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207-029
Image ~ject Well Hist®ry File Cc~r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~- ~ ~ Well History File Identifier Organizing (done) ,~~„a uiuumuiiiui o R„u~~e~~ iuuiiiuiiuui RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: iskettes, 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/ ~ Pro "ect Proofing II I II ~I II I I III I I III BY: Maria Date: ~ /s/ ' ~ i ~ x 30 = + ~ ~1~' =TOTAL PAGES on Scanning Preparat ~ (Count does not include cover sheet) ~ ^ BY: Maria ,., C Date: lL~ l C ~ ~ , j (.~ ~ _ lsl r ~ 1 Production Scanning ""' •"""" Stage 1 Page Count from Scanned File: ~ ~ (Count does include co er sheet) nt Matches Number in Scannin Preparation: 1~ YES NO Page Cou 9 BY: Maria Date: ~ ~ ~~~ /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II ~I II I II N I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III 10/6/2005 Well History File Cover Page.doc r: ~~~ ~ } ;~, .. ""' ^ ; MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 1 1 `u"~. DATA SUBMITTAL COMPLIANCE REPORT 5/712009 Permit to Drill 2070290 Well Name/No. KUPARUK RIV U WSAK 1J-105L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-(029~-233i4~6-61-00 MD 11383 TVD 3596 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1WINJ 1~'/~ REQUIRED INFORMATION _ __ _ __ _ __ '~ _ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res/USIT Well Log Information: Log/ Electr Data Digital Dataset Ty.~e Med/Frmt Number Name EDD D Asc Directional Survey ±iED C Lis 15317 Gamma Ray I~ Rpt 15317 ~ Verification ED C 17919 See Notes Log Induction/Resistivity og Induction/Resistivity i Well Cores/Samples Information: Name Directional Survey (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 7346 11383 Open 8/2/2007 3351 11383 Open 8/3/2007 LIS Veri, GR, ROP, FET Interval Start Stop ADDITIONAL INFORMATION Well Cored? Chips Received? ,_Y-1-AY Analysis .Y.LPI~- Received? __ _ _ _ _ _ _ _ _ _ _ w/Graphics 3351 11383 Open 8/3/2007 LIS Veri, GR, ROP, FET 0 0 4/23/2009 EWR Logs in PDS, EMF '~ and CGm graphics 25 Col 108 3596 Case 4/23/2009 MD DGR, EWR 29-Apr- j 2007 !, 25 Col 108 3596 Case 4/23/2009 TVD DGR, EWR 29-Apr- 2007 Sent Received Daily History Received? Formation Tops Sample Set Number Comments V (~jl'N DATA SUBMITTAL COMPLIANCE REPORT 5/712009 Permit to Drill 2070290 Well Name/No. KUPARUK RIV U WSAK 1J-105L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23346-61-00 MD 11383 ND 3596 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y Comments: ~ ~ Compliance Reviewed By: _ - _ - _ Date: ~~ C1.i'wL- _~'~~lJ ~ ~~E~L LDG TRA1~1~1~~I~'TAL Tea 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: 1 J-105+L 1 +L2+pB 1 April 7, 2009 AK-MW-4912996 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling , 6900 Arctic Blvd., Anchorage, AK 99518 1.T-105+L1+L2+pBl 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-23346-00,60,61,70 g 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-23346-00,60,61,70 g Digital Log Images 1 CD Rom 50-029-23346-00,60,61, 70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 B BP Exploration (Alaska} Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 1 ~~ l "~- ~ ~~~ t ~L°r ~`~ r5'an.Burln~~.:.i4}„1711'~'on.~~iii ~/~- 'L CfU ~ '~ V • ! , 1' ~ )a.tc: Signed. s ~~~.~ ;.~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180 - -o Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPFi DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, iJ-127, 1J-164, 1J-180 Tom ; Jim, The LPPISSN's on all of the West Salc DS1 E and DS1J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I ~niasn't sure if you ~Nanted the permit io drill number for the mainbore only or the laterals as .Nell so I included both. VlIELL ID Permit to Drill No. 1E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2) 1J-102 206-110 (MAINBORE}, 206-111 (L1), 206-'112 (L2) ~1J-105 207-027 (IVIAINBORE), 207-028 (L1 ), 207-029 (L2) 1J-127 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2} 1J-160 207-015 (MAiNBORE}, 207-016 (L1), 207-0'17 (L2) 1J-164 205-144 (MAINBORE}, 205-145 (L1}, 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7!9!2007), Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK West Sal< Production Engineer ConocoPhillips Alaska, inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 WELL LOG TRANSMITTAL To: State of Alaska July 2, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Lo~~ 1J-118 L2 ~' AK-MW-4912996 •--DWG formatted CD ~ erification listing. API#: 50-029-23346-b 1 `? ~~~ ~- f~P= 'w ~o ~ v~.a.w~ a -- ; ~o u l c~ (,o e L ~ -- `US ~. o~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~: :8 9 _S.3 - - - ~ i:::. Date: ~~~~ ~OG7 Signed: ai"vi V z ~ ao~ -~ ~ ~S3 0 ~- • 17-Jul-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-105L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,346.78' MD Window /Kickoff Survey 7,348.00' MD (if applicable) Projected Survey: 11,383.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518. ~____~ Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~?- c~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~((~~ ~ ~ , REPORT OF SUNDRY WELL OPERATIONSIar ~~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ ~ ° r~~-P~o~,N~~~~ Stimulate ^ {Other A ~ [ j Ail Alter Casing. ^ Pull Tubing ^ Perforate New Pool ^ S V Waiver ^ Time Extension ~~: Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, lnC. Development ^ Exploratory ^ 207-029 ~ 3. Address: Strati ra hic g p ^ Service ~ ^ 6. APt Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23346-61 '~ 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' < 1J-105L2 8. Property Designation: 10. Field/Pool(s): ALD 25661 & 25662 ~ Kuparuk River Fieid /West Sak Oil Pool - 11. Present Well Condition Summary: Total Depth measured 11383' feet .true vertical 3596' ~ feet Plugs (measured) Effective Depth measured 11364 feet Junk (measured) true vertical 3596 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 80' 80' SURFACE 3278' 10-3/4" 3387 2255' WINDOW L2 1' 7-5/8" 7349' 3645' PRODUCTION 8729' 7-5/8" 8838' 3820' D-SAND SLOTTED LINER 3736' 4-1 /2" 11364' 3596' Perforation depth: Measured depth: 7628' - 11319' true vertical depth: 3647 - 3595' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7324' MD . Packers &SSSV (type & measured depth) PKR = LEM ZXP Liner top pkr PKR = 7288' SSSV= NIP SSSV= 493' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~ ~FL, ~~~. 2 ~ 2~~7 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 838 328 28 932 202 Subsequent to operation 2014 1204 -3 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: 307-188 contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~ c~ r ~~ r Phone. 659-7535 Date ~~~~~~ ~P v u K 1 ~ I NA ~r~~~•~ ~~L~-,~ ?',~:~~ Form 10-404 Revised 04/2004 Submit Original Only: 1J-1Q~L~ ~~~CRl~ i !a~! ®F WQRK C~P~~~~ i F~ ~l7F~il~lAE2Y Dafe Event Summary Q7l06/07 Commenced. Water Injection o ~ ~ ~ o SARAH PALIN, GOVERNOR L>V1[a-7~ OIIt ~ ~5 333 W. 7th AVENUE, SUITE 100 CO1Q5~RQA~'IO1~T COrLDi155IO1Q l ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105L2 Sundry Number: 307-188 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~gday of June, 2007 Encl. ~0~-~-9 Sincerely, s C~v.3' ~~~~ ~ - ~-~• ~ E~EIVED 17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION li ~ JUN O ~ 2007 APPLICATION FOR SUNDRY APPROVA~aska oil & Gas Cons. Commission 20 AAC 25.280 „__~__ _ _ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Producer to Injector °" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 207-029 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23346-61 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ~ 1J-105L2 9. Property Designation: j,5'G~e ~ ( ~ 10. KB Elevation (ft): 11. Field/Pool(s): , Kuparuk River Unit /Q'p ~- Zs6L 2 /' G •~so7 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 (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11383' 3596' 11364' 3596' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 80' 80' SURFACE 3278' 10-3/4" 3387' 2255' WINDOW L2 1' 7-5/8" 7349' 3645' PRODUCTION 8729' 7.5/8" 8838' 3820' D-SAND SLOTTED LINER 3736' 4-1/2" 11364' 3596' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 71328' -11319' 31347' - 3595' 4-1 /2" L-80 7324' Packers and SSSV Type: Packers and SSSV MD (ft) PKR = LEM ZXP Liner top pkr PKR = 7288' SSSV=NIP SSSV= 493' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 25, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name ert D. C tensen Title: Production Engineering Technician Signature ~ Phone 659-7535 Date i9 ~„ g Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ 8~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ W Other: Qt ,O PAS 1. ~--GLC.._O G_ _ 'T1 ~V d- ~ BF(~ SUN ~ 9 ?OD7 Subsequent Form Required: ~® APPROVED BY Approved by: MIS IONER THE COMMISSION Date: Form 10-403 Revised 06/2006 1 1 E{ J/~ -jy-~- L1 1 Submit in Duplicate • ConocoPhillips June 1, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 70' Ave. Ste. 100 Anchorage, AK 99501 Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (90'n 659-7535 Fax: 659-7314 ~~~~~~ Jug 0 5 ~aa Alaska Oil & Gas Cans. Camm+'ss~a~4 Anchorage Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk West Sak wells 1J- 105, 1J-1O5L1, and 1J-1O5L2 from Oil Production to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 1J-105 (PTD 207-027), 1J-1O5L1 (PTD 207-028), and 1J-1O5L2 (PTD 207-029). If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, Robert D. Christensen Attachments • 1J-105L2 DESCRIPTION SUMMARY OF PROPOSAL t~ ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-105L2. This well has been pre-produced for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1 J-105L2 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (3387' and / 2254' tvd) was cemented with 600 sx AS Lite followed by 198 sx LiteCRETE. The 7-5/8" Intermediate casing (8838' and / 3820' tvd) was cemented with 480 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand LEM ZXP 4- 1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7288' and / 3635' tvd, Upper B sand LEM ZXP 4-1 /2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7465' and / 3662' tvd, and an Upper A sand HRD ZXP 4-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7820' and / 3719' tvd. The top of West Sak D sand was found at 7348' and / 3645' tvd. D sand Lateral window top is located @ 7348' and / 3645' tvd. The top of West Sak B sand was found at 7704' and / 3700' tvd. B sand Lateral window top is located @ 7707' and / 3701' tvd. The top of West Sak A sand was found at 7894' and / 3730' tvd. • • KRU 1J-105L2 ConocoPhillips Alaska, Inc. Lam.. DA_ ..asi--g rl~~~ Shoe. ~s~5~~ ~ 3~~~ 1V~J; ~J. t-~t~ ?~ ~~ ~'Tv~ ___~a_. Shoe. '~ ~`.%i, _C~ ~.~ 'iJ -~~-- 5 yyla ?2CKeT 1~5'~~ TV1'~, Cer ~t ~~~~~ o ~ _ S_~e ct~`~ and e_rs ~~~ Lo rl,'~j~.~ ~~ui~~ R'lC~~ --r:;~uius ?ress Test. _? 15 min ~Q min Comments . i '~"CHf~NIC~ ~ . 1NTEGRI'r r _ PART ~ 2 ~tCa 3-,~-~ = l~ ~ ~~`5 Cement Voles: Amt. liner Csg ~-~@~S~ DV ~~ C,~t -JOI to cover oers 5~lbb\s ~a-`t~1S~~~ri~`\to~~~~--v~1r~ .~SOC~c ~ 3~~o x S ~' ~eoretical TOC C3~~c~kS \ ~C. ^-J~O~~ _ _ Cement Bond Log (Yes or No) ~\LS In AOGCC File ~~S C3L evaluation, gone aDOVe perfs ~~ ~p~~~~ ~~ ~: ~~~ ~ ~~~ \c~~ Production Log: Type CONCLJS~ONS: i 1 ~ , j ? al t j ~a.it rL ~ ~S ~ ~~~~~s ~ Bvalt;ation ConocoPhillips May 21, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-105, 1J-105L1, 1J-105L2 Dear Commissioner: 1 ~~.J4~~P[.._.~~1 P,~,';Y` ;~ ~ 2001 ~ltl5n~ ;)ii ~~ t«~s Crttts. Commission Alictlo~ ape ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1 J-105, 1 J-105L1, 1 J- 105L2. 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 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ ~iAY ~ ~ ZQ07 WELL COMPLETION OR RECOMPLETION REPORT~~~~I~ rrs. CommissioCt 1a. WeII Status: Oil ^ .Gas Plugged Abandoned ^ Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: ;t1G Development a Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: April 29, 2007 l 12. Permit to Drill Number: 207-029 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded:Ar,~~ Z1~ 20©'7 1, 2007 5.2S• 13. API Number: 50-029-23346-61 4a. Location of Well (Governmental Section): Surface: 2186' FSL, 2432' FEL, Sec. 35, T11N, R10E, UM ~' 7. Date TD Reached: April 24, 2007 14. Well Name and Number: 1J-105L2 - Top of Productive Horizon: 1855' FSL, 1940' FWL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): 109' AMSL Ground (ft MSL): 81' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2176' FNL, 1901' FWL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 11364' MD ! 3596' ND West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 558776 ~ y- 5945998 Zone- 4 10. Total Depth (MD + ND): 11383' MD / 3596' TVD 16. Property Designation: 25661, 25662 TPI: x- 563150 y- 5945702 Zone- 4 Total Depth: x- 563147 - 5941672 Zone- 4 11. SSSV Depth (MD + ND): nipple @ 423' 17. Land Use Permit: 471, 2177 1 S. 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): 1514' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~ ' '7'3~$ h1D/ ~~ ~Y~ GR/Res/USIT S • 2S',e7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE NTI AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEME NG RECORD PULLED 20" X 34" 78.6# H-40 28' 108' 28' 108' 42" 36o sx AS 1 - 10.75" 45.5# L-80 28' 3387' 28' 2254' 13.5" 600 sx AS Lite, 198 sx DeepCRETE 7.625" 29.7# L-80 28' 8838' 28' 3820' 9.875" 4t3o sx DeepCRETE 4.5" (LEM) 12.6# L-80 7288' 7495' 3635' 3651' 6.75" blank liner 4.5" (HOOK) 11.6# L-80 7343' 7612' 3644' 3648' 6.75" blank liner 5.5" x 4.5" 11.6# L-80 7561' 11364' 3648' 3596' 6.75" slotted and blank liner 23. Open fo production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top 8 Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 7324' 7288', 7505' refer to slotted liner attached ` 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production May 11, 2007 Method of Operation (Flowing, gas lift, etc.) pre-producing injector-shares production with 1J-105 and 1J-105L1 Date of Test 5/14/2007 Hours Tested 8 hours Production for Test Period --> OIL-BBL 676 GAS-MCF 847 WATER-BBL 21 CHOKE SIZE 40 Bean GAS-OIL RATIO 1342 Flow Tubing press. 348 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1931 ~ GAS-MCF 2592 WATER-BBL 62 OIL GRAVITY -API (c:orr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~_~.. V ;~ not applicable '~ 1tFt~II;II_D ~ _...._~..,»..~.,...1_..., Form 10-407 Revised 2/2007 CONTINUED ON REVERSE S i S I~FI~ JuN ~ ~ 1UO7 ~-~ j, 28. GEOLOGIC MARKERS (List all formations and ma rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes / No If yes, list intervals and formations tested, Permafrost -Top Surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1651' 1514' needed, and submit detailed test information per 20 AAC 25.071. T3 3387' 2255' K15 3387' 2255' Ugnu C 5426' 3020' Ugnu B 5935' 3210' Ugnu A 6142' 3290' K13 6764' 3519' West Sak D 7348' 3645' West Sak C 11383' 3596' West Sak B 11383' 3596' West Sak A4 11383' 3596' N/A West Sak A3 11383' 3596' West Sak A2 11383' 3596' Formation at total depth: Kuparuk D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed N~ Ran hom Title: Drillino Team Leader ? Si ~~-~-~ D t ~ ~Z r ~~ ~ 3 gnature -o ~ e a Z -( ~ ~ ~. u INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: lowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of inte als cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical boratory information required by 20 AAC 25.071. Item 29: Provide a list of interva tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory infor ation required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report Company: ConocoPhillips Alaska Mc . Date: 5/27/2007 Time_ 10:55:56 YaRe~ 1 Field: Kuparuk River Unit '' Co-ordinate(NE) Reference: Well: 1J-105, Tru e North Site: Kuparuk 1J Pad Ver tical(TVD) Re ference: 1J-105L2: 109A WeIL• 1J-105 Sect5on(VS)Reference: Well (O.OON,O.OO E,180:QOAzi) Wellpath: 1J-105L2 Survey Calculation Method: Minimum Curvature I)h: Oracfe '. Field: Kuparuk River Unit North Slope Alaska United States ~, Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ' Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre !~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ', WeII: 1J-105--_-- -- Slot Name: I Well Position: +N/-S 79.11 ft Northing: 5945998.64 ft Latitude: 70 15 47.036 N ~ +E/-W -13.17 ft Easti ng : 558776.16 ft Longitude: 149 31 29.390 W I, Position Uncertainty: 0.00 ft Wellpath: 1J-105L2 Drilled From: 1J-105 500292334661 ~ Tie-on Depth: 7346.78 ft i Current Datum: 1 J-105L2: Height 109.00 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 3/18!2007 Declination: 23.58 deg Field Strength: 57620 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) ft I +N/-S ft __..- ---- +E/-W ft ---------- Direction deg - 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpa th Date: 5/17/2007 Validated: No Ve rsion: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 826.00 1 J-105P61 gyro (50 .00-826.00) CB-GYRO-SS Camera based gyro single shot 857.82 7061.58 1J-105P61 (857.82- 7347.33) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7071.00 7346.78 1J-105 (7071.00-11695.87) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC it 7348.00 11310.64 1J-105L2 (7348.00-11310.64) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ NID Inc! Azim TVD tivs TVD N/S E/W 111apN MapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945998.64 558776.16 TIE LINE 50.00 0.16 53.62 50.00 -59.00 0.02 0.02 5945998.66 558776.18 CB-GYRO-SS 100.00 0.30 141.62 100.00 -9.00 -0.04 0.16 5945998.60 558776.32 CB-GYRO-SS 171.00 0.36 41.63 171.00 62.00 -0.02 0.43 5945998.62 558776.59 CB-GYRO-SS 264.00 0.56 58.53 264.00 155.00 0.43 1.01 5945999.08 558777.16 CB-GYRO-SS 354.00 2.43 40.52 353.96 244.96 2.11 2.62 5946000.77 558778.77 CB-GYRO-SS 445.00 5.63 40.67 444.72 335.72 6.97 6.79 5946005.66 558782.89 CB-GYRO-SS 537.00 8.19 47.34 536.05 427.05 14.83 14.55 5946013.58 558790.59 CB-GYRO-SS ~, 629.00 10.54 48.84 626.82 517.82 24.81 25.70 5946023.65 558801.67 CB-GYRO-SS 656.00 11.03 48.60 653.34 544.34 28.15 29.50 5946027.01 558805.44 CB-GYRO-SS 731.00 13.44 44.36 726.63 617.63 39.12 40.98 5946038.08 558816.83 CB-GYRO-SS 826.00 17.70 47.21 818.13 709.13 56.84 59.30 5946055.93 558835.01 CB-GYRO-SS 857.82 17.28 47.55 848.48 739.48 63.31 66.34 5946062.46 558842.00 MWD+IFR-AK-CAZ-SC 954.15 20.32 51.42 939.66 830.66 83.40 89.98 5946082.74 558865.48 MWD+IFR-AK-CAZ-SC 992.72 21.50 53.16 975.69 866.69 91.82 100.87 5946091.23 558876.30 MWD+IFR-AK-CAZ-SC 1049.19 23.94 55.41 1027.77 918.77 104.53 118.59 5946104.08 558893.92 MWD+IFR-AK-CAZ-SC 1143.69 27.32 56.79 1112.97 1003.97 127.30 152.53 5946127.11 558927.67 MWD+IFR-AK-CAZ-SC 1183.40 27.88 56.24 1148.16 1039.16 137.45 167.87 5946137.38 558942.93 MWD+IFR-AK-CAZ-SC j 1239.22 29.39 56.68 1197.15 1088.15 152.23 190.17 5946152.33 558965.11 MWD+IFR-AK-CAZ-SC 1282.82 30.20 56.72 1234.98 1125.98 164.12 208.27 5946164.37 558983.13 MWD+IFR-AK-CAZ-SC 1378.63 36.29 57.82 1315.08 1206.08 1.92.47 252.46 5946193.06 559027.08 MWD+IFR-AK-CAZ-SC 1429.96 38.83 58.54 1355.76 1246.76 208.96 279.05 5946209.75 559053.54 MWD+IFR-AK-CAZ-SC 1478.00 40.28 57.98 1392.80 1283.80 225.06 305.06 5946226.05 559079.43 MWD+IFR-AK-CAZ-SC 1525.94 40.22 57.52 1429.39 1320.39 241.59 331.26 5946242.78 559105.49 MWD+IFR-AK-CAZ-SC 1582.89 42.42 56.42 1472.16 1363.16 262.09 362.78 5946263.53 559136.84 MWD+IFR-AK-CAZ-SC 1620.06 44.49 55.67 1499.14 1390.14 276.37 383.98 5946277.97 559157.93 MWD+IFR-AK-CAZ-SC ~ 1669.60 46.18 55.43 1533.96 1424.96 296.30 413.03 5946298.13 559186.83 MWD+IFR-AK-CAZ-SC I Halliburton Company Survey Report __ __ _ _ __ ' Company: ConocoPhillips Alaska Inc. Date: 5/17/2007 Time: 10:55:56 P:,~,e: 2 ', Field: Kuparuk River Unit Co-ordiuate(NEpRefercnec: WeII: 1J-105, True North Site: Kuparuk 1J Pad Vertical (TVD)Referencr. 1J-105L2: 109.0 R'ell: 1J-105 Section (VS)Refereuce: Well (O.OON,O.OOE,180.OOAzi) R'ellpath: 1J-105L2 Survey Calculation Method:. Minimum Curvature Uh: Orade Survey' __ _ -- - - - MD Incl Azim TVD S~,'f~D :v/S E/~ti' ~IapN MapF, fool ', ft deg deg ft ft ft ft ft ft 1715.45 48.80 55.59 1564.94 1455.94 315.44 440.89 5946317.48 559214.53 MWD+IFR-AK-CAZ-SC ~ 1756.82 51.18 55.32 1591.54 1482.54 333.40 466.98 5946335.65 559240.48 MWD+IFR-AK-CAZ-SC j 1809.45 51.26 56.92 1624.50 1515.50 356.27 501.04 5946358.78 559274.36 MWD+IFR-AK-CAZ-SC 1877.54 54.55 57.79 1665.57 1556.57 385.56 546.77 5946388.42 559319.85 MWD+IFR-AK-CAZ-SC I 1904.90 56.10 57.96 1681.13 1572.13 397.52 565.83 5946400.53 559338.81 MWD+IFR-AK-CAZ-SC 1955.07 55.90 57.63 1709.19 1600.19 419.69 601.02 5946422.97 559373.83 MWD+IFR-AK-CAZ-SC I 2000.46 57.26 56.55 1734.19 1625.19 440.28 632.82 5946443.80 559405.47 MWD+IFR-AK-CAZ-SC 2035.72 58.97 55.94 1752.81 1643.81 456.91 657.72 5946460.63 559430.23 MWD+IFR-AK-CAZ-SC 2094.86 62.29 57.36 1781.81 1672.81 485.23 700.77 5946489.28 559473.05 MWD+IFR-AK-CAZ-SC 2160.94 64.27 57.76 1811.52 1702.52 516.89 750.58 5946521.32 559522.61 MWD+IFR-AK-CAZ-SC 2190.98 65.61 58.31 1824.25 1715.25 531.29 773.66 5946535.91 559545.58 MWD+IFR-AK-CAZ-SC 2255.80 68.74 56.23 1849.39 1740.39 563.60 823.90 5946568.60 559595.56 MWD+IFR-AK-CAZ-SC 2284.90 69.79 56.29 1859.69 1750.69 578.72 846.54 5946583.89 559618.07 MWD+IFR-AK-CAZ-SC 2329.52 69.74 56.72 1875.13 1766.13 601.82 881.45 5946607.27 559652.80 MWD+IFR-AK-CAZ-SC 2379.75 69.84 56.48 1892.48 1783.48 627.77 920.80 5946633.52 559691.94 MWD+IFR-AK-CAZ-SC 2427.93 69.71 53.78 1909.14 1800.14 653.61 957.89 5946659.65 559728.83 MWD+IFR-AK-CAZ-SC 2475.69 69.43 53.96 1925.81 1816.81 680.00 994.04 5946686.31 559764.76 MWD+IFR-AK-CAZ-SC 2573.07 69.07 55.90 1960.31 1851.31 732.32 1068.56 5946739.21 559838.87 MWD+IFR-AK-CAZ-SC 2668.62 69.00 55.97 1994.50 1885.50 782.30 1142.48 5946789.76 559912.39 MWD+IFR-AK-CAZ-SC 2761.03 69.27 56.63 2027.41 1918.41 830.21 1214.32 5946838.22 559983.84 MWD+IFR-AK-CAZ-SC 2857.69 69.10 57.13 2061.76 1952.76 879.58 1289.99 5946888.18 560059.12 MWD+IFR-AK-CAZ-SC 2951.99 70.36 58.28 2094.43 1985.43 926.84 1364.76 5946936.01 560133.51 MWD+IFR-AK-CAZ-SC 3047.78 68.99 55.48 2127.71 2018.71 975.90 1439.99 5946985.66 560208.35 MWD+IFR-AK-CAZ-SC i 3141.74 67.32 56.57 2162.67 2053.67 1024.64 1512.31 5947034.95 560280.28 MWD+IFR-AK-CAZ-SC 3237.01 67.55 56.57 2199.23 2090.23 1073.11 1585.73 5947083.99 560353.31 MWD+IFR-AK-CAZ-SC j 3345.45 69.14 58.63 2239.25 2130.25 1127.10 1670.82 5947138.64 560437.97 MWD+IFR-AK-CAZ-SC ~ ' 3442.21 65.71 59.55 2276.39 2167.39 1172.99 1747.46 5947185.13 560514.24 MWD+IFR-AK-CAZ-SC ', 3537.73 65.96 61.45 2315.49 2206.49 1215.90 1823.31 5947228.62 560589.75 MWD+IFR-AK-CAZ-SC ~ !I 3596.12 65.22 64.10 2339.63 2230.63 1240.23 1870.58 5947253.31 560636.82 MWD+IFR-AK-CAZ-SC I 3633.41 65.88 65.30 2355.06 2246.06 1254.74 1901.27 5947268.06 560667.40 MWD+IFR-AK-CAZ-SC I I, 3669.03 67.11 65.93 2369.27 2260.27 1268.22 1931.02 5947281.77 560697.04 MWD+IFR-AK-CAZ-SC I 3728.04 67.16 66.18 2392.20 2283.20 1290.29 1980.71 5947304.22 560746.55 MWD+IFR-AK-CAZ-SC I~ 3777.68 67.17 68.01 2411.46 2302.46 1308.09 2022.85 5947322.36 560788.55 MWD+IFR-AK-CAZ-SC 3825.12 68.49 69.59 2429.37 2320.37 1323.98 2063.81 5947338.56 560829.38 MWD+IFR-AK-CAZ-SC 3918.86 68.09 74.35 2464.06 2355.06 1350.93 2146.59 5947366.15 560911.94 MWD+IFR-AK-CAZ-SC 4014.42 67.11 75.39 2500.47 2391.47 1373.99 2231.88 5947389.88 560997.03 MWD+IFR-AK-CAZ-SC 4110.62 67.51 80.06 2537.60 2428.60 1392.85 2318.57 5947409.41 561083.57 MWD IFR-AK-CAZ-SC 4205.78 68.38 84.20 2573.35 2464.35 1404.91 2405.91 5947422.15 561170.80 MWD+IFR-AK-CAZ-SC 4300.80 67.45 87.10 2609.08 2500.08 1411.59 2493.70 5947429.52 561258.52 MWD+IFR-AK-CAZ-SC 4395.43 68.23 92.41 2644.79 2535.79 1411.96 2581.29 5947430.57 561346.11 MWD+IFR-AK-CAZ-SC 4493.63 67.18 94.70 2682.05 2573.05 1406.33 2671.97 5947425.65 561436.81 MWD+IFR-AK-CAZ-SC 4588.36 68.50 96.34 2717.78 2608.78 1397.89 2759.29 5947417.89 561524.19 MWD+IFR-AK-CAZ-SC 4683.41 67.55 95.81 2753.35 2644.35 1388.56 2846.94 5947409.24 561611.90 MWD+IFR-AK-CAZ-SC ~ 4779.17 68.30 99.82 2789.35 2680.35 1376.49 2934.83 5947397.86 561699.87 MWD+IFR-AK-CAZ-SC i 4872.63 69.50 104.99 2823.02 2714.02 1357.75 3019.94 5947379.79 561785.12 MWD+IFR-AK-CAZ-SC i ' 4968.32 69.06 108.17 2856.88 2747.88 1332.22 3105.71 5947354.93 561871.08 MWD+IFR-AK-CAZ-SC 5065.43 69.07 110.92 2891.58 2782.58 1301.88 3191.17 5947325.26 561956.77 MWD+IFR-AK-CAZ-SC 5159.58 69.81 114.32 2924.66 2815.66 1267.97 3272.53 5947291.99 562038.38 MWD+IFR-AK-CAZ-SC ~! 5255.69 69.23 114.40 2958.28 2849.28 1230.84 3354.55 5947255.50 562120.68 MWD+IFR-AK-CAZ-SC 5349.24 68.78 115.10 2991.80 2882.80 1194.27 3433.86 5947219.56 562200.27 MWD+IFR-AK-CAZ-SC I 5444.91 68.27 118.24 3026.83 2917.83 1154.32 3513.41 5947180.24 562280.11 MWD+IFR-AK-CAZ-SC 5539.50 68.35 121.32 3061.80 2952.80 1110.67 3589.68 5947137.19 562356.72 MWD+IFR-AK-CAZ-SC 5634.92 68.64 124.68 3096.79 2987.79 1062.33 3664.12 5947089.43 562431.53 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc Usrte. .5/17/2007 Time: 10'55:56 Pa~c: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-105, True North Sitc: Kuparuk 1J Pad Vertiral(TVD)Reference: 1J-105L2:109.0 Well: 1J-105 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzI) ', Wellpath: 1J-105L2 Survey Calculation Method: Minimum Curvature D6: Oracle Suns. ~V D Incl Azim TVD Svs TVD ~/S E,~lv D1apIV MapE ~ Tool ft deg deg ft ft ft ft ft ft 5729. 60 67. 81 128 .24 3131.92 3022. 92 1010 .10 3734 .83 5947037. 76 562502. 63 MWD+IFR-AK-CAZ-SC 5821. 68 68. 00 131 .77 3166.56 3057 .56 955 .26 3800 .16 5946983. 44 562568. 39 MWD+IFR-AK-CAZ-SC 5917. 84 67. 17 133 .65 3203.23 3094 .23 894 .97 3865 .48 5946923. 67 562634. 17 MWD+IFR-AK-CAZ-SC 6013. 13 67. 29 136 .78 3240.12 3131 .12 832 .62 3927 .37 5946861. 81 562696. 53 MWD+IFR-AK-CAZ-SC 6107. 84 66. 97 139 .97 3276.94 3167 .94 767 .40 3985 .33 5946797. 05 562754. 99 MWD+IFR-AK-CAZ-SC i ~' 6204. 07 66. 40 144 .53 3315.04 3206 .04 697 .55 4039 .42 5946727. 63 562809. 62 MWD+IFR-AK-CAZ-SC 6298. 64 67. 96 148 .24 3351.73 3242. 73 624 .97 4087 .65 5946655. 44 562858. 41 MWD+IFR-AK-CAZ-SC 6392. 55 68. 51 151 .67 3386.56 3277. 56 549 .49 4131 .30 5946580. 30 562902. 65 MWD+IFR-AK-CAZ-SC 6487. 79 68. 90 155 .54 3421.16 3312. 16 470 .02 4170 .74 5946501. 15 562942. 70 MWD+IFR-AK-CAZ-SC ' 6583. 62 68. 87 159 .34 3455.69 3346. 69 387 .48 4205 .03 5946418. 90 562977. 63 MWD+IFR-AK-CAZ-SC i ~', 6680. 00 68. 68 161 .33 3490.59 3381. 59 302 .89 4235 .26 5946334. 55 563008. 52 MWD+IFR-AK-CAZ-SC 6775. 36 72. 18 163 .40 3522.53 3413 .53 217 .27 4262 .46 5946249. 15 563036. 38 MWD+IFR-AK-CAZ-SC 'i 6870. 19 76. 19 165 .88 3548.37 3439. 37 129 .31 4286 .60 5946161. 39 563061. 21 MWD+IFR-AK-CAZ-SC 6965. 40 76. 34 167 .67 3570.98 3461. 98 39 .28 4307 .76 5946071. 54 563083. 06 MWD+IFR-AK-CAZ-SC 7061. 58 78. 85 169 .66 3591.64 3482 .64 -52 .81 4326 .21 5945979. 60 563102. 23 MWD+IFR-AK-CAZ-SC 7071. 00 79. 11 168 .78 3593.44 3484 .44 -61 .89 4327 .94 5945970. 53 563104. 03 MWO+IFR-AK-CAZ-SC 7110. 68 79. 31 169 .89 3600.87 3491 .87 -100 .20 4335 .15 5945932. 29 563111. 54 MWD+IFR-AK-CAZ-SC 7159. 39 79. 06 171 .55 3610.01 3501 .01 -147 .42 4342 .87 5945885. 14 563119. 63 MWD+IFR-AK-CAZ-SC 7209. 25 78. 47 171 .25 3619.72 3510 .72 -195 .77 4350 .18 5945836. 85 563127. 32 MWD+IFR-AK-CAZ-SC 7252. 45 77. 54 170 .59 3628.70 3519 .70 -237 .50 4356 .85 5945795. 18 563134. 31 MWD+IFR-AK-CAZ-SC 7346. 78 82. 54 171 .74 3645.01 3536 .01 -329 .27 4371 .10 5945703. 53 563149. 28 MWD+IFR-AK-CAZ-SC 7348. 00 82. 53 171 .73 3645.17 3536 .17 -330 .47 4371 .28 5945702. 33 563149. 46 MWD+IFR-AK-CAZ-SC 7380. 09 85. 21 172 .60 3648.60 3539 .60 -362 .08 4375 .63 5945670. 76 563154. 06 MWD+IFR-AK-CAZ-SC 7439. 58 88. 66 174 .20 3651.78 3542 .78 -421 .08 4382 .45 5945611. 82 563161. 34 MWD+IFR-AK-CAZ-SC 7489. 79 92. 68 175 .55 3651.19 3542 .19 -471 .07 4386 .94 5945561. 87 563166. 22 MWD+IFR-AK-CAZ-SC 7582. 23 91. 63 178 .03 3647.72 3538 .72 -563 .29 4392 .11 5945469. 70 563172. 11 MWD+IFR-AK-CAZ-SC 7671. 47 91. 31 180 .37 3645.43 3536 .43 -652 .49 4393 .35 5945380. 53 563174. 05 MWD+IFR-AK-CAZ-SC 7763. 06 92. 77 181 .41 3642.17 3533 .17 -744 .00 4391 .93 5945289. 01 563173. 34 MWD+IFR-AK-CAZ-SC 7853. 76 91. 35 180 .85 3638.90 3529 .90 -834 .63 4390 .14 5945198. 39 563172. 26 MWD+IFR-AK-CAZ-SC 7893. 15 91. 41 181 .07 3637.96 3528 .96 -874 .00 4389 .48 5945159. 01 563171. 91 MWD+IFR-AK-CAZ-SC 7945. 03 93. 02 181 .08 3635.95 3526 .95 -925 .83 4388 .51 5945107. 18 563171. 34 MWD+IFR-AK-CAZ-SC 7984. 05 93. 33 181 .95 3633.79 3524 .79 964 - .78 4387 .48 5945068. 23 563170. 62 MWD IFR AK CAZ SC - - - 8035. 72 92. 22 182 .07 3631.29 3522 .29 -1016 .35 4385 .67 5945016. 65 563169. 21 MWD+IFR-AK-CAZ-SC 8065. 13 91. 80 182 .16 3630.26 3521 .26 -1045 .72 4384 .59 5944987. 27 563168. 35 MWD IFR-AK-CAZ-SC 8126. 67 92. 27 181 .68 3628.07 3519 .07 -1107 .19 4382 .53 5944925. 80 563166. 77 MWD+IFR-AK-CAZ-SC 8156. 04 92. 28 181 .39 3626.91 3517 .91 -1136 .53 4381 .74 5944896. 46 563166. 22 MWD+IFR-AK-CAZ-SC ~i 8215. 78 93. 19 181 .17 3624.06 3515 .06 -1196 .18 4380 .41 5944836. 80 563165. 35 MWD+IFR-AK-CAZ-SC 8270. 68 93. 52 180 .15 3620.84 3511 .84 -1250 .98 4379 .78 5944782. 00 563165. 15 MWD+IFR-AK-CAZ-SC II 8306. 33 92. 71 180 .36 3618.90 3509 .90 -1286 .58 4379 .62 5944746. 41 563165. 27 I MWD+IFR-AK-CAZ-SC 8354. 65 91. 54 180 .87 3617.11 3508 .11 -1334 .86 4379 .10 5944698. 13 563165. 12 MWD+IFR-AK-CAZ-SC 8397. 87 90. 92 181 .51 3616.19 3507 .19 -1378 .06 4378 .20 5944654. 92 563164. 56 MWD+IFR-AK-CAZ-SC 8446. 48 92. 58 181 .85 3614.70 3505 .70 -1426 .63 4376 .78 5944606. 35 563163. 52 MWD+IFR-AK-CAZ-SC 8543. 20 91. 60 180 .05 3611.17 3502 .17 -1523 .27 4375 .18 5944509. 72 563162. 67 MWD+IFR-AK-CAZ-SC ' 8636. 76 91. 16 177 .71 3608.92 3499 .92 -1616 .77 4377 .00 5944416. 23 563165. 23 MWD+IFR-AK-CAZ-SC '~ 8729. 54 91. 53 178 .12 3606.74 3497 .74 -1709 .47 4380 .38 5944323. 58 563169. 33 MWD+IFR-AK-CAZ-SC 8823. 15 91. 10 177 .82 3604.59 3495 .59 -1802 .99 4383 .69 5944230. 09 563173. 37 MWD+IFR-AK-CAZ-SC 8916. 15 91. 60 178 .99 3602.40 3493 .40 -1895 .93 4386 .28 5944137. 19 563176. 69 MWD+IFR-AK-CAZ-SC 9009. 58 90. 24 180 .17 3600.90 3491 .90 -1989 .34 4386 .97 5944043. 79 563178. 10 MWD+IFR-AK-CAZ-SC 9102. 83 91. 47 184 .21 3599.51 3490 .51 -2082 .49 4383 .40 5943950. 63 563175. 26 MWD+IFR-AK-CAZ-SC 9195. 78 91. 04 182 .88 3597.47 3488 .47 -2175 .24 4377 .66 5943857. 85 563170. 24 MWD+IFR-AK-CAZ-SC 9289. 05 90. 42 178 .77 3596.29 3487 .29 -2268 .47 4376 .32 5943764. 61 563169. 63 MWD+IFR-AK-CAZ-SC 9382. 29 88. 82 176 .48 3596.90 3487 .90 -2361 .62 4380 .18 5943671. 51 563174. 22 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/17/2007 Time: 10:55:56. Page: 4 '~ Field: Kuparuk River Unit Co-or dioate(NE)Refereuce: Well: 1J-105, Tn aeNorth Site: Ku paruk 1J Pad Vertical (T~'D) Reference: 1J-105L2: 109.0 ~', Well: 1J -105 Section (VS) Keference: Well (O.OON,O.OO E,180.OOAzi) ~Yellpath: tJ -105L2 Survey CakulatioreA~tethod: Minimum Curvat ure Db: Oracle Survcv - - - - ---. MD Incl Azim 1'1ll Sys T~'D N/S E/W ~11apN MapF' Tool ft deg deg ft ft ft ft ft ft 9475. 88 88.76 178.87 3598 .88 3489. 88 -2455 .11 4383.98 5943578 .06 563178.74 MWD+IFR-AK-CAZ-SC 9569. 23 91.47 180.11 3598 .69 3489. 69 -2548 .44 4384.81 5943484 .75 563180.30 MWD+IFR-AK-CAZ-SC 9663. 29 89.74 184.87 3597 .70 3488. 70 -2642 .38 4380.72 5943390 .79 563176.95 MWD+IFR-AK-CAZ-SC 9756. 77 92.28 186.53 3596 .05 3487. 05 -2735 .37 4371.44 5943297 .74 563168.40 MWD+IFR-AK-CAZ-SC ~ 9847. 57 90.30 183.45 3594 .01 3485. 01 -2825 .79 4363.55 5943207 .27 563161.21 MWD+IFR-AK-CAZ-SC 9941. 03 90.42 181.95 3593 .42 3484. 42 -2919 .14 4359.14 5943113 .90 563157.54 MWD IFR-AK-CAZ-SC 10034. 34 90.30 183.25 3592 .83 3483. 83 -3012 .35 4354.91 5943020 .66 563154.03 MWD+IFR-AK-CAZ-SC 10127. 57 89.99 183.49 3592 .60 3483. 60 -3105 .42 4349.43 5942927 .57 563149.28 MWD+IFR-AK-CAZ-SC 10218. 67 89.99 183.81 3592 .61 3483. 61 -3196 .33 4343.63 5942836 .62 563144.19 MWD+IFR-AK-CAZ-SC 10309. 08 90.48 181.44 3592 .24 3483. 24 -3286 .64 4339.49 5942746 .29 563140.76 MWD+IFR-AK-CAZ-SC 10399. 86 89.74 179.43 3592 .07 3483. 07 -3377 .41 4338.80 5942655 .52 563140.77 MWD+IFR-AK-CAZ-SC ' 10488. 70 90.48 179.40 3591 .90 3482. 90 -3466 .25 4339.71 5942566 .71 563142.37 MWD+IFR-AK-CAZ-SC 10581. ~ 70 89.99 179.06 3591 .52 3482. 52 -3559 .24 4340.96 5942473 .74 563144.35 MWD+IFR-AK-CAZ-SC '~ ; 10672. 04 89.87 180.54 3591 .63 3482. 63 -3649 .57 4341.27 5942383 .41 563145.37 MWD+fFR-AK-CAZ-SC 10764. 32 89.87 182.41 3591 .84 3482. 84 -3741 .82 4338.90 5942291 .16 563143.72 MWD+IFR-AK-CAZ-SC 10855. 92 90.48 182.60 3591 .56 3482. 56 -3833 .33 4334.89 5942199 .63 563140.43 MWD+IFR-AK-CAZ-SC 10944. 12 89.99 179.91 3591 .20 3482. 20 -3921 .50 4332.96 5942111 .46 563139.18 MWD+IFR-AK-CAZ-SC 11035. 84 89.19 178.17 3591 .85 3482. 85 -4013 .20 4334.50 5942019 .78 563141.44 MWD+IFR-AK-CAZ-SC i 11129. 25 89.80 179.92 3592 .67 3483. 67 -4106 .59 4336.06 5941926 .41 563143.72 MWD+IFR-AK-CAZ-SC 11220. 19 89.62 179.63 3593 .14 3484 .14 -4197 .53 4336.41 5941835 .49 563144.79 MWD+IFR-AK-CAZ-SC 11310. 64 88.57 179.96 3594 .56 3485 .56 -4287 .96 4336.74 5941745 .07 563145.82 MWD+IFR-AK-CAZ-SC 11383. 00 88.57 179.96 3596 .37 _ 3487 .37 -4360 .30 4336.79 5941672 .74 563146.43 PROJECTED to TD r: Time Logs Date From__ Tc Dur S. De th E_ De th Phase Code Subcode T COM 04/20/2007 01:15 02:00 0.75 7,703 7,703 COMPZ CASINC CIRC T Drop 29/32" ball -Pump down same - Total stks 856 on seat -Pressure up to 4200 psi (No Shear) Bleed pressure off to 2000 psi and pressure up to 4487 psi -Sheared ball set - PU wt 135K -Tool released 02:00 02:15 0.25 7,703 7,703 COMPZ RPCOh TRIP P Blow down top drive -Monitor well Static 02:15 06:00 3.75 7,703 0 COMPZ RPCO TRIP P POOH - UD Running Tool -( Inspection of tool showed all worked well. 06:00 06:30 0.50 0 0 COMPZ RPCOfv PULD P Clear all Tools from Rig floor -Clean ri floor of OBM 06:30 07:00 0.50 0 0 COMPZ RPCOti RURD P R/U Csg tools to run LEM asst' 07:00 11:00 4.00 0 358 COMPZ RPCOh PULD P P/U LEM asst' per detail and orient to MWD. RD casin tools and clear floor. 11:00 12:00 1.00 358 500 COMPZ RPCOti SRVY P RIH to 500' MD -Shallow pulse test MWD 12:00 14:00 2.00 500 7,552 COMPZ RPCOh TRIP P PJSM & Con't TIH w/ LEM to 7552' MD -Break circu - PR 3 BPM -Orient to hi h side - U wt 135K, Dn wt 75K 14:00 17:00 3.00 7,552 7,862 COMPZ RPCO CIRC P Pump in hole @ 4 deg left - PU single & 10' pup -Tag SBR @ 7851' -Work seals in w! 10-15K do wt -Worked in 11' to 7862' MD -LEM showed good latch. When LEM latched the orientation changed from 4L to 8R - Put 35k on LEM. 17:00 18:00 1.00 7,862 7,465 COMPZ RPCOh CIRC P Drop Ball and Pump same on seat - 615 stks -Pressure up to 4100 -Set ZXP and shear off tool. PU 5' and test ZXP packer for 5 mins @ 2500 psi. "OK" - PU to up wt 128k tools loose. Blow down TD 18:00 21:30 3.50 7,465 40 COMPZ RPCOh TRIP P POOH -Hole fill 1 bbl long 21:30 23:00 1.50 40 0 COMPZ RPCOh PULD P UD Running tools and MWD -Clear & Clean ri floor. 23:00 23:30 0.50 0 0 PROD3 DRILL PULD P P/U Mill asst' tools to rig floor 23:30 00:00 0.50 0 0 PROD3 DRILL SFTY P PJSM -Crew change -Baker rep discuss M/U of Mill ass 04/21/2007 00:00 00:15 0.25 0 0 PROD3 DRILL SFTY P PJSM -Hazard recognition P/U BHA Millin ass 00:15 02:00 1.75 0 0 PROD3 RIGMN SVRG P PJSM -Change out Top Drive saver sub. (Noted on inspection that threads were shar and worn 02:00 03:45 1.75 0 210 PROD3 DRILL PULD P M/U Whipstock asst' - PU seal, Trip anchor, whipstock, MWD and orient to same. 03:45 04:30 0.75 210 210 PROD3 DRILL SRVY P Program MWD 04:30 05:00 0.50 210 356 PROD3 DRILL PULD P Con't P/U BHA Mill asst' 05:00 09:15 4.25 356 7,097 PROD3 DRILL TRIP P TIH to 500' -Shallow test MWD 'OK" - Con'tTIH to 7097' MD I'<~c~€~ 2?" cif ;s'tt5 Time Logs 11I -- _ _ _ _ _ - __ _ - I bateFrom To Dur S De th E. De th Phase Code Subcode T COM _ 04/21/2007 09:15 09:45 0.50 7,097 7,185 PROD3 DRILL SRVY P Break Circu - MADD pass f/ 7111' to 7185' MD -Orient tool to Hi Side - Up wt 140k, Dn wt 85k. 09:45 10:45 1.00 7,185 7,348 PROD3 DRILL TRIP P Con't TIH, Orient to 12L Hi side, work torque out, Tag TOL @ 7465' MD, Observed seal enter SBR, Set trip anchor w/ 15k Dn wt. Shear off of slide w/ 35k do wt.-All appear "OK" ***Note** Whipstock set 12 Left of High Side. TOW @ 7348', BOW 7361' MD 10:45 12:00 1.25 7,348 7,348 PROD3 DRILL MILL P Displace over to drilling fluid MOBM, Start Millimg after MOBM had turned the corner around started mill @ 11:00 hrs, PR 280 gpm, PP 2400 psi, RPMs 90, Tor 5k. TOW 7348' MD 12:00 15:45 3.75 7,348 7,361 PROD3 DRILL MILL P Crew Change -PJSM - Mill D lat window f/ 7348' MD 7361' MD , WOM 2-4k, PR 300 gpm, PP 2350 psi, RPMs 90, Troq 3-6k, (pumped hi vis swee 7356' MD 15:45 21:00 5.25 7,361 7,380 PROD3 DRILL MILL P Drill with Mills f/ 7361' to 7380' MD Full gauge hole 6.75" to 7370' MD) about 10' below slide. Dressed window well with several passes with and without MP. Window in great shape. It appears the started Mill is worn out and cannot make our footage needed. After a discussion with all team members the decision was made to pull mill assy and go back with a mud motor. 21:00 21:30 0.50 7,380 7,380 PROD3 DRILL CIRC T Monitor Well -Pump dry job. 21:30 00:00 2.50 7,380 850 PROD3 DRILL TRIP T POOH to 850' 04!22/2007 00:00 00:15 0.25 850 110 PROD3 DRILL TRIP T PJSM - Con't POOH f! 850' to 110' MD 00:15 01:45 1.50 110 0 PROD3 DRILL PULD T UD BHA - Dn load data f/MWD - UD Mill Assy. -Upper Mill full gauge - Pilot Mill slick, very little cutrite remainin . 01:45 02:45 1.00 0 0 PROD3 DRILL OTHR T Pull wear bushing -Using stack clean tool flush BOPs and surface equipment to remove all metal cuttings - Re-Install wear bushin 02:45 03:00 0.25 0 0 PROD3 DRILL PULD T Clean & Clear Rig Floor 03:00 04:00 1.00 0 160 PROD3 DRILL PULD T PJSM - P/U BHA #18 04:00 04:30 0.50 160 160 PROD3 DRILL SRVY T Program MWD 04:30 07:30 3.00 160 7,266 PROD3 DRILL TRIP T TIH 160' to 458' MD -Shallow Test MWD - Con't TIH 458' to 7266.0 MD - U wt 118k, Dn wt 64k ,.....~._ .~.~m_.® ~. ®®_e ~%34~i' ~~ Ll~ ~~.~.'~ ~ l J I"~ Time Logs --- - ------ Date From To Dur S Depth E Depth - Phase Code S ubcode T COM 04/22/2007 07:30 __ 08:30 _____ 1.00 7,266 7,380 PRODS DRILL _ TRIP T Orient to 9 left Hi side -Stop Pump - Slide thru window t/ 7370'MD, No Problems @ Window, Wash & Ream t/ 7380' MD, PR 300 gpm, RPMs 50, Tor 5-6k 08:30 12:00 3.50 7,380 7,547 PRODS DRILL DDRL P Drlg & Slide w! Mud Motor 7380' to 7547' MD -ART .65, AST .61, ADT 1.26 hrs 12:00 20:30 8.50 7,547 8,442 PRODS DRILL DDRL P PJSM - Drlg f/ 7547' to 8442' MD / 3616' TVD (Pump wt/ Hi Vis sweep at 8400') ART 4.39 hrs, AST .82 hrs, ADT 5.21 hrs (Up wt 157k, Dn wt 74k, Rot wt 95k 20:30 21:00 0.50 8,442 8,442 PRODS DRILL CIRC P Con't circu sweep from hole - 15% ex on return -Record SPRs -Monitor well "Static" 21:00 22:00 1.00 8,442 7,266 PRODS DRILL TRIP P POOH on elevators f/ 8442 - 7266' MD (Open hole and window pulled clean - No roblems. 22:00 22:30 0.50 7,266 7,266 PRODS DRILL CIRC P Monitor well -Pump dry job - Blow do TD 22:30 00:00 1.50 7,266 4,943 PRODS DRILL TRIP P Con't POOH f/ 7266' to 4943' MD - Crew chan e 04/23/2007 00:00 01:30 1.50 4,943 93 PRODS DRILL TRIP P PJSM - Con't POOH to 93' 01:30 02:15 0.75 93 93 PRODS DRILL SRVY P Down Load MWD 02:15 03:00 0.75 93 0 PRODS DRILL PULD P UD Mud Motor BHA & Bit 03:00 03:15 0.25 0 0 PRODS DRILL PULD P Clean & Clear Rig Floor 03:15 04:30 1.25 0 93 PRODS DRILL PULD P P/U BHA# 19 -GeoPilot assy. 04:30 05:45 1.25 93 93 PRODS DRILL SRVY P Program MWD 05:45 09:30 3:75 93 8,303 PRODS DRILL TRIP P TIH to 8303' MD (@ 450' break in GeoPilot seals & bearing, Dn Link, Shallow test MWD 09:30 10:00 0.50 8,303 8,442 PRODS DRILL REAM P Wash & Ream 8303' to 8442' MD - PR 280 gpm, PP 2500 psi, RPMs 80, Tor 5-6k 10:00 12:00 2.00 8,442 8,540 PRODS DRILL DDRL P Drlg f/ 8442' to 8540' MD / 3607' TVD. ART .9 hrs 12:00 00:00 12.00 8,540 9,887 PRODS DRILL DDRL P PJSM & Drlg f/ 8540' - 9887' MD / 3586' TVD ADT 8.2 hrs Up wt 135k, Dn wt 45k, Rot wt 75k, ***Note*** Electrician, Larry Bishop checked fire & calibrated & tested gas alarms, H2S and Meth 04/24/2007 00:00 12:00 12.00 9,887 11,115 PRODS DRILL DDRL P Drilled 6 3/4" hole in "D" sand lateral from 9,887' to 11,115' MD/ 3,593' TVD, (1,228') ADT 8.2 hrs, ave MW 8.4 ppg, ave ECD 10.82 ppg, max gas 181 units, drilled thru 3 concretions for 20'. ~' ~~~ ~~ ~t ~ • Time Logs Date From To Dur S De th E. Dearth Phase__C_ode_ Subcode T COM _ _ ___ __ 04/24/2007 12:00 14:15 2.25 11,115 11,383 PROD3 DRILL DDRL P Drilled 6 3/4" hole in "D" sand lateral from 11,115' to 11,383' MD/ 3,596' TVD, (268') ADT 2.0 hrs, ave MW 8.4 ppg, ave ECD 10.89 ppg, max gas 166 units, drilled thru concretion from 11,368' to 11,373' and ABI showed 26 de . do le in 10' interval. 14:15 14:45 0.50 11,383 11,360 PROD3 DRILL CIRC P Circ hole above concretion at 11,360' while discussing concretion with town, decision was made to call 11,383' TD for the "D" sand lateral 14:45 20:00 5.25 11,360 7,325 PROD3 DRILL REAM P Backreamed out of hole from 11,360' to 7,556' then pumped out of hole to above TOW to 7,325' (TOW at 7,348'). BROOH at 312 gpm and 110 rpm's, ICP 3,500 psi, FCP 2,500 psi, no roblems BROOH. 20:00 21:15 1.25 7,325 7,325 PROD3 DRILL CIRC P Pumped 30 bbl hi vis sweep and Circ hole clean above TOW, saw no increase in cuttings from the sweep and circ a total of 2X btms up and was clean at the shakers, circ hole at 312 m, 2,500 si and 110 r m's. 21:15 00:00 2.75 7,325 10,530 PROD3 DRILL TRIP P RIH from 7,325' to 9,430' and lost down wt, cont to wash and rotate down from 9,430' to 10,530', washed down at 130 gpm, 850 psi and 50 r m's. 04/25/2007 00:00 00:45 0.75 10,530 11,365 PROD3 DRILL TRIP P Fin washing and rotating in hole from 10,530' to 11,365', did not go to btm at 11,383' due to concretion and high dogleg, washed down at 130 gpm at 850 si and 50 m's. 00:45 02:45. 2.00 11,365 11,365 PROD3 DRILL CIRC P Pumped 30 bbl hi vis sweep and began to circ out of hole, with sweep almost to surface began to swap hole over to 8.4 ppg SFMOBM, with sweep out of hole had a 10% in crease in cuttings, fin changing hole over to 8.4 ppg SFMOBM, circ hole at 310 gpm, at 3,600 si. 02:45 03:00 0.25 11,365 11,365 PROD3 DRILL OWFF P Monitored well-static, blew down top drive. 03:00 05:30 2.50 11,365 9,050 PROD3 DRILL TRIP P POOH from 11,365' taking torque and drag (T & D) readings every other std to 9,050' when we were able to est. a slack off wt for lubricity test, at 9,050' had 85K rot wt, 130K up wt and 40K do wt. 05:30 06:15 0.75 9,050 8,117 PROD3 DRILL TRIP X POOH 10 stds from 9,050' to 8,117' takin T & D readin s eve other std. 06:15 07:15 1.00 8,117 9,050 PROD3 DRILL TRIP X RIH 10 stds from 8,117' to 9,050' taking T & D readings with 0% tubes added to SFMOBM, RIH with no roblems. L~ l Time Logs ..Date From To Dur S. Depth E Depth Phase Code Subcode T COM 04/25/2007 07:15 08:15 _ 1.00 9,050 9,050 PRODS - DRILL - CIRC X _ _ _ _ - Circ hole at 9,050' adding 1% Versa tube to SFMOBM, Circ at 312 gpm, 2,850 psi, 100 rpm's with 5-8K ft-Ibs torque, at btms up and prior to tubes to surface had a 50% increase in cuttings., circ hole till 1 % tubes were in and out. 08:15 09:15 1.00 9,050 8,117 PRODS DRILL TRIP X POOH 10 stds from 9,050' to 8,117' takin T & D readin s eve other std. 09:15 10:30 1.25 8,117 9,050 PRODS DRILL TRIP X Monitored well-static, RIH from 8,117' and lost down wt at 8,875', rotated 2 stds do then washed last std down to 9,050' with 1°lo tubes in SFMOBM, prior trip with no tubes had no roblems RIH to 9 ,050' 10:30 12:00 1.50 9,050 9,050 PRODS DRILL CIRC X Circ hole at 9,050' adding an add. 2% Versa tube to system, at btms up had 30% increase in cuttings, circ hole till 3% total tubes were in system, circ at 312 m, 2,900 si and 130 m's. 12:00 13:00 1.00 9,050 8,117 PRODS DRILL TRIP X POOH 10 stds from 9,050' to 8,117' takin T & D readin s eve other std. 13:00 14:00 1.00 8,117 9,050 PRODS DRILL TRIP X RIH 10 stds from 8,117' to 9,050' taking T & D readings with 3% tubes added to SFMOBM, RIH with no problems at 9,050' had 75K rot wt, 130K u wt and 40K do wt. 14:00 16:30 2.50 9,050 6,809 PRODS DRILL TRIP X Pumped out of hole due to swabbing from 9,050' to 7,366', POOH from 7,366' thru the window to 6,809' and hole not taking proper fill due to swabbing, monitored well and well was static. 16:30 17:30 1.00 6,809 6,809 PRODS DRILL CIRC X Circ hole clean at 6,809' at btms up had 20% increase in cuttings, circ till clean at 310 gpm, 2,750 psi, 120 r m's with 4-5K ft-Ibs for ue 17:30 21:15 3.75 6,809 188 PRODS DRILL TRIP P POOH from 6,809' to 4,569', pumped out every other std due to swabbing, once supersliders were out of the hole was able to POOH on elevators, cont. to POOH from 4,569 to 188' standing back HWDP and ~ars. 21:15 21:45 0.50 188 91 PRODS DRILL PULD P POOH to 91' LD 3- 4 3/4" NMFDC's, stab and flt sub. 21:45 00:00 2.25 91 0 PRODS DRILL PULD P Downloaded MWD, fin POOH and LD BHA #19 and cleared ri floor. 04/26!2007 00:00 00:45 0.75 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner and fin cleaning ri floor. 00:45 01:00 0.25 0 0 COMPZ CASINC SFTY P Held PJSM with rig crew, tong operator and Baker rep on PU and RIH with liner and associated hazards. ~~ ~. ~ ~ ~ ,n. ~~~ 3'I €~~t ~ z C~ Time Logs Date From To Dur S. Depth E De th Phase Code Suhcode T COM 04/26/2007 01:00 03:00 2.00 0 3,736 COMPZ CASIN( PUTS P PU and RIH with 4 1/2" slotted and blank liner per well plan to 3,736'. RIH with guide shoe, 55 jts of blank and 32 jts of slotted 11.6#, L-80, BTC liner, used 24 torque rings on top jts and 86 stop rings and 86 Hydraform centralizers. 03:00 03:45 0.75 3,736 3,905 COMPZ CASIN( PUTB P MU Baker liner receptacle jt. and setting sleeve RIH to 3,811', st wt up 60K, do wt 55K, MU 1 std RIH to 3,905' and rotated liner at 20 rpm's, 1 K ft-Ibs for ue and 58K rot wt. 03:45 09:00 5.25 3,905 11,364 COMPZ CASINC RUNL P RIH with 4 1/2" liner on 4" DP from 3,905' to 11,364', no problems or rotation needed to get liner to btm, rotated liner on btm at 20 rpm's with 9K ft-Ibs torque, st wt up 175K, do wt 55K. 09:00 09:30 0.50 11,364 7,561 COMPZ CASINC OTHR P With liner on depth, dropped 29/32" setting ball and pumped down to seat, pressured up to 3,000 psi to release running tool, slacked off 5K wt then PU and was released from liner, set "D" lat liner with shoe at 11,364' and to of liner settin sleeve at 7,561'. 09:30 10:45 1.25 7,561 7,360 COMPZ CASINC CIRC P POOH from 7,561' to 7,360' (btm of WS) and circ hole with clean SFMOBM while circ out SFMOBM with 3% Versa Lube, circ across whipstock slot at 300 gpm at 2,040 si, st wt u 145K. 10:45 11:00 0.25 7,360 7,360 COMPZ CASINC OTHR P Monitored well-static, blew down top drive. 11:00 14:00 3.00 7,360 45 COMPZ CASINC RUNL P POOH from 7,360' to Baker liner runnin tool. 14:00 14:45 0.75 45 0 COMPZ CASIN PUTB P POOH and LD liner running tool and cleared ri floor. 14:45 15:00 0.25 0 0 COMPZ RIGMN SFTY P Held PJSM on slip and cutting of drillin line. 15:00 16:00 1.00 0 0 COMPZ RIGMN SVRG P Slip and cut 98' of drlg line, inspect and ad'ust drawwork brakes. 16:00 16:45 0.75 0 243 COMPZ FISH PULD P MU Baker fishing assembly BHA #20 with WS retrieving hook and RIH to 243'. 16:45 19:15 2.50 243 7,295 COMPZ FISH TRIP P RIH with BHA #20 from 243' to 7,295', st wt up 145K, do wt 80K, est circ at 3 bpm at 680 psi, st wt up 145K, do wt 75K 19:15 20:00 0.75 7,295 7,352 COMPZ FISH FISH P RIH from 7,295' and latched WS slot at 7,352' (top of WS at 7,348'), jarred on WS working st wt up to 90K over when WS came free, saw 10K increase in st wt. 20:00 20:30 0.50 7,352 7,259 COMPZ FISH OTHR P POOH 1 std and monitored well, well-static, blew down to drive. 20:30 00:00 3.50 7,259 1,546 COMPZ FISH TRIP P POOH with whipstock and fishing BHA #20 from 7,259' to 1,546' • i Time Logs - -. - -- - Date Frorn_ _To Dur S Depth- E Depth Phase Code Subcode T _ COM 04/27/2007 00:00 00:30 0.50 1,546 65 COMPZ FISH TRIP P Cont. to POOH with fishing BHA #20 and whipstock assembly from 1,546' to BHA at 65'. 00:30 02:30 2.00 65 0 COMPZ FISH PULD P POOH LD whipstock, WS seal assembly and fishing tools, cleared rig floor. 02:30 03:15 0.75 0 0 COMPZ CASINC RURD P Picked up slim hole handling tools to rig floor and RU to run "D" lat hook han er. 03:15 03:30 0.25 0 0 COMPZ CASINC SFTY P Held PJSM on MU hook hanger with slim hole MWD. 03:30 05:45 2.25 0 284 COMPZ CASINC PUTB P MU "D" lat hook hanger assembly with ECP packer and slim hole MWD RIH to 284', st wt up and down 40K, blk wt 35K. 05:45 09:45 4.00 284 7,587 COMPZ CASINC RUNL P Shallow tested MWD then RIH from 284' to 7,587' 09:45 11:00 1.25 7,587 7,612 COMPZ CASINC OTHR P Est circ at 3 bpm at 1,000 psi, st wt up 143K, do wt 80K, RIH thru window with no problems, oriented hook to 3L and cont. to RIH and hooked hanger on depth and showed to be 12R, PU oriented 180 deg's. out and rotated hook and RIH tagging XO, PU, re-orientated and RIH rehooking hanger at 15R and setting 40K wt down on hook. 11:00 12:00 1.00 7,612 7,343 COMPZ CASINC OTHR P Dropped 29/32" ball and pumped down to seat, with ball on seat pressured up to 2,000 psi to open ECP, pumped 1/2 bbl to inflate same, pressured up to 4,000 psi to release running and to blow ball seat, PU and was released from hook hanger, st wt up 140K, no problems running hook hanger. Top of hook hanger at 7,343' with end of mule shoe in "D" lat at 7,612' 12:00 15:30 3.50 7,343 107 COMPZ CASIN RUNL P POOH from 7,343' to running tool at 107' 15:30 17:15 1.75 107 0 COMPZ CASIN PUTB P POOH LD Baker running tool, inner string and slim hole MWD, cleared rig floor. 17:15 17:45 0.50 0 0 COMPZ CASINC RURD P RU to run "D" lat LEM 17:45 19:15 1.50 0 219 COMPZ CASINC PUTS P MU LEM assembly with slim hole MWD R!H to 219'. 19:15 23:00 3.75 219 7,282 COMPZ CASIN RUNL P RIH with LEM from 219' to 7,282', st wt u 143K, do wt 79K 23:00 00:00 1.00 7,282 7,400 COMPZ CASINC RUNL P Est. circ at 120 gpm, 1,100 psi then RIH from 7,282' to 7,400', no problems oin thru to of hook han er at 7,343' ~~~ _~ ~_ ~~m ~._ ~'ag~ ~3 ~~ 3~ L J C~ i Time Logs ~ Date Frorn To Dur S De th E_ De th Phase Code Subcode T COM 04/28/2007 00:00 00:45 0.75 7,400 7,491 COMPZ CASINC RUNL P Cont to RIH with LEM from 7,400', cite at 120 gpm, 1,100 psi, oriented to 161 L and RIH observing seals enter B lat tagging hook high as planned, PU and re-oriented to 14L and RIH latching LEM on depth, MWD showed to be 11 L, PU and snapped in and out of LEM twice and latched up same lace both times. 00:45 01:15 0.50 7,491 7,288 COMPZ CASIN OTHR P Dropped 1 3/4" ball and pumped down to seat, with ball on seat pressured up to 3,000 psi to set ZXP packer then up to 4,000 psi to release from running tool. Set LEM with top of ZXP packer at 7,288' with end of seals at 7,492'. 01:15 02:00 0.75 7,288 7,288 COMPZ CASIN( DHEO P Tested ZXP packer and csg to 2,500 si for 30 min, ood test. 02:00 05:00 3.00 7,288 77 COMPZ CASIN RUNL P PU and running tool was released from LEM, st wt up 140K, POOH from 7,288' to runnin tool at 77' 05:00 06:30 1.50 77 0 COMPZ CASINC PUTB P LD Baker running tool and slim hole MWD, cleared ri floor. 06:30 07:00 0.50 0 0 COMPZ RPCO PULD P Pulled wear bushing 07:00 07:45 0.75 0 0 COMPZ RPCOti RURD P RU to run 4 1/2" completion 07:45 08:00 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with rig crew, tong operator and Baker rep on running of com letion. 08:00 08:30 0.50 0 121 COMPZ RPCOh RCST P MU locator seal assembly and RIH with 3 jts of 4 1/2" tbg to 121' when Baker in Deadhorse informed us we need an add. seal section. 08:30 10:15 1.75 121 0 COMPZ RPCOti OTHR NP POOH and waited on add. seal section 10:15 17:15 7.00 0 7,192 COMPZ RPCOA RCST P MU add. seal section to locator and RIH with 4 1/2", 12.6#, L-80, IBTM tubing and completion assembly per well Ian to 7,192' 17:15 18:30 1.25 7,192 7,192 COMPZ RPCOh CIRC P Circ 1 complete hole volume, cite at 252 mat 600 si. 18:30 20:00 1.50 7,192 7,324 COMPZ RPCOCv HOSO P RIH from 7,192, located seals and tagged up on D lat LEM XO, spaced out completion, MU hanger and RIH landing 4 1/2" tbg with seals 3.26' above XO, st wt up 88K, do wt 55K, blk wt 35K. 20:00 20:30 0.50 7,324 7,324 COMPZ RPCO HOSO P RILDS, tested seals on tbg hanger to 5,000 si for 10 min. 20:30 22:30 2.00 7,324 7,324 COMPZ RPCOb NUND P ND BOP stack and set back same. 22:30 00:00 1.50 7,324 7,324 COMPZ RPCO NUND P NU Vetco Gray MB 222A tree and tested void to 5,000 psi for 10 min. RU work latform on tree. 04/29/2007 00:00 01:00 1.00 0 0 COMPZ RPCOh NUND P Tested tree to 5,000 psi for 10 min's, ulled TWC _ _ __~~ P age 3~ ~f ~5~ l J i Time Logs Date From To Dur S Depth E_ Depth Phase Code Subcode T COM ' 04/29/2007 01:00 09:30 _ 8.50 _ 0 0 COMPZ RPCOh PULD P _____ Held PJSM then LD DP out of the derrick, LD 13 stds hybrid pushpipe, 8 stds HWDP and 90 stds of 4" DP. Sim-ops: Little Red freeze protected the well with 280 bbls of diesel, ave 2 b mat 350 si. 09:30 10:30 1.00 0 0 COMPZ RPCOti OTHR P RU lubricator, installed BPV and secured well. 10:30 12:00 1.50 0 0 COMPZ RPCOti PULD P LD last 21 stds of 4" DP out of the derrick. Removed supersliders from DP in the i eshed after LD. 12:00 14:00 2.00 0 0 COMPZ RPCOti OTHR P Cleaned out pollution pans and fin. cleaning mud pits, rig off highline at 13:00 hrs. RELEASED RIG at 14:00 hrs 4/29/07 ~~__ ~..._~. ~~~~ 3~ cif ~~ • • 1J-105'D' Sand Liner Detail Well: 1J-105 `~, CO~ti~ClJP'~1NI1~?5 4-1/2"Slotted and Blank Liner Date: 4/26/2007 ' :~~: ins . ' Rig: Doyon 141 ~' DEPTH Jt _ ~ ~t - ~ ~ `.::::.; COMPLETE DESCRIPTION OF EQUIPMENT RUN ~ Page 1 LENGTH TOPS 7552.58 7552.58 7552.58 7552.58 4" DP to Surface =_> 7552.58 XO 3 1/2 IF x 4" HT 39 2.00 7552.58 Baker Liner setting tool( Does not stay in hole) 6.42 7554.58 HR Liner Setting Sleeve w/ 10' TBR 5.5" (ID 5.0") 12.68 7561.00 Liner Pup Jt 5.5" 15.5# L80 5.5"Hyd 521 b X p (4.89") 7.36 7573.68 Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p (ID 4.89") 41.82 7581.04 XO - 5.5" Hyd 521 box X 4.5" BTC pin w/ TR (ID 3.93") 1.42 7622.86 4 1/2" Pup Jt, 12.6 ppf, L-80 w/TR ID 3.98" 3.82 7624.28 Jts s5 to 86 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 86.71 7628.10 Jts 84 to s4 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 42.71 7714.81 Jts 83 to 83 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.64 7757.52 Jts 78 to 82 5 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) w/ TR 215.21 7801.16 Jts 77 to 77 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.08 8016.37 Jts 76 to 76 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 42.86 8059.45 Jts 75 to 75 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing w/ TR 42.85 8102.31 Jts 74 to 74 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) w/ TR 42.74 8145.16 Jts 73 to 73 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.24 8187.90 Jts 72 to 72 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 42.67 8231.14 Jts 71 to 71 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.03 8273.81 Jts 70 to 70 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 43.05 8316.84 Jts 69 to 69 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.41 8359.89 Jts 63 to 68 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 255.47 8403.30 Jts 62 to 62 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.45 8658.77 Jts 61 to 61 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.89 8702.22 Jts 60 to 60 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.48 8745.11 Jts 59 to 59 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.46 8788.59 Jts 58 to 58 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 43.64 8831.05 Jts 57 to 57 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.31 8874.69 Jts 56 to 56 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.07 8918.00 Jts 55 to 55 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 43.30 8959.07 Jts 54 to 54 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.24 9002.37 Jts 53 to 53 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 43.36 9045.61 Jts 52 to 52 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.25 9088.97 Jts 46 to 51 6 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 259.84 9132.22 Ran total of 55 jts Blank and 32 jts Slotted, Slots are 0.125" wide x 2.5" long x 32 slo/ft. w/ (32) 2.5" long x .125" @ 4 Circumferential adjacent rows, 3" Centers Up WI 175K sta ered 18 de ., 3 ft. non-slotted ends. NO Constrictors ran. Dn Wt 55K Ran torque rings in the top 24 jts (# 63 thru # 86) Block Wt 35K Ran shoe joint slick. Torqued liner w/o torque rings to 4500 ft-Ibs, w/ torque rings to 8000 ft/Ibs Supervisors: Guy Whitlock/ Peter wlson/ Dan Lowe ~ ! Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 45 to 45 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.98 9392.06 Jts 44 to 44 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 43.63 9435.04 Jts 43 to 43 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.41 9478.67 Jts 42 to 42 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 41.38 9522.08 Jts 41 to 41 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 43.20 9563.46 Jts 40 to 40 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.31 9606.66 Jts 39 to 39 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.38 9649.97 Jts 38 to 38 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 41.27 9693.35 Jts 37 to 37 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.50 9734.62 Jts 36 to 36 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 43.41 9778.12 Jts 35 to 35 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 9821.53 Jts 29 to 34 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 257.13 9864.93 Jts 28 to 28 1 Jts 4-112" BTC 11.6 ppf, L-80 Slotted Casing 42.93 10122.06 Jts 27 to 27 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 42.30 10164.99 Jts 26 to 26 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 10207.29 Jts 25 to 25 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 41.77 10250.69 Jts 24 to 24 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.36 10292.46 Jts 23 to 23 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 43.42 10335.82 Jts 22 to 22 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 43.25 10379.24 Jts 21 to 21 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 41.88 10422.49 Jts 20 to 20 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.50 10464.37 Jts 19 to 19 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.33 10507.87 Jts 18 to 18 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.64 10550.20 Jts 12 to 17 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 255.18 10591.84 Jts 11 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 10847.02 Jts 10 to 10 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 39.41 10890.42 Jts 9 to 9 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.11 10929.83 Jts 8 to 8 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.50 10972.94 Jts 7 to 7 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.61 11015.44 Jts 6 to 6 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.14 11059.05 Jts 5 to 5 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.27 11102.19 Jts 4 to 4 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.66 11145.46 Jts 3 to 3 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.26 11189.12 Jts 2 to 2 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.34 11232.38 Jts 1 to 1 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.23 11275.72 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blank shoe joint) 43.43 11318.95 41/2" Silver Bullet Shoe 1.67 11362.38 BOTTOM OF SHOE __> 11364.05 Remarks: Total = 86 Hydraform 4.5" X 5.75" centralizers and 86 Stop rings Ran 1 Hydra-form per joint floating under a stop ring installed in the middle of each joint. Liner weight only 60K up, 55K down. Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Re: Request to pre produce new West Sak tri-l~ral injector 1J-105... r ^ Subject: Re: Request to pre produce new West Saktri-lateral injector 1J-105 PTD #'s 2~--027, ~~ 6-028, 2~f-02') rom: Thomas ~~9aunder<tom_maunder@adminatate.ak.us> Date: Mon, 07 '~~1av 2007 14:59:1 1 -0800 7~0: ASK Probl~«i tiVcll Sups =n t6] 7(u~,conocop}~illips.coni> CC:.iamcs Rc~~ ~ jim_rcg~r~i-admin.statc.ak.us Perry, I forgot to mention in the earlier message, all the permit numbers should be 207 rather than 206. Tom Thomas Maunder wrote, On 5/7/2007 12:11 PM: Perry, The intent to pre-produce this well was described in the permit to drill. Sundries should be submitted to convert from producer to injector near the end of the production period. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/7/2007 9:54 AM: Tom, New West Sak injector 1J-105 PTD #'s 206-027, 206-028, 206-029 is being prepared fora 30 day pre-production period to start later this week. CPAI would like to pre-produce 1 J-105 via gas lift through the open sliding sleeve above the packer, intentional T X IA communication, and delay the tubing pressure test until after the pre-production period has ended. This plan is similar to previously approved pre-production plans for 1 J-118, and 1 J-160. The completion has a packer at 7296' with a sliding sleeve (CMD) at 6685' and gas lift mandrels at 2262' and 6387'. A gas lift valve will be installed in the station at 2262, a dummy will be left in the station at 6387' and the sleeve will be left open as the bottom lifting point. With the sleeve open there will be T x IA communication . The annulus (IA) will not be isolated from produced fluids per 20 AAC 25.200(d) while on pre-production. Gaslift will be injected down the IA preventing production fluids from entering the IA. Both surface and intermediate casing strings were tested to 3000 psi for 30 minutes prior to drilling ahead on 3/25/07 and 4/2/07 respectively. Rig testing has demonstrated sufficient integrity to prevent uncontrolled releases. The packer was tested to 2500 psi for 30 minutes on 4/28/07 just prior to running the completion. The tubing was not tested on the rig as the sleeve was run in the. open position. Coiled tubing is required to shift the sleeve due to well bore deviation. The tubing will be tested when the sleeve is closed at the end of the pre-production period and again during the state witnessed MITIA once injection has stabilized. Please confirm it is acceptable to proceed as described above. Sincerely ', Perry Klein Problem Well Supervisor 1 of 2 5/7/2007 3:17 PM Re: Request to pre produce new West Sak tri-I~ al injector IJ-105... s office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617 tx.conoeophillips.com 2 of 2 5/7/2007 3:17 PM Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 S.QR,4H P,4L~N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105L2 ConocoPhillips Alaska, Inc. Permit No: 207-029 Surface Location: 2186' FSL, 2432' FEL, SEC. 35, Tl 1N, R10E, UM Bottomhole Location: 2319' FNL, 2120' FWL, SEC. 1, TlON, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-105, Permit No. 207- 027, API No. 50-029-23346-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the- Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Com fission to witness any required test, contact the Commission's petroleum field inspe or t (907) 659-3607 (pager). DATED this day of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~EIVED ~j(~ ~-i:.~ 2 8 2007 ~4a~'~ca Q~! & Gas Gons. Commission Anchorage 1a. Type of Work: 1 b. Current Well Class: Exploratory Development Oil ^ 1 c. Specify if well is proposed for: Drill Q Re-drill ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ^/ Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-105L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11521' ' TVD: 3562' ' Kuparuk River Field 4a. Location of well (Governmental Section): 7. Property Designation: Surface: 2186' FSL, 2432' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25661 & 25662 ~ West Sak OiI Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2100' FSL, 1916' FWL, Sec. 36, T11 N, R10E, UM r ALK 471 & 2177 3/30/2007 Total Depth: 9. Acres in Property: 14. Distance to 2319' FNL, 2120' FWL, Sec. 1, T10N, R10E, UM ~ 2560 Nearest Property: > 2 miles - 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation / I?'J~L. 15. Distance to Nearest ~ ' g ' ESL s~~° ~ ~ Surface: x- 558776 y- 5945998 Zone- 4 7' ' (Height above GL): 28' RKB feet well within Pool: 1J-1a , zao' 7as8' ~ 16. Deviated wells: Kickoff depth: 7092' ` ft. 17. Maximum Anticipated Pressures in psig (see zo aa,C 25.035) Maximum Hole Angle: gs° deg Downhole: 1658 psig - Surface: 1253 psig ° 18. Casing Program S ecifications Setting Depth Quantity of Cement Size p To Bottom P c. t. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3265' 28' 28' 3293' 2250' 570 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8487' 28' 28' 8515' 3850' 500 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 4429' 7092' 3662' • 11521' • 3562' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): l~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee BOP Sketch Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ~ ^ ~ ^ Property Plat ^ Diverter Sketch Seabed Report Drilling Fluid Program ^/ 20 AAC 25.050 requirements / 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature \ ~ Phone ~ 5-E 73~~ Date ~Z(~ (D 7 i P a d All D Commission Use Only Permit to Drill 7 ' Z API Number: 3~ ~r l ~ Permit Approval See cover letter Number: Div ~ ~ I i r(/ 50- V ~i~~ Date: ~ ~ ~~ for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas rates, or gas contained in shales: ~~ r.~ •--~~ s ~~ `~ -V ~h~ Samples req'd: Yes ^ No [v~ ud log req'd: Yes ^ No [~ Other: H2S measures: Yes ^ No re I nal svy req'd: Yes [+~ No ^ 3 ~,. ~ ~O ~ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 7 r -.' ~ E ~ ('~ ` ~~ ~ `/ T / ~ Submit in uplzat~ ~ ,~ ~. ~t ... ~.fl.... \/ ~~©~ A~ion for Permit to Drill, Well 1 J-105 L2 Revision No.0 Saved: 23-Feb-07 Permit It -West Sak Well #1J-105 L2 Application for Permit to Dril/ Document .,,,~ ~., i~ .~ 11~1~ll Mpxirriix~ WTI I 1f41u e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f7 ......................................................................................._............... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ............_ ...................................................................................... 2 Requirements of 20 AAC 25.050(b) .............................................................................. :........................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...............................................................................:................... 3 4. Drilling Hazards Information ................................................................,.................. 3 Requirements of 20 AAC 25.005 (c)(4) ................................................................................................•- 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .......--•-•-• ......................................................................:............. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ...................................................... ................................. 4 ...... Requirements of 20 AAC 25.005(c)(8) .............................................................................................:..... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation. Information ................................:.................... 5 Requirements of 20 AAC 25.005 (c)(9) ....................................•---..................,......:.......-•---•--................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ......................................................................._........................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) .............................................................................~--................ 5 ~~~~& 1J-105L2 PERMIT IT Page 1 of 6 Printed: 23-Feb-07 • A~ion for Permit to Drill, Well 1J-105 L2 Revision No.O Saved: 23-Feb-07 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ..............................................................................:...:........:.... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ..................................................................:.........................:.. 6 Attachment 3 Well Schematic ...................................................•--•--•--.................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each we/1 must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a we/l with mu/tip/e we//branches, each branch must similarly be identified by a unique name and API nurn6er by adding a sutOx to the name designated for the welt by the operator and to the ncrmber assigned to the well by the commission. The well for which this Application is submitted wilt be designated as 1J-105 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application far a Permit to Dril/ must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each. objective formation, and at total depth, referenced to governmenta/section/roes (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/Geodetic Survey in the Nat/ono/ Oceanic and Atmospheric Administration,• (C) the proposed depth of the weJ! at the top of each abject/ve formatio`on and at total depth, ~4X` / Location at Surface 2187' FSL & ' FEL -Sec 35 - T11N - R10E ` ASPZone 4 NAD 27 Coordinates RKB E/evation 109' AMSL Northings: 5,945,998 Eastings: 558,776 Pad E/evation 81' AMSL Location at Top of Productive Interval West Sak "D" Sand 2100' FSL & 1916' FWL -Sec 36 - T11N - R10E ASP Zone 4 NAD 27 Coordinates MedSUred De th, RKB: 7,092 Northings: 5,945,947 Eastings.• 563,124 . Tote/ t/ertica/De th RKB; 3,662 Tote/ ~ertica/De th, SS.• 3,553 Location at Total De th 2319' FNL & 2120' FWL -Sec 1 - T10N - R10E ASP Zone 4 NAD 27 Coordinates Measured De _ th, RKB,' 11, 521 Northings: 5,941,530 Eastings: 563,366 Tota/ ~ertica/De th, RKB; 3,562 Tote/ t/ertica/ De th, SS.• 3,453 and (D) other information required by 20 AAC 25.050(6); 1J-105L2 PERMIT IT , Page 2 of 6 ~ "~ ~ Printed: 23-Feb-07 ~.°^° • A~ion for Permit to Drill, Well 1J-105 L2 Revision No.O Saved: 23-Feb-07 Requirements of 20 AAC 25.050(b) If a we/I is to be intentionally deviated, the application for a Permit to Dri11(Form 10-4111) must (1) include a plat, drawn fo a suitable scale, showing the path ofthe proposed wellbore, including all adjacent wellbores within 20® feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for all wel/s within 2Q© feet of the proposed wellbore (A) list the names of the operators of those we//s, to the extent that those names are known or discoverable in pub/ic records, and show that each named operator has been furnished a copy of the application by certif<ed mail; or (B) state that the app/icant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except far an item already on file wifh the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (Bt7PE) as required by ZO AAC 25.1735, Zf) AAC ZS.036, ar 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-54 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item. already on file with the commissr"on and identified in the application: (4) r"hformation on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential sarface pressure based on a methane. gradient; f. The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "D" sand formation is 1,253 psi, calculated thusly: MPSP =(3,685 ft TVD)(0.45 - 0.11 psi/ft) ` =1,253 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, last circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iJ-105 L2 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Perntit to Drill must be accompanied by each of the following items, except for an item a/ready on frle with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25, 030(1); The parent wellbore, 1J-105, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on fiile with the Commission. 1J-105L2 PERMIT IT Page 3 of 6 + Printed: 23-Feb-07 fi~ . A~ion for Permit to Drill, Well 1J-105 L2 Revision No.O Saved: 23-Feb-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to I1rit! must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (6J a complete proposed casing and cementing program as required by20 AAC 25.030, and a description of any slotted liner, pre- perforated liner; onscreen to be installed; Casino and Cementing Pronram Hole Top Btm Csg/Tbg Size Weigh Length MD/7VD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 11.6 L-80 BTC CSG 4,184 7,540 / 3,745 11,724 / 3,798 Slotted- no cement Slotted Lateral (1J-105) 4-1/2 6-3/4" B Sand 11.6 L-80 BTC CSG 4,125 7,440/. 3,728. 11,565 / 3,634 Slotted- no cement to - 4-1/2 6-3/4" D Sand 11.6 L-80 BTC CSG 4,429 7,092/ 3,662 11,521 / 3,562 Slotted- no cement Slotted Lateral (1J-105 L2) , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an r"tem a/ready on file with the . commission and identified in the application: (7) a diagram. and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on 1J-105 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except far an item already on file with the commr`ssian and identified in the application: (8) a drilling fluid program, inc/udr'ng a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) ~: Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 1J-105L2 PERMIT /T Page 4 of 6 ~"~y j ~ '^ Printed: 23-Feb-07 f ~ ~ ~ ~ . Value Densit , pp 8.6 Plastic Viscosity Ib/100 s 15 - 25 Yield Point 2 cP) 18 - 8 HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical Stabilit 650-900 A~on for Permit to Drill, Well 1J-105 L2 Revision No.O Saved: 23-Feb-07 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application far a Permit to Dri// must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application; (9) for an exploratory or stratigraphic test we/1, a tabulation setting out the depths of predr`cted abnarrnal/y geo pressured strata as required by ZO AAC Z5.033(17; Not applicable: Application is not for an exploratory or stratigraphic test well 10. Seismic Analysis .Requirements of 20 AAC 25.005 (c)(10) An apply"cation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; (10) for an exploratory or stratigraphic test we!/, a seismic refraction or reflection analysis as required by ZQ AAG Z5.1161(a); Not applicable: Application is not for an exploratory or stratigraphic test well 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; (i1) for a well dri/!ed from an ofi`shore platform, mobile bottom-founded structure, jack-up rig, or fleeting dri/ling vessel, an analysis afseabed condr""bons as required by ZtJ AAC Z5.061(b); Not applicable: Application is not for an offshore well 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the fol/owing items, except for an item already on file with the commission and identified in the application; (ZZ) evidence showing that the requirements of20AAC25.OZ5 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fo/lowmg items, except for an item already on fi/e with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the iJ-105 Application for Permit to Drill. r 1. Run and set Baker WindowMaster whipstock system, at window point of 7,092' MD / 3,662' TVD, the top. of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at 11,521' MD / 3,562' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. -RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 7J-105L2 PERMIT IT ®~ ~ ~t~~ Page5of6 Printed: 23-Feb-07 A~ion for Permit to Drill, Well 1J-105 L2 Revision No.0 Saved: 23-Feb-07 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. il. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 18. Rig up wireline. Replace gas lift valves with blank dummyvalves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri// mustc be accompanied by each of the fo/lowing items, .except for an item a/ready on fi/e with the commission and identified in the application: (14) a general descriptican of how the operator plans to dispose of dril/ing mud and cuttings and a statement of whether the aperator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the we/!.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well-All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous. substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-105L2 PERMIT IT Page 6 of 6 ~ ~~} Printed: 23-Feb-07 ConocoPhillips Alaska • Plan: 1J-105 L2 (wp04) Sperry Drilling Services Proposal Report -Geographic 23 February, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-105 1J-105 L2 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-105 Plan RKB @ 109.OOft (Doyon 141 (28+81)) N True API - US Survey Feet Sp®rry Grilling 3®rvices ORIGINAL HALLIBURTON Sperry Drilling Services Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-105 Wellbore: 1J-105 L2 Plan: 1J-105 L2 (wp04) WELL DETAILS: Plan lJ-105 Crtound Level: SL00 +N/-S +E/-W Northing Fasting Labttude Longitude Slot 0.00 0.00 5945993.64 558776.16 70°l5'47.036N 149°3l'29.39W FORMATION TOP DETAILS No.TVDPath TVDSS MDPath Formation 1 1512.00 1403.00 1648.94 Pfrost 2 1660.00 1551.00 1876.16 T3 3 1960.00 1851.00 2561.79 K15 4 2250.00 2141.00 3293.57 Casing Pt 5 2910.00 2801.00 4947.61 Ugnu C 6 3266.00 3157.00 5830.31 Ugnu B 7 3322.00 3213.00 5980.64 Ugnu A 8 3455.00 3346.00 6347.45 K 13 9 3662.00 3553.00 7092.04 W Sak D CASING DETAILS No ~iD TVD TVDss Natne Size t 3293.57 2250.00 2141.00 10314" 10-;.-1 2 7092.06 3662.00 3553.00 7 5/8" TOE\' '-~ 8 3 11521.11 3562.00 3453.00 41;2" 4-I 2500 r ~ - -L2 - 7 5!8" TOW @ 7092' MD-3662' TVD: 2100' FSL, 1916' FWL =Sec36-T11 N-R10E L2 - BHL @ 11521' MD, 3562' TVD: 2319' FNL, 2120' FWL - Sec01-T10N-R10E - a~ 3000 ~ ----- // _~ ~~ ~ ~ .-~ p ~ i ' C _-~---- -. --------'------------------------------- --_ O .. --~----- --------- ., -yg- - ~ ~ ~ i ° ' ~ o ~----------- - - - - ~ 3500 n o ~ ° ~ ~ 1J-105 L2 (wp04) s ------ --------====1J-105Laf~~)------------- o ----i Q - WSakD-------- - -__ -----o -- i-o - o -~---i i ~ i °o o~ o ° ° i o ~ o '~ -- 1J-105 (wp04) ~ ~ i i ~ ~ i p i i ~ i i i ~ 4000 i ~ ~ i , , i i ~ 1 J-105 D Top 01/09/07 ~, ~ ' ~ ~i i i i ~ , i i i i , i i i 4500 1J-105 MB_D CP1 01/19/07 , 1J-105 MB_D CP3 01/19!07 ~i 1J-105 MB_D CPS 01/19/07 ~ i i i i 1J-105 MB_D CP2 01/19/07 1J-105 MB_D CP4 01/19/07 1J-105 D Toe 01/19/07 5000 5500 i ~ i ~ i ~ -, -_. -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section at 180.00° (750 ft/in) ~ ConocoPhillips Alaska .i HALL IBURTON WELL DETAILS: Plan 11-105 Ground Levcl: 81.00 Sperry Grilling Services +N/-S +E:-\V Sonhing Easing Latittude Longitude Slot 0.00 0.00 5945998 64 558776.16 70° U'47 036N 149°31'2239W Project: Kuparuk River Unit Site: Kuparuk 1 J Pad zooo Well: Plan 1 J-105 Wellbore: 1J-105 L2 10 3/4" Casi ng @ 3294' MD, 2250' TVD~ 2066' FEL, 783' FEL -Sec35-TI I N-RIDE Plan: 1 J-105 L2 (wp04) lsoo o 0 SHL: 2187 FSL, 243Y FEL -Sec35-T7 ~, 1N-RIOE ~ ,a r i '~ ° J 1000 r r r r I ~O 500 i r r 35~\~ ~ r ~O r r s I ~O ~ ~J` ~ 0 250 " ' ' ' ~ - - ' - - - - - - - - - I J-1 O5 D Top 01; 09:07 L2 - 7 5/8 TOW @ 7092 MD, 3662 TVD: 2100 FSL, 1916 FWL - Sec36-T11N-RI OE -500 i 11-105 ',1B DCPI 01.19p i -1000 ~~ -1500 - - - - - - - IJ-105 MB D CP201/1910 ° _ o -c -2000 0 a -2500 ------- IJ-105 \II3 DCP3 6119.0 -3000 ______- IJ-105\113 DCP~0119 ii -3500 - ------- 11-105 MB DCP501/19,U -4000 L2 - BHL @ 11521' MD, 3562' TVD: 2319' FN4 2120' FWL - SecOl-Tl ON-RIDE -4500 ~~~~~~~---- ~______ ---- ll-IOSDToeOlil9/OJ 4 I/2" ~ i Plan 1J-105/I1-105 L2 (wp04) -5000 - CASING DETAIL S No MD TVD TVDss Natne Sizc T - l 3293.57 2250.00 2 7092.06 3662.00 - 11521.11 3562.00 2141.00 10 3/4" 10-3/4 355-3.00 7 5/8" TOW 7-5/8 3453.00 41/2" 4-I/2 M Azimuths to True North Magnetic North: 24.04° -5500 - Magnetic Field Strength: 57564.3nT Dip Angle: 80.77° Date: 7/5/2006 - Model: BGGM2005 6000 - -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 ~nnn «nn 6000 b-~ West(-)/East(+) (900 ft/in) ConocoPhillips Alaska ORIGINAL CanvcoPhil~ips Alaska Halliburton Company Planning Report -Geographic • Epee-ry DEillirtg ~iervices Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 ~~ Company: ConoCOPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 9J Pad North Reference: True Well: ~ Plan 1J-105 Survey Calculation Method: Minimum Curvature Wellbore: 1J-105 L2 Design: 1J-105 L2 (wp04) Project Kuparuk River Unit, North Slope Alaska, U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-105 Well Position +N/-S 0.00 ft Northing: 5,945,998.64ft Latitude: 70° 15' 47.036" N +E/-W 0.00 ft Easting: 558,776.16 ft Longitude: 149° 31' 29.390" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-105 L2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 7/5/2006 24.04 80.77 57,564 -- Design 1J-105 L2 (wp04) ~ ~~ Audit Notes: Version: Phase: PLAN Tie On Depth: 7,092.04 Vertical Section: Depth From (TVD} +N/-S +EI-W Direction (ft) (ft) Ift,) (°) 28.00 0.00 0.00 180.00 Plan Summary Measured Vertical Dogleg Build Turn Depth In clination Azimuth Depth +N/-S +E!-W Rate Rate Rate TFO (ft) (") (°) (ft) ift) (ft) (°1100ft) (°1100ft) (°/100ft) (°) 7,092.04 78.00 179.32 3,662.00 -85.58 4,347.73 0.00 0.00 0.00 0.00 7,104.04 79.91 179.32 3,664.30 -97.36 4,347.87 15.90 15.90 0.00 0.00 7,134.04 79.91 179.32 3,669.55 -126.89 4,348.22 0.00 0.00 0.00 0.00 7,402.90 95.26 174.33 3,680.87 -394.21 4,363.11 6.00 5.71 -1.85 -18.15 7,514.64 95.26 174.33 3,670.63 -504.94 4,374.09 0.00 0.00 0.00 0.00 7,661.19 92.54 177.80 3,660.67 -650.77 4,384.11 3.00 -1.85 2.36 128.03 8,511.19 92.54 177.80 3,623.00 -1,499.31 4,416.71 0.00 0.00 0.00 0.00 8,554.37 92.11 177.80 3,621.25 -1,542.42 4,418.36 1.00 -1.00 0.00 179.91 9,811.59 92.11 177.80 3,575.00 -2,797.86 4,466.58 0.00 0.00 0.00 0.00 9,894.71 91.28 177.87 3,572.54 -2,880.89 4,469.72 1.00 -1.00 0.08 175.39 10,277.24 91.28 177.87 3,564.00 -3,263.06 4,483.95 0.00 0.00 0.00 0.00 10,451.06 90.42 176.35 3,561.41 -3,436.64 4,492.71 1.00 -0.49 -0.87 -119.45 10,911.81 90.42 176.35 3,558.00 -3,896.44 4,522.01 0.00 0.00 0.00 0.00 11,011.93 89.55 176.84 3,558.02 -3,996.38 4,527.95 1.00 -0.87 0.49 150.62 11,521.12 89.55 176.84 3,562.00 -4,504.78 4,555.97 0.00 0.00 0.00 0.00 2/23/2007 10:22:09AM Page 2 of 6 COMPASS 2003.11 Build 48 ~t 1 +~ i Halliburton Company ~--~,~4,~~. ~~,>~~'i° CCJI'1C?CC?~~'11~[~5 Planning Report -Geographic p~~}~ Sperry Drilling Services Database: Company: Project: Site: Well: Welibore: Design: Planned Survey 1J-105 L2 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (') (°) (ft) (ft) (ft) (ft) fft) (ft) (°l100ft) (ft) 7,092.04 78.00 179.32 3,662.00 3,553.00 -85.58 4,347.73 5,945,947.00 563,124.00 0.00 85.58 L2 - 7 5/8" TOW @ 7092' MD, 3662' TVD: 2100' FSL, 1916' FWL - Sec36-T11N-R10E - W Sak D - 7 5/8" TOW - 1J-105 114 Mile Heel -1J-705 1 7,100.00 79.27 179.32. 3,663.57 3,554.57 -93.39 4,347.82 5,945,939.20 563,124.15 15.90 93.39 7,104.04 79.91 179.32 3,664.30 3,555.30 -97.36 4,347.87 5,945,935.23 563,124.23 15.90 97.36 7,119.46 79.91 179.32 3,667.00 3,558.00 -112.54 4,348.05 5,945,920.05 563,124.53 0.00 112.54 1J-105 MB D CPi 01f 99/07 7,134.04 79.91 179.32 3,669.55 3,560.55 -126.89 4,348.22 5,945,905.70 563,124.81 0.00 126.89 7,183.34 82.72 178.39 3,677.00 3,568.00 -175.61 4,349.20 5,945,856.99 563,126.17 6.00 175.61 1J-105 MB D Heel 01/19/07 7,200.00 83.67 178.08 3,678.97 3,569.97 -192.15 4,349.70 5,945,840.47 563,126.81 6.00 192.15 7,300.00 89.38 176.23 3,685.03 3,576.03 -291.79 4,354.66 5,945,740.87 563,132.54 6.00 291.79 7,400.00 95.09 174.39 3,681.13 3,572.13 -391.34 4,362.82 5,945,641.41 563,141.48 6.00 391.34 7,402.90 95.26 174.33 3,680.87 3,571.87 -394.21 4,363.11 5,945,638.53 563,141.78 6.00 394.21 7,500.00 95.26 174.33 3,671.98 3,562.98 -490.43 4,372.65 5,945,542.40 563,152.08 0.00 490.43 7,514.64 95.26 174.33 3,670.63 3,561.63 -504.94 4,374.09 5,945,527.91 563,153.63 0.00 504.94 7,600.00 93.68 176.36 3,663.99 3,554.99 -589.75 4,380.99 5,945,443.16 563,161.19 3.00 589.75 7,661.19 92.54 177.80 3,660.67 3,551.67 -650.77 4,384.11 5,945,382.18 563,164.78 3.00 650.77 7,700.00 92.54 177.80 3,658.95 3,549.95 -689.51 4,385.60 5,945,343.45 563,166.57 0.00 689.51 7,800.00 92.54 177.80 3,654.52 3,545.52 -789.34 4,389.43 5,945,243.66 563,171.19 0.00 789.34 7,900.00 92.54 177.80 3,650.09 3,541.09 -889.17 4,393.27 5,945,143.88 563,175.80 0.00 889.17 8,000.00 92.54 177.80 3,645.65 3,536.65 -989.00 4,397.10 5,945,044.09 563,180.42 0.00 989.00 8,100.00 92.54 177.80 3,641.22 3,532.22 -1,088.83 4,400.94 5,944,944.31 563,185.03 0.00 1,088.83 8,200.00 92.54 177.80 3,636.79 3,527.79 -1,188.65 4,404.77 5,944,844.52 563,189.64 0.00 1,188.65 8,300.00 92.54 177.80 3,632.36 3,523.36 -1,288.48 4,408.61 5,944,744.74 563,194.26 0.00 1,288.48 8,400.00 92.54 177.80 3,627.93 3,518.93 -1,388.31 4,412.44 5,944,644.95 563,198.87 0.00 1,388.31 8,500.00 92.54 177.80 3,623.50 3,514.50 -1,488.14 4,416.28 5,944,545.16 563,203.48 0.00 1,488.14 8,511.19 92.54 177.80 3,623.00 3,514.00 -1,499.31 4,416.71 5,944,534.00 563,204.00 0.00 1,499.31 1J-105 MB D CP2 011 19/07 8,554.37 92.11 177.80 3,621.25 3,512.25 -1,542.42 4,418.36 5,944,490.91 563,205.99 1.00 1,542.42 8,600.00 92.11 177.80 3,619.57 3,510.57 -1,587.99 4,420.11 5,944,445.36 563,208.10 0.00 1,587.99 8,700.00 92.11 177.80 3,615.89 3,506.89 -1,687.85 4,423.95 5,944,345.54 563,212.71 0.00 1,687.85 8,800.00 92.11 177.80 3,612.21 3,503.21 -1,787.70 4,427.78 5,944,245.73 563,217.33 0.00 1,787.70 8,900.00 92.11 177.80 3,608.53 3,499.53 -1,887.56 4,431.62 5,944,145.91 563,221.94 0.00 1,887.56 9,000.00 92.11 177.80 3,604.86 3,495.86 -1,987.42 4,435.45 5,944,046.09 563,226.55 0.00 1,987.42 9,100.00 92.11 177.80 3,601.18 3,492.18 -2,087.28 4,439.29 5,943,946.28 563,231.17 0.00 2,087.28 9,200.00 92.11 177.80 3,597.50 3,488.50 -2,187.14 4,443.12 5,943,846.46 563,235.78 0.00 2,187.14 9,300.00 92.11 177.80 3,593.82 3,484.82 -2,287.00 4,446.96 5,943,746.65 563,240.40 0.00 2,287.00 9,400.00 92.11 177.80 3,590.14 3,481.14 -2,386.86 4,450.79 5,943,646.83 563,245.01 0.00 2,386.86 9,500.00 92.11 177.80 3,586.46 3,477.46 -2,486.71 4,454.63 5,943,547.01 563,249.62 0.00 2,486.71 9,600.00 92.11 177.80 3,582.78 3,473.78 -2,586.57 4,458.46 5,943,447.20 563,254.24 0.00 2,586.57 9,700.00 92.11 177.80 3,579.10 3,470.10 -2,686.43 4,462.30 5,943,347.38 563,258.85 0.00 2,686.43 9,800.00 92.11 177.80 3,575.43 3,466.43 -2,786.29 4,466.13 5,943,247.57 563,263.47 0.00 2,786.29 9,811.59 92.11 177.80 3,575.00 3,466.00 -2,797.86 4,466.58 5,943,236.00 563,264.00 0.00 2,797.86 1J-105 MB D CP3 01( 19107 9,894.71 91.28 177.87 3,572.54 3,463.54 -2,880.89 4,469.72 5,943,153.01 563,267.79 1.00 2,880.89 9,900.00 91.28 177.87 3,572.42 3,463.42 -2,886.17 4,469.91 5,943,147.73 563,268.03 0.00 2,886.17 2/23/2007 10:22:09AM Page 3 of 6 COMPASS 2003.11 Build 48 Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Kuparuk 1J Pad North Reference: True Plan 1J-105 Survey Calculation Method: Minimum Curvature 1 J-105 L2 1 J-105 L2 (wp04) OR161NAL i ~,- `'~' Halliburton Company ~'t~~..L.l %T~:t C01'1©COPfII~~ipS Planning Report -Geographic Alaska Sperry Drilling Services Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Sitc: Kuparuk 1J Pad North Reference: True Wcll: Plan 1J-105 Survey Calculation Method: Minimum Curvature Wellbore: 1J-105 L2 Design: 1J-105 L2 (wp04) ~ Planned Survey 1J-105 L2 (wp04) Map Map MD Inclination Azimuth 7VD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section I (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/10otY) (ft) 10,000.00 91.28 177.87 3,570.19 3,461.19 -2,986.08 4,473.63 5,943,047.86 563,272.53 0.00 2,986.08 10,100.00 91.28 177.87 3,567.96 3,458.96 -3,085.98 4,477.35 5,942,948.00 563,277.02 0.00 3,085.98 10,200.00 91.28 177.87 3,565.72 3,456.72 -3,185.89 4,481.07 5,942,848.14 563,281.52 0.00 3,185.89 10,277.24 91.28 177.87 3,564.00 3,455.00 -3,263.06 4,483.95 5,942,771.00 563,285.00 0.00 3,263.06 1J-105 MB D CP4 01/19/07 10,300.00 91.17 177.67 3,563.51 3,454.51 -3,285.80 4,484.83 5,942,748.27 563,286.06 1.00 3,285.80 10,400.00 90.68 176.80 3,561.91 3,452.90 -3,385.66 4,489.66 5,942,648.45 563,291.67 1.00 3,385.66 10,451.06 90.42 176.35 3,561.41 3,452.41 -3,436.64 4,492.71 5,942,597.51 563,295.11 1.00 3,436.64 10,500.00 90.42 176.35 3,561.05 3,452.05 -3,485.47 4,495.82 5,942,548.71 563,298.61 0.00 3,485.47 10,600.00 90.42 176.35 3,560.31 3,451.31 -3,585.27 4,502.18 5,942,448.98 563,305.74 0.00 3,585.27 10,700.00 90.42 176.35 3,559.57 3,450.57 -3,685.06 4,508.54 5,942,349.24 563,312.88 0.00 3,685.06 10,800.00 90.42 176.35 3,558.83 3,449.83 -3,784.86 4,514.90 5,942,249.51 563,320.02 0.00 3,784.86 10,900.00 90.42 176.35 3,558.09 3,449.09 -3,884.65 4,521.26 5,942,149.78 563,327.16 0.00 3,884.65 10,911.81 90.42 176.35 3,558.00 3,449.00 -3,896.44 4,522.01 5,942,138.00 563,328.00 0.00 3,896.44 1J-105 MB D CP5 01/19/07 11,000.00 89.66 176.79 3,557.94 3,448.94 -3,984.47 4,527.28 5,942,050.02 563,333.96 1.00 3,984.47 11,011.93 89.55 176.84 3,558.02 3,449.02 -3,996.38 4,527.95 5,942,038.12 563,334.72 1.00 3,996.38 11,100.00 89.55 176.84 3,558.71 3,449.71 -4,084.31 4,532.79 5,941,950.23 563,340.25 0.00 4,084.31 11,200.00 89.55 176.84 3,559.49 3,450.49 -4,184.16 4,538.30 5,941,850.44 563,346.53 0.00 4,184.16 11,300.00 89.55 176.84 3,560.27 3,451.27 -4,284.00 4,543.80 5,941,750.65 563,352.82 0.00 4,284.00 11,400.00 89.55 176.84 3,561.05 3,452.05 -4,383.85 4,549.30 5,941,650.86 563,359.10 0.00 4,383.85 11,500.00 89.55 176.84 3,561.83 3,452.83 -4,483.69 4,554.81 5,941,551.07 563,365.38 0.00 4,483.69 11,521.12 89.55 176.84 3,562.00 3,453.00 -4,504.78 4,555.97 5,941,530.00 563,366.71 0.00 4,504.78 L2 - BHL @ 11521' MD, 3562' TVD: 2319' FNL, 2120' FWL - Sec01-T10N -R10E - 4 1/2" - 1J-105 D Toe 01/19/07 2/23/2007 10:22:09AM Page 4 of 6 COMPASS 2003.11 Build 48 n ]g; .. '.-. A Cc~nQCOPh~[fips Rlaska Halliburton Company Planning Report -Geographic • .,~.~" Sperry Drilfiing Services Database: Compass 2003.11 Company: ConocoPhillips Alaska, Inc Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-105 Wellbore: 1J-105 L2 Design: 1J-105 L2 (wp0~1i Local Co-ordinate Reference: Well Plan 1J-105 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: I rue Survey Calculation Method: lviinimum Curvature Geologic Targets 1J-105 L3 ND (ft> 3,677.00 - Polygon Point 1 Point 2 3,662.00 -Circle (radius 1,320.00) 3,558.00 - Polygon Point 1 Point 2 3,564.00 - Polygon Point 1 Point 2 3,667.00 - Polygon Point 1 Point 2 3,562.00 - Point 3,662.00 - Point 3,623.00 - Polygon Point 1 Point 2 3,662.00 -Circle (rad ius 1,320.00) 3,575.00 - Polygon Point 1 Point 2 Target Name +N/-S +E/ W Northing Eastiny -Shape ft ft (ft) (ftJ 1J-105 MB_D Heel 01/19/07 -85.59 4,347.73 5,945,947.00 563,124.00 0.00 0.00 5,945,947.00 563,124.00 -424.48 11.69 5,945,523.00 563,139.00 1J-105 1/4 Mile Toe -4,695.96 4,575.77 5,941,339.00 563,388.00 1J-105 MB_D CP5 01/19!07 -3,896.44 4,522.01 5,942,138.00 563,328.00 0.00 0.00 5,942,138.00 563,328.00 -608.36 33.97 5,941,530.00 563,366.71 1J-105 MB_D CP4 01/19/07 -3,263.06 4,483.95 5,942,771.00 563,285.00 0.00 0.00 5,942,771.00 563,285.00 -633.41 38.06 5,942,138.00 563,328.00 1J-105 MB_D CP1 01/19/07 -509.73 4,359.42 5,945,523.00 563,139.00 0.00 0.00 5,945,523.00 563,139.00 -989.74 57.29 5,944,534.00 563,204.00 1J-105 D Toe 01/19/07 -4,504.78 4,555.97 5,941,530.00 563,366.71 1J-105 D Top 01/09!07 -85.59 4,347.73 5,945,947.00 563,124.00 1J-105 MB_D CP2 01/19/07 -1,499.31 4,416.71 5,944,534.00 563,204.00 0.00 0.00 5,944,534.00 563,204.00 -1,298.63 50.87 5,943,236.00 563,265.00 1J-105 1/4 Mile Heel -85.59 4,347.73 5,945,947.00 563,124.00 1J-105 MB_D CP3 01/19/07 -2,797.86 4,466.58 5,943,236.00 563,264.00 0.00 0.00 5,943,236.00 563,264.00 -465.21 17.37 5,942,771.00 563,285.00 Prognosed Casing Points Measured Depth (ftj 3,293.57 7,092.06 11,521.11 Vertical Casing Hole Depth Diameter Diameter (ft) (~~) ~~~) 2,250.00 10-314 13-112 3,662.00 7-5/8 9-7/8 3,562.00 4-1/2 6-3/4 2/23/2007 10:22:09AM Page 5 of 6 COMPASS 2003.11 Build 48 ~Cll'1000P~"1i~~I~S Alaska • Halliburton Company Planning Report -Geographic Sperry Ciriiling Servioes atabase: ....._ Compass 2003 11 ompany: ConocoPhillips Alaska, Inc. roject: Kuparuk River Unit to Kuparuk 1J Pad 'ell: Plah 1J-105 cllbore: 1J-105 L2 esign: 1 J 105 12 ~wp04) Local Co-ordinate Reference: Well Plan 1J-105 ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth (ft) {°) (°) (ft) 1,648.94 47.24 56.34 1,512.00 1,876.16 53.76 56.34 1,660.00 2,561.79 66.64 58.76 1,960.00 3,293.57 66.70 67.00 2,250.00 4,947.61 65.84 96.03 2,910.00 5,830.31 68.13 134.13 3,266.00 5,980.64 68.13 134.13 3,322.00 6,347.45 69.87 147.85 3,455.00 7,092.04 78.00 179.32 3,662.00 +N/-E +E/-VII (ft) (ft) Name 301.03 387.17 Pfrost 396.48 530.50 T3 734.75 1,043.66 K15 1,027.24 1,647.66 Casing Pt 1,291.13 3,127.83 Ugnu C 951.23 3,843.76 Ugnu B 854.09 3,943.89 Ugnu A 594.82 4,165.04 K 13 -85.58 4,347.73 W Sak D Pian Annotations Measured Vertical Depth Depth (ft) (ft) 7,092.05 3,662.00 11,521.11 3, 562.00 Local Coordinates +N/-S +El-W Comment (ft) (ft) -85.59 4,347.73 L2 - 7 5/8" TOW @ 7092' MD, 3662' ND: 2100' FSL, 1916' FWL - Sec36-T1 -4,504.77 4,555.97 L2 - BHL @ 11521' MD, 3562' ND: 2319' FNL, 2120' FWL - Sec01-T10N-R1( 2/23/2007 10:22:09AM Page 6 of 6 COMPASS 2003.11 Build 48 :J ConocoPhillips Alaska • Plan: 1J-105 L2 (wp04) Sperry Drilling Services Anticollision Summary 23 February, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-105 1J-105 L2 Local Coordinate Origin: Centered on Well Plan 1J-105 Viewing Datum: Plan RKB @ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~~ ~ ~:~ .'~ a ,__ _. - Sperry Driifir~g ;3ervice~ f JRIGINAL StIRVEI' PROGR~IM COMPANY DETAILS: ConocoPhillips Alaska, Inc. ANTI-COLLISION SETTINGS Date: 2007-02-21700:00:00 Validated: 1'es Version: Engineering Interpolation Method: MD Interval: SOStations Calculation Method: Minimum Curvature Depth Range From: 7092.04 To 11521.1193581 Depth FromDepth't'o Survey/Plan Tool Error System: ISCWSA Maximum Range:1349.31193026007 28.00 800.00 CSGY'RO-SS Scan Method: Trav. Cylinder North Reference: Plan: 1J-105 L2 (wp04) 800.00 7092.04 MW'D+IFR-AI:-C.4LrSC Error Surtace: Elliptical Conic 7092.0411521.12 1J-l0i L2 (wp04) MWD+IFK-A6-CA~SC Warning Method: Rules Based 1 J-14 1ao so Travelling Cylinder Azimuth (TFO+AZI) (°J vs Centre to Centre Separation J150 ft/inJ NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-105 Ground Level: 81.00 +N/-S+E/•W Northing Easting Latittude Longitude Slot 0.00 0.00 5945998.64 558776.16 70°15'47.036N 149°31'29.39W REFERENCE INFORMATION Coordinate (N/E) Reference: Well Plan 1J-105, True North Vertical (TVD) Reference: Plan RKB @ 109.OOft (Doyon 141 (28+g1)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Plan RKB @ 109.OOft (Doyon 741(28+81)) Calculation Method: Minimum Curvature From Colour To MD I 0 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 --- -- 1750 1750 2000 2000 2250 2250 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 --- -- 8000 8000 9000 9000 10000 10000 13900 0 1ao 90 Travelling Cylinder Azimuth (I'F(}+AZI) ~°) vs Centre to Centre Separation [50 ft/in) Sac MD Inc Av ND ~W-5 ~E/~W DLe9 TFac° V9ec Targel 1 ]09204 ]800 1]9.32 3862.00 445.58 434].]3 0.00 0.00 BS.SB 2 ]10404 ]9.91 1]9.32 3664.30 -9)36 434].8] 15.% 0.00 9].36 3 ]134.04 ]9.91 1]9.32 %6955 -126.89 4348.22 0.00 0.00 126.89 4 ]402.90 95.26 1]4.33 %00 B] -394.21 4363.11 8.00 -18.15 394.21 5 )51464 %.26 1]4.33 36]0.63 -509.94 43]4.09 0.00 000 504.94 6 )%1.19 9Z 54 1]].80 36606) -650.)] 4384,11 3.00 128.03 650.]) 851119 92.54 1]]80 3623.00 -1499.31 4416)1 000 0.00 14%.31 1J-105 M8_D °P201119/0] B 85543] 92.11 17780 362125 -1542 d2 941036 1.00 1]991 1542.42 9 901155 92.11 1]]80 35]500 -2]9).86 4466.58 0.00 000 2)9).% 1J-105 MB DDP301119I0] 10 %9d ]1 9128 1)]8] 35]354 -2880.89 4469.]2 1.00 1]539 2080.89 - 11 102]]24 91.28 1)]8] 356400 -3263.06 448J% 0.00 000 326306 1J-105 M8_D CP401I19I0] 12 1045106 %.42 1)6.35 356141 -3436.69 4492.)1 1.00 -119.45 J4%64 50.42 1]6.35 355800 -38%44 952201 0.00 0.00 38%d0 1J-105 MB_D CPS Otl19/O) 11011.93 89.55 1)684 355802 -39%38 452]% 1.00 150.62 3996.38 to 11521.12 89.55 1]6.84 356200 -0504.)8 45559] 0.00 0.00 4504.]8 1J-105 DT°e 01/19'0] ',~-~ CC)l10~C~~F11~fIpS Alaska Halliburton Company Anticollision Report i,=w.:~..t,.1 a ~ ~3 Sperry Drilling Services Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-105 ~ Project: Kuparuk River Unit TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-105 L2 Database: Compass 2003.11 Reference Desiyn: 1J-105 L_2 (wp04) Offset TVD Reference: Offset Datum Reference 1J ii~5 L2 (wp04) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 7,092.04 to 11,521.12ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,349.31ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program From (ft) 28.00 800.00 7,092.04 Date 2/23/2007 To (ft) Survey (Wellhore} 800.00 1J-105 (wp04/ (1J-105) 7,092.04 1J-105 (wp04) (1J-105) 11,521.12 1J-105 L2 (wp04) (1J-105 L2) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 5:49:48PM Page 2 of 5 COMPASS 2003.11 Build 48 ORIGINAL • -` C4!"1 d CC3 ~ `fi't l ~ ~ 1 ~ 5 Alaska ~~ra~u~~~ti ,,. ;m Company: ConocoPhillips Alaska, Inc. I Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Well Error: Reference Wellbore i Reference Design: Plan 1J-105 O.OOft 1J-105 L2 1J-105 L2 (wp04) Halliburton Company Anticollision Report • Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-105 ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: Compass 2003.11 Offset ND Reference: Offset Datum Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well -Wellbore -Design (ft) (ft) (ft) No-Go Allowable Distance Deviation Warning (it) from Plan (ff) KuparuklJ I'ad 1J-102 - 1J-102 - 1J-102 Out of range 1J-102 - 1J-102 L1 - 1J-102 L1 Out of range 1J-102 - 1J-102 L2 - 1J-102 L2 Out of range 1J-102 - 1J-102 L2 PB1 - 1J-102 L2 P61 Out of range 1J-102 - 1J-102 L2 PB2 - 1J-102 L2 PB2 Out of range 1J-102 - 1J-102 PB1 - 1J-102 PB1 Out of range 1J-102 - 1J-102 PB2 - 1J-102 PB2 Out of range 1J-102 - 1J-102 PB3 - 1J-102 PB3 Out of range 1J-109 - 1J-109 - 1J-109 Out of range 1J-109 - 1J-109 PB1 - 1J-109PB1 Out of range 1J-109 -Plan 109a L1 - 1J-109a L1 (wp02) 11,500.49 11,882.72 1,188.75 210.88 977.87 Pass -Major Risk 1J-109 -Plan 1J-109a - 1J-109a (wp02) 11,446.54 11,833.05 1,211.29 222.95 988.33 Pass -Major Risk 1J-109 -Plan 1J-109a L2 - 1J-109a L2 (wp02) 11,444.76 11,824.14 1,185.50 215.70 969.80 Pass -Major Risk 1J-115 - 1J-115 - 1J-115 Out of range 1J-115 - 1J-115L1 - 1J-115L1 Out of range 1J-115 - 1J-115L1PB1 - 1J-115L1PB1 Out of range 1J-115- 1J-115L1PB2 - 1J-115L1PB2 Out of range 1J-115 - 1J-115L2 - 1J-115L2 Out of range 1J-115 - 1J-115L2PB1 - 1J-115L2PB1 Out of range 1J-115 - 1J-115L2PB2 - 1J-115L2PB2 Out of range 1J-115 - 1J-115PB1 - 1J-115PB1 Out of range 1J-115 - 1J-115PB2 - 1J-115PB2 Out of range 1J-115 - 1J-115PB3 - 1J-115PB3 Out of range 1J-115 - 1J-115PB4 - 1J-115PB4 Out of range 1 J-14 - 1 J-14 - 1 J-14 11,249.11 7,450.00 408.98 159.41 249.57 Pass -Major Risk 1J-152 - 1J-152 - 1J-152 Out of range 1J-152 - 1J-152 L1 - 1J-152 L1 Out of range 1J-152 - 1J-152 L2 - 1J-152 L2 Out of range 1J-152 - 1J-152 L2 P61 - 1J-152 L2 PB1 Out of range 1J-152 - 1J-152 PB1 - 1J-152 P61 Out of range 1J-152 - 1J-152 PB2 - 1J-152 P62 Out of range 1J-154 - 1J-154 - 1J-154 Out of range 1J-154 - 1J-154 L1 - 1J-154 L1 Out of range 1J-154 - 1J-154 L2 - 1J-154 L2 Out of range 1J-156 - 1J-156 - 1J-156 Out of range 1J-156 - 1J-156L1 - 1J-156L1 Out of range 1J-156 - 1J-156L1 P61 - 1J-156L1PB1 Out of range 1 J-156 - 1 J-156L2 - 1 J-156L2 Out of range 1J-159 - 1J-159 - 1J-159 Out of range 1J-159 - 1J-159 L1 - 1J-159 L1 Out of range 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 P61 Out of range 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 Out of range. 1J-159 - 1J-159 L2 - 1J-159 L2 Out of range 1J-159 - 1J-159 PB1 - 1J-159 PB1 Out of range Plan 1J-105 - 1J-105 - 1J-105 (wp04) 7,100.00 7,100.00 0.09 0.60 -0.51 FAIL - No Errors Plan 1J-105 - 1J-105 L1 - 1J-105 L1 (wp04) 7,100.00 7,100.00 0.09 0.60 -0.51 FAIL - No Errors Plan 1J-107 -Plan 1J-107 - 1J-107 (wp03) 11,512.47 11,950.00 1,206.35 201.90 1,004.45 Pass -Major Risk Plan 1J-107 -Plan 1J-107 L1 - 1J-107 L1 (wp03) 11,518.60 11,950.00 1,183.24 214.11 969.13 Pass -Major Risk Plan 1J-107 -Plan 1J-107 L2 (wp03) - 1J-107 L2 ~ 11,497.17 11,925.00 1,180.79 215.63 965.16 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (wp06) 7,798.60 5,999.99 841.51 124.35 717.15 Pass -Major Risk Plan 1J-120 -Plan 1J-120 L1 - 1J-120 L1 (wp06) _ 7,798.60 5,999.99 841.51 124.35 717.15 Pass - Ma~or Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 5:49:48PM Page 4 of 5 COMPASS 2003.11 Build 48 ~ ~~4 • r COCIOCOP~'t1~1~35 Alaska Company: ConocoPhillips Alaska. Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad i Site Error. O.OOft Reference Well: r?lan 1J-105 Well Error: c).OOft Reference Wellbore 1J-105 L2 ~ference Design: 1J-105 L2 (wp04) ~rnunary Site Name Offset Well -Wellbore -Design kuparuk 1J Pad Plan 1J-120 -Plan 1J-1 z0 Lz - 1J-120 L2 (wp06) Plan 1J-122 - 1J-122 L1 - 1J-122 L1 (wp03) Plan 1J-122 - 1J-122 L2 - 1J-122 L2 (wp03) Plan 1J-122 -Plan 1J-122 - 1J-122 (wp04) Plan 1 J-124 -Plan 1 J-124 - 1 J-124 (wp02) Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) Plan 1J-133 - 1J-133 - 1J-133 Intermediate Plan 1J-158 - 1J-158 - 1J-158 (wp07) Plan 1J-158 - 1J-158 L1 - 1J-158 L1 (wp07) Plan 1J-158 - 1J-158 L2 - 1J-158 L2 (wp07) Plan 1J-160 -Plan 1J-160 - 1J-160 (wp08) Plan 1J-160 -Plan 1J-160 L1 - 1J-160 L1 (wp08) Plan 1J-160 -Plan 1J-160 L2 - 1J-160 L2 (wp08) Rig: 1J-103 - 1J-103 - 1J-103 Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 Rig: 1J-103 - 1J-103 L1 PB1 - 1J-103 L1 PB1 Rig: 1 J-103 - 1 J-103 L2 - 1 J-103 L2 Rig: 1J-103 - 1J-103PB1 - 1J-103PB1 Rig: 1J-103 - 1J-103PB2 - 1J-103P62 Rig: 1J-103 - 1J-103PB3 - 1J-103P63 Rig: 1 J-118 - 1 J-118 - 1 J-118 Rig: 1J-118 - 1J-118 L1 - 1J-118 L1 Rig: 1J-118 - 1J-118 L1 - 1J-118 L1 (vvp07) Rig: 1J-118 - 1J-118 L2 - 1J-118 L2 Rig: 1 J-118 - 1 J-118 L2 - 1 J-118 L2 (wp07) Rig: 1J-118 - 1J-118 PB1 - 1J-118 PB1 Rig: 1 J-118 - 1 J-118 PB2 - 1 J-118 PB2 WSP-03 -WSP-03 -WSP-03 WSP-1S -WSP-1S -WSP-1S Halliburton Company Anticollision Report Sperry Grilling Services Local Co-ordinate Reference: Well Plan 1J-105 TVD Reference: Plan RKB @ 109.OOft (Doyen 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyen 141 (28+81 )) North Reference: Survey Calculation Method Output errors are at Database: Offset ND Reference: Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Depth Depth Distance (it) from Plart (ft) (ft) (ft) (ft) 7,798.Fi0 5,y99.99 841.51 124.35 717.15 8,392.97 6,000.00 1,127.82 124.02 1,003.80 8,392.97 6,000.00 1,127.82 124.02 1,003.80 8,200.94 5,950.00 1,092.39 122.46 969.93 8,698.93 6,050.00 1,136.72 128.51 1,008.20 11,227.91 7,425.00 398.12 171.73 226.39 7,225.33 6,400.00 1,233.57 103.30 1,130.28 7,207.41 6,375.00 1,233.38 102.23 1,131.15 7,207.42 6,375.00 1,233.44 102.67 1,130.76 7,337.86 6,550.00 1,220.14 104.79 1,115.35 7,225.33 6,400.00 1,233.57 103.29 1,130.28 7,225.33 6,400.00 1,233.57 103.30 1,130.28 7,225.33 6,400.00 1,233.57 103.30 1,130.28 7,109.91 5,525.00 697.50 94.62 602.88 7,109.91 5,525.00 697.50 95.18 602.32 7,113.91 5,550.00 682.92 97.58 585.34 7,109.91 5,525.00 697.50 94.47 603.02 7,113.91 5,550.00 682.92 97.58 585.34 7,109.91 5,525.00 697.50 94.49 603.01 7.109.97 5.525.00 697.51 94.62 602.89 Warning Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 5:49:48PM Page 5 of 5 COMPASS 2003.11 Build 48 • True Minimum Curvature 2.00 sigma Compass 2003.11 Offsei Daium ORIGIPJ^! oncaca~'hllips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1J-105 (wp04) 1/4 Mile Pool Scan Sperry Drilling Services February 23, 2007 X11/ HALLIBURTON Drilling and Formation Evaluation • iJ-105L rillin Hazard~Sumrna (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Lnterval Hazard Risk Level Miti anon Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ~~ ~ ~~` ~ ~ 1J-105L2 Drilling Hazards Summary. 2/23/2007 6:04 PM c ~~ 4~ va. d` 20" 94.0# x 34" Insulated Conductor, K-55, set at+/. 80' 10314" x 4112" Wellhead, 5,000 psf Tubing, 41/2", 12,8#, IBTM, Special Drift to +/• S00' 3.875" DB Nipple, for Possible SSSV, +/.500' ~_--- GLM, Camco KBMG, 41/2" X 1" GLM, Camco KBMG, 41/2" X 1" 10.3/4", 88#, BTC CMD Sliding Sleeve, w/ 3,81" DB Nipple, +/.1$ above seals Shoe set ~ 3293' MD, {{{ •''~ 2250' TVD / i Casing Sealbore Receptacle, 20' Lenofll Tubing String / 41/2" 12.0#, L•80, IBTM 3.958" ID, 3:833" Drift Seal 5412" X 7•S/8" ZXP Llhsr Assembly Top Packer w/ Holq 4A5" Seal C Downs ~a~a~ca-l~ilti 1Mest Sak 7-5/8" Injector 1J-105 Tri-Lateral Completion D•aand Window T ~t7092'MD,3662'TVD ~~ 'I)'S~ ateral Payzone ECP 4.1/2" 11.6# L•80 Slotted Liner Every Other Joint ,` \ ~ i 4.1/2" Guide Shoe /. ~ ~.~~ t7~"` •'°"•'^'//"'F. ~-4. 47/2" L ~ ho6„79eBA,'[.80 BTC ~ 5.1/T Tieback Sleev et @ 11. MD, 3562' TVD 4.112" X Seal Bores ~~`'•" 4.112" bent r Hash Model 'B'ROOK Hanger .3.68"ID - SealAesembly 5.1/2"X7•SIB"2XPLinerTop 4.75"SeaIOD Packer wl Hold Downs Lateral Entry Module(LEM) As Planned S Baker OIl Tools Lateral Entrv,~Qo I u M1 / Gar I ~ .~ Casing Sealbore B•aand WlOdtwv Jsn may be requlratlMhighly deviated 1&5'Dlverta Len th 9 ) 9 19.5'Sleeve Len th -r? Agsembly Receptacle ~ ~"~, ?t744Q'MD, 3728'TVD 'B' Sand Lateral °r deep appllaatloro (6'spproxlen th. 9 20' Length ~ d/ 4.1/2" 11.8# L•80 SioHed ..----- S 4Y2" X 7.518" ZXP Liner Top '~,t Pay=one ECP Liner Every Other Joint Packer with Hold Downs ~.-~=~. 44/2" X 7~/8" ~ •1/2 Guide Shoe Morbl'B' HOOK Hanna. ;: ` ..:::a .^`-.. .r~ ~--~_ Casing Sealbore Receptacle ~ ~/ ~i "` 41/2" Liner Shoe, 11.6#, L•80 BTC 4.75" ID ~ Set 11 53.68"IDs \5•V2" Tieback Sleeve ~ 565' MD, 3634' TVD ~` OHenBng.Proflle - \4.112"bent muleshoe `~,,,.- Automa0c Alignment of LEM 4412" 12.6# Tubin 3.562" DB Nipple 3.833" Ddft Poshive Latching Collet 3.958"Ip ~~~~~~~ +-•'•`` Indicates Corcect Location 5.1 f2"X7.5J6"2'J~ q' Seal Bore for Lateral Liner Top Pecker IsolaB on Seal Asembly ~ 7.518" 29.7# Casing, L-80, BTCM, Set .4.75"Seal OD 3.875"Seal ID ®eekx Nughas 2004 Thle doeumanl may nN ba raprodueao oralatrlfwbd, le wfiokarln fbn, At arty form or bl' aYI~S815'MD, 3850'TVD {84 deg). °"aT"~°' a`ry mesas Na lronk or mxhsnlcsl, Inclutling photoeotypig, reconbry, or by amr IMO,malbn ebraga antl nlrhValrygem now known aheroNer lnvanlW,vdlhaul wdaM pMmNsbn from Bekar Hughes NC. a"' Febn Eauiament Specifications Isolatlan • 3.68" ID whh Holtl Downs f Seal Assembly Lateral Ddtt, w/colt dlverter: 3.D0" / 4.75"Seel OD OD oT Diverter and Sleeve:+/.3.89" 'A' Sand U'ndulatina Lateral Dlverter and Sleeve Length:+/•18.5' !~ - Access Window S•1/2"X 75/8" Positive Lateral Access Yla Liner Han er /Packer Auembl at Flez Lock 4.1/2" 11.6# L•80 Slotted Thru•TUbing Dlverter 9 y Liner Han er Liner Eve Other Joint 44/2" Eccentric +1.7540'MD 9 ry ,~GUlde Shoe Seal Bore for Lateral Casing Sealbore Receptacle, Isolation • 3.68" ID 20' Length ' 4.1/2" Casing Shoa, 11.6#, L•80 BTC v,}~~,,;, ur Sst @ 11724' MD, 3850' TVD 1Ntth Diverters and Isolation Leterel Aaosss DNertar Latanl Isolatbn DWenu GS Running 7oN Stdng Installed Installed (3.00" Lateral DdftJ (2.SD" ID MNnbore Drtfl) 'GS'Proflle far ~ CNI Connector I . ~, ,rRunNnglRetdaving 1, ~ ~ Snap In1SnaP Out ~ .-Back Pressure Velva '~ i: i fPoaWve Locating'ti. I (1.60' Length) GoIIN y ~r ~'' rflow-Thru SwlvN ,;'~ Laterel bolatbn-" (126' Length) ~- Seals I _ ,: ~ Hydraulic i1 ~ /~~R mp rter ' . `. Dlswnnsct I t (1,60'Len9th) ~ IsolNlon/MNnbore~ ~ ~~ r,., GS 6pear ~ Dlverter Sleeve III ~~ (1.60'Langth) Latarel lsolatlon ~"° 8.98ft Approx. Seale ~ I i <I 4.1/2" X 7.5/8" HOOK Hanger Malnbore Drift 5.32" Malnbore Drift, with divertar: 4.83" Lateral OdR no diverter qr LEM: 3.88" Lateral Drift, w/ dlvarter, no LEM: 3.88" LaterallMalnbore Dlverter OD: 8.T5". 4-112" Lateral Entry Module Mafnbora Drift: 3.85" Malnbore Drltt, w/Isolation sleeve: 2:50" • • • • WALL iv~NtE ~G( /~- ~D5 G, Z PT~# ZO ~ ~ a2~' ®evelopment Service Exploratory Stratigraphic Pest Yon-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS ~L'HAT ~ (OPTIONS) APPLIES TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore se ent of existing ~ wel I ~ u ~' ~~ ~~ (If last two digits in I Permit No. ZO?-~2'7API No. 60-~9- Z33 ~ - 6~ i API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. i i PILOT HOLE . In accordance with 20 AAC 25.00~(f), a!1 records; data and. lobs ;acquired for the pilot hole must be clearly differentiated in both i ;well name ( PH) and API number (50- - -_) from records, data and logs i ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 12.055. Approval to perforate and produce /infect is contingent upon issuance of a conservation order approving a spacing j i ~ exception. assumes the ~ liability of any protest to the spacing exception that may occur. I ~ i ,DRY D[TCH ~ AlI dry ditch sample sets submitted to the Commission must be in i SA!~IPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. Please note the following special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the i Commission to obtain advance approval of such water well testing Rev: l '25%06 C:`jody~[ransmittal_checklist • • : ~ ~ ~ ~ ~ I rn o ~ m D ~ ~ a I , ° ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ a~, ~ ~ ~ ~ ~ p c N, v j ~ ¢ o , ~~ ~~ ~ 3 ~ ~ ~ ~~ ~ ~ ~ ~ ~~ ~ ~~ 3 ° ~ t i o c. 3. m. ~ •~-~ c o ' O! m ui I, N, ~ ~ E. 'c o m d m ', a m; a~i, ~ w 0 0. ~ N: ~ ~ c o ° m ~ m. ~ a E O o. T a~ o. ~ ~, t. ~, ~ a~ ~ m N; m. ° 3 ~ o Z .~ N. ~ o. 3. a~ ~ U. ~~ C L, ~. ~ ~ y. ~ Ili N• ~ ~ ~~ ~ ~, ~~ L. ~ ~ ~ ~ O' c .o' m. ~ ~ N •y, o. 3. ~ N o d U ..0. M. c C O ~ L ~~ 'O X ~ S _ U, G O, N v ~ ~ U ' -p~ N~ N' N' N _~ ~ ~ .O.I a~ a N' ~ L: N. C N~ 'O ~ ~ ~ C OD N• C,~ -`O N. 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C, O ~ 1 w : ~ rn 3 .~ ~ o •~ 3 0 ~ M ~~ ~~ ~ N. o: ~ ~ a =, d ~ o. ~ ~, a, ~, °, -o. .o- ~ U .c ~ m ~ m m m ~ ; ~ ui '. ~' c rn .°c. «f; E: a~ f0 °, o, ,~' ~ O' ~ '' m N ~'' c Z °, a~ d ° o. m. c o; °' o• ~ ¢ °' °' a~' a~ of .. Y ; _Z v o ._ v' o a~ ,~ ~ ~ a~ o' rn m' p. c ' c ~' c o ~ ', ~ o o v ~' ~~ o' v ~ f6 m c cM 3, o w. '~ ~ .., ~ a ~S' c m ~ o o ~' i o ~ ~, ~: T 5 0 c ~ v _o' m ~ vi o a ¢ o rn ° U' .n .o ~ o. ui o. a, 3. ~ y °. ~ Y ~~ '~, ~ ~ L O: ~. N ~C, T O 7 7 ~ 'O N ~, ~ Y O O. O O N. O O ~, f0 ~~ ~ Q N L N~ , >+ O Da O. N. ~ N g ~ d v m ~ .n o o m c~ ~.- Z° E° 3 a~ a~ L m 3 v a~' ~ Y , ¢ ~ ~; -o, m m. m. fl, fl; m w w, ~ m m v':. E a.°i `°' ~ ~ c ~ m. M ~ °, s m ~ y o d 3' i o ~ o >; ~ ~ o cn m v, ~ m 3 ~3. m o m .. o~ `~ v ~' 3 `°' d o d o ,o„ q- N' o. 3 ~' m m o' w ~ o a a s ,c 'm m -o. > ~ ~' o °' ~, o d .Q ~ m o L~ U p°. ~~ a: ° m ~ 'v ~ m a a?' o m m' ° m ~ ° c o a~' ° °' c: ~ o o' N: a' E' ami' m E t °~ o I ~' d w' °' c' -~' °~ n o~ ~~ m o, o ~ a~i; o~ u°i~ uoi. a _~ ~, aoi~~ v, ~~ a o' u? ai Y_~ ~°~ ai ~ o~, "a f0~ E~, ~ ~~~ N ", I ~~, c~ °' `~` o °2S = =' f6 (O 01 N' ~ V/ N 'C' r Vl, i m d N N f0 (6 O) (6 O ~ ~ ~ 'D O y C t pl ~°, ~, ~ .S, a d m ~ >; N' m a~, 0 3 ~ v rn. c c o~ ~ a~ c ~ m ~ ° a ~ ~ 0 3 0' $ ' a~ ~' >, m a- v. v -o. ~ Q ~, ~ w m m. > .~ r e v w :~ v j ~, ~ iL U ~ E a~ u3 a; ~ m ~ o t c c ~ c m N' -o -o o rn :°.' 3 ~ v c ° c m c: ~, '~. 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O a, a U ~' Q; a z I U N, U U, U U; ¢: ~- ¢, °_; o; m m; U ~: ~'', ~: a v, in, cn U ~ W a (~ _ ~ O ~ N M V ~ CO I~ W m O ~ N M C t0 (O t~ 00 O O ~ N M cf t!7 CO I~ W O ~- N M V tp (p I~ M O r r .-- r r r- ~ ~ ~ N N N N N N N N N N M M M M_ M M M_ M M _M U O _. _. ___ -_ --_.__ __..__ _____- __ _.. _... _.. .. _. _ _. ~ U d O N p N O C C ~ N l~6 N ~ N N U O W O IC ~ N C ^ M f ~ N O .N a ~ Y N ', •` N O E N •O J O ~ d ~'~ 01 U p .. ~ c ~ i o L U w~ E a LL ~ a w I° Q o d Q ¢ cn tL ¢ F- j ~ ¢ to Well f-iistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history fife. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1J105L2o04242007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 26 08:34:12 2007 Reel Header Service name .............LISTPE Date . ...................07/06/26 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date . ................... 07/06/26 Origin ................... 5T5 Tape Name. .... ........ UNKNOWN continuation Number...... 01 Previous Tape Name....... UNKNOwN Comments ................. STS LIS Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER; LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: c.rsc. ~v~~--C~g writing Library, scientific Technical services 1J-105 L2 500292334661 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-JUN-07 MWD RUN 2 MWD RUN 3 MWD RUN 13 w-0004912996 w-0004912996 w-0004912996 5. GREENE S. GREENE R. REPLOGLE G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 14 MWD RUN 15 w-0004912996 W-0004912996 R. REPLOGLE R. REPLOGLE G. WHITLOCK G. WHITLOCK ~ t Sir ~- 35 11N l0E 2186 2432 Page 1 • ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J105L2o0424200755N.txt 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3387.0 2ND STRING 6.750 7.625 7348.0 3RD STRING PRODUCTION STRING REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7348' MD/3645'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-105 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 13. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4, MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,14,15 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 14 ALSO INCLUDED AT- BIT INCLINATION (ABI), AND MWD RUN 15 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1-3,13-15 REPRESENT WELL 1J-105 L2 WITH API#: 50-029-23346-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11383'MD/3596'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). Page 2 17105L2004242007SSN.txt SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. .... ..1.0.0 Date of Generation.... .07/06/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPM RPS FET RPD ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3351.0 3371.0 3371.0 3371.0 3371.0 3371.0 3396.5 STOP DEPTH 11326.5 11333.5 11333.5 11333.5 11333.5 11333.5 11383.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3351.0 7071.0 3 7071.5 7348.0 13 7348.5 7380.0 14 7380.0 8442.0 15 8442.0 11383.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units .. .. ... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 Page 3 • 1)105L200424200755N.txt RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3351 11383 7367 16065 3351 11383 RPD MWD OHMM 0.02 2000 44.6247 15926 3371 11333.5 RPM MWD OHMM 4.31 2000 36.5475 15926 3371 11333.5 RPS MWD OHMM 0.46 201.6 33.7834 15926 3371 11333.5 RPX MWD OHMM 0.84 2000 32.7708 15926 3371 11333.5 FET MWD HOUR 0.19 589.74 1.38464 15926 3371 11333.5 GR MWD API 19.07 161.75 66.6127 15952 3351 11326.5 ROP MWD FT/H 0.19 1464.34 177.877 15974 3396.5 11383 First Reading For Entire File..........3351 .Last Reading For Entire File...........11383 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. .........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1,0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.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 3351.0 7071.0 RPM 3371.0 7071.0 RP5 3371.0 7071.0 RPx 3371.0 7071.0 RPD 3371.0 7071.0 FET 3371.0 7071.0 Page 4 • 17105L200424200755N.txt ROP 3396.5 7071.0 LOG HEADER DATA DATE LOGGED: 27-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7071.0 TOP LOG INTERVAL (FT): 3396.0 BOTTOM LOG INTERVAL (FT): 7071.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 82.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RE5I5. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3387.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.070 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Page 5 • 17105L2o04242007SSN.txt Name Service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 24 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 3351 7071 5211 7441 3351 7071 RPD MWD020 OHMM 3.64 2000 21.2179 7401 3371 7071 RPM MWD020 OHMM 4.31 2000 15.4362 7401 3371 7071 RPS MWD020 OHMM 0.46 201.6 13.1711 7401 3371 7071 RPX MWD020 OHMM 0.84 174.92 12.5591 7401 3371 7071 FET MWD020 HOUR 0.19 136.62 1.62178 7401 3371 7071 GR MWD020 API 19.07 161.75 63.5015 7441 3351 7071 ROP MWD020 FT/H 0.83 706.16 184.483 7350 3396.5 7071 First Reading For Entire File..........3351 Last Reading For Entire File...........7071 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7071.5 7348.0 RPD 7071.5 7348.0 FET 7071.5 7348.0 Page 6 ~ i 17105L2o042420075SN.txt RPX 7071.5 7348.0 RPM 7071.5 7348.0 ROP 7071.5 7348.0 RPS 7071.5 7348.0 LOG HEADER DATA DATE LOGGED: 29-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7348.0 TOP LOG INTERVAL (FT): 7071.0 BOTTOM LOG INTERVAL (FT): 7348.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.5 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3387.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT .MAX CIRCULATING TERMPERATURE: 5.070 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 7 • 17105L2o04242007SSN.txt Depth units. .. .. ..... 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 7071.5 7348 7209.75 554 7071.5 7348 RPD MWD030 OHMM 7.71 20.06 9.79417 554 7071.5 7348 RPM MWD030 OHMM 7.18 19.6 9.04328 554 7071.5 7348 RPS MWD030 OHMM 6.91 16.64 8.82874 554 7071.5 7348 RPX MWD030 OHMM 6.59 14.26 8.64989 554 7071.5 7348 FET MWD030 HOUR 0.34 23.5 0.799224 554 7071.5 7348 GR MWD030 API 68.79 107.62 91.9159 554 7071.5 7348 ROP MWD030 FT/H 3.12 1464.34 202.86 554 7071.5 7348 First Reading For Entire File..........7071.5 Last Reading For Entire File...........7348 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH -STOP DEPTH Page 8 17105L2o04242007SSN.txt ROP 7348.5 7380.0 LOG HEADER DATA DATE LOGGED: 22-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7380.0 TOP LOG INTERVAL (FT): 7348.0 BOTTOM LOG INTERVAL (FT): 7380.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.5 MAXIMUM ANGLE: 82.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7348.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 42.0 MUD PH: .O MUD CHLORIDES (PPM): 64000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 91.4 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 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 9 • • 17105L2o04242007SSN.txt ROP MWD130 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7348.5 7380 7364.25 64 7348.5 7380 ROP MWD130 FT/H 0.19 20.04 7.01453 64 7348.5 7380 First Reading For Entire File..........7348.5 Last Reading For Entire File...........7380 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 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: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7348.5 8378.0 FET 7348.5 8385.0 RPx 7348.5 8385.0 RPS 7348.5 8385.0 RPM 7348.5 8385.0 RPD 7348.5 8385.0 oP 7380.5 8442.0 $ LOG HEADER DATA DATE LOGGED: 22-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8442.0 TOP LOG INTERVAL (FT): 7380.0 Page 10 17105L2o04242007SSN.txt BOTTOM LOG INTERVAL (FT): 8442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 93.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 ABI AT-BIT INCLINATION 123943 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7348.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 92.0 MUD PH: ,Q MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3): 1.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 119.7 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .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 MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FT/H 4 1 68 28 8 Page 11 17105L200424200755N.txt First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7348.5 8442 7895.25 2188 7348.5 8442 RPD MWD140 OHMM 0.02 249.16 53.0641 2074 7348.5 8385 RPM MWD140 OHMM 9.85 129.89 44.3199 2074 7348.5 8385 RPS MWD140 OHMM 9.71 126.61 40.6418 2074 7348.5 8385 RPX MWD140 OHMM 6.87 772.45 39.2777 2074 7348.5 8385 FET MwD140 HOUR 0.27 589.74 2.50239 2074 7348.5 8385 GR MWD140 API 53.39 95.05 72.7164 2060 7348.5 8378 ROP MWD140 FT/H 1.27 294.61 177.025 2124 7380.5 8442 First Reading For Entire File..........7348.5 Last Reading For Entire File...........8442 File Trailer service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR RPX RPD FET RPM RP5 ROP LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 8378.5 8385.5 8385.5 8385.5 8385.5 8385.5 8442.5 SURFACE SOFTWARE VERSION: STOP DEPTH 11326.5 11333.5 11333.5 11333.5 11333.5 11333.5 11383.0 Page 12 24-APR-07 Insite • • 17105L2004242007SSN.txt DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11383.0 TOP LOG INTERVAL (FT): 8442.0 BOTTOM LOG INTERVAL (FT): 11383.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $$,6 MAXIMUM ANGLE: 92,( TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7348.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 73.0 MUD PH: ,Q MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3): 9.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 107.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction. .. ...............Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .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 MWD150 OHMM 4 1 68 4 2 RPM MWD150 OHMM 4 1 68 8 3 RPS MWD150 OHMM 4 1 68 12 4 RPX MWD150 OHMM 4 1 68 16 5 FET MWD150 HOUR 4 1 68 20 6 Page 13 • • 17105L2o04242007SSN.txt GR MWD150 API 4 1 68 24 7 ROP MWD150 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8378.5 11383 9880.75 6010 8378.5 11383 RPD MWD150 OHMM 5.51 1600.25 74.3053 5897 8385.5 11333.5 RPM MWD150 OHMM 9.79 1601.11 62.8934 5897 8385.5 11333.5 RPS MWD150 OHMM 20.73 115.63 59.585 5897 8385.5 11333.5 RPX MWD150 OHMM 24.55 2000 58.1148 5897 8385.5 11333.5 FET MwD150 HOUR 0.21 14.72 0.748889 5897 8385.5 11333.5 GR MWD150 API 43.52 98.77 66.0291 5897 8378.5 11326.5 ROP MWD150 FT/H 4.89 286.66 169.437 5882 8442.5 11383 First Reading For Entire File..........8378.5 Last Reading For Entire File...........11383 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/26 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................07/06/26 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EoF Physical EOF writing Library. scientific Technical services writing Library. Page 14 Scientific Technical services End Of LIS File 17105L2004242007SSN.txt Page 15
