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Home My WebLink About206-068 • OF T� gw\\\V�y ,• THE STATE Alaska Oil and Gas ,..4i ,,- � A o f Conservation Commission LAsKA mi, _ =_,,,,-., .,,, ,,_7__-:7=77- citt .5 - 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 h Main: 907.279.1433 0.A, ,,,min:-- Q, g$ Fax: 907.276.7542 www.aogcc.alaska.gov Robert Christensen NSK Production Engineering Specialist SCA" E17 , . 2. Li ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-156L1 Permit to Drill Number: 206-068 Sundry Number: 316-354 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cat243oerster Chair DATED this 2 day of July, 2016. RBDMS i-, --JUL 2 2 2016 • • RECEIVED • STATE OF ALASKA ,JUL 0 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION rj S )ZO 1 / APPLICATION FOR SUNDRY APPROVALS OG 'C 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate t'" Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: WINJ to WAG lam' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Exploratory r Development r 206-0680 • 3.Address: Stratigraphic j"' Service 1 . 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-23311-60 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA 1 Will planned perforations require spacing exception? Yes r No J'y KRU 1J-156L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025660;ADL025663 • Kuparuk River Field/West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ' 12963 • 3408 - 12924' - 3407' 943 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20 108' 108' SURFACE 2739' 10 3/4 2769' 2167' INTERMEDIATE 6046' 7 5/8 6072' 3490' B-SAND LINER 6687' 4 1/2 12925' 3408' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:6296-12885 • Slots:3407-3503 4 1/2 L-80 5675 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=CAMCO'DB'NIPPLE w/3.875 NO GO PROFILE = MD=497 TVD=496 SEAL ASSY=BAKER SBE SEAL ASSEMBLY - MD=5648 TVD=3412 12.Attachments: Proposal Summary F WellBore Schematic 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service '17 14.Estimated Date for 15. Well Status after proposed work: 07/20/16 OILWIND Suspended Commencing Operations: WDSPL p 16.Verbal Approval: Date: GAS r WAG 17, GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139t conocophillips.com Title: NSK Production Engineering Specialist Signature /4144 Date: '?../z /i FP Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: UR ^.,c Rug Integrity r BOP Test r Mechanical Integrity Test0.7'.--Location Clearance r Other: Post Initial Injection MIT Req'd? Yes No r Spacing Exception Required? Yes r No 'r Subsequent Form Required: !d„fog__ APPROVED BY Approved by:a/47 ��/._---> / COMMISSIONER 7TTHE COMMISSION Date: 7-22 tel` lin— ��`d�i f' AOC. !( '7�6 Submit Form and Form 10-403 Revised 11/20150 RAI61 Nvalid for 12 months from the date of approval. Attachments in Duplicate RBDMS -c- JUL 2 2 2016 / • • 1J-156L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-156L1 (PTD# 206-0680)from Water Only Injection Service to EOR Water Alternating Gas Injection service. Area of Review: West Sak well 1J-156L1 was completed as a Water Only Injector on July 7, 2006 to provide injection support into the West Sak B sands. Converting this well to a WAG injection well will provide enhanced recovery injection into the reservoir and increase the ultimate recovery of oil. This well will support existing producers 1 J- 152, 158, & 178. Area Map with Y4 mile radius around target injection zone (see attached): There are three wells which pentrate the Wsak interval within a 1/4 mile radius of 1J-156. Offset producer 1J- 152, and the production/injection pair 1J-180 & 182. The additional wells (158, & 178) are provided to give a complete picture of the developement area. Mechanical Condition of Well to be Converted: The mechanical condition of Wsak well 1 J-156 is good and is classified as a"Dual Casing -Trilateral"well. The injection tubing/casing annulus is isolated via a Baker ZXP Liner Top packer located at 5640' and (3411'tvd). Passed State-witnessed MIT-IA to 2010 psi was last performed on 16-MAY-14. KUP 1J-156L1 • COnOC ipS '.* Well Attributes Max Angle&MD TD Alaska.Inc Wellbore API/UWI Field Name Well Status Incl(") MD(ftKB) Act Btm(ftKB) tC.a,ocopt„Ibps' 500292331160 WEST SAK INJ 94.07 7,902.76 12,963.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date ••Well Con69:Multiple Laterals-1J-156L1,5/1720136 5522 AM $$51/:NIPPLE Last WO: 31.20 8/12/2006 Schernattc-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - ------- - Last Tag: Rev Reason:REVISE 11.6X/(Ds osborl 5/17/2013 HANGER,22 = 1111r """`" Casing Strings at '" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd CONDUCTOR, B-SAND LINER 41/2 3.476 6,238.3 12,925.1 3,407.6 11.60 L-80 BTC 26108 AS NIPPLE,497 Liner Details Top Depth (TVD) Top Incl Nomi... Top(RKB) IRKS) (") Item Description Comment ID(in) SU30 z,708RFACE, 6,238.3 3,497.2 90.34 SLEEVE BAKER'HR'LINER SETTING SLEEVE 5.500 GAS L,21IFT,1 6,290.4 3,497.1 89.89 XO BUSHING CROSSOVER BUSHING 3.930 3 12,885.5 3,407.6 90.13 XO Reducing 4.5"x3.5" 3.500 GAS LIFT, - 4.985 'Perforations&Slots SLEEVE-C, Shot 5,595 1 e Top)TVD) Btm)TVD) Dens Top(ftKB) Btm(RKB) (ftKB) (R1113) Zone Date (sh.. Type Comment LOCATOR, 6,296.0 6,425.0 3,497.1 3,499.3 WS B,1J-156L1 7/17/2006 32.0 SLOTS Alternating slotted/solid pipe 0.125"x SEAL ASSY. 2.5"x 32 spf @ 4 Circumferential 5648 adjacent rows,3"Centers staggered 18 deg.,3 ft non-slotted ends 6,641.0 6,985.0 3,499.1 3,486.2 WS B,1J-156L1 7/17/2006 32.0 SLOTS 7,370.0 7,802.0 3,496.9 3,502.6 WS B,1J-156L1 7/17/2006 32.0 SLOTS [(SAND LINER 8,062.0 8,494.0 3,489.1 3,474.0 WS B,1J-156L1 7/17/2006 32.0 SLOTS LEO,-\ 5,6405530 8,834.0 9,341.0 3,468.4 3,454.0 WS B,1J-156L1 7/17/2006 32.0 SLOTS D-SAND LINER HH, 9,595.0 10,105.0 3,442.6 3,431.2 WS B,1J-156L1 7/17/2006 32.0 SLOTS 5,6945,909 B-SAND LINER 10,359.0 10,870.0 3,428.6 3,431.2 WS B,1J-156L1 7/17/2006 32.0 SLOTS LEM, 6601-519eIIR 11,111.0 11,610.0 3,426.9 3,404.9 WS B,1J-156L1 7/17/2006 32.0 SLOTS BSAND LINER HH, /iiiin 8 11,857.0 12,885.0 3,407.2 3,407.6 WS B,1J-156L1 7/17/2006 32.0 SLOTS 6,070.6,283 SLOTS. ill 6,296-6,425 Notes:General&Safety SLOTS, End Date Annotation 6,641.6985 NTERMEDIATE, 7/28/2006 NOTE:MULTI-LATERAL WELL: 1J-156(A-SAND),1J-156L1(B-SAND),1J-156L2(D-SAND) 26-,961 W ii SLOTS, 7,370.7.802 B SLOTS, B B 8,062$494 • B B B R S SLOTS._ . B B 6,8349,341 pB B ft 51 ■ .-.-- SLOTS,_ . n 8 9595-15105 8 8 i a ■ P. B B 5 . SLOTS, - B 'a 10,359-10,870 B B i B B B B SLOTS, B 8 11,111-11,610 $ 8 B 8 8 8 B 8 B• B SLOTS, _._ - a a 11557-12885 ■ i1 F Mandrel Details B B Top Depth Top Port a B g-„ (ND) Teel OD Valve Latch Bice TRO Run N...Top(ftKB) (RKB) (") Make Model (In) Sery Type Type (In) (psi) Run Date _Com... B-SAND _ . 1 3,210.8 2,396.060.66 1 GAS LIFT DMY BK-5 0.000 0.09/26/2006 LINER, 2 4,984.8 3,222.7 65.42 CAMCO KBG-2-1R 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 623612925 TD(1J-156L1), 12,963 111 • `; sem 27Jun16 ConocoPhillips • Alaska, Inc. 1J-156 N 10-403 Sundry 0 0.15 0.3 0.45 0.6 Miles ADL025660 ,'N, `' ADL025661 f i I 1J yy, ) 0 /2 p L/ L/ 5 / ' A A I , it 1 1J-156 1J-152, e� 1 / / 1 p 1 ' a 1J-158 h0 / 1 / /f ADL025662 I i ' a'� 1J-152L2 ADL025663 ' i 1J-152L1 1J-156L2 1J-156L1 4 1 rnia liY i s'{ i 1J-156 Open IntervalI ..m■ END 1J-156L2 Open Interval 1J-156L1 Open Interval 1 ai , — 1J-156 Trajectory i *Well Pad 1 3 1J-178 31/4mi Radius 1J-156 I 31/4mi Radius 1J-156L2 ■ Tg T••••y i 1ADL380058 3 1/4mi Radius 1J-156L1 1 --�Well within 1/4mi Radius 1J-182L1 •• WestSak PA 1J-180L1• 1J-180 1J-182 KRU Boundary CPAI Lease d r",42'g } E E '-O¢ E E E v z E 3§ c - - o I 1:4—.4`A 3 c a a o..3 o a o �' '' 0 0 3 ,, 3 g Y c v; E 3 Y o a i 5 i' z z $¢o. z z z N z° o 19 a ti 19 a a E ntg o E Ertai : All m <°m ary m e m o t6` m n•m w - _ on u reN u A 1 U m V -3 G u 0 UW t O d 1 U m 8. 'AY, t V i141",1 ` 1", E� t v'C m E ,-g, °° E- c E ."--- u t. : ;„1.: = -,2F t -0f-of E f Vm t E F E Oca Et aEa a o_ -�`o - n o- m o 0 oo Mo eo n ' ' mE m • @J E @J o @J E @� o @, T E = ° o ° H _ _ c ° w e -5 12. RI 24r' o° o o�' o 2 ,;7.2 ,C c C o, C ,C c ,C o a a g.' '.2! "' d a LU « a. E, 74 co nWN/ E lau u73 La re c 4 u u u - u T r o i LL 7 0 T E n W m 41 o - W V O '6 Q n ry ry N N 12 U 0 _ p M M V S m to Ti, c 0 ry o O m `o o m m m m'815 a r o g -Eo a o o ff o .- a c 3 a a s a o a ti a 4o r a a a a a 4 a a 3 `a n a 41p In n n Image Projeet Well History File. Cover Page XHVZE This page identifies those items that were not scanned during the .initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. p~ ~ ~p - ~ fp ~ Well History File Identifier Organizing (done> RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ,~wo=,d~ uumiuu DIGITAL DATA Diskettes, No. ~,, ^ Other, No/Type: iii , Re,~a~~ee~ea iuiuuiuiiiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q $ /s/ Project Proofing III IIIIII II III II III BY: Maria Date: g /s/ Scanning Preparation _~_, x 30 = ~ + ~ =TOTAL PAGES_~~ 1' I (Count does not include cover sheet) '/~/~ BY: Maria Date: a / [~I ~ Q /s/ ~' I/' Production Scanning Stage 1 Page Count from Scanned Fil (Count does include cover sheet) Page Count Matches Numbe Preparation: YES NO BY: Maria Q8 /s/ ~~ Stage 1 If NO in stage 1, page(s) disc a found: YES NO BY: Maria e: _ ~~~ r in Scanning Date: ~/~. repancies wer Date: Scanning is complete at this point unless rescanning is required. "iuumuuMiui ReScanned BY: Maria Comments about this file: Date: Quality Checked uiuuuuiiiii 10/6/2005 Well History File Cover Page.doc • • ~. ~;* ~ ~ z~ ~. >x,+ ,r~ s~ MICROFILMED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • WELL LOG TRANSMITTAL October 15, 2008 AK-MW-4467716 J~lee~ 3 d ~ ARew~- Imo- -sl~ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: RE: MWD Formation Evaluation Logs: 1J-156 l+L1PB L2 ~ l l To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-156+L1+L1PB1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23311-00,60,61,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 5 0-029-23 311-00, 60, 61, 70 Digital Log Images 1 CD Rom 50-029-23311-00,60,61,70 ~~,{~~~~~ j;~ ~t ~ ~~ ~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska;99518 907-273-3.536 Date: BP Exploration (Alaska} Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ii /) Signed: ~ t~,ceo6-a~`t ~~ ~ ~-rsy lJ 1 C. cl~-~`z """ l~tS l ~ -~ C ~ o~-cam ~ ~~ is r7ts3 .2? ~~/ DATA SUBMITTAL COMPLIANCE REPORT 7/7/2008 ~,~.~s Permit to Drill 2060680 Well Name/No. KUPARUK RIV U WSAK 1J-156L1 Operator CONOCOPHILLIPS ALASKA INC `~-~~ MD 12963 TVD 3408 Completion Date 7/27/2006 Completion Status 1-OIL Current Status 1WINJ REQUIRED INFORMATION API No. 50-029-23311-60-00 UIC Y Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Typ Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments I~Kpt 14045 LIS Verification Open 8/22/2006 C Lis 14045 InductionlResistivity 2735 12902 Open 8/22/2006 GR, FET, ROP Res ~t 14045 LIS Verification Open 8/22/2006 P61 ~D C Lis 14045 Induction/Resistivity 2735 9187 Open 8/22/2006 GR, FET, ROP Res ~D D Asc Directional Survey 6072 12963 Open 11/9/2006 D Asc Directional Survey 6072 9248 Open 11/9/2006 PB 1 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~!-Pl.r Analysis 'V~ Received? Daily History Received? ~,! N Formation Tops ~/ N Comments: Compliance Reviewed By: Sample Interval Set Stan. Stop Sent Received Number Comments Date: by ~ Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have any questions, please contact llou~las t~ortcn at the rli~, at oo4-4y i ~ u~C slivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 06-066 ~ ~~ 512k 06-066PB1 ~ ao5-cx1Sf ~ r-5 ~la~- 13-31 A - (sue CaoS-!!o0 ~ ~y2'~ 114-11 A `~ ~~ !a6 ~S~a 114-11 AP61 14-21A uzcao5 -rv~ ~ ~5 x/31 15-39A o~olo-o~'br v~ ~Qy3a 16-06Bavc.-opt ~* ~s~l~'3 16-14B c70(o-CO3 " ~5~/3</ C-03B 9v5- ~5~f '~ X5',135 C-10A aas =~3~ 't5~a~ J-17C o~~-0$c~ ~ +5`~3 3 NGI-o7A uzeaoc.-~a~ ~ t5~lc3~f r i ~ ~ ~~ "' , Gf ~~ Please ~'ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 -~ ~ ~° ; ~, ~,- ~; ~ ~^ss" ~_~ , Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 :] • 26-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-156L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,742.94' MD Window /Kickoff Survey: 6,072.44' MD (if applicable) Projected Survey: 12,963.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ M~ ~ ~t1~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ao~-n6~ • • 26-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-156L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,002.04' MD Window /Kickoff Survey: 6,072.44' MD (if applicable) Projected Survey: 9,248.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICHC~?HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~a~~~. Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~S~--d6 8 ~~:~ • STATE OF ALASKA ~ ~r ~ I ~ ~ ZvUu ALASKA OIL AND GAS CONSERVATION COMMISSION . REPORT OF SUNDRY WELL OPERATI~I~ ~"` `~ ` ~ ~15~. lr~i~s~®~ r•~,. ,;~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other /^ Prod to WINJ .. Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhIIIIPS Alaska, Inc. Development ^ Exploratory ^ 206-068 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-156L1 - 8. Property Designation: 10. Field/Pool(s): ADL 25660 & 25663 Kuparuk River Field /West Sak Oil Pool 11. Present WeII Condition Summary: Total Depth measured 12963' feet true vertical 3408' ~ feet Plugs (measured) Effective Depth measured 12924 feet Junk (measured) true vertical 3407 ~ feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2659' 10-3/4" 2768' 2167 D-SAND WINDOI 1' 7-5/8" 5698' 3422' B-SAND WINDOI 1' 7-5/8" 6073' 3490' INTERMEDIATE 6852' 7-5/8° ~ 6961' Perforation depth: Measured depth: 6296'-12885' true vertical depth: 3497'-3408' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5674' MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 49T 12. Stimulation or cement squeeze summary: Intervals treated (measured) "~' ~~~ ()(,I ~ .t 20~~ 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 2865 3536 72 1190 248 Subsequent to operation 2117 978 1 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG ^ GINJ ^ WINJ QQ `~- 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: 306-322 Contact Bob Christensen /Bob Buchholz Printed Name be D. Ch ' nsen Title Production Engineering Technician Signature ~ i Phone 659-7535 Date l- ~~ ~~ djp -Form 10-404 Revised 04/2004 ~ ~ ~ ~ j ~ ~ (3 { t~ <, ~,~,., S~itOriginalO~nlY 1J-156L1 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/17/06 Well shut in for Producer to In'ector conversion 10/01/06 Commenced Water Injection Service Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-156L1 Sundry Number: 306-322 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October 2006 Encl. ~U~ ~`tS Ci r r.orc ~c r -~ STATE OF ALASKA ~'Z,_ ALASKA OIL AND GAS CONSERVATION COMMISSION ~E~EIVED SEP 1 8 2006 APPLICATION FOR SUNDRY APPROV/~~ka Oil & Gas Cans. Commission 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ . Perforate ^ Waiver ^ Other 0 Alter casing ^ Repair well ^ Plug Perforations. ^ Stimulate ^ Time Extension ^ ~ Chan e a roved ro ram 9 PP P 9 ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Producer to Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^/ Exploratory ^ 206-068 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-60 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 chang es: Spacing Exception Required? YeS ^ NO Q 1J-156L1 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660 & 25663 RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12963' 3408' 12924 3407 - Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE.. 2659' :LO-314" - 2768' 2167 D-SAND WINDOW ~~ 7-5/8" 5698' 3422 B-SAND WINDOW 1' 7-5/8" 6073' 3490 INTERMEDIATE 6852' 7-5/8" 6961' 3626 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6296-i2aa5~ 3as7'-a4os~ 4-1/2" L-80 5674' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 49T 13. Attachments: Description Summary of Proposal ^ 14. WeR'Glass`after proposed work: Detailed Operations Program ^ BOP Sketch ^ Expbratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 1, 2006 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 bent Q. ChrlStBnSen° Title:• Production Engineering Technician Signature j Phone 659-7535 Date ,.9 _ /3 ~~ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~©~ ,~~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Te st ~ Location Clearance ^ Other. ~ ~F~-, 0;;~ 4 2006 Subsequent Form Required: ~~t^` ~ ^ I ~' [~' ~1 A d b ~ \ APPROVED BY 2 ~ Q ~~ ^ pprove y: OMMISSIONER THE COMMISSION ~J Date: Form 10-403 Revised 06/2006 ~,~ ~ Submi4 in uplicate 1J-156L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-156L1. This well has been pre-producing for 27 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-156L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (2769' and / 2167' tvd) was cemented with 498 sx Class G followed by 184 sx Class G. The 7-5/8" Intermediate casing (6961' and / 3626' tvd) was cemented with 405 sx Class G. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5640' and / 3410' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5801' and / 3443' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 6161' and / 3505' tvd. The top. of West Sak D~sand was found at 568.3' and / 3419' tvd. a.. The top of West Sak B-sand was found at 6080' and / 3491' tvd. The top of West Sak A sand was-found at 7024' and ! 3630' tvd. } -. ~ : ` ~' KRU 1 J-156L1 ~o~c~c~~'~ii1i~~ ~,~~s~c~l, ~r°r~> 1J-156L1 API: 500292331160 Well T : PROD An le TS: d SSSV T e: NIPPLE Ori Com letion: 7/28!2006 An le TD: 90 d 12963 Annular Fluid: Last W/O: Rev Reason: GLV C/O Reference Lo : 28' RKB Ref Lo Date: Last U date: 8/9/2006 ;:. Last Ta TD: 12963 ftKB Last Ta Date: _ Max Hole An le: 94 d ~ 790.3 _ _ ring -ALL STRING n pt on Desc Size I Top ~ Bottom TVD~ Wt TGrade I Thread ~ ~ CONDUCTOR I 20.000 0 108 j 108 I 62.60 _ I H-40 I WELDED I I SURFACE 10.750 0 2768 ~ 2167 45.50 ~ L-80 BTC 0.00 I _ B-SAND LINER I __ 4.500 I 6238 j 12925 _ I__ 3408 I 11.60 I L-80 I BTC f T g ring - TUBT N ~ 500 O P BSS 4 ~ 341D7 ' 12V60_ GL 80e l__ - IBTMd Perforations Summary : - __ - Interval TVA T Zone Status Ft _ SPF _ - Date T e -- -__ __ _ ~ Comment 6296 - 12885 3497 - 3408 WS B,WS 6589 32 7/17/2006 Slots ARernating slotted/solid pipe C,WS B -- -- _ _ - _ Gas Lift Mandrels/Valves` _._ HANGER(D) St MD TVD Man Man Type V Mfr V Type V OD Latch (56945718, Mfr oD:s.soo) 1 3211 2396 CAMCO KBG-2-1 R GLV 1.0 BK 2 4983 3225 CAMCO KBG-2-1 R OV 1.0 BK _ .Other (plugs, equip., etc.) -COMPLETION HANGER (solo-sows, OD:7.625) Pert (6296-12885) _i_ ''~_ Port TRO Date Run Vlv Cmnt 0.188 1456 8/8/2006 0.313 0 8/8!2006 De th TVD T e Descri ion ID 22 22 HANGER VETCO GRAYTUBING HANGER 4.909" TOP CONNECTION 4.500 497 496 NIP CAMCO'DB-6' NIPPLE w/3.875 NO GO PROFILE 3.875 5595 3401 SLEEVE-O BAKER CMD SLIDING SLEEVE OPEN 3.812 5646 3412 LOCATOR BAKER LOCATOR 3.875 5648 3412 SEAL BAKER 4.75" SBE SEAL ASSEMBLY 3.875 5675 3417 SHOE MULE SHOE 3.958 Other lu s, tai ., etc. - B-SAND LINEa &LEM DETAIL De th TVD T e Descri ion ID 5801 3443 PACKER ZXP LINER TOP PACKER 4.970 5820 3447 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5840 3451 BUSHING CROSSOVER BUSHING 3.950 5841 3451 PUP 3.958 6060 3488 HANGER LEM ABOVE HOOK HANGER 3.980 6070 3490 HANGER LEM INSIDE HOOK HANGER 3.980 6070 3490 HANGER BAKER MODEL B-1 HOOK HANGER INSIDE CASING 4.500 6087 3492 HANGER BAKER MODEL B-1 HH FOR LEM OUTSIDE CASING 4.500 6094 3493 PUP 3.958 6118 3495 NIPPLE CAMCO'DB-6' NIPPLE 3.562 6183 3497 PACKER PAYZONE EXTERNAL CASING PACKER 3.930 6194 3497 SEAL BAKER SEAL ASSEMBLY 3.880 6205 3497 PUP 3.958 6238 3497 SLEEVE BAKER'HR' LINER SETTING SLEEVE :5.750 6247 3497 PUP 4.950 6254 3497 Bent Joint 3.958 6290 3497 BUSHING CROSSOVER BUSHING 3.930 12885 3408 XO CROSSOVER 4.500 12925 3408 SHOE - BAKER GUIDE SHOE _ - -- - 0.000 ~Other lu s, a ui ., etc.) - D-SAND LEM -- - -- - De th TVD T e Descri lion ID 5640 3410 PACKER D ZXP LINER TOP PACKER 4.970 5659 3414 SBR D 190-47 CASING SEAL BORE RECEPTACLE 4.750 5679 3418 Bushin D CROSSOVER BUSHING 3.950 5680 3418 PUP D 3.958 5684 3419 HANGER D LEM ABOVE HOOK HANGER 3.980 5694 3421 HANGER D LEM INSIDE HOOK HANGER 3.980 5694 Gener Date 3421 HANG_ER(D) BAKER MODEL B-1 HOOK HANGER FOR LEM INSIDE CASING 4.500 al Notes _ - - Note 7!28!2006 MULTI-LATERAL WELL: 1J-156 (A-SAND), 1J-156L1 (B-SAND), 1J-156L2 (D-SAND) TREE: VETCO GRAY / HORZ / 4-1/8" TREE CAP CONNECTION: 1.2" OTIS x 4-1/8" 5M -o~ ~ -~-- M~C:3ANICAL IIZTEGRITY R:.PORT BUD u.--.__ =..c r ~~~~ ~.. /a~ -c~ ~ `b~~ OPER ~ FIELD CC~~s-~ 1~-Z-~ ,~ Cj ;, LLL Nt1ME ER i ~ --15 ~ • - ~.~ ~ - ~ a- .~~LL DAT~_ TD: `o~~o~ ?~.. TVD; ?BTD: ?ID using '1~(~s Shoe. (~~MD ~Co~ TVD; liV. ~~- ?~ _.:,e.: gyp. Shoe - moo'--=' ~ ~1~_Pacicer `~ ole S«e and ~C"r'..P?~?C~.l, INTEGR?TY - ??AZT #I .__. .~ ~~ TVD TVD; Set at SG~'1~ P erf s to - L w~•~aw (oc~'t3 ~. ~ w~~`J o.~.~ s~S,SS r_nnuius Press Test• _~ 15 min ~0 min CocmZents : '~ CHA ~T I Cr"i, 1NTEGRI•r~ _ p~•r # 2 ~ ` 16 `~ i~ i~ 4 5 - ~~ Cement Volumes :-_ r~~t. Liner ~~. Cstr ~ DV ~Q6 C~,t Toi to cowcer oers ~- 3a?o KS Fs~ h1n~sC,,a-14~~ su `~~ ~c7 ~'`l~i ~-~' w~ teUOvJ D~~ ~~ l =eore tical TOC C 3~?~ XS ~C. "' BOO c ~ ~ fl~ ~ ` - ~,- ~ Cement Bond Log (Yes or No) L~~j In AOGCC File ~~(,p OCo ° CBL Evaluation, cone above perfs ~ ~ ~` ~` ~ ~ ~..~~'~~E (~ ~ (~,T k .~`+ ~ 'mil "~ r ~ Production I.og : Type ~ rte; Evaluation t` ~~ ^C`~ ~ - COt~CLJSIOtJS ?art #I. ~ . ~. ?art T2: ~~-z°~ ~~r~ G~Y R~~~E~`V~d STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 ~ 2006 WELL COMPLETION OR RECOMPLETION REPOI`~~aL~Commission 1a. Well Status: Oil O Gas Plugged ^ Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: f8g@ Development ^/ ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., .~ ~ orAband.: Julyy , 2006 12. Permit to Drill Number: 206-068 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded~~ t~ ~ , 2006 4~r'~ 13. API Number: 50-029-23311-60 4a. Location of Well (Governmental Section): Surface: 2094' FSL, 2559' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: July 15, 2006 ' 14. Well Name and Number: 1J-156L1 - At Top Productive Horizon: 175' FSL, 306' FEL, Sec. 34, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 1421' FNL, 221' FEL, Sec. 10, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12924' MD / 3407' TVD West Sak Oil Pool ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558649 y- 5945905 Zone- 4 10. Total Depth (MD + TVD): 12963' MD / 3408' TVD ' 16. Property Designation: ADL 25660 & 25663 TPI: x- 555640 y- 5943963 Zone- 4 Total Depth: x- 555786 ' - 5937089 • Zone- 4 11. Depth where SSSV set: nipple @ 497' 17. Land Use Permit: ALK 470 & 472 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 4077' MD 21. Logs Run: ~(~' (,~~ .~.w bo72 ~D ~ 3y9D'71~b 'QS ~ GR/Res, DenslNeu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RECORD PULLED 20" x 34" 94# K-55 28' 108' 28' 108' 42" 163 sx Class G 10.75" 45.5# L-80 28' 2769' 28' 2167' 13.5" 498 sx Class G, 184 sx Class G 7-5l8" 29.7# L-80 28' 6961' 28' 3626' 9-7/8" 405 sx Class G 4.5" 11.6# L-80 6238' 12925' 3497' 3407' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 5675' slotted liner from 6424'-11856' MD ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production August 17, 2006 Method of Operation (Flowing, gas lift, etc.) Pre-produced injector-shares production with 1J-156 and 1J-156L2 Date of Test 8/20/2006 Hours Tested 15 hours Production for Test Period --> OIL-BBL 1681 GAS-MCF 3073 WATER-BBL 33 CHOKE SIZE 85 Bean GAS-OIL RATIO 1921 Flow Tubing press. 578 psi Casing Pressure 1320 Calculated 24-Hour Rate -> OIL-BBL 2565 ~ GAS-MCF 4928 WATER-BBL 53 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". COil~PLCT(ON PATE NONE IIE FiEG Form 10-407 Revised 12/2003 S ~~'~ ~~~ ~ ~ nPQNTINUED Qly R~1(EI~S~ ~ ~ A ~ ~,y~ 'g' ~~ b~ji v LUDO U K I !/{~-1 ~f ~- ,~ ~~.~/~ r zs. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-156L1 Top West Sak B 6080' 3491' Base West Sak B 12962' 3408' ' N/A 1J-156L1 P61 TD 9248' 3432' ' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name. Rand homas - Title: Greater Kuoaruk Area Drillino Team Leader ~' lit ~ot~ Si gnature ~ne Z~„~ ~~-, ~ ~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22:. Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: list all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoF~h~il~ps Time Log Summary Welfview iNeb Repvrdng - --- -- Time Lo s _~ __ ___- Date From To Dur S. De th E De th Phase Code Subcode T COM 06/29/2006 00:00 08:00 8.00 0 0 MIRU MOVE DMOB P Move rig off of 1J-170 and spot up rig and all modules over 1J-156. No problems and no incidents. Rig Acce ted 08:00 hrs. 08:00 10:00 2.00 0 0 MIRU MOVE RURD P N/U Diverter, Load pipe shed w/drill pipe and strap same, weld toe board in derrick. Rig on Hi-Line power @ 09:00 hrs. 10:00 12:00 2.00 0 0 MIRU MOVE RURD P C/O saver sub, grabbers and bell guide to 4-1 /2" I F 12:00 13:15 1.25 0 0 MIRU MOVE RURD P Space out grabbers & safety wire top drive, clear rig floor, R/U floor and pipe shed to P/U 5" DP. 13:15 14:15. 1.00 0 0 MIRU WELCT BOPE P Perform Diverter test w/ State Man, Co. Rep, & Motorman. Diverter test witnessed by AOGCC rep Lou Grimaldi. Bag Close @ 47 sec. Knife valve close @ 7 sec. Accumulator psi before shut in = 3000psi, after = 1900 psi. 200 psi recovery = 44 sec. Overall recovery = 3min 8 sec. 5 btl avg = 2300 psi. Diverter Length 148' ~ of well. Gas alarms fom center calibrated and tested. 14:15 17:30 3.25 0 0 MIRU DRILL PULD P P/U 30 stands 5" DP, 6 stands 5" HWDP w/Jars, 1 stand 8" non-mag, some-o s mix s ud mud 17:30 18:30 1.00 0 0 MIRU DRILL PULD P M/U and stand back 1 stand Non-mag DC 18:30 21:30 3.00 0 0 MIRU DRILL PULD P P/U motor, re-orient sleeve on motor, M/U stabilizer & float sub 21:30 22:00 0.50 0 0 MIRU DRILL PULD P M/U bit, flood conductor and check for leaks. 22:00 22:15 0.25 0 0 MIRU DRILL PULD P Continue M/U BHA 22:15 22:30 0.25 0 108 SURFA DRILL DRLG P Wash and drill ice from 90' to 108' 22:30 00:00 1.50 108 150 SURFA DRILL DRLG P Spud Well -Drilling from 108' to 150'a ART = 1.2 hrs 06/30/2006 00:00 00:30 0.50 150 224 SURFA DRILL DDRL P Cont. Drilling from 150' to 224'.. HART =.5 00:30 01:00 0.50 224 224 SURFA DRILL TRIP P POOH to C/O BHA 01:00 01:15 0.25 224 224 SURFA DRILL PULD P M/U BHA, MWD, UBHO 01:15 01:30 0.25 224 224 SURFA DRILL PULD P Orient MWD to Motor 01:30 02:00 0.50 224 224 SURFA DRILL PULD P R/U Gyro 02:00 02:30 0.50 224 224 SURFA DRILL TRIP P RIH to 133' and Tag hard fill, UD 1 jt NMFDC & P/U stand of HWDP 4'ae~~ 1 of ~~' ~ - _ Time Logs Date From To Dur S. e th E De th Phase Code _ _S~~bcode T__ ~QM _ _ 06/30/2006 02:30 03:00 0.50 224 224 SURFA DRILL REAM. P Wash & Ream from 133' to 224' 03:00 03:15 0.25 224 224 SURFA DRILL TRIP P P/U 1 jt NMFDC & RIH to 224' 03:15 12:00 8.75 224 718 SURFA DRILL DDRL P Drilling from 224' to 718' MD (700' TVD). AST = 3.12, ART = 2.69, ADT = 5.81. Gyro @ 253' 20 min. Gyro @ 346' 20 min. Gyro @ 440' 20 min. Gyro @ 622' 20 min. PU = 74k, SO = 70k, Rot Wt = 70k, TQ on btm = 1-2k, TQ off btm = 1-2k, Jar Hrs = 63.17 12:00 00:00 12.00 718 1,870 SURFA DRILL DDRL P Drilling from 718' MD (700' TVD) to 1870' MD (1693' TVD), 130 spm, 530 gpm, 1475 psi on btm, 1250 psi off btm, 20-30k WOB, 85 rpm, PU = 92k, SO = 80k, TQ on btm = 5k, TQ off btm = 1 k, ADT = 8.45 hrs, ART = 6.22 hrs, AST = 5.01 hrs, Max Gas = 67 units, Jar hrs = 71.62, Bit hrs = 14.26 07/01/2006 00:00 00:15 0.25 1,870 1,870 SURFA DRILL SFTY P PJSM -Hazards of drilling and connections -Getting tools in and out from beaver slide 00:15 08:45 8.50 1,870 2,780 SURFA DRILL DDRL P Con't Drlg f/ 1870' to 2780' MD / 2173' TVD - TD surface csg point - Up wt 110k, Dn wt 75k, Rot wt 87k, Torq on and off bttm 7k. ADT 6.01 (2.81 Rot, 3.20 slide Jars = TT 77.63 08:45 09:00 0.25 2,780 2,780 SURFA DRILL CIRC P Circu 10 min to clear assy -Flow ck well -Static 09:00 12:00 3.00 2,780 1,095 SURFA DRILL TRIP P BROOH f/ 2780' MD to 1095' MD - PR 600 gpm, RPMs 85 ***Note*** Had hidrates gas 1984 units @ 2070' MD/ 1816' TVD and 2113 units @ 2358' MD/ 1961' TVD- 12:00 15:15 3.25 1,095 0 SURFA DRILL TRIP P Con't BROOH 1095' MD ghost reamer ( Top HWDP) - LD Ghost reamer - POOH to monels. - LD BHA #1 15:15 15:45 0.50 0 0 SURFA DRILL PULD P Clear all tools from rig floor -Clean rota area 15:45 17:00 1.25 0 0 SURFA DRILL RURD P RU to run 10.3/4" Csg. 17:00 17:30 0.50 0 0 SURFA DRILL SFTY P PJSM -Discuss know hazards - Review runnin detail 17:30 22:45 5.25 0 2,776 SURFA CASIN( RNCS P Run Surface Csg -Run 67 jts + 2 pup joints 10 3/4" 45.5# L80 BTC csg - Shoe @ 2776' MD/2171' TVD ***NOTE*"'* Had 1 small tight spot around the base of perma-frost (Jt #44 1848' MD) Took a little wt 25k - No roblem 22:45 00:00 1.25 2,776 2,776 SURFA CASINC CIRC P Circu and Condition w/ Franks Tool - PR 7 bpm, PP 550psi , Up wt 150k, Dn wt 78k 07/02/2006 00:00 00:15 0.25 2,776 2,776 SURFA CASIN( SFTY P PJSM on rigging down Franks tool & R/U cement head ?~~e ~ ~~ 2 - - -- - ~me Logs -- - -- - -_ - D_ate From _To_ Dur ~. epth E Depth Phase Code Subcode__ T__ 'OM _ ____~ 07/02/2006 00:15 00:30 0.25 2,776 2,776 SURFA CASIN( RURD P Rig down Franks tool & rig up cement head 00:30 02:00 1.50 2,776 2,776 SURFA CEMEP CIRC P Cont. circ & cond mud for cement 70 s m, 350 si 02:00 02:15 0.25 2,776 2,776 SURFA CEMEf~ SFTY P PJSM on cementing 02:15 05:30 3.25 2,776 2,776 SURFA CEME(~ DISP P Cement surface casing, 5 bbls, H2O test lines 3000 psi, 50 bbls. CW100, 50 bbls, Mud push, drop bottom plug, pump lead 410 bbls, 10.7 ppg, pump tail 80 bbls, 12 ppg, drop top plug, 20 bbls wash tub & lines, dosplace with ri 2350 strokes CIP 05:15 05:30 07:30 2.00 2,776 2,776 SURFA CASIN( RURD P Flush riser, take turn buckles off, take off diverter pipe, P/U on diverter stack to set emer enc sli s 07:30 08:30 1.00 2,776 2,776 SURFA CASIN( RURD P Set Slips (w/ 65k overpull) 08:30 09:00 0.50 2,776 2,776 SURFA CASIN( OTHR P Drain & cut off casing 09:00 12:00 3.00 2,776 2,776 SURFA CASIN( RURD P R/D diverter stack & clean cement out of same, ull out of cellar 12:00 13:00 1.00 2,776 2,776 SURFA CASIN( NUND P UD long bails, R/U 4" handling tools, sime-ops: weld on starting head flange, repair drag chain in pits, clean R/W, P/U mousehole 13:00 14:45 1.75 2,776 2,776 SURFA CASIN( RURD P Recharge accum bottles on top drive, UD 7 stds 5" DP in mousehole, some-ops -pull diverter sys out under roduction lines. Retrieve 3 test 'oints. 14:45 15:15 0.50 2,776 2,776 SURFA CASIN( OTHR P R/U 4" handling tools, PJSM & hazzard assessment on C/O saver sub. 15:15 16:45 1.50 2,776 2,776 SURFA CASIN( RURD P C/O 4-1/2" IF saver suv to 4" XT-39, sime-ops P/U starting head, collect tools, re are fro ni lin u in cellar 16:45 22:00 5.25 2,776 2,776 SURFA CASIN( OTHR P P/U 144 jts 4" XT-39 DP in mousehole, rack back in derrick 22:00 00:00 2.00 2,776 2,776 SURFA CASINO RURD P M/U 4" & 5" floor valves, M/U 1 std 6-3/4" non mag & rack back in derrick, UD mousehole, grease choke manifold, get test plug & wear ring uller from Vetco Gre 07/03/2006 00:00 00:15 0.25 0 0 SURFA CASIN( NUND P PJSM -discuss and review NU Well Head and BOPs 00:15 00:30 0.25 0 0 SURFA CASINO DHEQ P Testwefd on adaptor well head. 1900 si 10 min "OK" 00:30 01:00 0.50 0 0 SURFA WELC7 NUND P NU Well Head on adapter 01:00 03:00 2.00 0 0 SURFA WELCT NUND P NU BOPs 03:00 09:00 6.00 0 0 SURFA WELCT BOPE P Test BOPs and Choke manifold - 250 psi low and 3000 psi high - No failures - All test charted and held 5 min. AOGCC rep John H. Crisp waived witness test. ~'a€~€~ 3 of 22 Time Lomas Date From To Dur ~e th E De th Phase Code Subcode T 'OM 07/03/2006 09:00 09:15 0.25 0 _ 0 _ SURFA DRILL SFTY P PJSM -Discuss and review PU BHA 09:15 10:15 1.00 0 80 SURFA DRILL PULD P PU BHA #2 - Motor, MU bit, Flt sub, Stab, HOC, MWD, TM 10:15 10:45 0.50 80 80 SURFA DRILL SRVY P Up Load MWD 10:45 11:30 0.75 80 452 SURFA DRILL PULD P Con't PU BHA #2 - TIH w/ NMDCs, 8 'ts HWDP + Jars, XO 11:30 12:00 0.50 452 452 SURFA DRILL SRVY P Pulse Test MWD "OK" 12:00 12:15 0.25 452 460 SURFA DRILL PULD P PU Ghost reamer 12:15 13:00 0.75 460 2,597 SURFA DRILL TRIP P TIH to 2597' -Circu air from system 13:00 14:00 1.00 2,597 2,597 SURFA CASIN( DHEQ P RU and Test csg to 3000 psi on chart for 30 min -Good test - No bleedoff 14:00 15:30 1.50 2,780 2,805 SURFA CEMEf~ DRLG P Drlg out Flt collar, shoe track, Flt shoe 2769' MD w/ 9 7/8" bit, FR 450 gpm, PP 1100 psi, RPMs 60-65, Torq 5-8k, lus 25' of new hole to 2805' MD 15:30 17:00 1.50 2,805 2,805 SURFA DRILL CIRC P Circu re-conditioned mud around - Circu until mud is uniform in and out. 17:00 17:30 0.50 2,769 2,769 SURFA DRILL LOT P Pull to shoe - RU and Preform LOT - MW 9.0 ppg, 2169' TVD, 382 psi at surface = 12.4 EMW 17:30 18:00 0.50 2,805 2,867 INTRM1 DRILL DDRL P Drlg 9 7/8 " hole w/Motor f/ 2805' MD to 2867' MD / 2214' TVD - PR 550 m, PP 1250 si, WOB 8-10k, 18:00 19:00 1.00 2,867 2,867 INTRM1 DRILL SRVY T Trouble Shoot MWD - No Signal 19:00 19:30 0.50 2,867 2,867 INTRM1 DRILL CIRC T Circu BU -Max gas units 616 units 19:30 19:45 0.25 2,867 2,867 INTRM1 DRILL OWFF T Obsevre Well -Static 19:45 21:45 2.00 2,867 150 INTRM1 DRILL TRIP T POOH on elevators f/ 2867' 21:45 22:15 0.50 150 110 INTRM1 DRILL SRVY T Down Load MWD 22:15 22:45 0.50 110 60 INTRM1 DRILL PULD T LD MWD, TM collar & HOC 22:45 23:15 0.50 60 150 INTRM1 DRILL PULD T PU New MWD tool, TM collar & HOC 23:15 00:00 0.75 150 150 INTRM1 DRILL SRVY T Up Load MWD 07/04/2006 00:00 00:15 0.25 150 150 INTRM1 DRILL SFTY T PJSM on TIH 00:15 00:30 0.25 150 452 INTRM1 DRILL DHEQ T TIH T/ 452' MD & Shallow test MWD OK 00:30 01:30 1.00 452 2,768 INTRM1 DRILL TRIP T TIH T/ 2768' MD 01:30 02:00 0.50 2,768 2,768 INTRM1 DRILL CIRC T Circ Bottoms up, Gas cut 504 units, circ 500 al/min & 1100 si 02:00 02:15 0.25 2,768 2,865 INTRM1 DRILL TRIP T TIH F/ 2768' MDT/ 2865' MD, Survey on bottom 02:15 03:45 1.50 2,867 3,055 I NTRM1 DRILL DDRL P Drilling F/ 2867' MD to/ 3055' MD ~~ ~ ~~cJe ~ cf 22 - _ -- ~ Time Logs Date From To Du_ r_____5._~epth E. Depth Phase Code Subcode T 'OM __ 07/04/2006 03:45 04:15 0.50 3,055 3,055 INTRM1 DRILL SRVY T MWD Detection problems 04:15 12:00 7.75 3,055 3,940 INTRM1 DRILL DDRL P Drilling F/ 3055' MDT/ 3940' MD (2759' TVD), ADT = 5.52, AST = 2.68, ART = 2.84, PU = 112k, SO = 70k, ROT = 85k, TQ = 7k On abtm & 6k off btm, ECD = 9.65, Max Gas = 53 units dlg, 504 units on TIH, Jar hrs = 80.24, PR @ 3800' MD, 2691' TVD, MW = 9.0 ppg, MP #1 @ 30 spm = 250 psi, @ 40 spm = 320 psi, MP#2 @ 30 spm = 250 si, 40 s m = 320 si 12:00 00:00 12.00 3,940 5,088 INTRM1 DRILL DDRL P Held PJSM & Hazard assesment on drilling ahead & making connections, Drilling F / 3940' MD (2759' TVD) to 5088' MD (3266' TVD), 550 gpm, 1700 psi, 131 spm, 90 RPM, 10-20k WOB, ADT = 13.16, ART = 3.75, AST = 3.89, PU = 110k, SO = 78k, ROT = 92k, TQ = 5k on btm & 4.5k off btm, ECD = 9.91, Max GAs = 86 units, Jar hrs = 87.88, SPRs @ 5018' MD, 3238' TVD, MW=9.0, MP#1 @30 spm=320 psi, @ 40 spm = 410 psi, MP #2 @ 30 spm = 320 psi, @ 40 spm = 400 si 07/05/2006 00:00 00:15 0.25 5,088 5,088 INTRM1 DRILL SFTY P PJSM on drilling ahead & making connections 00:15 12:00 11.75 5,088 5,850 INTRM1 DRILL -DDRL P Drlg from 5088' MD to 5850' MD (3452' TVD). ADT = 8.61, AST = 2.09, ART = 6.52, PU = 110k, SO = 75k, ROT = 90k, TW = 6k on btm & 5-8k off btm, ECD = 9.65, Max Gas = 67 units, Jar hrs = 96.49. SPR @ 5802' MD (3443' TVD) w/ MW = 9.1 ppg: #1 MP @ 30 spm = 320 psi, @ 40 spm = 410 psi; #2 MP @ 30 spm = 320 psi, @ 40 s m=410 si 12:00 12:15 0.25 5,850 5,850 INTRM1 DRILL SFTY P PJSM on drilling ahead, scrubbing windwalls, & hazard assesment 12:15 00:00 11.75 5,850 6,699 INTRM1 DRILL DDRL P Dlg from 5850' MD (3452' TVD) to 6699' MD (3588' TVD). ADT = 7.24, ART = 4.94, AST = 2.3, PU = 115k, SO = 72k, ROT = 90k, TQ = 5-6k on btm & 6k off btm, ECD = 10.09, Max Gas = 198 units, Jar hrs = 103.73. SPRs @ 6699' MD (3588' TVD) w/ MW = g,2+: MP #1 @ 30 spm = 370 psi & @ 40 spm = 450 psi; MP #2 @ 30 s m = 370 si & 40 s m = 450 si 07/06/2006 00:00 00:15 0.25 6,699 6,699 INTRM1 DRILL CIRC P PJSM -Discuss drilling hazards & BROOH _ e F~~~e :, ct 22 - ----- Time Lois -- ---- -- --- -- _ ~ Date From To Dur e th E De th Phase Code Subcode QOM 07/06/2006 00:15 02:45 2.50 6,699 6,968 INTRM1 DRILL DDRL P _ Directional Drlg w/ Motor 6699' to 6968' MD / 3625' TVD. Up wt 120k, Dn wt 70k, Rot wt 85k On bttm torq 6-7k, PR 550 gpm, PP 2000 psi, Total ADT 2.31 hrs, (ART 1.44, AST .87), Total hrs on jars = 105.5. "**Note''* Jars came out of hole half cocked. These will be sent in to weartherford to be ins ected. 02:45 03:45 1.00 6,968 6,968 INTRM1 DRILL CIRC P Pump &Circu Wt/ HiVis ,Noted 10% increase in cutting when back to surface, PR 550 gpm, PP 2000 psi, RPMs 90. Hole appears to be in good sha a and clear of cuttin beds. 03:45 09:15 5.50 6,968 2,769 INTRM1 DRILL TRIP P Flow Ck well- Static - BROOH f/ 6968' to 2769'. PR 500 gpm, RPMs 90. All pulled well - No signs of pack off or cuttin roblems. 09:15 10:30 1.25 2,769 2,769 INTRM1 DRILL PULD P Std back last 2 stds 4" DP - UD all 5" DP 36 'ts 2769' to 1569' 10:30 12:00 1.50 2,769 2,769 INTRM1 DRILL CIRC P Circu & Pump Sweep at shoe until clean, PR 550 gpm, PP1300 psi, RPMs 50 12:00 13:15 1.25 2,769 311 INTRM1 DRILL SFTY P PJSM -Discuss hazards LD DP POOH & LD BHA 13:15 13:45 0.50 311 94 INTRM1 DRILL PULD P UD HWDP & Collars 13:45 14:30 0.75 94 94 INTRM1 DRILL SRVY P Dn Load MWD 14:30 15:00 0.50 94 0 INTRM1 DRILL PULD P UD MWD, Mud Motor & Bit 15:00 15:30 0.50 0 0 INTRM1 CASIN( RURD P Pull Wear Bushing 15:30 16:00 0.50 0 0 INTRM1 CASIN( RURD P Clean and clear rig floor -Lay all tools do beaver slide 16:00 17:30 1.50 0 0 INTRM1 CASIN( RURD P PJSM running csg - RU 7 5/8" csg tools -Slips, elevators, long bails, ower ton s, Franks tool 17:30 17:45 0.25 0 0 INTRM1 CASIN( SFTY P PJSM hazards rolling csg -Safety meetin with roustabouts in i e shed 17:45 18:15 0.50 0 0 INTRM1 CASIN( RUNL P PU pups and tools from beaver slid 18:15 18:30 0.25 0 0 INTRM1 CASIN( SFTY P PJSM with floor crew on hazards while runnin cs 18:30 19:00 0.50 0 168 INTRM1 CASIN( RNCS P Run Jts 1 thru 4 -Check floats - "OK" 19:00 21:45 2.75 168 2,758 INTRM1 CASIN( RNCS P Con't running csg f/-168' to 2758' MD - No roblems noted. 21:45 22:15 0.50 2,758 2,758 INTRM1 CASIN( CIRC P Circu csg volume @ surface shoe - 1253 stks 22:15 00:00 1.75 2,758 3,680 INTRM1 CASIN( RNCS P Con't running csg f/ 2758' MD to 3680' - Hole appears in good shape - No ti ht hole noted. 07/07/2006 00:00 00:15 0.25 3,680 3,680 I NTRM1 CASIN( SFTY P PJSM -Crew change -review hazards runnin cs Page ~ ®f '~' Time Loc,~s __ _ Da_t_e _____From To Dui _Lth E._De tp h Phase___ Code S_ubcode T ~~M_ _ 07/07/2006 00:15 02:15 2.00 3,680 6,962 INTRM1 CASIN( RNCS P Con't running 7 5/8" 29.7# L80 BCTM csg f/ 3689' to 6962' TD Shoe (162 jts cut off #163) No problems running cs - No ti ht hole 02:15 03:15 1.00 6,962 6,962 INTRM1 CEMEf~ CIRC P Circu BU + w/ Franks Tool (2779 stks total) - PR 7 bpm, PP 670 psi. Recip cs 20' 03:15 03:45 0.50 6,962 6,962 INTRM1 CEMEI~ RURD P R/D Franks Tool -Blow do TD - R/U CMT head 03:45 05:45 2.00 6,962 6,962 INTRM1 CEMEI~ CIRC P Con't to Circu and condition mud for CMT - PR 7 bpm, PP 450 psi -Start properties MW 9.6 ppg, FV 56, PV 9, YP 27, 10 min gels 18 and the After cond = MW 9.1+, FV 42, PV 10, YP 10, 10 min els 6 05:45 07:45 2.00 6,962 6,962 INTRM1 CEME(~ DISP P Cement 7 5/8" Csg, Pump 10 bbl CW100, Test lines to 3500 psi, pump 65 bbls, pump 75 bbls MudPush @ 12ppg, Drop bttm plug, pump 163 bbls tail cmt @ 12.5ppg, drop top plug, DS kick out w/ 2 bbls water. Rig displace with MOBM, 3127 stks, Bump Plug w/ 500 psi over to 1350 psi. Ck floats after 4 min "Held" - CIP 0730 hrs 07:45 08:00 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM -Review Slip setting procedures - Review known hazards 08:00 09:00 1.00 6,962 6,962 INTRM1 CASIN( RURD P P/U BOPs -RD CMT head -Clear tools from ri floor 09:00 10:30 1.50 6,962 6,962 INTRMI CASIN( NUND T Vetco/Gray set slips (planned). Had trouble with the first set of slips would not hold. Had to use and set second set of sli s. 10:30 12:00 1.50 6,962 6,962 INTRM1 CASIN( NUND P Cut Casing w/ Pneumatic Cutter 12:00 12:15 0.25 6,962 6,962 INTRM1 CASIN< SFTY P PJSM - instgll packoff/Nipple up BOP inch oints 12:15 12:45 .0.50 6,962 6,962 INTRM1 CASIN( RURD P Install pack off/ Rig down casing tools and than a bales 12:45 13:45 1.00 6,962 6,962 INTRM1 CASIN( NUND P Nipple up BOP, test pack off @ 3800 si 10 min . Install wear rin . 13:45 15:00 1.25 6,962 6,962 INTRM1 CASIN( OTHR P 7-5/8" x 10-3/4" annulus infectivity test w/ 9.0 ppg WBM (11.8 ppg EMW). Pump 120 BBL fresh water flush @ 3 BPM IP 600 psi & FP 730 psi. Stop pump & stabilize @ 400 psi & shut in. Freeze Protected Annulus w/ 83 BBLs Diesel @ 2.5 BPM IP 400 psi & FP 700 si. 15:00 15:15 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM -cut & slip drill line (Hazard Reco nition 15:15 16:15 1.00 6,962 6,962 INTRM1 RIGMN SVRG P Cut & Slip drill line 72', inspect brakes, check C-O-M, Lube Top Drive & Blocks 16:15 21:15 5.00 6,962 6,962 I NTRM1 DRILL TRIP P PU, drift, and RIH w/45jts Hybrid DC, 2.1 jts HWDP, & 99 jts 4" DP w/ Su er-Sliders F'ag~ r rrf d - _ Time Logs - - - - - _ ~ Date__ From To Dur She th E_ Depth Phase Code Subcoc l e T ~~M 07/07/2006 21:15 _ 23:30 _ 2.25 6,962 _ 6,962 INTRM1 DRILL _ _ TRIP _ P _ ___ POOH standing back drill string 23:30 00:00 0.50 6,962 6,962 INTRM1 DRILL RURD P Clean Rig Floor 07/08/2006 00:00 00:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on PU & MU BHA & 102 jts DP 00:15 01:15 1.00 0 96 INTRM1 DRILL PULD P PU & MU BHA #4, Motor, Float Sub, Stav, DM, SlimPhase 4, PWD, TM collar 96` MD 01:15 .03:30 2.25 96 96 INTRM1 DRILL SRVY P Plug in & up-load MWD (Trouble w/ si nal 03:30 04:00 0.50 96 371 INTRM1 DRILL PULD P PU & MU 3 jts non mag DCs, 1 jt HWDP, Jars, 4 'ts HWDP 04:00 08:00 4.00 371 6,716 INTRM1 DRILL TRIP P TIH from 371' to 6716' MD by PU 102 jsts of 4" DP from pipe shed and 68 stds from derrick 08:00 08:30 0.50 6,716 6,875 INTRM1 DRILL REAM P Wash down from 6716' MD to 6875' MD. Tagged up @ 6875' MD w/ 10k- On de th for float collar 08:30 09:30 1.00 6,875 6,875 INTRM1 CASIN( DHEQ P Circu air from system -Preform casing Test 3000 si & chart for 30 min 09:30 11:15 1.75 6,968 6,993 INTRM1 DRILL DRLG P Drill float equipment & 25' of new hole to 6993' MD. PU = 103k, SO = 70k, Rot = 80k, TQ = 5k, ADT = .07, AST _ .07 11:15 12:00 0.75 6,993 6,993 INTRM1 DRILL CIRC P Circ. BU and until mud is uniform in and out for LOT 12:00 12:15 0.25 6,993 6,993. INTRM1 DRILL SFTY P PJSM -Leak off test (Pressure Hazards 12:15 13:00 0.75 6,993 .6,993 INTRM1 DRILL FIT P Leak off test w/ 8.8 ppg, TVD 3628', OBM @ 15.9 ppg EMW. Blow down lines 13:00 00:00 11.00 6,993 7,660 PROD1 DRILL DDRL P Drill ahead from 6993' to 7660' MD (3658' TVD). AST = 1.02 hrs, ART = 6.82 hrs, ADT = 7.84 hrs, Jars (#14001358) = 7.91 hrs, PU = 135k, SO = 74k, ROT = 93k, TQ = 5k (on & off btm), ECDs = 10.13, Max Gas = 70 units, Kill rates w/ 8.7 ppg MW @ 7620' MD (3657' TVD): #1 Pump @ 30 spm = 700 psi, @ 40 spm = 910 psi; #2 Pump @ 30 spm = 650 psi, @ 40 . spm = 880 psi. SLIDE Ftg (7107-7140' @ 150R), (7337-7348' @ 20R), (7348-7382' @ 34R), 7439-7479' @ 10 R). Concretion MDs (7035-7042'), (7190-7192'), (7274-7277'), 7482-7606' ... Total = 136' 07/09/2006 00:00 00:15 0.25 7,660 7,660 PROD1 DRILL SFTY P PJSM - On drlg ahead -Discuss pinch oints rage ~ ~¢ ~~ t~ -- -- - - - - - -- - - -- --- ~ I Time Logs - -- Date From To Dur pth E._Deeth Phase _ Code Subcode T UM _ 07/09/2006 00:15 12:00 11.75 7,660 8,170 PROD1 DRILL DDRL P Drlg w/ Motor f/ 7660' MD to 8170' MD ADT 9.09 hrs, Up wt 135k, Dn wt 80k, Rot wt 105k, Torq On Bttm 6k -Off bttm 6k, ECDs 10.15, Max gas = 107 units, Jar hrs = 17 hrs. PR 298 gpm, PP 3300 psi, RPMs 80, WOB 10-15k. Concretions @ 7673' - 7706', 7730' - 7740', 7801' - 7812' , 7895' - 7940' Total 99' 12:00 12:15 0.25 8,170 8,170 PROD1 DRILL SFTY P PJSM - Drlg Ahead - BROOH hazards 12:15 14:00 1.75 8,170 8,281 PROD1 DRILL DDRL P Drlg w/ Motor f/ 8170' to 8281' MD / 3631' TVD, ADT 1.89 hrs, PR 300 m, PP 3200, RPMs 80, WOB 8-12k, 14:00 15:00 1.00 8,281 8,281 PROD1 DRILL CIRC P Get SPR -Pump up last Survey - CBU, Recip drill string full 90', PR 300 m. RPMs 80 15:00 16:30 1.50 8,281 6,898 PROD1 DRILL TRIP P POOH on elevators to 6898' MD small tight spots at 7435' & 7350') both wiped clean. These were noted to be set and slide area's. 16:30 17:15 0.75 6,898 6,898 PROD1 DRILL CIRC P Pump 30 sweep @ csg shoe. Pump, rotate and recip 90' stroke. PR 300 gpm, 70 RPMs -Sweep showed minimal increase in cutting -Hole a ears clean and in ood sha e. 17:15 18:15 1.00 6,898 8,281 PROD1 DRILL TRIP P RIH to 8258' MD -Precautionary wash to bttm 8281' MD / 3631' TVD. No tight hole noted - No fill 18:15 19:30 1.25 8,281 8,281 PROD1 DRILL CIRC P Pump 30 bbl Wt/Hi Vis sweep - Circu and condition, PR 300 gpm, 80 RPMs - Flow Ck well 19:30 20:15 0.75 8,281 8,281 PROD1 DRILL CIRC P CO well bore fluid to 8.7ppg SFOBM - Pump 123 bbls SFOBM -Displace w/ 62 bbls OBM including dry job -Drop 1.75" drift. 20:15 23:00 .2.75 8,281 160 PROD1 DRILL TRIP P POOH on elevators - No tight hole - recoverdrift -Std bk HWDP w/jars - LD MWD tools. 23:00 00:00 1..00 160 0 PROD1 DRILL SRVY P Down Load MWD 07/10/2006 00:00 00:15 0.25 90 90 PROD1 DRILL SRVY P Con't Down load MWD. 00:15 00:30 0.25 90 90 PROD1 DRILL SFTY P PJSM- Discuss UD BHA and known hazards 00:30 01:00 0.50 0 0 PROD1 DRILL RURD P UD BHA - TM collar, PWD, Slimephase 4, DM HOC, Stab, NM Flt Sub, Motor, Bit 01:00 01:30 0.50 0 0 COMPZ DRILL RURD P Clear & Clean Rig Floor 01:30 01:45 0.25 0 0 COMPZ CASIN( SFTY P PJSM - on Rigging up & running 4.5" slotted liner 01:45 03:30 1.75 0 2,040 COMPZ CASIN( RUNL P PU & MU 48 jts of 4.5" slotted liner 03:30 04:00 0.50 2,040 2,040 COMPZ CASINC PUTB P PU & MU seal bore ext., liner hanger, C2 ZXP liner to acker ~~ F~ge ~ of~2 Time Logs Date From_To Dur _ _~, _~pth E_De~h Phase Code Subcode T 'DM _ ~ 07/10/2006 04:00 07:30 3.50 2,040 8,282 COMPZ CASIN( RUNL P Cont. RIH with 4.5" liner on DP to 8282' MD. Tagged up w/ 20k down wei ht 07:30 08:15 0.75. 8,282 8,275 COMPZ CASIN( DHEQ P PU to 8275' MD, PU = 148k, SO = 85k, Drop ball and pump down @ 3 BPM & 500 psi. Pressure up to 2500 psi to set hanger, 4000 psi to set packer, back out of setting tool with 15 turns to the right, PU = 134k, SO = 90k 08:15 09:30 1.25 8,275. 3,561 COMPZ DRILL TRIP P Flow check well (static), POOH from 6150' to 3561' MD 09:30 10:30 1.00 3,561 3,561 COMPZ RIGMN RGRP T Hydraulic power unit line Leak ... Fix same 10:30 12:00 1.50 3,561 0 COMPZ DRILL TRIP P Continue POOH from 3561' to surface 12:00 12:15 0.25 0 0 COMPZ DRILL SFTY P PJSM on UD running tools (proper ri in of overhead loads 12:15 13:00 0.75 0 0 COMPZ DRILL RURD P Brreak & UD running tools, clean rig floor monitor well on tri tank 13:00 13:30 0.50 0 0 COMPZ RIGMN SVRG P Service rig, top drive, drawworks couplings, override clutch & drum s ear 13:30 14:15 0.75 0 0 COMPZ EVALV~ RURD P Spot SWS logging unit & off load. tools 14:15 14:30 0.25 0 0 COMPZ EVALVI~ SFTY P PJSM on PU & RU wireline tools & USIT to in Pinch Points 14:30 16:00 1.50 0 0 COMPZ EVAL~/1~ RURD P RU wireline & PU USIT tools 16:00 17:30 1.50 0 0 COMPZ EVALVI~ DHEQ P Calibrate & Check equipment 17:30 20:15 2.75 0 6,150 COMPZ EVALV~ ELOG P RIH w/ USIT#ools (begin to tractor down @ 18" 30 hrs from 5130' MD to 6150' MD Schlumber er Tractor. 20:15 22:30 2.25 6,150 4,000 COMPZ EVALVI~ ELOG P Logging from 6150-4000' MD 22:30 23:00 0.50 4,000 0 COMPZ EVAL1l~ ELOG P POOH 23:00 00:00 1.00 0 0 COMPZ EVALV~ RURD P Rig down wireline & lay down USIT tools. Well monitored -Static. 07/11/2006 00:00 00:15. 0.25 0 0 COMPZ EVAL~/1~ RURD P Continue LD Cement /Corrosion to in tools. 00:15 00:30 0.25 0 0 PROD2 DRILL SFTY P PJSM for PU/MU whipstock assembly. 00:30 02:15. 1.75 0 107 PROD2 STK WPST P PU/MU anchor, whipstock /mill, seals, stop sub, unloader, 3-1l2" HWDP, pups, blank sub, trip anchor, safety disconnect, drain. sub, debris catcher, lower water mellon mill, flex joint, string mill, 3-1/2" HWDP, float sub, MWD. 02:15 03:00 0.75 107 107 PROD2 DRILL SRVY P Upload MWD. 03:00 03:30 0.50 107 479 PROD2 STK WPST P Continue PU Bumper sub, XO and 3 stds of 4" x 4-3/4" h brid ush i e. ~_ ~'~ge 1g af`22 --- - __ Time Logs _ _ _ ~ ~ ~ - _ . Date From To Dur e th E C>epth Phase Code _Subcode _ _ , ~.OP~1 _ ___~ 07/11/2006 03:30 03:45 0.25 479 479 PROD2 DRILL DHEQ P ~,~oM,.a Shallow test MWD at 285 GPM and 1,075 si - oka . 03:45 06:00 2.25 479 5,220 m PROD2 STK WPST P RIH from 479' - 5,220'. 06:00 06:45 0.75 5,220 , .5,270 oo PROD2 STK WPST P Make correlation MAD pass of K-13 from 5,250-70' tmd, at 295 gal and 2,060 si. 06:45 07:30 0.75 5,270 6,148 PROD2 STK WPST P Continue TIH from 5,270 - 6,148'. 07:30 07:45 0.25 6,148 6,072 PROD2 STK WPST P Orient whipstock to 14 deg left, PU = 130K, SO = 90K. Set whipstock. Top of whi stock at 6,072' tmd. 07:45 12:00 4.25 6,072 6,085 PROD2 STK WPST P Mill B-lateral window. Pump 30 bbl Hi-Vis sweep at 6,080'. TOW= 6,072' BOW= 6,085' 12:00 12:15 0.25 6,085 6,085 PROD2 DRILL SFTY P PJSM for milling. 12:15 13:00 0.75 6,085 6,111 PROD2 STK WPST P Drill new hole from 6,085-6,111' tmd, with 6-3/4" full guage hole to 6,095'. Pum 30 bbl Hi-Vis swee . 13:00 14:00 1.00 6,111 6,111 PROD2 DRILL CIRC P Circulate sweep out of hole at 300 GPM, 120 RPM, reciprocating pipe from 6,111 - 6,065' and working string mills throu h window. 14:00 15:45 1.75 6,111 479 PROD2 DRILL TRIP P POOH with milling assembly. 15:45 16:30 0.75 479 4,060 PROD2 DRILL PULD P LD Bumper sub and download MWD 16:30 17:00 0.50 4,060 0 PROD2 DRILL PULD P LD MWD and milling assembly. Upper mill in au e. 17:00 18:15 1.25 0 0 PROD2 DRILL OTHR P Pull WB, flush stack, set WB and clean ri floor. 18:15 19:00 0.75 0 91 PROD2 DRILL PULD P PU/MU drilling assembly with 6-3/4" Concretion bit, 5" motor, float sub and MWD. Orient MWD. 19:00 19:30 0.50 91 91 PROD2 DRILL SRVY P Upload MWD. 19:30 20:15 0.75 91 1,762 PROD2 DRILL DHEQ P RIH 15 stds to 1,762', shallow test MWD: 260 GPM = 1,630 psi, 300 GPM= 2,100 si. 20:15 21:00 0.75 1,762. 1,873 PROD2 DRILL DHEQ P PU AGI-tater, shock sub and RIH to std #16 at 1,873'. Shallow test AGI-tater and MWD: 260 GPM= 2,100 psi, 300 GPM= 2,650 psi. AGI-tater pressure increase = +/- 550 si. 21:00 22:00 1.00 1,873 5,980 PROD2 DRILL TRIP P Continue RIH to 5,980' filling DP at 5,048` and 5,980'. 22:00 22:15 0.25 5,980 5,980 PROD2 DRILL SFTY P PJSM for cut and slip DL. 22:15 23:15 1.00 5,980 5,980 PROD2 RIGMN SVRG P Cut and slip 48' of DL. Inspect brakes, ,.,L,~,~....,. check Saver sub, tube blocks and Top - Drive. I I I t'-a~~ f~ ~f 2 ___ - - -- ~ Time Lomas __ _--- - ~ __ _ Date From To Dur ~e th E De th Phase Code Subcode T QOM 07/11/2006 23:15 00:00 0.75 5,980 6,095 PROD2 DRILL TRIP P Break circ orient to 10L and wash to 6,065' tmd. Slide to 6,085'. Slide and ream to 6,095'. PU=98K, S0= 70K. 07/12/2006 00:00 12:00 12.00 6,095 6,919 PROD2 DRILL DDRL P Directionally drill 6-3/4" B-lateral from 6,095' - 6,919' tmd (3,488') ADT= 6.87, ART= 5.15, AST= 1.72 PU= 104K, S0= 65K, ROT= 83K TQ on/off = 5,000 / 4,000 ft-Ib ECD= 9.92 ppg Max Gas= 71 umits Concretions: 6,118-124', 6,154-161', 6,263-278', 6,309-332', 6,349-370', 6,372-379', 6,390-397' = 83' 12:00 00:00 12.00 6,919 8,010 PROD2 DRILL DDRL P Directionally drill 6-3/4" B-lateral from 6,919' - 8,010' tmd (3,487') ADT= 8.54, ART= 5.80, AST= 2.74 PU= 118K, S0= 58K, ROT= 83K TQ on/off = 5,000 / 4,500 ft-Ib ECD= 10.38 ppg Max Gas= 150 umits Concretions: 6,988-996', 7,389-397', 7,492-511', 7,528-540', 7,586-601', 7,661-668', = 69' 07/13/2006 00:00 09:00 9.00 8,010 8,988 PROD2 DRILL DRLG P PJSM. Drill 8,010 - 8,988' and (3,448' tvd). ADT= 5.8, AST= 1.52, ART= 4.28 09:00 10:00 1.00 8,988 8,998 PROD2 DRILL CIRC P Pump 35 bbl weighted Hi-Vis sweep @ 302 GPM, 3,600 psi and 100 rpm. Had 25% increase in cutting returns. Evaluate eolo 10:00 12:00 2.00 8,998 9,115 PROD2 DRILL DRLG P Drill ahead from 8,988-9,115' and (3,445' tvd). ADT= 0.77, AST= 0.13, ART= 0.54 PU= 125K S0= 45K ROT= 82K ECD= 10.77 ppg Max Gas= 127 units 12:00 13:30 1.50 9,115 9,248 PROD2 DRILL DRLG P Drill ahead from 9,115-9,248' and (3,432' tvd). ADT= 1.19, AST= 0.25, ART= 0.94 PU= 125K S0= 45K ROT= 82K ECD= 10.77 ppg Max Gas= 127 units 13:30 14:30 1.00 9,248 8,788 PROD2 DRILL REAM T POOH to 8,860' with 50K over uILBROOH 8,845-8,788'. 14:30 15:45 1.25 8,825 8,832 PROD2 DRILL DDRL T Sidetrack B-lateral, troughing and time drilling from 8,825-8,832'. KOP @8,825' and AST= 1.25 hr. 15:45 16:00 0.25 8,832 8,850 PROD2 DRILL DDRL T Drill sidetrack hole from 8,832-8,850' md. AST= 0.18 hr ®_. .~ - _ t'a~ 'i 2 of ~~ -- --- - ---- Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 07/13/2006 16:00 16:30 0.50 8,850 8,850 PROD2 DRILL SRVY T Take check shot surveys. Orient toolface for slide drillin . 16:30 21:00 4.50 8,850 9,248 PROD2 DRILL DRLG T Drill ahead from 8,850' - 9,248' and , ADT= 4.43 21:00 00:00 3.00 9,248 9,371 PROD2 DRILL DRLG P Drill from 9,248-9,371' and (3,452' tvd) ADT= 0.70, AST= 0.22, ART= 0.48 07/14/2006 00:00 12:00 12.00 9,371 10,200 PROD2 DRILL DRLG P PJSM. Drill ahead B-lateral from 9,371-10,200' tmd (3,431' tvd) ADT= 8.0, AST= 2.69, ART= 5.31 hrs PU= 135K S0= 60K ROT= 94K TQ on/off = 6,500. / 6,500 ft-Ib ECD=.10.8 ppg Max Gas= 153 units Concretions: 9,372-378', 9,412-16', 9,492-501', 9,710-12', 9,778-8T, 9,792-9,800', 10,013-020' 12:00 00:00 12.00 10,200 11,261 PROD2 DRILL DRLG P PJSM. Drill ahead B-lateral from 10,200-11,261' tmd (3,431' tvd) ADT= 6.67, AST= 1.67, ART= 5.0 hrs PU= 135K S0= 60K ROT= 94K TQ on/off = 6,500 / 6,500 ft-Ib ECD= 10.8 ppg Max Gas= 153 units Concretions: 10,249-258', 10,365-366', 10,472-475', 10,546-550', 10,646-649' 07/15/2006 00:00 12:00 12.00 11,261 12,252 PROD2 DRILL DRLG P Drill ahead B-lateral 11,261' - 12,252' tmd (3,409) Pump 30 bbl Hi-Vis sweep at 11,550', with a 15% increase in cutting returns. ADT= 6.85, ART= 5.47, AST= 1.38 hrs, PU= 155K, S0= 47K, ROT= 100K, TQ on/off = 9,000 / 9,000 ft-Ib, Max Gas= 130 units, ECD= 11.16 ppg Concretions: 12,020-033', 12,049-055', 12,120-124', 12,142-150' 12:00 21:15 9.25 12,252 12,963 PROD2 DRILL DRLG P Drill ahead B-lateral 12,252' -12,963' tmd (3,407) Pump 30 bbl Hi-Vis sweep at 12,930'. ADT= 5.67, ART= 4.09, AST= 1.58 hrs, PU= 15K, S0= 35K, ROT= 100K, TQ on/off = 10,000 / 10,000 ft-Ib, Max Gas= 70 units, ECD= 11.27 ppg, Concretions: 12,020-033', 12,049-055',.12,120-124', 12,142-150' 21:15 22:30 1.25 12,963 12,963 PROD2 DRILL CIRC P Circ sweep out while reciprocating pipe with 90 rpm and 278 gpm. Had a 5% increase in cutting returns. Monitor well -static. Surve at TD. 22:30 22:45 0.25 12,963 12,963 PROD2 DRILL SFTY P PJSM for BROOH. 22:45 00:00 1.25 12,963 12,277 PROD2 DRILL REAM P BROOH from 12,963' - 12,277' at 90 rpm, 45-50 ft/min, 278 gpm and 4,000 si. ~_ P~~' 13 cif 22 Time Lomas - _ - ~ate From To Dur S. e th E. Depth Phase Code 5ubcode T '~M 07/16/2006 00:00 07:45 7.75 12,277 5,985 PROD2 DRILL REAM P BROOH from 12,277 - 6,085' md, at 90 rpm, 278 gpm, 40-45 ft/hr. Max overpull 10-12K. Pull thru window with pumps off, no problem. Hole unloading a "moderate" amount of sand while BROOH from 7,000' - 6,085'. 07:45 09:00 1.25 5,985 5,985 PROD2 DRILL CIRC P Pump 30 bbl weighted Hi-Vis sweep. Circ 3x btms up at 5,985' with 300 gpm, 3,000 psi, 40 rpm, TQ=4,000 ft-Ib. Had a 10% increase in cuttings returns when um in swee . 09:00 10:00 1.00 5,985 5,985 PROD2 RIGMN SVRG P Service TD and inspect saver sub. 10:00 11:00 1.00 5,985 6,825 PROD2 DRILL TRIP P RIH through window w/o problems. PU 105K, S0= 65K. 11:00 13:30 2.50 6,825 12,425 PROD2 DRILL TRIP P PJSM. RIH to 12,140', filling pipe at 8,788' and 11,560'. Ream from 12,140-184'. Continue RIH to 12,425 with slackoff weight decreasing from 45K-34K block wei ht . 13:30 14:30 1.00 12,425 12,963 PROD2 DRILL REAM P Ream from 12,425' to TD at 90 rpm, 271 gpm and 3,900 psi and 45-50 ft/min. Tag btm, set back stand and PU single to be able to reciprocate i e. 14:30 16:00 1.50 12,963 12,963 PROD2 DRILL CIRC P Pump 30 bbl Hi-Vis sweep. Circulate and reciprocate pipe with 90 rpm, 278 gpm and 4,000 psi (pressure limit). Sweep returned 10% increase in cuttings. Monitor well -static. PU=170K, S0=34K, ROT=100K. 16:00 17:15 1.25 12,963 12,963 PROD2 DRILL CIRC P Pump and displace open hole 325 bbl of 8.7 SFMOBM. 17:15 22:30 5.25 12,963 250 PROD2 DRILL TRIP P LD single and POOH to AGI-tater and shock sub, LD same. Continue POOH, stand back HWDP, jars and flex collars. 22:30 00:00 1.50 250 50 PROD2 DRILL SRVY P Download MWD. Max Gas= 78 units 07/17/2006 00:00 01:00 1.00 50 50 PROD2 DRILL PULD P Continue downloading MWD. 01:00 01:30 0.50 50 0 PROD2 DRILL PULD P Continue LD BHA, break bit, and LD motor. 01:30 02:00 0.50 0 0 COMPZ DRILL OTHR P Pull WB 02:00 05:30 3.50 0 0 COMPZ DRILL OTHR P RU pressure test equipment, chit recorder and test BOPE to 250 psi / 3,000 psi hi/low, holding for 5 minutes of stabilized pressure. Test upper pipe - rams, choke valve manifold valves number 1, 12, 13 and 14, manual kill line, upper IBOP, HCR Kill, choke manifold valves #5,8 and 10, Dart valve, CV No. 4,6,7, floor valve, CV 2, HCR, Annual reventer, and Blind rams. 05:30 06:00 0.50 0 0 COMPZ DRILL OTHR P RD test equipment, install WB. ® i'~~r~ ~~# of~2 ~ Time Logs Date From To Dur She th E. De th Phase Code Subcode ~OM __ _ __ _ 07/17/2006 06:00 07:00 1.00 0 0 COMPZ CASIN( RURD P Clean rig floor and RU liner running tools. 07:00 11:30 4.50 0 6,053 COMPZ CASIN( RNCS P PJSM. Run 140 joints of Blank / Slotted, 11.6 Ib/ft, L-80, BTC liner with torque rings installed and 4-1/2" x 6-3/8" Hydroform centralizers on each joint with Stop collars on the center of each ~oint. 11:30 12:30 1.00 6,053 6,693 COMPZ CASIN( RNCS P PJSM. Finish running 155 joints of Blank /Slotted, 11.6 Ib/ft, L-80, BTC liner with torque rings installed. PU= 82K, S0= 60K, ROT= 65K, TQ=3,000 ft-Ib at 10 and 20 rpm. RD liner runnin tools, clean ri floor. 12:30 16:30 4.00 6,693 12,925 COMPZ CASIN( RUNL P PU/MU 5-1/2" receptacle, Liner setting sleeve and running tool, continue running liner on 4" DP to 12,608' and where SO weight = 0. Commence rotating liner down, working through tight spot @ 12,802'. Continue rotating liner unfit tagging bottom at 12, 959' md. PU and locate liner shoe on depth at 12, 925'. PU=175K, S0= OK, ROT= 97K, TQ= 10,000 ft-Ib at 20 r m. 16:30 17:15 0.75 12,925 6,032 COMPZ CASIN( RUNL P Drop ball and pump down to ball seat, pressure up to 2,000 psi and release liner. Pressure up to 4,400 psi and shear out Circ sub. PU= 135K. PU and tag top of liner, confirming TOL at 6,238'. POOH with running tool to 6,032' 17:15 18:00 0.75 6,032 6,032 COMPZ CASIN( CIRC P CBU. Monitor well -static. Pump slug. 18:00 20:00 2.00 6,032 200 COMPZ CASIN( RUNL P POOH with displacement 6 bbl over Had lost 6 bbl whilst testin BOPE 20:00 20:15 0.25 200 0 COMPZ CASIN( OTHR P Inspect-ok, and LD liner running tools. 20:15 20:45 0.50 0 50 COMPZ FISH PULD P PU/MU whipstock retrieving fishing tools 20:45 22:45 2.00 50 6,115 COMPZ FISH TRIP P RIH to 6,068 filling DP at 3,.130' and 6,068'. PU single, PU= 125K, S0=82K. Break circ. 22:45 23:30 0.75 6,100 6,100 COMPZ FISH FISH P Wash across whipstock slot, and attem t to hook. 07/18/2006 00:00 02:15 2.25 6,077. 6,077 COMPZ FISH JAR P Attempt and Hook Whipstock @ 6,077. 02:15 02:30 0.25 6,077 5,975 COMPZ FISH TRIP P UD 1 jt. 4" DP Rack back 1 stand DP Pick u wt. 130k-145K. 02:30 03:30 1.00 5,975 5,975 COMPZ FISH CIRC P CBU @ 5975' 48 spm 173 gpm 850 psi Max as B/U 51 units. 03:30 07:30 4.00 5,975 100 COMPZ FISH TRIP P Monitor well & pump dry job. POH P/U 130k-135k Calculate for trip out 51 bbls. Actual 55 bbls. P ~c~~ ~;:~ Est 22 Time Logs Date From To Dur 5 e th E De th Phase Code Subcode l 'UM 07/18/2006 07:30 08:30 1.00 100 0 COMPZ FISH PULD P PJSM-Lay down BHA Whipstock & Trip anchor assembly,2 3.5" pups 1 jt. 3.5" HWDP & seal assembl . 08:30 09:15 0.75 0 0 COMPZ FISH OTHR P Clean & clear rig floor. 09:15 10:15 1.00 0 0 COMPZ RIGMN SVRG P PJSM-Slip & cut 66' Drlg. line. 10:15 10:45 0.50 0 0 COMPZ RPCOh PULD P P/U Baker &MWD slimhole tools. 10:45 11:15 0.50 0 0 COMPZ RPCOh PULD P R/U Csg. Equipment. 11:15 12:00 0.75 40 40 COMPZ RPCOh RCST P P/U Shoe jt. 1 jt. 4.5" tbg. 12:00 12:15 0.25 40 213 COMPZ RPCOh RCST P PJSM-on P/U Hook hanger (Pinch points, good comunications,Remjnder sto ro ram. 12:15 14:15 2.00 213 300 COMPZ RPCOti RCST P P/U & M/U Hook hanger/MWD assembly, running tool &RIH (SPT @ 300' 14:15 16:30 2.25 300 6,207 COMPZ RPCOh TRIP P RIH tag main bore XO @ MD 6207'-P!U wt. 135k S/O wt. 84k. 16:30 18:15 1.75 6,207 6,283 COMPZ RPCOti TRIP P Pull up to 6060'-rotate 6 revs. & work torque-enter window & TO 6261-orient tool face & hook @ 6087 @ 7L stack 40k-pull up wl hook @ 6060' turn 180 deg. S!O & tag XO @ 6290'-P/U to hook @ 6060' & reorient TF 0-S/O & hook @ (MD 6087 & Stack 45k TF 7L) w/shoe MD 6283'. 18:15 19:00 0.75 6,283 6,283 COMPZ RPCOh DHEQ P Drop & Pump ball on seat-Press. up 2000 psi increase to 2700 psi shear & inflate packer w/ 4 stks (14.2 gal).-shear out circ. sub w/ 4500 si-monitor well-Static-POOH to 6038'. 19:00 19:45 0.75 6,283 6,283 COMPZ RPCOh CIRC P CBU (Max gas units 57) Monitor well-static- um slu . 19:45 21:45 2.00 6,283 120 COMPZ RPCOh TRIP P POOH -Displacement 1.25 bbis. long. 21:45 23:00 1.25 120 0 COMPZ RPCOti PULD P Lay down running tools &MWD assembl . 23:00 23:30 0.50 0 0 COMPZ RPCOh RURD P Clear & clean rig floor of tools. 23:30 00:00 0.50 0 0 COMPZ RIGMN SVRG P Rig service-tube crown,blocks & Top Drive. 07/19/2006 00:00 00:30 0.50 0 0 COMPZ RPCOh SFTY P PJSM-Rig up csg. Equipment 00:30 02:30 2.00 0 477 COMPZ RPCOh PULD P M/U Lem assembly, Bent jt. w/ seals, 1 jt. 4 1/2" tbg. DB-6 nipple 3 pup jts. 7 jts. IBT 4.5" tbg.CSBR, ZXP w/ runnin tool & XO. 02:30 05:30 3.00 477 6,070 COMPZ RPCOti TRIP P RIH w/ LEM assembly P/U 140k S/O 88k. Latch @ 6070' w/ Seal Assembly @ 6197.62' (10.21' Inside A2 CSR). Pull 160k-unlatch to verify. Relatch LEM & ull 150k. e P~ge1S o€ 2~ Time Logs fate Frnm Tn I~iir S Tenth F F~enth Pha.~e C;nrie ~iihr.~de T „(~M 07/19/2006 05:30 06:00 0.50 6,070 6,070 COMPZ RPCOti OTHR P Drop ball & pump down @ 3 bpm 400 psi.; Ball on seat @ 455 strokes.Set ZXP pressure to 2200psi. Pressure to 4000 si release LEM. 06:00 06:30 0.50 6,070 6,070 COMPZ RPCOh OTHR P Test ZXP down annulus to 1000 f/ 10 min on chart OK. 06:30 07:15 0.75 6,040 6,040 COMPZ RPCOti CIRC P Pull up to 6040-CBU @ 80 spm 1500 si 37 units as on B/U. 07:15 09:30 2.25 6,040 0 COMPZ RPCON TRIP P Monitor well-pump dry job & POH. 09:30 10:00 0.50 0 0 COMPZ RPCOh OTHR P Lay down liner running tools. 10:00 10:30 0.50 0 0 COMPZ RPCOh OTHR P Clear & clean floor & pick up tools. 10:30 12:00 1.50 0 0 PRODS FISH PULD P PJSM-make up mill assembly. NO w/ seals-unloader sub & 1 't. 3.5" DP. 12:00 12:15 0.25 0 0 PRODS FISH PULD P PJSM-on pick up milling & Whipstock assembl . 12:15 13:00 0.75 0 200 PRODS FISH PULD P P/U & M/U Whipstock, mill & MWD assembly (Orient) & pick up bumper sub. 13:00 13:30 0.50 200 200 PRODS FISH PULD P Program MWD. 13:30 16:00 2.50 200 5,050. PRODS FISH TRIP P RIH (SPT@ 477) Fill dp @ 3280 cont. RIH to 5050' & break circ. 16:00 16:30 0.50 5,050 5,140 PRODS FISH TRIP P Mad pass from 5050 to 5140'.. 16:30 17:00 0.50 5,140 5,801 PRODS FISH TRIP P RIH to 5755-break circ. P/U 125k S/O 85k-tag 5801'-shear anchor w/ 25k & Set whipstock @ 16 deg Left of .~ Highside -confirm w/ 5k overpull-slack off & shear off whipstock w/ 45k RT wt 100k 80 r mt 3-5k 256 m 1750 si. 17:00 22:30 5.50 5,697 5,711 PRODS FISH MILL P Mill L-2 window from5697 to 5711. 22:30 00:00 1.50 5,711 5,720 PRODS FISH MILL P Mill new hole from 5711 to 5720'. 07/20/2006 00:00 00:45 0.75 5,720 5,741 PRODS FISH MILL P Continue to drill gauge hole from 5720' t0 5741'. 00:45 01.:45 1.00 5,741 5,741 PRODS FISH CIRC P Pump 30 bbls. weighted hi-vis sweep-work mills thru window w/ pumps & rotation & without pumps & rotation. No problems. P/U 125k S/O 95k. 01:45 03:00 1.25 5,741 3,461 PRODS FISH TRIP P Monitor well-SPR-Pump dry job & poh to 3461'. 03:00 06:45 3.75 3,461 0 PRODS FISH TRIP P PJSM-Rig up & relocate supersliders on drill i e while POH. 06:45 07:00 0.25 0 0 PRODS FISH PULD P Lay down BHA-XO & Bumper sub. 07:00 07:15 0.25 0 0 PRODS FISH PULD P Down load MWD. 07:15 08:00 0.75 0 0 PRODS FISH PULD P Continue lay down BHA-upper mill was in au e. 08:00 08:15 0.25 0 0 PRODS FISH OTHR P Clear & clearrrig floor. ~~~~~ 1T of ~2 ' Time Lo s _ ~~ natP Frnm Tn niir ti Tenth F (tenth Phase Cnrin tiiihrnrle 7 i,~)M 07/20/2006 08:15 09:15 .1.00 0 0 PROD3 FISH OTHR P Pull wear bushing-flush bop stack-run wear bushin . 09:15 11:00 1.75 0 100 PROD3 DRILL PULD P PJSM-Make BHA #8. 11:00 12:00 1.00 100 100 PROD3 DRILL PULD P Upload MWD. 12:00 12:15 0.25 100 100 PROD3 DRILL SFTY P PJSM-On Tripping & Drlg. 12:15 12:30 0.25 100 365 PROD3 DRILL TRIP P RIH w/ BHA #8 to 365'. Break in eo- ilot S.P.T. & command test. 12:30 14:00 1.50 365 5,691 PROD3 DRILL TRIP P RIH to 5691'-break circ. 270 gpm 1700# P/U 98k S/O 70k.RW 84k TQ 4k. 14:00 14:30 0.50 5,691 5,741 PROD3 DRILL CIRC P Wash & Slide from 5691 to 5731'- & ream 5731 to 5741'. 14:30 00:00 9.50 5,741 6,400 PROD3 DRILL DDRL P Drilling from 5741' to 6400' (TVD 3434') Actual Rotatin Time 6.63 Hrs. 07/21/2006 00:00 12:00 12.00 6,400 7,430 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 6400' to 7430'. (3435 TVD) P/U 110k S/O 60k ROT 80k TQ 5.5k Max gas 134 units ECD 10.26 SPR @ Concretion depths 6497'-6501', 6505'-6506', 6514'-6517', 6554'-6556', 7064'-7067', 7139'-7141', 7172'-7175', 7178'-7190', 7199'-7203', 7357'-7363', 7380'-7387', 7389'-7397',. 12:00 00:00 12.00 7,430 8,430 PROD3 DRILL DDRL P Drlg. 6.3/4" Horizontal hole from 7430' to 8430'. (3408 TVD) P/U 115k S/O 50k ROT 78k TQ 6k Max gas 125 units ECD 10.5 SPR @ Concretion depths 7412-7418-7500-7507-7550-7569-7571- 7588-7844-7849-7863-7872-7874-7876- 7881-7888-7905-7907-7910-7911-7995- 8002-8005-8063-8064-8067-& 8068. 07/22/2006 00:00 12:00 12.00 8,430 9,985 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole From 8430' to 9985'. (TVD 3365'.) ART-8.07 P/U 127k S/O 35k ROT 77k TQ on 7k TQ off 7.5k Max gas 363 units ECD 11.07 Concretions=8620-8621-8625-8626-87 21-8724-8733-8736-8753-8756-9185- & 9188. 12:00 00:00 12.00 9,985 11,508 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole From 9985' to 11508'. (TVD 3337') ART 7.38 P/U 137k S/O 0 ROT 82k TQ on 8.5k TQ off 8.5k Max gas 118 units ECD 11.45 Concretions 10435-10440-10732-10733-10744-1074 5-10750-10751-10763-& 10765'. 07/23/2006 00:00 07:30 7.50 11,508 12,285 PROD3 DRILL DDRL P Drlg. Horizontal hole from 11508 #o 12285'. (TVD) 3345'. (77T) ART 4.61 WOB 5-15K, RPM 135, Pu 160K, Dn OK, ROT 98K, TQ 9.5K on / 8.5K off, Max gas 289 units, Ave ECD's 11.8 07:30 08:15 0.75 12,285 12,285 PROD3 DRILL DHEQ T Trouble shoot MWD. Change Mode. __ _ __ Time Logs Bate Fmm Tn I~iir 5 anth F f~enth Phase ~:nrie Suhrnrlr ~,nM 07/23/2006 08:15 10:45 2.50 12,285 12-,566 PRODS DRILL DDRL P Drlg. Horizontal hole from 12285' to 12566'. (TVD) 3330' (281'). ART 1.45 P/U 160k S/O 0 Rot 98k TQ on 9.5k Off 8.5k Max as 289 units ECD 11..8 10:45 11:00 0.25 12,566 12,566 PRODS DRILL OTHR P SPR,s Lay Down Jt. 4" DP. 11:00 12:00 1.00 12,566 12,566 PRODS DRILL CIRC P Pump 30 bbls. weighted hi-vis sweep @ 12562' @ 83 spm 3370 psi 135 rpm T 8k. 12:00 12:30 0.50 12,566 12,566 PRODS DRILL CIRC P Circ. sweep out @ 83 spm 3370psi 135 r m 8k TQ "0" increase in returns. 12:30 12:45 0.25 12,566 12,566 PRODS DRILL OTHR P Monitor well-Static-install stripping rubbers. 12:45 21:30 8.75 12,566 12,566 PRODS DRILL TRIP P BROOH f/ 12,565' MD 3330 TVD to window @ 5711 MD @ 120 rpm 85 spm 310 gpm 3050 psi tq 7k pulled @ 40-45 FPM Calc displacement 45 bbls. Actual dis lacement 58.4 bbls. 21:30 21:45 0.25 12,566 12,566 PRODS DRILL OTHR P Monitor well inside window-Static- Pull stri in rubbers. 21:45 00:00 2.25 12,566 12,566 PRODS DRILL CIRC P Break circ. pump 35 bbls weighted hi-vis sweep @ 275 gpm till thru mwd , increase rate to 300 gpm 100 rpm, 2100 psi, 10% increase in returns, circulate shakers clean @ 3-bottoms u. 07/24/2006 00:00 01:00 1.00 12,566 5,600 PRODS DRILL OTHR P PJSM=Cut 91' drlg. line, Service top drive & ins ect saver sub. 01:00 03:15 2.25 5,600 10,127 PRODS DRILL TRIP P RIH, slide thru window-no problems, RIH to 10127' ran out of down wei ht. 03:15 06:00 2.75 10,127 12,560 PRODS DRILL TRIP P Wash & ream in hole from 10127' to 12560' @ 77 spm 280 gpm 50 rpm 2500 si TQ 6k, 06:00 07:30 1.50 12,560 12,560 PRODS DRILL CIRC P Pump 30 bbls. weighted hi-vis sweep 310 gpm 85 spm 120 rpm 3560 psi TQ 8.5k ECD 11.58 total gas 30 units 10% increase in cuttings on BU w/ swee . 07:30 08:45 1.25 12,560 12,560 PRODS DRILL CIRC P Pump 320 bbls. 8.7# SFOBM, Displace w/ 50 bbls. OBM including d 'ob. 08:45 12:00 3.25 12,560 7,652 PRODS DRILL TRIP P Monitor well, POH w/25-30k 175k P/U. 25-30k drag from 11970. (NOTE) Ramp on geo-pilot stuck @ 60deg. reflection. POH to 7652' P/U 125k S/O 52k. 12:00 14:45 2.75 7,652 0 PRODS DRILL TRIP P POH on elevators from 7652' No roblems ullin thru window. 14:45 15:45 1.00 0 0 PRODS DRILL PULD P Lay down hwdp, jars & 3 moneys. 15:45 16:30 0.75 0 0 PRODS DRILL OTHR P Down load MWD. 16:30 17:45 1.25 0 0 PRODS DRILL PULD P Pull up, Break bit, lay down MWD & Geo- ilot. 17:45 . 18:15 0.50 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. T ~ ~ ~ I"'~;g~ 13 Ctf ~~ ~me Lois -- ^ate From To Dur 5. e th E. De th Phase Code Subcode T C,OM 07/24/2006 18:15 18:45 0.50 0 0 COMPZ CASIN ( RURD P Rig up to run 4 1/2" slotted liner in "D" Lateral. 18:45 23:00 4.25 0 6,629 COMPZ CASIN( RUNL P PJSM=Run 4 1/2" liner to 6629', went thru window w/ no problems. Calc. displacement 27.7 Actual dis lacement 15.8 bbls. 23:00 23:30 0.50 6,629 6,629 COMPZ CASIN( PUTB P Change out handling tools=make up liner settin toot. 23:30 00:00 0.50 6,629 6,629 COMPZ CASIN( PUTB P Rig down csg. tools, rig up to run liner on 4" dp. P/U Jt. #154 82k S/O Jt. 154 58k. 07/25/2006 00:00 03:45 3.75 6,629 12,566 COMPZ CASIN( RUNL P Rotate liner @ 6730' 20 rpm TQ 3.5k=Run 4.5" slotted liner on 4" dp from 6629' to 12,566'=tag bottom P/U 170k S/O 45k. 03:45 04:00 0.25 12,566 12,551 COMPZ CASIN( RUNL P Pull up, rotate liner 20 rpm w/ 9K ft/Ib Torque, S/O tag bottom pull up to 12551.0 04:00 04:45 0.75 12,551 12,551 COMPZ CASIN( RUNL P Drop ball-set liner on depth while rotating. Pump down @ 4bpm saw no indication of ball seating after 1250 strokes. Shut down pumps. Mechanicaly released from liner 10k dro P/U 125k. 04:45 05:30 0.75 12,551 5,711 COMPZ DRILL CIRC P Pull 2 stands dp=CBU-wash whipstock slot from 5697-5711 @ 72 spm 1400 si 275 m. 05:30 08:00 2.50 5,711 0 COMPZ DRILL TRIP P Monitor well & POH. 08:00 08:30 0.50 0 0 COMPZ DRILL PULD P Lay down liner running tool & clean floor. 08:30 09:30 1.00 0 0 COMPZ DRILL PULD P PJSM-Make up whipstock retrieving tools. 09:30 12:00 2.50 0 5,604 COMPZ DRILL TRIP P RIH to 5604' P/U T25k S/O 85k. 12:00 12:15 0.25 5,604 5,604 COMPZ DRILL OTHR P Latched whipstock on second try ulled 60k over strin wt. 12:15 12:30 0.25 5,604 5,573 COMPZ DRLLL PULD P Lay down single. 12:30 13:00 0.50 5,573 5,573 COMPZ DRILL CIRC P CBU @ 86 spm 1800 psi No gas. 13:00 13:30 0.50 5,573 5,573 COMPZ DRILL CIRC P Monitorwell-static-pump dry job. 13:30 16:00 2.50 5,573 0 COMPZ DRILL TRIP P POH w/ whipstock. 16:00 17:45 1.75 0 0 COMPZ DRILL PULD P Lay down BHA & whipstock ramp assembl . 17:45 18:30• 0.75 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. 18:30 19:00 0.50 0 220 COMPZ CASIN( RURD P P/U hook hanger tools from bottom of slide. 19:00 20:00 1.00 220 220 COMPZ CASIN( RURD P Rig up csg. tools. 20:00 20:30 0.50 220 220 COMPZ CASIN( SFTY P PJSM=on making up & running hook han er assembl . Time Logs Date From To Dur S. e th E De th Phase Code Subcode T COM _ 07/25/2006 20:30 21:00 0.50 220 220 COMPZ RIGMN SVRG P Service top drive. 21:00 23:15 2.25 220 220 COMPZ CASIN ( RURD P Make up hook hanger assembly slimhole MWD, space out tbg. for inner strin . 23:15 00:00 0.75 220 220 COMPZ CASIN ( RURD P Lay down csg. tools, clear & clean rig floor. 07/26/2006 00:00 03:45 3.75 220 5,670 COMPZ CASIN( RUNL P Shallow test MWD-RIH to 5840'-Tag up in mother bore-pull up to 5670'. Rotate 3.5 turns to right-go thru window-orient 6 de .left. 03:45 04:45 1.00 .5,670 5,694 COMPZ CASIN( RUNL P Hook window-unhook turn 180 deg. go past-pull up-rehook set down 35k twice-hook set on depth @ 5711'-top of hook 5694'. 04:45 05:30 0.75 5,694. 5,694 COMPZ CASIN( CIRC P Drop ball-pump @ 2 bpm on seat @ 560 strokes-pressure up 2650 psi inflate ECP-release from hook-pressure to 4300 psi could not shear um out sub. 05:30 08:30 3.00 5,694 0 COMPZ DRILL TRIP P POH to 5672' monitor well pump pill & POH. 08:30 10:30 2.00 0 0 COMPZ CASIN( RURD P Rig down double stack tongs lay down hook running tool 3 jts. 2 7/8" wash i e & slim hole MWD. 10:30 11:30 1.00 0 0 COMPZ CASIN( KURD P Rig down tongs-clear & clean rig floor. 11:30 12:00 0.50 0 0 COMPZ CASIN< RURD P Rig up csg. equipment. 12:00 12:30 0.50 0 0 COMPZ CASIN( SFTY P PJSM=Hazard assesment on make up & runnin LEM. 12:30 15:30 3.00 0 5,653 COMPZ CASIN( RNCS P RIH w/ LEM on 4" DP to 5653'. 15:30 16:45 1.25 5,653 5,653 COMPZ CASIN( OTHR P Slid LEM into sealbore assembly, Latched up, unlatched then relatched, saw visual on wt. indicator, dropped ball & pumped down @ 36 spm 430 psi ball seat @ 460 strokes, pressured up to 2000 psi, saw shear, pump to 4000 si for 1 minute. 16:45 17:00 0.25 5,653 5,653 COMPZ CASIN< OTHR P Test ZXP packer @ 1000 psi for 10 minutes on chart. 17:00 17:45 0.75 5,653 5,653 COMPZ CASIN( CIRC P CBU @ 51 spm 770 psi. 17:45 18:00 0.25 5,653 5,653 COMPZ CASIN( RURD P Rig down test equipment. 18:00 18:30 0.50 5,653 5,653 COMPZ CASIN( CIRC P Pump dry job, blow down top drive & kill line. 18:30 20:45 2.25 5,653 0 COMPZ CASIN( OTHR P Monitor well-POH. 20:45 21:00 0.25 0 0 COMPZ CASIN( OTHR P Clean rig floor. & pull wear bushing. 21:00 21:45 0.75 0 0 COMPZ CASIN( RURD P Rig up csg. tools. 21:45 22:15 0.50 0 0 COMPZ CASIN< SFTY P PJSM on running tbg. w/ Baker re =Co. re & crew. ~~a ~_ ~._ r age 21_ o~ ~~ Time Logs Date Froni To Dur S. e~th_ E. Depth_ Phase Code Subcode ~OM 07/26/2006 22:15 00:00 1.75 0 660 COMPZ CASIN( OTHR P Running completion tbg. & accesaries. 07/27/2006 00:00 03:45 3.75 660 5,646 COMPZ RPCOti PULD P Continue to RIH w/ 4.5" 12.6# IBTM tbg. ran total of 180 jts. P/U 75k S/O 60k. 03:45 05:00 1.25 5,646 5,646 COMPZ RPCOti CIRC P Rig up circ. head Circ. 3 B/U @ 210 spm 810 gpm 1800 psi circ. till shakers clean ri down circ. head. 05:00 06:00 1.00 5,646 5,674 COMPZ RPCOh HOSO P RIH to 5674' tagged seal locator, pull u & s ace out w/ 5.80 u . 06:00 06:30 0.50 5,674 5,674 COMPZ RPCOti HOSO P Make up tbg. hanger & land tbg. P/U 75k S/O 60k. 06:30 07:30 1.00 5,674 5,674 COMPZ RPCOh DHEQ P RILDS-test tbg. hanger seals 5000 psi test10 mins. OK. 07:30 08:45 1.25 COMPZ RPCOti NUND P PJSM=Nipple down BOPE. 08:45 11:30 2.75 COMPZ RPCOI~ NUND P PJSM-nipple up tree-test void to 5000 si test tree & accuator 5000 si OK. 11:30 12:00 0.50 COMPZ RPCOh OTHR P Rig up cellar for displacement. Rig up to la down DP from derrick. 12:00 12:15 0.25 COMPZ RPCOh SFTY P PJSM= hazard assesment on laying down drill i e. 12:15 13:15 1.00 COMPZ RPCOh PULD P Lay down 16 stands 4" drill pipe. 13:15 13:30 0.25 COMPZ RPCOh SFTY P PJSM=on Freeze protect. 13:30 15:30 2.00 COMPZ RPCOh FRZP P Freeze protect tbg. & annulus w/ 255 bbls. diesel 5 b m. 15:30 16:15 0.75 COMPZ RPCOh PULD P Lay down 7 stands 4" drill pipe. 16:15 16:45 0.50 COMPZ RPCOh OTHR P Pick up BPV & set same w/ Vetco Gra . 16:45 21:00 4.25 COMPZ RPCOh PULD P Lay down the rest of slick pipe 82 stands. 21:00 00:00 3.00 COMPZ RPCOh PULD P Lay down 15 stands push pipe-7 stands hwdp-5 stands super slider i e. 07/28/2006 00:00 02:45 2.75 COMPZ RPCOh PULD P Continue laying down 4" DP from derrick-inspecting hard bands, removing supersliders from the ones that need new hard bands. 02:45 04:00 1.25 COMPZ RPCOh OTHR P Clear & clean rig floor & cellar. (Release rig from 1J-156 to Rig Maintenance 7-28-2006 0400. - Fie ~~ of 22 Halliburton Company, Survey Report (omwui~: ConucoPhillips Alaska Inr_ U~uc_ 8;0I~006 l iwc: 10:01.30 I'a~_c: 1 IicIJ: Kuparuk Ri ver Unit (u-ur~linau~(\I') Ilcfcrcnc~~: Well- 1J-156, T rue North ~~ih•: Kuparuk 1J Pad 1cr~ic:~l (f~l)) licli~rcncc: 1J-156L1: 109. 0 ~~cll: 1J-156 tiec~iun j~ti) Kcfercncc Well 0.OON.OOOEloQ00Azij 1Vellpath: 1J-156 L1 Survey (~alcul:~tion ~1etlioil: Minimum Curvature Ilh: Oracle Field: Kuparuk River Unit North Slo pe Alaska United States Map System:US State Plane Coordinate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-156 Slot Name: Well Position: +N/-S -13.52 ft Northing: 5945 905.02 ft • Latitude: 70 15 46.125 N +E/-W -140.85 ft Easting : 558649.22 ft Longitude: 149 31 33.105 W Position Un certainty: 0.00 ft Wellpath: 1 J-156L1 Drilled From: 1 J-156L1 PB1 500292331160 Tie-on Depth: 8742.94 ft Current Da tum: 1J -156L1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/28/2006 Declination: 24.04 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 18 0.00 Survey Program for Definitive Wellpath Date: 8!9/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 539.00 1J-156 gy ro (50.00-539.00) (0) CB-GYRO-SS Camera based gyro single shot 628.39 6002.04 1 J-156 (628.39-8233.13) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 6072.44 8742.94 1J-156L1 PB1 (6072 .44-9206.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 8784.71 12920.97 1J-156L1 (8784.71-12920.97) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ~IU Incl ~iim l~I) Sc~lll) V'C E1~ 11>i~iA \Ia~~l; Foul ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945905.02 558649.22 TIE LINE 50.00 0.12 309.10 50.00 -59.00 0.01 -0.02 5945905.03 558649.20 CB-GYRO-SS 100.00 0.33 302.21 100.00 -9.00 0.12 -0.18 5945905.14 558649.04 CB-GYRO-SS 170.00 0.16 227.52. 170:00 61.00 0.17 -0.42 5945905.18 558648.80 CB-GYRO-SS 261.00 0.84 274.09 261.00 152.00 0.13 -1.18 5945905.14 558648.04 CB-GYRO-SS 357.00 3.64 283.48 356.91 247.91 0.89 -4.85 5945905.87 558644.37 CB-GYRO-SS 446.00 7.52 285.11 445.47 336.47 3.07 -13.22 5945907.98 558635.98 CB-GYRO-SS 539.00 9.29 284.65 537.47 428.47 6.55 -26.36 5945911.36 558622.81 CB-GYRO-SS 628.39 10.78 282.16 625.49 516.49 10.14 -41.51 5945914.83 558607.63 .MWD+IFR-AK-CAZ-SC 661.48 12.02 281.08 657.93 548.93 11.45 -47.92 5945916.10 558601.22 MWD+IFR-AK-CAZ-$C 697.90 13.22 279.83 693.47 584.47 12.89 -55.75 5945917.47 558593.38 MWD+IFR-AK-CAZ-SC 764.19 15.65 278.50 757.66 648.66 15.51 -72.06 5945919.96 558577.05 MWD+IFR-AK-CAZ-SC 856.58 15.78. 279.44 846.60 737.60 19.41 -96.78 5945923.67 558552.30 MWD+IFR-AK-CAZ-SC 948.01 18.55 280.46 933.95 824.95 24.09 -123.35 5945928.15 558525.70 MWD+IFR-AK-CAZ-SC 1040.41 22.41 279.81 1020.49 911.49 29.76 -155.17 5945933.57 558493.84 MWD+IFR-AK-CAZ-SC 1133.37 25.84 279.39 1105.32 .996.32 36.09 -192.63 5945939.60 558456.34 MWD+IFR-AK-CAZ-SC 1225.55 28.82 279.19 1187.20 1078.20 42.91 -234.39 5945946.10 558414.53 MWD+IFR-AK-CAZ-SC 1320.60 32.24 280.08 1269.06 1160.06 51.01 -281.98 5945953.83 558366.88 MWD+IFR-AK-CAZ-SC 1413.40 34.96 281.94 1346.35 1237.35 60.85 -332.37 5945963.27 558316.41 MWD+IFR-AK-CAZ-SC 1506.74 35.50 281.10 1422.59 1313.59 71.60 -385.13 5945973.61 558263.58 MWD+IFR-AK-CAZ-SC 1598.95 36.98 280.44 1496.96 1387.96 81.78 -438.68 5945983.37 558209.95 MWD+IFR-AK-CAZ-SC 1692.74 39.87 279.40 1570.43 1461.43 91.80 -496.10 5945992.95 558152.47 MWD+IFR-AK-CAZ-SC 1782.84 46.17 278.46 1636.28 1527.28 101.31 -556.80 5946001.98 558091.71 MWD+IFR-AK-CAZ-SC 1875.42 48.72 278.17 1698.88 1589.88 111.17 -624.27 5946011.31 558024.16 MWD+IFR-AK-CAZ-SC 1967.60 52.01 275.99 1757.68 1648.68 119.88 -694.71 5946019.48 557953.67 MWD+IFR-AK-CAZ-SC 2060.57 58.03 272.32 1810.97 1701.97 125.31 -770.63 5946024.31 557877.71 MWD+IFR-AK-CAZ-SC 2154.73 58.56 270.78 1860.45 1751.45 127.47 -850.71 5946025.85 557797.63 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~uupan}: Conoco Phillips Alaska Inc. 11aic: 2/9/2006 lime: 10.01~~0 I'a~_c:_ Ficl~l: K uparuk Ri ver Unit ( '~,-ur~linatc(\I. ) Rclercncr: Well: 1J-156, T rue North tii~c: K uparuk 1J Pad 1~ crlical f~f~l)1 Kclircn~~e: 1J-156L1: 109 .0 ~'1cll: 1 J-15o ti cctiun 1~~~~1 Ilc fcrcncc: V~ell i0.OON.0-OOE1o0.OOAzi) '.1'i~llparh: 1J -156L1 til ing (aLulat iur~ 11ctlx>d: R~linimum Curv ature 116: Oracle ~unc~ ft deg deg ft ft ft ft ft ft 2242.55 60.83 269.43 1904.77 1795.77 127.60 -926.52 5946025.39 557721.83 MWD+IFR-AK-CAZ-SC 2335.91 60.92 269.25 1950.21 1841.21 126.66 -1008.07 5946023.82 557640.29 MWD+IFR-AK-CAZ-SC 2429.73 60.92 270.59 1995.81 1886.81 126.55 -1090.06 5946023.06 557558.31 MWD+IFR-AK-CAZ-SC 2523.25 61.26 268.34 2041.02 1932.02 125.78 -1171.91 5946021.66 557476.48 MWD+IFR-AK-CAZ-SC 2616.59 57.90 268.87 2088.28 1979.28 123.82 -1252.37 5946019.07 557396.05 MWD+IFR-AK-CAZ-SC 2709.57 58.96 268.53 2136.96 2027.96 122.02 -1331.56 5946016.65 557316.87 MWD+IFR-AK-CAZ-SC 2729.48 59.49 268.15 2147.14 2038.14 121.52 -1348.66 5946016.02 557299.78 MWD+IFR-AK-CAZ-SC 2826.57 60.03 267.98 2196.04 2087.04 118.69 -1432.49 5946012.54 557215.98 MWD+IFR-AK-CAZ-SC 2920.36 58.92 266.59 2243.68 2134.68 114.87 -1513.19 5946008.09 557135.33 MWD+IFR-AK-CAZ-SC 3012.90 58.01 264.09 2292.08 2183.08 108.47 -1591.79 5946001.08 557056.78 MWD+IFR-AK-CAZ-SC 3108.25 57.70 263.40 2342.82 2233.82 99.67 -1672.04 5945991.66 556976.61 MWD+IFR-AK-CAZ-SC 3202.47 59.79 259.98 2391.71 2282.71 88.01 -1751.72 5945979.38 556897.04 MWD+IFR-AK-CAZ-SC 3295.75 61.28 254.21 2437.62 2328.62 69.85 -1830.82 5945960.61 556818.08 . MWD+IFR-AK-CAZ-SC 3389.35 61.96 248.08 2482.14 2373.14 43.25 -1908.70 5945933.39 556740.43 MWD+IFR-AK-CAZ-SC 3482.06 60.16 242.90 2527.03 2418.03 9.63 -1982.49 5945899.21 556666.90 MWD+IFR-AK-CAZ-SC 3575.84 59.32 237.52 2574.31 2465.31 -30.57 -2052.76 5945858.46 556596.96 MWD+IFR-AK-CAZ-SC 3669.53 .59.15 236.82 2622.23 2513.23 -74.22 -2120.40 5945814.30 556529.66 MWD+IFR-AK-CAZ-SC 3762.54 59.35 236.61 2669.79 2560.79 -118.08 -2187.22 5945769.91 556463.19 MWD+IFR-AK-CAZ-SC 3856.53 59.81 237.44 2717.38 2608.38 -162.20 -2255.22 5945725.28 556395.55 MWD+IFR-AK-CAZ-SC 3949.79 62.02 236.39 2762.71 2653.71 -206.69 -2323.49 5945680.26 556327.63 MWD+IFR-AK-CAZ-SC 4041.96 62.70 235.18 2805.47 2696.47 -252.60 -2391.01 5945633.83 556260.48 MWD+IFR-AK-CAZ-SC 4135.29 62.94 233.80 2848.11 2739.11 -300.83 -2458.59 5945585.08 556193.28 MWD+IFR-AK-CAZ-SC 4228.84 63.84 233.61 2890.01 2781.01 -350.34 -2526.00 5945535.05 556126.27 MWD+IFR-AK-CAZ-SC 4324.27 63.22 228.72 2932.57 2823.57 -403.87 -2592.52 5945481.00 556060.17 MWD+IFR-AK-CAZ-SC 4415.66 61.95 227.40 2974.64 2865.64 -458.09 -2652.87 5945426.33 556000.25 MWD+IFR-AK-CAZ-SC 4511.02 62.68 223.46 3018.96 2909.96 -517.34 -2713.00 5945366.62 555940.59 MWD+IFR-AK-CAZ-SC 4604.16 61.72 221.00 3062.41 2953.41 -578.33 -2768.38 5945305.20 555885.70 MWD+IFR-AK-CAZ-SC 4695.44 62.82 217.23 3104.89 2995.89 -641.01 -2819.32 5945242.13 555835.25 MWD+IFR-AK-CAZ-SC 4789.29 65.39 211.95 3145.90 3036.90 -710.50 -2867.19 5945172.28 555787.93 MWD+IFR-AK-CAZ-SC 4882.76 66.00 206.67 3184.39 3075.39 -784.75 -2908.86 5945097.71 555746.84 MWD+IFR-AK-CAZ-SC 4977.56 66.41 201.68 3222.66 3113.66 -863.85 -2944.37 5945018.34 555711.95 MWD+IFR-AK-CAZ-SC 5071.42 68.37 197.34 3258.76 3149.76 -945.50 -2973.27 5944936.48 555683.69 MWD+IFR-AK-CAZ-SC 5163.66 71.51 194.39 3290.40 3181.40 -1028.83 -2996.93 5944852.98 555660.68 MWD+IFR-AK-CAZ-SC 5257.97 72.05 190.73 3319.90 3210.90 -1116.25 -3016.40 5944765.42 555641.89 MWD+IFR-AK-CAZ-SC 5351.05 75.87 186.20 3345.62 3236.62 -1204.69 -3029.53 5944676.88 555629.46 MWD+IFR-AK-CAZ-SC 5444.97 76.47 180.99 3368.09 3259.09 -1295.68 -3035.24 5944585.87 555624.45 MWD+IFR-AK-CAZ-SC 5538.34 77.43 178.91 3389.17 3280.17 -1386.63 -3035.16 5944494.93 555625.25 MWD+IFR-AK-CAZ-SC 5631.47 78.39 178.69 3408.68 3299.68 -1477.67 -3033.25 5944403.91 555627.86 MWD+IFR-AK-CAZ-SC 5722.81 78.34 178.91 3427.10 3318.10 -1567.12 -3031.38 5944314.49 555630.43 MWD+IFR-AK-CAZ-SC 5815.21 78.12 177.99 3445.95 3336.95 -1657.54 -3028.93 5944224.10 555633.58 MWD+IFR-AK-CAZ-SC 5909.06 80.59 179.04 3463.28 3354.28 -1749.73 -3026.54 5944131.93 555636.69 MWD+IFR-AK-CAZ-SC 6002.04 80.60 179.31 3478.48 3369.48 -1841.46 -3025.22 5944040.24 555638.72 MWD+IFR-AK-CAZ-SC ' 6072.44 80.56 179.15 3490.00 • 3381.00 -1910.90 -3024.29 5943970.81 555640.20 MWD+IFR-AK-CAZ-SC 6125.63 85.92 181.04 3496.26 3387.26 -1963.70 -3024.38 5943918.02 555640.51 MWD+IFR-AK-CAZ-SC 6160.68 89.90 182.77 3497.54 3388.54 -1998.70 -3025.55 5943883.01 555639.62 MWD+IFR-AK-CAZ-SC 6220.29 90.49 179.29 3497.34 3388.34 -2058.29 -3026.62 5943823.42 555639.01 MWD+IFR-AK-CAZ-SC 6313.19. 89.69 180.08 3497.19 3388.19 -2151.18 -3026.11 5943730.54 555640.25 MWD+IFR-AK-CAZ-SC 6404.65 88.27 178.22 3498.82 3389.82 -2242.61 -3024.75 5943639.13 555642.32 MWD+IFR-AK-CAZ-SC 6499.60 89.88 179.11 3500.35 3391.35 -2337.52 -3022.54 5943544.25 555645.27 MWD+IFR-AK-CAZ-SC 6592.52 90.31 178.56 3500.20 3391.20 -2430.42 -3020.65 5943451.38 555647.88 MWD+IFR-AK-CAZ-SC 6685.63 92.29 177.37 3498.08 3389.08 -2523.44 -3017.35 5943358.40 555651.91 MWD+IFR-AK-CAZ-SC 6780.22 92.10 181.23 3494.46 3385.46 -2617.94 -3016.19 5943263.92 555653.80 MWD+IFR-AK-CAZ-SC 6873.75 92.66 180.47 3490.58 3381.58 -2711.38 -3017.58 5943170.48 555653.14 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report (~nnipau~: ConocoPhillips Alaska Inc. I):uc: 3j°!2006 Iimc: 10.01.30 I'^~,c: 3 1 icl~l: Kuparuk River Unit (~o-or~linatclAF-1 ReCcrcncc: Well. 1J-156. True North tiitc: Kuparuk 1J Pad ~crticallh~I))Rclcrcncr: 1J-1.56L1. 100.0 ~~cII: 1J-15o Section I~SI Kcfcmncc Well (O OON.O-OOE,1S0.OOAzi) 15ell~iath: 1J-156L1 Sur~~c~ (~alculalion ~lctho~l: Minimum Curvature I1h: Oracle Sure c~ ~IU lucl \iim l ~ I) tip. T~"I) V "S 1~;'~~ ~la~iA 11a~iL lnul ft deg deg rt Yt ft ft ft ft 6967.71 93.40 180.53 3485.61 3376.61 -2805.20 -3018.40 5943076.67 555653.05 MWD+IFR-AK-CAZ-SC 7061.44 92.47 179.96 3480.81 3371.81 -2898.81 -3018.80 5942983.07 555653.38 MWD+IFR-AK-CAZ-SC 7155.38 90.55 179.95 3478.33 3369.33 -2992.71 -3018.72 5942889.18 555654.19 MWD+IFR-AK-CAZ-SC 7248.01 84.13 179.06 3482.63 3373.63 -3085.19 -3017.93 5942796.72 555655.70 MWD+IFR-AK-CAZ-SC 7340.92 82.39 178.58 3493.53 3384.53 -3177.43 -3016.03 5942704.50 555658.32 MWD+IFR-AK-CAZ-SC 7433.67 85.25 180.53 3503.52 3394.52 -3269.62 -3015.31 5942612.32 555659.75 MWD+IFR-AK-CAZ-SC 7528.59 89.87 179.93 3507.56 3398.56 -3364.43 -3015.69 5942517.53 555660.11 MWD+IFR-AK-CAZ-SC 7621.99 91.04 179.40 3506.82 3397.82 -3457.82 -3015.15 5942424.15 555661.38 MWD+IFR-AK-CAZ-SC 7715.88 90.49 178.26 3505.56 3396.56 -3551.68 -3013.23 5942330.32 555664.03 MWD+IFR-AK-CAZ-SC 7808.75 93.64 177.53 3502.22 3393.22 -3644.42 -3009.82 5942237.62 555668.16 .MWD+IFR-AK-CAZ-SC 7902.74 94.07 175.94 3495.90 3386.90 -3738.04 -3004.48 5942144.05 555674.23 MWD+IFR-AK-CAZ-SC 7995.48 91.85 178.21 3491.11 3382.11 -3830.53 -2999.76 5942051.62 555679.67 MWD+IFR-AK-CAZ-SC 8088.60 90.61 180.12 3489.11 3380.11 -3923.61 -2998.40 5941958.56 555681.75 MWD+IFR-AK-CAZ-SC 8181.68 92.84 179.33 3486.31 3377.31 -4016.64 -2997.96 5941865.54 555682.93 MWD+IFR-AK-CAZ-SC 8275.23 91.90 177.88 3482.44 3373.44 -4110.08 -2995.68 5941772.13 555685.93 MWD+IFR-AK-CAZ-SC 8368.79 92.16 180.50 3479.13 3370.13 -4203.56 -2994.36 5941678.67 555687.98 MWD+IFR-AK-CAZ-SC 8463.26 92.28 181.68 3475.47 3366.47 -4297.94 -2996.16 5941584.29 555686.92 MWD+IFR-AK-CAZ-SC 8556.63 93.89 179.27 3470.44 3361.44 -4391.16 -2996.93 5941491.07 555686.87 MWD+IFR-AK-CAZ-SC 8650.28 91.29 180.29 3466.21 3357.21 -4484.71 -2996.57 5941397.54 555687.96 MWD+IFR-AK-CAZ-SC 8742.94 89.82 180.07 3465.31 3356.31 -4577.36 -2996.86 5941304.90 555688.39 MWD+IFR-AK-CAZ-SC 8784.71 88.88 179.97 3465.78 3356.78 -4619.13 -2996.88 5941263.14 555688.70 MWD+IFR-AK-CAZ-SC 8835.61 84.87 179.70 3468.56 3359.56 -4669.94 -2996.73 5941212.33 555689.24 MWD+IFR-AK-CAZ-SC 8883.92 88.57 179.50 3471.32 3362.32 -4718.16 -2996.39 5941164.12 555689.95 MWD+IFR-AK-CAZ-SC 8930.80 90.92 180.30 3471.53 3362.53 -4765.04 -2996.31 5941117.25 555690.40 MWD+IFR-AK-CAZ-SC 8978.17 92.03 180.31 3470.31 3361.31 -4812.39 -2996.56 5941069.90 555690.52 MWD+IFR-AK-CAZ-SC 9023.28 92.65 179.85 3468.47 3359.47 -4857.46 -2996.63 5941024.83 555690.80 MWD+IFR-AK-CAZ-SC 9068.72 92.77 178.92 3466.32 3357.32 -4902.85 -2996.14 5940979.46 555691.64 MWD+IFR-AK-CAZ-SC 9115.52 93.28 178.72 3463.85 3354.85 -4949.57 -2995.18 5940932.75 555692.97 MWD+IFR-AK-CAZ-SC 9205.57 91.66 179.47 3459.97 3350.97 -5039.52 -2993.76 5940842.82 555695.09 MWD+IFR-AK-CAZ-SC 9296.68 92.77 179.00 3456.45 3347.45 -5130.56 -2992.54 5940751.81 555697.02 MWD+IFR-AK-CAZ-SC 9387.43 92.65 179.18 3452.16 3343.16 -5221.19 -2991.10 5940661.19 555699.16 MWD+IFR-AK-CAZ-SC 9476.57 93.34 177.66 3447.50 3338.50 -5310.17 -2988.65 5940572.24 555702.31 -MWD+IFR-AK-CAZ-SC 9567.78 91.97 179.59 3443.28 3334.28 -5401.25 -2986.46 5940481.19 555705.20 MWD+IFR-AK-CAZ-SC 9657.89 90.44 178.36 3441.38 3332.38 -5491.32 -2984.85 5940391.14 555707.52 MWD+IFR-AK-CAZ-SC 9747.26 89.63 178.38 3441.33 3332.33 -5580.66 -2982.31 5940301.84 555710.75 MWD+IFR-AK-CAZ-SC 9840.21 90.37 178.15 3441.33 3332.33 -5673.56 -2979.49 5940208.97 555714.29 MWD+IFR-AK-CAZ-SC 9929.76 92.35 178.21 3439.20 3330.20 -5763.04 -2976.65 5940119.53 555717.83 MWD+IFR-AK-CAZ-SC 10022.51 93.46 178.05 3434.50 3325.50 -5855.62 -2973.63 5940026.98 555721.57 MWD+IFR-AK-CAZ-SC 10112.38 90.87 178.46 3431.11 3322.11 -5945.38 -2970.89 5939937.26 555725.01 MWD+IFR-AK-CAZ-SC 10202.12 91.17 179.03 3429.51 3320.51 -6035.08 -2968.93 5939847.58 555727.67 MWD+IFR-AK-CAZ-SC 10293.67 89.82 181.16 3428.72 3319.72 -6126.62 -2969.08 5939756.05 555728.23 MWD+IFR-AK-CAZ-SC 10385.57 90.50 180.49 3428.46 3319.46 -6218.51 -2970.40 5939664.16 555727.62 MWD+IFR-AK-CAZ-SC 10476.05 91.05 178.48 3427.24 3318.24 -6308.97 -2969.59 5939573.72 555729.14 MWD+IFR-AK-CAZ-SC 10567.15 89.44 179.26 3426.85 3317.85 -6400.05 -2967.79 5939482.67 555731.65 MWD+IFR-AK-CAZ-SC 10655.39 88.63 180.03 3428.33 3319.33 -6488.27 -2967.25 5939394.46 555732.88 MWD+IFR-AK-CAZ-SC 10744.43 89.02 176.45 3430.16 3321.16 -6577.24 -2964.51 5939305,52 555736.31 MWD+IFR-AK-CAZ-SC 10834.92 89.57 179.97 3431.27 3322.27 -6667.66 -2961.69 5939215.13 555739.84 MWD+IFR-AK-CAZ-SC 10925.49 90.99 181.75 3430.83 3321.83 -6758.22 -2963.05 5939124.58 555739.18 MWD+IFR-AK-CAZ-SC 11017.70. 90.43 179.11 3429.69 3320.69 -6850.41 -2963.74 5939032.40 555739.21 MWD+IFR-AK-CAZ-SC 11109.25 92.91 179.26 3427.02 3318.02 -6941.90 -2962.44 5938940.92 555741.22 MWD+IFR-AK-CAZ-SC I i 11203.22 93.08 177.91 3422.11 3313.11 -7035.71 -2960.12 5938847.14 555744.27 MWD+IFR-AK-CAZ-SC 11295.11 93.21 180.61 3417.07 3308.07 -7127.45 -2958.94 5938755.43 555746.17 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~~mpan~: Co nocoPhillipsAlaska Inc. 1 iclil: Ku paruk Riv er Unit tiitc: Ku paruk 1J Pad ~1 c l l: 1 J- 15 b' ~1'clllruh: iJ- 156L1 Surcc~ X11) Intl ~cini l ~ I) ft deg deg ft 11389.58 93.40 178.69 3411.62 11484.48 91.73 178.83 3407.37 11578.15 90.81 180.74 3405.30 11669.94 90.75 179.81 3404.05 11764.53 89.26 179.98 3404.04 11856.29 90.30 180.00 3404.39 11951.19 91.36 180.36 3403.02 12044.99 90.19 181.68 3401.75 12137.67 87.84 181.02 3403.34 12233.18 87.47 182.22 3407.25 12325.40 88.64 181.94 3410.38 12418.91 89.50 177.72 3411.90 12512.50 90.06 177.01 3412.26 12606.49 90.99 178.80 3411.40 12699.63 91.61 177.10 3409.28 12792.08 90.18 175.10 3407.84 12886.61 90.12 174.13 3407.59 12920.97 89.81 174.08 3407.61 12963.00 89.81 174.08 3407.75 Ustc: 3l9/2006 Iiuic: 10:01 ~~0 Pa:;c: a Cu-ur~JinatclAF1 Rcfcrrncc: Weil: 1J-156, True North ~cr~iril i"Ill)) I~cfcrcucc: 1J-156L1: 109.0 ~cc~iuu 1~ ~1 llcFcn•ncc: Well i0 00N_O OOE i 80 OQAzi) tinr~c~' (~alculatiun ~IcUiuil: Minimum Curvature 1)h: Ofacle ft ft ft ft ft 3302.62 -7221 .75 -2958.36 5938661 .14 555747 .48 MWD+IFR-AK-CAZ-SC 3298.37 -7316 .53 -2956.31 5938566 .39 555750 .27 MWD+IFR-AK-CAZ-SC 3296.30 -7410 .17 -2955.96 5938472 .76 555751 .35 MWD+IFR-AK-CAZ-SC 3295.05 -7501 .95 -2956.40 5938380 .99 555751 .62 MWD+IFR-AK-CAZ-SC 3295.04 -7596 .54 -2956.22 5938286 .41 555752 .53 MWD+IFR-AK-CAZ-SC 3295.39 -7688 .30 -2956.21 5938194 .67 555753 .27 MWD+IFR-AK-CAZ-SC 3294.02 -7783 .19 -2956.51 5938099 .79 555753 .71 MWD+IFR-AK-CAZ-SC 3292.75 -7876 .96 -2958.18 5938006 .02 555752 .77 MWD+IFR-AK-CAZ-SC 3294.34 -7969 .59 -2960.36 5937913 .38 555751 .31 MWD+-FR-AK-CAZ-SC 3298.25 -8064 .98 -2963.06 5937817 .98 555749 .35 MWD+IFR-AK-CAZ-SC 3301.38 -8157 .09 -2966.40 5937725 .86 555746 .72 MWD+IFR-AK-CAZ-SC 3302.90 -8250. 56 -2966.12 5937632 .40 555747 .73 MWD+IFR-AK-CAZ-SC 3303.26 -8344. 05 -2961.82 5937538 .95 555752 .76 MWD+IFR-AK-CAZ-SC 3302.40 -8437. 97 -2958.39 5937445. 07 555756. 93 MWD+IFR-AK-CAZ-SC 3300.28 -8531. 02 -2955.06 5937352. 06 555760. 98 MWD+IFR-AK-CAZ-SC 3298.84 -8623. 24 -2948.77 5937259. 90 555767. 99 MWD+IFR-AK-CAZ-SC 3298.59 -8717. 35 -2939.90 5937165. 87 555777. 59 MWD+IFR-AK-CAZ-SC 3298.61 -8751. 53 -2936.37 5937131. 73 555781. 38 .MWD+IFR-AK-CAZ-SC 3298.75 -8793. 34 -2932.03 5937089. 96 555786. 04 PROJECTED to TD Halliburton Company Survey Report (~mupan~: ConocoPhillipsAlaska Inc. I)a~c: 3i9i2006 hinic: 09.36:25 Pa~~c: I Iirld: Kupflruk River Unit C is-ur~inatc~AI 1 Ilricrcncc: Well_ 1J-156. T rue North Rite: K~sparuk 1J Pad ~ 'crtical f Ills) K cfcrcn~c: 1J-156L1P51: 10>+.0 ~~cll: 1 J-1 56 S ection ~~~R~ ltcf cmucc: Well i0 00N 0 0 0E 100 00Azi) ~1'cllpath: IJ-156L1Pf?1 ti une~ ('alrulati un ~Ictlw~l: Minimum Curv ature I)b: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-156 Slot Name: Well Position: +N/-S -13.52 ft Northing: 5945 905.02 ft Latitude: 70 15 46.125 N +E/-W -140.85 ft Easting : 558649.22 ft Longitude: 149 31 33.105 W Position Un certainty: 0.00 ft Wellpath: 1 J-156L1 PB1 Drilled From: 1 J-156 500292331170 Tie-on Depth: 6002.04 ft Current Da tum: 1 J-156L1 PB1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic D ata: 6/28/2006 Declination: 24.04 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 8/9/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 50.00 539.00 1J-156 gyro (50.00-539.00) (0) CB-GYRO-SS Camera based gyro single shot 628.39 6002.04 1J-156 (628.39-8233.13) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6072.44 9206.00 1 J-156L1 PB1 (6072 .44-9206.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey X11) Intl \zim ~I ~~D tip',, ~I ~~D V;S I~.a~ ~IapA ~Tai~~t: lu~~l ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945905.02 558649.22 TIE LINE 50.00 0.12 309.10 50.00 -59.00 0.01 -0.02 5945905.03 558649.20 CB-GYRO-SS 100.00 0.33 302.21 100.00 -9.00 0.12 -0.18 5945905.14 558649.04 CB-GYRO-SS 170.00 0.16 227.52 170.00 61.00 0.17 -0.42 5945905.18 558648.80 CB-GYRO-SS 261.00 0.84 274.09 261.00 152.00 0.13 -1.18 5945905.14 558648.04 CB-GYRO-SS 357.00 3.64 283.48 356.91 247.91 0.89 -4.85 5945905.87 558644.37 CB-GYRO-SS 446.00 7.52 285.11 445.47 336.47 3.07 -13.22 5945907.98 558635.98 CB-GYRO-SS 539.00 9.29 284.65 537.47 428.47 6.55 -26.36 5945911.36 558622.81 CB-GYRO-SS 628.39 10.78 282.16 625.49 516.49 10.14 -41.51 5945914.83 558607.63 .MWD+IFR-AK-CAZ-SC 661.48 12.02 281.08 657.93 548.93 11.45 -47.92 5945916.10 558601.22 MWD+IFR-AK-CAZ-SC 697.90 13.22 279.83 693.47 584.47 12.89 -55.75 5945917.47 558593.38 MWD+IFR-AK-CAZ-SC 764.19 15.65 278.50 757.66 648.66 15.51 -72.06 5945919.96 558577.05 MWD+IFR-AK-CAZ-SC 856.58 15.78 279.44 846.60 737.60 19.41 -96.78 5945923.67 558552.30 .MWD+IFR-AK-CAZ-SC 948.01 18.55 280.46 933.95 824.95 24.09 -123.35 5945928.15 558525.70 MWD+IFR-AK-CAZ-SC 1040.41 22.41 279.81 1020.49 911.49 29.76 -155.17 5945933.57 558493.84 MWD+IFR-AK-CAZ-SC 1133.37 25.84 279.39 1105.32 996.32 36.09 -192.63 5945939.60 558456.34 MWD+IFR-AK-CAZ-SC 1225.55 28.82 279.19 1187.20 1078.20 42.91 -234.39 5945946.10 558414.53 MWD+IFR-AK-CAZ-SC 1320.60 32.24 280.08 1269.06 1160.06 51.01 -281.98 5945953.83 558366.88 MWD+IFR-AK-CAZ-SC 1413.40 34.96 281.94 1346.35 1237.35 60.85 -332.37 5945963.27 558316.41 MWD+IFR-AK-CAZ-SC 1506.74 35.50 281.10 1422.59 1313.59 71.60 -385.13 5945973.61 558263.58 MWD+IFR-AK-CAZ-SC 1598.95 36.98 280.44 1496.96 1387.96 81.78 -438.68 5945983.37 558209.95 MWD+IFR-AK-CAZ-SC 1692.74 39.87 279.40 1570.43 1461.43 91.80 -496.10 5945992.95 558152.47 MWD+IFR-AK-CAZ-SC 1782.84 46.17 278.46 1636.28 1527.28 101.31 -556.80 5946001.98 558091.71 MWD+IFR-AK-CAZ-SC 1875.42 48.72 278.17 1698.88 1589.88 111.17 -624.27 5946011.31 558024.16 MWD+IFR-AK-CAZ-SC 1967.60 52.01 275.99 1757.68 1648.68 119.88 -694.71 5946019.48 557953.67 MWD+IFR-AK-CAZ-SC 2060.57 58.03 272.32 1810.97 1701.97 125.31 -770.63 5946024.31 557877.71 MWD+IFR-AK-CAZ-SC 2154.73 58.56 270.78 1860.45 1751.45 127.47 -850.71 5946025.85 557797.63 MWD+IFR-AK-CAZ-SC 2242.55 60.83 269.43 1904.77 1795.77 127.60 -926.52 5946025.39 557721.83 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~inup:m~: ConocoPhillipsAlasha Inc. I):uc: 819!2006 l~imc: 09.36:25 I'a~~c: '_ I~lclil: K uparuF, River Unii Cu- urdinali~lAI~ ) Ri~frrcncc: V~Jell: 1J-156. T rue Nor[h tiitc: K uparuk 1J Pad ~cr tical(Ill)~ Ncfcrcncc: 1J-156L1PB1. 109.0 ~~ cll: 1 J-156 ~cc liun f~~~l Hcl crrncc: Well i0 00N.0- OOE.1 o0.OOAziI ~1i~ll~iatli: 1 J-15~L"IPE 1 ~ur cesl~alcul:~t iun~lcthud: Minimum Curv ature I)b: Oracle tiur<<~~ X11) lucl .Mini l ~I) ti~.lll) \ ti f_1~ ~lapA ~fn~il, lnul ft deg deg ft ft ft ft ft ft 2335.91 60.92 269.25 1950.21 1841.21 126.66 -1008.07 5946023.82 557640.29 MWD+IFR-AK-CAZ-SC 2429.73 60.92 270.59 1995.81 1886.81 126.55 -1090.06 5946023.06 557558.31 MWD+IFR-AK-CAZ-SC 2523.25 61.26 268.34 2041.02 1932.02 125.78 -1171.91 5946021.66 557476.48 MWD+IFR-AK-CAZ-SC 2616.59 57.90 268.87 2088.28 1979.28 123.82 -1252.37 5946019.07 .557396.05 MWD+IFR-AK-CAZ-SC 2709.57 58.96 268.53 2136.96 2027.96 122.02 -1331.56 5946016.65 557316.87 .MWD+IFR-AK-CAZ-SC 2729.48 59.49 268.15 2147.14 2038.14 121.52 -1348.66 5946016.02 557299.78 MWD+IFR-AK-CAZ-SC 2826.57 60.03 267.98 2196.04 2087.04 118.69 -1432.49 5946012.54 557215.98 MWD+IFR-AK-CAZ-SC 2920.36 58.92 266.59 2243.68 2134.68 114.87 -1513.19 5946008.09 557135.33 MWD+IFR-AK-CAZ-SC 3012.90 58.01 264.09 2292.08 2183.08 108.47 -1591.79 5946001.08 557056.78 MWD+IFR-AK-CAZ-SC 3108.25 57.70 263.40 2342.82 2233.82 99.67 -1672.04 5945991.66 556976.61 MWD+IFR-AK-CAZ-SC 3202.47 .59.79 259.98 2391.71 2282.71 88.01 -1751.72 5945979.38 556897.04 MWD+IFR-AK-CAZ-SC 3295.75 61.28 254.21 2437.62 2328.62 69.85 -1830.82 5945960.61 556818.08 .MWD+IFR-AK-CAZ-SC 3389.35 61.96 248.08 2482.14 2373.14 43.25 -1908.70 5945933.39 556740.43 MWD+IFR-AK-CAZ-SC 3482.06 60.16 242.90 2527.03 2418.03 9.63 -1982.49 5945899.21 556666.90 MWD+IFR-AK-CAZ-SC 3575.84 59.32 237.52 2574.31 2465.31 -30.57 -2052.76 5945858.46 556596.96 MWD+IFR-AK-CAZ-SC 3669.53 59.15 236.82 2622.23 2513.23 -74.22 -2120.40 5945814.30 556529.66 MWD+IFR-AK-CAZ-SC 3762.54 59.35 236.61 2669.79 2560.79 -118.08 -2187.22 5945769.91 556463.19 MWD+IFR-AK-CAZ-SC 3856.53 59.81 237.44 2717.38 2608.38 -162.20 -2255.22 5945725.28 556395.55 MWD+IFR-AK-CAZ-SC 3949.79 62.02 236.39 2762.71 2653.71 -206.69 -2323.49 5945680.26 556327.63 MWD+IFR-AK-CAZ-SC 4041.96 62.70 235.18 2805.47 2696.47 -252.60 -2391.01 5945633.83 556260.48 MWD+IFR-AK-CAZ-SC 4135.29 62.94 233.80 2848.11 2739.11 -300.83 -2458.59 5945585.08 556193.28 MWD+IFR-AK-CAZ-SC 4228.84 63.84 233.61 2890.01 2781.01 -350.34 -2526.00 5945535.05 556126.27 MWD+IFR-AK-CAZ-SC 4324.27 63.22 228.72 2932.57 2823.57 -403.87 -2592.52 5945481.00 556060.17 MWD+IFR-AK-CAZ-SC 4415.66 61.95 227.40 2974.64 2865.64 -458.09 -2652.87 5945426.33 556000.25 MWD+IFR-AK-CAZ-SC 4511.02 62.68 223.46 3018.96 2909.96 -517.34 -2713.00 5945366.62 .555940.59 MWD+IFR-AK-CAZ-SC 4604.16 61.72 221.00 3062.41 2953.41 -578.33 -2768.38 5945305.20 555885.70 MWD+IFR-AK-CAZ-SC 4695.44 62.82 217.23 3104.89 2995.89 -641.01 -2819.32 5945242.13 555835.25 MWD+IFR-AK-CAZ-SC 4789.29 65.39 211.95 3145.90 3036.90 -710.50 -2867.19 5945172.28 555787.93 MWD+IFR-AK-CAZ-SC 4882.76 66.00 206.67 3184.39 3075.39 -784.75 -2908.86 5945097.71 555746.84 MWD+IFR-AK-CAZ-SC 4977.56 66.41 201.68 3222.66 3113.66 -863.85 -2944.37 5945018.34 555711.95 MWD+IFR-AK-CAZ-SC 5071.42 68.37 .197.34 3258.76 3149.76 -945.50 -2973:27 5944936.48 555683.69 MWD+IFR-AK-CAZ-SC 5163.66 71.51 194.39 3290.40 3181.40 -1028.83 -2996.93 5944852.98 555660.68 MWD+IFR-AK-CAZ-SC 5257.97 72.05 190.73 3319.90 3210.90 -1116.25 -3016.40 5944765.42 555641.89 MWD+IFR-AK-CAZ-SC 5351.05 75.87 186.20 3345.62 3236.62 -1204.69 -3029.53 5944676.88 555629.46 MWD+IFR-AK-CAZ-SC 5444.97 76.47 180.99 3368.09 3259.09 -1295.68 -3035.24 5944585.87 555624.45 MWD+IFR-AK-CAZ-SC 5538.34 77.43 178.91 3389.17 3280.17 -1386.63 -3035.16 5944494.93 555625.25 MWD+IFR-AK-CAZ-SC 5631.47 78.39 178.69 3408.68 3299.68 -1477.67 -3033.25 5944403.91 555627.86 MWD+IFR-AK-CAZ-SC 5722.81 78.34 178.91 3427.10 3318.10 -1567.12 -3031.38 5944314.49 555630.43 MWD+IFR-AK-CAZ-SC 5815.21 78.12 177.99 3445.95 3336.95 -1657.54 -3028.93 5944224.10 555633.58 .MWD+IFR-AK-CAZ-SC 5909.06 80.59 179.04 3463.28 3354.28 -1749.73 -3026.54 5944131.93 555636.69 MWD+IFR-AK-CAZ-SC 6002.04 80.60 179.31 3478.48 3369.48 -1841.46 -3025.22 5944040.24 555638.72 MWD+IFR-AK-CAZ-SC 6072.44 80.56 179.15 3490.00 3381.00 -1910.90 -3024.29 5943970.81 555640.20 MWD+IFR-AK-CAZ-SC 6125.63 85.92 181.04 3496.26 3387.26 -1963.70 -3024.38 5943918.02 555640.51 MWD+IFR-AK-CAZ-SC 6160.68 89.90 182.77 3497.54 3388.54 -1998.70 -3025.55 5943883.01 555639.62 MWD+IFR-AK-CAZ-SC 6220.29 90.49 179.29 3497.34 3388.34 -2058.29 -3026.62 5943823.42 555639.01 MWD+IFR-AK-CAZ-SC 6313.19 89.69 180.08 3497.19 3388.19 -2151.18 -3026.11 5943730.54 555640.25 MWD+IFR-AK-CAZ-SC 6404.65 88.27 178.22 3498.82 3389.82 -2242.61 -3024.75 5943639.13 555642.32 MWD+IFR-AK-CAZ-SC 6499.60 89.88 179.11 3500.35 3391.35 -2337.52 -3022.54 5943544.25 555645.27 MWD+IFR-AK-CAZ-SC 6592.52 90.31 178.56 3500.20 3391.20 -2430.42 -3020.65 5943451.38 555647.88 MWD+IFR-AK-CAZ-SC 6685.63 92.29 177.37 3498.08 3389.08 -2523.44 -3017.35 5943358.40 555651.91 MWD+IFR-AK-CAZ-SC 6780.22 92.10 181.23 3494.46 3385.46 -2617.94 -3016.19 5943263.92 555653.80 MWD+IFR-AK-CAZ-SC 6873.75 92.66 180.47 3490.58 3381.58 -2711.38 -3017.58 5943170.48 555653.14 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (mupauc: ConocoPh!IlipsAlaska Inc_ 11atc : 8.92006 liuir. 09.3625 Pac: 3 Iirlil: Kuparuk Rive r Unit (~~~-u nlin;ilclAI.) 12cli~rcnce; Well. .J-156. T rue North ~itr: Kuparuk 1J P ad Pcrt ic~l f Ill)) K cfcrcucc: iJ-156L1P61 109.0 1~ ~~I1: 1J-156 ~ccti uu I~SI Itcfc rcucr. Well (O GON,O OOE.I o0 00Azi) '.lrllpadt: 1J-156L1FE1 tiun ~c~ (~alcul:uiu n A1cUunl: Minimum Curv ature 11h: Oracle tiurccc ~II> Incl liim 1 ~ U ti~~ "Ill) \ ti I=~~ ~lapA \Ia~iF; fnul ft deg deg ft ft Yt ft ft ft 6967.71 93.40 180.53 3485.61 3376.61 -2805.20 -3018.40 5943076.67 555653.05 MWD+IFR-AK-CAZ-SC 7061.44 92.47 179.96 3480.81 3371.81 -2898.81 -3018.80 5942983.07 555653.38 MWD+IFR-AK-CAZ-SC 7155.38 90.55 179.95 3478.33 3369.33 -2992.71 -3018.72 5942889.18 555654.19 MWD+IFR-AK-CAZ-SC 7248.01 84.13 179.06 3482.63 3373.63 -3085.19. -3017.93 . 5942796.72 555655.70 MWD+IFR-AK-CAZ-SC 7340.92 82.39 178.58 3493.53 3384.53 -3177.43 -3016.03 5942704.50 555658.32 MWD+IFR-AK-CAZ-SC 7433.67 85.25 180.53 3503.52 3394.52 -3269.62 -3015.31 5942612.32 555659.75 MWD+IFR-AK-CAZ-SC 7528.59 89.87 179.93 3507.56 3398.56 -3364.43 -3015.69 5942517.53 555660.11. MWD+IFR-AK-CAZ-SC 7621.99 91.04 179.40 3506.82 3397.82 -3457.82 -3015.15 5942424.15 555661.38 MWD+IFR-AK-CAZ-SC 7715.88 90.49 178.26 3505.56 3396.56 -3551.68 -3013.23 5942330.32 555664.03 MWD+IFR-AK-CAZ-SC 7808.75 93.64 177.53 3502.22 3393.22 -3644.42 -3009.82 5942237.62 555668.16 MWD+IFR-AK-CAZ-SC .7902.74 94.07 175.94 3495.90 3386.90 -3738.04 -3004.48 5942144.05 555674.23 MWD+IFR-AK-CAZ-SC 7995.48 91.85 178.21 3491.11 3382.11 -3830.53 -2999.76 5942051.62 555679.67 MWD+IFR-AK-CAZ-SC 8088.60 90.61 180.12 3489,11 3380.11 -3923.61 -2998.40 5941958.56 555681.75 MWD+IFR-AK-CAZ-SC 8181.68 92.84 179.33 3486.31 3377.31 -4016.64 -2997.96 5941865.54 555682.93 MWD+IFR-AK-CAZ-SC 8275.23 91.90 177.,88 3482.44 3373.44 -4110.08 -2995.68 5941772.13 555685.93 MWD+IFR-AFC-CAZ-SC 8368.79 92.16 180.50 3479.13 3370.13. -4203.56 -2994.36 5941678.67 555687.98 MWD+IFR-AK-CAZ-SC 8463.26 92.28 181.68 3475.47 3366.47 -4297.94 -2996.16 5941584.29 555686.92 MWD+IFR-AK-CAZ-SC 8556.63 93.89 179.27 3470.44 3361.44 -4391.16 -2996.93 5941491.07 555686.87 .MWD+IFR-AK-CAZ-SC 8650.28 91.29 180.29 3466.21 3357.21 -4484.71 -2996.57 5941397.54 555687.96 MWD+IFR-AK-CAZ-SC 8742.94 89.82 180.07 3465.31 3356.31 -4577.36 -2996.86 5941304.90 555688.39 MWD+IFR-AK-CAZ-SC 8835.38 94,33 179.44 3461.96 3352.96 -4669.71 -2996.47 5941212.56 555689.50 .MWD+IFR-AK-CAZ-SC 8929.69 95.19 178.23 3454.14 3345.14 -4763.68 -2994.56 5941118.62 555692.14 MWD+IFR-AK-CAZ-SC 9023.05 92.72 177.29 3447.70 3338.70 -4856.73 -2990.92 5941025.61 555696.51 MWD+IFR-AK-CAZ-SC 9114.97 93.77 178.17 3442.50 3333.50 -4948.43 -2987.28 5940933.95 555700.86 MWD+IFR-AK-CAZ-SC 9206.00 95.07 178.94 3435.48 3326.48 -5039.16 -2984.99 5940843.25 555703.85 MWD+IFR-AK-CAZ-SC 9248.00 95.07 178.94 3431.77 3322.77 -5080.99 -2984.22 5940801.43 555704.95 PROJECTED to TD • • WELL LOG TRANSMITTAL To: State of Alaska August 11, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-156, L1, L1 PB1 & L2, AK-MW-4467716 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23311-00, 60, 70, 61. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: ~~1 V ~~ AUG 2 2 2006 q Oil ~ ~,~ lions. Commission Anchorage 20~ -a~~-, ~o~. - o~~~ aa~ -o~~ ~iy03~ Re: 1J-156L1 B Lateral Geological Sidetrack PB1 Subject: Re: 1.1-1>6L1 B Lateral Geolo~~ical SidetrackPBl From: Thoi7las Maunder ~-toi7~~rlaunder@adzr~in.state.ak.us> Date: Mon. 17 ,ful ~~)~)~~ 09:>~:3; -0500 To: "Reill~~, Pah-ick.l" ~=Patrick.J.Rcilly(ciconocophillips.conl Thanks Pat. I will put a copy of this message in the file. ~j' Tom ~-~`~(o ~ ~ ~° O Reilly, Patrick J wrote, On 7/13/2006 1:58 PM: Tom, The details of the sidetrack are as follows: • Well: 1 J-156 • Rig: Doyon 141 • Date: 7/13/06 • Time: 1345 hrs • Last Casing: B Window 6,072' • MD of abandoned section: 8,825' - 9,248' We exited the top of the formation due to geologic uncertainty. We are preparing to make a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. If you need any additional information please contact me. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly,~conocophillips.cam «Patrick.J. ReillyCa~conocophillips.com.vcf» 1 of 1 7/17/2006 9:58 AM • r ~ ,~ 1 ~ ~ ~ °i .; ~ ~ ' ~ ~ ~ ', { I ALA.SS~ OIL A1QD G~5 COlYSER~ATIOI~T COMI~'II55IO1Q :~" Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 • FRANK N. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907j 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-156L1 ConocoPhillips Alaska, Inc. Permit No: 206-068 Surface Location: 2094' FSL, 2560' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 3860' FSL, 252' FEL, SEC. 10, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. 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. The permit is for a new wellbore segment of existing well KRU 1J-156, Permit No 206-067, API 50-029-23311-00. Injection should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness an required test, contact the Commission's petroleum field inspector at (9079-3607 (pager). rman DATED this ~ ay of June, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~. STATE OF ALASKA ~S ALASKA OIL AND GAS CONSERVATION COMMISSION (3~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ~ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180. 11. Well Name and Number: 1J-156L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12994' TVD: 3368' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2094' FSL, 2560' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25660 & 25663 West Sak Oit Pool ° Top of Productive Horizon: 337' FSL, 317' FEL, Sec. 34, T11 N, R10E, UM 8. Land Use Permit: ALK 470 & 472 13. Approximate Spud Date: 7/20/2006 Total Depth: 3860' FSL, 252' FEL, Sec. 10, T10N, R10E, UM 9. Acres in Properly: 2560 14. Distance to Nearest Property: <1 mile to KRU 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558649 y- 5945905 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 J-152L1 , 1189' @ 12E 16. Deviated wells: Kickoff depth: 5952' ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1532 psig Surface: 1157 psig ° 16. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2768' 28' 28' 2791' 2168' 510 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 6835' 28' 28' 6863' 3628' 400 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 7042' 5952' 3476' 12994' 3368' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ff): 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): Perforation Depth TVD (ft): 20. Attachments: Filing Fee _ BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` Phone ZbS-6~TLa Date S'l(z/O(~ d h All Drak Commission Use Only Permit to Drill?7 ~~ Number: .G..vtt:"j " ~~ API Number: 2 50- ~Zg - ~3 J~ ~ ' (p~ Permit Approval Date: • a ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas by s, or gas contained in shales: ~~~ ~` ~~-:a.~2 ~~~ ~~ .~5~ Samples req'd: Yes ^ No ~ M d log req'd: Yes ^ No L~ Other: c `. H2S measures: Yes i al svy req'd: Yes ~ No ^ ~~v a•~ex'~'~e C~~..c-C~~~ c~ ~~ c3ccGt~ w ~ l~~t)~-~~j. APPROVED BY THE COMMISSION DATE: (Q `~r ~O ,COMMISSIONER Form 10-401 Revised 12/2005 Sub it in Duplicat ~ ~ 61~ s•ic•o ~~ t 1 Ap~n for Permit to Drill, Well 1J-156 L1 Revision No.O Saved: 12-May-06 Permit It -West Sak Well #1J-156 L1 "„~ r.w i't Application for Permit to Drill Document :~; ~IaW~ll Mdxinlix~ Well VOlue 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 not done 1J-156L1 PERMIT IT Page 1 of 6 Printed: 12-May-06 ,.~ t t ~ ~ ~ i''~ • Ap~n for Permit to Drill, Well 1 J-156 L1 Revision No.O Saved: 12-May-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-156 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle 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 governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,094' FSL 2,560' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,905 Eastings: 558,649 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 337' FSL, 317' FEL, Section 34, T11N, R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 5 952 Northings: 5,944,125 Eastings: 555,627 Total Vertical De th, RKB: 3,476 Total Vertical De th, SS: 3,367 Location at Total De th 3,860' FSL, 252' FEL, Section 10, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12,994 Northings: 5,937,090 Eastings: 555,755 Total Vertical De th, RKB: 3,368 Total Vertical De th, SS: 3,259 and (D) other information required by 20 AAC 25.050(6); not done 1J-156L1 PERMIT IT Page 2 of 6 Printed: 12-May-06 ORIGINAL • Ap~n for Permit to Drill, Well 1J-156 L1 Revision No.O Saved: 12-May-06 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form i 0-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan iJ-156L1 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-156 L1. 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 commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak °B" sand formation is 1,157 psi, calculated thusly: MPSP = (3,404 ft TVD)(0.45 - 0.11 psi/ft) = 1,157 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-156 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1J-156, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. not done 1J-156L1 PERMIT IT Page 3 of 6 Printed: 12-May-06 ~~~ ~~>~ Ap~n for Permit to Drill, Well 1 J-156 L1 Revision No.O Saved: 12-May-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MDlND OD in (in) t Ib/ft Grade Connection ft ft (ft) Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,791 28 / 28 2,791 /2,168 510 sx ASLite Lead, 180 sx DeepCRETE Tail drift Cement Top planned 7-5/8 9-7/8 29.7 L-80 BTCM 6,863 28 / 28 6,863 / 3,628 3,650' MD / 2,592' TVD. Cemented w/ 400 sx DeepCRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 2,265 6,052 / 3,500 8,317 / 3,637 Slotted- no cement Lateral (1J-156) 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 7,042 5,952 / 3,476 12,994 / 3,368 Slotted- no cement Slotted Lateral (i]-156 Ll) _ - and 11.6 L-80 BTC 6,971 5,625 2,596 / 3, - slotted Lateral (1J-156 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on 1J-156 Ll. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density ( ) 8.8 Plastic Viscostiy 15 - 25 (lb/100 sfJ Yield Point 18 - 28 (cP) HTHP Fluid loss <4 0 (ml/30 min 200 si . not done 1J-156L1 PERMIT IT Page 4 of 6 Printed: 12-May-O6 ~~~~~~ • Ap~n for Permit to Drill, Well 1 J-156 L1 Revision No.O Saved: 12-May-06 & 150° Oil /Water Ratio 70 / 30 Electrical Stability 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i0) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (1 i) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-156 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,952' MD / 3,476' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at +/- 12,994' MD / 3,368' 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. not done 1J-156L1 PERMIT IT Page 5 of 6 Printed: 12-May-06 ~~~~~y • 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. Ap~n for Permit to Drill, Well 1 J-156 L1 Revision No.0 Saved: 12-May-06 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the "D" sand lateral 1J-156 L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic not done 1J-156L1 PERMIT /T Page 6 of 6 Printed: 12-May-O6 a • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-156 -Slot 1J-156 1J-156 L1 Plan: 1J-156 L1 (wp05) Proposal Report 14 April, 2006 IAA ~.~ '~"` I~_ Sperry Dirilling Services ORIGINAL N M N r NN~t~V 4, a - E Mo~i~V Q 2r°r-a F- w oO~~~ o ~oma~ z °°'~~ M N ~ ~ Q U D O O N O O O O O OOD 1040 °° '° v M N M M Z r N M ~ .~ ~ T ~ ma~J 3 ~ ~ ~ N YY~'7J ~ ~ Ce-~ 10 f6 ~ ~ Q ~ YYa ~~ ~j r 4) Y ~! ~ mN ~ m o a is N O O ~ O ~ , N N _ ____ J =, ~ ~ i ,' ~ ~ ~ i ~ i ~ , ~ ~ N ~ ~ pr G , N ~ N J N r O M ~ N p ^ Z` u ~ O ~ ~ \ _ ~ ~ ~ ~ ~ O O ' ~ ._ ' e ~(~ O ~ 0 Q ` z ~ 0 V -_ _ 3 `~'~-_ ~ ~• ~ ~f a0 ~ r 2` 10 r r ` ` ` ` J 12° N ~ O a 3 f _ _ _ _ J b 10 r a 1~ 'O r~ ` ~ o G ~ a ~ ~~ ~° r ~ N ~ ~ ~ N ~ O N ~ C7 M ~\ v ~ e ~ O C \~ ~ U ~ j ~ ~~ m \\ C •~ ~ d ~ m ~ d L \\ A ~ r ~ ~ ~j ~ M ~ ~ ~ ~ W ~ >O6 O J ~ > N O ~ F ; ~ \\ ~. 9 ~~ ~ ~ ~yy C `` \. NI ~ `~ ° ~' ~Ofi ~ E ~~ f z ~~~ 00 ~=69 ~ _--- ~ J _ _ _ _ - _ _ _ _ O 9 C r ' 0( O a 0 r J n `~9 0 0 0 °o 1i / O N M a N~ V ~ ~ O O 00 ~ (uilli _ _ _ _ _ - O 3 N =, ` ` ` ` ` \ ~ ` ` ` J ` ~ r N a ~~, 3 H r n ~ O F ~ a J tO0 3 ~r 10 H O O O V O Q1 N 0 .~ 0 n O ~~ O N _ c0 O 0 0 N O o -. o = 0 O O O N O (9 o~ _00 O ~ V U_ O ~ N ~N ~ M 0 M N O N O r O O 0 N 0 O O O O N to R 6. : Y 10 3l4" N A - ° O N -1000 ?00^ L1 : Top of 7 5l6" Window - 5952ft MD, 3476ft TVD : 337ft FSL & 317ft FEL -Sec 34 - T11 N - R1 E -1500 179, - ' ' - L1 : Bttm of Window - 5964ft MD, 3478ft - - - - - - L1 : End 30' Rathole -Begin Build ~ 5°/1008 to 92°, 5994ft MD, 3482ft D -2000 - - - _ _ 79° ------------------ 1J-166 L1 T1 (wp05 _ _ - L1 : Continue Geosteer in B-Sand, 6196ft MD, 3493ft 1J-156 L1 T2 (wp05 _ 1J•156 L1 T3 (wp05 - 1J-156 L1 T4 (wp05 - - - - - - - - _ _ 1J-156 L1 DD Poly (wp05) o - i9°~ _ DD Polygon Describes a corridor 100' wide ~' ~ , , with a 50'+/-allowance FJW from the V 1J-t s6 a rs (typos - _ _ _ _ _ _ _ _ _ ~ , proposed wellbore. r ~ ~, o Z -, t 79° ~ ~, t0 1J-156(wp05)8317ft M 1J-156 L1 T6 (wp06 79° 1J-156 L1 T7 (wp05 HALLIBURTON Sperry DHlling Services ~~ ConocoPhillips Alaska Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-156 Wellbore: 1J-156 L1 Plan: 1J-156 L1 (wp05) 79° 1J-156 L1 T8 (wp05 79° 1J-166 L7 T9 (wp05 CASING DETAILS No TVD MD Name Size 1 80.00 80.00 20" 20 2 2168.00 2791.96 10 3/4" 10-3/4 3 3476.02 5952.45 7 5/8" 7-5/8 4 3368.00 12994.66 4 1 /2" 4-1 /2 - ' ' ~ 1J-156 L2 (wpOS) ~ 12596ft MW 1J-156 L1 T10 Toe (wp05 L1 : BHL ~ 12995ft MD, 3368ft TVD - 4 112' r nn 'Azimuths to True North Magnetic North: 24.04° Magnetic Field Strength: 57564.2nT Dip Angle: 80.77° Date: 6/30/2006 Model: BGGM2005 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 , ~ Halliburton Energy Services ~ HAl1,.~1~URT© C01'1f3CC3Pht~~t~?5 Planning Report -Geographic - ----~- RISSk9 Sperry Drilling 5ervfees Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 - Slot iJ-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk'River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True - Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 L1 Design: 1 J-156 L1 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 J-156 -Slot 1 J-156 Well Position +N/-S 0.00 ft Northing: 5,945,905.10 ft Latitude: 70° 15' 46.125" N +E/-W 0.00 ft Easting: 558,649.10 ft Longitude: 149° 31' 33.109" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-156 L1 ,Magnetics Model Name Sample Date Declination Dip Angle Fieid Strength BGGM2005 2/2/2006 24.1919 80.7682 57,563 besign 1J-156 L1 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,952.44 Vertical Section: Depth From (TYD) +N/-S +E/-W Direction In) (ft) lft) (°) 28.00 0.00 0.00 180.00 4/14/2006 10:50:30AM Page 2 of 8 COMPASS 2003.11 Build 50 ,~ ~ 1 ~ ~Y:e~3 ~~j ~ ~ ' , Halliburton Energy Service s HAt.ttBUR"tptV 1ClCa ~Cyt ~fll~~l~?5 Planning Report -Geographic ---------~----- ~~- Alaska Sperry t3riiltifng Servifces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-156 -Slot 1 J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 L1 Design: 1J-156 L1 (wp05) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°1100ft) (°i100ft) (°) 5,952.44 80.00 179.30 3,476.02 -1,756.53 -3,035.78 0.00 0.00 0.00 0.0000 5,964.44 81.91 179.30 3,477.91 -1,768.38 -3,035.64 15.90 15.90 0.00 0.0000 5,994.44 81.91 179.30 3,482.13 -1,798.07 -3,035.28 0.00 0.00 0.00 0.0000 6,174.60 90.92 179.30 3,493.40 -1,977.69 -3,033.08 5.00 5.00 0.00 0.0000 6,198.33 92.10 179.30 3,492.77 -2,001.40 -3,032.79 5.00 5.00 0.01 0.0584 6,611.03 92.10 179.30 3,477.63 -2,413.79 -3,027.76 0.00 0.00 0.00 0.0000 6,635.08 90.90 179.30 3,477.00 -2,437.83 -3,027.47 5.00 -5.00 -0.01 -179.9423 6,704.89 89.51 179.16 3,476.75 -2,507.64 -3,026.53 2.00 -1.99 -0.20 -174.3530 7,085.25 89.51 179.16 3,480.00 -2,887.94 -3,020.97 0.00 0.00 0.00 0.0000 7,225.30 82.51 179.34 3,489.74 -3,027.56 -3,019.15 5.00 -5.00 0.13 178.5720 7,321.97 82.51 179.34 3,502.34 -3,123.39 -3,018.04 0.00 0.00 0.00 0.0000 7,512.17 92.02 179.30 3,511.41 -3,313.15 -3,015.78 5.00 5.00 -0.02 -0.2310 7,637.17 92.02 179.30 3,507.00 -3,438.06 -3,014.26 0.00 0.00 0.00 0.0000 7,651.09 92.30 179.30 3,506.48 -3,451.97 -3,014.09 2.00 2.00 -0.01 -0.3686 8,136.72 92.30 179.30 3,487.00 -3,937.17 -3,008.14 0.00 0.00 0.00 0.0000 8,178.98 91.45 179.30 3,485.62 -3,979.40 -3,007.63 2.00 -2.00 0.01 179.8358 8,637.04 91.45 179.30 3,474.00 -4,437.28 -3,002.04 0.00 0.00 0.00 0.0000 8,658.58 91.03 179.24 3,473.53 -4,458.82 -3,001.77 2.00 -1.98 -0.27 -172.2649 9,637.52 91.03 179.24 3,456.00 -5,437.51 -2,988.83 0.00 0.00 0.00 0.0000 9,696.81 92.21 179.30 3,454.33 -5,496.77 -2,988.07 2.00 2.00 0.10 2.8821 10,638.54 92.21 179.30 3,418,00 -6,437.73 -2,976.62 0.00 0.00 0.00 0.0000 10,669.53 91.59 179.24 3,416,97 -6,468.70 -2,976.22 2.00 -1.99 -0.19 -174.4491 11,639.25 91.59 179.24 3,390.00 -7,437.96 -2,963.40 0.00 0.00 0.00 0.0000 11,673.55 90.91 179.31 3,389.25 -7,472.25 -2,962.97 2.00 -1.99 0.19 174.4404 12,192.49 90.91 179.31 3,381.00 -7,991.08 -2,956.71 0.00 0.00 0.00 0.0000 12,251.53 90.93 180.49 3,380.05 -8,050.12 -2,956.61 2.00 0.03 2.00 89.1039 12,994.67 90.93 180.49 3,368.00 -8,793.13 -2,962.96 0.00 0.00 0.00 0.0000 4/14/2006 10:50:30AM Page 3 of 8 COMPASS 2003.11 Build 50 ~~~ ~ ~~~ . ~'" ~ ~ ~ Halliburton Energy Services ~ t~[p-1ri~(BUi~~roN CC7-C10C4~h1~1p5 Planning Report -Geographic ---~--~-m---- Alaska. 5parry Dr111iing 5e~ees Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-156 Survey Calculation Method: Weilbore: 1J-156 L1 Design: 1J-156 L1 (wp05) Well Plan 1J-156 -Slot 1J-156 Planning RKB @ 109.OOft (Goyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Planned Survey 1J-156 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Fasting DLSEV Vert Section (ft) (°) (°) (ftl (ft) (ft) {ft) (ft) (ft) (°/100ft) (ft1 5,952.44 80.00 179.30 3,476.02 3,367.02 -1,756.53 -3,035.78 5,944,125.15 555,627.38 0.00 1,756.53 L1 : Top of 7 5/8" Window - 5952ft MD, 3476ft TVD : 337ft FSL & 317ft FEL -Sec 34 - T11 N - R10E - 7 5/8" 5,964.44 81.91 179.30 3,477.91 3,368.91 -1,768.38 -3,035.64 5,944,113.31 555,627.62 15.90 1,768.38 L1 : Bftm of Window - 5964ft MD, 3478ft TVD 5,994.44 81.91 179.30 3,482.13 3,373.13 -1,798.07 -3,035.28 5,944,083.61 555,628.21 0.00 1,798.07 L1 : End 30' Rathole -Begin Build @ 5°/100ft to 92°, 5994ft MD, 3482ft TVD 5,999.98 82.18 179.30 3,482.90 3,373.90 -1,803.56 -3,035.21 5,944,078.13 555,628.32 5.00 1,803.56 6,099.98 87.18 179.30 3,492.16 3,383.16 -1,903.09 -3,033.99 5,943,978.62 555,630.31 5.00 1,903.09 6,174.60 90.92 179.30 3,493.40 3,384.40 -1,977.69 -3,033.08 5,943,904.04 555,631.80 5.00 1,977.69 6,198.33 92.10 179.30 3,492.77 3,383.77 -2,001.40 -3,032.79 5,943,880.33 555,632.28 5.00 2,001.40 L1 : Continue Geostee r in B-Sand , 6198ft MD, 3493ft TVD 6,199.98 92.10 179.30 3,492.71 3,383.71 -2,003.05 -3,032.77 5,943,878.69 555,632.31 0.00 2,003.05 6,299.97 92.10 179.30 3,489.04 3,380.04 -2,102.97 -3,031.55 5,943,778.78 555,634.31 0.00 2,102.97 6,399.97 92.10 179.30 3,485.37 3,376.37 -2,202.90 -3,030.34 5,943,678.88 555,636.30 0.00 2,202.90 6,499.97 92.10 179.30 3,481.70 3,372.70 -2,302.82 -3,029.12 5,943,578.98 555,638.30 0.00 2,302.82 6,599.97 92.10 179.30 3,478.04 3,369.04 -2,402.75 -3,027.90 5,943,479.08 555,640.30 0.00 2,402.75 6,611.03 92.10 179.30 3,477.63 3,368.63 -2,413.79 -3,027.76 5,943,468.03 555,640.52 0.00 2,413.79 6,635.08 90.90 179.30 3,477.00 3,368.00 -2,437.83 -3,027.47 5,943,444.00 555,641.00 5.00 2,437.83 1J-156 L1 T1 (wp05) 6,704.89 89.51 179.16 3,476.75 3,367.75 -2,507.64 -3,026.53 5,943,374.21 555,642.48 2.00 2,507.64 6,799.97 89.51 179.16 3,477.56 3,368.56 -2,602.70 -3,025.14 5,943,279.16 555,644.61 0.00 2,602.70 6,899.97 89.51 179.16 3,478.42 3,369.42 -2,702.69 -3,023.68 5,943,179.20 555,646.85 0.00 2,702.69 6,999.97 89.51 179.16 3,479.27 3,370.27 -2,802.67 -3,022.22 5,943,079.24 555,649.09 0.00 2,802.67 7,085.25 89.51 179.16 3,480.00 3,371.00 -2,887.94 -3,020.97 5,942,994.00 555,651.00 0.00 2,887.94 1J-156 L7 T2 (wp05) 7,099.97 88.77 179.18 3,480.22 3,371.22 -2,902.66 -3,020.76 5,942,979.28 555,651.33 5.00 2,902.66 7,199.97 83.78 179.31 3,486.71 3,377.71 -3,002.41 -3,019.44 5,942,879.56 555,653.42 5.00 3,002.41 7,225.30 82.51 179.34 3,489.74 3,380.74 -3,027.56 -3,019.15 5,942,854.41 555,653.91 5.00 3,027.56 7,299.97 82.51 179.34 3,499.47 3,390.47 -3,101.58 -3,018.29 5,942,780.40 555,655.35 0.00 3,101.58 7,321.97 82.51 179.34 3,502.34 3,393.34 -3,123.39 -3,018.04 5,942,758.60 555,655.77 0.00 3,123.39 7,399.97 86.41 179.32 3,509.87 3,400.87 -3,201.01 -3,017.13 5,942,681.00 555,657.28 5.00. 3,201.01 7,499.97 91.41 179.30 3,511.77 3,402.77 -3,300.95 -3,015.93 5,942,581.08 555,659.26 5.00 3,300.95 7,512.17 92.02 179.30 3,511.41 3,402.41 -3,313.15 -3,015.78 5,942,568.89 555,659.50 5.00 3,313.15 7,599.97 92.02 179.30 3,508.31 3,399.31 -3,400.88 -3,014.71 5,942,481.17 555,661.26 0.00 3,400.88 7,637.17 92.02 179.30 3,507.00 3,398.00 -3,438.06 -3,014.26 5,942,444.00 555,662.00 0.00 3,438.06 1J-156 L1 T3 (wp05) 7,651.09 92.30 179.30 3,506.48 3,397.48 -3,451.97 -3,014.09 5,942,430.09 555,662.28 2.00 3,451.97 7,699.97 92.30 179.30 3,504.52 3,395.52 -3,500.80 -3,013.49 5,942,381.27 555,663.26 0.00 3,500.80 7,799.97 92.30 179.30 3,500.51 3,391.51 -3,600.71 -3,012.27 5,942,281.38 555,665.26 0.00 3,600.71 7,899.97 92.30 179.30 3,496.49 3,387.49 -3,700.62 -3,011.04 5,942,181.49 555,667.26 0.00 3,700.62 7,999.97 92.30 179.30 3,492.48 3,383.48 -3,800.54 -3,009.82 5,942,081.60 555,669.26 0.00 3,800.54 8,099.97 92.30 179.30 3,488.47 3,379.47 -3,900.45 -3,008.59 5,941,981.71 555,671.26 0.00 3,900.45 8,136.72 92.30 179.30 3,487.00 3,378.00 -3,937.17 -3,008.14 5,941,945.00 555,672.00 0.00 3,937.17 1J-156 L1 T4 {wp05) 8,178.98 91.45 179.30 3,485.62 3,376.62 -3,979.40 -3,007.63 5,941,902.78 555,672.85 2.00 3,979.40 8,199.97 91.45 179.30 3,485.08 3,376.08 -4,000.38 -3,007.37 5,941,881.80 555,673.26 0.00 4,000.38 4/14/2006 10:50:30AM Page 4 of 8 COMPASS 2003.11 Build 50 ~ ' Halliburton Energy Service s HALLI~uATa COCIC3CQ 11~A[S ~~ Planning Report -Geographic ~__ Sperry Drilling Serves Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1J-156 L1 Design: 1J-156 L1 (wp05) Planned Survey 1J-156 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft- (ft) (ft) (ft) (ft) (°/100ft) (ftl 8,299.97 91.45 179.30 3,482.55 3,373.55 -4,100.34 -3,006.15 5,941,781.86 555,675.26 0.00 4,100.34 8,399.97 91.45 179.30 3,480.01 3,371.01 -4,200.30 -3,004.93 5,941,681.93 555,677.26 0.00 4,200.30 8,499.97 91.45 179.30 3,477.48 3,368.48 -4,300.26 -3,003.71 5,941,581.99 555,679.26 0.00 4,300.26 8,599.97 91.45 179.30 3,474.94 3,365.94 -4,400.22 -3,002.49 5,941,482.05 555,681.26 0.00 4,400.22 8,637.04 91.45 179.30 3,474.00 3,365.00 -4,437.28 -3,002.04 5,941,445.00 555,682.00 0.00 4,437.28 1J-156 L1 T5 (wp05) 8,658.58 91.03 179.24 3,473.53 3,364.53 -4,458.82 -3,001.77 5,941,423.47 555,682.44 2.00 4,458.82 8,699.97 91.03 179.24 3,472.79 3,363.79 -4,500.19 -3,001.22 5,941,382.11 555,683.31 0.00 4,500.19 8,799.96 91.03 179.24 3,471.00 3,362.00 -4,600.16 -2,999.90 5,941,282.15 555,685.41 0.00 4,600.16 8,899.96 91.03 179.24 3,469.21 3,360.21 -4,700.14 -2,998.58 5,941,182.20 555,687.51 0.00 4,700.14 8,999.96 91.03 179.24 3,467.42 3,358.42 -4,800.11 -2,997.25 5,941,082.25 555,689.61 0.00 4,800.11 9,099.96 91.03 179.24 3,465.63 3,356.63 -4,900.09 -2,995.93 5,940,982.30 555,691.71 0.00 4,900.09 9,199.96 91.03 179.24 3,463.84 3,354.84 -5,000.06 -2,994.61 5,940,882.35 555,693.81 0.00 5,000.06 9,299.96 91.03 179.24 3,462.05 3,353.05 -5,100.04 -2,993.29 5,940,782.39 555,695.91 0.00 5,100.04 9,399.96 91.03 179.24 3,460.25 3,351.25 -5,200.01 -2,991.97 5,940,682.44 555,698.01 0.00 5,200.01 9,499.96 91.03 179.24 3,458.46 3,349.46 -5,299.99 -2,990.65 5,940,582.49. 555,700.11 0.00 5,299.99 9,599.96 91.03 179.24 3,456.67 3,347.67 -5,399.96 -2,989.32 5,940,482.54 555,702.21 0.00 5,399.96 9,637.52 91.03 179.24 3,456.00 3,347.00 -5,437.51 -2,988.83 5,940,445.00 555,703.00 0.00 5,437.51 1J-156 L1 T6 (wp05) 9,696.81 92.21 179.30 3,454.33 3,345.33 -5,496.77 -2,988.07 5,940,385.75 555,704.21 2.00 5,496.77 9,699.96 92.21 179.30 3,454.20 3,345.20 -5,499.92 -2,988.04 5,940,382.60 555,704.28 0.00 5,499.92 9,799.96 92.21 179.30 3,450.35 3,341.35 -5,599.84 -2,986.82 5,940,282.71 555,706.27 0.00 5,599.84 9,899.96 92.21 179.30 3,446.49 3,337.49 -5,699.76 -2,985.60 5,940,182.81 555,708.27 0.00 5,699.76 9,999.96 92.21 179.30 3,442.63 3,333.63 -5,799.67 -2,984.39 5,940,082.92 555,710.26 0.00 5,799.67 10,099.96 92.21 179.30 3,438.77 3,329.77 -5,899.59 -2,983.17 5,939,983.02 555,712.26 0.00 5,899.59 10,199.96 92.21 179.30 3,434.92 3,325.92 -5,999.51 -2,981.95 5,939,883.13 555,714.25 0.00 5,999.51 10,299.96 92.21 179.30 3,431.06 3,322.06 -6,099.43 -2,980.74 5,939,783.23 555,716.25 0.00 6,099.43 10,399.96 92.21 179.30 3,427.20 3,318.20 -6,199.34 -2,979.52 5,939,683.33 555,718.24 0.00 6,199.34 10,499.96 92.21 179.30 3,423.35 3,314.35 -6,299.26 -2,978.30 5,939,583.44 555,720.24 0.00 6,299.26 10,599.96 92.21 179.30 3,419.49 3,310.49 -6,399.18 -2,977.09 5,939,483.54 555,722.23 0.00 6,399.18 10,638.54 92.21 179:30 3,418.00 3,309.00 -6,437.73 -2,976.62 5,939,445.00 555,723.00 0.00 6,437.73 1J-156 L1 T7 (wp05) 10,669.53 91.59 179.24 3,416.97 3,307.97 -6,468.70 -2,976.22 5,939,414.04 555,723.63 2.00 6,468.70 10,699.96 91.59 179.24 3,416.13 3,307.13 -6,499.11 -2,975.82 5,939,383.63 555,724.27 0.00 6,499.11 10,799.96 91.59 179.24 3,413.34 3,304.34 -6,599.07 -2,974.50 5,939,283.70 555,726.37 0.00 6,599.07 10,899.96 91.59 179.24 3,410.56 3,301.56 -6,699.02 -2,973.18 5,939,183.77 555,728.47 0.00 6,699.02 10,999.96 91.59 179.24 3,407.78 3,298.78 -6,798.97 -2,971.86 5,939,083.84 555,730.57 0.00 6,798.97 11,099.96 91.59 179.24 3,405.00 3,296.00 -6,898.92 -2,970.53 5,938,983.91 555,732.67 0.00 6,898.92 11,199.96 91.59 179.24 3,402.22 3,293.22 -6,998.87 -2,969.21 5,938,883.99 555,734.77 0.00 6,998.87 11,299.95 91.59 179.24 3,399.44 3,290.44 -7,098.83 -2,967.89 5,938,784.06 555,736.87 0.00 7,098.83 11,399.95 91.59 179.24 3,396.66 3,287.66 -7,198.78 -2,966.57 5,938,684.13 555,738.97 0.00 7,198.78 11,499.95 91.59 179.24 3,393.87 3,284.87 -7,298.73 -2,965.25 5,938,584.20 555,741.07 0.00 7,298.73 11,599.95 91.59 179.24 3,391.09 3,282.09 -7,398.68 -2,963.92 5,938,484.27 555,743.17 0.00 7,398.68 11,639.25 91.59 179.24 3,390.00 3,281.00 -7,437.96 -2,963.40 5,938,445.00 555,744.00 0.00 7,437.96 1J-156 L1 T8 (wp05) 11,673.55 90.91 179.31 3,389.25 3,280.25 -7,472.25 -2,962.97 5,938,410.71 555,744.70 2.00 7,472.25 11,699.95 90.91 179.31 3,388.83 3,279.83 -7,498.65 -2,962.65 5,938,384.33 555,745.22 0.00 7,498.65 11,799.95 90.91 179.31 3,387.24 3,278.24 -7,598.63 -2,961.45 5,938,284.37 555,747.21 0.00 7,598.63 4/14/2006 10;50:30AM Page 5 of 8 COMPASS 2003.11 Build 50 OR!G!NAL ~ ' ' Halliburton Energy Service s H,AL1LEt3t.3q-~-~~ ~Ot 1C?CC1 ~ ll~~t5 Planning Report -Geographic Sperry drilling Serwr~ces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1J-156 L1 Design: 1J-156 L1 (wp05) Planned Survey 1J-156 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/S +E/-W Northing Easting DLSEV Vert Section (ftl 1°) (°) (ft- (ft) lft- (ft) lft- (ftl 1°/100ft1 (ft) 11,899.95 90.91 179.31 3,385.65 3,276.65 -7,698.61 -2,960.24 5,938,184.41 555,749.19 0.00 7,698.61 11,999.95 90.91 179.31 3,384.06 3,275.06 -7,798.59 -2,959.03 5,938,084.45 555,751.18 0.00 7,798.59 12,099.95 90.91 179.31 3,382.47 3,273.47 -7,898.57 -2,957.83 5,937,984.50 555,753.16 0.00 7,898.57 12,192.49 90.91 179.31 3,381.00 3,272.00 -7,991.08 -2,956.71 5,937,892.00 555,755.00 0.00 7,991.08 1J-156 L1 T9 ( wp05) 12,199.95 90.91 179.46 3,380.88 3,271.88 -7,998.55 -2,956.63 5,937,884.54 555,755.14 2.00 7,998.55 12,251.53 90.93 180.49 3,380.05 3,271.05 -8,050.12 -2,956.61 5,937,832.97 555,755.56 2.00 8,050.12 12,299.95 90.93 180.49 3,379.27 3,270.27 -8,098.53 -2,957.02 5,937,784.56 555,755.53 0.00 8,098.53 12,399.95 90.93 180.49 3,377.64 3,268.64 -8,198.51 -2,957.88 5,937,684.59 555,755.45 0.00 8,198.51 12,499.95 90.93 180.49 3,376.02 3,267.02 -8,298.50 -2,958.73 5,937,584.61 555,755.38 0.00 8,298.50 12,599.95 90.93 180.49 3,374.40 3,265.40 -8,398.48 -2,959.59 5,937,484.63 555,755.30 0.00 8,398.48 12,699.95 90.93 180.49 3,372.78 3,263.78 -8,498.46 -2,960.44 5,937,384.66 555,755.22 0.00 8,498.46 12,799.95 90.93 180.49 3,371.16 3,262.16 -8,598.44 -2,961.29 5,937,284.68 555,755.15 0.00 8,598.44 12,899.95 90.93 180.49 3,369.54 3,260.54 -8,698.43 -2,962.15 5,937,184.70 555,755.07 0.00 8,698.43 12,994.67 90.93 180.49 3,368.00 3,259.00 -8,793.13 -2,962.96 5,937,090.00 555,755.00 0.00 8,793.13 L7 : BHL @ 12995ft MD, 3368ft TVD : 3860ft FSL & 252ft FE L -Sec 10 - T10N - R10E - 41/2" -1J-156 L1 T10 Toe (wp05) 4/14/200610:50:30AM Page 6 of 8 COMPASS 2003.11 Build 50 C?IGINAL ~'' ~ Halliburton Energy Services COt"IOCO~Ph1~~tp5 Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1 J-156 Wellbore: 1J-156 L1 Design: 1 J-156 L1 (wp05) HA4l.1 B V RTC Sperry Drilling Sarvi'css Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Geologic Targets 1 J-156 L1 TVD Target Name +N/-S +E!-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,368.00 1J-156 L1 T10 Toe (wp05) -8,793.13 -2,962.96 5,937,090.00 555,755.00 - Point 3,418.00 1J-156 L1 T7 (wp05) -6,437.73 -2,976.62 5,939,445.00 555,723.00 - Point 3,507.00 1J-156 L1 T3 (wp05) -3,438.06 -3,014.26 5,942,444.00 555,662.00 - Point 3,480.00 1J-156 L1 T2 (wp05) -2,887.94 -3,020.97 5,942,994.00 555,651.00 - Point 3,474.00 1J-156 L1 T5 (wp05) -4,437.28 -3,002.04 5,941,445.00 555,682.00 - Point 3,487.00 1J-156 L1 T4 (wp05) -3,937.17 -3,008.14 5,941,945.00 555,672.00 - Point 3,381.00 1J-156 L1 T9 (wp05) -7,991.08 -2,956.71 5,937,892.00 555,755.00 - Point 3,476.02 1J-156 L1 DD Poly (wp05) -1,756.58 -3,035.78 5,944,125.10 555,627.38 - Polygon Point 1 -50.00 0.44 5,944,125.15 555,577.38 Point 2 -49.86 -11.40 5,944,113.31 555,577.62 Point 3 -49.50 -41.11 5,944,083.61 555,578.21 Point 4 -47.31 -220.72 5,943,904.04 555,581.80 Point 5 -47.01 -244.44 5,943,880.33 555,582.28 Point 6 -41.98 -656.82 5,943,468.03 555,590.52 Point 7 -41.69 -680.86 5,943,444.00 555,591.00 Point 8 -40.75 -750.67 5,943,374.21 555,592.48 Point 9 -35.19 -1,130.97 5,942,994.00 555,601.00 Point 10 -33.36 -1,270.59 5,942,854.41 555,603.92 Point 11 -32.26 -1,366.42 5,942,758.60 555,605.77 Point 12 -30.00 -1,556.17 5,942,568.89 555,609.50 Point 13 -28.48 -1,681.09 5,942,444.00 555,612.00 Point 14 -28.30 -1,695.00 5,942,430.09 555,612.28 Point 15 -22.36 -2,180.20 5,941,945.00 555,622.00 Point 16 -21.84 -2,222.43 5,941,902.78 555,622.85 Point 17 -16.26 -2,680.31 5,941,445.00 555,632.00 Point 18 -15.99 -2,701.85 5,941,423.47 555,632.44 Point 19 -3.05 -3,680.54 5,940,445.00 555,653.00 Point 20 -2.30 -3,739.80 5,940,385.75 555,654.21 Point 21 9.17 -4,680.76 5,939,445.00 555,673.00 Point 22 9.55 -4,711.73 5,939,414.04 555,673.63 Point 23 22.38 -5,680.99 5,938,445.00 555,694.00 Point 24 22.81 -5,715.28 5,938,410.72 555,694.70 Point 25 29.07 -6,234.11 5,937,892.00 555,705.00 Point 26 22.82 -7,036.17 5,937,090.00 555,705.00 Point 27 122.83 -7,036.95 5,937,090.00 555,805.00 Point 28 129.08 -6,234.89 5,937,892.00 555,805.00 Point 29 122.82 -5,716.06 5,938,410.72 555,794.70 Point 30 122.38 -5,681.77 5,938,445.00 555,794.00 Point 31 109.56 -4,712.51 5,939,414.04 555,773.63 Point 32 109.17 -4,681.54 5,939,445.00 555,773.00 Point 33 97.71 -3,740.58 5,940,385.75 555,754.21 Point 34 96.96 -3,681.32 5,940,445.00 555,753.00 Point 35 84.02 -2,702.63 5,941,423.47 555,732.44 Point 36 83.75 -2,681.09 5,941,445.00 555,732.00 Point 37 78.16 -2.223.21 5.941,902.78 ____555.722.8$_ 4/14/2006 10;50:30AM Page 7 of 8 COMPASS 2003.11 Build 50 ~-' ~ Halliburton Energy Services ~ MAIE.IrtE3UR7'f~!!1 C€)t10COPh~~~t~?s Planning Report -Geographic ---~ Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk iJ Pad Well: Plan 1 J-156 Wellbore: 1J-156 L1 Design: i J-156 L1 (wp05) Sperry DriilrrtS Services Local Co-ordinate Reference: Well Plan 1J-156 - Slot iJ-156 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Point 38 Point 39 Point 40 Point 41 Point 42 Point 43 Point 44 Point 45 Point 46 Point 47 Point 48 Point 49 Point 50 Point 51 Point 52 3,390.00 - Point 3,477.00 - Point 3,456.00 - Point 77.64 -2,180.98 5,941,945.00 555,722.00 71.70 -1,695.78 5,942,430.09 555,712.28 71.53 -1,681.87 5,942,444.00 555,712.00 70.00 -1,556.95 5,942,568.89 555,709.50 67.75 -1,367.20 5,942,758.60 555,705.77 66.65 -1,271.37 5,942,854.41 555,703.92 64.81 -1,131.75 5,942,994.00 555,701.00 59.25 -751.45 5,943,374.21 555,692.48 58.32 -681.64 5,943,444.00 555,691.00 58.03 -657.60 5,943,468.03 555,690.52 53.00 -245.22 5,943,880.33 555,682.28 52.70 -221.50 5,943,904.04 555,681.80 50.51 -41.89 5,944,083.61 555,678.21 50.15 -12.18 5,944,113.31 555,677.62 50.00 -0.34 5,944,125.15 555,677.38 1J-156 L1 T8 (wp05) -7,437.96 -2,963.40 5,938,445.00 555,744.00 1J-156 L1 T1 (wp05) -2,437.83 -3,027.47 5,943,444.00 555,641.00 1J-156 L1 T6 (wp05) -5,437.51 -2,988.83 5,940,445.00 555,703.00 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (~~) (~~) 80.00 80.00 20 26 2,791.96 2,168.00 10-3/4 13-112 5,952.45 3,476.02 7-518 9-7l8 12,994.66 3,368.00 4-1/2 6-314 4/14/2006 10:50:30AM Page 8 of 8 COMPASS 2003.11 Build 50 ~~~~~~ • r ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-156 1J-156 L1 1 J-156 L1 (wp05) Anticollision Report 14 April, 2006 A~~~ Spelrr~ ©ritling ~elrvices ~~~~~.~~ O ~. O a O N i ^ m _ C f H F H F H !- H F r o " ~ v, ~ Z O x ~ J J J J J J J J J J c Euaia mm p Y N 3 ~ ~ t m Y 3" 'Eye°~ p ~ '^ eE '~ ~E:°.WO o ~ d do a°a,nm~°o ~°ar a rnh v rdo ri v~ >w r; ~: ro~ ~m a m~« yNLt~ rrr or c c3 °~v A~ ~ ~~~~oe°.r°.n,~.omMMhM°ry'$~~°n .°n°m °u i°.~rm-mm = o gip,. y' v dooo oaon vomo c ow`~~c c ~$ n°e vri°or r °oa°o °oe~°~°;oo c ~ mW~ eeoo omi ~v`'o^ogogo « o~a'omo O u m ~ y O T 0 0 0° 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 V U ~ o oc^ovi vicvi ~ioviovico:ooiocic ro~:oo:d rie CN m W ~~mnonnr nvmmm<marnrwwor.~~ O vvim~onwo~uonmomw<mrmm N` O N O I,f) O ~ O ~ Z WrminnnMr Nrvrv~~~~~o ooommnneenne o ty N N ~ N N C) O ^~ O 000000000 ooommmmmmmmm ~ ~ F M VVn m mM~nawwmwww~ W ~NM Ob<nm,00~N Mem-O r dnm Nnr Am rym" } N ~m ri m n~mnm ti~ Q '~ °eaa Mv~mmw~aveaa<mo F, ~ ~ ~ ~ ~ .g3 s °ea~a~~o~8~~<oao~a~oMOmo~aoS zm ~dMma J r N M 6 q m M M n h n n n~ r N n n N N n 'l d d r C~ a M o u C°emm ,°~yeoFnvmi m"mmm N 92 t") N ~ mmmmmmmmmmmmmmmmmmmmmmm mmmm Q m ~~ ~ Og~~m moumi v~imvdi virnavi e W Jd > ~ riddnm ~ V O V ~ ~ ~,,, mnmmmmmnrnrr~W'm~wmom+~~~~~~' 3 ~ r um ~~~~~~~~°~$nnwn««« a~wmammnmm 9 a C rno p p o~~ O ~ V` ,~ d t") N c C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 n w~ o 0 0 0 0 ~n o ~n 0 0 0 0 0 0 0 0 0 0 0 0 < m N ~ ~ o ~n o N ~n n o 0 0 0 0 0 0 0 0 ~ m Za m C O O O O O O O O O O O O O O O O O O O O C ~ O~ O~ O~ O O O O O O O O O O O m N ~n r o d ~n x 0 0 0 0 0 0 0 0 0 0 0 O ~ '- N m v ~n co n m rn o ~ N 3e ~ m ,~ ~ N ~ _ r _. ___.._. r V ~1' ` Z ~ + o ~~ __--__.. i ~, l ' 1 N F ~ _ _ __~ -~ ~/ i_` ~- C ~ ~ ~ / /, 1 CC m"' mm rme Z N J M / / ~ ~ / /~~/ i'~ ~ L W ~ Off' / / \// ! i/// ~ .-. - ~ ~ ~ omd ~ ~~ % ~% j~y~~ - ~... 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N O _. 2~~n~ E883 °-' m ~ d U G. r'g$v o ~"i ~ N o ~ N ~ e~ b ~ A U ~ • Halliburton Energy Services COt1000Pf 11~~Ip5 Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1 J-156 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Welfbore 1J-156 L1 Database: Reference Design: 1J-156 L1 (wp05) OffsetTVD Reference: • HALLIBURTON Sp®rry Drilling Services Welt Plan 1J-156 -Slot 1J-156 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-156 L1 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval SO.OOft Error Model: ISCWSA Depth Range: 5,952.44 to 12,994.67ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,496.67ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 4/13/2D06 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-156 (wp05) (1J-156) CB-GYRO-MS Camera based gyro multishot 800.00 5,952.44 1J-156 (wp05) (1J-156) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,952.44 12,994.67 1J-156 L1 (wp05) (1J-156 L1) 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 4/14/2006 11:12:38AM Page 2 of 4 COMPASS 2003.11 Build 50 ~, Halliburton Energy Services COI'lOCO1-I Ill~lps Anticollision Report Alaska Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1 J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1J-156 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-156 L1 Database: Reference Design: 1J-156 L1 (wp05) Offset ND Reference: HALLIBtJRTON Sperry Driiling Services Well Plan 1 J-156 -Slot 1 J-156 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+g1)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre bistance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 J Pad 1J-154 - 1J-154 - 1J-154 Out of range 1J-154 - 1J-154 L1 - 1J-154 L1 Out of range 1 J-154 - 1 J-154 L2 - 1 J-154 L2 Out of range 1 J-159 - 1 J-159 - 1 J-159 Out of range 1J-159 - 1J-159 L1 - 1J-159 L1 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 1 J-102 - 1 J-102 - 1 J-102 (wp06) Out of range Plan 1 J-102 - 1 J-102 L1 - 1J-102 L1 (wp06) Out of range Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp06) Out of range Plan 1J-103 -Plan 1J-103 - 1J-103 (wp02) Out of range Plan 1J-105 -Plan 1J-105 - 1J-105 (wp02) Out of range Plan 1J-107 -Plan 1J-107 - 1J-107 (wp02) Out of range Plan 1 J-109 -Plan 1 J-109 - 1 J-109 (wp05) Out of range Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Out of range Plan 1J-152- 1J-152- 1J-152 8,569.93 10,053.00 1,255.41 172.38 1,083.43 Pass- Major Risk Plan 1J-152 - 1J-152 L1 - 1J-152 L1 11,329.38 12,800.00 1,192.75 257.63 935.58 Pass -Major Risk Plan 1J-152 - 1J-152 L2 - 1J-152 L2 5,962.93 7,434.83 1,250.47 120.04 1,133.05 Pass -Major Risk Plan 1J-152- 1J-152 P61 - 1J-152 PB1 6,164.77 7,646.00 1,286.41 122.72 1,167.15 Pass- Major Risk Plan 1J-152 - 1 J-152 PB2 - 1J-152 PB2 7,809.80 9,296.00 1,249.47 155.11 1,095.02 Pass -Major Risk Plan 1J-156 - 1J-156 - 1J-156 (wp05) 5,999.95 5,999.98 1.40 4.72 -1.91 FAIL - No Errors Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp05) 12,603.85 12,596.01 78.02 104.24 33.16 Pass - No Errors Plan 1J-158 - 1J-158 - 1J-158 (wp03) Out of range Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI Out of range Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) Out of range Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Out of range Plan 1 J-162 - 1 J-162 L2 - 1 J-162 L2 (wp3.1) Out of range Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E Lat 5,958.87 6,350.00 833.51 115.31 733.99 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk- 1J-73 W Lat 5,958.87 6,350.00 833.51 115.31 733.99 Pass -Major Risk Plan 1J-173 Kuparuk - 1 J-73 Pilot - 1J-173 Pilot (wp 5,958.87 6,350.00 833.51 115.31 733.99 Pass -Major Risk Plan 1J-176 (02 Phase 2) -Plan 1J-176 - 1J-176 (wp 8,886.22 6,550.00 1,327.04 182.68 1,191.76 Pass -Major Risk Plan 1 J-178 (03 Phase 2) -Plan 1 J-178 - 1 J-178 (wp 10,624.61 8,000.00 873.43 239.49 688.59 Pass -Major Risk Plan 1J-180 (Q4 Phase 2) -Plan 1J-180 - 1J-180 (wp 12,959.11 9,950.00 129.37 20.28 128.90 Pass -Minor 1/200 Plan 1J-182 - 1J-182 - 1J-182 (wp05) 12,958.76 9,850.00 1,285.35 311.27 974.76 Pass -Major Risk Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 12,967.82 9,850.00 1,285.84 303.14 983.46 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2006 11:12:38AM Page 3 of 4 COMPASS 2003.11 Buifd 50 C4,61fJ1L 1J-156L~Drilling Hazards~ummarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming ~ ~ ~ ~ +, 1J-156L1 Drilling Hazards Summary ;..,d~ ~ F i prepared by Mike Greener 5/4/2006 12:13 PM o Insulated Conductor Casing 20", 94#, K55 x 34", 0.312" WT @ S +/_ g0' MD D co !~ ~_ '7 ;n S y ? ~ nrn- c ~ ..~. '-' to c o ~ ~ S ~`` - ~ y G I ~ ~~`) ~ z 1 s- 2 10-3/4", 68#, L-80, BTC, R3 ~ @ 2,792' MD / 2, l68' TVD ~~ 41.6 decrees 'CD 13-3/8" hole Top of liguu C (a~ 4,100' MD / 2,811' TVD ~ Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer @ x,xxx' MD, x,xxx' T VD Wellhead /Tubing Head /Tree, IO-3/4" x 4-'/:", 5,000 ksi "Cubing Stri ng. 4-l/Y', 12.G #, L-80, I6TM (I) 3.875" DB nipple set +/_ 500' Top of West Sak B (a~ 5,999' MD / 3,484' TVD ~~ Lateral Entry Module #I (LEM), Baker, with seal bore and ZXP packer @ x,xxx' MD, x,xxx' TVD Top of West Sak A ~i~ 6,2W' bID / 3,519' TVD - -~ Tubing, 4-'/" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for A2 liner _ @ 6,042' MD, 3,630' TVD 7-5/8", 40#, L-80, BTCM, R3 Csg @ 6,863' MD / 3 G28' TVD @ 86 degrees TD 9-5/8" hole (1) Gas LiR Mandrel, CMICO 4-I/2" x l" Model KBG-2, @ 25 deg, 1,200' MD, 1,169' TVD. (I) Gas LiR Mandrel, CAMCO 4-I/2" x 1" Model KBG-2, (r) 70 deg., (+/- I joint above sliding sleeve) - (1) Sliding Sleeve, with 3.812" nipple, @ 72 deg., (+/- I joint above seals) 156 L2 "U" Sand Window @ 5,625' MD / 3,404' TVD 73 degrees "D" Liner, 4-I/2", 116#, L80, BTCM, R2 156 L I "B" Sand Window @ 5,952' MD / 3,476' TVD 80 degrees - -- ~-- ~ "B" Liner, 4-1/2", I 1 6#, L80, BTCM, R2 Liner, I1-156 L2: 6-3/4" D sand lateral TD 12,596' MD / 3,303' TVD Angle 90 degrees l7-IS(i L1: - "B" sand I TD 12,994' nID 8 TVD Angle 90 grew 6-3/4 A2 sand lateral TD 8,317 MD / 3,637 TVD Angle 90 degrees i ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~ieu / a / S~ L. PTD# ZDc,~ UCc Development / Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new well bore segment of existing / ~ well ~~~ ~ ~~~ , v (If last two digits in permit No. Z,I.Yo ' G~'7, API No. 50-~- Z33 /~ - ~ . API number are c ~~,i,~, between 60-69) should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Com~any Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (,Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl ist • • a^ : : m ° , a v. ~: : : 3' Q : , c; ~, : , c O ~ o ~ o y c ~ ~ ~ ~° , O cn ~ ~ ~ o. ~ ~ ~ ~ ~ ~ c. ~ w ~ N. ~ ~ o ' ~ a. ~ : ~ v y O ~ . 0 m r t' t° v' , o, a~, ~, m: : m, E ~ O p o. a y. N, >, a~ __: coy d 4 v, v m c: c ~ _: m N. 0: m: a 03' ~ ~ .f0., ~ ~ ~ ~ O, ~ ~ ~ ~ Q: ~ ~~ ~ ~ , a ~ m, ~, _ O t U, ~ ~, ~ ~ m: a ~ N• 3. m: ~, ~ ~~ a' O' ~ m. a' ~ ~ L' , , ~ c a ~ ~, .~, ~ ~ a ~ 3. ~ ~ y, ~ a ~ ~ c, i; a , m ~ v`. ~ ~ °' rn O' a ~ p ~ ~, o, O: ~: w 4 ~ ~, a~, y ~: `r ~~ O~ ~ y: O~ ~ ~ , ~ ~ ~: d U: ~O, ~ ~ 0~ •a y, w~ ~ ~ ~ L~ uj~ _, ~ U Y ~ ~ 3 a~ c a O' o' ~' a, Z: 3, o ~ ~ O co: m . ~: , pOj: ~~ O. 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C, m 3; ° m m• m• o ° V, a~' Y = ,_ ~ , _ ~ ~ ° , , m• v ~ . ~ m. - c ~ . C. y m , O, m ~ . c N Z , "- ~ . : . . ~ m: o' d p: N i6 $ ~, c>, °, ~ o N: o a, , ~: v ~ ~ _ •3. rn ~ -q ~, ~ ~ uS a ~, '3; y •~, , ° Q , g; ~: •g J O U E' . , ~ m 6 ` , ~, ~ c a ~ 3, , H; H m c. H; '~ m `~ ° ? ~ d a; o, 'c ~ a ~ m N m. c _ Y . ~ m. m, ~, ~ ~ . a > c ° ~ 4 ' ' ~ 4 a~, a~, m ~ ~ - U, ` t o, °: ~, ~', ~, m, a a i. ~ v ~ ~' , O O ~, c i o ~ m. ~ . a~ a~ o m O U c a, J, , ~; ~, ~; O, , ~ ~, ~ O, a, a, U ~, Q; a; a, U, m, U. U. U, U, a; w - a; w - m, m, U, ~, ~' ~, a, O m; ~, V, W ma _ ~ o ~ N M~ O f0 I~ W O ~ ~ ~ ~ ~~ ~~ N N N N N N N N N N M M M M M M M M M M U U C r N w N ~ +~'' N U C Q. 00 CO (O o O y y Q O ~_ lf7 ~ ` m Q O _M ~ Q (O i0 `- O y /jj''/~] O y N E ~ J N •C a i rn C~ I O ` p c G. g ° o. Q U ~ a a a~ w a ~ ~ a~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, information- of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 09 10:29:23 2006 Reel Header Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA • Scientific Technical Services Scientific Technical Services 1J-156 L1 500292331160 ConocoPhillips Alaska, Inc. Sperry Drilling Services 09-AUG-06 MWD RUN 2 MWD RUN 3 JOB NUMBER: W- 0004467716 W-0004467716 LOGGING ENGINEER: P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN MWD RUN 6 MWD RUN 7 JOB NUMBER: W- 0004467716 W-0004467716 LOGGING ENGINEER:. T. GALVIN T. GALVIN OPERATOR WITNESS: M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2094 FEL: 2560 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING ~D(o -D!o ~ ~ f ~! D~15~ MWD RUN 5 W-0004467716 T. GALVIN D. GLADDEN DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 2769.0 7.625 6072.0 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 IS AN OPENHOLE SIDETRACK EXITING THE 1J-156 L1 PB1 WELLBORE AT 8785'MD/3466'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,6,7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 6,7 ALSO INCLUDED AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5-7 REPRESENT WELL 1J-156 L1 WITH API#: 50-029-23311-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12963'MD/3408'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2735.0 12902.0 RPM 2750.0 12909.0 RPX 2750.0 12909.0 FET 2750.0 12909.0 RPD 2750.0 12909.0 RPS 2750.0 12909.0 ROP 2780.5 12963.0 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 2735.0 2869.0 3 2815.0 6072.0 5 6072.5 6111.0 6 6072.5 8785.0 7 8785.5 12963.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2735 12963 7849 20457 2735 12963 RPD MWD OHMM 1.54 2000 38.2059 20319 2750 12909 RPM MWD OHMM 1.66 2000 31.9267 20319 2750 12909 RPS MWD OHMM 1.9 1742.62 31.4194 20319 2750 12909 RPX MWD OHMM 0.91 1345.1 30.3344 20319 2750 12909 FET MWD HOUR 0.19 153.95 1.13629 20319 2750 12909 GR MWD API 20.93 116.45 67.9058 20335 2735 12902 ROP MWD FT/H 0.43 535.08 186.811 20366 2780.5 12963 First Reading For Entire File..........2735 Last Reading For Entire File...........12963 • • File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2735.0 2823.0 RPD 2750.0 2814.5 FET 2750.0 2814.5 RPS 2750.0 2814.5 RPX 2750.0 2814.5 RPM 2750.0 2814.5 ROP 2780.5 2869.0 LOG HEADER DATA DATE LOGGED: 03-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT) 2869.0 BOTTOM LOG INTERVAL (FT) 2780.0 BIT ROTATING SPEED (RPM): 2869 HOLE INCLINATION (DEG MINIMUM ANGLE: 59.5 MAXIMUM ANGLE: 59.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud ~ MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 40.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) 3.300 110.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.890 72.0 MUD FILTRATE AT MT: 4.500 110.0 MUD CAKE AT MT: 3.200 110.0 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 ......... .....Undefine d Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefine d Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Cha nnel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Ns am Reading Reading DEPT FT 2735 2869 2802 269 2735 2869 RPD MWD020 OHMM 1.54 2000 419.052 130 2750 2814.5 RPM MWD020 OHMM 5.06 1743.45 59.1091 130 2750 2814.5 RPS MWD020 OHMM 7.67 24.86 15.797 130 2750 2814.5 RPX MWD020 OHMM 0.91 23.7 12.2931 130 2750 2814.5 FET MWD020 HOUR 0.51 57.61 29.5562 130 2750 2814.5 GR MWD020 API 26.44 105.29 59.0393 177 2735 2823 ROP MWD020 FT/H 41.91 448.81 235.299 178 2780.5 2869 First Reading For Entire File..........2735 Last Reading For Entire File...........2869 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ............... Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2815.0 6072.0 RPD 2815.0 6072.0 RPS 2815.0 6072.0 RPX 2815.0 6072.0 RPM 2815.0 6072.0 GR 2823.5 6072.0 ROP 2869.5 6072.0 LOG HEADER DATA DATE LOGGED: 06-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT) 6072.0 BOTTOM LOG INTERVAL (FT) 2869.0 BIT ROTATING SPEED (RPM): 6072 HOLE INCLINATION (DEG MINIMUM ANGLE: 57.7 MAXIMUM ANGLE: 85.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S): 67.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.300 110.0 MUD AT MAX CIRCULA~ TERMPERATURE: 3.860 ~2 MUD FILTRATE AT MT: 4.500 110.0 MUD CAKE AT MT: 3.200 110.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (TN): 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 ......... .....Undefine d Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefine d Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD 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 2815 6072 4443.5 6515 2815 6072 RPD MWD030 OHMM 5.6 109.63 15.7873 6515 2815 6072 RPM MWD030 OHMM 5.21 104.56 14.3476 6515 2815 6072 RPS MWD030 OHMM 4.94 1330.66 14.576 6515 2815 6072 RPX MWD030 OHMM 4.74 1345.1 13.2085 6515 2815 6072 FET MWD030 HOUR 0.23 8.42 0.752029 6515 2815 6072 GR MWD030 API 20.93 114.94 68.4927 6498 2823.5 6072 ROP MWD030 FT/H 0.43 432.8 175.098 .6406 2869.5 6072 First Reading For Entire File..........2815 Last Reading For Entire File...........6072 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6072.5 6111.0 LOG HEADER DATA DATE LOGGED: 11-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT) 6111.0., BOTTOM LOG INTERVAL (FT) 6072.0 BIT ROTATING SPEED (RPM): 6111 HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 64.0 MUD PH: •0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Re'L'6rd Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6072.5 6111 6091.75 78 6072.5 6111 ROP MWD050 FT/H 0.61 207.5 46.7131 78 6072.5 6111 First Reading For Entire File..........6072.5 Last Reading For Entire File...........6111 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # -- FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6072.5 8785.0 FET 6072.5 8785.0 GR 6072.5 8785.0 RPX 6072.5 8785.0 RPD 6072.5 8785.0 RPM 6072.5 8785.0 ROP 6111.5 8785.0 # ~ • LOG HEADER DATA DATE LOGGED: 13-JUL- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) TOP LOG INTERVAL (FT) 8785.0 BOTTOM LOG INTERVAL (FT) 6111.0 BIT ROTATING SPEED (RPM): 8785 HOLE INCLINATION (DEG MINIMUM ANGLE: 82.4 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 77.0 MUD PH: .0 MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 ROP MWD060 API FT/H 4 1 68 24 1 68 28 7 • 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6072.5 8785 7428.75 5426 6072.5 8785 RPD MWD060 OHMM 1.72 1501.61 33.4605 5426 6072.5 8785 RPM MWD060 OHMM 1.66 115.5 30.2838 5426 6072.5 8785 RPS MWD060 OHMM 1.9 139.19 30.3643 5426 6072.5 8785 RPX MWD060 OHMM 1.76 1261.08 30.1873 5426 6072.5 8785 FET MWD060 HOUR 0.21 153.95 1.56501 5426 6072.5 8785 GR MWD060 API 37.97 116.45 69.193 5426 6072.5 8785 ROP MWD060 FT/H 1.66 438.16 191.623 5348 6111.5 8785 First Reading For Entire File..........6072.5 Last Reading For Entire File...........8785 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8785.5 12909.0 RPX 8785.5 12909.0 RPS 8785.5 12909.0 RPD 8785.5 12909.0 GR 8785.5 12902.0 FET 8785.5 12909.0 ROP 8785.5 12963.0 LOG HEADER DATA DATE LOGGED: 15-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD .FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units........................ Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD070 RPM MWD070 RPS MWD070 RPX MWD070 FET MWD070 GR MWD070 ROP MWD070 12963.0 8785.0 12963 84.9 93.5 TOOL NUMBER 153879 48783 6.750 6962.0 Mineral Oil Base 8.80 67.0 .0 28000 3.4 .000 118.400 .000 .000 .0 120.0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8785. 12963 10874.3 RPD MWD070 OHMM 11.54 2000 53.0332 RPM MWD070 OHMM 10.37 2000 46.4645 RPS MWD070 OHMM 9.44 1742.62 45.6641 RPX MWD070 OHMM 8.42 169.96 44.2431 FET MWD070 HOUR 0.19 10.61 0.709846 GR MWD070 API 35.42 96.73 66.7852 ROP MWD070 FT/H 2.54 535.08 192.986 First Reading For Entire File... .......8785. 5 Last Reading For Entire File.... .......12963 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF 8356 8248 8248 8248 8248 8248 8234 8356 785.5 8785.5 8785.5 8785.5 8785.5 8785.5 8785.5 8785.5 12963 12909 12909 12909 12909 12909 12902 12963 Scientific Technical Services Scientific Technical Services End Of LIS File ~ f Sperry-Sun DriZ'ling Services • LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 09 16:26:17 2006 Reel Header Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-156 L1 PB1 API NUMBER: 500292331170 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 09-AUG-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 5 JOB NUMBER: MW0004467716 MW0004467716 MW0004467716 LOGGING ENGINEER: P. ORTH P. ORTH T. GALVIN OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 6 JOB NUMBER: MW0004467716 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2094 FEL: 2560 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS 9d(o `" b ~ C~ ~ ~Y~~ 5r 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) • 10.750 2769.0 7.625 6072.0 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 6072' MD/3490'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-156 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 5. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 6 ALSO INCLUDED AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,5,6 REPRESENT WELL 1J-156 L1 PB1 WITH API#: 50-029-23311-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9248'MD/3432'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER • FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2735.0 9187.0 RPX 2750.0 9194.0 RPS 2750.0 9194.0 RPM 2750.0 9194.0 FET 2750.0 9194.0 RPD 2750.0 9194.0 ROP 2780.5 9248.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2735.0 2869.0 3 2869.0 6072.0 5 6072.5 6111.0 6 6111.0 9248.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2735 9248 5991.5 13027 2735 9248 RPD MWD OHMM 1.54 2000 27.5935 12889 2750 9194 RPM MWD OHMM 1.66 1743.45 21.691 12889 2750 9194 RPS MWD OHMM 1.9 1330.66 21.3057 12889 2750 9194 RPX MWD OHMM 0.91 1345.1 20.4366 12889 2750 9194 FET MWD HOUR 0.21 153.95 1.39022 12889 2750 9194 GR MWD API 20.93 125.36 70.1738 12905 2735 9187 ROP MWD FT/H 0.43 448.81 181.237 12936 2780.5 9248 ~ w First Reading For Entire File..........2735 Last Reading For Entire File...........9248 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2735.0 2823.0 RPD 2750.0 2814.5 RPM 2750.0 2814.5 RPX 2750.0 2814.5 FET 2750.0 2814.5 RPS 2750.0 2814.5 ROP 2780.5 2869.0 LOG HEADER DATA DATE LOGGED: 03-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2869.0 TOP LOG INTERVAL (FT) 2780.0 BOTTOM LOG INTERVAL (FT) 2869.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.5 MAXIMUM ANGLE: 59.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER' S CASING DEPT~FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 2769.0 • Native/Spud Mud 9.10 40.0 8.5 100 7.0 3.300 110.0 4.890 72.0 4.500 110.0 3.200 110.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2735 2869 2802 269 2735 2869 RPD MWD020 OHMM 1.54 2000 419.052 130 2750 2814.5 RPM MWD020 OHMM 5.06 1743.45 59.1091 130 2750 2814.5 RPS MWD020 OHMM 7.67 24.86 15.797 130 2750 2814.5 RPX MWD020 OHMM 0.91 23.7 12.2931 130 2750 2814.5 FET MWD020 HOUR 0.51 57.61 29.5562 130 2750 2814.5 GR MWD020 API 26.44 105.29 59.0393 177 2735 2823 ROP MWD020 FT/H 41.91 448.81 235.299 178 2780.5 2869 First Reading For Entire File..........2735 Last Reading For Entire File...........2869 File Trailer Service name .............STSLIB.002 Service Sub Level Name.. S • Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2815.0 6072.0 RPX 2815.0 6072.0 RPM 2815.0 6072.0 RPS 2815.0 6072.0 RPD 2815.0 6072.0 GR 2823.5 6072.0 ROP 2869.5 6072.0 LOG HEADER DATA DATE LOGGED: 06-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6072.0 TOP LOG INTERVAL (FT) 2869.0 BOTTOM LOG INTERVAL (FT) 6072.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.7 MAXIMUM ANGLE: 85.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 67.0 MUD PH: 9.8 MUD CHLORIDES (PPM): • 150 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.300 110.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.860 93.2 MUD FILTRATE AT MT: 4.500 110.0 MUD CAKE AT MT: 3.200 110.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2815 6072 4443.5 6515 2815 6072 RPD MWD030 OHMM 5.6 109.63 15.7873 6515 2815 6072 RPM MWD030 OHMM 5.21 104.56 14.3476 6515 2815 6072 RPS MWD030 OHMM 4.94 1330.66 14.576 6515 2815 6072 RPX MWD030 OHMM 4.74 1345.1 13.2085 6515 2815 6072 FET MWD030 HOUR 0.23 8.42 0.752029 6515 2815 6072 GR MWD030 API 20.93 114.94 68.4927 6498 2823.5 6072 ROP MWD030 FT/H 0.43 432.8 175.098 6406 2869.5 6072 First Reading For Entire File..........2815 Last Reading For Entire File...........6072 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 L~ Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER • FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6072.5 6111.0 LOG HEADER DATA DATE LOGGED: 11-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6111.0 TOP LOG INTERVAL (FT) 6072.0 BOTTOM LOG INTERVAL (FT) 6111.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 64.0 MUD PH: .0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # • REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6072.5 6111 6091.75 78 6072.5 6111 ROP MWD050 FT/H 0.61 207.5 46.7131 78 6072.5 6111 First Reading For Entire File..........6072.5 Last Reading For Entire File...........6111 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6072.5 9194.0 RPD 6072.5 9194.0 GR 6072.5 9187.0 FET 6072.5 9194.0 . RPM 6072 9194.0 RPS 6072.5 9194.0 ROP 6111.5 9248.0 LO G HEADER DATA DATE LOGGED: 13-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9248.0 TOP LOG INTERVAL (FT) 6111.0 BOTTOM LOG INTERVAL (FT) 9248.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.4 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 77.0 MUD PH: .0 MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 ~ RPM MWD060 OHMM 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6072.5 9248 7660.25 6352 6072.5 9248 RPD MWD060 OHMM 1.72 1501.61 31.762 6244 6072.5 9194 RPM MWD060 OHMM 1.66 115.5 28.5741 6244 6072.5 9194 RPS MWD060 OHMM 1.9 139.19 28.4422 6244 6072.5 9194 RPX MWD060 OHMM 1.76 1261.08 28.148 6244 6072.5 9194 FET MWD060 HOUR 0.21 153.95 1.46969 6244 6072.5 9194 GR MWD060 API 37.97 125.36 72.2435 6230 6072.5 9187 ROP MWD060 FT/H 1.66 438.16 187.643 6274 6111.5 9248 First Reading For Entire File..........6072.5 Last Reading For Entire File...........9248 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File