The URL can be used to link to this page

Home My WebLink About206-115• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~,~~- ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided II (II'I I) II II I I) ~I~ ^ Rescan Needed II I II II II II II II (III RE CAN DI TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No.~ ^ Maps: ^ Greyscale Items: ^ Other, Nolfype: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Protect Proofing III 111111 IIIII II III BY: Maria Date: ~ ~ f~/ ~ /s/ P P Scanning Preparation ~ x 30 = + ~ t =TOTAL PAGES___ ~T' (Count does not include cover sheet) BY: Maria ~ Date:. /s/ ~~ ~ ~ ~ Production Scanning III II~IIIIIII IIIII Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~ (~ ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 111 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III () of II I II II IIIII ReScanned BY: Maria Date: !s/ Comments about this file: Quality Checked III 111111 III II'I II 10/6/2005 Well History File Cover Page.doc w I /7 s � THE STATE Alaska Oil and Gas �� °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue F Q" Anchorage, Alaska 99501 - 3572 ALAS'' Main: 907.279.1433 Fax: 907.276.7542 1 r r John Peirce S MAY 1 0 2013 Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 3 p � j - (15 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -103L1 Sundry Number: 313 -226 Dear Mr. Peirce: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, i° Cathy P. oerster Chair DATED this day of May, 2013. Encl. , _ STATE OF ALASKA h - ALIA OIL AND GAS CONSERVATION COM ION 3 ^ f "� APPLICATION FOR SUNDRY APPROVALS pQ�� mil 0 0 20 , 20 AAC 25.280 Dills--to-17 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Ch4l eogram r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing Other:MBE Treatment P 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r m Exploratory r 206 -115 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23318 -60 0 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1-i 1J - 103L1 6 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25661, 25662 a Kuparuk River Field / West Sak Oil Pool/. 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12445(1 3650 b 11584'.0 3651'® none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108' 108' SURFACE 2897 10.75 2925' 2243' PRODUCTION 7100 7.625 7130' 3790' LINER 5256 4.5 11584' 3651' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6782'- 11427' • 3665-3649' 0 4.5 L - 5015 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) 2 Swell packers 11427' MD, 3649' TVD and 11532 MDI, 3650 TVD m no SSSV 12. Attachments: Description Summary of Proposal Fie 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development jd A Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil I✓ ° Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Email: John.W.PeirceCcacop.com Printed Name John Peirce Title: Wells Engineer Signature , ✓‘. j f Phone: 265 -6471 Date „5/711.3 Commission Use Only 2 Sundry Number: 3 IS -22(0 Conditions of approval: Notify Commission so that a representative may witness ✓ ✓✓ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBDMS MAY 10 201 Other: Spacing Exception Required? Yes ❑ No [ Subsequent Fomi Required: / G 404- - c �nnnn ssl�N APPROVED BY Approved by: prov application is vary tern[ rri E ohs from thTe�l301Aval. Date: S' 1 U /3 Form 10-403 (Revised 10/2012) VL J Submit Form and Attachments in Duplicate r\ �� 57/e/ ORIGINA 1 \ \ ,4 \ t . • • 1J -105L1 to 1J -103L1 `B' MBE Crystal Seal Retreatment A Matrix Bypass Event (MBE) occurred on 4 -5 -12 in 1J -105L1 in the B sand lateral. A 5 -26 -12 IPROF saw the B MBE at 9550' RKB behind the 4.5" slotted liner. Almost all PWI was exiting the slotted liner at this MBE. A 9 -25 -12 Crystal Seal treatment sealed the B MBE, but the treatment broke down within a few months that resulted in shut -in of PWI to 1J -105. A 3 -24 -13 IPROF in 1J -105L1 confirmed the B MBE at —9550' RKB Crystal Sealed 9 -25 -12 was once again open taking all PWI. The 1J -105L2 D lateral was isolated with an Iso -Slv on 5 -23 -12 (for 9 -25 -12 B MBE Crystal Seal treatment), and the D Iso - Sleeve remains set. 1J-105 is configured to perform a 1J -105L1 B MBE Crystal Seal retreatment. The B Diverter remains set. It is proposed that 1J -105L1 B MBE will be resealed with Crystal Seal pumped down coil tubing. No well work needs to be done to prepare for 1J-105L1 for a retreatment. Large hole perforations already exist in 1J -105L1 across the B MBE, which were shot prior to pumping the initial B MBE treatment. A post - Crystal Seal IPROF will likely be run in 1J -105L1 to verify success of the job. Coil Tubing Procedure: RIH with either a large down port or side port nozzle on 2 "coil tubing. Park nozzle across the large hole perforation interval at 9540 - 9545' RKB in the 4.5" slotted liner just above the MBE at 9550' RKB. Pump a Crystal Seal retreatment as follows: a) Seawater down coil. Determine a steady treatment rate (likely between 1.5 - 2 bpm) to be held constant during the treatment through Flush (step f) to monitor MBE response to treatment and to note a CrystalSeal screenout during slurry pumping. Swap from Seawater to 2% KCI, b) 2% KCI Water with 0.05 ppg Crystal Seal (we will use 4 mm mesh for all stages b through e) down coil. Each stage volume is TBD during pumping based on the treating pressure response seen during stage. When called, continue pumping, c) 2% KCI Water w /0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out has not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace remaining Crystal Seal Slurry from coil to liner while POOH to D LEM, then swap to pumping Diesel FP down coil, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal become fully swollen and seal off the MBE before returning 1J -105L1 to PWI for treatment evaluation. Coil tubing will be used to perform a post - CrystalSeal treatment tag, a possible Crystal Seal cleanout, and a memory IPROF depending on post job PWI and offset producer responses. s KUP • 1J -103L1 ConocoPhillips l Well Attributes Max Angle & MD TD Alaska. Inc. Wellbore API/UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (ftKB) 500292331860 WEST SAK PROD 95.19 6,821.89 12,444.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' – SSSV: NONE 80 8/14/2012 Last WO: - 48.71 1/29/2007 Well Conk,' Multiple Laterals - 1 J - 1034 1 1 1 8 2 0 1 3 1 A 9 . 2 1 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date - , Tag: CTMD 4,895.0 3/30/2008 Rev Reason: GLV C/O osborl 1/18/2013 HANGER, 23 —f 1 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ B LINER Slotted 4 1/2 3.476 6,328.3 11,584.0 3,651.6 11.60 L -80 BTC Liner Details Top Depth (TVD) Top Intl Nomi... Top (ftKB) (RKB) ( °) Item Description Comment ID(in) _. _ -_ 6,328.3 3,666.8 81.95 HANGER 7 5/8 x 4 1/2" Mod B -1 Hook Hanger (inside csg) 4.500 CONDUCTOR — 6,345.0 3,671.9 87.80 HANGER 75/8 x 4 1/2" Mod B-1 Hook Hanger (Outside csg) 4.500 Insulated. l l 11,427.1 3,649.1 89.24 PACKER 4 1/2" x 6" Swell Packer 3.960 11,531.8 3,650.0 87.94 PACKER 4 1/2" x 6" Swell Packer 3.960 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (d11 Type Comment 6,782.0 11,427.0 3,664.9 3,649.1 WS B, 1J -103L1 1/5/2007 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" SURFACE, ____41 l centers staggered 18 deg, 3' 28 - 2,925 non- slotted ends ESPMendrel, Notes: General & Safety 3,257 End Date 1/29/2007 Annotation NOTE: B -SAND LEM TORN & PULLED @ INSIDE HOOK HANGER @ 6328' 1/29/2007 NOTE: MULTILATERAL WELL - 1J -103 (A -SAND, 1J -103L1 (B-SAND), 1J -103L2 (D-SAND) 4/16/2008 NOTE: WELL CONVERTED FROM ESP TO GAS LIFT ESP Mandrel, -5 4/17/2008 NOTE: WAIVERED WELL, TBG X IA COMM, FAILED ESP MN 4,295 10/14/2008 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 IIII DISCHARGE, allie.'v". 4.874 MI MI Ull INTAKE, 4,953 SEALS, 4,963 Mk, MOTOR, 4,977 - ':; Illc 5. oast GAUGE, 5,011 mem Centralizer, 5.013 WINDOW D. 5,9916,001 1 1 I I B Liner S-3 Paeker, 6,1186.179 \ [ 1 D LINER NFL 5,9896,249 WINDOW 6, 6,3326,342 B LINER LEM FISH. -8.469 PRODUCTION, ■ 30 -7,130 SLOTS, -- -- 6,782- 11,427 -- - - - - Mandrel Details III Top Depth Top Port (NO) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) 1') Make Model (in) Sery Type Type ('n) (poi) Run Date Com... B LINER 1 3,257.1 2417.0 60.01 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 1/3/2013 Slotted. 4,294.8 2,953.6 59.18 CAMCO KBMG 1 Gas Lift OV BK -5 0.313 0.0 1/10/2013 TD (7J 8, (IJ - 10347 10341) t.584 72,444 • ~~~ ~ ~ ~. ~ ~~ ; ~!~ ~ •~ ~„ ,I y~ !.. ~~F,~Yr MICROFILMED 6/30/2010 DO-NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc a8 ~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061150 Well Name/No. KUPARUK RIV U WSAK 1J-103L1 Operator CONOCOPHILLIPS ALASKA INC MD 12444 TVD 3650 Completion Date 1/29/2007 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Log s Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset pe Med/Frmt Number T y Name ff ~~ ,,,, D Asc Directional Survey Ir" D Asc Directional Survey C Lis 15055 Induction/Resistivity ~t 15055 LIS Verification ~D/ C Li 15056 /R i i i I d i ( s v n uct on es st ty ~~ 15056 LIS Verification Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run Scale Media No Start Stop OH / CH Received Comments 7146 12445 Open 3/27/2007 6297 7296 Open 3/27/2007 PB 1 2889 12444 Open 4/20/2007 LIS Veri, GR, FET, ROP 2889 12444 Open 4/20/2007 LIS Veri, GR, FET, ROP 2889 7295 Open 4/20/2007 P61 LIS Veri, GR, FET, ROP 2889 7295 Open 4/20/2007 P61 LIS Veri, GR, FET, ! ROP Sample Interval Set Start Stop Sent Received Number Comments s ADDITIONAL INFORMATION WeIlCored? Y/~ Chips Received? ~ Analysis Y~ Received? Comments: Daily History Received? (~~~ ~N~ Formation Tops ~1J" Compliance Reviewed By: Samples No API No. 50-029-23318-60-00 UIC N Directional Survey Yes Date: __~~__I~1'.(1~[_i~`^'~ ~ r WELL LGG TRANSIVITI'TAL To: State of Alaska December 5, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-103+L1+L1PB1+L2+PB1+PB2+PB3 AK-MW-4725792 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 J-103+L 1+L 1 PB 1+L2+PB 1+PB2+PB3 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23318-00,60,61,70,71,72,73 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23318-00,61 Digital Log Images 1 CD Rom 50-029-23 318 - 00, 60, 61, 70, 71, 72, 7 3 Ll, L1PB1, PB1, PB2, AND PB3 HAVE NO TVD. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: .,~- Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907-273-3536 lOr~a~. by it~d0.® ~ta(t~1~vr~a_ccs~~. ,~~ JILj ~ 1'~3D ~ Date: Signed: ~~ Y ~~ a6Co ~f t~ ~ ~~ ~-3~-~ ~~ Gtfo ~d ~- 30-1 ~ RE~EI~IE~ STATE OF ALASKA APR 2 2 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAT~II~oi1 & Gas Cons. Commission 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Ot C ra~ ESP to GL Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 206-115 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23318-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 110' 1J-103L1 8. Property Designation: 10. Field/Pool(s): ADL 25661 & 25662 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12445' feet true vertical 3650' feet Plugs (measured) Effective Depth measured 11584' feet Junk (measured) true vertical 3652' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2815' 10-3/4" 2925' 2243' PRODUCTION 7020' 7-5/8" 7130' 3791' D-SAND WINDOI 1' 7-5/8" 5992' 3612' B-SAND WIND01 1' 7-5/8" 6333' 3667' B-SAND LINER 5465' 4-1/2" 11584' 3652' Perforation depth: Measured depth: 6782'-11427' true vertical depth: 3665'-3649' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5015' MD. Packers &SSSV (type 8~ measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated measured > ; ~~ ~ ~,~~ ~ ~. 200th 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 515 115 19 212 188 Subsequent to operation 253 61 8 673 194 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development^ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.O. Exempt: N/A contact Bob Christensen /Bob Buchholz Printed Name Robert W. B chholz Title Production Engineering Technician u Signature 4~~~~ l~~" ~ ~ Phone 659-7535 Date ~,C // / /~ (ry s, / ( J- Form 10-404 Revised 04/2004 Submit nginal Only 1 ~~~ A l~ ~~ ~~~ 1J-103L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/17/08 Well returned to production as a gas lifted oil producer 04/16/08 Pulled 48' 3" TTC ESP from 4900' RKB. rye.,""-^.~ '~ KRU 1J-103L1 Conc~coF~hilt~ps Alaska, tnc II~~ .. 1J-103L1 _ _ _ _ _ -- -- - - - _ -- API: 500292331860 Well T :PROD An le ~ TS: de ~ SSSV Type: NONE Orig 1/29/2007 Angle @ TD: 94 deg @ 12445 I ~ ; Com letion: Ann ular Fluid: Last W/O: Rev Reason: C/O SOV Referenc ~' a Lo :29.81' RKB Ref L Date: Last U date: 11/5/2007 ~'; Last Ta TD: 12445 ftK6 ' ~ ~ Last Ta Date: x e ~~ 9 ~ Ma HoL Angle: 95 deg lob 6823 ~ -~~ Casing String -COMMON STRINGS ;~~ Descn Uon Sae To Bottom TVD Wt Grade Thread XO INTAKE - (as53ass3, OD:5:130) SEAL (ass3-asn, OD:5.130) MOTOR ~ (as77so11, OD:5.620) Pump Gauge - (50115013, OD:4:500) ,~~. It f SBE (61455146, G--~ ~ ~--. Pert (6782-11427) xo 11551-11552, OD:4.500) F 11 ~~ FIB '` f. 4. I CONDUCTOR SURFACE PRODUCTION D-SAND WINDOW 20.000 10.750 7.625 7.625 0 0 0 5991 108 2925 7130 5992 108 2243 3641 3611 94.00 45.50 29.70 0.00 H-40 L-80 L-80 WELD BTC BTC-M B-SAND LINER 4.500 6119 11584 3651 11.60 L-80 BTC B-SAND WINDOW 7.625 i 6332 6333 3667 0.00 Tubing String -TUBING Size Top Bottom TVD Wt Grade Thread x.500 0 5015 3311 12-60 L-80 IBTM-SCC -~ ;Perforations Stammary ° Interval TVD Zone Status Ft SPF Date Type i Comment 6,02 - 11-12' 665 - 36-19 ~;^;!S E -16-15 ~ 1 5 20 0, SLOTS Slotted Casing :Gas Lift Mandrels/Valv es _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv 1 3257 2416 CAMCO KBMG SOV 1.0 BK 0.000 0 Cmnt 0/19/200 2 4295 2954 CAMCO KBMG DMY 1.0 BK-5 0.000 0 1/28/2007 Other (plugs, equip., etc. nomh ~ Tin ~ ~.,.... - COMPLETIQN _.__ __ 23 23 HANGER n uv° VETCO GRAY TUBING HANGER IU 4 500 4874 3247 Discharge A-WELL DISCHARGE SUB . 0.000 Sub 4900 3259 PUMP ESP PUMP PACKOFF ASSEMBLY & TBG LOCK set 1/29/2007 0 000 4953 3283 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE . 0.000 4963 3288 SEAL TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA 0 000 4977 3294 MOTOR 418 HP KMHFER 2610 / 98 . 0 000 5011 3310 Pump A-WELL 1 PUMP GAUGE . 0.000 Gau e 5013 3311 Centralizer MOTOR CENTRALIZER 0 000 5989 3611 HANGER D-SAND BAKER MOD B1 FHH INSIDE CASING . 4 020 6119 3634 SLEEVE B-SAND LINER C-2 LINER HANGER SETTING SLEEVE . 5 070 6145 3638 SBE B-SAND LINER 197-47 CASING SEAL BORE EXTENSION . 4 750 6146 3639 XO Bushing B-SAND LINER CROSSOVER BUSHING . 3.830 6158 3641 PACKER B-SAND LINER BAKER S-3 PRODUCTION PACKER "PULLED TO 4.500 REMOVE B-SAND LEM -RESET PACKER"' 6169 3643 NIP B-SAND LINER CAMCO DB NIPPLE 3 562 6178 /n`27~ 3644 '}CGl WLEG B-SAND LINER WIRELINE GUIDE . 3.958 , - --' Other ---' (plugs, ' •' • •"-" • ' `-' "' `•"-' ~•~••-~ ` ~~•••-`• rvIVV O 1 rrll-l I IIVJILIG l.HJ11VU) I 4.ULU F equip., etc.) - B-SAND L[NER DETAIL De th TVD T e Descn tion ID 6345 3669 HANGER B-SAND LINER BAKER MOD B1 FHH OUSIDE CASING 4 020 6353 3669 . SWIVEL B-SAND LINER BAKER CASING SWIVEL 3 960 6391 3673 . NIP B-SAND LINER CAMCO 'DB-6' NIPPLE 3 563 6465 3678 . SEAL B-SAND LINER BAKER SEAL ASSEMBLY 4 020 11427 3649 . Swell B-SAND LINER AER SWELL PACKER 3.960 Packer 11531 3651 Swell B-SAND LINER AER SWELL PACKER 3.960 Packer 11551 3651 XO B-SAND LINER XO 3 500 11552 . 3651 BENT JT B-SAND LINER BENT JOINT TUBING w/END WELDED UP 2 gg2 Gertera . (Notes Date Note 1/29/2007 NOTE: B-SAND LEM TORN & PULLED INSIDE HOOK HANGER 6328' 1/29/2007 NOTE: MULTILATERAL WELL - 1J-103 (A-SAND, 1J-103L1 (B-SANDI. 1J-103L2 (D-sarvrn i • WELL LOC TRANS1~tITTAL To: State of Alaska April 18, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-103, PBI, PB2, PB3, Ll PBI, L1 & L2, AK-MW-4725877 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23318-00, 70, 71, 72, 73, 60 & 61 PLEASE ACI{NOWLEDGE RECEIPT BY SIGNING ANll RET'iJRNINC A COPY OF THE TRANSiVIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~~ ~~~ Datef~~~ ~' ~ X00? tea. ~<~ <, ~, . Signed: bolo ' ~ l~ ~''S °s` ~ 1565 ~ ~ t5 oS3 ~p(p-tt5 ~ t5~o5S y ~ SU 5' (~ ~ ~, -(l (o ~ 105' ~- # ~so~<~ 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-103L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,146.51' MD Window /Kickoff Survey 7,185.00' MD (if applicable) Projected Survey: 12,444.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ha14.0 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 02 a ~' 1/S 12-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-103L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,297.45' MD Window /Kickoff Survey 6,332.00' MD (if applicable) Projected Survey: 7,295.70' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date 7~~ 7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~ V ~~ STATE OF ALASKA ~ MA~ O ~ ZOO7 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO ~~~~~ ~0"~''"$~10~ 1a. Well Status: Oil O Gas Plugged Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: Development Q .• Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: January 29, 2007 ~ 12. Permit to Drill Number: 206-115 / R 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ December 006 3'f~~~' 13. API Number: 50-029-23318-60 4a. Location of Well (Governmental Section): Surface: 2225' FSL, 2441' FEL, Sec. 35, 711 N, R10E, UM ~ 7. Date TD Reached: ~,_ January 3, 2007 14. Well Name and Number: 1J-103L1 At Top Productive Horizon: 1985' FSL, 683' FWL, Sec. 36, T11N, R?OE, UM 8. KB Elevation (ft): ~~ 7 ~~S L 30' RKB ~D •/(y•07 15. FieldlPool(s): Kuparuk River Field Total Depth: 1161' FSL, 714' FWL, Sec. 01, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 11584' MD / 3651' TVD West Sak Oil Pool °~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 ~ y- 5946037 ~ Zone- 4 10. Total Depth (MD + TVD): 12444' MD / 3650' TVD ~ 16. Property Designation: ADL 25661 & 25662 TPI: x- 561892 y- 5945822 Zone- 4 Total Depth: x- 561978 - 5939719 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3628' MD 21. Logs Run: ~'•/k~~e,fJ ~ ~. ~~~ /YfD i~~'~ j yJ~ GR/Res / r ~ 3•i6•a7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE TING AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN RECORD PULLED 20" x 34" 62.6# H-40 30' 108' 30' 108' 42" aoo sx AS 1 10.75" 45.5# L-80 30' 2925' 30' 2243' 13.5" 545 sx AS Lite, 177 sx DeepCRETE 7-5/8" 29.7# L-80 30' 7130' 30' 3790' 9-7/8" 418 sx Class G 4.5" 11.6# L-80 6328' 11584' 3633' 3651' 6.75" slotted liner 23. Perforations 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 5015' 6106', 6157' slotted liner from 11447-6782' and 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) Oil Producer -shares production with 1J-103 and 1J-103L2 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 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". NONE y 1.: ~~ D~° . . ,: ~. ' ' ~.,,,~..-..~...~......:.r. Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE ~ MAR ~ 4 2007 ~?' ~Za i~ /1"~1d7 ~. 28. 29. 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-103L1 Top Kuparuk B 6330' 3666' 1 J-103L1 P61 TD 7295' 3641' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nam Rand Thomas Title: Greater Kuparuk Area Drillino Team Leader ~ ~~ ~~ , Signature hone 'Z CGS^ G ~ ,j ~;~ 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 ~,----,~ Cont~coPhi~lps Alaska! tnc. 'J-1`~ 03L1 _ -- AFI:i5U02`J2331xou XOINTAKE (4953963, OD:5.130) SEAL (ass3.as77, OD:5.130) MOTOR (4977-5011, OD:5.620) Pump Gauge (50115013, OD:4.500) L2ct Tag D2te ~ ping String - COMM cription CONDUCTOR SURFACE Well T~ omelet Last N TD: ~ 12444 ftKB Max Hnla Anple~ 95 den n f GS To Bottom 0 108 1 J-103L1 An ie car TS: de m An le TD: 94 de 12444 Rev Reason: NEW WELL Last U date: 2/26/2007 TVD ~ Wt ~ Grade I Thread ~ B-SAND WINDOW I 7.625 I 6332 I 6333 I 3667 I 0.00 I I I Tubing String - TUBtNG_ Size Top Bottom TVD ~ Wt Grade ~ Thread a5oo o soi; .;it ize,n ~-~ o iETr.t~;~~c .Perforations Summary nterval TVD Zone Status I ' Ft SPF Date Type Comment t„~-II~t27 3664- h48 .:SB -3~-t7 ~ 1;`,~nu~ ~UiT; ~I~>n~~i~ asiny Gas Lift MandrelsNaives St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VIv Cmnt 1 3257 2416 CAMCO KBMG SOV 1.0 BK-5 0.000 0 1/28/2007 2 4295 2953 CAMCO KBMG _ .._ . DMY 1.0 BK-5 n pin 0 1128/2007 IOther (plugs, equip., etc .).-COMPLETION J De th TVD T e Descri ion ID 23 23 HANGER VETCO GRAY TUBING HA NGER 4.500 4874 3247 Discharge A-WELL DISCHARGE SUB 0.000 A-WELL 1 SBE (6145146, OD:6.250) 7 Perf (6782-11427) XO ;11551-11552, OD:4.500) 6158 3640 PACKER BAKER S-3 PRODUCTION PACKER ``PULLED TOREMOVE B-SAND LEM - 4.500 RESET PACKER*` 6169 3642 NIP CAMCO DB NIPPLE 3.562 6178 3644 WLEG WIRELINE GUIDE 3.958 R3?Q 'i6EF; HANGER BAKER MOD B1 FHH /INSIDE CASINGI 4.020 KRU s Casing Detail Report 1 J-103 .... B-Lat Liner -_ Casing - --_ -- - - - - -- - -- ___ - - _ Casing Description Set Depth (ftKB) Run Date Set Tension (kips) B-Lat Liner 11,584.0 1/5/2007 Centralizers Scratchers 122 Hydraform Cent W/stop rings in middle of jt .Casco Com onents -- -- -1 M p Item Decal t(on i) OD in ~ ~ V~/t'IbaLft) Grade To Thread ,lts O I~en ft _ p(_ ~ _ To ftKB Btm ftKB) i ~ f~ies~ l ) Class Max OD In) ~ 7 5/8 x 4 1/2" Mod 4 1/2 1 16.70 6,328.3 6,345.0 B-1 Hook Hanger (inside csg) 7 5/8 x 4 1/2" Mod 4 1/2 1 6.23 6,345.0 6,351.2 B-1 Hook Hanger (Outside csg) Cross Over pup jt 4 1/2 1 2.02 6,351.2 6,353.2 Baker Casing Swivel 4 1/2 1 2.57 6,353.2 6,355.8 Cross Over pup jt 4 1/2 11.60 L-80 1 2.10 6,355.8 6,357.9 4.000 Blank Liner 4 1/2 11.60 L-80 BTC 10 424.54 6,357.9 6,782.5 4.000 Slotted Liner 4 1/2 11.60 L-80 BTC 110 4,644.60 6,782.5 11,427.1 4.000 4 1/2" x 6" Swell 4 1/2 1 19.52 11,427.1 11,446.6 Packer Blank Liner 4 1/2 11.60 L-80 BTC 2 85.24 11,446.6 11,531.8 4.000 4 1/2" x 6" Swell 4 1/2 1 19.55 11,531.8 11,551.4 Packer Cross Over 4 1/2 1 1.42 11,551.4 11,552.8 31/2"Tbgbentjt 31/2 9.30 L-80 1 31.21 11,552.8 11,584.0 2.992 W/Welded End Page 1/1 Report Printed: 2/28/2007 Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. ___ Date: 2/7/2007 __ "Time: 16:22:04 Page: Field: Kuparuk River Unit Co-ordinate('~`E)Reference: Wefl: 1J-103, Tr ue North Site: Kuparuk 1J Pad Vertical (TVD) Re ference: 1J-103L1: 109.7 WeIL• 1J-103 Section (VS) Reference: Welt (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-103L1 Survey Calculation Method: MinimumCurvat ure Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1J-103 Slot Name: ~ Well Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N i +E/-W -22.57 ft Fasting : 558766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft i Wellpath: 1J-103L1 Drilled From: 1J-103L1P61 ~ 500292331860 ~ Current Datum: 1 J-103L1: Tie-on Depth: Height 109.70 ft Above System 7146.51 ft Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angle: 80.81 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: 2/7/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name '~ ft ft 50.70 632.70 1J-103P61 gyro (50. 70-632.70) CB-GYRO-SS Camera based gyro single shot 662.65 6297.45 1J-103P61 (662.65- 8486.40) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6332.70 7146.51 1J-103L1P61 (6332. 70-7239.99) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7185.70 12404.02 1 J-103L1 (7185.70-12404.02) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl Azim TVD Sys TVD NIS E/yY b1apN 111apE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.70 0.00 0.00 5946037.60 558766.46 TIE LINE 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS i~ 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS 449.70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC ~ 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC j 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.86 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510,46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC 1847.57 50.10 34.66 1657.03 1547.33 517.74 321.58 5946557.78 559083.96 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report • (:ompany: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 16:22:04 __ __ Yage: 2 Field: Ku paru k River Uni t Co-or dinate(NE)Reference: Well: 1J-10 3, Tru e North Site: Ku paru k 1J Pad Vertical (TV D) Reference:" 1J-103L1: 1 09.7 Well: 1J-103 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzi) ~Vellpath: 1J- 103L1 Survey Calc ulation Method: _-- Minimum C urvat ure Ub: Oracle Survcv MD Inc l azim TVD Sys TVD ~"/S ElW MapN 1IapE i oul ft deg de g ft ft ft ft ft ft 1905. 12 50. 63 35 .76 1693. 74 1584. 04 553. 95 347. 13 5946594. 19 559109. 23 MWD+IFR-AK-CAZ-SC 1936. 93 51. 49 36 .82 1713. 74 1604. 04 573. 89 361. 78 5946614. 24 559123. 71 MWD+IFR-AK-CAZ-SC 2000. 86 51. 87 39 .61 1753. 38 1643. 68 613. 29 392. 80 5946653. 88 559154. 43 MWD+IFR-AK-CAZ-SC 2093. 95 53. 72 45 .46 1809. 70 1700. 00 667. 85 442. 92 5946708. 82 559204. 11 MWD+IFR-AK-CAZ-SC 2191. 18 56. 62 51 .14 1865. 26 1755. 56 720. 85 502. 51 5946762. 28 559263. 28 MWD+IFR-AK-CAZ-SC 2284. 31 58. 44 55 .15 1915. 27 1805. 57 767. 94 565. 37 5946809. 85 559325. 77 MWD+IFR-AK-CAZ-SC 2380. 32 59. 72 60 .12 1964. 62 1854. 92 811. 99 634. 92 5946854. 44 559394. 97 MWD+IFR-AK-CAZ-SC 2419. 46 59. 50 61 .37 1984. 42 1874. 72 828. 48 664. 38 5946871. 16 559424. 29 MWD+IFR-AK-CAZ-SC 2475. 95 58. 92 62 .59 2013. 34 1903. 64 851. 28 707. 21 5946894. 29 559466. 94 MWD+IFR-AK-CAZ-SC 2571. 00 59. 73 61 .27 2061. 83 1952. 13 889. 75 779. 34 5946933. 32 559538. 76 MWD+IFR-AK-CAZ-SC 2611. 14 59. 76 60 .92 2082. 06 1972. 36 906. 51 809. 70 5946950. 32 559568. 98 MWD+IFR-AK-CAZ-SC ~ 2666. 51 59. 94 60 .73 2109. 87 2000. 17 929. 85 851. 50 5946973. 98 559610. 60 MWD+IFR-AK-CAZ-SC ; 2695. 63 59. 05 61 .06 2124. 65 2014. 95 942. 06 873. 42 5946986. 35 559632. 42 MWD+IFR-AK-CAZ-SC i 2761. 59 57. 83 60 .61 2159. 17 2049. 47 969. 44 922. 50 5947014. 12 559681. 28 MWD+IFR-AK-CAZ-SC 2828. 92 58. 92 61 .14 2194. 48 2084. 78 997. 35 972. 58 5947042. 41 559731. 14 MWD+IFR-AK-CAZ-SC 2857. 58 59. 64 60 .94 2209. 12 2099. 42 1009. 27 994. 14 5947054. 51 559752. 60 MWD+IFR-AK-CAZ-SC i, 2968. 32 59. 14 61 .42 2265. 51 2155. 81 1055. 22 1077. 64 5947101. 10 559835. 73 MWD+IFR-AK-CAZ-SC 3038. 11 58. 93 61 .21 2301. 41 2191. 71 1083. 94 1130. 14 5947130. 23 559888. 00 MWD+IFR-AK-CAZ-SC i~ 3064. 31 58. 53 60 .89 2315. 01 2205. 31 1094. 78 1149. 74 5947141. 22 559907. 51 MWD+IFR-AK-CAZ-SC 3159. 47 58. 15 61 .48 2364. 96 2255. 26 1133. 82 1220. 71 5947180. 81 559978. 16 I MWD+IFR-AK-CAZ-SC 3253. 03 58. 77 61 .25 2413. 90 2304. 20 1172. 04 1290. 69 5947219. 56 560047. 84 MWD+IFR-AK-CAZ-SC 3349. 29 59. 73 61 .83 2463. 12 2353. 42 1211. 46 1363. 42 5947259. 54 560120. 25 MWD+IFR-AK-CAZ-SC 3443. 96 59. 44 65 .76 2511. 06 2401. 36 1247. 50 1436. 65 5947296. 16 560193. 19 MWD+IFR-AK-CAZ-SC 3537. 78 59. 12 70 .40 2559. 01 2449. 31 1277. 60 1511. 44 5947326. 84 560267. 73 MWD+IFR-AK-CAZ-SC 3633. 89 58. 32 74 .65 2608. 92 2499. 22 1302. 27 1589. 75 5947352. 12 560345. 85 MWD+IFR-AK-CAZ-SC 3728. 68 58. 19 80 .31 2658. 83 2549. 13 1319. 74 1668. 40 5947370. 19 560424. 34 MWD+IFR-AK-CAZ-SC 3822. 92 58. 63 85 .34 2708. 22 2598. 52 1329. 75 1748. 00 5947380. 83 560503. 86 MWD+IFR-AK-CAZ-SC ~ 3920 .15 58. 75 90 .21 2758. 77 2649. 07 1332. 97 1830. 97 5947384. 69- 560586. 80 MWD+IFR-AK-CAZ-SC 4016 .73 57 .89 96 .43 2809. 52 2699. 82 1328. 24 1912. 96 5947380. 60 560668. 81 MWD+IFR-AK-CAZ-SC 4109 .70 58. 93 105 .03 2858. 29 2748. 59 1313. 48 1990. 65 5947366 .45 560746. 61 MWD+IFR-AK-CAZ-SC 4205 .49 58 .97 109 .97 2907. 72 2798. 02 1288. 82 2068. 88 5947342. 40 560825. 02 MWD+IFR-AK-CAZ-SC 4302 .30 59. 16 115 .17 2957. 51 2847. 81 1256. 96 2145. 52 5947311 .14 560901. 90 MWD+IFR-AK-CAZ-SC 4396. 10 58. 94 118 .87 3005. 76 2896. 06 1220. 43 2217. 16 5947275 .17 560973. 82 MWD+IFR-AK-CAZ-SC ~ 4489. 53 58. 62 122 .32 3054. 20 2944. 50 1179. 77 2285. 93 5947235. 06 561042. 89 MWD+IFR-AK-CAZ-SC I 4586. 40 58. 36 128 .27 3104. 86 2995. 16 1132. 09 2353. 29 5947187. 91 561110. 61 MWD+IFR-AK-CAZ-SC 4680. 37 58. 90 131 .04 3153. 79 3044. 09 1080. 89 2415. 05 5947137. 20 561172. 77 MWD+IFR-AK-CAZ-SC 4775. 85 61. 69 130 .15 3201. 10 3091. 40 1026. 94 2478. 02 5947083. 75 561236. 15 MWD+IFR-AK-CAZ-SC 4868. 62 62. 42 130 .01 3244. 57 3134. 87 974. 18 2540. 72 5947031. 48 561299. 26 MWD+IFR-AK-CAZ-SC 4966. 54 63. 06 130 .13 3289. 42 3179. 72 918. 14 2607. 34 5946975. 98 561366. 30 MWD+IFR-AK-CAZ-SC 5060. 87 62. 79 132 .90 3332. 36 3222. 66 862. 48 2670. 22 5946920. 81 561429. 61 MWD+IFR-AK-CAZ-SC 5156. 49 63. 60 136 .59 3375. 49 3265. 79 802. 41 2730. 81 5946861 .22 561490. 67 MWD+IFR-AK-CAZ-SC 5251 .33 64. 45 139 .73 3417. 04 3307. 34 738. 90 2787. 67 5946798 .16 561548. 01 MWD+IFR-AK-CAZ-SC 5346 .95 67. 81 145 .86 3455. 76 3346. 06 669. 27 2840. 45 5946728 .95 561601. 33 MWD+IFR-AK-CAZ-SC 5442 .23 69 .73 151 .57 3490. 28 3380. 58 593. 40 2886. 52 5946653 .45 561647. 99 MWD+IFR-AK-CAZ-SC 5537 .26 73 .47 156 .74 3520. 29 3410. 59 512. 27 2925. 77 5946572 .64 561687. 86 MWD+IFR-AK-CAZ-SC 5631 .47 77 .44 159 .97 3543. 95 3434. 25 427. 53 2959. 37 5946488 .18 561722. 12 MWD+IFR-AK-CAZ-SC 5693 .55 78 .30 162 .00 3557. 00 3447. 30 370. 16 2979. 15 5946430 .96 561742. 34 MWD+IFR-AK-CAZ-SC 5723 .72 78 .56 161 .64 3563. 05 3453. 35 342. 07 2988. 37 5946402 .95 561751. 78 MWD+IFR-AK-CAZ-SC I 5820 .08 79 .35 163 .42 3581. 51 3471. 81 251. 87 3016. 76 5946312 .98 561780. 87 MWD+IFR-AK-CAZ-SC 5912 .60 79 .95 165 .42 3598. 14 3488. 44 164. 20 3041. 20 5946225 .51 561805. 99 MWD+IFR-AK-CAZ-SC 6010 .65 80 .83 165 .32 3614. 51 3504. 81 70. 66 3065. 62 5946132 .18 561831. 14 MWD+IFR-AK-CAZ-SC 6108 .38 78 .58 166 .72 3631. 97 3522. 27 -22. 64 3088. 85 5946039 .07 561855. 09 MWD+IFR-AK-CAZ-SC 6200 .88 80 .95 169 .74 3648. 41 3538. 71 -111. 74 3107. 40 5945950 .13 561874 .34 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ('nmpany: ConocoPhillips Alaska Inc. Date: 2/7/2007 Time: 16:22:04. Patc: 3 Field: Kuparuk River Unit Co-ordinaYe(NE}Reference: WeII: 1J-103, True North Sitc: Kuparuk 1J Pad Vertical (I'VD) Reference: 1J-103L1 109.7 WeIL•, 1J-103 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi} R'ellpath: 1J-103L1 Survey Calculation Method: Minimum Curvature I)h: Oracle __ __ _ _' Survev MD Incl ~cim T~'D Svs Tel) iCIS E/~V MapN MapE 'l'oot ft deg deg ft ~ ft ft ft ft ft I 6297.45 82.26 173.71 3662.51 3552.81 -206.26 3121.14 5945855.73 561888.82 MWD+IFR-AK-CAZ-SC < 6332.70 81.91 175.52 3667.37 ~ 3557.67 -241.01 3124.42 5945821.00 561892.37 MWD+IFR-AK-CAZ-SC 6402.41 87.03 179.46 3674.09 3564.39 -310.30 3127.45 5945751.75 561895.93 MWD+IFR-AK-CAZ-SC 6452.99 86.35 182.30 3677.01 3567.31 -360.78 3126.67 5945701.27 561895.55 MWD+IFR-AK-CAZ-SC 6495.66 87.77 184.69 3679.20 3569.50 -403.31 3124.07 5945658.72 561893.29 MWD+IFR-AK-CAZ-SC 6543.16 91.16 184.49 3679.64 3569.94 -450.65 3120.27 5945611.36 561889.86 MWD+IFR-AK-CAZ-SC ~ 6588.92 94.26 184.36 3677.48 3567.78 -496.22 3116.75 5945565.77 561886.69 MWD+IFR-AK-CAZ-SC ~, 6622.32 94.32 184.68 3674.98 3565.28 -529.42 3114.12 5945532.55 561884.32 MWD+IFR-AK-CAZ-SC ~ 6682.92 92.71 184.90 3671.26 3561.56 -589.69 3109.07 5945472.25 561879.74 MWD+IFR-AK-CAZ-SC ': 6733.47 93.77 184.86 3668.41 3558.71 -639.98 3104.78 5945421.93 561875.84 MWD+IFR-AK-CAZ-SC 6775.37 94.51 183.01 3665.38 3555.68 -681.67 3101.91 5945380.23 561873.30 MWD+IFR-AK-CAZ-SC 6822.59 95.19 182.62 3661.39 3551.69 -728.66 3099.60 5945333.22 561871.35 MWD+IFR-AK-CAZ-SC 6868.16 94.13 181.00 3657.69 3547.99 -774.06 3098.17 5945287.82 561870.28 MWD+IFR-AK-CAZ-SC 6914.50 93.95 178.47 3654.42 3544.72 -820.28 3098.38 5945241.61 561870.85 MWD+IFR-AK-CAZ-SC 6961.81 92.89 175.62 3651.60 3541.90 -867.43 3100.82 5945194.47 561873.65 MWD+IFR-AK-CAZ-SC 7005.19 94.26 175.10 3648.89 3539.19 -910.59 3104.32 5945151.35 561877.49 MWD+IFR-AK-CAZ-SC 7053.22 93.27 173.21 3645.74 3536.04 -958.26 3109.20 5945103.72 561882.74 MWD+IFR-AK-CAZ-SC 7101.50 93.77 173.09 3642.77 3533.07 -1006.11 3114.95 5945055.93 561888.86 MWD+IFR-AK-CAZ-SC 7146.51 91.72 174.55 3640.62 3530.92 -1050.80 3119.78 5945011.28 561894.05 MWD+IFR-AK-CAZ-SC 7185.70 89.83 175.46 3640.09 3530.39 -1089.83 3123.20 5944972.28 561897.77 MWD+IFR-AK-CAZ-SC I 7239.88 88.95 174.67 3640.67 3530.97 -1143.81 3127.86 5944918.34 561902.85 MWD+IFR-AK-CAZ-SC 7288.50 92.52 177.05 3640.04 3530.34 -1192.29 3131.37 5944869.90 561906.73 MWD+IFR-AK-CAZ-SC I 7335.64 92.28 175.45 3638.07 3528.37 -1239.28 3134.45 5944822.93 561910.18 MWD+IFR-AK-CAZ-SC 7384.84 90.61 175.61 3636.83 3527.13 -1288.32 3138.28 5944773.94 561914.40 MWD+IFR-AK-CAZ-SC 7429.04 92.28 178.25 3635.71 3526.01 -1332.43 3140.65 5944729.84 561917.11 MWD+IFR-AK-CAZ-SC 7480.38 90.30 178.76 3634.56 3524.86 -1383.74 3141.99 5944678.55 561918.85 MWD+IFR-AK-CAZ-SC 7521.79 90.99 178.63 3634.09 3524.39 -1425.14 3142.93 5944637.17 561920.11 MWD+IFR-AK-CAZ-SC 7615.22 90.98 178.71 3632.48 3522.78 -1518.53 3145.10 5944543.81 561923.01 MWD+IFR-AK-CAZ-SC 7709.05 89.13 178.78 3632.39 3522.69 -1612.33 3147.15 5944450.03 561925.80 MWD+IFR-AK-CAZ-SC ~ 7801.06 88.76 179.30 3634.09 3524.39 -1704.31 3148.69 5944358.08 561928.05 MWD+IFR-AK-CAZ-SC 7894.69 87.78 176.62 3636.92 3527.22 -1797.83 3152.02 5944264.60 561932.11 MWD+IFR-AK-CAZ-SC 7988.00 90.99 179.65 3637.92 3528.22 -1891.06 3155.06 5944171.40 561935.88 MWD+IFR-AK-CAZ-SC 8084.39 92.60 182.07 3634.90 3525.20 -1987.38 3153.61 5944075.08 561935.18 MWD+IFR-AK-CAZ-SC 8180.37 89.32 178.05 3633.29 3523.59 -2083.32 3153.51 5943979.16 561935.83 MWD+IFR-AK-CAZ-SC 8278.67 90.56 180.10 3633.39 3523.69 -2181.60 3155.10 5943880.90 561938.19 MWD+IFR-AK-CAZ-SC 8374.95 90.19 180.02 3632.76 3523.06 -2277.88 3155.00 5943784.63 561938.84 MWD+IFR-AK-CAZ-SC 8471.89 92.72 180.72 3630.30 3520.60 -2374.77 3154.37 5943687.74 561938.97 MWD+IFR-AK-CAZ-SC 8569.27 90.37 177.10 3627.67 3517.97 -2472.08 3156.23 5943590.47 561941.58 MWD+IFR-AK-CAZ-SC 8665.68 87.78 174.72 3629.23 3519.53 -2568.22 3163.10 5943494.40 561949.20 MWD+IFR-AK-CAZ-SC 8762.13 90.62 177.45 3630.58 3520.88 -2664.41 3169.68 5943398.26 561956.54 MWD+IFR-AK-CAZ-SC 8859.75 90.19 177.34 3629.89 3520.19 -2761.93 3174.12 5943300.79 561961.73 MWD+IFR-AK-CAZ-SC 8959.22 90.19 177.37 3629.56 3519.86 -2861.29 3178.71 5943201.48 561967.10 MWD+IFR-AK-CAZ-SC 9052.01 94.08 182.06 3626.10 3516.40 -2953.97 3179.18 5943108.81 561968.29 MWD+IFR-AK-CAZ-SC 9148.94 91.67 179.11 3621.24 3511.54 -3050.76 3178.19 5943012.03 561968.06 MWD+IFR-AK-CAZ-SC 9245.44 89.51 178.84 3620.24 3510.54 -3147.23 3179.92 5942915.58 561970.54 MWD+IFR-AK-CAZ-SC i Iii 9342.36 88.64 179.27 3621.81 3512.11 -3244.12 3181.52 5942818.72 561972.89 MWD+IFR-AK-CAZ-SC 9438.44 89.63 180.40 3623.26 3513.56 -3340.19 3181.79 5942722.66 561973.92 MWD+IFR-AK-CAZ-SC 9535.08 90.62 179.09 3623.05 3513.35 -3436.83 3182.22 5942626.04 561975.10 MWD+IFR-AK-CAZ-SC 9630.78 88.27 177.68 3623.98 3514.28 -3532.47 3184.92 5942530.43 561978.54 MWD+IFR-AK-CAZ-SC 9727.89 89.44 181.08 3625.92 3516.22 -3629.54 3185.97 5942433.38 561980.35 MWD+IFR-AK-CAZ-SC 9822.89 91.67 185.05 3625.00 3515.30 -3724.38 3180.89 5942338.52 561976.01 MWD+IFR-AK-CAZ-SC ', 9919.75 89.69 182.96 3623.85 3514.15 -3820.98 3174.13 5942241.87 561970.01 MWD+IFR-AK-CAZ-SC i Halliburton Company Survey Report __ _ __ __ Company: ConocoPhillips Alaska Inc. Date: 2/7/2007 "Time: 16:22:04 Page: 4 Fie(d: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1J-103,TrueNorth Sitc: Kuparuk 1J Pad Ycrtical ("1'Y'D) Reference: 1J-103L1: 109.7 ~Vcll: 1J-103 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J-103L1 Survey Calculation Method: Minimum Curvature I)b: Oracle _____' ___ __ Survey YID Ind Azim TVD Sys TVD N/S E/W MapN Y1apE Tool ft deg deg ft ft ft ft ft ft __ -- __ -_ 10016.45 89.20 182.34 3624.78 3515.08 -3917.58 3169.66 5942145.26 561966.29 MWD+IFR-AK-CAZ-SC 10113.05 89.32 183.06 3626.03 3516.33 -4014.06 3165.11 5942048.75 561962.49 MWD+IFR-AK-CAZ-SC 10209.61 89.75 183.30 3626.81 3517.11 -4110.47 3159.75 5941952.31 561957.89 MWD+IFR-AK-CAZ-SC 10307.88 90.12 179.04 3626.93 3517.23 -4208.69 3157.74 5941854.08 561956.65 MWD+IFR-AK-CAZ-SC 10403.46 88.83 176.98 3627.80 3518.10 -4304.21 3161.06 5941758.61 561960.71 MWD+IFR-AK-CAZ-SC 10500.29 90.37 178.03 3628.48 3518.78 -4400.94 3165.28 5941661.92 561965.68 MWD+IFR-AK-CAZ-SC 10596.66 88.89 177.42 3629.10 3519.40 -4497.23 3169.10 5941565.68 561970.26 MWD+IFR-AK-CAZ-SC 10694.13 89.81 181.98 3630.21 3520.51 -4594.66 3169.61 5941468.26 561971.53 MWD+IFR-AK-CAZ-SC 10790.59 90.00 184.09 3630.37 3520.67 -4690.98 3164.51 5941371.91. 561967.18 MWD+IFR-AK-CAZ-SC 10887.43 91.24 183.81 3629.32 3519.62 -4787.58 3157.84 5941275.27 561961.26 MWD+IFR-AK-CAZ-SC 10984.66 89.75 184.97 3628.48 3518.78 -4884.52 3150.39 5941178.28 561954.57 MWD+IFR-AK-CAZ-SC 11082.23 87.71 183.32 3630.64 3520.94 -4981.80 3143.34 5941080.96 561948.28 MWD+IFR-AK-CAZ-SC 11179.21 85.55 179.29 3636.34 3526.64 -5078.56 3141.14 5940984.19 561946.83 MWD+IFR-AK-CAZ-SC 11275.36 85.68 181.16 3643.70 3534.00 -5174.43 3140.76 5940888.34 561947.20 MWD+IFR-AK-CAZ-SC '~, 11372.27 88.89 182.75 3648.29 3538.59 -5271.16 3137.46 5940791.60 561944.65 MWD+IFR-AK-CAZ-SC 11468.94 89.51 181.03 3649.64 3539.94 -5367.76 3134.27 5940694.98 561942.22 MWD+IFR-AK-CAZ-SC 11565.95 88.58 177.31 3651.25 3541.55 -5464.73 3135.67 5940598.03 561944.38 MWD+IFR-AK-CAZ-SC 11661.86 90.37 174.44 3652.13 3542.43 -5560.37 3142.57 5940502.46 561952.03 MWD+IFR-AK-CAZ-SC 11759.38 90.56 176.16 3651.34 3541.64 -5657.56 3150.56 5940405.35 561960.77 MWD+IFR-AK-CAZ-SC 11855.21 88.08 178.94 3652.48 3542.78 -5753.28 3154.66 5940309.67 561965.62 MWD+IFR-AK-CAZ-SC 11952.71 89.14 179.04 3654.84 3545.14 -5850.73 3156.37 5940212.24 561968.09 MWD+IFR-AK-CAZ-SC 12046.87 90.31 179.43 3655.29 3545.59 -5944.88 3157.63 5940118.12 561970.09 MWD+IFR-AK-CAZ-SC 12144.52 91.17 180.42 3654.03 3544.33 -6042.52 3157.76 5940020.49 561970.98 MWD+IFR-AK-CAZ-SC ~i 12241.09 89.44 179.06 3653.52 3543.82 -6139.08 3158.20 5939923.94 561972.17 MWD+IFR-AK-CAZ-SC 12337.61 89.01 178.51 3654.83 3545.13 -6235.57 3160.24 5939827.48 561974.97 MWD+IFR-AK-CAZ-SC 12404.02 93.86 179.25 3653.16 3543.46 -6301.93 3161.54 5939761.15 561976.78 MWD+IFR-AK-CAZ-SC . 12444.70 93.86 179.25 3650.42 3540.72 -6342.51 3162.07 5939720.57 561977.63 PROJECTED to TD i Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . llate: 2!7/2007 Time: 15:41:40 Page: ' Field: Kuparuk River Unit Co -ordinate(NE} Reference: Well: 1 J-103, T rue North ' Site: Kuparuk 1J Pad Ve rtical (I'VD)Re ference: 1J-103L1PB1: 109.7 Well: 1J-103 Section (VS) Refer ence: Well (O.OON,O.OOE,180.OOAzi) Wcllpath: 1 J-103L1 P61 Survey Calcolatio u Method: Minimum Curvature Db: Oracle __ Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~WeII: 1J-103 Slot Name: '; Well Position: +N/-S 118.15 ft Northing: 5946037.60 ft Latitude: 70 15 47.420 N +E/-W -22.57 ft Easting : 558766.46 ft Longitude: 149 31 29.663 W Position Uncertainty: 0.00 ft ~ Wel-path: 1J-103L1PB1 Drilled From: 1J-103PB1 500292331873 Tie-on Depth: 6297.45 ft Current Datum: 1 J-103L1 PB1: Height 109.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/17/2006 Declination: 23.72 deg Field Strength: 57613 nT Mag Dip Angle: 80.81 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: 2/7/2007 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.70 632.70 1J-103P61 gyro (50. 70-632.70) CB-GYRO-SS Camera based gyro single shot ~ 662.65 6297.45 1J-103P61 (662.65- 8486.40) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6332.70 7239.99 1J-103L1P61 (6332. 70-7239.99) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC _~ Survey ___ _. J1D Inc! Azim '1'VD Sys TVD i~iS F:/W MapN MapE Taol ft deg deg ft ft ft ft ft ft i r I --- _ 28.00 0.00 0.00 28.00 __- -81.70 0.00 0.00 -- _ _ 5946037.60 558766.46 _ TIE LINE 50.70 0.25 249.97 50.70 -59.00 -0.02 -0.05 5946037.58 558766.41 CB-GYRO-SS 100.70 0.27 229.52 100.70 -9.00 -0.13 -0.24 5946037.47 558766.22 CB-GYRO-SS 172.70 0.12 359.52 172.70 63.00 -0.17 -0.37 5946037.43 558766.09 CB-GYRO-SS I 265.70 0.51 30.46 265.70 156.00 0.29 -0.16 5946037.89 558766.30 CB-GYRO-SS ' 356.70 2.11 37.81 356.67 246.97 1.96 1.07 5946039.57 558767.52 CB-GYRO-SS 449:70 4.85 40.20 449.49 339.79 6.32 4.66 5946043.95 558771.07 CB-GYRO-SS 540.70 7.05 40.78 539.99 430.29 13.49 10.79 5946051.17 558777.15 CB-GYRO-SS 632.70 9.14 41.61 631.07 521.37 23.22 19.33 5946060.97 558785.61 CB-GYRO-SS 662.65 9.64 37.87 660.62 550.92 26.98 22.45 5946064.75 558788.70 MWD+IFR-AK-CAZ-SC 755.80 13.09 36.17 751.93 642.23 41.66 33.47 5946079.52 558799.60 MWD+IFR-AK-CAZ-SC 859.30 14.13 35.32 852.52 742.82 61.43 47.69 5946099.39 558813.66 MWD+IFR-AK-CAZ-SC 910.08 14.02 34.53 901.78 792.08 71.55 54.76 5946109.57 558820.65 MWD+IFR-AK-CAZ-SC 955.52 15.61 32.52 945.71 836.01 81.24 61.17 5946119.31 558826.99 MWD+IFR-AK-CAZ-SC 997.70 16.81 30.35 986.21 876.51 91.29 67.30 5946129.41 558833.04 MWD+IFR-AK-CAZ-SC 1051.10 19.81 30.46 1036.90 927.20 105.76 75.79 5946143.94 558841.42 MWD+IFR-AK-CAZ-SC i ~ 1093.21 22.37 30.32 1076.19 966.49 118.83 83.45 5946157.07 558848.98 MWD+IFR-AK-CAZ-SC 1144.98 24.09 29.16 1123.76 1014.06 136.56 93.58 5946174.88 558858.96 MWD+IFR-AK-CAZ-SC 1239.84 26.42 29.85 1209.55 1099.85 171.78 113.52 5946210.24 558878.62 MWD+IFR-AK-CAZ-SC 1333.81 33.47 28.99 1290.92 1181.22 212.63 136.51 5946251.27 558901.29 MWD+IFR-AK-CAZ-SC 1429.22 39.14 28.54 1367.78 1258.08 262.13 163.67 5946300.98 558928.06 MWD+IFR-AK-CAZ-SC 1524.86 41.26 30.67 1440.83 1331.13 315.78 194.18 5946354.88 558958.15 MWD+IFR-AK-CAZ-SC 1620.64 45.44 30.58 1510.46 1400.76 372.35 227.67 5946411.68 558991.19 MWD+IFR-AK-CAZ-SC ~ 1715.23 50.93 33.01 1573.51 1463.81 432.20 264.85 5946471.82 559027.90 MWD+IFR-AK-CAZ-SC i 1757.67 51.38 32.66 1600.13 1490.43 459.98 282.77 5946499.73 559045.60 MWD+IFR-AK-CAZ-SC 1810.12 50.61 34.31 1633.14 1523.44 493.97 305.25 5946533.89 559067.82 MWD+IFR-AK-CAZ-SC 1847.57 50.10 34.66 1657.03 1547.33 517.74 321.58 5946557.78 559083.96 MWD+IFR-AK-CAZ-SC 1905.12 50.63 35.76 1693.74 1584.04 553.95 347.13 5946594.19 559109.23 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ __ _ Company: ConocoPhillips Alaska lnc. _ Date: Z/7/2007 Time: 15:41:40 Page: 2 Field: Kuparu kRive rUnit Co-or dinate(~E)Reference: We11:1J-10 3,T rueNorth Site: Ku paru k 1J Pad Vertical(1'V D) Reference: 1J-103L1PB1: 109.7 ' 1Nell: 1J -103 Section (VS}.Refer ence: Well(O.OON,O.OOE,180.OOAzi) Wellpath: 1J -103 L1PB1 SurveyCak ulationDlethod: MinlmumC urvature Db: Oracle __ S u ~-~~cv MD Inc l ~zim TVD Sys Tti'D N/S E/Vt" MapN J1apG Tool ft deg deg ft ft ft ft ft ft 1936 .93 51 .49 36. 82 1713. 74 1604. 04 573. 89 361. 78 5946614 .24 559123. 71 MWD+IFR-AK-CAZ-SC ~ 2000. 86 51. 87 39. 61 1753. 38 1643. 68 613. 29 392. 80 5946653. 88 559154. 43 MWD+IFR-AK-CAZ-SC 2093. 95 53. 72 45. 46 1809. 70 1700. 00 667. 85 442. 92 5946708. 82 559204. 11 MWD+IFR-AK-CAZ-SC 2191. 18 56. 62 51. 14 1865. 26 1755. 56 720. 85 502. 51 5946762. 28 559263. 28 MWD+IFR-AK-CAZ-SC 2284. 31 58. 44 55. 15 1915. 27 1805. 57 767. 94 565. 37 5946809. 85 559325. 77 MWD+IFR-AK-CAZ-SC 2380. 32 59. 72 60. 12 1964. 62 1854. 92 811. 99 634. 92 5946854. 44 559394. 97 MWD+IFR-AK-CAZ-SC 2419. 46 59. 50 61. 37 1984. 42 1874. 72 828. 48 664. 38 5946871. 16 559424. 29 MWD+IFR-AK-CAZ-SC 2475. 95 58. 92 62. 59 2013. 34 1903. 64 851. 28 707. 21 5946894. 29 559466. 94 MWD+IFR-AK-CAZ-SC 2571. 00 59. 73 61. 27 2061. 83 1952. 13 889. 75 779. 34 5946933. 32 559538. 76 MWD+IFR-AK-CAZ-SC 2611 .14 59 .76 60. 92 2082. 06 1972. 36 906. 51 809. 70 5946950. 32 559568. 98 MWD+IFR-AK-CAZ-SC 2666 .51 59. 94 60. 73 2109. 87 2000. 17 929. 85 851. 50 5946973. 98 559610. 60 MWD+IFR-AK-CAZ-SC 2695 .63 59 .05 61. 06 2124. 65 2014. 95 942. 06 873. 42 5946986. 35 559632. 42 MWD+IFR-AK-CAZ-SC 2761 .59 57 .83 60. 61 2159. 17 2049. 47 969. 44 922. 50 5947014. 12 559681. 28 MWD+IFR-AK-CAZ-SC 2828 .92 58 .92 61. 14 2194. 48 2084. 78 997. 35 972. 58 5947042. 41 559731. 14 MWD+IFR-AK-CAZ-SC 2857 .58 59 .64 60. 94 2209. 12 2099. 42 1009. 27 994. 14 5947054. 51 559752. 60 MWD+IFR-AK-CAZ-SC 2968 .32 59 .14 61. 42 2265. 51 2155. 81 1055. 22 1077. 64 5947101. 10 559835. 73 MWD+IFR-AK-CAZ-SC i 3038 .11 58 .93 61. 21 2301. 41 2191. 71 1083. 94 1130. 14 5947130. 23 559888. 00 MWD+IFR-AK-CAZ-SC 3064 .31 58 .53 60. 89 2315. 01 2205. 31 1094. 78 1149. 74 5947141. 22 559907. 51 MWD+IFR-AK-CAZ-SC 3159 .47 58 .15 61. 48 2364. 96 2255. 26 1133. 82 1220. 71 5947180. 81 559978. 16 MWD+IFR-AK-CAZ-SC 3253 .03 58 .77 61. 25 2413. 90 2304. 20 1172. 04 1290. 69 5947219 .56 560047. 84 MWD+IFR-AK-CAZ-SC 3349 .29 59 .73 61. 83 2463. 12 2353. 42 1211. 46 1363. 42 5947259 .54 560120. 25 MWD+IFR-AK-CAZ-SC 3443 .96 59 .44 65. 76 2511. 06 2401. 36 1247. 50 1436. 65 5947296 .16 560193. 19 MWD+IFR-AK-CAZ-SC 3537 .78 59 .12 70. 40 2559. 01 2449. 31 1277. 60 1511. 44 5947326 .84 560267 .73 MWD+IFR-AK-CAZ-SC 3633 .89 58 .32 74. 65 2608. 92 2499. 22 1302. 27 1589. 75 5947352 .12 560345. 85 MWD+IFR-AK-CAZ-SC 3728 .68 58 .19 80. 31 2658. 83 2549. 13 1319. 74 1668. 40 5947370 .19 560424 .34 MWD+IFR-AK-CAZ-SC 3822 .92 58 .63 85. 34 2708. 22 2598. 52 1329. 75 1748. 00 5947380 .83 560503. 86 MWD+IFR-AK-CAZ-SC 3920 .15 58 .75 90. 21 2758. 77 2649. 07 1332. 97 1830. 97 5947384 .69 560586 .80 MWD+IFR-AK-CAZ-SC 4016 .73 57 .89 96. 43 2809. 52 2699. 82 1328. 24 1912. 96 5947380 .60 560668 .81 MWD+IFR-AK-CAZ-SC 4109 .70 58 .93 105. 03 2858. 29 2748. 59 1313. 48 1990. 65 5947366 .45 560746 .61 MWD+IFR-AK-CAZ-SC 4205 .49 58 .97 109. 97 2907. 72 2798. 02 1288. 82 2068. 88 5947342 .40 560825 .02 MWD+IFR-AK-CAZ-SC 4302 .30 59 .16 115. 17 2957. 51 2847. 81 1256. 96 2145. 52 5947311 .14 560901 .90 MWD+IFR-AK-CAZ-SC ~ 4396 .10 58 .94 118. 87 3005. 76 2896. 06 1220. 43 2217. 16 5947275 .17 560973 .82 MWD+IFR-AK-CAZ-SC i 4489 .53 58 .62 122. 32 3054. 20 2944. 50 1179. 77 2285. 93 5947235 .06 561042 .89 MWD+IFR-AK-CAZ-SC ' 4586 .40 58 .36 128. 27 3104. 86 2995. 16 1132. 09 2353. 29 5947187 .91 561110 .61 MWD+IFR-AK-CAZ-SC 4680 .37 58 .90 131. 04 3153. 79 3044. 09 1080. 89 2415. 05 5947137 .20 561172 .77 MWD+IFR-AK-CAZ-SC i 4775 .85 61 .69 130. 15 3201. 10 3091. 40 1026. 94 2478. 02 5947083 .75 561236 .15 MWD+IFR-AK-CAZ-SC ' 4868 .62 62 .42 130. 01 3244. 57 3134. 87 974. 18 2540. 72 5947031 .48 561299 .26 MWD+IFR-AK-CAZ-SC 4966 .54 63 .06 130. 13 3289. 42 3179. 72 918. 14 2607. 34 5946975 .98 561366 .30 MWD+IFR-AK-CAZ-SC ~ 5060 .87 62 .79 132. 90 3332. 36 3222. 66 862. 48 2670. 22 5946920 .81 561429 .61 MWD+IFR-AK-CAZ-SC I 5156 .49 63 .60 136. 59 3375. 49 3265. 79 802. 41 2730. 81 5946861 .22 561490 .67 MWD+IFR-AK-CAZ-SC 5251 .33 64 .45 139. 73 3417. 04 3307. 34 738. 90 2787. 67 5946798 .16 561548 .01 MWD+IFR-AK-CAZ-SC 5346 .95 67 .81 145. 86 3455. 76 3346. 06 669. 27 2840. 45 5946728 .95 561601. 33 MWD+IFR-AK-CAZ-SC 5442 .23 69 .73 151. 57 3490. 28 3380. 58 593. 40 2886. 52 5946653 .45 561647 .99 MWD+IFR-AK-CAZ-SC 5537 .26 73 .47 156. 74 3520. 29 3410. 59 512. 27 2925. 77 5946572 .64 561687 .86 MWD+IFR-AK-CAZ-SC 5631 .47 77 .44 159. 97 3543. 95 3434. 25 427. 53 2959. 37 5946488 .18 561722 .12 MWD+IFR-AK-CAZ-SC 5693 .55 78 .30 162. 00 3557. 00 3447. 30 370. 16 2979. 15 5946430 .96 561742 .34 MWD+IFR-AK-CAZ-SC 5723 .72 78 .56 161. 64 3563. 05 3453. 35 342. 07 2988. 37 5946402 .95 561751 .78 MWD+IFR-AK-CAZ-SC 5820 .08 79 .35 163. 42 3581. 51 3471. 81 251. 87 3016. 76 5946312 .98 561780 .87 MWD+IFR-AK-CAZ-SC 5912 .60 79 .95 165. 42 3598. 14 3488. 44 164. 20 3041. 20 5946225 .51 561805 .99 MWD+IFR-AK-CAZ-SC 6010 ,65 80 .83 165. 32 3614. 51 3504. 81 70. 66 3065. 62 5946132 .18 561831 .14 MWD+IFR-AK-CAZ-SC I 6108 .38 78 .58 166. 72 3631 .97 3522. 27 -22. 64 3088. 85 5946039 .07 561855 .09 MWD+IFR-AK-CAZ-SC I 6200 .88 80 .95 169. 74 3648 .41 3538. 71 -111. 74 3107. 40 5945950 .13 561874 .34 MWD+IFR-AK-CAZ-SC ': Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J=103 Wellpath: 1 ;-103L1 PB1 Sun~cv __ __ Date: 21712007 Time: 15:41:40 Page: 3 Co-ordinate(NE)Reference: Well: 1J-103, True North Vcrtical(T~'D}Reference: 1J-103L1PB1: 109.7 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle ___ - - -_ MD lncl Azim TVD Sys TVD N/S ft deg deg ft ft ft 6297.45 82.26 173.71 3662.51 3552.81 -206.26 6332.70 81.91 175.52 3667.37 3557.67 -241.01 6402.41 87.03 179.46 3674.09 3564.39 -310.30 6452.99 86.35 182.30 3677.01 3567.31 -360.78 6495.66 87.77 184.69 3679.20 3569.50 -403.31 6543.16 91.16 184.49 3679.64 3569.94 -450.65 6588.92 94.26 184.36 3677.48 3567.78 -496.22 6622.32 94.32 184.68 3674.98 3565.28 -529.42 6682.92 92.71 184.90 3671.26 3561.56 -589.69 6733.47 93.77 184.86 3668.41 3558.71 -639.98 6775.37 94.51 183.01 3665.38 3555.68 -681.67 6822.59 95.19 182.62 3661.39 3551.69 -728.66 6868.16 94.13 181.00 3657.69 3547.99 -774.06 6914.50 93.95 178.47 3654.42 3544.72 -820.28 6961.81 92.89 175.62 3651.60 3541.90 -867.43 i 7005.19 94.26 175.10 3648.89 3539.19 -910.59 7053.22 93.27 173.21 3645.74 3536.04 -958.26 7101.50 93.77 173.09 3642.77 3533.07 -1006.11 7146.51 91.72 174.55 3640.62 3530.92 -1050.80 7196.36 89.31 175.71 3640.17 3530.47 -1100.46 7239.99 89.19 177.15 3640.74 3531.04 -1144.00 7295.70 89.19 177.15 3641.53 3531.83 -1199.64 E/W __ 11apN ___ MapE _ - 'fool ft ft ft 3121.14 5945855.73 561888.82 MWD+IFR-AK-CAZ-SC 3124.42 5945821.00 561892.37 MWD+IFR-AK-CAZ-SC 3127.45 5945751.75 561895.93 MWD+IFR-AK-CAZ-SC 3126.67 5945701.27 561895.55 MWD+IFR-AK-CAZ-SC 3124.07 5945658.72 561893.29 MWD+IFR-AK-CAZ-SC 3120.27 5945611.36 561889.86 MWD+IFR-AK-CAZ-SC 3116.75 5945565.77 561886.69 MWD+IFR-AK-CAZ-SC 3114.12 5945532.55 561884.32 MWD+IFR-AK-CAZ-SC 3109.07 5945472.25 561879.74 MWD+IFR-AK-CAZ-SC 3104.78 5945421.93 561875.84 MWD+IFR-AK-CAZ-SC 3101.91 5945380.23 561873.30 MWD+IFR-AK-CAZ-SC 3099.60 5945333.22 561871.35 MWD+IFR-AK-CAZ-SC 3098.17 5945287.82 561870.28 MWD+IFR-AK-CAZ-SC 3098.38 5945241.61 561870.85 MWD+IFR-AK-CAZ-SC 3100.82 5945194.47 561873.65 MWD+IFR-AK-CAZ-SC 3104.32 5945151.35 561877.49 MWD+IFR-AK-CAZ-SC 3109.20 5945103.72 561882.74 MWD+IFR-AK-CAZ-SC 3114.95 5945055.93 561888.86 MWD+IFR-AK-CAZ-SC 3119.78 5945011.28 561894.05 MWD+IFR-AK-CAZ-SC 3124.02 5944961.66 561898.67 MWD+IFR-AK-CAZ-SC 3126.73 5944918.14 561901.72 MWD+IFR-AK-CAZ-SC 3129.50 5944862.54 561904.93 PROJECTED to TD Time LocJs - __ Data From To Dur S _ D_ Fph_ E. Depth__Phase Coda Subcode T COM 12/28/2006 21:45 22:45 1.00 0 0 PROD1 CASIN( RURD P ' RU casing tools for 4-1/2" liner. 22:45 00:00 1.25 0 4,640 PROD1 CASIN ( RNCS P PJSM. run 4-1/2';.11.6 Ib/ft, L-80, BTG slotted liner. 12/29/2006 00:00 03:00 3.00 5,808 11,260 COMPZ CASIN( RUNL P Continue Tripping in hole w/ 4-1/2" slotted liner from 5808' to 11,260' 03:00 04:30 .1.50 11,260 6,425 COMPZ CASIN( OTHR P Drop 29/32" setting ball and pump down. Would not seat. Drop 1-3/4" setting ball and pump down same. Set liner hanger and ZXP packer. Top of Liner 6425' 04:30 05:00 0.50 6,425 6,425 COMPZ CASIN( OTHR P Test ZXP and annulus to 2500 psi for 15 minutes on chart 05:00 09:00 4.00 6,425 0 COMPZ CASIN( OTHR P Monitor well, blowdown top drive. POOH. 09:00 .10:00 1.00 0 0 COMPZ CASIN( OTHR P Break and laydown liner running tools. Clean floor and- monitor well 10:00 10:15 0.25 0 0 COMPZ WELCT SFTY P PJSM on testing BOPE (High ressures and hazard reco nition 10:15 14:15 4.00 0 0 COMPZ WELCT BOPE P Test BOPE to 250psi low and 3000 psi high. Test accumulator. Chuck Scheve, AOGCC, waived witnessing the test. Pull test plug and set wear rin .Test as alarms 14:15 14:45 0.50 0 0 COMPZ WELCT OTHR P Blow down Choke manifold and choke/kill lines 14:45 16:00 1.25 0 378 PROD2 STK PULD P P/U mill and whipstock assembly. Orient and P/U MWD 16:00 16:45 0.75 378 378 PROD2 STK OTHR P Upload MWD 16:45 17:15 0.50, 378 378 PROD2 STK PULD P P/U bumpers and RIH w/ 3 stands of Hybrid dc's and shallow pulse test. Blow down to drive 17:15 19:30 225 378 5,373 PROD2 DRILL TRIP P RIH with whipstock/mill assembly (Fill drillpipe @ 3262' and beak circulation " 5322' 19:30 20:00 0.50 5,373 5,412 PROD2 DRILL OTHR P Make. mad pass from 5373' to 5412' (sensor depth 5210' to 5300') and orient 15 de .left. 20:00 21:15 .1.25 5,412 6,348. PROD2 DRILL KOST P Continue RIH: Break circ @ 6348' (PU = 110k and S/O = 64k) Wash and tag no go @ 6429' MD and stack 20k to set trip anchor. Pull 10 k to verify. Shear off whipstock (oriented 18 de left of hi h side . 21:15 22:15 1.00 6,348 6,348 PROD2 DRILL CIRC P Circulate and displace SFOBM with 8.35 MOBM 22:15 00:00 1.75 6,332 6,338 PROD2 DRILL KOST P Mill window from 6332' to 6338' 12/30/2006 00:00 03:00 3.00 6,338 6,370 PROD2 DRILL KOST P Continue to mill 'B` Lat window from 6338' to 6370' Have 15' of gauge hole. TOW= 6332' BOW = 6345' 03:00 04:00 1.00 6,370 6,370 PROD2 DRILL KOST P . Dress window 04:00 06:45 2.75 6,370 98 PROD2 DRILL TRIP P Monitor well and pump slug. POOH to 98' - -- ~- -- -- --- - ~~F`t~ ~€v Or 3 ~~ ;~07 Time Logs Date From To Dur_ S_ Depth E 17~~th~ Ph~,e Coe;e SuCcode T COM 12/30/2006 06:45 07:00 0.25 98 98 PROD2 DRILL PULD P Down load MWD 07:00 08:00 1.00 98 0 PROD2 DRILL PULD P L/D BHA, XO, Bowen BS, float sub, TM collar, MWD HOC and mills 08:00 09:15 1.25 0 0 PROD2 DRILL OTHR P Pull wear ring and flush BOP stack. Set wear rin 09:15 10:15 1.00 0 125 PROD2 DRILL PULD. P M/U bit, Geo-pilot and MWD equip 10:15 11:30 1.25 125 125 PROD2 DRILL PULD P Upload MWD 11:30 12:45 1.25 125 383 PROD2 DRILL PULD P Continue P/U BHA 12:45 14:30 1.75 383 6,312 PROD2 DRILL .TRIP P RIH-fill drillpipe @ 3640 and break circulation @ 6256'. P/U = 100k, S/O=73k, rot=86k, Torque = 5-6k, Clean hole ECD= 9.34 14:30 15:00 0.50 6,312 6,370 PROD2 DRILL REAM P Check ABI and slide w/o pump from 6312 to 6358' From from 6358' to 6370' 15:00 00:00 9.00 6,370 . 7,005. PROD2 DRILL DDRL P Drill 6.75" hole from 6370'to 7005; TVD=3469', ADT=5.12. P/U=108k, so=65k, Rot=85k, Torque on/off=6k, ECD's=9.59 12/31/2006 00:00 06:30 6.50 7,005 7,295 PROD2 DRILL DDRL P Drill from 7005' to 7295' TVD = 3641' ART = 4.18 hours 06:30 07:00 0.5Q 7,295 7,185 PROD2 DRILL TRIP NP Stand back one stand and wait while geologists review sever dogleg caused b concretion 07:00 09:45 2.75 7,185 7,295 PROD2 DRILL KOST NP Cut trough from 7185' to 7215' brill. to 7295' ART= 1.3 09:45 12:00 2.25 7,295 7,373 PROD2 DRILL DDRL P Drill from 7295' to 7373' ND = 3631' ART =1.46 12:00 12:15 0.25 7,373 7,373 PROD2 DRILL SFTY P PJSM on making connections. 12:15 00:00 11.75 7,373 8,196 PROD2 DRILL DDRL P Drill from 7295' to 8196' TVD = 3627' ADT = 7.19 (Pumped hi vis/wt sweep @ 8050' Cuttings load increased by 10% 01/01/2007 00:00 12:00 12.00 8,196 8,851 PROD2 DRILL DDRL P Drill from 8196' to 8851' T~/D =3626' ART = 8.81 12:00 12:15 0.25 8,851 8,851 PRODZ DRILL SFTY P PJSM on drilling ahead and making connection including hazard reco nition 12:15 00:00 11.75 8,851 9,862 PROD2 DRILL DDRL P Drill from 8851' to 9862' TVD = 3624' ART = 8.11 01/02/2007 00:00 12:00 12.00 9,862 11,000 PROD2 DRILL DDRL P Directionally drilled 6 3/4"hole in "B" . sand lateral with Geopilot from 9,862' to 11,000' MD/ 3,624' TVD (1,138') ADT 8.58 hrs, drilled thru 8 concretions for 70'. 8.4 ppg MOBM, ave ECD 10.6 ppg, ave. BGG 75 units max as 256 units. Time Log s Date 01/02/200 From 7 12:00 To _--- 00:00 Dur 12.00 S De th 11,000 E. Death 12,030 .Phase _ PROD2 __ Code DRILL Subcode DDRL T P (0~~1 Drilled 6 3/4" hole in "B" sand lateral with Geopilot from 11,000' to 12,030' MD/ 3,654' ND (1,030') ADT 7.8 hrs, drilled thru 7 concretions for 50'. 8.4 ppg MOBM, ave ECD 11.3 ppg, ave BGG 65 units, max gas 181 units. Pumped 30 bbl wYd hi vis sweep at 11,500' and had a 10% increase in .cuttings, crossed fault at 11,450' and. drillin thru "C" shale at 12,030'. 01/03/2007 00:00 06:30 6.50 12,030 12,444 PROD2 DRILL DDRL P Drilled 6 3/4" hole in "B" sand lateral with Geopilot from 12,030' to 12,444' MD/ 3,649' ND {414') ADT 5.14 hrs, lateral T.D., 8.4 ppg MOBM, ave ECD 11.3 ppg, ave BGG 50 units, max gas 103 units. cont drilling thru "C"shale from 12,030' to 12,040', while drlg "B" sand formatiion was wet after crossing fault. 06:30 06:45 0.25 12,444 12,444 PROD2 DRILL OWFF P Monitored well-static, took SPR's and attem ted to sunre with no res onse 06:45 15:00 8.25 12,444 6,256 PROD2 DRILL REAM P Backreamed out of hole from 12,444' to 6,256', BROOH at 110 rpm's, 310 gpm, ICP 3,200 psi, FCP 2,200 psi, BROOH to 6,629' then pulled thru window to 6,256', no problems BROOH 15:00 17:30 2.50 6,256 6,443 PROD2 DRILL CIRC P Circ btms up at 6,256' at 310 gpm at 2,200 psi, dropped ball to open circ sub and washed down to 6,443' positioning circ sub at 6,241', pumped down at 2 bpm at 380 psi, with ball on seat pressured up to 4,200 psi and could not get ball to shear, unable to pump thru tool or reverse circ due to float in strip ,monitored well-static 17:30 20:30 3.00 6,443 200. PROD2 DRILL TRIP T POOH wet from 6,443' to 200' standin back HWDP and 'ars 20:30 22:00 1.50 200 100 PROD2 DRILL OTHR T LD circ sub and ball was on seat with no visible problem, shallow tested MWD tool and had no pulse, flushed thru tools and stood back NMFDC's 22:00 00:00 2.00 100 0 PROD2 DRILL PULD P Down loaded MWD and began to LD BHA #7 01/04/2007 00:00 01:00 1.00 0 0 PROD2 DRILL PULD P Fin POOH wet and LD BHA #7 then cleaned the ri floor 01:00 01:30 0.50 0 276 PROD2 DRILL PULD T MU clean out BHA #8 and RIH to 276' 01:30 05:30 4.00 276 6,332 PROD2 DRILL TRIP T RIH with BHA #8 from 276' to window at 6,332' 05:30 06:30 1.00 6,332 9,566 PROD2 DRILL TRIP P RIH from 6,332' thru the window to 9,1.85' and set down, washed thru and cont. RIH to 9,566' when we lost down wt Time Logs ~, O~te From_ To Dur S D:pth_E Depth Phase ;ode Subca~ie T COM -------- 01/04/2007 06:30 08:45 2.25 9,566 11,600 PROD2 DRILL TRIP P Washed downfrom9,566'to 11,600',. (liner setting depth), washed down at 200 gpm 1,150 psi and 100 rpm's with no roblems 08:45 11:15 2.50 11,600 11,600 PROD2 DRILL CIRC P Pumped 30 bbl wt'd hi vis sweep (2# over MW) and circ hole clean, had 10% increase in cuttings back from sweep and circ an add. 2X btms up and was clean at the shakers, circ hole at 88 spm, 310 gpm, 2,300 psi, 12b rpm's and 6K ft-Ibs of off btm torque 11:15 12:30 1.25 11,600 11,600 PROD2 DRILL CIRC P Displaced hole over from 8.4 ppg MOBM to 8.4 ppg SFMOBM, monitored well-static. 12:30 17:15 4.75. 11,600 0 PROD2 DRILL TRIP P POOH wet with BHA #8 from 11,600' and stood back HWDP, jars and NMFDC's, l_D bit sub and bit, cleaned ri floor 17:15 18:30 1.25 0 0 COMPZ RIGMN SVRG P Held PJSM, slip and cut 68' of drlg line then serviced to drive 18:30 19:00 0.50 0 329 COMPZ FISH PULD P MU fishing BHA #9 to retrieve whi 'stock RIH to 329' 19:00 20:00 1.00 329 3,125 COMPZ FISH TRIP P RFH from 329' to 3,125' and while attempting to fill pipe it pressured up to 1,000 psi and wouldn't bleed off, thou ht float was u side down . 20:00 21:30 1.50 3,125 3,125 COMPZ FISH TRIP NP POOH from 3,125' to 1;725' and was able to est circ at 4 bpm at 400 psi, RIH to 3,125' and was able to circ at 4 bpm at 400 psi, (possibly had ice plug in 'ars). 21:30 22:15 0.75 3,125 6,297 COMPZ FISH TRIP P Cont to RIH from 3,125' to 6,297, st wt up 105K, do wt 70K, est circ at 4 bpm at 500 si 22:15 23:00 0.75 6,297. 6,337 COMPZ FISH FISH P RIH and hooked whipstock on 3rd attempt, worked st wt up to 85K over (190K) with no movement, jarred on whipstock working up to 85K over st wt and whipstock came free on 6th hit. Hole took approx 2 bbls then monitored well and well was static, had 4K increase in st wt with 5-10K add. dra . 23:00. 00:00 1.00 6,337 6,017 COMPZ FISH TRIP P POOH from 6,33T to 6,019' 01/05/2007 00:00 02:45 2.75 6,017 59 PROD2 FISH TRIP P Cont. POOH with whipstock assembly. from 6,01 T to 59' 02:45 04:15 1.50 59 0 PROD2 FISH PULD P POOH from 59' LD fishing BHA #9, whipstock, space out jts and seal assembl ,cleared ri floor 04:15 04:45 0.50 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner 04:45 05:00 0.25 0 0 COMPZ CASINC SFTY P Held PJSM on running 4 1/2" Gner and associated hazards ~ __~ ~_ ~ t7 _~ Time Logs _ Date Fro~~ To Dur _ S,_D epth_ E D~~th_P'~ase Code Subco~e T COM _ 01/05/2007 05:00 09:00 4.00 0 5,226 COMPZ CASIN( PUTB P PU and RIH with 4 1/2" liner to 5,226', MU 3 1/2" bentjt with welded btm, 2-swell packers , 12 blank jts and 110 jts of slotted liner per well plan, ran 1 Hydraform cent. on stop ring perjt (122 total). 09:00 09:45 0.75 5,226 5,263 COMPZ CASIN( PUTB P PU Baker Hook Hanger assembly and MU slimhole MWD, oriented same, st wt u 75K, do wt 65K 09:45 10:15 0.50 5,263 5,263 COMPZ CASIN( KURD P RD liner running tools and repositioned 3 stds DP in the derrick 10:15 15:45 5.50 5,263 11,584 COMPZ CASIN( RUNL P RIH with 4.1/2" liner on 4" DP from 5,263' to 11,584', went thru window on 3rd try, cont to RIH and sat down at 10,428' and worked tight to 10,519',. RIH and sat down again at 11,336' worked liner down to 11,584' (setting de th), st wt up 180K, do wt 65K 15:45. 19:30 3.75 11,584 6,254 COMPZ CASINC OTHR P . Worked liner and hooked same, hooked and unhooked liner 6 times to verify on depth setting 30K wt do last time, verified with MWD while working hook. dropped ball and pressured up to 3,200 psi to release from hanger, attempted to blow ball seat pressuring up to 4,300psi with no success, POOH 1 std to 6,254', st wt up 145K, RU test pump and press. up to 4,500 psi and blew ball seat. Set top of hook hanger at 6,328' with end of liner at 11,584'. 19:30 21:15 1.75 6,254 6,254 COMPZ RIGMN RGRP T Replaced water spear, seals and bearing on Emalgco Dyna-Matic brake on drawworks 21:.15 00:00 2.75 6,254 1,933 COMPZ CASINC RUNL P POOH with Baker running tool from 6,254'to 1,933' 01/06/2007 00:00 01:15 1.25 1,933 0 COMPZ CASINC RUNL P POOH from 1,933' and LD Baker liner runnin tool and cleared ri floor. 01:15 01:45 0.50 0 0 COMPZ RPCOh RURD P RU to run LEM and held PJSM 01:45 04:00 2.25 0 393 COMPZ RPCOh PULD P MU "B" sand LEM assembly with MWD, RIH with 4 1/2" bentjt with seals, 1-jt 4 1/2" tbg, DB-6 nipple 1, jt tbg, 1-pup jt, LEM assembly with 6 jts of 4 1/2", 12.6#, L-80 IBTM tbg, CSBR and ZXP pkr RIH to 393', st wt up and do 42K 04:00 07:30 3.50 393 6,424 COMPZ RPCOh TRIP P RIH with LEM to 490` and shallow tested MWD, cont to RIH and sat down at 6,424', st wt up 137K, do wt 95K: Top of hook is at 6,328' with Bbtm of window at 6,345', DB nipple settin down at the btm of window. - - - - --- Tirne l_oy s D~'.e From To Dar S. De th E Depth Phase Code Suk,cud a T r'Oti1 01/06/2007 07:30 13:30' 6.00 6,424 6,088 COMPZ RPCOh _ __ OTHR _ _ P Attempted to work LEM up and would hang up, pulled and rotated into BOW with DB nipple and was able to PU thu, est circ at 130 gpm at 900 psi and worked LEM. down, oriented to 162 deg rt. of high side and RIH locating seals in "A" lat CSR, latched. LEM & unlatched to verify orientation and ck'd ok, dropped 1 3/4" ball and pumped down to seat, pressured up to 2,500 psi to set ZXP packer, pressured up to 4,200 psi to release from LEM, st wt up 130K, do wt 70K, set to of ZXP acker at 6,088' 13:30 -14:00 0.50 6,088 6,088 COMPZ RPCOh DHEQ P Pressure tested ZXP pkr and annulus to 2,500 psi for 10 min, good test and charted same 14:00 18:30 4.50 6,088 0 COMPZ RPCOh TRIP P PU to 130k and was released from LEM, POOH from 6,088' and LD Baker running tool, cleared and cleaned rig. floor 18:30 19:15 0.75 0 0 COMPZ DRILL OTHR P RIH with 3 stds of 4" DP with super sliders and inspected same and checked ok. NOTE: Decision was made to run LEM diverter tool to ensure LEM and hook alignment, called out for tools. 19:15 21:15 2.00 0 0 COMPZ RIGMN SVRG P Inspected saver sub and ck'd ok, serviced to drive. 21:15 23:00 1.75 0 0 COMPZ RPCOA OTHR T Brought 2 1/16" handling tools to rig floor while W:O. tools, cont to clean ri floor. 23:00 00:00 1.00 0 0 COMPZ RPCOh OTHR T Offloaded 2 1/16" tbg, diverter and subs and stra ed same. 01/07/2007 00:00 01:00 1.00 0 0 COMPZ RPCO(V RURD T RU tongs and rig floor for 2 1/16" CS H dril tb 01:00 03:30 2.50 0 333 COMPZ RPCOh PULD T MU #1 LEM Diverter (18' long) with XO's on 10 jts of 2 1/16" CS hydril tbg, um out sub XO to 4" DP RIH to 333' 03:.30 06:15 2.75 333 6,088 COMPZ RPCOh TRIP T RIH from 333' with LEM diverter to top of "B" lat ZXP packer at 6,088', st wt u 125K, do wt 9K 06:15 07:00 0.75 6,088 6,333 COMPZ RPCOh OTHR T RIH thru ZXP packer with diverter and tagged up in LEM at 6,333', st wt up 130K, do wt 98K set down 10K wt then snapped. in and out 3X to verify alignment, est circ at 3 1/2 bpm at 1,800 psi with 7K wt do on diverter to relase from GS spear, PU and saw no sna ,top of diverter at 6,315'. 07:00 07:15 0.25 6,333 6,315 COMPZ RPCOh OWFF T Monitored well-static, blew down-top drive 07:15 07:30 0.25 6,315 6,130 COMPZ RPCOh TRIP.. T POOH from 6,315' to 6,130' 07:30 12:00 4.50 6,130 6,130 COMPZ RIGMN RGRP T Changed out electrical service loop on top drive, changed out due to short in service loo . - ~_ ~ e~ - I~ a c3 . 'I ~ of :$ i I~ Tigie Logs -- Date _ _ From To Dur S Dep!h _ E Death Phase Coda tiuhcoda T COIv~ _ __ _ - j 01/07/2007 12:00 15:30 3.50 6,130 0 COMPZ RPCOA TRIP T Cont to POOH from 6,130' and LD 2 1/16" CS hydril tbg and GS running tool, cleared rig floor. calc fill on trip out 45 bbls, actual fill 51 bbls with 8.4 pp SFMOBM in the hole: 15:30 17:30 2.00 0 3,715 COMPZ RPCOti TRIP T MU 3" OD LEM drift on 11 jts of 2 1/16" CS h dril tb and RIM to 3,715'. 17:30 18:30 1.00 3,715 3,715 COMPZ RIGMN RGRP T Repositioned and re-tied D-rings on top drive service loop. 18:30 19:15 0.75 3,715 6,088 COMPZ RPCOh TRIP T RIH with 3"drift from 3,715' to top of ZXP acker at 6,088'. ' 19:15 21:00 1.75 6,088 6,324 COMPZ RPCOh OTHR T RIH from 6,088' and set down at 6,324', st wt up 133K, do wt 96K, top of diverter is at 6,315' and btm at 6,333', PU and est circ at 120 gpm at 600 psi and attempted to work drift down and cont. to set down at 6,324`, set down with 10K st wt, incresed pump rate to 260 gpm at 2,000 psi and with 10K do still wouldn't go deeper, PU to above diverter top and rotated drift 1/2 & 1/4 rounds and still wouldn't go thru LEM, dropped dart and um ed down too en ciresub. 21:00 21:15 0.25 6,324 6,324 COMPZ RPCOh OWFF T Monitored well-static, blew down top drive 21:15 00:00 2.75 6,324 1,503 COMPZ RPCOh TRIP T POOH with 3" drift from 6,324' to 1, 503' 01/08/2007 00:00 01:00 1.00 1,503 0 COMPZ RPCOh TRIP T Fin POOH and LD 2 1/16" tbg and 3" drift. 01:00 05:15 4.25 0 6,324 COMPZ RPCOti TRIP T MU 2.5" x 2.89" tapered drift and RIH on 11 jts of 2 1/16" CS hydril tbg and 4" DP, set down at 6,324', st wt up 130K, drt wt 96K 05:15 07:00 1.75 6,324 6,331 COMPZ RPCOh OTHR T Est circ at 6,324' at 125 gpm at 900 psi, worked tapered drift down from 6,324' to 6,331' (T) and was unable to go deeper, set down 40K wt and increased pump rate to 190 gpm at 4,800 psi and no change, no pump and no change, dropped ball and o ened ciresub. 07:00 07:15 0.25 6,331 6,331 COMPZ RPCOh OWFF T Monitored well-static, blew down top drive. 07:15 12:00 4.75 6,331 0 COMPZ RPCOh TRIP T POOH from 6,331' and LD CS hyd. tbg and tapered drift, found 2.89 cent. portion of drift scarred up and had 1 small piece of rubber stuck in water course, cleraed ri floor. 12:00 14:30 2.50 0 6,315. COMPZ RPCOh TRIP T MU LEM diverter GS retrieving tool and RIH on CS hyd. tbg and DP to 6,315', st wt u 125K, do wt 93K i__.-__-- _ -. -__ ~ ~ Time Logs D eta From 1-o Dur S. Depth E Depth Phase c ~~ie S~h~~che T CAM _ __ 01/08/2007 14:30 15:15 0.75 6,315 6,333 COMPZ RPCOh OTHR T Est circ at 80 gpm at 600 psi and set wt down on diverter at 6,315', stop circ and PU 20K over and diverter came free, PU 17' to conn. and dropped ball, RIH and sat back down on diverter and circ ball down and opened circ sub, shut do pump and PU taking 10K over st wt to ull diverter free. 15:15 15:30 0.25 6,333 6,333 COMPZ RPCOh OWFF T Monitored well -static, blew down top drive. 15:30 20:15 4.75 6,333 0 COMPZ RPCOh TRIP T POOH from 6,333' with LEM diverter, LD CS hyd. tbg and diverter, found welds on diverter broken and appears tapered drift was wedged in the slide: of the diverter, cleared ri floor. 20:15 21:30 .1.25 0 0 COMPZ RIGMN SVRG P Held PJSM, slipped and cut 65' of drlg line and serviced top drive. 21:30 22:15 0.75 0 0 COMPZ RPCOh RURD T PU Baker tools to rig floor an offloaded and stra ed 20 ~ts of 2 7/8" PAC DP 22:15 00:00 1.75 0 435 COMPZ RPCOh PULD T MU 3 1/2" concave mill on 2 7/8" PAC DP RIH to 435 ; PU mill, 2 jts PAC DP, 3 5/8" string stabilizer and 12 jts of 27/8" x 1" PAC DP (string stab 63' back from the mill 01/09/2007 00:00 02:00 2.00 435 6,270 COMPZ RPCOh TRIP T Fin MU BHA.#14 and RIH to 6,270', st wt u 128K, do wt 87K 02:00 02:15. 0.25 6,270 6,329 COMPZ RPCOR TRIP T Est circ at 250 gpm at 1700 psi, 25 rpm's at 6K ft-Ibs torque, rot wt 109K, up wt 130K, do wt 86K, RIH from 6,270' and set down at 6,329' with 5K wt dn. PU 10' 02:15 03:00 0.75 6,329 6,329 COMPZ RPCOR CIRC T Displaced hole over from 8.4 ppg SFMOBM to 8.4 ppg MOBM, circ hole at 250 mat 2,100 si 03:00 07:15 4.25 6,329 6,454 COMPZ RPCOti OTHR T Worked 3 1/2" mill thru LEM from 6,329' to 6,454'. with 3 5/8" stabilizer tagging up on DB nipple at 6,391', ave 24K wt, 70 rpm's, 4-6K ft-Ibs torque, circ at 69 spm, 250 gpm at 1,950 psi, while wo~kingmill would PU and RIH w/no rotation and would set down 5K wt at 6,333' then go thru setting 15K do at 6,339', was able to set wt do at 6,339' and 1-2 turns would rotate off, worked mill thru 6,330 to 6,359' for 30 min with no change, cont. to RIH, was able to RIH while circ & no rot. from 6,359' to top of DB nipple at 6,391', started to rotaed do working stabilizer 64' back from bit, rotated do to top of DB ni le with no roblems. i ~g~~`t~~t37 ~ ~ Time Log s _ - - __ _-, Date. 01/09/200 From To Dur S De~th 7 07:15 08:00 0.75 6,454 I _ , ,, E. D~-~th FI Lodi bubco~ie T COP:1 _ ___ 6,454 COMPZ RPCOh CIRC T Circ btms up at 6,454' while working 3 5/8" stabilizer thru LEM, Circ at 250 gpm, 1,950 psi, with pump off worked stab. thru LEM 2X with 2-4K drag do and did not stack out. Monitored shakers while circand working mills and did not see any rubber or pieces of metal come over. 08:00 08:15 0.25 6,454 6,454 COMPZ RPCOh OWFF T Monitored well-static, blew down top drive 08:15 13:30 5.25 6,454 0 COMPZ RPCOh TRIP T POOH from 6,454' and LD 14 jts of 2 7/8" PAC DP, 2-boot baskets (no recovery), 3 5/8" stab. in gauge and 3 1/2" concave mill was rounded and worn to 3.3/8". Appeared to be milling on LEM. 13:30 14:30 1.00 0 85 COMPZ RPCOh TRIP T Began to MU BHA #15 with LEM diverter RIH to 85', MU diverter, xo's and 2-'ts of 2 1/16" CS h d. tbh 14:30 16:15 1.75 85 85 COMPZ RPCOh OTHR NP Stood by due to insufficient hi line power, rig went on 1 motor while working on generator at CPF 1, serviced to drive. 16:15 19:00 2.75 85 6,315 COMPZ RPCOh TRIP T Fin MU BHA #15 and RIH to 6,315', st wt u 130K, do wt 98K 19:00 21:45 2.75 6,315 6,337 COMPZ RPCOh OTHR T RIH with diverter from 6,315' and set do at 6,333' with 5K wt dn, PU 10K over to pull free, RIH -and sat do at 6,335' with 5K dn, PU 10K over, then RIH setting 7K do at 6,336', PU 10-12K over, RIH setting 10K wt do to 6,337, took 10-12K over to pull free, decision was made to POOH and mill over packer, with wt do on diverter, pumped down ball and sheared circ sub. 21:45 22:00. 0.25 6,337 6,337 COMPZ RPCOh OWFF T Monitored well-static, blew down top drive 22:00 00:00 2.00 6,337 4,587 COMPZ RPCOR TRIP T POOH with diverter from 6,337 to 4,587, repositioning sliders down 2' while POOH 01/10/2007 00:00 04:30 4.50 4,587 333 COMPZ RPCOh TRIP T Cont. to POOH f/ 4587 to 333' relocating WWT S51 space (2' ) down. The old spacing had 2 laterals drillin time on them. 04:30 06:00 1.50 333 0 COMPZ RPCOh PULD T POOH LD BHA #15 LD LEM diverter, no si nificant mark's on diverter. 06:00 06:30 0.50 0 0 COMPZ WELCT BOPE P Pulled wear bushing 3?~~~ '? sa6 3 i ~ ~ ~ Time Log s D~aa From To Dur S D~pih E Depth _ Nh~„e _ Coda Subcode T LOP~~I 01/10/200 7 06:30 10:45 4.25 0 0 COMPZ WELC 7 BOPE P RU and tested all BOPE, floor valves and choke valves to 250 psi Lo / 3000 psi Hi w/ 4" test jt except lower pipe rams (4.5" rams). Test. lower rams. using 4.5" testjt .All equip tested good - No Leaks - Acc Test - Int 3000 psi, After close 1800 psi, 200 psi build 40 sec, Full build 3 min 20 sec, Spare bottles Av 2200 psi. NOTE: JohrrCrisp W/AOGCC waived witnessing of the test 10:45 11:15 0.50 0 0 COMPZ FISH PULD T Installed. wear bushing 11:15 12:45 1.50. 0 314 COMPZ FISH PULD T MU fishing BHA #16 RIH to 314', MU tie-back spear, bumper and oil jars, 3-stds hybrid push pipe and accelerator ~ars. 12:45 14:45 2.00 314 6,023 COMPZ FISH TRIP T RIH from 314' to 6,023', (top of ZXP pkr @ 6,088') rot wt 105K, up wt 125K, do wt 93K, 10 r m's, 4-5K ft-Ibs for ue. 14:45 15:15 0.50 6,023 6,090 COMPZ FISH FISH T RIH to 6,090' and latched into tie-back. sleeve, rotated 16 turns to the left, PU 1 OK over st wt and saw sleeve pull out of mandrel 15:15 15:30 0.25 6,090 6,090 COMPZ FISH OTHR T Monitored well- static 15:30 17:30 2.00 6,090 314 COMPZ FISH TRIP T POOH from 6,090' to BHA at 314' 17:30 18:45 1.25 314 0 COMPZ FISH PULD T POOH from 314', LD acceleratorjars, stood back hybrid push, LD spear and tie-back sleeve. 13.06' 18:45 19:30 0.75 0 318 COMPZ FISH PULD T MU milling BHA #17 RIH to 318', MU 6 3/4" x 5 3/8"shoe with 12' of extensions, washover ext. boot basket, 2-boot baskets,. oil and bumperjars and 3-stds of hybrid push i e. 19:30 23:15 3.75 318 6,096 COMPZ FISH TRIP T RIH from 318' and tagged up on ZXP acker at 6,096'. 23:15 00:00 0.75 6,096 6,096 COMPZ FISH MILL T Begin milling on ZXP packer assembly at 6,096', 1-2K WOM, 38 spm, 131 gpm at 550 psi, 100'rpm's with 5K ft-1bs torque, rot wt 85K, up wt 97K, do wt 70K. 01/11/2007 00:00 00:00 24.00 6,096 6,101 COMPZ FISH MILL T Contto mill overZXP packer from 6,096' to 6,100.5' (4.5' of approx. T) 2-15K WOM, 60-110- rpm's, 40 spm, 140 gpm, 500 psi, off btm free torque 3K ft-Ibs, on btm 4-6K ft-Ibs, varied WOM, rpm's and pump rates while milling, rot wt 80K, up wt 80K, do wt 80K, 8.5 ppg MOBM, ave BGG 30 units, pumped several sweeps with 0-10% increase in cuttin s: ---- --~ ~._. - - --- _-------j 3 ~ recta d3 ref ~? ~ Time Lo s ---- -- ~ Date Frem To Dar ~ Depth E Depth Pnase C~ ~e Subcoae T COM _ ' 01/12/2007 00:00 07:3u 7.50 6,101 6,105 CUMPZ FISH MILL T Cont to mill over ZXP packer from 6;100.5' to 6,104.5' (4' of 8.5' milled) 2-15K WOM, 60-110- rpm's, 40 spm, 140 gpm, 500 psi, off btm free torque 3K ft-Ibs, on btm 4-6K ft-Ibs, varied WOM, rpm's and pump rates while milling, rot wt 80K, up wt 80K, do wt 80K, 8.5 ppg MOBM, ave BGG 30 units, pumped 2 sweeps with 0-5% increase in cuttin s. 07:30 08:45 1.25 6,105 6,105 COMPZ FISH. CIRC T Pumped 30 bbl hi vis sweep and cite out of hole, had 5% increase in cuttings back from sweep, cite hole at , 210 gpm, 700 psi, worked boot baskets prior to POOH. 08:45 09:.00 0.25 6,105 6,105 COMPZ FISH OTHR T Monitored well-static, blew down top drive. 09:00 11:30 2.50 6,105 271 COMPZ FISH TRIP T POOH from 6,T04' to BHA #17 at 271' 11:30 13:15 .1.75 271 0 COMPZ FISH PULD T POOH from 271', stood back hybrid- push pipe and LD BHA, cleaned out boot basket and had full recovery of metal (6.6#), mill was 90% worn with ID of miA one. 13:15 15:00 1.75 0 325 COMPZ FISH PULD T PU and MU fishing BHA #18 with 4 1/16" spear`and extensions to go inside CSR-below pkr, RIH with bumper and oil jars, pump out sub, 3-stds hybrid push pipe and accel. 'ars. 15:00 17:15 2.25 325 6,096 COMPZ FISH TRIP T RIH with BHA #18 from 325° to 6,096' (top of ZXP packer). st wt up 95K, do wt73K 17:15 17:45 0.50 6,096 6,105 COMPZ FISH FISH T RIH from 6,096' to 6,105' and sat down on ZXP packer assembly, PU 20K over st wt and LEM came free, saw 5K add. st wt. (st wt u 100K 17:45 18:00 0.25 6,105 6,105 COMPZ FISH OTHR T Monitored well-static,. blew down top drive 18:00 22:15 4.25 6,105 325 COMPZ FISH TRIP T POOH from 6,105' to BHA at 325', did not see any drag when DB nipple & seals went thru hook. 22:15 00:00 1.75 325 0 COMPZ FISH PULD T POOH with fish from 325', LD acceL jars, stood back hybrid push pipe, LD bumper and oil jars, RU tbg tongs and LD fish, LD spear, milled over ZXP packer and csg seal bore receptacle. Pre . to LD LEM's 4 1/2" tb . 01/13/2007 00:00 01:15 1.25 0 0 COMPZ FISH PULD T POOH LD 6-jts of 4 1/2".12.6#, L-80 IBTM-SCC tbg, then POOH with LEM and found to have parted 1/2 down thru the window leaving approx 8' of LEM, 1- u 't, 2-'ts of 4 1/2" tb and seals. 01:15 02:45 1.50 0 0 COMPZ FISH OTHR T Pulled wear bushing and flushed out the stack, re-installed wear bushin . 02:45 03:45 1.00 0 0 COMPZ RIGMN SVRG P Serviced top drive and drawwo~ks _ r_ .._ _-- ~_._ _ ~~~~ ~~ oaf 37~ Tirz~e Logs I~ Date Frnm To Dur S D~~th E C~r,~h Pna~e Code Suhcode T CnP~~ _ __ - - 01/13/2007 03:45 07:30 3.75 0 0 COMPZ FISH WOEO T Waited on fishing tools. 07:30 09:45 2.25 0 372 COMPZ FISH PULD T PU and MU fishing BHA #19 RIH to 372',. MU tapered guide on 1-jt 2 7/8" PAC DP, spear with 3.557" nom OD grapple, ext's, stop sub to btm out on top of the hook, bumper and oil jars, pump out sub, 3-stds of hybrid push i e and accel. 'ars: 09:45 12:30 2.75 372 6,339 COMPZ FISH TRIP T RIH with BHA #19 from 372' to 6,339', st wt u 95K, do wt 73K 12:30 14:45 2.25 6,339 6,380 COMPZ FISH FISH T RIH from 6,339' to 6,380' with tapered guide, tagging top offish with grapple at 6,341', set 5K wt down to engage fish, PU and worked st wt up to 35K over st wt and had T of travel up, increased up wt to 50K over st wt and after 5th pulF fish came free, st wt up 98K, do wt 75K 14:45 15:30 0.75 6,380 5,873 COMPZ FISH TRIP T POOH from 6,380' to 5,873' 15:30 16:30 1.00 5,873 5,873 COMPZ FISH CIRC T Dropped ball and pumped down to seat and o en circ sub'. 16:30 20:00 3.50 5,873 372 COMPZ FISH TRIP T POOH from 5,873' to BHA at 372'. 20:00. 21:15 1.25 372 0 COMPZ FISH PULD T POOH from 372' LD accel. jars, stood back 3-stds hybrid push pipe, LD circ. sub, bumper and oil jars, POOH to spear and had no recovery, LD grapple and showed that the grapple was inside fish and pulled out and was sli htl a ed. 21:15 22:15 1.00 0 372 COMPZ FISH PULD T MU fishing BHA #20 RIH to 372', changed out grapple from a nominal OD of 3.557" to 3.671' and redressed circ sub RIH with BHA to 372'. 22:15 00:00 1.75 372 3,167 COMPZ FISH TRIP T RIH from 372' to 3167 01/14/2007 00:00 00:30 0.50 3,167 6,339 COMPZ FISH TRIP T RIH with BHA #20 from 3,167 to 6,339', st wt up 98K, do wt 74K 00:30 01:30 1.00 6,339 6,371 COMPZ FISH FISH T RIH from 6,339' and tagged up with tapered guide at 6,370' and spear at 6,331', worked guide and spear down with 15-20K wt do and. moved do hole 1' to 6,371' and spear at 6,332', attempted to pull fish out at 25K over 6X w/no movement, increased to 50K and after 6th try string came free, (no ~ars) st wt up 100K. 01:30 01:45 0.25 6,371 6,371 COMPZ FISH OTHR T Monitored well-static, blew down top drive. 01:45 06:30 4.75 6,371 372 COMPZ FISH TRIP T POOH wet from 6,371' to BHA # 20 at 372' __~ _ - • Trme Logs -- --- ~ '~ ~~! Fror.~ To Dur S Deb'-h E Depth Pnase C ode__ SuL,code_ T (~O(v1 ___ _ __ __ ~ 01/14/2001 06:30 07:15 0.75 372 0 COMPZ FISH PULD T POOH from 372', LD accel. jars and stood back 3 stds of hybrid push pipe, POOH to spear and had no recovery, spear looked like last one, that it had been inside fish but note ed. 07:15 08:00. 0.75 0 0 COMPZ FISH PULD T RU and broke out spear and grapple, cleaned ri floor. 08:00 10:15 2.25 0 0 COMPZ FISH OTHR T Serviced drawworkswhile having teleconference with CPAI and Baker re s. 10:15 12:00 1.75 0 0 COMPZ FISH PULD T Fin LD BHA #20 12:00 14:45. 2.75 0 441 COMPZ FISH PULD T PU and MU BHA #21 with 3 5/8" string mill and RIH to 441,', MU tapered guide (2 1!2" x 2 7/8"), 1-jt 2 7/8" PAC DP, ported sub, 3 5/8" OD string mill, 2 jts 3 1/2" DP, 2-boot basket's, bumper and oil jars, pump out sub, 3-stds h brid iash ipe. 14:45 16:45 2.00 441 6,315 COMPZ FISH TRIP T RIH from 441' to 6,315'. 16:45 19:00 2.25 6,315 6,402 COMPZ FISH MILL T Est circ at 50 spm, 175 gpm, 600 psi, 45 rpm's, 4K ft-Ibs free torque, rot wt 84K, up wt 96K, do wt 72K, RIH from 6,315' and sat down at 6,361 jmilf 36' back) with mill at 6,331', milled on LEM from 6,331.' to 6,335' with 3K WOM, took approx 30 min`s to mill, worked string mill thru spot 10X. and did not see any drag or torque, cont to rotate and RIH setting down at 6,402' with string mill at 6,363' with 5K wt dn, PU from 6,402' and circ hole working the'unk baskets. 19:00 19:15 0.25 6,402 6,402 COMPZ FISH OTHR T Monitored well-static, blew down top drive, 19:15 21:30 2.25 6,402 441 COMPZ FISH TRIP T POOH from 6,402'.to BHA #21 at 441'. calc fill on trip out 32 bbls, actual fill 38 bbls. 21:30 22:45 1.25 441 0 COMPZ FISH PULD T POOH from 441', stood back 3-stds hybrid push pipe, LD boot baskets (no recovery) then fin. LD BHA and cleaned ri floor. 22:45 00:00 1.25 0 140 COMPZ FISH PULD T Began to MU milling BHA #22 RIH to 140', MU tapered guide, string mill, 1 jt of 2 7/8" PAC DP, 5 1/2" pilot/packer mill, 2=is 3 1/2" DP and boot baskets. 01/15/2007 00:00 00:30 0.50 140 417 COMPZ FISH PULD T Fin MU BHA #22 RIH to 411 (Note: pilot mill is 40' back from tapered uide) 00:30 01:45 1.25 417 6,300 COMPZ FISH TRIP T RIH from 411 to 6,300', stwt up 96K, do wt 73K. I i - - ~ _ _. ~ ~ ~, .~ r f'~~.r . , ., _ ; • Time Logs -- - Date From To Dur S Depth E Depth Phase Cccie _ ~uh~~~; _e T t O(`.q '' 01/15!2007 01:45 02:00 0.25 6,300 6,373 COMPZ FISH TRIP T RIH and tagged up at 6,366' with pilot mill at 6,326', (top of hook at 6,328') set 5K wt do and rotated off hook, cont. to RIH setting down at 6,373' with mill depth of 6,333', est circ at 49 spm, 175 gprn at 650 psi, 80 rpm's at 4K ft-Ibs torque, rot wt 83K, up wt 96K, do wt 73K 02:00 16:00 14.00 6,373 6,375. COMPZ FISH MILL T Milled on LEM from 6,333' to 6,336' (3') when fish moved down hole 4', cont to mill on fish from 6,340' to 6,341' (1') when fished moved down hole an add. 13' to 6,394' drift depth and 6,354' mill depth. Assuming approx 116' offish left in hole and top of pilot mill at 6,354' that would put the seals at 6,470' with XO in CSR at 6;472' (2' high); milled at 6,354` for 30 min. with no movement. At 08:00 hrs, PU to just below top of hook at 6,326' with pilot mill and 10-15K drag then RIH setting down at 6,331', worked mill thru spot that was tight and' torquing up from 6,331' to 6,335'. PU and was able to work mill thru top of hook and down to 6,335' with no problems. Torque had smoothed out while millin at 6,335'. 16:00 00:00 8.00 6,375 6,382 COMPZ FISH MILL T Cont to mill on top offish at 6,335' mill depth, 6,375' guide depth to 6,342' mill depth, 6,382' guide depth. (7') (took 4 hrs to mill1' at 6,339) milled at 3-7K WOM, 100 rpm's, 75 spm, 265 gpm at 1,200 psi, rot wt 80K, up wt 95K, do wt 73K, off btm torque 4K ft-Ibs, on btm 4-7K ft-Ibs, pumped hi vis sweep with 0-5% increase in cuttin s. 01/16/2007 00:00 01:15 .1.25 6,383 6,383 COMPZ FISH CIRC T Continue circulate sweep out of hole. No increase in cuttings observed. Work strip from 6383' - 6321'. 01:15 03:15 2A0 6,383 417 COMPZ FISH TRIP T Monitor well -static. POOH from 6383'. -41 T. 03:15 04:30 1.25 417 0 COMPZ FISH PULD T Breakout & lay down -BHA. Observed left 40' of fishing assembly in hole. Left in hole packer mill stinger, 1 joint of 2 7/8 DP, string mill,. ported sub, crossover, and tapered guide with stabilizer. 04:30 05:00- 0.50 0 0 COMPZ FISH PULD T Clear & clean rig floor from OBM. 05:00 06:45 1.75 0 384 COMPZ FISH PULD T Make up BHA # 23:3 1/4" Itco spear assembl with 3.942" ra ple: 06:45 08:30. 1.75 384 6,342 COMPZ FISH TRIP T Trip in hole from 384' - 6342'. ~- - -- -- -- -- __ -- r~~a~~.2~ ~t 37 [~ Time Logs I L~ ~te F~em To Dur S D ~th_ E D~pjh_ Phase Code ,-L~c~de T COA1 - - - - _ _ -- 01l16/2007 08:30 09:30 1..00 6,342 6,342 COMPZ FISH FISH T Attempt to engage fish (LEM) at 6342' DPM. Could not verify engagement. Pumps @ 74 SPM - 1600 PSI. UP WT = 96K, SO WT = 71 K. 09:30 12:00 2.50 6,342 383 COMPZ FISH TRIP T Monitor well -static. POOH from 6342' - 383'. Crew Chan e. 12:00 12:45 0.75 383 0 COMPZ FISH PULD T Continue breakout & lay down BHA. No Fish. Grapple indicated marks on the first4 "wickers" on grapple on only one side of ra' ple. ' 12:45 13:15 0.50 0 0 COMPZ FISH PULD T Clear & clean rig floor from OBM. 13:15 14:30 1.25 0 0 COMPZ RIGMN SVRG T held PJSM with crew. Discuss safety issues and procedure for Slipping & cutting Drilling Line. Slip & cut drilling line. Service draw works and Top Drive. 14:30 15:45 1.25 0 383 COMPZ FISH PULD T Make up BHA #24:3 1/4" Spear assembl with 3.682" rap le. 15:45 18:00 2.25 383 6,257 COMPZ FISH- .TRIP T Trip in hole from 383' - 6257. 18:00 18:45 0.75 6,257 6,342 COMPZ FISH FISH T Establish pump rates @ 60 SPM - 1050 PSI. PU WT = 97K, SO WT = 73K. RIH to tag up on fish @ 6342' DPM. Work string to attempt to engage. Repeat attempts to engage fish. Could not verify emgagement with. any overpull or pump pressure. increase. 18:45 19:00 0.25 6,342 6,357 COMPZ FISH OTHR T Monitor well -static. Blow down Top Drive. 19:00 21:45 2.75 6,357 383 COMPZ FISH TRIP T POOH from 6257 - 383'. Observed ro er hole fill 21:45 23:00 1.25 383 0 COMPZ FISH PULD T Breakout & lay down BHA#24, Observed grapple left in hole. Spear indicated grapple was pulled straight off. Set screw in place, and scratch marks on-Helix of spear & bullnose verified strai ht ull off. 23:00 23:30 .0.50 0 361 COMPZ FISH PULD T Make up BHA #25.5 1/4" lead impression block assembl . 23:30 00:00 0.50 361 361. COMPZ FISH OTHR T Clean & clear floor area of OBM for TIH. 01/17/2007 00:00 00:15 0.25 0 COMPZ FISH PULD T Continue MU BHA # 25. 00:15 01:30 1.25 361 6,324 COMPZ FISH TRIP T Trip in hole from 361' - 6324'. 01:30 02:00 0.50 6,324 6,338 COMPZ FISH FISH T Establish parameters. UP WT = 94K, SO WT = 74K. Fill Drill string. Slack off to tag at 6331' set 2K on and weight felt off. Continue slack off to tag 6337 with 2K, continued to 6338' DPm and set down 15K. Note: This is 4' higher than when we last tagged & fished for tb 6342' DPM. 02:00 04:00: .2.00 6,338 361 COMPZ FISH TRIP T Blow down Top drive. POOH. from 6338' - 361'. ~--- -__ _.. ~e snid"s;,~tJ3`,~i'~ , ,~ _~ __.~ • Time Logs - - -- - - __ D ,'e _ From T~ D~.i~ S Depth _F. D~p~h Phase ~od~ Subcode T COM - -- 01/17/2007 04:00 04:30 0.50 361 0 COMPZ FISH PULD T Breakout & lay down BHA #25. Lay down Impression block: Inspect block. Marks indicated tagging up on Spear -Grapple left in hole, and junk on OD of block. 04:30 05:00 0.50 0 0 COMPZ FISH PULD T Clean & Clear Rig Flloor. Lay down Tools. Discuss options for operations with town. 05:00 06:00 1.00 0 0 COMPZ RIGMN SVRG T Service Top Drive. Re tie service lines. 06:00 08:00 2.00 0 0 COMPZ RIGMN SVRG T Change out saver sub on Top Drive. 08:00 08:30 0.50 0 0 COMPZ RIGMN SVRG T Inspect draw works chains, & replace cotter ins as rieeded: 08:30 10:15 1.75 0 0 COMPZ FISH WOOR T Discus options with town. SIMOPS: Clean bell pan on skate, .clean ri . 10:15 10:45 0.50 0 363 COMPZ FISH PULD T Make up BHA #26: Box Tap assembl . 10:45 12:00 1.25 363 2,225 COMPZ FISH. TRIP T Trip in hole from 363' - 2225'. Crew Chan e 12:00 12:15 0.25 2,225 3,158 COMPZ FISH . TRIP T Continue trip in hole from 2225' - 3158'. 12:15 12:30 0.25 3,158 3,158. COMPZ FISH TRIP T Fill drill string with mud. 12:30 13:00- 0.50 3,158 6,330 COMPZ FISH TRIP T Continue trip in hole from 3158' - 6330'. 13:00 13:45. 0.75 6,330 6,341 COMPZ FISH FISH T Pickup single from shed. Obtain parameters. UP WT = 96K, SO WT = 71 K, ROT WT = 84K. TQ = 3K @ 25 RPM's. 2 1/2 BPM - 300 PSI. Tag @ 6341' DPM. Stalled out @ 6K. Set down 10K. POOH, lay down single, Monitor well - staic: Blow down Top drive. 13:45 17:00 3.25 6,341 363 COMPZ FISH TRIP T POOH from 6341' - 363'. 17:00 17:45 0.75 363 0 COMPZ FISH PULD T Rack back Push pipe, breakout & lay down Box Tap assembly. Observed NO FISH, and marks indicated never en a ed. 17:45 20:30 2.75 0 0 COMPZ FISH PULD T Clean & send out all Baker Fishing tool equipment from rig floor. VAc out OBM from ID's of tools. for SPCC revention. 20:30 21:00 0.50 0 0 COMPZ WELC7 BOPE T Drain Stack. BOLDS. Pull wear bushin . 21:00 00:00 3.00 0 0 COMPZ WELC7 BOPE T Rig up test equipment. test BOP's. Witness of test waived by AOGCC I Chuck Sheave.. 01/18/2007 00:00 01:30 1.50 0 0 COMPZ WELC7 BOPE T Continue test BOP's. Perform Koomey test & check bottles for avg acce table ressures. 01:30 02:00 0.50 0 0 COMPZ WELCT OTHR T Rig up & install wear bushing. RILDS. La down runnin tool ~- ___ ~- ~~~~ ~>,~ ~sf ~7 l ~_.__ __ _ _ ._ ~ _ ~ __. ____ _ _ _._ • • ~ Time Logs D~t~ From To Dur S Depth E Depth PI ase _ Code Subco~= T COM J -- _ _ --- - - - - --- 01/18/2007 02:00 02:30 0.50 0 0 COMPZ RPCO(v PULD T Pull tools to floor. Casing tongs, slips etc... Held PJSM .Discuss safety issues and procedure for MU packer assembl . 02:30 03:30 .1.00 0 61 COMPZ RPCOh PULD T Make up S-3 Packer, Liner Hanger & Casing Seal Bore receptacle assembly as per BOT rep. Total length of assembly = 60.75', spaced out for i to to be set at 6120'. 03:30 05:45 2.25 61 0 COMPZ RPCOh PULD T RIH with assembly on firststand of DP. Tag up at 90'. Pull out to inspect packer.. All good. RIH to tag again at 104'. POOH. Decision to lay down packer assembly. Suspect junk in hole. Breakout & lay down packer assembly. Cup in inner string hung up. Sent back to shop for rebuild. Observed iron filin sin cu . 05:45 06:15 0.50 0 0 COMPZ RPCOIV OTHR T Clear & clean rig floor. Send tools out: 06:15 06:45 0.50 0 325 COMPZ FISH PULD T Make up clean out assembly, with 6 3/4" bit, scraper, upper watermelon mill, and string magnet with boot. baskets. Total BHA = 325.33'. 06:45 10:00 3.25 325 325 COMPZ FISH. WOEQ T Wait on tools to complete MU of BHA. Tools comin from BOT sho 10:00 10:15 0.25 325 325 COMPZ FISH PULD T Complete MU of BHA #26: Install 7 5/8" Scra er. 1.0:15 12:00 1.75 325 3,587 COMPZ FISH TRIP T Trip in hole from 325' - 358T. Observed ro er hole fill. Crew Chan e 12:00 12:45 0.75. 3,587 6,275 COMPZ FISH TRIP T Continue trip in hole from 3587 - 6275'. Did Hot to on an thin . 12:45 14:15 1.50 6,275 6,275 COMPZ FISH CIRC T Establish circulation & parameters. UP WT = 95K, SO WT = 74K, 60 SPM - 800 PSI. Pump Hi Visc weighted sweep. Observe little or no Iron recovery when sweep back to surface: Pum d 'ob. 14:15 14:30 0.25. 6,275 6,275 COMPZ FISH TRIP T Monitor well -static. Blow down Top Drive & lines. 14:30 16:45 2.25 6,275 325 COMPZ FISH TRIP T POOH from 6275' - 325'. Obseve pro er hole fill 16:45 18:00 1.25 325 0 COMPZ FISH PULD T Rack back push. pipe. Breakout & clean junk baskets & string magnet. Observed 10 Ibs of iron recovered. No bi feces. 18:00 18:30 0.50 0 0 COMPZ RPCOh OTHR T Clear & clean rig floor from OBM. Rig u tools to run Packer assembl . 18:30 19:30 1.00 0 61 COMPZ RPCOh PULD T Make up S-3 Packer; Liner Hanger & Casing Seal Bore receptacle assembly as per BOT rep. Total length of assembly = 60.75', spaced out for to to be set at 6120'. - ---- ----- - -~ -,- r ~ ~~~ 3_ _~ a.- ' • • f lime Loys I Da!e rro~7i To Dur S Decth E Depth Prase Code Subcoda T COM 01/18/2007 19:30 22:30 3.00 61 6,180 COMPZ RPCO4 TRIP T Trip in hole with packer assembly from 61' - to locate & spot top of setting sleeve @ 6119' DPM. Running speed at 60 ft/min as per BOT rep. Qbserved ro er hole fill 22:30 23:30 1.00 6,180 6,180 COMPZ RPCOh DHEQ T Obtain Parameters. UP WT- 97K, SO WT = 73K, 36 SPM - 450 PSI. Drop 1 3/4" ball down drill string. Pump down Drill string @ 3BPM -450 PSI. Observe ball seat at 436 BBIs pumped, andcontinue pressure to 4000 PSI to set packer. Hold pressure 5 minutes. Bleed pressures. Record on chart. 23:30 00:00 0.50 6,180 6,180 COMPZ RPCOh DHEQ T Pump down annulus to 1000 PSI, for 10 minutes. record on chart. Bleed all ressures. Crew Chan e 01/19/2007 00:00 01:45 1.75 6,119 0 COMPZ RPCOh TRIP NP Continue POOH from 6119' to surface. 01:45 02:00 0.25. 0 0 COMPZ RPCOh PULD NP Inspect, Breakout & lay down running. & settin tools. 02:00 02:45 0.75 0 0 PROD3 STK PULD P Clear & clean rig floor of OBM. Pull tools to floor. Held PJSM with crew & BOT rep. Discuss safety issues and procedure for making up whipstock assembl . 02:45 03:45 1.00 0 0 PROD3 STK PULD P Make up Whipstock assembly as per BOT rep, with space out pipe & seal assembl . 03:45 04:15 0.50 0 0 PRODS STK PULD P Make up MWD assembly. Orient to whi stock face. 04:15 04:45 0.50 0 0 PRODS STK PULD P Plug in and upload MWD assembly. 04:45 05:30- 0.75 0 506 PRODS STK PULD P Continue Make up remaining whi stock BHA. Total len th = 506.14' 05:30 07:30 2.00 506 5,346 r PRODS STK TRIP P Trip in hole from 506' - 5346'. 07:30 08:30 1.00 5,346 5,528 PRODS STK OTHR P Perform MAD PASS log from 5210' - 5320'. Sensor depths. 08:30 09:00 0.50 5,528 6,072 PRODS STK TRIP P . Continue trip in hole from 5528' - 6072'. 09:00 09:30 0.50 6,072 6,119 PRODS STK WPST P Establish parameters. UP WT = 115K, SO WT = 91 K. Orient whipstock face with MWD to 12 left of high side as per DD. Set whipstock. Observe anchor set with 10k, and verify set. Shear off bolt with 45Kset down. Pick up to neutral position. Rotate free with 4K free torque. Top of whipstock @ 5991' DPM. 09:30 12:00. 2.50 5,991 5,998 PRODS STK WPST P Mill window from 5991' - 5998'. ROT WT = 96K. 100 RPM's 4K TQ. Crew Chan e ~~~ :r~~ ~ ~.a ~~~~ • • TiiTie Logs Dafr Frci_n To D_ur S_D~~±h D-~th Ph~.P C' ~uir~.ode T COM 01/19/2007 12:00 13:30 1.50 5,998 6,004 PROD3 STK WPST. P Continue mill window from 5998' - 6004'. Pump 30 BBL Hi Visc weighted sweep. Observe 20% increase in cuttings upon sweep returned to surface. 13:30 15:15 1.75 6,004 6,031 PROD3 STK WPST. P Continue mill open hole from 6004' - 6031'. Gauged hole to 6023'. Pump 30 BBLS Hi Visc wei hted swee . 15:15 16:00 0.75 6,031 6,031 PROD3 STK WPST P Dress window with mills allowing sweep to return. Monitor well -static. Pump dry job. Blow down top drive & lines. 16:00 18:30 2.50 6,031 0 PROD3 STK TRIP P POOh with milling assembly from 6031' to the BHA. 18:30 19:30 1.00 0 0 PROD3 STK PULD P Plug in and download MWD assembly. Breakout & lay down mills. Gau a mills to full au e. 19:30 20:30 1.00 0 0 PROD3 STK. OTHR P BOLDS. Pull wear bushing. Rig up & flush BOP. stack. Install wear bushing. RILDS. 20:30 22:00 1.50 0 0 PROD3 DRILL PULD P Held PJSM with crew & Sperry Sun reps. Discuss safety issues and procedure for making up BHA. Make u 6 3/4" drillin BHA with Geo iiot. 22:00 23:15 1.25 0 367 PROD3 DRILL PULD P Plug in and upload MWD assembly. Continue make up remaining BHA. Total len th = 367.74'. 23:15 00:00 0.75 367 1,300 PROD3 DRILL TRIP P Trip in hole with BHA. Perform shallow ulse test. Break in Geo ilot. 01/20/2007 00:00 00:15 0.25 1,300 1,300 PROD3 DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 01:00 0.75 1,300 5,962 PROD3 DRILL TRIP P Continue trip in hole from 1300' - 5962'. Observed ro er hole fill. 01:00 01:15 0.25 5,962 6,031 PROD3 DRILL TRIP P Fill drill string with mud. Check Geo-Pilot deflection. Trip in hole through window area with no issues to 6023'. PU WT = 98K, SO WT = 75K, ROT WT = 84K. TQ 4K. 01:15 12:00 10.75 6,031 6,288 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 6031' - 6288' MD. ADT 8.0 HRS. Drilled $6' + of concretions.. Crew Chan e 12:00 12:15 0.25 6,288 6,288 PRODS DRILL SFTY P PJSM with-crew. Discuss safety issues and hazard reco nition issues. 12:15 00:00 11.75 6,288 7,246 PRODS, DRILL DDRL P Directional drill 6 3/4" hole in the D Lateral from 6288' - 7246' MD. ADT = 7.6 HRS. Drilled 46' of concretions. Crew Chan e 01/21/2007 00:00 00:15 0.25 7,246 7,246 PRODS DRILL SFTY P PJSM with crew. Discuss safety issues and hazard reco nition issues. 00:15 12:00 11.75 7,246 8,424 PRODS DRILL. DDRL P Directional drill 6 3/4" hole in the D Lateral from 7246' - 8424' MD. ADT = 7.1 HRS. Pump Hi Visc weightred swee s as needed. Crew Chan e 12:00 12:15 0.25 8,424 8,424 PRODS DRILL SFTY P PJSM with crew. Discuss safety i ssues and hazard reco nition issues. -~ I ~~~u ~~ oaf ~~ Changes in 1J-103 Subject: Changes in 1J-103 From: "Greener, Mike R." <Mike.R.Greener(i?conocophillips.corn% Date: Tue, 23 tan 2007 08:34:20 -0900 "C~-: -f~am Maunder <tom maunder(~ia~ln~in.statc.~~k.us=~ ~~o - ~.~~ '1-'here are t3wo items to report to you about. t ~ -- l a `~ ~ ~, l . Tl~e LEM and. hook assembly for tl~e "B" lateral ran into problems which recllired l.ls to attempt to retrieve the LE'~l. (The LEM got t~~~isted during the setting attempt) ~~'e were u~~successfui in rct~-ievin~,~ the L.E,~!l after spending 1. IVINI and about 12 days. Tl~e asset determined that `ve wc~>r11d contil~llle o11 i~~ith tl-le well al~d drill and col~lplete the "~" lateral. If, tl-lrougl~ GeoC;l~eln al~lalysis, it was detel-mi.ned later that the "A" ar "B" lateral were not producin~,~, then one or t~vo ~vinda~vs would. lac cut above the "D" wil~dow and latel•al would be drilled into the non-l~rodllcing zone. These additional windows, if 1•etluired, would be placed directly above tl~e "D" sand anal ~~-ollld be in the bottom. of the X13 interval. and ~vc~tlld not be in the Ugl~il sand. . -: The. asset decided for the "I)" ate1•al that, they wanted to check to ~e if the ~~an 11 c~fthe fault located at +i- 1 1,00' ~Tc~rllcl.l?e.~Jet as it,`~as i~l ,e cl-ossed tl~e same fau tl~e "B" lateral. If:the sand is not vet; then T could drill to a depth. +i- 13,00' tot 7 1.111 a tail down into the " " ~ and. to see i~ the "B" sand. was 11C) longer wet, Ifthe "B south. of the 1J-1.03, could th+ e not wet tl len the 1 J-13 5, directly dual lateral prodrlcer. 1f the "B" vas still let then the 1 ld lil~ely become a ,ingle lateral prodclcel-. Vie, if the "I~" sand is i~fet after- crossing the fault tl~el~ T ~ ld 'l'1.~ the well. and it `would be lli~hly likely that the 1:1- l 35 would 11ot be drilled, \ StatLls of the we11 this morning: e ha~r~; crossed the ault on the `'D" lateral and. the sand is not wet. So the plan forward is to drill. to 1.3,400' al~d they cheek tl~e "B" salad. Please let nee kz~lo~v our process forward for tlae state il~ al~el~dil~g tl~le permit as the '1,I.) of the "~" saner will be past the 500' allovvrlce. Mze Cireene;r «Greener, Mike R..vcf» ~`~ ~~ P~'`` ~ C-~-r~ 1 of 1 3/20/2007 10:10 AM Re: update on 1 J-103 and 1 J-180 wells ~ • Subject: Re: update on 1J-103 and 1J-180 wells From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 10 Jan ?007 16:25:39 -0900 To:'"Grecn~r. Z-like R." ~ Adike.K.Greenel-~reconoeophillips.~um ('(': "Thomas. I:a~~~i~ I." ~~IZan~i~~.L.Ch~~mas~icimocophil1i}~s.~~~m.. "l:cill~, 1'atriek J" <Patrick. .Reilly ~cconoc o p f~ i I l i p. coYn> Mike and Pat, Thanks for the information. Glad you are isolating that water. On deepening the surface casing, this message is sufficient. There haven't been any report hazards that would preclude setting a few hundred feet tvd deeper. Good luck with the operations. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 1/10/2007 3:57 PM: I m remiss in that I haven't kept you up to date on what has happened with the TD depth change on the 1J-103 well in tl~e A late~•al. ~~'hile 1 am at it 1 also Have some info on the 1 J-180 ~vel l for you.. -: r J- 3 rl'he '`A" lateral ended up being TD'd t 1.1.,2'12' ~ (o~°igir~al lien it depth way l S,Og4') ~t`l~e asset Suspected the formation tivould be vet if v~Ie crossed tl~e fault at +,/- 11,400' , This vas based on the results that were seen in the offset 1 J-1 {)2 well, ._--- ~~ `~~-~ The "B" lateral svgs planned to cross this same f~~~lt to determine if the sand. in that zone v~~as vet south of the .fault. We discovered that it was and TD's the ~vel1 at ~''~ 1.2,444'. We ran a liner to l 1,583' and. placed tu~o s~~~ell packers (one on each side of the fault which `~~as at +/- 11,400'). During the running of the LEM {lateral ent~~~ module) for the "" lateral we have encc~,utered some trouble and we are currently in the p~°ocess of retrieving it anal. eve plan to run a ne~~~ o~~e. Then eve will move to drilling the ``D" lateral. We a~°e currently drilling the surface section on this well. It looks like this section tivill reach the required ~I~VD depth of-~--/- 2,142' at a measured dcptl~ of ~--/- 3,jC}' 1~J1D. VVe would. like to continue drilling on this same path to extend our setting depth. of the sup°~ace casing to somewhere bete%een 3,8001' to 4, l 00' ~!lD ~vl~icl~ ~voi~ld be 2, l q2' to 2,250' T~'D, This would help us get our intermediate casing to depth. since we would be able to run more roller centralizers in t1~e surface x. interrned.iat annulus to reduce friction. 1 of 2 3/20/2007 9:39 AM Re: update on 1 J-103 and 1 J-180 wells ~~ I.~~~es this ',4'I~ depth ch.~e pose a p~-®blel~~ #t-c~m the c~r~~~irl~l permit dept for the sul-f~ce cr~sil~~ of~ 3,~7~' ~4I~, 2,1.42' 'I"~'I.)? ~1ike Greette:r «Greener, Mike R..vcf» 2 of 2 3/20/2007 9:39 AM • Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKf, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-103L1 ConocoPhillips Alaska, Inc. Permit No: 206-115 Surface Location: 2226' FSL, 2441' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 2517' FSL, 717' FEL, SEC. Ol, TlON, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development 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-103, Permit No. 206-114, API No. 50-029-23318-00. Production 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 any required test, cont~ um field inspector at (907) 659-3607 (pager). DATED this~day of August, 20uc~ cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~ R~~EIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ ~}~~ 2 8 2006 PERMIT TO DRILL fission 20 AAC 25.005 Alaska Oil & Gas Cons. Cotes R nrt1AT'rttftQJ 1a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone ^ Single Zone ^/ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-103L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11008' • TVD: 3596' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2226' FSL, 2441' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25661 & 25662 ~ West Sak Oil Pool - Top of Productive Horizon: 2284' FSL, 621' FWL, Sec. 36, T1 iN, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 11/22/2006 Total Depth: 2517' FSL, 717' FWL, Sec. 01, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558766 y- 5946037 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Neyy~~rest ~ Well within Pool: 1 J-14 , 9526' ~• 16. Deviated wells: Kickoff depth: 5954 • ft. Maximum Hole Angle: g2° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) 7 Downhole: 1641 psig ' Surface: 1240 psig ' 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' • 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2880' 28' 28' 2880' . 2242' • 510 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 6805' 28' 28' 6805' • 3790' • 410 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 5054' 5954' 3647' 11008' • 3596' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Pertoration Depth MD (ft): Pertoration Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch^ Drilling ProgramQ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ Phone Z 6S 6L 3d Date ~ ~~ ? /~s6 P h n Al k Commission Use Only Permit to Drill Number: ~~ •- //~ API Number: 50-oz9 - 23 ~~ ~ ~' ~ b Permit Approval Date: 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 , or gas contained in shales: ~r~~ t ~.~ 1 ~~ ~1 - ~~~ Samples req'd: Yes ^ No ~ Mu log req'd: Yes ^ No []' Other: ~°`''~~~`' ~S ~c~, ~ H2S measures: Yes ^ N re svy req'd: Yes [r]" No ^ APPROVED BY THE COMMISSION DATE: ~~ D ,COMMISSIONER Form 10-401 Revised 12/2005 ~' S~(l~Submit in Duplicate iSD 7.3 ~. c~ • Applic~or Permit to Drill, Well 1 J-103 L1 Revision No.0 Saved: 27-Jul-06 Permit It -West Sak Well #1J-103 L1 Application for Permit to Drill Document 1Mell Vp1uB Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (i) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 1J-103L1 PERMIT IT Page 1 of 6 Printed: 27-Jul-06 ~~~~~~z~ Applic~or Permit to Drill, Well 1J-103 L1 Revision No.O Saved: 27-Jul-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 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as iJ-103 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 file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to 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 2,226' FSL, 2 441' FEL, Section 35, T11N R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,946,037 Eastings: 558,766 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 2,284' FSL, 621' FWL, Section 36, T11N, R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 5,954 Northings: 5,946,120 Eastings: 561,827 Total Vertical De th, RKB: 3 647 Total Vertical De th, SS: 3,538 Location at Total De th 2,517' FSL, 717' FWL, Section 01, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 11,008 Northings: 5,941,075 Eastings: 561,968 Total Vertical De th, RKB: 3,596 Total Vertical De th, SS: 3,487 and (D) other information required by 20 AAC 25.050(b); 1J-103L1 PERMIT IT Page 2 of 6 Printed: 27-Jul-06 ORIGINAL Applic~or Permit to Drill, Well 1 J-103 L1 Revision No.O Saved: 27-Jul-06 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) 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 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 (t3) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-103 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 1,240 psi, calculated thusly: MPSP = (3,647 ft TVD)(0.45 - 0.11 psi/ft) = 1,240 psi ' (e) 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-103 Li 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-103, 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 pen`ormed in accordance with the'~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-103L1 PERMIT IT Page 3 of 6 Printed: 27-Jul-O6 ~2!GINAL • Applic~for Permit to Drill, Well 1 J-103 L1 Revision No.O Saved: 27-Jul-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 C Hole Top Btm CsglTbg Size Weigh Length MD/TVD MD/TVD OD in (in) t Ib/ft) Grade Connection (ft (ft) (ft) Cement Program 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 9,040 6,054 / 3,659 15,094 / 3,749 slotted- no cement Lateral iJ- 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 5,054 5,954 / 3,647 11,008 / 3,596 Slotted- no cement slOtt Lateral (1J-103 Ll) 4-1/2 an -80 BTC ,337 5,670 / 3, 11,007 / 3,52 otted- n en slotted Lateral (1J-103 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-103 L1. 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 muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit ( ) 8.6 Plastic Viscostiy Ib/100 sf) 15 - 25 Yield Point (cP) 18 - 28 HTHP Fluid loss (ml/30 min @ 200psi & 950° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 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. 1J-103L1 PERMIT IT Page 4 of 6 Printed: 27-Jul-06 (?R!GI~'AL • Applic~for Permit to Drill, Well 1J-103 L1 Revision No.O Saved: 27-Jul-06 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 frle 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: (i 0) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-103 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,954' MD / 3,647' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at +/- 11,008' MD / 3,596' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-103L1 PERMIT IT Page 5 of 6 '~ I ~ ~ Printed: 27-Jul-O6 . ,~ .cy~ ~ ~: L • Applic~or Permit to Drill, Well 1 J-103 L1 Revision No.0 Saved: 27-Jul-O6 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-103 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 frle 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 iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-103L1 PERMIT IT Page 6 of 6 A ~ Printed: 27-Jul-06 • • ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-103 -Slot 1 J-103 1J-103 L1 Plan: 1 J-103 L1 (wp06) Proposal Report 26 July, 2006 r. -r= - i w S$ t ~ ~ ± r r„ ~ i ' 1;( Sperry Drilling Services Q~!~I~AL w+ C/M`ON ' ~~ N C O fn ~ r a} ~ ~ cE ~ ?~ o O O d J O J ~ ~ O U m 'p 0~. ~U 67Q YYY _ ~ O (O M M 3 a C N N ~' C C C e' 1 Q Q Q m {[1 M N N d O D N EM 3 ~' Y ~ ~ ~ ~ - j~ J w O LLmFYI -~77Y$~~ N ~' ' ` Q ~ m ON r z.-na '. ' ' "' `~ ~ ~r,~M ~p a p ~- f N O f A t Y w ~ f O d ~im ~nomma~acom e arri~~o~i r~e.i aio~ai W O ~mm~ . ~ `- n. ~ L ~. = O ~- ~ d r ~ Z O N 1~ t D O D N O N d 1~ ~ M OmcOM W OYf 1p Of ~D aom ~~e-NNdddd~l N N ~ z Oyy W ODN O '. • D o O Y Yd O~ r '= Q zooooo00000o A 0 0 0 0 0 0 0 0 0 0 0 y NN°r J n ~ _ M ~ ~ a C G M i M) f V N N M ~ D t~ O N N~ef NN d - N Q U M 3 ~ V i. a G~ ~ ~ a. p 0' ~O d O~ vl N~ D T N N M h M M h M D O f00 O f O O ~ O ~ 0 N ~ a ~ LL ~~ NMd HtD I~NO~~~ Nt~O~ ~ ' ' ~ a N M M .I . ~' __------ "-- ~ o z ~ N M '. '~ ___ ~~ ~ 006 J y°j cO M ' O 0 N -__ 3 ~ 7 _, _ ~ , I~ H ~ J M O O ~ ~ d '~ rn rn(O ~Q O O ~ (V O J M m ~',~~ Q~ ~ M d O o N Z a o~~ ~ m'~ ^ a ~' d o o ion `~ J > 0 n 3 M ~ A W C~~ ___________ H J C~ W ~ W ~n ~ O O O ~ OHO C V 9 ~ M v O O Z d 91" O O N O ° 3B ~ o tli ° + '. 3 N f6 N ,~ ~ C ~ .o _- ~ +o _-"- - o W - ° fn 8 0 O 0 N U 3 ~ Y O ~ Q.4 ~ / , J .L " " " " r~ 0 0 °o a , "" ~ a a --------- `- ~ J 0 U ,~ a tD O M O - 3 °o ___ 1o J M O O O -_ ~ O. 3 N I ,061 _ _ ~ J I X08:' -6000 p ~ 0 0 i o . L~ ~ ~ I O ~ o ~ n ~ ~ "Ql , Ci a I i~OSI ~ ~ ~', ~, o o i ~ .E ~ ' °o °o °0 00 00 0 °o t ~ Q • ~ ~ N ~ M ~ (u!/1109L) y~daa !e~!~an anal d ~ ORIGINAL ~ Halliburton Energy Services L Conoco Phillips Planning Report -Geographic Alaska Sperry Driliing Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-103 -Slot 1J-103 Company: ConocoPhillips Alaska:, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Wellbore: 1J-103 L1 Design: 1J-103 L1 (wp06) 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-103 -Slot 1 J-103 Well Position +N/-S 0.00 ft Northing: 5,946,037.40 ft Latitude: 70° 15' 47.418" N +E/-W 0.00 ft Easting: 558,768.60 ft Longitude: 149° 31' 29.659" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wellbore -- 1J 103 L1 - -- _ _ - ~ Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 5/9/2006 24.10 80.77 57,564 Design 1J-103 L1 (wp06) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,954.96 Vertical Section: Depth From (TVD) +N/-S +EI-W Direction (ft) (ft) (ft) 1°) I 28.00 0.00 0.00 180.00 7/26/2006 9:55:57AM Page 2 of 8 ~~ ~~ COMPASS 2003.11 Build 50 . ~ `/ Halliburton Energy Services Conoco Phillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska, Inc. ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1 J-103 Survey Calculation Method: Wellbore: 1J-103 L1 Design: 1J-103 L1 (wp06) LI N Sperry Drilling Serviced Well Plan 1J-103 -Slot 1J-103 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +EI-W Rate Rate Rate TFO (ft) (°) (') (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 5,954.96 80.00 169.33 3,647.66 58.85 3,061.44 0.00 0.00 0.00 0.00 5,966.96 81.91 169.33 3,649.54 47.20 3,063.63 15.90 15.90 0.00 0.00 5,996.96 81.91 169.33 3,653.77 18.01 3,069.13 0.00 0.00 0.00 0.00 6,171.81 92.97 171.94 3,661.57 -154.06 3,097.49 6.50 6.33 1.49 13.32 6,277.00 92.97 171.94 3,656.11 -258.07 3,112.23 0.00 0.00 0.00 0.00 6,353.31 90.20 174.56 3,654.00 -333.80 3,121.19 5.00 -3.63 3.44 136.55 6,488.48 90.62 178.59 3,653.03 -468.69 3,129.26 3.00 0.31 2.98 83.97 7,041.04 90.62 178.59 3,647.00 -1,021.06 3,142.83 0.00 0.00 0.00 0.00 7,072.93 91.44 179.09 3,646.42 -1,052.94 3,143.47 3.00 2.57 1.55 31.13 7,288.21 91.44 179.09 3,641.00 -1,268.12 3,146.90 0.00 0.00 0.00 0.00 7,316.34 91.99 179.73 3,640.16 -1,296.23 3,147.19 3.00 1.93 2.30 50.00 7,436.32 91.99 179.73 3,636.00 -1,416.14 3,147.75 0.00 0.00 0.00 0.00 7,451.19 91.72 179.38 3,635.52 -1,431.01 3,147.86 3.00 -1.81 -2.40 -127.00 8,135.83 91.72 179.38 3,615.00 -2,115.29 3,155.29 0.00 0.00 0.00 0.00 8,175.16 90.65 179.88 3,614.19 -2,154.61 3,155.54 3.00 -2.71 1.28 154.68 9,336.09 90.65 179.88 3,601.00 -3,315.46 3,157.93 0.00 0.00 0.00 0.00 9,349.02 90.27 179.84 3,600.90 -3,328.40 3,157.96 3.00 -2.98 -0.36 -173.09 10,836.33 90.27 179.84 3,594.00 -4,815.69 3,162.22 0.00 0.00 0.00 0.00 10,870.92 89.23 179.77 3,594.15 -4,850.28 3,162.34 3.00 -2.99 -0.18 -176.63 11,008.37 89.23 179.77 3,596.00 -4,987.71 3,162.88 0.00 0.00 0.00 0.00 7/26/2006 9:55:57AM Page 3 of 8 COMPASS 2003.11 Build 50 at 1 >,.,. / • Halliburton Energy Services ConocoPhillips Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska, lnc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1 J-103 Survey Calculation Method: Wellbore: 1J-103 L1 Design: 1J-103 L1 (wp06) Planned Survey 1J-103 L1 (wp06) ~ T Sp®rry Drilling S®rvicea Well Plan 1 J-103 -Slot 1 J-103 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) 1,655.78 47.14 45.00 1,518.00 1,409.00 346.97 346.97 5,946,387.03 Base Perm 1,871.03 50.39 46.00 1,663.00 1,554.00 459.11 459.75 5,946,500.04 T3 2,367.82 55.60 58.03 1,955.00 1,846.00 722.31 762.47 5,946,765.57 K15 2,880.89 56.00 60.00 2,242.00 2,133.00 935.36 1,130.53 5,946,981.47 T3 + 550 -10 3/4" 4,022.47 54.57 93.33 2,892.00 2,783.00 1,284.43 1,984.30 5,947,337.15 Ugnu C 4,507.13 60.71 121.19 3,155.00 3,046.00 1,161.69 2,367.94 5,947,217.42 Ugnu B 4,652.40 63.10 127.45 3,223.00 3,114.00 1,088.31 2,473.16 5,947,144.88 Ugnu A 4,949.82 64.77 134.14 3,356.00 3,247.00 921.49 2,680.14 5,946,979.69 K13 5,670.64 77.00 165.03 3,587.00 3,478.00 328.27 2,994.34 5,946,389.00 WSAK D 5,817.34 77.00 165.03 3,620.00 3,511.00 190.19 3,031.26 5,946,251.22 WEAK C 5,939.92 79.65 168.84 3,645.00 3,536.00 73.39 3,058.63 5,946,134.65 WSAK B 5,954.96 80.00 169.33 3,647.66 3,538.66 58.85 3,061.44 5,946,120.13 L1 : TOW 7 5/8" - 5955' Mb, 3648' TVD - 2287' FSL 8: 621' FWL - 7 518" TOW ' 5,966.96 81.91 169.33 3,649.54 3,540.54 47.20 3,063.63 5,946,108.51 L1 : Btm of Window - 5967' MD, 3650' TVD 5,996.96 81.91 169.33 3,653.77 3,544.77 18.01 3,069.13 5,946,079.36 L1 : Begin Dir ~ 6.5°/100', TFO 13.3°: 5996.96' MD, 3653.77' TVD 6,000.00 82.10 169.38 3,654.19 3,545.19 15.06 3,069.68 5,946,076.41 6,100.00 88.43 170.87 3,662.44 3,553.44 -83.07 3,086.76 5,945,978.43 6,171.81 92.97 171.94 3,661.57 3,552.57 -154.06 3,097.49 5,945,907.54 L1 : Sail ~ 92.97°: 6172' MD, 3852' TVD 6,200.00 92.97 171.94 3,660.10 3,551.10 -181.93 3,101.44 5,945,879.70 6,277.00 92.97 171.94 3,656.11 3,547.11 -258.07 3,112.23 5,945,803.65 L1 : Continu e Dir ~ 5°/100', TFO 136.55°: 6277' MD, 3656' TVD 6,300.00 92.14 172.73 3,655.09 3,546.09 -280.83 3,115.29 5,945,780.91 6,353.31 90.20 174.56 3,654.00 3,545.00 -333.80 3,121.19 5,945,728.00 L1 : Continu e Dir ~ 3°/700', TFO 83.97°: 6353' MD, 3654' TVD - 1J-1 03 L1 T1 (wp06) 6,400.00 90.35 175.95 3,653.78 3,544.78 -380.33 3,125.05 5,945,681.51 6,488.48 90.62 178.59 3,653.03 3,544.03 -468.69 3,129.26 5,945,593.19 L1 : Sail ~ 90.62°: 6488' MD, 3653' TVD Map Fasting (ft) 559,110.82 559,222.71 559, 523.34 559,889.69 560,740.63 561.125.18 DLSEV Vert Section (°I100ft) (ft) 0.00 -346.97 1.55 -459.11 2.20 -722.31 0.33 -935.36 2.39 -1,284.43 5.00 -1,161.69 561,230. 96 4.14 -1,088.31 561,439. 21 2.10 -921.49 561,758. 00 4.38 -328.27 561,796. 00 0.00 -190.19 561,824. 27 3.73 -73.39 561,827 .19 4.00 -58.85 561,829 .47 15.90 -47.20 561,835 .20 0.00 -18.01 561,835 .78 6.45 -15.06 561,853 .62 6.50 83.07 561,864 .90 6.50 154.06 561,869 .07 0.00 181.93 561,880 .45 0.00 258.07 561,883 .69 4.99 280.83 561,890 .00 5.00 333.80 561,894 .22 3.00 380.33 561.899 .12 3.00 468.69 7/26/2006 9:55:57AM Page 4 of 8 ~~'~~~ ~` COMPASS 2003.11 Build 50 ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska, Inc. Project: KuparukRiver Unit Site: Kuparuk 1J Pad Well: Plan 1J-103 Wellbore: 1 J-103 L1 Design: 1J-103 L1 (wp06) Planned Survey 1J-103 L1 (wp08) Halliburton Energy Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: MD Inclination Azimuth TVD SSTVD +N/-S +E/-W (ft) (°) (°) (ft) (ft) (ft) (ft) 6,500.00 90.62 178.59 3,652.90 3,543.90 -480.21 3,129.54 6,600.00 90.62 178.59 3,651.81 3,542.81 -580.18 3,132.00 6,700.00 90.62 178.59 3,650.72 3,541.72 -680.14 3,134.45 6,800.00 90.62 178.59 3,649.63 3,540.63 -780.10 3,136.91 6,900.00 90.62 178.59 3,648.54 3,539.54 -880.07 3,139.37 7,000.00 90.62 178.59 3,647.45 3,538.45 -980.03 3,141.82 7,041.04 90.62 178.59 3,647.00 3,538.00 -1,021.06 3,142.83 L1 : Continue Dir @ 3°1100', TFO 31.13°: 7041' MD, 3647' TVD -1J-1 03 L1 T2 (wp06) 7,072.93 91.44 179.09 3,646.42 3,537.42 -1,052.94 3,143.47 L1 : Sail @ 9 1.44°: 7073' MD, 3546' TVD 7,100.00 91.44 179.09 3,645.74 3,536.74 -1,079.99 3,143.91 7,200.00 91.44 179.09 3,643.22 3,534.22 -1,179.95 3,145.50 7,288.21 91.44 179.09 3,641.00 3,532.00 -1,268.12 3,146.90 L1 : Continue Dir @ 3°1100', TFO 50°: 7288' MD, 3641 ' TVD - 1J-103 L1 T3 (wp06) 7,300.00 91.67 179.36 3,640.68 3,531.68 -1,279.90 3,147.06 7,316.34 91.99 179.73 3,640.16 3,531.16 -1,296.23 3,147.19 L1 : Sail @ 9 1.99°: 7316' MD, 3640' TVD 7,400.00 91.99 179.73 3,637.26 3,528.26 -1,379.84 3,147.58 7,436.32 91.99 179.73 3,636.00 3,527.00 -1,416.14 3,147.75 L1 : Continu e Dir ~ 3°1100', TFO -127.00°: 7436' MD, 3636' TVD - 1J -103 L1 T4 (wp06) 7,451.19 91.72 179.38 3,635.52 3,526.52 -1,431.01 3,147.86 L1 : Sail @ 9 1.72°: 7451' MD, 3636' TVD 7,500.00 91.72 179.38 3,634.06 3,525.06 -1,479.79 3,148.39 7,600.00 91.72 179.38 3,631.06 3,522.06 -1,579.74 3,149.48 7,700.00 91.72 179.38 3,628.06 3,519.06 -1,679.69 3,150.56 7,800.00 91.72 179.38 3,625.07 3,516.07 -1,779.64 3,151.65 7,900.00 91.72 179.38 3,622.07 3,513.07 -1,879.59 3,152.73 8,000.00 91.72 179.38 3,619.07 3,510.07 -1,979.54 3,153.82 8,100.00 91.72 179.38 3,616.07 3,507.07 -2,079.48 3,154.90 8,135.83 91.72 179.38 3,615.00 3,506.00 -2,115.29 3,155.29 L1 : Continue Dir @ 3°/100', TFO 154.68°: 8136' MD, 3615' TVD -1J-103 L1 T5 (wp06) 8,175.16 90.65 179.88 3,614.19 3,505.19 -2,154.61 3,155.54 L1 : Sail ~ 90.55°: 8175' MD, 3614 TVD 8,200.00 90.65 179.88 3,613.90 3,504.90 -2,179.45 3,155.60 8,300.00 90.65 179.88 3,612.77 3,503.77 -2,279.45 3,155.80 8,400.00 90.65 179.88 3,611.63 3,502.63 -2,379.44 3,156.01 8,500.00 90.65 179.88 3,610.50 3,501.50 -2,479.43 3,156.21 8,600.00 90.65 179.88 3,609.36 3,500.36 -2,579.43 3,156.42 8,700.00 90.65 179.88 3,608.23 3,499.23 -2,679.42 3,156.62 8,800.00 90.65 179.88 3,607.09 3,498.09 -2,779.41 3,156.83 8,900.00 90.65 179.88 3,605.95 3,496.95 -2,879.41 3,157.03 9,000.00 90.65 179.88 3,604.82 3,495.82 -2,979.40 3,157.24 9,100.00 90.65 179.88 3,603.68 3,494.68 -3,079.39 3,157.44 9,200.00 90.65 179.88 3,602.55 3,493.55 -3,179.39 3,157.65 9,300.00 90.65 179.88 3,601.41 3,492.41 -3,279.38 3,157.85 Sperry Drilling Services Well Plan 1 J-103 -Slot 1 J-103 Plan RKB @ 109;OOft (Dayon 141 (28+81)) Plan RKB @ 109.OOft(Doyon 141 (28+81)) True Minimum Curvature Map Map Northing Easting DLSEV Vert Section (ft) (ftl (°/100ft) (ft) 5,945,581.67 561,899.49 0.00 480.21 5,945,481.74 561,902.73 0.00 580.18 5,945,381.81 561,905.97 0.00 680.14 5,945,281.87 561,909.20 0.00 780.10 5,945,181.94 561,912.44 D.00 880.07 5,945,082.01 561,915.67 0.00 980.03 5,945,041.00 561,917.00 0.00 1,021.06 5,945,009.13 561,917.89 3.00 1,052.94 5,944,982.08 561,918.54 0.00 1,079.99 5,944,882.15 561,920.91 0.00 1,179.95 5,944,794.00 561,923.00 0.00 1,268.12 5,944,782.22 561,923.25 2.99 1,279.90 5,944,765.89 561,923.51 3.01 1,296.23 5,944,682.29 561,924.55 0.00 1,379.84 5,944,646.00 561,925.00 0.00 1,416.14 5,944,631.14 561,925.23 3.00 1,431.01 5,944,582.37 561,926.14 0.00 1,479.79 5,944,482.44 561,928.01 0.00 1,579.74 5,944,382.51 561,929.87 0.00 1,679.69 5,944,282.58 561,931.74 0.00 1,779.64 5,944,182.66 561,933.60 0.00 1,879.59 5,944,082.73 561,935.47 0.00 1,979.54 5,943,982.80 561,937.33 0.00 2,079.48 5,943,947.00 561,938.00 0.00 2,115.29 5,943,907.69 561,938.56 3.00 2,154.61 5,943,882.85 561,938.81 0.00 2,179.45 5,943,782.87 561,939.79 0.00 2,279.45 5,943,682.89 561,940.78 0.00 2,379.44 5,943,582.91 561,941.76 0.00 2,479.43 5,943,482.93 561,942.75 0.00 2,579.43 5,943,382.95 561,943.73 0.00 2,679.42 5,943,282.97 561,944.72 0.00 2,779.41 5,943,182.99 561,945.70 0.00 2,879.41 5,943,083.02 561,946.69 0.00 2,979.40 5,942,983.04 561,947.67 0.00 3,079.39 5,942,883.06 561,948.66 0.00 3,179.39 5,942,783.08 561,949.64 0.00 3,279.38 7/26/2006 9:55:57AM Page 5 of 8 COMPASS 2003.11 Build 50 ~ ~ / Halliburton Energy Services L4+~R Conoco Phillips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-103 - SIOt 1J-103 Company: ConocoPhillips Alaska, Inc. ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81 p Project: Kuparuk River Unit MD Reference: Plan RKB @ t09:00ft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Wellbore: 1J-103 L1 Design: 1J-103 L1 (wp06) Planned Survey 1J-103 L1 (wp06) Map Map MD Inclination Azimuth ND SSND +N/S +EI-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ftl (ftl (°/100ft) (ft) 9,336.09 90.65 179.88 3,601.00 3,492.00 -3,315.46 3,157.93 5,942,747.00 561,950.00 0.00 3,315.46 L1 : Continue Dir @ 3°/100', TFO -173.09 °: 9336' MD, 3601' ND - iJ -103 L1 T6 (wp06) 9,349.02 90.27 179.84 3,600.90 3,491.90 -3,328.40 3,157.96 5,942,734.07 561,950.13 3.00 3,328.40 L1 : Sail @ 90.27°: 9349' MD, 36001' ND 9,400.00 90.27 179.84 3,600.66 3,491.66 -3,379.38 3,158.10 5,942,683.10 561,950.68 0.00 3,379.38 9,500.00 90.27 179.84 3,600.20 3,491.20 -3,479.38 3,158.39 5,942,583.11 561,951.74 0.00 3,479.38 9,600.00 90.27 179.84 3,599.73 3,490.73 -3,579.37 3,158.68 5,942,483.13 561,952.81 0.00 3,579.37 9,700.00 90.27 179.84 3,599.27 3,490.27 -3,679.37 3,158.96 5,942,383.15 561,953.88 0.00 3,679.37 9,800.00 90.27 179.84 3,598.81 3,489.81 -3,779.37 3,159.25 5,942,283.16 561,954.94 0.00 3,779.37 9,900.00 90.27 179.84 3,598.34 3,489.34 -3,879.37 3,159.54 5,942,183.18 561,956.01 0.00 3,879.37 10,000.00 90.27 179.84 3,597.88 3,488.88 -3,979.37 3,159.82 5,942,083.19 561,957.08 0.00 3,979.37 10,100.00 90.27 179.84 3,597.41 3,488.41 -4,079.37 3,160.11 5,941,983.21 561,958.14 0.00 4,079.37 10,200.00 90.27 179.84 3,596.95 3,487.95 -4,179.37 3,160.39 5,941,883.23 561,959.21 0.00 4,179.37 10,300.00 90.27 179.84 3,596.49 3,487.49 -4,279.36 3,160.68 5,941,783.24 561,960.28 0.00 4,279.36 10,400.00 90.27 179.84 3,596.02 3,487.02 -4,379.36 3,160.97 5,941,683.26 561,961.35 0.00 4,379.36 10,500.00 90.27 179.84 3,595.56 3,486.56 -4,479.36 3,161.25 5,941,583.28 561,962.41 0.00 4,479.36 10,600.00 90.27 179.84 3,595.10 3,486.10 -4,579.36 3,161.54 5,941,483.29 561,963.48 0.00 4,579.36 10,700.00 90.27 179.84 3,594.63 3,485.63 -4,679.36 3,161.83 5,941,383.31 561,964.55 0.00 4,679.36 10,800.00 90.27 179.84 3,594.17 3,485.17 -4,779.36 3,162.11 5,941,283.33 561,965.61 0.00 4,779.36 10,836.33 90.27 179.84 3,594.00 3,485.00 -4,815.69 3,162.22 5,941,247.00 561,966.00 0.00 4,815.69 L1 : Conrtinue Dir @ 3°/100', TFO -176.63 °: 10836' MD, 3594' ND -1J-103 L1 T7 (wp06) 10,870.92 89.23 179.77 3,594.15 3,485.15 -4,850.28 3,162.34 5,941,212.42 561,966.39 3.00 4,850.28 L1 : Sail @ $9.23°: 10871' MD, 3594' ND 10,900.00 89.23 179.77 3,594.54 3,485.54 -4,879.35 3,162.45 5,941,183.35 561,966.73 0.00 4,879.35 11,000.00 89.23 179.77 3,595.89 3,486.89 -4,979.34 3,162.84 5,941,083.37 561,967.90 0.00 4,979.34 11,008.37 89.23 179.77 3,596.00 3,487.00 -4,987.71 3,162.88 5,941,075.00 561,968.00 0.00 4,987.71 L1 : BHL @ 11008' MD, 3596' TVD - 2517' FSL & 717' • ' FWL - Sec01-T10N-R10E - 4 112" - 1J-103 L1 T8 (Toe) (wp06) 7/26/2006 9;55:57AM Page 6 of 8 COMPASS 2003.118ui1d 50 ~~~~~ ' ~ ~ " ' ' ~/ Halliburton Energy Services ~ ;' _ ' t ConocoP hillips Planning Report - Geographic Alaska Sperry Drilling Services Database: EDM 2003:11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-103 -Slot 1J-103 Company: ConocoPhillipsAlaska, inc. TVD Reference: Plan RKB @ 109. OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109. OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad- North Reference: True Well: Plan 1J-103 Survey Calculation Method: Minimum Curvatu re Wellbore: 1J-103 L1, Design: 1J-103 L1 (wp06) Geologic Targets 1J-103 L1 TVD Target Name +NI-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,641.00 1J-103 L1 T3 (wp06) -1,268.12 3,146.90 5,944,794.00 561,923.00 - Point 3,654.00 1J-103 L1 T1 (wp06) -333.80 3,121.19 5,945,728.00 561,890.00 - Point 3,636.00 1J-103 L1 T4 (wp06) -1,416.14 3,147.75 5,944,646.00 561,925.00 - Point 3,647.00 1J-103 L1 T2 (wp06) -1,021.06 3,142.83 5,945,041.00 561,917.00 - Point 3,594.00 1J-103 L1 T7 (wp06) -4,815.69 3,162.22 5,941,247.00 561,966.00 - Point 3,596.00 1J-103 L1 T8 (Toe) (wp06) -4,987.71 3,162.88 5,941,075.00 561,968.00 - Point 3,615.00 1J-103 L1 T5 (wp06) -2,115.29 3,155.29 5,943,947.00 561,938.00 - Point 3,601.00 1J-103 L1 T6 (wp06) -3,315.46 3,157.93 5,942,747.00 561,950.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 2,880.89 2,242.00 10-3/4 13-1/2 5,954.97 3,647.66 7-5/8 9-718 11,008.36 3,596.00 4-1/2 6-314 7/26/2008 9:55:57AM Page 7 of 8 COMPASS 2003.11 Build 50 w Cono Database: Company: Project: Site: Well: coPhillips Alaska EDM 2003.11 Single User Dt ConocoPhillips Alaska, Inc. Kuparuk River Unft Kuparuk 1 J `Pad Plan 1J-103 Halliburton Energy Services Planning Report -Geographic ~ Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: L Sperry Drilling Services Wellbore: 1J-103 L1 esign: 1 J- f 03 L1 (wp06) D Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ftl (°) (°) 1ft) (ft) (ft) Name 1,655.78 47.14 45.00 1,518.00 346.97 346.97 Base Perm 1,871.03 50.39 46.00 1,663.00 459.11 459.75 T3 2,367.82 55.60 58.03 1,955.00 722.31 762.47 K15 2,880.89 56.00 60.00 2,242.00 935.36 1,130.53 T3+550 4,022.47 54.57 93.33 2,892.00 1,284.43 1,984.30 Ugnu C 4,507.13 60.71 121.19 3,155.00 1,161.69 2,367.94 Ugnu B 4,652.40 63.10 127.45 3,223.00 1,088.31 2,473.16 Ugnu A 4,949.82 64.77 134.14 3,356.00 921.49 2,680.14 K13 5,670.64 77.00 165.03 3,587.00 328.27 2,994.34 WSAK D 5,817.34 77.00 165.03 3,620.00 190.19 3,031.26 WSAK C 5,939.92 79.65 168.84 3,645.00 73.39 3,058.63 WSAK B 7/26/2006 9:55:57AM Page 8 of 8 COMPASS 2003.11 Build 50 ConocoPhillips Alaska • ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-103 1 J-103 L1 1 J-103 L1 (wp06) Anticollision Report 26 July, 2006 ,~ ~ _ ~. Sperry Drilling Services OR16!^' SURVEV PROGRAM Date. 21NK.117-IITINI:INI:IN1 Validated: Ycs Version: Depth From Depth To Survcc/Plan T1rol 2%.1X1 O.W CILGYRO-SS NINL011 51]51.96 MWD+IFR-AK-CAZSC 5751!16 111NW.37 1J-1113 Ll (epU6) MN'UtIFR-AK-CAZSC ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 5954.96 To 15094.7 261 51 91 01 Maximum Range:1706.6 7 2 61 51 91 01 Reference: Plan: iJ-103 L1 (wp06) NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-103 Ground Level: 81.00 +N/-S +E/-W Nonhing Easting Latittude Longitude Slot 0.00 0.00 5946037.40 558766.60 70°15'47.418N 149°31'29.659W 1J-103 0 ----.. ---~- Travelling Cylinder Azimuth (TFO+AZI) (°~ vs Centre to Centre Separation ~ 1511 ft/ink REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-101- Slot iJ-103, True North Vertical (ND) Reference: Plan RKB ~ 109.OOD (Doyon 141 (28+81)) Section (VS) Reference: Slot -1J-103(O.OON, O.OOE) Measured Depth Reference: Plan RKB ~ 109.OOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature a From Colour To Mf 0 250 250 500 500 750 750 -. _.. .... ~_ 1000 1000 1250 1250 1500 1500 - 1750 1750 2000 2000 2250 2250 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 sooo sooo sooo z7o so sooD loooo looo0 lzaoo _ 1J-14 ConocoPhillips Alaska, Inc. Drilling & Wells West Sak Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Ertor Surtace: Elliptical Conic Warning Method: Rules Based s« 6v Av Tw +w-s «-w aro Tr:< vs« r4rB<1 1 5951.% 00.00 169.]] )fid166 58.85 ]%1.46 0.00 2 6%5.% 01.91 169.33 ]64960 61.20 3%3.63 16.% 0.00 601.% 000 1).20 3 6995.% 81.91 169.1) 3651 )T 18.01 3069.1) 0.00 6 61)1 81 929) 1]1.% 3661ST -156.% 309)A9 6.50 000 -18.01 13.32 151.% 6 63]]00 92.9] 1]1.% 3656.11 -258.0] 3112.23 0.00 6 Bl5]J1 90.20 1]6% 3651.00 -)33.80 ]121.19 5.00 0.00 2%.Oi 1%.55 1)3.00 1J-10]L1 T110'W6l ] 6408.08 9062 1]8.59 365].0) 168.69 3129.35 300 B )D4104 90.62 1]8.69 )66].00 -103106 ]162.8] 0.00 83.9) 06869 0.00 1021.06 iJ-10]L1 T21wW61 9 >OT263 91.66 1]9.09 )60612 -105296 316].6] J.00 10 ]208.21 91.61 119.09 164100 -1268.11 3166.% 0.00 31.13 1052.91 0.00 1268.12 iJ-tOJ L1131wp061 11 )316.30 9t 99 115]3 )640.16 -12%.2] 316].19 1.00 12 ]638.]2 91.99 119 J3 3636.00 -161fi.14 316].16 000 50.00 12962] 0.00 141616 1J-1OJ L1 T6 M90fi) 13 ]651.19 91.]2 119]8 3535.52 -1631.01 )14].06 ]00 -12).00 14)1.01 16 01]5.8) 91.]2 1T9 ]e ]615.00 -1116.29 )165.29 000 15 01)6.16 9065 1)9.88 ]616.19 -2154.61 315556 ]00 000 2115.29 1J-103 L1 TS IwpOfil 151.68 2154.61 16 9]36.09 9065 1)9.% ]601.00 -3]15.46 315).9] 0.00 1] 9]4902 90.2] 1]9.81 3600.90 -)32060 315198 ].00 0.00 3315.46 1J-109 L1 Tfi l<TO61 -1)3.09 3328.90 1B 10836 J3 90.2] 1]9 84 3694.00 )81568 3182.22 0 00 19 1081092 89.23 1]9.T) 36%.16 1850.28 3162.34 J00 20110083] 89.23 1T9.)) )696.00 -098111 316288 0.00 0.00 4815.69 1J-10] L1 P (<NO61 -1]6.63 4850.28 O.OD 698).)1 1J-103 L1 TB IToe(IwpOe) 1so Travelling C~~linder Azimuth (TFO+AZI) (°J vs Centre to Centre Separation Plan 1J-135 (wp01)~ 180 • ll/' Halliburton Energy Services ConocoPh illips Anticollision Report Alaska Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O OOft North Reference: Reference Well: Plan 1J-103 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-103 L1 Database: Reference Design: 1J-103 L1 (wp08) Offset ND Reference: ~L~ T Sperry Driliing Services Wel I Plan 1 J-103 -.Slot 1 J-103 Plan RKB @ t09.00ft (Doyon 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81p True Minimum Curvature 1.00 sigma EDM 2003.1 Y Single User Db Offset Datum Reference 1J-103 L1 (wp06) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 5,954.96 to 11,008.37ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,298.04ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program From (ft) 28.00 800.00 5,954.96 Date 7/24/2006 To (ft) Survey (Wellbore) 0.00 1J-103 (wp06} (1J-103) 5,954.96 1J-103 (wp06) (1J-103) 11,008.37 1J-103 L1 (wp06) (1J-103 L1) Tool Name CB-GYRO-SS MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC Description Camera based gyro single shot MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/26/2006 10;17:21AM Page 2 of 4 COMPASS 2003.11 Build 50 ~~ a ~ • •p'~ Halliburton Energy Services ~ U a CQI~IQCQI'I . Il~~lp$ Anticollision Report Alaska Sperry Drilling Services Company: ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-103 -Slot 1J-103 Project: Kuparuk River Unit. TVD Reference: Plan RK8 @ 109:OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1 J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-103 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 1.00 sigma Reference Wellbore 1 J-103 L1 Database: EDM 2003.11 Single User Db Reference Design: 1 J-103 L1 (wp06) Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad. 1 J-03 - 1 J-03 - 1 J-03 Out of range 1J-14 - 1J-14 - 1J-14 9,525.74 6,075.00 231.78 172.68 81.86 Pass -Major Risk 1 J-152 - 1 J-152 - 1 J-152 Out of range 1 J-152 - 1 J-152 L1 - 1 J-152 L1 Out of range 1 J-152 - 1 J-152 L2 - 1 J-152 L2 Out of range 1J-152 - 1J-152 PB1 - 1J-152 PB1 Out of range 1 J-152 - 1 J-152 PB2 - 1 J-152 PB2 Out of range 1 J-154 - 1 J-154 - 1 J-154 Out of range 1 J-154 - 1 J-154 L1 - 1 J-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 P61 - 1J-159 L1 P61 Out of range 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 Out of range 1J-159 - 1J-159 L2 - 1J-159 L2 Out of range 1J-159 - 1J-159 PB1 - 1J-159 PB1 Out of range Plan 1J-102- 1J-102- 1J-102 (wp07) 5,974.18 4,799.98 1,195.59 108.65 1,095.15 Pass- Major Risk Plan 1J-102 - 1J-102 - 1J-102 Rig Surveys Out of range Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp07) 5,974.18 4,799.98 1,195.59 108.65 1,095.15 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp07) 5,974.18 4,799.98 1,195.59 108.65 1,095.15 Pass -Major Risk Plan 1J-103 - 1J-103 - 1J-103 (wp06) 5,974.99 5,975.00 0.47 3.25 -1.86 FAIL - No Errors Plan 1J-103 - 1J-103 L2 - 1J-103 L2 (wp06) 5,973.27 5,975.00 50.13 562.11 -159.25 FAIL- No Errors Plan 1J-105 - 1J-105 - 1J-105 (wp03) 6,450.55 7,325.00 1,233.96 123.77 1,126.81 Pass -Major Risk Plan 1J-105 - 1J-105 L1 - 1J-105 L1 (wp03) 10,605.49 11,533.66 1,250.03 241.07 1,010.90 Pass -Major Risk PIan1J-105-1J-105 L2-1J-105 L2(wp03) 10,566.82 11,489.11 1,250.74 241.69 1,009.97 Pass-Major Risk Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp02) Out of range Plan 1 J-109 -Plan 1 J-109 - 1 J-109 Project Ahead Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 Rig Surveys Out of range Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Out of range Plan 1J-115 -Plan 1J-115 - 1J-115 (wp05) 5,970.50 5,200.00 508.90 108.51 401.25 Pass -Major Risk Plan 1J-115 -Plan 1J-115 L1 - 1J-115 L1 (wp05) 5,970.50 5,200.00 508.90 108.51 401.25 Pass -Major Risk Plan 1J-115 -Plan 1J-115 L2 - 1J-115 L2 (wp05) 5,970.50 5,200.00 508.90 108.51 401.25 Pass -Major Risk Plan 1J-118 - 1J-118 - 1J-118 (wp03) 6,545.55 4,899.98 856.46 112.05 747.15 Pass -Major Risk Plan 1J-118 - 1J-118 L1 - 1J-118 L1 (wp03) 6,545.55 4,899.98 856.46 112.05 747.15 Pass -Major Risk Plan 1J-118 - 1J-118 L2 - 1J-118 L2 (wp03) 6,545.55 4,899.98 856.46 112.05 747.15 Pass -Major Risk Plan 1J-130 - 1J-130 - 1J-130 (wp02) 9,179.10 5,750.00 941.67 169.99 801.32 Pass -Major Risk Plan 1J-133 - D141 - 1J-133 - 1J-133 (wp06) 11,006.37 6,850.00 680.74 226.35 529.81 Pass -Major Risk Plan 1J-133 - D141 - 1J-133 L1 - 1J-133 L1 (wp06 11,006.37 6,850.00 680.74 226.36 529.82 Pass -Major Risk Plan 1 J-135 - 1 J-135 -Plan 1 J-135 (wp01) 10,997.34 6,700.00 311.01 225.76 182.78 Pass -Major Risk Plan 1 J-156 - 1 J-156 - 1 J-156 Rig Surveys Out of range Plan 1J-156 - 1J-156 L1 - 1J-156 L1 Out of range Plan 1J-156 - 1J-156 L1 P61 - 1J-156 L1 PB1 Out of range Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp05) Out of range Plan 1 J-156 - 1 J-156 L2 - 1 J-156 L2 Rig Surveys Out of range Plan 1 J-158 - 1 J-158 - 1 J-158 (wp03) Out of range Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI Out of range WSP-1 S -WSP-1 S -WSP-1 S Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/28/2006 10:17:21AM Page 3 of 4 COMPASS 2003.11 Buitd 50 ORIGINAL 1J-103Ll~rillin~ Hazards ~mmarv (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 ~ i ~ ~ 1J-103L1 Drilling Hazards Summary y ~ prepared by Shane Cloninger •.{ _ 5/12/2006 1:15 PM .....+ V ' ~i~ ~r 1 ~~ ~. [~r7 h f^ ~ w~ ~ ~ to ~ S ~ ` ~ 3 ~ >v '. ~' ~ o °n .~ '~ .. 7 r ? n ~ ,. 9 ` d '-' ... O W a Q~ ~~3 a= o~ :~~ R c;~ Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/z", 5,000 ksi Insulated Conductor Casing 20", 94#, K55 x 34", 0.312" WT L, +/- 30' MD 10-3/4", 45.5#, L-80, BTC, R3 @ 2,880' MD /2,242' TVD ~~ @ SG degrees TD 13-1/2" hole Top of Ognu C 4,022' MU / 2,892' TVD ~ Top of West Sak B (a7 5,955' bIU / 3,647' TVD -- -~ Lateral Entry Module # I (LEM), Baker, with seal bore and ZXP packer above. Tubing, 4-%" IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.SG2" "DB" nipple. Seal bore and ZXP packer for A2 liner +/- 90' below"B" window Top of West Sak A 6,805' MD / 3,790 TVD ~ 7-5/8", 29.7#, L-80, BTCM, R3 Csg @ G,805' MU / 3,790' TVD @ 85 degrees TD 9-7/8" hole Tubing String: 4-1/2", l2 G #, L-80, IBTM (1) Gas Lift Mandrel, CAMCO 4-1/2" x I" Model KhIBG w/ dwnmy valve @, one (1) set a 2,400' MD, 1,973' TVD. (l) Gas Lift Mandrel, CAMCO 4-l/2" x I" Model KMBG w/ dummy valve, (,c < 72 deg 5,300' MD, 3,489' TVD. Electric Submersible Pump, Centrilift 418 HP motor, with FC6000 wireline deployed pump. Bottom at 5,600' MD, 3,571 "I'VD 103 L2 "D" Sand Window @ 5,670' MD / 3,58T TVD 77 degrees "D" Liner, 4-1i2" I lb#, L80, BTC, R3 11-103 L2 (0.125" x 2.5" slots, 32 per fwt, 5.9° c open area) G-3/4" D sand lateral TD t 1,007' MD / 3,523' TVD Angle 88 degrees 103 LI "B" SandWindow @ 5,955' MD / ~,G47' TVD 80 degrees "B" Liner, 4-1/2", I LG#, L80, BTC, ]t3 (0.125" z 2.5" slots, 32 per foot, 5.9 % open area) ~ ~~ - ~~ 3 ~-1- AZ Sand Liner, 4-1/2", 1 LG#, L80, BTC, --R3 slotted, coaslrir torefor iso/ulion 1J-103 LI. G- 4" "B" sand lateral TD 11,00 ' MD / 3,59G' TVD Angle 89 degrees I1-103. G-3/4 AZ sand lateral TD 15,095' MD / 3,749' TVD Angle 89 degrees • • T~~SMITTA~ LETTER ~~ECKLIST WELL NAME K~~ ~"T ~~~ ~- PTV# Zvi - / / S" Development Service Exploratory Stratigraphi.c Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS i TEXT FOR APPROVAL LETTER j w'HAT j (OPTIONS) APPLIES I MULTI LATERAL i The permit is for a new wellbore segment of existing t j ~ ~ ~ welt t~i2lt; / ~- /h~ (If last two digits in Permit No. API number are ~ 2~ ^ ~l ~ API No. 50-UZ~ - 231 - bb, ' ~ ;between 60-69) j Production should continue to be reported as a function of the ;original API number stated above. ! 'PILOT HOLE j In accordance with 20 AAC 25.005(f), all records, data and logs ~ '' ! ,acquired for the pilot hole must be clearly differentiated in both ~ I ~ well name ( PH) and API number ~ i (50- - -) from records, data and logs I ~ acquired for well ;SPACING ~ The permit is approved subject to full compliance with 20 AAC ~ }EXCEPTION ~ 25.0>j. Approval to perforate and produce ! infect is contingent upon issuance of a conservation order approving a spacing ' i I I exception. assumes the j i liability of any protest to the spacing exception that may occur. ;DRY DITCH 1 All dry ditch sample sets submitted to the Commission must be in SAMPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j ~ ~ through target zones. i Please note the following special condition of this permit: ~ Non-Conventional ~ production or production testing of coal bed methane is not allowed i Well ~ for (name of welly until after (Com~anv Name) has designed and implemented. a water well testing program to provide baseline data ~ ~ on water quality and quantity. Company Name) must contact the ~ Commission to obtain advance approval of such water well testing Rev: t%'2.5!06 C:\jodyltransmitta!_checklist • • ~^ ~ N „ ; ~ i ~ , , 0 0 ~ ~ , a~ ~ d ° ~ , ~ o , o ~ ~ ~ ~ ~ M ~, ~, ~ ~, 3. o o ~ ~, 3' ~ ~~ rn r c, ~, ~, 3 ~ m~ -o c > L U ~ ~ O (6 ~ ~ ~ ~ ~ ~ ~ ~ f6 ~ ~ C ~ ~ ~ y, ~ ~ v w v. ~ a, o, °, m m~ D ~ O ~ uY ~ ~ d t' ` y o, a. a, `o. v ~ ~ vi' ~ L m. of ~ v o c O o' ' , ~ y ~ ~ fl, ~, a7 c' ~ Q ~, _ a N ~ ~ O = ~ ~ ~ ~ ~ ~ ~ ~ ~ (6 O N, ~ Or d N a O ~ m ~ co y. ~ ~ ~ ~ ~ t ~ Q. Q. ~ a. y, t 3. w -O, 0' p, _, p~ O, ~ ~ ~ a~ O, ~ _ ~ p~ _ L ' . ~~ ~ m a~, 3, ~ ~~ 3 ~ ~ ~ ~ ~ ~ ~ Q ° Z. ~ a~ ~ 3. ~ ~~ ~ ~ as ~~ 3 3 Q c , ~~ o ~ N' ~ ~ ~ ~ ~ ~ c `~ . ~ Y •v_a ° . m' W n`' ~ ~ ~ °~' `~' ~ ~ aL i m ~ 'o' ~ i o o o ° ~ v Z z ~ Y ~ 4 o ~ . 3. o ~ o a _ M, ~ ~ , , ~ c n, ~ °, o ~' r r ° ' ° ' ' ~, L N ~ Q O f0 m ° m N ~ v ~ c c r i c a~ ~ o, •° E 't >' v ~ r d ~ O N' ~ . j~ ~~ ~~ ~ , O. O' ~ ~~ O C~ ~ ~ ~ ~ ~ ~~ ~~ 'p~ ~, N, C~~ N, 4J~ N. ~ ~ L p ~ N, ~, ~ ~ ~ ~ ~ ~ ~, ~~ N, -~~ j i _ o' u~ a m N m. ~~ ~ ~, O, ~~ ~, ~ N N ~ ~ 0 d ~ ~ N V C ~ N t/l C m ~ v ' m' Y ~ . , f , ~ /7 ' c ' ~' o' ~~ 3. ' ~ , . o, ' ~ , L' ~ ca, m Z C7 m . f0 E; o, p ~ o 7 ~ a T ~ a N 0 D: ~ " N, . ~, ~ ~ ~ ~ ~, ~~ . 6' C, N' ~~ N~ ~, ~ d, L, ' U' a .. m Z N. O ~ ~ p, N, ~~ N• .1. ~ U' ~, ~ O' -, ~' O, O. Q ~ Q ~ O. ~~ f6 a ~ Q, ~ N, O. p- w ~ c6 cn I w n, ~ V, , ~' p., ~ , m' ' ~ _, Z' . y j ~ ~ H~ Q, N, y' N~ N~ y~ y1 NI yl N, N, N, N, N, N N ~ ~ NI N~ N N, N, N, N ~ Q, Q, Q, Q, ~ ~ ~ ~ Q, Q, Q, Q, O, N~ Q, N, ~ N. ~ fp Q, N, Q, N, fps tlA N~ N, N, N, tlA ~ N, O, Q, y~ y, N, N, ~ Q, Q, Q, O D. Z } ~ ~- ~ ~- } }; } } } } ~- Z Z Z Z Z Z Z Z Z Z >~ Z } Z ~ } ~- } } Z Z } ~- Z Z Z T , , O' - E. o~ ~ , , ~, ~~ ~ , ~ a i, ~ , . a o. C' C' ~ ~ O' Y ~ ~ o, D, ~ a~ ~ , ((a ~ ~ ~ 0, ~ ~ ~, ~ N, y~ N, ~ ~ a ~ d~ O. ~ ° ~ ~ O, W, ~ ~ d ° ~ ~ ~ ~ C, ~ ~ y •C, O N. ~ ~ p: ~ ~ N. ~ U. ~ ~ LLy ~~ ~ ~ N. ~1 Q lJ„~ ~ ~ i ~~ ~ N, d L, -O, O~ ¢~ N O ~ p O ~ ~ ~~ ~ ~ O O~ ~~ ~ ~ ~~ ~ r~ ~ ~ ~ ~ ~ ~ d T ~ ~ 7. N, ~ C, ~~ " N, C, a, 0 h' O. 7, p. ~ ~ Q ~~ N• f 6 C T N' N. ~ w ~ pp >i, "' O, N d N O` M. U N N. N c, O. - , QQ ~ 3' d'' a. N. N. ~ V N' p' N' f6' T O' a '"" O' ~2S ~~ ~~ N M' a' ~~ O N O N' ~ U _ _, 01 .o o, c. `, Z' w' ° ' c' v 3 3, ~, o o, an d U' o ° L ~ o. c. a~' m. c, y, °, d, , O, o, rn ~ ~' , °, Q' t, ' ~ ~, m c. of Y Z a E E a w a~ C E r C _ M' ° ca ~ N c c ~ o C ~ ~ a ~ •p-' c w C N ~ d N L a Q C c ~ ~ , . , o o v ° ~ ~ ~ , o' a' a ° ° ~ , , tn' N o o Q . ~ . 3' o ~' o ~ a , ,..~ ~} ~°` , °' c ~, ~, , , c' o Y, n., , . .°_, ~, •3 d' $ >~ w' '~' m' ~' >; ° •a~ '~n a ~ g c a~; ~ ~~ a ° ° ~ d a ~ ~ ~, m; °, ~ ; Y; m °, ° ° Z m -° ~ E ~ ~ ; ` a ~~ L ' ° Y m. o 5 N ~ Y ~ 0 , ~ i' ~, c r c a. f6. ' ' O O ~ ' L. t, L 7. p, f6' , C, a , , ' ' ' p, ' , o' w~ N, .-, N, ' , m , m ' v, 3 p. ~, . CI Q • • ~ , 7 (6 .. p. . O. ~ C; ~ i a ~ ~ a. ~~ m' ~ ~ ` . a N' ° ' ' O p N m' N M ~ N~ ~~ v °~ ~ y N~ N O d 3 °' O C ' a m a~ ~ `o w o fn a a a, N N, ; N 'a a a 6i 3; 3, a~ > a a m, N ~ ~' a ? 3 , U. ~' o ~ ; O, s o ° o' ~ 4 d .Q = ~ O, of ~ 3, o L~ Z' w, (.~ a° _~ a. ° m i' ' ' ~, n°. ~, i' ° i' a o a `° E' ° o, °~ ~ ~ ~~ Y, a i ° , y, a' ~ ~ ° ~ ~ o ~. d ~ N, ~, d ' N, d d ' d VA N~ , N. ~ , G U. N. , 3' y. ~ C' ' ' o2S = r U. f6. ~ co of a~ ~, O. O, °~ °, d Q Vi, !n, (6 ~ r c, N, a 0) (6 f6 f0. , ' ° rn ~' o, o o m ~ ~ ~, O • T -° a ~ Z. c, ° N a' ~ O. ~ , L d p '°" ~ ~, ~ a d m. y, T N, a~, a~' ~ 3' ~~ a' or ~ ° ~ c c °* C a~' c ~ ~, ~ ~ a ~, ~ ~ ~ o' °°' o, ~ N >, v y, ii U m' ~ -~ a' a a, v. c, o, °, a, _o s. c, c. -p, L,, °, a~, c~, ~ N' •~, a~ m, > ca a a o ` .~ ~ w r, m' , 3, :d N w ~ o' °~ n, o ° c' o ~, m F... ~, c 3, ~ ~ ~, ~ d o ~ ~ E ~ ' a, y o. ~, _ -°, a„ - •-, u?, ~, ,~ ` a E _ c ~, ~, ~ f0, ° c, ~ Z O , ~ m' ~, ° ° ° ~ ° w O, o, o ~ ~' ~ ~ 3, rn ~ v , ~, ~, o u% ~ 3, y, ~ n • o. ~, i~ ui J U a~ €; w `° , a - -' - ~ m c`> ' °~ °~ °~ a`r ~ ~, c - 3, °i c °~' c ~ ~'', N ~-, ~ a~i `~ m ~' ° o a; a', o~ '`, ~ cLi °~ d ~ E ~ .N, s ~° m. o ~ c m. a i, d J °. c, °, v "= O ~ ~; ~' ~ ~ 4 d a~ m a; a; U O - ~ o ~' Q. 4.; Z; o, ° ~, ~ ~, cn U U U U ~, a, U Q c a, ~ •- D; - "--; Q O O, L, °° °° U ~; ~', ~' m ~ a q a~, a i; U U ; U U W d , , , . , , , , , , , , , , , , , , , , , V ~ r N M cr to GO I~ M O O N M r v u~ CO h r r o0 O) O N N N N M et N N ~ t0 t~ ao N N N N W O N M M N M ~ M M M M c0 M M I~ M M M W M U F- C o d O N ~ ~ R o p o Y O N ~ C V O O ~ O 1 6 ~ ~ N ~ 10 ~ O'N W fl R ~ M n ~ • ao (M r o ~ a c N N N ~ C7 E w o m c • w ~ o U ~ a E Q a~ Q U ~ w n Q ~ m a Q~ i (7 Wefl f-History Fife 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 12 16:20:32 2007 Reel Header Service name ........... ..LISTPE Date .....................07/04/12 Origin ................. ..STS Reel Name .............. ..UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments ............... ..STS LIS Writing Library Tape Header Service name ........... ..LISTPE Date ................... ..07/04/12 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 MWD RUN 2 JOB NUMBER: W-0004725792 LOGGING ENGINEER: T. CALVIN OPERATOR WITNESS: D. GLADDEN MWD RUN 10 JOB NUMBER: W-0004725792 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: G. WHITLOCK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services 1J-103 L1 500292331860 ConocoPhillips Alaska, Inc Sperry Drilling Services 12-APR-07 MWD RUN 8 MWD RUN 9 W-0004725792 W-0004725792 P. ORTH P. ORTH G. WHITLOCK G. WHITLOCK 35 11N l0E 2225 2441 109.70 81.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 6332.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE av~-~~s '~ >sz~s NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-103 L1PB1 WELLBORE AT 7185'MD/3639'TVD. 4. MWD RUNS 1,8 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED FOR RUN 1, AND ONLY SROP DATA ARE PRESENTED FOR RUN 8. 5. MWD RUNS 2,9,10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 9,10 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,8-10 REPRESENT WELL 1J-103 L1 WITH API#: 50-029-23318-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12444'MD/3650'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.......07/04/12 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 2889.0 12386.5 RPX 2910.0 12393.5 FET 2910.0 12393.5 RPS 2910.0 12393.5 RPD 2910.0 12393.5 RPM 2910.0 12393.5 ROP 2935.5 12444.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH S MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 8 MWD 9 MWD 10 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2889.0 6332.0 6332.5 6370.0 6370.0 7185.0 7185.5 12444.0 Data Format Specification Record Data Record Type ................ ..0 Data Specification Block Type.. ...0 Logging Direction ............... ..DOwn Optical log depth units......... ..Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .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 C~ 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 2889 12444 7666.5 19111 2889 12444 RPD MWD OHMM 1.56 2000 35.187 18968 2910 12393.5 RPM MWD OHMM 1.29 2000 29.4419 18968 2910 12393.5 RPS MWD OHMM 1 2000 29.3451 18968 2910 12393.5 RPX MWD OHMM 3.39 2000 28.5521 18968 2910 12393.5 FET MWD HOUR 0.14 267.16 1.5206 18968 2910 12393.5 GR MWD API 19.57 135.94 70.1983 18996 2889 12386.5 ROP MWD FT/H 0.13 527.52 195.243 19018 2935.5 12444 First Reading For Entire File..........2889 Last Reading For Entire File...........12444 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record C~ 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 2889.0 6332.0 RPM 2910.0 6332.0 RPS 2910.0 6332.0 RPD 2910.0 6332.0 FET 2910.0 6332.0 RPX 2910.0 6332.0 ROP 2935.5 6332.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6332.0 TOP LOG INTERVAL (FT) 2935.0 BOTTOM LOG INTERVAL (FT) 6332.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 84.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 78.8 MUD FILTRATE AT MT: 6.000 74.0 MUD CAKE AT MT: 4.000 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2889 6332 4610.5 6887 2889 6332 RPD MWD020 OHMM 1.56 2000 22.3953 6845 2910 6332 RPM MWD020 OHMM 1.29 1645.31 12.9399 6845 2910 6332 RPS MWD020 OHMM 1 180.57 12.2869 6845 2910 6332 RPX MWD020 OHMM 3.39 166.05 11.7376 6845 2910 6332 FET MWD020 HOUR 0.14 55.89 1.69896 6845 2910 6332 GR MWD020 API 19.57 123.41 75.2939 6887 2889 6332 ROP MWD020 FT/H 1.07 527.52 185.593 6794 2935.5 6332 First Reading For Entire File..........2889 Last Reading For Entire File...........6332 File Trailer Service name ............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/04/12 Maximum Physical Record. .65535 File Type ............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 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. BTT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6332.5 6370.0 LOG HEADER DATA DATE LOGGED: 30-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6370.0 TOP LOG INTERVAL (FT) 6332.0 BOTTOM LOG INTERVAL (FT) 6370.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 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: 81.9 81.9 TOOL NUMBER 6.750 6332.0 Mineral Oil Base 8.40 60.0 .0 23000 2.0 .000 .0 .000 87.8 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 MWD080 FT/H 4 1 68 4 2 Name Service Unit Min Max Mean Nsam DEPT FT 6332.5 6370 6351.25 76 ROP MWD080 FT/H 0.13 33.42 15.3386 76 First Reading For Entire File..... .....6332.5 Last Reading For Entire File...... .....6370 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 First Reading 6332.5 6332.5 Last Reading 6370 6370 Physical EOF ~ ~ File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6332.5 7185.0 FET 6332.5 7185.0 RPX 6332.5 7185.0 RPS 6332.5 7185.0 RPM 6332.5 7185.0 RPD 6332.5 7185.0 ROP 6370.5 7185.0 LOG HEADER DATA DATE LOGGED: 31-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7185.0 TOP LOG INTERVAL (FT) 6370.0 BOTTOM LOG INTERVAL (FT) 7185.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.9 MAXIMUM ANGLE: 95.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6332.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 20750 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 96.8 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: C Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6332.5 7185 6758.75 1706 6332.5 7185 RPD MWD090 OHMM 9.46 567.32 32.1245 1706 6332.5 7185 RPM MWD090 OHMM 9.16 95.31 29.6254 1706 6332.5 7185 RPS MWD090 OHMM 8.85 122.37 30.8114 1706 6332.5 7185 RPX MWD090 OHMM 8.44 1246.35 34.8083 1706 6332.5 7185 FET MWD090 HOUR 0.17 267.16 5.91648 1706 6332.5 7185 GR MWD090 API 36.57 97.23 65.6269 1706 6332.5 7185 ROP MWD090 FT/H 4.58 424.09 206 1630 6370.5 7185 First Reading For Entire File..........6332.5 Last Reading For Entire File...........7185 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name ........... ..STSLIB.005 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/12 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: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7185.5 12393.5 RPD 7185.5 12393.5 ROP 7185.5 12444.0 GR 7185.5 12386.5 RPM 7185.5 12393.`_ FET 7185.5 12393.E RPS 7185.5 12393.E LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 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: 03-JAN-07 Insite 66.37 Memory 12444.0 7185.0 12444.0 85.6 93.9 TOOL NUMBER 160788 156401 6.750 6332.0 Mineral Oil Base 8.40 80.0 .0 20750 3.4 .000 .0 .000 111.0 .000 .0 .000 .0 Data Format Specification Record Data Record Type ............. .... .0 Data Specification Block Type .....0 Logging Direction ............ .... .DOwn Optical log depth units...... .... .Feet Data Reference Point ......... .... .Undefined Frame Spacing ................ .... .60 .lIN Max frames per record ........ .... .Undefined Absent value ................. .... .-999 Depth Units .................. .... . Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7185.5 12444 9814.75 10518 7185.5 12444 RPD MWD100 OHMM 5.58 1641.71 44.094 10417 7185.5 12393.5 RPM MWD100 OHMM 5.3 2000 40.2553 10417 7185.5 12393.5 RPS MWD100 OHMM 5.13 2000 40.3139 10417 7185.5 12393.5 RPX MWD100 OHMM 4.94 2000 38.5763 10417 7185.5 12393.5 FET MWD100 HOUR 0.17 5.02 0.683475 10417 7185.5 12393.5 GR MWD100 API 35.77 135.94 67.5746 10403 7185.5 12386.5 ROP MWD100 FT/H 4.78 460.83 201.109 10518 7185.5 12444 First Reading For Entire File..........7185.5 Last Reading For Entire File...........12444 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/12 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/04/12 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 12 15:59:21 2007 Reel Header Service name .............LISTPE Date .....................07/04/12 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 .....................07/04/12 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-103 L1 PB1 API NUMBER: 500292331873 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 12-APR-07 JOB DATA MWD RUN 2 MWD RUN 8 MWD RUN 9 JOB NUMBER: W-0004725792 W-0004725792 W-0004725792 LOGGING ENGINEER: T. GALVIN P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2225 FEL: 2441 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.70 GROUND LEVEL: 81.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2925.0 2ND STRING 6.750 7.625 6332.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP c~ U CA - ! l S ~/~Z~S ~, • OF WHICH WAS AT 6332' MD/3667'TVD, WITHIN THE RUN 2 INTERVAL OF 1J-103 PB1. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 8. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED FOR RUN 1. 5. MWD RUNS 2,9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 9 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,8,9 REPRESENT WELL 1J-103 L1PB1 WITH API#: 50-029-23318-73. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7295'MD/3641'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.......07/04/12 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 2889.0 7237.5 FET 2910.0 7244.5 RPD 2910.0 7244.5 RPS 2910.0 7244.5 RPM 2910.0 7244.5 RPX 2910.0 7244.5 ROP 2935.5 7295.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD S MWD 9 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2889.0 6332.0 6332.5 6370.0 6370.0 7295.0 Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .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 2889 7295 5092 8813 2889 7295 RPD MWD OHMM 1.56 2000 24.6006 8670 2910 7244.5 RPM MWD OHMM 1.29 2000 17.0867 8670 2910 7244.5 RPS MWD OHMM 1 2000 16.759 8670 2910 7244.5 RPX MWD OHMM 3.39 1246.35 16.6188 8670 2910 7244.5 FET MWD HOUR 0.14 267.16 2.51393 8670 2910 7244.5 GR MWD API 19.57 123.41 73.2923 8698 2889 7237.5 ROP MWD FT/H 0.13 527.52 187.802 8720 2935.5 7295 First Reading For Entire File..........2889 Last Reading For Entire File...........7295 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name ............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/04/12 Maximum Physical Record. .65535 File Type ............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log he ader 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 2889.0 6332.0 FET 2910.0 6332.0 RPX 2910.0 6332.0 RPS 2910.0 6332.0 RPM 2910.0 6332.0 RPD 2910.0 6332.0 ROP 2935.5 6332.0 LOG HEADER DATA DATE LOGGED: 20-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6332.0 TOP LOG INTERVAL (FT) 2935.0 BOTTOM LOG INTERVAL (FT) 6332.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 84.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT): 2925.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 68.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .000 78.8 MUD FILTRATE AT MT: 6.000 74.0 MUD CAKE AT MT: 4.000 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2889 6332 4610.5 6887 2889 6332 RPD MWD020 OHMM 1.56 2000 22.3953 6845 2910 6332 RPM MWD020 OHMM 1.29 1645.31 12.9399 6845 2910 6332 RPS MWD020 OHMM 1 180.57 12.2869 6845 2910 6332 RPX MWD020 OHMM 3.39 166.05 11.7376 6845 2910 6332 FET MWD020 HOUR 0.14 55.89 1.69896 6845 2910 6332 GR MWD020 API 19.57 123.41 75.2939 6887 2889 6332 ROP MWD020 FT/H 1.07 527.52 185.593 6794 2935.5 6332 First Reading For En tire File.... ......2889 Last Reading For Ent ire File..... ......6332 File Trailer Service name ..... ........STSLI B.002 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......07/04 /12 Maximum Physical Record..65535 File Type ........ ........LO Next File Name... ........STSLI B.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6332.5 6370.0 LOG HEADER DATA DATE LOGGED: 30-DEC-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6370.0 TOP LOG INTERVAL (FT) 6332.0 BOTTOM LOG INTERVAL (FT) 6370.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.9 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 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: TOOL NUMBER 6.750 6332.0 Mineral Oil Base 8.40 60.0 .0 23000 2.0 .000 .0 .000 87.8 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 MWD080 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 6332.5 6370 6351.25 76 6332.5 ROP MWD080 FT/H 0.13 33.42 15.3386 76 6332.5 First Reading For Entire File..........6332.5 Last Reading For Entire File...........6370 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 6370 6370 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... • Version Number...........1.0.0 Date of Generation.......07/04/12 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6332.5 7244.5 RPD 6332.5 7244.5 GR 6332.5 7237.5 RPM 6332.5 7244.5 FET 6332.5 7244.5 RPS 6332.5 7244.5 ROP 6370.5 7295.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 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: 31-DEC-06 Insite 66.37 Memory 7295.0 6370.0 7295.0 81.9 95.2 TOOL NUMBER 160788 156401 6.750 6332.0 Mineral Oil Base 8.40 80.0 .0 20750 3.4 .000 .0 .000 96.8 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 • Logging Direction .................Down Optical log depth units.. .........Feet Data Reference Point ..... .........Undefined Frame Spacing .....................60 .lIN Max frames per record .... .........Undefined Absent value ......................-999 Depth Units .............. ......... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6332.5 7295 6813.75 1926 6332.5 7295 RPD MWD090 OHMM 9.46 567.32 32.8721 1825 6332.5 7244.5 RPM MWD090 OHMM 9.16 2000 32.6402 1825 6332.5 7244.5 RPS MWD090 OHMM 8.85 2000 33.5325 1825 6332.5 7244.5 RPX MWD090 OHMM 8.44 1246.35 34.927 1825 6332.5 7244.5 FET MWD090 HOUR 0.17 267.16 5.57059 1825 6332.5 7244.5 GR MWD090 API 36.57 97.23 65.6807 1811 6332.5 7237.5 ROP MWD090 FT/H 1.71 424.09 203 1850 6370.5 7295 First Reading For Entire File..........6332.5 Last Reading For Entire File...........7295 File Trailer Service name ........... ..STSLIB.004 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/04/12 Maximum Physical Record ..65535 File Type .............. ..LO Next File Name......... ..STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/04/12 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/04/12 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF • End Of LIS File