &51].l~ Y1d]a9 3.U0 0.00 1]8.% 6338.48 OW 65t])3 tJ~t13MB B CPBUN110] 30156]5."/5 89.30 JSB91 J8165] 88~1.60 Ti<0.]) 1.00 -1]a.29 BBa160 Itt8at2.Jl 89.~0 JSB.9t 38]800 14~1.88 Tt]5.53 n isazs.so es.u ~sasb xzsn ins.is nxs.zi 0.00 i.oo 000 ]nt)98 tJ-112MBBCP9W110] isos~ ~a35.is 2J110118] 89.1d ]58% ]84100 611]25 T10]JO 0.00 000 BC11.35 1J-133MB_B_LP10W11T~ za ~~ass.n 89.59 35899 l&1150 8163.1< ]I06.53 3518aJ9.18 &9.59 35898 38a5.]0 80b1<2 ]18639 1.00 0.00 3B0 BC63.10 OUO BMC.<2 1J.1]]MB B TeeON110] COMPANY DETAILS: ConocoPhillips Alaska, Inc. ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 50Stations Depth Range From: 10779.79 To 18039.1561345006 Maximum Range:2000.35806479812 Reference: Plan: 1J-122 L1 (wp06) ~ 180 Travelling Cylinder Azi`uuth (TFO+A7.1) ~°~ vs Cenfre fo Centre Separafion ~30 fdin~ ~ Halliburton Company ~ Anticollision Report Casing Points 10779.79 3787.24 9.625 12.250 9 5/8" TOW 18039.19 3845.70 5.500 8.500 51/2" Plan: 1J-122 L1 (wp06) Date Composed: 5l14/2007 Version: 3 Principal: Yes Tied-to: F~om: Definitive Path Summary Kuparuk 1 D Pad 1 D-141 1 D-141 VO Out of range Kuparuk 1 D Pad 1 D-141 1 D-141 L1 VO Out of range Kuparuk 1 D Pad 1 D-30 1 D-30 V6 Out of range Kuparuk 1 D Pad 1 D-30 1 D30L1 V2 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32 V5 18036.07 9750.00 1058.11 147.53 910.58 Pass: Major Risk Kuparuk 1 D Pad 1 D-32 1 D-32L1 V1 18036.07 9750.00 1058.11 147.53 910.59 Pass: Major Risk Kuparuk 1 D Pad 1 D-32 1 D-32L1 P61 V1 18036.07 9750.00 1058.11 147.53 910.59 Pass: Major Risk Kuparuk 1 D Pad 1 D-34 1 D-34 V6 17142.72 9275.00 697.63 247.03 450.60 Pass: Major Risk Kuparuk 1 D Pad 1 D-34 1 D-34L1 V1 17143.57 9275.00 697.70 246.04 451.65 Pass: Major Risk Kuparuk 1 D Pad 1 D-34 1 D-34L1 PB1 V1 17143.57 9275.00 697.70 246.04 451.65 Pass: Major Risk Kuparuk 1 D Pad 1 D-37 1 D-37 V4 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L1 V1 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2 V3 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2P61 V1 Out of range Kuparuk 1 D Pad 1 D-39 1 D-39 V2 Out of range Kuparuk 1 D Pad Prelim: 1 D-13 Prelim: 1 D-13 VO Plan: Out of range Kuparuk 1J Pad 1J-03 1J-03 V10 12150.28 9250.00 1607.18 137.61 1469.57 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L1 V2 12150.24 9250.00 1607.17 138.76 1468.41 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2 V1 12150.24 9250.00 1607.17 138.76 1468.41 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2P61 V1 12150.24 9250.00 1607.17 138.76 1468.41 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109 V1 Out of range Kuparuk 1J Pad 1J-109 1J-109PB1 V3 Outofrange Kuparuk 1J Pad Plan 1J-111 Plan 1J-111 V1 Plan: 1 Outofrange Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L1 V2 Plan 17856.55 18056.49 1576.26 281.89 1294.38 Pass: Major Risk Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L2 V0 Plan 17856.08 16049.85 1579.38 468.61 1110.77 Pass: Major Risk Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 V2 Plan: 1 18037.31 16250.00 1574.25 297.02 1277.23 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L2 VO Plan 10797.46 10800.00 66.99 0.00 66.99 Pass: No Errors Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 V2 Plan: 1 10799.99 10800.00 0.47 0.00 0.47 Pass: No Errors Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V2 Plan: 1 16740.76 18437.52 1219.40 271.20 948.20 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L14(BQ) Plan 1J-L14(BQ) VO Pla 16757.19 15216.17 530.67 260.80 269.87 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L15(BP) Plan 1J-L15 D Lateral 16788.70 16334.71 581.16 262.88 318.28 Pass: Major Risk ~,~'~~~~~~~ GLOBAL SCAN APPLIED: All wellpat6s within 200'+ 100/1000 of reference Reference: Plan: 1J-122 L1 (wp06) & NOT PLANNED Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10779.79 to 18039.20 ft Scan Method: Trav Cylinder North Maximum Radius: 2001.12 ft Error Surface: Ellipse + Casing ~ ~ ~7 ~ ~ ~ 1J-122 L2 (wp06) 1/4 Mile Pool Scan Sperry Drilling Services May 1, 2007 ~ ~ HALLIBURTON Drilling and Pormation Evaluation ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Closest in POOL ;~ r~'~.,/ ~ A ~<.,~ ; ~ Closest A roach: Reference Well: 1J-122 L2 w 06 Plan Offset Well: 1D-34 3-D ctr-ctr Distance H<~ri~m~.~>~i ia =` -~° E z=u4~~~ ~°`~~'aj i~ Meas: Depth ncl. Angle RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)/W(-) View VS (0°) omments Meas. Depth nG. Angle RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E+)/W(-) View VS (0°) omments 97.98 ~ ''~ "_ z~ry `~~ '^d 7550 9.57 58.99 665.908 954269.6 660007 563.826 POOL Min Distance (797.98 ft) in POOL (10368.7 - 18031.58 MD) to 1D-34 (7883.33 - 8767.23 MD) 786.54 7.41 57.41 96171 954244.1 65260 5012.22 POOL Min Distance (797.98 ft) in POOL (10368.7 - 18031.58 MD) to 1J-122 L2 (wp06) Plan (7883.33 - 8767.23 MD) Closest A roach: Reference Well: 1J-122 L2 w 06 Plan Offset Well: 1J-109 3-D cV-ctr Distance Hpriz~, ~>~t `~3.~E.ar °_ 4u~as~,~: ~ifl~ e~~a Meas. De th nG. An le RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+ /W - View VS (0° omments Meas. De th ncl. An le RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E+/W - View VS 0° omments 711.24 `:'~~? z"> 9.' >£3~,~ 0368] 7.41 J6 592.183 947094.4 66103.7 388.02 POOL Min Distance (1711.24 ft) in POOL (10368 - 18031.58 MD) to 1J-109 (10850 - 15160 MD) 0840.27 0.91 78.58 633.31 945810.9 67234.8 157.02 in istance (1711.24 ft) in POO (10368 - 18031.5 MD) to 1J-122 L2 (wp06) Plan (10850 - 15160 MD) POOL Summary Template.xls 5l1/2007 2:18 PM QR1~INAL ~ ~ n N J Q H W ~ ~ Z ~ Q U ~ G1MC`DN NM4~~ !n ~ C1 1~ ~ ~ . H ~MOON 1p~y~~ Z~m~ Iq01tOM V1M0 ~j ~~t~i~c ~~rn~ ~ N M N M ~ M O M ~t~DO~ N 1~ P N M M ~OfNT ~OOf~ M voo~ OtDM N M O aoao ~~ O ~ N M Z ~ ~ ~ v ~ ~ ~ O ~ 0 0 O r C ~ O b M + N O W O : Ln .!.. M N d ~ C ~ D ~ A ~a ~ ~ N Y Y ~ 72~ aa~ YYa U r ~ N ~ O a m + m a a c 0 T O 0 ~ 0 0 o~ ~ m Y zv~ ~ °me~i o c ~u ~c o~~m m a ~n ~n -ym>X J ~ ~ ~ ~ ~ cc ~ ~ N~p ~ OW Z ~n z S ~ .~ 0 ~ I- • m a ~ ) ~ -` p V m z O J 0 U I ~ ( ~!/11005 £ 1(+143~ o N/~-) 43 n o S O O 0 ~ M ~ ~ O r 0 0 ~ 0 1~ i f V f `L iJ-122L~Drillin Hazard~'Summa (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure ' 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 ~ ~ ~ ~ r~ ~. ~,, ~ ~ ~. ~ ~ 1J-122L1 Drilling Nazards Summary 5/23/2007 2:59:00 PM 20" 94.0# x 34" Insulated Conductor, K-55, set at+/- SO' 133/8", 68#, BTC " Shoe set @ 4204' MD, 2265' ND Tubing String ~ \ 4112" 12.6#, L-80, IBTM 3 833" Drift 3 958" ID / / . . , 7" X 9~518" ZXP Liner Seal qssembly Top Packer wl Hold d,75" Seal OD Downs Tubing, 41/2", 12.6#, IBTM, Special Drift to +~- 500' 3.875" DB Nipple, for Possible SSSV, +/- 500' GLM, Camco KBMG, 41/2" X 1" GLM, Camco KBMG, 41/2" X 7" Sliding Sleeve, w/ 3.81" DB Nipple, +I-1 jt above seals Casing Sealbore Receptacle, 20' Length / Lateral Entry Module(LEM) D-sand Window t 10368' MD, 3701' ND 4-112" 11.6# L~0 SlotMd Payzone ECP Liner Every Other Joint ~ _ - ~i 7" X 9-518" Seal Bores Model'B' HOOK Hanaer 3.68" ID 7" X 9-SIS" ZXP Liner Top Packer wl Hold Downs Assemblv .-~ 7" X 9518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile Automatic Alignment of LEM Positive Latching Collet ~ Indicates Correet Location ~ Seal Bore for Lateral Isolation - J.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore tor Lateral Isolation - 3.68" ID ~ Isolation Seal Asembly 4.75" Seal OD 3.875" SeaIID 7" Tieback Sleeve ~4-112" bent muleshoe Seal Assembly 4.75" Seal OD ~ ~ Laterel Entry Module(LEM) ~ r.:. ~~s Baker Oi17'ools As Planned Lateral Entry M odule (LEM1 With Diverters and Isolation Lateral Access Diverter Laterallsolation Diverter GS Running Tool Sbing Installed ~~s~~~kd (3.00" Lateral Dr ik) (Y.50" ID Mainbor e DriR) 'GS' Profile for Coil Connector JRunning/Retrieving ~ (7.00' Length) Snap In/Snap Out /Positive Lowting~ rBack Prescure Valve Callet (1.80' length~ Latenl Isolation ~' / Flow-7hru Swivel Seals j ~ (1.25' Length) ~ Lateral Diverter f~ Hytlreulic Ramp Diaconnect ~so~atlon/ Mainbore~ ~~.w• ~eoeml o~~ener siK~e ~~ cs s~ar ~ (7.50' Length) Latenl Isolation 6.85 R Approz. Seals I I OAL' B-sand Window Casing Sealbore at 10779' MD, 3787' ND ~B' Sand Lateral Receptacle / ~ 20' Length ~ F112" 11.6# L~0 Slotted ~ Payzone ECP Liner Every Other Joint '°~.~~~ ~ I .4-V2"GuideShoe 95/8" ,~ 4112" Liner Shoe, 11.6#, L-80 BTC Seal Bores 7" Tieback Sleeve Set @ 78039' MD, 3845' ND 3.68" ID 4-112" bent muleshoe ` ~__ _ .._,_ 3.562" DB NiPPIe ~..1 ~ ` ~~ ~~ 3.833" Drift 3.958" ID ~ 7" X 9S18" ZXP LinerTopPacker ~ with Hold Downs 7" X 9-518" Flex Lock Liner Hanger 1 Packer Assembly at Line~ Hanger +1-'10880' MD, 7787 ND Casing Sealbore Receptacle, 20' Length Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral 5-112" 15.5 # L~0 Slotted \ Liner Every Other Joint `+~~~~~ Eccentric / .Guide Shoe ~ 7" X 9-5/8" HOOK Hanger ~! Mainbore Drift: 7.00" ~ Mainbore Drift, with diverter: 6.25" Lateral Drift, no diverter or LEM: 628" ~Lateral Drift, wl diverter, no LEM: 5.12" LaterallMainbore DiveAer OD: 8.50" 41/2" Lateral Entry Module Mainbore Drift: 3.68" Mainbore Drift, wl isolation sleeve: 2.50" Lateral DrHt, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.60 5-1/2" Casing Shoe, 15.5 #, L-80 BTC Set @ 18054' MD, 3990' ND 9-5/8" 40 # Casing, L-80, BTCM, Set m Baker Hug~es 2005. Thls document maynot be reproAUCeC ordlstributed, In whole or In part, In any }orm or Cy at @ 17816' MD, 3969' ND (84 deg) any means elxROnlc or mechanlcal, Inclutling PhototopN~9. recortling, or Ey any Informatlon stonge antl retrleval sysMm now knovm or hereaMr Inven[etl, vANOUt written permisslon hom Baker Huq~es Inc. ConocoPhillip~ West Sak 9-5/8" HBB Injector 1 J-122 Tri-Lateral Completion WP_os r 'D' Sand Lateral 4-1/2" Guide Shoe 41/2" Liner Shoe, 11.6#, L-80 BTC Set ~ 18031' MD, 3778' ND we.e sax e-sre^ reaae~~ai comPienon -m~.eror DrmnBy: RaN~bnNo.: May 34, 300T Marc U. Kuck 0 ~ • ~'R~4iYS10'tIT"~'A~ L~'fl'TEIa C'H~CKLIST ~VEI,L ~A!~tE ~`/~--~ ~-.~` ~ZZ, C.. I PTD# ZU 7' D'7 f Deve[opmenr ~ Service E~ lorato ~Yon-Conventional Wel[ P ~'~ Stratigraph~c 'I'est Cercle 4ppropriate Letter / Paragtaphs to be Includ~d in TraASmittal Letter ' Cf~CK i ADD-O~IS ~ ~'~'~T I •(OPTIOIVS) TEXT FOR APPROV4L LETTER ~ APPL[ES ~ , ~ ~ ~ MULTI LATERAL , The perntit i; for a new wetl6ore se ment f i g o ex sting ` I ~ we(t ~~(~ ~~ /2 Z ' I (If tast tw di i I , ~ o g t ~ AP[ number ' s in are , P~rmi~Yq~Zp -,D?l~ RPi No. ~0-D,~ _ Z _~' ; , , between 60-69) houtd continue to be reported as a function of rhe I ~' origina! 4P[ number stated above. ~ ~ P[LOT EfOCE ' ; ' ' i[n accoedance with 20 A.4C 2~.00~(~, a!i record;, data arid (o~s i ; acquired for the pilot ho(e m t b ~ i - us e ciearly differentiated in both ~ ; WelI name ( ' PE~ and API numb ~ ; ~ ~ i (~0- er ~ acquired for we(I ~-~ from records, data and logs ~ ~~ ~ SPACING ; EXCEPTION ~ Tt~e permit is approved subject to futf compliaczce with 20 AAC 2~ 055 A ! ~ ! ~ . . pprova to perforate and aroduce / inject is contingent ~ I upo~ issua f ,' ~ nce o a conservation order approving a spacing ~ I exception. ' ~ liabili ofan assumes the ~ ~ ty y protest to the s pacin g e x c e p t i o n t h a t m a y o c c u r. ~ j DRY DITCH ~ ~ ~ A![ dry ditch sample sets submitted to th -E ' i SA!~IPLE ~ ~ e ommission must be in i no greater than 30' sample intecvals &om below• the pecmafirost or ' ( f ~ ~ ; ~ ~ rom where samp[es are frst ca~ght and I0' samp(e interv~ats ; ~ through tacget zones. ~ ~ ~ i` o!j Conve~tionaf j Piease note the fottowing specia! condition of thi; , ~ production or production testi f I ; ng o coa! bed methane is not atlowed ~ ~ for (ciame of well) unti( after (Cornaanv Iv'ame) has designec! and ! ~ Ij ~ ~ implemented a water well testin ro , 8 p $~m to pmvide baseline data ~ ; oa water quatity and ti ~~ ~ quan ty. (Comnanv 1Vame) must contact the i Commission to obtain advance a roval f 6 pp o suc wa[er well testing ! ~ ~~artram ~ Rev: [ 2~i06 C:~jody~trartsmittat checklist ~ ~ ~^ ~ ~ ~ ~ , ~ ~, , ~ ~ ~ ~ ~ ' ,, ~ , ~ ~, ~, ~ ~ , ~ ,, ~ ~ , rn o N N , , , , , , , , , ; , , , , o, , ~, a~ ~ , , , , , , ~, v~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ v, ~ ~ ~ ~ , ~ ~ , y~ y~ _~ , ~ ~ ~ c ~ Q ~ ~ ~ ~ o~ ~ ~ ~ ~ ~ ; ~ ; ~ ~ ~ 3; ~ ~ ~ ~ ~ ~ ~.~ E, ~~ , ~ ~ , ~ , ~ ~ ~, , ~ t, ~ , , ~ ~ , 3, ~ , ~ , ~ , ~ ~ , ~ ~ , i ~ ~ ~ ~ ~ ~ v~, a , , ~ ~ ~ ~ ~ ~ ~ c>. w -_, 3 Q ~ 3 ,~ ~ ~ , ~ ~ ~ , ~ , ~ ~ ~ ~ v, 'v o~ , , , , , o , , ~ o. ~, ~ ~ o ~ ~ Q ~ . ~ ,~~ ~ , a>, ~ , ~ , ~ ~ , ~ ~ , , ~ ~ . , ~ ~ ~ ~ , ~ , , ~ ~ ~ ~ ~ N~ ~ ~~~ ~ ~ , ~ ' N c , = N . c ~ ~~ ~~ , ~~ Q rn ~~ ~~ ~~ ~, ~~ , , , ~~ ~, ~ ~ ~~ ~~~ ~~ , ~~ ~~ , ~~ ~ a; o~ ~, ~~ ~~ ~ 0 ~ ~ 0~, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , , ~ . . ~ ~ , , , c a ., ~ ~ ~ ,~, c~ ~ fn ~ ~ .~ , c ~ ~ ~ ~ ~ ~ ~ ~ , 4 ~ oT , , , ~~ g N~ N ~ t~ O ~~ ~ ~, ~ ~ ~~ 4 t .c ~ ~ ~ , ~ ~ , , ~ ~ ~ ~ , ~ ~ ~ ~ , , ~ , j~ O, ~ ~~ a, ~ Q ,"O~ ~ ~, , ~ O. -a V~ a , ~ x, ~ , O L E O o, ~, ~ >, a~ , , ~ a ~°, °' m, O a~, Z , ~ p) N~ , ~ m~ ~" 3 , ° ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , , ~ O ~ in ' ~ ~~ ~ ~ fl. ~ ~ y~ , p~ N~ ~ i ~ ~ N ~ o (~ ~ ~ ~ a ° , , ~ , r, ~, ~ Z` ~, ~: a ~~ , v, ~ m ~ ~ ~ ~ ~ ~ ~~ ~ ~ , ~ ~ ~~ m ~ ~ ao ~ ~"'' d g o, i.~ a~~ a. ~ ~ a~ m o N, ~ ~, ~ o, , -f°o, 3 , , ~ ~ -a O C0~ , ~, ~6 N ~ ~, Y~ '~ ~ ~' `°i ~' o' ' ~ °~ ~ ai , v, . 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O ILC ~ C ~ ~ ~ O~~ T/ ~~ ~ N y ' ~ N . ~ a1 C~ E ~ ,~ E a ~ ~ a w~ a~ U ~ a a a ~ W a ~ ~ ~ a~ , ~ Well History File APPE~IDIX Information of detailed nature that is not • particula~ly geRnane to the Weli Permitting Process but is part of the history file. To irnprove the readability of the Well History file and to simpl'rfy finding information, information of this nature is accumulaied at the end of the file under APPENDIX. No special efforl has been made to chronologically organiZe this category of information. , ~ 1J122L100713200755N.tXt Sperry-Sun Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed oct 03 08:55:45 2007 Reel Header Service name ............. LISTPE ~ate . ................... 07/10/03 Ori 9in ................... 5T5 Reel Name. .... ........ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Tape Header Service name ............. LISTPE ~ate . ................... 07/10/03 Origin ................... STs Tape Name. .... ........ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Physical EOF comment rtecord TAPE HEADER west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNE55: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: writing ~ibrary. writing ~ibrary. n \J 5cientific Technical services Scientific Technical Services 1J-122 L1 500292335960 ConocoPhillips Alaska, znc. Sperry Drilling Services 02-OCT-07 MWD RUN 2 MWD RUN 3 MWD RUN 5 w-0005034903 w-0005034903 w-0005034903 P. ORTH T. GALVIN T. GALVIN G. WHITLOCK D. GLADDEN D. GLADDEN MWD RUN 6 w-0005034903 P. ORTH M. THORTON 35 11N l0E 1836 2347 Page 1 2 (~'~' -U~-( `~ !5b 3a ' ~ ~ 1J122L10071320075SN.tXt ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: $1.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 15T STRING 12.250 13.375 3640.0 2ND STRING 8.500 9.625 10827.0 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 (ND). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10827'MD/3765'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-122 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 5. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 6 ALSO INCLUDED AT-BIT GAMMA (ABG). ABG DATA WERE APPENDED TO THE DGR DATA FROM Z3922'MD TO 13955.5'MD. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5,6 REPRESENT WELL 1J-122 L1 WITH API#: 50-029-23359-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13960'M~/3824'ND. 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 Page 2 ~ SPACING). SFXE = SMOOTHED $ 1J122L1007132007SSN.tXt ~ U FORMATION EXPOSURE TIME (DEEP SPACING). File Header Service name... .......STSLIB.001 service sub ~evel Name... version Number. ........1.0.0 ~ate of Generation.......07/10/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped DEPTH INCREMENT: .5000 # FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH STOP DEPTH GR 3608.5 13955.5 RPx 3630.0 13915.0 RPS 3630.0 13915.0 RPM 3630.0 13915.0 FET 3630.0 13915.0 RPD 3630.0 13915.0 ROP 3644.5 13959.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASE~INE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO MERGE TOP MERGE BASE 2 3608.5 9721.0 3 9721.0 10827.0 5 10827.5 10889.0 6 10889.0 13959.5 # REMARKS: MERGED MAIN PA55. $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing 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 Page 3 ~ • 1]122L1007132007SSN.tXt 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 3608.5 13959.5 8784 2.0703 3608.5 13959.5 RPD Mw~ OHMM 2.69 2000 24.3871 20571 3630 13915 RPM Mw~ OHMM 5.07 126.07 21.4202 20571 3630 13915 RPS Mw~ OHMM 3.81 1301.51 22.0524 20571 3630 13915 RPx MwD OHMM 1.27 431.97 22.5074 20571 3630 13915 FET MwD HOUR 0.12 201.52 1.70135 20571 3630 13915 GR Mw~ API 19 124.04 64.1522 20695 3608.5 13955.5 RoP MwD FT/H 0.17 650.36 210.237 20631 3644.5 13959.5 First Reading For Entire File..........3608.5 ~ast Reading For Entire File...........13959.5 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/03 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3608.5 9685.0 RPD 3630.0 9677.5 RPM 3630.0 9677.5 RPx 3630.0 9677.5 FET 3630.0 9677.5 RPS 3630.0 9677.5 RoP 3644.5 9721.0 Page 4 ~ ~ 1J122L10071320075SN.tXt $ # LOG HEADER DATA DATE LOGGED: 27-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9721.0 TOP LOG INTERVAL (FT): 3643.0 BOTTOM LOG INTERVAL (FT): 9721.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 69.4 MAXIMUM ANGLE: 79.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132484 EWR4 ELECTROMAG. RESIS. 4 77613 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3640.0 # BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 49.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.800 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.540 111.0 MUD FILTRATE AT MT: 5.000 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 ~ata specification Block Type.....0 Log~ing 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. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel Page 5 • . 1J122L1007132007SSN.tXt 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 3608.5 9721 6664.75 12226 3b08.5 9721 RPD MWD020 OHMM 2.69 2000 13.8095 12096 3630 9677.5 RPM MWD020 OHMM 5.07 51.95 11.6633 12096 3630 9677.5 RPS MWD020 OHMM 3.81 1301.51 11.377 12096 3630 9677.5 RPx MWD020 OHMM 1.27 45.01 9.60062 12096 3630 9677.5 FET Mw~020 HOUR 0.12 104.12 0.744482 12096 3630 9677.5 GR MwD020 ,4PI 19 118.52 63.2932 12154 3608.5 9685 ROP Mw~020 FT/H 6.45 504.03 226.4 12154 3644.5 9721 First Reading For Entire File..........3608 ~ast Reading For Entire File...........9721 File Trailer Service name... .......STSLIB.002 ServiCe Sub LeVel.Ndme... version Number. ........1.0.0 ~ate of Generation.......07/10/03 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 ~ate of Generation.......07/10/03 Maximum Physical rtecord..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: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 9678.0 RPx 9678.0 RPM 9678.0 RPS 9678.0 STOP DEPTH 10827.0 10827.0 10827.0 10827.0 Page 6 . • 1J122L1007132007SSN.tXt RPD 9678.0 10827.0 GR 9685.5 10827.0 ROP 9721.5 10827.0 $ # LOG HEADER DATA DATE LOGGED: 29-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10827.0 TOP LOG INTERVAL (FT): 9721.0 BOTTOM LOG INTERVAL (FT): 10827.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.6 MAXIMUM ANGLE: 85.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132484 EWR4 ELECTROMAG. RESIS. 4 77613 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3640.0 # BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (5): 43.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 50 FLUID LO55 (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.800 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.460 115.0 MUD FILTRATE AT MT: 5.000 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: $ # ~ata Format specification rtecord Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Page 7 ~ ~ 1J122L1007132007SSN.tXt Datum Specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9678 10827 10252.5 2299 9678 10827 RPD MwD030 OHMM 5.32 51.55 14.5322 2299 9678 10827 RPM MwD030 OHMM 5.12 60.58 14.5834 2299 9678 10827 RPS MwD030 OHMM 4.95 61.52 13.8071 2299 9678 10827 RPX MwD030 OHMM 4.54 43.45 11.4082 2299 9678 10827 FET MwD030 HOUR 0.18 31.3 1.58766 2299 9678 10827 GR MwD030 API 28.72 124.04 81.6072 2284 9685.5 10827 ROP Mw~030 FT/H 8.25 352.67 207.986 2212 9721.5 10827 First Reading For Entire File..........9678 ~ast Reading For Entire File...........10827 File Trailer Service name... .......STSLIB.003 Service Sub Level~Name... version -vumber. ........1.0.0 ~ate of Generation.......07/10/03 Maximum Physical Record..65535 File TyL~ e ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/03 Maximum Physical rtecord..65535 File Type. ............LO Previous File Name.......STS~IB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10827.5 10889.0 Page 8 ~ • 1J122L1007132007SSN.tXt $ # LOG HEADER DATA DATE LOGGED: 10-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10889.0 TOP LOG INTERVAL (FT): 10827.0 BOTTOM LOG INTERVAL (FT): 10889.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10827.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.35 MUD VISCOSITY (S): 85.0 MUD PH: .O MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 98.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth units. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 Page 9 ~ 1J122L100713200755N.tXt • First Last Name Service unit Min Max Mean Nsam rteading Reading DEPT FT 10827.5 10889 10858.3 124 10827.5 10889 RoP Mw~050 FT/H 1.16 48.16 18.9694 124 10827.5 10889 First Reading For Entire File..........10827.5 ~ast Reading For Entire File...........10889 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version ivumber. ........1.0.0 Date of Generation.......07/10/03 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.005 PhySiCdl EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation,......07/10/03 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: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 10827.5 13915.0 RPD 10827.5 13915.0 GR 10827.5 13955.5 FET 10827.5 13915.0 RPM 10827.5 13915.0 RP5 10827.5 13915.0 ROP 10889.5 13959.5 $ # LOG HEADER DATA DATE LOGGED: 13-JUL-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13960.0 TOP LOG INTERVAL (FT): 10889.0 BOTfOM LOG INTERVAL (FT): 13960.0 Page 10 ~ . 1J122L1007132007SSN.tXt BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 80.5 MAXIMUM ANGLE: 94.6 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10827.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 115.0 MUD PH: .O MUD CHLORIDES (PPM): 19750 FLUID LOSS (C3): 5.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERM PERATURE: .000 136.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ......... .0 Data Specification Block Type.... .0 Log~ing Direction ................ .DOwn Optical log depth units.......... .Feet ~ata Reference Point ............. .undefined Frame Spacing....... ........... .60 .1zN 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 MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 Page 11 ~ • 1J122L1007132007SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10827.5 13959.5 12393.5 6265 10827.5 13959.5 RPD MWD060 OHMM 10.27 155.32 48.7723 6176 10827.5 13915 RPM MWD060 OHMM 9.19 126.07 43.0747 6176 10827.5 13915 RPS MWD060 OHMM 9.25 183.75 46.03 6176 10827.5 13915 RPx MWD060 OHMM 8.35 431.97 51.9175 6176 10827.5 13915 FET MwD060 HOUR 0.14 201.52 3.61775 6176 10827.5 13915 GR MwD060 API 37.05 106.41 59.4491 6257 10827.5 13955.5 ROP MwD060 FT/H 0.17 650.36 182.922 6141 10889.5 13959.5 First Reading For Entire File..........10827.5 ~ast Reading For Entire File...........13959.5 File Trailer Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE ~ate . ...................07/10/03 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE ~ate . ...................07/10/03 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comment5 .................STS LIS Writing Physical EOF Physical EOF End Of LIS File ~ibrary. scientific Technical services ~ibrary. 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